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209-062
• • Image Project Well History File Cover Page XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. c Q g- 0 b oL. Well History File Identifier Organizing (done) ❑ Two -sided 111 IIIIII II III II 111 ❑ Rescan Needed Ill 1111111111111111 RE AN DIGITAL DATA OVERSIZED (Scannable) Color Items: ❑ Diskettes, No. ❑ Maps: ❑ Greyscale Items: ❑ 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 I IIIII BY: Maria Date: CI 1 Scanning Preparation x 30 = + = TOTAL PAGES r (Count does not include cover sheet) ° - - BY: Date: (Val f / /s/ Production Scanning III I II II III Stage 1 Page Count from Scanned File: a t: (Count does include cover sheet) Page Count Matches Number in Scanning Preparation: t NO BY: Maria Date: I /s/ Stage 1 If NO in stage 1, page(s) discrepancies were found: YES NO BY: Maria Date: /s/ Scanning is complete at this point unless rescanning is required. 111 II'III III II 11111 ReScanned III 11111111 11 1111 BY: Maria Date: /s/ Comments about this file: Quality Checked III I [11111 1lJII 10/6/2005 Well History File Cover Page.doc IIP - /r ,)// f SARAH PALIN, GOVERNOR ALASKA OIL AND GAS / 333 W. 7th AVENUE, SUITE 100 CONSERVATION COMMISSION / ANCHORAGE, ALASKA 99501 -3539 PHONE (907) 279 -1433 FAX (907) 276 -7542 Robert Tirpack Engineering Team Leader BP Exploration (Alaska) Inc. P.O. Box 196612 Anchorage, Alaska 99519 -6612 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, G -13B Well BP Exploration (Alaska) Inc. Permit No: 209 -062 Surface Location: 2224' FNL, 2368' FEL, Sec. 12, T11N, R13E, UM Bottomhole Location: 534' FNL, 194' FWL, Sec. 07, T11N, R14E, UM Dear Mr. Tirpack: 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. The permit is for a new wellbore segment of existing well PBU 12 -05A, Permit No. 207- 053, API 50- 029 - 2039101 -00. Production should continue to be reported as a function of the original API number stated above. 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). 4 Sincerely, Dan . Seamount Chair DATED this 7 day of June, 2009 cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. STATE OF ALASKA RECEIVED % i A LASK,•L AND GAS CONSERVATION COMMISSN 4-4.1- �� PERMIT TO DRILL Il !UN 1 0 2009 20 AAC 25.005 Alaska Oil & Gas Cons. Commission 1 a. Type of work 1 b. Current Well Class ❑ Exploratory ❑ Development Gas 1 c. Specify if well is p 0 ., ,, . - ❑ Drill C i Redrill ❑ Service ❑ Multiple Zone ❑ Coalbed Methane • Gad Hydrates ❑ Re -Entry ❑ Stratigraphic Test ® Development Oil ❑ Single Zone ❑ Shale Gas 2. Operator Name: 5. Bond: ® Blanket ❑ Single Well 11. Well Name and Number: BP Exploration (Alaska) Inc. Bond No. 6194193 PBU G - 13B 3. Address: 6. Proposed Depth: 12. Field / Pool(s): P.O. Box 196612, Anchorage, Alaska 99519 -6612 MD 11890' TVD 8974' Prudhoe Bay Field / Prudhoe Bay 4a. Location of Well (Governmental Section): 7. Property Designation: Oil Pool Surface: ADL 028280 & 028304 2224' FNL, 2368' FEL, SEC. 12, T11N, R13E, UM Top of Productive Horizon: 8. Land Use Permit: 13. Approximate Spud Date: 1535' FNL, 1269' FEL, SEC. 12, T11N, R13E, UM July 15, 2009 Total Depth: 9. Acres in Property: 14. Distance to Nearest Property: 534' FNL, 194' FWL, SEC. 07, T11N, R14E, UM 2560 13,754' 4b. Location of Well (State Base Plane Coordinates): 10. KB Elevation Plan 15. Distance to Nearest Well Within Pool: Surface: x- 657852 y- 5969417 Zone -ASP4 (Height above GL): 64' feet 978' 16. Deviated Wells: Kickoff Depth: 7000 feet 17. Maximum Anticipated Pressures in psig (see 20 AAC 25.035) Maximum Hole Angle: 93 degrees Downhole: 3175 Surface: 2294 18. Casino Program; Specifications Top - Settina Depth - Bottom Quantity of Cement. c.f. or sacks Hole Casing Weight Grade Coupling Length MD TVD MD TVD (including stage data) 8 -1/2" 7" 26# L -80 TC -II 8176' Surface Surface 8176' 7929' (See Below) 8 -1/2" 7" 26# L -80 BTC -M 500' 8176' 7929' 8676'_ 8384' 299 cu ft Class 'G' 6 -1/8" 4 -1/2" 12.6# L -80 IBT -M 3364' 8526' )*6 - .82''x7' 8974' 483 cu ft Class 'G' ArTnivi ct, c 19_ PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re -entry Operations) Total Depth MD (ft): Total Depth TVD (ft):I Plugs (measured): 'Effective Depth MD (ft): 'Effective Depth TVD (ft):I Junk (measured): 10844' 8990' 8790' 8790' 8486' None Casing Length Size Cement Volume MD TVD Conductor / Structural 110' 20" x 30" 8 cu vds Concrete 110' 110' Surface 2673' 13 -3/8" 3441 cu ft Arcticset I I 2673' 2673' Intermediate 8649' 9 -5/8" 1104 cu ft Class 'G' 8649' 8349' Production Liner 953' 7" 336 cu ft Class 'G' 8137' - 9090' 7851' - 8780' Liner 2701' 2 -3/8" 73 cu ft Class 'G' 8143' - 10844' 7856' - 8990' Perforation Depth MD (ft): Below CIBP: 9263' - 10690' Perforation Depth TVD (ft): 8933' - 8989' 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 John Rose, 564 - 5271 Printed Name Robe T Title Engineering Team Leader Prepared By Name/Number. Signature 1001 6�0 Phone 564 -4166 Date Terrie Hubble, 564 - 4628 Commission Use Only Permit To Drill API Number: Permit Approval See cover letter for Number: �09d�? 50 - 029 - 20600 - - Date: ( I7 U other reauirements 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: Er ' ' OO S*k VC:12 ., Samples Req'd: ❑ Yes I'No Mud Log Req'd: ❑ Yes ["No r ` HA Measures: grYes ❑ No Directional Survey Req'd: [Yes ❑ No Other: ` �� - APPROVED BY THE COMMISSION 7 Date - , COMMISSIONER Form 10 6 j /7 7 sed 1 0 R G N Submit e Duplicate - To: Tom Maunder, Petroleum Engineer Alaska Oil & Gas Conservation Commission From: John Rose - ODE Date: June 5, 2009 b p Re: PBU G -13B Permit to Drill Approval is requested for the drilling of the G -13B Ivishak sidetrack. For the planned drilling of this well, an 8 -1/2" intermediate hole will then be drilled from a KOP in the 9 -5/8" casing at -7000' MD to the top of the Sag River formation -8700' MD where a 7 ", 26.0# intermediate casing string will run and cemented. A 6 -W horizontal production hole will then be drilled to a final well TD at -11,890' MD where a 4 - ", 12.6 #, L -80 solid liner will be run and cemented to TD (there is the possibility of running a combination solid /slotted liner on this well). The planned completion for this well will include a 4 - ", 12.6 #, 13 chrome tubing string with 3 gas lift mandrels and a single S -3 production packer. This well is currently scheduled for Nabors 9ES beginning -07/15/09. Please refer to the additional data within this request for specific well details and do not hesitate to call if additional information is required. John Rose - ODE Office - 564 -5271 CeII - 748 -5223 G -13B Sidetrack Page 1 • • G -13B Planned Well Summary Well G -13B Well Horizontal Target Ivishak Type Sidetrack Objective Z1 B 1 API Number: 50- 029 - 20600 -02 Current Status Shut- In /P &A'ed Estimated Start Date: 07/15/09 Time to Complete: 25.8 Days Surface Northing Easting Offsets TRS Location 5969417 657852 3056' FSL / 2913' FWL 11N, 13E, 12 Northing Easting TVDss Offsets TRS Ivishak 5970129 658935 -8936 1535' FNL / 4009' FWL 11 N, 13E, 12 Target Bottom Northing Easting TVDss Offsets TRS Location 5971160 660376 -8910 535' FNL / 194' FWL 11N, 14E, 7 Planned KOP: 1 7000'MD / 6766'TVD 1 Planned TD: 11,890'MD / 8974' TVD Rig: 1 Nabors 9ES GL: 35.47' RTE: 64' Directional — Sperry wp03 KOP: 1 7000' MD Maximum Hole Angle: -21 in the 8 -1/2" intermediate section -93 in the 6-1/8" horizontal section Close Approach Wells: E -21 /G- 13/G- 13A/G -31 A/G -31 APL1 (all wells will be cleared through TRCW process + producers shut -in as required per the appropriate RP) Survey Program: Standard MWD +IIFR +MS Nearest Property Line: 13,754 Nearest Well within Pool: 978' to E -25 G -13B Sidetrack Page 2 • • Current Well Information Well Name: G -13A API Number: 50- 029 - 206 -01 PT D: 2001630 Well Type: Producer Current Status: Shut -In BHP: 3254 psi @ 8435' TVDss (7.4 ppg) BHT: 205° F @ 8435' TVDss Mechanical Condition: Tubing: 4 -1/2 ", 12.6 #, L -80, TDS tubing to 2115' MD 4 -1/2" x 3 -1/2" XO at 2115' MD 3 -1/2 ", 9.2 #, L -80, TDS tubing to 9090' MD TD / PBTD: Jet Cut in 2 -3/8" Coil Liner at 8773' MD w/TOC at 8790' MD Max Dogleg (to P &A): 3.5° /100' @ 7815' MD Max Angle (to P &A): 23° @ 6209' MD Wellhead Equipment: McEvoy SSH 13 -5/8" Wellhead Starting Head: McEvoy SSH 13 -5/8 ", 5000 psi with 3" outlet valve Tbg. Spool: 13 -5/8 ", McEvoy with 3 -1/8" outlet valve Tbg. Hanger: McEvoy, 7" IJ4S Csg. Hanger: 13 -5/8 ", McEvoy with 3-1/8" outlet valve Tbg. Head Adapter: 13 -5/8 ", McEvoy Tree: McEvoy 6 -3/8" bore x 7-1/16" flange BPV Profile: 6 -3/8" - J Completion Equipment: SSSV Landing Nipple: Otis 4 -1/2" (3.813" ID) Control line: none Gas Lift Mandrels: none Control line bands /clamps: none Casing Equipment: Surface Casing: 13 -3/8 ", 72 #, L -80 to 2672' MD 13 -3/8" Cement: Cemented to surface Intermediate Casing: 9 -5/8 ", 47 #, L -80, BTRS (ID = 8.681 ") to 8655' MD 9 -5/8" Cement: 2 stage Cmt Job - Pumped 214 bbls of Class G cement around the shoe (est. TOC at -6005' MD - planned KOP at -7000' MD) / Pumped 27 bbls Arctic Set 1 through DV Pkr at 2589' MD to place -460' of cement in the OA to -2200' MD. Tubing Fluids: Seawater w /2000' diesel cap (As Planned - MUST CONFIRM) IA Fluids Seawater w /2000' diesel cap (As Planned - MUST CONFIRM) OA Freeze Protection arctic pack to -2200' w /cement to shoe Perforations: P &A'ed w /cement & CIBP tested to 2100 psi (As Planned - MUST CONFIRM) Pre -Rig MIT Data: CMIT- TxIAxOA 2000 psi (5/7/09) PPPOT -T 5000 psi test good (5/31/09) PPPOT -IC 3500 psi test good (5/31/09) NEW Wellhead/Tree Requirements (w /Planned 7" Casing to Surface): Current Equipment - McEvoy SSH Proposed Wellhead - McEvoy SSH (with new 7" casing to surface to be set on "slips" or mandrel hanger) 1 - Mandrel Pack -Off CAT ID 67891 1 - Casing Slips CAT ID 94827 1 - Secondary Pack -Off CAT ID 67653 1 - Tubing Spool CAT ID 67883 1 - Tubing Hanger CAT ID 282293 1 - Tubing Head Adapter CAT ID 67901 1 - 4 -1/8" Replacement Tree - CAT ID 69517 G -13B Sidetrack Page 3 • • Formation Markers G -13B (Based on SOR / Sperry wp03) BPRF SV4 -2622 SV3 -2838 SV2 SV1 UG4 -4363 UG3 -4674 UG1 -5101 WS2 -5684 WS1 -5875 CM3 - 6121 CM2 -6980 CM1' -7183 THRZ -7300 BHRZ -7544 LCU -7546 TJF -7546 TJE -7564 TJD -7865 TJC -8019 TJB -8153 TSGR -8320 TSHU -8360 TSAD -8435 TCGL -8563 BCGL -8649 25N -8679 22N -8809 21N -8843 PGOC -8873 TZ1B -8878 14N -8878 TZ1A -8925 MHO -8949 Casing/Tubing Program Hole Csg / Wt/Ft Grade Conn Burst Collapse Length Top MD Bottom MD Size Tbg (psi) (psi) O.D. 8 -1/2" 7" 26# L -80 TC -II 7,240 5,510 8176' Surface 8176' 8 -1" 7" 26# L -80 BTC -M 7,240 5,410 500' 8176' 8676' 6 -1/8" 4 12.6# L -80 IBT -M 8,430 7,500 3364' 8526' 11,890' Tubing 4' " 12.6# 13Cr -80 Vam Top 8,430 7,500 8526' Surface 8526' G -13B Sidetrack Page 4 • Mud Program Intermediate Mud Properties: LSND 1 8 -1/2" hole section Depth Interval Density (ppg) PV YP API FL HTHP FL MBT PH KOP — THRZ 9.2 -9.3 10 -18 18 -28 <6 N/C <18 9 -10 THRZ- 8 -1/2" 10.0 12 -22 18 -28 4 -6 <10.0 <20 9 -10 TD Production Mud Properties: FLOPRO SF Reservoir Drill -in Fluid 1 6 -1/8" hole section Depth Interval Density (ppg) PV YP LSVR API Fl pH MBT 8676' — 11,890' 8.4 — 8.5 6 -12 22 -28 >20,000 6.0 -8.0 9.0 -9.5 < 3 Logging Program 8 -1/2" Intermediate: Sample Catchers — as required by Geology Drilling: Dir /GR/Res /PWD Open Hole: None Cased Hole: Run USIT /GR/CCL f /top tubing stub to surface in 9 -5/8" casing 6 -1/8" Production: Sample Catchers — as required by Geology Drilling: 1st Drilling BHA— Dir /GR 2nd Drilling BHA — Dir /GR /Res /Nue /Density Open Hole: None Cased Hole: None Cement Program Casing Size: 7" 26 #, L -80 Intermediate Casing Basis: Lead: None Tail: 1000' of 7" x 8 -1/2" open hole with 30% excess plus 80' shoe track. Tail TOC at 7676' MD (TOL). Total Cement Spacer 40 bbls of Viscosified Spacer weighted to 12 ppg (Mud Push II) Volume: Lead None Tail 53.3 bbls, 15.8 lb/gal Class G + adds —1.16 cuft/sk X;O s Temp BHST =190° F, BHCT TBD by Schlumberger ZW tel c Casing Size: 4 -1/2 ", 12.6 #, L -80, Production Liner Basis: Lead: None Tail: 3214' of 4 -1/2" liner x 6 -1/8" open hole with 40% excess, plus 150' 4 -1/2" x 7" liner lap, 200' of 7" x 4" DP plus 80' shoe track. Tail TOC at 8526' MD (TOL). Total Cement Spacer 25 bbls of Viscosified Spacer weighted to 11.5 ppg (Mud Push II) Volume: Lead None Tail 86 bbls, 15.8 lb/gal Class G + adds — 1.16 cuft/sk t-{ `b`°,'IcA Temp BHST 197° F, BHCT TBD by Schlumberger Y fps G -13B Sidetrack Page 5 • • 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 F -19A will be 14 days during drilling phase and 7 days during decompletion and surface casing work. Intermediate Interval Maximum anticipated BHP 3028 psi @ 8320' TVDss — TSAG (7.0 ppg EMW) Maximum surface pressure 2196 psi (.10 psi /ft gas gradient to surface) Planned BOP test pressure Rams test to 3,500 psi /250 psi. Annular test to 2,500 psi /250 psi 9 -5/8" Casing Test / 7" 3500 psi surface pressure Casing FIT to 11.3 ppg after drilling 20' from mid - window to satisfy ECD Integrity Test — 8 -1/2" hole management concerns, however, a minimum 9.9 ppg FIT provides "infinite" kick tolerance w/9.5 ppg mud in the hole. 7" Casing The VBR's will be changed to 7" rams to accommodate the 7" liner. Production Interval Maximum anticipated BHP 3175 psi @ 8809' TVDss — TSAD (7.0 ppg) Maximum surface pressure 2294 psi (.10 psi /ft gas gradient to surface) Planned BOP test pressure Rams test to 3,500 psi /250 psi. Annular test to 2,500 psi /250 psi 7" Liner / 4 -1/2" Liner Test 3500 psi surface pressure Integrity Test — 6 -1/8" hole FIT to 8.9 ppg after drilling 20' of new hole to satisfy the Kick Tolerance requirements which will provide an "infinite" influx volume with an 8.5 ppg mud weight in the hole. An FIT of 10.7 ppg will be targeted to satisfy ECD management concerns. Planned completion fluids 8.5 ppg Seawater / 6.8 ppg 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 Class I waste to DS -04 and /or Pad 3 for disposal / Contact the GPB Environmental Advisors (659 -5893) f /guidance. Fault Prognosis Throw Formation Where Encounter Fault MD Intersect TVD Intersect Est. Throw Direction Uncertainty Fault #3 - Z1 (Fault Questionable at BSAD) 11,650 0 - 15' D to N + / - 100 ft lateral G -13B Sidetrack Page 6 • Operations Summary (06/05/09) Current Well Issue/Status: 1. Perforations are isolated /P &A'ed below a cemented CIBP at 8790' MD. 2. The 4 -1/2" tubing has been cut at -40' MD collapsed tubing at -47' MD). 3. There is IAxOA communication above the TOC in the OA. 4. There is the "possibility' of damaged /collapsed 9 -5/8" casing near surface which may be related to the known collapsed tubing on this well at 47' MD. 5. 2 barriers are achievable in both the tubing and IA for MO /RU & ND tree /NU BOPE operations. Pre -Riq Work: 1. CMIT- TxIAxOA to 2000 psi. (NOTE: This CMIT was designed not to exceed the normal 2000 psi pressure test requirement for the OA, however, this test pressure is -82 psi short of AOGCC P &A test requirements, i.e., .25 psi /ft *8330' TVD = 2082 psi.) - DONE 2. PPPOT -IC to 3500 psi, PPPOT -T to 5000 psi. Cycle all LDS and replace /repair as required. - DONE 3. Drift tubing to 8050' in preparation for jet cut. Not Completed - Tubing collapsed at 47'. 4. Jet cut tubing at 8041' MD (mid -first full joint of tubing above the HBBP packer at 8082' MD (see tubing tally)). NOTE: With collapsed tubing at 47', an jet cut at -40' is currently planned. 5. Circulate the well to clean seawater through the tubing cut. Cannot be done. 6. Freeze protect T & IA to -2100 MD with diesel. 7. Set BPV in tubing hanger and test to 2000 psi from below. 8. Remove wellhouse and flow -lines and level pad as required. Proposed Drilling Riq Operations: 1. MI /RU. 2. CMIT- Tx1AxOA to 2000 psi. 3. Pull BPV w /tested lubricator and circulate out diesel freeze protection and displace the well to seawater. 4. Set and re -test TWC to 2,000 psi from below and 3500 psi from above for 10 minutes. 5. Nipple down tree. Nipple up and test BOPE to 3500psi. Pull TWC w /tested lubricator. 6. RIH w /internal tubing cutter on PAC DP and cut the 4 -1/2" tubing above the collapse at -40'. 7. RU & pull 4 -1/2" tubing from the cut depth at -40' MD. 8. Test lower set of rams if required. 9. RIH w /Baker mill /dressing assembly to "polish" the 4 -1/2" tubing stub and swallow the collapsed tubing at 47' in preparation for an external tubing at -130' MD ( -90' of tubing swallow). (Note: To eliminate the possibility of cutting into the the external casing strings (the 9 -5/8" & 13 -3/8" casing strings) here should be NO external milling capabilities built into this polish mill assembly.) 10. RIH w /Baker external tubing cutter and cut the tubing at -130' MD and TOH with cutter (will bring fish out of hole with this BHA). 11. PU 4 -1/2" tubing as required and a Baker over - shot/grapple and RIH and swallow the top of the tubing at -130' MD. 12. RU E -line and make tubing cut (jet cut) at 8041' MD. 13. Circulate the well to clean seawater. 14. Pull the 4 -1/2" x 3 -1/2" completion from the tubing cut at 8041' MD. 15. PU drillpipe and make bit and scraper run to the top of the tubing stub. 16. RU E -line and RIH w /GR/CCL to top stub and log -out to -6500' MD to find good KOP (a good shale / no casing collar) in the Colville. 17. RIH with HES EZSV bridge plug on E -line and set at -7000' MD, as required to avoid cutting a casing collar while milling the window. Test casing to 2000 psi f /30 min and chart. 18. With 2 barriers in the well, change -out the 9 -5/8" pack -offs (through the BOP stack). 19. P/U and RIH with 9-%" Baker bottom -trip anchor whip stock assembly. Orient whip stock and set on EZSV bridge plug. Shear off of whip stock. 20. Displace the well to LSND based milling fluid per MI mud program. (End Work Under Sundry Approval #309 -180 / Begin Work Under PTD #xxx -xxx) G -13B Sidetrack Page 7 • 21. Mill window in 9-%" casing at -7000' MD, plus approximately 20' of new hole beyond middle of window and circulate well -bore clean. 22. Pull up into 9 -%" casing and conduct a FIT. POOH. 23. M/U 8 -1/2" Dir /GR /Res /PWD assembly. RIH, kick off and drill the 8 -1/2" intermediate section to the top of the Sag River at -8700' MD. Circulate well clean, POOH. 24. Run and cement (1000' tail job) a 7 ", 26.0 #, TC -II, L -80 intermediate casing string and test to 3500 psi on the bump. 25. Spilt stack and install new tubing spool per Cameron wellhead specialist. 26. M/U and RIH with a 6 1/8" drilling assembly w /motor assembly w /insert bit, Dir /GR + insert bit and drill 20' of new hole and run FIT. 27. Drill ahead per the directional plan and land the well in the Ivishak target. 28. POOH for bit / BHA change. 29. MU and RIH with a 6 -1/8" drilling assembly w /PDC bit, Nue /Density and Impulse as detailed in well plan and mad -pass build section as required by Geologist in real time before drilling lateral. 30. Drill horizontal section to planned TD, short trip as necessary. 31. Circulate, short trip, spot liner running pill. POOH. 32. Run and cement a 4 -1 ", 12.6 #, L -80, IBT -M production liner. POOH L/D all drill pipe. 33. R/U and run 4 - ", 12.6 #, 13 Cr -80, VamTop completion tubing. Land the tubing RILDS. 34. Reverse circulate inhibited seawater to the production packer depth. 35. Drop ball & rod and set packer and individually test the tubing and annulus to 3,500psi 30 minutes. Record each test. 36. Shear the DCK valve and pump each way to confirm shear. 37. Set a TWC and test to 1000 psi from above and below. 38 Nipple down the BOPE. Nipple up the tree and test to 5,000psi. Pull TWC w /lubricator. 39. Freeze protect the well to 2,200' TVD with diesel. 40. Install BPV and secure the well. 41. Rig down and move off. Post -Ria Operations: (S -Riser Modification will be Required) 1. MI / RU slick line. 2. Pull the ball and rod / RHC plug from landing nipple below the production packer. 3. Install gas lift valves. 4. Install well house and instrumentation. G -13B Sidetrack Page 8 • • Drilling Hazards and Contingencies POST THIS NOTICE IN THE DOGHOUSE 1. Well Control A. With the KOP for the 8 -1/2" hole in the Colville "below" all Cretaceous injection activity, pore pressures for the intermediate hole should be "normal" (8.5 ppg) to less than normal as the interval is TD'ed into the Sag River formation (the Sag in this fault block is expected to be under - pressured at 7.4 ppg EMW). II. Lost Circulation /Breathing A. For the 8 -1/2" intermediate hole, the lost circulation /breathing potential should be minimized due to the relatively deep KOP in the Colville and given the fact the well has been design to minimize the hole angle into the top of the Sag (16 deg) to keep the mud weight relatively low (10.0 ppg). However, as there "may' be no cement behind the 9- 5/8" casing at the KOP and given the potential for a "weak" zone within the Colville below the KOP, lost circulation/breathing problems must be considered a possibility. B. As for the production interval of the well, lost circulation in the Sag River and Ivishak formations is usually fault related, however, the directional plan for this well has been optimized to eliminate the drilling of any "mapped" faults. Please refer to the MI mud program for details as they relate to dealing with lost circulation problems while drilling this interval of the well. III. Kick Tolerance /Integrity Testing Test Point Test Depth Test type EMW (lb/gal) 9 -%" window 20 -ft minimum from the 9 -%" window FIT 9.9 ppg min f /KT 3 ppg max f /ECD Mgt 7" shoe 20 -ft minimum from the 7" shoe FIT 8.9 ppg min f /KT 10.7 ppg max f /ECD Mgt IV. Stuck Pipe A. For the 8 -1/2" intermediate interval of the well, insufficient/poor hole cleaning support resulting in stuck pipe will be of primary concern. B. For the 6 -1/8" production interval of the well, both differential sticking and sticking as associated with insufficient/poor hole cleaning should be of primary concern. VI. Hydrogen Sulfide With H2S levels above the 100 ppm threshold, G -Pad is not considered an H2S pad (see below). However, as is standard practice, follow all RP recommendations as required for working in an H2S environment. Well Name H2S Level Date of Reading #1 Closest SHL Well H2S Level G-32A No data #2 Closest SHL Well 112S Level G-12B No data #1 Closest BHL Well H2S Level E-37A 14 ppm 3/8/2009 #2 Closest BHL Well H2S Level E-21B 10 ppm 11/28/2005 Max. Recorded H2S on Pad/Facility G-10C 40 ppm Other Relevant 112S Data G -Pad is not an H2S pad. (H2S alarms from rigs, etc.) VII. Faults There will be a Kingak fault crossing in the lower 6 -1/8" section of this well at -11,650' MD (Fault #3) that should be watched closely for the possibility of lost circulation. See SOR Section II on lost circulation for more details. VIII. Anti - Collision Issues There are 2 active producers (E -21 & G -31 A) and 3 non - producing wells (G -13, G -13A and G-31APB1) which do not pass Major Risk. The intersect point of these wells is "in zone ", therefore, a Tolerable Collision Risk Worksheet will be run on each well to determine if a Minor Risking of the well is appropriate and producing wells will be shut -in if required. CONSULT THE G - Pad DATA SHEET AND THE WELL PLAN FOR ADDITIONAL INFORMATION G -13B Sidetrack Page 9 • . ' TREE- ICEJOY WELLHEAD- MC13/0Y - 4 � SAFETY NOT ACTUATOR I - AX •6. 19 .6/ - 6591' IP.ELEJ - 31 .52 I 1 MEAKik - 96.10390 I - 14 5' ono sssv, ID- 3.813 rl DE Mt MD- 9119 ��,_,_ -1 2115 ]- 14 -1f7 X 3.12 X0. ID- 2.992' 1 Dan TVD- 81307 SS 25/3 1-19-647 DU P1441 127 CONDUCTOR H---for—/ OAS LET MANDRELS 46' 12!61/ L-80 IDS. 1-4 2115' 1 ST RID TVD DM' TYPE VLV LATCH PORT ram .0162 Opt, ID-. 3.959' 5 3061 3061 1 MAMA DEN 11111 0 Of /15A3? 4 5165 10 MERLA 64 22 A DIN RBI 0 01163 T 13.76'CS0,T2N, I I 2572' 3 6159 6341 22 PIERLA DIN RA 0 0342.01 ID 12.341 2 1631 1364 16 PIERLA DP W/ RA 0 Wr02U1 1 8036 1163 11 MERLA DIY RA 0 0202401 Minimum ID =1.90" p� 8190' SON 3 -12' PARKA SIMS NIP `� MILLED TO 2E0' ON MGM T IW XO - TOP OF 2 -3/8" LNR fig. H3 -1rr x0 m 4-1&, D - 395' I 03 lei 8083 -- 19-60' TIM HI I P PER. 0 - 4137 I :1 TC - I4- 112'XO TO 3.12. 0 3958" I (TOPOP23a LNRI :1 c 1 c ,k ' -23/8' TIM DEPLOY SLV.I0 -2.26' I irj - 1C' IP,ITEDSULLDDGGPE4R 0 311ESIM I 8180' —ITW CROSSOV ER PIN, 0- ISO' I 4 1 1 4 1 / 1 `` I9-6/7 LNR, 414, L30I TES. 0 -6561' H 8@59 ;iii�� ITOP OF ceuear 033.03.08) • . • /' 4 1 DAII - 12-318' W PD CHIP 43410506) 13 -12- TUG L- 1DS,0061 bit, 0 - 2997 1 Ti cs 441 PERPO RAM NSUMIARY i 1 REF LOG: SWSCNL2l11A1 ;, I ( 3-12'411' ROLLO UT WINDOW (G- 13A)91390' -9094' ANOLEATTOP PER?: 48' ® 9263' :•• ^,4 Not: RetertoPrai a:MtDI tor Itterlralpertdit +. ++ SEE SP P NT6NA L Op VS* ELATE i � . '. 1 - t 111 4 9463 -9218 C frb0703 : ! w ' i; 1 -9/16' 6 9311 -9331 C 06.0601 .• . 0, 4-;'. • • • ∎ 1-9/16 6 9346 -9066 C 0560.0 1 `..•••�•� • 4 1- 11116' 6 9446-9566 C 022201 • •• •• • 1- 11116' 6 9624 -9940 C 0222.01 • ••••••• re 44, ^•`••+ 0 1-11115' 6 101111 -10160 C 022701 • • *I I +4..,1 y NF 1- 11116' 6 10186 -10260 C 022201 • • .�4 1 -1111 6 10230 -10160 c 0211701 � * t + ,* il� 1- 1 1118' 6 10410 -10800 C 022201 0 • •' ...• 1- 11116' 6 10510 -10690 C 022201 r P ITD -I 10t7 I 1 -11115' 1 10611 -10890 c 022301 ill WHNSmCk i +iif,• 1-1 1116' 8 10612 -10!90 c 0224.01 .0� +x /' I1' L NR. 29N. LAO ITRS. DM 1 bpt. 0 - 6.184' I-1' ( LNR. 416X. L alien, .m3a t9t. ID- 1.995' H 1 d4' OA - (MI COMMITS DATE 14L j.17 COMMIE; PRU DHO E BAY UHF MIMI ORIGINAL COM Pl. • 044 0121/01 k$NPJC '°7 , : +'FIIIIIIIIIIIIII WELL: G -13A FTrrralum � r•> rr r, a:�����itr *31;.T.pit.ra,; ; t'L .TJ PERW1 4o: • 1I163D Lail -- n` vu ;� carrai,sll,r- 111.01 3T. ��''' .r� - • 1111111111 APING: 5D4029- 20800.4 7y11r41►:1'.7T- ' 1 "I.TT`I'' avirs.,..ii•P'a SEC 12. TUN, R13E,222ENSL &2361EWS (� ' i L[ r a y MINI MIMI IIIIIIIIIIMIMMIIIIIIIIIIII EP It plat ton (AM BB) G-1 3B Sidetrack Page 10 • . TREE- 4'SKCUU ACTUATOR- II LESO N � 1 3 w W.1OI .. AX LESD �LV�( SAFETY NOTES: ACT NI. EL Of ■ 6397 5P. ELEV 33.0 I I DeselAA 7 "x 8 "Annulus (GA) IO P - 321' 1ViaxAlgle 93degat939YIto 41 /Z "X•Nippleud in (3.813 9 -5"lorj- 2000'MD Data PAD 9179' Base of Diese I at -2000' MD Mtn No - 81300 SS • , Y egg 9506' DJ PkR 2:1' CONDUCIOR I 1'101 GAS LIFT PAANDRRS 13J1SC G,7?N,L� 2672' I — ■ ST PAD ND DEO TYPE V LV LA1CH RDRT CATE D- 12317 © 5 l SV Drilling Mud f2000' - 71376' MD — 3 3300 3791' 2 6 CO 6209' DIN Min. ID = }(N Nipple at 8516' MD � ` , 7 mCr 7633' oIN ID = 3.725' I TOW -7000' MD t 41/2 ", 12.6N, 13 CR, thamTop Tubing 9-5/8" Whipstock at 7000' MD — 9 -5,8" CIBP at 7025' MD — a 4 1/2 "X- Nipple (3.813" ID) -8401' MD —7" x 41/2" Baker S -3 packer at -8421' MD E4irr tedT0C- 7678'MD ▪ 41/2 "X- 1/2"XMD ' 41 "XN•Nipple(3.725 " ID) - 8521'MD Top of 4-12" • �.- 4-1f2 "WLEG at -8531' MD MD Liner -8528' >+ L —7 ". 26N. L -80. TC -II Casing to 8176' MD w /BT C-M Connections to 8676' MD 41/2 ",12.6N, L -80, IBT -M Liner - 11,890' MD • i 1 3 -1r2" Tubing Stub -8041' MD .- NI f 6T6 1-- I1 -„r'x0 TO •„r', 11 • 1.3;' I ► f6 f 1' 1-- 13-1 TM( MYiP Pk W, IC•• .66' ) is —y f cG_ p--1• -112 kO • a i -,1r•, 1. 1.331' I ITOP OF T1.k1i I 11_T• ON ITOP OF I - f 1 ..:' ■ -- ' I9 - 518• LA R, 17p, L ATR$, D - S 1681' I • • • 1 (TT� Cl. TTi3 i6•16616111 l � aI flrAgialRSRfILIM � I 11- 12 Ti ll.3.rf1- /6T0:,661Tbpi3O H 66P6' 1\ 4. =5 L g I 1 -■4 6 T'611LOlTWkDO0" ,4- 1:!: 3636' -363•' N Y .. 1 11 � AgRAIRAMS gli I I -„i'W MIPOTO Ck I-1 I 5 II9 161• ,61,67,6, I .e11+ 1 ,.34.1 -16 iTil i, .61 r, bP f, IO.6.,1 •' S 1r- 111 'Ik P,•.64.5 -i6 :TI, .6613661,0 • 8.336' 1-_I 1 I DATE R15! BY COIILIBr15 DATE R EV AY COPAMM'S I PRUDIIDERAY UNIT ORIGINAL COMPLETON 07121,07 I.SAJRIC GLVC,04:17f18Nt) UUELL:G -13A 02 ,01 CTO8101 RACK (G -13A) 04/15,08 RRD/TLH TAG CUT &C BP SET 1134A36.05) PERIUT No: 211630 03I1CLU1 CI-WA I< FINAL 10116.08 GJFIPJC BAITED SPEAR (125,O) APINo: 50-0M- 2060D-02 05/1201 RIM. ADD PERFG 1025,08 PJC DRAUUNG CDRRECTDNS SEC 12, T11N, R13E,2224' NSL& 2368' WEL 08,02.03 AJP.* TLHADD PERFS 05/13.09 Igr Propne d S Wrack 01/17,01 1U11C/KAKISRR ETD NS E' a plor3ilon (A131113) G -13B Sidetrack Page 11 by 0 G -13B (P3b) Proposal $chlumberger Report Date: May 26, 2009 Survey 1 DLS Computation Method: Minimum Curvature / Lubinski Client: BP Exploration Alaska Vertical Section Azimuth: 56.250° Field: Prudhoe Bay Unit - WOA Vertical Section Origin: N 0.000 ft, E 0.000 ft Structure / Slot: l: G - 1 3 D / G -13 ;' i stu TVD Reference Elevation: 64.0 ft relative to MSL Borehole: Plan 0 -13B Fe" i Sea Bed 1 Ground Level Elevation: 40.410 ft relative to MSL UWI/API#: 500292060002 Magnetic Declination: 22.707° Survey Name 1 Date: G -13B (P3b) / May 26, 2009 Total Field Strength: 57709.317 nT Tort 1 AHD 1 DDI I ERD ratio: 311.375° / 4592.85 ft / 6.276 / 0.510 Magnetic Dip: 80.929° Grid Coordinate System: NAD27 Alaska State Planes, Zone 04, US Feet Declination Date: May 15, 2009 Location LatlLong: N 70.32313980, W 148.72005356 Magnetic Declination Model: BGGM 2008 • Location Grid NIE YIX: N 5969417.000 ftUS, E 657852.000 ftUS North Reference: True North Grid Convergence Angle: +1.20522881° Total Corr Mag North a True North: +22.707° Grid Scale Factor: 0.99992831 Local Coordinates Referenced To: Well Head I Measured Azimuth Vertical NS EW Mag 1 Gray Directional Comments Inclination Sub -Sea TVD TVD DLS Northing Easting Latitude Longitude Depth True Section True North True North Tool Face Difficulty (ft) I (deg) (deg) (ft) (ft) (ft) (ft) (ft) (deg) I (deg/100ft ) I Index I (ftUS) (ftUS) Tie -In Survey 6997.97 20.53 57.00 6700.09 6764.06 1257.83 684.22 1055.60 151.33R 0.00 4.71 5970123.22 658892.90 N 70.32500881 W 148.71149486 Top Whipstock 7000.00 20.52 57.02 6701.99 6765.96 1258.54 684.60 1056.20 85.00L 0.64 4.71 5970123.62 658893.49 N 70.32500987 W 148.71149002 Cry 4/100 7020.00 20.86 50.29 6720.70 6784.67 1265.59 688.79 1061.88 152.35L 12.00 4.74 5970127.92 658899.08 N 70.32502130 W 148.71144396 7100.00 18.08 45.50 6796.12 6860.09 1291.96 706.59 1081.69 147.84L 4.00 4.79 5970146.14 658918.51 N 70.32506994 W 148.71128326 7200.00 14.85 37.17 6892.02 6955.99 1319.32 727.69 1100.51 139.84L 4.00 4.83 5970167.62 658936.88 N 70.32512756 W 148.71113066 CM2 7290.50 12.30 26.15 6980.00 7043.97 1338.62 745.58 1111.77 129.12L 4.00 4.87 5970185.75 658947.76 N 70.32517644 W 148.71103939 7300.00 12.06 24.74 6989.29 7053.26 1340.35 747.39 1112.63 127.74L 4.00 4.87 5970187.57 658948.58 N 70.32518139 W 148.71103240 7400.00 10.11 6.42 7087.45 7151.42 1354.92 765.61 1117.98 109.76L 4.00 4.91 5970205.90 658953.55 N 70.32523116 W 148.71098895 CM1 7496.94 9.52 343.80 7183.00 7246.97 1362.83 781.78 1116.70 87.46L 4.00 4.95 5970222.03 658951.93 N 70.32527531 W 148.71099935 7500.00 9.53 343.06 7186.02 7249.99 1362.98 782.26 1116.55 86.73L 4.00 4.95 5970222.51 658951.77 N 70.32527664 W 148.71100052 7600.00 10.53 320.67 7284.53 7348.50 1364.49 797.25 1108.34 64.67L 4.00 4.98 5970237.33 658943.25 N 70.32531760 W 148.71 06 THRZ 7615.74 10.82 317.63 7300.00 7363.97 1364.12 799.46 1106.44 61.69L 4.00 4.99 5970239.49 658941.30 N 70.32532363 W 148.71 3 7700.00 12.76 304.08 7382.49 7446.46 1359.43 810.52 1093.40 48.42L 4.00 5.01 5970250.28 658928.03 N 70.32535385 W 148.711 25 7800.00 15.70 292.96 7479.43 7543.40 1347.83 821.99 1071.78 37.64L 4.00 5.04 5970261.29 658906.18 N 70.32538520 W 148.71136349 End Cry 7820.43 16.35 291.19 7499.06 7563.03 1344.66 824.11 1066.56 -- 4.00 5.05 5970263.30 658900.91 N 70.32539098 W 148.71140586 BHRZ 7867.26 16.35 291.19 7544.00 7607.97 1337.08 828.88 1054.26 - -- 0.00 5.05 5970267.80 658888.52 N 70.32540401 W 148.71150554 LCU / TJF 7869.34 16.35 291.19 7546.00 7609.97 1336.75 829.09 1053.71 - -- 0.00 5.05 5970268.01 658887.97 N 70.32540459 W 148.71150998 TJE 7888.10 16.35 291.19 7564.00 7627.97 1333.71 831.00 1048.79 - -- 0.00 5.06 5970269.81 658883.00 N 70.32540981 W 148.71154991 TJD 8201.79 16.35 291.19 7865.00 7928.97 1282.98 862.93 966.43 - -- 0.00 5.08 5970300.00 658800.00 N 70.32549707 W 148.71221761 TJC 8362.29 16.35 291.19 8019.00 8082.97 1257.02 879.26 924.30 - -- 0.00 5.09 5970315.44 658757.53 N 70.32554171 W 148.71255923 TJB 8501.94 16.35 291.19 8153.00 8216.97 1234.43 893.48 887.64 - -- 0.00 5.10 5970328.88 658720.58 N 70.32558055 W 148.71285649 TSAG 8675.98 16.35 291.19 8320.00 8383.97 1206.28 911.19 841.94 - -- 0.00 5.12 5970345.63 658674.53 N 70.32562896 W 148.71322695 7" Csg 8675.99 16.35 291.19 8320.01 8383.98 1206.28 911.19 841.94 175.90L 0.00 5.12 5970345.63 658674.53 N 70.32562896 W 148.71322697 8700.00 16.35 291.19 8343.05 8407.02 1202.40 913.63 835.64 HS 0.02 5.12 5970347.94 658668.18 N 70.32563564 W 148.71327807 WellDesign Ver SP 2.1 Bld( users) G- 13 \G -13 \Plan G- 13B \G -13B (P3b) Generated 5/26/2009 11:00 AM Page 1 of 2 I Comments Measured Inclination Azimuth Subsea ND TVD Vertical NS EW Ma 1 Gray DLS Directional Northing Longitude I Depth I I True I I Section True North True North Tool Face I I Difficulty I g Easting Latitude Lon g (ft) (deg) (deg) (ft ) (ft► (ft ) (ft ) (ft ) (deg) (deg1100ft) Index (ftUS) (ftUS) Cry 16/100 8701.79 16.35 291.19 8344.78 8408.75 1202.12 913.80 835.19 88.35L 0.00 5.12 5970348.10 658667.73 N 70.32563610 W 148.71328167 TSHU 8717.66 16.61 282.29 8360.00 8423.97 1199.26 915.09 830.89 79.81L 15.98 5.13 5970349.30 658663.40 N 70.32563963 W 148.71331653 TSAD 8797.04 22.52 247.92 8435.00 8498.97 1176.41 911.78 805.62 47.28L 15.98 5.21 5970345.46 658638.20 N 70.32563059 W 148.71352147 8800.00 22.84 247.03 8437.73 8501.70 1175.29 911.35 804.57 46.46L 15.98 5.21 5970345.00 658637.16 N 70.32562940 W 148.71353002 Cry 16/100 8847.82 28.62 235.41 8480.82 8544.79 1154.69 901.21 786.56 133.80L 15.98 5.25 5970334.48 658619.38 N 70.32560170 W 148.71367599 8900.00 23.56 220.23 8527.72 8591.69 1132.13 886.12 769.51 120.14L 15.98 5.29 5970319.05 658602.65 N 70.32556050 W 148.71381428 TCGL 8938.12 21.13 205.48 8563.00 8626.97 1118.89 874.09 761.63 106.48L 15.98 5.32 5970306.85 658595.02 N 70.32552764 W 148.71387821 9000.00 20.53 177.47 8620.98 8684.95 1103.64 853.13 757.29 80.24L 15.98 5.36 5970285.81 658591.13 N 70.32547037 W 148.71391334 BCGL 9030.04 21.84 164.66 8649.00 8712.97 1099.14 842.47 759.01 68.29L 15.98 5.38 5970275.19 658593.06 N 70.32544125 W 148.71389947 25N 9062.62 24.24 152.81 8679.00 8742.97 1096.46 830.67 763.67 57.37L 15.98 5.40 5970263.48 658597.97 N 70.32540900 W 148.71386168 9100.00 27.89 142.00 8712.59 8776.56 1096.23 816.94 772.56 47.66L 15.98 5.43 5970249.95 658607.15 N 70.32537151 W 148.7137 7 9200.00 40.28 123.65 8795.47 8859.44 1110.48 780.37 814.14 32.33L 15.98 5.49 5970214.26 658649.49 N 70.32527157 W 148.71 22N 9218.07 42.74 121.38 8809.00 8872.97 1115.30 773.94 824.24 30.62L 15.98 5.50 5970208.04 658659.72 N 70.32525400 W 148.713 21N 9267.19 49.63 116.14 8843.00 8906.97 1131.73 756.99 855.31 26.99L 15.98 5.53 5970191.75 658691.14 N 70.32520769 W 148.71311870 9300.00 54.34 113.21 8863.21 8927.18 1145.27 746.22 878.80 25.18L 15.98 5.55 5970181.49 658714.85 N 70.32517827 W 148.71292827 PGOC 9317.33 56.85 111.80 8873.00 8936.97 1153.22 740.75 892.01 24.39L 15.98 5.56 5970176.29 658728.17 N 70.32516332 W 148.71282116 TZ1 B / 14N 9326.65 58.21 111.08 8878.00 8941.97 1157.71 737.88 899.33 24.00L 15.98 5.57 5970173.58 658735.54 N 70.32515548 W 148.71276186 9400.00 69.02 106.00 8910.56 8974.53 1197.93 717.16 961.55 21.73L 15.98 5.61 5970154.17 658798.18 N 70.32509884 W 148.71225736 TZ1A 9448.36 76.23 103.06 8925.00 8988.97 1228.64 705.61 1006.20 20.85L 15.98 5.64 5970143.56 658843.06 N 70.32506727 W 148.71189535 9500.00 83.96 100.12 8933.88 8997.85 1264.38 695.41 1055.99 20.34L 15.98 5.67 5970134.42 658893.05 N 70.32503940 W 148.71149167 Tgt 1 / Cry 10/100 9540.31 90.00 97.88 8936.00 8999.97 1293.92 689.12 1095.72 70.68R 15.98 5.69 5970128.97 658932.91 N 70.32502221 W 148.71116952 End Cry 9593.63 91.76 102.91 8935.18 8999.15 1332.17 679.51 1148.15 -- 10.00 5.72 5970120.45 658985.52 N 70.32499591 W 148.71074444 Cry 10/100 10248.58 91.76 102.91 8915.05 8979.02 1781.42 533.20 1786.23 92.83L 0.00 5.85 5969987.61 659626.49 N 70.32459587 W 148.70557126 10300.00 91.50 97.78 8913.58 8977.55 1818.33 523.97 1836.78 92.97L 10.00 5.87 5969979.45 659677.21 N 70.32457062 W 148.70516146 10400.00 90.96 87.79 8911.43 8975.40 1898.56 519.12 1936.51 93.19L 10.00 5.91 5969976.70 659777.02 N 70.32455731 W 148.70435287 10500.00 90.39 77.80 8910.24 8974.21 1987.89 531.65 2035.59 93.31L 10.00 5.95 5969991.30 659875.80 N 70.32459145 W 148.70354955 Tgt 2 10568.16 90.00 71.00 8910.00 8973.97 2052.62 549.96 2101.20 75.98L 10.00 5.97 5970010.99 659941.01 N 70.32464144 W 148.70301756 10600.00 90.77 67.91 8909.79 8973.76 2083.62 561.13 2131.01 76.00L 10.00 5.98 5970022.79 659970.58 N 70.32467194 W 148.70277583 10700.00 93.17 58.19 8906.35 8970.32 2182.73 606.36 2219.99 76.34L 10.00 6.02 5970069.87 660058.58 N 70.32479543 W 148.70205430 End Cry 10701.80 93.21 58.02 8906.25 8970.22 2184.53 607.31 2221.52 - -- 10.00 6.02 5970070.86 660060.09 N 70.32479803 W 148.70.0 Cry 10/100 10716.46 93.21 58.02 8905.43 8969.40 2199.15 615.06 2233.93 111.67L 0.00 6.02 5970078.87 660072.33 N 70.32481919 W 148.70194126 10800.00 90.10 50.26 8903.01 8966.98 2282.53 663.94 2301.54 111.90L 10.00 6.05 5970129.15 660138.90 N 70.32495267 W 148.70139292 Tgt 3 10802.80 90.00 50.00 8903.00 8966.97 2285.31 665.74 2303.69 90.65L 10.00 6.05 5970130.99 660141.01 N 70.32495757 W 148.70137550 10900.00 89.89 40.28 8903.10 8967.07 2380.58 734.22 2372.51 90.64L 10.00 6.08 5970200.90 660208.36 N 70.32514459 W 148.70081736 11000.00 89.78 30.28 8903.38 8967.35 2473.83 815.75 2430.19 90.61L 10.00 6.11 5970283.62 660264.32 N 70.32536727 W 148.70034944 11100.00 89.68 20.28 8903.86 8967.83 2559.47 906.05 2472.84 90.56L 10.00 6.14 5970374.79 660305.06 N 70.32561394 W 148.70000338 11200.00 89.59 10.28 8904.50 8968.47 2634.88 1002.39 2499.17 90.50L 10.00 6.17 5970471.66 660329.35 N 70.32587711 W 148.69978969 End Cry 11254.10 89.54 4.87 8904.91 8968.88 2670.59 1056.00 2506.30 - -- 10.00 6.19 5970525.40 660335.35 N 70.32602356 W 148.69973173 TD / 4 -1/2" Lnr 11890.06 89.54 4.87 8910.00 8973.97 3067.52 1689.64 2560.30 - -- 0.00 6.28 5971159.99 660376.01 N 70.32775455 W 148.69929210 Legal Description: Northing (Y) rftUS1 Easting (X) fftUSI Surface : 3055 FSL 2367 FEL S12 T11N R13E UM 5969417.00 657852.00 BHL : 4745 FSL 4714 FEL S7 T11 N R14E UM 5971159.99 660376.01 WellDesign Ver SP 2.1 131d( users) G- 13 \G -13 \Plan G- 13B \G -13B (P3b) Generated 5/26/2009 11:00 AM Page 2 of 2 by • • 0 Schiumberger WELL FIELD STRUCTURE G -13B (P3b) I Prudhoe Bay Unit - WOA I G -PAD Magnetic Parameters Surface Locallon 144027 Alaska State Planes. Zone 04. US Feet I Miscellaneous Mcdel'. BGGM 2008 Dlp: 80 929° Dale: May 15. 2009 Cat N70 19 23 303 Northing: 598941700 BUS G44 Corm Cl 20522881' Slot: 0.13 TW Re,: RMaty Table (63 97 S above MSL) Meg Dec 422.707° FS. 577093 nT Lon: W148 43 12 193 Easing: 657852 00 BUS Scab Fact: 09999283055 Plan: G.1313 (P3b) Spry Dale: May 26.2009 1200 1600 2000 2400 2800 3200 -13 Tie-In Survey Top Whipstock 6800 r a 6800 Cry 41100 - _.._.._.._.._.._.._.. T 2 ._.._.._.. _.._.._.._.._.._.._.._.._.. _. _.._.._.._.._.._.._.. _44___44 _.._.._.._.._.._.._.._ ._.. _.._.._.._.._....._.._.._.._.._ 7200 ••• 7200 _.._ .._.._.._.._.._..i.._.._..... ._.._ ..........._.._.._.._.._.._.._. _.._....._.._.._.._. . _..___....._.._.._.._.._.._.._ .-.. _..- . ... .._.._ .._.._....._.._.._ _.. ......_.._.._.._........ _.._. -Ifu .._.._.._.._.._.._.. _.._.._.._.._. _. ._.._.._.._.._.._....- ..... 44_44_..- .._......._.._.._.._.. _44_44- - .- ..- .. -.._ End CnA TJE .._i. O O V C - - - - - II ..._.._..- .. _ .. _. . _.. -44_44 Via .._.._.. -.. -.. _.. ._.._.....-.._.._. ._......._.._.._..........._..- __4444.- .._.._.._.._.._.._ 4_44_4. _.. _..........44_ - - 44 .. CD 8000 8000 N 0 _.._.._ .. _ .._.._.._..�.. 7c ...._.._.. _ .. _. . _..r.. 44_44_.. .._.._.._.... - ._.._i- ••_.._.._.._.._.._.._..- ._.._.._.._.._.._..- ..- ..�..- 44_44_ 0 _.. •' °' - J8 . .. _..- ..- . - _.._.._.._.._.._.._.. -..- .._.._.._.._.._44_44_.. - ._.._.._.._.._.._.. _..... 7" Cs, _ _ _ _ _ _ _ _ $ Fi ' ....._.._.._.._. c_.._.._.._.._.._.._. ._.._o_.._.._.._....._....._.._ ._.. _.._.._.._.._.._.._..i.._.._.._ 8400 _..... _..... _.. .. - _.. _.. _..f.._.._.._. .._.._.._.._. _.._.._.._.. _.._.. _.. _.._p_.._.._.._.. -44.. - .. -.._ _44_44 - 44_44- .. -..4444 ..44_44 -.._. _ . ...... ._.._.._._ _ _ _ .. _ .. - .._.__.._._ _.._ ........ ... _.__ . . ..- ..- ..- .._ .._.._.._.. _.- F.- - _ - - - •5N Cry 10/100 8800 8800 - - Tgt , End Cry Tgt 3 End Cry TO 14117? Lnr _44_44 fJ .. � .._.._.._.. _.. _.. _.. _.. _.._.._.._.._.._ ._.. _.. _. ._.. 44_44_ _44_44_.. _44_44_ ._.. _.._ 4_44_4._.. _.. _4444. _.._. - _.. _.._ ...- s........... o ,.e 14N• ...........uu.................. 11 ....alms ..... .u.. ............... .............o................. M.M. _ .. .. ._.. .._. _.._.._.._.:_.._.._.._.._.- _44_44_.._- .— .. —.._ _.._ _.._ i S p•. G -13B (P3b) G -13A Tgt 1 1 Cry 10/100 End Cry Cry 10/100 9200 t3 9200 1200 1600 2000 2400 2800 3200 Vertical Section (ft) Azim = 56.25 ° , Scale = 1(in):400(ft) Origin = 0 N / -S, 0 E / -V b 0 Schlumberger . WELL G -13B (P3b) I FIELD Prudhoe Bay Unit - WOA I STRUCTURE G -PAD Magnetic Parameters Surface Locafon NAD27 Alaska State Planes. Zone 04. US Feet Miscellaneous Motley. BOOM 2008 Dip 80.929° Date May 15, 2009 Cat N70 19 23 303 NorSNng. 5969417 00 ftUS Gn3 Cony. 41.20522881° Slot G-13 TVD Ref'. Rotary Table (63978 above MSL) Meg Dec •22.707° FS'. 57709.3 nT Lon. W148 43 12 193 Eas9n9. 657 852 00 110 5 Scale Fad'. 09999283055 Plan. 0.139 P3b) Srvy Date May 26. 2009 900 1200 1500 1800 2100 2400 2700 1800 i t 1800 .N' TD : P3b) -13A IF Al 1500 1500 G- 46FI138936ss 4 A A A Z _ 1200 1200 0 O (7) xry ..:.z. End :Cry Cry 161100 11 T•. C59 13 0) Cry 161100 (J) 900 EtfBCr4' 900 1n V V V • Tgt 1 I Cry 101100 End Cry Q 10/100 Tgt 3 End Cry Tgt 2 rv.10/160 600 Cry 4/100 ; 600 Top Whipstikck Tie -In Survey G -13 G -13B Fll 1 8936ss 300 • . 300 900 1200 1500 1800 2100 2400 2700 «< W Scale = 1(in):300(ft) E »> • • RntI lslon Report Company: North America - ALASKA - BP Local Co- ordinate Reference: Well G -13 - Slot 13 Project: Prudhoe Bay TVD Reference: Mean Sea Level Reference - Site: - -- PBG - Pad — - MDReference: — _ — 6-13i3 637.97 Site Error: 0.00ft North Reference: True Reference-Welt— —G-13 - - - -Survey-Calculation-Method: - - -- Minimum Curvature--- - - - - -- Well Error: 0.00ft Output errors are at 1.00 sigma ReferenceWellbore Plan G- 13B Database: EDM.16- Anc Prod _WH24P___ Reference Design: Plan #3 G-13B Offset TVD Reference: Offset Datum Reference Plan #3 G -13B Filter type: GLOBAL FILTER APPLIED: All wellpaths within 200'+ 100/1000 of refen Interpolation ethod: MD Interval 5.00ft Error Model: ISCWSA Depth Range: 7,000.00 to 11,890.06ft Scan Method: Tray. Cylinder North Results- Limited -by: Maximum center- centerdistance -of 138646ft Error Surface -EllipticaVConic Survey Too[ Prrogram ` Date 5/2612093 — From To — -- -_ - Serve e116ore — Tool Name Di scrT o —_ —. - -- (ft� (ft) � Y (� � pti- n 97.97 7,000.00 1 : Sperry-Sun BOSS gyro multi (G -13) BOSS -GYRO Sperry-Sun BOSS gyro multishot 7,000.00 8,000.00 Plan #3 G -13B (Plan G -13B) MWD MWD - Standard 7,000.00 8,676.00 Plan #3 G -13B (Plan G -13B) MWD +IFR +MS MWD + IFR + Multi Station 372672009TL:07 :63A16f Page 2 of 5 COMPASS 2003.16 Build 70 • �nticolftsion Report Company: North America - ALASKA - BP Local Co- ordinate Reference: Well G -13 - Slot 13 Project: Prudhoe Bay TVD Reference: Mean Sea Level Reference Site. PB Pad - MD - Reference: -- G--1 - t 63 - .97ft (Nabors Site Error: 0.00ft North Reference: True G -13 - -Survey-Calculation - Method: - - - -M - - - Welt Error: 0.00ft Output errors are at 1.00 sigma Reference Welibore G -13B Database: EDM .16 - Anc Prod - WH24P Reference Design: Plan #3 0-138 Offset TVD Reference: Offset Datum Summary Reference Offset Centre to No-Go Allowable Measured Measured Centre Distance Deviation Warning Site Name Depth Depth Distance (ft) from Plan Offset Well - Weilbore - Design (ft) (ft) - (ft) - - - (ft} -- -- - - - - -- PB E Pad E- 21= €=2YA E -21A - - -- 10,879.42 1 3,485.00 507.54 822 - 307 98 FAIL - E -37 - E -37 - E -37 8,977.61 12,512.00 879.70 433.33 528.74 Pass - Major Risk E -37 - E -37A - E -37A Out of range E -37 - E- 37APB1 - E- 37APB1 Out of range E -37 - E- 37APB1 - Plan #5 -2 Out of range PB G Pad G -01 - G -01 - 0 -01 Out of range G -01A - = G=6tA= 0-01 Out G -02 - G -02 - G -02 7,000.00 6,970.00 1,160.72 414.65 951.36 Pass - Major Risk G -02 - G -02A - G -02A 11,236.54 9,415.00 1,192.54 279.95 942.93 Pass - Major Risk G -02 - G -02B - G -02B 11,236.54 9,415.00 1,192.54 279.95 942.93 Pass - Major Risk G -03 - G -03 - G -03 Out of range G-03 C- 03,4-- G -03A- Out - of -ranges G-03 - Plan G-03B - G -03B Wp 2.0 Out of range G -04 - G -04 - G -04 Out of range G-04 - G -04A - G -04A Out of range G -04 - G -04B - G -04B Out of range G -04 - G -04B - Plan #3 Out of range G -09 - G -09 - G -09 Out of range G -09 - G -09A - G -09A Out of range G=09- G=0913 - G -096 - Out of range - G-09 - G -09B - Plan #2 Out of range GA1- C7,10 _OutoLrange G -10 - G -10A - G -10A Out of range G -10 - G -10B - G -10B Out of range G-10-- 0-10C - - Out ofrange 0 -11 - G -11 - G -11 Out of range G -11 -G-11A - G -11A Out of range G -11 -G-11B - G -11 B Out of range G-12-G-12 G-12-G-12-G-12 Out of range G--12 6-42 4 -G-12A - Out of- range- 0 -12 - G -12B - G -12B Out of range G -12 - G -12B - Plan #4 Out of range G-13-G-13-G-13 7,047.92 7,050.00 1.74 151.04 - 149.30 FAIL - Major Risk G -13 - G -13A - G -13A 7,047.92 7,050.00 1.74 151.04 - 149.30 FAIL - Major Risk -G-21---G-21 -0-21 Outotrange- G-21PB1 - G-21PB1 - G-21PB1 Out of range G -25 - G -25A - G -25A 11,050.00 12,391.30 1,268.15 417.56 850.53 Pass - Major Risk X26 0 ='Lb - G 26 Out of range G -26 - G -26B - G -26B Out of range G -29 - G -29 - G -29 Out of range G -29 - G -29A - G -29A Out of range G -30 - G -30 - G -30 10,712.83 9,450.00 1,021.25 489.55 537.07 Pass - Major Risk - G=30= - 0 , 30A= 0 -30A - 1(1,400 923000 937:78 35377 59 - 7.19 Pass - Major Risk G -30 - G -30B - G -30B 9,735.66 10,990.00 899.80 334.50 575.47 Pass - Major Risk __ - -_ G -30 - G -30B - Plan #6 - -__ 10,033.18 10,705.00 977.58 189.64 797.16 Pass - Major Risk G -31 - G -31 - G -31 9,150.00 9,255.00 1,021.74 213.51 858.04 Pass - Major Risk G -31 - G -31A - G -31A 9,257.38 10,095.00 166.39 185.76 -2.25 FAIL - Major Risk G-31-- G- 3- 1-APB1 - G3- 1AcPB4 -9217.32 1- 1 -5OE00 1-65:74 - - 1 -90-.05- -22.37- - Major Risk G-31 - G -31B - G -31B 9,109.77 8,880.00 1,056.07 187.19 943.38 Pass - Major Risk G -31 - G- 31BPB1 - G- 31BPB1 9,109.77 8,880.00 1,056.07 187.21 943.33 Pass - Major Risk G -32 - G -32 - G -32 8,825.00 8,720.00 1,077.11 355.83 735.62 Pass - Major Risk 5126/2009 11:07 53AM Page 3 of 5 COMPASS 2003.16 Build 70 • Writibollin Report Company: North America - ALASKA - BP Local Co-ordinate Reference: Well G-13 - Slot 13 Project: Prudhoe Bay TVD Reference: Mean Sea Level Reference PB G -- MD - Refetenew: G-13B g 63.97ft 9ES) Site Error: 0.00ft North Reference: True Reference Welt- --Suvey-Caletdation-Methed: Minimum-Curvature- Well Error: 0.00ft Output errors are at 1.00 sigma Reference Welibore Plan G-13B Database: EDM .16 - Anc Prod - WH24P Reference Design: Plan #3 G-13B Offset TVD Reference: Offset Datum Summary Reference Offset Centre to No-Go Allowable Measured Measured Centre Distance Deviation Warning Site Name Depth Depth Distance (ft) from Plan OffsetiNell-Weilbo re- Design (ft) (ft) iftt- (ft) PB G Pad G-32A= - 882500 — 87720.00 1,077.11 355 735.62 Pass- Major Risk 512672 11:07T53.01 Page 4 of 5 COMPASS 2003.16 Build 70 Project: Prudhoe Bay • Site: PB- O Pad -- Well: G -13 Wellbore: Plan G -13B Design: Plan #3 G -13B From KOP to TD Scan interval 100 ft Scale 1:100 E-21A and G -31 /A Risk 1:200 0 350 330 30 so G -31 /G -31A 250 200 300 60 G -31 /G -31 APB r s2 _ __ 15B 93 10 9 111 / 6 5 G- 13/G -13 79 80 270 11� \ 114 ' 1152 t 115 1 1 94 \ 712 is / l4 75 7/7 77 90 76 1 G-13/G-13A 5 1 V293 18, ' \ 155 rig 92 240 120 205 -- 300 I 150 —... 180 Travelling Cylinder Azimuth (TFO +AZI) [ vs Centre to Centre Separation [100 ft/in] Alaska Department of Natural,ources Land Administration System Page 1 of/ I Alaska Mapper Land Records /Status Plats Recorder's Search State Cabins Natural Resources Alaska DNR Case Summary File Type: ADL File Number: 28304 Printable Case File Summary See Township, Range, Section and Acreage? O Yes Q No New Search LAS Menu I Case Abstract I Case Detail I Land Abstract File: ADL 28304 _P !!) . Search for Status Plat Updates As of 06/12/2009 Customer: 000107377 BP EXPLORATION (ALASKA) INC PO BOX 196612/900 E. BENSON BL ATTN: LAND MANAGER - ALASKA ANCHORAGE AK 995196612 Case Type: 784 OIL & GAS LEASE COMP DNR Unit: 780 OIL AND GAS File Location: DOG DIV OIL AND GAS Case Status: 35 ISSUED Status Date: 09/14/1965 Total Acres: 2469.000 Date Initiated: 05/28/1965 Office of Primary Responsibility: DOG DIV OIL AND GAS Last Transaction Date: 12/04/2006 Case Subtype: NS NORTH SLOPE Last Transaction: AA -NRB ASSIGNMENT APPROVED Meridian: U Township: 011N Range: 014E Section: 05 Section Acres: 640 Search Plats Meridian: U Township: 011N Range: 014E Section: 06 Section Acres: 593 Meridian: U Township: 011N Range: 014E Section: 07 Section Acres: 596 Meridian: U Township: 011N Range: 014E Section: 08 Section Acres: 640 Legal Description 05 -28 -1965 ** *SALE NOTICE LEGAL DESCRIPTION * ** C14 -125 11N 14E UM 5, 6, 7, 8 2469.00 U- 3- 7 End of Case Summary Last updated on 06/12/2009. http: / /dnr.alaska.gov /projects /las /Case Summary.cfm ?FileType= ADL &FileNumber = 2830... 6/12/2009 Alaska Department of Natural ,ourees Land Administration System • Page 1 0 Alaska Mapper Land Records /Status Plats Recorder's Search State Cabins Natural Resources �® Alaska DNR Case Summary File Type: ADL File Number: 28280 Printable Case File Summary See Township, Range, Section and Acreage? ( New search 0 Yes O No LAS Menu I Case Abstract I Case Detail I Land Abstract File: ADL 28280 _ Search for Status Plat Updates As of 06/12/2009 Customer: 000107377 BP EXPLORATION (ALASKA) INC PO BOX 196612/900 E. BENSON BL ATTN: LAND MANAGER - ALASKA ANCHORAGE AK 995196612 Case Type: 784 OIL & GAS LEASE COMP DNR Unit: 780 OIL AND GAS File Location: DOG DIV OIL AND GAS Case Status: 35 ISSUED Status Date: 08/19/1965 Total Acres: 2560.000 Date Initiated: 05/28/1965 Office of Primary Responsibility: DOG DIV OIL AND GAS Last Transaction Date: 12/04/2006 Case Subtype: NS NORTH SLOPE Last Transaction: AA -NRB ASSIGNMENT APPROVED Meridian: U Township: 011N Range: 013E Section: 01 Section Acres: 640 Search Plats Meridian: U Township: 011N Range: 013E Section: 02 Section Acres: 640 Meridian: U Township: 011N Range: 013E Section: 11 Section Acres: 640 Meridian: U Township: 011N Range: 013E Section: 12 Section Acres: 640 Legal Description 05 -28 -1965 * ** SALE NOTICE LEGAL DESCRIPTION * ** C14- 91 TIIN, R13E, UM 1, 2, 11, 12 2,560.00 07 -07 -1987 * * * LISBURNE PARTICIPATING AREA DESCRIPTION T. 11 N., R.13 E., U.M. SECTION 1: ALL 640 ACRES SECTION 12: ALL 640 ACRES http: / /dnr.alaska.gov /projects /1as /Case Summary.cfm ?FileType= ADL &FileNumber = 2828... 6/12/2009 . . TRANSMITTAL LETTER CHECKLIST Q WELL NAME 16 G - J 1 PTD# cVe: /Development Service Exploratory Stratigraphic Test Non - Conventional Well 1 FIELD: /..1. II/ ��." POOL: Y�f tug+' 1 (� 6-i Circle Appropriate Lette to be Included in Transmitta etter CHECK ADD -ONS WHAT (OPTIONS) TEXT FOR APPROVAL LETTER APPLIES MULTI LATERAL The permit is for a new wellbore segment of existing well (If last two digits in Permit No. , API No. 50- - - API number are 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(0, all records, data and logs acquired for the pilot hole must be clearly differentiated in both well name ( PH) and API number (50- - - ) from records, data and logs acquired for well SPACING The permit is approved subject to full compliance with 20 AAC EXCEPTION 25.055. Approval to perforate and produce / inject is contingent upon issuance of a conservation order approving a spacing exception. assumes the liability of any protest to the spacing exception that may occur. DRY DITCH All dry ditch sample sets submitted to the Commission must be in SAMPLE no greater than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. Non - Conventional Please note the following special condition of this permit: Well production or production testing of coal bed methane is not allowed for (name of well) until after (Company Name) has designed and implemented a water well testing program to provide baseline data on water quality and quantity. (Company Name) must contact the Commission to obtain advance approval of such water well testing program. Rev: 1/11/2008 WELL PERMIT CHECKLIST Field & Pool PRUDHOE BAY, PRUDHOE OIL - 640150 Well Name: PRUDHOE BAY UNIT G-13B Program DEV Well bore seg 0 PTD#: 2090620 Company BP EXPLORATION (ALASKA) INC Initial Class/Type DEV / PEND Geo Area 890 Unit 11650 On/Off Shore On Annular Disposal Administration 1 Permit fee attached NA 2 _Lease number .appropriate Yes 3 Unique well name and number Yes 4 Well located in a defined pool Yes 5 Well_located proper distance_from_ drilling unit boundary Yes 6 Well _located proper _distance from other wells Yes 7 _Sufficient acreage_ayailable indriffing unit Yes 2560 acres. 8 ifdeviatecl, is_wellbore platincluded Yes 9 Operator only affected party Yes 10 Operator has_appropriate bond in force Yes Blanket Bond # 6194193. 11 Permit can be issued without conservation order Yes Appr D 12 Permitcon be issued without ad_ministrative_approval Yes ACS 6/12/2009 13 Can permit NI approved before15-day wait Yes 14 _Well _located within area andstrata authorized by Injection Order # (put 10# in_comments) (For I NA 15 All wells_within _1/4_mite_are_a_of review identified (For service well only) NA • 16 Pre-produced injector: duration_of pre-production less than 3 months (Forsen/ice well only) _ _ NA_ 17 Nonconven. gas _conforms to A$al .05,030(1,1.A),(1,2.A-D) NA 18 Conductor string_provided NA Condu ctor set in G-13 (181-072). Engineering : 19 Surface _casing_protects all known USDWs NA All aqu ifers exempted, AEO 1. 20 _C_MT_vol adequ_ate_to circulate on conductor & surf csg NA Surface casing set in G-13. 21 _C_Iv1T_voladequ_ate to tie-inicing string to_surf cs_g NA Production casing s et in G-13. 22 _C_MT_will coverall know_n_productive horizons Yes 23 _Casing designs adequate for C,_T, B&_p_ermafrost Yes 24 _Adequate_tankageor reserve pit Yes Rig equipped with steel pits. No reserve pit planned. All waste to approved disposal weli(s). 25 _Ifs_ re-drill has_a_10403 for abandonment been ap proved Yes 309-180 26 Adequate_wetlbore_ separatio_n _proposed Yes Proximity analysis performed. Traveling cylinder path calculated. Identified close approaches are in zone. 27 If diverter required, does it meet regulations NA BOP stack will already be in pla ce. Appr Date 28 _Drilling fluid, program schematic_& eq_uip_list_adequate Yes Maximum expected formation pressure 7.0 EMW. MW planned up to 10.0 ppg in 8.5" hole & 8.5 ppg in zone. TEM 6/16/2009 29 BOPEs,_do they _m_eet reg ulation Yes bir 30 BOPE_pre_ss rating appropriate; test to(put psig in _comments) _Ch Yes Yes MASP calculatecl at 2294 psi. 350_0 psi BOP test planned. 31 oke manifold complies w/AP1 RP-53_ (May 84) • 32 Work will occur withoutoperation shutdown Yes 33 is presence of H2S gas_ probable Yes Minor H2S is reported at G pad. Mud should pre clude 1-125 on rig. Rig has sensors and alarms. 34 Nlecha_nical_conclition of_ wells within Ace verified (For service well only) NA 35 Perrnitcan be issued YutO_ hydrogen_ sulfide measures No Max Level H28 on Pad is 40ppm on well G-10C. Geology 36 _D_ata_p_resented on potential o verpressure zones NA 37 Appr Date _Seistnic_analysis_ of shallow gas zo nes NA ACS 6/12/2009 38 Seabed condition survey (if off-shore) NA 39 Contact name/phone for weekly_progre_ss reporls_[exploratory only Yes John Rose - 564-5271. Geologic Engineering Public Date: Date Date Commissioner: Co issioner: t Commissioner 44 4-02
