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206-184
~~ ~ ~~ O .~l-lel~E 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 inspec~tiion of the file. ~~ ~rj - ~ O ~- Vl/ell Flistory f=ile Identifier ®rgan%Z%ng (done) RESCAN for Items: ~reyscale Items: ~ ~R~.~-' ^ Poor Quality Originals: VV ^ Other: NOTES: o,wd,a~ iuuimiuiuim DIGI L DATA Diskettes, No. I ^ Other, No/Type: BY: Maria ~_ Date: ((~ ~- Project Proofing BY: Maria Date: Scanning Preparation ~_ x 30 = QY: ~ Maria Date: P + ~ =TOTAL. PAGES n (Count does not include cover sheet) I /~/ /s/ ~ r ' r ' I IIIII~IIIIIIII(III Production Scanning Stage 1 Page Count from Scanned File: ~~ (Count does include cov r sheet) Pa a Count Matches Number in Scannin Pr paration: YES NO 9 g BY: Maria Date: lG~ ~ ~ ~ ~ lsJ Stage 1 If NO in stage 1, page(s) discrepancies were found: YES NO 111 BY: Maria Date: /s/ Scanning is complete at this point unless rescanning is required. II I II II II I (I II I I III ReScanned III 111111 IIIII II III BY: Maria Date:. /s/ Comments about this file: ~~ ^ Rescan Needed III IIIIIIIIII IIIIII OVERSIZED (Scannable) ^ Maps: ^ Other Items Scannable by a Large Scanner OVERSIZED (Non-Scannable) ^ Logs of various kinds: ^ Other:: /s/ ~/ a ~ lsl o~.„~n~..< iuiummumii 10!6!2005 Well History File Cover Page.doc OF • �'��\\I%7,t$,, THE STATE f �zE-Y e: 01 , a _ 3_ e 333 West Seventh Avenue ti t 3 , LiOVI RNOR SEAN PARNEI I. Anchorage, AJaska 99561-3572 Main 907.275 1433 SEAMED MM 2 0 2014 John McMullen Engineering Team Leader BP Exploration (Alaska), Inc. 1 r , -- P.O. Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU D-30B Sundry Number: 314-024 Dear Mr. McMullen: 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 form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration 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. Sincerely, a'& p c ' — Cathy P. oerster Chair DATED this Z't day of January, 2014. Encl. • STATE OF ALASKA 041:0( A ALASKA OIL AND GAS CONSERVATION COMMISSION v' ; `; ., APPLICATION FOR SUNDRY APPROVAL 20 AAC 25.280 0 IS l•Z� ft it.,1. Type of Request: ❑Abandon ®Plug for Redrill ' ❑Perforate New Pool ❑Repair Well ❑Change Approved Program . C„-1 kJ k..., 0 Suspend 0 Plug Perforations 0 Perforate 0 Pull Tubing 0 Time Extension ❑Operations Shutdown 0 Re-Enter Suspended Well 0 Stimulate 0 Alter Casing 0 Other 2. Operator Name 4. Current Well Class 5. Permit To Drill Number BP Exploration (Alaska) Inc. ❑Exploratory 0 Stratigraphic 206-184• 3. Address: ®Development 0 Service 6. API Number: P.O. Box 196612,Anchorage,Alaska 99519-6612 50.029-22646-02-00 - 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? PBU D-306• Will planned perforations require a Spacing Exception? 0YesN 9. Property Designatior 10.Field/Pool(s): ADL 028285 ' Prudhoe Bay Field/Prudhoe Bay Oil Pool • 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD(ft): Effective Depth TVD(ft): Plugs(measured): Junk(measured) 12670' ' 9046' • 11949' 9045' 10846', 11400' 11949' Casing Length Size MD TVD Burst Collapse Structural Conductor 110' 20" 110' 110' 1490 470 Surface 3421' 10-3/4" 35'-3456' 35'-3276' 5210 2480 Intermediate 10369' 7-5/8" 36'- 10405' 36'-9048' 8180 5120 Production Liner 219' 4-1/2" 10234'- 10453' 9050'-9047' 8430 7500 Liner 535' 3-1/2"x 3-3/16" 9960'- 10495' 8988'-9044' Liner 2734' 2-3/8" 9936'- 12670' 8979'-9046' 11200 11780 Perforation Depth MD(ft): Perforation Depth ND(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 10590'- 11950' 9042'-9045' 4-1/2", 12.6# L-80 9991' Packers and SSSV Type: 7-5/8"x 4-1/2" Baker S-3 Packer Packers and SSSV 9933'/8978' MD(ft)and ND(ft): 12. Attachments: 13.Well Class after proposed work: ®Description Summary of Proposal ®BOP Sketch 0 Detailed Operations Program 0 Exploratory 0 Stratigraphic ®Development 0 Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operation March 1,2014 0 Oil 0 WINJ 0 WDSPL 0 Plugged 16. Verbal Approval: Date 0 Gas 0 GINJ 0 GSTOR 0 Abandoned Commission Representative: 0 WAG 0 SPLUG ®Suspended 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: David Johnston,564-5985 Printed Name: Joh McMull Title: Engineering Team Leader Email: David.Johnston2©bp.com Signature: Phone: 564-4711 Date: /)ty,/1 Commission Use Only Conditions approval: Notify Commission so that a representative may witness 311.4_09,'LI Sundry Number: -r ❑Plug Integrity t'J BOP Test 0 Mechanical Integrity Test 0 Location Clearance A RBDMS MAY 9 2014 Other: O/� to 5 ¢ to 3 5-op /2 5" i --4y 4/ feroaIC pluJc placehiehfappr=oved per- ,7O Af1-C2571I2( 1 Spacing Exception Required? 0 Yes 11No Subsequent Form Required: to — •i.Q 7- G 9APPROVED BY / Approved By: / / AC MMISSIONER THE COMMISSION Date: —Z9'-/ -Form 10-403 Revised 10 2012 Approv�p10 in isly >�Ylmonths from the date of approval !Submit In Duplicate14(VL r l 23k , , To: Alaska Oil & Gas Conservation Commission From: David Johnston ; bP CTD Engineer Date: January 13, 2014 Re: D-30B Sundry Approval Sundry approval is requested to plug the D-30B perforations as part of the drilling and • completion of proposed D-30C coiled tubing sidetrack. History and current status: D-30 was originally completed in 1996. In 2003 a CTD sidetrack to D-30A was completed. It started to cycle after several months with high gas rates. The well was plugged and perfed a few times. Once all wellwork options were exhausted, the well was sidetracked to D-30B as a Z2A well, D-30B is now cycling for high GOR. There are no remaining well work options for well D-30B that would keep it online. Proposed plan: Sidetrack D-30B to the D-30C location using Nordic 1 Coiled Tubing Drilling rig on or around May 1, 2014. The D-30C sidetrack will be a dual string exit through the existing 4-1/2" and 7-5/8" liner and kick off in the Ivishak Zone 2Bu, to target a Zone 2A lateral. The proposed sidetrack is a -3,149' horizontal Ivishak Zone 2 producer, which will access a -36 acre reserves target in Drill Site 1. The lateral will be completed with a 3-1/2" X 3-1/4" X 2-7/8" L-80 liner which will be fully cemented and selectively perforated. This Sundry • covers plugging the existing D-30B perforations via the D-30C Primary cement lob or liner top packer set post rig with slick line if needed (alternate plug placement per 20 AAC 25.112(i)). The following describes work planned and is submitted as an attachment to Form 10-403. A schematic diagram of the proposed sidetrack is attached for reference. I Coti cve 74e 14-e fr cos ti,( q Go/ ti oni' Sc 4i yuir i rite pa, cii-P•yo cold 141„►, /.'t7`'/-e ,Qc4evje 1t'Ae,7 & 11-o'. f*,.,y the wed for !, / ._GG,_ re (V verb, ,or hi) ., Qi 40 rail //may Pre-Rig Work(scheduled to begin March 1st, 2014) 1. E Set a 4-1/2" CIBP at 9,914' ELMD and MIT 2. E Punch tubing at 9,906' - 9,912' 3. E Set Cement retainer at 9,900' 4. C Cement squeeze cement into IA for dual string exit TOC -9,000' MD 5. E Set 4-1/2" Whipstock at 9795' ELMD and HSTF 6. F MIT-T to 2,500 psi 7. V PT MV, SV, WV. 8. 0 Remove wellhouse and level pad. 5-vvi-0111 Rig Work(scheduled to begin May 1st, 2014) ✓,�` 1. MIRU and test BOPE 250 psi low and 3,500 psi high. (MASP 2,323 psi) 2. Mill 3.80" dual string window and 10' of rathole. _ �-- 3_ Drill build: 4.25" OH, 579' (24 deg DLS planned). 4. Drill lateral: 4.25" OH, 2,570' (12 deg DLS planned). 5. Run 3-1/2" X 3-1/4" X 2-7/8" L-80 liner leaving TOL at -9,600' MD. 6. Pump primary cement job: 41 bbls, 15.8 ppg, TOC at TOL.* 7. Perform liner cleanout and MCNL/GR/CCL log. 8. Perform liner lap test to 2,400 psi 9. Perforate liner based on log interpretation (-200'). 10. Freeze protect well to 2,500' MD. 11. Set TWC, RDMO. Post-Rig Work 1. 0 Re-install Wellhouse, and flow line 2. V Pull TWC 2. S Set Liner Top packer and MIT to 2,500 Psi (Only if needed)* 3. S Set Generic GLV's *Approved alternate plug placement if liner lap test fails per 20 AAC 25.112(i) David E. Johnston CTD Engineer 564-5985 CC: Well File Joe Lastufka TREE= 4"CNV V'VELLFEAD= FMC 1)-30 B SpINITIAL N&D-30A WELLBORES NOT SHOWN BROW ACTUATOR= BAKER-0 OKB.ELEV= 78.25' I WHIPSTOCK** BF.ELEV= 40.6' KOP= 1215' 2215' H4-1/2"HES HXO SSSV NF',ID=3.813" Max Angle= 96°@ 11001' Q LDatum MD= 9738' Datum ND= 8800'SS GAS LFT MANDRELS ST MD ND DEV TYPE VLV LATCH PORT DATE 10-3/4"CSG,45.5#,L-80 BTC,ID=9.950" —I 3456' 3 3779 3567 25 KBMG-M DOME BK 16 09/17/12 L 2 7144 6573 26 KBMG-M SO BK 20 09/17/12 1 9812 8921 58 KBMG-M DMY BK 0 03/20/96 r---- 9923' -14-1/2"HES X NIP,ID=3.813" Minimum ID = 1.941" @ 9944' 3-3/16" X 2-7/8" XO 5 g— 9933' H7-5/8"X 4-1/2"BKR S-3 PKR,D=3.875" N 1 9936' —13.70"BOT DEPLOYMENT SLV,D=3.00" 11 11 1 141 .• 9944' —I 3-1/2"X 2-3/8"XO,D=1.941" •::, 11/x/1 9957' —14-1/2"HES X NIP,D=3.813"(BEHIND CT LNR) ga/,/ 141Lt TOP OF CEMENT H 9960' 41 .t �� 9960' BKR LNR DEPLOY SLV W/SEAL LOC., 1/i� ��11/ I:)=2.39" 111 01' '111 9979' 4-1/2"HES XN NIP,ID=3.725"(BEHHVD CT LNR) •11 111,` •/1 14 4 1 114 11 9980' —13-1/2"HES XN NIP,ID=2.750" 4-1/2"TBG,12.6#,L-80 BTC-M, 9991' //1111 11 9982' H3-1/2"X 3-3/16"BKR XO,ID=2.80" /11 IIC .0152 bpf,D=3.958" /.41. '1111//, 111' 1111 9991' H4-1/2"WLEG,D=3.958" 1/11/1 1 1 1111 Alye ""— TOP OF 4-1/2"LNR —{ 10260' I '4'14 /1/ 11111 �/1/� 7-5/8"CSG,29.7#,USSS-95,D=6.875" —I 10405' I— //41/ .i/11.1 L 1. 1 11 4-1/2"LNR, 12.6#,L-80,D=3.953" —I 10453' 111 11/ 11111 .11/1 1111 1:' 3-3/16"LNR,6.2#,L-80 TOI,.0076 bpf,D=2.80" —1 10496' \\1,1 11 /, MILLOUT WINDOW(D-30B) 10495'-10501' ,4 WHIPSTOCK —1 10496' 1. ,4 PERFORATION SUMMARY 1/� 10745' H MARKER 3'PUP JT REF LOG:MCNtJCCL/GR ON 05/11/07 ,♦4���i ANGLE AT TOP PERF:95°@ 11020' 10846' --12-3/8"WFD aBP(09/04/12) Note:Refer to Roduction DB for historical pert data ipso, SIZE SEF INTERVAL Opn/Sqz DATE SHOT ` 11400' —12-3/8"WFD CBP(08/13/11) 1.56" 6 10590-10620 0 09/04/12 RA TAG —1 10501' / 1.56" 6 10662-10692 0 09/04/12 `` 1.56" 6 10720-10750 0 09/04/12 1.56" 6 10940 10970 C 08/14/11 .404., 11949' —FISH- HYD DISC, 1.56" 6 11020-11050 C 08/14/11 .V.v.• CIRC SUB,MOTOR& 1.56" 6 11084-11114 C 08/13/11 .�/* MILL(05/11/07) 1.56" 6 11430-11640 C 05/11/07 1.56" 6 11760-11950 C 05/11/07 2-3/8"LNR,4.7#,L-80 STL,.0039 bpf,ID=1.995" H 12670' DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 03/23/96 ORIG.HORZ.COMPLETION 04/22/12 MBM/PJC GLV C/O(04/21/12) WELL: D-30B 01/12/03_JLM/TLH CTD SIDETRACK(D-30A) 09/06/12 I I WJM3 SET CIBP&ADPERFS(09/04/12) PERMIT No: 206184 05/12/07 NORDIC 1 CTD SIDETRACK(D-30B) 09/24/12 BSEJJND GLV CIO(09/17/12) API No: 50-029-22646-02-00 05/13/07 /PAG DRLG DRAFT CORRECTIONS 10/11/13 PM/JMD CORRECIEUFERE TYPOS SEC 23,T11N,R13E,1655'FNL&1066'FEL 12/02/09 WH/JND DRLG DRAFT CORRECTIONS 08/18/11 PBS/PJC GBP/ADFERFS(08/13-14/11) BP Exploration(Alaska) TREE = 4" D WELLHEAD= FMC �30C SAFE,r NOTES:**"W�L ANGLE>70°@ 10046'*** ACTUATOR= BAKERC CTD Proposed Sidetrack INITIAL&D-30A WEiLBORES NOT SHOWN BLOW OKB.REV= 78.25' I 1 WHIPSTOCK"* BF.REV= 40.6' KOP= 1215' 2215' H4-1/2"HES HXOSSSV NP,ID=3.813" I Max Angle= 96°@ 11001' 0 I Datum MD= 9738' Datum TVD= 8800'SSZAI GAS LIFT MANDRELS ST MD ND DEV TYPE VLV LATCH PORT DATE 3 3779 3567 25 KBMG-M DOME BK 16 09/17/12 10-3/4"CSG,45.5#,L-80 BTC,ID=9.950" 3456' ( U 2 7144 6573 26 KBMG-M SO BK 20 09/17/12 �2} 58 KBMG-M Dv BK 0 Minimum ID = 1.941" @ 9944' 3-3/16" X 2-7/8" XO t,� TOP OF CEMENT H 9960' e1/ TOC Packer 4-1/2"x 7-5/8" —9,000' • r• Top of SAG @ -9,207' MD �i !i 1 . 11 TOL/TOC 3-1/2" @—9,600 111 \ • 111 1' ►1 11 •►11 i;I • TOWS Baker4-1/2"Monobore @9,79560° ' '• 3-1/4 x 2-7/8 Crossover and short joint 10,600'MD TD- 12944' MD Cement Retainer@ 9,910' 11111_Tubing Punch @ 9,918' .. 11 CIBP @ 9,924' — • 9923' H4-1/2"HES X NP,D=3.813" I 9933' H7-5/8"X 4-1/2"BKR S-3 PKR,ID=3.875" t Q 9936' H3.70"BOT DEPLOYMENT SLV,D=3.00" �, ► _11. 9957' —4-1/2"HES X NP,ID=3.813"(BEHND CT LNR) �.tr11 11. 9979' —14-1/2"HES XN NP,D=3.725"(BEHIND CT LNR) 411' *OA TOP OF 4-1/2"LNR —I 10260' 1111/'' I1111. H 14 1/ 4-1/2"TBG,12.6#,L-80 BTC-M, 9991' 7-5/8"CSG,29.7#,USSS-95,ID=6.875" H 10405' ____,A 1� , is i,1111 .0152 bpf, D=3.958" N 1.4 .. 11'0 ,114 10846' H2-3/8"WFD CIBP(09/04/12) i*Illir • � 11400' —12-3/8"WFDGBP(08/13/11) f. 2-3/8"LNR,4.7#,L-80 ST(�.0039 bpf, ID=1.995" H 12670' DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 03/23/96 ORIG.HORZ.COMPLETION 04/22/12 ABM/PJC GLV C/O(04/21/12) WELL: D-30B 01/12/03 JLM/TLH CTD SIDETRACK(D-30A) 09/06/12 I I WJND SET CDP&ADPERFS(09/04/12) FERMI No: 206184 05/12/07 NORDIC 1 CTD SIDETRACK(D-30B) 09/24/12 BSE/JND GLV CIO(09/17/12) API No: 50-029-22646-02-00 05/13/07 /PAG DRLG DRAFT CORRECTIONS 10/11/13 PM/JMD CORRECTED PERF TYPOS SEC 23,T11N,R13E, 1655'FNL&1066'FEL 12/02/09 WI /JND DRLG DRAFT CORRECTIONS 08/18/11 PBS/PJC CIBP/ADPERFS(08/13-14/11) BP Exploration(Alaska) . r ggi 411 t' r tel, . ruI - a"1 r 0 0 o = E m o LL'') a 5's $ /' _ 9 Y I F 1' RE V L2 ; ,"11 41 1111 s T O 2 m ,�, 0 " x/ 11 , , 0 U=E ' li : 'II1U 1 . ,, 20152 3 g al II I I 11r • 1 II I 9 I II 4 ►., E o $ C g m LQJL O � N ✓ a .. m I ... .t, 0 Q ��� $ 1 a III oICMIERI-1111E1 Ill ' o41 1 \ n1 O >iii F 1 S - l 6 1/ V x ilii•_•___••__•• NE a 1 H I11 Z re ,.. O m' vexI U U 63 Q ' I $ 111 C Eo III 0 111 IIO 0 iLLJK o F W U N . U 3 fal W ► e Y 0 ' q C ' rc C.) 111 r 1074.4V , .e� NM Ce g j — .=— ig ) : — o- Q o CI 1 11 i2 m V T Z II o O N 41H I g N u III < C I 111 ¢ 9 ZROi 111 i Gµ I 111 1I h , c Pu I 00 1 _ . I I III I I¢FII �� I`U� n g /^\ ' 11111=1 i10 I II I Cu STATE OF ALASKA OCT 0 3 2012 AIL OIL AND GAS CONSERVATION COMMODN REPORT OF SUNDRY WELL OPERATIONS AOGCC 1. Operations Abandon U Repair Well U Plug Perforations J Perforate U Other Performed: Alter Casing ❑ Pull Tubing❑ Stimulate - Frac ❑ Waiver ❑ Time Extension❑ Change Approved Program ❑ Operat. Shutdown❑ Stimulate - Other ❑ Re -enter Suspended WeIQ 2. Operator 4. Well Class Before Work: 5. Permit to Drill Number: Name: BP Exploration (Alaska), Inc Development 0 Exploratory ❑ 206 -184 -0 3. Address: P.O. Box 196612 Stratigraphic❑ Service ❑ '6. API Number: Anchorage, AK 99519 -6612 ` 50- 029 - 22646 -02 -00 ' 7. Property Designation (Lease Number): 8. Well Name and Number: ADL0028285 PBU D -30B 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field /Pool(s): To Be Submitted PRUDHOE BAY, PRUDHOE OIL 11. Present Well Condition Summary: Total Depth measured 12670 feet Plugs measured See Attachment feet true vertical 9046.04 feet Junk measured 11949 feet Effective Depth measured 10848 feet Packer measured 9933 feet true vertical 9052.64 feet true vertical 8977.72 feet Casing Length Size MD TVD Burst Collapse Structural None None None None None None Conductor 80 20" 91.5# H-40 36 - 116 36 -116 1490 470 Surface See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Intermediate None None None None None None Production None None None None None None Liner See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Perforation depth Measured depth 10590 -10620 feet 10662 - 10692 feet 10720 - 10750 feet 10940 - 10970 feet 11020 - 11050 feet 11084 - 11114 feet 11430 - 11640 feet 11760 - 11950 feet True Vertical depth 9041.88 - 9042.97 feet 9042.13 - 9042.45 feet 9044.16 - 9045.74 feet 9050.16 - 9047.61 feet 9042.44 - 9040.27 feet 9038.79 - 9038.67 feet 9045.39 - 9046.28 feet 9047.1 - 9045.43 feet Tubing (size, grade, measured and true vertical depth) 4 -1/2" 12.6# L -80 33 - 9991 33 - 9000.4 Packers and SSSV (type, measured and true vertical depth) 4 -1/2" Baker S -3 Perm P: 9933 8977.72 Packer None None None SSSV 12. Stimulation or cement squeeze summary: Intervals treated (measured): SCANNED JAN 2 3 2013 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: 493 29557 4 ..: t - • • • ' -- 0' 848 Subsequent to operation: 0 0 0 0 0 14. Attachments: 15. Well Class after work: Copies of Logs and Surveys Run Exploratort❑ Development [l "" /Service ❑ Stratigraphic ❑ Daily Report of Well Operations X 16. Well Status after work: Oil .. [ Gas ❑ WoSPIU GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP ❑ SPLUCJ 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 Garry Catron Prepared by Garry Catron 564 -4424 Printed Name Garry Catron Title PDC PE Signature 1/C4�ti Phone 564 -4424 Date 10/2/2012 RE3DMS OCT 0 5 2012 ef 3i gpct.,2 ORIGINAL (L9 y Form 10-404 Revised 11/2011 Submit Original Only • • D -30B 206 -184 -0 Plugs Attachement SW Name Date MD Description D -30B 9/6/2012 10848 2 -3/8" CIBP D -30B 8/15/2011 11400 2 -3/8" WFD CIBP Casing / Tubing Attachment ADL0028285 Casing Length Size MD TVD Burst Collapse CONDUCTOR 80 20" 91.5# H-40 36 - 116 36 - 116 1490 470 LINER 2734 2 -3/8" 4.7# L -80 9936 - 12670 8978.93 - 9046.04 11200 11780 LINER 38 3-1/2" 8.81# L -80 9944 - 9982 8982.12 - 8996.95 LINER 519 3- 3/16" 6.2# L -80 9982 - 10501 8996.95 - 9043.34 LINER 193 4 -1/2" 12.6# L -80 10260 - 10453 9051.16 - 9046.54 8430 7500 SURFACE 3421 10 -3/4" 45.5# L -80 35 - 3456 35 - 3276.41 5210 2480 SURFACE 3421 10 -3/4" 45.5# L -80 35 - 3456 35 - 3276.41 5210 2480 • TUBING 9958 4 -1/2" 12.6# L -80 33 - 9991 33 - 9000.4 8430 7500 • Daily Report of Well Operations ADL0028285 ACTIVITYDATE I SUMMARY ''I U ::W . COI. • •Jec we: e : • an. s cc • I O pe s. T /I /O= 2366/171/165 RU and perform weekly BOP test. RIH w/ MHA & 1.75" JSN drift. Tagged plug at 11399'ctmd, flagged pipe at 11379'ctmd. Load well w/ 100bbls 1% KCI while POOH. Make up WFD MHA w/ PDS GR /CCL logging toolstring. RIH to flag. Log up at 30fpm. Flagged pipe at 10790'ctmd. Process depth log, ( -1'). MU Weatherford setting TS w/ 2 3/8" CIBP. Fluid pack well bore /kill well w/ 5 bbl meth /wtr and 200 bbl KCL. RIH w/ 2 3/8" CIBP. Continued on 9/3/2012 09/04/2012 WSR Continued from 09/03/12 WSR. CTU #8 w/ 1.5" coil. Objective: Set CIBP and shoot 90' of perfs • RIH w/ 2 3/8" cibp to flag. Correct to flag. Set mid element plug @ 10850'. Stack 2k# to confirm set. PT plug to 500 psi. Good. POOH. Perform chain inspection. R placed 2 bad bearings on 260 Injector. MU MHA/firing head & 30'x1.56" 1606 PJ HMX gun assembly, OAL 37.83'. PT & RIH. Shoot bottom set 10720'- 10750' 6 SPF 1606PJ, POOH, ball recovered, MU 2nd set of 30' guns, PT & RIH. Shoot 2nd set of perfs 10662'- 10692', 6 SPF 1606PJ. POOH, ball recovered. MU 3rd set of perf guns, PT & RIH. Shoot 3rd set of perfs 10590' - 10 6SPF 1606PJ. Begin POOH. Job 9/4/2012 continued on 9/5/12 WSR. Continued from 09/04/12 WSR. CTU #8 w/ 1.5" coil. Objective: Set CIBP and shoot 90' of perfs. Continue POOH. FP well. At surface, confirmed shots fired and recovered ball. Cut 150' of pipe, 9/5/2012 performed chain inspection and changed packoff. RDMO. ***Job Complete*** • 7TiF3 == 4 CNV 11111 SA ES ANGLE> 70° Q 10046'°" EL WLHEAD = MC D -3 O B "INITIAL & D-30A WB.LBORES NOT SHOWN BELOW ACTUATOR BAKERC KB._ B�I/= . �._. 7825' WHIPSTOCK*" 1 BF. E..EV = 40.6' KOP= 1215' I 2215' 1-14 -112" FES HXO SSSV MP D= 3.813" 1 Max Angle = 96° r 1 ID Datum P013= 9738' Datum TVD = 8800' SS GAS LIFT MANDRELS ST MD TVD CEV TYPE VLV LATCH FORT DATE 110 -3/4" CSG, 45.5#, L -80 BTC, D = 9.950" H 3456' 3 3779 3567 25 KBMCrM DOME BK 16 09/17/12 2 7144 6573 26 KBMG-M SO BK 20 09/17/12 1 9812 8921 58 KBMG -M DIN BK 0 03/20/96 Minimum ID = 1.941" @ 9944' , 1 9823' (- 14 -1/2" HES X PP, D = 3.813" 3 -3/16" X 2 -7/8" XO _� I 9933' 1-17 -516" X 4-1/2" BKR S-3 FKR D = 3.875" •� /1 I . 9936' -- 13.70" BOT DEPLOY SENT SLV, ID= 3.00' 1 ∎ A' 9114' H3 -1/2" X 2 -3/8" XO, D= 1.941" 4 �1�/ 1�1�1 I 9957' H 4-1/2" HES X PP, D = 3.813" (BE-fi CT LNR) 14 ►1,,' TOP OF GRANT 9960' �� 4 1 ∎4 1 ► 1 1 1 • • 1 1 ■ ( 9960' 1 � BKR LN2 DEFLOY SLV W/SEAL LOC., 1 11 1 D = 2.39" '� �1 ►�1 � I 9978' H41/2" FEB XN MP, D= 3.725" (B&W CT LM) 1 • • 1 /,, 1 / 1 ■ 1' 9980' 3-1/2" HES XN NP, D = 2.750" • � 1 � 9982' 1- 1 3 -1/2" X 3 -3/16" BKRXO, D= 2.80" 41/2" TBG, 12.6 #, L BTC - M, 9991' 1111 ► 1 / .0152 bpf, D = 3.958" • �j 1111111∎1 •••1 1 111 9991' —141/2" WLEG, D = 3.958" 1 1•11 1111 1T0P OF 4-1/2" LN2 H 10260' 1 . 1 1 1 1 1 1 1 1 1 1 1.1 . 1 1 ■ 1 • / ► 01 �1 • 1�1 • 1 7 -5/8" CSG, 297#, USSS -95, D = 6.875" H 10405' 04 0.1 1 ► 1 1 1 1 1 1 1 41/2" LNi, 12.6#, L -80, 13= 3.953" H 10453' 1 1 • ► • 1 r1 1 11 • 11111 11111 1 \ / 1 M LLOUT WT'DOW (D -308) 10495' - 10501' I 13-3/16" LMT, 6.2#, L -80 TOL .0076 bpf, D = 2.80" 10496' ■/ /� W 'FSTOCK 10496' 1 1 • F'ffiFORATIDN SUMMARY � , 1 1 , 10745' — I MARKER 3' PUP JT I REF LOG: MCNUCCL/GR ON 05/11/07 V44. - `♦ ANGLE AT TOP PE RP 95° @ 11020' 10846' — 12 - 3/8" WFD CUP (09/04/12) Note: Refer to Production DB for historical pert data �`` SIZE SPF INTERVAL Opn/Sqz DATE � 1.56" 6 10590 - 10620 0 09/04/12 IRA TAG 1 10501' + 11400' 2 - 3/8" WFD CEP {08/13111) 1.56" 6 10662 - 10692 0 09/04/12 S 1.56" 6 10720 - 10750 0 09/04/12 ` 11949' 1— FISH - FK D DISC, 1.56" 6 11020 - 11050 C 08/14/11 1.56" 6 11084 - 11114 C 08/13/„ ,1* * ■ MILL ( 1ro TOR & 1.56" 6 11430 - 11640 C 05/11/07 11 1�1�t• ) 1.56" 6 11760 - 11950 C 05/11/07 1.56" 6 11940 - 11970 C 08/14/11 12 - 3/8" LMi, 4.7 #, L - 80 STL, .0039 bpf, D = 1.995" 12670' DATE REV BY COMMENTS DATE REV BY COA9AENTS PRIAHOEBAY UNIT 03/23/96 ORIG. HOR . COMPLETION 08/18/11 PBS/ PJC CEP/ ADF431FS (08/13 - 14/11) WELL: D-30B 01/12/03 JLM/TLH CTD SKIETRACK (D -30A) 04/22/12 NEM PJC GLV CIO (04/21/12) PERMT No: '06184 05/12/07 NORDIC 1 CTD SIDETRACK (D30B) 09/06/12 TIR/JMD SET CEP &ADPE FS (09/04/12) AR No: 50- 029 - 22646 -02 -00 05/13/07 /PAG CMG DRAFT CORRECTIONS 09/24/12 BSE!JMD GLV CIO (09/17/12) SEA 23, 711N, R13E, 1655' FM._ & 1066' FEL 05/31/07 CJMPAG GLV CIO 12/02/09 WWJMD DRLG DRAFT CORRECTIONS BP Exploration (Alaska) Prb 260340 Regg, James B (DOA) From: AK, D &C Well Integrity Coordinator [ AKDCWeIIIntegrityCoordinator @bp.com] � � 4( Sent: Sunday, April 22, 2012 9:28 PM To: Regg, James B (DOA); Schwartz, Guy L (DOA); AK, OPS GC1 OSM; AK, OPS GC1 Field O &M TL; AK, OPS GC1 Facility OTL; AK, OPS GC1 Wellpad Lead; AK, OPS Prod Controllers; Cismoski, Doug A; AK, D &C Well Services Operations Team Lead; AK, D &C Wireline Operations Team Lead; AK, RES GPB West Wells Opt Engr; Daniel, Ryan Cc: Olson, Andrew; Wills, Shane M Subject: OPERABLE: Producer D -30B (PTD #2061840) MIT -IA Passed All Producer D -30B (PTD #2061840) passed an MIT -IA proving two competent barriers in the wellbore. The well is reclassified as Operable. Please be aware of the potential for thermal expansion as the IA is fluid packed. Thank you, Mehreen Va it t (.i<:rri1J ;A9r.rrlydn t Well Integrity Coordinator BP Alaska Drilling & Wells Well Integrity Office: 907.659.5102 SUN G n Email: AKDCWelllntegrityCoordinator @BP.com From: AK, D &C Well Integrity Coordinator / Sent: Wednesday, April 18, 2012 5:35 PM f To: 'Regg, James B (DOA)'; 'Schwartz, Guy L (DOA)'; AK, OPS GC1 OSM; AK, OPS GC1 Field 0 &M TL; AK; OPS GC1 Facility OTL; AK, OPS GC1 Wellpad Lead; AK, OPS Prod Controllers; Cismoski, Doug A; AK, D &C Well Services Operations Team Lead; AK, D &C Wireline Operations Team Lead; AK, RES GPB West Wells Opt Engr; Daniel, Ryan Cc: Olson, Andrew; Wills, Shane M; King, Whitney Subject: UNDER EVALUATION: Producer D -30B (PTD #2061840) Sustained Casing Pressur,ion IA Above MOASP f All, Producer D -30B (PTD #2061840) was found to have sustained •asing pressure on the IA above MOASP. The wellhead pressures were tubing /IA/OA equal to 2300/2080/170 on 04/1 :12012. The well passed a TIFL on 03/26/2012, but has again exhibited TxIA communication. The well is reclassifie as Under Evaluation while diagnostics are progressed. The plan forward: 1. Slickline: Set Dummy Gas Lift Valves 2. Fullbore: MIT -IA to 2500 psi A TIO plot and wellbore schematic are attached or reference: « File: D- 30B.pdf » « File: D -30B TIO •' - 18- 12.doc » Thank you, 1 f6t,t. -3b-g P� Z 164c, Regg, James B (DOA) From: AK, D &C Well Integrity Coordinator [ AKDCWeIIlntegrityCoordinator @bp.com] 4 � t L ' Sent: Wednesday, April 18, 2012 5:35 PM Vgl To: Regg, James B (DOA); Schwartz, Guy L (DOA); AK, OPS GC1 OSM; AK, OPS GC1 Field O &M TL; AK, OPS GC1 Facility OTL; AK, OPS GC1 Wellpad Lead; AK, OPS Prod Controllers; Cismoski, Doug A; AK, D &C Well Services Operations Team Lead; AK, D &C Wireline Operations Team Lead; AK, RES GPB West Wells Opt Engr; Daniel, Ryan Cc: Olson, Andrew; Wills, Shane M; King, Whitney Subject: UNDER EVALUATION: Producer D -30B (PTD #2061840) Sustained Casing Pressure on IA Above MOASP Attachments: D- 30B.pdf; D -30B TIO 04- 18- 12.doc AN, Producer D -30B (PTD #2061840) was found to have sustained casing pressure on the IA above MOASP. The wellhead pressures were tubing /IA/OA equal to 2300/2080/170 on 04/15/2012. The well passed a TIFL on 03/26/2012, but has again exhibited TxIA communication. The well is reclassified as Under Evaluation while diagnostics are progressed. The plan forward: 1. Slickline: Set Dummy Gas Lift Valves 2. Fullbore: MIT -IA to 2500 psi A TIO plot and welibore schematic are attached for reference: APR 2 4 ZU «D- 30B.pdf» «D -30B TIO 04- 18- 12.doc» Thank you, Melareen Vazir t,Itt4t Uitc: (erind,t'f7!r/710}) = we:or5 Well Integrity Coordinator BP Alaska Drilling & Wells )[4Kr ( mil 70( • Well Integrity Office: 907.659.5102 t 2 5, S Email: AKDCWeIIlntegrityCoordinator @BP.com 1 • PBU D -30B PTD #2061840 4/18/2012 TIO Pressures Plot We0: D -30 4.000 • 3,000 - —411— Tbg IA 2.000 - -A— OA 00A 000A On 1,000 • y • ilIMMENN 01/21/12 01/28/12 02/04/12 02/11112 02/18/12 02/25/12 03/03/12 03110/12 03/17/12 03/24/12 03/31/12 04/07/12 04/14/12 1 TREE = 4" CIW WELLHEAD = FMC • SAFETY TES: * * *W ELL ANGLE > 70° @ 10046' * ** ACTUATOR = BAKER C D -3 O B ** *ORIGINAL & D -30A WELLBORES NOT SHOWN KB. ELEV = 78.25' ' ` BELOW WHIPSTOCK * ** BE. ELEV = 40.6' KOP = 1215 ! 2215' J- J4 -1/2" HES HXO SSSV NIP, ID = 3.813" I Max Angle = 96° @ 11001' • Datum MD = 9738' Datum TVD = 8800' SS GAS LIFT MANDRELS 10-3/4° CSG, 45.5 #, L -80 BTC, ID = 9.950" 1-1 3456' ST MD TVD DEV TYPE VLV LATCH PORT DATE 3 3779 3567 25 KBMG -M DOME BK 16 05/31/07 2 7144 6573 26 KBMG -M SO BK 20 05/31/07 1 9812 8921 58 KBMG -M DMY BK 0 12/14/02 Minimum ID = 1.941 @ 9944 1 9923' H4 -1/2" HES X NIP, ID = 3,813" 3 -3/16" X 2 -7/8" XO c, 1711 9933' J- 17 -5/8" X 4 -1/2" BKR S -3 PKR, ID = 3.875" J t�� I 9936' H3.70" BOT DEPLOYMENT SLV, ID = 3.00" I +� j�j 9944' J- I3 -1/2" X 2 -3/8" X0, ID = 1.941" l 1 V. * 1 41 4 1 1 1 4 9957' H4 -1/2" HES X NIP, ID = 3.813" (BEHIND CT LNR) I I TOP OF CEMENT H 9960' y1.1 ■' 4' 1' ► k A I 9960' I- BKR LNR DEPLOY SLV W /SEAL LOC., 11 , ∎ + H ID = 2.39" ► 1 , i - 4 'S ' 9979' — 14 -1/2" HES XN NIP, ID = 3.725" (BEHIND CT LNR) 1 r 6 i l l oil t1 .0 � �1� 9980' H3-1/2" HES XN NIP, ID = 2.750" I 1 ►/, N +. 1 1�∎�'I 9982' J 3 -1/2" X 3- 3/16" BKR X0, ID = 2.80" 1 4 -1/2" TBG, 12.6 #, L -80 BTC-M, 9991' )� "/' 1 J I X 111 .0152 bpf, ID = 3.958" � . +4 ' 4 011� � 11 9991' -{4 -1/2" WLEG, ID = 3.958" 1 ∎111 01 11. 'TOP OF 4 -1/2" LNR I 10260' +11'1' 1 k 4 4 1 4 4 1 4 11111 1111 111 1►t KfL(P= H Q(7a 51 X,1. �4 1 / 1 4 ► ►4 7 -5 CSG, 29.7 #, US 5 -95, ID = 6.875" I I 10405' 11 , 044 11* 14 -1/2" LNR, 12.6 #, L -80, ID = 3.953" , 10453' 111 /►1 ■ „ 1 ► : 1 MILLOUT WINDOW (D -30B) 10495' - 10501' 3- 3/16" LNR, 6.2 #, L -80 TCII, .0076 bpf, ID = 2.80" I 10496' ,1 , I WHIPSTOCK H I 10496' J ►��1' I 10745' N MARKER 3' PUP JT 1 4 ■ PERFORATION SUMMARY ■ REF LOG: MCNL /CCL /GR ON 05/11/07 "/ ` I 11400' H2-3/8" WFD CIBP (08/13!11) ANGLE AT TOP PERF: 95° @ 11020' IRA TAG I 10501' 1, Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn /Sqz ' DATE 11949' I FISH - HYD DISC, 1.56" 6 11020 - 11050 0 08/14/11 CIRC SUB, MOTOR & ■ 1.56" 6 11084 - 11114 0 08/13/11 , 1 ' �! MILL (05(11/07) 1.56" 6 11430 - 11640 0 05/11/07 .4 1.56" 6 11760 - 11950 0 05/11/07 S. 1.56" 6 11940 - 11970 0 08/14/11 12 -3/8" LNR, 4.7 #, L -80 STL, .0039 bpf, ID = 1.995" H 12670' I DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 03/23196 ORIG. HORZ. COMPLETION r 08/18/11 PBS / PJC CIBP/ ADPERFS (08/13 - 14/11) WELL: D-30B 01/12/03 JLM /TLH CTD SIDETRACK (D -30A) PERMIT No: x 206184 05/12/07 NORDIC 1 CTD SIDETRACK (D -30B) API No: 50 -029- 22646 -02 -00 05/13/07 /PAG DRLG DRAFT CORRECTIONS SEC 23, T11N, R13E, 1655' FNL & 1066' FEL 05/31/07 CJN/PAG GLV C/O 12/02/09 WH/JMD DRLG DRAFT CORRECTIONS BP Exploration (Alaska) ?Ott D-aB Prb 21)64 6 Regg, James B (DOA) From: AK, D &C Well Integrity Coordinator [ AKDCWeIIIntegrityCoordinator @bp.com] f'efl` "71(7 Sent: Tuesday, March 27, 2012 6:19 PM To: Regg, James B (DOA); Schwartz, Guy L (DOA); AK, OPS GC1 OSM; AK, OPS GC1 Field O &M TL; AK, OPS GC1 Facility OTL; AK, OPS GC1 Wellpad Lead; AK, OPS Prod Controllers; Cismoski, Doug A; AK, D &C Well Services Operations Team Lead; AK, D &C Wireline Operations Team Lead; AK, RES GPB West Wells Opt Engr; Daniel, Ryan Cc: Walker, Greg (D &C); Glasheen, Brian P; Olson, Andrew Subject: OPERABLE: Producer D -30B (PTD #2061840) TIFL Passed All, Producer D -30B (PTD #2061840) passed a TIFL on 03/26/2012 after the well was placed on production. The passing test confirms two competent barriers and the well is reclassified as Operable. Thank you, Mehreen Vazir (Alternate: ( ;L't'alt/ Murphy) Well Integrity Coordinator BP Alaska Drilling & Wells Well Integrity Office: 907.659.5102 Email: AKDCWeIllntegrityCoordinator @BP.com 54.,ANNEF) MAR % � 'l From: AK, D &C Well Integrity Coordinator Sent: Wednesday, March 21, 2012 6:45 PM To: 'Regg, James B (DOA)'; 'Schwartz, Guy L (DOA)'; AK, OPS GC1 OSM; AK, OPS GC1 Field O &M TL; AK, OPS GC1 Facility OTL; AK, OPS GC1 Wellpad Lead; AK, OPS Prod Controllers; Cismoski, Doug A; AK, D &C Well Services Operations Team Lead; AK, D &C Wireline Operations Team Lead; AK, RES GPB West Wells Opt Engr; Daniel, Ryan Cc: King, Whitney; Wills, Shane M; Glasheen, Brian P; Yusubov, Tural Subject: UNDER EVALUATION: Producer D -30B (PTD #2061840) Sustained IA Casing P • sure Above MOASP All, Producer D -30B (PTD #2061840) was found to have sus - ned IA casing pressure above MOASP. The wellhead pressures were tubing /IA/OA equal to 570/2040/240 o 13/18/12. The well is reclassified as Under Evaluation while further diagnostics are performed. Plan Forward: 1. Downhole Diagnostics: Cold TIFL - FAIL 2. Operations: Place well on production 3. Downhole Diagnostics: TIFL 4. Slickline: Change out orifice gas li valve (If TIFL fails) 5. Downhole Diagnostics: TIFL afte- gas lift valve change out A TIO plot a n d wellbore sche -tic have been included for reference. « File: D -30B. pdf » « File: D -30 TIO 03- 21- 2012.doc » 1 • • f i3tA, D -3og Regg, James B (DOA) Prb 7 - 0161 - o Sent: Wednesday, March 21, 2012 6 45 PMKDCWeIIlntegrityCoordinator @bp.com] S To: Regg, James B (DOA); Schwartz, Guy L (DOA); AK, OPS GC1 OSM; AK, OPS GC1 Field O &M TL; AK, OPS GC1 Facility OTL; AK, OPS GC1 Wellpad Lead; AK, OPS Prod Controllers; Cismoski, Doug A; AK, D &C Well Services Operations Team Lead; AK, D &C Wireline Operations Team Lead; AK, RES GPB West Wells Opt Engr; Daniel, Ryan Cc: King, Whitney; Wills, Shane M; Glasheen, Brian P; Yusubov, Tural Subject: UNDER EVALUATION: Producer D -30B (PTD #2061840) Sustained IA Casing Pressure Above MOASP Attachments: D- 30B.pdf; D -30 TIO 03- 21- 2012.doc AII, Producer D -30B (PTD #2061840) was found to have sustained IA casing pressure above MOASP. The wellhead pressures were tubing /IA/OA equal to 570/2040/240 on 03/18/12. The well is reclassified as Under Evaluation while further diagnostics are performed. Plan Forward: 1. Downhole Diagnostics: Cold TIFL - FAILED 2. Operations: Place well on production 3. Downhole Diagnostics: TIFL 4. Slickline: Change out orifice gas lift valve (If TIFL fails) - SC' 5. Downhole Diagnostics: TIFL after gas lift valve change out A TIO plot and wellbore schematic have been included for reference. 1 «D- 30B.pdf» «D -30 TIO 03- 21- 2012.doc» c Thank you, Y 4,1 11 4410E0 MAR '6; ella Mehreett Vazir 1 l /f / nul r: (Jerald .tipph)-) Well Integrity Coordinator BP Alaska Drilling & Wells Well Integrity Office: 907.659.5102 Email: AKDCWellIntegrityCoordinator @BP.com 1 PBU D -30B PTD #2061840 3/21/2012 TIO Pressures Plot Well D -30 4,000 • 3,000 Tbg • —F IA 2.000 —�- OA OOA On 1,000 • . . . . . . . 12/24/11 12131/11 01/07)12 01/14112 01/21/12 01/28/12 02104/12 02/11/12 02/18/12 02/25/12 03/03/12 03/10/12 03117)12 J TREE = 4" CM/ W • ELLHEAD = FMC S TES: ** *WELL ANGLE> 70° @ 10046' * ** ACTUATOR= BAKER C D •3 0 B ** *ORIGINAL & D -30A WELLBORES NOT SHOWN KB. ELEV = 78.25' ( I BELOW WHIPSTOCK*** BF. ELEV = 40.6' KOP = 1215' I 2215' H4-1/2" HES HXO SSSV NIP, ID = 3.813" 1 Max Angle = 96° @ 11001' • IL Datum MD = 9738' Datum TV D = 8800' SS GAS LIFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE I10 -3/4" CSG, 45.5 #, L -80 BTC, ID = 9.950" 1--L 3456' 3 3779 3567 25 KBMG -M DOME BK 16 05/31/07 2 7144 6573 26 KBMG -M SO BK 20 05/31/07 1 9812 8921 58 KBMG -M DMY BK 0 12/14/02 9923' H4-1/2" HES X NIP, ID = 3.813" Minimum ID = 1.941" @ 9944' 3 -3/16" X 2 -7/8" XO 0 " 9933' --- 17 -5/8" X 4 -1/2" BKR S -3 PKR, ID = 3.875" 3 '4 11 / 9936' H3.70" BOT DEPLOYMENT SLV, ID = 3.00" 3 ,' N �+ 9944' I-33-1/2"X 2 -3/8" X0, ID = 1.941" I 1 1�1 �� 4 1 1 1 / ►1 9957' H4_1/2" HES X NIP, ID = 3.813" (BEHIND CT LNR) I TOP OF CEMENT H 9960' x'1.,, ,A••� I ( r ) ►"I, I 9960' I-1 LNR DEPLOY SLV W /SEAL LOC., /.,g /i 1 ID =2.39" '1 t1 y t 9979' H4 -1/2" HES XN NIP, ID = 3.725" (BEHIND CT LNR) I 914 144 C S : 4 /1 01111 9980' H3-1/2" HES XN NIP, ID = 2.750" I 1 1 i�/ ► 4-1/2" TBG, 12.6 #, L -80 BTC -M, 9991' � 9982' 3 1/2" X 3- 3/16" BKR XO, ID = 2.80" 1 1 1 1 r , ► 0152 bpf, ID = 3.958" �� I 1 11' 1 1 11 ♦ 9991' 4 -1l2" WLEG, ID= 3.958" � 11 1 1� /1 + I I ∎1111 ►111 1.111 A 44; TOP OF 4 -1/2" LNR H 10260' I 1111, 1111 111 ► 11" k / 1 1/ ►/► I 7-5/8" CSG, 29.7 #, USSS -95, ID = 6.875" H 10405' I ��►� , x, 4 mik/1" file Fs; ,1 11 , ( 4 -1/2" LNR, 12.6 #, L -80, ID = 3.953" I-I 10453' I V0 A O 111 ■11 ��' 1 14 1 1 111,4 01 �� MILLOUT WINDOW (D -30B) 10495' - 10501' 13-3/16" LNR, 6.2 #, L -80 TCII, .0076 bpf, ID = 2.80" H 10496' 4 k ' 9 I WHIPSTOCK H 10496' I 1, `���� I 10745' I---I MARKER 3' PUP JT I 1 ■ PERFORATION SUMMARY * I 11400' H2-3/8" WFD CIBP (08 /13111) I REF LOG: MCNL /CCL /GR ON 05!11107 �� 1 ANGLE AT TOP PERF: 95 @ 11020' IRA TAG I 10501' Note: Refer to Production DB for historical pert data SIZE SPF INTERVAL Opn /Sqz DATE 11949' I- FISH - HY D DISC, 1.56" 6 11020 - 11050 0 08/14/11 ■ CIRC SUB, MOTOR & 1.56" 6 11084 - 11114 0 08/13/11 4 � , 4 MILL (05/11/07) 1.56" 6 11430 - 11640 0 05/11/07 4 1;11 1.56" 6 11760 - 11950 0 05/11/07 1.56" 6 11940 - 11970 0 08/14/11 2 -3/8" LNR, 4.7 #, L -80 STL, .0039 bpf, ID = 1.995" H 12670' 1 DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 03/23/96 ORIG. HORZ. COMPLETION 08/18/11 PBS/ PJC CIBP / ADPERFS (08/13 - 14/11) WELL: D-30B 01/12/03 JLM/TLH CTD SIDETRACK (D -30A) PERMIT No: r 206184 05/12/07 NORDIC 1 CTD SIDETRACK (D -30B) API No: 50 -029- 22646 -02 -00 05/13/07 /PAG DRLG DRAFT CORRECTIONS SEC 23, T11 N, R13E, 1655' FNL & 1066' FEL 05/31/07 CJN/PAG GLV C/O 12/02/09 WH /JMD DRLG DRAFT CORRECTIONS BP Exploration (Alaska) z66 -16 Regg, James B (DOA) From: AK, D &C Well Integrity Coordinator [ AKDCWelllntegrityCoordinator @bp.com] �� 1 (iqti v Sent: Saturday, January 14, 2012 9:11 PM To: Maunder, Thomas E (DOA); Regg, James B (DOA); Schwartz, Guy L (DOA); AK, OPS GC1 OSM; AK, OPS GC1 Field O &M TL; AK, OPS GC1 Facility OTL; AK, OPS GC1 Wellpad Lead; AK, OPS Prod Controllers; Cismoski, Doug A; AK, D &C Well Services Operations Team Lead; AK, D &C Wireline Operations Team Lead; AK, RES GPB West Wells Opt Engr; Daniel, Ryan; Glasheen, Brian P; AK, OPS Well Pad DG Cc: AK, D &C Well Integrity Coordinator; Walker, Greg (D &C); LeBaron, Michael J Subject: OPERABLE: Producer D -30B (PTD #2061840) Tubing Integrity Confirmed All, Producer D -30B (PTD #2061840) passed a TIFL on 01/10/2012 after bringing the well online proving tubing integrity has been restored. The well has been reclassified as Operable. Please call if you have any questions. Thank you, Gerald Murphy (alt. Mehreen Vazir) Well Integrity Coordinator Office (907) 659 -5102 _r t �L Cell (907) 752 -0755 }- Pager (907) 659 -5100 Ext. 1154 From: AK, D &C Well Integrity Coordinator Sent: Wednesday, December 28, 2011 6:59 PM To: 'Maunder, Thomas E (DOA)'; 'Regg, James B (DOA)'; 'Schwartz, Guy L (DOA)'; AK, OPS GC1 OSM; AK, OPS GC1 Field O &M TL; AK, OPS GC1 Facility OTL; AK, OPS GC1 Wellpad Lead; AK, OPS Prod Controllers; Cismoski, Doug A; AK, D &C Well Services Operations Team Lead; AK, D &C Wireline Operations Team Lead; AK, RES GPB West Wells Opt Engr; Daniel, Ryan Cc: King, Whitney; Wills, Shane M (Northern Solutions); Glasheen, Brian P Subject: UNDER EVALUATION: Producer D -30B (PTD #2061840) Sustained IA Casing Pressure Above MOASP All, Producer D -30B (PTD #2061840) has confirmed sustained IA casing pressure above MOASP. The wellhead pressures were tubing /IA/OA equal to 2360/2060/260 on 12/25/11. The well failed a TIFL and is reclassified as Under Evaluation. The well may remain online while work is conducted to restore integrity. 1. Downhole Diagnostics: TIFL when well is warm 2. Slickline: Change out orifice gas lift valve (If TIFL fails) 3. Downhole Diagnostics: TIFL after gas lift valve change out A TIO plot and wellbore schematic have been included for reference. Thank you, 1 • Mehreen Vazir oho mac: Gerald Alur /:hti) Well Integrity Coordinator BP Alaska Drilling & Wells Well Integrity Office: 907.659.5102 Email: AKDCWeIIIntegrityCoordinator @BP.com 2 Pa. 6-3& • Pib 06611340 Regg, James B (DOA) From: AK, D &C Well Integrity Coordinator [ AKDCWeIIlntegrityCoordinator @bp.com] �� tz /at Sent: Wednesday, December 28, 2011 6:59 PM To: Maunder, Thomas E (DOA); Regg, James B (DOA); Schwartz, Guy L (DOA); AK, OPS GC1 OSM; AK, OPS GC1 Field O &M TL; AK, OPS GC1 Facility OTL; AK, OPS GC1 Wellpad Lead; AK, OPS Prod Controllers; Cismoski, Doug A; AK, D &C Well Services Operations Team Lead; AK, D &C Wireline Operations Team Lead; AK, RES GPB West Wells Opt Engr; Daniel, Ryan Cc: King, Whitney; Wills, Shane M (Northern Solutions); Glasheen, Brian P Subject: UNDER EVALUATION: Producer D -30B (PTD #2061840) Sustained IA Casing Pressure Above MOASP Attachments: D- 30B.pdf; D -30B TIO 12- 28- 11.doc All, Producer D -30B (PTD #2061840) has confirmed sustained IA casing pressure above MOASP. The wellhead pressures were tubing /IA/OA equal to 2360/2060/260 on 12/25/11. The well failed a TIFL and is reclassified as Under Evaluation. The well may remain online while wor is conducted to restore integrity. 1. Downhole Diagnostics: TIFL when well is warm 2. Slickline: Change out orifice gas lift valve (If TIFL fails) 3. Downhole Diagnostics: TIFL after gas lift valve change out A TIO plot and wellbore schematic have been included for reference. at_Pi,P - el ° `t 1 ' 13 '` f ? Z5, «D- 30B.pdf» «D -30B TIO 12- 28- 11.doc» //647c O- Thank you, A FED (. ZUI)_ Mehreen Vazir ( /1lferrtrrte: Gerald Mur phy) Well Integrity Coordinator BP Alaska Drilling & Wells Well Integrity Office: 907.659.5102 Email: AKDCWeIIlntegrityCoordinator @BP.com 1 PBU D -30B PTD # 2061840 12/28/2011 TIO Pressures Plot Wet 0 -30 4 000 • 3,000 - •.-.. rn0 —U— IA 2,000 - OA •- - - -- 00A ■ On a-r.411 1,000 10/01/11 10/08/11 10/15/11 10/22/11 10/29/11 11/05/11 11/12/11 11/19/11 11/26/11 12/03/11 12/10/11 12/17/11 12/24/11 1 TREE = 4" CM/ • WELLHEAD = FMC SAFETY NO.: ** *WELL ANGLE > 70° @ 10046' * ** ACTUATOR = BAKER C D -3 0 B ** *ORIGINAL & D -30A WELLBORES NOT SHOWN KB. ELEV = 78.25' BELOW WHIPSTOCK*** BF. ELEV = 40.6' ' KOP = 1215' ` 2215' 1-14-1/2" HES HXO SSSV NIP, ID = 3.813" I Max Angle = 96° @ 11001' se D L atum MD = 9738' Datum ND = 8800' SS GAS LIFT MANDRELS ST MD ND DEV TYPE VLV LATCH PORT DATE 110-3/4" CSG, 45.5 #, L -80 BTC, ID = 9.950" H f 3456' 3 3779 3567 25 KBMG -M DOME BK 16 05/31/07 2 7144 6573 26 KBMG -M SO BK 20 05/31/07 1 9812 8921 58 KBMG -M DMY BK 0 12/14/02 9923' I- 14 -1/2" HES X NIP, ID = 3.813" Minimum ID = 1.941" @ 9944' 3 -3/16" X 2 -7/8" XO ►,1 I1 9933' -- 17 -5/8" X 4 -1/2" BKR S -3 PKR, ID = 3.875" I t .� 1 . 9936' I--1 3.70" BOT DEPLOYMENT SLV, ID = 3.00" I 411 9944' H3 -1/2" X 2 -3/8" XO, ID = 1.941" I ∎111. � t 4 11 1 1 9957' H4 -1/2" HES X NIP, ID = 3.813" (BEHIND CT LNR) TOP OF CEMENT YA, H 9 960' 6 )■ k 1 BKR LNR DEPLOY SLV W /SEAL LOC., ∎4 � ID =2.39 .' 1 /o 0t • 1 9979' H4 -1/2" HES XN NIP, ID = 3.725" (BEHIND CT LNR) I N.+ k Ill 9980' H3-1/2" HES XN NIP, ID = 2.750" I 4 -1/2" TBG, 12.6 #, L -80 BTC-M, 9991' Ps' 6 PAP I� 99982' 3 1/2" X 3- 3/16" BKR XO, ID = 2.80" I N 1 iN'1 6_64 N ♦ 0152 bp ID = 3.958" 1 + 1 + ! 11.4: 1111111 9991' 1-14-1/2" WLEG, ID = 3.958" I TOP OF 4 -1/2" LNR H I 10260' ,1� + 10♦ 1 1 + 1 111 111 ■ / 1 1 1 7 -5/8" CSG, 29.7 #, USSS -95, ID = 6.875" I 10405' 111, 11111 A/llu P'= 1 70frr` 141 • • I 4 -1/2" LNR, 12.6 #, L -80, ID - 3.953" I 10453' 1! / 111 1 ' 0 ' "el ■ i 11!11 / ,, , 4 MILLOUT WINDOW (D -30B) 10495' - 10501' 13-3/16" LNR, 6.2 #, L -80 TCII, .0076 bpf, ID = 2.80" I 10496' 1 / / 1 [WHIPSTOCK H 10496' I 1,`Q. 10748 — IMARKER PUPJT I MiS PERFORATION SUMMARY 11400' - 12 -3/8" WFD CIBP (08/13/11) I REF LOG: MCNL /CCL /GR ON 05/11/07 i t ANGLE AT TOP PERF: 95° @ 11020' RA TAG 10501' Sp ` Note: Refer to R DB for historical perf data SIZE SPF INTERVAL Opn /Sqz DATE 11949' 1 — FISH- HYDDISC, 1.56" 6 11020 - 11050 0 08/14/11 CIRC SUB, MOTOR & 1.56" 6 11084 - 11114 0 08/13/11 �'14, 1'1.'1, MILL (05/11/07) 1.56" 6 11430 - 11640 0 05/11/07 1 1.56" 6 11760 - 11950 0 05/11/07 1.56" 6 11940 - 11970 0 08/14/11 12 -3/8" LNR, 4.7 #, L -80 STL, .0039 bpf, ID = 1.995" H 12670' I DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 03/23/96 ORIG. HORZ. COMPLETION 08/18/11 PBS/ PJC CIBP/ ADPERFS (08/13 - 14/11) WELL: D-30B 01/12/03 JLM /TLH CTD SIDETRACK (D -30A) PERMIT No: 206184 05/12/07 NORDIC 1 CTD SIDETRACK (D -30B) ' API No: 50- 029 - 22646 -02 -00 05/13/07 /PAG DRLG DRAFT CORRECTIONS SEC 23, T11N, R13E, 1655' FNL & 1066' FEL 05/31/07 CJN/PAG GLV C/O 12/02/09 WH/JMD DRLG DRAFT CORRECTIONS BP Exploration (Alaska) STATE OF ALASKA . • ALASKA AND GAS CONSERVATION COMMISSIA 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 IO ' Re -enter Suspended Well ❑ 2. Operator BP Exploration (Alaska), Inc. 4. Well Class Before Work: 5. Permit to Drill Number: Name: Development El Exploratory ❑ ' 206 -1840 3. Address: P.O. Box 196612 Stratigraphic Service ❑ 6. API Number: Anchorage, AK 99519 -6612 . 50- 029 - 22646 -02 -00 8. Property Designation (Lease Number) : _ 9. Well Name and Number: ADLO- 028285 ,. PBU D -30B 10. Field /Pool(s): o PRUDHOE BAY FIELD / PRUDHOE OIL POOL 11. Present Well Condition Summary: Total Depth measured 12670 feet Plugs (measured) 11400 feet true vertical 9046.04 feet Junk (measured) 11949 feet Effective Depth measured 11949 feet Packer (measured) 9933 feet true vertical 9045.43 feet (true vertical) 8978 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 80' 20" 91.5# H -40 36 - 116 36 - 116 1490 470 Surface 3421' 10 -3/4 "45.5# L -80 35 - 3456 35 - 3276 5210 2480 Production 10371' 7 -5/8" 29.7# USSS -95 34 - 10405 34 - 9048 Liner 193' 4 -1/2" 12.6# L -80 10260 - 10453 9051 - 9047 8430 7500 Liner 38' 3 -1/2" 8.81# L -80 9944 - 9982 8982 - 8997 Liner 519' 3- 3/16" 6.2# L -80 9982 - 10501 8997 - 9043 Liner 2734' 2 -3/8" 4.7# L -80 9936 - 12670 8979 - 9046 11200 11780 Perforation depth: Measured depth: SEE ATTACHED - _ _ True Vertical depth: _ _ _ Tubing: (size, grade, measured and true vertical depth) 4 -1/2" 12.6# L -80 33 - 9991 33 - 9000 Packers and SSSV (type, measured and true vertical depth) 4 -1/2" Baker S -3 Perm Packer 9933 8978 RECEIVED' 12. Stimulation or cement squeeze summary: SEP 0 8 2011 Intervals treated (measured): Treatment descriptions including volumes used and final pressure: Alaska OtI & Gas Cans. Com s i 0t1 Anchor. 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas -Mcf Water -Bbl Casing Pressure Tubing pressure Prior to well operation: 359 14,213 0 1,668 Subsequent to operation: 1,282 28,542 106 296 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 , 0 Gas ❑ WDSPL ❑ GSTOR ❑ WINJ ❑ WAGE] GINJ p 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 1 1 2 Printed Na oe Last fk- Title Petrotechnical Data Technologist Signat 1 e 1A1 at J Phone 564 -4091 Date 9/8/2011 HB)C MS SEP 0 9 2011 cz` c,q Form 10 -404 Revised 10/2010 , < / l/ Submit Original Only D -30B 206 -184 PERF ATTACHMENT Sw Name Operation Date Perf Operation Code Meas Depth Top Meas Depth Base Tvd Depth Top Tvd Depth Base D -30B 5/12/07 PER 11,430._ 11,640. 9,045.39 9,046.28 D -30B 5/12/07 PER 11,760. 11,950. 9,047.1 9,045.43 D -30B 8/13/11 BPS 11,400. 11,950. 9,044.53 9,045.43 D -30B 8/13/11 APF 11,084. 11,114. 9,038.79 9,038.67 D -30B 8/14/11 APF 10,940. 10,970. 9,050.16 9,047.61 D -30B 8/14/11 APF 11,020. 11,050. 9,042.44 9,040.27 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 I • • • • D -30B DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY 8/13/2011; CTU #8 w/ 1.5" CT (CTV= 30.2) Scope: Drift, Jewelry /Depth log, CIBP (GSO) w/ 90' add perfs Cont. POOH w /Drift assembly. RD drift assembly, PU PDS logging tools, RIH. Log GR/CCI from 11500' to 10400'. POH. RIH and set WFT 2 -3/8" CIBP at 11400'. RIH jw/ SWS 1.56" perf gun #1 and perforate.EVAC DRILL TO COINCIDE W /GC -3. Tag plug 11,385', correlate counter to top shot depth, 11,368'. Shoot 1st set of perfs from ; 11,084'- 11,114' 6 -SPF PJ -HMX. RIH w /gun set #2, pert from 11,020'- 11,050' 6 SPF PJ -HMX. « « <JOB IN PROGRESS »» 8/14/2011 CTU #8 w/ 1.5" CT (CTV =30.2) ;Scope: Drift, Jewelry /Depth log, CIBP (GSO) w/ 90' add perfs RIH w /2nd set of 30' guns, perf from 11,020'- 11,050' 6 -SPF PJ -HMX. POOH. Replace injector hose. RIH w/ pert gun #3 and perforate 10940 - 10970'. POH. FP well. RDMO to C -41 :Job complete 3 , 1 t FLUIDS PUMPED BBLS 152 1% KCL 22 50/50 METH 174 TOTAL TREE = 4" CIW 1 1, , ,,aamamma WELLHEAD :r FMC ACTUATOR = E3AKER C D -3 0 B SAFETY Nit:***WELL ANGLE > 70° @ 10046"** ***ORIGINA D-30A WELLBORES NOT SHOWN KB, ELEV = 78.25 , BELOW WHIPSTOCK*** BF. ELEV = 40.6' KOP = 1215' 1 2215' H4-1/2" HES HXO SSSV NIP ID = 3.813" 1 Max Angle = 96° @ 11001' • [ Datum MD = 9738' Datum TVD = 8800' SS GAS LIFT MANDRELS EV TY PO 10-3/4" CSG, 45.5#, L-80 BTC, ID = 9.950" H 3456' ST MD WD D PE VLV LATCH RT DATE LI 3 3779 3567 25 KBMG-M DOME BK 16 05/31/07 2 7144 6573 26 KBMG-M SO BK 20 05/31/07 1 9812 8921 58 KBMG-M DMY BK 0 12/14/02 9923' H4-1/2" HES X NIP, ID = 3.813" Minimum ID = t941" @ 9944' 3-3/16" X 2-7/8" XO 11 9933' J-17-5/8" X 4-1/2" BKR S-3 PKR, ID = 3.875" I 9936' H3.70" BOT DEPLOYMENT SLV, ID = 3.00" 1 :4 1 I t4 0 9944' H3-1/2" X 2-3/8" XO, ID = 1.941" I V*, mil 9957' 1 HES X NIP, ID = 3.813" (BEHIND CT LNR) I TOP OF CEMENT I 9960' 44 'Om P0 P, tt 1 9960' 1 — BKR LNR DEPLOY SLV W/SEAL LOC., 4 1 0 4 • ID = 2.39" i V t 9979' H4 HES XN NIP, ID = 3.725" (BEHIND CT LNR) I ,.4 0 4 N I 9980' H3-1/2" HES XN NIP, ID = 2.750" I tAl P i .til qv r 1 4; 9982' H3-1/2" X 3-3/16" BKR XO, D = 2.80" .0152 bpf, ID = 3.958" 4-1/2" TBG, 12.6#, L-80 BTC-M, 9991' ■Qa i AI 9991' 1--14 WLEG, ID = 3.958" I 1TOP OF 4-1/2" LNR I 10260' 4% WAI, V0 . 4 V .1 4 • I • 'OM 0 A I 7 CSG, 29.7#, USSS ID = 6.875" 1-1 10405' ' 4 . 0: V• 6 4 • 0 0 # 0:0 010 I 4 LNR, 12.6#, L D = 3.953" 1 10453' 4 9 04 4 6 1 ' ' \ 1; i 7 0 4 MILLOUT WINDOW (D 10495' - 10501' 0 ‘ , • 13 LNR, 6.2#, L TCII, .0076 bpf, ID = 2.80" 1 10496' 0 ■ ' • 'WHIPSTOCK 1-1 10496' 1 'v4.*A 1 10745' I IVIARKER 3' PUP JT i''' ...''"'■ "tt4 PERFORATION SUMMARY 1 11400' 1 WFD CIBP (08/13/11) I i r .4411 REF LOG: MCNL/CCL/GR ON 05/11/07 ANGLE AT TOP PERF: 95° @ 11020 IRA TAG I 10501' Note: Refer to Production DB for historical perf data So SIZE SPF - INTERVAL Opn/Sgz DATE 11949' 1 FISH - HYD DISC, 1.56" 6 11020 - 11050 0 08/14/11./ 4, CRC SUB, MOTOR & 1.56" 6 11084 - 11114 0 08/13/11 / MILL (05/11/07) 1.56" 6 11430 - 11640 0 05/11/07 '110•• 44,4 1.56" 6 11760 - 11950 0 05/11/07 1.56" 6 11940 - 11970 0 08/14/11 12-3/8" LNR, 4.7#, L-80 STL, .0039 bpf, ID = 1.995" H 12670' 1 DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 03/23/96 ORIG. HORZ. COMPLETION 08/18/11 PBS/ PJC CIBP/ ADPERFS (08/13 - 14/11) WELL D-30B 01/12/03 JLMITLH CTD SIDETRACK (D-304) PERMIT No: /41 206184 05/12/07 NORDIC 1 CTD SIDETRACK (D-30B) API No: 50-029-22646-02-00 05/13/07 IPAG DRLG DRAFT CORRECTIONS SEC 23, T11N, R13E, 1655' FNL & 1066' FEL 05/31/07 CJN/PAG GLV C/0 12/02/09 WH/JMD DRLG DRAFT CORRECTIONS BP Exploration (Alaska) . • bp BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB -20 Post Office Box 196612 Anchorage, Alaska 99519 -6612 Marc h 06, 2011 F tipta) 9- 368 Mr. Tom Maunder RECEIVE' Alaska Oil and Gas Conservation Commission 333 West 7 Avenue MAR 0 9 NI Anchorage, Alaska 99501 sk8 Oil & Cos Cons. Cession Subject: Corrosion Inhibitor Treatments of GPB D Pad Inctio,6g6 Dear Mr. Maunder, Enclosed please find multiple copies of a spreadsheet with a list of wells from D 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) Date: 03/04/11 Corrosion • Initial top Vol. of cement Final top of Cement top off Corrosion inhibitor/ Well Name PTD # API # of cement pumped cement date inhibitor sealant date ft bbls ft na gal D -01 A 1970780 50029200540100 NA N/A NA N/A 1/31/2011 D -03A 2001340 50029200570100 NA 14 NA 100.30 1/19/2011 D -04B 2031100 50029200560200 NA 4 NA 56.10 2/19/2011 D -05 1700060 50029200580000 NA 0 NA trace 1/19/2011 D -06A 1970430 50029201480100 NA 0.5 NA 3.40 1/7/2011 D -07B 2051810 50029201620200 NA 0.5 NA 3.40 1/7/2011 D -08A 2021230 50029203720100 NA 0.5 NA 3.40 2/9/2011 D -09A 1990850 50029203810100 NA 0.7 NA 3.40 1/19/2011 D -10 1790530 50029203890000 NA 2.3 NA 8.50 3/2/2011 D-1113 2100770 50029204350100 NA 3.5 NA 23.80 1/6/2011 0-12 1800150 50029204430000 NA 1.3 . NA 5.10 1/15/2011 D -13A 2000810 50029204490100 NA 0.5 NA 2.55 3/31/2010 D -14A 1961530 50029204500100 NA 0.2 NA 0.85 1/15/2011 D -15A 1972120 50029204610100 NA 0.2 NA 0.85 1/15/2011 D -16A 2090250 50029206830100 NA 0.1 NA 0.85 2/20/2011 • D -17B 2021110 50029206920200 NA 1 NA 3.40 2/19/2011 D -18A 2011030 50029206940100 NA 5.4 NA 34.00 2/20/2011 D -19B 2011120 50029207070200 NA 0.8 NA 3.40 2/19/2011 0 1820440 50029207800000 NA 0.5 NA 1.70 2/19/2011 0-21 1820520 50029207880000 NA 0.2 NA 3.40 2/10/2011 D -22C 2081210 50029207370300 NA 0.2 NA 0.85 2/10/2011 D -23A 1961880 50029207380100 NA 13.5 NA 93.50 3/1/2011 0-24 1852990 50029215060000 NA 0.9 NA 6.80 1/8/2011 D -25A 2000240 50029215220100 NA 6 NA 32.30 1/15/2011 D -26B 2060980 50029215300200 NA 0.8 NA 3.40 2/19/2011 0-27A 2051930 50029215430100 NA 0.3 NA 1.70 2/10/2011 0-28B 2090890 50029215560200 NA 0.3 NA 1.70 2/10/2011 0-29 1852530 50029214700000 NA 13.3 NA 27.20 1/16/2011 �� D -30B 2061840 50029226460200 NA 2.2 NA 13.60 12/25/2010 D -31A 1960950 50029226720100 NA 3.3 NA 27.20 1/19/2011 0-33 1960360 50029226520000 NA 2.2 NA 18.70 1/8/2011 >~.~ ~ p ,, ,~,,,, "+, >, ~~ ~. ~.. ~- '~~ w$ _. ~.. ~, ~- ~. ~. t. ~..~ ,r ~, -- MICROFILMED 6/30/2010 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE C:\temp\Temporary Internet Files\OLK9\Microfilm_Marker.doc ~ ~1--~.. DATA SUBMITTAL COMPLIANCE REPORT 6/2/2009 Permit to Drill 2061840 Well Name/No. PRUDHOE BAY UNIT D-306 Operator BP EXPLORATION (ALASKI~ INC API No. 50-029-22646-02-00 MD 12670 ND 9046 Completion Date 5/12/2007 Completion Status 1-OIL Current Status 1-OIL UIC N REQUIRED INFORMATION Mud Log No Samples No Directional Survey es DATA INFORMATION Types Electric or Other Logs Run: MWD DIR, GR, RES, GR /CCL /CNL Well Log Information: Log/ Electr Data Digital Dataset Log Log Run (data taken from Logs Portion of Master Well Data Maint Interval OH / type mearrrmi rnwnurr rvame acme ~nrwa rvo wart slop ~.n rcecervea ~.ommenis D C Lis 15473 Neutron 9695 11935 Case 10/3/2007 LIS Veri, GR, CNT w/PDS and TIF graphics og 15473 Neutron 25 Blu 1 9703 11935 Case 10/3/2007 MCNL, Mem GR, CCL, CCL, CNL 10-Mat-2007 D D Asc Directional Survey 10486 12670 Open 7/24/2007 pt Directional Survey 10486 12670 Open 7/24/2007 D C Lis 15731 Induction/Resistivity 10490 12670 Case 12/6/2007 LIS, GR, ROP, RPD, RPS w/TXT and Meta graphics pt 15731 Induction/Resistivity 10490 12670 Case 12/6/2007 LIS, GR, ROP, RPD, RPS ~g Gamma Ray 25 Blu 10496 12670 Open 12/6/2007 GR 6-May-2007 og Induction/Resistivity 25 Blu 10496 12670 Open 12/6/2007 MD GR, MPR 6-May-2007 og Induction/Resistivity 2 Blu 10496 12670 Open 12/6/2007 TVD GR, MPR 6-May-2007 og See Notes 2 Blu 10490 11950 Open 12/6/2007 Depth Shift Monitor Plot Well Cores/Samples Information: Sample Interval Set Name Start Stop Sent Received Number Comments DATA SUBMITTAL COMPLIANCE REPORT 6/2/2009 Permit to Drill 2061840 Well Name/No. PRUDHOE BAY UNIT D-30B MD 12670 TVD 9046 ADDITIONAL INFORMATION Well Cored? Y 1' ~ Chips Received? 14714--' Analysis Y~ftd'- Received? Completion Date 5/12/2007 Operator BP EXPLORATION (ALASKI~ INC Completion Status 1-OIL Current Status 1-OIL Daily History Received? Formation Tops API No. 50-029-22646-02-00 UIC N Comments: Compliance Reviewed By: Date: i i i 'i , Transmittal Form BAKER HUGHES INTEQ Anchorage GEOScience Center To: AOGCC 333 West 7~h Ave, Suite 100 Anchorage, Alaska 99501 Attention: Christine Mahnken Reference: D-30B Contains the following: 1 LDWG Compact Disc (Includes Graphic Image files) 1 LDWG lister summary 1 blueline - GR Directional Measured Depth Log 1 blueline - MPR/Directional TVD Log 1 blueline - NIPR/Directional Measured Depth Log 1 blueline -Monitor Log LAC Job#: 1419644 Sent By: Deepa J glekar Dater DecT, 2007 -~- Received By: Date: PLEASE ACKNOWLEDGE RECEIPT BY SIGNING & RETURNING OR FAXING YOUR COPY FAX: ~°~?~ ZS', -6aj2~ ~6~4 _ ~ ~ L( ¢ ~ S ~ ~ ~ Baker Hughes INTEQ 7260 Homer Drive Anchorage, Alaska 99518 Direct: (907) 267-6612 FAX: (907) 267-6623 6Lt Nb #0 Atl t ~- ' "- __ ,,;.:r,: ,.... • Transmittal Form BAKER HUGHES INTEQ To: AOGCC 333 West 7th Ave, Suite 100 Anchorage, Alaska 99501 Attention: Christine Mahnken Reference: D-30B • Anchorage GEOScience Center Contains the following: 1 LDWG Compact Disc (Includes Graphic Image files) 1 LDWG lister summary 1 blueline - GR Directional Measured Depth Log 1 blueline - MPR/Directional TVD Log 1 blueline - MPR/Directional Measured Depth Log 1 blueline -Monitor Log LAC Job#: 1419644 Sent By: Deepa J glekar Received By: .~ Date:~`Dec:'7, '2007 ~. ~, ~ ~~ Date: _ _..~ - PLEASE ACKNOWLEDGE RECEIPT BY SIGNING & RETURNING OR FAXING YOUR COPY FAX: ~°0?~ 26', -562 ~6~ _ ~ ~ L j ~ ~ s ~- 3 / Baker Hughes INTEQ 7260 Homer Drive Anchorage, Alaska. 99518 Direct: (907) 267-6612 FAX: (907) 267-6623 mLti NA-IDM.S}AL H~1jj -I -,.........., ~~I . ~ r ~~. ~_:„. 09/28/07 NO. 4440 Alaska Data 8 Consulting Services Company: State of Alaska 2525 Gambell Street, Suite a00 Alaska Oil & Gas Cons Comm Anchorage, AK 99503-2838 Attn: Christine Mahnken ATTN: Beth 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay Well Jnh # Inn nasrrinfinn rlafn RI Cnlnr rtn 15-06A 11661158 MCNL 4~' L 06/21/07 1 F-26B 11216200 MCNL ~t </ 06/06/06 1 P2-11A 11285926 MCNL ~ 04/19/06 1 1 C-31B 11745223 MCNL ~L/ 05/31/07 1 1 E-03A 11628773 MCNL ~ ~C/ 05/09/07 1 1 K-12A 11745224 MCNL O _ ~, 06!02/07 1 1 18-10B 11485771 MCNL ~ / ~/`a-(o 11/08/06 1 1 C-086 11209599 MCNL --trj ~ ( (5L 04/22/06 1 1 D-30B 11628774 MCNL L '~' 05/10/07 1 1 fLCr1.7C NVnIVVVV6CUl7C RC~.CIr'1 6T .7WIVInIb Mn1U RGIURIVInIb VIVO IiVYT tHla'f 1V: BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 ~ ,, T!, ~i 900 E. Benson Blvd. °~- -' Anchorage, Alaska 99508 Date Delivered: ;, :~ ii~.i9f?@T Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth ) Received by: • ~ Page 1 of 2 Fleckenstein, Robert J (DOA) From: Hubble, Terrie L [Terrie.Hubble@bp.com] Sent: Thursday, July 26, 2007 11:32 AM To: Fleckenstein, Robert J (DOA) Cc: Saltmarsh, Arthur C (DOA) Subject: FW: PBU D-30B /PTD # 206-184 Per your request... Additional requested information. Top Perf MD: 11430' Bottom Perf MD: 11950' From: Hubble, Terrie L Sent: Friday, July 20, 2007 11:38 AM To: art_saltmarsh@admin.state.ak.us Subject: PBU D-30B /PTD # 206-184 Hi Art, Please reference the following well: Well Name: PBU D-30B Permit #: 206-184 API #: 50-029-22646-02-00 This well began Production on July 14, 2007 Method of Operations is: Flowing Date of Test: July 18, 2007 Hours Tested: 6 24-Hour Rate /Oil-Bbl: 1,014 24-Hour Rate /Gas-Mcf: 7,478 24-Hour Rate /Water-Bbl: 760 Test Rate /Oil-Bbl: 254 Test Rate /Gas-Mcf: 1,870 Test Rate /Water-Bbl: 190 Choke Size: 176 Gas-Oil Ration: 7,374 Flow Tubing Pressure: 200 Casing Pressure: 800 R ~~ JUL 2 61D07 7/26/2007 . ~ Page 2 of 2 Oil Gravity-API: Unavailable 7/26/2007 . STATE OF ALASKA ~~~~~~ ALASKA~IL AND GAS CONSERVATION COSSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG ~E~VE JLIN ~ 8 2007 ~iaska tail ~ Gas Cons. Cofnmissiori 1 a. Well Status: ®Oil ^ Gas ^ Plugged ^ Abandoned ^ Suspended 2oAAC zs.,os soAAC zs.,,o ^ GINJ ^ WINJ ^ WDSPL ^ WAG ^ Other No. of Completions One 1 b. Well Class: nC ol'age ®Development ^ Exploratory ^ Service ^ Stratigraphic 2. Operator Name: BP Exploration (Alaska) Inc. 5. Dat Comp , Susp., or Aba 5/12/2007 .,fly 12. Permit to Drill Number 206-184 - 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 6. Date Spudded 5/2/2007 ~' 13. API Number 50-029-22646-02-00 4a. Location of Well (Governmental Section): Surface: ' ' 7. Date T.D. Reached 5/6/2007 ' 14. Well Name and Number: PBU D-30B , 3625 FSL, 1066 FEL, SEC 23, T11 N, R13E, UM Top of Productive Horizon: 4994' FSL, 2664' FWL, SEC 24, T11 N, R13E, UM 8. KB (ft above MSL): 78.25' Ground (ft MSL): 40.6' 15. Field /Pool(s): , Prudhoe Bay Field / Prudhoe Bay Total Depth: 4789' FSL, 1488' FWL, SEC 24, T11 N, R13E, UM 9. Plug Back Depth (MD+TVD) 11949 9045 Pool 4b. Location of Well (State Base Plane Coordinates, NAD 27): Surface: x- 654088 y- 5959346 Zone- ASP4 10. Total Depth (MD+TVD) 12670 i 9046 16. Property Designation: ADL 028285 TPI: x- 657788 y- 5960793 Zone- ASP4 Total Depth: x- 656616 y- 5960563 Zone- ASP4 11. SSSV Depth (MD+TVD) None None 17. Land Use Permit: 18. Directional Survey ®Yes ^ No Submit electronic and rinted information er 20 AAC 25.050 19. Water depth, if offshore N/A ft MSL 20. Thickness of Permafrost (TVD): 1900' (Approx.) 21. Logs Obtained (List all logs here and submit electronic and printed information er 20 AAC 25.071): MWD DIR, GR, RES, GR ! CCL / CNL ~iVDOs/~ J0,~9~ ~'MD 9Q~,~ Sryb~ 22. CASING, LINER AND CEMENTING RECORD CASING SETTING DEPTH MD SETTING DEPTH TVD HOLE AMOUNT WT: PER FT. GRADE TOP BOTTOM ' TOP BOTTOM SIZE CEMENTING RECORD PULLED ` 20" 91.5# H-40 Surfac 110' Surface 110' 30" 260 sx Arctic et A rox. 10-3/4" 45.5# L-80 35' 3456' 35' 3276' 13-1/2" 1165 sx Permafrost'E' 498 sx'G' 7-5/8" 29.7# USSS-95 36' 10405' 36' 9048' 9-7/8" 553 sx Class 'G' 4-1/2" 12.6# L-80 10234' 10453' 9 50' 9047' 6-3/4" 636 sx Class 'G' 3-1/2" x 3-3/16" 8.81# / 6.2# L-80 9944' 8982' 9044' 3-3/4" 113 sx Class'G' 2-3/8" 4.7# L-80 9936' 12670' 8979' 9046' 3" 82 sx Class 'G' 23. Open to production or inject ion? ®Yes ^ No 24. TueING RECORD If Yes, list each i (MD+TVD of Top & Bottom; Pe nterval open rforation Size and Number): SIZE DEPTH SET MD PACKER .SET MD 1.56" Gun Diameter, 6 spf 4-1/2", 12.6#, L-80 9991' 9933' MD TVD MD TVD 11430' - 11640' 9045' - 9046' 11760' - 11950' 9047' - 9045' 25. ACID, FRACruRE CEMENT.SQUEEZE, ETC. . DEPTH INTERVAL MD AMOUNT ~ KIND OF MATERIAL USED 2500' Freeze Protect w/ McOH 26. PRODUCTION TEST Date First Production: Not on Production Yet Method of Operation (Flowing, Gas Lift, etc.): N/A Date Of Test: HOUrS Tested: PRODUCTION FOR TEST PERIOD OIL-BBL: GAS-MCF: WATER-BBL: CHOKE SIZE: GAS-OIL RATIO: Flow Tubing PreSS. CaSing PreSS: CALCULATED 24-HOUR RATE• OIL-BBL: GAS-MCF: WATER-BBL: OIL GRAVITY-API (CORK): 27. CORE DATA Conventional Core(s) Acquired? ^Yes ®No Sidewal l Core s A wired? ^Yes ®No If Yes to either question, list formations and intervals cored (MD+TVD of top and bottom of each), and summarize lithology and presence of oil, gas or water (submit separate sheets with this form, if needed). Submit detailed descriptions, core chips, photographs and laboratory analytical results per 20 AAC 250.071. L J~~1 ,~i ..~ S None ~ ~~ JUN ~. 4 ?D09 ~ 5-~ '4 ~ ~~D Form 10-407 Revised 02/2007 C NTINUED ON REVERSE SIDE rt'~ l~IC~~~IAL / 2S. GEOLOGIC MARKERS (LIST ALL FORMATIONS A KERS ENCOUNTERED): 29. FORMATION TESTS NAME D TVD Well Teste ^ Yes ®No Permafrost Top If yes, list intervals and formations tested, briefly summarizing test results. Attach separate sheets to this form, if needed, and submit Permafrost Base detailed test information per 20 AAC 25.071. Top of Zone 2A 10029' 9014' None (From Original Well, D-30) ------ -------------------------- - 14N/ Top Zone 1 B 10837' 9052' Formation at Total Depth (Name): Zone 2A 12668' 9046' 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. // ~ b~o8 / ~ ~ Q Title Technical Assistant Date Signed Terrie Hubble 1 PBU D-306 206-184 Prepared ByNameMumber. Terrie Hubble, 5 64-4628 Well Number Drilling Engineer: Pedro Rangel, 564-4623 Permit N . / A r val 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. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. IreM 1a: Classification of Service Wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. IreM 4b: TPI (Top of Producing Interval). IreM 8: The Kelly Bushing and Ground Level elevation in feet above mean sea level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. ITEM 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). IreM 20: Report true vertical thickness of permafrost in Box 20. Provide MD and TVD for the top and base of permafrost in Box 28. IreM 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. IreM 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). ITEM 28: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, or Other (explain). IreM 27: Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Submit detailed description and analytical laboratory information required by 20 AAC 25.071. IreM 29: Provide a listing of intervals tested and the corresponding formation, and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Form 10-407 Revised 02/2007 Submit Original Only BP EXPLORATION Operations Summary Report Legal Well Name: D-30 Common Well Name: D-30 Event Name: REENTER+COMPLETE Contractor Name: NORDIC CALISTA Rig Name: NORDIC 1 Start: 4/27/2007 Rig Release: 5/12/2007 Rig Number: N1 Date From - To Hours I Task I Code : NPT I Phase 4/27/2007 13:30 - 17:00 3.50 RIGD P PRE 17:00 - 00:00 7.00 MOB P PRE 4/28/2007 00:00 - 09:30 9.50 MOB N RREP PRE 09:30 - 10:30 1.00 MOB N WAIT PRE 10:30 - 20:30 10.00 MOB N WAIT PRE 20:30 - 22:00 1.50 MOB P PRE 22:00 - 00:00 2.00 BOPSU P PRE 4/29/2007 00:00 - 02:30 2.50 BOPSU P PRE 02:30 - 08:30 6.00 BOPSU P PRE 08:30 - 11:00 I 2.501 BOPSUFi N I HMAN I PRE 11:00 - 12:30 1.50 BOPSUFj P PRE 12:30 - 15:00 2.50 STWHIP P WEXIT 15:00 - 18:30 3.50 STWHIP P WEXIT 18:30-19:00 0.50 STWHIP P WEXIT 19:00 - 19:30 0.50 STWHIP P WEXIT 19:30 - 20:15 0.75 STWHIP P WEXIT 20:15 - 21:30 I 1.251 STWHIPI P I I WEXIT 21:30 - 21:55 0.42 STWHIP P WEXIT 21:55 - 23:00 1.08 STWHIP P WEXIT 23:00-00:00 1.00 STWHIP P WEXIT 4/30/2007 00:00 - 00:45 0.75 WHIP P WEXIT 00:45-01:35 I 0.831 WHIP IN ISFAL (WEXIT 01:35-02:00 0.42 WHIP N SFAL WEXIT 02:00-02:10 0.17 WHIP P WEXIT 02:10 - 02:30 0.33 WHIP P WEXIT 02:30-03:30 1.00 WHIP P WEXIT 03:30-06:30 I 3.OOIWHIP IP I (WEXIT Page 1 of 14 ~ Spud Date: 12/20/2002 End: 5/12/2007 Description of Operations Prep rig for turnkey rig move from P2-22 to D-30B, 12.4 miles Turnkey rig move - At 2100 hrs, Nordic 1 broke down with a blown inside rear fire off driller's side at the front of K pad access road, prepping fire for change out Turnkey rig move -Prepping inside rear fire on off driller's side, change out fire with new one Wait on Security, 1 hour, Turnkey rig move to D-Pad Waiting on Well Site Prep, changed top rams in BOP stack PJSM for moving over well, Back in over well, spot cutting box. Accept rig at 22:00 hours, 4/28/07 Greased tree and choke manifold, NU BOP's NU BOPS, change out btm set of rams Testing BOP, all rams, valves and lines to 250 psi - 4000 psi, annular preventer 250 psi - 2500psi, choke manifold valve #2 failed, redressed and tested #2 valve, OK, tested rams with 2" and 2 3/8" test joint, hard line to tiger tank OK, Jeff Jones w/ AOGCC waived witnessing BOP test. Re tests to 4000 psi test performed between 06:00 & 08:30 due to conflicting documents. RU lubricator and Pull BPV.LD BPV and lubricator. Fill pits while stabbing stripper and injector.. Thread cable thu injector to reel house. Attach grapple to CT. PT & pull coil to injector. Cut off coil connector. Coil straightener test. Attempt to straighten pipe with 600, 650, 700, 750, 900 & 1100 psi No impact. ram has bottomed out. Adjusted ram but still bottoming out. Repin to allow for more cylinder travel. Retest getting reverse bend at 500 psi. Retest 350 psi required to make 3 contact points. Increase pressure to 450 psi. Test Successful pipe deflection approximately 1/16" in 3' run. No pipe damage on any of the samples. Total 93' cut. Prep for slack management, RU reverse line to pits PJSM on slack management Circ, 5bbls, 1.50bpm, 200 psi, test inner reel valve to 4000 psi, filled CT w/ 42 bbls Rev circ for slack management while bring up Baker tools to rig floor Std Bk Injector, RU hydraulic CT cutter, cut 65' of 2" CT, leaving 8' of a-line hanging, offload cut pieces of CT to pipeshed Installed dipple CTC, pull test to 35k Heading up 2" a-coil thru Baker upper quick connect Finish heading up 2" a-coil thru Baker upper quick connect, Megger E Line, 2000+ Meg Ohms, 46 Ohms continuity test SLB installed RA tag, 5' from top of whipstock RU nozzle, stab injector, attempt to circ, CT froze up, RIH to thaw out CT to 2337', pump at 1.02bpm, 1050psi POH to BHA, brk out inj and UOC, LD nozzle Install base plate plug, test CTC to 3500psi PJSM on handling and running whipstock assy MU whipstock, packer assy, BHA #1, orient WS to MWD, Stab injector RIH w/ W hipstock/Packer Assy, surface check mwd tools, Up Printed: 5/14/2007 10:50:45 AM ~ ~ BP EXPLORATION Operations Summary Report ~~ ~.3oQ Legal Well Name: D-30 Common Well Name: D-30 Event Name: REENTER+COMPLETE Contractor Name: NORDIC CALISTA Rig Name: NORDIC 1 Date From - To Hours Task i Code 4/30/2007 03:30 - 06:30 3.00 WHIP P 06:30 - 07:10 0.67 WHIP P 07:10 - 07:30 I 0.331 WHIP I P V/.JV - VV.VV V.JV YYI Ilr r 08:00 - 08:30 0.50 WHIP P 08:30 - 11:15 2.75 WHIP P 11:15 - 11:30 0.25 WHIP P 11:30 - 00:00 12.50 WHIP N 5/1 /2007 100:00 - 14:30 I 14.50 I WHIP I N 14:30 - 20:30 I 6.001 WHIP I N I RREP IWEXIT 20:30 - 00:00 I 3.501 WHIP I N I IWEXIT 5/2/2007 00:00 - 00:15 0.25 STWHIP P WEXIT 00:15 - 01:30 1.25 STWHIP P WEXIT 01:30 - 03:45 I 2.251 STWHIPI P I IWEXIT 03:45 - 04:00 I 0.251 STWHIPI P I IWEXIT 04:00-04:25 I 0.421STWHIPIP I IWEXIT 04:25 - 05:25 I 1.001 STWHIPI P I IWEXIT 05:25 - 10:40 I 5.251 STWHIPI P I IWEXIT Start: 4/27/2007 Rig Release: 5/12/2007 Rig Number: N1 NPT Phase WEXIT WEXIT WEXIT WEXIT WEXIT WEXIT WEXIT RREP WEXIT RREP IWEXIT Page 2 of 14 Spud Date: 12/20/2002 End: 5/12/2007 Description of Operations wt 34.5k at 9900', Dn wt 18.8k RIH to 10440'. Log down at 2.4 fpm Tie - in log. Correction -11 ft. Up Wt = 31.8K RIH place top of WS at 10495'. 93R . Close EDC. Pressure up slowly to 1500 psi. hold for 1 minutes pressure to 2000 psi Shear at 2000 psi. PU to 10449 and Circulate crude from well. POH. Turbo Charger FIRE on #2 Cat extinguished by crew . Notify PBU Fire Chief. L Crane & Alan Graft POH slow on one motor LD WS running tools. Wait on Cat mechanic to evaluate fire damage, Turbo chargers failed on #2 Cat, cause under investigation. Using turbo chargers from motor that had exciter failure, located at Catipillar in Anchorage. Shipping from Anchorage on first flight out on 05/01/2007, Performing general housekeeping, inspecting rig equipment Wait on repair parts for #2 Cat from Anchorage, Turbo chargers failed on #2 Cat, cause under investigation. Performing general housekeeping, inspecting rig equipment Cat mechanic arrived at rig, installing blower on motor, waiting on turbo chargers to arrive from Anchorage, ETA on slope at 17:30 hours with Alaska Airlines, Performing general housekeeping, inspecting rig equipment Turbo chargers arrive rig. Changeout turbo charges on Gen Set #2. Function test Gen #2 ESD valves - OK. Meanwhile fill hole with 11 bbls of bio-KCL water. PJSM for P/U &RIH window milling BHA. M/U window milling BHA #2 with a 2.74" HC DSM, 2.74" diamond string reamer, Baker straight Xtreme motor, BHI DGS, DPS, EDC, P&C & LOC. M/U injector. RIH with milling BHA #2 pumping ~ min rate thru open EDC. Observe BHI VSS (Vibration Stick-Slip) sensors not working. Continue RIH past XN nipple to 10100'. Wt check: Up = 32.7k, down = 15k. Log down GR @ 150fph & tie into formation marker. Had +31' correction on BHI depth. Suspect wrong BHI depth tracking did not correct CTD. Check & found out that wrong BHA length was used for bit to GR sensor calculation. RIH with milling BHA #2. Dry tag WS/Lnr pinch pt @ 10493.7' Close EDC & bring on pumps. Wt check: Up = 30k, down = 17.5k. Retag WS/Lnr pinch pt C~ 10493'. Flag pipe & correct both CTD &BHI depth to 10495' (pinch pt CTD). - Start milling window with 1.7/1.7bpm 3150/3350psi, 1-2k DWOB & lfph ave ROP. Mill to 10496'. Mill window to 10500' with 1.7/1.7bpm 3150/3350psi, 1-2k DWOB & lfph ave ROP, Drilled 10' of new hole from 10500' - 10510' with 1.6/1.6bpm 3350/3300psi, 2 - 3k DWOB Unconfirmed depths of TOWS 10495', BOWS 10504', RA tag 10500', TOW 10495', BOW 10500' 10:40 - 11:45 1.08 STWHIP P WEXIT Displacing well to Flo-Pro, worked thru window several times, no problems Printed: 5/14/2007 10:50:45 AM BP EXPLORATION Operations Summary Report Page 3 of 14 Legal Well .Common W .Event Nam Contractor Aig Name: Date ~ Name: ell Name: e: Name: From - To D-30 D-30 REENTE NORDIC NORDIC Hours j R+COM CALIST 1 Task ~ PLET A Code E NPT Start Rig Rig Phase ' Spud Date: 12/20/2002 : 4/27/2007 End: 5/12/2007 Release: 5/12/2007 Number: N1 Description of Operations ',5/2/2007 11:45 - 14:00 2.25 STWHIP P WEXIT POH to BHA #2, displacing well to Flo-pro 14:00 - 14:45 0.75 STW HIP P WEXIT LD Baker motor and mill assy, Mills gauged out at 2.73" go / 2.72" no go, offload Baker tools down beaver slide ~~ 14:45 - 15:45 1.00 DRILL P PROD1 Changed out DPS, surface test tools 15:45 - 16:00 0.25 DRILL P PROD1 MU Drlg BHA #3, PU 2.70 degree X-treme motor, 2.7" x 3" DOSTRWD3242.70 Bit, HOT, DGS, DPS, EDC POWERCOMMS, WEAR SUB, LOC, scribe mtr to HOT, MU UOC, CTC, Stab injector 16:00 - 16:25 0.42 DRILL P PROD1 Performed surface test on BHI tools, OK 16:25 - 18:30 2.08 DRILL P PROD1 RIH with drilling BHA #3. 18:30 - 18:45 0.25 DRILL P PROD1 Conduct a rig evacuation drill - had a satisfactory response by the crew. Review procedure & roles and responsibilities during rig evacuation. Also noted some issues to be addressed (see Remarks section). Also had a camp fire/evacuation drill. 18:45 - 19:10 0.42 DRILL P PROD1 Tag @ 9960' -suspect top of Bkr Inr deploy slv. Close EDC. Roll pumps & run thru TO 3-1/2" Lnr. EOP flag is right on depth. Continue RIH to 10410'. 19:10 - 19:45 0.58 DRILL P PROD1 Log down GR @ 150fph & tie into formation marker. Correct BHI depth by +17' & CTDS by +2'. 19:45 - 20:00 0.25 DRILL P PROD1 RIH clean thru window & tag btm ~d 10512'. Commence drilling turn. Up wt = 29k. Run-in wt = 18k. PVT = 321 bbls. IAP = 115psi. OAP = Opsi. Freespin = 1.7bpm/2700psi. 20:00 - 21:40 1.67 DRILL P PROD1 Drill to 10700' with 95-100R TF, 1.7/1.7bpm, 2700/3000psi, 9.24ppg ECD, 2k DWOB & 145fph ave ROP. Saw RA Pip tag ~ 10501'. Adjust window depths to TOWS/TOW = 10496', BOW = 10501'. 21:40 - 22:15 0.58 DRILL P PROD1 Wiper trip clean to window. RBIH clean to btm. 22:15 - 00:00 1.75 DRILL P PROD1 Attempt to drill past 10700' -stacking wt & not getting any motor work. Work string without success. Attempt to drill with -10k CT wt - no luck. Suspect hi-DLS area on btm. No Lo-Torq on location so mix & pump down 30bbls of safe tube pill. Work string & finally take off drilling. li5/3/2007 00:00 - 00:45 0.75 DRILL P PROD1 Drill to 10780' with 95-100R TF, 1.7/1.7bpm, 2700/3000psi, 9.27ppg ECD, 1 k DWOB & 115fph ave ROP. Mix & pump down another 30bbls of safe tube pill. 00:45 - 01:00 0.25 DRILL P PROD1 Shoot off btm surveys. Confirm 67degs DLS from 10689' to 10728'. Decide to POOH for smaller bend motor. 01:00 - 02:45 1.75 DRILL P PROD1 POOH drilling BHA #3. paint EOP flag @ 9800'. Open up EDC. ~ 02:45 - 03:00 0.25 DRILL P PROD1 PJSM & THA for changing out BHAs. 03:00 - 03:40 0.67 DRILL P PROD1 OOH. S/B injector & UD BHA#3. Bit grade 2/1/I. ', 03:40 - 04:40 1.00 DRILL P PROD1 M/U lateral BHA #4 with BHI UOC, LOC, P&C, EDC, DPS, DGS, USMPR, HOT, 0.8deg X-treme motor & new Hycalog 2.7" x 3" SRX3408M bicenter bit #3. Scribe tools & M/U ~, injector. 04:40 - 07:00 2.33 DRILL P PROD1 Open up EDC &RIH lateral BHA#4 to 10480' 07:00 - 07:20 0.33 DRILL P PROD1 Tie-in pass f/ 10480' - 10500', missed RA tag, PU to 10470', repeat tie-in pass, +16' correction 07:20 - 07:30 0.17 DRILL P PROD1 RIH lateral BHA #4 tagged btm, 1.52/163 bpm 2633/2550psi, Up wt 32k, Dn wt 16.5k, PVT 321 bbls j 07:30 - 08:15 0.75 DRILL P PROD1 Madd Pass to 10520', RBIH to Btm !, 08:15 - 11:25 3.17 DRILL P PROD1 Drill to 10925' with 90 - 33R TF, 1.51/1.61 bpm, 2975/2914psi, Printed: 5/14/2007 10:50:45 AM ~ ~ BP EXPLORATION Page 4 of 14 Operations Summary Report Legal Well Name: D-30 Common Well Name: D-30 Spud Date: 12/20/2002 Event Name: REENTER+COMPLETE Start: 4/27/2007 End: 5/12/2007 Contractor Name: NORDIC CALISTA Rig Release: 5/12/2007 Rig Name: NORDIC 1 Rig Number: N1 Date From - To ~ Hours ; Task Code NPT Phase Description of Operations 5/3/2007 08:15 - 11:25 3.17 DRILL P PROD1 9.30ppg ECD, 2.65k DWOB & 87 - 41fph ROP. PVT 321 bbls 11:25 - 11:45 0.33 DRILL P PROD1 W iper to 10525', 5k overpulls at 10760' and 10721', RIH to btm, 5k down drag at 10720', rest of hole, no problems 11:45 - 13:15 1.50 DRILL P PROD1 Drill to 11075' with 141 - 177R TF, 1.51/1.61 bpm, 13:15 - 14:00 0.75 DRILL P PROD1 14:00 - 15:45 1.75 DRILL P PROD1 15:45 - 16:45 1.00 DRILL P PROD1 16:45 - 18:30 1.75 DRILL P PROD1 18:30 - 20:05 1.58 DRILL P PROD1 20:05 - 21:30 1.42 DRILL P PROD1 21:30 - 21:45 0.25 DRILL P PROD1 21:45 - 22:00 0.25 DRILL P PROD1 22:00 - 22:30 0.50 DRILL P PROD1 22:30 - 00:00 1.50 DRILL P PROD1 5/4/2007 00:00 - 01:25 1.42 DRILL P PROD1 01:25 - 02:30 1.08 DRILL P PROD1 02:30 - 06:00 3.50 DRILL P PROD1 06:00 - 06:45 0.75 DRILL P PROD1 06:45 - 07:45 1.00 DRILL P PROD1 07:45 - 10:10 2.42 DRILL P PROD1 3050/2950psi, 9.51 ppg ECD, 1.25k DWOB & 76 - 100fph ROP. PVT 312bb1s Wiper to 10525', no problems Drill to 11225' with 178-102R TF, 1.60/1.65bpm, 3250/3200psi, FS 2900psi, 9.59ppg ECD, 1.28k DWOB & 102 - 144fph ROP. PVT 304bb1s Wiper to 10525', no problems, RIH to btm, 5k down drag at 10715', and 10913', rest of hole, no problems Drill to 11300' with 80R TF, 1.60/1.65bpm, 3153/3100psi, FS 2845psi, 9.6ppg ECD, 1.24k DWOB & 87fph ROP. PVT 302bb1s Drill to 11398' with 120R TF, 1.7/1.7bpm, 30800/3250psi, 9.65ppg ECD, 2k DWOB & 75fph ave ROP. Up wt = 30k. Run-in wt = 11 k. PVT = 310bb1s. IAP = 185psi. OAP = Opsi. Freespin = 1.7bpm/3080psi. Wiper trip to 9700' (46degs inch. Had 10k O/pull ~ 10965' & 10755'. Had +/-5k O/pull across shale interval from 10900' to 10800'. RBIH to 10450'. Log down GR @ 150fph & tie into formation marker. Correct BHI & CTDS depths by +6'. RBIH. Set down in shale C~ 10920'. Poke thru & continue RIH to btm. Drill to 11484' with 70-110R TF, 1.7/1.7bpm, 3080/3200psi, 9.82ppg ECD, 1 k DWOB & 75fph ave ROP. Stacking wt & drilling ratty. Drill to 11548' with 10-70R TF, 1.7/1.7bpm, 3080/3400psi, 9.82ppg ECD, 1 k DWOB & 45fph ave ROP. Wiper trip to window. RBIH to btm. Shale interval was relatively clean. Attempt to drill ahead -stacking wt without much progress. Mix & pump down 25bbls of to-torq pill while W.O. new mud to arrive onsite. Take off drilling with pill out of bit. Drill to 11645' with 90L TF, 1.7/1.7bpm, 3080/3400psi, 9.77ppg ECD, 1.5k DWOB. Short wiper trip to 11430', displacing well to new Flo-Pro mud w/ 4 percent Lo-Torq and 12 PPB Kla-Gard at 1.68bpm, 3146psi, Up wt 28.9k Drill to 11697' with 75-52R TF, FS 2900psi at 1.61 bpm, 1.62/1.67bpm, 3135/3164psi, 9.58ppg ECD, 1.50k DWOB & 60-160fph ave ROP, Dn wt 11.6k, Up wt 30.5k, drilling with a -8.6k on CT weight transfer Wiper trip to window, slight bobbles at 10920', 10710'. RBIH, orienting motor to same as drilled, set down at 10811', PU, RIH to 10840', hole ratty to 10900', set down, attempt to work thru, POH to 10800', Up wt 34- 37K, RBIH, Dn wt 15k with 5 - 10k down drag at 10863', reduced pumps to get past 10863' w/ 15 - 11 K Dn Wt, RIH to 10913', PU, working thru ratty hole interval f/ 10840' - 10900', RBIH to 11650', work pipe do to btm, Dn wt Printed: 5/14/2007 10:50:45 AM ~ ~ BP EXPLORATION Page 5 of 14 Operations Summary Report Legal Well Name: D-30 Common Well Name: D-30 Spud Date: 12/20/2002 Event Name: REENTER+COMPLETE Start: 4/27/2007 End: 5/12/2007 Contractor Name: NORDIC CALISTA Rig Release: 5/12/2007 Rig Name: NORDIC 1 Rig Number: N1 Date j From - To Hours Task Code NPT Phase Description of Operations 5/4/2007 07:45 - 10:10 2.42 DRILL P PROD1 15k with 3 - 5k down drag Discussed ratty hole with town engineer, agreed to weighting mud system up to 9.2ppg incorporating the same mud properties. 10:10 - 12:15 2.08 DRILL P PROD1 Drill to 11739' with 56 - 45R TF, 1.52/1.61bpm, 3050/3059psi, 9.47ppg ECD, .5 - 1.34k DWOB & 100-162fph ave ROP, Dn wt 11.6k, Up wt 30.5k, drilling with -5 - 8.6k Dn wt on CT, weight transfer is getting worse, lithology 40 percent chert, 1 percent pyrite, rest sand 12:15 - 15:15 3.00 DRILL P PROD1 POH to BHA, 5 - 10k overpulls at 10748', 10721', 10710', Std bk Injector, brk out CTC 15:15 - 15:30 0.25 DRILL P PROD1 POH with Drlg BHA #4, LD Bit, Bit grade 5/3/I, inspect .8 degree motor 15:30 - 15:55 0.42 DRILL P PROD1 M/U lateral BHA #5 with BHI LOC, P&C, EDC, DPS, DGS, USMPR, HOT, Agitator, FVS, 0.8deg X-treme motor & new Hughes 2.7" x 3" DOSTRW D bicenter bit #4. Scribe tools 15:55 - 16:30 0.58 DRILL P PROD1 Surface test Baker tools, OK, MU UOC, stab injector 16:30 - 16:45 0.25 DRILL P PROD1 Shallow hole test Baker tools, OK 16:45 - 17:00 0.25 DRILL P PROD1 RIH straightening CT to 500', POH with 100', inspect straightened CT, Looks good 17:00 - 18:40 1.67 DRILL P PROD1 RIH straightening CT to 9000', note always disengaging straightener before crossing a welded section of CT 18:40 - 19:00 0.33 DRILL P PROD1 Continue RIH freely from 9000' to 10471'. 19:00 - 19:25 0.42 DRILL P PROD1 Log down GR ~ 120fph & tie into formation marker. Correct BHI depth by 13' & CTDS depth by +2'. 19:25 - 19:50 0.42 DRILL P PROD1 Close up EDC &RIH to btm. Set down in shale from 10870' to 10920'. Drop pump, set down & poke thru shale. Cont RIH to btm tagged ~ 11740'. 19:50 - 22:15 2.42 DRILL P PRODi Drill to 11897' with 50-80L TF, 1.7/1.7bpm, 3400/3550psi, 9.61 ppg ECD, -7k to -2k CT wt, 17.5k to 12.5k SWOB, 0.5k to 1 k DWOB & 135-45fph ave ROP. Up wt = 32k. Run-in wt = 10.5k. PVT = 307bb1s. IAP = 160psi. OAP = Opsi. Freespin = 1.6bpm/3500psi. 22:15 - 00:00 1.75 DRILL P PROD1 Wiper trip to window. Pulled thru shale interval with +/-8k O/Pull. Set down in shale from 10840' to 10920' while RBIH to btm. Drop pump, set down & run past shale intervals. 5/5/2007 00:00 - 00:20 0.33 DRILL P PROD1 Cont RIH to btm. 00:20 - 01:30 1.17 DRILL P PROD1 Drill to 11935' with 70L TF, 1.7/1.7bpm, 3400/3650psi, 9.73ppg ECD, -6k to -3k CT wt, 16.5k to 13.5k SWOB, 1 k DWOB & 35fph ave ROP. 01:30 - 01:45 0.25 DRILL P PROD1 Short BHA wiper. 01:45 - 03:30 1.75 DRILL P PROD1 Drill to 12065' with 45-70L TF, 1.6/1.6bpm, 3200/3400psi, 9.74ppg ECD, -5k to +4k CT wt, 15.5k to 6.5k SWOB, 1k DWOB & 85fph ave ROP. 03:30 - 05:15 1.75 DRILL P PROD1 W iper trip to window. Pulled thru shale interval with +/-8k O/Pull. Only saw minor wt bobbles across shale intervals while RBIH to btm. 05:15 - 06:15 1.00 DRILL P PROD1 Drill to 12092' with 125R TF, 1.65/1.65bpm, 3200/3450psi, 9.74ppg ECD, -5k CT wt, 15.5k SWOB, 1 k DWOB & 65fph ave ROP. 06:15 - 06:25 0.17 DRILL P PROD1 BHA wiper trip 06:25 - 10:05 3.67 DRILL P PROD1 Drill to 12240' with 153 - 178R TF, 1.63/1.70bpm, Printed: 5/14/2007 10:50:45 AM • BP EXPLORATION Operations Summary Report Page 6 of 14 Legal Well Name: D-30 Common Well Name: D-30 Spud Date: 12/20/2002 Event Name: REENTER+COMPLETE Start: 4/27/2007 End: 5/12/2007 Contractor Name: NORDIC CALISTA Rig Release: 5/12/2007 Rig Name: NORDIC 1 Rig Number: N1 Date From - To ; Hours Task ~ Code NPT Phase ! Description of Operations I 5/5/2007 06:25 - 10:05 ~ 3.67 ~ DRILL ~ P PROD1 ~ 3658/3680psi 9.75ppg ECD 2-4k CT wt, 1.1 k DWOB & 25 - 10:05 - 11:50 I 1.751 DRILL I P I I PRODi 11:50 - 12:30 I 0.671 DRILL I P I I PRODi 12:30 - 13:00 I 0.501 DRILL I P I I PROD1 13:00 - 18:00 I 5.001 DRILL I P I I PRODi 18:00 - 20:45 I 2.751 DRILL I P I I PRODi 20:45 - 21:40 I 0.921 DRILL I P I I PROD1 21:40 - 23:00 I 1.331 DRILL I P I I PROD1 23:00 - 23:15 I 0.251 DRILL I N I DFAL I PROD1 23:15 - 00:00 0.75 DRILL N DFAL PROD1 5/6/2007 00:00 - 02:00 2.00 DRILL N DFAL PROD1 02:00 - 02:15 0.25 DRILL N DFAL PROD1 02:15 - 03:00 0.75 DRILL N DFAL PRODi 03:00 - 03:15 0.25 BOPSUf~ N DFAL PROD1 03:15 - 04:15 1.00 DRILL N DFAL PROD1 04:15 - 06:00 1.75 DRILL N DFAL PROD1 06:00 - 06:20 0.33 DRILL N DFAL PROD1 06:20 - 06:40 0.33 DRILL N DFAL PROD1 06:40 - 07:25 I 0.751 DRILL I N I DFAL I PROD1 75fph ave ROP. PVT 290bb1s, Up wt 32k, Dn wt 10k, hole taking at 3bph Wiper trip to 9700', 5-10k O/pulls @ 10960' & 10933' and 10811'. Had +/-5k O/pull across shale interval from 10900' to 10800'. Up Wt from btm 31 k RIH to 10475', Tie in pass with RA marker to 10530', correct BHI and CT +12' RIH to btm, Dn wt 14.5k, slight bobbles at 10700 -10710', tight and ratty thru interval from 10840' to 10920' with pumps shut down, TF 60 R, bring pumps online at 10930', .45bpm, 1250 psi, increased rate at 11350' to .86bpm,1832psi, Dn wt 12k at 62fpm Drill to 12412' with 175R-148L TF, FS 3234psi at 1.51 bpm, 1.51/1.61 bpm, 3458/3480psi, 9.83ppg ECD, 2-10k CT wt, .58 - 1.5k DWOB & 30 -40fph ave ROP. Dn wt 10k, PVT 268bb1s, hole taking at 3bph, Up wt off btm 29k at 24fph Wiper trip to window. Pulled thru shale interval with 5-10k O/Pull. RBIH & set down @ 10708'. Set to as drilled TF of 90R & wash thru shale interval @ 0.5bpm. Continue RIH clean to btm. Drill to 12440' with LS TF, 1.7/1.7bpm, 3750/3900psi, 9.79ppg ECD, -5k CT wt, 15.5k SWOB, 1k DWOB & 30fph ave ROP. Orienter acting up. Drill to 12495' with 90R TF, 1.7/1.7bpm, 3750/3900psi, 9.91 ppg ECD, -5k CT wt, 15.5k SWOB, 1k DWOB & 60fph ave ROP. Stall & observe CT pressure lock up -suspect plug off somewhere in the BHA. Inner pressure from DPS = 3900psi & Annular pressure = 4250psi. Bleed off CTP & pump up again -BHA still plugged. Open up EDC &BHI lose communication with downhole tools. Review situation with Asset -want to POOH, change out BHA & continue drilling. POOH to check drilling BHA. Continue POOH with drilling BHA. PJSM & THA for changing out BHAs. OOH. P/U injector & inspect CT for flat spots - OK. S/B injector. Inspect & P/test CTC - OK. Inspect BHA & blow thru with air -found nothing plugged but will changeout all components. Blow air thru agitator -was not vibrating OK. UD BHA#5. Bit grade 8/2/1 with no plugged nozzle. Conduct weekly BOP function test -observe dead annular BOP indicator bulb on BOP control panel ~ driller's console. M/U lateral BHA #6 with BHI UOC, LOC, P&C, EDC, DPS, DGS, USMPR, HOT, Agitator, FVS, 0.8deg X-treme motor & used Hycalog 2.7" x 3" SRX3408M bicenter bit #5. Scribe tools & M/U injector. RIH lateral BHA#6 straightening CT to 9000' & disengaging straightener across butt welded sections of CT. Continue RIH freely from 9000' to 10470'. Log down GR @ 110fph & tie into formation marker. Correct BHI depth by 15' while CTDS was on depth. RIH to btm with minor wt bobbles across shales. Printed: 5/14/2007 10:50:45 AM BP EXPLORATION Page 7 of 14 ~ Operations Summary Report Legal Well Name: D-30 Common Well Name: D-30 Spud Date: 12/20/2002 Event Name: REENTER+COMPLETE Start: 4/27/2007 End: 5/12/2007 Contractor Name: NORDIC CALISTA Rig Release: 5/12/2007 Rig Name: NORDIC 1 Rig Number: N1 ~ ; ~ Date From - To ! Hours i Task Code; NPT Phase Description of Operations -- _ - = --- ~_____j _ -- 5/6/2007 07:25 - 13:00 5.58 DRILL P PROD1 Drill to 12662' with 78-105R TF, 1.55/1.58bpm, 3955/3955psi, 9.95ppg ECD, -3 to -9k CT wt, stacking wt, difficulty transfer wt, 8k SWOB, 1.49k DWOB & 30-60fph ave ROP, PVT 301 bbls, losing 3 bph to hole 13:00 - 13:40 0.67 DRILL P PROD1 13:40 - 14:15 0.58 DRILL P PROD1 14:15 - 16:45 2.50 DRILL P PROD1 16:45 - 17:00 0.25 DRILL P PROD1 17:00 - 17:30 0.50 DRILL P PROD1 17:30 - 18:15 0.75 DRILL P PROD1 18:15 - 21:00 2.75 DRILL P PROD1 21:00 - 21:15 0.25 DRILL P PROD1 21:15 - 22:00 0.75 DRILL P PROD1 22:00 - 22:30 0.50 CASE P RUNPRD 22:30 - 23:00 0.50 CASE P RUNPRD 23:00 - 00:00 1.00 CASE P RUNPRD 5/7/2007 00:00 - 04:45 4.75 CASE P RUNPRD 04:45 - 05:45 1.00 CASE P RUNPRD Troubleshoot Baker tools found short in HOT and wet connect (o-ring)failed Short wiper trip to 12000', no hole problems Drill to 12670' with 105 - 99R TF, 1.55/1.60bpm, 3760/3775psi, 9.95ppg ECD, -8 to -9k CT wt, stacking wt, difficulty transfer wt, 8k SWOB, 1.4k DWOB & 15 - 30fph ave ROP Geologist call TD at 12670'' Madd Pass from TD to RA marker at 10510', 900fph, TF 60-70R, 27k and 21k overpulls at 10876' and 10862' Tie-in pass fro 10510' to 10539', +10' correction for BHI, +.5' correction for SLB RIH with TF 65 - 90R, Dn wt 14k, Up wt at 30.7k, set down at 10711', worked through tight hole with 91 R TF, 1.15bpm, continued RIH with pumps at .52bpm, set down and worked through tight and ratty hole with pumps down f/ 10809 to 10900', individual tight spots at 10809', 10861, 10877', 10885',10903' with down drag of 8 - 16k before working through them. RIH from 10903' to btm at 12670' with Dn wt 12.8 - 9.5k, pumping 9.2ppg flo pro mud down CT at 1.4bpm, 3050psi, down drag of 5 - 6 k at 12111' and 12200', 9.2ppg mud rounded corner after 37 bbls pumped, pumped 50bbls before starting POH POH, laying in new 9.2 ppg Flo-Pro mud at 1.60bpm, 3585psi, Up Wt 30k, 53fph, 3-4k overpulls at 12145' and 12140', ratty hole from 10935 ' to 10874' with 2-3k overpulls, paint EOP flag at 9980' and 7804' PJSM & THA for UD BHA. OOH. P/U injector & inspect CT for flat spots - OK. S/B injector. Inspect & P/test CTC - OK. B/D BHA. UD BHA#6. Bit grade 3/3/I. Blow air thru agitator -was vibrating OK (will run liner with agitator). Bring in Baker tools & R/U for running completion liner. Held PJSM on M/U &RIH with liner. M/U 2-3/8" STL rotating guide shoe, 1 float collar, 1 shoe jt, 1 float collar & landing collar. M/U & drift first 5jts of 2-3/8" STL 4.7# L-80 liner with Baker 1.89" x 12" drift. 5th jt did not drift very well. UO 5th jt & observe damaged pin -must have been damaged from Stores. Replace bad jt. Decide to drift all other 2-3/8" Inr jts to eliminate any doubt. Continue M/U & drifting 54jts of 2-3/8" STL 4.7# L-80, 2-3/8" pup & 25jts of 2-3/8" STL 4.7# L-80 liner. Conduct valve drill while M/U Inr. M/U XO, Baker Deployment sleeve & GS Spear. M/U FVS, Agitator, DPS, EDC, P&C, LOC, & UOC. M/U injector. OA BHA length - 2772.57'. Printed: 5/14/2007 10:50:45 AM BP EXPLORATION Page 8 of 14 Operations Summary Report Legal Well Name: D-30 Common Well Name: D-30 Spud Date: 12/20/2002 Event Name: REENTER+COMPLETE Start: 4/27/2007 End: 5/12/2007 Contractor Name: NORDIC CALISTA Rig Release: 5/12/2007 Rig Name: NORDIC 1 Rig Number: N1 Date From - To Hours j Task ~ Code NPT ~ Phase 05:45 - 09:35 3.83~~ CASE ~ P ~ RUNPRD Description of Operations 5/7/2007 5/8/2007 RIH with liner assy on a-coil to btm at 12670', Up Wt 21 k, Dn wt 14k at 10496', corrected depth to upper flag with -24 correction, continue RIH, ratty hole from 10810 ' to 10900' with intermittent do drag of 3 - 5k, .51 bpm, 1450psi, RIH worked thru tight spots and intervals, occasionally setting down, at 11950', 11998', 12067', 12120', 12142', 12215, 12259', 12275', 12301', 12390' to 12448', 12461', 12473', 12530', 12646', Up wt on btm with liner without pumps 40k, Dn wt 6k Guide Shoe 12670', bottom Float Collar 12667', upper Float Collar 12634', Landing Collar 12633' Note: Baker downhole tools quit working at 11500' shoe depth 09:35 - 10:00 0.42 CASE P RUNPRD Circ 5 OH volumes at 1.4bpm, 3578psi 10:00 - 11:50 1.83 CASE P RUNPRD Shut down pumps, bled of CT pressure, confirmed Btm, Pump down CT, PU and release from deployment sleeve w/ Up wt of 25k, POH to liner running BHA, brk out injector and UOC, Installed lower quick blind and nozzle, std bk injector 11:50 - 12:05 0.25 CASE P RUNPRD Blow down BHA with air, POH, LD BHA LOC, wear sub, powercomms, EDC, DPS, blind x-o, agitator, FVS, x-o, GS spear 12:05 - 12:40 0.58 CASE P RUNPRD RU N2 unit, stab inj, PJSM on pickling 2" CT and N2 blow down operations, mixing 15bbls A261 inhibitor in pill pit 12:40 - 14:00 1.33 CASE P RUNPRD Pump 10bbls bleach, 40bbls FW, 15bbls A261 inhibitor, 6bbls McOH, lined up N2 returns to tiger tank, bkr circ thru 2" kill line, Test lines, Blow down E-Coil with N2, RD N2 unit while CT is bled down 14:00 - 14:30 0.50 CASE P RUNPRD PJSM with change out crew, reviewed operations on N2 job 14:30 - 17:00 2.50 CASE P RUNPRD Std Bk injector, Cut off CTC, secure end of a-line cable w/ rubber boot, install internal CTC, pull test. Spool back pipe, secure to reel 17:00 - 18:30 1.50 CASE P RUNPRD Swap out 2" a-coil with 2" a-free coil. 18:30 - 19:30 1.00 CASE P RUNPRD M/U hardline to reel. Slip grapple connector into CT & pull test. 19:30 - 19:45 0.25 CASE P RUNPRD PJSM & THA for stabbing CT into the injector. 19:45 - 20:00 0.25 CASE P RUNPRD Pull CT across pipeshed & stab CT thru injector. 20:00 - 20:45 0.75 CASE P RUNPRD M/U Baker CTC. Pull test to 35k - OK. 20:45 - 22:30 1.75 CASE P RUNPRD Install dart catcher. Pump 2bbls of McOH spacer ahead followed with 3bbls of water. Load & launch wiper dart. Chase dart with mud & pig CT. Did not observe dart bump after pumping 47bbls. S/D pump & reload/pump dart. Dart bump on catcher ~ 41.2bbls. P/test CTC, hardline to reel & inner reel valve to 4000psi _ OK. 22:30 - 22:45 0.25 CASE P RUNPRD PJSM for M/U &RIH with Baker LWP &CTLRT. 22:45 - 00:00 1.25 CASE P RUNPRD M/U Baker LWP, CTLRT with Hyd disconnect, swivel, XO, & 1 jt of 2-1/16" CSH tbg, OAL - 50.07'. M/U injector. Conduct valve drill while M/U BHA. 00:00 - 02:45 2.75 CASE P RUNPRD RIH with CTLRT BHA circ @ min rate. Wt check C~ 8500': Up = 26k. Run-in wt = 14k. Continue RIH smoothly & tag TOL ~ 9938'. Set down 10k down ~ 9946' & latch CTLRT into deployment sleeve. P/U @ 35k & confirm engagement. 02:45 - 03:45 1.00 CASE P RUNPRD Establish circ. PUH to ball drop position. Load 5/8" steel ball & circ with mud C~ 1.29/1.26bpm & 2200psi. Set down 10k down Printed: 5/74/2007 10:50:45 AM ~ ~ BP EXPLORATION Operations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date I From - To 5/8/2007 102:45 - 03:45 D-30 D-30 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Start: 4/27/2007 Rig Release: 5/12/2007 Rig Number: N1 Hours Task ;Code NPT Phase 1.00 CASE P IRUNPRD 03:45 - 06:00 2.25 CASE P RUNPRD 06:00 - 07:30 1.50 CEMT P RUNPRD 07:30 - 07:55 0.42 CEMT P RUNPRD 07:55 - 09:40 1.75 CEMT P RUNPRD 09:40 - 11:30 1.83 CEMT P RUNPRD 11:30 - 12:15 0.75 CEMT P RUNPRD 12:15 - 12:45 0.50 CEMT P RUNPRD 12:45 - 13:00 0.25 CEMT P RUNPRD 13:00 - 14:30 1.50 CEMT P RUNPRD 14:30 - 15:00 0.50 CEMT P RUNPRD 15:00 - 19:00 4.00 CEMT P RUNPRD 19:00 - 20:30 ~ 1.50 ~ CEMT ~ P ~ ~ RUNPRD 20:30 - 21:45 I 1.251 CEMT I P I IRUNPRD 21:45 - 23:30 I 1.751 CEMT I N I CEMT IRUNPRD Page 9 of 14 Spud Date: 12/20/2002 End: 5/12/2007 Description of Operations on CTLRT. Slow down pumps to 0.64/0.59bpm & 1240psi ~ 28bbls away. Ball on seat ~ 34.4bbls. Pressure up to 3700psi & release CTLRT. P/U ~ 25k & confirm release. Set back 10k down on CTLRT. Line up to pump via the cementing high-pressure line. Circ well to 2% KCL water with double friction reducer ~ 1.64/1.51 bpm & 1400psi. Send used FloPro to MI for reconditioning. Meanwhile R/U SLB cementers. Filling pits with double slick 2% KCL, 330 bbls, mixing 30 bbl biozan pill, while circ KCL around, total of 407bb1s PJSM on cementing operations with all involved personnel, Continue circulating 2% KCL @ 1.64/1.51bpm & 1400psi. Batch mix 17bbls 15.8ppg 'G' latex cmt with additives. Cmt to wt at 08:15hrs. Flush/PT lines to 4k. Pump 14.3bbls cmt slurry at 1.46/1.36bpm & 2300psi. Close inner reel valve & clean lines. Load/launch CTWP with 500psi. Zero MM in and out total. Chase with 30bbls bio-KCL at 1.88/1.62bpm and 3550 - 2900psi. Slow down pumps to 1.56/1.OObpm & 1775 - 3000psi C~ 33bbls. CTW P engage LW P at 41.4bbls away. Shear plug with 4100psi, fell back to 3750psi, then increased to 4250psi, reduced pump rate to .95bpm with 4358psi, continue displacing LW P, reduced pump rate to .37/.25bpm, 4171 - 4350psi at 46bbls pumped, at 48.5bbls pumped .30/.20bpm, 4400psi, at 49.5bbls pumped, .22/.09bpm, 4490psi, at 51.Obbls away, pump pressure at 4660psi, micro motion fluctuated to a quick 53bbls pumped, shut down pumps, pressure holding, did not see plug bump, bleed off, check floats -held. Pressure up to 850psi, sting out of liner, PU wt 25k, CIP ~ 09:32hrs. POH to CTLRT BHA POH, LD CTLRT BHA, offload from rig floor down beaver slide RU handling tools for running 1"CSH. PJSM on P/U &RIH cleanout BHA & 1" CHS tbg. M/U cleanout BHA #9 with 1.875" mill, 1-11/16" motor, lower MHA, XO & 1"CSH tbg. Little jerk dies not suitable for 1"CSH so call for Baker crummies. Conduct a rig evacuation & H2S drill. Continue M/U 46 stands of 1"CSH tbg, XO & upper MHA. M/U injector. Observe lots of scale from 1"CSH. Beat on 1"CSH & break circ ~ intervals to flushout scales. RIH with cleanout BHA #9. Circ 6 bbls at surface with no problem. SWS cement UCA sample at 520 psi at 2000 hrs. RIH clean thru top of liner at 9936'. Circ. at 1.1 bpm, 2500 psi, full returns. RIH at 45 fpm. Sat down at 11,948'. 685' above PBTD. 2-3/8" liner capacity = 2.65 bbls. Mill cement or LW P, 1.1 bpm, 2500-2700 psi, Circ Biozan pill. Liner was drifted with 1.89" drift after each connection make-up. Mill in hole is 1.875" OD. Mill down to 11,949.2' and stall Printed: 5/14/2007 10:50:45 AM ~ ~ BP EXPLORATION Page 10 of 14 Operations Summary Report Legal Well Common W Event Nam Contractor Rig Name: Date ~ Name: ell Name: e: Name: From - To ~; __ ~ D-30 D-30 REENTE NORDIC NORDIC Hours 1 R+COM CALIS 1 Task PLET TA Code ! -- E NPT 5!8/2007 21:45 - 23:30 1.75 CEMT N CEMT 23:30 - 00:00 0.50 CEMT N CEMT 5/9/2007 00:00 - 00:30 0.50 CLEAN N CEMT 00:30 - 02:30 2.00 CLEAN N CEMT 02:30 - 02:45 0.25 CLEAN N CEMT 02:45 - 04:45 2.00 CLEAN N CEMT 04:45 - 06:00 1.25 CLEAN N CEMT 06:00 - 06:15 0.25 CLEAN N CEMT 06:15 - 07:30 1.25 CLEAN N CEMT 07:30 - 09:30 2.00 CLEAN N CEMT 09:30 - 10:00 0.50 CLEAN N CEMT 10:00 - 10:50 0.83 CLEAN N CEMT 10:50 - 11:45 0.92 CLEAN N CEMT 11:45 - 13:00 1.25 CLEAN N CEMT 13:00 - 16:15 3.25 CLEAN N CEMT 16:15 - 16:30 0.25 CLEAN N CEMT Spud Date: 12/20/2002 Start: 4/27/2007 End: 5/12/2007 Rig Release: 5/12/2007 Rig Number: N1 Phase Description of Operations RUNPRD motor. Pick up 30' clean. RIH. Time Mill to 11950'. No more stalls. Pick up clean , 25.5K up wt. RUNPRD Mill on LWP. 1.1 bpm, 2100-2300 psi, full returns. No progress past 11,951'. Stacking wt with very little motor work. LW P and or Peewee dart may be spinning freely with mill, so very little motor work. RUNPRD Mill on LWP, 1.1 bpm, 2100-2400 psi, full returns. Stacking wt with little motor work. Spud several times. Not getting motor work. No further progress. No cement, rubber or metal seen on shaker. LW P may be spinning with mill. RUNPRD POH to check mill and motor. RUNPRD SAFETY MEETING. Review procedure, ha2ards and mitigation for standing back CSH workstring. RUNPRD Drop 1/2" ball and open circ sub. Stand back 46 stds of 1" CSH workstring. RUNPRD Recover mill and motor. Found 6" of Peewee dart rod stuck in center of mill. Bottom of rod was flush with face of mill and worn very smooth from spinning on it. Mill and motor OK. M/U new Mill and Motor and new circ sub. The rest of BHA is the same as BHA #9. RUNPRD PJSM on P/U &RIH cleanout BHA & 1" CHS tbg. RUNPRD M/U cleanout BHA #10 with new 1.875" mill, new 1-11/16" extreme motor, lower MHA, XO, 46 stands of 1" CSH tbg, XO & upper MHA. M/U injector. RUNPRD RIH with cleanout BHA #10 to 9900'. Wt check ~ 9900': Up = 30k. Run-in wt = 15k. Continue RIH. Wt check ~ 11900': Up = 31 k. Run-in wt = 14k. Smoothly tag TOLW P ~ 11960.98'. Establish freespin @ 0.95bpm/1970psi. RUNPRD Start milling LWP with 0.95/0.95bpm, 1970/2150psi, 1-2k WOB. Stall ~ 11961'. P/U with 10k O/pull & broke free. Re-establish freespin @ 1.1bpm/2300psi. RUNPRD Ease back into milling from 11960' with 1.11/1.11bpm, 2300/2500psi, 1k WOB. Spin on LWP for 15mins. PUH 10'. Re-establish freespin ~ 1.11 bpm/2430psi. RBIH, set down 2k & attempt to grind on LWP. Stall ~ 11961. P/U & drag up some debris along with the mill. Work the string from 11915' to 11950' & surge the CTP several times. Finally manage to shake string free. RUNPRD Circ 10bbls of bio-pill around. Not getting any AL, rubber or cement in btms up samples. RUNPRD Ease back into milling from 11959' with 1.11/1.11bpm, 2300/2400psi, 1.5k WOB. Pumping 2bbls bio-sweeps every 50bbls of fluid pumped. Mill down to 11961.6'. Stacking wt. P/U clean. Re-establish freespin @ 1.03bpm/2400psi. RUNPRD Stack wt & mill to 11978' with 1.03/1.03bpm, 2400/2650psi, -5k CT wt & 15.5k SWOB. P/U clean & Wt check: Up = 27.5k. Run-in wt = 8.5k. Adding 0.6% safe-tube to fluid system. RUNPRD Stack wt & mill to 11980' with 1.03/1.03bpm, 2400/2650psi, -5k CT wt & 15.5k SWOB. Motor about to stall. P/U & get bit stuck at 11,965'. 15' off Printed: 5/14/2007 10:50:45 AM • BP EXPLORATION Page 11 of 14 Operations Summary Report Legal Well Name: Common Well Name Event Name: .Contractor Name: Rig Name: D-30 D-30 REENTER+COMPLET NORDIC CALISTA NORDIC 1 Date From - To Hours Task ~ Code 15/9/2007 16:15 - 16:30 0.25 CLEAN N ~, 16:30 - 18:30 2.00 CLEAN N 18:30 - 21:30 21:30 - 00:00 15/10/2007 100:00 - 00:30 00:30 - 00:45 00:45 - 02:30 02:30 - 05:00 05:00 - 06:00 06:00 - 08:30 08:30 - 08:45 08:45 - 09:45 09:45 - 11:45 11:45 - 12:45 12:45 - 14:45 3.001 CLEAN I N 2.50 CLEAN N 0.50 CLEAN N 0.25 CLEAN N 1.75 CLEAN N 2.50 CLEAN N 1.00 CLEAN N 2.50 CLEAN N 0.25 CLEAN N 1.00 CLEAN N 2.00 CLEAN N 1.00 CLEAN N 2.00 CLEAN N Spud Date: 12/20/2002 Start: 4/27/2007 End: 5/12/2007 Rig Release: 5/12/2007 Rig Number: N1 NPT Phase ; Description of Operations CEMT RUNPRD bottom. STUC RUNPRD Work the string up to 65k & surge the pipe several times via the CT & annulus without luck. Finally getting some circ ~ 0.3bpm/4500psi. Circ down 0.6% safe-tube fluid to the mill &circ ~ 0.56bpm/4100psi. STUC RUNPRD Circ Safe-Cube 10 bbl out mill and pull to 64K without and with pump. Circ. 0.5 bpm at 4100 psi. Close choke, press well to 2000 psi, pull to 64K, open choke. Repeat. Stack full wt. Circ 10 bbl Biozan pill. Circ. 1.1 bpm at 4300 psi while high vis sweep going out mill. Work coil. Surge well. Pull 64K. No luck. Order 5 bbls, 15% HCL acid from SWS to treat 4# of AL in LW P. STUC RUNPRD Circ 10 bbl high vis Biozan around at 0.8 bpm, 4100 psi, Stacking full wt on coil. Work coil. Surge well to 2500 psi and pull to 64K, 2 times. No luck. Circ. with 62K up wt. while rig up SWS acid pumping equipment. STUC RUNPRD Work pipe max up /down wt. Circ at 0.8 bpm. Still bit stuck from AL, rubber or cement in hole from milling operation. Rig up SWS acid pumping equipment. Did rig spill drill. STUC RUNPRD SAFETY MEETING. Review procedure, hazards and mitigation for pumping 15%HCL acid. STUC RUNPRD Pump 5 bbls rig water. Press test lines to 4500 psi. Pump 5 bbls rig water. Stage 7 bbl, 15% HCL Acid with inhibitor. 0.8 bpm, 3000 psi. Stage 20 bbl rig water. 0.8 bpm, 2900 psi. Shut down SWS pump. Clear line. Displace with KCL water with rig pump. Spot 2 bbls acid out mill. Soak. STUC RUNPRD Soak acid 1/2 hour. Pump 1 bbl. soak acid 1/2 hr. Stack wt, pull to 62K. Performed rig fire drill. Pump 1/2 bbl, Work pipe up/down. Pump 1/2 bbl. Work pipe. -8K down wt to 64K up wt. No progress. Pump 1/2 bbl every 1/2 hour. Work pipe. 6 bbls out at 0500 hrs. STUC RUNPRD Work pipe. Pump 1/2 bbl every 1/2 hour. Pull to 64K, set down to -8K. No moverment. Surge well white pulling 64K. 3 times. No luck. Coil capacity = 41.4 bbls. CSH capacity = 1.8 bbls. Total = 43.2 bbl. STUC RUNPRD Circ out spent acid to the tiger tank ~ 1.02bpm/3400psi. STUC RUNPRD PJSM & THA for pumping crude. Conduct Reid vapor pressure test on crude sample - 0.2psi ~ 60F. STUC RUNPRD Pump down 50bbls of crude ~ 1.2bpm/3860psi. Circ crude out of the mill & pull 60k on stuck string. STUC RUNPRD With crude on the backside, work pipe from 11961' to 11933' between -8k & 65k without luck. STUC RUNPRD Circ out crude to the tiger tank ~ 1.02bpm/2740psi. STUC RUNPRD E Set string to 11 k C~3 11956'. Load/launch 5/8" phenolic ball & Printed: 5/14/2007 10:50:45 AM ~ i BP EXPLORATION Page 12 of 14 ~ Operations Summary Report Legal Well Name: D-30 Common Well Name: D-30 Spud Date: 12/20/2002 Event Name: REENTER+COMPLETE Start: 4/27/2007 End: 5/12/2007 Contractor Name: NORDIC CALISTA Rig Release: 5/12/2007 Rig Name: NORDIC 1 Rig Number: N1 Date From - To~ Hours i Task ~ Code NPT Phase Description of Operations 5/10/2007 12:45 - 14:45 2.00 CLEAN N STUC RUNPRD chase with 30bbls of bio-KCL @ 1.11/1.11 bpm & 3850psi. Slow down pumps to 0.64/0.64bpm & 1400psi @ 30bbls away. Ball on seat ~ 41.9bbls. Pressure up to 3200psi & disconnect BHA. P/U @ 26k & confirm disconnect. 14:45 - 15:00 0.25 CLEAN N STUC RUNPRD Sweep hole with 30bbls of bio-KCL ~ 1 bpm/4000psi. 15:00 - 18:30 3.50 CLEAN N STUC RUNPRD POOH with disconnected cleanout BHA swapping well to new 2% KCL water. 18:30 - 19:30 1.00 CLEAN N STUC RUNPRD Lay out SWS BHA. Freeze protect line to tiger tank. 19:30 - 19:45 0.25 CLEAN N STUC RUNPRD SAFETY MEETING. Review procedure, hazards and mitigation for standing back 1" CSH workstring. 19:45 - 21:45 2.00 CLEAN N STUC RUNPRD Stand back 46 stds of 1"CSH. Recover upper half of BOT Hyd Disconnect. 3 of the intemal dogs were broken off and missing, most likely left inside the lower half of disconnect. [ 8 internal dogs, each 4" long, 1/4" wide, 1/8" thick ]. 21:45 - 22:00 0.25 EVAL P LOWERI SAFETY MEETING. Review procedure, hazards and mitigation for M/U SWS MCNUGR logging tools and RIH with CSH workstring. 22:00 - 00:00 2.00 EVAL P LOWERI M/U BHA #11, SWS MCNUGR/CCL Logging tools with BOT Hyd Disc, 35 stds of CSH, SWS MHA and CTC. OAL = 2,165'. 5/11/2007 00:00 - 02:15 2.25 EVAL P LOWERI RIH with BHA #11, MCNUGR logging BHA on 1"CSH. Circ. at 0.3 bpm, 40 psi. 02:15 - 04:00 1.75 EVAL P LOW ER1 Log down from 9700' at 30 fpm. Circ. at 0.7 bpm, 780 psi. Tag bottom at 11,948'. Log up at 60 fpm while laying in new FloPro pert pill. 04:00 - 05:00 1.00 EVAL P LOW ER1 POH while circ at 1.8 bpm. 05:00 - 06:30 1.50 EVAL P LOW ER1 PJSM for standing back CSH workstring. Stand back 35 stands of 1"CSH. 06:30 - 06:45 0.25 EVAL P LOWERI PJSM for UD SWS MCNUCCUGR logging tool. 06:45 - 07:30 0.75 EVAL P LOWERI UD lower MHA, XO &SWS MCNUCCUGR logging tool. Check log data quality - OK. From log data, PBTD = 11949' & TOL = 9940'. 07:30 - 07:45 0.25 EVAL P LOW ER1 Line up to P/test liner lap. Observe faulty pressure transducer to Nordic chart recorder. 07:45 - 08:15 0.50 EVAL N SFAL LOW ERi Fix pressure transducer to Nordic chart recorder. 08:15 - 08:45 0.50 EVAL P LOW ER1 Line up & P/test wellbore via the CT as follows: Time WHP CTP IAP OAP Onset 0 0 170 0 0 2070 0 182 0 15 2036 0 177 0 30 2025 0 176 0 _> Passed: Leaked 2.2% of test pressure in 30 mins. Will not set LTP. 08:45 - 09:15 0.50 PERFO P LOW ERi Prep rig floor to run guns. R/U safety jt. Drift MHAs with 1/2" ball - OK. 09:15 - 09:30 0.25 PERFO P LOWERI PJSM on perforation job. 09:30 - 10:45 1.25 PERFO P LOWERI M/U 25jts of 1.56" HSD PJ1506 6spf guns & blanks with BCF ' ', firing system. i 10:45 - 12:00 1.25 PERFO P LOWERI t M/U lower disconnect, 26 doubles of 1" CSH tbg & upper MHA. M/U injector. 12:00 - 14:25 2.42 PERFO P LOWERI RIH with perforating BHA#12 circ 5bbls FloPro pert pill ahead ~ min rate. Wt check @ 9900' - Up wt = 28k & Run-in wt = 15.5k. Continue RIH with perforating BHA#12 to 11960'. PUH Printed: 5/14/2007 10:50:45 AM • BP EXPLORATION Page 13 of 14 ~ Operations Summary Report Legal Well Name: D-30 Common Well Name: D-30 Event Name: REENTER+COMPLETE Contractor Name: NORDIC CALISTA .Rig Name: NORDIC 1 Date From - To ~ Hours 'II Task Code NPT I L - __ 5/11/2007 ~ 12:00 - 14:25 ~ 2.421 PERFO~ P 14:25 - 15:00 I 0.581 PERFOBI P 15:00 - 16:00 I 1.001 PERFOBI P 16:00 - 16:15 0.25 PERFOB~ P 16:15 - 17:00 0.75 PERFO P 17:00 - 17:15 0.25 PERFO~ P 17:15 - 17:30 0.25 PERFO P 17:30 - 20:00 2.50 PERFO P 20:00 - 20:15 I 0.251 PERFOBI P 20:15 - 22:30 I 2.251 PERFOBI P 22:30 - 00:00 I 1.501 PERFOBI P 5/12/2007 00:00 - 02:45 2.75 PERFOF~ P 02:45 - 05:45 3.00 WHSUR P 05:45 - 06:00 I 0.251 WHSUR I P 06:00 - 07:15 I 1.251 WHSUR I P Spud Date: 12/20/2002 Start: 4/27/2007 End: 5/12/2007 Rig Release: 5/12/2007 Rig Number: N1 Phase Description of Operations LOWERI clean Q 29k to 11930'. RBIH & tag TOF ~ 11966'. Checked SLB mechanical depth counter gives a depth of 11959'. Review situtaion with ANC & agree to split the difference in depth between the CNL PBTD of 11949' & CTD of 11966'. Thus we'll perforate ~ 11958'. PUH to ball drop position ~ 11956'. Meanwhile R/U SLB sonogram detector to injector for shot detection. LOWERI Load & launch 1/2" AL ball. Position btm shot @ 11958'. Pump 5bbls of pert pill behind & chase ball C~ 1.52bpm/2400psi. Slow to 0.83bpm/880psi ~ 30bbls. Ball on seat after 39.8bbls away. S/D pumps &RBIH to 11965'. PUH, ramp up to 3690psi & observe guns fire with good pressure drop indication & sonogram detection. Perforated interval = 11430' - 11640' & 11760' - 11950'. POOH & check circ pressure @ 0.83bpm had 780psi (previously had 880psi) indicating guns have fired. Continue POOH with pert gun BHA. LOWERI POOH with pert gun BHA ~ 50fpm pumping down the CT ~ 0.83bpm/780psi. Observe Obbl loss/gain while POOH to TOL. LOWERI S/D pump &flowcheck well for 15 mins -well stable. LOWERI POOH with pert gun BHA @ 100fpm pumping down the CT 0.87bpm/600psi. Observe no loss/gain while POOH to surface. LOWERI S/D pump &flowcheck well for 15 mins -well stable. LOWERI S/B injector. R/U for UD 1"CSH. LOWERI UD 52 jts of 1" CSH rental work string to return to Baker fishing. LOWERI SAFETY MEETING. Rrview procedure, hazards and mitigation for laying out fired SWS pert guns and blanks. Checked safety joint for correct XO's. LOW ER1 Lay out fired pert guns. All shots fired. PEFORATEDINTERVALS = 11,430-11,640', 11,760- 11,950'. LOWERI RIH with all stands of 1"CSH in derrick. Lay out rental CSH in singles to return to Baker fishing. LOWERI Lay out 1"CSH rental workstring. POST Jet Stack with swizle stick, RIH and freeze protect 4-1/2" tubing to 2500' with MEOH. POOH. POST SAFETY MEETING. Review procedure, hazards and mitigation for pumping Bleech and inhibitor for storing coil. POST Pump 17bbls bleach, 40bbls fresh water, 15bbls A261 inhibitor, 6bbls McOH to pickle CT. 07:15 - 08:00 0.75 WHSUR N SFAL POST Observe faulty burner in N2 unit. SLB mechanic rectify burner problem. 08:00 - 08:15 0.25 WHSUR P POST PJSM for B/D CT with N2. 08:15 - 08:30 0.25 WHSUR P POST PR N2 lines - OK. 08:30 - 09:15 0.75 WHSUR P POST Blow down CT with N2 & bleed down. Meanwhile cleanout pits & outside tanks. 09:15 - 10:15 1.00 WHSUR P POST P/U injector. Cut-off nozzle. Stab injector back on well. Changeout packoffs & brass. S/B & set injector down on its base. 10:15 - 10:30 0.25 WHSUR P POST PJSM for installing BPV. 10:30 - 11:15 0.75 WHSUR P POST Open up & observe well -stable. R/U DSM dry rod & install BPV in THS. R/D dry rod. SI master & swab valves (23-1/2 Printed: 5/14/2007 10:50:45 AM • BP EXPLORATION Page 14 of 14 ~ Operations Summary Report .Legal Well Name: D-30 Common Well Name: D-30 Spud Date: 12/20/2002 Event Name: REENTER+COMPLETE Start: 4/27/2007 End: 5/12/2007 'Contractor Name: NORDIC CALISTA Rig Release: 5/12/2007 ',Rig Name: NORDIC 1 Rig Number: N1 Date ;From - To ;Hours Task Code ! NPT ~ Phase 5/12/2007 10:30 - 11:15 0.75 WHSUR P 11:15 - 11:30 0.25 WHSUR P 11:30 - 15:30 4.00 WHSUR P Description of Operations POST turns each). POST PJSM for stripping off & pulling back CT to the reel. POST P/U injector & cut off CTC. Prep end of CT for internal grapple. Slip grapple connector into CT, M/U & pull test. Strip-off CT from injector & spool back CT stub to reel. Secure CT with crossbar and chains & prep reel for shipment. Release reel drive bushings. P/U CT reel with bridge crane. Open up Bombay doors & lower CT reel onto Veco trailer. P/U replacement eline 2-3/8" CT reel into reel house with bridge crane & align drive pins & bushing. Meanwhile Nordic changeout BOP ram inserts for 2-3/8" CT, cleanout cuttings box, load out used tubulars, & check Koomey bottle pressures. 15:30 - 16:00 0.50 WHSUR P POST Grease choke manifold valves. Dismantle & inspect choke manifold valve #3. 16:00 -16:15 0.25 WHSUR P POST PJSM for N/D BOPE. Meanwhile Nordic continue cleaning out cuttings box & R/D outside stairs. 16:15 - 18:00 1.75 WHSUR P POST Nipple down BOP. Nipple up & pressure test tree cap. Clean-up cellar. Meanwhile SLB M/U hardline to reel & Nordic continue cleaning out cuttings box & R/D outside stairs. RELEASED RIG AT 1800 HRS, 05/12/2007. TOTAL TIME FROM RIG ACCEPT TO RELEASE WAS 13 DAYS, 20 HOURS. Held PJSM before moving rig off well and before rig move. Moved rig to G-27A at 2100 hrs. All further information will be on DIMS G-27A reports. Printed: 5/14/2007 10:50:45 AM -. • by BP Alaska s Baker Hughes INTEQ Survey Report INTEQ Company: BP Amoco Date: 5/15/2007 Time: 08:30:37 Page: 1 Field: Prudhoe Bay Co-ordinate(NE) Reference: Well: D-30, True North Site: PB D Pad Vertical (TVD) Reference: D-30 RKB 78.2 WeII: D-30 Section (VS) Reference: WeA (O.OON,O.OOE,65.49Azi) Wellpath: D-306 Survey Calculation Method: Minimum Curvature Db: Orade 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 : bggm2006 Site: PB D Pad TR-11-13 UNITED STATES :North Slope Site Position: Northing: 5955590.34 ft Latitude: 70 17 8.492 N From: Map Easttng: 652165.06 ft Longitude: 148 46 6.316 W Position Uncertainty: 0.00 ft North Refereuce: True Ground Level: 0.00 ft Grid Convergence: 1.16 deg Well: D-30 Slot Name: 30 D-30 Well Position: +N/-S 3716.81 ft Northing: 5959346.55 ft Latitude: 70 17 45.044 N +E/-W 1998.28 ft Easting : 654087.58 ft Longitude: 148 45 8.072 W Position Uncertainty: 0.00 ft Wellpath: D-30B Drilled From: D-30A 500292264602 Tie-on Depth: 10486.99 ft Current Datum: D-30 RKB Height 78.25 ft Above System Datum: Mean Sea Level Magnetic Data: 4130/2007 Declination: 23.92 deg Field Strength: 57656 nT Mag Dip Angle: 80.92 deg Vertical Section: Depth From (TVD) +N/-S +E/-W Direction ft ft ft deg 37.65 0.00 0.00 65.49 Survey Program for Definitive Wellpath Date: 10/23/2006 Validated: Yes Version: 5 Actual From To Survey Toolcode Tool Name ft ft 213.76 10450.00 1 : MWD -Standard (213.76-136 MWD MWD -Standard 10486.99 10486.99 MWD (10486.99-11935.00) (1) MWD MWD -Standard 10496.00 12670.00 MWD (10496.00.12670.00) MWD MWD -Standard Annotation MD TVD ft ft 10486.99 9044.67 TIP 10496.00 9043.83 KOP 12670.00 9046.04 TD Survey: MWD Start Date: 5/3/2007 Company: Baker Hughes INTEQ Engineer: Tool: MWD;MWD -Standard Tied-to: From: Definitive Path a66-. ~ y • • by BP Alaska Baker Hughes INTEQ Survey Report uvTEQ Company: BP Amoco Date: 5/15/2007 Time: 08:30:37 Page: 2 Field: Prudhoe Bay Co-ordinate(NE) Reference: Well: D-30, True North Site: PB D Pad Vertical (TVD) Reference: D-30 RKB 78.2 Well: D-30 Section (VS) Reference: Well (O.OON,O.OOE,65.49Azi) Weltpath: D-30B Survey Calculation Method: Minimum Curvature Db: Orade 5urvev MD ft Incl deg Azim deg TVD ft Sys TVD ft N/S ft E/W ft 10486.99 94.89 78.74 9044.67 8966.42 1502.49 4163.66 10496.00 95.85 80.55 9043.83 8965.58 1504.10 4172.49 10521.94 92.86 90.63 9041.85 8963.60 1506.08 4198.24 10544.27 91.20 99.26 9041.06 8962.81 1504.16 4220.45 10564.82 89.02 107.19 9041.02 8962.77 1499.46 4240.44 10590.41 87.05 117.08 9041.90 8963.65 1489.84 4264.10 10627.73 89.29 135.92 9043.10 8964.85 1467.75 4293.94 10660.79 93.78 150.51 9042.21 8963.96 1441.37 4313.68 10689.92 85.88 161.68 9042.30 8964.05 1414.80 4325.46 10728.05 87.48 187.39 9044.54 8966.29 1377.23 4329.04 10753.98 86.07 200.13 9046.01 8967.76 1352.13 4322.90 10784.35 85.12 213.51 9048.35 8970.10 1325.17 4309.27 10813.73 86.68 219.18 9050.45 8972.20 1301.58 4291.91 10843.65 86.01 220.96 9052.36 8974.11 1278.73 4272.69 10875.50 90.55 225.81 9053.32 8975.07 1255.61 4250.83 10906.32 93.25 227.81 9052.30 8974.05 1234.53 4228.38 10937.08 93.93 230.34 9050.37 8972.12 1214.42 4205.19 10968.59 95.60 232.10 9047.75 8969.50 1194.75 4180.71 11001.03 96.43 236.92 9044.35 8966.10 1176.03 4154.45 11034.48 94.09 237.53 9041.29 8963.04 1158.00 4126.45 11067.23 92.61 238.77 9039.37 8961.12 1140.74 4098.68 11108.70 89.51 240.72 9038.60 8960.35 1119.86 4062.87 11140.19 86.38 241.09 9039.73 8961.48 1104.56 4035.37 11171.17 85.46 245.76 9041.94 8963.69 1090.74 4007.74 11201.41 85.82 248.91 9044.24 8965.99 1079.12 3979.92 11233.08 89.66 251.45 9045.49 8967.24 1068.39 3950.16 11266.52 90.83 255.74 9045.34 8967.09 1058.95 3918.09 11297.23 92.92 259.77 9044.34 8966.09 1052.44 3888.10 11339.15 89.57 262.92 9043.43 8965.18 1046.14 3846.68 11368.56 88.86 266.57 9043.83 8965.58 1043.44 3817.40 11402.83 88.56 270.64 9044.60 8966.35 1042.61 3783.16 11431.99 88.10 274.08 9045.45 8967.20 1043.81 3754.04 11459.56 87.79 276.85 9046.44 8968.19 1046.43 3726.61 11491.65 88.19 279.89 9047.57 8969.32 1051.10 3694.89 11521.47 89.60 282.06 9048.14 8969.89 1056.78 3665.62 11549.87 91.69 285.40 9047.82 8969.57 1063.52 3638.04 11578.03 91.72 289.23 9046.98 8968.73 1071.89 3611.18 11609.84 90.64 287.45 9046.33 8968.08 1081.90 3580.99 11640.26 89.54 284.46 9046.28 8968.03 1090.26 3551.74 11672.30 89.02 278.92 9046.68 8968.43 1096.75 3520.38 11710.77 89.39 276.50 9047.22 8968.97 1101.91 3482.27 11740.90 90.37 273.91 9047.28 8969.03 1104.64 3452.27 11776.54 91.01 271.95 9046.85 8968.60 1106.46 3416.68 11800.00 89.42 270.25 9046.76 8968.51 1106.91 3393.22 11830.32 89.02 268.36 9047.18 8968.93 1106.55 3362.91 11860.96 92.12 266.72 9046.87 8968.62 1105.23 3332.30 11887.08 91.38 264.86 9046.07 8967.82 1103.31 3306.27 11921.53 90.43 261.84 9045.53 8967.28 1099.33 3272.06 11950.21 89.97 260.73 9045.43 8967.18 1094.98 3243.71 11985.46 90.00 257.84 9045.44 8967.19 1088.43 3209.08 12015.80 90.71 254.93 9045.25 8967.00 1081.29 3179.59 12038.79 91.84 254.27 9044.74 8966.49 1075.18 3157.44 12067.61 93.76 257.02 9043.48 8965.23 1068.04 3129.55 MapN 111apE ft ft 5960933.97 658219.26 5960935.76 658228.05 5960938.27 658253.75 5960936.80 658276.00 5960932.52 658296.08 5960923.38 658319.93 5960901.91 658350.22 5960875.94 658370.49 5960849.62 658382.80 5960812.13 658387.16 5960786.92 658381.53 5960759.68 658368.46 5960735.74 658351.59 5960712.51 658332.84 5960688.94 658311.47 5960667.41 658289.45 5960646.83 658266.68 5960626.67 658242.61 5960607.41 658216.74 5960588.81 658189.12 5960570.99 658161.71 5960549.38 658126.34 5960533.52 658099.16 5960519.13 658071.82 5960506.95 658044.25 5960495.62 658014.72 5960485.52 657982.85 5960478.40 657953.00 5960471.25 657911.72 5960467.95 657882.51 5960466.42 657848.29 5960467.02 657819.15 5960469.08 657791.68 5960473.10 657759.87 5960478.17 657730.50 5960484.34 657702.79 5960492.17 657675.76 5960501.55 657645.37 5960509.31 657615.97 5960515.15 657584.48 5960519.53 657546.27 5960521.65 657516.22 5960522.74 657480.60 5960522.71 657457.15 5960521.72 657426.85 5960519.78 657396.28 5960517.33 657370.29 5960512.64 657336.17 5960507.71 657307.92 5960500.45 657273.43 5960492.71 657244.10 5960486.15 657222.08 5960478.45 657194.34 VS DIS Tool ft deg/100ft 4411.80 0.00 MWD 4420.50 22.66 MWD 4444.75 40.42 MWD 4464.17 39.33 MWD 4480.41 40.02 MWD 4497.94 39.38 MWD 4515.94 50.81 MWD 4522.95 46.15 MWD 4522.64 46.94 MWD 4510.32 67.44 MWD 4494.32 49.35 MWD 4470.74 44.04 MWD 4445.16 19.97 MWD 4418.19 6.35 MWD 4388.71 20.85 MWD 4359.53 10.90 MWD 4330.09 8.50 MWD 4299.66 7.69 MWD 4268.00 15.00 MWD 4235.04 7.23 MWD 4202.61 5.89 MWD 4161.37 8.83 MWD 4130.00 10.01 MWD 4099.13 15.33 MWD 4069.00 10.45 MWD 4037.47 14.53 MWD 4004.37 13.30 MWD 3974.38 14.78 MWD 3934.08 10.97 MWD 3906.32 12.64 MWD 3874.81 11.91 MWD 3848.82 11.90 MWD 3824.95 10.10 MWD 3798.02 9.55 MWD 3773.75 8.68 MWD 3751.44 13.87 MWD 3730.47 13.60 MWD 3707.16 6.54 MWD 3684.01 10.47 MWD 3658.17 17.37 MWD 3625.63 6.36 MWD 3599.46 9.19 MWD 3567.84 5.78 MWD 3546.68 9.92 MWD 3518.95 6.37 MWD 3490.55 11.45 MWD 3466.07 7.66 MWD 3433.29 9.19 MWD 3405.69 4.19 MWD 3371.46 8.20 MWD 3341.67 9.87 MWD 3318.98 5.69 MWD 3290.64 10.58 MWD i ~ bP BP Alaska s Baker Hughes INTEQ Survey Report uvTE Q Company: BP Amoco Date: 5/15/2007 Time: 08:30:37 Page: 3 Field: Prudhoe Bay Co-ordinate(NE) Reference: Well: D-30, True North Site: PB D Pad Vertical (TVD) Reference: D-30 RKB 78.2 WeII: D-30 Section (VS) Reference: Well (O.OON,O.OOE,65.49Azi) Wellpath: D-30B Survey Calculation Method: Minimum Curvature Db: Oracle Survev MD ft Incl deg Azim deg T<~ ft Sys TVD ft N/S ft E/W ft MapN ft D1apE ft VS ft DLS Tool deg/100ft 12103.62 92.42 259.18 9041.73 8963.48 1060.63 3094.35 5960470.31 657159.31 3255.54 6.33 MWD 12144.50 89.72 261.70 9040.97 8962.72 1053.84 3054.06 5960462.70 657119.16 3216.06 9.03 MWD 12173.30 89.63 263.50 9041.13 8962.88 1050.13 3025.50 5960458.41 657090.69 3188.53 6.26 MWD 12207.79 90.98 266.59 9040.95 8962.70 1047.15 2991.14 5960454.72 657056.40 3156.04 9.78 MWD 12238.57 89.17 268.31 9040.91 8962.66 1045.78 2960.39 5960452.73 657025.69 3127.49 8.11 MWD 12269.92 89.79 270.19 9041.19 8962.94 1045.37 2929.05 5960451.67 656994.37 3098.80 6.31 MWD 12303.25 89.63 274.12 9041.36 8963.11 1046.63 2895.75 5960452.24 656961.05 3069.02 11.80 MWD 12340.62 89.91 276.99 9041.51 8963.26 1050.24 2858.56 5960455.10 656923.80 3036.68 7.72 MWD 12368.50 89.11 278.44 9041.75 8963.50 1053.99 2830.93 5960458.27 656896.10 3013.10 5.94 MWD 12405.17 86.96 280.82 9043.00 8964.75 1060.12 2794.81 5960463.66 656859,86 2982.77 8.74 MWD 12432.25 86.69 284.64 9044.51 8966.26 1066.07 2768.44 5960469.07 656833.38 2961.24 14.12 MWD 12469.54 88.13 286.84 9046.19 8967.94 1076.18 2732.59 5960478.44 656797.33 2932.81 7.05 MWD 12499.78 86.36 288.66 9047.64 8969.39 1085.39 2703.82 5960487.06 656768.38 2910.46 8.39 MWD 12530.85 88.61 291.75 9049.01 8970.76 1096.11 2674.70 5960497.17 656739.05 2888.40 12.29 MWD 12563.53 91.66 294,97 9048.93 8970.68 1109.06 2644.70 5960509.51 656708.80 2866.49 13.57 MWD 12594.28 92.34 299.46 9047.86 8969.61 1123.11 2617.38 5960523.00 656681.19 2847.45 14.76 MWD 12620.63 91.17 303.64 9047.05 8968.80 1136.89 2594.94 5960536.31 656658.48 2832.75 16.47 MWD 12670.00 91.17 303.64 9046.04 8967.79 1164.23 2553.85 5960562.80 656616.84 2806.70 0.00 MWD i ~ ~ ~ 4' C nru WELLHEAD = FMC --- - - . ACTUATOR = _ AXELSON KB. ELEV = 78.29 BF. ELEV = 40.8! 440 P = 1219 Max Angle=9n'..:tC'° i~r, 11n- -- - _ - -- Datum MD = 9738' _- DatumND= - 8800 SS ~~ ~ ~ SAfETYNOiES: HOWZONTAL& SDTRCK WELL FROM CTD/DRLG -DRAFT 2215 4112" HES HXO SSSV NIP, ID= 3,813' GAS LIFT MANDRELS 10-3+4" CSG, 46.5#, L-80, ID = 9,953' 3456' Minimum ID = 1.995" @ 9944' 2~/8" STL LN R BOT DEPLOY SLEEVE T LONG, 3" ID 9936' TOP OF CEMENT ~~' 3-3119' LNR, 8.2#, L-80, .0078 bpf, ID= 2.80' X83' 4102" TBG, 12.6#, L-80, .0152 bpf, ID = 3.958" 9891' TOP OF 4112" LNR 10260' 7-518" CSG, 29.7#, USSS-95, D = 8.875" 10405' TOP OF WHIPSTOCK 10453' RA TAG 10462 4102" WTHFD KS-WS PKR 10464' PBTD 13530' 41lZ" LNR, 12.8#, L-$0, ID= 3.953' 13621' ~ ST MD ND DEU TYPE VLV LATCH PORT DATE 3 3779 3587 25 KB MG- M DOME BK 16 05,31x07 2 7144 8573 26 443MG•M SO BK 20 05031x07 1 9812 8921 59 KB hr1G- M D fufY BK 0 12/14102 89?~-141 F2" H ES X N IP, ID = 3.813" 9833' 7-5P8" X 41F2" BKR S-3 PKR, D = 3.875" 336' (CNL: 9940') TOP OF 2-3 3" LINER J936' 9957' ~TC:F!-,F ~-?~~" LI!dET: !`E!,~ENT 41f2" HES XMIP, ID= 3.813" (BEHIND CTLNRJ 9959' BAKER LNR DEPLOY SLV 9979' 4112" HE5 XN NIP, D =3.725" (B9~IIND CT LNR) X80' ~3-1F2" HE^a XN NIP, D =2.750" 9982" 3.112"X33118'BAKERXO.ID=2.80' 98917 4112" W LEG, ID = 3.958' CNL: 11949' PERFORATION SUMMA RY REF LOG: MCNL/CCUGROF5/11/2007 TE-IN LOG: G~LOGY FDC LOG ANGLEATTOP FERF: 88° @ 11430' Note: Rsfer to Production DB for historical perf data SIZE SF1= INTERVAL OpnlSgz DATE 1-9/16" 6 11430- 11640 O 05/11/07 t-9/16" 6 11760- 11950 O 05!11/07 ~ 2-718" LNR, 6.16#, L-80-STL, .0058 bpf, ID= 2.372" ~ 10745' MA RKER 3' PUP JOINT I 2-3i3" LINER CEMBdTED& PERFED 12670' 10516 33M8" X 2-7x'8' XO, D = 2.441" 11260' BKR CIBP(OBJ08uU4) DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 03123,86 ORIG.HORd.COMPLEfION 08/25x1]4 LWBJKAK MgNDRELDEPTHCORRECTIONS WELL D-30E'. 01M2A3 JLMlTLH CTO SIDEfRACFt(D•3QA) 07/11/05 JLGIPJC PERFS PERMIT No: ~~~- 1.4 01M8A3 MH+TLH GLV UPDATE ! ~r1CA_4 JUE P;r~F:C>li-- t i_TG SIDETN..':.Cb-:: API No: 5x029-22846-OL 05M8A3 TMV/TLH LINER ID CORRECTION ~~`i 13:1_i7 F'AC; GRL-=- C~Fi::FT CORRECTIONS SEC 23, T11N, R13~ 3825' NSL&1068' WEL 09M7+03 CMDfTLP PERF ANGLECORRECTION 05131x107 CJN+PAG GLV C!O 08A8A4 BJMbUK ADPERFS & SET BKR CIBP BP E~cploration (Alaska) ECHANCAt_ ':;NNSTOC;K ~--~ 10496' WINDOW 10496' - 10501' RA pPTAG 10501' ~-~~ ~-S C®1dTSER~~'1`I®1!T C® SSI®1~T Pedro Rangel CT Drilling Engineer BP Exploration (Alaska) Inc. PO Box 196612 Anchorage, AK 99519-6612 ~i SARAH PALIN, GOVERNOR 333 W. 7th AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Re: Prudhoe Bay Field, Prudhoe Bay Pool, PBU D-30B BP Exploration (Alaska) Inc. Permit No: 206-184 Surface Location: 3625' FSL, 1066' FEL, SEC. 23, T11N, R13E, UM Bottomhole Location: 4708' FSL, 1487' FWL, SEC. 24, T11N, R13E, UM Dear Mr. Rangel: Enclosed is the approved application for permit to redrill the above referenced development well. This permit to drill does not exempt you from obtaining additional permits or an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 6607 (pager). Ch DATED thisday of December, 2006 Orman cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w-/o encl. - _ " ~ ~ L STATE OF ALASKA ~~~~IV~® . ,. ~~~ ,. ~ ~!~ ~~,,:.1 ~~ALAS 1L AND GAS CONSERVATION COMMI t p E C 2 0 2006 ~ PERMIT TO DRILL ~~~ 20 AAC 25.005 #~laska Oif & Gas Cons. Commission 1 a. Type of work ^ Drill ®Redrill ^ Re-Entry 1 b. Current Well Class ^ Exploratory ^ Development Gas ^ Service ^ Multiple Zone ^ Stratigraphic Test ®Development Oil ^ Single Zone 1 c. Specify if well is pro f~Qe ^ Coalbed Methane ^ Gas. Hydrates ^ Shale Gas 2. Operator Name: BP Exploration (Alaska) Inc. / 5. Bond: ®Blanket ^ Single Well Bond No. 6194193 / 11. Well Name and Number: PBU D-306 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 6. Proposed Depth: MD 12700 TVD 8970ss 12. Field /Pool(s): Prudhoe Bay Field / Prudhoe Bay 4a. Location of Well (Governmental Section): Surface: 3625' FSL 1066' FEL SEC 23 T11N R13E UM ~ 7. Property Designation: ADL 028285/ Pool , , , , , Top of Productive Horizon: 4992' FSL, 2665' FWL, SEC 24, T11 N, R13E, UM / 8. Land Use Permit: 13. Approximate Spud Date: April 1, 2007 Total Depth: 4708' FSL, 1487' FWL, SEC 24, T11 N, R13E, UM ~ 9. Acres in Property: 2560 14. Distance to Nearest Property: 18,500' 4b. Location of Well (State Base Plane Coordinates): Surface: x-654088 y-5959346 Zone-ASP4 10. KB Elevation (Height above GL): 78.25 feet 15. Distance to Nearest Well Within Pool: 750' 16. Deviated Wells: Kickoff Depth: 10495 feet Maximum Hole An le: 96 de rees 17. Maximum Anticipated Pressures in psig (see 20 AAC 25-.035) Downhole: 3200 Surface: 3154 18. Casin Pr ram: S ~fi ~ ns To - e in De th -Bo no u n i f Ce en .f. r a s Hole asin Wei ht Grade ou lin Len th MD TVD MD TVD includin sta a data 2-3/8" 4.7# L-80 STL 2450' 1 2 0' 8972' 12700' 8970' 48 sx Class ' ' 1 g, PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re-entry Operations) Total Depth. MD (ft): 11.935 ` Total Depth TVD (ft): 9042 Plugs (measured): 11260 Effective Depth MD (ft): 11260 Effective Depth TVD (ft): 9044 Junk (measured): None `asng Length ize ement Volume TVD Conductor/ Structural:- . 110' 2 260 sx Arcti s A r x. 110' 110' Surface = %:~ 3421' 10-3/4" 1165 sx P rmafro 'E' 498 sx Class 'G' 34 3276' Intermediate :.- . ~ `10369' 7-5/8" 553 x Cla 'G' 1 4 5' 9048' Pro cti n Liner 219' 4-1/2" 63 sx Class'G' 10234' - 10453' 9050' - 9047 Liner 19 1' 3-1/2" x 3-3/16" x 2-7/8" 11 sx la s ' 9944' - 11935' 8982' - 042' Perforation Depth MD (ft): 10880' - 11875' Perforation Depth TVD (ft): 9038' - 9041' 20. Attachments ®Filing Fee, $100 ®BOP Sketch ®Drilling Program ^ Time vs Depth Plot ^ Shallow Hazard Analysis ^ Property Plat ^ Diverter Sketch ^ Seabed Report ®Drilling Fluid Program ®20 AAC 25.050 Requirements 21. Verbal Approval: Commission Representative: Date: 22. I hereby certify that the,foregoing is true and correct. Contact Pedro Rangel, 564-4623 Printed Name Pedro Rangel Title CT Drilling Engineer Prepared By Name/Number: Si nature ~~ /~- ~~ ~° ~~ Phone 564-4623 Date (2 l °~ O G Terrie Hubble, 564-4628 Carr~mission Use Oni Permit To Drill ./ Num er: 0?06- /~Y API Number: 50-029-22646-02-00 Permit : r royal ~ See cover letter for h r r i n Conditions of Approval: If box is checked, well may not be used to(e~xplore for, test, or produce coalbed methane, gas hydrates, or gas contained shales: ~/ ©~ ~ ~~~ ~ ~ Samples Req'd: (_] Yes dNo Mud Log Req'd: ^ Yes Ltd No ~ 5 ~ n~ HZS Measures: [Yes ^ No Dir Tonal Survey Req'd: Yes ^ No Other: Date //~- ,Z~~ ~ ~ APPROVED BY THE COMMISSION ,COMMISSIONER Form 10-401 Revised 12/2005 ~ ~ ~ ^ ~ (~ t n ~ `~ ~ `-•~~ Submit In Duplicate • • by To: Winton Aubert, Petroleum Engineer Alaska Oil & Gas Conservation Commission From: Pedro Rangel, CTD Engineer Date: December 20, 2006 Re: Prudhoe Bay D-30B CTD Sidetrack Permit to Drill The sidetrack, D-30B, is scheduled to be drilled by Nordic 2 during the second half of April `07. The plan calls for a slimhole lateral with a solid liner and 600 ft of perforations on Zone 2 A. Pre-Rig Work: 1. O MIT-IA, and OA. (Last MIT IA/OA was done on 09/04/06) 2. S Run caliper log (Done on 09/03/06) 3. S Install Dummy valves on all GL mandrels (Done 09/04/06). 4. C Fish liner top packer @ 9,944' 5. C Dummy WS (15' x 2.625") drift to 10,516' ~- ~ ' 3~° Y ~~ ~~ 6. C Set CIBP @ 10,536 . 7. O Set BPV 8. O AC-LDS; AC-PPPOT-IC, T 9. O Test MV, SV, WV 10. O Bleed gas lift and production flowlines down to zero and blind flange 11 . O Remove wellhouse, level pad The pre CTD work is slated to begin on January O1, 2007. Rig Work: 1. MIlZU and test BOPS to 250 psi low and 3500 psi high. 2. Pull BPV 3. Set 3-3/16"monobore whipstock @ 10,495'. Reference Log: Liner Top Tie-In Memory GR/CCL 01/10/03 4. Mi112.74" window at 10,495' and 10' of openhole. Swap the well to Flo-Pro. 5. Drill Build: 3" OH, 322' (45 deg/100 planned) 6. Drill Lateral: 3" OH, 1,883' horizontal (12 deg/100 planned) -include resistivity ~~~-i- t 7. Run 2 3/8" solid liner leaving TOL at 10,250' ,~~ ~~ 8. Pump primary cement j ob to TOL, 10 bbl of 15.8 ppg cmt planned ~ ~~~~ `" 9. Run CO assembly v r1 b~~ ~ ~ l ,., 10. Run MCNL/GR/CCL log 11. Test liner lap to 2000 psi. ~'~'``"~ ~~ l w~~ -~ 12. Perforate 600 ft at the toe. 13. Freeze protect well, Set BPV, RDMO `~ Post-Rid Work 1. Pull BPV 2. Install well house. Hook up flow line. Mud Program: • Well kill: 8.6 ppg brine • Milling/drilling: 8.6 ppg Flo Pro or biozan for milling, new Flo Pro for drilling. Disposal: • All drilling and completion fluids and all other Class II wastes will go to Grind & Inject. • All Class I wastes will go to Pad 3 for disposal. Hole size: 3" Casing Program: • 2 3/8", 4.7# , L-80, STL connection Solid liner - 10,250 ft to 12,700 ft MD • A minimum of 10 bbls 15.8 ppg cement will be used for liner cementing. • TOC planned at 10,250 ft • 600 ft of perforations at the toe. Well Control: • BOP diagram is attached. • Pipe rams, blind rams and the CT pack off will be pressure tested to 250 psi and to 4000 psi. • The annular preventer will be tested to 250 psi and 2500 psi. c---------, Directional • See attached directional plan. Max. planned hole angle is 95 deg. • Magnetic and inclination surveys will be taken every 30 ft. No gyro will be run. • Distance to nearest property - 18,500' ft • Distance to nearest well within pool - 750' ft to D-14A Logging • MWD directional, Gamma Ray, and Resistivity will be run over all of the open hole section. • A cased hole GR/CCL/CNL log will be run. Hazards • The maximum recorded H2S level on D pad is 20 ppm in well D-30B on • 9/4/2006. • Lost circulation risk is moderate. Reservoir Pressure • Res. press. is estimated to be 3,200 psi at 8,800'ss (7 ppg EMW). Maximum surface pressure with gas (0.10 psi/ft) to surface is 2,320 psi. Pedro Rangel CTD Drilling Engineer 564-4623 CC: Well File Sondra Stewman/Terrie Hubble Disposal: • All drilling and completion fluids and all other Class II wastes will go to Grind & Inject. • All Class I wastes will go to Pad 3 for disposal. Hole size: 3" Casing Program: • 2 3/8", 4.7# , L-80, STL connection Solid liner - 10,250 ft to 12,700 ft MD • A minimum of 10 bbls 15.8 ppg cement will be used for liner cementing. • TOC planned at 10,250 ft • 600 ft of perforations at the toe. Well Control: ~C~ ,~' • BOP diagram is attached. • Pipe rams, blind rams and the CT pack off will be pressur~"~t~i 250 psi and to 4000 psi. • The annular preventer will be tested to 250 psi and~'S6~psi. Directional (~ • See attached directional plan. Max. planned hole a 95 deg. • Magnetic and inclination surveys will be taken e 0 ft. No gyro will be run. • Distance to nearest property -18,500' ft ~ • Distance to nearest well within pool - 750' f~o -14A Logging • MWD directional, Gamma Ray, and Re stivity will be run over all of the open hole section. • A cased hole GR/CCL/CNL log will e run. Hazards • The maximum recorded H2S el on D pad is 20 ppm in well D-30B on • 9/4/2006. • Lost circulation risk ism erate. Reservoir Pressure • Res. press. is esti ted to be 3,200 psi at 8,800'ss (7 ppg EMW). Maximum surfa pressure with gas (0.10 psi/ft) to surface is 3,154 psi. Pedro Rangel CTD Drilling 564-4623 s CC: ell File ondra Stewman/Terrie Hubble = 4" CNV LHEAD= FMC CTUATOR = AXELSON B. ELEV = 78.25' F. ELEV = 40.G OP= 1215' Angle = )8 ~ 10517' tum MD = 9738' tumTVO = 8800' SS 10-314" CSG, 45.5#, L-80, O = 9.953" H 3466' Minimum ID = 2.372" ~ 10616' 2-718" LINER D-30A • ITOP OF CEMENT I-{ 9980' 3-3/16" LNR, 6.2#, L-80, .007ti bpf, 10 = 2.80" 9983' 4-1/2" TBG, 12.8#, L-B0, .0152 bpf, ID = 3.958" 9991' TOP OF 4-1/2" LNR I--I 10260' l 7-5/8" CSG, 29.7#, USSS-95, ID = 6.875" TOP OF WHIPSTOCK RA TAG PBTD 4-1R" LNR, 12.6#, 1-80, ID = 3.953" ~ locos' f 10453' 10482' 10464' 1~~ PERFORATION SUMMARY REF LOG: SWS MEMORY GRICCL ON 01/10/03 ANGLE AT TOP PERF: 88 ~ 11020' Note: Refer to Production DB for historical perf data S¢E SPF INTERVAL Opn/Sgz DATE 2" 6 11020 - 11070 O 06106/04 2" s 10880 - 10910 0 o7n 1/05 2" 6 10920-10950 O 07/11/05 2" 4 11325-11500 O 01/11/03 2" 4 11550 -11750 O 01/11/03 2" 4 11800 - 11875 O 01 /12103 2-7/8" LNR, 6.16#, NOTES: HORIZONTAL 3 SOTRCK W ELL 221(' H4-1/2" HES HXOSSSV NIP, ID=3.813" CHAS I IF'r MAN(]RELS ST MD TVD DEV TYPE VLV LATCH PORT DATE 3 3779 3567 25 KBMG-M DOME BK 16 01/18/03 7144 6573 26 KBMG-M SO BK 20 01/16/03 1 9812 8921 59 KBMG-M DMY BK 0 12/14/02 9923' H 4-1/2" HES X NIP, ID = 3.813" 9933' 7-5/8" X 4-1/2" BKR S-3 PKR, O= 3.875" 9944' 4-1/2" X3-1/2" LNR TOP PKR, O = 2.560" 19' H BA KER LNR DEPLOY SLV W/SEAL LOC., ID = 2.39" 9967' 4-12" HES X NIP, ~ = 3.813" (BFJiWD CT LNR) 9879' 4-1/2" HES XN NIP, ID = 3.725" (BEH9dD CT LNR) 9980' I-{3-1/2" HES XN NAB, D = 2.750" 9982' 3-1/2" X 3-3/16' BAKER XO, ID = 2.80" 9991' 4-1/2" WLEG, O = 3.958" 10516' 3-3/16" X 2-718" XO, ID = 2.441" 11280' BKR GBP (06/06104) ~ PBTD ~--1 11902' .0058 bpf, ID = 2.372" 11' DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 08/23/>t6 ORIG. HORZ. COMPLETION 06/25!04 LWBIKAK MANDREL DEPTH CORRECTIONS WELL: D-30A 01H2103 JLMITLH CTD 81DETRACK (D-30A) 07/11/05 JLG/PJC PERFS PERMIT No:'2022400 01118/03 MH/TLH GLV UPDATE API No: 50-029-22646-01 05/18103 TMNITLH LNVER D CORRECTION SEC 23, T11 N, R13E, 3625' NSL b 1066' WEL 09/17/03 CMO/TLP PERF A NGLE CORRECTION 06/06/04 BJMcU ADPERFS 8 SET BKR GBP BP Expbratbn (Alaska) 17EE _ . . NELLHEAD = \CTUATOR = AX CB. ELEV = 3F. ELEV = COP = ~Aax Angle = ;18 ~ ~tum MD = ]atum ND = 8E 10-314" 4.,~ D-30B ELSON 78.25' Proposed CTD Sidetrack 40.6' 1215' O L-80, ID = 9.953" H 3456' NOTES: HORIZONTAL E4 SDTRCK WELL 2215' ~4-1/2" HES HXO SSSV NIP, ID = GAS LIFT MANDRELS ST MD ND DEV TYPE VLV LATCH PORT DATE 3 3779 3567 25 KBMG-M DOME BK 16 01/18/03 1 7144 9812 6573 8921 26 59 KBMG-M KBMG-M SO DMY BK BK 20 0 01/18/03 12/14102 9923' ~4-1/2" HES X NIP, ID = 3.813" 9933' 7-518" X 4-1/2" BKR S-3 PKR, ID = 3.875" 9957' H4-1/2" HES X NIP, ID = 3.813" (BEHIND CT LNR) 9959' BAKER LNR DEPLOY SLV 9979' 4-112" HES XN NIP, ID = 3.725" (BEHIND CT LNR) 3-3116" LNR, 6.2#, L-80, .0076 bpf, ~ = 2.80" ~-~ 9983• -112" TBG, 12.6#, L-80, .0152 bpf, ID = 3.958" 9991' ITOP OF 4-1/2" LNR ~--~ 1 ~.7#, USSS-95, ID = 6.875" 10405' TOP OF WHIPSTOCK 10453' RA TAG 10462' 4-1/2" WTHFD KS-WS PKR 10464' PBTD 13530' L-S0. ID = 3.953" 1---I 13891' PERFORATION SUMMARY REF LOG: SWS MEMORY GR/CCL ON 01/10/03 ANGLEATTOPPERF:88(~ 11020' Note: Refer to Productan DB for historical pert data SIZE SPF INTERVAL Opn/Sqz DATE 2" 6 11020 - 11070 0 06106!04 2" 6 10880 - 10910 0 07!11/05 2" 6 10920 - 10950 0 07!11/05 2" 4 11325 - 11500 0 01 /11 /03 2" 4 11550 - 11750 0 01/11/03 2" 4 11800 - 11875 0 01/12/03 1 1 9980' H3-1/2" HES XN NIP, ID = 2.750" 9982' ~-~ 3-1/2" X 3-3/16' BAKER XO, ID = 2.80" 9991' 4-1/2" WLEG, ID = 3.958" 1 0250' Top of 2-3/8" Liner 10250' Top of Cement 10516' 10536' 11260' DATE REV BY COMMENTS DATE REV BY COMMENTS 03/23/96 ORIG. HORZ. COMPLETION 06/25/04 LWB/KAK MANDREL DEPTH CORRECTIONS 01/12/03 JLM/TLH CTD SIDETRACK (D-30A) 07111105 JLG/PJC PERFS 01118!03 MH/TLH GLV UPDATE 05/18/03 TMNITLH LINER ID CORRECTION 09!17!03 CMO/TLP PE3tF ANGLE CORRECTION 06/06/04 BJMcUK ADPERFS & SET BKR CIBP erfed H 12700' i Whipstock w / R/A tags 6" X 2-7/8" X0, ID = 2.441" CIBP PRUDHOE BAY UNIT WELL: D-30A PERMIT No: 1022400 API No: 50-029-22646-01 SEC 23, T11 N, R13E, 3625' NSL Ex 1066' WEL BP Exploration (Alaska) BP Alaska by Baker Hughes INTEQ Planning Report Asa s INTEQ Company: BP Amoco Date: 10/23/2006 Time: 10:24:44 Page: 1 Field: Prudhoe Bay Co-ordinate(NE} Reference: Well: DSO, TNe NOrth Site: PB D Pad Vertical (TVD) Reference: D-30 RKB 7$.2 Well: D-30 Section (VS) Reference: Well (O.OON,O.OOE,265.OOAzi} Wellpath: Plan 4, D-30B Survey Calcnla6on Method: Minimum Curvature Db: Orade 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 2 006 Sys Datum: Mean Sea Level Geomagnetic Model: bggm Site: PB D Pad TR-11-13 UNITED STATES :North Slope Site Position: Northing: 5955590.34 ft Lafitude: 70 17 8.492 N From: Map Fasting: 652165.06 ft Longitude: 148 46 6.316 W ~ Position Uncertainty: 0.00 ft North Reference: True i Ground Level: 0.00 ft _ Grid Convergence: 1.16 deg Well: D-30 Slot Name: 30 D-30 Well Position: +N!-5 3716.81 ft Northing: 5959346.55 ft Latitude: 70 17 45.044 N +E!-W 9998.28 ft Fasting: 654087.58 ft Longitude: 148 45 8.072 W Position Uncertainty: 0.00 ft Wel-path: Plan 4, D-30B Drilled From: D-30A Tie-on Depth: 10486.99 ft Current Datum: D-30 RKB Height 78.25 ft Above System Datum: Mean Sea Level Magnefic Data: 10/23/2006 Declinafion: 24.14 deg Field Strength: 57647 nT Mag Dip Angle: 80.91 deg Vertical Section: Depth From (TVD) +N/-S +E/-W Direction ft ft ft deg 37.65 0,00 0.00 265.00 Plan: Plan #4 Date Composed: 10!23/2006 Copy Lamar's plan 4 Version: 4 Principal: Yes Tied-to: From: Definitive Path Targets Map Map <--- Latitude -> ~- Longitude --> Name Description TVD +N/-S +E/-W Northing Fasting Deg Min Sec Deg Min See Dip. Dir. ft ft ft ft ft D-30B Polygon 78.25 1336.75 2540.55 5960735.00 656600.00 70 17 58.187 N 148 43 54.010 W -Poygon 1 78.25 1336.75 2540.55 5960735.00 656600.00 70 17 58.187 N 148 43 54.010 W -Polygon 2 78.25 877.76 2436.11 5960274.00 656505.00 70 17 53.673 N 148 43 57.059 W -Polygon 3 78.25 960.67 4295.33 5960395.00 658362.00 70 17 54.480 N 148 43 2.860 W -Polygon 4 78.25 1444.53 4455.30 5960882.00 658512.00 70 17 59.238 N 148 42 58.188 W -Polygon 5 78.25 1544.74 4202.28 5960977.00 658257.00 70 18 0.225 N 148 43 5.563 W D-30B FauR1 78.25 1168.63 4202.57 5960601.00 658265.00 70 17 56.526 N 148 43 5.561 W -Polygon 1 78.25 1168.63 4202.57 5960601.00 658265.00 70 17 56.526 N 148 43 5.561 W -Polygon 2 78.25 905.47 4353.22 5960341.00 658421.00 70 17 53.937 N 148 43 1.173 W D-30B Target! 9048.25 1091.63 3908.91 5960518.00 657973.00 70 17 55.770 N 148 43 14.122 W D-30B Target2 9048.25 1090.15 2517.49 5960488.00 656582.00 70 17 55.762 N 148 43 54.684 W Annotation MD TVD ft ft 10486.99 9044.67 TIP 10495.00 9043.93 KOP 10515.00 9042.15 End of 9 Deg/100 DLS 10545.00 9042.31 4 10762.66 9052.76 5 10817.66 9051.83 End of 45 Deg/100 DLS 11317.66 9047.73 7 11567.66 9047.86 8 BP Alaska by Baker Hughes INTEQ Planning Report ~.~^ s INTEQ Company: BP Amoco Field: Prudhoe Bay Date: 10/23/2006 Time: 10:24:44 Co-ordinate(NE) Reference: We1F. D-30, Tn~e North Page: 2 Site: PB D Pad Vertical (TVD) Reference: D-30 RKB 78.2 WeR: D-30 Section (VS) Reference: Well (O,OON,O.OOE,265.DOAzi) Wellpatb: Plan 4, D-30B Survey Calcalation Metbod: Minimum Curvature Db: Orade Annotation MD TVD -- ft 11967.66 9048.03 9 - 12367.66 9048.16 10 12700.00 9048.24 TD Plan Section Information MD Incl ATim TVD +N/S +E/ W DLS Build Tnrn TFO Target ft deg deg ft ft ft deg1100ft deg/100ft deg/100ft deg 10486.99 94.89 78.74 9044.67 1502.49 4163.66 0.00 0.00 0.00 0.00 10495.00 95.74 80.35 9043.93 1503.94 4171.51 22.65 10.61 20.10 61.99 10515.00 94.47 81.63 9042.15 1507.06 4191.18 9.00 -6.37 6.38 135.00 10545.00 84.90 91.17 9042.31 1508.94 4221.05 45.00 -31.88 31.80 135.00 10762.66 91.00 189.06 9052.76 1361.48 4343.75 45.00 2.80 44.97 89.70 10817.66 90.91 213.81 9051.83 1310.69 4323.81 45.00 -0.17 45.01 90.00 11317.66 89.97 263.80 9047.73 1059.89 3909.54 10.00 -0.19 10.00 90.80 11567.66 89.97 288.80 9047.86 1087.13 3663.02 10.00 0.00 10.00 90.00 11967.66 89.98 248.80 9048.03 1078.95 3271.18 10.00 0.00 -10.00 270.00 12367.66 89.98 288.80 9048.16 1070.77 2879.34 10.00 0.00 10.00 90.00 12700.00 89.99 255.57 9048.24 1083.28 2551.88 10.00 0.00 -10.00 270.00 5arvey MD Incl Azim SS TVD N/S E/W MapN MapE DI.5 VS TFO Tod ft deg deg ft ft ft ft ft deg/100ft ft deg 10486.99 94.89 78.74 8966.42 1502.49 4163.66 5960933.97 658219.26 0.00 -4278.77 0.00 MWD 10495.00 95.74 80.35 8965.68 1503.94 4171.51 5960935.58 658227.07 22.65 -4286.71 61.99 MWD I 10500.00 95.42 80.67 8965.19 1504.76 4176.42 5960936.50 658231.96 9.00 -4291.67 135.00 MWD 10515.00 94.47 81.63 8963.90 1507.06 4191.18 5960939.10 658246.68 9.00 -4306.58 135.03 MWD 10520.00 92.87 83.22 8963.58 1507.72 4196.13 5960939.86 658251.61 45.00 -4311.57 135.00 MWD 10530.00 89.68 86.39 8963.36 1508.62 4206.08 5960940.97 658261.54 45.00 -4321.56 135.10 MWD 10540.00 86.49 89.57 8963.69 1508.97 4216.07 5960941.52 658271.52 45.00 -4331.54 135.17 MWD 10545.00 84.90 91.17 8964.06 1508.94 4221.05 5960941.59 658276.50 45.00 -4336.50 135.07 MWD 10550.00 84.92 93.42 8964.51 1508.74 4226.03 5960941.50 658281.48 45.00 -4341.44 89.70 MWD 10560.00 84.97 97.94 8965.39 1507.75 4235.94 5960940.71 658291.41 45.00 -4351.23 89.50 MWD 10570.00 85.06 102.46 8966.26 1505.99 4245.74 5960939.15 658301.24 45.00 -4360.84 89.10 MWD 10580.00 85.18 106.97 8967.11 1503.46 4255.37 5960936.82 658310.93 45.00 -4370.22 88.71 MWD 10590.00 85.32 111.49 8967.94 1500.18 4264.78 5960933.73 658320.40 45.00 14379.30 88.32 MWD 10600.00 85.50 116.00 8968.74 1496.17 4273.90 5960929.91 658329.60 45.00 -4388.04 87.95 MWD 10610.00 85.70 120.51 8969.51 1491.45 4282.68 5960925.37 658338.47 45.00 -4396.38 87.59 MWD 10620.00 85.93 125.01 8970.24 1486.05 4291.07 5960920.15 658346.97 45.00 -4404.26 87.24 MWD 10630.00 86.18 129.52 8970.93 1480.01 4299.01 5960914.27 658355.03 45.00 -4411.64 86.91 MWD 10640.00 86.46 134.02 8971.57 1473.37 4306.45 5960907.78 658362.60 45.00 -4418.47 86.60 MWD 10650.00 86.76 138.51 8972.16 1466.16 4313.35 5960900.72 658369.65 45.00 -4424.72 86.32 MWD 10660.00 87.08 143.01 8972.70 1458.43 4319.66 5960893.11 658376.12 45.00 -4A30.33 86.05 MWD 10670.00 87.42 147.50 8973.18 1450.22 4325.35 5960885.03 658381.97 45.00 -4435.29 85.81 MWD 10680.00 87.77 151.99 8973.60 1441.59 4330.38 5960876.51 658387.18 45.00 -4439.55 85.59 MWD 10690.00 88.14 156.48 8973.95 1432.59 4334.73 5960867.60 658391.71 45.00 -4443.09 85.40 MWD 10700.00 88.52 160.97 8974.24 1423.28 4338.35 5960858.36 658395.52 45.00 -4445,88 85.24 MWD 10710.00 88.91 165.45 8974.47 1413.71 4341.24 5960848.86 658398.61 45.00 -4447.93 85.11 MWD 10720.00 89.30 169.93 8974.63 1403.95 4343.37 5960839.14 658400.94 45.00 -4449.21 85.01 MWD 10730.00 89.70 174.42 8974.71 1394.04 4344.73 5960829.26 658402.50 45.00 -4449.70 84.94 MWD 10740.00 90.10 178.90 8974.73 1384.06 4345.32 5960819.30 658403.29 45.00 -4449.41 84.90 MWD 10750.00 90.50 183.38 8974.68 1374.07 4345.12 5960809.30 658403.30 45.00 -4448.34 84.89 MWD 10760.00 90.90 187.86 8974.56 1364.12 4344.14 5960799.34 658402.52 45.00 -4446.50 84.92 MWD 10762.66 91.00 189.06 8974.51 1361.48 4343.75 5960796.69 658402.18 45.00 -4445.88 84.97 MWD 10770.00 91.00 192.36 8974.39 1354.28 4342.38 5960789.46 658400.97 45.00 -4443.89 90.00 M111~ 10780.00 90.99 196.86 8974.21 1344.60 4339.86 5960779.74 658398.65 45.00 -4440.54 90.06 MWD 10790.00 90.98 201.36 8974.04 1335.16 4336.59 5960770.23 658395.57 45.00 -4436.45 90.14 MWD BP Alaska by Baker Hughes INTEQ Planning Report ~a~ E~iuc~s INTEQ Company; BP Amoco Date: 10/23!2006 Time: 10:24:44 Page: 3 Field: Prudhoe Bay Co-ordinate(NE) Reference: Weii: D~30, True North Site: PB D Pad Vertical (T'VD) Reference: D-30 RKB 78.2 Well: D-30 Section (VS) Reference: Well (O.OON,O.OQE,265.OOAzi} Wellpath: Plan 4, D-30B Survey Calcalation Method: Minimum Curvature Db: Orade Survey MD Inc! Azim SS TVD N/S E/W MapN MapE DLS VS TFO Tool ft deg deg ft ft ft ft ft deg/100ft ft deg 10800.00 90.96 205.86 8973.87 1326.00 4332.59 5960760.99 658391.75 45.00 -4431.67 90.21 MWD 10810.00 90.93 210.36 8973.71 1317.18 4327.88 5960752.08 658387.22 45.00 -4426.21 90.29 MWD 10817.66 90.91 213.81 8973.58 1310.69 4323.81 5960745.51 658383.29 45.00 -4421.59 90.36 MWD 10850.00 90.86 217.04 8973.08 1284.35 4305.07 5960718.79 658365.09 10.00 -4400.62 90.80 MWD 10900.00 90.78 222.04 8972.37 1245.81 4273.25 5960679.61 658334.07 10.00 -4365.56 90.85 MWD 10950.00 90.70 227.04 8971.72 1210.19 4238.19 5960643.28 658299.75 10.00 -4327.53 90.92 MWD 11000.00 90.61 232.04 8971.14 1177.76 4200.16 5960610.08 658262.40 10.00 -4286.82 90.99 MWD 11050.00 90.52 237.04 8970.65 1148.76 4159.44 5960580.26 658222.29 10.00 -4243.74 91.04 MWD 11100.00 90.42 242.04 8970.24 1123.43 4116.36 5960554.04 658179.74 10.00 -4198.61 91.09 MWD 11150.00 90.32 247.04 8969.91 1101.94 4071.23 5960531.64 658135.06 10.00 -4151.78 91.13 MV11D I 11200.00 90.22 252.04 8969.68 1084.47 4024.40 5960513.21 658088.60 10.00 -4103.60 91.17 MWD 11250.00 90.11 257.04 8969.53 1071.15 3976.22 5960498.91 658040.72 10.00 -4054.45 91.19 MWD 11300.00 90.01 262.04 8969.48 1062.07 3927.07 5960488.82 657991.76 10.00 -4004.69 91.20 MWD 11317.66 89.97 263.80 8969.48 1059.89 3909.54 5960486.29 657974.28 10.00 -3987.04 91.21 MWD 11350.00 89.97 267.04 8969.50 1057.31 3877.31 5960483.05 657942.12 10.00 -3954.71 90.00 MWD 11400.00 89.97 272.04 8969.53 1056.91 3827.33 5960481.62 657892.16 10.00 -3904.88 90.00 MWD 11450.00 89.97 277.04 8969.55 1060.86 3777.50 5960484.55 657842.26 90.00 -3855.59 90.00 MWD 11500.00 89.97 282.04 8969.58 1069.15 3728.21 5960491.82 657792.81 10.00 -3807.20 89.99 MWD 11550.00 89.97 287.04 8969.60 1081.69 3679.83 5960503.37 657744.19 10.00 -3760.10 89.99 MWD 11567.66 89.97 288.80 8969.61 1087.13 3663.02 5960508.46 657727.27 10.00 -3743.83 89.99 MWD 11600.00 89.97 285.57 8969.62 1096.68 3632.13 5960517.38 657696.20 10.00 -3713.89 270.00 MWD 11650.00 89.97 280.57 8969.64 1107.99 3583.44 5960527.68 657647.29 10.00 -3666.37 270.00 MWD ~ 11700.00 89.97 275.57 8969.67 1115.00 3533.95 5960533.68 657597.67 10.00 -3617.68 270.00 MWD 11750.00 89.98 270.57 8969.69 1117.68 3484.04 5960535.34 657547.72 10.00 -3568.20 270.01 MWD 11800.00 89.98 265.57 8969.71 1116.00 3434.08 5960532.63 657497.81 10.00 -3518.28 270.01 MWD 11850.00 89.98 260.57 8969.73 1109.97 3384.47 5960525.58 657448.33 10.00 -3468.33 270.01 MWD 11900.00 89.98 255.57 8969.75 1099.64 3335.56 5960514.25 657399.65 10.00 -3418.71 270.01 MWD 11950.00 89.98 250.57 8969.77 1085.08 3287.74 5960498.72 657352.14 10.00 -3369.80 270.01 MWD 11967.66 89.98 248.80 8969.78 1078.95 3271.18 5960492.25 657335.71 10.00 -3352.77 270.02 MWD 12000.00 89.98 252.04 8969.79 1068.11 3240.72 5960480.80 657305.48 10.00 -3321.48 90.00 MWD 12050.00 89.98 257.04 8969.80 1054.79 3192.54 5960466.49 657257.59 10.00 -3272.32 90.00 MWD 12100.00 89.98 262.04 8969.82 1045.71 3143.39 5960456.40 657208.64 10.00 -3222.57 90.00 MWD 12150.00 89.98 267.04 8969.84 1040.95 3093.63 5960450.63 657158.99 10.00 -3172.58 90.00 MWD 12200.00 89.98 272.04 8969.86 1040.55 3043.65 5960449.20 657109.03 10.00 -3122.76 89.99 MWD 12250.00 89.98 277.04 8969.87 1044.51 2993.82 5960452.13 657059.14 10.00 -3073.46 89.99 MWD 12300.00 89.98 282.04 8969.89 1052.79 2944.53 5960459.40 657009.69 10.00 -3025.08 89.99 MIND 12350.00 89.98 287.04 8969.90 1065.33 2896.14 5960470.95 656961.06 10.00 -2977.97 89.99 MWD 12367.66 89.98 288.80 8969.91 1070.77 2879.34 5960476.04 656944.15 10.00 -2961.71 89.99 MWD 12400.00 89.98 285.57 8969.91 1080.32 2848.45 5960484.96 656913.07 10.00 -2931.77 270.00 MWD 12450.00 89.98 280.57 8969.93 1091.63 2799.76 5960495.26 656864.17 10.00 -2884.25 270.00 MWD 12500.00 89.98 275.57 8969.94 1098.64 2750.27 5960501.26 656814.55 10.00 -2835.56 270.00 MWD 12550.00 89.99 270.57 8969.95 1101.32 2700.36 5960502.92 656764.59 10.00 -2786.07 270.00 MWD 12600.00 89.99 265.57 8969.97 1099.64 2650.40 5960500.21 656714.69 10.00 -2736.16 270.00 MWD 12650.00 89.99 260.57 8969.98 1093.61 2600.78 5960493.16 656665.21 10.00 -2686.20 270.01 MWD 12700.00 89.99 255.57 8969.99 1083.28 2551.88 5960481.83 656616.52 10.00 -2636.58 270.01 2 3/8" ~ • Q i ~~ $~!!sE a .n -r~= ~~_ ~, m j 8 ~+ a ~ ~ ~ ~ -~ ,~, ~ ~ e, ~ ~ ~ ~ ~ ~~ ~ ~ 1 8 8 ~ ~ ~ ~., o ~ a ~~ s ~ ~ \, a ~ ~ ~ ~ ~~ i ~ \ s n ~ 9 a §~ a $e ~ ~ ~ N s ~E r H . e• 8 I ~ 8 ~ ~ 8 ~ ~ ~ ~~,~ ~ $ 8 ~ $ 8 8 8 8 6 8 8 ~ $ 8 ~ 8 8 8 S $ Iwnroo-1 (.W WNA-IVI~oY d 3 7 E i t g~ u ~fP~ I s 2 tyiC¢i e39pL{~C~igS f fY~ti~~~~? a aacs - e^ e- ~ i V 3 ~ ~ _ ii CSt ' i:~~iii~~:{ _ x °~ z 8888 I i ~ ~ ~ ~~ ~3 I'= ~~av i ' ~ Q ~ y ~ ~ $ E ~ ',~ Yoof ~~~QO { qa as ~ £~§~x~~fE~ ~ -- _ a~~ ~ o. yy ii 9 ~ ~ ?y^tic^^i i~f~: Y ~=~i ~ i ig ~ ~ ~i;R~iEi~E~ eS7=E~ 37 , ~ ~ i T i 3 j[ . . ,...:.. d w . . i~ ~ 3ii~q~i~i~! ~ ~ ~ ~ ~ ~ ~ e ~ ~ ~ s s ~ ~ ~ . . . p [~uaosl wd.a i ~~ a _ ents are • `m ~ D-306 BAG bag of slips of pipes 2~~ combi ram/slips TOTs ~ ~ Mud Cross I I Mud Cross flow cross TOTs middle of pipe/slips 2~~ combi ram/slips Swab Valy Blind/Shears Flow Tee RE: [Fwd: [Fwd: D-30B]] • Subject: RE: [Fwd: [Fwd: D-30B]] From: "McLaughlin, Sean M" <Sean.McLaughlin@bp.com% Date: Thu, 28 :Dec 2006 16:12:59 -0900 ~I'o: I~hoi~~as ~~laun~ier to~» maundcr~~r acln~in.siatc.ak.us- C'C: I'c~iro l~ar~icl Ran~~tl Escar7a<rE~~drnl~'uanchor<<«e~.~~ilfieid.511~.cc~m=~ Torn, l agree Pedro has some interesting math. Let's use this: • Res. press. is estimated to be 3,200 psi at 8,800'ss (7 ppg EMW). Maximum surface pressure with gas (0.10 psi/ft) to surface is 2,320 psi. l revised and attached the permit summary far your convenience. Pedro will be out ofi the office through Jan 8th. Please let me know if anything else on the permit application needs locked at. Thanks, Sean Sean McLaughlin CTD Engineer 564-4387 Office 223-6784 Cell 564-5510 Fax -------- Original Message -------- Subject: D-30B Date: Wed, 27 Dec 2006 15:57:57 -0900 From: Thomas Maunder atom maunder(rx~,admin.state.ak.us> Organization: State of Alaska To: pedro.ran,~;cl(%bp.com Pedro, I am reviewing the permit application for D-30B. In the reservoir pressure section you state the MASP to be 3154 psi. With 3200 psi BHP at 8800' ss and .1 psi/ft, I cannot calculate 3154. Would you please respond with the correct surface pressure? Thanks in advance. Call or message with any questions. Tom Maunder, PE AOGCC D-30B Summary for Permit.doc Content-Description: D-30B Summary for Permit.doc Content-Type: application/msword Content-Encoding: base64 1 of 1 12/29/2006 7:49 AM - Alaska Department of Natural$esources Land Administration System Page 1 of 8 ~Iaska Mapper Land Records/Status Plats Recorder's Search State Cabins F~~tur~l Re'caur~e5 IBS c1 a St'c~Ct File Type: AUL File Number: ~ 282$5 iii Printable Case File Abstract See Township, Range, Section and Acreage? ~'° Yes No New Search 1_AS_Menu_ ~ Case Summary I Case Detail ~ Land Abstract -. File: ADL 28285 `` ' As of 12/26/2006 Customer: 000107377 BP EXPLORATION (ALASKA) INC PO BOX 196612/900 E. BENSON BL ATTN: LAND MANAGER- ALASKA ANCHORAGE AK 995196612 Case Type: 784 OIL & GAS LEASE COMP DNR Unit: 780 OIL AND GAS File Location: DOG DIV OIL AND GAS Case Status: 35 ISS/APPRV/ACTV AUTH Status Date: 08/19/1965 Total Acres: 2560.000 Date Initiated: 05/28/1965 Office of Primary Responsibility: DOG DIV OIL AND GAS Last Transaction Date: 12/04/2006 Case Subtype: NS NORTH SLOPE Last Transaction: AA-NRB ASSIGNMENT APPROVED Meridian: U Township: O11N Range: 013E Section: 13 Section Acres: 640 Search Plats Meridian: U Township: O11N Range: 013E Section: 14 Section Acres: 640 Meridian: U Township: O11N Range: 013E Section: 23 Section Acres: 640 Meridian: U Township: O11N Range: 013E Section: 24 Section Acres: 640 Case Actions OS-28-1965 TRACT DEFINED SALE DATE 07-14-1965 STATUS (11) 11 TRACT DEFINED BID TYPE 1 FIXED ROYALTY RATE SALE NUMBER 14 TRACT NUMBER 96 FORM NUMBER 5 DL-IOCTOBER 1963 CONDITIONAL Y/N N PRIMARY TERM 10 http:/1www.dnr.state. ak.us/las/Case_Abstract. cfm?FileType=ADL&FileNumber=028285... 12/26/2006 ' Alaska Department of Natura esources Land Administration System Page 2 of 8 07-14-1965 NOTIFICATION LESSEE DESIGNATED NEW REL (20) 20 NOTIFICATION LESSEE OLD REL CODE 21 DISPOSAL NAME NOTIFICATION CID NUMBER 154737 BP EXPLORATION COMPA OLD CID # (SALE NO) 4568 SALE 14 07-14-1965 INITIAL OWNER SEGMENT CODE 1 CID NUMBER 000154737 BP EXPLORATION COMPA WORKING INTEREST % 100 ROYALTY INTEREST % 87.500000 07-14-1965 INITIAL OWNER SEGMENT CODE 1 CID NUMBER 000004568 SALE 14 ROYALTY INTEREST % 12.500000 07-14-1965 BID RECEIVED STATUS (12) 12 BID RECEIVED BID TYPE 1 FIXED ROYALTY RATE TOTAL BONUS BID 121856 DEPOSIT AMOUNT 24375 ROYALTY SHARE % 12.500000 BP EXPLORATION COMPANY (ALASKA) INC., 100% 07-16-1965 LEASE AWARDED STATUS (13) 13 LEASE AWARDED 08-19-1965 LEASE ISSUED EFFECTIVE DATE 09-01-1965 EXPIRATN DATE 08-31-1975 STATUS (20) 20 ACTIVE 08-08-1966 NOTIFICATION LESSEE CHANGED NEW NL (20} 20 NOTIFICATION LESSEE OLD NL (20) 20 NOTIFICATION LESSEE NEW NOTIF LESSEE CID# 107377 BP EXPLORATION USA I OLD NOTIF LESSEE CID# 154737 BP EXPLORATION COMPA 08-11-1966 ASSIGNMENT APPROVED EFFECTIVE DATE 08-08-1966 SEGMENT CODE l ASSIGNOR'S CID 000154737 BP EXPLORATION COMPA ASSIGNEE'S CID 000107377 BP EXPLORATION USA I http://www.dnr. state.ak.us/las/Case_Abstract.cfm?FileType=ADL&FileNumber=028285... 12/26/2006 • Alaska Department of Natura~sources Land Administration System WORKING INTER % ASSIGNED 100 ROYALTY INTER % ASSIGNED 75 02-17-1969 CUSTOMER CHANGED NAME NEW NAME: BP OIL CORPORATION OLD NAME: BP EXPLORATION USA INC. 08-28-1969 CUSTOMER CHANGED NAME NEW NAME: BP ALASKA INC OLD NAME: BP EXPLORATION COMPANY (ALASKA) INC. 10-06-1969 ASSIGNMENT APPROVED EFFECTIVE DATE 10-06-1969 SEGMENT CODE 1 ASSIGNOR'S CID 000154737 BP ALASKA INC Page 3 of 8 ASSIGNEE'S CID 000107377 BP OIL CORPORATION ROYALTY INTER % ASSIGNED 12.500000 12-17-1971 COMMENTS PURSUANT TO AS 38.05, WELL DATA IS REQUIRED WITHIN 30 DAYS OF LESSEE'S RECEIPT OF THIS NOTICE OR 30 DAYS AFTER THEIR RECEIPT OF SAID DATA. 01-25-1974 CUSTOMER CHANGED NAME NEW NAME: SOHIO PETROLEUM COMPANY OLD NAME: BP OIL CORPORATION 04-08-1974 PATENT RECEIVED EFFECTIVE DATE 03-27-1974 EXPIRATN DATE 03-27-1984 TITLE ACQUISITIONFILE NUMBER NOT ONDOCUMENT. 04-01-1977 UNITIZED EFFECTIVE DATE 04-01-1977 UNIT CODE PB PRUDHOE BAY TOTAL ACRES 2560 UNIT ACRES 2560 LEASE COMMITTED TO PR UDHOE BA Y UNIT AREA. DECISION NOT IN FILE. 02-26-1979 CUSTOMER CHANGED NAME NEW NAME: SOHIO NATURAL RESOURCES COMPANY OLD NAME: SOHIO PETROLEUM COMPANY 02-21-1980 CUSTOMER CHANGED NAME NEW NAME: SOHIO ALASKA PETROLEUM COMPANY OLD NAME: SOHIO NATURAL RESOURCES COMPANY 03-25-1986 CUSTOMER CHANGED NAME http://www.dnr.state.ak.us/las/Case Abstract.cfm?FileType=ADL&FileNumber-028285... 12/26/2006 i Alaska Department of Natural esources Land Administration System Page 4 of 8 NEW NAME: STANDARD ALASKA PRODUCTION COMPANY OLD NAME: SOHIO ALASKA PETROLEUM COMPANY 07-07-1987 PARTICIPATING AREA ESTABLISHED EFFECTIVE DATE 12-01-1986 UNIT CODE PB PRUDHOE BAY TOTAL ACRES 2560 UNITIZED ACRES 2560 PARTICIPATING ACRES 640 FORMATION OF THE INITIAL LISB URNS PARTICIPATING AREA. 01-31-1989 CUSTOMER CHANGED NAME NEW NAME: BP EXPLORATION (ALASKA) INC OLD NAME: STANDARD ALASKA PROD UCTION COMPANY 02-28-1989 COMMENTS ASSIGNMENT OF 16.4246 ROYALTYINTEREST TO SOCO INC AND SUBSEQUENTLY TO BP PR UD. BAY ROYALTY TRUST IS DEFINED IN ORR CONVEYANCE. 02-28-1989 ASSIGNMENT APPROVED EFFECTIVE DATE 02-27-1989 SEGMENT CODE 1 ASSIGNOR'S CID 000107377 BP EXPLORATION (ALAS ASSIGNEE'S CID 000012213 THE STANDARD OIL COM ROYALTY INTER % ASSIGNED 16.424600 02-28-1989 ASSIGNMENT APPROVED EFFECTIVE DATE 02-27-1989 SEGMENT CODE 1 ASSIGNOR'S CID 000012213 THE STANDARD OIL COM ASSIGNEE'S CID 000012212 BP PRUDHOE BAY ROYAL ROYALTY INTER % ASSIGNED 16.424600 12-19-1996 COMMENTS UPPER NET PROFITS ROYALTYINTEREST (NPRI) CONVEYANCE BETWEEN BP ALASKA INC. AND BP EXPLORATION (ALASKA) INC. PLACED IN CASE FILE. OS-10-2000 CUSTOMER CHANGED NAME NEW NAME: PHILLIPS ALASKA, INC. OLD NAME: ARCO ALASKA, INC. 08-03-2000 ASSIGNMENT APPROVED EFFECTIVE DATE 07-01-2000 SEGMENT CODE 1 http://www.dnr.state.ak.us/las/Case Abstract.cfm?FileType=ADL&FileNumber-028285... 12/26/2006 . Alaska Department of Natura~sources Land Administration System Page 5 of 8 ASSIGNORS CID 000107377 BP EXPLORATION (ALAS ASSIGNEES CID 000106346 PHILLIPS ALASKA, INC WORKING INTER % ASSIGNED 36.492700 ROYALTY INTER % ASSIGNED 31.931110 08-03-2000 ASSIGNMENT APPROVED EFFECTIVE DATE 07-01-2000 SEGMENT CODE 1 ASSIGNORS CID 000107377 BP EXPLORATION (ALAS ASSIGNEES CID 000106600 EXXON MOBIL CORPORAT WORKING INTER % ASSIGNED 35.822830 ROYALTY INTER % ASSIGNED 31.344980 08-03-2000 ASSIGNMENT APPROVED EFFECTIVE DATE 07-01-2000 SEGMENT CODE 1 ASSIGNORS CID 000107377 BP EXPLORATION (ALAS ASSIGNEES CID 000033073 MOBIL ALASKA E&P INC WORKING INTER % ASSIGNED .999800 ROYALTY INTER % ASSIGNED .874830 08-03-2000 ASSIGNMENT APPROVED EFFECTIVE DATE 07-01-2000 SEGMENT CODE 1 ASSIGNORS CID 000107377 BP EXPLORATION (ALAS ASSIGNEES CID 000034758 FORCENERGY INC WORKING INTER % ASSIGNED .020000 ROYALTY INTER % ASSIGNED .017500 08-08-2000 COMMENTS CONVEYANCE & MERGER (UPPER LOWER NPRI & UPPER NPRI) DOC. DATED 6/30/00 BETWEEN STANDARD OIL & BP EXPLORATION WAS PLACED IN THE CASE FILE. 01-02-2001 COMMENTS OVERRIDING ROYALTYINTERESTS ARE NOT TRACKED AFTER INITIAL SEPARATION FROM THE WORKING INTEREST. CHECK THE APPROPRIATE RECORDER `S OFFICE. 03-30-2001 ASSIGNMENT APPROVED EFFECTIVE DATE 02-01-2001 SEGMENT CODE 1 ASSIGNORS CID 000034758 FORCENERGY INC http://www.dnr. state.ak.us/las/Case_Abstract.cfin?FileType=ADL&FileNumber=028285... 12/26/2006 Alaska Department of Natura~sources Land Administration System Page 6 of 8 ASSIGNEES CID 000004134 FOREST OIL CORPORATI WORKING INTER % ASSIGNED .020000 ROYALTY INTER % ASSIGNED .017500 07-09-2001 COMMENTS A SUMMATION OF OVERRIDING ROYALTY INTERESTS HAS OCCURRED. INDIVIDUAL OVERRIDING ROYALTYINTERESTS ARE ND LONGER TRACKED SEPARATELY. 07-31-2001 CUSTOMER CHANGED NAME NEW NAME: EXXONMOBIL ALASKA PRODUCTION, INC. OLD NAME: MOBIL ALASKA E&P INC. 09-21-2001 ASSIGNMENT APPROVED EFFECTIVE DATE 07-01-2001 SEGMENT CODE 1 ASSIGNORS CID 000106604 EXXON MOBIL CORPORAT ASSIGNEES CID 000033073 EXXONMOBIL ALASKA PR WORKING INTER % ASSIGNED 35.822830 ROYALTY INTER % ASSIGNED 31.344980 09-26-2002 CUSTOMER CHANGED NAME NEW NAME: CONOCOPHILLIPS ALASKA, INC. OLD NAME: PHILLIPS ALASKA, INC. 12-04-2002 ASSIGNMENT APPROVED EFFECTIVE DATE 11-01-2002 SEGMENT CODE 1 ASSIGNORS CID 000107377 BP EXPLORATION (ALAS ASSIGNEES CID 000106539 CHEVRON U.S.A. INC WORKING INTER % ASSIGNED .309314 ROYALTY INTER % ASSIGNED .270650 12-04-2002 ASSIGNMENT APPROVED EFFECTIVE DATE 11-01-2002 SEGMENT CODE 1 ASSIGNORS CID 000106346 CONOCOPHILLIPS ALASK ASSIGNEES CID 000106539 CHEVRON U.S.A. INC WORKING INTER % ASSIGNED .423315 ROYALTY INTER % ASSIGNED .370401 12-04-2002 ASSIGNMENT APPROVED EFFECTIVE DATE 11-01-2002 SEGMENT CODE 1 http://www.dnr. state.ak.us/las/Case_Abstract.cfm?FileType=ADL&FileNumber=028285... 12/26/2006 Alaska Department of Natura~sources Land Administration System ~ Page 7 of 8 ASSIGNORS CID 000033073 EXXONMOBIL ALASKA PR ASSIGNEES CID 000106539 CHEVRON U.S.A. INC WORKING INTER % ASSIGNED .427139 ROYALTY INTER % ASSIGNED .373747 12-04-2002 ASSIGNMENT APPROVED EFFECTIVE DATE 11-01-2002 SEGMENT CODE 1 ASSIGNORS CID 000004134 FOREST OIL CORPORATI ASSIGNEES CID 000106539 CHEVRON U.S.A. INC WORKING INTER % ASSIGNED .000232 ROYALTY INTER % ASSIGNED .000203 12-31-2002 STATUS CODE STANDARDIZED STATUS CODE 35 ISS/APPRV/ACTV AUTH * * * * * STAT US CODE STANDARDIZATION STATUS CODE CHANGED BYBATCH UPDATE 12-04-2006 ASSIGNMENT APPROVED EFFECTIVE DATE 09-01-2006 SEGMENT CODE 1 ASSIGNOR'S CID 000004134 FOREST OIL CORPORATI ASSIGNEE'S CID 000106346 CONOCOPHILLIPS ALASK WORKING INTER % ASSIGNED .007361 ROYALTY INTER % ASSIGNED .006441 12-04-2006 ASSIGNMENT APPROVED EFFECTIVE DATE 09-01-2006 SEGMENT CODE 1 ASSIGNOR'S CID 000004134 FOREST OIL CORPORATI ASSIGNEE'S CID 000107377 BP EXPLORATION (ALAS WORKING INTER % ASSIGNED .005211 ROYALTY INTER % ASSIGNED .004560 12-04-2006 ASSIGNMENT APPROVED EFFECTIVE DATE 09-01-2006 SEGMENT CODE 1 ASSIGNOR'S CID 000004134 FOREST OIL CORPORATI ASSIGNEE'S CID 000033073 EXXONMOBIL ALASKA PR WORKING INTER % ASSIGNED .007196 ROYALTY INTER % ASSIGNED .006296 http ://www. dnr. state. ak.us/las/Case_Abstract.cfm?FileType=ADL&FileNumber-0282 85... 12/26/2006 Alaska Department of Natural esources Land Administration System Page 8 of 8 Legal Description OS-28-1965 * * *SALE NOTICE LEGAL DESCRIPTION* * * C14-96 TI 1 N-R13E- UM 13,14, 23,24 2, 560.00 LISB URNS PARTICIPATING AREA DESCRIPTION T. 11., R. 13 E., U.M. SECTION 13: ALL 640 ACRES CONTAINING 640 ACRES, MORE OR LESS. O1F CalS@ ~1Stlr"~C'~ Last updated on 12/26/2006. Not sure who to contact? Have a question about DNR? Visit the °?_'~~;,. Ir=~orrnaf:~n Center. Report technical problems with this page to the 1Naster• Site optimized for Netscape 7, IE 6 or above. This site also requires that all CQC3KIE must be accepted. State of Alaska Natural Resources LAS Home Copyright Privacy System_Skatus http://www. dnr. state. ak.us/las/Case_Abstract.cfin?FileType=ADL&FileNumber=028285... 12/26/2006 • • Terri L. Hubble. ss-si,zs2 317 BP Exploration AK Inc. ^Mastercard Check" PO Box 19661-2 MB 7-5 Anchorage, AK 99519 ~ Z ~ .~ DATE PAY TO THE ORDER OF _ _.._, Fi"rst National Bank_Alaska _ - AnchoragRe, AK..99:501 MEMO L/" ~ _. ~:~25200060~:99~46227i556~~' 03L? • • TRANSIVIITTAi, LETTEIa CFIECKLIST ~vEI;L NAIVIE .O.~l/ D X08 PTD# o.?GK J~~ ~/ Development Service Exploratory Stratigraphic Test iYon-Conventional Well Circle Appropriate Letter !Paragraphs to be Included in Transmittal Letter CHECK ADD-ONS TEXT FOR APPROVAL LETTER VI~'HAT ~ (OPTIONS) APPLIES J ~ ~ MliLTI LATERAL ~ The permit is for a new wellbore segment of existing ~ well ' ~ (IF last two digits b API in ~ Permit No. , API No. ~0- - - . ! num er ; between 60-69) are Production should continue to be reported as a function of the I i ,original API number stated above. .PILOT HOLE ~ [n accordance with 20 AAC 25.00~(f), al! records, data and logs acquired for the pilot hole must be clearly differentiated in both I well name ( PH) and API number ~ ~ (~0_ _ -_) from records, data and logs i ~ acquired for well ~ SPACING The permit is approved subject to full compliance with 20 AAC EXCEPTION ~ 25.05. Approval to perforate and produce /inject is contingent upon issuance of a conservation order approving a spacing j i I exception. assumes the ~ i liability of any protest to the spacing exception that may occur. i F I ,DRY D[TCH ;All dry ditch sample sets submitted to the Commission must be in SAMPLE I no greater than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals j through target zones. Please note the following special condition of this permit: ~ Non-Conventional ~ production or production testing of coal bed methane is not allowed Well ;for (name of well) until after jCompany Name) has designed and implemented a water well testing program to provide baseline data on water quality and quantity. (Company Name) must contact the !Commission to obtain advance approval of such water well testing 'program. ~ Rev: 12~r06 C:' jody'~transmittal_checklist • • -I ~ N : i rn o N ~, : ' ~ ~ i m D ~, >, ~ o ~ ~ ~ - ~, I ° c ~~ t, , ~ a a I I ~ ~ ~ ~: c y ' ~ m~ ~ .~ N: y: ~ i ~~ ~ (6. ~ ~ O ~~ a, °: ~, ~I ° y, Q a, N s ~ o ~ ~' • ~ - o c O y O > E. E O ~ ~ a Q N O. L: 09 O, ~ 3, ~ -o, v. N N ~. N ~ m , ' ~ i ~ ~, . o d ~ v i t '~ c v, 4 c ° ~ y ~ ~, o ~ ~ Q o: ~ O ~ O N d 1~ m L . W Q ' ~ ~ ~ ~ co. o o. ~ M, M. .~ . •Q 4 ~ ° ~ ~ ~ O ~ . , , ~ ~ : ~ ~ ~ 0' ~ ~ ~ ~ ~ M' ~ .E ~ ~~ ~ 00 ~ ~~ ~ i ~ M: m .. . 4 ~ D a ~ ~ ~~ 0 N ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ t li N~ (6, ~' 'Ulu (0 U ~ ~~ ~ (6 : ui o ~ ~~ ~~ °~ ~ fl, c 3 ~ ~: ~ n 0 ~ ~ ~ ~ . (0 N (0 : f6' Y ~ °~ '7 0 (U ~ ~ ~ _ ~ ~ O, 0. U V, ~: ~: ~: , . ~ CY ~ W (6 j: ~: R ~ , .D N ~ W ~ ' ; A ~~ ~ a Q >- ~ r ~- } ~; r ~ >- ~ , , , , , , , , >-, >-, >-, >~ z, z, z, z z, ; z, z, }, }, ~, ~-, ~, z, >-, >-, r, r, r, ~, z, z z z z z, o' ~: °: ~ ' ~ o. ~ : o o ~~, _ ° U o v (D ~ ~ m. v N~ ~; ' ~ 3. 0 a; : ~~ M : ~: . U J p O ~, a, ~ . ~: N• O• I o` 'c a> is ~ c' > , . , ~ a ~ m; w ~ ~, ~ a .a -o. o. Q, ~ ,~ o. c, o m v, m i m~ ~ r o N m I.. U ~ C. L~ ~ ~ U• N >' 7. ~ ~~ ' ~ ~ a L. ~, ~ E N ~ ~7 p ~ ~ O 7 N d1 ~ W ~ ~ ~ ~ -`O~ ~, C• .0, ~ O• 0, C• 'O f0. N, g ~ ~ ~~ Q C, 0' m. ~ p. O, O 0' ~ ~ d' t. ~ C' C' 0• p 0 OS . . _ ~ ~ E E 'O~ ' C, C ' E ' ' r ~~ N, O. M C C in, , ~ C ~ ~~ ,«N, ~ I- ~ ~ c ~ N. N 0 Q • N L ~ Q. c c O ~ O ~ O O 7 ~ ~ O ° ° m. a~ y o O (n a a' 3 O ~ ° ° mo ~ .-. a U C ~ o. ~, n.. c} '~ O ~ •3 0 0 >' y h m' ~' T a~ 'w ~ c, . c. ~? - o; ~ c Y 4 ° ~: ° 4 a~~ .~ m ~ o' ° ° n c. o: ° c Q Z~ o E~ ° ; • m 4 a~ o~ ~ a .c m' 3' v m' 3 ~ E Q N. ~ °' G 'O, ~„ ~ ~ ~, . °: ca. ~ fl< °~ ~: ~, -° ~ ~ : ~ °: 'O~ E~ v. ~: ~ 4h ~ c: ~, . ~-, a~, ~ °: m o, N Vk L, M ~ ° Q 3, °. o, C 0 ~ : c E , . ~ Y, ° a Q a, ~ n ° o a ~ °> Q ° ° ° ~ ~ o: ° , Q ' ° N ° a ° ~~ ~ ~, o o. ~ ~ m ° ~ o. o. °- ~ w, :?. Y - y: v. ~ ~ ° ~, ~ o O ~ N' ~ ~, ~ m' ~, rn a ~ rn co ; N' " ~: N a c , ~ ~ °' ~: ° ~ ~ ° , ~ . ~ °~ ~ , v i 4 ~ ~? m w~..; ~ , . ~ ~ c of °= m m m ~ m' ° ~ a1 3 2 ~~ o o , o s ~ ~ ~, ~: ~~ ~ . a ~, n : ~ 3' , m , : . a~ : c 3 , : : '~ i ~ o? °' °' T c' ui -Q' •~ °' a~ m ~ Y . ~ w- o .~: -o' •~ , a ~ ~ m ~, c -: -a a -o, a v. ~`~ °' ° ~ n ' m. ~ ~ , , -a ~ a-°i rn ;a N, a~i asi > , , rn ~ r. ~, ~ °' w N. ~ ' , ~ ° ° ~ ~ ~ ~ ~ ii d ° ~: ~, d ~, ~ °, v' °. ° _, c c. • ~ 3' v. ~ a> cu. v ~° m' m' o ~ ui ~ ° _, 3, ~° o ar ' ' t6' o. ~ is c. m. c. $, ~' K H W ~, ~ c 3. m. m. v v so. v ~ ~' o m `o' °' m. ° E , m v w ° ~' ~' . v v. a~, o. o. - - 0 = m ° v ~ ~ co, $ m, °~ ~ a E' = c c~ ° .c' ~' m, o m ~' m ~ ~ m' E' 6 a ~ ~ ~ c ~, c c: ~ H H H •N; ~; a, a; ' ~' >' ' ~ n •~ ' w c ~ N i -. Y a ~ ~ . ~ ~ ~ ' ~ ' , 0 a O ~ a> O o , a' U ~, ~ z i U v' U U ~ ~ ; p , m' m' U U ' ~ ' c i o, ~ ~'i ' a ;a o' , ~' u i ' v' ~ ~ 1 ~ S , ~' ~ , ; ~; Q; a; ; n; , ; ; o ; ¢; r= ¢; , ; ~; ~' i n fti W a Z ' ~ ~ ~ ~ ~ i ~ ~ ~ ~ N M~ M (O I~ W m O M M M I M M ... ~ V ~ _ N -_- M V t! ) -- ___. _. (O __. I~ O O ___. ___... r- _ _._. __.__ - _- .-_ ~ _ N N __-_._ N __.- N N N N N N N M M - _ -__._. - .. __- M _ M M O 0 ~, 0 0 0 0 N °° ~ °~ ~ N ~ ~ N ° W m N C ~ ~ ~ - ~ O' ~• N .~ ~ 0 ~ ~ A J ik ~ Q. cn I C G. ~ `'~ Q. In U W ~ d a a 4 Q ~ W 4 Imo- ~ ~~ °~ C7 Q Q Welf 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 Wetl History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special efifort has been made to chronologically organize this category of information. .. !~ i **** REEL HEADER **** MWD 07/12/03 BHI 01 LIS Customer Format Tape **** TAPE HEADER **** MWD 07/05/06 1419644 01 2.375" CTK *** LIS COMMENT RECORD *** Remark File Version 1.000 Extract File: ldwg.las _Version Information VERS. 1.20: CWL5 log ASCII Standard -VERSION 1.20 WRAP. NO: One line per frame --Well Information Block #MNEM.UNIT Data Type Information STRT.FT 10490.0000: Starting Depth STOP.FT 12670.0000: Ending Depth STEP.FT 0.5000: Level Spacing NULL. -999.2500: Absent Value COMP. COMPANY: BP Exploration (Alaska), Inc. WELL. WELL: D-30B FLD FIELD: Prudhoe Bay Unit LOC LOCATION: 70 deg 17' 45.04"N 148 deg 45' 8.07"W 3625' FSL, 1066' FWL CNTY. COUNTY: North Slope STAT. STATE: Alaska SRVC. SERVICE COMPANY: Baker Hughes INTEQ TOOL. TOOL NAME & TYPE: 2.375" CTK DATE. LOG DATE: 06-May-07 API API NUMBER: 500292264602 --Parameter Information Block #MNEM.UNIT Value Description #--------- ---------------- -------- ------------------------ SECT. 23 Section TOWN.N T11N Township RANG. R13E Range PDAT. MSL Permanent Datum EPD .F 0 Elevation Of Perm. Datum LMF RKB Log Measured from FAPD.F 78.25 Feet Above Perm. Datum DMF RF Drilling Measured From EKB .F 0 Elevation of Kelly Bushing EDF .F 78.25 Elevation of Derrick Floor EGL .F 0 Elevation of Ground Level CASE.F N/A Casing Depth OS1 DIRECTIONAL Other Services Line 1 -Remarks ~~-t~~ '~ r S~-~ 1 (1) All depths are Measured Depths (MD)unless otherwise noted. (2) All True Vertical Depths (SSTVD) are Subsea corrected. (3) All Formation Evaluation data is realtime data. (4) Baker Hughes INTEQ utilized CoilTrak downhole tools and the Advantage surface system to log this well. (5) Tools ran in the string included Casing Collar Locator, an Electrical Disconnect and Circulating Sub, a Drilling Performance Sub (Inner and Outer Downhole Pressure, Vibration and Downhole Weight on Bit), a Directional and Gamma Sub, and a Hydraulic Orienting Sub with a Near Bit Inclination Sensor and Ultra Slim Resistivity Sub. (6) Data presented here is final and has been depth adjusted to PDCL (Primary Depth Control Log from Schlumberger dated 10-May-2007. A block shift of 2.754' was applied from 11925.7 ft.MD to TD. (7) The sidetrack was drilled from D-30A through a milled window in 3- 3/16" liner. Top of window 10496 ft.MD (8966.0 ft.SSTVD) Bottom of window 10501 ft.MD (8965.0 ft.SSTVD) (8) Tied to D-30A at 10486.99 ft.MD (8968.0 ft.SSTVD) (9) Entire resistivity curve was logged during MAD Pass after TD. (10) MWD Runt was used to set the Whipstock. No logging data is presented for this run. (11) The interval from 12635 to 12670 ft.MD (8968.3 to 8968.70 ft.SSTVD) was not logged due to sensor bit offset at TD. MNEMONICS: GRAX -> Gamma Ra y MWD-AAPI [MWD] (MWD-API units) ROPS -> Rate of Penetration, feet/hour TVD -> Subsea T rue Vertical Depth, feet CURVE SHIFT DATA BASELINE, MEASURED, DISPLACEMENT 10498, 10 497.3, ! -0.689453 10509, 10 507.4, ! -1.5498 10560.2, 10560.5, ! 0.34375 10562.6, 10562.4, ! -0.171875 10565, 10 564.8, ! -0.171875 10578, 10 576.6, ! -1.37695 10581.9, 10582.4, ! 0.516602 10587.2, 10586.2, ! -1.0332 10590, 10 590.6, ! 0.688477 10591.2, 10592.9, ! 1.72168 10601.8, 10602.2, ! 0.344727 10620.1, 10619.4, ! -0.688477 10622.7, 10622, ! -0.688477 10624.9, 10624.6, ! -0.34375 10625.9, 10626.5, ! 0.516602 10630.1, 10628.5, ! -1.5498 10632.3, 10631.8, ! -0.516602 10649.2, 10646.3, ! -2.92676 10660.8, 10659.6, ! -1.20508 10682.9, 10682, ! -0.861328 10687.9, 10685.3, ! -2.58301 10689.9, 10688.4, ! -1.54883 10693, 10 692.7, ! -0.344727 10711.8, 10710.6, ! -1.20508 10746.1, 10743.2, ! -2.92676 10749.4, 10748.4, ! -1.0332 10751, 10 750.1, ! -0.860352 10752.9, 10753, ! 0.171875 10756, 10 754.9, ! -1.03223 10758.4, 10757.3, ! -1.0332 10780.3, 10776.7, ! -3.61523 10783.2, 10779.4, ! -3.78711 10787.2, 10784.2, ! -2.92773 10793.9, 10789.7, ! -4.13281 10799.9, 10795.8, 10807.3, 10800.6, 10808.7, 10802.2, 10810.1, 10803.5, 10812.8, 10809.4, 10816.1, 10812.7, 10817.3, 10813.7, 10819.7, 10815.6, 10825, 10820.8, 10826.7, 10822.7, 10828.9, 10825, 10833.2, 10829.8, 10844.9, 10840.8, 10879.1, 10874.6, 10884.8, 10879.9, 10886.3, 10881.7, 10888, 10883.2, 10908.7, 10909.9, 10910.1, 10911.6, 10913, 10914.4, 10919.9, 10919.9, 11004.9, 11010.6, 11009, 11013.1, 11010.9, 11015.7, 11013.1, 11018, 11050.7, 11051.9, 11053.3, 11054.7, 11057.6, 11058.8, 11061.2, 11061.2, 11062.4, 11062.7, 11064.1, 11065.1, 11066.2, 11068, 11069.1, 11068.9, 11070.5, 11069.4, 11071.8, 11071.1, 11074.9, 11075.8, 11077, 11077.9, 11196.2, 11197.5, 11210.3, 11212.5, 11213.4, 11215.2, 11218.9, 11222.1, 11223.3, 11225.4, 11225.2, 11226.8, 11230.2, 11231.1, 11232.8, 11234.5, 11235, 11236.4, 11239.9, 11243.1, 11243.1, 11246.1, 11317, 11314.4, 11320.9, 11316.3, 11323.5, 11324, 11325.8, 11326.1, 11331.1, 11328, 11333.2, 11330.1, 11334.9, 11333, 11339.2, 11334.9, 11340, 11335.7, 11343, 11338.3, 11345.2, 11342.8, 11359.2, 11354.4, 11364, 11361.6, 11375, 11369.9, 11460.9, 11459.9, 11462.3, 11460.9, 11464.9, 11462.1, 11468.2, 11464.4, 11472.1, 11468.5, . f i i i i i i i . ' i i i i -4.13184 -6.71484 -6.54199 -6.54297 -3.44336 -3.44434 -3.61621 -4.13184 -4.13281 -3.95996 -3.95996 -3.44434 -4.13281 -4.47656 -4.82031 -4.64844 -4.82031 1.20508 1.54883 1.37695 0 5.68164 4.13184 4.82129 4.82129 1.20508 1.37695 1.20605 0 0.34375 1.0332 1.89453 -0.172852 -1.0332 -0.689453 0.861328 0.860352 1.37793 2.23828 1.89355 3.27148 2.06641 1.5498 0.861328 1.72168 1.37695 3.27148 2.92773 -2.58301 -4.64941 0.516602 0.344727 -3.09961 -3.09863 -1.89453 -4.30371 -4.30469 -4.64844 -2.41016 -4.82031 -2.41016 -5.16602 -1.0332 -1.37695 -2.75488 -3.78809 -3.61621 11474, 11470.1, ! -3.95996 11476.3, 11472.1, ! -4.13184 11478.7, 11475.9, ! -2.75391 11481.1, 11477.5, ! -3.61621 11507.3, 11506.4, ! -0.861328 11754.1, 11751.7, ! -2.41113 11756.5, 11753.2, ! -3.27148 11760.1, 11756.5, ! -3.61523 11826.3, 11825.3, ! -1.0332 11832.3, 11831, ! -1.37695 11833.5, 11832, ! -1.5498 11835.1, 11833.4, ! -1.72168 11842, 11842.2, ! 0.171875 11854.9, 11860.6, ! 5.68164 11862.5, 11865.6, ! 3.09961 11868, 11873.5, ! 5.50977 11869.9, 11875.3, ! 5.33789 11878, 11879.6, ! 1.54883 11881.1, 11884.4, ! 3.27148 11887, 11889.7, ! 2.75391 11891.1, 11891.9, ! 0.861328 11898.1, 11896.1, ! -2.06641 11899.2, 11897.4, ! -1.72168 11900, 11899.2, ! -0.861328 11907.1, 11909, ! 1.89355 11909.7, 11911.7, ! 2.06641 11912.1, 11913.1, ! 1.0332 11913.3, 11914, ! 0.688477 11915, 11915.5, ! 0.516602 11916.2, 11916.9, ! 0.688477 11918.1, 11920, ! 1.89453 11919.1, 11922.1, ! 2.92773 11921.2, 11924, ! 2.75488 11922.9, 11925.7, ! 2.75488 EOZ END ! BASE CURVE: GROH, OFFSET CURVE: GRAX Tape Subfile: 1 208 records... Minimum record length: 10 bytes Maximum record length: 132 bytes **** FILE HEADER **** MWD .001 1024 *** INFORMATION TABLE: CONS MNEM VALU ------------------------------------ WDFN D-30B 5.xtf LCC 150 CN BP Exploration (Alaska) Inc. WN D-30B APIN FN Prudhoe Bay Unit COUN North Slope STAT Alaska • *** LIS COMMENT RECORD *** !!!!!!!!!!!!!!!!!!! Remark File Version 1.000 The data presented here is final and has been depth shifted to a PDCL of Schlumberger dated 10-May-2007 *** INFORMATION TABLE: CIFO MNEM CHAN DIMT CNAM ODEP ---------------------------------------------------- GR GR GRAX 0.0 ROP ROP ROPS 0.0 RAD RAD RACLX 0.0 RAS RAS RACHX 0.0 RPD RPD RPCLX 0.0 RPS RPS RPCHX 0.0 * FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame Size is: 28 bytes Logging direction is down (value= 255) Optical Log Depth Scale Units: Feet Frame spacing: 0.500000 Frame spacing units: [F ] Number of frames per record is: 36 One depth per frame (value= 0) Datum Specification Block Sub-type is: 1 FRAME SPACE = 0.500 * F ONE DEPTH PER FRAME Tape depth ID: F 6 Curves: Name Tool Code Samples Units Size Length 1 GR MWD 68 1 AAPI 4 4 2 ROP MWD 68 1 F/HR 4 4 3 RAD MWD 68 1 OHMM 4 4 4 RAS MWD 68 1 OHMM 4 4 5 RPD MWD 68 1 OHNIIK 4 4 6 RPS MWD 68 1 OHNIIK 4 4 24 Total Data Records: 122 Tape File Start Depth = 10490.000000 Tape File End Depth = 12670.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = feet **** FILE TRAILER **** Tape Subfile: 2 135 records... Minimum record length: 54 bytes Maximum record length: 4124 bytes **** FILE HEADER **** ! ~ MWD .002 1024 *** INFORMATION TABLE: CONS MNEM VALU -------------------------------- WDFN D-30B.xtf LCC 150 CN BP Exploration (Alaska) WN D-30B APIN FN Prudhoe Bay Unit COUN North Slope STAY Alaska *** LIS COMMENT RECORD *** !!!!!!!!!!!!!!!!!!! Remark File Version 1.000 This file contains the raw-unedited field data. *** INFORMATION TABLE: CIFO MNEM CHAN DIMT CNAM ODEP ---------------------------------------------------- GRAX GRAX GRAX 0.0 ROPS ROPS ROPS 0.0 RACL RACL RACLX 0.0 RACH RACH RACHX 0.0 RPCL RPCL RPCLX 0.0 RPCH RPCH RPCHX 0.0 * FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame Size is: 28 bytes Logging direction is down (value= 255) Optical Log Depth Scale Units: Feet Frame spacing: 0.250000 Frame spacing units: [F ] Number of frames per record is: 36 One depth per frame (value= 0) Datum Specification Block Sub-type is: 1 FRAME SPACE = 0.250 * F ONE DEPTH PER FRAME Tape depth ID: F 6 Curves: Name Tool Code Samples Units Size Length 1 GRAX MWD 68 1 AAPI 4 4 2 ROPS MWD 68 1 F/HR 4 4 3 RACL MWD 68 1 OHMM 4 4 4 RACH MWD 68 1 OHMM 4 4 5 RPCL MWD 68 1 OHMM 4 4 6 RPCH MWD 68 1 OHMM Total Data Records: 243 Tape File Start Depth = 10490.000000 Tape File End Depth = 12670.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = feet **** FILE TRAILER **** Tape Subfile: 3 256 records... Minimum record length: 54 bytes Maximum record length: 4124 bytes **** TAPE TRAILER **** MWD 07/05/06 1419644 01 **** REEL TRAILER **** MWD 07/12/03 BHI 01 Tape Subfile: 4 2 records... Minimum record length: 132 bytes Maximum record length: 132 bytes 4 4 24 r~ ~ ~ Tape Subfile 1 is type: LIS ~ ~ Tape Subfile 2 is type: LIS DEPTH GR ROP RAD RAS RPD RPS 10490.0000 50.7971 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 10490.5000 50.6547 -999.2500 2162.8501 6933.3096 0.5404 93913.0312 10500.0000 317.5266 4.6685 128.4891 427.5729 0.1007 6.1398 10600.0000 34.2485 124.3000 10.2295 10.3959 10.3062 9.5560 10700.0000 176.1306 104.0638 10.2651 9.5304 11.2047 11.7814 10800.0000 125.5825 60.3747 10.5242 10.9610 13.7730 15.2743 10900.0000 189.0910 43.3664 11.2646 11.0772 11.7233 11.0067 11000.0000 23.4464 107.0635 9.3934 8.6000 10.1022 10.3448 11100.0000 23.9026 116.8110 9.3575 9.5717 9.8720 9.1092 11200.0000 29.4247 86.7285 5.1998 4.1352 4.3108 4.0462 11300.0000 27.1581 92.8061 6.2665 5.9395 6.9701 7.4998 11400.0000 31.7100 256.4631 7.4444 6.0979 5.5944 4.7550 11500.0000 18.7984 82.6539 7.6430 6.5041 6.5164 5.8798 11600.0000 26.8000 79.6915 4.4371 3.6627 3.8169 3.6829 11700.0000 26.0915 120.1976 3.8185 2.8914 2.9297 3.0430 11800.0000 25.8793 132.7088 4.9510 4.2876 4.3168 4.0342 11900.0000 18.9336 80.5640 5.7785 5.5122 6.2863 6.5390 12000.0000 21.3198 101.5998 5.9286 5.1246 5.5896 5.4108 12100.0000 182.6384 50.2380 8.4214 10.1348 13.1810 15.8128 12200.0000 51.3399 66.3399 10.3131 10.9911 8.6064 6.9667 12300.0000 32.4594 70.0399 6.6460 7.4734 9.6118 11.8730 12400.0000 88.7589 63.4385 4.7456 4.7780 12500.0000 35.0599 58.5168 5.4854 6.6173 12600.0000 32.2801 125.1436 6.1138 6.3182 12670.0000 -999.2500 36.1182 -999.2500 -999.2500 Tape File Start Depth = 10490.000000 Tape File End Depth = 12670.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = feet • 4.5820 4.3108 4.7194 -999.2500 4.6596 4.5596 5.5245 -999.2500 Tape Subfile 3 is type: LIS DEPTH GRAX ROPS RACL RACH RPCL RPCH 10490.0000 50.5000 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 10490.2500 50.6250 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 10500.0000 56.5000 1.0000 2162.8501 6933.3096 0.1430 5.4080 10600.0000 31.7000 124.3000 9.9570 9.6880 10.2390 9.5560 10700.0000 181.6000 109.8000 10.1110 9.4830 11.1100 11.7260 10800.0000 91.5000 76.3000 10.5120 10.2920 13.2050 14.5520 10900.0000 192.4000 45.4000 10.5470 11.5880 11.6980 11.5640 11000.0000 36.5000 93.9000 9.4630 9.1400 9.9620 9.6490 11100.0000 24.0000 136.1000 9.4910 9.8260 9.8720 9.1940 11200.0000 29.7000 85.3000 5.2050 4.1860 4.2900 3.9980 11300.0000 32.6000 94.8000 6.3320 5.8340 7.1560 7.7790 11400.0000 27.6000 1724.3999 7.1150 5.5200 5.4160 4.7060 11500.0000 20.4000 95.0000 7.6220 6.5370 6.4580 5.7800 11600.0000 26.8000 84.6000 4.4460 3.9070 3.9660 3.8630 11700.0000 25.6000 97.5000 3.7090 5.1850 4.0900 4.6710 11800.0000 26.8000 123.9000 5.0150 4.3000 4.2620 3.8590 11900.0000 16.5000 48.0000 5.7420 5.4560 6.2550 6.5390 12000.0000 20.1000 94.9000 6.5730 5.6200 5.9280 5.4970 12100.0000 149.8000 60.4000 7.5220 11.1450 13.5060 17.4500 12200.0000 53.7000 56.0000 10.1450 9.8500 8.7250 7.2940 12300.0000 26.2000 66.0000 6.4820 7.0650 9.3550 12.7260 12400.0000 105.7000 33.1000 5.2660 5.4970 12500.0000 29.6000 78.8000 7.3990 9.7690 12600.0000 35.9000 85.0000 8.1530 5.9540 12670.0000 -999.2500 -999.2500 -999.2500 -999.2500 Tape File Start Depth = 10490.000000 Tape File End Depth = 12670.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = feet 4.4400 4.9850 5.6600 -999.2500 5.1160 5.5220 8.3550 -999.2500 ~ ~ Tape Subfile 4 is type: LIS
