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205-064
• szc°t 11 WELL LOG TRANSMITTAL#902983182 To: Alaska Oil and Gas Conservation Comm. November 21, 2017 Attn.: Makana Bender RECEIVED 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 D%A%%/20Gv DEC 2 Z 2011 M K.BENDER RE: Leak Detect Log: U-06B AO GCC Run Date: 12/12/2015 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Chris Gullett, Halliburton Wireline &Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 **No confirmation for reciept of original, this is a resubmission** U-06B Digital Log Image files 1 CD Rom 50-029-21117-02 Leak Detection Log 1 Color Log 50-029-21117-02 50011 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Chris Gullett 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-273-3527 FRS_ANC@halliburton.com Date: Signed: 6eAzat STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMI REPORT OF SUNDRY WELL OPERATIO S 1. Operations Performed Abandon 0 Plug Perforations 0 Fracture Stimulate 0 Pull Tubing 0 Operations shutdown 0 Suspend 0 Perforate 0 Other Stimulate 0 Alter Casing 0 Change Approved Program 0 Plug for Redrill 0 Perforate New Pool 0 Repair Well 11 Re-enter Susp Well 0 Other:Packer Squeeze IVI 2. Operator Name: BP Exploration(Alaska),Inc 4. Well Class Before Work 5. Permit to Drill Number 205-064 3. Address: P.O.Box 196612 Anchorage, Development El Exploratory 0 AK 99519-6612 Stratigraphic 0 Service ❑ 6. API Number: 50-029-21117-02-00 7. Property Designation(Lease Number): ADL 0028263 8. Well Name and Number: PBU U-06B 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: RECEIVED Total Depth: measured 15229 feet Plugs measured feet I I U I � �oq true vertical 9020 feet Junk measured 11800 feet I Effective Depth: measured 11825 feet Packer measured 11306 feet true vertical 9005 feet Packer true vertical 8719 feet Casing: Length: Size: MD: TVD: Burst: Collapse: Structural Conductor 80 20"x 30" 31 -111 31-111 Surface 2646 13-3/8"72#L-80 30-2676 30-2676 4930 2670 Intermediate 2929 9-5/8"47#L-80 29-2958 29-2958 6870 4760 Production Liner See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Perforation Depth: Measured depth: See Attachment feet FF rt,iyt True vertical depth: See Attachment feet S`ANNED 3t�l��, j `ft`"' Tubing(size,grade,measured and true vertical depth) See Attachment t� See Attachment See Attachment Packers and SSSV(type,measured and See Attachment See Attachment See Attachment true vertical depth) 12.Stimulation or cement squeeze summary: Intervals treated(measured): 11050'-11240'in IA. Treatment descriptions including volumes used and final pressure: 145 Bbls 50/50 Methanol/Water,10.7 Bbls 15.8#Class G Cement,336 Bbls Diesel,312 psi. 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 135 133 2094 1349 322 Subsequent to operation: Shut-In 14.Attachments:(required per 20 AAC 25.070.25.071,&25.2831 15.Well Class after work: Daily Report of Well Operations WI Exploratory 0 Development m Service 0 Stratigraphic 0 Copies of Logs and Surveys Run 0 16.Well Status after work: Oil 0 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 W __ Phone +1 907 564 4424 Date 7/25/16 Form 10-404 Revised 5/2015 VT-1--, rr J 7"/1 ' RBDMS 1,1" AUG - 1 2016 Submit Original Only Air it9A1,4 • • C, a co co O o 0 0 Lc, o o I> O � O v O O O I- N U 0 0 0 0 0 i CO I� CO M 3O CO N V Ca 'Cr CO 1"--- CO 00 � CO CO CO r O I� O O Co N- O O O CO O N N- N N 00 CO CO 01 i 1 1 i 1 1 H CO O N— O O CO O M M N N N N CO O Ln CO O O O O 6) r N I I I V p co < 0 O O 0 O O CO M I"- ti 01 M N I� N N C _ CO O O coO co O co J O J J C1 OM N 4# (.0 .N N X � � N• N (Q N • N ao 00 N _ 6) U M - N N M c- r 2 O r L O 0)O N V �t co C 00 O O) I— O J N N co M LU C 0 Q '(17 U W W 0 0 LL Z Z z (XW W W m m ODI— ZZDD UU) zJJI— F- • s w L6 m• CD C) N U) O O CO O I� M M M r- O ti O N CO O O I 0 O 00 �- V 4 4 N M o 00 N N N N 0N M I— N- CA O — N v— O CO O 00 O O O O O O O O00 0 0 0 0 0 0 0 0 CA M O O O Cb 00 CO CA O O C)) CO 00 I- a O ▪ M LC) C) N .- OO LC) LC) M Lf) U) LC) N CO I- _ . 00 CO M V LC) M O M ) O M N CO CO 0 4 00 O 6 r LC) O O V O N U7 0 O M O O (NI O (NI O CO C) CO C) 0 0 0 0 C) > 0 CO C)) CA C) C) ) Oo 00 00 00 CA ) CA C) 00 0 w O O• o WW z W w 0 W o - i- J o_ w 55Y " 0 00 < Y Y g = CO 0 0 0 0 0 0 LC) LC) O LC) LC) U) O O O - - J < < W W W CO O LO O CO O N 00 OO M M M N N N I� J J J Q cn tl a LC) O O c- N CO CO 00 O N MCO N- O < < < W L1 0 00 • N N C1 N N N N N Cn M CO Cr) C) vcr 0 0 0 J J J J m Q Q Q O O a 0 0 0 w00 imiO O W W W O Z 0 O Z m 2 2 2 O c ci m (Jn va) CCD QC a o _ = CO 0 0 0 0 0 0 LO CO O O O Ln O LU LC) p. 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(0 In Cf) N- CO CO CO CO M C7 (0 N CD iidlL= 4-1116"CM/ • U —0 6 NO WELLHEAD; MCEVOY S TES: WELL ANGLE>70°@ 11789'"` ACTUATOR BAKER 3-1/2"CHROME TBG***MAX DOGLEG:17.6°@ 11851' L1 OKB.ELEV 8430' REF ELEV= 7& I 1 27' --(41/2"X 3-112"XO,D=2.992"i 63' BF.ELEV= 48.80' CONDUCTOR, ? 2192' }—3-1/2"FES X NI',D=2.813" KOP= 7700' #, , Max Angle= 970 @ 13609' p= " & 2192' —3-1/2"DREAMCATCHER(06/26/16) Datum MD= 8967 L Datum TVD= 8800 SS 2786' I-9-5/8"X 7"ZXP IP& FLEX LOCK HGR,ID=6.31" 13-3/8"CSG,72#,L-80 BUD TT, =12.347" 2685' 1/41 4i �' MLLOUT.INDOW(11-06B) 2958'-2974' _-_ 9-518"WHPSTOCK(04/30/05) — —2944j-- [9-5/8"CSG,47#,L-80 BUTT,13 8.681" 1—{ —2958 . .`\ ST MD TVD DEV TYPE VLV LATCH FORT DATE • 6 3000 3000 3 MIG DMY RK 0 02/05/09 11^ 5 3848 3810 26 NM DOME RK 16 06/26/16 Minimum ID =2.74" @ 11352' 1 4 7111 6012 50 MMG SO RK 20 06/26/16 MILLED 3-1/2" XN NIPPLE 3 9122 7301 51 MMG DMY RK 0 07/28/15 2 10376 8108 48 MMG DMY RK 0 07/28/15 CMT IN IA(06/24/16) — 11050'-11240' *1 11223 8665 49 MMG DMY RK 0 02/20/13 )��� '.2 *STA#1 =CEMENTED [TBG DAMAGE(06/24/16)j—{ 11240' ��t' '•t$ 11283' .—3-1/2"HES X NP,D=2.813" 11304' —3-1/2'X 4-1/2"XO,D=2.94" 11306' —7"X 4-1/2"BKR S-3 PKR,D=3.875' 5 ►. 11310' --I4-1/2"X 3-1/2"XO,D=2.96" 11331' —3-1/2'HESX NP,D=2.813" 11352' —3-1/2'HES XN NP,MLLED ID=2.74"(08/11/15) 11361' j__7"X 5"BKR ZXP LW w ITIB3ACK SLV,D=4.42`J 3-1/2"TBG,9.2#,13CR-80 VAM ACE, --I 11366' M K 11366' }—3-1/2"‘A/LEG&3-1/2"X 4-1/2"XO,D=2.992" .0087 bpf,ID=2.992" i i \ 11378' —7"X 5"BKR HMC HGR,D= 4.43' 11385' —5"X 4-112'XO,D=3.96" 7"LNR,26#,L-80 BTC,.0383 bpf,ID=6.276" }— 11535;1 L 11800'CTM J FISH:MILLED CBP(06/24/16) 4-1/2"BKR FLOW-THRU WHPSTOCK(09/26/15) — 11825' MLLOUT WINDOW(U-06B L1) 11829'-11835' PERFORATION SUMMARY I l I i. �`.`` 11867'ELM —JET CUT LNR(02/10/16) • �. -. REF LOG:MEM RESISTIVITY LOG ON 08/01/997? ■ .. ■ ANGLE AT TOP F F:NIA ■ . Note:Refer to Production DB for historical pert data : . . SIZE SPF MERVAL Opn/Sqz SFIOT SQZ • . SEE PAGE 2 FOR PERFORATION DETAILS • - 1 1 -06. . ►...•.•. .I,U-068 L1 2-3/8"LNR 4.7#,13CR-80 1H511, — 12939' / 4-1/2"LNR, 12.6#,L-80 LBT-M,.0152 bpf,ID=3.958' I--- 14405'-1 ,0039 bpf,ID=1.995' DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 06/28/84 AUDI 2 ORIGINAL COMPLETION 05/23/16,J14../..IND UPDATE)TOP OF MLLOUT WINDOW WELL. U-06B L1 08/04/99 N9ES CTD SIDETRACK(U-06A) 05/23/16 JNL/JMD UPDATED TOP OF SLID LNR PERMT No:'2050640,'2151230 05/11/05 MES ATTEMPTED SDTRCK(U-068) 07/06/16 JCF/JMD SQZ CMT 8 MILL CBP(06/24/16) AR No: 50-029-21117-02(60) 06/08/05 N2ES SIDETRACK(U-06B) 07/06/16 JR/JMD SET OREAMCATCFE2(06/26/16) SEC 18,T11N,R13E, 103'FSL&1663'FEL 10/03/15 NORDICI CTD ML ST(U-06B L1)TEMP SHIT 07/06/16 JR/JM) GLV C/O(06/26!16) 04/27/16 NORDIC2 RWO(CUTBPULL 2-3/8"LNR) BP Exploration(Alaska) • U -06B • L1 I 111 PERFORATION SUMMARY REF LOG:MEM RESISTIVITY LOG ON 08/01/99?? 4 4,0, ANGLE AT TOP PERF:52"@ 11538' Note:Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz SHOT SQZ U-066 2" 6 11538-11568 0 11/07/11 2-1/2" 6 11750- 12000 0 06/06/05 2-1/2" 6 12020-12050 0 06/06/05 2-1/2" 6 12080-12100 0 06/06/05 2-1/2" 6 12130-12160 0 06/06/05 2-1/2" 6 12180- 12200 0 06/06/05 2-1/2" 6 12300-12620 0 06/06/05 2-1/2" 6 12635- 12685 0 06/06/05 2-7/8" 6 12715-12885 0 06/06/05 ►� 2-7/8" 6 12900-13030 0 06/06/05 2-7/8" 6 13040- 13235 0 06/06/05 2-7/8" 6 13290- 13335 0 06/06/05 2-7/8" 6 13345- 13625 0 06/06/05 4 , 2-7/8" 6 13660- 13720 0 06/06/05 2-7/8" 6 13735- 13920 0 06/06/05 2-7/8" 6 13975- 14170 0 06/06/05 U-06B L1_ 46,TSLID 11879-12566 SLOT 09/30/15 SLID 12875-12938 SLOT 09/30/15 ■ ■ • ■ •■ ■ -176.■ �u-068 r.1 DATE REV BY COMMENTS DATE REV BY COMuBYTS PRUDHOE BAY UNIT 06/28/84 AUDI 2 ORIGINAL COMPLETION 05/23/16 JNUJMD UPDATE?TOP OF MLLOUT WMDOW WELL: U-06B L1 08/04/99 N9ES CTD SIDETRACK(U-06A) 05/23/16 JNUJMD UPDATED TOP OF SLID LIC — PERMR No 2050640,'2151230 05/11/05 N7ES ATTBNPT®SDTRCK(U-066) 07/06/16 JCF/JM)SQZ CMT&MLL CBP(06/24/16) AR No: 50-029-21117-02(60) 06/08/05 N2ES SIDETRACK(11-06B) 07/06/16 JR/JMD SET DREAMCATC1-ER(06/26/16) SEC 18,T11N,R13E 103'FSL&1663'FEL 10103/15 NORDICI CTD ML ST(U-06B L1)TEMP SINS 07/06/16 JR/JMD GLV C/O(06/26/16) 04127/16 NORDIC2 RWO(CUT&PULL 2-3/8"LNR) BP Exploration(Alaska) XHVZE . . Image Project Well History File Cover Page 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. ¿05 - 0 f04- Well History File Identifier Organizing (done) D Two-sided ""1111111 ""111I D Rescan Needed III 111111111111111I RJ8CAN ~ ,Color Items: i Greyscale Items: D Poor Quality Originals: DIGITAL DATA ~iskettes, No. 4- D Other, NolType: OVERSIZED (Scannable) D Maps: D Other Items Scannable by a Large Scanner D Other: OVERSIZED (Non-Scannable) D Logs of various kinds: NOTES: oate7/iÓ/07 D Other:: BY: ~ /5/ tl1P 1111111111111111111 Project Proofing BY: ~ /5/ wtf Scanning Preparation BY: Date: Production Scanning 11111111111111 11111 Stage 1 Page Count from Scanned File: I () 0 (Count does include cover sheet) Page Count Matches Number in Scanning Preparation: \ÁES ~ Date:?/ /0/07 If NO in stage 1, page(s) discrepancies were found: YES NO /5/ VV1 P BY: Stage 1 NO BY: Maria Date: /51 111111111111111111I Scanning is complete at this point unless rescanning is required. ReScanned 1111111111111111111 BY: Maria Date: 151 Comments about this file: Quality Checked 11111111/1111111111 10/6/2005 Well History File Cover Page.doc • P /05 64D Regg, James B (DOA) From: AK, D &C Well Integrity Coordinator [ AKDCWeIIIntegrityCoordinator @bp.com] Sent: Tuesday, March 27, 2012 5:47 PM C�' 5/z z _ To: Regg, James B (DOA); Schwartz, Guy L (DOA); AK, OPS GC2 OSM; AK, OPS GC2 Field O &M TL; AK, OPS GC2 Wellpad Lead; AK, OPS Well Pad SW; AK, OPS Prod Controllers; Cismoski, Doug A; Daniel, Ryan; AK, D &C Wireline Operations Team Lead; AK, D &C Well Services Operations Team Lead; AK, RES GPB West Wells Opt Engr; AK, RES GPB East Wells Opt Engr; Brown, Don L. Cc: Walker, Greg (D &C); Olson, Andrew Subject: OPERABLE: U -06B (PTD #2050640) Wellbore integrity confirmed All, Producer U -06B (PTD #2050640) passed a TIFL on 03/26/2012 after the well was placed on production confirming tubing integrity. Also, an OA repressurizatiori test was performed from 3/19 -3/23 and the OA build up rate was —5 psi /day making the IAxOA communication manageable by bleeds. The well is reclassified as Operable and can remain on production. Thank you, Mehreen Vazir ( :1ltcrihne: Gerald A'luiy It }1 Well Integrity Coordinator BP Alaska Drilling & Wells DMA Well Integrity Office: 907.659.5102 Email: AKDCWelllntegrityCoordinator @BP.com From: AK, D &C Well Integrity Coordinator Sent: Wednesday, March 21, 2012 5:57 PM To: 'Regg, James B (DOA)'; 'Schwartz, Guy L (DOA)' Cc: Wills, Shane M; King, Whitney; Arend, Jon (NORTHERN SOLUTIONS C); Yusubov, Tural Subject: UNDER EVALUATION: U -06B (PTD #2050640) Sustained IA . nd OA Casing Pressure Over MOASP Jim, Guy, Producer U -06B (PTD #2050640) is currently Under Evalu on for previously reported sustained casing pressure on the OA above MOASP per the note below. While performin• • iagnostics, the well has been found to have sustained casing pressure on the IA above MOASP. On 03/18/2012 the bing /IA/OA were equal to 2130/2130/700 psi. The well will remain Under Evaluation while diagnostics continue order to restore integrity to the well. A follow up notification will be provided to the AOGCC with results. Updated Plan Forward: 1. Wellhead: Shut in well and perform PPP*T -IC - FAILED 2. Wellhead: Cycle Lock Down Screws • energize primary seal on Inner Casing Pack Off - DONE 3. Downhole Diagnostics: Cold TIFL AILED 4. Downhole Diagnostics: OA Rep -ssurization Test - IN PROGRESS 5. Operations: Put well on prod ion 6. Downhole Diagnostics: W- TIFL 7. Slickline: Change out G 's (if warm TIFL fails) 1 • • but CC _0(og Regg, James B (DOA) 76c-064-0 From: AK, D &C Well Integrity Coordinator [ AKDCWeIIlntegrityCoordinator @bp.com]� Sent: Wednesday, March 21, 2012 5:57 PM Z' lz -- To: Regg, James B (DOA); Schwartz, Guy L (DOA) Cc: Wills, Shane M; King, Whitney; Arend, Jon (NORTHERN SOLUTIONS LLC); Yusubov, Tural Subject: UNDER EVALUATION: U -06B (PTD #2050640) Sustained IA and OA Casing Pressure Over MOASP Jim, Guy, Producer U -06B (PTD #2050640) is currently Under Evaluation for previously reported sustained casing pressure on the OA above MOASP per the note below. While performing diagnostics, the well has been found to have sustained casing pressure on the IA above MOASP. On 03/18/2012 the tubing /IA/OA were equal to 2130/2130/700 psi. The well will remain • ender Evaluation while diagnostics continue in order to restore integrity to the well. A follow up notification will be provided to the AOGCC with results. Updated Plan Forward: 1. Wellhead: Shut in well and perform PPPOT -IC - FAILED 2. Wellhead: Cycle Lock Down Screws to energize primary seal on Inner Casing Pack Off - DONE 3. Downhole Diagnostics: Cold TIFL - FAILED 4. Downhole Diagnostics: OA Repressurization Test - IN PROGRESS 5. Operations: Put well on production 6. Downhole Diagnostics: Warm TIFL 7. Slickline: Change out GLVs (if warm TIFL fails) 8. Wellhead: Re- engergize seconday seals on Inner Casing Pack Off (if OA Repressurization Test exhibits unmanageable OA build up rate) Please let me know if you have any questions. LP f inCi Thank you, ' ; !' MAR %� /AN, = z- (3� A l tf' _ 6g 70 p5, Mehreen Vazir r = 3 ) /. ilernaie Gerald Murphy) Well Integrity Coordinator °A = 7.7t2 BP Alaska Drilling & Wells tf, 64oPs,' Well Integrity Office: 907.659.5102 9 nt t Fl Email: AKDCWeIIlntegrityCoordinator @BP.com From: Reynolds, Charles (Alaska) _ _ ._ -._,_ N Sent: Saturday, March 03, 2012 2 :29 PM To: AK, D &C Well Integrity Coordinator; 'Regg, James B (DOA)'; 'S artz, Guy L (DOA)'; AK, OPS GC2 OSM; AK, OPS GC2 Field 0 &M TL; AK, OPS GC2 Wellpad Lead; AK, OPS Well • .• SW; AK, OPS Prod Controllers; Cismoski, Doug A; Daniel, Ryan; AK, D &C Wireline Operations Team Lead; A • &C Well Services Operations Team Lead; AK, RES GPB West Wells Opt Engr; AK, RES GPB East Wells Opt Engr; Bro , Don L. Cc: Walker, Greg (D &C); Clingingsmith, Mike 3; 01 • , Andrew; Vo, Nick (Hoang) Subject: UNDER EVALUATION: U -06B (PTD # 150640) Sustained OA Casing Above MOASP All 7, 1 Regg, James B (DOA) P Z05064-0 From: Reynolds, Charles (Alaska) [Charles.Reynolds @bp.com] �� . j Sent: Saturday, March 03, 2012 2:29 PM �1 /� To: AK, D &C Well Integrity Coordinator; Regg, James B (DOA); Schwartz, Guy L (DOA); AK, OPS GC2 OSM; AK, OPS GC2 Field O &M TL; AK, OPS GC2 Wellpad Lead; AK, OPS Well Pad SW; AK, OPS Prod Controllers; Cismoski, Doug A; Daniel, Ryan; AK, D &C Wireline Operations Team Lead; AK, D &C Well Services Operations Team Lead; AK, RES GPB West Wells Opt Engr; AK, RES GPB East Wells Opt Engr; Brown, Don L. Cc: Walker, Greg (D &C); Clingingsmith, Mike J; Olson, Andrew; Vo, Nick (Hoang) Subject: UNDER EVALUATION: U -06B (PTD #2050640) Sustained OA Casing Above MOASP Attachments: Producer U -06B (PTD #2050640) TIO Plot.doc; U- 06B.pdf All, Producer U -06B (PTD #2050640) has reported sustained OA casing over MOASP. The wellhead pressures were tubing /IA/OA equal to 200/1820/1520 on 3/1/2012. The well has been reclassified as Under Evaluation. The well may remain online while work is conducted to attempt to restore integrity. Plan forward: 1. Wellhead: Shut -in well and perform cold Positive Pressure Packoff Test - Inner Casing (PPPOT -IC). - 2. D: Outer Annulus Re- pressurization Test A TIO plot and wellbore schematic have been included for reference. Thanks, (34- se Charles Reynolds $1L,VIINED MAR 0 7 25 ti Filling in for... Mehreen Vazir '`i-' e (tlt< <ri hit e: Gerald 1 -lin ythv; Well Integrity Coordinator BP Alaska Drilling & Wells Well Integrity Office: 907.659.5102 Email: AKDCWelllntegritvCoordinator @BP.com 1 PBU U -06B PTD #2050640 3/3/2012 TIO Pressures Plot Wet U-06 4,000 • 3,000 A 9 2,000 - — OA OOA • 000A On 1,000 • 12!03111 12/10/11 12/17/11 12124l11 12/31/11 01/07/12 01 /14/12 01/21/12 01128/12 02/04/12 02/11/12 02/18/72 02/25/12 03/03/12 ' I TREE = 4" CIW 0 • WELLHEAD = MCEVOY ® � SAFETY NOTES: ORIGINAL WELLBORE (U -06) IS NOT ■r ACTUATOR = BAKER SHOWN ON DIAGRAM * * *3- 1 /2 " CHROME TBG * ** _KB. ELEV = 84.30' BF. ELEV = 48.80' \ I 27' I_I4 -1/2" X 3 -1/2" XO, ID = 2.992" I -- K - OP = 7700' Max Angle = 96 @ 12208' (_ Datum MD = 8967 I ( 2192' I I 3 -1/2" HES X NIP, ID = 2.813" I Datum TV D = 8800' SS 27$6' I- 9 -5/8" X 7" ZXP LNR TOP PKR & 113 -3/8" CSG, 72 #, L -80, ID = 12.347" I-I 2680' I FLEX LOCK HNGR, ID = 6.31" ffJ 04 ow- 3 ?O Fs, GAS LIFT MANDRELS Minimum ID = 2.635" @ 11352' ST MD TVD DEV TYPE VLV LATCH PORT DATE 6 3000 3000 3 MMG DMY RK 0 02/05/09 3-1/2" HES XN NIPPLE 5 3848 3810 26 MMG DOME RK 16 02/05/09 4 7111 6012 50 MMG DOME RK 16 02/05/09 3 9122 7301 51 MMG DOME RK 16 11/04/08 (WHIPSTOCK (04/30/05) I 2944' 2 10376 8108 48 MMG DMY RK 0 06/11/05 1 11223 8665 49 MMG SO RK 22 11/04/08 19 -5/8" CSG, 47 #, L -80, ID = 8.681" H -2974 I ---- I HES EZSV (04/28105) H 2980 MILLOUT WINDOW (U -06B) 2958' - 2974' a 7 Mi:q(' = 6`b - PERFORATION SUMMARY .1 Kt.' REF LOG: MEM. RESISTIVITY LOG ON 08/01/99 ?? �i �� :v.v.: 11283' H 3 -1/2" HES X NIP, ID = 2.813" I ANGLE AT TOP PERF: 52° @ 11538' Note: Refer to Production DB for historical perf data �—I 11304' 1-13-1/2" X 4 -1/2" XO, ID = 2.94" I SIZE SPF INTERVAL Opn /Sqz DATE 11306' I- 7" X 4 -1/2" BKR S -3 2" 6 11538 - 11568 O 11/07/11 0 C PKR, ID = 3.875" 2 -112" 6 11750 - 12000 0 06/06/05 ' 2 -1/2" 6 12020 - 12050 0 06/06/05 11310' I— I4 -1/2" X 3 -1/2" XO, ID = 2.96" I 2 -1/2" 6 12080 - 12100 0 06/06/05 2 -1/2" 6 12130 - 12160 0 06/06/05 11331' H3 -112" HES X NIP, ID = 2.813" I 2 -1/2" 6 12180 - 12200 0 06/06/05 2 -1/2" 6 12300 - 12620 0 06/06/05 2 -1/2" 6 12635 - 12685 0 06/06/05 2 -7/8" 6 12715 - 12885 0 06/06/05 11352' 1-13-1/2" HES XN NIP, ID = 2.635" I 2 -7/8" 6 12900 - 13030 0 06 11361' I- 7" X 5" BKR ZXP LNR TOP PKR 2 -7 /8" 6 13040 - 13235 0 06/06/05 w /TIEBACK SLV, ID = 4.42" 2 -7/8" 6 13290 - 13335 0 06/06/05 ' 11366' I- 3 -1/2" WLEG & 3-1/2" X 2 -7/8" 6 13345 - 13625 0 06/06/05 2 -7/8" 6 13660 - 13720 0 06/06/05 4 -1/2" XO, ID = 2.992" 2 -7/8" 6 13735 - 13920 0 06/06/05 11378' I- 7" X 5" BKR HMC LNR 2 -7/8" 6 13975 - 14170 0 06/06/05 HNGR, ID = 4.43" 11385' H5" X 4-1/2" XO, ID = 3.96"1 3 -1/2" TBG, 9.2 #, 13CR -80 VAM ACE, .0087 bpf, ID = 2.992" H 11366' 17" LNR, 26 #, L -80 BTC, .0383 bpf, ID = 6.276" H 11535' II I 1 I I PBTD H 14316' I AO. 14-1/2" LNR, 12.6 #, L -80 IBT, .0152 bpf, ID = 3.958" I—I 14405' DATE REV BY COMMENTS - DATE REV BY COMMENTS PRUDHOE BAY UNIT 06/28/84 ROBERTS ORIGINAL COMPLETION 03/31/11 JCM/PJC PULL JUNK BASKET (03/29/11) WELL: U -06B 08/04/99 WHITLOW CTD SIDETRACK (U-06A) - 07/29/11 BSE/PJC RECOVER T-STRING (03/16/11) PERMIT No: 2050640 05/11/05 N7ES ATTEMPTED SDTRCK (U -06B) 01/12/11 JCMI PJC ADPERFS (11 /07/11) API No: 50- 029 - 21117 -02 06/08/05 N2ES SIDETRACK (U -06B) SEC 18, T11N, R13E, 103' NSL & 1663' WEL 11/17/10 RCT /PJC FISH - SL TOOL STRING (11/09/10) _ 12/08/10 GJF /PJC JUNK BASKET (11 /28/10) if BP Exploration (Alaska) TE OF ALASKA . . ALASKA OIL ANNS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Abandon ❑ Repair Well ❑ Plug Perforations ❑ Stimulate ❑ Other ❑ Performed: Alter Casing ❑ Pull Tubing ❑ Perforate New Pool ❑ Waiver❑ Time Extension ❑ Change Approved Program ❑ Operat. Shutdown ❑ Perforate El Re -enter Suspended Well ❑ 2. Operator BP Exploration (Alaska), Inc. 4. Well Class Before Work: 5. Permit to Drill Number: Name: Development 0 Exploratory ❑ 205 -0640 3. Address: P.O. Box 196612 Stratigraphic❑ Service ❑ 6. API Number: Anchorage, AK 99519 -6612 - 50- 029 - 21117 -02 -00 8. Property Designation (Lease Number) : N =YO 9. Well Name and Number: ADLO- 028263 0 C4.- 7 46 f t(1,30 PBU U -06B 10. Field /Pool(s): PRUDHOE BAY FIELD / PRUDHOE OIL POOL 11. Present Well Condition Summary: Total Depth measured 15229 feet Plugs (measured) None feet true vertical 9020.42 feet Junk (measured) None feet Effective Depth measured 14315 feet Packer (measured) 2786 11306 feet true vertical 8955.95 feet (true vertical) 2786 8719 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 80' 20" 30 - 110 30 - 110 Surface 2656' 13 -3/8" 72# L -80 29 - 2685 29 - 2685 4930 2670 Production 2930' 9 -5/8" 47# L -80 28 - 2958 28 - 2958 6870 4760 Liner 8749' 7" 26# L -80 2786 - 11535 2786 - 8866 7240 5410 Liner 3044' 4 -1/2" 12.6# L -80 11361 - 14405 8756 - 8961 8430 7500 Liner Perforation depth: Measured depth: SEE ATTACHED - _ True Vertical depth: _ _ jAQ,�yl�� } }xW` a i , a' � Tubing: (size, grade, measured and true vertical depth) 3 -1/2" 9.2# 13Cr80 27 - 11366 27 - 8759 Packers and SSSV (type, measured and true vertical depth) 7" Baker ZXP Too Packer 2786 2786 4 -1/2" Baker S -3 Perm Packer 11306 8719 RE,CENE 12. Stimulation or cement squeeze summary: :Z \I a3 C,1 Intervals treated (measured): OMIliS O gt Gas G 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: 195 141 1341 185 Subsequent to operation: 180 131 1321 183 14. Attachments: 15. Well Class after work: Copies of Logs and Surveys Run Exploratory❑ Development 0 , Service ❑ Stratigraphic ❑ Daily Report of Well Operations X 16. Well Status after work: Oil ` Ei Gas ❑ WDSPL ❑ GSTOR ❑ WINJ ❑ WAG❑ GINJ ❑ SUSP❑ SPLUG ❑ 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: NA Contact Joe Lastufka Printed Na oe Lastufka Title Petrotechnical Data Technologist Signatu Phone 564 -4091 Date 11/30/2011 Form 10-404 Revised 10/2010 OM Zon � � S DEC o i / :� bmit Original Only U -06B 205 -064 PERF ATTACHMENT Sw Name Operation Date Perf Operation Code Meas Depth Top Meas Depth Base Tvd Depth Top Tvd Depth Base U -06B 6/6/05 PER 11,750. 12,000. 8,979.83 9,022.93 U -06B 6/6/05 PER 13,735. 13,920. 9,012.66 8,992.12 U -06B 6/6/05 PER 13,660. 13,720. 9,020.22 9,014.12 U -06B 6/6/05 PER 13,345. _ 13,625. 9,014.35 9,024.13 U -06B 6/6/05 PER 13,290. _ 13,335. 9,009.05 9,013.35 U -06B 6/6/05 PER 13,040. 13,235. 8,991.95 9,004.32 U -06B 6/6/05 PER 12,900. 13,030. 8,980.33 8,991.38 U -06B 6/6/05 PER 12,715. 12,885. 8,975.05 8,978.74 U -06B 6/6/05 PER 12,635. 12,685. 8,981.15 8,976.94 U -06B 6/6/05 PER 12,300. 12,620. 9,015.38 8,982.5 U -06B 6/6/05 PER 12,180. 12,200. 9,027.51 9,025.8 U -06B 6/6/05 PER 12,130. 12,160. 9,029.42 9,028.7 U -06B 6/6/05 PER 12,080. 12,100. 9,028.39 9,029.1 U -06B 6/6/05 PER 12,020. 12,050. 9,024.65 9,026.82 U -06B 6/6/05 PER 13,975. 14,170. 8,985.67 8,963.99 • U -06B 11/7/11 APF 11,538. 11,568. 8,867.7 8,886.01 AB ABANDONED PER PERF APF ADD PERF RPF REPERF BPP BRIDGE PLUG PULLED SL SLOTTED LINER BPS BRIDGE PLUG SET SPR SAND PLUG REMOVED FCO FILL CLEAN OUT SPS SAND PLUG SET FIL FILL SQF SQUEEZE FAILED MIR MECHANICAL ISOLATED REMOVED SQZ SQUEEZE MIS MECHANICAL ISOLATED STC STRADDLE PACK, CLOSED MLK MECHANICAL LEAK STO STRADDLE PACK, OPEN OH OPEN HOLE • • U -06B DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY 11/7/2011; ** *WELL FLOWING ON ARRIVAL * * *(ELINE PERF) INITIAL T /I /O= 300/1800/250 PSI INITIAL VALVE POSITIONS: MASTER/WING /SSV/VALVES TO CASING /GAS LIFT /CHEM INJ= OPEN, SWAB= CLOSED PERFORATED FROM 11538'- 11568' WITH 30'X 2" HSD 2006 PJ HMX, 6 SPF, 60 'DEG PHASE. CCL TO TOP SHOT= 4.25' CCL STOP DEPTH= 11533.75' FINAL T /I /O= 500/1500/0 PSI FINAL VALVE POSITIONS: MASTER/W ING /SSV/VALVES TO CASING /GAS LIFT /CHEM INJ= OPEN, SWAB= CLOSED ** *JOB COMPLETE * ** FLUIDS PUMPED BBLS 1 DIESEL 1 METH 2 TOTAL TREE= 4" CIW WELLHEAD = MCEVOY SAFETY NOTES: ORIGI ELLBORE (U -06) IS NOT ACTt1AT'OF7 = BAKER u - 6 B SHOWN ON DIAGRAM "*'1-1/2" CHROMETBG""" KB. -- EV = . , _ 8-440' BF. ELEVw- - ' _ 48.80' - k - 61 5 = . . - ___ _ _ . 7 700' I 27' H4- X 3 -1 /2" XO, ID = 2.992" J Max Angie = 96 @ 12208' Datum MD = 8967 I 2 192 ' H HES X NIP, ID 2.8 13" I Datum ND = 8800' SS 9 5/8" X 7" ZXP LNR TOP PKR & 113 -3/8" CSG, 72 #, L -80, ID = 12.347" H 2680' ( , 2786' FLEX LOCK HNGR, ID = 6.31" GAS LIFT MANDRELS Minimum ID = 2.635" @ 11352' ST MD TVD DEV TYPE VLV LATCH PORT DATE 6 3000 3000 3 MMG DMY RK 0 02/05/09 3 -1/2" HES XN NIPPLE 5 3848 3810 26 MMG DOME RK 16 02/05/09 4 7111 6012 50 MMG DOME RK 16 02/05/09 3 9122 7301 51 MMG DOME RK 16 11/04/08 2 10376 8108 48 MMG DMY RK 0 06/11/05 !WHIPSTOCK (04/30/05) H 2944' 1 11223 8665 49 MMG SO RK 22 11/04/08 1 9 -5/8" CSG, 47 #, L -80, ID = 8.681" I I — 2974 I-- 4 0 / HES EZSV (04/28/05) H 2980' MILLOUT WINDOW (U -06B) 2958' - 2974' PERFORATION SUMMARY a1v$ It REF LOG: MEM. RESISTIVITY LOG ON 08/01/99 ?? m .1 K .v.v: L 11283' 212" HES X NIP, ID = 2.813" 1 ANGLE AT TOP PERF: 52° @ 11538' Note: Refer to Production DB for historical perf data 11304' I-- (3 - 1/2" X 4 -1/2" XO, ID = 2.94" 1 / SIZE SPF INTERVAL Opn /Sqz DATE 11306' , � 7" X 4 -1/2" BKR S -3 2" 6 11538 - 11568 0 11/07/11 ✓ CO kt, PKR, ID = 3.875" 2 -1/2" 6 11750 - 12000 0 06/06/05 2 -1/2" 6 12020 - 12050 0 06/06/05 11310' H4 -1/2" X 3 -1/2" X0,10 = 2,96" I 2 -1/2" 6 12080 - 12100 0 06/06/05 2 -1/2" 6 12130 - 12160 0 06/06/05 2 -1/2" 6 12180 12200 0 06/06/05 1 11331' H3 -1/2" HES X NIP, ID = 2.813" I 2-1/2" 6 12300 - 12620 0 06/06/05 2 -1/2" 6 12635 - 12685 0 06/06/05 2 -7/8" 6 12715 - 12885 0 06/06/05 1 11352' H3-1/2" HES XN NIP, ID = 2.635" 1 2 -7/8" 6 12900 - 13030 0 06 11361' 117" X 5" BKR ZXP LNR TOP PKR 2 -7/8" 6 13040 - 13235 0 06/06/05 w /TIEBACK SLV, ID = 4.42" 2 -7/8" 6 13290 - 13335 0 06/06/05 2 -7/8" 6 13345 - 13625 0 06/06/05 11366' H 3 -1/2" WLEG & 3 -1/2" X 2 -7/8" 6 13660 - 13720 0 06/06/05 4-1/2" XO, ID = 2.992" 2 -7/8" 6 13735 - 13920 0 06/06/05 11378' H 7" X 5" BKR HMC LNR 2 -7/8" 6 13975 - 14170 0 06/06/05 HNGR, ID = 4.43" 11385' I X 4-1/2" XO, ID = 3.96" l I3 -1/2" TBG, 9.2 #, 13CR -80 VAM ACE, .0087 bpf, ID = 2.992" 1 11366' • 1 [7" LNR, 26 #, L -80 BTC, .0383 bpf, ID = 6.276" H 11535' 1 1 1 1 PBTD 14316' 1 tty, 14-1/2" LNR, 12.6 #, L -80 IBT, .0152 bpf, ID = 3.958" 14405' DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 06/28/84 ROBERTS ORIGINAL COMPLETION 03/31/11 JCM/PJC PULL JUNK BASKET (03/29/11) WELL: U -06B 08/04/99 WHITLOW CTD SIDETRACK (U -06A) ' 07/29/11 BSE/PJC RECOVER T- STRING (03/16/11) PERMIT No: 2050640 05/11/05 N7ES ATTEMPTED SDTRCK (U -06B) 01/12/11 JCM/ PJC ADPERFS (11/07/11) API No: 50- 029 - 21117 -02 06/08/05 N2ES SIDETRACK (U -06B) SEC 18, T11N, R13E, 103' NSL & 1663' WEL 11/17/10 RCT /PJC FISH - SL TOOL STRING (11/09/10) 12/08/10 GJF /PJC JUNK BASKET (11/28/10) I BP Exploration (Alaska) 01 -AUG -2011 Schhaberger No. 5774 Alaska Data & Consulting Services Company: State of Alaska 2525 Gambell Street, Suite 400 Alaska Oil & Gas Cons Comm Anchorage, AK 99503 -2838 Attn: Christine Shartzer ATTN: Stephanie Pacillo 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Well Job # Log Description Date BL Color CD I R -28 BJGT -00051 SBHPS 23-Jul-11 _ 1 1 MPB -23 BJCR -00099 LEAK DETECTION LOG 22-Jul-11 1 1 06 -01 BBSK -00080 PPROF W/ DEFT & GHOST 23-Jul-11 1 1 py-- 01tY- - U -06B BJGT -00053 SBHPS 25-Jul-11 1 1 1 / 7 e I M-03A BJGT -00052 SBHPS 24-Jul-11 1 01 -20 BBSK -00054 LDWG EDIT OF RST 5- Mar -11 1 1 P2 -52 BJGT -00021 LDWG EDIT OF RST 6- Mar -11 1 1 • PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Alaska Data & Consulting Services Petrotechnical Data Center LR2 -1 2525 Gambell Street, Suite 400 900 E. Benson Blvd. Anchorage, AK 99503 -2838 s ,- c. 2 . RECEVEDh RECEIVEP AUG " 2011 OPERABLE: U -06B (PTD #2050640)6 Pressure Manageable Page 1 pr1 L Regg, James B (DOA) From: AK, D &C Well Integrity Coordinator [ AKDCWeIIlntegrityCoordinator ©bp.com] Sent: Tuesday, April 26, 2011 9:35 AM To: Regg, James B (DOA); Maunder, Thomas E (DOA); Schwartz, Guy L (DOA); AK, OPS GC2 OSM; AK, OPS GC2 Field O &M TL; AK, OPS GC2 Wellpad Lead; AK, OPS Well Pad SW; AK, OPS Prod Controllers; Cismoski, Doug A; AK, D &C Wireline Operations Team Lead; AK, D &C Well Services Operations Team Lead; AK, RES GPB West Wells Opt Engr; AK, RES GPB East Wells Opt Engr; Brown, Don L.; Daniel, Ryan Cc: Walker, Greg (D &C); Clingingsmith, Mike J (Swift); Roschinger, Torin T. Subject: OPERABLE: U -06B (PTD #2050640) OA Pressure Manageable All, Producer U -06B (PTD #2050640) was recently being evaluated for IAxOA communication after the well was reported to have sustained OA casing pressure. During the diagnostics, an OA repressurization test was conducted and the build up rate was —10 psi /day making it manageable to operate. The well has been reclassified as Operable and may continue production. Please contact Well Integrity if the OA pressure becomes unmanageable. Thank you, Mehreen Vazir (Alternate: Gerald Murphy) Well Integrity Coordinator BP Alaska Drilling & Wells as A PR 2, 6 2 Well Integrity Office: 907.659.5102 Email: AKDCWeIIlntegrityCoordinator @BP.com From: AK, D &C Well Integrity Coordinator Sent: Thursday, April 14, 2011 8:29 PM To: 'Regg, James B (DOA)'; 'Maunder, Thomas E (DOA)'; 'Schwartz, Guy L (DOA)'; A, , OPS GC2 OSM; AK, OPS GC2 Field 0 &M TL; AK, OPS GC2 Wellpad Lead; AK, OPS Well Pad SW; AK, OPS Prod Controllers; Cismoski, Doug A; Engel, Harry R; AK, D &C Wireline Operations Team Lead; AK, D &C Well Services Operations Team Lead; AK, RES GPB West W- Opt Engr; AK, RES GPB East Wells Opt Engr; Brown, Don L. Cc: AK, D &C Well Integrity Coordinator; Walker, Greg (D &C); Clingi ■smith, Mike J (Swift) Subject: UNDER EVALUATION: U -06B (PTD #2050640) Sust. • ed OA Casing Above MOASP All, Producer U -06B (PTD #2050640) has c firmed sustained OA casing over MOASP. The wellhead pressures were tubing /IA/OA equal to 80/1860/1020 on 4/12/2011. The well has been reclassified as Under Evaluation. The well may re -in online while work is conducted to attempt to restore integrity. Plan forward: 1. DHD: Outer Annulus Repr- ssurization Test (OART) 2. Wellhead: Positive Pres/ure Packoff Test - Inner Casing (PPPOT -IC) A TIO plot and wellbore schematic have been included for reference. 4/26/2011 UNDER EVALUATION: U -06B (PT,050640) Sustained OA Casing AboveOASP Page 1 of 1 Regg, James B (DOA) From: AK, D &C Well Integrity Coordinator [ AKDCWellIntegrityCoordinator @bp.comj , q (1516)ii Sent: Thursday, April 14, 2011 8:29 PM To: Regg, James B (DOA); Maunder, Thomas E (DOA); Schwartz, Guy L (DOA); AK, OPS GC2 OSM; AK, OPS GC2 Field O &M TL; AK, OPS GC2 Wellpad Lead; AK, OPS Well Pad SW; AK, OPS Prod Controllers; Cismoski, Doug A; Engel, Harry R; AK, D &C Wireline Operations Team Lead; AK, D &C Well Services Operations Team Lead; AK, RES GPB West Wells Opt Engr; AK, RES GPB East Wells Opt Engr; Brown, Don L. Cc: AK, D &C Well Integrity Coordinator; Walker, Greg (D &C); Clingingsmith, Mike J (Swift) Subject: UNDER EVALUATION: U -06B (PTD #2050640) Sustained OA Casing Above MOASP Attachments: Producer U -06B (PTD #2050640) TIO PIot.doc; U -06B (PTD #2050640) wellbore schematic.pdf All, ;/' Producer U -06B (PTD #2050640) has confirmed sustained OA casing over MOASP. The wellhead pressures were tubing /IA/OA equal to 180/1860/1020 on 4/12/2011. The well has been reclassified as Under Ev_ aluation. The well may remain online while work is conducted to attempt to restore integrity. Plan forward: 1. DHD: Outer Annulus Repressurization Test (OART) 2. Wellhead: Positive Pressure Packoff Test - Inner Casing (PPPOT -IC) - A TIO plot and wellbore schematic have been included for reference. «Producer U -06B (PTD #2050640) TIO Plot.doc» «U -06B (PTD #2050640) wellbore schematic.pdf» Please call if you have any questions or concerns. Thank you, Gerald Murphy (alt. Torin Roschinger) Well Integrity Coordinator Office (907) 659 -5102 t `'' ) APR 5 2,0) Cell (907) 752 -0755 Pager (907) 659 -5100 Ext. 1154 4/15/2011 PBU U -06B PTD #2050640 4/14/2011 TIO Pressures Plot Well: U -06 4.000 - =.000 - — Tbg —F IA 2,000 - - -- OA 11-11-11-•-• • OOA 000A On 1,000 - 01 /15/11 01/22/11 01/29/11 02/05/11 02/12/11 02/19/11 02/28/11 03/05/11 03/12/11 03/19/11 03/26/11 04/02/11 114/09/11 • TREE= 4" CW WELLHEAD = MCEVOY SAFETY NOTES:OGINAL WELLBORE (U-06) IS NOT ACTUATOR= BAKER % 111 6 B , SHOWN ON DIAGRAM ***3-112" CHROMETBG*** KB. ELEV. 84.30' BF. ELEV = 48.80' KOP = 7700' 8'' i—] I 27' H4-112" X 3-1/2" XO, ID = 2.992" 1 2 2 7 1 8 9 6 2: F L-1 9 3 :5 1: 8 2: X H 7 E , S , z X x N p IP L , N I R D = 1 Datum MD = 8967 Max Angle . 96 @ 1220 ...., Datum TVD = 8800 SS 113-3/8" CSG, 72#, L-80, ID = 12.347" I-I 2680' 1 W-....------1 FLEX LOCK HNGR, ID = 6.31" GAS LIFT MANDRELS Minimum ID = 2.635" @ 11352' ST MD TVD DEV TYPE VLV LATCH PORT DATE 6 3000 3000 3 MMG DMY RK 0 02/05/09 ' 3-1/2" HES XN NIPPLE 5 3848 3810 26 MMG DOME RK 16 02/05/09 4 7111 6012 50 MMG DOME RK 16 02/05/09 3 9122 7301 51 MMG DOME RK 16 11/04/08 1WHIPSTOCK (04/30/05) 2944' 2 10376 8108 48 MMG DMY RK 0 06/11/05 1 1 11223 8665 49 MMG SO RK 22 11/04/08 1 9-5/8" CSG, 47#, L-80, ID = 8.681" H -2974 F----- , IHES EZSV (04/28/05) H 2980' MILLOUT WINDOW (U-06B) 2958' - 2974' ve, - way , TAvi 11283' H3-1/2" HES X NIP, ID= 2.813" j --- PERFORATION SUMMARY ..... „....---1 11304' 1-13-1/2" X 4-1/2" XO, ID = 2.94" I REF LOG: mai. RESISTIVITY LOG ON 08/0199? ANGLE AT TOP PERF: 66 @ 11750' ■..... II 11306' I__ 7" X 4-1/2" BKR S-3 Note: Refer to Production DB for historical perf data FKR, ID = 3.875" '44\„ - SIZE SPF INTERVAL Opn/Sqz DATE 11310' H 4-1/2" X 3-1/2" X0, ID = 2.96" I 2-1/2" 6 11750 - 12000 0 06/06/05 2-1/2" 6 12020 - 12050 0 06/06/05 11331' 1-13-112" HES X NIP, ID = 2.813" I 2-1/2" 6 12080 - 12100 0 06/06/05 s 2-1/2" 6 12130 - 12160 0 06/06/05 2-1/2" 6 12180 - 12200 0 06/06/05 2-1/2" 6 12300 - 12620 0 06/06/05 11352 1-13-1/2" HES XN NIP, ID = 2.635" I 2-1/2" 6 12635 - 12685 0 06/06/05 ,./.,,,, 11361' 1- 7" X 5" BKR ZXP LNR TOP FKR 2-7/8" 6 12715 - 12885 0 06/06/05 w /TIEBACK SLV, ID '» 4.42" 2-7/8" 6 12900 - 13030 0 06/06/05 2-7/8" 6 13040 - 13235 0 06/06/05 1 11366' I- 3-1/2" WLEG & 3-1/2" X ' 2-7/8" 6 13290 - 13335 0 06/06/05 4-1/2" XO, ID = 2.992" 2-7/8" 6 13345 - 13625 0 06/06/05 2-7/8" 6 13660 - 13720 0 06/06/05 11378' - 7" X 5" BKR HMC LNR 1 HNGR, ID = 4.43" 2-7/8" 6 13735 - 13920 0 06/06/05 2-7/8" 6 13975 - 14170 0 06/06/05 11385' 1-15" X 4-1/2" X0, ID = 3.96" I 13-1/2" TBG, 9.2#, 13CR-80 VAM ACE, .0087 bpf, ID = 2.992" H 11366' / 17" LNR, 26#, L-80 BTC, .0383 bpf, ID = 6.276" H 11535' 4 4 1 1 ??? F FISH - SL TOOL STRING • 33' w/ 3' 108 WIRE (11/09/10) I I 1PBTD 1-1 14316' I 0.0A 14-1/2" LNR, 12.6#, L-80 IBT, .0152 bpf, ID .- 3.958" I-1 14405' DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 06/28/84 ROBERTS ORIGINAL COMPLETION 12/04/05 DAV/TLH DRLG DRAFT CORRECTIONS WELL: U-06B 08/04/99 WHITLOW CTD SIDETRACK (U-06A) 11/10/08 KJB/SV GLV C/O (11/04/08) PERMIT No: F 2050640 05/11/05 N7ES ATTEMPTED SDTRCK (U-06B) 11/17/10 RCT/PJC FISH - SL TOOL STRING (11/09/10 API No: 50-029-21117-02 06/08/05 N2ES SIDETRACK (U-06E3) 12/08/10 GJF/PJC JUNK BASKET (11/28/10) SEC 18, T11N, R13E, 103' NSL & 1663' WEL 06/14/05 RMH/PJC GLV C/O ' 03/31/11 JCM/PJC PULL JUNK BASKET (03/29/11) 09/11/05 KSB/TLH GLV C/O BP Exploration (Alaska) 6i bp BP Exploration (Alaska) Inc. s: o Attn: Well Integrity Coordinator, PRB -20 ti 3 No Post Office Box 196612 Anchorage, Alaska 99519 -6612 N olti$) (} S$ 4 vans fo . M December 20, 2010 Mr. Tom Maunder a �S A .— Lfr laska Oil and Gas Conservation Commission 333 West 7 Avenue U - 13 Anchorage, Alaska 99501 Subject: Corrosion Inhibitor Treatments of GPB U Pad Dear Mr. Maunder, Enclosed please find multiple copies of a spreadsheet with a list of wells from U Pad 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, Jerry Murphy, at 659 -5102. Sincerely, Torin Roschinger 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) U -pad Date: 12/20/10 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 U -01 1920110 50029222440000 NA _ 0.8 NA 3.4 1/12/2010 U -02A 1982390 50029211700100 NA 0.6 NA 1.7 1/12/2010 U -03 0841470 50029211730000 NA 0.4 NA 1.7 1/12/2010 U -05A 2090700 50029211920100 NA 0.6 NA 3.4 1/12/2010 U-06B 2050640 50029211170200 NA 1.9 NA 15.3 1/13/2010 U -07 1840900 50029211270000 NA 0.6 NA 5.1 1/13/2010 U -08A 1982020 50029211360100 NA 1.4 NA 8.5 1/13/2010 U -09A 1982120 50029211440100 NA 0.2 NA 1.7 1/13/2010 U -10 1851970 50029214230000 NA 7.7 NA 57.8 12/28/2009 U -11B 1931080 50029214200200 NA 0.8 NA 5.1 1/13/2010 U -12A 2041470 50029214090100 NA 0.6 NA 3.4 1/12/2010 U -13 1781010 50029203550000 NA 0.1 NA 3.4 1/12/2010 U -14 1931000 50029223860000 NA 0.1 NA 1.7 1/13/2010 U -15B 2011970 50029225650200 NA 1.4 NA 13.6 1/13/2010 Producers with sustained casing pressuon IA and OA due to proration • Page 1 of 1 Regg, James B (DOA) Zo — 661 - From: AK, D &C Well Integrity Coordinator [ AKDCWellIntegrityCoordinator @bp.com] ft Sent: Tuesday, January 11, 2011 6:58 AM L 11 (1( To: Maunder, Thomas E (DOA); Regg, James B (DOA); Schwartz, Guy L (DOA) Cc: AK, D &C Well Integrity Coordinator; King, Whitney; Walker, Greg (D &C); Quy, Tiffany; Cismoski, Doug A; Engel, Harry R; AK, RES GPB West Wells Opt Engr; AK, RES GPB East Wells Opt Engr Subject: Producers with sustained casing pressure on IA and OA due to proration Jim/Tom /Guy, The following wells were found to have sustained casing pressure on the IA during the proration January 8 -9. The immediate action is to perform a TIFL on each of the wells and evaluate for IA repressurization. If any of the wells fail the TIFL, a follow up email will be sent to the AOGCC for each individual well. 14 -24 (PTD #1830910) W -26A (PTD #1990810) The following wells was found to have sustained casing pressure on the OA during the proration January 10. The immediate action is to perform an OART and evaluate if the IAxOA pressure is manageable by bleeds. If the IAxOA communication is unmanageable, a follow up email will be sent to the AOGCC notifying you of the remedial plan. -068 PTD #205064 U -12A (PTD #2041470) Please call with any questions or concerns. AdOINED JAN 2 0 2011 Thank you, Gerald Murphy (alt. Torin Roschinger) Well Integrity Coordinator Office (907) 659 -5102 Cell (907) 752 -0755 Pager (907) 659 -5100 Ext. 1154 1/11/2011 OPERABLE: Producer U -06B (PTD #50640) OA pressure manageable • Page 1 of 2 Regg, James B (DOA) From: AK, D &C Well Integrity Coordinator [ AKDCWelllntegrityCoordinator @bp.com] I Sent: Tuesday, November 23, 2010 2:43 PM I ?� I iI Z 10 To: AK, D &C Well Integrity Coordinator; Regg, James B (DOA); Maunder, Thomas E (DOA); AK, OPS GC2 OSM; AK, OPS GC2 Wellpad Lead; AK, OPS Well Pad HU; Engel, Harry R; AK, D &C Well Services Operations Team Lead, AK, D &C Wireline Operations Team Lead; Cismoski, Doug A; Schwartz, Guy L ( DOA) Cc: Brown, Don L.; King, Whitney Subject: OPERABLE: Producer U -06B (PTD #2050640) OA pressure manageable Attachments: U -06B TIO Plot 11- 23- 10.doc All, Producer U- 06B.(PTD #2050640) was recently being ev aluated for IAxOA communicatio after the well was reported to have sustained OA casing pressure. During the diagnostics, an O repressurization tes stabilized at 500 psi making it manageable to operate. The well has been reclassified as Operable and may continue production. Please notify Well Integrity if the OA pressure begins to increase. A TIO plot has been included for reference. <<U -06B TIO Plot 11- 23- 10.doc>> Thank you, Torin Roschinger (alt. Jerry Murphy) Well Integrity Coordinator Office (907) 659 -5102 Harmony Radio x2376 Cell (406) 570- 9630�� P oll Pager (907) 659 -5100 Ext. 1154 From: AK, D &C Well Integrity Coordinator Sent: Tuesday, November 16, 2010 10:57 PM To: 'Regg, James B (DOA)'; 'Maunder, Thomas E (DOA)'; AK, OPS GC2 OSM; AK, OPS GC2 Wellpad Lead; AK, OPS Well Pad HU; Engel, Harry R; AK, D &C Well Services Operations Team Lead; AK, D &C Wireline Operations Team Lead; Cismoski, Doug A; Schwartz, Guy L (DOA) Cc: Brown, Don L.; King, Whitney; AK, D &C Well Integrity Coordinator Subject: UNDER EVALUATION: Producer U -06B (PTD #2050640) Sustained OA Casing Pressure All, Producer U -06B (PTD #2050640) has sustained casing pressure on the OA. The TIOs were 100/920/1200 psi on 11/13/10 after the well had been shut -in. During an OA repressurization test on 11/15, the build -up -rate was measured — 570psi /day. The well has been reclassified as Under Evaluation and may be produced to keep the wellhead warm for diagnostics and repair for up to 28 -days. The plan forward for the well is as follows: 1. D: OA repressurization test - BUR —570 psi /day 2. W: PPPOT-IC 3. D: Re -DART pending PPPOT -IC results A wellbore schematic and TIO plot have been attached for reference. 11/23/2010 OPERABLE: Producer U -06B (PTD # 50640) OA pressure manageable Page 2 of 2 << File: U -06B WBS.pdf>> «File: U -06 TIO Plot 11- 16- 10.doc» Thank you, Torin Roschinger (alt. Jerry Murphy) Well Integrity Coordinator Office (907) 659 -5102 Harmony Radio x2376 Cell (406) 570 -9630 Pager (907) 659 -5100 Ext. 1154 11/23/2010 UNDER EVALUATION: Producer U�6B (PTD #2050640) Sustained Casing Above ... Page 1 of 1 Regg, James B (DOA) From: AK, D &C Well Integrity Coordinator [ AKDCWellintegrityCoordinator @bp.com] Sent: Tuesday, November 16, 2010 7:29 AM To: Maunder, Thomas E (DOA); Regg, James B (DOA); Schwartz, Guy L (DOA); AK, OPS GC2 OSM; AK, D &C Wireline Operations Team Lead; AK, OPS GC2 Field O &M TL; AK, OPS GC2 Wellpad Lead; AK, OPS Prod Controllers; Cismoski, Doug A; Engel, Harry R; AK, D &C Well Services Operations Team Lead; AK, RES GPB West Wells Opt Engr; AK, RES GPB East Wells Opt Engr Cc: King, Whitney; AK, D &C Well Integrity Coordinator Subject: UNDER EVALUATION: Producer U -06B (PTD #2050640) Sustained Casing Pressure Above MOASP Attachments: Producer U -06 (PTD #2050640) TIO Plot.doc; Producer U -06 (PTD #2050640) wellbore schematic.pdf All, Producer U -06B (PTD #2050640) has confirmed sust OA casing pressure above MOAS The wellhead pressures were tubing /IA/OA equal to 100/920/1200 on 11/13/2010. The well has been reclassified as Under Evaluation. The well may remain onl ni a while work is conducted to attempt to restore integrity. The plan forward: 1. DHD: Outer Annulus Represurization Test (DART) 2. Wellhead: Positive Pressure Packoff Test - Inner Casing (PPPOT -IC) A TIO plot and wellbore schematic have been included for reference. <<Producer U -06 (PTD #2050640) TIO Plot.doc>> <<Producer U -06 (PTD #2050640) wellbore schematic.pdf>> Please call if you have questions or concerns. Thank you, Gerald Murphy (alt. Torin Roschinger) AAAAW NG 1 8 2UID Well Integrity Coordinator Office (907) 659 -5102 Cell (907) 752 -0755 Pager (907) 659 -5100 Ext. 1154 11/16/2010 PBU U -06B PTD #2050640 11/16/2010 TIO Pressures Plot Well: U -06 4.000 i i i 3,000 i i - 0 Tbg —� IA 2,000 —A OA OOA - 0 OOOA On r 1,000 • 08128110 09111110 09125110 10109110 10!23!10 11106110 TREE = 4" CNV SAFET ES: ORIGINAL WELLBORE (U -06) IS NOT I WELLHEAD = MC EVOY ._...._... SHOWN QA DIAGRAM ._ U 0 6 B — 3-1/2" CHROME TBG A CTUATOR= BAKER � ��., - —° K B. ELEV = 84.3 BF. ELEV = 48.80' Of 7700' 27' 4 -1/2" X 2" XO, I D = 2.992" KOP= Max Angle = 96 @ 12208' Datum MD = 8967 2192 3 -1l2" HES X NIP, ID = 2.8 Datum TV D = 8800' SS 2786' 9 -5/8" X 7" ZXP LNR TOP PKR & 13 -3/8" CSG, 72 #, L -80, ID = 12.347" 26$0' FLEX LOCK HNGR, ID = 6.31" i GAS LIFT MANDRELS Minimum ®= 2.635" 11352 ST MD TVD DEV TYPE VLV LATCH PORT DATE 6 3000 3000 3 MMG DMY RK 0 02/05/09 3 -1/2" HES XN NIPPLE 5 3848 3810 26 MMG DOME RK 16 02/05/09 4 7111 6012 50 MMG DOME RK 16 02/05/09 3 9122 7301 51 MMG DOME RK 16 11/04/08 2 10376 8108 48 MMG DMY RK 0 06/11/05 WHIPSTOCK (04/30/05) 2944' 1 11223 8665 49 MMG SO RK 1 22 11/04/08 HES EZSV (04 29$0' �4 �I V 2958' - T WINDOW (U -06B} 2958' - 2974' I 11283 3-1/2" HES X NIP, ID = 2.813" TOP OF CEMENT 04(24/05} 7290' CTM 11304 3 -1/2" X 4 -1/2" XO, ID = 2.94" 11306 7" X 4 -1/2" BKR S -3 R PKR, ID = 3.875 TOP OF 2 -7i8" LNR $358 11310' 4 -1/2" X 3 -1/2" TOP OF 7" LNR 8381' 11331 13-1/2" HES X NIP, I = 2.813" 4 -1/2" TBG 12.6 #, L -80, ID = 3,958" 8413' E 9 -5 /8" CSG, 47 #, L -80, ID = 8.681" $$$9" 11352 3 -1/2" HES XN NIP, ID = 2.635" q- 11361 1 7" X 5" BKR ZXP LNR TOP PKR PERFORATION SUMMARY w/TIEBACK SLV, ID = 4.42" REF LOG: MEM. RESIST(/(FY LOG ON 08101199 ?? A 11366 3 -1/2" WLEG &3 -1/2" X ANGLE AT TOP 66 @ 11750 Note: Refer to Production DS for historical perf data 4 -112" XO, ID = 2.992" SIZE SPF INTERVAL Opn /Sqz DATE 1378' 7" X 5" BKR HMC LNR 2 -1 /2" 6 11750 - 12000 O 06/06/05 HNGR, ID = 4.43" 2 -1/2" 6 12020- 12050 O 06/06/05 2 -1/2" 6 12080 - 12100 O 06/06/05 3 -112" TBG, 9.2 # 11366' 11385 5" X 4 -112" XO, ID = 3.96" 2-1/2" 6 12130 - 12160 O 06/06/05 13CR80 VAM ACE, 2 -1/2" 6 12180 - 12200 O 06/06/05 .0087 bpf, ID = 2.992" 2 -1/2" 6 12300- 12620 O 06/06/05 2 -1/2" 6 12635 - 12685 O 06/06/05 7" LNR, 26 #, L -80 BTC 11535' 2 -7/8" 6 12715 - 12885 O 06/06/05 0383 bpf, ID = 6.276" 2 -7/8" 6 12900 - 13030 O 06/06/05 2 -718" 6 13040 - 13235 O 06/06/05 2 -7/8" 6 13290 - 13335 O 06/06/05 2 -718" 6 13345 - 13625 O 06/06/05 2 -7/8" 6 13660 - 13720 O 06/06/05 PBTD 14316' 2 -7/8" 6 13735 - 13920 O 06/06/05 2 -7/8" 6 13975 - 14170 O 06/06/05 4 -1/2" LNR, 12.6 #, L -80 14405' IBT, .0152 bpf, ID = 3.958" DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 06/28/84 ROBERTS ORIGINAL COMPLETION 12/04/05 DAV /TLH DRLG DRAFT CORRECTIONS WELL: U-06B 08/04/99 WHITLOW CTD SIDETRACK (U -06A) 11/10/08 KJB /SV GLV C/O (11/04/08) PERMIT No: 0 2050640 05/11/05 WES ATTEMPTED SDTRCK (U -06B) API No: 50- 029 - 21117 -02 06/08/05 N2ES SIDETRACK (U -06B) SEC 18, T11N, R1 3E, 103' NSL & 1663' WEL 06/14/05 RMH /PJC GLV C/O 09/11/05 KSB /TLH I GLV C/0 BP Exploration (Alaska) UNDER EVALUATION: Producer U B (PTD #2050640) Sustained OA Ca,* Pressure Page 1 of 1 Regg, James B (DOA) From: AK, D &C Well Integrity Coordinator [ AKDCWellintegrityCoordinator @bp.com] A Frt 11 Sent: Tuesday, November 16, 2010 10:57 PM To: Regg, James B (DOA); Maunder, Thomas E (DOA); AK, OPS GC2 OSM; AK, OPS GC2 Wellpad Lead; AK, OPS Well Pad HU; Engel, Harry R; AK, D &C Well Services Operations Team Lead; AK, D &C Wireline Operations Team Lead; Cismoski, Doug A; Schwartz, Guy L (DOA) Cc: Brown, Don L.; King, Whitney; AK, D &C Well Integrity Coordinator Subject: UNDER EVALUATION: Producer U -06B (PTD #2050640) Sustained OA Casing Pressure Attachments: U -06B WBS.pdf; U -06B TIO Plot 11- 16- 10.doc All, Producer U -06B (PTD #2050640) has sustained casing pressure on the OA. The TIOs were 100/920/1200 psi on 11/13/10 after the well had been shut -in. During an OA repress urization test on 11115 , the build -up -rate was measured - 5 70psi /da y. The well has been reclassified as n der Evaluation and may be produced to keep the wellhead warm for diagnostics and repair for up to 28 -days. The plan forward for the well is as follows: 1. D: OA repressurization test - BUR -570 psi /day 2. W: PPPOT -IC 3. D: Re -DART pending PPPOT -IC results NOV 1 8 201D A wellbore schematic and TIO plot have been attached for reference. <<U -06B WBS.pdf>> <<U -06B TIO Plot 11- 16- 10.doc>> Thank you, Torin Roschinger (alt. Jerry Murphy) Well Integrity Coordinator Office (907) 659 -5102 Harmony Radio x2376 Cell (406) 570 -9630 Pager (907) 659 -5100 Ext. 1154 11/17/2010 PBU U -06B PTD 2050640 11/16/2010 TIO Pressures Plot Well_ U -06 4.i ii fl • 3.000 —#— Tbg —F- IA 2,000 —A OA OOA --*- OOOA r an 1:nno • 08!23110 09/11110 00125110 10109110 10/23/10 11106/10 TREE = 4" CIW SAFETY ES: ORIGINAL WELLBORE (U -06) IS NOT WELLHEAD= MCEVOY SHOWN DIAGRAM ACTUATOR= BAKER U -p 6 B — 3 -1/2" CHROMETBG _T...:e KB. ELEV = 84.30' BF. ELEV = 48.80' 2T 4 -1/2" X 3 -112" KOP= 7700' Max Angle = 96 @ 12208' Datum MD = 8967 2192 3 -1/2" HES X NIP, ID = 2.8 Datum TV D = 8800' SS 2786-- 9 -518" X 7" ZXP LNR TOP PKR & 13 -3/8" CSG, 72 #, L -80, ID = 12.347" 2680' FLEX LOCK HNGR, ID = 6.31" GAS LIFT MANDRELS Minimum ID = 2.635" 11352 ST MD TVD DEV TYPE VLV LATCH PORT DATE 6 3000 3000 3 MMG DMY RK 0 02/05/09 3 -112" HES XN NIPPLE 5 3848 3810 26 MMG DOME RK 16 02105/09 4 7111 6012 50 MMG DOME RK 16 02/05/09 3 9122 7301 51 MMG DOME RK 16 11/04/08 2 10376 8108 48 MMG DMY RK 0 06/11/05 WHIPSTOCK (0 2944' 1 11223 8665 49 MMGI SO RK 1 22 11/04/08 err i t � i HES EZS (04/28/05) 2980' MILLOUT WINDOW (U -06B) 2958'-2974' 11283` 3 -1 /2" HES X NIP, ID = 2.813) i TOP OF CEMENT 04/2 7290 CTM 11304 3 -112" X 4 -1 /2" X0, ID = 2.94" 11306 7" X 4 -1/2" BKR S -3 TOP OF 2 - LNR 8358` – 11310 r4 -112" X 3 -1/2" XO, ID = 2.96" TOP OF 7" LNR 8381 ` 11331' 13-1/2" HES X NIP, ID = 2.813' 4 -1/2" TBG 12.6 #, L -80, ID = 3.958" 8413' I 9-518" CSG, 47 #, L -80, ID = 8.681" 8889 11352 3 -1/2" HES XN N I = 2.63 11361 7" X 5" BKR ZXP LNR TOP PKR 1 PERFORATION SUMMARY w !TIEBACK SLV, ID = 4.42" REF LOG: MEM, RESISTIVITY LOCH ON 08?01 /997? ANGLEATTOP PERF: 66 @ 11750 11366 3 -112" WLEG & 3 -1/2" X Note: Refer to Production DB for historical perf data 4 -1/2" XO, ID = 2.992" SIZE SPF INTERVAL Opn /Sqz DATE 1137$' 1 7" X 5" BKR HMC LNR 2-1/2" 6 11750 - 12000 0 06/06/05 HNGR, ID = 4.43" 2 -1/2" 6 12020 - 12050 0 06/06/05 2 -1/2" 6 12080 - 12100 0 06106/05 3 -112" TBG 9.z #. 11366' 113$5 2 -1/2" 6 12130- 12160 0 06/06/05 13C R80 VAM ACE 2-1/2" 6 12180- 12200 0 06/06/05 0087 bpf, ID = 2.992" 2 -1/2" 6 12300- 12620 0 06/06/05 __ 1 2 -1/2" 6 12635 - 12685 O 06/06/05 7" LNR, 26 #, L -80 BTC 11535' 6 12715 - 12885 0 06/06/05 ,0383 bpf, ID = 6.276" 2 -7(8" 6 12900 - 13030 O 06/06/05 2 -7/8" 6 13040 - 13235 0 06/06/05 2 -7/8" 6 13290 - 13335 0 06/06/05 2 -7/8" 6 13345 - 13625 O 06/06/05 pBTD 14316' 2 -7/8" 6 13660 - 13720 O 06/06/05 2 -7/8" 6 13735 - 13920 O 06/06/05 2 -7/8" 6 13975 - 14170 O 06/06/05 4-1/2" LNR, 12.6 #, L -80 14405' IBT, .0152 bpf, ID = 3.958" DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 06/28/84 ROBERTS ORIGINAL COMPLETION 12/04/05 DAV /TLH DRLG DRAFT CORRECTIONS WELL: U-06B 08/04/99 WHITLOW CTD SIDETRACK (U -06A) 11/10/08 KJB /SV GLV C/O (11/04/08) PERMIT No: 0 2050640 05/11/05 N7ES ATTEMPTED SDTRCK (U -06B) API No: 50- 029 - 21117 -02 06/08/05 N2ES SIDETRACK (U -06B) SEC 18, T11N, R1 3E, 103' NSL & 1663' WEL 06/14/05 RMHIPJC GLV C/O 09/11/05 KSB /T-H I GLV C/O BP Exploration (Alaska) OPERABLE: Producer U-06B (PTD # 050640) OA pressure manageable by b eds Page 1 Regg, James B (DOA) From: AK, D&C Well Integrity Coordinator [AKDCWeIIlntegrityCoordinator@bp.com] ~~gy ~1'~I1~ Sent: Sunday, July 25, 2010 6:19 AM (( 1 To: Schwartz, Guy L (DOA); Regg, James B (DOA); Maunder, Thomas E (DOA); AK, OPS GC2 OSM; AK, OPS GC2 Facility OTL; AK, OPS GC2 Wellpad Lead; AK, OPS Well Pad HU; Engel, Harry R; AK, D&C Well Services Operations Team Lead; AK, D&C Wireline Operations Team Lead; Cismoski, Doug A Cc: Brown, Don L.; Janowski, Carrie; AK, D&C Well Integrity Coordinator Subject: OPERABLE: Producer U-06B (PTD #2050640) OA pressure manageable by bleeds All, An OA repressurization test was conducted on Well U-06B (PTD #2050640) after the wellhead seals were reenergized. The build-up rate is ~45 psi/day making it manageable by bleeds. The well has been rec aT sslfled as Operable and may continue on production. Please contact Well Integrity if the OA pressure be comes unmanageable. Call with any questions or concerns. Thank you, Toxin Roschinger (alt. Jerry Murphy) Well Integrity Coordinator Office (907) 659-5102 Harmony Radio x2376 Cell (406) 570-9630 Pager (907) 659-5100 Ext. 1154 a f; , t; From: AK, D&C Well Integrity Coordinator Sent: Friday, July 16, 2010 4:28 PM To: AK, D&C Well Integrity Coordinator; 'Regg, James B (DOA)'; 'Maunder, Thomas E (DOA)'; AK, OPS OSM; AK, OPS GC2 Facility OTL; AK, OPS GCZ Wellpad Lead; AK, OPS Well Pad HU; Engel, Harry R; Engel, Harry R; AK, D&C Well rvices Operations Team Lead; AK, D&C Wireline Operations Team Lead; Cismoski, Doug A Cc: Brown, Don L.; King, Whitney Subject: UNDER EVALUATION: U-068 (PTD #2050640) Sustained OA Casing All, Well U-06B (PTD #2050640) has confirmed sustain OA casing pressure. The TIOs were 160/1800/1040 psi on 07/14/10. The well has be reclassified as Under Evaluation and may be produced for diagnostics and repair for up to 2 days. The plan forward for the well is as follow . 1. D: OA repressurization test 2. W: PPPOT-IC 3. D: Re-OART pending PPPO -IC results A wellbore schematic an~'10 plot have been attached for reference. File: U-066 WB~S'pdf» « File: U-06B TIO Plot 07-16-10.doc » 8/10/2010 UNDER EVALUATION: U-06B (PT~#2050640) Sustained OA Casing Press Page 1 of 1 Regg, James B (DOA) From: AK, D&C Well Integrity Coordinator [AKDCWeIIlntegrityCoordinator@bp.com] Sent: Friday, July 16, 2010 4:28 PM ~~~ ?f Z3~i° To: AK, D&C Well Integrity Coordinator; Regg, James B (DOA); Maunder, Thomas E (DOA); AK, OPS GC2 OSM; AK, OPS GC2 Facility OTL; AK, OPS GC2 Wellpad Lead; AK, OPS Well Pad HU; Engel, Harry R; Engel, Harry R; AK, D&C Well Services Operations Team Lead; AK, D&C Wireline Operations Team Lead; Cismoski, Doug A Cc: Brown, Don L.; King, Whitney Subject: UNDER EVALUATION: U-06B (PTD #2050640) Sustained OA Casing Pressure Attachments: U-06B WBS.pdf; U-06B TIO Plot 07-16-10.doc All, Well U-066 (PTD #2050640) has confirmed sustained OA casing pressure. The TIOs were 160/1800/1040 psi on 07/14/10. The well has been reclassified as Under Evaluation and may be produced for diagnostics and repair for up to 28-days. The plan forward for the well is as follows: 1. D: OA repressurization test r ~~ ~ ~ 6 ~~ ~,,:. a 3. D: Re-DART pending PPPOT-IC results A wellbore schematic and TIO plot have been attached for reference. «U-06B WBS.pdf» «U-066 TIO Plot 07-16-10.doc» Thank you, Torin Roschinger (alt. Jerry Murphy) Well Integrity Coordinator Office (907) 659-5102 Harmony Radio x2376 Cell (406) 570-9630 Pager (907) 659-5100 Ext. 1154 13 ~'~,'` ~.~ , ~ z oaf l~c~ "= 53~u~,` ,~P . l G4e~~s'' Ala ~lT~{ P- lQ, 3 ncrE;,c~. ~~ ~ ~ 4q y 7/20/2010 PBU U-06B PTD 2050640 7/16/2010 TIO Pressures Plot ~,aaa 3,oaa ',aaa 1:aaa Well: U-06 l --*- Tbg --~-- IA -~- OA OOA -* OOOA On ad117i 1 a a41~d110 a51a111 a x510811 a aF11511 a 0512110 a51t911 a a61a511 a x5112110 x611911 a aG12611 a 071x3110 0110110 TREE = 4" CM+ WELLHEAD = MCEVOY ACTUATOR BAKER KB. ELEV = ~ 84.30' BF. ELEV - 48.80' KOP = 7700' Max Angle = 96 @ 12208' Datum MD = 8967 Datum TVD = 8800' SS ~ 13-3l8" CSG, 72#, L-80, ID = 12.347" I-( 26$0' •u-osg ~~ SAFETY: ORIGINAL WELLBORE(U-06) IS NOT SHOWN AGRAM **"3-112°' GHROMETBG*** 2T 4-1/2" X 3-112" XO, ID = 2.992" 2192' 3-1/2" HES X NIP, ID = 2.813" 27$6' 9-5/8" X 7°' ZXP LNR TOP PKR & FLEX LOCK HNGR, ID - 6.31" GAS LIFT MANDRELS Minimum ID ®2.635" @ 11352' 3-112" HES XN NIPPLE WHIPSTOCK {04130/05) ~-~ 2944 HES ¢sv {o4r2s/05) 29$0' TOP OF CEMENT 04124(05) ~---~ 7290' CTM TOP OF 2-718" LN ~--~-._-8358' TOP OF 7" LNR1 83$1' 11283, (-) 3-1/2" HES X NIP, ID = 2.813" 11304' 3-1l2" X 4-1/2'" XO, ID = 2.94" 11306' 7" X 4-112" BKR S-3 PKR, ID - 3.875" 11310' - 4-1/2" X 3-112" XO, ID = 2.96" 11331' 3-1i2" HES X NIP, ID = 2.813" 4-1(2" TBG 12.6#, L-80, ID = 3.958" 9-5/8" CSG, 47#, L-80, ID = 8.681" ST MD ND DEV TYPE VLV LATCH PORT DATE 6 3000 3000 3 MMG DMY RK 0 02/05!09 5 3848 3810 26 MMG DOME RK 16 02/05/09 4 7111 6012 50 MMG DOME RK 16 02/05/09 3 9122 7301 51 MMG DOME RK 16 11!04108 2 10376 8108 48 MMG DMY RK 0 06/11!05 1 11223 8665 49 MMG SO RK 22 11/04108 ~~ ~',~,, MILLOUT WINDOW (U=06B} ~~ ~ 2958' - 2974' 3-1t2" TBG, 9.2#, 11366' 13CR80 VAM ACE, .0087 bpf, ID = 2.992" 7" LNR, 26#, L-80 BTC, ~~~ 11535' .0383 bpf, ID = 6.276" PBTD ~ 14316' ~- 4-1(2" LNR, 12.6#. L-80 14405' IBT, .0152 bpf, ID - 3.958" DATE REV BY COMMENTS DATE REV BY COMMENTS 06/28/84 ROBERTS ORIGINAL COMPLETION 12(04105 DAVlTLH DRLG DRAFT CORRECTIONS 08!04!99 WHITLOW CTD SIDETRACK (U-06A) 11/10108 KJB/SV GLV C!O {11(04!08) 05111!05 N7ES ATTEMPTED SDTRCK U-06B} 06/08/05 N2ES SIDETRACK (U-06B} 06(14/05 RMHIPJC GLV C/O 09/11/05 KSBITLH GLV C/O 11352' ~ 3-112"" HES XN NIP, ID = 2.635" 11361' 7" X 5'" BKR ZXP LNR TOP PKR ~ w/TIEBACK SLV, ID = 4.42" i 11366' 3-1l2" WLEG & 3-112" X 4-112" XQ, ID = 2.992" ' 11378 K ~H....,.,..-- MC LNR HNGR, ID 43" 113$5' 5" X 4-112" XO, ID = 3.96" PRUDHOE BAY UNIT WELL: U-06B PERMIT No: 1050640 API No: 50-029-21117-02 SEC 18, T11N, R13E, 103' NSL & 1663' WEL BP Exploration (Alaska) STATE OF ALASKA ALAS OIL AND GAS CONSERVATION COMM ION ~~ ~~ .s /ff-~ ~IAY .~ ~ ~(J(~S' REPORT OF SUNDRY WELL OPERATION~eska ~;; ~, ~~~ ~,,~ 1. Operations Abandon ~ Repair Well ~ Plug Perforations ~ Stimulated Other ACID ft: 4 '4Ssu:: Performed: Alter Casing ~ Pull Tubing ~ Perforate New Pool ~ Waiver Time Extension Change Approved Program ~ Operat. Shutdown ~ Perforate ~ Re-enter Suspended Well 2. Operator BP Exploration (Alaska), Inc. 4. Current Well Class: 5. Permit to Drill Number: Name: Development ~- Exploratory 2o5-os4o - 3. Address: P.O. Box 196612 Stratigraphic Service (~ 6. API Number: Anchorage, AK 99519-6612 50-029-21117-02-00 - 7. KB Elevation (ft): 9. Well Name and Number: 76.63 DF - PBU U-066 - 8. Property Designation: 10. Field/Pool(s): ADLO-028263 - PRUDHOE BAY Field/ PRUDHOE OIL Pool 11. Present Well Condition Summary: Total Depth measured 15229 ' feet Plugs (measured) None true vertical 9020.42 - feet Junk (measured) None Effective Depth measured 14315 - feet true vertical 8955.95 - feet Casing Length Size MD TVD Burst Collapse Conductor 110 20" Surface - 110 Surface - 110 Surface 2685 13-3/8" 72# L-80 Surface - 2685 Surface - 2685 4930 2670 Production 2958 9-5/8" 47# L-80 Surface - 2958 Surface - 2958 6870 4760 Liner 8749 7" 26# L-80 2786 - 11535 2786 - 8866 7240 5410 Liner 3044 4-1/2"12.6# L-80 11361 - 14405 8756 - 8961 8430 7500 Perforation depth: Measured depth: SEE ATTACHED - _ _ _ True Vertical depth: _ _ _ _ _ Tubing: {size, grade, and measured depth) 3-1/2" 9.2# 13CR80 SURFACE - 11366' 0 0 - Packers and SSSV (type and measured depth) 7"X4-1/2" BKR S-3 PKR 11306', 0 0 0 0 0 0 12. Stimulation or cement squeeze summary: Intervals treated (measured): j~~~,~),~t~t ~ 1~1~1 ~ ~ ~`;~ V r ~ 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: 248 195 182 179 Subsequent to operation: 248 202 306 180 14. Attachments: 15. Well Class after proposed work: Copies of Logs and Surveys Run Exploratory [~ Development - Service Daily Report of Well Operations X 16. Well Status after proposed work: Oil - Gas ~ WAG GINJ ~ WINJ WDSPL 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 Gary Preble Printed Name Gary Preble Title Data Management Engineer Signature Phone 564-4944 Date 5/13/2009 Form 10-404 Re sed 04/201 ! ; : k~ ~ ~ , ; ~ ~~Submit Original Only U-06B 205-064 PERF ATTA(_NMFNT Sw Name Operation Date Perf Operation Code Meas Depth Top Meas Depth Base Tvd Depth Top Tvd Depth Base U-066 6/6/05 PER 11,750. 12,000. 8,979.83 9,022.93 U-066 6/6/05 PER 13,660. 13,720. 9,020.22 9,014.12 U-066 6/6/05 PER 13,345. 13,625. 9,014.35 9,024.13 U-06B 6/6/05 PER 13,290. 13,335. 9,009.05 9,013.35 U-06B 6/6/05 PER 13,040. 13,235. 8,991.95 9,004.32 U-06B 6/6/05 PER 12,900. 13,030. 8,980.33 8,991.38 U-06B 6/6/05 PER 13,735. 13,920. 9,012.66 8,992.12 U-06B 6/6/05 PER 12,715. 12,885. 8,975.05 8,978.74 U-06B 6/6/05 PER 12,300. 12,620. 9,015.38 8,982.5 U-O6B 6/6/05 PER 12,180. 12,200. 9,027.51 9,025.8 U-06B 6/6/05 PER 12,130. 12,160. 9,029.42 9,028.7 U-06B 6/6/05 PER 12,080. 12,100. 9,028.39 9,029.1 U-06B 6/6/05 PER 12,020. 12,050. 9,024.65 9,026.82 U-06B 6/6/05 PER 12,635. 12,685. 8,981.15 8,976.94 U-06B 6/6/05 PER 43,975. 14,170. 8,985.67 8,963.99 AB ABANDONED PER PERF APF ADD PERF RPF REPERF BPP BRIDGE PLUG P ULLED SL SLOTTED LINER BPS BRIDGE PLUG SET SPR SAND PLUG REMOVED FCO FILL CLEAN OUT SPS SAND PLUG SET FIL FILL SQF SQUEEZE FAILED MIR MECHANICAL ISOLATED REMOVED SQZ SQUEEZE MIS MECHANICAL ISOLATED STC STRADDLE PACK, CLOSED MLK MECHANICAL LEAK STO STRADDLE PACK, OPEN OH OPEN HOLE • • U-06B DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY ACTIVITYDATE SUMMARY 5/2/2009 CTU #6 Job sco a :Mill scale & acid treatment; Preform week) BOP test RIH P Y w/3 bladed 2.50" mill tag fill at 12824' start pumping. DSO came by no Gas lift. Tried pumping without GL unable to get good returns. **** Continued on X5/3/09 ***** 5/2/2009~ASRC Test Unit #1, S/B, Assist CTU, ***Job in progress*** __ .. ~. _ _u______ 5/3/2009CTU #6 1.75" CT Job Scope: Mill/Acid Treatment Continued from 5/2/09 DSO €came by GasLift is ready have ASRC open up let the well stabilize. Start millin at12823' not seeing any wt loss and very little motor work stop at 13200'. Make short trip back to SO at 11223' to sweep hole. RBIH to 13400' still not seeing any motor work until we picked up off bottom decided to make another trip to the SO got to 12318' unable to PUH work pipe pump FloPro sweep get jar lick popped free.Cleaned hole with another pill of FloPro RBIH to resume milling made it to 13714' make short trip to SO got to 11350' can't move up or own. ump pi own coil get bottoms up chase out of coil with diesel still unable to move pipe. Pump pill down backside to nozzle start Iworking pipe poped free after several attempts POOH check tools. MU Venturi RIH to see if we can pickup any debris in the well. ***** Continued on 5/4/09 ****** 5/3/2009~ASRC Test Unit #1, Assist CTU, ***Job in progress*** 5/4/2009=CTU #6 1.75" CT Mill/FCO/Acid Continued from 5/3/09 RIH w/ 2.240" Venturi . RIH to 1st x-nipple venturi thru all nipples shut down pump continue RIH to 14200' didn't see an hin made several weight checks no overpulls. PP-~H came back thru nipples no problem. RIH w/ 2" JSN Preform FCO to 14200'. !Pumpers on loction spot equipment. Start pumping NH4CL to displace gas Efrom well cap backside with 52 bbls dieseLPre job infectivity 1,7 bpm @ 1243 ipsi.""""Job Continued 5/5/09 "'"'~" 5/4/2009~ASRC Test Unit #1, Assist CTU, ***Job in progress*** 5/5/2009~CTU #61.75" CT Job Scope: Acid Treatment Continued from 5/4/09 Hold PJSM before acid job. Acidize all perforation from 11750' to 14170' w / 200 bbls 12% HCL & 200 bbls 9:1% Mud Acid """"Job Continued On 5/5/2009~ASRC Test Unit #1, Assist CTU, ***Job in progress*** 5/6/2009~CTU #6 1.75" CT POOH blowdown coil for reel swap.RDMO go to shop for ~maintenace**** Job Complete ****** 5/6/2009~ASRC Test Unit #1 continue with acid flowback. ***Job in progress*** 5/7/2009~ASRC Test Unit #1 continue with acid flowback. ***Job in progress*** 5/8/2009~ASRC Test Unit #1 Cont. flowback and begin well test. **'`Job in progress*** 5/9/2009jASRC Test Unit #1 complete test and rig down. FLUIDS PUMPED BBLS 125 50/50 METH 90 2% KCL 55 2% KCL 0.6% SAFELUBE 84 DIESEL 1160 XS KCI 870 XS/SL 80 FLOPRO 200 9:1 % MUD ACID 165 NH4CL 2829 Total ~ ~ WELL LOG TRANSM/TTA! ~~. ProActive Diagnostic Services, Inc. To: AOGCC Christine Mahnken 333 W. 7th Ave Suite 100 Anchorage, Alaska 99501 (907] 793-1225 RE : Cased Hole/Open Hole/Mechanical Logs and/or Tubing Inspection(Caliper/ MTT] The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the fogowing BP Exploration (Alaska), Inc. Petrotechnical Data Center Attn: Joe Lastuflca LR2-1 900 Benson Byrd. Anchorage, Alaska 99508 and ProActive Diagnostic Services, Inc. Attn: Robert A. Richey 130 West international Airport Road Suite C _ Anchorage, AK 99518 ~.~_ 6,~~/ ~~•~ ~~~ Fax: (907) 245-6952 1] Date . z~ ~~ ~ ~i~~ . ~€~~ PROACTNE DIAGNOSTIC SERVICES, 81C., 130 W. INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 89518 PHONE: (807)245-8951 FAX: (8071245$8952 E-MAIL: pdsanchoraae~memorVloa.com WEBSITE:www.memorvlog.com 2] Gas Lift Survey 17,1an-09 U-066 EDE ~~ -~ Signed : ~ ' ~~ L- ~'~ Print Name: C:\Doci¢nents end Settings\Ow~rlDesk[op\Tiansnrit BP.docx OPERABLE: U-06B (PTD #2050640) Tubing Integrity Restored and OA Repressurization Mana... Page 1 of 2 • • Regg, James B (DOA) From: NSU, ADW Well Integrity Engineer [NSUADWWeIIlntegrityEngineer@BP.com] ~~ ~IZ~,~ Sent: Thursday, November 06, 2008 9:16 PM To: Regg, James B (DOA); Maunder, Thomas E (DOA); GPB, Area Mgr West (GC2/WRD); GPB, GC2 OTL; GPB, GC2 Wellpad Lead; GPB, Well Pad HU; Rossberg, R Steven; Engel, Harry R; NSU, ADW Well Operations Supervisor; Hibbert, Nancy; GPB, Wells Opt Eng; GPB, Optimization Engr Cc: Townsend, S. Eliot; NSU, ADW Well Integrity Engineer Subject: OPERABLE: U-06B (PTD #2050640) Tubing Integrity Restored and OA Repressurization Manageable All, r Well U-06B {PTD #2050640) passed an OA Repressurization Test on 10/2$/08 when the OA demonstrated negligible build up. In addition, the well passed a TIFL on 11/05/08 after gas lift valve work was completed. Both tests indicate the we`tf"fi~s confirmed integrity and is therefore reclassified as Operable. Please calf with any questions or concerns. Thank you, Andrea Hughes Well Integrity Coordinator -, . ( f~ ~; ~~~~~ Office: (907) 659-5102 "'~t'~~~~ `~~~ Pager: (907) 659-5100 x1154 From: NSU, ADW Well Integrity Engineer Sent: Sunday, October 19, 2008 1:23 PM To: 'Regg, James B (DOA)'; 'Maunder, Thomas E (DOA)'; GPB, Area Mgr West (GC2/WRD); GPB, GC2 OTL; GPB, GC2 Wellpad Lead; GPB, Well Pad HU; Rossberg, R Steven; Engel, Harry R; NSU, ADW Well Operations Supervisor; Hibbert, Nancy Cc: NSU, ADW Well Integrity Engineer; Holt, Ryan P (ASRC) Subject: UNDER EVALUATION: U-06B (PTD #2050640) Sustained Casing Pressure on the IA and OA All, Well U-06B (PTD #2050640) was found to have sustained casing pressure on the IA;3nd OA. The TIOs were 1280/2020/1200 psi when the OA pressure was bled on 10/16/08. The well failed a TIFL on 10/18/08 when the tubing pressure tracked during the IA bleed. The well has been reclassified as Under Evaluation and placed on a 28-day clock. The plan forward for the well is as follows: 1. D: Bleed OAP and TIFL -FAILED 2. D: OA repressurization test to determine OAP build-up rate 3. S: Change out gas lift valves 4. D: re-TIFL, bleed IAP and OAP to 0 psi 5. W: PPPOT-IC A wellbore schematic and TIO plot have been attached for reference. `~ Please call with questions or concerns. 11/28/2008 OPERABLE: U-06B (PTD #2050640) Tubing Integrity Restored and OA Repressurization Mana... Page 2 of 2 • Thank you, Andrea Hughes Well Integrity Coordinator Office: (907) 659-5102 Pager: (907) 659-5100 x1154 I L/28/2008 PBU U-06B PTD 205-064 TIO Pressures ~ 1100 ~,r1ao z,oor.~ 1 io0 IC~~ ~~(-ZE~3 • • 07i19i08 07i26i0$ 08i02i0$ 0$109i0~3 Obi16i08 Ot3123if~3 Ck3f~1i06 09i06ifk3 09i1310S 0012010$ 0912'10E 101041(10 10111108 TRF~ = 4" CNV WELLHEAD= - MCEVOY . ACTUATOR= ,~ SAKER ' KB. ELEV = 84.30' BF. ELEV..- _._ . _ 48.80' -. .~ _ .,_~,~.,-..._ KOP = ~-~.-,__W.. ~.-,. 7 700' Max Angle = 96 (a7 12208' Datum MD _ 8967 Datum TVD - 8800' SS ~ u-oss 2786 SA NOTES: ORIGINAL WELLBORE {U-0&} IS NOT SN+~ON DIAGRAM '"`*3-112" CHROM E TBG*** 4-112'° X 3-1i2" XO, iD = 2.992" ;~-- 3-112" HES X NIP, ID = 2.813" ~-- 9-5(8" X 7" ZXP LNR TOP PKR & FLEX LOCK HNGR, ID = 6.31 "' GAS LIFT MANDRELS 13-31$" CSG, 72#, L-80, ID = 12.347" ~--L 2680' ~--' Minimum ID = 2.635" @ 11352' 3-112" NES XN NIPPLE WHIPSTOCK {04!30105) HES EZSV {04128105) I 2980' E TOP OF CEMENT 04124105) TOP OF 2-718" LNR TOP OF 7" LNR 4-1/2" TBG 12.6#, L-80, ID = 3.958" 9-5i8" CSG. 47#, L-80, ID = 8.681" ST MD TVD DEV TYFE VLV LATCH PORT DATE 6 3000 3000 3 MMG DMY RK 0 09111105 5 3848 3810 26 MMG DOME RK 16 09111105 4 7111 6012 50 MMG DOME RK 16 09/11/05 3 9122 7301 51 MMG DOME RK 16 09111!05 2 10376 8148 48 MMG DMY RK 0 06/11/05 1 11223 8665 49 MMG SO RK 20 09/11/05 ~` `~ mi~LOUT wiNDOw {u-os6} zsss' - za7a' 11283' (-~ 3-112" HES X NIP, ID = 2.813" 11304` 3-1/2" X 4-112" XO, ID = 2.94" 11.30$' 7" X 4-112" BKR 5-3 PKR, ID = 3.875" 8381' PERFORATION SUMMARY REF LOG: hrflEtvl. RESISTIVITY LOG'~s"N 08i01199?'? ANGLE AT TOP PERF: 66 @ 11750' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL OpnlSgz DATE 2-112" 6 11750 - 12000 O 06(06/05 1 2-112" 6 12020 - 12050 O 06106!05 2-1/2°` 6 12080 - 12100 O 06!06105 2-112" 6 12130 - 12164 O 06/06/05 2-112" 6 '12180 - 12200 O 06l06J05 2-112" 6 12300 - 12620 O 06;06105 2-1f2" 6 12635 - 12685 O 06!06105 2-718" 6 12715 - 12885 O 06106/05 2-7/8" 6 12900 - 13030 O 06/06/05 2-718" 6 13040 - 13235 O 06/06/05 2-718" 6 13290 - 13335 O 06106105 ' 2-718" 6 13345 - 13625 O 06/06105 ~~ 2-718" 6 13660 - 13720 O 06/06105 1 2-718" 6 13735 - 13920 O 06!06(05 2-7f8" 6 13975 - 14170 O 06106105 3-112" TBG, 9.2#, -j 11366• 13CR80 VAMACE, .0087 bpf, ID = 2.992" 7" LNR, 26#, L-80 BTC~- 11535' .0383 bpf, iD = 6.276" PBTD 14316' ~4-1(2" LNR, 12.6#; L-80 14405' ' IBT; .0152 bpf, ID = 3.958" DATE REV BY COMMENTS 06t28l84 ROBERTS ORIGINAL COMPLETION U8I04199 WHITLOW CTD SIDETRACK {U-06A, 051111U5 N7ES ATTEMPTED SDTRGK {U 061t18105 N2ES SIDETRACK (U-06B} 06/14105 RMHIPJC GLV Ci0 09;'11/05 KSBiTLH GLV CIO DATE REV BY~ 12144/05 DAVITLH DRLG 11310" 4-1/2" X 3-1l2" XO, ID = 2.96" 11331' 3-112" HES X NIP, ID = 2.813" 11352' 13-112" HES XN NIP, ID = 2.635" 11361' 7'° X 5" BKR ZXP LNR TOP PKR w 1TIEBACK SLV, ID = 4.42" 11366' 3-112" WLEG & 3-112" X 4-112" XO, BD = 2.992" 11378' 7" X 5°' BKR HMC LNR HNGR, ID = 4.43" 11385' S'° X 4-112" XO, ID = 3.96" PRUDHOE BAY UNiT WELL: U-O6B PERMIT No: 2050640 API No: 50-029-21 1 1 7-02 SEG 18. T11N. R13E. 103' NSL & 1663' WEL BP ExpBoration {Alaska) 8Jw~ DATA SUBMITTAL COMPLIANCE REPORT 7/2/2007 Permit to Drill 2050640 Well NamelNo. PRUDHOE BAY UNIT U-06B MD 15229/' TVD 9020 _ Completion Date 6/8/2005 Operator BP EXPLORATION (ALASKA) INC Completion Status 1-01L Current Status 1-01L )fI"¿ )M.Þ, ~~-- API No. 50-029-21117-02-00 UIC N REQUIRED INFORMATION Mud Log No Samples No Directional su~ DATA INFORMATION Types Electric or Other Logs Run: MWD DIR / GR / PWD, MWD DIR / GR / RES Well Log Information: Log/ Electr Data Digital Dataset Type Med/Frmt Number Name r- D Asc Directional Survey ê Directional Survey D Asc Directional Survey Directional Survey ß-~ Asc Directional Survey Asc Directional Survey Production r:c Lis 15240 I nd uction/Resistivity ~ 15240 Induction/Resistivity -,--_.._~ Well Cores/Samples Information: Name (data taken from Logs Portion of Master Well Data Maint Log Log Run Interval OH/ Scale Media No Start Stop CH Received 0 11535 Open 5/27/2005 0 11535 Open 5/27/2005 0 3193 Open 5/27/2005 0 3193 Open 5/27/2005 0 15229 Open 7/29/2005 0 15229 Open 7/29/2005 2 Blu 11550 13400 Case 4/20/2007 13035 15229 Open 6/25/2007 Interval Start Stop ADDITIONAL INFORMATION Well Cored? Y ~ Chips Received? ŸTFr" Analysis ~ Received? --~-,-----~~-~-~~_._---~------~._- -~--'---~'-'~~--~--~- Comments: e Comments -l I I MWD I Mem PPL w/Deft, GR, I CCL, Spin, Temp, Pres 24- ·1 Feb-2007 LIS Veri, GR, FET, ROP W/~lAII oil b..l QIIY I ur PB 1 PB 1 IIFR 13035 15229 Open 6/25/2007 LIS Veri, GR, FET, ROP e Sent Sample Set Number Comments Received Daily History Received? &/N ~ Formation Tops .--_._~--~--~_. DATA SUBMITTAL COMPLIANCE REPORT 7/2/2007 Permit to Drill 2050640 Well NamelNo. PRUDHOE BAY UNIT U-06B Operator BP EXPLORATION (ALASKA) INC MD 15229 TVD 9020 Completion Date 6/8/2005 Completion Status 1-01L Current Status 1-01L t Date: Compliance Reviewed By: API No. 50-029-21117-02-00 7~5 UIC N --- -<tJ.eJ e . e e WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Corom. Attn.: Librarian 333 West ih Avenue, Suite 100 Anchorage, Alaska 99501 June 21, 2007 RE: MWD Formation Evaluation Logs: U-06B AK-MW-3684031 1 LDWG formatted CD rom with verification listing. API#: 50-029-21117-02 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COpy OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry Drilling Services Attn: Rob Kalish 6900 Arctic Blvd. Anchorage, Alaska 99518 BP Exploration (Alaska) Inc. Petrotechnical Data Center MB33 900 E. Benson Blvd. Anchorage, Alaska 99508 RECE.~\¡E[J Date:tlUN 2 I Z007 Signed: tl~ l\Iaska Oil 8: Gas Cons. Commissioi I Anchor3Ç e ()a)-O~'-1 -p; t 6-é)'-I{) REC D 04/16/07 Schlumbepger APR 2 U Z007 NO 4214 Alaska Data & Consulting Services 2525 Gambe" Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Oil & Gas Cons. commiss!œ Anchorage Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 c90<0-~~/ Field: Prudhoe Bay Well Job# Log Description Date BL Color CD 02-15 11661130 MEM PROD PROFILE 02/25/07 1 U-06B 11469946 MEM PROD PROFILE 02/24/07 1 P-09L 1 11676933 LEAK DETECTION LOG 03/18/07 1 U-12A 11649941 MEM PROD PROFILE 02/17/07 1 Z-32BL 1 11661128 MEM PROD PROFILE 02/19/07 1 L-04 11649945 MEM SPINITEMP/PRESS LOG 02/18/07 1 DS 16-22 11676935 LEAK DETECTION LOG 03/22/07 1 DS 12-31 11594485 LEAK DETECTION LOG 03/23/07 1 DS 07-35 11676932 LEAK DETECTION LOG 03/17/07 1 06-07 11637114 LEAK DETECTION LOG 03/16/07 1 L5-28AL 1 11660526 MEM PROD PROFILE 02/08/07 1 03-33B 11661131 MEM TEMP/PRESS SURVEY 03/01/07 1 Z-19A 11649953 STATIC PRESS & TEMP LOG 03/21/07 1 F-11B 11649954 MEM PROD PROFILE 03/22/07 1 P2-37 A 11628754 MEM DEPTH CONTROL LOG 02/11/07 1 P2-58 11661129 MEM STATIC PRESS SURVEY 02/24/07 1 Y -06A 11628751 MEM INJECTION PROFILE 02/09/07 1 Z-35 11628753 DEPTH CONTROL LOG 02/10/07 1 P2-40 11637320 PROD PROFILE 02/25/07 1 05-20B 11649952 MEM DEPTH DETERMINATION 03/20/07 1 03-36 11649951 MEM STATIC PRESS & TEMP 03/18/07 1 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COpy EACH TO: BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage. AK 99503-2838 ATTN: Beth Date Delivered: Received by: é)( e - . AOGCC Helen Warman 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 . Re: Distribution of Survey Data for Well U-06B Dear Dear Sir/Madam: Enclosed is one disk with the *.PTT and *.PDF files. Tie-on Survey: Window / Kickoff Survey: Projected Survey: 11,468.96' MD 0.00' MD 15,229.00' MD (if applicable) 12-Jul-05 PLEASE ACKNOWLEDGE RECEIPT BY SENDING AN EMAIL TO CARL.ULRICH@HALLlBURTON.COM OR SIGNING AND RETURNING A COpy OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Carl Ulrich 6900 Arctic Blvd. Anchorage, AK 99518 Date ~} fJ- Vj J.tt)- Signed 11JtJj¡~ Please call me at 273-3545 if you have any questions or concerns. Regards, Carl Ulrich Survey Manager Attachment(s) .).J S' - ~ ~ '-I F.I J... . . AOGCC Helen Warman 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 Re: Distribution of Survey Data for Well U-06B MWD Dear Dear Sir/Madam: Enclosed is one disk with the *.PTT and *.PDF files. Tie-on Survey: Window / Kickoff Survey: Projected Survey: 11,468.96' MD 0.00 I MD 15,229.00' MD (if applicable) PLEASE ACKNOWLEDGE RECEIPT BY SENDING AN EMAIL TO CARL.ULRICH@HALLlBURTON.COM OR SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Carl Ulrich 6900 Arctic Blvd. Anchorage, AK 99518 11 J J Date ') l ~ :k'1 Signed /" tJr,....J tJ Ji.v) Please call me at 273-3545 if you have any questions or concerns. Regards, Carl Ulrich Survey Manager Attachment(s) 12-Jul-05 ÂO)-- Ò~~r:;/L . .. STATE OF ALASKA _ ALAS~D GAS CONSERVATION COM WELL COMPLETION OR RECOMPLETION REPORT AND LoRECEIVED JUL 1 2 Z005 1a. Well Status: 1m Oil o Gas o Plugged o Abandoned o Suspended o WAG 1.t'i!ðJtI)~~,~~n 20AAC 25.105 20AAC 25.110 OGINJ OWINJ o WDSPL No. of Completions One Other o Stratig ÞÞhøreService 2. Operator Name: 5. Date Comp., Susp., or Aband. 12. Permit to Drill Number BP Exploration (Alaska) Inc. 6/8/2005 205-064 305-124 3. Address: 6. Date Spudded 13. API Number P.O. Box 196612, Anchorage, Alaska 99519-6612 5/1/2005 50- 029-21117-02-00 4a. Location of Well (Governmental Section): 7. Date TD. Reached 14. Well Name and Number: Surface: 5/30/2005 PBU U-06B 103' FSL, 1663' FEL, SEC. 18, T11N, R13E, UM 8. KB Elevation (ft): 15. Field I Pool(s): Top of Productive Horizon: 2751' FNL, 2085' FEL, SEC. 24, T11 N, R12E, UM 76.63' Prudhoe Bay Field I Prudhoe Bay Total Depth: 9. Plug Back Depth (MD+ TVD) Pool 2164' FNL, 127' FEL, SEC. 23, T11N, R12E, UM 14316 + 8956 Ft 4b. Location of Well (State Base Plane Coordinates): 10. Total Depth (MD+TVD) 16. Property Designation: Surface: x- 632339 y- 5960690 Zone- ASP4 15229 + 9020 Ft ADL 047451 TPI: x- 627017 y- 5957744 Zone- ASP4 11. Depth where SSSV set 17. Land Use Permit: Total Depth: x- 623686 y- 5958275 Zone- ASP4 (Nipple) 2192' MD 19. Water depth, if offshore 20. Thickness of Permafrost 18. Directional Survey 1m Yes ONo NIA MSL 1900' (Approx.) 21. Logs Run: MWD DIR I GR I PWD, MWD DIR I GR I RES :;12. CASING, liNER AND CEMENTING RECORD 7~T~~~ <;SETTINØ EP'fI;IMO . < SETTING' [ EPTH TVP ~~r < " 'WT; '¡PER ¡:+. <.3~PI; TOÞ tsOTTOM .IOP ItsOtTOM , ·P..·..·"'...., 20" x 30" Insulated Conductor Surface 110' Surface 110' 36" 8 cu vds Concrete 13-3/8" 72# L-80 Surface 2685' Surface 2685' 17-1/2" 3746 cu ft Permafrost 'E' and II 9-5/8" 47# L-80 Surface 2958' Surface 2958" 12-1/4" 1740 cu ft Class 'G', 279 cu ft PF 7" 26# L-80 2786' 11535' 2786' 8866' 8-1/2" 1420 cu ft Class 'G', 196 cu ft 'G' 4-1/2" 12.6# L-80 11361' 14405' 8756' 8961' 6-1/8" 730 cu ft Class 'G' 23. Perforations oRen to Production (MD + TVD of To£ and 24. " , , Bottom Interval, Size and Number; if none, state' none"): SIZE DEPTH SET (MD) PACKER SET (MD) 2-1/2" Gun Diameter, 6 spf 2-7/8" Gun Diameter, 6 spf 3-1/2",9.2#,13Cr80 11366' 11306' MD TVD MD TVD 11750' -12000' 8980' - 9023' 12715' - 12885' 8975' - 8979' 25. Aê.õ,.. ~< ,i, 12020' - 12050' 9025' - 9027' 12900' - 13030' 8980' - 8991' 12080' - 12100' 9028' - 9029' 13040' - 13235' 8992' - 9004' DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 12130' - 12160' 9029' - 9029' 13290' - 13335' 9009' - 9013' 12180' -12200' 9028' - 9026' 13345' - 13625' 9014' - 9024' Freeze Protect wI 155 Bbls of Diesel 12300' - 12620' 9015' - 8983' 13660' - 13720' 9020' - 9014' 12635' - 12685' 8981' - 8977' 13735' - 13920' 9013' - 8992' 13975' - 14170' 8986' - 8964' 26. PRODUCTION TEST Date First Production: Method of Operation (Flowing, Gas Lift, etc.): June 20, 2005 Gas Lift Date of Test Hours Tested PRODUCTION FOR Oll-BSl GAs-McF W A TER-Bsl CHOKE SIZE GAS-Oil RATIO TEST PERIOD ... Flow Tubing Casing Pressure CALCULATED ... Oll-Bsl GAs-McF WATER-Bsl Oil GRAVITY-API (CORR) Press. 24-HoUR RATE 27. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water (attach separate sheet, if necessary). Submit core chips; if none, state "none". None rcõi\1PÜ:T;6i~-i RBDMS 8F!. ,; 7005 ~~t , ,!" ~L RBDMs ~: "rm ~¡ I ! ¡\¡ " ':10 ¡' i ~ED ; G,r Form 10-407 ,-.-" 3 CONTINUED ON REVERSE SIDE ~8. GEOLOGIC MARKERS NAME MD Top HRZ 8642' Base HRZ I LCU 9097' Kingak 9625' Sag River 11530' Shublik A 11570' Shublik B 11646' Shublik C 11678' Shublik D 11701' Eileen 11717' Sadlerochit 11721' 29. TION TESTS Include and briefly summarize test results. List intervals tested, TVD and attach detailed supporting data as necessary. If no tests were conducted, state "None". 6996' None 7285' 7621' 8863' 8888' 8935' 8955' 8970' 8980' 8982' 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. Signed Terrie Hubble ~ . Title Technical Assistant Date 07..{Z'OS PBU U-06B Well Number Prepared By Name/Number: Drilling Engineer: Terrie Hubble, 564-4628 Ken Allen, 564-4366 205-064 305-124 Permit No. I A roval No. 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. ITEM 1a: Classification of Service Wells: Gas Injection, Water Injection, Water-Altemating-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. ITEM 4b: TPI (Top of Producing Interval). ITEM 8: The Kelly Bushing elevation in feet above mean low low water. Use same as reference for depth measurements given in other spaces on this form and in any attachments. ITEM 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). ITEM 20: True vertical thickness. ITEM 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITEM 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). ITEM 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, or Other (explain). ITEM 27: If no cores taken, indicate "None". ITEM 29: List all test information. If none, state "None". Form 10-407 Revised 12/2003 Submit Original Only Legal Name U-06 Common Name: U-06 4/30/2005 FIT 5/24/2005 FIT ,806 (psi) 11.76 (ppg) 4,328 (psi) 9.40 (ppg) - Printed: 6/13/2005 11: 1 0:30 AM 408 (psi 460 (psi 9.10 (ppg) 8.40 (ppg) 2,958.0 (ft) 8,865.0 (ft 2,958.0 (f 11,557.0 (ft) Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: U-06 U-06 REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 7ES Start: 4/26/2005 Rig Release: 6/8/2005 Rig Number: Spud Date: 6/11/1984 End: 5/11/2005 4/26/2005 00:00 - 04:00 4.00 MOB P PRE Move pits and position to install moving jeep, prepare sub for derrick down move, pull sub off well and position to lay down derrick, move satilite camp from P2-Pad to U-Pad. Lay down derrick and prepare Sub & Pits for move. 04:00 - 22:00 18.00 MOB P PRE Move Sub, Pits and remeainder of rig equipment from Pt. Mac 2 to U-Pad 22:00 - 00:00 2.00 RIGU P PRE Lay matting boards & herculite around cellar, spot sub over well U-06 @23:15 hrs, build berms, prepare to raise derrick. 4/27/2005 00:00 - 01 :00 1.00 RIGU P PRE Raise derrick, continue to rig-up on U-06a. (Pre-spud meeting at 23:30 hrs on 4/26/05 during pre-tour meeting.) 01 :00 - 02:00 1.00 RIGU P PRE Bridle down, bridle up top-drive. 02:00 - 04:00 2.00 RIGU P PRE Move in pits, hang bridle lines in derrick. 04:00 - 04:45 0.75 WHSUR P DECOMP Accept rig at 04:00 hrs, pull BPV w/lubricator (DSM), take on seawater in pits. 04:45 - 06:00 1.25 WHSUR P DECOMP RU to displace well, finish loading pits W/8.5 ppg seawater. 06:00 - 06:30 0.50 WHSUR P DECOMP Test gas alarms. 06:30 - 10:30 4.00 WHSUR P DECOMP Displace well with seawater, gas encountered (circ through choke), pump 380 bbls seawater, monitor well to ensure well is "dead", pressure test well to 3500 psi, test good. 10:30 - 12:00 1.50 WHSUR P DECOMP Function all LDS's on tubing and casing spools. 3 LDS on tubing spool frozen in locked position. Test 9 5/8" packoff- failed. Test Tubing Hanger - OK. 12:00 - 13:45 1.75 WHSUR P DECOMP Work on siezed tubing head LDS, set TWC & test to 1000 psi f/below, blow down lines. 13:45 - 14:45 1.00 WHSUR P DECOMP ND tree & adapter flange. 14:45 - 15:45 1.00 WHSUR P DECOMP Cut & grind down siezed tubing head LDS's. 15:45 - 18:00 2.25 BOPSU P DECOMP NU BOPE. 18:00 - 18:30 0.50 BOPSU P DECOMP RU to test BOPE, tighten leaking gland nuts. 18:30 - 23:30 5.00 BOPSU P DECOMP Test BOPE & choke manifold 250/3500 psi (All tests witnessed by J. Rose - Wellsite Leader & C. Weaver NAD Tool Pusher / witness waived by AOGCC (John Spaulding). 23:30 - 00:00 0.50 BOPSU P DECOMP RD testing equipment & blow-down linesfTD. 4/28/2005 00:00 - 00:30 0.50 PULL P DECOMP Pulled TWC (w/lubricator - DSM). 00:30 - 01 :00 0.50 PULL P DECOMP MU landing joint to pull tubing. 01 :00 - 01 :30 0.50 PULL P DECOMP Back-out LDS's. 01 :30 - 02:30 1.00 PULL P DECOMP Pulled tubing free (80K Ibs), circulate well surface to surface plus w/pumping surfactant wash to clean well (well cleaned-up), 11 bpm, 200 psi. 02:30 - 03:00 0.50 PULL P DECOMP LD landing joint, disconnect control line, LD tubing hanger. 03:00 - 06:00 3.00 PULL P DECOMP POOH w/50 joints 4 1/2" tubing & control line (26 rubber protectors + 2 steel bands recovered from string). 06:00 - 06:30 0.50 PULL P DECOMP Cut control line from SSSV and RD spooling unit. 06:30 - 08:00 1.50 PULL P DECOMP POOH with total of 76 full joints of 41/2" tubing, clean rig floor. 08:00 - 09:00 1.00 DHB P DECOMP RU to run E-Line. 09:00 - 10:15 1.25 DHB P DECOMP RIH & POOH w/junk basket, 8 1/2" guage ring and gamma ray to 3175'. 10:15 -11:30 1.25 DHB P DECOMP LD gauge ring and basket, change head on wireline unit, MU EZSV bridge plug. . 11 :30 - 13:30 2.00 DHB P DECOMP RIH w/CCL and set EZSV on wireline at 2980'. 13:30 - 14:30 1.00 DHB P DECOMP Pressure test casing t/3500 psi f/30 min (OK), blow down lines. Printed: 6/13/2005 11: 1 0:39 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: U-06 U-06 REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 7ES Start: 4/26/2005 Rig Release: 6/8/2005 Rig Number: Spud Date: 6/11/1984 End: 5/11/2005 18:00 - 19:45 1.75 DECOMP 19:45 - 21:30 1.75 DECOMP 21 :30 - 00:00 2.50 DECOMP 4/29/2005 00:00 - 02:00 2.00 DECOMP 02:00 - 03:00 1.00 DECOMP 03:00 - 03:15 0.25 DHB P DECOMP 03:15 - 04:30 1.25 DHB P DECOMP 04:30 - 05:15 0.75 STWHIP P WEXIT 05:15 - 12:30 7.25 STWHIP P WEXIT 12:30 - 15:00 2.50 STWHIP P WEXIT 15:00 - 16:30 1.50 STWHIP P WEXIT 16:30-18:15 1.75 STWHIP P WEXIT 18:15 -19:15 1.00 STWHIP P WEXIT 19:15 - 22:00 2.75 STWHIP P WEXIT 22:00 - 00:00 2.00 STWHIP P WEXIT 4/30/2005 00:00 - 03:00 03:00 - 08:30 3.00 STWHIP P 5.50 STWHIP P WEXIT WEXIT 08:30 - 09:30 1.00 STWHIP P WEXIT 09:30 - 15:00 5.50 STWHIP P WEXIT 15:00 - 16:30 1.50 STWHIP P WEXIT 16:30 - 17:30 1.00 STWHIP P WEXIT 17:30 - 19:00 1.50 STWHIP P WEXIT 19:00 - 21 :30 2.50 STWHIP P WEXIT 21 :30 - 23:00 1.50 STWHIP P WEXIT 23:00 - 00:00 1.00 DRILL P INn 5/1/2005 00:00 - 03:00 3.00 DRILL P INT1 03:00 - 04:30 1.50 DRILL P INT1 PU 42 joint of 5" drillpipe f/ RTTS packer. PU & M/U RTTS and set at @40', RU & test lower pipe rams 250 psi, pipe began to hydraulic out 2200 psi, Bleed pressure, pick up & check RTTS - OK. Reset RTTS at 40' and tested f/above to 1000 psi. ND BOP stack. CO tubing spool and 9 5/8" pack-off & tested pack-off to 5000 psi. NU BOP stack. Continue to NU BOP's. RU & test lower pipe rams and flanges to 250 low/3500 high (leaking gland nuts - required some tightening), RD testing equipment. Install wear bushing. Retrieve storm packer (no pressure below packer) and LD all equipment. POOH 14 stands 5" drillpipe. PU and rack-back 53 stands of 5" drillpipe. PU and RIH w/90 joints of 5" drillpipe. Cut 105' of drilling line. POOH and rack-back 30 stands of 5" drillpipe. PJSM, RU Gyro Data and Sperry E-Line. PU and rack-back 5 stands of HWDP and 9 drill collars. PJSM, PU whipstock mill assembly. (NOTE: Pre-Spud meeting at tour change for new crew at 23:30 hours.) RIH w/whipstock to 2944' (2 min/stand). At 36' above EZSV, oriented the whipstock to 328.5 degrees w/#1 gyro. The #2 gyro tool malfunctioned and could not confirm whipstock orientation and was pulled out of the hole f/service. While work on #2 gyro, PU single joint of drillpipe and a 10' pup and tagged the top of the EZSV at 2980'. Both gyro's were then run to confirm the final whipstock orientation at 321 degrees. Anchor whipstock and shear off, displaced from seawater to the 9.1 ppg milling fluid. Milled window f/2958' t/2974' and drilled new hole to 2986' w/o problem (appeared to be some cement behind casing), 423 gpm, 480 psi, 100k rt wt, 11 Ok up, 95k dn, 1-2k tq, 70 rpm. Circulate, rotate and reciprocate f/2986 t/2958' 650 bbls @ 423 gpm, 480 psi, pump sweep and circulate clean. Pull t/2950' and perform FIT to 11.7 ppg EMW (20' of hole f/mid-window at 2966 to 2986'). POOH to BHA. LD BHAfmilling assembly. Pull wear ring & flush stack, set wear ring. PU BHA #2 to drill 8 1/2" hole. Complete MU of BHA #2, RIH on 5" drillpipe (1x1 f/59 jts out of pipe shed) to 2900'. Obtain slow pump rates, PWD baseline, run gyro. NOTE: PWD base-line calculations as follows: Printed: 6/13/2005 11: 1 0:39 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: U-06 U-06 REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 7ES Start: 4/26/2005 Rig Release: 6/8/2005 Rig Number: Spud Date: 6/11/1984 End: 5/11/2005 5/1/2005 03:00 - 04:30 1.50 DRILL P INT1 GPM RPM Actual Model Differential 500 100 9.56 ppg 9.85 ppg .29 ppg 600 100 9.58 ppg 9.90 ppg .32 ppg AVG .30 ppg Based upon the above data, .3 ppg will now be added to our "modeled" ECD values which will then represent our "clean-hole" ECD value. That "clean-hole" ECD value plus .6 ppg (per the well plan) now represent our PWD "hard-line" for path-forward 8 1/2" hole drilling operations. 04:30 - 05:00 0.50 DRILL P INT1 Ease through window to rat-hole TD at 2986' (no problems). 05:00 - 06:30 1.50 DRILL P INT1 Orient tool face w/gyro at 2986'. 06:30 - 08:00 1.50 DRILL P INT1 Drill f/2986' tl3193', 500 gpm, 1450 psi. 08:00 - 10:00 2.00 DRILL P INT1 Gyro survey(s) indicate well path 180 degrees off. 10:00 - 11 :00 1.00 DRILL P INT1 Run #2 gyro to confirm directional problem (confirmed problem - decision made to sidetrack well). 11 :00 - 13: 15 2.25 STKOH N DFAL INT1 Pump dry job, begin TOOH to check BHA, POOH to top of BHA. 13:15 - 15:30 2.25 STKOH N DFAL INT1 Handle BHAlchange out bit (picked up new MX-C1). 15:30 - 17:30 2.00 STKOH N DFAL INT1 TIH tl2909'. 17:30 - 17:45 0.25 STKOH N DFAL INT1 Circulate 71 bbls @ 500 gpm, 1370 psi. 17:45 - 18:00 0.25 STKOH N DFAL INT1 Ease through window to 3004' w/o pump (ok). 18:00 - 22:00 4.00 STKOH N DFAL INT1 Gyro survey to confirm tool-face orientation f/ sidetracking well - 4 good seats (330 deg.) with same reading on first tool Lead tattle-tail confirmed seat in UBHO. 2nd. tool gave same reading but on POH did not show mark on tattle-tail. Gyro Data hand bumped 2nd tool on wind wall standing it back damaging gyro mechanism. Re-ran 1 st tool to comfirm reading. There is no other backup tool in Alaska. 22:00 - 00:00 2.00 STKOH N DFAL INT1 Time drill for sidetrack f/2986' tl2989', 400 gpm, 925 psi, 11 Ok up, 110k dn. AST = 2.35 hrs ART = 0.30 hrs ADT = 2.65 hrs 5/2/2005 00:00 - 10:00 10.00 STKOH N DFAL INT1 Control/time drilling for open-hole sidetrack f/2989 tl3193', 400-500 gpm, 945-1500 psi. (Note: Gyro surveys poviding good data). 10:00 - 00:00 14.00 DRILL P INT1 Drill ahead in new 8 1/2" hole f/3193' tl4608', 4-5k tq on, 4k tq off, 544 gpm, 1640 psi, 145k up, 125k dn, 130k rt, 80 rpm. Actual ECD's staying within 0.4 ppg of calculated. Pumped sweeps @ 3,758' & 4,512'. ART = 4.16 hrs AST = 8.69 hrs ADT = 12.85 hrs 5/3/2005 00:00 - 04:30 4.50 DRILL P INT1 Drill ahead f/4608' tl4984', 15-20k wob, 1750 psi on, 1600 psi off, 4-5k tq on, 4k tq off, 145k up, 125k dn, 130k rt, 80 rpm, calc ECD - 9.9 ppg, act ECD - 10.1 ppg. 04:30 - 05:00 0.50 DRILL P INT1 Circulate and condition hole (pump 2+ X BU to include 25 bbl weighted sweep (11 + ppg)), 580 gpm, 2020 psi, 100 rpm, Printed: 6/13/2005 11: 1 0:39 AM legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: U-06 U-06 REENTER+COMPlETE NABORS ALASKA DRilLING I NABORS 7ES Start: 4/26/2005 Rig Release: 6/8/2005 Rig Number: Spud Date: 6/11/1984 End: 5/11/2005 5/3/2005 04:30 - 05:00 0.50 DRILL P INT1 ECD/PWD differential = <.1 ppg. 05:00 - 05:30 0.50 DRILL P INT1 POOH f/4984' t/4796' (pull tight and swab). 05:30 - 09:00 3.50 DRILL P INT1 Back-reamed out of hole f/4796' t/3193' (hole pulled tight thorought back-reaming process, over-pull was no more that 30k, torq 5-8k), 500 gpm, 80 rpm. From 3193', pumped out of hole w/o rotation to avoid BHA rotation within the window/whipstock. 09:00 - 09:30 0.50 DRILL P INT1 Pull bit above whipstock to @2900' and RIH 2 time to 3200' to insure our ability to get back into the "right" hole just outside the window (no problems/OK). 09:30 - 10:30 1.00 DRILL P INT1 Pumped a dry job, MAD pass logged the well f/3004' t/2718' (pull at 7'/min). 10:30 - 12:00 1.50 DRILL P INT1 Continue to POOH f/bit/BHA. 12:00 - 14:30 2.50 DRILL P INT1 Handle BHA, change out bit, down-load MWD. 14:30 - 15:00 0.50 DRILL P INT1 RIH t/2915'. 15:00 - 16:30 1.50 DRILL P INT1 Rig service - cut 730' of drilling line, service top drive & crown. 16:30 - 18:15 1.75 DRILL P INT1 RIH t/4905' 18:15 -18:45 0.50 DRILL P INT1 Circulated (1 full bottoms-up while rotating & reciprocating the drillpipe) f/4905' t/4984', staged pumps up to 540 gpm, 1270 psi, 60-100 rpm, 4k tq (no problems - ECD/PWD differential <.1 ppg - bottoms-up mud had slight increase in cuttings load), obtained SPR's. 18:45 - 00:00 5.25 DRILL P INT1 Drill ahead f/4984' t/5566', 165k up, 125k dn, 135k rt, 7k tq on, 6k tq off, 110 rpm. AST = .87 hrs ART = 4.63 hrs ADT = 5.5 hrs 5/4/2005 00:00 - 22:30 22.50 DRILL P INT1 Drilling f/5566' t/7740', 100 rpm, 545 gpm, 1850 psi on, 175k up, 130k dn, 150k rt, 8.5 tq on. 22:30 - 23:30 1.00 DRILL P INT1 Clean pump suctions to improve MWD signal. 23:30 - 00:00 0.50 DRILL P INT1 Drilling f/7740' t/7835', 205k up, 145k dn, 160k rt, 110 rpm, 10k tq on, 9k tq off, 550 gpm, 1715 psi off, 1980 psi on, calc ECD = 10.3 ppg, act ECD = 10.7-10.9 ppg. AST = 2.55 hrs / ART = 11.08 hrs / ADT = 13.63 hrs 5/5/2005 00:00 - 08:30 8.50 DRILL P INT1 Drill ahead f/7835 t/8420', 10-15k wob, 550 gpm, 2050/1850 psi on/off, 10/8.5k tq on/off, 215k up, 150k dn, 165k rt, 110 rpm, weighted mud system to 10.9 ppg. (Note: calc ECD = 10.3 ppg, act ECD = 10.7 ppg (prior to weight-up)) 08:30 - 00:00 15.50 DRILL P INT1 Control drill 1 OO'/hr f/8420' t/9531', 235k up, 155k dn, 175k rt, 120 rpm, 500 gpm, 1910 psi, 13k tq on, 11.5 tq off. Calculated ECD = 11.94 ppg. PWD ECD = 12.20 ppg AST = 1.62 hrs / ART = 14.38 hrs / ADT = 16.0 hrs 5/6/2005 00:00 - 00:00 24.00 DRILL P INT1 Drilling ahead f/9531, t/10,946', control drill at 100'/hr, 500 gpm, 2300/2100 psi on/off, 10-15k wob, 16/14.5k tq on/off, 260k up, 170k dn, 190k rt, 100 rpm, calc ECD = 11.9 ppg, act ECD = 11.9-12.1 ppg. AST=1.7hrs / ART=14.82hrs / ADT= 16.52 hrs Note: 2 - 290 bbl batches of new 10.9 ppg mud have been delivered f/the MI mud plant (since the "spike" weight-up addition at the top of the HRZ) to help maintain effective mud properties. The 1st batch was added at @21:00 hrs on 5/5, Printed: 6/13/2005 11:10:39 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: U-06 U-06 REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 7ES Start: 4/26/2005 Rig Release: 618/2005 Rig Number: Spud Date: 6/11/1984 End: 5/11/2005 5/6/2005 00:00 - 00:00 24.00 DRILL P INT1 2nd batch was addedat @21:00 hrs on 5/6. In both cases, 290 bbls of mud was removed from the active system prior to the addition of the new mud. A 3rd - 290 bblload is scheduled for delivery at 06:00 hrs on 5/7. 5/7/2005 00:00 - 10:00 10.00 DRILL P INT1 Drill ahead f/10,946' t/11,482', 100'/hr, 500 gpm, 2300/2120 psi on/off, 5/1 Ok wob, 15/12k tq on/off, 280k up, 180k dn, 200k rt, 100 rpm, calc ECD = 12.0 ppg, act ECD = 12.0 ppg. 10:00 - 10:30 0.50 DRILL N DFAL INT1 Lost pump 500 psi pressure, checked out surface system f/I eaks. 10:30 - 14:00 3.50 DRILL P INT1 POOH to window as wiper trip for interval TD and to locate a possible drillpipe washout, locate washout on stand #57 (6039'). Wash out was in tubular section 2' above pin. 14:00 - 14:30 0.50 DRILL N DFAL INT1 LD stand #57. 14:30 - 17:00 2.50 DRILL P INT1 Continue to POH to above window to service rig. (NOTE: POH very good, no hole problems.) 17:00 - 19:00 2.00 DRILL P INT1 Service top-drive, cut & slip 98' of drilling line. 19:00 - 21 :00 2.00 DRILL P INT1 RIH. Held up in original 8 1/2" hole at3193'. Work pipe 2 times with no success, pull above window. Screw in to top drive. RIH on top-drive with brake off to allow natural orientation, successfully got back into sidetracked hole and continued to RIH. 21 :00 - 23:15 2.25 DRILL P INT1 RIH with no problems to 6600' (bit just into top of Colville). 23:15 - 00:00 0.75 DRILL P INT1 Circulate well to break gels and to insure good mud in the annulus, circulated open-hole volume back to the window at 2974',400 gpm, 1280 psi, 50 rpm. (NOTE: Will circulate again at 8500' Uust above HRZ) prior to running to bottom to drill well to TD.) ART = 4.87 hrs / AST = 1.6 hrs / ADT = 6.47 hrs 518/2005 00:00 - 01 :30 1.50 DRILL P INT1 RIH f/6600' t/8550' and prepare to circulate well (staging into well to insure quality mud in annulus). 01 :30 - 02:00 0.50 INT1 Circulate well and condition mud at 8550', pumped 230 bbls mud while staging pumps up to 400 gpm. 02:00 - 03:30 1.50 DRILL P INT1 RIH to 11,367' and tagged fill, staged pumps to 500 gpm w/100 rpm while working pipe. Washed bit to bottom (11,482') at full drilling rate. Fill on bottom to include minor amounts of splintered shale. Also had some down-hole mud loss and screen blinding issues. 03:30 - 07:00 3.50 DRILL P INT1 Drill ahead f/11 ,482' t/11,535', 500 gpm, 2250 psi on, 98 rpm, 15k tq, 2k wob. Control drilled/circulated samples to confirm top of Sag River formation per Geologists. The interval was TD'ed 5' into the Sag. 07:00 - 09:00 2.00 DRILL P INT1 Circulate well and condition mud in preparation f/POOH. 09:00 - 14:30 5.50 DRILL P INT1 Monitored well, dropped ESS, pumped 5 stands out, pumped dry job, POOH to 3065' (ok). 14:30 - 15:30 1.00 DRILL P INT1 Ream out entrance to sidetracked hole w/ghost reamer, 140 rpm, 450 gpm, 1300 psi (f/2980' t/3065' w/reamer), pumped dry job for remainder of POOH. 15:30 - 17:00 1.50 DRILL P INT1 Continued POOH to HWDP. 17:00 - 19:30 2.50 DRILL P INT1 LD HWDP & BHA. 19:30 - 20:00 0.50 CASE P INT1 Remove wear bushing, install test plug. 20:00 - 22:00 2.00 CASE P INT1 Change upper ram to 7", test door seal to 3500 psi, remove Printed: 6/13/2005 11:10:39AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: U-06 U-06 REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 7ES Start: 4/26/2005 Rig Release: 6/8/2005 Rig Number: Spud Date: 6/11/1984 End: 5/11/2005 5/8/2005 20:00 - 22:00 2.00 CASE P INT1 test plug, intall wear bushing, RD associated equipment. 22:00 - 00:00 2.00 CASE P INT1 RU to run 7" liner. 5/9/2005 00:00 - 00:30 0.50 CASE P INT1 Begin to run 7" liner (26#, L-80, BTC-M), ran shoe joint, float joint and landing collar joint. Used Frank's tool to fill liner to check floats. Packing in wash pipe f/top-drive leaked at 100 psi. Decided to change-out packing. 00:30 - 03:45 3.25 CASE N RREP INT1 Change-out top-drive wash pipe packing. 03:45 - 06:30 2.75 CASE P INT1 Resume liner running from joint #3 and run in to 9 5/8" casing window. Fill every joint with fill up tool. 06:30 - 07:30 1.00 CASE P INT1 Circulate and condition mud at 5 bpm, 1 1/2 times bottoms up with 320 psi. Hole taking fluid - 30 bbllost. 07:30 - 09:30 2.00 CASE P INT1 Run casing into opent hole (hole taking 3 bbls/10 joiints). 09:30 - 10:30 1.00 CASE P INT1 Circulate down joints 100-104 (4197' to 4321 ') to move thick mud up hole and obtain a bottoms up. 10:30 - 11 :30 1.00 CASE P INT1 Run 7" to joint #127 (5274'). 11 :30 - 12:00 0.50 CASE P INT1 Circulate down 5 joints through the Ugnu formation on joints #127-131 to obtain a bottoms up. Circulate at 4 BPM. 12:00 - 14:00 2.00 CASE P INT1 Continue to run liner to joint #150. (6229') 14:00 - 14:45 0.75 CASE P INT1 Circulate down 5 joints through Schrader formation Uoints 150-154) at 4 bpm, 400 psi, 18 bblloss, 130 bbls circulated, 190k up, 128k dn. 14:45 - 17:15 2.50 CASE P INT1 Run liner to 8380'. 17:15 - 18:30 1.25 CASE P INT1 Circulate down 7 joints at 4 bpm, and wash to top of HRZ formation at 8642'. To obtain a bottoms up. Lost 68 bbl, 140 bbls circulated, 240k up, 145k dn. Lay down Frank's fill up tool. 18:30 - 18:45 0.25 CASE P INT1 Run liner to 8722', total 210 joints. 18:45 - 19:30 0.75 CASE P INT1 Lay down casing equip. Pick up liner hanger & RU to RIH w/5" drillpipe. 19:30 - 23:30 4.00 CASE P INT1 PU single & TIH - fill every 5 stands DP to stand #15 at 10,217'. Then circulate each stand down from there to bottom at 11,535',2-3 bpm, 750 psi, 140k dn. Tagged bottom and pulled up 2' w/liner shoe at 11,533' and top of liner PBR at 2783'. 23:30 - 00:00 0.50 CEMT P INT1 Stage up pumps/circulate liner at 2.5 bpm, 600 psi. Lost 307 bbls mud running liner and circulating. 5/10/2005 00:00 - 01 :00 1.00 STWHIP P LNR1 With liner 2' off bottom at 11,533', staged pumps to 6 bpm, OK. 01 :00 - 01 :30 0.50 STWHIP P LNR1 MU cementing head. 01 :30 - 02:00 0.50 STWHIP P LNR1 Circulate and condition mud. PJSM for cement job and liner set process. 02:00 - 03:30 1.50 STWHIP P LNR1 Pumped cement job per plan: 45 bbls 11.4 ppg mud push 252 bbls 12.0 ppg class 'G' Lead slurry 35 bbls 15.8 ppg class 'G' Tail slurry (good returns throughout) Sement in place at 04:45 hrs 03:30 - 05:00 1.50 STWHIP P LNR1 Displace cement w/rig pumps: 382 bbls 10.9 ppg mud (lost 17 bbls during displacement). 05:00 - 06:30 1.50 STWHIP P LNR1 Bump plug on calculated strokes and pressured to 1300 psi before pressure bled off. Pumped 1/2 the shoe track volume (1.6 bbls) with no pressure build up. Unable to set liner hanger. Decision made to mechanically set liner top packer. Rotated off liner and circulated 30 bbls mud to clear cement from above Printed: 6/13/2005 11:10:39 AM legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: U-06 U-06 REENTER+COMPlETE NABORS ALASKA DRilLING I NABORS 7ES Start: 4/26/2005 Rig Release: 6/8/2005 Rig Number: Spud Date: 6/11/1984 End: 5/11/2005 5/10/2005 05:00 - 06:30 1.50 STWHIP P LNR1 liner. Set back down on liner to set packer with weight (50K), repeat process while rotating to insure packer set. Circulate cement out of hole 4 bbls. cement at bottoms up. 06:30 - 08:00 1.50 STWHIP P LNR1 Displace mud from liner top to surface w/fresh water. Rig down casing running equipment. 08:00 - 10:00 2.00 STWHIP P SURE Monitor well. POH and UD 5" drill pipe and Baker running tools. 10:00 - 16:30 6.50 STWHIP P SURE RIH w/ 5" drill pipe in derrick to 2700' POH and UD drill pipe. 16:30 - 17:15 0.75 STWHIP P SURE Pressure test 7" liner, liner top packer and 9-5/8" casing to surface. Hold 1500 psi for 30 min. 17:15 - 21 :00 3.75 STWHIP P SURE Continue UD drill pipe from derrick. 21 :00 - 21 :30 0.50 BOPSU P SURE Pull wear bushing and install test plug. 21 :30 - 23:00 1.50 BOPSU P SURE Change upper rams to 3.5" x 6" variable and test door seal to 3500 psi. Pull test plug. 23:00 - 00:00 1.00 DUMRN P SURE Attempt dummy run w/tubing hanger. Can not get hanger through BOP stack. 5/11/2005 00:00 - 06:00 6.00 STWHIP N DPRB SURE Continue w/attempt to make dummy run w/tubing hanger. Can not get hanger through BOP stack. Appears to hang up at ring at top of Hydril. Use top drive to attempt to push through. S/O 20k Ibs. Will not go. Ran test plug and it lands wIno problem. Cleaned rubber out of BOP. No visible obstruction. Tubing hanger OD 12-3/8", test plug OD 12-1/4". 06:00 - 08:30 2.50 STWHIP P SURE Made several attempts to make dummy run w/original redressed tubing hanger. Cameron acquiring new style hanger and pups as backup if old unit wil not land. TIH w/66 jts 4-1/2" NSCT tubing to 2740'. Land original hanger, w/some difficulty getting through Hydril. Run in lock down screws. 08:30 - 09:00 0.50 DEMOB P SURE RIH w/two way check valve and pressure test to 1000 psi from below. 09:00 - 16:00 7.00 DEMOB P SURE ND BOP and NU tree. Tested tree, tubing hanger and adaptor flange to 5000 psi. Side valve on tree leaking, capped w/plug and needle valve. Master valve functioning improperly. RU drill site maintenance and pull two way check valve. 16:00 - 18:15 2.25 DEMOB P SURE RU hot oil company and reverse circulate 160 bbls diesel to inner annulus. Hook up hose and allow diesel to U-tube annulus to tubing and equalize. 18:15 - 19:30 1.25 DEMOB P SURE Install back pressure valve and test to 1000 psi. 19:30 - 22:00 2.50 DEMOB P SURE Clear floor, clean cellar, secure well. Cut and slip drill line. Release rig for move to S-pad at 22:00. 5/20/2005 05:00 - 18:00 13.00 MOB P PRE Move camp & mud pits from Niakuk well # 65A to U-pad well # 06B. 18:00 - 00:00 6.00 MOB P PRE Move sub base from Niakuk well # 65A to U-pad well # 06B. 5/21/2005 00:00 - 12:00 12.00 MOB P PRE Lay derrick down, move sub base from Niakuk well # 65A to U-Pad well # 06B. 12:00 - 18:00 6.00 MOB P PRE Spot sub over well # U-06. 18:00 - 22:00 4.00 RIGU P PRE Raise & pin derrick. Raise & pin chute to pipe shed. Bridle down & tie back lines. R/U floor. 22:00 - 00:00 2.00 RIGU P PRE Rig up truck lost drive line while spotting mud pits, repair truck in the field. 5/22/2005 00:00 - 02:00 2.00 MOB P PRE RIU, hook up lines between pits & sub base. Prep. pits to take on fresh water. 02:00 - 02:30 0.50 WHSUR P DECOMP Accept rig @ 0200 hrs. 5/22/2005. Hold pre-spud meeting with drill crew & MWD hand. Printed: 6/13/2005 11:10:39 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: U-06 U-06 REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 7ES Start: 4/26/2005 Rig Release: 6/8/2005 Rig Number: Spud Date: 6/11/1984 End: 5/11/2005 5/22/2005 02:30 - 03:00 0.50 WHSUR P DECOMP Take on fresh water to pits. Hook up secondary annulus valve. 03:00 - 04:00 1.00 FISH P DECOMP R/U drill site maint lubricator & pull BPV. 04:00 - 06:30 2.50 WHSUR P DECOMP Pump soap pill & displace diesel from kill string with fresh water @ 2740'. Pump @ 10 bpm @ 1100 psi. Tubing & annular pressure = O. 06:30 - 07:30 1.00 WHSUR P DECOMP Install TWC valve, test from below to 1000 psi, blow down lines. 07:30 - 09:30 2.00 WHSUR P DECOMP Nipple down tree & adaptor flange, verify tubing hanger lifting threads are 4.5" BTC. 09:30 - 11 :30 2.00 WHSUR P DECOMP Nipple up 135/8" x 5000 psi BOPE. 11 :30 - 18:30 7.00 WHSUR P DECOMP R/U & test BOPE, 250 psi low test & 3500 psi high test. Annular preventor tested to 250/2500, blow down lines. Test witnessed by WSL & AOGCC rep. Chuck Schevie. 18:30 - 19:30 1.00 WHSUR P DECOMP P/U lubricator & extension, pull TWC valve, R/D. 19:30 - 20:00 0.50 PULL P DECOMP M/U landing joint, screw into hanger, BOLDS, pull hanger/tubing to rig floor. 20:00 - 20:30 0.50 PULL P DECOMP R/U to UD tubing. Break & UD hanger & landing joint. 20:30 - 23:00 2.50 PULL P DECOMP POH UD 4.5", NSCT, L-80, tubing/kill string. R/D casing tools & clear rig floor. 23:00 - 23:30 0.50 PULL P DECOMP Test 7" casing to 3500 psi for 30 min. OK. 23:30 - 00:00 0.50 PULL P DECOMP M/U test joint & dart valve, prepare to test bottom rams & dart valve. 5/23/2005 00:00 - 01 :00 1.00 BOPSU P DECOMP Test dart valve & lower pipe rams to 250 psi low & 3500 psi high. Test witnessed by WSL James Willingham. 01 :00 - 01 :30 0.50 BOPSU P DECOMP Install wear ring. 01 :30 - 04:00 2.50 DRILL P PROD1 M/U BHA, P/U tri-cone bit & directional drilling assy. Orient, upload MWD tools, shallow test MWD tools @ 250 gpm @ 950 psi. 04:00 - 06:30 2.50 DRILL P PROD1 RIH P/U drill pipe from 454' to 3277'. Fill pipe, pipe took proper fill of 28 bbl. Good flow for 2 min then string plugged. 06:30 - 07:30 1.00 DRILL N DPRB PROD1 POH slow from 3277' to 2642' wet. 07:30 - 08:30 1.00 DRILL N DPRB PROD1 Trapped air & mud overflowing drill pipe, bleed air from pipe. 08:30 - 09:30 1.00 DRILL N DPRB PROD1 POH from 2624' to 454'. 09:30 - 10:30 1.00 DRILL N DPRB PROD1 Check MWD tools for debris/obstructions, OK. Pump to clear tools @ 250 gpm @ 950 psi. Stand back MWD tools & motor. 10:30 - 11 :00 0.50 DRILL N DPRB PROD1 M/U mule shoe, flex collars, HWDP & jars, pump down string, OK. 11 :00 - 12:00 1.00 DRILL N DPRB PROD1 RIH with drill pipe from 376' to 3198'. Pump through string, OK. 12:00 - 14:00 2.00 DRILL N DPRB PROD1 POH with mule shoe, rack back HWPD & collars, UD mule shoe. 14:00 - 14:30 0.50 DRILL N DPRB PROD1 M/U tri-cone bit, motor, MWD, collars & jars. Pulse check. 14:30 - 15:30 1.00 DRILL N DPRB PROD1 RIH to 2774'. 15:30 - 16:00 0.50 DRILL N DPRB PROD1 Circ drill pipe volume. 16:00 - 19:00 3.00 DRILL P PROD1 RIH P/U drill pipe to 7385', fill pipe @ 930' intervals. 19:00 - 20:00 1.00 DRILL P PROD1 CBU @ 250 gpm @ 1600 psi. 20:00 - 23:00 3.00 DRILL P PROD1 RIH from 7385' to 10873', tag cement 595' high, plugged bit, pressure up & unplug. Circulate, 1 jet still plugged. 23:00 - 00:00 1.00 DRILL P PROD1 POH & rack back 16 stands of pipe to drill with, RIH P/U pipe to reach bottom. 5/24/2005 00:00 - 01 :00 1.00 DRILL P PROD1 POH from 9906' to 9128', Rack back drill pipe to drill with, break eire, pump @ 250 gpm @ 2000 psi. 01 :00 - 02:00 1.00 DRILL P PROD1 Service top drive, check dwks brakes, lube rig. 02:00 - 03:30 1.50 DRILL P PROD1 RIH P/U drill pipe to 10842'. Install blower hose. Printed: 6/13/2005 11:10:39 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: U-06 U-06 REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 7ES Start: 4/26/2005 Rig Release: 6/8/2005 Rig Number: Spud Date: 6/11/1984 End: 5/11/2005 5/24/2005 03:30 - 07:00 3.50 DRILL P PROD1 Tag plug @! 10873'. Drill hard cement and Float eqip to 11530' WOB = 20, RPM = 40, pump @ 265 gpm @ 2150 psi. TO off 9K, TO on 10K. 07:00 - 09:00 2.00 DRILL P PROD1 Displace well with 8.4 ppg Flo-Pro mud - 270 gpm @ 1800 spi. Pumped 100 bbls water, 50 bbl mud spacer ahead. 09:00 - 09:30 0.50 DRILL P PROD1 SPR. Drlg out shoe and 22' new formation to 11557'. 09:30 - 10:30 1.00 DRILL P PROD1 Circ and cond mud. Pertormed FIT to 9.4 ppg EMW - 8.4 ppg mud / 460 psi surtace press. Witnessed by John Rail. 10:30 - 22:30 12.00 DRILL P PROD1 Drlg f/11557' to 11812'. Motor / bit not yielding reqired dog leg to land.PU 185, SO 145, TO 4.5K, 274 gpm - 2000 psi. ART 1.97 hrs. AST 9.05 hrs. 22:30 - 23:30 1.00 DRILL P PROD1 CBU for trip out. Flow check. 23:30 - 00:00 0.50 DRILL P PROD1 POOH for BHA change. POOH to 7" shoe - drop dart and open circ sub - slug DP. 5/25/2005 00:00 - 04:00 4.00 DRILL P PROD1 POOH to BHA. 04:00 - 04:30 0.50 DRILL P PROD1 PJSM. Pull BHA. Break bit. 04:30 - 05:30 1.00 DRILL P PROD1 Down load LWD's.Adjust motror to 1.83 deg. Make up new bit. CO cjrc sub. Orient. 05:30 - 06:00 0.50 DRILL P PROD1 Wait on orders. 06:00 - 06:30 0.50 DRILL P PROD1 RIH w/BHA. Shallow test MWD tools. 06:30 - 07:30 1.00 DRILL P PROD1 RIH to 3276'. Fill pipe. 07:30 - 08:30 1.00 DRILL P PROD1 Service top drive. Lubricate rig. 08:30 - 09:30 1.00 DRILL P PROD1 RIH P/U DP f/3276' to 4210'. 09:30 - 12:00 2.50 DRILL P PROD1 RIH to 9626'. Break circ every 3,000'. 12:00 - 13:00 1.00 DRILL P PROD1 Slip and cut drlg line. 13:00 - 14:00 1.00 DRILL P PROD1 RIH f/9626' to btm @ 11,812'. No problems. 14:00 - 00:00 10.00 DRILL P PROD1 Drill f/11812' to 12,094'. AST = 5.12, ART = 1.66. UP 185k, Dwn 140K, ROT 166K. TO off 5-6K, TO on 6.5 -7.5K. 280 gpm - 2,000 psi. 5/26/2005 00:00 - 00:00 24.00 DRILL P PROD1 Drill from 12094' to 12802'. TVD 8,975'. 282 gpm- 2150 psi. TO on 10K, TO off 8K, UP 190K, DWN 130K, ROT 160K. AST 10.45 hrs, ART 7.46 hrs. 5/27/2005 00:00 - 05:30 5.50 DRILL P PROD1 Drill from 12802' to 13,035'. UP 185K, DWN 130K, ROT 160K. TO on 9500, TO off 8000. Pump 280 gpm- 2150 psi. AST .9, ART 2.96 05:30 - 06:00 0.50 DRILL P PROD1 Pump sweep into csg shoe @ 13035'.275 gpm @ 2100 psi. Monitor well. Static. B/D TD. 06:00 - 07:00 1.00 DRILL P PROD1 POOH f/13035' to 11535'. No problems. 07:00 - 07:30 0.50 DRILL P PROD1 Drop dart. Open circ sub@ 11535'. CBU @ 13 BPM. 07:30 - 11 :00 3.50 DRILL P PROD1 POOH f/11535' to 454'. 11 :00 - 12:30 1.50 DRILL P PROD1 STD back BHA. Down load MWD. LD circ sub, MWD. Break bit and LD motor. 12:30 - 13:30 1.00 DRILL P PROD1 MU PDC bit / 5" motor 1.5 deg, PU MWD, orient, load MWD. RIH w/BHA and shallow test. 13:30 - 15:00 1.50 DRILL P PROD1 RIH f/550' to 3277'. Break circ. 15:00 - 17:30 2.50 DRILL P PROD1 PU 4" DP f/3277' to 6357'. 17:30 - 19:00 1.50 DRILL P PROD1 RIH f/11535' to 13035', 19:00 - 20:00 1.00 DRILL P PROD1 Lub rig. Service TD. Install blower hose. 20:00 - 20:30 0.50 DRILL P PROD1 RIH f/11535' to 12990'. SPR's. Wash to btm @ 13035'. No fill. No problems. 20:30 - 00:00 3.50 DRILL P PROD1 Drill f/13035' to 13313'. AST 0 hrs, ART 2.38 hrs. UP 195K, DN 120K, RT 160K. TO off 11K , TO on 12K. 280 gpm - 2100 psi. Printed: 6/13/2005 11: 1 0:39 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: U-06 U-06 REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 7ES Start: 4/26/2005 Rig Release: 6/8/2005 Rig Number: Spud Date: 6/11/1984 End: 5/11/2005 5/28/2005 00:00 - 06:30 6.50 DRILL P PROD1 Drill f/13315' to 13,492'. Hard sliding f/13,435' - 13,490'. Wall sticking. AST 1.03 ART 1.62 UP 195 DN 125 ROT 160300 gpm 2500 psi TO off 11 k ON 12K 06:30 - 07:00 0.50 DRILL P PROD1 Circ sweep out of open hole - 330 gpm 2200 psi. 07:00 - 08:00 1.00 DRILL P PROD1 POOH f/13492' to 11492'. No problems. 08:00 - 09:00 1.00 DRILL P PROD1 Drop dart - open circ sub - CBU @ 500gpm2000 psi. 09:00 - 12:30 3.50 DRILL P PROD1 POOH f/11492' to 454'. 12:30 - 13:00 0.50 DRILL P PROD1 PJSM. Stand back BHA to 79'. 13:00 - 14:00 1.00 DRILL P PROD1 Downlload MWD tools. Remove pulser. LD BHA. 14:00 - 15:30 1.50 DRILL P PROD1 PU 4.75" motor 1.83 deg, 6 1/8" MX-18Dx bit, MWD / Lwd. Orient tools. Upload tools. RIH w/ BHA. Shallow test tools - 250 gpm 850 psi. 15:30 - 19:00 3.50 DRILL P PROD1 RIH to 11535'. Fill pipe every 3000'. 19:00 - 20:00 1.00 DRILL P PROD1 Cut drilling line. 20:00 - 20:30 0.50 DRILL P PROD1 Lubricate rig. Service TD. 20:30 - 21 :30 1.00 DRILL P PROD1 RIH to 13462'. Wash 30' to Bottom. No problems. Survey / SPR's. 21 :30 - 00:00 2.50 DRILL P PROD1 Drill f/13492' to 13608'. AST 1.33 hrs, ART .55 hrs, UP 194K DN 125K RT 160K. TO off 7K. TO on 9K. Pump 280 gpm 2130 psi. 5/29/2005 00:00 - 00:00 24.00 DRILL P PROD1 Drill from 13608' to 14574'. ART 13.70 hr, AST 3.81 hrs.UP 190K, DN 120K, RT 155k. TO OFF 7k, ON 9-10K. 280 gpm- 2300 psi 5/30/2005 00:00 - 19:30 19.50 DRILL P PROD1 Drill from 14574' t015229'. AST 9.74, ART 8.02 hrs.UP 190, DN 120, ROT 155, TO off 8K, TO on 10K. Pump 280 gpm @ 2225 / 2330 psi. RPM 50. Fault @ 15007' - 20bbl initial loss. Fault zone from 15007' to 15080'. Lossing 140 bph drilling /40 bph static @ 15048'. Pumped 30 bbl LCM pills while drilling. 19:30 - 20:00 0.50 DRILL P PROD1 Spot 50 bbl pill w/ 30 #/ bbls LCM ( safe carb/ mix 11) on bottom. Static losses 42 bph. 20:00 - 21 :30 1.50 DRILL N DPRB PROD1 POOH f/15229' to 11800'. Hole taking 50 bbl/hr. 21 :30 - 22:00 0.50 DRILL N DPRB PROD1 Open circ sub @ 11628'. 22:00 - 23:00 1.00 DRILL N DPRB PROD1 Spot 50 bbl pill w/ 80#/bbl LCM ( safe carb/ mix 11) from 11628' -10330'. POOH to 11,535'. 23:00 - 23:30 0.50 DRILL N DPRB PROD1 Monitor well for 30 min. Static loss rate 52 BPH. 23:30 - 00:00 0.50 DRILL N DPRB PROD1 POOH f/11535' to 10558'. Loss rate 50 - 60 BPH. Total estimated mud loss last 24 hrs - 1358 bbls. 5/31/2005 00:00 - 02:30 2.50 DRILL N DPRB PROD1 POOH f/10558'-5142' . Losses 60 bbls/hr. No decrease in loss rate w/ 80 #/bbl LCM pill on Bottom. 02:30 - 05:00 2.50 DRILL N DPRB PROD1 RIH to 11,492 to spot LCM pill. Losses 50 bbl/hr mud. Lost 311 bbls in last 5 hrs. 05:00 - 06:00 1.00 DRILL N DPRB PROD1 Spotted 50 bbl LCM Pill 80#/bbl LCM ( 40# Mix I 1/40# safe carb) f/11 ,492 to 10,100'. Losses 90 bph While Pumping. 06:00 - 06:30 0.50 DRILL N DPRB PROD1 POOH f/11 ,492' - 10,000'. 06:30 - 07:30 1.00 DRILL N DPRB PROD1 Monitored well - Static Losses 60 bph. 07:30 - 08:00 0.50 DRILL N DPRB PROD1 RIH f/10,000' -11,492'. 08:00 - 09:30 1.50 DRILL N DPRB PROD1 Mixed and Pumped 50 bbl, 60 ppb LCM Pill - Safecarb / Mix I I. 09:30 - 13:30 4.00 DRILL N DPRB PROD1 POOH f/11 ,492' to 454'. Loss Rate 28 bph. 13:30 - 16:30 3.00 DRILL N DPRB PROD1 PJSM. L / D HWDP, NMDC, Jars. Flushed Tools. Downloaded LWD's. L / D BHA. Cleared Floor. Static Loss Rate 26 bph. 16:30 - 23:00 6.50 LCR N DPRB RUNCMP M / U Mule Shoe Sub on 4" DP. RIH to 14,500'. Filled DP Every 3,000'. Loss Rate 24 bph. Replaced Hydrolic on TD 13,938' Printed: 6/13/2005 11:10:39 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: U-06 U-06 REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 7ES Start: 4/26/2005 Rig Release: 6/8/2005 Rig Number: Spud Date: 6/11/1984 End: 5/11/2005 5/31/2005 23:00 - 00:00 1.00 LCR N DPRB RUNCMP Washed Down w/ Mule Shoe f/14,500' - 14,685'. Pump Rate 250 gpm - 1300 psi. Losses 80 bph. Total loss past 24 hrs 1013 bbls. 6/1/2005 00:00 - 00:30 0.50 LCR N DPRB RUNCMP Washed Down to 14,900' w/ Mule Shoe Sub, No problems. Losses 80 bph Pumping, Pump Rate 250 gpm, 1,250 psi. 00:30 - 02:30 2.00 LCR N DPRB RUNCMP Circulated Bottoms Up to Clean Up Well bore, Losses 70-80 bbls/hr. 02:30 - 03:00 0.50 LCR N DPRB RUNCMP Pumped and Spotted 38 bbl 87ppb LCM Pill to Mule Shoe at 14,900'. Closed Annular. 03:00 - 04:00 1.00 LCR N DPRB RUNCMP Pumped and Squeezed 23 bbls of LCM Pill into Wellbore at 14,900'. Squeeze Rate 0.5 to 0.25 bbl/ min. Final Pressure 375 psi. Shut Down Pump, Pressure Bled Off to 350 psi in 1 min. 04:00 - 06:00 2.00 LCR N DPRB RUNCMP Bled Off Pressure, Opened Annular, P / U to 14,850'. Circulated Bottoms Up, 250 gpm, 1,225 psi. Monitored Well for Losses - 20 bbls / hr. 06:00 - 07:00 1.00 LCR N DPRB RUNCMP Shut Down Pump, Circulated Over Top of Wellbore, Monitored Well, Static Losses 5 - 6 bph. 07:00 - 10:00 3.00 LCR N DPRB RUNCMP Continued to Circulate Bottoms Up. . Pump Rate 250 gprn, 1,250 psi, Losses 20 bph. 10:00 - 10:30 0.50 LCR N DPRB RUNCMP Pumped and Spotted 30 bbl - 80 ppb LCM Pill to Mule Shoe at 14,900'. Pump Rate 250 gpm, 1,250 psi. Parameters: String Weight Up 190,000#, String Weight Down 120,000#, String Weight Rotating 150,000#. 10:30 - 12:00 1.50 LCR N DPRB RUNCMP Closed Annular, Pumped and Squeezed 21 bbls of LCM Pill into Wellbore at 14,900'. Squeeze Rate as Follows: Total Pumped Rate Pressure 1.16 bbls 0.29 bpm 350 psi 4.65 bbls 0.29 bpm 388 psi 4.77 bbls 0.29 bpm 390 psi - Shut Dwn 2 Minutes 200 psi 6.99 bbls 0.29 bpm 356 psi 7.22 bbls 0.29 bpm 390 psi - Shut Dwn 2 Minutes 130 psi 9.30 bbls 0.23 bpm 383 psi 9.73 bbls 0.23 bpm 390 psi - Shut Dwn 2 Minutes 120 psi 10.49 bbls 0.23 bpm 315 psi 15.15 bbls 0.23 bpm 342 psi 21.00 bbls 0.23 bpm 375 psi - Shut Dwn 5 Minutes 360 psi Bled Down Pressure, Opened Annulus 12:00 - 13:30 1.50 LCR N DPRB RUNCMP Spotted Remaining LCM Pill in Wellbore. P / U to 14,850', 35,000# Overpull to Move Drill String. Circulated Bottoms Up, Pump Rate 250 gpm, 1,300 psi. Losses While Pumping 22 bph. 13:30 - 14:30 1.00 LCR N DPRB RUNCMP Shut Down Pump, Circulated Over Top of Wellbore, Monitored Well, Static Losses 9 bph. 14:30 - 16:00 1.50 LCR N DPRB RUNCMP Continued to Circulate Bottoms Up While Mixing 30 bbl 80 ppb LCM Pill, Pump Rate 250 gpm, 1,250 psi, Losses 25 bph. 16:00 - 17:30 1.50 LCR N DPRB RUNCMP Circ and condition mud @ 14875'.300 GPM @ 1470 psi. Loss rate 30 BPH. 17:30 - 00:00 6.50 LCR N DPRB RUNCMP Wash down f/14875' to 14980'. No problems. Circ and Printed: 6/13/2005 11: 1 0:39 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: U-06 U-06 REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 7ES Start: 4/26/2005 Rig Release: 6/8/2005 Rig Number: Spud Date: 6/11/1984 End: 5/11/2005 6/1/2005 17:30 - 00:00 6.50 LCR N DPRB RUNCMP condition mud @ 14980'.200 GPM @ 1180 psi. Loss rate 20 BPH. Screen shakers up to 250's and continue to clean up mud. Wait on Dowell to spot cement plug. Static loss rate 4 BPH. 6/2/2005 00:00 - 02:00 2.00 LCR N OPRB RUNCMP Circ and condition mud to spot cement plug. 150 gpm @ 1050 psi. 16 BPH loss rate. 02:00 - 03:00 1.00 LCR N DPRB RUNCMP Circ and condition mud - PJSM - Batch mix cement. MU head pin to spot cement plug. 03:00 - 03:30 0.50 LCR N DPRB RUNCMP Switched to Dowell. Pressure Tested Lines to 2,100 psi, OK. Pumped 15 bbls Water at 4.0 bpm, 1,095 psi, 20 bbls 15.8 ppg Class G Cement w/ 0.300 %bwoc Dispersant, 0.250 %bwoc Retarder, 2.000 gal/sk GASBLOK, 0.200 gal/sk Antifoam, 2.0 # I bbl cem-net and 0.250 # / bbl celloflake, Cement Pump Rate 4.0 bpm, 1,075 psi. Displaced Cement Plug w/7.5 bbls Water Pump Rate 4.5 bpm, 450 psi. Switched to Rig Pump, Pumped and Displaced Balanced Cement Plut w/136 bbls mud, Pump Rate 4.75 bpm, 750 psi. Balanced Cement Plug Set f/14,980' to 14,430' (550'). Losses to Well bore While Spotting Cement Plug, 2 bbls. 03:30 - 04:00 0.50 LCR N DPRB RUNCMP Pulled Out of Cement Slowly to 14,330'. 04:00 - 04:30 0.50 LCR N DPRB RUNCMP Pumped 20 bbls to Flush DP, Pump Rate 100 gpm, 500 psi. 04:30 - 05:30 1.00 LCR N DPRB RUNCMP POOH to 7" Liner Shoe at 11 ,533' . 05:30 - 12:00 6.50 LCR N DPRB RUNCMP Monitored Well For Losses. 0600 hrs - 0700 hrs - 4.00 bbls 0700 hrs - 0800 hrs - 4.50 bbls 0800 hrs - 0900 hrs - 4.00 bbls 0900 hrs - 1000 hrs - 4.25 bbls 1000 hrs - 1100 hrs - 4.00 bbls 1100 hrs - 1200 hrs - 4.00 bbls 12:00 - 16:30 4.50 LCR N DPRB RUNCMP POOH w/4" DP. LD Mule Shoe Sub. Loss Rate 6 BPH. 16:30 - 17:00 0.50 LCR N DPRB RUNCMP PJSM. M / U Clean Out BHA. - 6 1/8" Bit, B.S, 2 Jts 3.5" HWDP, Jars, 3Jts 3.5" HWDP. 17:00 - 22:00 5.00 LCR N DPRB RUNCMP RIH slow to 11,535'. Fill DP every 3,000'. Loss rate 10 BPH. 22:00 - 23:00 1.00 LCR N DPRB RUNCMP CBU @ 11,535'.200 gpm -1080 psi. Loss Rate 10 BPH. UP 215K, ON 125K, RT 160k, RPM 80, TO 11.5k 23:00 - 00:00 1.00 LCR N DPRB RUNCMP RIH f/11 ,535' to 14,311'. No Problems. UP 240K ON 110K Pumps Off. 6/3/2005 00:00 - 01 :00 1.00 CONDH DPRB RUNPRD Washed f/14,311' to 14,385'. Reamed Down f/14,385' to 14,423' w/ 5k- 15K WOB. Set 25k on Bit Without Rotating @ 14,423' - Weight Did Not Pump Off. 01 :00 - 03:00 2.00 CONDH P RUNPRD Circulated and Conditioned Mud to Run 4.5" Liner. 200 gpm- 1,400 psi. Rotated 80 RPM. Loss rate 12 bph. TO 16k , UP 240k, DW 130K 03:00 - 05:00 2.00 CASE P RUNPRD POOH from 14,423' to 11,500'. String Weight Up 275K. Loss rate 4 bph. 05:00 - 05:30 0.50 CASE P RUN PRO Pumped and Spotted 108 bbl Liner Running Pill at 7" shoe, 11,533', Pump Rate 200 gpm, 1,350 psi. Pumped Slug and Dropped Rabbit. 05:30 - 10:00 4.50 CASE P RUNPRD POOH w/4" DP to 200'. 10:00 - 10:30 0.50 CASE P RUNPRD POOH, B / 0 and L / D Clean Out BHA. Cleared and Cleaned Rig Floor. 10:30 - 11 :00 0.50 CASE P RUNPRD Held PJSM w/ Rig Crew, Baker Rep, Casing Hand, Toolpusher and Drilling Supervisor. R / U 4-1/2" Liner Handling Equipment. Printed: 6/13/2005 11:10:39 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: U-06 U-06 REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 7ES Start: 4/26/2005 Rig Release: 6/8/2005 Rig Number: Spud Date: 6/11/1984 End: 5/11/2005 M / U 4-1/2" Liner Float Equipment and Joints. Average M / U Torque 3,950 ft /Ibs. Bakerlocked First 3 Connections. Filled Liner and Checked Floats, OK. M / U and RIH w/71 Joints 4-1/2" 12.6# L-80 IBT Liner w/ Float Shoe, Float Collar and Landing Collar. Average M / U Torque 3,950 ft /Ibs. Filled Liner Every 5 Joints. C/O Handling Tools. M / U 7" x 5" HMC Liner Hanger w/7" x 5" ZXP Packer. M / U 1 Stand 4" DP to 3,151'. Circ Liner Volume x 2, 5 BPM, 200 psi. 65K Up & Down. RIH w/4.5" Liner on 4" DP f/3, 151' to 11,512' - 90 see / std. Filled Every 20 Stds. Loss Rate 10 bph. M / U Cementing Head to DP Pup. L / D Two Singles. Pumped DP and Liner Volume - 3 BPM, 730 psi. Loss Rate 18 bph. UP 220K, DWN 125K. RIH w/4.5" liner on 4" DP f/11 ,512' to 12,073', 2 min / std. Loss Rate 10 bph. No problems. RIH w/4-1/2" Liner on DP to 14,405'. M / U Cementing Head / Manifold and DP Single. Filled Pipe and Broke Circulation, 2 bpm. P / U on Drill String, 80,000# Overpull, Slacked Off and Stacked Out 40,000# on Liner, Could not Move Liner. RUNPRD Circulated Bottoms Up, Staged Up Pumps to 5 bpm, 1,260 psi. Loss Rate 30 bph. Held PJSM w/ Rig Crew, Dowell Crew, Baker Rep, Mud Engr, Truck Drivers, Toolpusher and Drilling Supervisor. RUNPRD Continued to Circulate While Dowell Batch Mixed Cement and Spacer. 5 bpm, 1,260 psi, Loss Rate 30 bph. RUNPRD Switched Over to Dowell. Pumped 5 bbls of Water at 3 bpm, 500 psi. Shut in Cement Manifold and Tested Lines to 4,500 psi., OK. Pumped 10 bbls of 8.3 ppg CW, Pump Rate 5.00 bpm, 1,250 psi. Pumped 25 bbls 9.6 ppg Mud Push Pump Rate 5 bpm, 1,200 psi. Pumped 130 bbls (625 sks) 15.8 ppg Premium Class G Cement w/2.00 gall sk GASBLOK, 0.420 %bwoc Dispersant, 0.170 %bwoc Retarder, 0.200 gal/ sk Antifoam. Pumped Cement at the Following Rates: Pumped Rate Pressure 25.0 bbls 4.90 bpm 1,423 psi 50.0 bbls 4.90 bpm 1,550 psi 75.0 bbls 5.00 bpm 1,015 psi 100.0 bbls 5.00 bpm 1,020 psi 125.0 bbls 5.00 bpm 1,045 psi 130.0 bbls 5.00 bpm 1,040 psi Opened Floor Valve and Washed Up Lines Behind Drill Pipe Dart Dropped and Pumped Drill Pipe Dart w/ 5.0 bbls Water 5 bpm, 300 psi Displaced Cement w/45 bbl Perf Pill and 112 bbls of Mud at the Following Rates: Pumped Rate Pressure 25.0 bbls 6.50 bpm 485 psi 50.0 bbls 6.50 bpm 475 psi 60.0 bbls 5.00 bpm 875 psi 80.0 bbls 5.00 bpm 1,360 psi 6/3/2005 11 :00 - 12:00 1.00 CASE P RUNPRD 12:00 - 16:30 4.50 CASE P RUNPRD 16:30 - 17:00 0.50 CASE P RUNPRD 17:00 - 17:30 0.50 CASE P RUNPRD 17:30 - 22:30 5.00 CASE P RUNPRD 22:30 - 23:30 1.00 CASE P RUNPRD 23:30 - 00:00 0.50 CASE P RUNPRD 6/4/2005 00:00 - 01 :30 1.50 CASE P RUNPRD 01 :30 - 02:00 0.50 CASE P RUNPRD 02:00 - 03:00 1.00 CASE P 03:00 - 04:00 1.00 CASE P 04:00 - 05:30 1.50 CEMT P Printed: 6/13/2005 11: 1 0:39 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: U-06 U-06 REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 7ES Start: 4/26/2005 Rig Release: 6/8/2005 Rig Number: Spud Date: 6/11/1984 End: 5/11/2005 6/4/2005 04:00 - 05:30 1.50 CEMT P RUNPRD 100.0 bbls 5.00 bpm 1,950 psi Slowed Pump Rate Rate 105.0 bbls 2.00 bpm 1,400 psi 114.0 bbls 2.00 bpm 1 ,400 psi Observed DP Dart Latch Up and Shear Wiper Plug. Pressure Increased to 2,700 psi, Sheared Wiper Plug, Decreased to 1,400 psi Increased Pump Rate 120.0 bbls 4.00 bpm 2,000 psi 140.0 bbls 4.00 bpm 2,200 psi 155.0 bbls 2.00 bpm 1,930 psi Wiper Plug Bumped w/160.0 bbls Total Displacement Pumped. Pressured up to 3,500 psi to Set Liner Hanger. Held Pressure f/ 5 Minutes, Bled Down Pressure and Checked Floats, Floats Held. Cement in place at 0530 hrs. 05:30 - 06:00 0.50 CEMT P RUNPRD Pressured Up to 4,500 psi to Activate Pusher Tool to Set ZXP Packer. Observed Good Surface Indication of Packer Setting. Bled Down Pressure, Applied 12 Right Hand Turns into Drill String to Release Liner Running Tool from Hanger. Pressure Up on DP to 2,000 psi, P / U on Drill String 10', Observed Drop in Pressure Indicating Running Tool Released from Hanger. Reengaged Pump and Pumped 40 bbls to Move Cement and Contaminate Cement, 5 bpm, 3,200 psi. Slowed Pump Rate and Rotated Drill String, 30 rpm, Slacked Off and Stacke 75,000# on ZXP Packer to Ensure Packer is Set. Repeated Procedure x 2. 06:00 - 08:00 2.00 CEMT P RUNPRD P / U Additional 10' and Circulated Bottoms Up to Clean Out Cement. Pump Rate 10 bpm, 3,500 psi. Circulated Back 60 bbls of Good Cement. Circulated Until All Cement Returns Were Out of Hole. 08:00 - 11 :00 3.00 CEMT P RUNPRD Shut Down Pumps, B / 0 and L / D Lines, Cement Manifold and 2 Joints of 4" DP. Cleaned Out Pits, Under Shakers and Cuttings Box for Seawater Displacement. 11 :00 - 13:00 2.00 CEMT P RUNPRD Held PJSM. Pumped 45 bbl Hi Vis Sweep Followed by 700 bbls of Clean 8.5 ppg Seawater to Displace Mud in Wellbore. Pump Rate 12.25 bpm, 2,300 psi. 13:00 - 15:30 2.50 CEMT P RUNPRD POOH Stood Back 71 Stands of 4" DP. 15:30 - 18:00 2.50 CEMT P RUNPRD Held PSM. Slipped On New Drilling Line. 18:00 - 18:30 0.50 CEMT P RUNPRD Service Top Drive. 18:30 - 22:30 4.00 CEMT P RUNPRD POOH laying down 150 jts 4.5" DP and Running tool- clear floor. 22:30 - 23:00 0.50 BOPSU RUNPRD Pull wear ring and set test plug. 23:00 - 00:00 1.00 BOPSU RUNPRD RU to test BOP's. Test BOP's as per BP policy to 250 psi Low and 3500 psi High.Test witness waived by Jeff Jones w/ AOGCC. Test witnessed by CO. man / Tour Pusher. 6/5/2005 00:00 - 04:30 4.50 BOPSU P RUNPRD Continued Testing BOPE - 250 psi Low /3,500 psi High. Witness of BOPE Test Waived by AOGCC Rep Jeff Jones, Test Witnessed by BP Drilling Supervisor and Nabors Tour Pusher. Volume Tested Koomey. Lower IBOP Failed. R / D Test Equipment, Blew Down Top Drive. 04:30 - 05:30 1.00 CASE P RUNPRD Closed Blind Rams and Tested 4-1/2" Liner Top to 3,500 psi f/ 30 min. Pumped 8 bbls. Test OK. 05:30 - 06:00 0.50 BOPSU P RUNPRD B/O and Removed Lower IBOP. Printed: 6/13/2005 11: 1 0:39 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: U-06 U-06 REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 7ES Start: 4/26/2005 Rig Release: 6/8/2005 Rig Number: Spud Date: 6/11/1984 End: 5/11/2005 Perf Intervals: 13,975' - 14,170'; 13,735' - 13,920'; 13,660'- 13,720'; 13,345' - 13,625'; 13,290' - 13,335'; 13,040' - 13,235'; 12,900' - 13,030'; 12,715' - 12,885'; 12,635' - 12,685'; 12,300'- 12,620'; 12,180' -12,200'; 12,130' -12,160'; 12,080' -12,100'; 12,020' - 12,050'; 11,750 - 12,000'. C/O to 2-7/8" PAC Handling Equipment. M / U 20 Joints 2-7/8" PAC DP. C/O to 4" DP Handling Equipment. RIH w/ Perf Guns on 4" DP to 10917'. Trouble shoot & repair crown saver. RIH - tagged landing collar @ 14,314'. 195K up , 145K down. Pulled up and spotted bottom shot @ 14170'. Perforate Ivishak f/14170' - 11,750'. wI 6 spf - Break circulation. PJSM. Closed Hydril and pressured up to 3000 psi - bleed off and open hydril. Fired guns - only one shot detected @ surface. Wait 20 min for second gun to fire - no indication on surface. Hole took 10 bbls water. Pump dry job. POOH to standing back DP to 11745'. No problems. Monitor well 10 min. - static loss 5 BPH. Continue POOH to 9795'. POOH wI 4" DP. Change handling tools. LD 5 jts 2 7/8" PAC DP - stand back 5 stds. Lost total 27 bbls sea water to formation. PJSM. Break out and lay down top firing head - top firing head did not fire. POOH L / D Unfired 2.5" Perf Guns. Interval from 11,170' to 12,685 not Perforated. B/ 0 and L / D 2-7/8" DPC Perf Guns, All Shots Fired. Ivishak intervals perforated - 14170' - 13975', 13920' - 13735', 13720'- 13660',13625' - 13345', 13335' - 13290', 13235' - 13040', 13030' - 12900', 12885' - 12715', - 1590' w/6 spf. DFAL OTHCMP Cleaned and Cleared Rig Floor. Held PJSM w/ Rig Crew, Schlumberger TCP Crew, Tool Pusher and Drilling Supervisor. DFAL OTHCMP M / U 2-1/2" DCP Perf Guns, Perf Intervals: 12,635' - 12,685'; 12,300' - 12,620'; 12,180' - 12,200'; 12,130' -12,160'; 12,080' -12,100'; 12,020' -12,050'; 11,750 - 12,000'. C/O to 2-7/8" PAC Handling Equipment. M / U 20 Joints 2-7/8" PAC DP. C/O to 4" DP Handling Equipment. RIH w/ Perf Guns on 4" DP to 12,702'. String Weight Up 190,000#, String Weight Down 145,000#. Dropped Ball and Allowed to Fall Down Hole. M / U Top Drive 07:00 - 08:00 1.00 OTHCMP 08:00 - 08:30 0.50 OTHCMP 08:30 - 09:00 0.50 PERFUB P OTHCMP 09:00 - 12:00 3.00 PERFUB P OTHCMP 12:00 - 13:00 1.00 PERFUB P OTHCMP 13:00 - 17:00 4.00 PERFUB P OTHCMP 17:00 - 19:30 2.50 PERFUB P OTHCMP 19:30 - 21 :00 1.50 PERFUB P OTHCMP 21 :00 - 22:00 1.00 PERFUB P OTHCMP 22:00 - 00:00 2.00 PERFUB P OTHCMP 6/6/2005 00:00 - 03:00 3.00 PERFUB P OTHCMP 03:00 - 04:00 1.00 PERFUB P OTHCMP 04:00 - 05:30 1.50 PERFUB P OTHCMP 05:30 - 09:00 3.50 PERFUB P OTHCMP 09:00 - 09:30 0.50 PERFUB N 09:30 - 11 :00 1.50 PERFUB N 11 :00 - 12:00 1.00 PERFUB N DFAL OTHCMP 12:00 - 17:00 5.00 PERFUB N DFAL OTHCMP 17:00 - 17:30 0.50 PERFUB N DFAL OTHCMP R / U 2-7/8" and 2-1/2" TPC Perforating Gun Handlling Equipment. Installed Repaired Lower IBOP. Tested Lower IBOP, 250 psi /3,500 psi, Held Each Test f/5 Minutes w/ No Leaks or Pressure Loss. Test Witnessed by BP Drilling Supervisor and Nabors Tool Pusher. Held PJSM wI Rig Crew, Schlumberger TCP Crew, Tool Pusher and Drilling Supervisor. M / U 2-7/8" x 2-1/2" TCP Perf Guns As Follows:Total Blank Guns 463.49', Total Loaded Guns 1,980'. Printed: 6/13/2005 11: 1 0:39 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: U-06 U-06 REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 7ES Start: 4/26/2005 Rig Release: 6/8/2005 Rig Number: Spud Date: 6/11/1984 End: 5/11/2005 6/6/2005 17:00 - 17:30 0.50 PERFUB N DFAL OTHCMP and Placed Guns on Depth to Perforate 11,750' - 12,685'. Engaged Pump, 2.5 bpm, 365 psi. Ball on Seat w/38 bbls Pumped, Pressure Increased to 500 psi, Guns Fired. Good Surface Indication of Guns Firing. 17:30 - 18:00 0.50 PERFUB N DFAL OTHCMP POOH to 11,500', Monitored Well. Static loss rate 4 BPH. 18:00 - 21 :00 3.00 PERFUB N DFAL OTHCMP POOH laying down 4" DP to 6000'. 21 :00 - 22:00 1.00 PERFUB P OTHCMP Slip and cut 89' drilling line. 22:00 - 22:30 0.50 PERFUB P OTHCMP Service top drive. 22:30 - 00:00 1.50 PERFUB N DFAL OTHCMP LD DP f/ 6000' - 3188'. 6/7/2005 00:00 - 01 :00 1.00 PERFUB N DFAL OTHCMP LD 4" DP to 1601'. 01 :00 - 02:30 1.50 PERFUB N DFAL OTHCMP RU tongs / change handeling tools. LD 20 jts 2 7/8" PAC DP. 02:30 - 05:00 2.50 PERFUB N DFAL OTHCMP PJSM w/ Crew, DPC perf crew, tool pusher, and Co. Rep. LD fired 2.5" guns. All guns fired. Ivishak intervals perf f/11750' - 12,685' (720' @ 6 spf). RD tongs and clear perf tools from rig floor. 05:00 - 05:30 0.50 PERFUB P OTHCMP RIH w/14 stds 4" DP - POOH laying down DP. 05:30 - 06:00 0.50 PERFUB P OTHCMP Respool drill line on dwks drum, inspect dog knot. 06:00 - 08:30l 2.50 RUNCO RUNCMP UD drill pipe, pull wear ring, clear & clean rig floor. 08:30 - 10:00 1.50 RUNCO RUNCMP PJSM. R/U tubing equipment, compensator, double stack tongs & stabbing board. 10:00 -11:30 1.50 RUNCO WAIT RUNCMP Wait on tail pipe assy. 11 :30 - 12:30 1.00 RUNCO RUNCMP M/U tail pipe/packer assy. 12:30 - 00:00 11.50 RUNCO RUNCMP RIH with 3.5",9.2 #, 13Cr-80, Van Ace tubing. 6/8/2005 00:00 - 02:00 2.00 RUNCO RUNCMP RIH with 3.5", Cr-80, 9.2 #, Vam Ace tubing to 11332'. 02:00 - 04:00 2.00 RUNCO RUNCMP P/U tag joints, R/U circ sub, pump @ 3 bpm @ 280 psi. Tag bottom of tie back sleeve, space out WLEG midway in tie back sleeve @ 11366'. UWT = 117K, DWT = 85K. 04:00 - 07:00 3.00 RUNCO RUNCMP Reverse circ 212 bbls of clean inhibited seawater down the annulus taking returns to the slop tank. Pump @ 3 bpm @ 280 psi. 07:00 - 08:30 1.50 RUNCO RUNCMP Drop 1 5/16" ball & rod. Pressure up on tubing to 4400 psi, set packer & hold for 30 min test, OK. Pump down annulus, pressure up to 3500 psi & hold for 30 min test, OK. Bleed off tubing & observe DCR valve shear. Bleed all pressure to 0 psi. 08:30 - 11 :00 2.50 RUNCO RUNCMP Install Cameron TWC & test from below to 1000 psi. Blow down all mud lines. PJSM. N/D BOPE. 11 :00 - 12:30 1.50 RUNCO RUNCMP N/U adaptor flange & 4 1/16" X 5000 psi Cameron tree. 12:30 - 13:30 1.00 RUNCO RUNCMP Test tree & adaptor flange to 5000 psi, OK. 13:30 - 14:30 1.00 RUNCO RUNCMP R/U DSM lubricator & pull TWC valve. 14:30 - 15:00 0.50 RUNCO RUNCMP R/U circ hoses & LRHOS 15:00 - 18:00 3.00 RUNCO HMAN RUNCMP R/D rig floor & prep for rig move. [ Waiting on diesel for freeze protect. ] 18:00 - 19:00 1.00 RUNCO RUNCMP Reverse circulate 155 bbl of diesel @ 2.5 bbl min @ 1000 psi. 19:00 - 20:00 1.00 RUNCO RUNCMP Connect annulus to tubing & allow deisel to U-tube. 20:00 - 20:30 0.50 RUNCO RUNCMP Dry rod Cameron BPV into tree, test from below to 1000 psi. 20:30 - 21 :00 0.50 RUNCO RUNCMP R/D circ hoses & LRHOS. 21 :00 - 22:00 1.00 RUNCO RUNCMP Remove 2nd annulus valve & secure well. Rig released @ 22:00 hrs 618/2005. Printed: 6/13/2005 11: 1 0:39 AM SCHLUMBERGER Survey report Client...................: BP Exploration (Alaska) Inc. Field....................: Prudhoe Bay Well. . . . . . . . . . . . . . . . . . . . .: U-06B API number...............: 50-029-21117-02 Engineer. ......... ... ....: M. Perdomo COUNTY:.. ................: North Slope Borough STATE: . . . . . . . . . . . . . . . . . . .: Alaska ----- Survey calculation methods------------- Method for positions.....: Minimum curvature Method for DLS...........: Mason & Taylor ----- Depth reference ----------------------- Permanent datum..........: MEAN SEA LEVEL Depth reference... .......: Driller's Depth GL above permanent.. .....: 48.80 ft KB above permanent.......: N/A Top Drive DF above permanent.......: 76.50 ft ----- Vertical section origin---------------- Latitude (+N/S-).........: 0.00 ft Departure (+E/W-) ... .....: 0.00 ft ----- Platform reference point--------------- Latitude (+N/S-).........: -999.25 ft Departure (+E/W-)........: -999.25 ft Azimuth from Vsect Origin to target: 260.52 degrees [(c)2005 IDEAL ID9_1C_02J Spud date... . . . . . . . . . . . . . : Last survey date... ......: Total accepted surveys...: MD of first survey.......: MD of last survey... .....: 30-Apr-05 08 -May- 05 125 0.00 ft 11535.00 ft . ----- Geomagnetic data ---------------------- Magnetic model.. .........: BGGM version 2004 Magnetic date. ..... ......: 28-Apr-2005 Magnetic field strength..: 1152.51 HCNT Magnetic dec (+E/W-).....: 24.67 degrees Magnetic dip.. ...........: 80.82 degrees ----- MWD survey Reference Reference G... ...........: Reference H..... .........: Reference Dip...... ......: Tolerance of G.. .........: Tolerance of H.... .......: Tolerance of Dip.........: Criteria --------- 1002.68 mGal 1152.51 HCNT 80.82 degrees (+/-) 2.50 mGal ( + / - ) 6. 00 HCNT (+/-) 0.45 degrees . ----- Corrections --------------------------- Magnetic dec (+E/W-).....: 24.67 degrees Grid convergence (+E/W-).: 0.00 degrees Total az corr (+E/W-)....: 24.67 degrees (Total az corr = magnetic dec - grid conv) Survey Correction Type ...: I=Sag Corrected Inclination M=Schlumberger Magnetic Correction S=Shell Magnetic Correction F=Failed Axis Correction R=Magnetic Resonance Tool Correction D=Dmag Magnetic Correction SCHLUMBERGER Survey Report -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ Seq Measured Incl Azimuth Course TVD Vertical Displ Displ Total At DLS Srvy Tool # depth angle angle length depth section +N/S- +E/W- displ Azim (deg/ tool Corr (ft) (deg) (deg) (ft) (ft) (ft) (ft) (ft) (ft) (deg) 100f) type (deg) -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ 1 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 TIP None 2 92.20 0.00 242.02 92.20 92.20 0.00 0.00 0.00 0.00 0.00 0.00 GYD GC SS None - 3 192.20 0.57 191.22 100.00 192.20 0.18 -0.49 -0.10 0.50 191.22 0.57 GYD GC SS None - - 4 292.20 0.57 195.26 100.00 292.19 0.56 -1. 46 -0.32 1.49 192.57 0.04 GYD GC SS None - - 5 392.20 0.57 174.42 100.00 392.19 0.80 -2.43 -0.41 2.46 189.51 0.21 GYD GC SS None 6 492.20 1.13 155.45 100.00 492.18 0.58 -3.82 0.05 3.82 179.24 0.62 GYD GC SS None. - 7 592.20 1.13 144.55 100.00 592.16 -0.11 -5.52 1. 03 5.62 169.41 0.21 GYD GC SS None - - 8 692.20 0.57 154.82 100.00 692.15 -0.68 -6.78 1. 82 7.02 165.00 0.58 GYD GC SS None - - 9 792.20 0.57 158.88 100.00 792.14 -0.91 -7.69 2.21 8.00 163.99 0.04 GYD GC SS None - - 10 892.20 0.57 148.84 100.00 892.14 -1.19 -8.58 2.64 8.98 162.88 0.10 GYD GC SS None 11 992.20 0.57 149.73 100.00 992.13 -1.55 -9.44 3.15 9.95 161.53 0.01 GYD GC SS None - - 12 1092.20 0.57 158.00 100.00 1092.13 -1. 84 -10.33 3.59 10.93 160.84 0.08 GYDGC SS None - 13 1192.20 0.57 174.44 100.00 1192.12 -1.91 -11.28 3.82 11.91 161.28 0.16 GYD GC SS None - - 14 1292.20 0.57 185.57 100.00 1292.12 -1. 75 -12.27 3.82 12.85 162.70 0.11 GYD GC SS None - - 15 1392.20 0.57 163.42 100.00 1392.11 -1. 68 -13.24 3.92 13.81 163.52 0.22 GYD GC SS None 16 1492.20 0.57 156.66 100.00 1492.11 -1.86 -14.18 4.26 14.80 163.29 0.07 GYD GC SS None - - 17 1592.20 0.57 166.53 100.00 1592.10 -2.02 -15.12 4.57 15.79 163.18 0.10 GYD GC SS None - - 18 1692.20 0.57 205.37 100.00 1692.10 -1.77 -16.05 4.47 16.66 164.43 0.38 GYD GC SS None - 19 1792.20 0.08 156.46 100.00 1792.10 -1.50 -16.56 4.29 17.11 165.49 0.52 GYD GC SS None - - 20 1892.20 0.10 193.10 100.00 1892.09 -1.48 -16.71 4.29 17.26 165.59 0.06 GYD GC SS None 21 1992.20 0.00 122.71 100.00 1992.09 -1.45 -16.80 4.27 17.33 165.72 0.10 GYD GC SS None. - - 22 2092.20 0.57 95.50 100.00 2092.09 -1. 93 -16.85 4.77 17.51 164.19 0.57 GYD GC SS None - - 23 2192.20 0.57 76.12 100.00 2192.09 -2.91 -16.77 5.75 17.73 161. 09 0.19 GYD GC SS None - - 24 2292.20 0.57 82.47 100.00 2292.08 -3.90 -16.59 6.72 17.90 157.94 0.06 GYD GC SS None - - 25 2392.20 0.57 112.65 100.00 2392.08 -4.82 -16.72 7.68 18.39 155.34 0.30 GYD GC SS None 26 2492.20 0.57 92.55 100.00 2492.07 -5.73 -16.93 8.63 19.00 152.99 0.20 GYD GC SS None - - 27 2592.20 0.57 92.60 100.00 2592.07 -6.70 -16.97 9.63 19.51 150.44 0.00 GYD GC SS None - - 28 2692.20 0.57 112.93 100.00 2692.06 -7.60 -17.19 10.58 20.19 148.39 0.20 GYD GC SS None - - 29 2792.20 0.57 98.46 100.00 2792.06 -8.50 -17.46 11.53 20.92 146.56 0.14 GYD GC SS None - - 30 2892.20 0.15 105.52 100.00 2892.06 -9.09 -17.57 12.15 21.36 145.33 0.42 GYD GC SS None [(c)2005 IDEAL ID9_1C_02J SCHLUMBERGER Survey Report -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ Seg Measured Incl Azimuth Course TVD Vertical Displ Displ Total At DLS Srvy Tool # depth angle angle length depth section +N/s- +E/w- displ Azim (degl tool Corr (ft) (deg) (deg) (ft) (ft) (ft) (ft) (ft) (ft) (deg) 100f) type (deg) -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ 31 2958.00 0.15 105.52 65.80 2957.86 -9.25 -17.61 12.31 21. 49 145.04 0.00 Top of Window 32 2975.00 2.00 325.00 17.00 2974.85 -9.14 -17.38 12.17 21. 21 145.00 12.46 Bottom of Window 33 2987.00 2.28 346.20 12.00 2986.85 -9.03 -16.97 11.99 20.78 144.76 6.95 End of Mill Run 34 3002.80 3.17 338.38 15.80 3002.63 -8.91 -16.26 11.75 20.06 144.14 6.09 GYD GC SS None - 35 3102.00 8.33 323.11 99.20 3101.30 -5.03 -7.96 6.43 10.23 141. 08 5.38 GYD GC SS None 36 3219.52 15.98 308.71 117.52 3216.12 9.70 9.00 -11. 34 14.47 308.43 6.95 MWD IFR MS Non. - 37 3313.72 16.21 304.48 94.20 3306.63 27.81 24.55 -32.30 40.57 307.24 1. 27 MWD IFR MS None - 38 3408.74 15.63 289.97 95.02 3398.05 48.51 36.43 -55.27 66.20 303.39 4.22 MWD IFR MS None - 39 3501.60 16.84 273.62 92.86 3487.25 72 .52 41.56 -80.46 90.56 297.32 5.07 MWD IFR MS None - 40 3596.65 19.19 260.47 95.05 3577.67 101. 57 39.84 -109.63 116.64 289.97 4.93 MWD IFR MS None 41 3690.73 21.36 249.28 94.08 3665.95 133.85 31.21 -140.92 144.33 282.49 4.71 MWD IFR MS None - 42 3785.20 24.21 242.08 94.47 3753.06 169.11 16.05 -174.14 174.87 275.27 4.22 MWD IFR MS None - 43 3878.75 27.06 240.36 93.55 3837.39 207.29 -3.46 -209.59 209.62 269.05 3.15 MWD IFR MS None - - 44 3973.36 30.16 239.89 94.61 3920.44 249.75 -26.03 -248.86 250.22 264.03 3.29 MWD IFR MS None - 45 4069.14 34.40 240.96 95.78 4001.40 297.78 -51. 24 -293.35 297.79 260.09 4.47 MWD IFR MS None 46 4164.33 37.24 240.96 95.19 4078.57 350.27 -78.28 -342.05 350.90 257.11 2.98 MWD IFR MS None - 47 4258.55 40.65 241.10 94.22 4151. 84 406.10 -106.96 -393.86 408.12 254.81 3.62 MWD IFR MS None - 48 4352.20 44.01 243.45 93.65 4221.07 465.99 -136.26 -449.69 469.88 253.14 3.97 MWD IFR MS None - 49 4445.98 45.77 240.98 93.78 4287.51 528.80 -167.12 -508.22 534.99 251.80 2.64 MWD IFR MS None - 50 4540.21 49.17 243.29 94.23 4351.21 594.69 -199.54 -569.61 603.55 250.69 4.03 MWD IFR MS None 51 4633.88 48.93 244.01 93.67 4412.60 662.39 -230.94 -633.00 673.81 249.96 0.63 MWD IFR MS Non. - - 52 4728.29 50.15 241.36 94.41 4473.87 730.76 -263.91 -696.81 745.11 249.26 2.50 MWD IFR MS None - 53 4822.54 50.37 241.78 94.25 4534.12 799.30 -298.41 -760.54 816.99 248.58 0.41 MWD IFR MS None - 54 4931.13 50.57 240.44 108.59 4603.24 878.29 -338.87 -833.87 900.10 247.88 0.97 MWD IFR MS None - 55 5026.09 49.96 240.65 94.96 4663.94 946.93 -374.78 -897.45 972.57 247.33 0.66 MWD IFR MS None - 56 5120.65 50.01 240.73 94.56 4724.74 1015.05 -410.24 -960.60 1044.54 246.87 0.08 MWD IFR MS None - - 57 5215.01 50.64 240.99 94.36 4784.98 1083.45 -445.60 -1024.04 1116.79 246.48 0.70 MWD IFR MS None - 58 5310.04 51. 42 240.80 95.03 4844.75 1153.04 -481.54 -1088.59 1190.34 246.14 0.84 MWD IFR MS None - 59 5404.43 49.80 240.69 94.39 4904.65 1221.68 -517.19 -1152.23 1262.98 245.83 1. 72 MWD IFR MS None - 60 5499.00 49.81 240.14 94.57 4965.68 1289.52 -552.85 -1215.05 1334.92 245.53 0.44 MWD IFR MS None - [(c)2005 IDEAL ID9 lC_02J SCHLUMBERGER Survey Report -------- ------ ------- ------ -------- -------- ---------------- -'-------------- ------ -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ Seq Measured Incl Azimuth Course TVD Vertical Displ Displ Total At DLS Srvy Tool # depth angle angle length depth section +N/s- +E/w- displ Azim (degl tool Corr (ft) (deg) (deg) (ft) (ft) (ft) (ft) (ft) (ft) (deg) 100f) type (deg) -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ 61 5592.17 50.87 240.59 93.17 5025.14 1356.85 -588.32 -1277.40 1406.36 245.27 1. 20 MWD IFR MS None - 62 5684.39 49.19 239.85 92.22 5084.38 1423.13 -623.41 -1338.74 1476.78 245.03 1. 92 MWD IFR MS None - 63 5779.82 49.08 239.27 95.43 5146.82 1490.53 -659.98 -1400.96 1548.63 244.78 0.47 MWD IFR MS None - 64 5874.20 49.63 239.11 94.38 5208.30 1557.23 -696.65 -1462.47 1619.92 244.53 0.60 MWD IFR MS None - 65 5970.91 49.35 239.00 96.71 5271.12 1625.66 -734.46 -1525.53 1693.12 244.29 0.30 MWD IFR MS None 66 6065.44 48.85 238.56 94.53 5333.01 1692.03 -771.50 -1586.63 1764.26 244.07 0.64 MWD IFR MS Non. - 67 6159.09 49.06 238.29 93.65 5394.51 1757.47 -808.48 -1646.80 1834.56 243.85 0.31 MWD IFR MS None 68 6253.67 50.02 240.29 94.58 5455.88 1824.55 -845.22 -1708.67 1906.29 243.68 1. 90 MWD IFR MS None - 69 6350.51 49.82 240.13 96.84 5518.24 1894.04 -882.03 -1772.98 1980.26 243.55 0.24 MWD IFR MS None - 70 6445.81 49.95 239.94 95.30 5579.64 1962.31 -918.43 -1836.12 2053.01 243.43 0.20 MWD IFR MS None 71 6540.71 49.50 239.92 94.90 5640.99 2030.09 -954.71 -1898.78 2125.28 243.31 0.47 MWD IFR MS None - 72 6636.05 49.24 240.08 95.34 5703.07 2097.85 -990.89 -1961. 44 2197.52 243.20 0.30 MWD IFR MS None - 73 6728.73 48.85 239.80 92.68 5763.82 2163.38 -1025.95 -2022.02 2267.41 243.10 0.48 MWD IFR MS None - 74 6822.68 49.79 240.75 93.95 5825.06 2230.23 -1061.27 -2083.89 2338.57 243.01 1. 26 MWD IFR MS None - 75 6918.24 49.36 240.28 95.56 5887.03 2298.58 -1097.08 -2147.22 2411.25 242.94 0.59 MWD IFR MS None 76 7011.09 50.01 241. 35 92.85 5947.10 2365.23 -1131.60 -2209.02 2482.00 242.88 1.12 MWD IFR MS None - 77 7103.93 49.45 241.29 92.84 6007.11 2432.13 -1165.59 -2271.17 2552.81 242.83 0.61 MWD IFR MS None - 78 7197.16 50.56 241. 63 93.23 6067.03 2499.64 -1199.71 -2333.92 2624.21 242.80 1. 22 MWD IFR MS None - 79 7292.36 50.00 242.26 95.20 6127.87 2569.05 -1234.15 -2398.54 2697.43 242.77 0.78 MWD IFR MS None - 80 7387.77 49.41 242.09 95.41 6189.57 2638.12 -1268.12 -2462.89 2770.19 242.76 0.63 MWD IFR MS None 81 7483.64 49.74 242.30 95.87 6251.74 2707.40 -1302.17 -2527.45 2843.17 242.74 0.38 MWD IFR MS None 82 7580.49 49.44 242.79 96.85 6314.52 2777.55 -1336.17 -2592.89 2916.92 242.74 0.49 MWD IFR MS None - 83 7672.98 49.86 242.07 92 .49 6374.40 2844.55 -1368.79 -2655.37 2987.40 242.73 0.75 MWD IFR MS None - 84 7767.19 50.41 242.08 94.21 6434.79 2913.14 -1402.65 -2719.26 3059.71 242.71 0.58 MWD IFR MS None - 85 7860.50 49.92 242.51 93.31 6494.56 2981.20 -1435.97 -2782.69 3131. 36 242.70 0.63 MWD IFR MS None - 86 7956.15 50.54 241. 44 95.65 6555.75 3050.90 -1470.51 -2847.59 3204.87 242.69 1. 08 MWD IFR MS None - 87 8050.51 50.89 240.88 94.36 6615.50 3119.80 -1505.74 -2911.56 3277.88 242.65 0.59 MWD IFR MS None - 88 8144.56 49.90 239.98 94.05 6675.45 3187.86 -1541.50 -2974.59 3350.28 242.61 1.29 MWD IFR MS None 89 8239.53 49.95 239.59 94.97 6736.60 3255.82 -1578.07 -3037.39 3422.87 242.55 0.32 MWD IFR MS None - 90 8334.93 50.52 240.72 95.40 6797.62 3324.57 -1614.56 -3100.99 3496.13 242.50 1. 09 MWD IFR MS None [(c)2005 IDEAL ID9_1C_02] SCHLUMBERGER Survey Report -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ Seq Measured Incl Azimuth Course TVD Vertical Displ Displ Total At DLS Srvy Tool # depth angle angle length depth section +N/S- +E/W- displ Azim (deg/ tool Corr (ft) (deg) (deg) (ft) (ft) (ft) (ft) (ft) (ft) (deg) 100f) type (deg) -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ 91 8427.31 49.89 240.46 92.38 6856.74 3391.29 -1649.41 -3162.82 3567.07 242.46 0.72 MWD IFR MS None - 92 8521.74 49.10 240.06 94.43 6918.08 3458.65 -1685.03 -3225.17 3638.82 242.41 0.90 MWD IFR MS None 93 8616.55 50.20 241.10 94.81 6979.46 3526.57 -1720.51 -3288.10 3711.04 242.38 1. 43 MWD IFR MS None - 94 8711.14 49.30 240.18 94.59 7040.58 3594.47 -1755.91 -3351.02 3783.20 242.35 1. 21 MWD IFR MS None - 95 8805.73 50.40 240.33 94.59 7101.57 3662.29 -1791.78 -3413.80 3855.45 242.31 1.17 MWD IFR MS None 96 8899.04 51.31 241. 01 93.31 7160.47 3730.36 -1827.22 -3476.89 3927.78 242.28 1.13 MWD IFR MS Non. - 97 8990.89 51.21 240.70 91.85 7217.95 3797.82 -1862.11 -3539.46 3999.41 242.25 0.28 MWD IFR MS None - 98 9084.98 50.70 240.84 94.09 7277.22 3866.60 -1897.80 -3603.23 4072.46 242.22 0.55 MWD IFR MS None - 99 9180.37 50.46 240.61 95.39 7337.80 3935.93 -1933.83 -3667.51 4146.12 242.20 0.31 MWD IFR MS None - 100 9274.37 50.47 241. 09 94.00 7397.63 4004.20 -1969.14 -3730.82 4218.60 242.17 0.39 MWD IFR MS None 101 9369.80 50.43 240.58 95.43 7458.40 4073.48 -2005.00 -3795.08 4292.16 242.15 0.41 MWD IFR MS None - 102 9463.36 50.33 241.04 93.56 7518.06 4141.33 -2040.15 -3857.99 4364.21 242.13 0.39 MWD IFR MS None - 103 9555.98 50.25 241. 18 92.62 7577.24 4208.53 -2074.57 -3920.38 4435.45 242.11 0.14 MWD IFR MS None - 104 9652.10 50.25 241.97 96 .12 7638.70 4278.42 -2109.75 -3985.37 4509.35 242.10 0.63 MWD IFR MS None - 105 9747.08 50.01 241.56 94.98 7699.59 4347.45 -2144.24 -4049.59 4582.24 242.10 0.42 MWD IFR MS None 106 9842.05 49.90 241. 79 94.97 7760.69 4416.26 -2178.73 -4113.59 4654.94 242.09 0.22 MWD IFR MS None - 107 9936.67 49.69 242.10 94.62 7821.77 4484.76 -2212.72 -4177.36 4727.21 242.09 0.33 MWD IFR MS None - 108 10030.55 49.79 242.38 93.88 7882.44 4552.78 -2246.09 -4240.76 4798.85 242.09 0.25 MWD IFR MS None - 109 10124.25 49.56 243.04 93.70 7943.07 4620.79 -2278.84 -4304.24 4870.28 242.10 0.59 MWD IFR MS None - 110 10220.03 49.19 243.26 95.78 8005.44 4690.17 -2311. 68 -4369.10 4942.96 242.12 0.42 MWD IFR MS None 111 10314.37 48.80 242.53 94.34 8067.34 4758.03 -2344.11 -4432.48 5014.15 242.13 0.72 MWD IFR MS Non. - 112 10409.14 48.21 242.18 94.77 8130.13 4825.47 -2377.05 -4495.36 5085.13 242.13 0.68 MWD IFR MS None - 113 10502.60 49.57 241.61 93.46 8191. 57 4892.20 -2410.22 -4557.47 5155.55 242.13 1.53 MWD IFR MS None - 114 10595.75 49.22 241. 70 93.15 8252.20 4959.12 -2443.80 -4619.71 5226.27 242.12 0.38 MWD IFR MS None - 115 10690.05 49.05 242.28 94.30 8313.90 5026.74 -2477.29 -4682.67 5297.58 242.12 0.50 MWD IFR MS None 116 10784.12 48.50 241. 99 94.07 8375.89 5093.88 -2510.36 -4745.22 5368.33 242.12 0.63 MWD IFR MS None - 117 10878.39 48.44 241.83 94.27 8438.39 5160.76 -2543.59 -4807.48 5438.90 242.12 0.14 MWD IFR MS None - 118 10972.51 48.76 242.02 94.12 8500.64 5227.67 -2576.81 -4869.77 5509.50 242.11 0.37 MWD IFR MS None - 119 11067.51 48.59 241. 18 95.00 8563.37 5295.16 -2610.74 -4932.52 5580.84 242.11 0.69 MWD IFR MS None - 120 11162.43 49.52 240.43 94.92 8625.57 5362.65 -2645.72 -4995.11 5652.52 242.09 1.15 MWD IFR MS None [(c)2005 IDEAL ID9 1C_02] SCHLUMBERGER Survey Report -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ Seq Measured Incl Azimuth Course TVD Vertical Displ Displ Total At DLS Srvy Tool # depth angle angle length depth section +N/S- +E/W- displ Azim (deg/ tool Corr (ft) (deg) (deg) (ft) (ft) (ft) (ft) (ft) (ft) (deg) 100f) type (deg) -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ 121 11256.74 49.07 240.62 94.31 8687.08 5429.84 -2680.90 -5057.35 5723.98 242.07 0.50 MWD IFR MS None - 122 11351.18 48.71 240.78 94.44 8749.17 5496.78 -2715.72 -5119.40 5795.12 242.06 0.40 MWD IFR MS None 123 11436.18 50.54 241.48 85.00 8804.23 5557.86 -2746.98 -5176.11 5859.86 242.05 2.24 MWD IFR MS None - 124 11468.83 51.42 241.32 32.65 8824.79 5581.83 -2759.12 -5198.38 5885.23 242.04 2.72 MWD IFR MS None 125 11535.00 51. 42 241. 32 66.17 8866.05 5630.68 -2783.95 -5243.76 5936.95 242.04 0.00 Projection to TD . [(c)2005 IDEAL ID9 1C_02J . SCHLUMBERGER Survey report Client...................: BP Exploration (Alaska) Inc. Field.... ................: Prudhoe Bay Well. . . . . . . . . . . . . . . . . . . . .: U-06BPB1 API number...............: 50-029-21117-70 Engineer...... .... .... ...: M. Perdomo COUNTy:..................: North Slope Borough STATE:... ................: Alaska ----- Survey calculation methods------------- Method for positions.....: Minimum curvature Method for DLS...........: Mason & Taylor ----- Depth reference ----------------------- Permanent datum..... .....: Mean Sea Level Depth reference..........: Driller's Depth GL above permanent.......: 48.80 ft KB above permanent. ......: N/A Top Drive DF above permanent.......: 76.50 ft ----- Vertical section origin---------------- Latitude (+N/S-).........: 0.00 ft Departure (+E/W-)........: 0.00 ft ----- Platform reference point--------------- Latitude (+N/S-).........: -999.25 ft Departure (+E/W-)..... ...: -999.25 ft Azimuth from Vsect Origin to target: 23.79 degrees [(c)2005 IDEAL ID9_1C_01.4] Spud date............. ...: Last survey date.........: Total accepted surveys...: MD of first survey.. .....: MD of last survey........: 30-Apr-05 01-May-05 36 0.00 ft 3193.00 ft . ----- Geomagnetic data ---------------------- Magnetic model.... .......: BGGM version 2004 Magnetic date............: 29-Apr-2005 Magnetic field strength..: 1152.54 HCNT Magnetic dec (+E/W-).....: 24.67 degrees Magnetic dip.............: 80.82 degrees ----- MWD survey Reference Reference G......... .....: Reference H..............: Reference Dip............: Tolerance of G..... ......: Tolerance of H...........: Tolerance of Dip......... : Criteria --------- 1002.68 mGal 1152.51 HCNT 80.82 degrees (+/-) 2.50 mGal (+/-) 6.00 HCNT (+/-) 0.45 degrees . ----- Corrections --------------------------- Magnetic dec (+E/W-).....: 24.67 degrees Grid convergence (+E/W-) .: 0.00 degrees Total az corr (+E/W-)....: 24.67 degrees (Total az corr = magnetic dec - grid conv) Survey Correction Type ...: I=Sag Corrected Inclination M=Schlumberger Magnetic Correction S=Shell Magnetic Correction F=Failed Axis Correction R=Magnetic Resonance Tool Correction D=Dmag Magnetic Correction SCHLUMBERGER Survey Report -------- ------ ------- ------ -------- -------- ---------------- --------------- -------- ------ ------- ------ -------- -------- ---------------- --------------- Seq Measured # depth (ft) Incl angle (deg) Azimuth angle (deg) Course length (ft) TVD depth (ft) Vertical section (ft) Displ +N/S- (ft) Displ +E/W- (ft) Total displ (ft) At Azim (deg) -------- ------ ------- ------ -------- -------- ---------------- --------------- -------- ------ ------- ------ -------- -------- ---------------- --------------- 1 2 3 4 5 0.00 92.20 192.20 292.20 392.20 6 7 8 9 10 492.20 592.20 692.20 792.20 892.20 11 12 13 14 15 992.20 1092.20 1192.20 1292.20 1392.20 16 17 18 19 20 1492.20 1592.20 1692.20 1792.20 1892.20 21 22 23 24 25 1992.20 2092.20 2192.20 2292.20 2392.20 26 27 28 29 30 2492.20 2592.20 2692.20 2792.20 2892.20 0.00 0.00 0.57 0.57 0.57 1.13 1.13 0.57 0.57 0.57 0.57 0.57 0.57 0.57 0.57 0.57 0.57 0.57 0.08 0.10 0.00 0.57 0.57 0.57 0.57 0.57 0.57 0.57 0.57 0.15 0.00 242.02 191. 22 195.26 174.42 155.45 144.55 154.82 158.88 148.84 149.73 158.00 174.44 185.57 163.42 156.66 166.53 205.37 156.46 193.10 122.71 95.50 76.12 82.47 112.65 92.55 92.60 112.93 98.46 105.52 [(c)2005 IDEAL ID9_1C_01.4] 0.00 92.20 100.00 100.00 100.00 100.00 100.00 100.00 100.00 100.00 100.00 100.00 100.00 100.00 100.00 100.00 100.00 100.00 100.00 100.00 100.00 100.00 100.00 100.00 100.00 100.00 100.00 100.00 100.00 100.00 0.00 92.20 192.20 292.19 392.19 492.18 592.16 692.15 792.14 892.14 992.13 1092.13 1192.12 1292.12 1392.11 1492.11 1592.10 1692.10 1792.10 1892.09 1992.09 2092.09 2192.09 2292.08 2392.08 2492.07 2592.07 2692.06 2792.06 2892.06 0.00 0.00 -0.49 -1. 46 -2.39 -3.48 -4.64 -5.47 -6.15 -6.78 -7.36 -8.00 -8.78 -9.69 -10.54 -11.26 -11. 99 -12.88 -13 .43 -13.56 -13.65 -13.49 -13.03 -12.47 -12.20 -12.01 -11.65 -11.46 -11.32 -11.17 0.00 0.00 -0.49 -1. 46 -2.43 -3.82 -5.52 -6.78 -7.69 -8.58 -9.44 -10.33 -11.28 -12.27 -13 .24 -14.18 -15.12 -16.05 -16.56 -16.71 -16.80 -16.85 -16.77 -16.59 -16.72 -16.93 -16.97 -17.19 -17.46 -17.57 0.00 0.00 -0.10 -0.32 -0.41 0.05 1. 03 1. 82 2.21 2.64 3.15 3.59 3.82 3.82 3.92 4.26 4.57 4.47 4.29 4.29 4.27 4.77 5.75 6.72 7.68 8.63 9.63 10.58 11. 53 12.15 0.00 0.00 0.50 1. 49 2.46 3.82 5.62 7.02 8.00 8.98 9.95 10.93 11.91 12.85 13.81 14.80 15.79 16.66 17.11 17.26 17.33 17.51 17.73 17.90 18.39 19.00 19.51 20.19 20.92 21.36 0.00 0.00 191. 22 192.57 189.51 179.24 169.41 165.00 163.99 162.88 161. 53 160.84 161. 28 162.70 163.52 163.29 163.18 164.43 165.49 165.59 165.72 164.19 161.09 157.94 155.34 152.99 150.44 148.39 146.56 145.33 DLS (deg/ 100f) 0.00 0.00 0.57 0.04 0.21 0.62 0.21 0.58 0.04 0.10 0.01 0.08 0.16 0.11 0.22 0.07 0.10 0.38 0.52 0.06 0.10 0.57 0.19 0.06 0.30 0.20 0.00 0.20 0.14 0.42 Srvy Tool tool Corr type (deg) TIP None GYD GC_SS GYD_GC_SS GYD_GC_SS GYD_GC_SS GYD_GC_SS GYD_GC_SS GYD_GC_SS GYD_GC_SS GYD_GC_SS GYD_GC_SS GYD_GC_SS GYD_GC_SS GYD_GC_SS GYD_GC_SS GYD_GC_SS GYD_GC_SS GYD_GC_SS GYD_GC_SS GYD_GC_SS GYD_GC_SS GYD_GC_SS GYD_GC_SS GYD_GC_SS GYD_GC_SS GYD_GC_SS GYD_GC_SS GYD_GC_SS GYD_GC_SS GYD_GC_SS ------ ------ ------ ------ None None None None None . None None None None None None None None None None None None None None None. None None None None None None None None None SCHLUMBERGER Survey Report -------- ------ ------- ------ -------- -------- ---------------- --------------- -------- ------ ------- ------ -------- -------- ---------------- --------------- Seq Measured # depth (ft) Incl angle (deg) Azimuth angle (deg) Course length (ft) TVDSS depth (ft) Vertical section (ft) Displ +N/S- (ft) Displ +E/W- (ft) Total displ (ft) At Azim (deg) -------- ------ ------- ------ -------- -------- ---------------- --------------- -------- ------ ------- ------ -------- -------- ---------------- --------------- 31 32 33 34 35 36 2958.00 2975.00 2986.00 3016.00 3110.00 3193.00 0.15 2.00 0.72 1. 86 6.01 6.01 105.52 325.00 13.41 121. 65 157.01 157.01 [(c)2005 IDEAL ID9_1C_01.4] 65.80 17.00 11.00 30.00 94.00 83.00 2957.86 2974.85 2985.85 3015.85 3109.61 3192.06 -11.15 -10.99 -10.82 -10.71 -14.29 -20.24 -17.61 -17.38 -17.15 -17 .22 -22.56 -30.56 12.31 12.17 12.07 12.53 15.75 19.15 21.49 21. 21 20.97 21.30 27.51 36.06 145.04 145.00 144.86 143.96 145.07 147.93 DLS (deg/ 100f) 0.00 12.46 14.68 7.32 4.91 0.00 ------ ------ Srvy Tool tool Corr type (deg) ------ ------ Top of Window Bottom of Window End of Mill Run GYD_GC SS None GYD_GC SS None Projection to TD 4IÞ . BPXA North Slope Alaska BPXA U-06B . Job No. AKZZ3684031, Surveyed: 30 May, 2005 Survey Report 16 June, 2005 Your Ref: API 500292111702 Surface Coordinates: 5960690.00 N, 632339.00 E (70018' 02.3320" N, 148055' 41.2415" W) Grid Coordinate System: NAD27 Alaska State Planes, Zone 4 Kelly Bushing Elevation: 76. 63ft above Mean Sea Level . SpE!f""If""IY-S:UI'1 DRII..L.ING SERVICeS A Hambu'rton Company Survey Ref: svy4623 BPXA Survey Report for U-06B Your Ref: API 500292111702 Job No. AKZZ3684031, Surveyed: 30 May, 2005 North Slope Alaska BPXA Measured True Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (0/100ft) 11468.96 51.420 241.320 8748.29 8824.92 2759.12 S 5198.38 W 5957839.75 N 627190.02 E 5585.23 Tie On Point 11492.65 51.330 240.990 8763.08 8839.71 2768.05 S 5214.59 W 5957830.54 N 627173.97 E 1.153 5602.70 11520.83 51.970 240.590 8780.57 8857.20 2778.83 S 5233.88 W 5957819.41 N 627154.87 E 2.529 5623.52 11552.82 52.290 240.150 8800.20 8876.83 2791.32 S 5255.83 W 5957806.54 N 627133.14 E 1.476 5647.24 11615.66 54.650 235.900 8837.62 8914.25 2818.07 S 5298.63 W 5957779.04 N 627090.82 E 6.605 5693.90 11665.49 59.410 235.430 8864.73 8941.36 2841.65 S 5333.14 W 5957754.86 N 627056.73 E 9.585 5731.85 . 11709.31 63.040 236.090 8885.82 8962.45 2863.25 S 5364.89 W 5957732.70 N 627025.37 E 8.388 5766.75 11743.72 65.700 235.320 8900.70 8977.33 2880.73 S 5390.51 W 5957714.77 N 627000.06 E 7.989 5794.93 11774.25 69.250 235.860 8912.39 8989.02 2896.67 S 5413.78 W 5957698.43 N 626977.08 E 11.742 5820.53 11802.54 71.740 234.410 8921.84 8998.47 2911.91 S 5435.65 W 5957682.81 N 626955.47 E 10.040 5844.63 11834.74 76.930 234.590 8930.53 9007.16 2929.91 S 5460.89 W 5957664.37 N 626930.56 E 16.127 5872.51 11850.76 79.570 235.590 8933.79 9010.42 2938.88 S 5473.75 W 5957655.17 N 626917.86 E 17.576 5886.69 11865.84 82.010 235.910 8936.21 9012.84 2947.26 S 5486.05 W 5957646.58 N 626905.71 E 16.315 5900.21 11895.86 86.850 237.100 8939.12 9015.75 2963.74 S 5510.96 W 5957629.66 N 626881.09 E 16.598 5927.52 11928.99 87.280 237.820 8940.82 9017.45 2981.54 S 5538.85 W 5957611.37 N 626853.52 E 2.529 5957.99 11959.74 85.180 240.980 8942.84 9019.47 2997.15 S 5565.26 W 5957595.29 N 626827.39 E 12.320 5986.62 11989.57 84.870 244.480 8945.43 9022.06 3010.77 S 5591.67 W 5957581.21 N 626801.22 E 11.735 6014.93 12019.94 85.180 247.930 8948.06 9024.69 3022.97 S 5619.35 W 5957568.52 N 626773.76 E 11.363 6044.26 12057.90 86.850 252.330 8950.70 9027.33 3035.84 S 5654.95 W 5957555.03 N 626738.39 E 12.371 6081.51 12081.97 87.470 255.430 8951.89 9028.52 3042.51 S 5678.04 W 5957547.95 N 626715.42 E 13.119 6105.39 12118.21 89.570 258.980 8952.83 9029.46 3050.53 S 5713.36 W 5957539.31 N 626680.25 E 11.378 6141.55 12149.22 91.600 262.740 8952.51 9029.14 3055.46 S 5743.97 W 5957533.85 N 626649.73 E 13.778 6172.55 . 12177.41 94.080 265.320 8951.11 9027.74 3058.39 S 5771.97 W 5957530.43 N 626621.79 E 12.686 6200.65 12208.90 96.120 267.500 8948.32 9024.95 3060.35 S 5803.27 W 5957527.91 N 626590.53 E 9.461 6231.84 12239.81 96.250 271.060 8944.98 9021.61 3060.74 S 5833.99 W 5957526.98 N 626559.82 E 11 .458 6262.19 12270.43 95.750 274.520 8941.78 9018.41 3059.26 S 5864.40 W 5957527.93 N 626529.38 E 11.356 6291.93 12300.88 95.810 278.680 8938.71 9015.34 3055.77 S 5894.49 W 5957530.88 N 626499.24 E 13.594 6321.02 12331.07 95.940 282.730 8935.62 9012.25 3050.20 S 5923.99 W 5957535.94 N 626469.64 E 13.351 6349.18 12361.96 96.000 286.520 8932.41 9009.04 3042.44 S 5953.72 W 5957543.17 N 626439.79 E 12.204 6377.20 12394.98 96.120 289.480 8928.92 9005.55 3032.30 S 5984.94 W 5957552.76 N 626408.39 E 8.922 6406.30 12423.26 95.930 289.690 8925.95 9002.58 3022.87 S 6011.44 W 5957561.72 N 626381.73 E 0.998 6430.86 12453.77 95.570 289.690 8922.90 8999.53 3012.64 S 6040.02 W 5957571.45 N 626352.98 E 1.180 6457.34 12503.93 96.240 287.290 8917.74 8994.37 2996.82 S 6087.33 W 5957586.43 N 626305.39 E 4.943 6501.35 12549.03 96.120 287.310 8912.88 8989.51 2983.48 S 6130.14 W 5957599.01 N 626262.35 E 0.270 6541.35 12594.99 95.440 288.590 8908.25 8984.88 2969.39 S 6173.64 W 5957612.33 N 626218.61 E 3.141 6581.89 16 June, 2005 - 16:44 Page 2 of 5 DrillQuest 3.03.06.008 BPXA Survey Report for U-06B Your Ref: API 500292111702 Job No. AKZZ3684031, Surveyed: 30 May, 2005 North Slope Alaska BPXA Measured True Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (0/100ft) 12643.43 95.070 289.290 8903.82 8980.45 2953.745 6219.27 W 5957627.18 N 626172.72 E 1.629 6624.27 12673.93 94.700 289.410 8901.22 8977.85 2943.67 S 6247.94 W 5957636.75 N 626143.87 E 1.275 6650.87 12705.92 93.340 287.200 8898.98 8975.61 2933.65 S 6278.23 W 5957646.23 N 626113.41 E 8.097 6679.07 12735.85 92.340 284.570 8897.49 8974.12 2925.47 S 6306.98 W 5957653.91 N 626084.52 E 9.391 6706.06 12769.88 89.570 283.060 8896.93 8973.56 2917.34 S 6340.02 W 5957661.45 N 626051.34 E 9.270 6737.28 12801.38 88.830 280.600 8897.37 8974.00 2910.885 6370.84 W 5957667.36 N 626020.41 E 8.154 6766.60 . 12829.41 88.090 282.850 8898.12 8974.75 2905.19 S 6398.28 W 5957672.57 N 625992.88 E 8.447 6792.70 12877.34 84.130 281.740 8901.37 8978.00 2895.01 5 6444.99 W 5957681.93 N 625946.00 E 8.579 6837.07 12921.61 83.510 282.450 8906.14 8982.77 2885.795 6488.03 W 5957690.39 N 625902.80 E 2.122 6877.96 12969.86 85.550 281.880 8910.73 8987.36 2875.67 S 6534.97 W 5957699.68 N 625855.68 E 4.388 6922.57 13012.07 86.360 282.530 8913.71 8990.34 2866.77 S 6576.13W 5957707.86 N 625814.38 E 2.458 6961.67 13057.48 87.160 280.350 8916.28 8992.91 2857.775 6620.56 W 5957716.06 N 625769.80 E 5.107 7003.99 13105.27 86.730 282.220 8918.83 8995.46 2848.44 S 6667.36 W 5957724.58 N 625722.84 E 4.010 7048.57 13155.61 86.300 280.390 8921.89 8998.52 2838.59 S 6716.63 W 5957733.56 N 625673.41 E 3.728 7095.52 13198.23 85.680 280.560 8924.87 9001.50 2830.86 S 6758.43 W 5957740.55 N 625631.47 E 1.508 7135.45 13246.91 85.240 279.820 8928.72 9005.35 2822.27 5 6806.20 W 5957748.29 N 625583.56 E 1.764 7181.12 13291.54 84.750 279.200 8932.61 9009.24 2814.93 5 6850.04 W 5957754.86 N 625539.59 E 1.767 7223.13 13343.88 84.190 282.020 8937.66 9014.29 2805.34 5 6901.25 W 5957763.55 N 625488.23 E 5.468 7272.02 13387.93 83.630 282.130 8942.33 9018.96 2796.175 6944.08 W 5957771.96 N 625445.25 E 1.295 7312.73 13426.43 82.880 281 .200 8946.85 9023.48 2788.44 S 6981.52 W 5957779.03 N 625407.67 E 3.090 7348.36 13479.54 84.060 280.880 8952.89 9029.52 2778.34 S 7033.31 W 5957788.22 N 625355.71 E 2.301 7397.74 13521.57 90.370 281.570 8954.93 9031.56 2770.175 7074.46 W 5957795.66 N 625314.42 E 15.102 7436.97 13557.89 93.890 283.320 8953.59 9030.22 2762.35 5 7109.90 W 5957802.85 N 625278.85 E 10.821 7470.60 . 13573.64 93.710 283.330 8952.54 9029.17 2758.73 5 7125.19 W 5957806.21 N 625263.50 E 1.145 7485.08 13608.56 96.560 283.080 8949.42 9026.05 2750.785 7159.05 W 5957813.55 N 625229.51 E 8.193 7517.14 13668.22 96.310 284.130 8942.73 9019.36 2736.84 5 7216.67 W 5957826.48 N 625171.65 E 1.798 7571.63 13719.74 95.190 284.080 8937.57 9014.20 2724.35 S 7266.38 W 5957838.10 N 625121.72 E 2.176 7618.57 13763.00 97.420 281.950 8932.82 9009.45 2714.66 5 7308.27 W 5957847.04 N 625079.67 E 7.108 7658.27 13811.86 97.050 282.110 8926.66 9003.29 2704.56 5 7355.68 W 5957856.31 N 625032.10 E 0.824 7703.33 13856.70 95.810 281.930 8921.64 8998.27 2695.28 5 7399.26 W 5957864.82 N 624988.36 E 2.794 7744.75 13905.20 95.250 282.320 8916.97 8993.60 2685.145 7446.45 W 5957874.12 N 624940.99 E 1.405 7789.60 13949.27 97.050 281.540 8912.25 8988.88 2676.08 5 7489.32 W 5957882.43 N 624897.97 E 4.447 7830.37 13998.40 97.050 281.770 8906.22 8982.85 2666.23 5 7537.08 W 5957891.43 N 624850.05 E 0.465 7875.81 14042.58 96.370 281.600 8901.05 8977.68 2657.355 7580.04 W 5957899.56 N 624806.93 E 1.586 7916.70 14089.11 95.500 282.280 8896.24 8972.87 2647.77 S 7625.32 W 5957908.34 N 624761.49 E 2.368 7959.75 16 June, 2005 - 16:44 Page 3 of 5 Dril/Quest 3.03.06.008 BPXA Survey Report for U-06B Your Ref: API 500292111702 Job No. AKZZ3684031, Surveyed: 30 May, 2005 North Slope Alaska BPXA Measured True Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (0/100ft) 14135.21 96.680 281.400 8891.35 8967.98 2638.37 S 7670.19 W 5957916.95 N 624716.47 E 3.187 8002.42 14183.72 96.180 280.930 8885.92 8962.55 2629.03 S 7717.48 W 5957925.45 N 624669.02 E 1.410 8047.50 14229.28 94.260 281.920 8881.78 8958.41 2620.05 S 7761.95 W 5957933.65 N 624624.40 E 4.737 8089.85 14264.17 92.410 282.300 8879.75 8956.38 2612.74 S 7796.00 W 5957940.36 N 624590.22 E 5.413 8122.21 14295.81 90.060 284.200 8879.06 8955.69 2605.49 S 7826.79 W 5957947.07 N 624559.31 E 9.550 8151.36 14323.11 87.280 285.020 8879.70 8956.33 2598.61 S 7853.20 W 5957953.48 N 624532.79 E 10.617 8176.26 . 14364.33 86.910 285.260 8881.79 8958.42 2587.85 S 7892.93 W 5957963.53 N 624492.87 E 1.070 8213.65 14417.04 85.930 285.910 8885.08 8961.71 2573.72 S 7943.61 W 5957976.77 N 624441.95 E 2.230 8261.26 14462.77 84.740 286.040 8888.80 8965.43 2561.18 S 7987.42 W 5957988.54 N 624397.92 E 2.618 8302.38 14507.71 85.370 288.930 8892.67 8969.30 2547.73 S 8030.12 W 5958001.24 N 624354.99 E 6.558 8342.24 14559.30 87.840 292.190 8895.73 8972.36 2529.64 S 8078.33 W 5958018.47 N 624306.47 E 7.919 8386.77 14600.51 87.100 292.910 8897.55 8974.18 2513.85 S 8116.35 W 5958033.59 N 624268.18 E 2.504 8421.63 14650.66 86.110 292.570 8900.52 8977.15 2494.50 S 8162.52 W 5958052.12 N 624221.68 E 2.087 8463.93 14694.17 85.430 291.340 8903.73 8980.36 2478.28 S 8202.77 W 5958067.63 N 624181.15 E 3.223 8500.91 14742.77 84.560 292.230 8907.97 8984.60 2460.31 S 8247.72 W 5958084.81 N 624135.89 E 2.556 8542.25 14788.47 85.060 292.450 8912.10 8988.73 2443.01 S 8289.82 W 5958101.36 N 624093.49 E 1.195 8580.88 14837.44 84.310 293.090 8916.64 8993.27 2424.14 S 8334.78 W 5958119.44 N 624048.21 E 2.010 8622.07 14882.04 87.960 293.230 8919.64 8996.27 2406.64 S 8375.68 W 5958136.21 N 624007.00 E 8.190 8659.49 14932.04 87.840 293.380 8921.47 8998.10 2386.88 S 8421.57 W 5958155.17 N 623960.77 E 0.384 8701.44 14975.47 87.530 292.920 8923.23 8999.86 2369.82 S 8461.47 W 5958171.52 N 623920.58 E 1.277 8737.95 15024.97 86.670 292.980 8925.73 9002.36 2350.54 S 8507.00 W 5958190.00 N 623874.72 E 1.742 8779.62 15068.77 85.990 293.690 8928.54 9005.17 2333.23 S 8547.13 W 5958206.60 N 623834.29 E 2.242 8816.32 15125.04 84.130 294.520 8933.38 9010.01 2310.33 S 8598.30 W 5958228.59 N 623782.72 E 3.617 8862.96 . 15161.24 84.250 294.650 8937.05 9013.68 2295.35 S 8631.05 W 5958242.99 N 623749.71 E 0.487 8892.76 15229.00 84.250 294.650 8943.83 9020.46 2267.23 S 8692.32 W 5958270.03 N 623687.95 E 0.000 8948.49 Projection Survey All data is in Feet (US Survey) unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well Reference. Northings and Eastings are relative to Well Reference. Global Northings and Eastings are relative to NAD27 Alaska State Planes, Zone 4. The Dogleg Severity is in Degrees per 100 feet (US Survey). Vertical Section is from Well Reference and calculated along an Azimuth of 260.4150 (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 15229.00ft., The Bottom Hole Displacement is 8983.14ft., in the Direction of 255.381 0 (True). 16 June, 2005 - 16:44 Page 4 of 5 DrillQuest 3.03.06.008 North Slope Alaska Comments Measured Depth (ft) 11468.96 15229.00 BPXA Survey Report for U-06B Your Ref: API 500292111702 Job No. AKZZ3684031, Surveyed: 30 May, 2005 BPXA Station Coordinates TVD Northings Eastings (ft) (ft) (ft) 8824.92 9020.46 2759.12S 2267.23 S Survey tool }roaram for U-068 Fro m Measured Vertical Depth Depth (ft) (ft) 0.00 2892.20 3102.00 0.00 2892.06 3101.30 Comment 5198.38 W Tie On Point 8692.32 W Projection Survey . To Measured Vertical Depth Depth Survey Tool Description (ft) (ft) BP High Accuracy Gyro - GCT-MS (U-06) AK-1 BP _HG - GYD-GC-SS (U-06B(intermediate» MWD+IIFR+MS (U-06B(intermediate» . 16 June, 2005 - 16:44 Page 5 of 5 DrillQuest 3.03.06.008 2892.20 3102.00 15229.00 2892.06 3101.30 9020.46 , M1N ID = 2.75" 2680' 13Cr80 Vam Top TOW -2958' GLM X nipple - 3 1/2" X - 7 X 4-1/2" Baker 8-3 11331' - 3 1/2" X NIPPLE 11352' - 3 1/2"X NIPPLE 11,360' - 7" X 5" Baker Flex-Lock Liner Hanger with ZXP -7",26#, L-80, BTC-M 7300' 8323' 8381' 4-1/2", 8889' gyrojdal& Gyrodata Incorporated 1682 W. Sam Houston Pkwy. N. Houston. Texas 77043 713/461-3146 Fax: 713/461-0920 SURVEY REPORT BP U-PAD #U-06B NABORS #7ES PRUDHOE BAY, AK AK0405G 547 MAY 4, 2005 t~[Plf . Serving the Worldwide Energy Industry with Precision Survey Instrumentation ;}. Q 'C - G ~ "'I . gyro/data . Gyrodata Incorporated 1682 W. Sam Houston Pkwy. N. Houston, Texas 77043 713/461-3146 Fax: 713/461-0920 May 9,2005 Ms. Sharmaine Copeland BP Exploration (Alaska) Inc. 900 E. Benson Blvd. Petrotechnical Data Center, LR2-1 Anchorage, Alaska 99508 Re: U-Pad, Well #U-06B Prudhoe Bay, Alaska Enclosed, please find one (1) original, two (2) copies, and two (2) disks of the completed survey of the above referenced well. We would like to take this opportunity to thank you for using Gyrodata, and we look forward to serving you in the future. Sincerely, IQt0 Paul E. Neumann Operations/Account Manager - PEN:tmf Serving the Worldwide Energy Industry with Precision Survey Instrumentation A Gyrodata Directional Survey for BP EXPLORATION ALASKA Lease: U-Pad Well: U-06B, 5" Drillpipe . Location: Nabors #7ES, Greater Prudhoe Bay, Alaska Job Number: AK0405G 547 Run Date: 04 May 2005 Surveyor: Jeff Smith Calculation Method: MINIMUM CURVATURE Survey Latitude: 70.300648 deg. N Longitude: 148.928123 deg. W Azimuth Conection: Gyro: Bearings are Relative to True North . Proposed Well Direction: 325.000 deg Veliical Section Calculated rrom Well Head Location Closure Calculated rrom Well Head Location Horizontal Coordinates Calculated rrom Well Head Location A Gyrodata Directional Survey BP Exploration Alaska Lease: U-Pad Well: U-06B, 5" DriIIpipe Location: Nabors #7ES, Greater Prudhoe Bay, Alaska Job Number: AK0405G 547 deg. deg. VERTICAL SECTION feet DOGLEG SEVERITY deg.l 100 ft. VERTICAL DEPTH feet CLOSURE DIST. AZIMUTH feet deg. HORIZONTAL COORDINATES feet MEASURED DEPTH feet IN C L AZIMUTH 2892.20 0.15 105.52 -21.5 0.00 2884.26 21.5 145.6 17.72 S 12.15 E . --------------------------------------------------------------------------------------------------------------------------------_._-----------------------------------------_.~--------------------- 2953 - 3102 FT. RATE GYROSCOPIC WHIPSTOCK AND MOTOR ORIENTATION RUN INSIDE 5" DRILLPIPE ALL MEASURED DEPTHS AND COORDINATES REFERENCED TO NABORS #7ES MSL OF 76.5 FT. GYRO TOOLFACE EQUALS THE DIRECTION OF THE KEYWAY TIE-IN DATA PROVIDED BY SCHLUMBERGER -------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------- 2953.00 0.08 29.83 -21.5 0.25 2945.06 21.5 145.3 17.70 S 12.25 E 2987.00 2.28 346.20 -20.9 6.54 2979.05 20.9 144.6 17.02 S 12.10 E 3009.00 3.17 338.38 -19.9 4.35 3001.03 19.9 143.7 16.03 S 11.77 E 3057.00 6.51 328.42 -15.9 7.15 3048.85 15.9 141.7 12.48 S 9.86 E 3102.00 8.33 323.11 -10.1 4.32 3093.47 10.1 139.6 7.70 S 6.57 E Final Station Closure: Distance: 10.12 ft Az: 139.56 deg. . 2 BP Exploration Alaska " Well: U-Pad U-06B 5" Drillpipe Location: Nabors #7ES, Greater Prudhoe Bay, Alaska - : I I -8 _I" +----t---~ ,~I I I -_~IOTTOM H LE -- -9 -- OCATE -- I - D: 3102.00 I -- i . . -1 0 ----~-~-----+-------_i_---~- : I i ! i i I . I i -ll~--r------:------~---!-~------r- ¡ . , , Inrun Gyrodata AK0405G_547 DEFINITIVE I , I I i i I I--~r---- . I I I I i . I I ---+----t---~T-----+---~----------- I I I [ I I I ----+-----+.'------~--------------- , , . , Ii' I ; I I I ! , I j I I I t----------- I -1-- I 1- . I I I ......... -12 ------i d:: - i ....... I i i I i ~ i ~ -13 I ð I . I z - I I -14 . ..1---1-1- [ I I - i ;--1 -15 - -----+-----t~-- I I I I I i -16 --+-----l--- --t---1 i i I I I I l ,I I I I~ I ! I i -L ! I Á. I -17 - I I I I I I --- · I +---- i I 1 - -I - r -r r- -- - ---1-~- t--rl ! .----- ----- I I "~ + . I .~---~- I I -18 - --¡-L----;-,t------¡-,- I 6.5 7.0 7.5 8.0 9.0 9.5 10.0 EASTING (ft) 10.5 11.0 11.5 12.0 12.5 BP Exploration Alaska . Well: U-Pad U-06B 5" Drillpipe Location: Nabors #7ES, Greater Prudhoe Bay, Alaska ~ i i f- I \ 7--~L I I I r- i I ! I I ~ i ¡ - I ! ! I 6 --.--r--~------·---------¡ I I I I , I I i I ' ! - I !i 5- __-L___._____-+-_~_ I I i - I : i II , - I I II Ii , I' - i .-- ~ ----l------------~-----~----~-~------------I--- I ! I I I I · , - I I -- II I 2 -=--t' : - I i; - I ì _ I i I ¡ -" i I I I I i , i I I I I ---+- i ... .......... .:t: o o ~ - 01 ( ) ~4 ç I-t cr:: LU > LU !./) 19 3 LU ....J 19 o o ... 1 ------t--~----------!- I I I - I J ¡ r-r--I- I I I \ ! I I I I I i , , I I I I I I I I I I I I ' o I 2950 2975 3000 3025 3050 MEASURED DEPTH (ft) .... I I I I Inrun Gyrodata AK0405G__547 DEFINITIVE I ¡ I II I ~ - +----- I I I I t-l- _nnn . I I I I J, I : +---------~---ftOiTOM-riötc-------· I LOCATED I I r1D: 3102.00 I , ì I I I I I I -~ . ----- . I I I I I I I I I I 3075 3100 3125 . . Schlumberger Drilling & Measurements MWD/LWD Log Product Delivery Customer BP Exploration (Alaska) Inc. Dispatched To: Helen Warman (AOGCC) Well No U-06B Date Dispatched: 10-May-05 Installation/Rig Nabors 7ES Dispatched By: Nate Rose Data No Of Prints No of Floppies Surveys 2 1 / I , "', I. .0 ()ll.J Please sign and return to: James H. Johnson Received By: II' BP Exploration (Alaska) Inc. I Petrotechnical Data Center (LR2-1) 900 E. Benson Blvd. Anchorage, Alaska 99508 Fax: 907 -564-4005 e-mail address: johnsojh@bp.com LWD Log Delivery V 1.1 , 10-02-03 Schlumberger Private rJ{¿ '^~- ~ 06'-( . . Schlumberger Drilling & Measurements MWD/LWD Log Product Delivery Customer BP Exploration (Alaska) Inc. Dispatched To: Helen Warman (AOGCC) Well No U-06BPB1 Date Dispatched: 10-May-05 Installation/Rig Nabors lES Dispatched By: Nate Rose Data No Of Prints No of Floppies Surveys 2 1 1/ I v) r¡ J /W Please sign and return to: James H. Johnson Received By: ~ BP Exploration (Alaska) Inc. ~ Petrotechnical Data Center (LR2-1) 900 E. Benson Blvd. Anchorage, Alaska 99508 Fax: 907-564-4005 e-mail address: johnsojh@bp.com LWD Log DeliveryV1.1, 10-02-03 Schlumberger Private r;r.... ~I:\~~\Ç~.;.( ìfrr \ U It ~ i -~ ,..,.,...., r::""', ! n I ~ A In IW ~I. U' 1111::3 D" I iL' í.ß \ S~ l.:::!.) U ~.JÜ L. ú""'ù 0 . ¡ !í I I FRANK H. MURKOWSKI, GOVERNOR I í / .1 , ¡ ¡ ~5 ~()ÞJ .. A".IA~1iA OIL AND GAS CONSERVATION COMMISSION 333 W. 7'" AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAJ< (907)276-7542 Bill Isaacson Senior Drilling Engineer BP Exploration (Alaska) Inc. P.O. Box 196612 Anchorage, Alaska 99519-6612 Re: Prudhoe Bay U-06B Sundry Number: 305-124 Dear Mr. Isaacson: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed fonn. Please provide at least twenty-four (24) hours notice for a representative of the Commission to witness any required test. Contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. ìJi~~ ~;7 Foerster CommissIoner DATED thisM day of May, 2005 Encl. en S·/6w()5 ,~41\- t:; II~ I 'It.1D5 ... STATE OF ALASKA tJ~ 5/lØ' . . lED ALASKA ðrr AND GAS CONSERVATION COrvllSION RECE\\ · ../ APPLICATION FOR SUNDRY APPROVAL MA'f 1 % 2GüS . n 20 AAC 25.280 Ctìr~ Comm\SS\lhc .\", m\ & G8$ 'd:' . .& 1. Type of Request: ;ow' ~nchor&lJe - o Abandon o Repair Well o Plug Perforations o Stimulate o Other o Alter Casing o Pull Tubing I o Perforate New Pool o Waiver o Time Extension o Change Approved Program II Operation Shutdown o Perforate o Re-Enter Suspended Well 2. Operator Name: 4. CurrentJ'ell Class: 5. Permit To Drill Number BP Exploration (Alaska) Inc. !HI Development o Exploratory 205-064 / 3. Address: o Stratigraphic o Service 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-21117-02-00 ./ 7. KB Elevation (ft): 28.5' 9. Well Name and Number: PBU U-06B / 8. Property Designation: 10. Field 1 Pool(s): ADL 047451 Prudhoe Bay Field I Prudhoe Bay Pool 11. PRESENT WELL CONDITION SUMMARY .. .. Total Depth MD (ft): Total Depth TVD (ft): I Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 11535 8866 11535 8866 None None Casing Length Size MD TVD Burst Collapse ~trlJctllf; I 110' 20" x 30" 110' 110' ~lJrf; Cp. 2685' 13-3/8" 2685' 2685' 4930 2670 Inter 8889' 9-5/8" 2958' 2958' 6870 4760 Liner 8748' 7" 2785' - 11533' 2785' - 8866 7240 5410 Perforation Depth MD (ft): I Perforation Depth TVD (ft): I Tubing Size: Tubing Grade: I Tubing MD (ft): None N/ A None NIA NIA Packers and SSSV Type: None Packers and SSSV MD (ft): NIA 12. Attachments: 13. Well Class after proposed work: / !HI Description Summary of Proposal o BOP Sketch o Exploratory !HI Development o Service o Detailed Operations Program 14. Estimated Date for M~wf1 ,,2005 15. Well Status after proposed work: Commencing Operations: !HI Oil <" o Gas o Plugged o Abandoned 16. Verbal Approval: Daté: 5/11/2005 o WAG DGINJ DWINJ o WDSPL Commission Representative: Winton Aubert 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Ken Allen, 564-4366 Printed Name BiIIlsaacson Title Senior Drilling Engineer U-l~~! \- Date sl "I as Prepared By Name/Number: Siç¡nature Phone 564-5521 Terrie Hubble, 564-4628 Commission Use Only I I Sundry Number: 305":- I;)..l..f Conditions of approval: Notify Commission so that a representative may witness o Plug Integrity o BOP Test o Mechanical Integrity Test o Location Clearance Other: Ml prÞ 'tOe; - 0&4- s t-L 17 u-I ~ t; h--LÇ. ~pI1· RBDMS 8Fl MAY J 9 2D05 Subsequent Form Required: it? ··407 Ot. C-+ eyr {,V...l { I ~/.e þ'w,- . Approved By: ~ ¡J/l A L APPROVED BY COMMISSIONER THE COMMISSION Date 5'-/6 - tJs- 7'/ Form 10-403 Revised 06/'¥O4 , Submit In Duplicate L . . Obp GI6JJ..JJJI6r~ To: Winton Aubert - AOGCC Date: May 11, 2005 From: Ken Allen - BPXA GPB Rotary Drilling Subject: U-06B Application for Sundry Approval - Temporary Shutdown of Drilling Operations Approval is requested for the proposed Temporary Shutdown of Drilling Operations of PBU well U-06B. U-06A was P&A'd as per Sundry 305-084 in April 2005. The well was sidetracked and the intermediate hole was drilled and the 7" liner was ran and cemented as per Permit to Drill 205- /' 064. The Drilling Operation is being temporarily shutdown to allow Rig Nabors 7ES (N-7ES) to move across the Kuparuk River before it breaks up washing out the bridge. All the wells on N-7ES summer drilling schedule are across the Kuparuk River. In order to alleviate the chance of N-7ES " getting stranded on the East side of the Kuparuk River, the decision was made to move across the bridge as soon as ConocoPhillips finished construction on the bridge. Rig Nabors 2ES (N- 2ES) will resume drilling operations on U-06B once finished with the current NK-65A well. Well U-06B has had the 7" liner run and cemented as per plan. Attached is the actual schematic / showing the current well bore status along with the proposed Kill String. N-7ES plans to move off of U-06B once the well is secured. Rig Nabors 2ES (N-2ES) will move on U-06B to finish drilling the production section and complete the well about May 15th, 2005. Ria Operations: 1. RU and run 4-1/2" kill string to -2,200'. / 2. Combo test the Tubing and IA to 1,500 psi for 30 minutes. 3. Set and test TWC. 4. NO BOPE. NU and test the tree to 5,000 psi. 5. Freeze protect th:.P'ell to -2,200' and secure the well. 6. RDMO N-7ES 7. MIRU Nabors 2ES 8. Pull BPV. Circulate out freeze protection and displace well to freshwater. Set TWC. 9. Nipple down tree. Nipple up and test BOPE. Pull TWC. // 10. Pull 4-1/2" tubing. 11. MU 6-1/8" BHA with Dir/GR/RES/ABI on 4" DP. RIH to the 7" landing collar. 12. Pressure test wellbore to 3500 psi for 30 minutes. 13. Drill shoe track. Swap over to 8.4 ppg mud and drill 20' of new formation. Perform FIT. 14. Drill the 6-1/8" production interval building to horizontal, targeting Z4B Ivishak. Drill ahead to ~ an estimated TO of 16,734' MD. 15. Run a 4-1/2" slotted liner throughout the 6-1/8" wellbore and back into the 7" drilling liner to place top of liner with 150' of overlap. 16. Release from liner, displace well to clean seawater. 17. Run the 3-1/2",9.2#, 13Cr80 completion tying into the 4-1/2" liner top. / U-06A Application for Sundry . . 18. Set packer and test the tubing to 3,500 psi and annulus to 3,500 psi for 30 minutes. 19. Set and test TWC. 20. NO BOPE. NU and test the tree to 5,000 psi. 21. Freeze protect the well to -2,200' and secure the well. /' 22. RDMO Post-Ria Work: 1. Install well house and flowlines. 2. MIRU slickline. Pull the ball and rod / RHC plug from 'XN' nipple below the new production packer. 3. Install gas lift valves. Estimated N-7ES Release Date: Estimated N-2ES Spud Date: 5/12/05 5/15/05 Ken Allen Operations Drilling Engineer 907.564.4366 U-06A Application for Sundry u B Current as of 4-1/2", 12.6#, L-80 Kill String - 2,200' 2680' 2,785' 13-3/8",72", L-80 9-5/8" X 7" Baker Flex-Lock Liner Hanger with ZXP HES EZSV 2,980' -3200' 11/05 11,533' - 7",26#, L-80, BTC-M 7300' 8323' 8381' Cmt P&A Plug 8889' 9-5/8",47#, L-80 2-7/8",6.16#, L-80 01 -05-05 RBT Proposed Completion - wp01 01-10-05 RBT Proposed Completion - wp01 02-08-05 RBT Proposed Completion - wp06 03-30-05 KWA Proposed Completion - wp07 PRUDHOE BAY UNIT WEll: U-06B API NO: Permit NO: GPB Rotary Drilling . . Ken, This confirms AOGCC's verbal approval to temporarily shut down drilling operations on PBU U-06B (PTD 205-064), as described below. Please submit a Form 10-403 with appropriate documentation as required. Thank you, Winton Aubert AOGCC 793-1231 Allen, Kenneth W (SSDS) wrote: Winton, As per our phone conversation, I have attached the document outlining the current operations on U-06B with N-7ES along with a schematic of the wellbore. We are estimating the move off of U-06B this evening (5/11/05) or early tomorrow (5/12/05) morning. The rig will then wait until Friday for the bridge repairs to be completed before moving across the bridge. N-2ES is estimated to move over and resume drilling operations on U-06B around May 15th, 2005. If you need any further information please let me know. Thanks, Ken Allen Operations Drilling Engineer Mobile: 907.748.3907 Office: 907.564.4366 e-mail: allenkw(á?bp.com . . To: Winton Aubert - AOGCC Date: May 11, 2005 From: Ken Allen - BPXA GPB Rotary Drilling Subject: U-06B Application for Sundry Approval - Temporary Shutdown of Drilling Operations Approval is requested for the proposed Temporary Shutdown of Drilling Operations of PBU well U-06B. U-06A was P&A'd as per Sundry 305-084 in April 2005. The well was sidetracked and the intermediate hole was drilled and the 7" liner was ran and cemented as per Permit to Drill 205- 064. The Drilling Operation is being temporarily shutdown to allow Rig Nabors 7ES (N-7ES) to move across the Kuparuk River before it breaks up washing out the bridge. All the wells on N-7ES summer drilling schedule are across the Kuparuk River. In order to alleviate the chance of N-7ES getting stranded on the East side of the Kuparuk River, the decision was made to move across the bridge as soon as ConocoPhillips finished construction on the bridge. Rig Nabors 2ES (N- 2ES) will resume drilling operations on U-06B once finished with the current NK-65A well. Well U-06B has had the 7" liner run and cemented as per plan. Attached is the actual schematic showing the current well bore status along with the proposed Kill String. N-7ES plans to move off of U-06B once the well is secured. Rig Nabors 2ES (N-2ES) will move on U-06B to finish drilling the production section and complete the well about May 15th, 2005. Ria Operations: 1. RU and run 4-1/2" kill string to -2,200'. 2. Combo test the Tubing and IA to 1,500 psi for 30 minutes. 3. Set and test TWC. 4. ND BOPE. NU and test the tree to 5,000 psi. 5. Freeze protect the well to -2,200' and secure the well. 6. RDMO N-7ES 7. MIRU Nabors 2ES 8. Pull BPV. Circulate out freeze protection and displace well to freshwater. Set TWC. 9. Nipple down tree. Nipple up and test BOPE. Pull TWC. 10. Pull 4-1/2" tubing. 11. MU 6-1/8" BHA with Dir/GR/RES/ABI on 4" DP. RIH to the 7" landing collar. 12. Pressure test well bore to 3500 psi for 30 minutes. 13. Drill shoe track. Swap over to 8.4 ppg mud and drill 20' of new formation. Perform FIT. 14. Drill the 6-1/8" production interval building to horizontal, targeting Z4B Ivishak. Drill ahead to an estimated TD of 16,734' MD. 15. Run a 4-1/2" slotted liner throughout the 6-1/8" wellbore and back into the 7" drilling liner to place top of liner with 150' of overlap. 16. Release from liner, displace well to clean seawater. 17. Run the 3-1/2",9.2#, 13Cr80 completion tying into the 4-1/2" liner top. U-06A Application for Sundry . . 18. Set packer and test the tubing to 3,500 psi and annulus to 3,500 psi for 30 minutes. 19. Set and test TWG. 20. NO BOPE. NU and test the tree to 5,000 psi. 21. Freeze protect the well to -2,200' and secure the well. 22. RDMO Post-Ria Work: 1. Install wellhouse and flowlines. 2. MIRU slickline. Pull the ball and rod / RHC plug from 'XN' nipple below the new production packer. 3. Install gas lift valves. Estimated N-7ES Release Date: Estimated N-2ES Spud Date: 5/12/05 5/15/05 Ken Allen Operations Drilling Engineer 907.564.4366 907.748.3907 U-06A Application for Sundry B Current as of 4-1/2", 12.6#, L-80 Kill String - 2,200' 2680' 2,785' 13-3/8",72", L-80 9-5/8" X 7" Baker Flex-Lock Liner Hanger with ZXP HES EZSV 2,980' -3200' 1/05 11,533' - 7",26#, L-80, BTC-M 7300' 8323' 8381' Cmt P&A Plug 2-7/8", 6.16#, L-80 8889' 9-5/8",47#, L-80 9325' Date o i -05-05 OHO-05 02-08-05 03-30-05 7", 26#, L-80 Rev By Comments RBT Proposed Completion - wpOi RBT Proposed Completion - wp01 RBT Proposed Completion - wp06 KWA Proposed Completion - wp07 PRU BAY UNIT WELL: U-06B API NO: Permit NO: GPB Rotary Drilling -~rru Y¡ J¡ì 9r rE _ ~ j 10\ lil~ nJ.! U-IJl"~' It ~ -" - -- -".. LJ ,!...'=! . '11) ~ lUJlf , AIfASIiA. OIL AND GAS CONSERVATION COMMISSION FRANK H. MURKOW5KI, GOVERNOR 333 W. 7'" AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Bill Isaacson Senior Drilling Engineer BP Exploration (Alaska), Inc. PO Box 196612 Anchorage, Alaska 99519 Re: PBU U~' ¡¿'. ¿; iP8 BP Exploration (Alaska), Inc. Permit No: 205-064 Surface Location: 103' 1663' WEL, Sec. 18, TIIN, RI3E, UM Bottomhole Location: 1597' SNL, 1463' WEL, Sec. 23, TIIN, RI2E, UM Dear Mr. Isaacson: Enclosed is the approved application for permit to redrill the above development well. This permit to redrill does not exempt you from obtaining additional permits or approvals 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. ase provide at least twenty-four (24) hours notice for a representative of the Commissio to itness any required test. Contact the Commission's petroleum field inspector at (907) 65 -360 (pager). DATED thisM day of April, 2005 cc: Department of Fish & Game, Habitat Section wlo encl. Department of Environmental Conservation wlo encl. - - . . 1 a. Type of work o Drill II Redrill rb. Current Well Class 0 Exploratory II Dev _"!=! ORe-Entry o Stratigraphic Test 0 Service 0 Development Gas J¡ ne 2. Operator Name: 5. Bond: 181 Blanket o Single Well 11. Well Name and Number: BP Exploration (Alaska) Inc. Bond No. 2S100302630-277 PBU U-06B "..- 3. Address: 6. Proposed Depth: 12. Field / Pool(s): P.O. Box 196612, Anchorage, Alaska 99519-6612 MD 16735 TVD 9007 Prudhoe Bay Field I Prudhoe Bay 4a. Location of Well (Governmental Section): 7. Property Designat~-, :;... Þ 3 - Pool Surface: ADL -if 7'1» 103' NSL, 1663' WEL, SEC. 18, T11 N, R13E, UM Top of Productive Horizon: 8. Land Use Permit: 13. Approximate Spud Date: 2945' SNL, 2394' WEL, SEC. 24, T11 N, R12E, UM April 24, 2005 Total Depth: 9. Acres in Property: 14. Distance to Nearest Property: 1597' SNL, 1463' WEL, SEC. 23, T11N, R12E, UM 2560 20,243 4b. Location of Well (State Base Plane Coordinates): 10. KB Elevation 15. Distance to ~~Well Within Pool Surface: X-632339 y-5960690 Zone- ASP4 (Height above GL): 28.5 feet U-07, ~t 3235' MD 16. Deviated Wells: Kickoff Depth: 3000 feet 17. Maximum Anticipated Pressures in psig (see 20 AAC 25.035) Maximum Hole Angle: 93 deQrees Downhole: 3400 Surface: 2507./ 18. Casing Program: Specifications Setting Depth .. Quantity of.Cement Size Top . Bottom (c.f.or sacka) Hole Casino, Weight Grade Coupling Length MD TVD MD TVD (including staae data) 8-1/2" 7" 26# L-80 BTC-M 8799" 2850' 2850' 11649' 8932' 1432 cu ft Class 'G', 195 cu ft 'G' 6-1/8" 4-1/2" 12.6# L-80 IBT-M 52ß6' 11499' 8835' 16735' 9007' Uncemented Slotted Liner 19. PRESENTWELL CONDITION SUMMARY (To be complet$d for RedrillANP Re-entry operationS) Total Depth MD (ft): Total Depth TVD (ft): I Plugs (measured): I Effective Depth MD (ft): IEffective Depth TVD (ft):1 Junk (measured): 10972 9018 None 10912 9014 None Casing Length Size Cement Volume MD TVD ~tfllr.tl Ir::ll Conrluctor 110' 20" x 30" 18 cu yds Concrete 110' 110' ~Urf::lCA 2685' 13-3/8" 12746 cu ft Permafrost 'E', and II 2685' 2685' IntArmAdi::!tA 8889' 9-5/8" 1740 cu ft Class 'G', 279 cu ft PF 8889' 8812' Pr .... ··i n LinAr 541' 7" ~71 cu ft Class 'G' 8381' - 8922' 8343' - 8843' Liner 2614' 2-7/8" 129 cu ft Class 'G' 8358' - 1 0972' 8322' - 9018' Perforation Depth MD (ft): 9420' - 10190' IPerfOration Depth TVD (ft): 9047' - 8963' 20. Attachments 181 Filing Fee, $100 o BOP Sketch 181 Drilling Program o Time vs Depth Plot o Shallow Hazard Analysis 181 Property Plat o Diverter Sketch o Seabed Report 181 Drilling Fluid Program 181 20 AAC 25.050 Requirements 21. Verbal Approval: Commission Representative: Date: 22. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Ken Allen, 564-4366 Printed Name Bill Isaacson Title Senior Drilling Engineer L -1. - k - 2.0/05 Prepared By Name/Number. Sicmature Phone 564-5521 Date 10\ Terrie Hubble, 564-4628 Commission Use Only Permit To Drill . J API Number: 16:~~it Ll1X~ 60 I See cover letter for Number: Zo..!:"-ðL 50-029-21117-02-00 other requirements Conditions of Approval: sam.~uired [J Yes .><tNo Mud Log R'equiréd [J Yes ~No Other ít'-(t¡tj},,;~e..;;;. ~es [J No Directional Survey Required ~es LJ No t/Þ! /ðš Aooroved B;l J ~ ~ APPROVED BY -- THE COMMISSION Date Form 1 0-401 Re~ 06/2~ ~ ßli}YJ5 t.J/~ S~bmit I(Duplicate \.c.JGÂ- . STATE OF ALASKA I ALASKA Wi.. AND GAS CONSERVATION CO ISSION PERMIT TO DRILL 20 AAC 25 005 / OR/GIi\L~1 ~Z\ 4-1 wI 'liJO$" RECËIVED APR 2 0 2005 íOn Well U-06B . . Planned Well Summary I Target Objective Horizontal Sidetrack Zone 4 I API Number: I AFE Number: I PBD 4P2343 I Surface Location Target Location Target Location Bottom Location Planned KOP: Planned Spud: 50-029-21117-02 Offsets TRS 5,176' FNL / 1 ,662' FEL 11N,13E,18 / Offsets TRS 2,944' FNL / 2,393' FEL 11 N, 12 E, 24 Easti n Offsets TRS 624,312.00 2,504' FNL / 4,786' FEL 11 N, 12 E, 24 Easti n Offsets TRS 622,341.00 1,597' FNL /1,462' FEL 11 N, 12 E, 23 / Planned TD: 16,735' md ('" Planned TVD: 9,007' I CBE: 147.50' I RTE: 128.50' 3,000' md 04/24/05 I Rig: I Nabors 7ES I / Maximum Hole Inclination: Proximity Issues: Survey Program: Nearest Well: Nearest Pro ert Line U-06B Sidetrack Version 1.0 Directional ProQram WP07 Exit oint: 3,000' md / 2,923' sstvd · Roughly vertical to the KOP at 3,000' md in the original well bore. · _500 in the planned 8-1/2" intermediate section from 4,493' - 11,649' md (Planned 8-1/2" TO). · _930 in the lanned 6-1/8" roduction section at 12,450'md. Well K241112 fails major risk criteria and will be risk based at 1 :200. The point this well fails is within the reservoir section of Directional Plan 07. This well has been abandoned. All other surrounding wells pass major risk criteria. Gyro will be used to set the Whipstock and initial surveys until clear of magnetic interference. Standard MWD+IIFR+MS for the rest of the wellbore. Well U-07, with center-to-center distance of -67' at 3,235' md. 20,243' to the nearest PBU ropert line. Page 1 . . Loa~ina Proaram 6-1/8" production: Cased Hole: o en Hole: Required Sensors 1 Service Real time MWD Dir/GR/PWD throughout the interval. Two sample catchers will be re uired at com an man call out. Real time MWD Dir/GR/Res throughout the interval. Two sample catchers will be re uired at com an man call out. None lanned None lanned Hole Section: 8-1/2" intermediate: Mud Pro~ram Funnel Vis 50 - 60 Hole Section 1 operation: I Drilling 6 1/8" production interval Type Density (ppg) PV (cP) LSRV (cP) YP Chlorides API FL pH (lb/100ft2) FloPro SF 8.4 8 -15 >25,000 24 - 30 < 30,000 4-6 9.0-9.5 / Casina I Tubin~ Proaram Hole CasinglTubing Wt. Gr~e Connection Length Top Bottom Size Size / md 1 tvd md 1 tvd 8-1/2" 7" 26.0# L-80 BTC-M 8,799' 2,850 I 2,850 11,649 I 8,932 6-1/8" 4-1/2" I solid 12.6# L-80 IBT-M 366' 11,499 I 8,835 11,865 I 9,027 6-1 18" 4-1/2" I slotted 12.6# L-80 IBT-M 4,870' 11,865 I 9,027 16,735 I 9,007 Tubina 3-1 12" 9.2# 13Cr-80 Vam Top 11 ,499' Surface 11,499 I 8,835 U-06B Sidetrack Version 1.0 Page 2 Slurry Design Basis: Fluids Sequence I Volume: BHST: BHCT: Test 9 5/8" casin to surface Intermediate casin window 9 5/8" casin / 7" liner Intermediate liner shoe . . CementinQ PrOQram 7",26#, L-80, BTC-M drillin liner Lead slurry: fully cemented 7" X 8 %" annulus with 40% exce s (3000'- 10,649', plus 150' of 9-5/8" x 7" liner lap. Tail slurry: fully cemented 7" X 8 %" annulus with 40% excess (10,649'- 11,649', Ius 80' of 7",26# shoe track. Pre-Flush None lanned S acer 45bbls MudPUSH at 1 . Lead Slur 255 bbls /1 ,432 ft Class 'G', 12 Tail Slur 35 bbls /195 ft / 68 k Class 'G', 15.8 2200 - 1380 Cement will be mixed on the fly CasinQ I Formation InteQritv TestinQ Test Point Test Type 30 min recorded FIT 30 min recorded FIT Test pressure 3,500 si surface 11.7 EMW 3,500 si surface 9.4 EMW / / Well Control Well control equipment consisting of 5,000psi working pressure pipe rams (2), blind/shear rams, and an annular preventer will be installed and is capable of handling maximum potential surface pressures. The ram configuration will be: BOPE and drilling fluid system schematics are currently on file with the AOGCC. Well Interval: Maximum antici ated BHP: Maximum suñace ressure: Calculated kick tolerance: Planned BOPE test ressure: BOPE configuration for 7" drillin liner. U-06B Sidetrack Version 1.0 Change out one set of rams to 7" pipe rams. . Page 3 . . Disposal Annular Injection: No annular injection in this well. Cuttings Handling: Cuttings generated from drilling operations are to be hauled to the Grind and Inject station at DS-04. Any metal cuttings should be sent to the North Slope Borouqh. Fluid Handling: All drilling and completion fluids and other Class /I wastes are to be hauled to DS-04 for iniection. All Class I wastes are to be hauled to Pad 3 for disposal. Geolo~lic Proanosis Formation ssTVD (ft) Uncertainty (ft) MD (ft) Comments SV3 -2860 +/- 10' SV2 -3065 +/- 10' 3142 SV1 -3360 +/- 20' 3437 UG3 -4050 +/- 50' 4127 UG1 -4630 +/- 50' 4707 UG MA (top SB) -4900 +/- 50' 4977 SB OBF base (base SB) -5530 +/- 50' 5607 THRZ -6850 +/- 50' 6927 LCU/BHRZ -7125 +/- 50' 7202 TKNG -7410 +/- 50' 7487 TJF -7800 +/- 35' 7877 TJE -8000 +/- 25' 8077 TJD -8270 +/- 25' 8347 TJC -8570 +/- 25' 8647 TJB -8700 +/- 25' 8777 TJA -8770' +/- 25' 8847 TSGR -8855 +/- 10' 8932 TSHU -8880' +/- 10' 8957 TElL -8940' +/- 10' 9017 TSAD -8950' +/- 10' 9027 Est pressure -3400psi Top HOT -8975' +/- 10' Not crossed in plan II. ( t TD Criteria 8-1/2" interval TSGR formation will be 7" casinq point. 6-1/8" interval End of Wellplan / Geo-ploygon is a hard line. Toe up near TO to confirm penetration of TSAD. Once across the final fault we would rather TO early by TD Criteria: confirming the TSAD rather than reaching the end of the polygon before confirming TSAD. Consult with Anchorage Drilling Engineer and Town Geologist to confirm final directional plan near upon nearing the final fault (estimated crossinq @ 15,040'). U-06B Sidetrack Version 1.0 Page 4 . . Fault Proanosis Fault Formation MD Intersect TVDss Estimated Direction of Uncertainty Encountered Intersect Throw Throw Fault 1 KinQak JD 11 ,145' 8,538' -30' D/U N-S +/- 220' Fault 2 Zone 4 15,040' 8,946' -35' U/D West +1- 110' · Weff Plan 7 (wp7) paraffels fault A from top Kingak through Kingak E but remains -475 north of the fault. From Kingak 0 and deeper the wp7 azimuth drills away from the plane of fault A (see along weffbore seismic section in technical package). · WP7 will cross fault 1 in the Kingak 0, -490' MD above the Sag River casing point, posing minimal risk to liner setting depth. · Lost circulation risk crossing fault 2 in Zone 48 is considered low because the fault strikes NNE-SSW, or perpendicular to the maximum horizontal stress in the region which should pinch the fault closed. · There are 3 offsetting/bounding faults NOT crossed by U-068 wp6; these are referenced as fault A (E~W fault 350' south of target poly) fault 8 (N-S fault 175' west of target poly), and fault C (E-W fault that tips out 160' SW of tarqet poiy) respectively. Qperations SUmmary Pre-Ria Work: 1. Rig up slickline, Drift 4-1/2" tubing to top of 2-7/8" liner at 8,358' MD. Drift 2-7/8" to as deep as possible. 2. Fluid pack the tubing and inner annulus. 3. P&A perfs and 2-7/8" liner from the PBTD to -7,300' MD. RIH with coil to PBTD. Lay in 31 bbls of cement to -7,300' MD. Obtain Squeeze with 5 additional bbls. POH with coil. a. Cement Calculations: · 2-7/8" liner = 10,912' - 8,358' or 2,554' (-15 BBLS) · 4-1/2" tubing = 8,358' - 7,300' or 1,058' (-16 BBLS) · Squeeze an additional 5 BBLS for a total cement volume of 36 BBLS 4. Rig up slickline, drift 4-1/2" tubing and tag TOC. 5. Pressure test T X IA to 3,500 psi for 30 minutes. Pressure test the OA to 2,000 psi for minutes. 6. Chemical cut the 4-1/2",12.6#, L-80 tubing at - 3,200' MD. 7. Circulate the well to sea water through the Chemical cut. Freeze protect the IA and tubing with diesel to -2,200'. 8. Bleed OA, IA & TBG to zero. Test the 9-5/8" pack-off to 3,500 psi and tubing hanger seals to 5,000 psi. Function all lock-down screws. Repair or replace as needed. 9. Bleed casing and annulus pressures to zero. Set a BPV in tubing hanger. Secure well. 10. Remove the well house. Level the pad. Please provide total well preparation cost on the handover form. Ria Operations: 1. MIRU Nabors 7ES 2. Pull BPV. Circulate out freeze protection and displace well to seawater. Set TWC. 3. Nipple down tree. Nipple up and test BOPE. Pull TWC. 4. Pull 4-1/2" tubing from chemical cut at -3,200' MD. 5. RU e-line. Run GR/JB for 9-5/8", 47# casing with CCL to just above top of tubing stub at 3,200' MD. 6. RIH with CIBP on e-line. Set CIBP to avoid cutting a casing collar during window milling operations. 7. 9-58 a er ottom trip whipstock assembly. RIH, orient whipstock and set on CIBP. 8. Swap over to 9.0 ppg LSND milling and drilling fluid. 9. Mill window in 9-5/8" casing at 3,000' MD (top of window) plus 20' past middle of window. Perform .,,/ TM;<:. /<o-4i.?{ FIT. POOH. t 10. MU 8-1/2" drilling assembly with Dir/GR/PWD on 5" DP and RIH. Kick off and drill the 8-1/2" C1IfProVA..-. intermediate interval, building and turning at 3-4°/100' to -~Id angle. 11. Drill ahead to the top of the HRZ. Increase mud weight to \O~pg for HRZlKingak drilling. U-06B Sidetrack Version 1.0 Page 5 . . 12. Drill ahead to casing point at Top Sag River to an estimated depth of 11,649' MD./' 13. Run and cement a 7" drilling liner throughout the 8-1/2" hole and back into the 9-518" casing with 150' ,/ of overlap. Displace cement with mud. POOH. 14. MU 6-1/8" BHA with Dir/GR/RES/ABI on 4" DP. RIH t.o the 7" landing collar. 15. Pressure test well bore to 3,500 psi for 30 minutes. /' 16. Drill shoe track. Swap over to 8.4 ppg mud and drill 20' of new formation. Perform FIT. 17. Drill the 6-1/8" production interval building to horizontal, targeting Z4B Ivishak. Drill ahead to an / estimated TO of 16,735' MD. 18. Run a 4-1/2" slotted liner throughout the 6-1/8" wellbore and back into the 7" drilling liner to place top /' of liner with 150' of overlap. 19. Release from liner, displace well to clean seawater. 20. Run the 3-1/2", 9.2#, 13Cr80 completion tying into the 4-1/2" liner top. 21. Set packer and test the tubing to 3,500 psi and annulus to 3,500 psi for 30 minutes. /' 22. Set and test TWC. 23. NO BOPE. NU and test the tree to 5,000 psi. 24. Freeze protect the well to -2,200' and secure the well. 25. RDMO Post-RiQ Work: 1. Install well house and flowlines. 2. MIRU slickline. Pull the ball and rod / RHC plug from 'XN' nipple below the new production packer. 3. Install gas lift valves. Job 1: Move In I RiQ Up I Test BOPE Reference RP .:. "Drilling/Workover Close Proximity Surface and Subsurface Wells" SOP. .:. "Hydrogen Sulfide" SOP. .:. "ADW Rig Move" RP. Issues and Potential Hazards ? No wells will require shut-in for the rig move onto U-06A. However, U-11 is 40.0' to the Northwest. This is the closest neighboring well. Care should be taken while moving onto the well. Spotters should be employed at all times. ? The U-06A well bore will be secured with 2 barriers, (the P&A cement plug and seawater). Prior to pulling the tree, verify there is a static column of seawater to surface and that no pressure exists. ? U-Pad_will be considered a H2S site. Standard Operating Procedures for H2S precautions should be followed at all times. Recent H2S data from the pad is as follows: Well Name H2S Readin #1 Closest SHL with H2S Readin U-11 10 #2 Closest SHL with H2S Readin U-14 30 #1 Closest BHL with H2S Readin U-06A none available #2 Closest BHL with H2S Readin P-08A 1 6/5/2004 Max Recorded H2S Readin on the Pad U-09A 80 7/2/2002 W-08A - 10 ppm on 5/9/2004, W-01A - 15 ppm on 7/30/200, -09A 100 ppm on 3/16/2003. Date 6/6/2004 8/5/2000 )0. Post Permit to Drill and Summary of Drilling Hazards in the dog house and camp prior to spud. U-06B Sidetrack Version 1.0 Page 6 . . Job 2: De-complete Well Reference RP .:. "De-completions" RP Issues and Potential Hazards / ~ The U-06A well bore will be secured with 2 barriers, (the P&A cement plug and the seawater). Prior to pulling the tree, verify there is a static column of seawater to surface and that no pressure exists. ~ Monitor the well to ensure the fluid column remains static prior to pulling the completion. ~ Note and record required PU weight to pull tubing at cut point (-3,200'). ~ Have all wellhead and completion equipment NORM-tested, following retrieval. ~ This wellhead is a McEvoy SSH. The tubing hanger should be a 12" X 4.5" BTC top and bottom (records are unclear at this time). Have a spear on location as a contingency. Once the stack has been nippled down, verify the hanger thread and type in preparation for de-completion. ~ There is a 4-1/2" Otis SSSV landing nipple with dual 1,4" encapsulated control lines at 2,097'.There should be about 26 rubber protectors and 2 Stainless Steel bands securing the control lines. Job 3: Run Whip Stock Reference RP .:. "Whipstock Sidetracf(' RP. Issues and Potential Hazards ~ A 9 5/8" whip stock will be run and set in the existing intermediate casing. ~ According to the initial cementing report, there will probably not be cement behind the 9 5/8" casing at the sidetrack point. ~ Once milling is complete, circulate a minimum of 1-1/2 bottoms up and pump a "Super Sweep" pill to remove metal debris created from the milling process. Ditch magnets should be used throughout job. ~ Once the milling BHA is out of the hole the entire stack and flow lines should be flushed to remove metal debris that may have settled out in these areas. Ensure BOP equipment is operable. Job 5: Drill 81/2" Intermediate Hole Interval Reference RP .:. "Prudhoe Bay Directional Guidelines" RP .:. "Shale Drilling, Kingak and HRZ' RP. .:. "Lubricants for Torque and Drag Management' RP .:. "Leak-off and Formation Integrity Tests" SOP U-06B Sidetrack Version 1.0 Page 7 . . Issues and Potential Hazards ~ This well bore will exit the original well in the SV3 sands, and drill to the top of the Sag River formation. For this well, the HRZ/Kingak will require a mud weight of 10.9ppg, according to the Kingak Polar plot. Maintain mud weight at 10.9 ppg -100' md above the HRZlKingak to 7" liner point. Follow all shale drilling practices to minimize potential problems. ~ KICK TOLERANCE: In the worst-case scenario of 8.0 ppg pore pressure at the Sag River depth, a fracture gradie;æt-1i1.S ppg at the 9 5/8" casing window, and 10.9 ppg mud in the hole, the kick tolerance i 44 BBLS. ~ This well path Will-f~;s a fault in the Kingak at -8,538' sstvd, -11,145' md. The fault has a throw of approximately 30'. This fault has not been crossed previously. The crossing of this fault is deemed a low risk hazard. Job 6: Run and Cement 7" Intermediate Liner Reference RP .:. "Shale Drilling, Kingak and HRZ' RP. .:. "Intermediate Casing and Cementing Guidelines" RP .:. "Running and Cementing a Drilling Liner" RP .:. Schlumberger Cement Program. Issues and Potential Hazards ~ Swab and surge pressure should be minimized with controlled liner running speeds and by breaking circulation slowly. Excessive swab / surge pressures could initiate Kingak instability problems. ~ Ensure the liner top packer is set prior to POOH. Slack off with rotation to the maximum allowable down weight, as per Baker representative. Job 7: Drill 6 1/8" Production Hole Interval Reference RP .:. "Leak-off and Formation Integrity Tests" SOP .:. "Prudhoe Bay Directional Guidelines" RP .:. "Lubricants for Torque and Drag Managemenf' RP Issues and Potential Hazards ~ The U-OSB wellbore crosses one planned fault in the production section at 8,94S' ssTVD / 15,040' MD. Be prepared for the possibility of losses from unmapped faults. U-OSB Sidetrack Version 1.0 Page 8 . . Job 9: Run 4%" Production Liner Reference RP .:. "Modified Conventional Liner Cementing' RP .:. "Handling and Running 13 Chrome" RP .:. Schlumberger Cement Program. Issues and Potential Hazards ~ The completion design is to run a 4-1/2", 12.6#, L-80 IBT-M solid liner throughout the production interval. ~ Differential sticking is possible. The 8.5ppg Flo-Pro will be -550 psi over balanced to the Ivishak Zone 4 formation. Minimize the time the pipe is left stationary while running the liner. ~ Ensure the liner top packer is set prior to POOH. Slack off with rotation to the maximum allowable down weight, as per Baker representative. ~ Sufficient 4-1/2" liner will be run to extend -150' back up into the 7" liner. Job 12: Run 3%" 13Cr-80 ComÞletion Reference RP .:. "Completion Design and Running' RP .:. "Handling and Running 13 Chrome" RP .:. "Casing and Tubing connections" RP Issues and Potential Hazards ~ Diesel will be used to freeze protect the well to 2,200'. The diesel flash point is 1000 F. Diesel vapor pressure is - 0.1 pSia at 1000 F. ~ The completion, as designed, will be to run a 3-1/2",9.2#, 13Cr-80, Vam TOP production tubing string, stinging into the 4-1/2" liner tieback sleeve. Take all the normal precautions while running the 13Cr-80 tubing: clean threads if / contaminated, use a stabbing guide, single joint compensator, properly dope and hand-start each pin. Use Jet Lube Seal Guard thread compound and torque turn each connection. Tubing should arrive on location with the proper thread dope. Confirm type of thread compound prior to RIH. U-06B Sidetrack Version 1.0 Page 9 . . Job 13: ND/NU/Release Ria Reference RP .:. "ADW Rig Move' RP. .:. "Freeze Protecting an Inner Annulus" RP. Issues and Potential Hazards ~ No wells will require shut-in for the rig move off U-06B. However, U-11 is 40.0' to the Northwest. This is the closest neighboring well. Care should be taken while moving off the well. Spotters ,/ should be employed at all times. U-06B Sidetrack Version 1.0 Page 10 TREE = 4" CrN . U -06A ~ NOTES: 700 @ 9227' & 900 @ 9268' I WELLHEAD = MCEVOY ACTUATOR = BAKER KB. ELEV = 84.30' Current BF. ELEV = 48.80' KOP= 7700' 2097' 4-1/2" OTIS DBE SSSV NIP, ID = 3.813" I Max Angle = 102 @ 9684' . Datum MD = 8967 DatumTVD = 8800' SS 13-3/8" CSG, 72#, L-80. ID = 12.347" I 2680' J ~ GAS LIFT MANDRELS I ST MD TVD DEV TYÆ VLV LATCH PORT DATE 5 2992 2908 0 CAM RK 4 5136 5050 7 CAM RK ~ 3 6585 6497 2 CAM RK 2 7607 7518 4 CAM RK Minimum 10 = 2.441" @ 8331' 1 8259 8146 21 CAM RK TOP OF 2-7/8" LINER · . 8321' 1-14-1/2" PARKER SWS NIP, ID = 3.813" I 1 8322' H K-22 TUBING ANCHOR I :8 0:::::::: 8323' 9-5/8" x 4-112" BAKER PERM A<R, ID - 3.99" ........, TOP OF 2-7/8" LNR I 8358' I I 8358' 1-1 DEPlOYMENT SLEEVE I TOPOF7" LNR 1 8381' r--I · - : . I 8380' 4-1/2" OTIS SWS NIP, ID = 3.813" I · . 8401' 4-1/2" OTIS XN NIP, ID = 3.8" 14-1/2" TBG 12.6#, L-80, 0.0152 bpf. ID = 3.958" I 8413' I 8413' 1-14-1/2" WLEG I I TOP OF CEMENT I 8600' I 8398' H ELMD TT LOGGED 11/22/90 I I I 9-5/8" CSG, 47#, L-80. ID = 8.681" , 8889' ... .. I I TOP OF WHIPSTOCK I 8920' I Iii MILLOUT WINDOW I RA TAG I 8930' 8919' - 8929' I PERFORA TION SUMMARY REF LOG: MEMORY RESISTIVITY LOG ON 08/01/99 A PBTD 1-1 10912' I ANGLE AT TOP PERF: 98 @ 9420' / Note: Refer to Production DB for historical perf data r SIZE SPF INTERV AL Opn/Sqz DATE 2" 4 9420 - 9528 0 08/04/99 2" 4 9540 - 9576 0 08/04/99 2" 4 9664 - 9690 0 08/04/99 2" 4 9814 - 9842 0 08/04/99 2" 4 9902 - 9958 0 08/04/99 2" 4 9980 - 9988 0 08/04/99 2-7/8" LNR, 6.16#, L-80, STL, .0058 bpf, ID = 2.441" I 10972' I 2" 4 10154 - 10190 0 08/04/99 I PBTD I 9280' I 7" LNR, 26#. L-80. 0.0383 bpf. ID = 6.276" I 9325' DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 06/28/84 ROBERTS ORIGINAL COMPLETION WELL: U-06A 08/04/99 WHITLO,^ CTD HORIZONTAL SIDETRACK PERMIT No: 199-0750 01/31AJ1 SIS-QAA CONVERTED TO CANVAS API No: 50-029-21117-01 03/08/01 SIS-MD FINAL SEC 18, T11 N, R13E 03/30/02 RN/TP CORRECTIONS BP Exploration (Alaska) TREE = WELLHEA D = ACTUATOR = KB. ELEV = BF. ELEV - KOP= Max Angle - Datum MD = Datum TVD = 4" CrN MCEVOY BAKER 84.30' 48.80' 7700' 102 @ 9684' 8967 8800' SS ~/ U-06A Pre-Rig I 2097' 4-1/2" OTIS DBE SSSV NIP, ID = 3.813" I . J ~ I 13-3/8" CSG, 72#, L-80, ID = 12.347" I 2680' I f-vv -3200' - Tubing Cut Minimum 10 = 2.441" @ 8331' TOP OF 2-7/8" LINER -7300' - Top of P&A Cmt 1-14-1/2" PARKER SWS NIP, ID = 3.813" I~ _ ¡p..' I 8322' H K-22 TUBING ANCHOR I !I}/;.\44; 8r·)···· TOPOF2-7/8"LNR 8358' I .'~i .,......: 8381' ~ I -i·¡;·· . -/< : '~0ti 8321' oc:::::::; ......., 8323' 8358' 8380' 9-5/8" X 4-112" BAKER PERM A<R, ID = 3.99" I- DEPLOYMENTSLEEVE I 4-1/2" OTIS SWS NIP, ID = 3.813" I I ITOPOF 7" LNR I 8401' 4-1/2" OTIS XN NIP, ID = 3.8" I 8413' 1-14-1/2" WLEG I 1 8398' H ELMD TT LOGGED 11/22/90 I 14-1/2" TBG 12.6#, L-80, 0.0152 bpf, ID = 3.958" I I TOP OF CEMENT I 8413' I 8600' I 8889' ~ I 8920' I 8930' I ". .. . ~ . J :.: ~ .' ~~ -~ '-~...~ ..............~ ~. ......... ~ """-4l 9-5/8" CSG, 47#, L-80, ID = 8.681" I I TOP OF WHIPSTOCK I I RA TAG 1 MILLOUT WINDOW 8919' - 8929' PERFORA TION SUMMARY REF LOG: MEMORY RESISTIVITY LOG ON 08/01/99 ANGLEAT TOP PERF: 98 @9420' Note: Refer to Production DB for historical perf data SIZE SPF INTERV AL Opn/Sqz DA TE 2" 4 9420 - 9528 0 08/04/99 2" 4 9540 - 9576 0 08/04/99 2" 4 9664 - 9690 0 08/04/99 2" 4 9814 - 9842 0 08/04/99 2" 4 9902 - 9958 0 08/04/99 2" 4 9980 - 9988 0 08/04/99 2" 4 10154 -10190 0 08/04/99 A PBTD 1-1 10912' I / ~ 10972' I 2-7/8" LNR, 6.16#, L-80, STL, .0058 bpf, ID = 2.441" I PBTD I I 7" LNR, 26#, L-80, 0.0383 bpf, ID = 6.276" I I I SAFETY NOTES: 700 @ 9227' & 900 @ 9268' 9280' I 9325' I DA TE REV BY COMMENTS DA TE REV BY 06/28/84 ROBERTS ORIGINAL COMPLETION 08/04/99 WHITLOIfI CTD HORIZONTAL SIDETRACK 01/31/01 SIS-QAA CONVERTED TO CANVAS 03/08/01 SIS-MD FINAL 03/30/02 RNlTP CORRECTIONS PRUDHOE BA Y UNrr WELL: U-06A PERMrr No: 199-0750 API No: 50-029-21117-01 see 18, T11N, R13E BP Exploration (Alaska) COMMENTS U... B Proposed Completion 2680' 2850' 13-3/8", 72", L-80 GLM Design: #6 - 3000' MD - 3-1/2" X 1-1/2" DV #5 - 3800' MD - 3-1/2" X 1-1/2" SV #4 - 6135' MD - 3-1/2" X 1-1/2" DV #3 - 7540' MD - 3-1/2" X 1-1/2" DV #2 - 8393' MD - 3-1/2" X 1-1/2" DV #1 - 11430' MD - 3-1/2" X 1-1/2" DV 9-5/8" X 7" Baker Flex-Lock Liner Hanger with ZXP and C-2 running tool TREE = WELLHEAD = 4"CIW MCEVOY Tubing Tail: -10' Pup Joint -X Nipple (2.813") -10' Pup Joint -Packer -20' Pup Joint -X Nipple (2.813") -20' Pup Joint -XN Nipple (2.75") -10' Pup Joint -WLEG 8889' TOW -3000' Max Angle = 102 @ 9684' Datum~MD =--_n-8967 DatUm T\7o;-- m_ 8800' 58 3-1/2",9.2#, 13Cr80, Vam Top HES EZSV -3020' -3200' Note: #1 GLM installed right above X nipple 11 ,449' - 7 X 4-1/2" Baker S-3 Packer 11 ,499' - 7" X 5" Baker Flex-Lock Liner Hanger with ZXP and HR running tool 11,649' - 7", 26#, L-80, BTC-M 7300' 8323' 8381' Cmt P&A Plug - -- 4-1/2", 12.6#, L-80, IBT, Slotted ----_____.d\II ---------- --~ 9-5/8",47#, L-80 16,7~' 2-7/8", 6.16#, L-80 7", 26#, L-80 01-05-05 01-10-05 02-08-05 03-30-05 RBT RBT RBT KWA Proposed Completion - wp01 Proposed Completion - wp01 Proposed Completion - wp06 Proposed Completion - wp07 BAY U-06B NO: Permit GPB Rotary Drilling C(1Þ,WANY DETAILS Name TVD INFORMATION Depth FlH D"11lb Tu }fHilHi() TnI"Nunh TARGET DETAILS Northing Basting Shape .\~'Y(\O()! 3ðºOOWJ)3Ø~9%§q"/'fj) 4"!IüO' : 3250' MD. 3248.52'TVD 22 '" '" "" 15. Õ '" 'e ~ <> ~ FORMATION TOP DETAILS No. TVDPath MDPath Formatîon ! 2 3 4 5 6 7 8 9 10 II 12 13 ]4 ] 5 16 17 I g 19 SB) SURVEY PROGRAM Pbnn..xJ: u"oún wpU7 V:';9 MWD'rFR'MS \VELL DETAilS Creak'd By: Dìgital Bu;;iness Client U:.;e¡ Pian: U-Ü6B wp07 (U-06/Plan U-OÔH¡ Checked R¡:vieweJ O¡:¡¡ç (J..{¡(, NMr1<è See MD ¡ne Azì +E/-W DLeg TF ace VSec Target 12.28 0.00 000 -11.02 12.00 -10.80 3.00 1.26 4.00 0.00 U-06B 'n 0.00 0.00 15.00 7.7] 0.00 (J.OO 13.00 [I-06B T2 13.00 0.00 5.00 U-06B T3 5.00 0.00 0.00 4.00 -1],30 U-06B T4 4.00 -30.68 0.00 0.00 4.00 105.82 U-06B T5 4.00 120.06 0.00 0.00 4.00 U-06B 1'6 4.00 0.00 4.00 U-06B T7 4.00 0.32 924335 0.00 0.00 10123.92 U-06B T8 CASING DETAILS No TVD MD Name Size 7" 7.000 4 ]/2" 4.500 SECTION DETAILS 2999.86 -17.60 TVD +N/-S 904LI8 -2119.45 9007.00 -1693.74 Start Dir l5"/100':] 1667,J7' End Dir : ¡ 1917.99' MD, Start Dir 13"/100': 12101.43' MD, 904L53'TVD End Dìr : J 2449.47' MD. 9033.77' TVD Stili Dir 5'liIOO'; J2630.93' MD, 9025.07TVD End Dir : 12772.55' MD, 9022.08'TVD Start Dìr 4"/\00' : l3629.16' MD, 9031.9'TVD I End Di, : I 2 3 4 5 6 7 8 9 10 I] 12 13 14 15 16 17 18 19 21) 21 22 23 24 25 26 8043.43'TVD : 14357.09' MD, 9003.61 'TVD End Dir : 14799.34' MD, 9007.69'''1'VD / . S'aIt Dir4"/100': ]4927.07' MD. OO]7.62'TVD End Dìr ' Vertical Section at 266.(1)" [1400ft/in] 0041.J2TVD : ] 5727.37' MD. 9041. I 8' TVD Depth: 16734.85' MD. 9007' TVD U-06B wp07 12600 COMPANY OF:rAILs BI'AlUO(U See MD fne 3 4 5 6 7 8 9 10 II 12 13 14 15 16 17 18 19 20 2] 22 23 24 25 26 5' 2 c c ... :£ 'è o ~ E -g if> Azi SECTION DETAILS TVD +N/-S ['meN'.wlh rkplb Fm D<Jplh To -JOlJ(jJ)() foul PRO(iRAM REFERENCE INFORtvtXlmN ¡-E/-W 0.00 12.00 3.00 4.00 0.00 0.00 15.00 /1J.OO 13.00 13.00 0.00 5.00 5.00 0.00 4.00 4.00 0.00 4.00 4.00 0.00 4.00 4.00 0.00 4.00 4.00 0.00 DLeg TFace PìmJJk-',J: 0-06H wpü7 VW MWD, tFR'MS VSec Target TARGET DETAILS 0.00 Name TVD +E/-IN 1.26 515.51 7.71 0.00 -0.84 85.94 0.00 U-06BT8 U-06BTI U-06BT2 U-06B T3 U-06B '1'4 U-06BT5 U-06BT6 U-06BT7 Pian: U -06B wpÜ7 (L! -06¡PIan l]-ÚÓBJ S!lll J4í\"S5'4!.24!W OÓ Northing Easting Shape TVD MD Name 7" 4 1i2" FORMATION TOP DETAILS No. TVDPath MDPath Formation Size 7.000 4.500 sa} . Sperry-Sun BP Planning Report . Company: BPAmoco Date: 3/31/2005 Time: 14:03:17 Page: 1 Field: Prudhoe Bay Co-ordinate(NE) Reference: Well: U-06, True North Site: PB U Pad Vertical (TVD) Reference: 48.5 + 28.5 77.0 Well: U-06 Section (VS) Reference: Well (0.00N,O.00E,266.00Azi) Wellpath: Plan U-06B Survey Calculation Method: Minimum Curvature Db: Oracle Plan: U-06B wp07 Date Composed: 12/2/2004 Version: 39 Principal: Yes Tied-to: From: Definitive Path 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: bggm2004 Site: PB U Pad TR-11-13 UNITED STATES: North Slope Site Position: Northing: 5960534.13 ft Latitude: 70 18 1.170 N From: Map Easting: 630178.07 ft Longitude: 148 56 44.315 W Position Uncertainty: 0.00 ft North Reference: True Ground Level: 0.00 ft Grid Convergence: 0.99 deg Well: U-06 Slot Name: 06 U-06 Well Position: +N/-S 118.42 ft Northing: 5960690.00 ft Latitude: 70 18 2.332 N +E/-W 2163.48 ft Easting : 632339.00 ft Longitude: 148 55 41.241 W Position Uncertainty: 0.00 ft Casing Points MD TVD Diameter Hole Size Name ft ft in in 11649.39 8932.00 7.000 8.500 7" 16734.00 9007.03 4.500 6.125 41/2" Formations MD TVD Formations Lithology Dip Angle Dip Direction ft ft deg deg 0.00 SV4 0.00 0.00 0.00 SV3 0.00 0.00 3142.50 3142.00 SV2 0.00 0.00 3441.48 3437.00 SV1 0.00 0.00 4208.03 4127.00 UG3 0.00 0.00 5079.03 4707.00 UG1 0.00 0.00 5498.91 4977.00 UG_MA (top SB) 0.00 0.00 6478.63 5607.00 SB_OBF _base (base SB) 0.00 0.00 8531.39 6927.00 THRZ 0.00 0.00 8959.04 7202.00 Leu / BHRZ 0.00 0.00 9402.25 7487.00 TKNG 0.00 0.00 10008.75 7877.00 TJF 0.00 0.00 10319.77 8077.00 TJE 0.00 0.00 10739.65 8347.00 TJD 0.00 0.00 11206.19 8647.00 TJC 0.00 0.00 11408.35 8777.00 TJB 0.00 0.00 11517.21 8847.00 TJA 0.00 0.00 11649.39 8932.00 TSGR 0.00 0.00 11689.02 8957.00 TSHU 0.00 0.00 11822.69 9017.00 TElL 0.00 0.00 11864.92 9027.00 TSAD 0.00 0.00 0.00 Top HOT 0.00 0.00 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 U-06B Fault 1 8615.00 -1511.08 -4841.76 5959094.01 627524.99 70 17 47.455 N 148 58 2.369 W -Polygon 1 8615.00 -1511.08 -4841.76 5959094.01 627524.99 70 17 47.455 N 148 58 2.369 W -Polygon 2 8615.00 -2667.39 -4953.15 5957936.01 627433.99 70 17 36.082 N 148 58 5.594 W -Polygon 3 8615.00 -3374.21 -5029.61 5957228.01 627369.99 70 17 29.130 N 148 58 7.808 W Company: Field: Site: Well: Wellpath: BP Amoco Prudhoe Bay PB U Pad U-06 Plan U-06B Targets Name -Polygon 4 U-06B T1 U-06B Fault A -Polygon 1 -Polygon 2 -Polygon 3 -Polygon 4 U-06B Fault B -Polygon 1 -Polygon 2 U-06B Fault C -Polygon 1 -Polygon 2 U-06B T5 U-06B T8 U-06B T3 U-06B T6 U-06B Fault 2 -Polygon 1 -Polygon 2 -Polygon 3 -Polygon 4 U-06B T4 U-06B T2 U-06B T7 U-06B Poly -Polygon 1 -Polygon 2 -Polygon 3 -Polygon 4 -Polygon 5 -Polygon 6 -Polygon 7 -Polygon 8 Plan Section Information MD ft 3000.00 3020.00 3250.00 4492.76 11657.17 11667.17 11917.99 12101.43 12121.72 12449.47 Inel deg 0.00 2.40 9.30 49.98 49.98 49.98 87.36 87.36 90.00 92.75 Description Dip. Dir. Azim deg 91.81 325.00 325.00 240.60 240.60 240.60 245.30 245.30 245.26 287.80 TVD ft 8615.00 . Sperry-Sun BP Planning Report +N/-S ft -2667.39 . Date: 3/31/2005 Time: 14:03:17 Page: 2 Co-ordinate(NE) Reference: Well: U-06, True North Vertical (TVD) Reference: 48.5 + 28.5 77.0 Section (VS) Reference: Well (0.00N,0.00E,266.00Azi) Survey Calculation Method: Minimum Curvature Db: Oracle +EI-W ft -4953.15 Map Northing ft 5957936.01 Map Easting ft 627433.99 8937.00 -2853.58 -5285.51 5957744.01 627104.99 8977.00 8977.00 8977.00 8977.00 8977.00 8977.00 8977.00 8977.00 8977.00 8977.00 8977.00 -3937.23 -3937.23 -2969.96 -2958.81 -2969.96 -4411.39 -4411.39 -8672.35 -10100.49 -8672.35 359.46 -9843.99 359.46 -9843.99 -2021.89 -10367.05 -2201.09 -9790.08 -2201.09 -9790.08 -1844.92 -10760.03 5956676.00 627997.99 5956676.00 627997.99 5957568.00 623720.99 5957554.00 622292.99 5957568.00 623720.99 5960876.01 622490.99 5960876.01 622490.99 5958486.01 622009.99 5958317.01 622589.99 5958317.01 622589.99 5958656.01 621613.99 8999.00 -2603.40 -8074.76 5957945.01 624311.99 9007.00 -1693.74 -10030.20 5958820.01 622340.99 <..-. Latitude --> Deg Min Sec 70 17 36.082 N <-- Longitude -> Deg Min See 70 17 34.249 N 148 58 15.276 W 148 58 5.594 W 70 17 23.597 N 70 17 23.597 N 70 17 33.073 N 70 17 33.165 N 70 17 33.073 N 70 18 5.804 N 70 18 5.804 N 70 17 42.376 N 70 17 40.622 N 70 17 40.622 N 70 17 44.111 N 148 57 49.783 W 148 57 49.783 W 148 59 53.975 W 149 0 35.595 W 148 59 53.975 W 149 0 28.246 W 149 0 28.246 W 149 0 43.400 W 149 0 26.577 W 149 0 26.577 W 149 0 54.862 W 70 17 36.685 N 148 59 36.571 W 70 17 45.608 N 149 0 33.595 W 9022.00 -2976.78 -6297.92 5957603.01 626094.99 70 17 33.030 N 148 58 44.778 W 9022.00 -2424.01 -8467.00 5958117.44 623916.69 70 17 38.445 N 148 59 48.008 W 9025.00 9025.00 9025.00 9025.00 9025.00 -2969.96 -2969.96 -2375.62 -1336.32 -2375.62 -8672.36 -8672.36 -8569.86 -8289.50 -8569.86 5957568.01 623720.99 5957568.01 623720.99 5958164.01 623812.99 5959208.01 624074.99 5958164.01 623812.99 9032.00 -2790.47 -7164.84 5957774.01 625224.99 9042.00 -3045.64 -5681.98 5957545.01 626711.99 9042.00 -2139.99 -9073.68 5958390.71 623305.14 9047.00 9047.00 9047.00 9047.00 9047.00 9047.00 9047.00 9047.00 9047.00 TVD ft 2999.86 3019.85 3248.52 4330.00 8937.00 8943.43 9033.09 9041.53 9042.00 9033.77 -2521.69 -2521.69 -2829.06 -2347.33 -1391.92 -1856.40 -2634.13 -3251.83 -2900.64 +N/-S ft -17.60 -17.26 1.93 -159.72 -2853.58 -2857.34 -2960.59 -3037.16 -3045.64 -3065.10 -5331.67 -5331.67 -5939.23 -8132.26 -9959.86 -10109.08 -8658.44 -5787.64 -5112.29 +EI-W ft 12.28 12.03 -1.40 -505.60 -5285.51 -5292.18 -5497.08 -5663.56 -5681.98 -6001.53 5958075.01 5958075.01 5957757.01 5958200.01 5959123.01 5958656.01 5957904.01 5957337.01 5957700.01 627052.99 627052.99 626450.99 624249.99 622405.99 622264.99 623728.99 626609.99 627278.99 DLS Build Turn deg/10OO deg/10OO deg/10OO 0.00 0.00 0.00 12.00 12.00 0.00 3.00 3.00 0.00 4.00 3.27 -6.79 0.00 0.00 0.00 0.00 0.00 0.00 15.00 14.90 1.88 0.00 0.00 0.00 13.00 13.00 -0.19 13.00 0.84 12.98 70 17 33.073 N 70 17 33.073 N 70 17 38.920 N 70 17 49.144 N 70 17 38.920 N 148 59 53.975 W 148 59 53.975 W 148 59 51.008 W 148 59 42.870 W 148 59 51.008 W 70 17 34.854 N 148 59 10.047 W 70 17 32.357 N 148 58 26.826 W 70 17 41.231 N 149 0 5.700W 70 17 37.513 N 70 17 37.513 N 70 17 34.485 N 70 17 39.203 N 70 17 48.578 N 70 17 44.008 N 70 17 36.376 N 70 17 30.328 N 70 17 33.787 N TFO Target deg 0.00 325.00 0.00 -92.27 0.00 U-06B T1 0.00 7.71 0.00 -0.84 U-06B T2 85.94 148 58 16.628 W 148 58 16.628 W 148 58 34.328 W 148 59 38.255 W 149 0 31.557 W 149 0 35.888 W 148 59 53.580 W 148 58 29.901 W 148 58 10.227 W . . Sperry-SUD BP Planning Report Company: BP Amoco Date: 3/31/2005 Time: 14:03:17 Page: 3 Field: Prudhoe Bay Co-ordinate(NE) Reference: Well: U-06, True North Site: PB U Pad Vertical (TVD) Reference: 48.5 + 28.5 77.0 Well: U-06 Section (VS) Reference: Well (0.00N.0.00E,266.00Azi) Wellpatb: Plan U-D6B Survey Calculation Metbod: Minimum Curvature Db: Oracle Plan Section Information MD Incl Azim TVD +N/-S +E/-W DLS Build Turn TFO Target ft deg deg ft ft ft deg/10OO deg/10OO deg/10OO deg 12630.93 92.75 287.80 9025.07 -3009.71 -6174.11 0.00 0.00 0.00 0.00 12759.14 90.00 282.00 9022.00 -2976.78 -6297.92 5.00 -2.14 -4.52 -115.27 U-06B T3 12772.55 89.34 282.13 9022.08 -2973.98 -6311.03 5.00 -4.90 0.98 168.70 13629.16 89.34 282.13 9031.90 -2793.97 -7148.45 0.00 0.00 0.00 0.00 13645.92 90.00 282.00 9032.00 -2790.47 -7164.84 4.00 3.92 -0.78 -11.30 U-06B T4 13715.87 92.41 280.57 9030.53 -2776.78 -7233.42 4.00 3.44 -2.04 -30.68 14357.09 92.41 280.57 9003.61 -2659.24 -7863.20 0.00 0.00 0.00 0.00 14576.16 90.00 289.00 8999.00 -2603.40 -8074.76 4.00 -1.10 3.85 105.82 U-06B T5 14799.34 85.54 296.74 9007.69 -2516.83 -8280.04 4.00 -2.00 3.47 120.06 14927.07 85.54 296.74 9017.62 -2459.53 -8393.76 0.00 0.00 0.00 0.00 15008.59 88.30 295.00 9022.00 -2424.01 -8467.00 4.00 3.38 -2.14 -32.29 U-06B T6 15011.43 88.23 295.09 9022.09 -2422.81 -8469.56 4.00 -2.42 3.18 127.29 15634.50 88.23 295.09 9041.32 -2158.73 -9033.58 0.00 0.00 0.00 0.00 15678.77 90.00 295.00 9042.00 -2139.99 -9073.68 4.00 3.99 -0.20 -2.92 U-06B T7 15727.37 91.94 295.01 9041.18 -2119.45 -9117.72 4.00 4.00 0.02 0.32 16734.85 91.94 295.01 9007.00 -1693.74 -10030.20 0.00 0.00 0.00 0.00 U-06B T8 Survey MD Incl Azim TVD Sys TVD N/S EIW DLS MapN MapE Tool/Comme t ft deg deg ft ft ft ft deg/100ft ft ft 3000.00 0.00 91.81 2999.86 2922.86 -17.60 12.28 0.00 5960672.62 632351.58 Start Dir 12°/1 3020.00 2.40 325.00 3019.85 2942.85 -17.26 12.03 12.00 5960672.96 632351.34 Start Dir 3°/10 3100.00 4.80 325.00 3099.69 3022.69 -13.14 9.15 3.00 5960677.02 632348.39 MWD+IFR+MS 3142.50 6.08 325.00 3142.00 3065.00 -9.84 6.84 3.00 5960680.28 632346.02 SV2 3200.00 7.80 325.00 3199.07 3122.07 -4.16 2.86 3.00 5960685.89 632341.93 MWD+IFR+MS 3250.00 9.30 325.00 3248.52 3171.52 1.93 -1.40 3.00 5960691.91 632337.56 Start Dir 40/10 3300.00 9.43 312.72 3297.85 3220.85 8.02 -6.73 4.00 5960697.90 632332.13 MWD+IFR+MS 3400.00 10.85 291.30 3396.32 3319.32 17.00 -21.53 4.00 5960706.62 632317.18 MWD+IFR+MS 3441.48 11.79 284.32 3437.00 3360.00 19.47 -29.27 4.00 5960708.95 632309.39 SV1 3500.00 13.35 276.29 3494.12 3417.12 21.69 -41.78 4.00 5960710.95 632296.85 MWD+IFR+MS 3600.00 16.45 266.36 3590.76 3513.76 22.06 -67.40 4.00 5960710.86 632271.23 MWD+IFR+MS 3700.00 19.86 259.64 3685.78 3608.78 18.10 -98.24 4.00 5960706.37 632240.46 MWD+IFR+MS 3800.00 23.45 254.86 3778.72 3701.72 9.85 -134.17 4.00 5960697.48 632204.69 MWD+IFR+MS 3900.00 27.15 251.30 3869.11 3792.11 -2.67 -175.01 4.00 5960684.24 632164.08 MWD+IFR+MS 4000.00 30.92 248.55 3956.53 3879.53 -19.39 -220.56 4.00 5960666.73 632118.84 MWD+IFR+MS 4100.00 34.74 246.34 4040.54 3963.54 -40.23 -270.60 4.00 5960645.01 632069.18 MWD+IFR+MS 4200.00 38.59 244.53 4120.74 4043.74 -65.09 -324.88 4.00 5960619.21 632015.35 MWD+IFR+MS 4208.03 38.90 244.40 4127.00 4050.00 -67.25 -329.41 4.00 5960616.96 632010.85 UG3 4300.00 42.47 243.00 4196.73 4119.73 -93.84 -383.14 4.00 5960589.43 631957.61 MWD+IFR+MS 4400.00 46.36 241.68 4268.15 4191.15 -126.35 -445.09 4.00 5960555.84 631896.24 MWD+IFR+MS 4492.76 49.98 240.60 4330.00 4253.00 -159.72 -505.60 4.00 5960521.41 631836.34 End Dir : 4492 4500.00 49.98 240.60 4334.66 4257.66 -162.45 -510.43 0.00 5960518.60 631831.55 MWD+IFR+MS 4600.00 49.98 240.60 4398.97 4321.97 -200.05 -577.15 0.00 5960479.84 631765.51 MWD+IFR+MS 4700.00 49.98 240.60 4463.27 4386.27 -237.65 -643.87 0.00 5960441.07 631699.47 MWD+IFR+MS 4800.00 49.98 240.60 4527.57 4450.57 -275.25 -710.58 0.00 5960402.30 631633.43 MWD+IFR+MS 4900.00 49.98 240.60 4591.88 4514.88 -312.85 -777.30 0.00 5960363.54 631567.39 MWD+IFR+MS 5000.00 49.98 240.60 4656.18 4579.18 -350.45 -844.02 0.00 5960324.77 631501.35 MWD+IFR+MS 5079.03 49.98 240.60 4707.00 4630.00 -380.16 -896.74 0.00 5960294.13 631449.16 UG1 5100.00 49.98 240.60 4720.48 4643.48 -388.05 -910.74 0.00 5960286.00 631435.31 MWD+IFR+MS 5200.00 49.98 240.60 4784.79 4707.79 -425.65 -977.45 0.00 5960247.24 631369.27 MWD+IFR+MS 5300.00 49.98 240.60 4849.09 4772.09 -463.25 -1044.17 0.00 5960208.47 631303.24 MWD+IFR+MS 5400.00 49.98 240.60 4913.40 4836.40 -500.85 -1110.89 0.00 5960169.70 631237.20 MWD+IFR+MS 5498.91 49.98 240.60 4977.00 4900.00 -538.04 -1176.88 0.00 5960131.36 631171.88 UG_MA (top S8) 5500.00 49.98 240.60 4977.70 4900.70 -538.45 -1177.61 0.00 5960130.94 631171.16 MWD+IFR+MS 5600.00 49.98 240.60 5042.00 4965.00 -576.05 -1244.32 0.00 5960092.17 631105.12 MWD+IFR+MS . . Sperry-Sun BP Planning Report Company: BP Amoco Date: 3/31/2005 Time: 14:03:17 Page: 4 Field: Prudhoe Bay Co-ordinate(NE) Reference: Well: U-06, True North Site: PB U Pad Vertical (TVD) Reference: 48.5 + 28.5 77.0 Well: U-06 Section (VS) Reference: Well (0.00N,0.OOE,266.00Azi) Wellpath: Plan U-06B Survey Calculation Method: Minimum Curvature Db: Oracle Survey MD Inel Azim TVD Sys TVD N/S EIW DLS MapN MapE TooI/Comme t ft deg deg ft ft ft ft deg/1 OOft ft ft 5700.00 49.98 240.60 5106.31 5029.31 -613.65 -1311.04 0.00 5960053.40 631039.08 MWD+IFR+MS 5800.00 49.98 240.60 5170.61 5093.61 -651 .25 -1377.76 0.00 5960014.64 630973.04 MWD+IFR+MS 5900.00 49.98 240.60 5234.92 5157.92 -688.85 -1444.47 0.00 5959975.87 630907.00 MWD+IFR+MS 6000.00 49.98 240.60 5299.22 5222.22 -726.45 -1511.19 0.00 5959937.10 630840.96 MWD+IFR+MS 6100.00 49.98 240.60 5363.52 5286.52 -764.05 -1577.91 0.00 5959898.34 630774.92 MWD+IFR+MS 6200.00 49.98 240.60 5427.83 5350.83 -801.65 -1644.63 0.00 5959859.57 630708.88 MWD+IFR+MS 6300.00 49.98 240.60 5492.13 5415.13 -839.26 -1711.34 0.00 5959820.80 630642.84 MWD+IFR+MS 6400.00 49.98 240.60 5556.44 5479.44 -876.86 -1778.06 0.00 5959782.04 630576.80 MWD+IFR+MS 6478.63 49.98 240.60 5607.00 5530.00 -906.42 -1830.52 0.00 5959751.55 630524.87 SB_OBF _base ~ 6500.00 49.98 240.60 5620.74 5543.74 -914.46 -1844.78 0.00 5959743.27 630510.76 MWD+IFR+MS 6600.00 49.98 240.60 5685.04 5608.04 -952.06 -1911.50 0.00 5959704.50 630444.72 MWD+IFR+MS 6700.00 49.98 240.60 5749.35 5672.35 -989.66 -1978.21 0.00 5959665.74 630378.68 MWD+IFR+MS 6800.00 49.98 240.60 5813.65 5736.65 -1027.26 -2044.93 0.00 5959626.97 630312.64 MWD+IFR+MS 6900.00 49.98 240.60 5877.95 5800.95 -1064.86 -2111.65 0.00 5959588.20 630246.60 MWD+IFR+MS 7000.00 49.98 240.60 5942.26 5865.26 -1102.46 -2178.37 0.00 5959549.43 630180.56 MWD+IFR+MS 7100.00 49.98 240.60 6006.56 5929.56 -1140.06 -2245.08 0.00 5959510.67 630114.52 MWD+IFR+MS 7200.00 49.98 240.60 6070.87 5993.87 -1177.66 -2311.80 0.00 5959471.90 630048.48 MWD+IFR+MS 7300.00 49.98 240.60 6135.17 6058.17 -1215.26 -2378.52 0.00 5959433.13 629982.45 MWD+IFR+MS 7400.00 49.98 240.60 6199.47 6122.47 -1252.86 -2445.24 0.00 5959394.37 629916.41 MWD+IFR+MS 7500.00 49.98 240.60 6263.78 6186.78 -1290.46 -2511.95 0.00 5959355.60 629850.37 MWD+IFR+MS 7600.00 49.98 240.60 6328.08 6251.08 -1328.06 -2578.67 0.00 5959316.83 629784.33 MWD+IFR+MS 7700.00 49.98 240.60 6392.39 6315.39 -1365.66 -2645.39 0.00 5959278.07 629718.29 MWD+IFR+MS 7800.00 49.98 240.60 6456.69 6379.69 -1403.26 -2712.10 0.00 5959239.30 629652.25 MWD+IFR+MS 7900.00 49.98 240.60 6520.99 6443.99 -1440.86 -2778.82 0.00 5959200.53 629586.21 MWD+IFR+MS 8000.00 49.98 240.60 6585.30 6508.30 -1478.46 -2845.54 0.00 5959161.77 629520.17 MWD+IFR+MS 8100.00 49.98 240.60 6649.60 6572.60 -1516.07 -2912.26 0.00 5959123.00 629454.13 MWD+IFR+MS 8200.00 49.98 240.60 6713.91 6636.91 -1553.67 -2978.97 0.00 5959084.23 629388.09 MWD+IFR+MS 8300.00 49.98 240.60 6778.21 6701.21 -1591.27 -3045.69 0.00 5959045.47 629322.05 MWD+IFR+MS 8400.00 49.98 240.60 6842.51 6765.51 -1628.87 -3112.41 0.00 5959006.70 629256.01 MWD+IFR+MS 8500.00 49.98 240.60 6906.82 6829.82 -1666.47 -3179.13 0.00 5958967.93 629189.97 MWD+IFR+MS 8531.39 49.98 240.60 6927.00 6850.00 -1678.27 -3200.07 0.00 5958955.77 629169.24 THRZ 8600.00 49.98 240.60 6971.12 6894.12 -1704.07 -3245.84 0.00 5958929.17 629123.93 MWD+IFR+MS 8700.00 49.98 240.60 7035.42 6958.42 -1741.67 -3312.56 0.00 5958890.40 629057.89 MWD+IFR+MS 8800.00 49.98 240.60 7099.73 7022.73 -1779.27 -3379.28 0.00 5958851.63 628991.85 MWD+IFR+MS 8900.00 49.98 240.60 7164.03 7087.03 -1816.87 -3446.00 0.00 5958812.87 628925.81 MWD+IFR+MS 8959.04 49.98 240.60 7202.00 7125.00 -1839.07 -3485.39 0.00 5958789.98 628886.82 LCU / BHRZ 9000.00 49.98 240.60 7228.34 7151.34 -1854.47 -3512.71 0.00 5958774.10 628859.77 MWD+IFR+MS 9100.00 49.98 240.60 7292.64 7215.64 -1892.07 -3579.43 0.00 5958735.33 628793.73 MWD+IFR+MS 9200.00 49.98 240.60 7356.94 7279.94 -1929.67 -3646.15 0.00 5958696.57 628727.69 MWD+IFR+MS 9300.00 49.98 240.60 7421.25 7344.25 -1967.27 -3712.87 0.00 5958657.80 628661.66 MWD+IFR+MS 9400.00 49.98 240.60 7485.55 7408.55 -2004.87 -3779.58 0.00 5958619.03 628595.62 MWD+IFR+MS 9402.25 49.98 240.60 7487.00 7410.00 -2005.72 -3781.09 0.00 5958618.16 628594.13 TKNG 9500.00 49.98 240.60 7549.86 7472.86 -2042.47 -3846.30 0.00 5958580.27 628529.58 MWD+IFR+MS 9600.00 49.98 240.60 7614.16 7537.16 -2080.07 -3913.02 0.00 5958541.50 628463.54 MWD+IFR+MS 9700.00 49.98 240.60 7678.46 7601.46 -2117.67 -3979.74 0.00 5958502.73 628397.50 MWD+IFR+MS 9800.00 49.98 240.60 7742.77 7665.77 -2155.27 -4046.45 0.00 5958463.97 628331 .46 MWD+IFR+MS 9900.00 49.98 240.60 7807.07 7730.07 -2192.88 -4113.17 0.00 5958425.20 628265.42 MWD+IFR+MS 10000.00 49.98 240.60 7871.38 7794.38 -2230.48 -4179.89 0.00 5958386.43 628199.38 MWD+IFR+MS 10008.75 49.98 240.60 7877.00 7800.00 -2233.76 -4185.72 0.00 5958383.04 628193.60 TJF 10100.00 49.98 240.60 7935.68 7858.68 -2268.08 -4246.60 0.00 5958347.67 628133.34 MWD+IFR+MS 10200.00 49.98 240.60 7999.98 7922.98 -2305.68 -4313.32 0.00 5958308.90 628067.30 MWD+IFR+MS 10300.00 49.98 240.60 8064.29 7987.29 -2343.28 -4380.04 0.00 5958270.13 628001.26 MWD+IFR+MS 10319.77 49.98 240.60 8077.00 8000.00 -2350.71 -4393.23 0.00 5958262.47 627988.20 TJE . . Sperry-Sun BP Planning Report Company: BPAmöco Date: 3/31/2005 Time: 14:03:17 Page: 5 Field: Prudhoe Bay Co-ordinate(NE) Reference: Well: U-06, True North Site: PB U Pad Vertical (TVD) Reference: 48.5 + 28.5 77.0 Well: U-06 Section (VS) Reference: Well (O.00N,O.00E,266.00Azi) Wellpath: Plan U-06B Survey Calculation Method: Minimum Curvature Db: Oracle Survey MD Incl Azim TVD Sys TVD N/S E/W DLS MapN MapE ToolIComme t ft deg deg ft ft ft ft deg/10OO ft ft 10400.00 49.98 240.60 8128.59 8051.59 -2380.88 -4446.76 0.00 5958231.37 627935.22 MWD+IFR+MS 10500.00 49.98 240.60 8192.89 8115.89 -2418.48 -4513.47 0.00 5958192.60 627869.18 MWD+IFR+MS 10600.00 49.98 240.60 8257.20 8180.20 -2456.08 -4580.19 0.00 5958153.83 627803.14 MWD+IFR+MS 10700.00 49.98 240.60 8321.50 8244.50 -2493.68 -4646.91 0.00 5958115.07 627737.10 MWD+IFR+MS 10739.65 49.98 240.60 8347.00 8270.00 -2508.59 -4673.36 0.00 5958099.70 627710.92 TJD 10800.00 49.98 240.60 8385.81 8308.81 -2531.28 -4713.63 0.00 5958076.30 627671.06 MWD+IFR+MS 10900.00 49.98 240.60 8450.11 8373.11 -2568.88 -4780.34 0.00 5958037.53 627605.02 MWD+IFR+MS 11000.00 49.98 240.60 8514.41 8437.41 -2606.48 -4847.06 0.00 5957998.77 627538.98 MWD+IFR+MS 11100.00 49.98 240.60 8578.72 8501.72 -2644.08 -4913.78 0.00 5957960.00 627472.94 MWD+IFR+MS 11156.42 49.98 240.60 8615.00 8538.00 -2665.30 -4951.42 0.00 5957938.13 627435.68 U-06B Fault 1 11200.00 49.98 240.60 8643.02 8566.02 -2681.68 -4980.50 0.00 5957921.23 627406.91 MWD+IFR+MS 11206.19 49.98 240.60 8647.00 8570.00 -2684.01 -4984.62 0.00 5957918.84 627402.82 TJC 11300.00 49.98 240.60 8707.33 8630.33 -2719.28 -5047.21 0.00 5957882.47 627340.87 MWD+IFR+MS 11400.00 49.98 240.60 8771.63 8694.63 -2756.88 -5113.93 0.00 5957843.70 627274.83 MWD+IFR+MS 11408.35 49.98 240.60 8777.00 8700.00 -2760.02 -5119.50 0.00 5957840.46 627269.31 TJB 11500.00 49.98 240.60 8835.93 8758.93 -2794.48 -5180.65 0.00 5957804.93 627208.79 MWD+IFR+MS 11517.21 49.98 240.60 8847.00 8770.00 -2800.95 -5192.13 0.00 5957798.26 627197.42 TJA 11600.00 49.98 240.60 8900.24 8823.24 -2832.08 -5247.37 0.00 5957766.17 627142.75 MWD+IFR+MS 11649.39 49.98 240.60 8932.00 8855.00 -2850.66 -5280.32 0.00 5957747.02 627110.13 7" 11657.17 49.98 240.60 8937.00 8860.00 -2853.58 -5285.51 0.00 5957744.01 627104.99 U-06B T1 11667.17 49.98 240.60 8943.43 8866.43 -2857.34 -5292.18 0.00 5957740.13 627098.39 Start Dir 15°/1 11689.02 53.23 241.14 8957.00 8880.00 -2865.68 -5307.14 15.00 5957731.53 627083.58 TSHU 11700.00 54.86 241 .40 8963.45 8886.45 -2869.95 -5314.93 15.00 5957727.13 627075.86 MWD+IFR+MS 11724.69 58.54 241.95 8977.00 8900.00 -2879.74 -5333.10 15.00 5957717.02 627057.87 U-06B Fault A 11800.00 69.76 243.39 9009.78 8932.78 -2910.77 -5393.22 15.00 5957684.94 626998.31 MWD+IFR+MS 11822.69 73.15 243.78 9017.00 8940.00 -2920.34 -5412.49 15.00 5957675.03 626979.22 TElL 11854.73 77.92 244.30 9025.00 8948.00 -2933.91 -5440.37 15.00 5957660.97 626951.58 U-06B Fault 2 11864.92 79.44 244.47 9027.00 8950.00 -2938.23 -5449.39 15.00 5957656.49 626942.64 TSAD 11900.00 84.68 245.02 9031.84 8954.84 -2953.05 -5480.79 15.00 5957641.12 626911.50 MWD+IFR+MS 11917.99 87.36 245.30 9033.09 8956.09 -2960.59 -5497.08 15.00 5957633.30 626895.35 End Dir : 1191 12000.00 87.36 245.30 9036.87 8959.87 -2994.82 -5571.51 0.00 5957597.76 626821.55 MWD+IFR+MS 12100.00 87.36 245.30 9041.47 8964.47 -3036.56 -5662.26 0.00 5957554.43 626731.55 MWD+IFR+MS 12101.43 87.36 245.30 9041.53 8964.53 -3037.16 -5663.56 0.00 5957553.81 626730.26 Start Dir 13°/1 12121.72 90.00 245.26 9042.00 8965.00 -3045.64 -5681.98 13.00 5957545.01 626711.99 U-06B T2 12200.00 90.72 255.41 9041.51 8964.51 -3071.95 -5755.60 13.00 5957517.41 626638.86 MWD+IFR+MS 12300.00 91.60 268.38 9039.48 8962.48 -3086.01 -5854.37 13.00 5957501.61 626540.36 MWD+IFR+MS 12400.00 92.39 281.37 9035.99 8958.99 -3077.54 -5953.73 13.00 5957508.33 626440.87 MWD+IFR+MS 12449.47 92.75 287.80 9033.77 8956.77 -3065.10 -6001.53 13.00 5957519.92 626392.86 End Dir : 1244 12500.00 92.75 287.80 9031.35 8954.35 -3049.68 -6049.59 0.00 5957534.50 626344.54 MWD+IFR+MS 12600.00 92.75 287.80 9026.56 8949.56 -3019.15 -6144.70 0.00 5957563.34 626248.92 MWD+IFR+MS 12630.93 92.75 287.80 9025.07 8948.07 -3009.71 -6174.11 0.00 5957572.26 626219.35 Start Dir 5°/10 12700.00 91.27 284.67 9022.65 8945.65 -2990.42 -6240.38 5.00 5957590.38 626152.75 MWD+IFR+MS 12759.14 90.00 282.00 9022.00 8945.00 -2976.78 -6297.92 5.00 5957603.01 626094.99 U-06B T3 12772.55 89.34 282.13 9022.08 8945.08 -2973.98 -6311.03 5.00 5957605.58 626081.84 End Dir : 1277 12800.00 89.34 282.13 9022.39 8945.39 -2968.21 -6337.86 0.00 5957610.87 626054.90 MWD+IFR+MS 12900.00 89.34 282.13 9023.54 8946.54 -2947.19 -6435.62 0.00 5957630.16 625956.79 MWD+IFR+MS 13000.00 89.34 282.13 9024.69 8947.69 -2926.18 -6533.38 0.00 5957649.45 625858.69 MWD+IFR+MS 13100.00 89.34 282.13 9025.83 8948.83 -2905.17 -6631.15 0.00 5957668.73 625760.58 MWD+IFR+MS 13200.00 89.34 282.13 9026.98 8949.98 -2884.15 -6728.91 0.00 5957688.02 625662.47 MWD+IFR+MS 13300.00 89.34 282.13 9028.13 8951.13 -2863.14 -6826.67 0.00 5957707.31 625564.36 MWD+IFR+MS 13400.00 89.34 282.13 9029.27 8952.27 -2842.12 -6924.43 0.00 5957726.60 625466.26 MWD+IFR+MS 13500.00 89.34 282.13 9030.42 8953.42 -2821.11 -7022.19 0.00 5957745.88 625368.15 MWD+IFR+MS . Sperry-Sun BP Planning Report . Company: BP Amoco Date: 3/31/2005 Time: 14:03:17 Page: 6 Field: Prudhoe Bay Co-ordinate(NE) Reference: Well: U-06. True North Site: PB U Pad Vertical (TVD) Reference: 48.5 + 28.5 77.0 Well: U-06 Secôon (VS) Reference: Well (0.00N.0.00E.266.00Azi) Wellpatb: Plan U-06B Survey Calculation Metbod: Minimum Curvature Db: Oracle Survey MD Inel Azim TVD Sys TVD N/S EIW DLS MapN MapE ToolIComme t ft deg deg ft ft ft ft deg/10OO ft ft 13600.00 89.34 282.13 9031.57 8954.57 -2800.10 -7119.95 0.00 5957765.17 625270.04 MWD+IFR+MS 13629.16 89.34 282.13 9031.90 8954.90 -2793.97 -7148.45 0.00 5957770.79 625241.44 Start Dir 4°/10 13645.92 90.00 282.00 9032.00 8955.00 -2790.47 -7164.84 4.00 5957774.01 625224.99 U-06B T4 13700.00 91.86 280.90 9031.12 8954.12 -2779.73 -7217.84 4.00 5957783.80 625171.82 MWD+IFR+MS 13715.87 92.41 280.57 9030.53 8953.53 -2776.78 -7233.42 4.00 5957786.48 625156.19 End Dir : 1371 13800.00 92.41 280.57 9027.00 8950.00 -2761.36 -7316.05 0.00 5957800.45 625073.31 MWD+IFR+MS 13900.00 92.41 280.57 9022.80 8945.80 -2743.03 -7414.26 0.00 5957817.04 624974.79 MWD+IFR+MS 14000.00 92.41 280.57 9018.60 8941.60 -2724.70 -7512.48 0.00 5957833.64 624876.27 MWD+IFR+MS 14100.00 92.41 280.57 9014.40 8937.40 -2706.37 -7610.70 0.00 5957850.23 624777.76 MWD+IFR+MS 14200.00 92.41 280.57 9010.20 8933.20 -2688.04 -7708.91 0.00 5957866.83 624679.24 MWD+IFR+MS 14300.00 92.41 280.57 9006.01 8929.01 -2669.71 -7807.13 0.00 5957883.43 624580.73 MWD+IFR+MS 14357.09 92.41 280.57 9003.61 8926.61 -2659.24 -7863.20 0.00 5957892.90 624524.49 Start Dir 4°/10 14400.00 91.94 282.22 9001.98 8924.98 -2650.77 -7905.23 4.00 5957900.63 624482.31 MWD+IFR+MS 14500.00 90.84 286.07 8999.56 8922.56 -2626.34 -8002.15 4.00 5957923.35 624384.99 MWD+IFR+MS 14576.16 90.00 289.00 8999.00 8922.00 -2603.40 -8074.76 4.00 5957945.01 624311.99 U-06B T5 14600.00 89.52 289.83 8999.10 8922.10 -2595.47 -8097.24 4.00 5957952.54 624289.37 MWD+IFR+MS 14700.00 87.52 293.29 9001.68 8924.68 -2558.75 -8190.20 4.00 5957987.61 624195.79 MWD+IFR+MS 14799.34 85.54 296.74 9007.69 8930.69 -2516.83 -,8280.04 4.00 5958027.94 624105.23 End Dir : 1479 14800.00 85.54 296.74 9007.74 8930.74 -2516.53 -8280.63 0.00 5958028.23 624104.64 MWD+IFR+MS 14900.00 85.54 296.74 9015.52 8938.52 -2471.67 -8369.66 0.00 5958071.51 624014.84 MWD+IFR+MS 14927.07 85.54 296.74 9017.62 8940.62 -2459.53 -8393.76 0.00 5958083.22 623990.53 Start Dir 4°/10 15000.00 88.01 295.18 9021.72 8944.72 -2427.66 -8459.22 4.00 5958113.94 623924.52 MWD+IFR+MS 15008.59 88.30 295.00 9022.00 8945.00 -2424.01 -8467.00 4.00 5958117.44 623916.69 U-06B T6 15011.43 88.23 295.09 9022.09 8945.09 -2422.81 -8469.56 4.00 5958118.59 623914.10 End Dir : 1501 15100.00 88.23 295.09 9024.82 8947.82 -2385.27 -8549.74 0.00 5958154.72 623833.28 MWD+IFR+MS 15200.00 88.23 295.09 9027.91 8950.91 -2342.89 -8640.26 0.00 5958195.50 623742.03 MWD+IFR+MS 15300.00 88.23 295.09 9030.99 8953.99 -2300.50 -8730.78 0.00 5958236.28 623650.79 MWD+IFR+MS 15400.00 88.23 295.09 9034.08 8957.08 -2258.12 -8821.31 0.00 5958277.06 623559.54 MWD+IFR+MS 15500.00 88.23 295.09 9037.17 8960.17 -2215.74 -8911.83 0.00 5958317.84 623468.29 MWD+IFR+MS 15600.00 88.23 295.09 9040.25 8963.25 -2173.35 -9002.35 0.00 5958358.62 623377.05 MWD+IFR+MS 15634.50 88.23 295.09 9041.32 8964.32 -2158.73 -9033.58 0.00 5958372.69 623345.57 Start Dir 4°/10 15678.77 90.00 295.00 9042.00 8965.00 -2139.99 -9073.68 4.00 5958390.71 623305.14 U-06B T7 15700.00 90.85 295.00 9041.84 8964.84 -2131.02 -9092.92 4.00 5958399.34 623285.75 MWD+IFR+MS 15727.37 91.94 295.01 9041.18 8964.18 -2119.45 -9117.72 4.00 5958410.47 623260.75 End Dir : 1572 15800.00 91.94 295.01 9038.71 8961.71 -2088.76 -9183.50 0.00 5958440.00 623194.45 MWD+IFR+MS 15900.00 91.94 295.01 9035.32 8958.32 -2046.51 -9274.07 0.00 5958480.65 623103.16 MWD+IFR+MS 16000.00 91.94 295.01 9031.93 8954.93 -2004.25 -9364.64 0.00 5958521.30 623011.86 MWD+IFR+MS 16100.00 91.94 295.01 9028.54 8951.54 -1962.00 -9455.21 0.00 5958561.95 622920.57 MWD+IFR+MS 16200.00 91.94 295.01 9025.14 8948.14 -1919.74 -9545.78 0.00 5958602.60 622829.28 MWD+IFR+MS 16300.00 91.94 295.01 9021.75 8944.75 -1877.49 -9636.35 0.00 5958643.24 622737.98 MWD+IFR+MS 16400.00 91.94 295.01 9018.36 8941.36 -1835.23 -9726.92 0.00 5958683.89 622646.69 MWD+IFR+MS 16500.00 91.94 295.01 9014.97 8937.97 -1792.98 -9817.49 0.00 5958724.54 622555.40 MWD+IFR+MS 16600.00 91.94 295.01 9011.57 8934.57 -1750.72 -9908.06 0.00 5958765.19 622464.10 MWD+IFR+MS 16700.00 91.94 295.01 9008.18 8931.18 -1708.47 -9998.63 0.00 5958805.84 622372.81 MWD+IFR+MS 16734.00 91.94 295.01 9007.03 8930.03 -1694.10 -1 0029.43 0.00 5958819.66 622341.77 41/2" 16734.85 / 91.94 295.01 9007.00 8930.00 -1693.74 -10030.20 0.00 5958820.01 622340.99 U-06B T8 . 1) 2) 3) . . SO"IO ALASKA PETROLEUM COMPANY WELLHEAD LOCATION DATA WELL U-6 Pad U Wellhead Location 103 NSL 1663 WEL x = 632339 y = 5960690 LAT. 700 18' 02.333" LONG. 1480 55' 41.248~ 4) Bearing of·Gyro Marker 5) Local Benchmark Elevation 6) Top Edge of Cellar * 7) Base Flange Elevation 8) Kelly Bushing Elevation N 540 03' w** (True) 48.68' Bolt Nnrt"hcdrte- Ft. AMSL Term Well B X-mas Tree 47.50' Nnrth!'::itlp Ft. AMSL ~ß . ~O g.4,~ Ft. AMSL Ft. At-'SL Base Flange and Kelly Bushing NOT Installed This Date. ** Gyro Marker = Term Well B * NOTES: 1) Items 1 and 2 should be filled in by the Drilling Supervisor on the rig when a new well spuds in. 2) The surveyor should fill in Items 3. 4. 5 and 6. 3) 4) 5) The completed form should be returned to Drilling Dept. for distribution. The bearing of the Gyro Harker is requi red as a True. not a J.1agnetic beadng. Base Flange and Kelly Bushing Elevations measured by the Drilling Supervisor. . ~ ""',;\~ ._-.... OF At.. ,;\\ ~~f". ........... -1.s-. t, -..f........ t" tj"...~ 7. :r i::!".O '. '.. ..-~ I ",. -" .. . .,,'" ~ /II." l.. ~ * '. " -æ:" : '. ~...:... "7 ........",(7. -,. ° ~ ~ ....... ~. .lJ.:~" .0j! r. OJ .~i! t ~ ':. ary L McNeIl .: ~ ~ .... .... .. . "'5121 .0 ~ '" "JI~~ ... .- .0 ~,.- .~ t"., .... ..' ~.. ., .....0 IJ. ...-.... ..",~ _ ", ~!)'CSSID!C,.'- \.: _- '\.~-...~"'~.. C] Rf.ULATJON: ,-...." District Field Engineer - 2 District Drilling [ngineer/Dlilling Engineer - 1 Slope - to ~ig for ~osting - 2 ~ell Record Clerk. r.eology - 1 '~e 11 Fil es Engineering Associate. Drilling - Original Petroleum Engineering. SFO -1 E1len M. Hi ller fl.tA¥ã I.."IJU ate I WELL PRODUCER .. WELL INJECTOR ... DATE: 01/16/2005 SCALE: 1" 200' MAP DATE: 2003 UNIT - U bs14495.dgn . ., 1:1. è 5 èOOObOl:qql.1.'" b è è? . FifstNatiOt'lal Ban\<. Alas\<.a AnchOfage. þ$ 99'50" MEMO \.r{j~b 1ERR\E L HUBBLE BPEXI'LORA 1\ONAK 'NC pC 6CX~9ôM 2 Me 7-5 ANCHORAGE.. AK 99519-6612 '" l.SSb"· MastercaróC\-\eCk" 01.q1. D",1E 89_611252 '\94 . . TRANSMIT AL LETTER CHECK LIST CIRCLE APPROPRIATE LETTER/P ARAGRAPHS TO BE INCLUDED IN TRANSMITTAL LETTER WELLNAME~Cf Ú-06.ß PTD# ..:;2.0,<) - CJ b Y CHECK WHAT ADD-ONS "CLUE" APPLIES (OPTIONS) MULTI The permit is for a new wellbore segment of LATERAL existing well_, Permit No, API No. . (If API number Production should continue to be reported as last two (2) digits a function of the original API number stated are between 60-69) above. PILOT HOLE In accordance with 20 AAC 25.005(t), all (PH) records, data and logs acquired for the pilot hole must be clearly differentiated in both name (name on permit plus PH) and API number (50 - 70/80) from records, data and logs acquired for well (name on permit). SPACING The permit is approved subject to full EXCEPTION compliance with 20 AAC 25.055. Approval to perforate and produce/iniect is contingent upon issuance of a conservation order approving a spacing exception. (Company Name) assumes the liability of any protest to the spacing exception that may occur. DRY DITCH All dry ditch sample sets submitted to the SAMPLE Commission must be in no greater than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. Rev: 04/01105 C\jody\trans m ittal_ checklist . . Well bore seg 0 Annular Disposal 0 Well Name: PRUDHOE BAY UNIT U-06B Program DEV. ALASKA) INC Initial ClasslType _DEV fj~GeoArea 890 Unit 11650 On/Off Shore Dn Administration Yes - - - - - 2 .Lease .numberappropriate. . Yes. . . . 3 .U.n[q!Je weltn.ame.aoQ OUlTJb.er . . . . . . . . ...... .Y.es.. - - - - - - - - - - - - - - ~ - - - - 4 WeUJQcated [na.d.efil1e~Lp.o01 . . Yes 5 WeJUQcated prQperdistance from driJling uoitb.o!Jl1d.ary. . . Yes 6 WeUJQcated pr.oper .d[stance. from Qtber wells. . Yes. . 7 .Sutficiel1tacrea~e.aYailable [n.drilliog unit. . . ... Yes. 8 Kdeviated, isweJlbQre platil1cJu.deQ . . - - -- . . Yes. . 9 .OJ)erator 0111" affected party. . . . . Yes. 10 .DJ)erator bé!s.apprQpriate.Qond inJQrce . . . . . . . . . . .. . . .... .Yes.. . - - . - - - - - - - - - - - - - -- 11 PelJT)it ~ao be issued witbQut co.nservatioo order. . Yes Appr Date 12 PelJT)it c.ao be issued witbQut ad.mil1istratille.appr.ovaJ . . Yes. - - - - - - - -- RPC 4/20/2005 13 Can permit be approved before 15-day wait Yes 14 WellJQcated withil1 area an.d.strataauthorized by.lnjecti.oo Order # (put 10# [n.cQmments) (for NA - - -- 15 All welJs.witJ1inJ14.n:Jite.area.oJ reyiew id.eotified (Fou~efVice.we[lol1l,,>- . . . . . . _ . . _ . . .NA. . - - - - - - - - - - - - - - - - - -- 16 Pre-produ.ced. injector; duration of pre-J)roductiol1 less. tÞal13 mOl1tbs (for.servlce welt Qnly) NA.. - - - - - 17 AÇMPJ)l1djng .of CQn.si$teocy.h.as beenj$sued. forJbis project . . NA - - - - - -- Engineering 18 .C.ooQu.ctor stril1g.prQv[ded . . - - - - - .NA - - - - - - - -- - - - - - 19 .Surface .casil1g protects alLknowl1 USDWs . NA 20 CMT. v.ot é!deQuateJo circ.utate.oncooduct.or Be surf.C$9 . . . . NA. - - - - - 21 .CMT. v.ot adeQ u.ateJo tie-ln JQngstriog to .s!Jrf csg . . NA. - - - - - - 22 .CMT will coyeraJll<l1ow.npro.ductiye bQrizol1s . . . . . . . No. SI.ottedJiner.. . 23 .C.asing de.signs ad.eQua.te f.or C,T, B&.permafrost . .Yes. . 24 Adequatetan.kage.or re.serve pit. . Yes lIIabofS.7ES. . . 25 Jf.are-drill~ basa. 10,.403 JQr abandonment beeo approved. . Yes 4/7/2005. . - - - - - 26 Adequatewe[lQore $eparation.proJ)osed. . . . . _ . . . . . . . . _ . . _ . .Yes __ . - - - - - - - - - - - - - - - - - . 27 Kdiverter required, dQes it meet reguJatiol1s. . . . . . . . . . . . NA Sidetrack. . Appr Date 28 .Drilliog fluid. pro~ram schematic & equip Jistadequate. . . . . . .Yes Max MW 1U .ppg.. . . WGA 4/20/2005 29 BQPES,do.they meetreguJatiol1 . - - - - - - - - - Yes - - - - 30 .BQPE.press rajing approprié!te;test to.(put PSig In.commel1ts>- .Yes. Test to .3500 ps[.MSf> 25.D7 psi 31 .C.hQ çe.mé!nifold cQmpJies. w/APtRf>-53 (May 64>- Yes. . - - - - 32 WQr ç will .occur withoytoperatjonsbutdown. . - - - - - Yes - - - - - - - - - 33 J$ presence. oJ H2S gas. proQable. . - - - -- - - - - - Yes. 180ppmon pad. 34 Mecha.n[caLcoodjt[oflof wells withil1 AOR yeriJied. (for service w~1J only) NA - Geology 35 PelJT)it can be issued w/Q hydrogen s.ulfide meas.ures . - - - - - No 36 .D.atapreseoted. Qn pote.ntié!l oveJpre$sur~ .zOl1e$. . NA Appr Date 37 .Seismic.analysis. Qf sbaJlow gas.zpoes. . NA RPC 4/20/2005 38 SeabedcOl1dítipo survey.(if oft-shore) . .NA - - -- 39 . CQntacll1amelpÞoneJQr.we~~ly pr.ogress.reports [explQratpry .0fllYl NA - Geologic Date: Engineering Date Commissioner: Commissioner: Pr~ 4-/2.// S . . Well 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. e e U06B005302005SSN.txt Sperry-sun Drilli~g.services LIS Scan Utlllty $Revision: 3 $ LisLib $Revision: 4 $ Tue Jun 12 07:49:45 2007 Reel Header service name.. ..... .... ..LISTPE Date. . . . . . . . . . . . . . . . . . . . .07/06/12 ori gi n. . . . . . . . . . . . . . . . . . . STS Reel Name...... ..........UNKNOWN Continuation Number..... .01 Previous Reel Name...... . UNKNOWN Comments........ .........STS LIS writing Library. scientific Technical Services Tape Header service name. ............LISTPE Date. . . . . . . . . . . . . . . . . . . . .07/06/12 ori gi n . . . . . . . . . . . . . . . . . . . STS Tape Name......... ..... ..UNKNOWN continuation Number......Ol previous Tape Name.......UNKNOWN Comments................ .STS LIS writing Library. Scientific Technical Services physical EOF Comment Record TAPE HEADER Prudhoe Bay (WOA) MWD/MAD LOGS # WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: # JOB DATA U-06B 500292111702 BP Exploration (Alaska) Inc. sperry Drilling Services 11-JUN-07 JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 1 w-0003684031 D. RICHARDSO J. RALL MWD RUN 2 W-0003684031 N. WHITE J. RALL MWD RUN 3 w-0003684031 D. RICHARDSO J. RALL JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 4 w-0003684031 J. BOBBITT J. RALL # SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: 18 11N BE 5176 1662 Page 1 ~-ó(¡,4{ "'" 6-~% e e U06B005302005SSN.txt ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: 76.63 48.80 # WELL CASING RECORD 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 6.125 7.000 11533.0 # REMARKS: 1. ALL DEPTHS ARE BIT DEPTHS UNLESS OTHERWISE NOTED. THESE DEPTHS ARE MEASURED DEPTH (MD). 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTH (TVD). 3. THIS WELLBORE WAS EFFECTED BY DRILLING OFF OF A CEMENT PLUG, THE TOP OF WHICH WAS AT THE 7" CASING SHOE (11533'MD/8865'TVD) IN THE U-06B WELLBORE. THE ACTUAL PLANNED KOP WAS 11535'MD. 4. MWD RUNS 1-4 COMPRISED DIRECTIONAL, DUAL GAMMA RAY (DGR) UTILIZING GEIGER- MUELLER TUBE DETECTORS, ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4), AND AT-BIT INCLINATION (ABI). 5. DEPTH SHIFTING FOR THIS WELL WAS WAIVED PER E-MAIL FROM D. DORTCH (SAIC/BP) DATED 4/11/07, QUOTING AUTHORIZATION FROM COLE ABEL (BP). THIS LOG IS THE SDCL FOR U-06B. 6. MWD RUNS 1-4 REPRESENT WELL U-06B WITH API#: 50-029-21117-02. THIS WELL REACHED A TOTAL DEPTH (TD) OF 15229'MD/9020'TVD. SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRC = SMOOTHED GAMMA RAY COMBINED. SEXP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (EXTRA SHALLOW SPACING). SESP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (SHALLOW SPACING). SEMP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (MEDIUM SPACING). SEDP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (DEEP SPACING). SFXE = SMOOTHED FORMATION EXPOSURE TIME. SLIDE = NON-ROTATED INTERVALS REFLECTING BIT DEPTHS. $ File Header service name... ..........STSLIB.001 service Sub Level Name... Page 2 e e U06B005302005SSN.txt version Number.......... .1.0.0 Date of Generation.......07/06/12 Maximum physical Record. .65535 Fi 1 e Type. . . . . . . . . . . . . . . . LO Previous File Name...... .STSLIB.OOO comment Record FILE HEADER FILE NUMBER: EDITED MERGED MWD Depth shifted and DEPTH INCREMENT: # FILE SUMMARY PBU TOOL CODE GR RPD RPS RPM FET RPX ROP $ 1 clipped curves; all bit runs merged. .5000 START DEPTH 11483.5 11515.0 11515.0 11515.0 11515.0 11515.0 11535.5 STOP DEPTH 15177 . 0 15184.0 15184.0 15184.0 15184.0 15184.0 15229.0 # BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --- BASELINE DEPTH $ # MERGED DATA SOURCE PBU TOOL CODE BIT RUN NO MERGE TOP MERGE BASE MWD 1 11483.5 11813.0 MWD 2 11813.0 13035.0 MWD 3 13035.0 13492.0 MWD 4 13492.0 15229.0 $ # REMARKS: MERGED MAIN PASS. $ # Data Format specification Record Data Record Type..................O Data specification Block Type.....O Log~ing Direction... ............. . Down optlcal log depth units...........Feet Data Reference point........ ..... .undefined Frame spacing... ..................60 .1IN Max frames per record...... ...... .undefined Absent value... .............. .....-999 Depth Uni ts. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O Name service Order units Size Nsam Rep code offset Channel DEPT FT 4 1 68 0 1 RPD MWD OHMM 4 1 68 4 2 RPM MWD OHMM 4 1 68 8 3 RPS MWD OHMM 4 1 68 12 4 RPX MWD OHMM 4 1 68 16 5 FET MWD HOUR 4 1 68 20 6 GR MWD API 4 1 68 24 7 ROP MWD FT/H 4 1 68 28 8 page 3 e e U06B005302005SSN.txt Fi rst Last Name service unit Min Max Mean Nsam Reading Reading DEPT FT 11483.5 15229 13356.3 7492 11483.5 15229 RPD MWD OHMM 0.11 2000 21. 3388 7339 11515 15184 RPM MWD OHMM 0.09 2000 16.9172 7339 11515 15184 RPS MWD OHMM 0.63 1729.18 14.2943 7339 11515 15184 RPX MWD OHMM 0.48 2000 19.3874 7339 11515 15184 FET MWD HOUR 0.31 17.8 1.90198 7339 11515 15184 GR MWD API 16.18 545.96 46.271 7388 11483.5 15177 ROP MWD FT/H 0.14 408.07 68.8454 7388 11535.5 15229 First Reading For Entire File..........11483.5 Last Reading For Entire File... ........15229 Fi 1 e Trail er Service name... ..........STSLIB.001 service sub Level Name... version Number...... .....1.0.0 Date of Generation...... .07/06/12 Maximum physical Record. .65535 File Type... ............ .LO Next File Name..... ..... .STSLIB.002 physical EOF File Header service name.... .........STSLIB.002 service sub Level Name... version Number. ..........1.0.0 Date of Generation.......07/06/12 Maximum physical Record..65535 File Type...... ..........LO previous File Name.......STSLIB.001 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE GR RPD RPM RPX RPS FET ROP $ 2 header data for each bit run in separate files. 1 .5000 START DEPTH 11483.5 11515.0 11515.0 11515.0 11515.0 11515.0 11535.5 STOP DEPTH 11761. 0 11768.0 11768.0 11768.0 11768.0 11768.0 11813.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: 24-MAY-05 Insite Page 4 e e U06B005302005SSN.txt DOWNHOLE SOFTWARE VERSION: 66.37 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 11813.0 TOP LOG INTERVAL (FT): 11533.0 BOTTOM LOG INTERVAL (FT): 11813.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 51.3 MAXIMUM ANGLE: 65.7 # TOOL STRING (TOP TO VENDOR TOOL CODE DGR EWR4 $ BOTTOM) TOOL TYPE DUAL GAMMA RAY Electromag Resis. 4 # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # # # REMARKS: $ # Data Format specification Record Data Record Type............ ......0 Data specification Block Type.....O Log~ing Direction........ ....... ..Down Optlcal log depth units...... .....Feet Data Reference Point..... .........undefined Frame spacing....... ............. .60 .1IN Max frames per record.............undefined Absent val ue. . . . . . . . . . . . . . . . . . . . . . - 999 Depth uni ts . . . . . . . . . . . . . . . . . . . . . . . Datum specification Block sub-type...O TOOL NUMBER 160788 156404 6.125 11533.0 Flopro 8.50 47.0 9.9 6700 11.0 .800 .440 .700 1. 200 70.0 132.8 70.0 70.0 Name Service order Units size Nsam Rep code offset channel DEPT FT 4 1 68 0 1 RPD MWD010 OHMM 4 1 68 4 2 RPM MWD010 OHMM 4 1 68 8 3 RPS MWD010 OHMM 4 1 68 12 4 RPX MWD010 OHMM 4 1 68 16 5 FET MWD010 HOUR 4 1 68 20 6 page 5 GR MWD010 ROP MWD010 Name service unit DEPT FT RPD MWD010 OHMM RPM MWD010 OHMM RPS MWD010 OHMM RPX MWD010 OHMM FET MWD010 HOUR GR MWD010 API ROP MWDOlO FT/H e e U06B005302005SSN.txt API 4 1 68 24 7 FT/H 4 1 68 28 8 Fi rst Last Min Max Mean Nsam Reading Reading 11483.5 11813 11648.3 660 11483.5 11813 0.55 2000 154.43 507 11515 11768 0.09 2000 109.255 507 11515 11768 0.63 1352.46 62.8412 507 11515 11768 0.65 732.85 49.0565 507 11515 11768 0.77 4.31 2.37264 507 11515 11768 28.5 545.96 130.384 556 11483.5 11761 2.71 111.34 36.247 556 11535.5 11813 First Reading For Entire File... .......11483.5 Last Reading For Entire File.... .......11813 File Trailer service name. ............STSLIB.002 service sub Level Name... version Number...........1.0.0 Date of Generation.......07/06/12 Maximum physical Record..65535 Fi 1 e Type... . . . . . . . . . . . . . LO Next File Name.......... .STSLIB.003 physical EOF File Header Service name.... .........STSLIB.003 Service sub Level Name... version Number. ..........1.0.0 Date of Generation.......07/06/12 Maximum physical Record..65535 Fi 1 e Type. . . . . . . . . . . . . . . . LO previous File Name.......STSLIB.002 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE GR RPX FET RPM RPD RPS ROP $ # LOG HEADER DATA 3 header data for each bit run in separate files. 2 .5000 START DEPTH 11761. 5 11768.5 11768.5 11768.5 11768.5 11768.5 11813 . 5 STOP DEPTH 12983.0 12990.0 12990.0 12990.0 12990.0 12990.0 13035.0 page 6 e e U06B005302005SSN.txt 27-MAY-05 DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE DGR EWR4 $ BOTTOM) TOOL TYPE DUAL GAMMA RAY Electromag Resis. 4 # # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (s): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format specification Record Data Record Type............. .....0 Data specification Block Type.....O Log~ing Direction................ . Down optlcal log depth units..... ......Feet Data Reference point....... .......undefined Frame spacing.. .............. .... .60 .1IN Max frames per record.............undefined Absent value...... ...... ..........-999 Depth Uni ts. . . . . . . . . . . . . . . . . . . . . . . Datum specification Block sub-type...O Insite 66.37 Memory 13035.0 11813.0 13035.0 69.3 96.3 TOOL NUMBER 160788 156404 6.125 11533.0 Flo pro SF 8.40 43.0 10.0 5500 9.2 .800 .400 .700 1. 200 70.0 147.0 70.0 70.0 Name service order DEPT RPD MWD020 RPM MWD020 Rep 68 68 68 page 7 code offset channel o 1 4 2 8 3 Units Size Nsam FT 4 1 OHMM 4 1 OHMM 4 1 RPS MWD020 RPX MWD020 FET MWD020 GR MWD020 ROP MWD020 Name service unit DEPT FT RPD MWD020 OHMM RPM MWD020 OHMM RPS MWD020 OHMM RPX MWD020 OHMM FET MWD020 HOUR GR MWD020 API ROP MWD020 FT/H e OHMM OHMM HOUR API FT/H U06B005302005SSN.txt 4 1 68 12 4 1 68 16 4 1 68 20 4 1 68 24 4 1 68 28 Min 11761. 5 6.23 5.57 5.14 5.13 0.47 17.5 0.71 Max 13035 446.49 276.35 26.59 385.67 16.71 162.7 408.07 Mean Nsam 12398.3 2548 11.4545 2444 10.9539 2444 9.48425 2444 9.23633 2444 2.02532 2444 43.1721 2444 59.9421 2444 First Reading For Entire File........ ..11761.5 Last Reading For Entire File...........13035 File Trailer service name.............STSLIB.003 service sub Level Name... version Number.......... .1.0.0 Date of Generation...... .07/06/12 Maximum physical Record. .65535 Fi 1 e Type. . . . . . . . . . . . . . . . LO Next File Name. ..........STSLIB.004 physical EOF File Header Service name.. ...........STSLIB.004 service sub Level Name... version Number...........1.0.0 Date of Generation.. ... ..07/06/12 Maximum Physical Record. .65535 Fi 1 e Type. . . . . . . . . . . . . . . . LO Previous File Name.... ...STSLIB.003 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE GR RPS FET RPM RPX RPD ROP 4 e 4 5 6 7 8 Fi rst Reading 11761. 5 11768.5 11768.5 11768.5 11768.5 11768.5 11761.5 11813 . 5 Last Reading 13035 12990 12990 12990 12990 12990 12983 13035 header data for each bit run in separate files. 3 .5000 START DEPTH 12983.5 12990.5 12990.5 12990.5 12990.5 12990.5 13035.5 STOP DEPTH 13440.0 13447.0 13447.0 13447.0 13447.0 13447.0 13492.0 page 8 e e $ U06B005302005SSN.txt # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE DGR EWR4 $ BOTTOM) TOOL TYPE DUAL GAMMA Electromag RAY Resis. 4 # # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (s): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ 28-MAY-05 Insite 66.37 Memory 13492.0 13035.0 13492.0 82.9 87.0 TOOL NUMBER 160788 156404 6.125 11533.0 Flo Pro 8.50 50.0 9.3 5400 7.6 .800 .390 .700 1. 200 70.0 150.8 70.0 70.0 # Data Format specification Record Data Record Type......... .........0 Data specification Block Type.....O Logging Direction........... ......Down optlcal log depth units.. ....... ..Feet Data Reference point............. .undefined Frame spacing.. .............. .....60 .1IN Max frames per record. ... .........undefined Absent value........ ...... ....... .-999 Depth uni ts . . . . . . . . . . . . . . . . . . . . . . . Datum specification Block sub-type...O Name Service order Units size Nsam Rep Code offset channel Page 9 e e U06B005302005SSN.txt DEPT FT 4 1 68 0 1 RPD MWD030 OHMM 4 1 68 4 2 RPM MWD030 OHMM 4 1 68 8 3 RPS MWD030 OHMM 4 1 68 12 4 RPX MWD030 OHMM 4 1 68 16 5 FET MWD030 HOUR 4 1 68 20 6 GR MWD030 API 4 1 68 24 7 ROP MWD030 FT/H 4 1 68 28 8 Fi rst Last Name service unit Min Max Mean Nsam Reading Reading DEPT FT 12983.5 13492 13237.8 1018 12983.5 13492 RPD MWD030 OHMM 5.76 14.58 9.25517 914 12990.5 13447 RPM MWD030 OHMM 4.87 15.16 9.08767 914 12990.5 13447 RPS MWD030 OHMM 4.63 13.84 8.46055 914 12990.5 13447 RPX MWD030 OHMM 4.71 13 .87 8.04869 914 12990.5 13447 FET MWD030 HOUR 0.31 16.39 2.39906 914 12990.5 13447 GR MWD030 API 17.72 141.06 37.0937 914 12983.5 13440 ROP MWD030 FT/H 0.14 235.94 103.252 914 13035.5 13492 First Reading For Entire File.. ...... ..12983.5 Last Reading For Entire Fi1e...........13492 Fi 1 e Trail er Service name... ..........STSLIB.004 Service Sub Level Name... version Number.. ........ .1.0.0 Date of Generation.......07/06/12 Maximum physical Record..65535 Fi 1 e Type... . . . . . . . . . . . . . LO Next File Name.... ...... .STSLIB.005 physical EOF File Header service name.......... ...STSLIB.005 service Sub Level Name... version Number.. .........1.0.0 Date of Generation.......07/06/12 Maximum physical Record. .65535 Fi 1 e Type...... . . . . . . . . . . LO previous File Name.......STSLIB.004 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE GR RPM RPX RPS 5 header data for each bit run in separate files. 4 .5000 START DEPTH 13440. 5 13447.5 13447.5 13447.5 STOP DEPTH 15177.0 15184.0 15184.0 15184.0 page 10 e e RPD FET ROP $ 13447.5 13447.5 13492. 5 U06B005302005SSN.txt 15184.0 15184.0 15229.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE DGR EWR4 $ BOTTOM) TOOL TYPE DUAL GAMMA RAY Electromag Resis. 4 # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (s): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # # # REMARKS: $ # Data Format specification Record Data Record Type......... .........0 Data Specification Block Type.....O Log~ing Direction............ .....Down optlcal log depth units... ........Feet Data Reference point............. .undefined Frame spacing... ............. .....60 .1IN Max frames per record.... .........undefined Absent value..................... .-999 Depth uni ts. . . . . . . . . . . . . . . . . . . . . . . page 11 30-MAY-05 Insite 66.37 Memory 15229.0 13492.0 15229.0 84.1 97.4 TOOL NUMBER 160788 156404 6.125 11533.0 Flo-pro 8.50 46.0 8.9 3200 9.5 .690 .250 1.310 1. 410 70.0 201.2 65.0 65.0 e e U06B005302005SSN.txt Datum specification Block sub-type...O Name Service Order units size Nsam Rep code offset channel DEPT FT 4 1 68 0 1 RPD MWD040 OHMM 4 1 68 4 2 RPM MWD040 OHMM 4 1 68 8 3 RPS MWD040 OHMM 4 1 68 12 4 RPX MWD040 OHMM 4 1 68 16 5 FET MWD040 HOUR 4 1 68 20 6 GR MWD040 API 4 1 68 24 7 ROP MWD040 FT/H 4 1 68 28 8 Fi rst Last Name service Unit Min Max Mean Nsam Reading Reading DEPT FT 13440. 5 15229 14334.8 3578 13440. 5 15229 RPD MWD040 OHMM 0.11 1974.13 12.0483 3474 13447.5 15184 RPM MWD040 OHMM 0.19 1318.56 9.69645 3474 13447.5 15184 RPS MWD040 OHMM 0.69 1729.18 12.1281 3474 13447.5 15184 RPX MWD040 OHMM 0.48 2000 25.1821 3474 13447.5 15184 FET MWD040 HOUR 0.47 17.8 1. 61574 3474 13447.5 15184 GR MWD040 API 16.18 221.77 37.4037 3474 13440.5 15177 ROP MWD040 FT/H 1 363.17 71.2738 3474 13492. 5 15229 First Reading For Entire File......... .13440.5 Last Reading For Entire File...........15229 Fi 1 e Trail er service name..... ....... .STSLIB.005 service sub Level Name... version Number.......... .1.0.0 Date of Generation...... .07/06/12 Maximum physical Record. .65535 Fi 1 e Type. . . . . . . . . . . . . . . . LO Next File Name...... .....STSLIB.006 physical EOF Tape Trailer service name. ....... .....LISTPE Date............. ..... ...07/06/12 ori gi n. . . . . . . . . . . . . . . . . . . STS Tape Name...... .... ......UNKNOWN continuation Number..... .01 Next Tape Name.. .........UNKNOWN Comments...... ...........STS LIS writing Library. scientific Technical services Reel Trail er service name........ .....LISTPE Date............. ........07/06/12 Ori gi n. . . . . . . . . . . . . . . . . . . STS Reel Name............... . UNKNOWN continuation Number... ...01 Next Reel Name. ..........UNKNOWN Comments.......... ..... ..STS LIS writing Library. scientific Technical services page 12 e physical EOF Physical EOF End of LIS File e U06BOOS30200SSSN.txt page 13
