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Home My WebLink About208-164Image Project Well hlistory File Cover Page xl-ivzE 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 ~r are viewable by direct inspection of tl~e file. ~~~ - ~ tt~ ~- WeN History File Identifier Organizing (done) ^ Two-sided III (I'III II III II III ^ Rescan Needed III IIIII IIII III III RE CAN DIGITAL DATA OVERSIZED (Scannable) C for Items: ^ Diskettes, No. ^ Maps: Greyscale Items: ` P ^ Other, No/Type: ^ Other Items Scannable by a Large Scanner ^ Poor Quality Originals: OVERSIZED (Non-Scannable) ^ Other: ^ Logs of various kinds: NOTES: ^ Other:: BY: Maria ~ Date: ~ ~ ~ /s/ Project Proofing III 111111 IIIII II III BY: Maria Date: I ~ ~ ~ /s/ Scanning Preparation ,~ x 30 = ~ + `~ =TOTAL PAGES (Count does not include cover sheet) ' /~ /) ~ , BY: Maria Date: ` ' ,~ ~ /s/ `/ ~/ Y Production Scanning III IIIIIIIIIII IIIII Stage 1 Page Count from Scanned File: ~ '~ (Count does include cover eet) Page Count Matches Number in Scanning Preparation: YES NO BY: Maria Date: ~ 1 ~/ Q /s/ ~~ Q Stage 1 If NO in stage 1, page(s) discrepancies were found: YES NO BY: Maria Date: fs/ Scanning is complete at this point unless rescanning is required. II ~ ~I ~I II I II II IIIII ReScanned BY: Maria Date: /s/ Comments about this file: Quality Checked III 111111 III II'I III 10/6/2005 Well History File Cover Page.doc i/ ~~~ ~~~ ~~ ~~ iiilll~~o Terrie Hubble ~~~j~~~ Drilling Technologist BP Exploration (Alaska) Inc. Drilling & Wells 900 East Benson Boulevard P.O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 ~^"~;, January 13, 2009 ~,~,~~ ~ r~.> Alaska Oil & Gas Conservation Commission 333 West 7th Avenue, Suite 100 A~aSkaQll ~ ~~~ ~1„ii~ ~ ~ ~~~'''~~'~~~~ Anchorage, Alaska 99501 AnCO'ior~~~ Reference: API # 50-029-23398-01-00 Permit # 208-164, PBU 12-37A Direct: (907) 564-4628 Terrie.hubble~bp.com To Whom It May Concern: Please cancel approved Permit to Drill for PBU 12-37A, Permit Number 208-164 (50-029-23398-01-00). You may wish to also cancel the associated Application for Sundry Approval (for Permit to Drill 208-144, Approval #308-358). The Permit and Sundry were part of a contingency plan that was deemed unnecessary after drilling PBU 12-37. Thank you very much for your assistance in this matter. Sincerely, Terrie Hubble xc: Well Files PDC iR ~. ,iAN t 5 20Q~ S~R.4fl PALIfiI, GO!/~RR/OR 333 W. 7th AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Greg Hobbs Engineering Team Leader BP Exploration Alaska Inc. PO Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU 12-37A BP Exploration Alaska Inc. Permit No: 208-164 Surface Location: 829' FSL, 738' FEL, Sec. 18, T10N, R15E, UM Bottomhole Location: 2082' FSL, 642' FWL, Sec. 08, T10N, R15E, UM Dear Mr. Hobbs: 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) 659-3607 (pager). Sincerely, ~7'~J~ Cath P. Foerster Commissioner `/~~- DATED this Z7 day of October, 2008 cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. ` STATE OF ALASKA ~~r~ ~ ~ ~I ALASKA ~D GAS CONSERVATION COMMISSION ` ~ ~ I O'r PERMIT TO DRILL ~~3 20 AAC 25.005 Contingency Plan to Sidetrack 1 a. Type of work ^ Drill ®Redrill ^ Re-Entry 1 b. Current Well Class ^ Exploratory ^ Development Gas ^ Service ^ Multiple Zone ^ Stratigraphic Test ®Development Oil ^ Single Zone 1 c. S ecify 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 12-37A 3. Address: P.O. Box 196612, Anchors e, Alaska 99519-6612 6. Proposed Depth: MD 13152' TVD 8634' 12. Field /Pool(s): Prudhoe Bay Field / Prudhoe Bay 4a. Location of Well (Governmental Section): Surface: 829' FSL 738' FEL SEC 18 T1 N R1 E M 7. Property Designation: ADL 028330, ADL 028329 Pool , , . , , , U 0 5 Top of Productive Horizon: 4772' FSL, 1210' FEL, SEC. 18, T10N, R15E,UM 8• Land Use Permit: 13. Approximate Spud Date: October 21, 2008 Total Depth: 2082' FSL, 642' FWL, SEC. 08, T10N, R15E, UM 9. Acres in Property: 2560 14. Distance to Nearest Property: 18,530' 4b. Location of Well (State Base Plane Coordinates): Surface: x-696862 -5931140 Zone-ASP4 10. KB Elevation Planned (Hei ht above GL): feet 15. Distance to Nearest Well Within PSI: 910' 16. Deviated Wells: Kickoff Depth: 9715 feet Maximum Hole A le: 105 d rees 17. Maximum Anticipated Pressures in psig (see 20 AAC 25.035) Downhole: 3262 Surface: 2462 Hole Casin Wei ht Grade Cou tin Len MD TVD MD TVD includin sta a data _ t 19. PRESE NT WELL CONDITION S UMMARY (To be completed for Redrill and Re-entry Operations) Total Depth MD (ft): tanned: 10463' Total Depth TVD (ft): Plugs (measured): None Effective Depth MD (ft): Planned: 10313' Effective Depth TVD (ft): 9090' Junk (measured): None sin Leri Size Cement Volume MD TVD onductor / Strucural Surface -1/ " Intermediate Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): 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 A proval: Commission Re resentative: Date: 22. I hereby certify that the foregoing is true and correct. Contact Travis Peltier, 564-4511 Printed Name Gr H bs Title Engineering Team Leader ~~area ey Nar~e/ra,mber: Si nature Phone 564-4191 Date /~' Z Terrie Hubble, 564-4628 Co issio Onl Permit To Drill • ~?l»'-~d~f API Number: 5o-o~9a~39Po/~ Permit Approval See cover letter for Conditioru 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: ^ Yes l~No Mud Log Req'd: ^ Yes (~NO "2 cs1®~~ + ~ ~~~ HrS Wleasures: Yes ^ No Directional Survey Req'd: Yes ^ No Other. ~ V Date ~ -Z -vj~ ~ APPROVED BY THE COMMISSION COMMISSIONER Form 10-401 Revised 12/2005 ~ :161NAL Submit In Duplicate ~ ~6 J~ ~ L ~~ J From: Maunder, Thomas E (DOA) ~,, Sent: Thursday, October 23, 2008 1:39 PM To: Peltier, Travis M Cc: Hobbs, Greg S (ANC); Smith, Phil G (ASRC); Tirpack, Robert B; DOA AOGCC Prudhoe Bay; Foerster, Catherine P (DOA) Subject: RE: 12-37A PTD and DS 12-37 (208-144) Travis, Thanks for the revised information for 12-37A. I will place it in the permit package. There appears to be issue that has come up on 12-37 that I wish to advise you of. You may already be aware of this. Inspector Jeff Jones was just at the rig for the diverter inspection. Some non-compliance issues were noted. These include: Inoperative hydraulic pressure gauges on the remote BOP panel. 2. It appears that the operation of the knife valve and diverter are not sequenced properly since the diverter is closed prior to the knife valve being fully opened. The inoperative gauges on the remote panel is an item that was observed during a BOP inspection about 3 weeks ago and the Inspector was informed at that time that repairs would be accomplished following the completion of that well. Apparently that repair work was not accomplished. Inspectar Jones informed the BP WSL that operations on DS 12-37 may not proceed until the repairs are made and proper operationlfunction witnessed by an Inspector. The Commission reserves the righ# to pursue an enforcement action regarding these matters. Cal! or message with any questions. Tom Maunder, PE AOGCC From: Peltier, Travis M [mailto:Travis.Peltier@bp.com] Sent: Thursday, October 23, 2008 1:06 PM To: Maunder, Thomas E (DOA) Ce: Hobbs, Greg S (ANC); Smith, Phil G (ASRC); Tirpack, Robert B Subject: 12-37A PTD Tom, Thanks for the phone call. As per your request, here is the updated 12-37A PTD pages that reflect that we have NO AC issues in this 6-1/8" wellbore as well as the Anadrill Directional Plan. Thanks again, and I will keep you informed of 01-18's status as well. -Travis Peltier GPB Rotary Drilling (907)564-4511 «12-37 (P6) report.pdf» «12-37_P6_export_file.txt» «12-37A PTD October 22_08 update.doc» 2/6/2009 r: To: Alaska Oil & Gas Conservation Commission From: Travis Peltier, ODE Date: September 25, 2008 Re: 12-37A Sidetrack well Permit to Drill The 12-37 well is scheduled to be drilled by Nabors Rig 7ES which is currently scheduled to move onto the location around Nov 10, 2008. 12-37 is a new, ultra-slim hole design well completing the Sag with an Ivishak pilot hole. The 12-1/4" hole will be drilled to the topmost, competent shale of the SV3 where the 9-5/8" surface casing will be run and cemented. An 8-3/4" hole will then be drilled to the top of the Sag River Formation, with 7" casing top set with cement. The planned pilot hole then is drilled into the Ivishak Z2 to a TD of 10,463'MD. We will plug back this pilot hole to the 7" shoe, and drill a Sag lateral to a TD of 13,152' MD. The lateral requires this 12-37A permit to drill. In either case, a solid 4- 1/2" production liner will be run and cemented in place. The Ivishak reservoir (e.g. Z2) will be completed if it turns out to be economically attractive. Should the Ivishak reservoir be completed, the Sag target will be preserved as a future CTD candidate. , Please • following Well Summary as detailed on the next few pages: 12-37A Permit to Drill Application Page 1 Planned Well Summary Well 12-37A Well Sidetrack T e Producer API Number: TBD Target Sag Ob'ective River Current Status 12-37A will be a sidetrack from an existing wellbore. Estimated Start Date: 21-Oct-2008 Time to Com lete: 30.6 Da s Surface Northin Eastin Offsets TRS Location 5,931,140 696,863 829' FSL / 738' FEL 10N, 15E, 18 Target Northin Eastin TVDss Offsets TRS Locations 5,935,070 696,273 -8,655 4772' FSL / 1210' FEL 10N, 15E, 18 Bottom Northin Eastin TVDss Offsets TRS Location .5,937,707 698,047 -8,565 2082' FSL / 642' FEL 10N, 15E, 8 Planned KOP: Surface Planned TD: 13,152'MD / 8,565' TVDss Ri Nabors 2ES BFE: 41' RTE: 68.5' Directional - Anadrill "12-37 (P6) report" KOP: Surface Maximum Hole Angle: ~25° in the 12-1/4" surface section (@ 1,915' MD to TD) ~47° in the 8-3/4" intermediate section (@ 8,916' MD to TD) 105° in the 6-1/8" sa horizontal section 10,048' MD. Close A roach Wells: There are no close approach issues with this well. Surve Pro ram: MWD Standard + IFR /Cassandra / MS Nearest Pro a Line: 18,530' to the PBU property line to the South Nearest Well within Pool: 01-30 is the closest well at 910' ctr-ctr distance. Contacts Name Phone # E-mail Drilling Engineer Travis Peltier 564-4511 travis.peltier(c~bp.com Geologist Daniel Schafer 564-5098 daniel.schaferna,bp.com Pad Engineer Trina Cooper 564-4212 Katrina.Coonerna,bp.com 12-37A Permit to Drill Application Page j( • Planned Well Summary Well Sidetrack • Well 12- A Target Sag T e Producer Ob'ective River API Number: TBD Current Status 2-37A will be a sidetrack from an existing wellbore. Estimated Start Date: 21- ct-2008 Time to Com lete: 30.6 Da s Surface Northin Eas 'n Offsets TRS Location 5,931,140 696,8 829' FSL / 738' FEL 10N, 15E, 18 Target Northin Eastin T ss Offsets TRS Locations 5,935,070 698,273 -8, 5 4772' FSL / 1210' FEL 10N, 15E, 18 Bottom Northin Eastin TVDss Offsets TRS Location 5,937,707 698,047 -8,565 082' FSL / 642' FEL 10N, 15E, 8 Planned KOP: Surface Plan d TD: 13,152'MD / 8,565' TVDss Ri Nabors 2ES BFE: 41' RTE: 168.5' ~, Directional -Sperry 12-37_wp5 ~ ~~~~~~~` KOP: Surface ~~~' Maximum Hole Angle: ~25° in the 12-1/4" surface section (C 1,915' to TD) ~47° in the 8-3/4" intermediate section (@ 8,916' D to TD) 105° in the 6-1/8" sa horizontal section @ 10,04 MD. Close A roach Wells: 12-21 and 01-13 in the 6-1/8" section. Surve Pro ram: MWD Standard + IFR /Cassandra / MS Nearest Pro ert Line: 18,530' to the PBU property line to the South Nearest Well within Pool: 01-30 is the closest well at 910' ctr-ctr distance. Contacts Drilling Engineer Geologist Pad Engineer Name Phone # Travis Peltier 564-4511 Daniel Schafer 564-5098 Trina Cooper 564-4212 12-37A Permit to Drill Application Page 2 Formation Markers 12-37 (Ba~on SOR) • Formation /Zone (TVDss) MD TVD Thick MD Thick An le NOTE: All formation tops are required from 1000' above proposed KOP to TD for sidetracks NOTE: All formation to s are re uired from surface to TD for all new wells NOTE: All formation to s aze Based on 12-37_w 4 Formation SSTVD MD TVD Thick MD Thick An le Surface 69 0 2749 2885 0.0 SV4 -2680 2885 630 698 24.2 SV3 -3310 3583 200 221 24.4 SV2 -3510 3804 405 448 24.2 SV1 -3915 4252 695 768 24.4 UG4 -4610 5020 90 100 24.4 UG3 -4700 5120 730 807 24.2 UGl -5430 5927 575 636 24.2 WSZ -6005 6563 265 294 24.2 WS 1 -6270 6857 205 226 24.4 CM3 -6475 7083 520 576 24.4 CM2 -6995 7659 917 1035 24.2 CMl -7912 8694 244 341 39.1 THRZ -8156 9035 188 275 47.0 BHRZ -8344 9310 86 126 47.0 TKNG -8430 9436 31 46 47.0 TJB -8461 9482 75 110 47.0 TJA -8536 9592 119 174 47.2 TSGR -8655 9766 5 8 47.0 7" Lnr Set Point -8660 9774 19 27 47.0 TSHU -8679 9819 211 S6 62.8 TSHB -8699 98_75 12 90 76.2 Invert Dint - Shublik B -8711 9965 24 135 90.0 TSHU / BSGR -8687 101(10 38 175 105.0 Crest in Sa - Be 'n Horizontal -8649 10275 ll 690' 92:3 Sa -Horizontal section -8638 10965 12 764 90.9 - Sab -Horizontal - Turn u structure -8626 11729 34 746 90.9 Sa -Horizontal -Mid section u structure -8592 ] 2475 27 676 91.6 Sa - TD -8565 13'151 92.2 12-37A Permit to Drill Application Page 3 • Casina/Tubina Program • Hole Csg / Wt/Ft Grade Conn Burst Collapse Length Top Bottom Size Tbg (psi) (psi) MD / MD / O.D. TVDrkb TVDrkb 6-1/8" 4'/z' 12.6# 13Cr- 80 VAM Top 10,160 10,530 3,579' 9,624' / 8,626' 13,152' / 8,634 Tubing 4 %" 12.6# 13Cr- 80 Vam Top 10,160 10,530 9,573' GL 9,624' / 8,626' Mud Program 6'/e" Production Hole Mud Pro erties FloPro-SF Interval Densi PV YP PH API Filtrate MBT 9,774'-13,152' Final Well TD 8.4-8.6 6-12 22-28 9.0-9.5 6-8 <3 Logging Program 6'/e" Hole Section: Sample as required by well site Geologist MWD / LWD: DIR/GR/RES O en Hole: None Cased Hole: None Cement Program Casin Size 4.5" 12.6#, 13CR-80 Production Liner Basis: Lead: None Tail: 3378' of open hole with 40% excess, 80' shoe tract, 150' 4-'/2" x 6-1/8" liner lap, and 200' of 7" x 4" DP excess. Tail TOC: 9,424' MD (200' above Liner Top) Total Cement Volume: Spacer 20 bbls of Mudpush II Weighted to 12 ppg Lead None Tail 87.9 bbls, 495 cult, 423 sks 15.8 Ib/ al Class G + adds -1.17 cuft/sk Tem BHST = 203°F, BHCT = 137 °F Surface and Anti-Collision Issues Surface Shut-in Wells: There are no wells requiring surface shut-in in order to move onto the well. At surface, 12-12A to the north and 12-11 to the south are nearest wells. Each are 60' from the planned spud location. Close Approach Shut-in Wells: No wells will be shut-in in order to drill 12-37A. Hydrogen Sulfide DS 12 is designated as an H2S site. Recent HZS data from the pad is as follows: Date of Wn11 W~mn 1-19C 1 oval Raadine #1 Closest SHL Well H2S Level #2 Closest SHL Well H2S Level 12-11 NA 12-12A 20 m 3/8/2008 12-37A Permit to Drill Application Page f • Casina/Tubina Program • Hole Csg / Wt/Ft Grade Conn Burst Collapse Length Top Bottom Size Tbg (psi) (psi) MD / MD / O.D. TVDrkb TVDrkb 6-1/8" 4 ~/z" 6# 13Cr- 80 VAM Top 10,160 10,530 3,579' 9 624' / 8,626 13,152' / 8,634 Tubing 4'/z" 12. 13Cr- 80 Vam Top 10,160 10,530 9,573' GL 9,624' / 8,626 Mud Program 6-'/8" Production Hole Mud Pro ert s FloPro-SF Interval Densi PV YP PH API Filtrate MBT 9,774'-13,152' Final Well TD 8.4-8.6 6-12 22-28 9.0-9.5 6-8 <3 Logging Program 6-'/8" Hole Section: Sample as required by well ~ e Geolo ist MWD / LWD: DIR/GR/RES O en Hole: None Cased Hole: None --- - ~a~' ~, Cement Program ..~----~~- Casin Size 4.5" 12.6#, 13CR-80 Production Liner Basis: Lead: None Tail: 3378' of open hole with 40% excess, 80' shoe trac 150' 4-Yz" x 6-1/8" liner lap, and 200' of 7" x 4" DP excess. Tail TOC: 9,424' MD (-200' above Liner Top) Total Cement Volume: Spacer 20 bbls of Mudpush II Weighted to 12 ppg Lead None Tail 87.9 bbls, 495 cuft, 423 sks 15.8 Ib/ al Class G + ad -1.17 cuft/sk Tem BHST = 203°F, BHCT = 137 °F Surface and Anti-Collision Issues Surface Shut-in Wells: There are no wells requiring surface shut-in in order to move onto the well. At surface, 12-12A the north and 12-11 to the south are nearest wells. Each are 60' from the planned spud location. Close Approach Shut-in Wells: Two wells will be shut-in in order to drill 12-37A. 01-13 and 12-21 in the production hole with the appro ches being 763' and 860' at 11,323' and 9,882' MD, respectively. Hydrogen Sulfide DS 12 is designated as an H2S site. Recent H2S data from the pad is as follows: Date of Well Name H2S Level Readin #1 Closest SHL Well H2S Level 12-11 NA 12-37A Permit to Drill Application Page 4 • Hydrogen Sulfide DS 12 is designated as an H2S site • Recent H2S data from the pad is as follows: Date of Well Name H2S Level Reading #1 Closest SHL Well H2S Level #2 Closest SHL Well H2S Level #1 Closest BHL Well H2S Level #2 Closest BHL Well H2S Level Max. Recorded H2S on Pad/Facility Other Relevant H2S Data 12-11 NA 12-12A 20 m 3/8/2008 1-30 NA 1-10 NA 12-03 300 10/7/2003 12-zz 300 siz i/zoos (H2S alarms from rigs, etc.) DS 12 is a HZS site • Faults The 12-37A wellpath is not expected to intersect any mapped faults. Well Control Well control equipment consisting of 5,000 psi working pressure pipe rams (2), blind shear rams, and annular preventer will be installed and are capable of handling the maximum potential surface pressures. Based upon calculations below, BOP equipment will be tested to 3,500 psi. BOP regular test frequency for 12-37A will be 14 days during drilling phase. Diverter, BOPE and drilling fluid system schematics on file with the AOGCC. Production Interval Maximum antici ated BHP 3262 si C~ 8800' TVDss 7.2 EMW Maximum surface ressure 2462 si .10 si/ft as radient to surface Kick tolerance Infinite with a 8.8 FIT Planned BOP test pressure Rams test to 3,500 psi/250 psi. Annular test to 2,500 si/250 si 9-5/8" Casin /7" Liner Test 3500 si surface ressure Inte rit Test - 6-1/8" hole 8.8 FIT after drillin 20' of new hole Planned com letion fluids 8.5 Seawater / 7.2 Diesel Disposal • No annular injection in this well. • Cuttings Handling: Cuttings generated from drilling operations will be hauled to grind and inject at DS-04. Any metal cuttings will be sent to the North Slope Borough. • Fluid Handling: Haul all drilling and completion fluids and other Class II wastes to DS-04 for injection. Haul all Class I waste to Pad 3 for disposal. 12-37A Permit to Drill Application Page 5 • Drilling Hazards and Contingencies POST THIS NOTICE IN THE DOGHOUSE I. Well Control A. The Sag in this fault block is expected to be under-pressured at 7.2 ppg EMW. This pressure is estimated based on offset well pressures. 3500 psi test pressure is in accordance with the RP for Prudhoe production well casing tests. II. Lost Circulation/Breathing A. The 12-37A is not expected to intersect any mapped faults. B. There have been no significant lost circulation events in the area. The loss events that have occurred usually are less than 100 bbls in total volume, with 01-30 being the largest volume lost. of 100 barrels. III. Kick Tolerance/Integrity Testing A. The Kick Tolerance for the production section infinite with planned mud weights. The FIT will prove up adequate formation strength for expected ECD's. B. Integrity Testing Test Point Test Depth Test e EMW (Ib/gal) 7" shoe 20-ft minimum from the 7" shoe FIT 8.8 minimum IV. Stuck Pipe A. Significant directional work will be required in the production hole section. Hole cleaning and differential sticking tendency will be of concern. Watch for signs of tight hole and short trip /back ream as required to avoid stuck pipe. VI. Hydrogen Sulfide A. DS-12 is designated as an H2S site; H2S levels of potentially lethal concentrations have been recorded on this pad. The maximum recorded on this pad is 300 ppm, both at 12-03 and 12-22 in 2003 and 2005, respectively. VII. Faults A. Little faulting is expected along the planned trajectory. See Section II on lost circulation for more details. VIII. Anti-Collision Issues B. There are no close approach issues with this well. ~-- CONSULT THE DS-12 DATA SHEET AND THE WELL PLAN. FOR ADDITIONAL INFORMATION 12-37A Permit to Drill Application Page Drillin~Hazards and Conting~Tfci POST THIS NOTICE IN THE DOGHOUSE I. Well Control A. The Sag in estimated I Prudhoe pi II. Lost fault block is expected to be under-pressured at 7.2 ppg EMW. This pressure is ion offset well pressures. 3500 psi test pressure is in accordance with the RP for l~n well casing tests. A. The 12-37A is not exp ted to intersect any mapped faults. B. There have been no sig icant lost circulation events in the area. The loss events that have occurred usually are less than 100 Is in total volume, with 01-30 being the largest volume lost of 100 barrels. Iii. Kick Tolerance/Integrity Tes g A. The Kick Tolerance for the pro tion section infinite with planned mud weights. The FIT will prove up adequate formation strength fore ected ECD's. B. Integrity Testing Test Point Test Depth Test t e EMW (lb/gal) T' shoe 20-ft minim from the 7" shoe FIT 8.8 minimum IV. Stuck Pipe A. Significant directional work will be required in the oduction hole section. Hole cleaning and differential sticking tendency will be of concern. Watch for sig of tight hole and short ~I~ s~ uired to avoid stuck pipe. ~~ ~~ VI. Hydrogen S e - "~~ A. - is designated as an H2S site; H2S levels of potentia lethal concentrations have been recorded on this pad. The maximum recorded on this pad is 300 ppm, th at 12-03 and 12-22 in 2003 and 2005, ~~ respectively. VII. Faults A. Little faulting is expected along the planned trajectory. See Section II' lost circulation for more details. `, VI11. Anti-Collision Issues B. Due to close approach concerns, two wells will be shut-in in order to drill 12- 01-13 and 12-21 in the production hole with the approaches being 763' and 860' at 11,323' and 9, 2' MD, respectively. CONSULT THE DS-12 DATA SHEET AND THE WELL PLAN FOR INFORMATION • 12-37A Permit to Drill Application Page 6 Operations Summary Current Condition and history: / 12-37A will be a sidetrack out of a newly drilled well. Ria Operations: 1. Continuing from the 12-37 PTD step #20. ~Q~~--~~~ 2. POOH, VD BHA. PU cement plug BHA. 3. RIH and la in cement lu .Circulate out excess cement at 7" shoe. POOH and LD cementin BHA. 4. RIH with Sag sidetrack BHA. Kick-off into Sag. 5. POH when directional work is complete. LD BHA. 6. PU horizontal BHA, RIH and drill to TD at 13,182' MD. 7. Condition the hole as required in preparation of running and cementing the 4-'/z" production liner. If necessary, spot liner running pill on bottom. POOH, VD excess 4" drill pipe, and VD BHA. 8. R/U and run the 4'/z", 12.6#, 13Cr-80, VamTop liner. CBU at 7" shoe and TD as necessary. Cement the liner per Dowell program. Release from the liner and set the packer. Circulate excess cement to \~~~ surface. 9. Displace the well to seawater above the liner top. POOH and inspect and VD liner running tools. ~~~ 10. After cement reaches a minimum 1000 psi compressive strength, R/U and pressure test the casing x liner string to 3,500psi for 30 minutes and record the test. 11. R/U and perforate well on drillpipe. 12. R/U and run a 4-'h", 12.6#, 13Cr-80, Vam Top completion w/ GLM's. Space and land the tubing with the tubing tail inserted into the liner tie back sleeve. RILDS. 13. Reverse circulate filtered seawater and corrosion inhibitor into the tubing x casing annulus. 14. Drop ball/rod and set liner top hanger/packer. 15. Individually test the tubing and annulus to 3,500 psi for 30 minutes and record each test. 16. Shear DCR valve. • 17. Install TWC and test. 18. N/D the BOPE. 19. N/U the adapter flange and tree. Test tree and adapter to 5,000 psi with diesel. 20. RU DSM. Pull TWC. 21. R/U circulating lines and test. Freeze-protect the tubing and annulus to 2,000' TVD and allow the diesel to U-tube to equilibrium. 22. Install a BPV and VR plugs in the annulus valves. 23. Secure, rig down and move off. Post-Riq Operations: 1. MI / RU slick line. Pull the ball and rod / RHC plug from landing nipple below the production packer. 2. Install gas lift valves. 3. Install the well house, instrumentation, and flow line. Estimated Pre-rig Start Date: 10/14/2008 Estimated Spud Date: 10/21/2008 r~ U 12-37 Permit to Drill Application Page 7 KB. ¢EV = ~ ~ ~ 59 BF. ELEV = 30.5 KOP= Max Angle = Datum MD = Datum TVD = 8800 • Proposed TOC • TREE = CNV 41!16 5M WELLHEAD = FMC Gen 5 CSG HEAD = 11 " SM VW T' MANDREL HANGER 8 PACKOFF TBG SPOOL = 11" X 11" 5M TBG HANGER = 11 " X 41 /7' ADPFLANGE= 11"X41/15' '80' 20', 215.5#, A-53, Insulated Conductor -2200' HES 4-1/2'X' Landing Nipple; ID= 3.813" 3,682' 9-5/8", 40 #/ft, L-80, BTC, ID = 8.835" GAS LIFT MANDRELS (41/7' x 1" KBMG) Propos d Completion 12-37A Minimum ID = 3.725" ~ 4-112" HES XN NIPPLE 4-1/7', 12.6#/11, 13 Chrome, VamTop, ID = 3.958" Ivishak ~~~~, Plugback ST MD TVD DEV TYPE VLV LATCH PORT DATE 4 DCK 2 S/O 3 DMY DMY z aunr oMY 1 DMY DMY ,484' HES 4-1 /2" X NIPPLE; I.D. 3.813' ,514' BAKER PKR 7" X 4-1/2' S-3, ID = 3.88", xx' TBS 544' HES 4-1 /2" X NIPPLE; IO = 3.813" x,574' HES 4-1/2" XN NIPPLE; ID = 3.725' 1624' 7° x 4-1 /2° Baker Flex-Loc Liner Hanger (ID =2.992") w/ ' ZXP Liner Top Pkr w/ 10' TBS (ID = 5.25") X774' 7", 26 #/ft, L-80, BTC-M (f/9,774'to 5000' MD) & TC-II (f/5000' to Surd, ID = 6.276" PERFORATION SUMMARY (TBD} REF LOG: (TBD) ANGLEAT TOP PERF: TBD @ TBD"YIJ Note: Refer to RoduStion ~ for historiSal pert data 3,002' 4-1/2" PBTD 3,162' 4-1/2", 12.6#, 13CR-80, VamTOP, ID = 3.958" DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHDE BAY UNIT TMP INITIAL WELL: DS 12-37 PERMIT No: API No: BP ~ploration (Alaska) OMPANY DETAILS BP Amucu ttp Iculation MethuJ. Minimum Curvature Ertur System: ISCWSA Scan McihoJ. Trav CylinJcr North Ertor Sur(acc: EIIip6cal + Casing CASING DETAILS No. TVD MD Name Size I 8634.00 1315 L82 4 1/Z" 4.500 HALLIBURTON perry drilling Services REFERENCE INFORMATION Co-ordinate (N/E) Re(crenec Wcll Centre: 12-37 Plan, True Nonh Vcnical ITVD) Rclbrcncc: 41'GL+'_%.5=695 69.00 Section lA'S) Rcli•ranec. Slut - Io.I)ON,OAOE) Mcawral Ucpih liclcrcncr JI'GI ~'f.S=G95 69.W C:d.ul.u ion .Method. ~Lnumim ('unaturc SURVEY PROGRAM Fm DcpihTo Sunny/Plan Tuul Plan:l2-37 WP 5.0 (12-37PIan/12-37 Plan) r(1 13151.%2 Planned: 1?-37 WP S.0 V25 MWD+IFR+MS Crrca[ed By: Sperry Drilling Dale: 5/30/2008 WELL DETAILS Name +N/-S +E/-W Nunhing Easting Latitude LongituJe Sbt 12-37 Plan -14%1.41 -1142.76 5931140.11 (196%63.34 70°12'57.%91N 14%°24'43.067W N/A Scc MD Inc Azi TVD +N/-S +E/-W DLcg TFacc VScc Targc[ I 9715.00 47.00 (IAO 8688.77 3906.56 -488.02 OAO 0.00 3726.16 2 9735.00 49.40 0.(10 8702.10 3921.47 -488.02 12.00 0.00 3740.76 3 9965.09 90.00 351.00 8780.41 4131.68 -506.85 18.00 346.32 3942.78 4 10048.42 105.00 351.00 8769.57 4213.06 -519.73 ISAO 0.00 4019.84 5 10198.42 IOSAO 3iL00 8730.74 4356.16 -542.40 0.00 0.00 4155.36 6 10311.80 90.00 SAO 8715.91 4467.90 -546.06 18A0 136.07 4264.03 7 10542.28 90.90 46.48 8714A2 4671.00 -448.15 18A0 88.64 4482.78 8 11729.61 90.90 46.48 8695.34 5488.53 412.69 0.00 0.00 5458.03 9 l 1772A9 92.70 49.36 8694.00 5516.98 44410 8.00 57.98 5492?8 12-37 D TI 10 12408.62 92.70 49.36 8664A(1 593L07 926.69 0.00 0.00 5995.70 12-37 Cont T2 rev I I1 12698.15 9211 31.98 8651.50 6)49.62 1114.48 6A0 -91.23 6247.82 12 131 ~ 1.82 9211 31.98 8634.00 6534.15 1354.59 OAO 0.00 6673.08 12-37 Cunt T3 Rcv 2 c 0 0 i 6 U 7 U 2 F TARGET DETAILS ! li_~ - _~ 1 Name TVD +N/-S +E/-W Northing Easting Shape 12-37 Con[ T3 Rev 1 8617.00 6534.15 1354.59 5937707.OU 698047.00 Point 12-37 Cont T3 Rcv 2 8634.00 6534.15 1354.59 5937707.00 698047AU Point 12-37 Cont T3 8639.00 6534.15 1354.59 5937707.0(1 698(147.00 Point 12-37 ContT2 8644.00 5931.07 926.69 5937093.00 697635.U0 Point 12-37 Cont T2rcv I 8664.00 5931.07 926.69 5937093.00 697635A0 Point SiUO 6000 12-37DT1 8694A0 SS 16.98 44410 5936666A9 697163.50 Point 12-21 1000' Target 8713.00 4175.29 354.68 5935323A0 697109.00 Circle (Radius: 1000) Vertical Section at 11.71 ° [SOOft/in] ir~ 12-371P6) Proposal Schlumberger Report Date: September 30, 2008 Survey 1 DLS Computation Method: Minimum Curvature / Lubinski Client: BP Exploration Alaska Vertical Section Azimuth: 35.530° Field: Structure 1 Slot: Prudhoe Bay Unit- EOA DS-12 112-37 M ~~ VeAical Sedion Origin: ~ TVD Reference Datum: N 0.000 ft, E 0.000 ft Rotary Table Well: ~ f ~~ Plan 12-37 TVD Reference Elevation: 67.60 ft relative to MSL Borehde: ~; ~ Plan 12-37 ~~a Sea Bed 1 Ground Level Elevation: 39.10 ft relative to MSL UWIIAPI#: 50029 Magnetic Declination: 23.066° Survey Name 1 Date: 12-37 (P6) I September 30, 2008 Total Field Strength: 57692.588 nT Tort 1 AHD 1 DDI I ERD ratio: 197.569° l 7369.96 ft 16.33810.838 Magnetic Dip: 80.688° Grid Coordinate System: NAD27 Alaska State Planes, Zone 04, US Feet Dedination Date: November 10, 2008 location LaULong: N 70.21608164, W 148.41197563 Magnetic Dedination Model: BGGM 2008 Location Grid NIE YIX: N 5931140.330 ftUS, E 696861.770 ftUS North Reference: True North Grid Convergence Angle: +1.49433645° Toted Carr Mag North -> True North: +23.066° Grid Seale Fedor: 0.99994403 Local Coordinates Referenced To: Well Head L` Comments Measured Indination Azimuth Sub-Sea 7VD TVD Vertical NS EW Mag 1 Grav DLS Directional Northing Easting Latkude Longitude Depth Sedion Tod Face Difficulty k d d k ff k ff ff de d 100 ff Index ffUS ffUS eoc ow uc n nn Sao SO'3Sn7a a7 a0a979 n~ N 7n 99RR7QQ'I w 1dR d15Andn7 KVY GN ZD/"IUU y///. uu yr. uv v.u4 oow.co o~av.oo caao. iv .ao.,c. ~, -~~... ..~ .~., ... .... .,..... __"__. _. _. ____. _. __ .-.^ __""'. .._. .."'.-" 9800. 00 52. 75 0.00 8678.06 8745.66 2948. 06 3970. 19 -486. 84 HS 25. 00 5.43 5935096. 24 696271. 59 N 70. 22692793 W 148.41590408 TSHU 9801. 55 53. 14 0.00 8879.00 8748.60 2949. 07 3971. 43 -486. 84 HS 25. 00 5.44 5935097. 48 696271. 56 N 70.22693132 W 148.41590408 9850. 00 65 .25 0.00 8703.76 :8771.36 2982. 87 4012. 96 -486. 84 HS 25. 00 5.52 5935139. 00 696270. 48 N 70. 22704479 W 148.41590410 9900. 00 77 .75 0.00 8719.60 8787.20 3021. 39 4060. 28 -486. 84 HS 25. 00 5.60 5935186. 30 696269. 24 N 70. 22717407 W 148.41590412 90° Pt 9949. 00 90. 00 0.00 8724.82 8792.42 3060. 96 4108. 91 -486. 84 HS 25. 00 5.66 5935234. 91 696267. 98 N 70.22730692 W 148.41590415 9950. 00 90 .25 0.00 8724.81 8792.41 3061. 77 4109 .91 -486. 84 HS 25. 00 5.66 5935235. 91 696267. 95 N 70. 22730965 W 148.41590415 Crv 10/100 9985. 00 99 .00 0.00 8721.99 8789.59 3090. 14 4144 .76 -486. 84 HS 25. 00 5.71 5935270 .75 696267. 04 N 70. 22740487 W 148.41590417 10000. 00 100 .50 0.00 8719.45 8787.05 3102. 17 4159 .54 -486. 84 HS 10. 00 5.71 5935285 .52 696266. 66 N 70. 22744525 W 148.41590417 10050. 00 105 .50 0.00 8708.21 8775.81 3141. 80 4208 .25 -486. 84 HS 10. 00 5.74 5935334 .21 696265. 39 N 70. 22757831 W 148.41590420 EOC 10065. 00 107 .00 0.00 8704.01 8771.61 3153. 52 4222 .65 -486. 84 --- 10. 00 5.75 5935348 .60 696265. 01 N 70. 22761765 W 148.415904 KOP 10165. 00 107 .00 0.00 8674.78 8742.38 3231. 35 4318 .28 -486. 84 LS 0. 00 5.77 5935444 .19 696262. 52 N 70. 2 22787890 W 148.4159042 10200. 00 103 .50 0.00 8665.57 8733.17 3258. 82 4352 .04 -486. 84 LS 10. 00 5.78 5935477 .94 696261. 64 N 70. 22797114 W 148.41590427 10250. 00 98 .50 0.00 8656.03 8723.63 3298. 75 4401 .11 -486. 84 LS 10. 00 5.81 5935526 .99 696260. 36 N 70. 22810519 W 148.41590430 10300 .00 93 .50 0.00 8650.81 8718.41 3339. 21 4450 .82 -486. 84 LS 10 .00 5.83 5935576 .68 696259. 06 N 70. 22824099 W 148.41590432 Crv 10/100 10323 .00 91 .20 0.00 8649.87 8717.47 3357. 91 4473 .80 -486 .84 89.82R 10 .00 5.84 5935599 .65 696258 .46 N 70. 22830377 W 148.41590433 10350 .00 91 .21 2.70 8649.30 8716.90 3380. 24 4500 .78 -486 .20 89.SSR 10 .00 5.86 5935626 .64 696258 .39 N 70. 22837749 W 148.41589921 10400 .00 91 .21 7.70 8648.24 8715.84 3423. 37 4550 .55 -481 .67 89.98R 10 .00 5.88 5935676 .50 696261 .62 N 70. 22851345 W 148.41586268 10450 .00 91 .21 12.70 8647.18 8714.78 3468. 54 4599 .73 -472 .82 90.09R 10 .00 5.90 5935725 .90 696269 .19 N 70. 22864782 W 148.41579127 10500 .00 91 .20 17.70 8646.13 8713.73 3515. 40 4647 .95 -459 .72 90.19R 10 .00 5.92 5935774 .45 696281 .03 N 70. 22877956 W 148.41568554 10550 .00 91 .18 22.70 8645.10 8712.70 3563. 60 4694 .85 -442 .46 90.30R 10 .00 5.95 5935821 .78 696297 .06 N 70. 22890769 W 148.41554627 10600 .00 91 .15 27.71 8644.08 8711.68 3612. 76 4740 .07 -421 .18 90.40R 10 .00 5.97 5935867 .53 696317 .16 N 70. 22903122 W 148.41537455 WeltDesign Ver SP 2.1 Bld( doc40x 100) 12-37\Plan 12-37\Plan 12-37\12-37 (P6) Generated 9/30/2008 3:33 PM Page 1 of 2 Comments Measured Inclination Azimuth Sub-Sea TVD ND Vertical NS EW Mag 1 Grav DLS Directional Northing Easting Latitude Longitude Depth Section Tod Face Difficulty n .____ __ d -. .. d ~~ ~. k -~.- .- n -~.~ ~.. k ........ ~.. n .-..... ww n nnw nn d nn cne~ d 1100 k An nn Index c nn nUS cnncn~A nc kUS n_nc~n AA AG AI ~n .f.f[f~An.fA IAI SAO A1C~~~GG 1 Ut)~U.VV `Jl.ll 3L./l 8043.1U 8/lV./U 3000AC 9/OJ.co -ooo.vo av. avrt ~u.uv o.aa a, ,.av vavo-. ,.w - , . i~~.t ,..,, ivv 10700.00 91.06 37.71 8642.15 8709.75 3712.50 4824.09 -367.22 90. 59R 10.00 6.01 5935952.92 696368.90 N 70.22926077 W 148.41493915 10750.00 91.00 42.71 8641.25 8708.85 3762.31 4862.26 -334.96 90. 68R 10.00 6.03 5935991.92 696400.15 N 70.22936505 W 148.41467880 10800.00 90.94 47.71 8640.41 8708.01 3811.57 4897.47 -299.49 90. 77R 10.00 6.04 5936028.04 696434.69 N 70.22946124 W 148.41439258 End Crv 10826.44 90.90 50.35 8639.98 8707.58 3837.28 4914.80 -279.53 -- 10.00 6.05 5936045.88 696454.19 N 70.22950860 W 148.41423150 Crv 6/100 11754.18 90.90 50.35 8625.35 8692.95 4734.03 5506.68 434.72 3. 68R 0.00 6.16 5936656.16 697152.72 N 70.23112557 W 148.40846696 12-37 Tgt 1 11769.15 91.80 50.41 8625.00 8692.60 4748.50 5516.23 446.25 3. 74R 6.00 6.17 5936666.00 697164.00 N 70.23115164 W 148.40837389 End Crv 11784.83 92.74 50.47 8624.38 8691.98 4763.64 5526.21 458.33 --- 6.00 6.17 5936676.29 697175.81 N 70.23117890 W 148.40827640 Crv 6/100 12248.48 92.74 50.47 8602.23 8669.83 5211.10 5820.97 815.54 91 .23E 0.00 6.22 5936980.24 697525.19 N 70.23198408 W 148.40539311 12250.00 92.74 50.38 8602.15 8669.75 5212.57 5821.93 816.71 91 .23E 6.00 6.22 5936981.24 697526.34 N 70.23198672 W 148.40538367 12300.00 92.67 47.38 8599.79 8667.39 5261.16 5854.77 854.33 91 .37E 6.00 6.23 5937015.05 697563.09 N 70.23207643 W 148.4050800 12350.00 92.59 44.38 8597.50 8665.10 5310.29 5889.54 890.18 91 .51 L 6.00 6.25 5937050.74 697598.01 0 N 70.23217141 W 148.40479061 12400.00 92.51 41.37 8595.27 8662.87 5359.82 5926.15 924.16 91 .64E 6.00 6.26 5937088.22 697631.03 N 70.23227139 W 148.40451629 12-37 Tgt 2 12406.22 92.50 41.00 8595.00 8662.60 5366.01 5930.82 928.25 91 .68E 6.00 6.26 5937093.00 697635.00 N 70.23228417 W 148.40448323 12450.00 92.42 38.37 8593.12 8660.72 5409.63 5964.48 956.18 91 .79E 6.00 6.27 5937127.37 697662.04 N 70.23237610 W 148.40425779 12500.00 92.32 35.37 8591.05 8658.65 5459.56 6004.44 986.15 91 .91E 6.00 6.28 5937168.09 697690.96 N 70.23248526 W 148.40401583 End Crv 12507.12 92.31 34.94 8590.76 8658.36 5466.68 6010.25 990.25 -- 6.00 6.28 5937174.01 697694.90 N 70.23250115 W 148.40398276 TD 13146.46 92.31 34.94 8565.00 8632.60 6105.47 6533.91 1356.15 - 0.00 6.35 5937707.00 698047.00 N 70.23393158 W 148.40102861 Legal Description: Northing (Yl fftUSl Eastina (X) fftUSl Surface : 828 FSL 738 FEL S18 T10N R15E UM 5931140.33 696861.77 12-37 Tgt 1 : 1064 FSL 272 FEL S7 T10N R15E UM 5936666.00 697164.00 12-37 Tgt 2 : 1479 FSL 5068 FEL S8 T10N R15E UM 5937093.00 697635.00 TD / BHL : 2082 FSL 4638 FEL S8 T10N R15E UM 5937707.00 698047.00 `~ u WeIlDesign Ver SP 2.1 Bld(doc40x 100) 12-37\Plan 12-37\Plan 12-37\12-37 (P6) Generated 9/30/2008 3:33 PM Page 2 of 2 by Schiumberger ~" 12-37 (P6) FlELD Prudhoe Bay Unit - EOA 51R1G1~ DS-12 Ma8m8c Paramsbrs 6vlaca LocaBOn N6D2] ~laslu 6tale Rams, Zan.Oa. u8 FM 6bc Wrrwaa 6bW RGG613008 Oq 80.888' DMa Nowmpw 10. 2006 It N)0125].Bea NaMap 59311aa.33 hU5 Grtl Cam: v1.a8a30616' Bla1. 12-0) TW RSI RwrvtaW 16].6011 aEOVa M6L1 a6p 0.c °23068' F6 6)682.8 nT Lm: W1aB 2a 0.3.112 EaaWq 6BB6GI.T/6U5 Scab FM. 0.898wa0262 Ran: 12-J]fP8) Srvy Deta 6eParn0ai 30. 2006 ~ 2800 3200 3600 4000 4400 4800 5200 5600 6000 8400 O O 8800 _Np U 9200 -37P81 (PB) crv 7a700 KOP Crv 251700 50° Pt 7- c69 crv 1a1oo End Crv Crv 10/100 237P81(Po) End 12-J7 T0t 1 12-J7 T0t 2 End Crv Crv 6/100 I End Crv Crv 61100 1 1 72-37 (P8) 2800 3200 3600 4000 4400 4800 5200 5600 6000 Vertical Section (ft) Azim = 35.53°, Scale = 1(in):400(ft) Origin = 0 N/-S, 0 E/-V 8400 8800 9200 - bp Schlumberger wru HELD snxucTUaE 12-37 (P6) Prudhoe Bay Unit - EOA DS-12 Mewls Penn-Nre 6urlaw L6wibn NaDi) Playa Stab Pdwa.lwe 01. US Fed Mbwldrboua MoEN: 6GGM 20w Oip: 60 G66' 0.1s N6vam6sr 10, 1006 Lal' N)0126)e9a Non6ag 69JI Ia03]RUS GN COm ~1 a9aJJ6a6' 6bt 11~J) NDRd RWary Tads (b)BORaEPVe M6LI Map 0.c. •2]066• F6. 616926 nT Wta6la aJ.l11 Eaa9lq b9666t ))RU6 bwb Fad:099991a0261 Pbn. 12-J)(P6) 6rvy DMa. saplemMr b.1006 -400 0 400 800 1200 6400 6000 5600 n n n Z O 0 a c 5200 d m U V V V 4800 4400 4000 to 237 (PO) ?v End Crv 12-37 Tgf 2 Crv 6/100 Entl Crv ua7 rp ~ crv MtoO End Crv Crv 10/700 12-37P81 (P8) crv ~m~ao End Crv Crv 10/100 90° PI NOP Crv 26N 00 7" Csy P -aoo o aoo aoo lzoo «< W Scale = 1(in):400(ft) E »> 6400 6000 5600 5200 4800 4400 4000 • BP Alaska Anticollision Report • Company: BP Amoco Date: 9/30/2008 Time: 16:04:47 Page: 1 Field: Prudhoe Bay Reference Site: PB DS 12 Ca-ordinate(NE) Reference: Welt Plan 12-37, True North Reference Well: Plan 12-37 Vertical (TVD) Refere nce: 12-37 Plan 67.6 Reference Welipath: 12-37 Plan Db: Oracle GLOBAL SCAN APPLIED: All wellpaths within 200'+ 100/1000 of reference -There are 1[~fAlilleeells in thisRlilWpal Plan 8~ PLANNED PROGRAM Interpolation Method: MD Interval: 5.00 ft Error Model: ISCWSA Ellipse Depth Range: 9777.00 to 13 146.46 ft Scan Method: Trav Cylinder North Maximum Radius: 1511.80 ft Error Surface: Ellipse + Casing ~ Survey Program for Definitive Welipath Date: 9/30/2008 Validated: No Version: 1 Planned From To Survey Toolcode Tool Name ft ft - - - - -- I -- ! 28.50 500.00 Planned: Plan #& 12-37PB1 V1 ( GYD-GC-SS Gyrodata gyro single shots I 500.00 3620:00 Planned: Plan #6 12-37P61 V1 ( MWD+IFR+MS MWD + tFR + Multi Station !, ', 3620.00 9710.00 Planned: Plan #6 12-37P61 V1 ( MWD+IFR+MS MWD +IFR + Multi Station 9710.00 9777.00 Planned: Plan #6 12-37P61 V1 ( MWD+IFR+MS MWD +IFR + Multi Station 9777.00 13146.46 Planned: Plan #6 12-37 V2 MWD+IFR+MS MWD + 1FR + Multi Station Casing Points MD TVD Diameter Hole Size Name ft ft in in !~ 4233.93 3967.60 _ .......9.625 12.250 9 5/8" 9772.24 8727.60 7.000 8.500 7" 13146.46 8632.60 4.500 6.125 4-1/2" Summary _ ~~ Offset Welipath ~ -- _ Reference Offset Ctr-Gtr No-Go Allowable _ Site Well Welipath MD MD Distance Area Deviation Warning ft ft ft ft ft - ~ __ -- - r I PB DS 01 01-05 Plan Cont 01-056 V7 PI _- - 12720.19 15056.43 --- 1174.29 172.66 1001.63 ~. Pass: Major Risk ~ I PB DS 01 01-10 01-10 V2 12834.85 9215.00 831.87 296.88 534.99 Pass: Major Risk ~! PB DS 01 01-13 01-13 V2 11251.17 9985.00 732.46 602.42 130.04 Pass: Major Risk PB DS 01 01-18 01-18 V9 10250.00 9455.00 1465.57 313.72 1151.85 Pass: Major Risk ', PB DS 01 01-30 01-30 V1 13146.39 9070.00 811.84 390.78 421.06 Pass: Major Risk ! ', PB DS 01 01-30 Plan 01-30a V3 Plan: 0 13146.39 9060.00 811.84 388.30 423.54 i Pass: Major Risk PB DS 12 12-09 12-D9 V1 Out of range PB DS 12 12-10 12-10 V1 Out of range PB DS 12 12-10A 12-10A V3 Out of range PB DS 12 PB DS 12 12-11 12-11 12-11 V1 Plan 12-11A V1 Plan: P Out of range Out of range PB DS 12 12-12 12-12 V3 Out of range PB DS 12 12-12 12-12A V6 10023.83 10060.00 775.12 170.00 605.13 Pass: Major Risk ~I PB DS 12 12-13 12-13 V7 Out of range !~ PB DS 12 12-13 12-13A V6 Out of range ! PB DS 12 12-13 12-136 V6 Out of range PB DS 12 12-13 12-13BP61 V5 Out of range !, PB DS 12 12-13 12-13BPB2 V10 Out of range PB DS 12 t2-20 12-20 V7 10137.69 10440.00 1201.29 185.63 1015.66 Pass: Major Risk PB DS 12 12-20 12-20A V17 9778.78 10455.00 1484.79 174.71 1310.07 Pass: Major Risk PB DS 12 12-21 12-21 V1 10050.65 9825.00. 853.74 605.08 248.66 Pass: Major Risk i L PB DS 12 Plan 12-37 Plan 12-37P61 V2 Plan: 9780.00 9780.00 0.02 123.87 -123.85 FAIL: Major Risk FieldPrudhoe Bay SitePB DS 12 We11:Plan 12-37 Wellpathx2-37 Plan 393 300 200 100 o ~ 100 200 300 L313 0 Travelling Cylinder Azimuth (TFO+AZI) [deg] vs Centre ,- - --- From Surface - TD ,Scan interval 100 ft Scale 1:100 -- - -- ~ 12-37A PTD Maunder, Thomas E (DC1A) Page 1 of 1 From: Peltier, Travis M [Travis.Peltier@bp.com] Sent: Thursday, October 23, 2008 1:06 PM To: Maunder, Thomas E (DOA) Cc: Hobbs, Greg S (ANC); Smith, Phil G (ASRC); Tirpack, Robert B Subject: 12-37A PTD Attachments: 12-37 (P6) report.pdf; 12-37_P6_export_file.txt; 12-37A PTD October 22_0$ update.doc Tom, Thanks for the phone call. As per your request, here is the updated 12-37A PTD pages that reflect that we have NO AC issues in this 6-1/8" weltbore as well as the Anadrill Directional Plan. Thanks again, and I will keep you informed of 01-18's status as well. -Travis Peltier GPB Rotary Drilling (907)564-4511 «12-37 (P6) report.pdf» «12-37_P6_export_file.txt» «12-37A PTD October 22_08 update.doc» 10/23/2008 • • Maunder, Thomas E (D®A) From: Peltier, Travis M [Travis.Peltier@bp.com] Sent: Wednesday, October 08, 2008 8:43 AM To: Maunder, Thomas E (DOA) Cc: Hobbs, Greg S (ANC) Subject: RE: DS 12-37 Tom, Thank you for find this. Yes, H is a missed edit. It should read DS 12. It will read incorrectly as H-pad as well on the 12-37A PTD. -T From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov] Sent: Wednesday, October 08, 2008 8:29 AM To: Peltier, Travis M Cc: Hobbs, Greg S (ANC) Subject: RE: DS 12-37 Travis, I am completing my review of the 12-37 - Ivishak penetration. On the Drilling Hazards sheet regarding H2S, it say "H Pad" although the wells listed are on D~12. Was the "H" a missed edit? Thanks, Tom Maunder, PE `AOGCC From: Peltier, Travis M [mailto:Travis.Peltier@bp.com] Sent: Monday, October 06, 2008 4:15 PM To: Maunder, Thomas E (DOA) Cc: Hobbs, Greg S (ANC); Smith, Phil G (ASRC); Hubble, Terrie L; Smith, Chasity R (DOA) Subject: RE: DS 12-37 Tom, FY1, they should be there tomorrow. -T From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov] Sent: Monday, October 06, 2008 3:13 PM To: Peltier, Travis M Cc: Hobbs, Greg S (ANC); Smith, Phil G (ASRC); Hubble, Terrie L; Smith, Chasity R (DOA) Subject: RE: DS 12-37 Travis, et al, I have checked around over here and so far as I can determine, we have not received the new information. Our receptionist was anticipating receiving new information, but she hasn't seen anything. It is probably appropriate to resend the document. Thanks, 10/8/2008 ks., ~ ~ a • ~ Tarn Maunder, Pi^ AOGCC From: Peltier, Travis M [mailto:Travis.Peltier@bp.com] Sent: Monday, October 06, 2008 2:17 PM To: Maunder, Thomas E (DOA) Cc: Hobbs, Greg S (ANC); Smith, Phil G (ASRC) Subject: RE: DS 12-37 Tom, I saw that the signed PTD's and Sundry went out to you on October 2 for 12-37 and 12-37A. I was wondering when I would know of any reviews or approvals since our planned spud is in about 12 - 15 days. -T From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov] Sent: Thursday, September 25, 2008 5:18 AM To: Peltier, Travis M; Hobbs, Greg S (ANC) Cc: Saltmarsh, Arthur C (DOA); Davies, Stephen F (DOA) Subject: RE: DS 12-37 Travis, That is correct. The key document is the Ivishak hole PTD. #2 I'd say is the Sag horizontal. The sundry can wait a little until you have the specifics. As long as everyone knows the process, then there shouldn't be any bumps in the road. Call or message with any questions. Tom Maunder, PE AOGCC From: Peltier, Travis M [mailto:Travis.Peltier@bp.com] Sent: Wednesday, September 24, 2008 4:17 PM To: Maunder, Thomas E (DOA); Hobbs, Greg S (ANC) Cc: Saltmarsh, Arthur C (DOA); Davies, Stephen F (DOA) Subject: RE: DS 12-37 Tom, Thanks for the clarification. Just to summarize what I am reading, I will need to do the following things: 1) Send in a new PTD for 12-37, detailing the Ivishak hole 2) Send in a Sundry to plug and abandon this hole (50% chance according to the reservoir engineer) 3) Send in a PTD for 12-37A, detailing the Sag horizontal. Outcome: If we end up completing the Ivishak, the P&A Sundry and 12-37A PTD will eventually expire. If we end up P&A'ing 12-37, then we have all of the paperwork in place to procede with drilling the Sag river formation. Thanks, and let me knotiv if f have things stated correctly. If so, I will get new PTD's and Sundry out to you ASAP. -T From: Maunder, Thomas E (DOA) [maiito:tom.maunder@alaska.gov] Sent: Wednesday, September 24, 2008 2:08 PM 10/8/2008 • • To: Peltier, Travis M; Hobbs, Greg S {ANC) Cc: Saltmarsh, Arthur C (DOA); Davies, Stephen F (DOA) Subject: RE: DS 12-37 Travis and t3reg, ! have spoken with my colleague Steve over here regarding the intent for this well. The application presently in house is permitted for a Sag [3HL with an Ivishak picot hole, not. a well with a completed Ivishak. 8Ht_.. If there is the possibility that tine well will be completed as an Ivishak weir.; there that is the permit the well should: be spudded with. If the Ivishak BHt_ is not productive, then the Sag BHL would be drilled as 12-37A. Anyway;. what that gets. us to is that it wilt be necessary to submit a new PTD for the Ivishak BHL, We will. treat that application as a replacement for ttte p~rckage presently irr house. If you expect the Ivishak 13HL to likely be plugged, then you: should sub-mit another ap~atscation fior the Sag SHL 12-37A.. A sundry would be needed. for the plugging, however f don't tieiieve there will tae any issues with that. Sorry about the pape~-wark hassle, however it can get problematic.. when the permitted 8HL winds up not. getting dritle~i: and the rr~pletad SNL is, irr a deeper fdrmt~tion. Colt or mes.~ge v+aittr any q;uestions.. Torn Maunder. €~~~ AOGCC From: Peltier, Travis M [mailto:Travis.Peltier@bp.com] Sent: Wednesday, September 24, 2008 9:02 AM To: Maunder, Thomas E (DOA) Cc: Hobbs, Greg S (ANC) Subject: RE: DS 12-37 Tom, I would expect our spud date to be around the 21st of October. -T From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov] Sent: Wednesday, September 24, 2008 8:41 AM To: Peltier, Travis M Cc: Hobbs, Greg S (ANC) Subject: RE: DS 12-37 Travis, Thanks for ulad..~ting the nrrrnber's, t wondered about the 8-112" versus 8-314" Note sia:es, but es you point~'~d out. 8- 1 " ~ti~as tlY~'~~u~tr€3;.~~t tl~e d~sr:Lrr~t. I w'sl3 s#ili' hay*e to sps~a,l~ w*ttr Stoma;e 33av+es sa*~ tae Ix~lo# bale k~eeps:r/versus pl,.rc3 t~a~k. Whea~r a~ sp4Ad planrreri~~ Torre Maunder, PC AC/~ CC From: Peltier, Travis M [mailto:Travis.Peltier@bp.com] Sent: Wednesday, September 24, 2008 8:33 AM To: Maunder, Thomas E (DOA) Cc: Hobbs, Greg S (ANC) Subject: RE: DS 12-37 Tom, Thanks for catching this, and Im sorry I made a large error. The intermediate hole size should be 8-3/4" rather than 8-1/2". Checking the volumes, they are all correct for 8-3/4". What is incorrect are all of the places where state 8-1/2" in the Permit to Drill rather than 8-3/4". I have changed them all in the attached document. The lead section in the 8-3/4" is LiteCrete, with a 2.45 cu. ft. / sk. The correct number of sks for the lead is --369 and 10/8/2008 • • should be stated that way on page 5. Unless it is misstated some~Nhere else, the number is correct. The tail volume for the surface section includes a 6 bbl volume for the shoe tract section. T#~is adds another 30 sks to the 188 sks required for the open hole for a total of 218 sks. In regards to the pilot hole, should I submit another PTD to you before we drill that section or should I just keep you updated on our progress? t know not a lot of welts like this are drilled, but there do seem to be a few that pop-up every year, Thanks again for the help and catching my errors. -Travis Peltier (907)564-4511 From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov] Sent: Friday, September 19, 2008 2:18 PM To: Peltier, Travis M , Cc: Hobbs, Greg S (ANC) Subject: DS 12-37 Travis, I am reviewing the permit application for this well. Would you please check the 7" cement calculations? You state that the tail should cover 1000' with 40% XS. I calculate the necessary volume (for 8.5" x 7") to be 31.6 bbls rather than the 40.5 bbls you have planned. For the lead, I calculate the necessary length as 9774-1000-800- 3683 = 4291'. The gage volume calculates to be 96.9 bbls. Adding 40% XS gives 135.6 bbls which requires 310 sx as opposed to the 196 sx planned. I believe the liner calculation is OK, but I also did a quick calculation of the surface tail and I would calculate the necessary sx fora 500' column with 40% XS (for 12.25" x 9.625") as 188 sx. Also, I need to look into how this well may evolve. If the pilot hole proves to be "a keeper", the a new permit may be necessary. I need to speak with Steve Davies next week. The permit as written is appropriate if the pilot hole is plugged back and the horizontal section drilled. Thanks in advance. Call or message with any questions. Tom Maunder, PE AOGCC 10/8/2008 __ __ Alaska Department of Natural Resources Land Administration System Page 1 of 2 • ~:I~ ~ ~ ~ ~~r,s~~ .~ ~ ... .. -=~;.;i ~ .:;;~c~rder`s C~arch Stale Cabins ~1~#u ~ S~l9C~S A1a~ka DAR ~~s~ urnmar~ File Type: ADL File Number: 28329 ~ ~ Printable Case File_Summary See Township, Range, Section and Acreage? New Search ~' Yes ~' No ~_ _ _. ___ ___ ~- t_AS nller~[~ i Case Abstract ~ Gase Detail ~ Land Abstract ~~. File: aDL 28329 '~ Searcn for Status flat l~~dates Custonzef~~ 000107377 BP EXPLORATION (ALASKA) INC PO BOX 196612/900 E. BENSON BL ATTN: LAND MANAGER- ALASKA ANCHORAGE AK 995196612 Corse. Type: ~~~ OIL & GAS LEASE COMP DNR Unit: 780 OIL AND GAS Fde .Locution: DOG D[V OIL AND GAS Case Stcrtzss: ~5 ISSUED ~Statr,rs Date: 09/14/1965 TotulAcres: 2501.000 Date Initiated: 05/28/1965 Office of P~~irrzary kesponsibidity: DOG DIV OIL AND GAS Last Ti-ansac°tion Date: 12/04/2006 Case Subr}pe: f~=~ NORTH SLOPE Last Transaction: AA-NRB ASSIGNMENT APPROVED 1Ic~~~r~linn.~ l_! 7nititsli~j~- U I (liV~ Kcrri~~: O l ~E Sc~~uun: (l, P1.~f , ll~rl~/,ian: U 7(~~rjr_s~hi~~.~ O1(1V' 1('r~r~~~>: U I~i, .ti'c~~°tinir.~ Ub ll~'rulian: U I ~ncrt.~'{uJ~: U 10N h'cui,re.~ I l I~ I; Scclrnit.~ (!- ll~~i^idian: U ToK~i~~hi/~: U I l~N Ru~t~~r.~ (11 ~I~: Se~~~inn: (i8 Lcgat Descripti~u 0~-z8-196 ~ ~`*SAI,F_ ,VOTIC'E LEGAL DE~SC'RIPTIO~~'* `* C'1-~-1 ~9 TIO1V-R1 ~1'-UNI ~, 6, ?, ~~ 201.00 U- 3- ~ ~ ~l '/ ~'~~~iinn Ac~~~~s: ((40 Se~~;rci~ S'~~c~~run A~~r~~s: (,40 Last updated on 10/22/2008. http://www.dnr.state.ak.us/las/Case_Summary.cfm?FileType=ADL&FileNumber=28329... 10/22/2008 Alaska Department of Natural Resources Land Administration System . Page 1 of 2 • ., ~ -.~~ ~ r.j ,.,~-~~ :.; "_ . ~- .,ta'~i 4~'ui~ ~ec~rc:er'~ search Stag Cabins ~i1~tE~ is~o~urc:es t~ 5 File Type: AFL _ ~ File Number: 28330 ~ Printable Case File_Summ...ary See Township, Range, Section and Acreage? _ ! New Search J ~` Yes ~`; No _._~..._ ~._ - _... !_aS ittier~r !Case Abstract I Case Detail I Land Abstract ~. File: ADL ?8330 ~''~' S~.~ruh for Stz~tus €'!at U~~at~s Customer: 000107377 BP EXPLORATION (ALASKA) INC PO BOX 196612/900 E. BENSON BL ATTN: LAND MANAGER- ALASKA ANCHORAGE AK 995196612 Case Ty~~e: ~~ OIL & GAS LEASE COMP DNR I~i7it.~ 780 OIL AND GAS File Locatzon: DOG DN OIL AND GAS Case ,4tutus: 3.5 ISSUED Status Date: 08/ 1)/ 1965 Total Acres: 2512.000 Date Initiated: 0/28/1965 Office of Primcny ResTonsibility: DOG DIV OIL AND GAS Last Transaction Dcrte: 12/04/200b Case Subtyj~e : ~~S NORTH SLOPE Last Transaction: AA-NRB ASSIGNMENT APPROVED Ih~i~rc/tu~r: l_ I %~,,,~rtc{u~~ U i O\~ l~~nr;;~~: Ol ~E Section: I7 Section ~cre.~.~ f~-~U Search J~~ar~ _l~c'Y7~/Iclll.~ i_~ ~Ull'71.1'~1f~): ~)~~)~' ~i(7i7~ri:': OIJl', ,~CCILDn: I8 ~SeCtlOnr~~-/'C'1'.~~)~~ _~~~'F'!c/Icfll.' !~ ~Ull'/l.~'{ll~?: OION ~~a11~~C'.' OI~l'. .tit'Ctlon: I~~ .S'C'CtI0i1:JCl'c'~: hl lJ~~~•ic/icrfz~ [; lnirn~hip: Ol!)N 2un,~r: 01 ~1~: Section: ~0 Section 1cr~~s. 6-x(1 Lcgal llc~scription 0~ -2<4-196 * * *SALE NOTICE LEGAL DESCRIPTION' C7=~-160 TION-RISE-U.~I17,18,19,20 212.00 U- 3- 7 C) ~5'~ 1 y Last updated on 10/22/2008. http://www.dnr. state.ak.us/las/Case_Summary.cfm?FileType=ADL&FileNumber=28330... 10/22/2008 • TRANSMITTAL LETTER CHECKLIST WELL NAME ~~`/ ,I~ ~~~ PTD# ~Dd'--/6~L Developments ______ Service Exploratory ______ Stratigra 6ic Test _.__,_Non-Conventional Wee p FIELD: _ f~eyO~o~' ~A,Y POOL: _ /~-~uOyoE' /.gy din Circle Appropriate Letter /Paragraphs to be Included in Transmittal Letter CFIECI{ ADD-ONS ~yI.IAT (OPTIONS) ~~. FOR APPROVAL LETTER APAL[ES MULTI LA'I`EItAG The permit is for a new wellbore segment of existing well (If last two digits in permit No. API number are . API No. SO- between 60-69) production should continue to be reported as a function of the original API number stated above. PILOT HOLE In accordance with 20 AAC 25.005(t), alt records, data and logs acquired for the pilot hole must be clearly differentiated in both well name ( PEI) and AP[ number ~S~ --- _._.) from records, data and logs acquired for well SPACING The permit is approved subject to full compliance with ZO AAC EXCEPTION 25.055. Approva! to perforate and pimduce /inject is contittgept upon issuance of a conservation order approving a spacing exception. assumes the liability of any protest to the spacing exception that may occur. •.•_...~.,~.n All dry ditch sample sets submitted to the Commission must be in SAMPLE no greater than 30' sample intervals from below the from where samples are first caught and 10' sample intervals throe et zones. 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