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212-121
Image Project Well History File Cover Page XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. al cQ - LQ j_ Well History File Identifier Organizing (done) ❑ Two-sided ❑ Rescan Needed RESCAN: OVERSIZED: NOTES: vr/C or Items: El Maps: �j�CELfI- )z( rascale Items: ❑ Logs: ❑ Poor Quality Originals: ❑ Other: ❑ Other: rvfBY: Maria Date: 0- )11-f /s/ Project Proofing BY: Maria Date: I ,;_13i i /s/ Of Scanning Preparation I x 30 = ° + l = TOTAL PAGES .! (Count does not include cover sheet) BY: Maria Date: { a 3 1 Is, Production Scanning J Stage 1 Page Count from Scanned File: 3 (Count does include covers et) Page Count Matches Number in Scannin Preparation: ES NO BY: I.� .. Date: (a. � /� /s/ mp Stage 1 If NO in stage 1, page(s) discrepancies were found: YES NO BY: Maria Date: /s/ Stage 2 Additional Well Reports: YES NO TOTAL PAGES: Digital version appended by: Meredith Michal Date: /s/ Final Page Count: Stage 1 + Stage 2: TOTAL PAGES: Scanning is complete at this point unless rescanning is required. ReScanned BY: Maria Date: /s/ Comments about this file: Quality Checked 7/8/2014 Well History File Cover Page_20140708.doc o v o ; o o ; 9 < < < I o • o Z Z Z M Z 1 c >• >- r to c'.1 N rn 0 ml 2 aa) Q 1 ��-' L �. I T d O N >' �I = N o < I 1 0f2 c I i C 1 I N I a Z a I1 t t o a co 1 .6 0 Q Q Toto a) a) 2 o 2 0 0 U o o Z 924 Z < 0 Q 0 C Y— N a E N Z Z too U E >- >- > H- g co U 03 N N Q E E m a� LL d o 0 Li !I O z d a1 N o C C a.. d m a) CO LU Ce O m cc a) m 1 a -0 LL E N W w m N N _ _ 03 o a 1 C. m O U E Z co c)d co cc rn w co Qu) 1 m y J D. m J 7 a m Z E Om O in 11 of ,I w c U U j C c Z c t ai i 11 G li2 co m0 co 0 N E a) 0. 00 E o Q V ;5 U I C Z aa) o J = o >- >- r E -- to a' Z co Ec. a Q I as a. co !' o�v 2 E Z J N N o N i m C N 1 m m J u) 2 ~ E II w r m � �'/A� = 0 `� c 6 N 1 asm V+ 0 ptu c o O p j c Q a, c I - ip a ° 1 c c) m o a 1 L 0 Q Z 0 Z o 2 2 m • 0 o D 2 a Z 1 N a) 3 C E E N I d' Z w ZrZ o 1 I/31a ›- ›- >- N CO p a) E 0 c 0 o 0 J ` y0 w 1w } C CO cc- N N rere 0 5 w 0 Z y W O N H , ,1 r+ a y d' O C 2 a) g € '� E E Z ID N Y w m y R O CD 0 ? « C �� Z F m Z m o o p O v 6 y Q o o Q o p « C U I w LL m o _ cv m a y U 1 5 I Z w --I U re v c?)) d N E O y a s a y '.g a y o o aoi O o aoi m c Q a 11; al 0 H ?s -I 0 H � � U 4 C9 I' O 0 6 H U O -I 7 O 0 O o NrA N a' O 1+a' O O 7 N Z 7 o+ U N 5 T q mi o E. I U z U < z0 = % al+ /��/ m cu LL Q -='„, O z = Cl. U NO Ce J 0- 1.11 W w U m QN — w J o tii iGO g; ; oE0 N ron 1 co a I- E '. E m CO o 0 Q _ 1 a I— ii,,, Qo- H o E E U t A z o p I' , m N 9 N ; N d I >y E rees d oU a 8 E a II o p70 21 2 - / 2 / Ferguson, Victoria L (DOA) From: Ferguson,Victoria L(DOA) Sent: Wednesday, September 25,2013 4:43 PM To: Davies, Stephen F(DOA);Colombie,Jody J (DOA); Hunt,Jennifer L(DOA) Subject FW:Withdraw A-45 PTD 212-121 Steve, Does anyone else need to see this PTD withdrawal? Thanx, Victoria From: Lastufka,Joseph N [mailto:Joseph.Lastufkaftbp.com] Sent: Wednesday, September 25, 2013 3:11 PM To: Ferguson, Victoria L(DOA) Cc: Mammadov, Famil; Ramos,Tania ((Udeihoven Oilfield System Services (UOSS)) Subject: Withdraw A-45 PTD 212-121 Victoria, Please withdraw PTD 212-121(A-45),as we will be submitting a new PTD with different conductor coordinates.We will be submitting a new PTD for A-45. Thank you, Joe Lastufka Alaska Wells Technologist Cell: (907) 227-8496 Office: (907) 564-4091 w�a w BP Exploration AlaskaI900 E.Benson B1vd.IRoom: 788DIAnchorage,AK 1 PTP 2)Z —Iz1 Ferguson, Victoria L (DOA) From: Ferguson,Victoria L(DOA) Sent: Wednesday, September 25, 2013 9:47 AM To: 'Mammadov, Famil' Cc: Davies,Stephen F (DOA); Lastufka,Joseph N (Joseph.Lastufka@bp.com) Subject: RE:A-45 Well Naming(PTD 212-121) Farnil, Please send an email withdrawing the previous A-45 PTD(212-121) and submit a new PTD application with the new conductor coordinates for A-45. A-45 will have a new PTD number. I hope this answers your question. Thanx, Victoria Victoria Ferguson Senior Petroleum Engineer State of Alaska Oil&Gas Conservation Commission 333 W.7th Ave,Ste 100 Anchorage,AK 99501 Work (907)793-1247 victoria ferqusonalaska qov From: Mammadov, Famil [mailto:famil.mammadov@bp.com] Sent: Monday, September 23, 2013 9:24 AM To: Ferguson, Victoria L(DOA) Cc: Lastufka, Joseph N Subject: A-45 Well Naming Dear Victoria, I have a question in reference to A-45 well, permit#212121. The planned surface well location has recently been changed. However,we installed a conductor prior changing the planned location.The reason for the change was the risk of having gas across the conductor after drilling the intermediate hole section. As far as I know the installed conductor coordinates were communicated to the state.Could you please advise if we could keep the name of the well the same with the newly planned location, i.e.calling new location—A-45? If not,what do we need to do? Old location coordinates—see attached New location:X: 654454.83 Y:5948915.29(3748' FSL 1532' FNL)—50'south of A-39 well. Regards, Famil Mammadov 1 GWO I BP Alaska I Drilling Engineer—N\ .totary I Mobile:+1 (907)306 77391 Office:+1 (907)564 4135 email:famil.mammadov@bp.com bp.com 2 :� , . I, ) to I 13?�.. „`� � 16� j .17 ; 4GC-1t {A-45 13+35.12• -L2:iz4i2o 34• I �, '11• BOC - 1_�J 33. _._ .„ k - 41: C l GC-3 .`%1t— 399. 25• ' ` 25 30 zs I� .,_,..�y PROJECT _C.P.S. e A PAD •1 _:.AREA1.,..i.: t �' 7• 1 B-PAD - ‹ I 433 •35 0, %, ..-•.�"36 .31 ' ‘32 40•• 1i * " P. � 6 5• ` VICINITY MAP IL . ) 4• l N.T.S. • �>I29• 113 2 ' C 1 • }) 28• ��'\�.., �C'9 z6, c`�'�u •9 25. ' .._. `.... ... .. ......... 24. X14 •'...:14. .......... 23• .32 �, 'Ichard�F. Allison c8~ M M ;t1");6;:5ss •15 � � � 608 �=42. •16 w �,J ,• '3',��,2i•• •38 I OtW- ���• 20• •30 �.�)�� •1a SURVEYOR'S CERTIFICATE •19 I HEREBY CERTIFY THAT I AM PROPERLY REGISTERED AND LICENSED TO PRACTICE LAND SURVEYING IN THE STATE OF ALASKA AND THAT THIS AS-BUILT ' REPRESENTS A SURVEY MADE BY ME OR UNDER MY DIRECT SUPERVISION AND THAT A—PAD ALL DIMENSIONS AND OTHER DETAILS ARE CORRECT AS OF SEPTEMBER 9, 2012. LEGEND liQIES AS-BUILT CONDUCTOR 1. ALASKA STATE PLANE COORDINATES ARE ZONE 4, NAD27. 2. BASIS OF LOCATION IS A-PAD MONUMENTS A-2 & A-3. • EXISTING CONDUCTOR 3. BASIS OF ELEVATION IS A-PAD MONUMENT A-2. ELEVATIONS ARE BP MEAN SEA LEVEL (M.S.L.) DATUM. 4. GEODETIC POSITIONS ARE NAD27. 5. PAD MEAN SCALE FACTOR IS 0.9999273. 6. REFERENCE HELD BOOK: NS12-55, PGS. 33-35. 7. DATE OF SURVEY: SEPTEMBER 9, 2012. LOCATED WITHIN PROTRACTED SECTION 35, T. 11 N., R. 13 E., UMIAT MERIDIAN, ALASKA WELL A.S.P. PLANT GEODETIC GEODETIC CELLAR SECTION NO. COORDINATES COORDINATES POSITION(DMS) POSITION(D.DD) BOX ELEV. OFFSETS Y=5,949,470.09 N= 3,319.97 70'16'07.851" 70.2688475' 4,303' FSL A-45 X= 654,444.88 E= 1,000.20 148'45'03.567" 148.7509908' 46.7' 920' FEL AS-BUILT CONDUCTOR DRArm. _.__..__ .-_.....__ I'- liob'1 f--.. JACOBS bp0 '1 CRf it ----- ---- ----` HACKLEMAN _� _ „ �A 9/11,12 -- - ----_... huII �." 61HAA.NG . ?„.2 WOA 04_ WOA A—PAD 11ISSacr -- AS—BUILT CONDUCTOR 00.1,02 tz ATI ISSUED FOR INFORMATION .0 00, °"� '•O WELL A-45 1 °F ..NW MEM we NO nATF ::...a By?C.K Mq,uer. am. 1030 1"-500` - ST7ncillEAlASEASEAN PARNELL, GOVERNOR ALASKA OIL AND GAS 333 W.7th AVENUE,SUITE 100 CONSERVATION COMDIISSION ANCHORAGE,ALASKA 99501-3539 PHONE (907)279-1433 FAX (907)276-7542 John Egbejimba Engineering Team Leader BP Exploration (Alaska), Inc. P.O. Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU A-45 BP Exploration (Alaska), Inc. Permit No: 212-121 Surface Location: 4303' FSL, 919' FEL, Sec 35, T11N, R13E, UM Bottomhole Location: 1938' FSL, 195' FEL, Sec. 26, T11N, R13E, UM Dear Mr. Egbejimba: Enclosed is the approved application for permit to 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 al day of August, 2012. cc: Department of Fish 86 Game, Habitat Section w/o encl. (via e-mail) Department of Environmental Conservation w/o encl. (via e-mail) STATE OF ALASKA RECEIVED ALAS. •./IL AND GAS CONSERVATION COMMI. iN P I 1; 0 7 2012 PERMIT TO DRILL 20 AAC 25.005 1a.Type of work: lb.Proposed Well Class' '®Development Oil ❑Service-Winj ®Single Zone - 1c. Speci y i well i pppped for: ®Drill • 0 Redrill 0 Stratigraphic Test 0 Development Gas ❑Service-Supply 0 Multiple Zone 0 Coalbed Gas 0 Gas Hydrates 0 Re-Entry 0 Exploratory 0 Service-WAG 0 Service-Disp ❑Shale Gas 2. Operator Name: 5 Bond: ®Blanket 0 Single Well 11. Well Name and Number: BP Exploration (Alaska) Inc. Bond No. 6194193 • PBU A-45 • 3. Address 6. Proposed Depth: 12.Field/Pool(s). P.O. Box 196612,Anchorage,Alaska 99519-6612 MD 10524' • TVD 8810' Prudhoe Bay/Prudhoe Bay . 4a. Location of Well(Governmental Section) 7 Property Designation(Lease Number). Surface. ADL 028286 • 4303' FSL, 919' FEL, Sec. 35,T11N, R13E, UM Top of Productive Horizon: 8 Land Use Permit. 13. Approximate Spud Date: • 851' FSL, 764' FEL, Sec.26,T11N, R13E, UM January 29,2013 Total Depth 9.Acres in Property. 14 Distance to Nearest Property: 1938' FSL, 195' FEL, Sec.26,T11N, R13E, UM 2560 21910' 4b. Location of Well(State Base Plane Coordinates-NAD 27) 10 KB Elevation above MSL: 90.3' - feet 15.Distance to Nearest Well Open Surface. x- 654445 • y-5949471 • Zone- ASP4 GL Elevation above MSL feet to Same Pool• 364' 16 Deviated Wells Kickoff Depth 400' feet • 17 Maximum Anticipated Pressures in psig(see 20 AAC 25.035) Maximum Hole Angle. 103 degrees Downhole. 3362 Surface 2511 18. Casing Program: Specifications Top-Setting Depth-Bottom Quantity of Cement,c.f.or sacks Hole Casing Weight Grade Coupling Length MD TVD MD TVD (including stage data) 20" 215.5# A-53 100' Surface Surface 110' 110' 260 sx Arcticset(Approx.) 12-1/4" 9-5/8" 40# L-80 BTD 3283' Surface Surface 3283'• 3280' 1514 sx DeepCrete, 328 sx Class'G' 8-3/4" 7" 26# L-80 VamTop 9057' Surface Surface 9057' • 8597' 307 sx Class'G' 6-1/8" 4-1/2" 12.6# 13Cr85 VamTop 1611' 8913' 8474' 10524', 8810' 207 sx Class'G' 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) Casing Length Size Cement Volume MD TVD Conductor/Structural Surface Intermediate Production Liner Perforation Depth MD(ft) Perforation Depth TVD(ft) 20 Attachments 0 Property Plat ®BOP Sketch ®Drilling Program 0 Time vs Depth Plot 0 Shallow Hazard Analysis ®Diverter Sketch 0 Seabed Report ®Drilling Fluid Program ®20 AAC 25 050 Requirements II 21 Verbal Approval. Commission Representative: Date. 22. I hereby certify that the foregoing is true and correct. Contact Famil Mammadov,564-4135 Printed Name John Egbejimba Title Engineering Team Leader Prepared By Name/Number Signature - e..9iygef,4441 Phone 564-5859 Date J7// t_ Joe Lastufka,564-4091 Commission Use Only Permit To Drill . API Number Permit oval Da e: See cover letter for Number. ;Z(2 ill50-C>L`t -2 -I.7S'•-Ce5GY i '\ 1', other requirements Conditions of Approval. If box is checked,w-elll may not be used to explore for,test,or produce coalbed methane,gas hydrates,or gas contained shales b Other: 3`51°° PS(- 50 P /iS r Samples Req'd 0`(es Mud Log Req'd ❑yes ['No H2S Measures' Yes 0 No Directional Survey Req'd ❑'Yes 0 No &eij,/� /e_�n o✓� < MO e)` ace_ep o if_e.,., 2.3 A.,4c- z ST 0 3 36S) Q , (PPROVED BY THE COMMISSION Date v -3-0 (,), ' ,COMMISSIONER ' Form 10-401 Revised 07/2009 This permit is valid for 24 months(net&tirrv.120 AAC 25.005(g)) Submit In Duplicate �'Q 7<__ tS/'/6 12.___ ."204_ by 0 To: Alaska Oil & Gas Conservation Commission From: Famil Mammadov, Drilling Engineer Date: August 3, 2012 Re: A-45 Permit to Drill A permit to drill is requested for a new grassroots well to be named A-45. The primary target for the well is Ivishak Zone 4. The A-45 well is currently scheduled to be drilled by Parker 272 rig beginning 01/29/13. The maximum anticipated surface pressure from Shublik formation with a full column of gas from TD to surface is —3496 psi (assume 9.8 ppg as max PP at the Shublik). The maximum ancipated surface pressure from the permeable reservoir sands is 2542 psi (assume 7.5 ppg max PP at Ivishak). The Parker 272 rig is equipped with 5000 psi rated four preventer BOP stack(3 rams and an annular). The BOP's will be tested to 3500 psi. A detailed operations summary is included with the permit application. Below is a brief summary of planned drilling operations: 1. As pre-rig work; a. Install 20" conductor casing b. Prepare location for the rig move c. 2. With the drilling rig on the well; a. Move in Parker 272 rig and function test diverter b. Drill 12-1/4"surface hole to 3283 ft MD • c. Run 9-5/8" surface casing and cement to surface d. Nipple up BOPE and test. e. Pressure test surface casing. Drill out the shoe and perform LOT f. Drill 8-3/4" intermediate hole to top of the reservoir at 9,057 ft MD. • g. Run 7"casing and cement to min 1,500 ft above TSGR h. Drill out of intermediate shoe and perform FIT. i. Drill 6-1/8" horizontal production hole through Zone 4 of the Ivishak to TD at 10,524 ft MD j. Run and fully cement a 4-1/2" chrome production liner. k. Run drill pipe conveyed perforating guns. I. Run 4-1/2"completion tubing. Sting into liner tieback sleeve and set production packer. m. Pressure test the tubing and the inner annulus. n. Rig down and move off the well. In addition to a planned well summary, a directional plan and proposed completion diagram is attached to the permit application. If there are any questions concerning information on A-45, please do not hesitate to use the contact information below. Famil Mammadov Office: 907-564-4135 Cell: 907-306-7739 A-45 PTD Page 1 8/3/2012 Planned Well Summary Well A-45 - Type Producer Objecet tive Ivishak Current Status Grass Roots Well Estimated Start Date: 01/29/13 Time to Complete: 40 Days Surface Northing Easting Offsets TRS Location 5949471 • 654445 - 4303 FSL / 919 FEL • 11N 13E sec 35 • Northing Easting TVDss Offsets TRS TSGR 5951212 654553 -8507 762 FSL 7474 FEL 11N 13E sec 26 • TSAD 5951301 654561 -8630 850 FSL / 764 FEL 11N 13E sec 26 • BHL 5952395 655108 -8720 1933 FSL / 195 FEL 11N 13E sec 26 Planned KOP: 400' MD / 310' TVDss • Planned TD: 10,524' MD/ 8720' TVDss - Rig: Parker 272 BF/RT: 47,0' / 43.3' RTE: 90.30' - Directional — Schlumberger (P7) KOP: 400' MD Maximum Hole Angle: —32° in the 8-3/4" intermediate section —102.55° in the 6-1/8" production section • Close Approach Wells: A-45 �se approach towards A-13 well and fails to pass major risk crite ia. A- ell is currently non-operable and it's planned to be plugged and a ndoned prior the spud date. Close proximity of this well cannot be avoided since the objective of A-45 well is to replace the current perforated zones of A-13. Minor risk of 1:200 allows currently planned placement of A- 45 well. Survey Program: Survey Tool Program Date 7!3!2012 From To (tt) (R) Survey(Wegbore) Tool Name Description 43.30 500.00 A-45 plan#7(A-45 plan current) GYD-GC-SS Gyrodata gyro single shots 500.00 2.500.00 A-45 plan#7(A45 plan current) MWD MWD-Standard 2.500.00 3283.00 A-45 plan#7(A-45 plan current) MWD+IFR.MS MWD+IFR+Mule Station 3,283.00 4,800.00 A-45 plan#7(A45 plan current) MWD MWD-Standard 3.283.00 9.060.00 A-45 plan#7(A-45 plan current) MWD+IFR+MS MWD+IFR+Multi Station 9,060.00 10,523.60 A-45 plan#7(A-45 plan current) MWD MWD-Standard 9,060.00 10.523.60 A45 plan#7(A45 plan current) MWD+IFR+MS MWD+IFR+Multi Station Nearest Property Line: 21,910 ft. • Nearest Well within Pool: 364 ft A-45 PTD Page 2 8/3/2012 Formation Tops & Pore Pressure Estimate / I [4rAncci Estimated Depth Fluid Most Likely Minimum Maximum M" �rncl Formation Formation Top Uncertainty Type Pore Pressure Pore Pressure Pore Pressure tAA (TVDss) (+/-TVD ft) (for sands) (EMW ppg) (EMW ppg) (EMW ppg) (-(lJ) G1 340 ±20 No 8.35 8.35 8.45 g,-s-- 9-L SV6 1670 ±20 No 8.35 8.35 8.45 BPRF 1950 ±20 No 8.35 8.35 8.90 EOCU 2325 ±20 No 8.35 8.35 8.90 SV5 2340 ±20 No 8.35 8.35 8.90 Fl--S--1.L SV4 2690 ±20 No 8.35 8.35 8.90 SV3 3040 ±20 No 8.35 8.35 8.50 SV2 3230 ±20 No 8.35 8.35 8.50 SV1 3620 ±20 No 8.35 8.35 8.50 p UG4 4120 ±20 No 8.35 8.35 8.50 .O 9` 7 UG4A 4330 ±20 No 8.35 8.35 8.50 _ UG3 4385 ±20 No 9.40 8.35 9.40 UG1 4880 ±20 No 9.40 8.35 9.40 WS-2 5440 ±20 Wet 8.35 8.35 8.50 WS-1 (SB_OA) 5680 ±20 Wet 8.35 8.35 8.50 CM-3 5960 ±20 No 8.35 8.35 9.10 CM-2 6420 ±30 No 9.62 8.35 9.90 `j: - /0.3 Fault#1 (CM2) 6650 ±100 MD --- 9.62 8.35 9.90 CM-1 7100 ±30 No 9.62 9.60 10.50 / TLBK 7255 ±30 No 9.62 9.60 7 10.50 Fault#2(LBK) 7275 ± 100 MD --- 9.62 9.60 10.50 • THRZ 7415 ±30 No 9.62 9.60 t0.50 LCU 7625 ±30 Wet 9.62 9.60 9.90 TKNG(TJG) 7625 ±30 No 9.62 9.60 9.90 u' TJF(faulted) 7710 ±30 No 9.62 9.60 9.90 Fault#3(TJF) 7710 ±100 MD --- 9.62 9.60 9.90 TJE 7790 ±30 No 9.62 9.60 9.90 TJD 8105 ±30 No 9.62 9.60 9.90 Fault#4(TJD) 8165 ±100 MD --- 9.62 9.60 9.90 TJC 8220 ±30 No 9.62 9.60 9.90 TJB 8350 ±30 No 9.62 9.60 9.90 TJA 8435 ±30 No 9.62 9.60 9.90 TSGR 8507 ±30 Yes Oil/Gas 7.40 6.05 7.6Q TSHU 8535 ±30 OiVGas 7.38 6.05 (9.80 ) g S-g,g TSAD(46P) 8630 ±30 Yes Oil/Gas 7.32 6.08 7.50 45N 8657 ±30 Yes Oil/Gas 7.31 6.08 7.50 45P 8658 ±30 Yes Oil/Gas 7.31 6.08 7.50 44N 8692 ±30 Yes Oil/Gas 7.28 6.08 7.50 44P 8694 ±30 Yes Oil/Gas 7.24 6.08 7.50 pR. I2 PGOC 8680 ±40 Yes Oil/Gas 7.22 6.08 7.50 43N 8724 ±30 Yes Oil/Gas 7.22 6.05 7.50 43P 8728 ±30 Yes Oil/Gas 7.22 6.05 7.50 42N 8754 ±30 Yes Oil/Gas 7.22 6.08 7.50 42P 8757 ±30 Yes Oil/Gas 7.22 6.08 7.50 POWC(heel) -8765 ±40 Yes Oil/Gas 7.22 6.08 7.50 POWC(heel) -8765 ±40 Yes Oil/Gas 7.22 6.08 7.50 42P 8751 ±30 Yes Oil/Gas 7.22 6.08 7.50 42N 8749 ±30 Yes Oil/Gas 7.22 6.08 7.50 43P 8719 ±30 Yes Oil/Gas 7.22 6.08 7.50 43N 8713 ±30 Yes Oil/Gas 7.22 6.08 7.50 43N 8705 ±30 Yes Oil/Gas 7.22 6.08 7.50 43P 8710 ±30 Yes Oil/Gas 7.22 6.08 7.50 POWC(toe) 8720 ±40 Yes Oil/Gas 7.22 6.08 7.50 A-45 PTD Page 3 8/3/2012 Casing/Tubing Program Hole Liner/ Wt/Ft Grade Conn Burst Collapse Length Top Bottom Size Tbg O.D. (psi) (psi) (ft) MD I TVDrkb MD I TVDrkb 12-1/4" 9-5/8" 40# L-80 BTC 5,750 3,090 3,283 Surface 3,283' /3,280' 8-3/4" 7" 26# L-80 VaHCop 7,240 5,410 9,057 Surface 9,057' /8,597' 6-1/8" 4 '/2" 12.6# 130-85 Vam-Top 8,430 7,500 1,611 8,913'/8,474' 10,524' /8,810' Tubing 4 '/2" 12.6# 13Cr-85 Vam-Top 8,430 7,500 8,918 Surface 8,918' /8,477' Mud Program Surface Hole Mud Properties: HFGBM 12-1/4" Hole Section Density LSYP YP API FL Chlorides Funnel Depth IntervalpH Viscosity ppg 2x3-6 lb/100 ft2 m1l30min mg/I sec/qt 0-2050 (BPRF) 8.5 - 9.2 40 - 60 50 - 80 NC <1000 10.3- 11 60-120 2050- Section TD 8.5 -9.2 30-40 30-50 NC <1000 10.3- 11 60-120 Intermediate Hole Mud Properties: LSND 8-3/4" hole section Depth Interval Density PV YP API FL HTHP FL MBT PH PPg 3284—4450 8.8—9.7 8-16 18-28 <6 NC <15 9-10 4450 - 7700 9.9— 10.3 8-16 18-28 <6 NC <15 9-10 7700—section TD 10.3— 10.5 10-20 17-28 0-6 <10 <20 9-10 Production Mud Properties: Biopolymer Reservoir Drill-in Fluid 6-1/8" hole section Depth Interval Density (ppg) PV YP LSVR API FL pH MBT 7" shoe to TD 8.5—8.8 - <12 20-28 >15,000 >8 9.0-9.5 <4 Logging Program 12-1/4" Surface: Sample Catchers— not required for surface hole section Drilling: Dir/GR/Res - Open Hole: None Cased Hole: None 8-3/4" Intermediate: Sample Catchers—as required by Geology Drilling: Dir/GR/Res Open Hole: None Cased Hole: Cement evaluation log if required 6-1/8" Production: Sample Catchers—as required by Geology Drilling: Dir/GR/Res/Neu/Den Open Hole: None Cased Hole: None A-45 PTD Page 4 8/3/2012 Cement Program Casing Size 9-5/8" 40#, L-80 Surface Casing Lead: Open hole volume + 300% excess through permafrost and 40% excess below Basis: permafrost. Port collar used if hole conditions dictate Lead TOC: Surface Tail: Open hole volume + 40% excess + 80 ft shoe track Tail TOC: 300-1000 ft MD above casing shoe Total Cement Spacer 100 bbls of Viscosified Spacer weighted to 10.0 ppg (Mud Push II) Volume: Lead 492 bbls, 2763 cuft, 1514 sks of 11.0 ppg DeepCRETE, Yield 1.$2ft'_Lsk_. Tail 68 bbls, 382 cuft, 328 sks of 15.8 ppg Class G + adds— 1.16 ft'/sk Casing Size 7" 26#, L-80 Intermediate Casing Basis: Lead: None Tail: Open hole volume + 30% excess + 80' shoe Tail TOC: 1500 ft above 7" shoe (@ 7557 ft MD) Total Cement Spacer 30 bbls of Viscosified Spacer weighted to 12.0 ppg (Mud Push II) Volume: Lead N/A Tail 64 bbls, 359 cuft, 307 sks of 15.8 lb/gal Class G + adds— 1.17 cuft/sk Casing Size 4.5" 12.6#, 13CR Production Liner Basis: Lead: None Tail: Volume of open hole + 40% excess + 80' shoe track + 150' of liner lap + 200' of 7" x 4" DP excess. Tail TOC: 8713' MD (cement at TOL w/excess to be circulated out) Total Cement Spacer 30 bbls of Viscosified Spacer weighted to 12 ppg (Mud Push II) Volume: Lead N/A Tail 43 bbls, 242 cuft, 207 sks of 15.8 lb/gal Class G + GasBlok + adds— 1.17 cuft/sk Surface and Anti-Collision Issues Surface Shut-in Wells: • There are no wells requiring surface shut-in in order to move onto the well. At surface, the A-45 well will be placed —30' north of the A-13 well. Close Approach Shut-in Wells: • One off-set well A-13 fails Major Risk analysis for their close approach proximities within the pay zone, however, it passes Minor Risking at 1:200. A-13 well does not represent any safety risk as it is currently suspended and non-operable. It is planned to plug and abandon A-13 well prior the spud. A-45 PTD Page 5 8/3/2012 Hydrogen Sulfide A pad is considered an H2S site. Recent H2S data from the pad is as follows: (6) H2S Data Well Name H2S Level Reading Date Comments Parent Well(if sidetrack) N;A N;A N/A #1 Closest SHL Well H2S Level A-13 110 ppm 7,20;2010 #2 Closest SHL Well H2S Level A-35 28 ppm 9/17/1995 #1 Closest BHL Well H2S Level A-13 110 ppm 7/20/2010 #2 Closest BHL Well H2S Level A-12A 40 ppm 12512012 #3 Closest BHL Well H2S Level A-34A 40 ppm 626,2008 #4 Closest BHL Well H2S Level A-256 18 ppm 2;7/2012 Max.Recorded H2S on Pad/Facility A-37 400 ppm 3/17/1998 Other Relevant H2S Data A-pad is considered an H2S facility (H2S alarms from rigs,etc.) Faults Formation Where Encounter Fault MD Intersect TVDss Intersect Est.Throw Throw Direction Uncertainty Fault#1 - CM2 6 860 0 6 650 0 40 ft South +i-100'MD Fault#2- TLBK 7 608-0 7 275 0 25 ft South +r- 00'MD Fault#3-Kingak(TJF) 8 120 0 7 710 0 50 ft South +r-100'MD Fault#4-Kingak(TJD) 8 658 0 8 165 0 40 ft South +1-100'MD Drilling Waste Disposal • There is no annular injection in this well. • Cuttings Handling: Cuttings generated from drilling operations will be hauled to grind and inject at DS-04. Any metal cuttings will be sent to the North Slope Borough. • Fluid Handling: Haul all drilling and completion fluids and other Class II wastes to DS-04 for injection. Haul Class I waste to DS-04 and/or Pad 3 for disposal / Contact the GPB Environmental Advisors (659- 5893)f/guidance. Well Control Well control equipment consisting of 5,000 psi working pressure pipe rams (2), blind/shear rams, and annular preventer will be installed and are capable of handling the maximum potential surface pressures. Based upon calculations below, BOP equipment will be tested to 3,500 psi. BOP regular test frequency for A-45 will be 14 days during drilling phase (unless stipulated otherwise) and 7 days during de-completion and surface casing work. Intermediate Interval Maximum anticipated BHP f 3362 psi @ TSGR at 8507 ft TVDss (7.6 ppg EMW) Maximum surface pressure ' 2511 psi (.10 psi/ft gas gradient to surface from TSGR) 25.1 bbls from Colville 2 assuming 9.62 ppg PP gradient+ 0.5 ppg KI Kick tolerance 28.9 bbls from Ugnu assuming 9.4 ppg PP gradient+ 0.5 ppg KI 35.7 bbls from Sag river 7.4 ppg PP gradient + 0.5 ppg KI Planned BOP test pressure Rams test to 3,500 psi/250 psi. Annular test to 2,500 psi/250 psi A-45 PTD Page 6 8/3/2012 9-5/8" Casing Test/7" 3500 psi surface pressure Casing Integrity Test—8-3/4" hole FIT after drilling 20'-50' from middle of window 7" Casing The VBRs will be changed to 7" rams to accommodate the 7" casing Production Interval 4349 psi @ Shublik at 8535' TVDss (9.8 ppg EMW)— non permeable Maximum anticipated BHP 3418 psi @ Ivishak Zone 4 at 8765' TVDss (7.5 ppg EMW)- permeable L____3496 psi (.10 psi/ft gas gradient to surface from Shublik) Maximum surface pressure 2542 psi(.10 psi/ft gas gradient to surface from Ivishak Zone 4) ' Infinite with 11.94 ppg frac gradient, assuming a maximum 8.0 ppg max Kick tolerance pore pressure in the Ivishak sands with a 8.6 ppg MW. Planned BOP test pressure Rams test to 3,500 psi/250 psi. Annular test to 2,500 psi/250 psi Integrity Test—6-1/8" hole FIT after drilling 20'-50' of new hole 4-1/2" Production Liner 3500 psi surface pressure Planned completion fluids 8.6 ppg Brine/6.8 ppg Diesel Variance Requests: • To avoid the risk of plugging the flow line with large rocks and wood encountered while drilling surface hole, it is requested to drill without a flow paddle for the first portion of the surface hole. While the flow paddle is removed from the flow line, PVT alarms will be used and the pit levels accurately monitored for any pit gain. Also, a visual check will be made during connections by looking down the riser to ensure the well is not flowing. After returned debris that could plug the flow line diminishes the flow paddle will be reinstalled. ,2A4-1 -et "() COD �¢ W _p, 1"' A-45 PTD Page 7 8/3/2012 A-45 General Operational Summary Pre-Rig Work: 1. Install 20" conductor casing. 2. Weld an FMC landing ring for the FMC Gen 5 wellhead on the conductor. 3. If necessary, level the pad and prepare location for rig move 4. Remove well houses as necessary Rig Operations: 5. MIRU Parker 272. r > }, J 1 vtg/z-` 6. Nipple up and function test diverter. 7. Prepare pits with Drillplex Mud and PU drill pipe to TD the surface interval and stand back in the derrick. 8. MU 12-1/4" drilling assembly with DIR/ GR/ RES and directionally drill surface hole to TD in SV3 shale at—3,283 ft MD. If needed, perform a wiper trip at the base of permafrost. 9. Circulate bottoms up and condition hole as necessary, then POOH 10. Run and cement 9-5/8" 40# L-80 BTC surface casing. A TAM port collar may be run at 500 ft as a contingency 11. Nipple down diverter and nipple up casing/tubing head. Nipple up BOPE and pressure test to 250 psi • / 3,500 psi 12. Pressure test 9-5/8" casing to 250 psi / 3,500 psi for 5 min / 30 min respectively - 13. Make up 8-3/4" drilling BHA with DIR/GR/ RES/PWD and RIH to float collar picking up 4" drill pipe as required to TD the intermediate interval. 14. Drill out shoe track and displace well to LSND drilling fluid. Drill 20 ft of new formation and perform LOT to min 12.5 ppg. 15. Drill 8-3/4" hole section to intermediate TD, approximately 5-10 ft in TSGR at— 9057 ft MD. • 3284 ft MD-4450 ft MD: 8.8-9.7ppg • 4450 ft MD—7700 ft MD: 9.9— 10.3 ppg • 7700 ft MD—section TD: 10.3— 10.5 ppg 16. Circulate bottoms up until hole clean and condition mud for 7" casing running/cementing. 17. Change upper rams to 7" and test 250 psi/3,500 psi --- c e, si7 Via,; 18. Run and cement 7" 26 ppf L-80 VAM TOP HC production casing. Bump plug and ensure that float ra)- valve holds 19. Pressure test 7" casing to 250 psi/3,500 psi for 5 min/30 min respectively when the plug bumps A-45 PTD Page 8 8/3/2012 20. Ensure annulus remains open for freeze protection by injecting drilling fluid into the annulus until cement reaches 500 compressive strength 21. Install 9-5/8" x 7" casing pack-off and test as per FMC representative. 22. Change out 7" top rams back to VBR. Perform 250/3,500 psi BOP pressure test. - 23. Freeze protect the 7" x 9-5/8" annulus once 500 psi cement compressive strength reached. 24. MU and RIH 6-1/8" drilling assembly with DIR/ GR/ RES / NEU / DEN. Pick up additional drill pipe if required. 25. Displace well to 8.6 ppg LSND polymer fluid from above the shoetrack 26. Drill out shoetrack and 20 ft of new formation. Perform an FIT to min 9.0 ppg 27. Drill ahead 6-1/8" hole section to well TD at— 10,524 as per directional proposal and wellsite geologist. 28. Condition the hole as required in preparation of running and cementing 4-1/2" production liner. Spot liner running pill on bottom if necessary. POOH, L/D excess 4" drill pipe and BHA 29. RU and run 4-1/2" 12.6 ppf 13 CR VAM TOP liner. Circulate bottoms up 7" shoe and TD as necessary 30. Cement 4-1/2" liner per Schlumberger program. Release from the liner and set the packer. Circulate excess cement to surface. 31. Displace well to—8.6 ppg brine above the liner top. POOH and lay down drill pipe and liner running tools. A)° r` 32. Pressure test 7 casing x 4-1/2" liner to 250 psi / 3,500 psi for 5/30 min each. N, p7syira test 33. MU drill pipe conveyed perf guns. RIH and perforate. Perforation intervals will be based on "as-drilled" LWD. POH and lay down drill pipe and perforation guns. Verify all shots fired. 34. RU and run 4-1/2", 12.6 ppf, 13-Cr Vam Top tubing with gas lift mandrels. Space and land the tubing with the tubing tail inserted into the liner tie-back sleeve. Run in lock down screws. 35. Reverse circulate brine to surface 36. Drop ball /rod and set packer. 37. Individually test the tubing and annulus to 3,500 psi for 30 min. Record each test. k 38. Shear the DCK valve in GLM 39. Install TWC and test from above to 250 psi / 3,500 psi for 5 minutes each and from below to 250 / 3,500 psi for 5 min / 30 min. 40. Nipple down BOPE. Nipple up the adaptor flange and tree and test to 250 psi/ 5,000 psi for 5 min each with diesel. 41. RU and test DSM Lubricator. Remove TWC valve 42. RU circulating lines. Freeze protect the well to —2,200 ft TVD and allow diesel to U-tube reaching equilibrium. 43. Install a BPV, then the VR plugs in the annulus valves if necessary A-45 PTD Page 9 8/3/2012 44. Secure the well. Rig down and move off. Post-Rig Work: 45. Install tree. Pull BPV. 46. R/U Slickline and pull ball and rod / RHC. 47. Replace the DCK shear valve with a dummy GLV. 48. Pull dummy valves and replace with gas lift valves. Pull VR Plugs. 49. Flowback well through test separator until production stream acceptable for GC processing. 50. Install wellhouse(s)and flowline(s). 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W $ $li § r _ I. , i �lil'limmi'III��1tllillwd1mm..I _4—_ ;4111:_-: - S a a a o 4 a �� Oil r y I i i k. i<141-€11<11 O i '- rill I - \ eaa N.V. coN , a t. F, IIPTOD 'CB F iI xs� 1 N - --I I—i H------::::_j I IP 111161 W I- C I2ta _ u.„a3 5=„£3E iE� g Q ae E x4 ils it i III g ze ' p 1 M N o c e ' r Y d ti g w+ i. d 3 d 'q 3 O <3 M u2 U) 03 a wAAA JJ J I— 1- * Q Weliplan Addendum Contingency for well control when non-shearable equipment is across the BOPE shear rams This document will provide guidance for rig operations when a well control event arises and there is non- shearable equipment hanging from the derrick across the BOPE shear rams. Prior to picking up or running any equipment or tools in the hole, a PJSM and discussion is required to identify and note any equipment which will be run through the BOPE and is non-shearable. A risk assessment shall be performed for any equipment which is deemed non-shearable. The risk assessment must address the following: 1. Can variable bore rams seal against the equipment? 2. Can an annular preventer seal against the equipment? 3. Is a cross-over readily available to make-up into equipment? 4. Is a single joint or full stand of DP readily available to lower equipment below the BOPE stack? 5. How the equipment can be intentionally dropped down hole. 6. Are weights of equipment known so that hydraulic jacking force of wellbore pressure can be calculated. 7. Accurate and up to date shearing capabilities for the current shear rams installed is available. 8. Has each crew member been versed on individual roles and responsibilities? If there is a well control event happens with non-shearable equipment across the BOPE shear rams, the following procedure should be followed: 1. Based on the risk assessment above, gain control of the well by either: a. Closing the appropriate preventer(pipe ram, VBR, or annular) or b. Placing a sealable piece of equipment across the BOPE and closing the appropriate preventer or c. Dropping equipment and closing the Blind or Blind/Shear rams. 2. If well conditions permit, contact appropriate personnel. If not, proceed with well kill operations. This may include placing shearable equipment(i.e. drillpipe) across the shear rams by stripping in/out of the hole. A-45 PTD Page 13 8/3/2012 A-45 Drilling Hazards and Contingencies POST THIS NOTICE IN THE DOGHOUSE I. Well Control A. Surface Hole — the interval is normally pressured. Gas bubbling was observed in the cellar of the off- set A-13 well during production (not gaslift or payzone gas). B. Intermediate Hole -the planned mud weight will be ranging from 8.8— 10.5 ppg depending on depth of drilling. Sufficient mud weight will account for: 1. Potential cretaceous injection pressures (9.6 ppg max). 2. Sag River pore pressure(7.6 ppg max). 3. HRZ and Kingak shale stability. C. Production Hole - The Sag River and Ivishak formations in this area are expected to be under- pressured at 7.4 - 7.6 ppg EMW. This interval will be drilled with a 8.6 ppg reservoir drill-in fluid. II. Lost Circulation/Breathing A. Surface Hole- Lost circulation is considered a minimal risk if mud properties remain in specification. B. Intermediate Hole - A-45 well is expected to intersect 4 faults in the intermediate section. Risk of losses in his interval is considered as "high". Wellbore breathing has occurred in the area. C. Production Hole - Severe lost circulation events have happened in the production hole sections. III. Kick Tolerance/Integrity Testing A. Kick tolerance Hole Section Fracture Gradient at weak Kick Tolerance point(ppg) (bbls) Intermediate Assuming 12.47 from LOT 25.1 Production Assuming 9.0 from FIT Infinite - B. Integrity Testing Test Point Test Depth Test type 9-5/8" shoe 20-ft minimum from the 9-s/8" shoe LOT 7" shoe 20-ft minimum from the 7" shoe FIT IV. Hydrogen Sulfide As A-Pad is considered an H2S site, refer to the ADW "Hydrogen Sulfide" SOP for the appropriate operational guidelines. The max recorded H2S readings on the pad were 400 ppm in A-37 in March 1998. A-13 (closest well at surface) recorded 110 ppm in July 2010. A-45 PTD Page 14 8/3/2012 V. Faults - A-45 wellpath is expected to intersect 4 faults in intermediate section (in Colville and Kingak formations). The faults have been crossed 20 times in the past, with 4 incidents of lost circulation Formation Where Encounter Fault MD Intersect TVDss Intersect Est. Throw Throw Direction Uncertainty Fault#1 - CM2 6 860 0 6 650 0 40 ft South +1-100'MD Fault#2- TLBK 7 608 0 7 275 0 25 ft South +1-100'MD Fault#3-Kingak(TJF) 8.120 0 7 710 0 50 ft South +11-100'MD Fault#4-Kingak(TJD) 8 658 0 8 165 0 40 ft South +/-100'MD VI. Anti-Collision Issues A. The P&A A-13 wellbore is a close approach concern. The A-45 well path doesn't pass Major Risk analysis at following depth ranges: • 3212—3408 ft MD V • 10,242-10,319 ft MD A minor risk criterion at 1:200 was applied for A-13 wellbore. CONSULT THE A PAD DATA SHEET AND THE WELL PLAN FOR ADDITIONAL INFORMATION. A-45 PTD Page 15 8/3/2012 Wellbore Schematic TREE=VWH-LFEAD= 41/E A 5 WEATHESAFETY R MTOMTORING SHACK MUST BEES: WARMNG MO AMIT tft IN NED OFF ACTUATOR= BEFORE ANY WELLWORK INVOLVING EXPLOSIVES CAN Proposed KB.ELEV= BEGIN. CONTACT PAD OPERATOR"'CHROME TBG"` BF.ELEV= KOP= 430' h —100 -'+.. ';5#,A-53,Insulated Conductor Max Angle= 103 deg i 2000' H 41/2' SSSV NP,D=3.813' Datum MD= 10,400 • Datum WO= 8,800 GAS LFT LAM:FE S 9-5/8'CSG,408,L-80.BTC.D"8.835' --{ 3283' ST MD TVD DEV TYPE VLV LATCH PORT 4 3700 3697 0 KBG-2 DCK-2 SEX 1' 3 5900 5890 17 I03G-2 DUd BK I' 2 7600 7362 32 KBG-2 DI.JIvI DK 1' 1 8700 8295 32 KBG-2 DUM BK 1' Minimum ID=3.725"@8908' 4-112"XN I dti �S 8757' —4-1/2'XN'D= 3.813' 8-3/4 hole 8808' H7"X4-117 PKR I ' 8838' —14-1/2'X MP,ID=3.813' 4 12'TBC,12.611,130 80 V T,.0162 kV,D 3.068' y 8900' • I I 8908' —1412'XN NP,D=3.725" 8918' H4-I2'TUBING TAI 'TOP OF4-12-LhRH 6913' I L. 7'LN;26#,L-80,VamTop I-C,0383 Lpf,1E1=6276' —4 f0,T I - ° 7" @U TS G R FBIFORATU)N SUMMARY REF LOG: ANGLE AT TOP PERF 6-1/8" hole Note:leer to Production DB for historical perf data — SIZE SPF INTERVAL Opn/Sqz LATE 4-12'INR,12.640,190--80 H 10624' ( , , --86° DATE REV BY CO1.9.1ENTS DATE REV BY OOMbUITS FRUD OEBAY LINT 03119/12 11118E PROPOSED wpie WELL: A-0L: 07/19/12 MI PROPOSEDpSi FEFUTNo: AH No: SR.'35.TIM/ R131-,4303 FSI &919'Fri.. BP Exploration(Alaska) A-45 PTD Page 16 8/3/2012 Directional Plan and Anticollision Summary A-45(P7)Proposal Report BciM mburger (Def Plan) Report Date. Juni D5.7012-03:14 PM Survey 01.3 Computation 11x4, Client BP Eaploraeon Alaska Ventral Section Azimuth '3 WO°,Tue Nortnl Lt • F4W: A-a�a Bay 4,n.F�$i bi lity study VG Reference D nano Oo.413,.;Sa d A-PAD:4-45 Bay W�• atwe.slot 4-45 TVG Reference Elevation. le 300 0 atm*MSL • BPredaM. 4-45 Seabed Ground Elevation. 48.55 0 above MSL 7 OWl 34580 tink1r51y11!L k4c9Mn Magnetic Decimation. 20.594' Survey Mame. 0-45(P7) Total Feld Strength 57645.131 nT Survey Date February 27.2012is 04p Eng. 61.024• Tort 4030 r D41 ERE,Rada. 156.541':3164 394 0 15.768;0.350 De/117uon Gate Demist r 31 2012 Cmrtlwlate R4aence System: 94027 Masks Stale Plane.23.,4 04,US Feet Magnel.0 Dec9nalion Model BOON 2011 Location Cat-Long' M 70 16].85122.W 148.45'354791' 730 Reference 1.0 Ranh • Location Grid MSS, R 5..71 150 505,E 834445 030815 Gr.d_convergence Used 0.00" CR5 End Convergence Angle. t 17504887` Total TermCorr D nn-•True 21541. G rid Scale Factor. 05929271 Luul Coord Re4erence3 To WY.-teat Comments MD Intl Aue True TV058 TVD V5EC MS 894 TY DLS Directional North, Fasting (01 7) 77 (R1 1111 1141 401 931 I'! 7!19061 D4M1Ind.ly ln4 (11051 414081 070 000 0.00 340.00 .0030 0.00 0.00 000 000 34191 740 0D0 5940471.15 05491503 100.00 0.00 34000 0.70 100.00 0.00 05 0.5 34CM 0.00 0.00 5444471.15 05444503 20.00 000 340.00 109 70 200.00 0.00 20 400 34091 0.00 0.00 5949471.15 654445 03 O 06-Curve 7/100 30000 0.0 340 00 200 70 300.00 D.0 200 0 00 34091 0.0 000 594.71.15 054445 03 40.00 1.0 340.0 300 OD 300 00 0.:2 3.62 -030 MOM 1.0 0.0 5949471.00 604444 71 Of 430.31 1.30 34000 340.00 430.30 1.22 139 -05f 3404 1.00 0.29 5949/72.53 654444.49 0444.2733 50.45 2.0 3400 409.0 414.00 20 328 •119 34CM 1.0 0.84 501047440 60444377 00.00 4.0 34.0 500.52 544.82 7 24 6.20 .2.96 NCM 7.0 1 54 5444470 2B 654141 04 70000 0.0 3400 00.13 001443 14.47 15.14 -548 05 20 2.02 504048741 05443873 Curve 2:30 90.0 800 340 0 706.34 796 08 2.50 27 91 1013 LS 20 2.39 5040408.77 0.434 33 0000 4.0 34.0 07.03 847.03 34 00 30.5 .14.30 L5 2.0 2.02 5044510 14 0.04424 03 10000 4.0 3400 0725 907.55 41.02 4748 .1728 34CM 20 279 5440618.20 05442078 POO 0 2.0 .0 0 1001 10 1097 40 46.20 .40 -19 07 3414 2 0 2.80 5449523.14 65.24 89 End Curve 120.0 00 34 0 110108 1107.38 47.71 514 •10 67 34191 2 0 2.35 544452.77 05442 20 1014 953 340.0 1207.0 1207.91 47 71 544 .1997 3444 0.0 7.00 5.952477 650474 20 140.0 000 340.0 130700 1017.38 47.71 54.04 1967 31191 0.00 2.35 504952.77 054424 20 130.0 0.0 340.0 140100 1497.38 47.71 564 -1907 MOM 00 2.00 5.452.]7 65142423 100.0 0.0 340 20 1507.00 1507 38 47.71 544 -11167 31191 0.0 2 se 5048524 77 65424 20 1701.0 0.0 340 00 107.08 1047 38 47 71 54 04 -19.07 31191 0.0 296 5040524 77 64424 20 SW 1762.92 70 3400 10700 1765.30 4771 5104 -1967 34090 00 296 594052.77 65442426 9090 0.0 34 0 1707.00 74 47.71 5104 -19.67 34C11434C1140.0 240 5040524 77 654424 20 140000 0.0 410 4447 3 1807.08 1807 38 47.71 54 04 -19.07 3414 0.0 296 5040524 77 654424 20 260700 0.0 340 0 1907.08 107 38 47.71 54 04 -19.67 3404 0.0 2 96 594452 77 05442 20 BPRF 201207 0.00 34.0 1950.00 5 204.30 17.71 54.04 .9267 341 0.00 2.96 594952.7] 059121.76 00 0.0 4.0 34 2.0 3 2007.06 2947.36 47.74 54.04 19.67 CM 0.0 zoo 5.432.77 05442420 2245.0 0.0 340 0 210'.0 2197 38 47.71 54:2 -1967 34084 D.0 2.00 544962.77 0044270 2300.0 0.0 340 30 2207 08 2237.38 47.71 5404 .111107 31CM 0.0 2.96 504832.77 05114 20 240.0 0.0 34 0 2307 08 2347.39 47.71 5404 .19 67 31091 0 0 2.0 504052477 054474 20 SO21792 00 340.0 2325 00 215.30 17.71 54 04 -19 67 3491 000 0.96 594952.77 054424 2 SYS 232.92 O0 340 0 2310.00 243030 4771 54 04 -99 67 34041 0.00 296 5949524 77 6502 26 250.0 0.00 340 0 2407 08 2407.38 47.71 5404 -19 67 34044 0.0 2.96 544052.77 054424 20 200.0 000 34.0 2507.08 2547.38 47.71 544 .19.67 34DM 0.0 240 504052.77 0542.20 27000 0 0 340 0 707.08 2087 38 47.71 5404 .19 07 NCM 0.0 2.80 504852.77 051424 20 5114 2-162.92 00 340.0 2690.30 270.30 17 71 5404 -1297 341 0 0 295 5949524.77 65424 26 280.0 0 CO 340 45 2707.03 2747 38 47.71 5401 .1967 NOM 0.0 2.40 5049521.77 454424 2 2860.0 0 ea 34 0 2401 0 2907 38 47.71 544 .1967 34DM 0.0 2.96 5040574.77 474424 20 30011 000 340 00 7007.08 700;38 47.71 544 -19.47 34044 0.00 2.40 5040524.n .4424 20 3'0.0 0 CO 340 03 3007.00 1007 38 47.71 54 4 -1967 3444 0.00 2.97 5.9524 77 65424 20 743 373292 0.0 34.0 30400 311.30 47.71 50.04 -7997 341 000 296 594952.77 6542.26 320000 0.00 MO 0 3107.00 3197.38 17.71 54 04 -.67 340M 0.0 2.90 594452 77 0542 20 SMlane Casing 7<82.42 0.0 440.0 3100 . 32030 4771 5404 -1567 341 000 296 5349524.77 65442426 330.0 0.0 340 0 3207.04 3207.36 47 71 544 .1967 34044 0.0 296 5440524 77 054124 20 442 332292 00 34.0 3230.0 3309.30 1771 5400 -9967 3444 000 2.96 594952.77 65442424 340.0 0.0 340 0 3307.08 1307.38 47 71 544 -1967 MOM 13.0 2.00 5440524 77 054424 20 3500.0 0 0 342 00 3407 08 344710 47.71 544 -14.07 NOM D 0 296 5040524.77 45424 20 3000 0.0 340 0 3507.04 3507.38 47 71 5E04 -19.67 54044 0.0 2.90 5940524 77 054424 26 370.0 0.0 300 390'00 3647.38 4771 914 -19.67 34044 00 290 594032.77 05442426 701 371292 00 340.0 3620.0 3710.30 4771 544 -1967 34094 0.00 296 594952.77 6302426 3806.0 00 340 3717 00 375730 47.71 504 -1967 NOM 00 2 D 5040524.77 55442420 3900.0 O DO 34a 00 3877 08 3807.36 4.71 54.04 .1887 .04 0.00 296 504452.77 65424 2 400000 D.DO 34.00 3007.08 7097.38 47.71 54.04 1947 NCM 00 2,414 594052.77 654242 4100.0 00 3400 400700 430738 47.71 914 -1967 NCM 0 D 2.35 501952477 054424 20 4200.00 0 C 34 00 4107 De 410138 47.71 914 -1967 34CM 000 2.35 5.962477 55424 20 1161 1212.92 0.00 34.0 412000 4210.30 4771 3404 -1997 30054 000 296 594942.77 6542429 43000 0.45 14000 4207.08 4X17.38 47.71 914 -1967 34191 0.0 2De 5.852477 05442420 44130.00 0.0 3400 4307.08 4397.38 47.71 544 -1967 NCM 0.00 235 5.65277 65422 401.4 422.92 0.40 34.00 433090 02030 1771 54.04 -198] 3194 000 2.96 591952.77 6542126 4X63 47',.92 0.0 340.0 43850 4475.30 17.71 54.04 -1967 34 O0 2 952..96 58477 65424:6 450.0 0.0 340 0 407 04 4407 38 47.71 544 .19 67 34091DM 0 0 2 DO 5040824.n 6542 20 400.0 C.0 340.0 4507 0 4597.38 47.71 544 .1987 34191 00 2.00 5849524.71 05424 20 470.5 0.0 340 4007 C0 404738 47.71 5004 .19 97 34054 00 2De 594042.71 65422 4800.0 0 0 34.0 4707 0 4747 38 47.71 544 .1907 34CM 0 0 2.35 504052.77 454424 20 400.00 000 340.5 4907 08 4897 34 4771 5E04 .19 07 34191 0 00 2.00 5040524.77 54424 20 UGI .77 92 0.0 NO 0 180.00 4970 30 17.0 54 04 -1967 3401 000 2.96 554952.77 654424 26 50000 D.0 340 0 40108 449].38 47 71 314 -10.07 34091 0.0 2.46 504952 77 ..424 20 510.00 0.D0 34.0 500706 5097.38 47.71 544 1957 34191 000 200 5044524.77 05442420 5220.00 0.00 34.40 5107.08 5147.36 47.71 544 .1967 34DM 000 200 594952477 00442.20 530.0 0.00 340.0 5207.08 5237.14 47.71 5404 -19.07 3491 0.00 200 504452.71 0042420 Curve 3'10 5343.09 0.0 340 0 5250.77 5341 07 47.71 54 04 -19 67 5 5084 0.0 2.06 5049524 77 054424 20 540000 1.00 550 5307.07 5307 37 48.53 54 07 -1959 5 5034 300 3 01 5049525 0 054424 32 55000 460 550 5406.04 5497.21 55.03 040 -19.03 50044 3.0 112 5040531 t4 0442475 WS-2 553323 5.68 5.56 540..0 553030 5700 63. -18.76 NS 3.0 316 550534 14 6542498 500.0 160 556 5006.31 550001 04 ea 113 -1860 R5 3.0 3.25 5943544 80 054425 57 570.0 40.09 556 5905.02 5095.32 044 5]02 -1046 MS 10 13B 5.055761 6542579 WS115B 0.51 5776.62 1299 5.56 5680 00 5770 30 96.01 102 66 -11.tl HS 300 349 5949873.48 0417 0 500.0 1369 556 5702.75 5703.05 101.38 10.03 -14.4 45 3.00 3.52 5044378.80 05428 41 500.0 16.00 5.50 570.25 5889.55 127 30 134 11 _11 B7 45 3 0 365 5940004 98 054430 41 A-45 PTD Page 17 8/3/2012 CovIw9lNs YD 596! 11.044r n Te55054 150 VSEC IN EW TO MSDie lional 1190045 Casting 40) F) (1 IRI In/ 079 541 IN 41 CH6016 Di165.6.Index 0850 MUST 6000.00 14.95 5.55 5801.24 6094.54 158.18 105.17 9456 HS 3.00 3.74 5499636.00 064432.70 0443 607032 21.80 5.56 5960.00 605030 182.62 189.96 344 HS 300 367 594966593 65443470 0100.00 22.89 550 508147 507777 193.33 231.15 5.35 05 3.00 3.65 5940572.13 064435.56 620600 25.00 5.00 576.5 015.08 23.47 24152 -138 HS 3.65 4.01 5040712 93 064439.60 0300.00 26.00 555 5107.62 0.5702 278.67 287.48 365 05 3.00 4.12 540359.53 054442.19 5400.00 31.00 556 6254.05 5344.36 351.41 33144 392 145 300 122 6045806.5 06444502 End Curve 01030 3200 556 602.04 6353.14 33.02 325 845 135 3.00 323 5440.10 551445.44 0500.00 32.00 5.5 0338.47 0429.17 381.01 30916 1346 HS 000 4.28 5405196 65445007 0367 63567 3200 5.5 42000 651030 43197 440.62 0796 NS 000 4,34 5949912.01 65445395 55.00 32 00 5.5 0423.87 513.57 43.4 412.00 1918 05 0.00 4.34 544014.30 554454.12 370050 32.00 5.50 50640 804.78 45 5 400.4 23.32 115 0.00 4.30 5510457 13 0.345 17 05000 32.5 5.5 553.29 504.88 339.65 548.34 2955 HS 0.5 4.43 505590.00 05440.22 Fast 611CM2) 6966.88 32.00 5.5 6650.00 6240.30 57415 5935 31.0 HS 000 4.46 5950055.30 654464.93 650.00 32.5 5.56 667905 875.30 541.52 51 11 3150 HS 0.00 4.47 5550072.60 054400 27 750.00 32.5 5.5 0630* 553.10 643.4 653.57 3072 03 0_40 4.51 5050126.63 034470 32 715.00 3200 5.5 51).80 047.4 590 37 765.5 435 65 0.5 1.54 5050178 40 04474 37 7:30.5 3200 5.5 00325 7122.63 748 79 759.36 4890 045 0.5 15 5050231 30 054478 42 7300.00 32.5 5.56 7117.30 7107.5 51 22 81.10 54.12 65 0.5 161 5035284 13 064442 47 0441 7397.51 32.5 5.5 71005 716034 52.34 53.53 0013 HS 000 463 5950335.65 6544.542 745.00 32.5 5.56 7102.11 7192.41 53 5 364.0 5026 05 0.5 4_63 5050330 4 57445.52 7500.5 32.5 55 71591 727).21 9507 017.50 0430 HS 0.5 400 545034.75 654400.57 71840 750.29 32.00 5.56 725500 134530 946.06 959.93 6551 HS 000 4.80 595043220 65449383 75500 32.00 5.56 7171.= 730202 05.5 97033 0532 65 0.5 4.60 505442.5 5440.63 00500214.80? 763.07 32.5 556 727500 736130 660.53 37237 6= NS 000 4.6 550444.67 65440.78 77500 32.5 5.5 735.52 - 744692 1010.51 452307 745 HS 0.5 1.71 5050445.40 6744409 7127 77665 3200 5.56 741300 755.30 147.08 159.04 520 HS 000 4.72 5950531.89 65450147 750.5 32.00 5.515 7441.33 7531.5 105.36 107581 7074 HS 0.5 473 5650345.20 654502.73 795.00 32.5 5.50 7520.13 701513 1115.5 112836 403 65 0.5 4.75 555501.13 55455.78 900000 32.00 55 7010.4 770124 115.20 110130 805 HS 0.00 4 77 555053.4 814510.83 710!0(7)0, 8073.5 3280 554 76255 7715.30 1076.90 1190.4 9091 05 065 478 5950662.72 65451,50 9.0000 32.5 5.5 766.74 775.4 122.5 5214.4 55 14 45 0.00 4.70 505075.79 654514 5 7.6 110,4641 311687 32.5 5.5 77105 79530 1779.44 1.6291 9606 HS 080 4.80 5950713.67 654315.56 9200.30 32.60 5.55 7780.5 7071.85 127.5 02679 130 33 35 0.00 4 81 5450750.5` 651519 93 TA 821115 325 5.5 77905 7880.30 1276.90 029266 10090 its 000 4.91 55507655/ 65451938 9300 20 32.5 5.515 705.35 7953.5 1325.44 533553 15 46 HS 000 4.83 55508.2 46 554522 08 9400.00 32.00 356 7950.70 54095 137.01 135227 11054 HS 0.00 4.85 5650965.29 5452703 5560 72 32.5 5.5 803.06 8121 26 1438.33 1445.01 115 73 55 0 5 4.80 5955918.12 5453.5 7A7 0582 55 32.5 5.56 8155 7495 30 1473.67 7.8 57 119 97 040 000 4 5 5950501.76 65453.42 96500 32.0 5.50 811977 0.'0 C7 148270 744775 12086 05 0.00 4.80 5050070.4 5489.13 F.344(7.04 8653.34 32.00 55 8163.5 8255.30 1510.72 1525.19 123.40 005 000 489 55099514 654537 29 5700.00 32.00 55 920457 024.87 153619 15665.50 126.5 05 0.5 4.5 595102370 54530.16 730 0718.19 32.00 55 822000 8310.30 194672 1560.09 12693 815 400 490 551033.40 55453932 990065 325 5.5 929438 937558 1587,01 1553.24 13113 HS 0.5 4.51 551076.62 65143.23 736 9571.46 3200 5.54 835000 4440 30 1625.01 1640.4 13.86 035 000 492 551114.39 63434612 956000 32 5 5.55 0374.'0 0456 49 1640.4 105598 136.26 05 0.5 402 5031120.46 555447.26 1.5 0971.= 32.5 50 843300 852530 10774 189384 13 65 140 05 4.39 595116734 65455018 5000.5 32 5 5.56 45E.5, 5544 29 1555.47 170972 141.40 145 0 5 4.4 595 4182.25 5545133 7500 9050 32.00 35 8507'00 855'30 0722.75 173899 14,035 115 05 4.95 59512/2.20 6545362 T•7.44.9 905613 32.5 558 830110 855740 172221 173965 14431 N5 05 4.95 555121226 65453.53 75140 905963 32.5 55 853500 8623.30 1733.46 175600 5405 96 000 4.95 5957229.4 654554.96 01005 32.00 5.5 0543.70 53.80 1744.95 176197 1465 05 05 400 551235.12 054535.36 0904.53 32.5 556 551.90 5642.26 17244 175555 14703 5760 000 456 565130.21 054555.77 9000.00 42.5 715 523.64 9713.4 183328 552190 153.19 4465 1200 65 551255.78 5545581 754074651 9208.74 43.85 7.27 863140 872030 091023 080600 1334 4495 1280 5.07 567/3574 654X144 465 9247 74 48.51 773 85740 0747.30 053606 1854.4 157.0 4.078 125 5.11 595132870 63456453 467 3 9249 26 4170 55 00 839 30 1939.32 010097 167 78 4.635 12.80 511 5951329.83 64564 5 935.00 7471 8.28 8086.41 8770.)1 167853 000090 443.35 375 12.5 516 505135.30 5595544 4444 N 639452 333 83 8092.00 878244 180261 189906 166 37195 1200 if6 59513:3.91 0545699 060// 135.05 5.73 8.37 8645 878430 1105.51 135.94 1430 1061 1200 516 5951375.92 65457027 436 (� 8396 76 6277 8.09 8724 5 881430 1935.72 1974.80 171.87 1435 12.00 122 55142602 054576 01 430 V 0375.66 6383 3.35 8728.00 0819.30 1415 59396 77211 2495 325 322 3935433.60 5457789 0100.00 06.75 614 0736.77 9921.47 19567 •95140 170.5 33279 125 5.25 14145.5 574560 01 4105 04511 72.15 0.47 8754.00 8844.30 2007.76 2023.56 58241 3267 1200 528 55649769 6345865 420 05523 7337 9.4 375146 8847,30 201740 7072.69 18501 3.162 125 521 5515106 63458828 850030 78.71 5.4 9767.75 0374 08 2050.71 2076.30 1303' 3110 125 533 54155.5 5954 71 043,4121150 550435 4.5 1046 0777.01 047.31 215306 2107.48 30875 66 1200 5.40 556142.30 06405420 550.30 X..71 1052 8776.97 567.27 2150 88 2173.33 290 87 64 12.5 540 555146.17 94510 25 Curve 12130 5554 35 161.4 1772 975.5 550 03 2253 10 225491 777 5 5 54R 1200 5.47 5851740.05 04825 30 075.30 101.4 1240 875..40 8855.70 2256 52 220.5 22000 86 0995 12.5 5.47 55/.1746 80 064627 40 950.5 100.62 2472 9741.01 53 31 235 10 235.12 250•4 88 318 12.5 5.54 5951838 83 5156 01 0000.5 102.6 3732 9722.03 88'2.33 2440.24 241850 31000 01028 125 560 5551929.41 5470444 End 64548 542.53 103.5 4224 9712'3 5803.03 346.5 2478.56 33057 05 1200 5.62 56155.6 047300 Clove 12+15 097144 10255 07 24 5730 45 8746 75 251197 2490.34 95 52 174 748 0.00 5.03 5551877 17 54748.17 1050.5 6.13 4235 073'00 8191 36 2536.13 2520.15 37444 174 8R 12.00 5.04 551658.20 064707.5 4457513 1570.43 655 4.39 545.5 875.30 2002.67 2675.5 420.32 149044. 12.5 5.6 5552051.00 04810.30 1015.5 60.00 43.15 065.08 0780.38 523.222 255299 44248 14500 230 5.00 5562072.44 0563.16 105500 67.90 4215 6887.31 6741.01 2710.89 20551 51020 146071 25 372 542147.37 0455.36 1800.5 5.13 41.15 9702.55 8742 5 2754.33 2741_13 576'50 144.425 25 5.74 550323332 65445.20 End Curve 1034158 86.41 4073 0705.53 8765 03 2936.34 277253 5382 HS 25 575 54225.27 65450179 10903.00 591 40.73 671030 55.5 2588.23 2810.5 41.75 05 000 5.75 54235.05 65026.61 05542755 10490.48 641 40.73 8717.22 090752 205.17 25190 537.961 371R 0.5 5.78 505235.4 5053.70 10600.00 5.52 40.88 8118.20 695365 207).X0 2892.10 3544 3708R 25 5.76 5552376.4 6500230 445 7051 TD ‘ 062300 . 5.0 1 .5 418 8720 5 5 55 10 30 2008.15 25 . 72226 2.004 579 50523 .00 55107 38 Survey DM 61.03 Legal 0e9.550on: 644...6 m Sudaw 435 3 5510159 FEL 59 7119 9513E UM 4 5045471190 6!010.336 4-451043 105 031 151 FE 20 7118 0151.91 50520549 4 00 6818.380 045644 r0'0.141.3531 F31.15 FE 26 7110 613E1* • 55236495 50107.360 A-45 PTD Page 18 8/3/2012 bp ScIdumberger A-45(P7) I Prudhoe Bay Unit-WOA STRUC.03. A-PAD I Kam Zone Fox .$10.000000 Ng* 180,11.4 Z.1 DP NI 021. boo 1040e.e.11.a12 La, N'DINT713 Nome. 5010471 153.14S Gre 1,75.020W Slat A-45 NOP. .031,01,11.000/1314 Map Dec 20.009. 15 Sae 1Kr LOIN VI 14845 2 521 E..45 054445.010*V3 74041.100=.110 02I 4550211 9y0.m F04,27.3112 -1000 -500 0 500 1000 1500 A-45 T014/trr 3000 Cors2ri 44: 3000 A.1.5 FTE 1C110VO UM. End Cleve En0 Clove• 2500 4 2500 A45 T013 Cuero 12,1. ' 1 Cave 22'1 i' 2000 f 2000 A A-15T1_PS 245 A A rc 4616. 1111 1500 •2 V V V 1000 .4. 4 1000 500 500 End Curve Curve 3400 End Claw •• 0 02 i 0 Cry 2/100 KOP..Cov 1.100 RTE -1000 -500 0 500 1000 1500 c« W Scale=1:500(ft) E >>> A-45 PTD Page 19 8/3/2012 BP Anticollision Report Company: North America-ALASKA-BP Local Co-ordinate Reference: Well A-45 planning Project: Prudhoe Bay TVD Reference: WELL @ 90.30ft(Generic Rig) Reference Site: PB A Pad MD Reference: WELL @ 90.30ft(Generic Rig) Site Error: 0.00ft North Reference: True Reference Well: A-45 planning Survey Calculation Method: Minimum Curvature Well Error: 0.00ft Output errors are at 1.00 sigma Reference Wellbore A-45 plan current Database: EDM 16-ANC Prod-WH24P Reference Design: A-45 plan#7 Offset ND Reference: Offset Datum Reference A-45 plan#7 Filter type: GLOBAL FILTER APPLIED:All wellpaths within 200'+100/1000 of refer Interpolation Method: MD Interval 25.00ft Error Model: ISCWSA Depth Range: Unlimited Scan Method: Tray.Cylinder North Results Limited by: Maximum center-center distance of 1,248.03ft Error Surface: Elliptical Conic Survey Tool Program Date 7/3/2012 From To (ft) (ft) Survey(Wellbore) Tool Name Description 43.30 500 00 A-45 plan#7(A-45 plan current) GYD-GC-SS Gyrodata gyro single shots 500.00 2,500.00 A-45 plan#7(A-45 plan current) MWD MWD-Standard 2500.00 3283.00 A-45 plan#7(A-45 plan current) MWD+IFR+MS MWD+IFR+Multi Station 3.283.00 4.800.00 A-45 plan#7(A-45 plan current) MWD MWD-Standard 3283.00 0,060.00 A-45 plan#7(A-45 plan current) MWD+IFR+MS MWD+IFR+Multi Station 9.060.00 10.523 60 A-45 plan#7(A-45 plan current) MWD MWD-Standard 9,060.00 10.523.60 A-45 plan#7(A-45 plan current) MWD+IFR+MS MWD+IFR+Multi Station 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 A Pad A-04-A-04-A-04 4,165.28 4,450.00 384.33 58.21 326.22 Pass-Major Risk A-06-A-06-A-06 4.015.30 4,275.00 79.30 57.16 22.14 Pass-Major Risk A-09-A-09-A-09 4,342.56 4.350.00 514.81 62.56 452.27 Pass-Major Risk A-09-A-09A-A-09A 4,342.56 4,350.00 514.81 62.56 452.27 Pass-Major Risk A-10-A-10-A-10 425.76 425.00 361.46 7.84 353.62 Pass-Major Risk A-11-A-11-A-11 3,815.33 3.850.00 196.47 68.58 128.07 Pass-Major Risk A-12-A-12-A-12 337.03 325.00 141.16 6.72 134.43 Pass-Major Risk A-12-A-12A-A-12A 337.03 325.00 141.16 6.72 134.43 Pass-Major Risk A-13-A-13-A-13 10.280.05 9.400.00 362.36 409.93 -44.26 FAIL-Major Risk A-25-A-25-A-25 3.424.99 4.150.00 146.53 74.71 71.83 Pass-Major Risk A-25-A-25A-A-25A 3,430.19 4.150.00 146.61 74.82 71.78 Pass-Major Risk A-25-A-25B-A-25B 3,423.21 4.150,00 146.55 74.68 71.90 Pass-Major Risk A-33-A-33-A-33 336.09 325.00 306.39 7.18 299.21 Pass-Major Risk A-34_DIMS-A-34-A-34 386.80 375.00 196.72 6.68 190.04 Pass-Major Risk A-34A-A-34A-A-34A 3.775.38 3,775.00 219.34 60.30 159.08 Pass-Major Risk A-35-A-35-A-35 4,732.71 4.725.00 121.72 54.60 67.18 Pass-Major Risk A-39-A-39-A39 447.52 450.00 506.00 1.53 498.47 Pass-Major Risk A-39-A-39A-A-39A 447.52 450.00 506.00 7.25 498.75 Pass-Major Risk A-39-A-39A-Plan 5 447.52 450.00 506.00 7.25 498.75 Pass-Major Risk A-43-A-43-A-43 2,773.12 2,950.00 353.64 70.04 285.90 Pass-Major Risk A-45 PTD Page 20 8/3/2012 Page 1 of 1 Schwartz, Guy L (DOA) From: Mammadov, Famil [famil.mammadov@bp.com] Sent: Thursday, August 16, 2012 3:53 PM To: Schwartz, Guy L(DOA) Subject: RE: A-45(PTD 212-121) Guy, Ideally, our preference is to drill without the paddle to the base of permafrost(which is at 2043' MD). However, having confirmed with my colleagues we came to conclusion that 1000' will be sufficient. As for the Parker 272 rig schedule, it is quite uncertain. We are trying to optimize our rig moves between the pads. Spudding A-45 might be either 2nd or 4th well drilled from Parker 272. Please let me know if you need any further information Regards, Famil From: Schwartz, Guy L(DOA) [mailto:guy.schwartz@alaska.gov] Sent: Thursday, August 16, 2012 3:39 PM To: Mammadov, Famil Subject: A-45 (PTD 212-121) Famil, Can you clarify the expected depth to which the paddle would be removed during the surface hole? Typically BP asks for 1000' md. Also, as this is the second planned well for Parker 272 it may still be on a one week BOP test cycle until the rig has proven track record of acceptable tests. Guy Schwartz Senior Petroleum Engineer AOGCC 793-1226 (office) 444-3433 (cell) 8/16/2012 TRANSMITTAL LETTER CHECKLIST WELL NAME Prudhoe Bay Unit A-45 PTD 212121 X Development Service Exploratory Strat_granh3e Test Non-Conventional Well FIELD: PRUDHOE BAY POOL: PRUDHOE BAY OIL POOL Circle Appropriate Letter/Paragraphs to be Included in Transmittal Letter Ann-ONS CHECK (OPTIONS) WHAT TEXT FOR APPROVAL LETTER APPLIES MULTI LATERAL The permit is for a new wellbore segment of existing well , Permit No. (if last two digits in API No. 50- - - . Production should API number are continue to be reported as a function of the original API number between 60-69) stated above. PILOT HOLE 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 ( PI-I) and /API number (50- - - ) from records, data and logs acquired for well SPACING The permit is approved subject to full compliance with 20 AAC 1 EXCEPTION 25.055. Approval to perforate andproduce !-inject is contingent iinon iscifanee of a rnncervatinn 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. Should conventional core be acquired in this n i r r i well, representative chip samples from each foot of core must be submitted to the Commission in accordance with 20 AAC 25.071. 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