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Home My WebLink About215-023Guhl, Meredith D (DOA) From: Lastufka, Joseph N <Joseph.Lastufka@bp.com> Sent: Monday, April 3, 2017 4:31 PM To: Loepp, Victoria T (DOA); Guhl, Meredith D (DOA) Cc: G ANC PDC; Wright, Chelsea (Sperry Sun Drilling Services); Egbejimba, Uchenna J Subject: Cancel Permit to Drill for X-121-1 (PTD #215-023) Victoria, Please cancel the Permit to Drill for X-121-1 (PTD #215-023). This well will not be drilled. 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 BP Exploration Alaska1900 E. Benson Blvd.lRoom: 788DIAnchorage, AK THE STATE °fALASKA GOVERNOR BILL WALKER John McMullen Engineering Team Leader BP Exploration (Alaska), Inc. P.O. Box 196612 Anchorage, AK 99519-6612 Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 www.aogcc.olasko.gov Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU X-12L1 BP Exploration (Alaska), Inc. Permit No: 215-023 Surface Location: 520' FNL, 695' FEL, SEC. 07, T1ON, R14E, UM Bottomhole Location: 744' FNL, 399' FWL, SEC. 08, T10N, 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, 01-/� Daniel T. Seamount, Jr. Commissioner DATED this ��day of February, 2015. STATE OF ALASKA RECEIVED ALAS DIL AND GAS CONSERVATION COMM ON PERMIT TO DRILL -]AN 3 0 2015 f l y 20 AAC 25.005 _ 1 a.Type of work: 1 b.Proposed Well Class: ® Development Oil - ❑ Service - Wini ® Single Zone • 1 c. Specify if well is proposed for: ❑ rill ER Lateral ❑ Stratigraphic Test ❑ Development Gas ❑ Service - Supply ❑ Multiple Zone ❑ Coalbed Gas ❑ Gas Hydrates edrill ❑ 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 X-12L1 3. Address 6. Proposed Depth: 12. Field / Pool(s) P.O. Box 196612, Anchorage, Alaska 99519-6612 MD 11360' - TVD 8748'ss ' Prudhoe Bay / Prudhoe Bay . 4a. Location of Well (Governmental Section): 7. Property Designation (Lease Number): Surface: ADL 028313 520' FNL, 695' FEL, Sec. 07, T10N, R14E, UM 8. Land Use Permit: 13. Approximate Spud Date: Top of Productive Horizon: 219' FNL, 1628' FEL, Sec. 07, T10N, R14E, UM March 1, 2015 9. Acres in Property: 14.Distance to Nearest Property: Total Depth 744' FNL, 399' FWL, Sec. 08, T10N, R14E, UM 2501 13500' 4b. Location of Well (State Base Plane Coordinates - NAD 27): 10.KB Elevation above MSL: 74.36' feet 15.Distance to Nearest Well Open Surface: x 665202 • y- 5939594 • Zone- ASP4 GL Elevation above MSL: 38.96' feet to Same Pool: 750' 16. Deviated Wells: Kickoff Depth: 9055' feet 17. Maximum Anticipated Pressures in psig (see 20 AAC 25.035) Maximum Hole Angle: 107 degrees Downhole: 3402 ' Surface: 2506 18. Casing Program S ecifications Top - Setting Depth - Bottom Quantity of Cement, c.f. or sacks Hole Casing Weight I Grade Coupling Length MD TVD MD TVD (including stage data) 4-1/4" 2-7/8" 6.5# 13Cr85 STL 3000' 8360' 8115'ss 11360' 8748'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). 9730' 9559' None 9678' 9507' None Casing Length Size Cement Volume MD TVD Conductor / Structural 80' 20" 8.6 cu yds Concrete 36- 116' 36' - 116' Surface 2628' 13-3/8" 3885 cu ft Permafrost 1 36' - 2664' 36' - 2664' Intermediate 8851' 9-5/8" 1220 cu ft Class 'G' 133 cu ft Permafrost 34' - 8885' 34' - 8714' Production Liner 1370' 7" 420 cu ft Class 'G' 8360' - 9730' 8189' - 9559' Perforation Depth MD (ft): 9510' - 9220' Perforation Depth TVD (ft): 9339' - 9049' 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. 1 hereby certify that the foregoing is true and correct: Contact Travis Boltz, 564-5750 J Printed Name John,.Pdg Jl�len% Title Engineering Team Leader Email Travis.Boltz@bp.com 5711 Signature Phone 564-Date Commission Use Only Permit To Dril)' API Number: Permit Ap v I to See cover letter for Number: j' f .j T (� 50-029-20468-60-00 �r 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: L130P frsf 7,0 35-0Q f S l Samples Req'd: ❑ Yes O No Mud Log Req'd: []'Yes E'No 14k-) v� ci! Gb)' 12 rL VC v1 z�' ttS fo Z SOU �5I H2S Measures: Eyes ❑��o Directional Survey Req'd: ❑ Yes ❑ No Spacing exception req'd: ❑ Yes [� No inclination -only svy Req'd: ❑ Yes ❑'No APPROVED BY Z / i I I -5 APPROVED BY COMMISSIONER THE COMMISSION Date Form 10-401 Revised 10/2012 Thi� p rK4 if �ff 4 l&nlhs from the date of approval (20 AAC 25.005(g)) Submit Form and Attachments In Duplicate r7'/- Z/(P//"5- V V 1`1 ` /y / 4-/- /• /i,;' To: Alaska Oil & Gas Conservation Commission From: Travis Boltz Obp CTD Engineer Date: January 29, 2015 Re: X-121_1 Permit to Drill Request Approval is requested for a permit to drill a CTD sidetrack from well X-121_1 using Nordic 1 to a target in Ivishak Zone 4B. Rig Work scheduled to begin February 1st, 2015 1. MIRU and test BOPE 250 psi low and 3,500 psi high. 2506 psi MASP . 2. Mill 3.80" window and 10' of rathole. 3. Drill Build section: 4.25" OH, —300' 370 deg/1 00planned) 4. Drill Lateral section: 4.25" OH, 1855' 120 de /100planned) 5. Run 2-7/8" slotted liner to leaving TOL 8,360' MD. 6. Freeze protect well to 2500' MD 7. Set TWC, RDMO Post -Rig Work: 1. Re -install wellhouse, flowline and pull TWC. 2. Set GLV's Mud Program: • Milling/drilling: 8.6 ppg PowerVis for milling window and drilling (594 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 9,055' MD to 11,360' MD Liner Program: • 2-7/8", 6.5 Ib/ft, 13Cr-85, STL, Slotted 8360' MD - 11,360' 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 1060, inclination at kick off point is 1.4° • Magnetic and inclination surveys will be taken every 30 ft. No gyro will be run. • Distance to nearest property - 13,500'. • Distance to nearest well within pool - 750'. Logging: • MWD directional, Gamma Ray and Resistivity will be run over all of the open hole section. Anti -Collision Failures: • None Hazards: • X pad is considered a H2S pad. Well X-02 had 124 ppm H2S on 9/11/2014. • Most recent H2S level on X-02 is 124 ppm recorded on 9/11 /2014. • The lost circulation risk in X-10A is considered to be high, with 2 fault crossings Reservoir Pressure: • The reservoir pressure on X-12L1 expected to be 3402 psi at 8962' TVDSS. (7.3 ppg equivalent). - - • Maximum expected surface pressure with gas (0.10 psi/ft) to surface is 2,506 psi. • An EMW of 8.6 ppg for this well will provide 605 psi over -balance to the reservoir. Travis Boltz CC: Well File CTD Engineer Joseph Lastufka I ' TREE = 63/8" " CIW !(VELLHEAD = GRAY ACTUATOR = BAKER C INITIAL KB. ELE 74.36' BF. ELEV = 40.16' KOP = 3150' Max Angle Datum MID = Datum TV D = 8800' SS PROPOSED 120" CONDUCTOR 1—I ? 13-3/8" CSG, 72#, L-80 BTRS, D = 12.347" 1-� 2664' Minimum ID TOP OF 3-112" LNR/ CEMENTED I 836W TOP OF 7" LNR 8360' 4-1/2" TBG, 12.6#, 1-80-A/B MOD I 8405' BTRS IPC, .0152 bpf, D = 3.958" 1 9-5/8" CSG, 47#, L80-BTRS, D = 8.681" H 8885' 1- 3-1/2' LNR _#, 13CR-85 STL, _bpf, ID = 9050' 7" BKR WHIPSTOCK (XX/XX/14) j 9055' 7" LNR 29#, L-80 BTRS, .0371 bpf, ID = 6.184" -9055' PERFORATION SIAMMRY REF LOG: BRCS ON 08-25-80 ANGLE AT TOPPERF: 1 @9010' Note: Refer to Production DB for historical perf data SIZE SPF I INTERVAL I Opn/Sqz I SHOT SQZ X-12A 3-3/8" 4 9010 - 9034 O 03/09/89 3-1/8" 4 9056 - 9070 O 02/11/81 3-1/8" 4 9076 - 9090 O 02/11/81 3-3/8" 4 9090 - 9096 O 04/27/89 3-3/8" 4 9106 - 9160 O 02/11/81 3-1/8" 4 9170 - 9181 O 02/11/81 2-7/8" 6 9198 - 9204 O 05/17/98 2-7/8" 6 9205 - 9209 O 05/17/98 2-7/8" 6 9212 - 9220 O 05/17/98 X-12A L1 SLTDI _— I O I -_ /—/—I X-12A L1 SAI 'NOTES: CHROME LNR 2114' H SSSV OTIS LAND NIP. D = 3.813" 2534' DV PKR GAS LIFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE 5 2981 2980 7 OTIS DOME RM 16 05/05/07 4 5143 4987 15 OTIS DOME RM 16 05/05/07 3 7151 6981 2 OTIS DOME RM 16 05/05/07 2 7880 7709 1 OTIS DMY RA 0 03/29/80 "1 8112 7941 1 1 OTIS SO RM 20 03/26/10 ""NU I E: I KUUBLE SETTING UGLV IN #1 ON 8/29/05 8223' OTIS XA SLD SLV, D = 3.813" 8281' 1--- [BKR SBR TBG SEAL ASSY 1 8300' 9-5/8" BKR SAB PKR, D = 3.813" s348' 4-1 /2" OTIS X NIP, D = 3.813" $360'—]3.70" DEPLOYMENT SLV, ID = 3.00" 8374' 4-1/2" HES XN NIP MILLED TO 3.80" (XX/XX/XX) 8405' 4-1/2" TBG TAL, BKR SOS, D = 1958" 1 8391' H ELMD TT DATE NOT AVAILABLE I 9050' 1-13-1/2 X 2-7/8" XO ID = " MILLOUT WINDOW (X-12A) 9060' - 9069' ---1 9070' HAIL SWELL PKR 9750' I —I HAL SWELL PKR \ jk14 5 FBTD 1135W 2-7/8" SLOTTED LNR #, 13-CR STL, _bpf, ID = " 11360' DATE REV BY COMMENTS DATE REV BY COMVEVTS 08/29/80 ORIGINAL COMPLETION 12/09i14 JMD BUILT PROPOSED CTD (X-12AL1) PRUDHOE BAY UNIT WELL: X-12A PERMIT No: API No: 50-029-20468-01 Sec_ 7, T10N, R14E, 520' FLN 8 694' FEL BP Exploration (Alaska) I . TF7a 63/8' " CIW *ELLHEAD = GRAY I ACTUATOR = BAKER Cj INrfIAL KB. ELE 74,36' BF. ELEV = 40.16' KOP = 3150' Max Angle = 27° @ 3800' Datum MD = 9045' Datum TV D = 8800' SS 13-3/8" CSG, 72#, L-80, ID = 12.347" 2664' " Minimum ID = 3.725" @ 8374' 4-1/2" OTIS XN NIPPLE TOP OF 7- LNR I 8360' LBO-A/B MOD 8405' BTRS PC, .0152 bpf, D = 1958' 9-5/8' CSG, 47#, L80-13TRS, D = 8.681- PERFORATION SLLWRY REF LOG: BHCS ON 08-25-80 ANGLEAT TOP PERF: 1 @ 9010' Note: Refer to Production DB for historical pert data SV-E SPF INTERVAL Opn/Sqz SHOT SOZ 3-3/8" 4 9010 - 9034 O 03/09/89 3-1/8" 4 9056 - 9070 O 02/11/81 3-1/8" 4 9076 - 9090 O 02/11/81 3-31W 4 9090 - 9096 O 04/27/89 3-3/8" 4 9106 - 9160 O 02/11/81 3-1/8' 4 9170 - 9181 O 02/11/81 2-7/8" 6 9198 - 9204 O 05/17/98 2-7/8" 6 9205 - 9209 O 05/17/98 2-7/8" 6 9212 - 9220 O 05/17/98 PBTD 967V 7" LNR, 29#, L-80, .0371 bpf, D = 6.184- 973W SAf NOTES: X-12 ® 2114' —�SSSV OTIS LAND NIP, ID = 3.813" 253,V 40V PKR GAS LIT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE 5 2981 2981 5 OTIS DOME RM 16 05/05/07 4 5143 4987 19 OTIS DOME RM 16 05/05/07 3 7151 6980 2 OTIS DOME RM 16 05/05/07 2 7880 7709 1 OTIS DMY RA 0 03/29/80 " 1 8112 1 7941 1 1 1 OTC SO RM 20 03/26/10 "NU I If 111MULE SET ►1NG MLV IN #1 ON 8/29105 $223' OTIS XA SLD SLV, D = 3.813- 828V BKR SBR, TBG SEAL ASSY 8300' 9-5/8" BKR SA B PI(R, D = 3.813" $34g' 4-1 /2" OTIS X NIP, D = 3.813" 8374 4-1/2' OT1S XN NP, D= 3.725" 8405'—14-1/2" TBG TAL, BKR SOS, D = 3.958- 8391' E3MDTTDATENOTAVAILABLE 9074' 1---H MARKER JOW DATE REV BY COMMENTS DATE REV BY COWS TTS 08/29/80 ORIGINAL COMPLETION 04/26/07 DAV(TL GLV C/O (4/14/07) 05116/06 KSB/PJC GLV CIO 05/05/07 A GLV CJO 07/09/06 JLJ/PAG PLUG SET/PULL HISTORY 05/09/07 LWB/PJC GLV TVD CORRECTIONS 07/09/06 JLJ/PAG PULL PXN RUG @ 8374 03/26/10 SWC (PJ GLV CIO 0812410E 1COwTfA WANEfRSAFETY NOTE 10/31/14 PJC TREEILEGEND COFRRECTIONS 04/02/07 MS/PJC PULL FISH @ 9222 (09/22/00) PRUDHOE BAY LNT WELL: X-12 R9RMT No: '1800440 AR No: 50-029-20468-00 Sec. 7, T10N, R14E, 520' FLN 8 694' FEL BP Exploration (Alaska) • W N W mum a= m 0 Cl) lot a 0 J CL m v L � a � Ln m ■_ N N _ X O V i 0a s m C �XNN c a m Co Z a`axx a N N Igaz W m H z a U z Q ❑ O ' a N m � � Y N D Q N(CD) J � U m w � 3 X m N a) m Y ` .c ❑ N Ci .a c o � L w Gf N O C 01 U 10 p U V d 7 o w y m U m •c ma 0 J Z N 0 i O 0L N �J m � h 0 U m d Qm Y U) Q U T O a CO E a) m Q o a L L J J O X N N N o o 2 m z d m X X X Q a R .. o. � o c Z+tW" m a rn 0 ° :: m m y 0 CL 0 c o o a m a� U N C f0 N U > w U J � N m m o � wcm N C C 27 D m' W O = O � 7 Of a D U d x0 C7 w U >; r- z m �0 m U LO m Z N :3 d v C a au N N f° Q' m co Q 7Z Q m E y _ .� w N O N00 o O. 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Cylinder North Results Limited by: Maximum center -center distance of 1,332.46 us Error Surface: Elliptical Conic Survey Tool Program Date 1/28/2015 From To (usft) (usft) Survey (Wellbore) Tool Name Description 100.00 9,000.00 1 : Sperry -Sun BOSS gyro multi (X-12) BOSS -GYRO Sperry -Sun BOSS gyro multishot 9,000.00 11,360.00 X-121_1 WP04 (X-121-1) MWD MWD - Standard — Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (usft) (usft) Name (in) (in) 8,885.00 8,639.60 9 5/8" 9.625 12.250 11,360.00 8,748.13 2 7/8" 2.875 4.250 Summary Reference Measured Site Name Depth Offset Well - Wellbore - Design (usft) PB X Pad X-04 - X-04 - X-04 X-04 - X-04A - Plan #10 X-04A update X-04 - X-04A - X-04A X-05 - X-05 - X-05 X-06 - X-06 - X-06 X-08 - X-08 - X-08 X-08 - X-08A - Drilling Plan 081603 X-08 - X-08A - X-08A X-09 - X-09 - X-09 X-09 - X-09A - X-09A X-09 - X-09B - X-09B X-09 - X-098 - X-09B wp04 X-10 - X-10 - X-10 X-10 - X-10A - X-10A X-10 - X-10A - X-10A WP07 X-11 - X-11 - X-11 X-11-X-11A-X-11A X-12 - X-12 - X-12 9,074.99 X-13 - X-13 - X-13 X-13 - X-13A - X-13A X-14 - X-14 - X-14 X-14 - X-14A - X-14A X-15 - X-15A - Plan #4 X-17 - X-17 - X-17 X-18 - X-18 - X-18 X-19 - X-19 - X-19 X-19 - X-19A - X-19A X-19 - X-19B - X-19B CC - Min centre to center distance or coveroent 112812015 2:58:10PM Offset Centre to No -Go Allowable Measured Centre Distance Deviation Warning Depth Distance (usft) from Plan (usft) (usft) (usft) 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 Out of range Out of range Out of range Out of range Out of range Out of range 9,075.00 0.32 0.81 -0.48 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 Out of range Out of ranae nt, SF - min separation factor. ES - min ellipse separation Page 2 COMPASS 5000.1 Build 61 of BP FIN A 9 by Travelling Cylinder Report MYGMES INTEQ Company: North America - ALASKA - BP Project: Prudhoe Bay Reference Site: PB X Pad Site Error: 0.00 usft Reference Well: X-12 Well Error: 0.00 usft Reference Wellbore X-121_1 Reference Design: X-121_1 WP04 Summary Site Name Offset Well - Wellbore - Design PB X Pad X-19 - X-19BL1 - X-19BL1 X-19 - X-19BL2 - X-19BL2 X-19 - X-19BL2-01 - X-19BL2-01 X-19 - X-19BL2-01* - X-1981-2-01 X-19 - X-19BPB1 - X-19BPB1 X-20 - X-20 - X-20 X-20 - X-20A - X-20A X-20 - X-20PB1 - X-20PB1 X-22 - X-22 - X-22 X-22 - X-22A - X-22A X-22 - X-22PB1 - X-22PB1 X-23 - X-23 - X-23 X-24 - X-24 - X-24 X-24 - X-24A - X-24A X-25 - X-25 - X-25 X-26 - X-26 - X-26 X-27 - X-27 - X-27 X-28 - X-28 - X-28 X-29 - X-29 - X-29 X-30 - X-30 - X-30 X-30 - X-30A - Plan #13 X-30 - X-30A - X-30A X-30 - X-30APB1 - Plan #11 X-30 - X-30APB1 - X-30APB1 X-30 - X-30APB2 - X-30APB2 X-30 - X-30PB1 - X-30PB1 X-31 - X-31 - X-31 X-31 - X-31 L1 -Plan #4x X-31 - X-31 L1 - X-31 L1 X-32 - X-32 - X-32 X-34 - X-34 - X-34 X-34 - X-34PB1 - X-34PB1 X-35 - X-35 - X-35 X-35 - X-351_1 - Plan #5 X-35 - X-351_1 - X-351_1 X-36 - X-36 - X-36 Local Co-ordinate Reference: ND Reference: MD Reference: North Reference: Survey Calculation Method: Output errors are at Database: Offset ND Reference: Well X-12 Mean Sea Level RKB @ 74.36usft True Minimum Curvature 1.00 sigma EDM R5K - Alaska PROD - ANCP1 Offset Datum Reference Offset Centre to No -Go Allowable Measured Measured Centre Distance Deviation Warning Depth Depth Distance (usft) from Plan (usft) (usft) (usft) (usft) 9,016.38 9,200.00 1,295.85 209.57 1,086.34 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 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 Out of range Out of range Out of range Out Of range Out of range Out of range Out of range Pass - Major Risk Out of range Out of range Out of range Out of range Out of range Out of range Offset Design PBX Pad - X-12 - X-12 - X-12 Offset Site Error: 0.00 usft Survey Program: 100-BOSS-GYRO 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 +NI-S +E/-W Hole Size Centre Distance Deviation (usft) (usft) (usft) (usft) (usft) (usft) (") (usft) (usft) (in) (usft) (usft) (usft) 9,025.00 8,779.58 9,025.00 8,779.58 0.01 0.02 -3.01 301.91 -933.89 5.625 0.00 0.47 -0.47 FAIL- NOERRORS, CC 9,050.00 8,804.57 9,050.00 8,804.57 0.03 0.05 -3.01 301.33 -933.82 5.625 0.00 0.49 -0.47 FAIL-NOERRORS 9,074.99 8,829.55 9,075.00 8,829.57 0.03 0.07 -16.47 300.75 -933.80 5.625 0.32 0.81 -0.48 FAIL - NOERRORS, ES, SF 9,099.63 8,853.98 91100.00 8,854.56 0.03 0.10 -42.19 300.14 -933.84 5.625 2.92 2.40 0.52 Pass-NOERRORS 9,122.91 81876.36 9,125.00 8,879.55 0.03 0.12 -43.30 299.55 -933.90 5.625 9.33 3.96 5.37 Pass - NOERRORS 9,144.01 8,895.63 9,150.00 8,904.55 0.03 0.14 -42.81 298.99 -933.95 5.625 19.13 5.32 13.80 Pass - NOERRORS 9,162.57 8,911.50 9,175.00 8,929.54 0.04 0.16 -42.37 298.45 -933.99 5.625 31.78 6.45 25.33 Pass - NOERRORS 9,178.57 8,924.18 9,200.00 8,954.53 0.04 0.18 -42.04 297.94 -934.02 5.625 46.76 7.36 39.39 Pass-NOERRORS CC - Min centre to center distance or covergent point, SF - min separation factor, ES - min ellipse separation 1/28/2015 2:58:10PM Page 3 COMPASS 5000.1 Build 61 BP IG&I bP Travellin C Under Re Report BAKER 0�' 9 Cylinder p NU6NES INTEQ Company: North America - ALASKA - BP Project: Prudhoe Bay Reference Site: PB X Pad Site Error: 0.00 usft Reference Well: X-12 Well Error: 0.00 usft Reference Wellbore X-121-1 Reference Design: X-121-1 WP04 Offset Design PB X Pad - X-12 - X-12 - X-12 Survey Program: 100-BOSS-GYRO Reference Offset Semi Major Axis Measured Vertical Measured Vertical Reference Offset Toolface+ Depth Depth Depth Depth Azimuth (usft) (usft) (usft) (usft) (usft) (usft) (I 9,192.25 8,934.17 9,225.00 8,979.53 0.04 0.20 -41.77 9,203.89 8,942,00 9,250.00 9,004.53 0.05 0.21 -41.53 9,213.81 8,948.16 9,275.00 9,029.52 0.05 0.23 41.31 9,222.30 8,953.02 9,300.00 9,054.52 0.06 0.25 41.11 9,230.00 8,957.10 9,325.00 9,079.52 0.06 0.25 40.95 9,235.90 8,960.00 9,350.00 9,104.52 0.07 0.26 -40.82 9,240.56 8,962.15 9,375.00 9,129.52 0.07 0.27 -40.71 9,246.17 8,964.58 9,400.00 9,154.52 0.08 0.27 -40.72 9,250.00 8,966.13 9,425.00 9,179.52 0.08 0.28 -40.72 9,254.13 8,967.71 9,450.00 9,204.52 0.09 0.28 -40.75 9,260.00 8,969.78 9,475.00 9,229.52 0.09 0.29 40.83 9,260.00 8,969.78 91500.00 9,254.52 0.09 0.29 -40.81 9,260.00 8,969.78 9,525.00 91279.52 0.09 0.29 -40.80 9,265.63 8,971.56 9,550.00 9,304.52 0.10 0.29 40.88 91270.00 8,972.81 9,575.00 9,329.52 0.10 0.29 -40.94 9,270.00 8,972.81 91600.00 9,354.52 0.10 0.29 -40.91 9,270.00 8,972.81 9,625.00 9,379.52 0.10 0.28 40.89 9,270.00 8,972.81 9,650.00 9,404.52 0.10 0.28 40,87 9,274.91 8,974.08 9,675.00 9,429.52 0.11 0.27 -40.95 9,280.00 8,975.24 9,700.00 9,454.52 0.12 0.26 41.03 9,280.00 8,975.24 9,725.00 9,479.52 0.12 0.26 41.02 9,280.00 8,975.24 9,730.00 9,484.52 0.12 0.25 -41.02 Local Co-ordinate Reference: ND Reference: MD Reference: North Reference: Survey Calculation Method: Output errors are at Database: Offset ND Reference: Offset Wellbore Centre +N/-S +E/-W (usft) (usft) 297.49-934.03 297.09-933.98 296.77-933.87 296.51-933.72 296.30-933.54 296.15-933.39 296.05 -933.27 296.00 -933.16 295.97 -933.08 295.92 -933.02 295.86 -932.98 295.78 -932.95 295.72 -932.93 295.71 -932.88 295.76 -932.82 295.87 -932.74 296.01 -932.67 296.19 -932.65 296.37 -932.66 296.56 -932.67 296.75 -932.68 296.79 -932.68 Well X-12 Mean Sea Level RKB @ 74.36usft True Minimum Curvature 1.00 sigma EDM R5K - Alaska PROD - ANCP1 Offset Datum Rule Assigned: NOERRORS Casing - Centre to No Go Hole Size Centre Distance (in) (usft) (usft) 5.625 63.58 8.0 5.625 81.85 8.6 5.625 101.27 9.1 5.625 121.59 9.4 5.625 142.64 9.7 5.625 164.28 9.9 5.625 186.42 10.1 5.625 208.93 10.3 5,625 231.77 10.4 5,625 254.86 10.5 5.625 278.19 10.7 5,625 301.64 10.7 5.625 325.33 10.7 5.625 349.06 10.8 5.625 372.98 10.9 5.625 396.96 10.9 5.625 421.07 10.9 5.625 445.29 10.9 5.625 469.50 11.0 5.625 493.87 11.1 5.625 518.20 11.1 5.625 523.07 11.1 Offset Site Error: 0.00 usft Offset Well Error: 0.00 usft Allowable Warning Deviation (usft) 9 55.49 Pass - NOERRORS 6 73.19 Pass - NOERRORS 1 92.15 Pass - NOERRORS 7 112.11 Pass - NOERRORS 7 132.86 Pass - NOERRORS 9 154.29 Pass - NOERRORS 5 176.26 Pass - NOERRORS 4 198.59 Pass - NOERRORS 6 221.31 Pass - NOERRORS 8 244.27 Pass - NOERRORS 4 267.45 Pass - NOERRORS 4 290.90 Pass - NOERRORS 4 314.58 Pass - NOERRORS 8 338.17 Pass - NOERRORS 8 361.99 Pass - NOERRORS 8 385.97 Pass - NOERRORS 8 410.09 Pass - NOERRORS 8 434.31 Pass - NOERRORS 9 458.41 Pass - NOERRORS 8 482.69 Pass - NOERRORS 8 507.02 Pass - NOERRORS 8 511.89 Pass - NOERRORS CC - Min centre to center distance or covergent point, SF - min separation factor, ES - min ellipse separation 1/28/2015 2:58:10PM Page 4 COMPASS 5000.1 Build 61 .�440 BP EARN ,0 ES bpi Travelling Cylinder Report NU6N INTEQ Company: North America - ALASKA - BP Project: Prudhoe Bay Reference Site: PB X Pad Site Error: 0.00 usft Reference Well: X-12 Well Error: 0.00 usft Reference Wellbore X-121-1 Reference Design: X-121-1 WP04 Local Co-ordinate Reference: ND Reference: MD Reference: North Reference: Survey Calculation Method: Output errors are at Database: Offset ND Reference: Well X-12 Mean Sea Level RKB @ 74.36usft True Minimum Curvature 1.00 sigma EDM R5K - Alaska PROD - ANCP1 Offset Datum Offset Design PB X Pad - X-32 - X-32 - X-32 Offset Site Error: 0.00 usft Survey Program: 110-MWD, 9096-EMS 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 +NI-S +E/-W Hole Size Centre Distance Deviation (usft) (usft) (usft) (usft) (usft) (usft) (I (usft) (usft) (in) (usft) (usft) (usft) 9,016.38 8,770.96 9,200.00 8,797.09 36.45 21.42 17.88 1,535.10 -536.09 4.875 1,295.85 209.57 1,086,34 Pass - Major Risk, CC, ES, 9,039.70 8,794.28 9,225.00 8,821,89 36.45 21.44 17.76 1,537.88 -537.62 4.875 1,298.54 209.79 1,089.00 Pass - Major Risk 9,055.00 8,809.57 9,250.00 8,846.70 36.45 21.47 17.66 1,540.58 -539.08 4.875 1,301.24 209.35 1,091.66 Pass - Major Risk 9,067.07 8,821.64 91275.00 8,871.53 36.45 21.49 17.55 1,543.21 -540.47 4.875 1,304.11 209.90 1,094.60 Pass - Major Risk 9,075.00 8,829.56 9,300,00 8,896.36 36.45 21.51 17.43 1,545.77 -541.80 4.875 1,307.25 209.87 1,097.80 Pass - Major Risk 9,084.84 8,839.36 9,325.00 8,921.20 36.45 21.53 17.20 1,548.27 -543.07 4.875 1,310.65 209.79 1,101.32 Pass - Major Risk 9,090.00 8,844.49 9,350.00 8,946,05 36.45 21.55 16,99 1,550.71 -544.28 4.875 1,314,34 209.70 1,105.15 Pass - Major Risk 9,094.82 8,849.24 9,375.00 8,970.91 36.45 21.57 16.77 1,553.09 -545.42 4.875 1,318.37 209.53 1,109.43 Pass - Major Risk 9,100.00 8,854.34 9,400.00 8.995.78 36.45 21.59 16.54 1,555.45 -546.48 4.875 1,322.79 209.30 1,114.19 Pass - Major Risk 9,100.00 8,854.34 9,425.00 9,020.65 36.45 21.61 16.29 1,557.82 -547.47 4.875 1,327.65 209.34 1,119.08 Pass - Major Risk CC - Min centre to center distance or covergent point, SF - min separation factor, ES - min ellipse separation 1/28/2015 2:58:10PM Page 5 COMPASS 5000.1 Build 61 a 2 d f m _ � o tl 6 O 2 N j F n1 U d O N t V y fn � V V n1 d m � n C � � d E U d d 0 $ a u o U m m U S /4GI L LD 6 N N C y R E O ii Qm o fO I d 1 O n d I o , N a c Z > Adilk' E� YEIO O m _ 1 U � U > I o� �3 U 1 Ed `� N rc rc U l N a \ J • o � E � W W \ W 1 , _ Y O f I ' � d U ' C9 1 f � 1 to 1 U � � 1 U 1 0 m 1 1 N Fl ir_ I m CIO I d c a 1 Davies, Stephen F (DOA) From: Boltz, Travis <Travis.Boltz@bp.com> Sent: Thursday, February 05, 2015 9:48 AM To: Davies, Stephen F (DOA) Subject: RE: PBU X-121_1 (PTD #215-023) Drilling Hazards Attachments: X-121_1 PTD.doc Stephen, I must have mixed of the well names as I was working on both permits at the same time. I apologize. The lost circulation risk for X-12 is considered to be high. Our mitigation for lost circulation is to ensure we have enough fluid/trucks on location to provide enough keep the hole full. Attached is the corrected PTD. Thanks! Respectfully, Travis Boltz Coiled Tubing Drilling Engineer Cell: 502-640-1645 Office: 907-564-5750 From: Davies, Stephen F (DOA) [mailto:steve.davies@alaska.gov] Sent: Wednesday, February 04, 2015 5:34 PM To: Boltz, Travis Cc: Schwartz, Guy L (DOA) Subject: PBU X-121_1 (PTD #215-023) Drilling Hazards Travis, In the Hazards section of the Permit to Drill application for PBU X-121-1, the last bullet point states that the lost circulation risk in X-10A is considered to be high, with 2 fault crossings. Is this text left over from an older application for X-10A, or does BP consider the lost circulation risk in X-121_1 to be high? If X-121_1 risk is high, what mitigation measures does BP plan for the well? Thanks, 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 7`h 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.daviessteve.davies@alaskagov. TRANSMITTAL LETTER CHECKLIST WELL NAME:. PTD: Ps C J Development _ Service _ Exploratory _ Stratigraphic Test _ Non -Conventional FIELD: POOL: / <cZJZ Check Box for Appropriate Letter / Paragraphs to be Included in Transmittal Letter CHECK OPTIONS TEXT FOR APPROVAL LETTER MULTI LATERAL The permit is for a new wellbore segment of existing well Permit (If last two digits No. , API No. 50- - - - in API number are Production should continue to be reported as a function of the original between 60-69) API number stated above. 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 name Pilot Hole ( PH) and API number (50- - - - ) from records, data and logs acquired for well (name on permit). The permit is approved subject to full compliance with 20 AAC 25.055. Approval to produce / inject is contingent upon issuance of a Spacing Exception conservation 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 4/2014 WELL PERMIT CHECKLIST Field & Pool PRUDHOE BAY, PRUDHOE OIL - 640150 PTD#:2150230 Company BP EXPLORATION (ALASKA) INC Initial Class/Type Well Name: PRUDHOE BAY UNIT X-121_1 Program DEV Well bore seg [I DEV / PEND GeoArea 890 Unit 11650 On/Off Shore On Annular Disposal Administration 17 Nonconven. gas conforms to AS31.05.030(j.1.A),(j.2.A-D) NA 1 Permit fee attached NA 2 Lease number appropriate Yes Entire well in ADL 028313 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 conforms to 7 Sufficient acreage available in drilling unit Yes CO 341 D, Rule 2. 8 If deviated, is wellbore plat included Yes 9 Operator only affected party Yes 10 Operator has appropriate bond in force Yes Appr Date 11 Permit can be issued without conservation order Yes 12 Permit can be issued without administrative approval Yes SFD 2/4/2015 13 Can permit be approved before 15-day wait Yes 14 Well located within area and strata authorized by Injection Order # (put 10# in comments) (For 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 18 Conductor string provided NA Conductor set in PBU X-12 Engineering 19 Surface casing protects all known USDWs NA Surface casing set in PBU X-12 20 CMT vol adequate to circulate on conductor & surf csg NA Surface casing set and fully cemented 21 CMT vol adequate to tie-in long string to surf csg NA 22 CMT will cover all known productive horizons No Productive interval will be completed with slotted liner 23 Casing designs adequate for C, T, B & permafrost Yes 24 Adequate tankage or reserve pit Yes Rig has steel tanks; all waste to approved disposal wells 25 If a re -drill, has a 10-403 for abandonment been approved NA 26 Adequate wellbore separation proposed Yes Anti -collision analysis complete; 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 3402 at 8962'TVDss; 7.3 ppg EMW; will drill w/ 8.6 ppg EMW VTL 2/5/2015 29 BOPEs, do they meet regulation Yes 30 BOPE press rating appropriate; test to (put psig in comments) Yes MPSP is 2506 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 X-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 (7.3 ppg). SFD 2/4/2015 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 4 Z -i/ /S