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Home My WebLink About215-063Davies, 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 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-24L2). 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.LastufkaPbp.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. THE STATE 01ALASKA GOVERNOR BILL WALKtR John McMullen Engineering Team Leader BP Exploration (Alaska), Inc. P.O. Box 196612 Anchorage, AK 99519-6612 Alaska 0*1 and C', P-F Conservation 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-24L2 BP Exploration (Alaska), Inc. Permit No: 215-063 Surface Location: 1875' FNL, 2172' FEL, SEC. 02, T11N, R13E, UM Bottomhole Location: 4179' FSL, 723' FWL, SEC. 35, T12N, R13E, 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, �� P��Vt�Cathy P. Foerster Chair DATED this day of April, 2015. STATE OF ALASKA OIL AND GAS CONSERVATION C( ION PERMIT TO DRILL 20 AAC 25.005 RECEIVED APR 0 2 2015 1 a. Type of work: 1 b.Proposed Well Class:'® Development Oil ❑Service - Win I ® Single Zone 1c. 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 ff Single Well 11. Well Name and Number: BP Exploration (Alaska) Inc. Bond No 6194193 • PBU F-241L2 3. Address 6. Proposed Depth: 12. Field / Pool(s) P.O. Box 196612, Anchorage, Alaska 99519-6612 MD 14610' TVD 9010'SS Prudhoe Bay / Prudhoe Bay 4a. Location of Well (Governmental Section): 7. Property Designation (Lease Number): Surface: ADL 028280, 028278 & 028277 ' 1875' FNL, 2172' FEL, Sec. 02, T11N, R13E, UM 8. Land Use Permit: 13. Approximate Spud Date: Top of Productive Horizon: 3450' FSL, 1395' FEL, Sec. 34, T12N, R13E, UM June 15, 2015 9. Acres in Property: 14.Distance to Nearest Property: Total Depth 4179' FSL, 723' FWL, Sec. 35, 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: 11995' feet 17. Maximum Anticipated Pressures in psig (see 20 AAC 25.035) Maximum Hole Angle: 92 degrees Downhole: 3249 ' Surface: 2369 • 18. Casing Program Specifications I 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" 3-1/4" x 2-7/8" 6.6# / 6.4# L-80 TCII / 2985' 11625' 8589'ss 14610' 9010'ss 112 sx Class 'G' STL 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) 12430' 9240' 121,e 12387' 92 1 None Casing Length Size Cement Volume MD TVD Conductor / Structural 80' 20" 8 cu vids Concrete 36' - 116' 36' - 116' Surface 2642' 13-3/8" 3909 cu ft Permafrost 11 36' - 2678' 36' - 2662' Intermediate 11837' 9-5/8" 240 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: Date 22. I hereby certify that the foregoing is true and correct: Contact Zach Browning, 564-5220 Printed Name Email Zachary. Browning@bp.com John; all "� Title Engineering Team Leader i Si nature - 564-4711 at��A D e 9 q Phone - / Commission Use Only Permit To Drill API Number: Permit Approval Date- See cover letter for Number: f 50-029-21030-61-00 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 shales: Other: 13 G �� f - 5 7/ 7'_0 5 G O P 5 Samples Req'd [I Yes ❑ No Mud Log Req'd: ❑,�(.Yes [2( No h �vl C� �7/ l ✓lh 14?_ fi1.5 4 i` o Z SUUps HzS Measures: 0 Yes El No Directional Survey Req'd: L+� Yes ❑ No Spacing exception req'd: [:]Yes ETNo inclination -only svy Req'd: []Yes 9No APPROVED BY�APPROVED BY COMMISSIONER THE COMMISSION Date Form 10-401 Revised 10/2012 This permit is valid for 24 m a p 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 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 pert 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" OH, 147' 351 de /100 planned). 4. Drill lateral section: 4.25" OH, 1835' 120 deg/1 00planned) 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" OR 720' 251 de /100 planned). 9. Drill lateral section: 4.25" OH, 1895' 120 deg/1 00planned) 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 — 14,01T 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 (L2) • 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 1000(L1) and 92°(L2), inclination at kick off point is 44' 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-241-1) 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 F24L1&L2 is considered to be Medium. Reservoir Pressure: • The reservoir pressure on F-24L1&L2 is expected to be 3,249 psi at 8,800' TVDSS (7.1 ppg equivalent). • 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 TFZM= 4" CIW V1ILHEAD = McEVOY ACTUATOR= BAKER KB. ELEV = 70.78' BF. ELEV = 37.44' KOP = 24W Max Angle = 57 @ 7800' Datum MD = 11913' 13-3/8" FOC DaturnTVD= 8809 SS 13-3/8" CSG, 72#, L-80, D = 12.347" 2679' 2679' F-24 Minimum ID = 2.313" @ 11606' X 2-7/8" NIP REDUCER 4-1/2" BKR OM -SET PATCH (03119/10) 11390' - 11420' TOP OF 7" LNR 1-i 11614' 4-1/2" LW 12.6#, L-80, .0152 bpf, D = 3.953" 1—+ 11689' 9-5/8" LNR, 47#, L-80, .0732 bpf, D = 8.681" 11870' ' PERFORATION SUKWRY REF LOG: SWS BRCS ON 11/12/83 ANGLE AT TOP PERF: 43 @ 11908' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz 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 — 1238T �-,, 7" LNR, 26#, L-80 U4S, .0383 bpf, D = 6.276" 12428' I AFETY NOTES: 2183' 14-1/2" OTIS SSSV NP, ID = 3.813" GAS LIFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE 11 3270 3176 33 OTIS LBD DOME 1 0 03/27/10 10 r 5800 4826 53 OTIS LBD DMY RA 0 01/02/92 9 7810 5980 57 OTIS LBD DOME RM 0 03/27/10 8 9082 6756 47 OTIS LBD DMY RA 0 01/02/92 9868 7308 44 OTIS 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 8376 36 OTIS LBD DMY RA 0 01/02/92 " 1 11409 8490 40 1 OTIS I RDI DMY RM 0 04/06/09 51 A A 1 = GUv tjQjJ tsr FA I GH (wil9I1 u) 114T5' 4 1/2" OTIS XA SLD SLV D = 3.813" 11532' BOT P8R SEAL 11556' 9 5/8" BOT PKR (3H) D = 3.958" 11606' 9 5/8" BOT PKFZ (3H) D = 3.958" 11606' 4-1/2" OTIS X NP, D = 3.813" 11606' 4-1/2" X 2-7/8" X D = 2.313"(02/14/10) 1164� 4-1/2" OTIS XN NIP, D = 3.725" — 11689' 4 112" TBG TAIL, D = 3.958" 11683' ELMDTT LOGGED 11/15/83� 11971' H MARKER JOM 121"' 1-i BP- 07/23/93 FN (v) 12138' B-AU PRl1DHOEBAY LI IT VVH1: F-24 PEFMT No: '1831540 AR No: 50-029-21030-00 SEC2, T11R R13E DATE REV BY COM ENTS DATE REV BY COMu NT5 I 11/17183 ORIGINAL COMPLETION 03105/10 SEW/RPC CIS, NP RED & PLUG (02114/10) 10/05/01 RWrP CORRECTIONS 03/29/10 CJhYPJC PULL PLUG! C/O GLV (03/27/10) 03/18/06 RLMPAG BP CORRECTION 03/27/09 RIVIM RK TREE CIO (03/21/09) 05/31/09 1 MFnTLH I GLV C/O (04/03/09 & 04/06/09) BP Exploration (Alaska) O6/30/09 I DAvrrLHj CATCHER SUB SET(04/65/69) 1 1 TRH= 4" CIW V4E-LHEAD= WEVOY ACTUATOR= BAKER KB. ELEV = 70.78' BF_ ELEV = 37.44' 2400' Max Angle = 57 @ 7800' Datum MD= DatumTVD= _11913' 8800' SS � rc; t,a ' CONDUCTOR, 13-3/8" CSG, 72#, L-80 BUTT, D = 12.347• 42679- � Minimum ID = a.... _.- d..�� — TOP OF CEMENT IN IA (XX/XX/15) — OF 3-1/4" X 2-718 " 13C r-85 LNR I —11625 TOP OF 7" LNR 11614' 4-1/2" TBGPCy 12.6#, L-80 BUTT, 1169W .0152 bpf, D = 3.953" 9-5/8" LNR, 47#, L-80, .0732 bpf, D = 8.681" 11870' 17" MARKER JOINT 119Ts• 7" X 4-1/2" DELTA WHIPSTOCK( ^"11995 44' INC. TOP OF 2-7/8" LNR V 12020 7" X 4-1/2" DELTA WHIPSTOCK (XX/)0CI75) � PERFORATION SUMMARY REF LOG: SWS BRCS ON 11/12/83 ANGLE AT TOP PERF: WA Note: Refer to Production DB for historical perf data SIZE I SPF I INTERVAL I Opn/Sgz I SHOT I SO: SEE PAGE 2 FOR PERFORATION DATA 44' 3 3/8• BP (07/23/93) - FN @ 12138' ELMD 12144' 7" LNR, 26#, L-80 U4S, .0383 bpf, D = 6276' 12308' 7" LNR, 29#, L-80 BUTT, .0371 bpf, ID = 6.184" 12428' F -2 4 SAFETY NOTES: L. 2183' 4-1/2" OTIS SSSV NP, D = 3.813" 2596' — 9 s/s" DV PACKER OTIS GAS LFT MANCIRR S ST MD I TVD DEV ITYPEI VLV LATCH PORTI DATE 11 3270 3814 35 LBD DOME RM 16 03/27/10 10 r 5800 4834 r 53 LBD DMY RA 0 11/17/83 9 7810 5989 F 57 LBD DOME RM 16 03/27/10 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 7762 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 85W 41 LBD `DMY RM 0 04/06/09 aIJA* I -unT --Vvt31=jCST rAil:htU3/19flu) 11475' 4 1/2" OTIS XA SLD SLV D = 3.813" BOT PBR SEAL 11532' 11556' 9 5/8" X 4-1/2" BOT PKR (3-H) D = 3.958" 11606' 4-1/2" OTIS X NP, 3.813" (XXIXX/i5) INC. —11625 3.70" BKR DEPLOY SLV, D = 3.00" 11614' 9-5/8" X 7• BKR LNR FIGR, D = 1164W 4-1/2" OTIS X NP, MILLED TO = 3.80" (XX/XX/15) 11690' -14-1/2" TBG TAIL, D = 3.958" 11683 B_ND TT LOGO 11/15/83 3-3116" X 2-7/8" XO, D 2.377" I 2EA RA TAGS 3-1/4" LNR, 6.6#, L-80 TCI, .0079 bpf, D = 2.850" 2-7/8" LNR #, 1--Cr STL, 1—='"='O tX158 bpf, ID = 2-441" 22020 3.70" DEPLOY SLV, D=3.00" 2-718" SLID LNR _#, L-80 STL, —13271 0058 bpf, D = 2-441" DATE 11/17/83 XX/=15 03/08/15 PRUDHOE BAY UNIT WELL F 24 L1 & L2 PERMIT No: '1831540, _ AR No: 50-029-21030-00 (60)1(61) S� 2, T11 N, R13E, 1875' FNL & 2172' FEL REV BY COWENTS DATE REV BY COWAENTS ORIGINAL COMPLETION CID MULIT-LATERAL (F 24 L1 / L2) PJC BUILD PROPOSAL BP Exploration (Alaska) �sa� F-24 Pro p L l & t._ DATE REV BY COMMENTS DATE REV BY COMMBVTS FRLJDHOE BAY UNIT 11/17183 ORIGINAL COMPLETION WELL- F- PERFORATION SUMMARY REF LOG: SWS BRCS ON 11l12183 ANGLE AT TOP FERF: � :�� ', Pbte= Refer to Production DB for historical pert data SQE SPF INTERVAL OpnlSgz SHOT SOZ 3-3/8" 4 11908 - 11912 S 01/05/88 01/21/88 3-3l8" 6 11� - 11980 O 03l15/88 3-1/8" 4 12072- 12138 S 06l25/86 01/21/88 3-3/8" 4 12072 - 12738 O 08l07/88 3-3l8" 6 72075 - 12035 O 05129/95 3-118" 4 12148- 12785 S 06/25/86 01/21/88 3-1/8" 4 12170 - 12185 S 03/26l86 06/14186 F-24 L7 F-24 L2 24 L1 8 L2 PERMIT No: '1831540, AR No: 50-029-21030-� {60}/{61 } SEC 2, T11 t� R13E, 1875' � & 2172' Fa Xi�JX)U1 CTDMULIT-LATff�AL {F 24 L1 L2) 0310�15 PJC BUILD PROPOSAL BP Exploration {Alaska) 0 a a p J Q IL 3: F- m .a N p 0 N a L V L) Z m � a`a.LLLL a N N W a U Z Q O O LL. d N N Y > (Ucu r N 0 J Q N U) LL C m Co J LL 'G Cl ( 2 O Cl r 2 w hi u C N d d 0 L c CI C_ p U d •O U 60] c c d A y � u Q m o�`, -0 m dv a w V a d � L m a p 0 N >>� J F O 7 Z U) O O Q 4) m a C m a U a- m n. 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N fi. • T-1 I� 0 o a N o^ o o - o 0 0- —o om o o _ z3I � F I a r m . • vm- - mz n oo.= 6 6 Nr.-.-.-.-N N.�^JN o � NNn A 2 2 M t22 I� m m m m m m m m m m m m m m m m rn h- m^- 0 a Lry m-- mmmm��mmm o N N N m m e v (ut/1{sn S9) gldoQ leopian ani I �_ _. _. 2 -.__ ----_-.__ -. - `- - - N o� � c , c m 3 �2m o ry N r < C .-- 0 o LL R W a- 9623 C � J A N 55 pp e l a 00 �� _ _--Y �9 a 7 a 00 N W of N V r � 1 h c aau: ti.$ .. a ��=e3 SLN3aSEJO o00 =a 6 or a 0 r o W W ^ {o Q 00 (uE/8sn oS[) (+)illlolN/(-)ulnoS j fA Nw LAINZ a%go 9 q ■| ; § 666\;26;6;6;;; ;\( f 2 \ )k % LU � �mete,e,ww \25agSese22 )) }[/ 0 \ 0 North America - ALASKA - BP Prudhoe Bay PB F Pad F-24 500292103000 F-24 L2 F-24 L2 WP07 Travelling Cylinder Report 25 March, 2015 f p P _-- BAKER HUGHE5 BP /Glis 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-24 Well Error: 0.00 usft Reference Wellbore F-24 L2 Reference Design: F-24 L2 WP07 Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Output errors are at Database: Offset TVD Reference: 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 L2 WP07 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 14,610.00usft Scan Method: Tray. Cylinder North Results Limited by: Maximum center -center distance of 1,657.48 usft Error Surface: Elliptical Conic Survey Tool Program Date 3/25/2015 From To (usft) (usft) Survey (Wellbore) Tool Name Description 100.00 11,900.00 1 : Schlumberger GCT multishot (F-24) GCT-MS Schlumberger GCT multishot 11,900.00 14,610.00 F-24 L2 WP07 (F-24 L2) MWD MWD - Standard Casing Points 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 8768.65 Intermediate Casing 9.625 12.250 14,625.00 51/2" 5.500 6.000 Summary Site Name Offset Well - Wellbore - Design PB F Pad F-13 - F-13 - F-13 F-13 - F-13A - F-13A F-13 - F-13B - F-13B F-13 - F-13BPB1 - F-13BPB1 F-14 - F-14 - F-14 F-19 - F-19 - F-19 F-19 - F-19A - F-19A F-19 - Plan F-19B - Plan #10b F-19B F-21 - F-21 - F-21 F-21 - F-21 PB1 - F-21 PB1 F-22 - F-22 - F-22 F-22 - Plan F-22A - Plan F-22A F-23 - F-23 - F-23 F-23 - F-23A - F-23A F-23 - F-23B - F-23B WP03 F-24 - F-24 - F-24 F-24 - F-24 L1 - F-24 L1 WP04 F-33 - F-33 - F-33 F-33 - F-33A - F-33A F-33 - F-33APB1 - F-33APB1 F-34 - F-34 - F-34 F-34 - F-34A - F-34A F-34 - F-34APB1 - F-34APB1 F-34 - F-34B - F-34B F-35 - F-35 - F-35 Reference Offset Centre to No -Go Allowable Measured Measured Centre Distance Deviation Warning Depth Depth Distance (usft) from Plan (usft) (usft) (usft) (usft) 13,625.00 13,950.00 1,211.18 272.03 13,766.40 11,975.00 795.93 246.06 12, 024.94 12, 025.00 1.02 1.95 11,975.00 11,975.00 0.00 0.39 Out of range Out of range Out of range Out of range Out of range Out of range 963.69 Pass - Major Risk Out of range 567.08 Pass - Major Risk Out of range Out of range Out of range Out of range Out of range Out of range -0.93 FAIL-NOERRORS -0.39 FAIL-NOERRORS Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range CC - Min centre to center distance or covergent point, SF - min separation factor, ES - min ellipse separation 312512015 12-56:27PM Page 2 COMPASS 5000.1 Build 61 BP rel.I Travelling Cylinder Report BAKER HUGHES Company: North America - ALASKA - BP Local Co-ordinate Reference: Well F-24 Project: Prudhoe Bay TVD Reference: Mean Sea Level Reference Site: PB F Pad MD Reference: ORKB @ 70.78usft Site Error: 0.00 usft North Reference: True Reference Well: F-24 Survey Calculation Method: Minimum Curvature Well Error: 0.00 usft Output errors are at 1.00 sigma Reference Wellbore F-24 L2 Database: EDM R5K- Alaska PROD - ANCP1 Reference Design: F-24 L2 WP07 Offset TVD Reference: 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-36 - F-36 - F-36 12,680.00 12,150.00 608.21 350.20 322.82 Pass - Major Risk F-36 - F-360 - F-361_1 WP05 14,604.86 14,275.00 478.67 273.97 206.35 Pass - Major Risk F-36 - F-361_2 - F-361_2 WP05 12,680.00 12,150.00 608.21 345.47 326.11 Pass - Major Risk F-36 - F-36L3 - F-36L3 WPO5 12,680.00 12,150.00 608.21 345.00 326.44 Pass - Major Risk F-37 - Plan F-37A - Plan #8 F-37 12,320.00 13,200.00 1,297.93 205.85 1,093.92 Pass - Major Risk F-37 - Plan F-37ALl - Plan #8 F-37ALl 12,320.00 13,200.00 1,297.93 205.91 1,093.85 Pass - Major Risk F-42 - F-42 - F-42 Out of range F-42 - F-42A- F-42A Out of range F-48 - F-48 - F-48 11,908.92 11,750.00 1,604.97 35067 1,293,96 Pass- Major Risk PB T Pad T-01 - T-01 - T-01 Out of range T-07 - T-07 - T-07 Out of range Offset Design PB F Pad - F-19 - F-19A - F-19A Onset Site Error. 0.00 usft Survey Program: 94-GYD-CT-CMS, 8214-BLIND, 8290-INC+TREND, 8480-MWD+IFR+MS-WOCA, 11813-INC+TREND, 11876-MWD 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 Warning Depth Depth Depth Depth Azimuth +NIS +EI-W Hole Size Centre Distance Deviation (usft) (usft) (usft) (usft) (usft) (usff) (I (usft) (usft) (in) (usft) (usn) (usft) 13,615.54 8,975.99 13,980.00 8,622.78 54.52 64,89 157.18 4,544.70 -3,169.62 5.250 1,211.58 272.28 963.74 Pass - Major Risk 13,625.00 8,976.44 13,925.00 8,622.44 54.54 64.87 155.96 4,552.47 -3,115.17 5.250 1,211.32 271.71 964.05 Pass - Major Risk 13,625.00 8,976.44 13,950.00 8,622.60 54.54 64.88 156.02 4,548.94 -3.139.92 5.250 1,211.18 272.03 963.69 Pass - Major Risk, CC, ES, SF 13,625.00 8,976.44 13,975.00 8,622.75 54.54 64.89 156.09 4,545.40 -3,164B7 5.250 1,211.57 272.35 963.84 Pass - Major Risk 13,639.54 8,977.09 13,900.00 8,622.16 54.57 64.87 154.24 4,556.29 -3,090.47 5.250 1,211.43 272.36 963.96 Pass - Major Risk 13,650.00 8,977.52 13,850.00 8,621.07 54.59 64.87 152.88 4.565.45 -3,041,33 5.250 1,211-59 272.70 964.30 Pass - Major Risk 13,650.00 8,977.52 13,875.00 8,621.65 54.59 64.87 152.96 4,560.64 -3,065.86 5.250 1,211.54 272.88 963.95 Pass - Major Risk 13,662.04 8,978.00 13,825.00 8,620.54 54.61 64.86 151.43 4,570.60 -3,016.87 5,250 1,211.61 273.42 964.05 Pass - Major Risk 13,675.00 8,978.47 13,775.00 8,619.88 54.64 64.86 149.84 4,580.72 -2,967.92 5.250 1,212.85 274.13 965.12 Pass - Major Risk 13,675.00 8,978.47 13,800.00 8,620.15 54.64 64.86 149.88 4,575.82 -2,992.43 5.250 1,211.95 274.30 963.99 Pass - Major Risk 13,684.57 8,978.79 13,750.00 8,619.71 54.66 64.86 148.71 4,585.36 -2,943.35 5,250 1,214.37 274.82 966.30 Pass - Major Risk 13,700.00 8,979.26 13,675.00 8,619.55 54.68 64.86 146.90 4,599.50 -2,869.70 5.250 1,220.83 275.82 972.28 Pass - Major Risk 13,700.00 8,979.26 13,700.00 8,619.53 54.68 64.86 146.90 4,594.84 -2,894.26 5.250 1,218.25 275.97 969.55 Pass- Major Risk 13,700.00 8,979.26 13,725.00 8,619.59 54.68 64.86 146.90 4,590.09 -2,918.80 5.250 1,216.24 276.13 967.38 Pass- Major Risk 13,714.43 8,979.65 13,650.00 8,619.63 54.71 64.86 145.24 4,604.17 -2,845.14 5.250 1,223,61 277.16 974.17 Pass - Major Risk 13,725.00 8,979.90 13,600.00 8,620.20 54.72 64.85 144.08 4,612.76 -2,795.89 5.250 1,230.98 278.03 980.88 Pass - Major Risk 13,725.00 8,979.90 13,625.00 8,619.81 54.72 64.a5 144.03 4,608.73 -2,820.56 5.250 1,226.90 278.18 976.76 Pass - Major Risk 13,736.46 8,980.14 13,575.00 8,620.80 54.74 64.85 142.82 4,616.47 -2,771.17 5.250 1,235.61 279.21 984.61 Pass - Major Risk 13,750.00 8,980.38 13,500.00 8,622.89 54.76 64.85 141.49 4,627.48 -2,697.02 5.250 1,251.74 280.45 999A9 Pass - Major Risk 13,750.00 8,980.38 13,525.00 8,622.37 54.76 64.85 141.41 4,623.64 -2,721.71 5.250 1,246.08 280.58 993.85 Pass. Major Risk 13,750.00 8,980.38 13,550.00 8,621.55 54.76 64.85 141.32 4,620.15 -2,746.46 5.250 1,240.64 280.71 988.47 Pass - Major Risk 13,765.12 8,980.60 13,475.00 8,623.14 54.78 64.85 139.80 4,631.32 -2,672.32 5.250 1,257.64 282.24 1,003.99 Pass - Major Risk 13,775.00 8,980.71 13,425.00 8,623.50 54.80 64.85 138.81 4,638.65 -2,622.86 5.250 1,271.00 283.31 1,016.31 Pass - Major Risk 13,775.00 8,980.71 13,450.00 8,623.33 54.80 64.85 138.72 4,635.05 -2,647.60 5.250 1,264.10 283.42 1,009.46 Pass - Major Risk 13,785.96 8,980.81 13,400.00 8,623.32 54.81 64.85 137.60 4,641.56 -2,598.03 5,250 1,278.93 284.68 1,023.09 Pass - Major Risk 13,800.00 8,980.89 13,325.00 8,623.11 54.82 64.85 136.24 4,649.45 -2,523.45 5.250 1,305.34 286.33 1,047.74 Pass - Major Risk 13,800.00 8,980.89 13,350.00 8,623.15 54.82 64.85 136.14 4,646.94 -2,548.32 5.250 1,296.11 286.43 1,038.61 Pass - Major Risk 13,800.00 8,980.89 13,375.00 8,623.17 54.82 64.85 136.03 4,644.34 -2,573.18 5.250 1,287.38 286.54 1,029.98 Pass - Major Risk CC - Min Centre to center distance or oovergent point, SF - min separation factor, ES - min ellipse separation 3/25/2015 12:56:27PM Page 3 COMPASS 5000.1 Build 61 TRANSMITTAL LETTER CHECKLIST WELL NAME: �= PTD: Development _ Service _ Exploratory Stratigraphic Test _ Non -Conventional /-? FIELD: - POOL: zfLIlse- ./l 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#: 2150630 Company BP EXPLORATION (ALASKA) INC Initial Class/Type Well Name: PRUDHOE BAY UNIT F-241L2 Program DEV Well bore seg 0 DEV / PEND GeoArea 890 Unit 11650 On/Off Shore On Annular Disposal C Administration 1 Permit fee attached NA 2 Lease number appropriate Yes Surface location in ADL 028280, top prod interval in ADL 028278, 3 Unique well name and number Yes TD in ADL 028277. 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 AS31.05.030(j.1.A),(j.2.A-D) NA 18 Conductor string provided NA Conductor set in PBU F-24 Engineering 19 Surface casing protects all known USDWs NA Surface casing set in PBU F-24 20 CMT vol adequate to circulate on conductor & surf csg NA Surface casing 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 production 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 NA 26 Adequate wellbore separation proposed Yes Anti -collision analysis complete; no major risk failures 27 If diverter required, does it meet regulations NA Appr Date 28 Drilling fluid program schematic & equip list adequate Yes Max formation pressure is 3249 psi(7.1 ppg EMW); will drill w/ 8.6 ppg EMW VTL 4/8/2015 29 BOPEs, do they meet regulation Yes 30 BOPE press rating appropriate; test to (put psig in comments) Yes MPSP is 2369 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 4/3/2015 38 Seabed condition survey (if off -shore) NA 39 Contact name/phone for weekly progress reports [exploratory only] NA Geologic Engineering Public Commissioner: Date: Date Commissioner Date P TS 11 /7 � S&4sioner: 71s