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211-119
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. Qi L - IL9 Well History File Identifier Organizing (done) El Two-sided ❑ Rescan Needed RE AN: OVERSIZED: NOTES: Color Items: ❑ Maps: rayscale Items: ❑ Logs: El Poor Quality Originals: ❑ Other: ❑ Other: BY: ASEW Date: / /s, imp Project Proofing BY: aj Date: I /s/ ttl P Scanning Preparation aration x 30 = + = TOTAL PAGES ca. 7 (Count does not include cover sheet) BY: Maria Date: (e.14//q- /s/ � Production Scanning Stage 1 Page Count from Scanned File: a.,(((count does include cover sh ) P.•- Count Matches Number in Scanning Preparation:aration: YES NO PBY: ,l. - Date: (6-1114.JiLl. /s/ Mr Stage I 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 c 0 Ca- ‘- < < < M ca Z Z Z NS6 N Z 0 } } } 4110 N ifitaT o) U y ai o >- ! s >, O m E m c u' N E m < O N O y O Z a U L L O \------ Q o o -a 2 2 C > o o U 75 g d U 0 0 Z 2i rn a) Z N` j o - Z Z Q I Y OU 2 2 10 hi U m } } p a) Qccs is a O m a O ii C a O a O U o N m 0 To coEtm- ca w I a) t NNz ° o) L10 '� ca E a N E Wil. Ill - N W 0 m N U a C o n m d E _j Ca ZN 9 N `p = o rn CI) (f) < ui R' Z 0 O o> a c —.J a) a E a «° R a 0 --0.0= 0 N 0,:6 c U U O M C ZI d J N O y Cl) a) ON C o rn TO E Q J N Z I 0 as U_t.0 el J a NII >- >- } Q C O r 6 H O C N co ca _O C Z ° ( m CO c ani E m c o h E W cu O a> t c N 2 '/� coN coN U co c A C C o QC co a m a U a Q ZI g m O Z E o L T O U E 0 8' 0 2 Co. co -o -1 ' Z 1 aa) E c6 o Z ct Z O uo cn 0 Z d _0 O W g t CO O - N F " :° E ° N a r Q Z L C f6 a W E O_ a N O O p W O Z ct) W O d CL 1- f6 Q N d' 0 C > Z O '_LL N Z H N Gl o Q O U _ _ N Q O C «ici L 0 W LL N O d 2 - U ca co 2 E - m Q ai J m m 0 U O E o E E 0 O H W o a o ° oma 0 a v v McMains, Stephen E (DOA) From: Lastufka,Joseph N <Joseph.Lastufka@bp.com> Sent: Thursday,June 27, 2013 9:19 AM To: McMains, Stephen E (DOA) Cc: McMullen, John C Subject: W-12AL2 PTD#211-119 Steve, We would like to withdraw this Permit to Drill,there are no plans to move forward with the permitted lateral. Please let me know if you have any questions or require any additional information. Thank you, Joe Lastufka Alaska Wells Technologist Cell: (907) 227-84961 Office: (907) 564-4091 Irv.i 772 AEI BP Exploration AlaskaI900 E. Benson Blvd.IRoom: 788DIAnchorage,AK 1 • STATE OF ALASKA RECEIVED ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVAL JAN 2 0 zoi? 20 AAC 25.280 3�aslra L)i(u Gala :ons. (•� SSi0n 1. Type of Request: ❑Abandon 0 Plug for Redrill 0 Perforate New Pool 0 Repair Well 0 Change Approved rogf h1 ❑Suspend 0 Plug Perforations 0 Perforate 0 Pull Tubing 0 Time Extension - ®Operations Shutdown 0 Re-Enter Suspended Well 0 Stimulate 0 Alter Casing 0 Other 2. Operator Name: 4. Current Well Class: 5. Permit To Drill Number BP Exploration(Alaska) Inc. ® Development 0 Exploratory 211-119 • 3. Address: 0 Service 0 Stratigraphic 6. API Number: P.O. Box 196612,Anchorage,Alaska 99519-6612 50-029-22023-61-00 - 7. If perforating,closest approach in pool(s)opened by this operation to nearest 8. Well Name and mber: property line where ownership or landownership changes: PBU W-12AL2 • Spacing Exception Required? 0 Yes ®No 9. Property Designation: 10.Field/Pool(s): _ ADL 028263&047452 Pru• oe Bay Field/Prudhoe Bay Oil Pool 11. PRESENT WELL CONDITION SU ARY Total Depth MD(ft): Total Depth ND(ft): Effective Depth MD(ft): !Effective epth TVD(ft): Plugs(measured): Junk(measured): 20888' 9049' %I 19094' 8984' _ None None Casing Length Size Ale TVD Burst Collapse Structural Conductor 110' 20" r r' Surface 2987' 13-3/8" .27' 2.: ' 4• I 227' Intermediate 12869' 9-5/8" ` / •I ' :4 4' .:71 47.1 Production Liner 830' 7" 12747'- 13577' 8344'-8802' 7240 5410 Liner 7478' 4-1/2" A 1341.'-21::8' 8724'- •I •' :4 I 7 '0 Ati A Perforation Depth MD(ft): Peif n a-IND( v Tubing Size: Tubing Grade: Tubing MD(ft): None for W-12AL2 \ / 4-1/2", 12.6# L-80 13411' Packers and SSSV Type: 7"x 4-1/2"E. d •'packer Packers and SSSV 13355'/8698' MD(ft)and TVD(ft): 12. Attachments: 13.Well Class after proposed work: ® Description Summary. Proposal 0 BOP Sketch 0 Detailed Operations ' ogram 0 Exploratory 0 Development 0 Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: Immediately 0 Oil - 0 WINJ 0 WDSPL 0 Plugged 16. Verbal Approval: Date: 1/19/2012 0 Gas ❑GINJ ❑GSTOR ❑Abandoned 0 WAG 0 SPLUG 0 Suspended Commission Representativ : Guy L. Schwartz 17. I hereby certify that the for-going is true and correct to the best of my knowledge. Contact Matt Ross,564-5782 Printed Name Joh 4 Ay-' /,4, / , Title En ineering Team Leader Prepared By Name/Number: Signature Phone 564-4711 Datev--,-- ,/ Terrie Hubble,564-4628 Commission Use Only Conditions4proval: Notify Commission so that a representative may witness 52,- /��7 O Sundry Number: l.�C� ❑ Plug Integrity 0 BOP Test 0 Mechanical Integrity Test 0 Location Clearance Other: Subsequent Form Required: R8DMS AN 2 4 2012 APPROVED BY Approved By: rr COMMISSIONER THE COMMISSION Date Form 10-403 Revise 01`/2 10 Submit In Duplicate w RIGINAL ,�/�� v Hubble, Terrie L From: Ross, Matthew Sent: Thursday, January 19, 2012 4:31 PM To: Hubble, Terrie L Subject: W-12 Operational Shutdown We operationally shutdown on W-12 for the following reasons. We do not have the required equipment, specifically a coiled tubing reel with sufficient length to drill the second lateral, AL2 on W-12. In the planning phase of the well, we did have two coiled tubing reels specifically built to meet the extended length required to drill both laterals. However, due to equipment failure for the first reel &human error involving lack of communication for the second reel we do not have the required equipment to complete the tasks of adding 200' of perforations nor to start drilling the AL2 portion of W-12. We do plan to return to W-12 and drill the second lateral.This process to acquire one more reel of sufficient length from the manufacture will require time - 4 months. It will take approximately 3 to 4 weeks to respool our current reel that would not fit into the rig, this involves acquiring a spooling jig from Tenaris in Texas &having it shipped to Schlumberger's yard in Deadhorse. There are numerous issues in construction &transporting due to the shear size of the reels. To transport the reel from Tenaris's yard in Texas it involves specially built floats (lowboy trailer). All reels this large in size involve transporting it on land to Seattle then on a barge to Whittier. In 2009 the Whittier tunnel had a 188" height limit requirement on the reel spool. Suffice to say that only a 188" OD reel spool would fit on a specially built lowboy trailer going through the tunnel. Ever since then our coiled tubing reels have been limited to 96"wide by 188" in height. Both Nordic CTD rigs are limited to 96" in width & 188" in height for the acceptance of the reel spool size. Our standard size of reel is 180" We ordered the reel for W-12 in 2011. However, in late 2010 the Whittier tunnel was further limited by height restrictions thereby reducing our effective reel spool height to 180". Tenaris was aware of the height restrictions during the transport of the reel as they are required to buy the needed road permits for the transportation of the reel.This was not communicated to Schlumberger. When Schlumberger ordered a 25,000'coiled tubing spool from Tenaris and in order to compensate for the reduction in height, a increase in width was the only option. Again, this was not communicated to Schlumberger. Tenaris sent a spool measuring 105"wide by 177" in height that had 25000' of coiled tubing on it.The 105" wide coiled tubing spool will not fit inside the rig. Schlumberger is looking into bypassing Whittier&having the reels shipped to Anchorage or Valdez thus allowing the reels to be 188" in height thereby avoiding the issue on our extended reach CTD wells. Matt Ross 1 TREE= 4-1/16"FMC VJ...'1 2AL 1 & L2, SAFE. NOTES:1570WELL ANGLE-70 @ 13705 _ ** WELLHEAD= FMC PERFS @ 15700'-15940'POSSIBLY SQZ(05/14/07) ACTUATOR= BAKER &MILLED OUT(02/24/09)-SEE AWGRS*** KB.ELEV= 83.67' Operation Shutdown BF.ELEV= 54.37' KOP= 880' Max Angle= 98 @ 14783' Datum MD= 13782' ' 2159' —14-1/2"HES X NIP,ID=3.813" Datum TVD= 8800'SS GAS LIFT MANDRELS ST MD ND DEV TYPE VLV LATCH PORT DATE 7 3873 3198 r 52 MMG DOME RK 16 09/17/07 13-3/8"CSG,68#,L-80, ID=12.415" H 3079' 6 5965 4409'55 MMG DMY RK 0 11/22/98 El 5 7408 5226'56 MMG DOME RK 16 09/17/07 4 8735 5989 r 54 MMG DMY RK 0 11/22/98 Minimum ID = 3.80" @ 13399' 3 10062 678952 MMG DOME RK 16 09/17/07 4-1/2" HES XN NIPPLE milled out 2 11390 7597 F 57 MMG SO RK 22 09/17/07 1 12471 8197 r 59 MMG DMY RK 0 03/22/07 12747' —TOP OF BKR TIEBACK SLV,ID=7.50" /; J 12754' —19-5/8"X 7"BKR ZXP PKR,ID=6.188" 12760' —9-5/8"X 7"BKR HMC HGR, ID=6.188" TOP OF CEMENT 12710' ¢sv H 13070'] 9-5/8"CSG,47#,NT-80S, ID=8.681" — 14075' \ 9-5/8"MILLOUT WINDOW(W-12A) 12905'-12965' PERFORATION SUMMARY \ \ 13411' — 4-1/2"TBG, 12.6#, L-80, .0152 bpf, ID=3.958" REF LOG: BHI CCL/GR ON 1/10/12 I I 13344' 1—4-1/2"HES X NIP, ID=3.813" ANGLE AT TOP PERF: 93 @ 16775' Note: Refer to Production DB for historical perf data Z Z 13355' 1—7"X 4-1/2"BKR S-3 PKR. ID=3.875" SIZE SPF INTERVAL Opn/Sqz DATE 2-7/8" 16775- 1752 Open 01/10/12 I I 13379' 1—4-1/2"HES X NIP,ID=3.813" ' 1— 4-1/2"HES XN NIP, ID=3.80"(milled out) 13410' }— 7"X 4-1/2"BKR TIEBACK SLV, ID5.25" 4 13411' j--4-1/2"WLEG, ID=3.958" 13423' H ELMD TT LOGGED 07/30/99 13416' 1—7"X 5"BKR ZXP LTP w/HGR,I0=4.458" *SEE SAFETY NOTE FOR DETAILS 7"LNR,29#,L-80,MOD, .0371 bpf, ID=6.184° — 13577' 14574' 1—4-1/2"MARKER JT 15609' H4-1/2"MARKER JT L1: 16774' - 17096' M Cement Milled Out to Full Liner ID Drift r , Re-perforate 750 ft Zn 4 r - Mill cement to 19,094' 4-1/2"LNR, 12.6#,L-80,NSCT, .0152 bpf, ID=3.958" — 20888' •�••4 20800' 1— PBTD DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT V 1990 ORIGINAL COMPLETION 02/24/09 RLM/PJC MILL CMT PLUG WELL: W-12A 11/22/98 JJONES SIDETRACK NABORS 18E 03/01/09 PJC DRAWING CORRECTIONS PERMIT No: • 05/03/07 CJA/PJC SET CBP 01/19/11 MR CTD SIDETRACK API No: 50-029-22023-01 05/13/07 JGM/PJC CEMENT PLUG SEC 21,T11 N,R12E, 1542'SNL&1196'WEL 09/17/07 DAV/PJC GLV C/O 01/14/09 CJA/SV MILL CMT PLUG(12/18/08) BP Exploration(Alaska) W-12AL 1 & AL2 Page 1 of 1 Schwartz, Guy L (DOA) From: Schwartz, Guy L(DOA) Sent: Monday, January 23, 2012 3:55 PM To: 'Ross, Matthew' Cc: Saltmarsh,Arthur C (DOA) Subject: RE: W-12AL1 &AL2 (211-119) Matthew, I am returning the sundry for OP shutdown on W-12AL2 as not needed. You did not start this permitted lateral so an Operation Shutdown is not required. The PTD remains active. Guy Schwartz Senior Petroleum Engineer AOGCC 793-1226 (office) 444-3433(cell) From: Schwartz, Guy L(DOA) Sent: Thursday, January 19, 2012 8:35 AM To: 'Ross, Matthew' Subject: RE: W-12AL1 &AL2 (211-118) Ross, Per our conversation please submit a 403 sundry with an operational shutdown for the lateral AL1. Hold off on a 10-404 till you have a better idea of how long it will be till you get back on the well to finish up the lateral. The motherbore can still be perfed and put on production as you see fit. If it looks like longer than 60 days till you restart work then submit a 10-404 report on the drilling work to date. Guy Schwartz Senior Petroleum Engineer AOGCC 793-1226 (office) 444-3433 (cell) From: Ross, Matthew [mailto:rossmo@BP.com] Sent: Thursday, January 19, 2012 7:29 AM To: Schwartz, Guy L(DOA ) Subject: W-12AL1 &AL2 Guy; We do not have the required equipment, specifically a coiled tubing reel with sufficient length to drill the second lateral, AL2 on W-12. In the planning phase of the well,we did have two coiled tubing reels specifically built to meet the extended length required to drill both laterals. However, due to equipment 1 failure for the first reel &human error for the second reel we do not have the required equipment to start drilling AL2. We do plan to return to W-12 and drill the second lateral. This process to acquire two more reels of sufficient length from the manufacture will require time. I need guidance on how to leave W-12 (operational shutdown or otherwise). Many thanks. Matt Ross 980-0552 1/23/2012 SEAN PARNELL, GOVERNOR ALASKA OIL AND GAS 333 W.7th AVENUE,SUITE 100 CONSERVATION COMMIISSION 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 W-12AL2 BP Exploration (Alaska), Inc. Permit No: 211-119 Surface Location: 1542' FNL, 1196' FEL, SEC. 21, T11N, R12E, UM Bottomhole Location: 2544' FNL, 3806' FEL, SEC. 33, T11N, R12E, UM Dear Mr. McMullen: Enclosed is the approved application for permit to re-drill the above referenced development well. The permit is for a new wellbore segment of existing well PBU W-12A, Permit No 198- 182, API 50-029-22023-01. Production should continue to be reported as a function of the original API number stated above. 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 ommission order, or the terms and conditions of this permit may result in the re .cation or suspension of the permit. O .4. p• . 4ioner DATED this IL-day of September, 2011. 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 RECEIVED ALAS )IL AND GAS CONSERVATION COMMI )N SEP 01 2011 PERMIT TO DRILL �,�� 20 AAC 25.005 (}� 1 a.Type of work: 1 b.Proposed Well Class: likir®Development Oil 0 Service-Willi 0 Single Zone • p clfy i� eafilnitSiOn PM ❑ Drill 0 Redrill 0 Stratigraphic Test 0 Development Gas 0 Service-Supply 0 Multiple.Zone 0 Coalbed Gilajalsailydrates ❑ Re-Entry 0 Exploratory 0 Service-WAG 0 Service-Disp 0 Shale Gas 2. Operator Name: 5.Bond: 0 Blanket 0 Single Well 11. Well Name and Number: BP Exploration(Alaska)Inc. Bond No. 6194193 PBU W-12AL2 3. Address: 6. Proposed Depth: 12.Field/Pool(s): P.O.Box 196612,Anchorage,Alaska 99519-6612 MD 17005' , TVD 8879'ss Prudhoe Bay Field/Prudhoe 4a. Location of Well(Governmental Section): 7. Property Designation(Lease Number): Bay Oil Pool Surface: ADL 028263&047452 , 1542'FNL, 1196'FEL,SEC.21,T11N,R12E, UM Top of Productive Horizon: 8. Land Use Permit: 13. Approximate Spud Date: 658'FNL,2112'FEL, SEC.33,T11N, R12E, UM November 15,2011 Total Depth: 9.Acres in Property: 14.Distance to Nearest Property: 2544'FNL,3806'FEL, SEC.33,T11N, R12E, UM 2560 3,117' 4b. Location of Well(State Base Plane Coordinates-NAD 27): 10.KB Elevation above MSL: 83.67' feet 15.Distance to Nearest Well Open Surface: x- 612049 y-5958715 Zone- ASP4 GL Elevation above MSL: 53.17' feet to Same Pool: 1490' 16.Deviated Wells: Kickoff Depth: 15760' feet 17.Maximum Anticipated Pressures in psig(see 20 AAC 25.035) Maximum Hole Angle: 95 degrees Downhole: 3441 Surface: 2561 18. Casing Program: Specifications Top-Setting Depth-Bottom Quantity of Cement,c.f.or sacks Hole Casing Weight Grade Coupling Length MD TVD MD ND (including stage data) 4-1/4" 2-7/8" 6.5# L-80 STL 1255' 15750' 8908'ss, 17005' 889Tssjincemented 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 ND(ft): Junk(measured): 20888' 904$' 15850' 8987' 15850' None Casing Length Size Cement Volume MD ND Conductor/Structural Surface 110' 20" 110' 110' Intermediate 298T 13-3/8" 4338 sx Coldset II 302T 2683' Production 12869' 9-5/8" 1211 sx Class'G' 12905' 8434' Liner 830' 7" 151 sx Class'G' 12747'- 13577' 8344'-8802' Liner 7478' 4-1/2" 728 sx Class'G' 13410'-20888' 8724'-9049' Liner(W-12AL1) 1060' 2-7/8" Uncemented Slotted Liner 16765'-17825' 8848'-8837' Perforation Depth MD(ft): All Peres Squeezed Off Perforation Depth ND(ft): N/A 20.Attachments: 0 Property Plat 0 BOP Sketch 0 Drilling Program 0 Time vs Depth Plot 0 Shallow Hazard Analysis 0 Diverter Sketch 0 Seabed Report 0 Drilling Fluid Program ®20 AAC 25.050 Requirements 21. Verbal Approval: Commission Representative: Date: 22. I hereby certify that the f.°•oin• is true and correct. Contact Eli Vazquez,564-5918 Printed Name Jo l Mc - I /JC/,� Title Engineering Team Leader / ill \ Prepared By Name/Number.Signature7 jPhone 564-4711Date Teme Hubble,564-4628 Commission Use Only // Permit To Dril API Number: Permit Ap ro al Datp: See cover letter for Number: - ///4,950-029-2202341-00 k.a % 1 other requirements Conditions of Approval: If box is checked,well not be used to explore for,test,or produce coalbed methane,thgas hydrates,or gas contained shales: 11 jt 3500 dos` kx'P / 574-- Other: ` Samples Req'd: ❑ es I No Mud Log Req'd: ❑ Yes tINo -IEZ5-oo �,f; /4,rtta.. � -44't�K*-.-..) HA Measures: 0/Yes 0 No a -. ional Survey Req'd: "Yes 0 No af, Date 9,, // APPROVED BY THE COMMISSION COMMISSIONER Form 10-401 Revised 07/2009 This permit is valid for 24 months from the date o .. ' AAC 25.00 g)) Submit In Duplicate ORIGI A , ....- - ...., ,, To: Alaska Oil&Gas Conservation Commission From: Eli Vazquez CTD Engineer 0 bp Date: August 31st, 2011 Re: W-12A L1 &W-12A L2 PTD Request Approval is requested for a permit to drill a CTD sidetrack from well W-12A. Well W-12A was originally completed in April 1990 and sidetracked in December 1998. Water broke through in this well in 2002 and it was identified to be coming from a fault in the heel of the well where the liner had been eroded due to the water. In 2007 a bridge plug was set at 15,050' and to serve as base for the cement squeeze job to abandon the perforations above this depth and liner holes. The cement squeezed into the liner holes and perfs which shut off the water but the plug failed and the cement got below the bridge plug, filling the liner with cement. The well is in sound mechanical condition. It passed an MIT-IA to 3000 psi and MIT-OA to 2000 psi (August 2011). The August 2011 Caliper shows the 4'/z" tubing to be in good to poor condition with respect to corrosive damage, with a maximum penetration of 44% recorded in area of corrosion in joint at 5,504' MD and a maximum cross sectional wall loss of 20% recorded at 5,979' MD. The calliper also shows heavy deposits from 10,859' MD to 11,393' MD restricting the I.D. to a minimum of 3.11 in at 11,050' MD. Service coiled tubing units have successfully milled the plug and cement down to 15,850' and where weight on bit became a problem and no further milling was possible. There is no flow from perforations that have been exposed after milling which indicates the failed cement job also squeezed the perforations below the bridge plug. The proposed CTD Sidetrack will mill the existing cement to 20,450, recomplete the well and drill two laterals. Combined, the two laterals will provide access to -2000' of upper Zn 4 oil column and add significant rate. The perforations will restore another 2000' of upper Zn 4 production. The multilateral sidetrack, W-12A L1 &W-12A L2, is scheduled to be drilled by Nordic 2 starting on December 1st 2011. The pre rig includes milling the XN Nipple and deposits inside 4%"tubing. The Nordic 2 drilling rig will then move on and mill the existing cement down to 20,450' md, re-perforate 2000' of Zn 4 in parent W-12A well and drill two laterals via mechanical whipstocks that will be retrieved once the 2-7/8" slotted liners have been run. The following describes the planned work. A schematic diagram of the proposed sidetrack is attached for reference. CTD Sidetrack Summary Pre-CT Rig Work: The pre CTD work is planned to begin November 15th, 2011. 1. W Check tubing hanger LDS. 2. W PPPOT-T to 5000 psi i 3. C Mill heavy deposits from 10,859' MD- 11,393' MD and XN Nipple at 11,399' MD. PAD 4. C Drift for retrievable whipstock to-14,000' MD. 5. V PT tree(MV,SV,WV) 6. D Bleed wellhead pressures down to zero. 7. D Bleed production flow lines and GL lines down to zero and blind flange. 8. 0 Remove wellhouse, level pad. Rig Sidetrack Operations: (Scheduled to begin on December 1st, 2011 using Nordic Rig 2) 1. MIRU Nordic Rig 2. 2. NU 7-1/16" CT Drilling BOPE and test. 3. Mill —4600 ft of cement inside 4W liner. 4. Perforate 2000'of Zn 4 in parent W-12A. 5. Run caliper for proper whipstock setting. 6. Set retrievable 4W whipstock at 16,755' md. ztl-Iib 7. Mill 3.80"single string high side window in 4W12.6#L-80 production liner from retrievable whipstock. \ , ,, , DLSturn and12 DLSlateral wi h 4 . bi-center bit to 17 825 MD. 8. Drill 40 t / L , 9. Run 2-7/8"slotted liner and drop 10 ft outside window. 10 Set2nd retrievable 4W whipstock at 15.740'md. 11. Mill 3.80"single string high side window in 4W12.6#L-80 production liner from retrievable whipstock. 12. Drill 40 DLS turn and 12 DLS lateral with 4W bi-center bit to 17,005' MD. t. 13. Run 2-7/8"slotted liner and drop 10 ft outside window. 14. Retrieve both whipstocks. 11"5y 15. Freeze protect well to 2200'ND. I ' D 16. Set BPV. ND 7-1/16" BOPE stack. Freeze protect tree and PT tree cap to 3500 psi. 02ff 17. RDMO Nordic 2. Mud Program: • Well kill: 8.6 ppg seawater/brine. • Milling/drilling: 8.6 ppg Geo-VIS for milling window and drilling. Disposal: • All Class II drilling and completion fluids and all other Class II wastes will go to Grind &Inject at DS 4. • All Class I wastes will go to Pad 3 for disposal. Hole sizes: 4Y." hole: 16,755' and— 17,830' and (W-12A L1) 4W hole: 15,740' and— 17,005' and (W-12A L2) Casing Program: Slotted Completion • 2-'/8", L-80 6.5 lb/ft STL slotted liner, W-12A L1 16,765' and—17,825' and • 22/8", L-80 6.5 lb/ft STL slotted liner, W-12A L2 15,750' and—17,005' and ■ Not cemented. Well Control: • BOP diagram is attached. • Pipe rams, blind rams and the CT pack off will be pressure tested to 250 psi and to 3500 psi. • The annular preventer will be tested to 250 psi and 3000 psi. Directional • See attached directional plan. Maximum planned hole angle for W-12A Ll is 98° at 16,795' and and 95° at 16,190' and for W-12A L2. • Magnetic and inclination surveys will be taken every 30 ft. No gyro will be run. • Distance to nearest property—2,823'for W-12A L1 and 3,117'for W-12A L2. • Distance to nearest well within pool —2,718' from W-12A L1 to W-10A and 1,490' from W-12A L2 to W- 10A. Anti-Collision • W-12A L1 o None • W-12A L2 o None Logging • MWD directional, Gamma Ray and Resistivity logs will be run over all of the open hole section while drilling. • Hazards • Most recent H2S level on W-12A is 15 ppm recorded on September 10, 2011. • The maximum recorded H2S level on W Pad is 60 ppm on well W-01 (August 16th, 2005). • No fault crossing is expected for both laterals. • The lost circulation risk in the W-12A L1 & L2 is medium to low due to uncertainty of potential losses at unmapped faults /fractures. Well trajectory designed to avoid crossing any mapped faults and possible fault damage zones for both laterals. Reservoir Pressure • The reservoir pressure is estimated to be: o W-12A L1: 3,373 psi at 8,800 TVDss(7.37 ppg equivalent) based on offset pressures. o W-12A L2: 3,441 psi at 8,800 TVDss(7.52 ppq equivalent) based on offset pressures. • Max expected surface pressure with gas (0.10 psi/ft)to surface is: o W-12A L1: 2,493 psi. o W-12A L2: 2.561 psi. 1t- Eli Vazquez Coiled Tubing Drilling Engineer CC: Well File Sondra Stewman/Elizabeth Barker TREE_ • 4-1/16"FMC SAFE- _ NOTES: WELL ANGLE-70°@ 13768'*** WELLHEAD= FMC 2 A PERFS @ 15700'-15940'POSSIBLY SOZ(05/14/07) ACTUATOR= BAKERVV &MILLED OUT(02/24/09)-SEE AWGRS'"" KB.ELEV= 83.67' BF.ELEV= 54.37' KOP= 880' Max Angle= 98 @ 14783' Datum MD= 13782' I I 2159' -14-1/2"HES X NP,ID=3.813" Datum ND= 8800'SS GAS LIFT MANDRELS ST MD ND DEV TYPE VLV LATCH PORT DATE 7 3873 3198 52 MMG DOME RK 16 09/17/07 13-3/8"CSG,68#,L-80, ID=12.415" —{ 3079' 6 5965 4409` 55 MMG DMY RK 0 11/22/98 El 5 7408 _5226` 56 MMG DOME RK 16 09/17/07 4 8735 5989'54 MMG DMY RK 0 11/22/98 Minimum ID = 3.725" @ 13399' 3 10062 6789'52 MMG DOME RK 16 09/17/07 4-1/2" HES XN NIPPLE 2 11390 7597`57 MMG SO RK 22 09/17/07 1 12471 8197"59 MMG DMY RK 0 03/22/07 J { 12747' —ITOP OF BKR TIEBACK SLV. ID=7.50" 12754' —19-5/8"X 7"BKR ZXP PKR,ID=6.188" T. TOP OF CEMENT 12710' 12760' H9-5/8"X 7"BKR HMC HGR,ID=6.188" EZSV -1 13070'J 9-5/8"CSG,47#,NT-80S,ID=8.681" —I 14075' N9-5/8"MILLOLIT WINDOW(W-12A) 12905'- 12965' PERFORATION SUMMARY 13411' H 4-1/2"TBG, 12.6#,L-80,.0152 bpf,ID=3.958" REF LOG:ANADRILL ME RESISTIVITY ON 10/04/98 ANGLE AT TOP PERF: 83 @ 14255' 1 1 13344' H4-1/2"HES X NIP,ID=3.813" Note:Refer to Production DB for historical perf data g S 13355' H7"X 4-1/2"BKR S-3 PKR,ID=3.875" SIZE SPF INTERVAL Opn/Sqz I DATE 2-7/8" 4 14255-14275 S 05/13/07 I I 13379' H4-1/2"HES X NIP,ID=3.813" 2-7/8" 4 14950-14970 S 05/13/07 , ' L 13399' H4-1/2"HES XN NIP,ID=3.725" 1 2-7/8" 4 "15700- 15740 GS? 05/04/02 L_13410' H 7"X 4-1/2"BKR TIEBACK SLV, 105.25" 2-7/8" 4 "15780- 15820 C/S? 05/03/02 2-7/8" 4 *15865- 15885 GS? 05/03/02 (/ 13411' —4-1/2"WLEG, =3.958" 2-7/8" 4 *15920-15940 GS? 04/29/02 13423' —ELMD TT LOGGED 07/30/99 , 2-3/4" 4 16734-17516 C 11/17/98 13416' —7"X 5"BKR ZXP LTPw/HGR,1D=4.458" 2-3/4" 4 19550-20450 11/17/98 SEE SAFETY NOTE FOR DETAILS , 7"LNR,29#,L-80,MOD, .0371 bpf,ID=6.184" —I 13577' 14574' H4-1/2"MARKER JT •••• •• 15609' H4-112"MARKER JT �•�• •••• •• Top of Cement(2/20/09),Bottom Unknown 15850' �••• •••• ••�• •••� 4-1/2"LNR, 12.6#,L-80,NSCT, .0152 bpf,ID=3.958" —1 20888' ....40,4 DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 1990 ORIGINAL COMPLETION 02/24/09 RLM/PJC MILL CMT PLUG WELL: W-12A 11/22/98__JJONES SIDETRACK NABORS 18E 03/01/09 PJC DRAWING CORRECTIONS PERMIT No:`1981820 05/03/07 CJA/PJC SET CBP 08/29/11 EV W-12 AR No: 50-029-22023-01 05/13/07 JGM'PJC CEMENT PLUG SEC 21,T11 N,R12E, 1542'SNL&1196'WEL 09/17/07 DAV/PJC GLV C/O 01/14/09 CJA/SV MILL CMT PLUG(12/18/08) BP Exploration(Alaska) ' 4-1/16"FMC W 12 A WELLHEAD .,AFETY NOTES: WELL ANGLE-70°@ 13768'*** WELLHEAD= FMC - ACTUATOR= BAKER IPERFS @ 15700'-15940'POSSIBLY SQZ(05/14/07) KB.ELEV= 83.67' Proposed Pre CTD MILLED OUT(02/24/09)-SEE AWGRS*** BF.ELEV= 54.37' KOP= 880' Max Angle= 98 @ 14783' Datum MD= 13782' I I 2159' —14-1/2"HES X NIP,D=3.813" Datum TVD= 8800'SS GAS LIFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE 7 3873 3198 52 MMG DOME RK 16 09/17/07 13-3/8"CSG,68#,L-80,ID=12.415" —{ 3079' 6 5965 4409' 55 MMG DMY RK 0 11/22/98 5 7408 5226' 56 MMG DOME RK 16 09/17/07 4 8735 5989 54 MMG DMY RK 0 11/22/98 Minimum ID = 3.80" @ 13399' 3 10062 6789 52 MMG DOME RK 16 09/17/07 4-1/2" HES XN NIPPLE milled out 2 11390 7597` 57 MMG SO RK 22 09/17/07 1 12471 8197' 59 MMG DMY RK 0 03/22/07 j12747' —TOP OF BKR TIEBACK SLV, D=7.50" ----FI� 12754' —9-5/8"X 7"BKR ZXP PKR, D=6.188" TOP OF CEMENT —1__I--....„.......12710' 12760' —19-5/8"X 7"BKR HMC HGR,ID=6.188" EZ SV —I 13070'1 9-5/8"CSG,47#,NT-80S, D=8.681" —I 14075' \ 9-5/8"MILLOUT WINDOW(W-12A) 12905'- 12965' PERFORATION SUMMARY I 13411' H 4-1/2"TBG, 12.6#,L-80, .0152 bpf,ID=3.958" REF LOG:ANADRLL ME RESISTIVITY ON 10/04/98 ANGLE AT TOP PERF: 83 @ 14255' ' I 13344' H4-1/2"HES X NIP,ID=3.813" Note:Refer to Production DB for historical perf data g g 13355' H7"X 4-1/2"BKR S-3 PKR,ID=3.875" SIZE SPF INTERVAL Opn/Sqz DATE 2-7/8" 4 14255-14275 S 05/13/07 1 I 13379' }--L4-1/2"HES X NP,D=3.813" 2-7/8" 4 14950-14970 S 05/13/07 i ' H 4-1/2"HES XN NIP,ID=3.80"(milled out) I 2-7/8" 4 "15700- 15740 GS? 05/04/02 13410' H7"X 4-1/2"BKR TIEBACK SLV,ID5.25" 2-7/8" 4 "15780- 15820 GS? 05/03/02 2-7/8" 4 •15865- 15885 GS? 05/03/02 (/ N 13411' —4-1/2"WLEG, ID=3.958" 2-7/8" 4 •15920 15940 GS? 04/29/02 13423 EL TT LOGGED 07/30/9 2-3/4" 4 16734- 17516 C 11/17/98 13416' —7"X 5"BKR ZXP LTPw/HGR,10=4.458" 2-3/4" 4 19550-20450 C 11/17/98 "SEE SAFETY NOTE FOR DETAILS , 7"LNR,29#,L-80,MOD,.0371 bpf,ID=6.184" —I 13577' � ••• 14574' H4-1/2"MARKER JT ••• •• •••• 15609' H4-1/2"MARKER JT �•�• •• •••• Top of Cement(2/20/09),Bottom Unknown ( 15850' •••• •••i •••• •4. •'.'� --I 20800' PBTD 4-1/2"LNR, 12.6#,L-80,NSCT,.0152 bpf,D=3.958" —I 20888' .••=4 DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 1990 ORIGINAL COMPLETION 02/24/09 RLM/PJC MILL CMT PLUG WELL: W-12A 11/22/98 JJONES SIDETRACK NABORS 18E 03/01/09 PJC DRAWING CORRECTIONS PERMIT No:'1981820 05/03/07 CJA/PJC SET CBP 08/29/11 EV W-12 API No: 50-029-22023-01 05/13/07 JGM(PJC CEMENT PLUG SEC 21,T11 N,R12E, 1542'SNL&1196'WEL 09/17/07 DAV/PJC GLV C/O 01/14/09 CJA/SV MILL CMT PLUG(12/18/08) BP Exploration(Alaska) 1 TREE= 4-1/16"FMC70° WELLHEAD= FMC W-1 2A Ll & L2 P RFS NOTES: WELL ANGLE- @ 13705"" = I PERFS @ 15700'-15940'POSSIBLY SQZ(05/14/07) ACTUATOR= BAKER &MILLED OUT(02124/09)-SEE AWGRS"' KB.ELEV 83.67' Proposed CTD Multi Lat Sidetrack BF.ELEV= 54.37' KOP= 880' Max Angle= 98@14783' Datum MD= 13782' . 2159' H4-1/2"HES X NIP,ID=3.813" Datum TVD= 8800'SS GAS LIFT MANDRELS ST MD ND DEV TYPE VLV LATCH PORT DATE 7 3873 3198 52 MMG DOME RK 16 09/17/07 13-3/8"CSG,68#,L-80, ID=12.415" 3079' 6 5965 4409`55 MMG DMY RK 0 11/22/98 El 5 7408 5226'56 MMG DOME RK 16 09/17/07 4 8735 5989`54 MMG DMY RK 0 11/22/98 Minimum ID =3.80" @ 13399' 3 10062 6789 r 52 MMG DOME RK 16 09/17/07 4-1/2" HES XN NIPPLE milled out 2 11390 75s7"57 MMG SO RK 22 09/17/07 1 12471 8197 59 MMG DMY RK 0 03/22/07 l ) 1 12747' -JTOP OF BKR TIEBACK SLV, ID=7.50" 1F-1 12754' —19-5/8"X 7"BKR ZXP PKR,ID=6.188" TOP OF CEMENT 12710' 12760' —19-5/8"X 7"BKR HMC HGR,ID=6.188" EZSV — 13070'] 9-5/8"CSG,47#,NT-80S, ID=8.681" --I 14075' 9-5/8"MLLOUT WINDOW(W-12A) 12905'-12965' PERFORATION SUMMARY 13411' H4-1/2"TBG, 12.6#,L-80,.0152 bpf,ID=3.958" REF LOG:A NA DRILL ME RESISTN ITY ON 10/04/98 , ' 13344' H4-1/2"HES X NIP,ID=3.813" ANGLE AT TOP PERF: 83 @ 14255' Note:Refer to Production DB for historical pert data g Z I 13355' H7"X 4-1/2"BKR S-3 PKR,ID=3.875" SIZE SPF INTERVAL Opn/Sqz DATE 1 13379' H4-1/2"HES X NIP,ID=3.813" 2-7/8" 4 14950- 14275 RePerf Pending 13394' H-4-1/2"HES XN NIP, ID=3.80"(milled out) 2-7/8" 4 14950-14970 RePerf Pending ' ' 2-7/8" 4 `15700-15740 RePerf Pending 13410' 7"X 4-1/2"BKR TIEBACK SLV, ID5.25" 2-7/8" 4 "15780-15820 RePerf Pending i 13411' —4-1/2"WLEG,ID=3.958" 2-7/8" 4 *15865-15885 RePerf Pending 2-7/8" 4 '15920 15940 RePerf Pending It 13423' —ELMD TT LOGGED 07/30/99 2-3/4" 4 16734- 17516 RePerf Pending 13416' —7"X 5"BKR ZXP LTPw/HGR.ID=4.458" 2-3/4" 4 19550-20450 RePerf Pending SEE SAFETY NOTE FOR DETAILS �' �-^ --..„ —�„—__ / L N 2-7/8", L-80, 6.5#Slotted liner 7"LNR,29#,L-80,MOD, .0371 bpf, D=6.184" —I 13577 I L2: 15740'- 17005' 14574' 4-1/2"MARKER JT 4 gi , --�. 15609' H4-1/2"MARKER JT 2-7/8", L-80, 6.5#Slotted liner L______________i I L1: 16755'- 17825' Retrieve all Whipstocks I Cement Milled Out to FuN Liner ND Drift Re-perforate—2000 ft Zn 4 Mill cement to 20,470' 4-1/2"LNR, 12.6#,L-80,NSCT, .0152 bpf,ID=3.958" —I 20888' re$ 20800' PBTD DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 1990 ORIGINAL COMPLETION 02/24/09 RLM/PJC MLL CMT PLUG WELL: W-12A L1 &L2 11/22/98 JJONES SIDETRACK NABORS 18E 03/01/09 PJC DRAWING CORRECTIONS PERMIT No: PENDING 05/03/07 CJA/PJC SET CBP 08/29/11 EV CTD PROPOSED SIDETRACK API No: 50-029-22023-01 05/13/07 JGM/PJC CEMENT PLUG SEC 21,T11 N,R12E,1542'SNL&1196'WEL 09/17/07 DAV/PJC GLV C/O 01/14/09 CJA/SV MILL CMT PLUG(12/18/08) BP Exploration(Alaska) a • m I 0 0- J � Q � C.) = L U- C Q _ cC M ' m 0 N i s °- Q a V 2.11eigZ , `W Q N N = a ime Za` a � � a m Q= W Z • 01 O O 0 0 N CD (0 0 CO 0 N O 0 0 n 0 0 0 0 0 (0 0 .- 0 0 0 ,- a L2 O O O N M O O 0) 0) 0) 0) O N N In 0) 0) 0) 0) a) co a0 (0 N- O O m 0 tou A o v o N 6 co coO M m N O N O 0 a N : : : : : : : :U)c0c0u : : : : : N 33ti O O O O O N a E CO x 3 • o 0 N '• 8 •E • J o • F- 2 W 0 e O N- n (D U) CO M 00 a CD O U) M N 00 0 0 (O CO 0) O M CO n 0) O a- 6 o n a N n M O U) (D (D (O n a) N 0OD M CO M N- M N a M CO U OI o0 c0 o co n n o (O (n U) LO a a co C o c o 0 0 0 0 0 0 0 0 0 o O o 0 2 L jp O o OO O O CO OO CO (O 0 O (D (O 0 2 W ix a2 C O 07 V . 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Nn' a)OImo, . , -e, 00,Aa) �������, j�� All , .. : U rii iiiiii imimi, . :- z. 12 J « gA Y Ea tki A: c 6 co N _T N ryry a) (l ry c TU li M N N 0 : N m 1 Fi n N • Kill BP BAKIR NYalltf Travelling Cylinder Report 0 bp INTEQ Company: North America-ALASKA-BP Local Co-ordinate Reference: Well W-12 Project: Prudhoe Bay TVD Reference: Mean Sea Level Reference Site: PB W Pad MD Reference: W-12A @ 83.67ft(Nabors 18E) Site Error: 0.00ft North Reference: True Reference Well: W-12 Survey Calculation Method: Minimum Curvature Well Error: 0.00ft Output errors are at 1.00 sigma Reference Wellbore W-12AL2 Database: EDM.16-ANC Prod-WI-124P Reference Design: Plan 3 Offset TVD Reference: Offset Datum Reference Plan 3 Filter type: GLOBAL FILTER APPLIED:All wellpaths within 200'+100/1000 of reference Interpolation Method: MD Interval 25.00ft Error Model: ISCWSA Depth Range: 15,715.13 to 17,005.00ft Scan Method: Tray.Cylinder North Results Limited by: Maximum center-center distance of 1,897.45ft Error Surface: Elliptical Conic Survey Tool Program Date 8/31/2011 From To (ft) (ft) Survey(Wellbore) Tool Name Description 54.60 12,896.69 Survey#1 GCT MS(W-12) GCT-MS Schlumberger GCT multishot 12,905.00 15,715.13 Survey#2 MWD(W-12A) MWD MWD-Standard 15,715.13 17,005.00 Plan 3(W-12AL2) MWD MWD-Standard Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (ft) (ft) Name (in) (in) 17,005.00 8,879.11 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 W Pad W-07-W-07A-W-07A Out of range W-08_DIMS-W-08-W-08 Out of range W-08_DIMS-W-08A-W-08A Out of range W-09-Plan W-09B-Plan#2 Out of range W-09-W-09-W-09 Out of range W-09-W-09A-W-09A Out of range W-09-W-09APB1-W-09APB1 Out of range W-10-W-10-W-10 16,725.00 14,375.00 1,545.36 328.55 1,284.19 Pass-Major Risk W-10-W-10A-W-10A 16,725.00 14,900.00 1,005.84 320.40 755.93 Pass-Major Risk W-12-W-12A-W-12A 15,774.93 15,775.00 1.11 4.58 -2.65 FAIL-Major Risk W-12-W-12AL1-Plan 2 15,774.93 15,775.00 1.11 2.94 -1.42 FAIL-Major Risk PBU MP 11-33-11-12 1 PBU MP 11-33-11-12 1-PBU MP 11-33-11-12 1- Out of range CC-Min centre to center distance or covergent point,SF-min separation factor,ES-min ellipse separation 8/31/2011 11:33:36AM Page 2 of 9 COMPASS 2003.16 Build 73 so, gillill Ii 1 at �� J *. 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X x Page 1 of 1 Schwartz, Guy L (DOA) From: Schwartz, Guy L(DOA) IAJ.-( -At-2- Sent: Friday,August 19, 2011 9:54 AM Fr!) al f- 11 1 To: 'Vazquez, Eleazar' Cc: 'Lastufka,Joseph N (Wipro)' Subject: RE: W-12A L1 & L2 Sundry&Permit to Drill (PTD 198-182) Eleazar, Based on what I can tell from our records you won't need to submit a 403 to do cover the pre-drilling wellwork on the motherbore. The well was never suspended and you are proposing to add two laterals and reperf some of the liner in the Motherbore. Submit a 401's for each lateral with a full detail of the operational steps(pre and post lateral drilling operations) needed and you should be good to go. Note 1 A 10-404 report should be generated after the wellwork is completed for the motherbore (PTD 198-182)to capture the milling and post perfing once the laterals are completed. Note 2 The Commission never received a report on the cementing sqz job that occurred in 2007 on the motherbore W-12A(PTD 198-182) This should have been reported in a 10-404. We have the milling operation details from 2008 in our records however. Can you submit that data for our records.. on a 10- 404 please. 4---> 5u bh,;(4,Q Y wJ( >9°P/e2 Call me if you have any questions. Guy Schwartz Senior Petroleum Engineer AOGCC 793-1226 (office) 444-3433 (cell) From: Vazquez, Eleazar [mailto:vazgeO@BP.com] Sent: Thursday, August 18, 2011 5:10 PM To: Schwartz, Guy L(DOA) Subject: W-12A Ll &L2 Sundry&Permit to Drill Hi Guy, A series of cement squeeze jobs were performed on well W-12A in May 2007 that successfully abandoned the perfs and holes inside the 4'/s°liner as planned. However, the plug set at 15,050' and failed and allowed the cement to get past it and inside the 4%" liner. To the best of my knowledge, the current top of cement inside the 4'/z"liner is 15,850' and with an unknown bottom of cement(could be all the way to PBTD or shallower). As Nordic 1 is planning to mill all of the cement inside the liner, drill two laterals, retrieve the whipstocks, and re perforate the area that was plugged with the failed squeeze cement jobs in 2007(see schematics attached). Question: Do I need to submit an application for Sundry Approval? Or,would an application for PTD suffice? Thanks in advance, Eli Vazquez Dri'hnq Engineer.Coiled T;dn nq Do,' '1.1 BP Exploratino OfSCe. i9 04-5118 Moate. i)O7)2 I 9/9/2011 Alaska Department of Natural Resources Land Administration System Page 1 of 3 Alaska Mapper Land Records/Status Plats Recorder's Search State Cabins Natural Resources I find Alaska DNR Case Summary File Type: ADL File Number: 47452 d Printable Case File Summary See Township,Range,Section and Acreage? Yes No New Search LAS Menu I Case Abstract I Case Detail I Land Abstract AA ` y PlatUpdates ADL 47452 Search for Status Plat;U dates As of 09/08/2011 Customer: 000107377 BP EXPLORATION(ALASKA)INC PO BOX 196612/900 E.BENSON BL ATTN:LAND MANAGER-ALASKA ANCHORAGE AK 995196612 Case Type: 784 OIL&GAS LEASE COMP DNR Unit: 780 OIL AND GAS File Location: DOG DIV OIL AND GAS Case Status: 35 ISSUED Status Date: 09/30/1969 Total Acres: 2560.000 Date Initiated:08/11/1969 Office of Primary Responsibility:DOG DIV OIL AND GAS Last Transaction Date: 12/04/2006 Case Subtype: NS NORTH SLOPE Last Transaction:AA-NRB ASSIGNMENT APPROVED Meridian: U Township: 011N Range: 012E Section: 27 Section Acres:640 Search Plats Meridian: U Township: 011N Range: 012E Section: 28 Section Acres:640 Meridian: U Township: OLIN Range: 012E Section: 33 Section Acres:640 Meridian: U Township: 011N Range: 012E Section: 34 Section Acres:640 Legal Description 08-11-1969***SALE NOTICE LEGAL DESCRIPTION*** C23-037 T11 N-RI2E-UM GENERAL 27 640.00 ALL 28 640.00 ALL 33 640.00 ALL 34 640.00 ALL TOTAL ACRES-2560.00 04-01-1977****UNITIZED AND LEASE LEGAL DESCRIPTION******* LEASE COMMITTED IN ENTIRETY TO THE PRUDHOE BAY UNIT PRUDHOE BAY UNIT TRACT 80 http://dnr.alaska.gov/projects/las/Case Summary.cfm?FileType=ADL&FileNumber=47452... 9/8/2011 Alaska Department of Natural Resources Land Administration System Page 1 of 3 lioaska Mapper Land Records/Status Plats Recorder's Search State Cabins Natural Resources I find• Alaska DNR Case Summary File Type: ADL File Number: 28263 rol Printable Case File Summary See Township,Range,Section and Acreage? Yes No New Search I LAS Menu I Case Abstract I Case Detail I Land Abstract rile: ADL 28263 Map Search for Status Plat Upd tes As of 09/08/2011 Customer: 000107377 BP EXPLORATION(ALASKA)INC PO BOX 196612/900 E.BENSON BL ATTN:LAND MANAGER-ALASKA ANCHORAGE AK 995196612 Case Type:784_ OIL&GAS LEASE COMP DNR Unit: 780 OIL AND GAS File Location:DOG DIV OIL AND GAS Case Status:35 ISSUED Status Date: 08/11/1965 Total Acres: 2560.000 Date Initiated:05/28/1965 Office of Primary Responsibility:DOG DIV OIL AND GAS Last Transaction Date: 10/06/2009 Case Subtype: NS NORTH SLOPE Last Transaction:CHNGTEXT CHANGE LEGAL TEXT Meridian: U Township: O11N Range: 012E Section: 15 Section Acres:640 Search Plats Meridian: U Township: 011N Range: 012E Section: 16 Section Acres:640 Meridian: U Township: 011N Range: 012E Section: 21 Section Acres:640 Meridian: U Township: 011N Range: 012E Section: 22 Section Acres:640 Legal Description 05-28-1965***SALE NOTICE LEGAL DESCRIPTION*** C14-59 T11N,R12E,UM 15, 16,21,22 2560.00 11-28-1969 SEGMENT 1 T 11N,R 12E,UM SECTION 15:640 ACRES SECTION 16:640 ACRES CONTAINING 1280 ACRES,MORE OR LESS. SEGMENT 2-LANDS ASSIGNED T I1N,R 12E,UM SECTION 21:640 ACRES SECTION 22:640 ACRES CONTAINING 1280 ACRES,MORE OR LESS. 04-01-1977 ****UNITIZED AND LEASE LEGAL DESCRIPTION************ ENTIRE LEASE COMMITTED TO PRUDHOE BAY UNIT PRUDHOE BAY UNIT TRACT 55 T. I I N.,R. 12 E.,UMIAT MERIDIAN,ALASKA http://dnr.alaska.gov/projects/las/Case Summary.cfm?FileType=ADL&FileNumber=28263... 9/8/2011 TRANSMITTAL LETTER CHECKLIST WELL NAME 7)..672/ /i? '1 7 PTD# /2/I9 V Development Service Exploratory Stratigraphic Test Non-Conventional Well FIELD: , ,ez/Z,A4 C �'P' POOL: ,e'1./Q,c/GL4—.e 4)/ ©/G Circle Appropriate Letter/Paragraphs to be Included in Transmittal Letter CHECK ADD-ONS WHAT (OPTIONS) TEXT FOR APPROVAL LETTER APPLIES MULTI LATERAL The permit is for a new wellbore segment of existing well der/../ J1//p3, (If last two digits in Permit No. API number are /9f/rA , API No. 50-CW-04aekrev-00. 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(f), 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 perforate and 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. 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