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Home My WebLink About216-121Guhl, Meredith D (DOA) From: Guhl, Meredith D (DOA) Sent: Monday, November 26, 2018 9:22 AM To: 'Lastufka, Joseph N' Cc: Davies, Stephen F (DOA); Rixse, Melvin G (DOA); Loepp, Victoria T (DOA) Subject: PBU 05-0613, PTD 216-121, Permit Expired Hello Joe, The permit to drill 216-121, PBU 05-0613, issued to BP Exploration (Alaska) on October 10, 2016, has expired under Regulation 20 AAC 25.005 (g). The PTD will be marked expired in the AOGCC database. If you have any questions, please contact me. Thank you, Meredith Meredith Guhl Petroleum Geology Assistant Alaska Oil and Gas Conservation Commission 333 W. 7th Ave, Anchorage, AK 99501 meredith.guhl@alaska.gov Direct: (907) 793-1235 CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Meredith Guhl at 907-793-1235 or meredith.guhl@alaska.gov. rrP A16-eta Loepp, Victoria T (DOA) From: Lastufka, Joseph N <Joseph.Lastufka@bp.com> Sent: Tuesday, December 05, 2017 9:13 AM To: Loepp, Victoria T (DOA) Subject: RE: Updated BOPE Schematic for the following wells Attachments: Updated BOPE Schematic for the following wells; Updated BOPE Schematic for the following wells Follow Up Flag: Follow up Flag Status: Flagged Victoria, Sorry to bother you but could you please confirm the approval to change the BOPE schematic for the following wells? If you need any additional information please let me know. Thank you, Joe Lastufka Information and Data Controller Cell: (907) 227-84961 Office: (907) 564-4091 `. b BP Exploration Alaska1900 E. Benson Blvd.lRoom: 788DIAnchorage, AK From: Lastufka, Joseph N Sent: Wednesday, November 29, 2017 9:59 AM To: Victoria. Loepp@alaska.gov Subject: Updated BOPE Schematic for the following wells Victoria, As Zach Browning indicated on Monday, we are changing the BOP stack for Nabors CDR2. This change will affect the approved and out for approval Permit to Drills. Please see list below for well name and PTD # (if available): 05-06B (PTD #216-121) E-07B (currently out for approval) E-12A (PTD #216-127) L-118L1 (PTD #217-006) Thank you, Joe Lastufka Information and Data Controller Cell: (907) 227-84961 Office: (907) 564-4091 Well Slimhole Quick Test Sub to Otis Top of 7" Otis Distances from top of riser Excluding quick -test sub Top of Annular Top of Annular Elemer. CDR2-AC 4 Ram BOP Schematic Date 21-Nov-17 f-CDR2 Rig's Drip Pan Bottom Annular 8.0 ft CL Blind/Shears 9.3 It CL 2" Pipe/Slips 10.1 ft--" Bi B2 Kill Line r" CL 2-3/8" x 3-1/2" VBRs 12.6 ft —► CL 2" Pipe/Slips 13.4 ft 4 7.1/16" 5k Flange X 7" Otis Box Hydril 7 1116" Annular B3 rUn B4 CL of Top Swab 16.0 ft Swab ,le T1 e T2 CL of Flow Cross 17.4 ft A Master CL of Master 18.8 ft LDS �fJ IA OA LDS O Ground Level Choke Line Test Pump Hose /-)� z / 4- / z1 Well Blank (._ R2-AC BOP Schematic Du.e Quick Test Sub to Otis 1.1 ft—'—-— - —' — -- Top of7"Otis O.Oft .—.—.—.—.—.—.—.—.——.—.—.—.—._ —CDR2 Rig's Drip Pan Distances from top of riser Excluding quick -test sub Top of Annular F 0.0 ft 7-1/1W' 5k Flange x T' Otis Box Hydril71/16" Top Annular Element 0.7 ft Annular Bottom Annular 2.0 f4 CL Blind/Shears fit 2" Pipe'slips CL 2" Combi's► BS 7 68 Deployment ' �, p CL 2.3/8" Combi's CL 2 3/8" Combi's CL Blind/Shears CL 2" Combi's 6.6 ft —t 7.4 ft110 Kill Line YB1 CL of Top Swab CL of Bottom Swab CL Flow Tee CL of SSV CL of Master Valve LDS Gound Level --71 10.o n —► 10.7 ft B2 13.3 ft 14.8 ft 16.2 ft BOP2 17.5 ft } Fusable 19.0 ft BON 20.5 ft �--►d 83 ,4 --Swab 2 ,----Swab 1 /< T1 Ae T2 Master 2 Master 1 Choke Line ,: roke Line Test Pump Hose Loepp, Victoria T (DOA) From: Browning, Zachary H <Zachary.Browning@bp.com> Sent: Thursday, December 29, 2016 9:49 AM To: Loepp, Victoria T (DOA) Cc: Hyatt, Trevor, Tempel, Joshua; Lastufka, Joseph N Subject: RE: Change in Rig BOPE Diagram Attachments: CDR2 Bighole BOP Stack.pdf, CDR2 Slimhole BOP Stack.pdf Follow Up Flag: Follow up Flag Status: Flagged Victoria, The previously attached BOP schematic showed the ram configuration for only our slimhole wells. Please use the Slimhole diagram for wells: E-12A 05-06B Please use the Bighole diagram for wells: 03-24B 03-27A 09-29A F-22A F-35A Sorry for the confusion. Thanks, Zach From: Lastufka, Joseph N Sent: Wednesday, December 28, 2016 2:16 PM To: Victoria.Loepp@alaska.gov Cc: Hyatt, Trevor; Browning, Zachary H; Tempel, Joshua Subject: Change in Rig BOPE Diagram Victoria, There will be a rig change for BPXA set to begin February 1st. Please replace the following wells from Nordic 2's BOP sketch to the new rig, CDR2's BOP Sketch. 03-24B (not approved, submitted 12/6) 03-27A (not approved, submitted 12/20) 05-06B (PTD #216-121) 09-29A (PTD #216-129) E-12A (PTD #216-127) F-22A (not approved, submitted 11/30) F-35A (PTD #216-152) If you have any questions or need additional information please let me know THE STATE 9 4, A -V 44115", me"31- k" 0, 4"' GOVERNOR BILL WALKER Sean McLaughlin Drilling Supervisor BP Exploration (Alaska), Inc. P.O. Box 196612 Anchorage, AK 99519-6612 I:f.', . ! , +mil 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 www.aogcc.alaska.gov Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU 05-06B BP Exploration (Alaska), Inc. Permit to Drill Number: 216-121 Surface Location: 1910' FSL, 1256' FWL, SEC. 32, T11N, R15E, UM Bottomhole Location: 3791' FNL, 658' FEL, SEC. 06, T10N, R15E, UM Dear Mr. McLaughlin: Enclosed is the approved application for permit to re -drill 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 AOGCC 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 AOGCC 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 an AOGCC order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Sincerely, P� Cathy . Foerster Chair DATED this I � day of October, 2016. SEP 13 2016 STATE OF ALASKA -ASKA OIL AND GAS CONSERVATION COMMIS PERMIT TO DRILL 20 AAC 25.005 A eNf-e%t"% la. Type of Work: 1 b. Proposed Well Class: Exploratory - Gas ❑ Service - WAG ❑ Service - Disp ❑ 1 c. Specify if well is proposed for: Drill ❑ Lateral ❑ StratigrapNc Test ❑ Development - Oil Q Service - Winj ❑ Single Zone ❑ Coalbed Gas ❑ Gas Hydrates ❑ Redrill Q • Reentry ❑ Exploratory - Oil ❑ Development - Gas ❑ Service - Supply ❑ Multiple Zone ❑ Geothermal ❑ Shale Gas ❑ 2. Operator Name: 5. Bond Blanket Q 'Single Well ❑ 11 Well Name and Number: BP Exploration (Alaska), Inc Bond No. 29S105380 - PBU 05-06B ' 3 Address: 6. Proposed Depth: 12. Field/Pool(s): P.O. Box 196612 Anchorage, AK 99519-6612 MD: 12600' • TVD: 8981'ss PRUDHOE BAY, PRUDHOE OIL 4a. Location of Well (Governmental Section): 7. Property Designation (Lease Number): ADL 028326 & 028329 ' Surface: 1910' FSL, 1256' FWL, Sec. 32, T11N, R15E, UM 8. Land Use Permit: 13. Approximate spud date: 1516' FNL, 883' FEL, Sec. 06, T1ON, R15E, UM Top of Productive Horizon: 70-099 December 1, 2016 9. Acres in Property: 2491 & 2501 14. Distance to Nearest Property: Total Depth: 3791' FNL, 658' FEL, Sec. 06, T10N, R15E, UM 23000 4b. Location of Well (State Base Plane Coordinates - NAD 27): 10. KB Elevation above MSL: 69 feet 15. Distance to Nearest Well Open to Same Pool: Surface: x- 698353 ' y- 5948106 ' Zone - ASP 4 GL Elevation above MSL: 35.25 feet 450 16. Deviated wells: Kickoff Depth: 10015 feet 17. Maximum Anticipated Pressures in psig (see 20 AAC 25.035) Maximum Hole Angle: 96 degrees Downhole: 3345 ' Surface: 2465 18. Casing Program: Specifications Top - Setting Depth - Bottom Cement Quantity, c.f. or sacks Hole Casinq Weiqht Grade Coupling Length MD TVD MID TVD(including stage data 3-1/4" 2-3/8" 4.7# L-80 TH511 2635' 9965' 8596'ss 12600' 8981'ss 76sxClass'G' 19. PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re -Entry Operations) Total Depth MD (ft): Total Depth TVD (ft): 1 Plugs (measured): Effect. Depth MD (ft): Effect. Depth TVD (ft): Junk (measured): 1 10644 9125 9669,10470 9669 83 None Casing Length Size Cement Volume MD TVD Conductor/Structural 80 20" 550 sx PF 1 35 - 115 35 - 115 Surface 2676 13-3/8" 5300 sx Arctic Set 33 - 2709 33 - 2709 Intermediate 10183 9-5/8" 1500 sx C, 115 sx Arctic Set 31 - 10214 31 - 8809 Production Liner 932 3-1/2" x 2-7/8" 20 Bbls Class 'G' 9712 - 10644 8377 - 9125 Perforation Depth MD (ft): 10426 - 10559 Perforation Depth TVD (ft): 8970 - 9065 20. Attachments Property Plat ❑ BOP Sketch Q Drilling Program Q Time v. Depth Plot ❑ Shallow Hazard Analysis ❑ Diverter Sketch ❑ Seabed Report ❑ Drilling Fluid Program Q 20 AAC 25.050 requirements Q 21. Verbal Approval: Commission Representative: Date 22. 1 hereby certify that the foregoing is true and the procedure approved herein will not be deviated Contact Hvatt, Trevor from without prior written approval. Email Trevor.Hyatt@bp.com Printed Name Sean McLaughlin Title Drillinq Supervisor q Signature %r -� (� t (-I , Phone +1 907 564 4387 Date l ( Z Commission Use Only Permit to Drill Number: — Z API Number: 50- 029-20173-02-00 Permit Approval Date: See cover letter for other requirements: 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 in shales: 13' Other: 13cP rt 5 t f o 3 S(» p 5 q Samples req'd: Yes ElNo E: Mud log req'd: Yes ❑ No 1;3/ �} rtYt lJ� G, r to re-V- e, ✓2 �C t$+ H2S measures Yes V No El Directional svy req'd: Yes 12/ No —❑ Spacing exception req'd: Yes El No L Inclination -only svy req'd: Yes ❑ No L�l/ Post initial injection MIT req'd: Yes ❑ No D APPROVED BY Approved by: T COMMISSIONER THE COMMISSION Date: � ✓T� to/6/Jb ORIGINAL Form 10-401 Revised 11/2015 This permit is valid for 24 months from the date of approval (20 AAC 25.005(g)) Submit Form and Attach ents in Duplicate 7 __?,/�/41_ To: Alaska Oil & Gas Conservation Commission From: Trevor Hyatt CTD Engineer Date: September 12 2016 Re: 05-06B Permit to Drill Request Rig: Nordic 2 Target Reservoir: Ivishak Zone 2 r,0o, W ,&,.j bp History and current status: 05-06 was intitially drilled as a rotary drilling well in 1976. Well 05-06A was drilled as a vertical Z2 CTD sidetrack in June 1995. The initial perforations (10434' - 10443') in lower Z2B did not flow. The interval was re -perforated along with adperfs from 10426' - 10434'. The Z2B perfs still did not flow. An unsuccessful acid stimulation was pumped in August 1995 to open the perforations. Z2A adperfs (10520' - 10530') were perforated in September 1995 and a POGLM was installed in October 1995 to lift the well to production. In late 2001, 05-06A was evaluated for potential IAxOA leaks and passed a TIFL and MIT-OA to 2500 psi. The well also passed a TIFL and MIT-OA in mid-2002. A RST log run in January 2003 indicated a remaining Z213 oil column with a Z2A gas under -run. Based on the RST information, a CIBP was set at 10470' in February 2003 to isolate the Z2A under -run and Z2B adperfs (10440' - 10450') were shot. Additional Z2B adperfs (10426' - 10446') were shot in March 2003. The well passed a TIFL following the adperfs. Due to the low IOR value for this well, an IBP set at 9640' to secure the well for LTSI. In February 2006, a LDL identified the leak location at the 5-1/2" POGLM located at 7772'. In October 2006, braided line pulled the stuck POGLM and set a tubing patch from 7767' - 7797' to cover the tubing punch holes in December 2007. A DSSSV was installed and the well passed a subsequent MIT -IA to 3000 psi. Following the tubing patch, the well did not flow. The DS operator attempted several backflows with no success. Small well work jobs have been performed until now. No further non -rig operations are options are present. The well is ready to be sidetracked. �'l l f ice( S in c� tic ZOI Z Proposed plan: Nordic 2 Coiled Tubing Drilling rig will drill a through tubing sidetrack on or around December 1 st, 2016. Nordic 2 will exit into Zone 4 Ivishak formation above the existing 05-06A perforations. The sidetrack will target Zone 2A/2B1 reserves. The proposed sidetrack is a -V2,585' MD horizontal Ivishak Zone 2A/2B1 producer. The lateral will be completed with a 2-3/8" L-80 liner which will be cemented and perforated isolating the current Zone 2A/2B1 perforations. CTD Drill and Complete 05-06B program: Rig Start Date January 1st 2017 Pre -Rig Work 1. S Pull PX Plug. Set DSSSV. Drift for Whipstock. 2. E Set 3-1/2" packer whipstock* 3. V Pre CTD Tree Work Rig Work: 1. MIRU and test BOPE to 250 psi low and 3,500 psi high. Maximum expected surface pressure with gas (0.10 psi/ft) to surface is 2,465 psi. 2. Mill 2.80" window plus 10' of rathole. Swap the well to 8.5-9.5 ppg PowerPro. 3. PU drilling BHA with GR/Resistivity 4. Drill 3.25" hole to TD at-12,600' MD 5. Run 2-3/8" L-80 liner leaving TOL at-9,965' MD. 6. Pump primary cement bringing TOC to TOL, 15.8 bbls of 15.3 ppg liner cmt planned* 7. Cleanout liner and run GR/CCL log if cement job does not go as planned. 8. Test liner lap to 2,400 psi. 9. Freeze protect well, RDMO Post Rig: 1. V: Tree work as necessary. 2. S: LTP if necessary* and KO GLV's. 3. F: Pressure Test LTP if necessary. 4. C: Perforate liner per asset instructions (-60' MD at first) and N2 lift for KO. 5. T: ASRC flowback. * Approve per :-r o,Gjrf i ecr well kcro d�c4i d q siQt e A17- S to 41c'e pra,� �,cN win Aw On -rl'W y 9' Mud Program: • Well kill: 8.4-8.6 ppg brine. • Milling/drilling: 8.4-9.5 ppg Power Pro for milling window and drilling (>500 psi over -balance ). Disposal: • All drilling and completion fluids and all other Class II wastes will go to Grind & Inject. • All Class I wastes will go to Pad 3 for disposal. Hole size: 3.25" Liner Program: • 2-3/8", 4.7# L-80, TH 511 9,965' MD — 12,600' MD • A minimum of 15.8 bbls of 15.3 ppg cement will be used for liner cementing. (TOC 9,965' MD) • The primary barrier for this operation: a minimum EMW of 8.4 ppg. • A X-over shall be made up to a safety joint including a TIW valve for all tubulars ran in hole. Well Control: • BOP diagram is attached. • Pipe rams, blind rams and the CT pack off will be pressure tested to 250 psi and to 3,500 psi. • The annular preventer will be tested to 250 psi and 3,500 psi. Directional • See attached directional plan. Maximum planned hole angle is 960. • Magnetic and inclination surveys will be taken every 30 ft. • Distance to nearest property — 23,000' • Distance to nearest well within pool — 450' Logging • MWD directional, Gamma Ray and Resistivity will be run over all of the open hole section. • Cased hole GR/CCL logs will be run if cleanout run is needed. Perforating: • 1.56", 6 spf, perf guns • The primary barrier for this operation: a minimum EMW of 8.4 ppg. An EMW of 8.4 ppg for this well will provide 500 psi over -balance to the reservoir. • A X-over shall be made up to a safety joint including a TIW valve for all tubulars ran in hole. Anti -Collision Failures • 01-17A Fails Major Risk for 05-06B WP14 Anti -Collision. 01-17A is P&A'd and will be minor risked. Hazards • DS-05 is not an H2S pad • Medium Risk of lost circulation with one planned fault crossings Reservoir Pressure • The reservoir pressure on 05-06B is expected to be 3,345 psi at 8800' TVDss. (7.31 ppg equivalent). • Maximum expected surface pressure with gas (0.10 psi/ft) to surface is 2,465 psi. • An EMW of 8.4 ppg for this well will provide 500 psi over -balance to the reservoir. Trevor Hyatt CC: Well File CTD Engineer Joseph Lastufka Loepp, Victoria T (DOA) From: Hyatt, Trevor <Trevor.Hyatt@bp.com> Sent: Thursday, October 06, 201610:08 AM To: Loepp, Victoria T (DOA) Subject: RE: PBU 05-06B(PTD 216-121) Anti -collision Victoria, The close approach is in the section of the 01-19 below where 01-19A kicked off (technically the well passed major risk, but it was close so we minor risked the well). The close approach is in the area of 01-19 that is abandoned and doesn't have impact on the current 01-19C well (as this well passes AC). Let me know if you need more info. Trevor Hyatt BP Exploration (Alaska), Inc. Coil Tubing & RWO Drilling Engineer Trevor.HVatt@bp.com Work: 907-564-4627 Cell: 907-223-3087 From: Loepp, Victoria T (DOA)[mailto:victoria.loepp@alaska.gov] Sent: Thursday, October 06, 2016 9:31 AM To: Hyatt, Trevor Subject: PBU 05-06B(PTD 216-121) Anti -collision Trevor, PBU 01-19 fails major risk and is minored. What anti -collision mitigation measures will be in place; SI @ surface or deep plug set? Thanx, Victoria Victoria Loepp Senior Petroleum Engineer State of Alaska Oil & Gas Conservation Commission 333 W. 7th Ave Anchorage, AK 99501 Work: (907)793-1247 Victoria. Loepp(o)a laska.gov CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Victoria Loepp at (907)793-1247 or Victorb.Loepp)Aalaska.clov VVELLHEAD = FMCI ACTUATOR = FMC AXEL INITIAL KB. ELEV = BF EFEl/ = 69 KOP = 2709 Max Angle = 45" @ 10529 Datum MD = 10289 Datum TVD 8800' SS 20" OONDUCTOR , 94#, FT40, D = 19.124" 80' 13 3/8" CSG, 72#, W80 BTRS, D = 12.347" 2709' Minimum ID = 2.42" @ 10161' TOP OF 2-7/8" LN R U' 5 _0 6A SAFL NOTES: I 2159' H 5-1/2" FEES FRO SSSV W. D = 4.562" 7780' - 7781' 1-1 TBG PUNCH - 5 HOLES (10/26/95) 9549' S 1/2" OTIS XN NP, D = 4.455" 9553' 5-1/2" BOT PBR ASSY, D = 3.92" ' I(03/20/12 CALIPER) 9595' 9-5l8" X 5-1/2" BKR SAB F'1CR, ID = ? 5-1/2" TBG, 17#, W80 BTRS, 9608' 9608' .0232 bpf, D = 4.892" 9669' 4-1/2" OTIS X NP, D = 3.813" 9669' 4-1l2" PX RUG (01l31l16) TOP OF 3-1/2" 64119712' 9712'—14-1/2" G LANDING SEAL SUB, D = 3.0" 4-1/2" TBG, 12.6#, W80 MOD 8-RD, 9734' 9733' 4 1/2" BOT SHEAFdOIJT SUB (BEFiD CT LNR) .0152 bpf, D = 3.958" 9733' 4-1/2" TUBING TAIL (BE}MID CT LNR) 3-1/2" LNR, 9.3#, L-80 FL4S, 0087 bpf, D = 2.992" 1 10161' 1 9-5/8" CSG, 47#, W80 BTRS, ID = 8.681" —I ^ 10214 PERFORATION SUMMARY REF LOG: BHCS ON 06/26/95 ANGLE AT TOP FEW: 45" @ 10426' Note: Refer to Production DB for historical pert data SIZE SPF INTERVAL as SHOT SOZ 2-1/8" 2 10426 - 10446 S 07/18/95 04/02/96 2" 6 10426 - 10446 O 03/17/03 2-1/8" 4 10434 - 10446 S 07/02/95 04/02/96 2" 6 10440 - 10450 O 02122/03 2-1/8" 4 10520 - 10530 C 09/05/95 1-11/16" 4 10539 - 10559 C 05/22/98 FBTD 10610' 2-7/8" LW 6.5#, L-80 FL4S, 10643' .0058 bpf, D= 2.441" TD H 106" 10161' j--� 3-1/2" X 2-7/8" XO, D = 2A20" 9-5/8" MLLOUT VVINDOW (05-06A) 10214' - 10219 1047W j—j WFD CBP (02/22/03) 10633' 1—I2-7/8" PORTED PUP. D = 2.441" PRUDHOE BAY UHT WELL: 05-06A PERMIT No: 1950840 AR No: 50-029-20173-01 SEC 32, T11K R15E, 1913' FSL 8 1258' FWL DATE REV BY COMMENTS DATE REV BY COMMENTS 06/18/76 ROW 34 INITIAL COMPLETION 04/21/12 SET/ PJC XN NIP DEPTH OORRECTION 06/28195 N1 E5 CTD SIDETRACK (05-06A) 04/22/12 SET/ PJC SET PX PLUG (4/10/12) 03/22/12 SWC1JMD SET FIX RUG (03/20/12) 06/21/13 CJWJMD PULL X LOCK/PLUGJFISH (03/27/13) 03/28/12 PJC DRAWING CORRECTIONS 06/24/13 SVVC/JMD SET X LOCK/X NIP RED/PLUG (04/03/13) 03129l12 PJC PERF/ MILL OUT CORRECTIO 02/02/16 I TBD/JMD PULL PLUG 8 NP RED/SET PLUG(01/31/16) BP Exploration (Alaska) 04/21/12 1 RCT/ PJC I PULL PX PLUG (4/10/12) VVE-LFEAD = - ------ - ---------------- ACTUATOR = F!41C OKB. E LEV = 69 BF. E LBI = — KOP = 2709 MFax Angle = _° a@— Datum MD= Datum TVD = 8800' SS PROPO,AL REV 1 20" CONDUCTOR, 94#, H-40, ID 13-3/8" CSG, 72#, MN-80 BTRS, D=12-347" 2709' Minimum ID = " 5-1/2" TBG, 17#, M -80 BTRS, 9608' 0232 bpf, D = 4.892" TOP OF 3-1/2" LNR I—{ 9712' 4-1/2" TBG, 12.6#, M -80 MOD 8-RD, 973,V 0152 bpf, D = 3-958" 5/8" X 3-1/2" TOC PE R SCMT (Ot/31I16) 9930' TOLlrOc (_/_/_} 9965' 3-1l2" XL KB PKR WHIPSTOCK( „_/___) 10015' 1 3-112" LW9.3#, L-80 FL4S, �10015` .0087 bpf, ID 2-992' 9-5/8" CSG, 47#, W80 BTRS, D = 8-681" �10214 PE WORA-MN SJjkAAARY REF LOG: ,A4 / ANGLE AT TOP PE W: —'CD Note: Eaefer to Production DB for historical perf data SIZE SPF Kr R1/AL US SHOT SQZ SAF OTES@'_ WELL ANGLE > 70" @ O 5 -O 6 MAX DLS PBTD 2-3/8" LNR, #, L-80 12600' — bpf, D = __ ' 101 2159' 1—� 5-1/2" FES HRQ SSSV NIP, D = 4-562" 7780' - 7781' 1-� TBG PUNCH - 5 HOLES (10/26195) 9549'�� 5 1!2" OTIS XN NP, D = 4-455" 9553' S-1/2" BOT PBR ASSY, D = 3-92" (03J20/12 CALF) 9595' 9-5/8" X 5-1/2" BKRSAB RCP, ID=? 9669' 4 1/2" OTIS X NP, D = 3-813" 9712' —�4 1t2" G LANDING SEAL Sly, D = 3.0" 9733' 4-1/2" BOT SHEAROUr SUB (BEHIND CT LNR) 9733' 4-1/2' R BEING TAIL (Ba*U CT LNR) 9965' 1-12-70" DEPLOYMENT D= MLLOUT WINDOW (05-06B) 00000' - 00000' DATE PEV BY COML434TS DATE REV BY 0OMv1314TS 06/18/76 ROW 34 INITIAL COMPLETION 06/28/95 N1 ES CTD SIDETRACK (05-06A) CTD SIDETRACK (05-06E' 07/22/16 JMD BULT PROPOSAL 10712U161 THJMD BULT PROPOSAL REV 1 PUP JT w IRA TAG PRIDFDE BAY L T WELL: 05-06B PERMIT No: AR No: 50-029-20173 " SEC 32, T11 N, R15F 1913' FSL 81258' FWL BP Exploration (Alaska) all R,4d, Cl) � 0 CL CD v � o cl) CDQ. 0 CO W 0 C� a.fn zLl cL a. 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O N N N N N N N N IV N N a- Y 3 E a L Z ui F W 0 z z a 0 O U N h W m l l M t m 7 N N Q m b Nm , [n� l v l N O n N I� < m m 0 0 N Nc? +l Nl NOO NO�Tm N N N N N N N N N N f/1O M nNmnMt70 W < � <M �mNOR V th f W Nm W ZOO�{{^mr p;z M V V OOI ON...O >an V V m C<O �m V <C ^NnI V On �nOOYI(NI� Ol N�O»Yf tpN NNNnN � > m mmmml` L a oo m m m m m m m m m m m op aWD m = O ado Z ewe .�-uoi 2 U O M C 11 t' 1 Q N O N 4 n 6 N n 6 u) m N m = mcv ooi of of oid cio6^rWmlc vim oiv� vranul ulmmr E< t.2m e =�U8 's m d N o [N�lNv hum!lOa r 1G 0V Ma A WOO OAm V% 00 W Of O......mm W ww m O EOUO N m m 0 m � �o �OOOOOOOOmmmminm O 4% T N = N �e CCNYfNNNhai ai W ��fV NG OO�t7mmmmt�l<m O�O�yy NOO C17 C �w 05w E 3= u io---- -nm^mW 5 m-Nnv�nmrmW m U LO O O O O O O r- o m o 0 0 0 O O O O N o m 0 o Q4 U �p 0 O LO O O O O O O I- O V) O u) o O O O O Ci moa m 0=°� mo0� comp 0 O y m m U a m c0 0 • •ilk O O O O N r- O O _o 0 M O o-- O O CD C o . (6 0 v L Q o 0 ui 0 U C � p w � .5 v U � C � o 0 Q N E O Z O O_ I N O �O / N NO O O'D N o O N O li) O m N O O OO Q M 0 O w r��o'o'� t o U 0 0 0 0 o p n m CD N [= by North America - ALASKA - BP Prudhoe Bay PB DS 05 05-06 500292017300 05-06B 05-06B WP14 Travelling Cylinder Report 08 September, 2016 BAKER NUGHES h BP HARD pTravelling Cylinder Report BAKER HUGHES Company: North America - ALASKA - BP Project: Prudhoe Bay Reference Site: PB DS 05 Site Error: 0.00 usft Reference Well: 05-06 Well Error: 0.00 usft Reference Wellbore 05-06B Reference Design: 05-06B WP14 Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Output errors are at Database: Offset TVD Reference: Well 05-06 Mean Sea Level 15 06 6/14/1995 00:00 @ 69.00usft (generic drilling rig) True Minimum Curvature 1.00 sigma EDM R5K - Alaska PROD - ANCP1 Offset Datum Reference 05-06B WP14 Filter type: GLOBAL FILTER APPLIED: All wellpaths within 200'+ 100/1000 of reference Interpolation Method: MD Interval 25.00usft Error Model: ISCWSA Depth Range: 9,900.00 to 12,600.00usft Scan Method: Tray. Cylinder North Results Limited by: Maximum center -center distance of 1,456.68 usft Error Surface: Elliptical Conic Survey Tool Program Date 9/8/2016 From To (usft) (usft) Survey (Wellbore) Tool Name 100.00 9,900.00 Camera based gyro multisho (05-06) CB -GYRO -MS 9,900.00 12,600.00 05-06B WP14 (05-06B) MWD Casing Points Summary Description Camera based gyro multishot MWD - Standard Measured Vertical Casing Hole Depth Depth Diameter Diameter (usft) (usft) Name (in) (in) 80.00 11.00 20" 20.000 26.000 2,709.00 2,639.81 13 3/8" 13,375 17.500 10,015.00 8,570.02 3 1/2" x 9 5/8" Dual String Exit 3.500 3.500 12,600.00 8,980.59 2 3/8" 2.375 3.250 Site Name Offset Well - Wellbore - Design PB DS 01 01-17 - 01-17A- 01-17A 01-17 - 01-17B - 01-17B 01-19 - 01-19 - 01-19 01-19 - 01-19A- 01-19A 01-19 - 01-19B - 01-196 01-19 - 01-19C - 01-19C 01-21 - 01-21 - 01-21 01-21 - 01-21A- 01-21A PB DS 05 05-06 - 05-06 - 05-06 05-06 - 05-06A - 05-06A 05-27 - 05-27 - 05-27 05-27 - 05-27A - 05-27A 05-27 - 05-27B - 05-27B 05-27 - 05-27BPB1 - 05-27BPB1 05-41 - 05-41 A - 05-41 A 05-41 - 05-41A- Plan #6 Reference Offset Centre to No -Go Allowable Measured Measured Centre Distance Deviation Warning Depth Depth Distance (usft) from Plan (usft) (usft) (usft) (usft) 12,409.78 9,850.00 439.07 9.21 429.86 ass -Minor 1! 12,425.00 9,975.00 933.69 535.07 398.55 R,sk---, 11,033.07 10,075.00 1,015.45 12.44 1,011.35 Minor 1/10 11,037.69 10,050.00 1,035.07 918.42 131.62 Pass- Major Risk 11,050.00 9,975.00 1,040.56 912.79 154.68 Pass- Major Risk 11,085.19 9,900.00 1,048.74 883.27 200.37 Pass - Major Risk 11,925.00 9,575.00 1,280.13 846.03 440.24 Pass - Major Risk 10,350.00 10,743.00 970.55 943.78 42.11 Pass - Major Risk 10,222.91 10,225.00 24.90 2.67 24.90 Pass - NOERRORS 10,222.88 10,225.00 25.59 0.65 25.59 Pass - NOERRORS Out of range Out of range Out of range Out of range 10,139.79 10,725.00 870.30 782.77 297.71 Pass - Major Risk 10,142.42 10,749.98 881.76 784.05 270.86 Pass - Major Risk CC - Min centre to center distance or covergent point, SF - min separation factor, ES - min ellipse separation 9/8/2016 9:03:27AM Page 2 COMPASS 5000.1 Build 81B BP FUG ��"�� Travelling Cylinder Report BAKER HUGHES Company: North America - ALASKA - BP Project: Prudhoe Bay Reference Site: PB DS 05 Site Error: 0.00 usft Reference Well: 05-06 Well Error: 0.00 usft Reference Wellbore 05-06B Reference Design: 05-06B WP14 Local Co-ordinate Reference TVD Reference: MD Reference: North Reference: Survey Calculation Method: Output errors are at Database: Offset ND Reference: Well 05-06 Mean Sea Level 15 : 06 6/14/1995 00:00 @ 69.00usft (generic drilling rig) True Minimum Curvature 1.00 sigma EDM R5K - Alaska PROD - ANCP1 Offset Datum eference Depths are relative to 15 : 06 6/14/1995 00:00 @ 69.00usft ( Coordinates are relative to: 05-06 iffset Depths are relative to Offset Datum Coordinate System is US State Plane 1927 (Exact solution), Alaska Zone 04 entral Meridian is 150' 0' 0.000 W Grid Convergence at Surface is: 1.51 ° Ladder Plot 1600 ----------- 1200 - -- --- —' -- - - - - -- ----- -- - --------- - - - - -- I m a- - - - - m a� a 800 c� 0 a� 400 0 0 2500 5000 7500 10000 12500 15000 Measured Depth LEGEND 01-17,01-17A,01-17AV2 $ 05-41,05-41A,05-41AV3 —fr- 01-19,01-19B4O1-19BV0 01-17,01-17B4O1-17BV2 $ 05-41,05-41A, Plan #6 V2 $ 01-19,01-19A,01-19AV6 01-21,01-21A,01-21AV2 01-19,01-19,01-19V7 05-06,05-06,05-06V2 $ 01-21,01-21,01-21 V1 01-19,01-19C,01-19CV0 05-06,05-06A,05-06AV1 CC - Min centre to center distance or covergent point, SF - min separation factor, ES - min ellipse separation 9/8/2016 9:03:27AM Page 22 COMPASS 5000.1 Build 81B BP FCFla -bp Travelling Cylinder Report BAKER "kOW HUGHES Company: North America - ALASKA - BP Project: Prudhoe Bay Reference Site: PB DS 05 Site Error: 0.00 usft Reference Well: 05-06 Well Error: 0.00 usft Reference Wellbore 05-06B Reference Design: 05-06B WP14 Local Co-ordinate Reference: ND Reference: MD Reference: North Reference: Survey Calculation Method: Output errors are at Database: Offset ND Reference: Well 05-06 Mean Sea Level 15 06 6/14/1995 00:00 @ 69.00usft (generic drilling rig) True Minimum Curvature 1.00 sigma EDM R5K - Alaska PROD - ANCP1 Offset Datum eference Depths are relative to 15 : 06 6/14/1995 00:00 @ 69.00usft ( Coordinates are relative to: 05-06 ffset Depths are relative to Offset Datum Coordinate System is US State Plane 1927 (Exact solution), Alaska Zone 04 entral Meridian is 150' 0' 0.000 W Grid Convergence at Surface is: 1.51 Separation Factor Plot 9.00 O @ 6.00 LL o 1, m N � I 3.00 0.00 0 2500 5000 7500 10000 12500 Measured Depth LEGEND —X— 01-17,01-17A,01-17AV2 $ 05-41,05-41A,05-41AV3 01-19,01-19B4O1-19BV0 01-17,01-17B4O1-17BV2 $ 05-41,05-41A, Plan #6 V2 $ 01-19,01-19A,01-19AV6 - 01-21,01-21A,01-21AV2 —f 01-19,01-19,01-19V7 05-06,05-06,05-06V2 $ 01-21,01-21,01-21 V1 —fir— 01-19,01-19C,01-19CV0 05-06,05-06A,05-06AV1 CC - Min centre to center distance or covergent point, SF - min separation factor, ES - min ellipse separation 9/8/2016 9:03:27AM Page 23 COMPASS 5000.1 Build 81B �04 BP FfAas bp Travelling Cylinder Report BAKER HUGHES Company: North America - ALASKA - BP Project: Prudhoe Bay Reference Site: PB DS 05 Site Error: 0.00 usft Reference Well: 05-06 Well Error: 0.00 usft Reference Wellbore 05-06B Reference Design: 05-06B WP14 Local Co-ordinate Reference: ND Reference: MD Reference: North Reference: Survey Calculation Method: Output errors are at Database: Offset ND Reference: Well 05-06 Mean Sea Level 15 : 06 6/14/1995 00:00 @ 69.00usft (generic drilling rig) True Minimum Curvature 1.00 sigma EDM R5K - Alaska PROD - ANCP1 Offset Datum aference Depths are relative to 15 : 06 6/14/1995 00:00 @ 69.00usft ( Coordinates are relative to: 05-06 ffset Depths are relative to Offset Datum Coordinate System is US State Plane 1927 (Exact solution), Alaska Zone 04 entral Meridian is 150° 0' 0.000 W Grid Convergence at Surface is: 1.51 ° Travelling Cylinder Prot 1995 330 30 1710 1425 10125 300 ` 60 - 10138 112 570 9984 07 285 1900 270 410975 10428 12250 90 12450 10375 11051242.5 570 0 C '19 855 240 �\ 1140 120 \11568 1425 1710 210 150 1995 180 Azimuth from North [°] vs Centre to Centre Separation [950 usft/in] LEGEND 01-17,01-17A,01-17AV2 $ 05-41,05-41A,0541AV3 —9— 01-19,01-19B4O1-19BV0 01-17,01-17B4O1-17BV2 05-41,05-41A, Plan #6 V2 $ 01-19,01-19A,01-19AV6 —4— 01-21,01-21A,01-21AV2 —lf 01-19,01-19,01-19V7 05-06,05-06,05-06V2 $ 01-21,01-21,01-21 V1 01-19,01-19C,01-19CV0 05-06,05-06A,05-06AV1 CC - Min centre to center distance or covergent point, SF - min separation factor, ES - min ellipse separation 9/8/2016 9:03.27AM Page 24 COMPASS 5000. 1 Build 81 B \ � CL North America - ALASKA - BP Prudhoe Bay PB IDS 05 05-06 05-06B 05-06B WP14 Plus 500ft MD AOGCC Offset Well Report 08 September, 2016 BAKER NUGHES bood b BP W/r2 pAnticollision Report BAKER HUGHES Company: North America - ALASKA - BP Project: Prudhoe Bay Reference Site: PB DS 05 Site Error: 0.00usft Reference Well: 05-06 Well Error: 0.00usft Reference Wellbore 05-06B Reference Design: 05-06B WP14 Plus 500ft MD Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Output errors are at Database: Offset TVD Reference: Well 05-06 Mean Sea Level 15 06 6/14/1995 00:00 @ 69.00usft (generic drilling rig) True Minimum Curvature 1.00 sigma EDM R5K - Alaska PROD - ANCP1 Offset Datum Reference 05-06B WP14 Plus 500ft MD Filter type: GLOBAL FILTER APPLIED: All wellpaths within 200'+ 100/1000 of reference Interpolation Method: MD Interval 25.00usft Error Model: ISCWSA Depth Range: 9,900.00 to 13,100.00usft Scan Method: Tray. Cylinder North Results Limited by: Maximum center -center distance of 1,506.68usft Error Surface: Elliptical Conic Survey Tool Program Date 9/8/2016 From To (usft) (usft) Survey (Wellbore) Tool Name Description 100.00 9,900.00 Camera based gyro multisho (05-06) CB -GYRO -MS Camera based gyro multishot 9,900.00 13,100.00 05-06B WP14 Plus 500ft MD (05-06B) MWD MWD - Standard Summary Site Name Offset Well - Wellbore - Design PB DS 01 01-17 - 01-17 - 01-17 01-17 - 01-17A- 01-17A 01-17 - 01-17B - 01-17B 01-17 - 01-17C - 01-17C 01-19 - 01-19 - 01-19 01-19 - 01-19A - 01-19A 01-19 - 01-19B - 01-19B 01-19 - 01-19C - 01-19C 01-21 - 01-21 - 01-21 01-21 - 01-21A- 01-21A 01-32 - 01-32A - 01-32A Plan 01-35 - Plan 01-35 - 01-35 wp03 PB DS 05 05-06 - 05-06 - 05-06 05-06 - 05-06A - 05-06A 05-06 - 05-06B - 05-06B WP14 05-41 - 05-41 A - 05-41 A 05-41 - 05-41 A - Plan #6 Reference Offset Centre to Measured Measured Centre Depth Depth Distance (usft) (usft) (usft) 12,700.00 9,650.00 458.11 12,409.78 9,850.00 439.07 12,743.77 9,450.00 625.93 12,800.00 9,300.00 620.40 11, 009.03 10, 225.00 1,030.43 11, 037.69 10, 050.00 1,035.07 11,050.00 9,975.00 1,040.56 11,085.19 9,900.00 1,048.74 11,925.00 9,575.00 1,280.13 10,350.00 10,743.00 970.55 13,100.00 10,025.00 766,51 13,100.00 8,625.00 1,262.00 10,222.91 10,225.00 24.90 10,222.88 10,225.00 25.59 12,600.00 12,600.00 0.00 10,139.79 10,725.00 870.30 10,142.42 10,749.98 881.76 9/8/2016 1:19:20AM Page 2 of 32 COMPASS 5000.1 Build 81B Loepp, Victoria T (DOA) From: Hyatt, Trevor <Trevor.Hyatt@bp.com> Sent: Thursday, October 06, 2016 10:08 AM To: Loepp, Victoria T (DOA) Subject: RE: PBU 05-06B(PTD 216-121) Anti -collision Victoria, The close approach is in the section of the 01-19 below where 01-19A kicked off (technically the well passed major risk, but it was close so we minor risked the well). The close approach is in the area of 01-19 that is abandoned and doesn't have impact on the current 01-19C well (as this well passes AC). Let me know if you need more info. Trevor Hyatt BP Exploration (Alaska), Inc. Coil Tubing & RWO Drilling Engineer Trevor.Hyatt@bp.com Work: 907-564-4627 Cell: 907-223-3087 From: Loepp, Victoria T (DOA)[mailto:victoria.loepp@alaska.gov] Sent: Thursday, October 06, 2016 9:31 AM To: Hyatt, Trevor Subject: PBU 05-06B(PTD 216-121) Anti -collision Trevor, PBU 01-19 fails major risk and is minored. What anti -collision mitigation measures will be in place; SI @ surface or deep plug set? Thanx, Victoria Victoria Loepp Senior Petroleum Engineer State of Alaska Oil & Gas Conservation Commission 333 W. 7th Ave Anchorage, AK 99501 Work: (907)793-1247 Victoria. Loepp Malaska.gov CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Victoria Loepp at (907)793-1247 oryictoria.Loepww alaska.gov TRANSMITTAL LETTER CHECKLIST WELL NAME: PTD: Development _ Service Exploratory Stratigraphic Test _ Non -Conventional FIELD: POOL: Check Box for Appropriate Letter / Paragraphs to be Included in Transmittal Letter CHECK OPTIONS TEXT FOR APPROVAL LETTER MULTI The permit is for a new wellbore segment of existing well Permit LATERAL No. , API No. 50- - - - (If last two digits Production should continue to be reported as a function of the original in API number are API number stated above. between 60-69) In accordance with 20 AAC 25.005(f), all records, data and logs acquired for the pilot hole must be clearly differentiated in both well Pilot Hole name ( PH) and API number (50- - - -� from records, data and logs acquired for well (name on permit). The permit is approved subject to full compliance with 20 AAC 25.055. Approval to produce/inject is contingent upon issuance of a conservation Spacing Exception order approving a spacing exception. (Company Name) Operator assumes the liability of any protest to the spacing exception that may occur. All dry ditch sample sets submitted to the AOGCC must be in no greater Dry Ditch Sample than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. Please note the following special condition of this permit: production or production testing of coal bed methane is not allowed for Non -Conventional (name of well) until after (Company Name) has designed and Well implemented a water well testing program to provide baseline data on water quality and quantity. (Company Name) must contact the AOGCC to obtain advance approval of such water well testing program. Regulation 20 AAC 25.071(a) authorizes the AOGCC to specify types of well logs to be run. In addition to the well logging program proposed by (Company Name) in the attached application, the following well logs are also required for this well: Well Logging Requirements Per Statute AS 31.05.030(d)(2)(B) and Regulation 20 AAC 25.071, composite curves for well logs run must be submitted to the AOGCC within 90 days after completion, suspension or abandonment of this well. Revised 2/2015 WELL PERMIT CHECKLIST Field & Pool PRUDHOE BAY, PRUDHOE OIL - 640150 C PTD#:2161210 Company BP EXPLORATION (ALASKA) INC. Initial Class/Type Administration 17 Nonconven. gas conforms to AS31.05.0300.1.A),0.2.A-D) NA 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 available in drilling unit Yes 8 If deviated, is wellbore plat included Yes 9 Operator only affected party Yes 10 Operator has appropriate bond in force Yes Appr Date 11 Permit can be issued without conservation order Yes 12 Permit can be issued without administrative approval Yes SFD 9/14/2016 13 Can permit be approved before 15-day wait Yes 14 Well located within area and strata authorized by Injection Order # (put 10# in comments) (For NA 15 All wells within 114 mile area of review identified (For service well only) NA 16 Pre -produced injector: duration of pre -production less than 3 months (For service well only) NA Well Name: PRUDHOE BAY UNIT 05-06B Program DEV Well bore seg DEV / PEND GeoArea 890 Unit 11650 On/Off Shore On Annular Dispc Surface Location lies within ADL0028326; Top Prod Int & TD lie within ADL0028329. PRUDHOE BAY, PRUDHOE OIL POOL - 64015, governed by CO 341 F CO 341 F, Rule 2: There shall be no restrictions as to well spacing except that no pay shall be opened in a well closer than 500 feet to the boundary of the affected area. Planned well conforms to CO 341 F, Rule 2. 18 Conductor string provided NA Conductor set in PBU 05-06 Engineering 19 Surface casing protects all known USDWs NA Surface casing set in PBU 05-06 20 CMT vol adequate to circulate on conductor & surf csg NA Surface casing set and fully cemented 21 CMT vol adequate to tie-in long string to surf csg NA 22 CMT will cover all known productive horizons Yes Productive interval will be completed with cemented liner and perforated 23 Casing designs adequate for C, T, B & permafrost Yes 24 Adequate tankage or reserve pit Yes Rig has steel tanks; all waste to approved disposal wells 25 If a re -drill, has a 10-403 for abandonment been approved Yes PTD 195-084, Sundry 316-465 26 Adequate wellbore separation proposed Yes Anti -collision analysis complete;01-17A fails major risk and is P&A'd;01-19 fails but is abd in the section 27 If diverter required, does it meet regulations NA Appr Date 28 Drilling fluid program schematic & equip list adequate Yes Max formation pressure is 3345 psig(7.3 ppg EMW ); will drill w/ 8.4 ppg EMW VTL 10/6/2016 29 BOPEs, do they meet regulation Yes 30 BOPE press rating appropriate; test to (put psig in comments) Yes MPSP is 2465 psig; will test BOPS to 3500 psig 31 Choke manifold complies w/API RP-53 (May 84) Yes 32 Work will occur without operation shutdown Yes 33 Is presence of H2S gas probable Yes H2S measures required 34 Mechanical condition of wells within AOR verified (For service well only) NA 35 Permit can be issued w/o hydrogen sulfide measures No DS 05 wells are H2S-bearing. H2S measures are required. Geology 36 Data presented on potential overpressure zones Yes Planned drilling mud program (8.4 ppg) appears adequate to control operator's forecast Appr Date 37 Seismic analysis of shallow gas zones NA pore pressure gradient (about 7.3 ppg). Should higher pore pressures be encountered, SFD 9/14/2016 38 Seabed condition survey (if off -shore) NA BP has immediate access to nearby fluid mixing facilities. 39 Contact name/phone for weekly progress reports [exploratory only] NA Geologic Engineering Public Commissioner: Date: Co sinner: Date MConer Date