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Home My WebLink About203-141 e e Image Project Well History File Cover Page XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. ~ 03 - L Lf L Well History File Identifier Production Scanning Stage 1 Page Count from Scanned File: 'J-Q- (Count does include cover sheet) Page Count Matches Number in sc. a7in~ j'eparation: L YES BY: ~ Date:3 7106 Stage 1 If NO in stage 1, page(s) discrepancies were found: YES Organizing (done) D Two-sided II 111111111" 111111 RESCAN ~olor Items: o Greyscale Items: DIGITAL DATA D Diskettes, No. D Other, No/Type: D Poor Quality Originals: D Other: NOTES: BY: ~ oateÔ/7/0 ¿, , I oate3/7!Ob I I ~X30= 0 Project Proofing BY: ~ Scanning Preparation BY: Date: BY: Maria Date: Scanning is complete at this point unless rescanning is required. D Rescan Needed "I II 111111" "1111 OVERSIZED (Scannable) D Maps: D Other Items Scannable by a Large Scanner OVERSIZED (Non-Scannable) D Logs of various kinds: D Other:: m£ III 1111111111'/111I mE Isl Isl III 11111111111/1111 NO J~ VY1 P NO Isl III 11111111I11 1111I ReScanned BY: Maria Date: Isl Comments about this file: III II 111111 1111111I Quality Checked 11111111I111111111I 10/6/2005 Well History File Cover Page.doc • ti OF Ti 0 w . I7j, s v THE STATE Alask. Oil and Gas 1 „ALASKA Conservation Commission GOVERNOR SEAN PARNELL 333 West Seventh Avenue *.R OF ALASJ. � OR 2 2 2.013 Anchorage, Alaska 99501 -3572 CqNNE� Main: 907.279.1433 M Fax: 907.276.7542 John McMullen Engineering Team Leader ' o , / 1 BP Exploration (Alaska), Inc. P.O. Box 196612 Anchorage, AK 99519 -6612 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU G -12B Sundry Number: 313 -121 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 Commission grants for good cause shown, a person affected by it may file with the Commission 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, Cathy P. • erster Chair DATED this 4-Z of March, 2013. Encl. STATE OF ALASKA D D 3(zZJ . ALA OIL AND GAS CONSERVATION COM ION s,;,L, 1 ' 2, ;4 APPLICATION FOR SUNDRY APPROVAL 20 AAC 25.280 A 0 G CC 1. Type of Request: ❑ Abandon ® Plug for Redrill • ❑ Perforate New Pool ❑ Repair Well ❑ Change Approved Program ❑ Suspend ❑ Plug Perforations ❑ Perforate ❑ Pull Tubing ❑ Time Extension ❑ Operations Shutdown ❑ Re -Enter Suspended Well ❑ Stimulate ❑ Alter Casing ❑ Other 2. Operator Name 4. Current Well Class 5. Permit To Drill Number BP Exploration (Alaska) Inc. ❑ Exploratory ❑ Stratigraphic 203 -141 • 3. Address: ® Development. ❑ Service 6. API Numbe P.O. Box 196612, Anchorage, Alaska 99519 -6612 50.029- 20597 -02 -00 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? PBU G -12B• Will planned perforations require a Spacing Exception? ❑ Yes N o 9. Property Designatior 10. Field / Pool(s): ADL 028280• 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• • 11360' 9053' • 11325' 9048' • 10486', 10650' None Casing Length Size MD TVD Burst Collapse Structural Conductor 110' 20" x 30" 110' 110' Surface 2672' 13 -3/8" 2672' 2672' 4930 2670 Intermediate 9721' 9 -5/8" 9721' 8443' 6870 4760 Production Liner 574' 7" 9212' - 9786' 8044' - 8494' 8160 7020 Liner 2138' 3 - 1/2" x 3 - 3/16" x 2 - 7/8" 9222' - 11360' 8052' - 9053' Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): • 9784' - 11310' 8493' - 9045' 7 ", 26# x 4 - 1/2 ", 12.6# L - 80 9279' Packers and SSSV Type: 9 - 5/8" Baker Packer Packers and SSSV • 9169' / 8011' MD (ft) and TVD (ft): 12. Attachments: 13. Well Class after proposed work: • _! Description Summary of Proposal ® BOP Sketch • ❑ Detailed Operations Program ❑ Exploratory ❑ Stratigraphic ® Development. ❑ Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operation March 25, 2013 ❑ Oil ❑ WINJ ❑ WDSPL ❑ Plugged 16. Verbal Approval: Date ❑ Gas ❑ GINJ ❑ GSTOR ❑ Abandoned Commission Representative: ❑ WAG ❑ SPLUG ® Suspended • 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Matt Ross, 564 -5782 Printed Name: John , n Title: Engineering Team Leader E ail: rossmo @bp.com Signature: / Phone: 564 - 4711 Date: ) 8 l3 i Commission Use Only Conditions of approval: Notify Commission so that a representative may witness �1 ( Z Sundry Number: ❑ Plug Integrity al BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance Other: .5 'frs � 35 I) .; - A 111'1'11 aft 11/ 0laCt�r� p2' r 2 0 �},-- �� 1.12- /C Spacing Exception Required? ❑ Yes [7 ' No Subsequent Form Required: /G — 4 c / RBDMS MAR 2 2 0 APPROVED BY Approved By: 0/ 76eA COMMISSIONER THE COMMISSION Date: 3 22_ 7� For 0 3 e ise L 0 01 Approved application is valid for 12 months from the date of approval VL r— 3120/3 Submit In Duplicate d //, 1 'ti • • • To: Alaska Oil & Gas Conservation Commission From: Matthew Ross by CTD Engineer Date: March 8, 2013 Re: G -12B Sundry Approval Sundry approval is requested to plug the G -12B perforations as part of drilling and completion of proposed G -12C coiled tubing sidetrack. History and current status: G -12B was drilled as a CTD sidetrack to its current location in Sept -2003. Multiple interventions over the last few years to reduce GOR have had limited success. Currently, G -12B is shut -in because of high GOR and there are no remaining non -rig intervention options to return the well to competitive status. Proposed plan: Sidetrack G -12B to the G -12C location using Nordic 2 Coiled Tubing Drilling rig on or around April 25 2013. The G -12C sidetrack will exit the existing 3- 3/16" liner and kick off in Zone 3 and land in Zone 2. This sidetrack will be completed with a 2 -3/8" L -80 liner in the production interval and cemented in place. This Sundry covers plugging the existing G- 12B perforations via the G -12C primary liner cement lob and a liner top packer if the liner lap pressure test fails (alternate plug placement per 20 AAC 25.112(i)). The following describes the work planned and is submitted as an attachment to Form 10 -403. A schematic diagram of the proposed sidetrack is attached for reference. n � --e / / /79s reamer lbeee ® G% to Sc,cirvr E7 t4 / PivC r , . coq w ( , ti tS Cy& 1iafr d !�P /.�If7 COvf /9 p /eat; �GY�� 60 3 t r ee ,„„ 5 5 0 a O no rAd cf r� 0 '1'0411 f OF Fec �' w�eh 5 ► '� , S,dcl( r�h'x wec 01' , i ie A f-or i, i ' oV e d `e co VQ'�, Niftc • • Required Permit? Rig ork (s eduled to begin March 25th, 2013) 10 -403 PTD 1. S Drift for 3- 3/16" packer whipstock to 10,200' MD No No 2. E Set 3- 3/16" packer whipstock at 10,140' MD. No No 3. E Jet cut at 9240' MD (3 -1/2" liner below deployment sleeve) No No 4. S Fish deployment sleeve and 3 -1/2" liner No No 5. S Drift for new deployment sleeve No No 6. V Set TWC No No 7. V PT MV, SV, WV No No 8. 0 Bleed well and flowlines to zero No No 9. 0 Remove wellhouse and level pad No No Fr A- Required Permit? Rig Work (scheduled to begin April 25th, 2013) 10;41/4,, P ! 1. MIRU and test BOPE 250 psi low and 3,500 psi high. Yes No 2. Mill 2.74" window at 10,140' and 10' of rathole. No Yes 3. Drill build: 3.25" OH, 560' (23 - 25 deg DLS planned) No Yes 4. Drill lateral: 3.25" OH, 1385' (12 deg DLS planned). No Yes 5. Run 2 -3/8" liner leaving TOL at 9,214' MD No Yes 6. Pump primary cement job: 9.5 bbls, 15.8 ppg, TOC at 10,125' Yes* Yes 7. Perform liner cleanout and MCNL /GR /CCL log No Yes 8. Test liner lap to 2400 psi. No Yes T 1� 9. Perforate liner based on log interpretation ( - 200') No Yes 10. Freeze protect well to 2500' MD No Yes 2 / 3'D 11. Set BPV; RDMO No Yes * Approved alternate plug placement per 20 AAC 25.112(i) Post -Rig Work: 1. Re- install wellhouse, flowline and pull BPV. 2. Set liner top packer with slickline as needed if failed liner lap pressure test in Rig Work step 8 above. 3. Perform nitrogen lift to kick -off well. Matthew Ross CTD Engineer 564 -5782 CC: Well File Joe Lastufka i 1 TREE 'z McEVOY 6" • WELLHEAD= McEVOY • •AFETYNOTES: I , ACTUATOR = OTIS G - 12 B I KB. ELEV = 65.72' BF. ELEV = 37.2' KOP = 9780' Max Angle 93 @ 10855' I 2094' H 7" OTIS SSSV LAND NIP, ID = 5.962" I Datum MD = 10253' Datum TV D = 8800' SS 2574' 1-19-5/8" DV COLLAR' 13 -3/8" CSG, 72 #, L -80, ID = 12.347" I-1 2672' II 0 0 3088' H 35' WFD TBG PATCH (09/14/06), ID = 3.90" I Minimum ID = 2.441" @ 10669' •1 1: ( 3103' I-I TUBING PUNCH HOLES I 3- 3/16" x 2 -7/8" XO o 0 17" TBG, 26 #, L -80 U4S, IPC, .0382 bpf, ID = 6.276" H 9150' I 9149' H 7" PBR SEAL ASSY I 1 ► I 9169' 1-19-5/8" BKR PKR, ID = 4.75" I 9 169' -{ 7" X 4-1/2" XO, ID = 3.958" I TOP OF 7" LNR H 9212' ni ' I 9212' H 4-1/2" OTIS X NIP, ID = 3.813" I 'TOP OF 3- 3/16" & 2 -7/8" LNR H 9214' ELM I 1 9222' -13 -1 /2" BKR DEPLOY SLV, ID = 3.00" I I I 9231' 1-13-1/2" HES X NIP, ID = 2.813" I I 9242' 1-13-1/2" X 3- 3/16" XO, ID = 2.786" I ' I 9245' I- 4 -1/2" OTIS XN NIP, MILLED OUT ID = 3.725" BEHIND 14-1/2" TBG, 12.6 #, .0152 bpf, ID - 3.958" I-1 9277' I 9277' H 4-1/2" WLEG, ID = 3.958" I LINER ■ I 9266' I-1 ELMD TT LOGGED 06/07/82 I 19 -5/8" CSG, 47 #, L -80, BTRS, ID = 8.671" H 9720' I WHIPSTOCK (09/ ? ?/03) H 9780' MILLOUT WINDOW (G -12B) 9785' ' - 9792' PERFORATION SUMMARY REF LOG: MCNL /CCL /GR ON 09/29/03 • 10486' H 3-1/2" CIBP (07/09/10) I ANGLE AT TOP PERF: 37° 9784' Note: Refer to Production DB for historical perf data a,.. /," � 4:t;i* a SIZE SPF INTERVAL Opn /Sqz DATE � -Iv :V 2" 2 9784 - 9794 0 12/24/08 �� % ' 2" 6 9794 - 9824 0 12/24/08 'a. ' , , ,t.I a 106 — I CIBP (08/09/07) I 2" 6 10570 - 10595 C 08/11/07 "Ilea ■-• , ∎ �� 2" 4 10710 - 11180 C 09/29/03 Ili um• •-■ 10699' I- 3- 3/16" X 2 -7/8" XO 2" 4 11250 - 11310 C 09/29/03 Ir (TM/ LSL), ID = 2.441" t IT LNR, 29 #, L -80, .0371 bpf, ID = 6.875" H 10745' 3- 3/16" LNR 6.2 #, L -80, 10699' .0076 bpf, ID = 2.805" a. 12-7/8" LNR, 6.16 #, N-80, FL4S, ID = 2.347" I-J 11715' • I PBTD I—I 11325' / 12-7/8" LNR, 6.16, L -80 STL, .0058 bpf, ID = 2.441" I—I 11360' I. DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 07/12/81 ORIGINAL COMPLETION 09/14/06 TEL/THL SET TOP ASSY PATCH WELL: G -12B 07/17/96 CTD SIDETRACK (G -12A) 08/16/07 RLM/PJC SET CIBP/ ADPERF (08/09/07) PERMIT No: '2031410 09/30/03 JLM/TLH CTD SIDETRACK (G -12B) 08/17/07 SRB /PJC REPERF ( 08/11/07) API No: 50- 029 - 20597 -02 08/28/06 RRD /PAG PULL BTM ASSY PATCH (07/03/I 6)1/13/09 MV /SV ADPERF (12/24/08) SEC 12, T11 N, R13E, 2334' FNL & 2367' FEL 08/31/06 RRD /PAG RESET BTM ASSY PATCH 07/11/10 WEC/SV SET CIBP (07/09/10) 09/05/06 CJN/PJC PULL FISH @ 3119' BP Exploration (Alaska) . . TNT - At FvOy 6- 0 WELLHEAD , ht EVOY G-1 2C SAFETY NOTES: ACTUATOR= OTIS kW Et_EV = 65.727 Proposed CTO Sidetrack 8,F uiv - 372 • KOP - 9780" H u Angle = /3 g. 10855 —1 2094' Hr ons sssv ....AfEbtsV, ID = 5 MT 1025 DM= tvia = 3' 0 011WITI WO= 8800' SS , = 2574. - 9 5M* rAl COLLAR I 13 3/8* CSC, 7 . 80,10 1.,' ..4/' 1 .. 2872' _ , r 3088' -Pi WM 1 Pik, T CA ■ (M1 4,0C; ID 3 40 ■:.■ Minimum ID = 2441" @ 10669 1 T3103 - I-41111\6 PUNCH 1 Ps 9149' 1 SCA L ASSY 1 3-3/16" x 2-7/8" XO C:4 7' 1G. 200. 140 U4S, IM, .0382 bpf. Ds 9.274* 9160' 'soar - 13 - 1 , 2* OUP (07/0 I rcp 119:318 aKR ria D ,-- 4 75' , 9189 x 4-1/r x0, ID - 3.953 I TOP OFT L1 }-r r • I L 9212' 1-F-112 . 0TO x fir. 1, - 5 ai a' TOP or 2- 3,13 LP - 1 ... 9214' F‘ I ,.._ , Cheat o 3-3/16 liner I , i • 9245' 3 ' , IL 14712:—IAIIED°11s= IT 73:729 1 BEHND 44/2' 180, 12,89, .0152 bp1:13 6 3 H oar farr r I , ----- ---I ar 1 n=ster " UNER 1121_fo .... _J -LELAI) T LOGGED 0607W �C3 474 -80, BIT-IS , U=8871' ,-1 9720' II/VHPSTOCK (09/77103)1-1 9780' I FTRFORAT1ON SUMVIARY TD a 12 pss• TO C at10 ,125 T D REF LOG: LOUCCUGR ON 09129103 1 , .,( Tc w 1- a•1:_.-1:: M: ANGLE AT TOP PIT+ 3T (9 9784' 0 -, _—. - , - .. Nme: Refer to Producbcn 08 for historical data - :41'i annta.- SIZE SW INTIRVAL (141/Saz DATE !..14:, r:-1 2' 2 9734 - 9/94 0 12/24108 7 ■N r ed 4 410411 • 40,1{,. 01 1 r e, 4114% 2' 6 9704 - 9824 0 12/24/08 - . j$4*, r 6 10510- 10595 C 08111107 i " t44 a . , \ '...41. taw - 1N {c 2' 4 10710 - 11180 C 0929103 .;;;slie iir • \:, . z , ;,, : 44 I r. to r 4 11250 ,. 11310 C 0E929/03 'A,, \ "41*-• ...011 10600" 34118' X 2,7/84 xo \ * II (INY Lel), IDA 2-441' • .1. ...OA 7 7" Lt4R, 299,140, 03/1 W 1) - 6 8 /ft' - -- 10745' / 1 3-3/1E* Lift 6.2& LAO, - 10699 : I is. N.. ! 0076 bpi, 13 - 2.805* 12-7/8' LNR 6 164, 480, FL49, 1) . 2 347" 1- 11715` FWD 11326 ; 12 7/9* LW, 6 16 L 80 SIT: ,005116pf, 11)* 2.441 11360' rA f f Try FL 1 COMM WIT ' WV BY COMM:NTS PRUDHOE BAY UNIT ■ 0712181 1 01;10 NAL COMPLETION 09/14 Taffit SIT TOP ASSY PATCH WELL* G 0717+ ,CTD siDETRACK (G-12AI 08/16/07 RLY11 sO CUFF A01-441- {084)9i0 /) FERMI Nb '031410 09/30/03 JILMITIN CT() SIDETRACK (G0214 06/17/07 SRB/PJC REPERF i, 0&1 107) API Kt. 50 38/26)(16 F94:11/AG RH BIM ASSY PATO1 (07/03/C 01/13/09 IN/S'/ A 111:14. 112/24/08) SEC 12, 111N, R13E, 2334 FNL 8 2387 FEL ■ NORDIC CTD UNIT # 2 CHOKE / REEL / CIRCULATION MANIFOLD DIAGRAM in r _i Cho e Penel Standoioe 2' Circulation Line I Driller Gaune� _• .M10 :a: M MMB MM9 ! Manual Choke r ®? C I CIRCULATING MANIFOLD — • • • • - MM 1B O R' I MM 15 •a aka , I SLB Transducer n .'. Nil Sensor .— I _• - MM7•Y• I Baker Choke snasnears all MM 13 MM ■■ MM17 KILL SIDE MANUAL VALVE Hain :zcomue: CHOKE SIDE I MANUAL VALVE #� �• KILL MCR I Rev C r Line II f / CHOKE MCR I f Air Blow down * ... MM74 �:.' 1 1. �. . — ' aWli"' . o.rxr 8. °� r .. ' f a i — .; rwa f VI � - I III A Choke One I Coked Tubing — i . • _ - ar9skf ravra ^l7Bi:^1Id T:'i'r": 1/ 9 ommim____ simeT I I Ba. rChoke Uuime % I, I I M P2 , MPI :a: • I ♦ eT1 '. Iii I J I- Kill Llne R FA V I d BOP 18 I HP 11 HP 10,.. Tranducers COILED TUBING I I / ,- BOP 17 _I I } CIRCULATING SYSTEM I O � . , I I- HP 18 I ... HP 14 P19 HP I To Inner Reel I ,. Valve HP 18 HP7 HP5 HPd 111.3 IT il — HP13 _ _ _ _ _ g I I .. I _ _ ■ ws I I HP 12 HP 2 HP 1 ..." A ! HP 18 / / cement line N2 SLB / / I CHOKE MANIFOLD - - - _. I HP 17 N2 TriFlow Si A •/ CM BS MOB - • •i �-�. Gaune I . - I CM 2B ' CHOKE LINE x' OAS BUS : • . . •I• I -- Teat Pump Inlet — CM 30 / ? � -- . . . .. .. .. I (4 CM] / .pg��@p I � Jt ../. / X. RBA PHI .... """- I 4Wav Block CM14 C Flow 9 HC' / _ N M1 / CMB CM34 - — I thud IMF CMS CMG _ _ I PB2 - leg is I _ 0' 9 Baker Choke Line a a a a a a .. Ugh J I I- from wal — -� - CHOKE LINE I CM13 • • I I I — CM2 POSSUM BELLY CM28 CM21 • CMI oeo C rr • I _ M�cio • CM20 / CHOKE LINE Tank I Mill . • . �a'rT � •yvd moll ♦di• e / — CM18 CM19 _ ID CM27 / - -- TIGER TANK .�. / , _ b / I / 4 • Page l of 1 Subject: FW: INTENT PLUG for RE -DRILL WELLS: Corrected From: Davies, Stephen F (DOA) Sent: Monday, February 08, 2010 10:52 AM To: Foerster, Catherine P (DOA); McMains, Stephen E (DOA); Schwartz, Guy L (DOA); Saltmarsh, Arthur C (DOA); Aubert, Winton G (DOA) Subject: RE: INTENT PLUG for RE -DRILL WELLS: Corrected Revised procedure with an additional step per Cathy's comment: INTENT PLUG for RE -DRILL WELLS (IPBRD) Type Work Code in RBDMS / 1. When a Form 10 -403 is submitted requesting approval to plug a well for redrill, the initial reviewer (Art or Steve D.) will check to make sure that the "Plug for Redrill" box in the upper left corner of the 403 form is checked. If the "Abandon" box is checked, we will cross that erroneous entry out and initial it on f both copies of the Form 10 -403 (AOGCC's and operator's copies). / 2. On the Form 10 -403 if "Abandon" is checked in Box 15 (Well Status after proposed work), Art or Steve D. will cross that erroneous entry out and initial it on both copies of the Form 10 -403 (AOGCC's and operator's copies). Instead, we will check the "Suspended" box. Guy and Winton will serve as quality control for steps 1 and 2. 3. When Steve McMains receives the Form 10 -403 with a check in the "Plug for Redrill" box, he will enter the existing code "IBPRD" into RBDMS. This code automatically generates a comment under the History tab stating "Intent: Plug for Redrill." 4, When Steve McMains receives any Form 10 -407, he will check the History tab in RBDMS for this comment. If he sees the "Intent: Plug for Redrill" code, and cannot find any evidence that a subsequent re -drill has been COMPLETED, he will assign a status of SUSPENDED to the well bore in RBDMS, no matter what status is listed on the 10 -407. Steve will also change the status on the 10 -407 form to SUSPENDED, and will date and initial his change. If Steve does not see the "Intent: Plug for Redrill" comment or code, he will enter the status listed on the Form 10 -407 into RBDMS. 5. When the Form 10 -407 for the redrill is received, Steve M. will change the original well's status from suspended to abandoned. 6. The first week of every January and July, Steve M. and Steve D. will check the "Well by Type Work Outstanding" user query in RBDMS to ensure that all of the Plug for Redrill wells have been handled properly. At this same time, Steve M. and Steve D. will also review the list of suspended wells for accuracy. Thanks, Steve D. T___. ..___..___..\TTt ' «DD TIDT A /t /')f11') i • bp BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB -20 Post Office Box 196612 Anchorage, Alaska 99519 -6612 May 18, 2 a 2012 0 y Mr. Jim Regg 54.,ANIIIEDAuc 0 7 2012 Alaska Oil and Gas Conservation Commission 333 West 7 Avenue Anchorage, Alaska 99501 g■d0 Subject: Corrosion Inhibitor Treatments of GPB G -Pad d^ Dear Mr. Regg, Enclosed please find multiple copies of a spreadsheet with a list of wells from GPB Pad G that were treated with corrosion inhibitor in the surface casing by conductor annulus. The corrosion inhibitor is engineered to prevent water from entering the annular space and causing external corrosion that could result in a surface casing leak to atmosphere. The attached spreadsheet represents the well name, API and PTD numbers, top of cement depth prior to filling and volumes of corrosion inhibitor used in each conductor. As per previous agreement with the AOGCC, this letter and spreadsheet serve as notification that the treatments took place and meet the requirements of form 10 -404, Report of Sundry Operations. If you require any additional information, please contact me or my alternate, Gerald Murphy, at 659 -5102. Sincerely, p� Mehreen Vazir BPXA, Well Integrity Coordinator • • BP Exploration (Alaska) Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10 -404) G-Pad Date: 03/05/2012 Corrosion Initial top of Vol. of cement Final top of Cement top off Corrosion inhibitor/ Well Name PTD # API # cement pumped cement date inhibitor sealant date ft bbls ft na gal G -01A 1931710 50029202140100 3.0 _ NA 3.0 NA 10.2 5/10/2010 G -02B 2081580 50029202170200 0.5 NA 0.5 NA 2.6 5/10/2010 G -03A 1970700 50029202210100 0.7 NA 0.7 NA 6.0 5/27/2010 G-04B 2061400 50029202250200 0.1 NA 0.1 NA 1.7 5/10/2010 G -05 1780970 50029203510000 0.0 NA 0.0 NA 0.0 5/10/2010 G -06A 2060120 50029203580100 0.6 NA 0.6 NA 5.1 5/12/2010 G -07 1790180 50029203590000 0.5 NA 0.5 NA 3.4 5/11/2010 G -08A 2061830 50029205810100 0.1 NA 0.1 NA 0.9 5/27/2010 G -098 2071100 50029205820200 9.0 NA 9.0 NA 69.7 5/20/2010 G -10C 2060090 50029205530300 0.9 NA 0.9 NA 8.5 3/5/2012 G -118 2080270 50029205830200 0.0 NA 0.0 NA 0.0 5/21/2010 .-°! G -12B 2031410 50029205970200 0.5 NA 0.5 NA 2.6 5/13/2010 G -13A 2001630 50029206000100 0.0 NA 0.0 NA Trace 5/12/2010 G -14B 2090680 50029206460200 0.7 NA 0.7 NA 5.1 5/22/2010 G -15B 2080650 50029206470200 26.0 4.0 0.5 7/16/2011 3.4 7/19/2011 G -16A 2090560 50029206430100 0.0 NA 0.0 NA Trace 5/22/2010 G -17A 2060760 50029206190100 21.4 4.0 0.6 7/16/2011 3.4 7/19/2011 G -18A 1990320 50029206200100 71.7 14.0 1.0 7/16/2011 8.5 7/19/2011 G -19B 2071240 50029215990200 0.0 NA 0.0 NA Trace 5/22/2010 G -21 1951540 50029226040000 0.5 NA 0.5 NA 3.4 5/12/2010 G -238 2091440 50029216800200 0.5 NA 0.5 NA 4.3 5/11/2010 G -24A 2060820 50029216710100 0.1 NA 0.1 NA 0.9 5/11/2010 G -25B 2070860 50029216520200 5.3 NA 5.3 NA 23.8 5/28/2010 G -26B 2050480 50029216610200 2.0 NA 2.0 NA 6.8 5/11/2010 G -27A 2070310 50029216460100 0.5 NA 0.5 NA 2.6 5/30/2010 G -296 2101410 50029216500200 2.8 NA 3.0 NA 17.0 5/13/2010 G -30C 2091510 50029216130300 1.0 NA 1.1 NA 5.1 5/30/2010 G -31B 2090310 50029216160200 0.8 NA 0.8 NA 6.0 5/21/2010 G -32A 1970010 50029216360100 0.8 NA 0.8 NA 3.4 5/21/2010 To: AOC~C Christine Mahnken 333 W. 7th Ave Suite 100 Anchorage, Alaska 99501 (907] 793-1225 RE : Cased Hole/Open Hple/Mechanical Logs and/or Tubing Inspection(Caliper/ MTT] The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the following BP Exploration (Alaska), Inc. ~~ Petrotechnical Data Center , ~ ,_ /~/ Attn: Joe Lastuflca LR2 - 1 ~. ~~ (~ 900 Benson Blvd. ~ Z Anchorage, Alaska 99508 _~- and ProActive Diagnostic Services, Inc ~, ~. Attn: Robert A. Richey v .:: ~,,,;,~`~~'.~ ~~' ~~. 4`` ~~~"; ~S~ 130 West International Airport Roa~"'J~`'~ ~ `(S~ , Suite C 1~~v Anchorage, AK 99518 Fax: (907) 245952 1 ] LeakDetection - WLD 04Apr~09 F-24 Color Log / E[~ 50-029-21030-00 2) Production Profile 24-Mar-09 G12~ Color Log / ~?E .; 5597=02 Signed : Date Print Name: PROACTIVE DIAGNOSTIC SERVICES, INC., 130 W. INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245-8951 Fax: (907)245.88952 E-malt.. ~ - WEesrrE : cr C:\Docutuents end Settings\Ownet\Desktop\TYensini[_liP.docx K~GEiV~® • ~~ ~ STATE OF ALASKA ~~~ 3 ALA OIL AND GAS CONSERVATION COM~ION ~ ZOO$ REPORT OF SUNDRY WELL OPERATI~y~ Oil & Gac r,,.,~ ~___ 1. Operations Abandon ~ Repair Well ~ Plug Perforations ~ Stimulate ~ Ot~i~r C Performed: Alter Casing ~ Pull Tubing ~ Perforate New Pool ~ Waiver Time Extension ~~8 Change Approved Program ~ Operat. Shutdown ~ Perforate Q Re-enter Suspended Well 2. Operator BP Exploration (Alaska), Inc. 4. Current Well Class: 5. Permit to Drill Number: Name: Development r Exploratory ~~ 203-1410 3. Address: P.O. Box 196612 Stratigraphic ~ Service 6. API Number. Anchorage, AK 99519-6612 50-029-20597-02-00 7. KB Elevation (ft): 9. Well Name and Number: 65.7 KB PBU G-12B . 8. Property Designation: 10. Field/Pool(s): ADLO-028280 PRUDHOE BAY Field/ PRUDHOE OIL Pool 11. Present Well Condition Summary: Total Depth measured 11360 feet Plugs (measured) None true vertical 9052.79: feet Junk (measured) None Effective Depth measured 11325 feet a~r~ ~y P1~ true vertical 9048 feet Casing Length Size MD TVD Burst Collapse Conductor 110 20" 91.5# H-40 39 - 149 39 - 149 1490 470 Surface 2634 13-3/8" 72# L-80 38 - 2672 38 - 2672 4930 2270 Production 9683 9-5/8" 47# L-80 37 - 9720 37 -8442 6870 4760 Liner 573 7" 29# L-80 9212 - 9785 8044 - 8494 8160 7020 Liner 20 3-1/2" 9.3# L-80 9222 - 9242 8052 - 8067 10160 10530 Liner 1457 3-3/16" 6.2# L-80 9242 - 10699 8067 - 9036 8520 7660 Liner 661 2-7/8" 6.16# L-80 10699 - 11360 9036 - 9053 13450 13890 Perforation depth: Measured depth: SEE ATTACHED - _ _ _ _ True Vertical depth: _ _ _ _ Tubing: (size, grade, and measured depth) 7" 26# L-80 27 - 9169 4-1/2" 12.6# L-80 9169 - 9277 Packers and SSSV (type and measured depth) 7" Arrow PAC Packer 3091 7" Arrow PAC Packer 3107 7" Baker Packer 9169 0 0 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: ~ L jp,j~ ~ "~ j~(~~ 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing pressure Prior to well operation: SI Subsequent to operation: „~ ~ ° 14. Attachments: 15. Well Class after proposed work: copies of Logs and surveys Run Exploratory Development Service Daily Report of Well Operations X 16. Well Status after proposed work: Oil r' ' Gas WAG ~ GINJ ~ WINJ ~ WDSPL 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: N/A Contact Gary Preble Printed Name Gary Pre I Title Data Management Engineer Signature Phone 564-4944 Date 12/29/2008 runic iv-wvw r~CVJtiCU V'+/LVVO auuiiui viiyniai vn~y G-12B 203-141 PERF ATTACMENT C~ Sw Name Operation Date Pert Operation Code Meas Depth Top Meas Depth Base Tvd Depth Top Tvd Depth Base G-12B 9/29/03 PER 10,710. 11,180. 9,036.75 9,037.09 G-12B 9/29/03 PER 11,250. 11,310. 9,037.64 9,045.47 G-12B 8/9/07 APF 10,590. 10,595. 9,011.64 9,013.02 G-12B 8/11/07 APF 10,570. 10,595. 9,006.18 9,013.02 G-12B 8/31/07 BPS 3,118. 11,310. 3,116.62 9,045.47 G-12B 12/23/08 APF 9,804. 9,814. 8,508.38 8,516. G-12B 12!23/08 APF ~ 9,814. ~/' 9,824. 8,516. 8,523.47 G-12B 12/24/08 APF 9,784. 9,794. 8,492.73 8,500.62 G-12B 12/24/08 APF 9,794. 9,804. 8,500.62 8,508.38 AB ABANDONED PER PERF APF ADD PERF RPF REPERF BPP BRIDGE PLUG P ULLED SL SLOTTED LINER BPS BRIDGE PLUG SET SPR SAND PLUG REMOVED FCO FILL CLEAN OUT SPS SAND PLUG SET FIL FILL SQF SQUEEZE FAILED MIR MECHANICAL ISOLATED REMOVED SQZ SQUEEZE MIS MECHANICAL ISOLATED STC STRADDLE PACK, CLOSED MLK MECHANICAL LEAK STO STRADDLE PACK, OPEN OH OPEN HOLE C~ G-12B DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY ACTIVITYDATE SUMMARY 12/23/2008 ""`WELL SHUT-IN ON ARRIVAL, SSV OPEN, INITIAL PRESSURES ~ ~ 1500/150/0. SSV OPEN.*"" RIH, SHOT INTERVAL FROM 9804-9824 FT (IN TWO RUNS AS PER PE) 'WITH L 2" PJ HSD 2006 HMX, 6 SPF. SURFACE AND VISUAL 'CONFIRMATION OF GUN FIRING. 3***JOB IN PR ,CONTINUED ON 24-DEC-2008 WSR*""* 12/24/2008**"JOB CONTINUED FROM 23-DEC-2008."** (PERFORATED 9794'-9804' WITH 2" 6SPF 60 DEG PHASED PJ2006 GUN. ALSO SHOT 9784'-9794' WITH 2 SPF 60 DEGREE PHASED PJ2006. LOADED ONLY PHASE ONE AND TWO OF GUN, LEFT OTHER FOUR BLANK AS PER PROGRAM. ALIGNED WPPT TOOL ZERO TO SLPIT THE MIDDLE OF THE 60 DEGREE LOADED PHASES. ORIENTED GUN TO 27.1 DEGREES RIGHT OF HIGH SIDE LOOKING DOWN HOLE TO AVOID SHOOTING THROUGH WHIPSTOCK. SHOT PHASES WERE AT 3 DEGREES LEFT OF HIGH SIDE AND 57 DEGREES RIGHT OF HIGH SIDE. ALL SHOTS FIRED. FINAL PRESSURES WERE T/I/O = 1800/150/0. DSO NOTIFIED WELL LEFT SHUT-IN, OF VALVE POSITION AND READY TO POP. j ~***JOB COMPLETE"** __ __ FLUIDS PUMPED BBLS 1 diesel 1 Total - STATE OF ALASKA ~v~~ ALAS~IL AND GAS CONSERVATION COMMI~N . VED '~U~ ~ 6 2007 REPORT OF SUNDRY WELL OPERATIONS ~~aska Dil & Gas Cons 1. Operations Abandon ~ Repair Well ~ Plug Perforations ~ Stimulate ~ Other ~ QpChnrana -~~ Performed: Alter Casing ~ Pull Tubing ~ Perforate New Pool ~ Waiver ~ Time Extension ~ Change Approved Program ~ Operat. Shutdown ~ Perforate Q' Re-enter Suspended Well [~ 2. Operator BP Exploration (Alaska), Inc. 4. Current Well Class: 5. Permit to Drill Number: Name: De~elopment ~ Exploratory ~ 203-1410 ~ 3. Address: P.O. Box 196612 Stratigraphic ~ $eCVICe ~ 6. API Number: Anchorage, AK 99519-6612 50-029-20597-02-00 ~ 7. KB Elevation (ft): 9. Well Name and Number: 65.7 KB ~ PBU G-12B ~ 8. Property Designation: 1Q. Field/Pool(s): ADLO-028280 ` PAUDHOE BAY Field/ PRUDHOE OIL Pool ~ 11. Present Well Condition Summary: Total Depth measured 11360 ~ feet Plugs (measured) None true vertical 9052.79 ~ feet Junk (measured) None Effective Depth measured 11325 ' feet true vertical 9048 feet Casing Length Size MD ND Burst Collapse Conductor 80 20" 91.5# H-40 30 - 110 30 - 110 1490 470 Surface 2643 13-3/8" 72# L-80 29 - 2672 29 - 2671.93 4930 2670 Liner 20 3-1/2" 9.3# L-80 9222 - 9242 8051.73 - 8067.19 10160 10530 Production 9692 9-5/8" 47# L-80 28 - 9720 28 - 8441.7 6870 4760 Liner 573 7" 29# L-80 9212 - 9785 8044 - 8493.53 8160 7020 Liner 1457 3-3/16" 6.2# L-80 9242 - 1069y 8067.19 - 9035.61 Liner 661 2-7/8" 6.16# L-80 10699 - 1136n 9036 - 9053 13450 13890 Perforation depth: Measured depth: 10570 - 11310 ca~5 ~^~~,~}\ /~;~,y~~~~~~ ~~ -''" "~\'Z True Vertical depth: 9006 - 9045 = ~~ Tubing: (size, grade, and measured depth) 7" 26# L-80 27 - 9169 4-1/2" 12.6# L-80 9169 - 9277 Packers and SSSV (type and measured depth) 9-5/8" BAKER PKR 9169' _. ... .. . ....,_ _. 0 0 0 0 0 0 12. Stimulation or cement squeeze summary: Intervals treated (measured): i~-; ~~ ~~Gfi ^` L ' `' ' i ;l ~ ~, ~ ° ~+#«»~ .. ~ ~ ~t t , ? ~Y 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: 730 57400 11 0 1067 Subsequent to operation: 0 0 0 0 0 14. Attachments: 15. Well Class after qroposed work~ Copies of Logs and Surveys Run Exploratory ~ Development ~ Service ~ Daily Report of Well Operations X 16. Well Status after proposed work: Oil ~ Gas ~ WAG ~' GINJ ~ WINJ ~ WDSPL ~ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: N/A Contact Gary Preble Printed Name Gary Preble ,,- Title Data Management Engineer Signature -° Phone 564-4944 Date 8/13/2007 ' ion ~ ..,~„ ~., ~..~ ~ ~~.~~~~ ~„~~.,V i ~ ~ V ~ , 1 ~ 1~r `' "`. " L y, C~~ „u~~~~~....~~y~~~a~ .,~~~y ,. a, , hi1U '~ C? ,. . . J~er g~(o~ ~ ~ G-12B DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY 8/10/2007~CTU #8, Add Perf; MIRU. MU WFD MHA. Standby for SLB TCP personnel to `complete job on Nordic. ConY on WSR 8/11/07 ... 8/11/2007;CTU #8, Perf; Cont' from WSR 8/10/07...waiting on TCP. TCP hand on location at ;0050; PJSM. MU and RIH with perforating assembly. Correct depth to bottom shot °"at CIBP. Fire 25' of perf guns (2" OD PJ 2006 HMX 6 spf 60 degree phasing) over `tl interval 10570-10595' MD (ref: SLB CNL 09/29/03). POH. Confirm all shots fired. Recover ball at surface. Turn well over to Pad Operator to POP. RDMO CTU #8. ~Job Complete. FLUIDS PUMPED BBLS 44.4 50/50 MeOH 44.4 TOTAL • • -~.._ --_ -~. MICROFILMED 03/01 /2008 DO NOT PLACE :.,_ ~_ ,o . ~~ ,.~.: ;: -. F~, ..t ~_ ANY NEW MATERIAL UNDER THIS PAGE F:~LaserFiche\CvrPgs_Inserts~lVticrofilm_Marker.doc ,-= ---- "-- STATE OF ALASKA _I OCT 1 0 2006 ALASKA OIL AND GAS CONSERVATION COMMISSION C C ., n REPORT OF SUNDRY WELL OPERA Tlð~il & 2::hO;::~ ommlsSIO 1. Operations Performed: AbandonD Alter Casing 0 Change Approved Program 0 Repair WellŒJ Pull TubingD Operation ShutdownD PluÇJ Perforations D Perforate New PoolO Perforate 0 Stimulate 0 WaiverO OtherD Time Extension 0 Re-enter Suspended WellO 5. Permit to Drill Number: 203-141 6. API Number 50-029-20597-02-00 2. Operator Name: 3. Address: BP Exploration (Alaska), Inc. 4. Current Well Class: Development [!] ExploratoryO P.O. Box 196612 Anchorage, Ak 99519-6612 7. KB Elevation (ft): StratigraphicO Service 0 9. Well Name and Number: G-12B 10. Field/Pool(s): Prudhoe Bay Field / Prudhoe Oil Pool 65.70 8. Property Designation: ADL-028280 11. Present Well Condition Summary: Total Depth measured 11360 feet true vertical 9053.0 feet Plugs (measured) None Effective Depth measured 11325 feet Junk (measured) None true vertical 9048.0 feet Casing Length Size MD TVD Burst Collapse CONDUCTOR 110 20" 91.5# H-40 39 149 39.0 149.0 1490 470 SURFACE 2634 13-3/8" 72# L-80 38 - 2672 38.0 - 2672.0 4930 2270 PRODUCTION 9683 9-5/8" 47# L-80 37 - 9720 37.0 - 8442.0 6870 4760 LINER 573 7" 29# L-80 9212 - 9785 8044.0 - 8494.0 8160 7020 LINER 20 3-1/2" 9.3# L-80 9222 - 9242 8052.0 - 8067.0 10160 10530 LINER 1457 3-3/16" 6.2# L-80 9242 - 10699 8067.0 - 9036.0 8520 7660 LINER 661 2-7/8" 6.16# L-80 10699 - 11360 9036.0 - 9053.0 13450 13890 Perforation depth: Measured depth: 10710-11180, 11250-11310 ~CANNE[) OCT ~ 1 2005 ç} True vertical depth: 9037-9037,9038-9045 Tubing ( size. grade. and measured depth): 7" 26# L-80 @ 34 9169 4-1/2" 12.6# L-80 @ 9169 9277 Packers & SSSV (type & measured depth): 7" Patch @ 3091 3121 9-5/8" Baker Packer @ 9169 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: RBDMS 8Ft 0 CT 1 1 2006 Prior to well operation: Subsequent to operation: Oil-Bbl SI SI Representative Daily Averaqe Production or Iniection Data Gas-Mef Water-Bbl Casing Pressure 13 o o o o Tubing Pressure o o ~ 15. Well Class after proposed work: ExploratoryD 16. Well Status after proposed work: OilŒJ GasD DevelopmentŒ] ServiceD 14. Attachments: Copies of Logs and Surveys run _ Daily Report of Well Operations _ WAG D GINJD WINJD WDSPLD Prepared by DeWayne R. Schnorr (907) 564-5174. Sundry Number or N/A if C.O. Exempt: N/A 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact DeWayne R. Schnorr ::::::ame ;;;;:~~ Form 10-404 Revised 4/2004 CJ-N -, G-'· \l A I Title Petroleum Engineer Phone 564-5174 Date 10/9/06 G-128 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY 09/14/2006 TIIIO = 100/200/40. Assist E-Line Pumped 40 bbls crude down Tbg. Final WHP's = 100/220/40. 09/1412006 SET WEATHERFORD ARROW-PAK PATCH UPPER PACKER ASSEMBLY, TOTAL TOOL STRING 42.6' IN LENGTH. TOTAL PATCH LENGTH = 35.44', MINIMUM 10 = 3.90", MID ELEMENT OF UPPER PACKER ASSEMBLY SET AT 3091' TIIIO = 100/20010 09113/2006 T/I/O= 100/250/20. Temp= SI. AlL= 720 psi (SI at the casing valve). WHP's (pre-patch). TP increased 80 psi, lAP decreased 190 psi and OAP unchanged since 09-05-06. 09/06/2006 TIIIO= SSV/250/20. Temp= SI. WHP's, IA FL (pre TIFL). AIL line SI @ IA casing valve. IA FL @ 618'. 09/05/2006 T/I/O= 201440/20 Assist SIL CMIT- TxlA to 2500 psi. [PASSED] Bled pressures down. Final WHP= 400/300/20. 09105/2006 ** WELL SHUT IN UPON ARRIVAL ** {fish e-line/patch} PULLED E-LlNE FISH FROM 3093' SLM. SET CAT STANDING VALVE AND WEATHERFORD TEST TOOL @ 3,107' SLM, CMIT WI LRS TO 2500 PSI GOOD TEST, PULLED CAT STANDING VALVE AND TEST TOOL. ***TURNED WELL OVER TO PAD OP, LEFT SHUT IN*** 08/31/2006 SET WEATHERFORD 7" PATCH. LOG CORRELATED TO PATCH SETTING RECORD FROM 8-APR-2006. INTENTIONALLY PULLED OFF DUE TO PARTIAL SET AND I OR NOT SHEARING OFF LOWER ANCHOR SECTION AFTER FIRING. WILL SEND SCHEMATIC TO SLlCKLlNE PE FOR FISHING OPERATIONS. ***** JOB NOT COMPLETE***** 08/22/2006 T/I/O=50/350/10, Temp=SI. TBG & IA FL (pre-patch). TBG FL @ 162', IA FL @ 1032'. FLUIDS PUMPED BBLS 2 Diesel --- PT Surface Equipment 40 Crude 42 TOTAL Page 1 ( TREE = WELLHEAD = ACTUATOR = lB.-ELEV = SF. REV = KOP= Max Angle = Datum MD = Datum TV D = r-kEVOY 6" McEVOY OTIS 65.72' 37.2' 9780' 93 @ 10855' 10253' 8800' SS I 13-3/8" CSG, 72#, L-80, ID = 12.347" 1--1 2672' Minimum ID = 2.441" @ 10669' TOP OF LINER 17" TBG, 26#, L-80, LJ4S, IPC, .0382 bpf, 10 = 6.276" 1--1 9169' G-12B ~NOTES: . 2094' 1--1 7" OTIS SSSV LAND NIP, ID = 5.962" 1 ~ j 2574' 1--1 9-5/8" DV COLLAR 1 ID ~ ~ g ~ 3091'-????'I-1WFDTBG PATCH (09/14/06), ID = 3.90" 1 I 3103' l-f TUBING PUNCH HOLES 1 ~ g ~ 9149' 1--1 7" PBR SEAL ASSY 1 .:x ~ 9169' 1-1 9-5/8" BAKER A<R, 10 = 4.75" 1 ~ [- 9169' 1-1 7" x 4-1/2" XO 1 9212' 1-1 4-1/2" OTIS X NIP, ID = 3.813" 1 - ~ H 9222' 1-1 3-1/2" BKR DEPLOY SLV, 10 = 3.00" 1 9231' 1-1 3-1/2" HES x NIP, ID = 2.813" 1 9242' 1--1 3-1/2" x 3-3/16" XO, ID = 2.786" 1 J . I 9245' 1- 4-1/2" OTIS XN NIP, MILLED our ID = 3.725" (BEHIND LNR) \ I 9277' l-f 4-1/2" WLEG (BEHIND LNR) 1 I 9266' l-f ELMD TT LOGGED 06/07/82 (BEHIND LNR) I TOP OF 7" LNR 1-1 9212' TOP OF 3-3/16" &2-7/8" LNR 1--19214' ELM 1 4-1/2" TBG, 12.6#, .0152 bpf, ID = 3.958" l-f 9277' ~ 9-5/8" CSG, 47#, L-80, BTRS, 10 = 8.671" 1--1 9720' ~ 1 WHIPSTOCK (09/7?/03) 1---1 9780' I ÆRFORA TION SUMMA.RY REF LOG: MCNUCCUGR ON 09/29/03 ANGLE AT TOP ÆRF: 86 @ 10710' Note: Refer to Production DB for historical perf data SIZE SPF INTERV AL Opn/Sqz DA TE 2" 4 10710 - 11180 0 09/29/03 2" 4 11250 - 11310 0 09/29/03 7" LNR, 29#, L-80, .0371 bpf, ID = 6.875" 1--1 I 2-7/8" LNR, 6.16#, N-80, FL4S, ID = 2.347" DA TE REV BY COMMENTS 07/12/81 ORIGINAL COMPLETION 07/17/96 CTD SIDETRACK (G-12A) 09/30/03 JLM/TU" CTD SIDETRACK (G-12B) 06/07/05 KDClTLH GLV C/O 03/17/06 JUITLH PATCH PULLED (03/10/06) 04/17/06 RRD/PAG SEf BTM ASSY PATCH (04/08/06) MILL our WINDOW (G-12B) 9785" - 9792' I 10699' 1- 3-3/16" x 2-7/8" XO (TI\III LSL), 10 = 2.44" 3-3/16" LNR, 6.2#, L-80, -f .0076 bpf, ID = 2.805" PSTD 1--1 11325' 2-7/8" LNR, 6.16, L-80 STL, .0058 bpf, ID = 2.441" 1---1 DATE 08/28/06 08/31/06 09/05/06 09/14/06 REV BY RRD/PA G RRD/PA G CJNlPJC TEL/TLH COMMENTS PULL BTM ASSY PATCH (07/03/06) RESET BTM ASSY PATCH PULL FISH @ 3119' SET TOP ASSY PATCH PRUDHOE BA Y UNIT WELL: G-12B ÆRMIT No: 2031410 API No: 50-029-20597-02 SEC 12, T11 N, R13E, 2334' FNL & 2367' FEL BP Exploration (Alaska) · e WELL LOG TRANSMITTAL -f c9o?J-- 14 ¡ To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West ih Ave., Suite 100 Anchorage, Alaska 99501 February 17, 2006 t 8500 RE: MWD Formation Evaluation Logs G-12B, The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Rob Kalish, Sperry Drilling Services, 6900 Arctic Blvd., Anchorage, AK 99518 907-273-3500 G-12B: LAS Data & Digital Log Images: 50-029-20597 -02 1 CD Rom ô~ .11~~ \Ò(p '$ü ð~ DATA SUBMITTAL COMPLIANCE REPORT 12/5/2005 Permit to Drill 2031410 Well Name/No. PRUDHOE BAY UNIT G-12B Operator BP EXPLORATION (ALASKA) INC S,v.l.. ~O ~~ API No. 50-029-20597-02-00 MD 11360 /' TVD 9053 ~ Completion Date 9/30/2003 /' Completion Status 1-01L Current Status 1-01L UIC N -~-~------ Dire~ Yes J- ----_._-~~~~~._-- REQUIRED INFORMATION Mud Log No Samples No --.---.-.-.---- ---~--_._--- - -.- ------.---------- DATA INFORMATION Types Electric or Other Logs Run: SGRC, GR, EWR, MGR, CCL, CNL Well Log Information: (data taken from Logs Portion of Master Well Data Maint Electr Digital Dataset Log Log Run Interval OH/ Med/Frmt Number Name Scale Media No Start Stop CH Received Comments C Tf 13023 Neutron 9150 11318 Case 2/28/2005 MCNL ------------¡ V Directional Survey 9700 11360 10/10/2003 I~ASC 12264 LIS Verification 8977 11306 Open 11/24/2003 Neutron 2 Blu 8976 11308 Case 11/24/2003 Compensated Neutron Log - Memory GRlCCUCNL Casing collar locator 2 Blu 8976 11308 Case 11/24/2003 Compensated Neutron Log - Memory ~ GRlCCUCNL Las 12274 Casing collar locator 8742 9774 Case 10/6/2003 ~ Indl:lGtieR/RÐsislivity ~ t..:~~ ~~ ~__ LJ~...) 9770 11359 Open 12/8/2003 ~ RatA of P';¡RetFBtion 977~ 1135::1 1~/R/?nn::\ ~ Leak 2 Slu 9150 11318 Case 2/3/2005 mem borax log/mem gr, eel, en' Well Cores/Samples Information: Sample Interval Set Name Start Stop Sent Received Number Comments . . DATA SUBMITTAL COMPLIANCE REPORT 12/5/2005 Permit to Drill 2031410 Well Name/No. PRUDHOE BAY UNIT G-12B Operator BP EXPLORATION (ALASKA) INC API No. 50-029-20597-02-00 MD 11360 TVD 9053 Completion Date 9/30/2003 Completion Status 1-01L Cu rrent Status 1-01 L UIC N ADDITIONAL INFORMATION Well Cored? ~ Chips Received? ry / N - Daily History Received? 'QyN 1iJN Formation Tops Analysis Received? ~ ~-_.._---_._-".- o~ \~'-~ ~fJ~~~ ,~\N\~:l¿~ ß.'^t, 'f'\~ bi') ~. RV-~~"L~ ~L ç::'u0?..ú ~ Co ----þ--------..-. --_._"_._.__.._._"-~._"--~ ___0___.__--- ~~ <.. ~ ~sAJ ~)S-Òiì J À. ~~-J~------ fo..I'W\o.w e ~r7 I~ . Comments: -~---- Compliance Reviewed By: Date: . ¿::?-¡ /ú? ¡::-:>J ,~7 -/~/ 02/28/05 Schlumberger NO. 3354 Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Helen Warman 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay . Color ,~q; \ ['10 lð~ Well Job # LOQ DescriDtion Date Blueline Prints CD ~¿ D.S. 07-03A 10715406 MCNL 06/03/04 1 -1c.f.'Í K-10B 10715402 MCNL 05/16/04 1 (:.-017 D.S.02-15A 10715404 MCNL 05/18/04 1 -lt~- D.S.18-13A 10715395 MCNL 04/16/04 1 .¡tj{- G-12B 10715391 MCNL 03/21/04 1 µ( D.S. 05-26A 10715420 MCNL 08/19/04 1 1 Wf 15-04A 10715374 MCNL 01/14/04 1 1 -t)'j~ 18-02A 10621764 RST 02/23/64 1 1 O~:..c 18-04B 10708056 RST 03/05/04 1 1 -{)11Í L 1-01 10913000 USIT 12/25/04 1 -i-:R- L5-17 10900124 USIT 11/30/04 1 -Zit H-18 10703975 RST 02/17/04 1 1 r9 2-62/Q-17 10900129 RST 12/24/04 1 1 '}f' L5-15 10708050 RST 02/07/04 1 1 L5-15 10563129 RST 11/15/03 1 1 ~ L5-15 10672368 RST 04/16/04 1 1 ~ L5-15 10913848 RST 09/26/04 1 1 , E-17 10703983 RST 04/09/04 1 1 / G-15A 10679055 RST 02/02/04 1 J 1 V n ;¿OJ '1, i-1? 203 1.0{- ,;&:3 rqs: .{t£- (}5 ('6<3 ¡ '.' 1 ('¡'- ¡8t. PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Date Delivered: ~?Þ5 I Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2 .38 ATTN: Beth . f1 !t£~~ Receive J !07S~ ,.""J> .' ,- Sc~luIIIblPgep ?1Ð3 - /if 01/24/05 NO. 3318 Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 A TIN: Beth Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Helen Warman 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay .. Color Well Job# Loa Description Date Blueline Prints CD .2()'fJ-:lf( G-12B 10715391 MCNL 03/21/04 1 1rDJ'¡ i (, 5-318 ;)...&T· ìqLJ 10728396 MCNL 04/03/04 1 D-04B 10715393 MCNL 04/07/04 1 DS 18-13A 10715395 MCNL 04/16/04 1 203-1'15 K-10B 10715402 MCNL 05/16/04 1 DS 02-15A 10715404 MCNL 05/18/04 1 'J..c;t - J 2 S DS 2-33A 10670016 MCNL OS/23/04 1 . ¡ 9j..~ DS 07 -03A 10715406 MCNL 06/03/04 1 ~-¡ql. DS 07 -29C 10715407 MCNL 06/04/04 1 1lfð/2: E-15B 10861913 MCNL 06/05/04 1 ~';ðl DS 18-27C 10715410 MCNL 06/13/04 1 f¡f:-CC(l E-24B 10861916 MCNL 06/20/04 1 'i0q DS 18-31 10715413 MCNL 07/05/04 1 -110 K-09C 10861920 MCNL 07/16/04 1 ~'O'ltf C-17B 10715418 MCNL 08/10/04 1 f'1~·r1t4 C-39 10715421 MCNL 08/19/04 1 Prints'--' onlv-Job not complete) PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 ~}s Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-283 ATTN: Beth · Date Delivered: ... . STATE OF ALASKA .. ALAS~IL AND GAS CONSERVATION CO.SSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: SuspendD Operation ShutdownO WaiverD Abandon D Perforate D OtherD Alter Casing D Repair WellŒ Plug PerforationsD Stimulate D Time Extension 0 Change Approved Program D Pull TubingD Perforate New Pool D Re-enter Suspended Well 0 2. Operator 4. Current Well Class: 5. Permit to Drill Number: Name: BP Exploration (Alaska), Inc. 203-1410 Development Œ ExploratoryD 3. Address: P.O. Box 196612 6. API Number Anchorage, Ak 99519-6612 Stratigraphic D Service D 50-029-20597-02-00 7. KB Elevation (ft): 9. Well Name and Number: 65.70 G-12B 8. Property Designation: 10. Field/Pool(s): ADL-028280 Prudhoe Bay Field / Prudhoe Oil Pool 11. Present Well Condition Summary: Total Depth measured 11360 feet true vertical 9052.8 feet Plugs (measured) None Effective Depth measured 11325 feet Junk (measured) None true vertical 9047.7 feet Casing Length Size MD TVD Burst Collapse Conductor 80 20" 91.5# H-40 30 - 110 30.0 - 110.0 1490 470 Liner 573 7" 29# L-80 9212 - 9785 8044.0 - 8493.5 8160 7020 Liner 20 3-1/2" 9.3# L-80 9222 - 9242 8051.7 - 8067.2 10160 10530 Liner 1457 3-3/16" 6.2# L-80 9242 - 10699 8067.2 - 9035.6 Liner 661 2-7/8" 6.16# L-80 10699 - 11360 9035.6 - 9052.8 13450 13890 Production 9692 9-5/8" 47# L-80 28 - 9720 28.0 - 8441.7 6870 4760 Surface 2643 13-3/8" 72# L-80 29 - 2672 29.0 - 2671.9 4930 2670 Perforation depth: Measured depth: 10710 -11180,11250 -11310 True vertical depth: 9036.75 - 9037.09,9037.64 - 9045.47 RECEiVED Tubing ( size, grade, and measured depth): 7" 26# L-80 @ 26 - 9169 5-1/2" 17# L-80 @ 3091 - 3107 , FE B 7 9 2004 Packers & SSSV (type & measured depth): 7" Arrow PAC Packer @ 3091 7" Arrow PAC Packer @ 3107 PJi3$l{e em & Gas r.nn", (,^_ 7" Baker Packer @ 9169 12. Stimulation or cement squeeze summary: t1J1~ -~"'''' , t Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13 Representative Dailv Averaae Production or Iniection Data Oil,Bbl I Gas-Met I Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: New Well, No Prior Production 150 Subsequent to operation: 3452 I 1.77 I 61 150 287 14. Attachments: 15. Well Class after proposed work: ExploratoryD DevelopmentŒ Service D Copies of Logs and Surveys run _ 16. Well Status after proposed work: Operational Shutdown 0 OilŒ GasD WAGD GINJD WINJD WDSPLD Daily Report of Well Operations. X Prepared by Garry Catron (907) 564-4657. 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: Contact Garry Catron N/A Printed Name Garry Catron Title Production Technical Assistant Signature fi /', A, C·h=. Phone 564-4657 Date 2/10/04 " II L~~~' E:iF rrrE'~ c): :~ìfr1';;ì ¡ 'I'~ . !re.r ~ Form 10-404 Revised 12/2003 ,r.:o.' k . . G-12B DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY 10/09/03 ***WELL SHUT IN ON ARRIVAL*** (PRE PATCH) RUN BRUSH AND 5.94" GAUGE RING TO CLEAN UP OBSTRUCTION @ 1635' SLM DRIFT W/ DUMMY WEATHERFORD PATCH (5.938" O.D. X 6') TO 3250' SLM (NO PROBLEMS) 10/10/03 A 7" ARROW PAC PATCH (POGLM) WAS SET FROM 3091'-3107' (ELEMENT TO ELEMENT) WITH A GL MANDREL W/ A DUMMY VALVE -1" BK LATCH. LOG WAS CORRELATED TO SCHLUMBERGER" TUBING PATCH DETECTION" DATED 10-0CT-98. 10/13/03 T/I/O = 0/1960/0, TEMP = S/I. IA FL (DIAGNOSE HYDRATES). IA FL @ 125'. 10/14/03 Change out Station 1 Dummy Valve with S/O Dual Flow Orifice Valve (24 & 28 Port Size). FLUIDS PUMPED BBLS : TOTAL No Fluids Pumped o Page 1 "TREE = McEV OY 6" ., ¡'sAFETY NOTES: I WELLHÐ\D- M: BI OY G-12B ACTU/\ TOR = 011S KB. B..EV - 65.72' BF. B..EV = 37.2' KOP= 97BO' fltax Anqle - 93 @ 10855' 2094' 7' OTIS SSSV LAND NIP, ID = 5.962" Datum rvD = 10253' . Datum TVD- 8800' SS 0 2574' 9-518" rJ./ COLLA R I 0 !!J I I 13-3/8" CSG, 72#, L-80, ID = 12.34 T' 2672' j ~ -13091'-3107' PA TCH (1 0/1 0103), ID = 2.99" I I ~ W GAS LIFT MANDRELS "- ISTI fv[) I lVD I DEVI 1YPE IVLVILATælPORfI DATE ~ 1 I 3091 I 3090 1 9 1 WFD 1 SO" 1 BEK I "" 110/14/03 Minimum ID = 2.441" @ 10669' t ""DUAL FLOW ORIFICE WITH 24 & 28 PORT TOP OF LINER ~ "\ 3103' 1UBINGPUNCHHOLES I ì 9149' T' A3R SEAL ASSY I 9169' 1'5< Ie 9169' 9-518" BAKER PKR, ID - 4.75" I 7" TBG, 26#, L-80, U4S, IPC, .0382 bpf, 10 = 6.726" \ --I 9169' 7' x4-1/2"xOI I TOPOF7" LNR 9212' I . 9212' 4-1/2" OTIS X NIP,IO =3.813" I !!!!! I TOP OF 3-3/16" & 2-7/8" LNR 9214' ELM. 9222' - 3-1/2" BKR OEA..OY SlV, 10 = 3.00" I ~ - 9231' - 3-1/2" I-ES X NIP, D = 2.813" . I 9242' - 3-1/2" X 3-3116" XO, 10 - 2.786" 1 9245' - 4-1/2" 011S XN NIP, MILLEDOvr 10=3.725" (BEHNO LNR) I 4-1/2"18G,12.6#,1.5646bpf,10=3.958" 9277' 927T -1 4-1/2" WLffi (BEHNOLNR) I I 9266' H B..rvD TT LOGGEO 06107182 (BEHNO LNR) I I 9-518" CSG, 47#, L-BO, BTRS, 10 = 8.671" 9720' 1---4 ~ I WHIPSTOCK (09/??103) H 9780' I I I MILLOvr WINDOW (G-12B) 9785" - 9792' PERFORATION SUMv1ARY REF LOG: MCf'..I.../CCLlGR ON 09/29/03 ANGLEATTOP ÆRF: 86 @ 10710' J\bte: Refer to Production OB for historical Jerf data SIZE SPF INTERIf AL OpnlSqz CV\ TE 2" 4 10710-11180 0 09/29/03 2" 4 11250-11310 0 09/29/03 ~ 1 0699' 3-3/16" X 2-7/8" XO (TIW LSL), D = 2.44" "'¡Q2~ I 7" LNR, 29#, L-BO, .0371 bpf, 10 = 6.875" 10745' I I 3-3/16" LNR, 6.2#, L-80, -1 10699' I I .0076 bpf,lD =2.805" 2-7/fr' LNR, 6.16#, N-BO, R...4S, 10 = 2.347" 11715' r ì A3ID 11325' I 2-7/8" LNR, 6.16, L-BO STL, .0058 bpf, 10 = 2.441" 11360" I CV\ TE REV BY CO Mv1 ENTS OATE RBI BY COMv1ENTS PRUOI-k)E BAY LNIT 07/12/81 ORIGINAL COMPLErION WELL: G-12B 07/17/96 CTD SIDErRACK (G-12A) PERfvIT J\b: 2031410 09130103 JLM /TL~ CTD SlDErRACK(G-12B) API J\b: 50-029-20597-02 10/12/03 CJS/llP GLV PA TCH (POGLM) SET SEe 12, T11 N, R13E, 2334' FNL & 2367 FB.. 10/14/03 JCM/llH GLV C/O 12/29/03 JBM/PAG 10 CORREeTON 8P Exploration (Alaska) ~ . . ()03 -~/LII WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Howard Okland 333 West 7th Avenue, Suite 100 Anchorage, Alaska December 08, 2003 RE: MWD Formation Evaluation Logs G-12B, AK-MW-2669096 1 LDWG formatted Disc with verification listing. ~I#: 50-029-20597-02 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Rob Kalish 6900 Arctic Blvd. Anchorage, Alaska 99518 BP Exploration (Alaska) Inc. Petro-Technical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Signed:' é\..;'-.kU~~~~) \.~ìY"'. Date: RECEIVED DECO 8 2003 Ala.. 0/1 &: G$S G<ms. G<>mmitøif.!o M¡;:h~ .. f~~b~~ --""" ---------.. ~~~\'i\~ ~~ Schlumberger Alaska Data & Consulting Services 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Beth Well P1-02A ~)( h -r l t"J.....V) G-12B ~,;.. -'4 \ D.S. 5-02Ä ,~r \ t. ~ 1- \ D.S. 5-16B '\ ~ -ì - . ê:\ (") E-14A ! L, -¡ -\ ~.~ P1-06 1~ to - l """)-T' P1-09 ,c r ÍI -- I h l-.¡ Job# 10672311 10563472 10558550 10558555 10560299 10674382 10560312 Log Description RST-SIGMA MCNL MCNL MCNL RST -SIGMA RST-SIGMA RST-SIGMA PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Petrotectnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, AI~~ka995{)8 Date Delivered: RECEIVED NOV 24 2003 Þ-þA¥.f; 0!1 & Gas (;()ns. (;ommÎ88ÌOn Andtomge 11/11/03 NO. 3028 Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Lisa Wee pie 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay Color . Date Blueline Prints CD 09/14/03 1 1 .....-; 'J -... 09/29/03 1 1 roU 06/10/03 1 1 ¡..>., 06/16/03 1 1 of/; 09/12/03 1 1 10/04/03 1 1 ' v -,< 10/15/03 1 1 "i i" .c L e= Schlumberger GeoQuest 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Beth Received ~cJ "-....I.~D\C ~~~IY\. _ STATE OF ALASKA _A ALAS~ AND GAS CONSERVATION COM"'WION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1a. Well Status: 181 Oil o Gas o Plugged o Abandoned o Suspended o WAG 1b. Well Class: 20AAC 25.105 20AAC 25.110 181 Development o Exploratory OGINJ OWINJ o WDSPL No. of Completions One Other o Stratigraphic o Service 2. Operator Name: 5. Date Comp., Susp., or Aband. 12. Permit Number BP Exploration (Alaska) Inc. 9/30/2003 203-141 3. Address: 6. Date Spudded 13. API Number P.O. Box 196612, Anchorage, Alaska 99519-6612 9/20/2003 50- 029-20597-02-00 4a. Location of Well (Governmental Section): 7. Date T.D. Reached 14. Well Number Surface: 9/27/2003 PBU G-12B 2334' SNL, 2367' WEL, SEC. 12, T11N, R13E, UM 8. Elevation in feet (indicate KB, DF, etc.) 15. Field and Pool Top of Productive Horizon: 1380' SNL, 739' WEL, SEC. 11, T11N, R13E, UM KBE = 65.70' Prudhoe Bay Field / Prudhoe Bay Total Depth: 9. Plug Back Depth (MD+ TVD) Pool 1908' SNL, 191' WEL, SEC. 11, T11 N, R13E, UM 11325 + 9048 Ft 4b. Location of Well (State Base Plane Coordinates): 10. Total Depth (MD+TVD) 16. Lease Designation and Serial No. Surface: x- 657854 y- 5969307 Zone- ASP4 11360 + 9053 Ft ADL 028280 --~-- 11. Depth where SSSV set 17. Land Use Permit: TPI: x- 654183 y- 5970185 Zone- ASP4 Total Depth: x- 654742 y- 5969668 Zone- ASP4 (Nipple) 2094' MD 19. Water depth, if offshore 20. Thickness of Permafrost 18. Directional Survey 181 Yes ONo NI A MSL 1900' (Approx.) 21. Logs Run: SGRC, GR, EWR, MGR, CCL, CNL 22. CASING, LINER AND CEMENTING RECORD CASING SETTING DEPTH HOLE SIZE WT.PER-FT. GRADE lOP BOTTOM SIZE CEMENTING RECORD AMOUNT PULLED 20" x 30" Insulated Conductor Surface 110' 36" 8 cu yds Concrete 13-3/8" 72# L-80 Surface 2672' 17-1/2" 3441 cu ft AS II, 186 cu ft Top Job 9-5/8" 47# L-80 Surface 9721' 12-1/4" 1305 cu ft Class 'G', 130 cu ft AS II 7" 29# L-80 9212' 9786' 8-1/2" 360 cu ft Class 'G' . 8.81# /6.2# /6.16# L-80 9222' 11360' 3-3/4' x 4-1/8' 125 cu ft Class 'G' . 3-1/2" x 3-3/16' x 2-7/8" 23. Perforations open to Production (MD + TVD of Top and 24. TUBING RECORD Bottom Interval, Size and Number; if none, state "none"): SIZE DEPTH SET (MD) PACKER SET (MD) 2" Gun Diameter, 4 spf 7", 26#, L-BO 9169' 9169' MD TVD MD TVD 4-112", 12.6#, L-80 9169' - 9279' 10710' -11180' 9037' - 9037' .25, ACID, .. UI;:.MI:N I ETC. 11250' - 11310' 9038' - 9045' DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 2000' Freeze Protect with MeOH 26. PRODUCTION TEST Date First Production: Method of Operation (Flowing, Gas Lift, etc.): October 17, 2003 Flowing Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAs-McF WATER-BBL CHOKE SIZE I GAS-OIL RATIO 10/19/2003 4 TEST PERIOD + 4,244 14,374 106 1760 3,387 Flow Tubing Casing Pressure CALCULATED + OIL-BBL GAs-McF WATER-BBL OIL GRAVITY-API (CORR) Press. 212 24-HoUR RATE 25,464 86,244 636 24.8 27. CORE DATA Brief description_of.l~thology. porosity, fractures, apparent dips and presence of oil, gas or water (attach separate sheet, if necessary). Submit core ctllp,st!f O()'\e..sté:it!: "none". ! .'.."11: . None ...)~ ~'l: i .4..J (:'"d,: -þ .. . ...-. ORIGINAL I VERiFIED ! l-~~d Form 10-407 Revised 2/2003 CONTINUED ON REVERSE SIDE , ') IY :;¡ _>"m·c, ( . ' MDM~ Bflb OCT 2: I ZOO,) \9 28. GEOLOGIC MARKER~ 29. RMATION TESTS Include and briefly summarize test results. List intervals tested, NAME MD TVD and attach detailed supporting data as necessary. If no tests were conducted, state "None". Shublik 9830' 8528' None Sadlerochit 9936' 8606' Top CGL 10116' 8749' Base CGL 10231' 8831' 25N 10316' 8892' 25P 10324' 8897' 22N 10402' 8943' 22P 10416' 8951' 21N 10604' 9016' 21P 10619' 9020' Zone 1 B 11170' 9037' 14N 11185' 9037' 14P 11245' 9037' 30. List of Attachments: Summary of Daily Drilling Reports, Surveys 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed Terrie Hubble '1:Ô Title Technical Assistant Date IO/aaJo PBU G-12B Well Number Prepared By Name/Number: Drilling Engineer: Terrie Hubble, 564-4628 Ted Stagg, 564-4694 203-141 Permit No. I A roval No. INSTRUCTIONS GENERAL: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. ITEM 1a: Classification of Service Wells: Gas Injection, Water Injection, Water-Altemating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. ITEM 4b: TPI (Top of Producing Interval). ITEM 8: The Kelly Bushing elevation in feet above mean low low water. Use same as reference for depth measurements given in other spaces on this form and in any attachments. ITEM 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). ITEM 20: True vertical thickness. ITEM 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITEM 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). ITEM 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, or Other (explain). ITEM 27: If no cores taken, indicate "None". U:~ GIf'~Al ITEM 29: List all test information. If none, state "None". Form 10-407 Revised 2/2003 .., - Page 1 of16 BP EXPLORATION . . . . .. ... . . qþer~ti()ns Surnrj1:ary Repprt G-128 G-128 REENTER+COMPLETE Start: 9/13/2003 NORDIC CALISTA Rig Release: 9/30/2003 NORDIC 1 Rig Number: N1 From -¡-rd'!Hours:Task I Code I NPT : Phase I RREL from K-08a @ 0900 hrs. Prep to move off well and fix problems with moving system Safety mtg re: move to G-12 Move rig off K Pad and onto K Pad road. Turn onto G Pad access before twin towers. Cross mats and arrive on G Pad Set rig down between pads and place rig on Standby. Wellhouse was just removed. WO FL to be drpressured and removed. Spot camp. DSM set flowback tank Safety mtg re: move over well Move DS/N #1 over tree and set down NU BOPE NU BOPE Test BOPE. Witness waived by AOGCC Fill pits, prep injector Cut off CTC. Install BOT CTC. PT 30k Swap out lubricator. Install nozzle assy. Fill CT w/ 2% KCI. Check well for pressure and none. IA 200, OA -7 Pre Spud mtg MU fishing BHA (4" GS spear) RIH w/ BHA #1 taking wellbore fluids to cutting box 9200' 32.6k Fin circ out MeOH 1.5/640. RIH and tag deployment sleeve at 9254' CTD. Latch fish POOH filling from BS 37k 30'/min until clear of tailpipe PVT 217. POOH w/2-7/8" liner Tag up, PVT 194, IA 270. Hole did not take proper fill. Monitor 30 min while hold safety mtg and get tools ready-wellbore stable, hole full Stand back inj. LD fishing BHA. LD deployment sub. RU to LD liner. MI WL unit LD 17 jts and one 14' cut section of 2-7/8" 6.4# L-80 FL4S. Clean chemical cut. Connections looked good. Had external pitting on most joints. NORM reading zero. Could see cement on the lowside on the first 48' above the cut after pipe had dried out Kick while tripping drill Safety mtg re: RU slickline tools RU slickline tools Run 3.625" LIB and decentralizer. RIH down to top of fish. No TEL in the tool string, so going off of SL depths. Mushy tag 3 times at 9764'. POOH. Tag up, layout 3.625" LIB. No marks on LIB. Slight marks on edge of LIB almost look like it has been pinched. Get materials to run 2.5" LIB and decentralizer. RIH with 2.5" LIB, 2.6" decentralizer, and extra weight bar. No TEL in tool string, depths are SLM. Hung up at 9764', then fell thru down 30' deeper, to 9791'. During set down they lost span jar action for a moment. DECOMP Inspect LIB. Found 2-7/8" liner top impression on the low side of the hole. Looks as if the liner is as expected, and on the low side. The early set down at 9764' may indicate some contaminated cement up above the top of fish. This would not Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: bate: 1/1/2003 9/13/2003 - 0.00 POST 09:00 - 13:15 4.25 MOB N PRE 13:15 -13:35 0.33 MOB P PRE 13:35 - 16:55 3.33 MOB P PRE 16:55 - 22:45 5.83 MOB N PRE 22:45 - 23:00 0.25 MOB P PRE 23:00 - 23:30 0.50 MOB P PRE 23:30 - 00:00 0.50 BOPSUF P PRE 9/14/2003 00:00 - 02:00 2.00 BOPSUF P PRE 02:00 - 07:30 5.50 BOPSUF P PRE 07:30 - 08:00 0.50 CLEAN P DECOMP 08:00 - 08:30 0.50 CLEAN P DECOMP 08:30 - 10:30 2.00 CLEAN P DECOMP 10:30 -10:45 0.25 CLEAN P DECOMP 10:45 - 11 :40 0.92 CLEAN P DECOMP 11:40-13:10 1.50 CLEAN P DECOMP 13:10 -13:25 0.25 CLEAN P DECOMP 13:25 - 14:55 1.50 CLEAN P DECOMP 14:55 - 15:30 0.58 CLEAN P DECOMP 15:30 - 16:00 0.50 PULL P DECOMP 16:00 - 17:00 1.00 PULL P DECOMP 17:00 - 17:15 0.25 CLEAN P DECOMP 17:15 - 17:45 0.50 CLEAN P DECOMP 17:45 - 20:00 2.25 CLEAN P DECOMP 20:00 - 21 :30 1.50 CLEAN P DECOMP 21 :30 - 22:30 1.00 CLEAN P DECOMP 22:30 - 22:50 0.33 CLEAN P Spud Date: End: Description of Operations ..-----.-.--.-------.---......--...--....-- Printed: 10/6/2003 1:51:08 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date 9/14/2003 9/15/2003 9/16/2003 22:30 - 22:50 22:50 - 00:00 00:00 - 06:00 06:00 - 08:00 08:00 - 08:55 08:55 - 10:45 10:45-11:15 11:15 -11:30 11 :30 - 12:30 12:30 - 13:00 13:00 - 14:30 14:30 - 16:00 16:00 - 16:25 16:25 - 17:45 17:45 - 18:45 18:45 - 19:30 19:30 - 19:50 19:50 - 22:30 22:30 - 00:00 00:00 - 01 :00 01 :00 - 02:00 BP EXPLORÄTION Operations Summary Report 0.33 CLEAN P 1.17 CLEAN N 6.00 CLEAN N 2.00 CLEAN N 0.92 CLEAN P 1.83 CLEAN P 0.50 CLEAN P 0.25 CLEAN P 1.00 CLEAN P 0.50 CLEAN P 1.50 CLEAN N 1.50 CLEAN P 0.42 CLEAN P 1.33 CLEAN P 1.00 CLEAN P 0.75 CLEAN N 0.33 CLEAN N 2.67 CLEAN N 1.50 CLEAN P 1.00 CLEAN 1.00 CLEAN Page 2 of16 Start: 9/13/2003 Rig Release: 9/30/2003 Rig Number: N1 Spud Date: End: G-128 G-128 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 From - To i Hours Task Code NPT Phase Description of Operations .. DECOMP be an entirely bad thing as it may act as an entry guide to the top ofthe fish. WAIT DECOMP Release SL unit. Discussion with Baker fishing hand, BP Co Rep, and BP town concludes that the best option forward for a lowside fish is the 3.0" OD piloted mill. Wait on Baker fishing to complete fabricating mill. WAIT DECOMP Continuing to wait on mill fabrication. DECOMP Mills and UR here. Cuss 'n discuss DECOMP MU milling assy #1 (3.0" mill with pilot, 2-7/8 Navidrill motor) IA 265 DECOMP RIH w/ BHA #3 circ'ing at min rate and filled the CT with the extra fluid from prior run. . . DECOMP 9300' 34k Start pump 2.5/2070 RIH 15-20'/min 23k in 7" liner. Begin 100k used mud DECOMP Tag TOL at 9808' CTD with first mud at mill and stall. PUH 33.4k. Ease back down to first motor work DECOMP First motor work at 9808.0' CTD. Corr to 9772.0' and flag. 2.5/2160 Begin milling 2-7/8" liner DECOMP 9773.0' 2.5/2290 w/70-150# diff FLUD DECOMP 9773.5' Got a fair amount of btms up gas. PUH 32k and red rate to 1.5 bpm while circ out gas and wait on truck with remainder of mud-dispatcher trying to save us money sent mud in small trucks. .. red rate to 0.5/1190 after gas out and got mud back to surface, but not enough volume to circ DECOMP 9773.5' 2.5/2430 Resume milling. Mill to 9775.4', but acting too smooth (no stalls) DECOMP 9775.4' Chk FS 2.5/2430 RIH and resume milling and got motor work at 9774.9'. Get back to btm and resume milling w/ 200# diff. Mill to 9775.7' IA 408 PVT 286 DECOMP PUH 30.5k. POOH to check wear pattern on mill DECOMP LD BHA. Check mill and JB. Found a few curly pieces of metal in the junk basket along with cement. Examined the mill and found no wear on the pilot, and wear in a circular 2-7/8" pattern on the mill face, with several chipped cutters. This suggests that the mill has been operating properly on the 2-7/8" liner, and doing what we wanted it to. If we were along side the fish there should be wear on the pilot. Rig up the same mill, moter BHA back up to resume milling. SFAL DECOMP While stabbing injector on tree, a hydraulic hose was found leaking. It will need to be repaired prior to RIH. SFAL DECOMP Safety meeting to discuss nature of the hose failure, the repair needed, and possible hazards and mitigation. Issues discussed were working at heights, proper fall protection, using ladders to stand on, slips from hydraulic fluid, spills to pad from leaking hose, trapped pressure, lockoutltagout on controls to power pack. SFAL DECOMP Proceed with rapairs to injector. DECOMP RIH with BHA #3 to resume milling. 3.0" piloted mill, 2.875" motor, PH6, jars, Junk baskets, MHA. DECOMP Continue RIH with BHA #3. Pump 30 bbls of MI cat hair super sweep at 1/4 #/BBL. Pumping thru the cement line to bypass the filters. Stage it to be at the mill when the BHA gets to TD. DECOMP Weight check at 9700'=40 klbs. Kick on pumps. Free Printed: 10/6/2003 1:51:08 PM . . . .. """ " " "" " BP EXPLORA TIÖN Operations Summary Report Spud Date: Start: 9/13/2003 End: Rig Release: 9/30/2003 Rig Number: N1 PhaseJ .___....~~scriPtion of Operations DECOMP spin=2600 psi at 2.6 bpm. Tag top of fish. Make -26' correction. set depth to last tag of 9775.7'. Ease into milling. No stall. 2.55/2.55/2800 psi. Asked mud man to raise system viscosity. Want to bring it up to the max we can get for carrying ability while keeping pump pressure at approximately 3000 psi. Did not see any unusual pressure charecler when pumping cat hair out of mill. Able to mill at 2.0 fph. DECOMP 9779.5', Milling ahead. Making surprisingly good progress? Milling faster than I would have expected on steel. 2.55/2.63/2830 psi. Had 1 stall in last hour. DECOMP 9787.7'. Hard to believe we milled 8.2' in the past hour. Still waiting for bottoms up from the first cat hair sweep. We will send another sweep after seeing the first one. DECOMP 9788', First cathair sweep back to surface. No large chunks of metal in sweep. There are metal fines on the ditch magnets. Total weight of recovered metal from magnets so far is about 5 Ibs. Note that this sweep went thru the bit just as this run got back to bottom. Only 3.7' of liner had been milled up at that point. DECOMP 9790.0', Pumping another 30 bbl cat hair sweep. DECOMP 9791.1', 2.57/2.62/3186 We have made 3.4' in the past hour. ROP has slowed down. DECOMP 9793.2', Getting fine steel fuzz back on the ditch magnets at about the same rate as during window milling. Metal particle size appears to be quite small. Only a few curley-ques seen on shaker. Still getting lots of cat hair back. First sweep appears to have strung out quite a bit. Cat hair coming off of the shakers is reactive when placed near a magnet. Captured a sample of cat hair from the shaker and looked at it under a microscope, and are getting some pieces of fine iron, some pipe scale, and formation sand? Where the sand is coming from I can't say. 9794.0,2.9' in last hour. 2.58/2.61/3100 psi. Pit vol=283 bbls. IAP=430 psi, OAP=240 psi. Stall at 9797', PU above 9772' clean with no hang ups. RIH smooth Continue milling. 9797.1',3.1' in last hour. 2.58/2.66/3113 psi. Pit vol=281 bbls. 9800.0' and stacking. 30' wiper 2.6/2720, 35k, clean. RIH and get motor work at 9798.6' Mill back down and get to 9799.3', but still stacking Start 30 bbI1/4#/bbl Supersweep pill mixed in mud. Recip while pill exits mill. See flag at 9773' (1' off) Ease back in hole 2.5/2680 and first wt loss and motor work at 9798.0'. Resume milling w/200# diff, but still stacking and no progress. Appears mill is worn POH. Recheck flag at 9773.0'. Assume TD is 9797.0' which gives enough room for a 17.5' Gen 2 WS with bottom at 9794', top at 9776.5', TOW at 9781', BOW at 9787.5'-a Sag River exit. 7" collar is at 9779'. STUC DECOMP Stuck BHA at 9338' both ways. Assume junk baskets hung up in milled out XN nipple. Work in increments and after 3 jar ""> Date G-12B G-12B REENTER+COMPLETE NORDIC CALISTA NORDIC 1 From - To \ Hours. Têsk ..Code I NPT ¡ Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 9/16/2003 1.00 CLEAN 01 :00 - 02:00 02:00 - 03:00 1.00 CLEAN 03:00 - 03:20 0.33 CLEAN 03:20 - 03:40 0.33 CLEAN 03:40 - 04:00 04:00 - 04:50 0.33 CLEAN 0.83 CLEAN 04:50 - 05:00 0.17 CLEAN 05:00 - 05:45 0.75 CLEAN DECOMP 05:45 - 05:50 0.08 CLEAN DECOMP 05:50 - 06:00 0.17 CLEAN DECOMP 06:00 - 07:00 1.00 CLEAN DECOMP 07:00 - 07:50 0.83 CLEAN DECOMP 07:50 - 08:30 0.67 CLEAN DECOMP 08:30 - 08:50 0.33 CLEAN DECOMP 08:50 - 09:05 0.25 CLEAN DECOMP 09:05 - 09:15 0.17 CLEAN N Page:3 of 16, Printed, 10/612003 1,51,08 PM Page 40f 16 ,sP EXPLORATION Operâti,ons Summary Report ... Legal Well Name: G-128 Common Well Name: G-128 Event Name: REENTER+COMPLETE Contractor Name: NORDIC CALISTA Rig Name: NORDIC 1 Date I From - To ' Hours' Task I Code NPT 9/16/2003 09:05 - 09:15 09:15 - 09:50 0.17 CLEAN N 0.58 CLEAN N STUC SFAL 09:50 - 11 :05 1.25 CLEAN P 11:05-12:15 1.17 CLEAN P Spud Date: Start: 9/13/2003 End: Rig Release: 9/30/2003 Rig Number: N1 Phase I ,... Description of Operations DECOMP licks came free and pull to 9260'. Then, injector tripped out. . . DECOMP Injector kept tripping out and stopping upward progress. Use override and pull to safety at 9100'. Reboot PC, PUH for a few feet and still trips out. Repeat 3 times. Replace wiring to weight cell DECOMP Resume POOH. Recovered pill and had more metal than previous pills and more curlies DECOMP LD milling BHA. Mill was in gauge/metal munchers were 1/2 worn. Junk baskets were both full of curlies and a couple of 1" x 2" thin wafers. MU nozzle assy. Will clean out junk with higher density sweeps before underreaming RIH w/ BHA #4 (3.0" nozzle w/1" hole) Corr to flag at 9673.8' and reset to 9758.7' PUH 42k at min rate. RIH and tag at min rate at 9798.0', clean. PUH 42k, clean. Start 30 bbI1/2# Supersweep pill 2.1/2000 Circ pill to nozzle while POOH into tailpipe to 9250' and clean 2.5/2600, RBIH 1/2 #/BBL cathair sweep out nozzle. Pull up to 9750, park coil, kick on both pumps to pump at maximum rate. Pumping at 4.35/4.1/4135 psi. Lets see what this brings up. 2nd 1/2# cat hair sweep back to surface. It contains significant amounts of entrained curley-ques. No potato chip sized pieces, but lots of 1/4" by 2" c-q's. The metal concentration was high as the start of the sweep arrived back at surface, and tapered off to virtually none at the end of the sweep. 12:15 -14:05 1.83 CLEAN P DECOMP 14:05 - 14:10 0.08 CLEAN P DECOMP 14:10-14:50 0.67 CLEAN P DECOMP 14:50 - 16:00 1.17 CLEAN P DECOMP 16:00 - 16:30 0.50 CLEAN P DECOMP 16:30 - 18:00 1.50 CLEAN P 18:00 - 18:30 0.50 CLEAN P Mix another cat hair sweep. This time in viscosified mud to at least 150klsrv plus mud with 3/4 #/bbl of cat hair. DECOMP Pump 30 bbls of 3/4# cat hair sweep with 150+ klsrv mud. This is very thick, walk on water, jesus mud. Pump it out the nozzle with the nozzle at TD. Chase the sweep up hole to 9750', then park coil with rate at maximum of. DECOMP Recovering 3/4 #/bbl sweep. Appears to be considerably less metal concentration in this sweep. Virtually no big pieces of metal, and very hard to detect any metal by visual examination. 18:30 - 21 :00 2.50 CLEAN P DECOMP 21 :00 - 21 :30 0.50 CLEAN P DECOMP 21 :30 - 22:00 0.50 CLEAN P DECOMP 22:00 - 22:30 0.50 CLEAN P DECOMP 22:30 - 00:00 1.50 CLEAN P DECOMP 9/17/2003 00:00 - 00: 15 0.25 CLEAN P DECOMP 00:15 - 01:00 0.75 CLEAN P DECOMP RIH while circ at 4.4 bpm, tag bottom and POH while circ at 4.2 - 4.4 bpm, 3800 psi. Tag up at surface, did not see any additional metal when close to surface. UO BHA. M/U jetting BHA to clean BOP stack. Circ. at 4.5 bpm and jet across BOP stack several times until clean. UO jetting nozzle. M/U Baker 3.625" guide mill and DB Underreamer with 6.101" blades. M/U 2-7/8" extreme motor, circ sub, disconnect, Bowen Up Jars, 2 Jts 2-3/8" PH6 tubing and CTC. Total length = 92.81 ft. RIH with underreaming BHA to clean out cement to top of 2-7/8" liner. RIH with BKR Underreaming BHA. 6.101" blade dia. RIH to 9400 ft. Circ. at 2.7 bpm at 2600 psi, Open UR blades at 9400 ft, saw pressure shift when blades open. RIH at 8 FPM to 9750 ft with no motor work. RIH to flag at 2 FPM. Printed: 10/6/2003 1:51:08 PM .... SP'EXPLORATION . .. Operations SummaryiR~po"f DECOMP Correct to flag at 9767'. [-33 ft CTD). UR down at 1.0 FPM. No motor work. First small motor work at 9782 ft. UR down at 0.6 FPM, 2.7 bpm, 2600 psi. Easy cement milling. DECOMP UR firm cement starting at 9788 ft. UR down at 0.5 fpm, 2.7 bpm, 2700 psi, 100 psi motor work. Had 4 stalls at 9794-9795 ft. UR down slow to 9796 ft. Pick up to 9730 ft. DECOMP Underream down to 9796 ft. again. Clean hole, no motor work, Stall at 9796 ft. Circ. 30 BBL very high vise FloPro pill. UR slow down to 9798 ft. Pick up to 9700 ft and ream down at 5 FP, clean, no motor work. Stall at 9798 ft again at top of 2-7/8" liner. DECOMP Circ. 2% KCL water with 1/2 PPB Biozan for logging and milling window. Drop 3/4" steel ball to open circ sub. Displace with Biozan water at 2.6 bpm, 1900 psi. Ball on seat at 54 bbls. sheared circ sup open at 2800 psi. POH while circ. at 3.6 bpm, 2150 psi. Tag up at surface, stand back injector, lay down under reamer BHA All recovered ok. Recoverd 3 arms on underreamer. Wait on HES crew to changeout. Safety meeting prior to rigging up HES. HES does not have the necessary eq. Call for packoff from Deadhorse shop. Rig up HES and PDS MFC. RIH with MFC tool. Set down in 7" PBR seal. Can't get down. Tagging up at 9110' SLM. POOH to layout MFC and make a drift run to TD. Lay down MFC, PU pump bailer, centralizer, spang jars. Run drift run with 2-1/2" pump bailer. Could not get down to bottom. Tagging up at 9110' SLM, same depth as last run. Nearest jewelry at 9169' Tag up at surface with pump bailer. Dump it out and find approximately 5 Ibs of steel cuttings in the pump bailer. (About 2" in the bottom of a 5 gallon bucket). The cutting size is mostly the curly-ques we were looking for while milling. The partical size is in the moderate to small range. Nothing huge, nothing fine. Mostly from 1/4" -1-1/2", down to 1/32x1/2". DECOMP Run #2. RU 3.0" X 10ft pump bailer with ball check for 1 run while HES brings a 3.5" pump bailer from Deadhorse. RIH, work pump bailer. POH. Good recovery of small/ medium sized metal. [ 10 Ibs ). SFAL DECOMP RIH. Depth encoder failed at 8000 ft. POH and repair. DECOMP Run #3. RIH with 3.5" X 10ft pump bailer with flapper check. Work on bottom. POH. Good recovery again. [15 Ibs]. Total of 30lbs from 3 bailer runs. Also 10 Ibs from earlier junk baskets. DECOMP Run #4. RIH with 3.5" pump bailer. Work on bottom. POH. Very good recovery [25 Ibs), fine / medium metal cuttings. Weighed with scale, total metal from 4 runs = 55 Ibs, about 3 gal. DECOMP Run #5. RIH with 3" pump bailer. Work on bottom. POH. Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: G-128 G-128 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Date From - To Hours Task I Code NPT . Phase - -- ----- 9/17/2003 01 :00 - 01 :50 0.83 CLEAN P 01 :50 - 03:15 1.42 CLEAN P 03: 15 - 05:00 1.75 CLEAN P 05:00 - 06:00 1.00 CLEAN P 06:00 - 08:25 2.42 CLEAN P DECOMP 08:25 - 09:00 0.58 CLEAN P DECOMP 09:00 -10:15 1.25 CLEAN N WAIT DECOMP 10:15 - 10:35 0.33 CLEAN P DECOMP 10:35 -12:15 1.67 CLEAN N WAIT DECOMP 12:15 - 12:45 0.50 CLEAN P DECOMP 12:45 - 15:45 3.00 EVAL P DECOMP 15:45 - 16:30 0.75 EVAL P DECOMP 16:30 - 17:45 1.25 CLEAN P DECOMP 17:45 - 18:10 0.42 CLEAN P DECOMP 18:10 - 20:30 2.33 CLEAN P 20:30 - 22:00 22:00 - 00:00 1.50 CLEAN N 2.00 CLEAN P 9/18/2003 00:00 - 01 :30 1.50 CLEAN P 01 :30 - 03:00 1.50 CLEAN P Päge'5: of: 16 Start: 9/13/2003 Rig Release: 9/30/2003 Rig Number: N1 Spud Date: End: Description of Operations . ----.-....----.-. Printed: 10/612003 1:51:08 PM / .... .., ............... BP EXPLORATION Page 6 of 16 . ... Operations Summåry~ep;èrt Legal Well Name: G-12B Common Well Name: G-12B Spud Date: Event Name: REENTER+COMPLETE Start: 9/13/2003 End: Contractor Name: NORDIC CALISTA Rig Release: 9/30/2003 Rig Name: NORDIC 1 Rig Number: N1 I NPT I I i Date' From ,.To Hours Task Code Phase I Description of Operatiol1s ----_.~ .~._- .--.----..-- .-----.- -_: .... -...-.-..-- ----- 9/18/2003 01 :30 - 03:00 1.50 CLEAN P DECOMP Recover 20 Ibs of metal. [75 total from 5 runs]. 03:00 - 04:00 1.00 CLEAN P DECOMP Run #6. RIH with 3.5" pump bailer. Work on bottom. POH. Recovered [7 Ibs], fine / medium metal cuttings. 04:00 - 05:00 1.00 CLEAN P DECOMP Run #7. RIH with 3.5" pump bailer. Work on bottom. POH. Recovered [8 Ibs], fine / medium metal cuttings. Total of 90 Ibs recovered with pump bailer runs so fare. Also total of 10 Ibs recovered from magnets. 05:00 - 06:00 1.00 CLEAN P DECOMP Run #8. RIH with 3" pump bailer. Work on bottom at 9116' [ started cleanout at 9102'], POH. Recovered 12 Ibs metal. Total of 102 Ibs from pump bailer runs. 06:00 - 07:15 1.25 CLEAN P DECOMP Run #9. RIH with 3" pump bailer. Work on bottom at 9117.5'. POOH. 07:15 - 08:15 1.00 CLEAN P DECOMP Tag up at surface with Bailer run #9. Dump 11 Ibs of medium sized cuttings. Total recovery now at 113 Ibs from the bailer runs. HES needs to cut 150 of wire and redress pump bailer. 08: 15 - 09:40 1.42 CLEAN P DECOMP Run Bailer run #10 with 3" bailer again. Work on bottom, POOH. Recovered 8 Ibs from the bailer. Most medium size cuttings, 2 chunks 1/2" x 1.5". Total 120 # so far. 09:40 - 11 :00 1.33 CLEAN P DECOMP Run #11, 3" bailer. Work on bottom at 9116', broke thru. Made it down to 9788', SLM. POOH. Recovered 4 bls from the bailer. Same material as previous runs. Total 124 Ibs so far. 11 :00 - 12:15 1.25 CLEAN P DECOMP RIH with 6.2" brush to knock any remaining debris down out of 7" tubing into 4-1/2" tubing tail pipe. Made it down to 9169' easlily. Looked like 1 bobble on weight were we saw the debris on previous runs. 12:15 - 13:30 1.25 CLEAN P DECOMP Lay down brush for 7", pick up brush for 4.5". Tool string will be 3" pump bailer, 4.5" brush, TEL to tie in to tubing tail. 13:30 - 14:00 0.50 CLEAN P DECOMP RIH with brush for 4.5" tubing tail, bailer, TEL Tie into Tubing tail. Tagged bottom at 9813! POOH. 14:00 -15:15 1.25 CLEAN P DECOMP Tag up at surface, pump bailer, bailer was empty. Lay down bailer, hook up PDS MFC-GR-CCL tool. Check out caliper tool. 15:15 - 17:45 2.50 EVAL P DECOMP Log MFC-GR-CCL from TD to 9100'. 17:45 - 18:15 0.50 EVAL P DECOMP Stand by on downloading of MFC-GR-CCL information. 18:15 -18:45 0.50 EVAL P DECOMP PDS reports that they have good log data. Rig down HES unit. 18:45 - 20:00 1.25 WHIP P WEXIT Back in and spot SWS logging unit. 20:00 - 20:15 0.25 WHIP P WEXIT SAFETY MEETING. Review procedure, hazards and mitigation for RIU and M/U of SWS running tools and BKR Whipstock. 20:15 - 21:00 0.75 WHIP P WEXIT Rig up SWS E-Line running tools. 21 :00 - 21 :30 0.50 WHIP N WAIT WEXIT Wait on orders form town to run whipstock. 21 :30 - 22:45 1.25 WHIP P WEXIT M/U BKR Gen 2, 3-5/8" OD whipstock on SWS running tools. Orient TF to running tools. 22:45 - 00:00 1.25 WHIP P WEXIT RIH with BKR whipstock on SWS E-Line. 9/19/2003 00:00 - 01 :00 1.00 WHIP P WEXIT Log Tie-in with SWS GRlCCLlBKR Whipstock. Good Tie-in. TD = 9796 ft, Ref. SCMT/GR of 06/08/03. Casing collars on depth. Set top of Baker Gen 2 whipstock at 9766 ft. Set whipstock and logged off. RIH and tag top of whipstock at Printed, 10/6/2003 1,51,08 PM . . .. . .. . sF> EXPLÖRAT/ÖN Operations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: G-12B G-12B REENTER+COMPLETE NORDIC CALISTA NORDIC 1 ; Date From - To Hour$ I Task Code NPT Phase 9/19/2003 00:00 - 01 :00 1.00 WHIP P WEXIT 01 :00 - 01 :45 0.75 WHIP P WEXIT 01:45 - 02:15 0.50 WHIP P WEXIT 02: 15 - 02:45 0.50 WHIP P WEXIT 02:45 - 04: 15 1.50 WHIP P WEXIT 04:15 - 04:30 0.25 WHIP P WEXIT 04:30 - 05:00 0.50 WHIP P WEXIT 05:00 - 05:30 0.50 WHIP P Page 7 of 16 Start: Rig Release: Rig Number: Spud Date: End: 9/13/2003 9/30/2003 N1 Description of Operations --.---.---..--..-..-----.-.--.-..-- ~_._-_._----_.-_._---_.~---_._-- 9765 ft. Whipstock set OK and did not fall down hole. TF = 25 deg. Right. POH with SWS running tools. Rig Down SWS E-Line equipment. M/U Cement Nozzle BHA w/ big hole nozzle, 1 jt, 2-38" PH6, XO, circ sub, disc, XO, CTC. Total length = 37.75'. RIH with Cementing BHA to lay cement on whipstock. SAFETY MEETING. Review procedure, hazards and mitigation for pumping 5 bbl cement job. Correct -29 ft CTD at flag. RIH and lightly tag whipstock pinch point at 9768 ft. Baker whipstock is still set in place. Pick up 10ft and flag CT at 9758 ft, for cleanout depth marker. Stage 5 bbl water. Press test cement line. WEXIT Stage 5.5 bbl, 15.8 ppg, G Cement. 1.1 bpm, 400 psi. Stage 5 bbl water. Stage 33 bbl, 2 ppb Biozan water to contaminate Cement during dress off. Displace with 1/2 ppb Biozan water. 2.9 bpm, 1900 psi. Lay in 5 bbl cement at 1.5 bpm, WCTOC at 9610 ft. Pull to 9470'. Wait on cement to fall around whipstock before dressing off to flag on CT. RIH and contaminate cement with 33 bbls Biozan, Dress off down to flag on CT. Circ. cement out of well. 3.8 bpm, 2100 psi. POOH with cementing BHA. Pumping 3.65 bpm, pulling at 60%, trying to chase contaminated cement OOH. IAP=340 psi, OAP=O psi. Tag up at surface, lay down cementing BHA. Pick up jetting nozzle, jet the stack. Standby while hydril hand works on accumulator. Make up Milling BHA. BHA #7 RIH with milling BHA. SWS cement lab reports that cement is at 1000 psi compressive strength as of 11 :00. We may begin milling when back at bottom. Check depth at first flag. Correction is -57'. RIH. WEXIT Tag top of cement at 9757', should be more like 9775'. Kick on pumps, start milling cement. UCA shows 1400 psi compressive strength cement at this time. We will re set our depth to whipstock pinch point of 9785.5', based on tied in to PDC log for depth control once we are confident we are on the pinch point. Milling at 2.7/2.7/1450 psi. At pinch point, make a +12' correction. Depth at top of window is 9785.5'. Milling at 2.7/2.7/1534 psi. Top of cement was at 9769'. 9786.3',0.8' into window. 2.7/2.7/1590 psi. 190 psi motor work, 2000 Ibs weight on bit. IAP=312 psi, OAP=80 psi. Cement is at 2000 psi compressive strength at 14:45. 9787.2', 1.7' into window. 2.65/2.67/1626 psi. 222 psi motor work. 3800 Ibs weight on bit. Pump 20 bbl sweep of 2# biozan/bbl pill. 05:30 - 06:00 0.50 WHIP P WEXIT 06:00 - 06:15 0.25 WHIP P WEXIT 06: 15 - 09:30 3.25 WHIP P WEXIT 09:30 - 10:05 0.58 WHIP P WEXIT 10:05 - 10:30 0.42 STWHIP N RREP WEXIT 10:30 - 11 :00 0.50 STWHIP P WEXIT 11 :00 - 12:40 1.67 STWHIP P WEXIT 12:40 - 13:05 0.42 STWHIP P 13:05 - 14:00 0.92 STWHIP P WEXIT 14:00 -15:00 1.00 STWHIP P WEXIT 15:00 - 15:15 0.25 STWHIP P WEXIT 15:15 - 16:00 0.75 STWHIP P WEXIT Printed: 10/6/2003 1 :51 :08 PM ..... Page 8 of 16 BP EXPLORATION . . . . ... Operati:ons SUmtPary ~~port Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date G-12B G-12B REENTER+COMPLETE NORDIC CALISTA NORDIC 1 From - To I Hours I Task I Code I NPT ¡ Phase _..__._____.____.___ -----.----------.-:__.__.1__.._.----. 16:00 - 16:50 0.83 STWHIP P WEXIT 9/19/2003 16:50 - 17:00 0.17 STWHIP P WEXIT 17:00-17:10 0.17 STWHIP P WEXIT 17:10 - 17:25 0.25 STWHIP P WEXIT 17:25 - 18:00 0.58 STWHIP P WEXIT 18:00 - 19:00 1.00 STWHIP P WEXIT 19:00 - 20:10 1.17 STWHIP P WEXIT 20:10 -21:15 1.08 STWHIP P WEXIT 21 :15 - 21 :45 0.50 STWHIP P WEXIT 21 :45 - 22:45 1.00 STWHIP P WEXIT 22:45 - 23:45 1.00 STWHIP P WEXIT 23:45 - 00:00 0.25 STWHIP P WEXIT 9/20/2003 00:00 - 01 :00 1.00 STWHIP P WEXIT 01 :00 - 03:30 2.50 STWHIP P WEXIT 03:30 - 03:45 0.25 DRILL P PROD1 03:45 - 05:00 1.25 DRILL P PROD1 05:00 - 05:30 0.50 DRILL P PROD1 05:30 - 06:00 0.50 DRILL N DFAL PROD1 06:00 - 06:25 0.42 DRILL P PROD1 06:25 - 07:50 1.42 DRILL N DFAL PROD1 07:50 - 08:45 0.92 DRILL N DFAL PROD1 08:45 - 09:25 0.67 DRILL N DFAL PROD1 Start: Rig Release: Rig Number: I 1 Spud Date: End: 9/13/2003 9/30/2003 N1 Description of Operations 9787.9',2.4' into window. 2.63/2.65/1650 psi. 230 psi motor work. 4700 Ibs weight on bit. 9788.4', Stacking more weight and getting more motor work. 9788.5',3.0' into window. 2.65/2.65/1770 psi. 370 psi motor work. 5700 Ibs weight on bit. PU to check depth. Hung up at 9775' and stalled the motor. RIH and are free. PU again, hung up again_ RIH, free. Backream slowly up thru obstruction. Got up thru it ok. 9788.5', Back on bottom, pump 20 bbls of 2# bio sweep. Got to try to keep those cuttings lifted. 9788.7',3.2' into window. 2.63/2.63/1835 psi. 430 Ibs motor work. 3400 Ibs weight on bit. 9790', 4.5' into window, 2.6/2.6, 1650 psi, 200 Ibs motor work, 1000 # wob. 9791', 5.5' into window, 2.6/2.6, 1600 psi, 200 Ibs motor work, 500# wob. 9792.2'. Extra motor work. Back ream up thru window, clean. Pull to 9750' and ream down clean to bottom. Mill down, exit casing at 9792.5 ft. 7 ft window. [9785.5- 9792.5 ft ], Mill formation at 10 fph. 2.5/2.5 bpm, 1600 psi, 1500# wob. Milled to 9802.5 ft. Back ream up thru window, Circ. high vis Biozan sweep. Clean window. Ream down. Clean. Back Ream, Ream down and up a total of 3 times. Clean window. Circ. in 30 bbl, Cross linked FloPro to carry out metal milled from window. Lay in 17 bbls from TD at 2.0 bpm, Pull at 55 fpm. Leave top of XL pill at 9350'. Circ last 13 bbls XL pill to surface. Displace pill with KCL water. Displace 30 BBL, Cross linked FloVis pill with 50 bbl, KCL water. Leave top of XL Pill at 9350'. Circ. well to new FloPro from 9350 ft. POH while chasing Biozan to surface with new flopro. 2.9 bpm, 2350 psi. Clean rig pits. Haul off fluids. PRE-SPUD MEETING. Review well plan with all personnel. Review procedure, hazards and mitigation to M/U MWD BHA. M/U SWS CTC. Pull/ Press test. M/U 2.57 deg motor and re-built HC 3.75-4.125" Bi-center bit. M/U Sperry MWD and SWS MHA. RIH with MWD build BHA. Shallow hole test tools. Circulation press to high. 4200 psi at 2.5 bpm. POH and check motor / bit. Change out motor. Adjust new motor. M/U BHA. Shut down operations for crew change and safety meeting. Continue troubleshooting BHA looking for plug. Found a couple poppy seed sized pieced of debris in the pulser. Found seals failed on orienter. Change out orienter. Pump thru BHA at surface. Got pulses and 2800 psi pump pressure. All looks ok. RIH with BHA #8. Check pump pressures at 200', all worked ok. Rate=2.5, pressure=3000, Pulser working ok. 3050', While RIH, rate dropped off, pressure built up. Pumping 0.5 bpm, 2000 psi and building. Try cycling pumps to clean it up. Cycled pumps several times. Appears to be plugged up Printed: 10/6/2003 1 :51 :08 PM "W" - ..... Page 9 öf 16 . . .. .. BPEXPLORA TION Operations Summary Report DFAL PROD1 again. Pumping 1.7 bpm, 4000 psi. DFAL PROD1 Tag up at surface. Stand back injector. Check motor, motor is fine. C/o Sperry equalizer sub. Pull Sperry orienter. Found a small amount of fine "poppy seed" sized gravel in the top of the probe. Approximately 15 pieces of very small sized gravel. It isn't sand, but almost that size. Where this is from is difficult to say. Change out Schlumberger MHA. Stand back BHA. Stab injector on well. Dismantle and inspect Schlumberger in line filter. Check Rig filter screens on suction lines. The filters are intact, but they have too large of mesh size to stop these very small particles. Put everything back together. PT all. Pump down coil, taking returns to the pits. Pump at 4.5 bbl/min 3400 psi. Pump 2 coil volumes thru coil. SI pumping, stab BHA, make up injector. DFAL PROD1 Kick on pumps at 200',2.5 bpm, 3000 psi, everything is ok. RIH to do shallow hole test at 3200', keep pumps on at .7 bpm while RIH. Shallow hole test of orienter. Only getting 10 degree clicks, but pressures are all good and the MWD is working. Decide to RIH, and try to get some hole dug today. Keeping pump rate at 0.7 while RIH. DFAL PROD1 SI pumps, Run thru 4-1/2 tail pipe. Stop at 9300', kick on pumps. Pump pressure is 4200 psi at 2.5 bpm. Pulser not working. *&^%$^%$##@@. Looks like we are plugged off again. Cycle pumps to attempt to free plug in BHA several times. No success. POOH, at 8300', cycle pumps and everything is working again. RIH, the BHA is intermittantly plugging off and getting free. RIH and try to get it to work for a while. Driller kicks centrafuge on and reports significant particulate material being kicked out. DFAL PROD1 Run back in the hole. Again. Tie into 9500' EOP flag. Make -5' correction. RIH. Everything works down to the window. SI pumps, run thru the window. Tag up pumps off at 9804', PU kick pumps on. Evertything working. Tag pumps on at 9802.8 Attempt to orient to 60R. Tool shut down again. POOH to sort this mess out. Call for MI to build new system. Call for empty vac truck to empty and clean pits. Tag up at surface. Stand back the injector. Hold PJSM tool box talk. Change out orienter, this one only gave 10 deg clicks. Change out probe. Wait on vac trucks of new mud from MI. Clean pits while waiting. Circ. new FloPro thru coil, recover old FloPro. 2.7 bpm, 2000 psi. Send old FloPro to MI to get filtered. Will use it near end of this well. M/U MWD build BHA. .. Legal Well Name: G-128 Common Well Name: G-128 Event Name: REENTER+COMPLETE Contractor Name: NORDIC CALISTA Rig Name: NORDIC 1 Date. :¡'From ~ To ' Hours iTélSk Code I NPT ¡ Phase 9/20/2003 08:45 - 09:25 09:25 - 12:10 0.67 DRILL N 2.75 DRILL N 12:10 - 14:00 1.83 DRILL N 14:00 - 14:40 0.67 DRILL N 14:40 - 15:10 0.50 DRILL N 15:10 - 17:00 1.83 DRILL N DFAL PROD1 17:00 - 18:00 1.00 DRILL N DFAL PROD1 18:00 - 20:15 2.25 DRILL N DFAL PROD1 20: 15 - 20:45 0.50 DRILL N DFAL PROD1 20:45 - 21 :00 0.25 DRILL N DFAL PROD1 Start: 9/13/2003 Rig Release: 9/30/2003 Rig Number: N1 I Spud Date: End: Description of Operations ------_._. . -- Geo looked at sample of debris from previous run. It appears to be formation sand. However, some of it appeared to be chert. We have drilled no chert on this well as yet. The source of the material is probably not this well. Possibly a dirty vac truck when the mud was delivered? Printed: 10/6/2003 1 :51 :08 PM - ... BP EXPLORATION Page tOpf 16 ;:i¡O¡perations Summary Report Legal Well Name: G-12B Common Well Name: G-12B Spud Date: Event Name: REENTER+COMPLETE Start: 9/13/2003 End: Contractor Name: NORDIC CALISTA Rig Release: 9/30/2003 Rig Name: NORDIC 1 Rig Number: N1 Date. From - To Hours Task _ _~_~_~~ I NPT I Phase I Description of Operátiol1s ----.-"-----..- 9/20/2003 21 :00 - 23:00 2.00 DRILL N DFAL PROD1 RIH with MWD build BHA. Shallow test tools. OK. 2.4 bpm, 2800 psi. RIH. Test orienter. OK. RIH. 23:00 - 23: 15 0.25 DRILL P PROD1 Tag TD 9805 ft. Drill to 9808 ft. 23:15 - 23:45 0.50 DRILL P PROD1 Orient TF around to 60R. 23:45 - 00:00 0.25 DRILL P PROD1 Drilling build section, 2.5/2.5 bpm, 2800 psi, 53 RTF, Drilled to 9815 ft. 9/21/2003 00:00 - 01 :30 1.50 DRILL P PROD1 Drilling build section. 2.4/2.4 bpm, 2900 psi, 60R TF, Drilled to 9850'. Saw XL FloVis in returns. XL had metal in it as planned. Took samples. XL fluid was spread out over 100 ppbs of returns. Came over shaker in 1/4" chunks. Firmly cross linked. 01 :30 - 02:30 1.00 DRILL P PROD1 Drilling, 2.5/2.5 bpm, 2900 psi, 65R TF, 35 FPH, Drilled to 9862 ft. 02:30 - 03:40 1.17 DRILL P PROD1 Log tie-in with RA tag to original open hole GR. Good tie-in. [- 4.5 ft]. RA tag is at 9,786.5 ft. 03:40 - 05:00 1.33 DRILL P PROD1 Orient TF. Unable to get clicks on bottom. Pull to window. Got one click. Keep trying different things to get clicks, unable to orient. 05:00 - 06:20 1.33 DRILL N DFAL PROD1 POH due to locked orienter. 06:20 - 07:30 1.17 DRILL N DFAL PROD1 Stand back injector. Lay down BHA. 07:30 -13:15 5.75 BOPSUF P PROD1 Perform weekly BOP test. Witness of the test was waived by the State of Alaska, AOGCC, Chuck Sheve. Blind shear rams failed to test. Change out seals. New seals passed fine. 13:15 - 14:30 1.25 DRILL N DFAL PROD1 MU BHA 11 with new style Hughes Bi-center bit. 14:30 - 16:30 2.00 DRILL N DFAL PROD1 RIH with MWD BHA #11. 2.57 deg motor. Shallow hole test, OK. Test orienter, OK. Tag TD at 9858 ft. 16:30 - 16:45 0.25 DRILL N DFAL PROD1 Orient TF to 120R. 16:45 - 19:30 2.75 DRILL P PROD1 Drilling, 2.6/2.6 BPM, 2800 PSI, 124R, 20 FPH, Drilled to 9890 ft. 19:30 - 22:00 2.50 DRILL P PROD1 Drilling, 2.6/2.6 BPM, 3000 PSI, 121 R, 8 FPH, Drilled to 9910 ft, having difficulties w/motor stalling w/only 300 psi differential 22:00 - 22:30 0.50 DRILL P PROD1 Drilling, 2.6/2.6 BPM, 3000 PSI, 121R, 7.5 FPH, Drilled to 9914 ft, Motor keeps stalling. Decision made to trip out, c/o motor. 22:30 - 23:45 1.25 DRILL P PROD1 POH to c/o motor 23:45 - 00:00 0.25 DRILL P PROD1 Lay down BHA, c/o motor 9/22/2003 00:00 - 00:45 0.75 DRILL P PROD1 MU BHA 12 with new motor, kept same bi-centered bit. 00:45 - 02:30 1.75 DRILL P PROD1 RIH with MWD BHA #12. 2.57 deg motor. Tag TD @ 9914'. 02:30 - 02:45 0.25 DRILL P PROD1 Orient TF to 120R. 02:45 - 06:00 3.25 DRILL P PROD1 Drilling, 2.6/2.6 BPM, 2800 PSI, 120R, 10 FPH, Geo sample shows layered limestones and shales, slow drilling ahead. Drilled to 9943 ft. 06:00 - 08:30 2.50 DRILL P PROD1 Drilling, 2.8/2.8 bpm, 2950 psi, 130R, 30 fph, 33 deg incl, Drilled to 10,000 ft. 08:30 - 09:40 1.17 DRILL P PROD1 Orient TF to 70R. 09:40 - 10:30 0.83 DRILL P PROD1 Drilling, 2.8/2.8 bpm, 2950 psi, 70R, 30 fph, 31 deg incl, Drilled to 10,030 ft. 10:30 - 12:30 2.00 DRILL P PROD1 POH for 1.04 deg motor. Flag CT at 9600' EOP. POH. 3.0 BPM , 3250 PSI. 12:30 - 13:30 1.00 DRILL P PROD1 C/O Motor, Adjust motor to 1.04 deg bend, Re-run HC bi-center bit, [0-0-1], Check Sperry impeller, OK. C/O packoff. Printed: 10/6/2003 1:51:08 PM · .. ..., BP EXPLORATION Page 11bf 16 Operations Summary Report Legal Well Name: G-12B Common Well Name: G-12B Spud Date: Event Name: REENTER+COMPLETE Start: 9/13/2003 End: Contractor Name: NORDIC CALISTA Rig Release: 9/30/2003 Rig Name: NORDIC 1 Rig Number: N1 I ¡ Task Code NPTi Phåse Date L From - To ' Hours Description of Operations ---_...._._-~---- ------ ..-----.-.-.--.-.-...--.---- 9/22/2003 13:30 - 15:30 2.00 DRILL P PROD1 RIH to TD. Correct -1 ft CTD at TD. 15:30 - 15:50 0.33 DRILL P PROD1 Orient TF to 60R. 15:50 - 17:20 1.50 DRILL P PROD1 Drilling turn in Zone 4, 2.8/2.8 bpm, 3000 psi, 60R, 80 fph, 37 deg incl, Drilled to 10102'. 17:20 - 17:30 0.17 DRILL P PROD1 Wiper trip to window. Clean hole. 17:30 - 17:50 0.33 DRILL P PROD1 Log tie-in with RA tag at 9790'. Added 1 ft to CTD. 17:50 - 18:00 0.17 DRILL P PROD1 RIH to TD. 18:00 - 19:00 1.00 DRILL P PROD1 Drilling turn in Zone 4, 2.8/2.8 bpm, 3000 psi, 60R, 80 fph, 37 deg incl, Drilled to 10130 ft 19:00 - 20:40 1.67 DRILL P PROD1 Drilling turn in Zone 3, 2.8/2.8 bpm, 3000 psi, 90R, 6 fph, 44 deg incl, Drilled to 10140 ft 20:40 - 21 :45 1.08 DRILL P PROD1 Drilling turn in Zone 3, 2.8/2.8 bpm, 3000 psi, 90R, 3 fph, 44 deg incl, Drilled to 10145 ft 21:45 - 23:15 1.50 DRILL P PROD1 POH for new bit. Flag CT at 9100' EOP. POH. 2.2 BPM, 2200 PSI. 23:15 - 00:00 0.75 DRILL P PROD1 MU BHA #14 w/ hedgehog bit. 9/23/2003 00:00 - 02:30 2.50 DRILL P PROD1 RIH with MWD BHA #14 w/ Hedgehog bit. 1.04 deg motor. Stop @ RA tag. Correct -15 ft at tag. 02:30 - 02:45 0.25 DRILL P PROD1 Orient TF to 120L. 02:45 - 05:00 2.25 DRILL P PROD1 Drilling turn in Zone 3, 2.8/2.8 bpm, 3000 psi, 120L, 3 fph, 42 deg incl, Drilled to 10151 ft, Hedgehog bit only making 3 fph, decision made to POH & run tricone. 05:00 - 06:30 1.50 DRILL P PROD1 POH for new bit. 2.8 BPM , 2800 PSI. 06:30 - 07:00 0.50 DRILL P PROD1 M/U HC 3.75" Tri-cone bit to drill Zone 3. Check motor and orienter. 07:00 - 09:00 2.00 DRILL P PROD1 RIH with MWD BHA #15, 1.04 deg motor and 3.75" HC tri-cone bit. RIH clean to TD. Tag TD at 10165 ft and correct depth to 10,151 ft. 09:00 - 09:10 0.17 DRILL P PROD1 Orient TF to 90L. 09:10 - 10:30 1.33 DRILL P PROD1 Drilling Zone 3, break in bit with 2.2 bpm, 2300 psi, light WOB, 90L TF, Drilled to 10170'. 10:30 - 10:40 0.17 DRILL P PROD1 Orient TF to 90R. 10:40 - 13:00 2.33 DRILL P PROD1 Drilling Zone 3, 2.2 bpm, 2300 psi, 3-5K WOB, 90R TF, Drilled to 10190'. 2.8 on botttom drilling hrs. 13:00 - 14:00 1.00 DRILL P PROD1 Drilling Zone 3, 2.2 bpm, 2300 psi, 3-5K WOB, 80R TF, Drilled to 10202'. 3.8 drilling hrs. 14:00 - 14:45 0.75 DRILL P PROD1 Drilling Zone 3, 2.2 bpm, 2300 psi, 3-5K WOB, 80R TF, Drilled to 10212'. 4.5 drilling hrs. 14:45 - 16:30 1.75 DRILL P PROD1 POH. Clean hole. Circ. Flopro across the top while POH. 16:30 - 16:50 0.33 DRILL P PROD1 RIG EVACUATION DRILL. Meet in primary muster area. All personnel at muster area and accounted for in under 2 minutes. Review safety concerns of rig evacuation with crew. 16:50 - 17:30 0.67 DRILL P PROD1 C/O Bits, recovered all of tri-cone bit. M/U PDC bit for last 30 ft of zone 3. C/O MWD prope. 17:30 - 19:30 2.00 DRILL P PROD1 RIH with MWD BHA #16 with 1.04 deg motor and Bit #8, Security PDC, FM2533R, 5 bladed bit with large cutters. Shallow test Sperry tools. OK. RIH & tag @ window. PUH & Orient TF to ROHS. RIH clean thru window. 19:30 - 19:55 0.42 DRILL P PROD1 Log up GR & tie-into RA PIP tag - subtract 17' from CTD. Printed: 10/6/2003 1:51:08 PM "W" .... qÎJoê,~at~:nEsX;~::'~: R1Po~ Page 12 of 16 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: G-12B G-12B REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Start: 9/13/2003 Rig Release: 9/30/2003 Rig Number: N1 Spud Date: End: Date From - To Task Code NPT Phase Description of Operations ._-----_._._-_._-_.-._~..__._..__..__.__. 9/23/2003 19:55 - 20:05 0.17 DRILL P PROD1 Continue RIH & tag @ 10179'. 20:05 - 20: 10 0.08 DRILL P PROD1 Orient TF to 80R 20:10 - 20:30 0.33 DRILL P PROD1 Ream to 10206' with 75R TF, 2.5/2.5bpm, 2800/2850psi, 225fph ave ROP. 20:30 - 21 :30 1.00 DRILL P PROD1 Drill to 10226' with 65R TF, 2.5/2.5bpm, 2900/3350psi, 20fph ave ROP. Observe MWD quit pulsing. 21 :30 - 22:20 0.83 DRILL N DFAL PROD1 Troubleshoot MWD. Recycle pumps to get pulses - no luck. PUH above window & recycle pumps again - no success. 22:20 - 23:45 1.42 DRILL N DFAL PROD1 POOH for MWD. 23:45 - 00:00 0.25 DRILL N DFAL PROD1 PJSM for C/O drilling BHA #16. 9/24/2003 00:00-01:15 1.25 DRILL N DFAL PROD1 UD MWD package. Check bit - OK (as went-in). C/O MWD probe - had to use the same directional module that was POOH as spare unit is not OK. Scribe tools. M/U injector. 01 :15 - 03:20 2.08 DRILL N DFAL PROD1 RIH with drilling BHA #17. SHT tools - OK. Continue RIH & tag TD @ 10244'. Correct CTD to 10226'. 03:20 - 03:30 0.17 DRILL N DFAL PROD1 Orient TF to 130L. Observe faulty Nordic Gen-1 motor - seeing water in the oil. 03:30 - 04:00 0.50 DRILL N SFAL PROD1 POOH to 9000' to circulate above window. 04:00 - 06:30 2.50 DRILL N SFAL PROD1 W.O. on Cat rep to determine extent of damage on faulty Gen-1 motor. Meawhile park bit @ 9000' & circ @ min rate. Determined that Gen-1 motor needs replacement. Repair time est - +/- 24 hrs. 06:30 - 08:00 1.50 DRILL N SFAL PROD1 POH. 08:00 - 08:30 0.50 DRILL N SFAL PROD1 UO BHA. 08:30 - 13:00 4.50 DRILL N SFAL PROD1 Remove Generator set #1. Cat man on location. 13:00 - 18:30 5.50 DRILL N SFAL PROD1 Install used Generator set from Nordic 2. Full package, so less wiring and piping needed. 18:30 - 21 :30 3.00 DRILL N SFAL PROD1 Commission & load test newly installed Gen set 1 - OK. 21 :30 - 22:05 0.58 DRILL N SFAL PROD1 PJSM. M/U drilling BHA #18 with 1.04 deg bend motor, Sperry shock sub, GRlMWD & re-run bit #10 [SEC DBS FM2533R). Scribe tools. M/U injector. 22:05 - 23:45 1.67 DRILL N SFAL PROD1 RIH with drilling BHA #18. SHT tools - OK. Continue RIH below window to 9855'. 23:45 - 00:00 0.25 DRILL N SFAL PROD1 Log up GR for tie-into RA PIP tag. 9/25/2003 00:00 - 00:40 0.67 DRILL N SFAL PROD1 Continue logging-up GR & tie-into RA PIP tag - subtract 21' from CTD. 00:40 - 00:55 0.25 DRILL N SFAL PROD1 RIH & tag TD @ 10231'. 00:55 - 01 :15 0.33 DRILL N SFAL PROD1 Orient TF to 90L. 01 :15 - 03:05 1.83 DRILL P PROD1 Drill to 10255' with 90-100L TF, 2.5/2.5bpm, 2900/3300psi, 20fph ave ROP. Should have penetrated Zone-2 @ 10240'-10245' . 03:05 - 04:00 0.92 DRILL P PROD1 Orient & drill to 10267' with 70-90L TF, 2.5/2.5bpm, 2950/3300psi, 15fph ave ROP. 04:00 - 05:05 1.08 DRILL P PROD1 Orient & drill to 10279' with 65L TF, 2.5/2.5bpm, 2950/3250psi, 15fph ave ROP. 05:05 - 05: 15 0.17 DRILL P PROD1 Orient TF to 70R. 05:15 - 06:00 0.75 DRILL P PROD1 Drill to 10300' with 40-65L TF, 2.5/2.5bpm, 2950/3250psi, 30fph ave ROP. 06:00 - 07:30 1.50 DRILL P PROD1 Drill Zone 2 with 65L TF, 2.5/2.5 bpm, 2950/3250 psi, 45 deg incl, Drilled to 10,315'. 07:30 - 09:30 2.00 DRILL P PROD1 Drill Zone 2 with 65L TF, 2.8/2.8 bpm, 3150/3550 psi, 46 deg incl, Drilled to 10,335'. 09:30 - 10:20 0.83 DRILL P PROD1 Drill Zone 2 with 65L TF, 2.8/2.8 bpm, 3200/3600 psi, 47 deg Printed: 10/6/2003 1 :51 :08 PM ~ BP EXPLORATION Operations Summary Report Page 13 of 16 Legal Well Name: G-128 Common Well Name: G-128 Spud Date: Event Name: REENTER+COMPLETE Start: 9/13/2003 End: Contractor Name: NORDIC CALISTA Rig Release: 9/30/2003 Rig Name: NORDIC 1 Rig Number: N1 . . NPT ¡ .. .. ... Date Fron):i·:Yo ¡ Hours Task Code Phase l Descriptiolï QfOþerätions _......~....- ----.--. 9/25/2003 09:30 - 10:20 0.83 DRILL P PROD1 incl, Drilled to 10,341'. 10:20 - 12:40 2.33 DRILL P PROD1 POH for bi-center bit and Sperry Resistivity tool. Flag CT at 9600' EOP. 12:40 - 14:45 2.08 DRILL P PROD1 C/O motor, bit and M/U Sperry Resistivity tool. Test Res tool. 14:45 - 16:45 2.00 DRILL P PROD1 RIH with MWD RES BHA #19, 1.37 Deg motor and Smith Bi-center 3.75 X 4.125" bit. Tie-into coil flag, -22 ft. 16:45 - 17:00 0.25 DRILL N SFAL PROD1 Park bit at 9700' while repairing hyd hose on Gen Set #1. 17:00 - 17:15 0.25 DRILL P PROD1 Orient TF to get thru window. 17:15-18:30 1.25 DRILL P PROD1 RIH. Ream down at misc. depths from 10100' - TD tagged @ 10341'. Bi-center bit has longer 3.75" gauge than bit. 18:30 - 18:35 0.08 DRILL P PROD1 Orient TF to 70R. 18:35 - 19:30 0.92 DRILL P PROD1 Drill to 10354' with 40-50R TF, 2.6/2.6bpm, 3050/3350psi, 30fph ave ROP. Tight spot @ 10354'. Pulled free with 80k. 19:30 - 22:25 2.92 DRILL P PROD1 Drill to 10414' with 80-90R TF, 2.6/2.6bpm, 3050/3350psi, 25fph ave ROP. 22:25 - 22:40 0.25 DRILL P PROD1 Orient TF to 60R. 22:40 - 23:50 1.17 DRILL P PROD1 Drill to 10450' with 60R TF, 2.6/2.6bpm, 3050/3350psi, 35fph ave ROP. 23:50 - 00:00 0.17 DRILL P PROD1 Orient TF to LOHS. 9/26/2003 00:00 - 00:05 0.08 DRILL P PROD1 Continue orienting TF to 65L. 00:05-01:10 1.08 DRILL P PROD1 Drill to 10500' with 60L TF, 2.6/2.6bpm, 3050/3300psi, 60fph ave ROP. 01:10 - 02:10 1.00 DRILL P PROD1 Wiper trip to window. Pulled tight from 10320' to 10254'. Pulled free with 80k. 02:10 - 02:40 0.50 DRILL P PROD1 RBIH clean to btm. 02:40 - 02:55 0.25 DRILL P PROD1 Orient TF to 80L. 02:55 - 03:25 0.50 DRILL P PROD1 Drill to 10511' with 70L TF, 2.6/2.6bpm, 3050/3300psi, 35fph ave ROP. 03:25 - 03:50 0.42 DRILL P PROD1 Orient TF to 120L. 03:50 - 06:30 2.67 DRILL P PROD1 Drill to 10590' with 115L TF, 2.6/2.6bpm, 3050/3300psi, 45fph ave ROP. 06:30 - 07:00 0.50 DRILL P PROD1 Wiper trip to window. Clean hole. RIH clean to bottom. 07:00 - 09:30 2.50 DRILL P PROD1 Drilling, 2.6/2.6 bpm, 3000 - 3600 psi, 80R, 74 deg incl, Drilled to 10616'. 09:30 - 11 :00 1.50 DRILL P PROD1 Drilling, 2.6/2.6 bpm, 3000 - 3600 psi, 90R, 74 deg incl, Drilled to 10650'. 11 :00 - 12:00 1.00 DRILL P PROD1 Drilling, 2.6/2.6 bpm, 3000 - 3600 psi, 90R, 74 deg incl, Drilled to 10697'. 12:00 - 12:30 0.50 DRILL P PROD1 Wiper trip to window. Clean trip out. 12:30 - 13:00 0.50 DRILL P PROD1 Log tie-in to RA tag. Add 7 ft CTD. 13:00 - 13:45 0.75 DRILL P PROD1 Log down with MAD pass with RES / GR at 15 FPM. 13:45 - 15:00 1.25 DRILL P PROD1 Drilling, 2.6/2.6 bpm, 3000 - 3600 psi, 90R, 80 deg incl, Drilled to 10764'. 15:00 - 15:30 0.50 DRILL P PROD1 Orient TF around. 15:30 - 17:15 1.75 DRILL P PROD1 Drilling, 2.6/2.6 bpm, 3100 - 3600 psi, 90R, 80 deg incl, Drilled to 10825'. Landed well at 8977 ft. 17:15 - 18:20 1.08 DRILL P PROD1 Wiper trip to window. Clean hole. RIH clean to TD. 18:20 - 18:30 0.17 DRILL P PROD1 Drilling, 2.6/2.6 bpm, 3100 - 3600 psi, 90R, 90 deg incl, Drilled to 10846'. 18:30 - 18:45 0.25 DRILL P PROD1 Orient TF to 120R. 18:45 - 20:00 1.25 DRILL P PROD1 Drill to 10895' with 130R TF, 2.6/2.6bpm, 3100/3600psi, 60fph Printed: 10/6/2003 1:51:08 PM .... - Page 140f 16 BP EXPLORATION Operations Summary Report' Legal Well Name: G-12B Common Well Name: G-12B Event Name: REENTER+COMPLETE Contractor Name: NORDIC CALISTA Rig Name: NORDIC 1 Date [From - To Hours! Ta~_~._! ~~.~~1~.-':: I 9/26/2003 18:45 - 20:00 20:00 - 20:35 20:35 - 20:50 20:50 - 21 :30 21 :30 - 22:05 22:05 - 23: 10 23:10 - 00:00 9/27/2003 00:00 - 00:10 00:10 - 02:55 02:55 - 03:30 03:30 - 04:20 04:20 - 04:50 04:50 - 05:05 05:05 - 06:20 06:20 - 07:00 07:00 - 08:30 08:30 - 10:00 10:00 - 12:00 12:00-14:10 14:10 - 15:00 15:00 - 15:20 15:20 - 16:20 16:20 - 18:40 18:40 - 19:30 19:30 - 20:00 20:00 - 20:45 20:45 - 21 :30 21 :30 - 21 :45 21 :45 - 00:00 9/28/2003 00:00 - 00:50 00:50 - 02:45 1.25 DRILL P 0.58 DRILL P 0.25 DRILL P 0.67 DRILL P 0.58 DRILL P 1.08 DRILL P 0.83 DRILL P 0.17 DRILL P 2.75 DRILL P 0.58 DRILL P 0.83 DRILL P 0.50 DRILL P 0.25 DRILL P 1.25 DRILL P 0.67 DRILL P 1.50 DRILL P 1.50 DRILL P 2.00 DRILL P 2.17 DRILL P 0.83 DRILL P 0.33 DRILL P 1.00 DRILL P 2.33 DRILL P 0.83 DRILL P 0.50 CASE P 0.75 CASE P 0.75 CASE P 0.25 CASE P 2.25 CASE P 0.83 CASE P 1.92 CASE P Phase PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 COMP COMP COMP COMP COMP COMP COMP Start: 9/13/2003 Rig Release: 9/30/2003 Rig Number: N1 Spud Date: End: Description of Operations ...-..-.. -..---..---.------ ave ROP. Wt stacking. Drill to 10921' with 130R TF, 2.6/2.6bpm, 3100/3600psi, 60-100fph ave ROP. Orient TF to 20R. Drill to 10942' with 60R TF, 2.6/2.6bpm, 3100/3600psi, 40fph ave ROP. Stacking wt - will swap mud after drilling pass expected fault zone. Orient & drill to 10966' with 80-90R TF, 2.6/2.6bpm, 3100/3600psi, 50fph ave ROP. Wiper trip clean to window. RBIH. Orient & drill to 11009' with 100R TF, 2.6/2.6bpm, 3100/3600psi, 75fph ave ROP. Orient TF to 80R. Drill to 11146' with 80-100R TF, 2.7/2.7bpm, 3200/3600psi, 60-150fph ave ROP. Meanwhile swap well to new SFFP mud with 75k LSRV, 3% L-T & 4ppb K-G. Wiper trip clean to window. Log up GR & tie-into RA PIP tag - subtract 2' from CTD. RBIH clean to btm. Orient TF to 80R. Drill to 11192' with 75R TF, 2.7/2.7bpm, 3150/3600psi, 50-85fph ave ROP. Orient TF to left. Drilling, 2.6/2.6 bpm, 3100 -3500 psi, 120L, 90 deg, Stacking weight. Drilled to 11210'. Drilled into shale at 11190'. Wiper trip to window. Drilling, 2.6/2.6 bpm, 3100 -3500 psi, 140L, 89 deg, Stacking weight. Drilled to 11255'. Drilled out of shale at 11245'. Drilling, 2.6/2.6 bpm, 3100 -3500 psi, 90L, 82 deg, Drilled to 11360'. Well at TD. Wiper trip to window. Clean hole. Log final Tie-in with RA tag. On depth, no correction. RIH to TD. Tag Final TD at 11,360 ft BKB. POH to run Liner. Flag coil at 9100 ft EOP and 7600 ft EOP. OOH. SIB injector. PJSM. UO BHA. Bit grades 3/2/1 with some minor abrasion on the outer edge blades (very good for 1 st trial). Cut CT & M/U Baker CTC. Pull test to 35k & P/test to 3500 psi - OK. Meanwhile download resistivity data. Load wiper dart & launch same. Chase dart with mud & pig CT. Dart bumped on catcher @ 60bbls. PJSM. RIU for RIH completion liner. C/O lubricator for convenient working height. PIT lubricator to 3500psi - OK. PJSM for M/U & RIH completion liner. M/U float equipment, 20jts 2-7/8" 6.16# L-80 STL liners, pups, LSL sub, 47jts 3-3/16" 6.2# L-80 TCllliners. M/U Baker CTLRT with, XO, 3-1/2" pups & 'X' nipple. M/U injector. RIH with liner on CT. See flag @ 9769'. Correct CTD (-22') to 9747'. Check up wt - 41k, down wt - 23k. RIH clean @ 50 fpm Printed: 10/6/2003 1:51:08 PM /~ - ... ..: .... BP EXPLORATION Page 15 Öf 16 Operations Sumtn:ary Report . '. Legal Well Name: G-12B Common Well Name: G-12B Spud Date: Event Name: REENTER+COMPLETE Start: 9/13/2003 End: Contractor Name: NORDIC CALISTA Rig Release: 9/30/2003 Rig Name: NORDIC 1 Rig Number: N1 ! NPT I Date From~To Hours Ta$k' Code Phase ¡Description of Operations I -----...-.-.- , - -. --.. ---- 9/28/2003 00:50 - 02:45 1.92 CASE P COMP thru window. See 2nd flag -3' off depth. Tag TD solid @ 11350' CTD. P/U @ 48k. RBIH @ 20k & retag TO solid @ same depth. 02:45 - 03:35 0.83 CASE P COMP Load 5/8" steel ball & circ with mud @ 2.5/2.5bpm, 2500psi. Set down 10k Ibs down on CTLRT. Continue circ ball to seat. Slow down @ 35bbls away. Ball on seat @ 47.8bbls. Pressure up to 3900psi & release CTLRT. P/U @ 29k & confirm release. Stack back 1 Ok Ibs on CTLRT 03:35 - 07:30 3.92 CASE P COMP Displace well to 2% KCI at 3.0/3.0bpm & 21 OOpsi. Meanwhile RlU Dowell cementers. Ship back used mud to MI. Clean rig pits. Fill with 2% KCL water. 07:30 - 07:45 0.25 CEMT P COMP SAFETY MEETING. Review procedure, hazards and mitigation for cement job. 07:45 - 08:15 0.50 CEMT P COMP Press test cement line. Batch cement. Cement at wt at 08:10 HRS. 08: 15 - 09:00 0.75 CEMT P COMP Stg 3 bbl KCL water. Stg 22.2 bbl, G cement, 15.8 ppg. 2.4 bpm, 2100 psi. Stop pump. Purge cement line. Insert dart. Displace dart / cement with 30 bbl Biozan water and displace with KCL water. 2.8 bpm, 2100 psi. Slow pump at 56 bbls. Dart on seat at 60.5 bbls. sheared at 3200 psi. Displace at 3.0 bpm, 2600 psi, Slow at 73 bbls, bump plug at 75.3 bbls [75.4 bbls calc.]. Hold 2000 psi. OK. Check back flow. OK 09:00 - 10:30 1.50 CEMT P COMP Sting out from top of liner. POH. Replace CT volume with Biozan. 10:30 - 12:15 1.75 CEMT P COMP LlO BKR CTLRT. Prep to run cleanout BHA with SWS Memory CNLlGRlCCL. Offload extra joints of liner. Clean cuttings tank. 12:15 - 12:30 0.25 EVAL P COMP Safety Meeting. Review procedure, hazards and mitigation for CNL log / clean out BHA M/U. 12:30 - 15:10 2.67 EVAL P COMP M/U 2.3" mill, motor, SWS carrier with Memory CNLlGRlCCL, circ sub, hyd discon, 36 stds of CSH workstring, hyd discon, checks and CTC. Total Length = 2271 ft. 15:10 - 16:20 1.17 EVAL P COMP RIH with Memory CNLlGRlCCL with motor and mill. 16:20 - 18:45 2.42 EVAL P COMP Log down with CNL from 9100 ft at 30 fpm while circ in 15 BBL, high vis [150,000 CP ] FloPro Per pill. SWS lab reported Cement at 1000 psi CT. Tag PBTD at 11,328 ft and correct to 11,324 ft. Continue to circ FloPro pill to bit. 66 bbls. 18:45 - 19:25 0.67 EVAL P COMP Log up @ 60fpm from PBTD to 9000' while laying-in perf pill in liner. 19:25 - 20:25 1.00 EVAL P COMP POOH from 9000'. 20:25 - 21 :15 0.83 EVAL P COMP OOH. SIB injector. Pop off & drop 5/8" ball to open circ sub. Flush 1-1/4" CSH. 21 :15 - 21 :30 0.25 EVAL P COMP PJSM on RIB 1-1/4" CSH. 21 :30 - 23:00 1.50 EVAL P COMP LID 20 singles of 1-1/4" CSH. RIB 26 doubles. 23:00 - 23:15 0.25 EVAL P COMP PJSM for LID SWS source & logging tool. 23:15 - 00:00 0.75 EVAL P COMP LID MCNLlGRlCCL logging tool. Check for data quality - good. 9/29/2003 00:00 - 08:00 8.00 BOPSUF P COMP Perform weekly BOPE pressure/function test. AOGCC test witness waived by John Crisp. C/O washed out valve #15 on choke manifold. Meanwhile download & fax CNL data to ANC Printed: 10/612003 1:51:08 PM - 'WI" m BP EXPLORATION Page 16 of 16 q:perations Summary Report . Legal Well Name: G-128 Common Well Name: G-128 Spud Date: Event Name: REENTER+COMPLETE Start: 9/13/2003 End: Contractor Name: NORDIC CALISTA Rig Release: 9/30/2003 Rig Name: NORDIC 1 Rig Number: N1 From -To I Hours I .. . .. . Date Task Code NPT ¡ Phase ¡:::¡ Desçription of Operations --- -.-.....--- -. ---- 9/29/2003 00:00 - 08:00 8.00 BOPSUF P COMP Geo - confirms no changes in perf intervals. C/O failed blind / shear rams. Re-test. OK. 08:00 - 09:00 1.00 CEMT P COMP Pressure test liner lap with 2000 psi for 30 minutes. Chart press test. 2040 initial press. 2000 psi final press. Good Test. Bleed down press to zero. 09:00 - 09:15 0.25 PERF P COMP SAFETY MEETING. Review procedure, hazards and mitigation for M/U of SWS perf guns. 09:15 -11:00 1.75 PERF P COMP M/U SWS 2", PowerJet perf guns, loaded with 4 spf. 11:00-12:30 1.50 PERF P COMP M/U BKR hyd disc, RIH w/ 26 stds CSH workstring, M/U SWS Hyd Disc, CTC. BHA = 2239 ft. 12:30 - 14:30 2.00 PERF P COMP RIH with Perf BHA on CT. Tag PBTD at 11325 ft. Correct depth to 11,322 ft. from SWS memory CNLlGR log of 09/28/03. Pump 20 bbls of 150,000 CP FloPro perf pill. 14:30 - 15:00 0.50 PERF P COMP Position bottom perforating charge at 11,310 ft BKB. Insert 5/8" steel ball and displace with HV FloPro pill. Displace pill with KCL water. Ball on seat at 53.4 bbls. Sheared firing head at 3000 psi. 15:00 - 16:30 1.50 PERF P COMP POH with perf guns. 16:30 - 18:30 2.00 PERF P COMP Layout CSH in singles. 18:30 - 18:45 0.25 PERF P COMP SAFETY MEETING. Review procedure, hazards and mitigation for laying out SWS perf guns. Possible trapped pressure with 3 blanks. 18:45 - 22:00 3.25 PERF P COMP LID perf guns & blanks. ASF! Load out perf guns & blanks. RID SWS. 22:00 - 22:30 0.50 RIGD P COMP M/U FP nozzle BHA. M/U injector. 22:30 - 23: 10 0.67 RIGD P COMP RIH FP nozzle BHA to 2025'. 23:10 - 23:30 0.33 RIGD P COMP POOH freeze protecting with 60/40 MeOH. SI master valve (24-1/2 turns). LID nozzle BHA. 23:30 - 23:40 0.17 RIGD P COMP PJSM. PfT N2 lines - OK. 23:40 - 00:00 0.33 RIGD P COMP Blow down CT with N2. Meanwhile clean out pits & tanks. 9/30/2003 00:00 - 00:30 0.50 RIGD P POST Continue blowing down CT with N2 & bleed off. 00:30 - 02:30 2.00 RIGD P POST PJSM. NID BOP. N/U & P/test tree cap. Release rig at 02:30 on 9/30103. Printed: 10/6/2003 1:51:08 PM . AOGCC Howard Okland 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 . Re: Distribution of Survey Data for Well G-12B Dear Dear Sir/Madam: Enclosed are two survey hard copies. Tie-on Survey: Window / Kickoff Survey: Projected Survey: 9,700.00' MD 9,780.00' MD 11,360.00' MD (if applicable) Please call me at 273-3545 if you have any questions or concerns. Regards, William T. Allen Survey Manager Attachment(s) ~~~i\\~ (~03 -) ill 08-0ct-03 Sperry-Sun Drilling Services North Slope Alaska BPXA PBU WOA G Pad G-12B Job No. AKMW2669096, Surveyed: 27 September, 2003 Survey Report 6 October, 2003 Your Ref: API 500292059702 Surface Coordinates: 5969307.00 N, 657854.00 E (70019' 22.2212" N, 148043'12.2020" W) Grid Coordinate System: NAD27 Alaska State Planes, Zone 4 Surface Coordinates relative to Project H Reference: 969307.00 N, 157854.00 E (Grid) Surface Coordinates relative to Structure Reference: 2440.23 N, 1604.74 E (True) Kelly Bushing: 65. 70ft above Mean Sea Level Elevation relative to Project V Reference: 65.70ft Elevation relative to Structure Reference: 65.70ft 551::J&¡tI"""V-55U:í! [jAIL LING SEAVlces A Halliburton Company DEFINITIVE . . Survey Ref: svy4108 Sperry-Sun Drilling Services Survey Report for PBU_WOA G Pad - G-12B Your Ref: APIS002920S9702 Job No. AKMW2669096, Surveyed: 27 September, 2003 BPXA North Slope Alaska Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (0/100ft) 9700.00 37.270 284.400 8360.08 8425.78 725.32 N 3810.62 W 5969952.00 N 654028.97 E -3856.17 Tie On Point MWD Magnetic 9777.00 37.040 287.090 8421.45 8487.15 737.93 N 3855.37 W 5969963.67 N 653983.96 E 2.131 -3902.66 9780.00 37.030 287.200 8423.85 8489.55 738.46 N 3857.10 W 5969964.17 N 653982.22 E 2.233 -3904.47 Window Point 9820.75 41.940 301.580 8455.36 8521.06 749.25 N 3880.48 W 5969974.47 N 653958.62 E 25.406 -3929.98 . 9860.33 45.600 320.830 8484.06 8549.76 767.23 N 3900.78 W 5969992.01 N 653937.95 E 34.789 -3954.65 9890.31 42.910 333.570 8505.58 8571.28 784.71 N 3912.11 W 5970009.25 N 653926.25 E 30.942 -3970.60 9920.42 39.740 347.490 8528.23 8593.93 803.33 N 3918.78 W 5970027.72 N 653919.19 E 32.234 -3982.41 9950.40 36.650 0.700 8551.83 8617.53 821.67 N 3920.75 W 5970046.02 N 653916.84 E 29.077 -3989.66 9980.28 32.600 16.390 8576.46 8642.16 838.35 N 3918.36 W 5970062.74 N 653918.87 E 32.672 -3992.25 10012.04 32.330 33.480 8603.32 8669.02 853.67 N 3911.25 W 5970078.21 N 653925.66 E 28.820 -3989.93 10043.45 37.530 44.400 8629.09 8694.79 867.53 N 3899.90 W 5970092.31 N 653936.72 E 25.838 -3983.13 10073.32 41 .150 50.920 8652.19 8717.89 880.24 N 3885.89 W 5970105.31 N 653950.45 E 18.381 -3973.46 10100.47 43.700 58.680 8672.25 8737.95 890.75 N 3870.93 W 5970116.14 N 653965.19 E 21.434 -3962.22 10130.05 45.370 60.440 8693.33 8759.03 901.26 N 3853.05 W 5970127.02 N 653982.85 E 7.020 -3948.19 10160.86 44.050 65.550 8715.23 8780.93 911.11 N 3833.75 W 5970137.27 N 654001.93 E 12.427 -3932.62 10193.98 44.230 68.720 8739.01 8804.71 920.06 N 3812.51 W 5970146.67 N 654022.98 E 6.687 -3914.92 10221.08 44.760 76.830 8758.35 8824.05 925.67 N 3794.39 W 5970152.66 N 654040.97 E 21.055 -3899.24 10250.81 43.790 71.720 8779.65 8845.35 931.29 N 3774.43 W 5970158.69 N 654060.82 E 12.432 -3881.79 10280.13 44.230 65.020 8800.74 8866.44 938.79 N 3755.52 W 5970166.59 N 654079.57 E 15.943 -3865.89 10310.70 46.700 70.130 8822.19 8887.89 947.08 N 3735.38 W 5970175.30 N 654099.53 E 14.392 -3849.06 10340.97 49.690 77.360 8842.38 8908.08 953.35 N 3713.74 W 5970182.03 N 654121.03 E 20.350 -3830.20 . 10371.48 56.120 86.870 8860.80 8926.50 956.60 N 3689.68 W 5970185.78 N 654145.01 E 32.558 -3808.14 10400.83 57.710 95.680 8876.84 8942.54 956.04 N 3665.14 W 5970185.73 N 654169.57 E 25.718 -3784.50 10431.77 60.260 105.020 8892.81 8958.51 951.25 N 3639.10 W 5970181.50 N 654195.69 E 27.141 -3758.21 10461.87 64.050 106.610 8906.87 8972.57 943.99 N 3613.50 W 5970174.78 N 654221.44 E 13.429 -3731.61 1 0492.48 71.370 100.260 8918.48 8984.18 937.46 N 3585.98 W 5970168.83 N 654249.09 E 30.651 -3703.38 10529.84 74.010 91.800 8929.61 8995.31 933.74 N 3550.55 W 5970165.85 N 654284.60 E 22.740 -3668.41 1 0561 .12 74.450 85.640 8938.12 9003.82 934.41 N 3520.47 W 5970167.16 N 654314.65 E 19.003 -3639.84 10591.36 74.010 79.120 8946.35 9012.05 938.27 N 3491.64 W 5970171.62 N 654343.39 E 20.799 -3613.40 10620.11 73.920 81.760 8954.29 9019.99 942.86 N 3464.40 W 5970176.78 N 654370.53 E 8.831 -3588.69 6 October, 2003 - 8:37 Page 2 of 4 DrillQuest 3.03.02.005 Sperry-Sun Drilling Services Survey Report for PBU_WOA G Pad - G-12B Your Ref: API 500292059702 Job No. AKMW2669096, Surveyed: 27 September, 2003 BPXA North Slope Alaska Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (0/100n) 10652.82 77.890 91.630 8962.27 9027.97 944.66 N 3432.78 W 5970179.25 N 654402.11 E 31.674 -3558.97 10686.12 81.500 98.320 8968.24 9033.94 941.81 N 3400.16 W 5970177.08 N 654434.78 E 22.540 -3526.95 10718.79 85.990 107.310 8971.80 9037.50 934.60 N 3368.54 W 5970170.54 N 654466.55 E 30.606 -3494.60 10754.08 86.260 115.240 8974.19 9039.89 921.84 N 3335.76 W 5970158.47 N 654499.59 E 22.433 -3459.52 10788.10 86.700 123.350 8976.28 9041.98 905.24 N 3306.17 W 5970142.50 N 654529.52 E 23.829 -3426.37 . 10823.54 91.980 122.820 8976.69 9042.39 885.90 N 3276.49 W 5970123.79 N 654559.60 E 14.973 -3392.33 10854.99 93.300 117.710 8975.24 9040.94 870.07 N 3249.36 W 5970108.53 N 654587.06 E 16.764 -3361.77 10885.21 90.220 121.230 8974.31 9040.01 855.21 N 3223.07 W 5970094.23 N 654613.65 E 15.472 -3332.28 10921.32 86.870 131.280 8975.23 9040.93 833.90 N 3194.00 W 5970073.53 N 654643.16 E 29.325 -3298.25 10952.00 91.630 136.560 8975.63 9041.33 812.63 N 3171.92 W 5970052.73 N 654665.69 E 23.166 -3270.91 10982.72 92.420 143.260 8974.55 9040.25 789.16 N 3152.16 W 5970029.68 N 654685.94 E 21.947 -3245.15 11011.70 90.400 152.770 8973.83 9039.53 764.61 N 3136.83 W 5970005.47 N 654701.78 E 33.536 -3223.32 11040.62 91.720 158.060 8973.30 9039.00 738.33 N 3124.81 W 5969979.44 N 654714.35 E 18.849 -3204.14 11071.44 92.250 163.170 8972.23 9037.93 709.28 N 3114.59 W 5969950.62 N 654725.18 E 16.659 -3185.87 11105.26 90.570 170.570 8971.40 9037.10 676.38 N 3106.91 W 5969917.88 N 654733.55 E 22.430 -3168.91 11137.95 89.070 180.970 8971.50 9037.20 643.83 N 3104.51 W 5969885.39 N 654736.64 E 32.142 -3157.09 11168.20 90.660 189.250 8971.57 9037.27 613.72 N 3107.20 W 5969855.23 N 654734.58 E 27.871 -3150.86 11198.25 90.750 190.660 8971.20 9036.90 584.13 N 3112.39W 5969825.54 N 654730.01 E 4.701 -3147.18 11228.43 89.780 186.780 8971.06 9036.76 554.31 N 3116.97W 5969795.62 N 654726.06 E 13.252 -3142.83 11260.85 83.170 180.440 8973.06 9038.76 522.05 N 3119.01 W 5969763.33 N 654724.70 E 28.218 -3135.36 11297.25 81.500 173.210 8977.92 9043.62 486.05 N 3117.02 W 5969727.38 N 654727.45 E 20.212 -3122.93 11330.56 81.590 165.990 8982.82 9048.52 453.67 N 3111.07 W 5969695.13 N 654734.07 E 21.441 -3107.77 . 11360.00 81.590 165.990 8987.13 9052.83 425.41 N 3104.02 W 5969667.03 N 654741.72 E 0.000 -3092.77 Projected Survey All data is in Feet (US Survey) unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well Reference. Northings and Eastings are relative to Well Reference. Global Northings and Eastings are relative to NAD27 Alaska State Planes, Zone 4. The Dogleg Severity is in Degrees per 100 feet (US Survey). Vertical Section is from Well Reference and calculated along an Azimuth of 107.000° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 11360.00ft., The Bottom Hole Displacement is 3133.04ft., in the Direction of 277.804° (True). 6 October, 2003 . 8:37 Page 3 of 4 DrillQuest 3.03.02.005 Sperry-Sun Drilling Services Survey Report for PBU_WOA G Pad - G-12B Your Ref: API 500292059702 Job No. AKMW2669096, Surveyed: 27 September, 2003 BPXA North Slope Alaska Comments Measured Depth (ft) Station Coordinates TVD Northings Eastings (ft) (ft) (ft) Comment 9700.00 9780.00 11360.00 8425.78 8489.55 9052.83 725.32 N 738.46 N 425.41 N 3810.62 W 3857.10 W 3104.02 W Tie On Point Window Point Projected Survey . Survey tool program for G-12B From Measured Vertical Depth Depth (ft) (ft) To Measured Vertical Depth Depth Survey Tool Description (ft) (ft) 0.00 9700.00 0.00 9700.00 8425.78 11360.00 8425.78 BP High Accuracy Gyro (G-12) 9052.83 MWD Magnetic (G-12B) . 6 October, 2003 - 8:37 Page 4 of 4 DrillQuest 3.03.02.005 . WELL LOG TRANSMITTAL f)03- I ~/l . ProActive Diagnostic Services, Inc. To: State of Alaska AOGCC 333 W. 7"'Street Suite # 700 Anchorage. Alaska 99501 RE: Distribution - Final Print[s) The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention of : Joey Burton / Jeni Thompson ProActive Diagnostic Services. Inc. P. O. Box 1369 Stafford. TX 77497 BP Exploration (Alaska). Inc. Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Anchorage. AK 99508 loG DIGITAL MYLAR / BLUE LINE REPORT WELL DATE TYPE OR SEPIA PRINT(S) OR CD-ROM FILM COLOR Open Hole 1 1 1 . Res. Eva!. CH 1 1 1 8-128 9-17-03 Mech. CH It~¡~ 1- j..~ Caliper Survey Signed: "'--'",-- '" "': ~ t"\ "'--'- lV, ~\~'''' \. ç ~ ':"').~V··~~ Date: '. ,." cc··r \,; Ò /.: Print Name: PRoACTivE DiAGNOSTic SERvicES, INC., PO Box 1 }b9 STAffoRd IX 77477 Phone:(281) 565-9085 Fax:(281) 565-1369 E-mail: pds@memorylog.com Website: www.memorylog.com .;~~~\\\ ~ . . FRANK H. MURKOWSKI, GOVERNOR AI/ASIiA OIL AND GAS CONSERVATION COMMISSION 333 W. 7'" AVENUE, SUITE 100 ANCHORAGE. ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Ted Stagg CT Drilling Engineer BP Exploration (Alaska), Inc. PO Box 196612 Anchorage AK 99519-6612 Re: Prudhoe Bay Unit G-12B BP Exploration (Alaska), Inc. Permit No: 203-141 Surface Location: 2334' SNL, 2367' WEL, Sec. 12, TIIN, R13E, UM Bottomhole Location: 1863' SNL, 72' WEL, Sec. 11, T11N, R13E, UM Dear Mr. Stagg: Enclosed is the approved application for permit to redrill the above development well. This permit to redrill does not exempt you from obtaining additional permits or approvals required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Please provide at least twenty-four (24) hours notice for a representative of the Commission to witness any required test. Contact the Commission's North Slope petroleum field inspector at 659-3607 (pager). Sincerely, æ-~ ~k~ Randy Ruedrich Commissioner BY ORDER OF THE COMMISSION DATED thisft day of August, 2003 cc: Department ofFish & Game, Habitat Section wlo encl. Department of Environmental Conservation wlo encl. Exploration, Production and Refineries Section 'vJGA- "IB{~~i'f . STATE OF ALASKA . ALASKA AND GAS CONSERVATION CO SSION PERMIT TO DRILL 20 AAC 25.005 1a. Type of work o Drill II Redrill rb. Current Well Class o Exploratory II Development Oil o Multiple Zone ORe-Entry o Stratigraphic Test o Service o Development Gas o Single Zone 2. Operator Name: 5. Bond: 181 Blanket o Single Well 11. Well Name and Number: BP Exploration (Alaska) Inc. Bond No. 2S 100302630-277 PBU G-12B / 3. Address: 6. Proposed Depth: 12. Field I Pool(s): P.O. Box 196612, Anchorage, Alaska 99519-6612 MD 11350 TVD 8966 Prudhoe Bay Field I Prudhoe Bay 4a. Location of Well (Governmental Section): 7. Property Designation: Pool Surface: ADL 028280 2334' SNL, 2367' WEL, SEC. 12, T11N, R13E, UM 8. Land Use Permit: 13. Approximate Spud Date: Top of Productive Horizon: 09/18/03 ~ 1571' SNL, 1023' WEL, SEC. 11, T11N, R13E, UM Total Depth: 9. Acres in Property: 14. Distance to Nearest Property: 1863' SNL, 72' WEL, SEC. 11, T11 N, R13E, UM 2560 15062' 4b. Location of Well (State Base Plane Coordinates): 10. KB Elevation KBE= 15. Distance to Nearest Well Within PO~I/ Surface: x-657854 y-5969307 Zone,c..SP4 (Height above GL): 65.72' feet G-29A is 863' away at 10850' 16. Deviated Wells: 17. Anticipated pressure (see 20 AAC 25.035) / 0 Kickoff Depth 9792 ft Maximum Hole Angle 92 Max. Downhole Pressure: 3200 psig. Max. Surface Pressure: 2144 psig 18I.Casing Program Specifications Setting Depth aUål"ltltýof Cement Size Top Bottom (c.f. or sacks) Hole Casina Weiaht Grade CouDlina Lenath MD TVD MD TVD (includina staae data) 3-3/4" x 4-1/8" 3-3/16" x 2-7/8" 6.2# /6.16# L-80 ST-L 1758' 9592' 8524' 11350' 8966' 112 cu ft Class 'G' 19. PRESENT WELL CONDITION SUMN4ARY (To~.C9rnpleted for Redrill AND .... ... Total Depth MD (ft): Total Depth TVD (ft): Plugs (measured): I Effective Depth MD (ft): Effective Depth TVD (ft):1 Junk (measured): 11715 ~23 11300 11300 9048 N/A ~"C¡i""i"t ¡..'¡ ,/. {,{ ,¡ Si?èi ,> ,/" .>".. "T . ,. ......, » iMD, >i ·/TVD StrlJctlJr~1 Conductor 110' 20" x 30" 8 cu vds Concrete 110' 110' ~. 1_ 2672' 13-3/8" 3627 cu ft Arcticset II 2672' 2672' t iate 9721' 9-5/8" 1305 cu ft Class 'G', 130 cu ft AS II 9721' 8443' Production Liner 1533' 7" 360 cu ft Class 'G' 9212' - 10745' 8044' - 9008' Liner 2491' 2-7/8" 94 cu ft Class 'G' 9224' - 11715' 8053' - 9023' Perforation Depth MD (ft): 10890' - 11675' IperfOration Depth TVD (ft): ·9025' - 9025' 20. Attachments 181 Filing Fee 181 BOP Sketch 181 Drilling Program o Time vs Depth Plot o Shallow Hazard Analysis o Property Plat o Diverter Sketch o Seabed Report o Drilling Fluid Program 18120 AAC 25.050 Requirements 21. Verbal Approval: Commission Representative: Date: 22. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Ted Stagg, 564-4694 Printed Name Ted Stagg Title CT Drilling Engineer "1. 1/ j/~ Date &>h~3 Prepared By Name/Number: Sianature ...f '"7.f::Jí{¿'7.A. Phone 564-4694 Terrie Hubble, 564-4628 v t?17 Commission Use ani' Permit To Drill I API Number: Permit APQi~ILf ï1J I See cover letter for Number: 2.oJ - /"Y'; 50- 029-20597-02-00 Date: I other requirements Conditions of Approval: Samples Required DYes .ØI No Mud Log Required' DYes ~No Hydrogen Sulfide Measures ZJ Yes DNo Directional Survey Required ~Yes DNo Other: '-e..<;. + 'BoPE fc 3 5"00 , PlL {tJ ~L~ ~lhIA ~//tf~] t ' UII~· f J /...~ - BY ORDER OF ADDroved Bv: .- . v COMMISSIONER THE COMMISSION Date Form 10-401 Revised 3/2003 '! Sl¡bmit ~rl Dupl1C:ate e - BP G-12B Sidetrack Summary of Operations: / A CTD through tubing sidetrack is planned for well G-12A. Prior to sidetracking, the existing 2 7/8" liner will be plugged then cut and recovered. The coil sidetrack, G-12B, will exit the 7" liner in Zone 4, if a deep / cut/pull of the 2 7/8" is successful, or in the Sag River if a higher cut of the 2 7/8" is required. A mechanical whipstock will be used to exit the 7". Note: The well plan is based on the higher cut at 9770'MD. ../ A 3.75"~0Ie will be drilled to the Zone 2 target. The production liner will be 3 3/16" x 2 7/8", fully /" cemen~~lerforated. Phase 1: Prep work. Planned for Sept. 1, 2003. 1. E-line will set and test a cast iron bridge plug in the existing 2 7/8" liner at 10,050' MD (8639'ss). 2. E-line will chemically cut the 2 7/8" at approx. 10,OOO'MD (8600ss), in Zone 4. 3. Service coil will pull on the severed liner to confirm if it is free. If not free, e-line will make a second cut at approx. 9770' MD (8416'ss). Service coil will again pull on the liner to confirm if it is free. When the 2 7/8" has been confirmed to be free, service coil will rig down and leave retrieval of the severed 2 7/8" for Nordic 1. Phase 2: Recover severed 2 7/8", mill 2 7/8" to 9812' if necessary, unde~am, set whipstock, mill / window, drill and complete sidetrack: Planned for Sept. 18,2003. Drilling coil will be used to recover the severed 2 7/8" liner, mill to approx. 9812' MD (8449'ss) if necessary, underream the 7" liner, set the mechanical whipstock at 9792' MD (8433'ss):"mill a 3.80" window then drill and complete the directional hole as per attached plan. The production liner, 3 3/16" x 2 7/8", will be cemented from TD to 200' above the window. A 41/8" bi-center bit will be used from _ the window to approx, 10,700' MD then a 3.75" bit will be used from 10,700 to TD. Mud Program: · Phase 1 : Seawater · Phase 2: Mill with seawater/biozan, drill with Flo-Pro (8.6 - 8.7 ppg) / 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. Casing Program: · The 3 3/16" x 2 7/8" production liner will be cemented from TD, (11 ,350' MD~, 89 '. ,to approx. 9592' MD (8524'ss) which is 200 ft above the window. Cement volume will 0 b minimum, based on 40% excess in open hole. . ..< · The 3 3/16" x 2 7/8" liner will be selectively perforated. Well Control: · BOP diagram is attached. / · Pipe rams, blind rams and the CT pack off will be pressure tested to 400 psi and to 3500 psi. · The annular preventer will be tested to 400 psi and 2500 psi. Directional · See attached directional plan. Max. planned hole angle is 92 deg. · Magnetic and inclination surveys will be taken every 30 ft. No gyro will be run. Logging · An MWD Gamma Ray/Resistivity log will be run over all of the open hole section. · A Memory CNL will be run in the cased hole. e e Hazards · The highest H2S recorded to date on G-Pad is 10 ppm. / Crossing one fault, with low risk of lost circulation. Tubing is communicating with the IA:"'The IA will be doub.J,e valved. OA pressure will be / continuously monitored and maintained below 1000 psi."Note: A POGLM will be installed, post· completion, to restore tubing integrity. · · Reservoir Pressure Res. press. is estimated to ~3200 psi at 8800'ss (7.0ppg emw). Max. surface pressure with gas (0.12 psi/ft) to surface is 2144psi. TREE = ' McEVOY 6" WELLHEAD = McEVOY I 13-3/8" CSG, 72#, L-80, ID:= 12.347" I Minimum ID :::: 2.347" @ 9224' TOP Of LINER ÆRFORA TION SUMMARY REF LOG: NONE USED MWD/PBD ANGLE AT TOP PERF: 81 @ 10890' Note: Refer to Production DB for historical perf data SPF INTERV AL Opn/Sqz 2" 4 10890 - 10950 2" 6 11047 - 11072 2" 4 11150 - 11450 2" 6 11179 - 11204 2" 6 11246 - 11271 2" 6 11292 - 11312 2" 4 11505 -11675 2" 6 11080 - 11155 COMMENTS ORIGINAL COM PLET10N CTD SDTRK COMPLETION CONVERTED TO CANVAS REV ISION CORRECTIONS 9217' NOTES: 2094' 2514' 9169' 9169' 2-7/8" LNR, 6.16#, N-80, FL4 .0058 bpf, ID:= 2.347" SEC BF' BP Amoco Parent WeUpMh: Thl'onMÐ: Rjg: Ref. Ðcatum~ V.Section Angle 101.00' WELLPATH. OeTNLS Phm.#30·128 !iO0292t)Sn02 6·12 9700.00 18: 12 6/24/198100:00 55.7Oft ~~:: ~~~= :=:~Ð "'0 30.72 ..00 REFERENCE INFORMATION Co-ordinate {NtE¡ Reference: Well Centre: G·12, True North Vertical (TVD Reference: System; Mean Sea Level Section (VS Reference: Slot - 12 (O.OON.O.OOE) Measured Depth Rßferenœ: 18: 126/24/198100:00 65]0 Calculation Method: Minimum Curvature SECTiON DErAl1.$ M. .., +N14 TF.I>(¡.(> V$~c T,,,g"f 1 37.21 2$4.4n 72$.31} (U)O ! 37,002$UI2: 740,no 9jM9- 38.t¡7 2!:9.M. 744.41> 4;),31 309.11.1 76M$$. 4UI9 347.:11; Jtr7.37 . 34.79- 2ii.S3 600.-ao : 55,00 90-42- $49.46 $(1'.00 103.47 911.21 91.29- 151.46 62:&.&9 ,. 91.'\& 134.26 471,02 ANNOTATiONS TVÞ MÐ Al1t1Otatlon T" ''0' · · · · 7 · · Tf.J 8300 T Azimuths to True North I Magnetic North 2560" Created By Dlgita! Busrness Chent UserDate 7/2212003 Magnetic Field Strength 57567nT Dip Angle 80 86' Date 7/22/2003 Model bggm2003 __ _ ~ ~ ~ ~ "'~"""~<~~"'M<_M~"__"._~~_~" T Plao; Plan #3 (G-121PJan#3 G-12B) LEGEND 1250 1200 1150 1100 1050u 1000 - I: ;¡s 950 ë m 900 ..... - .t.. 850 .I: 1:: " ~ 750 . - .I: .. :::s " CI) -4050 -4000-3950 -3900-3850 -3800 -3750 -3700 -3650 -3600 -3550 -3500-3450 -3400 -3350 -3300-3250 -3200 -3150 -3100 -3050 -3000 -2950 -2900 -2850 -2800 -2750 -2700 West{-)/East(+) [50ft/in] -4050 -4000 -3950 -3900 -3850 -3800 -3750-3700 -3650 -3600 -3550-3500 -3450 -3400 -3350 -3300 -3250-3200 -3150 -31 00 -3050 -3000 -2950 -2900 -2850 -2800 -2750 -2700 -2650 -2600-2550 -2500 -2450 -2400 -2350 -2300 -2250 -2200-2150 Vertical Section at 107.00° [50ft/in] ObP I BP-GDB . Ba er Hughes INTEQ Planning Relft)rt ... RA,=, INTEQ Date: 7/22/2003 Time: 17:20:50 Page: Co-ordinate(NE) Reference: Well: G-12, True North Vertical (fVD) Reference: System: Mean Sea Level Section (VS) Reference: Well (0.00N,O.OOE,107.00Azi) Calculation Method: Minimum Curvature Db: Oracl Site: Well: Wellpath: Prudhoe Bay PB G Pad G-12 Plan#3 G-128 Field: Prudhoe Bay North Slope UNITED STATES Map System:US State Plane Coordinate System 1927 Geo Datum: NAD27 (Clarke 1866) Sys Datum: Mean Sea Level Map Zone: Coordinate System: Geomagnetic Model: Alaska, Zone 4 Well Centre bggm2003 .~. .. _M. ____n________ -- ------ ------ --- ~-~--- -------- - ----- -~-~-------~- Site: PB G Pad TR-11-13 UNITED STATES: North Slope Site Position: Northing: From: Map Easting: Position Uncertainty: 0.00 ft Ground Level: 0.00 ft 5966832.87 ft 656301.39 ft Latitude: 70 18 Longitude: 148 43 North Reference: Grid Convergence: 58.211 N 59.013 W True 1.19 deg Well: G-12 Slot Name: 12 G-12 Well Position: +N/-S 2441.44 ft Northing: 5969306.99 ft Latitude: 70 19 22.221 N +E/-W 1603.90 ft Easting : 657854.00 ft Longitude: 148 43 12.202 W Position Uncertainty: 0.00 ft Well path: Plan#3 G-12B 500292059702 Current Datum: 18: 126/24/1981 00:00 Magnetic Data: 7/22/2003 Field Strength: 57567 nT Verticat Section: Depth From (TVD) ft 30.72 +N/-S ft 0.00 Drilled From: Tie-on Depth: Above System Datum: Declination: Mag Dip Angle: +E/-W ft 0.00 G-12 9700.00 ft Mean Sea Level 25.60 deg 80.86 deg Direction deg 107.00 Height 65.70 ft Targets G-12B Polygon3.1 0.00 1018.37 -3568.63 5970250.00 654265.00 70 19 32.228 N 148 44 56.368 W -Polygon 1 0.00 1018.37 -3568.63 5970250.00 654265.00 70 19 32.228 N 148 44 56.368 W -Polygon 2 0.00 671.69 -3255.83 5969910.00 654585.00 70 19 28.820 N 148 44 47.233 W -Polygon 3 0.00 418.57 -3111.11 5969660.00 654735.00 70 19 26.331 N 148 44 43.006 W -Polygon 4 0.00 528.82 -2883.72 5969775.00 654960.00 70 19 27.416 N 148 44 36.371 W -Polygon 5 0.00 837.87 -3072.28 5970080.00 654765.00 70 19 30.455 N 148 4441.878 W -Polygon 6 0.00 1078.62 -3342.29 5970315.00 654490.00 70 19 32.822 N 148 44 49.762 W G-12B Intermediate Hardline 0.00 976.05 -3934.63 5970200.00 653900.00 70 19 31.810 N 148 45 7.051 W -Polygon 1 0.00 976.05 -3934.63 5970200.00 653900.00 70 19 31.810 N 148 45 7.051 W -Polygon 2 0.00 1021.63 -3723.61 5970250.00 654110.00 70 19 32.260 N 148 45 0.892 W G-128 Fault 2 0.00 1484.61 -3383.77 5970720.00 654440.00 70 19 36.815 N 148 44 50.978 W -Polygon 1 0.00 1484.61 -3383.77 5970720.00 654440.00 70 19 36.815 N 148 44 50.978 W -Polygon 2 0.00 904.71 -2920.83 5970150.00 654915.00 70 1931.113 N 148 44 37.458 W G-12B Fault 1 0.00 1311.74 -3962.57 5970535.00 653865.00 70 1935.112 N 148 45 7.872 W -Polygon 1 0.00 1311.74 -3962.57 5970535.00 653865.00 70 1935.112 N 148 45 7.872 W -Polygon 2 0.00 829.76 -3637.62 5970060.00 654200.00 70 19 30.373 N 148 44 58.379 W -Polygon 3 0.00 553.49 -3343.34 5969790.00 654500.00 70 19 27.657 N 148 44 49.786 W -Polygon 4 0.00 829.76 -3637.62 5970060.00 654200.00 70 19 30.373 N 148 44 58.379 W G-12B Fault 3 0.00 964.28 -2899.57 5970210.00 654935.00 70 1931.699 N 148 44 36.838 W -Polygon 1 0.00 964.28 -2899.57 5970210.00 654935.00 70 1931.699 N 148 44 36.838 W -Polygon 2 0.00 484.93 -2699.59 5969735.00 655145.00 70 19 26.986 N 148 44 30.996 W G-12B Fault 4 0.00 356.74 -2787.31 5969605.00 655060.00 70 19 25.724 N 148 44 33.555 W -Polygon 1 0.00 356.74 -2787.31 5969605.00 655060.00 70 19 25.724 N 148 44 33.555 W -Polygon 2 0.00 383.74 -2406.64 5969640.00 655440.00 70 19 25.991 N 148 44 22.444 W G-12B T3.1 8433.00 739.51 -3864.58 5969965.00 653975.00 70 19 29.484 N 148 45 5.003 W -- --------------- - .'- -------,---------------- --------.-..--.--.-.--.------.------------------......-..-----_._,._._~----~. _._m.._______ ___ G-12B T3.2 ObP I BP-GDB . Ba er Hughes INTEQ Planning Re~rt B.. KA_ HUG". lNTEQ ..__...._...__u_. ... ...__.._u__. Date: 7/22/2003 Time: 17:20:50 Page: 2 Co-ordinate(NE) Reference: Well: G-12, True North Vertical (TVD) Reference: System: Mean Sea Level Section (VS) Reference: Well (0.00N,0.00E,107.00Azi) Survey Calcul.ation Method: Minimum Curvature Db: Oracle _____n. ._n 8965.00 8975.00 470.93 -2984.97 5969715.00 654860.00 70 19 26.847 N 148 44 39.325 W 910.44 -3430.86 5970145.00 654405.00 70 1931.167 N 148 4452.345 W 9700.00 9792.00 9812.00 9862.00 9942.00 10017.00 10397.84 10706.67 11156.67 11350.00 8360.08 8433.43 8449.24 8485.36 8542.73 8602.85 8883.49 8975.29 8969.79 8965.54 TIP KOP 3 4 5 6 7 8 9 TO . . _.__.~--..._-~..,..,.~..._.._-~ ------~~---~------_._--_._-~----~~-,--_._._-_._---------------~. ------------------ -'----------------- ----.-,..--'.-'.--.'.- Plan #3 Identical to Lamar's Plan #3 Principal: Yes Date Composed: Version: Tied-to: 7/22/2003 2 From: Definitive Path ft deg deg ft ft ft deg n._....... 9700.00 37.27 284.40 8360.08 725.30 -3810.62 0.00 0.00 0.00 0.00 9792.00 37.00 287.62 8433.43 740.60 -3863.99 2.13 -0.29 3.50 99.19 9812.00 38.57 289.06 8449.24 744.46 -3875.62 9.00 7.84 7.22 30.00 9862.00 49.31 309.15 8485.36 761.66 -3905.29 35.00 21.49 40.17 60.00 9942.00 41.09 347.36 8542.73 807.37 -3935.16 35.00 -10.27 47.76 120.00 10017.00 34.79 29.53 8602.85 850.80 -3929.91 35.00 -8.41 56.23 120.00 10397.84 55.00 90.42 8883.49 949.46 -3708.52 12.00 5.31 15.99 90.00 10706.67 90.00 103.47 8975.29 911.21 -3421.80 12.00 11.33 4.22 22.00 11156.67 91.29 157.46 8969.79 629.89 -3091.98 12.00 0.29 12.00 88.40 11350.00 91.19 134.26 8965.54 471.02 -2984.25 12.00 -0.05 -12.00 270.00 9700.00 37.27 284.40 8360.08 725.30 -3810.62 5969951.93 654029.24 -3856.17 0.00 0.00 TIP 9725.00 37.19 285.27 8379.99 729.17 -3825.24 5969955.49 654014.54 -3871.29 2.13 99.19 MWD 9750.00 37.11 286.15 8399.91 733.26 -3839.78 5969959.27 653999.93 -3886.38 2.13 98.50 MWD 9775.00 37.04 287.02 8419.86 737.56 -3854.22 5969963.27 653985.40 -3901.45 2.13 97.80 MWD 9791.46 37.00 287.60 8433.00 740.51 -3863.68 5969966.02 653975.87 -3911.36 2.13 97.10 G-12B 9792.00 37.00 287.62 8433.43 740.60 -3863.99 5969966.11 653975.56 -3911.69 2.13 96.64 KOP 9800.00 37.63 288.21 8439.79 742.10 -3868.61 5969967.50 653970.92 -3916.54 9.00 30.00 MWD 9812.00 38.57 289.06 8449.24 744.46 -3875.62 5969969.72 653963.86 -3923.94 9.00 29.53 3 9825.00 41.00 295.07 8459.23 747.60 -3883.32 5969972.69 653956.09 -3932.21 35.00 60.00 MWD 9850.00 46.43 305.02 8477.31 756.29 -3898.19 5969981.07 653941.04 -3948.98 35.00 55.38 MWD 9862.00 49.31 309.15 8485.36 761.66 -3905.29 5969986.29 653933.84 -3957.33 35.00 48.17 4 9875.00 47.16 314.53 8494.03 768.11 -3912.51 5969992.59 653926.48 -3966.13 35.00 120.00 MWD 9900.00 43.81 325.88 8511.58 781.73 -3923.92 5970005.96 653914.79 -3981.02 35.00 116.42 MWD 9925.00 41.70 338.41 8529.97 796.65 -3931.85 5970020.71 653906.55 -3992.97 35.00 108.44 MWD 9942.00 41.09 347.36 8542.73 807.37 -3935.16 5970031.36 653903.02 -3999.26 35.00 99.22 5 9950.00 39.76 351.15 8548.82 812.47 -3936.13 5970036.43 653901.94 -4001.68 35.00 120.00 MWD 9975.00 36.47 4.32 8568.52 827.81 -3936.80 5970051.75 653900.95 -4006.80 35.00 117.11 MWD ObP I BP-GDB . Ba er Hughes INTEQ Planning ReJ'órt .Ii. ..... ïÑ~rnQ ---- Date: 7/22/2003 Time: 17:20:50 Page: 3 Co-ordinate(NE) Reference: Well: G-12. True North Vertical (TVD) Reference: System: Mean Sea Level Section (VS) Reference: Well (0.00N.0.00E.107.00Azi) Survey Calculation Method: Minimum Curvature Db: Oracle Field: Prudhoe Bay Site: PB G Pad Well: G-12 Wellpath: Plan#3 G-12B ." ___m.n____.. .... __..___.. ___no ... ......._.____. _.__.._. on.. . 10000.00 34.83 19.10 8588.88 841.99 -3933.89 5970065.99 653903.55 -4008.18 35.00 106.73 MWD 10017.00 34.79 29.53 8602.85 850.80 -3929.91 5970074.89 653907.34 -4006.94 35.00 94.70 6 10025.00 34.80 31.21 8609.42 854.74 -3927.60 5970078.87 653909.57 -4005.89 12.00 90.00 MWD 10050.00 34.98 36.45 8629.93 866.61 -3919.65 5970090.91 653917.27 -4001.75 12.00 88.62 MWD 10075.00 35.39 41.61 8650.36 877.79 -3910.58 5970102.27 653926.10 -3996.35 12.00 84.32 MWD 10100.00 36.01 46.64 8670.67 888.25 -3900.43 5970112.95 653936.03 -3989.70 12.00 80.11 MWD 10125.00 36.84 51.50 8690.79 897.97 -3889.22 5970122.89 653947.04 -3981.82 12.00 76.02 MWD 10150.00 37.85 56.15 8710.67 906.91 -3876.98 5970132.09 653959.08 -3972.73 12.00 72.11 MWD 10175.00 39.04 60.59 8730.25 915.05 -3863.75 5970140.50 653972.14 -3962.45 12.00 68.41 MWD 10200.00 40.39 64.78 8749.49 922.37 -3849.56 5970148.12 653986.17 -3951.02 12.00 64.94 MWD 10225.00 41.88 68.74 8768.32 928.84 -3834.45 5970154.91 654001.14 -3938.47 12.00 61.71 MWD 10250.00 43.50 72.47 8786.70 934.46 -3818.47 5970160.87 654017.00 -3924.83 12.00 58.72 MWD 10275.00 45.23 75.97 8804.57 939.21 -3801.65 5970165.96 654033.71 -3910.13 12.00 55.99 MWD 10300.00 47.06 79.26 8821.89 943.07 -3784.04 5970170.19 654051.23 -3894.42 12.00 53.48 MWD 10325.00 48.99 82.36 8838.62 946.03 -3765.70 5970173.54 654069.51 -3877.75 12.00 51.20 MWD 10350.00 50.99 85.28 8854.69 948.08 -3746.67 5970175.99 654088.49 -3860.15 12.00 49.12 MWD 10375.00 53.06 88.04 8870.08 949.22 -3727.00 5970177.54 654108.13 -3841.67 12.00 47.25 MWD 10397.84 55.00 90.42 8883.49 949.46 -3708.52 5970178.18 654126.60 -3824.07 12.00 45.55 7 10400.00 55.24 90.54 8884.73 949.45 -3706.75 5970178.20 654128.37 -3822.37 12.00 22.00 MWD 10425.00 58.03 91.86 8898.48 949.01 -3685.87 5970178.20 654149.24 -3802.28 12.00 21.93 MWD 10450.00 60.83 93.11 8911.19 948.07 -3664.37 5970177.71 654170.76 -3781.45 12.00 21.21 MWD 10475.00 63.65 94.28 8922.83 946.64 -3642.30 5970176.75 654192.86 -3759.92 12.00 20.57 MWD 10500.00 66.47 95.40 8933.37 944.73 -3619.71 5970175.31 654215.48 -3737.76 12.00 20.03 MWD 10525.00 69.30 96.47 8942.79 942.33 -3596.68 5970173.40 654238.55 -3715.03 12.00 19.55 MWD 10550.00 72.14 97.51 8951.04 939.46 -3573.26 5970171.02 654262.03 -3691.80 12.00 19.15 MWD 10575.00 74.98 98.51 8958.11 936.11 -3549.52 5970168.18 654285.83 -3668.12 12.00 18.81 MWD 10600.00 77.83 99.48 8963.99 932.31 -3525.52 5970164.88 654309.90 -3644.06 12.00 18.52 MWD 10604.89 78.38 99.67 8965.00 931.52 -3520.80 5970164.18 654314.64 -3639.31 12.00 18.30 G-12B 10625.00 80.68 100.44 8968.65 928.07 -3501.33 5970161.14 654334.17 -3619.68 12.00 18.26 MWD 10650.00 83.53 101.38 8972.09 923.38 -3477.02 5970156.97 654358.58 -3595.06 12.00 18.12 MWD 10675.00 86.38 102.30 8974.29 918.27 -3452.65 5970152.37 654383.05 -3570.26 12.00 17.99 MWD 10700.00 89.24 103.23 8975.24 912.75 -3428.29 5970147.37 654407.52 -3545.35 12.00 17.91 MWD 10706.67 90.00 103.47 8975.29 911.21 -3421.80 5970145.96 654414.04 -3538.69 12.00 17.87 8 10725.00 90.06 105.67 8975.28 906.60 -3404.06 5970141.73 654431.87 -3520.38 12.00 88.40 MWD 10750.00 90.14 108.67 8975.23 899.22 -3380.18 5970134.85 654455.90 -3495.39 12.00 88.40 MWD 10775.00 90.23 111.67 8975.15 890.60 -3356.71 5970126.73 654479.54 -3470.43 12.00 88.41 MWD 10800.00 90.31 114.67 8975.03 880.77 -3333.73 5970117.38 654502.72 -3445.58 12.00 88.42 MWD 10825.00 90.39 117.67 8974.88 869.75 -3311.30 5970106.84 654525.38 -3420.90 12.00 88.43 MWD 10850.00 90.47 120.66 8974.69 857.56 -3289.47 5970095.12 654547.46 -3396.46 12.00 88.45 MWD 10875.00 90.55 123.66 8974.47 844.26 -3268.31 5970082.26 654568.89 -3372.34 12.00 88.47 MWD 10900.00 90.63 126.66 8974.21 829.86 -3247.88 5970068.30 654589.62 -3348.59 12.00 88.50 MWD 10925.00 90.71 129.66 8973.92 814.42 -3228.22 5970053.27 654609.59 -3325.28 12.00 88.53 MWD 10950.00 90.78 132.66 8973.59 797.97 -3209.40 5970037.22 654628.75 -3302.47 12.00 88.56 MWD 10975.00 90.85 135.66 8973.24 780.55 -3191.47 5970020.19 654647.04 -3280.23 12.00 88.60 MWD 11000.00 90.92 138.66 8972.85 762.23 -3174.48 5970002.23 654664.42 -3258.62 12.00 88.65 MWD 11025.00 90.99 141.66 8972.43 743.03 -3158.47 5969983.38 654680.83 -3237.70 12.00 88.69 MWD 11050.00 91.05 144.66 8971.99 723.03 -3143.48 5969963.70 654696.23 -3217.52 12.00 88.74 MWD 11075.00 91.12 147.66 8971.51 702.27 -3129.56 5969943.24 654710.58 -3198.14 12.00 88.80 MWD 11100.00 91.17 150.66 8971.01 680.82 -3116.75 5969922.05 654723.84 -3179.62 12.00 88.85 MWD 11125.00 91.23 153.66 8970.49 658.72 -3105.08 5969900.21 654735.97 -3161.99 12.00 88.91 MWD 11150.00 91.28 156.66 8969.94 636.04 -3094.58 5969877.75 654746.95 -3145.32 12.00 88.98 MWD 11156.67 91.29 157.46 8969.79 629.89 -3091.98 5969871.67 654749.68 -3141.04 12.00 89.04 9 11175.00 91.29 155.26 8969.38 613.11 -3084.64 5969855.04 654757.37 -3129.11 12.00 270.00 MWD ObP Field: Site: Well: Wellpath: Survey Prudhoe Bay PB G Pad G-12 Plan#3 G-12B .. BP-GDB e Bàrér Hughes INTEQ Planning Report Date: Time: Page: 4 Co-ordinate(NE) Reference: Well: G-12, True North Vertical (TVD) Reference: System: Mean Sea Level Section (VS) Reference: Well (0.OON,0.00E,1 07 .00Azi) Survey Calculation Method: Minimum Curvature Db: Oracle ft deg 11200.00 91.29 11225.00 91.28 11250.00 91.27 11275.00 91.25 11300.00 91.24 11325.00 91.21 11350.00 91.19 EIW MapN MapE VS DLS TFO deg ft ft ft ft ft ft deg/10OO deg .. -.... .........-.... _u 152.26 8968.81 590.69 -3073.59 5969832.87 654768.89 -3111.99 12.00 269.95 MWD 149.26 8968.25 568.89 -3061.38 5969811.32 654781.55 -3093.94 12.00 269.88 MWD 146.26 8967.70 547.75 -3048.05 5969790.47 654795.32 -3075.01 12.00 269.82 MWD 143.26 8967.14 527.34 -3033.63 5969770.37 654810.17 -3055.25 12.00 269.75 MWD 140.26 8966.60 507.71 -3018.16 5969751.07 654826.05 -3034.72 12.00 269.68 MWD 137.26 8966.07 488.92 -3001.68 5969732.63 654842.91 -3013.47 12.00 269.62 MWD 134.26 8965.54 471.02 -2984.25 5969715.10 654860.72 -2991.56 12.00 269.55 TD e All Measurements are from top of Riser L.. Q) en .- a: top of bag .......................... bttm of bag middle of slips Blind/Shears middle of pipes middle of flow cross middle of blindlshears .......................... middle of pipelslips .......................... Flow Tee e 8/6/2003 BAG TOTs / Mud Cross TOTs / e e P055115 DATE 7/14/2003 CHECK NO. 055115 DATE INVOICE I CREDIT MEMO DESCRIPTION GROSS VENDOR DISCOUNT NET 7/14/2003 INV# PR071003E PERMIT TO DRILL FEE ~ ., V:z.J) TOTAL ~ THE ATTACHED CHECK IS IN PAYMENT FOR ITEMS DESCRIBED ABOVE. No.P OS 5115 CONSOLIDATED COMMERCIAL ACCOUNT NOT VALID 120 D Y ,,'\;·\::'::::o.:;::g~-/.S~t.~!i;\;· ~I ............./:~~ .............._,...... ~.......J ......::..:..~,'<~.~ &/I.. '. ..;..... ';'.' ~'..' :" .:-., /1 ....,. ~...~ Ii: ~-4 ;jI"1·... . <;;:i:';:::8~ ;:\(.ij~;::~i~:::;·~:;;·~k:i~¡i:~~·:~:i. :;~':~~:~;'::i: :::1 u·OSS¡l.Su· .:Or..¡·20iBI1SI: O¡2?811E:.u· Company Well Name: PRUDHOE BAY UNIT G-12B Program DEV Well bore seg D PTD#:2031410 Field & Pool ~asslType DEV 11-01L GeoArea 890 Unit 11650 On/Off Shore ~ Annular Disposal D Administration Perm it fee attached. · Yes. - - - - - - - - - - - - - - 2 .Lease .number .appropriate · Yes. 3 .U.nique well.n.arne.and lJi.J.mb.er · Yes. - - - - - - - - - - - - - - - - - - -- 4 Well JQc¡¡ted in.a. d.efil1ed ppol. · Yes. 5 WeJUQc¡¡ted prpper .distance. from driJling ul1itb.oUl1dary · Yes 6 WelUQcated proper .distance from other weUs Yes. 7 S.ufficiel1tacreaQ.eayailable indrilJilJQ. i.J.njl. . . . · Yes. - - - - - - - - - - - - - - - - 8 Jf.deviated. js weJlbQre pl¡¡til1cJuded . . . . . . . · Yes. - - - - - - 9 Operator only affected party . · Yes. - - - - - -- 10 .Operator has.apprppriate. b.ond inJorce . . . . . . . . . . · Yes. - - - - - - - - - - - - - - - - - 11 Permit c.an Þe iSSi.J.ed wjthQut conservatiOI1 order. · Yes. Appr Date 12 Permit can Þe iSSi.J.ed wjthQut admil1istrati",e.apprpvaJ . . · Yes. - - - - - - - - - - - - - - - - - - - RPC 8/13/2003 13 Can permit be approved before 15-day wait Yes 114 WeJIJQc¡¡ted withil1 area an.d str¡¡t¡¡ authorized by InjectiplJ Order # (Put 10# in.c.ornrn.ents). (for. NA e 15 AJI weUs.wit)1in.1l4.mile.area.of reyiew jd.entified (Fpr servjc.e.w.ell only). . . . . . . . . . . . . NA. . - - - - - - - - - - - - - - - - - - - 16 Pre-produçed injector; .duratio.n.of pre-produGtipo less t)1an 3 mon.ths (for service well QnJy) .NA. 17 ACMP F:indjng.of ConsiJ>tency has Þeen issued for this pr.oject . . . NA - - - - - - - Engineering 18 .C.ondu.ctor strin.g.prQvided . NA 19 .S.uITaœ .c¡¡sing. PJQtec.ts all.known USDWs . NA 20 .CMT v.ol adequ.ate.to circulateoncPl1ductpr & surfcJ>g . - - - - - - - - - - NA - - - - -- 21 .CMT vol adequ.ate.to tie-inJQng .string to.surf ~g NA. . 122 .CMTwil! coyer.aH kl1o.w.n.pro.ductiYe hQrizons. Yes. - - - - - - - - - - - - - - I 123 .G.asing de.signs adec;¡uate fpr C.T, B&permafr.ost. Yes. I - - - - - - - - - 124 .Adequatetan.kage.oJ re.serve pit. . . . . . Yes. CTDU. 25 Jf.a.re-drill, i1asa to-403 fQr abandon.ment been ¡¡pprQved . . Yes. * - - - - - - - - - - - - - 126 .Adequate .w.ellbore. sep¡¡r¡¡tjo.n .proposed. . . . . . . . . . . . . . . . . . . . . . . Yes. I - - ~ - - - - - - - - - - - - - - - - 127 Jf.djvecter required, dQes jt meet reguJatioos NA Sidetrack. . Appr Date 28 DJilJilJQ. fJujd program sc.hernatic.& eq.uip Jist.adequate. Yes. Max MW.8~ 7. ppgc WGA 8/13/2003 129 .BPPEs..dp .they meet reguJatiOI1 . - - - - - - Yes. I - - - - - - e I~~ .BPPEPress rating appropriate; test to.(pu.t psig in .commeots) Yes Testto.3500.psi. .MSP 2144 psi Chokemanjfold cQmpJies w/P-PI. RF'-53 (May 84). Yes. 132 Work will pccur withputoperatjonshi.J.tdo.wn. . . . . Yes. 33 Js presence Qf H2S gas probaÞle . No. 34 Mechanical.C9oditjon p{ wells within AOß yerified (Fors.ervjce welJ on.ly). NA Geology 35 Permit can Þe issu.ed .w!o hyd(Ogen sulfide meas.ures . - - - - - - - - - No 36 .D.ata.preselJted on. pote.ntial pveJpressuœzOl1es. . . . . . . . . . . NA. Appr Date 37 .Seisrnic.analysjs Qf shaJlow gas.z.ones. .NA. RPC 8/13/2003 38 Seab.ed .col1djtjplJ sllrvey(if ofH;hore) . NA - - - - - - - - - 39 CQntact l1amelphon.eforV>ieelsly prpgress.reports [exploratpryonly] .NA - ~ - :k- Geologic Engineering Public c Commissioner: Date: Commissioner Date Commissioner ~ - e Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify fìnding information, information of this nature is accumulated at the end of the fìle under APPENDIX. No special effort has been made to chronologically organize this category of information. . . ~Ô3-)J-ll Sperry-Sun Drilling Services LIS Scan Utility $Revision: 3 $ LisLib $Revision: 4 $ Fri Dee 05 10:55:58 2003 Reel Header Service name....... ......LISTPE Date.....................03/12/05 Origin...................STS Reel Name................UNKNOWN Continuation Number......Ol Previous Reel Name.......UNKNOWN Comments.................STS LIS Writing Library. Scientific Technical Services Tape Header Service name.............LISTPE Date.....................03/12/05 Origin. . . . .. . . . . . . .. . . . . . STS Tape Name....... . . . . . . . . . UNKNOWN Continuation Number......Ol Previous Tape Name.......UNKNOWN Comments.................STS LIS Writing Library. Scientific Technical Services Physical EOF Comment Record TAPE HEADER Prudhoe Bay MWD/MAD LOGS # WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: # JOB DATA G-12B 500292059702 BP Exploration (Alaska) Inc. Sperry-Sun Drilling Services 05-DEC-03 JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 2 MW0002669096 S. LATZ WHITLOW/ SARB MWD RUN 3 MW0002669096 S. LATZ WHITLOW/SARB MWD RUN 4 MW0002669096 S. LATZ WHITLOW/SARB JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 5 MW0002669096 S. LATZ WHITLOW/MCNE MWD RUN 6 MW0002669096 S. LATZ WHITLOW/MCNE MWD RUN 7 MW0002669096 S. LATZ WHITLOW/EGBE JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 8 MViI0002669096 B. JAHN ViIHITLOW/EGBE MWD RUN 9 MW0002669096 B. cTAHN ViIHITLOW/ EGB MWD RUN 10 MW0002669096 B. JAHN ViIHITLOW/EGBE JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 11 MW0002669096 B. JAHN WHITLOW / EG # SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: 12 11N 13E 2334 2367 RECEIVED 65.70 DEC 0 8 2003 Alaska O¡ &: Gªs Cons. Commi8$ion And11Jf!ge '~~~.~~ . . DERRICK FLOOR: GROUND LEVEL: # WELL CASING RECORD 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 4.125 4.500 9277.0 # REM}\RKS : 1. ALL DEPTHS ARE MEASURED DEPTH (MD) UNLESS OTHERWISE NOTED. 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTH - SUBSEA (TVDSS) . 3. THE WELL WAS EFFECTED BY MEANS OF A WHIPSTOCK, THE TOP OF WHICH WAS AT 9780'MD AND THE BOTTOM WAS AT 9792'MD. 4. MWD RUNS 2 - 10 COMPRISED DIREC'l'IONAL WITH DUAL GAMMA RAY (GM), UTILIZING GEIGER-MUELLER TUBE DETECTORS. NO PROGRESS WAS MADE IN RUN 1 DUE TO RIG PROBLEMS. ALTHOUGH ONLY ONE FOOT WAS MADE IN RUN 9, THE MWD DATA ARE PRESENTED SEPARATELY. 5. MWD RUN 11 COMPRISED DIRECTIONAL WITH DGR AND ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4). EWR4 DATA ABOVE THE RUN 11 INTERVAL WERE ACQUIRED WHILE POOH AFTER THE COMPLETION OF RUN 11. THESE UPHOLE DATA WERE MERGED WITH THE RUN 11 DATA - NO SEPARATE MAD PASS DATA ARE PRESENTED. 6. LOG AND DIGITAL DATA ONLY WERE SHIFTED TO A SCHLUMBERGER CASED-HOLE GAMMA RAY RUN IN G-12B ON 29 SEPTEMBER 2003. THESE PDC DATA WERE PROVIDED TO SSDS BY KURT COONEY (BP) ON 10 NOVEMBER 2003. LOG HEADER DATA RETAIN ORIGINAL DRILLERS' DEPTH REFERENCES. 7. MWD RUNS 2 - 11 REPRESENT WELL G-12B WITH API#: 50-029-20597-02. THIS WELL REACHED A TOTAL DEPTH (TD) OF 11360'MD/8986'TVDSS. SROP SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRC SMOOTHED GAMMA RAY COMBINED. SEXP SMOOTHED PHASE SHIFT-DERIV~D RESISTIVITY (EXTRA SHALLOW SPACING). SESP = SMOOTHED PHASE SPACING) . SEMP = SMOOTHED PHASE SPACING) . SEDP = SMOOTHED PHASE SPACING) . SFXE = SMOOTHED FORMATION EXPOSURE TIME (DEEP RESISTIVITY) . SHIFT-DERIVED RESISTIVITY ( SHALLOW SHIFT-DERIVED RESISTIVITY (MEDIUM SHIFT-DERIVED RESISTIVITY (DEEP $ File Header Service name.............STSLIB.001 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......03/12/05 Maximum Physical Record..65535 File Type................ LO Previous File Name.......STSLIB.OOO Comment Record FILE HEADER FILE NUMBER: EDITED MERGED MWD Depth shifted DEPTH INCREMENT: # FILE SUMMARY PBU TOOL CODE GR FET RPD RPM RPS RPX ROP $ . 1 . and clipped curves; all bit runs merged. .5000 START DEPTH 9768.5 9794.0 9794.0 9794.0 9794.0 9794.0 9801. 0 STOP DEPTH 11308.0 11320.5 11320.5 11320.5 11320.5 11320.5 11352.5 # BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH 9768.5 9773.5 9780.0 9789.0 9819.5 9827.0 9841.0 9869.5 9874.5 9877.5 9891.0 9892.5 9894.5 9898.5 9900.5 9907.5 9926.5 9931.0 9935.0 9941. 0 9989.0 10007.0 10015.5 10023.5 10046.0 10060.0 10066.0 10074.5 10077.5 10084.0 10104.5 10108.0 10119.5 10124.5 10132.5 10147.5 10155.5 10165.0 10192.0 10298.5 10320.0 10332.5 10338.0 10342.5 10383.0 10411.5 10414.5 10433.0 10441.5 10458.5 10476.0 10506.5 GR 9770.5 9775.5 9781. 0 9790.0 9825.0 9830.0 9842.5 9869.5 9875.5 9879.0 9891. 0 9892.5 9894.0 9899.0 9900.5 9906.5 9926.5 9930.5 9934.5 9940.5 9987.5 10005.5 10014.5 10023.5 10043.5 10059.5 10066.0 10075.0 10077.5 10083.0 10105.5 10107.5 10121. 0 10127.0 10135.5 10151. 0 10159.5 10168.5 10192.0 10294.0 10316.5 10328.5 10333.0 10337.5 10380.5 10407.5 10409.5 10429.5 10438.0 10455.0 10474.5 10505.0 10530.0 10537.5 10564.5 10579.5 10603.0 10607.0 10611. 0 10664.0 10673.5 10704.5 10746.5 10756.5 10771.5 10821. 0 10903.0 10964.5 10971.5 11006.0 11056.5 11125.5 11132.0 11176.5 11204.5 11211.5 11229.0 11245.0 11258.0 11274.5 11295.0 11352.5 $ # MERGED DATA SOURCE PBU TOOL CODE MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD $ # REMARKS: . 10528.5 10537.0 10565.0 10579.5 10602.5 10606.0 10609.0 10668.0 10676.0 10708.5 10749.0 10761.5 10774.5 10823.0 10907.5 10968.0 10975.5 11009.5 11059.5 11131.0 11136.5 11181. 0 11208.0 11215.5 11233.0 11250.0 11260.0 11279.5 11302.0 11359.5 BIT RUN NO MERGE TOP 9770.5 3 9859.5 4 9914.0 5 10030.0 6 10145.0 7 10151.0 8 10206.0 9 10230.0 10 10231.0 11 9795.5 MERGE BASE 9859.5 9914.0 10030.0 10145.0 10151. 0 10206.0 10230.0 10231. 0 10341.0 11359.5 MERGED MAIN PASS. $ # Data Format Specification Record Data Record Type.................. 0 Data Specification Block Type. ....0 Logging Direction.................Down Optical log depth units...........Feet Data Reference Point..............Undefined Frame Spacing.....................60 .1IN Max frames per record.............Undefined Absent value..................... .-999 Depth Units....................... Datum Specification Block sub-type...O Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD FT/H 4 1 68 4 GR MWD API 4 1 68 8 3 RPX MWD OHMM 4 1 68 12 4 RPS MWD OHMM 4 1 68 16 5 RPM MWD OHMM 4 1 68 20 6 RPD MWD OHMM 4 1 68 24 7 FET MWD HOUR 4 1 68 28 8 Name Service Unit Min Max Mean Nsam . First Reading Last Reading . . DEPT FT 9768.5 11352.5 10560.5 3169 9768.5 11352.5 ROP MWD FT/H 0.12 2183.73 62.4311 3104 9801 11352.5 GR MWD API 17.33 527.67 53.4355 3080 9768.5 11308 RPX MWD OHMM 0.55 2000 28.5629 3054 9794 11320.5 RPS MWD OHMM 0.36 962.54 24.5425 3054 9794 11320.5 RPM MWD OHMM 0.4 392.09 25.5576 3054 9794 11320.5 RPD MWD OHMM 1. 37 2000 72.3918 3054 9794 11320.5 FET MWD HOUR 0.22 133.91 31. 5529 3054 9794 11320.5 First Reading For Entire File..........9768.5 Last Reading For Entire File...........11352.5 File Trailer Service name.............STSLIB.OOl Service Sub Level Name... Version Number...........l.O.O Date of Generation.......03/12/05 Maximum Physical Record..65535 File Type................LO Next File Name...........STSLIB.002 Physical EOF File Header Service name.............STSLIB.002 Service Sub Level Name... Version Number...........l.0.0 Date of Generation.......03/12/05 Maximum Physical Record..65535 Fi I e Type................ LO Previous File Name.......STSLIB.OOl Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE GR ROP $ 2 header data for each bit run in separate files. 2 .5000 START DEPTH 9770.5 9803.5 STOP DEPTH 9829.5 9859.5 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG HINIMUM ANGLE: M}\XIMUM ANGLE: 21-SEP-03 Insite 4.3 Memory 9858.0 9803.0 9858.0 37.0 37.0 # TOOL STRING (TOP TO VENDOR TOOL CODE GM $ BOTTOM) TOOL TYPE Dual GR TOOL NUMBER # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): 4.125 9277.0 # BOREHOLE CONDITIONS MUD TYPE: Flo Pro . . MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: 8.60 65.0 9.4 18000 11.6 .000 .000 .000 .000 .0 117.0 .0 .0 # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY 1HZ): # REMARKS: $ # Data Format Specification Record Data Record Type.................. 0 Data Specification Block Type.....O Logging Direction................. Down Optical log depth units...........Feet Data Reference Point..............Undefined Frame Spacing..................... 60 .1IN Max frames per record.............Undefined Absent value..................... .-999 Depth Units....................... Datum Specification Block sub-tÿ~e...O Service Order Units FT FT/H API Size 4 4 4 Code Offset o 4 8 Channel 1 Name DEPT ROP GR MWD020 MWD020 Nsam 1 1 1 Rep 68 68 68 3 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 9770.5 9859.5 9815 179 9770.5 9859.5 ROP MWD020 FT/H 7.87 74.06 37.2706 113 9803.5 9859.5 GR MWD020 API 49.36 386.26 103.435 119 9770.5 9829.5 First Reading For Entire File..........9770.5 Last Reading For Entire File...........9859.5 File Trailer Service name.............STSLIB.002 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......03/12/05 Maximum Physical Record..65535 Fi 1 e Type................ LO Next File Name...........STSLIB.003 Physical EOF File Header Service name.............STSLIB.003 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......03/12/05 Maximum Physical Record..65535 File Type............... .LO Previous File Name.......STSLIB.002 Comment Record . FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE GR ROP $ 3 . header data for each bit run in separate files. 3 .5000 START DEPTH 9830.0 9860.0 STOP DEPTH 9887.0 9914.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE GM $ BOTTOM) TOOL TYPE Dual GR # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMl,RKS : $ # Data Format Specification Record Data Record Type.................. 0 Data Specification Block Type.. ...0 Logging Direction.................Down Optical log depth units...........Feet Data Reference Point..............Undefined Frame Spacing.....................60 .IIN Max frames per record.............Undefined Absent value..................... .-999 Depth Uni t.s . . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O Name Service Order DEPT ROP MWD030 21-SEP-03 Insite 4.3 Memory 9914.0 9858.0 9914.0 42.9 45.6 TOOL NUMBER 4.130 9277.0 Fl0 Pro 8.60 65.0 9.5 18500 11.2 .000 .000 .000 .000 .0 130.8 .0 .0 Units Size Nsam Rep Code Offset Channel FT 4 1 68 0 1 FT/H 4 1 68 4 2 . . GR MWD030 API 4 1 68 8 3 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 9830 9914 9872 169 9830 9914 ROP MWD030 FT/H 8.52 37.88 21.3191 109 9860 9914 GR HWD030 API 60.31 527.67 178.894 115 9830 9887 First Reading For Entire File..........9830 Last Reading For Entire File...........9914 File Trailer Service name.............STSLIB.003 Service Sub Level Name... Version Number...... . . . . .1. 0.0 Date of Generation.......03/12/05 Maximum Physical Record..65535 File Type................ LO Next File Name...........STSLIB.004 Physical EOF File Header Service name.............STSLIB.004 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......03/12/05 Maximum Physical Record..65535 File Type............... .LO Previous File Name.......STSLIB.003 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUHHARY VENDOR TOOL CODE GR ROP $ 4 header data for each bit run in separate files. 4 .5000 START DEPTH 9887.5 9914.5 STOP DEPTH 10002.0 10030.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TO DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG HINIMUM ANGLE: MAXIMUM ANGLE: 22-SEP-03 Insite 4.3 Memory 10030.0 9914.0 10030.0 32.6 39.7 # TOOL STRING (TOP TO VENDOR TOOL CODE GM $ BOTTOM) TOOL TYPE Dual GR TOOL NUMBER # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): 4.130 9277.0 # BOREHOLE CONDITIONS . . MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: Flo Pro 8.60 65.0 9.5 18500 11.2 .000 .000 .000 .000 .0 120.0 .0 .0 # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type.................. 0 Data Specification Block Type.....O Logging Direction.................Down Optical log depth units...........Feet Data Reference Point..............Undefined Frame Spacing.....................60 .1IN Max frames per record.............Undefined Absent value..................... .-999 Depth Units....................... Datum Specification Block sub-type...O Name Service Order DEPT ROP MWD040 GR MWD040 Units FT FT/H API Size Nsam Rep Code 4 1 68 4 1 68 4 1 68 Offset o 4 8 Channel 1 2 3 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 9887.5 10030 9958.75 286 9887.5 10030 ROP MWD040 FT/H 6.07 38.09 25.8632 232 9914.5 10030 GR MWD040 API 27.17 483.56 116.578 230 9887.5 10002 First Reading For Entire File..........9887.5 Last Reading For Entire File...........10030 File Trailer Service name.............STSLIB.004 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......03/12/05 Maximum Physical Record..65535 File Type............... .LO Next File Name...........STSLIB.005 Physical EOF File Header Service name.............STSLIB.005 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......03/12/05 Maximum Physical Record..65535 File Type............... .LO Previous File Name.......STSLIB.004 . Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: if FILE SUMMARY VENDOR TOOL CODE GR ROP $ 5 . header data for each bit run in separate files. 5 .5000 START DEPTH 10002.5 10030.5 STOP DEPTH 10117.0 10145.0 if LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: if TOOL STRING (TOP TO VENDOR TOOL CODE GM $ BOTTOM) TOOL TYPE Dual GR if BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): if BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: if NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): if TOOL STANDOFF (IN): EWR FREQUENCY (HZ): if REMARKS: $ if Data Format Specification Record Data Record Type.................. 0 Data Specification Block Type.....O Logging Direction.................Down Optical log depth units...........Feet Data Reference Point..............Undefined Frame Spacing..................... 60 .1IN Max frames per record......... ... .Undefined Absent value..................... .-999 Depth Units....................... Datum Specification Block sub-type...O 22-SEP-03 Insite 4.3 Memory 10145.0 10030.0 10145.0 32.3 43.7 TOOL NUMBER 4.130 9277.0 Flo Pro 8.60 65.0 9.2 18500 8.0 .000 .000 .000 .000 .0 127.3 .0 .0 Name Service Order DEFT Units Size Nsam Rep Code Offset Channel FT 4 1 68 0 1 . . ROP MWD050 FT/H 4 1 68 4 2 GR MWD050 API 4 1 68 8 3 Fi.rst Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 10002.5 10145 10073.8 286 10002.5 10145 ROP MWD050 FT/H 6.8 89.94 43.2216 230 10030.5 10145 GR MWD050 API 22.68 127.52 39.4705 230 10002.5 10117 First Reading For Entire File..........10002.5 Last Reading For Entire File...........10145 File Trailer Service name.............STSLIB.005 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......03/12/05 Maximum Physical Record..65535 File Type................ LO Next File Name...........STSLIB.006 Physical EOF File Header Service name.............STSLIB.006 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......03/12/05 Maximum Physical Record..65535 File Type................ LO Previous File Name.......STSLIB.005 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE Sm'1MARY VENDOR TOOL CODE GR ROP $ 6 header data for each bit run in separate files. 6 .5000 START DEPTH 10117.5 10145.5 STOP DEPTH 10124.0 10151. 0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DO¡~HOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL 1FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIHUM ANGLE: MA,'{IMUM ANGLE: 23-SEP-03 Insite 4.3 Memory 10151.0 10145.0 10151.0 45.4 45.4 # TOOL STRING (TOP TO VENDOR TOOL CODE GM $ BOTTOM) TOOL TYPE Dual GR TOOL NUMBER # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): 3.750 9277.0 . . BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: Flo Pro 8.60 65.0 9.2 18500 8.0 .000 .000 .000 .000 .0 130.8 .0 .0 # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type...... ......... . . .0 Data Specification Block Type.. ...0 Logging Direction.................Down Optical log depth units...........Feet Data Reference Point..... .........Undefined Frame Spacing.....................60 .1IN Max frames per record.............Undefined Absent value...................... -999 Depth Uni ts . . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O Service Order Units FT FT/H API Size 4 4 4 Code Offset o 4 8 Channel 1 2 3 Name DEPT ROP GR MWD060 MWD060 Nsam 1 1 1 Rep 68 68 68 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 10117.5 10151 10134.3 68 10117.5 10151 ROP MWD060 FT/H 3.83 10. 6.47583 12 10145.5 10151 GR MWD060 API 20.22 34.34 25.4479 14 10117.5 10124 First Reading For Entire File..........l0117.5 Last Reading For Entire File...........l0151 File Trailer Service name.............STSLIB.006 Service Sub Level Name... Version Number...........l.0.0 Date of Generation.......03/l2/05 Maximum Physical Record..65535 File Type................ LO Next File Name...........STSLIB.007 Physical EOF File Header Service name.............STSLIB.007 Service Sub Level Name... Version Number...........l.0.0 Date of Generation.......03/l2/05 Maximum Physical Record..65535 Fi 1 e Type................ LO Previous File Name.......STSLIB.006 . Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE GR ROP $ 7 . header data for each bit run in separate files. 7 .5000 START DEPTH 10124.5 10151. 5 STOP DEPTH 10178.5 10206.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE GM $ BOTTOM) TOOL TYPE Dual GR # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type.................. 0 Data Specification Block Type.....O Logging Direction.................Down Optical log depth units...........Feet Data Reference Point..............Undefined Frame Spacing.....................60 .1IN Max frames per record.............Undefined Absent value...................... -999 Depth Units....................... Datum Specification Block sub-type...O 23-SEP-03 Insite 4.3 Memory 10206.0 10151. 0 10206.0 44.1 44.1 TOOL NUMBER 3.750 9277 . 0 Flo Pro 8.60 65.0 9.2 18500 8.0 .000 .000 .000 .000 .0 130.8 .0 .0 Name Service Order Units Size Nsam Rep Code Offset Channel . . DEPT FT 4 1 68 0 1 ROP MWD070 FT/H 4 1 68 4 2 GR MWD070 API 4 1 68 8 3 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 10124.5 10206 10165.3 164 10124.5 10206 ROP MWD070 FT/H 3.75 47.27 14.6667 110 10151. 5 10206 GR MWD070 API 21. 6 44.34 30.7385 109 10124.5 10178.5 First Reading For Entire Fi1e..........10124.5 Last Reading For Entire File...........10206 File Trailer Service name.............STSLIB.007 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......03/12/05 Maximum Physical Record..65535 File Type........ ....... .LO Next File Name...........STSLIB.008 Physical EOF File Header Service name.... .........STSLIB.008 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......03/12/05 Maximum Physical Record..65535 File Type................ LO Previous File Name.......STSLIB.007 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE GR ROP $ 8 header data for each bit run in separate files. 8 .5000 START DEPTH 10179.0 10206.5 STOP DEPTH 10202.0 10230.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TO DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED IRPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: 23-SEP-03 Insite 4.3 Memory 10230.0 10206.0 10230.0 44.1 44.1 # TOOL STRING (TOP TO VENDOR TOOL CODE GM $ BOTTOM) TOOL TYPE. Dual GR TOOL NUMBER # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): 3.750 9277.0 . . # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: Flo Pro 8.60 65.0 9.0 18500 9.0 .000 .000 .000 .000 .0 130.8 .0 .0 # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type.................. 0 Data Specification Block Type.....O Logging Direction.................Down Optical log depth units...........Feet Data Reference Point..............Undefined Frame Spacing.....................60 .1IN Max frames per record.............Undefined Absent value......................-999 Depth Units....................... Datum Specification Block sub-type...O Service Order Units FT FT/H API Size 4 4 4 Code Offset o 4 8 Channel 1 2 3 Name DEPT ROP GR MWD080 MWD080 Nsam 1 1 1 Rep 68 68 68 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 10179 10230 10204.5 103 10179 10230 ROP MWD080 FT/H 11. 9 1276.57 89.409 48 10206.5 10230 GR MWD080 API 22.91 35 29.2108 47 10179 10202 First Reading For Entire File..........10179 Last Reading For Entire File...........l0230 File Trailer Service name............ .STSLIB.008 Service Sub Level Name... Version Number...........l.0.0 Date of Generation.......03/12/05 Maximum Physical Record..65535 Fi 1 e Type................ LO Next File Name...........STSLIB.009 Physical EOF File Header Service name.............STSLIB.009 Service Sub Level Name... Version Number...........l.0.0 Date of Generation.......03/12/05 Maximum Physical Record..65535 File Type................ LO . Previous File Name.......STSLIB.008 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE GR ROP $ 9 . header data for each bit run in separate files. 9 .5000 START DEPTH 10202.5 10230.5 STOP DEPTH 10203.0 10231. 0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE GM $ BOTTOM) TOOL TYPE Dual GR # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type..................O Data Specification Block Type.....O Logging Direction.................Down Optical log depth units...........Feet Data Reference Point..............Undefined Frame Spacing.....................60 .1IN Max frames per record.............Undefined }\bsent value..................... .-999 Depth Uni ts . . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O 24-SEP-03 Insite 4.3 Memory 10231. 0 10230.0 10231. 0 44.1 44.1 TOOL NUMBER 82758 3.750 9277.0 Flo-Pro 8.60 65.0 9.0 18500 9.0 .000 .000 .000 .000 .0 130.0 .0 .0 . . Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD090 FT/H 4 1 68 4 GR MWD090 API 4 1 68 8 3 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 10202.5 10231 10216.8 58 10202.5 10231 ROP MWD090 FT/H 22.5 23.03 22.765 2 10230.5 10231 GR MWD090 API 18.93 19.31 19.12 2 10202.5 10203 First Reading For Entire File..........l0202.5 Last Reading For Entire File...........l0231 File Trailer Service name.............STSLIB.009 Service Sub Level Name... Version Number...........l.0.0 Date of Generation.......03/12/05 Maximum Physical Record..65535 File Type............... .LO Next File Name...........STSLIB.010 Physical EOF File Header Service name.............STSLIB.010 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.... ...03/12/05 Maximum Physical Record..65535 Fi 1 e Type................ LO Previous File Name.......STSLIB.009 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE GR $ 10 header data for each bit run in separate files. 10 .5000 START DEPTH 10203.5 STOP DEPTH 10309.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER 1FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: 24-SEP-03 Insite 4.3 Memory 10341.0 10231. 0 10341. 0 43.8 46.7 # TOOL STRING (TOP TO VENDOR TOOL CODE GM $ BOTTOM) TOOL TYPE Dual GR TOOL NUMBER # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): 4.125 9277 . 0 . . # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: Flo Pro 8.60 65.0 8.9 18500 9.0 .000 .000 .000 .000 .0 130.8 .0 .0 # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type.............. ....0 Data Specification Block Type.....O Logging Direction.................Down Optical log depth units...........Feet Data Reference Point..............Undefined Frame Spacing.....................60 .1IN Max frames per record. .......... ..Undefined Absent value......................-999 Depth Units....................... Datum Specification Block sub-type...O Name Service Order DEPT ROP MWD100 GR MWDlOO Units FT FT/H API Size 4 4 4 Code Offset o 4 8 Channel 1 Nsam Rep 1 68 1 68 1 68 2 3 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 10203.5 10341 10272.3 276 10203.5 10341 ROP MWDl 0 0 FT/H 6.74 57.95 22.8636 220 10231. 5 10341 GR MWDl 0 0 API 17.33 34.85 26.3054 212 10203.5 10309 First Reading For Entire File..........10203.5 Last Reading For Entire File...........10341 File Trailer Service name.............STSLIB.010 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......03/12/05 Maximum Physical Record..65535 File Type................LO Next File Name...........STSLIB.011 Physical EOF File Header Service name.............STSLIB.011 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......03/12/05 Maximum Physical Record..65535 File Type................ LO . . Previous File Name.......STSLIB.010 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE RPD RPM RPS RPX FET GR ROP $ 11 header data for each bit run in separate files. 11 .5000 START DEPTH 9795.5 9795.5 9795.5 9795.5 9795.5 10309.5 10341. 5 STOP DEPTH 11327.5 11327.5 11327.5 11327.5 11327.5 11315.0 11359.5 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TO DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: 27-SEP-03 Insite 4.3 Memory 11360.0 10341. 0 11360.0 49.7 93.3 # TOOL STRING (TOP TO VENDOR TOOL CODE EWR4 GM $ BOTTOM) TOOL TYPE ELECTROMAG. Dual GR TOOL NUMBER RESIS. 4 # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): 4.125 9277.0 # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: Flo Pro 8.60 65.0 8.9 18500 8.6 .190 .090 .220 .230 62.0 138.2 62.0 62.0 # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: .~ " # Data Format Specification Record Data Record Type..................O Data Specification Block Type.....O Logging Direction........... ......Down Optical log depth units...........Feet Data Reference Point..............Undefined . . Frame Spacing. . . . . . . . . . . . . . . . . . . . .60 .1IN Hax frames per record.............Undefined Absent value..................... .-99? Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD110 FT/H 4 1 68 4 2 GR MWD110 API 4 1 68 8 3 RPX MWDl10 OHJv!!v! 4 1 68 12 4 RPS MWD110 OHJv!!v! 4 1 68 16 5 RPM MWD110 OHJv!!v! 4 1 68 20 6 RPD MWDl10 OHJv!!v! 4 1 68 24 7 FET MWD110 HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 9795.5 11359.5 10577.5 3129 9795.5 11359.5 ROP MWDl10 FT/H 0.12 2183.73 79.1544 2037 10341. 5 11359.5 GR MWD110 API 18.36 181.5 41.181 2012 10309.5 11315 RPX MWD110 OHJv!!v! 0.55 2000 28.1287 3065 9795.5 11327.5 RPS MWD110 OHJv!!v! 0.36 962.54 24.4146 3065 9795.5 11327.5 RPM MWDl10 OHJv!!v! 0.4 392.09 25.3365 3065 9795.5 11327.5 RPD MWD110 OHMH 1. 37 2000 70.1256 3065 9795. 5 11327.5 FET MWD110 HOUR 0.22 133.91 31.2223 3065 9795.5 11327.5 First Reading For Entire File..........9795.5 Last Reading For Entire File...........11359.5 File Trailer Service name.............STSLIB.011 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......03/12/05 Maximum Physical Record..65535 File Type................LO Next File Name...........STSLIB.012 Physical EOF Tape Trailer Service name.............LISTPE Date.................... .03/12/05 Origin.................. .STS Tape Name................UNKNOWN Continuation Number......01 Next Tape Name...........UNKNOWN Comments.......... .......STS LIS Writing Library. Scientific Technical Services Reel Trailer Service name.............LISTPE Date.....................03/12/05 Origin. . . . . . . . . . . . . . . . . . . STS Reel Name................UNKNOWN Continuation Number......01 Next Reel Name...........UN~~OWN Comments.................STS LIS Writing Library. Scientific Technical Services Physical EOF Physical EOF End Of LIS File . .