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Home My WebLink About203-180 ) ) Image Project Well History File Cover Page XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. ~ 0:3 - 1 <30 Well History File Identifier Organizing (done) o Two-sided 11111111I1111111111 RESCAN DIGITAL DATA D Color Items: o Greyscale Items: D Diskettes, No. D Other, NolType: D Poor Quality Originals: D Other: NOTES: Date: Jð- ~ IOS- Date: I&- '.g..q IOS- I X 30 = l"=) D + Date: IJ-ja-r/OS- BY: G:"Maria ') Project Proofing BY: ~ Scanning Preparation BY: ~_ Production Scanning o Rescan Needed 1111111111111111111 OVERSIZED (Scannable) o Maps: o Other Items Scannable by a Large Scanner OVERSIZED (Non-Scannable) o Logs of various kinds: o Other:: VV/P 111111111111111111I 151 /s/ m9 a, if = TOTAL PAGES ,-'Jt¡ (Count does not i~~;ude cover sheet) ß1 !J 1111111111111111111 Stage 1 Page Count from Scanned File: l ~ S (Count does include cover sheet) VYES BY: Page Count Matches Number in sca~ninr preparat~ ?Marig) Date: ld-f9-1/0$ If NO in stage 1, page(s) discrepancies were found: Stage 1 BY: Date: Maria Scanning is complete at this point unless rescanning is required. ReScanned BY: Date: Maria Comments about this file: NO [) (Y1 151 YES NO 151 1111111111111111111 1111111111111111111 151 Quality Checked 1111111111111111111 10/6/2005 Well History File Cover Page.doc STATE OF ALASKA 'o?~$-D1T ~ ~ / . ~ ALASK~IL AND GAS CONSERVATION COM SION ~ ~ Zl;~a~ WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1a. Well Status: ^ Oil ^ Gas ^ Plugged ®Abandoned ^ Suspended zoAACZS.~os zoAACZS.r~o ^ GINJ ^ WINJ ^ WDSPL ^ WAG ^ Other No. of Completions Zero 1 b. Well Class: -" ®Development ^ Exploratory ^ Service ^ Stratigraphic 2. Operator Name: BP Exploration (Alaska) Inc. 5. Date Comp., Susp., or Aband 7/5!2008 12. Permit to Drill Number 203-180 308-167 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 6. Date Spudded 11/16/2003 13. API Number 50-029-20768-01-00 4a. Location of Well (Governmental Section): Surface: ' ' 7. Date T.D. Reached 11/22/2003 14. Well Name and Number: PBU 13-30A NSL, 1511 1990 WEL, SEC. 14, T10N, R14E, UM Top of Productive Horizon: 469' NSL, 4061' WEL, SEC. 14, T10N, R14E, UM g KB (ft above MSL): 74.5' Ground (ft MSL): 15. Field /Pool(s): Prudhoe Ba Field / Prudhoe Ba Y Y Total Depth: 181' SNL, 3440' WEL, SEC. 23, T10N, R14E, UM 9. Plug Back Depth (MD+TVD) 10753 8980 Pool 4b. Location of Well (State Base Plane Coordinates, NAD 27): Surface: x- 685705 y- 5932020 Zone- ASP4 10. Total Depth (MD+TVD) 10753 8980 16. Property Designation: ADL 028315 TPI: x- 683194 y_ 5930437 Zone- ASP4 Total Depth: x- 683832 y- 5929802 Zone- ASP4 11. SSSV Depth (MD+TVD) N/A 17. Land Use Permit: 18. Directional Survey ^ Yes ®No Submit electronic and rinted information er 20 AAC 25.050 19. Water depth, if offshore N/A ft MSL 20. Thickness of Permafrost (TVD): 1900' (Approx.) 21. Logs Obtained (List all logs here and submit electronic and printed information per 20 AAC 25.071): DIR, GR, RES, ABI 22. CASING, LINER AND CEMENTING RECORD CASING SETTING DEPTH MD SETTING DEPTH TVD HOLE AMOUNT WT. PER FL GRADE TOP BOTTOM TOP BOTTOM SIZE CEMENTING RECORD PULLED 20" 91.5# H-40 Surface 80' Surface 80' 30" 2130# Poleset 13-3/8" 72# L-80 Surface 2608' Surface 2608' 17-1/2" 2854 sx Fondu 400 sx Permafrost 9-5/8" 47# L-80 / S00 Surface 7990' Surface 7551' 12-1/4" 500 sx Class 'G' 300 sx PF 'C' 7" 26# L-80 7830' 9590' 7402' 8866' 8-1/2" 169 sx Class 'G' 4-1/2" 12.6# L-80 9455' 10753' 8762' 8980' 6-1/8" Uncemented Slotted Liner 23. Open to production or inject ion? ^ Yes ®No 24. TUBING RECORD If Yes, list each i (MD+TVD of Top & Bottom; Pe nterval open rforation Size and Number): SIZE DEPTH .SET MD PACKER .SET fND 4-1/2", 12.6#, 13Cr80 9459' 9403' MD TVD MD TVD 25. ACID, FRACTURE,. CEMENT'SOUEEZE, ETC. ~i ~'`, J~ i~~s~1~~~ /-{~Iyj `g e ~~~8 DEPTH INTERVAL MD AMOUNT & KIND OF MATERIAL USED " Set Cement Retainer 9580' (Milled up 06/27/08) -9730' P&A w/ 22.5 Bbls Class'G' & 24.5 Bbls Class'G' 9628' Set Whipstock 26. PRODUCTION TEST Date First Production: Not on Production Method of Operation (Flowing, Gas Lift, etc.): N/A Date Of Test: HOUfS Tested: PRODUCTION FOR TEST PERIOD OIL-BBL: GAS-MCF: WATER-BBL: CHOKE SIZE: GAS-OIL RATIO: Flow Tubing PreSS. CaSing PreSS: CALCULATED 24-HOUR RATE OIL-BBL: GAS-MCF: WATER-BBL: OIL GRAVITY-API (CORK): 27. CORE DATA Conventional Core(s) Acquired? ^ Yes ®No Sidewal l Core s A wired? ^ Yes ®No If Yes to either question, list formations and intervals cored (MD+TVD of top and bottom of each), and summarize lithology and presence of oil, gas or water (submit separate sheets with this form, if needed). Submit detailed descriptions, core chips, photographs and laboratory analytical results per 20 AAC 250.071. L~EI'10k O None i~~.~"~5=~.~..~ Form 10-407 Revised 02/2007 /"~ n ~ ~ I ~ I~ TINUED ON REVERSE SIDE ` ~'~~~-v ~~ ~ ' ~~'~ '~ ~ LYU° 28. GEOLOGIC MARKERS (LIST ALL FORMATIONS AN ERS ENCOUNTERED): 29. FORMATION TESTS NAME TVD Well Teste ^ Yes ®No Permafrost Top If yes, list intervals and formations tested, briefly summarizing test results. Attach separate sheets to this form, if needed, and submit Permafrost Base detailed test information per 20 AAC 25.071. Sag River 9591' 8867' None Shublik 9617' 8887' Shublik B 9649' 8910' Shublik C 9671' 8924' Sadlerochit 9734' 8960' 45N 9753' 8970' Formation at Total Depth (Name): 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. / O7 / ~' /~ Signed Terrie Hubble Title Drilling Technologist Date PBU 13-30A 203-180 308-167 Prepared By Name/Number. Te-rie Hubble, 564-4628 Well Number Permit No. / A royal No. Dn/ling Engineer: Greg Sarber, 564-4330 INSTRUCTIONS GeNew-~: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. IreM 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. IreM 4b: TPI (Top of Producing Interval). IreM 8: The Kelly Bushing and Ground Level elevation in feet above mean sea level. Use same as reference for depth measurements given in other spaces on this form and in anyattachments. IreM 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). IreM 20: Report true vertical thickness of permafrost in Box 20. Provide MD and TVD for the top and base of permafrost in Box 28. IreM 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. IreM 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). IreM 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-Jn, or Other {explain). IreM 27: Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Submit detailed description and analytical laboratory information required by 20 AAC 25.071. IreM 29: Provide a listing of intervals tested and the corresponding formation, and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Form 10-407 Revised 02/2007 Submit Original Only • 13-30A, Well History • Date Summary 5/20/2008 MAKE SEVERAL RUNS TROUBLE SHOOTING RESTRICTIONS C~ 1.5' SLM, AND 27' SLM, INSTRUCTED TO RIG DOWN. 6/2/2008 RAN 3.70" CENT, S-BLR, SD ~ 9' SLM, ABLE TO WORK TOOLS TO 27' SLM (no sample). RAN 2.80", 3.375", AND 3.50" G-RING TO 500' SLM W/O ANY PROBLEMS. UNABLE TO GET PAST 12' SLM W/ 3.75" G-RING. RAN A 3.80" L.I.B. AND SD @ 8' SLM, RING IMPRESSION ON L.I.B. UNABLE TO MAKE IT PAST 37' SLM W/ 3.67" JUNK BASKET (Empty). UNABLE TO MAKE IT PAST 7' SLM W/ 4 1/2" BLB, 3.50" G-RING (Nothing in brush). RAN 3.50" BROACH TO JUST ABOVE SVLN ~ 2~226~D, UNABLE TO MAKE IT PAST 130' SLM W/ 3.625" BROACH. RAN PEDRADAT SBHPS PER PROGRAM (Good Data). ABLE TO WORK 3.625" BROACH FROM 130' TO 150' SLM, (small bits of scale in teeth). 6/3/2008 WORKED 3.625" BROACH FROM 150' TO 350' SLM, THEN DRIFTED TO 2,150' SLM. WORKED 3.675" BROACH, SD ~ 38' SLM TO 88 'SLM, GOT SOLID AT 88' SLM. 6/5/2008 T/I/0= 2040/1500/0 Temp = SI Acid Treatment (CTD Prep) Load IA prior to Tbg acid wash. Pumped 3 bbls neat & 400 bbls crude down IA to load. 6/5/2008 T/I/O=SSV/1100/250. Temp SI. Shoot IA FL & check AL line status (FB call in). AL line disconnected & blinded. 2" Intergal flange on IA. IA FL C~3 7070' MD (S/O STA # 2). 6/6/2008 Pumped 5 bbls neat, 160 bbls 1 %KCL, 5 bbls of 15% HCL pumped C~ 2 bpm, soaked for 30 mins, pumped 12 bbls of 15% HCL at min rate, soaked for 30 mins. Displaced Tbg with 205 bbls 1 %KCL & 50 bbls of diesel for freeze protect. FWHP's=vac/300/300. Wellhead valves checked for position and tags hung upon departure. 6/12/2008 T/I/0= 0+/320/260. Temp= SI. Assist Slickline (CTD Prep) MIT-IA *PASSED* to 3000 psi. (2nd attempt) Pumped 59.9 bbls of 78° crude to achieve test pressure. Lost 60 psi / 1st 15 min. Lost 20 psi / 2nd 15 min. Lost a total of 80 psi during the 30 minute test. Bled back -20 bbls to gas. FWHP= 0/440/280. Annulus casing valves are tagged and open to gauges. 6/12/2008 DRIFT TUBING W/ 3.805" G.RING TO "XN" C~4 9439' SLM (NO ISSUES). SET WCS ON "XN" C~3 9432', SLM. PULL RK-OGLV STA #2 C«~ (7070' MD), PULL RK-LGLV STA # 3 ~ (5,741' MD). PULL RK-LGLV STA # 4 C«3 (3,869' MD), SET RK-DGLV's IN STA#'S 4, 3, 2. PULL M!T WCS FROM 9432' SLM. DRIFT TUBING W/ 3.70" CENT. TO 9,650' SLM. PERFORM SBHPS (SEE DATA TAB). PASSED MIT-IA. 6/17/2008 R/U E-LINE AND SET HALLIBURTON COMPOSITE FASDRILL CEMENT RETAINER AT 9580'. RESTRICTION SEEN AT -7340' ON TRIP IN AND ON TRIP OUT. RAN PSP CALIPER LOG AND FOUND TUBING COMES IN A LITTLE AND THE FLUID DENSITY GOES TO WATER AT 7328'. FINAL T/I/O = 250/400/200 PSI. WELL LEFT SHUT IN, ALL VALVES LEFT IN SAME CONDITION AS PER ARRIVAL, DSO NOTIFIED. JOB COMPLETE. 6/19/2008 T/I/O=SSV/400/200, Temp=Sl. PPPOT-T (PASS), PPPOT-IC (PASS). Pre CTD. PPPOT-T: Stung into test port (0 psi). Function LDS, all moved freely. Pumped through void, clean returns. Pressured void to 5000 psi, lost 100 psi in 15 min, lost 0 psi in second 15 min (PASS). Bled to 0 psi. PPPOT-IC: Stung into test port (800 psi), bled to 0 psi. Function LDS, all moved freely. Pumped through void, clean returns. Pressured void to 3500 psi, lost 150 psi in 15 min, lost 50 psi in second 15 min (PASS). Bled to 0 psi. 6/25/2008 MIRU. Perform weekly BOP test. MU and RIH with HES cement retainer stinger assy. Load and fluid pack well with 245 bbls 1 %KCL followed by 103 bbls diesel. Mix and pump 22.5 bbls Class 'G' cement at 15.8ppg -Did not see pressure bump. Overdisplace with 2 bbls of water and 1 bbl biozan. Page 1 of 3 13-30A, Well History Date Summary 6/26/2008 No pressure bump on cement. Overdisplace cement thru retainer with 2 bbls water and 1 bbl biozan to clean retainer. Unsting from retainer, circulate biozan OOH- WOC and order more cement. Circ 1% XSKCL OOH displacing with diesel. Stab back into retainer at 9587' ctmd. Establish infectivity into well with 1 % KCL. Seeing some resistance to injection at 1 bpm, also seeing delayed response on coil backside (>WHP). Elect to pump 2nd cement job while closely monitoring WHP. Establish injection down coil backside at min rate to maintain fluid packed wellbore. Pum 24.5 bbls Shut down backside injection once a few bbls of cement were under the retainer. Squeeze pressure clnwl; increased after 17 bbls were under the retainer. Hesitate squeeze remaininn cement achieving a 8 S nci bump. A total of 24 bbls of cement were pumped under the retainer with 0.5 bbl dumped on top. POOH maintaining approx. 500 psi overbalance by filling voidage with 50 50 methanol. Well shut in with 750 psi trapped WHP. WOC. MU/RIH w/ 3.80 Parabolic Mill (WHP at 760) - Work thru XN at 9426 -Tag XN at 9447 (9455 ctm). 6/27/2008 Mill XN at 9447," (9452 ctm - 9453 ctm) Make three clean passes thru XN- RIH tag at 9479 ctm - POH chase bio pill to surface. Disco parted in lubricator- Strip lub over TS and pull TS from well. The shear screws in disco backed out and were missing, when TS weight was relieved from disco, it allowed sleave to shift and release TS. MU/RIH w/ BHA and 3.70 3 blade Opticut Mill. Sat down dry at 9481' ctmd. Milled from 9481' to 9575' ctmd with little to no motor work. Began to see reduced ROP at 9575' ctmd. Saw ood motor work startin at 9588' ctmd (retainer). Milled throu h retainer with st Ils. Milled good cement down to 9730' ctmd, then stalled several times Elected to abort any furt er attempts to get deeper. Returns were 1 for 1 and Geovis sweeps were loaded with cement. Circulated Geovis sweep off bottom and POOH at 80%. Freeze protected well with 50/50 methanol. PT well to 500 psi WHP, jug tight. RD. Job Complete. 6/28/2008 RAN 3.70" X 20' DUMMY WHIPSTOCK. SET DOWN HIGH ~ 9370'SLM. RAN 3.70" X 10' DUMMY WHIPSTOCK. SET DOWN C~ 9392' SLM & WORKED TO 9600' SLM. RAN 3.70" CENT. SET DOWN ~ 9601' SLM -WORKED DOWN TO 9703' SLM. RAN 3.70" GAUGE RING, UNABLE TO MAKE HOLE PAST 9719' SLM. RAN 3.70" X 20' DUMMY WHIPSTOCK, UNABLE TO MAKE HOLE PAST 9604' SLM. 6/29/2008 RAN 10'x3.70" DMY WHIPSTOCK, UNABLE TO PASS 9600' SLM. RAN 3.70" CENT., 2' STEM, & 3.70" GAUGE RING TO 9719' SLM, PASSED THROUGH 9600' EASILY. SAT DOWN C~ 9449' SLM W/ 3.75" CENT./ 3.75" GAUGE RING. RAN 3.70" CENT,2' X 1 7/8",3.70" CENT,2' X 1 7/8" & 3.70" GAUGE RING TO 9717' SLM. RAN 3.70" CENT,2' X 1 7/8",3.70" CENT,2' X 1 7/8" & 3.75" GAUGE RING. SET DOWN C~ 9599' SLM & WORKED TO 9717' SLM. RAN 20' X 3.70" DUMMY WHIPSTOCK. UNABLE TO PASS 8071' SLM. RAN 3.70" CENT,2' X 1 7/8",3.70" CENT,2' X 1 7/8" & 3.79" GAUGE RING, WORKED TOOLS FROM 9596' SLM TO 9705' SLM. RAN OC,3.625" CENT & 10" X 3.70" DUMMY WHIPSTOCK, UNABLE TO PASS 9599' SLM. RAN 3.70" CENT, 3'x2-1/8", 3.75" CENT, 3' x 1-7/8", & 3.79" GAUGE RING, WORKED TOOLS FROM 9600' SLM TO 9709' SLM. RAN OC,3.625" CENT & 10" X 3.70" DUMMY WHIPSTOCK, SAT DOWN C~1 9603' SLM. 6/30/2008 RAN 3.70" CENT., 3' x 2-1/8" STEM, 3.79" GAUGE RING, 3' x 1-7/8" STEM, & 3.75" CENT - S/D ~ 9603 SLM. RAN 3.625" CENT., 4-1/2" GR, & 10' x 2.70" DMY WHIPSTOCK -SET DOWN ~ 9603' SLM. RAN 12' X 3.625"STEM W/3.50" CENT ON BTM -SET DOWN C~ 9615' SLM. RAN 18' X 3.628" WHIPSTOCK -SET DOWN C~ 9616' SLM. 7/1/2008 MIRU. MU /RIH Weatherford 2 7/8" PDM w/ 3.80" Diamond Speed Mill. Milled from 9500' ctmd to 9730' ctmd. Did not see any obvious motor work. Dry tag at 9734' ctmd. Made three passes through this interval. Circulated out of hole at 80%. FP well to 3700' with 50/50 methanol. RD CTU. Job Complete. 7/2/2008 R/U SLICKLINE. 7/3/2008 TAG TOP X NIPPLE C~1 9394' SLM W/ 4 I/2" X CATCHER SUB. RAN 10' X 3.70" DMY WHIPSTOCK, S/D ~ 9630' SLM. RAN 18' X 3.68" BAKER WHIPSTOCK, S/D C~ 9702' SLM. WELL SHUT-IN ON DEPARTURE, DSO NOTIFIED. Page 2 of 3 ~ ~ 13-30A, Well History Date Summary 7/5/2008 INITIAL T/I/O: 0/50/0 PSI. SET TOP OF WHIPSTOCK AT 9628'. ORIGINALLY WAS TO BE SET AT ' 9640', COLLAR AT 9644', MADE IT NECESSARY TO MOVE SET DEPTH UP ONE JOINT. TAGGED TD AT 9680'. SURFACE AND VISUAL CONFIRMATION OF WHIPSTOCK SETTING SSV LEFT OPEN PER DSO INSTRUCTIONS. DSO INSPECTED SITE. FINAL T/I/O: 0/0/0 PSI. WELL LEFT SHUT IN. 7/6/2008 T/I/0=5.0/0. Set 5" GRAY K BPV. Pre-CTD. Page 3 of 3 • • BP EXPLORATION Page 1 Operations Summary Report Legal Well Name: 13-30 Common Well Name: 13-30 Spud Date: 7/6/1982 Event Name: REENTER+COMPLETE Start: 7/10/2008 End: 7/17/2008 Contractor Name: NORDIC CALISTA Rig Release: 7/17/2008 Rig Name: NORDIC 1 Rig Number: F k I~' ~ i i f O i ! D Date rom - To Hours i Tas Code NPT Ph escr pt on o perat ons ase , 7/10/2008 23:00 - 00:00 1.00 MOB P PRE Ri cce ted 23:00. Move over well. 7/11/2008 00:00 - 02:00 2.00 MOB P PRE N/U BOP stack. Spot reel trailer for picking up reel. 02:00 - 02:20 0.33 MOB P PRE SAFETY MEETING. Discuss hazards and crew placement for picking up reel. 02:20 - 03:00 0.67 MOB P PRE Lift reel into frame and insert pins. Rig up CT riser section and install collection tub around riser. 03:00 - 06:00 3.00 BOPSU P PRE Start BOP test. Test witness waived by John Crisp. 06:00 - 13:00 I 7.00 I BOPSUp P I I PRE 13:00 - 16:45 I 3.751 RIGU I P I I PRE 16:45 - 17:00 0.25 RIGU P PRE 17:00 - 17:30 0.50 RIGU P PRE 17:30 - 18:30 1.00 RIGU P PRE 18:30 - 18:50 0.33 RIGU P PRE 18:50 - 20:00 1.17 RIGU P PRE 20:00 - 20:20 0.33 RIGU P PRE 20:20 - 21:30 1.17 RIGU P PRE 21:30 - 22:20 0.83 RIGU P PRE 22:20 - 23:00 0.67 RIGU P PRE 23:00 - 00:00 1.00 RIGU P PRE 7/12/2008 00:00 - 01:20 1.33 RIGU P PRE 01:20 - 02:00 0.67 RIGU P PRE 02:00 - 03:00 1.00 RIGU P PRE 03:00 - 04:10 1.17 STWHIP P WEXIT 04:10 - 06:00 I 1.831 STWHIPI P I I WEXIT Test lower 2-3/8" Combi P/S rams to 250 / 3,500 psi. Test upper 2-3/8" combi P/S rams, leak on choke line flange. Tighten and re-test. Test Manifold valves 3,7,10,12,15 &18 and inside kill 350/3500 psi Test Manifold valves2,6,11 & 16 350/3500 psi Test Manifold valve 17 350/3500 psi Test HCR No Test. Test 3" Manual valve 350/3500 psi Test 2-3/8 Variables 350/3500 psi Test Anular 350/2500 psi Test 3-1/2 varaibles.350/3500 psi Test Blinds 350/3500 psi Prep floor to PU stuffing box and pull cable across. Repair and retest HCR.OK , Install grapple in CT.~Pump open SSV. PJSM for pulling CT across. Pull CT across and cut off grapple. Prepare to PU lubricator. High level H2S alarm drill, and Rig evacuation exercise. All personnel muster and are accounted for in 3 min. Found out the recent chipping and grinding dust had plugged off one of the H2S sensor filter caps. This cap was replaced and others on the rig inspected for plugging. PU BPV lubricator to rig floor. Pull BPV. About 50 psi underneath. L/D BPV equipment. Continuity and resistance test of wire. Resistance test fails, troubleshoot plugs and connections. Problem is found in reel house, run new cable from there down to BHI shack. Install cable boot. MU CT riser to well. Line up valves to fill reel backwards. Fill reel then pump high rate to move cable. Break off CT riser, rig up hydraulic CT cutter. Cut 360 ft of pipe to find cable. Install CT connector. Pump up weight cell. Pull test to 35 Klbs, good. Install cable head. Electric test is OK. Troubleshoot pressure gauge in reel house, not working. Pressure test CT connector and cable head to 4,000 psi, good. PU window milling BHA to rig floor. MU BHA #1 - 3.80 HCC Mill + 3.79 Diamond string reamer + 2-7/8 BOT Xtreme motor + 2 jts PH6 + 3.0" CoilTrack. Make up injector to CT riser. RIH, take returns out to flowback tank. RIH to 9590'. Printed: 7/23/2008 2:26:19 PM • BP EXPLORATION Operations Summary Report Page 2 Legal Well Name: 13-30 Common Well Name: 13-30 Spud Date: 7/6/1982 Event Name: REENTER+COMPLETE Start: 7/10/2008 End: 7/17/2008 Contractor Name: NORDIC CALISTA Rig Release: 7/17/2008 Rig Name: NORDIC 1 Rig Number: I Date From - To Hours Task Code NPT Phase Description of Operations 7/12/2008 106:00 - 07:00 1.00 STWHIP P WEXIT Log tie-in. Log inconclusive. Tag 9642.4'. Correct to 9628 WS ~3•~A 09:30 - 11:00 I 1.501 STWHIPI P 11:00 - 13:00 2.00 STWHIP P 13:00 - 14:00 1.00 STWHIP P 14:00 - 15:00 1.00 STWHIP P 15:00 - 16:00 1.00 STWHIP P 16:00 - 16:45 0.75 STWHIP P 16:45 - 19:50 3.08 STWHIP P 19:50 - 21:00 1.17 STWHIP P 21:00 - 21:40 0.67 STWHIP P 21:40 - 00:00 2.33 STWHIP P 17/13/2008 100:00 - 01:20 I 1.33 I STW H I P I P 01:20 - 03:45 ~ 2.42 STWHIP P 03:45 - 04:00 0.25 STWHIP P 04:00 - 04:45 0.75 STWHIP P 04:45 - 05:20 0.58 DRILL P 05:20 - 07:25 2.08 DRILL P 07:25 - 09:00 1.58 DRILL P 09:00 - 10:40 1.67 DRILL P 10:40 - 11:30 0.83 DRILL N VV CIII ~ Vr W[ 3411, UIV W< Ian, ZA8/LA4 Dpm ~ LOVVp51, L4GV IJ51 = FS, WOB iK, Time mill .1fU Complete changeover to 2# bio.lnteq DHWOB sub giving incorrect readings. WEXIT PU re-establish drilling perameters.Rezero Inteq DHWOB sub. Up wt 31 K, DN wt 14.7K FS 2120 psi ~ 2.53 bpm. Mill at 2.53/2.53 bpm 2285 psi.12.5K surface wt (2.2 WOB) DHWOB sub 3.78K 9629,6' 2.5/2.5 ~ 2410 psi WOB 4.3 (surface wt) 6.96 iNTEO WOB. WEXIT Mill at 2.53/2.53 bpm 2530 psi.9.6K surface wt (5 WOB) DHWOB sub 9.29K. Drill to 9631.5' WEXIT Mill at 2.51/2.51 bpm 2468 psi.9.6K surface wt (4 WOB) DHWOB sub 8.3K. Drill to 9633.0. WEXIT Mill at 2.51/2.51 bpm 2400 psi.9.6K surface wt (4 WOB) DHWOB sub 5.3K. Drill to 9634 WEXIT Mill at 2.55/2.55 bpm 2388psi. 10.2K surface wt (3.8 k WOB) DHWOB sub 5.OK. Drill to 9635.3' WEXIT Mill at 2.55/2.55 bpm 2439psi. 10.6K surface wt (3.4 k WOB) DHWOB sub 5.2K. Drill to 9636 WEXIT Mill at 2.54/2.54 bpm 2464 psi. 10.5K surface wt (3.4 k WOB) DHWOB sub 5.8K. WEXIT Mill at 2.55/2.55 bpm 2388 psi. 10.2K surface wt (3.8K WOB) DWOB 2.OK. 9639 ft. WEXIT Mill at 9640.7 ft 2.64/2.64 bpm 2512 psi. 9.1 K surface wt (4.8K WOB) DWOB 5.1 K. WEXIT Mill to 9,640 ft. Pick up to 9620 ft to find new free spin of 2300 psi at 2.60 bpm. Sample at 9640 ft has 10% formation, rest is cement and metal. 22:00 - 9641.22 ft 2.63/2.64 bpm, 2440 psi. CT weight is 11.9K, DWOB = 3.3K. 23:00 - 9644.02 ft 2.64 / 2.65 bpm, 2490 psi. CT weight is 9.9 Klbs, DWOB = 4.9 Klbs. Sample at 9642 ft is 30% formation. WEXIT Reach end of rathole at 9,649 ft. Park here and allow weight to drill off. Start mud swap. Pick up for 1st pass through window. Slight motor work seen pulling up through 9628 ft, TOW, and going back down. repeat 2 more times. Top Window WEXIT Dry pass through window is clean, no hangups. Open EDC and POOH. Pump 3 bpm while POOH. WEXIT Tag stripper. SAFETY MEETING. Discuss hazards and mitigations for change out BHA. WEXIT L/D BHA #1. Mill is 3.78" no-go. PROD1 P/U BHA #2. 3.75" HYC bit + 1.8 deg Xtreme motor + 3" CoilTrack. PROD1 RIH BHA #2 to 9550'. PROD1 Log tie-in. Correction -11'. Tag TD. 9667 correct to 9656 PROD1 Drilling at 2.5/2.5 bpm @ 3000 psi, 2760 psi FS, RREP PROD1 Adjust SLB power pack. Printed: 7/23/2008 2:26:19 PM .LHEAD= GRAY UATOR = AXELSON ELEV•= 87' ELEV = 25.1' ' = 7992' Angle = 94.6' im MD = 9404' im TVD = 8800' SS 13-3/8" CSG, 72#, L-80, ID = 12.347" ~~ ~ ~V~ CTD Sidetrack Minimum ID = 3.725" @ 9446' 4-1 /2" XN NO-GO NIPPLE SAFETY NOTES: 4-1 /2" CHROME TBG 14-1/2" X NIP, ID = 3.813" ~ GAS LIFT MANDRELS ST MD TV D DEV TYPE V LV LATCH PORT DATE 3002 3001 9 MMG-M DMY RK - 12/06/03 4 3869 3827 23 MMGM DOME RK 16 12/06!03 3 5741 5515 27 MMGM DOME RK 16 12/06/03 2 7070 6706 25 MMGM S/O RK 24 12/06/03 1 7600 7190 23 MMGM DMY RK - 11/24/03 I 7830' I 9-5/8" CSG, 47#, L-80, ID = 8.681" 19-5/8" X 7" BAKER HGR / PKR I TOP OF 9-5/8" WINDOW 7992' 14-1/2" X NIP,ID = 3.813" ~ 14-1/2" X NIP, ID=3.813" ~- I 9426' I~ 14-1R' TBG, 12.ON, 1l-CR-80, .0152 bpf, ID - 3.958- H 9469' 4-1/2" TIEBACK SLV 9455' a-1/2" WLEG 9459' 5"X7" LNR HGR 9466' 7" LNR, 26#, L-80 MOD~BTC 9590' Mechanical Whipstock #2 - 9620' Mechanical Whipstock #1 - 9628' 9402' H4-1/2" X 7" BAKER S-3 PKR - 9,435' -Top of Liner - 3-1/2" X Nipple - 3-1/2" x 3-3/16" Crossover Cement Top at Window TD = 12,100' ~ 3-3/16" x 2-7/8" Crossover 3-1l2" x 3-3/16" x 2-7/8" Solid Liner ~ 4-112" SLTD LNR, 12.6#, .0152 bpf, ID = 3.958" HH 1 9864' IBP 13-30A P&A 13000' 113-30B. Wet Zone 4. P8A'd w ith ceme~~~ I ]ATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNfr /21/82 ORIGINAL COMPLETION WELL: 13-30A /27/03 JLGlrLP PROPOSED 2ES SIDETRACK PERMIT No: 1821010 /06103 RMH/TLP GLV GO AR No: 50-029-20768-01 SEC 14, T10N, R14E, 3882.14' FEL 8 4347.07' FNL BP Exploration (Alaska) -~ -~~~ ALASSA OIL A1~TD GAS C01~5EItQA'I`IO1~T COMI~II5SIOIQ Greg Sarber CT Drilling Engineer BP Exploration Alaska Inc. PO Box 196612 Anchorage, AK 99519-6612 SARAH PALIN, GOVERNOR 333 W. 7th AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 3' ,~~ b c~,o Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU 13-30A Sundry Number: 308-167 Dear Mr. Sarber: ~~ ~~~~ M~~ ~ ~ ~?00 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 Commssion an application for rehearing. A request for rehearing is considered timely if it is received by 4:30' PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Sincerely, ~- ~~ Cathy . Foerster Commissioner DATED this ~r day of May, 2008 • Encl. STATE OF ALASKA j~ ALA OIL AND GAS CONSERVATION COM~ION I~JC~S/~ ~''~~~` ~ ~ 200$ APPLICATION FOR SUNDRY APPROVAL J~; ~ t,7~s sons. Commissars 20 AAC 25.280 1. Type of Request: ®Abandon ~ ^ Suspend ^ Operation Shutdown ^ Perforate ^ Time Extension ~ ^ Alter Casing ^ Repair Well ®Plug Perforations ~ ^ Stimulate ^ Re-Enter Suspended Well ^ Change Approved Program ^ Pull Tubing ^ Perforate New Pool ^ Waiver ^ Other 2. Operator Name: 4. Current Well Class: 5. Permit To Drill Number BP Exploration (Alaska) Inc. ®Development ^ Exploratory 203-180 - 3. Address: ^ Service ^ Stratigraphic 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-20768-01-00 7. If perforating, closest approach in pool(s)-opened by this operation to nearest 8. Well Name and Number: property line where ownership or landownership changes: PBU 13-30A - Spacing Exception Required? ^ Yes ®No 9. Property Designation: 10. KB Elevation (ft): 11. Field /Pool(s): _ ADL 028315 ~ KBE = 74.5'- Prudhoe Bay Field / Prudhoe Bay Pool 12. PRESENT WELL CONDITION SUM MARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 10753 - 8980 ~ 10753 ~ 8980 _ N!A N/A sin en th Size MD TVD B rst Colla se Structural d r 0' 20" 80' 80' 1490 470 Surface 2608' 13-3/8" 2608' 2608' 4930 2670 Intermediate 7990' 9-5/8" 7990' 7551' 6870 4750 Pr du i n Liner 732' 7" 7830" - 9590' 7402' - 8866' 7240 5410 Liner 1298' 4-1/2" 9455' - 10753' 8762' - 8980' 8430 7500 Pertoration Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): Slotted 9602' -10712' Slotted 8875' - 8983' 4-112", 12.6# 13Cr80 9459' Packers and SSSV Type: 7" x 4-1/2" Baker S-3 Packer Packers and SSSV MD (ft): 9403' 13. Attachments: 14. Well Class after proposed work: ® Description Summary of Proposal ^ BOP Sketch ^ Detailed Operations Program ^ Exploratory ®Development ^ Service 15. Estimated Date for 16. Well Status after proposed work: Commencin O erations: May 17, 2008 ^ Oil ^ Gas ^ Plugged ®Abandoned 17. Verbal Approval: Date: ^ WAG ^ GINJ ^ WINJ ^ WDSPL Commission Representative: 18. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Greg Sarber, 564-4330 Printed Nam reg Sar er Title CT Drilling Engineer ~ Prepared By NamelNumber: Signature „~-~'"`(~ ~ Phone 564-4330 Date Sondra Stewman, 564-4750 Commission Use Onl Sundry Number: ~~ Conditions of approval: Notify Commission so that a representative may witness \ ` ~ w ^ Plug Integrity ^ BOP Test ^ Mechanical Integrity Test ^ Location Clearance ~-`~ ~O`s' h~ `~ Q`~ c~, rrrr~~ ~" ~~~Ctco~~, Other: 3S~C'~ s ~ ~ ~ ~ Q V TcCS -. Subsequent Form Required: i~~~ . l APPROVED BY ~ A roved B : COMMISSIONER THE COMMISSION Date - 7 - ~~ Form 10-403 Revised 0 /2006 Submit In Duplicate ~~,~~~~IAL ~~.~~~~~~a~ ~~ To: Tom Maunder • • Petroleum Engineer Alaska Oil & Gas Conservation Commission From: Greg Sarber CTD Engineer Date: May 2, 2008 Re: DS 13-30A Sundry Approval Sundry approval is requested to abandon perforations on well 13-30A. History - Well13-30A was a horizontal rig sidetrack from 13-30 and completed 11-27-03 with a 4-1/2" L-80 slotted liner. Eiesistivity lops indicated the reservoir interval was swept and well tests confirmed 6-7000 BFPD at 99% weer cut_ The well was non-productive and was not produced after initial testing. It has been identified as a CTD sidetrack candidate. In preparation for the CTD sidetrack, 13-30A was POP 1-31-08 to verify facilities operability, annular integrity, and obtain current WC sampling. The well again tested at WC greater than 99% and there was not enough oil to determine API gravity. Within 3 days of POP, the DSO reported bubbling in the cellar and around wellhead. Water samples_confirmed water in cellar is ground water. Operations shut-in the weN due to a potential surface casing leak on 2-3-08. Choke index problems were noted and the SSV would not close. A tubing caliper was run. The well was dummied off, TTP set, and aMIT-IA and MIT-OA w/N2 passed following a bradenhead UT. The well was POP again and passed a hot MIT-OA w/N2 verifying surface casing integrity. It is currently classified as operable, and we are continuing to monitor OA pressures to ensure no IA x OA communication or that it is manageable by bleeds. REASON FOR SUNDRY: In order to achieve adequate isolation for the 2-7/8" liner cement job on the 13-046 sidetrack, it will be necessary to abandon all the perforations in the existing parent well bore. Pre-CT Rig Work: (Scheduled to begin on May 17, 2008) 1. MIT-IA, -OA Done 2-27-2008 2. Dummy GLV's Done 2-11-2008 3. Drift thru WS setting depth (9600') with 3.7" drift for cement retainer. 4. Set HES composite cement retainer at 9540'. 5. Pump cement thru cement retainer to P&A slotted liner. (Minimum of 15 bbls) 6. Mill XN nipple at 9447' to 3.80" with left handed motor. 7. Mill cement retainer at 9540', and cement in 4-1/2" liner to 9750'. With conventional motor assembly. 8. Drift and tag with dummy whipstock. -x9. Set Baker 4-1/2" monobore whipstock using SLB WPPT tool. Set top at 9,700', with high side orientation. ~~ 10. PPPOT-IC, -T; LDS 11. PT MV, SV, WV ~ 12. Blind and bleed lines, remove well house, level pad Rig Sidetrack Operations: (Scheduled to begin on June 21, 2008 using Nordic rig 1) 1. MIRU Nordic Rig 1 2. NU 7-1/16" CT Drilling BOPE and test. 3. Pull BPV. 4. Mill 3.80" window at 9,700'. 5. Drill build/turn section with 3.75" x 4.125" bicenter bit, and land well. 6. Drill lateral section to 13,000. 7. Run and cement a 3-1/2" x 2-7/8" L-80 liner string. 8. Make a cleanout run with mill and motor to PBTD in combination with a MCNL-GR-CCL tool. 9. Perforate well 10. Circulate well to KWF brine. FP well to 2000' with diesel. 11. Set BPV. ND 7-1/16" stack. F~e and PT tree cap to 3500 psi. • 12. RDMO Nordic 1. Post-Rig Work: 1. Re-install wellhouse and FL's. 2. Pull BPV. 3. Run live gas lift design. 4. POP Well Greg Sarber CTD Engineer CC: Well File Sondra Stewman/Terrie Hubble '. TREE= GRAY GEN2 WELLHEAD= ACTUATOR=~ GRAY AXH.SON KB. ELEV = 87' BF. ELEV = 25.1' KOP = 7992' Mex Angb = 94.6` Datum MD = 9404, Datum TV D = 8800' SS ~ 13-30A 13-3/8° CSG, 72ri!, L-80, ID = 1 z.347° ~--~ ygp8' Minimum ID = 3.726" ~ 9446' 4.112" XN NO-GO NIPPLE SAFETY NOTES: 4-1/2" CHROME TBG 141 /2" X NIP. ID = 3.813" I GAS LIFT M4NDf~LS ST MD ND DEV TYPE VLV LATCH FORT DATE 3002 3001 9 MMCrM DIIdY RK -~ 12/06/03 4 3869 3827 23 MMCrM DOME RK 16 12106!03 3 5741 5515 27 MMG-M DOME RK 16 12108103 2 7070 6706 25 NAM S!O RK 24 12/06/03 1 7600 7190 23 MMG-M DMY RK ~ 11/24/03 IPKR PERFORATION SIArMARY REF LOG: BRCS ON 07/18!82 ANGLEATTOP PB~F: 20 ~ 9408' Note: Refer to Roduction DB for historical perf data SIZE SPF INTERVAL Opn/Sgz DATE 3318" 4 9408 -9430 S 3-318" 4 9502 -9514 5 2-7/8" 4 8525 -9590 S SLTD LNR 9602 -9885 O SLTD LNR 10174 - 10712 O = 8.184" TOP OF 8-5/8" WINDOW 7992' / 9382' --) 4112" X IWP, ID = 3.813" 9402' - 4-1/Y' X 7" BAKER S-3 PKR 942g' 41/7" X NIP, IA = 3 R13" 9447' 41/2" XN NP, ID= 3.725" 946b' 41/2"TIESACKSLV ~ ~ ~ ~ ~ ~ ~ ~ 52 bpf, ID=3.958' 945$' ~~ ~~ ~ i 7" LNR, 2611, L-8a MD68TG 9690' ~Y ~ DATE REV BY COMMBVTS OWTE REV BY COMMENTS 07121!!2 ORIGINAL COMPLETKIN 11R7f0.1 JLGITLP PROPOS®2B81DETR+ICK 12!06/03 RMH/TLP GLV GO PRUGHOE BAY UNR WH.L: 13-30A F'EfiMT No: 182'1010 AR No: 50029.2076!}01 SEC 14, T10N, R14E, 3882.14' FEL 84347.07' FNL BP Bcplorstion (Alaska) GRAY GBJ 2 .D= GRAY >R= AXELSON = 8T = 25.1' 7997 s = 94.6' i = 9404' 13-3l8" CSG, 72l, L-80, ID " 12 34T' ~~ Minimum ID 19-5/8' CSG. 47l, L80 ID = 8.661 ' I 2" T~BACK PERFORATION SUMMARY Rff LOG: BRCS ON 07/18182 ANGLE AT TOP PERF 20 ®9408' Note: Refer to Production DB for hrstorwal pert data SIZE SPF INTE3iVAL OpnlSgz DOTE SLTD LNR 9602 -9885 isolated proposed SLTD LNR 10174 - 10712 isolated proposed I I GAS LIFT MANDRELS ST MD ND DEV TYPE VLV LATCH PORT DATE 3002 3001 9 MMG-M DWIY RK - 12/061D3 4 3869 3827 23 MMG-M DOME RK 16 12/06103 3 5741 5515 27 MMG-M DOME RK 16 12n16~03 2 7070 6706 25 MMG-M S10 RK 24 12IO6A3 1 7600 7190 23 MMG-M OIIAY RK - 112403 "~ 7830' ~--~ 9-518" x 7" BAKER HGR / PKR 3-3116" L-BOX 2-718' 13G cmt'ed and perfed 13000' TOP OF 9-5/8" WINDOW 7992' 402' H4-117' X 7• BAKER S3 R 9416' BOT KB LTP Top of ComonVLnor 9435' 9446' 3-L2" X NiP, iD=2.813" 1670' H3-112 x 2-7l8 X-ovor 13 30B 13-1!7 x 2-718" 13Cr LNR crttd and perfd I DATE REV BY COMMENTS DATE REV BY COMMEfYTS 07!21182 ORIGINAL COMPLETION 1112710) JLGRLP 2E3 SIDETRACK 12lO6I03 RMHrTLP GLV GO 04117IOB MSE PROFDS~ CTD SOETRACK Pro~~osed CTD Sidetrack V'JP#12 I saFETY NOTES: 4-112" CHROME TBG 13 3 PRU]HOE BAY l%IfT W3L 13308 PHiMIT No: AP No: 50-029.20768.02 SEC 14, T10N, R14~ 3882.14' FEL 8 4347.OT BP Fkpbratlon (Alaska) n _ .~ ,:~ --, MICROFILMED 03/01/2008 DO NOT PLACE ~~~ ~- ._ ~. .., ~} ' - ` ANY. NEW MATERIAL UNDER THIS PAGE F: \LaserFiche\CvrPgs_Inserts\Microfilm_Marker. doc . . WELL LOG TRANSMITTAL ProActive Diagnostic Services, Inc. To: AOGCC Christine Mahnken 333 W. 7th Ave 8uite 100 Anchorage, Alaska 99501 (907) 793-1225 RE: Cased Hole/Open Hole/Mechanical logs and/or Tubing Inspection(Caliper / MTrJ The technical data listed below is being submitted herewith. Please acknowledge receipt by retuming a signed copy of this transmittal letter to the attention of : ProActive Diagnostic Services. Inc. Attn: Robert A. Richey 130 West Intemational Airport Road Suite C Anchorage. AK 99518 Fax: (907) 245-8952 1 Bl/ EDE Disk 0.8.13 - 30A Correlation log w/ Static 2O-JurHJ7 1) 2) 3) 4) 5) 6) 7) SCANNED JUl 1 0 2001 .;# d~~r~O /5.Q~5- RECEIVED Signed: (1 í1 / ' ¡¿ " _. . Æ JUL 0 3 Z007 Print Name: ill ' t- I 1 (141tAe )1/1011 v, .¿ () v'\ O~a Oil ~ ~4'C: r.M!';. Commission Anchorage .../' . PRoAcTIVE DIAGNOSTIC SERVICES, INC., 130 W. INTERNATIONAL AIRPORT AD SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245-8951 FAX: (907)245-8952 E-MAIL: PDSANCHORAGE@MEMORYLOG.COM WEBSITE: WV'JW.MEMORYLOG.COM D:\Master_ cOPY- 00_ PDSANC-2OxxIZ _ WordlDistributionITransmit1a'- SheetslTransmit_ Origínal.doc - - ---------------- BP Exploration [Alaska). Inc. 13 - 30A Prudhoe Bay North Slope Surface - Before RIH Static Temperature/Pressure Survey Elapsed Time Temperature Pressure (Minutes) (Deg. F) (psia) 0.0 43.70 232.20 0.5 43.25 234.13 1.0 42.52 235.36 1.5 42.24 236.21 2.0 41.63 236.82 2.5 41 .48 237.27 3.0 41.57 237.62 3.5 41.55 237.89 4.0 41.11 238.11 4.5 41.13 238.29 5.0 41.09 238.44 5.5 40.93 238.57 6.0 40.82 238.67 6.5 40.75 238.76 7.0 40.82 238.84 7.5 40.83 238.91 8.0 40.69 238.97 8.5 40.71 239.02 9.0 40.60 239.07 9.5 40.62 239.11 10.0 40.58 239.14 AVERAGE 41.36 237.68 Date: June 20, 2007 Start time: 04:52:00 Data 45 45 44 44 u.. 43 ~ 43 c 42 42 41 41 40 o 2 3 4 5 Minutes 6 7 8 9 10 Pressure Data 250 245 240 235 Current Wellhead Wellhead Pressure (psi g) : Wellhead Temperature (deg. Inner Annulus Pressure (psig) : Outer Annulus Pressure (psig) : <I: ø 230 0.. 225 220 215 210 o 2 3 4 5 6 Minutes 7 8 9 10 Page 1 ------------------- BP Exploration [Alaska). Inc. 13 - 30A Prudhoe Bay North Slope TVDss MD. = 9,605' Static Temperature / Survey Elapsed Time Temperature Pressure (Minutes) (Deg. F) (psia) 0.0 217.55 3347.23 0.5 217 .62 3347.16 1.0 217.63 3347.09 1.5 217.71 3347.03 2.0 217.73 3346.97 2.5 217.78 3346.93 3.0 217.80 3346.91 3.5 217.95 3346.89 4.0 217.86 3346.88 4.5 217.84 3346.88 5.0 217.82 3346.88 5.5 217.83 3346.89 6.0 217.80 3346.90 6.5 217.83 3346.91 7.0 217.85 3346.92 7.5 217.78 3346.94 8.0 217.77 3346.95 8.5 217.78 3346.96 9.0 217.78 3346.98 9.5 217.80 3346.99 10.0 217.83 3347.01 10.5 217.85 3347.02 11.0 217.85 3347.04 11.5 217.79 3347.05 12.0 217.82 3347.06 12.5 217.85 3347.08 13.0 217.84 3347.09 13.5 217.91 3347.10 14.0 217.88 3347. 11 14.5 217.86 3347.12 15.0 217.89 3347.13 AVERAGE 217.80 3347.00 Date: June 2007 Start time: 07:20:00 Data 220 205 ., ~. .. .~ ... .. ,. .. -- - 215 u.. ~ 210 c 200 o 1 1 2 2 3 3 4 4 5 5 6 6 7 7 8 8 9 9 10 10 11 11 1212131314141515 Minutes Pressure Data 3350 3330 3310 <I: ¡;,¡ 1:1. 3290 3270 ------ ,. . 3250 , o 1 1 2 2 3 3 4 4 5 5 6 6 7 7 8 8 9 9 10 10 11 11 1212131314141515 Minutes Page 2 ------------------- B.P Exploration [Alaska). Inc. 13-30A Prudhoe Bay North Slope TVDss MD. = 9,474' Temperature / Pressure Survey Time Temperature Pressure (Minutes) (Deg. F) (psi a) 0.0 213.32 3316.72 0.5 213.38 3316.78 1.0 213.34 3316.83 1.5 213.39 3316.87 2.0 213.39 3316.91 2.5 213.42 3316.93 3.0 213.38 3316.96 3.5 213.38 3316.98 4.0 213.43 3316.99 4.5 213.42 3317.00 5.0 213.40 3317.01 5.5 213.42 3317.02 6.0 213.40 3317.03 6.5 213.40 3317.03 7.0 213.42 3317.04 7.5 213.40 3317.04 8.0 213.39 3317.04 8.5 213.40 3317.04 9.0 213.37 3317.04 9.5 213.37 3317.04 10.0 213.38 3317.04 10.5 213.35 3317.04 11.0 213.51 3317.04 11.5 213.57 3317.04 12.0 213.29 3317.04 12.5 213.95 3317.04 13.0 213.49 3317.04 13.5 214.42 3317.04 14.0 214.39 3317.04 14.5 214.24 3317.04 15.0 214.26 3317.04 AVERAGE 213.54 3316.99 Date: June 20, 2007 Start time: 06:43:00 Data 220 ~. .. ., ... Ø& - .~. - - -- '. .. 215 u.. ~21O Q 205 200 0112233445566778899101011111212131314141515 Minutes Pressure Data 3350 3330 3310 <I: ø Il. 3290 3270 - - - - - .. - - - - - - - 3250 0112233445566778899101011111212131314141515 Minutes Page 3 --------------- - -- BP Exploration [Alaska). Inc. 13 - 30A Prudhoe Bay North Slope TVDss MD. = 9,343' Static Temperature / Survey Date: June 2007 Start time: 07:01 :00 Elapsed Time I Pressure (Minutes) (Deg. F) (psia) 0.0 214.28 3287.77 0.5 217.72 3287.83 1.0 214.95 3287.88 1.5 213.31 3287.92 2.0 217.87 3287.95 2.5 215.51 3287.97 3.0 218.25 3287.99 3.5 216.21 3287.99 4.0 210.10 3288.00 4.5 215.47 3287.99 5.0 214.69 3287.99 5.5 213.03 3287.99 6.0 215.24 3287.98 6.5 213.95 3287.98 7.0 208.29 3287.97 7.5 209.35 3287.96 8.0 209.98 3287.95 8.5 207.44 3287.94 9.0 207.42 3287.93 9.5 207.43 3287.92 10.0 207.42 3287.91 10.5 207.39 3287.90 11.0 207.38 3287.90 11.5 207.37 3287.89 12.0 207.38 3287.88 12.5 207.37 3287.88 13.0 207.36 3287.87 13.5 207.36 3287.86 14.0 207.33 3287.86 14.5 207.33 3287.85 15.0 207.32 3287.84 I . 211.01 3287.92 r.v.....' "".......... Data 220 215 u.. ~ 210 c 205 200 0112233445566778899101011111212131314141515 Minutes Pressure Data 3350 3330 3310 <I: ¡¡¡ 0.. 3290 - - - - "'--"'- 3270 3250 o 1 1 2 2 3 3 4 4 5 5 6 6 7 8 8 9 9 10 10 11 11 1212131314141515 Page 4 ------------------- BP Exploration [Alaska/Inc. 13-30A Prudhoe Bay North Slope TVDss MD. = Static Temperature/Pressure Survey Elapsed Time Temperature Pressure (Minutes) (Deg. F) (psi a) 0.0 217.23 3344.22 0.5 217.33 3344.30 1.0 217.33 3344.38 1.5 217.46 3344.46 2.0 217.54 3344.53 2.5 217.52 3344.60 3.0 217.58 3344.67 3.5 217.58 3344.75 4.0 217.58 3344.82 4.5 217.56 3344.90 5.0 217.50 3344.97 5.5 217.52 3345.04 6.0 217.52 3345.11 6.5 217.56 3345.18 7.0 217.56 3345.25 7.5 217.55 3345.32 8.0 217.56 3345.38 8.5 217.48 3345.44 9.0 217.54 3345.50 9.5 217.54 3345.56 10.0 217.54 3345.62 10.5 217.53 3345.67 11.0 217.60 3345.73 11.5 217.57 3345.78 12.0 217.56 3345.83 12.5 217.58 3345.87 13.0 217.59 3345.92 13.5 217.58 3345.96 14.0 217.58 3346.00 14.5 217.61 3346.04 15.0 217.61 3346.08 AVERAGE 217 .53 3345.25 Date: June 2007 Start time: 06:10:00 Data 220 N' ~. ~. .- .- - - -- - 215 u.. ~21O Q 205 200 0112233445566778899101011111212131314141515 Minutes Pressure Data 3350 - - - 3330 3310 <I: ø 0.. 3290 3270 3250 o 1 1 2 2 3 3 4 4 5 5 6 6 7 7 8 8 9 9 101011 111212131314141515 Minutes Page 5 ------------------- B.P Exploration [Alaska). Inc. 13 - 30A Prudhoe Bay North Slope Surfece - After POOH Static Temperature / Survey Date: June 2007 Start time: 08:33:00 Time Temperature Pressure I (Minutes) (Deg. F) (psia) 0.0 40.61 239.84 0.5 41.33 239.85 1.0 42.18 239.78 1.5 42.02 239.72 2.0 42.29 239.68 2.5 42.44 239.61 3.0 43.07 239.53 3.5 43.02 239.45 4.0 43.35 239.38 4.5 43.09 239.31 5.0 43.34 239.24 5.5 43.78 239.17 6.0 43.64 239.11 6.5 43.99 239.05 7.0 43.94 239.00 7.5 44.18 238.95 8.0 44.14 238.90 8.5 44.01 238.85 9.0 44.42 238.81 9.5 44.35 238.77 10.0 44.22 238.73 AVERAGE 43.21 239.27 Data 45 45 44 44 u.. 43 ~43 c 42 42 41 41 40 o 2 3 4 5 6 7 8 9 10 Minutes Pressure Data 250 245 240 235 ......._......... - .... <I: ¡¡¡ 230 CI. Current Wellhead Wellhead Pressure (psig) : Wellhead Temperature (deg. Inner Annulus Pressure (psig) . Outer Annulus Pressure (psi g) : 225 220 215 210 o 2 3 4 5 6 Minutes 7 8 9 10 PagE! 6 ------ --------- BP Exploration [Alaska). Inc. 13 - 30A Prudhoe Bay North Slope Downhole Temp/Press Temperature / Survey Date: June 2007 Start time: 6: 10:00 End time: 7:20:00 Data 220 215 u.. ~ 210 c 205 200 -200 0 200 400 600 800 1000 1200 Minutes Pressure Data 3350 3330 3310 <I: ø 0.. 3290 3270 3250 -200 ------ _..~......- ---_._.,-~-_.. o 200 400 600 800 1000 1200 Minutes Page 7 e e WELL LOG TRANSMITTAL rJ () '3 -< / ¥ () 13 '5[67 To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West ih Ave., Suite 100 Anchorage, Alaska 99501 February 16, 2006 RE: MWD Formation Evaluation Logs 13-30A, The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Rob Kalish, Sperry Drilling Services, 6900 Arctic Blvd., Anchorage, AK 99518 907-273-3500 ,. 13-30A: LAS Data & Digital Log Images: 50-029-20768-01 1 CD Rom ()~,Q9J~\)O(¡¡ G dl~j'J