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207-035
RECEIVED woo 2 9 7019 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG la. Well Status: Oil ❑ Gas ❑ SPLUG ❑ Other ❑ Abandoned 0 Suspended ❑ GINAOG � 20AAC 25.105 20AAC 25.110 ^'6 WAG ❑ WDSPL I]No. of Completions: Zero 1b. Well Class: Development 0 Exploratory ❑ Service ❑ Stratigraphic Test ❑ 2. Operator Name: 6. Date Comp., Susp., or Abend.: 14. Permit to Drill Number/Sundry BP Exploration (Alaska), Inc 11/3/2019 207-035 . 319-252 3. Address: 7. Date Spudded: 15. API Number: P.O. Box 196612 Anchorage, AK 99519-8612 5/5/2007 50-029-20078-01-00 ' 4a. Location of Well (Governmental Section): e. Date TD Reached: 16. Well Name and Number: 5/13/2007 PBU 04-01A ' Surface: 1327' FNL, 295' FEL, Sec. 34, T11N, R15E, UM ' 9 Ref Elevations KB 64.00 17. Field/Pool(s): Top of Productive Interval: 3637' ENT, 1435' FWL, Sec. 35, T1IN, R15E, UM GL 32.30 BE Surface PRUDHOE BAY, PRUDHOE OIL ° Total Depth: 3031' FNL, 968' FWL, Sec. 35, T11N, R15E, UM 10. Plug Back Depth(MD/TVD): 18. Property Designation: Surface / Surface ADL 028325 & 028324 4b. 4b. Location of Well (State Base Plane Coordinates, NAD 27): 11. Total Depth (MD WD): 19. DNR Approval Number: Surface: x- 712575 ' y- 5950537 Zone - ASP 4 11374'18993' . 70-039 TPI: x- 714373 y- 5948278 Zone - ASP 4 12. SSSV Depth (MD/TVD): 20 Thickness of Permafrost MD/IVD: Total Depth: x- 713888 y- 5948870 Zone - ASP 4 None 1900' (Approx.) 5. Directional or Inclination Survey: Yes ❑ (attached) No 0 13. Water Depth, if Offshore: 21. Re-drill/Lateral Top Window Submit electronic and printed information per 20 AAC 25.050 N/A (f[ MSL) 9278'/ 8585' MD/TVD: 22. Logs Obtained List all logs run and, pursuant to AS 31.05.030 and 20 AAC 25.071, submit all electronic data and printed logs within 90 days of completion, suspension, or abandonment, whichever occurs first. Types of logs to be listed include, but are not limited to: mud log, spontaneous potential, gamma ray, caliper, resistivity, porosity, magnetic resonance, dipmeter, formation tester, temperature, cement evaluation, casing collar locator, jewelry, and perforation record. Acronyms may be used. Attach a separate page if necessary MVVD / GR / RES, CNL / GR / CCL, Cement Evaluation 23. CASING, LINER AND CEMENTING RECORD CASING Wf. PER FT. GRADE SETTING DEPTH MD SETTING DEPTH TVD HOLE SIZEAMOUNT CEMENTING RECORD PULLED TOP BOTTOM TOP BOTTOM 30" 157.5# B 31' 111' 31' 1 111' 39" 1 Fondu to Surface 20" 94#/133 H -40/K-55 31' 1185' 31' 1185' 26" 1 750 sx Fondu, 280 sx Class'G' 13-3/8" 72# N-80 1140' 2686' 1140' 2686' 17-1/2" 975 ax Fondu, 485 sx Class'G', 330 ax Fondu 1111' 9-5/8" 47#/40# 43.5# L-80/600-95 1188' 9278' 1188' 8585' 12-114" 430 sx Class'G', 80 sx Class'G', 100 ax Fondu, 450 sx Class'G' 1069' 3-1/2"x3-3/16"8.81#!6.2# L-80 8983' 11369' 6324' 8992' 4-1/4" 1132 sx Class'G' x2-7/8" /6.16# 24. Open to production or injection? Yes ❑ No 0 25, TUBING RECORD If Yes, list each interval open (MD/1VD of Top and Bottom; Perforation Size and Number, Date Perfd): GRADE DEPTH SET (MD) PACKER SET (MD/TVD) 4-1/2" 12.6# L-80 1123' /L AbA ild-ok 4-1/2" 12.6# 13Cr80 x 5-1/2" 17# L-80 3510'-9184 18930'/ 8276', 9063' / 8396' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. OWWWW AT j 61 Was hydraulic fracturing used during completion? Yes ❑ No 0 Per 20 AAC 25.283 (i)(2) attach electronic and printed information VEED DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED See Attached 27. PRODUCTION TEST Date First Production: Not on Production Method of Operation (Flowing, gas lift, etct: N/A Date of Test:Production Hours Testetl: 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: G85 -MDF: Water -Bbl: Oil Gravity- API(com: Form 10.407 Revised 5/2017 CONTINUED ON PAGE 2 Submit ORIGINAL only oel�,�y� a��g RBDMS ' DEC 0 2 2019 28. CORE DATA Conventional Core(s) Yes ❑ No 0 Sidewall Cores Yes ❑ No 0 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 25.071. 29. GEOLOGIC MARKERS (List all formations and markers encountered): 30. FORMATION TESTS NAME MD TVD Permafrost - Top Well Tested? Yes ❑ No 2 Permafrost - Base If yes, list intervals and formations tested, briefly summarizing test results. Attach Top of Productive Interval 9295' 8800' separate sheets to this form, if needed, and submit detailed test information per 20 AAC 25.071. Sadlerochit - Zone 4 9295' 8600' CGL - Zone 3 9446' 8698' Base of CGL - Zone 2 9520' 8735' Zone 1 11215' 8968' Formation at total depth: Zone 1 11215' 8968' 31. List of Attachments: Summary of Pre -Rig Work, Summary of Daily Reports, Summary of Post -Rig Work, Photo Documentation, Wellbore Schematic Diagram Information to be attached includes, but is not limited to: summary of daily operations, wellbore schematic, directional or inclination survey, core analysis, paleontological report, production or well test results, per 20 AAC 25.070. 32. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Authorized Name: Lastufka, Joseph N Contact Name: Worthington, Ares J Authorized Title: SIMeci t Contact Email: Aras.Worthmgton@bp.com 11( Authorized Signature: Dat:O\Cj-[Z I'� Contact Phone: +1 907 564 4102 INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion reportand log on all types of lands and leases in Alaska. Submit a well schematic diagram with each 10-407 well completion reportand 10-404 well sundry report when the downhole well design is changed. All laboratory analytical reports regarding samples or tests from a well must be submitted to the AOGCC, no matter when the analyses are conducted. Item la. 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 1 b. Well Class Service wells: Gas Injection, Water Injection, Water -Alternating -Gas Injection, Salt Water Disp, Water Supply for Injection, Observation or Other. Item 4b. TPI (Top of Producing Interval). Item 9. The Kelly Bushing and Ground Level elevations in feet above mean sea level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 15. The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). Item 20. Report true vertical thickness of permafrost in Box 20. Provide MD and TVD for the top and base of permafrost in Box 29. Item 22. Review the reporting requirements of 20 AAC 25.071 and, pursuant to AS 31.05.030, submit all electronic data and printed logs within 90 days of completion, suspension, or abandonment, whichever occurs first. Item 23. Attached supplemental records should show the details of any multiple stage cementing and the location of the cementing tool. Item 24. 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 27. Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, or Other ( explain). Item 28. 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. Item 30. 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, Item 31. Pursuant to 20 AAC 25.070, attach to this form: well schematic diagram, summary of daily well operations, directional or inclination survey, and other tests as required including, but not limited to: core analysis, paleontological report, production orwell test results. Form 10-407 Revised 512017 Submit ORIGINAL Only TREE= DRY HOLE SUSPENDED [WELLHEAD= MCEVOY VEEDD 30'COND 111 04 ACTUATOR= REMO OKB. ELEV =in'TBGRJNCH(03120119) 64' 4-12" KILL STM G 1123' REF ELEV =�' TBG, 12.6#, LA0 NSCT BF. ELEV =FACE 0152 bpf, ID=3.958" KOP =3200' Max Ie= 10041' (09/11/19) Dafen TV =1087 0' CSG gq# 1185' Dalen ND =00' S 0/133#, K-55 D = 18.750' ET CUT CSG 1188 -ELM 9) 5/8' CSG, 47#, 2484' 80, D = 8.681' 13-3/8' , N-80, D = 12.347' 2686' TBG STUB(0725/19) 3510'ELM MiniID = 2.380" @ 10058' 3-3/1-7/8" XO BG PUNCH (03/20/19) 8920' - 8926' 4-12' 1UG, 12.6# 13CR80 VAM, I 9017' .0152 bpf. D = 3.958" 9-5/8• LNR, 47#, SOO-95, .0732 bpf, D = 8.681' 9747' PERFORATION SUMMARY REF LOG: CAL ON 05/16/07 ANGLE AT TOP PERF: 34' @ 9300" Note: Refer to Production DB for historical perf data 3-1/2' LNR 8.81#, L80 STL, 9040' .0087 bpf, D =a2-992' Opn/Sgz I SHOT "9185' TOP OF MILLED CMT (DMS 0429107) 6 9300-9330 C 17#, L-80 PC, .0232 bpf , D = 4.892' �91� 9-5/8• LNR, 47#, SOO-95, .0732 bpf, D = 8.681' 9747' PERFORATION SUMMARY REF LOG: CAL ON 05/16/07 ANGLE AT TOP PERF: 34' @ 9300" Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sgz I SHOT SQZ 2" 6 9300-9330 C 04/23/15 0427107 2" 6 9382-9397 C 04/23/15 CTD SIDETRACK (04-01A) 2' 6 9408-9425 C 04!22/15 09117/19 2-1/2" 6 9464-9469 C 10/10/09 2-1/2• 6 9452-9457 C 10/10/09 2" 6 9970-10020 C 05/17/07 2" 6 10500 - 10650 C 05/17/07 2" 6 10770 - 10800 C 05/17/07 2" 6 10895 - 11300 C 05/17!07 SAFETY NOTES: WELL REQUIRES A SSSV '442' CHROME TBG"' WELL ANGLE >70' @ 9592' — DEPTHS MEASURED WITH I -COIL DURING 52007 CTD (04.01A)'•' Fol 3892' - 8925' EST TXW TOC (03/29/19) SLM TXLA TOC (04/10/19) 8909' 4-12' HES X NP, ID = 3.813' 8930' 9-5/8• X 4-12• BKR S3 HYDR I4 -7/Z- Ht X NP, D = 3,813' 4-12• XX PLUG (10/20/17) 3.70' DEPLOY SLV W/ 4• GS PROFILE, 3-1/2. OTIS X NP. D = 2.813' 19-5/8• X 4-12' UNDUE OVERSHOT 3-12•x3-3/16'XO,1)=2.786 BEHIND 5-12' BKR SEAL ASSY CT LNR 19-5/8"X 5-7/2' BKR FB -1 PKR W /SEALBI EXT. 5-1/2' OTIS XN NO-GO NP, D = 4.45' 1106,0-vc URK "H Nvul Sue I BEHIND 1184• 5-12'TUBNGTAL(CNTD) CT LNR MILLED WINDOW (04-01A CORRECTED) 9278'- 9287' 3-3/16- LNR, 6.2#, L-80 TCI, .0076 bpf, D = 2.80• DATE REV BY COMMENTS DATE REV BY COMMENTS 01/10!11 ORIGNAL COMPLETION 1023/19 TWJMD TBG X CONDUCTOR CMT 1020/19 0710790 RWO 11/14/19 JNUJMD ADDED BF 0427107 ORDIC RWO 05111IM7 ORDIC CTD SIDETRACK (04-01A) 08/24/19 P-272 CSG RECOVERY 09117/19 AAO III SUSPENDED J 3 -3116 -X D = 2.380' 10720' 2-7/8 VVFD 0056 PRUDHOE BAY UNIT WELL: 04-01A PERMIT No:'2070350 API No: 50-029-20078-01 SEC 34, T11 N, R15E,1327' FNL & 29: BP Expkaation (Alaska) WELL NAME: 04-01A 26. Acid, Fracture, Cement Squeeze, Etc. Depth Interval (MD) Amount & Kind of Material Used 3510' Cut & Pull Tubing 2403' 84 Bbls Class'G' 1188' Cut & Pull 9-5/8" Casing 1170' Set CIBP 1095' Cut & Pull 13-3/8" Casing Surface 1422 Bbls Class 'G' T/I/O/OO = 13/82/3/3. Temp = SI. TBG & IA FLs (WIE request). Dryhole tree installed. Wellhouse removed, temporary scaffold installed. Integral installed on IA. TBG FL @ surface. IA FL @ near surface. TP decreased 7 psi, IAP decreased 6 psi, OAP, OOAP unchanged since 5/29/19. SV, MV = C. IA, OA, OOA = OTG. 02:00 6/8/2019 T/I/O/OO = 11/81/3/3. Temp = SI. TBG & IA FLs (WIE request). Dryhole tree installed. TBG FL @ surface. IA FL @ near surface. TP decreased 2 psi, IAP decreased 1 psi, OAP, OOAP unchanged since 06/08/19. Bled TP from 11 to 0 psi <1 sec, Bled IAP from 81 psi to 76 psi in <1 sec (to verify near surface). Final WHPs = 0/76/3/3. 6/13/2019 SV, MV = C. IA, OA, OOA = OTG. 17:00 T/I/O/OO = 8/80/4/4. Temp = SI. T & IA FL (WIE Req). T FL @ surface. IA FL @ 100' (1.5 bbls). Dry hole tree. No wellhouse or flowlines. Temporary scaffold installed. TP decreased 3 psi, IAP decreased 1 psi and the OAP & OOAP increased 1 psi since 6/21/2019 6/13/19. T/I/O/OO = 0+/80/0+/0+. Temp = SI. TBG & IA FL (WIE Req). No wellhouse, flowline or AL. Temporary scaffolding installed. TBG FL @ surface. IA FL @ near surface. No change in the WHPs since 6/21/19. 6/27/2019 SV, MV = C. IA, OA, OOA = OTG. 14:00. T/I/O/OO = 0+/80/0+/0+. Temp = SI. TBG & IA FL (WIE Req). No wellhouse, flowline or AL. Temporary scaffolding installed. TBG FL @ surface. IA FL @ near surface. No change in the WHPs or FLs since 6/27/19. 7/4/2019 SV, MV = C. IA, OA, OOA = OTG. 15:15 T/I/O/OO = 5/76/0/0+. Temp = SI. CMIT-TxIA to 2682/2446 FAILED & MIT -OA to 1268 psi PASSED (pre P&A). Max applied = 2750 psi. Target = 2500 psi. Max applied = 1320 psi. Target = 1200 psi. Dryhole tree installed. Integral installed on IA =inspection current. Wellhouse removed. Temporary scaffold & secondary containment installed. T FL @ surface. IA & OA FL @ near surface. Used a total of 5.4 bbls of diesel to pressure TP & IAP to 2750/2749 psi. Monitored for 30 min. On the 4th attempt TP/IAP lost 35/163 psi in the 1st 15 min & 33/140 psi in the 2nd 15 min for a total loss of 68/303 in 30 min. Bled TP/IAP to 0 psi (3.8 bbls). Used a total of 2.4 bbls of diesel to pressure OAP to 1320 psi. Monitored for 30 min. After 3rd test OAP decreased 31 psi in the 1st 15 min & 19 psi in the 2nd 15 min for a total loss of 50 psi in 30 min. Bled OAP to 0 psi (0.5 bbl). Tags hung. 7/5/2019 Final WHPs = 0/60/0/0. ***WELL S/I ON ARRIVAL*** JET CUT 4.5" TUBING AT 3510' ELM (5' below collar @ 3505'), CCL TO CUT = 6.3'. CCL STOP DEPTH = 3503.7' LOG CORRELATED TO TUBING TALLEY DATED 04-22-07 7/8/2019 ***DSO NOTIFIED JOB COMPLETE*** T/I/O/OO = ?/160/20/0+. Temp = SI. TBG & IA FL (WIE Req). No wellhouse, flowline or AL. Temporary scaffolding removed. Well is prepped for rig. Unable to obtain T FL & TP due to no scaffolding. IA FL @ surface. 7/11/2019 SV, MV = C. IA, OA, OOA = OTG. 22:40 T/I/O = 0/150/0 TEMP = 55* Function LDS (TBG). Off seated (SBS) High pressure. R/U test equipment onto test port. Stung into test void 140 psi, bled to 0 psi. Monitored for 15 min, pressure slowly builds in test void . Hold open 7/15/2019 bleed on (SBS). Function all (LDS) all moved freely, torque all (LDS) to 500 ft/lbs. Daily Report of Well Operations PBU 04-01A T/1/0=0/150/0, Temp=Sl. Function LDS (IC). Stung into IC test void (0+ psi), bled void to 0 psi. Monitor for 30 min, no change in pressure. All LDS functioned, 3 LDS were tight but fully functioned, the rest functioned freely. Torqued to 500 Ib/ft. 7/16/2019 T/I/0/00 = MV/130/10/0+. Temp = SI. Bleed WHPs to 0 psi (pre pulling unit). Wellhouse, scaffold, & AL removed. Dryhole tree installed. Integral installed on IA =inspection current. Temporary containment installed around conductor. IA FL @ near surface. OA FL @ surface. OOA FL @ near surface. Bled IAP to BT from 130 psi to BT from 130 psi to 0 psi n 1 hr (gas/fluid mix, 0.5 bbl). Held open bleed for 1 hr. Bled OOAP to BT From 0+ to 0 psi in <1 min (all gas). Held open bleed for 1 hr. Bled OAP to BT from 10 psi to 0 psi in 1 hr (<0.1 bbl). No monitor. Final WHPs = MV/0/0/0. 7/22/2019 MV = C. IA, OA, OOA = OTG. 13:00 24 HR Summary: Complete moving of rig equipment to DS 04, staging rquipment away from we 01, Fullbore prepping to circulate well, load tanks with brine, Litle Red on location to circulate well. FB completed 385 bbl 9.8 brine circ. Monitored well 2 hrs. Full and no flow. Walk down w/ DSO. Sim -Ops w/ GNI. Valve shop pull THA/valve. Cameron installed checked hanger threads (good) Set base beam and pony sub. Spotting sub. Sub in place and pinned, Back carrier onto sub base, PJSM: Peak crane, rig up crane, spot HPU, water tank and doghouse, rig crane down, Spot gen set and combo building, spot catwalk. Prep 7/23/2019 and raise derrick, scope derrick to full height. rig up lines, guide wires. T/1/0/00= 0/0/0/0 Temp= S/I (LRS Unit 72 - Circ Out Pre All American Pulling Unit) Pumped the following down the TBG, taking returns from IA, to open top tank: 385 bbls of 110* F 9.8 ppg NaCL Bled surface pressures to 0 psi. Monitor WHP for build up, none observed. Maintain open bleeds on TBG and IA, no flow observed. DHD had control of the well upon departure. 7/23/2019 Final T/1/0/00= 0/0/0/0. 24 hour summary: Continue RU. Hook up electrical and service lines. RU beaver slide, cat walk, and pipe racks, MU boot. Complete Rig acceptance Audit. Review related SCE list. Edit SCE list to record keeping revisions. Install riser on BOP to flow box, make up cross over to hanger, back out lock downs, pull hanger to the floor, tbg free good cut, lay down 4.5" Vam Top tubing. 24 hour forecast: 7/24/2019 Next BOP test: Z pad; Initial/WeeklyTripping Drill: 7/21/19; Brine weight in/out 00:00 hrs: T/I/O = 0/0/0. Install THA. Torque to API specs. RDMO ***Job Complete*** SEE LOG 7/25/2019 FOR DETAILS Final TWO = 0/0/0. Clear and clean floor, rig up SLB slick line for GR/JB run. run 8.52 GR to 3504' SLM, POH with junk basket clean, rig SLB slickline down. No TBG ran back in hole. Completed pulling TBG from jet cut at 3510' ELMD. Secure floor, scope and lower Derik. Release Pulling Unit @ 0600 hrs. Completion componets and TBG sent to Grieve Pad for AOGCC inspection. Transport Carrier, sub and pony subs to Peak Yard in preparation for packaging equipment onto purpose-built trailer to stream line equipment moves. ***Job Complete*** 7/25/2019 ****SWCP #4522 RIG ASSIST AAO UNIT III**** DRIFTED W/ 5.94" JUNK BASKET W/ 8.52" GAUGE RING TO TBG CUT ga 3 504' SLM / 3,510' ELMD (Empty) 7/25/2019 ****JOB COMPLETE, SPOC NOTIFIED UPON DEPARTURE**** Daily Report of Well Operations PBU 04-01A IA/0/00 = Vac/0/0. Temp = SI. TBG & IA FL (WIE req). IA FL @ Near Surface. All American unit removed the TBG. 7/26/2019 SV, MV = C. IA, OA = OTG. 16:25 TWO = 0/0/0. RD Dry hole Tree, RU tree cap bonnet. 4 bolted THA. RDMO. ***Job 8/1/2019 Complete***. ***WELL S/I ON ARRIVAL*** (Caliper/CAST/Gyro) PERFORM READ 40 ARM CALIPER LOG FROM 3500' TO SURFACE BEGIN CAST-M CEMENT LOG FROM 3495' TO SURFACE 8/2/2019 ***JOB CONTINUED ON 03-AUG-19 WSR*** ***JOB CONTINUED FROM 02-AUG-19*** (HES Caliper/CAST/Gyro) LOG CAST-M CEMENT LOG FROM 3495' TO SURFACE. LOG GYRODATA GYRO FROM 3495' TO SURFACE. 8/3/2019 ***JOB COMPLETE ON 03-AUG-2019*** T/1/0=0/0/0 Removed tree cap bonnet, installed dryhole tree. Torqued to API specs. Re- 8/5/2019 installed nuts on THA x tubing spool. Torqued to specs. FWP's 0/0/0. CTU 9 1.75" CT, 0.156" wt. Objective: P&A MIRU. Perform weekly BOP test. Standby for SLB cement crew currently on P272 8/9/2019 ***Job in Progress*** CTU 9 1.75" CT, 0.156" wt. Objective: P&A. ***Continue from 8/9/19*** Continue standby for SLB cement crew currently on P272. Make SLB BHA w/ 3.0" ball drop nozzle. RIH and tag,, PUH to 3500' and lay in 84 bbls of 15.8 ppq Class G cement. ETOC 2403'. Lay in 9.8 ppg brine from 2403' to surface. Make three passes up and down jetting tree & BOP's w/ PowerVis. Pop off well, ball recovered. RDMO 8/10/2019 ***Job in Progress*** T/1/0/00 = VAC/VAC/1/0. Temp _--SI. WHPs (WIE Request). No wellhouse, flowline or scaffolding. Used manlift to access tree. Installed gauge on OA. Dry hole tree. 8/13/2019 SV, MV = C. IA, OA, OOA = OTG. 04:30 T/1/0= vac/vac/vac Temp= S/I (CMIT-TxIA for Plug & Abandon) 4 si Tar et Pressure= 2500/2500 psi, Max Applied Pressure= 2750/2750 psi. Pressured TxIA to 2735/2749 psi with 2 bbls 9.8 brine. TxIA lost 87/85 psi in 1st 15 minutes and 30/30 psi in 2nd 15 minutes, for a total of 117/115 psi during 30 minute test. Bled back TxIA, returned —2 bbls. Tubing valves= closed; Annulus valves= open. 8/14/2019 FWHP's 0/0/0 T/I/O = 0/0/0. Removed Dry Hole Tree and THA. Tree and THA left on location. RDMO 8/14/2019 ***Job Complete*** SEE LOG FOR DETAILS Final WHP = 0/0/0. ***WELL SHUT IN IN ARRIVAL *** CUT 9 5/8 CASING 1188' WITH 8,188 " JET CUTER LOG GR CCL AFTER CASING CUT FROM 1320' TO 1050' ELM. 8/16/2019 ***WELL SHUT IN ON DEPARTURE, TURN OVER TO DSO *** T/I/O = 0/0/180. Install Dry hole tree and THA, Torque THAxTS to 1500 FT LBS. RU Piggy Back IA, PT IA Piggy Back 350/3500 PSI (Pass) Charted and Retained. RU Piggy 8/16/2019 Back OA, PT OA Piggy Back 350/3500 PSI (Pass) Charted and Retained. RDMO. ***Job T/I/O = 7Nac/110. Temp = SI. Bleed OAP to 0 psi. No wellhouse, AL, flowline, or scaffold. Dryhole tree installed. Unable to reach tree cap for TP. OA FL @ surface. Bled OAP from 110 psi to 90 psi in 20 mins (2.0 bbls fluid). Job discontinued per WIE. Monitored for 30 mins. WHPs unchanged. Final WHPs = ?/Vac/90. 8/18/2019 Tree Valves = Unk. IA, OA = OTG. 1345 hrs. North America -ALASKA - BP Page i of 5 Operation Summary Report Common Well Name. 04-01 AFE No Event Type: PLUGANDABANDON(P)(A) .Start Date: 8/20/2019 'End Date: 8/24/2019 '.H-S4CW00022X-EX-(1,600,000.00) Project: PBU Site: 04 — -- Rig Name/No.: PARKER 272 Spud Datefrime: 11/27/1970 12:00:OOAM Rig Release: 8/24/2019 Rig Contractor: PARKER DRILLING CO. _ BPUOI' USA00001115 Active datum: KB @75.85usR (above Mean Sea Level) -� Date From - To 8/20/2019 118:00 - 2000 Him (hr) 2.00 Task RIGID Code NPT Pj Total Depth (usft)— Phase Description of Operations _ PRE GENERAL RIG DOWN -SKID FLOOR I li LAYOVER DERRICK (375K MAX) 20:00 - 21:30 1.50 RICO P ! _ I- DISCONNECT INTERCONNECTS _ PRE PREPARE TO MOVE TO 04-01 -COMPLETE PRE MOVE INSPECTIONS !' - SPLIT MODULESAND STAGE FOR MOVE AT PAD ENTRANCE REMOVEDUMMYHOUSE — 121:30 - 00:00 2.50 1 RIGID I P GAUGES ON WELLHEAD RE-INSTALL GAUGES ON WELLHEAD PRE START RIG MOVE FROM L3 TO OSO4 8/21/2019 100:00 - 0300 0— 3. 0 0690 3.03.OT 3.00 RIGDP� P ABAN COMPLETE RIG MOVE TO DS04 ARAN SPOT RIG OVER 04-01 1 - SET WELLHOUSE !-SPOT DRILL MOD I - MARRY MUD MOD AND UTILITY MOD TO 06:00 - 07:30 1.50 r RIGU P DRILLMOD_ _ 1 BAN i RIG UP OPERATIONS HOOK UP INTERCONNECTS ABAN PERFORM CHECKLIST FOR RAISING 07:30 - 08:00 0.50 RIGU P DERRICKAND RAISE DERRICK 08:00 - 08:3 0.50 4 RIGU P __'-505KOFFRACK ABAN SKID RIG FLOOR TO DRILLING POSITION - RAISE PIPE CAT I - INSTALL FLOW LINE IL -SKID HAUNCH 108:30 - 10001,50 RIGU P I — - ABAN GENERAL RIG UP - RIG UP ON THE RIG FLOORAND IN THE MUD PITS -PERFORM DERRICK INSPECTION - - - COMPLETE PRE-SPUD CHECKLIST 2.00 RIGU P-- , --—ACCEPT RIG AT 10:00- 0:00'""10:0012:00 ABAN NIPPLE DOWN DRY HOLE TREEAND 10:0012:0 0 ! - ADAPTER FLANGE SIMOPS: -BRIDLE DOWN 112:00 - 16:00 4.00 1 RIGU P �— -RIG UP DERRICK ABAN NIPPLE UP HIGH PRESSURE RISER AND BOP STACK 1 TORQUE BOLTS TO SPEC - INSTALL CHOKE LINE, FLOW RISER, AND (TURNBUCKLES 116:00 - 19:00 3.00 RIGU P ABAN PERFORM SHELL TEST ON ROPE WITH ANNULAR ON 4" TEST JOINT 1! - PRESSURE TEST TO 250 PSI LOWAND 2500 PSI HIGH FOR 5 MIN EACH (PASS) ! - SET TEST PLUG IN TUBING HANGER AND -RUN IN LOCKDOWN SCREWS _-- -21:00 19.00 19:30 0.50 RIGU P -- CAMERON REP ON LOCATION TO OPERATE (LOCK DOWN SCREWS ABAN 1 PERFORM RIG EVAC/H2S DRILLAND AAR - -- 19.30 2t00 1.50 DISPL P P ---- --- 1,200.00 ABAN (SINGLE IN THE HOLE WITH 4" DP TO 1200' MD - 22:00 1.00 DISPIL P T 1,200.00 ABAN RIG UP TO CIRCULATE OUT FREEZE � PROTECT FROM THE OA Printed 11/25/2019 3:15:01PM **All depths reported in Drillers Depths'" North America - ALASKA - BP Page 2 of 5 Operation Summary Report Common Well Name: 04-01 AFE No Event Type: PLUGANDABANDON(PXA) Start Date: 8/20/2019 End Date: 8/24/2019 H-54CW00022X-EX-(1,600,000.00) Pmject: PBU j Site: 04 - - Rig Name/No.: PARKER 272 Spud Date/Time: 11/27/1970 12:00:00AM Rig Release: 8/24/2019 Rig Contractor: PARKER DRILLING CO. I BPUOI: USA00001115 Active datum: KB @75.85usft (above Mean Sea Level) Date From - ToI Hrs Task CodeNPT Total Depth I Phase', Description of Operations (hr) DISPL I P (usft) 1,200.00 ABAN DISPLACE FREEZE PROTECT FROM OAAS 22:00 - 00:00 2.00 - j 1 FOLLOWS: — PUMP 12 BBL OF HEATED 6.8 PPG DIESEL TO THE END OF THE DP TAKING RETURNS UP THE IA - CLOSE ANNULAR AND OPEN OA '- PUMP 50 BBL OF HEATED 6.8 PPG DIESEL AND DISPLACE WITH 12 BBL OF 9.8 PPG BRINE, TAKING RETURNS UP THE OA TO THE ! 1TIGER TANK _ _ = ALLOW DIESEL TO SOAK FOR 1 HOUR 8/22/2019 100:00 - 02:00 2.00 DISPL P 1,200.00 ABAN CIRCULATE OUT FREEZE PROTECT FROM OA ! 1- STAGE PUMPS UP FROM 2 BPM TO 8 BPM, 900 PSI - PUMP BARAKLEAN PILL — -- 1 — — `MONITOR- WELL FOR 10 MIN (STAT --- -- 10200 - 02:30IC) 0.50 DISPL P _ 1,200.00 ABAN !PULL4" DPOUT OFTHE HOLEAND STAND --..____1 - —.�— 02:30 07:00 —� 4.50 _�_�4_ BOPSUR P __1,200.00 _ __ BACK IN THE DERRICK ABAN NIPPLE DOWN THE BOP STACKAND HIGH PRESSURE RISER - - REMOVE THE FLOW RISER, TURN BUCKLES, AND FLOW LINE 1- BREAK BOLTS AND REMOVE STACKAND j RISER - BREAK BOLTS ON BOTTOM OF TUBING HEAD - CAMERON REP ON LOCATION TO WATCH - FOR CASING GROWTH, NO GROWTH OBSERVED, LAY DOWN TUBING HEAD --- - INSTALL HANDLES ON CASING SLIPS AND WIRE TIE THEM TOGETHER --._ 07:00 08:30 _ 1.50 BOPSUR P �1,200.00 ABAN NIPPLE UPTHE BOP STACKAND HIGH PRESSURE RISERS ADD 30" SPACER SPOOL IN PLACE OF THE ''. TUBING HEAD SIMOPS: RIG UP DOYON CASING EQUIPMENT 1,200.00 ABAN PRESSURE TEST BOP STACKTO 250 PSI I 08'30 09:000.50 11 BOPSUR P " LOWAND 500 PSI HIGH FOR 5 MIN EACH i - TEST WITH BLIND RAMS AGAINST THE DOWNHOLE CEMENT PLUG 09:00 76:30 ___._.. 7.50 - CASING P 1,200.00 ABAN MAKE UP9-5/8" SPEAR ASSEMBLY AND SPEAR 9-5/8" CASING -APPLY STEAM TO WELLHEAD AND PULL 1 9-5/8" CASING I - ATTEMPT TO PULL CASING WITH 130K-180K WITH NO SUCCESS - RECIEVE APPROVAL TO STAGE UP TO 250K TO PULL CASING - - CASING PULLED FREE AT 230K 76:30 - 79:00 2.50 CASING P 1,200.00 1 ABAN -PULLS-5/8" CASING OUTOFTHE HOLE FROM +1200' MD TO SURFACE '- LAY DOWN 1-17.04' CUT JOINT, i PUP JOINT, 27 FULL JOINTS, 1-3.29' CUT JOINT 190000 19:30 0.50 CASING P - PU 83K, SO 83KAT 1200'MD 1,200.00 ABAN RIG DOWN CASING EQUIPMENT Printed 11/25/2019 3:15:01PM **All depths reported in Drillers Depths** Printed 11/25/2019 3:15:01 PM —All depths reported in Drillers Depths** North America - ALASKA - BP Page.3 of 5 Operation Summary Report - - Common Well Name: 04-01 - AFE No Event Type: PLUGANDABANDON(P)(A) Start Date: a/20/2019 End Date: 8/24/2019 'H-S4CW00022X-EX-(1,600,000.00) Project: PBU Site: 04 -- - - Rig Name/No.: PARKER 272 Spud Date/Time: 11/27/1970 12:00:OOAM Rig Release: 8/24/2019 Rig Contractor: PARKER DRILLING CO. BPUOI: USA00001115 Active datum: KB @75.85usR (above Mean Sea Level) - Date From - To Hrs Task Code NPT Total Depth Phase Description of Operations hr) 1930 - 20:00 0.50 CASING P 200. 1,200.00 ABAN MAKEUP 13-3/8" CASING CLEANOUT ASSEMBLY TO 16' MD -9 BLADE JUNK MILL - 3 BLADE STAB FLOAT SUB WITH PORTED FLOAT !20:00 - 21:00 1.00 CASING P 1 1 2W.00 ABAN _ RUN IN THE HOLE WITH CLEANOUT BHA ON 4" DP TO THE 9-5/e" CASING STUB AT 1204' MD ---- ,121:00 - 21:30 0.50 CASING. P __F1 __ 204 ARAN _ - TAGGED STUMP 2 TIMES PUMP 35 BBL HIGH VIS SWEEP AND CIRCULATE HOLE CLEAN WITH 2X BOTTOMS UP i - 650 GPM, 370 PSI 120 RPM 1 KFT-LBS To 121:30 - 00:00 2.50 CASING p - 1,204.00 ABAN RACK BACK 2 STANDS AND PERFORM STRIPPING DRILL WITH CHRIS YEAROUT'S CREW I- HOLD Di KICK WHILE TRIPPING DRILL TO SECURE WELL 8/23/2019 00:00 02:00 2.00 CASING P 1,204.00 ABAN PERFORM STRIPPING DRILL WITH JAMES 1 HUNDLEY'S CREW - HOLD D1 KICK WHILE TRIPPING DRILL TO 03:00 SECURE WELL _ :00 - 1.00 CASING P 1,204.00 ABAN PULL OUT OF THE HOLEAND LAY DOWN THE CLEANOUT BHA FROM 1061' MD TO SURFACE -MONITOR WELL FOR 10 MIN PRIOR TO ----.— - _r03 03 00 — — PULLING OUT OF THE HOLE (STATIC) 0330 0.50 CASING P 1,204.00 ABAN CLEAN AND CLEAR THE RIG FLOOR 0 330 0 05:30 2.00 CASING P —__ 1,204.00 ABAN RIG UP SLB ELINE UNITAND LOGGING —... _ TOOLS ;05:30 05.30 - 09:30 4.00 CASING P 1,204.00 ABAN -_ LOG 13-3/8" CASING WITH SONIC CALIPER I AND USIT LOGGING TOOLS - SEND LOG RESULTS TO ANCHORAGE TEAM 3010:00 0.50 CASING P 1,204.00 ABAN AND DEVELOP PLAN FORWARD RIG DOWN ELINE UNIT ___._--__. flog 00 - 11:00 1.00_._. CASING P 1,204.00 ABAN MAKEUP AND RUN IN THE HOLE WITH 13-3/8" 'CIBP TO 1170' MD SET CIBP AT 1170'MD WITH 35 TURNS TO THE RIGHTAND PU 55KOVERPU LL TO 'SHEAR 1:00 71:30 --- -SET DOWN IOK TO CONFIRM SET 0.50 CASING P 1,204.00 ABAN 1 PULL OUT OF THE HOLE FROM 1170' MD TO SURFACE - LAY DOWN CIPS RUNNING TOOL - 12:30 1.00 ? CASING P 1,204.00 ABAN - CLEAR RIG FLOOR MAKE UPAND RUN IN THE HOLE WITH SLB 111:30 12.30 _— 13-3/8" CASING CUTTER TO 1095' MD SPACE OUT CUTTERS AT 1095' MD - 14:30 2.00 CASING P 1,204.00 ABAN --- I CUT 13-3/8" CASING AT 1095' MD 10 BPM, 590 PSI - 80 RPM, 1-5 KFT-LBS TORQUE - OBSERVE PRESSURE DROP FROM 590 PSI ! TO 300 PSI AND TORQUE DROP FROM 5-1 — — KFT-LBS TORQUE TO CONFIRM CUT Printed 11/25/2019 3:15:01 PM —All depths reported in Drillers Depths** NorthAmerica-ALASKA -BP Page 4of5 Operation Summary Report Common Well Name'. 04-01- -- - _ - -- -- AFE No Event Type: PLUG AND ABANDON(PXA) (Start Date: 8/20/2019 End Date: 8/24/2019 H-S4CW00022X-EX-(1,600,000.00) Project: PBU Site: 04 -- –_ Rig Name/No.. PARKER 272 Spud DateMme: 11/27/1970 12:00:00AM Rig Release: 8/24/2019 Rig Contractor PARKER DRILLING CO. _ BPU01: USA00001115 Active datum: KB @75.85usft (above Mean Sea Level) Date From - To Him Task Code NPT Total Depth I Phase Description of Operations hr)(usft) 'CIRCULATE 14:30 - 20:30 6.00 CASING P 1,204.00 ARAN OUT FREEZE PROTECT FROM ODA I- SPOT DIESEL TO END OF DP i- CLOSE ANNULAR AND OPEN OOATO TIGER TANK - PUMP AND DISPLACE 50 BBL HEATED DIESEL INTO THE OOAAT 2 BPM, 300 PSI - ALLOW DIESEL TO SOAK FOR 1 HR '- PUMP 510 BBL OF HEATED 9.8 PPG BRINE TO DISPLACE FREEZE PROTECT FROM ODA '- PUMP HEATED 9.8 BRINE AT BPM UNTIL BRINE OBSERVED IN RETURNS, STAGE UP TO 9 BPM FOR 1.5X BOTTOMS UP - PUMP 40 BBL BARAKLEEN SWEEP SURFACE TO SURFACE MONITOR WELL FOR 10 MIN (STATIC) 20:30 - 22:00 1.50 CASING P 1,204.00 ABAN PULL OUTOF THE HOLE WITH CASING ICUTTERASSEMBLY _ 22:00 - 22:30 0.50 - CASING P 1,204.00 ABAN - CHANGE OUT CUTTERS ON SURFACE RUN CASING CUTTER T047' AND CUT 13-3/8" ' CASING BELOW WELLHEAD - 6 BPM, 660 PSI 80 RPM, 5KFT-LBS TORQUE -OBESERVE PRESSURE AND TORQUE FALL OFF CONFIRMING CUT --�_ 'I i — - LAY DOWN CASING CUTTER ASSEMBLY 22::3030 00:00 - 1.50 BOPSUR P-� 1,204.00 ABAN NIPPLE DOWN BOP STACK . i.- DRAIN STACK - PULL FLOW RISER AND REMOVE TURNBUCKLES - BREAK BOP BOLTS, REMOVE BOP STACK AND SETBACK ON STUMP —F_.__REMOVE HIGH PRESSURE RISERS _ 8/24/2019 0000 - 02:00 2.00 BOPSUR P 1,204.00 ABAN NIPPLE DOWN 9-5/8" CASING HEADAND '.. PERMAFROST HEAD - LAY DOWN BOTH HEADS TOGETHER TO BE SEPARATED OFF-SITE - REMOVE 13-3/8" CUT JOINT WITH I WELLHEAD 02:00 - 02'.30 0.50 CASING P 1,204.00 ABAN MAKE UP 13-3/8" SPEARASSEMBLY ,- RUN INAND SPEAR 13-3/8" CASING - PULL CASING TO RIG FLOOR - 108K TO BREAK OVER CASING, 105K UP _.-_.WEIGHT 02:30 - 03:30 1.00 CASING P 1,204.00 ABAN CIRCULATE HOLE CLEAN WITH 1X BOTTOMS UP - STAGE PUMPS UP TO 8 BPM, 50 PSI - RECIPROCATE 38' -TAKE RETURNS TO CELLAR BOX _— 03:30 - 04:00 '. 0.50 CASING I P 1,204.00 ABAN RIG UP DOYON CASING EQUIPMENT '- CHANGE OUT TONG JAWSAND INSTALL ELEVATORS - DISENGAGE SPEAR AND REENGAGE SPEAR TO ENSURE SPEAR CAN BE REMOVED EASILY 04:00 - 10'.30 6.50 CASING P j 1,204.00 ABAN PULL 13-3/8" CASING FROM CUT AT 1095' MD TO SURFACE '- LAY DOWN X CUT JOINT, 28 FULL JOINTS, AND 20.30' CUT JOINT 10 30 - 11:30 1.00 CASING P 1,204.00 I'I ABAN CLEAN RIG FLOOR RIG DOWN CASING EQUIPMENT Printed 11/25/2019 3:15:01PM **All depths reported in Drillers Depths"' Printed 11/25/2019 3:15:01 PM **All depths reported in Drillers Depths" North Arnenca - ALASKA - BP Page 5 of 5 Operation Summary Report Common Well Name: 04-01 AFE No Event Type: PLUGANDABANDON(PXA) 1 Start Date: 8/20/2019 iEnd Date: 8/24/2019 '..H-S4CW00022X-EX-(1,600,000.00) Project: PBU Site: 04 Rig Name/No.: PARKER 272 Spud Date/Time: 11/27/1970 12:00 OOAM Rig Release: 8/24/2019 Rig Contractor. PARKER DRILLING CO. BPUOI: USA00001115 Active datum: KB @75.85usft (above Mean Sea Level) Date From - To His Task 1 Code I NPT TotalDepth Phase Description of Operations (hr) _ I I (u ft) .11:30 - 13:00 li 7.50 CASING P 1,204.00 ABAN i MAKE UPAND RUN IN THE HOLE WITH 20" CASING CLEANOUT ASSEMBLY TO THE TOP OF THE CASING STUB AT 1095'MD 113:00 -- —�' _ _ _ - 17-1/2" BIT - 15-7/8" STRING STAB - 14:30 1.50 �— CASINCo P 1,204.00 ABAN CIRCULATE HOLE CLEAN WITH 2X BOTTOMS UP -700 GPM, 1060 PSI 720 RPM, 7 KFT-LBS TORQUE _.._ �_ MONITOR WELL FOR 10 MIN (STATIC) 14:30 - 16:3 2.00 CASING P j 1,204.0ABAN 0 PULL OUT OF THE HOLE FROM 1095' MD TO SURFACE LAYING DOWN DRILL PIPE LAY DOWN CLEANOUT ASSEMBLY 17:00 CASING P 1,204.00 _ 11 7:00 - 21:00 4.00 ABAN I _t CASING N r r 1,204.00 ABAN CLEAN RIG FLOOR CLEAN PITS i- EXTENDED TIME CLEANING PITS DUE TO INSUFFICIENT NUMBER OF VAC TRUCKS AVAILABLE FOR CLEANING PITS SIMOPS GENERAL RIG DOWN -CLEAN ARCTIC PACK FROM RIG FLOOR - SECURE TOP DRIVE AND BRIDLE UP '- SECURE PIPE IN PIPE SHED - RIG DOWN RIG FLOOR . '- REMOVE HANDRAILS FROM ROOFTOP - PERFORM DERRICK INSPECTION j - PERFORM PRE -SKID CHECKLIST - SKID FLOOR AND LAY OVER DERRICK (370K I MAX) -� RELEASED AT 27:00"' Printed 11/25/2019 3:15:01 PM **All depths reported in Drillers Depths" ***SWS 2362 RIG SUPPORT FOR PARKER 272*** (P&A) PARKER 272 IN CONTROL OF WELL ON ARRIVAL. LOG 13-3/8" CASING WITH SLB USIT FOR PIPE EVALUATION 1200' TO SURFACE 8/23/2019 PIPE EVALUATION COMPLETE. RDMO. ***WELL COVERED UPON ARRIVAL*** RIG UP AND RUN READ HI-RES PRESSURE-TEMP-GR-CCL, 80-ARM CALIPER LOG FORM 1023' MD TO SURFACE W/ READ PRESSURE-TEMP-GR-CCL, OAL=9', OAW= 43#, MAX OD=2" WITH 10" CENTRALIZER LOG FROM 881' MD TO SURFACE W/ READ 80-ARM CALIPER, OAL=13', OAW=410#, MAX OD=9" WITH 20" CENTRALIZERS 9/8/2019 ***WELL LEFT UNCOVERED, WSL INFORMED*** Release off L-200A at 12:00 hrs to 04-01A Crew change- PTSM = Rig Move. Move and stage koomey unit - boiler - choke maniflold on CC2A Ball Mill Pad - Move and stage on location pump room - gen - lower equipment units Wait on Tool service to lay plywood and rig mats across the Kuparuk bridge - lay 9/9/2019 mats over culverts Crew change- PTSM = Rig Move. Wait on Tool service to lay plywood and rig mats across the Kuparuk bridge - lay mats over colverts Move and stage BOP and boiler on CC2A Ball Mill Pad - Move and stage on DS4 pump room - gen - lower equipment units. PJSM with Peak, Security and Rig Crews on moving sub. 5 hr delay @ CC2A due to flats on trailer and matting culverts. Move down K-Pad acess rd. to West Dock to DS4 access road. Spot sub over well - Set support modules and hook up. 24 hr Forecast:Finish hooking up suport units 9/10/2019 Accept the AAO-111 Unit to DS4-01A at 00:01 hrs on 9-11-2019 24 hr Summary: Crew Change - PTSM = Rig up - verifying proper hose and electrical alighnment. Rig Evac drill - Pre Workover with Night Crew. Hook up air pump from 20" conductor to bleed trailer. Prep rig floor and the yard for 4.5" tubing. Ran 27 As of 4-1/2" NSCT 12.6# L-80 to 1123' AAO RKB (or 1143' P-272 RKB) Hung string on top of 20" w/ (- beam clamp. Fluid level -20 from surface. Released @ 1700 hrs 9/11/2019 24 hr Forecast: Prep to move. Move to J-22 scheduled f/ 0900 tomorrow SLB Ful lbore pumping crew Job Scope Plug and abandon TBG x 20" casing from 1170' to sruface. MIRUPT SLB pumpers. Pump down kill string taking returns from 20" conductor: 5 bbls 60/40, 5 bbls FW spacer, and 422 bbls 15.8 ppg Class G cement. Arctic Pack to surface after 300 bbls away, clean cement to surface 408 bbls away. Job Complete. 15.8 ppg Class G cement in 4-1/2" TBG and 20" conductor EST BOC TBG x conductor = 1123'MD / 1123' TVD 10/20/2019 TOC in TBG x conductor = surface *** Permanent P&A. *** Excavate around wellhead to 12'. Cut wellhead 9.25' below pad grade. Pad elevation 29.5', tundra elevation 25.5'. Wellhead cut = 3.25' below tundra grade. AOGCC witness of TOC and marker plate install is Guy Cook. Pulled shoring box and backfill excavation with gravel. 11/3/2019 *** Job Complete *** ` Ty t e• � Ai6 a T3 ) ' L Originated: Schlumberger PTS - PRINT CENTER 6411 A Street Anchorage, AK 99518 (907) 273-1700main (907)273-4760fax Delivered to: +% AOGCC * \�I ATTN: Natural Resources Technician II r--' Alaska Oil & Gas Conservation Commision 333 W. 7th Ave, Suite 100 Anchorage, AK 99501 207035 TRANSMITTALDATE TRANSMITTAL # L i SERVICE ORDER SERVICE COLOR WELL NAME API # If FIELD NAME DESCRIPTION DELIVERABLE DESCRIPTION DATA TYPE DATE LOGGED PRINTS CDs 50-029-20078-01 PRUDHOE BAY 50-029-21902-00 PRUDHOE BAY me Signature return via courier or sign/scan and email a copy 1 A Transmittal Receipt signature confirms that a package (box, IIV envelope, etc.) has been received and the contents of the package have been verified to match the media noted above. The Date specific content of the CDs and/or hardcopy prints may or may not have been verified for correctness or quality level at this h Schlumberger and BP point. Schlumberger -Private MEMORANDUM TO: Jim Regg �� 1i(Z'�i`I P. I. Supervisor FROM: Guy Cook Petroleum Inspector State of Alaska Alaska Oil and Gas Conservation Commission DATE: 11/01/19 SUBJECT: Surface Abandonment PBU 04-01A BPXA PTD 2070350; Sundry 319-252 11/01/19: 1 arrived on site and met with Rob Liddelow (BPXA). I inspected the cement after the final cut was made and it was good hard cement. I also confirmed the cut-off ✓ depth was 3.5 feet below ground level. I checked that the information on the marker plate was correct and, after its installation, that it was completely welded to the conductor. I told Mr. Liddelow they could proceed on with their operation. Attachments: Photos (3) ✓ 2019-1101_Surface Abandon PBU_04-OIA_gc.docx Pagel of 3 I 1 I ✓is Mi. 11J � CO t.11 • CIi` /I iw+✓V� l.�r LLJ i 1 l \ l• 217035 '-, Date: 8/23/2019 3 1 15 6 70 Transmittal Number: 93703 UL BPXA WELL DATA TRANSMITTAL Enclosed are two (2) discs containing the information listed below. If you have any questions please contact Merion Kendall: 907-564-5216; merion kendaIl(a b com. SW Name API Date Com an Descri tion Disk Number 02-02 500292007400 7/27/2019 BPXA COMPOSITED GYROSCOPIC SURVEY 1 02-02A 500292007401 7/27/2019 BPXA COMPOSITED GYROSCOPIC SURVEY 1 03-28 500292111400 7/24/2019 BPXA COMPOSITED GYROSCOPIC SURVEY 1 04-01 500292007800 8/3/2019 BPXA COMPOSITED GYROSCOPIC SURVEY 1 04-01A 500292007801 8/3/2019 BPXA COMPOSITED GYROSCOPIC SURVEY 1 09-44 500292208700 7/23/2019 BPXA COMPOSITED GYROSCOPIC SURVEY 2 09-44A 500292208701 7/23/2019 BPXA COMPOSITED GYROSCOPIC SURVEY 2 09-44APB1 500292208770 7/23/2019 BPXA OMPOSITED GYROSCOPIC SURVEY 2 V-227 500292341700 7/20/2019 BPXA COMPOSITED GYROSCOPIC SURVEY 2 rrcasc 319rr anct nman a copy of this transmittal to. GANCPDC(a�bp365 onmicrosoft com Thank you, -bier Xendaff Subsurface Information Management AOGCC Department of Natural Resources ConocoPhillips Alaska, Inc. ExxonMobil, Alaska 1 Subsurface Information Management 900 E. Benson Blvd. PO Box 196612 Anchorage, AK 99519-6612 THE STATE OIALASKA GOVERNOR MIKE DUNLEAVY Sean McLaughlin Engineering Team Lead — CTD BP Exploration (Alaska), Inc. P.O. Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Prudhoe Oil Pool, PBU 04-01A Permit to Drill Number: 207-035 Sundry Number: 319-252 Dear Mr. McLaughlin: Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 w .aogcc.oloska.gov Enclosed is the approved application for the sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration 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. Sincerely, /A Daniel T. Seamount, Jr. Commissioner S� DATED this -? day of May, 2019. RBDMS 44�m 0 3 2019 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 MAY 15 2019 1. Type of Request: Abandon 0 • Plug Perforations ❑ Fracture Stimulate ❑ Repair Well ❑ h Ido Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing ❑ Change Approved Program ❑ Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other ❑ 2. Operator Name: BP Exploration (Alaska), Inc 4, Current Well Class: Expt loraory ❑ Development 0 • 5. Permit to Drill Number 207-035 ' 3. Address: P.O. Box 196612 Anchorage, AK 99519-8612 St2tigraphic ❑ Service ❑ 6. API Number: 50-029-20078-01-00 7. If perforating: What Regulation or Conservation Order governs well spacing in this pool? S. Well Name and Number: Will planned perforations require a spacing exception? Yes ❑ No 13 PBU 04-01A . 9. Properly Designation (Lease Number): 10. Field/Pools: ADL 028325 & 028324 PRUDHOE BAY. PRUDHOE OIL ' 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (8): Total Depth TVD(ft) : Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): 3892, Junk (MD): 11374 8995 3892 3892 8954,9530,10720 None Casing Length Size MD TVD Burst Collapse Stmctural Conductor 80 30" 31 .111 31 - 111 880 Surface 1154 20" 31 .1185 31-1185 1530/2320 520/1500 Intermediate 2657 13-3/8" 29-2686 29 - 2886 4930 2670 Intermediate 9252 9-5/8" 26-9278 26 - 8587 6870/6820!7510/8150 4760/3330/4130/5080 Liner 2386 3 -1/2"x3 -3116"x2-7/8" 8983- 11369 8325-8994 Perforation Depth MD (ft): Perforation Depth TVD (ft): 1 Tubing Size: Tubing Grade: Tubing MD (ft): 9300-11300 8606 - 8984 4-1/2"12.6#x5-1/2" 17# 13CrB0 / L-80 24-9184 Packers and SSSV Type: 41/7' Baker S-3 Hydro Set Packer Packers and SSSV MD (ft) and TVD (ft): 8930 / 8278 612" Baker FBA Packer 9063/8396 12. Attachments. Proposal Summary 0 Wellbore Schematic m 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ® Exploratory ❑ Stratigraphic ❑ Development El , Service ❑ 14. Estimated Date for Commencing Operations: June 15, 2019 15. Well Status after proposed work: Oil ❑ WINJ ❑ WDSPL ❑ Suspended ❑ 16. Verbal Approval: Date: GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned 4 17. 1 hereby certify that the foregoing is true and the procedure approved herein will not Contact Name: Mclaughlin, Sean M be deviated from without prior written approval. Contact Email: Sean.MCLaughknIff]bp.com Authorized Name: Mcaughlin, Sean M Contact Phone: Authorized Title: Engineering Team Lead - CTD Authorized Signature: j � 1^� Date: l COMMISSION USE ONLV� Conditions of approval: Notify Commission so that a representative may witness Sundry Number: Plug Inter g ty ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance Other'5''44, 4 Te 'Ae ae . n 16WC706q-_Uft E.�%Ct�wLLewsT�%�✓Q Gt f d%rP,�XL°'•L' A -42L Post Initial Injection MIT Req'd? Yes ❑ No ❑ Spacing Exception Required? Yes 11 No Subsequent Form Required: tAA e' [IMS -OA/ JUN 0 3 2 Approved byAPPROVED BYTHE : COMMISSIONER COMMISSION ) I S/> Date: vs�p�c) [A ORIGINAL Form 10-403 Revised 04/2017 Approved application is valid for 12 months from the date of approval. MG-kZI M17 s'-%6✓y Submit Form and Attachments in Duplicate hp f Sundry request for 04-01A Final Abandonment Well: 04-01A Date: 05/06/2019 Engineer: Sean McLaughlin MASP: 10 psi (for DPZ 1 and water flow- no gas) Well Type: Producer Estimated Start date: June 15, 2019 History: The 04-01A reservoir was abandoned under Sundry 319-009. There is a deep cement plug from 8925' to 3892'. This Sundry request is to perform final abandonment for 04-01 and fill the obligations of 00 149. Scope of Work: The objective of the remainer of the P&A is to gather surveillance information on the casing strings and then perform the final P&A at surface. - All recovered casing will be numbered and saved for study. All casing will be tested for NORM. AOGCC will be notified to inspect the casing strings. Proposed P&A Procedure: 1. Fullbore — MIT -OA to 1200 psi 2. Eline- Cut 4-1/2" tubing at 3500' (CBL may be required) 3. Tool Service- Prepare pad for Parker AAO 4. AAO- ND dry hole tree and tubing head adapter. Circulate the well to 9.8 ppq brine. LD 4-1/2" tubing. Freeze protect to 500'. 5. AAO- RU Eline. Make gauge run. Cleanout 9-5/8" if necessary. NU THA and master valve. 6. Eline- Caliper/GR and Gyro log of 9-5/8" casing to 3500' 7. Coil — Lay in cement to 2400' (across 13-3/8" casing shoe) B. Eline- Cut 9-5/8" at 2200' 9. Tool Service- Prep pad for Parker 272 10. Parker- NU 13-5/8" BOPE 11. Parker- Verify no surface compression in the 9-5/8" by working LDS. If compression is expected utilize Cameron compression release tools. 12. Parker- Spear 9-5/8", reciprocate and circulate to tank, Lay down 9-5/8" casing. Need 14" high torque tongs 13. Parker- RU eline to Caliper/GR and CBL of 13-3/8" casing 14. Parker — Set 13-3/8" CIBP at 1400' (cmt required to min of 1300'). PT to 1000 psi 15. Parker- Internal cut of 13-3/8" at 1 100'and 100' 16. Parker- ND BOPE 17. Parker- Spear 13-3/8", reciprocate and circulate Arctic Pack to tank, Lay down 13-3/8" casing hanger and stub. Be prepared to cut casing apart. 18. Parker - 13-3/8", reciprocate and circulate Arctic Pack to tank, Lay down 13-3/8" casing. Be prepared to cut casing apart. 19. Parker — RU eline to Caliper and GR/CCL/Hi-Res Temp Log 20" 20. Parker — NU casing and tubing spool. Run kill string to 1350'. RDMO 21. Fullbore- Cement to surface 22. Projects - Fill all unfilled annuli to surface with cement. Excavate and cut all casings 3' below Tundra Notify Inspector of opportunity to witness cut off prior to welding plate. Take picture once the wellhead is cut off. 23. Bead weld an abandonment plate on top of the cut off casing with the following information: BP Exploration Alaska, Inc. 04-01 A N PTD# 2070350 API No. 50-029-20078 24. Backfill excavation with gravel/fill to ground level. 25. Obtain Site Clearance Approval from AOGCC. TREE= DRY HOLE WELLHEAD= McEVOY ACTUATOR= REMOVED OKB. ELLV = 64' REF ELEI/ = 64' BF. ELEV = KOP= _ 35.3' 3200' Max Angle = 91 • @ 10041' Datum M7= 10676' Datum TVD= 8800 SS 111-40/133#, K-55 / D= 18.750' 9-5/8' CSG, 47#, 2464' L-80, ID = 8.681' 33/8" CSG, 72#, N-80, D = 12.347' 2686' Minimum ID =2.380" @ 10058' 3-3116" x 2-718" XO SAFETY NOTES: WELL REQUIRES A SSSV —4-12" O -01 A CHR.OM E TBG— WELL ANGLE >70* @ 9592— DEPTHS M EASURED WITH I -COIL DURING 5/2007 CTD (04-01A) 21 SW 4-1/2- HES 130R PP, D=3.813" r -AR 1 FT DANMRFI R ST MD TVD DEV TYPE VLV LATCH PORT DATE 5 3231 3227 11 MMG DOME RK 16 06/19/07 •4 5651 5414 30 MMC SO RK 20 06/19/07 -3 7396 6917 28 MMG DMY RK 0 0426/07 •2 8140 7571 28 MMG DMV RK D 0426/07 '1 8838 8196 26 MMG EMPTY C 0220/19 '01.215 BEHIND ESTIMATED TMA CMT 0329/19 3892' -892W EST TXEA TOC (0329119) SLM TMA TOC (04110119) 8909' 14-1/2'HESXNP.D=3.813• 1 5-1/2- TBG, 17#, L-80 FC, .0232 bpf , D = 4.892' H 9184' I 1 9-5/8" LNR, 47#, SOO-95, .0732 bpf, D= 8.681- 1 PERFORATION SUMMARY REF LOG: CNL ON 05/16/07 ANGLE AT TOP PERF: 34" @ 9300" Note: Refer to Production DB for historical pert data SIZE SPF NIEFWAL Opn/Sqz SHOT 6830' 1-19-5113- X 4-12" BKR S3 HY DRO PKR, D = 3.875" 6 9300-9330 C 8 05118/07 NORpC 2" 6964' 4-12-HES X NIP, ID C 0423/15 FULLE)KVALVE/SETXXPLUG 2' 6 9408-9425 8884' 4 -1/2 -XX PLUG(1020117) 2-12" 6 9464-9469 C 10/10/09 8883"' 3.70" DEPLOYSLV w/4" GS PROFLE, D=3.00' 6 9452-9457 C 10/10109 2' 9007' 3-12.OTIS X NP, D = 2.813" 4-12" TBG, 12.6# 13CR80 YAM, 9017' 2' 6 10500-10650 C 05/17/07 .0152 bpi, D = 3.958" 2' 6 10770 - 10800 C 05/17/07 2' 6 10895 - 11300 C 05/17/07 9017' 4-12•X5-12•XO, D= 3.958'(BENNO LNR) 4-12" TBG STUB (0426/07) 9022' 9028' 9-s/6"X4-1rz•UNIQUE ov13x6Hor 31/2' LNR, 8.81#, L80 STL, 9040' 9040' —13-1/2'X 3-3/16" XO, D= 2.786' .0087 bpf, D = 2.992' BEHIND 9069' 5-12' BKR SEAL ASSY CT LNR 8063' 9-5/8'X5-12'BKR FBA R(R w/SEALBOR EXT. OF MILLED CIVET (ONES 0429/07) "9186' -6—=-4. 917T 4 5-12" OTIS x NO-GO NP 4 5 " 1 5-1/2- TBG, 17#, L-80 FC, .0232 bpf , D = 4.892' H 9184' I 1 9-5/8" LNR, 47#, SOO-95, .0732 bpf, D= 8.681- 1 PERFORATION SUMMARY REF LOG: CNL ON 05/16/07 ANGLE AT TOP PERF: 34" @ 9300" Note: Refer to Production DB for historical pert data SIZE SPF NIEFWAL Opn/Sqz SHOT SOZ 2' 6 9300-9330 C 0423/15 05118/07 NORpC 2" 6 9382-9397 C 0423/15 FULLE)KVALVE/SETXXPLUG 2' 6 9408-9425 C 04/22/15 2-12" 6 9464-9469 C 10/10/09 2-12" 6 9452-9457 C 10/10109 2' 6 9970- 10020 C 05mro7 2' 6 10500-10650 C 05/17/07 2' 6 10770 - 10800 C 05/17/07 2' 6 10895 - 11300 C 05/17/07 116-15-12" BKR SHEAROUT SUB I BEHIND 1184' 5-12" TU[1NG TAL (CMT'D) CT LNR MILLED WINDOW (04-01 A CORRECTED) 9278' - 9287'. 8630' 3-3/16'BKR CBP(0422/15) 10058' 3-3/16' X 2-7/8' XO, D = 2.380 10720' 2-718"WFD CBP 3-3/16" LNR, 6.2#, L-80 TCI, .0076 bpf. D= 2.60" L80 DATE RH/ BY COMM130S DATE REV BY COMMENTS 01110/71 ORIGINAL COMPLETION 11/27/18 JNJJMD ADDED Tiff, BF, & COND DO" 07107/90 RWO 02/25/19 CJWJM) GLV CIO (0220/19) 04127/07 NORDIC RENO 02/28/19 KFVJMD DRY HOLETR E 05118/07 NORpC CTDSIDEERACK(04-01A) 03(21/19 m+jrvu TBGRx4cH(0320/19) 07/25/17 RJHJMD ADDED 30.006D & 20" CSG 04/22/19 J Tx W CMT PLUG (0329/19) 1023117 J FULLE)KVALVE/SETXXPLUG 05/07/19 JNIJMD TXIA SLM MEASURED TOC DEP11H ® 11336"' X058 bpf, D = 2.441' 11388"` PR UDHOE BAY EMT WELL 04-01A PE IMIT No: '2070350 AR No: 50-029-20078-01 SEC 34, T1 IR FEE 5F 1327' FTL & 296 FEL BP Exploration (Alaska) TREE= DRY HOLE VLEiL(EAD McEvoy 30 COND -1 —iv— 04-01 A ACTUATOR= REMOVED � OIB. ELEV = 64• RUP ELEV = &P BF. ELEV = 35.3' 1,85• 55 MaA= 91' @10041 D)-18750" naWmMD= 1067V �13-3/8" CBG, 72#, N-80, D = 12.347-3/8• CBG. 724, N-80. D = 12.347/�z66s• C DPZ1 1964'- 7402' Minimum ID = 2.380" @ 10068' MD 3-3/16" x 2-7/8" XO 4-12• TBG PINCH (0320/19) -8820• --892w — P&A PLAN DPZ3 9295 - N/A M 4-12" TBG, 12.6# 13CR80 VAM, 901T .0152 bpf, 1)= 3.958" NMRVAL 4-12" TBG STUB (0426/07) SHOT SOZ 9pgQ 6 31/2' LW 8.81#, LBO STL, C .0087 baf. D = 2.992" 061897 D= 4.892' PERFORATION SUMMARY REF LOG: CNL ON 05/16/07 ANGLE ATTOP PERF: 34' a 9300" Nola: Raferb Pmdur.8on DB br Nslodcal perf dab SIZE SPF NMRVAL Oprwsqz SHOT SOZ 2' 6 9300-9330 C 0423115 061897 7 6 9382-9397 C 042315 7023117 7 6 9408-9425 C D4)2215 2-12" 6 9464-9469 C 10/10/09 2-12" 6 9452-9457 C 1010/09 7 6 9970 -1 D020 C 05/17/07 7 6 105DO-10650 C 05/17/07 7 6 10770 -10800 C 05/17/07 7 6 10895-11300 C 05/17/07 Cut 13-3/8 at 1100' Kill/Cmt string to 1350' 13-3/8 CIPB at 1400' Cut 9-5/8" at 2200' Cement 9-5/8" to 2400' — Cut 4-1/2" at 3500' �"3692�• -8925• ESTTXIA TOC (0329119) 1 SSW l 4-1/2" HES X NP. D = 3.813" D= 3.875" 14-112" HES X NP, D = 3.81 r112" HES X NP, D = 3.813 4-12" XX RUG (1020/17) 3.70" DER.OY SLV w 14- GS PFIOFLE D= 3.00" 3-1/2"OTISX NP D=2613• a Mu -vz ArJ'10-nal, �u=�.iao- I BEHIND 9059'S-12"BKRSEALASSY CT LNR 9063' 9-59" X 5-12• BKR FB -1 PKR w /SEALBOR EXl 9172 5-12' OTB XN NO-GO w.. D= 4.45' 91183's12"BKRSHEAROUTSIJ3 BEHIND 9184' 5-12" TUBM TAL (CMT'D) CT LNR MILLED WINDOW (04-01 A CORRECTED) 9278' -9287- F3=1 9287' 9630• 8-3/16' BKR CBP (0422!15) 10058' 3-3/16' X 2-718" XO, / D = 2.380' LNR, 6.2#, L-80 TCIL 10068• Of, D = 2.80' DATEREV BY COMMENTS DATE REV BY COMMENTS 0110/71 ORIGINAL COMPLETION 1127/18 JNUJMD ADDED REF, BF, 8 COND DEPTH 0710790 RWO 9225/19 CJWJMD GLV C/O (02f20/19) 042/97 ORDIC2 RWO 0228/19 KP/JMD DRYHOLETREE 061897 ORDIC2 CTD SDETRACK(04-01A) 0321/19 MH/JMD TBG PUNCH(0320/19) 0725/17 RJWJMD ADDED 30'COND 820'CSG 0422/19 RD/JMD TxVa CMT PLUG 0329/79 7023117 GS/JMD PULLED KVALVE/SET XX PLUG PBTD PRUDHOE BAYUNIT WELL: 04-01A PERMIT No: 2070350 API No: 50-029-20078-01 , T11 N, R15E,1327' FNL 8 29; SP Exploration (Alaska) CBP II 1 2 3 4 4,_211 o a o 0 A A T-875/8 , SHENKAI SL 13-5M ANNULAR 6'-103/16.. 0 SHENKAI SL 13-5M DOUBLE RAM B B 9,_17/6„ 8'-5" 4,_6776„ 1'-4'/6N 3'-2%6" F-1/2 C ilk C 10,-4„ V-41�27MINOPEN DDDIDDD 5_31/2„ CLOSING/OPENNING VOLUME (GAL) 30 ITEMS CLOSING VOL OPENNING VOL ANNULAR 23.59 17.41 D RAM 4.39 3.91 D HCR 0.40 0.40 NOTES' THE CONTENTS OF THIS DRAWING PROJECT TRIE BOP INFORMATION IN THIS ARE THE PROPERTY OF WESTERN NY MAEROOWG ND 13-5M BOP STACK DRAWING IS FOR REPRODUCTION OF THIS REPRODUCTION OF THIS A-000-75-002 REFAND OR DRgNANG WIT E%PRESg "`9"11"'-"' OM1M1N 0_TE SCALE WfWHT REV IS NOT AND IS NOT FOR CONSTRUCTION. OF ENERG SE oP ESOOR N CORP18 ^a"'�°� ^<^ TV 26/L_22018 N.T.S. O INITIAL RELEASE TY MJP 01 REV DESCRIPTpN BY APPD DATE DATE gpPROVEO MJP DATF SIZE 01/Mad2078 A SHEET i OF 1 ST£RGYgERWCEg STRICTLY PROHIBITED. 1 2 3 4 ap k i I! t 13 5/5n• SPoOL i] w RNtL Tyr IJ 5n' w nAIYiD f10110Y f111M(E UE J-I(e• w nNcm ,wllw GlE WlK SPGR SIVOL 11/e w ruxsen IflCr/lN0 G1E wa5c i4 t] 5/5" w fl/IQ to .r-I/e' w rwl wsE tJ s/e• w rWAfn eonw 13 v SIIIooFD ,mwid m sSW w neilCFn mr WSW gwtm eoiio,I Cf]1M Me'efll IiEN tlS6%tW.tRl1! Ne' f1Ji MIEWIfF dlY ! NIE Lgln SPoOL /�FJGY OF➢nOOlf q1 OPEAI�RMS It• w AMwO IOP IIEOINItnEt115 I I• w riw�csn iloiiw Gen RM Assaw II• w nnmFn IOP 6012 BOP STACK (DRAFT Dula m 5eex MIrE urauY eor ,s -5n' w srSPu ur ,}sn' w siwxn for i»n' w rwicm Iona Iwl tws IpP, is s/e• w IqI Bots Doses BOP u 5Po' w ulnen ,ar is sn• w item Ilorlo R/ s-i/Y W Iwsw. Ings r/ tt' eooSIER ,l 5n' w Snmen 1aP is 5n' w nwao Ilvrtw Y (s) J in• w Joe Q1R£15 M u z-Vlr w FlflI Rosi 2-1/1e• w C }I/r w M5 YIlr w nwlvn I GIF: w w ]-In• w FlMei➢ InOPnAn Gx ww: Mt W. ,J 5/r w W M2 musW 1J5/rwm w t] 5/5• w nexun ImemY 8.3.17 L. C.) IaP or sown Te5(t cn tmi rrE sus e]nm ro ]i[ IIOROY of TIt naeos � _. _ _ - - - 3] /orw o+d orl raps e5aeas s,NeiR sK IIF31 IIp1 iiRL 95115Y as sooxe Soul ,r w ilrca. ,r w InpR - - r ravc ru alntn (an a n _. •. _ tr alae JFn.-o-GIP ap k i I! t 13 5/5n• SPoOL i] w RNtL Tyr IJ 5n' w nAIYiD f10110Y f111M(E UE J-I(e• w nNcm ,wllw GlE WlK SPGR SIVOL 11/e w ruxsen IflCr/lN0 G1E wa5c i4 t] 5/5" w fl/IQ to .r-I/e' w rwl wsE tJ s/e• w rWAfn eonw 13 v SIIIooFD ,mwid m sSW w neilCFn mr WSW gwtm eoiio,I Cf]1M Me'efll IiEN tlS6%tW.tRl1! Ne' f1Ji MIEWIfF dlY ! NIE Lgln SPoOL /�FJGY OF➢nOOlf q1 OPEAI�RMS It• w AMwO IOP IIEOINItnEt115 I I• w riw�csn iloiiw Gen RM Assaw II• w nnmFn IOP 6012 BOP STACK (DRAFT Dula m 5eex MIrE urauY eor ,s -5n' w srSPu ur ,}sn' w siwxn for i»n' w rwicm Iona Iwl tws IpP, is s/e• w IqI Bots Doses BOP u 5Po' w ulnen ,ar is sn• w item Ilorlo R/ s-i/Y W Iwsw. Ings r/ tt' eooSIER ,l 5n' w Snmen 1aP is 5n' w nwao Ilvrtw Y (s) J in• w Joe Q1R£15 M u z-Vlr w FlflI Rosi 2-1/1e• w C }I/r w M5 YIlr w nwlvn I GIF: w w ]-In• w FlMei➢ InOPnAn Gx ww: Mt W. ,J 5/r w W M2 musW 1J5/rwm w t] 5/5• w nexun ImemY 8.3.17 L. C.) BP EXPLORATION (ALASKA) INC., PRUDHOE BAY UNIT 04-01A (207-03S) PRUDHOE BAY, PRUDHOEOIL ProductionMonthly 1 r�� 'rr "CZ,- 1,000,000 .0 c O CL 100,000 LL 0 y 10,000 m _ c 0 0 O m LL o 1,000 u Z 7 V vOm 100 3 0 r 10 1 Jan -2005 Jan -2007 Jan -2009 Jan -2011 Jan -2013 Jan -2015 Jan -2017 Jan -2019 e Produced Gas (MCFM) - GOR . Produced Water (BOPM) o Produced Oil (BOPM) 10,000,000 1,000,000 O 0 100,000 0m 3 0 10,000 T 0 1,000 0 d N 100 m 0 10 s SPREADSH EET_2070350_PBU_04-01A_P rod -I nject_Cu Nes_Wel I_Oil_V 120_20190515.xlsx 5/16/2019 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS EUtZ0Vcv R, 7 901Q 1. Operations Performed Abandon ❑ Plug Perforations 0 Fracture Stimulate ❑ Pull Tubing ❑ Operations shutdown Suspend ❑ Perforate ❑ Other Stimulate ❑ Alter Casing ❑ Change Approved Program 6.'e❑ Plug for Rednil ❑ Perforate New Pool ❑ Repair Well ❑ Re-enter Susp Well ❑ Other: Secure Reservoir 0 2. Operator Name: SP Exploration (Alaska), Inc 4. Well Class Before Work Development 0 Exploratory ❑ 5. Permit to Drill Number: 207-035 3. Address: P.O. Box 196612 Anchorage, AK 99519-6612 1 Stratigraphic ❑ Service ❑ 6. API Number: 50-029-20078-07-00 7. Property Designation (Lease Number): ADL 028325 & 028324 = 8. Well Name and Number: PBU 04-01A 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pools: PRUDHOE BAY, PRUDHOE OIL 11, Present Well Condition Summary: 3892, 8954, Total Depth: measured 11374 feet Plugs measured 9530, 10720 feet true vertical 8995 feet Junk measured None feet Effective Depth: measured 3892 feet Packer measured 8930, 9063 feet true vertical 3052 feet Packer true vertical 8278.8396 feet Casing: Length: Size. MD. TVD: Burst'. Collapse: Structural Conductor 80 30" 31 - 111 31 - 111 880 Surface 1154 20" 31 -1185 31-1185 1530 / 2320 520/1500 Intermediate 2657 13-3/8" 29-2686 29-2666 4930 2670 Production 9252 9-5/8" 26-9278 26-8587 6870/6820/7510/8150 4760/3330/4130/5080 Liner 2386 3-1/Z'x 3-3/16" x 2 8983-11369 8325-8994 Perforation Depth. Measured depth: 9300-11300 feet True vertical depth: 8606-8984 feet Tubing (size, grade, measured and We vertical depth) 4-112" 12.6# x 5-1/2" 17# 13Cr80 / L-80 24-9184 Packers and SSSV (type, measured and 4-1/2" Baker S-3 Hydro Set Packer 8930 8278 true vertical depth) 5-1/2" Baker FB -1 Packer 9063 8396 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas-Mcr Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: 490 21603 12034 1576 934 Subsequent to operation: Shut -In 14. Attachments: pecmree Per 20 rac 25.070 25, 071, a 252831 15. Well Class after work: Daily Report of Well Operations 0 Exploratory ❑ Development 0 Service ❑ Stratigraphic ❑ Well Status after work. Oil 0 Gas ❑ WDSPL ❑ Copies of Logs and Surveys Run ❑ 16. Printed and Electronic Fracture Stimulation Data ❑ 1 GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP ❑ SPLUG ❑ 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 319-009 Authorized Name: Worthington, Area J Contact Name: Worthington, Area J Authorized Title: Interventions & Integrity Engineer Contact Email: Aras.WorthingtonAbp.com Authorized Signature: Date:/� f Contact Phone: +1 907 564 4102 Form 16404 Revised 04/2017Me (Rxw# A? Submit Original Only /lr���y �BDMS��MAY 0 8 2019 T/I/O/00 = 350/350/0/0. Temp = SI. WHP's (post bleed). SV and WV LOTO. No AL, flowline or wellhouse. Temporary scaffold installed. TP obtained via flow cross. TP & IAP increased 40 psi from 1/23/19. 1/31/2019 SV, WV = LOTO. SSV = C. MV = 0. IA, OA, OOA = OTG. 22:00. T/I/O/00 = 400/400/3/1. Temp = SI. WHPs (post bleed). No AL, flowline, or wellhouse. Temporary scaffolding around wellhead. TP and IAP increased 50 psi, OAP increased 3 psi, and OOAP increased 1 psi since 01/31/19. 2/11/2019 SV, SSV = C. WV = LOTO. MV = O. IA, OA, OOA = OTG. 01:00 T/I/O = 440/440/4/2. Temp = SI. WHPs (post bleed). No AL, flowline, or wellhouse. Hardline rigged up from IA casing valve to 04-40 wellhead. Temporary scaffolding around wellhead. TP and IAP increased 40 psi, OAP increased 1 psi and OOAP increased 1 psi since 02/11/19. 2/19/2019 SV, SSV = C. WV = LOTO. MV = O. IA, OA, OOA = OTG. 15:00 T/I/O/00 = 1580/270/4/2. Temp = SI. TBG, IA, OA FL's (Slickline request). TBG FL @ 8100' (123 bbls). IA FL @ 5651' (Sta #4, SO, 302 bbls). OA FL @ Surface. 2/20/2019 Slickline in control of well. TWO = 376/376/10 Assist Slickline (Circ out TBG & IA down 04-40 FL) Circ TBG & IA down TBG up IA to well 04-40 FL to circ out. Pumped 5 bbls 60/40 meth spear followed by 53 bbls FW surfractant, followed by 633 bbls 9.8 brine. pumped 6.5 bbbls 60/40 methanol down TBG, shut in outlet well and U-Tube TBG & IA to FP for 45 min. Pumped 4.8 bbls 60/40 meth for pretest. Took Tbg/IA to 2205/2175 psi on 2nd test. Tbg/IA lost 71/51 psi in the 1st 15 mins, 50/50 psi in 2nd 15 mins and 46/47 psi in 3rd 15 mins for a total loss of 2/20/2019 167/148 psi in 45 min pretest. ***Job Cont to 02-21-2019 WSR*** ****WELL S/I ON ARRIVAL****(reg comp) SET 4-1/2" WHIDDON CATCHER AT 8942' SLM. PULL RK-DGLV FROM STA 1 @ 8839' SLM AND LEFT POCKET EMPTY. PULL 4-1/2" WHIDDON CATCHER FROM 8942' SLM. LRS CIRC OUT T X IA WITH 620 BBLS 9.8 BRINE (see LRS log) 2/20/2019 ****CONT WSR ON 2-21-19**** ***Job Cont from 02-21-2019 WSR*** Pumped 7.6 bbls 60/40 meth down Tbg for AOGCC CMIT-TxIA. Took Tbg/IA to 2485/2443 psi. 1st 15 mins Tbg/IA lost 90/82 psi, 2nd 15 mins g ost /66 psi and 3rd 15 mins Tbg/IA lost 68/70 psi for a total loass of 229/218 psi during 45 min test. CMIT-TxIA PASSED at 2256/2225/17 AS PER AOGCC EQUIREMENTS (AOGCC Re Matthew Herrera) . Bled back -7.6 bbls. SSL on well at 2/21/2019 a arture FWHP:877/867/10 ****CONT WSR FROM 2-20-19****(reg comp) TAG 4-1/2" XX-PLUG W/ 2' 1-7/8" STEM, 3.625" CENT, 3.50" LIB @ 8954' MD. (flag wire 8920' MD)**STATE WITNESSED** LRS PER RM PASSING CMIT TxIA AS PER AOGCC REQUIREMENTS (SEE LRS LOG) **STATE WITNESSED** DRIFT TO 8932' SLM W/ 3.805" GAUGE RING. BAILAT 8939' SLM W/ 10'x3.0" PUMP BAILER, REC 5 CUPS OF PARAFFIN. ****WELL S/I ON DEPARTURE, DSO NOTIFIED**** 2/21/2019 ***UNABLE TO PERFORM TUBING PUNCH DUE TO MANPOWER ISSUES*** T/1/0=680/72010. Temp = SI. WHPs (WIE Req). No Flowline, AL or Well house. Temp scaffolding & secondary containment installed around tree. 2/26/2019 SV, WV, SSV = C. MV = O. IA, OA = OTG. 00:15 1PT'd.. T/1/0=300/0/0 R/D production tree, R/U Dryhole tree Temp #04. Torqued to API specs. 2/27/2019 see "Field Charted tests" FWP's 300/0/0 see log for details. Daily Report of Well Operations 04-01 A TWO = 640/630/0+. Temp = SI. WHPs (WIE Req). Dryhole tree installed. Wellhouse removed. Temporary scaffolding & secondary containment installed. T FL @ surface. IA FL @ 190'(11 bbls). TP decreased 40 psi, IAP decreased 90 psi from 2/26/19. 3/2/2019 SV,= C. MV = O. IA, OA = OTG. 22:30 T/I/O = 240/400/0+. Temp = SI. WHPs (WIE Req). Dryhole tree installed. Wellhouse removed. Temporary scaffolding & secondary containment installed. T FL @ surface. IA FL @ 352'(19 bbls). TP decreased 400 psi, IAP decreased 230 psi from 3/2/19. 3/7/2019 SV= C. MV = O. IA, OA = OTG. 14:20. T/I/O/00 = 150/350/4/3. Temp = SI. TBG / IA FL (WIE Req.) Dryhole tree installed. No AL, flowline, or wellhouse, Tbg FL @ surface. IA FL @ 415'(22 bbls). TP decreased 90 psi, IAP decreased 50 psi and IA FL fell out 63' since 03/07/19. 3/10/2019 SV = C. MV = O. IA, OA, OOA = OTG. 08:30 T/1/0/00 = Vac/270/0+/0+. Temp = SI. WHPs (WIE request). No AL, Wellhouse or scaffolding. Dryhole tree installed. TBG FL @ Near Surface. IA FL @ 570' (30 bbls). The IA FL depressed 155', TP went on a vac, IAP decreased 70 psi, OAP and OOAP remained 3/17/2019 unchanged since 3-10-19. SV = C. MV = O. IA, OA, OOA = OTG. 16:00 ***WELL S/I ON ARRIVAL ***(P&A) DRIFTED TBG W/ 3.48" CENT TO XX PLUG @ 8954' MD. RAN SLB E-FIRE & TBG PUNCH, PUNCH TBG FROM 8920-8925' MD. 3/20/2019 ***WELL S/I ON DEPARTURE, DSO NOTIFIED OF WELL STATUS*** T/I/O/00 = 0/270/0+/0+. Temp = SI. TBG/IA FL's (WIE request). No AL, Wellhouse or scaffolding. Dryhole tree installed. TBG FL @ Near Surface. IA FL @ 630' (34 bbls). The IA FL depressed 60'. TP, IAP, OAP and OOAP remained unchanged since 3-17-19. SV, 3/23/2019 MV = C. IA, OA, OOA = OTG. 21:00 T/1/0/0=200/255/10/0 Temp=Sl (LRS Unit 46 -Assist SLB Cement Crew: Balance Cement Plug) Pump the following down the Tubing, Up the IA to 04-40's Flowline: 5 bbis of 60/40 spear. SLB pumped Freshwater, Cement, and Foam Balls 64 bbis of Brine 10 bbis of 60/40 meth. U-Tube between TxIA (2 bbls TBG/8 bbls IA) for Freeze Protect. Bled TBG and IA to 0 psi. Freeze Protect Outlet Well 04-40's Flowline w/ 2 bbls 60/40 and 48 bbls crude. Hang FP tags on 04-01 MV and IA CV and 04-40 WV. Valve Positions=SV SV MV closed CVs OTG Hardline SI 3/29/2019 FWHP=0/0/0/0 ***SLB Fuilbore Pumping Crew*** Job Scope: Plug and Abandonment w/balanced cement plug TBG x IA Pumped 5 bbis 60/40 meth, 3 bbis freshwater spacer, 304 bbis of 15.8 ppg class G cement, 2 bbis freash water and shut down pumping. Lined up to launch two six inch foam balls behind cement. Back on line w/64 bbis 9.8 ppg NaCl, 10 bbis of 60/40. Line up TBG & IA to Utube 60/40 into IA. Freeze protected flowline on 04-40 15.8 ppg Class G cement in TBG & IA. Cement top @ 4500' MD / 4398' TVD Bottom of cement 8925' MD 3/29/2019 '"*Job Complete*** T/I/O/00 = 5/50/5/3. Temp = SI. TBG & IA FL (WIE request). No wellhouse, AL or flowline. Temporary scaffolding installed. TBG FL @ near surface. IA FL @ near surface. 3/31/2019 T/I/O/00 = Vac /50/5/0+. TBG & IA FLs (WIE request). No wellhouse or flowline. TBG FL @ near surface. IA FL @ near surface. 4/6/2019 SV, MV = C. IA, OA, OOA = OTG. 14:50 Daily Report of Well Operations 04-01 A ***WELL SHUT IN ON ARRIVAL*** (plug and abandonment) DRIFT 2.5" CENT, S.BAILER & TAG TOC @ 3892' SLM RUN PDS CALIPER LOG FROM 3816' SLM TO SURFACE 4/10/2019 ***CONT. TO 4/11/19 WSR*** ***CONT. FROM 4/10/19 WSR*** (plug and abandonment) RIG DOWN EQUIPMENT FOR WEATHER. 4/11/2019 ***JOB POSTPONED DUE TO HIGH WINDS*** T/1/0=54/54/vac/vac Temp=S/I (LRS Unit 70- Assist HES-Relay Unit: State Witnessed CMIT-TxIA/ P&A) Pre AOGCC CMIT-TxIA FAILED @ 2670/2497 psi. Max applied =2750 psi. Target pressure= 2500 psi. Pressured T/IA to 2719/2715 with 4.63 bbls 60/40 meth. 1st 15 min T/IA lost 25/114 psi 2nd 15 min T/IA lost 24/104 psi for a total of 49/218 psi during 30 min test.Bled T/IA to 67/71 psi recovering— 2.9 bbls See log for details on previous pre test. AOGCC CMIT-TxIA FAILED @ 2647/2454. Max Applied =2750 psi target psi= 2500 psi Pressured T/IA to 2724/2714 psi with 2.9 bbls 60/40 meth 1 st 15 min T/IA lost 44/146psi 2nd 15 min T/IA lost 33/_114 psi 3rd 15 min T/IA lost 26/104 psi 4th 15 min T/IA lost 26/94 psi. rest ran in per state witness (Brian Bixby) Bled T/IA to 45/49 psi rcovering — 3.2 bbls. Pumped 2.5 bbls 60/40 MW down TBG/IA in attempt to achieve a passing CMIT-TxIA. Bled T/IA to 45/49 psi, recovering — 2 bbls 4/14/2019 1 SV MV= closed. IA OA ODA= open. Final Wh 's=45/49/0/vac ***CONT. FROM 04/10/2019 WSR*** (plug & abandonment) CMIT-TxIA FAILED (STATE WITNESS BY BRIAN BIXBY) RIH W/ 2.5" CENT, & 1.75" SAMPLE BAILER AND TAGGED TOP OF CEMENT @ 3895' SLM. (STATE WITNESSED BY BRIAN BIXBY/BOB NOBLE)... CEMENT SAMPLE 4/14/2019 RECOVERED T/I/O/00 = 130/200/5/3. Temp = SI. TBG & IA FLs (WIE request). No wellhouse or flowline. TBG FL @ 855' (13 bbls), IA FL @ surface. 4/15/2019 SV, MV = C. IA, OA, OOA = OTG. 03:30 T/1/0/00=60/110/0/0. Temp = Sl. TBG & IA FLs (WIE request). No wellhouse or flowline. TBG & IA FL's @ surface. TP decreased 70 psi, IAP decreased 90 psi, OAP decreased 5 psi, OOAP decreased 3 psi from 4/15/19. 4/23/2019 SV, MV = C. IA, OA, OOA = OTG. 04:40. T/I/O/00 = 40/100/3/3. Temp = SI. TBG/IA FL (WIE Req). No wellhouse or flowline. Temporary scaffolding. TBG FL @ surface & IA FL @ near surface. TP decreased 20 psi, IAP decreased 10 psi, OAP and OOAP increased 3 psi since 4-23-19. 5/1/2019 SV, MV = C. No SSV. IA, OA = OTG. 17:00 WELLH6ID= MCEVOY ACTUATOR= R13MED OKB. ELEV SHOT SOZ FIEF ELBl 6 BF. EUB/ = 35.3' KOP= 3200' Max Angle = 91' @ 10041' Datum MD= 10676' DabmTVD= B800'SS V CSG, 94#, 1-40/133#, K-55 D =18.750' 9-5/8' CSG, 47,1 80. D = 8.681" Minimum ID = 2.380" @ 10058' 33/16" x 2-718" XO 4A2• TBG PUNCH (032o/19) N 8920• - $926' 4-12" TBG, 12.6# 13CR90 VAM, .0152 bpf. D= 3.958' bpf, D = 2.992• = 4.892" .0732 bpf, D = 8.681 • PERFORATION SUMMARY FEF LOG: CNL ON 05/16/07 ANGLE AT TOP PERF: 34" @ 9300" Note: Refer to Production OB for historical perf data SIZE SPF INTERVAL Opn1Sgz SHOT SOZ 2" 6 9300-9330 C 0423/15 2" 6 9382-9397 C 0423/15 2' 6 9408-9425 C 0422/15 2-1/2" 6 9464-9469 C 10/10/09 2-12• 6 9452-9457 C 10/10/09 2' 6 9970-10020 C 05/17107 2• 6 10500- 10650 C 05/17107 2" 6 10770-10800 C 05/17107 2" 6 10895 - 11300 C 05/17/07 SAFETY NOTES: WELL REQUIRES A SSSV '••4-1/2" 04-01 A CHROME TBG- WELL ANGLE >70- @ 9592' ••" DEFTHS MEASURED WITH I -COIL DURING 5/2007 CTD (04-01A) ^• —IFE 2169' 4-12" HES I3CR X NIP, 1) GAS LIFTMANDRELS 'GLM BEHIND ESTIMATED TXIA CMT 0329119 3892' -8925• EST TXW TOC (03/29/19) SUM TXIA TOC (04/10/19) 890.9' 4-12" HES X NP, D = 3.813' $830' 01/10!71 9-5/8" X 4-12' BKR S3 HYDRO WJ;4 D = 3.875" ST MD TVD DEV TYPE VLV LATCH PORT DATE 5 3231 3227 11 MMG DOME RK 16 06/19107 •4 5651 5414 30 MMG SO RK 20 06/19/07 •3 7396 6917 28 MMG DMY RK 0 04/26/07 2 8140 7571 28 MMG DMY RK 0 04/26/07 •1 8838 8196 26 MMG EMPTY - 0220119 'GLM BEHIND ESTIMATED TXIA CMT 0329119 3892' -8925• EST TXW TOC (03/29/19) SUM TXIA TOC (04/10/19) 890.9' 4-12" HES X NP, D = 3.813' $830' 01/10!71 9-5/8" X 4-12' BKR S3 HYDRO WJ;4 D = 3.875" n� a_�n•ucsv Na n=a n�a• 9077' "4-12- X 5-1rZ- XO, D = 3.958- tB99ND LNR) 9029' 9-5/8"X4-12"UNDUE OVERSHOT 9040' 3-12"X3-3116' XO, D = 2.7x6" BEHIND 9069' 5-12BKR SEAL ASSY CT LNR 9063' 9-S/8' X 5-12" BKR FB -1 PKR w /SEALBOR EXT 9172'-11 5-12' OTIS XN NO-GO NP, D = 4.45' (CMTD 03108107) 9183' 5-12' BKR SHEAROUT SUB BEHIND 91BW 5-12' TUBING TAL (CMT"D1 CT LNR MILLED WINDOW (04-01A CORRECTED) 9278' - 9287' LNR 6.2#, L-80 TCII, >f. D = 2.80" LNR DATE REV BY COMMENTS DATE REV BY COMMENTS 01/10!71 ORIGINAL COMPLETION 1127/18 JNJJMD ADDEO REF, BF, & COPD DEPTH 07107/90 RWO 0225/19 CJNJM) GLV C,O (0220/19) 0427107 00FRMODIC RWO 0228/19 KP/JMD DRY HOLETREE OW18/OTNOImIC CTD SIDETRACK (04-01A) 0321/19 M�JA�D TBG PUNCH (03/20119) 0725/17 3.HJMJ ADDED 30" COPD & 20" CSG 0422!19 J Tx W CMT PLUG (0329/19) 7 M 1023/1GS/J PULLED K VALVE/SEF XX PLUG 05/07/19 JNJJM) TXW SUM MEASURED TOC DMH ID = 2.380' I'BTD 11336"` PRUDHOE BAY UNIT V*LL 04-OIA PERW No: 1070350 API No: 50-029-20078-01 SEC 34, T11 N, R1 5E, 1327' FPL & 295' FEL 812 E1ipkfration (Alaska) MEMORANDUM TO: Jim Regg P.I. Supervisor FROM: Brian Bixby Petroleum Inspector State of Alaska Alaska Oil and Gas Conservation Commission DATE: April 14, 2019 SUBJECT: Well Bore Plug & Abandonment PBU 04-01A BPXA PTD 207-035; Sundry 319-009 Section: 34 Township: 11N Range: 15E Meridian: Umiat Drilling Rig: n/a - Rig Elevation: Operator Rep: Brenton Nicholson Casing/Tubing Data (depths are MD) Conductor: 30" - O.D. Shoe@ Surface: 20" -O.D. Shoe@ Intermediate: 13 3/8" O.D. Shoe@ Production: 9 5/8" O.D. Shoe@ Liner: 3 1/2" x 2 7/8" O.D. Shoe@ Tubing: 41/2" -O. D. Tail@ Plugging Data: Test Data: n/a Total Depth: 11374 ft MD ' Lease No.: ADL 28325 - Suspend: P&A: XXX 111 • Feet 1185 Feet 2686 Feet 9278 _ Feet 11369 - Feet 9184 Feet Casing Removal: Csg Cut@ Feet Csg Cut@ Feet Csg Cut@ Feet Csg Cut@ Feet Csg Cut@ Feet Tbg Cut@ Feet Type Plug Founded on Depth Btm Depth To MW Above Verified Fullbore Bridge plug 3895 ft MD 9.8 ppg brine Wireline tag 2454 2350 2256 OA 0 0 0 0 0 Initial 15 min 30 min 45 min 60 min Result Tubing 1 2724 2680 2647 - 2621 2595 IA 2714 - 2568 2454 2350 2256 OA 0 0 0 0 0 Remarks: Sundry 319-009 (revised 3/5/2019) limits P&A work to installation and verification of Plug #1 to facilitate decompletion at a later date. The MIT was a combination tubing and IA test - inconclusive due to pressure loss and lack of stabilization. I witnessed a good hard cement tag in the tubing with slickline at 3895 ft (slickline measurement) but it tagged higher than the planned 4500 ft noted in the revised sundry approval. They are going to regroup and discuss the path forward. Attachments: 4/17/2019 Email with Revised Sundry 319-009 Approval rev. 11-28-18 2019-0414_Plug_Verification_PBU_04-01A_bb J P6A 04-o IA- Regg, James B (DOA) Pri) Z07&35 u From: Bixby, Brian D (DOA) Sent: Wednesday, April 17, 2019 4:54 PM To: Regg, James B (DOA) Subject: Fwd: Sundry Modification - Well 4-01 Attachments: 04-01 P&A Program Rev 2.doc; ATT00001.htm; ATT00002.htm Jim, I'm sure you have already got these but I said I would send them to you! Brian Sent from my iPhone Begin forwarded message: From: "Nicholson, Brenton Todd" <Brenton.Nicho!son@bp.com> To: "Bixby, Brian D (DOA)" <brian.bixbv@a!aska.gov> Subject: FW: Sundry Modification - Well 4-03 Brian, See attached Revision, the 4500' cement is under the Fullbore section and the approval from Mel is below. Please let me know if you need any more information. Thanks, Again! From: Rixse, Melvin G (DOA) <melvin.rixse@alaska.gov> Sent: Tuesday, March 5, 2019 3:52 PM To: Worthington, Aras 1 <Aras.Worthington@bp.com> Cc: Montgomery, Travis 1 <Travis. Montgom ery@bp.com>; Hibbert, Michael <Michael.Hibbert@BP.com>; Schwartz, Guy L (DOA) <guy.schwartz@alaska.gov> Subject: FW: Sundry Modification - Well 4-01 Aras, For well PBU 04-01: AOGCC will request to have witnessed tag and pressure test of the top of the cement plug placed at —4500'. AOGCC will also approve a GR/Caliper log of the production tubing above the cement plug. Mel Rixse Senior Petroleum Engineer (PE) Alaska Oil and Gas Conservation Commission 907-793-1231 Office 907-223-3605 Cell CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Mel Rixse at (907-793-1231) or (Melvin. Rixse@alaska.e.ov). cc. Travis Montgomery, Michael Hibbert, Guy Schwartz From: Rixse, Melvin G (DOA) Sent: Monday, March 4, 2019 11:27 AM To: Hibbert, Michael <Michael.Hibbert@bp.com> Cc: Guy L Schwartz (DOA) (guy. schwa rtz@aIaska.gov) <guy.schwartz@alaska.gov>; Worthington, Aras 1 <Aras. Worthington@bp.com> Subject: FW: Sundry Modification - Well 4-01 Michael, BPXA has AOGCC approval to punch tubing from 8920'-8925' MD then circulate cement into the tubing with returns up the IA placing TOC at -4500' in both the tubing and IA to secure well 04-01A. A modified sundry will be required for additional P&A work on this well. Mel Rixse Senior Petroleum Engineer (PE) Alaska Oil and Gas Conservation Commission 907-793-1231 Office 907-223-3605 Cell CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Mel Rixse at (907-793-1231) or (MeI_vin_Rixse alaeka.¢ov). cc. Guy Schwartz, Aras Worthington From: Hibbert, Michael <Michael.Hibbert[a@BP.com> Sent: Thursday, February 28, 2019 2:38 PM To: Rixse, Melvin G (DOA) <melvin.rixse@alaska.gov> Subject: Sundry Modification - Well 4-01 Hi Mel, Here is the updated program to place a reservoir cement plug above the packer on 4-01. BP wants to proceed with this cement plug due to a history of repressurization. The remainder of the P&A plan will be submitted after the AOGCC has made a final ruling on Docket OTH-18-064. Let me know if you have any questions. Thanks, Michael Hibbert BP Alaska - �Intervention & Integrity Engineer �� I F-1 Email: Michael.Hibbert@bp.com Prsu o4 --cls 944fP&A Rev 2 514,9 Intervention Engineer Michael Hibbert (907) 564-4351 Production Engineer Meredyth Richards (907) 564-4867 2f77[73St? 5�i+d� SO -001 History 04-01A was completed in 1971 with a Gen 1 wellhead and three string casing design. The outer casing string is set in permafrost. GWO has determined that these wells are at risk for sudden wellhead movement, as demonstrated by 02-03A and 02-02A. As such, the AOGCC has requested this well be plugged and abandoned to mitigate HSSE consequence associated with this potential risk. Objective Place lower cement plug in the wellbore. The cement top in the tubing and IA will be at 4500' MD. This depth was selected to bring the cement up to and across a significant portion of the 9-5/8" cement that only is present from 4040' MD to 5966' MD. This P&A was designed to conform to BP Practice 100221: Zonal Isolation and BP Alaska's deviations captured in eMOC 10439. Procedural steps Slickline/Fullbore � 7 IXMT TT. WATNVlc.�eieYTe7�,TJ■ __ 10 __ Z Met _•• 2 r". This steps are striked because they have already been completed. Slickline 5. MU 5' tubing punch and punch from 8920'- 8925' MD. (This step may be moved to E -Line if E -fire is not available). JV- - k\�` V" Fullbore 1. Pump cement job down tubing with returns from IA. The top of cement in the IA will be at 4500' MD and at —4500' MD in the tubing. Keep track of brine returns from the IA if practical. Maximum tubing pressure 2500 psi. ➢ 5 bbls MEOH ➢ 3 bbls FW spacer ➢ 304 bbls of Class G cement per design ➢ Foam wiper ball ➢ 2 bbls FW spacer 64 bbls 9.8 ppg brine 10 bbsl of 60/40 U -tubed into tubing and IA (2 bbls into the tubing and 8 bbls into the IA) Cement Type/weight: Class G 15.8 ppg mixed on the fly. Field blend to be =lab ppg +/- 0.1 ppg Pressure Slurry Temperature: between 800 and 110°F 0 Fluid Loss: 40-200cc (20-100cc/30 min) 3000 Compressive Strength: 2000 psi in 48 hrs. 2500 Thickening Time: I Minimum 5 hours 2000 Cement Ramp for Blend Time Temp Pressure 0:00 90 0 1:00 130 3000 2:00 120 2500 3:00 110 2000 4:00 100 1500 7:00 80 1000 15:00 40 0 Fullbore 1. M to 2500 psi Gvt,--- rkTA Slickline 2. Tag TOC. Remainder of P&A to be resubmitted after AOGCC final ruling on Docket OTH-18-064. VVEL.LHEAD= MCEVOY ACTUATOR= AXB.SON OK8 EEV = 64' BF BEV ? KP 3200' Max Angle - 91" @ 10041' Datum MD 10676' Datum TVD = 8800'SS DS O4-01 Current Status OTES: WELL REOUIRESA SSSV —4-12" 3D' COND -{ TBG"' WELL ANGLE >70' @ 9592' —DEPTHS MEASOREO WITH I -COIL DOPoNG 52007 CTO (04-01AI — 20' CSG, 94#, 11 MD 1+40/133#, K -55D=18.750' DEV 2159' I 4-12' HES I3CR X NR D=3.813'9-5/8' CSG,47#, 24 ISG PORT L -8o, ID GAS LFT MANDI;EL.S N80, D= 12.347' 2686' .0152 bpf, D=3.958' SPF 41/2' TBG STUB (04126/07) , ST MD TVD DEV TYPE VLV LATCH PORT DATE 4 3 2 1 3231 5651 7396 8140 8838 3227 5414 6917 7571 8196 11 30 28 28 26 tMfJIC MW MVAC MMG AMC CDA£ SO DMY Ow DW RK R( RK RK RK 76 20 0 0 0 06119107 19/07 26/07 28/07 :04r26107 9464-9469 O 10/10/09 Minimum ID = 2.380" @ 10058' 3-3116" x 2-718" XO 41/7 TBG, 12.6# 13CRBD VAM, I-1 9077 LNR 47#, SIX fEFtFORATION SLAOARY REF LOG: CN- ON 05/16/07 ANGLEAT TOP PERF: 34' @ 9300' Note: Refer to Production DB for historical perf data .0152 bpf, D=3.958' SPF 41/2' TBG STUB (04126/07) 8022' SOZ 2' 904W 3-117 LNR, 8.81#, LBO STL, .0087 bpf, D = 2.992' 9172' TOP OF MILLED CMT (DMS D429/07) "9186' 9382-9397 O 0123/15 15-1/2- TBG, 17#, L-80 Po, .0232 bpf , ID - 4 892' 9104' LNR 47#, SIX fEFtFORATION SLAOARY REF LOG: CN- ON 05/16/07 ANGLEAT TOP PERF: 34' @ 9300' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL OprVSgz SHOT SOZ 2' 6 9300-9330 O 0423/15 9172' 7 6 9382-9397 O 0123/15 S12' BKR SFEAFROITf S118 BEHIND 2' 6 9408-9425 O 0422/15 MILLED WINDOW (04-01A CORRECTED) 9278'-9287' 2-1/7 6 9464-9469 O 10/10/09 2-12' 6 9452-9457 O 10/10/09 2' 6 9970-10020 C 05117/07 2' 6 10500 - 10650 C 05/17/07 2' 6 10770-10800 C 05/17/07 2' 6 10895 -11300 C lYu/17ro7 9FT-7fY HES X NP, D = 3.813' X 4-12' BKR S3 HY DF HESX NP, D=3.813' XX RUG (1 =0117)] DEPLOY SLV w 14' GS 901-14-12- X 5-12' XO, D= 3.958' (BEHIND I" 9029' 9-5/9' X 4-12' UMOLIE OVERSHOT 9040' 31/2' X 3-3/16' XO, ID= 2.786' BEHIND 9059' 5-1/2-BKR SEAL ASSY CT LNR 9063'... 9 -SB' X 5-1/2' BKR FE -1 PKR w /SEALBOR B(T. 9172' S 12' 076 XN NO-GO NP, D = 4.4� 06118107 NORDIC2 CM (T'D03/6HI07) 9183' S12' BKR SFEAFROITf S118 BEHIND 9184' 5-12' Ti18NGTAIL (CM T'D) CT LNR IRDMTEDKVALVEw/PSI MILLED WINDOW (04-01A CORRECTED) 9278'-9287' 33/16' LIQ 6.240, L-80 TCA, 0076 hof. D= 2.80' D = 2.380- J i� 22�WP FSTv1-1 1335— L80 $TL, .0058 bpf, D = 2.441' 11 DATE FFV BY COMMENTS DATE FWV BY COMMENTS 01/10/71 ORIGINAL COMPLETION 06130/16 JTMJMD UPDATED PSI VALUE 07107/90 RWO 07125/17 RIWJMD ADDED 30'COND 820'CSG 0427107 NORDIC2 RWO 10/23/17 MGS/JM0 RAL® K VALVE/SE7 XX PLUG 06118107 NORDIC2 CTD SIDETRACK(04-04A) 02103/16 GRCMH K VLV UPDATE PER STATE PEGS 06/28/16 JAD IRDMTEDKVALVEw/PSI PRLUO IDE BAY lM WELL 04-01A PERMIT No `2070350 An No: 50-029-20078-01 T11 K R15F 1327' FNL 8 295' FEL BP Exploration (Alaska) TREE= M:EVOI WELLHEAD = MCEVOY ACTUATOR= AXELSON OKE. ELEV = 64' BE. ELEV = ? KOP= 3200' Max Angle = 91" WWW, Datum MD = 10676' Datum TVD = 8800'SS � DS 04-01 P&A Status NOTES: WELLREQUIRES A SSSV —4-112" "'NJ _ ME TBG" WELL ANGLE >TO -@9592' —DEPTHS MEASURE) WITH I -COIL DURING 512007 CTO (04-01A)— 1+40/133#.11) = 8.750K-55 I / Bi l J ' r- 2159' 4-12' HES l3CR X NP, 113=1813' Drilling (original) Cement: 9-5/8" Casing: est. 4040' MD to 5970' MD pumped through stage collar XXPwiC2 4bclb4,f2 _Yri-vacke-o 6g3,r -Ft 14-1'2*: 11r TBG, 12.6# "CReO VAM, 901T .0152 bpf®- 3.958' L4-1/2'TBGsTUB(04/28/07) 9022' 3-1/2' LNR, 8.81#, LBO STL, — 9040' .0087 bpf, D=2.992' = 4.892' B- LNR 47#, 500-95..0732 bpf, ID = 8.681' fBZ FORATION SUMMARY REP LOG: CW ON 05/16/07 ANGLEAT TOP PEW: 34' @ 9300' Note: Polar to Production DB for historical pert data SIZE SPF MEZVAL OprVSqz SHOT SOZ 2' 6 9300-9330 O 0423115 ?ATE r 6 9382-9397 O 0423/15 11 2" 6 9408-9425 O 0422/15 2-11T 6 9464-9469 O 10/10/09 5414 2-1/2' 6 9452-9457 0 10110/09 RK 2' 6 9970-10020 C 05117107 7396 2' 6 10500 - 10650 C 05/17/07 OW r 6 10770 - 10600 C 05/17/07 2 r 8 10895 - 11300 C 05/17/07 MMG D = 2.80' T ME) ND DEV nPE VLV LATCHRO064,r26fO7 9172' ?ATE 5 3231 3227 11 MT4G DOM£ RK 119107 4 5651 5414 30 MMG SO RK !19!07 3 7396 6917 28 MR1(' OW RK 26107 2 8140 7571 28 MMG DMI RK 26107 1 8838 8196 26 M G, OW RK First Cement Plug: TBG: 4500' MD to 8925' MD IA: 4500' to 8925' MD - 3 70' Dt�L.OV SL V w l A' GS Fl20HLE U=3 )7- 3-12' OTIS X PID', D = 2.813" �_.-. 902W —L9_5/6'%4_i/r UNIOLEOVHSHOT 9040' 312'X3-3/16'XO,ID=2.786" BEHIND 069' 5-1/2'BKR SEAL ASSY CT LNR 9063' 9-5/8' X 5-12' BKR FB -1 PKR w /SEALBOR TXT. 9172' 5-12' OTE; XN NO-GO NP, D = 4.45' 0427/07 NORDIC2 (cwtr 03/08/07) 9183' 5-12' BKR SFEAROt1T SLB BEHIND 9184' 5-trz- TUBNG TAL(CUT'D) CT LNR MILLED WINDOW (O4 -01A CORRECTED) 9278'- 9287' FBTD JL 6.16#, L80 STL, .0058 bpf, 0=2441- DATE D=2.441" DATE REV BY COM..94M DATE RH/ BY COMz£MS 01110/71 ORIGINAL COMPLETION 06/30)16 JTMJMD UPDATED PSI VALUE 07107190 RWO 07/25/17 RJWJMD ADDED 30' COND 820' CSG 0427/07 NORDIC2 RWO 10123/17 MGS1J&C PULLED K VALVESET XX PLUG 05118/07 NORDIC2 CTD SIDETRACK [04-01A) 02/03/16 GRCT1_H K VLV UPDATE PER STATEREGS 0628/16 JMD LIPDATEB K VALVE w/PSI I3-3/16' X 2-718' XO. O= 2.380' PRUDHOE BAY tNT WELL: 04-01A PERMIT No: `2070350 APINo: 50-029-20018-01 SEC 34, T11 N, RI 5F 1327' FNL 8 295' FEL BP Exploration (Alaska( MEMORANDUM TO: Jim Regg 76� wim P.I. Supervisor FROM: Matt Herrera Petroleum Inspector Section: 34 Township: Drilling Rig: NA Rig Elevation: Operator Rep: Rob Ryan Casing/Tubing Data (depths are MD): Conductor: 30" O.D. Shoe@ Surface: 20" O.D. Shoe@ Intermediate: 13 3/8" O.D. Shoe@ Production: 9 5/8" O.D. Shoe@ Liner: 31/2"x27/8"-O.D. Shoe@ Tubing: 5 1/2" x 4 1/2" -O.D. Tail@ Plugging Data: Test Data: State of Alaska Alaska Oil and Gas Conservation Commission DATE: February 21, 2019 Tvoe Plua SUBJECT: Plug Verification De th Btm Depth To MW Above PBU 04-01A ' Tubing Bottom 8954 ft MD BPXA - NA Wireline tag OA PTD 2070350; Sundry 319-009 11N Range: 15E Meridian: Umiat - NA Total Depth: 11369 `A46 V Lease No.: ADL 028325 Suspend: P&A: X Casing Removal: 111 Feet Csg Cut@ Feet 1185 Feet CSg Cut@ Feet 2686 - Feet Csg Cut@ Feet 9278 Feet Csg Cut@ Feet 11369 Feet Csg Cut@ Feet 9184 - Feet Tbg Cut@ Feet Tvoe Plua Founded on De th Btm Depth To MW Above Verified Tubing Bottom 8954 ft MD 8954 ft MD NA Wireline tag OA 16 16 17 17 Initial 15 min .10 min d5 min Racial+ Tubing 2485 2395 1 2324 2256 IA 2443 2361 2295 2225 P OA 16 16 17 17 initial 15 min 30 min 45 min Result Tubing IA OA Remarks: PBU 04-01A is completed with a Gen 1 wellhead 3 string casing design and has been determined a risk for sudden upward wellhead movement. Well to be P&A per Sundry 319-009. Combo MIT TAA was performed with top four gaslift mandrels open. Test pumped 7.7 bbl, returned 7.6 bbl fluid. Attachments: none rev. 11-28-18 2019-0221_Plug_Verification_PBU_04-01A_mh THE STATE °fALASKA GOVERNOR MIKE DUNLEAVY Aras J. Worthington Interventions & Integrity Engineer BP Exploration (Alaska), hie. P.O Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Prudhoe Oil Pool, PBU 04-01A Permit to Drill Number: 207-035 Sundry Number: 319-009 Dear Mr. Wothington: Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 w .aogcc.alaska.gov Enclosed is the approved application for the sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration 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. Sincerely, 119 Daniel T. Seamount, Jr. Commissioner DATED this .30 day of January, 2019. RBDMS$MAN 3 12019 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 RECEiVh'IJ JAN 11 2019 1. Type of Request: Abandon 0 Plug Perforations ❑ Fracture Stimulate ❑ Repair Well ❑ O ere n ea Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing ElChang a aro rtl"L] Plug for Reddll ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other ❑ 2. Operator Name: BP Exploration (Alaska), Inc 4. Current Well Class: Exploratory ❑ Development 0 • 5. Permit to Drill Number 207-035 ' 3, Address: P.O. Box 196612 Anchorage, AK 99519-6612 Slretigraphic ❑ Service ❑ 6 API Number 50-029-20078-01-00 ' 7. If perforating: S. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require a spacing exception? Yes ❑ No 0 PBU 04-01A 9. Property Designation (Lease Number): 10. Field/Pools: ADL 028325 & 028324' PRUDHOE BAY. PRUDHOE OIL - 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): 11374 6995 ' 8954 8299 8954.9530.10720 None Casing Length Size MD TVD Burst Collapse Structural Conductor 80 30" 31-111 31 - 111 880 Surface 1154 20" 31 -1185 31-1185 1530/2320 520/1500 Intermediate 1 2657 13-318" 29 - 2686 29 -2686 4930 2670 Intermediate 9252 9-5/8" 28-9278 26-8587 6870/6820!/510/8150 4760/3330/413015080 Liner 2386 3-1/2" x 3-3116" x 2-7/8" 8983-11369 8325-8994 Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade. Tubing MD (ft). 9300- 7 7300 Be06 - 8984 4-1 /2" 12.6# x 5-1/2" 17# 13Cr80 / L-80 24-9184 Packers and SSSV Type: 4-1/2" Baker 8-3 Hydro Set Packer Packers and SSSV MD (ft) and TVD (ft): 8930 / 8278 5-1/2" Baker FB -1 Packer 9063/8398 12. Attachments: Proposal Summary 0 Wellbore Schematic 0 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stratigraphic ❑ Development 0 ' Service ❑ 14. Estimated Date for Commencing Operations: January 25, 2019 15. Well Status after proposed work: Oil ❑ WINJ ❑ WDSPL ❑ Suspended ❑ 16. Verbal Approval: Date: GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned 0 ' 17. 1 hereby certify that the foregoing is true and the procedure approved herein will not Contact Name: Worthington, Area J be deviated from without priorwritten approval. Contact Email: Ares.Worthingtonabp.00m Authorized Name: Worthington, Area J Contact Phone: +1 907 564 4102 Authorized Title: Interventions & Integrity Engineer Authorized Signature: Date: COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: - O I Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test 19-'-' Location Clearance Other: P koC`-6 &nc u vvL eC + C - !S 1 A),6 i C /QT2f-d Post Initial Injection MIT Req'd? Yes ❑ No ❑ Spacing Exception Re fired? Yes ❑ No E( Subsequent Form Required: 0--q 7 •'" ,�/75W APPROVED BYTHE /) Approved by: COMMISSIONER COMMISSION Date: Ax `� Form 10403 Revised 04/2017 ORIGINAL RMM910)AN 3 12019 /•"r�'IC�-7 ^Af`%�'o Submit Formand Approved application is valid for 12 months from the date of approval. Attachments in uplicete 04-01 P&A Intervention Engineer Aras Worthington (907) 564-4102 Production Engineer Meredyth Richards (907) 564-4867 Expected start date: January 25t' 2019 History 04-01A was completed in 1971 with a Gen 1 wellhead and three string casing design. The outer casing string is set in permafrost. GWO has determined that these wells are at risk for sudden wellhead movement, as demonstrated by 02-03A and 02-02A. As such, the AOGCC has requested this well be plugged and abandoned to mitigate HSSE consequence associated with this potential risk. Objective Place cement plugs in the wellbore. Excavate and cut casings 3' below original tundra level and install marker cap. Procedural steps Slickline/Fullbore 1. Pull bottom DGLV @ 8838' MD. 2. Circulate down tubing and up IA with surfactant wash followed by 9.8 ppg brine ➢ 5 bbls MEOH ➢ 50 bbls hot (160 deg) freshwater + surfactant; 2 gal/mgal F103 and 2 gal/mgal U067 ➢ 620 bbls 9.8 ppg brine 3. AOGCC Witnessed CMIT TAA to 1500 psi. ✓ /b' a 4. AOGCC Witnessed tag top of XX plug @ 8954' MD. Flag wire for depth control. 5. MU 5' tubing punch and punch from 8920'— 8925' MD. (This step may be moved to E -Line if E -fire is not available). Fullbore 1. Pump cement job down tubing with returns from at 2200' MD in the tubing. ➢ 5 bbls MEOH ➢ 595 bbls of Class G cement per design ➢ Foam wiper ball ➢ 2 bbls FW spacer ➢ 31 bbls 9.8 ppg brine IA. The top of cement in the IA will be at surface and Cement Type/weight: Class G 15.8 ppg mixed on the fly. Field blend to be =lab ppg +/- 0.1 pp Pressure Slurry Temperature: between 800 and 110°F 0 Fluid Loss: 40-200cc (20-100cc/30 min) 3000 Compressive Strength: 2000 psi in 48 hrs. 2500 Thickening Time: Minimum 5 hours 2000 Cement Ramp for Blend Time Temp Pressure 0:00 90 0 1:00 130 3000 2:00 120 2500 3:00 110 2000 4:00 100 1500 7:00 80 1000 15:00 40 0 E-Line/Fullbore 1. MITT to 2500 psi 2. Tag TOC 3. Run GR log and caliper survey from TOC to surface (log all the way into the Tree - this log is for future subsidence surveillance/analysis). 4. Perforate @ —1800' MD through 4-1/2" tubing and 9-5/8" casing. Fullbore 1. RU to pump down the tbg and take returns from the OA. Pump the following: ➢ 50 bbis hot (160F) diesel ➢ 30 bbis hot (160F) 9.8 ppg brine ➢ SD for one hour to let diesel soak in OA and loosen Arctic Pack ➢ 50 bbls hot (160 deg) freshwater + surfactant; 2 gal/mgal F103 and 2 gal/mgal U067 ➢ 150 bbis hot (160F) 9.8 ppg brine 2. Once clean brine is consistently returned from the OA indicating that all hydrocarbons have been circulated out of the annuli, pump OA surface cement plug as follows down Tubing_ The TOC in the OA will be at surface and at —1000' MD in the tubing. ➢ 5 bbls MEOH ➢ 5 bbls freshwater spacer ➢ 135 bbls 15.8 ppg cement per design ➢ Foam wiper ball ➢ 2 bbis FW ➢ 13 bbis 9.8 ppg brine Cement Type/weight: Class G 15.8 ppg mixed on the fly. Field blend to be =lab pp +/- 0.1 pp Pressure Slurry Temperature: between 80° and 110°F 0 Fluid Loss: 40-200cc (20-100cc/30 min) 1000 Compressive Strength: 2000 psi in 48 hrs. 0 Thickening Time: Minimum 4 hours 0 Cement Ramp for Blend Time Ternp Pressure 0:00 90 0 1:00 70 1000 2:00 60 0 3:00 50 0 4:00 40 0 7:00 40 0 15:00 30 0 E -Line 1. Perforate @ —900' MD through 4-1/2" tubing, 9-5/8" casing, and 13-3/8" casing. Fullbore 1. RU to pump down the tbg and take returns from the OOA. Pump the following: ➢ 80 bbls hot (160F) diesel ➢ 15 bbls hot (160F) 9.8 ppg brine ➢ SD for one hour to let diesel soak in OA and loosen Arctic Pack ➢ 60 bbls hot (160 deg) freshwater + surfactant; 2 gal/mgal F103 and 2 gal/mgal UO67 ➢ 180 bbls hot (160F) 9.8 ppg brine 2. Once clean brine is consistently returned from the OA indicating that all hydrocarbons have been circulated out of the annuli, pump OOA and Tubing cement plug as follows down Tubing. Top of cement will be at surface in both the OOA and the Tubing. ➢ 5 bbls MEOH ➢ 5 bbls freshwater spacer ➢ 190 bbls 15.8 ppg cement per design Cement Type/weight: Class G 15.8 ppg mixed on the fly. Field blend to be =lab ppg +/- 0.1 ppg Slurry Temperature: between 800 and 110°F Fluid Loss: 40-200cc (20-100cc/30 min) Compressive Strength: 2000 psi in 48 hrs. Thickening Time: Minimum 4 hours Cement Ramp for Blend Time Temp Pressure 0:00 90 0 1:00 70 1000 2:00 60 0 3:00 50 0 4:00 40 0 7:00 40 0 15:00 30 0 Volume Calculations: volume top MD bot MD Size ID bbls/ft. Ft. bbls Special Projects 1. Excavate and Cut off all casings and wellhead 3' below original tundra level. Top job the 30" annulus and all other annuli and tubing with cement as needed. 2. AOGCC witness cement tops in all annuli 3. Bead weld marker cap on outermost casing string (30" Conductor) to read as follows: BP Exploration Alaska, Inc. 04-01A PTD # 207-035 API # 50-029-20078-01 0/7 116 -yj 17 19.124" 20" x 13-3/8" annulus to 20" 94# x x 900' Surface 900' 13-3/8" 13.375" 0.182 900' 164 12.347" 13-3/8" 72# x 13-3/8" x 9-5/8" Surface 1800' x 9-5/8" 9.625" 0.0581 1800' 105 8.681" 9-5/8" x 4-1/2" annulus Surface 8930' 9-5/8" 47# x 4-1/2" 0.0535 8930' 488 4-1/2" tubing Surface 2200' 4-1/2" 12.6# 3.958" 0.0152 2200' 33 4-1/2" tubing Surface 8954' 1 4-1/2" 12.6# 1 3.958" 0.0152 1 8954' 146 Special Projects 1. Excavate and Cut off all casings and wellhead 3' below original tundra level. Top job the 30" annulus and all other annuli and tubing with cement as needed. 2. AOGCC witness cement tops in all annuli 3. Bead weld marker cap on outermost casing string (30" Conductor) to read as follows: BP Exploration Alaska, Inc. 04-01A PTD # 207-035 API # 50-029-20078-01 0/7 116 -yj 17 TREE = Wfl.I.FEAD= ACTUATOR= OICB. fl.EV = _ BOFF aLV = KOP= Wr Amb=- kCEVOY MCEVOY DS O4-01 Current Status T6: WELL RBMARPS A SSSV —4-1/2' AXELSON 30"CIXO TBG— WELL ANGLE a70"@959r—DEPTHS 64• MEASURED WITH I -COIL DURING 512007 CTD (04-01A) 20' CSG, 94#, 1185' 32W, 1+401133#, K55 ®10041' D=18.750' 2159' 412'HES 13CRX NP,D=3.813' 106M 9-518' CSG. 47#, u 8ED0' L-80,0=9.681• GASLETM4NDFFLS Minimum ID =2.380" @ 10058' 33H8" x 2-718" XO 4112' TBG.126# 13CFi0 VAM, 9017 .0152 W. D= 3.958' 412' TBG STUB (0426107) 8022' 3112' LFR. 8.81#, LBO STL, .0087 bpf, D = 2.992' 170, 19-5/8' LNR. 470, S0095, PEF FORATION SUMMARY FrEF LOG CAL ON 05116107 ANGLEAT TOPPH€: WO 93OD" Fbba- Refer to Production DB for tislormal peri data S(ZE SPF INTERVAL IST SHOT M0 TVD DEV TYPE VLV LATCH PORT DATE C6G, 720, N-80, ID= 12.347' 2686' 9382-9397 3231 3227 11 kMG DOME RK 16 06119107 2-1/2" 6 9464 - 9469 O 4 5651 5414 30 MAG SO R( 20 06119107 6 9970-10020 C 05117/07 3 73% 6917 29 k1.f DW w 0 0426107 C 05/17107 2' 2 8140 7571 28 MAG DW FIC 0 0426+07 1 8838 8196 26 MAC OMV BM 0 04/26107 Minimum ID =2.380" @ 10058' 33H8" x 2-718" XO 4112' TBG.126# 13CFi0 VAM, 9017 .0152 W. D= 3.958' 412' TBG STUB (0426107) 8022' 3112' LFR. 8.81#, LBO STL, .0087 bpf, D = 2.992' 170, 19-5/8' LNR. 470, S0095, PEF FORATION SUMMARY FrEF LOG CAL ON 05116107 ANGLEAT TOPPH€: WO 93OD" Fbba- Refer to Production DB for tislormal peri data S(ZE SPF INTERVAL OpnlSW SHOT SOZ 2" 6 9300-9330 O 0423115 8029' 2" 6 9382-9397 O 0423115 06128/16 JID 2' 6 9408-9425 O 0422115 2-1/2" 6 9464 - 9469 O 10110,09 2-112' 6 9452-9457 O 10/10/09 2" 6 9970-10020 C 05117/07 2' 6 10500-10650 C 05/17/07 2' 6 10770 -10800 C 05/17107 2' 6 10895 -11300 C 05/17107 D=2.80' 6Ib➢ 1 8930- )y3518'X412'B9 tS3WDROWP D=3.875' 8864' 4-V2"FESXNP,D=3.813" 8864' 412" XX PLUG (1020/17) 8983"' 3.70' DEPLOY SLV w 14- GS PROFILE ID 0725117 R1WJM) ADDED 30" CORD 820"CSG 3-12' 0775 X 9017 412' X 5-12' XO, D = 3.958" (BEHIND LNR) 8029' 9-618' X 4-12" UA4(X1E OV H25HOT l� 312'X3-116'XO,1D=2.786' BEHIND 8068' 5-12" BKR sEAI AssY CT LNR 91�—(5-12' BKR SFEAROUr SUB BEHIND 9184' 5-12" TUBING TAL (CMT'0) CT LNR MILLED WINDOW (04.01A CORRECTED) 9278'-9267' 9530' 3-116'BKR CBP(0422/15) 10068' 3-3116' X 2-7W XO, / D = 2.380' PBro11�� 6.160, LBO STL, .0058 bpf, D = 2.441" 11369"' DATE REV BY COMMENTS DATE REV BY COMIVENT5 01110!71 ORIGINAL COMPLETION 06130116 JTM'JM) UPDATED PSI VALUE 07107M RIND 0725117 R1WJM) ADDED 30" CORD 820"CSG 04127107 IORI= RWO 1112117 MGS1JME PULLED VALVEJSE )0(PLUG 05118107 CTDSIOETR1kCK(0401A) 02/0116 :; C K VLV UPDATE PER STATE REGS 06128/16 JID UPDATEDKVALVEwIPS1 PRDHOE BAY UM WELL: 04-01A PERMT No: `2070350 AH No: 50.02320078-01 T11N, R15E, 132T REL 8 295' FE- ED BrpbratEon (Atrka) TFEE WEVOY W9.LHEkD= Mf�VOY DS O4-01 P&A Status NOTES: WELL ROXARB A SSSV "Y-112- ermrerno evo circ 30'COFD ME TBG—WELL ANGLE >TO-@9592'•••DEPTHS Third Cement Plug: TBG: Surface to 900' MD OOA: Surface to 900' MD Drilling (original) Cement: 9-5/8" Casing: est. 4040' MD to 5970' MD pumped through stage collar 4-12' TBG. 12.6# 13CFffi0 VAM, 9012 .0152 bpf, D = 3.958• 312' LNR 8.811, LBO STL, .0087 bpf. D = 2.992' 0=4.892* 47#, 50695, .0732 bpf, D= 8.681' PEiFORATDNSUK"RY RTE LOG: CNL ON 0511&07 ANGLEAT TOP IBiF: 34-0930V We %fer to PYodwbon DB for Iistorical pert data SIZE SPF INTERVAL OpNSrR SHOT SO7 2' 6 9300-9330 O 14/23!15 5651 7 6 9382-9397 O 0423115 SO 2' 6 9408-9425 O 04122/15 7396 2-1/2' 6 9464-9469 O 10/10/09 DFM 2-112 6 S452-9457 O 10/10A9 8140 2' 6 9970- 1002D C 05/17/07 DFM 7 6 10500-10650 C 05/17/07 8838 2' 6 10770-10800 C 05/17/07 DMV 2' 8 10895- 11300 C O5/17R{7 4 3 2 1 Second Cement Plug: TBG: 1000' MD to 1800' MD OA: Surface to 1800' MD 3231 3227 11 MW, DOFF RA 16 06119/07 5651 5414 30 MIAG SO RK 20 0019107 7396 6917 28 MAG DFM PK 0 0126/07 8140 7571 28 M` G DFM FM 0 04/26107 8838 8196 26 MAG DMV RA 0 0426107 First Cement Plug: TBG: 2200' MD to 8930' MD IA: Surface to 8930' MD {� 3.70• DEPLOY SLV w / 4' GS PROFILE, D= 3.00• 3-12'OTISX NP. D=2.813' X 5-12• XO, D= 3.958' (BEHIND LMA x BEHIND CT LNR BEHIND CT LNR MLLED VVINDOW104-01 A CORRECTED) 9278'-9287' 3-3x16' LNR 62#, L-80 TOL .0076 bpf. D= 2.80' DATE REV BY OOM6S4TS DATE REV BY COK46E M 0111WI ORDINAL COMPLETION 0630/16 JTMJFO UPDATED PSI VALUE 07107190 IWO 0725/17 RBYJW ADDED30'COLD820'CSG 0427107 NOFIDIC, RWO 1023/17 IwIGSIJKC PLA -LED K VALVEiSET XX PLUG 0511&07 NDR= CTD SIDETRACK(04-01A) 02JO3116 GRWLF K VLV UPDATE PER STATEREGS 0628/16 JFO UIFDATIDKVALVEw/PSI 8KR l'BP(0422/15) 3-3118' X 2-7/8' XO. D = 2.380' 120' 2-7/8' VWD PBTD — t 1335'•' J r, ID=zMr11369"' PRUDHDESAY wT WELL: 04-OIA F EFur No: `2070350 AR ND: 50-029-20078-01 TI IR R15E 1327' FNL & 296 BP Bcplaratbn (Alaska) Rixse, Melvin G (DOA) From: Worthington, Aras J <Aras.Worthington@bp.com> Sent: Tuesday, January 22, 2019 2:53 PM To: Rixse, Melvin G (DOA) Subject: RE:PTD207-035 Sundry 319-009 DSO4-01A P&A Mel, The geologists have indicated that there is no Sag in this wellbore. BP lists the DPZs in this well as follows: DPZ1: 1964' MD -7402' MD DPZ2: Not present in this wellbore DPZ3: 9295' MD—TD Aras Worthington Well Interventions & Integrity Engineer BP Alaska Inc. Office: (907) 564-4102 Cell: (907) 440-7692 From: Rixse, Melvin G (DOA) <melvin.rixse@alaska.gov> Sent: Wednesday, January 16, 2019 4:11 PM To: Worthington, Aras J <Aras.Worthington@bp.com> Subject: PTD207-035 Sundry 319-009 DSO4-OIA P&A Aras, Where is the top of sag on this well? (Is that DPZ2 in the BP world?) Mel Rixse Senior Petroleum Engineer (PE) Alaska Oil and Gas Conservation Commission 907-793-1231 Office 907-223-3605 Cell CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Mel Rixse at (907-793-1231) or (Melvin.RixsePalaska.govI. STATE OF ALASKA OLASKA OIL AND GAS CONSERVATION COMMIS. REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed Abandon 0 Plug Perforations 0 Fracture Stimulate 0 Pull Tubing 0 Operations shutdown 0 Suspend 0 Perforate 0 Other Stimulate ❑ Alter Casing ❑ Change Approved Program 0 Plug for Redrill 0 Perforate New Pool 0 Repair Well � Re-enter Susp Well 0 Other:K-Valve Q 2. Operator Name: BP Exploration(Alaska),Inc 4. Well Class Before Work 5. Permit to Drill Number: 207-035 3. Address: P.O.Box 196612 Anchorage, Development Q Exploratory 0 AK 99519-6612 Stratigraphic 0 Service ❑ 6. API Number: 50-029-20078-01-00 7. Property Designation(Lease Number): ADL 0028324 8. Well Name and Number: PBU 04-01A 9. Logs(List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pools: PRUDHOE BAY,PRUDHOE OIL 11.Present Well Condition Summary: Total Depth: measured 11374 feet Plugs measured 9530/10720 feet , E � true vertical 8995 feet Junk measured feet Effective Depth: measured 9530 feet Packer1 L_B 2 5 2016 measured See Attachment feet true vertical 8741 feet Packer true vertical See Attachment feet aCC'°{ AO Casing: Length: Size: MD: TVD: Burst: Collapse: Structural 80 30"157.5#B Grad 29-109 29-109 Conductor See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Surface See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Intermediate See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Production Liner See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Perforation Depth: Measured depth: 9300-9330 feet feet 9382-9397 feet 9408-9425 feet 9452-9457 feet 9464-9469 feet 9970-10020 feet 10500-10650 feet 10770-10800 feet 10895-11300 feet True vertical depth: 8606-8629 feet feet 8664-8673 feet 8680-8689 feet 8703-8705 feet 8709-8711 feet 8796-8798 feet 8815-8856 feet 8895-8904 feet 8926-8984 feet Tubing(size,grade,measured and true vertical depth) See Attachment See Attachment See Attachment Packers and SSSV(type,measured and See Attachment See Attachment See Attachment true vertical depth) 4-1/2"K Valve 2155 2155 12.Stimulation or cement squeeze summary: Intervals treated(measured): Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 76 949 10101 1673 231 Subsequent to operation: 3581 14245 5166 1530 699 14.Attachments:(required per 20 AAC 25.070.25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations Q Exploratory ❑ Development Q Service 0 Stratigraphic 0 Copies of Logs and Surveys Run 0 16.Well Status after work: Oil Q Gas 0 WDSPL 0 Printed and Electronic Fracture Stimulation Data 0 GSTOR 0 WINJ 0 WAG 0 GINJ 0 SUSP 0 SPLUG 0 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: 316-084 Contact Catron,Garry R(Wipro) Email Garry.Catron@bp.com Printed Name Catron,Garry R(Wipro) Title PDC Principal Engineer Signature Phone +1 907 564 4424 Date 2/25/16 Form 10-404 Revised 5/2015 4.16[!d V1.1 / ./ RBDMS u. FEB 2 6 2016 Submit Original Only • • Packers and SSV's Attachment PBU 04-01A SW Name Type MD TVD Depscription 04-01A SSSV 2155 2154.97 4-1/2" K Valve 04-01A TBG PACKER 8928.15 8276.31 4-1/2" Baker S-3 Hydro Set Packer 04-01A TBG PACKER 9061.76 8395.51 5-1/2" Baker FB-1 Packer • 0 m In 0 N- 0 Q, O o o O o o O o pCD CO CO CO co 0 CO CO N co in CO in CO C.) ' O 4 - M N Cr) M O� N Or LO M Nr 3LC) CO O) 0 CO CO LC) r m O r N 't CO CO N- CO co VI-CO t` 0 N CO CO CO N N CO N CO "Zr O if, '- CO CO CO CO CO N. Cr) N- 00) CO LO r 00 r r N N LC) N- CO CO 00 00 CO CO CIIIIIIIIIIIIIII I— O CON N LC) N 00 N 0 0 Lo CO cr Cr) CO N N- N r- 0 r CO N N00 N N N LM COCO C1OO CO N COO C CI) O N M CO CO Ln CO CO L) Lo O� N E O L[) co LC) C (O Cr LO Cr CO O M N CO r co T. r (Oo d' LC) N N- CD O r = r r N N LC) CO 0) 0 0) 0 V 0 Q 2 1.0 M Q O 0) 0NCOvCOCCOO LM[) CMO (o , rN O 4 N N Cb N N N 0N0 00O 8 O N 0 C O a N LC) 0000coa 1 0 i 000 CO o • 0 L_ O i ' 00 0 0) 0vL9zz JO00 � � -jM � C Cpm *kNN4tO � U)* C\I N y Lu a M - - O •• N- _ cci co 03 � � r' -0\O �0\0 -00 � coT' - CO - ' N _ N r 00 - ONNChMch � L � MCO(N I CO 0 0 4 t N- CO co 0 0 Ln CO N- (O C C1Dcn O N M LSC) O ON NLC) O coO J0O M r r N CO N r r r 0) r W W W W 0X00 aaQQ � D U U W W W 0 5 W ; H U U VD00u_ u_ CCCCCCCtcc rYZZ Et Z Z rt CC W W W W W W W m m I- 000D ~ F- F- I— ZZZ00 cn00 (ncAZZZZJJJ1_ H • • Lo a o ci ai 73W > N Q- 2ao © CL w = co J CL H c0 E W Z co c) w a ,- N o a X H .� H co Z Z F- g ) Q a) La 0 0 0 Z Z3) @� oar = z W cc C) J U CO LL D m J CL 0 _ w �-. a) co Q = O O m > Z - 0 a n o o I N Lr) (n (n 0 E. CC a) Q 2 co Y J 0 N Cl) �' Q CV i- c) ZD •N m C a) O 0 O cc o O * _ H 6 Q Q O a (n �N ,- 'N 0 O � w a) m m* LU - J v N N 0 LI +�- N C N O v* CV CO J p Q -D a) )ccEo O .- O 0 O W C > (n Q co Y2 co 3 ,� II Ni' d) Uva , o >- (n a, - o 0b) _a p p >(0 2 cti m cw� N y 2 HN > mN Lo m o �n vOi 3 N COc00 � W Q 2 _ @ W FO- m � O ti 'p O w N. Cl) J •N (r)_ 0 — � � � 00 � � m 7 o -� p x - - > _ 2 �oo11N 0 �• (n CL II = tlo N „ EQ N co (nN /J� vp w O C E- -"E's m = = Q (� Cr) a) ,= N > � v 7 - •0 0 * F- O 1,1 CD N O 4 O * O N * L.L. CL CO c > Z > N * M CI m*0 Z O N `. O W °� * cc vW v� CO O > W *I Z N W CO0 Z �+ CO Lij Nt' CI! Ci- II Q -J = CLw (� y- � � YU N 0 * Q W �1 J CC d 0 252 = Q 0 QHZm ICI)_45 E50 p0 m * > 0w< < ceO O 0. -c6HF- E co > F- (n O > • -(1--) ) 0 .E _ Z0 � W d * w � Qcc � Q QOXre Q EETo co) -Q � ) 0 co u-I= CoC rt j • .. - £ E cNi ia 2 •/ 2 k o_ c o_ m 5 ° k • c o $ f • kLE • / - 0 § o c f 2k 3 .g & fx o t O $ a w o g « ■ Eek < / = a § f O c / c EE co 2Kz w / 2 ± � E ■ 8 oo. % 01 x < / O m 0 < h- (N o b 0) / cp & � 0 ƒ A � / < Lo/ w / II RS ' o �U�o © ! 7 / w U I— t — p � / \ / < q - 0z • � 7 � w � ƒ re reNw 0 _ I-EEkq < w� � u) _ = m ƒ D o -J / u 1 0 O c kI ® � 0 wz q ® 3 p / k U / ¥ _I L / w k o ƒ / \ / •2/ •�/ Z � ) � « m < ■ W < ® @2 w O w c R m m I cL | 5 m / � � � � / TREE= MCEVOY • WELLHEAD= MCEVOY 0 4-01 A _-SA TES: WELL REQUIRE A SSSV *'"4-1/2" ACTUATOR= AXELSON CHROME TBG*'"WELL ANGLE>70°@ 9592'""DEPTHS OKB.ELEV= 64' I I MEASURE)WITH I-COIL DURING 5/2007 CTD(04-01A)"*' BF.ELEV= 9 KOP= 3200' 2159' J4-112*HES 13CR X NP,D=3.813" Max Angie= 91°@10041' ! Lotum MD= 10676' 9-5/8•CSG,47#, -H 2464' x2159' IN 4-1/2"K VALVE STALLED 05/29/15 Datum ND= 8800'SS L-80,ID=8.681' I GAS LIFT MANDRELS 13-3/8"CSG,72#,N-80,D=12.34r —{ 2686' J ST MD ND DEV TYPE VLV LATCH FORT DATE 5 3231 3227 11 MMG DOME RK 16 06/19/07 4 5651 5414 30 MAG SO RK 20 06/19/07 3 7396 6917 28 MAG DMY RK 0 04/26/07 2 8140 7571 28 MMG DMY RK 004/26/07 1 8838 8196 26 MAG DMY RK 0 104/26107 Minimum ID =2.380" @ 10058' 8909' H4-1/2"HES X NP,D=3.813" 3-3/16"x 2-7/8" XO ►iM ►� 8930' —9-5/8"X 4-1/2-BKR S3 HYDRO PKR,ID=3.875" 8954' -H4-1/2"HES X NP,D=3.813" 8983"7—3.70'DEPLOY SLY w/4"GS PROFILE,D=3.00" I9007' 3-1/2"OTIS X NP,D=2.813") 4-1/2"TBG,12.6#13CR80 VAM, --I 9017' K .0152 bpf,D=3.958" 4-1/2"TBG STUB(04/26/07) 9022' —") 9017' H4-1/2'X 5-1/2"XO,D=3.958"(BEM LNR) pm _ - 9029' —9-5/8"X 4-1/2"UNIQUE OVERSHOT 3-1/2"LNR,8.81#,L80 STL, — 9040' 0087 bpf,D=2.992' Irs9040' H3-1/2"X 3-3/16"XO,ID=2.786" BEHIND _ 9059' —15-1/2"BKR SEAL ASSY CT LNR Ileal E 9063' -19-518"X 5-1/2"BKR FB-1 PKR w/SEALBOR EXT. TOP OF KILLED CMT(DMS 04/29/07) —� **9185' ,. 0 ii 9172' —5-1/2"OTE XN NO-GO NP,D=4.45" 5-1/2"TBG,17#,L-80 PC,.0232 bpf,ID=4.892" 9184' v s ICCIll�� i'v' ►04%1 ! *� 9183' -{5 112"BKR SI-FARO JT SUB BEHIND 4"FIII , CT LNR < of�� 9184' —5-1/2"TUBING TAIL(cMrD) 68% AAA 9-5/8"LNR,47#,S00-95,.0732 bpf,D=8.681" 974T1,11101 11 i�►�it� •.,, MILLED WINDOW(04-01A CORRECTED)9278' 9287' IIIIil- III ►IIII • PERFORATION SUMMARY4.••••••••�� � N. ►11111111.' 1 -41: 9530' —{3-3/16"BKR CBP(04/22/15) REF LOG: CNL ON 05/16/07 ;������ �v'• " ANGLE AT TOP FERE:34° 9300" +� C�3 . e '44.,. 10058' �3-3/16-X 2-7/8•XO, Note:Refer to Production DB for historical pert data M�41ir'NIN r•Ne•I '..113=2.380' SEE SW INTERVAL Opn/Sqz SHOT SQZ _ _ _ - _ _ _ N"sem f.�•,4 10720' --2-7/8'WFD CBP 2" ' 6 9300-9330 0 04/23/15 2" 6 9382-9397 0 04/23/15 `„ �`� (03/19/15) 2' 6 9408-9425 0 04/22/15 `4 `- 2-1/T 6 9464-9469 0 10/10/09 3-3/16"LNR,62#,L-80 TCS, —{ 10058' ,`sza.I,/ '` 2-1/2" 6 9452-9457 0 10/10/09 0076 bpf,ID=2.80" t+1,'` 2" 6 9970-10020 C 05/17/07 2" 6 10500-10650 C 05/17/07 PBTD -I 11335'** �`;*� •*+ 2" 6 10770-10800 C 05/17/07 ��`%��' 2" 6 10895-11300 C 05/17/07 2-7/8'LNR,6.16#,L80 STL,.0058 bpi,D=2.441" H 11369'** DATE REV BY COMMENTS DATE REV BY CONVENTS PRUDH O E BAY UNIT' 01/10/71 ORIGINAL COMPLETION 12/17/10 MB/JM) ADDEDSSSV SAHLIY NOTE WELL: 04-01A 07/07/90 RWO 03/23/15 SRIYJMD SET CBP(03/19/15) PERMIT No:82070350 04/27/07 ••.►C,RWO 04/24/15 BF/PJC CEP SET/ACFERF RF(04/22-04/23/15) AR No: 50-029-20078-01 05/18/07 NORDIC-CTD SIDETRACK(04-01A) 02/03/16 GRCITLH K VLV UPDATE PER STATE REQS SEC 34,T11N,R15E,132T FNL&295'FEL 06/30/09 RL7TLH DRLG DRAFT FINAL CORRECTIONS 10/14/09 MV/PJC ADFERFS(10/10/09) BP Exploration(Alaska) • OF 74, • • 4,9����//, 4 THE STATE Alaska Oil and Gas 41 -s—dim.—`*4 ofA LASKA Conservation Commission t5rt= �� 333 West Seventh Avenue 1. ,�. l. GOVERNOR BILL WALKER -•--Anchorage, Alaska 99501-3572 OF " Main: 907.279.1433 ALAS Fax: 907.276.7542 www.aogcc.alaska.gov Ryan Daniel SCANNED ��� � Alaska Wells Integrity and Compliance Team Leader 2U11 BP Exploration(Alaska), Inc. P.O. Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU 04-01A Permit to Drill Number: 207-035 Sundry Number: 316-084 Dear Mr. Daniel: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration 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. Sincerely, 4,/ /0....2"...azz ... Cathy :. Foerster Chair DATED this Go day of February, 2016. RBDMS 1,1/ FEB 2 5 2016 STATE OF ALASKA • ALASKA OIL AND GAS CONSERVATION CON/11,0N • APPLICATION FOR SUNDRY APPROLS 20 MC 25.280 • 1 1 Type of Request: Abandon 0 Plug Perforations ❑ Fracture Stimulate ❑ Repair Well 0 Operations shutdown IDI Suspend 0 Perforate ❑ Other Stimulate ❑ Pull Tabing ❑ Change Approved Program ❑ Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other 4-1/2"K-Valve Design Q ' 2. Operator Name: BP Exploration(Alaska),Inc 4. Current Well Class: 5. Permit to Drill Number: 207-035. 3. Address: P.O.Box 196612 Anchorage,AK Exploratory ❑ Development Q ElService ID6. API Number: 50-029-20078-01-00 . 99519-6612 Stratigraphic 7. If perforating: What Regulation or Conservation Order governs well spacing in this pool? 8. Well Name and Number: Will planned perforations require a spacing exception? Yes ❑ No Q PBU 04-01A • 57, Frt_D 9. Property Designation(Lease Number): 10. Field/Pools: ADL 0028324 PRUDHOE BAY,PRUDHOE OIL F ER 0 V 4 ?016 11. PRESENT WELL CONDITION SUMMARY %75 Z f zs//f. Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth TVD: MPSP(psi): Plugs(MD): Junk(MD): 11374 • 8995 • 9530 8741 9530/10720 Casing Length Size MD TVD Burst Collapse Structural 80 30"157.5#B Grade 29-109 29-109 0 Conductor See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Surface See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Intermediate See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Production Liner See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): See Attachment See Attachment See Attachment See Attachment See Attachment Packers and SSSV Type: See Attachment Packers and SSSV MD(ft)and TVD(ft): See Attachment 4-1/2"K Valve 2155, 2155 12.Attachments: Proposal Summary De Wellbore Schematic Q 13.Well Class after proposed work: Detailed Operations Program 0 BOP Sketch ❑ Exploratory ❑ Stratigraphic 0 Development Q Service 0 14.Estimated Date for Commencing Operations: 15. Well Status after proposed work: Oil Q - WINJ ❑ WDSPL 0 Suspended 0 16.Verbal Approval: Date: GAS 0 WAG ❑ GSTOR ❑ SPLUG 0 Commission Representative: GINJ ❑ Op Shutdown 0 Abandoned ❑ 17.I hereby certify that the foregoing is true and the procedure approved herein will not Contact Daniel,Ryan be deviated from without prior written approval. Email Ryan.Daniel@bp.com Printed Name Daniel,Ryan Title Alaska Wells Integrity&Compliance Team Leader Signature / •,..i: Phone +1 907 564 5430 Date U A ?04 COMMISSION USE ONLY ✓Il Conditions of approval:Notify Commission so that a representative may witness Sundry Number: Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: Post Initial Injection MIT Req'd? Yes 0 No ❑ Spacing Exception Required?/� Yes 0 No RI Subsequent Form Required ,O -404 4.....144,,_. //' APPROVED BYTHE Approved by: / COMMISSIONER COMMISSION Date:2 ORDINAL RBDMSU1, FEB 252016 s , Submit Form and Form 10-403 Revised 11/2015 Approved application is valid for 12 months from the date of� 'p> I. �, '1b� Attachments in Duplicate �' '` sl z,�'/' • • m w a 0 0 0 0 0 o 0 0 00 0 !a N O r-- Cfl CO CO CO 0 0 00 Lo CO CD IN- CO r O co Lo N V .-- N N V' CO 'Cr to M I` CO rr i MO O CO N COO O O O O t0 o 0 0 Lo 3 co CO O) CA CO CO CO c- ,:rm s- N V V CO CO Imo- 00 . CO N- s- 0c.,4 ON Cr CO CO CO N N CO N O ct V O to CO LO CO CO N I"-- CO I` 0 0) (0 O co c r' CO d' CO CO I� CO I` O) CO LO r r N N Lo ti co co c0 co co co H O CA tLo CO 44- CO CD CO N ti N LO A 60) .- coN N N OD N c N 'Cl- CO CO CO CO f- N CO r' N LO IN- CO CO CO CO C O) N d' CO CO CO LO CO O LO M O E co ..0O O NCO O .- v- N N t!) 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C wooi ' *k * * OHO * N * ` J .� N � vco_ v) *- (Oc'j �-0 Lo O O C'7 M to 0_0 NI- co N E0 _ Q O N N T- 0 La LO I M M N N LO CO C) , CT) 4 L O M N N- CO CO O) O) to co I- CO dC N c') N U d CD 0 0 N .- 0) 0 0 0 00 M � r N OCD N- v to O r i -J W W W W Q C! � HHHH CO O Q Q Q Q )C .cUUIli 0 00 W0 ctzz [tfxWwWwWWWmm HOODDI- Hl-- I-- z_ z_ z Do coUUcnw zzzJJJHH • • a, N a9 m C) .4- N O) LC) N- CO I- n) L Cr) O 'Cr N h ":1" CO p, CO C`7 CA In r- N- cn V' M w N N- CO O s- O) Ln O CO O CO CO CO N N- N- CO 0) C)) p CO co co CO CO CO co co CO Ct O F' Ln (N T CO N- N- CO N L() LC) N N- 6) n) CO N CO N O. in V" 6 N CO in in 4 O O O CO Ccp co OO CO O O N COCOO C) > CI CO CO CO CO CO CO CO CO CO 0 I— LU CL 0 p p CO Z I- I- o a Lucp wa pp Q U O 0 m co cn .--. U U ~Ili W ++ O C� N In coON LC) O O _I -J Q Q U) W Cr C m M C�) (N V CDNI' O CO C70 (") < < < W a a 0 _Z ///�����, p p) O Cy) O O O O O T 000 —IW Z W - O CD d r T T T Q Q Q O 0 a O L�LI a _ _ = Z o 0 ,_ 2 0 0 0 w p V a W W W a Q _i Q 2 2 O cn N cn cn cn as r ++ O Q et 2 0 Oo = O N CO N 0 CD 0 Ln n O- O CO O in co f` O ti CD m Cl CA CA 0) 0) 0) 0 0 0 cr II 2 2 2 0 cn cn cn c co CD a cu TsO c) c oLL LL LL LL LL Cl) (/) (/) Cl) co12_ aaaaaaaa iii < < « ¢ m0002CO 0 4) m a a; I— cv LO1.0LOooLOLOLO � 0 T T T T T T T 0 0 c 0 0 0 0 0 0 0 0 0 W Z O N N N N N N N N N Z �- Q w .� CO C`7 N C Q N N N N O W O J N Cr N N CV N N CV N Z a W U 0 W CU O. 'V' t v 0 0 t ct Q CI J I- J J W W Cr d O m o p W -I J Q O W W < < a cn LL E tL Cn a w a) E zQaQQarrrr 0 0 0 0 0 0 0 0 OI u_ a Cn O LL N X u_: V- V- 4N444t no fa- aact —J00wa 0 0 0 0 0 0 0 0 0 < < CO CO LL T. cn cn a w • • I Packers and SSV's Attachment PBU 04-01A SW Name Type MD TVD Depscription 04-01A SSSV 2155 2154.97 4-1/2" K Valve 04-01A TBG PACKER 8928.15 8276.31 4-1/2" Baker S-3 Hydro Set Packer 04-01A TBG PACKER 9061.76 8395.51 5-1/2" Baker FB-1 Packer • Wireline Work Request Ver6/6/01 A 11 global wells organization Distribution Wireline(4) Well: 04-01A AFE: APBWELIRSL Reading File Date: 5/20/2015 Engineer: Kenda IOR: 200 FTS: Yes AWGRS Job Scope: SSSV for Rate H2S Level: Problem Description K-Valve installed in well is closing at a higher Pwh than necessary. Redeisgn K Valve with a lower • set pressure to allow well to produce at a lower Pwh for increased IOR Valve is currently closing at approximately 1000 psi Pwh.WII lower set pressure in attempt to have well shut in at a Pwh of 725 psi Initial Problem Review Well was recently reperfed, seeing large increase in oil rate and formation gas rate. Well does not require lift gas as of right now. Plan is to lower set pressure by 275 psi from previous set pressure of 903 psi©60 degrees. Remedial Plan -WIRELINE ACTION DSO: Please flow well at flowing well head pressure greater than 725 psi. HES: "K"Valve Test Rack Set Pressure 628 psi at 60 deg F. Date Work Completed Well Status/Results Date by Problem Resolved ? Y N : Well Review(Post GLV or Choke Installation) Pre Installation Post Installation Liquid Rate (STBL/D) Expected NOB: Avg. WC (%) Actual NOB: Lift Gas (MMSCF/D) MGOR used for NOB: TGLR (SCF/STBL/D) FTP (psi)/Steady? MAINTENANCE ONLY CLP (psi)/Steady? (e.g. Fix AC,Shallower for Slugging) Casing Press. (psi)/Steady? RATE (Non-Post-WW) Orifice Depth: (e.g.deepen, optimize orifice) IA Fluid Level: Post-Wellwork Date of FL Survey: / / Follow-up Recommendations: • • "K"Valve Calculation Sheet DS 04-01A Date: 05/08/15 Test Date 05/03/15 Gross Fluid Rate 7818 BLPD Flowing Well Head Pressure 774 psi Flowing Well Head Temperature 110 deg F GOR 3656 scf/bbl TGLR 1776 scf/bbl Flowing Pressure Calculations Based on Hagedorn-Brown Multiphase Flow Correlation "K"Valve Setting Depth TVD 2155 ft Flowing Tubing Pressure With Gas Lift NA psi Flowing Tubing Pressure Without Gas Lift 775 psi Valve set to close at 725# Pwh Flowing Tubing Pressure @ 775# Pwh 1118 psi "K"Valve Test Rack Set Pressure at 60 deg F 628 psi Valve Size &Volume Ratio 4.5" 1.314 NOTE: Well needs to flow at> 725# Pwh Valve set to close at 725# Pwh • S Tubing Pressure at Valve 966 BPT(psis) 980 >1238 <1238 Temperature (deg F) at Valve 138 a 1.435E-05 2.38212E-05 b 1.179244 1.150852 Base Pressure 852.521739 c -1001.226 -980.57628 Base Temp (TV-60) 78 840.44398 837.5246831 Corrected Pressure 837.524683 psia TCF 0.85426834 ✓olume Ratio for Valve Size = 1.314 Pb @ 60 = 825.223219 Test Rack Pressure = 628 l Volume Ratios 4 1/2" & 5 1/2" 1.314 3 1/2" 1.257 2 7/8" 1.211 2 3/8" 1.204 I Fttt= MC3 V OY well-IAD= WEN/OY O 4-01 A SAF OTEs. WELL REQUIRES A SSSV '"-41n- •ACTUATOR AXE ON CHROME TBG"-WELL ANGLE>70'@ 9592'""' THS _OKB.ET_EV=_. . I ' 1 MEA WITH I-COIL DURING 5/2007 CTD(04-01A)"' 64' BF.EP/= KOP= -3200' Max Angk 91° 10041' 215W —4-1/2'HES 13CRXNP,D=3.813" 131EH Datum MD= 10676' 9-5/8'CSG,47#, — 2464' 2169' —4-1/2"K VALVE INSTALLED 05/29/15 Datum ND= 8800'SS L-80,ID=8.681' GAS LFTMAICRIS [ 13-3/8-CSG,720,N-80,I)=12.34r —{ 2686' u ST MD TVD ( V TYPE VLV LATCH •PORT DATE 5 3231 3227 11 MAG DOME RK 16 06/19/07 L 4 5651 5414 30 MMG SO RK 20 06/19/07 3 7396 6917 28 MM3 DMY RK 0 04/26/07 2 8140 7571 28 MAG DMY RK 0 04/26/07 1 8838 8196 26 WAG DMY RK 0 04/26/07 Minimum ID =2.380" @ 10058' I I 890W 4-1/2"HES X PP,D=3.813" 3-3/16" x 2-7/8" XO 8930' H9-5/8"X 4-12"BKR S3 HYDRO PKR,D=3.875' I ' 8964' —4-1/2'HES X INP,D=3.813' 3.70"DEPLOY SLV w/4'GS PROFILE,D=3.00' 900T —3-12'OTIS X NP,D=2.813' 4-1/2"TBG,12.6#13CR80 VAM, —1 901T D152 bpf,D=3.958' fl_a (BEHIND( 901T H4-1/2'X 5-1/2'XO,D=3.958"(BND LNR) TL 4-1/2'TBG sE(0426/07) H 9022' ( "..-------- --029' —19-5/8"X 4-12'LIMOlEOVERSHOT 3-12'LNR,8.81#,L80 STL, H 9040' 0087 bpi,D=2.992' 9040' —3-12'X 3-3/16'X0,D=2.786' BEHIND _ __ 906W [H5-1/2"BKR SEAL ASSY CT LNR 9063' H9-5/8"X 5-12'BKR FB-1 PKR w/SEALBOR EXT. TOP OF MLLED CMT(DMS 04/29/07) —I "9185' • • 9172' --5-12"OTIS XN NO-GO np,D=4.45" API ,,, (CM TD 03/08/07) 5-1/2 TBG,17#,L-80 PC,.0232 bpf,D=4,892' H 9184' . 9183' -{5-1/2"BKR SI-EAR UT SUB BEHIND ► e 9184' —5-12"TUBNG TA (CMTD) CT LNR 9-5/8"LIAR,47#,S00-95,.0732 bpf,D=8.681" — 9747' �•�{ t♦� �MILLED WINDOW(04-01A CORRECTED)9278' 9287' ►" % . Fl3�FOF?/1Tl<)NSIJMAAARY1 ,. 8630' H3-3/16'BKR CUP(04/22!15) REF LOG: al.ON 05/16/07 ♦_`!_9�i►_5►`t_� m + ANGLE AT TOP FEW:34°Q 9300' '# , 10068' —3-3/16"X 2-Ire'XO, Note:Refer to Production DB for historical pert data 5517;i;►_N / " % D=2.380' SIZE SPF 1I1U VAL Opn/Sgz SHOT SCY N': // % 2' " 6 9300-9330 0 04/23/15 + l 10720' --2-7/8'WFD CEP 2" 6 9382-9397 0 04/23/15 �`-� (03/19/15) 2" 6 9408-9425 0 0422/15 �••: �• 2-1/2" 6 9464-9469 0 10/10/09 3-3/16'ii 6.2#,L-80 TCS 10058' N'' '.A'~.N 2-1/2" 6 9452-9457 0 10/10/09 .0076 bpf,D=2.80' J 'a," 2' 6 9970-10020 C 05/17/07 +�.,� ,. 2" 6 10500 10650 C 05/17/07 PBTD —1 11336"' % `. 2' 6 10770-10800 C 05/17/07 -%' 2' 6 10895-11300 C 05/17/07 2-7/8'Lf,6.16#,L80 STL,.0058 bpf,D=2.441' H 11369"' DA I L REV BY COMAEN S - DATE REV BY COMMENTS FRUDF10E BAY UNIT 01/10171 ORIGINAL COMPLETION 12/17/10 1143/JMD AIMED SSSV SAFETY NOTE WELL 04-01A 07/07/90 RWO 0323/15 SREYJMD SET CEP(03/19/15) FERMI No:`1070350 04/27/07 NORDIC2 RWO 04/24/15 BF/PJC CiBP SET/ADFERF(0422-04/23/15) AR No: 50-029-20078-01 05/18/07 NOimC2 CTD SIDETRACK(04-01A) 02/03/16 GRCITU-I K VLV UFIAATE PER STATE REQS SEC 34,T11 N,R15E, 1327'FM_&295'Fa 06/30/09 RCITLH DRG DRAFT MAL CORRECTIONS 10/14/09 MV/PJC ADFERFS(10/10/09) BP Exploration(Alaska) STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1 Operations Abandon ll Plug Perforations L Fracture Stimulate U Pull Tubing U Operations shutdown ❑ Performed Suspend ❑ Perforate E Other Stimulate ❑ Alter Casing ❑ Change Approved Program ❑ Plug for Rednll ❑ Perforate New Pool Repair Well ❑ Re-enter Susp Well ❑ Other e/8 P 2 Operator 4 Well Class Before Work 5 Permit to Drill Number BP Exploration(Alaska),Inc Name Development El Exploratory❑ 207-035-0 3 Address P 0 Box 196612 Stratigraphic ❑ Service❑ 6.API Number Anchorage,AK 99519-6612 50-029-20078-01-00 7 Property Designation(Lease Number) 8 Well Name and Number ADL0028324 PBU 04-01A 9 Logs(List logs and submit electronic and pnnted data per 20AAC25 071) 10 Field/Pool(s) PRUDHOE BAY,PRUDHOE OIL 11 Present Well Condition Summary RECEWED Total Depth measured 11374 feet Plugs measured See Attachment feet true vertical 8994 87 feet Junk measured None feet ,JUN 0 1 2015 Effective Depth measured 9530 feet Packer measured See Attachment feet AOG VC true vertical 8741 29 feet true vertical See Attachment feet Casing Length Size MD TVD Burst Collapse Structural None None None None None None Conductor See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Surface See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Intermediate See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Production None None None None None None Liner See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Perforation depth Measured depth 9300-9330 feet 9382-9397 _ feet 9408-9425 feet 9452-9457 feet 9464-9469 feet 9970-10020 feet 10500-10650 feet 10770-10800 feet 10895-11300 feet True Vertical depth 8605 55-8628 79 feet 8664 22-8673 34 feet 8679 71 -8689 02 feet 8702 98-8705 49 feet 8708 97-8711 45 feet 8795 67-8797 77 feet 8815 28-8855 76 feet 8894 82-8904 47 feet 8.925 75-8983 69 feet Tubing(size,grade,measured and true vertical depth) See Attachment See Attachment See Attachment Packers and SSSV(type,measured and true vertical depth) See Attachment See Attachment See Attachment Packer 4-1/2"K Valve 2155 2154 97 SSSV 12 Stimulation or cement squeeze summary Intervals treated(measured) SCANNED o t' , Treatment descriptions including volumes used and final pressure 13 Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 95 0 9708 1699 235 Subsequent to operation 70 780 9970 1671 229 1 14 Attachments. '15 Well Class after work Copies of Logs and Surveys Run ❑ Exploratory ❑ Development (] Service ❑ Stratigraphic ❑ Daily Report of Well Operations E 16 Well Status after work Oil 0 Gas ❑ WDSPL ❑ Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP ❑ SPLUG ❑ 17 I hereby certify that the foregoing is true and correct to the best of my knowledge Sundry Number or N/A if C 0 Exempt N/A Contact Garry Catron Email Garry.Catron@BP.Corn Printed Name Garry Catron Title PDC PE Signature il64A.,_....? Phone 564-4424 Date 6/1/2015 It 71- &,/j SJi RBDMSj JUN - 3 2015 '774 � 04-01A 207-035 Plugs Attachement SW Name Date MD Description 04-01A 4/23/2015 9530 3-3/16" Baker CIBP 04-01A 3/20/2015 10720 2-7/8"WFD CIBP Packers and SSV's Attachment 207-035 SW Name Type MD ND Depscription 04-01A SSSV 2155 2154.97 4-1/2" K Valve 04-01A - PACKER 8928.15 8276.31 4-1/2" Baker S-3 Hydro Set Packer 04-01A PACKER 9061.76 8395.51 5-1/2" Baker FB-1 Packer m H O 0 CD CD CD oUP - 01Tr Lc) M NNNCNO V CD CD M N CD Or- N O UP Up O• M 01 t 0 01 4 m• � NCOCOI00 MO• TrTro � U/ (NJ 6toN- NNCD Ul T- OD �- f- M I- CO M N CD M CD CD• 4 to N T- CO T- f, N NrCD CO CM E9oD Co Nr- OO N- (A o to 00 CO O AANt M (D 1- Mr- T- T- Cto O ,— N toN- tocoto D M v- NOOCD N- N to to N- N- N T- to N- O N C° M r (O N to N CA 00 M to N T- to N- • O 0 T- NtoNCONNNNCDO 6 T O 00 M CD M M N- N M N to N- OD 00 OD T- to 4.0 M O cq op UD OV to al N N- oo O O M O T- OD(D O OD T- OD T- N to CO CD CD OD N CD CD I I 1 , 1 , I , , M Q L (A " M COD Tr tUl M OMO M N CA CD T N COM NONNt000coma NC) • 0 .0o • N rn �— CD rnOo0a00Io O 'n aoo O ao I N aD ao 0 ao 2YJUOU4m �# *kMJ C - 4# fn 00 N 4t • Cp N c4 Ni lt 01 ,r to 4# O CD T f— (O (A M - O N- 00 _ CO - 00 00 T- ZNI V ObtjcoEo T- UIMM - N N O -(45't M N Af1";" � M- to CD I CDM M 4 CD pMMNMN- CDCD CroI- COCDO C N M Tr 0 O CA N CD 01 O N 'Cr 0 0 a) NMCN- ' 03 T- J W W W W Q Q Q Q H U U w w CI CI w w w w V• OO tk CCCCCju.. u.. 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MCOY 0 4 01 A V� 1LFEAD= MCEVEVOY � SAFETY NOTES: WELL RBQURPS A SSSV ""4-112" ACTUATOR= AXELSON CHROME TBG"'WELL ANGLE>700 @ 9592'""DEPTHS OKB ELEV= 64' I I MEASURED WITH I-COIL DURING 5/2007 CTD(04-01A)"" BF.ELEV= ? KOP= 3200' 2159' —4-1/2'HES 13CR X NE'D=3.813" Max Angle= 91'@10041' Datum MD= 10676' 9.5/8"CSG,47#, —{ 2464' 1--,'"< >K Datum?VD= 880°'SS L-80,D=8.681" GAS LFT MANDRELS 13-3/8"CSG,72#,N-80,13=12.347" H 2686' ST MD TVD DEV TYPE VLV LATCH PORT DATE 5 3231 3227 11 MIG DOME RK 16 06/19/07 4 5651 5414 30 MMG SO RK 20 06/19/07 3 7396 6917 28 MM3 DMY RK 0 04/26/07 2 8140 7571 28 MAG DMY RK 0 04/26/07 1 8838 8196 26 MM3 DMY RK 0 04/26/07 Minimum ID =2.380" @ 10058' 8909' --14-112"res X NP,D=3.813" 3-3/16" x 2-7/8" XO ��� �� 8930' H9-5/8"X 4-1/2"BKR S3 HY DRO PKR,D=3.875" _ _ 8954' H4-1/2"HES X NP,13=3.813" 8983' —13.70"DEPLOY SLV w/4"GS PROFILE,D=3.00" I 9007' —I 3-1/2"0115 X NP,D=2.813" 4-1/2"TBG,12.6#13CR80 VAM, H 9017' .0152 bpf,D=3.958" --4 9017' —14-1/2"X 5-1/2"XO,D=3.958"( LNR) 4-1x2"TBG STUB(04/26/07) —I 9022' ger _ 9029' —19-518"X 4-1/7 UNIQUE OVERSHOT 3-1/2"LNR,8.81#,L80 STL, --I 9040' 0087 bpf,D 2.992' 9040' —13-1/2'X 3-3/16"XO,ID=2.786" BEHIND 1117-.-74 _ __ 9059' —15-1/2"BKR SEAL ASSY CT LNR 9063' H 9-518'X 5-1/7 BKR FB-1 PKR w/SEALBOR EXT. TOP OF MLLED CMT(DMS 04/29/07) —I *"9185' 9172' J--5-1/2"OTIS XN NO-GO TIP,D=4A5" to 5-1/2"TBG,17#,L-80 IPC,.0232 bpf,ID=4.892" —1 9184' qy�► ry (CMT'D 0310$/07) 6.- -614.16,41,e'e, ,AN 9183' —15-1/2"BKR SrEAROUT SUB BEHIND 9184' 5-1/2"TUBING TAIL(CMT'D) CT LNR 9-5/8"LNR 47#,S00-95,.0732 bpf,D=8.681' H 974T . MILLED WW DOW(04-01A CORRECTED)9278'-9287' .1 PERFORATION SUMMARY ,. 9630' —{3-3/16"BKR CEP(04/22/15) REF LOG: CNL ON 05/16/07 ,MI x ,- ,_ ANGLE AT TOP FERE:34"@ 9300" - " 10058' —3-3/16"X 2-7/8"XO, Note:Refer to Production 06 for historical pert data �' �e D=2.380" SIZE SPF INTERVAL Opn/Sqz SHOT SQZ - ''Ar��.,, 2" 6 9300-9330 0 04/23/15 :,, a 10720' 2-7/8"INFO CEP 2" 6 9382-9397 0 04/23/15 —:•••... "•...., (03/19/15) 2" 6 9408-9425 0 04/22/15 "•�`' A 2-1/2" 6 9464-9469 0 10/10/09 - ``� )i'� 3 3/16"LIR,6.2#,L-80 TCS 10058' �i40, , 2-1/7 6 9452-9457 0 10/10/09 .0076 bpf,ID=2.80" y� r, 2" 6 9970- 10020 C 05/17/07 r 2" 6 10500-10650 C 05/17/07 PBTD —{ 11335*** N 2" 6 10770-10800 C 05/17/07 ����' 2" 6 10895-11300 C 05/17/07 2-7/8"LW,6.16#,L80 SU,.0058 bpf,ID=2.441' H 11369'*' DATE REV BY COMMENTS DATE REV BY C OMNENTS PRUDHOE BAY MT 01/10/71 ORIGINAL COMPLETION 06/30/09 RC/TLH DRLG DRAFT FINAL CORRECTIONS WELL: 04-01A 07/07190 RWO 10/14/09 MV/PJC ADPERFS(10/10/09) PERMIT No:'2070350 04/27/07 NORDIC2 RWO 12/17/10 MB/JMD ADDED SSSV SAFETY NOTE API No: 50-029-20078-01 05/18/07'NORD1CZCTD SIDETRACK(04-01A) 03/23/15 SRLYJMD SET CUP(03/19/15) SEC 34,T11 N,R15E,1327'FNL&295'FEL 06/19/07 GJF/PJC GLV CIO 04/24/15 BF/PJC CEP SET/ADPERF(04/22-04/23/15) 06/15/09 RC/TLH DRLG DRAFT CORRECTIONS BP Exploration(Alaska) Wallace, Chris D (DOA) From: AK, D&C Well Integrity Coordinator <AKDCWeIllntegrityCoordinator@bp.com> Sent: Tuesday, May 12, 2015 12:48 PM To: AK, OPS FS2 OSM; AK, OPS FS2 DS Ops Lead; AK, OPS FS2 Facility OTL; AK, OPS FS2 Field OTL; AK, OPS PCC EOC TL; AK, D&C Wireline Operations Team Lead; AK, D&C Well Services Operations Team Lead; Cismoski, Doug A; AK, RES GPB East Wells Opt Engr; AK, OPS EOC Specialists; Daniel, Ryan; AK, RES GPB West Wells Opt Engr; G GPB FS2 Drillsites; Phillips, Patti J;Wallace, Chris D (DOA) Cc: AK, D&C DHD Well Integrity Engineer; AK, D&C Well Integrity Coordinator; AK, D&C Projects Well Integrity Engineer; AK, OPS FF Well Ops Comp Rep; Sternicki, Oliver R; Regg, James B (DOA) Subject: OPERABLE: Producer 04-01A (PTD #2070350) SSSV installed Attachments: image001.jpg; image002.png All, Producer 04-01A(PTD#2070350) has previously operated without a sub-surface safety valve (SSSV) due to a passing No Flow Test(NFT) on 12/31/13, as per 20 AAC 25.265(1)(1)(B). Recent wellwork has been performed, invalidating the previous test and subsequent approval. The well is required to have a SSSV when online as per 20 AAC 25.265(d) to prevent the possibility of unassisted flow of hydrocarbons to surface. The sub-surface safety valve was installed on 05/11/15.The well is reclassified as Operable. Please call with any questions. Thank you, SCANNED MAY 2 1 2015 Kevin Parks (Alternate Whitney Pettus) BP Alaska-Well Integrity Coordinator GWGlobal Wells Y Y Organization Office: 907.659.5102 WIC Email:AKDCWeIllntegrityCoordinator@bp.com From: AK, D&C Well Integrity Coordinator Sent: Wednesday, April 29, 2015 2:35 PM To: AK, OPS FS2 OSM; AK, OPS FS2 DS Ops Lead; AK, OPS FS2 Facility OTL; AK, OPS FS2 Field OTL; AK, OPS PCC EOC TL; AK, D&C Wireline Operations Team Lead; AK, D&C Well Services Operations Team Lead; Cismoski, Doug A; AK, RES GPB East Wells Opt Engr; AK, OPS EOC Specialists; Daniel, Ryan; AK, RES GPB West Wells Opt Engr; G GPB FS2 Drillsites; Phillips, Patti J Cc: AK, D&C DHD Well Integrity Engineer; AK, D&C Well Integrity Coordinator; AK, D&C Projects Well Integrity Engineer; AK, OPS FF Well Ops Comp Rep; AK, D&C WL Completions Superintendent Subject: UNDER EVALUATION: Producer 04-01A (PTD #2070350) All, 1 Producer 04-01A(PTD#2070350) recently failed a No Flow Test,therefore a sub surface safety valve (SSSV) is required. In order to establish the correct setting for the K valve, down hole pressures gauges has been set in the SSSV nipple to get accurate flowing pressure.The well is reclassified as Under Evaluation and can be brought on line to get the required data. Please call with any questions. Thanks, Kevin Parks (Alirrn(11( Whilnry Pettus) BP Alaska-Well Integrity Coordinator GINGlobal Wells Organization Office: 907.659.5102 WIC Email:AKDCWellIntegrityCoordmator@bp.com From: AK, D&C Well Integrity Coordinator Sent: Sunday, March 29, 2015 3:15 PM To: AK, OPS FS2 OSM; AK, OPS FS2 DS Ops Lead; AK, OPS FS2 Facility OTL; AK, OPS PCC EOC TL; AK, D&C Wireline Operations Team Lead; AK, D&C Well Services Operations Team Lead; Cismoski, Doug A; AK, RES GPB East Wells Opt Engr; AK, OPS EOC Specialists; Daniel, Ryan; AK, RES GPB West Wells Opt Engr; G GPB FS2 Drillsites; Phillips, Patti J; Stechauner, Bernhard; AK, OPS FS2 Field OTL; 'Regg, James B (DOA) (jim.regg@alaska.gov)'; 'chris.wallace@alaska.gov' Cc: AK, D&C Well Integrity Coordinator; AK, D&C DHD Well Integrity Engineer; AK, D&C Projects Well Integrity Engineer; AK, OPS FF Well Ops Comp Rep; Sternicki, Oliver R Subject: NOT OPERABLE: Producer 04-01A (PTD #2070350) Failing NFT post wellwork All, Producer 04-01A(PTD#2070350) recently had downhole wellwork performed.Subsequently,the well has been unable to pass a No-flow Test and as a result will need a SSSV in order to operate accordance with regulation 20 AAC 25.265. The well has been reclassified as Not Operable until the required valve has been installed. Please call with any questions. Thank you, Laurie Climer (Alternate:Kevin Parks) BP Alaska-Well Integrity Coordinator GW G crlki Wt,ris Diganirmt•on WIC Office: 907.659.5102 WIC Email: AKDCWelllntegrityCoordinator@BP.com 2 Wallace, Chris D (DOA) From: AK, D&C Well Integrity Coordinator <AKDCWellIntegrityCoordinator@bp.com> Sent: Sunday, March 29, 2015 3:15 PM To: AK, OPS FS2 OSM;AK, OPS FS2 DS Ops Lead;AK, OPS FS2 Facility OTL;AK, OPS PCC EOC IL;AK, D&C Wireline Operations Team Lead; AK, D&C Well Services Operations Team Lead; Cismoski, Doug A;AK, RES GPB East Wells Opt Engr;AK, OPS EOC Specialists; Daniel, Ryan;AK, RES GPB West Wells Opt Engr; G GPB FS2 Drillsites; Phillips, Patti J; Stechauner, Bernhard; AK, OPS FS2 Field OTL; Regg,James B (DOA);Wallace, Chris D (DOA) Cc: AK, D&C Well Integrity Coordinator;AK, D&C DHD Well Integrity Engineer;AK, D&C Projects Well Integrity Engineer; AK, OPS FF Well Ops Comp Rep; Sternicki, Oliver R Subject: NOT OPERABLE: Producer 04-01A(PTD#2070350) Failing NFT post wellwork Attachments: 04-01A NFT Approval 01-10-14.pdf; image001jpg All, Producer 04-01A(PTD#2070350) recently had downhole wellwork performed.Subsequently,the well has been unable to pass a No-flow Test and as a result will need a SSSV in order to operate accordance with regulation 20 AAC 25.265. The well has been reclassified as Not Operable until the required valve has been installed. Please call with any questions. Thank you, Laurie Climer (Alternate:(Alternate: Kevin Parks) SC NNE© ��, -`'� �� s _ BP Alaska-Well Integrity Coordinator GINGlow!Wells �/V Drganizaton WIC Office: 907.659.5102 WIC Email: AKDCWeIIIntegrityCoordinator@BP.com 1 e P~ect Well Histo File Co~ Pa e Imag ~ ry g 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. Q ~ - Q~~j Well History File Identifier Organizing (done) o.~..;~ IIIIIIIYIIIIIIII R~~~~ ~iiisiiiiuiuu RES AN Color Items: ^ Greyscale Items: ^ Poor Quality Originals: ^ Other: NOTES: DIG AL DATA Diskettes, No. ^ Other, No/Type: OVERSIZED (Scannable) ^ Maps: ^ Other Items Scannable by a Large Scanner OVERSIZED (Non-Scannable) ^ Logs of various kinds: ^ Other:: BY: Maria Date: /s/ ~ Pro'ect Proo>>:ng II I I I ~I II I~ I I I I II I BY: Maria Date: /s/ x 30 = + =TOTAL PAGES Scanning Preparation ~_ ~/ I ~ /D ~ Ceunt fees not include cover sheet) ,t/~/~ BY: Maria Date: /s/ Y -~{~ Production Scanning .. i n ^i u n ~n ~ ~ ^n Stage 1 Page Count from Scanned File: --r~-=-- (Count does include cove heet) h Number in Scannin Pre aration: V YES NO Page Count Matc es 9 P BY: Maria Date: ~ ~ $ O /s/ Stage 1 If NO in stage 1, page(s) discrepancies were found: YES NO BY: Maria Date: /~ Scannin is complete at this point unless rescanning is required. II I II ~I II I II ~ I I III 9 Rescanned III 1111111111 IIIII BY: Maria Date: /~ Comments about this file: Quality Checked III II'lII III II'I III 1.0/6/2005 Well History File Cover Page.doc MEMORANDUM • State of Alaska • Alaska Oil and Gas Conservation Commission DATE: Friday, November 12, 2010 TO: Jim Regg P.I. Supervisor �� 1q , I SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC 04 -01 A FROM: Jeff Jones PRUDHOE BAY UNIT 04 -01A Petroleum Inspector Src: Inspector Reviewed By P.I. Supry s 2 NON - CONFIDENTIAL Comm Well Name: PRUDHOE BAY UNIT 04 -OIA API Well Number: 50- 029 - 20078 -01 -00 Inspector Name: Jeff Jones Insp Num: mitJJ101110183245 Permit Number: 207 -035 -0 Inspection Date: 11/10/2010 Rel Insp Num: Packer Depth Pr etest Initial 15 M in. 30 Min. 45 Min. 60 Min. Well 04-OIA Type Ind. N' TVD 8260 I 410 410 415 415 415 — —— P.T.D 2070350 jTypeTest SPT Test psi 2500 'r OA 120 120 130 130 ! 130 I nterval OTHER P/F P Tubing 380 2500 2420 2380 2380 Notes: MIT -T on a shut in suspended well. No well house. 3.6 BBLS diesel pumped. 1 well inspected, no exceptions noted. - NOV Friday, November 12, 2010 Page 1 of I OPERABLE: Producer 04-OlA (PTD~70350) IAxOA communication mana~ble by bleeds Page 1 of 2 Regg, James B (DOA) From: AK, D&C Well Integrity Coordinator [AKDCWeIIlntegrityCoordinator@bp.com] ~~~ ~C~o~~o Sent: Thursday, July 22, 2010 10:09 PM j To: Regg, James B (DOA); Maunder, Thomas E (DOA); Schwartz, Guy L (DOA); AK, OPS FS2 DS Ops Lead; AK, OPS FS2 Facility OTL; AK, OPS FS1 OSM; Engel, Harry R; AK, RES GPB East Production Optimization Engineer; AK, OPS EOC Specialists; AK, RES GPB West Production Optimization Engineer; Cismoski, Doug A; AK, D&C Well Services Operations Team Lead; AK, D&C Wireline Operations Team Lead Cc: Bommarito, Olivia O; Janowski, Carrie; AK, D&C Well Integrity Coordinator Subject: OPERABLE: Producer 04-01A (PTD#2070350) IAxOA communication manageable by bleeds All, Producer 04-01A (PTD# 2070350) was recently shut-in due to unmanageable IAxOA communication. On 07/16/10, the inner casing hanger seals were re-energized followed by an OA repressurization test yielding abuild-up-rate ~6 psi/day. The well has been reclassified as Operable and may continue to be produs~.ed. P-ease let Well Integrity know if the OA pressure build-up-rate becomes unmanageable by bleeds. Thank you, Torin Roschinger (alt. Jerry Murphy) Well Integrity Coordinator Office (907) 659-5102 Harmony Radio x2376 Cell (406) 570-9630 Pager (907) 659-5100 Ext. 1154 From: AK, D&C Well Integrity Coordinator Sent: Monday, July 12, 2010 5:14 PM To: AK, D&C Well Integrity Coordinator; 'Regg, James B (DOA)'; 'Maunder, Thomas E (DOA)'; 'Schwartz, Guy (DOA)'; AK, OPS FS2 DS Ops Lead; AK, OPS FS2 Facility OTL; AK, OPS FSl OSM; Engel, Harry R; AK, RES GPB East Production Optimization Engineer; AK, OPS EOC Specialists; AK, RES GPB West Production Optimization Engineer; Cismoski, Doug A; AK, D&C Well Services Operations Team Lead; AK, D&C Wireline Operations Team Lead Cc: Bommarito, Olivia 0; King, Whitney Subject: UNDER EVALUATION: Producer 04-O1 (PTD#2070350) Confirmed Sustained OA Casing Pressure All, Producer 04-01 (PTD# 2070350) has confirmed sustained casing pressure on the OA. The wellhead pressures were Tbg/IA/OA at SSV/1840/1270 on 07/12/10. The well has been reclassified as Under Evaluation. It may be produced up to 28 days for diagnostics and repair work. A TIO plot and wellbore schematic have been included for reference. The plan of action is as follows. 1. DHD: OA repressurization test - 2. W: PPPOT-IC 3. DHD: OA repressurization test (pending PPPOT-IC results) Please contact Well Integrity with any questions or concerns. ~~.. « File: 04-01 TIO Plots.doc» « File: 04-01A WBS.pdf» Thank you, 8/10/2010 OPERABLE: Producer 04-OlA (PTD~70350) IAxOA communication mana~ble by bleeds Page 2 of 2 Tiffany Quy (for the Well Integrity Coordinator Gerald Murphy/Torin Roschinger) Projects Well Integrity Engineer phone: (907) 659-5102 cell: (253) 576-6153 tiffg0@bp.com 8/10/2010 UNDER EVALUATION: Producer~Olpl(PTD#2070350) Confirmed Susta~d OA Casing Pre... Page 1 of 1 Regg, James B (DOA) From: AK, D&C Well Integrity Coordinator [AKDCWeIIlntegrityCoordinator@bp.com] ~~~ 7 I~S~~° Sent: Monday, July 12, 2010 5:14 PM To: AK, D&C Well Integrity Coordinator; Regg, James B (DOA); Maunder, Thomas E (DOA); Schwartz, Guy L (DOA); AK, OPS FS2 DS Ops Lead; AK, OPS FS2 Facility OTL; AK, OPS FS1 OSM; Engel, Harry R; AK, RES GPB East Production Optimization Engineer; AK, OPS EOC Specialists; AK, RES GPB West Production Optimization Engineer; Cismoski, Doug A; AK, D&C Well Services Operations Team Lead; AK, D&C Wireline Operations Team Lead Cc: Bommarito, Olivia O; King, Whitney Subject: UNDER EVALUATION: Producer 04-01 (PTD#2070350) Confirmed Sustained OA Casing Pressure Attachments: 04-01 TIO Plots.doc; 04-01A WBS.pdf All, ~~ ~~,®t P~ Producer ~ (PTD# 2070 50) has confirmed sustained casing pressure on the OA. The wellhead pressures were Tbg/IA/OA at SSV/1840/1270 on 07/12/10. The well has been reclassified as Under Evaluation. It may be produced up to 28 days for diagnostics and repair work. A TIO plot and wellbore schematic have been included for reference. The plan of action is as follows. 1. DHD: OA repressurization test ~ 3 ,, 3. DHD: OA repressurization test (pending PPPOT-IC results) ~~~ ~ = 53~o~s~ Please contact Well Integrity with any questions or concerns. `~Gp = 23, 6aC©~f N~~P ; ~~, «04-01 TIO Plots.doc» «04-01A WBS.pdf» ~ Thank you, Tiffany Quy (for the WeII Integrity Coordinator Gerald Murphy/Torin Roschinger) Projects Well Integrity Engineer phone: (907) 659-5102 cell: (253) 576-6153 tiffg0@bp.com 7/15/2010 PBU 04-01A PTD 2070350 7/12/2010 TIO Pressures Plot a,ooo 3,000 z,aao 1,aoo 04/17/10 0424/10 05!01 /10 05/OBn0 05/15/10 0522n0 wee: o~-m ~- T6g -f- IA -4-- OA OOA • OOOA o~ o ,- osrosno osnzno T osnsno os~zsno m/oano o7nono • TREE = MCEV Ol' WELLHEAD= MCEVOY ACTUATOR = AXELSON KB. ELEV.-. 64' BF. ELEV = KOP - 3200' Max Angle = 91 (a7 10041' Datum MD = 1067ti' Datum TVD = 8800' SS 9-5/8" CSG, 47#, L-80, ID = 8.681" 13-318" CSG, 72#, N-80, 1D = 12.347" I 2464' 1 GAS LIFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE 5 3231 3227 11 MMG DOME RK 18 06!19/07 4 5651 5414 30 MMG SO RK 20 06!19!07 3 7396 6917 28 MMG DMY RK 0 04!26!07 2 8140 7571 28 MMG DMY RK 0 04!26!07 1 8838 8196 26 MMG DMY RK 0 04(26!07 I 2686' I $909' 4-112" HES 13CR X NIP, ID = 3.813" $930' 9-5/8" X 4-112" BKR S3 HYDROSET PKR, ID = 3.875" 89~ 4-1/2" HES 13CR X NIP, ID = 3.813" Minimum ID = 2.380" @ 10058' 3-3116" x 2-718" Xt~ 4-i/2" TBG, 12.6# 13CR80 VAM, .0152 bpf, ID = 3.958" 13-112" LNR, 8.81#, L80 STL, .0087 bpf, ID = 2.992" I 8983"''' --3.70" DEPLOY 5LV w/ 4" GS PROFILE, ID = 3.00"~ g007' 3-112" OTIS X NIP, ID = 2.813" 9017' 4-1/2" X 5-112" XO, ID = 3.958" {BEHIND PIPE] 9022' TOP OF TBG STUB (TAG 04126/07) {BEHIND PIPE) 9029' 9-518" X 4-1/2" UNIQUE OVERSHOT (BEHIND PIPE) 9040' 3-1/2" X 3-3/16" XO, ID = 2.786" {BEHIND PIPE) 9059' 5-112" BAKER SEAL A5SY (BEHIND PIPE] 9063' 9-518" X 5-112" BAKER. FB-1 PKRw/SEALBOR EXT. 9185°"" TOP OF MILLED CEMENT (DIMS 04/29/07} 9172' 45" -1 /2" OTIS XN NO-GO NIP, ID = ~ ( CMT'D 03/08/07 & BEHIND PIP 9183' S-112" BKR SHEAROUT SUB (CMT'D & BEHIND PIPE] 9184' S-1/2" TUBING TAIL (GMT'D & BEHIND PIPE] I 9017' I I 9040' i 5-1 /2" TBG, 17#, L-80 IPC, .0232 bpf , ID = 4.892" I 9184' HEELED WINDOW (CORRECTED}: 9278' - 928T 9-518" LNR, 47#, SOO-95, .0732 bpf, ID = 8.681" ~ 9747' PERFORATION SUMMARY REF LOG: CNL ON 05/16!07 ANGLE AT TOP PERF: 64' @ 9452" Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 2-1/2" 6 9452 - 9457 O 10/10/09 2-112" 6 9464 - 9469 O 10/10/09 2" 6 9970 - 10020 O 05/17/07 2" 6 10500 - 10650 O 05/17/07 2" 6 10770 - 10800 O 05!17/07 2" 6 10895 - 11300 O 05/17/07 DATE REV BY COMMENTS DATE REV BY COMMENTS 01/10/71 ORIGINAL COMPLETION 06/30/09 RC/TLH DREG DRAFT FINAL CORRECTIONS 07107190 RWO 10!14/09 NN/PJC ADPERFS (10/10!09) 04/27(07 NORDIC2 RWO 05/18!07 NORDIC2 CTD SIDETRACK (04-01Aj 06(19107 GJF/PJC GLV C/O 08115/09 RCITCH DREG DRAFT CORRECTIONS PRUDHOE BAY UNIT WELL: 04-01 A PERMIT No: 2070350 API No: 50-029-20078-01 SEC 34, T11 N, R15E, 3815.26' FEL & 3818.38' FNL BP Exploration (Alaska) 10058' -j 3-3/16" X 2-718" I XO, ID = 2.380" 3-3/16" LNR, 6.2#, L-80 TCII, .0076 bpf, ID = 2.80" PBTD 11335°*~ ~ 2-7/8" LNR, 6.16#, L80 STL, .0058 bpf, ID = 2.441" 11369'~`~` • ~,- ~' ~~ ~,. ~, '~ ; ~~° ,~ ~,,~ _ ~~ "~_ r r ~ ~ . ~. ~~. ~ ~ ~ ~~ h "iw.~. ".. ~~ 4. MICROFILMED 6/30/2010 DO NOT PLAC E ANY NEW MATERIAL UNDER THIS PAGE C:\temp\Temporary Internet Fiies\OLK9\Microfilm_Marker.doc STATE OF ALASKA ALA~OIL AND GAS CONSERVATION COMMIS REPORT OF SUNDRY WELL OPERATIONS ~RECEI~/~C~ ocT r ~ zoo~ NY....Y.., nY o_ n__ n 1. Operations Abandon ~ Repair V1Q Plug Pertorations ~ Stimulate ~ er ' Performed: Atter Casing ~ Pull Tut~ Perforate New Pool ~ Waiver~ Time Extension ^ Anchorag~ Change Approved Program ~ Operat. Shutd~ Perforate Q Re-enter Suspended Well ~ 2. Operator BP Exploration (Alaska), Inc. 4. Well Class Before Work: `^~ 5. Permit to Drill Number: Name: Development ^~ Exploratory ^ 207-0350 3. Address: P.O. Box 196612 Stratigraphic^ Service ^ 6. APt Number: Anchorage, AK 99519-6612 ~= 50-029-2007&01-00 8. operty Designation (Lease Number) : 9. Well Name and Number: ADLO-028324 ~ PBU 04-01A 10. ' Id/Pool(s): PRUDHOE BAY FIELD / PRUDHOE OIL POOL 11. Present Well Condition Summary: ~' Total Depth measured 11374 feet Plugs (measured) None feet true vertical 8994.87 feet Junk (measured) None feet Effective Depth measured 11335 feet Packer (measured) 8930' 9063' true vertical 8988.94 feet (true vertical) 8278' 8397' Casing Length Size MD ND Burst Collapse Structural Conductor 115 30" 157# B SURFACE - 115 SURFACE - 115 880 Surface 1185 20" 133# /94# H&K SURFACE - 1185 SURFACE - 1185 2320 1500 Intermediate 2686 13-3/8" 72# N-80 SURFACE - 2686 SURFACE - 2686 4930 2670 Production 9278 9-5/8" 47# 43.5# 40# S/N SURFACE - 9278 SURFACE - 8587 Liner 2368 3-1/2"X3-3-3/16" L-80 8983 - 11369 8325 - 8994 Liner 2-7/8" 8.81#/6.2#/6.16# Perforation depth: Measured depth: SEE ATTACHED - _ _ _ _ True Vertical depth: _ _ _ _ _ Tubing: (size, grade, measured and true vertical depth) 4-1/2" 12.6# 13CR80 SURFACE - 9017' SURFACE - 8356' 5-1 /2" 1 ~# L-80 9017' - 91 &4' 8356' - 8504' Packers and SSSV (type, measured and true vertical depth) 9-5/8"X4-1/2" BKR S3 HYDROSET PKR 8930' 8278' 9-5/8"X5-1/2" BAKER FB-1 PKR 9063' 8397' 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing pressure Prior to well operation: 223 5011 8031 235 Subsequent to operation: 226 5361 8621 223 14. Attachments: . Well Class after work: Copies of Logs and Surveys Run Exploratory^ Development ^~ Service ^ Daily Report of Well Operations X Well Status after work: Oil ~ Gas WDSPL GSTOR ~ WAG ^ GINJ^ WINJ^ SPLUG ^ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: N/A Contact Gary Preble . Printed Name Gary Preble Title Data Management Engineer Signature Phone 564-4944 Date 10/13/2009 ~,~~y~' ~`~ ~~ ~~~ ~~L ~~ /d /y °~ ~ ~ Form 10-404 Revised 7/2009 Submit Originai Only 04-01 A 207-035 PFRF oTTOC:HMFNT Sw Name Operation Date Perf Operation Code Meas Depth Top Meas Depth Base Tvd Depth Top Tvd Depth Base 04-01A 5/17/07 PER 9,970. 10,020. 8,795.67 8,797.77 04-01A 5/17/07 PER 10,500. 10,650. 8,815.28 8,855.76 04-01A 5/17/07 PER 10,770. 10,800. 8,894.82 8,904.47 04-01A 5/17/07 PER 10,895. 11,300. 8,925.75 8,983.69 04-01 A 10/10/09 AP 5 9,452. 9,457. 8,702.98 8,705.49 04-01A 10/10/09 APF 5' 9,464, 9,469. 8,708.97 8,711.45 i ~ ~ ~ 04-OlA DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY FLUIDS PUMPED BBLS 1 MEOH 1 diesel 2 Total C 7 ~u~. e, DATA SUBMITTAL COMPLIANCE REPORT 6/2/2009 Permit to Drill 2070350 Well Name/No. PRUDHOE BAY UNIT 04-01A Operator BP EXPLORATION (ALASK/y INC API No. 50-029-20078-01-00 MD 11374 TVD 8995 Completion Date 5/17/2007 Completion Status 1-OIL Current Status 1-OIL UIC N REQUIRED INFORMATION Mud Log No Samples No Directional Survey Yes DATA INFORMATION Types Electric or Other Logs Run: MWD DIR, GR, RES, CNL / GR /CCL (data taken from Logs Portion of Master Well Data Maint Well Log Information: Log/ Electr Data Digital Dataset Log Log Run Interval OH / Typ Med/Frmt Number Name Scale Media No Start Stop CH Received Comments D Asc Directional Survey 9200 11374 Open 7/24/2007 pt Directional Survey 9200 11374 Open 7/24/2007 ~D C Las 15620 Induction/Resistivity 9249 11374 Open 10/26/2007 LAS, RPM, GR, RAM, ROP w/PDF graphics og 16016 Neutron 25 Blu 8654 11237 Open 3/13/2008 MCNL, GR, CCL, 15-May- ~'I 2007 C 16016 Neutron 25 8671 11232 Open 3/13/2008 LIS Veri GR, CNT pt LIS Verification 9520 11373 Open 1/20/2009 LIS Veri, GR, ROP, RAD, RAS, RPD, RPS D C Pds 17484 Induction/Resistivity 9520 11373 Open 1/20/2009 LIS Veri, GR, ROP, RAD, 'i RAS, RPD, RPS ', wog Induction/Resistivity 25 Col 9063 11374 Open 1/20!2009 MD MPR, GR 13-May-2007 I og Gamma Ray 25 Col 9063 11374 Open 1/20/2009 MD GR 13-May-2007 L- g Gamma Ray 25 Col 9063 11374 Open 1/20/2009 TVD GR 13-May-2007 `~'" See Notes 2 Col 9240 11372 Open 1/20/2009 Depth Shift Monitor Plot Well Cores/Samples Information: Name Interval Start Stop Sample Set Sent Received Number Comments DATA SUBMITTAL COMPLIANCE REPORT 6/2/2009 Permit to Drill 2070350 Well Name/No. PRUDHOE BAY UNIT 04-01A Operator BP EXPLORATION (ALASt(A) INC MD 11374 TVD 8995 Completion Date 5/17/2007 Completion Status 1-OIL Current Status 1-OIL ADDITIONAL INFORMQ~TION Well Cored? Y ~ Daily History Received? Y N Chips Received? 'rC % N Formation Tops ' N Analysis Y / N Received? API No. 50-029-20078-01-00 UIC N Comments: INTEQ Log ~ Data Transmittal Form To: State of Alaska -A®GCC 333 W. 7`h Ave. Suite 100 Anchorage, Alaska 99501 Attention: Christine Mahnken Reference: 04-OlA Contains the following: 1 LDWG Compact Disc ~~ (Includes Graphic Image files) 1 LDWG lister summary 1 color print - GR Directional Measured Depth Log (to follow) 1 color print - MPR/Directional TVD Log (to follow) 1 color print - MPR/Directional Measured Depth Log (to follow) LAC Job#: 1413210 Sent by: Terri Tuminello Date: 01/16/09, n - - ,~ r'` Lteceived by: ~ 1j ~` ~ Date: PLEASE ACKNOWLEDGE RECEIPT BY SIGNING & .RETURNING OR FAXING YOUR COPY FAX: (~07j 267-6623 Baker Hu hes INTE °`- "` T` ~->~~~ a 7260 Homer Drive ~ Anchorage, Alaska 99518 _ Direct: (907) 267-6612 INT~Q FAX: (907) 267-6623 / ~ , -- BAKER MVl~NES ~..I Baker Atlas PRINT DISTRIBUTION LIST CUMYANY BY EXYLUKA'I'lUN (ALASKA) 1NC CUUN'1'Y NOK'IH SLUYE BUKUUCiH WELL NAME 04-OlA STATE ALASKA FIELD PRUDHOE BAY UNIT DATE 1/16/2009 THIS DISTRIBUTION LIST AUTHORIZED BY: Terri Tuminello SO # 14113210 Copies of Copies Digital Copies of Copies Digital Each Log oFFilm Data Each Log of Film Deta 2 Company BP EXPLORATION (ALASKA) INC 1 Company DNR - DMSION OF OIL & GAS Person PETROTECHNICAL DATA CENTER Person KRISTIN DIRKS Address LR2-1 Address 550 WEST 7TH AVE 900 E BENSON BLVD. SUITE 802 ANCHORAGE, AK 99508 ANCHORAGE AK 99501 1 Company EXXON MOBIL PRODUCTION CO Company Person FILE ROOM Person Address 800 BELL STREET Address EMB GSC 3082A HOUSTON, TX 77002 1 Company STATE OF ALASKA - AOGCC Company Person CHRISTINE MAHNKEN Person Address 333 W. 7TH AVE Address SUITE 100 ANCHORAGE AK 99501 Company Company Person Person Address Address Company Company Person Person Address Address Data Disseminated Bv~ BAKER ATLAS-PDC 17015 Aldine Westfield, Houston, Texas 77073 Tlils Distribution List Comuleted Bv: v~.i"; ~' _ ~' Page 1 of 1 03!12!08 ~~~~~~~~ N0. 4629 Alaska Data & Consulting Services Company: State of Alaska 2525 Gambell Street, Suite aoo Alaska Oil & Gas Cons Comm Anchorage, AK 99503-2838 ATTN: Beth Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: P.Bay,Endicott ~,.~ .. ~ ,.,. ne ..+:,.., n~+e al c~hY rn C-176 12031461 USIT - 4ti 03/09/08 1 1 1-67/T-20 12014001 USIT - L .~ 03/09/08 1 1 E-216 11661157 MCNL a' 06/19/07 1 1 02-35B 11216177 MCNL ~ 02/09/06 1 1 C-34A 11216194 MCNL ~ ~ Q( 05/11/06 1 1 G-08A 11628761 MCNL ~ ~ 05/11/07 1 1 04-O1A 11661146 MCNL - 05/15/07 1 1 PLEASE AGKNUWLtUtat F{tt;t1Y1 l;SY SIIaNIIVIa Hrvu tStl Uti1V11VU VIVt I.VYT CHlin ~ v: BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 900 E. Benson Blvd. ` Anchorage, Alaska 99508 Date Delivered: t ' ~ ~ ~~-~~~~~ Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-283 ATTN: Beth Received by: C7 LJ I.J Date Z 0-12-2007 Transmittal Number:92914 BPXA WELL DATA TRANSMITTAL Enclosed are the materials listed below. (BPXA FIELD LOG DATA) If you have any questions, please contact Douglas Dortch at the PDC at 564-4973 ~a Delivery Contents 1 CD-ROM Containing Field Log Data & Electronic Log Prints for the following wells: 02-12B o~b~- =c~_ ~_~S__61~_. __... 02-16CPBiaO '~--0$~_ ~ S6!9 _ __ 04-01 A ~0~-D3.S ~` is an ------- 15-16B_~~, - v~3.___45~1_ 15-16BP61 _~~~~3 _E~~_______ 15-16BP6~ .:fin ~-^~"~ tsc,a3_ 18-27DP61_- _aQ~_13~._l_~~~-" _____ G-24A c?64- O~a__.1 J`~'7~-_ .._. G-24AP61 aUlo--s~~a.._!~~---___.__.._.~__._.. P2-11A ~QCo -G~olfo_ _lb-~a~9_._.____.___--_- P2-11 APB1 ._2C~ca-c~.al_fo..._1563 a_ _.._..___.__....-- P2-36A _ ~il~_- Qa_2.. _ 1573/.__.__ ..__ .....--- _. P2-37A a05-0~~--.__. t. _. -_~~~O3.a P2-37APB1..~p.5.',_D.S ~...~.~f,33.-.~.__ 102 '`_--- -- ~ ~P= ~ 102P6 Please Sign and Return one copy of this transmittal. Thank You, Douglas Dortch Petrotechnical Data Center Attn: State of Alaska - AOGCC Attn: Christine Mahnken 333 W. 7th Ave, Suite 100 Anchorage, Alaska 99501 Petrotechnical Data Center LRZ-1 900 E. Benson Blvd. PO Box 196612 Anchorage, AK 99519-6612 Page 1 of 1 Saltmarsh, Arthur C (DOA) From: Hubble, Terrie L [Terrie.Hubble@bp.com] Sent: Monday, October 22, 2007 1:37 PM To: Saltmarsh, Arthur C (DOA) Subject: PBU 04-01A / PTD # 207-035 H i Art, Please reference the following well: Well Name: PBU 04-01A Permit #: 207-035 API #: 50-029-20078-01-00 Top Perf MD: 9970' Bottom Perf MD: 11300' This well began Production on October 12,2007 Method of Operations is: Gas Lift Date of Test: August 24, 2007 Hours Tested: 3 24-Hour Rate /Oil-Bbl: 864 24-Hour Rate /Gas-Mcf: 648 24-Hour Rate /Water-Bbl: 3,431 Test Rate 1 Oil-Bbl: 108 Test Rate 1 Gas-Mcf: 81 Test Rate 1 Water-Bbl: 429 Choke Size: 128 Gas-Oi! Ration: 750 Flow Tubing Pressure: 209 Casing Pressure: 1,580 Oil Gravity-API: Unavailable 10/23/2007 STATE OF ALASKA ~-~ E~E~VE® ALASKA~IL AND GAS CONSERVATION COM~SSION .~ a--j;J~ 1 5 2007 f~ WELL COMPLETION OR RECOMPLETION REPORT AND LOG •,„v'>~a iii! ~ Gas Cons. Commission A-fnl.nr9[1G 1a. Well Status: ®Oil ^ Gas ^ Plugged ^ Abandoned ^ Suspended 1b. Well Class: zoAAC zs.,os zoAAC zs.,,o ®Development ^ Exploratory ^ GINJ ^ WINJ ^ WDSPL ^ WAG ^ Other No. of Completions One ^ Service ^ Stratigraphic 2. Operator Name: 5. Dat Comp , Susp., or Aban 12. Permit to Drill Number BP Exploration (Alaska) Inc. 5/17/2007 ~ 207-035 ~ 3. Address: 6. Date Spudded 13. API Number P.O. Box 196612, Anchorage, Alaska 99519-6612 5/5/2007 ~ 50-029-20078-01-00 4a. Location of Well (Governmental Section): 7. Date T.D. Reached 14. Well Name and Number: Surface: 5/13/2007 ~ PBU 04-01A ' ' ~ 1327 FNL, 295 FEL, SEC. 34, T11 N, R15E, UM Top of Productive Horizon: 8. KB (ft above MSL): 64'' 15. Field /Pool(s): 3684' FNL, 1871' FWL, SEC. 35, T11 N, R15E, UM Ground (ft MSL): 30' Prudhoe Bay Field / Prudhoe Bay Total Depth: 9. Plug Back Depth (MD+TVD) Pool 2996' FNL, 922' FWL, SEC. 35, T11N, R15E, UM 11335 8989 4b. Location of Well (State Base Plane Coordinates, NAD 27): 10. Total Depth (MD+TVD) 16. Property Designation: Surface: x- 712575 y- 5950537 Zone- ASP4 11374 ' 8995 - ADL 028324 _ TPI: x- 714810 y- 5948243 Zone- ASP4 11. SSSV Depth (MD+TVD) 17. Land Use Permit: Total Depth: x- 713840 y- 5948904 Zone- ASP4 None None 18. Directional Survey ®Yes ^ No 19. Water depth, if offshore 20. Thickness of Permafrost (TVD): Submit electronic and rinted information er 20 AAC 25.050 N/A ft MSL 1900' (Approx.) 21. Logs Obtained (List all logs here and submit electronic and printed infnrm~+~.,., ~~~ ~n ~ ~~ ~~ ^'1): MWD DIR, GR, RES, CNL / GR / CCL `j//~YGbiJG~ q~~'%~Q _ S~~ ~d 22. CASING, LINER AND CEMENTING RECORD CASING ^$ETTING DEPTH MD SETTING DEPTH'TVD :HOLE AMOUNT WT._PER FTr GRADE TOP BOTTOM TOP BOTTOM SIZE" CEMENTING RECORD PULLED 30" 157# B Surface 115' Surface 115' 39" Cement to Surface 20" 133# / 94# H & K Surface 1185' Surface 1185' 26" 750 sx Fondu FI ash 280 sx'G' 13-3/8" 72# N-80 Surface 2686' Surface 2686' 17-1 /2" 975 sx Fondu Flyash, 485 sx'G', 330 sx Fondu g_5/g~~ 47#, 43.5#, 40# S & N Surface 27 ' Surface 8587' 12-1 /4" 430 sx'c', 8o sx'G', 100 sx Fondu, 450 sx'G' 3-1/2" x 3-3/16" 8.81# / 6.2# L-80 8983' 11369' 8325' 8994' 4-1/4" 112 sx lass 'G' x 2-7/8" / 6.16# 23. Open to production or inject ion? ®Yes ^ No 24: TU81NG RECORD If Yes, list each i (MD+TVD of Top & Bottom; Pe nterval open rforation Size and Number): SIZE DEPTH SET MD PACKER SET MD 2" Gun Diameter, 6 spf 4-1/2", 12.6#, 13Cr80 9029' 8930' MD TVD MD TVD 9970' - 10020' 8796' - 8798' 2j CEMENT SQUEEZE ETC. ACID FRACTURE 10500' - 10650' 8815' - 8856' , , , , 10770'- 10800' 8895' - 8904' DEPTH INTERVAL MD AMOUNT 8c KIND OF MATERIAL USED 10895' -11300' 8926' - 8984' Freeze Protect w/ 35 Bbls of Diesel 26. PRODUCTION TEST Date First Production: Method of Operation (Flowing, Gas Lift, etc.): Not on Production Yet N/A Date Of Test: HOUfS Tested: PRODUCTION FOR OIL-BBL: GAS-MCF. WATER-BBL: CHOKE SIZE: GAS-OIL RATIO: TEST PERIOD Flow Tubing CaSing PreSS: CALCULATED OIL-BBL: GAS-MCF: WATER-BBL: OIL GRAVITY-API (CORK): PreSS. 24-HOUR RATE 27. CORE DATA Conventional Core(s) Acquired? ^Yes ®No Sidewal f Cores Ac uired? ^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. None ~ ~ JUN 2 2 2Q07 S O __ Form 10-407 Revised 02/20070 n ~ /~ ~ ~~ CONTINUED ON REVERSE SIDE /_ 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. Sadlerochit 9295' 8601' None 42P 9374' 8659' 41 P 9403' 8677' Zone 3 9446' 8700' 27P 9520' 8736' 26P 9950' 8795' 25P 10183' 8801' 24N 10482' 8812' 24P 10600' 8840' 23N 10632' 8850' 22N 10696' 8870' 22P 10770' 8895' 21 P 11020' 8941' 14P 11215' 8970' 13N 11288' 8982' Formation at Totai Depth (Name): 13N 11288' 8982' 30. List of Attachments: Summary of Daily Drilling Reports, Well Schematic Diagram, Surveys 31. I hereby certify that the foreg ing is true and correct to the best of my knowledge. / ~~ ~ Title Technical Assistant Date Signed Terrie Hubble ' I ~~f~b7 PBU 04-01A 207-035 Prepared ey Name/Number. Terrie Hubble, 564-4628 Well Number Permit No. / A rOVal NO. Drilling Engineer: Mel Rixse, 564-5620 INSTRUCTIONS GeNeRa~: 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, Sali 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. Irene 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 any attachments. Irene 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). Irene 20: Report true vertical thickness of permafrost in Box 20. Provide MD and ND 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. Irene 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-In, 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 BP EXPLORATION Page 1 of 7 ~ Operations Summary Report Legal Well Name: 04-01 Common W Event Nam Contractor Rig Name: Date ! ell Name: 0 e: Name: From - To 4-01 WORKO NORDIC NORDIC Hours VER CALIST 2 Task ~ A Code PT ~ Start Rig Rig Phase Spud Date: 11/27/1970 : 4/1/2007 End: 4/15/2007 Release: 5/18/2007 Number: Description of Operations 4/17/2007 09:00 - 11:00 2.00 RIGU P PRE Rig released from End 1-39 ~ 09:00 on 4-17-2007. Prep to move rig off well. Warm moving system for 45 min. 11:00 - 11:30 0.50 MOB P PRE Held PJSM &THA for moving rig off well & pre-move safety meeting with crew, security & tool services. 11:30 - 11:45 0.25 MOB P PRE Jack-up rig & move rig off well. 11:45 - 12:00 0.25 RIGU N HMAN PRE While laying down 16"x17' mouse hole, 15 gallons of condensate inside mouse hole leaked onto the pad (condensate was from steam hose used to thaw mouse hole). Informed Endicott environmental & front desk. Environmental informed us to chip up & bag the leak. 12:00 - 12:45 0.75 MOB P PRE Move off well. Meanwhile, SLB service injector & reel package. 12:45 - 18:00 5.25 MOB P PRE Held PJSM &THA prior to laying derrick down. Lower derrick & back fill mouse hole with gravel. 18:00 - 23:59 5.98 MOB P PRE Move Nordic 2 from Endicott Island to DS 04-01. 23:59 - 00:00 0.02 MOB P PRE Nordic 2 is - 8 mile into the journey. 4/18/2007 00:00 - 00:01 0.02 MOB P PRE Continue rig move from Endicott Island to DS 04-01. Currently 8 miles into the journey. 00:01 - 05:00 4.98 MOB P PRE Nordic 2 is currently on the road to DS 17 05:00 - 05:45 0.75 MOB N HMAN PRE As Nordic 2 made the corner from Endicott turn off to DS 17, drilling mud from the sump in front of the draw works (which would normally be caught by the drip pan under the rotary table, but was taken off to be modified for DS 4-01) spilled onto the road. Incident was reported to 5700, 2-3 gallons of drilling mud spilling onto the road. Were instructed to clean it up and continue on with the rig move. 05:45 - 12:30 6.75 MOB P PRE Continue to the DS4 pad. 12:30 - 18:00 5.50 MOB P PRE Work on installing drip pan below rig tloor prior to raising derrick. W indspeeds 30MPH -gusting to 40MPH. 18:00 - 19:00 1.00 MOB P PRE PJSM &THA & reviewed procedure for installing drip pan below rig floor. 19:00 - 23:30 4.50 MOB P PRE Drip pan has been installed. Needs to be leak tested. 23:30 - 00:00 0.50 MOB N WAIT PRE Currently in Phase 2 on all pads. 4/19/2007 00:00 - 06:00 6.00 MOB N WAIT PRE Wait on winds to lower below 30 MPH prior to raising derrick. Perform preventive maintenance on the pits/suction valves. 06:00 - 16:30 10.50 MOB N WAIT PRE Winds are 20-25 MPH. 16:30 - 17:00 0.50 MOB P PRE Get with DSO for permit to work for raising derrick, picking up BOP's & backing over well. PJSM &THA prior to rasing derrick. Reviewed procedure for raising derrick & assigned a leader (Driller). 17:00 - 18:00 1.00 MOB P PRE Raise derrick & secure it w/ pins. 18:00 - 18:15 0.25 MOB P PRE C/O With night crew, inspect rig & review job scope. 18:15 - 19:00 0.75 MOB P PRE Write procedure for installing tong line on D/S of derrick. Review procedure & assign a leader (Driller). Fill out Man rider permit. Review THA for skidding BOP's w/ loader & assign a leader (Motorman). 19:00 - 20:30 1.50 MOB P PRE Install tong line on D/S. 20:30 - 20:45 0.25 MOB P PRE Review procedure for scoping out derrick & clearing floor, assign leader (Driller). 20:45 - 21:30 0.75 MOB P PRE Scope out derrick & secure it. 21:30 - 21:45 0.25 MOB P PRE Review procedure for general R/U. 21:45 - 00:00 2.25 MOB P PRE Release blocks from scoping cables, pick up and secure bridal cables in derrick, clear floor, M/U injector gooseneck & move injector off rotary table. Pick up bales. Printed: 5/21/2007 9:09:55 AM ~- BP EXPLORATION Page 2 of 7 Operations Summary Report Legal Well Name: 04-01 Common Well Name: 04-01 Spud Date: 11/27/1970 Event Name: WORKOVER Start: 4/1/2007 End: 4/15/2007 Contractor Name: NORDIC CALISTA Rig Release: 5/18/2007 Rig Name: NORDIC 2 Rig Number: ~ ~ ~ ~ i Date From - To Hours ~ Task Code NPT Phase ___- 4/20/2007 ~ 00:00 - 01:00 1.00 MOB P I PRE 01:00 - 03:30 ~ 2.501 MOB P PRE 03:30 - 05:00 1.50 ~ MOB P ~ PRE 05:00 - 06:00 I 1.001 MOB I P I I PRE 06:00 - 15:00 I 9.001 MOB I P I I PRE 15:00 - 18:00 3.00 (MOB P PRE 18:00 - 18:45 I 0.751 MOB I P I I PRE 18:45 - 20:30 I 1.751 MOB I P I I PRE 20:30 - 23:00 I 2.501 MOB I P I I PRE 23:00 - 00:00 1.001 MOB P PRE 4/21/2007 00:00 - 00:30 0.50 MOB P PRE 00:30 - 01:00 0.50 MOB P PRE 01:00 - 01:15 0.25 MOB P PRE 01:15 - 03:30 2.25 MOB P PRE 03:30 - 04:20 I 0.831 MOB I P I I PRE 04:20 - 04:30 0.17 MOB P PRE 04:30 - 13:30 9.00 MOB P PRE Description of Operations Write procedure /THA for picking & handling BOP's in cellar w/ shipping stand & review w/crew. Pick BOP stack w/draw works & secure it in the cellar. Install 13 5/8" to 11 " XO. PJSM &THA for backing over well w/ Nordic 2. Move from pad entrance. Simultaneously, lay down herculit liner & lay down rig mats around wellhead & bleed down OA from 100 psi to 0 psi to slop oil trailer in 5 min (initial fluid, went to gas). T/IA/OA/OOA WHP's = na/0/0/0. Spot Nordic 2 over ramp area. Wait on DSO & c/o Nordic crew. Spotted rig over well with 13-5/8" hanging in cellar Held THA /PJSM on Nipple down tree and adaptor flange. Spotted office trailer hook up communications and set cutting box. Sent TL camp to Nordic 1. Building stairs and walk ways up onto ice pad. ND MV and adaptor flange. Install rig mats for cutting box Welding stairs to rig mats for passage up on top of the ice pad. Approved by DSO Pulled the adaptor flange with blocks. C/O w/ day crew, inspect location, PJSM &THA for handling adaptor flange & N/U BOP's. Get measurments & verify spaceout for test joint 10.75" stub + 8" XO, have 21.75" from base of 11"flange to bottom of variable rams - 3.25" to spare. Remove adaptor flange & lifting slings from blocks. Inspect & clean hanger landing threads (threads are good), verift no trash on top of BPV. MU LH ACME x 7" XO & count # of turns - 9.5 turns. Cameron confirmed all LDS are operational. Lay down walking mats around rig. R/U rig mats for cuttings box (16). Clean ring groove, install studs & new ring gasket, N/U BOP's & torque studs to spec. Veco harline crew is R/U tiger tank line to choke line on rig, PT - 500/4000, blow down w/ rig air. Release BOP stack from draw works. R/U 1502 x 2" integral on IA w/ new ring gasket. R/U choke & kill line. Raise & shim rig w/ 2x6 's. Torque remainder BOP studs to spec. PJSM &THA prior to handling & installing riser on BOP's. Pick up & install new riser w/ new gasket, silicone & rubber gaskets. GBR modifying new top riser section, fill up piping & welding second set of stairs to rig matting. Hook up BOP hoses. Hook up jumper hose to read pressure on OOA. Hook up sensors to IA, OA, OOA & install guards over flanges. PJSM Prior to changing out current variable rams for 7" x 5.5" variable rams. Function test BOPE. Swap out current variable rams for 7"x4.5" variable rams. Cut off landing in cellar to open BOP doors. Loading pits with 120deg SW Building stairs /ramps up to cutting box. Fluid packed the new riser /boots (ok). Closed blinds. Fluid packed surface line. AOGCC wavered witnessing BOP test Lou Grimalli AOGCC. Pressure up on the BOP body and casing to 250 / 3,000 psi (ok). MU 7" SLB lubricator and pulled BPV and install TWC. Printed: 5/21/2007 9:09:55 AM BP EXPLORATION Page 3 of 7 Operations. Summary Report Legal Well Name: 04-01 Common Well Name: 04-01 Spud Date: 11/27/1970 Event Name: WORKOVER Start: 4/1/2007 End: 4/15/2007 Contractor Name: NORDIC CALISTA Rig Release: 5/18/2007 Rig Name: NORDIC 2 Rig Number: I I Date ,From - To Hours ~ Task ~ Code NPT ~ Phase 4/21/2007 ~ 13:30 - 18:00 4.501 BOPSUF~ P ~ ~ PRE 18:00 - 18:20 0.33 BOPSU P PRE 18:20 - 19:30 1.17 BOPSU P PRE 19:30 - 20:00 0.50 BOPSU P PRE 4/22/2007 20:00 - 20:15 0.25 BOPSU P PRE 20:15 - 21:00 0.75 BOPSU P PRE 21:00 - 22:30 1.50 BOPSU P PRE 22:30 - 23:00 0.50 PULL P DECOMP 23:00 - 00:00 1.00 PULL P DECOMP 00:00 - 01:30 1.50 PULL P DECOMP 01:30 - 02:00 0,50 PULL P DECOMP 02:00 - 03:50 1.83 PULL P DECOMP 03:50 - 04:00 ( 0.171 PULL I P I I DECOMP 04:00 - 07:30 I 3.501 PULL I P I I DECOMP 07:30 - 11:15 I 3.751 PULL I P I I DECOMP 11:15 - 17:00 I 5.751 PULL I P I I DECOMP 17:00 - 17:30 0.50 PULL P DECOMP 17:30 - 18:00 0.50 PULL P DECOMP 18:00 - 18:30 0.50 PULL P DECOMP 18:30 - 23:00 4.50 PULL P DECOMP Description of Operations BOP test AOGCC Lou Grimalli wavered witnessing BOP test. Tested 7"-4-1/2" variables using 7" and 5-1/2" casing as per AOGCC. Temp today at +28deg F for most of the day C/O w/ day crew. PJSM &THA for BOP testing. Continue w/ BOP test. Finished BOP test. Chart recorded, as well as electronically recorded by SLB & Nordic. UD test joint, & P/U 7" lubricator for pulling TWC. PJSM &THA prior to pulling TWC w/ Veco valve shop crew. Attempt to pull TWC. Install bow spring centralizer & attempt to pull TWC again. Lay down 7" lubricator & tidy rig floor. Fill out THA & man rider permit for pinning tog bucket for ODS tings. PJSM &THA prior to picking up 3 1/2" elevators, making up stabbing valve & landing joint. P/U 3 1/2" elevators, make up & torque stabbing valve & xo's. P/U 3 1/2" 13.3# S-135 D.P. & make up & torque to 3 1/2" IFx4 1/2" IF & 4 1/2" IFx7" BUT & 7" BUTx7" LH ACME for the landing joint. Land in hanger 9 1/2 turns to the left. Hook up 2" circulating hose from standpipe manifold to tiger tank line on choke manifold for reverse circulating. R/U circulating equipment.. PJSM &THA prior to circ out well. Inspect T.T. & cellar. T/IA/OA/OOA = 0/0/32/0. Reverse circulate 100 bbls w/ S.W. down IA @ 4 BPM 600 psi taking returns up the TBG out to tiger tank to get diesel F.P. out of well bore. @ 100 bbls away, stop reverse circulating and line up to pump down the TBG, taking returns up the IA out to the tiger tank w/ 2 bbls of Safe-Surf-O added to active pits. Returns have cleared up (210bb1s returned to T,T.). Shut down pumping & blow down reverse circulating hose w/ rig air to T.T. & disconnect it. Simultaneously, conduct PJSM &THA for picking up GBR equipment &SLB spooler. Resume pumping down TBG taking returns up IA back into the rig pits. Increase pump rate to 180 SPM - 6 bbl/min @ 1080 psi. PU on tubing and hanger came out of tubing spool at 157,000. Pulled hanger to floor. RU GBR tongs. Backed off landing joint, well is unbalanced. Screwed landing joint in and circulated 600 bbl's and mixed up dry pill. Pilled 30 bbl 9.5 ppg down tubing. Backed off landing joint and hanger POOH laying down 7" 26#/ft completion Filling hole every 5 joints. Having some trouble with control lines bunching up. 30 jts lay down at 17:00 Lost 3 bands on 1st 30 jts 7" Unload pipe shed and change out SLB control liner spool POOH laying down 7" and 5-1/2" completion C/O w/ day crew. PJSM &THA for pulling 7" & 5.5" completion. Currently C~2 the SSSV profile. Recovered 53 of 59 (according to Camco records) stainless steel bands holding control & balance lines in place. PJSM &THA prior to handling/laying Printed: 5/21/2007 9:09:55 AM ! ~ BP EXPLORATION Page 4 of 7 Operations Summary Report Legal Well Name: 0 4-01 Common W ell Name: 0 4-01 Spud Date: 11/27/1970 Event Nam e: WORKO VER Start : 4/1/2007 End: 4/15/2007 Contractor Name: NORDIC CALIST A Rig Release: 5/18/2007 Rig Name: NORDIC 2 Rig Number: Date I From - To ~ Hours Task Code NPT ~ Phase Description of Operations 4/22/2007 18:30 - 23:00 -- 4.50 -- - PULL P - _ DECOMP down 7" completion outside. 23:00 - 23:15 0.25 PULL P DECOMP PJSM &THA for C/O 7" elevators for 5.5" elevator & equipment. 23:15 - 00:00 0.75 PULL P DECOMP Swap out 7" elevators for 5.5" & start pulling 5.5" completion. 4/23/2007 00:00 - 06:00 6.00 PULL P DECOMP Continue to pull 5.5" completion & jewelry from well bore. Currently ~ GLM #4. Held PJSM &THA prior to bleed down OA for 9 5/8" casing spool removal. Bled OA from 59 psi to 0 psi in 20 min to a slope trailer. 06:00 - 07:00 1.00 PULL P DECOMP Crew change walk around and Conducted PJSM on LD completion 07:00 - 09:15 2.25 PULL P DECOMP LD completion Recovered all of the old completion as programmed. Cut off piece looks good and is 22.50 ft long. Top of stub at 9026 ft DD. 09:15 - 10:45 1.50 PULL P DECOMP Unloaded pipe shed and loaded out GBR and SLB equipment. 10:45 - 11:30 0.75 EVAL P DECOMP PT 9-5/8" casing to 3,070 psi and in a charted 30 min the WHP = 3,008 psi Bleed the OA down and no flow, Also bled down the OOA and no pressure or flow 11:30 - 14:45 3.25 WHSUR P DECOMP PU pipe spinners and load pipe shed with 3-1/2" DP 14:45 - 16:15 1.50 WHSUR P DECOMP Conversed with town on plan forward. Because of DWOP Regulation and RP, decided to PU 4-3/4" DC to set plug with. Loaded 12 4-3/4" DC, calipered, measured and drifted Load pipe shed with 12 4-3/4" DC's Talked to Schlumberger about loading 2-3/8" CT in reel house and install 2-3/8" blocks in injector 16:15 - 18:00 1.75 WHSUR P DECOMP RIH with 12-4-3/4" DC, RTTS /Storm Packer. RIH with 4 jts of 3-1/2" DP Set packer 18:00 - 18:30 0.50 W HSUR P DECOMP C/O w/ day crew. PJSM &THA prior to handling DP & setting RTTS/Storm Packer. 18:30 - 19:30 1.00 WHSUR P DECOMP RIH w/ 4 jts & set packer ~ 134'. PT to 500 psi below packer & hold for 5 min. No flow, packer is set & is holding, bleed off pressure & unsting from packer & pull 4 jts of 3-1/2" DP. Close blinds & PT packer from above w/ 500 psi & hold for 5 min. Packer is holding from above, bleed off pressure. 19:30 - 20:00 0.50 BOPSU P DECOMP PJSM &THA & review procedure for nipple down BOPE. 20:00 - 00:00 4.00 BOPSU P DECOMP Bleed off Komey unit, blow down kill line, suck down stack. Remove kill line from BOP's. Remove upper & lower riser section. Install BOP lifting ring. ND 13-3/8"x11" XO on bottom of BOP's & at tubing spool flange. Remove IA & OA crash guard &SLB sensors. CIW is bleeding down 9-5/8" packoff void. Ensure OA is @ zero. 4/24/2007 00:00 - 02:00 2.00 WHSUR P DECOMP PJSM &THA prior to lifting BOP's & tubing spool & changing out primary casing seal. Took - 12k to pop tubing spool free. Lift BOP's off adaptor flange. Lift off tubing spool w/ forklift & remove from wellhead. MU BOP spool piece on top of tubing spool. 02:00 - 03:00 1.00 WHSUR N SFAL DECOMP THA &PJSM prior to cutting seized bolt from casing spool. Fill out hot work permit & begin sawing bolt from casing spool. Schlumberger is changing out 2" gripper blocks to 2-3/8" gripper blocks on the injector. 03:00 - 06:00 3.00 WHSUR P DECOMP Ensure OA is 0 psi. Back out LDS on casing spool, remove screws on seal lockdown mechanism. Having difficulty with the screws. Remove old seal. Clean the seal bore. Function LDS in Printed: 5/21/2007 9:09:55 AM BP EXPLORATION Operations Summary Report Legal Well Name: Common Well Name Event Name: Contractor Name: Rig Name: 04-01 04-01 WORKOVER NORDIC CALISTA NORDIC 2 Date I From - To ~~ Hours I Task I Code I NPT - , _ __~ 4/24/2007 03:00 - 06:00 3.00 ~ WHSUR P 06:00 - 07:00 1.00 WHSUR P 07:00 - 12:00 5.00 WHSUR P 12:00- 14:00 I 2.001 WHSURIP 14:00 - 18:00 I 4.001 W HSUR I P 18:00-18:30 ~ 0.50~WHSUR~P 18:30 - 20:00 I 1.501 W HSUR I P 20:00 - 20:30 I 0.501 W HSUR I P 20:30 - 20:45 ~ 0.251 WHSUR ~ P 20:45 - 21:45 I 1.001 WHSUR I P 21:45 - 22:00 0.25 WHSUR P 22:00 - 23:30 1.50 WHSUR P 23:30 - 00:00 0.50 CLEAN P 14/25/2007 100:00 - 02:45 I 2.751 CLEAN I P 02:45 - 05:00 2.25 CLEAN P 05:00 - 06:50 1.83 CLEAN P 06:50 - 08:30 I 1.671 CLEAN I P Page 5 of 7 Spud Date: 11 /27/1970 Start: 4/1/2007 End: 4/15/2007 Rig Release: 5/18/2007 Rig Number: Phase Description of Operations DECOMP & out. Installed seals, tested and RILDS. PU 13-5/8" spool and CIW 13-5/8" tubing hanger. DECOMP Crew change, PJSM with crew and plan a way forward. DECOMP Torque up tubing spool and lower BOP down on spools to complete the torque process. Cleaning out pipe shed. Installed riser and kill and choke lines. PT the casing hanger flange and packoff seal to 3,800 psi. Left pressure on for 30 min and witnessed the test. DECOMP PJSM on install upper riser in BOP. Secured to drip pan. PJSM &THA prior to picking a-coil. Schlumberger picked up 2-3/8" a-coil, ID #13472e, used coil life peak of 63% ~ 10,500', 322,515 R.F. Total length of 15,088 ft. DECOMP Change out variables to 2-7/8" X 5-1/2". Hook up kill line. PU 13-5/8" test plug and set in spool working to get test plug in the 13-5/8" tubing hanger Checked the LDS. CIW inspected the tubing spool and ran in LDS, PT same. DECOMP C/O with day crew. PJSM &THA for pressure testing BOPE - full body test & variable test. DECOMP Fill BOP stack w/ sea water via mud cross. Leave IA valve open to atmosphere -contingency for hanger test plug leakage. Full body test against annular -low 250 psi & high 3500 psi for 5 minute each. Small leak on gray lock fitting on kill line, bleed off & tighten tlange. Resume P.T. low & high. Annular passed. P.T, low & high on variable rams. Failed on high pressure test. Cycle variable rams. Repeat test low & high. Variable rams passed. DECOMP Back out LDS & remove 4.5" tubing hanger test joint. Break out test joint on floor. DECOMP PJSM &THA prior to pulling RTTS packer. Simultaneously, PJSM &THA w/ Schlumberger prior to C/O brass in stuffing box. DECOMP PU 2 stds of 3-1/2" dp &RIH to 134'. RU & close TIW. Set down on RTTS packer & spins 21 times into packer. Open TIW & check for flow - no flow. Break & LD TIW valve. PUH & LD 4 jts of 3-1/2" DP. Check for flow before bringing RTTS packer through BOP's - no flow. Break out & LD RTTS packer. Schlumberger has C/O brass in stuffing box. DECOMP PJSM &THA prior to PU & LD drill collars. DECOMP POH & LD 12 jts of DC's. DECOMP PJSM &THA w/ SLB slickline crew prior to PU & handling slickline. DECOMP Rig up .125" wire &slickline tools & equipment. Hang top slickline shive on blocks. Steam/clean junk basket. Zero bottom of tool string @ the rotary table, 23.15' correction to LDS. RIH w/ 8.50" junk basket to 9021' (9044' uncorrected), tag twice -same depth, RU line wiper & POH w/ slickline. Begin loading pipe shed w/ 4-1/2" 13Cr80 Vam Top tubing. DECOMP POH w/ slickline. Pulling heavy due to small fluid bypass. DECOMP Top of junk basket ports are plugged w/ paraffin. Recovered 1 S.S. control line band & 1 small partial control line band & 1/4 gallon of hard paraffin. Clean junk basket w/ steam. Zero SL ~ rotary table. RIH w/junk basket. Tagged at 9047 ft W LMD DECOMP POH w/ slickline. Pulling heavy due to small fluid bypass. Printed: 5/21/2007 9:09:55 AM ~ ~ BP EXPLORATION Operations Summary Report Legal Well Name: 04-01 Common Well Name: 04-01 Event Name: WORKOVER Contractor Name: NORDIC CALISTA Rig Name: NORDIC 2 Date i From - To Hours ~ Task ~ Code ~ NPT _-- ' - ~ ' - 4/25/2007 06:50 - 08:30 ~ 1.67 ~ CLEAN (P 08:30 - 09:30 09:30 - 10:15 10:15 - 10:30 10:30 - 11:00 11:00 - 17:15 17:15 - 20:30 20:30 - 21:00 21:00 - 00:00 4/26/2007 00:00 - 06:00 06:00 - 06:30 06:30 - 13:30 13:30 - 16:00 16:00 - 16:30 16:30 - 17:25 17:25 - 20:30 20:30 - 21:30 1.00 CLEAN P 0.75 CLEAN P 0.25 CLEAN P 0.50 CLEAN P 6.25 BUNCO 3.25 RUN 0.50 RUN 3.00 RUN 6.00 RUN 0.50 RUN 7.00 RUN 2.501 RU 0.50 RU 0.92 RU 3.08 RU 1.00 RU 21:30 - 22:00 22:00 - 22:55 22:55 - 23:30 23:30 - 00:00 4/27/2007 100:00 - 01:00 01:00 - 01:30 01:30 - 03:00 03:00 - 04:00 04:00 - 04:15 0.50 RUN 0.92 RUN 0.58 RUN 0.50 RUN 1.00 RUN 0.50 WHSUR P 1.50 WHSUR P 1.00 WHSUR P 0.25 WHSUR P Page 6 of 7 Spud Date: 11 /27/1970 Start: 4/1 /2007 End: 4/15/2007 Rig Release: 5/18/2007 Rig Number: Phase Description of Operations DECOMP No material recovered ,evidence on hard schmoo on the upper part of the junk basket DECOMP RIH with 6" LIB, tagged at 9047 ft WLMD DECOMP POOH with 6" LIB. Good indication of the 5-1/2" stub located at 9047 ft WLMD DECOMP Held PJSM on RD wireline. DECOMP RD wireline RUNCMP Load pipe shed with 4-1/2" completions. Loading out tool service equipment and make ready rig floor for running 4-1/2" completion RUNCMP RU Doyon to run completion RUNCMP PJSM &THA & review procedure for running chrome completion. RUNCMP Running 4-1/2" tubing with Doyon Torque Tum (Torque =4450 ft-Ib). RUNCMP Continue running 4-1/2" 13Cr Vam Top completion with Doyon Torque Turn (Torque = 4450 ft-Ib). RUNCMP Crew change and held THA and discussed SOP for running completion tubulars RUNCMP Continue running 4-1/2" 13Cr Vam Top completion with Doyon Torque Turn (Torque = 4450 ft-Ib). Kick while tripping tubulars drill. Ran 210 jts 4-1/2" Tubing. Tagged the top of the stub at 9,022 ft. Sheared the shear stock and went in the hole another 4 ft to 9,030 ft. Marked pipe and PUH LD 3 joints of 4-1/2" tubing. Calculated Space out and install 3 4-1/2" pup joints RUNCMP Installed Space out PJ and CIW hanger. RIH and RU to reverse circulate wellbore. Set top of hanger below annular closed same. RUNCMP PJSM with crew and truck drivers RUNCMP Spot truck and add 1 drum Corrosion inhibitor in both truck RUNCMP Reverse circulate in corrosion inhibitor in the well at 3.00 bpm. RUNCMP Stop pumping, suck out stack. Land tubing, take out LDS & verify hanger has landed. RILDS. Drop ball & rod. RUNCMP PJSM &THA prior to setting packer & pressure testing tubing/casing. RUNCMP Pressure test tubing & chart it to 3500 psi for 30 min. 15 min for the chart to stabilize. Test was good. RUNCMP Bleed of tubing pressure to 1500 psi. Install tee and gauge on top of landing joint to monitor pressure on tubing. RUNCMP Pressure test IA & chart it to 3000 psi for 30 min. Let chart stabilize. RUNCMP IA pressure test for 30 min passed. Line up & bleed TBG via Baker choke & shear top GLM. Sheared @ 400 psi. Pump 10 bbls of S.W. down IA taking returns up the TBG to confirm sheared GLV. POST PJSM &THA w/ LRS prior to pumping diesel FP down IA & also setting BPV. POST RU LRS to IA. PT lines to 3500 psi & pump 140 bbls diesel down IA taking returns up tbg. POST Set 4-1/2" H style BPV &LRS to tested from below. Good test, RD LRS. POST PJSM &THA for the ND procedure. Printed: 5/21/2007 9:09:55 AM BP EXPLORATION Page 7 of 7 Operations Summary Report Legal Well Name: 04-01 Common Well Name: 04-01 Spud Date: 11/27/1970 Event Name: WORKOVER Start: 4/1/2007 End: 4/15/2007 Contractor Name: NORDIC CALISTA Rig Release: 5/18/2007 Rig Name: NORDIC 2 Rig Number: - ~ Description of Operations Date From - To ~ Hours Task ~ Code NPT Phase , 4/27/2007 04:15 - 12:00 7.75 WHSUR P POST Blow down lines in prep for ND BOP. Suck out stack. PJSM following crew change Open up 13-5/8" Stack and prep for stacking at Price Pad ND riser and 13-5/8" BOP's 12:00 - 15:00 3.00 WHSUR P POST Installed 13-5/8" 5 k X 4-1/8" 5k tree adaptor and 4-1/8" master valve. Changed to Sidetrack Section of the Project. Reenter and Completion 4/16!2007 Printetl: 5/21/2007 9:09:55 AM i ! BP EXPLORATION Page 1 of 17 Operations Summary Report Legal Well Name: 04-01 Common Well Name: 04-01 Spud Date: 11/27/1970 Event Name: REENTER+COMPLETE Start: 4/16/2007 End: 5/10/2007 Contractor Name: NORDIC CALISTA Rig Release: 5/18/2007 Rig Name: NORDIC 2 Rig Number: Date From - To Hours ~ Task ~ Code i NPT Phase - 4/27/2007 15:00 - 16:00 1.00 MOB P PRE 16:00 - 16:15 0.25 MOB P PRE 16:15 - 16:35 0.33 MOB P PRE 16:35 - 18:00 1.42 MOB P PRE 18:00 - 18:30 0.50 MOB P PRE 18:30 - 21:30 3.00 MOB P PRE 21:30 - 22:00 I 0.501 MOB I P I I PRE 22:00 - 22:30 0.50 MOB P PRE 22:30 - 23:00 0.50 MOB P PRE 23:00 - 00:00 1.00 MOB P PRE .4/28/2007 00:00 - 01:50 1.83 BOPSU P PRE 01:50 - 03:30 I 1.671 BOPSUR P I I PRE 03:30 - 04:00 0.50 BOPSU~ P PRE 04:00 - 04:30 0.50 BOPSU P PRE 04:30 - 06:00 1.50 BOPSU P PRE 06:00 - 13:30 I 7.501 BOPSUR P I I PRE 13:30 - 15:00 I 1.501 BOPSUR P I I PRE 15:00 - 16:00 1.00 BOPSU P PRE 16:00 - 18:00 2.00 RIGU P PRE 18:00 - 18:30 0.50 RIGU P PRE 18:30 - 20:00 1.50 RIGU P PRE 20:00 - 21:00 1.00 RIGU P PRE 21:00 - 22:00 1.00 RIGU P PRE 22:00 - 22:40 0.67 RIGU P PRE 22:40 - 23:30 0.83 RIGU P PRE 23:30 - 00:00 0.50 RIGU P PRE 4/29/2007 00:00 - 01:30 1.50 RIGU P PRE 01:30 - 01:45 0.25 RIGU P PRE 01:45 - 02:00 0.25 RIGD P PRE 02:00 - 02:15 0.25 RIGU P PRE 02:15 - 03:45 I 1.501 RIGU I P I I PRE 03:45 - 03:50 I 0.081 RIGU I P I I PRE 03:50 - 04:20 I 0.501 RIGU I N I HMAN I PRE Description of Operations Finished installing CIW Tree Adaptor and test to 5000 psi. Installed Master valve and companion flange on top of the valve. Held PJSM on moving off well with crew and DSO. Read the SOP and mitigated the hazards discussed Open doors, jack rig up and move off well Swap BOP out i.e. Change 13-5/8" to 7-1/16" BOP's PJSM &THA & review moving rig/CO BOP's C/O configuration on BOP stack. MU 7-1/i 6"x4-1/16" XO on bottom of BOP's. PJSM &THA prior to backing over well w! Nordic &SLB & DSO. Back over well. PJSM &THA prior to NU 7-1/16" BOPE NU 7-1/16" BOPE Continue to NU BOPE, torque all flanges to spec. Hook up ROPE hoses. Hook up IA,OA & OOA sensors. Shim rig. Hook up Choke & Kill fine. Get BOP measurements. Label BOP controls. Stab 10' lubricator on top of annular. PJSM &THA prior to rigging up Veco to remove BPV. Pull BPV & set a TWC to test BOP's. Function test BOPs. Fill stack with water. Conducted shell test on BOP and master valve. Conducting BOP at 250 / 3500 psi. Jeff Jones wavered witness BOP RD BOP testing equipment. Called the valve shop to pull TWC. PU injector and stabbed packoff on. Pull injector to side and RU to pull TWC with lubricator Held PJSM on pulling CT across pipe shed and stabbing in injector and packoff. Pull TWC after repairing pulling tool RD and load out Pull CT across and stab in injector Day crew C/O. PJSM &THA prior to RU slickline. RU slickline unit. RIH w/ slickline & retrieve ball & rod. Recovered ball & rod. RIH w/ 4.5" OM-1 & pull DCK from GLM #5. Recovered DCK valve. RIH w/ 4.5" OM-1 & set 1.5" DMY valve in GLM #5. Set good. Pressure test IA to confirm integrity. Passed test. RIH w/ 4.5" GS to retrieve RHC plug C~ 8976'. Recovered RHC plug. PJSM &THA prior to RD slickline. RD slickline unit. PJSM &THA prior to filling coil w/ fluid & CT slack management. Fill coil w/fluid ~3 1.5 bbls/min. Caught fluid @ 53 bbls away. S/D & bleed off. Stab injector on well & conduct slack management. SD & bleed off, SLB hand noticed that the lower half of stuffing box is weeping fluid from the injection/wellhead port adaptor. Lower half of stuffing box is missing a boss fitting plug from the factory. Pop off well & stab over circulating hole on rig floor & circulate fluid. Install new boss fitting, stab injector on well & PT. PT was Printed: 5/21/2007 9:10:07 AM r ~ BP EXPLORATION Operations Summary Report Page 2 of 17 !, Legal Well Name: 04-01 Common Well Name: 04-01 Spud Date: 11/27/1970 Event Name: REENTER+COMPLETE Start: 4/16/2007 End: 5/10/2007 Contractor Name: NORDIC CALISTA Rig Release: 5/18/2007 Rig Name: NORDIC 2 Rig Number: Date From - To Hours Task 1 Code NPT Phase Description of Operations i 4/29/2007 03:50 - 04:20 0.50 RIGU N HMAN PRE good. 04:20 - 08:00 3.67 RIGU P PRE Conduct slack management. Cut 68' of coil to find wire. Meg 08:00 - 10:00 I 2.001 STWHIPI P I I WEXIT 10:00 - 12:00 2.00 STWHIP P WEXIT 12:00 - 13:00 1.00 STWHIP P WEXIT 13:00-13:301 0.501STWHIPIP I (WEXIT 13:30-19:131 5.721STWHIPIP I (WEXIT 19:13-19:20 0.12 STWHIP P WEXIT 19:20-19:54 0.57 STWHIP P WEXIT 19:54-20:03 0.15 STWHIP P WEXIT 20:03-21:00 0.95 STWHIP P WEXIT 21:00 - 21:59 0.98 STWHIP N MISC WEXIT 21:59 - 23:45 I 1.771 STWHIPIP I I WEXIT 23:45-00:00 ~ 0.25~STWHIP~P ~ WEXIT 4/30/2007 00:00 - 01:00 1.00 STW H I P P W EXIT 01:00-03:361 2.60~STWHIPIP I WEXIT 03:36-04:101 0.571STWHIPIP I (WEXIT 04:10-05:08 I 0.971STWHIPIP I (WEXIT 05:108 - 09:47 I 4.50 STWHIP P WEXIT Ohm wire -good test. Install CTC and Pulled test to 35k and pressure tested to 3500 psi Cir CT working on floor. Circulated through CT at 1.52 bpm to finalize the slack management. PU Mill BHA #1 and confirmed scribed line and offset. Stab on well Open EDC RIH Logged tie-in with CCL from 8950 ft to 9150 ft and corrected -2 ft. Logged GR from 8,630 ft to 8,750 and no correction. RIH and tagged at 9185" confirmed again at 9185' PUH and start circulating and orient TF to 180 deg Milling hard cement with LS TF Op = 2.48 / 2.49 bpm at 2,320 psi off bottom and 2500 psi on bottom pressure. ROP on cement started at 41 fph to 14 fph in 2 ft Stalled at 9,189 ft. Cement hard at 5-15 fph Stop pumping, pick up & orientate to 180 deg HS. 34k pick up weight. Begin milling cement ramp @ 9288' with HS TF Op = 2.48 / 2.49 bpm at 2,350 psi off bottom and 2552 psi on bottom pressure. ROP on cement ramp - 20 fph. Stop drilling, pick up and back ream cement ramp & pilot hole. Dress the entrance of the pilot hole. Open EDC & pick up to 8940 ft. RIH ~ 800 fph & tie in. No correction needed. Stop moving coil. Reduce pump rate. SLB coil supervisor noticed the reel bushing end plate & bolt fell out of the reel. Stop & repair the problem. Increase pump rate & POH to PU casing exit BHA. PJSM & THA prior to handling BHA's. Tag stuffing box brass, RIH to 200 ft. Stop pumping & close EDC. No flow check. LD cement pilot hole milling BHA. PU & MU window milling BHA. BHI tool tested good. Open EDC &RIH. Set down in GLM #2 & GLM #1, orientate to get through. Set down in X profile @ 8909 ft, pump through motor to get passed. Logged tie-in with CCL from 8950 ft to 9150 ft and corrected -3 ft. Shut down pumps, orient TF to low side &RIH. Sit down 9250 ft. Try different orientations. Try different speeds. Orientate to LS & try pumping ~ min rate. Suspect we are hitting a collar edge. RIH ~ 3 ft/min while pumping 2.4 bbls/min. Tag @ 9300 ft. Pick up & orientate TF to HS. Milling 9-5/8" Casing as per schedule Op = 2.51 / 2.50 bpm at 2087 psi Note: Swapped MP1 to MP2 at 07:00 hrs. Seeing some motor work at 9301.3 ft with very little WOB Concern about damage mill while working through the collar at Printed: 5/21/2007 9:10:07 AM ~ ~ ~~ ` (X-01 Qt BP EXPLORATION Page 3 of 17 Operations Summary Report Legal Well Name: 04-01 Common Well Name: 04-01 Spud Date: 11/27/1970 Event Name: REENTER+COMPLETE Start: 4/16/2007 End: 5/10/2007 Contractor Name: NORDIC CALISTA Rig Release: 5/18/2007 Rig Name: NORDIC 2 Rig Number: i Date From - To Hours Task Code NPT Phase Description of Operations 4/30/2007 05:17 - 09:47 4.50 STWHIP P WEXIT 9,251 ft. At 9301.4. the Pp inc 40 psi and short term WOB. Could be sliding down the wall instead of cutting a notch in casing 09:47 - 11:35 1.80 STWHIP P WEXIT PUH ream out area between 9,255 ft to 9,230 ft. RIH WO pump. Tagged at 9248 ft PU and tried again and set down at 9248 ft HS TF Tried RIH at 2.00 BPM at HS and worked our way through NOTE: 9-5/8" casing collar at approximate) 9,251 ft. Could be bad casing or a damaged gage on the mill? Pumped 20 bbl HV biozan pill PUH from 9,300 ft and orient TF to 45L and back ream 9,255 ft to 9,230 ft. SD pump, orient TF to HS and RIH. Tagged at 9,248 ft. Worked through easier than before. RIH to 9,300 ft. Sweep out of CT, PUH, orient TF to 45R and back ream from 9,255 ft to 9,230 ft. Turn TF to HS SD pump and RIH Started sweep # 2 (25 bbl) Last RIH wo/ pump, clean at 9,248 ft. RIH chasing pill 11:35 - 13:40 2.08 STWHIP P WEXIT POOH chasing sweep to surface. Open EDC at 9,137 ft. PJSM with crew on handling BHA 13:40 - 14:45 1.08 STWHIP P WEXIT Stood back Coiltrac BHA and broke off motor and bit. DP0088 gauge looked worn but not that bad. The center core point has a piece of dia matrix broken off the diameter and thickness of a quarter. PU New mill and 2.25 deg bend motor 14:45 - 17:00 2.25 STWHIP P WEXIT Open EDC. RIH. Set down at 7,405 ft (GLM#3). orient TF to HS from 30R RIH orient TF to 90R RIH and tagged 8,157 ft (GLM 2), orient TF around to get past. RIH, tagged at 8,857 ft (GLM1) with HS TF. RIH orienting TF around and got past. Stopped at 8940 ft to tie-in 17:00 - 17:10 0.17 STWHIP P WEXIT RIH at 1,000 fUhr logging CCL from 8940 ftCorrected -2 ft 17:10 - 17:30 0.33 STWHIP P WEXIT RIH and tagged 9301.5 ft, Slacked off to 9200 ft and PU to 9301.5 Op = 2.55 at 2320 psi off bottom, Vp = 369 bbls 7:30 - IT Start milling window at 17:30 hrs Op=2.59/2.61 bpm CTP = 2318 psi Vp = 369 bbl Mixing in the pits C~ 20:31 hrs. 5/1/2007 00:00 - 01:40 1.67 STWHIP P WEXIT Continue milling 9-5/8" casing as per extended schedule Op = 2.57 / 2.61 bpm CTP = 2278 psi W OB = 0.08 Vp = 371 bbl 01:40 - 06:00 4.33 STWHIP P WEXIT Seeing some motor work at 9303.0 ft with an increase in WOB Op=2.57/2.61 bpm CTP = 2340 psi W0B=0.82-0.58 Vp = 371 bbl 06:00 - 10:00 4.00 STWHIP P WEXIT Milling window at 0.1 ft/6 min Op = 2.56 / 2.60 bpm at 2443 psi on bottom, (off bottom = 2300 psi) WOB and motor work consistance after slacking off. Samples show very little metal with mostly cement. Stopped at 9307.5 ft and picked up. Pumped 20 bbl HV pill and RIH and motor work Printed: 5/21/2007 9:10:07 AM • • BP EXPLORATION Operations Summary Report Legal Well Name: 04-01 Common Well Name: 04-01 Event Name: REENTER+COMPLETE Contractor Name: NORDIC CALISTA Rig Name: NORDIC 2 Date From - To ~ Hours ~ Task Code NPT 5/1/2007 106:00 - 10:00 4.001 STWHIP~ P 10:00 - 10:40 0.671 STWHIP P 10:40 - 11:30 I 0.831 STWHIPI P 11:30 - 11:45 I 0.25 I STW HI P I P 11:45 - 13:45 2.00 STWHIP P 13:45 - 14:15 0.50 STWHIP P 14:15 - 15:00 0.75 STWHIP P 15:00 - 16:30 1.50 STWHIP P 16:30 - 17:45 1.25 STWHIP P 17:45-19:35 1.83 STWHIP P 19:35 - 20:05 0.50 STWHIP P 20:05 - 20:25 0.33 STWHIP P 20:25 - 21:50 1.42 STWHIP P 21:50 - 22:20 0.50 STW H I P N 22:20 - 22:30 0.17 STWHIP N 22:30 - 22:40 0.17 STWHIP N 22:40 - 00:00 1.33 STWHIP N 5/2/2007 00:00 - 00:55 0.92 STW H I P N 00:55 - 01:40 0.75 STWHIP N Start: 4/16/2007 Rig Release: 5/18/2007 Rig Number: Phase WEXIT WEXIT WEXIT WEXIT WEXIT WEXIT WEXIT WEXIT WEXIT WEXIT WEXIT WEXIT WEXIT DFAL WEXIT DFAL WEXIT DFAL WEXIT DFAL WEXIT DFAL WEXIT DFAL WEXIT Page 4 of 17 ~ Spud Date: 11 /27/1970 End: 5/10/2007 Description of Operations increased at 9307.3 ft and WOB inc at the same depth. Sample shows an increase in metal up to 10% from <i Looks like the mill is in the cemented 9-5/8" annulus. Window could be from 9303 ft to 9309 ft Set WOB to try and mill cement up 6-7 fph at 3k W OB and delta P = 500 psi Drilled down to 9310.8 ft PUH to check parameters 2680 psi at 2.78 bpm PU was clean. Last sample showed 80% metal and cement. The cement has earthy tones which is evidence of annular cement. RIH took wt and motor work at 9310.6 ft. Milling cement and taking sample to Geo Sample at 9,310' stall at 9,311.1 ft, could have pop out at 9,311 ft. ROP consistant at 13 fph WOB 4 k. Drilled from 9,311 ft to 9,313 ft. Sample at 9311 is 90% metal. Sample at 9313 ft was Op=2.57/2.61 bpm CTP = 2340 psi W06=0.82k-4.5k Vp = 371 bbl PUH to 9,300 ft, reamed down to 9,315 ft, PUH SD pumps and dry tag TD at 9315'. With pump at 0.58 bpm PUH out of ramp and pilot hole to surface. Get off well Unstab coil LD BHA tools. RU and cut 115' of coil and wire. Rehead coil. Test same. MU window dressing BHA with 2.25 deg motor. Test tools. Run in hole. Log tie-in to CCL from 8900'-9150', corr -3'. Cfosed EDC, start pump 0.6/650 RIH at min rate and LS to 9288'. Swap to HS and tag w/ MW at 9306.3'. Start motor 2.45/2090 and ease in hole looking for window First MW, then stall at 9306.58'. After several stalls at the same depth, get by and stall again at 9306.78'. Get to 9307.1' w/ more stalls After the third stall at 9307.1', started stacking wt before getting back to TD. Also, had 200 psi incr in CTP. Acts like something is alongside the BHA. Backream to above TOC to 9170' w/ no pressure or wt loss. RBIH at 0.8/780 following DTF. Start pump at 9300' and RIH 10'/min and start losing wt at 9305'. Stack 8k wob w/ no MW at 9306'. PU w/ no overpull and repeat. Time to chk the BHA POOH circ thru mill to check BHA. Had 10k overpull at 9070' and lost 250 psi CTP-maybe shucked something RBIH at min rate/DTF. Start pump at 9300' 2.50/2230 and started stacking wt at 9303'. Put 8k wob and had no MW (same as before) POOH (again) circ thru mill to check BHA. No OP at 9070'. Open EDC at 8950' and circ 2.76/1830 Finish POOH to check BHA Standback BHA. Found motor had backed off at connection at adjustment ring and rotor had pulled out of stator by 3' Printed: 5/21/2007 9:10:07 AM • • BP EXPLORATION Page 5 of 17 Operations Summary Report Legal Well Name: 04-01 Common Well Name: 04-01 Event Name: REENTER+COMPLETE 'Contractor Name: NORDIC CALISTA Rig Name: NORDIC 2 Date From - To Hours Task Code' NPT 5/2/2007 ~ 00:55 - 01:40 0.75 ~ STWHIP N . DFAL 01:40 - 04:30 04:30 - 06:45 2.83STWHIPN (DFAL 2.251 STWHIPI N I DFAL 06:45 - 07:00 0.25 STWHIP N DFAL 07:00 - 07:15 0.25 STWHIP N DFAL 07:15 - 08:15 1.00 STWHIP P 08:15 - 12:15 4.00 STWHIP P 12:15 - 12:30 0.25 STWHIP P 12:30 - 12:45 0.25 STWHIP P 12:45 - 15:00 . 2.25 STWHIP P 15:00 - 15:20 15:20 - 15:45 15:45 - 17:30 17:30 - 17:45 17:45 - 18:00 18:00 - 18:40 18:40 - 19:55 19:55 - 23:00 23:00 - 00:00 5/3/2007 00:00 - 02:20 0.331 STWHIPIP Spud Date: 11 /27/1970 Start: 4/16/2007 End: 5/10/2007 Rig Release: 5/18/2007 Rig Number: Phase Description of Operations WEXIT (probably at overpull spot). No debris was .left in hole. Remove WFT crayola mill from motor-mill had no damaged diamonds anywhere WEXIT MU same WFT 3.80" crayola mill on 2.25 deg BHI extreme motor BHI cycle EDC and found a piece of brass shear stock that could not be removed. Change out EDC. Had trouble reprogramming WEXIT RIH w/ BHA #5 circ thru EDC 0.52/440 Continue to work on BHI software/programming problem. Problem solved before reaching TD. WEXIT Log CCL tie in. Add 2' correction. WEXIT Continue to run in hole. WEXIT Ream window area. 2150 psi fs at 2.74 bpm. HS toolface. Tag TD at 9313' and stall. Pick up and stall several times at 9312'. Make no additional forward progress wiith continued stalls and pickups. No overpulls. Suspect some kind of junk. WEXIT Backream a total of eight up passes from 9308' to 9285' at 45, 75, 105 deg orientation left and right of high side. Noted minimal motor work each pass. WEXIT Run in hole with HS toolface. Window smooth, but tag and stall at 9312'. Appear to be hitting some kind of junk. WEXIT Log CCL tie in. Add 2' correction. WEXIT Open EDC. Circulate out of hole. Hold PJSM in ops cab to review BHA handling procedure. WEXIT At surface. Get off well. Remove and inspect crayola mill. No significant marks on mill. 0.42 STWHIP N DPRB WEXIT MU 3.78" od parabolic diamond mill on 2.25 deg mtr. 1.75 STWHIP N DPRB WEXIT Get on well. Run in hole. 0.25 STWHIP N DPRB WEXIT Log CCL tie in from 8900'. Subtract 2' correction. 0.25 STWHIP N DPRB WEXIT Run in hole through pilot and window. Start pump at 9300' and stalled at 9307.9' 0.67 STW HIP N DPRB WEXIT Attempt to get started at 9307.9' for 30 min w/o success. Had 6 sharp stalls 1.25 STWHIP N DPRB WEXIT Ease in hole over 30 min to 9307.9' at 2.45/2040 and then start to make slow hole. After 40 min were at 9309.0' w/ 1.75k wob and 250 psi dill. Park and wait to drill off. Ease ahead until stall at 9309.6' w/ 2.Ok wob and 200 psi dill. PU clean.. RBIH and stall at 9308.5' 3.08 STWHIP N DPRB WEXIT Ease back in hole and remill from 9307.8' Stalled after 5 min at 9307.9'. Had three more stalls during the next hour at the same depth while time milling. Finally get by 9307.9' and time drill ahead at +/-0.05'/3 min. Started taking wt and showing dill at 9309.0'. Mill to 9309.4' and stalled with 3.4k wob and 600 psi dill 1.00 STWHIP N DPRB WEXIT PUH clean at 35k, but motor appeared stalled w/ new FS of 2.45/3050. RBIH at same pump parameters and was clean going by 9307.9'! Tag at 9309.2' and lost 'extra' pressure. PUH clean and find new FS at 2.4/2300. RBIH and resume milling from 9309.30' w/ 1 k wob and 300 psi dill. Mill to 9309.7' w/ 3k wob and 250 psi dill and motor stalled. Seeing small pieces of rubber on shaker 2.33 STWHIP N DPRB WEXIT Wiper to 9100' was clean. Open EDC. POH to check/change Printed: 5/27/2007 9:10:07 AM • r BP EXPLORATION Page 6 of 17 Operations Summary Report Legal Well Common W Event Nam Contractor Rig Name: Date ~ Name: 0 ell Name: 0 e: Name: From - To 4-01 4-01 REENTE NORDIC NORDIC Hours R+COM CALIST 2 Task ~ PLET A Code ~ E NPT 5/3/2007 00:00 - 02:20 2.33 STWHIP N DPRB 02:20 - 03:00 0.67 STWHIP N DPRB 03:00 - 08:00 5.00 STWHIP N DPRB 08:00 - 09:00 1.00 STWHIP N DPRB 09:00 - 10:30 1.50 STWHIP N DPRB 10:30 - 11:00 0.50 STWHIP N DPRB 11:00 - 12:30 1.50 STWHIP N DPRB 12:30-14:00 1.50 STWHIP N DPRB 14:00 - 14:30 0.50 STWHIP N DPRB 14:30 - 16:30 2.00 STWHIP N DPRB 16:30 - 17:20 0.83 STWHIP N DPRB 17:20 - 19:40 2.33 STWHIP N DPRB 19:40 - 20:00 0.33 STWHIP N DPRB 20:00 - 20:40 0.67 STWHIP N DPRB 20:40 - 23:20 2.67 STWHIP P 23:20 - 00:00 0.67 STWHIP P 5/4/2007 00:00 - 02:00 2.00 STWHIP P 02:00 - 02:40 0.67 STWHIP P Spud Date: 11 /27/1970 Start: 4/16/2007 End: 5/10/2007 Rig Release: 5/18/2007 Rig Number: Phase Description of Operations WEXIT BHA 2.75/2300 WEXIT LD drilling BHA. Motor felt tight enough, but recovered a 1 "x2" chunk of rubber in possum belly so laid motor down. The mill had worn diamonds on the taper from about the 3.70" OD to/thru the gauge 3.79" area. This suggests a small hole or one that is continually closing ...yes, the other'c' words WEXIT Cut off 115' CT for chrome management. Install CTC and PT at 45k. Test a-line. WEXIT MU 3.8 one step DSM on 2.2 deg motor. MU and test tools. Get on well. WEXIT Run in hole. WEXIT Log CCL tie in from 8900'. Subtract 3' correction. WEXIT Tag up and stall at 9310.4'. PU and begin milling ahead from 9310.2'. 3325 psi fs at 2.32 bpm. Mill approximately 0.2'-0.3'. Begin "milling ahead". Tag again at 9315'. Drill ahead to 9320'. Checking samples. Amount of formation increasing with each sample. WEXIT Ream and back ream from 9315' to 9300' several times. Dry drift. Hole appears to be smooth. WEXIT Backream up through pilot hole. WEXIT Open EDC. Circulate out of hole. Hold PJSM in Ops Cab to discuss changing motor mills. WEXIT At surface. Get off well. Change one step to crayola mill hanging in derrick. WEXIT RIH WEXIT Log CCL from 8950-9150'. Corr -3.0'. Close EDC WEXIT RIH circ at 0.48/480 thru mill. RIH thru HS ramp and bring up rate to 2.56/2150 at 9305' and promptly stall at 9311.2'. Repeat at 5'/min and stall at 9310.7'. Take a slower approach at 0.6'/min and had no MW or wt loss until set down then stall at 9318'.0'. Repeat TD tag and started losing wt at 9320.6' and stalled at 9321.3' w/ 2k wob. Had mini-overpull. Repeat tagging TD twice from below window and stalls were not as bad nor were there anymore overpulls (assume junk was pushed to the side of the hole-and will be a surprise at another time) WEXIT Backream at HS TF and stalled at 9306'. Repeat and was clean Begin dressing window on the upstroke at 1.5'/min of various TF's from 105E to 105 R to 9295', then ream at HS TF 10'/min back to TD and setting 3-5k to wear down junk. Most tags at TD had no MW, but some had sharp stalls, Had one good 12k overpull, but most had no OP's. So, still have junk below window. Dry run was clean to TO Swapped to new Flo Pro mud preceded by a 20 bbls hi-vis bio sweep while backreaming WEXIT POOH to 9100'. Open EDC. Circ 2.75/1800 while POOH for drilling assy WEXIT Continue POH w/ window dressing assy circ thru EDC 2.68/2250 WEXIT LD BHI assy to reconfigure. LD BHI motor and WFT crayola mill. Mill was missing a 4-1/4" x 2-1/4" piece of the top reaming band that is braised onto the body of the mill with silver solder. It is felt this piece came off during the stall before the first pass Printed: 5/21/2007 9:10:07 AM ~ • BP EXPLORATION Page 7 of 1 ; Operations Summary Report Legal Well Name: 0 4-01 Common W ell Name: 0 4-01 Spud Date: 11/27/1970 Event Nam e: REENTE R+COM PLET E Start : 4/16/2007 End: 5/10/2007 Contractor Name: NORDIC CALIS TA Rig Release: 5/18/2007 Rig Name: NORDIC 2 Rig Number: D t F T ~ ~ T k i f O i D i a e rom - o Hours as Code NPT Phase pt on o perat escr ons 5/4/2007 02:00 - 02:40 0.67 STWHIP P WEXIT that made it thru the window based on the deepness of circular scars on the nose of the mill 02;40 - 04:30 1.83 STWHIP P WEXIT Discuss fishing ops w/ BTT SWS inspect and grease chains BHI reconfigure BHA Nordic function test BOP's 04:30 - 09:00 4.50 STWHIP N DFAL WEXIT WO BTT to build mule shoe guide for Venturri JB 09:00 - 10:15 1.25 STWHIP N DFAL WEXIT Bring Baker tools onto rig. Hold PJSM to dicuss making up BHA. MU Venturi assembly w/ mule shoe on Inteq mwd. OrienUscribe bent sub to HS tool face. Stab coil. Get on well. Test tools. 10:15 - 12:15 2.00 FISH N DFAL WEXIT Run in hole. 12:15 - 12:30 0.25 FISH N DFAL WEXIT Log CCL tie in. Subtract 3' correction. Close EDC. 12:30 - 14:30 2.00 FISH N DFAL WEXIT 35k# up, 23.5k# do wt. 750 psi at 0.27 bpm. Orient LS tool face while in pilot hole, then orient to HS for ramp and window. Tag at 9,310'. PU . Set do again. Orient to 90L. RIH. Set do at 9310'. PU. RIH. Set do again at 9310'. Orient to 180 deg. RIH. Set down at same spot. Orient to 608. Set down same place. Try setting a little WOB and orient around. Can see DHWOB changes, but still setting down. Try orienting to 458. Set down. Orient to 45L. Set down. Make a few higher speed "runs" at it. All resulting in set dns at 9310'. 14:30 - 16:45 2.25 FISH N DFAL WEXIT Open EDC. Pull out of hole circlulating at min rate. Hold PJSM 16:45 - 17:30 0.75 FISH N DFAL WEXIT At surface. LD venturi BHA w/ no recovery 17:30 - 18:30 1.00 FISH N DFAL WEXIT Cut 120' of coil for chrome management 18:30 - 22:00 3.50 FISH N WEXIT Behead CTC. PT 45k. Behead a-line. PT CTC at 4k 22:00 - 22:30 0.50 FISH N WEXIT MU 3.75" junk mill on BHI 2.4 deg motor 22:30 - 00:00 1.50 FISH N WEXIT RIH w/ BHA #10 circ thru EDC 0.54/1070 5/5/2007 00:00 - 00:25 0.42 FISH N DFAL PROD1 Continue RIH w/junk mill assy 00:25 - 00:55 0.50 FISH N DFAL PROD1 Log tie-in down from 8940'-9150', corr -3.0'. Close EDC 00:55 - 01:15 0.33 FISH N DFAL PROD1 RIH 0.42/1140 circ thru mill following DTF. Set down at 9310.4' on first try at 7'/min. RIH thru window clean at 25'/min w/ nary a bobble. Tag at 9320.3' PUH clean at 30.6k and bring motor to rate 2.43/2670. Ease back in hole 01:15 - 04:55 3.67 FISH N DFAL PROD1 Time mill down to junk 2.43/2622/58 and find first MW at 9319.34' Mill to 9320.5' in one hr and had 4k wob w/ no MW. PU several times while staying below window and get new cutting pattern established. Had a few stalls and some mini overpulls. Cycle pipe when MW ends and grind up junk until no more MW. Pulled thru window one time and was clean both ways. Spend another 30 min at TD w/ minimal stalls/MW. Did not drill any new hole 04:55 - 07:00 2.08 FISH N DFAL PROD1 POH thru window, clean. Had a 10k overpull at HS/LS change point at 9285', but was smooth thru rest of cement ramp. Open EDC at 9100'. POOH circ thru EDC 2.75/2500 07:00 - 07:30 0.50 FISH N DFAL PROD1 At surface. Get off well. LD milling assembly. Large amount of wear on concave face, blades, and upper mandrel. This mill did a lot of work. 07:30 - 08:30 1.00 DRILL P PROD1 MU drilling build assembly on Inteq tools. (HYC 4.25" bi on a 2.0 deg Xtreme). Stab coil. Get on well. Test tools. 08:30 - 10:15 1.75 DRILL P PROD1 Open EDC. Run in hole. Circ at 0.38 bpm. Printed: 5/21/2007 9:10:07 AM • • BP EXPLORATION Page 8 of 17 ~ Operations Summary Report Legal Well Name: 04-01 Common Well Name: 04-01 Spud Date: 11/27/1970 Event Name: REENTER+COMPLETE Start: 4/16/2007 End: 5/10/2007 Contractor Name: NORDIC CALISTA Rig Release: 5/18/2007 Rig Name: NORDIC 2 Rig Number: Date ~ From - To ~ Hours Task Code i NPT Phase 5/5/2007 10:15 - 10:45 0.50 DRILL P PROD1 10:45 - 11:00 0.25 DRILL P PROD1 11:00 - 16:00 I 5.001 DRILL P I PROD1 16:00 - 16:15 0.25 DRILL P PROD1 16:15 - 17:00 0.75 DRILL P PROD1 17:00 - 17:45 I 0.751 DRILL I P I I PROD1 17:45 - 18:00 0.25 DRILL P PROD1 18:00 - 23:10 5.17 DRILL P PROD1 23:10 - 23:35 0.42 DRILL P PROD1 23:35 - 00:00 0.42 DRILL P PROD1 5/6/2007 00:00 - 00:45 0.75 DRILL P PROD1 00:45 - 01:10' 0.42 DRILL N DPRB PROD1 01:10 - 03:15 2.08 DRILL N DPRB PROD1 03:15 - 03:45 0.50 DRILL N DPRB PROD1 03:45 - 05:30 1.75 DRILL N DPRB PROD1 05:30 - 07:30 2.00 DRILL N DPRB PROD1 07:30 - 08:45 1.25 DRILL N DPRB PROD1 08:45 - 10:15 I 1.501 DRILL I N I DPRB I PROD1 10:15 - 11:45 1.50 DRILL P PROD1 11:45 - 12:15 0.50 DRILL P PROD1 12:15 - 13:30 1.25 DRILL P PROD1 13:30 - 16:30 3.00 DRILL N DFAL PROD1 16:30 - 17:00 0.50 DRILL N DFAL PROD1 17:00 - 19:00 2.00 DRILL N DFAL PROD1 Description of Operations Log CCL tie in from 8950' to 9140'. Subtract 1' correction. Close EDC. Orient to low side. Run through pilot hole. Oreitn to HS. RIH. Set down at 9110'. 760 psi ~ 0.16 bpm. SI pump. PU. RIH. Through window OK. Tag btm at 9121'. PU and bring on pumps.2770 psi at 2.5 bpm fs. Circulate at 9118' to try and clear any junk in front of bit. Drill ahead from 9321'. 2780 psi fs at 2.50 in/2.50 out. DHWOB: 3-4k#. BHP/ECD: 4343/9.75 ppg. IA/OA/PVT: 48/52/278 bbls. Had several stalls in first 10 feet, then smoothed out. Wiper trip to 9320'. Hole smooth. Log GR tie in from 9280' to confirm mother wellbore tie in. A 23' discrepency for top of Ivishak depth is suspected, needs to be confirmed. Subtract 23' correction. Log "new" CCL log is correctly tied in to the Ivishak.l When tied in to this log, the ramp top is at 9266', window top at 9278', and window bottom at 9287. '~'~ Run in hole. Set down at 9287' (window btm). PU. Run through ok 2nd try. Drill from 9427' 2.25/2800/ 85L w/ 100-200 psi dill, 1.5-3.5k wob w/ 9.91 ECD concentrating on turn. Drill thru Z3 at 18'/hr and into the 2P. Do not have a surrey yet W iper to window was clean Drill to 9627 Drill from 9627' 2.4/2900/80L w/ 100-300 psi dill, 1-3k wob at 10.01 ECD. Drill to 9670' and still do not have a survey. We are at 200' horizontal separation from the old wellbore. Try a number of things including allow-off w/o success Wiper to window and to 9100' was clean Open EDC. POOH to check directional package 2.6/2500 LD drilling BHA. Bit was 6-2-I and ringing on the nose Change out DGS tool. MU BHA RIH w/ BHA #12 (RB HCC bi bit, 2.0 deg motor) circ thru EDC Log CCL tie in from 8940'. Subtract 24' correction. Log tie in across Ivishak from 9270' to verify correct tie in. No additional correction. Set down at BOW 9287'. PU. Run in hole ok with bobble at BOW. Take directional surveys while tripping in hole. Start surveys at 9455'. Additional surveys every 30'. Not getting expected turn. Review plan and discuss with team. Decide to drill ahead. Should be able to get 25 deg/100 or better with new bit. Drill ahead from 9670'. 2580 psi fs at 2.21 in/2.20 out. 3-4k# DHWOB. IA/OA/PVT: 430/73/263 bbls. Wiper trip to 9300'. Hole smooth. Drill ahead from 9800'. Hit a hard spot. Having trouble communicating with MWD. Trouble shoot from surface. Unable to regain tool functionality. Open EDC once above window. Circulate out of hole. Hold PJSM in ops cab to review BHA handling, pumping slack, and cutting coil. At surface. Flow check. Get off well. LD BHA tools. Close master valve. Rig up to reverse circulate for slack management. Pump slack Printed: 5/21/2007 9:10:07 AM ~ r BP EXPLORATION Page 9 of 17 Operations Summary Report Legal Well Name: 04-01 Common Well Name: 04-01 Spud Date: 11/27/1970 Event Name: REENTER+COMPLETE Start: 4/i 6/2007 End: 5/10/2007 Contractor Name: NORDIC CALISTA Rig Release: 5/18/2007 Rig Name: NORDIC 2 Rig Number: Date From - To Hours Task Code NPT Phase 5/6/2007 17:00 - 19:00 2.00 DRILL N DFAL PROD1 19:00 - 22:00 3.00 DRILL N DFAL PROD1 22:00 - 22:45 0.75 DRILL N DFAL PROD1 22:45 - 00:00 ( 1.251 DRILL I N I DFAL I PROD1 5/7/2007 00:00 - 01:10 1.17 DRILL N DFAL PROD1 01:10 - 03:05 1.92 DRILL N DFAL PROD1 03:05 - 04:15 1.17 DRILL N DFAL PROD1 04:15 - 04:30 0.25 DRILL N DFAL PROD1 04:30 - 05:00 0.50 DRILL N DFAL PROD1 05:00 - 05:20 0.33 DRILL N DFAL PROD1 05:20 - 07:00 1.67 DRILL P PROD1 07:00 - 07:30 0.50 DRILL P PROD1 07:30 - 09:15 1.75 DRILL P PROD1 09:15 - 10:15 I 1.001 DRILL I N I SFAL I PROD1 10:15 - 10:30 0.25 DRILL N SFAL PROD1 10:30 - 11:30 1.00 DRILL P PROD1 11:30 - 15:45 4.25 DRILL P PROD1 15:45 - 16:30 0.75 DRILL P PROD1 16:30 - 19:25 2.92 DRILL P PROD1 19:25 - 20:15 0.83 DRILL P PROD1 20:15 - 22:15 2.00 DRILL P PROD1 22:15 - 00:00 1.75 DRILL P PROD1 5/8/2007 00:00 - 01:30 1.50 DRILL P PROD1 01:30 - 03:40 2.17 DRILL P PROD1 03:40 - 04:20 0.67 DRILL P PROD1 04:20 - 05:00 0.67 DRILL P PROD1 05:00 - 08:30 3.50 DRILL P PROD1 08:30 - 09:15 0.75 DRILL P PROD1 Description of Operations back through reel. Cut off 121' off CT Install CTC and PT 45k. Head up BHI. PT CTC at 4000 psi. MU BHA while pumping slack forward one CT volume over the bunghole 1.8/2300 RIH w/ BHA #13 (2.4 deg motor) to 1500'. Not able to communicate with MW D tools. POOH LD drilling BHA. Tool tested okay. Find that a-line had pulled out of head, but also had 2' of slack forward Finish reconnect a-line to UOC. MU BHA RIH w/ BHA #14 circ thru EDC 0/6/1290 Log tie-in to CCL from 8900'-twice, w/ no correction each time RIH 0.5/1360 and saw no indication of window. RIH to 9350' Log GR tie-in logging up, then log GR tie-in going down. Corr -26.0' Stretch is 1' W iper to TD was clean Drill from 9829' 2.5/3260/85L w/ 200-400 psi dill, 1.5-2.5k wob w/ 10.17 ECD at 86 deg at 8725' TVD in 26P Wiper trip to 9300'. Hole smooth except unable to get past 9921'. Try the usual things. Cannot get past problem depth. Drill ahead from 9921' with original drilled tool face. 2800 psi fs at 2.30 bpm in/2.21 out. 2-3k# DHWOB. IA/OA/PVT: 427/66/246 bbls. Lost 2 deg incl at "sidetrack" point. Drill to 9960'. Pull back to 9900'. RIH. No problem getting past 9921'. Continue to drill ahead. Stop to obtain a survey. Surveys do not look right. There is a disconnect with those obtained just up hole. Decide to pull up hole and log GR tie in to ivishak. Add 33' correction. Some how the SLB depth wheel must have slipped during the previous wiper trip. The "sidetrack" never happened. Run in hole. Re log interval from 9950' to 9980' to get an on depth GR. Drill ahead from 9973'. 2450 psi fs at 2.2 in/2.11 out. 2-3k# DHWOB. ROP variable. Continue left turn. Getting 24 deg doglegs while holding 8733' TVD. Wiper trip to 9300'. Hole smooth. Drill ahead from 10150'. 2450 psi fs at 2.2 in/2.11 out. 2-3k# DHWOB. ROP variable. Continue left turn. Getting 24 deg doglegs while holding 8733' TVD. Start mud swap when nearing EOB. Drill to 10250' which is EOB/turn Wiper to window was clean. Open EDC at 9100' POH for lateral assy circ 2.6/2200 while finish mud swap LD build BHA. Bit was 7-2-I and coring on nose Finish prep Res tool. MU lateral BHA RIH w/ BHA #15 (HYC bi bit, 1.2 deg motor) circ thru bit 0.5/1120 Log GR tie-in down from 9300', Corr -19' Precautionary ream 2.3/2470 to TD tagged at 10245' was clean Log MAD pass up at 300'/hr 1.4/1720. Add 3' correction. Run in hole with reduced pump rate to reduce mwd tool vibration (1850 psi at 1.54 bpm). Re-log a short interval at Printed: 5/21/2007 9:10:07 AM ~ r BP EXPLORATION Page 10 of 17 Operations Summary Report Legal Well Name: 04-01 Common Well Name: 04-01 Spud Date: 11/27/1970 Event Name: REENTER+COMPLETE Start: 4/16/2007 End: 5/10/2007 'Contractor Name: NORDIC CALISTA Rig Release: 5/18/2007 'Rig Name: NORDIC 2 Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations ~ 5/8/2007 08:30 - 09:15 0.75 DRILL P PROD1 9980'. Hole smooth. 17k# do wt. 09:15 - 14:00 4.75 DRILL P PROD1 Drill ahead from 10247'. 2620 psi fs at 2.33 in/2.33 out. IA/OA/PVT: 288/56/255 bbls. Continue turn to left. Drill to 10400' 14:00 - 14:40 0.67 DRILL P PROD1 Wiper to/thru window was clean. PUH to above TOC 14:40 - 15:00 0.33 DRILL N SFAL PROD1 Park at 9140'. Replace bearing on injector chains 15:00 - 16:00 1.00 DRILL N PROD1 RIH thru window clean at 0.5/1100. Wiper to TD at 2.3/2500 was clean 16:00 - 16:50 0.83 DRILL P PROD1 Drill from 10400' to 10434' in a 26 api sand. Having erratic MW and slow penetration rate 16:50 - 17:45 0.92 DRILL P PROD1 Wiper to window was clean 17:45 - 19:30 1.75 DRILL N DFAL PROD1 POH to check BHA circ 1.3/1630 19:30 - 19:45 0.25 DRILL N DFAL PROD1 Flow check &PJSM &THA w/ crew prior to handling coil & BHA. 19:45 - 21:52 2.12 DRILL N DFAL PROD1 Break off coil from BHA & P.T. coil to 4000 psi -good test. PU & stand back BHA & visually inspect BHA for pressure loss - good. C/O motor. Clean debris from inside of bit (plastic wrapping & coal). Simultaneously inspect injector chain bearings -good. MU BHA to coil. 21:52 - 23:50 1.97 DRILL N DFAL PROD1 RIH w/ BHA #16 (HYC bi bit, 1.2 deg motor) circ thru bit 0.5/1201 23:50 - 00:00 0.17 DRILL N DFAL PROD1 Log GR tie-in down from 9300' 5/9/2007 00:00 - 00:45 0.75 DRILL N DFAL PROD1 Sat down twice at 9311' going 1.5fUmin, ran through no problem at 10fUmin. Log GR tie-in down from 9311', Corr -23' 00:45 - 01:30 0.75 DRILL P PROD1 Wiper trip to 10434' 2.Obbl/min ~ 2500 psi. Hole smooth. 01:30 - 02:49 1.32 DRILL P PROD1 Drill ahead from 10434'. 2550 psi fs at 2.05 in/2.01 out. IA/OA/PVT: 342/61/245 bbls. ROP is 40-95 ft/hr with 2.2K W OB. 02:49 - 03:46 0.95 DRILL N SFAL PROD1 Swab on pump #1 is leaking. W iper trip to 9100'. PJSM &THA w/ Nordic crew. Review procedure & lock out procedure w/ crew. 03:46 - 04:23 0.62 DRILL N SFAL PROD1 Open EDC and circulate bottoms up from 9100', keep coil slowly moving up hole. 04:23 - 05:20 0.95 DRILL P PROD1 Pump #1 is fixed & tested. Close EDC &RIH w/ 1.4bbls/min ~ 2000 psi. 05:20 - 06:30 1.17 DRILL P PROD1 Drill ahead from 10497'. 3050 psi fs at 2.45 in/2.37 out. IA/OA/PVT: 442/68/238 bbls. ROP is 30-55 fUhr with 1.5-2.2K WOB. Drill to 10529' and not sliding well. Order dry product from MI 06:30 - 07:15 0.75 DRILL P PROD1 Spend time reaming and back reaming 24N? due to sticky hole and non-sliding 07:15 - 08:15 1.00 DRILL P PROD1 Attempt to drill ahead again and drill to 10535' 08:15 - 09:15 1.00 DRILL P PRODi Ream and backream again due to inability to slide. Tend to stack and stall Receive Flolube and 776 on location 09:15 - 09:35 0.33 DRILL P PROD1 Drill w/ stacking and stalling w/ numerous pickups to 10544' and appear to get out of ratty drilling at 10540' 09:35 - 10:00 0.42 DRILL P PROD1 120' wiper while swap pumps and PT leaking swab cap 10:00 - 10:30 0.50 DRILL P PROD1 Attempt to drill again, but stacking/stalling and not sliding too well. Drill to 10553' while continuing to fix equipment problems to mix a lubricious pill 10:30 - 11:40 1.17 DRILL P PROD1 Slow wiper while fin mix pill and start it downhole 11:40 - 12:30 0.83 DRILL P PROD1 Drill ahead like there was never a problem 2.36/3200/160L w/ Printed: 5/21/2007 9:10:07 AM BP EXPLORATION Page 11 of 17 ~ Operations Summary Report Legal Well Common W Event Nam Contractor Rig Name: Date Name: 0 ell Name: 0 e: Name: From - To 4-01 4-01 REENTE NORDIC NORDIC Hours ~ R+COM CALIST 2 Task PLET A Code' E NPT Start Rig Rig Phase f Spud Date: 11/27/1970 : 4/16/2007 End: 5/10/2007 Release: 5/18/2007 Number: Description of Operations 5/9/2007 11:40 - 12:30 0.83 DRILL P PROD1 100-300 psi dill, 1-3k wob at 10.22 ECD at 100'/hr until running out of pill at 10565'. Then, penetration rate ended 12:30 - 14:00 1.50 DRILL P PROD1 Wiper while wo another pill 14:00 - 14:30 0.50 DRILL P PROD1 Resume drilling 2.26/3030/90L albeit noTlike before. Assume we are back in shale. Drill to 10570' 14:30 - 16:00 1.50 DRILL P PROD1 W iper to window while incr lubricant in whole mud system 16:00 - 20:20 4.33 DRILL P PROD1 Drill from 10570' 2.30/3030/90L IA/OA/PVT: 750/115/216 bbls. 20:20 - 20:30 0.17 DRILL P PROD1 Short 80' wiper trip -clean. Last sample from 10,575' was claystone. 20:30 - 23:05 2.58 DRILL P PROD1 Drill from 10595' 2.30/3040/90L IA/OA/PVT: 812/125/211 bbls. 23:05 - 23:20 0.25 DRILL P PROD1 Short 70' wiper trip -sat down @ 10620', otherwise smooth.. Last sample from 10,625' was claystone. 23:20 - 00:00 0.67 DRILL P PROD1 Drill from 10,647' 2.30/3090/90L IA/OA/PVT: 845/131/202 bbls. 5/10/2007 00:00 - 02:50 2.83 DRILL P PROD1 Continue to drill from 10,647' 2.30/3090/90L IA/OA/PVT: 845/131/202 bbls. 02:50 - 04:45 1.92 DRILL P PROD1 Stacking & stalling. Wiper from 10,660' to 9400' -smooth hole. 04:45 - 07:00 2.25 DRILL P PROD1 Drill from 10,660' 2.25/3000/90L IA/OA/PVT: 819/131/190 bbls. Drill to 10674' Penetration rate is too slow 07:00 - 07:45 0.75 DRILL P PROD1 Wiper to/thru window was clean 07:45 - 10:00 2.25 DRILL P PROD1 POH circ thru bit 2.2/2800 10:00 - 11:00 1.00 DRILL P PRODi LD drilling BHA. Motor was tite. Bit was 7-2-I and starting to core on the nose 11:00 - 16:00 5.00 BOPSU P PROD1 Fill stack w/ water. Perform biweekly BOPE test. AOGCC Bob Noble witnessed test 16:00 - 19:15 3.25 DRILL P PROD1 Break down HP filters in reel house to check for debris CT chrome management. Cut off CTC. Cut off 120 ft. Install dimple connector. 19:15 - 20:30 1.25 DRILL P PROD1 Pull test coil connector to 45,000 lbs. Start to re head BHI tools. 20:30 - 22:30 2.00 BOPSU P PROD1 Fill coil & P.T. connector to 4000 psi -good test. P.T. inner reel valve per BOPE test. P.T. stuffing box per BOPE test. 22:30 - 23:20 0.83 DRILL P PROD1 PJSM & THA prior to handling BHA. PU & MU BHA & stab coil onto BHA. 23:20 - 23:50 0.50 DRILL N SFAL PROD1 Spray down injector with water & flush needle bearings into sump. Vacume out sump to collect needle bearings & trash. 23:50 - 00:00 0.17 DRILL P PROD1 RIH w/ coil. IA/OA/PVT: 6/42/113 bbls. Pump through coil ~ min rate. 5/11/2007 00:00 - 00:30 0.50 DRILL P PROD1 Continue RIH. 00:30 - 00:50 0.33 DRILL N SFAL PROD1 Stop at 1000ft and align injector gooseneck. 00:50 - 02:20 1.50 DRILL P PROD1 Continue to RIH 02:20 - 02:50 0.50 DRILL P PROD1 Sat down twice at 9312', ran through no problem at 20ft/min. Log GR tie-in down from 9312', corr -25' 02:50 - 04:00 1.17 DRILL P PROD1 Wiper trip to 10674' 2.Obbl/min @ 2316 psi. Sat down at 10,579ft. Bring rate up to 2.5 bbl/min @ 3000 psi. seeing motor work from 10,560ft to 10,595ft. Sat down @ 10,595ft. Back reem up hole. Stall while picking up ~ 10,560ft. R1H, appears that we lost a burst dick on the pulsation dampener on pump #2. Switch to pump #1 & pick up. Seeing motor work C~ 10,560ft to 10,550ft, & 10,545ft. RIH, sat down. Pick up to 10,450ft 28-31 k#. 04:00 - 04:20 0.33 DRILL P PROD1 RIH ~ 25 fUmin, 2.45 bbl/min ~ 2875 psi. 17.8k # RIW. Sat down but popped through @ 10,553ft. Printed: 5/21/2007 9:10:07 AM ~ ~ BP EXPLORATION Page 12 of 17 Operations Summary Report Legal Well Common W Event Nam Contractor Rig Name: Date i Name: 0 ell Name: 0 e: Name: From - To 4-01 4-01 REENTE NORDIC NORDIC Hours i R+COM CALIST 2 Task PLET A Code E NPT Start Rig Rig Phase ' Spud Date: 11/27/1970 : 4/16/2007 End: 5/10/2007 Release: 5/18/2007 Number: Description of Operations 5/11/2007 04:20 - 04:55 0.58 DRILL P PROD1 Drill ahead from 10674'. 2725 psi fs at 2.41 in/2.47 out. IA/OA/PVT: 353/62/20 bbls (mud swap). ROP is 60-85 ft/hr with 1.7-3.2K WOB. 04:55 - 07:40 2.75 DRILL P PROD1 Reverse drilling break. 10k #Ibs over pull off bottom. Resume drilling. 2742 psi fs at 2.41 bbl/min. Drill to 10825' ', 07:40 - 10:00 2.33 DRILL P PROD1 Wiper to window. Had a few 5k over pulls 10600-10500'. Had a set down w/ MW at 10545'. Ream this area until clean. RIH and tag at 10826' 10:00 - 11:15 1.25 DRILL P PROD1 Drill from 10826' 2.04/2370/108 w/ 100-250 psi MW w/ 0.5-2,Ok wob w/ 9.90 ECD. Bring TF to HS in 21 P and to level out for entering Zone 1. Using reduced pump rate due to BHI getting good vibrations ... Drill to 10863' 11:15 - 12:10 0.92 DRILL P PROD1 Wiper to 10500' while repair pump #1. Still have 5k over pull and MW at 10545' 12:10 - 15:30 3.33 DRILL P PROD1 Drill from 10863-10952' 15:30 - 16:50 1.33 DRILL P PROD1 W iper to window was clean 16:50 - 17:30 0.67 DRILL P PROD1 Log tie-in up from 9320'. Add 6.0' ~ Experiment w/ pumping low rate thru MM's (needed water instead of mud) 17:30 - 18:45 1.25 DRILL P PROD1 Wiper back to TD. Some motor work ~ 10,545 ft & 10,750ft. 18:45 - 20:00 1.25 DRILL P PROD1 Drill ahead from 10,956ft. 2900 psi fs at 2.3 in/2.3 out. IA/OA/PVT: 702/99/312 bbls. ROP is 40-60 ft/hr with 2.82K W OB. 20:00 - 20:10 0.17 DRILL P PROD1 Stacking weight, wiper trip to 10,920ft. Slight over pull from 10,970ft-10,960ft. 20:10 - 20:45 0.58 DRILL P PROD1 Drill ahead from 11,000ft. 2872 psi fs at 2.31 in/2.31 out. IA/OA/PVT: 754/104/307 bbls. ROP is 30-50 ft/hr with 2.8-5.OK W OB. 20:45 - 21:20 0.58 DRILL P PROD1 Suspect bit balling, last sample was clay stone & shale. Add water to pit #3 & pump 30 bbl to-vis pill 21:20 - 21:30 0.17 DRILL P PROD1 Stacking weight, wiper trip to 10,900ft. Slight over pull at 10,960ft. Sat down at 10,935ft, pick up 1000 psi coil pressure increase. 21:30 - 21:45 0.25 DRILL P PROD1 Drill ahead from 11,024ft. 2872 psi fs at 2.31 in/2.31 out. IA/OA/PVT: 774/107/315 bbls. ROP is 30-50 ft/hr with 2.8-5.OK W OB. 21:45 - 22:00 0.25 DRILL P PROD1 Stacking weight. Have 900 psi motor work & 9 k WOB. Wiper trip. Clean pick up, motor work from 11,024ft to 10,987ft. 22:00 - 22:10 0.17 DRILL P PROD1 Setting down at 11,018ft. Try to work to bottom. Not drilling off, have 600 psi motor work. Bottoms up sample from Lo-Vis pill resulted in rubber pieces across shaker. 22:10 - 00:00 1.83 DRILL N DFAL PROD1 POH. 5/12/2007 00:00 - 00:50 0.83 DRILL N DFAL PROD1 PJSM & THA prior to handling BHA while POH with coil. 00:50 - 02:20 1.50 DRILL N DFAL PROD1 Unstab coil from BHA. Break off old motor & pick up other ~, motor. Clean bit (1 nozzle plugged with rubber), 1 chipped tooth on face & 1 chipped back reaming tooth. Re-run same PDC bit. 02:20 - 04:15 1.92 DRILL N SFAL PROD1 Lost communication with tool. Unstab from BHA & check/clean connection. Replace lower quick connect. 04:15 - 06:25 2.17 DRILL N DFAL PROD1 RIH with 1.2 degree motor & 3.75" PDC bit. 06:25 - 06:50 0.42 DRILL N DFAL PROD1 Log tie-in down from 9317' CTD (did not see window). Corr -27' 06:50 - 07:50 1.00 DRILL N DFAL PROD1 W Iper to TD. Had set down and OP at 10715' Printed: 5/21/2007 9:10:07 AM BP EXPLORATION Page 13 of 17 Operations Summary Report Legal Well Common W Event Nam Contractor Rig Name: Date II Name: 0 ell Name: 0 e: Name: From - To ~ . 4-01 4-01 REENTE NORDIC NORDIC Hours -- R+COM CALIST 2 Task PLET A Code E NPT Start Rig Rig Phase I Spud Date: 11/27/1970 : 4/16/2007 End: 5/10/2007 Release: 5/18/2007 Number: Description of Operations 5/12/2007 07:50 - 09:10 1.33 DRILL N DFAL PROD1 Had a hard time getting by 10700-800' w/ set downs and overpulls. Ream and back ream shale area from 10700-800' with high GR area at 10750' being the worst 09:10 - 09:35 0.42 DRILL N DFAL PROD1 Finish wiper to TD and had MW and wt loss at 10960'. Find TD at 11004'? Nope, just some more shale. Redrilt to TD at 11021' 09:35 - 10:45 1.17 DRILL P PROD1 Drill from 11021' 2.34/3050/1058 w/ 100-500 psi dill, 2-4.5k wob w/ 10.4 ECD to 11074' and stacking 10:45 - 11:00 0.25 DRILL P PROD1 BHA wiper and had trouble getting down past 11017'. Ream until it cleaned up 11:00 - 14:30 3.50 DRILL P PROD1 Drill from 11074' 2.46/3330/60-908 w/ 100-500 psi dill, 2-5k wob w/ 10.50 ECD at 80 deg. Drill to 11175' 14:30 - 15:50 1.33 DRILL P PROD1 Wiper to window. Had a few overpulls w/ MW around 11020', 10750' and 10540' 15:50 - 16:15 0.42 DRILL P PROD1 Log tie-in up from 9360', corr +3' ~, 16:15 - 17:30 1.25 DRILL P PROD1 Wiper back to TD was not too bad. Slowed running speed to ~I 15-20'/min from 10500' to 10810' and had no set downs, just a few spots w/ MW 17:30 - 20:15 2.75 DRILL P PROD1 Drill from 11175' 2.32/3290/708 w/ 200-500 psi dill, 2-5k wob w/ 10.49 ECD at 81 deg 20:15 - 20:25 0.17 DRILL P PROD1 BHA wiper. Clean pickup. 20:25 - 22:20 1.92 DRILL P PROD1 Drill from 11294' 2.46/3270/758 w! 200-500 psi dill, 2-5k wob w/ 10.57 ECD at 81 deg 22:20 - 23:35 1.25 DRILL P PROD1 Wiper to window. Had a few overpulls w/ MW around 11015', 10980', 10820-10810', 10745'-10735', 10660'-10650' and 10540'. All relate to TF changes. 23:35 - 00:00 0.42 DRILL P PROD1 Log tie-in. No correction needed. 5/13/2007 00:00 - 01:15 1.25 DRILL P PROD1 W iper to TD. Swap to new mud while RIH. 01:15 - 02:30 1.25 DRILL P PROD1 Drill from 11326' 30-50fUhr 2.46/3275/758 w/ 200-500 psi dill, 2-4k WOB w/ 10.72 ECD with 144 degree BHT 02:30 - 03:30 1.00 DRILL P PROD1 New mud at surface. Drill from 11349' 10-40ft/hr 2.46/2700/908 w/ 200-400 psi dill, 2-4k WOB w/ 9.93 ECD 03:30 - 04:50 1.33 DRILL P PROD1 TD has been reached. Wiper to window for final tie in. 04:50 - 05:20 0.50 DRILL P PROD1 Log for tie in. +2ft correction. 05:20 - 06:40 1.33 DRILL P PROD1 Wiper to TD w/ one set down at 10750'. Tag TD at 11374' which is final corrected TD 06:40 - 08:00 1.33 DRILL P PROD1 W iper to window. 2.5/2600? w/ OP's and MW at the usual spots 08:00 - 08:50 0.83 DRILL N DFAL PROD1 Park at 9726' w/ pinhole on inside of bend. Discuss. Then, pull bad spot onto reel Had 200k RF in chrome and 521 k RF total 08:50 - 11:05 2.25 DRILL P PROD1 POH thru rest of OH and window, clean while filling from BS. Fin POOH for liner 11:05 - 12:00 0.92 DRILL P PROD1 LD drilling BHA. Begin circ FW at min rate thru bung hole MIRU SWS N2 12:00 - 12:15 0.25 DRILL P PROD1 Crew change/safety mtg 12:15 - 13:00 0.75 DRILL P PROD1 RU additional hoses to pump mud out of reel house. Fin displace CT w/ FW 0.37/680 w/ about 1/2 going into reel house 13:00 - 14:15 1.25 DRILL P PROD1 PT SWS N2 ~ 4000 psi. Blow down reel w/ N2 to tiger tank and bleed off 14:15 - 17:00 2.75 CASE P RUNPRD Cut off CTC. Install internal grapple. Pull CT to reel and secure Clean up mud on bombay doors Back in VECO lowboy Printed: 5/21/2007 9:10:07 AM BP EXPLORATION Page 14 of 17 Operations Summary Report Legal Well Name: 04-01 Common Well Name: 04-01 Event Name: REENTER+COMPLETE Contractor Name: NORDIC CALISTA Rig Name: NORDIC 2 Start: 4/16/2007 Rig Release: 5/18/2007 Rig Number: Spud Date: 11 /27/1970 End: 5/10/2007 Date I From - To ' Hours I Task I Code I NPT 5/13/2007 ~ 17:00 - 17:15 0.251 CASE I P 17:15 - 18:00 0.75 CASE P 18:00 - 00:00 6.00 CASE P 5/14/2007 00:00 - 03:15 3.25 CASE P 03:15 - 03:25 0.17 CASE P 03:25 - 04:00 0.58 CASE P 04:00 - 05:00 1.00 I CASE I N I SFAL 05:00 - 09:30 4.50 CASE N SFAL 09:30 - 09:40 0.17 CASE N SFAL 09:40 - 11:40 2.00 CASE P 12:10-13:10 10: OICASE P 13:10 - 13:40 0.50 CASE P 13:40 - 15:10 1.50 CASE P 15:10 - 16:00 0.83 CASE P 16:00 - 16:45 I 0.751 CASE I P 16:45 - 18:30 ~ 1.751 CASE ~ P 18:30 - 20:15 I 1.75 I CASE I P 20:15 - 21:00 I 0.75 I CASE I P 21:00-21:10 ~ 0.17 21:10 - 21:25 0.25 21:25 - 22:00 I 0.58 I R Phase ( Description of Operations RUNPRD Safety mtg for load out reel w/SWS Safety mtg for run liner w/ Nordic RUNPRD Nordic set back injector. RU floor to run liner SWS -oad out used 2-3/8" E-CT RUNPRD Run 2-7/8" & 3-3-16" liner. Fill liner while changing out elevators. RUNPRD Continue to RIH with liner. RUNPRD PSJM &THA prior to stabbing coil. Investigate traction motor. RUNPRD Make injector ready to stab coil. C/O winch cable on drum to pull coil. PJSM &THA prior to stabbing coil. RUNPRD Investigate traction motor. Coupling from traction motor to hydraulic pump is out of alignment. RUNPRD Pull test grapple connector & remove shipping bar from reel. Schlumberger master coil mechanic called & shut us down and prevented us from using the traction motor. Started Schlumberger down time C~ 4:OOam. SWS mechanics and Nordic electrician evaluated traction motor, hyd pump and blower fan and found no problems. Start power pack and leave running RUNPRD Safety mtg re: pull and stab CT RUNPRD Pull CT to floor and stab into injector. Install slip-on CTC and dart catcher. Pump 3 bbls McOH, PT inner reel valve. Fill CT w/ FW @ 3 bpm. Load dart and displace w/ FW 2.4/1060 and dart hit at 51.5 bbls RUNPRD Install BTT CTC. PT 35k, 4000 psi RUNPRD Fill CT w/ mud while displ FW to cuttings box thru bung hole Nordic electrician experiment w/'in' MM RUNPRD Install BTT CTLRT RUNPRD RIH w/ liner on CT circ 0.33/1020 w/ mud RUNPRD 9100' 35.2k, 14.2k 0.32/990 RIH thru window, clean and head to TD at 60'/min. First setdown at 10510'. Lost weight from 13k to 3k by 11333' CTD RUNPRD Work pipe w/ and wo pump and set down solid at 11333' for 30 min, PUH 60' 41-65k at times and finally work by obsruction and work to TD tagged several times at 11398' CTD stacked wt. Normal correction is -23' RUNPRD Park at ball drop spot and load 5/8" aluminum ball. Circ ball to seat w/full returns 2.5/3200. Slow to 0.5 bpm for last 10 bbls. Had to surge to get on seat. Ball seat sheared at 4150 psi. PU 30.8k and were released from liner. Set back down and circ mud 0.78/1414 during crew change. RUNPRD Swap entire wellbore to 2% KCL. PJSM &THA prior to cementing operations. RUNPRD Begin batch mixing cement. KCL returns at surface at 173 bbls pumped, clean KCL at 180 bbls. Cement is up to weight 15.90 ppg @ 20:30 with 4 hrs thickening time. RUNPRD 2.00 bbl/min C~3 1400 psi w/ KCL. Pressure test cement lines 250/3000 psi. RUNPRD Zero micro motion with cement @ MM & start pumping cement down coil. 16.00 ppg, 2.00 bbl/min in & 1.89 bbl/min out. Pumped 23.1 bbls of 16.00 ppg cement. RUNPRD Stop pumping, isolate reel & clean up cement lines with biozan & vac out. Load dart into coil. Having minor difficulties loading Printed: 5/21/2007 9:10:07 AM • • BP EXPLORATION Page 15 of 17 .Legal Well Name: Common Well Name Event Name: Contractor Name: Rig Name: Operations Summary Report 04-01 04-01 Spud Date: 11 /27/1970 REENTER+COMPLETE Start: 4/16/2007 End: 5/10/2007 NORDIC CALISTA Rig Release: 5/18/2007 NORDIC 2 Rig Number: Date ~ From - To Hours ~ Task 5/14/2007 21:25 - 22:00 0.58 REMCD 22:00 - 22:25 0.42 REMCD 22:25 - 22:50 0.42 REMC~ 22:50 - 00:00 1.17 REM( 5/15/2007 00:00 - 01:50 1.83 REM( I ~~ 01:50 - 02:05 0.25 REM( 02:05 - 03:00 0.92 RIGU 03:00 - 03:50 0.83 RIGU 03:50 - 04:15 0.42 RIGU 04:15 - 08:15 4.00 RIGU 08:15 - 10:00 1.75 RIGU 10:00 - 11:35 1.58 RIGU 11:35 - 11:45 0.17 CASE 11:45 - 12:45 1.00 CASE 12:45 - 15:12 2.45 CASE 15:12 - 15:30 15:30 - 16:45 16:45 - 17:00 17:00 - 18:30 0.30 CASE 1.25 CASE 0.25 CASE 1.50 CASE 18:30 - 18:45 18:45 - 20:45 0.25 CASE 2.00 CASE i Code NPT ~ Phase Description of Operations P RUNPRD dart. Mix another 10bbls of biozan in pits (cementers used 8 bbls for clean up). P RUNPRD Zero coil reel MM, pressure up & launch dart with biozan. 2.52bpm in / 2.43bpm out ~ 1200 psi CTP. Pumped 30 bbls of biozan, swap to KCL. Zeroed return MM ~ 44.3 bbls on the in MM. P RUNPRD 50.5 bbl away on MM @ reel. Reduce pump rate to .66 bpm, 322 psi. 51.4 bbls away dart has landed (7.0 bbs return MM), 3050 psi to shear. Displace liner w/ dart ~ 1.3 bpm in MM 1.16 bpm out MM, 1500 psi CTP. Reduce pump rate to 0.95 bpm 1447psi at 66.0 bbls on in MM, 20.0 bbls out MM. Dart has landed 67.2bbls on in MM, 21.2 bbls on retrun MM (21.2 bbls behind pipe). Pressure up to 2900 psi, shut down and open Baker choke to check the floats. Floats are holding, pressure up coil to 400 psi and unsting from deployment sleeve. P RUNPRD POH while pumping coil displacement only. P RUNPRD Continue to POH. SLB lab called, 250psi compressive strength C~3 00:30. P RUNPRD PJSM &THA for handling BHA. Break apart liner BHA. P LOW ER1 Make up BHA with proper torque & locke tite on appropriate threads. Drift each CSH joint on the pipe skate before picking it up & running it in the hole, rattle as required. PJSM prior to handling RA source. Pick up SWS logging source to RF & logging tools. P LOWERI Install source in logging tools & make up rest of logging BHA. P LOWERI Stop RIH & secure well. Veco water truck had hydraulic spill. Make appropriate phone calls -5700. P LOWERI Continue to RIH. SRT notified us not to contain spill with absorb. Fin MU 78 jts 1-1/4" CSH. Add upper MHA P LOWERI RIH w/ BHA #20 circ 15 bbls fresh Flo Pro mud at 0.4/300. Displace w/ KCI P LOWERI Log down at 30'/min from 8700' ACS move in a blade and loader w/ dump bin. Scrape up and haul off contaminated snow/ice from spill area P RUNPRD Tag at 11297' CTD which is 60' higher than expected. Start pump and attempt to make hole, but had no progress after 10 min. Will find out what PBD is when CNL is downloaded P RUNPRD Log up from 11297' to 8700' at 60'/min leaving mud in liner for perforating POOH circ thru mill filling hole w/ 0.5 bpm returns. Just started getting dirty returns back when .. . P RUNPRD Park at 8067' after notice pinhole on reel already one wrap onto reel Finish POOH filling from the BS w/ charge pump P RUNPRD Held PJSM on standing back CSH in derrick P RUNPRD POOH standing CSH in the derrick P RUNPRD Held PJSM on handling MCNL logging tool with RA source P RUNPRD Break off logging tools & download data. LD rest of BHA. MIRU & cool down N2 unit. CO with day crew. P RUNPRD PJSM &THA prior to blowing down reel with N2. P RUNPRD Blow down reel with N2. Stop pumping N2, rig down pump unit. Let coif bleed off. Re-rig winch drum for handling coil. Install Printed: 5/21/2007 9:10:07 AM BP EXPLORATION Operations Summary Report .Legal Well Name: Common Well Name ..Event Name: 'Contractor Name: ~I, Rig Name: Date 5/15/2007 04-01 04-01 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 Start: 4/16/2007 Rig Release: 5/18/2007 Rig Number: Page 16 of 17 ~ Spud Date: 11/27/1970 End: 5/10/2007 From - To ! Hours I Task I Code NPT I Phase 18:45 - 20:45 2.00 CASE P 20:45 - 21:00 0.25 CASE P 21:00 - 22:00 1.00 CASE P 22:00 - 22:45 I 0.751 CASE I P 22:45 - 00:00 ~ 1.25 ~ CASE ~ P 15/16/2007 100:00 - 02:51 I 2.851 CASE I P 02:51 - 03:15 I 0.401 CASE I P 03:15 - 03:30 0.25 CASE P 03:30 - 04:35 1.08 CASE P 04:35 - 06:00 I 1.421 PERFOBI P 06:00 - 07:00 1.00 PERFO P 07:00 - 09:30 2.50 PERFO P 09:30 - 12:30 I 3.001 PERFOBI P 12:30 - 13:00 I 0.501 PERFOBI P 13:00 - 14:00 I 1.001 PERFOBI P 14:00 - 16:30 I 2.501 PERFOBI P 16:30 - 18:00 I 1.501 PERFOBI P 18:00 - 18:30 I 0.501 PERFOBI P 18:30 - 21:20 I 2.831 PERFOBI P Description of Operations RUNPRD internal grapple connector in coil. RUNPRD PJSM &THA prior to unstabbing coil from injector. RUNPRD Pull coil across & secure ~ reel. PJSM &THA prior to performing LLT. RUNPRD Pressure test liner lap to 2000 psi & chart for 30 min -passed. Prepare reel for unloading from reel house, hook up slings to bridge crane, unbolt lock plates, retract drive motors. RUNPRD Drop reel from reel house & pick up new reel. Release from bridge crane & secure lifting shackles. RUNPRD Fill out hot work permit. Prep coil & MU internal grapple for stabbing into the injector. Make up hard line to coil nubbin on inside of reel, having great difficulties doing this. Load pipe shed with 2" pert guns and sort according to pert interval. RUNPRD Pull test grapple connector & re-torque. Release coil from shipping bar & remove clamp. RUNPRD PJSM &THA for stabbing coil & picking up pert guns. RUNPRD Pull coil across & stab into injector & hook up to coil into the levelwind arm. Cut 5' of coil to remove grapple connector. Dress end of coil tubing, install SLB dimple connector & pull test to 35k. Attach dart catcher, install injector legs & sit injector over bung hole on rig floor. C/O coil stabbing winch cable for injector side load cable on RF winch drum. LOWERI Begin picking up pert guns & BHA. Simultaneously, pig & fill coil w/ methanol spear & KCL. LOW ER1 Crew change PJSM to finish PU the remaining 15 pert guns. LOW ER1 Pumped 2-3/8 CT dart Vol= 60.9 bbl. SIMOP picking up 15 2" pert guns. Run 52 jts of 1-1/4" CSH as per BHA summery. Liner Summary: Top of liner at 8,983 ft PBTD 11,335.25 ft Shoe ~ 11,369.33 ft MCNL tagged at 11,327.69 ft Delta L = 7.56 ft = 0.04 bbl cement LOW ER1 RIH with Perf run # 1 wt at 8900 ft = 27.5k up, RIH to 11,200 ft Wt up 36k Tagged at 11344 ft and corrected -13 ft to 11, 327 ft (Current PBTD). Pumped 8 bbl of HV Flo-Pro LOWERI Dropped 1/2" AI ball and lanched same with 500 psi. Confirmed MM data. LOW ERi Displacing 1/2" ball to firing head. Vol = 63.5 bbl. Had to jack around with flow rate to get ball on seat. Perforated at 3500 psi from 11,300 ft to 10,500 ft. Pulled a little tight coming up from 11,300 ft LOW ERi POOH and painted flag at 7500 ft EOP. Stopped at 8,900 ft and checked flow, (No flow). POOH. Held PJSM while POOH LOW ER1 Tagged up, checked flow(OK) Unstabbed injector and POOH standing back 1.25" CSH. Circ at min rate through coil to bung hole on RF. LOW ER1 C/O with day crew. PJSM &THA & daily walkaround/inspection. Begin mixing a 30 bbl pert pill. SLB ET's are working on wireless video, SLB screens are inactive. VP's = 242 bbls per rig monitor system. LOWERI Have holes in guns. Fill hole, took 1 bbl to get returns. Continue to POH with guns. Printed: 5/21/2007 9:10:07 AM • BP EXPLORATION Page 17 of 17 Operations Summary Report Legal Well Name: 04-01 Common Well Name: 04-01 Event Name: REENTER+COMPLETE Contractor Name: NORDIC CALISTA Rig Name: NORDIC 2 Date I From - To I Hours I Task I Code 15/16/2007 21:20 - 22:00 0.67 PERFO P 22:00 - 22:40 0.67 PERFO P 22:40 - 23:10 0.50 PERFO P 23:10 - 00:00 0.83 PERFO P 5/17/2007 00:00 - 00:50 0.83 PERFO P 00:50 - 02:15 1.42 PERFO P 102:15 - 04:30 2.251 PERFOB P 04:30 - 06:00 I 1.501 PERFOBI P 06:00 - 07:00 1.00 PERFOB~ P 07:00 - 10:30 3.50 PERFOB P 10:30 - 12:24 1.90 W HSU R I P 12:24 - 13:27 1.05 WHSUR P 13:27 - 16:00 2.55 WHSUR P 16:00 - 17:30 1.50 DEMOB P 17:30 - 22:30 5.00 DEMOB P 22:30 - 23:00 0.501 DEMOB P 23:00 - 23:30 I 0.501 DEMOB I P 23:30 - 00:00 0.50 DEMOB P 5/18/2007 00:00 - 01:00 1.00 DEMOB P 01:00 - 02:00 1.00 bEMOB P 02:00 - 02:15 0.25 DEMOB P 02:15 - 03:00 0.75 DEMOB P 03:00 - 05:00 2.00 DEMOB P 05:00 - 09:00 4.00 DEMOB P Spud Date: 11/27/1970 Start: 4/16/2007 End: 5/10/2007 Rig Release: 5/18/2007 Rig Number: NPT Phase i, Description of Operations -- -L_ _ _--- -- LOWERI All guns fired. Pick up new guns. LOWERI PU &RIH with CSH LOW ER1 Pick up injector & stab on to BHA. Stab on to well. LOWERI Bump up & set depths &RIH with pert BHA. VP's = 240. LOWERI Continue RIH w/ 2" pert guns. LOWERI RIH with Perf run # 2 wt at 8844 ft = 27.5k up, At flag, correct depth to 8817 ft. RIH to 10,050 ft Wt up 32k. Drop 1/2" AL ball w/ pert pill, launched same with 500 psi. Ball on seat at 63 bbls, perforated at 3300 psi from 10,020 ft to 9970 ft. LOW ERi Stopped at 9440 ft and checked flow, (No flow). POOH. Held PJSM while POOH LOWERI Tagged up, checked flow (OK). VP's = 236 bbls. Unstabbed injector and POOH laying down 1.25" CSH. Circ at min rate through coil to bung hole on RF. LOW ER1 Crew change, PJSM on LD perf guns LOWERI LD perf guns, all shots fired, RIH with 20 stands of 1.25" CSH. LD same POST RU to FP the tubing using 55 bbl of diesel from 2500 ft to surface. Took sample to confirm quality of diesel. Installed BPV and closed Master Valve POST RU and Pumped coiled tubing pickle juice, POST Blow down CT with N2 folllowing PJSM on pumping N2 and prep to pull CT across pipe shed. Held PJSM on demob CT POST Pull CT across pipe shed POST ND kill & choke line. RD BOP hoses. ND BOP stack & PU w/ blocks & secure in cellar. Engage drive system & warm up drive unit via spinning tires. NU tree cap on top of master valve. RD IA & OA sensors & crash guards. TBG/IA/OA/OOA = NA/0/0/0 psi. POST PJSM &THA prior to moving off well. Simultaneously, SLB & Nordic electrician are locking out SCR's to remove traction motor. POST Move off well. Position rig off edge of pad to remove SLB traction motor. POST RD SLB traction motor. Rig released @ midnight 5-17-07 POST Continue to RD SLB traction motor. Rig camp left for Kuparuk ~ 1:00. POST PU handy berm. Load rest of rig mats & misc stuff. POST PJSM &THA for lifting SLB traction motor off of Nordic 2 rig. POST SLB traction motor has been removed from the rig. Simultaneously, begin swapping BOP ram components to Kuparuk configuration. Wait on security. POST BOPE have been swapped over to new configuration. POST RU 4-1/2" tree. Let Well Support go and hired Grease Crew to PT to the tree to 5000 psi. PT tree to 5000 psi. Rig Started move to Kuparuk at 09:00 hrs Printed: 5/21/2007 9:10:07 AM * s ~ • C~ bP BP Alaska $ Baker Hughes INTEQ Survey Report iNTE Q Company: BP Amoco Date: 5/14/2007 Time: 08:44:52 Page: 1 Field: Prudhoe Bay Co-ordinate(NE) Reference: Well: 04-01, True North Site: PB DS 04 Vertical (TVD) Reference: 1:01 11/27/1970 00:00 64.0 Well: 04-01 Section (VS) Reference: Well (O.OON,O.OOE,143.85Azi) Wellpath: 04-01A Survey Calculation Method: Minimum Curvature Db: Orade Annotation I/1D TVD ft ft 9200.00 8518.14 TIP 9278.00 8586.95 KOP 11374.00 8994.87 TD Survey: MWD Start Date: 5/14/2007 Company: Baker Hughes INTEQ Engineer: Tool: MWD;MWD -Standard Tied-to: From: Definifive Path Survey MD Iucl Azim TVD Sys TVD N/S E/W MapN MapE VS DLS Tool ft deg deg ft ft ft ft ft ft ft deg/100ft 9200.00 27.83 157.00 8518.14 8454.14 -2231.57 1668.88 5948353.85 714305.95 2786.41 0.00 MWD 9278.00 28.35 157.78 8586.95 8522.95 -2265.47 1683.00 5948320.36 714321.02 2822.12 0.82 MWD 9297.36 35.14 157.69 8603.40 8539.40 -2274.89 1686.86 5948311.05 714325.14 2832.00 35.07 MWD 9329.21 42.43 157.57 8628.21 8564.21 -2293.33 1694.45 5948292.84 714333.25 2851.36 22.89 MWD 9356.66 47.20 157.50 8647.68 8583.68 -2311.20 1701.84 5948275.18 714341.14 2870.16 17.38 MWD 9393.66 53.27 150.48 8671.35 8607.35 -2336.69 1714.36 5948250.06 714354.38 2898.12 21.93 MWD 9424.31 57.98 145.33 8688.66 8624.66 -2358.08 1727.82 5948229.05 714368.43 2923.34 20.69 MWD 9454.32 59.99 136.13 8704.15 8640.15 -2377.95 1744.09 5948209.66 714385.26 2948.97 27.10 MWD 9475.66 60.56 130.62 8714.74 8650.74 -2390.67 1757.55 5948197.33 714399.07 2967.19 22.58 MWD 9499.53 60.80 124.86 8726.43 8662.43 -2403.40 1774.00 5948185.07 714415.88 2987.17 21.06 MWD 9532.73 60.88 117.72 8742.62 8678.62 -2418.44 1798.75 5948170.73 714441.04 3013.92 18.78 MWD Field: Prudhoe Bay North Slope UNffED STATES Map System:US State Plane Coordinate System 1927 Map Zone: Alaska, Zone 4 Geo Datum: NAD27 (Clarke 1866) Coordinate System: Well Centre Sys Datum: Mean Sea Level Geomagnetic Model : bggm2006 Site: PB DS 04 TR-11-15 UNITED STATES :North Slope Site Position: Northing: 5953265.35 ft Latitude: 70 16 31.598 N From: Map Easting: 711234.97 ft Longitude: 148 17 27.907 W Position Uncertainty: 0.00 ft North Reference: True Ground Level: 0.00 ft Grid Convergence: 1.61 deg Well: 04-01 Slot Name: 01 04-01 Well Position: +N/-S -2764.73 ft Northing: 5950537.29 ft Latitude: 70 16 4.406 N +E/-W 1262.78 ft Easting : 712574.80 ft Longitude: 148 16 51.150 W Position Uncertainty: 0.00 ft Wellpath: 04-01A Drilled From: 04-01 50029200780100 Tie-on Depth: 9300.00 ft Current Datum: 1:01 11 /27/1970 00:00 Height 64.00 ft Above System Datum: Mean Sea Level Magnetic Data: 2/21 /2007 Declination: 24.23 deg Field Strength: 57674 nT Mag Dip Angle: 80.97 deg Vertical Section: Depth From (TVD) +N/-S +E/-W Direction ft ft ft deg 43.00 0.00 0.00 143.85 Survey Program for Definitive Wellpath Date: 5/14/2007 Validated: Yes Version: 3 Actual From To .Survey Toolcode Tool Name ft ft 100.00 9200.00 1 : Camera based gyro multisho CB-GYR0.MS Camera based gyro multishot 9278.00 11374.00 MWD (9278.00-11374.00) MWD MWD -Standard ~~~~ ~ ~S_ . ~ • • bP BP Alaska Baker Hughes INTEQ Survey Report iNTE Q Company: BP Amoco Date: 5/14/2007 Time: 08:44:52 Page: 2 Field: Prudhoe Bay Co-ordinate(NE) Reference: WeA: 04-01, True North Site: PB DS 04 Vertical (TVD) Reference: 1:01 11/27/19 70 00:00 64.0 Well: 04-01 Sectio n (VS) Reference: WeA (O.OON,O.OOE,143.85Azi) Wellpath: 04-01A Survey Calcula[ion Method: Minimum Curvature Db: Orade survey MD Incl Azim "I'VD Sys TVD N/S E/VV MapN MapE VS DLS Too( ft deg deg ft ft ft ft ft ft ft deg/100ft 9561.66 65.66 113.38 8755.64 8691.64 -2429.56 1822.06 5948160.27 714464.65 3036.64 21.27 MWD 9591.74 70.98 109.10 8766.75 8702.75 -2439.66 1848.10 5948150.91 714490.97 3060.16 22.08 MWD 9621.67 76.90 105.23 8775.03 8711.03 -2448.13 1875.57 5948143.22 714518.66 3083.20 23.35 MWD 9653.60 82.48 100.66 8780.75 8716.75 -2455.15 1906.17 5948137.07 714549.44 3106.92 22.44 MWD 9688.17 86.03 95.17 8784.21 8720.21 -2459.88 1940.22 5948133.30 714583.61 3130.83 18.84 MWD 9721.86 89.02 85.86 8785.67 8721.67 -2460.18 1973.83 5948133.95 714617.22 3150.90 29.00 MIND 9766.72 87.05 78.07 8787,21 8723.21 -2453.92 2018.19 5948141.46 714661.38 3172.01 17.90 MWD 9799.03 87.08 70.21 8788.86 8724.86 -2445.11 2049.20 5948151.15 714692.14 3183.19 24.30 MWD 9835.60 86.46 62.78 8790.93 8726.93 -2430.56 2082.66 5948166.63 714725.17 3191.18 20.36 MWD 9866.24 87.85 55.37 8792.45 8728.45 -2414.84 2108.90 5948183.09 714750.95 3193.96 24.58 MWD 9895.31 89.42 48.53 8793.14 8729.14 -2396.94 2131.77 5948201.62 714773.30 3193.00 24.13 MWD 9923.84 88.47 42.53 8793.67 8729.67 -2376.96 2152.11 5948222.16 714793.07 3188.87 21.29 MWD 9979.39 86.19 28.35 8796.27 8732.27 -2331.88 2184.21 5948268.14 714823.88 3171.40 25.83 MWD 10011.53 88.90 21.70 8797.65 8733.65 -2302.80 2197.78 5948297.58 714836.63 3155.92 22.32 MWD 10041.36 90.74 14.48 8797.74 8733.74 -2274.46 2207.04 5948326.17 714845.08 3138.50 24.98 MWD 10072.76 88.47 6.75 8797.96 8733.96 -2243.63 2212.82 5948357.15 714849.99 3117.01 25.66 MWD 10103.18 88.09 359.00 8798.87 8734.87 -2213.28 2214.34 5948387.53 714850.65 3093.41 25.50 MWD 10134.85 88.34 351.61 8799.86 8735.86 -2181.76 2211.75 5948418.97 714847.17 3066.43 23.34 MWD 10167.20 88.93 343.35 8800.63 8736.63 -2150.21 2204.75 5948450.30 714839.28 3036.82 25.59 MWD 10194.89 90.40 336.30 8800.79 8736.79 -2124.24 2195.20 5948475.99 714829.01 3010.22 26.01 MWD 10219.49 89.11 330.18 8800.90 8736.90 -2102.29 2184.13 5948497.62 714817.32 2985.96 25.42 MWD 10248.29 87.54 322.64 8801.74 8737.74 -2078.32 2168.22 5948521.13 714800.74 2957.22 26.73 MWD 10280.00 90.03 318.18 8802.42 8738.42 -2053.90 2148.02 5948544.97 714779.86 2925.59 16.10 MWD 10308.69 88.43 315.80 8802.80 8738.80 -2032.92 2128.45 5948565.38 714759.71 2897.11 10.00 MWD 10338.32 88.03 312.59 8803.72 8739.72 -2012.28 2107.22 5948585.42 714737.91 2867.92 10.91 MWD 10369.67 89.14 307.64 8804.49 8740.49 -1992.10 2083.26 5948604.92 714713.39 2837.48 16.18 MWD 10400.95 88.55 305.92 8805.12 8741.12 -1973.37 2058.22 5948622.92 714687.82 2807.59 5.81 MWD 10429.91 85.97 302.51 8806.51 8742.51 -1957.11 2034.30 5948638.50 714663.46 2780.35 14.75 MWD 10458.20 83.28 301.51 8809.16 8745.16 -1942.18 2010.42 5948652.75 714639.17 2754.21 10.14 MWD 10487.20 80.89 298.06 8813.15 8749.15 -1927.91 1985.50 5948666.31 714613.85 2727.99 14.38 MWD 10518.56 78.58 295.81 8818.74 8754.74 -1913.93 1957.99 5948679.50 714585.97 2700.47 10.20 MWD 10550.50 74.07 294.42 8826.29 8762.29 -1900.76 1929.90 5948691.88 714557.52 2673.27 14.74 MWD 10581.81 73.30 289.91 8835.09 8771.09 -1889.43 1902.08 5948702.42 714529.39 2647.70 14.04 MWD 10609.41 72.00 286.24 8843.32 8779.32 -1881.25 1877.05 5948709.89 714504.13 2626.33 13.54 MWD 10640.10 72.30 282.35 8852.73 8788.73 -1874.04 1848.74 5948716.29 714475.64 2603.82 12.10 MWD 10672.21 71.52 278.48 8862.71 8798.71 -1868.52 1818.73 5948720.96 714445.48 2581.65 11.71 MWD 10700.00 71.22 274.22 8871.59 8807.59 -1865.61 1792.57 5948723.13 714419.25 2563.87 14.57 MWD 10743.02 70.28 266.41 8885.79 8821.79 -1865.38 1751.99 5948722.22 714378.68 2539.75 17.28 MWD 10773.51 70.70 260.32. 8895.98 8831.98 -1868.70 1723.46 5948718.10 714350.26 2525.60 18.88 MWD 10804.62 72.12 257.76 8905.90 8841.90 -1874.31 1694.52 5948711.67 714321.49 2513.05 9.04 MWD 10834.92 75.51 259.36 8914.35 8850.35 -1880.08 1666.00 5948705.10 714293.15 2500.89 12.28 MWD 10863.30 78.89 260.81 8920.63 8856.63 -1884.84 1638.74 5948699.57 714266.04 2488.65 12.91 MWD 10892.32 82.23 263.32 8925.39 8861.39 -1888.79 1610.40 5948694.83 714237.81 2475.12 14.33 MWD 10920.20 82.36 267.30 8929.13 8865.13 -1891.04 1582.87 5948691.79 714210.36 2460.70 14.15 MWD 10949.94 83.41 272.50 8932.82 8868.82 -1891.09 1553.37 5948690.91 714180.87 2443.34 17.71 MWD 10980.16 83.88 277.98 8936.16 8872.16 -1888.35 1523.47 5948692.81 714150.91 2423.49 18.09 MWD 11012.83 83.07 283.78 8939.88 8875.88 -1882.23 1491.61 5948698.03 714118.89 2399.75 17.81 MWD 11049.78 81.27 288.62 8944.92 8880.92 -1872.02 1456.47 5948707.23 714083.48 2370.78 13.86 MWD 11082.55 80.37 293.21 8950.15 8886.15 -1860.48 1426.26 5948717.92 714052.96 2343.64 14.10 MWD 11114.51 81.36 298.25 8955.22 8891.22 -1846.78 1397.84 5948730.81 714024.17 2315.82 15.87 MWD 11144.88 81.31 302.18 8959.80 8895.80 -1831.68 1371.90 5948745.17 713997.81 2288.32 12.79 MWD 11178.57 81.83 306.46 8964.74 8900.74 -1812.89 1344.39 5948763.17 713969.78 2256.92 12.66 MWD 11210.23 81.62 311.01 8969.30 8905.30 -1793.29 1319.95 5948782.07 713944.80 2226.68 14.24 MWD f. bP BP Alaska s Baker Hughes INTEQ Survey Report uvTE Q Company: BP Amoco Date: 5!14/2007 Time: 08:44:52 Page: 3 Field: Prudhoe Bay Co-ordinate(NE) Reference: Well: 04-01, True North Site: PB DS 04 Vertical (TVD) Reference: 1:01 11/27/1970 00:00 64.0 Well: 04-01 Section (VS) Reference: WeA (O.OON,O.OOE,143.85Azi) Wellpatb: 04-01A Survey Calculation Method: Minimum Curvature Db: Orade >urvey hiD Inc! Aam TVD Sys TVD N/S E/V1' MapN MapE VS DLS Tool ft deg deg ft ft ft ft ft ft ft deg/100ft 11239.58 80.50 314.04 8973.86 8909.86 -1773.70 1298.59 5948801.05 713922.89 2198.26 10.89 MWD 11269.85 80.47 317.29 8978.87 8914.87 -1752.35 1277.73 5948821.81 713901.44 2168.71 10.59 MWD 11300.14 81.12 322.08 8983.72 8919.72 -1729.56 1258.39 5948844.04 713881.47 2138.90 15.76 MWD 11330.43 81.59 326.21 8988.27 8924.27 -1705.29 1240.85 5948867.80 713863.25 2108.96 13.57 MWD 11374.00 81.00 332.09 8994.87 8930.87 -1668.34 1218.78 5948904.12 713840.14 2066,10 13.41 MWD EE _ ~ MCEV OY ~ V 6F ~ V ' ~ I S~O TES: LLHEA D = MCEV OY t ~ TuATOR= AXELSON R WO + CTD Sidetr ack - ELEV = - 64' _ _ ~\~~~ ~~A~T ELEV = ? 2159, 4-1/2" HES "X" Nipple 'P = 3200' • 3.813 ID x Angle = 91 ~ 10040' :um MD = 9592' GAS LIFT MANDRELS :um TVD= 8800' SS ST MD TVD DEV TYPE VLV LATCH FORT DA 518" CSG 9 47# L 80 ID = 8 681" 2454' S 3231 3227 10 MMG DMY RK 0 04/3( - , , - , . 4 5651 5414 30 MMG OMY RK 0 04/30 3 7396 6917 29 MMG DMY RK 0 04J3C 2 8140 7571 28 MMG DMY RK 0 0413( 1 8838 8195 26 MMG DMY RK 0 04/3( 13-3/8" CSG, 72#, N-80, ID = 12.347" 2686' 4-1i2" X Nip ID= 3 813" 8910' . . , " " ' PKR 9-5/8 X 4.5 8930 " 4-1/2" X Nip, ID= 3.813" 8g$4' 8983' Top of 3112 Liner 9008' 3-1/2" X NIP, ID = 2.813" 4-112' 12.6#lit 11Cr80 Vam Top ID 3.958" ' " 9028' 9022 Top of 5-112 Tubing Stub 9029' Base of Custom Overshot 9041' 3-1/2"-3-3116" X-over 9063' 9-518" X S-1/2" BAKER FB-1 PKR 9171' 5-112" OTIS XN NO-GO NIP, ID = 4.45" 5-112" TBG, 17#, L-80, .0232 bpf , ID = 4.892" 91$4' 9183' 5-112" BAKER SHEA ROItf SUB 9184' S-1 /2" TUBING TAIL PERFORATION SUMMARY 9163' ELMD TT LOGGED 08/13/90 REF LOG: BHCS ON 12/2780 ANGLEATTOP PERF: 28 ~ 9371' 9200' Top of cement Note: Refer to Production DB for historical perf data SQE SPF INTERVAL Opn/Sqz DATE 3-318" 6 9371 - 9379 isolated proposed 9287' Cement Ramp Window 3-318" 4 9404 - 9402 isolated proposed 10059' 33/16 x 2-7/8 X-over 3-318" 2 9417 - 9446 isolated proposed 3-318" 6 9425 - 9445 isolated proposed 3-3/8" 4 9429 - 9457 isolated proposed 3-318" 0.5 9479 - 9499 isolated proposed 3-318" 6 9507 -9514 isolated proposed j 3-3/16" X 2-7/8" liner 11369' 3-318" 2 9507 - 9519 isolated proposed 9350' Adjusted sand toP 3-318" 0 125 9512 -9536 isolated ro osed " . p p 3-318 0.5 9556 -9577 isolated proposed ' 3-3/8" 6 9570 -9578 isolated proposed 9394 TOP OF CEINENT CAP 12/03/04 2-7/8" 4 9627 -9647 isolated proposed 2-718" 4 9642 -9662 isolated proposed 2-7/S" 4 9666 -9678 isolated proposed 9429' , TOP OF 20, 40 SAND CAP 12/03!04 3-318" 1 9681 -9695 isolated proposed 2-7/8" 4 9682 - 9721 isolated proposed 2" 6 9970 - 10020 Open 05!17/07 " 2 6 10500 - 10650 Open 05/17!07 2" 6 10770-10800 Open OS/t 7/07 2" 6 10895-11300 Open 05!17!07 9574' BOTTOM OF SAND CAP PBTD ' 9648 i/8" LNR, 47#, SOO-95, .0732 bpf, ID = 8.681" 9747' DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNfr 11110!71 ORIGINAL COMPLETION 12!03104 KEY/TLP SAND CAP /CEMENT CAP WELL: 0401 A 17/07/90 LAST WORKOVER 12/08!05 DAVlTLP MIN. ID 8 OPEN PERF CORRECT. PERMfT No: 1700420 )5!31!01 RHttlh CORRECTIONS 12/28/04 RACCRP GLV CIO API No: 50-029-20078-00 1 /23/02 ?/TP MINMUM ID CORRECTION 03/24/05 KEY/TLH SAND CAP SEC 34, T11 N, R15E, 3815.26' FEL 83818.38' F 18/16/04 MLH/TLP ADD PERFS FROM 12/06/93 OSi17!07 D Wkiret Work Over 8 Sidetrack ~ mQ/n~ a \n/rn o \A/A ~/CD en ecru since oo ~....~.....~:.... rw~....~...~ ~~ r 11/09/04 STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BO PE Test Report Submit to: ,€iE`3..rE'~~~ ~~r~~~3_s~~kf_,~ x;~s , ,S y ci;i~.~~.~v ~'+~-~.~E37'~E~~? i~c~.jiit~~~i~t3?~Tif~ ~~f i~:F~. ie ~.feS b~~i"~ ~€~~:I~E`t~Si£?i£14r.T?.3~lT:i~3 sta'k~,.ak.us Contractor: Nordic Rig No.: 2 DATE: 5/10/07 Rig Rep.: Holmes Rig Phone: 659-4398 Rig Fax: 659-4356 Operator: BPX Op. Phone: 659-4393 Op. Fax: 659-4356 Rep.: Ross / Sevcik E-Mail ~l~~cj~~~~rlcrt~:~ic~~~c?~:if~us~f~t~~7~?:c_~~I Well Name: PBU 04-01A PTD # 207-035 Operation: Drlg: XXX Workover: Explor.: Test: Initial: Weekly: Bi-Weekly XXX Test Pressure: Rams: 250-3500 Annular: 250-3500 Valves: 250-3500 MISC. INSPECTIONS: TEST DATA FLOOR SAFETY VALVES: Test Result Test Result Quantity Test Result Location Gen.: P Well Sign P Upper Kelly NA Housekeeping: P Drl. Rig P Lower Kelly NA PTD On Location P Hazard Sec. P Ball Type 2 P Standing Order Posted P Inside BOP NA BOP STACK: Quantity Size/Type Test Result MUD SYSTEM: Visual Alarm Stripper 1 2 3/8" P Trip Tank P P Annular Preventer 1 7 1/16" P Pit Level Indicators P P #1 Rams 1 Blind /Shear P Flow Indicator P P #2 Rams 1 2 3/8"combi's P Meth Gas Detector P P #3 Rams 1 2 3/8 x 3 1/2 P H2S Gas Detector P P #4 Rams 1 2 3/8"combi's P #5 Rams N/A NA Quantity Test Result Choke Ln. Valves 1 3 1/8" P Inside Reel valves 1 P HCR Valves 2 3 1/8" P Kill Line Valves 1 3 1/8" P ACCUMULATOR SYSTEM: Check Valve 2 2 1/16" NT Time/Pressure Test Result System Pressure 2950 P CHOKE MANIFOLD: Pressure After Closure 1950 P Quantity Test Result 200 psi Attained 23sec P No. Valves 14 P Full Pressure Attained 1 min/45sec P Manual Chokes 1 P Blind Switch Covers: All stations Y Hydraulic Chokes 1 P Nitgn. Bottles (avg): 4 @ 2000 Test Results Number of Failures: 0 Test Time: 5 Hours Components tested 29 Repair or replacement of equipment will be made within 0 days. Notify the N orth Slope Inspector 659-3607, follow with written confirmation to Superviser at: ,fir~3,..~f~g~ ~~~r~i~3_sf~tf,~?t: Remarks: The inside reel valve was tested after the coil connector was installed & stripper were tested after the injector was picked up. The two 2 1/16" valves are only used during & on pressure de to ment wells. Distribution: 24 HOUR NOTICE GIVEN orig-Well File YES. XXX NO c - Oper./Rig Waived By c -Database Date 5/9/07 Time ?????? c -Trip Rpt File Witness Bob Noble c -Inspector Test start 11:00 Finish 16:00 Coil Tubing BFL 11/09/04 Nordic 2 BOP 5-10-07p.xls r ~ Subject: RE: Request for 3000 PSI Maximum Pressure Test on DS4-01A Rig Work Over From: "Sarber, Greg J" <SarberJG@BP.com> Date: Tue, 17 Apr 20tT7 15:23`:17 -0800 ~ `--\-iJ ~ ~"~~-~,~~ To: "Rixset Mel G" ~=Me1Rixse~ f3P.com> CC': Thomas Iv1au11der atom_maunder~~c~;adniin.state.ak.u> U t---~ - t~ '~ ~ ~d~- ~~~ Mel, You might need to add a little clarity so that the folks at the AOGCC can understand what you are requesting. DETAILS The rig is moving on to DS 4-01; which is a very unusual well It has a very high wellhead. !n order to rig up on this well we have built a 4' elevated ice pad on top of DS4, and we have nippled the tree down to the master valve. In order for the rig to move over the well, they will have the 13-5f8" BOP stack hanging in the cellar. Once aver the well, we can not rig up to pull the BPV prior to NU the ROPE, The first operation by the rig will be to Hippie down the master valve, and nipple up the BOPE. Prior to pulling the BPV, we need to body test the BOPS. This will result in the entire wellbore down to the cement P&A plug being pressured up to BOP test pressure. After we have performed the body test, we will pull the BPV, and set a TWC. The full ROPE test will then be performed to the pressures as required by the sundry, REQUEST Vl~hat you are requesting is that the AOGCC allow you to perform an initial body test to 3000 psi instead of 3500 psi. This pressure is above the maximum expected wellhead. pressure with a full column of gas.- This pressure is the maximum that our standard operating proceedures allow on the 9-5I8" casing. if you present the information to the AOGCC like this, they should have no problem with allowing you to proceed with the operation. Cheers, Greg From: Rixse, Mel G Sent: Tuesday, April 17, 2007 2:13 PM To: Thomas Maunder Cc: NSU, ADW Drlg Nordic 2 Supervisor Subject: Request for 3000 PSI Maximum Pressure Test on DS4-OlA Rig Work Over Date: 17-April-2007 To: Tom Maunder, AOGCC Drilling Engineer I would like to request that Nordic 2, while it is doing the rig workover on DSO4-01, internal pressure test the 9-5/8" casing to no more than 3000 psi. The pre-rig well work tested this casing to 3000 psi. I would like to not expose this casing to 500 psi additional pressure. I believe that based upon a reservoir pressure of 3400 psi, in the worst case scenario with the casing filled only with gas, the expected maximum pressure at surface will be 2520 psi. 1 of 2 4!19;2007 12:04 PM BP is planning to change thZS9-5/8" casing pack-offs. The 9-5/8" annultis will be exposed while we change those seals. Please let me know if you approve this change. Sincerely, Mel Rixse Coiled Tubing Drilling Engineer BP Explorafian Alaska; lnc. (9~7}564-562Q - Office (9D7}223-3605 - Cef1 2 of 2 4/l 9/2007 J 2:04 PM Subject: RE: Request for 3000 PSI Maximum Pressure Test on DS4-OlA Rig Work Over From: "Rixse, Mel G" <Me1.Rixse cr bp.com> Date: Tue, 17 Apr 2007 16:58;02 -0800. ~~~~~ '°- Q ~ ~'"`t, (~ ~-~~~, To: Thon3as Ma~nder,< tom_maund~r~,admn.stafie.ak.us> Tom. Thank you for getting back to me. V11e are doing the workover on 04-01 in preparation for the sidetrack. !should have referred to this workover as 04-01 not 04-01A which will be drilled once the workover is done. I will note this 3000 psi pressure test in the handover notes to production operations. Mel From: Thomas Maunder [mailto:tom_maunder@admin.state.ak.us] Sent: Tuesday, April 17, 2007 2:22 PM To: Rixse, Mel G Cc: NSU, ADW Drlg Nordic 2 Supervisor Subject: Re: Request for 3000 PSI Maximum Pressure Test on DS4-OlA Rig Work Over Mel, et al: Testing to 3000 psi looks appropriate for the well conditions you give. It is probably appropriate to be sure that the handover notes to production conspicuously note that the 9-5/8" casing has not been tested beyond 3000 psi. With regards to changing the packoff, I believe the BOP will still be in place which will give you a mechanical well control device if needed. One other question, has the redrill been accomplished yet? If no new hole has been drilled, by convention the work is still within DS 04-01. Call or message with any questions. Tom Maunder, PE AOGCC Rixse, Mel G wrote, On 4/17/2007 2:12 PM: Date: 17-Apri 1-2007 To: Tom Maunder, AOGCC Drilling Engineer I would like to request that Nordic 2, while it is doing the rig workover on DSO4-01, internal pressure test the 9-5/8" casing to no more than 3000 psi. The pre-rig well work tested this casing to 3000 psi. I would like to not expose this casing to 500 psi additional pressure. I believe that based upon a reservoir pressure of 3400 psi, in the worst case scenario with the casing filled only with gas, the expected maximum pressure at surface will be 2520 psi. BP is planning to change the 9-5/8" casing pack-offs. The 9-5/8" annulus will be exposed while we change those seals. Please let me know if you approve this change. Sincerely, ~l!leI t~ixse Cc~ile~ i u~i~~g t~rillir~g ~ngir~eer ~~' Ex/~lor~tion ~/~sk~. It~c. 1 of 2 4/l 9/2007 ]2:03 PM SAR,4H PALIiY, GOllERPIOR 333 W. 7th AVENUE, SUITE 100 ANCHORAGE, ALASItA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Mel Rixse CT Drilling Engineer BP Exploration (Alaska) Inc. PO Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU 04-OlA BP Exploration (Alaska) Inc. Permit No: 207-035 Surface Location: 1327' FNL, 295' FEL, SEC. 34, T11N, R15E, UM Bottomhole Location: 3028' FNL, 839' FWL, SEC. 35, T11N, R15E, UM Dear Mr. Rixse: Enclosed is the approved application for permit to redrill the above referenced development well. This permit to drill does not exempt you from obtaining additional permits or an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 6~~J607 (pager). DATED this ,~ day of March, 2007 cc: Department of Fish 8s Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. STATE OF ALASKA ~~ ALAS~IL AND GAS CONSERVATION COMMI~N 3~ t~ MAR 1 3 2007 PERMIT TO DRILL Alaska Oil & Gas Cons, Commission 20 AAC 25.005 Qrtrhnrann 1 a. Type of work ^ Drill ®Redrill ^ Re-Entry 1 b. Current Well Class ^ Exp-oratory ^ Development Gas ^ Service ^ Multiple Zone ^ Stratigraphic Test ®Development Oil ^ Single Zone 1 c. Specify if well is proposed for: ^Coalbed Methane ^ Gas Hydrates ^ Shale Gas 2. Operator Name: BP Exploration (Alaska) Inc. 5. Bond: ®Blanket ^ Single Well Bond No. 6194193 ~ 11. Well Name and Number: PBU 04-01A 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 6. Proposed Depth: MD 11075 - TVD 8918ss 12. Field /Pool(s): , Prudhoe Bay Field / Prudhoe Bay 4a. Location of Well (Governmental Section): Surface: 1327' FNL 295' FEL SEC 34 T11 N R15E UM 7. Property Designation: ADL 028324 Pool , , , . , , Top of Productive Horizon: 3601' FNL, 1388' FWL, SEC. 35, T11 N, R15E, UM ' 8. Land Use Permit: 13. Approximate Spud Date: March 20, 2007 ' Total Depth: 3028' FNL, 839' FWL, SEC. 35, T11 N, R15E, UM ~ 9. Acres in Property: 2560 14. Distance to Nearest Property: 20,420' 4b. Location of Well (State Base Plane Coordinates): Surface: x-712575 y-5950537 Zone-ASP4 10. KB Elevation (Height above GL): 64 feet 15. Distance to Nearest Well Within Pool: 747' 16. Deviated Wells: Kickoff Depth: 9300 feet Maximum Hole An le: 90 de rees 17. Maximum Anticipated Pressures in psig (see 20 AAC 25.035) Downhole: 3250 Surface: 2370 1 asin Pr ram: 5 ecfi lio ns ` To - ttin D th -Bo ttom uan i of Cement c.f. or sa Hole Casin Wei ht Grade Cou lin Len th MD TVD MD TVD includin sta a data 4-1 /4" 3-3/16" x 2 6.2# / 6.1 L-80 TC-II / STL 1915' 9160' 8419' 11075' 8918' 106 sx Class 'G' 19. PRESE NT WELL CONDITION SUMMARY (To be completed for Redrill and Re-entry Operations) Total Depth MD (ft): 9790 Total Depth TVD (ft): 9039 Plugs (measured): 9246 Effective Depth MD (ft): 9394 Effective Depth TVD (ft): 8689 Junk (measured): None asing Length ize Cement Volume MD Conductor /Structural 1185' 20" 750 sx Fondu FI ash 28 sx Class 'G' 11 5' 1185' Surface 2686' 13-3/8" 975 sx Fondu FI ash 485 sx'G' 330 sx Fondu 2686' 2686' Intermediate Pr coon 9749' 9- /8" 43 sx' 80 sx'G' 10 x F ndu 450 sx'G' 974 ' 9002' Liner Perforation Depth MD (ft): All Perfs Below Sand Plug: 9371' - 9578' perforation Depth TVD (ft): 8669' - 8851' 20. Attachments ®Filing Fee, $100 ®BOP Sketch ®Drilling Program ^ Time vs Depth Plot ^ Shallow Hazard Analysis ^ Property Plat ^ Diverter Sketch ^ Seabed Report ®Drilling Fluid Program ®20 AAC 25.050 Requirements 21. Verbal Approval: Commission Representative: Date: 22. I hereby certify that the foregoing is true and correct. Contact Mel Rixse, 564-5620 Printed Name Mel Rixs Title CT Drilling Engineer ,,sy~~ r~ Prepared By Name/Number: Si nature Phone 564-5620 Date `z%'~~" ~/ Terrie Hubble, 564-4628 Commission Use Onl Permit To Drill Numb r: ~~i~D3s API Number: 50-029-20078-01-00 Permit A royal Date: See cover letter for other re uirements Conditions of Approval: If box is checked, well may not be used to explore for, test, or produce Coalbed methane, gas hydrates, or gas contained shales: Samples Req'd: Q,Yes ~No ud Log Req'd: ^ Yes dNo HZS Measures: d Yes ^ No ' ection Survey Req'd: ~ Yes ^ No Other: ~~~ ~°~ \~j~3 ~ ~~~ D ~ PROVED BY THE COMMISSION Date ~ ~ ,COMMISSIONER Form 10-401 Revised 12/2005 `-~~ ~----~- Submit In Duplicate ORIGINAL • • BP Prudhoe Bay DSO4-OlA RWO and CTD Sidetrack Pre-Rig Work Summary: 1. O Check the tubing hanger and IC casing hanger lock down screws for free movement. Completely back out and check each lock down screw for breakage (check one at a time). PPPOT-T & IC. 2. S Drift 7" x S-1/2" tubing for composite plug/jet cutter and 3-3/4" bit to base of tubing tail. 3. S Pu113 3/8" retrievable IBP in 5 1/2" tubing. 4. C Run memory gamma ray/CCL 5. C Reverse circulate sand plug 9246' to 9350' MD. 6. C Set 17#/gal cement sidetrack plug from 9350'MD to base of 5-1/2" tubing tail at 9184'MD. 7. O Perform MIT-IA to 3000 psi 8. E Run SCMT (CBL) to assure existing 7" x 5-1/2" tubing has no external backfill. 9. E Chemical cut 5-1/2" tubing @ ~9028'md 10. F Circulate well with seawater and freeze-protect with diesel through the cut 11. O Bleed WHPs to 0 psi. 12. O Bleed production flow lines and GL lines down to zero and blind flange 13. O Set a BPV in the tubing hanger 14. O Build 4' ice pad 15. O Remove wellhouse Nordic 2 RWO -Tubing Swap. Rig Work: 1. MIRU with 13-5/8" BOPE behind well head on BOP tolley. 2. Set TWC and test to 1000 psi. 3. ND tree and tubing adapter flange. NU 13-5/8" BOPE with 4-1/2" x 7" VBR pipe rams. Pressure test to 3500 psi. Annular preventer tested to 3500 psi. Circulate out freeze protection fluid and circulate well to clean kill weight brine through the cut. 4. Pull TWC. 5. Pull and LD 7' x 5-1/2" to chemical cut. 6. Set test plug 7. Change Rams to 2-7-8" x 5-1 /2". Pressure test body and Rams 8. Pull test plug 9. RIH w/ RTTS above 20K# 3-1/2" DP 10. Change out 9-5/8" packoff and test to 5000 psi 11. Retrieve RTTS and DP 12. RU Slickline, RIH with LIB 13. Run Junk basket/gauge ring for new 9-5/8" packer down to top of tubing stub. 14. RU Eline. Run USIT log on 9-5/8" interval (9059' -surface). Check for casing damage and cement quality. 15. Run 4-1/2", 12.6# 13CR-80 Vam Top completion 13Cr-80 stacker packer completion with Baker S-3 packer. Position packer at 8989' MD. Install new packoff. Space out TTail with custom overshot on tubing stub. Screw in lock down screws. Circulate inhibited 8.7 ppg NaCI brine into the T x IA annulus above the packer. 16. Drop ball and rod, set PKR, test tubing and annulus to 3500 psi. 17. Circulate in diesel freeze protection on T and IA to 2200'. • 18. Set TWC and test to 1000 psi. 19. ND BOPE. NU and test tree to 5,000 psi. 20. NU 7-1/16" CTD stack and test. Coiled Tubing Drilling work: • Pull TWC. ~~~ ~~ c~~~ C~ ~~~~ ~o 1. 2. 3. 4. 5. ~~~~ ~: 8. ~' ~\ Mill cement ramp for 9-5/8" casing exit Mill window 3.8" window in 9-5/8" casing, TOW, 9300' MD Drill build section, 713' MD with ~ 4-1/4" bicenter bit Drill lateral, ~ 1062' MD with ~ 4-1/4" bicenter bit Run and cement 3-3/16" x 2-7/8" solid liner, TOL ~9160'MD in CR tubing tail. CNL log Perforate oil producing zones RDMO Mud Program: • Well kill: 8.6 ppg brine • Milling/drilling: 8.6 ppg Flo Pro or biozan for milling, new Flo Pro for drilling. Disposal: • All drilling and completion fluids and all other Class II wastes will go to Grind & Inject. • All Class I wastes will go to Pad 3 for disposal. Hole size: 4-1/4" Casing Program: fully cemented liner • 3-3/16" L-80 6.2# L-80 TC-II X 2-7/8", L-80 6.16# STL 9150' MD - 11,075' MD • A minimum of 22 bbls 15.8 ppg cement will be used for liner cementing. • TOC planned at 9150' MD ~. `~~,~~ ~~ Well Control: • BOP diagrams are attached. • Pipe rams, blind rams and the CT pack off will be pressure tested to 250 psi and to 3500 psi. • The annular preventer will be tested to 250 psi and 2500 psi. Directional • See attached directional plan. Max. planned hole angle is 90 deg. • Magnetic and inclination surveys will be taken every 30 ft. No gyro will be run. • Distance to nearest property - 20,420 ft. • Distance to nearest well within pool - 747 ft. (04-46) Logging • MWD directional, Gamma Ray, and resistivity will be run over all of the open hole section. • A cased hole CNL/GR/CCL log will be run. Hazards • • • The maximum recorded H2S level on 04-OlA is 67 ppm • Lost circulation risk is moderate Reservoir Pressure • The max res. press. is estimated to be 3250 psi at 8800'ss (7.1 ppg EMW). • Max. surface pressure with gas (0.10 psi/ft) to surface is 2370 psi. = MCEVOY LHEAD = M",El/OY CTIIATOR = AXELSON . ELEV = 64' F. ELEV = OP = 3200' Angle = 33 ~ 6700' tan FAD = 95.92' tum TVD = 8800' SS ~ 9-5/8" CSG, 47#, L-80, ID = 8.681" ~ 13-3/8" CSG, 72#, N-80, ID = 12.347" H 2686' TBG, Z6#, L-80, .0383 bpf , ID = 6.278" 3009' Minimum ID = 4.45" ~ 9171' 5-1/2" OTIS XN NIPPLE 5-1 /2" TBG, 17#, L-80, .0232 bpf , O = 4.892" ~--~ 9184' PERFORAT'~N SUMMARY REF LOG: BHCS ON 12/27!70 ANGLE AT TOP PERF: 28 ~ 9371' Note: Refer to Production DB for h~torical perf data SIZE SPF INTERVAL Opn/Sgz DATE 3-3/8" 6 9371 -9379 C 09/09/97 3-3/8" 4 9404 -9402 S 11 /15J93 3-3l8" 2 9417 - 9446 S 11 /15/93 3-318" 6 9425 -9445 C 12/06/93 3-3/8" 4 9429 -9457 S 11 /15/93 3-3/8" 0.5 9479 -9499 S 02/24/90 3-318" 6 9507 -9514 C 12/06/93 3-3/8" 2 9507 -9519 S 02/24/90 3-318" 0.125 9512 -9536 S 0224/90 3-3/8" 0.5 9556 -9577 S 0224190 3-3/8" 6 9570 - 9578 C 12/06/93 2-7/8" 4 9627 - 9647 S 0224!90 2-7/8" 4 9642 -966'1 S 0224/90 2-7/8" 4 9666 -9678 S 0224/90 3-318" 1 9681 -9695 S 11 /15/93 2-7/8" 4 9682 - 9721 S 0224/90 3-3/8" 4 9695 - 9709 S 11/15/93 3-318" 4 9708 - 9728 S 11/15193 9-5/8" LNR, 47#, SOO-95, .0732 bpf, ID = 8.681" H 9747' DIATE REV BY CONVENTS DATE REV BY COMMENTS 01110171 ORIGINAL COMPLETION 12/03!04 KEYRLP SAND CAP/ CEM]Yf CAP 07/07/90 LAST VYOR[{O1/92 12!08/05 DAV/TLP MN ID & OPEN PERF CORRECT. 05/'31101 RHftlh CORRECTIONS 1228/04 RAC/TLP GLV C!O 11/23/02 ?!fP MNMAUM ID CORRECTION 03/24/05 KEY/TLH SAND CAP 08/16104 M_HITLP ADD PERFS FROM 12/06/93 11/08104 JLWITLP WAVER SAFETY NOTE 9394' ~~ TOP OF CEMENT CAP 1 9429' ~'1 TOP OF 20/40 SAND CAP 12/03/04 9674' ~-~ BOTTOM OF SAND CAP PRIIDI-IOE BAY UNff WELL: 04-01 P92MT No: 1700420 AR No: 50-029-20078-00 5EC 34, T11 N, R15~ 3815.26' FEL &3818.38' FNL BP 6~ploration (Alaska) 04-01 2182' T' CAMCO BAL-O SSSV NIP, ID = 5.94" GAS LIFT MANDRELS ST ND TVD DEV TYPE VLV LATCH PDRT DATE 3110 3108 9 OTiS LB DOME RM 16 12/28/04 2 5312 5121 30 OT1S LB DONE RM 16 12/28!04 3 6641 6268 33 OTIS LB DMY RO-5 0 4 7249 6788 29 OT1S LB DMY RO-5 0 5 7585 7084 28 OTIS LB DMY RO-5 0 6 7923 7381 29 OT1S LB SO NONE 28 7 8'159 7677 28 OT1S LB DMY RO-5 0 8 8602 7983 27 OT1S LB DMY RO-5 0 9 8.941 8288 Z6 OT1S LB DMY RO-5 0 3009' 7" X 5-112" XO 8069' S-1 /2" BA KER SEA L A SSY 9pg3' 9-5/8" X5-1/2" BAKER FB-1 PKR I 9171' 5-1 /2" OTIS XN NO-GO NIP, ID = 4.45" 9183' 5-12"BAKERSHEAROUTSUB 9184' 5-12" TUBING TAIL 9183' ELMD TT LOGGED 08113/90 9246' ~~ TOP OF SAND CAP 03/24/05 TREE = MCEVOY LHEAD = MCEVOY CTLUITOR = AXELSON . ELEV = sa' F. ELEV = OP= 3200' x Angle = 33 ~ 6700' tum MD = 9597 tum TVD = 8800' SS 47#, L-80, ID = 8.681" ~-~ 2464' 13-318" CSG, 72#, N-80, ID = 12.34T' H 2686' ','?° x. Nor ',D= 3.813" 8969' ~-5,'8" x a s" PKR 8989' 4-1 /2" X Nip, ID= 3 E`3' 9009' REF LOG: BRCS ON 1227/70 A NGLE AT TOP PERF: 28 Q 9371' Note: Refer to Plnduction DB for historical perf data SIZE SPF INTERVAL OpNSgz DATE 3-3/8" 6 9371 -9379 • o c~ s r-' 3-3/8" 4 9404 -9402 r_.. ropcsea 3-3/8" 2 9417 -9446 so ated proposed 3-3/8" 6 9425 -9445 soiated proposed 3-318" 4 9429 - 9457 solated proposed 3-3/8" 0.5 9479 -9499 solated proposed 3-318" 6 9507 -9514 solated proposed 3-3/8" 2 9507 -9519 solated proposed 3-318" 0.125 9512-9536 s:;atec proposed 3-3/8" 0.5 9556-9577 ~catec proposed 3-3/8" 6 9570-9578 saated proposed 2-7/8" 4 9627 -9647 so ateo proposed 2-7/8" 4 9642 -9662 sa~ated proposed 2-7/8" 4 9666 -9678 salated proposed 3-3/8" 1 9681 -9695 solated proposed 2-718" 4 9682 - 9721 solated proposed 3-3/8" 4 9695 - 9709 so~ated proposed 3-3l8" 4 9708 - 9728 solated proposed PBTD ~ 8648, 9-5/8" LNR, 47#, SOO-95, .0732 bpf, ID = 8.681" 9747' 04-01A [ Proposed CTD Sidetrack 2 3 4 5 6 7 8 9 4-1 i2" SSSV NIP, ID=3 °`3" GAS ~ = i I~M~hDR~S TYPE VLV LATCH PORT DA " - I -~ 9059' 9063' 9150' 916U' H ,~ata~=Ov^-s,o• 9-5/8" X 5-1/2" BAKER FB-1 PKR . ~ :;, _ ~ "z 9171' 5-12" OTIS XN NO-GO NIP, ID = 4.45" 9183' 5-112" BAKER SHEAROUT SUB 1 9184' 5-1/7' TUBING TAIL '. 9163' ELMD TT LOGGED 08/13/90 ~ 'Do 9300' _ .: UV ~~ow I 10100' ~ '? X-over '~" Ircr ~-~ 11075' ~ 9350' A: ~5?_.. sa^,..., . 9394' TOP OF CEMENT CAP 12/03/04 9429' TOP OF 20/40 SAND CAP 12/03/04 DATE REV BY COMMENTS DATE REV BY COMM7V'TS 01110171 ORIGINAL COMPLETION 12/03/04 KEYlfLP SANDCAP/CEMENT CAP 07!07190 LAST WORKOVER 12/08/05 DAVfrLP MIN. ID 8 OPEN PERF CORRECT. 05/31/01 RHttlh CORRECTIONS 1228/04 RAClTI.P GLV GO 1123/02 ?/TP MNIMUM ID CORRECTION 0324/05 KEYlTLH SAND CAP 08!16/04 MLWTLP ADD PERFS FROM 12106193 11/08/04 JLW/TLP WANER SAFETY NOTE ~ BOTTOM OF SAND CAP ~ PRUDHOE BAY UNrr WELL: 0401 PERMT No: 1700420 API No: 50.029-20078-00 SEC 34, T71 N, R15~ 3815.26' FEL & 3818.38' FNL BP Exploration (Alaska) • r by BP Alaska ~ Baker Hughes INTEQ Planning Report INTE Q Company: $P Amoco Date: 2/26/2007 Time: 13:55:26 ' Pagr. t Field: Prudhoe Bay Co-ordinate(NE) Reference: Well: 04-01, True North Site: ' PB DS 04 Vertical (TVD) Reference: 1 t 01 11/27/1970 00:00 64:0 Weli: 04-01 Section (VS) Referencet Well. (O.OON,O.OOE,315.OOAzi) Welipaths PIarr2, 04-01A SnrveyCakulation Method: Minimum Curvature Db: Oracle Field: Prudhoe Bay North Slope UNITED STATES Map System:US State Plane Coordinate System 1927 Map Zone: Alaska, Zone 4 Geo Datum: NAD27 (Clarke 1866) Coordinate System: Well Centre Sys Datum: Mean Sea Level Geomagnetic Model: bggm2006 Site: PB DS 04 TR-11-15 UNITED STATES :North Slope Site Position: Northing: 5953265.35 ft Latitude: 70 16 31.598 N From: Map Fasting: 711234.97 ft Longitude: 148 17 27.907 W Position Uncertainty: 0.00 ft North Reference: True Ground Level: 0.00 ft Grid Convergence: 1.61 deg Well: 04-01 Slot Name: 01 04-01 Well Position: +N/-S -2764.73 ft Northing: 5950537.29 ft Latitude: 70 16 4.406 N +E/-W 1262.78 ft Fasting : 712574.80 ft Longitude: 148 16 51.150 W Position Uncertainty: 0.00 ft Wellpath: Plan 2, 04-01A Drilled From: Plan 1, 04-01A Tie-on Depth: 9200.00 ft Current Datum: 1:01 11/27/1970 00:00 Height 64.00 ft Above System Datum: Mean Sea Level Magnetic Data: 2/21/2007 Declination: 24.23 deg Field Strength: 57674 nT Mag Dip Angle: 80.97 deg Vertical Section: Depth From (TVD) +N/-S +E/-W Direction ft ft ft deg 43.00 0.00 0.00 315.00 Plan: Plan #2 Date Composed: 2/21!2007 copy Lamar's plan 2, 25/100 DLS Version: 2 Principal: Yes Tied-to: From: Definitive Path Targets Map Map <-- Latitude ----> <-- Longitnde --> Name Description TVD +N/-S +E/-W Northing Fasting Deg Mio Sec Deg Min' Sec Dip. Dir. ft ft ft ft ft 04-01A Fault 1 64.00 -2655.86 1606.91 5947927.99 714256.00 70 15 38.284 N 148 16 4.393 W -Polygon 1 64.00 -2655.86 1606.91 5947927.99 714256.00 70 15 38.284 N 148 16 4.393 W -Polygon 2 64.00 -1964.89 2220.70 5948635.99 714850.00 70 15 45.078 N 148 15 46.528 W 04-01A Target 1 8920.10 -2096.52 2134.95 5948501.99 714768.00 70 15 43.783 N 148 15 49.025 W -Circle (Radius: 200) 04-01A Target 2 8981.87 -1702.71 1138.72 5948867.50 713761.10 70 15 47.659 N 148 16 18.012 W -Circle (Radius: 200) -Plan hit target Annotation MD TVD ft ft 9200.00 8518.14 TIP 9300.00 8606.30 KOP 9314.00 8618.25 End of 40 Deg/100' DLS 9354.00 8649.37 4 9454.00 8712.09 5 9554.00 8762.17 6 9629.00 8797.56 7 9704.00 8831.82 8 9779.00 8865.01 9 10013.37 8920.55 End of 25 Deg/100' DLS 10313.37 8929.60 11 10688.37 8954.19 12 11075.00 0.00 TD ~ • by BP Alaska Baker Hughes INTEQ Planning Report INTE Q Company: BP Amoco Dstr. 2/26/27 Time: 13;55:26 Page: 2 Feld; Prudhoe Bay Co-ordieataPiE) Refsreuce: Well: 04-01, True NoAM Site: PB DS 04 Vertical (TVD) Reference: 1:01 11/27/1 970:00:00 64 .0 Welk 04-01 Sectioe (~'S) Reterencec Well (O.OON,O .OOE,315.OOAzi) Wellpath: Plan 2, 0401 A Survey Calcalatioe 19etbod: Mirrimum Curvature Db: Orade Plan Section Information MD Iacl . Azim TVD +N/-S +E/-W DLS Bni~ Tarr TFO Target ft deg deg ft ft ft degllOOft deg/1OOft degl100ft deg 9200.00 27.83 157.00 8518.14 -2231.57 1668.88 0.00 0.00 0.00 0.00 9300.00 28.50 158.00 8606.30 -2275.18 1686.94 0.82 0.67 1.00 35.61 9314.00 34.10 158.00 8618.25 -2281.92 1689.66 40.00 40.00 0.00 0.00 9354.00 43.61 153.06 8649.37 -2304.67 1700.14 25.00 23.79 -12.35 340.00 9454.00 59.31 127.87 8712.09 -2362.74 1750.51 25.00 15.69 -25.19 300.00 9554.00 61.62 99.18 8762.17 -2396.69 1829.13 25.00 2.31 -28.69 268.00 9629.00 62.62 77.97 8797.56 -2395.01 1894.86 25.00 1.33 -28.28 268.00 9704.00 63.55 56.95 8831.82 -2369.53 1956.11 25.00 1.24 -28.04 268.00 9779.00 64.41 36.08 8865.01 -2323.47 2004.61 25.00 1.16 -27.82 268.00 10013.37 90.00 341.38 8920.55 -2107.88 2031.85 25.00 10.92 -23.34 287.00 10313.37 86.65 305.51 8929.60 -1870.90 1856.24 12.00 -1.12 -11.96 264.30 10688.37 86.22 260.42 8954.19 -1789.06 1500.94 12.00 -0.12 -12.02 268.00 11075.00 85.95 306.93 8982.14 -1700.39 1136.46 12.00 -0.07 12.03 92.00 Survey MD Incl Azim SS TVD N/S E/W MapN 'MapE 1)LS VS TFO Tool ft deg deg ft ft ft ft ft deg/t00ft' ft deg ' 9200.00 27.83 157.00 8454.14 -2231.57 1668.88 5948353.85 714305.95 0.00 -2758.03 0.00 MWD 9225.00 28.00 157.25 8476.23 -2242.35 1673.43 5948343.20 714310.81 0.82 -2768.88 35.61 MWD 9250.00 28.16 157.51 8498.29 -2253.21 1677.96 5948332.47 714315.64 0.82 -2779.76 35.38 MWD 9275.00 28.33 157.75 8520.31 -2264.16 1682.46 5948321.66 714320.45 0.82 -2790.68 35.16 MWD 9300.00 28.50 158.00 8542.30 -2275.18 1686.94 5948310.77 714325.24 0.82 -2801.64 34.94 MWD 9314.00 34.10 158.00 8554.25 -2281.92 1689.66 5948304.11 714328.15 40.00 -2808.33 0.00 MWD 9325.00 36.69 156.43 8563.22 -2287.79 1692.13 5948298.31 714330.78 25.00 -2814.23 340.00 MWD 9350.00 42.65 153.47 8582.45 -2302.23 1698.91 5948284.07 714337.96 25.00 -2829.23 341.28 MWD 9354.00 43.61 153.06 8585.37 -2304.67 1700.14 5948281.66 714339.26 25.00 -2831.83 343.56 MWD 9375.00 46.42 146.78 8600.22 -2317.50 1707.60 5948269.05 714347.08 25.00 -2846.17 300.00 MWD 9400.00 50.16 140.07 8616.87 -2332.45 1718.73 5948254.42 714358.63 25.00 -2864.61 304.44 MWD 9425.00 54.24 134.07 8632.20. -2346.88 1732.19 5948240.38 714372.49 25.00 -2884.34 308.92 MWD 9450.00 58.59 128.69 8646.03 -2360.61 1747.82 5948227.09 714388.50 25.00 -2905.10 312.59 MWD 9454.00 59.31 127.87 8648.09 -2362.74 1750.51 5948225.04 714391.25 25.00 -2908.50 315.58 MWD 9475.00 59.27 121.76 8658.82 -2373.04 1765.32 5948215.16 714406.35 25.00 -2926.26 268.00 MWD 9500.00 59.59 114.51 8671.55 -2383.18 1784.28 5948205.57 714425.59 25.00 -2946.84 271.12 MWD 9525.00 60.31 107.34 8684.08 -2390.90 1804.48 5948198.42 714445.99 25.00 -2966.58 274.81 MWD 9550.00 61.41 100.30 8696.26 -2396.10 1825.67 5948193.82 714467.31 25.00 -2985.24 278.41 MWD 9554.00 61.62 99.18 8698.17 -2396.69 1829.13 5948193.32 714470.79 25.00 -2988.11 281.84 MWO 9575.00 61.57 93.21 8708.17 -2398.69 1847.48 5948191.85 714489.19 25.00 -3002.50 268.00 MWD 9600.00 61.85 86.12 8720.03 -2398.56 1869.48 5948192.60 714511.17 25.00 -3017.96 270.84 MWD 9625.00 62.48 79.09 8731.71 -2395.71 1891.38 5948196.06 714532.99 25.00 -3031.43 274.21 MWD 9629.00 62.62 77.97 8733.56 -2395.01 1884.86 5948196.86 714536.44 25.00 -3033.39 277.49 MWD 9650.00 62.56 72.06 8743.23 -2390.19 1912.85 5948202.19 714554.30 25.00 -3042.71 268.00 MWD 9675.00 62.82 65.03 8754.71 -2382.07 1933.51 5948210.89 714574.71 25.00 -3051.58 270.72 MWD 9700.00 63.42 58.06 8766.03 -2371.45 1953.09 5948222.05 714593.99 25.00 -3057.92 273.95 MWD 9704.00 63.55 56.95 8767.82 -2369.53 1956.11 5948224.06 714596.95 25.00 -3058.69 277.11 MWD 9725.00 63.48 51.08 8777.19 -2358.49 1971.31 5948235.52 714611.83 25.00 -3061.63 268.00 MWD 9750.00 63.72 44.11 8788.31 -2343.40 1987.83 5948251.07 714627.92 25.00 -3062.65 270.62 MWD 9775.00 64.29 37.18 8799.28 -2326.36 2002.46 5948268.51 714642.05 25.00 -3060.94 273.72 MWD 9779.00 64.41 36.08 8801.01 -2323.47 2004.61 5948271.47 714644.12 25.00 -3060.41 276.76 MWD 9800.00 66.05 30.59 8809.82 -2307.55 2015.07 5948287.68 714654.14 25.00 -3056.55 287.00 MWD 9825.00 68.25 24.24 8819.53 -2287.10 2025.66 5948308.41 714664.14 25.00 -3049.59 289.30 MWD 9850.00 70.68 18.09 8828.31 -2265.28 2034.10 5948330.46 714671.96 25.00 -3040.12 291.77 MWD 9875.00 73.31 12.12 8836.05 -2242.34 2040.28 5948353.57 714677.49 25.00 -3028.27 293.93 MWD 9900.00 76.10 6.33 8842.65 -2218.55 2044.14 5948377.46 714680.67 25.00 -3014.18 295.78 MWD 9925.00 79.03 0.67 8848.03 -2194.20 2045.62 5948401.84 714681.47 25.00 -2998.00 297.31 MWD 9950.00 82.06 355.13 8852.14 -2169.57 2044.71 5948426.44 714679.86 25.00 -2979.94 298.53 MWD • • by BP Alaska s Baker Hughes INTEQ Planning Report uvTE Q Gompaay; BP Amoco Date: 2/26/2007 Time: 13:55;26 Page:. 3 Fief: Prudhoe Bay Co-ordi®xte(NE) Reference: Well: 04-01, Tnie NoctM Site: PB DS 04 ' Vertical (TVD) Refere®ee: 1 : Ot 11/27/1970 00:00 64.0 Welk 04-01 Sectiee (VS) References VYeN (O:OON,O.OOE,315.OOAzi) WellpatL: Plan 2, 04-01 A Survey Czakulatio® Method: Minimum Curvature Db: oracle Survey MD Incl Azim SS TVD N/S E/W MapN MapE • DLS VS TFO Tool ft deg deg ft ft ft ft ft deg/t00ft ft deg 9975.00 85.16 349.67 8854.93 -2144.95 2041.42 5948450.95 714675.88 25.00 -2960.21 299.44 MWD 10000.00 88.31 344.26 8856.35 -2120.65 2035.80 5948475.08 714669.57 25.00 -2939.05 300.05 MWD 10013.37 90.00 341.38 8856.55 -2107.88 2031.85 5948487.73 714665.26 25.00 -2927.23 300.36 MWD 10025.00 89.86 339.99 8856.56 -2096.90 2028.00 5948498.59 714661.11 12.00 -2916.75 264.30 MWD 10050.00 89.56 337.00 8856.69 -2073.65 2018.84 5948521.58 714651.29 12.00 -2893.82 264.30 MWD 10075.00 89.27 334.02 8856.94 -2050.90 2008.47 5948544.03 714640.29 12.00 -2870.41 264.32 MWD 10100.00 88.97 331.03 8857.33 -2028.72 1996.94 5948565.87 714628.14 12.00 -2846.58 264.35 MWD 10125.00 88.68 328.04 8857.84 -2007.18 1984.27 5948587.04 714614.87 12.00 -2822.39 264.39 MWD 10150.00 88.39 325.06 8858.48 -1986.33 1970.50 5948607.49 714600.51 12.00 -2797.90 264.45 MWD 10175.00 88.11 322.07 8859.24 -1966.23 1955.66 5948627.17 714585.11 12.00 -2773.20 264.53 MWD 10200.00 87.83 319.08 8860.12 -1946.93 1939.80 5948646.01 714568.71 12.00 -2748.33 264.62 MIND 10225.00 87.56 316.09 8861.13 -1928.49 1922.95 5948663.96 714551.35 12.00 -2723.38 264.73 MWD 10250.00 87.29 313.10 8862.25 -1910.96 1905.17 5948680.99 714533.08 12.00 -2698.41 264.85 MWD 10275.00 87.03 310.11 8863.49 -1894.38 1886.50 5948697.03 714513.95 12.00 -2673.49 264.98 MWD 10300.00 86.78 307.11 8864.84 -1878.81 1866.99 5948712.05 714494.01 12.00 -2648.68 265.13 MWD 10313.37 86.65 305.51 8865.60 -1870.90 1856.24 5948719.64 714483.04 12.00 -2635.49 265.29 MWD 10325.00 86.61 304.11 8866.29 -1864.28 1846.71 5948726.00 714473.33 12.00 -2624.06 268.00 MWD 10350.00 86.51 301.11 8867.79 -1850.83 1825.69 5948738.85 714451.94 12.00 -2599.69 268.08 MWD 10375.00 86.42 298.11 8869.33 -1838.50 1804.00 5948750.56 714429.91 12.00 -2575.63 268.26 MWD 10400.00 86.35 295.10 8870.91 -1827.33 1781.69 5948761.09 714407.30 12.00 -2551.96 268.45 MWD 10425.00 86.28 292.1U 8872.51 -1817.34 1758.83 5948770.43 714384.16 12.00 -2528.74 268.64 MWD 10450.00 86.22 289.09 8874.15 -1808.57 1735.48 5948778.54 714360.58 12.00 -2506.02 268.83 MWD 10475.00 86.18 286.08 8875.80 -1801.03 1711.70 5948785.40 714336.60 12.00 -2483.88 269.03 MWD 10500.00 86.14 283.08 8877.48 -1794.75 1687.57 5948790.99 714312.28 12.00 -2462.37 269.23 MWD 10525.00 86.12 280.07 8879.17 -1789.75 1663.13 5948795.31 714287.73 12.00 -2441.56 269.43 MWD 10550.00 86.11 277.06 8880.86 -1786.04 1638.47 5948798.32 714262.98 12.00 -2421.49 269.63 MWD 10575.00 86.10 274.06 8882.56 -1783.62 1613.65 5948800.04 714238.10 12.00 -2402.23 269.83 MWD 10600.00 86.11 271.05 8884.26 -1782.51 1588.74 5948800.44 714213.16 12.00 -2383.83 270.04 MWD 10625.00 86.13 268.04 8885.95 -1782.71 1563.80 5948799.54 714188.24 12.00 -2366.33 270.24 MWD 10650.00 86.16 265.04 8887.63 -1784.21 1538.90 5948787.33 714163.40 12.00 -2349.80 270.45 MWD 10675.00 86.20 262.03 8889.30 -1787.02 1514.12 5948793.83 714138.71 12.00 -2334.26 270.65 MWD 10688.37 86.22 260.42 8890.19 -1789.06 1500.94 5948791.42 714125.59 12.00 -2326.38 270.85 MWD 10700.00 86.17 261.82 8890.96 -1790.85 1489.47 5948789.31 714114.18 12.00 -2319.53 92.00 MWD 10725.00 86.08 264.83 8892.65 -1793.75 1464.70 5948785.71 714089.50 12.00 -2304.07 91.91 MWD 10750.00 85.99 267.83 8894.38 -1795.34 1439.81 5948783.41 714064.67 12.00 -2287.60 91.70 MWD 10775.00 85.92 270.84 8896.14 -1795.63 1414.88 5948782.42 714039.75 12.00 -2270.18 91.50 MWD 10800.00 85.86 273.85 8897.93 -1794.61 1389.97 5948782.73 714014.82 12.00 -2251.84 91.28 MWD 10825.00 85.81 276.85 8899.75 -1792.29 1365.15 5948784.35 713989.95 12.00 -2232.64 91.07 MWD 10850.00 85.77 279.86 8901.58 -1788.67 1340.48 5948787.28 713965.19 12.00 -2212.64 90.85 MWD 10875.00 85.74 282.87 8903.43 -1783.75 1316.04 5948791.50 713940.62 12.00 -2191.89 90.63 MWD 10900.00 85.73 285.88 8905.29 -1777.57 1291.89 5948797.00 713916.31 12.00 -2170.44 90.41 MWD 10925.00 85.72 288.89 8907.15 -1770.12 1268.10 5948803.77 713892.32 12.00 -2148.35 90.18 MWD 10950.00 85.73 291.89 8909.02 -1761.43 1244.74 5948811.79 713868.72 12.00 -2125.69 89.96 MWD 10975.00 85.75 294.90 8910.87 -1751.54 1221.86 5948821.04 713845.58 12.00 -2102.51 89.73 MWD 11000.00 85.78 297.91 8912.72 -1740.45 1199.53 5948831.49 713822.94 12.00 -2078.88 89.51 MWD 11025.00 85.83 300.92 8914.55 -1728.21 1177.81 5948843.12 713800.89 12.00 -2054.87 89.29 MWD 11050.00 85.88 303.93 8916.35 -1714.84 1156.77 5948855.89 713779,48 12.00 -2030.53 89.07 MIND 11075.00 85.95 306.93 8918.14 -1700.39 1136.46 5948869.76 713758.77 12.00 -2005.95 88.85 3 3/16" • • ~i~i ~ S 'i r~ fi~~ X86 { t, ri~l ~1 ~ ' 1~t~ ttl~ try ~ b , t ,~ i t„ ,~ ~~, ~ 1~ ~ rl~i rtir riT~li rti C~ I T lilT ~~1 1.i 111 c 1{ 1i ~11} 111 ;F;i ~itl ~t1 t~{1 111 'jll r(_t~ ' ~{ Ali It1! !II~~ i 'jt il, liF tlll} ~#i 1~~~~ i I i;it I i t' ~ ,~r t.. 1 r }1 ,}~l ~fl i~t lilll ~} 4i 1 i rI~ , i t i ~I Iltl X11 ~1iCtt~r tiifitt~t I[1a tzt~ ~ti )~} fiC ~'~{ Ilil tt tt~l !t~} ~}:t I~#a Itl} 111 1f }~ }r+t r}} tll ~[jJ rtrj fl}1 '.•i~' '~ k + ~{i t~fit~tl lfll Irll il.illi'+'l~i}Ixlr ~7t} itl~ 1~~~ ~ '1 `~ ~~~~ . }~~}t~;rat x}1{~(i~~ i~#? rFi~ly~y#~rt~,ttlt±~l1 1161 ~ ,f ~ pA$ ~F t; +~-F + ,.i jr ~Ftrl' .~.~ }~.. i I, 1 _~_ e~ ~b~ + F t -(I I lia a ~. +- ~~ i {I ttlT ~~lt Itt~ ~f~> ~i. ,~r~ il.i. ;~ ~' - I. a~+r lifr tt i t'}~I trt±. ,}+f jjc; ', ;$ k }t_~ rt ,: _ '.f ~ r_a a ~ }~i`T 1, 4 ~ ~ ~ ' f FBI ~1k1 I~F1 ~"~ 4' $ s Ir 1 ~ 1{~f qtr tti( ~~ ~ ~ ~- ~~f i s ~'~{ k ~~ ~ I~ _~ ~ I,~I ~ ~' ~ I'tf ~L r ~ ~ ~ I~ fi# ~r~= ~ ~ Ill{ f~li it+i~4ifi ~.~#F I ` ~ g 11 ~ ~ I ~~~ i tt '}~ t' ~ ice„ I~~ 'Il~ ait~ fli~ftli. t{t i~;;i f j rj C~ ~' hi rjt; :,t ~rtrl, lr~l lili ~1i1 i{a! (~i~ ~If 1,}I !ial~7tii ~~if f+~rl e 1 k it m ~ ''r1t f }t ~~ ; ~~ F~af jt11 . ~l' 1aT~ ~ F }` 11 F + ~ ~i ~ $_r FF..; g ~; I !r~~l~•~ r {t [ ! iE 1 ~ llfli~ il~ t a! r~!z~}j }~;i t-i}~ x++t it1l }~,:I±f + {ti;~:' I+ i~ ,t„ ~;r }r I~ , ,, . - - - [.wloo~l IAa+aN-IanM , t ;~ ~ ~~ ~ i I f' j ~~ ~~ tl~~~~,1~ ~~ d F ~ ea: H-~ 1 1 "J ~., ~sso Y •• : as - iw ~ a ~ ~ 0 g g°; a SSS3::R iii ~SS _ 1 ~1 ~ 4 ~ ~ ~ ~e~x4~ ~ ; e~iiz:a:e:i 1 1 a I f ~'1 ~ 4 1 i j ~~ i !4 3 S•i:: 7. s i i I ~ ~ 11 j ~l{ ' 1 I ~,~c ::5. i=i~# ~ ~ ?91......i:3e ;~ ~L ~ f t1t {~,~~ti :~r~ `+_ IWWtI NMI I~a/Y~A M ~~9M i A 's ~+t ~ ~' i - ~ l~ < e ,, 1.- i #~I±, by BP Alaska Anticollision Report ~.r ~~ 1NTEQ Company: BP Amoco. Date: 2/26!2007 Time: 14:01:25 Page:. 1 Field: Prudhoe Bay Reference Site: PB DS 04 Co-ord~ate(NE) Aeferencr. Well: 04-01, True North Reference We1L 04-01 Vertical (1'VD) Reference: 1:01 1.1/27/1970'00:00 64..0 Reference Welipath: Plan. 2, 04-01A Db: Orede GLOBAL SCAN APPLIED: All wellpaths within 200'+ 100/1000 of reference -There are 1seelis io thic9lehtYpal Plan & PLANNED PROGRAM Interpolation Method: MD Interval: 100.00 ft Error Model: ISCWSA Ellipse Depth Range: 9200.00 to 11075.00 ft Scae Method: Trav Cylinder North Maaimam Radios: 2000.00 ft Error Surface: Ellipse + Casing Survey Program for Defmitive Welipath Date: 2/21/2007 Validated: No Version: 1 Planned From To Survey Tookode Tooi Name ft ft 100.00 9200.00 1 : Camera based gyro multisho CB-GYRO-MS Camera based gyro multishot 9200.00 11075.00 Planned: Plan #2 V3 MWD MWD -Standard Casing Points MD TVD Diameter Hok S~ Name ft ft in in 11075.00 8982.14 3.188 4.125 3 3/16" Summary ~--- Offset Welipath ----- -> Refereuce Offset Ctr-Gtr No-Go Allowable Site Wei Welipath MD MD DtcEaece Area Deviation Warning ft ft_" ft ft ft 04-01,PIan 2, 04-01A,P 1 0200.00 10200.00 0.00 411.84 -411.84 FAIL: Major Risk PB DS 04 04-01 04-01 V1 9300.00 9300.00 0.00 495.95 -495.95 FAIL: Major Risk PB DS 04 04-32 04-32 V3 Out of range PB DS 04 04-32 04-32A V2 Out of range PB DS 04 04-46 04-46 V1 9360.00 10300.00 746.97 555.77 191.19 Pass: Major Risk PB DS 09 09-15 Plan 09-15A V2 Plan: 0 9820.00 14200.00 635.67 410.66 225.02 Pass: Major Risk Site: Well: Rule Assigned: Major Risk Welipath: 04-01,PIan 2, 04-01A,PIan #2 Inter-Site Error: 0.00 ft Reference Offset Semi-Major Axis Ctr-Ctr No-Go Albwable MD TVD MD TVD Ref Offset.. TFO+A ZI TFO-AS Casiog/HSflistaace Area Deviation Wareing ft ft ft ft ft ft deg deg in ft ft ft 9200.00 8518.14 9200.00 8518.14 121.24 0.00 157.00 0.00 4.125 0.00 396.86 -396.86 FAIL 9300.00 8606.30 9300.00 8606.30 122.32 0.38 158.00 0.00 4.125 0.00 400.42 -400.42 FAIL 9400.00 8680.87 9400.00 8680.87 122.97 1.47 140.07 0.00 4.125 0.00 404.92 -404.92 FAIL 9500.00 8735.55 9500.00 8735.55 111.52 2.72 114.51 0.00 4.125 0.00 372.39 -372.39 FAIL 9600.00 8784.03 9600.00 8784.03 82.03 3.59 86.12 0.00 4.125 0.00 285.71 -285.71 FAIL 9700.00 8830.03 9700.00 8830.03 56.05 3.89 58.06 0.00 4.125 0.00 209.62 -209.62 FAIL 9800.00 8873.82 9800.00 8873.82 68.91 3.69 30.59 0.00 4.125 0.00 249.50 -249.50 FAIL 9900.00 8906.65 9900.00 8906.65 94.26 3.13 6.33 0.00 4.125 0.00 325.06 -325.06 FAIL 10000.00 8920.35 10000.00 8920.35 115.85 3.47 344.26 0.00 4.125 0.00 389.40 -389.40 FAIL 10100.00 8921.33 10100.00 8921.33 122.36 4.49 331.03 0.00 4.125 0.00 409.66 -409.66 FAIL 10200.00 8924.12 10200.00 8924.12 122.79 5.55 319.08 0.00 4.125 0.00 411.84 -411.84 FAIL 10300.00 8928.84 10300.00 8928.84 118.04 6.54 307.11 0.00 4.125 0.00 398.48 -398.48 FAIL 10400.00 8934.91 10400.00 8934.91 108.29 7.36 295.10 0.00 4.125 0.00 370.15 -370.15 FAIL 10500.00 8941.48 10500.00 8941.48 94.04 7.94 283.08 0.00 4.125 0.00 328.32 -328.32 FAIL 10600.00 8948.26 10600.00 8948.26 76.03 8.25 271.05 0.00 4.125 0.00 275.26 -275.26 FAIL 10700.00 8954.96 10700.00 8954.96 60.41 8.55 261.82 0.00 4.125 0.00 229.38 -229.38 FAIL 10800.00 8961.93 10800.00 8961.93 80.88 11.10 273.85 0.00 4.125 0.00 291.62 -291.62 FAIL 10900.00 8969.29 10900.00 8969.29 98.39 13.61 285.88 0.00 4.125 0.00 345.02 -345.02 FAIL 11000.00 8976.72 11000.00 8976.72 111.89 15.73 297.91 0.00 4.125 0.00 386.45 -386.45 FAIL Site: PB DS 04 Well: 04-01 Ruk Assigned: Major Risk Welipath: 04-01 V1 Inter-Site Error: 0.00 ft Reference Offset Semi-MajorAais Ctr-Ctr No-Go Allowable MD TVD MD TVD Ret Offset TFO+AZI TFO-HS Casing/HSingtarce Area Deviatioe Wareieg ! i by BP Alaska Anticollision Report ~.r INTEQ Company: BP AmoCO Date: 2/26/2007 Time: 14:01:25 'Page: 2 Fiehl; Prudhoe Bay Reference Site: PB DS 04 Co-erdirate(NE) Retcreece: W811: 0401, T-ue North Reference Well: 04-01 Vertical (TVD) Rekrcnce: 1 : Of 1 ( /27/1970 00: 00 64:0 Rekreace Wellpath: Plan 2, 0401 A Db: Orade Site: PB DS 04 Well: 04-01 Rule Assigned: Major Risk Wellpath: 04-01 V1 Inter-Site Error: 0.00 ft Reference OCfset Semi-Major Aaig CtrGtr No-Go Allowable MD TVD MD TVD Ret Offset TFO+AZI TFO-HS Casiag/HSUistaace Area Deviation Warning ft ft ft ft ft ft deg deg in ft ft ft 9200.00 8518.14 9200.00 8518.14 121.24 121.24 157.00 0.00 13.625 0.00 487.92 -487.92 FAIL 9300.00 8606.30 9300.00 8606.30 122.32 123.58 158.00 0.00 13.625 0.00 495.95 -495.95 FAIL 9394.15 8677.08 9400.00 8694.28 123.01 126.75 312.87 171.30 13.625 22.97 212.85 -189.88 FAIL 9468.55 8719.52 9500.00 8782.48 117.40 122.99 290.11 166.47 13.625 75.34 355.66 -280.32 FAIL 9530.90 8750.99 9600.00 8870.77 103.6( 110.13 271.10 165.44 13.625 142.13 430.29 -288.15 FAIL 9579.15 8774.14 9700.00 8958.07 88.91 95.89 256.64 164.61 13.625 218.06 456.96 -238.90 FAIL 9616.88 8791.95 9800.00 9047.36 76.26 83.79 245.58 164.22 13.625 299.95 458.36 -158.41 FAIL 9647.26 8805.97 9900.00 9135.66 66.99 75.32 236.95 164.12 13.625 386.24 449.69 -63.45 FAIL 9671.77 8817.24 10000.00 9223.95 60.98 70.55 230.10 164.17 13.625 475.47 436.36 39.11 Pass 9690.55 8825.78 10100.00 9312.24 57.52 68.49 224.79 164.10 13.625 566.93 420.30 146.63 Pass 9705.53 8832.50 10200.00 9400.54 55.64 68.34 220.54 164.02 13.625 660.06 404.07 256.00 Pass 9720.38 8839.13 10300.00 9488.83 55.91 70.60 216.64 164.27 13.625 754.39 391.83 362.57 Pass 9732.50 8844.53 10400.00 9577.13 57.02 73.58 213.42 164.44 13.625 849.62 380.63 468.99 Pass 9742.51 8848.99 10500.00 9685.42 58.11 76.90 210.74 164.55 13.625 945.56 369.24 576.32 Pass Site: PB DS 04 Well: 04-46 Rale Assigned: Major Risk Wellpath: 04-46 V1 Inter-Site Error: 0.00 ft Reference Offset Semi-MajorAais Ctr-Ctr No-Go Allowable MD TVD MD TVD Ref Offset TFO+AZI TFO-HS Casiug/HSt3istance Area Deviation Warning ft ft ft ft ft ft deg deg in ft ft ft 9253.81 8565.65 10200.00 8439.07 121.82 61.93 226.50 68.95 746.14 547.40 198.75 Pass 9360.00 8653.69 10300.00 8533.83 122.68 60.53 227.58 76.38 746.97 555.77 191.19 Pass 9386.21 867f.84 10400.00 8629.50 123.08 58.62 229.34 85.67 753.50 561.17 192.33 Pass 9408.49 8686.23 10500.00 8725.56 122.64 56.47 231.71 93.75 768.27 560.71 207.55 Pass 9428.56 8698.26 10600.00 8821.54 121.62 54.14 234.25 100.98 791.49 554.11 237.39 Pass 9446.18 8708.02 10700.00 8917.55 120.28 51.81 236.92 107.44 824.99 542.42 282.58 Pass 9460.00 8715.16 10800.00 9013.51 118.77 49.94 239.39 113.26 867.12 528.30 338.83 Pass 9480.00 8725.38 10900.00 9109.89 115.56 47.00 240.22 119.91 917.43 504.91 412.52 Pass 9488.76 8729.84 10993.40 9200.69 113.79 45.72 242.09 124.32 970.16 490.64 478.52 Pass Site: PB DS 09 Well: 09-15 Rule Assigned: Major Risk Wellpath: Plan 09- 15A V2 Plan: 09-15A Wp #8 V18 Inter-Site Error: 0.00 ft Retereece Offset Semi-Major Aai4 Ctr-Ctr No-Go Allowabh: MD TVD MD TVD Ref Onset TFO+AZI TFO-HS Casing/HSU~tance .Area Deviation Warning ft ft ft ft ft ft deg deg in ft ft ft 9720.00 8838.96 12500.00 8821.81 55.88 44.52 141.57 89.09 6.250 1940.29 229.88 1710.41 Pass 9720.00 8838.96 12600.00 8821.42 55.88 44.47 142.45 89.97 6.250 1866.59 228.70 1637.89 Pass 9710.29 8834.62 12700.00 8821.15 55.72 43.27 144.71 89.52 6.250 1783.90 224.59 1559.31 Pass 9704.00 8831.82 12800.00 8821.02 55.62 42.48 146.29 89.34 6.250 1693.83 224.80 1469.03 Pass 9702.56 8831.17 12900.00 8820.86 55.77 42.31 146.93 89.59 6.250 1598.16 225.24 1372.92 Pass 9700.97 8830.46 13000.00 88f9.76 55.94 42.12 147.33 89.54 6.250 1499.12 225.81 1273.32 Pass 9701.23 8830.58 13100.00 8817.65 55.92 42.17 147.12 89.41 6.250 1399.32 225.79 1173.53 Pass 9702.11 8830.97 13200.00 8815.28 55.82 42.31 146.70 89.23 6.250 1299.74 225.68 1074.06 Pass 9703.12 8831.42 13300.00 8812.90 55.71 42.43 146.20 89.01 6.250 1200.22 225.52 974.70 Pass 9704.00 8831.82 13400.00 8810.53 55.62 42.55 145.67 88.72 6.250 1100.78 225.53 875.26 Pass 9704.00 8831.82 13500.00 8808.31 55.62 42.57 145.14 88.19 6.250 1001.75 225.63 776.13 Pass 9710.78 8834.84 13600.00 8807.26 55.73 43.47 143.11 88.05 6.250 906.38 226.71 679.67 Pass 9720.00 8838.96 13700.00 8805.01 55.88 44.70 139.94 87.46 6.250 818.81 233.85 584.96 Pass 9731.45 8844.07 13800.00 8800.95 56.93 46.21 135.56 86.28 6.250 742.30 250.26 492.04 Pass 9747.91 8851.39 13900.00 8797.31 58.98 48.28 129.61 84.92 6.250 681.54 280.94 400.60 Pass 9768.47 8860.44 14000.00 8794.17 62.73 50.71 122.39 83.40 6.250 641.39 322.32 319.07 Pass • > by BP Alaska Anticollision Report • 19Litr s 1NTEQ ..Company: BP Amoco Date:. 2/26/2007 Time: 14:01':25 Page:::... 3 Field: Pnrdhoe Bay. . Retereeee Site:.: PB DS 04 Go•erdfmate(NE} Reference: WeN: 0401, True .North Reference Well: 04-01 Vertical (TVI)) Reference: 1:01 11 /27/1970 00:00 64.0 Rekrenee Welipath: Plan 2, 04-01 A Db: Orade Site: PB DS 09 Well: 09-15 Rule Assigned: Major Risk Wellpath: Plan 09- 15A V2 Plan: 09-15A Wp #8 V18 Inter-Site Error: 0.00 ft Reference Offset Semi-MajorAais Ctr-Ctr No-Ga Albwabie MD TVD MD TVD Ref Offsct TFO+AZI TFO-HS Casing/H~ista~ee Area Deviatroa Warning ft ft _ ft ft ft ft' deg deg in ft ft ft 9792.80 8870.86 14100.00 8791.57 67.56 53.17 114.45 81.99 6.250 625.65 367.70 257.96 Pass 9820.00 8881.66 14200.00 8789.59 73.41 55.46 106.57 81.08 6.250 635.67 410.66 225.02 Pass 9845.28 8890.73 14300.00 8788.24 79.77 57.22 99.87 80.64 6.250 669.99 444.46 225.53 Pass 9868.26 8898.07 14400.00 8787.57 85.84 58.48 94.52 80.81 6.250 725.08 470.54 254.54 Pass 9887.13 8903.39 14500.00 8786.70 90.86 59.26 90.54 81.25 6.250 795.51 489.23 306.29 Pass 9900.00 8906.65 14600.00 8784.99 94.26 59.69 87.83 81.50 6.250 871.54 500.68 370.87 Pass 9920.00 8911.06 14700.00 8783.27 99.36 60.08 84.03 82.23 6.250 950.97 517.01 433.95 Pass 9930.48 8913.04 14800.00 8781.55 101.87 60.22 82.02 82.57 6.250 1033.20 524.26 508.94 Pass 9940.00 8914.66 14900.00 8779.83 104.15 60.29 80.25 82.91 6.250 1117.77 530.59 587.17 Pass 9951.51 8916.35 15000.00 8778.11 106.68 60.26 78.15 83.35 6.250 1204.23 537.50 666.73 Pass 9960.00 8917.42 15100.00 8776.40 108.55 60.21 76.62 83.68 6.250 1292.31 542.26 750.05 Pass 9968.08 8918.29 15200.00 8774.68 110.13 60.11 75.18 84.00 6.250 1381.73 546.20 835.53 Pass 9980.00 8919.32 15300.00 8772.96 112.47 59.85 72.95 84.37 6.250 1472.35 551.87 920.48 Pass 9980.00 8919.32 15400.00 8771.24 112.47 59.92 73.11 84.53 6.250 1563.85 551.58 1012.26 Pass 9980.00 8919.32 15500.00 8769.49 112.47 59.98 73.26 84.67 6.250 1656.32 551.38 1104.95 Pass 9992.12 8920.05 15600.00 8766.61 114.52 59.60 70.92 84.96 6.250 1749.40 555.97 1193.43 Pass 10000.00 8920.35 15700.00 8763.73 115.85 59.32 69.41 85.15 6.250 1843.22 558.71 1284.52 Pass 10000.00 8920.35 15800.00 8760.85 115.85 59.38 69.53 85.27 6.250 1937.55 558.52 1379.03 Pass • • a N2 13" Comp BOP Well: DSO4-01A Rig Floor Telescoping Riser 7-11 ft scope 6.00 ft Input distance from rig floor to fop of Hydril 8.34 ft C~ Hydril 3-118" 5k, R-35\API i CHOKE LINE by BX160 API HYDRIL "G K" 13-5/8" 5k Annular 4.67 ft BX160 API Ring 1.50 ft 13-518"5k Shaffer SL BOP Blind Rams API Ring KILL LINE ~~I 1.83 ft 5k, R-35 1.50 ft 13-518"5k Shaffer 4-1 /2" x 7"" VBR's BX160 2.67 ft BX160 API Ring 13-518"5k Tubing Hanger Base Flange GL distance to Ri_q Floor Page 1 N2 13" Comp BOP Well: DSO4-01 Ria Floor Riser 7-11 ft scope r-, Input distance from rig floor to top of Hydril HYDRIL "GK" C~ Hydril 13-5/8" 5k Annular love MSL by 4.67 ft BX160 API Ring 1.50 ft 13-5i8"5k Shaffer SL BOP Blind Rams 3-118" 5k, R-35 API Ri s ~-- BX160 API Ring KILL LINE 1.83 ft ass CHOKE LINE BX160 API Ring ~_; !iiTl ~3-1/8" 5k, R-35 API Rings 13-518"5k Shaffer 5-112" 2-7/8" VBR's L ~~ BX160 1.50 ft 2.67 ft BX160 API Ring 13-518"5k Tubing Hanger Base Flange GL distance to Rig Floor I 26.50 Page 1 • • • Maunder, Thomas E (DOA) From: Thomas Maunder [tom_maunder(a3admin.state.ak.us] Sent: Monday, February 26, 2007 4:23 PM To: Rixse, Mel G Subject: Re: Pre Rig and Rig Work for DSO4-01A...wi11 call Page 1 of 3 `~ J~ Thanks Mel, I am sending the sundry to be finalized. By copy of this email, you have approval to move ahead with the pre-rig work. Tom Maunder, PE AOGCC Rixse, Mel G wrote, On 2/26/2007 4:16 PM: Tom, Thanks for your quick response. Terrie Hubble will make sure this all gets properly placed in your approved Sundry and we don't go out with anything else. Mel From: Thomas Maunder [mailtoaom_mau_ nder~?admi_n.state_ak._us] Sent: Monday, February 26, 2007 4:02 PM To: Rixse, Mel G Subject: Re: Pre Rig and Rig Work for DSO4-01A...will call Mell, Here is your note. I have separated the proposed operations into sundry and permit to drill. Essentially we (the worker bees) consider all work done prior to exiting the casing to be done in the existing welibore. We look at the exit as being the spud of the sidetrack ar lateral. Hope this helps. Tom Maunder, PE AOGCC Rixse, Mel G wrote, On 2/26/2007 3:39 PM: Pre-Rig Work Summary: 1. O Check the tubing hanger and IC casing hanger lock down screws for free movement. Completely back out and check each lock down screw for breakage (check one at a time). PPPOT-T & IC. 2. S Drift ?" x 5-112" tubing for composite plug/jet cutter and 3-3/4" bit to base of tubing tail. 3. S Pull 3 3/8" retrievable IBP in 5 1/2" tubing. 4. C Run memory gamma ray/CCL 5. C Reverse circulate sand plug 9246' to 9350' MD. 6. C Set 17#/gal cement sidetrack plug from 9350'MD to base of 5-1/2" tubing tail at 9184'MD. 7/11/2007 • 7. O Perform MIT-IA to 3000 psi 8. E Run SCMT (CBL) to assure existing 7" x 5-1/2" tubing has no external backfill. 9. E Jet cut 5-1/2" tubing @ ~9028'md 10. F Circulate well with seawater and freeze-protect with diesel through the cut 11. O Bleed WHPs to 0 psi. 12. O Bleed production flow lines and GL lines down to zero and blind flange 13. O Set a BPV in the tubing hanger 14. O Build 4' ice pad 15. O Remove wellhouse Rig Work: 1. MIRU. 2. Set TWC and test to 1000 psi. 3. ND tree and tubing adapter flange. NU 13-5/8" BOPE with 2-7/8" x 5- 1/2"" VBR pipe rams. Pressure test to 3500 psi. Annular preventer tested to 3500 psi. Circulate out freeze protection fluid and circulate well to clean kill weight brine through the cut. 4. Pull TWC 5. Pull and LD 7" x 5-%2" tubing string to the cut. Inspect jet cut. once OOH. 6. PU 3 -1 /2" DP and overshot and casing scraper to polish top of tubing stub (9028'md). 7. Change out 9-5/8" packoff and test to 5000 psi. 8. RU slckline. Run Junk basket/gauge ring for new 9-518" packer down to top of tubing stub. 9. RU Eline. Run USIT log on 9-5/8" interval (9059' -surface). Check for casing damage and cement. quality. 10. Run 4-1/2", 12.6# 13CR-80 Vam Top completion 13Cr-80 stacker packer completion with Baker S-3 packer. Position packer at M8989' MD. Install new packoff. Space out TTail with custom overshot on tubing stub. Screw in lock down screws. Circulate inhibited 8.7 PPg NaCI brine into the T x IA annulus above the packer. 11. Drop ball and rod, set PKR, test tubing and annulus to 3500 psi. 12. Shear DKR valve in upper GLM. Circulate in diesel freeze protection on T and IA to 2200'. 13. Set TWC and test to 1000 psi. 14. ND BOPE. NU and test tree to 5,000 psi. Pull TWC, Sundry above here. Drilling permit below here. 1. NU 7-1/16" CTD stack and test. 2. Dummy top GLM. 3. Mill Cement Ramp Page 2 of 3 7/11/2007 Page 3 of 3 4. Mi113.80" window at 10,940'and 10' of rathole. Swap the well to Flo- Pro. 5. Dri114.125" build section and land well. 6. Drill Lateral: 3.75" OH, ,with resistivity 7. Run 3-3/16" x 2-7/8" solid liner leaving TOL at 9150', 5 bbls of 15.8 ppg cmt 8. Pump primary cement leaving TOC at TOL 9150' 9. Cieanout liner 10. MCNL/GR/CCL log 11. Test liner lap to 2000 psi. 12. Perforate liner per asset instructions (100') 13. Freeze protect well, Set BPV, RDMO Post-Rig Work: 1. Move wellhouse, Install production flowline, pail BPV 2. Run GLVs Mel Rixse CTD Engineer 564-5620 7/11/2007 Alaska Department of Natural Resources Land Administration System Page 1 of 2 • v~Jr~ ,~ _, ~.:.~r„`~ State Cabins ~~1~1i~,~i a=, ~~~~ ~" ~ ~ ~c'1 LAS Menu ~ Case Abs*~~-~ct ~ Case Detail i Land Abstract ~. l~rlc~: DUI. 2'{32$ '~` Sea ,a3 f~.r ~, :.a ~Ba~ Ll~c! ,t,,.; 1s oP (i_; ~ I ~ X2007 Custo~ncr: OOOI07377 BP EXPLORATION (ALASKA) INC PO BOX 1 966 1 2/900 E. BENSON BL, ATTN: LAND MANAGER- ALASKA ANCHORAGE AK 995196612 Case Ttipe: 784 OIL ~ GAS LEASE COMP DNR Unit: 780 OIL AND GAS Nile I,oc°ution: DOG DIV OIL AND GAS ('use Slu[t~s: 35 ISS/APPRV/ACTV AUTH Slulus Dale: 09/14/1965 Total Acres: 2560.000 Duce h~itiatc~c l: 05/28/1965 Office ofPrlmrny ResJ~onsibilily: DOG DN OIL AND GAS Lust Trunsuction Dote: 12/04/2006 Case ,Suhtvhe .~ NS NORTH SLOPE Lust Trunsactio~7: AA-NRB ASSIGNMENT APPROVED IVIerlLhlan: IJ IOIb'nS17lIJ: OI I I`J RCl17ge: OI SE S~'c'1(032: 2J S'L'C/loll ACreS': (i4U Searc~s Flats rvlericliurl: U Totirizshih: 01 IN Range: O1>I~, 5'c~c~lr~vl. '~, Section ~~lcres: 640 dleridr~ ul: U T oti~~nship: 01 I N Range: O 1 ~ I ti~~c~ln ~lr.~ ~ ~ Section Acres: 640 ~llcridi~ l~r - U Townsjiih: O I I N Range: 015E Sectrolz: h Section Acres: 640 .Legal Desc-•iption I) ~-?8- I )6~ * * ~ SALE A'OTICF, LLGAL DESY;RIF'TI(>;~" C'J-/-154 Tlll~'-RI ~E-I%al?J.?6.3?,3G?~60.00 t-= ~- Last updated on 03/13/2007. http://www.dnr.state.ak.us/las/Case_Summary.cfm?FileType=ADL&FileNumber=28324&... 3/ 13/2007 • • Terri L. Hubble ss-si,2e2 327 BP Exploration AK Inc. °Mastercard Check" PO Box 196612 MB 7-5 ~ I~'V Anchorage, AK 995.7 9 - DATE PAY TO THE (}~~ %~/~ ~O - v~(J fl(ll 14 R First National Bank Alaska -- Anchorage, AK 96501 ~~ ~ '~ ~ ~ MEMO ~:L25200060~:99L4622715561t' 03:27 • • ~'~tANS1dIIT"I'Ai, LE1'~'E1Z C~I~CICLIST WELL NAIVtE ~,~U D~ -O/~ P~-D~ 0?0~03~" / ®evelopment Service Exploratory Stratigraphic Vest Non-Conventional Well Circle Appropriate Letter /Paragraphs to be Included in Transmittal Letter CHECK i ADD-ONS TEXT FOR APPROVAL LETTER ,' WHAT ; (OPT[ONS) aPPLIES I I MULTI LATERAL ~ The permit is for a new we116ore segment of existing ~ ~ we[l ~ (If last two digits in Permit No. ,API No. ~0- - - i API number are ;between 60-69) Production should continue to be reported as a function of the ' ~ original API number stated above. i PILOT HOLE U accordance with 20 A.AC 25.00~(f), all records, data and logs ;acquired for the pilot hole must be clearly differentiated in both ;well name ( PH) and API number ' (SO- - -_) from records, data and logs ~ ~ acquired for well SPACING The permit is approved subject to full compliance with 20 AAC EXCEPTION 12~.0>j. Approval to perforate and produce /infect is contingent ,' I upon issuance of a conservation order approving a spacing j exception. assumes the ~ ~ liability of any protest to the spacing exception that may occur. i ,DRY D[TCH ~ All dry ditch sample sets submitted to the Commission must be in 'i SA!~IPLE I no greater than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals j through target zones. ' ;Please note the following special condition of this permit: Non-Conventional i production or production testing of coal bed methane is not allowed Well i for (name of well) until after (Companv Name) has designed and implemented a water well testing program to provide baseline data I on water quality and quantity. (Company Name) must contact the ~ Commission to obtain advance approval of such water well testing program. ~ Rev: l 2~i06 C ^ jody~transmittal_checklist • • ~^ N ~ a ti ~~ ~ a ; o ~ s ~ , Q ~ i y ~, ~ ~ ~ ~ ~~ f6, c, O~ a I , y (6 tll' N N, L ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ a NOS ~ ~ ~ ~ N w cn ~, ~ o O ~ o '- m' (4 L, a. oa ~ 'o ~ ~ ~ a ~ Q ~ ~, ~ I 4 ~, ~ ~ aoi , o ~ o ~ o' r O ~ ~ n o I j~ ; Z d ~ m ~' h, I ~.~ o ~ ~ m ~ Q -o ~° ~ ~ I o. o o ~; uNi ° ~. } m o Z U; ~ a c~i '~ m ; ~ = o ~ ; ~. ~ n c ~ II o O ~ a. 3; o 0 0 ~ ~ ~ ~ o. ° Q' O, O, a, (6 ~ Z ~ ~, o' ~ o, o. rn o o. O' m. Q. N' m. ~ w o ; I N~ N y~ N~ N, N~ U1 N.. N. y~ N~ y. N ~ i ~ ~ ~ N: y~ ~~ N~ N~ ~ N N N O N N ,, ~ ~ N, a~, a~, a~, a~~ a~~ a~, o, a~~ a~, a~, a~~ a~, a~ Q; Q. Q; Q i Q. Q, Q. Q. a~, a~, a~, o, a~, Q, a~, a~. a~~ a~. a~, a~~ Q. o. Q. Q; Q; a~ Q >- >', ~, ~, >', >-, ~, ~, >-, ~, ~, ~ ~ Z, Z, Z, Z Z, Z, Z, Z, >-, ~-, 1-, >-, )-, Z. >-, >- >-, >-, }, ~, Z, Z; Z. Z, Z, >-. N o , _ ~ ~ ~ ~ . 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Y~ .O-" ~ _ .~~ D. O. N, N. >: N' N' N, N ~i, C -O' D) ._ ~ O' O' N, G C' N, ~ ~ `O: t ~ O' U O ~' N' ~~ >+ ~ O ~ ~, m' ~ - a. a. a. U c m' ~ ~. .o a ~_ o ;~ 'N a~ a~ >, rn o, ~. ° o w o. i .o c. ~ c ~ g o~ ~ ~~ ~~ ~~ ~~ m ~, o. ~~ c. c. ~, ~3 ~ a ~ ~~ m m ~~ ~~~ ~ = 3 -g ~ ~ ~~ o, ~~ m~ c a~~ c~ o. m. ~~ ~ ;~ m. ~ ~~ ar ~ ~ m m, E m. o. ° ~?~ '- 4; - c. .cv, o, ~, m v c ~ Q1 c v v v c o' o ° ° v ti a' c; ~, ~ m. o o; - a' m ~ m a~' ~... Q E' -' a~ c I o ~ a. .1 m~ .~ N 6 0' o o ~~. ~ a~ a~ ~ ~, c ~ ~ °" c ~I c ~ ~ ~ ~ ~~ ~ ~'; ~ > ~ nw., a o' Y ~ cLi ~ ~ ,y, ~, c,. Y >, m; ~ c, °~' °~ °~ ~, a q 4 a~ a~ m o' - ~, o, ~I o ° ~; ~ ~ o, a. ~°, a, a -, O O, ~ ° °' o ' a~ m a~, o o, u ~~,~,~,~;'s,~,~~;O,o,a,a,v ~'Q,a,z v<n;v,v;v v.¢,=,¢,~,o m;m,v;~' ~',~';a,o,<n,usv w Q _ O r N M V ~ (O I~ W O O r N M V ~t7 CO I~ M O r N M V ~ CO I~ W O r r r r r r r ~- r N N N N N N N N N 6J OM M M M M M M M M M (~ O .__.. __ - _._...__ - _ r _ _._.. __ __. ____- _ -. ... _. U ~~ o 0 0 fG C +O'' ~ .4+ N .. ~ ~~.. N ~ 'n ~ p ~ li p~~ ~ M w O iv ~ ~ r r a. M C M ( (h J O N N ~ N J ~# ~ Q ~ ~ Q rL ~ ~ Q ~ W ~~ Q Q it c Q Iw- N Q Q 'S a Q w c9 (` ~ A ^ m `v J` N ^ (~ n~ `'' 3 rno c c 0 .~ o N .N c ~ ~~ wv ui ~ ~ O l''7 a`> U O O O y /!~ t ...~ O U r~ ~~ Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. **** REEL HEADER **** MWD 09/01/13 BHI O1 LIS Customer Format Tape **** TAPE HEADER **** MWD 07/05/13 1413210 Ol 3.0" CTK *** LIS COMMENT RECORD *** tapescan.txt !!!!!!!!!!!!!!!!!!! Remark File version 1.000 !!!!!!!!!!!!!!!!!!! Extract File: ldwg.las version Information VERS. 1.20: OWLS log ASCII Standard -VERSION 1.20 WRAP. NO: One line per frame well Information Block #MNEM.UNIT Data Type Information STRT.FT 9250.0000: Starting De th STOP.FT 11373.0000: Ending Dept h STEP.FT 0.5000: Level Spacing NULL. -999.2500: Absent value COMP. COMPANY: BP Exploration (Alaska), Inc. WELL. WELL: 04-OlA FLD FIELD: Prudhoe Bay Unit LOC LOCATION: 70 deg 16' 4.406"N 148 deg 16' 51.150"w CNTY. COUNTY: North slope Borough STAT. STATE: Alaska SRVC. SERVICE COMPANY: Baker Hughes INTEQ TOOL. TOOL NAME & TYPE: 3" CTK DATE. LOG DATE: 13 May 2007 API API NUMBER: 500292007801 Parameter Information Block #MNEM.UNIT Value Description SECT. 34 Section TOWN.N T11N Township RANG. R15E Range PDAT. MSL Permanent Datum EPD .F 0 Elevation Of Perm. Datum LMF KB Log Measured from FAPD.F 64 Feet Above Perm. Datum DMF KB Drilling Measured From EKB .F 0 Elevation of Kelly Bushing EDF .F 64 Elevation of Derrick Floor EGL .F 0 Elevation of Ground Level Page 1 ~~ ~ ~ tapescan.txt CASE.F N/A Casing Depth OS1 DIRECTIONAL Other Services Line 1 Remarks (1) All depths are Measured Depths (MD) unless otherwise noted. (2) All depths are Bit Depths unless otherwise noted. (3) All True vertical Depths (TVDSS) are Subsea corrected. (4) All Formation Evaluation data is realtime data. (5) Baker Hughes INTEQ utilized coilTrak downhole tools and the Advantage surface system to lob this well.. (6) Tools ran in the string included Casing Collar Locator, an Electrical Disconnect and Circulating Sub, a Drilling Performance sub (Inner and Outer Downhole Pressure, vibration and Downhole weight on Bit), a Directional and Gamma sub, and a Hydraulic orienting sub with a Near Bit Inclination Sensor. (7) Data presented here is final and has been depth adjusted to a PDC (Primary Depth Control) log provided b schlumberger GR CNL dated 15 May 2007 per BP Exploration (Alaska, Inc. (8) The sidetrack was drilled from 04-O1 through a milled window in a 9 5/8 inch liner. Top of window 9278 ft.MD (8523 ft.TVDSS) Bottom of window 9287 ft.MD (8530 ft.TVDSS) (9) Tied to 04-01 at 9295 feet MD (8537 feet TvDSS). (10) Baker Hughes INTEQ Runs 1, 2, 5, 6, 8, 9 and 10 are milling and window dressing runs. (11) The interval from TvDSS) was not logged due to sensor to (12) The resisitivity 8737 ft TVDSS) was reamed-lodged (13) The resisitivity ft TvDSS) 11344 feet to 11374 feet MD (8926 feet to 8931 feet bit offset at well TD. interval from 9287 ft. to 10210 ft, MD (8531 ft to up on run 15 10.6 hours after being drilled. unterval from 10404 ft to 10434 ft MD (8741 ft to 8743 was logged on run 16 8.5 hours after being drilled. (14) The resisitivity interval from 10643 ft to 10673 ft MD (8790 ft to 8799 ft Tvoss) was logged on run 17 21.5 hours after being drilled. MNEMONICS: GRAX -> Gamma Ray [MWD] (MWD-API units) ROP~VG -> Rate of Penetration, feet/hour RACLX -> Resistivity (AT)(LS)400kHz-Compensated Borehole Corrected (OHMM) RACHX -> Resistivity (AT)(LS)2MHz-Compensated Borehole Corrected (OHMM) RPCLX -> Resistivity (PD)(LS)400kHz-Compensated Borehole Corrected (oHMM) RPCHX -> Resistivity (PD)(LS)2MHz-Compensated TvDSS -> True vertical Depth (subsea) CURVE SHIF T DATA BASELINE, MEASURED, DISPLACEMENT 9254.1, 9254.93, ! 0.829102 9259.49, 9260.94, ! 1.45117 9264.26, 9265.5, ! 1.24316 9265.92, 9267.78, ! 1.86523 9283.54, 9286.23, ! 2.69434 9292.45, 9294.11, ! 1.65918 9295.98, 9298.67, ! 2.69531 9297.63, 9300.33, ! 2.69531 9298.88, 9301.37, ! 2.4873 9301.16, 9304.27, ! 3.10938 9306.13, 9308.83, ! 2.69531 9309.24, 9311.73, ! 2.48828 9311.52, 9314.84, ! 3.31738 9314.63, 9317.74, ! 3.11035 9319.82, 9321.89, ! 2.07324 Page 2 Borehole Corrected (OHMM) tapescan.txt 9325.04, 9327.94, ! 2.90137 9333.54, 9336.23, ! 2.69434 9341.83, 9344.11, ! 2.28027 9346.18, 9348.46, ! 2.28027 9348.26, 9351.16, ! 2.90234 9350.95, 9353.65, ! 2.69434 9358.83, 9361.73, ! 2.90234 9363.8, 9366.5, ! 2.69531 9367.54, 9369.82, ! 2.28027 9372.1, 9374.58, ! 2.48828 9375.62, 9377.28, ! 1.6582 9377.07, 9379.35, ! 2.28027 9381.42, 9384.95, ! 3.52441 9395.45, 9398.15, ! 2.69531 9398.56, 9401.05, ! 2.48828 9400.64, 9402.92, ! 2.28027 9403.33, 9405.82, ! 2.4873 9404.58, 9408.1, ! 3.52441 9429.04, 9432.15, ! 3.10938 9436.71, 9440.23, ! 3.52441 9443.55, 9446.45, ! 2.90234 9446.24, 9449.14, ! 2.90137 9453.9, 9458.05, ! 4.14648 9516.5, 9519.19, ! 2.69434 9520.23, 9523.55, ! 3.31641 9563.44, 9566.34, ! 2.90234 9571.11, 9574.01, ! 2.90234 9574.22, 9577.12, ! 2.90234 9576.08, 9578.78, ! 2.69531 9680, 96 82.08, ! 2.07324 9762.19, 9764.88, ! 2.69531 9781.46, 9784.78, ! 3.31738 9788.51, 9790.79, ! 2.28027 9794.32, 9796.18, ! 1.86621 9803.53, 9804.57, ! 1.03613 9807.47, 9808.3, ! 0.829102 9818.25, 9818.66, ! 0.415039 9834.21, 9838.15, ! 3.93848 9837.73, 9841.46, ! 3.73145 9841.67, 9844.78, ! 3.10938 9920.01, 9922.5, ! 2.48828 9924.99, 9927.68, ! 2.69434 9941.93, 9943.79, ! 1.86523 9948.77, 9948.98, ! 0.207031 9953.74, 9954.57, ! 0.829102 9959.76, 9959.76, ! 0 9963.48, 9963.69, ! 0.207031 9965.97, 9966.17, ! 0.207031 9969.7, 9970.73, ! 1.03613 10010.5, 10009.6, ! -0.829102 10020.6, 10019.8, ! -0.829102 10068.7, 10067.8, ! -0.830078 10096, 10094.4, ! -1.6582 10106.6, 10107.4, ! 0.829102 10150.2, 10145.8, ! -4.35352 10161.4, 10157.2, ! -4.14551 10164.5, 10159.7, ! -4.76758 10168.8, 10163.4, ! -5.38965 10173.8, 10167.8, ! -6.01172 10175.5, 10171.3, ! -4.14648 10178.6, 10174.7, ! -3.93945 10185.2, 10181.3, ! -3.93848 10227.3, 10224, ! -3.31641 Page 3 10233.5, 10231, 10271.9, 10270.7, 10287.7, 10287.5, 10293.7, 10291, 10306.8, 10305.2, 10312.9, 10309.7, 10328.6, 10325.3, 10331.9, 10328, 10358, 10356.6, 10365.4, 10362.5, 10411.5, 10408.4, 10415.8, 10412.7, 10490, 10485.4, 10494.7, 10490, 10499.7, 10495.1, 10505.8, 10504.3, 10514.3, 10515.3, 10526.1, 10527.7, 10541.2, 10541.4, 10546.2, 10546.8, 10554.7, 10553.9, 10561.5, 10561.5, 10565.9, 10565.7, 10570.3, 10573.6, 10577.8, 10580.1, 10582.8, 10586.5, 10590.4, 10592.7, 10597.6, 10598, 10602.8, 10603.6, 10610.5, 10610.5, 10615.9, 10617.1, 10623.5, 10623.5, 10638.9, 10638.7, 10643.2, 10642, 10648, 10645.7, 10661.9, 10660.4, 10671.8, 10670.2, 10676, 10674.5, 10678.9, 10678, 10688.1, 10686.3, 10689.2, 10687.7, 10691, 10689.6, 10697.9, 10694.8, 10709.3, 10706, 10712.2, 10708.7, 10719.7, 10715.6, 10722.4, 10719.5, 10728.6, 10724.3, 10734.6, 10730.7, 10740.8, 10739, 10746.9, 10743.7, 10751, 10749.8, 10760.1, 10756.8, 10768.2, 10766.5, 10772.1, 10770.1, 10789, 10787, 10807.1, 10807.1, 10812.7, 10812.7, 10818.7, 10817.3, 10826.6, 10825.8, 10840.3, 10838.9, 10845.3, 10843.2, 10855, 10852.6, tapescan.txt -2.4873 -1.24414 -0.207031 -2.69434 -1.6582 -3.10938 -3.31738 -3.93848 -1.45117 -2.90234 -3.10938 -3.10938 -4.56055 -4.76855 -4.56055 -1.45117 1.03613 1.6582 0.207031 0.621094 -0.829102 -0.207031 3.31641 2.28027 3.73145 2.28027 0.415039 0.829102 0 1.24414 0 -0.207031 -1.24316 -2.28027 -1.45117 -1.6582 -1.45117 -0.829102 -1.86523 -1.45117 -1.45117 -3.10938 -3.31738 -3.52344 -4.14648 -2.90137 -4.35352 -3.93848 -1.86621 -3.10938 -1.24414 -3.31738 -1.6582 -2.07227 -2.07324 0 0 -1.45117 -0.829102 -1.45117 -2.07324 -2.4873 Page 4 tapescan.txt 10861.3, 10859.6, ! -1.6582 10867.3, 10864.6, ! -2.69531 10874.1, 10870.4, ! -3.73145 10883, 10878.5, ! -4.56055 10889.7, 10886.3, ! -3.31641 10899.6, 10894.6, ! -4.97559 10904.4, 10901.3, ! -3.10938 10917.6, 10913.5, ! -4.14551 10919.9, 10917.8, ! -2.07227 10922.6, 10920.1, ! -2.4873 10925.9, 10924.3, ! -1.6582 10932.1, 10929.2, ! -2.90137 10940.7, 10938.2, ! -2.4873 10955.5, 10952.3, ! -3.10938 10962.7, 10961, ! -1.6582 10966.8, 10965.6, ! -1.24414 10974.9, 10974.9, ! 0 10988.4, 10987.7, ! -0.62207 10990.2, 10992.7, ! 2.4873 11014.5, 11016.3, ! 1.86621 11016.8, 11017.8, ! 1.03711 11058.6, 11058.8, ! 0.207031 11061.5, 11061.5, ! 0 11065.2, 11065.9, ! 0.62207 11072.1, 11071.5, ! -0.62207 11074, 11075, ! 1.03613 11086.6, 11085.8, ! -0.829102 11092.6, 11093, ! 0.414062 11094.5, 11094.3, ! -0.207031 11097.8, 11098.8, ! 1.03711 11128.7, 11127.6, ! -1.03711 11134.4, 11134.8, ! 0.414062 11141, 11140, ! -1.03613 11178.5, 11177.7, ! -0.830078 11201.9, 11200.2, ! -1.6582 EOZ END ! BASE CURVE: GROH, OFFSET CURVE: GRAX Tape subfile: 1 258 records... Minimum record length: 10 bytes Maximum record length: 132 bytes **** FILE HEADER **** MWD .001 1024 *** LIS COMMENT RECORD *** !!!!!!!!!!!!!!!!!!! Remark File version 1.000 The data presented here is final and has been depth adjusted to a PDC (Primary Depth Control) log provided by schlumberger GR CNL dated 15 May 2007 per BP Exploration (Alaska), Inc. Page 5 tapescan.txt * FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame Size is: 28 bytes Logging direction is down (value= 255) optical Lod Depth Scale units: Feet Frame spacing: 0.500000 Frame spacing units: [F ] Number of frames per record is: 36 one depth per frame (value= 0) Datum Specification Block Sub-type is: FRAME SPACE = 0.500 * F ONE DEPTH PER FRAME Tape depth ID: F 6 Curves: Name Tool 1 GR MWD 2 ROP MWD 3 RAD MWD 4 RAS MWD 5 RPD MWD 6 RPS MWD Code samples units 68 1 AAPI 68 1 F/HR 68 1 OHMM 68 1 OHMM 68 1 OHMM 68 1 OHMM 1 Size Length 4 4 4 4 4 4 4 4 4 4 4 4 24 Total Data Records: 118 Tape File Start Depth = 9250.000000 Tape File End Depth = 11372.500000 Tape File Level Spacing = 0.500000 Tape File Depth units = feet **** FILE TRAILER **** Tape Subfile: 2 131 records... Minimum record length: 54 bytes Maximum record length: 4124 bytes **** FILE HEADER **** MWD .001 1024 *** LIS COMMENT RECORD *** !!!!!!!!!!!!!!!!!!! Remark File version 1.000 This file contains the raw-unedited field MWD data. Page 6 • i tapescan.txt * FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame Size is: 28 bytes Logging direction is down (value= 255) optical Lod Depth scale units: Feet Frame spacing: 0.250000 Frame spacing units: [F ] Number of frames per record is: 36 one depth per frame (value= 0) Datum specification Block sub-type is: FRAME SPACE = 0.250 * F 1 ONE DEPTH PER FRAME Tape depth ID: F 6 Curves: Name Tool Code samples units size Length 1 GR MWD 2 ROP MWD 3 RAD MWD 4 RAS MWD 5 RPD MWD 6 RPS MWD 68 1 AAPI 68 1 F/HR 68 1 OHMM 68 1 OHMM 68 1 OHMM 68 1 OHMM 4 4 4 4 4 4 4 4 4 4 4 4 24 Total Data Records: 237 Tape File Start Depth = 9248.750000 Tape File End Depth = 11374.000000 Tape File Level Spacing = 0.250000 Tape File Depth units = feet **** FILE TRAILER **** Tape Subfile: 3 250 records... Minimum record length: 54 bytes Maximum record length: 4124 bytes **** TAPE TRAILER **** MWD 07/05/13 1413210 O1 **** REEL TRAILER **** MWD Page 7 tapescan.txt 09/01/13 BHI O1 Tape subfile: 4 2 records... Minimum record length: 132 bytes Maximum record length: 132 bytes 0 Tape Subfile 1 is type: LIS 0 Tape subfile 2 is type: LIS DEPTH GR ROP RAD RAS RPD RPS 9250.0000 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 9250.5000 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 9300.0000 47.9579 10.6598 2000.0000 47.6792 20.2493 18.9296 9400.0000 110.3803 47.9000 15.1050 9.7246 8.8958 8.0665 9500.0000 21.4187 29.3000 8.6499 7.7103 7.2547 7.0053 9600.0000 25.3602 67.9437 3.8030 3.7209 3.5312 3.3940 9700.0000 28.5945 105.3152 3.1398 3.4265 3.6830 4.3150 9800.0000 29.8727 95.7891 4.6421 5.2432 5.1856 5.6921 9900.0000 31.4302 106.7913 3.0473 2.9689 2.8083 2.6773 10000.0000 24.8720 139.5917 18.5349 27.4577 21.7996 22.5739 10100.0000 27.7293 25.0283 8.1180 5.2891 5.1611 4.4398 10200.0000 30.9956 52.4352 3.3128 3.4977 3.5750 4.0582 10300.0000 29.8138 36.4989 4.3641 5.0203 5.0965 6.0230 10400.0000 29.9054 44.0043 5.8440 4.1689 Page 8 ~ ~ tapescan.txt 4.1026 3.9234 10500.0000 80.3506 44.6753 16.6355 25.8396 24.2893 30.9396 10600.0000 112.2927 15.3828 49.3182 45.4383 29.2657 27.3743 10700.0000 133.6265 76.9585 8.0101 7.2326 5.8891 4.9677 10800.0000 30.7993 85.3064 7.4647 6.3956 5.8066 5.3625 10900.0000 35.5866 94.1619 21.5355 25.5829 21.2810 21.6550 11000.0000 147.3000 50.6978 13.9753 14.6231 12.5694 12.4588 11100.0000 89.2855 35.8276 8.4463 7.6524 7.4508 7.4976 11200.0000 80.1387 39.4850 17.6976 16.3861 15.0686 15.4316 11300.0000 168.5584 113.4510 16.2681 13.8454 11.5730 10.6944 11372.5000 -999.2500 49.2000 -999.2500 -999.2500 -999.2500 -999.2500 Tape File Start De th = 9250.000000 Tape File End Depth = 11372.500000 Tape File Level Spacing = 0.500000 Tape File Depth units = feet 0 Tape Subfile 3 is type: LIS DEPTH GR ROP RAD RAS RPD RPS 9248.7500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 9249.0000 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 9300.0000 70.2000 58.7000 2179.3999 91.2840 22.5440 18.4090 9400.0000 110.8000 34.6000 16.7390 11.0760 10.2260 9.7660 9500.0000 21.4000 18.4000 7.2150 6.7330 6.3190 6.3070 9600.0000 22.2000 68.4000 3.5110 3.5310 3.3830 3.3510 9700.0000 24.9000 106.3000 3.1800 3.4590 3.6370 4.1010 Page 9 tapescan.txt 9800.0000 30.9000 96.7000 4.6140 4.5750 9900.0000 25.4000 112.8000 2.9500 2.8060 10000.0000 22.5000 140.1000 22.2630 23.3880 10100.0000 26.7000 21.3000 5.2670 4.5620 10200.0000 27.3000 51.7000 3.6270 3.9440 10300.0000 32.2000 43.5000 4.6110 5.3740 10400.0000 28.4000 55.4000 4.3230 4.1370 10500.0000 124.9000 73.1000 26.1500 36.1220 10600.0000 114.1000 14.1000 29.3390 27.6760 10700.0000 150.6000 73.4000 5.6960 4.8410 10800.0000 25.3000 87.3000 6.3310 6.0270 10900.0000 74.2000 98.1000 18.8230 17.5380 11000.0000 142.0000 73.5000 12.3130 11.7740 11100.0000 100.2000 36.6000 7.4410 7.4270 11200.0000 73.0000 44.5000 14.1030 13.7760 11300.0000 157.6000 30.5000 11.7480 11.0480 11374.0000 -999.2500 49.2000 -999.2500 -999.2500 Tape File Start Depth = p 9248.750000 Tape File End ~ept = 11374.000000 Tape File revel Spacing = 0.250000 Tape File Depth units = feet 0 Tape 5ubfile 4 is type: LIS 4.5410 3.1650 18.6120 8.2120 3.4070 4.0990 6.0600 16.4240 49.9940 7.7140 7.7070 21.8470 14.3180 8.4360 17.7140 16.1560 -999.2500 4.9550 3.1350 27.7940 5.3460 3.6220 4.5100 4.3860 26.8270 45.5820 6.8220 6.8400 25.7510 14.6240 7.6490 16.1680 13.5400 -999.2500 Page 10
