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215-062
Davies, Stephen F (DOA) From: Lastufka, Joseph N <Joseph.Lastufka@bp.com> Sent: Wednesday, June 17, 2015 10:37 AM To: Davies, Stephen F (DOA); Bettis, Patricia K (DOA) Cc: Browning, Zachary H Subject: RE: F-24A WP_08 Steve, That is correct. Please withdraw PTD #'s 215-062 and 215-063 (F-241-1 and F-241-2). Thanks, Joe From: Davies, Stephen F (DOA)[mailto:steve.davies@alaska.gov] Sent: Wednesday, June 17, 2015 10:28 AM To: Lastufka, Joseph N; Bettis, Patricia K (DOA) Cc: Browning, Zachary H Subject: RE: F-24A WP_08 Joe, From your email below, I understand that BP is then withdrawing Permits to Drill 215-062 and 215-063. If this is correct, please let me know so that I can close out those two permit files. Thanks, Steve Davies AOGCC 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 Steve Davies at 907-793-1224 or steve.davies@alaska.gov. From: Lastufka, Joseph N [mailto:Joseph.Lastufka@bp.com] Sent: Tuesday, June 16, 2015 11:13 AM To: Davies, Stephen F (DOA); Bettis, Patricia K (DOA) Cc: Browning, Zachary H Subject: F-24A WP_08 Steve, We have changed our drilling plan (PTD # 215-062 and 215-063) and no longer will be drilling 2 laterals, instead we will be drilling an A sidetrack. Please expedite the PTD that will be sent as soon as possible, as we are currently on -site drilling. Please let me know if you have any questions. Davies, Stephen F (DOA) From: Lastufka, Joseph N <Joseph.Lastufka@bp.com> Sent: Tuesday, June 16, 2015 11:13 AM To: Davies, Stephen F (DOA); Bettis, Patricia K (DOA) Cc: Browning, Zachary H Subject: F-24A WP_08 Attachments: F-24 L2 WP08.txt Steve, We have changed our drilling plan (PTD # 215-062 and 215-063) and no longer will be drilling 2 laterals, instead we will be drilling an A sidetrack. Please expedite the PTD that will be sent as soon as possible, as we are currently on -site drilling. Please let me know if you have any questions. Thanks, Joe THE STATE Of .,c-,LASKA 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 vain: 907.279.1433 Fox:907.276.7542 www.aoccc.alaska.gov Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU F-24L1 BP Exploration (Alaska), Inc. Permit No: 215-062 Surface Location: 1875' FNL, 2172' FEL, SEC. 02, T11N, R13E, UM Bottomhole Location: 34' FSL, 1591' FWL, SEC. 27, T12N, RUE, UM Dear Mr. McMullen: 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, 9-1— Cathy P. Foerster Chair DATED this / 7 a y of April, 2015. STATE OF ALASKA RECEIVED OIL AND GAS CONSERVATION C( A ON PERMIT TO DRILL 20 AAC 25.005 010 2 2015 e-y r+ r+Ili", 1 a.Type of work: 1 b.Proposed Well Class:, ® Development Oil ❑ Service - Wini ® Single Zone 1 c. Spec p posed 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-241L1 - 3. Address 6. Proposed Depth: 12. Field / Pool(s) P.O. Box 196612, Anchorage, Alaska 99519-6612 MD 14017' • TVD 8929'ss - Prudhoe Bay / Prudhoe Bay 4a. Location of Well (Governmental Section): 7. Property Designation (Lease Number): Surface: ADL 028280 & 028278 , C �=7 1 1875' FNL, 2172' FEL, Sec. 02, T11N, RUE, UM 8. Land Use Permit: � - i 13. Approximate Spud Date: Top of Productive Horizon: 3450' FSL, 1395' FEL, Sec. 34, T12N, R13E, UM s June 15, 2015 9. Acres in Property: 14.Distance to Nearest Property: Total Depth 34' FSL, 1591' FEL, Sec. 27, T12N, R13E, UM 2560 6000' 4b. Location of Well (State Base Plane Coordinates - NAD 27): 10.KB Elevation above MSL: 70.78' feet 15.Distance to Nearest Well Open Surface: x 652648 y- 5974939 • Zone- ASP4 GL Elevation above MSL: 35.58' , feet to Same Pool: 750' 16. Deviated Wells: Kickoff Depth: 12035' feet 17. Maximum Anticipated Pressures in psig (see 20 AAC 25.035) Maximum Hole Angle: 100 degrees Downhole: 3249 - Surface: 2369 18. Casing Program Specifications Top - Setting Depth - Bottom Quantity of Cement, c.f. or sacks Hole Casing Weight Grade Coupling Length MD TVD MD TVD (including stage data) 4-1/4" 2-7/8" 6.4# L-80 STL 1997' 12020' 8877'ss 14017 8929'ss Uncemented Slotted 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). 1 12430' 9240' 12144' 12387' 9209' None Casing Length Size Cement Volume MD TVD Conductor / Structural 80' 20" 8 cu yds Concrete 36' - 116' 36' - 116' Surface 2642' 13-3/8" 3909 cu ft Permafrost II 36' - 2678' 36' - 2662' Intermediate 11837' 9-5/8" 2240 cu ft Class'G', 575 cu ft Class'G% 133 cu ft PF C 33' - 11844' 33' - 8820' Production Liner 816' 7" 314 cu ft Class 'G' 11614' - 12430' 8652' - 9240' Perforation Depth MD (ft): 11908' - 12185' Perforation Depth TVD (ft): 8867' - 9067' 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: 22. 1 hereby certify that the foregoing is true and correct: Date Contact Zach Browning, 564-5220 il achary.Browning@bp.com Printed Name - johry)y�' ,u�en Title Engineering Team Leader ry 9@bp.com _ 564-4711 �. 7,2' Signature_ Phone Date Commission Use Only Permit To Drill L%�i- 450-029-21030-60-00 API Number: Permit Approval Date: 1 See cover letter for I Number: 1411-7 1 !� 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 [�] Other: j f S f v O U 5 contained shales: Samples Req'd: ❑ Yes �No Mud Log Req'd: []Yes' 3"No r!h h u/cT r p, e-V_-" tr r to Z 5Z)O P5 ' H2S Measures: 9Yes ❑ No Directional Survey Req'd: L37 Yes ❑ No Spacing exception req'd: ❑ Yes dNo inclination -only svy Req'd: ❑ Yes © No APPROVED BY APPROVED B COMMISSIONER / lJ THE COMMISSION Date Form 10-401 Revised 10/2012 This permit is valid for 24 mo s t d tN ar val (20 AAC 25.005(g)) Submit Form and Attachments In Duplicate To: Alaska Oil & Gas Conservation Commission From: Zach Browning CTD Engineer Date: March 27, 2015 Re: F-24 L1&L2 Permit to Drill Request Obp Approval is requested for a permit to drill a CTD sidetrack lateral from well F-24 with Coiled Tubing Drilling rig Nordic 2 on or around April 25th, 2015. The F-24 L1 &L2 sidetracks will each be single string exits through the existing 7" liner and kick off in the shublik at 44 degrees inclination. Both wells will build and land in Zone 4B. The proposed L1 sidetrack is a -1982' horizontal Zone 4 producer, which will target Zone 4B reserves to the north of the parent. L1 will be completed with a 2-7/8" L-80 slotted liner with the top of the liner brought just inside the window to 12,020' MD. The proposed L2 sidetrack is a -2615' horizontal Zone 4 producer, which will target Zone 4B reserves to the North and West of the parent. L2 will be completed with a 3-1/4" x 2-7/8" 13Cr solid liner completion cemented in place and selectively perforated based off of logs. The TOC will be left 500' outside the window allowing production to be maintained from both the parent and L1. The existing perf intervals are below the KOP but will not be isolated at this time. If production from the parent or L1 needs to be shut off in the future it will be isolated via a LTP. RigWork scheduled to begin June 15th, 2015 1. MIRU and test BOPE 250 psi low and 3,500 psi high. (MASP = 2369 si 2. Mill 3.80" window at 12,035' and 10' of rathole. 3. Drill build section: 4.25" OR 147' 350 de /100 planned). 4. Drill lateral section: 4.25" OH, 1835' 121 de /100planned) 5. Run 2-7/8" L-80 slotted liner leaving TOL at -12,020' MD. 6. Set 4-1/2" x 7" Delta WS with top set at 11,995' MD 7. Mill 3.80" window at 11,995' MD and 10' of rathole. 8. Drill build section: 4.25" OH, 720' 251 de /100 planned). 9. Drill lateral section: 4.25" OH, 1895' 121 de /100planned) 10. Run 3-1/4" x 2-7/8" 13Cr solid liner leaving TOL at-11,625' MD. 11. Pump primary cement leaving TOC at 12,495' MD (500' outside window), 23.1 bbls of 15.8 ppg liner cmt planned 20% OH excess). 12. Perform GR/CCL cleanout/logging run. 13. Perforate well based on log interpretation. 14. Freeze protect well to 2500' MD 15. Set TWC, RDMO Post -Rig Work: 1. Re -install wellhouse, flowline and pull TWC. 2. Install GLVs. 3. ASRC flowback. SIT. Mud Program: • Well kill (if needed): 8.4 ppg brine (595 psi over -balance) • Milling/drilling: 8.6 ppg PowerVis for milling window and drilling (686 psi over -balance). Disposal: • All Class I & II non -hazardous and RCRA-exempt drilling and completion fluids will go to GNI at DS 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 12,035' MD to 14,017' MD (L1) • 4.25" from 11,995' MD to 14,610' MD (L2) Liner Program: • 2-7/8", 6.4 Ib/ft, L-80 STL slotted liner: 12,020' MD — 14,017' MD (L1) • 3-1/4", 6.6 Ib/ft, with 3-3/16" 6.2 Ib/ft TCII connections, 13Cr solid liner: 11,625' MD — 12,900 MD (1-2) • 2-7/8", 6.4 Ib/ft, 13Cr STL solid liner: 12,900' MD — 14,610' MD (1-2) • A minimum of 23.1 bbls of 15.8 ppg cement will be used for L2 liner cementing (TOC at—12,495' MD). • The primary barrier for this operation: a minimum EMW of 8.4 ppg (595 psi over -balance). • 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 plans WP_04 for L1 and WP_07 for L2. Maximum planned hole angle is 100°(L1) and 92°(L2), inclination at kick off point is 440 for both laterals. • Magnetic and inclination surveys will be taken every 30 ft. No gyro will be run. • Distance to nearest property — 6000' • Distance to nearest well within pool — 750' (T-07 to F-24L1) Logging: • MWD directional, Gamma Ray, and Resistivity will be run through the entire open hole section. • Cased hole GR/CCL logs will be run inside casing after completing L2. Perforating: • 2" Powerjet, 60 deg random phasing, 6 spf, pert guns. 1-1/4" CSH work string, & 2-1/16" CSH. • The primary barrier for this operation: a minimum EMW of 8.4 ppg (595 psi over -balance). ' • A X-over shall be made up to a safety joint including a TIW valve for all tubulars ran in hole. Anti -Collision Failures: • F-24 fail major risk — No errors (parent well) • F-241-2 fails major risk with F24L1 — No errors (fails at KO) Hazards: • F-Pad is considered an H2S pad. • F-24 H2S level was recorded at 100ppm on 2/24/2014. • The lost circulation risk for both laterals F241_1 &L2 is considered to be Medium. Reservoir Pressure: s • The reservoir pressure on F-241-1&L2 is expected to be 3,249 psi at 8,800' TVDSS (7.1 ppg equivalent). i • Maximum expected surface pressure with gas (0.10 psi/ft) to surface is 2,369 psi. • An EMW of 8.6 ppg for this well will provide 686 psi over -balance to the reservoir. Zach Browning CC: Well File CTD Engineer Joseph Lastufka 564-5220 TRH = 4" CNV WELLHEAD= WEVOY ACTUATOR = BAKER KB. ELEV = 70.78' BF. ELEV = 37.44' KOP = 2400' Mtox Angie = 57 @ 78W Datum ND= 1191313-3/8" FOC Datum TV D = 8800' SS 13-3/8" CSG, 72#, L-80, D = 12.347" 2679' 2679' F -24 Minimum ID = 2.313" a@ 11606' 4-1/2" X 2-7/8" NIP REDUCER 112" BKR ONE SET PATCH (03/19/10) 11390' - 11420' TOP OF 7" LNR 1--1 11614' 4-1/2" LNR, 12.6#, L-80, .0152 bpf, D = 3.953" 1-1 11689' 9-5/8" LNR, 47#, L-80, .0732 bpf, D = 8.681" (-1 11870' PERFORATION SLA AARY REF LOG: SWS BHCS ON 11/12/83 ANGLE AT TOP PEW: 43 @ 11908' Note: Refer to Production DB for historical perf data SIZE SPF KnERVAL Opn/Sgz DATE 3-318" 6 11908 - 11980 O 03/15/88 3-1/8' 4 12072 - 12138 O 08/07/88 3-1/8" 4 12148- 12185 S 01/21/88 PBTD j 1238T �� 7" LNR, 26#, L-80 U4S, .0383 bpf, D = 6.276" 12428' AFETY NOTES: t 2183' 14-1/2" OTIS SSSV NIP, ID = 3.813" GAS LIFT MANDRlS ST MD TVD DEV TYPE VLV LATCH PORT DATE 11 3270 3176 33 OTIS LBD DOME RM 0 03/27/10 10 r 5800 4826 53 OTIS LBD DMY RA r 0 01/02/92 9 7810 5980 57 OTIS LBD DOME RM 0 03/27110 8 9082 6756 47 OTIS LBD OW RA 0 01/02192 9868 7308 44 OTtS LBD DOME RM 0 03/27/10 6 10315 7641 41 OTIS LBD DMY RA 0 01/02/92 5 10462 7752 41 OTIS LBD DMY RA 0 01/02/92 4 10769 7986 40 OTIS LBD DMY RA 0 01/02/92 3 10913 8097 39 OTIS LBD SO RM 24 03/27/10 2 11262 r,8376 36 OTIS LBD OW RA 0 01/02/92 "1 11409 r8M4900 40 1 OTIS LBD DMY I RM 0 04/06/09 " S I A S l= (:V V tJd3) t5Y NA I GH (INMI9/10) 11475' 4 1/2" OTIS XA SLD SLV D = 3.813" 11532' BOT PBR SEAL 11556' 9 5/8" BOT PKR (3-H) D = 3.958" 11606' 9 518" BOT PKI R (3-H) ID = 3.958" 11606' 4-1/2" OTIS X NP, D = 3.813" 11606--1 4-1/2" X 2-7/8" X NP REDUCER, D = 2.313" (02/14110) 11649' 4-1/2" OTIS XN NIP, D = 3.725" 11689' 4-1/2" TBG TAtL, D = 3.958" F77TTW71—FIELMID TT LOGGED 11/15/83 11971' 1—dMARKERJOINT 12144' 1--� BP - 07/23/93 FN (rD 1213& ELND PRUDHOE BAY UNTT WELL: F-24 PEFW No:'1831540 API No: 50-029-21030-00 SEC 2, T11 N, R13E DATE REV BY COWARSITS DATE REV BY OORMAENT5 11/17/83 ORIGINAL COMPLETION 03/05/10 SEW/RPC C/S, NP RED & PLUG (02/14/10) 10/05/01 RWTP CORRECTIONS 03/29/10 CJN(PJC PULL PLUG/ CYO GLV (03/27/10) 03/18/06 RLNYPAG BPS TION 03/27/09 MAM RK TREE CIO (03/21 /09) 05/31/09 N M-H I GLV GO (04/03/09 & 04/06/09) BP Exploration (Alaska) 06/30/09 DAV/TLH CATCHER SUB SET (04/05/09) VYELLHEAD= WEVOY ACTUATOR= BAKR KB. E LEV = i 70.78' BF. E-EV = 37A4' KOP = ---- 24W Max Angle = 57_@_7800' DaturnkU= 11913' DaturnTVD= 8800' SS D= 13-3/8" CSG, 72#, L-80 BUTT, D = 12.347' -4 2679'--'/ Prop.sal Minimum ID = „ ny @ TOP OF CE41B14T N l A (XX/XX/15) — OF 3-1/4" X 2-7/8 " 130-85 LNR H -11625 TOP OF 7" LNR 11614' 4-1/2" TBG-PC, 12.6#, L-80 BIfTT, 11690' _0152 bpf, D = 3.953" 9-5/8` LNR, 47#, L-80, .0732 bpf, D=8.681" 1 887W 7" MARKMJOgff ! 11976_--- 7" X 4-1/2" DB-TA WHPSTOCK (XX/XX/15) -11995 44" INC- TOP OF 2-718" LNR M12020 7" X 4-1/2" DELTA VWIPSTOCK {XXlXXl15) �12035 PERFORATION SUMMARY REF LOG: SWS BRCS ON 11/12/83 ANGLE AT TOP PE RF: NA Note: Refer to Production DB for historical pert data SEE I SPF I INTERVAL I Opn/Sgz I SHOT I SOZ SEE PAGE 2 FOR PERFORATION DATA 44* 3-3/8' BP (07123/93) - FN @ 12138' EFND 12144' 7` LNR, 26#, L-80 U4S, .0383 bpf, D = 6276' 1230$' 7" LNR, 29#, L-80 BUTT, .0371 bpf, ID = 6.184" 12428' F -2 4 SAFETY NOTES: L'I & L2 2183' 41 /2" OTIS SSSv NP, D = 3.813" 2596' �9 5/8" DV PACKER OTIS GAS LIFT MA NnRFA S ST MD I TVD DEV TYPEI VLV LATCH PORT DATE 11 3270 3814 35 LBD DOME RM 16 03l27/10 10 5800 4834 53 LBD DMY RA 0 11/17/83 9 7810 5989 r 57 LBD DOME RM r 16 0307110 8 9083 6765 47 LBD DMY RA 0 11/17/83 7 9868 7318 43 LBD DOME RM 16 03/27/10 6 10315 7651 41 LBD DMY RA 0 11/17/83 5 10463 T762 41 LBD DMY RA 0 11/17/83 4 10769 7995 40 LBD DMY RA 0 11/17/83 3 10914 8107 39 LBD SO RM 24 03/27/10 2 11263 8387 38 LBD DMY RA 0 11/17/83 1 11410 8500 41 1 LBD I "DMY I RM 0 104106109 a IA W 1 = Um T UUV tNkD t3Y NA IGH (03/19/10) 11475' 4 1/2" OTIS XA SLD SLV ID = 3.813" 11532' BOT PBR SEAL 11556' 9 5/8" X 4-1/2' BOT PKR (3-H} D = 3.958" 11606' 4-1/2" QT6 X NP, 3.813" {XX/XXl15} 43° INC- ^11625 3.70" BKR DB�LOY SLV, D = 3A0" 11614` 9-518" X 7` BKR LNR HGR, D = " 11648' 4-1Y2` OTIS X NP, MILLED TO = 3.80" (XX/XX/15) 11690`j- 4-1/2" TBG TAL, D - 3.95ir 11683' B.MD TT LOGG®11/15/83 3-3/16" X 2-7/8" XO, D 2377" I 2FA RA TAGS 3-1/4" LNR, 6.6#, �- L-80 TCII, .0079 bpf, D = 2.850" 2-7/8" LNR, #, 13Cf STL, -74610 1.0058bpf,[D=2441' �12020 3.70" DEPLOY SLV, ®= 3.00" 2-7/8" SLID LNR, #, L-80 STL, ^ 13271 .0058 bpf, D = 2-441" DATE 11/17/83 )OWOU15 03/08115 PRUDHOE BAY UNIT WELL- F 24 L1 & L2 cif No: '1831540, AR No: 50-029-21030-00 (60)/(61) SEC 2, T11 N, R13E, 1875' FNL & 2172' FEF REV BY CORN ENTS DATE REV BY OOAaf3ffS ORIGINAL COMPLETION CID MULIT-LATERAL (I -24 L11 1-2) PJC BUILD PROPOSAL BP Exploration (Alaska) F-24 r'y r DATE RRUDHOEBAY LMT REV BY 00MM8NT5 DATE REV BY COMvBdiS PERFORATION Sl1MNARY REF LOG: SWS BRCS ON 11/12/83 ANGLE AT TOP PERF: ': Nate: Refer to Production DB for historical pert data SIZE SPF INTERVAL Opn/Sgz SHOT SQZ 3-318" d 11908- 11912 S 01J05188 01/21/88 3-38' 6 11908 - 11980 O 03/15/88 3-1/8" 4 12072 - 12138 S 06/25186 01/21/88 3-3/8" 4 12f?72 - 12138 O 08/07l88 3-3/8" 6 12075 - 12095 O 05/29l95 3-1/8" 4 12148 - 12185 S 06/25l86 01/21/88 3-118" 4 12170 - 12185 S 03/26186 06/14/86 F-24 L1 F-24 L2 WELL:- F 24 L1 & L2 PERMITNo- '18315d0, --, AR No. 50-029-21030-� {fi0}J{6t `- SEC 2, T11 N, R73E, 1875' FPL � 2172' FEL 11/17/83 0(agNAL COMPLETION (�/XXlt CID MULff-LATERAL (� 2d L1 i L2; 03/08it5 PJC BIRD PROPOSAL BP Exploration (Alaska) ) �21 Q a O CL a Q m N O N td JLL L Z aLL `aiiii a m Cl) W MI mum a U z p O � L N O Y o N pp U Z m ^ U Q CL U) 3 m 'C N Y 3 O W ui u .o C O N L d d d d O R C N V R u aci � CD c v w � O U m � A � r J F ri Z UJ ❑ 0 O a (D m a m F- .a U IL m 0- U) Q O U > CL m a E Q o d J J L 6 LL V V V O ` c] N N N z d d LL LL. 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O I- N m O>> O O m J F 2 (A O Y o M (D N C d o m ri E N O U G Q. N m a m O U a. m d E 2 m c N m � U N d m `o U :6 U d d O n N M 0 1- LL N aD (O Cl! U C N M O O N N . O N aD (D U 0 .�.. Q U> C)O O O O O O O O C m d m m d L p O E d0 m 7 a (D m O Q J J N A N V L= 6 LL V V V d O m N N N Z d d LL li LL Q- C_ O c a G tR ♦ W a O1 C E c°�a`m33a L) m cn J T d Z � � o p m O � O p m C ] m m d p E ¢ rn M E N LL -O a m O a O c c U LL H Y V w (D w M m M C� I- N Q1 � u] N (O '7 (D 1 (n (n (D Ln (o co to � g v v v v v v c d + _ m c =o O O V (D V (D c' O LD Ql L!l N (D O N M V P- N O V 0 O M M O O N m O m N N m o M O J M N N M M M N N V (D m N h aD O O M V (D N V h N CC L O N rh N O of .- M O I- D) m M D O n m N O. N I- m m a) a) m W aD aD 00 a0 m DO m M O O 06 w 0 0 m m 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 d L O O 6 6 6 N N N Il r-� O O M u'1 O M O N M O. y W O O O (D O N V I- O m N N N N C'i N m "t d N C O O C C Q IL E J rl F � o x h F LL a.+ o y �n c T S (u!/Ijsn OSL) (+)4uop /(-)41nos - - - N x � I � D o � �00000000000o a3 n J - Nm "1v pry-rym ---.- i7, ���2v-Z2 Sa I N 3�mm��n��vo�� - o V4�44444V4V4-_.-- o au,6 O .NONom m �a���mi8gmmmo 30 ommI - 000000000 - - om�m������ o�J y (ut/}Tsn OS) gldaQ poilian onil 2m—= amid$ QNJ 3a'- LL ' m 0 • N d' 7 ry N r., a � M w 00 OFy�p n(ut/ isn tA Im �oz NOW am* 9 K IL !(k § North America - ALASKA - BP Prudhoe Bay PB F Pad F-24 500292103000 F-24 L1 F-24 L1 WP04 Travelling Cylinder Report 25 March, 2015 wr P ja &I BAKER HUGNES *440, by z44i Company: North America - ALASKA - BP Project: Prudhoe Bay Reference Site: PB F Pad Site Error: 0.00 usft Reference Well: F-24 Well Error: 0.00 usft Reference Wellbore F-24 L1 Reference Design: F-24 1_1 WP04 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: ri.s BAKER HUGHES Well F-24 Mean Sea Level ORKB @ 70.78usft True Minimum Curvature 1.00 sigma EDM R5K - Alaska PROD - ANCP1 Offset Datum Reference F-24 L1 WP04 Filter type: GLOBAL FILTER APPLIED: All wellpaths within 200'+ 100/1000 of reference Interpolation Method: MD Interval 25.00usft Error Model: ISCWSA Depth Range: 11,900.00 to 14,017.00usft Scan Method: Tray. Cylinder North Results Limited by: Maximum center -center distance of 1,598.18 usft Error Surface: Elliptical Conic Survey Tool Program Date 3/25/2015 From To (usft) (usft) Survey (Wellbore) 100.00 11,900.00 1 : Schlumberger GCT multishot (F-24) 11,900.00 14,017.00 F-24 L1 WP04 (F-24 L1) Casing Points Summary Tool Name Description GCT-MS Schlumberger GCT multishot MWD MWD - Standard Measured Vertical Casing Hole Depth Depth Diameter Diameter (usft) (usft) Name (in) (in) 110.00 39.22 Conductor 200.000 200.000 2,679.00 2,591.89 Surface Casing 13.375 17.500 11,870.00 8,768.65 Intermediate Casing 9.625 12.250 14,017.00 8,929.27 31/4" 3.250 4.250 Site Name Offset Well - Wellbore - Design PB F Pad F-19 - F-19 - F-19 F-22 - Plan F-22A - Plan F-22A F-24 - F-24 - F-24 F-33 - F-33 - F-33 F-36 - F-36 - F-36 F-36 - F-36L1 - F-361_1 WP05 F-36 - F-361_2 - F-361_2 WP05 F-36 - F-361_3 - F-361_3 WP05 F-37 - Plan F-37A - Plan #8 F-37 F-37 - Plan F-37ALl - Plan #8 F-37ALl F-48 - F-48 - F-48 PB R Pad Plan R-42 - Plan R-42 - Plan #5c R-42 PB T Pad T-01 - T-01 - T-01 T-07 - T-07 - T-07 Reference Offset Centre to Measured Measured Centre Depth Depth Distance (usft) (usft) (usft) 12,050.00 12,050.00 0.19 12,932.10 12,400.00 648.79 12,932.10 12,400.00 648.79 12,932.10 12,400.00 648.79 12,932.10 12,400.00 648.79 13,225.00 13,550.00 939.24 13,225.00 13,550.00 939.24 12, 275.00 11, 825.00 1,596.76 14,012.36 18,150.00 419.52 14,017.00 8,625.00 982.09 No -Go Allowable Distance Deviation Warning (usft) from Plan (usft) Out of range Out of range 0.96 -0.68 FAIL-NOERRORS Out of range 413.94 272.82 Pass - Major Risk 406.86 279.39 Pass - Major Risk 406.86 279.39 Pass - Major Risk 406.17 280.03 Pass - Major Risk 316.29 622.47 Pass - Major Risk 316.50 622.26 Pass - Major Risk 334.67 1,270.00 Pass - Major Risk 188.17 235.76 Pass - Major Risk Out of range 352.79 736.26 Pass - Major Risk Offset Design PB F Pad - F-24 - F-24 - F-24 Offset Site Error: 0.00 usft Survey Program: 100-GCT-MS Rule Assigned: NOERRORS 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 Warning Depth Depth Depth Depth Azimuth +N/S +E/-W Hole Size Centre Distance Deviation (usft) (usft) (usft) tusk) (usft) (usft) (°) (usft) (usft) (in) (usft) (usft) (usft) CC - Min centre to center distance or covergent point, SF - min separation factor, ES - min ellipse separation 3/25/2015 9:48.24AM Page 2 COMPASS 5000.1 Build 61 I 1 I 1 I 1 i I I I I I I \ 1 1 I I — I 1 1 O I I _ I 1 I i I I I 1 1 I 1 1 I I I I x I I I I I I 1 I 1 I I I I I I �U I I I TRANSMITTAL LETTER CHECKLIST WELL NAME:L—Y ���� PTD: Zi �7i Development Service _ Exploratory _ Stratigraphic Test _ Non -Conventional 17 FIELD: POOL: a "6 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 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 (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 PTD#:2150620 Company BP EXPLORATION (ALASKA) INC Initial Class/Type Well Name: PRUDHOE BAY UNIT F-241_1 Program DEV Well bore seg L� DEV / PEND GeoArea 890 Unit 11650 On/Off Shore On Annular Disposal E Administration 1 Permit fee attached Yes 2 Lease number appropriate Yes Surface location in ADL 028280; portion of wellbore passes thru ADL 028277; 3 Unique well name and number Yes TD in ADL 028278. 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 11 Permit can be issued without conservation order Yes Appr Date 12 Permit can be issued without administrative approval Yes 13 Can permit be approved before 15-day wait Yes SFD 4/3/2015 14 Well located within area and strata authorized by Injection Order # (put 10# in comments) (For NA 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 17 Nonconven. gas conforms to AS31.05.0300.1.A),0.2.A-D) NA 18 Conductor string provided NA Engineering 19 Surface casing protects all known USDWs NA 20 CMT vol adequate to circulate on conductor & surf csg NA 21 CMT vol adequate to tie-in long string to surf csg NA 22 CMT will cover all known productive horizons No 23 Casing designs adequate for C, T, B & permafrost Yes 24 Adequate tankage or reserve pit Yes 25 If a re -drill, has a 10-403 for abandonment been approved NA 26 Adequate wellbore separation proposed Yes 27 If diverter required, does it meet regulations NA Appr Date 28 Drilling fluid program schematic & equip list adequate Yes VTL 4/8/2015 29 BOPEs, do they meet regulation Yes 30 BOPE press rating appropriate; test to (put psig in comments) Yes 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 34 Mechanical condition of wells within AOR verified (For service well only) NA 35 Permit can be issued w/o hydrogen sulfide measures No Geology 36 Data presented on potential overpressure zones Yes Appr Date 37 Seismic analysis of shallow gas zones NA SFD 4/3/2015 38 Seabed condition survey (if off -shore) NA 39 Contact name/phone for weekly progress reports [exploratory only] NA Geologic Engineering Public Commissioner: Date: Co ssioner: Date Commissioner Date Conductor set in PBU F-24 Surface casing set in PBU F-24 Surface casing fully cemented Productive interval will be completed with slotted liner Rig has steel tanks; all waste to approved disposal wells Anti -collision analysis complete; no major risk failures Max formation pressure is 3249 psi(7.1 ppg EMW); will drill w/ 8.6 ppg EMW MPSP is 2369 psi; will test BOPS to 3500 psi H2S measures required F-Pad wells are H2S-bearing. H2S measures are required. Planned drilling mud program (8.6 ppg) appears adequate to control operator's forecast pore pressure gradient of 7.1 ppg.
