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Home My WebLink About208-131CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Rixse, Melvin G (OGC) To:Oliver Sternicki Cc:PB Wells Integrity; McLellan, Bryan J (OGC) Subject:20230331 1716 01-21A APPROVAL TO FLOW UNDER EVAL (PTD# 208-131) request to POP Under eval with failed CMIT-TxIA for up to 60 days Date:Friday, March 31, 2023 5:17:53 PM Oliver, Hilcorp is approved to POP PBU01-21A under evaluation for 60 days with the following conditions: 1. No gas lift, i.e., well will be on natural flow production 2. IA pressure to remain below MOASP. 3. A plug an perf to higher zone will require a 10-403. Mel Rixse Senior Petroleum Engineer (PE) Alaska Oil and Gas Conservation Commission 907-793-1231 Office 907-297-8474 Cell CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Mel Rixse at (907-793-1231 ) or (Melvin.Rixse@alaska.gov). cc. Bryan McLellan From: Oliver Sternicki <Oliver.Sternicki@hilcorp.com> Sent: Friday, March 31, 2023 2:16 PM To: Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov>; McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov> Cc: PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Subject: 01-21A (PTD# 208-131) request to POP Under eval with failed CMIT-TxIA for up to 60 days Subject correction Bryan, Mel, Natural flow producer 01-21A (PTD# 208-131) was made not operable on 12/5/2018 after being flagged for anomalous IA repressurization and failing a subsequent CMIT-TxIA on 12/02/2018. On 3/15/2023 a CMIT-TxIA failed with a LLR of 2 bpm at 600 psi. A plug was recently reset at 8700’ MD and an MIT-T passed to 2603 psi on 03/29/2023, confirming the primary well barrier. Based on this passing test and the pressure test history it is suspected that the failing CMIT-TxIA is due to a deep PC leak or a failed production packer at 8678’ MD. Hilcorp requests permission to place the well online, under evaluation for up to 60 days to measure production flow rates and determine if the well is economic to repair. 60 days is requested such that if the current perforations are uneconomic, a plug and perf to a higher zone can be executed and the well tested again. The well will not require gas lift to flow and GLMs will remain dummied. IA pressure will be maintained below MOASP. Regards Oliver Sternicki Hilcorp Alaska, Hilcorp North Slope LLC Well Integrity Engineer Office: (907) 564 4891 Cell: (907) 350 0759 Oliver.Sternicki@hilcorp.com The information contained in this email message is confidential and may be legally privileged and is intended only for the use of theindividual or entity named above. If you are not an intended recipient or if you have received this message in error, you are herebynotified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, pleaseimmediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently deletethis message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that theonward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. RECEIVE 2.01c_k3\ JUN 28 2017 11111 'LS 3t1 WELL LOG TRANSMITTAL#903911203 AOGCC To: Alaska Oil and Gas Conservation Comm. June 23, 2017 Attn.: Makana Bender 333 West 7th Avenue, Suite 100 DATA LOGGED Anchorage,Alaska 99501 6/2a/201'i vl.K.BENDER RE: Coil Flag Log: 01-21A Run Date:3/15/2017 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Fanny Sari, Halliburton Wireline &Perforating, 6900 Arctic Blvd.,Anchorage, AK 99518 01-21A Digital Data(LAS),Digital Log file(Field Data) 1 CD Rom 50-029-20827-01 Coil Flag Log(Field Print) 1 Color Log 50-029-20827-01 scow JUL 0 721)17 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline &Perforating Attn: Fanny Sari 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-275-2605 Fax: 907-273-3535 FRS_ANC@halliburton.com Date: Signed: /DAL. . .Li c-k)z_edaa • • 2:6. 0`3) WELL LOG TRANSMITTAL#903911203 • To: Alaska Oil and Gas Conservation Comm. June 12, 2017 Attn.: Makana Bender RECEIVED�^G C�`1,c 333 West 7th Avenue, Suite 100 {„+ 11� G Anchorage,Alaska 99501 DATA LOGGED JUN 2 2 2017 uENDE IN.K.BENDER RE: Coil Flag Log: 01-21A Run Date:3/17/2017 AOGCC The technical data listed below is being submitted herewith.Please address any problems or concerns to the attention of: Fanny Sari,Halliburton Wireline&Perforating, 6900 Arctic Blvd.,Anchorage,AK 99518 01-21A Digital Data(LAS),Digital Log file(Field Data) 1 CD Rom 50-029-20827-01 Coil Flag Log(Field Print) 1 Color Log 50-029-20827-01 WO '® JUL 1 12017 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline&Perforating Attn: Fanny Sari 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-275-2605 Fax: 907-273-3535 FRS_ANC@halliburton.com Date: Signed: z ,.E'i4 STATE OF ALASKA -, ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed Abandon 0 Plug Perforations ® Fracture Stimulate 0 Pull Tubing 0 Operations shutdown 0 Suspend 0 Perforate ® Other Stimulate ❑ Alter Casing 0 Change Approved Program 0 Plug for Redrill 0 Perforate New Pool 0 Repair Well 0 Re-enter Susp Well 0 Other: C//3 p tar 2. Operator Name: BP Exploration(Alaska),Inc ' 4. Well Class Before Work 5. Permit to Drill Number: 208-131 3. Address: P.O.Box 196612 Anchorage, Development 0 Exploratory 0 AK 99519-6612 Stratigraphic 0 Service ❑ 6. API Number: 50-029-20827-01-00 7. Property Designation(Lease Number): ADL 0028329 8. Well Name and Number: PRUDHOE BAY UNIT 01-21A 9. Logs(List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pools: PRUDHOE BAY,PRUDHOE OIL 11.Present Well Condition Summary:Total Depth: measured 10743 feet Plugs measured 10225 feet ECR E IV E D true vertical 9056 feet Junk measured feet APR 0 6 2017 Effective Depth: measured 10225 feet Packer measured 8689 feet true vertical 9056 feet Packer true vertical 8147.45 feet AOGCC Casing: Length: Size: MD: TVD: Burst: Collapse: Structural Conductor 80 20"91.5#H-40 37-117 37-117 1490 470 Surface 2538 13-3/8"72#L-80 36-2574 36-2574 4930 2670 Intermediate 9039 9-5/8"47#L-80 33-9072 33-8505 6870 4760 Production Liner See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Perforation Depth: Measured depth: 9820 9851 feet feet 9852-9883 feet 9884-9915 feet 10250-10650 feet True vertical depth: 9054-9056 feet feet 9056-9058 feet 9058-9060 feet 9055-9052 feet Tubing(size,grade,measured and true vertical depth) 4-1/2"12.6#13Cr80 31-8841 31 -8289 Packers and SSSV(type,measured and See Attachment See Attachment See Attachment true vertical depth) 12.Stimulation or cement squeeze summary: Intervals treated(measured): F r' •1 scope) MAY 16 L0 1: Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 440 39361 402 510 907 Subsequent to operation: 140 33 420 1452 800 14.Attachments:(required per 20 AAC 25.070.25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations ® Exploratory ❑ Development I1 Service 0 Stratigraphic 0 Copies of Logs and Surveys Run 0 16.Well Status after work: Oil RI Gas 0 WDSPL 0 Printed and Electronic Fracture Stimulation Data 0 GSTOR ❑ WINJ 0 WAG 0 GINJ 0 SUSP 0 SPLUG 0 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: N/A Contact Catron,Garry R(Wipro) Email Garry.Catron@bp.com Printed Name Catron,Garry R(Wipro) Title PDC Principal Engineer Signature Phone +1 907 564 4424 Date 4/5/17 Form 10-404 Revised 5/2015 off 0/7 j k71—` 57/017 RBDMS ��APR - 7 2017 Submit Original Only • • a) N o to 0 0 co 0 co 0 ta r,_ CO N O CO co 1.00 N V U CD H L 0) 0Occ CO0) CO c N CO CO o) O 'Cr CO LC) to CO LO LC) CO - O O N N CO CO CO O) 0) CO a I I I I I I I I H r- O d' co r- M co <- N to COCOCONNCOCDCO CO CO CO 0 Q C • NV N O t[) - Eto O N CO N CO N CA 0) C)) O' 0p Z M CO O O N- M CO CO N- N O co co co r- r-- N N 00 00 CA H• Wo \ OO O O O co o (b T0O co co U a}Z J 000 J _M _ es N c\I N *k �N .111to f� *k CO • CO • - 0 CV U a rnco Oz � o "? to N. - N co M N co N 00 ti C7) O M 0 • 0c.0• D tO O to Co co • N 0 Ln CA tf) co W Ct • 0• W 1-1W CO 0 • ZwLWWm ODI- ZZZZD U Cn Z J J J J H • • Packers and SSV's Attachment PRUDHOE BAY UNIT 01-21A SW Name Type MD TVD Depscription 01-21A TBG PACKER 8688.66 8147.45 4-1/2" Baker S-3 Hydro Set Packer 01-21A PACKER 8752.78 8207.07 2-7/8" Baker KB Packer • 0 a- EdTr) Q Tn o D c L) a) 2 0) 0) o .3 * o a U m * O 0) 7,-S ca fxaa) •• � @ � o � Yo 3 N O c o o0 � 3 N o � '� � N O o L_ (0 + -° 'ca) N L 0 N- U a) _� O C t O J co aj M O o Q 2 a o 10 O a - L O o O o O U) cm 0)C (1) = ((“; 176 (U 3 ) t U) > a) O > 7 * U) O) 0)10 "a o0 W c w C O (6 ,- a:1 700 O CD > _d 00 0 W ,- E 2m - -c - 2 O - (6 o - M O - U) i L O o a 20_ NO `-- � Z � cy) � � a) o_ O 0 u) a) O U) O ( .. -C (n C J Q) O O D , -c LO c) o c c U Y o_ c a) c CD - In 'O (n SZ 7 0 U 4 O - co 7 O U O 0 0 Q } .SN io � � � � L � � � � coa a c 0) a) OO crn O o a3 47. i CL ? O ?N c'aI 10 Z'.(0coo E a)Q O Z cv L � 2 * O 0 7 _Oo * E � OwN � *x 7 0 02 (0 (0 Q co t xJ * a) a) Urno `n 0E- r O —. Dc° ° O_ co co x Qs a) °_o E 0 O a 2 mN m 7 — Z UV ) OU) c - (0 U om o o o)oN U L `t U v 't .C' c 0 -c 7 `t 7 - a) �_ `t a) a) o -o . (A a) LO , Q- O a) _E-0 ,., Q 7 Q , O Q= .- Q. 0 CO Q ` Q .= `� J ( 2 Q2 0CV 13 CU � (a m E Q W N co a) • c O 2 4 c p) a) N • LO , ° `zi 1:3 Co° oO > n ,- > . Upd > U 7- • >Q ' .3ma)= oWE oo0c cn = ai � E IX ° ao � ca Mc cpi � a) a)? o � oo r) po � OOaN ° OAaO > rn O a)2inmco 0- m N 72 O .Q .Q rQ.0) _0 &o Q- ' oO _a LQa J * O mN Q U 0 Cl) j • _ N UDi7:2• m U � 30 (a O) co UabC0INo_ � w 0 rn a) W a) - M N m a) - o O In - Ln 2 (DEE -6 N Q- r a) c J U 7 a) Y N .. N- 2 Q N -a N 0 .E .- O U U T* D -c o rn Q o `o n at 2 7 Q- a) E 2 a) - 4* n ow i- - mva * 1- O c t I � c) E coo -0am — 7 H 0 -3 vCD \ 0 E U Cl- Q (ca o a ; U 2 -J o� o (ct o * U CC : CO ,- W F- N- r- r- 0 >- 0 0 c 0 � � N N N N (,) DD CO 00 m co _ r r I M M M M 0 Q (. TREE • • = FMc WELLHEAD= FMC 0 1 -21A CHR M E TBG*** SAFETY NOTES: WELL ANGLE>70° 9740'"•4 112" ACTUATOR= BAKER ' ' OKB.BEV= 74' "COND # -nom"` BF.ELEV= 28' — ' ' 2186' -14-1/2"HES X NP,0=3.813" KOP= 2900' Max Angle= 94°@ 10142' D=—" Datum MD= 9471 Datum TVD= 8800'SS GAS UFT MANDRELS 13-3/8"CSG,72#,L-80, D=12.34T -t 2671' I-4 ST M) ND DEV TYPE VLV LATCH FORT DATE 5 3001 2997 15 MMG DMY RK 0 12/14/02 LI 4 3768 3719 21 MAG DOME RK 16 12/09/09 3 6253 5996 29 MING SO RK 20 12/09/09 2 7978 7499 26 MMG DMY RK 0 12/09/02 Minimum ID = 2.37" @ 8768' 1 8596 8062 22 AVG MY RK 0 12/09102 4-1/2' X 2-7/8" BKR KB LTP I I 8666' -14-1/2'IIM X NP,D=3.813" S S 8678' H9-518"X 4-1/2"BKR S-3 PKR D=3.875' 8768' -14-112'x 2-7/8"BKR KB LTP,ID=2.37'(07/05/14) 8763' H 3.70"DEPLOYMENT SO!,ID=3.000" TOP OF 7"LM --I 8773' I IF 8797' -14-112"HES x NIP, D=3.813" I r 8817' -4-1/2"HES XN NP MLLE)D TO 3.80"(09/06/08) 4-1/2'TBG,12.6#,13CR VAM ACE, H 8830' ` ' 8830' -14-112'YVLEG,D=3.958" .0152 bpf,D=3.958" 9-5/8"CSG,47#,L-80, D=8.6811'1-1 9069' j 1 I. 3-1/2"LNR,9.2#,L-80 STL, --I 9220' ]----k , 9220' H3-1/2"x 3-1/16"xo,D=2.786" .0087 bpf,V=2.992" MLLOUT WTNDOW(01-21A)9345'-9352' 7"W IPSTOCK(08/24/08)W/RA TAG a 9350' --1 9340' 7"LNR 29#,L-80,D=6.184']H 9864' 1/• S 610200' 1-13-1116*X 2-7/8"XO,ID=2.377" PERFORATION SUVIIMRY 10225' 2-7/8"WFD 10k DEFERENTIAL REF LOG: SWS CNUGR/CCL 09/30/08 CEP(03/17!17) ANGLE AT TOP PERF: 84°@ 9820" 0, Note:Refer to Production DB for historical perf data �•S4•44.44•1444 SIZE SPF INTERVAL Opn/Sqz SHOT SQZ 4,4.0, I 2' 6 9820-9851 0 03/17/17 2" 6 9852-9883 0 03/16/17 3-3/16'LNR,6.2#,L-80 TCt H 10200' 2" 6 9884-9915 0 03/16/17 .0076 bpf,D=2.80" 2" 6 10250-10650 C 09/29/08 L PBTD .1-_10707'_ "S'v 2-7/8"LNR,6.4#,L-80 STL, -1 10743' ' .0058 bpf,ID=2.441" DATE REV BY COMMENTS DATE REV BY COMVE4TS PRUDHOE BAY UNIT 10/20/82 ORIGINAL COMPLETION 03/14/17 EFDIJMD PULLED PX FLOG(03/13/17) WELL: 01-21A 12/09/02 PWKAK RINO 03/20/17 MZ/JMD SET CEP 8 ADPERFS(03/16-17/17) PERMf No: 2081310 09/30/08‘1ORDIC 5 CTD SIDETRACK(01-21A) API No: 50-029-20827-01 10/15/14 WO PJC LTP DEPTH CORRECTION SEC 8,T1 ON,R15E,401'FNL&506'FWL 03/10/17 GIB/JM.)SET PX PLUG(03/08/17) 03/14/17 KP/JM3 TREE C/O(03/11/17) BP Exploration(Alaska) Image Pro~ct Well History File Cove~age 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. p~©~ - ~3 ~_ Well History File Identifier Organizing (done) ^ Two-sided III 111111 II III II III ^ Rescan Needed RE AN DIG AL DATA Color Items: Diskettes, No. ' ^ Greyscale Items:. ^ Other, No/Type: ^ Poor Quality Originals: ^ Other: NOTES: BY: Maria Date: Project Proofing BY: OVERSIZED (Scannable) ^ Maps: ^ Other Items Scannable by a Large Scanner OVERSIZED (Non-Scannable) ^ Logs of various kinds: ^ Other:: /O /s/ ~1 ~d P ~uu~~~~~~uu~~~ mP Scanning Preparation / x 30 = ~ d + ~~ =TOTAL PAGES ~/~ //D (Count does not include cover sheet) ~ /~/~ BY: Maria Date: /s/ ~!/ !Y!1 c Production Scanning """"""" " "' Stage 1 Page Count from Scanned File: ~ ~ (Count does include cov sheet) hes Number in Scannin Pre aration: 1/ YES NO Page Count Matc 9 p BY: Maria Date: 3 3 ~ Io /s/ Stage 1 If NO in stage 1, page(s) discrepancies were found: YES NO BY: Maria Date: ~s~ Scannin is complete at this point unless rescanning is required. III II') II I II II I I III 9 ReScanned BY: Maria Comments about this file: Date: Date: Quality Checked 91111111111111 10/6/2005 Well History File Cover Page doc • • bp BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB -20 Post Office Box 196612 Anchorage, Alaska 99519 -6612 May 11,2012 OALIG 1 art. Mr. Jim Regg Alaska Oil and Gas Conservation Commission o g, 13' 333 West 7 Avenue Anchorage, Alaska 99501 ( � �! Q Subject: Corrosion Inhibitor Treatments of GPB DS -01 Dear Mr. Regg, Enclosed please find multiple copies of a spreadsheet with a list of wells from GPB DS- 01 that were treated with corrosion inhibitor in the surface casing by conductor annulus. The corrosion inhibitor is engineered to prevent water from entering the annular space and causing external corrosion that could result in a surface casing leak to atmosphere. The attached spreadsheet represents the well name, API and PTD numbers, top of cement depth prior to filling and volumes of corrosion inhibitor used in each conductor. As per previous agreement with the AOGCC, this letter and spreadsheet serve as notification that the treatments took place and meet the requirements of form 10 -404, Report of Sundry Operations. If you require any additional information, please contact me or my alternate, Gerald Murphy, at 659 -5102. Sincerely, Mehreen Vazir BPXA, Well Integrity Coordinator . • BP Exploration (Alaska) Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top -off Report of Sundry Operations (10 -404) DS-01 01/20/12 Corrosion Initial top of Vol. of cement Final top of Cement top off Corrosion inhibitor/ Well Name PTD # API # cement pumped cement date inhibitor sealant date ft bbls ft NA gal 01 -01C 2070920 50029210070200 0.8 NA 0.8 NA 8.5 10/22/2011 01 -02 1691190 50029200530000 4.8 NA 4.8 NA 78.2 9/17/2010 01 -03A 1952040 50029200630100 2.3 NA 2.3 NA 22.2 10/10/2010 01 -04A 2011520 50029200700100 Dust Cover NA NA NA NA NA 01 -05B 2070480 50029200760200 1.5 NA 1.5 NA 5.1 1/20/2012 01 -06A 1950080 50029201120100 Sealed conductor NA NA NA NA NA 01 -07A 1940820 50029201570100 Sealed conductor NA NA NA NA NA 01 -08A 2051950 50029201600100 Sealed conductor NA NA NA NA NA 01 -09A 1940330 50029201640100 Dust Cover NA NA NA NA NA 01 -10 1750430 50029201690000 Sealed conductor NA NA NA NA NA 01 -11 1770570 50029202680000 Sealed conductor NA NA NA NA NA 01 -12A 2021920 50029202690100 Sealed conductor NA NA NA NA NA 01 -13 1770590 50029202700000 Sealed conductor NA NA NA NA NA 01 -14A 2091290 50029202810100 Sealed conductor NA NA NA NA NA 01 -15A 1952100 50029202870100 Sealed conductor NA NA NA NA NA 01 -16 1780080 50029202880000 Sealed conductor NA NA NA NA NA 01 -178 2040120 50029202890200 Sealed conductor NA NA NA NA NA 01 -18A 2090720 50029203030100 Sealed conductor NA NA NA NA NA 01 -19B 2081770 50029208000200 0.1 NA 0.1 NA 0.9 9/16/2010 01 -20 1821460 50029208210000 0.1 NA 0.1 NA 9.4 10/22/2011 ----, 01 -21A 2081310 50029208270100 41.0 2.0 0.4 7/8/2011 9.4 10/22/2011 01 -22B 2100340 50029208480200 0.2 NA 0.2 NA 1.7 10/11/2010 01 -23 1821800 50029208540000 0.2 NA 0.2 NA 11.1 10/21/2011 01 -24A 1921320 50029208600100 0.3 NA 0.3 NA 3.4 10/10/2010 01 -25 1822030 50029208740000 0.0 NA 0 NA 10.2 10/25/2011 01 -26A 1990120 50029208850100 0.0 NA 0 NA 7.3 10/21/2011 01 -28A 2091250 50029215970100 0.0 NA 0 NA 8.5 10/22/2011 01 -29 1861050 50029216040000 Dust Cover NA NA NA NA NA 01 -30 1861110 50029216060000 1.9 NA 1.9 NA 11.9 10/11/2010 01 -31 1861320 50029216260000 0.0 NA 0 NA 9.4 10/21/2011 01 -32 2021850 50029216220100 15.0 NA 15 NA 15.3 10/11/2010 01 -33 1861220 50029216170000 3.0 NA 3 NA 34.0 10/11/2010 01 -34A 2081250 50029216090100 Sealed conductor NA NA NA NA NA DATA SUBMITTAL COMPLIANCE REPORT 2/2512010 Permit to Drill 2081310 Well Name/No. PRUDHOE BAY UNIT 01-21A Operator BP EXPLORATION (ALASK/~ INC MD 10743 ND 9056 Completion Date 9/30/2008 Completion Status 1-OIL Current Status 1-OIL APi No. 50-029-20827-01-00 UIC N _. REQUIRED INFORMATION ~ /~~~ Mud Log No Samples No Directional Survey Yes DATA INFORMATIDN Types Electric or Other Logs Run: MWD, DIR, RES, MCNL / G R /CCL, ROP /Press / Res (data taken fro m Logs Portion of Master Well Data Maint Well Log Information: Log/ Electr Data Digital Dataset Log Log Run Interval OH / Tye Med/Frmt Number Name Scale Media No Start Stop CH Received Comments D D Asc Directional Survey 9300 10743 Open 11/14/2008 pt Directional Survey 9300 10743 Open 11/14/2008 C Lis 17244~1eutron 8380 10634 Case 12/10/2008 LIS Veri, CNT, GR ', og Neutron 2 Blu 8382 10618 Case 12/10/2008 MCNL, Mem Lee, GR, CCL, CNL 29-Sep-2008 D C Las 17468~nduction/Resistivity 9094 10743 Open RPM, GR, RAD, RAM, ROP, RPD t LIS Verification 9093 10744 Open 1/28/2009 LIS Veri, GR, ROP, RAD, RAS, RPD, RPS D C Lis 17501 eduction/Resistivity 9093 10744 Open 1/28/2009 LIS Veri, GR, ROP, RAD, RAS, RPD, RPS Log Induction/Resistivity 25 Col 9340 10743 Open 1/28/2009 MD MPR, GR 28-Sep-2008 Log Induction/Resistivity 25 Col 9340 10743 Open 1/28/2009 TVD MPR, GR 28-Sep- 2008 Log Gamma Ray 25 Col 9340 10743 Open 1!28/2009 MD GR 28-Sep-2008 ~rCog See Notes 5 Col 9090 10739 Open 1/28/2009 Depth Shift Monitor Plot Log See Notes 5 Col 9090 10740 Open 1!28/2009 Mad Pass Depth Shift II Monitor Plot Well Cores/Samples Information: ~I Sample Interval Set Name Start Stop Sent Received Number Comments DATA SUBMITTAL COMPLIANCE REPORT 2/25/2010 Permit to Drill 2081310 Well Name/No. PRUDHOE BAY UNIT 01-21A Operator BP EXPLORATION (ALAStCA) INC MD 10743 TVD 9056 Completion Date 9/30/2008 Completion Status 1-OIL Current Status 1-OIL ADDITIONAL INFORMATION Well Cored? Y / N Chips Received? Y / N Analysis Y / N Received? Comments: Daily History Received? Y / N Formation Tops Y / N API No. 50-029-20827-01-00 UIC N Compliance Reviewed By: Date: ~. .;TOT OPAERABLE: 01-21A (PT081310) Secured w/ a downhole plug Page 1 of 2 Regg, James B (DOA) From: NSU, ADW Well Integrity Engineer [NSUADWWeIIlntegrityEngineer@BP.comJ Sent: Saturday, September 19, 2009 10:43 AM ~c~~,ci /r~4i ~~ i To: NSU, ADW Well Integrity Engineer; Regg, James B (DOA); Maunder, Thomas E (DOA); GPB, FS1 DS Ops Lead; GPB, FS1 OTL; GPB, Area Mgr East (FS1/2/COTU/Seawater); NSU, ADW Well Operations Supervisor; Rossberg, R Steven; Engel, Harry R; GPB, Wells Opt Eng; GPB, EOC Specialists; GPB, Optimization Engr; Schwartz, Guy L (DOA) Cc: Seltenright, Ana Maria - Subject: NOT OPAERABLE 01-21A (PTD #2081310 ecured w/ a downhole plug r All, Well 01-21A (PTD #2081310) was secured with a downhole plug on 09117/09. On 09118/09, an MIT-T passed verifying the plug is holding. The well has been reclassified as Not Operable and will remain shut-in until remedial work is taken. _. -.. Please call with any questions or concerns. Thank you, Torin Roschinger (alt. Anna Dube) Well Integrity Coordinator Office (907) 659-5102 Cell (406) 570-9630 Pager (907) 659-5100 Ext. 1154 From: NSU, ADW Well Integrity Engineer Sent: Wednesday, September 09, 2009 4:22 PM '~ To: 'Regg, James B (DOA)'; 'Maunder, Thomas E (DOA)'; GPB, FSl DS Ops Lead; GPB, FS1 OTL; GPB, Area Mgr East (FSl/2/COTU/Seawater); NSU, ADW Well Operations Supervisor; Rossberg, R Steven; Engel, Harry R; GPB, Wells Opt Eng; GPB, EOC Specialists; GPB, Optimization Engr; 'Schwartz, Guy (DOA) <guy.schwartz@alaska.gov>' Cc: NSU, ADW Well Integrity Engineer; Seltenright, Ana Maria; Williams, Carrie Subject: UNDER EVALUATION: Ol-21A (PTD #2081310) TIFL Failed All, Well 01-21A (PTD #2081310) has been found to have sustained casing pressure on the IA. The wellhead pressures were tubing/IA/OA equal to 921/2140/450 on 09/02/09. A TIFL failed on 09/07/09 confirming TxIA communication. The well has been reclassified as Under Evaluation and may continue to be produced while efforts are made to mitigate the communication. The plan forward for the well is as follows: 1. Slickline: Set DGLVs 2. Pumping: MIT-IA to 3000 psi A wellbore schematic and TIO plot have been included for reference. File: 01-21A.pdf» « File: 01-21A TIO Plot.doc» `~ 11 /5/2009 NOT OPAERABLE: O 1-21 A (PT~2081310) Secured w/ a downhole plug. Page 2 of 2 Thank you, Torin Roschinger (alt. Anna Dube) Well Integrity Coordinator Office (907) 659-5102 Cell (406) 570-9630 Pager (907) 659-5100 Ext. 1154 11/5/2009 PBU 01-21A PTD 2081310 9-9-2009 TIO Pressures I ~ 4.000 7 ......... 3,000 i 2,000 1 1,000 ___ __ ~A ~~~~~~f~~~~~-~~~f~~~~^~ ~ # Tbg -~- IA ~- OA OOA ~- ODOA On 06!13!09 06!20!09 06!27!09 07!04!09 07!11!09 07!18!09 07!25!09 08!01!09 08!08109 08!15!09 08!22!09 08129!09 09!05!09 REE _ FMC WELLHEAD= FMC RCTUATOR = AXELSON KB. ELEV = 74' BF. ELEV = 28' KOP = 2900' Max Angle = 94° @ 10142' Datum MD = 9471 datum TV D = 8800' SS 13-318" CSG, 72#, L-80, ID = 12.347" ~ 2571' Minimum ID = 2.31" @ 8776' ALUMINUM PROFILE IN LNR 01-21 A SA ES: *** 4-1 /2" CHROMETBG*** WELL APIGLE> 70° @ 9740'. 2185° I-{ 4-1/2" HES X NIP, ID = 3.813" CA S I ITT MA Ni-DRFI S ST MD TVD DEV TYPE VLV LATCH PORT DATE 5 3001 2997 15 MMG DMY RK 0 12/14!02 4 3768 3719 21 MMG DOM RK 16 10!08108 3 6253 5996 29 MMG SO RK 20 10/08/08 2 7978 7499 26 MMG DMY RK 0 12/09102 1 8596 8062 22 MMG DMY RK 0 12109!02 $$56~ -14-1/2" HES X NIP, ID = 3.813" $67$' 9-5/8" X 4-1l2" BKR S-3 PKR, ID = 3.875" $763' 3.70" DEPLOYMENT SLEEV E, ID = 3.000" TOP OF 7" LN] $773' $797' 4-112" HES X NIP, ID = 3.813" $$1T 4-1/2" HES XN NIP MILLED ID TO 3.80" (09!06108) 4-1/2" TBG, 12.6#, 13CR, $$30' 8830' 4-1/2" WLEG, ID = 3.958" .0152 bpf, ID = 3.958" 9-5/8" CSG, 47#, L-80, ID = 8.681" 9069° ___ -•.._-- _-- MILLOUT WINDOW 9345' - 9352' 3-1/2'" LNR, 9.2#, L-80 STL, 9220° .0087 bpf, ID = 2.992" 9222' 3-1/2" X 3-1116" XO, ID = 2.786" 7" WHIPSTOCK (08/24!08) 9340° -- RA TAG 9350' PERFORATION SUMMARY REF LOG: SWS CNL/GR/CCL 49/30(08 ANGLE AT TOP PERF: 91 ` @ 10,250' Note: Refer to Fraduction DB far historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 2" 6 10250 - 10650 O 09/29108 PBTD 9725' 7" LNR, 29#, L-80, ID = 6.184" 9$54' TD 9$57' 3-3/16" LNR, 6.2#, L-80 TGII, .0076 bpf, ID = 2.80" 10200' 10202° ~-{ 3-1116" X 2-7/8" XO, ID = 2.377" I PBTD I-I 10707° 10743° f-12-7/8" LNR,6.4#, L-80 STL, .0058 bpf, ID = 2.441" DATE REV BY COMMENTS DATE REV BY COMMENTS 10120/82 ORIGINAL COMPLETION 12/09/02 PH/KAK RWO 09!30!08 NORDIC 2 CTD SIDETRACK (01-21 A) 10/03/08 ITCH CORRECTIONS 10!12/08 DAV/PJC GLV C/O (10/08/08) 08124!09 CR/JMD DRLG DRAFT CORRECTIONS PRUDHOE BAY UNIT WELL: 01-21A PERMIT No: 2081310 API No: 50-029-20827-01 SEC 5, T10N, R15E, 4860.05' FEL & 2871.08' FNL BP Explaration (Alaska) ~ ~ INTEQ Log & Data Transmittal Form To: State of Alaska -AOGCC 333 W. 7~" Ave. Suite 100 Anchorage, Alaska 99501 Attention: Christine Mahnken Reference: Ol-21A Contains the following: 1 LDWG Compact Disc (Includes Graphic Image files) 1 LDWG lister summary 1 color print - GR Directional Measured Depth Log (to follow) 1 color print - GR Directional TVD Log (to follow) LAC Job#: 2213107 Sent by: Terri Tuminello Date: 01/26/09 ~ ~' ,: -, , Received by: Date: g ~~n ~ ~„~ ~ ~atG PLEASE ACKNOWLEDGE RECEIPT BY SIGN '~ ~ ~ RNING OR FAXING YOUR COPY FAX: (907) 267-6623 ItVTEQ Baker Hughes INTEQ 7260 Homer Drive Anchorage, Alaska 99518 Direct: (907) 267-6612 FAX: (907) 267-6623 ~p~-i3 l ~~ ~b I M~J6NES Baker Atlas PRINT DISTRIBUTION LIST COMPANY BP EXPLORATION (ALASKA) INC COUNTY NORTH SLOPE BOROUGH WELL NAME 01-21A STATE ALASKA FIELD PRUDHOE BAY UNIT DATE 1/26/2009 THIS DISTRIBUTION LIST AUTHORIZED BY: Terri Tuminello SO #: 2213107 Copies of Copies Digital Copies of Copies Digital Each Log 2 of Film Data Company BP EXPLORATION (ALASKA) INC Each Log 1 of Fihn Data Company DNR -DIVISION OF OIL & GAS Person PETROTECHNICAL DATA CENTER Person KRISTIN DIItKS Address LR2-1 Address 550 WEST 7TH AVE 900 E BENSON BLVD. SUITE 802 ANCHORAGE. AK 99508 ANCHORAGE. AK 99501 1 Company EXXON MOBIL PRODUCTION CO Company Person FILE ROOM Person Address 800 BELL STREET Address EMB GSC 3082A HOUSTON, TX 77002 1 Company STATE OF ALASKA - AOGCC Company Person CHRISTINE MAHNKEN Person Address 333 W. 7TH AVE Address SUITE 100 ANCHORAGE. AK 99501 Company Company Person Person Address Address Company Company Person Person Address Address Data Disseminated By BAKER ATLAS-PDC 17015 Aldine Westfield, Houston, Texas 77073 This Distribution List Completed Bv: ~~-l31 Page 1 of 1 ~~ Date 12-12-2008 Transmittal Number:93025 ~~~ ~. ~. ,~;.. ~: ~~ BPXA WELL DATA TRANSMITTAL Enclosed are the materials listed below. (BPXA FIELD LOG DATA} If you have any questions, please contact Douglas Dortch at the PDC at 564-4973 Delivery Contents 1 CD-ROM Containing Field Log Data & Electronic Log Prints for the following wells: 01-21 A 18-24B N-14B N-14BPB1 Y-05BP61 Y-09AL1 Y-09AL1-01 .~-~ ,,; Please ~~ign and Return one copy of this transmittal. Thank You, Douglas Dortch Petrotechnical Data Center Attn: State of Alaska - AOGCC Attn: Christine Mahnken 333 W. 7th Ave, Suite 100 Anchorage, Alaska 99501 ~~~.--l=/;~ ~~'-its` ~ ~~ ~-t ~ 1 G,~ - t ~~ i ^fi~ t ~~~" t~'J l~~/~7~'/ Petrotechnical Data Center LR2-1 900 E. Benson Blvd. PO Box 196612 Anchorage, AK 99519-6612 12/08/08 Sshlumherger NO. 4995 Alaska Data & Consulting Services Company: State of Alaska 2525 Gambell Street, Suite 40o Alaska Oil & Gas Cons Comm Anchorage, AK 99503-2838 Attn: Christine Mahnken ATTN: Bethi 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Well Jnh # 1 nn npscrintinn n~ro Rr r.,i... r•n li I• R-03A 4994 INJECTION PROFILE (REVISED) 10/08/08 1 1 13-23A 4994 INJECTION PROFILE 10/21/08 1 1 01-26A 4994 SCMT 11/13!08 1 1 D-29 4994 USIT 10/19/08 1 1 15-028 4994 MEM PROD PROFILE - 11/25/08 1 1 H-05A 4994 MEM PROD & INJ PROFILE 11/20/08 1 1 E-32A 4994 SCMT ( 11/04/08 1 1 12-17 4994 PRODUCTION LOG O C-/ 11/04!08 1 1 P2-41 4994 PRODUCTION LOG - 11/07/08 1 1 1-29/M-25 4994 PRODUCTION LOG (p _ 11/04/08 1 1 MPC-05A 4994 MEM LDL r 11/15/08 1 1 L-114A 4994 USIT ~- r- ( j 11/03/08 1 1 A-07 4994 PRODUCTION PROFILE ~ - ( ~ 11/27/08 1 1 07-18 4994 INJECTION PROFILE ~- - 12/02/08 1 1 15-126 4994 MEM PROD PROFILE - (p - Q ~ 11/27/08 1 1 4-40/P-43 4994 MEM LDL i9 ' - '~' , C;r ' 11/26/08 1 1 N-14B 4994 MCNL --(~'~~ ~ 09/20/08 1 1 01-21A 4994 MCNL 09/29/08 1 1 E-29A 4994 MCNL - 09/01/08 1 1 of GACC Af•Ilw1A\1111 rnnr n BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 ii ':? Date Delivered: Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503 8 8 ATTN: Beth Received by: C_~ C~ ~~~ BJIKER i~[lGNFS ~~~~ 7260 Homer Drive Anchorage, AK 99518 To Whom It May Concern: November 14, 2008 `Please find enclosed directional survey data for the following wells: N-14BPB1 N-14B Ol-21A Y-09AL1 Y-09AL1-O1 Enclosed for each well is: tea copies of directional survey reports 1 ea 3.5" floppy diskette containing electronic survey files Please sign and return one copy of this transmittal form to: BP Exploration (Alaska) Inc. Petrotechnical Data Center, LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 to acknowledge receipt of this data. RECEIVED BY: ~~~ _, State of Alaska AOGCC DATE: ~ ~ Cc: State of Alaska, AOGCC d ~ '~~~ ~ ~ Maunder, Thomas E (DOA) From: Reynolds, Charles [Charles.Reynolds@bp.com] Sent: Monday, November 10, 2008 10:24 AM To: Maunder, Thomas E (DOA) Subject: RE: DS 01-21A (208-131) Tom, Page 1 of 1 I apologize that our change in operations had not previously been relayed to you. Since May of this year we have been using a new liner running tool on our big hole (3-3/16" x 2-7/8") liner jobs. This new tool was developed to allow us to use coil with the eline in place to run and cement the liner, thereby saving us the task of swapping reels. The tool has been used on K-04C, G-15B, 13-30C, 02-25A, E-29A, N-146 which were all completed prior to 01-21A, and recently on 18-06, G-02 and Y-05. From this point forward this should be our standard liner running procedure. If you have any additional questions, or would like any additional information please feel free to contact me. Charles Reynolds BP Alaska Coil Tubing Drilling Ph: (907) 564-5480 Cell: (907) 575-6234 Email: Charles.Reynolds@BP.com From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov] Sent: Monday, November 10, 2008 9:37 AM To: Reynolds, Charles Cc: McMullen, John C Subject: DS 01-21A (208-131) Charles, I am reviewing the operations report submitted with the completion report. When the liner was run and cemented 9/28 - 9/29, was the a-coil used for this? On other CT liner operations, I believe that the coils were changed out but I don't find any mention of that operation in this case. Could you provide further information to help me understand what occurred on this well? Thanks in advance. Tom Maunder, PE AOGCC 11/10/2008 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION ;~ ~ ~ ~ 200$ WELL COMPLETION OR RECOMPLETION REPORT AND LOG ~ ~'~~ n _ ~~ ~. 60th 1a. Well Status: ®Oil ^ Gas ^ Plugged ^ Abandoned ^ Suspended 1b. Well Class: ~;;;,_,~,., t,~ zoAAC zs.los zoAAC zs.11o ®Development ~loratory ^ GINJ ^ WINJ ^ WDSPL ^ WAG ^ Other No. of Completions One ^ Service ^ Strati raphic 2. Operator Name: 5. Date Comp., Susp., or Aban,,d,~i 12. Permit to Drill Number BP Exploration (Alaska) Inc. 9/30/2008 ' !~''" 208-131 3. Address: 6. Date Spudded 13. API Number P.O. Box 196612, Anchorage, Alaska 99519-6612 9/25/2008 ' 50-029-20827-01-00 4a. Location of Well (Governmental Section): 7. Date T.D. Reached 14. Well Name and Number: Surface: 9/28/2008 ~ PBU 01-21A 401' FNL, 506' FWL, SEC. 08, T10N, R15E, UM Top of Productive Horizon: 8. KB (ft above MSL): 74' 15. Field /Pool(s): 2575' FNL, 76' FWL, SEC. 05, T10N, R15E, UM Ground (ft MSL): 39.98' Prudhoe Bay Field / Prudhoe Bay Total Depth: 9. Plug Back Depth (MD+TVD) Pool 1934' FNL, 4985' FWL, SEC. 06, T10N, R15E, UM 10707' 9054' 4b. Location of Well (State Base Plane Coordinates, NAD 27): 10. Total Depth (MD+TVD) 16. Property Designation: Surface: x- 697828 y- 5940499 Zone- ASP4 10743' ~ 9056' ADL 028329 TPI: x- 697306 y- 5943592 Zone- ASP4 11. SSSV DeN A(MD+TVD) 17. Land Use Permit: Total Depth: x- 697172 y- 5944229 Zone- ASP4 18. Directional Survey ®Yes ^ No 19. Water depth, if offshore 20. Thickness of Permafrost (TVD): mi I r ni n rin in rm i n r AA N/A ft MSL 1900 (Approx.) 21. Logs Obtained (List all logs here and submit electronic and printed information per 20 AAC 25 071): MWD, DIR, RES, MCNL / GR / CCL, ROP /Press / Res L,//it/~Ohl~ 93 .6iyD ~~6~ ~ ~~~ 22. CASING, LINER AND CEMENTING RECORD CASING SETTING DEPTH MD SETTING DEPTH TVD HOLE AMOUNT WT. PER FT. GRADE TOP BOTTOM TOP BOTTOM SIZE CEMENTING RECORD PULLED 1. -4 rf 1 # P e " 2200 sx ColdSet III 400 sx ColdSet II - / " 47 rf rf -1 4" I I 7" L-80 77 ' 7 2' -1/ " I 3-1/2" x 3-3/16" ' 7 ' ' " ' x 2-7/8" / 23. Open to production or injection? ®Yes ^ No 24. TuawcRECORD If Yes, list each interval open SIZE DEPTH .SET MD PACKER .SET MD (MD+TVD of Top 8 Bottom; Perforation Size and Number): 2" Gun Diameter, 6 SPF 4-1/2", 12.6#, 13-Cr 8830' 8678' MD TVD MD TVD 10250' - 10650' 9055' - 9052' 25. ACID, FRACTURE, CEMENT .SQUEEZE, ETC. DEPTH INTERVAL MD AMOUNT S~ KIND OF MATERIAL USED Freeze Protected with 31 Bbls of Diesel 26. PRODUCTION TEST Date First Production: Method of Operation (Flowing, Gas Lift, etc.): October 18, 2008 Gas Lift Date Of Test: HOUrS Tested: PRODUCTION FOR OIL-BBL: GAS-MCF: WATER-BBL: CHOKE SIZE: GAS-OIL RATIO: 10/16/2008 6 TEST PERIOD 58 184 114 48 3155 Flow Tubing Casing Press: CALCULATED OIL-BBL: GAS-MCF: WATER-BBL: OIL GRAVITY-API (CORK): Press. 24-HOUR RATE..' 233 735 455 27. CORE DATA Conventional Core(s) Acquired? ^Yes ®No Sidewall Cores Ac wired? ^Yes ®No If Yes to either question, list formations and intervals cored (MD+TVD of top and bottom of each), and summarize lithology and presence of oil, gas or water (submit separate sheets with this form, if needed). Submit detailed descriptions, core chips, photographs and laboratory analytical results per 20 AAC 250.071. None ,~~~~ ' "t008 9.~~''~~ „' ._ .7.. FOrm 10-407 ReVISed 02/2007 CONTINUED ON REVERSE SIDE ~ ~`'+~ ~ ~ t ~~'~~t~ / L8. GEOLOGIC MARKERS (LIST ALL FORMATIONS AND RS ENCOUNTERED): 29. FORMATION TESTS NAME MD TVD Well Tested? ^ Yes ®No Permafrost Top If yes, list intervals and formations tested, briefly summarizing test results. Attach separate sheets to this form, if needed, and submit Permafrost Base detailed test information per 20 AAC 25.071. Top of CGL 9393' 8807' None Base of CGL 9457' 8862' Top 23S6 /Zone 26 9578' 8955' 22TS 9613' 8979' Top 21 TS /Zone 2A 9682' 9017' HOT 9975' 9065' HOT (Inverted) 10085' 9064' Base 21TS /Zone 2A 10085' 9064' Formation at Total Depth (Name): Base 21 TS /Zone 2A 10085' 9064' 30. List of Attachments: Summary of Daily Drilling Reports, Well Schematic Diagram, Surveys 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. t~ Signed Sondra Ste Title Drilling Technologist Date ~ ~ ~ - ~~ PBU 01-21A 208-131 Prepared ByName/Number. Sondra Stewman, 564-4750 Well Number Permit No. / A rOV81 NO. Drilling Engineer: Charles Reynolds, 5645480 INSTRUCTIONS GeNeRAL: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. ITEM 1a: Classification of Service Wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. IreM 4b: TPI (Top of Producing Interval). IreM 8: The Kelly Bushing and Ground Level elevation in feet above mean sea level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. IreM 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). IreM 20: Report true vertical thickness of permafrost in Box 20. Provide MD and TVD for the top and base of permafrost in Box 28. IreM 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. IreM 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). IreM 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, or Other (explain). IreM 27: Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Submit detailed description and analytical laboratory information required by 20 AAC 25.07E IreM 29: Provide a listing of intervals tested and the corresponding formation, and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Form 10-407 Revised 02/2007 Submit Original Only . TREE= '. U~IEILHEA D = FMC AGTUATDR = AXELSON KB. ELEV = 74` BF. ELEV = 28' _ KOP = 2940' Max Angle - . ;.~ ~> ~ 1~~~?` DatumMD= 9463' dotum TV D = 8800' SS DItLG DRAFT O7 -21 A SAFETY' NC7TES: CHRt7ME TBG. 13-318'° GSG, 72#, L-80, Id = 12.347" (~ ~"~'/'~' 2185" 4-1 /2" NES X NIP, Id = 3.813" GA S L IFT MANDRELS ST Md 1V d DEl/ TYPE V LV FA 7CH PORT DATE S 3001 2~7 15 MMG DMY RK ~ 12~'14l02 4 3768 3719 21 MMG DC)~r7 RK 1G 10?OF3~'QS +~~~~ 5396 29 arru» so RK 24 1 oloaro8 2 7978 7499 26 MMG DMY RK t) 12(09102 1 8596 81}62 22 14tWIG dMY RK 0 12!09/02 8fi58` --~~-~ rz" ~~s x NVP, iD = 3.813° Sfi7$' N 9-518" X4-1/2" BKR S-3 PKR, ID= 3.875" -;,-~ Tt7P I° LIP~ER TUP l3F 7" LNR 4112° Fll=s x NIP, IQ = a.s1 ~° 1 8817' - 4112'° rlES xN NIP, ID gilled t~ - 3.80" 4112" TBG, 12.G#, ~~-cat, 8829' gg3p' 4112" u~EG, ID = ~ a~ .x152 bpf, III = 3.95H" 9-518" CSG, 47#, L-80, IL7 = 8,689°' 9f169' r- PERF(3RATIQN ~"~.,r:1MARY REF LQG:a'S ANGLEATTOPF~FRI" -. (i ' .? ,. Nate; Refer to Prod~.tction ~Lt for hfstoncal peel data S(ZE SPF ~,I.1L :`C'AL Opn/Sgz L7ATE 0 1 - C7 ~s-rn 97zs 7'" LNR 29#, L-8b, 1~3 6 184" 9854' 985T DATE.... REV BY GC7MtlENTS DATE REV BY GgNAtAENTS 1©i2U/82 C1121GENAL GLIMPLETIQN 12{09102 Ptir'KAK RWO Q913U108 NOF~C3lC1 GTQ S1C7ETRACK {01-21A) 10103/08 ITLH GC)RRECTIONS 1(711 ^l08 DAV/PJG GLV C1C7 (10?081fI8) PRUDHC7E BAY UNff V+IELL: 01-29 A PERMTI` Ng: `2081310 API No: 50-t?29~-217827-01 5EG 5, T10N, R15! 4860 OS' FEL ~ 2871.Q8' FNL BP Eacplcrration (Alasl~a~ BP EXPLORATION Page 1 of 7 Operations Summary Report Legal Well Name: 01-21 Common Well Name: 01-21 Spud Date: 10/2/1982 Event Name: REENTER+COMPLETE Start: 9/22/2008 End: 9/30/2008 Contractor Name: NORDIC CALISTA Rig Release: 9/30/2008 Rig Name: NORDIC 2 Rig Number: Date From - To ~~ Hours Task ~' Code I NPT II Phase 'I Description of Operations 9/22/2008 10:00 - 14:30 4.50 MOB P PRE Prep to lower derrick. Slop injector. Lower gooseneck. Hold PJSM. Scope derrick. Open pipe shed roof. Lower derrick. 14:30 - 00:00 9.50 MOB P PRE Move from N Pad towards DS 1. 9/23/2008 00:00 - 06:00 6.00 MOB P PRE Move via West Dock Rd to DS 1. 06:00 - 14:00 8.00 MOB P PRE Spot rig on back pad. Prep to raise derrick. 14:00 - 15:00 1.00 MOB P PRE Remove tree cap. Move rig over tree and set down. Accept rig at 1400 hrs 9/23/08 15:00 - 20:00 5.00 BOPSU P PRE Nordic NU BOPE. SWS load in used 2-3/8 E-CT reel from N-14 (HS90, FF) MI RU satellite office. Set welding shack. RU Tiger tank. Get BOP measurements. RU Handy berm. Grease mud manifold valves, choke valves, reel valves & mud cross valves. Function test BOPE. Fill stack w/ water & shell test. 20:00 - 22:00 2.00 BOPSU N SFAL PRE Tighten tree flange bolts from adaptor spool on upwards, including the blind flange on the wing valve. 22:00 - 22:30 0.50 BOPSU P PRE Fill stack w/ water & shell test. Blow down stack & replace choke line grey lock. Re-test -good. 22:30 - 00:00 1.50 BOPSU P PRE BOPE test 250psi/3500psi per AOGCC regs. Lou Grimaldi waived witness. Load pits w/ 2% KCL & 2ppb biozan water, stinger in safe tube. 9/24/2008 00:00 - 02:00 2.00 BOPSU P PRE Continue to test BOP's. 02:00 - 03:00 1.00 BOPSU N SFAL PRE Upper 2-3/8" combi rams failed to test. PJSM. Blow down stack. Open ram doors & replace rams. Rubber goods appear to be in excellent condition w/ no tears or marks. Inspect ceramic coating inside BOP's, appears to be ok but minor cracking. Ram guide is slightly disfigured, file it to like new condition. Install new rubber goods on rams & reinstall. Fill stack with water. 03:00 - 03:30 0.50 BOPSU P PRE Complete BOP test per AOGCC regs -PASS. 03:30 - 05:40 2.17 RIGU P PRE PJSM regarding RU injector & stabbing coil. PU & place stuffing box onto well. PU injector & stab onto & pin into stuffing box. Hook up stuffing box hoses. Run stabbing winch cable across roof & into injector chains & install onto winch drum. Pull test grapper connector & retighten. Remove shipping bar. 05:40 - 07:15 1.58 RIGU P PRE Pull coil across & stab into the injector. Stab onto well. 07:15 - 10:30 3.25 RIGU P PRE Rev circ coil filling w/ rig water. Pump slack into the reel PT packoff and inner reel valve as part of BOPE test Cut off 365' of CT before finding wire 10:30 - 12:30 2.00 STWHIP P WEXIT MU SWS 16 dimple CTC (twice). PT 40k# and PT 4kpsi between seals Head up BHI. PT 4000 psi 12:30 - 13:00 0.50 STWHIP P WEXIT Attempt to open swab valve w/o success Pump slack forward w/ FW 3.0/2050 to bunghole while wo Valve crew 13:00 - 13:45 0.75 STWHIP P WEXIT Fin wo Valve crew to open grease locked swab. Open swab and MV and check well for pressure-none 13:45 - 13:55 0.17 STWHIP P WEXIT Safety mtg re: MU milling BHA 13:55 - 14:40 0.75 STWHIP P WEXIT MU window milling BHA 14:40 - 16:40 2.00 STWHIP P WEXIT RIH w/ BHA #1 (3.80" window mill + SR) circ KCI w/ 2ppb j fir- ~ biozan thru mill 0.45/340 taking returns to tiger tank 16:40 - 17:20 0.67 STWHIP P WEXIT 9250' 37.1 k, 25.8k RIH 0.5/590 and tag at 9365.3 rnncea: iw°rzuu° c w:cy rm • BP EXPLORATION Page 2 of 7 Operations Summary Report Legal Well Name: 01-21 Common Well Name: 01-21 Spud Date: 10/2/1982 Event Name: REENTER+COMPLETE Start: 9/22/2008 End: 9/30/2008 Contractor Name: NORDIC CALISTA Rig Release: 9/30/2008 Rig Name: NORDIC 2 Rig Number: i Date From - To Hours Task I~' Code ~ NPT ~, Phase ~ Description of Operations 9/24/2008 16:40 - 17:20 0.67 STWHIP P WEXIT PUH w/ 3k overpull. Start motor 2.55.1880 and ease in hole looking for pinch point. First MW at 9364.8'. Corr to 9344.6' and flag Biozan back to surface, start keeping returns PVT 167 17:20 - 23:00 5.67 STWHIP N HMAN WEXIT Mill window from 9344.6' 2.52/2076 Mill to theoretical exit point with zero WOB & no visible stacking at surface & no increase in CT psi during the entire milling ops. No visible amount of metal coming across the shaker, slight metal on the ditch magnets. Circulate bottom's up while milling at same speed. Wiper up & down & consult town. 23:00 - 00:00 1.00 STWHIP P WEXIT Continue to mill per SOP's from 9353ft 2.52bpm ~ 2060psi, 0 WOB. Mill 10ft of theoretical rat hole while looking at samples. 9/25/2008 00:00 - 00:45 0.75 STWHIP P WEXIT Continue to mill 10ft of rathole. Seeing 100psi motor work & 0.1 k WOB at 9356.5ft. stop milling &PUH. No formation in last sample. Resume milling from 9356.5ft with 3 stalls in a row. 00:45 - 09:00 8.25 STWHIP P WEXIT Mill at 0.1fU6min from 9357.7ft, 2.52bpm ~ 2260psi (200psi motor work), 2-2.5k WOB. Samples show an increase in metal. At 9363.5' had incr in MW then lost wt and dill and assume BOW 09:00 - 11:15 2.25 STWHIP P WEXIT Drill o en hole to 9374' and see sand and chert in sam les 11:15 - 12:20 1.08 STWHIP P WEXIT Ream and backream window until clean while swap to fresh Flo Pro mud. Dry tag was clean 12:20 - 14:00 1.67 STWHIP P WEXIT POOH circ 2.74/2640 thru mill while fin displ wellbore to mud 14:00 - 14:30 0.50 STWHIP P WEXIT LD milling assy. Mill gauged 3.77" NG, SR 3.79" 14:30 - 15:55 1.42 DRILL P PROD1 MU build assy PVT 280 15:55 - 17:35 1.67 DRILL P PROD1 RIH w/ BHA #2 (1.8 deg motor w/ bi bit). circ thru EDC 0.35/720 17:35 - 18:30 0.92 DRILL P PRODi Log tie-in down from 9170' (-36ft corr. 18:30 - 23:20 4.83 DRILL P PRODi Drill build section from 9360 ft. Op=2.50/2.50 bpm ~ 2550 psi Density=8.58/8.63 ppg DH Press=4315 psi ECD=9.50 ppg DH W06=1.5k-3k ROP= 25-45 fph PV=326 bbls Drilled to 9500 ft. Centrifuge the mud. 23:20 - 23:40 0.33 DRILL P PRODi Wiper to the window. Pull through the window -clean. Open EDC &PUH to 9170ft. 23:40 - 00:00 0.33 DRILL P PROD1 Log down for tie-in (Oft corr. RIH to 9380ft. Log RA tag in whipstock. 9/26/2008 00:00 - 00:10 0.17 DRILL P PROD1 Continue to log RA tag (9350ft). 00:10 - 00:15 0.08 DRILL P PROD1 Wiper to TD at min rate. 00:15 - 02:55 2.67 DRILL P PROD1 Drill build section from 9500 ft. Op=2.50/2.50 bpm ~ 2500 psi Density=8.57/8.68 ppg DH Press=4373 psi ECD=9.59 ppg DH WOB=1.5k-2.5k ROP= 40-75 fph PV=334 bbls Drilled to 9650 ft. 02:55 - 03:20 0.42 DRILL P PROD1 Wiper to the window. 03:20 - 06:45 3.42 DRILL P PROD1 Drill build section from 9650 ft. Op=2.50/2.50 bpm ~ 2900 psi Density=8.61/8.70 ppg DH Press=4464 psi ECD=9.66 ppg rnntea: twti¢uus zasza rnn r~ L BP EXPLORATION Page 3 of 7 Operations Summary Report Legal Well Name: 01-21 Common Well Name: 01-21 Spud Date: 10/2/1982 Event Name: REENTER+COMPLETE Start: 9/22/2008 End: 9/30/2008 Contractor Name: NORDIC CALISTA Rig Release: 9/30/2008 Rig Name: NORDIC 2 Rig Number: Date From - To ~~~ Hours Task Code', NPT ~~ .Phase ~~ Description of Operations - - __ 9/26/2008 03:20 - 06:45 3.42 DRILL P PROD1 DH WOB=1.5k-2.5k ROP= 40-75 fph PV=326 bbls Penetration slowed to 20'/hr by 9700' 06:45 - 08:25 1.67 DRILL P PROD1 Incr in penetration rate at 9702' and assume Z2A top. Drill 2.50/2880/30L w/ 100-200 psi dill, 1.5-2.Ok wob w/ 9.68 ECD at 64 deg NBI while continue the build. Drill to 9800' 08:25 - 09:00 0.58 DRILL P PROD1 Wiper to window was clean both directions 09:00 - 10:30 1.50 DRILL P PROD1 Drill from 9800' 2.50/2870/308 w/ 100-200 psi dill, 1.0-2.Ok wob w/ 9.71 ECD at 77 deg NBI while finish the build. Lay TF over to land at 88 deg to search for HOT. Begin catching 25' samples. Drill to 9900' (8986' TVD) PVT 320 10:30 - 11:20 0.83 DRILL P PROD1 100' wiper after NBI showed 89 deg and stops on orientor were in the wrong spot. Drill from 9900' w/ 90-1208 TF to keep dropping to 8992' TVD target. Drill to 9918'. Do another 100' wiper (sticky just off btm at 9900') to readjust TF due to position of stops. Drill to 9950' 11:20 - 12:10 0.83 DRILL P PROD1 W iper to window with 20k OP again at 9900'. No wt loss or MW on wiper in hole. Mud color is darker and appears we are in the HOT now PVT 315 12:10 - 12:35 0.42 DRILL P PRODi Drill from 9950' 2.4/2670/808 w/ 100-150 psi dill, 1.0-1.5k wob w/ 9.74 ECD and control drill at 120'/hr. Drill to 10000' and appear to be in heavy oil sands PVT 310 12:35 -.13:10 0.58 DRILL P PROD1 Wiper to window to circ up samples w/ minor OP at 9900' 13:10 - 13:20 0.17 DRILL P PROD1 Log tie-in down from 9380', Corr +1' 13:20 - 13:40 0.33 DRILL P PROD1 Wiper back to TD was clean PVT 310 Found HOT in 9975' sample 13:40 - 14:00 0.33 DRILL P PROD1 Drill from 10002' 2.56/2750/208 w/ 100-200 psi dill, 1.0-2.Ok wob w/ 9.78 ECD and build to 92 deg to get set up for invert. Drill to 10035' PVT 305 14:00 - 14:30 0.50 DRILL P PROD1 Wiper thru window was clean 14:30 - 16:30 2.00 DRILL P PROD1 POOH for lateral ass circ thru EDC 3.3/3000 16:30 - 20:20 3.83 DRILL P PROD1 LD build assy. Inspect bit 5-1 & starting to core out on the snout, removed 2 pieces of rubber (suspect stator rubber). MU new 2 7/8" mud motor w/ 1.3deg & rebuilt HYC bit. Simultaneously, SLB is adjusting the injector. Place MM in hole & MU coil track tools to same. Stab coil into tools & stab onto well. Tag up. Power up tools. Set counters. 20:20 - 22:10 1.83 DRILL P PROD1 RIH, circ through bit at min rate. 22:10 - 23:05 0.92 DRILL N SFAL PROD1 BOT depths are 20ft difference. Repair BOT encoder (love joy connector). 23:05 - 23:20 0.25 DRILL P PROD1 Log down for tie-in (-35ft corr. 23:20 - 23:50 0.50 DRILL P PROD1 Wiper to TD. Lost 3bbls on trip in hole. 23:50 - 00:00 0.17 DRILL P PROD1 Drill lateral section from 10,035 ft. Op=2.50/2.48 bpm ~ 2850 psi Density=8.64/8.70 ppg DH Press=4575 psi ECD=9.80 ppg DH WOB=0.75k-1.25k ROP= 50-75 fph PV=294 bbls 9/27/2008 00:00 - 02:30 2.50 DRILL P PROD1 Drill lateral section from 10,055 ft. Op=2.50/2.48 bpm ~ 2850 psi Density=8.64/8.70 ppg DH Press=4575 psi ECD=9.80 ppg DH WOB=0.75k-1.25k ROP= 50-75 fph PV=294 bbls t'nntea: tatirzuurs e:tsry rnn • BP EXPLORATION Page 4 Of 7 Operations Summary Report Legal Well Name: 01-21 Common Well Name: 01-21 Spud Date: 10/2/1982 Event Name: REENTER+COMPLETE Start: 9/22/2008 End: 9/30/2008 Contractor Name: NORDIC CALISTA Rig Release: 9/30/2008 Rig Name: NORDIC 2 Rig Number: Date From - To Hours Task '~ Code ~ NPT ', Phase Description of Operations 9/27/2008 100:00 - 02:30 2.501 DRILL P PROD1 02:30 - 02:35 0.08 DRILL P PROD1 02:35 - 04:55 2.33 DRILL P PROD1 04:55 - 05:25 0.50 DRILL P PROD1 05:25 - 06:15 0.83 DRILL P PROD1 06:15 - 06:50 0.58 DRILL P PROD1 06:50 - 07:40 0.83 DRILL P PROD1 07:40 - 08:10 0.50 DRILL P PROD1 08:10 - 10:00 1.83 DRILL P PROD1 10:00 - 11:05 ~ 1.08 ~ DRILL ~ P ~ ~ PROD1 11:05 - 12:30 1.421 DRILL P PRODi 12:30 - 13:05 0.58 DRILL P PROD1 13:05 - 13:15 0.17 DRILL P PROD1 13:15 - 13:45 0.50 DRILL P PROD1 13:45 - 15:35 1.83 DRILL P PROD1 15:35 - 16:15 0.67 DRILL P PROD1 16:15 - 16:45 0.50 DRILL P PROD1 16:45 - 17:00 0.25 DRILL P PROD1 17:00 - 17:35 0.58 DRILL P PROD1 17:35 - 17:55 0.33 DRILL P PROD1 17:55 - 20:00 ~ 2.08 ~ DRILL ~ N ~ STUC PROD1 20:00 - 21:10 1.171 DRILL ~ N STUC PROD1 21:10 - 22:45 1.58 DRILL P PROD1 22:45 - 22:55 0.17 DRILL P PROD1 22:55 - 23:50 0.92 DRILL P PROD1 23:50 - 00:00 0.17 DRILL P PROD1 Surface temp = 96 BHCT = 140 Drill to 10,185ft Wiper to 10,070ft. MAD pass up from 10,070ft to 9360ft f~ 300ft/hr. PUH & log down across RA marker for tie-in (-2ft corr). Wiper to TD -clean. Drill lateral section from 10,185 ft. Op=2.50/2.48 bpm ~ 2750 psi Density=8.68/8.77 ppg DH Press=4615 psi ECD=9.90 ppg DH W06=0.75k-1.25k ROP= 40-100 fph PV=286 bbls Drill to 10,239ft Wiper while replace swab in pump #1 Pull thru window and perform injector maint Wiper back to TD while fin repair pump #1 PVT 289 Drill from 10238' 2.50/2670/908 w/ 100-200 psi dill, 0.5-1.5k wob w/ 9.88 ECD and hold 90 deg at 8980' TVD. Control drill at 120'/hr w/frequent PU's due to dill sticking. Drill to 10400' while fin repair of pump #1 PVT 284 Wiper to window was clean. Test pump #1. Wiper to TD was clean PVT 276 Drill from 10400' 2.48/2650/608 w/ 100-400 psi dill, 0.7-1.8k wob w/ 9.91 ECD holding at 8980' TVD. Control drill at 150'/hr to 10440'. Swap to left side and drill to 10550' Wiper to window was clean Log tie-in down to RA marker, corr -5' Wiper to TD was clean PVT 272 Drill from tag at 10548' 2.51/2700/25L w/ 100-350 psi dill, 1.0-1.8k wob w/ 9.96 ECD and target 8978' TVD since HOT was seen in samples. Penetration rate slowed after 10600' and acts like formation change. See mudstone in samples so drop TF back to target 8980' TVD. Drill to 10660' PVT 272 Wiper to window was clean Open EDC and jet 7" liner solids 3.90/3650 to EOT. RBIH Log tie-in down from 9200', corr -3' Close EDC. Wiper to TD while start swap to fresh mud Drill from 10660' 2.49/2560/110L w/ 100-400 psi dill, 1.0-2.Ok wob w/ 9.80 ECD while drop back to 8982' TVD and fin swap to fresh mud. Drill to 10673' PUH 36k to survey. Red pump rate while RIH. Stacked wt 15: off btm, PUH and were stuck. Cycle a few times up to 20k over, then stack wt and SD pump for crew changeout Cycle 4 times while working up to 75k, -aft of travel. PU to neutral & pump. Yo-yo pumps & pull, then try to pressure up backside to 500psi & pull. Order crude. Wait on crude. Mix & pump hi-vis pill. Seeing loss of wt while pum ing pill become impatient, pull free ~ 70k. Wiper to the window -clean. Open EDC. Log down for tie-in from 9170ft (+2ft corr). W iper to TD -clean. Drill lateral section from 10,673 ft. Op=2.68/2.68 bpm ~ 2880 psi Nrinted: twtiauuts zas:zarwi • • BP EXPLORATION Page 5 of 7 Operations Summary Report Legal Well Name: 0 1-21 Common W ell Name: 0 1-21 Spud Date: 10/2/1982 Event Name : R EENTE R+COM PLET E Start : 9/22/2008 End: 9/30/2008 Contractor Name: N ORDIC CALIST A Rig R elease: 9/30/2008 Rig Name: N ORDIC 2 Rig N umber: Date From - To Hours I Task Code NPT Phase Description of Operations 9/27/2008 23:50 - 00:00 0.17 DRILL P PRODi Density=8.62/8.64 ppg DH Press=4478 psi ECD=9.61 ppg DH WOB=1.75k-2.5k ROP= 75-100 fph PV=245 bbls Drill to 10,687ft. 9/28/2008 00:00 - 01:10 1.17 DRILL P PROD1 Drill lateral section from 10,687 ft. - Op=2.61/2.61 bpm ~ 2750 psi Density=8.61/8.64 ppg DH Press=4525 psi ECD=9.71 ppg DH W06=1.75k-2.5k ROP= 75-100 fph PV=245 bbls Drill to 10,750ft. 01:10 - 03:40 2.50 DRILL P PROD1 MAD pass up from TD to 10,060ft. 03:40 - 04:05 0.42 DRILL P PROD1 Wiper to the window. PUH to 9200ft. 04:05 - 04:35 0.50 DRILL P PROD1 Log down for tie-in (-2ft corr. 04:35 - 05:35 1.00 DRILL P PROD1 Wiper to TD, pump 40 bbl 120k LSRV liner pill while RIH. Taa . final TD twice hard at 10 74 ft.i 05:35 - 06:30 0.92 DRILL P PROD1 POH, lay in 120k LSRV liner pill. 06:30 - 08:15 1.75 DRILL P PROD1 POH from window circ thru bit 2.3/2250 Flag at 8421' EOP 08:15 - 09:00 0.75 DRILL P PROD1 LD drilling BHA 09:00 - 10:30 1.50 CASE P RUNPRD Cut off CTC. RU hyd cutter and cut off 98' of CT due to wear. Pump out 301' of eline to bung hole 10:30 - 11:15 0.75 CASE P RUNPRD Dress end of CT and wire and install BTT CTC. PT 40k, 4kpsi 11:15 - 11:45 0.50 CASE P RUNPRD Set inj on legs. RU to run liner 11:45 - 12:15 0.50 CASE P RUNPRD Safety mtg/crew change out of Nordic crews 12:15 - 16:00 3.75 CASE P RUNPRD MU Uni ue Indexin Guide Shoe + float a ui ment w/ 17 'ts 2-7/8" 6.4# L-80 STL, 31 jts 3-3/16" 6.2# L-80 TC11, 14 jts 3-1/2" 9.2# L-80 STL liner. MU BTT SELRT assy 16:00 - 17:05 1.08 CASE P RUNPRD MU MHA + 4 jts 2-3/8 PH6 17:05 - 19:40 2.58 CASE P RUNPRD RIH w/liner on CT circ 0.35/1350 WT ck at 9300ft, 43k up & 29k down. RIH past window was clean. Speed bump at 9825ft. PU & correct to the flag. Continue to RIH. Tag bottom twice at 10,743ft, up wt is 47k. TOL ~ 8763' 19:40 - 22:35 2.92 CEMT P RUNPRD Pump 7bbls of 2% slick KCL to flush out inner reel hardline. Drop & launch 5/8" steel ball. RIH & set 10k down. Ball on seat at 44bbls away, sheared at 3600psi. PUH to confirm released, up wt is 38k -released from liner. Set back down w/ 10k on it. Swap well over to 8.45ppg 2% slick KCL at 3.08bpm in / 3.01 bpm out @ 1600psi w/ 48psi WHP. Reduce rate after 2 bottom's up. 1.55bpm in / 1.46bpm out ~ 540psi. Spot, RU & prime up SLB cementers. 22:35 - 22:50 0.25 CEMT P RUNPRD PJSM regarding pumping cement. 22:50 - 23:20 0.50 CEMT P RUNPRD Batch mix cement. Cement at WT at 23:04. Fluid pack & P.T. cement lines to 4k -good. 23:20 - 00:00 0.67 CEMT P RUNPRD Pump 24bbls of 15.8ppg class G cement at 2bpm ~ 1000psi. Clean out cement line w/ bio & air. Displace cement with 2ppb slick biozan. Displace 22bbls of cement, SD pumps, PU & exhaust remaining cement. Sting back into liner, shear LWP ~ 2000psi. Displace LWP to the latch collar. 9/29/2008 00:00 - 00:30 0.50 CEMT P RUNPRD SD pumps & check floats. Total cement behind pipe 22.4bbls. Pressure up to 500psi & unsting from liner. Nrinted: tuitiizuuts za~:zarm BP EXPLORATION Page 6 of 7 Operations Summary Report Legal Well Name: 01-21 Common Well Name: 01-21 Spud Date: 10/2/1982 Event Name: REENTER+COMPLETE Start: 9/22/2008 End: 9/30/2008 Contractor Name: NORDIC CALISTA Rig Release: 9/30/2008 Rig Name: NORDIC 2 Rig Number: Date i From - To Hours ICI Task' Code NPT Phase Description of Operations 9/29/2008 00:30 - 02:35 2.08 CEMT P 02:35 - 02:50 0.25 CEMT P 02:50 - 04:20 1.50 CEMT P 04:20 - 04:35 0.25 EVAL P 04:35 - 07:50 3.25 EVAL P 07:50 - 09:00 1.17 EVAL P 09:00 - 10:35 1.58 EVAL P 10:35 - 10:50 I 0.25 I EVAL I P 10:50 - 12:55 I 2.081 EVAL I P 12:55 - 14:20 1.42 EVAL P 14:20 - 15:00 0.67 EVAL P 15:00 - 16:30 1.50 EVAL P 16:30 - 17:30 1.00 EVAL P 17:30 - 19:20 1.83 EVAL P 19:20 - 19:30 0.17 EVAL P 19:30 - 20:05 0.58 EVAL P 20:05 - 20:40 I 0.58 I EVAL I P 20:40 - 21:45 ~ 1.08 ~ EVAL ~ P 21:45 - 23:00 1.25 EVAL P 23:00 - 23:10 0.17 EVAL P 23:10 - 00:00 0.83 PERFO P 9/30/2008 100:00 - 02:15 I 2.251 PERFOBI P 02:15 - 04:25 2.17 PERFO~ P 04:25 - 05:25 1.00 PERFO P RUNPRD POH &circ. No cement returns seen while POH. RUNPRD PJSM regarding LD SELRT BHA. RUNPRD LD SELRT BHA. LOWERI PJSM regarding MU logging BHA. LOWERI MU logging BHA w/ 62 jts of CSH Cement comp str=600 psi at 0645 hrs LOWERI MU MHA w/ 4 jts 2-3/8" PH6 tubing LOWERI RIH w/ BHA #5 (2.30" D331 mill w/ MCNL) circ slick KCI 0.4/180 LOWERI 8700' 35.Ok, 24.6k RIH and to at min rate at 8812.5' CTD. PUH 35k, start motor 1.41/1400. Ease in hole and look for first MW LOWERI Mill from first MW ~ 8811.7' 1.44/1430 w/ 100-200 psi dill, 0.1-0.3k wob to 8812.8' over 1.5 hrs. See aluminum in samples. Had 5 stalls. No noticable cement in returns, bu_t had H chan a Pump 50 bbls of 2 ppb biozan in pills. Ream/backream 8112' area clean. PUH to 8500' LOW ER1 Log down from 8500' at 30'/min 0.54/320 while circ FloVis pill to mill. Tag at 10747' CTD. PU 40k LOWERi Log up from 10747' to 8500' leaving fresh FloPro mud in liner LOW ER1 POOH w/ CT circ 0.75/440 LOW ERi Set injector on legs. Drop ball and open circ sub. LD MHA w/ 4 jts PH6 LOWERi Standback CSH LOWERI PJSM regarding removing source from logging tools. LOWERI Remove source from tools. Down load data -have good data. Recovered 1/2" ball. PBTD = 10,707ft. LOWERI Fill hole _ 1 bbl. PU injector. MU swizzle stick BHA. Stab onto well. LOWERI Jet stack until clean. Pop off well. Set back injector. Cement is at 2000psi compressive strength at 20:15. Load pipe shed w/ 2" pert guns. LOWERI Perform liner lap test to 2000psi -PASS. Time WHP IA OA 21:45 2007 35 37 22:00 1912 35 37 22:15 1886 35 37 Isolate w/ valves & retest Time WHP IA OA 22:20 2100 35 37 22:35 2080 35 37 22:50 2075 35 37 LOWERI Function test ROPE per AOGCC regs. LOWERI Run pert guns as per program. 426ft of 2" 6SPF, 5/8"~ disconnect, 31 stds CSH, 3/4" disconnect, check valve, 2 stds PH6 tbg, lockable swivel and CTC. LOWERI Continue to MU pert BHA. PU injector, MU to BHA. Stab injector onto well. Set counters. LOWERI RIH w/ pert BHA. WT ck at 8700ft, up wt = 36k & do wt = 24k. Tag twice at 10,746ft, up wt = 40k. Correct depth to 10,707ft LOWERI PUH to pert depth. Circulate 10bbls of Flo-Pro, drop 1/2" steel ball followed by 5 bbls of flo-pro chased w/ 2% slcik KCL. RU Printed: 10/6/2008 2:13:29 F'M BP EXPLORATION Page 7 of 7 Operations Summary Report Legal Well Name: 01-21 Common Well Name: 01-21 Spud Date: 10/2/1982 Event Name: REENTER+COMPLETE Start: 9/22/2008 End: 9/30/2008 Contractor Name: NORDIC CALISTA Rig Release: 9/30/2008 Rig Name: NORDIC 2 Rig Number: I Task Code NPT Phase Description of Operations Qate From - To Hours ~ 9/30/2008 04:25 - 05:25 1.00 PERFO P LOWERI SLB shot detector. Perform drive by shooting & perforate from 10,250ft to 10,650ft w/ 6 spf 2" pert guns. Good indication of firin . 05:25 - 07:30 2.08 PERFO P LOW ER1 POH. Flow check at TOL -loosing fluid - 4bbls. Finish POH 07:30 - 08:30 1.00 PERFO P LOW ERi Set injector on legs. LD MHA and 4 jts Ph6 08:30 - 10:15 1.75 PERFO P LOWERI LD CSH singles LRS load CT w/ 32 bbls diesel while circ to bung hole (due to lack of trucks) 10:15 - 10:30 0.25 PERFO P LOWERI Safety mtg re: LD perf guns 10:30 - 12:40 2.17 PERFO P LOWERI LD perf puns-all shots fired. Load out spent perf guns. MU nozzle BHA. Stab onto well. 12:40 - 14:00 1.33 RIGU P POST RIH to 2000ft. Lay in diesel FP. Tag up, well is on a vac. Pop off well. Spot & RU SLB nitrogen pump truck. 14:00 - 14:30 0.50 WHSUR P POST D rod 5" FMC BPV. 14:30 - 16:00 1.50 RIGD P POST Cool down nitrogen unit. Pump corrosion inhibitor cocktail into the coil. Pump 10bbls of methanol. PJSM regarding using nitrogen. Blow down reel with nitrogen. RD nitrogen unit. Let coil bleed down to Opsi. Pop off well. 16:00 - 16:50 0.83 RIGD P POST LD nozzle BHA. Prep end of coil for grapple connector. Vac out pits, tiger tank & cuttings box. Hoist BOT BHA commponents to the ground. 16:50 - 17:00 0.17 RIGD P POST PJSM regarding pulling coil across. 17:00 - 18:30 1.50 RIGD P POST Pull coil across and secure coil. 18:30 - 18:50 0.33 RIGD P POST PJSM for RD of BOP's PJSM for removing reel iron and electrical from reel house. 18:50 - 21:30 2.67 RIGD P POST ND BOP's and prep reel to be lowered. PJSM for lowering reel Lower reel while ND BOP's 21:30 - 00:00 2.50 RIGD P POST Continue to ND BOP's. Install tree cap. PT cap to 5000 psi -pass. Release rig ~ 00:00 Printed: 10/6/2008 2:13:29 PM • - ,, ~~ BP Alaska `f~~ - Baker Hughes INTEQ Survey Report Gib BAKER FIUGIIES INTEQ Company: BP Amoco Date 9/29/2008 Time. 11:53:44 Page: 1 Fuld: Prudhoe Bay Co-ordinate(NE) Reference: Well: 01-21, True North ~ i Site. PB DS 01 V crt~cul (TVD) Keferenee: 33.21 10/2/1982 00:00 74.0 ~~~ Well: 01-21 Section (VS) Reference: Well (O.OON,O.OOE,351.52Azi) Wellpath: 01-21A Sm'vey Calculation Method: Minimum Curvature Db: Oracle Field: Prudhoe Bay North Slope UNITED STATES Map System:US State Plane Coordinate System 1927 Map Zone: Alaska, Zone 4 Geo Datum: NAD27 (Clarke 1866) Coordinate System: Well Centre Sys Datum: Mean Sea Level Geomagnetic Model: bggm2007 Site: PB DS 01 TR-10-15 UNITED STATES :North Slope Site Position: Northing: 5941932.14 ft Latitude: 70 14 43.905 N From: Map Easting: 697237.60 ft Longitude: 148 24 24.004 W Position Uncertainty: 0.00 ft North Reference: True Ground Level: 0.00 ft Grid Convergence: 1.50 deg Well: 01-21 Slot Name: 21 01-21 Well Position: +N/-S -1447.63 ft Northing: 5940499.56 ft Latitude: 70 14 29.667 N +E/-W 553.21 ft Easting : 697828.47 ft Longitude: 148 24 7.922 W Position Uncertainty: 0.00 ft Wellpath: 01-21 A Drilled From: 01-21 500292082701 Tie-on Depth: 9300.00 ft Current Datum: 33:21 10/2/1982 00:00 Height 74.00 ft Above System Datum: Mean Sea Level Magnetic Data: 7/7/2008 Declination: 23.27 deg Field Strength: 57684 nT Mag Dip Angle: 80.92 deg Vertical Section: Depth From (TVD) +N/-S +E/-W Direction ft ft ft deg 34.00 0.00 0.00 351.52 Survey Program for Definitive Wellpath Date: 7/7/2008 Validated: Yes Version: 2 Actual From To Survey Toolcode Tool Name ft ft 100.00 9300.00 1 : Camera based gyro multisho CB-GYRO-MS Camera based gyro multishot 9340.00 10743.00 MWD (9340.00-10743.00) MWD MWD -Standard Annotation _ -_ -- - MD fVD ft ft 9300.00 8719.88 TIP 9340.00 8757.61 KOP 10743.00 9056.01 TD Survey: MWD Start Date: 9/29/2008 Company: Baker Hughes INTEQ Engineer: Tool: MWD;MWD -Standard Tied-to: From: Definitive Path Survey - - _ _ - lncl ~1ziro T~'D Sys "CVD - N/S E/W MapN MapE y'S DLS Tool ft deg deg ft ft ft ft ft ft ft _ - deg/100ft _ -- 9300.00 19.50 357.00 8719.88 8645.88 2633.64 _ -85.04 5943129.92 697674.35 2617.40 0.00 MWD 9340.00 19.30 356.61 8757.61 8683.61 2646.91 -85.78 5943143.16 697673.26 2630.63 0.60 MWD 9344.60 19.71 356.58 8761.95 8687.95 2648.44 -85.87 5943144.69 697673.13 2632.16 9.02 MWD 9373.67 22.34 356.44 8789.08 8715.08 2658.85 -86.51 5943155.08 697672.22 2642.55 9.04 MWD 9407.38 27.87 354.87 8819.60 8745.60 2673.11 -87.61 5943169.30 697670.75 2656.81 16.52 MWD 9449.57 32.67 354.20 8856.02 8782.02 2694.27 -89.65 5943190.40 697668.16 2678.04 11.41 MWD 9481.08 36.20 346.05 8882.02 8808.02 2711.78 -92.75 5943207.82 697664.60 2695.82 18.40 MWD 9511.91 39.13 337.40 8906.44 8832.44 2729.61 -98.69 5943225.49 697658.19 2714.33 19.58 MWD 9544.82 42.15 326.95 8931.44 8857.44 2748.48 -108.72 5943244.09 697647.67 2734.47 22.60 MWD 9570.00 44.80 322.89 8949.71 8875.71 2762.64 -118.68 5943257.98 697637.34 2749.95 15.29 MWD 9600.48 47.98 314.73 8970.75 8896.75 2779.19 -133.22 5943274.14 697622.37 2768.46 22.00 MWD ., ~ BP Alaska Baker Hughes INTEQ Survey Report ~~ BAKER NLIGNES :. YY '~, I I ~I Company: Field: Site: Wcll: Wcllpath: BP Amoco Prudhoe Bay PB DS 01 01-21 01-21A Date: 9/29/2008 Time: 11:53:44 Page: Co-ordinate(NE) Refcrence: Well: 01-21, True North Vertical ('fVll) Reference: 33:21 10/2/1982 00:00 74.0 Section (VS) Refcrence: Well (O.OON,O.OOE,351.52Azi) Survey Calculation Method: Minimum Curvature Db: 2 racle Sur~ev b1U lncl Azim TVD Sys'I'V D N/S E/R' IVIapN MapN~ VS DLS "Cool ft deg deg ft ft ft ft ft ft ft deg/100ft 9630. 88 53. 64 311. 94 8989 .96 8915. 96 2795. 33 -150. 36 5943289. 83 697604. 81 2786. 96 19.93 MWD 9662. 04 58. 45 307. 87 9007 .36 8933. 36 2811. 88 -170. 19 5943305. 85 697584. 56 2806. 25 18.85 MWD 9690. 96 63. 37 304. 84 9021 .42 8947. 42 2826. 85 -190. 55 5943320. 28 697563. 82 2824. 05 19.32 MWD 9739. 55 72. 67 301. 54 9039 .59 8965. 59 2851. 44 -228. 23 5943343. 88 697525. 51 2853. 93 20.15 MWD 9772. 28 79. 44 298. 28 9047 .48 8973. 48 2867. 26 -255. 75 5943358. 96 697497. 58 2873. 63 22.83 MWD 9810. 06 83. 25 299. 26 9053 .16 8979. 16 2885. 23 -288. 48 5943376. 07 697464. 39 2896. 24 10.41 MWD 9851. 26 88. 15 308. 82 9056 .26 8982. 26 2908. 21 -322 .47 5943398. 14 697429. 81 2923. 97 26.01 MWD 9882. 34 87. 36 315. 61 9057 .47 8983. 47 2929. 06 -345 .46 5943418. 39 697406. 29 2947. 99 21.98 MWD 9914. 99 84. 62 322. 77 9059 .76 8985. 76 2953. 69 -366 .73 5943442. 45 697384. 38 2975. 48 23.43 MWD 9947. 27 84. 28 328. 15 9062 .88 8988. 88 2980. 15 -384 .94 5943468. 41 697365. 48 3004. 33 16.62 MWD 9980. 31 86. 52 332. 29 9065 .54 8991. 54 3008. 73 -401 .29 5943496. 55 697348. 38 3035. 01 14.21 MWD 10009. 24 89. 17 336. 03 9066 .62 8992. 62 3034. 74 -413 .89 5943522. 22 697335. 11 3062. 60 15.84 MWD 10039. 20 92. 30 338. 37 9066 .24 8992. 24 3062. 35 -425 .50 5943549. 52 697322. 78 3091. 62 13.04 MWD 10073. 21 92. 70 341. 99 9064 .76 8990. 76 3094. 31 -437 .01 5943581. 16 697310. 43 3124. 92 10.70 MWD 10106. 73 93. 78 345. 02 9062 .86 8988. 86 3126. 39 -446 .52 5943612. 99 697300. 09 3158. 06 9.58 MWD 10141. 69 94. 48 341. 78 9060 .34 8986. 34 3159. 80 -456 .48 5943646. 12 697289. 26 3192. 57 9.46 MWD 10177. 94 94. 22 338. 46 9057 .59 8983. 59 3193. 79 -468 .77 5943679. 77 697276. 08 3228. 00 9.16 MWD 10209. 51 91. 04 340. 08 9056 .14 8982. 14 3223. 28 -479 .93 5943708. 96 697264. 15 3258. 81 11.30 MWD 10250. 66 91. 41 346. 14 9055 .26 8981. 26 3262. 63 -491 .87 5943747. 98 697251. 18 3299. 49 14.75 MWD 10280. 24 90. 58 348. 71 9054 .75 8980. 75 3291. 49 -498 .31 5943776. 66 697243. 98 3328. 99 9.13 MWD 10311. 71 89. 94 351. 19 9054 .61 8980. 61 3322. 48 -503 .80 5943807. 49 697237. 68 3360. 45 8.14 MWD 10347. 82 89. 32 354. 89 9054 .84 8980. 84 3358. 31 -508 .18 5943843. 20 697232. 37 3396. 54 10.39 MWD 10380. 41 88. 89 358. 53 9055 .35 8981. 35 3390. 84 -510 .05 5943875. 66 697229. 65 3428. 98 11.25 MWD 10426. 25 91. 26 3. 75 9055 .29 8981. 29 3436. 65 -509 .14 5943921. 48 697229. 35 3474. 16 12.51 MWD 10458. 72 91. 47 2. 20 9054 .51 8980. 51 3469. 07 -507 .45 5943953. 92 697230. 19 3505. 97 4.82 MWD 10486. 11 90. 18 0. 29 9054 .12 8980. 12 3496. 45 -506 .86 5943981. 31 697230. 06 3532. 97 8.41 MWD 10524. 94 89. 72 356. 38 9054 .15 8980. 15 3535. 25 -507 .98 5944020. 07 697227. 92 3571. 51 10.14 MWD 10556. 65 91. 69 354. 11 9053 .76 8979. 76 3566. 85 -510 .61 5944051. 58 697224. 46 3603. 15 9.48 MWD 10585. 41 92 .58 351. 43 9052 .69 8978. 69 3595. 36 -514 .23 5944079. 98 697220. 10 3631. 88 9.81 MWD 10616. 13 91 .01 348. 41 9051 .73 8977. 73 3625 .58 -519 .60 5944110. 06 697213. 93 3662. 57 11.08 MWD 10659. 81 88 .86 343. 66 9051 .78 8977. 78 3667 .96 -530 .14 5944152. 14 697202. 29 3706. 03 11.94 MWD 10689. 65 87 .33 340. 93 9052 .77 8978. 77 3696 .36 -539 .21 5944180. 30 697192. 48 3735. 47 10.48 MWD 10705. 78 86 .38 338. 52 9053 .66 8979. 66 3711 .47 -544 .79 5944195. 25 697186 .50 3751. 23 16.04 MWD 10743. 00 86 .38 338. 52 9056 .01 8982. 01 3746 .04 -558 .39 5944229. 45 697172 .00 3787. 43 0.00 MWD ,~ ~ !{~-.v-Rg ; . a 7ya ~ ~ j{}~ (q, ]pI-.^~~~ ( ~„ )~ f~ a j ~gjl ~ ~ `, ~ _., 1 °'+.~"~ ~..,~ ..Y t~..i 4.-...w° .~ d.~i i.~ L.~.` 6...1 ~.l ~1._..J ~...5 ~,1 ~~ ~..R ALASS1l OIL A1QD GAS COI~TSERQATIOI~T COMI~IISSIOIQ Charles Reynolds CT Drilling Engineer BP Exploration Alaska Inc. PO Box 196612 Anchorage AK 99519-6612 SARAH PALIN, GOVERNOR 333 W. 7th AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU O 1-21A BP Exploration Alaska Inc. Permit No: 208-131 Surface Location: 401' FNL, 506' FWL, SEC. 08, T10N, R15E, UM Bottomhole Location: 3336' FSL, 72' FEL, SEC. 06, T10N, R15E, UM Dear Mr. Reynolds: Enclosed is the approved application for permit to redrill 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. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). Sincerely, ,r Daniel T. Seamount, Jr. Chair DATED this~'S day of August, 2008 cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. ~~~.~ G~ STATE OF ALASKA ~ ~, fl.,~~ ALAS. IL AND GAS CONSERVATION COMMI N PERMIT TO DRILL i~~'~~ 20 AAC 25.005 f"'n ,. h - ~~ ~~„ r~ ~,~~,~ e 1 a. Type of work ^ Drill ®Redrill ^ Re-Entry 1 b. Current Well Class ^ Exploratory ^ Development Gas ^ Service ^ Multiple Zone ^ Stratigraphic Test ®Development Oil ^ Single Zone 1 c. Specify if we11 is proposed`for: ^ Coalbed Methane F^ Gas Hydrates ^ Shale Gas 2. Operator Name: BP Exploration (Alaska) Inc. 5. Bond: ®Blanket ^ Single Well Bond No. 6194193 11. Well Name and Number: PBU 01-21A 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 6. Proposed Depth: MD 10730' TVD 8980'ss 12. Field /Pool(s): Prudhoe Bay Field / Prudhoe Bay 4a. Location of Well (Governmental Section): Surface: ' ' S C 7. Property Designation: ADL 028329 Pool 401 FNL, 506 FWL, E . 08, T10N, R15E, UM Top of Productive Horizon: 2197' FSL, 432' FWL, SEC. 05, T10N, R15E, UM 8. Land Use Permit: 13. Approximate Spud Date: October 4, 2008 Total Depth: 3336' FSL, 72' FEL, SEC. 06, T10N, R15E, UM 9. Acres in Property: 2560 14. Distance to Nearest Property: 23,500' 4b. Location of Well (State Base Plane Coordinates): Surface: x-697828 y-5940499 Zone-ASP4 10. KB Elevation (Height above GL): 74' feet 15. Distance to Nearest Well Within Pool: 800' 16. Deviated Wells: Kickoff Depth: 9350 feet Maximum Hole An le: 92 de rees 17. Maximum Anticipated Pressures in psig (see 20 AAC 25.035) Downhole: 3267 SurFace: 2387 18. Casin Pr ram`. S ecificatio ns To - Settin De th -Bo ttom uanti of Cement c.f: orsacks Hole Casin Wei ht Grade Cou lin Len th MD TVD MD TVD includin sta a data 4-1 /8" s-v2" x 33/16" 9.3# / 6.2# L-80 STL / TCII 1960' 8770' 8149'ss 10730' 8980'ss 104 sx Class 'G' x 2-~/a" / 6.16# 1 g. PRESE NT WELL CONDITION S UMMARY (To be completed. for Redrill and Reentry Operations) Total Depth MD (ft): 9857' Total Depth TVD (ft): 9249' Plugs (measured): None Effective Depth MD (ft): 9725' Effective Depth TVD (ft): 9123' Junk (measured): None Casing Length Size Cement Volume MD' TVD Conductor /Structural 80' 20" 1900 # Poleset 80' 80' Surface 2571' 13-3/8" 2200 sx ColdSet III 400 sx ColdSet II 2571' 2571' Intermediate 9068' 9-5/8" 500 sx Class'G' 300 sx ColdSet I 9068' 8502' Production Liner 1081' 7" 380 sx Class 'G' 8773' - 9854' 8226' - 9246' Perforation Depth MD (ft): 9596' - 9630' Perforation Depth TVD (ft): 9000' - 9033' 20. Attachments ^ Filing Fee, $100 ®BOP Sketch ®Drilling Program ^ Time vs Depth Plot ^ Shallow Hazard Analysis ^ Property Plat ^ Diverter Sketch ^ Seabed Report ®Drilling Fluid Program ~ 20 AAC 25.050 Requirements 21. Verbal Approval: Commission Representative: Date: 22. I hereby certify that the foregoing is true and correct. Contact Charles Reynolds, 564-5480 Printed Name Charles Reynolds Title CT Drilling Engineer g Prepared By Name/Number: Si nature Phone 564-5480 Date FS-S- o~y Terrie Hubble, 564-4628 Commission`Use Onl Permit To Drill Number:.~?O~ .~ D API Number: 50-029-20827-01-00 Permit Ap royal See cover letter for Date: other re uirements Conditions of Approval: r-y If box is checked, well may not be used to explore for, test, or produce coalbed me~~th//ane, gas hydrates, or gas contained shales: L~1 Samples Req'd: ^ es LrJNo Mud Log Req'd: ,^,/Yes ~No HZS Measures: Yes ^ No Directional Survey Req'd: LvJ Yes ^ No Other: ~~j '/ APPROVED BY THE COMMISSION ~~ss Date ,COMMISSIONER Form 10-401 Revised +~L/2005 ®~ _ ~~ Submit In Duplicate IGINAL by BPXA Prudhoe Bay DS 01-21 CTD Sidetrack August 4, 2008 CTD Sidetrack Summary Pre-Rig Work: (Scheduled to begin on August 8, 2008) 1. MIT-IA, OA 2. PPPOT-T, -IC 3. Slick line drift with dummy whipstock 4. Eline set whipstock at 9,340' 5. Service coil pump downsqueeze min 15bb1 cement 6. Service coil mill XN 7. PT MV, SV, WV. 8. Bleed production flow lines and GL lines down to zero and blind flange. 9. Remove wellhouse, level pad. Rig Sidetrack Operations: (Scheduled to begin on October 4, 2008 using Nordic rig 2) 1. MIRU Nordic Rig 2 2. NU 7-1/16" CT Drilling BOPE and test. 3. Mill 3.8"" window through 7". 4. Drill build and lateral section to 10,730'. 5. Run and cement a 3-1/2" x 3-3/16" x 2-7/8" L-80 liner string. 6. Make a cleanout run with mill, motor and SWS GR-CNL logging tool. 7. Perforate well. 8. FP well to 2000' with diesel. 9. Set BPV. ND 7-1/16" stack. FP tree and PT tree cap to 3500 psi. 10. RDMO Nordic 2. Post-Rig Work: 1. Re-install wellhouse and FL's. 2. Pull BPV. 3. Run gas lift design. 4. POP Well lihud Program: • Well kill: 8.4 ppg brine. • Milling/drilling: 8.6 ppg Flo Pro or biozan for milling, new 8.6 ppg Flo Pro for drilling. Disposal: • All drilling and completion fluids and all other Class II wastes will go to Grind & Inject. • All Class I wastes will go to Pad 3 for disposal. Hole size: 4.125" (bi-center bits used) Casing Program: fully cemented liner • 3-1/2", L-80 9.3# STL 8,770' - 9,250' and • 3-3/16", L-80 6.2# TCII 9,250' and - 10,200' and • 2-7/8", L-80 6.16# STL 10,250'md - 10,730' and • A minimum of 21.5 bbls 15.8 ppg cement will be used for liner cementing. • TOC planned at 9,150' Existing casing/tubing Information 13-3/8", L-80 72#, Burst 5380, collapse 2670 psi 9-5/8", L-80, 47# Burst 6870, collapse 4750 7", L-80 29#, Burst 8160, collapse 7030 psi 4-1/2", 13-CR 12.6#, Burst 8430, collapse 7500 psi 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 2500 psi. Directional • See attached directional plan. Maximum planned hole angle is 91.53 deg at 10,191.45. • Magnetic and inclination surveys will be taken every 30 ft. No gyro will be run. • Distance to nearest property line - 23,500 ft. • Distance to nearest well within pool - 800 ft. (05-41 A C~2 10,730') Logging • MW D directional, Resistivity and Gamma Ray will be run over all of the open hole section. • Cased hole MCNL/GR/CCL will be run. Hazards • The maximum recorded H2S level on Drill Site 1 was 140 ppm on well 01-07A. • Zero fault crossings, risk of lost circulation low. Reservoir Pressure • The reservoir pressure on 01-21A is expected to be 3,267 psi at 8,800' TVDSS. (7.14 ppg equivalent) • Max. expected surface pressure with gas (0.10 psi/ft) to surface is 2,387 psi. C.R.Reynolds CTD Engineer CC: Well File Sondra Stewmanlf errie Hubble LLHEAD =' FMC CTUATOR = AXELSON B. ELEV = T4' F. ELEV = 28' OP = 2900' aX An 31 seoa alum MD = 9463' alum TVO = 8800' SS I 13-318" CSO.72ar. L-80. ID =12.347" I Minimum ID = 3.725" ~ 8817' 4-112" HES XN NIPPLE 01-21 SAFETYNOTES: CN~METBG. 1 I 4112' NES X NNi, ID = 3.813" I [SAC 1 IFT MAA[1RRl C ST MD TVD DEV TYPE VLV LATCH PORT DATE S 3001 2997 15 MM4 OMY RK 0 12114!02 4 3768 3719 21 MM4 DMY RK 0 051281 3 6253 5996 29 MMt3 DMY RK 0 12109!02 7978 7499 2B MMG DMY RK 0 12109A2 1 8596 8062 22 MMO DMY RK 0 12109A2 ~ 4-1/2"HESXNP,~=3.813" I I 9-518" x 4-1 ~2" BKR S-3 PKR, ~ = 3.875" I TOP ~ 7" LNR 4-112" TB0,12.6i, 73-CR, .0152 bpf, ~ = 3.958" nnnna PERFORAT~PI SUMMARY REF LOO: BHCS ON 10M5182 ANS3LE AT TOR PERF: 18 ~ 9550' Note: Refar to Production D8 for historical erf data SIZE SPF NVTERYAL OpNS~ DATE 4 9550 -9570 S O6M 3189 4 9598 -9806 0 0612'i ~9 4 9608 -9807 S O6M 3189 4 9613 -9818 S 06/21/89 4 9818 -9630 0 OBM 3189 7' LNR, 29f, L-80, ID = 8.184" I-i 9854' 8797' I-f 4-112" HES X NIP, ID = 3.613" 8817' -{ 4-117' HES XN RNP , ID = 3.725" ~' 4-112" INLEO, ~ = 4.0" DATE REV t3Y COMMENTS DATE REV ®Y COMMENTS 16/24A2 OWGtNAL COMPLETION 06~D5103 CMOIrLP MAX ANGLE 12/NA2 Pt1/KAK t>aAiO 08M TA3 CMOrtLP PERT ANf3LE CORRECTION 02104A1 KAK C01<tRECTtONS 08F26A3 KEtMAK REMOVE SAND Dt1MP 02i10A1 JA G~IV MODI~ICATtONS OSp1A8 KSB/i'D GLV C10(5/28108) 11115A1 DAVMK SAND DUMP 12/31 b2 TMNIKK FCO PRUDHOE t'JAY UNIT wELL: m-21 PERMIT No: 'i 821520 API Nor 50-029-20827-00 SEC 5. T10N, R15E, 4860.05' FEL 82871.08' FNL t~ Expbratbn (Ahsks} TREE _ WELLHEAD = FMC ACTUATOR= AXELSON KB. ELEV = 74' BF. ELEV = 28' 01-21A Proposed CTD Sidetrack 12 18 12 12 12 PRUDNC~E BAY UNIT WELL: 01-21 A PERMIT No: API No: 50-029-20827-01 SEC 5 T10N R15E, 4860.05' FEL 8 2871.08' FNL BP Expbratbn (J11sda) DATE REV BY COMMENTS DATE REV BY COMMENTS 1~l2W82 ORK~NAL COhPLETK)N O6105N3 CMOlTLP MAX ANGLE 12l09AD2 PNlKAK RWO 08M7r1D3 CMOlTLP PERF ANGLE CORRECTION 02A4A1 KAK CORRECTIONS 08C26A03 KBMAK REMOVE SAND DUMP 02MOAD1 JA GLV MODIFICATIONS OSf311~08 KSBlTD GLV CFD (5l28r08) 11115N1 DAVMK SAND DUMP O7l02~U8 MSE PROPOSED CTD SIDETRACK 12f311~02 TMNMK FCO \ by ~ BP Alaska ~ °. Baker Hughes INTEQ Plannin Re ort g P uvT;EQ Company: BP Amoco Date: 7/7/2008 Time 16:37.29 Page: 1 Field: Prudhoe Bay Co-ordinate(NE) Reference: Well: 01-21, True North Site: PB DS 01 Vertical (TVD) Reference: 33:21 10/?11982 00:00 74.0 Well: 01-21 Section (VS) Reference: Well (0.00N,0.00E,340.00Azi) Wellpath: Plan 3, 01-21A Survey Calculation Method: Minimum Curvature Db: Oracle Targets MaP MaP <---- Latitude ----> <--- Longitude ---> Name Description TVD +N/-S +E/-W Northing Easting Deg Min Sec Deg Min Sec Dip. Dir. ft ft ft ft ft 01-21 A Polygon 74.00 2928.35 -256.73 5943420.00 697495.00 70 14 58.467 N 148 24 15.388 W -Polygon 1 74.00 2928.35 -256.73 5943420.00 697495.00 70 14 58.467 N 148 24 15.388 W -Polygon 2 74.00 3775.06 -499.60 5944260.00 697230.00 70 15 6.795 N 148 24 22.453 W -Polygon 3 74.00 3706.25 -736.50 5944185.00 696995.00 70 15 6.118 N 148 24 29.343 W -Polygon 4 74.00 2996.47 -565.06 5943480.00 697185.00 70 14 59.137 N 148 24 24.355 W -Polygon 5 74.00 2827.71 -424.43 5943315.00 697330.00 70 14 57.477 N 148 24 20.265 W 01-21A Fault 1 74.00 2914.81 -122.03 5943410.00 697630.00 70 14 58.334 N 148 24 11.471 W -Polygon 1 74.00 2914.81 -122.03 5943410.00 697630.00 70 14 58.334 N 148 24 11.471 W -Polygon 2 74.00 2980.31 -140.32 5943475.00 697610.00 70 14 58.978 N 148 24 12.002 W -Polygon 3 74.00 3796.77 -373.98 5944285.00 697355.00 70 15 7.008 N 148 24 18.799 W -Polygon 4 74.00 4074.06 -456.74 5944560.00 697265.00 70 15 9.735 N 148 24 21.206 W -Polygon 5 74.00 3796.77 -373.98 5944285.00 697355.00 70 15 7.008 N 148 24 18.799 W -Polygon 6 74.00 2980.31 -140.32 5943475.00 697610.00 70 14 58.978 N 148 24 12.002 W 01-21 A Fau It 2 74.00 3769.79 -679.81 5944250.00 697050.00 70 15 6.743 N 148 24 27.694 W -Polygon 1 74.00 3769.79 -679.81 5944250.00 697050.00 70 15 6.743 N 148 24 27.694 W -Polygon 2 74.00 3924.61 -670.75 5944405.00 697055.00. 70 15 8.265 N 148 24 27.431 W 01-21 A Target 3 9054.00 3745.59 -596.41 5944228.00 697134.00 70 15 6.505 N 148 24 25.268 W 01-21 A Target 2 9056.00 3409.56 -486.19 5943895.00 697253.00 70 15 3.200 N 148 24 22.062 W 01-21 A Target 1 9066.00 2940.34 -332.44 5943430.00 697419.00 70 14 58.585 N 148 24 17.590 W Field: Prudhoe Bay North Slope UNITED STATES Map System: US State Plane Coordinate System 1927 Map Zone: Alaska, Zone 4 Geo Datum: NAD27 (Clarke 1866) Coordinate System: Well Centre Sys Datum: Mean Sea Level Geomagnetic Model: bggm2007 Site: PB DS 01 TR-10-15 UNITED STATES :North Slope Site Position: Northing: 5941932.14 ft Latitude: 70 14 43.905 N From: Map Easting: 697237.60 ft Longitude: 148 24 24.004 W Position Uncertainty: 0.00 ft North Reference: True Ground Level: 0.00 ft Grid Convergence: 1.50 deg Well: 01-21 Slot Name: 21 01-21 Well Position: +N/-S -1447.63 ft Northing: 5940499.56 ft Latitude: 70 14 29.667 N +E/-W 553.21 ft Easting : 697828.47 ft Longitude: 148 24 7.922 W Position Uncertainty: 0.00 ft Wellpath: Plan 3, 01-21 A Drilled From: 01-21 500292082701 Tie-on Depth: 9300.00 ft Current Datum: 33:21 10/2/1982 00:00 Height 74.00 ft Above System Datum: Mean Sea Level Magnetic Data: 7/7/2008 Declination: 23.27 deg Field Strength: 57684 nT Mag Dip Angle: 80.92 deg Vertical Section: Depth From (TVD) +N/-S +E/-W Direction ft ft ft deg 34.00 0.00 0.00 340.00 Plan: Plan 3 Date Composed: 7/7/2008 Copy Marys Version: 1 Principal: Yes Tied-to: From: Definitive Path by ~ BP Alaska Baker Hu hes INTEQ Plannin Re ort g g P INTEQ Company: BP Amoco Date: 7/7/2008 Time: 16 :37:29 Page: 2 Field: Prudhoe Bay Co-ordinate(NE) Reference: Well: 01-21, T rue North Site: PB DS 01 Vertical (TVD) Reference: 33:2 1 10!2/1982 00:00 74 .0 Well: 01-21 Section (VS) Reference: Well (O.OON,O. OOE,340.OOAzi) Wellpath: Plan 3, 01-21A Survey Calculation Method Minimum Curvature Db: Oracle Annotation MD TVD -_--- ft ft 9300.00 8719.88 TIP 9350.00 8767.05 KOP 9370.00 8785.83 End of 9 deg / 100 ft DLS 9440.00 8848.04 4 9580.00 8959.20 5 9856.44 9066.23 6 9891.44 9066.10 End of 1 8 deg / 100 ft DLS 10191.44 9060.77 8 10291.44 9058.12 9 10381.44 9056.08 10 10481.44 9054.72 11 10730.00 9053.97 TD Plan Section Information MD Inc! Azim TVD +NI-S +FJ-W DLS Build Turn TFO Target ft deg deg ft ft ft degl100ft deg/100ft deg/100ft deg 9300.00 19.50 357.00 8719.88 2633.64 -85.04 0.00 0.00 0.00 0.00 9350.00 19.25 356.51 8767.05 2650.21 -85.98 0.60 -0.50 -0.98 212.80 9370.00 21.05 356.51 8785.83 2657.08 -86.40 9.00 9.00 0.00 0.00 9440.00 33.16 4.35 8848.04 2688.85 -85.71 18.00 17.30 11.20 20.00 9580.00 43.52 326.60 8959.20 2768.56 -109.73 18.00 7.40 -26.97 278.00 9856.44 90.00 306.32 9066.23 2940.86 -284.64 18.00 .16.81 -7.33 333.00 9891.44 90.44 312.61 9066.10 2963.10 -311.64 18.00 1.25 17.96 86.00 10191.44 91.53 348.60 9060.77 3220.13 -456.49 12.00 0.36 12.00 88.00 10291.44 91.50 336.59 9058.12 3315.35 -486.34 12.00 -0.03 -12.00 270.00 10381.44 91.10 347.39 9056.08 3400.79 -514.12 12.00 -0.45 11.99 92.00 10481.44 90.45 359.37 9054.72 3499.93 -525.63 12.00 -0.65 11.98 93.00 10730.00 89.89 329.55 9053.97 3736.71 -591.47 12.00 -0.22 -12.00 269.00 Survey MD Inc! Azim SS TVD N/S EtW MapN MapE ALS VS TFO Tool ft deg deg ft ft ft ft ft deglt00ft ft deg 9300.00 19.50 357.00 8645.88 2633.64 -85.04 5943129.92 697674.35 0.00 2503.90 0.00 MW D 9350.00 19.25 356.51 8693.05 2650.21 -85.98 5943146.45 697672.98 0.60 2519.79 212.80 MW D 9370.00 21.05 356.51 8711.83 2657.08 -86.40 5943153.31 697672.38 9.00 2526.39 0.00 MW D 9375.00 21.90 357.34 8716.48 2658.91 -86.50 5943155.14 697672.23 18.00 2528.14 20.00 MW D 9400.00 26.19 0.69 8739.31 2669.09 -86.65 5943165.31 697671.82 18.00 2537.76 19.23 MW D 9425.00 30.53 3.16 8761.30 2680.95 -86.23 5943177.18 697671.92 18.00 2548.76 16.16 MW D 9440.00 33.16 4.35 8774.04 2688.85 -85.71 5943185.08 697672.24 18.00 2556.00 13.99 MW D 9450.00 33.45 1.12 8782.40 2694.33 -85.45 5943190.57 697672.35 18.00 2561.07 278.00 MW D 9475.00 34.54 353.30 8803.14 2708.26 -86.14 5943204.48 697671.29 18.00 2574.40 280.70 MW D 9500.00 36.09 345.99 8823.55 2722.45 -88.75 5943218.60 697668.31 18.00 2588.63 287.19 MW D 9525.00 38.06 339.27 8843.50 2736.81 -93.26 5943232.83 697663.42 18.00 2603.66 293.16 MW D 9550.00 40.37 333.16 8862.88 2751.25 -99.65 5943247.10 697656.66 18.00 2619.41 298.52 MW D 9575.00 42.97 327.64 8881.56 2765.68 -107.87 5943261.30 697648.07 18.00 2635.78 303.26 MWD 9580.00 43.52 326.60 8885.20 2768.56 -109.73 5943264.13 697646.13 18.00 2639.12 307.38 MWD 9600.00 46.76 324.36 8899.30 2780.23 -117.77 5943275.59 697637.79 18.00 2652.84 333.00 MWD 9625.00 50.85 321.87 8915.77 2795.26 -129.07 5943290.32 697626.10 18.00 2670.83 334.58 MW D 9650.00 54.99 319.65 8930.84 2810.70 -141.69 5943305.41 697613.08 18.00 2689.65 336.22 MWD 9675.00 59.16 317.65 8944.43 2826.44 -155.55 5943320.79 697598.81 18.00 2709.19 337.56 MWD 9700.00 63.37 315.82 8956.45 2842.39 -170.58 5943336.34 697583.37 18.00 2729.32 338.65 MW D 9725.00 67.59 314.12 8966.82 2858.46 -186.67 5943351.98 697566.86 18.00 2749.92 339.53 MWD 9750.00 71.84 312.52 8975.49 2874.54 -203.73 5943367.61 697549.39 18.00 2770.86 340.23 MW D 9765.59 74.49 311.56 8980.00 2884.53 -214.81 5943377.30 697538.06 18.00 2784.04 340.79 01-21 A 9773.39 75.82 311.09 8982.00 2889.51 -220.47 5943382.13 697532.26 18.00 2790.66 341.07 01-21 A 9775.00 76.09 311.00 8982.39 2890.54 -221.65 5943383.12 697531.06 18.00 2792.02 341.19 MW D 9800.00 80.35 309.53 8987.49 2906.35 -240.32 5943398.44 697511.98 18.00 2813.27 341.21 MW D by ~ BP Alaska r Baker Hu es INTEQ Plannin Re ort 1~ g P sw INTEQ Company: BP Amoco Date: 7/7/2008 Time: 16 :37:29 Page: 3 'i Field: Prudhoe Bay Co-ord inate(NE) Reference: Well: 01-21, True North Site: PB DS 01 Vertical (TVD) Reference: 33:2 1 10/2/1982 00:00 74 .0 Well: 01- 21 Section (VS) Reference: Well (O.OON,O.OOE,340.OOAzi) Wellpath: Plan 3, 01-21 A Survey Calculation Method: Minimum Curvatu re Db: Oracle Survev r-- MD _ _ Incl - Azim SS TVD N/S E/W MapN MapE DLS VS TFO Tool ', ft deg deg ft ft ft ft ft deg/100ft ft deg 9825.00 84.62 308.10 8990.76 2921.88 -259.63 5943413.46 697492.27 18.00 2834.46 341.51 MW D 9850.00 88.90 306.68 8992.17 2937.03 -279.46 5943428.08 697472.05 18.00 2855.48 341.70 MW D 9856.44 90.00 306.32 8992.23 2940.86 -284.64 5943431.78 697466.78 18.00 2860.86 341.78 MW D 9875.00 90.23 309.65 8992.20 2952.28 -299.26 5943442.81 697451.86 18.00 2876.59 86.00 MW D 9891.44 90.44 312.61 8992.10 2963.10 -311.64 5943453.29 697439.20 18.00 2890.99 86.01 MW D 9900.00 90.47 313.63 8992.03 2968.94 -317.89 5943458.98 697432.80 12.00 2898.62 88.00 MW D 9925.00 90.58 316.63 8991.80 2986.66 -335.52 5943476.22 697414.71 12.00 2921.30 88.01 MW D 9950.00 90.68 319.63 8991.53 3005.27 -352.21 5943494.39 697397.54 12.00 2944.49 88.04 MW D 9975.00 90.78 322.63 8991.21 3024.73 -367.89 5943513.43 697381.35 12.00 2968.15 88.07 MW D 10000.00 90.88 325.63 8990.85 3044.99 -382.54 5943533.29 697366.18 12.00 2992.19 88.11 MW D 10025.00 90.97 328.63 8990.44 3065.98 -396.10 5943553.92 697352.07 12.00 3016.55 88.15 MW D 10050.00 91.07 331.62 8990.00 3087.65 -408.55 5943575.25 697339.05 12.00 3041.18 88.20 MW D 10075.00 91.16 334.62 8989.51 3109.94 -419.85 5943597.24 697327.18 12.00 3065.99 88.25 MW D 10100.00 91.24 337.62 8988.99 3132.80 -429.97 5943619.82 697316.46 12.00 3090.92 88.31 MW D 10125.00 91.33 340.62 8988.43 3156.15 -438.87 5943642.93 697306.95 12.00 3115.91 88.37 MWD 10150.00 91.41 343.62 8987.83 3179.93 -446.55 5943666.50 697298.66 12.00 3140.88 88.44 MW D 10175.00 91.48 346.62 8987.20 3204.08 -452.96 5943690.47 697291.61 12.00 3165.77 88.51 MW D 10191.44 91.53 348.60 8986.77 3220.13 -456.49 5943706.43 697287.66 12.00 3182.07 88.59 MW D 10200.00 91.53 347.57 8986.54 3228.50 -458.26 5943714.75 697285.68 12.00 3190.53 270.00 MW D 10225.00 91.53 344.57 8985.87 3252.76 -464.27 5943738.83 697279.03 12.00 3215.38 269.97 MW D 10250.00 91.52 341.57 8985.21 3276.66 -471.55 5943762.54 697271.12 12.00 3240.33 269.89 MW D 10275.00 91.51 338.57 8984.55 3300.15 -480.07 5943785.80 697261.99 12.00 3265.32 269.81 MW D 10291.44 91.50 336.59 8984.12 3315.35 -486.34 5943800.82 697255.33 12.00 3281.75 269.73 MW D 10300.00 91.46 337.62 8983.90 3323.23 -489.67 5943808.61 697251.79 12.00 3290.29 92.00 MW D 10325.00 91.35 340.62 8983.28 3346.57 -498.57 5943831.71 697242.28 12.00 3315.27 92.03 MW D 10350.00 91.24 343.62 8982.72 3370.36 -506.25 5943855.29 697233.98 12.00 3340.25 92.10 MW D 10375.00 91.13 346.61 8982.20 3394.51 -512.67 5943879.26 697226.93 12.00 3365.14 92.17 MW D 10381.44 91.10 347.39 8982.08 3400.79 -514.12 5943885.50 697225.32 12.00 3371.53 92.23 MW D 10400.00 90.98 349.61 8981.74 3418.97 -517.82 5943903.57 697221.14 12.00 3389.88 93.00 MW D 10425.00 90.82 352.61 8981.35 3443.66 -521.68 5943928.15 697216.63 12.00 3414.41 93.04 MW D 10450.00 90.66 355.60 8981.03 3468.52 -524.25 5943952.94 697213.41 12.00 3438.65 93.09 MW D 10475.00 90.49 358.60 8980.78 3493.49 -525.51 5943977.86 697211.49 12.00 3462.54 93.13 MWD 10481.44 90.45 359.37 8980.72 3499.93 -525.63 5943984.30 697211.21 12.00 3468.63 93.16 MW D 10500.00 90.41 357.14 8980.58 3518.48 -526.19 5944002.82 697210.16 12.00 3486.25 269.00 MW D 10525.00 90.36 354.14 8980.42 3543.40 -528.09 5944027.69 697207.61 12.00 3510.33 268.98 MW D 10550.00 90.30 351.14 8980.27 3568.19 -531.29 5944052.38 697203.76 12.00 3534.72 268.96 MW D 10575.00 90.25 348.15 8980.16 3592.78 -535.78 5944076.85 697198.62 12.00 3559.36 268.95 MW D 10600.00 90.19 345.15 8980.06 3617.10 -541.56 5944101.01 697192.21 12.00 3584.19 268.93 MW D 10625.00 90.13 342.15 8979.99 3641.09 -548.59 5944124.80 697184.55 12.00 3609.13 268.92 MW D 10650.00 90.07 339.15 8979.95 3664.67 -556.88 5944148.15 697175.65 12.00 3634.13 268.91 MW D 10675.00 90.02 336.15 8979.93 3687.79 -566.38 5944171.01 697165.54 12.00 3659.11 268.91 MW D 10700.00 89.96 333.15 8979.93 3710.38 -577.09 5944193.31 697154.25 12.00 3683.99 268.90 MW D 10725.00 89.90 330.15 8979.96 3732.38 -588.96 5944214.99 697141.80 12.00 3708.73 268.90 MW D 10730.00 89.89 329.55 8979.97 3736.71 -591.47 5944219.25 697139.18 12.00 3713.65 268.91 MW D [~+n+osl .oa•osc ~~ uoeoas m~L>.an dq E Neld tll Z-LO'E ~Id (lZ-LO)LZ-LO ---- ON3~J31 ~oe~wa s ~oewa in ~~wa ~.~ ae~s~ oao „o ~a.a~o .+~.... wa rw ss .. .. ~. uno wnwu~w wuiAw ~onei~~iso 00 OC 13700 NOOZ01 lZZ io15 ague as (S~l ~e5 aw leag u~eeww eea(Ofi )I1~i oaf VwN a ~l'l l ~ II M ueiawa (3iN~a ae'J Noiivwao~Ni 3oN3a333a °~ NW°.+i Mf~o ~iP:o new n ueuva m m ne(am< <:: cc w. m aas ~s-w r..enxu ~ v~i i~o c°L~ e~seld d9 by ~ BP Alaska Anticollision Report 1NTLQ Company: BP Amoco Date: 7!7/2008 Time: 16:50:20 Page: 1 I Field: Prudhoe Bay Reference Site: PB DS 01 Co-ordinate(NE) Reference: Well: Ot-21, True North Reference Well: 01-21 Vertical (TVD) Reference: 33:21 10!2/1982 00:00 74.0 Reference Weppath: Plan 3, 01-21A Db: Oracle GLOBAL SCAN APPLIED: All wellpaths within 200'+ 100/1000 of reference -There are 1)~eY~nm~ls in this fii!hllcipal Plan & PLANNED PROGRAM Interpolation Method: MD Interval: 25.00 ft Error Model: ISCWSAEIIipse Depth Range: 9300.00 to 10730.00 ft Scan Method: Trav Cylinder North Ma7rimum Radius: 1269.60 ft Error Surface: Ellipse + Casing Survey Program for Definitive Wellpath Date: 7/7/2008 Validated: No Version: 0 Planned From To Survey Toolcode Tool N ame ft ft 100.00 9300.00 1 : Camera based gyro multisho CB-GYRO-MS Camera based gyro multishot 9300.00 10730.00 Planned : Plan 3 V1 MWD MWD -Standard Casing Points -_ _.__ - r MD TVD Diameter Hole Size Name ft ft in in 10730.00 9053.97 - ~ - 2.875 4.125 2 7/8" Summary <---------------------- Offset Wellpath ----- ----- -----------> Reference Offset Ctr-Ctr No-Go Allowable i ', Site Well Wellpath MD MD Distance Area Deviation Warning ft ft ft ft ft PB DS 01 01-21 01-21 V1 9350.00 9350.00 0.00 424.00 -424.00 FAIL: Major Risk PB DS 01 01-32 01-32A V1 Out of range PB DS 05 05-06 05-06 V2 Out of range PB DS 05 05-06A 05-06A V1 Out of range PB DS 05 OS-41 05-41A V3 Out of range Site: PB DS 01 Well: 01-21 Rule Assigned: Major Risk Wellpath: 01-21 V 1 Inter-Site Error: 0.00 ft Reference Off§et Seroi-Ma,~or Axis Ctr-Ctr No-Go Allowable MD TVD MD TVD Ref Offset TFO+A ZI TFO-HS Casing/IISDistance Area Deviation Warning ft ft ft ft ft ft deg deg in ft ft ft 9300.00 8719.88 9300.00 8719.88 112.40 112.40 357.00 0.00 0.00 421.88 -421.88 FAIL 9325.00 8743.47 9325.00 8743.46 112.61 112.81 356.51 0.00 0.03 423.25 -423.21 FAIL 9350.00 8767.05 9350.00 8767.05 112.81 113.22 356.51 0.00 0.00 424.00 -424.00 FAIL 9374.98 8790.46 9375.00 8790.66 112.82 113.64 180.03 182.70 0.54 136.09 -135.56 FAIL 9399.77 8813.10 9400.00 8814.29 112.81 114.05 188.50 187.83 2.74 184.30 -181.56 FAIL 9424.05 8834.49 9425.00 8837.94 112.75 114.38 191.75 188.67 6.92 210.63 -203.70 FAIL 9447.88 8854.63 9450.00 8861.62 112.77 114.82 192.35 190.55 12.92 217.85 -204.93 FAIL 9471.96 8874.63 9475.00 8885.33 112.67 115.15 187.22 192.99 19.44 182.99 -163.56 FAIL 9495.69 8894.06 9500.00 8909.06 111.99 114.90 180.09 192.88 26.31 143.30 -117.00 FAIL 9518.83 8912.63 9525.00 8932.80 110.76 114.07 172.55 191.68 33.81 139.92 -106.11 FAIL 9541.18 8930.12 9550.00 8956.56 109.05 112.76 165.27 190.02 42.19 175.06 -132.87 FAIL 9562.59 8946.38 9575.00 8980.32 106.95 111.03 158.52 188.21 51.61 219.68 -168.07 FAIL 9582.77 8961.20 9600.00 9004.09 104.69 109.06 152.51 186.24 62.15 259.70 -197.55 FAIL 9600.90 8973.92 9625.00 9027.87 102.76 107.45 147.81 183.55 74.03 286.80 -212.77 FAIL 9617.81 8985.17 9650.00 9051.66 100.77 105.80 143.96 181.41 87.25 304.37 -217.12 FAIL 9633.53 8995.07 9675.00 9075.46 98.83 104.17 140.79 179.70 101.66 315.17 -213.51 FAIL 9648.10 9003.75 9700.00 9099.27 96.97 102.58 138.14 178.33 117.12 321.05 -203.92 FAIL 9661.56 9011.31 9725.00 9123.10 95.15 101.04 135.91 177.20 133.58 322.84 -189.26 FAIL 9673.91 9017.87 9750.00 9146.99 93.47 99.60 134.01 176.27 150.98 322.65 -171.67 FAIL 9685.29 9023.57 9775.00 9170.89 91.86 98.23 132.37 175.49 169.15 320.15 -151.00 FAIL 9695.81 9028.55 9800.00 9194.80 90.37 96.96 130.95 174.83 187.92 316.77 -128.85 FAIL 9705.56 9032.90 9825.00 9218.71 88.98 95.77 129.70 174.27 207.24 312.40 -105.16 FAIL 9714.60 9036.71 9850.00 9242.62 87.68 94.68 128.60 173.78 227.03 307.47 -80.44 FAIL 9717.01 9037.69 9857.00 9249.31 87.33 94.38 128.31 173.66 232.65 306.08 -73.43 FAIL BP CTD BOP Stackup ' 2 3/8" Coil b p ~ Well: 01-21 A _ Rig: Nordic 2 Rig Floor to Top of Bag: 9.23' 7 1/16" ti drill Annular, 5000 psi (9.23' 7 1/16" 5000 si, RX-46 Blind Shears TOT 12.65') 23/8" Combi's TOT 13.56') 7 1/18" 5000 si, RX-46 Kill Line „~.,." 2 1/16" 5000 psi, RX-24 1 ~ 2 3/8" x 3 1/2" Variable Ram 16.10') ~~ 2 3/8" Combi TOT 16.66' 7 1/16" 5000 si, RX-46 f'i- 7 1/16" x 3 1/8" Flan ed Ada ter Tree Size: 41!18" Swab Valve 20.04' Flow Line SSV 22.88' Master Valve 24.86') Lock Down Screws 26.68' Ground Level 31.00' • TRANSMITTAL LETTER CHECKLIST WELL NAME _ i--' ~ ~/-~/~ PTD# ~Od~/.~/D Developments Service Exploratory Stratigraphic Test Non-Conventional Well FIELD: /~,ewD~oE /~AY POOL: ~.t~t/D.y~" ,~AJ/ 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 (If last two digits in API number are - permit No. , API No. 50- 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 (SO- - _) from records, data and Logs acquired for well SPACING The permit is approved subject to fait compliance with 20 AAC EXCEPTION 25.055. Approval to perforate and produce /inject is contingept 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 throu h tar et canes. 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 wain until after (Comoanv Namel has designed and implemented a water well testing program to provide baseline data on water quality and quantity. 1Comuanv NameLmust contact the Commission to obtain advance approval of such water well testing ro Rev: 1!11/2008 Alaska Department of Natural Resources Land Administration System Page 1 of~ ~ . , ,~,;;.. _~~ _ ;-1~is Recorder`s ~earcn State Ga€ains 1~1~tu~ ~~s Alaska DNR Cass Summary File Type: ADS File Number: 28329 ~ Pr..n..table .Case Fil.e_Summary See Township, Range, Section and Acreage? ~` Yes No New Search l_AS Mena I Case Abstract I Case Detail I Land Abstract ~~ , File: ADL 28329 Search for Status Ptat Updates ~ti c,CQb;'14,''~'L~OS Customer: 000107377 BP EXPLORA1~lOV (ALASKA)1NG PO BOX t966i2/900 E. BENSON BL ATTN: LAND MANAGER- ALASKA ANCHORAGE AK 995196612 Cuse Type: O[L & GAS LEASE COMP DNR Unit: 780 OIL-AND GAS File Location: DOG DIV OIL AND GAS Case Status: 35 ISSUED Status Date: 09/14/1965 Total Acres: 2501.000 Date Initiated: 05/28/1965 Office of Prirr~tary Responsibility: DOG DIV OIL AND GAS Last Transaction Date: 12/04/2006 Case Subtype: S NORTH SLOPE Last Transaction: AA-NRB ASSIGNMENT APPROVED Meridian: T~ To~~~~~~{ri~~: 0I ON Ram~t~: (11 ~1: .5'c~~~uon: OS Section ~1ci~~~s: 610 Search r~lats Meridian: U 7ulrnsfli/~: Q 1 UN Rarz~{e.~ U I ~t, Seetr~~it.~ U6 .ti~c~cliurl .~I~~re,~: 6O~) Meridian: U 7utii~n.~h1/~: 0111N /~uri~c~.~ I)1 SE Secli~~ir: U % .1'~~c~/inn :lcf~c,~~: (; L Meridiara.~ l ! 7nirnshii>: 0 I QN l~~nr,~~~.~ 015E Sectio~~ ~ f 1~ ,Sc~c~rr»7 ~lcr~~s: (i~[0 Lc;;al Description 0~ -28-196 * * *SALE NOTICE LEGAL DESCRIPTIDN* C1-1-1~9 TION-RISE-UM~,6, 7,8 2501.00 U- 3- 7 ~Ctd t~ 'Su arjt Last updated on 08/14/2008. http://www.dnr. state.ak.us/las/Case_Summary. cfm?FileType=ADL&FileNumber=28329&... 8/ 14/2008 WELL PERMIT CHECKItST Field i£ Pool PRUDHOE BAY, PRUDHOE OIL -640150 Weil Name: PRUDHOE BAY UNIT 01-21A Program DEV Well bore seg ^ PTD#:2081310 Company BP EXPLORATION (ALASKA) INC Initial Classftype DEV 11-OIL GeoArea 890 Unh 11650 On1Off Shore Qn Annular Disposal ^ Administration 1 Pe[mikfeeattached-- --------- - -- ------ ------- ~--- - - - - - --------------- -- - -- ------ 2 Lease number appropriate----- -- -- - ----- --- - --- -- Yes-- ------ - - - - - - ----------- -- --- - --- ---- 3 UniQUa4veil-name andnumttet-- -- ------ -- - -- --- --- Yes -- -- -- ------ --- -- --- -- -- -- -- -- ---- 4 -Welllocakedin_adeflned_p901------- -- -- ------ - --------- Yes- PtudhoeBaYFieid - - - - --------------- -- - - -- ------ 5 -Wfllllrlcakedptop~rdistance$omdrUlin9unit_boundary--.------------------- Yes-- ----------------------------------------------------------------- 6 -WeIUQCated p[oper distance from otherwQlis - - - - - - - - - - - - Yes - - - - - - - - - - - - - - - - - - - - - - - - - - ~ - - 7 Suificiegtecreageavailablein_dnllingunit--_-------_---____----_----- Yes-- .--.-25.69 acres•----------------------------------------_-- --------------- 8 If-deviat~d,isweilborepiat_included ------- -- - ---- -- Yes - -- -- -- -- ----- ------ --- - -- -- - - ---- - 9 ORetatoroniyaffectedRarb- - ---- -- - - ---- -- Yes --- -- -- -- ----- ------------------ - - --- ---- -- --- ---- 10 Opstatotbes_appropriatebo-ndiAfprce-------------------------------- YSS-- -----QlanketBond#6124198•.-----------------------------------.------------- 11 PetmitcanbelssuedwithoutGOnsfln/atiDnerder---------------------------- Yes.- ---.....--------------------------------------------------------------- Appr Date 12 Pemlikcanbeissuedwkhoutadmin~itative.approval----------------------_- Yes-- -----.------.-.---__-__-.- ACS 8!1412008 13 Can permit be approved before l$-day_wah__._...-- - ~-- - - - . Yes-- - ---- -- -- -- --- --- -- ---- --- - - - -- ---- - - -- .. 14 -4ye1114catadwithinarQaand_strataauthprizedby-InjectionOrdet#(put19#in_comments)-(F4r- -NA--- --------------------------------------------------------_-------------- 15 All!n~ells_within114_mileatfla_aftevietivideMifiad(Fo[4eNicewell9nly)--------------- -NA--- ----------------------------------.---------------.---------------.---- 16 Pte-produced injector;dur~tionofpre-producti9nlessthan3mgnths_(For-servicewsll Qnly)- -PtA_-- --------------------------------------------------.-------------------- 17 -KoDCOnYan.gas.c9nfortnstcA$81,05:08Q(j1.A)~Cl•2.A-D) -- - ------ ---- -~--- - - - ... - - ------ ------------ -- -- --- - -- -------- Engineering 18 Canducto[sttirtg.provided----------------------------------------- -NA--- _---_CortduCtorset_int)541.21(182-152J•--------------------------------..-.-...------ 19 Surface-casingprotecisall_knowrtUSDWS______-_---------------------- -NA--- -----Noaquifers,A1O4!$,-Conclusion-5____________-____-_______-----_-------_--_-- 20 CMTvoladsquatetecirculate_on-conducto[&surfcsg-__--_----------------- -NA-._ ----_S4rfacecasing set in QS 91.21.________-____________-_______-_____--_--------- 21 CMTvoladequaietolie-inlQngstringtosurfcsg__________________________ _NA-_ ----_ProductiQn_casingsetin_D$Q1.21,_________________-_--_._-__--______-_______ 22 CMT-willcover.allknown-productive horizons--------------------------- -- Yes-- -------------.------------------...-----------------------------._-_-- 23 Casing designs adequatefo[C,T,B&permafrost--------------------------- Yes-- ----.----------.---.--.-----.----------------------------------_--_-- 24 Adequate tankage_or reserve pit - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - Yes _ _ - - _ -Rig equipped with steel pits, Ato-reserve pit planned._ All waste_t4 apRroved disposal well(s). - - - - - _ _ - - - _ - - 25 Ifa_re-d[ilGhas_a10.4083orabandonment4eepaRproved---------------------- Yes-- -.---182,152----_---------------_-------------------------------------_ 26 Adequate wellpote separationproposed - - - - - - - --- - - - - - - - - - - - - - - - - - - - - - - Yes _ _ - - - _ - Proximity analysis performed, Nearest segment is P$~A portion of DS 01-21 and paths diverge.- - - - - _ - - - _ - - 27 Ifdivert@rrequited,doesitmeetregulations---------------------------- -- NA__- _-___QOPSiackwillalteady_be-irlRlace,--------------------------------------.------- Appr Date 28 Drilling fluid-program schematic & Q4uip list adequake- - - - - - - - - - - - - - - - - - - - - - - - Yes - _ - _ .Maximum expected formation pressure 7,2-EMW._ PAVY planned $.$ ppg. _ - _ _ . _ _ _ - - - - - - - - - - - - - - - - - TEM 8!1812008 29 BOPIS,-do-theymeetregulation- - ------ -- - -- ------ Yes- - - - - -- -- - - ------------- -- -- - -- --- ~~`~ 30 BOPE_press feting apptopriaie;lest to_(put psig in comments)_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ - - - _ - - MASP calculated at 2887 psi, 8500_psi_ BOP testplanned, _ _ - _ _ _ _ _ - . _ _ - - - - - - - _ - - - - - - _ - - _ ~ -_ 31 Choke manifoldc~nplieswlAPI-RP•58(_MaY$4_)- -- - - ---- ----- Yes- - - -- -- ----- ---- ---------- -- - - - -- --- - 32 Work willoccutwithoutoperationshutdown---- --- --- - - --- ------ Yes- --- ~- - - - --- --------------- --- ---- - - 33 Is presence of H2S gasprgbabie- - - - - - - - - - - - --- - - _ . - - - - - - - - - - - - _ - - . Yes . _ _ - H2$ is reported_at DS 01.- Mud should preclude on_rig, Rig_has sensors and alarms._ - _ - - - - - - _ _ - - - _ - - _ 34 Mechanical-condition of wells withinA4Rverified(FCrsetvicewellonly)------------- NA--- --------------.--------------,------------------------------------.--- Geology 35 Permit can beissuesfwlohydrogen_su(fidemeasutes_______._.______________ Na___ _____MaxH2Slavelondnhsite_1=140_ppmonwe1101.7A.___________-__--__.____-____--_____ 36 Data-Rresented ort Rolflntiai ove~pressu[e zones - - - - - - - - - - - -~! - - - - - - - - - - - - - - - - - - - - - - - - - - - - Appr Date 37 Seismicanatysisofshallow9as_zones---------------------.-----_----- NA__- ________ -.- ACS 811412008 38 SeabedcondAkons~rrvay_(ifoffshote)---_--_.-_------------------__- NA-- . 39 Contactnamelphoneforweekly-progressrepods_(explotatoryonltt]---_-_---__.--_- Yes__ __-__CharlesReynolds-_564.5480,__-__________________________________________- Geologic Date: Engineering Date Public Date Commissioner. Commissioner: Commissioner WELL PERMI CHECKLIST Field & Pool PRUDHOE BAY, PRUDHOE OIL - 640150 Well Name: PRUDHOE BAY UNIT 01-21A Program DEV Well bore seg ['~, PTD#:2081310 Company BP EXPLORATION (ALASKA) INC Initial ClasslType DEV ! PEND GeoArea 890 Unit 11650 On1Off Shore On Annular Disposal Administration 1 1 Permit-fee attached. NA i 2 Lease number appropriate_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ _ _ 3 Unique well_name and number _ , _ _ - _ Yes _ _ 4 Well located in a. defined pool Yes - - - - - - .Prudhoe Bay Field - - - 5 Well located p[oper distanre_from drilling unit-bopndary_ _ _ _ _ _ Yes _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . _ - . 6 Well located properdistance_fromothe-rwells_______ _________________ ___ Yes__ ________________________--.--...- 7 Sufficient acreage available in-drilling unit_ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ _ _ _ _ _ 2560 acres. _ _ _ _ - _ _ - _ _ . - 8 If_deviated,is_wellboreplat-included_______________________ _______ ___ Yes__ ____ 9 Ope[atoronlyaffectedparty -------------- Yes-- ----____.__-________ - - - 10 Operatorhas-appropriate_bondfnforce____-___- Yes.- --.--BlanketBond#6194193____ __ ________________________ ______ ______________ 11 Permitcan be issued without conservation order- _ - - - Yes - - - _ - . - 12 Permitcan be issued without administrativ-e-approval _ _ _ _ _ _ _ _ _ _ _ _ _ __ _ _ _ _ _ _ _ _ Yes - - Appr Date 13 _C_an permit tie approved before 15-day wait Yes ACS 8!1412008 14 Well located within area and_strata authorized by-Injection Order # (put 10# in_comments)-(For- NA- - - - - - - 15 All wells within1l4.milearea_ofreviewidentified(Forservicewellonly)________ ___ __ NA_-_ -_--..---.--- ------_----_-_________________________-------.------.-.-- 16 Pre-produced injector; duration of preproduction I_essthan-3 months-(For_service well only) _ - NA_ _ - _ - - . 17 Nonconven, gas conforms to AS31,05,030(j.1_.A),(j.2.A-D) - NA_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 18 -- Conductor string_provided _ _ _ _ _ _ _ _ . - InCmpt - - - - - _ _ _ _ Engineering 19 Surface casing_protectsall_knownUSDWs-_________ InCmpt _________ ____________- -.---...-....-.- -.--.----- ---__--_----__--_ 20 CMT_u_ol_adequ_ate_tocircul_ate.o_nconductor&surf-csg__-- --------------_- InCmpt ________________________ 21 CMT.vol-adequate_totie-inlongstringtosurfcsg__ ___ __ ______ ___ InCmpt -- .--..- -__________ __ __________ ___ ______ __._-.--.- -._-____ -....- 22 CMT.will cover all known_productivehorizons- .. - _ _ _ _ _ _ _ _ _ _ _ . InCmpt - _ _ _ _ - - _ - 23 Casing designs adequate f_or C,_T, B &_ permafrost- - - . - - InCmpt - - - . - - .. - 24 Adequate tankage_or reserve pit - . - .. InCmpt _ _ _ _ _ _ - - - - - - - - - - - - - - - - - 25 If a. re-drill, has_a_ 10-403 fo_r abandonment been approved InCmpt - 26 Adequatewellboreseparation_proposed- . - - - - - _ - _ _ _ InCmpt _ - _ _ - - - _ _ _ _ _ _ _ _ _ _ _ __ _ _ 27 If diverter required, does it meet regulations_ InCmpt ~ 28 Drilling fluid_program schematic & equip list adequate_ InCmpt ---- Appr Date ~ 29 BOPEs, do the meet_ re ulation _ y InCmpt - - - - - - .. - 30 BOPE_pressratingappropriate;testtc_(putpsigincomments)__ ______ ___ ____ _ InCmpt -_-.--.....-------.__-_ __-_______ ________________ __ ___.______ -___ 31 Choke_manifoldcomplieswlAPl_RP-53(fviay84)-.-__-- __ InCmpt --.- ______________ __ __________ ___ ____________ __________ ____.-.- 32 Work will occur without operation shutdown- - InCmpt 33 Is presence_of H2$ gas-probable - InCmpt - .. . 34 I Mechanical condition of wells withinAORverified(Fo[servicewellonly)-__-___-_____ InCmpt ____-_-------------_---_.____--_--_-__-_--------___------- ---------- - - 135 -- Permitcan be issued wlo hydrogen_sulfiderneasures - - - . - - No_ Max H2$ lev_el on_drill site-1=140ppm on well 01-7A. - --- Geology 36 Data-presented on potential overpressure zones- - - - - - - - - - - - - - - - - - - - NA_ - - - - - _ - 37 Seismic analysis-of shallow gas_zones_ _ _ _ _ _ - NA- - - - - - - - - - - - - - - _ - - - - Appr ate 38 Seabed condition Survey_(if off_-shore) NA ------ ACS 8/14!2008 X39 Contact namelphone for weekly_progress reports_ [exploratory only] Yes Charles Reynolds --564-5480, - - - - - - - . ~ - Geologic Engineering P Commissioner: Date: Co fission r: Date Co issi r Date • . Welt History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. • • tapescan.txt **** REEL HEADER **** MWD 09/01/26 BHI 01 LIS Customer Format Tape **** TAPE HEADER **** MWD 08/09/28 2213107 O1 3" CTK *** LIS COMMENT RECORD *** !!!!!!!!!!!!!!!!!!! Remark File version 1.000 !!!!!!!!!!!!!!!!!!! Extract File: ldwg.las version Information VERS. 1.20: CWLS log ASCII Standard -VERSION 1.20 WRAP. NO: One line per frame well Information Block #MNEM.UNIT Data Type Information STRT.FT 9093.0000: Starting De th STOP.FT 10744.0000: Ending Dept h STEP.FT 0.5000: Level spacing NULL. -999.2500: Absent value COMP. COMPANY: BP Exploration (Alaska), Inc. WELL. WELL: 01-21A FLD FIELD: Prudhoe Bay Unit LOC LOCATION: 70 deg 14' 29.667"N 148 deg 24' 7.922"w CNTY. COUNTY: North Slope Borough STAT. STATE: Alaska SRVC. SERVICE COMPANY: Baker Hughes INTEQ TOOL. TOOL NAME & TYPE: 3" CTK DATE. LOG DATE: 28 Sep 2008 API API NUMBER: 500292082701 Parameter Information Block #MNEM.UNIT Value SECT. 08 . TOWN.N T10N . RANG. R15E . PDAT. MSL . EPD .F 0 . LMF DF . FAPD.F 74 . DMF DF . EKB .F 0 EDF .F 74 EGL .F 0 Page 1 Description section Township Range Permanent Datum Elevation Of Perm. Datum Log Measured from Feet Above Perm. Datum Drilling Measured From Elevation of Kelly Bushing Elevation of Derrick Floor Elevation of Ground Level ~p'~ (`3 ! t~Sb( ~ ~ tapescan.txt CASE.F N/A Casing Depth OS1 DIRECTIONAL Other Services Line 1 Remarks (1) All depths are Measured Depths (MD) unless otherwise noted. (2) All depths are Bit Depths unless otherwise noted. (3) All True vertical Depths (TVDSS) are Subsea corrected. (4) All Formation Evaluation data is realtime data. (5) Baker Hughes INTEQ utilized CoilTrak downhole tools and the Advantage surface system to log this well.. (6) Tools ran in the string included Casing Collar Locator, an Electrical Disconnect and circulating sub, a Drilling Performance sub (Inner and outer Downhole Pressure, vibration and Downhole weight on Bit), a Directional and Gamma sub, and a Hydraulic orienting sub with a Near Bit Inclination sensor. (7) Data presented here is final and has been depth adjusted to a PDC (Primary Depth Control) log provided by schlumberger GR CNL dated 29 Sep 2008 per Priya Mara with BP Ex loration (Alaska), Inc. (8) The sidetrack was drilled ~rom 01-21 through a milled window in a 7 inch liner. Top of window 9345 ft.MD (8687.9 ft.TVDSS) Bottom of window 9352 ft.MD (8694.5 ft.TVDSS) (9) Tied to 01-21A at 9300 feet MD (8645.9 feet TVDSS). (10) The interval from 10703 feet to 10743 feet MD (8974.4 feet to 8982.0 feet TvDSS) was not logged due to sensor to bit offset at well TD. MNEMONICS: GRAX -> Gamma Ray [MWD] (MWD-API units) ROP~4VG -> Rate of Penetration, feet/hour RACLX -> Resistivity (AT)(LS)400kHz-Compensated Borehole Corrected (OHMM) RACHX -> Resistivity (AT)(LS)2MHz-Compensated Borehole Corrected (OHMM) RPCLX -> Resistivity (PD)(LS)400kHz-Compensated Borehole Corrected (OHMM) RPCHX -> Resistivity (PD)(LS)2MHz-Compensated Borehole Corrected (OHMM) TVDSS -> True vertical Depth (subsea) CURVE SHIFT DATA BASELINE, MEASURED, DISPLACEMENT 9101.41, 9101.82, ! 0.414062 9108.25, 9109.29, ! 1.03613 9113.22, 9114.67, ! 1.45117 9117.16, 9117.99, ! 0.829102 9119.03, 9120.06, ! 1.03613 9122.55, 9124, ! 1.45117 9125.45, 9126.08, ! 0.62207 9132.5, 9132.09, ! -0.414062 9135.4, 9135.2, ! -0.207031 9138.1, 9137.68, ! -0.415039 9139.96, 9139.14, ! -0.829102 9142.87, 9141.42, ! -1.45117 9146.39, 9145.15, ! -1.24414 9149.5, 9149.5, ! 0 9152.4, 9152.82, ! 0.415039 9154.68, 9155.1, ! 0.415039 9157.58, 9157.58, ! 0 9161.11, 9161.11, ! 0 9163.6, 9163.39, ! -0.207031 9166.5, 9166.5, ! 0 9171.89, 9172.51, ! 0.62207 9176.6, 9176.6, ! 0 9179.09, 9179.09, ! 0 9181.78, 9181.99, ! 0.207031 9185.3, 9185.51, ! 0.208008 9189.04, 9189.04, ! 0 Page 2 9192.35, 9191.94, 9194.63, 9194.84, 9327, 9327, ! 9330.94, 9331.36, 9344.62, 9343.8, 9348.98, 9348.98, 9350.64, 9351.05, 9352.71, 9353.33, 9358.93, 9358.51, 9361, 9361.42, 9366.18, 9367.63, 9369.29, 9369.5, 9371.57, 9372.2, 9373.23, 9374.89, 9382.76, 9383.17, 9385.25, 9385.45, 9387.73, 9388.36, 9390.22, 9390.84, 9392.29, 9393.12, 9394.99, 9395.2, 9404.29, 9404.46, 9408.05, 9408.46, 9409.92, 9410.74, 9439.15, 9440.54, 9443.14, 9443.83, 9474.53, 9475.57, 9483.02, 9483.89, 9488.23, 9489.09, 9509.15, 9508.28, 9515.74, 9516.6, 9522.85, 9524.24, 9540.36, 9541.58, 9542.62, 9543.83, 9549.03, 9548.33, 9555.97, 9556.31, 9566.89, 9567.76, 9570.71, 9571.57, 9574.18, 9575.04, 9577.3, 9578.34, 9580.25, 9581.11, 9607.3, 9608.86, 9609.56, 9610.94, 9613.37, 9615.11, 9616.67, 9618.75, 9623.36, 9623.36, 9625.62, 9625.1, 9627.18, 9627.35, 9634.12, 9632.9, 9648.51, 9649.38, 9652.67, 9653.37, 9660.83, 9660.83, 9665.51, 9665.51, 9668.97, 9669.15, 9670.71, 9670.88, 9680.59, 9680.94, 9683.54, 9683.19, 9690.65, 9690.3, 9695.68, 9695.68, 9704.53, 9704.18, 9715.28, 9714.58, 9724.3, 9723.26, 9725.66, 9726.7, 9728.96, 9729.3, tapescan.txt ! -0.415039 ! 0.208008 0 ! 0.415039 ! -0.829102 ! 0 ! 0.415039 ! 0.62207 ! -0.415039 0.414062 ! 1.45117 ! 0.208008 ! 0.62207 ! 1.6582 ! 0.414062 ! 0.207031 ! 0.62207 ! 0.62207 ! 0.829102 ! 0.207031 ! 0.172852 ! 0.414062 ! 0.829102 ! 1.38672 ! 0.694336 ! 1.04102 ! 0.867188 ! 0.867188 ! -0.867188 ! 0.867188 ! 1.3877 ! 1.21387 ! 1.21484 ! -0.693359 ! 0.34668 ! 0.867188 ! 0.867188 ! 0.867188 ! 1.04102 ! 0.867188 ! 1.56152 ! 1.3877 ! 1.73438 ! 2.08203 ! 0 ! -0.520508 ! 0.173828 ! -1.21387 ! 0.867188 ! 0.694336 ! 0 ! 0 ! 0.172852 ! 0.173828 ! 0.34668 ! -0.34668 ! -0.347656 ! 0 ! -0.34668 ! -0.694336 ! -1.04004 ! 1.04004 ! 0.34668 Page 3 tapescan.txt 9732.08, 9732.94, ! 0.867188 9738.32, 9738.32, ! 0 9756.01, 9754.8, ! -1.21387 9758.96, 9758.26, ! -0.693359 9761.73, 9761.04, ! -0.694336 9777.34, 9777.51, ! 0.172852 9781.67, 9781.33, ! -0.34668 9789.13, 9789.83, ! 0.693359 9793.12, 9793.29, ! 0.173828 9797.11, 9796.94, ! -0.173828 9813.12, 9811.56, ! -1.56055 9818.84, 9819.02, ! 0.173828 9821.45, 9820.92, ! -0.520508 9834.57, 9835.09, ! 0.519531 9840.98, 9843.41, ! 2.42773 9845.84, 9846.7, ! 0.867188 9849.65, 9850.69, ! 1.04004 9864.57, 9866.3, ! 1.7334 9874.16, 9873.46, ! -0.694336 9876.41, 9875.89, ! -0.520508 10107.6, 10108, ! 0.34668 10140.7, 10141.6, ! 0.867188 10145.7, 10145.4, ! -0.34668 10149.7, 10148.5, ! -1.21387 10155.6, 10157.3, ! 1.73438 10196, 10194.1, ! -1.9082 10201.2, 10198.3, ! -2.94824 10209.2, 10205.4, ! -3.81543 10224.8, 10221.3, ! -3.46875 10252.3, 10248.7, ! -3.64258 10261.7, 10257.7, ! -3.98926 10264.6, 10261.7, ! -2.94824 10269, 10266.9, ! -2.08105 10279.2, 10279, ! -0.173828 10367.8, 10361.7, ! -6.06934 10429.1, 10425.3, ! -3.81543 10465.7, 10465.1, ! -0.520508 10471.7, 10471.4, ! -0.34668 10558.8, 10556.7, ! -2.08105 10562.8, 10560, ! -2.77441 10566.4, 10563.1, ! -3.2959 10591.8, 10588, ! -3.81543 10598.8, 10593.4, ! -5.37695 10600.7, 10596.4, ! -4.33594 10607.3, 10603.6, ! -3.64258 10618.7, 10615.4, ! -3.2959 EOZ END ! BASE CURVE: GROH, OFFSET CURVE: GRAX Tape Subfile: 1 210 records... Minimum record length: 10 bytes Maximum record length: 132 bytes **** FILE HEADER **** MWD .001 1024 Page 4 • tapescan.txt *** LIS COMMENT RECORD *** !!!!!!!!!!!!!!!!!!! Remark File version 1.000 The data presented here is final and has been depth shifted to a PDCL from Schlumberger GR CNL dated 29 sep 2008 per Priya Maraj with BP Exploration (Alaska), Inc. * FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame size is: 28 bytes Logging direction is down (value= 255) Optical Lod Depth Scale units: Feet Frame spacing: 0.500000 Frame spacing units: [F ] Number of frames per record is: 36 one depth per frame (value= 0) Datum specification Block sub-type is: FRAME SPACE = 0.500 * F ONE DEPTH PER FRAME Tape depth ID: F 6 Curves: Name Tool 1 GR MWD 2 ROP MWD 3 RAD MWD 4 RAS MWD 5 RPD MWD 6 RPS MWD Code Samples Units 68 1 AAPI 68 1 F/HR 68 1 OHMM 68 1 OHMM 68 1 OHMM 68 1 OHMM Total Data Records: 92 Tape File start Depth = Tape File End Depth = Tape File Level Spacing = Tape File Depth units = **** FILE TRAILER **** Tape Subfile: 2 105 Minimum record length: 54 Maximum record length: 4124 **** FILE HEADER **** MWD .001 1 Size Length 4 4 4 4 4 4 4 4 4 4 4 4 24 9093.000000 10739.500000 0.500000 feet records... bytes bytes Page 5 ~ ~ tapescan.txt 1024 *** LIS COMMENT RECORD *** !!!!!!!!!!!!!!!!!!! Remark File version 1.000 The data presented here is final and has been depth shifted to a PDCL from MwD 01-21A dated 28 Sep 2008 per Doug Stoner with BP Exploration (Alaska), Inc. * FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame size is: 28 bytes Logging direction is down (value= 255) optical Log Depth Scale Units: Feet Frame spacing: 0.500000 Frame spacing units: [F ] Number of frames per record is: 36 one depth per frame (value= 0) Datum specification Block sub-type is: FRAME SPACE = 0.500 * F 1 ONE DEPTH PER FRAME Tape depth ID: F 6 Curves: Name Tool 1 GR MWD 2 ROP MWD 3 RAD MWD 4 RAS MWD 5 RPD MWD 6 RPS MWD code samples units 68 1 AAPI 68 1 F/HR 68 1 OHMM 68 1 OHMM 68 1 OHMM 68 1 OHMM size Length 4 4 4 4 4 4 4 4 4 4 4 4 24 Total Data Records: 92 Tape File Start De th = Tape File End Depth = Tape File Level Spacing = Tape File Depth Units = **** FILE TRAILER **** Tape Subfile: 3 105 Minimum record length: 54 Maximum record length: 4124 9093.500000 10740.000000 0.500000 feet records... bytes bytes Page 6 i ~ tapescan.txt **** FILE HEADER **** MWD .001 1024 *** LIS COMMENT RECORD *** !!!!!!!!!!!!!!!!!!! Remark File version 1.000 This file contains the raw-unedited field MADPass data. * FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame Size is: 28 bytes Logging direction is down (value= 255) optical Lod Depth Scale units: Feet Frame spacing: 0.250000 Frame spacing units: [F ] Number of frames per record is: 36 one depth per frame (value= 0) Datum specification Block sub-type is: FRAME SPACE = 0.250 * F 1 ONE DEPTH PER FRAME Tape depth ID: F 6 Curves: Name Tool 1 GR MWD 2 ROP MWD 3 RAD MWD 4 RAS MWD 5 RPD MWD 6 RPS MWD Code samples units 68 1 AAPI 68 1 F/HR 68 1 OHMM 68 1 OHMM 68 1 OHMM 68 1 OHMM Size Length 4 4 4 4 4 4 4 4 4 4 4 4 24 Total Data Records: 184 Tape File Start De th = Tape File End Depth = Tape File Level Spacing = Tape File Depth Units = **** FILE TRAILER **** Tape Subfile: 4 197 Minimum record length: 34 Maximum record length: 4124 9093.000000 10740.000000 0.250000 feet records... bytes bytes Page 7 - • tapescan.txt **** FILE HEADER **** MWD .001 1024 *** LIS COMMENT RECORD *** !!!!!!!!!!!!!!!!!!! Remark File version 1.000 This file contains the raw-unedited field MwD data. * FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame size is: 28 bytes Logging direction is down (value= 255) optical Lod Depth scale units: Feet Frame spacing: 0.250000 Frame spacing units: [F Number of frames per record is: 36 one depth per frame (value= 0) Datum specification Block sub-type is: FRAME SPACE = 0.250 * F 1 ONE DEPTH PER FRAME Tape depth ID: F 6 Curves: Name Tool 1 GR MWD 2 ROP MWD 3 RAD MWD 4 RAS MWD 5 RPD MWD 6 RPS MWD Code samples units 68 1 AAPI 68 1 F/HR 68 1 OHMM 68 1 OHMM 68 1 OHMM 68 1 OHMM Size Length 4 4 4 4 4 4 4 4 4 4 4 4 24 Total Data Records: 184 Tape File Start Depth = Tape File End Depth = Tape File Level Spacing = Tape File Depth Units = **** FILE TRAILER **** Tape Subfile: 5 197 Minimum record length: 54 Maximum record length: 4124 9093.000000 10743.000000 0.250000 feet records... bytes bytes Page 8 tapescan.txt **** TAPE TRAILER **** MWD 08/09/28 2213107 O1 **** REEL TRAILER **** MWD 09/01/26 BHI Ol Tape subfile: 6 2 records... Minimum record length: 132 bytes Maximum record length: 132 bytes Tape subfile 1 is type: LIS Tape Subfile 2 is type: LIS DEPTH GR ROP RAD RAS RPD RPS 9093.0000 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 9093.5000 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 9100.0000 58.8614 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 9200.0000 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 9300.0000 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 9400.0000 27.6324 34.8566 31.1359 71.5936 31.0503 24.8997 9500.0000 24.5185 53.3251 25.7123 62.4074 39.2680 35.0763 9600.0000 24.2674 71.9516 19.7725 33.8015 31.8281 32.2638 9700.0000 30.1484 14.6745 13.6972 17.9751 16.5754 15.7290 Page 9 ~ i tapescan.txt 9800.0000 99.0421 88.7336 6.5285 7.4483 8.1008 8.9079 9900.0000 25.9503 123.6565 4.9037 5.3224 5.1340 4.9724 10000.0000 22.2663 364.3313 5.0044 5.4762 5.2717 5.1417 10100.0000 23.9119 89.6627 7.7980 9.5984 9.9358 10.5292 10200.0000 54.2647 54.7289 7.1802 7.5301 7.8192 8.4884 10300.0000 28.4846 99.0526 9.3958 12.0596 12.3982 13.1041 10400.0000 25.7168 157.1995 7.7337 9.3438 10.7963 12.7928 10500.0000 21.5870 134.4483 7.3495 7.0386 6.3826 5.6386 10600.0000 62.3000 81.1000 8.7500 9.9120 9.1510 8.9380 10700.0000 -999.2500 81.7789 8.5032 9.3540 8.2764 7.4998 10739.5000 -999.2500 70.2801 -999.2500 -999.2500 -999.2500 -999.2500 Tape File Start De th = 9093.000000 Tape File End Depth = 10739.500000 Tape File Level Spacing = 0.500000 Tape File Depth units = feet 0 Tape subfile 3 is type: LIS DEPTH GR ROP RAD RAS RPD RPS 9093.5000 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 9094.0000 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 9100.0000 59.0386 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 9200.0000 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 9300.0000 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 9400.0000 27.5992 34.7371 -999.2500 -999.2500 -999.2500 -999.2500 Page 10 ~ i tapescan.txt 9500.0000 25.8805 48.0650 26.1572 58.0934 34.1949 29.1472 9600.0000 24.2699 71.6757 20.1259 31.5155 27.2388 26.0885 9700.0000 31.3271 12.4293 14.2907 18.6856 15.9761 14.5212 9800.0000 98.1571 87.5110 6.5804 7.6843 8.3597 9.3113 9900.0000 26.1117 121.7846 4.8167 5.2231 5.1628 5.1229 10000.0000 22.1795 371.3588 5.0006 5.4622 5.2832 5.1726 10100.0000 23.0341 89.9553 7.8423 9.6338 9.5830 9.8922 10200.0000 55.5541 53.0860 7.4566 7.8002 8.0187 8.5907 10300.0000 28.0617 96.0594 9.4451 12.3999 12.3237 12.7344 10400.0000 25.0856 157.3333 7.7872 9.6283 11.2023 13.5478 10500.0000 21.6853 134.1470 6.8520 6.3039 5.8400 5.2452 10600.0000 62.3000 89.3624 9.2199 10.4375 9.4028 8.9878 10700.0000 -999.2500 80.6578 8.3678 9.2479 8.1900 7.4862 10740.0000 -999.2500 70.2000 -999.2500 -999.2500 -999.2500 -999.2500 Tape File Start Depth = 9093.500000 Tape File End Depth = 10740.000000 Tape File revel spacing = 0.500000 Tape File Depth units = feet 0 Tape Subfile 4 is type: LIS DEPTH GR ROP RAD RAS RPD RPS 9093.0000 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 9093.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 9100.0000 57.4000 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 9200.0000 -999.2500 -999.2500 -999.2500 -999.2500 Page 11 tapescan.txt -999.2500 -999.2500 9300.0000 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 9400.0000 28.2000 36.9000 -999.2500 -999.2500 -999.2500 -999.2500 9500.0000 23.8000 56.1000 26.3660 57.5360 34.7100 29.4880 9600.0000 21.3000 70.4000 20.1670 32.2470 28.6980 27.8330 9700.0000 29.4000 16.1000 14.5210 18.9600 15.8880 14.2780 9800.0000 101.9000 72.6000 6.6400 7.7610 8.4010 9.3810 9900.0000 26.8000 113.8000 4.8050 5.2080 5.1470 5.1160 10000.0000 22.3000 361.6000 5.0000 5.4620 5.2820 5.1770 10100.0000 21.7000 90.4000 7.8370 9.6120 9.5990 9.9580 10200.0000 31.6000 85.7000 6.3400 6.5110 6.6860 7.4420 10300.0000 28.5000 123.0000 9.4690 12.1230 12.0970. 12.5040 10400.0000 32.9000 128.1000 7.7590 9.3430 10.3810 11.8140 10500.0000 22.4000 148.0000 6.9700 6.4660 5.9530 5.3060 10600.0000 61.0000 115.9000 8.5830 9.6760 9.0360 9.0450 10700.0000 46.5000 84.1000 8.8780 10.0770 8.7460 7.8610 10740.0000 -999.2500 66.0000 -999.2500 -999.2500 -999.2500 -999.2500 Tape File start De th = 9093.000000 Tape File End Depth = 10740.000000 Tape File Level Spacing = 0.250000 Tape File Depth units = feet 0 Tape Subfile 5 is type: LIS DEPTH GR ROP RAD RAS RPD RPS 9093.0000 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 Page 12 tapescan.txt 9093.2500 -999.2500 -999.2500 -999.2500 -999.2500 9100.0000 57.4000 -999.2500 -999.2500 -999.2500 9200.0000 -999.2500 -999.2500 -999.2500 -999.2500 9300.0000 -999.2500 -999.2500 -999.2500 -999.2500 9400.0000 28.2000 36.9000 30.8800 24.6700 9500.0000 23.8000 56.1000 39.8490 35.7150 9600.0000 21.3000 70.4000 31.6140 31.9800 9700.0000 29.4000 16.1000 16.7240 15.8580 9800.0000 101.9000 72.6000 8.2050 9.0490 9900.0000 26.8000 113.8000 5.1450 4.9970 10000.0000 22.3000 361.6000 5.2720 5.1430 10100.0000 21.7000 90.4000 9.8820 10.5100 10200.0000 31.6000 85.7000 6.3610 6.8270 10300.0000 28.5000 123.0000 12.2680 12.9380 10400.0000 32.9000 128.1000 9.6880 10.6910 10500.0000 22.4000 148.0000 6.4970 5.6940 10600.0000 61.0000 115.9000 9.0720 9.3390 10700.0000 46.5000 84.1000 9.4490 8.5750 10743.0000 -999.2500 70.2000 -999.2500 -999.2500 Tape File Start Depth = p 9093.000000 Tape File End ~ept = 10743.000000 Tape File Level Spacing = 0.250000 Tape File Depth units = feet Page 13 -999.2500 -999.2500 -999.2500 -999.2500 31.2680 25.6900 19.7410 13.7460 6.5110 4.8910 5.0040 7.7670 6.2840 9.4950 7.6700 7.4930 8.3270 9.2760 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 71.6330 61.9560 34.3790 18.0460 7.4760 5.3190 5.4760 9.5770 6.1720 11.9190 8.9260 7.2120 9.2600 10.9620 -999.2500 Tape subfile 6 is type: ~zs tapescan.txt Page 14