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Home My WebLink About193-154 Pages NOT Scanned in this Well History File XHVZE This page identifies those items that were not scanned during the initial scanning project. They are available in the original file and viewable by direct inspection. /f5-/5~ File Number of Well History File PAGES TO DELETE Complete RESCAN o Color items - Pages: o Grayscale, halftones, pictures, graphs, charts - Pages: o Poor Quality Original - Pages: o Other - Pages: DIGITAL D~ ~ Diskettes, NOp.- o Other, NolType OVERSIZED . 0 Logs of various kinds o Other COMMENTS: Scanned by: Bevert" Dian~athan Lowell Date~g' I~ ø; o TO RE-SCAN Notes: Re-Scanned by: Beverly Dianna Vincent Nathan Lowell Date: Is! ~ _ . Paper Preview 4~ ~.- ~ ,. _~ . _ rt___ ,~'~;,`~:~~~" ' " ~ % ? C ~~~ ~ ~! ~.. r _ ~ Add to Cart _ __. -- __. _.._ . _ i Search Results New Search ~ View Cart ~ "'~~' ~~~ `~`' Paper Number 116771-MS ~~~ ~~ ~ DOI What's this? 10.2118/116771-MS Title Prudhoe Bay Well P2-15 Surface Casing Failure Authors J. Anders, SPE, D. Cismoski, SPE, R. Daniel, SPE, A. Dube, SPE, H. Engel, SPE, A. Hughes, SPE, and T. Norene, SPE, BP Exploration (Alaska) Inc.; R. Hamiiton, FMC; and W. Mohr, Edison Welding Institute Source SPE Annual Technical Conference and Exhibition, 21-24 September 2008, Denver, Colorado, USA Copyright 2008. Society of Petroleum Engineers Preview Summary While pre-heating the surFace casing landing mandrel in preparation nf welding to repair a leak on Prudhoe Bay well P2-15, the wellhead suddenly and unexpectedly moved downward approximately 18 inches. This failure resulted in an injury and required a rig workover to repair the well. The wellhead was cut below the surface casing landing mandrel and sent to a company specializing in metallurgical analysis to determine the cause of movement. A se~tion of the surface casing was identified with reduced wall thickness due to drilling wear. As heat was applied to raise the wellhead to welding temperature, the reduced wall thickness section of the surface casing experienced a temperature increase greater than the design pre-heat temperature. This thin-walled section of the casing began losing tensile strength, eventuaNy resulting in the surFace casing collapsing inward and allowing the wellhead to rapidly subside. This paper discusses the causes of the failure and presents recommendations to prevent future faiiures of this type. Discussion o# Incident Prudhoe Bay well P2-15 is in WAG (wateralternating- gas) injection service. It was drilled in 1994 and completed using 10-3/4 inch surface casing and 20 inch conductor casing. In 2004, leakage from the lower connection of the surFace casing landing mandrel was identified. The well remained in injection service until September 2006, then was shut-in pending repair of the leak. . STATE OF ALASKA I ALASKA OIL AND GAS CONSERVATION COM SION APR 1 1 2007 WELL COMPLETION OR RECOMPLETION REPORT AND LOG k 0'1 & G C C ,. J\lãs 'a as ons. ommlsslon RECEIVED' . 1a, Well Status: DOil DGas D Plugged 181 Abandoned D Suspended DWAG 1 b. Well Class: 20AAC 25.105 20AAC 25.110 D Development D Exploratory DGINJ DWINJ D WDSPL No. of Completions Zero Other .,.--... D Stratigraphic 181 Service 2. Operator Name: 5. Date Comp., Susp., ortb:¡" 12. Permit to Drill Number BP Exploration (Alaska) Inc. 3/18/2007 -!-t,,1 193-154 307-008 3. Address: 6. Date Spudded If' 13. API Number P.O. Box 196612, Anchorage, Alaska 99519-6612 02/19/1994 50- 029-22409-00-00f 4a. Location of Well (Governmental Section): 7. Date 1.0. Reached 14. Well Name and Number: Surface: 03/05/1994 P2-15 21' FNL, 1171' FWL, SEC. 14, T12N, R14E, UM 8. KB Elevation (ft): 15. Field 1 Pool(s): Top of Productive Horizon: 1005' FSL, 4542' FWL, SEC. 02, T12N, R14E, UM ~ 47.5' Prudhoe Bay Field 1 Point Total Depth: 9. Plug Back Depth (MD+ TVD) Mcintyre Pool 1272' FSL, 4680' FWL, SEC. 02, T12N, R14E, UM . 12125· + 9211 Ft 4b. Location of Well (State Base Plane Coordinates): 10. Total Depth (MD+TVD) 16. Property Designation: Surface: x- 681407 y- 5998559 Zone- ASP4 12220 + 9278 Ft ADL 365548 TPI: x- 684616 y- 6004946 Zone- ASP4 11. Depth where SSSV set 17. Land Use Permit: Total Depth: x- 684748 y- 6005215 Zone- ASP4 N/A MD DYes 181 No 19. Water depth, if offshore 20. Thickness of Permafrost 18. Directional Survey N/A MSL 1750' (Approx.) . 21. Logs Run: GR 1 CNL 1 ZDL 1 DIFL 1 MWD 22. CASING, LINER AND CEMENTING RECORD CASING SETTING DEPTH MD SETTING DEPTH 'NO HOLE ÄMOUNT SIZE Wr. PER FT. GRADE Top BOTTOM Top BOTTOM SIZE CEMENTING.RECORD PULLED 20" 91.5# H-40 Surface 80' Surface 80' 30" 260 sx Arctic Set (ADDrox.) 10-3/4" 45.5# NT80LHE Surface 4380' Surface 3662' 13-1/2" 1326 sx Coldset III 354 sx Class 'G' 7-5/8 29.7# NT95HS Surface 1221 0' Surface 9271' 9-7/8" 506 sx Class 'G' 712 sx CIa!':!': 'G' 23. Perforations open to Production (MD + TVD of Top and 24. TUBING RECORD < Bottom Interval, Size and Number; if none, state "none"): SIZE DEPTH SET (MD) PACKER SET (MD) None 4-112", 12.6#, L-80 10610' - 11727' 11655' MD TVD MD TVD SCANNED APR 2 7 2007 25. ACID, FRACTURE, CEMENTSaUEEZÊ,eTC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED P&A Perfs wI 12.4 Bbls of Class 'G' 10575' Set EZSV (left running tool on) & Whipstock on top (TOW #1 at 10555') 1 0456' Set 2nd EZSV CIBP (TOW #2 at 10453') 26. PRODUCTION TEST Date First Production: Method of Operation (Flowing, Gas Lift, etc.): Not on Injection N/A Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAs-McF WATER-BBL CHOKE SIZE I GAS-OIL RATIO TEST PERIOD ... Flow Tubing Casing Pressure CALCULATED OIL -BBL GAs-McF WATER-BBL OIL GRAVITY-API (CORR) Press. 24-HoUR RATE+ 27. CORE DATA Brief ~escriptio~ of ~ithology, por~sity, f~actures, apparent dips and presence of oil, gas or water (attach separate s_~ry). Submit core chips; If none, state none. · ./ft,T't:. . f W>~ . ~1 . None . ~ Form 10-407 Revised 12/2003 CONTINUED ON REVERSE SIDE OR I GINA L RBDMSBFl APR 252007 ~(~\ 6 .. 28. GEOLOGIC MARKE 29. ORMATION TESTS NAME MD TVD Include and brie y summarize test results. List intervals tested, and attach detailed supporting data as necessary. If no tests were conducted, state "None". Top of Kuparuk 11788' 8968' None 30. List of Attachments: Summary of Pre-Rig Work and Daily Drilling Reports, Well Schematic Diagram 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed Terrie Hubble Title Technical Assistant Date DY/t / P2-15 Well Number 193-154 307-008 Permit No. I A roval No. Prepared By Name/Number: Drilling Engineer: Terrie Hubble, 564-4628 Phil Smith, 564-4897 INSTRUCTIONS GENERAL: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. ITEM 1a: Classification of Service Wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. ITEM 4b: TPI (Top of Producing Interval). ITEM 8: The Kelly Bushing elevation in feet above mean low low water. Use same as reference for depth measurements given in other spaces on this form and in any attachments. ITEM 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). ITEM 20: True vertical thickness. ITEM 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITEM 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). ITEM 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, or Other (explain). ITEM 27: If no cores taken, indicate "None". ITEM 29: List all test information. If none, state "None". Form 10-407 Revised 12/2003 Submit Original Only · Page 1 of 3 Digital Wellfile . Well Events for SurfaceWell - P2-15 Location: BP -> ALASKA -> GREATER PRUDHOE BAY -> GPMA -> P2 -> P2-15 Date Range: 18/Jan/2007 to 01/Mar/2007 Data Source(s): AWGRS Events Source Well AWGRS P2-15 AWGRS P2-15 AWGRS P2-15 AWGRS P2-15 AWGRS P2-15 AWGRS P2-15 AWGRS P2-15 Date 03/01/2007 02/28/2007 02/27/2007 02/26/2007 02/26/2007 02/26/2007 02/26/2007 AVVGRS P2-15 02/25/2007 AWGRS P2-15 02/24/2007 AWGRS P2-15 AWGRS P2-15 AWGRS P2-15 AWGRS P2-15 AWGR5 P2-15 02/24/2007 02/24/2007 02/23/2007 02/23/2007 02/22/2007 Description T/I/0=0/15/0+. Temp=SI. Continuous monitor on annulus bleeds. Bled lAP from 15 psi to 0 psi in 30 seconds. Marginal increase throughout day monitor. Continuous bleed on OAP, max pressure BUR .5 psi in 3 hrs. FWHP=0/3/0+. T/I/O = SSV/38/0. Temp=SI. (Monitor WHP's for Rig). lAP decreased 6 psi overnight from 44 psi to 38 psi. lAP decreased 16 psi in 1 hr from 34 psi to 18 psi. Tree cap bonnet appears to be leaking at flange. OAP increases an average of .5 psi every hr. Bled OAP to 0 psi every hr. T/I/O = SSV/15/0. T/I/O = SSV/63/0. Temp=SI. (Monitor WHP's for Rig). lAP decreased 19 psi to 44 psi over 12 hrs. OAP increased to 4.5 psi over 2 hr shut in. Bled OA to 0 psi. T/I/O = SSV/44/0. T/I/O=O/O/O Maintain open bleed on OA, MIT-IA @ 1500 psi. (PASSED) (Rig Prep) Pumped 1. 7 bbls. Amb. diesel down IA to pressure to 1500 psi., IA lost 20 psi. in 1st 15 min. and 20 psi. in 2nd 15 min. and 20 psi. in 3rd 15 min. with total of 60 psi.in 45 min. test. Bleed pressure back to 0 psi. Final WHP's 0/0/0 T/I/O = 1500/1500/0. Temp = SI. AL = SI. (Monitor WHP's for Rig). Start day monitor at 1900. Hot Oil on location performing CMIT TxlA at time of arrival. OAP BUR approx. 0.2 psi/hr. Final WHP's = SSV/O/O. T/I/O=SSV/O/O. PPPOT-T (PASS) (Pre- SC weld repair). FMC New Standard. Casing head: 10 3/4" x 13 5/8" 5m w/ (1) 2" FMC model 120 & (1) 2" CIW OA valves. Tubing head: 13 5/8" 5m x 13 5/8" 5m w/ (2) 2" FMC model 120 IA valves. Tubing head adapter: 13 5/8" 5m x 4 1/16" 5m. Tree: 4 1/16" 5m Cameron w/ Baker actuator. PPPOT-T: Sting into test void to check pressure (0 psi). Pump through test void until clean fluid was achieved. Pressured void to 5000 psi, found slight leak from threads of offside Alemite fitting, replaced fitting. Pressured void to 5000 psi for 30 min test, lost 150 psi in first 15 min, lost 50 psi in second 15 min (PASS). Bled void pressure to 0 psi. T/I/O = 0/0/.25 ( Surface Casing Repair) ( Pre RWO) CMIT - Tx IA ( PASS) to 1500 psi, MIT- T ( FAIL) to 1500 psi, MIT-IA (Failed) ( 2 attempts) to 1500 psi. Pressured up TBG w/0.5 bbis Diesel to 1500 psi, TBG lost 150 psi in 1st 15 min and 110 psi in 2nd 15 min for a total loss of 260 psi in 30 min test, Pressured up IA w/ 2.3 bbls Diesel to 1500 psi, IA lost 20 psi in 1st 15 min and 40 psi in 2nd 15 min for a total loss of 60 psi in 30 min test. Bleed All Pressures Back. Increase Tubing and IA pressures with 1.9 bbls diesel to 1500 psi, lost 20 psi in 1st 15 min, lost 0 psi in 2nd 15 min for total 1055 of 20 psi Bled back 1 bbl from TBG and bleed back,S bbl from IA , Final WHPs = 0/0/0 T/I/O = 7/0/0. Temp = 51. (Monitor WHP's for Rig). Start day monitor at 0800. IA on vac. OA on vac. Final WHP's = 7/vac/vac. T/I/O= 0/0/0 [Surface Casing leak] Assist With Cement Job. Pressure test all surface hardline to 4000 psi. Log for Schlumberger Cement Pump Truck. Pumped 4 bbls of 90* diesel down tubing & U-tubed to the IA. Freeze protected returns lines to open top tanks with 9 bbls neat methanol. FWP'S=vac/vac!vac RWO-Prep -**Balanced Cmt Plug**. MIRU DS Cement van. Circulate 590 bbls (94 deg F) 9.65 ppg NACL brine surface to surface through open GlM at 11597' md. Mix and pump on the fly 7 bbls of 11 ppg MudPush IIspacer, followed by 12.4 bbls of 13.8 ppg Class G extended cement, and 4 bbls tail spacer. Displace at 4.5 bpm w/ 9.65 ppg brine. LRS FP surface with 4 bbls diesel and U-tubed (surface is FP to 96'). Maximum pressure on OA during operation was 4.75 psig (No -leakage from wellhead). Cement in place at 2200 hrs. Sample at lab waiting on compressive strength before MIT-T and MIT-IA. ***Job complete.*** T/I/0=7/0+/0. Temp=SI. (Monitor WHP's for Rig). Start day monitor at 0800. OA increased 1.75 psi in 2 hr. , bled OA to 0 psi in 5 seconds. OA inreased 1.1 psi in 1 hr. bled IA to 0 psi in 1.5 min. Bled OA to 0 in 3 seconds. OA increased .75 psi in 1 hr. IA increased to 0+ in 1 hr. Bled IA to 0 psi in 1 min. Bled OA to 0 psi in 3 seconds. Started OA open bleed to bleed tank @ 1400 hrs. Cement crew on location. Final WHP's = 7/0/0 T/I/0=7/20/0. Temp=SI. Eval SC Leak. Bled lAP to 0 psi in 10 mins all gas, after IA bleed SC leak stopped. Installed tempary SC patch over leak point, no apparent leak at this time. Installed Well head surface casing support where conductor had been removed. Final WHPs 7/0/0. T/I/0=7/40/0. Temp=SI. Monitor WHP's for Rig. Insalled new gauge on IA. New gauge reads 20 psi. Casing leaks @ 20 drips per min. Final WHP's= 7/20/0. T/I/0=7/40/0. Temp=SI. Monitor WHPs for Rig. Surface casing leaking 20 drops per min. http://digitalwellfile.bpweb.bp.comIW ellEvents/Home/Default. aspx 4/11/2007 Digital Wellfile AWGRS P2-15 02/16/2007 AwGRS P2-15 02/10/2007 AWGRS P2-15 02/06/2007 AWGRS P2-15 02/04/2007 AWGRS P2-15 02/03/2007 AYif:Æ5 P2-15 02/03/2007 AWGRS P2-15 02/03/2007 AWGRS P2-15 02/02/2007 AWGRS P2-15 02/02/2007 AWGRS P2-15 01/30/2007 AWGRS P2-15 01/30/2007 AWGRS P2-15 01/29/2007 AWGRS P2-15 01/27/2007 AWGRS P2-15 01/26/2007 AWGRS P2-15 01/25/2007 . . Page 2 of 3 T/I/0=?/30/0. Temp=S1. Remove gravel from cellar,.1I Katch Kan. Remove 1 yard of gravel from cellar. Installed 20" Katch Kan with drip liner as secondary containment. Heater is on loctaion. T/I/0=30/30/0. S1. Eval (10 3/4 casing). Installed jewelry on OA and IA valves. Installed 3000# test gauge on IA. Left open to gauges. 10-3/4" surface casing threads are visible through OA valve. Tree well head repair: Asked to look and eval well for Drill site lead. Advised on way to release tension on tree and flowline for removal. Found bolting on tree also bent. Well head is leaning towards center of pad. ***Continued from 02-03-07 WSR*** Freeze protect tubing & IA (Determine source of OA leak & patch SC) - Pump 85 bbls 60/40 MW down IA taking returns up tubing thru jumper to flowline on well 14, Re Rig to pump down tubing taking returns up lA, Pump 30 bbls MW down tubing taking returns up IA thru jumper line to FL of well 14, Bleed WHP's to 0 psi (1.6 bbls) Final WHP's=O/O/O ***NOTE; All WH valves were left SI due to WH condition*** T/I/O=200/175/0 Freeze protect tubing & IA (Determine source of OA leak & patch SC) - Begin pumping MW down IA taking returns up tubing thru jumper to well 14 FL ***Continued on 02-04-07 WSR*** T/I/0=250/270/0. Temp= S1. Final prep for weld. Assist with weld (SC repair). Moved in to bleed WHP's and prep for weld post FB eire-out. Initial fluid levels; Tbg near surface, IA @ surface and OA FL @ 30'. Bled Tbg and lAP from 250/270 to 0 psi in 15 minutes (.54 bbls returned to slop tank). Displaced an additional 6.25 bbls from the Tbg and IA with N2. U- tubed Tbg and IA for 30 minutes while rigging up N2 for OA purge. WHP's= 210/210/0. Tbg FL @ 138' (2.1 bbls). IA FL @ 132' (3.5 bbls). Rigged down U-tube line and purged OA w/N2 for 60 minutes. Pre job safety meeting (pre-weld) held with all personnel involved with the on- site work. Welders moved in and set up there equipment for the weld and commenced to pre- heat the casing. "'4 minutes into the pre-heating operation, the well head quite suddenly dropped'" 18". All personell evacuated the well house and mustered at the Northeast edge of the pad. Operations, Wells Group Supervisors and Response personnel notified by the site champion. Once Operations and Supervision assessed the scene, the welding equipment and the outside N2 equipment were gathered up and removed from the site. All non essential personnel were released from the location. ***Continued from 02-02-07 WSR*** CMIT TxIA to 3500 psi, PASSED / Circ out (Determine source of OA leak & patch SC) - Pressure TxIA to 3560/3500 w/ 13.4 bbls meth, Start testing, 1st test T/I lost 20/0 psi in 15 min, T/I lost % psi in 2nd 15 min, PASSED, Bleed TxIAP to production Circ out - Pump 709 bbls SW down tubing taking returns up IA through jumper line to flowline on well 14, RD tubing, RU jumper ine, FP jumper line w/ 5 bbls meth, Water left @ surface on well Final WHP's=O/O/O ******NOTE; Well is not freeze protected****** T/I/0=700/60/40 CMIT TxIA to 3500 psi, INCOMPLETE (Determine source of OA leak & patch SC) - Pressure T/I to 3500/2840 psi w/ 8 bbls meth, Attempt to bleed TP to equalize Tx lAP, IA went on vac w/ 500 psi on tubing, Begin to u-tube TxIA to equalize TxIAP's ***Continued on 02-03-07 WSR*** T/I/O= SSV/50/0. Temp=S1. Prep for weld (SC Repair). IA FL @ surface. OA FL @ 30'. Fresh gravel added to cellar on 01-31-07. Cellar is 40" deep. Spotted heater to warm up well house prior to eire-out and weld (well house door secured open and DSO notified). Snow removal cleared the pad in the afternoon. All equipment staged and ready for repair work. ** CONT FROM 1-29-07 WSR** PULLED 1" BK-DGLV FROM STA 2 @ 11597' SLM. PULLED EMPTY C-SUB FROM 11674' SLM. ****NOTE:-n STA.# 2 LEFT EMPTY***** ** TURNED WELL OVER TO DSO, LEFT SHUT IN** (SSV,TRSSSV DUMPED) T/I/O=SSV/O/O. PPPOT-IC (PASS) (pre- SC weld repair). FMC New Standard. Casing head: 10 3/4" x 13 5/8" 5m w/ (1) 2" FMC model 120 & (1) 2" CIW OA valves. Tubing head: 135/8" 5m x 13 5/8" 5m w/ (2) 2" FMC model 120 IA valves. Tubing head adapter: 13 5/8" 5m x 4 1/16" 5m. Tree: 4 1/16" 5m Cameron w/ Backer actuator. PPPOT-IC: Stung into test void to check pressure (20 psi). Bled pressure to 0 psi. Pumped through void untill clean returns were achieved. Pressured void to 3500 psi for 30 min test, lost 100 psi in first 15 min, lost 50 psi in second 15 min (PASS). ***WELL S/I ON ARRIVAL, TRSSSV ,SSV DUMPED***{pre circ out} SET 4 1/2 WHIDDEN C- SUB @ 11674' SLM CURRENTLY ATTEMPTING TO PULL GLV FROM STA. # 2 @ 11597' SLM ** CONT ONTO 1-30-07 WSR** T/I/0=40/0/0. Temp=S1. SC Repair. TBGP increased 40 psi over night. Cleaned debris and black substance from SC and landing ring connection to expose leak point. Removed loose cement and gravel from cellar. Removed cement ring above exposed conductor pipe. T/I/O=O/O/O. Temp=S1. SC Repair. Bleed TBGP, lAP, OAP to 0 psi. Rig up Wachs window cutter, made two 24" vertical cuts on Conductor pipe. Rig up Wachs Split Frame Cutter, and cut and removed 24" section out of Conductor, dropped landing nipple. Inspected and took photos of SC leak. Final WHPs 0/0/0. T/I/0=330/0/10. Temp=S1. SC Repair Project. TBG FL near surface. Bled TBGP from 330 psi http://digitalwellfile.bpweb.bp.comIW ellEvents/Home/Default.aspx 4/11/2007 Digital Wellfile AJP1GRS P2-15 01/23/2007 AWGRS P2-15 01/22/2007 AWGRS P2-15 01/21/2007 AWGJ~.S P2-15 01/20/2007 AWGRS P2-15 01/20/2007 AWGR5 P2-15 01/19/2007 AWGRS P2-15 01/19/2007 AWGRS P2-15 01/18/2007 AWGRS P2-15 01/18/2007 . Page 3 of3 to 0 psi in 30 mins to bleed trailer(fluid & gas mix). B.OAP to 0 psi in 5 mins. Spot up equiptment for Conductor cut tomorrow. ** CONT FROM 1-22-07 WSR** (surf csg repair) BAILED FILL OUT OF PLUG BODY. PULLED 4.5 PXN PLUG BODY BRUSHED X NIPPLE @ 11684' SLM SET 4.5 PX PLUG BODY @ l1,689'MD (l1,684'SLM) . SET PRONG ( 1 3/4" FN, 1 7/8" BODY, 96" OAL) @ 11681' SLM. MAX PSI WHEN SET= 750 PSI. BLED TBG TO 250 FROM 750, GOOD TEST. ** TURNED WELL OVER TO DSO, LEFT SHUT IN** ***WELL S/I ON ARRIVAL*** (surf casing repair) PULLED P-PRONG FROM 11698' SLM. UNABLE TO LATCH PLUG BODY @ 11700' SLM. CURRENTLY BAILING SCHMOO W/ 10' x 3" PUMP BAILER @ 11702' SLM ** CaNT ONTO 1-23-07 WSR** T/I/0=830/0/0. Temp=SI. SC RepaTBG FL @ surface. Bleed TBGP from 830 psi to 400 psi in 15 mins to production on well P2-14, TBGP pressure would not bleed off any lower. 51 TBG bleed, monitor for 15 mins, TBGP increased 400 psi. Removed 2 yards off cement from cellar. Final WHPs 800/0/0. T/I/0=860/0+/30. Temp=SI. SC Repair. TBG FL near surface. Bled TBGP from 860 psi to 400 psi to production on well P2-14 for 2.5 hrs. At 400 psi TBGP would not drop any lower (all fluid). 51 TBG bleed and monitor for 15 mins, TBGP increased 430 psi. OA FL near surface. Bled OAP from 30 psi to 0 psi in 3 mins. Note: Flow line has blind installed. Flushed conductor w/water to remove any residuals. Final WHPs 820/0+/0+. **** CONTINUE FROM 1/19/07 *** BLEED TUBING TO 300 PSI, RIG DOWN. **** WELL LEFT SHUT IN AND TURNED OVER TO DSO *** T/I/O = 1100/50/0 ( Continued from 1/18/07) . Assist Slickline, Pump as Directed. Pumped 23 bbls Diesel to free tool. Brush-n-Flush tubing with 230 bbls of 180* diesel. MIT- TBG to 3000 psi (PASSED). Pumped 2 bbls to reach test pressure. TBG lost 100 psi in 1st 15 min and 40 psi in 2nd 15 min, for a total loss of 140 psi in 30 min test. Bleed back pressure. Final WHPs 800/0/0 **** CONTINUE FROM 01/18/06 *** LRS PUMPED 230 BBLS. DIESEL, BRUSHED WITH A 3.805 G. RING WITH 4.5 B.L.B TO XN @ 11694' SLM . SET 4.5 PXN PLUG @ 11,686' SLM. (4 EA. 1/4" EQ. PORTS 96" * 1 7/8" P-PRONG 1 3/4" FN) . MIT TUBING TO 3000 PSI PASSED. *** CONTINUED WSR ON 1/20/07 *** T/I/O = 850/50/0 Assist Slickline, Pump as Directed. Pumped 3 bbls Meth, 9 bbls Diesel Down TBG ( Continued n 1/19/07 WSR) **** WELL SHUT IN ON ARRIVAL *** RUN 3.77' SWEDGE, 4.5" BRUSH TO 11498' SLM (XN - NIPPLE). HUNG UP @ 11516' SLM W/ 8' * 2 1/8" STEM OJ, LSSJ, 4 1/2 X-LINE ANS 4 1/2 PXN PLUG BODY, WORK TOOL TO 11,530' SLM . *** CONTINUE TO 01/19/07 *** http://digitalwellfile.bpweb.bp.com/W ellEvents/Home/Default.aspx 4/11/2007 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: P2-15 P2-15 REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 7ES Start: 2/28/2007 Rig Release: 4/7/2007 Rig Number: Spud Date: 2/19/1994 End: 4/7/2007 311/2007 09:00 - 09:30 0.50 MOB P PRE Prep rig floor for laying down derrick 09:30 - 10:30 1.00 MOB P PRE Lay down derrick 10:30 - 15:00 4.50 MOB P PRE Prepare pit module for move. Disconnect electrical from mechanic shop, camp and connexs. Break service lines from substructure to pit module. 15:00 - 20:00 5.00 MOB P PRE Move Camp and Pits from W-Pad to P2-15. Stage pits on P2-15, spot camp and shop 20:00 - 00:00 4.00 MOB P PRE Move Sub off W-204 and stage on Pad. 3/2/2007 00:00 - 17:00 17.00 MOB P PRE Move Sub Unit from W-Pad to P2-15 - Sub on Location waiting on pre-rig 17:00 - 00:00 7.00 MOB P PRE Perform derrick inspection, Link tilt proximity switch checked out ok. Raise Derrick & ready rig for moving onto P2-15. Rig on 'standby wi full crew' rate from 1700-0000 3/3/2007 00:00 - 17:30 17.50 MOB N WAIT PRE Rig standing by for pre-rig to complete. 01 :00 - Flowline finally thawed out enough to get some flow through. Methanol spotted in flowline. 03:00 - Pad operations began blowing down flowline in preparation for removal. 100-ton crane mobilized and prepping to roll from WOA to P2-15. Expecting flowline pick to take place sometime late this morning. 10:00 - Crane on location and prepping for flowline removal. 11 :00 - 12:00 in depth pre-spud meeting held wi both crews. 13:00 - Flowline Removed. Roads and Pads begins to level pad. 15:00 - Pad leveling complete. Return to rig-move operations. 17:30 - 19:00 1.50 MOB P PRE Clear snow and prep area around wellhead for rig-mats. 19:00 - 21 :30 2.50 MOB P PRE Lay Rig mats on location. Spread herculite. Spot 3 wellhead assemblies, conductor buttweld sub, and mud-cross behind well on herculite. 21 :30 - 00:00 2.50 MOB P PRE Move rig to wellhead and onto mats. 3/4/2007 00:00 - 01 :30 1.50 MOB P PRE Continue jockey rig over well. Check wi plumb-bob and line up center of rotary tabe over top of tree cap. Rig Accept at 01 :30 hrs. 01:30 - 03:15 1.75 WHSUR P DECOMP Close and button up cellar. ND master valve and adapter flange. Install stop plug in Cameron HP BPV for later BOP test. 03:15 - 04:00 0.75 WHSUR P DECOMP RU T-Bar and check rig spacing in regards to pulling BPV after BOPE made up - OK. PU Landing joint and run through rotary table to tubing hanger. Try to MU to threads in tubing hanger. Only able to make up 1.5 turns out of 8.5. 04:00 - 05:00 1.00 WHSUR P DECOMP Jack rig back up and re-position 4 inches back. Attempt to MU landing joint again. Able to get 4 turns before in bind. Jack rig again and move another 6 inches back. MU landing joint full 8.5 turns - OK. Baker fishing hand on location for input on rig positioning for tubing pulling - Good. 05:00 - 10:30 5.50 WHSUR P DECOMP MU mudcross and Blind-Shear onto wellhead. 10:30·12:00 1.50 WHSUR P DECOMP Rig up equipment to cut & weld riser for BOPE due to the leaning wellhead. 12:00 - 18:00 6.00 WHSUR P DECOMP Cut, hang, and weld riser into position that will fit with level rig Printed: 4/912007 11:14:06 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: P2-15 P2-15 REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 7ES Start: 2/28/2007 Rig Release: 4/7/2007 Rig Number: Spud Date: 2/19/1994 End: 4/7/2007 314/2007 12:00 - 18:00 6.00 WHSUR P DECOMP and leaning wellhead. 18:00 - 19:00 1.00 WHSUR P DECOMP RID welding equipment. Clean and clear cellar area. 19:00 - 21 :00 2.00 WHSUR P DECOMP PJSM. ND riser, remove blank plate (for wellhead protection during cutting and welding operations), and replace wi API gasket. NU Riser & RU BOP test equipment. 21 :00 - 23:00 2.00 BOPSU P DECOMP PJSM. Pressure up and block in 3800psi on control line to SSSV to prevent trapping pressure below SSSV if pressure from BOP test was to leak by HP-BPV during test. Test single gate blind shear rams for 5 minutes @ 250psi & 5 rnin @ 3000psi. Repeat test 4 times to test inner choke valve, outer choke valve, inner kill valve, outer kill valve. All tests OK. Test witnessed by BP WSL Matt Martyn, NAD tool pusher Biff Perry. Witness waived by AOGCC Rep. Chuck Scheve. 23:00 - 23:30 0.50 WHSUR P DECOMP PJSM and hazard analysis wi all hands on pulling the HP-BPV without a lubricator. 23:30 - 00:00 0.50 WHSUR P DECOMP RIH wi T-Bar and screw into dart portion of HP-BPV. Screw dart into BPV to release poppit, but not getting enough turns. Work dart in an out several turns but no success in un-seating poppit. 3/5/2007 00:00 - 00:30 0.50 WHSUR P DECOMP Continue trying to pull HP-BPV. After several attempts but no success in un-seating poppit. Pull HP-BPV dart and RIH wI standard BPV setting tool. No problems unseating poppit. Saw bubbles above rams when poppit released confirming pressure release from below BPV. Continue to thread retrieval tool into BPV and successfully pull BPV. Well static. 00:30 - 01 :30 1.00 WHSUR P DECOMP Pull master bushing and run in 4-1/2" NSCT landing joint. MU landing joint 8 turns into hanger. Cover hole in rig floor. RU casing running scaffolding in order for slickline and E-line to work at level height wi top of landing joint. PJSM wi Slickline crew and rig hands. 01 :30 - 04:30 3.00 WHSUR P DECOMP RU and RIH wi slickline flapper checker to SSSV. Slickline took control of SSSV and held 4500 psi on control line. Tag up on no-go above valve and check that flapper is open. Tool not hanging up in SSSV. POOH. No visible damage to tattle tales once tool at surface. RD flapper checker toolstring. 04:30 - 09:30 5.00 EVAL P DECOMP RU 3.75" OD Broach tool string & RIH for drift and work cement stringers in preparation for E-Line jet cutter (OD of Jet Cutter is 3.65"). Had to work area 10' above SSSV for 2-3 minutes before passing through wI broach. Continue RIH wi no problems until tag up at 10,660' SLM (target E-Line cut depth 11,020'). Work broach for 30-45 minutes and only able to make 5 feet of progress to a depth of 10,665 SLM. Begin POOH. Consult wi Phil Smith in town and decide to cancel slickline operations, and move to E-Line targeting a shallower cut depth. RD Slickline once at surface. 4500psi left blocked in to SSSV control line and monitored for E-Line. 09:30 - 10:30 1.00 PERF P DECOMP PJSM wI E-line crew and hands on location. Spot and RU for E-Line Jet Cutter operations. 10:30 - 12:00 1.50 PERF P DECOMP RIH wi 3.65" OD SCP Jet-Cutter toolstring. No problems RIH until gently set down wI tool at 10,651' ELM. Confirmed set down and logged back up to inspect pipe wi CCL. Printed: 41912007 11:14:06 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: P2-15 P2-15 REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 7ES Start: 2/28/2007 Rig Release: 4n/2007 Rig Number: Spud Date: 2/19/1994 End: 4n/2007 315/2007 12:00·12:45 0.75 PERF P DECOMP Pull into position and cut tubing at 10,610' ELM = 18' up from first collar seen on CCL. Good indication of cutter firing. 12:45 . 14:30 1.75 PERF P DECOMP POOH & Rig Back E-Line for circulation. 14:30 - 17:30 3.00 CLEAN P DECOMP PJSM wI hands. RU circulating lines to pump through cut at 10,610' md. Pumped 11 bbls 9.6 brine down tubing @ 2.5 bpm 300 psi to recover freeze protect diesel from annulus. Reverse circulated 40 bbls 80 vis 9.5 ppg spacerlsweep followed by 518 bbls 9.6ppg brine from surface to surface @ 4bpm 700psi. Recovered 20 bbls of strung out diesel freeze protect fluids and cement spacer fluid from tubing and annulus. Note: While circulating, OA pressure built up to as much as 6psi. Above 3 psi, needle valve opened and constantly bled pressure. Total of -20 gal bled off during circulation and OA went on a vac afterwards. 17:30 - 18:30 1.00 CLEAN P DECOMP RU to RIH wI second E-Line Jet Cutter. PJSM wI new rig crew prior to arming cutter. 18:30 - 19:30 1.00 PERF P DECOMP RIH wI 3.65" OD SCP Jet-Cutter toolstring to SSSV. Correlate depth to tubing tally. Pull into position and cut tubing at 2,288' ELM = 10' below the top of the first full joint below the TRSSSV. Good indication of cutter firing. 19:30 - 20:15 0.75 PERF P DECOMP POOH & Rig Down E-Line. Have E-line unit stand by until tubing hanger pulled in case shallower cut needed to get hanger out of bind. 20:15 - 20:45 0.50 WHSUR P DECOMP PJSM wI Hands for attempting to pull tubing hanger to floor. FMC hands backed out all tubing lock down screws. FMC and Camco bled off pressure on SSSV control line to zero. RU floor to pull tubing hanger. 20:45 - 21 :00 0.25 WHSUR P DECOMP Start pulling tubing hanger via landing joint. Calculated hookload wI 2290' of tubing is 48k Ibs. Slowly PU to 55k trying to work landing joint back and forth wI link-tilt. Saw a 3k release when trying to work wI link tilt. While pulling 52k, unable to work angle much wI link-tilt. RU tugger & strap to landing joint to help pull joint towards skate and release bind. Slowly work tubing hanger free by keeping 5-7k overpull on landing joint, and working landing joint back and forth with tugger. 21:00 - 21:15 0.25 WHSUR P DECOMP Tubing hanger free. PU = 48k Ibs. Work tubing hanger up through modified riser adjusting angle as needed using tugger to clear edges on ram body, and rotary table I rig floor. Tubing hanger at rig floor. 21:15 - 00:00 2.75 PULL P DECOMP Break out tubing hanger. Start spooling operations for control line. Pull and lay down 4-1/2", 12.6# tubing from 2,288' cut depth to 1,263'. Note: Opened needle valve on OA - no flow or pressure. Leaving valve wide open and monitoring output wI Veco hand stationed in cellar. 3/6/2007 00:00 - 04:00 4.00 PULL P DECOMP Continue pulling 4.5" 12.6# completion string from 1,263' md to surface (Original cut made 10' below top of full joint under Printed: 4/912007 11 :14:06 AM · Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: P2-15 P2-15 REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 7ES Start: 2/28/2007 Rig Release: 4/7/2007 Rig Number: Spud Date: 2/19/1994 End: 4/7/2007 DECOMP SSSV @ 2,288' md.) spooling single 1/4" SS control line while pulling. All tubing recovered successfully and control line spooled wlo incident. 29 of 30 SS bands recovered from well. Jet cut stub slightly mushroomed but clean and not split. Max OD on cut end -5.1 ". Clear rig floor of tubing pulling equipment. Load pipeshed wI 4-3/4" DC's & strap same. RIH wI 244-3/4" DC's. Rack back 8 stands of to be readily available for use as weight pipe below storm packer after cutting 7-5/8" casing. Clean and clear rig floor of collar handling equipment. MU Baker Multi-String mechanical casing cutter tool and RIH to 200'. Displace top 200' of well bore and riser to diesel. RU and make handy all tools needed during time from cutting 7-5/8" casing through setting storm packer to help reduce the time that the annulus is exposed through the wellhead. Locate collar depths wI mechanical cutter. Found collar at 111.45' md and 70.51' md. RIH to 90.45' md and begin cutting 7-5/8" 29.7# casing. Cutting parameters were 45 rpm, 1.5k torque, 240 gpm, 685 psi. Confirm cut by RIH and POH past cut depth and take weight. Saw 270 psi decrease after cut complete. DECOMP POH & LD cutter tool. Blades show sign of wear on teeth up to -1 cm. DECOMP RU Packott retrieval tool, RIH and latch solidly into packott. Back out lock down screws and retrieve packott to surface wI a 15k overpull to unseat, then free to move. No excessive wear or lock down screw grooves on packott. HMAN DECOMP RU & RIH wI casing spear to pull 7-5/8" casing hanger to floor wI 60' casing stub. Work hanger through wellhead wI restriction. Hanger appears to be in a bind. Able to get 1.5 feet of movement, and then hit a restriction at 150k overpull where we would get no pipe movement for the next 25k of tension. Work pipe repeatedly and get exactly the same results. HMAN DECOMP Suspect ditticulty pulling pipe is due to 7-5/8" collar on bottom casing hanger pup (1.6 feet) is hanging up solidly when reaching the point where the 10-3/4" casing was jammed into hanger. We think the 10-3/4 could be undergauge and holding the 7-5/8" collar. Consult wI town ODE Phil Smith. Decision made to RIH and re-cut 7-5/8" casing in middle of pup immediately below casing hanger to allow a drift or milling run prior to getting collars through top of 10-3/4". HMAN DECOMP RIH wI mechanical cutter again. Locate top of casing hanger top @ 27.3' wI tool blades, and RIH an additional 1.3 ft. Begin cutting 7-5/8" 2.97# casing. Cutting parameters were 45 rpm, 1.5k torque, 268 gpm, 870 psi. Confirm cut by RIH and POH past cut depth and take weight. Saw 300 psi decrease after cut complete. POOH, LD mechanical cutter. 3/6/2007 00:00 - 04:00 4.00 PULL P 04:00 - 05:00 1.00 DHB P DECOMP 05:00 - 07:00 2.00 DHB P DECOMP 07:00 - 08:00 1.00 DHB P DECOMP 08:00 - 08:30 0.50 DHB P DECOMP 08:30 - 10:00 1.50 T A P DECOMP 10:00 - 10:30 0.50 TA P DECOMP 10:30 - 12:00 1.50 TA P DECOMP 12:00 - 13:30 1.50 TA P DECOMP 13:30 - 14:00 0.50 TA P 14:00 - 15:30 1.50 WHSUR P 15:30 - 17:30 2.00 WHSUR N 17:30 - 18:00 0.50 WHSUR N 18:00 - 19:00 1.00 TA N Note: shortly before RD from second cut, designated cellar observer noted fluid trickling from wellhead connection to Printed: 4/912007 11:14:06 AM · Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: P2-15 P2-15 REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 7ES Start: 2/28/2007 Rig Release: 4/7/2007 Rig Number: Spud Date: 2/19/1994 End: 4/7/2007 316/2007 18:00 - 19:00 1.00 TA N HMAN DECOMP 10-3/4" casing and into pre-prepared absorb and catch-can. 19:00 - 20:30 1.50 WHSUR N HMAN DECOMP RU & RIH wi casing spear to pull 7-518" casing hanger to floor wi casing hanger only and l' of pup. Work hanger through wellhead wi restriction. Hanger still appears to be in a bind. Seeing same 1.5 feet of movement, and then hitting a restriction at 150k overpull where we would get no pipe movement for the next 25k of tension. 20:30 - 21 :00 0.50 WHSUR N HMAN DECOMP Run packoff back into hole in hopes that packoff will help to centralize casing hanger and reduce bind from leaning wellhead. 21 :00 - 23:30 2.50 WHSUR N HMAN DECOMP RU & RIH wi casing spear to pull 7-5/8" casing hanger to floor wi casing hanger only and l' of pup wI packoff installed. Work hanger through wellhead wi restriction. Hanger still appears to be in a bind. Seeing same 1.5 feet of movement, and then hitting a restriction at 150k overpull where we would get no pipe movement for the next 25k of tension. 23:30 - 00:00 0.50 WHSUR N HMAN DECOMP RU Packoff retrieval tool, RIH and retrieve packoff to surface wlo overpull to unseat, free to move. Again, no wear or lock down screw grooves on packoff. 3/7/2007 00:00 - 02:00 2.00 WHSUR N HMAN DECOMP Nipple Down riser in order to work hanger out of wellhead without bind from angle between wellhead and riser. 02:00 - 03:30 1.50 WHSUR N HMAN DECOMP Attempt to pull hanger free by RIH wi only spear and lifting sub to below rig floor, Sting into hanger and work spear wi 2 tuggers - one through rotary table, and one through mouse-hole to get proper angle. Never saw any movernent in hanger after working repeatedly. 03:30 - 05:00 1.50 WHSUR N HMAN DECOMP Investigated and prepared tools for attempting to pull on hanger wi bridge cranes. Insufficient rigging equipment available to safely rig up elevators to cranes. Shut down and decide to pull again wi topdrive on joint of pipe. 05:00 - 07:00 2.00 WHSUR N HMAN DECOMP MU single joint of pipe and stab into casing spear. Pull on casing hanger wI joint of pipe in topdrive, but no riser between rams and rig floor. Saw the same results as in previous attempts, but able to visually check that the hanger and spear tools are not in a pinch or bind in the BOP or wellhead. Pulled up to 200k over. LD casing spear. 07:00 - 09:00 2.00 WHSUR N HMAN DECOMP Nipple riser back up to RIH and make another casing cut. 09:00 - 11 :00 2.00 TA N HMAN DECOMP PU 7-5/8" Baker multistring casing cutter wi 8" blades and RIH to make cut just below casing hanger again. Located previous cut wi blades and begin to make cut in same spot. Cutting parameters: 850 psi, 290 gpm, 1.4k TO, 60 rpm. After 2.5 minutes, pressure dropped tJ 560psi and still1.4k TO. After 12 minutes, TO dropped to 0.9k. Continue to cut for another 2 minutes and saw no further pressure drop or torque decrease. POOH. 11 :00 - 11 :30 0.50 WHSUR N HMAN DECOMP RU and RIH wi casing spear assembly and successfully retrieve casing hanger. No overpull needed to unseat or pull out of hole. 11 :30 - 12:00 0.50 WHSUR N HMAN DECOMP Run back in hole wi casing spear after laying down 7-5/8" hanger and sting into casing stub. Attempted unsuccessfully (pulled 200k over) to pull casing stub out wlo hanger. Casing not cut at previous cut. 12:00 - 13:30 1.50 TA N HMAN DECOMP PU 7-5/8" Baker multistring casing cutter wi 8" blades and RIH Printed: 4/9/2007 11:14:06 AM . . Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: P2-15 P2-15 REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 7ES Start: 2/28/2007 Rig Release: 4/7/2007 Rig Number: Spud Date: 2/19/1994 End: 4/7/2007 3/7/2007 12:00 - 13:30 1.50 TA N HMAN DECOMP to make in middle of second joint below the surface (90.5' md) again. Located previous cut wI blades and begin to make cut in same spot. Cutting parameters: 520 psi, 276 gpm, 1.5k TO, 60 rpm. After 15 minutes, no pressure drop seen but TO dropped to 1.4k. Confirm cut wI blades by setting down 4k on cut. POOH. RD cutter. 13:30 - 14:00 0.50 WHSUR P DECOMP RU and RIH wI casing spear assembly and successfully retrieve -61.4' of 7-5/8" casing. No overpull needed to pull out of hole. 14:00 - 15:30 1.50 WHSUR P DECOMP PJSM wI hands. RU casing equipment and break out I lay down 1.47' cut off pup from below casing hanger, 41.83' full joint, and 18.07' cut off joint from above cut. RD casing equipment, clean & clear rig floor. 15:30 - 17:00 1.50 WHSUR P DECOMP RU 9.50" OD string mill to drift the 10-3/4 casing for storm packer. Unable to pass bottom of wellhead wI string mill. POOH, LD mill assembly. Clean and clear rig floor and consult wI town. 17:00 - 18:30 1.50 WHSUR P DECOMP RIH wI muleshoe, 8 stands 4-3/4" DC's, 2 stands HWDP to 923' MD. Drain fluid from stack as metal displaces fluid on RIH to avoid having fluid run out of casing during planned storm packer run to come. 18:30 - 20:00 1.50 WHSUR P DECOMP POOH. Stand back 8 stands DC's and 2 stands HWDP. 20:00 - 21 :30 1.50 BOPSU P DECOMP PJSM. Remove blind-shear rams from single gate BOP. Blow down service lines between pits and rig in preparation for repositioning rig. 21 :30 - 00:00 2.50 BOPSU P DECOMP PJSM. ND BOPE and mudcross. 3/8/2007 00:00 - 02:00 2.00 BOPSU P DECOMP Continue to ND single gate BOP and 13-5/8" mudcross. Once BOPE moved off of wellhead, the top of the 10-3/4" casing was visible. Casing visible egged and torn in one line where casing was very thin. At bottom of tear there was a curly-O protruding about 1.5 inches into casing. 02:00 - 02:45 0.75 WHSUR P DECOMP Clean out cellar area and make room for FMC to set up Wachs Cutter assembly. 02:45 - 03:45 1.00 WHSUR P DECOMP Rig up Wachs cutter for casing cut just below top of exposed 10-3/4" collar. Casing and collar are both egged, but collar is less egged. FMC recommends cutting top of collar for best chance of success in this situation. 03:45 - 06:30 2.75 WHSUR P DECOMP Make Wachs cutter on 10-3/4" casing. Casing egged, but cut went well. Pulled wellhead off of the surface casing stub and inspect cut. Casing severely worn. Threads from the casing collar can be seen worn through inside the pin of the lower joint. Disconnect pits from sub and begin to roll pits back in preparation for moving rig back. 06:30 - 08:30 2.00 DHB P DECOMP RU & RIH w/741 , of 4-3/4" DC's. Pick up storm packer and set 5' below 10-3/4" stump. Back out running tool and Lay Down. Well secure. 08:30 - 10:00 1.50 WHSUR P DECOMP Clean and suck out cellar box. Prepare cellar tJ move rig off. 10:00 - 12:00 2.00 WHSUR P DECOMP Move rig back off of well 30 feet prior to repositioning. Remove cut off wellhead, single-gate ram body, 13-5/8" mud cross, 20· riser for MU to single-gate. 12:00 - 14:30 2.50 WHSUR P DECOMP PJSM wI hands. Hang straight 20" riser in cellar. Spot and Printed: 4/9/2007 11:14:06 AM · Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: P2-15 P2-15 REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 7ES Start: 2/28/2007 Rig Release: 4/7/2007 Rig Number: Spud Date: 2/19/1994 End: 4/7/2007 3/812007 12:00 - 14:30 2.50 WHSUR P DECOMP Hang 20" diverter in cellar area. Move Sub unit back over well P2-15. 14:30 - 16:30 2.00 WHSUR P DECOMP PJSM wI hands. Spot pits back up to Sub unit. MU service lines from pits to rig. 16:30 - 18:00 1.50 WHSUR P DECOMP In preparation for welding operations, clean and steam cellar box, top of storm packer, area around wellhead. Prepare 34" long extension of 20" conductor for positioning on existing pipe. PJSM wI hands and GBR welder. 18:00 - 19:00 1.00 WHSUR P DECOMP Cut remaining stub of 10-3/4" surface casing off of well level wI top of existing cement in 10-3/4" x 20" annulus. 19:00 - 20:00 1.00 WHSUR P DECOMP NU 34" long extension of 20" conductor pipe wI landing ring installed. Tack weld in place and shim to level conductor. 20:00 - 21 :30 1.50 WHSUR P DECOMP Remove 20" extension, and cut top of existing 20" piece to level in order to facilitate weld. Alternative is to spend -2.5+ hours building up 1" gap between existing and new 20" pipe. 21 :30 - 23:30 2.00 WHSUR P DECOMP Weld 34" extension to existing 20" conductor. Weld looks good and top of metal to metal seal on conductor is level. During welding operations, hands broke apart tubing spool from casing spool in truck shop. 23:30 - 00:00 0.50 DIVRTR P DECOMP Begin NU diverter stack to 20" conductor pipe. 3/9/2007 00:00 - 05:00 5.00 DIVRTR P DECOMP Continue to install Diverter on conductor and diverter lines through drillers side windwalls. 05:00 - 06:00 1.00 DIVRTR P DECOMP Function test surface diverter system. Wittness of diverter system wavied by AOGCC rep Lou Grimaldi. Test wittnessed by BP WSL Matt Martyn, Nabors Toolpusher Linwood Toussant. 06:00 - 07:30 1.50 DHB P DECOMP RU & RIH to 30'. Sting into and release storm packer and LD. 07:30 - 10:00 2.50 DIVRTR P DECOMP Fill stack and check diverter for leaks. Knife valve leaking. Disconnect diverter line fl knife valve and change out gasket. Reinstall diverter line & fill stack. No significant leaks. 10:00 - 12:00 2.00 CLEAN P DECOMP Circulate out diesel - 90 bbls of diesel freeze protect that swapped out wI 9.6# brine from 10-3/4 x 7-5/8" annulus. 12:00 - 14:00 2.00 DHB P DECOMP POOH and LD 1 joint 4" DP, & 15 Joints of rental 4-3/4" spiral DC's, Stand back 3 stands of Spiral DC's for use wI backoff tool later 14:00 - 14:30 0.50 PULL P DECOMP Clean & clear rig floor, Service topdrive. 14:30 - 16:30 2.00 PULL P DECOMP MU 4-1/2" Spear BHA - Spear, packoff (packoff damaged, replace wI new packoff), bumper sub, jars, 3-stands 4-3/4" spiral DC·s. 16:30 - 18:45 2.25 PULL P DECOMP RIH picking up singles from pipeshed from 306' - top of fish at 2,288'. Record PU of 61k prior to stinging into fish. 18:45 - 19:00 0.25 PULL P DECOMP Successfully spear 4-1/2" fish at 2,288' md and PU. Pulled free without sticking @ 140k PU. 19:00 - 20:00 1.00 PULL P DECOMP Pick up 5 feet and CBU wI 9.6 ppg brine. Pumped 315 bbls @ 291 gpm, 908 psi. Seeing schmoo and parafin over shakers @ -1600 strokes when fluid from fish by 7-5/8 reaches surface. At end of circulation, shakers still showing slight schmoo and parafin returns, but at <5% of original amount. 20:00 - 21 :00 1.00 PULL P DECOMP Monitor well, blow down topdrive. POOH to 4-112 spear BHA. 21 :00 - 22:00 1.00 PULL P DECOMP LD BHA. Stand back 3-stands of 4-3/4" spiral DC's, LD Jars, & Bumper sub. 22:00 - 23:00 1.00 PULL P DECOMP RU to LD 4-1/2" tubing joints. RU to pull 4-1/2 tubing. Jet cut Printed: 4/912007 11 :14:06 AM · Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: P2-15 P2-15 REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 7ES Start: 2/28/2007 Rig Release: 4/7/2007 Rig Number: Spud Date: 2/19/1994 End: 4/7/2007 3/9/2007 22:00 - 23:00 1.00 PULL P DECOMP was belled out to -5" and had a few small curly-O's sitting on it (not part of Jet cut). Longest one was 1.5 inches long. Break out and lay down 30.55' cutoff joint. 23:00 - 00:00 1.00 PULL P DECOMP POOH laying down 21 joints of 4.5" tubing string to 7,461' md. PU - 98k. 3/10/2007 00:00 - 09:30 9.50 PULL P DECOMP Continue to pull and LD 4-1/2" NSCT tubing. Total of 181 joints of tubing laid down. Cut stub at end was 23.73' long. 09:30 - 10:30 1.00 PULL P DECOMP Rig down 4-1/2" tubing handling equipment. Clean and clear rig floor 10:30 - 11 :00 0.50 PULL P DECOMP MU & RIH 7-5/8" mechanical casing cutter w/ 3" blades (OD of blades when @ full extension -9") to make cut in middle of joint near 2,650' md. 11 :00 - 12:30 1.50 PULL P DECOMP RIH w/ 7-5/8" cutter with stands from derrick to 2,293' md. 12:30 - 13:15 0.75 PULL P DECOMP RIH w/ 7-5/8" mechanical cutter picking up 12 joints of drill pipe from pipeshed to 2,671' md. 13:15 - 14:00 0.75 PULL P DECOMP Pressure up on blades and attempt to find collar joints above and below 2,671' md. Saw only a slight bobble to indicate a collar. Casing tally shows collars at 2,672' and 2,631'. Position pipe for cut depth of 2,650' md. 14:00 - 14:15 0.25 PULL P DECOMP Start cutting casing @ 2,650' md. Cutting parameters were 88 spm, 257 gpm, 988 psi, 2.0k TO, 50 rpm, PU - 62k, SO· 62k, RT - 66k. 14:15 - 14:30 0.25 PULL P DECOMP Casing cut complete. Cutting parameters were 90 spm, 262 gpm, 863 psi, 1.8k TO, 60 rpm, PU - 62k, SO - 62k, RT - 66k. 14:30 - 15:30 1.00 PULL P DECOMP CBU w/ 9.6 ppg brine @ 2,650'. Flowpath rnost likely up 7-5/8 x DP annulus as weight of 2600' of 7-5/8" pipe is still compressing casing cut. Parameters were 85 spm, 249 gpm, 896 psi. 15:30 - 16:00 0.50 PULL P DECOMP Mix & pump 20 bbl NaCI dry job. Monitor well, blow down topdrive. 16:00 - 17:00 1.00 PULL P DECOMP POOH 284' md standing back DP to 4-3/4" spiral drill collars. 17:00 - 18:00 1.00 PULL P DECOMP Stand back drill collars. Lay down casing cutter assembly. Blades show wear out to the 45 degree extension point. Cutters show significant wear on top and bottom of blades from weight of 7-5/8 cut piece continueing to compress blades after cut. 18:00 - 19:00 1.00 PULL P DECOMP RU 7-5/8" casing spear assembly & RIH to 90'. Engage fish and PU 5 feet to confirm free. Casing free @ 90k PU. 19:00 - 19:30 0.50 PULL P DECOMP CBU w/ 9.6 brine. Begin to break out stand first stand, and pipe coming back wet. Restab stand. 19:30 - 19:45 0.25 PULL P DECOMP Continue to circulate 9.6 brine until brine is surface-to-surface. Unstab pipe. Stand is dry. 19:45 - 20:00 0.25 PULL P DECOMP Stand back DP until 7-5/8" casing spear is at surface and in slips. 20:00 - 20:45 0.75 PULL P DECOMP Monitor well. Blow down topdrive. RU floor to pull casing. PJSM for pulling 7-5/8" casing. 20:45 - 00:00 3.25 PULL P DECOMP Pull & LD Upper cut joint of 7-5/8" casing (23.15 ft.), and 50 full joints to 537' md. 3/11/2007 00:00 - 01 :00 1.00 PULL P DECOMP Continue POOH w/ 12 more joints of 7-5/8" casing for a total of 62 joints pulled plus top cut joint and bottom cut joint. Bottom cut joint was 20.98'. 01 :00 - 02:00 1.00 PULL P DECOMP PU first pulled cut joint of 7-5/8" and break out spear assembly. RD spear, crossover and handling subs, and cut joint. Printed: 4/912007 11:14:06 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: P2-15 P2-15 REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 7ES Start: 2/28/2007 Rig Release: 4/7/2007 Rig Number: Spud Date: 2/19/1994 End: 4/7/2007 3111/2007 02:00 - 03:00 1.00 PULL P DECOMP Daylight Savings Time - Spring Forward. 03:00 - 03:30 0.50 PULL P DECOMP Clean & clear rig floor. RU to run pipe for storm packer. 03:30 - 04:30 1.00 DHB P DECOMP RIH to 465' w/2 stands HWDP and 3 stands 4-3/4" spiral drill collars as weight for storm packer. 04:30 - 04:45 0.25 DHB P DECOMP MU HES storm packer to string. 04:45 - 05:30 0.75 DHB P DECOMP Storm packer hanging up somewhere is the stack. Attempting to work into hole. 05:30 - 06:00 0.50 DHB P DECOMP Storm packer through stack, and running in hole w/5 stands of DP to set. 06:00 - 06:30 0.50 DHB P DECOMP CBU 63 bbls 9.6ppg brine prior to setting storm packer. 06:30 - 06:45 0.25 OHB P DECOMP Release from storm packer and pick up 3 feet. Spot 15 BBL high viscosity pill above packer. 06:45 - 07:00 0.25 OHB P DECOMP POOH and RD from storm packer run. 07:00 - 09:00 2.00 CLEAN P OECOMP PJSM. RU for running 16" washpipe. MU sawtooth burnshoe wI 17.25" OD cutright and 15.125" 10 of cutright to first joint of 16" washpipe. 09:00 - 09:30 0.50 CLEAN P DECOMP RIH to top of cement & mark casing for reference point. 31' md is 0 feet of cement reamed. 09:30 - 12:00 2.50 CLEAN P DECOMP Clean out cement in 20" by 10-3/4" annulus from 31' to 33' md (2 feet of cement washed). Parameters were 30 rpm, 218 gpm, 40 psi, 1-2k torque. 12:00-21:30 9.50 CLEAN P OECOMP Continue cleaning out cement in 20" by 10-3/4" annulus from 33' to 38' md (total of 7 feet of cement washed). Make connection wI second joint of 16" washpipe once Parameters were: 45 spm, 109 gpm, 42 psi, 45 rpm, 2k torque, 6k WOB. Began seeing metal shavings over shakers. Speculate that metal shavings are from milling of a centralizer on pipe. (2 centralizers listed as being run in the well on the top joint of surface pipe) 21 :30 - 23:00 1.50 CLEAN P DECOMP POOH wI burnshoe. ID of collar behind burns hoe is 15.01" and ID of cutright on burns hoe is 15.125". Speculate that Smaller ID on inside of wash pipe is holding back ROP. At surface, inspect burns hoe and collar behind cutright is a smaller ID than cutright by 1/8". There is some metal wear on inside of burnshoe, but not enough to account for metal shavings over shakers. Mobilize 2 other burnshoes from baker shop. Note: Spill champion found brine in cellar wI likely source as riser connection from 16" pipe knocking on master bushings repeatedly. Reported to Mark @ 5700 5 gal brine leak wI 4.5 gal to secondary containment and 112 gal to cellar floor. 23:00 - 00:00 1.00 CLEAN P DECOMP Suck out stack wI junk pump to an annular fluid level below the 10-3/4" stub. Not clear from surface if washed hole is on center with 10-3/4" casing or not. Unable to tell either way. 3/12/2007 00:00 - 00:30 0.50 CLEAN N DPRB DECOMP Wait on new burnshoes from Baker to arrive on location 00:30 - 01 :00 0.50 CLEAN P DECOMP 2 new bumshoes arrived on location from baker shop. Steam off and inspect both. Inspect burnshoe 1 wI 17.25" burnshoe OD and 14.75" burnshoe ID and burnshoe 2 wI 17.125" burns hoe OD and 15" burnshoe ID. Decide to run burnshoe 1. 01 :00 - 01 :30 0.50 CLEAN P DECOMP RU and RIH wI new bumshoe. Tag up at -34' md wI 4' of original rathole below us. Post derrickman in cellar to inspect riser when pumps come on. 01 :30 - 02:30 1.00 CLEAN P DECOMP Bring pumps on and wash down again. Wash thorough Printed: 4/912007 11:14:06 AM · Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: P2-15 P2-15 REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 7ES Start: 2/28/2007 Rig Release: 4/7/2007 Rig Number: Spud Date: 2/19/1994 End: 4/7/2007 3112/2007 01 :30 - 02:30 1.00 CLEAN P DECOMP previous hole from 34'-38' md = 4-8 feet of cement washed. At 38' md, ROP again slowed to prior slow ROP (-1 ft/hr). Similar amount of metal shavings over shakers. At 02:30, spill champion reported fluid level coming up in cellar from underneath spill dikes. -1 bbls brine in cellar. Shut down pumps pick up off bottom. 02:30 - 03:30 1.00 CLEAN P DECOMP Observe cellar and fluid level was rising slowly wI time. Fluid level observed in riser was falling slightly also. Assess leak and regroup. We have cut through the 20" conductor. 03:30 - 04:30 1.00 CLEAN P DECOMP Consult w/ town and look towards plan forward. Called John @ 5700 and revise original leak report to -1 bbl brine leaked into cellar. 04:30 - 06:00 1.50 CLEAN P DECOMP Rig down all 16" washpipe and handling equipment. 06:00 - 06:30 0.50 CLEAN P DECOMP Clean & Clear rig floor. 06:30 - 08:30 2.00 DIVRTR P DECOMP ND 20" diverter to inspect results of washing over 10-3/4" 08:30 - 09:00 0.50 CLEAN P DECOMP Suck down fluid level inside 10-3/4" pipe and 10-3/4" by 20" annulus. 09:00 - 09:30 0.50 EV AL P DECOMP Inspect inside of 10-3/4" pipe and 20" conductor after fluid level pumped down. Cement sheath is on the highs ide of the conductor. Directional survey in records from existing well shows an inclination of 1.27 degrees. Cement sheath is on highs ide of hole. Polished metal on low-side shows that the 20" conductor was being slightly shaved shortly after beginning to mill and continued to get worse. Though there was evidence of conductor being milled, there was no obvious hole visible from 9' above the bottom of milled cement. 10-3/4" casing shows no sign of being cut. There was a diifference in fluid level between the annulus and the inside of the 10-3/4" that confirms no hole in the 10-3/4". 09:30 - 14:30 5.00 REMCM P DECOMP Consult w/ Anchorage and work towards plan forward. Prepare tools that would likely be needed for a cement job to re-fill washed over section and seal leak from conductor to cellar. Clean & service rig. 14:30 - 16:30 2.00 REMCM P DECOMP Mix and pour 2 bbls 15.7 ppg 'AS1' cement between 10-3/4" casing and 20" conductor anulus. CIP @ 1600 hrs. 16:30 - 19:30 3.00 DIVRTR P DECOMP PJSM. NU 20" Diverter. Function test bag and knife valve - OK. 19:30 - 20:30 1.00 DHB P DECOMP MU RTTS storm packer retrieval tool & RIH to 475' md. Circulate out high vis pill and dump at surface. Returns didn't flow over shakers, but on visual inspection of flowpath, there wasn't any significant debris present. 20:30 - 21 :15 0.75 DHB P DECOMP RTTS retrieval tool is at packer depth, but unable to sting into packer. Working pipe to sting into packer. 21:15 - 21:30 0.25 DHB P DECOMP Successfully into storm packer by several inches w/ retrieval tool, but not fully seated. Stab topdrive into pipe and work into packer while washing. Continue to work pipe to thread into packec 21 :30 - 22:00 0.50 DHB P DECOMP Threaded into storm packer and release packer elements. Slight gas bubbles fizzed to surface, but no change in fluid level. Blow down topdrive, monitor well. Printed: 419/2007 11:14:06 AM · Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: P2-15 P2-15 REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 7ES Start: 2/28/2007 Rig Release: 4/7/2007 Rig Number: Spud Date: 2/19/1994 End: 4/7/2007 3112/2007 22:00 - 22:30 0.50 DHB P DECOMP POOH to storm packer. Break out and lay down packer assembly. Some metal shavings similar to returns while milling were in top of packer. 22:30 - 23:30 1.00 DHB P DECOMP Continue to RD BHA weight pipe. Stand back 3 stands of 4-3/4" spiral DC's and 2 stands of HWDP. Clean & Clear rig floor. 23:30 - 00:00 0.50 EVAL P DECOMP Spot E-Line unit and RU for Gauge Ring I Junk Basket run. 3/13/2007 00:00 - 01 :00 1.00 EVAL P DECOMP PJSM for E-Line operations wI rig crew and Schlumberger hands. Begin RIH wI 6.20" OD gauge ring I junk basket. RIH to Casing stub @ 2,650' md. 01 :00 - 01 :30 0.50 EV AL P DECOMP Stacking out on 7-5/8" casing stub at 2,650' md. Work tool repeatedly to try to descend. Setting down solidly wI bottom of gauge ring (no bevel on outside of ring), and not bottom of tool. Able to see weight difference between slackoff of basket weight and slack off of entire tool - 1 foot deeper indicating that tool bottom is clearing stub, but gauge ring is hanging up on low side. 01:30-02:15 0.75 EVAL P DECOMP Worked tool into casing stub. Clean slackoff descending to top of tubing stub @ 10,610' md. Tag solidly on tubing stub. Pick up clean. 02:15 - 03:00 0.75 EVAL P DECOMP POOH wI tool from tubing stub to surface. No overpulls while POOH. 03:00 - 03:15 0.25 EVAL P DECOMP Tool at surface. Empty junk basket and recover 1-2 gallons of schmoo coated debris. Debris ranged from 2-3 mm particles up to 3-4 inch chunks of cement along wI metal cuttings. One curled chunk of casing 2" x 2". RIH for second junk basket run. 03:15 - 04:15 1.00 EVAL P DECOMP RIH and tag tubing stub again. Had to work tool into casing stub @ 2,650' again, but not as difficult this time. Again, no significant weight loss on RIH other than entering casing stub. 04:15 - 05:00 0.75 EVAL P DECOMP Tool at surface. Empty junk basket and recover some debris but less than half as much as run #1. Halliburton is okay wI RIH for setting EZSV based on amount of debris. Again, debris ranged from 2-3 mm particles up to 3-4 inch chunks of cement along wI metal cuttings. 05:00 - 06:30 1.50 DHB N WAIT DECOMP Mobilize Halliburton to bring bridging plug for EZSV. 06:30 - 08:30 2.00 DHB P DECOMP RU & RIH wI 7-5/8" EZSV on Schlumberger setting tool. Max OD of EZSV is 6.12". 08:30 - 09:30 1.00 DHB N DFAL DECOMP Unable to release from EZSV after activating Schlumberger setting tool. Make several attempts to pull free. Consult wltown team. Decision made to pull free flrope socket. 7200# rope socket pulled out leaving top of setting tool at 10572'. 09:30 - 11 :00 1.50 DHB P DECOMP POH w/e-lline. RD e-line equipment. 11 :00 - 12:00 1.00 FISH P DECOMP PJSM wlBaker, all hands, WSL to run Baker 7-5/8" backoff tool. RU to RIH wlbackoff tool. 12:00 - 15:30 3.50 FISH P DECOMP MU and RIH wlnine 4.75" drill collars wlmuleshoe on bottom, blank sub, lower anchor, power section, upper anchor, xaver sub, pump out sub, xaver sub, 1 std. 4" HWDP, fill HWDP wldiesel «to create differential in favor of annulus). Total lengtht BHA = 404.36'. 15:30 - 16:30 1.00 FISH P DECOMP RIH dry wldrill pipe stds flderrick to 2498' and PU drill pipe singles to 2658'. 16:30 - 17:30 1.00 FISH P DECOMP Fill drill pipe w/9.6 ppg brine. Printed: 41912007 11:14:06AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: P2-15 P2-15 REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 7ES Start: 2/28/2007 Rig Release: 4/7/2007 Rig Number: Spud Date: 2/19/1994 End: 4/7/2007 3/13/2007 17:30 - 18:00 0.50 FISH P DECOMP Attempt to set backoff tool at 2672'. Pressure up to 500 psi and attempt to set backoff tool slips. SO. Slips did not set. Attempt to pressure up to 500 psi second time. Pressure began to bleed off at 125 psi. Pumping down drill pipe at 1/2 bpm, 130 psi. 18:00 - 19:30 1.50 FISH N DFAL DECOMP Drill pipe running over. Shut in TIW valve. Allow diesel to migrate to surface. 19:30 - 20:00 0.50 FISH N DFAL DECOMP Circulate 11 bbls. 9.6 ppg brine at 46 gpm, 223 psi. 20:00 - 21 :30 1.50 FISH N DFAL DECOMP Blow down topdrive. POH and check pump out sub. OK. 21 :30 - 23:30 2.00 FISH N DFAL DECOMP POH. Screw in to and pump on back-off tool and find leak in power source section of backoff tool. LD tool. 23:30 - 00:00 0.50 FISH N DFAL DECOMP Clean rig floor while mobilizing new backoff tool f/Baker. 3/14/2007 00:00 - 01 :30 1.50 FISH N DFAL DECOMP MU backoff BHA and rerun above nine 4.75" drill collars in hole w/muleshoe on bottom. MU blank sub, new lower anchor, new power section, upper anchor, xover sub, pump out sub, xover sub, 1 std. 4" HWDP. Totallengtht BHA =: 404.36'. 01 :30 - 03:00 1.50 FISH N DFAL DECOMP Fill HWDP w/diesel (to create differential in favor of annulus). 03:00 - 04:30 1.50 FISH N DFAL DECOMP RIH wldrill pipe dry w/backoff BHA to 2658'. 04:30 - 05:30 1.00 FISH N DFAL DECOMP Fill drill pipe w/9.6 ppg brine. 05:30 - 06:30 1.00 FISH N DFAL DECOMP Fill drill pipe w/casing fill line. 06:30 - 08:30 2.00 FISH N DFAL DECOMP Pressure up to 500 psi to activate backoff tool. SO 5K#. Pressure up to 1800 psi, SO 5K, pressure to 3250 psi and tool turned 1/2 turn. Tool would not ratchet when pressure bled off. Pressure up to 4000 psi two times and bleed off. Tool would not ratchet back. PU and drop ball. Pressure up to 2500 psi and circulation sub sheared out. 08:30 - 10:00 1.50 FISH N DFAL DECOMP Circulate surface to surface w/236 bbls. brine and overboard diesel at surface. Well out of balance. CBU to get well back in balance. 10:00 - 11 :30 1.50 FISH N DFAL DECOMP POH f/2672' to 107'. Brine wt. 9.6 ppg. 11 :30 - 12:45 1.25 FISH N DFAL DECOMP Inspect backoff tool and install new shear pins in tool. Change out circulating sub. 12:45 - 17:30 4.75 FISH N DFAL DECOMP RIH to 2672'. Fill every five stands w/diesel utilizing casing fill line (25 mins/ea five filled). 17:30 - 18:30 1.00 FISH P DECOMP Pressure up to 500 psi and function backoff tool. Back out casing 4.5 turns. 18:30 - 19:45 1.25 FISH P DECOMP Drop ball to circulation sub and circulate diesel out of hole and overboard. 255 gpm, 189 psi. 19:45 - 21:15 1.50 FISH P DECOMP Monitor well. Brine wt. 9.6 ppg. BD topdrive. POH to back off tool. 21 :15 - 22:30 1.25 FISH P DECOMP LD back off tool. Stand back 3 stds 4.75" drill collars. 22:30 - 00:00 1.50 FISH P DECOMP RIH w/7-5/8" casing spear to 2592'. 3/15/2007 00:00 - 01 :00 1.00 FISH P DECOMP RIH and tag up on top of stub at 2650'. PU 60K, SO 60K. PU 5K over string wt. and rotate string to left 7 turns w/2K tq. Fish came free. PU wt 60K. 01 :00 - 02:00 1.00 FISH P DECOMP POH w/spear. 02:00 - 02:30 0.50 FISH P DECOMP LD 7-518" spear BHA and 14.76' stub w/NSCC box down. 02:30 - 04:30 2.00 CASE P DECOMP RU 7-5/8" casing running equipment. 04:30 - 15:00 10.50 CASE P DECOMP PJSM w/casing hand, all hands, WSL, tourpusher. RIH w/7-5/8" 29.7# mixed NSCC and TCII casing string w/cutlip guide and triple thread connection w/NSCC box down. Had difficulty w/collars and centralizers entering 10-3/4" casing stub. Drained stack and found that casing collars were hanging up Printed: 4/912007 11 :14:06 AM · Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: P2-15 P2-15 REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 7ES Start: 2/28/2007 Rig Release: 4/7/2007 Rig Number: Spud Date: 2/19/1994 End: 4/7/2007 3115/2007 04:30 - 15:00 10.50 CASE P DECOMP on high side of 10-3/4" casing. Installed two set screws in each centralizer to hold centralizers in place under casing collars and difficulty getting into 10-3/4" casing ceased. RIH wIno further problem to 2441 '. LD 2 jts of NSCC w/damaged threads. Replaced wfTC-II. 15:00 - 15:30 0.50 CASE P DECOMP PJSM. Change out bales to accomodate cementing head. 15:30 - 17:00 1.50 CASE P DECOMP RIH to 2664'. 17:00 - 18:00 1.00 CASE P DECOMP PU = 90K string wt. SO = 85K string wt. SO slowly while rotating and work tq. down to screw over 7-5/8" NSCC pin looking up w/collar looking down on bottom of screw in sub. Work 7K tq. down to connection. Pull test casing to 200K. OK. 18:00 - 19:00 1.00 CASE P DECOMP MU cement head wl7-5/8" casing wiper plug installed to 7-5/8" string. Test lines to 4000 psi. Test csg. to 2000 psi f/10 min. w/80K pulled over string wt. OK. Pressure up and shear out ES cementer sleeve at 3350 psi. Circulate 80 deg. brine until brine 80 deg in and out. 19:00 - 20:00 1.00 CASE P DECOMP PJSM w/Schlumberger. Fill lines w/fresh water and pressure test lines to 3000 psi. OK. 20:00 - 22:00 2.00 CASE P DECOMP Mix on the fly and pump 147 bbls. 15.8 ppg class G cement w/GASBLOK and 1 ppb of CEMNET at 5.7 bbl/min. ICP = 250 psi. SD. Shut casing in and wash up Schlumberger cementing lines to flow line w/fresh water. Blow lines back to trucks. Switch to rig pumps to displace w/9.6 ppg brine. Drop casing wiper plug and see indicator trip. Plug away. Displace 65 bbls at 5 bpm. With permission of both pad operator and Brian Collier, BP N. Slope environmental dept., route returns direct to cellar box and sucked cement out w/two supersuckers. W/112 bbls. away slow rate to 2 bpm, 1092 psi. Bump plug w/2105 stks/121.5 bbls. FCP = 1092 psi. Increase pressure to 2105 psi and see ES cementer sleeve shear and close. Hold 2000 psi f/3 minutes w/chart. OK. Estimate 42 bbls. cement back to surface. Check cement sample f/cellar and find weight at 15.6 ppg. Bleed off to flowline and check ES cementer. No back flow. Note: checked cement in 7-5/8" x 20" annulus and it had slumped to 10' and held steady and cement set up. Checked again for flowback into 7-5/8". No f/owback. RD and BD lines. 22:00 - 22:30 0.50 CASE P DECOMP Remove diverter flow line. ND diverter and PU 20" Hydril 2'. 22:30 - 00:00 1.50 CASE P DECOMP PJSM wlFMC and RU and install FMC Gen VI casing slips. SO 90K on slips. 3/16/2007 00:00 - 04:00 4.00 CASE P DECOMP RU Wachs cutter and cut casing. 04:00 - 06:00 2.00 CASE P DECOMP ND diverter, clear rig floor, clean pits, prepare casing/wellhead for welders and inspection, remove top of cuttings tank to clean diesel out of tank while waiting on wellhead welding inspectors (CWI). Perform off critical path tasks. Move wellhead equipment and adaptor spool to cellar during wait periods. 06:00 - 18:00 12.00 WHSUR P DECOMP PJSM wlWSL, crew, toolpusher, CWI, drilling safety adviser, FMC well tech, E&I Cooper Heat machine technician. Establish necessity of firewatch at all times. CWI inspected casing stub and well head bell nipple for cracks wlvisible dye penetrant. Preheat weld area w/propane weed burner and Printed: 4/9/2007 11:14:06 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: P2-15 P2-15 REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 7ES Start: 2/28/2007 Rig Release: 4/7/2007 Rig Number: Spud Date: 2/19/1994 End: 4/7/2007 3/16/2007 06:00 - 18:00 12.00 WHSUR P DECOMP Cooper Heat machine to 500F to 600F. Perform rig maintenance, top drive maintenance, clean rig. Rotate crew to cellar to maintain firewatch. 18:00 - 19:45 1.75 WHSUR P DECOMP Place FMC Gen VI Bell Nipple over casing stub at 18:00 and begin preheat process on bell nipple with heat blanket. 19:45 - 00:00 4.25 WHSUR P DECOMP Begin weld on lower, external weld FMC Gen VI bell nipple to 7-5/8" 29.70 L-80 casing stub. Check each weld section w/temp probe and heat, weld and inspect as required by CWI. 3/17/2007 00:00 - 03:00 3.00 WHSUR P DECOMP PJSM w/crew, toolpusher, WSL. Preheat, weld, and inspect FMC Gen VI bell nipple as required by BP CWI. Rotated crew to maintain firewatch at all times. Welding completed at 03:00. 03:00 - 04:30 1.50 WHSUR P DECOMP Post weld heating process begins. Heat bowl area w/Cooper Heat machine under ceramic blankets per BP CWI to 900 deg. F. 04:30 - 09:00 4.50 WHSUR P DECOMP Begin cooling process. Cool welds slowly via use of Cooper heat blankets 04:30 until welds are below 100 deg. F. 09:00 - 10:30 1.50 WHSUR P DECOMP CWI inspection of welds on bell nipple. 10:30 - 12:30 2.00 WHSUR P DECOMP Pressure test inner and outer welds on bell nipple per FMC. Nitrogen test bleeding off slowly at 1500 psi. No visible leaks in welds. Perform test with water. Held 3000 psi for 20 minutes. 12:30 - 13:30 1.00 WHSUR P DECOMP MU Gen VI tubing head, test metal seal 1000 psi f/10 rnin. OK. 13:30 - 17:30 4.00 BOPSU P DECOMP NU BOP. Install shear rams. 17:30 - 18:00 0.50 BOPSU P DECOMP RU to test BOP. 18:00 - 00:00 6.00 BOPSU P DECOMP Pressure test BOP. 250 psi low pressure. 4500 psi high pressure. 4" test jt. Test gas monitors, PVT, and flow alarms. BP WSL Lowell Anderson, Nabors tourpusher Lenward Toussant, AOGCC representative Jeff Jones witnessed test. Off the critical path: Cemented 10' slump in 7-5/8" x 10" x 20" annulus cement via 4" port. Poured 45 gallons 15.7ppg Artic Lite Cement down annulus w/angled tube and funnel. Filled void until water came to surface. Drained water off through 4" port. Filled w/cement two more times until no water flowed off top of cement. Cement visible to level of 4" port. 3/18/2007 00:00 - 01 :00 1.00 BOPSU P DECOMP BOP test w/4.5" test jt. Test top and bottom rams to 4500 psi. Test annular preventer to 3500 psi. 01 :00 - 01 :30 0.50 BOPSU P DECOMP Rig down test equipment. BD. Install wear bushing. 01 :30 - 02:30 1.00 CLEAN P DECOMP PU cleanout BHA w/HCC 6.75" STX-1ser bit. # 5110355,7-518" casing scraper, 2 boot baskets, bit sub w/float installed, Bowen lub bumper sub, Bowen oil jars, 3 stands 4.75" drill collars, xo sub to HT40. BHA OAL = 312.51'. 02:30 - 05:00 2.50 CLEAN P DECOMP PU 4" HT40 drill pipe f/pipe shed and RIH to plug in ES cementer at 2655'. 05:00 - 05:30 0.50 CLEAN P DECOMP Pressure test 7-5/8" casing 2000 psi from surface to plugs in ES cementer at 2655'. (Tag up on stringer at 2652'). Hold for 5 mins. OK. 05:30 - 07:30 2.00 CLEAN P DECOMP Drill cement stringer, plugs, cement and clean out ES cementer/baffle collar from 2655' to 2665'. PU 68K, SO 68K, Rot. 68K, 250 gpm, 500 psi, 40-50 rpm. 5-15K WOB, 1.5K tq. off, 2.5-3K tq. on. Drop through and work 6.75" bit and 7-5/8" Printed: 4/912007 11:14:06 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: P2-15 P2-15 REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 7ES Start: 2/28/2007 Rig Release: 4/7/2007 Rig Number: Spud Date: 2/19/1994 End: 4/7/2007 3/18/2007 05:30 - 07:30 2.00 CLEAN P DECOMP Baker scraper through ES cementer several times with no resistance. Circulated 2" chunks of rubber and small amount of cement chunks across shakers. No metal or metal shavings. 07:30 - 13:30 6.00 CLEAN P DECOMP RIH picking up 4" HT-40 drill pipe + 4 stands from derrick to 10570' . 13:30 - 14:00 0.50 CLEAN P DECOMP SO slowly to 10576' and put 30K down on Schlumberger running tool left in well on top of EZSV to compress running tool. PU to 10535'. 14:00 - 15:15 1.25 CLEAN P DECOMP RU and test 7-5/8" casing to 4500 psi on chart f/30 minutes f/surface to EZSV bridge plug at 10585'. OK. RD/BD lines and kill line. 15:15 - 16:30 1.25 CLEAN P DECOMP Displace 9.6 ppg brine f/well to 10.5 ppg LSND mud with 4 drums of Steel/ube EP metal to metal lubricant in spacer pill. 420 gpm, 2238 psi, 46 rpm, 7K tq., PU 180K, SO 120K, Rot 143K. ~\t'\ 16:30 - 17:00 0.50 CLEAN P DECOMP Pump dry job. Monitor well. 17:00 - 22:00 5.00 CLEAN P DECOMP POH to BHA at 312'. \>2.-, SF'! 22:00 - 23:00 1.00 CLEAN P DECOMP PJSM. Stand back 3 stands 4.75" drill collars. Lay down cleanout BHA. 10 Ibs of cement, small amount of metal shavings, 2 brass chunks 3/4" OD in lower boot basket. Nothing in upper boot basket. Used 6.75" cleanout bit HCC STX-1 ser. # 5110355 no add I. damage, scraper no damage to blade blocks or body after drillout of ES cementer. 23:00 - 00:00 1.00 STWHIP P WEXIT PU BHA #18 Baker window milling whipstock assy. including: special built solid bottom stop plug (to keep top of Schlumberger setting tool fish on top of EZSV f/entering bottom trip anchor upon application of set down wt with whipstock/anchor assy), bottom trip anchor, 7-5/8" Baker Gen II Whipstock, window mill, bit sub, upper mill, float sub, 1 jt. 4" HT-40 HWDP, Schlumberger Impulse MWD, orienting sub, Bowen lub bumper sub, 3 stds. 4.75" drill collars, XO, 17 jts. 4" HT-40 HWDP. OAL of BHA = 896.96'. 3/19/2007 00:00 - 01 :00 1.00 STWHIP P WEXIT Continue PU whipstock BHA #18 to top of HWDP and shallow test MWD. 250 gpm. 730 psi. OK. 01 :00 - 06:00 5.00 STWHIP P WEXIT RIH wn-5/8" whipstock/bottom trip anchor BHA #18. 06:00 - 06:30 0.50 STWHIP P WEXIT Orient whipstock high side. 250 gpm, 1530 psi. RIH and tag top of Schlumberger setting tool at 10575'. PU 185K, SO 120K. SO and set bottom trip anchor w/20K down. PU and pull 1 OK over string wt. to confirm anchor set. SO 30K and feel brass tray/mill running pin shear. Take SPRs. 10570' MD/8087' TVD. 06:30 - 12:00 5.50 STWHIP P WEXIT Mill window f/10555' to 10569'. 250 gpm, 1525 psi, 100 rpm, 8K tq. off, 8-9K tq. on, PU 185K, SO 120K, Rot 145K. Pump 25 bbl Hi-Vis sweep. Recover total of 55# metal. TOW = 10555', MOW = 10562', BOW = 10569'. 12:00 - 19:30 7.50 STWHIP P WEXIT Mill window + 20' of new hole f/10569' to 10582'. 5K WOB, 242 gpm, 1602 psi on, 1561 psi off, PU 175K, SO 122K, Rot 145K, 9K tq. on, 10K tq. off, 100 rpm. 19:30 - 20:45 1.25 STWHIP P WEXIT Ream back through window to 10553'. No trouble through window. Atternpt ream down ffTOW to 10558', took 15K wt, pull15K drag to 10555', SO no rotation, took wt. at 10557', SO w/o rotation or pumps, took 15K at 10557'. No pack off seen Printed: 4/912007 11 :14:06 AM · P2-15A FROM DRLG - DRAFT . SAÆTY NOTES: TREf:\= WELLHEAD- ACTUATOR = KB. ELEV = BF. ELEV = KOP= Max Angle - Datum MD = Datum TVD = CWV FMC BAKERC 40.4' 11.2' 987' S7 @ 124S2' ????' SSOO' 5S 110-3/4" CSG, 45.5#, NT-SO, ID = 9,953" I Minimum ID = 3.725" @ 10,318' HES XN NIPPLE 4-1/2" TBG, 12.6#, TG-II LSO, .0152 bpf, ID = 3958" 10330' ÆRFORA TION SUMMARY REF LOG: 4-1/2" Liner Tally 04/04/2007 A NGLE AT TOP ÆRF: 56 @ 11860' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DA TE 2-1/2" 6 11860 - 11950 0 04/05/07 2-1/2" 6 12200 - 12350 0 04/05/07 2-1/2" 6 12400 - 12510 0 04/05/07 2-1/2" 6 12550 - 12710 0 04/05/07 14-1/2" TBG, 12.6#, LSO, .0152 bpf, ID = 3.95S" I 11727' 12125' I 7-5/S" CSG, 29.7#, NT-95, ID = 6.875" I 12210' DATE 03/08/94 o 1/0S/06 09/24/06 02/03/07 02/09/07 02/24/07 REV BY COMMENTS ORIGINAL COM PLETION EZLlPJC 7-5/S' CSG CORRECTION ROW/PAG WAIVER SFTY NOTE DELETED KSBfTLH GL V C/O SWC/PAG SET PXN PLUG (1/23/07) MSSfTLH CEMENT PLUG 29' 4-1/2" HES X-NIP, ID = 3.S13" I 10-314" 45.5# L-SO CSG Cut @ Cellar Base 1982' 4-1/2" HESX-NIP,ID=3.S13" I 4-1/2" x 7 -5/S" Baker S-3 Packer I 4-1/2" HES X-NIP, ID = 3.813" I 4-1/2" HES XN-NIP, ID = 3.725" I 4-1/2" TUBING TAIL, WLEG ID = 3.95S" 7-5/8" BKR ZXP LNR TOP PKR, ID = 4.930" MIL LOUT WINDOW IN 7-5/S" 10453 - 104671 I PBTD I 12713' 14-1/2" TBG, 126#, TC·II LSO, .0152 bpf, ID = 3.95S" H 12798' -J SET PXN PLUG (01/23/07) I -i 4-1/2" TUBING TAIL, WLEG I H ELMD TT LOGGED 03/26/94 I DATE REV BY COMMENTS 04/07107 MJrvv7ES SIDETRACK COM PLETION 04/08/07 /PAG DRLG DRAFT CORRECTIONS POINT MCINTY RE UNrr WELL: P2-15A ÆRMrr No: 207-032 API No: 50-029-22409-01 SEC 14, T12N, R14E, 599.28' FEL & 4005.61' FNL BP Exploration (Alaska) RE: P2- I 5 Plan forward . . Thanks Tom, It appears the conductor may indeed have been driven at something other than vertical: worn surface casing, trouble with 7 5/8" hanger in BOPs while reciprocating, survey showing 5+ degree GLS at 90', and wachs cutter cutting less than horizontal the other day. Pretty strong case for it anyway. Phil From: Thomas Maunder [mailto:tom_maunder@admin.state.ak.us] Sent: Monday, March 12, 2007 12: 11 PM To: Smith, Phil G (ASRC) Subject: Re: P2-15 Plan forward Phil, The proposed design removes 1 layer of redundancy in the shallower sections of the well. So long as the well maintains integrity (no communication to the IA) there shouldn't be an issue. However, it is possible that the well would need to be SI if such communication would develôp. One other item, you mention of the possibility of drilling out of the conductor. Any ideas what might have deflected the assembly? As shallow as you are, one wouldn't expect to deflectthatmllch so soon. Regards, Tom Maunder, PE AOGCC SCANNED MAR 0 9 2007 Smith, Phil G (ASRC) wrote, On 3/12/2007 9:21 AM: Tom, As mentioned this morning, we have evidence that we cut through the 20" conductor on P2-15 as we attempted to washover the 10 3/4" surface casing. Our preferred plan forward is to re-cement the 10 3/4" x 20" annulus top-job style and tieback the 7 5/8" casing to surface and build the wellhead off of the 7 5/8" casing with FMC Gen 6 equipment. The 7 5/8" casing would be a premium thread from the screw-in point at 2650' MD to surface and the entire annulus from the screw-in depth to surface would be cemented. Our tubing would remain 4 1/2" as listed in the permit request, leaving the 4 1/2" x 7 5/8" the only open annulus in the well, similar to the P2-34 injector. Please advise if this is an acceptable completion design, pending satisfactory tubing and casing integrity tests. Thanks, Phil «P2-15A Proposed 2.bmp» I ofI 3/12/2007 1:48 PM Re: P2-15 (193-154) RWO change of scope . , . . Phil, The procedure you have provided can supersede the procedure approved with sundry 307-008. There is no need to file an additional 403. BOP tests prior to finally NU on the 7-5/8" casing to clean out the cement and recover the tubing and packer should be to 3000 psi. The BOP test on the 7-5/8" casing should be to your planned casing test of 4500 psi. Good luck with the operations. Keep the Inspectors and myself informed if plans get changed. Tom Maunder, PE AOGCC Smith, Phil G (ASRC) wrote, On 2/2012007 9:51 AM: Tom, After AOGCC approval of the P2-15 RWO, an attempt was made to repair the leaking surface casing without the rig. During the process of pre-heating the bell nipple and surface casing for welding the surface casing swaged into the bell nipple and dropped the wellhead approximately 18". Nabors 7ES is scheduled to move over the well in approximately 10 days to perform the attached scope of work to repair the wellhead and establish surface casing integrity. Please advise if further documentation is required to review and approve the change of scope. Thanks, Phil «P2-15 Ops summary - NU Riser.doc» '::> c..o.",-'f<ð ;)-( q(g -0"'\ Þ.f¿<tvA.. 1 of 1 2/20/2007 4:32 PM . . P2-15 RWO Summary \ <\?:> _ \ ~ L\ Current Condition: · SC leak discovered 5/6/04 with N2 Test r--+ ÖI~S \::\V\W · SBHP @ 8800' MD = 4250 psi (9.3 ppg) 7/28/03, Current estimate 4050 psi · On PW injection until 7/15/06 · PX Plug set in X nipple at 11,689' MD 1/23/07 · Pulled GLVfrom 11,597' bottom station 1/30107 · PPPOT-IC passed 3500 psi 1/30107 · CMIT TxlA passed 3500 psi, loaded TxlA wI 709 bbls SW 2/3107 · FP wI 55 bbls MEOH (net) in IA I 30 bbls tbg 60/40 214/07 ::..- 'S \ 'ì 0 ,\>C;. \ · Removed 24" section from conductor below landing nipple . .8 09)/7 · Welders preheating casing for weld job when wellhead dropped down around 18" inside kt':f-. ( conductor. This caused flowlinel downcomer to be in a major bind and platform is deformed. Flowline pressure was bled off right away and fire department was called out to stand by. Flowline disconnected inside mod via spool removal. Tree studs bent 2/3/07 · Monitoring well bore pressures every three hours and inspecting OA for signs of flow. "U\:S? ~ l.{'OS-O·~.. \ (<6<6ùJ) =- ~<J50- ~O Pre-Rig Work: 1. Remove gravel from cellar to cellar box base to expose conductor deeper. 2. Herculite line cellar 3. Install FMC base plate with fluted hanger support. 4. Remove well house and surrounding well houses for rig move. 5. Remove S-riser (Wells Group detailed procedure available through Tyler Norene). 6. Install scaffolding around well to access tree cap. 7. RU and pressure test hardline to tree cap with IA returns to a twinned well or frac tank(s). Establish circulation down tubing through open GLM at 11,597'. 8. Mix 700 bbls of 9.6 ppg brine at 100°F. Average well temperature from lower GLM to surface is 80°F. Average density of the brine will stabilize at 9.65 ppg at 80°F. Final temp at coldest point in the well is 20°F. Cooling 9.6 brine from 100°F to 20°F increases fluid density to 9.8 ppg - near the crystallization point of NaCI and provides freeze protection to -5°F. BHP at 8800' TVD is estimated at 4050 psi (8.9+ ppg EMW); 9.6 ppg brine offers 340 psi overbalance to a 4050 psi reservoir @ 8800' TVD. 9. Pump 500 bbls (Tubing and annulus volume + 20 bbls) of 9.6 ppg NaCI brine down tubing. Switch to Dowell and pump 8.6 bbls 12.5 ppg MudPush lead spacer, 12.5 bbls 15.8 ppg class G cement, and 5 bbls tail spacer. Displace with 167 bbls 9.6 NaCI brine to place a 300' balanced cement plug in the tubing and annulus. 10. Open equalizing valve between tubing and annulus at surface and allow U-tube for 5 minutes. Close valve and pump 2 bbls diesel (76') into tubing annulus. Reopen equalizing valve at U-tube to freeze protect the tubing and annulus to ±50'. 11. Close tubing and annulus valves and blow down surface lines. 12. Wait on cement 6 hours and pressure test tubing and annulus independently to 3000 psi while monitoring the OAP. 13. Bleed tubing and casing to zero psig. 14. Install TWC in tubing hanger. Provide handover form to 7ES well site leader and perform pre-rig pad inspection. . . Proposed Procedure Summary: \S~-\'::> ~ 1. Move in Nabors 7ES with 20" riser and 13 5/8" flange staged in rig cellar. 2. Remove tree and adapter flange. Install mud cross, 13 5/8" blind shear ram, and 20" riser. Ttest the blind ram to 3000 psi through the mud cross against the TWC. Drain diesel from blindlshear assembly via the mud cross. 3. Reposition rig as required to position top of riser in the mud box. 4. Move in pipe shed and pit complexes. 5. Verfiy SSSV is open (not locked out) and annulus pressure is bled to zero. Open blindlshears, and pull the TWC with a lubricator. 6. RU slickline at drift the tubing to TOC. Broach tubing as required for stringers significantly above calculated TOC. Consider running SSSV lock open sleeve. 7. RU e-line and cut tubing in the first full joint above the tag up depth. Release wireline after verifying tubing will pull free from the cut. 8. Circulate the 2 bbls diesel freeze protection from the well with 9.6 ppg brine. 9. Spear tubing hanger and pull tubing to rig floor. Make second cut in the first full joint below the SSSV if necessary. Prepare to spool single/bare control line. 10. Lay down tubing and cut joint. 11. RIH with 7 5/8" mechanical casing cutter. Displace well to diesel from 2 stands below the wellhead to keep brine from entering the 10 :X" casing during the mechanical cut. Cut casing in the center of a full joint one stand below the hanger. 12. Pull 7 5/8" packoff. 13. Spear 75/8" cut casing joint and lay down same. 14. RIH with 10 :X" storm packer and 4 :X" collars as required for weight. Set storm packer 30' below the wellhead. Drain riser and POH dry. 15. ND 20" riser, blind ram and mud cross, and casing and tubing spools. 16. Secure starting head with tugger lines and nylon slings. 17. Cut and remove 20" conductor stub as close to ground level as possible with hydraulic band saw. Chip away cement sheath. 18. Cut surface casing with hydraulic band saw immediately above the exposed surface casing collar. Remove starting head. 19. Install overshot with LH thread box up to exposed surface casing collar. 20. Make up a single joint of LH thread DP to the torque cap and remove 10 :X" casing collar with top drive. 21. Inspect 10:X" BTC threads. BakerLok on new 10 :X" collar on single joint of 10:X" BTC, box down. Install 10 :X" torque ring into box. BakerLok exposed surface casing threads and make up joint to exposed buttress connection. Cut joint with Wachs cutter as required to obtain desired base flange height. . Contingency to cut off and remove 10 :X" pin if damaged and install slip-on flange and short riser assembly to accommodate the starting head. 22. Slip 20" conductor pup over top of 10 :X" casing stub and butt-weld same to existing 20" casing to provide ample space for the Slip-Loc starting head. Fill annular space with 15.8 ppg cement. 23. Install FMC Snap-Loc starting head and 11" 5M x 7 5/8" casing spool. 24. Nipple up and test BOPs. 25. Pull and lay down 10:X" storm packer. 26. RIH 7 5/8" hydraulic back off tool and back off cut stub. 27. RIH spear and recover backed off stub 28. RIH triple connection sub on 7 5/8" casing and make up to exposed threads. 29. Break stack at the casing head and cut off 7 5/8" casing as per FMC with Wachs cutter. Apply tension as per FMC and set casing slips. 30. Install tubing spool and 7 5/8" packoff. Pressure test packoff. 31. NU and test BOPs 32. RIH and circulate diesel from the well with 9.6 ppg brine. . Recover tubing below the SSSV if necessary . . '~~-\SL\ 33. RIH with 6 :X" wash-pipe and wash over tubing while reducing brine weight to 9.3 ppg I add brine viscosifier as necessary. Perform outside cut(s) and recover sections of tubing until the GLM is recovered. 34. Pressure test casing to 4500 psi. 35. Wash over final section of 4 %" tubing and production packer. Be prepared to lose circulation andlor circulate gas from below the packer after milling the packer seals. 36. RIH with overshot and recover production packer and tailpipe. 37. RIH with 7 5/8" casing scraper to PBTD and circulate the well to clean brine. LDDP. 38. Run 4 ~" L-80 TCII completion. 39. Land the tubing hanger and RILDS 40. Drop the ball and rod and set the packer. Test the tubing to 4500 psi. Bleed pressure to 2000 psi and test the IA to 4500 psi. Shear the DCK valve. 41. Set the TWC and test to 1000 psi. ND BOPE. NU tree and test to 5000 psi. 42. Freeze protect the Tubing and IA to -2000' TVD with diesel. Install a BPV and test to 1000 psi. 43. RD/MO. P2-15 Wellhead Incident . . Sundry: 307-031 PTD: 193-1540 SCANNED fEB 2 6 2007 Summary of events: Remedial work was underway to repair surface casing integrity. A fluted casing hanger and the 10 %" surface casing it was connected to were being preheated in preparation for sealing a thread leak in the connection. Just as the pre-heat temperature of 300 degrees farenheit was reached, the surface casing collapsed into the casing hanger - traveling a distance of 18". During the event a Wellhead valve struck a welder - he was evaluated at the Prudhoe Bay medical center and released without restriction. The well is secure. An investigation has been conducted but no definitive finding will be determined until the workover is underway. We have representatives coming from Edison Welding and an FMC wellhead design engineer to evaluate prior to the rig's arrival. Current plan is to use 7ES during this ice road season. Pictures will be forthcoming later today Doug 1 of 1 2/21/20077:51 AM ~: FW: P,2-15 Summary Proposal . . Tom - 'q~:,,- \ 5l.{ In a case where the damage was too extensive, the intention is indeed to achieve isolation w/cement for the new production casing. In the case of P2-15, the situation is that we have a small thread leak and no actual surface casing leak. We will handle this as a typical bradenhead repair. Thank you - Jack L. Winslow Well Integrity Engineer office - 659-5102 pager - 659-5100, ext. 1154 SCANNED JAN 2 5 2007 -----Original Message----- From: Thomas Maunder [mailto:tom maunder@admin.state.ak.us] Sent: Thursday, January 25, 2007 8:01 AM To: NSU, ADW Well Integrity Engineer Subject: Re: FW: P2-15 Summary Proposal Thanks Jack, The only question I have is with regard to "damage too extensive". CPAI has been welding sleeves of casing to restore integrity. If damage is too extensive, is it the intent to achieve isolation with the cement job for the new production casing? Call or message with any questions. Tom Maunder, PE AOGCC NSU, ADW Well Integrity Engineer wrote, On 1/25/2007 7:51 AM: All - Here is the final version of the procedure summary for P2-15 conductor cut and surface casing repair. Call if you have any questions. *Description Summary of Proposal:* *Pre Work:* 1) 1/21/06: MIT-IA to 3000 psi, Passed. 2) 1/5/07: Eval surface casing leak depth - Found fluid misting from cottom of the conductor landing ringe flute at the threaded connection. 3) 1/16/07: Remove gravel in cellar to - 5' depth. 4) 1/20/07: Bleed OA to zero. Monitor overnight. *Proposed Procedure Summary:* 1) 2) 3 ) 4) cutter. RU Slickline, set TTP - complete. CMIT TxIA to 3000 psi - passed. Bleed all pressures to zero - day of cut, in progress. Remove necessary amount of conductor with WACHS (cold work) lof2 1/29/2007 7:54 AM RE: FW: P2-15 Summary Proposal . . 5) Inspect leak point. If damage is too extensive for nonrig repair, skip to step 15. 6) Set up weld package. 7) Pull GLV in station #2. 8) Circulate well to water. Freeze protect. 9) Depress tubing and IA fluid levels with N2. 10 Establish double block and bleed on flowline. 11 Purge OA with N2. Monitor for LEL per hot work permit requirements. 12 Perform surface casing weld per Welding Procedure. 13 Inspect surface casing weld. 14) MITOA to 1000 psi. 15) Re-establish purge as before. Re-assemble conductor pipe and landing ring. Weld per Welding Procedure. 16) Inspect conductor welds, 17) Backfill cellar with gravel. Thank you - */Jack L. Winslow (for Anna Dube)/* Well Integrity Engineer office - 659-5102 pager - 659-5100, ext. 1154 20f2 1/29/20077:54 AM . . SARAH PALIN, GOVERNOR AI4ASIiA OIL AND GAS CONSERVATION COMMISSION 333 W. 7th AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Ross Warner Production Engineer BP Exploration (Alaska), Inc. PO Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Pt. McIntyre Oil Pool, P2-15 Sundry Number: 307-031 SCANNED JAN 2 3 7007 /L1 \ø...y \'1 Dear Mr. Warner: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. DATED thisz..{day of January, 2007 Encl. I .. ¢ /7 RECEIVED STATE OF ALASKA . iL ALASKA OIL. AND GAS CONSERVATION COMMISSION ~ ",\JAN 2 3 Z007 APPLICATION FOR SUNDRY APPROVAL ') A' laska Oil & Gas Cons. Commission 20 AAC ~5 ~80 DlS 1. Type of Requeat~ Abàndon 0 Suspend D OperatIonal shutdown U Perforate U WalllêrÐ OttIer U Alter (;aslng 0 Repair well 0 ' Plug PerfQrationa 0 Stimulate 0 Time Extension 0 - Cnlilnge approved program 0 Pull M ~erforatÐ New Pool 0 Re-enter Suspendad Well 0 .- 2, Operator Name: \b~ 4. Current well CI88&: 5. Permil to Drill Number~ ßP I::xpjoratlon (Alaljtlil), Inc. Development [J E)Cf>loratory [J 193-1540 , 3. Address; lox 196612 Stratigraphic [J Service iii e. API Number. Anchorage. AK 99519-6612 I 50-029-22409-00-00 . 7. KB Elevation (It): 9, Well Name and Number: 47.5 KB P2·15 - Property Designation: 10. FieldlPoOls(s): f£..#~1oC.. 0;( ADLO-365548 ' Point Mcintyre Pool FIeld /..Rwd~CMI 1tI Pool..è1> ¡.,¿ ~_.? 11. PReSeNT WELL C~PITION SuMMARY Total Deptn MD (II): ITotal Depth "f'VD (It): IEftectlve Depth MD (It): Ellectiv9 Depth TVD (It): IPlugl (measured): -JUnk (measured): 12220 . 9278 ( 12125 9211 None None easing Length Size MD TVD Buret cOllapee Conductor 80' 20" 91.5# H-40 33' 113' 33' 113' 1490 470 Surface 4348' 10·3/4" 45.5# NT-80 32' 4380' 32' 3663' 5210 2480 Production 12182' 7-518" 29.1# NT·95 28' 12210' 31' 9271' 8180 5120 Perforation Depth MD (ft): Perforation Depth TVD (It): Tubing Size: lublng Grade: rublng MD (It); 11'790' - 11830' 8969' - 8999' 4-1/2" 12.6# L-80 29' - 11727' 11920'·11970' 9084' . 9100' - - Packers and sssv Type: 4-1/2" Cameo TRDP SSV Packers ¡¡¡nd sSSv MD (It): 2255 7-5/8"x4-1/2" Baker SABL-3 plilCkar 11655 0 0 0 0 12. Attachments: DescriDtiva Summary of Proposal ~ 13. Well Class after Pf'QPOaad WOI'k: Detailed Operations Program 0 BOP Sketch D E)Cf>loratory [J Del/lillopment [J Service iii 14, Estimated Date lor 15. Well Status after proposed work: Commencing Operations: 1/24/2007 Oil [] Gas [] Plugged [J Abandoned [J 16. Verbal Approval: Date: WAG [J GINJ [J WINJ fa WDSPL [J Comm;nion Aepresentliltive: Prepared by l:JI;IIY t',øule 564-4944 17. I ner'éby certify that the loregoing il; true and corret:110 the be6t of my knowledge. Contact Roøø Wamer Printed Name Ross Wlilmer A_ // Title Production Enoineer Slgnatute C-Jn _. _ ~ ./.JIhA - chAne 564-5359 Date 1/2312007 COMMISSION USE ONLY Conditions of approval: Notlly Commissjon so that a representative mey witness SUndry Numb9r: 3>0~-O3\ Plug Integlity 0 BOP Test 0 Mechanical Integrity Test 0 Locallon Clearance 0 Other: ?'-'o\~~Ù~Q:"\-~\"Ct-- C>~ 5*'i~\)-AÛ~ \-0 S\.J~C(L(µ<>\~ . ... .C 1'10\\ ~ 3A,,>~"-c.~D~D\,V T»N.-\ì \0 Ç> '\ \::."-'> ~ ,>, --~ ~~D' ¥:> ç-e:~" , S_"'Fo~_;"" '-\O~i APPROVED BY /.. tt/--tJ:;- Approved by; } ) ~MMISSIONER -ru.... , SION Date: - LOOl ~, ~NVI~ '~ '-- .=.= .,. c!/'"\IY .,;, 'f dJUl ....... þb 1·Z.~·0 Form 10-403 Revi;ed 11/2004 E0 3Ð'itd _ ORIGINAL :~lN8 'itl'ita-H8310~13d 900ÞÞ99L06 7 Submit in Duplicate 90:L1 L00G/EG/10 . . bp o GP8 Greeter Prudhoe Bey Date: 1/23/07 To: AI.sk. Oil. Gas Conservation Commision From: Ross Warner - Production Engineer Subject: P2-15i Application for Sundry Approval Approval Is requested for a nonrig repair of the surface casing leak in P2-151. .- Further investigation hEl8 indicated thElt the leak is very close to the surface- If excessive damage If found after removal of the casing, we propose to re-assemble the conductor and proceed as described In approved Sundry 307-008 for a rlg- repair. All Welding Procedures are to be prepared by a Mechanical Engineer. The casing cut is to be perfonned shortly after the well Is circulated to water. - Estimated time for the cut Is January 24.2007. ~w~ Ross Warner Production Engíneer Office: 564-5359 Cell: 250-3441 P2·151 Applioatian far Sundry l0 3Ð'ï1d :~lNJ-'ï11'ï1a-HJ310~13d S00ÞÞ9SL06 S0:Ll L00l/El/10 . . P2~151 Description Summary of Proposal: Pre Work Completed: 1) 1/21/06: MIT-IA to 3000 psi, Passed. 2) 1/5/07: Eval surface casing leak depth - Found fluid misting from bottom of the conductor landing ring flute at the threaded connection. 3) 1/16/07: Removed gravel in cellar to - 5' depth. 4) 1/20/07: Bled OA to zero. Monitored overnight. . Proposed Procedure Summary: 1) RU Slickline. SetTTP. Pull GLV in station #2. 2) Circulate well to water. CMIT TxlA to 3000 psi. 3) Bleed all pressures to zero. 4) Depress tubing and IA fluid levels with N2. . 5) Establish double block and bleed on flowline. (No AL line present). 6) Remove several feet of conductor with WACHS (cold work) cutler. Lower landing ring. Inspect leak point. If damage is too extensive for nonrig repair, skip to step 11. 7) Purge OA with N2. Monitor for LEL per hot work permit requirements. 8) Perform surface casing weld per Welding Procedure. 9) Inspect surface casing weld. 10) MIT -OA to 1000 psi. 11) Re-establish purge as before. Re-assemble conductor pipe and landing ring. Weld per Welding Procedure. 12) Inspect conductor welds. 13) Backfill cellar with gravel. Þ0 39'ii'd :~lN8-'ii'1'ii'a-H8310~13d 900ÞÞ99L05 90:Ll L00l/El/10 Re: P2-15 (193-154) . . Hi Mike, This confirms "verbal approval" to proceed with the excavate and cut work on P2-15 (193-154). Tom Maunder, PE AOGCC Warren, Mike wrote, On 1/2312007 3 :32 PM: Hello Tom: Here is my-Email per our conversation. Please "reply to all" with approval to proceed with the conductor/casing work. Thanks, Mike Warren 1 of 1 1/23/2007 4:04 PM 1'.t::. r £'-1 J ùlU 1al.,v va;:)u15 YV '-'lU '.......""" Andrea, Referring to the "task matrix" attached to the workover conservation order (CO 556), in the middle column of page 4 it is indicated that a 403 is not needed however a 404 is required when the work is completed. _ _ ___.&Jo.__ _ - Call or message with any questions. Tom Maunder, PE AOGCC 6CANNED JAN 16 2007 Hughes, Andrea wrote, On 1/16/20077:29 AM: Tom, We have identified a thread leak on the top pup of the surface casing on Well P2-15 (PTD 1931540). Our plan is to seal weld the connection and I need to verify if a 10-403 is required. Thank you, Andrea Hughes Well Integrity Coordinator Office: (907) 659-5102 Pager: (907) 659-5100 x1154 J of J 1/16/2007 10:53 AM '4t . SARAH PALIN, GOVERNOR AltA.SIiA OIL AND GAS CONSERVATION COltDllSSION 333 W 7th AVENUE,SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Greg Hobbs Senior Drilling Engineer BP Exploration (Alaska), Inc. PO Box 196612 sCANNED JAN 1 9 2007 Anchorage, AK 99519-6612 / \5Üt \~?J Re: Prudhoe Bay Field, Point McIntyre Oil Pool, Well Name: P2-15 Sundry Number: 307-008 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 Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. DATED this Q¿'day of January, 2007 Encl. ¡A01 ~ \\\ D~ ¡lIb r 7 Cv::r-I/71 ,07 .ßH. .. STATE OF ALASKA ~//-a? RECEIVE ALASKA OIL AND GAS CONSERVATION COMM.ON t_, APPLICATION FOR SUNDRY APPROVA~'2-.JAN 0 4 20 MC 25 280 1. Type of Request: o Abandon o Alter Casing o Change Approved Program o Suspend ~ Repair Well ~ Pull Tubing o Operation Shutdown o Plug Perforations o Perforate New Pool o Perforate o Stimulate o Waiver f;$fq,¡>,~_1.!. !¡lIt. Q( .\,I.G.'} \.IV! "e;" I,P"",,, ¡¡,,;,,, iI., W lime t:xten~lon h Hnc mage ORe-Enter SuspendedWell o Other 2. Operator Name: BP Exploration (Alaska) Inc. 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 7. If perforating, closest approach in pool(s) opened by this operation to nearest property line where ownership or landownership changes: Spacing Exception Required? 0 Yes 181 No 9. Property Designation: 10. KB Elevation (ft): ADL 365548 / 47.5' I (,1;'22'1\:,'(: Total Depth MD (ft): 12220 'r Casino Structural Conrluctnr Surface Intermediate Production Liner 4. Current Well Class: o Development 0 Exploratory o Stratigraphic 181 Service 5. Permit To Drill Number 193-154 J 6. API Number: 50-029-22409-00-00 .; 8. Well Name and Number: P2-15 if Total Depth TVD (ft): Effective Depth MD (ft): 9278 12125 Lenath Size 11. Field / Pool(s): ( Prudhoe Bay Field / Point Mcintyre Pool - ~ Effective Depth TVD (ft): Plugs (measured): Junk (measured): 9211 None None TVD Bur~ CollaDse MD 80' 4348' 20" 10-3/4" 80' 4380' 80' 3662' 1490 5210 470 2480 12182' 7-5/8" 12210' 9271' 8180 5120 Perforation Depth MD (ft): I Perforation Depth TVD (ft): I 11790' - 11970' 8969' - 9100' Packers and SSSV Type: 7-5/8" x 4-1/2" Baker 'SABL-3' packer Tubing Size: 4-1/2", 12.6# Tubing MD (ft): 11727' 13. Attachments: 181 Description Summary of Proposal 0 BOP Sketch o Detailed Operations Program 15. Estimated Date for Commencinç¡ Operations: 17. Verbal Approval: Commission Representative: 18. I hereby certify that the foregoing is true and correct to the best of my knowledge. Printed Name Greg Hqqbs / Title Senior Drilling Engineer RfIIt Tubing Grade: L-80 I Packers and SSSV MD (ft): 11655' 14. Well Class after proposed work: o Exploratory 0 Development 181 Service January 25, 2007 Date: 16. Well Status after proposed work: o Oil 0 Gas o WAG 0 GINJ o Plugged ~WINJ o Abandoned o WDSPL Contact Kris Honas, 564-4338 Signature Phone 564-4191 Date ,f¥!o:t Prepared By Name/Number: Terrie Hubble, 564-4628 ~7 ~. Commission Use Only Conditions of approval: Notify Commission so that a representative may witness o Plug Integrity 1.SOP Test ~echanicallntegrity Test 0 Location Clearance Other: 4 c;OO r::2!r'\ \ 'J' 1(">\ 'YJ yo -\.c<:,",", . ÆJ Subsequent Form Required: L.töY ~r II Approved By: W 'hhoMMISSIONER Form 10-403 Revised06l2006 V ~~ R\ , I N A L I Sundry Number: . ?n/.. ~K- RBOMS 8Ft JAN 1 8 2007 APPROVED BY THE COMMISSION Date 1-/1,. ~ 0 r Submit In Duplicate . . To: Alaska Oil & Gas Conservation Commission Date: January 2,2007 From: Kristopher Honas - BPXA GPB Rotary Drilling Engineer Subject: P2-15i Application for Sundry Approval Approval is requested for a rig workover planned on P2-15. This well is a Kuparuk injector that was suspended due to a surface casing leak on 9/24/06. A rig workover is required to bring the well back on water injection with future MI injection capabilities. The repair will include cutting the 7-5/8" production casing above 4400' MD. New 7-5/8" casing will then be ran and fully cemented to surface. The tubing will also be replaced from a cut above the packer at 11,635' MD. The new tubing will be 4-1/2" TCII with a "stacker packer" completion. This work over is currently scheduled for Nabors 7es at the end of February. The date will depend on the completion of an ice road to the PM2 pad. Pre-rig work will start after Sundry approval has been obtained. Estimated Pre-Rig Start: Estimated Spud Date: 01/25/07 02/25/07 Kristopher E. Honas GPB Rotary Drilling Engineer Office: 564-4338 Cell: 440-2389 P2-15i Application for Sundry . . P2-15 RWO Procedure Summary Pre-Rig Work: 1. Bleed OA, IA & T to zero psi. PPPOT - T & IC. Function all LDS and repair / replace as necessary. 2. Drift 4-1/2" tubing for the chemical cutter and fast drill plug down to the W-Ieg. Run a standard bottom hole pressure survey. 3. Set a fast drill plug below the packer at -11664' MD. 4. Run a caliper log in the 4-1/2" tubing. 5. String shot and punch the tubing. Chemical cut the 4-1/2" L-80 tubing at -11635' MD near the top of the second pup joint above the packer. Reference the tubing tally dated 3/8/94. 6. Circulate the well bore clean with seawater. Freeze protect the well with diesel (-2000' TVD). CMIT T x IA to 4500 psi for 30 minutes. 7. Set a back pressure valve in the tubing hanger. 8. Remove the well house, remove the flow lines and level the pad as needed. Proposed Procedure Summary: 1. MI/RU Nabors 7es. 2. CMIT TxlA to 4500 psi for 30 minutes. 3. Pull the back pressure valve and circulate out the diesel freeze protection, displace the well with 9.2 ppg brine KWF (note: there is not kill weight fluid in the well prior to pumping out freeze protect). 4. Monitor the OA, IA and tubing pressure to confirm well is dead. 5. Set the TWC. ND tree. NU BOPE and pressure test. Pull the TWC. 6. Pull and LD the 4-1/2" 12.6# L-80 tubing from the chemical cut at -11635' MD. 7. RU Schlumberger E-line and run USIT. The USIT will be used to confirm that top of cement is below -3500' MD behind the 7-5/8" casing. 8. Set a retrievable bridge plug in the 7-5/8" casing at -4100' MD (or a minimum of 600' below the cut depth determined from the USIT log). Test the RBP to 1000 psi to confirm a competent seal. Turn the well over to 9.8 ppg brine and spot 50' of sand on top of the RBP. 9. Use a hydraulic multi-string casing cutter to cut the 7-5/8" casing in the middle of a full joint at -3500' MD. Circulate up the 7-5/8" x 10-3/4" annulus with brine. 10. Spear the 7-5/8" casing and POOH. 11. RIH with a back off tool and back out the 7-5/8" casing stub at the nearest collar. RIH with a spear and remove the stub. 12. RIH with new 7-5/8" 29.7# L-80 TCII casing. Screw the guide-shoe into 7-%" casing. Pull the casing into 250K tension. Decrease tension to 1 OOK and pressure up to -1050 psi to set the external packer. 13. Continue to pressure up to 3500 psi recording on chart and shearing open the ES cementer. RU Schlumberger cementing and pump 160 bbls of 15.8 ppg class G cement to surface (139 bbls + 15% excess). 14. Break the stack and set the emergency slips as per wellhead specialist. Cut the 7-5/8" casing with Wachs cutter. 15. NU BOPE and test the new 7-5/8" packoff to 3800 psi (80% of casing collapse). 16. RIH with clean-out milling assembly and drill out the ES cementer. Continue milling down to the sand on the RBP. 17. Pressure test the casing to 4500 psi. 18. RIH with RBP retrieving tool. Reverse off excess sand until returns are clean, latch and unseat the RBP. 19. PU 3-3/4" bladed junk mill assembly. Drill out the fast drill plug set at -11664' MD and push it through the bottom of the 4-1/2" tubing. POOH displacing with 9.2 ppg brine. 20. RIH with 4-1/2" 12.6# L-80 TCII tubing with stacker packer configuration. 21. Land the tubing hanger and RILDS 22. Drop the ball and rod and set the packer. Test the tubing to 4500 psi. Bleed pressure to 2000 psi and test the IA to 4500 psi. Shear the DCK valve. P2-15i Application for Sundry . . 23. Set the TWC and test to 1000 psi. ND BOPE. NU tree and test to 5000 psi. 24. Freeze protect the Tubing and IA to -2000' TVD with diesel. Install a BPV and test to 1000 psi. 25. RD/MO. Post-RiQ Work: 1. Install wellhouse and flowlines. 2. MIRU slickline. Pull the ball and rod / RHC plug from 'X' nipple below the new production packer. Well Coordinates: Surface Location: Bottom Hole Location: X = 681,407 X = 688,127 Y = 5,998,559 Y = 6,004,027 P2-15i Application for Sundry TREE = . WELLHEAD = ACTUA TOR = KB. ELEV = BF. ELEV = KOP= Max Angle = Datum MD = Datum1VD = CrN FMC BAKER C 47.5' 10.45' 987' 48 @ 4042' 11623' 8800' SS 110-3/4" CSG, 45.5#, NT-80, ID = 9.953" Minimum ID = 3.75" @ 117 OTIS XN NIPPLE 14-1/2" TBG, 12.6#, L80, .0152 bpf, ID = 3.958" . .FETY NOTES: P2-15 . 2255' 1-1 4-1/2" CAMCO TRDPSSSV, ID = 3.812" I I 4380' -µ ~ GAS LIFT MANDRELS ST MD 1VD DEV TYÆ VLV LATCH PORT DATE L 1 4805 3970 48 OTIS BK OS' 2 11597 8827 43 OTIS BK . . 11634' H 4-1/2" OTIS X NIP, ID = 3.813" I :8 'o:::;:¡::> J 11655' H 7-5/8" X 4-1/2" BAKER SABL-3 PKR. ID = 3.875" I c;...;> I 11689' H 4-1/2" OTIS X NIP, ID = 3.813" I I I I I 11705' H 4-1/2" OTIS XN NIP, ID = 3.75" I I 11727' I 11727' H 4-1/2" TUBING TAIL, WLEG I 1 11718' H ELMD IT LOGGED 03/26/94 I I j 0' perf data DATE 07/21/94 07/21/94 I 12125' I I 12210' I ÆRFORA TION SUMMARY REF LOG: DIL ON 03/05/94 ANGLEATTOPÆRF: 43 @ 1179 Note: Refer to Production DB for historical SIZE SPF INTERV AL Opn/Sqz 3-3/8" 6 11790 - 11830 0 3-3/8" 6 11920 - 11970 0 DATE 03/08/94 07/22/04 01/08/06 07/04/06 09/24/06 PBTD I 7-5/8" CSG. 29.7#, NT-95, ID = 6.875" REV BY COMMENTS ORIGINAL COM PLETION A TD/TLP WAIVER SAFETY NOTE EZLlPJC 7-5/8' CSG CORRECTION RDW/PAG WAIVER SAFETY NOTE RDW/PAG WAIVER SFTY NOTE DELETED DATE COMMENTS POINT MCINTYRE UNrT WELL: P2-15 ÆRMrT No: '1931540 API No: 50-029-22409-00 SEC 14, T12N, R14E, 599.28' FEL & 4005.61' FNL REV BY BP Exploration (Alaska) TREE =<' E LLHE /!D= ACTUATOR= KB. ELEV= BF. ELEV = KOP = Max Angle = Datum MD = Datum TVD= CIW FMC BAKE R C 47.5' 10.45' 987' 48 @ 4042' 11623' 8800'SS P'15 Proposed Minimum ID = 3.75" @ 11705' OTIS XN NIPPLE PERF ORATION SUMMA.RY REF LOG: D IL ON 03105.94 ANGLE AT TOP PERF: 43 @ 11790' Note: Refer to Production D 8 for historical SIZE SPF INTERV/Il 0 rv'S 3·315" 6 11790-1183) 0 3·315" 6 11920-11970 0 e rf data DATE 7121/1994 7121/1994 . -1 3500' I 10-314" CSG, 45.5#, NT-80, 10 = 9.953 I IT 2 1 OM UFT NUIIDRELS NÐ TW TYPE VLV 5542' 450(1 KBG-2 SV 9070 700(1 KBG-2 DV DATE 11530' 4-1/2" HES 'X' NIPPLE 10 = 3.813" 11551' H 7-5/8" BKR S-3 PKR, 10 = 3.875" 11575' 4-1/2" HES 'X' NIPPLE 10 = 3.813" 11635' 11655' 7 5/8" X 4-1/2" BKR SABL-3 PKR 10 3.875" 11689' 4-1/2"OTIS'X'NIPPLE 10=3.813" 11705' 4-1/2" OTIS 'XN' NIPPLE 10 = 3.75" 11 727' I PBTO I 7-518" CSG 29.7# NT-95 10 = 6.875 DATE REV BY COMMENTS DATE REV BY COMMENTS 3ß/1994 ORIGINAL COMPLETION 7122/2004 ADTITLP WAIVER SAFETY NOTE 118rJJffi EZUPJC 7-5/'ò' CSG CORR EC TION 7/4/IJffi RDW IPAG 7·5/'ò' CSG CORR EC TION 912412006 RDW IPAG WAIVER SAFETY NOTE DELETED 11/14/IJ06 KEH RW 0 Point Mclntve Un~ WELL: P2·15 P EJ;MrT No: 1931540 .API No: 50-029-22409-00 Sec 14 T12N R14E 599.28' FEL&4û05.61' FNL • f~.anr~ aa. ~uRa~o~vs~~, cov~RwoR 333 W. T" AVENUE, SUI'E 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 =AX (907} 276-7542 ~py0y~~~Ll~1~~®I~A A>Div><hv><sTxAT~~~>E apP~®vA~. ~®. AI®a>F.ooz Ms. Anna Dube, Well Integrity Coordinator ~~ BP Exploration (Alaska) Inc. Attn: Well Integrity Engineer, PRB-2~ ~ P.O- Box 196612 `~( ~f,~~~~ JAN Q ~ 200$ Anchorage, AK 99~ 19-6612 RE: Cancellation of Administrative Approval AIO 04E.002 (Well Lisburne P2-1~) Dear GIs. Dube: Pursuant to BPXA's request dated October 10, 2006 AOGCC hereby cancels Administrative Approval AIO 04E.002, which allows water injection in well Lisburne P2-1~. This well exhibited a surface casing leak, and BPXA did not at the time propose repairing the well to eliminate the problem. The Commission determined that water injection could safely continue in the well, but subject to a number of restricti~~e conditions set out in the administrative approval. Since then, BPXA has determined that Lisburne P2-1Ss condition has deteriorated to the point that safe operation is no longer supported. The well will remain shut in for evaluation of repair options. Consequently, Administrative Approval AIO O~E.002 no Longer applies to operation of this well. Instead, injection in well Lisburne P2-1 ~ will be governed by provisions of the underlying Area Injection Order Lo. 3. ®ONE at Anchorage, Alaska and dated ®ctober 15, 2006. The Alaska ®il and Gas Conseevati®n C®~nrnission ~ ; ~. ~'~-~`' ~~Jo K;~rorman Cathy F erster ~~ Chairman Commissioner ~y yet - ~ 'r~~~^~p~~ a ~+ ~jF'~T AI)iVdINISTRATIVE APPROiTE~L 4E, 0~+2 vtr. Steve Rossberg Wells Manager BP Exploration (Alaska) Inc. P.O. Box 196612 anchorage, AK 993 1 9-66 1 2 333'rV. T"AVENUE, SUITE 100 ANCHORAGE, ALASKA 9950-3539 ?HONE (907} 279-1433 FAX (9C7} 276-7542 RE: Lisburne P2-1 ~ (PTD 193-1 ~4) Request for administrative Approval Dear ~Ir. Rossber~: Pursuant to Rule 9 of Area Injection Order ("AIO"} 04E.000, the Alaska Oil and Gas Conservation Commission ("AOGCC" or "Commission") hereby grants BP Exploration (Alaska) Inc. ("BPXA")'s request for administrative approval to continue water injection in the subject well. AOGCC finds that BPXA has elected to perform no corrective action at this time on Lisburne PZ-1~. The Commission further finds that, based upon reported results of BPXA's diagnostic procedures, Lisburne P2-I5 exhibits two competent barriers to release of well pressure. Accordingly, the Commission believes that the well's condition does not compromise overall well integrity so as to threaten the environment or human safety. AOGCC's administrative approval to continue water injection in Lisburne P2-1~ is conditioned upon the following: 1. BPXA shall record wellhead pressures and injection rate daily; 2. BPXA shall submit to the AOGCC a monthly report of well pressures and injection rates; ~~ FRArVK h. r~lURi(OWSPCI, GOVERr•IOR 3. BPXA shall perform an annual MIT - IA to 1.2 times the maximum anticipated well pressure, the anniversary date of which shalt be this approval's effective date; • qtr ~~~v~ t2ossber~ stay ! 8, 2006 P3~Z ~ OC ~ 4. BPXA shall immediately shut in the well and notify the AOGCC if there is any change in the well's mechanical condition; and ~. after well shut in due to a change in the we11's mechanical condition, ~OGCC appro~•al shall be required to restart injection. .~s provided in AS 31.0.080, 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 tilt with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PSI on the 23rd day following the date of this letter, or the next working day if the 23rd day fails on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. DONE at ~n~ho, _;~laska and dated ':vlay 18, 2006. Chairman '~~ ~ ~~' Cathv~ . Foerster Commissioner Well P2-15 (PTD #1931540) Classified as Tie - Cancel Waiver All, The waiver for well P2-15 been cancelled and the well has been reclassified as Trouble. The waiver process relating to wells with surface casing leaks has been reviewed and the finding is that GPB will no longer waiver these types of wells. Lead Operator: Will you please ensure any waiver related signage is removed from the well house. Please call with any questions. Andrea Hughes (Filling in for Joe Anders) Well Integrity Engineer Office: (907) 659-5102 Pager: (907) 659-5100 x1154 ~~!E[) 'Ï ,~., 1 of I 9/25/2006 10:52 AM Recently approved waiver for P2-15 (PTD #1931540) e Jim and Winton, Please see the attached waiver for P2-15 (PTD #1931540). «P2-15 SC Leak waiver notice 06-06-06.pdf» If you have any questions, please don't hesitate to call. Thank you, }lnna (j)u6e Well Integrity Coordinator GPB Wells Group Phone: (907) 659-5102 Pager: (907) 659-5100 x1154 C t t D . t· . P2-15 SC Leak waiver notice on en - escnp Ion. 06-06-06.pdf SC Leak waiver notice 06-06-06.pdf Content-Type: application/octet-stream Content-Encoding: base64 1 of 1 7/13/20062:37 PM e e Notice of Waivered Well WELL: P2-15 WELL TYPE: Water Injector DATE: 06-06-06 Injection Data: 06/04/06: 14.0 MBWD @ 2264 psi. Pressures: Injecting SI Tubing 2450 psi 340 psi Inner Annulus 140 psi 260 psi Outer Annulus 130 psi 20 psi REASON FOR NOTICE: Surface Casing Leak COMMUNICATION INDICATED BY: · MIT-OA w/N2 Failed @ 270 psi - 11/24/05. TUBING INTEGRITY DEMONSTRATED BY: · MIT-IA Passed to 4000 psi - 04/08/06. PRODUCTION CASING INTEGRITY DEMONSTRATED BY: · MIT-IA Passed to 4000 psi - 04/08/06. IMPORTANT CONSIDERATIONS / COMMENTS: · 2 Levels of protection are competent tubing and production casing tested to at least 1.2 times the maximum injection pressure. · AOGCC issued Administrative Approval (AIO 4E.002) for continued water injection. · OAP limit of 100 psi was assigned to accommodate minor thermal induced pressure changes. · This waiver supercedes the current waiver dated - 07/22/04. PLAN OF ACTION: Any deviation from this waiver must be pre-approved by the Wells Group and the Operations Manager · Water Injection Only - No Mllnjection allowed. · Monitor well head pressures and log daily. · Ensure no LEL in wellhouse or continuous liquid leak to cellar. · Submit a monthly report of injection rate and wellhead pressures to the AOGCC. · Perform the following waiver compliance testing: . Annually conduct an MIT -IA to 1.2x the maximum well pressure. · Stop injection and notify the AOGCC upon indication of compromised integrity. Operating Limits Max lAP = 1000 psi Max OAP = 100 psi )'lnna (j)u6e Well Integrity Coordinator I am approving this document 2006.06.08 13:45:37 -08'00' Date \ Digitally signed by Olsen, Clark A Olsen Clark AJ,DN:CN=Olsen,ClarkA , Ij\Jiç.~on: I am approving this document Date: 2006.06.08 17:22:41 -08'00' Cusack, Louis Åg~~~~~i~nu~~~n~~~c~ LouisA " '~~ason: I am approving this document , 'Oate:2006.06.09 15:19:13 -08'00' Well Operations Supervisor Date Area Manager Date Rossberg, R Steven Digitally signed by Rossberg, R Steven f DN: CN = Rossberg, R Steven gçª~on: I am approving this document DåteJ2006.06.0817:18:02 -08'00' Kurz, John Wells Manager Date Operations Manager Dignally signed by Kurz, John .' ON: CN = Kurz, John ¡,"Rç¡¡son: I am approving this document /./ Oata-: 2006.06.27 22:23:32 -08'00' l/ Date Distribution: OS I Pad Operator OS I Pad Engineer WOE 1. Operations Abandon 0 Repair Well 0 Performed: Alter Casing 0 Pull Tubing 0 Change Approved Program 0 Operat. Shutdown 0 2. Operator BP Exploration (Alaska), Inc. Name: _ STATE OF ALASKA . AlJ1IP. Oil AND GAS CONSERVATION COM ION REPORT OF SUNDRY WELL OPERATIONS o o o (J" W&A- -//2-7/0.c . .. I //~}A.) 1 jJ-.1 J O{ v P.O. Box 196612 Anchorage, AK 99519-6612 7. KB Elevation (ft): Plug Perforations Perforate New Pool Perforate 4. Current Well Class: Development 0 Stratigraphic 0 Stimulate 0 Other 0 Cancel Sundry WaiverD Time Extension 0 Re-enter Suspended Well 0 5. Permit to Drill Number: 3. Address: o 193-1540 V' 6. API Number: L~ 50-029-22409-00-00 9. Well Name and Number: Exploratory Service 47.5 KB P2-15 ADL-365548 11. Present Well Condition Summary: 10. Field/Pool (s): Point Mcintyre Field/ Point Mcintyre Oil Pool 8. Property Designation: Total Depth measured 12220 true vertical 9278.23 feet feet Plugs (measured) Junk (measured) None None Effective Depth measured 12125 true vertical 9210.92 feet feet Casing Conductor Surface Production Length Size MD TVD Burst 80 20" 91.5# H-40 33 - 113 33 - 112.99 1490 4348 10-3/4" 45.5# NT-80 32 - 4380 32 - 3662.48 5210 12179 7-5/8" 29.7# NT-95 31 - 12210 32 - 9271.15 8180 Collapse 470 2480 5120 Perforation depth: Measured depth: 11790 - 11830 True Vertical depth: 8969.12 - 8998.55 11920 -11970 9064.29 - 9100.47 Tubing: (size, grade, and measured depth) 4-1/2" 12.6# L-80 29R1!6f~ Packers and SSSV (type and measured depth) 4-1/2" Camco TRDP SSV 4-1/2" Baker SABL-3 Packer 2aM"JJ~ 2 {} ~J 1.1655 (h¡ "\1 f2. Stimulation or cement squeeze summary: Intervals treated (measured): RBDMS 8Ft APH :¿ 8 7006 Treatment descriptions including volumes used and final pressure: Prior to well operation: Subsequent to operation: 14. Attachments: Copies of Logs and Surveys Run Daily Report of Well Operations Oil-Bbl o o Representative Daily Average Production or Injection Data Gas-Mef Water-Bbl Casing Pressure o 0 0 o 0 0 15. Well Class after proposed work: Exploratory 0 Development 16. Well Status after proposed work: Oil 0 Gas 0 WAG 0 Tubing pressure o o 13. Service IØ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. GINJ 0 WINJ IØ WDSPl 0 Sundry Number or N/A if C.O. Exempt: 304·191 Contact Anna Dube / Joe Anders '¡', Title Well Integrity Coordinator , ~ Phone 907-659-5102 Date 4/20/2006 Form 10-404 Revised 04/2004 Submit Original Only MEMORANDUM e e State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg P.I. Supervisor ~efCl tr/14/0£'" DATE: Monday, April 10, 2006 SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) mc P2-15 PRUDHOE BAY UN PTM P2-15 Src; Inspector \lA.y \~ FROM: Lou Grimaldi Petroleum Inspector NON-CONFIDENTIAL Reviewed By: P.I. Suprv jBr2- Comm Well Name: PRUDHOE BAY UN PTM P2-15 API Well Number 50-029-22409-00-00 Inspector Name: Lou Grimaldi Insp Num: mitLG060408140527 Permit Number: 193-154-0 Inspection Date: 4/8/2006 ReI Insp Num facker Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. P2-15 ¡Type Inj. ! w if TVD ! IA ! I I Well I 8870 30 i 4010 3980 3970 , P.T. ! 1931540 !TypeTest I SPT I Test psi 2217.5 ! OA i 50 48 52 52 I I " ! I Interval OTHER P/F P v/ Tubing I 2160 ! 2200 2180 2170 I I -- Notes Test for waiver application. Known OA compromise at 150 psi. IA appears competent. <' n ,Yo Ç);' Monday, April 10, 2006 Page I of I MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg '}/ I Þ P.I. Supervisor ",,-efr 2. Z4- 0:;- DATE: Monday, January 03, 2005 SUBJECT: Mechanical Integrity Tests BP EXPLORA nON (ALASKA) INC P2-15 PRUDHOE SAY UN PTM P2-15 tK\~ \0\J FROM: Jeff Jones. Petroleum Inspector Src: Inspector Reviewed By: P.I. Suprv ~~~.t!-- Comm NON-CONFIDENTIAL Well Name: PRUDHOE BAY UN PTM P2-15 API Well Number: 50-029-22409-00-00 Insp Num: mitJJ041223162612 Permit Number: 193-154-0 Rei Insp Num: Inspector Name: Jeff Jones Inspection Date: 12/23/2004 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well P2-15 Type Inj. P TVD 8869 IA 0 4000 3970 3970 P.T. 1931540 TypeTest SPT Test psi 2217.25 OA 60 60 60 75 Interval OTHER P/F p Tubing 2125 2120 2100 2120 Notes: MITLA for SOA sundry 304-191. OA was allowed to bleed fluid to open tank while pressurizing IA to prevent exceeding 100 PSI and was then SfI. 1 well house inspected; no exceptions. Well has known leak to surface and cellar is diked with pit liner. SCANNED MAR 1 4: 2.GO~ì Monday, January 03,2005 Page 1 of I ) TREE = WB..LHEAD = A CtÜÁTÖR~" 'Kä'ï~Léi; , , ì3F,'EÜ:\i;' ,. 'KÒp;"" .,. ,., ..."'.. ,.~,~",~,~9.~.,:::,,, . Datum MD = DatumTVD = eM! FMC SA KEFf ë .. ""4'7.'5;' 10:45' ""'9si' .. .,,"... ....... , .".. ..~8,,~,~g~?,:. 11623' 8800' SS 110-3/4" CSG, 45.5#, NT-80, D = 9.953" 1---1 4380' Minimum ID = 3.75" @ 11705' OTIS XN NIPPLE 14-112" 1BG, 12.6#, L80, .0152 bpf, D =3.958" 1---1 11727' 1 PERFORA 1l0N SUMI'v\A.RY REF LOG: OIL ON 03/05/94 ANGLEA TTOPPERF: 43 @ 11790' Note: Refer to Production DB for historical perf data SIZE SPF INTERv' AL Opn/Sqz DATE 3-3/8" 6 11790-11830 0 07/21/94 3-3/8" 6 11920-11970 0 07121/94 1 R3TD 1--4 12125' [7-5/8" CSG, 29.7#, NT-80, 10= 6.875" 1---1 12210' DA TE REV BY COMMENTS 03108194 ORIGINAL COMPLETION 09/15/01 RNITP CORREC1l0NS 07/22/04 ATDITLP WAIVERSAFETY NOTE P2-15 ,J SAFETY NOTES: *** SURFACE CSG LEAK ~ OPER LIMITS: MAX lAP = 2500 PSI; MAX OAP = 100 PSI *** (WANER 07/22/04) ~ :8: 2255' 1-1 4-1/2" CAMCO TRDP SSSV, 10 = 3.812" 1 ~ L GAS LIFT MANDRELS ST MD TVD DEV TYPE VL V LATCH FDRT DA TE 1 4805 3970 48 OTIS BK 2 11597 8827 43 OTIS BK I I 1 11634' 1-1 4-1/2" OTIS X NIP, 10 = 3.813" 1 &-i 11655' 1-17-5/8" X 4-1/2" BAKERSABL-3 PKR, 10 = 3,875" 1 1 11689' 1---1 4-1/2" OTIS X NIP, 10=3.813" 1 I 11705' 1---1 - - 11727' 1---1 1 11718' 1---1 4-1/2" OTS XN NIP, 10 = 3.75" 4-1/2" TUBING TAIL, WLEG 1 ELMO TT LOGGED 03/26/94 1 I ~ DATE REV BY COMMENTS POINT MONTYRE UNIT WB..L: P2-15 ÆRMlT No: 1931540 API No: 50-029-22409-00 SEe 14, T12N, R14~ 599.28' FEL & 4005.61' FNL BP Exploration (Alaska) ( l ( BP Exploration (Alaska) Inc. Attn: Well Integrity Engineer, PRB-24 Post Office Box 196612 Anchorage, Alaska 99519-6612 ò May 18, 2004 Mr. Winton Aubert, P.E. Alaska Oil & Gas Conservation Commission 333 W. 7th Ave. Anchorage, Alaska 99501 RECEIVED MAY 2 0 2004 Alaska Oil & Gas Cons. Commission Anchorage Subject: P2-15 (PTD 1931540) Application for Sundry Approval for PWI with surface casing leak. Dear Mr. Aubert: Attached is Application for Sundry Approval form 10-403 for well P2-15 requesting approval to continue injection into a water injection well with a surface casing leak to the conductor. If you require any additional information or clarification, please contact Anna Dube or Joe Anders at (907) 659-5102. SincerJr' ~N~~ Anna Dube Well Integrity Coordinator Attachments Application for Sundry Approval form 10-403 Description Summary of Proposal Wellbore Schematic ORIGINAL 1. Type of Request: Abandon D Alter Casing D Change Approved Program D 2. Operator Name: VJ(ÍR- & I i4!z.CJo4- í STATE OF ALASKA ( P7-S b! Ie; /1 ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVAL 20 MC 25.280 Suspend D Repair Well D Pull Tubing D Operation Shutdown D Plug Perforations D Perforate New Pool D 4. Current Well Class: 3. Address: P.O. Box 196612 Anchorage, Ak 99519-6612 7. KB Elevation (ft): 47.50 KB 8. Property Designation: ADL-365548 Development D Exploratory D PerforateD WaiverŒ) Annular DisposalD StimulateD Time ExtensionD OtherD Re-enter Suspended WellD 5. Permit to Drill Number: 193-1540 /' BP Exploration (Alaska), Inc. 11. Total Depth MD (ft): ITotal Depth TVD (ft): 12220 9279.2 Casing Length /' 6. API Number 1"/ StratigraphicD Service ŒJ 50-029-22409-00-00 9. Well Name and Number: P2-15 /' 10. Field/Pool(s): pt Mcintyre Oil Field / pt Mcintyre Oil Pool PRESENT WELL CONDITION SUMMARY I Effective Depth MD (ft): I Effective Depth TVD (ft): 12125 9164.4 S~ MD WD Conductor 80 Surtace 4348 Perforation Depth MD (ft): 11790 - 11830 11920 - 11970 Packers and SSSV Type: 4-1/2" Baker SABL-3 Packer 4-1/2" Cameo TRDP SSV 12. Attachments: Description Summary of Proposal D 20" 91.5# H-40 10-3/4" 45.5# NT-80 Perforation Depth TVD (ft): 8969.1 - 8998.6 9064.3 - 9100.5 top 33 32 bottom top 113 4380 Tubing Size: Plugs (md): Junk (md): None None Burst Collapse 33.0 32.0 bottom 113.0 3662.5 Tubing Grade: L-80 1490 5210 Tubing MD (ft): 29 470 2480 4.5 " 12.6 # 11727 Packers and SSSV MD (ft): 11655 2255 13. Well Class after proposed work: Detailed Operations Program Œ} BOP Sketch D ExploratoryD DevelopmentD Service ŒI ..-,,,, 14. Estimated Date for Commencing Operation: 16. Verbal Approval: Commission Representative: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Date: 15. Well Status after proposed work: Oil D GasD WAG 0 GINJD Plugged D ,Abandoned 0 WINJŒ)I WDSPLD Prepared by Garry Catron 564-4657. June 1 2004 Contact Anna Cube Printed Name Signature c; A~ Dube ), /J ~ Â ..c-t çJ-" ~~ Title Phone Well Integrity Coordinator 659-5102 5/18/04 Commission Use Only Conditions of approval: Notify Commission so that a representative may witness , Sundry Numb5h?i-/9' / , Plug Integrity D "BqP T/estD r Mjc~anciallntegrit}' Test q, L?c~tion Clear~nce 0 -L , { Â.-dd wU! n c. t-t--, 1 ("'1hK<"~,wC1.1IAJcul{ey 11~"t. ~~WCL(4 ~ ':1. Other: Pr7> n ý II. - r It <I-(f:e ý 1 tw (I '" tll/S. A ff HJ \{ 4..1 £AI' f4 V'f S, (p I '1- 6/ 2..Do ¿" Subsequ nt Form equir . ~f- /" ... BY ORDER OF . f;'ð V Approved: .. ~.. ---- THE COMMISSION Date. ~ ORIGI AL I JUN 2. 9 'nnl~ RECEIVED MAY 2 0 2004 Form 10-403 Revised 12/2003 Alaska Oil & Gas Cons. Cornmission Anchorage SUBMIT IN DUPLICATE P2-15 Description Summary of Proposal 05/18/04 - ì Problem: Produced Water Injectol with a surface casing leak to the conductor. ( ~ Well History and status: Well P2-15 (PTD 1931540) has a surface casing leak to the conductor. A MIT-OA failed at 150 psi on 05/06/04 with an audible leak to the conductor. A MIT-IA passed to 3500 psi on 05/14/04 demonstrating competent tubing and production casing. Recent Well Events: > 05/05/04: DSO reported audible leak in conductor while pressuring up OA to 400 ~/ psi to bring back online during conversion from SWI to PWI > 05/06/04: MIT-OA Failed at 150 psi, Audible SC leak close to surface. .--- > 05/14/04: MIT-IA Passed to 3500 psi This Sundry request is to allow for continued water injection in this well. The following supports the request: . A MIT-IA passed to 3500 psi on 05/14/04, indicating the tubing and ,/'/ production casing are capable of withstanding injection pressure. . Pressure and injection rates will be monitored and recorded daily and /~. checked for indications of a tubing or production casing leak. Proposed action plan: 1. Allow well to continue water injection only. 2. Record wellhead pressures and injection rates daily. 3. Perform 2-year MIT-IA. , 4. Stop injection and notify the AOGCC if there is an indication of a loss of tubing or casing integrity. TREE = WELLHEAD = A CTl.1A. TOR = KB. ELEV = BF. ELEV = KOP= Max Ange = Datum MD = DatumTVD = CrN FMC SA KER C 47.5' 10.45' 987' 48 @ 4042' 11623' 8800' SS 110-3/4" CSG, 45.5#, NT-SO. D = 9.953" H 4380' Minimum ID = 3.75" @ 11705' OTIS XN NIPPLE 4-1/2" TBG, 12.6#, L80, 0.0152 bpf, ID = 3.958" 1-1 11727' 1 ÆRFORA llON SUMI'v\l\RY REF LOG: OIL ON 03/05/94 ANGLE AT TOP PERF: 43 @ 11790' Note: Refer to Production œ for historical perf data SIZE SFT INTERVAL Opn/Sqz DATE 3-3/8" 6 11790-11830 0 07/21/94 3-3/8" 6 11920-11970 0 07/21/94 P2-15 8 ~ L I ~ I I SA FEfY NOTES: .\ 2255' H 4-1/2"CAMC01RŒ>SSSV,ID=3.812" I GAS LIFT MANDRELS ST MD TVD DEV TYPE VL V LATCH FORT DATE 1 4805 3970 48 OTIS BK 2 11597 8827 43 OTIS BK 1 11705' 1-1 1 11727' 1-1 1 11718' 1-1 ~ 1 PBTD 1-4 12125' I .~- 1 7-5/8" CSG, 29.7#, NT80, D = 6.875" 1-1 12210' 1-- DATE 03/08194 11/21/00 02/22/01 09/15/01 REV BY SIS-Is I SIS- MD RN/TP COMMENTS ORIGINAL COMA-ETlON CONVERTED TO CANV AS FINAL CORRECllONS DATE REV BY ~ I 11634' 1-1 4-1/2" OTIS X NIP, ID = 3.813" 1 ~ 11655' 1-1 7-5/8" X 4-112" BAKER SABL-3 PKR, ID = 3.875" I CO MrvENTS 1 11689' H 4-1/2" OTIS X NIP, ID = 3.813" 1 4-1/2" OTIS XN NIP, ID=3.75" 4-1/2" TUBING TAIL, WLEG I EUv'D IT LOGGED 03126/94 I PONT MCNTYRE UNIT WELL: P2-15 PERMT f\b: 93-154 API f\b: 50-029-22409-00 SEC 14 T12N R14E 599.28 ÆL 4005.61 FNL BP Exploration (Alaska) MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission THRU: Tom Maunder P.I. Supervisor TO: Camille O. Taylor (-p(~ DATE: July 2, 2002 v Chair SUBJECT: Mechanical Integrity Tests BPX Pt. Maclntyre 2 P2-15, 16, 46 FROM: Jeff Jones PBU Petroleum Inspector Pt. Maclntyre Field NON- CONFIDENTIAL Packer Depth Pretest Initial 15 Min. 30 Min. WellI P2-15 Type lnj.I S I T.V.D. I 88701 Tubing I 1200 I 1200 I 1200 I 1190 Ilntervall 4 P.T.D.I 1931540 Type testI P I Testpsil 2218 I Casingl 8O I 2300 I 229O1 22701 P/FI P Notes: Pre-test pressures monitored 15 min. & stable, Held press, test extra 15 min. & stabilized @ 2270. W~,,I P2-16 I Type,nj.I s I ~.v.~. 18744 ]Tubing I 1200 [ 1200 I 1200 I 1200 I lnterval] 4 P.T.D.I 1931230ITypetestl P I Testpsil 2186 I CasingI 220 I 22601 2240l 22401 P/FI P Notes: Pre-test pressures monitored 15 min. & stable. I I T,,e,.J.I s I I Tub, n, 14 00 14 00 14 00 I,nte,v ,l4 P.T.D.I 1931320 ITypetestl P ITestpsil 2072 I Casingl 50 I 229O1 22901 2250l P/F I P Notes: Pre-test pressures monitored 15 min. & stable. F = FRESH WATER INJ. G = GAS INJ. S = SALT WATER INJ. N = NOT INJECTING M= Annulus Monitoring P= Standard Pressure Test R= Internal Radioactive Tracer Survey A= Temperature Anomaly Survey I= Initial Test 4= Four Year Cycle V= Required by Variance W= Test during Workover D= Differential Temperature Test O= Other (describe in notes) Test's Details July 2, 2002: I traveled to BPX's PM-2 Pad to witness 4 year MITs on water injection wells P2-15, P2-16 and P2-46 in the Pt. Maclntyre Field. Roland Johnson was the BPX representative in charge of testing today and he performed the task in a safe and proficient manner. The pre-test pressures were monitored for 15 min. and were found to be stable. The standard annulus pressure test was then performed on each well, with all three wells passing the MIT's. The pressure test on well P2-15 was held an additional 15 minutes to further demonstrate integrity, and the test pressure stabilized at 2270 PSI. Summary.: I witnessed successful MIT's on BPX's water injection wells P2-15, P2-16 and P2-46 in the Pt. Maclntyre Field, PBU. M.I.T.'s performed: A Number of Failures: 0 Total Time during tests: A Attachments: cc: CANNED JUL ~ i 2_002 MIT report form 5/12/00 L.G. MIT PBU Pt Mac 2-15,16,46 7-2-02 JJ.xls 7/18/2002 ON OR BEFORE C :LOI~.Ixlv~'[LM-DOC c R N I T Ar'e dr'y \*/as the Ar'e we'i'i Weii 'i' s C O H H E N T S p n,3 r. r- I n d 'i' v 'i' d u a 'i ~,,t e 'i I ..... F' a g e" i 'e o i o,~ ~' c a 'i H a t e r' 'i a i s I n v e ~ ....r' y D a t e; 0 t~ / i ~+ / 96 DATA T DATA ...... C, LijS RUN I) ATE ..... RECVD ~RVEY R 0-~-12200, ,3CT J~/~ Ot~/ 19/'9~ ~RVEY.~ D 0-~12072~ GCT~ Ot.~./'19/'9a ~RVEV R 0~-1 1697 ~ H~/D ~*/~ Oz~/ 19/96 ~RVEY D 0 ..... 11697~ HV,/D 04./'19/94 ~..L/,SNL/GR/CAL L 11650'~1218~ I 0~-/'19/9~ ~,ZFL/'GR/'SP L 8700-" 12220 1 04/ 19/94 ~STVD L 11650-~i2220 i 0~¢/ 19/'9~ 1 ~BI'-IP L 11650---12200 I 04/19/94 ~ET L 11580---1211t~ I Oa./ 19/94 ~,SBT L 11580- i2094 '1 04/ 19/94. ~080 T 8700~-12220~ OH--DIFL 0/~/'19/94 JPERF L 11750--12084- '1 09/"29/'9~ d~'tch samp'ies r'equ'i'r'ed? yes ~And i"ece~e.~- nq ... we'i'i cor'ed? yes (~_~_¢na'iys~'s & ciescr'5'pt"l'c,n r'ec~~ yes tests r'equired, s ~ece'i've~}' 'yes n compliance R 0 Date: ARCO Alaska Inc. Greater Point McIntyre Engineering September 29, 1994 Subject: Transmittal Number 745 From: ARCO Alaska, Inc. To:AC)GCC Bob Crandall 3001 Porcupine Drive Anchorage, AK 99501 The following Greater Point McIntyre Area data are enclosed. This information is confidential and your cooperation in maintaining confidentiality is appreciated: Well Name Data Description L3-O1 ..Tubing Puncher Record ~q - · ~ ~f ~2-%Bit and Ring Resistivity · ~ ~.DR-Final ~ xL~ CI~R-Very Enhanced Resistivity-Gamma Ray ~rue Vertical Depth CDR-Final .~I'--14 ~ .injection Profile Log (Press-Temp-SPIN-GR) ~t':21 Injection Profile Log (Press-Temp-SPIN-GR) Perforation Record 2-2/8" Phased EJEI 6 SPF -07 :~or~tmg Record with GR/C£L lewelry Log P~ Perfor. a~ion Record 3-3 A" HSD liB HIII 6 SPF cjP2-1,8/ perforating Record with GR/CCL Jewelry Log ~/P2-21 Perforation Record 3-3/s HSD 4lB H-JU 6 SPF Transmittal Number: 745 Page: Run # Date Run Company 1 9/6/94 Schlumberger 1-12 3/6/94 Schlumberger 1-12 3/19/94 Schlumberger 1-12 3/19/94 Schlumberger 1-12 3/19/94 Schlumberger 8/23/94 Schlumberger 8/23/94 Schlumberger 7/27/94 Schlumberger 7/27/94 Schlumberger 7/21/94 Schlumberger 7/25/94 Schlumberger 7/25/94 Schlumberger 7/22/94 Schlumberger STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown __ Stimulate__ Pull tubing __ Alter casing __ Plugging _ Repair well __ Perforate Other X -- 2. Name of Operator ARCO Alaska, Inc. 3. Address P.O. Box 100360, Anchorage, AK 99510 4. Location of well at surface 21' SNL, 1171' EWL, Sec. 14, T12N, R14E At top of production interval 989' NSL, 690' WEL, Sec. 2, T12N, R14E At effective depth 989' NSL, 690' WEL, Sec. 2, T12N, R14E At total depth 1220" NSL, 633' WEL, Sec. 2, T12N, R14E 5. Type of Well: Development Exploratory Stratigraphic Service 6. Datum elevation (DF or KB) RKB=28' :7. Unit or Property name Point Mclntyre 8. Well number P2-15 9. Permit number/approval number 93-154 /94-204 10. APl number 500292240900 1 1. Field/Pool Prudhoe Bay/Point Mclntyre feet 12. Present well condition summary Total Depth: measured: true vertical: 12220 feet Plugs (measured) None. 9278 feet Effective Depth: measured: true vertical: Casing Length Conductor 80' 4348' Surface Size 20" 10-3/4 12125 feet Junk (measured) None. 9211 feet Cemented Measured depth 260 sx Arcticset (approx.) 80' 1326 sx CS 111/354 sx "G" 4380' True vertical depth 80' 3662' Intermediate 12182' 7-s/8'' 506 sx Class "G" 12210' 9271' Liner Perforation depth: measured 11790-11830', 11920-11970' true vertical 8969-8998', 9064-9100 Tubing (size, grade, and measured depth) 4-1/2'' 12# L80 @ 11727 Packers and SSSV (type and measured depth) Pkr. @ 11655', TRDP SSSV @ 2255' 13. Stimulation or cement squeeze summary Intervals treated (measured) N/A RECEIVED ABchon Treatment description including volumes used and final pressure 14. Prior to well operation Subsequent to operation Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure 1 730 730 8 11 00 n/a n/a 3896 0 Tubing Pressure 529 1087 15. Attachments 116. Copies of Logs and Surveys run ~ Daily Report of Well Operations ~ Oil__ Gas 17. I hereby certify that the foregoing is tr~ue ¢igd~rrect to the best of my knowledge. S'g~ ned Evan L. Rael ~ tie Engineer' Form 10-404 Rev 06/15/88 Status of well classification as: Suspended Service x SWI Date September 22, 1994 SUBMIT IN DUPLICATE P2-15 Daily Report of Well Operations 08/15/94 8/12/94 8/14/94 08/27/94 08/28/94 P2-15 WIRELINE RAN MEMORY PRESSURE GAUGES IN PREPARATION FOR PBU. P2-15 SI FOR PBU. P2-15 WIRELINE PULLED MEMORY PRESSURE GAUGES. P2-15 STATE WITNESSED MIT COMPLETED, PASSED. P2-15 STARTED WATER INJECTION. RECEIVED ' & Gas(jvn~. ', . , , {,otnm~ss~on ~liohor~ . . STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test OPERATOR: Arco A/aska lr~. FIELD I UNIT I PAD: Pt, t,~ / P2 DATE: ~ 8~27~94 COMMENTS: ! IC~ME~TS: ~ ~ ~~ i= 10. 5 ~ / .~ ~M. ' .......... :COMMENTS: 'TUBING INJECTION FLUID: P = PRODUCED WATER INJ. 8 = SALT WATER INJ M = MISCIBLE INJ. I = INJECTION N = NOT INJECTING RECEIVED c- DItII c - Tdp RI:Il Fill C - tnq:~ .,::_ ;:k~,,:i ,:, ,~ Gas Cons. Commission A 3chor~ ...~ ANNULAR FLUID: P.P.O. Grad. WELL TEST: DIESEL 6.8 0.35 Initial X GLYCOL 0.00 4 - Year SALT WATER 0.00 Workover _ DRILLING MUD 0.00 Other OTHER 0.00 At)GCC REP SIGNATURE OPERATOR REP SIGNATURE J29HH1BD.XLS ,~ C, Pltlr, Ak)nz~l_O,.~ 1 ..[Rev' STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION CuMMISSION WELL COMPLETION OR RECOMP LETION REPORT AND LOG 1. Stalus of Well Classification of Service Well OIL [] GAS [] SUSPEI,,~ED [] ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number ARCO Alaska, inc. 93-154 3. Address E~. APl Number P. O, Box 196612, Anchorage, Alaska 99519-6612 5o- 029-22409 4. Location of well at surface 9. Unit or Lease Name 21'SNL, 1171'EWL, SEC. 14, T12N, R14E -~'~.--~. ~~¥-'~;,;~ Mclntyre ~ ¢;0),JPL ~T,~ Point At Top Producing Interval 1008' 5. Elevation in feet (indicate KB, DF, etc.) ~6. Lease Designation and Serial No. KBE = 46.5' I ADL 365548 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. 115. Water Depth, if offshore 116. No. of Completions 2/19/94 3/5/94 7/21/94I N/A feet MSL I One 12220' MD/9264' TVD 12125' MD/9228' TVD YES [] N3 [] 2251' feet MD 1750' (Approx.) 22. Type Electric or Other Logs Run GR/CNL/ZDL/DIFL/MWD 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 20" 91.5# H-40 Surface 80' 30" 260 sx Arcticset (Approx.) 10-3/4" 45.5# NT-8OLHE 32' 4380' 13-1/2" 1326 sx CS 111/354 sx "G" 7-5/8" 29. 7# NT-95HS 28' 12210' 9-7/8" 506 sx Class "G" 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MDI PACKER SET (MDt Gun Diameter 3-3/8" 6 spf 5-1/2", NT-80 11723' 11651' MD TVD (ss) 11920'-11970' 9016'-9051' 11790'-11830' 8922'-8904' .~6. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 27. PRODUCTION TEST Date First Production IMethod of Operation (Flowing, gas lift, etc.) 7/22/94 I FIowing Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF ¢/ATER~BBL CHOKESIZE IGAS-OIL RATIO I TEST PERIOD Flow Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF ~VATER-BBL OIL GRAVITY-APl (corr) Press. 24-HOUR RATE 28. CORE DATA Brief description of lilhology, porosity, fractures, apparent dips, and presence of oil, gas or water. Submit core chips. RECEIVED AJaska Oil & Gas Cons. Commission gnch0rage. Form 10-407 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE -~. 30. GEOL~ MARKERS ~'.ORMATION TESTS NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Subsea Colville Group 8830' 6779' Kalubik 11772' 8909' Kuparuk 11788' 8921' RECEIVED AU ; - 5 1994 A~sk~ 0ii & Gas Cons. Commission Anchorage--: 31. LIST OF A'I-I'ACHMENTS 32, I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ~~ Title OrJllJnoEnclineerSu.Dervisor Date - / 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 OPERATIONa PAGE: 1 WELL: PM2-15 BOROUGH: NORTH SLOPE UNIT: POINT MCINTYRE FIELD: POINT MCINTYRE LEASE: API: 50-029-22409 PERMIT: APPROVAL: ACCEPT: 02/18/94 05:00 SPUD: 02/19/94 04:30 RELEASE: 03/07/94 05:00 OPERATION: DRLG RIG: DOYON 14 WO/C RIG: 02/19/94 ( 1) PU BHA %1. TD: 110'( 0) 02/20/94 ( 2) TD: 1198' (1088) 02/21/94 (3) TD: 3585'(2387) 02/22/94 ( 4) TD: 4400' ( 815) 02/23/94 (5) TD: 4400' ( 0) MW: 8.5 VIS: 33 TURNKEY RIG MOVE F/P2-29 T/P2-15. RIG ACCEPTED AT 17:00 HOURS ON 2/18/94. TAKE ON WATER FOR SPUD MUD. MIX SPUD, SPOT AND DIKE VRCA CUTTING TANK AND NU 20" DIVERTER STACK. REPLACE BROKEN FORK ON LOADER. NU FLOW LINE. PU BHA NUMBER 1. REAM OUT LAST DD SET MW: 8.7 VIS:124 MU BHA %1. TEST DIVERTER, SERV. RIG AND FILL HOLE. SPUD 13.5 HOLE. DRILL ICE F/38 T/95, C/O CONDUCTOR F/95 T/il0. PU SPERRY SUN MWD TOOL AND OIENT. PLUGGED BIT, POOH, CO BIT AND RIH. 13.5" HOLE TO 500, K/P POINT. ORIENT DYNA DRILL AND DIRECTIONAL DRILL ON. DRILL 13.5" HOLE F/500 TO/1198. REAM OUT LAST DD SET F/1062-1198'. 5.7 DEGREES DLS. DRILLING MW: 9.2 VIS:ll5 CONTINUE TO REAM OUT DOG LEG F/l105 T/1198. DIRECTIONAL DRILLING 13.5" HOLE F/1198 T/3585. CONTROL ANGLE AND DIRECTION. DRILLING MW: 9.3 VIS:ll5 CONTINUE DIRECTIONAL DRILLING 13.5" HOLE F/3585 T/4400 TD. CIRC AND COND. HOLE FOR TRIP. POOH LD MOTOR, MWD AND PU ND AND STB. RIH TO 2100. HIT BRIDGE. WASH AND REAM F/2070 TO 2176. LD 18 JOINTS OF DP AND RUN PIPE OUT OF DERRICK. CONTINUE TO WASH AND REAM F/2176 TO 2740. CIRC 10-3/4 @ BTTM 4380' MW: 9.3 VIS:103 REAM TO 2798. RIH TO 4400. CIRC AND COND. HOLE TO RUN 10-3/4" CSG. THICK MUD RETURNING. PUMPING AT 150 GPM. RECIP. PIPE AND INCREASE RATE TILL CIRC. AT 700 GPM. HOLE CLEAN. DROP SURVEY AND POOH. HOLE IN GOOD COND. LD BHA. ND 18" RISER AND REPLACE W/20" RISER, HOOK UP FLOWLINE. RU AND RUN 10-3/4" 45.5% NT-80 W/1 CENTRALIZER ON JTS 1 THRU 20. CIRC LAST JT AND LNDG. JT TO BTTM. CSG SHOE AT 4380' FLOAT COLLAR AT 4302'. TOTAL JTS = 110. ~U6 - 5 1994 Gas Cons. Commission Anchorage WELL : PM2-15 OPERATION: RIG : DOYON 14 PAGE: 2 02/24/94 ( 6) TD: 4400' ( 0) 02/25/94 ( 7) TD: 6375' (1975) 02/26/94 (8) TD: 7300' ( 925) 02/27/94 ( 9) TD: 8290' ( 990) 02/28/94 (10) TD: 9321' (1031) 03/01/94 (11) TD:10342' (1021) RIH WITH BIT NO. 2 MW: 9.0 VIS: 38 CIRC AND COND MUD FOR CMTNG 10.75" CSG. MIX AND PUMP CMT AND BUMP PLUG W/2000 LBS AT 11:30. LD CMT EQUIP. BACK OUT AND LD LNDG JT. ND FLOWLINE AND 20" DIVERTER. PU LINE FOR TOP JOB. HOOK UP BJ AND CMT TOP JOB. NU FMC SPLIT SPEED HEAD, BOPE AND CHOKE LINES. LENGTHEN CHOKE HOSE. TEST BOPE T/5000PSI. RUN WEAR BUSHING, CHANGE KELLY WIPER RUBBER. PU NEW BHA AND RIH. WITH BIT #2. DRILLING AND SURVEYING MW: 9.2 VIS: 39 TEST 10.75" CSG TO 3000PSI. OK. DRILL FLOAT EQUIPMENT AND 80' CMT. CIRC OUT THICK MUD. DRILL SHOE AND 10' NEW HOLE TO 4410. CIRC AND COND MUD. FOR LOT. PERFORM LOT 14.3 EMW. DRILLING AND SURVEYS TO 4785. REPAIR RIG CONVEYER BROKEN BELT. DRILL AND SURVEY TO 5326. CIRC FOR WIPER TRIP. TRIP TO SHOE OK. DRILL AND SURVEY TO 6375. DRILLING MW: 9.3 VIS: 40 DRILLING AND SURVEYING TO 6439. CBU FOR WIPER TRIP. WIPER TRIP TO SHOE. DRILING AND SURVEYING TO 7000. CBU 20 STND WIPER TRIP. OK. DRILLING AND SURVEYING TO 7300. DRILLING AND SURVEYING MW: 9.4 VIS: 45 DRILLING AND SURVEYING TO 7553. CBU. DROP SURVEY AND POOH FOR NEW BIT. RETRIEVE SURVEY, PULL MWD PROBE, CHANGE BIT, CHANGE OUT LEAD COLLAR AND INSTALL MWD PROBE AND ORIENT. PULL AND SERVICE WEAR RING. RIH SLIP AND CUT 119' OF DL. RIH. DRILL AND SURVEY TO 8290. POOH F/NEW BIT MW: 9.6 VIS: 47 DRILLING AND SURVEYING TO 8574. CBU FOR WIPER TRIP TO 7495. DRILLING AND SURVEYING TO 9321. CBU. DROP SURVEY AND POOH F/BIT CHANGE WIPER TRIP MW: 9.7 VIS: 48 FINISH POOH FOR NEW BIT. RETRIEVE SURVEY, CHECK MUD PROBE AND CHANGE BIT. RIH WASH AND REAM 70' TO BTTM. DRILL AND SURVEY F/9321 T/10342. CBU. WIPER TRIP 30 STANDS. RECEIVED AUG - $ 1994 Oil & Gas Cons. Commission Anchora~ WELL : PM2-15 OPERATION: RIG : DOYON 14 PAGE: 3 03/02/94 (12) TD:l1490' (1148) 03/03/94 (13) TD:l1850' ( 360) 03/04/94 (14) TD:12100' ( 250) 03/05/94 (15) TD:12100' ( 0) DRILLING MW: 9.9 VIS: 49 FINISH WIPER TRIP. NO FILL. DRILL F/10342 T/10435. 15 BBL GAIN IN MUD TANKS AFTER 7300 STROKES. PICK UP WELL FLOWING. SHUT WELL IN. CBU THRU CHOKE AT 45 SPM. STOP, CHECK. OPEN ANNULAR AND OBSERVE WELL, OK. DRILLING F/10435 T/11366. CBU. WIPER TRIP TO 8300. OK. DRILLING AND SURVEYING F/11366 T/11490. DRILLING MW: 9.9 VIS: 48 DRILLING AND SURVEYING F/11490 T/11770. CBU FOR BIT TRIP. DROP SURVEY, PUMP DRY JOB, POOH - HOLE OK. LD MWD AND DYNA DRILL. PULL WEAR BUSHING AND SERVICE. SLIP AND CUT DL 59.5' MU BHA #5 AND TIH W/ LOCKED ASSY. BREAK CIRC AT SHOE AND 8500'. HOLE OK. RIEAM F/11730 T/11770. DRILL 9-7/8" HOLE TO 11850. PU TELCO LWD TOOLS & RIH MW: 9.9 VIS: 48 DRILL 9-7/8" HOLE W/BHA #5 F/11850 T/12100 TD. CBU AND COND. HOLE. 10 STND SHORT TRIP MAX. PULL 370,000#. HOLE GOOD. CBU FOR E-LOGS. POOH AND STAND BACK ALL. RU ATLAS WL, RUN GR/CN/ZDL/DIFL. LOG F/1075 UP TO 8700. POOH AND RD. PU TELECO LWD TOOLS AND RIH. MW: 9.9 VIS: 0 03/06/94 (16) TD:12220' ( 120) 03/06/94 (17) TD:12220' ( 0) POOH FOR LOGS MW:10.0 VIS: 48 MU AND TEST MWD/LWD. SURFACE TEST W/DC'S AND 1 JT HWDP. RIH FOR MAD PASS. FILL PIPE AT SHOE. TEST AT 7600 PSI. OK. LD 45 JTS OF 5" DP. PU KELLY, BREAK CIRC AND LOG W/MAD PASS AT 300 FPH F/10686 T/11257. TELCO TOOL DN. TRY TO RESTART. RIH TO 12100. DRILL F/12100 TO 12220 CBU FOR LOGS. POOH LD 29 JTS FOR MAD PASS W/ANADRILL. WL LOG. HOLE IN GOOD CONDITION. LD DP TO RUN 7-5/8" CSG MW:10.0 VIS: 47 POOH FOR E-LOGS. DOWNLOAD TELECO MWD/LWD TOOL AND LD. RU ATLAS WL AND RUN GR/CN/ZDL/DIFL LOG/F/LOGGER DEPTH NOF 12223 UP TO 8700. POOH AND RD. RIH FOR CONDITIONING TRIP TO RUN CSG. CUT DL 59.5' FILL PIPE AT 8500. PU JTS TO 12220. BREAK CIRC, COND. HOLE FOR CSG. 115 SPM/2800PSI. RUN WATER AND LOWER WT TO 9.9 PPG. LD DP. RECEIVED AUG --5 i994 Aiaska 0il & Gas Cons. Commission Anchora~je WELL : PM2-15 OPERATION: RIG : DOYON 14 PAGE: 4 03/07/94 (18) TD:12220' ( 0) 03/08/94 (19) TD: 12220' ( 0) LANDING 7-5/8" CSG MW: 9.9 VIS: 47 POOH AND LD DP. PULL WEAR RING AND CHANGE MIDDLE RAN TO 7-5/8". TEST BOP'S TO 3500 PSI CHECK DOOR SEALS. RUN CASG. BROKE BRAKE BAND OFF DRILLER SIDE, REPLACE. 295 JTS OF 7-5/8" 29.7# NT95SH NSCC CASING RAN BY REPORT TIME. COMPLETION ON AFE 2C0056 MW: 8.5 VIS: 0 CIRC. W/7-5/8" CSG LANDED ON FMC FLUTED HANGER SHOE AT 12210 FLOAT AT 12125. UNABLE TO RECIPROCATE PIPE DUE TO FLUTED HAGR. HANGING UP IN BOP'S. MAX PULL 400,000#. TOTAL JTS RUN 295. PUMP 20 BBLS FRESH WATER, TESTED LINES TO 4000PSI, FOLLOWED BY 70 BBBLS MCS-4 SPACER, 506 SX CLASS G CMT. 594 CU/FT DISPLACED W/557 BBLS SEAWATER AT 13 BPM. BUMP PLUG W/3000PSI. CIP @ 12:39 HOURS ON 3/7/94. PLUGS HELD OK. SLURRY WT 15.7 PPG. LD RUNNING TOOL. SET FMC 7-5/8" PACKOFF TESTED TO 5000PSI OK. INJECT 315 BBLS MUD DOWN ANNULUS OF 10-3/4" X 7-5/8". RELEASED RIG TO COMPLETION AFE 2C0056 AT 17:00 HOURS ON 3/7/94. SIGNATURE: (drilling superintendent) DATE: RE¢£IVED AU~ ~5 '1994 A~s~ Oil & Gas Cons. Commission Anchora.j~. BP/AAI SHARED SERVICE DAILY OPERATION. PAGE: 1 WELL: BOROUGH: UNIT: FIELD: LEASE: API: PERMIT: APPROVAL: PM 2-15 COMPLETION NORTH SLOPE POINT MCINTYRE POINT MCINTYRE 50-029-22409 ACCEPT: SPUD: RELEASE: OPERATION: DRLG RIG: DOYON 14 WO/C RIG: DOYON 16 03/08/94 (1) TD:12220 PB:12125 03/09/94 (2) TD:12220 PB:12125 LANDING TUBING MW: 8.5 Seawater RU TO RUN 4.5" TBG. CLEAN AND STRAP. RUN 4.5" 12.6# L-=80 NSCT TBG W/JEWELRY. RIG RELEASED MW: 8.5 Seawater ND BOP'S, NU ADAPTER FLANGE AND TEST TO 5000PSI. NU TREE, TEST TO 5000PSI. RU FIELD SERV. PULL 4" 2-WAY VALVE. RU LITTLE RED HOT OIL SERV. PUMP DN 4.5" 235 BBLS HEATED DIESEL. TO FREEZE PROTECT ANNULUS (7-5-8 X 4.5) TO 2300. PUMP 90 BBLS TO PROTECT 10-3/4 X 7-5/8 TO 2300. DROP BALL AND SET PACKER AT 11651 W/4000PSI. BLEED TO 0. REPRESSURE TBG TO 4000PSI FOR 30 MIN. LOST 250PSI. PRESSURE TEST 7-5/8 X 4.5 ANNULUS TO 4000PSI FOR 30 MIN. 0 PRESSURE LOSS. CLEAN PITS AND PUMP OUT CELLAR. SECURE TREE AND INSTALL BPV. RIG RELEASED AT 22:00 HOURS ON 3/8/94. SIGNATURE: (drilling superintendent) DATE: RECEIYED 0ii & Gas Gons. Commission Anchora~~, SPERRY-SUN DRILLING SERVICES ANCHORAGE ALASKA PRUDHOE BAY DRILLING 500292240900 NORTH SLOPE CO~PUT~TZON D~TE ~ 3/~/94 DATE OF SURVEY: 030994 MWD SURVEY JOB NUMBER: AK-MW-40018 KELLY BUSHING ELEV. = 36.05 FT. OPERATOR: BP EXPLORATION TRUE SUB-SEA COURS MEASD VERTICAL VERTICAL INCLN DEPTH DEPTH DEPTH DG MN COURSE DLS TOTAL DIRECTION RECTANGULAR COORDINATES DEGREES DG/100 NORTH/SOUTH EAST/WEST VERT. SECT. 0 .00 -36.05 225 224.98 188.93 314 313.96 277.91 404 403.94 367.89 494 493.93 457.88 0 0 N .00 E .00 .00N 1 12 S 58.60 W .53 1.23S 1 6 S 71.50 W .31 1.98S 1 0 S 59.90 W .26 2.65S 0 30 N 79.00 W .78 2.97S .00E 2.01W 3.62W 5.12W 6.18W .00 -2.04 -3.48 -4.79 -5.58 584 583.92 547.87 674 673.85 637.80 764 763.55 727.50 855 853.86 817.81 944 942.02 905.97 1 6 N 14.40 E 1.37 2.06S 3 0 N 10.20 E 2.12 1.10N 6 18 N 27.20 E 3.93 7.81N 7 41 N 28.60 E 1.55 17.60N 8 6 N 28.90 E .45 28.32N 6.35W 5.72W 3.04W 2.16E 8.04E -4.86 -1.79 5.38 16.46 28.70 1034 1030.73 994.68 1127 1121.68 1085.63 1220 1212.20 1176.15 1312 1301.24 1265.19 1403 1388.84 1352.79 11 11 N 32.00 E 3.49 41.29N 12 53 N 32.30 E 1.83 57.73N 13 36 N 30.90 E .83 75.88N 15 30 N 28.70 E 2.15 95.95N 15 53 N 29.70 E .53 117.44N 15.74E 26.07E 37.23E 48.69E 60.71E 43.77 63.15 84.43 107.54' 132.16 1498 1479.67 1443.62 1591 1567.76 1531.71 1684 1655.31 1619.26 1776 1741.25 1705.20 1869 1826.97 1790.92 18 6 N 29.90 E 2.32 141.54N 19 17 N 30.40 E 1.30 167.32N 20 6 N 30.60 E .86 194.33N 21 42 N 29.20 E 1.82 222.78N 23 53 N 27.00 E 2.54 254.57N 74.51E 89.49E 105.40E 121.75E 138.69E 159.93 189.73 221.07 253.88 289.90 1963 1911.69 1875.64 2057 1993.53 1957.48 2152 2073.45 2037.40 2245 2150.28 2114.23 2339 2226.41 2190.36 27 23 N 27.70 E 3.74 290.70N 31 30 N 27.20 E 4.37 331.71N 33 54 N 27.40 E 2.53 377.31N 34 42 N 27.90 E .91 423.73N 37 5 N 29.30 E 2.70 472.10N 157.39E 178.68E 202.22E 226.54E 252.93E 330.57 376.76 428.06 480.45 535.55 2431 2298.45 2262. 2525 2369.06 2333. 2618 2436.74 2400. 2712 2504.36 2468. 2804 2570.37 2534. 40 39 47 N 29.10 E 2.94 522.03N 01 42 47 N 27.90 E 3.30 576.56N 69 43 47 N 28.40 E 1.14 632.79N 31 44 12 N 28.80 E .52 690.12N 32 44 5 N 29.90 E .84 745.97N 280.84E 310.42E 340.51E 371.77E 403.18E 592.76 654.79 718.56 783.86 847.93 2898 2638.10 2602. 2992 2706.08 2670. 3085 2773.20 2737. 3180 2841.19 2805. 3273 2906.56 2870. 05 43 42 N 27.90 E 1.54 803.02N 03 43 42 N 32.30 E 3.23 859.18N 15 43 54 N 32.70 E .37 913.47N 14 44 42 N 30.60 E 1.76 969.94N 51 46 0 N 27.20 E 2.95 1027.86N 434.68E 467.23E 501.81E 536.62E 568.56E 913.10 978.00 1042.23 1108.48 1174.62 R'ECEjVED AP~ ~i 9 1994 A{aska Oil & Gas Cons. CoJ,~rr~ission Aritho[age SPERRY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE 2 PRUDHOE BAY DRILLING PT. McINTYRE/P2-15 500292240900 NORTH SLOPE COMPUTATION DATE: 3/11/9 DATE OF SURVEY: 030994 MWD SURVEY JOB NUMBER: AK-MW-40018 KELLY BUSHING ELEV. = 36.05 FT. OPERATOR: BP EXPLORATION TRUE SUB-SEA COURS MEASD VERTICAL VERTICAL INCLN DEPTH DEPTH DEPTH DG MN COURSE DLS TOTAL DIRECTION RECTANGULAR COORDINATES DEGREES DG/100 NORTH/SOUTH EAST/WEST VERT. SECT. 3368 2972.43 2936.38 3461 3036.45 3000.40 3554 3100.11 3064.06 3647 3163.59 3127.54 3740 3226.90 3190.85 46 12 46 47 46 47 47 5 47 5 N 28.10 E .71 1088.49N 600.33E N 26.50 E 1.40 1148.43N 631.26E N 26.30 E .16 1209.16N 661.40E N 25.60 E .64 1270.26N 691.14E N 27.80 E 1.73 1331.11N 721.75E 1243.06 1310.49 1378.23 1446.10 1514.17 3832 3289.59 3253.54 3925 3352.83 3316.78 4019 3416.16 3380.11 4111 3478.01 3441.96 4206 3542.62 3506.57 47 0 47 17 48 0 47 30 46 47 N 29.90 E 1.67 1390.09N 754.23E N 29.50 E .45 1449.31N 788.01E N 27.60 E 1.67 1510.33N 821.20E N 27.00 E .73 1570.84N 852.44E N 23.70 E 2.65 1633.75N 882.25E 1581.50 1649.67 1719.13 1787.20 1856.70 4299 3606.22 3570.17 4329 3626.70 3590.65 4500 3744.08 3708.03 4595 3810.97 3774.92 4688 3879.79 3843.74 46 47 46 44 40 54 0 17 12 17 N 24.90 E .95 1695.58N 910.17E N 25.80 E 2.22 1715.40N 919.56E N 24.10 E .83 1828.12N 972.02E N 26.30 E 2.75 1889.16N 1000.72E N 27.40 E 4.27 1944.95N 1028.93E 1924.33 1946.22 2070.27 2137.59 2200.07 4782 3951.00 3914.95 4875 4020.00 3983.95 4969 4088.63 4052.58 5062 4156.26 4120.21 5156 4224.05 4188.00 41 12 43 0 43 12 43 30 44 12 N' 27.60 E .97 1999.37N 1057.26E N 28.40 E 2.02 2054.41N 1086.54E N 26.70 E 1.25 2111.35N 1116.24E N 27.00 E .39 2168.31N 1145.07E N 27.40 E .80 2226.23N 1174.84E 2261.41 2323.74 2387.95 2451.75 2516.85 5248 4289.89 4253.84 5341 4356.17 4320.12 5435 4422.82 4386.77 5528 4488.58 4452.53 5621 4554.17 4518.12 44 24 44 42 45 0 45 0 45 17 N 26.90 E .44 2283.40N 1204.16E N 25.10 E 1.40 2342.04N 1232.76E N 29.00 E 2.94 2401.05N 1262.90E N 28.40 E .46 2458.73N 1294.48E N 27.20 E .97 2517.05N 1325.22E 2581.07 2646.23 2712.47 2778.23 2844.15 5712 4617.67 4581.62 5805 4682.15 4646.10 5898 4746.76 4710.71 5991 4810.83 4774.78 6084 4874.32 4838.27 46 46 46 46 47 12 0 0 54 0 N 29.30 E 1.93 2574.46N 1356.08E N 31.80 E 1.95 2632.15N 1390.13E N 30.60 E .93 2689.37N 1424.78E N 33.00 E 2.11 2746.64N 1460.30E N 31.30 E 1.34 2804.17N 1496.46E 2909.31 2976.28 3043.11 3110.41 3178.24 6177 4938.52 4902.47 6268 5001.91 4965.86 6361 5066.28 5030.23 6456 5131.67 5095.62 6549 5195.45 5159.40 45 42 46 0 46 24 46 35 46 47 N 27.00 E 3.63 2862.90N 1529.25E N 29.30 E 1.84 2920.46N 1560.05E N 29.90 E .63 2978.82N 1593.20E N 30.40 E .44 3038.41N 1627.81E N 30.70 E .32 3096.69N 1662.22E 3245.50 3310.78 3377.90 3446.79 3514.44 SPERRY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE 3 PRUDHOE BAY DRILLING PT. McINTYRE/P2-15 500292240900 NORTH SLOPE COMPUTATION DATE: 3/11/9 DATE OF SURVEY: 030994 MWD SURVEY JOB NUMBER: AK-MW-40018 KELLY BUSHING ELEV. = 36.05 FT. OPERATOR: BP EXPLORATION TRUE SUB-SEA COURS MEASD VERTICAL VERTICAL INCLN DEPTH DEPTH DEPTH DG MN COURSE DLS TOTAL DIRECTION RECTANGULAR COORDINATES DEGREES DG/100 NORTH/SOUTH EAST/WEST VERT. SECT. 6642 5259.71 5223.66 6737 5326.06 5290.01 6828 5389.04 5352.99 6922 5453.75 5417.70 7015 5519.10 5483.05 45 47 N 27.20 E 2.93 3155.50N 1694.77E 45 35 N 28.10 E .71 3215.73N 1726.32E 46 47 N 27.90 E 1.33 3273.72N 1757.15E 46 12 N 25.50 E 1.96 3334.61N 1787.79E 44 30 N 27.90 E 2.59 3393.71N 1817.49E 3581.65 3649.63 3715.30 3783.42 3849.51 7107 5584.89 5548.84 7200 5651.28 5615.23 7291 5715.62 5679.57 7384 5781.32 5745.27 7475 5846.61 5810.56 44 12 N 29.30 E 1.11 3450.17N 1848.27E 44 42 N 26.90 E 1.89 3507.61N 1878.93E 45 17 N 29.30 E 1.98 3564.36N 1909.24E 44 47 N 28.60 E .76 3621.95N 1941.10E 43 30 N 25.80 E 2.58 3678.29N 1970.08E 3913.82 3978.93 4043.26 4109.07 4172.41 7571 5916.25 5880.20 7666 5984.47 5948.42 7758 6049.97 6013.92 7850 6115.37 6079.32 7944 6182.53 6146.48 43 30 N 26.20 E .29 3737.69N 1999.04E 44 42 N 27.40 E 1.54 3796.69N 2028.86E 44 30 N 29.90 E 1.92 3853.36N 2059.82E 44 54 N 28.40 E 1.23 3909.88N 2091.33E 43 54 N 29.70 E 1.44 3967.37N 2123.26E 4238.41 4304.48 4369.06 4433.76 4499.53 8037 6249.59 6213.54 8130 6316.66 6280.61 8223 6383.45 6347.40 8316 6450.12 6414.07 8408 6516.02 6479.97 43 47 N'28.80 E .68 4023.58N 2154.74E 43 54 N 27.90 E .68 4080.28N 2185.33E ~44 17 N 29.20 E 1.06 4137.12N 2216.26E 44 5 N 28.40 E .64 4193.94N 2247.50E 44 24 N 28.60 E .36 4250.35N 2278.13E 4563.95 4628.37 4693.09 4757.92 4822.12 8501 6582.97 6546.92 8594 6651.11 6615.06 8689 6721.26 6685.21 8781 6788.93 6752.88 8875 6857.73 6821.68 43 30 N 27.40 E 1.32 4307.34N 2308.44E 42 17 N 31.40 E 3.20 4362.48N 2339.48E 42 30 N 27.90 E 2.49 4418.13N 2371.15E 42 47 N 27.40 E .49 4473.34N 2400.08E 43 5 N 29.20 E 1.34 4529.72N 2430.44E 4886.65 4949.93 5013.95 5076.27 5140.31 8969 6926.20 6890.15 9061 6992.82 6956.77 9154 7059.83 7023.78 9248 7127.45 7091.40 9340 7193.80 7157.75 43 24 N 29.90 E .60 4585.75N 2462.20E 43 47 N 28.80 E .93 4641.05N 2493.30E 44 0 N 28.80 E .21 4697.56N 2524.36E 44 0 N 30.00 E .89 4754.45N 2556.42E 43 42 N 30.60 E .56 4809.47N 2588.57E 5204.71 5268.14 5332.63 5397.92 5461.63 9433 7260.98 7224.93 9526 7328.04 7291.99 9620 7395.78 7359.73 9714 7463.51 7427.46 9807 7530.63 7494.58 43 47 N 32.70 E 1.57 4864.21N 2622.31E 43 54 N 32.10 E .46 4918.61N 2656.83E 43 54 N 34.30 E 1.62 4973.14N 2692.52E 43 54 N 30.90 E 2.51 5028.02N 2727.62E 43 42 N 30.90 E .21 5083.26N 2760.67E 5525.85 5590.15 5655.13 5720.13 5784.46 SPERRY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE 4 PRUDHOE BAY DRILLING PT. McINTYRE/P2-15 500292240900 NORTH SLOPE COMPUTATION DATE: 3/11/94 DATE OF SURVEY: 030994 MWD SURVEY JOB NUMBER: AK-MW-40018 KELLY BUSHING ELEV. = 36.05 FT. OPERATOR: BP EXPLORATION TRUE SUB-SEA COURS COURSE DLS TOTAL MEASD VERTICAL VERTICAL INCLN DIRECTION RECTANGULAR COORDINATES VERT. DEPTH DEPTH DEPTH DG MN DEGREES DG/100 NORTH/SOUTH EAST/WEST SECT. 9900 7597.98 7561.93 43 30 N 31.10 E .26 5138.23N 2793.71E 5848.55 9994 7666.16 7630.11 43 30 N 30.90 E .15 5193.69N 2827.03E 5913.20 10084 7731.45 7695.40 43 30 N 30.60 E .23 5246.94N 2858.71E 5975.12 10177 7798.91 7762.86 43 30 N 30.00 E .44 5302.21N 2891.01E 6039.11 10269 7865.70 7829.65 43 24 N 30.00 E .11 5357.00N 2922.64E 6102.37 10364 7934.55 7898.50 43 42 N 29.90 E .32 5413.71N 2955.32E 6167.81 10458 8002.57 7966.52 43 35 N 31.40 E 1.11 5469.53N 2988.39E 6232.66 10551 8069.97 8033.92 43 30 N 30.60 E .60 5524.45N 3021.39E 6296.68 10645 8138.04 8101.99 43 42 N 29.50 E .83 5580.56N 3053.85E 6361.49 10736 8203.83 8167.78 43 42 N 30.60 E .83 5634.98N 3085.33E 6424.34 10829 8271.07 8235.02 43 42 N 30.40 E .15 5690.34N 3117.94E 6488.56 10924 8339.75 8303.70 43 42 N 30.20 E .14 5747.01N 3151.06E 6554.17 11018 8407.65 8371.60 43 47 N 28.80 E 1.04 5803.58N 3183.06E 6619.17 11111 8474.89 8438.84 43 35 N 30.00 E .92 5859.55N 3214.60E 6683.41 11202 8540.90 8504.85 43 24 N 28.80 E .93 5914.12N 3245.35E 6746.05 11293 8607.13 8571.08 43 12 N- 30.00 E .93 5968.49N 3275.98E 6808.45 11387 8675.76 8639.71 43 0 N 30.00 E .21 6024.11N 3308.10E 6872.66 11478 8742.37 8706.32 42 54 N 29.30 E .54 6078.00N 3338.77E 6934.66 11572 8811.28 8775.23 42 47 N 28.80 E .38 6133.88N 3369.81E 6998.58 11666 8880.31 8844.26 42 42 N 30.60 E 1.30 6189.30N 3401.42E 7062.37 11697 8903.13 8867.08 42 30 N 28.80 E 3.98 6207.53N 3411.82E 7083.35 THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE-DIMENSION MINIMUM CURVATURE METHOD. HORIZONTAL DISPLACEMENT = 7083.35 FEET AT NORTH 28 DEG. 47 MIN. EAST AT MD = 11697 VERTICAL SECTION RELATIVE TO WELL HEAD VERTICAL SECTION COMPUTED ALONG 28.79 DEG. SPERRY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE PRUDHOE BAY DRILLING PT. McINTYRE/P2-15 500292240900 NORTH SLOPE COMPUTATION DATE: 3/11/94 DATE OF SURVEY: 030994 JOB NUMBER: AK-MW-40018 KELLY BUSHING ELEV. = 36.05 FT. OPERATOR: BP EXPLORATION INTERPOLATED VALUES FOR EVEN 1000 FEET OF MEASURED DEPTH TRUE SUB-SEA TOTAL MEASD VERTICAL VERTICAL RECTANGULAR COORDINATES MD-TVD DEPTH DEPTH DEPTH NORTH/SOUTH EAST/WEST DIFFERENCE VERTICAL CORRECTION 0 .00 -36.05 .00 N .00 E .00 1000 997.32 961.27 35.96 N 12.46 E 2.68 2000 1944.30 1908.25 306.20 N 165.49 E 55.70 3000 2711.86 2675.81 863.85 N 470.18 E 288.14 4000 3403.44 3367.39 1497.81 N 814.66 E 596.56 2.68 53.02 232.44 308.42 5000 4111.23 4075.18 2130.31 N 1125.78 E 888.77 6000 4816.98 4780.93 2752.15 N 1463.88 E 1183.02 7000 5508.40 5472.35 3384.42 N 1812.57 E 1491.60 8000 6222.89 6186.84 4001.14 N 2142.40 E 1777.11 9000 6948.72 6912.67 4604.22 N 2472.82 E 2051.28 292.21 294.25 308.58 285.51 274.17 10000 7670.52 7634.47 5197.24 N 2829.15 E 2329.48 11000 8394.66 8358.61 5792.66 N 3177.06 E 2605.34 11697 8903.13 8867.08 6207.53 N 3411.82 E 2793.87 278.21 275.86 188.53 THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE-DIMENSION MINIMUM CURVATURE METHOD. SPERRY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE PRUDHOE BAY DRILLING PT. McINTYRE/P2-15 500292240900 NORTH SLOPE COMPUTATION DATE: 3/11/94 DATE OF SURVEY: 030994 JOB NUMBER: AK-MW-40018 KELLY BUSHING ELEV. = 36.05 OPERATOR: BP EXPLORATION FT. INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH 0 .00 -36.05 36 36.05 .00 136 136.05 100.00 236 236.05 200.00 336 336.05 300.00 436 436.05 400.00 536 536.05 500.00 636 636.05 600.00 736 736.05 700.00 837 836.05 800.00 937 936.05 900.00 1039 1036.05 1000.00 1141 1136.05 1100.00 1244 1236.05 1200.00 1348 1336.05 1300.00 TOTAL RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST .00 N .00 E .00 N .00 E .26 S .42 W 1.35 S 2.21 W 2.12 S 4.02 W 2.93 S 5.60 W 2.89 S 6.53 W .80 S 6.06 W 5.32 N 4.24 W 15.49 N 1.00 E MD-TVD VERTICAL DIFFERENCE CORRECTION .00 .00 .00 .01 .01 .03 .02 .05 .02 .06 .02 .07 .01 .10 .03 .31 .22 .97 .66 27.58 N 7.63 E 1.92 .95 42.19 N 16.30 E 3.37 1.45 60.51 N 27.83 E 5.70 2.33 80.83 N 40.20 E 8.49 2.79 104.42 N 53.34 E 12.08 3.59 1452 1436.05 1400.00 1557 1536.05 1500.00 1663 1636.05 1600.00 1770 1736.05 1700.00 1878 1836.05 1800.00 1990 1936.05 1900.00 2107 2036.05 2000.00 2227 2136.05 2100.00 2351 2236.05 2200.00 2480 2336.05 2300.00 129.32 N 67.49 E 157.75 N 83.88 E 188.26 N 101.81 E 220.97 N 120.74 E 258.19 N 140.54 E 302.22 N 163.41 E 355.12 N 190.72 E 415.02 N 221.93 E 478.53 N 256.54 E 550.27 N 296.34 E 16.11 4.03 21.36 5.25 27.44 6.08 34.35 6.91 42.90 8.55 54.56 11.66 70.96 16.41 91.64 20.68 115.09 23.45 144.47 29.38 2617 2436.05 2400.00 2756 2536.05 2500.00 2895 2636.05 2600.00 3033 2736.05 2700.00 3172 2836.05 2800.00 632.20 N 340.20 E 180.99 36.52 717.11 N 386.63 E 220.15 39.16 801.29 N 433.76 E 259.11 38.96 883.39 N 482.54 E 297.41 38.30 965.57 N 534.03 E 336.72 39.31 3315 2936.05 2900.00 3460 3036.05 3000.00 3606 3136.05 3100.00 3753 3236.05 3200.00 3900 3336.05 3300.00 1055.02 N 1148.06 N 1243.54 N 1339.82 N 1433.48 N 582.52 E 379.41 42.69 631.07 E 424.37 44.97 678.33 E 470.49 46.12 726.34 E 517.39 46.90 779.06 E 564.20 46.81 SPERRY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE PRUDHOE BAY DRILLING PT. McINTYRE/P2-15 500292240900 NORTH SLOPE COMPUTATION DATE: 3/11/94 DATE OF SURVEY: 030994 JOB NUMBER: AK-MW-40018 KELLY BUSHING ELEV. = 36.05 FT. OPERATOR: BP EXPLORATION INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH 4048 3436.05 3400.00 4196 3536.05 3500.00 4342 3636.05 3600.00 4488 3736.05 3700.00 4629 3836.05 3800.00 TOTAL RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST 1529.91 N 831.44 E 1627.34 N 879.44 E 1724.42 N 923.92 E 1820.44 N 968.58 E 1910.40 N 1011.31 E MD-TVD VERTICAL DIFFERENCE CORRECTION 660.35 47.67 706.66 46.30 752.32 45.67 793.48 41.16 4762 3936.05 3900.00 4896 4036.05 4000.00 5034 4136.05 4100.00 5172 4236.05 4200.00 5312 4336.05 4300.00 1987.78 N 1051.20 E 2067.58 N 1093.66 E 2151.22 N 1136.37 E 2236.59 N 1180.21 E 2324.01 N 1224.31 E 826.08 32.59 860.90 34.82 898.09 37.19 936.69 38.60 976.65 39.96 5453 4436.05 4400.00 5595 4536.05 4500.00 5738 4636.05 4600.00 5882 4736.05 4700.00 6027 4836.05 4800.00 2412.62 N 1269.31 E 2500.77 N 1316.85 E 2591.17 N 1365.46 E 2679.83 N 1419.14 E 2769.26 N 1474.96 E 1017.66 41.01 1059.19 41.53 1102.51 43.32 1146.54 44.03 1191.86 45.33 6173 4936.05 4900.00 6317 5036.05 5000.00 6462 5136.05 5100.00 6607 5236.05 5200.00 6751 5336.05 5300.00 2860.64 N 1528.06 E 2951.31 N 1577.40 E 3042.40 N 1630.16 E 3133.85 N 1683.30 E 3224.72 N 1731.12 E 1237.40 45.54 1281.13 43.74 1326.32 45.19 1371.89 45.57 1415.22 43.33 6896 5436.05 5400.00 7038 5536.05 5500.00 7178 5636.05 5600.00 7320 5736.05 5700.00 7460 5836.05 5800.00 7598 5936.05 5900.00 7738 6036.05 6000.00 7879 6136.05 6100.00 8018 6236.05 6200.00 8156 6336.05 6300.00 3317.96 N 1779.84 E 3408.43 N 1825.28 E 3494.17 N 1872.11 E 3582.36 N 1919.34 E 3669.27 N 1965.71 E 3754.55 N 2007.34 E 3841.50 N 2053.00 E 3928.01 N 2101.14 E 4012.20 N 2148.48 E 4096.77 N 2194.06 E 1460.38 45.16 1502.72 42.34 1542.53 39.81 1583.99 41.46 1624.39 40.39 1662.25 37.86 1702.43 40.18 1743.15 40.72 1782.19 39.04 1820.86 38.67 8296 6436.05 6400.00 8436 6536.05 6500.00 8573 6636.05 6600.00 8709 6736.05 6700.00 8845 6836.05 6800.00 4181.95 N 2241.02 E 4267.58 N 2287.52 E 4350.65 N 2332.41 E 4430.10 N 2377.49 E 4512.01 N 2420.54 E 1860.36 39.50 1899.99 39.63 1937.54 37.55 1973.01 35.47 2009.26 36.25 SPERRY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE PRUDHOE BAY DRILLING PT. McINTYRE/P2-15 500292240900 NORTH SLOPE COMPUTATION DATE: 3/11/94 DATE OF SURVEY: 030994 JOB NUMBER: AK-MW-40018 KELLY BUSHING ELEV. = 36.05 FT. OPERATOR: BP EXPLORATION INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH TOTAL RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST MD-TVD VERTICAL DIFFERENCE CORRECTION 8982 6936.05 6900.00 4593.83 N 2466.85 E 2046.51 37.25 9120 7036.05 7000.00 4677.43 N 2513.30 E 2084.89 38.38 9259 7136.05 7100.00 4761.64 N 2560.57 E 2123.90 39.02 9398 7236.05 7200.00 4844.09 N 2609.41 E 2162.41 38.51 9537 7336.05 7300.00 4925.13 N 2660.93 E 2201.06 38.65 9675 7436.05 7400.00 5005.38 N 2714.00 E 2239.84 38.78 9814 7536.05 7500.00 5087.70 N 2763.33 E 2278.45 38.60 9952 7636.05 7600.00 5169.18 N 2812.35 E 2316.43 37.99 10090 7736.05 7700.00 5250.70 N 2860.93 E 2354.29 37.86 10228 7836.05 7800.00 5332.72 N 2908.62 E 2392.14 37.85 10366 7936.05 7900.00 5414.96 N 2956.03 E 2430.02 37.88 10504 8036.05 8000.00 5496.75 N 3004.97 E 2468.18 38.16 10642 8136.05 8100.00 5578.90 N 3052.91 E 2506.20 38.01 10780 8236.05 8200.00 5661.48 N 3101.00 E 2544.51 38.32 10918 8336.05 8300.00 5743.95 N 3149.28 E 2582.83 38.32 11057 8436.05 8400.00 5827.44 N 3196.18 E 2621.30 38.46 11195 8536.05 8500.00 5910.10 N 3243.14 E 2659.28 37.98 11332 8636.05 8600.00 5992.02 N 3289.57 E 2696.63 37.35 11469 8736.05 8700.00 6072.88 N 3335.90 E 2733.33 36.70 11605 8836.05 8800.00 6153.98 N 3380.87 E 2769.71 36.38 11697 8903.13 8867.08 6207.53 N 3411.82 E 2793.87 24.17 THE CALCULATION PROCEDURES USE A LINEAR INTERPOLATION BETWEEN THE NEAREST 20 FOOT MD (FROM MINIMUM CURVATURE) POINTS SURVEY F'~'m UIDANCE ~IONTINUOUS ~IOOL Company ARCO ALASKA, INC. . . . Well Name P2-15 (23' FNL, 1171' FWL, SEC 14, TWN 12N, RNG 14E) m · Field/Location. POINT HCINTYRE, NORTH SLOPE, ALASKA i i · i i Job Reference No. Date 94142 26-MAR- 1994 ~ Computed By: WEST SINES . SCHLL~VIBERGF-R · GCT DIRECTIONAL SURVEY CUSTOMER LISTING FOR ARCO ALASKA, INC. P2 - 15 POINT MCINTYRE NORTH SLOPE, ALASKA SURVEY DATE: 26-MAR-1994 ENGINEER: T. WEST METHODS OF COMPUTATION TOOL LOCATION: MINIMU~ CURVATURE INTERPOLATION: LINEAR VERTICAL SECTION: HORIZ. DIST. PROJECTED ONTO A TARGET AZIMUTH OF NORTH 28 DEG 4 MIN EAST ARCO ALASKA, INC. P2 - 15 POINT MCINTYRE NORTH SLOPE, ALASKA COMPUTATION DATE' 5-APR-94 PAGE DATE OF SURVEY' 26-MAR-1994 KELLY BUSHING ELEVATION' 47.50 FT INTERPOLATED VALUES FOR EVEN 100 FEET OF MEASURED DEPTH TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN 0 O0 100 O0 200 O0 300 O0 400 O0 500 O0 600 O0 700 O0 800 O0 900 O0 0 0 N 0 0 E 1 16 S 61 58 W I 6 S 63 16 W I 0 S 67 34 W 0 38 S 86 52 W 0 37 N 52 38 W I 0 N 4 40 W 4 27 N 19 43 E 7 3 N 26 19 E 8 27 N 29 30 E -47.50 52.50 152.48 252.46 352 45 452 44 552 44 652 33 751 77 850 86 ENGINEER' T. WEST 0 O0 100 O0 199 98 299 96 399 95 499 94 599 94 699 83 799 27 898 36 VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH FEET DEG/IO0 FEET FEET FEET DEG MIN 0 O0 -0 18 -1 91 -3 37 -4 38 -4 67 -3 95 -0 03 10 46 23 91 0 O0 0 O0 0 oo 0 O0 0 O1 0 O1 0 02 0 O5 0 O2 0 O2 0 O0 N 0 11 S 1 08 S 1 84 S 2 26 S 2 08 S 0 98 S 3 02 N 12 61 N 24 48 N o O0 E 0 20W 2 04W 3 70W 5 07 W 6 03W 6 56W 5 72W 1 42W 4 91 E 0 O0 N 0 0 E 0 2 4 5 6 6 6 12 24 22 S 61 44 W 31 S 62 9 W 13 S 63 34 W 55 S 65 58 W 38 S 7O 58 W 64 S 81 31W 47 N 62 10 W 69 N 6 26 W 97 N 11 21E lo00.00 1100.00 1095 120o,00 1192 1300 O0 1289 140o oo 1385 1500 O0 1481 1600 O0 1576 1700 O0 1670 1800 O0 1763 1900 O0 1855 997 04 11 1047 63 1145 61 1242 88 1338 59 1434 43 1528 51 1623 78 1716 65 1808 949 54 lO 11 61 12 16 13 13 18 11 15 2 38 16 14 09 17 38 93 19 9 O1 20 27 28 21 54 15 24 54 N 30 36 E N 32 1 E N 31 16 E N 29 29 E N 29 23 E N 29 49 E N 29 41 E N 29 28 E N 28 1 E N27 4 E 40 05 59 54 81 62 105 97 133 03 161 98 193 66 227 53 263 58 303 05 0 02 0 O1 00l 0 O2 0 01 0 O2 0 O1 0 O1 0 O2 0 O3 38 45 N 55 73 94 118 143 171 200 232 267 12 N 23.18 E 59 92 N 34 85 E 81 95 N 47 16 E 106 55 N 6O 41E 133 71N 74 74 E 161 23 N 90 47 E 193 69 N 107 22 E 227 27 N 124 60 E 263 33 N 142 74 E 303 13.01E 40 59 N 18 42 E 79 N 22 48 E 72 N 25 14 E 02 N 26 25 E 05 N 27 0 E 99 N 27 29 E 66 N 27 51E 53 N 28 7 E 58 N 28 13 E O5 N 28 6 E 2000 O0 1944 77 1897.27 29 11 2100 22OO 2300 2400 2500 2600 2700 28O0 2900 O0 2030 O0 2113 O0 2196 O0 2275 O0 2352 O0 2425 O0 2497 O0 2569 O0 2641 50 1983.00 32 30 91 2066.41 34 16 O0 2148 50 35 40 68 2228 18 38 33 03 2304 53 41 50 18 2377 68 43 40 30 2449 80 44 5 02 2521 52 44 7 14 2593 64 43 37 3000 O0 2713 43 2665 93 43 48 3100 3200 3300 3400 3500 36OO 3700 3800 3900 oo 2785 oo 2857 O0 2927 oo 2996 O0 3064 O0 3133 O0 3201 O0 3269 oo 3336 59 2738 10 2809 17 2879 29 2948 84 3017 03 3085 05 3153 O1 3221 94 3289 09 43 55 60 44 54 67 46 2 79 46 31 34 46 52 53 47 9 55 47 13 51 47 7 44 47 20 N 26 51 E N 26 24 E N27 3 E N28 18 E N 28 46 E N 28 7 E N 27 18 E N 27 46 E N 28 16 E N 28 43 E 348 33 399 77 454 90 512 O1 572 40 636 95 705 13 774 39 844.08 913.35 N 29 9 E N 29 23 E 1051 N 27 39 E 1121 N 25 43 E 1192 N 25 35 E 1265 N 25 52 E 1337 N 26 5 E 1410 N 26 34 E 1484 N 27 23 E 1557 N 27 55 E 1630 982 44 66 54 85 O6 80 90 16 Sl 89 0 . 04 O. 02 0.01 0.03 0 03 0 03 0 O1 0 O1 0 O0 0 O0 o O0 0 O0 0 O2 00l 0 O1 0 O0 0 O0 0 O0 0 O1 o oo 307 68 N 163 30 E 348 33 N 27 57 E 353 402 453 5O6 563 623 685 746 8O7 69 N 186 33 E 399 98 N 211 07 E 454 57 N 237 57 E 512 60 N 266 49 E 572 30 N 297 34 E 636 76 N 328 84 E 705 16 N 360 91E 774 71 N 393 60 e 844 59 N 426 65 E 913 77 N 27 47 E 91 N 27 39 E 02 N 27 39 E 41 N 27 45 E 96 N 27 50 E 13 N 27 48 E 40 N 27 47 E 09 N 27 48 E 36 N 27 51E 868 05 N 460 09 E 982 44 Iq 27 55 E 928 989 1053 1118 1184 1250 1315 1381 1446 41 N 493 99 E 1051 66 N 28 1 E 70 N 527 58 E 1121 54 N 28 4 E 48 N 559 53 E 1192 86 N 27 58 E 67 N 590.73 E 1265 07 N 27 50 E 28 N 622.31E 1337 83 N 27 43 E 02 N 654.36 E 1410.94 N 27 38 E 73 N 686.86 E 1484.22 N 27 34 E 11 N 720.12 E 1557.58 N 27 32 E 10 N 754.22 E 1630.96 N 27 33 E ARCO ALASKA, INC. P2 - 15 POINT M¢INTYRE NORTH SLOPE, ALASKA COMPUTATION DATE: S-APR-94 PAgE 2i DATE OF SURVEY: 26-MAR-1994 KELLY BUSHING ELEVATION: 47.50 FT ENGINEER: T. WEST INTERPOLATED VALUES FOR EVEN 100 FEET OF MEASURED DEPTH TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH FEET DEG/IO0 FEET FEET FEET DEG MIN 4000 O0 3404 38 3356.88 47 55 4100 4200 4300 4400 4500 4600 4700 4800 4900 O0 3471 O0 3539 O0 3607 O0 3676 O0 3745 O0 3815 O0 3889 O0 3965 O0 4038 34 3423.84 47 37 34 3491.84 46 57 68 3560,18 46 50 22 3628.72 46 25 09 3697.59 46 38 24 3767.74 43 59 50 3842.00 40 27 24 3917.74 41 35 89 3991.39 43 3 N 28 1E 1704.73 N 27 0 E 1779.00 N 25 23 E 1852.26 N 25 22 E 1925.19 N 25 28 E 1997.92 N 25 30 E 2070.36 N 26 13 E 2141.55 N 27 4 E 2208.47 N 27 18 E 2273.76 N 27 28 E 2341.40 0 01 0 03 0 O0 0 oo 0 01 0 01 0 O3 0 01 0 O3 0 O0 1511 30 N 788 85 E 1704 79 N 27 34 E 1577 1642 1708 1774 1840 1904 1964 2022 2082 02 N 823 98 N 855 96 N 886 73 N 917 18 N 949 33 N 980 17 N 1010 24 N 1040 29 N 1071 45 E 1779 47 E 1852 73 E 1925 96 E 1998 17 E 207O 17 E 2141 18 E 2208 02 E 2274 15 E 2341 O6 N 27 34 E 35 N 27 3O E 31 N 27 25 E OB N 27 21E 55 N 27 17 E 77 N 27 14 E 71 N 27 13 E 01 N 27 13 E 65 N 27 13 E 5000 O0 4111 84 4064.34 43 14 5100 5200 5300 5400 5500 5600 5700 5800 5900 O0 4184 O0 4256 O0 4328 O0 4399 O0 4469 O0 4540 O0 4610 O0 4680 O0 4749 45 4136 95 43 39 48 4208 05 4280 05 4351 96 4422 60 4493 35 4562 12 4632 65 4702 98 44 10 55 44 29 55 45 0 46 44 47 10 45 21 85 46 2 62 45 44 15 46 4 6000 OO 4818 64 4771 14 46 41 6100 6200 6300 6400 6500 6600 6700 6800 6900 O0 4887 O0 4956 O0 5026 O0 5095 O0 5163 O0 5232 O0 5301 O0 5371 O0 5440 15 4839 65 46 34 43 4908 93 45 48 O0 4978 50 46 10 O0 5047 50 46 32 70 5116 20 46 40 25 5184 75 46 33 71 5254.21 45 29 34 5323.84 46 21 03 5392.53 46 43 7000 O0 5509 89 5462 39 44 26 7~00 O0 5581 7200 O0 5652 7300 O0 5723 7400 O0 5794 75OO O0 5866 7600.00 5938 7700.00 6009 7800.00 6081 79OO.OO 6152 42 5533 92 44 19 94 5605 44 44 31 76 5676 26 45 13 09 5746.59 44 53 11 5818.61 43 37 35 5890.85 43 57 86 5962,36 44 34 29 6033.79 44 35 25 6104.75 44 55 N 27 33 E 24O9 79 N 27 14 E 2478 N 27 3 E 2547 N 26 48 E 2617 N 26 47 E 2688 N 28 59 E 2758 N 28 33 E 2829 N 28 57 E 2901 N 30 56 E 2972 N 3O 55 E 3O44 54 90 73 12 63 41 05 64 42 N 3O 55 E 3116 73 N 30 21E 3189 N 29 36 E 3261 N 29 45 E 3333 N 3O 2 E 34O5 N 3O 7 E 3478 N 29 18 E 3551 N 27 29 E 3623 N 27 18 E 3694 N 26 33 E 3767 49 56 37 71 33 10 03 80 46 Iq 25 50 E 3838 96 N 25 54 E 3908 79 N 26 22 E 3978 64 N 26 48 E 4O49 N 26 13 E 4120 N 25 28 E 4189 N 26 1E 4258 N 27 18 E 4328 N 28 43 E 4398 N 29 3 E 4469 22 29 59 68 56 55 O0 0 O1 0 O0 0 O0 0 O1 0 O1 0 O1 0 O1 0 02 0 O1 0 O1 0 01 0 02 0 O0 0 O1 0 O0 0 O1 0 O2 0 oo 0 01 0 O1 00l 0 O0 0 O1 0 O1 0 04 0 O0 0 O1 0 O1 0 04 0 oo 2142 96 N 1102 75 E 2410 05 N 27 14. E 22O3 2265 2328 2390 2453 2515 2578 2640 2701 99 N 1134 72 N 1166 O0 N 1197 89 N 1229 19 N 1262 21N 1296 13 N 1330 04 N 1366 69 N 1403 41E 2478 03 E 2548 66 E 2618 32 E 2688 34 E 2758 45 E 2829 73 E 2901 76 E 2972 71E 3044 80 N 27 14 E 16 N 27 14 E O1 N 27 13 E 42 N 27 13 E 92 N 27 14 E 68 N 27 16 E 31 N 27 18 E 86 N 27 22 E 59 N 27 27 E 2763 81 N 1440 90 E 3116 86 N 27 32 E 2826 2888 2951 3014 3076 3140 3203 3267 3331 39 N 1478 95 N 1514 36 N 1549 11N 1585 99 N 1622 12 N 1658 45 N 1692 19 N 1725 98 N 1758 15 E 3189 03 E 3261 59 E 3333 66 E 3405 10 E 3478 36 E 3551 47 E 3623 46 E 3694 38 E 3767 58 N 27 37 E 64 N 27 39 E 43 N 27 42 E 76 N 27 45 E 37 N 27 48 E 13 N 27 50 E 05 N 27 51E 83 N 27 5O E 49 N 27 49 E 3396 19 N 1789 93 E 3839 O1 N 27 47 E 3459 3521 3584 3648 3711 3773 3835 3897 3959 08 N 1820 84 N 1851 96 N 1882 50 N 1914 O1N 1944 34 N 1974 82 N 2006 57 N 2038 24 N 2073 40 E 3908 13 E 3978 77 E 4049 66 E 4120 73 E 4189 67 E 4258 02 E 4328 95 E 4398 03 E 4469 84 N 27 45 E 70 N 27 44 E 29 N 27 42 E 37 N 27 41E 70 N 27 39 E 81 N 27 37 E 69 N 27 36 E 68 N 27 37 E 12 N 27 38 E COMPUTATION DATE' 5-APR-94 PAGE 3 ARCO ALASKA, INC. P2 - 15 POINT MCINTYRE NORTH SLOPE, ALASKA DATE OF SURVEY' 26-MAR-1994 KELLY BUSHING ELEVATION' 47.50 FT ENGINEER' T. WEST INTERPOLATED VALUES FOR EVEN 100 FEET OF MEASURED DEPTH ]-RUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH FEET DEG/1OO FEET FEET FEET DEG MIN 8000 O0 6223 77 6176 27 43 44 8100 8200 8300 8400 8500 8600 8700 8800 8900 O0 6295 O0 6368 O0 6439 O0 6511 O0 6582 O0 6656 O0 6729 O0 6803 O0 6876 95 6248 04 6320 84 6392 52 6464 98 6535 O1 6608 68 6682 15 6755 29 6828 45 43 48 54 43 59 34 44 11 02 44 18 48 44 14 51 42 30 18 42 37 65 42 49 79 43 11 N 28 5 E 4538 88 N 27 49 E 4608 N 27 42 E 4677 N 27 52 E 4747 N 27 42 E 4816 N 27 33 E 4886 N 27 12 E 4954 N 27 7 E 5022 N 26 58 E 5090 N 27 13 E 5158 09 4O O0 72 68 98 59 42 6O 0 O0 0 O0 0 O0 0 O0 0 O0 0 02 0 O0 0 O0 0 O0 0 O0 4020 56 N 2106 55 E 4538 99 N 27 39 E 4081 4143 4204 4266 4328 4388 4449 4509 4570 71N 2138 05 N 2171 63 N 2203 30 N 2236 28 N 2268 95 N 2300 13 N 2330 55 N 2361 27 N 2392 97 E 4608 24 E 4677 67 E 4747 20 E 4816 64 E 4886 04 E 4955 87 E 5022 71E 5090 76 E 5158 20 N 27 39 E 51 N 27 39 E 11 N 27 4O E 84 N 27 40 E 80 N 27 40 E 10 N 27 39 E 72 N 27 39 E 55 N 27 38 E 74 N 27 38 E 9000 O0 6949 04 6901 54 43 29 9100 9200 9300 9400 9500 9600 9700 9800 9900 O0 7021 O0 7093 O0 7165 O0 7237 O0 7309 O0 7381 O0 7453 O0 7525 O0 7598 36 6973 38 7045 25 7117 50 7190 70 7262 81 7334 83 7406 84 7478 07 7550 86 43 5O 88 44 2 75 43 50 O0 43 47 20 43 47 31 43 55 33 43 55 34 43 55 57 43 36 N 27 44 E 5227.21 N 28 14 E 5296.27 N 28 34 E 5365.64 N 29 26 E 5435.17 N 29 49 E 5504.28 N 29 42 E 5573.44 N 29 41 E 5642.69 N 29 49 E 5712.04 N 29 46 E 5781.39 N 29 41 E 5850.52 0 O1 o O0 0 01 0 O1 o O0 0 O0 0 O0 0 O0 0 O0 0 O0 4631 17 N 2424 37 E 5227 36 N 27 38 E 4692 4753 4814 4874 4934 4994 5054 5114 5174 15 N 2456 18 N 2489 03 N 2523 07 N 2557 13 N 2592 33 N 2626 56 N 2660 78 N 2695 83 N 2729 79 E 5296 77 E 5365 40 E 5435 68 E 5504 04 E 5573 33 E 5642 76 E 5712 24 E 5781 42 N 27 38 E 78 N 27 39 E 3O N 27 40 E 39 N 27 41E 54 N 27 43 E 78 N 27 44 E 11 N 27 46 E 46 N 27 47 E 53 E 5850 58 N 27 49 E 10000 OO 7670 57 7623 07 43 32 10100 O0 7743 10200 O0 7815 10300 O0 7888 10400 O0 7960 10500 O0 8032 10600 O0 8105 10700 O0 8177 10800 O0 8249 10900 O1 7695 47 7767 O1 7840 50 7913 81 7985 13 8057 37 8129 60 8202 O0 8321 80 8274 51 43 34 97 43 32 51 43 26 O0 43 41 31 43 39 63 43 45 87 43 43 10 43 47 30 43 46 N 29 39 E 5919 37 N 29 36 E 5988 28 N 29 31E 6057 17 N 29 28 E 6125 99 N 29 17 E 6194 86 N 29 14 E 6263 91 N 29 13 E 6332 97 N 29 16 E 6402 10 N 29 19 E 6471 23 N 29 18 E 6540 41 0 O0 0 O0 0 O0 0 O0 0 O0 0 O0 0 O0 0 oo 0 oo 0 oo 5234 69 N 2763 61 E 5919 42 N 27 50 E 5294 5354 5414 5474 5534 5595 5655 5715 5776 62 N 2797 57 N 2831 48 N 2865 52 N 2899 78 N 2933 06 N 2966 39 N 3000 70 N 3034 03 N 3068 68 E 5988 32 N 27 51E 67 E 6057 21 N 27 52 E 57 E 6126 O1 N 27 53 E 35 E 6194 88 N 27 54 E 10 E 6263.93 N 27 55 E 82 E 6332 98 N 27 56 E 60 E 6402 11 N 27 57 e 43 E 6471 24 N 27 58 E 32 E 6540 42 N 27 59 E 11000 O0 8393 99 8346.49 43 KO 11100.00 8466 11200.00 8538 11300.00 8610 11400.00 8683 11500.00 8756 11600.00 8829 11700.00 8902 11800.00 8976 1190000 9049 10 8418.60 43 52 19 8490.69 43 48 64 8563.14 43 20 35 8635.85 43 17 30 8708.80 43 7 44 8781.94 42 55 87 8855.37 42 32 41 8928,91 42 34 68 9002.18 43 18 N 29 6 E 6609 60 N 28 58 E 6678.88 N 28 59 E 6748.16 N 29 0 E 6817.09 N 29 0 E 6885.73 N 29 3 E 6954.11 N 28 51E 7022.30 N 28 55 E 7090.18 N 28 42 E 7157.94 N 28 3 E 7225.99 0.00 0.00 0.00 0.00 0.01 0.00 0.00 0.02 0.01 0,01 5836 44 N 3102 07 E 6609 60 N 27 59 E 5897 5957 6017 6077 6137 6197 6256 6316 6376 02 N 3135 65 N 3169 94 N 3202 99 N 3235 79 N 3269 45 N 3302 90 N 3334 26 N 3367 11 N 3400.02 E 7225 70 E 6678.88 N 28 0 E 26 E 6748 16 N 28 1 E 68 E 6817 09 N 28 1E 96 E 6885 73 N 28 2 E 14 E 6954 11 N 28 2 E 18 E 7022 30 N 28 3 E 93 E 7090 18 N 28 3 E 63 E 7157 94 N 28 4 E 99 N 28 4 E COMPLFFATION DATE: 5-aPR-94 PAGE 4 ARCO ALASKA, INC. P2 - 15 POINt MCINTYRE NORTH SLOPE, ALASKA DATE OF SURVEY: 26-MAR-1994 KELLY BUSHING ELEVATION: 47.50 FT' ENGINEER: T. WEST INTERPOLATED VALUES FOR EVEN 100 FEET OF MEASURED DEPTH TRUE SUB-SEA COURSE VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN FEET DEG/IO0 FEET FEET FEET DEG MIN 12000.00 9121.96 9074.46 44 10 N 27 26 E 7295.09 12100.00 9193.12 9145.62 44 53 N 26 42 E 7365.33 12200.00 9263.98 9216.48 44 53 N 26 42 E 7435.87 0.01 6437.30 N 3432.12 E 7295.09 N 28 4 E 0.00 6499.85 N 3464.11 E 7365.33 N 28 3 E 0.00 6562.89 N 3495.80 E 7435.87 N 28 3 E ARCO ALASKA, TNC. P2- 15 POINT MCINTYRE NORTH SLOPE, ALASKA COMPUTATION DATE: 5-APR-94 PAGE 5 DATE OF SURVEY: 26-MAR-1994 KELLY BUSHING ELEVATION: 47.50 ET ENGINEER' T. wEst INTERPOLATED VALUES FOR EVEN 1000 FEET OF MEASURED DEPTH TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN 0.00 -47 50 0 0 O0 997.04 949 54 10 11 O0 1944,77 1897 27 29 11 O0 2713.43 2665 93 43 48 O0 3404 38 3356 O0 4111 84 4064 O0 4818 64 4771 O0 5509 89 5462 OO 6223 77 6176 O0 6949 04 6901 88 47 55 34 43 14 14 46 41 39 44 26 27 43 44 54 43 29 0 O0 1000 2000 3000 4000 5000 6000 7000 8000 9000 VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH FEET DEG/IO0 FEET FEET FEET DEG MIN 0 O0 0 O0 N N 0 OE N 30 36 E 40 N 26 51E 348 N 29 9 E 982 N 28 I E 1704 N 27 33 E 24O9 N 3O 55 E 3116 N 25 5O E 3838 N 28 5 E 4538 N 27 44 E 5227 O5 33 44 73 79 73 96 88 21 0 O0 0 02 0 04 0 O0 0 01 0 01 0 01 0 01 0 O0 0 01 38 307 868 1511 2142 2763 3396 4020 4631 45 N 13 68 N 163 05 N 460 30 N 788 96 N 1102 81N 1440 19 N 1789 56 N 2106 17 N 2424 01E 40 30 E 348 09 E 982 85 E 1704 75 E 2410 90 E 3116 93 E 3839 55 E 4538 37 E 5227 0 O0 E 0 O0 N 0 0 E 59 N 18 42 E 33 N 27 57 E 44 N 27 55 E 79 N 27 34 E 05 N 27 14 E 86 N 27 32 E 01 N 27 47 E 99 N 27 39 E 36 N 27 38 E 10000.00 7670,57 7623.07 43 32 11000.00 8393.99 8346.49 43 50 12000.00 9121.96 9074.46 44 10 12200.00 9263.98 9216.48 44 53 N 29 39 E 5919.37 N 29 6 E 6609.60 N 27 26 E 7295.09 N 26 42 E 7435.87 0. O0 0.00 0.01 O. O0 5234.69 N 2763.61 E 5919.42 N 27 50 E 5836.44 N 3102.07 E 6609.60 N 27 59 E 6437.30 N 3432.12 E 7295.09 N 28 4 E 6562.89 N 3495.80 E 7435.87 N 28 3 E ARCO ALASKA, INC. P2 - 15 POINT MCINTYRE NORTH SLOPE, ALASKA COMPUTATION DATE' 5-APR-94 PAGE 6 DATE OF SURVEY' 26-MAR-1994 KELLY BUSHING ELEVATION' 47.50 FT INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG HIM 0 0 N 0 0 E 0 40 N 62 59 W 1 13 S 61 43 W I 2 S 65 32 W 0 52 S 69 42 W 0 32 N 85 26 W 0 41 N 29 4 W 2 3 N 8 28 E 6 10 N 24 18 E 7 43 N 28 I E 0 O0 47 50 147 51 247 53 347 55 447 55 547 56 647 58 747 88 848 63 -47 50 0 O0 100 O0 200 O0 300 O0 400 O0 500 O0 600 O0 700 O0 8OO O0 N 30 15 E N 31 21E N 31 56 E N 30 15 E N 29 14 E N 29 47 E N 29 45 E N 29 36 E N 28 21E N 27 4 E ENGINEER' T. WEST 0 O0 47 5O 147 50 247 50 347 50 447 50 547 50 647 50 747 50 847 50 900 O0 9 17 O0 11 17 O0 12 49 O0 14 11 O0 15 52 O0 16 58 O0 18 47 O0 20 8 O0 21 35 O0 24 35 949.73 947.50 1051.35 1047.50 1000 1153.67 1147.50 1100 1256.48 1247.50 1200 1360.07 1347.50 1300 1464.30 1447.50 1400 1569.41 1547,50 1500 1675,47 1647.50 1600 1782.45 1747.50 1700 1891.04 1847.50 1800 N 26 50 E N 26 27 E N 27 26 E N 28 43 E N 28 12 E N 27 29 E N 28 4 E N 28 46 E VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH FEET DEG/IO0 FEET FEET FEET DEG MIN 0 oo 0 O0 -1 04 -2 64 -3 96 -4 59 -4 47 -2 86 4 46 16 71 2003.11 1947 50 1900.00 29 20 50 2000.00 32 55 50 2100.00 34 37 50 2200.00 37 36 50 2300,00 41 39 50 2400.00 43 45 50 2500.00 44 13 50 2600.00 43 37 50 2700.00 43 47 50 2800.00 44 43 2120.22 2047 2240.73 2147 2364.20 2247 2493.93 2347 2630.88 2447 2770.00 2547 2908.79 2647 3O47.20 2747 3186.44 2847 3329 32 2947.50 2900.00 46 12 65 3047.50 3000 O0 46 49 31 56 49 56 71 17 95 02 122 O0 151 37 183 72 219 02 257 04 299 32 3474 3621 3768 3915 4064 4211 4358 4503 4644 27 3147.50 3100 38 3247.50 3200 58 3347.50 3300 48 3447.50 3400 94 3547.50 3500 20 3547.50 3600 52 3747.50 3700 17 3847.50 3800 349 81 410 71 477 93 550 32 632 92 726 46 823 18 919 42 N 29 21E 1015 09 N 27 56 E 1111 96 O0 47 7 O0 47 10 O0 47 24 O0 48 2 O0 46 56 O0 46 49 O0 46 37 O0 42 9 N 25 33 E 1213 97 N 25 46 E 1319 33 N 26 10 E 1426 48 N 27 7 E 1534 34 N 27 57 E 1642 35 N 27 48 E 1752 68 N 25 22 E 1860 98 N 25 23 E 1967 59 N 25 30 E 2072 92 N 26 35 E 2171 70 0 O0 0 O0 0 O0 0 O0 0 O0 0 O0 0 01 0 04 0 02 0 01 0 O0 N 000N 0 59 S 1 47 S 2 13 S 2 25 S 1 67 S 0 22 N 7 18 N 18 17 N 0 O0 E 0 O0 E 1 11 W 2 85W 4 42 W 5 55W 6 37 W 6 49 W 3 99 W 1 43 E 0 O0 N 0 0 E 0 O0 N 0 0 E I 26 S 61 55 W 3 20 S 62 39 W 4 91 S 64 20 W 5 98 S 67 56 W 6 58 S 75 17 W 6 50 N 88 2 W 8 21 N 29 5 W 18 23 N 4 31E 0 02 0 O3 0 01 0 02 0 O1 0 O1 0 01 0 01 0 O2 0 04 31 12 N 46 65 85 108 134 162 193 226 264 8 73 E 91E 49 36 E 71 70 E 95 O1E 122 47 E 151 54 E 183 02 E 219 52 E 257 62 N 17 O0 N 29 44 N 41 93 N 55 50 N 69 59 N 85 28 N 103 50 N 121 O0 N 141 32 32 N 15 40 E 94 N 21 1E 33 N 24 18 E 08 N 26 1E 03 N 26 48 E 38 N 27 19 E 72 N 27 45 E O2 N 28 4 E 04 N 28 13 E 04 E 299 32 N 28 7 E O. 04 0.02 0.01 0.03 O. 03 0.01 0.01 0. O0 0. O0 0.02 309.00 N 163 97 E 349 81 N 27 57 E 363.50 N 191 423.46 N 221 487.24 N 255 559 74 N 295 642 70 N 338 728 28 N 383 812 90 N 429 896 54 N 476 981 22 N 523 21 E 410 72 N 27 45 E 62 E 477 94 N 27 38 E 87 E 550 34 N 27 42 E 44 E 632 92 N 27 50 E 66 E 726 47 N 27 47 E 73 E 823.19 N 27 47 E 57 E 919.42 N 27 51 E 05 E 1015.09 N 27 58 E 14 E 1111.96 N 28 4 E 0 O0 0 O0 0 O0 0 O1 0 O0 0 O1 0 O0 0 O0 00l 0 05 1072 54 N 568 68 E 1213 98 N 27 56 E 1167 63 N 614 1264 O2 N 661 1360 51N 709 1456 22 N 759 1553 66 N 811 1650 86 N 859 1747 30 N 904 1842.48 N 950 1931.34 N 993 26 E 1319 23 E 1426 51E 1534 58 E 1642 32 E 1752 21E 1861 92 E 1967 27 E 2073 58 E 2171 35 N 27 45 E 52 N 27 37 E 40 N 27 33 E 42 N 27 33 E 74 N 27 34 E 07 N 27 30 E 73 N 27 23 E 11 N 27 17 E 93 N 27 13 E ARCO ALASKA, INC. P2 - 15 POINt MCINTYRE NORTH SLOPE, ALASKA COMPUTATION DATE: 5-APR-94 PAGE 7 DATE OF SURVEY: 26-MAR-1994 KELLY BUSHING ELEVATION: 47.50 FT ENGINEER: T. WEST INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ, DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH FEET DEG/IO0 FEET FEET FEET DEG MIN 4776 39 3947 50 3900 O0 41 2 4911 5049 5187 5327 5468 5609 5753 5896 6042 79 4047 03 4147 49 4247 3O 4347 38 4447 84 4547 34 4647 90 4747 14 4847 50 4000 50 4100 50 4200 50 4300 50 4400 50 4500 50 4600 50 4700 50 4800 O0 43 6 O0 43 26 O0 44 7 O0 44 38 O0 44 44 O0 45 26 O0 45 38 O0 46 3 O0 46 50 N 27 14 E 2258.18 N 27 29 E 2349.44 N 27 26 E 2443.44 N 27 4 E 2539 18 N 26 45 E 2636 88 N 28 32 E 2736 37 N 28 32 E 2836 42 N 30 31E 2939 31 N 30 55 E 3042 20 N 30 53 E 3147 39 0 02 0 O0 0 O0 0 O0 0 O1 0 02 0 01 0 02 0 01 0 O0 2008 40 N 1032 88 E 2258 43 N 27 13 E 2089 2172 2257 2345 2433 2521 2611 2699 2790 43 N 1074 81N 1118 96 N 1162 10 N 1206 67 N 1251 37 N 1299 38 N 1349 78 N 1402 15 N 1456 86 E 2349 29 E 2443 07 E 2539 29 E 2637 63 E 2736 80 E 2836 68 E 2939 57 E 3042 67 E 3147 69 N 27 13 E 70 N 27 14 E 45 N 27 14 E 16 N 27 13 E 67 N 27 13 E 68 N 27 16 E 55 N 27 20 E 37 N 27 27 E 51 N 27 34 E 6187.18 4947 50 4900 O0 45 53 6331.09 5047 6476.42 5147 6622 14 5247 6765 57 5347 6910 89 5447 7052 58 5547 7192 37 5647 7333 75 5747 7474 31 5847 50 5000 5O 5100 50 5200 50 5300 50 5400 50 5500 50 5600 50 5700 50 5800 O0 46 18 O0 46 35 O0 46 23 O0 46 0 oo 46 39 O0 44 20 O0 44 28 O0 45 24 O0 43 32 N 29 36 E 3252 36 N 29 50 E 3355 N 30 6 E 3461 N 28 51E 3567 N 27 21E 3669 N 26 29 E 3775 N 25 51E 3875 N 26 18 E 3973 N 26 47 E 4O73 N 25 28 E 4171 81 2O 15 96 38 68 29 21 90 0.01 0.00 0. O0 0.02 0 O1 0 O1 0 O0 0 O1 0 O1 0 O0 2880 95 N 1509 48 E 3252 45 N 27 39 E 297O 3062 3154 3245 3339 3429 3517 3606 3695 85 N 1560 16 N 1613 15 N 1666 12 N 1714 07 N 1761 26 N 1805 05 N 1848 38 N 1893 02 N 1937 74 E 3355 50 E 3461 15 E 3567 06 E 3669 92 E 3775 94 E 3875 76 E 3973 59 E 4073 12 E 4172 87 N 27 43 E 24 N 27 47 E 17 N 27 51E 98 N 27 51E 41 N 27 49 E 73 N 27 46 E 35 N 27 44 E 29 N 27 42 E O0 N 27 40 E 7612 73 5947 50 5900 O0 44 3 7752 7893 8032 8171 8310 8450 8588 8724 73 6047 31 6147 86 6247 48 6347 69 6447 35 6547 46 6647 23 6747 8860.56 6847 50 6000 50 6100 50 6200 50 6300 50 6400 50 6500 50 6600 50 6700 50 6800 O0 44 20 O0 44 57 O0 43 48 O0 43 54 O0 44 11 O0 44 29 O0 42 31 00 42 40 O0 43 2 N 26 10 E 4267 53 N 28 9 E 4365 N 29 3 E 4464 N 27 58 E 4561 N 27 43 E 4657 N 27 52 E 4754 N 27 38 E 4851 N 27 14 E 4947 N 27 6 E 5039 N 27 6 E 5131 49 28 60 60 45 94 18 O1 65 0.01 0.01 O. O0 0.00 0. O0 0.00 0 O0 0 O0 0 O0 0 O0 3781 29 N 1978 58 E 4267 66 N 27 37 E 3868 3955 4040 4125 4211 4297 4382 4463 4546 50 N 2023 12 N 2070 62 N 2117 52 N 2162 22 N 2207 50 N 2252 O1N 2296 75 N 2338 29 N 2380 21E 4365 74 E 4464 23 E 4561 04 E 4657 15 E 4754 55 E 4852 47 E 4947 35 E 5039 45 E 5131 63 N 27 37 E 41 N 27 38 E 72 N 27 39 E 72 N 27 39 E 56 N 27 4O E O6 N 27 40 E 3O N 27 39 E 14 N 27 39 E 79 N 27 38 E 8997.88 6947.50 6900.00 43 29 9136 27 7047.50 7000.00 43 55 9275 9413 9552 9691 9830 9968 10106 10244 34 7147.50 7100.00 44 0 85 7247.50 7200 O0 43 47 39 7347 50 7300 O0 43 51 21 7447 50 7400 O0 43 56 04 7547 50 7500 O0 43 49 19 7647 50 7600 O0 43 30 20 7747 50 7700 O0 43 34 18 7847 50 7800 O0 43 31 N 27 43 E 5225 75 N 28 20 E 5321 41 N 29 9 E 5418 06 N 29 49 E 5513 85 N 29 40 E 5609 70 N 29 49 E 5705 94 N 29 45 E 5802 20 N 29 38 E 5897.48 N 29 35 E 5992.55 N 29 30 E 6087.59 o Ol 0 O0 0.01 O. O0 O. O0 0 .o0 O. O0 O. O0 O. oo O. oo 4629 87 N 2423.69 E 5225 90 N 27 38 E 4714 4799 10 N 2515 4882 39 N 2562 4965 65 N 2610 5049 27 N 2657 5132.85 N 2705 5215.65 N 2752 5298.33 N 2799 5381.05 N 2846 28 N 2468 70 E 5321 05 E 5418 44 E 5513 O0 E 5609 73 E 5706 57 E 5802 78 E 5897 79 E 5992 66 E 6087 55 N 27 38 E 2O N 27 39 E 96 N 27 42 E 8O N 27 44 E 02 N 27 46 E 27 N 27 48 E 53 N 27 49 E 59 N 27 51E 62 N 27 53 E COMPUTATION DATE: 5-APR-94 PAGE 8 ARCO ALASKA, INC. P2 - 15 POINT MCINTYRE NORTH SLOPE, ALASKA DATE OF SURVEY: 26-MAR-1994 KELLY BUSHING ELEVATION: 47.50 FT ENGINEER: T. wEST INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH FEET DEG/IO0 FEET FEET FEET DEG MIN 10382 03 7947 50 7900 O0 43 40 10520 10658 10797 10'935 11074 11212 11350 11487 11624 30 8047 66 8147 09 8247 59 8347 21 8447 90 8547 70 8547 94 8747 66 8847 50 8000 50 8100 50 8200 50 8300 50 8400 50 8500 50 8600 50 8700 50 8800 O0 43 39 O0 43 44 O0 43 47 O0 43 46 O0 43 52 O0 43 47 O0 43 23 O0 43 7 O0 42 54 N 29 18 E 6182 46 N 29 14 E 6277 N 29 16 E 6373 N 29 19 E 6469 N 29 12 E 6565 N 29 1E 6661 N 29 0 E 6757 N 29 0 E 6851 N 29 2 E 6945 N 28 52 E 7039 92 53 22 02 O0 O9 89 87 09 0 O0 0 O0 0 O0 0 O0 0 O0 0 O0 0 O0 o O0 0 O0 0 O0 5463 69 N 2893 28 E 6182 48 N 27 54 E 5547 5630 5713 5797 5881 5965 6048 6130 6212 O1N 2939 46 N 2986 94 N 3033 50 N 3080 38 n 3127 45 N 3173 38 N 3219 58 N 3265 15 N 3310 94 E 6277 64 E 6373 44 E 6469 35 E 6565 04 E 6661 58 E 6757 55 E 6851 14 E 6945 28 E 7039 94 N 27 55 E 54 N 27 57 E 23 N 27 58 E 03 N 27 59 E O1 N 28 0 E 09 N 28 1E 89 N 28 2 E 88 N 28 2 E 09 N 28 3 E 11760.77 8947.50 8900.00 42 36 11897.01 9047.50 9000.00 43 16 12035.72 9147,50 9100.00 44 34 12176.74 9247.50 9200.00 44 53 12200.00 9263.98 9216.48 44 53 N 28 52 E 7131.41 N 28 5 E 7223.94 N 27 19 E 7320.06 N 26 42 E 7419.46 N 26 42 E 7435.87 O. 02 0.01 0.01 O. O0 O. O0 6293.00 N 3354.87 E 7131.41 N 28 4 E 6374.30 N 3399.05 E 7223.94 N 28 4 E 6459.48 N 3443.61 E 7320.06 N 28 4 E 6548.23 N 3488.43 E 7419.46 N 28 3 E 6562.89 N 3495.80 E 7435.87 N 28 3 E ARCO ALASKA, INC. P2 - 15 POINT MCINTYRE NORTH SLOPE, ALASKA MARKER gCT LAST READING TD COMPUTATION DATE: 5-APR-94 INTERPOLATED VALUES FOR CHOSEN HORIZONS PAGE 9 DATE OF SURVEY: 26-MAR-1994 KELLY BUSHING ELEVATION: 47.50 FT ENGINEER: T. WEST SURFACE LOCATION = 23' FNL · 1171~ FWL, SEC14 T12N R14E MEASURED DEPTH TVD RECTANGULAR COORDINATES BELOW KB FROM KB SUB-SEA NORTH/SOUTH EAST/WEST 12072.30 9173.49 9125.99 6482.38 N 3455.33 E 12130.00 9214.38 9166,88 6518.76 N 3473.61 E ARCO ALASKA, INC. P2 - 1S POINT MCINTYRE NORTH SLOPE, ALASKA MARKER TD COMPUTATION DATE: 5-APR-94 PAGE 10 DATE OF SURVEY: 26-MAR-1994 KELLY BUSHING ELEVATION: 47.50 FT ENGINEER: T. WEST ~~~ STRATIQRAPHIC SUMMARY ~~~ SURFACE LOCATION = 23' FNL & 1~71' FWL, SEC14 T~2N RZ4E MEASURED DEPTH TVD RECTANGULAR COORDINATES BELOW KB FROM KB SUB-SEA NORTH/SOUTH EAST/WEST 12130.00 9214.38 9166.88 6518.76 N 3473.61E FINAL WELL LOCATION AT l-D: TRUE SUB-SEA MEASURED VERTICAL VERTICAL DEPTH DEPTH DEPTH HORIZONTAL DEPARTURE DISTANCE AZIMUTH FEET DEG MIN 12200.00 9263.98 9216.48 7435.87 N 28 3 E Reference Number AKCC00000094142 SCHLUMBERGER WELL SERVICES Interpretation & Computing Services - USA Computer Processing Service Order -- Client Charges Processing Center: Alaska Division Computing Center 500 West International Airport Road Anchorage, ALASKA USA 99518 (907) 562-7669 Responsible Log Analyst(s): RAMONA SINES District # 46150 District Name PRUDHOE BAY Field Engineer WEST 5-APR-1994:14 Service Order 480432 Client No. Client Address : 031035002 : BP EXPLORATION (ALASKA) INC - PBU : PBU NORTH SLOPE ACCOUNTING, PBU BOC P.O. BOX 196612 ANCHORAGE 995196612 AK API Number : 5002922409 Well : P2-15 Section : 14 Township : 12N Range : 14E County : State : ALASKA Country : USA Region : LAND Field : POINT MCINTYRE Operating Company: ARCO ALASKA, INC. Responsible Sales Engineer: BETTIS , F.E. Products sold by: BETTIS , F. E. Products ordered by: R. STRICKLAND Date Invoiced: Client Representative : R. STRICKLAND Date Entered : 05-APR-1994:07:16 Service : GCT Run # : 1 Start Depth: 90 Stop Depth : 12072 Product Processed Code Quantity 6410 1.0 FT 6108 2.0 EA Book Pri ce I 1370.00 4O0.00 All currencies are in UNITED STATES Product-Code Key 6410 6108 GCT DIRECTIONAL SURVEY ADDITIONAL TAPE COPIES Actual Price I 1370.00 400.00 $ 1770.00 DOLLAR Price Schedule AKD-LAND-94 AKD-LAND-94 COMPANY ARCO ALASKA, INC. FIELD P2 - 15 WELL POINT MCINTYRE COUNTRY USA RUN ONE DATE LOGGED 26-MAR-1994 REFERENCE 94142 All interpretations are ol)inions based on inferences from electrical or other measurements and we cannot, and do not guarantee the accuracy or correctness of anyinterpretat one. and we shall not. except in the case of gross or wilfull negligence on our part_, be liable or responsible for any loss, costs, damaqes or expenses incurred or sustained by anyone result ng from any interl3retafion made by any of our officers, agents or em0ioy.ees.. 'l'h~e .se interpretations are also subject to our Ge~eral Terms andCondit~ons as set out in our currer~ pnce ~:~cneoule. WELL- P2-15 (23' FNL, 1171' FWL, SEC 14, T12N, R14E) HORIZONTAL PROJECTION NOFITH 12000 10000 8000 6000 4000 2000 -2000 SOUTH -4000 FiEF 94142 SCALE: I / 2000 IN/Iq' -6000 -4000 -2000 0 2000 4000 6000 8000 10000 WEST EAST WELL- P2-15 · (23' FNL, 1171' FWL, SEC 14, T12N, R14E) VERTICAL PROJECTION -4000 -2000 0 2000 4000 6000 8000 10000 12000 ~'8.0 PROJECTION ON VERTICAL PLANE 208.0 - 2"J.O ,SCALED IN VEI=IT]CAL DEPTHS HOI:I1Z ~CALE = 1 / 2000 IN/FT STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon __ Suspended __ Alter casing ~ Repair well . Change approved program x 2. Name of Operator ARCO Alaska, Inc. 3. Address P.O. Box 100360, Anchorage, AK 99510 4. Location of well at surface 21' SNL, 1171' EWL, Sec. 14, T12N, R14E At top of production interval 989' NSL, 690' WEL, Sec. 2, T12N, R14E At effective depth 989' NSL, 690' WEL, Sec. 2, T12N, R14E At total depth 1220" NSL, 633' WEL, Sec. 2, T12N, R14E Operation Shutdown __ Re-enter suspended well ___ Plugging __ Time extension ___ Stimulate Pull tubing Variance Perforate Other 5. Type of Well: Development ___ Exploratory Stratigraphic Service ORIGINAL 6. Datum elevation (DF or KB) RKB=28' 7. Unit or Property name Point Mclntyre 8. Well number P2-15 9. Permit number 93-154 10. APl number 500292240900 11. Field/Pool Prudhoe Bay/Point Mclntyre [eet 12. Present well condition summary Total Depth: measured: true vertical: 12220 feet Plugs 9278 feet (measured) None. Effective Depth: measured: true vertical: Casing Length Size Conductor 80' 20" 4348' 10-3/4" Surface Intermediate 12182' 7-5/8'' 12125 feet Junk (measured) None. 9211 feet Cemented Measured depth 260 sx Arcticset (approx.) 80' 1326 sx CS 111/354 sx "G" 4380' True vertical depth 80' 3662' 506 sx Class "G" 12210' 9271' Liner Perforation depth: measured 11790-11830', 11920-11970' true vertical 8969-8998', 9064-9100 Tubing (size, grade, and measured depth) 4-1/2'' 12# L80 @ 11727 Packers and SSSV (type and measured depth) Pkr. @ 11655', TRDP SSSV @ 2255' RECEIVED d U L 2 8 1994 Alaska Oil & Gas Cons. Commission Anchora~je 13. Attachments Description summary of proposal x Convert well from Producer to Water Injection. Detailed operation program __ 4. Estimated date for commencing operation August 1, 1994 16. If proposal was verbally approved Name of approver Date approved 17. I here~_.xcertJfy t~.~.,,~.oing is true and correct tothe best of my knowledge. Signed ~.,/.,~¢~ ¢:.-"'"(~[,orge K. Phillips Title GPMA Sr. Engineer BOP sketch -- 15. Status of well classification as' Oil Gas Suspended Service Water Injector FOR COMMISSION USE ONLY Conditions of approval: Plug integrity_ BOP test Mechanical Integrity Test ~ Approved by order of the Commissioq Form 10-403 Rev 06/15/88 Notify Commission so representative may witness Location clearance__ Subsequent for required 10- i./, O//' original Signed By '~3vid W. Johnston Commissioner Approved Copy Returned Approval No. / Date SUBMIT IN TRIPLICATE Attachment 1 Conversion to Water Injection Point McIntyre P2-15 ARCO Alaska requests approval to convert Well P2-15 from an oil producer to a water injector. This well will be operated as a Class II UIC well in compliance with Area Injection Order 4A. Water will be injected for the purpose of enhanced recovery into the Kuparuk interval between the depths of 11790' and 11970' measured depths This interval correlates with the strata found in ARCO's Point Mclntyre Well No. 11 between the measured depths of 9908' - 10665' as authorized in Rule 1 of this injection order. A Mechanical Integrity Test will be performed before injection is initiated and every four years thereafter, in compliance with Rule 6 of this order. This well's injection volumes, average injection pressure, and average annulus pressure will be reported to the AOGCC monthly. RECEIVED JUL 2 8 1994 A.laska Oil & Gas Cons. Commission Anchora.,~t~ Date: Subject: From: To.- .... ARCO Alaska Inc. Great~ Point McIntyre Engineering April 19, 1994 Transmittal Number 720 ARCO Alaska, Inc. Bob Crandall AOGCC 3001 Porcupine Drive Anchorage, AK 99501 The following Greater Point Mclntyre Area data are enclosed. This information is confidential and your Cooperation in maintaining confidentiality is appreciated: NK-26 FINAL DISKETTE: MWDw/Sub-Sur£ace 3-17-94 Anadrill q~o~ Directional Survey Pl-17 "/FINAL LOG: Production Profile 3-7-94 Schlumberger P1-21 ~FINAL LOG: Perf Record 3 3/8" HSD - 6 SPF I 2/5/94 Schlumberger P2-06 q~-to~ P2-06 P2-06 P2-12 P2-12 P2-15 P2-15 P2-15 ~'/~AL LOG: Perforation Record 2 1/8" Phased Enerjet '~AL LOG: Static Pressure Survey Press-Temp-Gr / CCL FINAL DISKETTE: GCT -Surface w/SuJ Directional Survey t' ~( /FINAL LOG: Perf Record 3 3/8" HJ~, 6 SPF "'FINAL LOG: Static Pressure Survey Press-Temp-Gr/CCL ~INAL TAPE: DIFL/CN/ZDL/GR w/LIS Vet V/FINAL LOG: Sub-Sea Vertical Depth (MWD Directional Survey) INAL LOG: ]3orehole Profile d/FINAL LOG: Z-Densilog Comp NEUTRON GR/Caliper P2-15 1 1/30/94 Schlumberger 1 1/31/94 Schlumberger 1 1-7-94 Schlumberger 1 1/29/94 Schlumberger I 1/29/94 Schlumberger 1 3-5-94 Atlas 1 3-5-94 Atlas 1 3-5-94 Atlas Wireline 1 3-5-94 Atlas Well Name P2-15 P2-15 P2-15 P2-t5 P2-15 P2-161 P2-161 P2-23 P2-29 P2-29 P2-29 P2-29 P2-29 P2-29 P2-29 P2-29 Data Description "I~INAL LOG: Dual Induction Focused Log GR/SP FINAL DISKETTE: MWD Survey w/LIS Vet FINALLOG: Cement Evaluation (CET-GR) v/~~NAL LOG: Cement Bond Log (CBT-GR) ~FINAL DISKETTE: GCT w/Sub-surface Directional Survey LIS Vet ~2qAL LOG: Perforating Depth Control Powered Gun GR ~2WAL LOG: Perforation Record 3 3/8"HJ II, 6 SPF ~/FINAL DISKETTE;,MWD Survey w/LIS Vet ~/FINAL TAPE: DIFL/CN/ZDL/GR w/LIS Vet 1 /FINAL LOG: Borehole Profile v'~]2WAL LOG: Sub-Sea Vertical Depth (Directional Drillers Data) //FINAL LOG: Z-Densilog Comp NEUTRON GR/Caliper V"FINAL LOG: Dual Induction Focused Log 1 '~INAL DISKETTE:~ ~ Survey w/LIS Vet 1 ~'FINAL DISKETTE: Electronic Multi-shot 1 Survey w/LIS Vet v~FINAL LOG: Cement Evaluation Log (CET-GR) 1 Run # 1 Date Run 3-5-94 3-9-94 3-26-94 3-26-94 3-26-94 1/26/94 1/27/94 3-23-94 2/12/94 2-12-94 2-12-94 2-12-94 2-12-94 2-10-94 2-10-94 3-25-94 Company Atlas Sperry Sun Schlumberger Schlumberger Schlumberger Schlumberger Schlumberger Sperry-Sun ATLAS Atlas Atlas Atlas Atlas Sperry-Sun Sperry Sun Schlumberger Transmittal Number: 720 Page: 2 . . Well Name P2-29 P2-29 P2-30 P2-30 P2-30 Data Description v(/~AL LOG: Cement Bond Log (CBT-GR) V/FINAL DISKETTE: _Sub_-Sy.rface Directional_ Survey (GCT) ~ '/FINAL TAPE: CH Edit 3 Pass CNT-G with Average Pass w/Ver List d/FINAL TAPE: CH Edit TDTP 3 Passes and Average w/Vet List LOC.' C~J'V-C~ / ~c- '~FFINAL LOG: TDTP Depth Corrected Run # 1 Date Run 3-25-94 3-20-94 1-8-94 1-8-94 12-8-93 Company Schlumberger Schlumberger Schlumberger Schlumberger Schlumberger P2-31 P2-31 P2-31 P2-31 P2-31 P2-31 P2-42 P2-42 P2-42 P2-42 P2-42 FINAL DISKETTE: MW w/Sub-Surface Directional Survey f-~ ~vF]2Xle rAL~~TTE: Electronic MultiShot w/LIS FINAL LOG: Sub Sea VD (Multi-shot Directional Survey) ~//FINAL LOG: Dual Laterolog/GR/SP FINALLOG: Borehole Profile /FINAL LOG: Z-Densilog/CompNeutron/GR/Caliper '~AL LoG: Dual Induction Focused Log/GR/SP '/'FINAL LOG: Formation Multi-Tester/GR ~FINAL LOG: Sub-Sea Vertical Depth (MWD Directional Survey) V/FINAL LOG: Z-Densilog/Compensated Neutron/GR/Caliper V/FINAL LOG: Borehole Profile 04-08-94 4-10-94 4-10-94 4-10-94 4-10-94 4-10-94 1/9/94 1/9/94 1/9/94 1/9/94 1/9/94 Sperry Stm Sper~:y Sun Atlas Wireline Atlas Wireline Atlas Wireline Atlas Wireline Atlas Atlas Atlas Atlas Arias Transmittal Number: 720 Page: 3 Well Name Data Descri,>tion P242 7/~AL DISKETTE: M~D Survey w/LIS Ver P2-51 v//FENAL LOG' TDTP Depth Corrected / P2-51 --~F~'JAL TAPE: CH Edit 3 Pass TDTP w/Average Pass w/Ver List / / P2-5i 'Fh-NAL TAPE: CH Edit 3 Pass CNTG and Average w/Vet List P2-57 [~INAL LOG: 2.5" CNT-~Depth Corrected w/Average w/Vet List Run # Date Run Company 1/8/94 Sperry-Sun 1-11-94 1-11-94 1-11-94 11-14-93 11-14-93 Schlumberger Schlumberger Schlumberger Schlumberger Schlumberger Please sign and return tO' Elizabeth R. Barker, ATO-415 ARCO Alaska, Inc. P.O. Box 100360 Anchorage, Alaska 99510-0360 Transmit-tM Number: 720 Page: 4 ALASKA OIL AND GAS CONSERVATION COMMISSION WALTER J. HICKEL, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 TELECOPY: (907) 276-7542 October 13, 1993 Michael Zanghi Drilling Engineer Supervisor ARCO Alaska, Inc. P O Box 196612 Anchorge, AK 99519-6612 Re: Point McIntyre P2-15 ARCO Alaska, Inc. Permit No: 93-154 Sur. Loc. 23'SNL, ll71'EWL, Sec. 14, T12N, R14E, UM Btmhole Loc. l176'NSL, 589'WEL, Sec. 2, T12N, R14E, UM Dear Mr. Zanghi: 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 BOPE 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 on the North Slope pager at 659-3607. David W. ~hnsto~ _~ Chairman BY ORDER OF THE COMMISSION dlf/Enclosures cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. [)riD!ed on recycJc,¢J rmper l? ;, ,., ,, . . · STATE OF ALASKA ' ALASKA (JIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 2O AAC 25.005 ila. TyPe of work Drill [] Redrilll-lllb. Type of well. Exploratoryl-] Stratigraphic Testl-] Development Oil[] Re-Entry [] DeepenF'II 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 = 53.5 feet Point Mclntyre 3. Address 6. Property Designation ~. O. Box 196612. Anchoraae. Alaska 99519-~612 ADL $65548 4. Location of well at surf-ace 7. Unit or property Name 1 1. Type Bond(see 20 ^AC 25.025) 23'SNL, 1171'EWL, SEC. 14, T12N, R14E Point Mclntyre At top of productive interval 8. Well number Number 989' NSL, 690' WEL, SEC. 2, T12N, R14E P2-15 U-630610 At total depth 9. Approximate spud date Amount 1176' NSL, 589' WEL, SEC. 2, T12N, R14E 12/6/93 $200,000.00 !12. Distance to nearest 13. Distance to nearest well 4. Number of acres in property;15. Proposed depth(uOandTVD) 'property line ADL 34622-4689' feet P2-59-359'@ 2800' TVD feet 2560 12092' MD/9195' TVD feet 16. To be completed for deviated wells 17. Anticipated pressure (sm 20 AAC 25.035 (e)(2)) Kickoff depth 5~2 feet Maximum hole anple 4~ 0 Maximum sudace 3330 psig At total depth (TVD) 8800'/45~O psis] 18. Casing program Setting Depth s!ze. Specifications Top Bottom Quantity of cement Hole Casing Weight Grade Coupling Length M D TVD M D TVD (include stage data) 30" 20" 91.5# H-40 Weld 80' i Surface 80' 80' 280 cu fl Arcticset (Approx.) 13-1/2" 10-3/4" 45.5# J-55 BTC 4347' 41' 41' 4388' 3700' 2831 cuft"E"/4O6cufl"G"/235cufl"C" 9-7/8" 7-5/8" 29.7# NT95HS NSCC :12051' 41' 41' 12092' 9195' 583 cuft Class "G" 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 RECEIVED Intermediate Production OCT - ] Liner Perforation depth: measured &laska 0il & Gas Cons. true vertical Anchorage 20. Attachments Filing fee [] Property plat [] BOP Sketch [] Diverter Sketch [] Drilling program[] Drilling fluid program [] Time vs depth plot [] Refraction analysis[] Seabed report[] 20 AAC 25.050 requirementsl-I 21 ! here.17,.v certify ·SignedI¢'~'~["' thatlthe,,foregoing,, : . ,/_ is true and correct to the best of my knowledge t/~ [~_~i',,.,,.~ T i t l e Drillin~T EnE/inoer Suporvisor Date Commission Use Only Permit Number IAPI number IApproval date See cover letter ~'j~-/c<"z7/ J50-o.z.-'~- 2-_..2--~rc~'~ J /~/,~_/~' for other requrements Conditions of approval Samples required [] Yes ]E~'NO Mud Icg requJ~'ed'E~]-~es ~ No Hydrogen sulfide measures [] Yes ¢ No Directional survey required ~ Yes [] NO Required working pressure for BOPE [] 2M; I-']3M- J~,SM; []10M' 1-115M; Other: Approved by Commissioner by order of Form 10-401 Rev. 12-1-85 Submit in tr'~plicate Type of Well (producer or injector)' Well Name: [PM 2-15 Well Plan Summary IWATER INJECTOR Surface Location: ] 23 FNL, 1171 FWL, SEC 14, T12N, R14E Target Location:I 989 FSL, 690 FEL, SEC 2, T12N, R14E Bottom Hole Location: 1176 FSL, 589 FEL,SEC 2, T12N, R14E ]AFEmumber: 12C0045 ] [Rig: [DOYON#14 I Estimated Start Date: [MD: ] 12092 [ I12'6'93 I [ TVD: [,Operating days to complete' [ 18 [9195 I [KBE: 153.5' Well Design (conventional, slimhole, etc.)- I SLIMHOLE / LONGSTRING Formation Markers: Formation Tops MD TVD (BKB) WEST SAK 8991 6984 K- 10, K-5, HRZ 11723 8938 KALUBIK 11774 8968 KUPARUK 11788 8978 TD 12092 9195 ~ . Casing/Tubin[ram: Hole Size Csg/ Wt/Ft Grade Conn Length Top Btm Tbg O.D. MD/TVD MD/TVD 30" 20" 91.5# H-40 WLD 80' GL 80/80 13-1/2" 10-3/4" 45.5# J-55 BTC 4347' 41'MD 4388/3700 9-7/8" 7-5/8" 29.7# NT-95HS NSCC 12051' 41' MD 12092/9195 TBG 4-1/2" 12.6g L-80 NSCT 11688' 41' MD 11729' MD Well Plan Summary RECEIVED P2-15 Page 1 o CT - 1 199,5 Alaska Oil & Gas Cons. Commission Logging Prol [Open Hole Logs: SURFACE PRODUCTION Cased Hole Logs: ,ram. NONE GR/Resistivity/Neutron/Density w/MWD (From top of K-10 to TD) Gvro/Cement Bond Log (After Rig Release) Mud Program'. Special design considerations I Fresh water dispersed mud to TD (KCL is not needed in water injection wells) Surface Mud Properties: ] SPUD Density Marsh Yield 10 sec 10 min pH Fluid (PPG) Viscosity Point gel gel Loss 8.7 300 40-60 30-60 60-80 9-10 15-25 Intermed{ate Mud Properties: [ Fresh / lightly dispersed Density Marsh Yield I0 sec 10 min pH Fluid (PPG) Viscosity Point gel gel Loss 9.5 50 20-40 15-20 20-30 9-10 10-20 Production Mud Properties: ] Fresh/lightly dispersed/HTHP < 12 Density PV Yield 10 sec 10 min pH Fluid (PPG) Viscosity Point gel gel Loss 9.5 8-15 25-30 5-15 10-20 9-10 10-15 10.0 15-30 25-30 8-12 <25 9-9.5 8-10 API HTHP < 12 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. Directional'. [ KOP: [ 522'; departure = 7371' @ TD Maximum Hole Angle: [45 DEG; 28 D,EG Azimuth Close Approach Well: [ P2-5,9 @ 2800 tvd in P2 -15 [ (359; Spred Factor = 4.6) The above listed wells will be secured during the close approach. EC'EIVED 1998 lldaka t~tl & L~aS COtiS. Commission Anchorage Well Plan Summary P2-15 Page 2 Surface Casing Depth: Surface Casing Size: Surface Casing Weight: Bit Diameter: Excess Factor Intermediate Casing Depth: Intermediate Casing Size Intermediate Casing Weight: Proposed Top of Cement Bit Diameter: Excess Factor: P2-15 Cement Volumes Surface String 4388 10 3/4 45.5 13.5 2 LEAD (TYPE "E" PERMAFROST) Yield 2.17 Density 1 2 # sacks 1304 (2831 Cu. Ft.) TAIL (CLASS G) Yield 1.16 Density 15.8 # sacks 350 (406 Cu. Ft.) TOP JOB (TYPE "C" PERMAFROST) # sacks 2 50 (235 Cu. Ft.) .94 cuft/sx 15.6 ppg Production String 12092 7 5/8 29.7 -- . 1 O788 9 7/8 1.9 LEAD Yield I .98 Density 1 5 # sacks 0 # bbls 0 TAIL (CLASS G) Yield 1.2 Density 15.8 # sacks 4 86 # bbls I 04 (0 Cu. Ft.) (583 Cu. Ft.) OCT ~,laska 0il & Gas Cons. Commission Anchorage . . . . . . . . , MIRU drilling rig. P2-15 Operations Summary Spud well and drill 13-1/2" hole to 4388' md/3700' tvd building angle to 45 degrees. KOP is at 522'. Set 10-3/4" casing and cement same. Test casing to 3000 psi for 30 minutes. Nipple up BOPs and test same to 5000 psi. Pick up 9-7/8" BHA and drill 10' of new hole and perform leakoff test. Continue drilling to 12092' md / 9195' tvd. Open hole logs will be completed with MWD tools. Set 7 5/8" L-80 casing and cement same, displacing with 10.5 ppg brine. Test casing to 4000 psi for 30 minutes. Displace the top 2200' tvd of casing with diesel. Run 1 joint 4-1/2" tubing & install a master valve & tree cap. The well will be completed at a later date. Freeze protect the annulus with diesel. Release rig. Run cased hole logs: cement bond log, gyro. Note: This well will be completed after DOYON #14 moves off location. OCT- ! -~laska 0ii & Gas Cons. Commission Anchorage Prudhoe Bay Drilli' r Point MeIn[yre, Alaska Well' P2-15 File' P2-15wp (I HALL IBURTON' DRILLING SYSTEHS 05/14/1993 3.:10 cm 522 lOOO--i\ 2000 6000 VERTICAL VIEW SCALE 1000 ft. / DIVISION TVD REF: WELLHEAD VERTICAL SECTION REF: WELLHEAD 0,00' ~ 0 MD TIE IN 0,00' ~ 522 MD START OF BUILD ~ 2.00 BEG/lO0 FT 4.00' @ 722 MD 8.00' ~ 922 MD 12.00' ~ 1122 MD 16 00' ~ 1322 HD 20 00' ~ 1522 MD 24 00' ~ 1722 MD 28 00' e 1922 MD 32 00' ~ 2122 ND 36.00' @ 2322 HD 40,00' @ 2522 MD 44.00' ~ 2722 MD 821 44.50' ~ 2747 MD END OF BUILD 10.750 OD, 8 4388 HD, 3700 TVB HORIZONTAL VIEW SCALE 1000 ft. / DIVISION SURVEY REF: WELLHEAD ~°.>~o 1000 2000 'b - e>o° I 3000 7000 · --6000 --5000 '~e. --4000 --3000 --2000 --1000 0 4OOO 698~ 5198 44.50' 8 8991 MD WEST SAK 9195 10000 71~0 714~ /ib~ 7301. 7371 -- 44,50' 8 11788 MD TARGET - KUPARUK 44.50' 8 11992 MD 44.50' ~ 12092 MD TOTAL DEPTH I I I I 1000 2000 3000 4000 VERTICAL SECTION PLANE: 28.48' CRITICAL POINT DATA MD Inc Azl TVD North TIE IN 0 0.00 0.00 0 0 0 START ar BUILD 522 0,00 0,00 522 0 0 @ 8.00 DEG/iO0 END OF BUILD 2747 44.50 28.48 2530 722 392 WEST SAK 8991 44.50 28.48 6984 4569 2479 K-lO, K-5, HRZ 11732 44.50 28.48 8938 6258 3395 KALUBIK 11774 44.50 28.48 8968 6284 3409 TARGET - 11788 44.50 28.48 8978 6293 3413 KUPARUK TOTAL DEPTH 12092 44.50 28.48 9195 6479 3515 I 5000 I 6000 I 7000 1 8000 ,Alaska Oil & Gas ~o;ls. uommismo, Anchorage Dote Plotted Created By Checked By Approved By Date 5114/93 BHL DATA I ~ 9194'8~l 12091.52J VS 7371.41] North 6479.50] East 3514.80J ITEM ' APPROVE (1) Fee (2) Loc 8] (3) Admin [..~/_ [9 thru 13] [10 & 13] [14 thru 22] (4) Casg (5) BOPE Company_ ** CHECK LIST FOR NEW WELL PERMITS ** DATE YES NO 2. 3. 4.' 5. 7. Is operator the only affected Catty .................................. ~ 8 Can Cerrnit be a¢~roved before 15-day ~ait ............................ [23 thru i 10. 11. 12. 13. 14. 15. 16. 17. 18. 19. 20. 21. 22. 23. 24. 25. 26. 27. 28. (6) Other ~_~L [29 thru 31] 29. 30. 31. 32. 33. (7) Contact [32] (8) Addl geo 1 ogy' eng i nee r i ng: . //'/, DWJ~ MTM ~ RPC~.~ BEW~. DH '-- TA~~ ./ / REMARKS Is permit fee attached ............................................... Is well to be located in a defined pool .............................. Is well located proper distance from property line ................... Is well located proper distance from other wells ..................... Is sufficient undedicated acreage available in this pool ............. Is well to be deviated & is wellbore plat included ................... Does operator have a bond in force ................................... ~ Is a conservation order needed ....................................... ,, , Is administrative approval needed .................................... Is lease nL~nber appropriate .......................................... ~_ .... Does well have a unique name & nL~nber ................................ Is conductor string provided ......................................... ~ Will surface casing protect all zones reasonably expected to serve as an underground source of drinking water .................. ~ Is enough cement used to circulate on conductor & surface ............ t? Will cement tie in surface & intermediate or production strings ...... ~ Will cement cover all known productive horizons ..................... ~ Will all casing give adequate safety in collapse, tension, and burst. ~ Is well to be kicked off from an existing wellbore ................... - -~ Is old wellbore abandonment procedure included on 10-403 ............. Is adequate wellbore separation proposed ............................. Is a diverter system required ........................................ _-~ Is drilling fluid program schematic & list of equipment adequate ..... Are necessary diagrams & descriptions of diverter & BOPE attached .... Does BOPE have sufficient pressure rating -- test to ~'~ psig ..... Does choke manifold comply w/API RP-53 (May 84) ...................... Is presence of H2S gas'probable ...................................... FOR EXPLORATORY & STRATIGRAPHIC WELLS: Are data presented on potential overpressure zones ................... Are seismic analysis data presented on shallow gas zones ............. If offshore loc, are survey results of seabed conditions presented... Name and phone number of contact to supply weekly progress data ...... requirements ............................................. Additional Additional MERIDIAN: remarks' UM SM WELL TYPE' Exp/Dev Redrill Inj Rev rev 6/93 jo/6.011 INITIAL GEOL UNIT ON/OFF POOL CLASS STATUS AREA ~ SHORE 0 -rz ~0 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 simp!iff/finding information, informati;3n 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. Tape Subfile 2 is type: LIS TAPE HEADER POINT MCINTYRE UNIT OPEN HOLE WIRELINE LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION(FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD P2 - 15 500292240900 ARCO ALASKA INCORPORATED ATLAS WIRELINE SERVICES 15-MAR-94 RUN 2 RUN 3 RUN 1 6166.00 J. DAHL BAKER/WESTER 14 12N 14E 23 1171 46.50 45.00 10.45 OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 1ST STRING 2ND STRING 3RD STRING 10.750 4380.0 PRODUCTION STRING 9.875 12220.0 REMARKS: DIFL/ZDL/CN/GR. MARCH 4 TRIP IN HOLE: CIRCULATION STOPPED AT 17:30, 03-MAR-94. TD NOT REACHED DUE TO A BRIDGE AT 11095'. TOOL LOGGED FROM 10782' DUE TO HOLE PROBLEMS BELOW. DENSITY-NEUTRON RUN IN THE COMBINATION BUT NOT LOGGED BECAUSE THE ZONE OF INTEREST WAS NOT REACHED. A DIFL REPEAT WAS ALSO RECORDED. MARCH 5 TRIP IN HOLE: CIRCULATION STOPPED AT 03:00, 05-MAR-94. DIFL/GR WAS DIGITALLY SPLICED AT 10708' WITH THE UPPER PORTION LOGGED ON 04-MAR-94. SP SHIFT AT 10708' IS DUE TO SPLICE. AFTER WIPER TRIP THE BOTTOM PORTION WAS LOGGED TO TD. NEUTRON LOG PARAMETERS: SANDSTONE MATRIX, CALIPER CORRECTED, CHISM NOT ACTIVE, NO CASING OR SALINITY CORRECTIONS APPLIED. REPEAT PASS HAS PROBABLE MUDBALL ON TOOL FROM TD TO 12000'. 5 PASSES WERE ATTEMPTED TO GET A FULL REPEAT BARITE PRESENT IN MUD SYSTEM (1.1%). PER CLIENTS REQUEST, BOREHOLE & TORNADO CHART CORREC- TIONS WERE APPLIED TO THE DIL DATA. THE DIL DATA WAS CORRECTED FOR BOREHOLE SIZE (9.875"). THE CORRECTED DATA WAS WAS THEN USED IN THE ATLAS TORNADO CHART TO GET AN "RT" CURVE & "DI" CURVE (depth of invasion) . A DEPTH SHIFTED RAW CN CURVE IS INCLUDED IN THE FINAL FILE PER ARCO ALASKA'S REQUEST. FILE HEADER FILE NUMBER: 1 EDITED OPEN HOLE MAIN PASS All tool strings with depth shifted and clipped curves; (including cased hole). DEPTH INCREMENT: 0.5000 FILE SUMMARY LDWG TOOL CODE GR DIL SDN 2435 $ BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA START DEPTH STOP DEPTH 8700.0 12162.0 8700.0 12220.0 11650.0 12184.0 11650.0 12167.0 GR (MEASURED DEPTH) BASELINE DEPTH 8694.0 8740.5 8746.0 8749.0 8787.5 8837.5 8884.5 8910.5 8957.0 8966.0 8971.5 8987.5 8988.0 9028.0 9030.0 9076.0 9142.0 9147.5 9217.5 9218.0 9236.5 9245.5 9290.0 9313.0 9314.0 9386.0 9430.0 9465.5 9480.0 9484.0 9511.0 9514.0 9684.5 9685.0 9919.0 9919.5 9922.5 9943.5 9944.0 10004.0 ......... EQUIVALENT UNSHIFTED DEPTH LL8 ILM 8694.0 8694.0 8741.0 8746.5 8746.5 8750.0 8788.0 8838.0 8884.5 8911.0 8909.5 8956.5 8966.5 8971.5 8987.5 8987.5 9027.0 9030.0 9076.0 9142.5 9148.0 9218.0 9218.5 9236.5 9245.5 9290.0 9289.5 9312.5 9314.5 9386.0 9430.0 9465.5 9481.0 9484.5 9511.5 9511.5 9514.0 9686.0 9685.5 9920.5 9920.0 9923.0 9943.5 9944.0 10005.0 RHOB NPHI 8694.0 8694.0 all runs merged 10068.5 10069.0 10175.5 10232.5 10270.0 10271.5 10471.0 10535.0 10594.0 10906.0 11038.0 11039.0 11119.5 11152.5 11257.0 11345.0 11408.0 11438.5 11490.0 11492.0 11730.5 11732.0 11733.0 11741.5 11743.0 11746.0 11747.5 11752.5 11754.5 11755.0 11755.5 11760.0 11760.5 11771.0 11772.0 11774.0 11774.5 11787.0 11791.0 11793.5 11798.0 11800.5 11802.5 11803.0 11808.0 11811.5 11814.5 11815.5 11820.0 11821.0 11821.5 11830.5 11833.5 11835.0 11845.0 11850.5 11851.0 11854.0 11857.5 11859.0 10068.5 10270.5 10472.5 10535.0 10594.5 11038.5 11151.5 11407.0 11438.5 11489.5 11732.5 11773.5 11798.0 11822.0 11859.5 10068.5 10175.0 10231.0 10271.0 10471.0 10534.0 10593.0 10905.0 11038.0 11118.5 11151.0 11255.5 11344.5 11407.0 11490.5 11731.5 11742.5 11754.0 11759.0 11770.0 11771.0 11792.5 11802.5 11811.0 11814.5 11821.5 11851.0 11858.0 11732.0 11740.5 11747.5 11755.0 11760.5 11787.5 11802.5 11814.5 11831.0 11836.0 11854.5 11730.0 11733.5 11741.5 11746.0 11751.5 11754.5 11760.0 11771.0 11774.0 11786.5 11790.5 11797.0 11799.5 11807.5 11820.0 11830.5 11833.0 11845.5 11851.5 11859.5 11860.0 11863.5 11868.0 11874.0 11880.0 11893.0 11903.0 11904.0 11904.5 11907.5 11911.0 11915.5 11921.0 11923.5 11925.5 11926.5 11932.0 11936.0 11936.5 11946.0 11948.5 11951.0 11965.5 11966.0 11966.5 11973.5 11976.0 11985.5 11998.5 12001.0 12005.0 12009.0 12011.0 12020.0 12023.5 12025.5 12026.0 12027.0 12028.5 12033.0 12040.5 12041.0 12062.5 12067.0 12069.0 12101.0 12129.0 12166.0 12230.0 $ MERGED DATA SOURCE LDWG TOOL CODE GR GR DIL DIL SDN 2435 11904.0 11915.5 11966.5 12025.0 12033.0 12069.0 12230.0 RUN NO. 1 1 1 1 1 1 11860.0 11863.5 11911.5 11925.0 11936.0 11945.5 11950.0 11965.5 12000.5 12028.0 12040.0 12230.0 PASS NO. 3 10 3 10 10 10 11860.5 11864.5 11868.5 11904.5 11907.5 11859.0 11874.0 11880.0 11893.0 11902.5 11936.0 11921.0 11923.0 11927.0 11931.5 11965.5 11976.0 11986.0 12021.0 12024.0 12027.0 11948.5 11966.0 11974.5 11985.5 11999.0 12005.5 12009.5 12011.5 12026.0 12041.5 12101.0 12230.0 12040.5 12061.5 12066.5 12129.0 12166.0 12230.0 MERGE TOP 8700.0 10708.0 8700.0 10708.0 11650.0 11650.0 MERGE BASE 10708.0 12162.0 10708.0 12220.0 12184.0 12167.0 $ REMARKS: MAIN PASS. DIFL/GR DATA IS A COMBINATION OF 04-MAR-94 & 05-MAR-94 RECORDED LOGS. MTEM, SP, TEND, & TENS WERE SHIFTED WITH LL8. ILD, RT, & DI WERE SHIFTED WITH ILM. DRHO, PEF, & CALl WERE SHIFTED WITH RHOB. FUCT & NUCT WERE SHIFTED NPHI. DI = DEPTH OF INVASION. RT = TRUE FORMATION RESISTIVITY. CN WN FN COUN STAT / ? ?MATCH1 · OUT / ? ?MATCH2. OUT / ??MATCH3. OUT /??MATCH4. OUT $ : ARCO ALASKA INC. : P2 - 15 : POINT MCINTYRE : NORTH SLOPE : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 17 Curves: Name Tool Code Samples Units 1 GR DIL 68 1 GAPI 2 LL8 DIL 68 1 OHMM 3 ILM DIL 68 1 OHMM 4 ILD DIL 68 1 OHMM 5 RT DIL 68 1 OHMM 6 DI DIL 68 1 IN 7 SP DIL 68 1 MV 8 MTEM DIL 68 1 DEGF 9 TEND DIL 68 1 LB 10 TENS DIL 68 1 LB 11 RHOB SDN 68 1 G/C3 12 DRHO SDN 68 1 G/C3 13 PEF SDN 68 1 BN/E 14 CALl SDN 68 1 IN 15 NPHI 2435 68 1 PU-S 16 FUCT 2435 68 1 CPS 17 NUCT 2435 68 1 CPS API API API API Log Crv Crv Size Length Typ Typ Cls Mod 4 4 55 965 57 0 4 4 50 746 76 1 4 4 50 746 76 1 4 4 50 746 76 1 4 4 50 746 76 1 4 4 50 746 76 1 4 4 50 746 76 1 4 4 50 746 76 1 4 4 50 746 76 1 4 4 50 746 76 1 4 4 22 779 91 0 4 4 22 779 91 0 4 4 22 779 91 0 4 4 22 779 91 0 4 4 98 211 23 1 4 4 98 211 23 1 4 4 98 211 23 1 68 * DATA RECORD (TYPE# 0) 1014 BYTES * Total Data Records: 506 Tape File Start Depth = 12230.000000 Tape File End Depth = 8694.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 127315 datums Tape Subfile: 2 785 records... Minimum record length: Maximum record length: 62 bytes 1014 bytes Tape Subfile 3 is type: LIS FILE HEADER FILE NUMBER: 2 RAW OPEN HOLE MAIN PASS Composite of all curves and log header data from all tool strings for a single run; Run #1 presented first followed by separate files for any other subsequent runs. RUN NUMBER: 1 TOOL STRING NUMBER: 1 PASS NUMBER: 3 DEPTH INCREMENT: 0.2500 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 8700.0 DIFL 8700.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME CIRCULATION ENDED: TIME LOGGER ON BOTTOM: TD DRILLER (FT): TD LOGGER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): LOGGING SPEED (FPHR): STOP DEPTH 10722.0 10782.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE CHT MODL MIS GR CN ZDL KNJT KNJT TEMP PCM DIFL $ CABLEHEAD TENSION MODAL SUB MASS ISOLATION SUB GAMMA RAY COMPENSATED NEUTRON Z-DENSITY KNUCKLE JOINT KNUCKLE JOINT TEMPERATURE PULSE CODE MODULATOR DUAL INDUCTION BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE(IN): DRILLER'S CASING DEPTH (FT): LOGGER' S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: FLUID LOSS (C3): MAXIMUM RECORDED TEMPERATURE (DEGF): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): 04-MAR-94 FSYS REV. J001 VER. 1.1 1730 03-MAR-94 55 04-MAR-94 12100.0 11095.0 8700.0 10782.0 3000.0 TOOL NUMBER 3974XA 3517XA 3967XA 1309XA 2435XA 2222EA/2222MA 3921NA 3921NA 2806XA 3506XA 1503XA 9.875 4380.0 0.0 LIGHTLY DISPERSED 9.90 49.0 9.9 4.0 137.0 1.780 68.0 MUD AT BOTTOM HOLE TEMPERATURE (BHT): MUD FILTRATE AT MT: MUD FILTRATE AT BHT: MUD CAKE AT MT: MUD CAKE AT BHT: 0.920 2.340 0.000 1.300 0.000 137.0 68.0 0.0 68.0 0.0 NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): 0.00 0.000 TOOL STANDOFF (IN): 1.5 REMARKS: MAIN PASS from first trip in hole (04-MAR-94). TD NOT REACHED DUE TO A BRIDGE AT 11095'. TOOL LOGGED FROM 10782' DUE TO HOLE PROBLEMS BELOW. DENSITY-NEUTRON RUN IN THE COMBINATION BUT NOT LOGGED BECAUSE THE ZONE OF INTEREST WAS NOT REACHED. $ CN WN FN COUN STAT : ARCO ALASKA INC. : P2 - 15 : POINT MCINTYRE : NORTH SLOPE : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 12 Curves: Name Tool Code Samples Units I GR DIFL 68 1 GAPI 2 RFOC DIFL 68 1 OHMM 3 RILM DIFL 68 1 OHMM 4 RILD DIFL 68 1 OHMM 5 RT DIFL 68 1 OHMM 6 DI DIFL 68 1 IN 7 VILD DIFL 68 1 MV 8 SP DIFL 68 1 MV 9 TEMP DIFL 68 1 DEGF 10 CHT DIFL 68 1 LB 11 TTEN DIFL 68 1 LB 12 SPD DIFL 68 1 F/MN API API API API Log Crv Crv Size Length Typ Typ Cls Mod 4 4 67 456 14 5 4 4 27 515 24 6 4 4 06 213 78 0 4 4 04 903 06 0 4 4 04 903 06 0 4 4 06 213 78 0 4 4 04 522 10 6 4 4 53 419 67 0 4 4 40 467 34 0 4 4 78 867 34 0 4 4 78 867 34 0 4 4 13 331 34 0 48 * DATA RECORD (TYPE# 0) Total Data Records: 442 994 BYTES * Tape File Start Depth = 10792.000000 Tape File End Depth = 8696.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 109006 datums Tape Subfile: 3 524 records... Minimum record length: 62 bytes Maximum record length: 994 bytes Tape Subfile 4 is type: LIS FILE HEADER FILE NUMBER: 3 RAW OPEN HOLE MAIN PASS Composite of all curves and log header data from all tool strings for a single run; Run #1 presented first followed by separate files for any other subsequent runs. RUN NUMBER: TOOL STRING NUMBER: PASS NUMBER: DEPTH INCREMENT: FILE SUMMARY 1 2 10 0.2500 VENDOR TOOL CODE START DEPTH STOP DEPTH GR 8700.0 12179.0 DIFL 8700.0 12229.0 ZDL 11650.0 12203.0 2435 11650.0 12185.5 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME CIRCULATION ENDED: TIME LOGGER ON BOTTOM: TD DRILLER (FT): TD LOGGER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): LOGGING SPEED (FPHR): TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE CHT MODL MIS GR CN ZDL KNJT TEMP PCM DIFL $ CABLEHEAD TENSION MODAL SUB MASS ISOLATION SUB GAMMA RAY COMPENSATED NEUTRON Z-DENSITY KNUCKLE JOINT TEMPERATURE PULSE CODE MODULATOR DUAL INDUCTION BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE(IN): DRILLER'S CASING DEPTH (FT): LOGGER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: FLUID LOSS (C3): MAXIMUM RECORDED TEMPERATURE (DEGF): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) 05-MAR-94 FSYS REV. J001 VER. 1.1 300 05-MAR-94 1431 05-MAR-94 12220.0 12223.0 8700.0 12220.0 1800.0 TOOL NUMBER 3974XA 3517XA 3967XA 1309XA 2435XA 2222EA/2222MA 3921NA 2806XA 3506XA 1503XA 9.875 4380.0 0.0 LIGHTLY DISPERSED 10.00 48.0 9.9 4.2 164.0 MUD AT MEASURED TEMPERATURE (MT): MUD AT BOTTOM HOLE TEMPERATURE (BHT): MUD FILTRATE AT MT: MUD FILTRATE AT BHT: MUD CAKE AT MT: MUD CAKE AT BHT: 1.530 0.710 1.830 0.000 1.280 0.000 70.0 164.0 70.0 0.0 70.0 0.0 NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): THERMAL SANDSTONE 2.65 0.000 TOOL STANDOFF (IN): 1.5 REMARKS: MAIN PASS from second trip in hole (05-MAR-94). THE DIFL/GR DATA ABOVE 10708' WAS RECORDED 04-MAR-94 & WAS SPLICED IN THE FIELD FOR COMPLETE DATA COVERAGE. $ CN WN FN COUN STAT : ARCO ALASKA INC. : P2 - 15 : POINT MCINTYRE : NORTH SLOPE : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 21 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 19 2O 21 GR DIFL 68 1 GAPI RFOC DIFL 68 1 OHMM RILM DIFL 68 1 OHMM RILD DIFL 68 1 OHMM RT DIFL 68 1 OHMM DI DIFL 68 1 IN VILD DIFL 68 1 MV SP DIFL 68 1 MV TEMP DIFL 68 1 DEGF CHT DIFL 68 1 LB TTEN DIFL 68 1 LB SPD DIFL 68 1 F/MN ZDEN ZDL 68 1 G/C3 ZCOR ZDL 68 1 G/C3 PE ZDL 68 1 BN/E CAL ZDL 68 1 IN CNC 2435 68 1 PU-S CNCF 2435 68 1 PU-S CN 2435 68 i PU-L LSN 2435 68 1 CPS SSN 2435 68 1 CPS 4 4 67 456 14 5 4 4 27 515 24 6 4 4 06 213 78 0 4 4 04 903 06 0 4 4 04 903 06 0 4 4 06 213 78 0 4 4 04 522 10 6 4 4 53 419 67 0 4 4 40 467 34 0 4 4 78 867 34 0 4 4 78 867 34 0 4 4 13 331 34 0 4 4 52 443 33 1 4 4 09 884 61 1 4 4 76 731 33 1 4 4 24 115 90 6 4 4 98 211 23 1 4 4 98 211 23 1 4 4 52 326 75 5 4 4 84 023 70 1 4 4 83 368 34 1 * DATA RECORD (TYPE# 0) Total Data Records: 1286 974 BYTES * 84 Tape File Start Depth = 12230.000000 Tape File End Depth = 8694.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 438506 datums Tape Subfile: 4 1368 records... Minimum record length: 62 bytes Maximum record length: 974 bytes Tape Subfile 5 is type: LIS FILE HEADER FILE NUMBER: 4 RAW OPEN HOLE REPEAT PASSES Composite of all curves and log header data from all tool strings for a single run; Multiple repeat passes for individual tool strings, if they exist, follow in a separate file. Run #1 presented first followed by separate files for any other subsequent runs. RUN NUMBER: 1 TOOL STRING NUMBER: 1 PASS NUMBER: 4 DEPTH INCREMENT: 0.2500 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 8700.0 DIFL 8700.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME CIRCULATION ENDED: TIME LOGGER ON BOTTOM: TD DRILLER (FT): TD LOGGER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): LOGGING SPEED (FPHR): TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE CHT MODL MIS GR CN ZDL KNJT KNJT TEMP PCM DIFL $ CABLEHEAD TENSION MODAL SUB MASS ISOLATION SUB GAMMA RAY COMPENSATED NEUTRON Z-DENSITY KNUCKLE JOINT KNUCKLE JOINT TEMPERATURE PULSE CODE MODULATOR DUAL INDUCTION BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE(IN): DRILLER'S CASING DEPTH (FT): LOGGER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: FLUID LOSS (C3): MAXIMUM RECORDED TEMPERATURE (DEGF): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) STOP DEPTH 8894.5 8955.0 04-MAR-94 FSYS REV. J001 VER. 1.1 1730 03-MAR-94 141 04-MAR-94 12100.0 11095.0 8700.0 10782.0 3000.0 TOOL NUMBER 3974XA 3517XA 3967XA 1309XA 2435XA 2222EA/2222MA 3921NA 3921NA 2806XA 3506XA 1503XA 9.875 4380.0 0.0 LIGHTLY DISPERSED 9.90 49.0 9.9 4.0 137.0 MUD AT MEASURED TEMPERATURE (MT): MUD AT BOTTOM HOLE TEMPERATURE (BHT): MUD FILTRATE AT MT: MUD FILTRATE AT BHT: MUD CAKE AT MT: MUD CAKE AT BHT: 1.780 0.920 2.340 0.000 1.300 0.000 68.0 137.0 68.0 0.0 68.0 0.0 NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): 0.00 0.000 TOOL STANDOFF (IN): 1.5 REMARKS: REPEAT PASS from first trip in hole (04-MAR-94). $ CN WN FN COUN STAT : ARCO ALASKA INC. : P2 - 15 : POINT MCINTYRE : NORTH SLOPE : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 12 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GR DIFL 68 1 GAPI 4 2 RFOC DIFL 68 1 OHMM 4 3 RILM DIFL 68 1 OHMM 4 4 RILD DIFL 68 1 OHMM 4 5 RT DIFL 68 1 OHMM 4 6 DI DIFL 68 1 IN 4 7 VILD DIFL 68 1 MV 4 8 SP DIFL 68 1 MV 4 9 TEMP DIFL 68 1 DEGF 4 10 CHT DIFL 68 1 LB 4 11 TTEN DIFL 68 1 LB 4 12 SPD DIFL 68 1 F/MN 4 4 67 456 14 5 4 27 515 24 6 4 06 213 78 0 4 04 903 06 0 4 04 903 06 0 4 06 213 78 0 4 04 522 10 6 4 53 419 67 0 4 40 467 34 0 4 78 867 34 0 4 78 867 34 0 4 13 331 34 0 48 * DATA RECORD (TYPE# 0) 994 BYTES * Total Data Records: 58 Tape File Start Depth = 8965.000000 Tape File End Depth = 8693.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 123164 datums Tape Subfile: 5 137 records... Minimum record length: 62 bytes Maximum record length: 994 bytes Tape Subfile 6 is type: LIS TOOL STRING NUMBER: PASS NUMBER: DEPTH INCREMENT: FILE SUMMARY FILE HEADER FILE NUMBER: 5 RAW OPEN HOLE REPEAT PASSES Composite of all curves and log header data from all tool strings for a single run; Multiple repeat passes for individual tool strings, if they exist, follow in a separate file. Run #1 presented first followed by separate files for any other subsequent runs. RUN NUMBER: 1 2 6 0.2500 VENDOR TOOL CODE START DEPTH STOP DEPTH GR 11760.0 12166.0 DIFL 11760.0 12224.0 ZDL 11760.0 12189.5 2435 11760.0 12172.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME CIRCULATION ENDED: TIME LOGGER ON BOTTOM: TD DRILLER (FT): TD LOGGER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): LOGGING SPEED (FPHR): TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE CHT MODL MIS GR CN ZDL KNJT TEMP PCM DIFL $ CABLEHEAD TENSION MODAL SUB MASS ISOLATION SUB GAMMA RAY COMPENSATED NEUTRON Z-DENSITY KNUCKLE JOINT TEMPERATURE PULSE CODE MODULATOR DUAL INDUCTION BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE(IN): DRILLER'S CASING DEPTH (FT): LOGGER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: FLUID LOSS (C3): MAXIMUM RECORDED TEMPERATURE (DEGF): 05-MAR-94 FSYS REV. J001 VER. 1.1 300 05-MAR-94 1317 05-MAR-94 12220.0 12223.0 8700.0 12220.0 1800.0 TOOL NUMBER 3974XA 3517XA 3967XA 1309XA 2435XA 2222EA/2222MA 3921NA 2806XA 3506XA 1503XA 9.875 4380.0 0.0 LIGHTLY DISPERSED 10.00 48.0 9.9 4.2 164.0 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT BOTTOM HOLE TEMPERATURE (BHT): MUD FILTRATE AT MT: MUD FILTRATE AT BHT: MUD CAKE AT MT: MUD CAKE AT BHT: 1.530 0.710 1.830 0.000 1.280 0.000 70.0 164.0 70.0 0.0 70.0 0.0 NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): THERMAL SANDSTONE 2.65 0.000 TOOL STANDOFF (IN): 1.5 REMARKS: REPEAT PASS from second trip in hole (05-MAR-94). $ CN WN FN COUN STAT : ARCO ALASKA INC. : P2 - 15 : POINT MCINTYRE : NORTH SLOPE : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 21 Curves: 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 19 2O 21 Name Tool Code Samples Units GR DIFL 68 1 GAPI RFOC DIFL 68 1 OHMM RILM DIFL 68 1 OHMM RILD DIFL 68 i OHMM RT DIFL 68 1 OHMM DI DIFL 68 1 IN VILD DIFL 68 1 MV SP DIFL 68 1 MV TEMP DIFL 68 1 DEGF CHT DIFL 68 1 LB TTEN DIFL 68 1 LB SPD DIFL 68 1 F/MN ZDEN ZDL 68 1 G/C3 ZCOR ZDL 68 1 G/C3 PE ZDL 68 1 BN/E CAL ZDL 68 1 IN CNC 2435 68 1 PU-S CNCF 2435 68 1 PU-S CN 2435 68 1 PU-L LSN 2435 68 i CPS SSN 2435 68 I CPS API API API API Log Crv Crv Size Length Typ Typ Cls Mod 4 4 67 456 14 5 4 4 27 515 24 6 4 4 06 213 78 0 4 4 04 903 06 0 4 4 04 903 06 0 4 4 06 213 78 0 4 4 04 522 10 6 4 4 53 419 67 0 4 4 40 467 34 0 4 4 78 867 34 0 4 4 78 867 34 0 4 4 13 331 34 0 4 4 52 443 33 1 4 4 09 884 61 1 4 4 76 731 33 1 4 4 24 115 90 6 4 4 98 211 23 1 4 4 98 211 23 1 4 4 52 326 75 5 4 4 84 023 70 1 4 4 83 368 34 1 84 * DATA RECORD (TYPE# 0) Total Data Records: 172 974 BYTES * Tape File Start Depth = 12230.000000 Tape File End Depth = 11758.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 480065 datums Tape Subfile: 6 253 records... Minimum record length: Maximum record length: 62 bytes 974 bytes Tape Subfile 7 is type: LIS CN IS RAW RECORDED NEUTRON IN LIMESTONE UNITS WITH NO BOREHOLE OR ENVIRONMENTAL CORRECTIONS APPLIED. THIS CURVE HAS BEEN DEPTH SHIFTED. THE SAME SHIFTS WERE APPLIED AS THOSE USED FOR NPHI, FUCT, & NUCT CURVES IN THE EDITED MAIN PASS FILE. THIS FILE IS INCLUDED IN THIS FORMAT PER ARCO ALASKA REQUEST. * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 1 Curves: Name Tool Code Samples Units CN 2435 68 1 PU-L * DATA RECORD (TYPE# 0) Total Data Records: 56 API API API API Log Crv Crv Size Length Typ Typ Cls Mod 4 4 88 101 47 5 4 1022 BYTES * Tape File Start Depth = 12230.000000 Tape File End Depth = 8694.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 137311 datums Tape Subfile: 7 61 records... Minimum record length: 62 bytes Maximum record length: 1022 bytes Tape Subfile 8 is type: LIS 94/ 3/15 01 **** REEL TRAILER **** 94/ 3/17 01 Tape Subfile: $ 2 records... Minimum record length: 132 bytes Maximum record length: 132 bytes End of execution: Thu 17 MAR 94 3:32p Elapsed execution time = 9 minutes, 8.0 seconds. SYSTEM RETURN CODE = 0