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Home My WebLink About212-084Page 1 of 2 Schwartz, Guy L (DOA) From: Johnston, David [David.Johnston2@BP.com] Sent: Wednesday, July 18, 2012 11:10 AM To: Schwartz, Guy L (DOA) Cc: Lastufka, Joseph N (Northern Solutions) Subject: RE: 07-22A and 07-22B permit to drill Guy, k'(D Z(2--OSY I would like to request to withdraw PTD #212-084 for well 07-22A at this time. I would also like to request the name change on the second permitted target to reflect: PTD 212-085 with an API suffix of -02 to be named 07-22A. Thanks again, David Johnston CTD Engineer 564-5985 From: Schwartz, Guy L (DOA) [mailto:guy.schwartz@alaska.gov] Sent: Wednesday, July 18, 2012 9:40 AM To: Johnston, David Cc: Davies, Stephen F (DOA) Subject: RE: 07-22A and 07-22B permit to drill David, Request to withdraw the first permit ( 7-22A / PTD 212-084) and then we can rename the second permitted target to 07-22A and it becomes drilled well. (We cannot change the API number for the PTD so it will remain -02 suffix. ) So the well will be 07-22A and PTD 212-085 with an API suffix of -02 Guy Schwartz Senior Petroleum Engineer AOGCC 793-1226 (office) 444-3433 (cell) From: Johnston, David [mailto:David.Johnston2@BP.com] Sent: Wednesday, July 18, 2012 9:17 AM To: Schwartz, Guy L (DOA) Subject: 07-22A and 07-22B permit to drill Guy, Thanks for working with me on getting both 07-22A and 07-22B permits to drill issued. We have found the targets of 07-22A to be undesirable and are going to drill the 07-22B targets. We will not be plugging back what we have drilled already, we are just going to continue to drill ahead from our current depth to the new direction north, instead of continuing the turn to the north west. We would like to maintain the 07-22A wellbore name, and not use the (B) name. Please advise me of what steps you would like me to take to maintain this name, and under which permit. 7/18/2012 Page 2 of 2 Thanks for your time, David Johnston BP Alaska, CTD Engineer 564-5985 7/18/2012 A LT fZ SEAN PARNELL, GOVERNOR FT ti A ALASSA OIL AND GAS � 333 W. 7thAVENUE, SUITE 100 CONSERVATION COMMSSIOK ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 John McMullen Engineering Team Leader BP Exploration (Alaska), Inc. P.O. Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU 07-22A BP Exploration (Alaska), Inc. Permit No: 212-084 Surface Location: 183 l' FNL, 682' FWL, Sec. 34, T 11 N, R 14E, UM Bottomhole Location: 4771' FNL, 422' FEL, Sec. 33, 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 Commission 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 Commission 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 a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Sincerely, Cathy . Foerster Chair DATED this�O day of June, 2012. cc: Department of Fish & Game, Habitat Section w/o encl. (via e-mail) Department of Environmental Conservation w/o encl. (via e-mail) STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 FIECEIVED JUN 2 0 201Z AOGcc 1 a. Type of work: ❑ Drill ® Redrill ❑ Re -Entry 1 b. Proposed Well Class: ® Development Oil ❑ Service - Winj ® Single Zone ❑ Stratigraphic Test ❑ Development Gas ❑ Service - Supply ❑ Multiple Zone ❑ Exploratory ❑ Service - WAG ❑ Service - Disp 1 c. Specify if well is proposed for: ❑ Coalbed Gas ❑ Gas Hydrates ❑ Shale Gas 2. Operator Name: BP Exploration (Alaska) Inc. 5. Bond: ® Blanket ❑ Single Well Bond No. 6194193 - 11. Well Name and Number: PBU 07-22A 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 6. Proposed Depth: 12. MD - 10820' ' TVD 8975'ss Field / Pool(s): Prudhoe Bay / Prudhoe Bay 4a. Location of Well (Governmental Section): Surface: 1831' FNL, 682' FWL, Sec. 34, T11N, R14E, UM Top of Productive Horizon: 5208' FNL, 234' FEL, Sec. 33, T11 N, R14E, UM Total Depth: 4771' FNL, 422' FEL Sec. 33, T11N, R14E, UM 7. Property Designation (Lease Number): ADL 028309 8. Land Use Permit: proximate Spud Date: July 15, 2012 9. Acres in Property: XX 14. 2560 Distance to Nearest Property: 22000' 4b. Location of Well (State Base Plane Coordinates - NAD 27): Surface: x- 676899 - 5949110 Zone- ASP4 10. KB Elevation above S feet 15. GL Elevation above 7.59' feet Distance to Nearest Well Open to Same Pool: 1100' 16. Deviated Wells: Kickoff Depth: 9750' feet Maximum Hole Angle: 91 de rees 17. Maximum Anticipa r sures in psig (see 20 AAC 25.035) Downhole: Surface: 2370 18. Casing Program: Specifications To - S epth - Bgftom Quantity of Cement, c.f. or sacks Hole Casing Wei ht I Grade Coupling Length MD MD TVD(including sta a data 4-1/2' 3-1/2"x3-1/4"x2-7/6" 9.2# / 6.6# / 6.5# L-80 STL / TC-II 1720' 91 1's 1 0' 8975'ss 77 sx Class 'G' 19. PRESENT WELL CONDITION SUM (To bA completed for Redrill and Re-entry Operations) Total Depth MD MY 10285' Total Depth TVD (ft): 9210' Plugs (mea ur 0 tive Depth MD (ft): 10250' Effective Depth TVD (ft): 9178' Junk (measured): 10024' Casing Length Size Cement Volume MD TVD Conductor / Structural 79' 20 . 190 oleset 79. 79' Surface 2542' 13- 1520 sx Fondu 400 sx PF C 2542' 2542' Intermediate 9500' 9-6/8X 7 500 sx Class'G' 300 sx PF C 9500' 8510' Production Liner 1090' 300 sx Class 'G' 9195' - 10285' 8242' - 9210' Perforation Depth MD (ft): 10042' - 10064' - Perforation Depth TVD (ft): 8990' - 9010' 20. Attachments: ❑ Property Plat BOP Sketch ® Drilling Program ❑ Time vs Depth Plot ElShallow Hazard Analysis A Diverter Sketch ❑ Seabed Report ® Drilling Fluid Program ® 20 AAC 25.050 Requirements 21. Verbal Approval: Commissi96 Representative: Date: 22. 1 hereby certify that the foreg ng is true and correct. Contact David Johnston, 564-5985 Printed Name Johi Title Engineering Team Leader Prepared By Name/Number: Signature Phone 564-4711 Date 6 � r/Z Joe Lastufka, 564-4091 Commission Use Only Permit To Dr Number: ( API Number: 50-029-20925-01-00 e: Permi • Ap r val 21� See cover letter for other requirements Conditions of Appro f: If box is checked, well may not eeuused to explore for, test, or produce coalbed meethane gas hydrates, or gas contained shales: 13/ Other: / Ov �s' �G5-f Samples Req'd: [I Yes 01 Mud Log Req'd: ❑ Yes [3/No H2' Measures: Q Yes ❑ No Directional Survey Req'd: Q Yes ❑ No p / Z �D A ROVED BY THE COMMISSION Date (p �—O l / COMMISSIONER Form 10-401 Revised 07/2009 This permit is valid for 24 tromt1adatof pprovp((20 AAC 25.005(g)) ' Submit In uplicate i7 L To: Alaska Oil & Gas Conservation Commission From: David E. Johnston Obp CTD Engineer Date: June 14, 2012 Re: 07-22A Permit to Drill Request Approval is requested for a permit to drill a CTD sidetrack from well 07-22. CTD Drill and Complete 07,33`A program: Rig Start Date: July 15t", 2012 Pre -Rig Work: (scheduled to begin July 1, 2012) 1. S Dummy GLV's (done 4/13/12) 2. D MIT-OA to 2,000 psi (passed 4/13/12) 3. D MIT -IA to 3,000 psi (passed 4/13/12) 4. S Dummy WS drift to 9,800' - Failed 6/8/2012 5. C Dummy whipstock drift to 9,800 ft 6. W AC -LDS; AC-PPPOT-IC, T 7. W PT MV, SV, WV 8. F Load and kill well with 8.4 ppg 1 % KCL 9. V Install TWC 10. O Bleed gas lift and production flowlines down to zero and blind flange 11.0 Remove wellhouse, level pad Rig Work: (scheduled to begin on July 15, 2012) 1. MIRU Nordic 2 and test BOPE to 250 psi low and 3500 psi high. 2. Pull TWC and bullhead kill well 3. Set top of 4-1/2" X 7" through tubing whipstock at 9,750 ft and 205 deg TF 25 deg LOLS) 4. Mill 3.8" window at 9750' and 10' of rathole. 5. Drill Build: 4.25" OH, 450' (28 deg/100 planned) with resistivity 6. Drill Lateral: 4.25" OH, 620' (28 deg/100 planned) with resistivity 7. Run 3-1/2" x 2-7/8" solid chrome liner leaving TOL at 9,100' 8. Pump primary cement leaving TOC at 9600', 16 bbls (planned) of 15.8 ppg class G liner cement. 9. Cleanout liner and MCNL/GR/CCL log 10. Test liner lap to 2400 psi. 11. Perforate liner per asset instructions (-300') 12. Freeze protect well, RDMO Post -Rig Work: 1. Re -install wellhouse, flowline and pull BPV. 2. Set 4-'/2" liner top packer, and test to 2,400 psi (If liner lap test fails) 3. Generic GLV's Mud Program: • Well kill: 8.4 ppg brine. • Milling/drilling: 8.6 ppg PowerVis for milling window and drilling (686 psi over -balance). Disposal: 9 All drilling and completion fluids and all other Class 11 wastes will go to Grind & Inject. • All Class I wastes will go to Pau 3 for disposal. Hole size: 4.25" Liner Program: • 3-1/2", 9.2#, L-80, STL Solid liner 9,100' MD — 9,600' MD • 3-1/4", 6.6#, L-80, TC-II Solid Liner 9,600' MD — 10,250' MD • 2-7/8", 6.5#, L-80, STL Solid Liner 10,250' MD — 10,820' MD • A minimum of 16 bbls of 15.8 ppg cement will be used for liner cementing. (TOC 9,600 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 911. • Magnetic and inclination surveys will be taken every 30 ft. No gyro will be run. • Distance to nearest property — 22,000'. • Distance to nearest well within pool — 1,100' (07-01 B). • A planned contingency if 07-22A lands wet at 10,200 ft is to stop drilling the 07-22A �- directional plan and switch to 07-22B directional plan. BP will be applying for both drilling permits concurrently. Logging • MWD directional, Gamma Ray and Resistivity will be run over all of the open hole section. • Cased hole GR/CCL/MCNL logs will be run. • If available an open hole caliper log will be ran through the build section for swell packer evaluation data. • If available an open hole Multi Express tool for high quality density and saturation data will be ran. Perforating: • SWS 2", 6 spf, perf guns, 1-1/a" CSH work string, & 2-3/8" PH6 • 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. - Anti -Collision Failures • No Failures Hazards • The maximum recorded H2S level on DS 07 was 50 ppm on well 07-24 on 5/15/2005. Reservoir Pressure • The reservoir pressure on 07-22 is expected to be 3,250 psi at 8.800' TVDSS. (7.1 ppg equivalent). • Maximum expected surface pressure with gas (0.10 psi/ft) to surface is 2,370 psi. • An EMW of 8.4 ppg for this well will provide 595 psi over -balance to the reservoir. David E. Johnston CC: Well File CTD Engineer Terrie Hubble/Joe Lastufka TREE = GRAY GEN 2 WELLHEAD = GRAY', ACTUATOR = AXELSON li KB. 11EV = 58' BF ELEV = ? KOP = 2900' Max Ang� = 37 @ 6200` Datum MD = 9894' Datum TVD = 8800' SS 13-318" CSG, 72#, L-80, ID= 12.347' f- 2542' EST TOP OF CEMENT IN IA (724/05) 8938' Minimum ID = 3.813" @ 2086' 4-1/2" HES NIPPLE 412" TBG, 12.6#, 13CR-80, .0152 bpf, ID = 3.958" 9125' 5-12" TBG STUB 9134' 5-1/2' TBG-FC, 17#, L-80, .0232 bpf, ID = 4.892 9157' TOP OF 7' LNR H 9195' 1 4-1 /2" TBG-PC, 12.6#, L-80, .0152 bpf, ID = 3.958" H 9257' 9-5/8" CSG, 47#, L-80, ID = 8.681" 9500' PERFORATION SUMMARY REF LOG: BHCS ON 03/18/83 ANGLE AT TOP PERT 26 @ 10018' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sgz DATE 3-3/8" 4 10018 - 10038 S 12/04/83 3-3/8" 4 10042 - 10062 O 12/04/83 3-3/8" 6 10054 - 10064 O 02/19/98 PBTD f - 10250' � 7" LNR, 29#, L-80, .0371 bpf, ID = 6.184" 10285' 07-22 SAFET . ,JTES: *'* 4-112" CHROM E TBG ***GLM #4 (IA) IS COVERED IN CEMENT*** 2016' H 4-1/2' HES X NIP, ID = 3.813" GAS LIFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE 1 2 3 *4 3106 5981 7918 8947 3093 5520 7100 8028 16 37 30 28 MMG MMG MMG MMG DMY DMY DMY - RK RK RK - 0 0 0 04/13/12 04/13112 07/24/05 0724105 *CEM ELATED IN 9017' 4-112' HES X NIP, ID = 3.813" 9038' 9-5/8" X 4-12" BKR S-3 PKR ID = 3.958" 9062' 4-12" HES X NIP, ID = 3.813" 9126' HUNIQUE MACHINE OVERSHOT 9157' 5-12" BKR PBRASSY, ID=4.09' 9172' 9-5/8" X 5-12" BKR SA PKR 9244' 4-1/1" CAMCO D13-6 NIP, ID= 3.813" 9256' 4-1/2' BKR SHEA ROUT SUB 9257' 4112' WLEG, ID 33.958" 9251' ELMD TT LOGGED 05/18/98 10024' "FISH: IBP RUBBER ELEMENT (05118/05) PRUDHOE BAY UNIT WELL: 07-22 PERMIT No:'1830390 API No: 50-029-20925-00 SEC 34, T11 N, R14E, 354.89' FEL & 190.64' FNL DATE REV BY COMMENTS DATE REV BY COMMENTS I 03/22183 ORIGINAL COMPLETION 0729/05 JNA/PJC MILL CMT & FASDRILL @ 9195 09111101 RWrP RWO 0421/12 CDJ/ PJC GLV C/O (04/13/12) 10115104 I03SITLP RWO D626/05 BMcL/PJC PULL IBP/ SET FASDRILL @9195 0724/05 jBMcIJPJCjCEMElNT BP Exploration (Alaska) 08/07/05 1 DAV/PJC I GLV CIO TREE = GRAY GEN 2 WELLHEAD= ACTUATOR = _GRAY AXELSON KB. ELEV = _ 58' BF. ELEV = KOP = 2900' Max Angle = 37 @ 6200' Datum MD = 9894' Datum TV D = 8800' SS 13-3/8" CSG, 72#, L-80, ID= 12.347" f—I 2542' F EST TOP OF CEMENT IN IA (7/24/05) 8938' ME TBG 0 7 -2 2 A SAGLM #4 (IA) IS COVERED NRCCEM ENT•'* proposed C TD sidetrack 2086' 4-1/2" HES X NIP, ID= 3.813" GAS LIFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE 1 3106 3093 16 MMG DMY RK 0 04/13/12 2 5981 5520 37 MMG DMY RK 0 04/13/12 3 7918 7100 30 MMG DMY RK 0 07/24/05 *4 8947 8028 28 MMG - 07/24/05 "C: tM tN I tU 1 N 9017' 4-1 /2 HES X NIP. ID = 3.8 i 3" 9038' —j9-5/8" X 4-112" BKR S-3 PKR, ID = 3.958" Minimum ID = 2.377" � 10500° 3-1/4" X 2-7/8" X® 9062' 4-1/2 HES X NIP, ID = 3.813" e 28 Topof312"Tiler@-9,100, 4-1/2" TBG, 12.6#, 13CR-80, .0152 bpf, ID=3.958" 9125' 9126' UNIQUE MACHINE OVERSHOT 5 1 /2" TBG STUB 9134' 9157' 5-1/2" BKR PBRASSY, ID = 4.00" 5-12" TBG-PC, 17#, L-80, .0232 bpf, ID = 4.892" 9157' 9172' 9-5X K2SAB PKR T S G R = 9 ,511 'M D 9183' T' X 4-1 /2" XO, ID = 3.958" TOP OF 7" LNR H 9195' 4-12" TBG-PC, 12.6#, L-80, .0152 bpf, ID = 3.958" I 9257' 9-5/8" CSG, 47#, L-80, ID = 8.681" 9500' PERFORATION SUMMARY REF LOG: BHCS ON 03/18/83 ANGLE AT TOP PEW 26 @ 10018' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 3-3/8" 4 10018 - 10038 S 12/04/83 3-3/8" 4 10042 - 10062 O 12/04/83 3-3/8" 6 10054 - 10064 0 02/19/98 PBTD 10250' 7" LNR, 29#, L-80, .0371 bpf, ID = 6.184" 10285' 0 28 9244' 1-14-112' CAMCO DB-6 NIP. ID = 3.813" 9256'-1 4-1/2" BKR SHEAROUT SUB 9257' 4-12" WLEG, ID = 3.958" 9251' ELMD TT LOGGED 05/18198 3 12"x 3 3/16"X0 Top ofcem entat-9,600' TD @ 10,820' 3 1/4"x 2 7/8"XO @ -10,250' 4 12"x 7"TT wh�)stDck @ 9,750' ` 10024' 1-1 FISH: IBP RUBBER ELEMENT (05/18/05) BAY UNIT WELL 07-22A PERMIT No: r1830390 API No: 50-029-20925-00 SEC 34, T11 N, 1314E� 354.89' FEL & 190.64' FNL DATE REV BY COMMENTS DATE REV BY COMMENTS IPRUDHOE 03122/83 ORIGINAL COMPLETION 07/29/05 JNA/PJC MILL CMT & FASDRILL @ 9195 09/11101 RNITP RNO 04/21/12 CDJ/ PJC GLV C/O (04/13112) 10115104 KBSITLP RWO i,i"';"`. ^ % rNJH proposed CTD sidetrack 0626/05 BMcL/PJC PULL IBP / SET FASDRILL @9195 0724/05 BMc 1JPJCj CEMENT BP Exploration (Alaska) 08107/D5 DAV/PJC I GLV C/O a H z Q O J Cl. 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P P +- 6 Y i P+ Y V i P WOA2 BAKER HUGHES INTEQ North America - ALASKA - BP Prudhoe Bay PB DS 07 07-22 / Lat: 070°15'59.451"1 Long: 0148°34'10.322"W 07-22A Plan 3 Travelling Cylinder Report 22 May, 2012 ri.r BP BAKER HUGHES Travelling Cylinder Report Obp INTEQ Company: North America - ALASKA - BP Project: Prudhoe Bay Reference Site: PB IDS 07 Site Error: 0.00ft Reference Well: 07-22 Well Error: 0.00ft Reference Wellbore 07-22A Reference Design: Plan 3 Local Co-ordinate Reference TVD Reference: MD Reference: North Reference: Survey Calculation Method: Output errors are at Database: Offset TVD Reference: Well 07-22 - Slot 22 Mean Sea Level Kelly Bushing / Rotary Table @ 58.00ft (NABORS 4ES; True Minimum Curvature 1.00 sigma EDM .16 - ANC Prod - WH24P Offset Datum deference Plan 3 =ilter type: GLOBAL FILTER APPLIED: All wellpaths within 200'+ 100/1000 of referE nterpolation Method: MD Interval 25.00ft Error Model: ISCWSA )epth Range: 9,750.00 to 10,820.00ft Scan Method: Tray. Cylinder North results Limited by: Maximum center -center distance of 1,278.90ft Error Surface: Elliptical Conic Survey Tool Program Date 5/22/2012 From To (ft) (ft) Survey (Wellbore) Tool Name Description 100.00 9,750.00 1 : Camera based gyro multisho (07-22) CB -GYRO -MS Camera based gyro multishot 9,750.00 10,820.00 Plan 3 (07-22A) MWD MWD - Standard Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (ft) (ft) Name (in) (in) 10,820.00 8,974.74 2 7/8" 2.875 4.125 Summary Reference Offset Centre to No -Go Allowable Measured Measured Centre Distance Deviation Warning Site Name Depth Depth Distance (ft) from Plan Offset Well - Wellbore - Design (ft) (ft) (ft) (ft) PB DS 07 07-01 - 07-01A - 07-01A 10,520.00 10,275.00 943.95 455.75 488.12 Pass - Major Risk 07-01 - 07-01APB1 - 07-01APB1 10,500.00 9,917.00 1,237.45 508.85 728.75 Pass - Major Risk 07-01 - 07-01 B - 07-01 B 10,340.00 10,725.00 994.68 744.08 251.11 Pass - Major Risk 07-02 - 07-02 - 07-02 Out of range 07-02 - 07-02A - 07-02A Out of range 07-02 - 07-02B - 07-02B Out of range 07-19 - 07-19 - 07-19 Out of range 07-19 - 07-19A - 07-19A Out of range 07-20 - 07-20 - 07-20 Out of range 07-20 - 07-20A - 07-20A Out of range 07-20 - 07-20B - 07-20B 07-20 - 07-20B - Plan #4 Out of.range", q t of range 07-21 - 07-21 - 07-21 Out of range 07-22 - 07-22 - 07-22 9,774.98 9,775.00 0.52 22.90 -20.9 FAIL - Major Rile' 07-35 - 07-35 - 07-35 Out of ran/' 07-35 - 07-35A - Plan 3 Qut Afrange 07-36 - 07-36 - 07-36 Out of range CC - Min centre to center distance or covergent point, SF - min separation factor, ES - min ellipse separation 512212012 10:11:52AM Page 2 of 7 COMPASS 2003.16 Build 73 n D N y 3 Z m m c O � y m N 3 3 A ONi O � m Ci 3 F � 3 3 3 r m m F z r n n p u o= n m F o F Z v 0 ci T JC C G p N � N 3 c m /1 m n v Z/ z 9 O T 3 � O 3 3 A N W 3 m x N S 3 u \ 3 T m � A y a m A c 3 W r n n y n Z = x 3 N 3 3 = N 3 a m m 0 3 o n 3 1 n (7 n N A 3 V1 3 3 Z n C) 3 u m o y� � ♦ o O r� x m r Er 3 A 'c c m 3 ® Z � � 3 m A D n 1 m O m r 3 m x D SS 0 D 3 � m n m � 0 �1 m J R lFD i 4 � n x m ~ o v m m x m r m TRANSMITTAL LETTER CHECKLIST WELL NAME Z PTD# l DL v Development Service Exploratory Stratigraphic Test Non -Conventional Well FIELD: 11C�2� POOL: Check Box for Appropriate Letter / Paragraphs to be Included in Transmittal Letter CHECK ADD-ONS WHAT (OPTIONS) TEXT FOR APPROVAL LETTER APPLIES MULTILATERAL The permit is for a new wellbore segment of existing well (If last two digits in permit No. , API No. 50- - - API number are between 60-69) Production should continue to be reported as a function of the original API number stated above. PILOT HOLE In accordance with 20 AAC 25.005(t), all records, data and logs acquired for the pilot hole must be clearly differentiated in both well name ( PH) and API number (50- - -) from records, data and logs acquired for well SPACING The permit is approved subject to full compliance with 20 AAC EXCEPTION 25.055. Approval to produce / inject is contingent upon issuance of a conservation order approving a spacing exception. assumes the liability of any protest to the spacing exception that may occur. DRY DITCH All dry ditch sample sets submitted to the Commission must be in SAMPLE no greater than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. Non -Conventional Please note the following special condition of this permit: Well production or production testing of coal bed methane is not allowed for (name of well) until after (Company Name) has designed and implemented a water well testing program to provide baseline data on water quality and quantity. (Company Name) must contact the Commission to obtain advance approval of such water well testing program. Rev: 9/09/2011 WELL PERMIT CHECKLIST Field & Pool PRUDHOE BAY, PRUDHOE OIL - 640150 PTD#:2120840 Coml Administration 17 1 2 3 4 5 6 7 8 9 10 Appr Date 11 12 SFD 6/21/2012 13 14 15 16 Engineering ,,pr Date GLS 6/25/2012 Geology Appr Date SFD 6/21/2012 18 19 20 21 22 23 24 25 26 27 28 29 30 31 32 33 34 ny BP EXPLORATION (ALASKA) INC Initial Class/1 Nonconven. gas conforms to AS31.05.0300.1.A),0.2.A-D) Permit fee attached Lease number appropriate Unique well name and number Well located in a defined pool Well located proper distance from drilling unit boundary Well located proper distance from other wells Sufficient acreage available in drilling unit If deviated, is wellbore plat included Operator only affected party Operator has appropriate bond in force Permit can be issued without conservation order Permit can be issued without administrative approval Can permit be approved before 15-day wait Well located within area and strata authorized by Injection Order # (put 10# in comments) (For All wells within 1/4 mile area of review identified (For service well only) Pre -produced injector: duration of pre -production less than 3 months (For service well only) Conductor string provided Surface casing protects all known USDWs CMT vol adequate to circulate on conductor & surf csg CMT vol adequate to tie-in long string to surf csg CMT will cover all known productive horizons Casing designs adequate for C, T, B & permafrost Adequate tankage or reserve pit If a re -drill, has a 10-403 for abandonment been approved Adequate wellbore separation proposed If diverter required, does it meet regulations Drilling fluid program schematic & equip list adequate BOPEs, do they meet regulation BOPE press rating appropriate; test to (put psig in comments) Choke manifold complies w/API RP-53 (May 84) Work will occur without operation shutdown Is presence of H2S gas probable Mechanical condition of wells within AOR verified (For service well only) NA NA Yes Yes Yes Yes Yes Yes Yes Yes Yes Yes Yes Yes NA NA NA NA NA NA NA Yes Yes Yes Yes Yes NA Yes Yes Yes Yes Yes Yes NA 35 Permit can be issued w/o hydrogen sulfide measures No 36 Data presented on potential overpressure zones Yes 37 Seismic analysis of shallow gas zones NA 38 Seabed condition survey (if off -shore) NA 39 Contact name/phone for weekly progress reports [exploratory only] NA Well Name: PRUDHOE BAY UNIT 07-22A Program DEV DEV / PEND GeoArea 890 Unit 11650 On/Off Shore On Entire well within ADL 028309 PRUDHOE BAY, PRUDHOE OIL POOL - 64015, governed by CO 341D CO 341 D, Rule 2; There shall be no restrictions as to well spacing except that no pay shall be opened in a well closer than 500 feet to the boundary of the affected area. onductor set in DS 7-22 Surface casing set in IDS 7-22 No aquifers in area... Cemented and perfed liner is planned. Liner will be cemented up to 9600ft and ( inside 7" liner) to isolate old perfs. Rig has steel pits. All waste to approved disposal wells. 312-232 setting Whipstock ... cementing and testing liner. Proximity analysis performed ... no issues. Wellhead in place. BOP will be placed on production tree. Max formation press= 3250 psi (7.1 ppg EMW) Will drill with 8.4 ppg mud... MASP = 2370 psi Will test BOP to 3500 psi H2S on pad.. Rig has sensors and alarms. IDS 07 wells are H2S-bearing. H2S measures are required. Expected reservoir pressure is 7.1 ppg EMW. Wellbore will be drilled using 8.4 - 8.6 ppg mud, coiled tubing, and managed pressure drilling technique. Geologic Engineering blic CTD sidetrack... Well 7-22B also permitted as a contingency BHL if 7-22A planned wellpath is wet. GIs. Commissione : Date: Commissioner: Date m issi ner Date Well bore seg Annular Disposal