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Home My WebLink About215-121Davies, Stephen F (DOA) From: Lastufka, Joseph N <Joseph.Lastufka@bp.com> Sent: Thursday, May 12, 2016 8:41 AM To: Davies, Stephen F (DOA) Cc: Bettis, Patricia K (DOA) Subject: RE: 02-14B WP15 Final Files (PTD No. 215-121) Steve, I apologize for the confusion... It was decided that since the new plan for 02-14B was well over 500' different at the bottom hole location a new Permit to Drill would be required. Please cancel PTD# 215-121 (also named 02-14B). If you have any questions or need additional information please don't hesitate to let me know. Thank you, Joe Lastufka Information and Data Controller Cell: (907) 227-84961 Office: (907) 564-4091 Vv BP Exploration AlaskaJ900 E. Benson B1vd.lRoom: 788DIAnchorage, AK From: Davies, Stephen F (DOA) [maiIto: steve.davies@alaska.0 1 Sent: Wednesday, May 11, 2016 6:26 PM To: Lastufka, Joseph N Cc: Bettis, Patricia K (DOA) Subject: RE: 02-14B WP15 Final Files (PTD No. 215-121) Joe, It's getting late, so maybe I'm confused. AOGCC approved Permit to Drill No. 215-121 (API No. 50-029-20446-02-00) for PBU 02-14B on July 24, 2015. On May 9, 2016, AOGCC received another Permit to Drill application for PBU 02-14B. Can you help me out? Is this new application a revision? 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 1 Davies, Stephen F (DOA) From: Lastufka, Joseph N <Joseph.Lastufka@bp.com> Sent: Thursday, May 12, 2016 8:41 AM To: Davies, Stephen F (DOA) Cc: Bettis, Patricia K (DOA) Subject: RE: 02-14B WP15 Final Files (PTD No. 215-121) Steve, I apologize for the confusion... It was decided that since the new plan for 02-14B was well over 500' different at the bottom hole location a new Permit to Drill would be required. Please cancel PTD# 215-121 (also named 02-14B). If you have any questions or need additional information please don't hesitate to let me know. Thank you, Joe Lastufka Information and Data Controller Cell: (907) 227-84961 Office: (907) 564-4091 -------------------------------------------------------------------------------------- rEi BP Exploration Alaska1900 E. Benson Blvd.lRoom: 788DIAnchorage, AK -------------------------------------------------------------------------------------- From: Davies, Stephen F (DOA)[maiIto: steve.davies@alaska.gov] Sent: Wednesday, May 11, 2016 6:26 PM To: Lastufka, Joseph N Cc: Bettis, Patricia K (DOA) Subject: RE: 02-14B WP15 Final Files (PTD No. 215-121) Joe, It's getting late, so maybe I'm confused. AOGCC approved Permit to Drill No. 215-121 (API No. 50-029-20446-02-00) for PBU 02-14B on July 24, 2015. On May 9, 2016, AOGCC received another Permit to Drill application for PBU 02-14B. Can you help me out? Is this new application a revision? 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 1 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 (maiIto: Joseph. Lastufka2bp.com] Sent: Monday, May 09, 2016 10:14 AM To: Davies, Stephen F (DOA); Bettis, Patricia K (DOA) Subject: 02-14B WP15 Final Files Steve, This Permit to Drill will be delivered this afternoon. Please let me know if you have any questions. Thanks, Joe 2 pTD 21.7—i2/ Loepp, Victoria T (DOA) From: Ciolkosz, Ryan R <Ryan.Ciolkosz@bp.com> Sent: Wednesday, July 22, 2015 9:47 AM To: Loepp, Victoria T (DOA) Cc: Lastufka, Joseph N Subject: RE: PBU 02-14B(PTD 215-121) liner cement Follow Up Flag: Follow up Flag Status: Flagged Victoria, could you clarify what you need for verification? Please see my calcs below. % Excess Gauge Volume Bottom Top Length Cement Volume Shoe Track 0.005790555 13175 13095 35 0.2 bbls 3-1/4" Liner x OH 20 0.00728863 13175 10970 2205 19.3 bbls 3-1/2" Liner x Tubing 0.003319499 10970 9650 1320 4.4 bbls Total 23.9 bbls 1.16 sx/cuft 134.0 cuft 115.5 sxs From: Loepp, Victoria T (DOA) [ma iIto: victoria. loepp@alaska.gov] Sent: Tuesday, July 21, 2015 1:35 PM To: Ciolkosz, Ryan R Subject: PBU 02-14B(PTD 215-121) liner cement Ryan, The 116 sx does not seem to be an adequate amount of cement for the production liner. Could you please verify? 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 aaalaska.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@aloska.aov SchiumbugeP Cementing lc ' Report CefnCAT v1.6 Well 1D-145 Client ConocoPhillips Field Kuparuk SIR No. DDKA-00020/7689 Engineer John Morrison Job Type Surface Country United States .lob Date 07-23-2015 Time ----- mrorsass ia:u:n Pressure Rate - top out densi - Rig floor pres Surface densi Messages 10:43:39 g head rate heck h head rate check Reset Total, Vol = 11.78 bt 11:34:00 12:24:00 pjsm 13:14:00 on location @ 0900 mix water temp 80 degrees rig pump down, lined up to c start 5 bbls water ahead Reset Total, Vol = 5.0 bbl low pressure stall 14:04:00 High PT to 4000 bleed off, good test start 75 bbls CW-100 flow out 18% down on pump, CW-100 pur Reset Total, Vol = 75.3 bbl 14:54:DO start batching MPII start pumping MPII return flow 20% going dowr Down on pump, start batchit lead cement wet Reset Total, Vol = 72.9 bbl 15:44:00 start pumping lead cement 20% return flow, going dowi silo swap cement scaled @ 11* durin< CW-100 @ shoe 16:34:00 1 MP II @ shoe bottom plug landed cement @ shoe down on pump Reset Total, Vol = 432.2 bb tail mudscaled @ 12* 17:24:00 Reset Total, Vol = 68.9 bbl start 10 bbis water behind still reciprocating down on pump, rig is lining i 1090 strokes away 18:03:31 8 bpm return flow 23 % bumped plug @ 3584 stroke 01:18:53 re -spotted for top job mixing top out with small to Reset Total, Vol = 9.5 bbl 02:14:00 start pumping water ahead have returns in the cellar 03:09:00 Reset Total, Vol = 45.0 bbl start batching cement Reset Total, Vol = 0.05 bbl scale 11.3 04:04:00 cement to surface 04:59:00 11* cement to surface 05:34:43 57.1 total bbls pumped for t hh:mm:ss MOD 1000 2000 3000 4000 5000 0.00 Z.o 4.0 &0 6.0 10.0 5.0 10.0 MD 20.0 25.0 0.00 1250 2500 3750 5000 0.00 6.3 Ms 16.6 25.0 PSI B/M LB/G PSI LB/G I THE STATE °'ALASKA GOVERNOR BILL WALKER John McMullen Engineering Team Leader BP Exploration (Alaska), Inc. P.O. Box 196612 Anchorage, AK 99519-6612 C Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 www.cogcc.alaska.gov Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU 02-14B BP Exploration (Alaska), Inc. Permit No: 215-121 Surface Location: 4713' FSL, 851' FWL, SEC. 36, T11N, R14E, UM Bottomhole Location: 4021' FSL, 1417' FWL, SEC. 36, T11N, R14E, 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, Cathy P. �oerster Chair DATED this Zy" day of July, 2015. STATE OF ALASKA ASKA OIL AND GAS CONSERVATION COMMIS` PERMIT TO DRILL 20 AAC 25.005 RECEIVED JUL 16 2015 la. Type of Work: 1 b. Proposed Well Class: Development - Oil Q Service - Winj ❑ Single Zone 0 1c. Spec ed for: Drill ❑ Lateral ❑ Stratigraphic Test ❑ Development - Gas ❑ Service - Supply ❑ Multiple Zone ❑ Colabed Gas ❑ Gas Hydrates ❑ Redrill Q Reentry ❑ Exploratory ❑ Service - WAG ❑ Service - Disp ❑ Geothermal ❑ Shale Gas ❑ 2. Operator Name: 5. Bond Blanket Q Single Well ❑ 11 Well Name and Number: BP Exploration (Alaska), Inc Bond No. 6194193 PBU 02-14B ' 3 Address: 6. Proposed Depth: 12. Field/Pool(s): P.O. Box 196612 Anchorage, AK 99519-6612 MD: 13173' TVD: 8947'ss PRUDHOE BAY, PRUDHOE OIL 4a. Location of Well (Governmental Section): 7. Property Designation (Lease Number): ADL 028308 Surface: 4713' FSL, 851' FWL, Sec. 36, T11N, R14E, UM 8. Land Use Permit: 13. Approximate spud date: Top of Productive Horizon: 1182 FNL, 1621' FEL, Sec. 35, T11N, R14E, UM November 15, 2015 9. Acres in Property: 2560 14. Distance to Nearest Property: Total Depth: 4021' FSL, 1417' FWL, Sec. 36, T11N, R14E, UM 33350' 4b. Location of Well (State Base Plane Coordinates - NAD 27): 10. KB Elevation above MSL: 57.93' feet. 15. Distance to Nearest Well Open Surface: x- 687592 y- 5950634 Zone - ASP-4 GL Elevation above MSL: 31' feet. to Same Pool: 520' 16. Deviated wells: Kickoff Depth: 10986' feet 17. Maximum Anticipated Pressures in psig (see 20 AAC 25.035) Maximum Hole Angle: 92 degrees Downhole: 3310 Surface: 2414 18. Casing Program: Specifications Top - Setting Depth - Bottom Cement Quantity, c.f. or sacks Hole Casing Weight Grade Coupling Length MD TVD MD TVD (including stage data) 4-1 /4" 3-1 /2" x 3-1/ "9.3# / 6.6 L-80 STL / TCII 3523' 9650' 8816'ss 13173' 8947'ss 116 sx Class 'G' x 2-7/8" / 6.5# / STL 19 PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re -Entry Operations) Total Depth MD (ft): Total Depth TVD (ft): 1 Plugs (measured): Effect. Depth MD (ft): Effect. Depth TVD (ft): Junk (measured): 1 11880' 8995' 9121', 11200' 9121' 8427' None Casing Length Size Cement Volume MD TVD Conductor/Structural 81, 20" 431 sx Arcticset 27' - 108' 27' - 108' Surface 2685' 13-3/8" 2300 sx Fondu, 400 sx PF 'C' 26' - 2711' 26' - 2711' Intermediate 9224' 9-5/8" 1100 sx Class'G', 300 sx PF 'C' 24' - 9248' 24' - 8554' Scab Liner 6429' 7" 356 sx Class'G'. 348 sx Class'G' 2819' - 9248' 2819' - 8554' Liner 2807' 4-1/2" 348 sx Class'G' 9072' - 11879' 8378' - 8995' Perforation Depth MD (ft): 9680' - 11780' Perforation Depth TVD (ft): 8891 ' - 8994' 20. Attachments Property Plat ❑ BOP Sketch Q Drilling Program Q Time v. Depth Plot ❑ Shallow Hazard Analysis ❑ Diverter Sketch ❑ Seabed Report ❑ Drilling Fluid Program Q 20 AAC 25.050 requirements Q 21. Verbal Approval: Commission Representative: Date 22. 1 hereby certify that the foregoing is true and correct. Contact Ciolkosz, Rvan R Email Ryan.Ciolkosz(nbp.com Printed Name Joh ull n Title Engineering Team Leader Signature Phone +1 907 564 4711 Date Commission Use Only Permit to rill Number: API Number: Date: See Permit ApprovNaql, cover letter for other 50-029-20446-02-00 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 contained in shales: 51/ Other Samples req'd: Yes ❑ No Mud log req'd: Yes ❑ No QOP test �-O 3� 00'p5 111/ i An v1 L11 a !_ 1)1—r l�Cvl fry ftS �fD Z 5� 2Ssmeasures Yes No ❑/ Directional svy req'd: Yes 0 No ❑ Spacing ex�ption req'd: Yes El [/ Inclination -only svy req'd: Yes ❑ No [it/ APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: 7 . —/ S ORIGINAL r-rz- T124115` Form 10-401 Revised 10/2012 This permit is valid for 24 months from the date of approval (20 AAC 25.005(g)) Submit Form and Attachments in Du licate EC EIVED STATE OF ALASKA .ASKA OIL AND GAS CONSERVATION COMMIS.S J U L 14 2015 PERMIT TO DRILL 1 20 AAC 25.005 1a. Type of Work: 1 b. Proposed Well Class: Development - Oil Q Service - Winj ❑ Single Zone Q 1 c.' Specify if viellis proposed for: Drill ❑ Lateral ❑ Stratigr.phic Test ❑ Development - Gas ❑ Service - Supply ❑ Multiple Zone ❑ Colabed Gas ❑ Gas Hydrates ❑ Redrill Q Reentry ❑ Exploratory ❑ Service - WAG ❑ Service - Disp ❑ Geothermal ❑ Shale Gas ❑ 2. Operator Name: 5. Bond Blanket Q Single Well ❑ 11 . Well Name and Number: BP Exploration (Alaska), Inc Bond No. 6194193 PBU 02-14B 3 Address: 6. Proposed Depth: 12. Field/Pool(s): P.O. Box 196612 Anchorage, AK 99519-6612 MD: 13173' TVD: 8947'ss PRUDHOE BAY, PRUDHOE OIL 4a. Location of Well (Governmental Section): 7. Property Designation (Lease Number): ADL 0028308 Surface: 4713' FSL, 851' FWL, Sec. 36, T11N, R14E, UM 8. Land Use Permit: 13. Approximate spud date: Top of Productive Horizon: 1182 FNL, 1621' FEL, Sec. 35, T11 N, R14E, UM November 15, 2015 9. Acres in Property: 2560 14. Distance to Nearest Property: Total Depth: 4021' FSL, 1417' FWL, Sec. 36, T11 N, RUE, UM 33350' 4b. Location of Well (State Base Plane Coordinates - NAD 27): 10. KB Elevation above MSL: 57.93' feet 15. Distance to Nearest Well Open Surface: x- 687592 y- 5950634 Zone - ASP4 GL Elevation above MSL: 31' feet to Same Pool: 520' 16. Deviated wells: Kickoff Depth: 1 o986' feet 17. Maximum Anticipated Pressures in psig (see 20 AAC 25.035) Maximum Hole Angle: 92 degrees Downhole: 3310 Surface: 2414 18. CasinU2-7/8" Specifications Top - Setting Depth - Bottom Cement Quantity, c.f. or sacks Hole Weiqht Grade Coupling Length MD TVD MD TVD (including staqe data) 4-1/4" "9.3# / 6.6 L-80 STL / TCII 3523' 9650' 8816'ss 13173' 8947'ss 116 sx Class'G' 6.5# / STL 19. PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re -Entry Operations) Total Depth MD (ft): Total Depth TVD (ft): I Plugs (measured): Effect. Depth MD (ft): Effect. Depth TVD (ft): A, Junk (measured): 11880, 8995' 9121'.1 00' 84 None Casing Length Size l C ent Volum _'_ MD TVD Conductor/Structural See Attach See Attachment f'K _ee-A atY ment See Attachment See Attachment Surface See Attac See Attachment e -- ' Se achment b See Attachment See Attachment Intermediate See Attac See Attachment a achment See Attachment See Attachment Production See Attach See ent Se Attachment See Attachment See Attachment Liner See Attao- See Attl�10 See Attachment See Attachment See Attachment Perforation Depth MD (ft): See attachment Flerroration Uepth See attachment IX- 11 20. Attachments Property Plat ❑ q,(Ptrh11 Q Drilling Program Q Time v. Depth Plot ❑ Shallow azard Analysis El Diverter Sketch ❑ Seabed Report ElDrilling Fluid Progr# Q 20 AA 5.050 requirements Q 21 Verbal Approval: Commission Representative: Date 22. 1 hereby certify that the foregoing is true and correct. Contact i sz van R / 7 John ll Emai ' Ciolkosz b .com Printed Name McMd Title Engineering Team Leader " Signature Phone +1 907 564 4711 to-7 Commission Use Only Permit to DnIIL-- API Number: ermit A p oval See cover letter for other Number: I 50-029-20446-02-00 Date:, i, requirements: It}e�methane, hydrates, or gas contained in shales: ❑ Conditions of approval : If box is checked, well may not be used to explore foZes Other: Samples reNo ❑ Mud log req'd: Yes ❑ No ❑ H2S measNo ❑ Directional svy req'd: Yes ❑ No ❑ Spacing exception rNo ❑ Inclination -only svy req'd: Yes ❑ No ❑ fAPPROVED BY Approved by: CPMMISSIONER THE COMMISSION Date: ORIGINAL Form 10-401 Revised 10/2012 This permit is valid for 24 months from the date of approval (20 AAC 25.005(g)) Submit Form and Attachments in Duplicate U p U a w w � L.L a a x U � N x U 47 U O O O U d0' co 00 00 to � c L Q p CO- U «� c x U u) U) (D x w - li xi U A U� u o x U) UM 0 M o O x N N r C0 M co O V LO N O M LO u7 O 00 N 00 07 U') O N I- 00 00 00 ci I�CflvM.--f�N O CO Rf N N N M co N +.� f— N co co Q Q CO CO O = r N - v- r I� LO N N 0o N co Ncomm co � O C m C N •y N N N LO 00NO M CD Ri U o rn o 0 o��moo O o J J z J O M N = *k w J CO CO N * N — V * * N N fn M 00 I— (DO N - O M Lb - 0O - N N N d7 t t � � 00 00 CD m � N O N I) O � t.() C 00 C0 Ct V 00 00 J N co (D N 00 W W 0 Q Q c O W O Z ccaa D 2 E 0 U0U. of Z Z W W Q W m O �- U z =) 0C5zzcn�H d U) m O (D 00 'IT O N m _ LO 00 V LO O Cl) a co 0i 00 � IT y a7 0 0 0 fN 0 0) p 00 0) 0 0 0 0') 0) p 00 00 0) a) O 00 H n. O 6) 00 (D LC) 00 t N �- Lo CO LO V — Lo O m L- O 6) CD 0 00 0) 00 0') 00 CD 0 N 0 N 0 0')p C) p 00 00 0) O) 0) 00 F- m La m co r OOo00o00 _ m O (O O L� m 0) Lo rn — C = m r- N l6 N Ci Q 0 F- C' O N r acorn— 0 0 0 0 m _O O mco O O �Lo(o0)rnoItCN p m m m m 0 0 CU L 0 CU L v O U c LL LL M d m m w d Q Q m m m m m a O m Q. N p 0 0 0 0 0 0 0 O O O O O O O O O - N N N N N N CV T 00 w 00 m m OL N N N N NCU N O am E Z Q Q Q Q Q Q Q z v Nt 77 v v v v to N N N N N N N O O O O O O O 0 W > Y Q 0 W J F W W J cn W Z Q U W J CD D J 0 o a o > J Q= J z cWn z p 0 o O LOIN Wa -1 IL Q-i w 2i O U O cn cn a O W c can co can W J D a W Cn LU O O O J LU LL Z O a a a Q W W N W N LL. Z W a W 0 LL1 J (U W W LL W 0 0 m p h C� J J O O W W Q Q m m LL LL (n (n a a' LL a NO COLL a a L) J C w a Q ¢ m CO LL LL cn cn a a To: Alaska Oil & Gas Conserves,ion Commission From: Ryan Ciolkosz Rig: Nordic 2 CTD Engineer Target Reservoir: Ivishak Zone 1 Date: July 13, 2015 Re: 02-14B Permit to Drill Request Obp History and current status: 02-14 was initially drilled as a barefoot completion 1980. The 9-5/8' production casing was set into the Ivishak. A RWO in 1988 installed and cemented a 7" production liner across the barefoot interval. In 2003 the parent well was rig sidetracked to its current location. The rig initially ran a 7" scab liner from the top of the old cut tubing sub at 9290 all the way up to 2827' MD to repair a logged PC leak at 3280' in the 9-5/8" casing. The 7" liner was fully cemented. The crews saw -20 bbls contaminated cement returns, presumably from the top of the 7", and all cementing parameters seemed normal. The top of the 7" also had an LTP installed. The notes form the 2003 sidetrack reflected that they wanted to pert the Put River and install a straddle assembly, but their economics at the time did not allow the extra expense, so they left a gap between their top of 4-1/2" liner, and their tubing tail. In Feb-2011 the well failed a warm TIFL. After DGLV's were set, a subsequent MIT -IA failed losing 1240 psi in the first 15 minutes. An LDL showed a leak to be at 6163' MD (not a GLM). The well was made non operable for TxIA communication. the well was patched and lasted 4 more months before a subsequent tubing leak happened. Given the poor caliper results, no further non -rig operations were pursued. The well has been SI non -operable since. Proposed plan: : After a planned RWO to perform a tubing swap, Nordic 1 Coiled tubing Drilling rig will drill a through tubing sidetrack on or around Nov 15, 2015. Nordic 2 will set a whipstock at-10,986' and exit into Zone 1 Ivishak formation in the existing 02-14A perforations. The side track will target Zone 1A/1 B reserves. The proposed sidetrack is a-2,207' horizontal Ivishak Zone 1A/1B producer. The lateral will be completed with a 3-1/2" x 3-1/4" x 2-7/8" L-80 liner which will be cemented and perforated isolating the current Zone 1A/1B perforations. CTD Drill and Complete 02-14B program: Rig Start Date: Nov 155t 2015 Pre-RigWork 1. V Pull BPV 2. S Pull B&R and RHC insert, Dummy off Shear GLV 3. F Pressure test CIBP 4. C Mill 4-1/2" CIBP and Push to PBTD, Dummy WS drift 5. V Pre CTD Tree Work Rig Work: 1. MIRU and test BOPE to 250 psi low and 3,500 psi high. Maximum expected surface pressure with gas (0.10 psi/ft) to surface is 2,414 psi. 2. RIH and set 4-1/2" whipstock Top at-10,986' MD 3. Mill 3.80" window plus 10' of rathole. Swap the well to 8.5-9.5 ppg PowerPro. 4. PU drilling BHA with GR/Resistivity 5. Drill 4.25" hole to TD at-13,173 MD 6. Run 3-1/2" x 3-1/4" x 2-7/8" L-80 liner leaving TOL at-9,650' MD. 7. Pump primary cement bringing TOC to TOL, 24 bbls of 15.8 ppg liner cmt planned* 8. Cleanout liner and run RPM/GR/CCL log if cement job does not go as planned. 9. Test liner lap to 2,400 psi. 10. Perforate liner per asset instructions (up to 1500') 11. Freeze protect well, set TWC, RDMO Post Rig: 1. V: Pull TWC, tree work as necessary. 2. S: LTP if necessary.* and KO GLV's 3. T: ASRC flowback * Approved alternate plug placement per 20 AAC 25.112(i) Mud Program: • Well kill: 8.4-8.6 ppg brine. • Milling/drilling: 8.4-9.5 ppg Power Pro for milling window and drilling (>606 psi over -balance ). Disposal: • All drilling and completion fluids and all other Class II wastes will go to Grind & Inject. • All Class I wastes will go to Pad 3 for disposal. Hole size: 4.25" Liner Program: • 3-1/2", 9.3#, L-80, STL Solid Liner 9,650' MD — 10,970' MD • 3-1/4", 6.6#, L-80, TCII Solid Liner 10,970' MD — 13,134 MD • 2-7/8", 6.5# L-80, STL 13,134' MD — 13,173' MD • A minimum of 24 bbls of 15.8 ppg cement will be used for liner cementing. (TOC 9,650' MD) • The primary barrier for this operation: a minimum EMW of 8.4 ppg. • A X-over shall be made up to a safety joint including a TIW valve for all tubulars ran in hole. Well Control: • BOP diagram is attached. • Pipe rams, blind rams and the CT pack off will be pressure tested to 250 psi and to 3,500 psi. • The annular preventer will be tested to 250 psi and 3,500 psi. Directional • See attached directional plan. Maximum planned hole angle is 920. • Magnetic and inclination surveys will be taken every 30 ft. • Distance to nearest property — 33,350' • Distance to nearest well within pool — 520' Logging • MWD directional, Gamma Ray and Resistivity will be run over all of the open hole section. • Cased hole GR/CCL/RPM logs will be run if cleanout run is run. Perforating: • SWS 2", 6 spf, perf guns, 1-1/4" CSH work string, & 2-1/16" CSH • The primary barrier for this operation: a minimum EMW of 8.4 ppg. An EMW of 8.4 ppg for this well will provide 606 psi over -balance to the reservoir. • A X-over shall be made up to a safety joint including a TIW valve for all tubulars ran in hole. Anti -Collision Failures 02-04A fails Anti-Collison with 02-1413's wellpath from: 12,915'—12,970' MD on 02-1413's Wellpath 11,675'-11,766' MD on 02-04A's Wellpath. • 02-04A was abandoned below 10,386' MD with a CIBP (05/19/04), below 10,805' MD with CIBP (07/14/03) and below 11,210' with a CIBP(05/11/02) • 02-10/02-10A/02-10APB1 does not fail Anti -Collision with 02-146's wellpath, however, it does come within 25' (9000') at its closest point. • 02-10/02-10A/02-10APB1 wellbore(s) were sidetracked at 7,799' MD with a CIBP set at 7821' (28/5/00), 02-10/02-10A/02-10APB1 was abandoned with 22 bbls of 15.8# class G cement squeeze down to 8250' Hazards • DS-02 is not an H2S pad • Low Risk of lost circulation with two planned fault crossings Reservoir Pressure • The reservoir pressure on 02-14 is expected to be 3,310 psi at 8966' TVDss. (7.1 ppg equivalent). • Maximum expected surface pressure with gas (0.10 psi/ft) to surface is 2,414 psi. • An EMW of 8.4 ppg for this well will provide 606 psi over -balance to the reservoir. Ryan Ciolkosz CC: Well File CTD Engineer Joseph Lastufka Ryan Ciolkosz CC: Well File CTD Engineer Joseph Lastufka WELLHEAD GRAY ACTUATOR _ OKB. ELEV : 64' BF. ELEV = 34' KOP = 9248' Max Angie = —' @ --- Datum MID = Datum TV D : 8800' SS 02-14A RW O 02-14B CTD PROPOSED 20"CONDUCTOR, 91.5#, H-40, D = 19.124" 13-3/8" CSG, 72#, N-80 BUTT, D = 12.347" 02-14 1 113' 1 1 2717" 1 Minimum ID = " @ ' 14-1/2" TBG, 12.6#, L-80, .0152 bpf, ID = 3.958" 14-1/2- EZ DRILL CBP(06/09/15) I— 9121' SLID WHPSTOCK ^9248' 9-5/8" CSG, 47#, L-80, D = 8.681" 7" SCAB LNR, 26#, L-80, D = 6.276" ^ 9248' d ITOP OF LNR/CMT (— 9650' 3-1/2' LW ___#, L-80 STL, .0087 bpf, D= 2.992' 10970' 4-1/2" PKR WHIPSTOCK (XX/XX/XX) 10986' 4-1/2' LNR, 12.6#, L-80, .0152 bpf, ID = 3.958" �10986' PERFORATION SUFAAARY REF LOG: ON XX/XX/XX ANGLE AT TOP PERF: " @' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sgz DATE SQZ 8905 - 8935 3-1/4" LNR, 6.6#, L-80 TC11, .0079 bpf, D = 2.85" 11 13134' PBTD — 2-7/8" LNR, 6.5#, L-80 STL, .0058 bpf, ID = 2441" 13175' 14-1/2" HES X NIP, D = 3.813" 1 2827' I--i. 9-5/8" X 7" LNR TOP PKR GAS LIFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE 8 7 6 5 4 3 2 1 $6$5' 7" X 4-1/2- HES TNT PKR, ID = 3.865" 4-1/2" HES X NIP, ID = 3.813" L� 4-1/2' HES XD SLDNG SLV {—=4-1/2" BLAST JOINTS (—'LONG) 9000' 7" X 4-1/2" HES TNT PKR, D = 3.865" d-1 /2" HES X NP, ID = 3.813" 9072' LNR TIC -BACK SLV, D = 4.37" 1 t31uD TT NOT LOGGED 9083' 7" X 5" BKR ZXP LTP, D = 4.370" 9094' 7" X 5" HMC HGR, D = 4.410" `L 9100' 5" X 4-1/2" XO, D _3 9� MLLOUT WNDOW (02-14A) 9248' - 9260' 9650' 3.70" DEPLOY SLV, D = 3.00" 10970' —j 3-1 /2" X 3-3/16" XO, D = 2.786' 4-1/2" MLLOUT WINDOW (02-148) 10986' - 11716- 7—FPUP JT w /RA TAG 13134' 1—i3-3/16" X 2-7/8" XO, D= 2.377" DATE REV BY COMMENTS DATE REV BY COMMENTS 06117/80 ?? ORIGINAL COMPLETION 08/13/88 PKR 176 RWO 09108/03 WES SIDETRACK (02-14A) 06/30/15 JMD RWO & CTD PROPOSED PRUDHOE BAY UNIT WELL: 02-14B PEF$AT No: AR No: 50-029-20446-02 SEC 36, T11 N , R14E, 567' FNL 8 851' FWL. BP Exploration (Alaska) TRg = 5" X 7" L FMC 120 WELLHEAD ' GRAY ACTUATOR BAKER C OKB. ELEV : 64' BF. ELEV = 34' KOP = 9249 20' CONDUCTOR 113' Max Angle = 97° @ 11063' 1063, Datum LU = 9627 91.5#, H-40, Datum TV D : 8800, SS D = 19.124" D = 12.347" 271T 13-3/8" CSG, 72#, N•80 BUTT, Minimum ID = 3.725" @ 8865' 4-1/2" HES XN NIPPLE /2" TBG, 12.6#, L-80, .0152 bpf, D = 3.958" 1-j 8877' 4-1/2" EZ DRILL CBP (06/09/15) — 9121' SLMD 9-518" CSG 47#, L-80 BTC, ID 8.681" M9260 7" SCAB LNR, 26#, L-80, D = 6.276" ^-9260 PERFORATION SUMMARY REF LOG: ANGLE AT TOP PEW: 571 @ 9680' Note: Refer to Production DB for historical perf data SQE SPF INTERVAL Opn/Sqz SHOT SOZ 2-7/8" 6 9680- 9700 O 04/02/10 2-1/2" 6 9910 - 9930 O 05/10/06 2-7/8' 6 9930 - 9958 O 03/14/06 2-11T 4 10010 - 10210 O 09/07/03 2-1/2" 4 10430 - 11110 O 09/07/03 2-1/2" 4 11260 - 11780 C 09/07/03 02 -14A I SA 'NOTES: WELL ANGLE> 701 @ 9899'. 219,V—�4-1/2" HES X W, ID= 3.813" 282T I—i 9-5/8" X 7" LNR TOP PKR GAS LIFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE 3 3287 3286 5 KBG-2 DMY BK 0 03/03/11 2 6338 5782 39 KBG-2 DMY BK 0 03/03/11 1 8401 7711 10 KBG-2 DMY BK 0 06/09/15 8800 J—{ 4-1/2" HES X W, ID = 3.813" 8821' 7" X 4-1/2- BKR S-3 PKR D = 3.875" 4-1 /2" HES X hP, ID = 3.813" 8865' 1--14-112" HES XN NP, ID = 3.725" 8877'-14-1/2" VVLEG, ID = 3.958" aAU TT NOT LOGGED 9072' LNR TIEBACK SLV, D = 4.37" 9Q$3' 7' X 5" BKR ZXP LTP, D = 4.370' 9094' 7" X 5" HMC HGR, D = 4.410- 9r� 5" X 4-1/2- XO, D = 3.90" Ih&LOLfF VITDOW (02-14A) 9248' - 9260 FBTD 4-1/2" LNR, 12.6#, L-80, .0152 bpf, D = 3.958" DATE REV BY COMv NTS DATE REV BY COMu WS 06/17/80 ?? ORIGINAL COMPLETION 01/02/14 DUJWD TREE CIO (12/22/14) 08/13/88 PKR 176 RWO 05/08/15 GJB/ PJC PULL PATCW NIP RDCR (5/6-5/7/15) 09/08/03 N2ES SIDETRACK(02-14A) 06/29/15 DU-VJMD SETCBP/GLV C/O (06/09115) 11/18/13 RKT/JNU PULL PXN RUG (11/13/13) 06/30/15 JMD PRE -RIG CLEAN UP OS/12/14 JLS/ PJC SET PATCH (05110/14) 05/14/14 PJC MN ID CORRECTION 11200- 1—i4-1/2" CIBP(01106/06) 11 11792' 11879' PRUDHOE BAY LMT WELL: 02-14A PERMT No- 2031250 API No: 50-029-20446-01 SEC 36, T11 K R14E, 567' FNL 8 851' FVVL BP Exploration (Alaska) 02 Q Cl) it Q 0 J CL Q (1) L �/A \ T T E a m _ m 0 0 0 0 cn m O Z a`aoo a m a N IA Mg a= a U Z Q v N Of a ca 6) (6 J Q 7 O U Y /��`� N (n G E 'o O co V C 0 N I— :5 OW ui V .a O O d L w d c O c N U N a u ui c c Cc m O cc, N w 6 o :? `0 ar U N V z d r a a N O 7 J F Z M a Q rn d m 0 U a m a Qm Y Q Q 0 T � N m j N 2 Z LL o o 0 c % .0 a� c ° °' m d m } a m • W O c 0 o 0 a ° U) m U a xO uJ U �Z m rn O U a m Z a` a) � 0 N N N m Y U)a Z d E ci 7 v N °i 0 N M O M 0 a` c� Z� Z�x Cl n c o 3 � CD co C Lo N N N O V � m Qj N J � U C Y � C Q O) N J J U' N > 7 O J J U L N C (D F (q C 9 d o LL � N N o - - o o CD O 3 3 3 Q O o o Cl o oo � v o n o— co 0 oo per) (p M (N cl) 6J M Q) (D o W) W (D C oc t a o 00 o m w 3o > v C7 c o� nti m w o C r c m 10 O 'ot Z W N C N L — m,-. 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(n N N N N N N N N Z o 0 0 0 0 0 0 0 W C) w J 9 m i EL 4 g m o 0 o v m o N N N N N N U a o o N o m o 0 0 o N O N N N N N N CV Q 0 0 0 0 0 0 0 0 0 Q Q Q o 0 0 o v N N O O O O O O O O O � N _ Q N O O f CO C pp N p N �O rN Om ( m 8 N O O C O o O L Q O Z E O L 7 o N E N Q a o N i North America - ALASKA - BP Prudhoe Bay PB DS 02 02-14 500292044600 02-14B 02-14B WP11 Travelling Cylinder Report 08 July, 2015 Few FFK,-- a BAKER NUGHES �,.., BP rel.2 by Travelling Cylinder Report BAKER HUGHES Company: North America - ALASKA - BP Project: Prudhoe Bay Reference Site: PB DS 02 Site Error: 0.00 usft Reference Well: 02-14 Well Error: 0.00 usft Reference Wellbore 02-14B Reference Design: 02-14B WP11 Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Output errors are at Database: Offset TVD Reference: Well 02-14 Mean Sea Level 2-14A: @ 57.93usft (2-14A:) True Minimum Curvature 1.00 sigma EDM R5K - Alaska PROD - ANCP1 Offset Datum Reference 02-14B WP11 Filter type: GLOBAL FILTER APPLIED: All wellpaths within 200'+ 100/1000 of reference Interpolation Method: MD Interval 25.00usft Error Model: ISCWSA Depth Range: 10,841.16 to 13,173.16usft Scan Method: Tray. Cylinder North Results Limited by: Maximum center -center distance of 1,514.62 usft Error Surface: Elliptical Conic Survey Tool Program Date 7/7/2015 From To (usft) (usft) Survey (Wellbore) Tool Name Description 93.93 9,193.93 02-14 Srvy 2 GYD-CT-DMS (02-14) GYD-CT-DMS Gyrodata cont.drillpipe m/s 9,248.00 10,841.16 2-14A Srvy 2 MWD+IFR+MS (02-14A) MWD+IFR+MS-WOCA MWD + IFR + Multi Station W/O Crustal 10,841.16 13,173.16 02-14B WP11 (02-14B) MWD MWD- Standard Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (usft) (usft) Name (in) (in) 93.93 36.00 20" 20.000 30.000 2,710.93 2,652.80 13 3/8" 13.375 17.500 9,248.00 8,495.78 9 5/8" 9.625 12.250 13,173.15 8,947.41 2 7/8" 2.865 4.250 Summary Site Name Offset Well - Wellbore - Design PB IDS 02 02-01 - 02-01 - 02-01 02-01 A - 02-01 C - 02-01 C 02-04 - 02-04 - 02-04 02-04 - 02-04A - 02-04A 02-05 - 02-05 - 02-05 02-05 - 02-05A - 02-05A 02-05 - 02-05APB1 - 02-05APB1 02-06 - 02-06 - 02-06 02-06 - 02-06A - 02-06A 02-06 - 02-06B - 02-06B 02-06 - 02-06C - 02-06C 02-07 - 02-07 - 02-07 02-07 - 02-07A - 02-07A 02-07 - 02-07APB1 - 02-07APB1 02-07 - 02-07APB2 - 02-07APB2 02-07 - 02-07B - 02-07B 02-07 - 02-07BPB1 - 02-07BPB1 02-07 - 02-07BPB2 - 02-07BPB2 02-08 - 02-08 - 02-08 02-08 - 02-08A - 02-08A 02-08 - 02-08APB1 - 02-08APB1 02-08 - 02-086 - 02-08B 02-09 - 02-09 - 02-09 02-09 - 02-09A - 02-09A Reference Offset Centre to Measured Measured Centre Depth Depth Distance (usft) (usft) (usft) 12,650.00 9,575.00 1,495.55 12, 970.34 11, 766.00 155.40 12, 359.51 12, 820.00 1,500.94 No -Go Allowable Distance Deviation Warning (usft) from Plan (usft) Out of range 229.32 1,276.41 Pass - Major Risk Out of range 0.58 155.10 Pass - Minor 1/20 Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range 217.53 1,291.40 Pass - Major Risk 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 71812015 7 23:08AM Page 2 COMPASS 5000.1 Build 61 A/ 1 BP Travelling Cylinder Report BAKER HUGHES Company: North America - ALASKA- BP Local Co-ordinate Reference: Well 02-14 Project: Prudhoe Bay TVD Reference: Mean Sea Level Reference Site: PB DS 02 MD Reference: 2-14A: @ 57.93usft (2-14A:) Site Error: 0.00 usft North Reference: True Reference Well: 02-14 Survey Calculation Method: Minimum Curvature Well Error: 0.00 usft Output errors are at 1.00 sigma Reference Wellbore 02-14B Database: EDMR5K-Alaska PROD -ANCP1 Reference Design: 02-14B WP11 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 DS 02 02-09 - 02-09APB1 - 02-09APB1 Out of range 02-09 - 02-09AP62 - 02-09APB2 Out of range 02-09 - 02-09B - 02-09B Out of range 02-09 - 02-09BPB1 - 02-09BPB1 Out of range 02-09 - 02-09C - 02-09C Out of range 02-09 - 02-09D - 02-09D Out of range 02-10 - 02-10 - 02-10 12,681.33 9,000.00 196.75 11.44 195.83 Pass - Minor 1/20 02-10 - 02-10A- 02-10A 12,686.31 8,900.00 267.14 9.53 266.51 Pass - Minor 1/20 02-10 - 02-10APB1 - 02-10APB1 12,686.31 8,900.00 267.14 9.55 266.48 Pass - Minor 1/20 02-10 - 02-10B - 02-10B 12,625.00 8,875.00 472.37 196.93 295.23 Pass - Major Risk 02-11 - 02-11 - 02-11 Out of range 02-11 - 02-11A- 02-11A Out of range 02-12 - 02-12 - 02-12 Out of range 02-12 - 02-12A - 02-12A Out of range 02-12 - 02-12APB1 - 02-12APB1 Out of range 02-12 - 02-126 - 02-12B Out of range 02-12 - 02-12C - 02-12C Out of range 02-12 - 02-12D - 02-12D Out of range 02-13 - 02-13 - 02-13 Out of range 02-13 - 02-13A- 02-13A Out of range 02-13 - 02-13B - 02-13B Out of range 02-13 - 02-13C - 02-13C Out of range 02-14 - 02-14 - 02-14 Out of range 02-14 - 02-14A- 02-14A 10,975.00 10,975.00 0.04 1.00 -0.75 FAIL- NOERRORS 02-14 - 02-146 - 02-14B Out of range 02-15 - 02-15 - 02-15 Out of range 02-15 - 02-15A - 02-15A Out of range 02-15 - 02-15APB1 - 02-15APB1 Out of range 02-15 - 02-15B - 02-15B Out of range 02-16 - 02-16 - 02-16 Out of range 02-16 - 02-16A - 02-16A Out of range 02-16 - 02-16B - 02-16B Out of range 02-16 - 02-16C - 02-16C Out of range 02-16 - 02-16CPB1 - 02-16CPB1 Out of range 02-17 - 02-17 - 02-17 Out of range 02-17 - 02-17A - 02-17A Out of range 02-17 - 02-17B - 02-17B Out of range 02-18 - 02-18 - 02-18 Out of range 02-18 - 02-18A- 02-18A Out of range 02-18 - 02-18AP61 - 02-18APB1 Out of range 02-18 - 02-18APB2 - 02-18APB2 Out of range 02-18 - 02-18APB3 - 02-18APB3 Out of range 02-18 - 02-18B - 02-18B Out of range 02-18 - 02-18BPB1 - 02-18BPB1 Out of range 02-18 - 02-18C - 02-18C Out of range 02-18 - 02-18CPB1 - 02-18CPB1 Out of range 02-19 - 02-19 - 02-19 Out of range 02-20 - 02-20 - 02-20 Out of range 02-21 - 02-21 - 02-21 Out of range 02-21 - 02-21 A - 02-21 A Out of range 02-21 - 02-21 B - 02-21 B Out of range 02-22 - 02-22 - 02-22 Out of range 02-22 - 02-22A - 02-22A Out of range c(- - min centre to center distance or covergent point, SF - min separation factor, ES - min ellipse separation 71812015 7:23:08AM Page 3 COMPASS 5000.1 Build 61 Company: North America - ALASKA - BP Project: Prudhoe Bay Reference Site: PB DS 02 Site Error: 0.00 usft Reference Well: 02-14 Well Error: 0.00 usft Reference Wellbore 02-14B Reference Design: 02-146 WP11 BP Travelling Cylinder Report Local Co-ordinate Reference: ND Reference: MD Reference: North Reference: Survey Calculation Method: Output errors are at Database: Offset TVD Reference: FSA2 BAKER HUGHES Well 02-14 Mean Sea Level 2-14A: @ 57.93usft (2-14A:) 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 DS 02 02-22 - 02-226 - 02-226 13,173.16 9,625.00 630.04 282.11 348.29 Pass - Major Risk 02-23 - 02-23 - 02-23 11,525.00 8,925.00 1,293.68 154.32 1,139.56 Pass - Major Risk 02-23 - 02-23A - 02-23A 10,864.27 10,125.00 1,119.95 144.15 983.16 Pass - Major Risk 02-23 - 02-23PB1 - 02-23PB1 11,562.25 9,050.00 1,125.94 137.49 993.29 Pass - Major Risk 02-24 - 02-24 - 02-24 Out of range 02-24 - 02-24A - 02-24A Out of range 02-25 - 02-25 - 02-25 Out of range 02-25 - 02-25A - 02-25A Out of range 02-26 - 02-26 - 02-26 Out of range 02-26 - 02-26A - 02-26A Out of range 02-26 - 02-26APB1 - 02-26APB1 Out of range 02-26 - 02-26APB2 - 02-26APB2 Out of range 02-26 - 02-26B - 02-26B Out of range 02-26 - 02-26C - 02-26C Out of range 02-27 - 02-27 - 02-27 Out of range 02-27 - 02-27A - 02-27A Out of range 02-28 - 02-28 - 02-28 Out of range 02-28 - 02-28A - 02-28A Out of range 02-28 - 02-28APB1 - 02-28APB1 Out of range 02-30 - 02-30 - 02-30 Out of range 02-30 - 02-30A - 02-30A Out of range 02-30 - 02-30B - 02-30B Out of range 02-30 - 02-30BPB1 - 02-30BPB1 Out of range 02-32 - 02-32 - 02-32 Out of range 02-32 - 02-32A - 02-32A Out of range 02-32 - 02-32APB1 - 02-32APB1 Out of range 02-32 - 02-32APB2 - 02-32APB2 Out of range 02-32 - 02-32APB3 - 02-32APB3 Out of range 02-32 - 02-32B - 02-32B Out of range 02-32 - 02-32C - 02-32C Out of range 02-32 - 02-32CP81 - 02-32CPB1 Out of range 02-33 - 02-33 - 02-33 11,900.00 8,750.00 1,222.68 203.72 1,035.13 Pass - Major Risk 02-33 - 02-33A- 02-33A 11,900.00 8,750.00 1,222.68 203.66 1,035.20 Pass - Major Risk 02-33 - 02-33B - 02-33B Out of range 02-35 - 02-35 - 02-35 13,173.16 8,550.00 761.80 178.28 651.01 Pass - Major Risk 02-35 - 02-35A- 02-35A 13,173.16 8,525.00 765.62 178.44 656.26 Pass - Major Risk 02-35 - 02-35B - 02-35B 13,173.16 8,525.00 765.62 178.50 656.24 Pass - Major Risk 02-36 - 02-36 - 02-36 Out of range 02-36 - 02-36A - 02-36A Out of range 02-36 - 02-36APB1 - 02-36APB1 Out of range 02-40 - 0240 - 02-40 Out of range 02-40 - 02-40PB1 - 02-40PB1 Out of range Plan 02-41 - Plan 02-41 - 02-41 wp06 Out of range Offset Design PB DS 02 - 02-01 A - 02-01 C - 02-01 C Offset site Error. 0.00 usft Survey Program: 112-GYD-CT-CMS, Reference 2914-INC+TREND, 3459-MWD+IFR+MS-WOCA Offset Semi Major Axis Rule Assigned: Major Risk Offset Well Error. 0.00 usft Measured Vertical Depth Depth (usft) (usft) Measured Vertical Reference Offset Toofface+ Depth Depth Azimuth (usft) (usft) (usft) (usft) (°) Offset Wellbore +N/S usft (usft) Centre +E/-W (usft) Casing - Centre to Hole Size Centre m) (usft f ) No Go Distance (usft) Allowable Warning Deviation (usft) 11,900.00 8.950.71 10,150.00 8,904+38 25.15 30.10 9.67 969.58 -424.61 4.375 1,507.62 193.48 1,319.93 Pass - Major Risk 11,900.00 8,950.71 10,175.00 8,904.21 25.15 30.13 9.67 976,91 -448.51 4.375 1,511.37 193.66 1,323.50 Pass - Major Risk -1-1 uiata11- ui wvelyent Point, or - min separation Tactor, to - min enlpse separation 7/8/2015 7.23:08AM Page 4 COMPASS 5000.1 Build 61 Loepp, Victoria T (DOA) From: Loepp, Victoria T (DOA) Sent: Tuesday, July 21, 2015 1:35 PM To: Ciolkosz, Ryan R (Ryan.Ciolkosz@bp.com) Subject: PBU 02-14B(PTD 215-121) liner cement Ryan, The 116 sx does not seem to be an adequate amount of cement for the production liner. Could you please verify? 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. Loeppa-alaska.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.go_v Davies, Stephen F (DOA) From: Davies, Stephen F (DOA) Sent: Thursday, July 16, 2015 9:55 AM To: 'Ryan.Ciolkosz@bp.com' Cc: Lastufka, Joseph N (Joseph.Lastufka@bp.com); Schwartz, Guy L (DOA); Bettis, Patricia K (DOA); Loepp, Victoria T (DOA) Subject: PBU 02-14B (PTD #215-121) Ryan, The intent of AOGCC's Permit to Drill application form is to provide a single -page summary for each proposed well, including —for proposed redrill wells —the present condition of the parent wellbore. Repeated use of the phrase "See Attachment" to describe the present condition of casing and cement within PBU 02-14A (the parent wellbore for PBU 02-14B) is not sufficient. The Permit to Drill application for PBU 02-14B will be returned to BP for correction. Future applications containing the phrase "See Attachment" within well -data boxes will be considered deficient, and they will be returned to BP. Thanks for your help, Steve Davies Senior Petroleum Geologist Alaska Oil and Gas Conservation Commission (AOGCC) Phone: 907-793-1224 AOGCC: 907-279-1433 Fax: 907-276-7542 333 West 7ch Avenue, Suite 100 Anchorage, AK 99501 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. For future Permit to Drill applications, please enter well data into all appropriate boxes on the 10-401 form. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION NOTICE OF APPLICATION DEFICIENCY Well: PBU 02-14B Permit to Drill: 215-121 The attached application is being returned due to the deficiency or deficiencies listed below. Please submit a new application and all required supporting information. _ insufficient information to confirm that the casing and cementing program will protect freshwater aquifers insufficient information to demonstrate that the proposed perforations will be in compliance with applicable spacing provisions insufficient information to demonstrate that adequate barriers to flow will be maintained failure to calculate (or to calculate accurately) anticipated pressures insufficient information to confirm quality of cement and TOC, relative to proposed perforations _insufficient or contradictory well location information or coordinates _ins fficient or contradictory geologic prognosis information _other: Use of the phrase "See Attachment" within the "Present Well Condition Summary" section of the Permit to Drill appl&'nm isinsufficient. Please provide casing and cement data for the parent well PBU 02-14A. i.1 7 Workflow for Deficient Applications Geologist/Engineer Reviewer — fill out, initial, and date the Notice of Application Deficiency form (attached) and pass the checklist with the folder containing the deficient application to Sam. Sam — • make a photocopy of the Notice of Application Deficiency form (deficiency form); and • in the front -desk ledger spreadsheet for 401s or 403s, enter the date the deficient application was returned, enter "courier" or "mail" into the appropriate column, and, in the comments column, enter "Application deficient, returned to operator" (do not make an entry into the Date Approved column); and • mark a line through all pages of the application (original and duplicate), write "Application deficient", and have a Commissioner initial original and duplicate, • pass to Angela the folder that contains the duplicate copy of the deficiency form and the duplicate copy of the deficient application; and • pass the original deficiency form and the original deficient application to Phoebe or Jenni. Angela — • via courier or mail, return the duplicate deficiency form and the duplicate copy of the deficient application to the operator; Phoebe or Jenni — • in RBDMS, under the History tab for the well, enter the new TYP_WORK code DTDAR (Date Deficient Application Returned to operator); and • place the folder in the confidential room for filing. Makana — will process Deficient Permit to Drill Applications in their new well file folders from Phoebe through her confidential mailbox; she will create labels and add PTD codes to folders, and then physically file them; and will process Deficient Application for Sundry through the confidential room general mailing, she will file the document within its well history folder; in the Confidential Room if the well is confidential, or give to Maria for scanning and then file into its well file folder in the Records Room of the Library if it is non -confidential. When AOGCC receives a replacement application: Angela — log the application in as usual into the 401 or 403 ledger spreadsheet and pass the folder to the geologist. Geologist — • review the application for completeness: o if the application is deficient, pass the folder to Sam, as outlined above, or o if the application is complete: ■ check the History tab for the well in RBDMS to see if a deficient application is outstanding: ■ if no deficient applications are listed, process as usual; or ■ if this is a re -submitted deficient application, in RBDMS under the History tab for the well, enter the new TYP_WORK code DTDAS (Date Deficient Application Re -submitted - Deficiencies Resolved); ■ retrieve the 401 or 403 folder containing the deficient application from the Confidential Room and place the re -submitted application in it; and ■ process as usual. TRANSMITTAL LETTER CHECKLIST WELL NAME:/ PTD: _ j Z./ Development _ Service _ Exploratory Stratigraphic Test _ Non -Conventional FIELD: POOL: Check Box for Appropriate Letter / Paragraphs to be Included in Transmittal Letter CHECK OPTIONS TEXT FOR APPROVAL LETTER MULTI The permit is for a new wellbore segment of existing well Permit LATERAL (If last two digits No. , API No. 50- - - - 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 sample 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#: 2151210 Company BP EXPLORATION (ALASKA) INC Initial Class/Type Well Name: PRUDHOE BAY UNIT 02-14B Program DEV Well bore seg [; DEV / PEND GeoArea 890 Unit 11650 On/Off Shore On Annular Disposal C Administration 1 Permit fee attached NA 2 Lease number appropriate Yes Entire well lies within ADL 0028308. 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 341D, 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 7/17/2015 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 02-14 Engineering 19 Surface casing protects all known USDWs NA Surface casing set in PBU 02-14 20 CMT vol adequate to circulate on conductor & surf csg NA Surface casing set and fully cemented 21 CMT vol adequate to tie-in long string to surf csg NA 22 CMT will cover all known productive horizons Yes Productive interval will be completed with cemented 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 Yes PTD 203-125, Sundry 315-428 26 Adequate wellbore separation proposed Yes Anti -collision analysis complete;major risk failures 02-04:abd w/ CIBP; 02-10:cement & CIBP 27 If diverter required, does it meet regulations NA Appr Date 28 Drilling fluid program schematic & equip list adequate Yes Max form pressure is 3310 psi(7.1 ppg EMW ); will drill w/ 8.4 ppg EMW VTL 7/23/2015 29 BOPEs, do they meet regulation Yes 30 BOPE press rating appropriate; test to (put psig in comments) Yes MPSP is 2414 psi; will test BOPS to 3500 31 Choke manifold complies w/API RP-53 (May 84) Yes 32 Work will occur without operation shutdown Yes 33 Is presence of H2S gas probable Yes H2S measures required 34 Mechanical condition of wells within AOR verified (For service well only) NA 35 Permit can be issued w/o hydrogen sulfide measures No DS 02 wells are H2S-bearing. H2S measures are required. Geology 36 Data presented on potential overpressure zones Yes Planned drilling mud program (8.4 ppg) appears adequate to control operator's forecast Appr Date 37 Seismic analysis of shallow gas zones NA pore pressure gradient of 7.1 ppg. SFD 7/17/2015 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 Di S z' 1s C, Zs��s