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215-068
Guhl, Meredith D (DOA) From: Guhl, Meredith D (DOA) Sent: Friday, May 5, 2017 10:46 AM To: Lastufka, Joseph N Subject: PBU F-18A L1 PTD 215-068 and F-18A L1-01 PTD 215-069 Hello Joe, Permits to Drill 215-068 and 215-069, for Prudhoe Bay Unit F-18A L1 and F-18A 1-1-01, issued 27 April 2015, has expired under Regulation 20 AAC 25.005 (g). The PTDs 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. I THE STATE °fALAS -KA GOVERNOR BILL WALKER John McMullen Engineering Team Leader BP Exploration (Alaska), Inc. P.O. Box 196612 Anchorage, AK 99519-6612 Alaska Oil and Gas Conservation Commission 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 F-18AL1 BP Exploration (Alaska), Inc. Permit No: 215-068 Surface Location: 2955' FNL, 2195' FEL, SEC. 02, T11N, R13E, UM Bottomhole Location: 2435' FNL, 878' FWL, SEC. 36, T12N, R13E, UM Dear Mr. McMullen: Enclosed is the approved application for permit to re -drill the above referenced development well. The permit is for a new wellbore segment of existing well Permit No. 209-018, API No. 50-029- 20636-01-00. Production should continue to be reported as a function of the original API number stated above. 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, Cathy P. oerster Chair DATED this V day of April, 2015. STATE OF ALASKA RECEIVED ALA; DIL AND GAS CONSERVATION COMM : ON APR 0 9 2015 PERMIT TO DRILL 20 AAC 25.005 1 a.Type of work: 1 b.Proposed Well Class:. ® Development Oil ❑ Service - Wini . ® Single Zone 1 c. Specify if well is proposed for: ❑ Drill ' ® Lateral ❑ Stratigraphic Test ❑ Development Gas ❑ Service - Supply ❑ Multiple Zone ❑ Coalbed Gas ❑ Gas Hydrates ❑ Redrill ❑ Reentry ❑ Exploratory ❑ Service - WAG ❑ Service - Disp ❑ Geothermal ❑ Shale Gas 2. Operator Name: 5. Bond . ® Blanket ❑ Single Well 11. Well Name and Number: BP Exploration (Alaska) Inc. Bond No . 6194193 PBU F-18AL1 3. Address 6. Proposed Depth: 12. Field / Pool(s) P.O. Box 196612, Anchorage, Alaska 99519-6612 MD 13274' • TVD 8705'ss • Prudhoe Bay / Prudhoe Bay , 4a. Location of Well (Governmental Section): 7. Property Designation (Lease Number): Surface: ADL 028280& 028277 ' 2955' FNL, 2195' FEL, Sec. 02, T11N, R13E, UM 8. Land Use Permit: 13. Approximate Spud Date: Top of Productive Horizon: 3567' FNL, 756' FEL, Sec. 35, T12N, R13E, UM June 1, 2015 9. Acres in Property: 14.Distance to Nearest Property: Total Depth 2435' FNL, 878' FWL, Sec. 36, T12N, R13E, UM 2560 2322' 4b. Location of Well (State Base Plane Coordinates - NAD 27): 10.KB Elevation above MSL: 65.2' • feet 15.Distance to Nearest Well Open Surface: x 652649 • y- 5973859 • Zone- ASP4 GL Elevation above MSL: 36.08' • feet to Same Pool: 153' 16. Deviated Wells: Kickoff Depth: 10927' . feet 17. Maximum Anticipated Pressures in psig (see 20 AAC 25.035) Maximum Hole Angle: 100 degrees Downhole: 3221 ' Surface: 2341 ' 18. Casing Program Specifications Top - Setting Depth - Bottom I Quantity of Cement, c.f. or sacks Hole Casing Weight Grade Coupling Length I MD TVD MD TVD (including stage data) 4-1/4" x 3-1/4" x 6.6# / 4.7# L-80 TCII / 2624' 10650' 8658'ss 13274' 8705'ss 15 sx Class'G' Uncemented Slotted 3-1/4" 2-3/8" 511 Liner 19. PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re-entry Operations) Total Depth MD (ft): Total Depth TVD (ft): Plugs (measured): Effective Depth MD (ft): Effective Depth TVD (ft): Junk (measured) 12747' 8799' None 12747' 8799' 1 None Casing Length Size Cement Volume MD TVD Conductor / Structural Surface 110, 20" x 30" 8 cu yds Concrete 110, 110, Intermediate 2720' 13-3/8" 3906 cu ft Permafrost II 2720' 2689' Production 6487' 9-5/8" 1690 cu ft Class 'G' 130 cu ft PF 'C' 6487' 5268' Liner 4352' 7" 643 cu ft LiteCrete 195 cu ft Class 'G' 6322' - 10674' 5161' - 8738' Liner 1 2225' 1 4-1/2" Uncemented Slotted Liner 10521' - 12746' 8645' - 8799' Perforation Depth MD (ft): Slotted Liner: 12720' - 12701' Perforation Depth TVD (ft): Slotted Liner: 8801' - 8802' 20.Attachments: ❑ Property Plat ® BOP Sketch ® Drilling Program ❑ Time vs Depth Plot ❑ Shallow Hazard Analysis ❑ 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 Nathan Sperry, 564-4258 Printed Name John " Title Engineering Team Leader Email Nathan.Sperry@bp.com Signature Phone 564-4711 Date / �J Commission Use Only Permit To Drill rj '3 API Number: JPermit Apr D [Seeover letter for Number. f Ci 50-029-20636-60-00% 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 ©/ Other: v G 5 Sam les Re d contained shales: 8610 f rs �" f 3 $ P P q ❑ Yes �No Mud Log Req'd: ❑ Yes [ONo S fit/% r C VC ✓L tCk- tfS t ' H2S Measures: [2rYes E] No Directional Survey Req'd: [, `Yes ❑ No Spacing exception req'd: ❑ Yes Ly No inclination -only svy Req'd: ❑ Yes ©`No APPROVED BY _ Z, --/� APPROVED BY;64,1��MISSIONER THE COMMISSION Date Form 10-401 Revised 10/20J2 T s i i li the from the date of approval (20 AAC 25.005(g)) Submit Form Attachments In Duplicate To: Alaska Oil & Gas Conservation Commission From: Nathan Sperry CTD Engineer Date: April 8, 2015 Re: F1 8AL1 &AL1 -01 Permit to Drill Request Obp Approval is requested for a permit to drill a CTD sidetrack lateral from well F-18A with the Nordic 2 Coiled Tubing Drilling rig on or around June 1st, 2015. The sidetracks will exit the 4-1/2" slotted liner in the base of the Sag at 10,924' MD (90 deg inc). Both wells will be drilled in the Sag. The proposed AL1 sidetrack is a -2350' horizontal Sag producer, which will target Sag reserves to the north of the parent. L1 will have a 3-1/4" protection string run across 4 faults and cemented in with the TOC left 500' outside the window, allowing production to continue from the parent well. The lateral will be completed with a 2-3/8" L-80 slotted liner with a liner top billet set at 11,985'. The proposed AL1-01 sidetrack is a-1,115' horizontal Sag producer, which will target Sag reserves to the North and West of the parent. AL1-01 will be completed with a 2-3/8" L-80 solid liner with the TOL brought just inside the protection string. The existing pert intervals are below the KOP but will not be isolated at this time. — RigWork scheduled to begin June 1st, 2015 1. MIRU and test BOPE 250 psi low and 3,500 psi high. (MASP = 2341 si 2. Bullhead kill well w/ 1.5x the tubing volume of 1 % KCI. 3. Set 4-1/2" monobore WS at 10,927' MD at 200 deg ROHS. 4. Mill 3.80" window at 10,927' and 10' of rathole. 5. Drill build section: 4.25" OH, 670' 20° de /100 planned). 6. Drill lateral section AL1: 4.25" OH, 208' 12° de /100 planned). 7. Run 3-1/4" protection string. Cement in place w/ 3 bbls 15.8ppg Class G cement. Estimated TOC at 11,425' 500' outside window). 8. Mill out shoetrack. Drill lateral section AL1 3.25" OH, 1449' 12' deg/1 00 planned). 9. Run 2-3/8" 511 L-80 slotted liner to TD w/ liner top billet set at 11,985' MD. 10. Drill lateral section AL1-01: 3.25" OH, 1115' 120 de /100 planned). 11. Run 2-3/8" 511 L-80 slotted liner to TD w/ TOL left just inside the protection string. 12. Freeze protect well to 2500' MD. 13. 1 Set TWC, RDMO. Post -Rig Work: 1. Re -install wellhouse, flowline and pull TWC. 2. Install GLVs. 3. ASRC flowback. Mud Program: • Well kill: 8.4 ppg brine (622 psi over -balance) • Milling/drilling: 8.6 ppg PowerVis for milling window and drilling (714 psi over -balance). Disposal: • All Class I & II non -hazardous and RCRA-exempt drilling and completion fluids will go to GNI at IDS 4 or Pad 3 at DS 6. • Fluids >1 % hydrocarbons or flammables must go to Pad 3. • Fluids >15% solids by volume must go to GNI. • Fluids with solids that will not pass through 1/4" screen must go to GNI. • Fluids with PH >11 must go to GNI. Hole Size: • 4.25" from 10,927' MD to 11,825' MD (AL1) • 3.25" from 11,825' MD to 13,274' MD (AL1) • 3.25" from 11,985' MD to 13,100' MD (AL1-01) Liner Program: • 3-1/4", 6.6 Ib/ft, with 3-3/16" 6.2 Ib/ft TCII connections, L-80 solid liner: 10,650' MD — 11,825 MD (AL1) • 2-3/8", 4.7 Ib/ft, L-80 511 slotted liner: 11,980' MD — 13,274' MD (AL1) • 2-3/8", 4.7 Ib/ft, L-80 511 slotted liner: 11,815' MD — 13,100' MD (AL2) • A minimum of 3 bbls of 15.8 ppg cement will be used for cementing the 3-1/4" string (TOC at —11,425' MD). • The primary barrier for this operation: a minimum EMW of 8.4 ppg (622 psi over -balance). • A crossover 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 plans WP05 for AL1 and WP-07 for AL1-01. Maximum planned hole angle is 99.6° (AL1) and 94' (AL1-01). • Magnetic and inclination surveys will be taken every 30 ft. • Distance to nearest property — 2322' • Distance to nearest well within pool — 153' (F-33A in Zone 4) Logging: • MWD directional, Gamma Ray, and Resistivity will be run over all of the open hole section. Anti -Collision Failures: • F-18AL1 fails major risk with the parent well at the KOP, F-33A, and F-33APB1. • F-18AL1-01 fails major risk with F-33A and F-33APB1. Hazards: • F-Pad is considered an H2S pad. • F-18 H2S level was recorded at 17ppm on 3/14/2014. • The lost circulation risk for both laterals F-18AL1&AL1-01 is considered to be medium. Reservoir Pressure: The reservoir pressure on F-18AL1&AL1-01 is expected to be 3,221 psi at 8,800' TVDSS (7.04 ppg equivalent). -- - Maximum expected surface pressure with gas (0.10 psi/ft) to surface is 2,341 psi. An EMW of 8.6 ppg for this well will provide 714 psi over -balance to the reservoir. Nathan Sperry CC: Well File CTD Engineer Joseph Lastufka 564-4258 Loepp, Victoria T (DOA) From: Sperry, Nathan <Nathan.Sperry@bp.com> Sent: Friday, April 24, 2015 2:52 PM To: Loepp, Victoria T (DOA) Subject: RE: PBU F-18AL1(PTD 215-068); PBU F-18AL1-01(PTD 215-069) Anti -collision Hi Victoria, F-33A is an active Zone 4 producer. In order to mitigate the consequences of a collision, we will shut in, lockout, and tag out F-33A. Our mud weight would be sufficient to overcome the pressure encountered if we were to collide with F-33A. Please let me know if you need any additional information. Regards, Nathan Sperry Drilling Engineer O: 907-564-4258 C: 907-268-8416 From: Loepp, Victoria T (DOA)[ma iIto: victoria. loepp(abalaska.gov] Sent: Friday, April 24, 2015 2:02 PM To: Sperry, Nathan Subject: PBU F-18AL1(PTD 215-068); PBU F-18AL1-01(PTD 215-069) Anti -collision Nathan, What mitigation measures allow the minor risking of major risk failure F-33A? Thanx, Victoria Victoria Loepp Senior Petroleum Engineer State of Alaska Oil & Gas Conservation Commission 333 W. 7th Ave, Ste 100 Anchorage, AK 99501 Work: (907)793-1247 Victoria. Loepp cDalaska.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 Victoria. Loepp@alaska.aov I TREF_= aw WELLHEAD= FIVIC ACTUATOR = BAKER C KB. ELEV = 70.33' BF. ELEV = 37.58' KOP= 2109 Max Angle = 93` @ 12658' _'CONDUCTOR ? Datum MD= WA '# Datum TVD = 8809 SS ID = 13-3/8- CSG, 72#, L-80, D = 12.347- 2720' Minimum ID = 3.726" a@ 10610' 4-1/2" XN NIPPLE TOP OF 7" LNR —{ 6322' I9-5/8" VMPSTOCK 648T 9-5/8" CSG, 47#, L-80, D = 8.681" 6487 ITOP OF 4-1/2" PROD LNR 1052V 4-1/2" TBG, 12.6#, 13CR-80 VAM TOP, 10522' .0152 bpf, ID= 3.958" 7" CSG, 26#, L-80 BTGM, .0383 bpf, D = 6.276" —( 10674' F-18A PERFORATION SIAMtARY REF LOG: , A NGLE AT TOP PEW: ' Note: Refer to Roduction DB for historical perf data SQE SPF INTERVAL Opn/Sqz SHOT SQZ ' 4-1/2" SLTD 10720 - 12703 SLTD 03/18/09 , , , 4-1/2" SLTD LNR, 12.6#, L-80 BT-M 1—=146' , .0152 bpf, D = 3.958" , , , , , SAF VOTES: —CHROME TBG & NIPPLES —WELL ANGLt > 70" (& 10771'- 2180' J—j 4112" HAS X M? D = 3.813" 2&W 9-5/8" DV P R GAS I FT MANE IRR S ST MD TVD DEV TYPEJ VLV LATCHI FORT DATE 3 4046 3696 51 KBG2 DWfl' BK 0 03/08/15 2 7551 6092 30 KBG2 DMY BK 0 03/08/15 1 9501 7805 27 KBG2 DW BK 0 03/19l09 6t 322' I—{ 9-5/8" X 7" "HRD" BKR ZXPN LTP, Iw/11'PBR,D=6. 6338' 9-5/8" X 7" BKR FLIX LOCK HGR, D = _' MLLOUT VVNDOW (F-18A) 6487' - 6504- 103�—t4-112' HES X NP, D = 3.813' 10406' 7" X 4-1/2' BKR 5-3 PKR, ID = 3.87" 10439' 4 t J2" HES X NP, D = 3.813" 10510' 41l2" HES XN NP, D = 3.725' 10621' 7" X 5" BKR ZXP LTP w / 12' PBR, D = 4.46" 10522' 10b4S' 7" X 5" BKR HMC /DC SLIP HGR, D = 4.45" 1055V 57x 4-l/2" XO, D = 3.930" DATE I REV BY COMMENTS DATE REV BY CON6131TS 11/061811 GRV ORIGINAL COMPLETION 03/09/15 PJC LNR/ CSG CORRECTIONS 03/09/09 N7ES SIDETRACK(F-18A) 03/11/15 PJC STATION# 1 DMY CORRECTION 04/06/09 /SV CORRECTIONS 05/31/09 MF/TLH GLV GO (04/08/09) 03/26/10 JM/JMD I DRLG DRAFT CORREC,'T10NS 03/08/15 JTG/ PJCJ GLV GO PRUDHOE BAY IMF WELL: F-18A PERMrr No: "2090180 API W: W029-20636-01-00 SEC 2, T11 N, R13F,2325' FSL 8 2194' FEL BP Exploration (Alaska) TREE = aw WELLHEAD = _ FMC ACTUATOR = BAKER C KB. B�V = -- 70 33' 13F. ELEV = _ 37.58' KOP= _ 21W Max Angle 93' @ 12656 Datum MD = NIA Datum iVD 8800' SS _ "CONDUCTOR — —_# D= 13-3/8" CSG, 72#, L-80, D = 12.347" SALT IOTES: —CHROME TBG & NIPPLES —WELL F-18AL1 & AL1-01 ANGLL.70°010771'— CTD Sidetrack I I`j 1 1 1 2180' —14-1/2' H13S X NP, D = 3.813" 25W H 9-5/8" DV FKR 2720' �—A I I I I IL GAS 1 FT Ma,NrMRR S Minimum ID = 3.725" @ 10610' 4-1/2" XN NIPPLE TOP OF 7" LNR —6322' I9-5/8" WHIPSTOCK I 6487' 9-5/8- CSG, 47#, L-80, D = 8.681" '-6487 PERFORATION SUMR ARY REF LOG: ANGLE AT TOP PERF: Note: Refer to Production DB for historical perf data 4-1/2" I SLTD 110720 - 127031 SLTD 103/18/09 ST SALT IOTES: —CHROME TBG & NIPPLES —WELL F-18AL1 & AL1-01 ANGLL.70°010771'— CTD Sidetrack I I`j 1 1 1 2180' —14-1/2' H13S X NP, D = 3.813" 25W H 9-5/8" DV FKR 2720' �—A I I I I IL GAS 1 FT Ma,NrMRR S Minimum ID = 3.725" @ 10610' 4-1/2" XN NIPPLE TOP OF 7" LNR —6322' I9-5/8" WHIPSTOCK I 6487' 9-5/8- CSG, 47#, L-80, D = 8.681" '-6487 PERFORATION SUMR ARY REF LOG: ANGLE AT TOP PERF: Note: Refer to Production DB for historical perf data 4-1/2" I SLTD 110720 - 127031 SLTD 103/18/09 ST MD TVD DEV TYPE VLV LATCH PORT DATE 3 4046L69 51 KBG2 DMY BK 0 03/08/15 2 7551 30 KBG2 DMY BK 0 03/081151 9501 27 KBG2 DMY BK 0 03/19/09 6322' 19-5/8" X 7" "HRD" BKR ZXPN LTP, w/1VPBR,D=6_ 6338' 9-5/8" X 7' BKR FLDC LOCK HGR, D = _" MLLOUT WINDOW (F-18A) 6487' - 6504' 1037E 1—j4-1/2" HES X NP, D = 3.813" 10406' H 7" X 4-1/2" BKR S-3 PKR D = 3.87" 10439' I—j4-1/2" HES X NP, D = 3.813" 10510' j--j4-1/2" HES XN NIP, D=3.80" ITOP OF 4-1/2" PROD LNR 10521' 10621' 7" X 5" BKR ZXP LTP w / 12' PBR, D = 4.46" 4-1/2" TBG, 12.6#, 13CP-80 VAM TOP, 10522' 10522' 4-1/2" WLEG, D = 3.958" .0152 bpf, ID = 3.958" 10646' 7" X 5" BKR HMC /DC SLP HGR D = 4.45" TOL-10,650'MD (in 4-1/2" solid) 10551' 5"x 4-1/2" XO, D=3.930"� 7" CSG, 26#, L-80 BTC-M, .0383 bpf, ID = 6.276" H 10674' Top of Slotted 10, 720' MD � , '\ , 90°'h TOWS 10,927' MD , 4-1/2" SLTD LNR, 12.6#, L-80 ET-M, 12746' , .0152 bpf, D = 3.958" 2-3/8" L-80 slotted liner AL1 v TOL - 2-3/8" 11,985' MD TD—13,274' MD ' TOC—111425'MD (3 bbls total) \ 3-1/4" shoe at—11,825'MD 2-3/8" L-80 slotted IinerAL1-01 3-1/4" L-80 solid liner TD 13,100' MD , l DATE REV BY CORAL MS DATE REV BY COMMENTS 11/06/81 GRV ORIGINAL COMPLETION 03/09/15 PJC LNRI CSG CORRECTIONS 03/09/09 N7ES SIDETRACK (F-18A) 03/11/15 PJC STATION # 1 DW CORRECTION 04/06/09 /SV CORRBCTIONS 05/31/09 WffLH GLV GO (04/08109) 103/26/101 JIWJMD DRLG DRAFT CORRECTIONS 03l08/15 1 JTG/ PJ GLV CJO PRUDHOE BAY UNIT WELL F 18A PERMIT No: 02090180 AR No: 50-029-20636-01-00 SEC 2, T11 N, R13E, 2325' FSL & 2194' FEL BP Exploration (Alaska) -------------------- ---------------------- --► I I 1 I I wa Uf U I 1 / I � I 1 I I I I I I _ oho I � 2 i N I U s Y I � } Q I I U 1 1 LL I f I o I O I 1 H 2 d I I I I w LL 'm m N U i 2 0pz I `o d f $uLLI = $ Y Z 1 CM N Z m U 0 3 S I 0 1 e U U I O Z a C CL Q W cm L L m a p o a ooCM LL o Q Z M QL LL 00 00 C a m O. co a`maLiLL 0 0 N W ASA `um lz U Z Q 0 v O N Q. 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LL17 o 0 0 O O CO Na d3 nF m z ym ' G Zmo� �m w m o o c c 0O oa F E t Qm O U w E d G m¢g¢ ¢o a'. o¢ o 0 0 0 0 N N N m a mo ¢ j aLLLL U LL w m N W A, ULLC > a UaUO[]�y ' ¢ = o= 33N I N ea mmmmmm w LLLLLLLLLLLL F m o O m m o I U En mm LL mm�onm c emmmn LLn mmmoo m CD U N u tf O z E O L E Q North America - ALASKA - BP Prudhoe Bay PB F Pad F-18 500292063600 F-18AL1 F-18AL1 WP05 Travelling Cylinder Report 08 April, 2015 BAKER NUGHES by Travelling Cylinder Report BAKER HUGHES Company: North America - ALASKA - BP Project: Prudhoe Bay Reference Site: PB F Pad Site Error: 0.00 usft Reference Well: F-18 Well Error: 0.00 usft Reference Wellbore F-18ALl Reference Design: F-18ALl WP05 Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Output errors are at Database: Offset TVD Reference: Well F-18 Mean Sea Level F-18A OKB @ 65.20usft True Minimum Curvature 1.00 sigma EDM R5K - Alaska PROD - ANCP1 Offset Datum Reference F-18ALl WP05 Filter type: GLOBAL FILTER APPLIED: All wellpaths within 200'+ 100/1000 of reference Interpolation Method: MD Interval 25,00usft Error Model: ISCWSA Depth Range: 10,796.84 to 13,274.00usft Scan Method: Tray. Cylinder North Results Limited by: Maximum center -center distance of 1,524.49 usft Error Surface: Elliptical Conic Survey Tool Program Date 4/8/2015 From To (usft) (usft) Survey (Wellbore) Tool Name Description 94.77 6,469.87 F-18 Srvy 2 GYD CT CMS (F-18) GYD-CT-CMS Gyrodata cont.casing m/s 6,487.00 6,504.00 F-18A Srvy 1 Blind (F-18A) BLIND Blind drilling 6,534.00 6,804.00 F-18A Srvy 2 Inc+Trend (F-18A) INC+TREND Inclinometer + known azi trend 6,902.17 10,606.89 F-18A Srvy 3 MWD+IFR+MS (F-18A) MWD+IFR+MS-WOCA MWD + IFR + Multi Station W/O Crustal 10,675.89 10,796.84 F-18A Srvy 4 MWD+IFR+MS (F-18A) MWD+IFR+MS-WOCA MWD + IFR + Multi Station W/O Crustal 10,796.84 13,274.00 F-18ALl WP05 (F-18AL1) MWD MWD - Standard Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (usft) (usft) Name (in) (in) 2,714.87 2,618.93 13 3/8" 13.375 17.500 10,522.00 8,579.99 41/2" 4.500 6.125 10,674.00 8,672.35 7" 7.000 8.500 11,825.00 8,728.61 31/4" 3.250 4.250 13,274.00 8,704.64 2 3/8" 2.375 3.000 Summary Reference Offset Centre to No -Go Allowable Measured Measured Centre Distance Deviation Warning Site Name Depth Depth Distance (usft) from Plan Offset Well - Wellbore - Design (usft) (usft) (usft) (usft) PB F Pad F-05 - F-05 - F-05 11,10a00 10,675.00 1,483.53 418.52 1,073.52 Pass - Major Risk F-05 - F-05A- F-05A 11,085.73 11,950.00 1,067.88 425.50 673.58 Pass - Major Risk F-18 - F-18 - F-18 13,274.00 11,325.00 322.56 10.08 321.98 Pass - Minor 1/10 F-18 - F-18A- F-18A 10,925.00 10,925.00 0.00 1.12 -1.02 FAIL- NOERRORS F-19 - F-19 - F-19 12,075.00 11,300.00 1,236.74 418.00 833.56 Pass - Major Risk F-19 - F-19A- F-19A Out of range F-21 - F-21 P B 1 - F-21 P B 1 Out of range F-22 - Plan F-22A - Plan F-22A Out of range F-23 - F-23 - F-23 Out of range F-23 - F-23A - F-23A Out of range F-23 - F-23B - F-23B WP03 Out of range F-24 - F-24 1_1 - F-24 L1 WP04 Out of range F-24 - F-24 L2 - F-24 L2 WP07 Out of range F-27 - F-27 - F-27 Out of range F-27 - F-27A - F-27A Out of range F-27 - F-27B - F-27B Out of range F-28 - F-28C - F-28C Out of range F-33 - F-33 - F-33 Out of range F-33 - F-33A - F-33A 11,950.00 12,000.00 138.90 1.41 138.59 Pass - Minor 1/10 F-33 - F-33APB1 - F-33APB1 11,877.10 11,950.00 165.45 1.63 165.04 Pass - NOERRORS uu - min centre to center aistance or covergent point, 61- - min separation tactor, ES - min ellipse separation 41812015 11:04:21AM Page 2 COMPASS 5000.1 Build 61 Company: North America - ALASKA - BP Project: Prudhoe Bay Reference Site: PB F Pad Site Error: 0.00 usft Reference Well: F-18 Well Error: 0.00 usft Reference Wellbore F-18AL1 Reference Design: F-18ALl WP05 BP Travelling Cylinder Report Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Output errors are at Database: Offset TVD Reference: FelkI BAKER HUGHES Well F-18 Mean Sea Level F-18A OKB @ 65.20usft True Minimum Curvature 1.00 sigma EDM R5K - Alaska PROD - ANCP1 Offset Datum Summary Reference Offset Centre to No -Go Allowable Measured Measured Centre Distance Deviation Warning Site Name Depth Depth Distance (usft) from Plan Offset Well - Wellbore - Design (usft) (usft) (usft) (usft) PB F Pad F-34 - F-34A- F-34A 11,675.00 10,875.00 1,322.26 421.79 908.48 Pass- Major Risk F-34 - F-34APB1 - F-34APB1 11,675,00 10,875.00 1,322.26 421.81 908.46 Pass- Major Risk F-34 - F-34B - F-34B 10,800.00 10,675.00 374.33 357.48 65.33 Pass - Major Risk F-35 - F-35 - F-35 Out of range F-42 - F-42 - F-42 Out of range F-47 - F-47 - F-47 Out of range F-47 - F-47A - F-47A Out of range Offset Design PB F Pad - F-05 - F-05 - F-05 Offset Site Error. 0.00 usft Survey Program: 100-GYD-CT-CMS, 9600-CB-GYRO-MS Rule Assigned: Major Risk Offset Well Error: 0.00 usft Reference Offset Semi Major Axis Measured Vertical Measured Vertical Reference Offset Toolface + Offset Wellbore Centre Casing - Centre to No Go Allowable Waming Depth Depth Depth Depth Azimuth +N/S +E/-W Hole Size Centre Distance Deviation (usft) (usft) (usft) (usft) (usft) (usft) (I (usft) (usft) (in) (usft) (usft) (usft) 11,050.00 8,725.65 10,360.00 8,178,74 99.06 31,87 119.21 3,799.99 2,681.22 5.875 1,520+41 397.62 1,147.60 Pass - Major Risk 11,062.09 8,725.72 10,375.00 8,200.06 99.07 31.92 117.59 3,807.42 2,691.94 5.875 1,514.23 403.27 1,134.48 Pass - Major Risk 11,064.30 8,725.73 10,400.00 8,221.28 99.08 31.96 117.93 3,814.85 2,702.86 5.875 1,508.77 404.35 1,126.45 Pass - Major Risk 11,075.00 8,725.79 10,425.00 8,242.40 99.09 32,01 116.58 3,822.28 2,713.99 5.875 1,503.99 408.74 1,115.96 Pass- Major Risk 11,075.00 8,725.79 10,450,00 8,263.42 99.09 32.06 117.37 3,829.69 2,725.31 5.875 1,499.56 408.88 1,109.90 Pass - Major Risk 11,075.00 8,725.79 10,475.00 8,284.33 99.09 32.11 118.16 3,837.19 2,736.79 5.875 1,495.61 409.06 1,104.37 Pass - Major Risk 11,075.00 8,725.79 10,500.00 8,305.12 99.09 32.17 118.95 3,844.83 2,748.39 5.875 1,492.09 409.23 1,099.32 Pass - Major Risk 11,075.00 8,725.79 10,525.00 8,325.78 99.09 32.23 119.74 3,852+62 2,760.10 5.875 1,488.98 409.40 1,094.76 Pass- Major Risk 11,075.00 8,725.79 10,550.00 8,346.32 99.09 32.28 120.53 3,860,56 2,771.93 5.875 1,486.30 409.58 1,090.68 Pass- Major Risk 11,075.00 8,725+79 10,575.00 8,366.75 99.09 32.35 121.32 3,868.49 2,783.97 5.875 1,484.23 409.80 1,087.21 Pass - Major Risk 11,075.00 8,725.79 10,600,00 8,387.07 99.09 32.43 122.10 3,876.22 2,796.31 5.875 1,482.93 410.03 1,084.59 Pass - Major Risk 11,075.00 8,725.79 10,625.00 8,407.28 99.09 32.50 122.89 3,883.76 2,808.95 5.875 1,482.43 410.26 1,082.81 Pass - Major Risk 11,087.46 8,725.86 10,650.00 8,427.37 99.10 32.57 121.22 3,891.11 2,821.89 5.875 1,482.39 414.78 1,077.17 Pass - Major Risk, CC 11,100.00 8,725.93 10,675.00 8,447.31 99.11 32.67 119.50 3,898.29 2,835.14 3.750 1,483.53 418.52 1,073.52 Pass- Major Risk, ES, SF 11,100.00 8,725.93 10,700.00 8,467.07 99.11 32.76 120.29 3,905+35 2,848.73 3.750 1,485.14 418.81 1,073.95 Pass - Major Risk 11,100.00 8,725+93 10,725.00 8,486.65 99.11 32.86 121.07 3,912.27 2,862.65 3.750 1,487.53 419.09 1,075.23 Pass- Major Risk 11,100.00 8,725.93 10,7%00 8,506.04 99.11 32.96 121.85 3,919.06 2,876.90 3.750 1,490.69 419.37 1,077.35 Pass- Major Risk 11,100.00 8,725.93 10,775.00 8,525,27 99.11 33.07 122.61 3,925.71 2,891.42 3.750 1,494.59 419.72 1,080.21 Pass - Major Risk 11,100.00 8,725.93 10,800.00 8,544.38 99.11 33.19 123.37 3,932.22 2,906.17 3.750 1,499.15 420.06 1,083.81 Pass - Major Risk 11,100.00 8,725.93 10,a25.00 8,563.37 99.11 33.31 124.12 3,938.60 2,921.13 3.750 1,504.39 420.41 1,088.15 Pass - Major Risk 11,100.00 8,725.93 10,850,00 8,582,23 99.11 33.42 124.85 3,944.85 2,936.30 3.750 1,510.28 420.76 1,093.20 Pass - Major Risk 11,100.00 8,725.93 10,875.00 8,600.94 99.11 33.57 125.58 3,950.95 2,951.71 3.750 1,516.85 421.17 1.098.93 Pass - Major Risk 11,110.99 8,725.99 10,900.00 8,619.50 99.13 33.71 124.12 3,956.91 2,967.37 3.750 1,523.84 424.13 1,102.36 Pass - Major Risk CC - Min Centre to center distance or covergent point, SF - min separation factor, ES - min ellipse separation 41812015 11:04:21AM Page 3 COMPASS 5000.1 Build 61 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 LATERAL The permit is for a new wellbore segment of 'existingi well Permit No. L%� API No. 50-�x - 6)L0. (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 onpermit). 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 (CompM 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 PTD#: 2150680 Company BP EXPLORATION (ALASKA) INC Initial Class/Type Well Name: PRUDHOE BAY UNIT F-18AL1 Program DEV Well bore seg [] DEV / PEND GeoArea 890 Unit 11650 On/Off Shore On Annular Disposal Administration 17 Nonconven. gas conforms to AS31.05.030(j.1.A),(j.2.A-D) NA 1 Permit fee attached NA 2 Lease number appropriate Yes Surface location in ADL 028280, top prod interval & TD in ADL 028277. 3 Unique well name and number Yes 4 Well located in a defined pool Yes PRUDHOE BAY, PRUDHOE OIL POOL - 64015, governed by CO 341D 5 Well located proper distance from drilling unit boundary Yes CO 341 D, Rule 2: There shall be no restrictions as to well spacing except that no pay shall be 6 Well located proper distance from other wells Yes opened in a well closer than 500 feet to the boundary of the affected area. Planned well 7 Sufficient acreage available in drilling unit Yes conforms to CO 341 D, Rule 2. 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 4/16/2015 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 Yes 15 All wells within 1/4 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 18 Conductor string provided NA Conductor set in PBU F-18 Engineering 19 Surface casing protects all known USDWs NA Surface casing set in PBU F-18 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 No Productive interval will be completed with uncemented slotted liner 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 NA 26 Adequate wellbore separation proposed Yes Anti -collision analysis complete; F-33A fails major risk -will SI and LO during drilling 27 If diverter required, does it meet regulations NA Appr Date 28 Drilling fluid program schematic & equip list adequate Yes Max formation pressure is 3221 psi(7.04 ppg EMW); will drill w/ 8.6 ppg EMW VTL 4/24/2015 29 BOPEs, do they meet regulation Yes 30 BOPE press rating appropriate; test to (put psig in comments) Yes MPSP is 2341 psi; will test BOPS to 3500 psi 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 F-Pad wells are H2S-bearing. H2S measures are required. Geology 36 Data presented on potential overpressure zones Yes Planned drilling mud program (8.6 ppg) appears adequate to control operator's forecast Appr Date 37 Seismic analysis of shallow gas zones NA pore pressure gradient of 7.1 ppg. SFD 4/16/2015 38 Seabed condition survey (if off -shore) NA 39 Contact name/phone for weekly progress reports [exploratory only] NA Geologic Engineering Public Commissioner: Date: Commissioner: Date Commissioner Date Y) TS Z,� l z? 1 IS 02$44�
