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Home My WebLink About203-168 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMeDN REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed Abandon ❑ Plug Perforations ❑ Fracture Stimulate 0 Pull Tubing ❑ Operations shutdown 0 Suspend 0 Perforate IZI Other Stimulate ❑ Alter Casing 0 Change Approved Program 0 Plug for Redrill 0 Perforate New Pool 0 Repair Well ❑ Re-enter Susp Well 0 Other: 0 2. Operator Name: BP Exploration(Alaska),Inc 4. Well Class Before Work 5. Permit to Drill Number: 203-168 3. Address: P.O.Box 196612 Anchorage, Development El Exploratory 0 AK 99519-6612 Stratigraphic 0 Service ❑ 6. API Number: 50-029-22057-02-00 7. Property Designation(Lease Number): ADL 0028261 8. Well Name and Number: PBU S-27B 9. Logs(List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pools: PRUDHOE BAY,PRUDHOE OIL 11.Present Well Condition Summary: RECE IVED Total Depth: measured 16700 feet Plugs measured 11895 feet true vertical 8994 feet Junk measured feet AUG 0 9 2016 Effective Depth: measured 11895 feet Packer measured 10523 feet true vertical 9037 feet Packer true vertical 8613 feet p CC Casing: Length: Size: MD: TVD: Burst: Collapse: Structural Conductor 80 20"Conductor 32-112 32-112 Surface 2656 13-3/8"68#NT-80 31-2687 31-2687 5020 2260 Intermediate 9943 9-5/8"47#NT-80 30-9973 30-8265 6870 4760 Production Liner See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Perforation Depth: Measured depth: 10785-10815 feet 11000-11030 feet 11054-11084 feet 11142-11147 feet 11642-11672 feet 11682-11712 feet 11729-11754 feet 12970-12995 feet 14439-16656 feet True vertical depth: 8769-8787 feet feet 8896-8909 feet 8920-8932 feet 8952-8953 feet 9012-9016 feet 9017-9021 feet 9022-9025 feet 9065-9064 feet 9002-8998 feet Tubing(size,grade,measured and true vertical depth) See Attachment See Attachment See Attachment Packers and SSSV(type,measured and See Attachment See Attachment See Attachment true vertical depth) 12.Stimulation or cement squeeze summary: Intervals treated(measured): Treatment descriptions including volumes used and final pressure: SCANNED JAN 3 12017, 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 9 3392 106 1442 242 Subsequent to operation: 202 238 3404 1825 254 14.Attachments:(required per 20 AAC 25.070.25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations m Exploratory ❑ Development I1 Service 0 Stratigraphic ❑ Copies of Logs and Surveys Run 0 16.Well Status after work: Oil El Gas 0 WDSPL 0 Printed and Electronic Fracture Stimulation Data 0 GSTOR ❑ WINJ 0 WAG 0 GINJ 0 SUSP 0 SPLUG 0 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: N/A Contact Catron,Garry R(Wipro) Email Garry.Catron@bp.com Printed Name Catron,Garry R(Wipro) Title PDC Principal Engineer Signature 4r_editi7\ Phone +1 907 564 4424 Date 8/9/16 Form 10-404 Revised 5/2015 �j V1-1- t l C' RBDMS I.A.- AUG 1 1 2016 Submit Original Only • i Q. OooO0000 C CO fl .- O O M O M O — N N- V- Ln L) U) IC) N U N o 0 0 o O S o 0 0 i N I� M M co O co O 00 N V V ,q - ca CO co 00 00 CO N N- LO M V a7 N LO N- O) CO CO Nr O O V (1) N N- O O CO CO co co N CO CO CO M 00 CO CO CO 0 1 1 1 1 1 1 1 1 1 1 H CO CO O) N Lf) N- N N- O V co co co CO N O CO (9 CO CO CO M CO CO CO C O 6) O) '— N- O N O LU N CO CO N- O IU) C[) N � OCO � 0000 N •W W NN 0 0 (n N- O (N (N CO CO ICO CO CO CO O N 0 c) 0 0 r r CO O r,-.CD C) O O CO 0 FL UU C U Z ~ 000 J M M M (.0 r r J CO 4* •(n NN r- *k N (13 N O N CO O N N N 00 O coti N N N to N N N M ' ' r +' CO M LO N N O LO 't N CO r- M = 00 CO O) M O) 1 O Ln M C) N O) — W H C 0 W W .y 0 U U O C C Z Z Z Z Z Z W W W CO CO CO CO CO O D H Z Z D J J J D UU) ZJ_JF- HHRH 0 • Packers and SSV's Attachment PBU S-27B SW Name Type MD TVD Depscription S-27B PACKER 9816.34 8148.76 7" Liner Top Packer S-27B TBG PACKER 10522.84 8612.84 4-1/2" Baker S-3 Perm Packer S-27B PACKER 10585.3 8650.37 5" Baker ZXP Top Packer S-27B PACKER 14347.26 9005.4 4-1/2" Baker ECP Packer • • 0 _ 0a 2 / E\ % $ .- r 0 o- o% < - I 2 _ 2 cU / f / � § � - \ / f ? / G / O p 0 R / k 2z 2 c ® 2 L 0 eL = / D < I k ■ 2 « < x Co UJ g / 3 ct _oI I 0to= › / 0 - / W / / / s_ ® ix / \ ƒ cl_ \ / z z [ o / ƒ rt ± , 0 o $ ± < / % CI 2 2 ± R R Oco / ./ \ 2 Qz a � ƒ w z _\ - / :2 / k \ I- c / ¥ 2 Rm G 0El o O \ b \ / I 0 (O_ m 3 \ 9 2 3 2 / t 2 z « - 0 \ ± 9 = ± I 6 � i \ / / ƒ / / / NODD —E \ \ / EV 2 # 2 0 / 2 q / / \ / / N < Z \ \ / Ou \ � D J ~ 2 2 0 3 \ O / o w o 6 $ E / 2G0 ƒ Z / G2n2 # _Io G A2 = r \ - ƒ / 15 ODO wy < Rp- < < , m ± LIozzzo2 ƒ E � � Jco / ƒ � / < OO- O \ / / / w \ \ \ ƒ 0 ® bUU ± % U ± _ -J R * ± ± < E ? J —I M Ca O _I CO / / / / \ / 0,_ > > = / . < / \ D / / / cc \ / / w 1- < < e o e e \ d d \Es w 5 $ » ^ 03 / ® \ \ < WEE= 4"CNV �WH-LFEAD= FMC FETY NOTES: 3"FLOWL�E IN SKI).PORTIONS OF ACTUATOR= BAKE THIS WELLS FLOWLNE ARE 3"'" PREVIOUS KB.BEV= 65.3' VVELLBORES NOT SHOWN"' ChROIVE TBG&LNR— BF.B.EV= 3679' I WELL ANGLE>70°@11110'. KOP= 9973' Mai:Angie= 97 @ 14123' 2193' -H4-1/2"HES X NP,ID=3.813" Datum MD= 10944' Datum TVD= 8800'SS 3009' H 3-1/2'X 4-1/2"XO,D=2 992" GAS LIFT MANDRELS 13-3/8"CSG,68#,NT-80,D=12-415" — 2689' — ST MD IVO DEV TY FE VLV LATCH PORT DATE 6 3062 3062 6 MMG-2 DMY RK 0 04/18/04 4-1/2'TBG, 12.6#.13CR-80 VAM TOP. — 3009' 5 4129 4061 30 MMG-2 DOME RK 16 10/17/06 0152 bpf,C=3.958' 4 6452 5761 45 MMG-2 DOW. RK 16 10/17/06 Minimum ID = 2.750" @ 10569' 3 8275 7056 44 MMG-2 SO RK 24 10/17/06 + 2 9688 8054 43 MNG-2 DMY RK 0 04/18/04 3-1/2" HES XN NIPPLE '� 1 10378 8526 52 MVI-2 DMY RK 0 04/18/04 9809' H 9-5/8"X 7"BKR TEEBACK,D=7.50" 9-5/8"CSG,47#,NT-80-S,ID=8.681' H --9973 9816' H 9-5/8"X r BKR LIP&HGR D=6.26" ML LOUT WINDOW(S-27B)9973'-9989' 10500' H 3-1/2"HES X NP,ID=2.813" 10521' H4-1/2"X 3-1/2"XO,ID=2.990" C 10523' —j7"X 4-1/2"BKR S3 FKR,D=3.875" 10527' H3-1/2"X 4-1/2"XO,D=2.990" 10548' H3-1/2"HES X NP,D=2.813" 10569' H3-1/2"HES XN Imo',D=2.750" 10574' H 7"X 5-1/2"BKR LNR TIEBACK,D=5.25" 3-1/2"TBG, 12.6#,13CR80 VAM ACE, H 10580' 10580' —14-1/2"X 3-1/2'XO,D=2.992" .0152 bpf,ID=2.992" 10582' H4-1/2"WLEG,D=3.958' 10585' H 7"X 4-112"BKR ZXP LTP w/LNR HGR,ID=4.430" 7"LNR,26#,L-80 BTC-M,0383.bpf,D=6.276" H 10740' 1_411 PEf2FORATION SUMMARY REF LOG: SPERRY SUN vM.O ON 11/28/03-12/15/03 ANGLE AT TOP FUZE: 53"@ 10785' Note:Refer to Production OB for historical perf data SIZE SPF NTERVAL Opn/Sqz SHOT SQZ 2" 6 10785-10815 0 07/11/16 2" 6 11000-11030 0 07/11/16 2" 6 11054-11084 0 07/11/16 11895' H4-1/2"EP(04/18/13) 2" 6 11142-11147 0 07/11/16 2" 6 11642-11672 0 04/17/13 2" 6 11682-11712 0 04/17/13 I I 2-1/2" 6 11729-11754 0 08/26/04 I I 2-1/2" 6 11970-12995 0 08/26/04 4-1/2" SLOT 14439-16699 SLID 12112/03 11697' H PBTD 4-1/2"LNR,26#,L-80 BIC,.0152 bpf,D=3.958" H 16700' DATE REV BY COMMS NI S DATE REV BY COMN6NTS PRUDHOE BAY (MT 11/11/90 ORIGINAL COMPLETION 07/13/16 RCT/JMD PULLED PXN PLUG(07/06/16) WELL_ S-27B 11/20/95 PAB SIDETRACK(S27A) 07/13/16 CJS/JM) ADPERFS(07/11/16) FERMT No:"1031680 12/21/03 JOM/KK RIG SIDETRACK(S-27B) 07/14/16 KDP/JMD TREE C/O(07/04/16) AR No: 50-029-22057-02 04/30/13 KJB/PJC CEP!ADPERF(04/17/13) SEC 35,T12N,T12E, 1633'FN. &4048 FEL 04/30/13 PJC DRAWING REFORMAT 10/07/15 NLWIJMD PULL FLOW THRU SUBSET PXN PLUG BP Exploration(Alaska) 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. Q 03 - L b S Well History File Identifier Organizing (done) D Two-sided ""1111111" 111111 RESCAN DIGITAL DATA D Color Items: D Greyscale Items: D Diskettes, No. D Other, NofType: D Poor Quality Originals: D Other: NOTES: Date I! ¡r¡!O(p Datel/lt! /ó & ~ x 30 = jL; D Date J J¡1! 00 BY: ~ Project Proofing BY: "'-~ Scanning Preparation BY: ~ Production Scanning Stage 1 77 (Count does include cover sheet) V YES NO ~p Page Count from Scanned File: BY: Page Count Matches Number in SCa¡nDin9.7.p ep~ration: ~ Date: I 11/00 If NO in stage 1, page(s) discrepancies were found: Stage 1 BY: Maria Date: Scanning is complete at this point unless rescanning is required. ReScanned BY: Maria Date: Comments about this file: D Rescan Needed 1111111111111111111 OVERSIZED (Scannable) D Maps: D Other Items Scannable by a Large Scanner OVERSIZED (Non-Scannable) D Logs of various kinds: D Other:: ~~ ,~"IIIIIIIIIIIIIII mP /5/ + i & = TOTAL PAGES r-t~ f (Count does not i~~~ude cover ste~t) m 11111111111111 "III /5/ YES NO /5/ 1111111111111111111 11111111111111 ,,1/1 /5/ Quality Checked 1IIII1I111111111111 10/6/2005 Well History File Cover Page.doc 9 tU 1 STATE OF ALASKA A•KA OIL AND GAS CONSERVATION COM•ON MAY 1 is "2.01 REPORT OF SUNDRY WELL OPERATIONS AOGCC 1. Operations Abandon 11 Repair Well U Plug Perforations U. Perforate U , Other (J Performed: Alter Casing ❑ Pull Tubing❑ Stimulate - Frac ❑ Waiver ❑ Time Extension0 Change Approved Program ❑ Operat. Shutdown❑ Stimulate - Other ❑ Re -enter Suspended Well❑ 2. Operator 4. Well Class Before Work: 5. Permit to Drill Number: Name: BP Exploration (Alaska), Inc • Development 0 . Exploratory ❑ 203 -168 -0 3. Address: P.O. Box 196612 Stratigraphic❑ Service ❑ 6. API Number: Anchorage, AK 99519 -6612 50- 029 - 22057 -02 -00 7. Property Designation (Lease Number): 8. Well Name and Number: . ADL0028261 PBU S -27B 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field /Pool(s): . To Be Submitted PRUDHOE BAY, PRUDHOE OIL 11. Present Well Condition Summary: Total Depth measured 16700 feet Plugs measured 11895 feet true vertical 8994 feet Junk measured None feet Effective Depth measured 11895 feet Packer measured See Attachment feet true vertical 9037.47 feet true vertical See Attachment feet Casing Length Size MD TVD Burst Collapse Structural None None None None None None Conductor 80 20" 91.5# H -40 30 - 110 TVD - 1490 470 Surface 2660 13 -3/8" 68# NT -80 29 - 2689 - 5020 2260 Intermediate None None None None None None Production 9945 9 -5/8" 47# NT -80 28 - 9973 - 6870 4760 Liner See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Perforation depth Measured depth 11642 - 11672 feet 11682 - 11712 feet 11729 - 11754 feet 12970 - 12995 feet 14439 - 16656 feet True Vertical depth 9011.96 - 9015.97 feet 9017.22 - 9020.7 feet 9022.49 - 9024.92 feet 9064.96 - 9064.36 feet 9001.92 - 8997.52 feet Tubing (size, grade, measured and true vertical depth) 4-1/2" 12.6# 13Cr80 27 - 3009 27 - 3008.69 Packers and SSSV (type, measured and true vertical depth) See Attachment See Attachment See Attachment Packer None None None SSSV 12. Stimulation or cement squeeze summary: Intervals treated (measured): s r W 4SED j U L 2 2 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: 6 164 4008 1772 233 Subsequent to operation: 12 84 112 910 212 14. Attachments: 15. Well Class after work: Copies of Logs and Surveys Run Exploratory❑ Development el Service ❑ Stratigraphic ❑ Daily Report of Well Operations X 16. Well Status after work: Oil 12 Gas ❑ WDSPLU GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP ❑ SPLUG❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: N/A Contact Nita Summerhays Email Nita.Summerhays( BP.com Printed Name Nita ummerha s Title Petrotechnical Data Technician Signat _ � � % / %L / � `'`L� Phone 564 -4035 Date 5/13/2013 - ✓L- RBDMS MAY 13 201 X1 // 3 /" Form 10-404 Revised 10/2012 4 Submit Original Only • • Daily Report of Well Operations ADL0028261 ACTIVITYDATE 1 SUMMARY ** *WELL SHUT IN ON ARRIVAL* ** DRIFT TUBING WITH A 2.5" CENT & SAMPLE BAILER. TOOLS SD @ 11107' SLM/11136' MD. BAILER RECOVERED 1/4 CUP OF SAND & SCALE.. DRIFT TUBING WITH A 3.25" CENTRALIZER. TAG 3 1/2" x 4 1/2" XO @ 2980' SLM FOR A +29' CORR. BACK TO 3009' MD. RAN SLB DUAL PPK GAUGES PER PROGRAM WITH GOOD DATA. ** *WELL LEFT SHUT IN. PAD OP WALK THROUGH UPON 4/10/2013 DEPARTRUE * ** - lep og, £, 'e e ;. MIRU. MU Dimple CTC. PT. MU PDS GR CCL logging BHA (Total Max OD 2.5 ", OAL 14.81'). PT PCE, Open Swab + SSV, Bullhead well to 2% SL KCL w/ SafeLube, RIH to 1800' 4/16/2013 « <IN PROGRESS »> CTU #8 1.75" - Depth Log, Add Perf, Set IBP Cont. RIH with PDS GR CCL. Log from 12,000' to 10,250' and paint flag at 11,750' uncorrected. POOH. LD PDS BHA. Good Data, +5 correction to Sperry 11/28/03 OH log. Matches well bore diagram config, MU 30' gun assembly, 2" x 30', 6 spf 60 degree, pwr Jet HMX. PT & RIH. Shoot 1st interval from 11,682 to 11,712'. POOH. LD spent guns. MU 2nd perf assembly. PT. Load well with 2% KCL w/ SafeLube. RIH. Tie in to coil flag at 11,752' CTM at top shot. Perforate 11,642' - 11,672' CTM. POOH 4/17/2013 « <IN PROGRESS »> CTU #8 1.75" - Depth Log, Add Perf, Set IBP Cont. RIH with PDS GR CCL. Log from 12,000' to 10,250' and paint flag at 11,750' uncorrected. POOH. LD PDS BHA. Good Data, +5 correction to Sperry 11/28/03 OH log. Matches well bore diagram config, MU 30' gun assembly, 2" x 30', 6 spf 60 degree, pwr Jet HMX. PT & RIH. Shoot 1st interval from 11,682 to 11,712'. 4/17/2013 « <IN PROGRESS »> CTU #8 1.75" - Depth Log, Add Perf, Set IBP Cont. RIH with PDS GR CCL. Log from 12,000' to 10,250' and paint flag at 11,750' uncorrected. POOH. LD PDS BHA. Good Data, +5 correction to Sperry 11/28/03 OH log. Matches well bore diagram config, MU 30' gun assembly, 2" x 30', 6 spf 60 degree, pwr Jet HMX. PT & RIH. Shoot 1st interval from 11,682 to 11,712'. POOH. LD spent guns. MU 2nd perf assembly. PT. Load well with 2% KCL w/ SafeLube. RIH. Tie in to coil flag at 11,752' CTM at top shot. Perforate 11,642' - 11,672' CTM. POOH 4/17/2013 « <IN PROGRESS »> CTU #8 1.75" - Depth Log, Add Perf, Set IBP OOH with perforating assembly, LD guns, All shots fired, ball recovered. RIH w/ 2.5" IBP and setting assembly. Tie in to coil flag. Set 2.50" IBP @ 11895' mid element, top of IBP @ 11,888' CTM POOH, running tool indicates good set. RDMO 4/18/2013 « <Job complete »> • • Daily Report of Well Operations ADL0028261 ** *WELL S/I ON ARRIVAL * ** ATTEMPT TO RIG UP, CRANE ISSUES 4/19/2013 ** *WSR CONTINUED ON 4/20/13 * ** ** *WSR CONTINUED FROM 4/19/13 * ** SET 3 -1/2" XN LOCK W/ FLOW THRU SUB @ 10540' SLM/10569' MD BAD SET INDICATED BY PARTIALLY SHEARED CHECK SET PULL 3 -1/2" XN LOCK W/ FLOW THRU SUB FROM 10540' SLM/10569' MD 4/20/2013 ** *WSR CONTINUED ON 4/21/13 * ** ** *WSR CONTINUED FROM 4/20/13 * ** BRUSH X & XN NIPPLE @ 10548' MD & 10569' MD W/ 3.5" BLB SET 3 -1/2" XN LOCK W/ FLOW THRU SUB @ 10540' SLM/10569' MD GOOD SET VERIFIED BY SHEARED CHECK SET 4/21/2013 ** *WELL LEFT S/I ON DEPARTURE * ** Casing / Tubing Attachment ADL0028261 Casing Length Size MD TVD Burst Collapse CONDUCTOR Length 20" 91.5# H -40 30 VIE 110 TVD 1490 470 LINER 7" 26# L -80 9809 10740 7240 5410 LINER 4 -1/2" 12.6# L -80 10574 16700 8430 7500 PRODUCTION 9 -5/8" 47# NT -80 28 9973 6870 4760 SURFACE 13 -3/8" 68# NT -80 29 2689 5020 2260 TUBING 4 -1/2" 12.6# 13Cr80 27 3009 8430 7500 • ID 1 • • Packers and SSV's Attachment ADL0028261 SW Name Type MD ND Depscription S -27B PACKER 9816 8083.2 7" Baker Packer S -27B PACKER 10523 8547.63 4 -1/2" Baker S -3 Perm Packer S -27B PACKER 10585 8584.89 4 -1/2" Baker ZXP Packer • Tom= 4'GW V11Bllt�AD = FMC • ISTY NOTE'S: 3' FLOVVLNE N SKID. PORTIONS OF ACTUATOR = 076 S-27B THS VIEWS FLOWL9E ARE 3' *"' PREVIOUS KB. B1'1/ = 65.3' WELU3ORES NOT SHOWN'*' CFROMETBG & LN2" BF. ELEV = 36.79' I .4 1 KOP= 9973' M6 Mole gle = 97 @ 14123' , I 2193' I- 14-12' H9; X NP, D = 3.813' I Datum M) = 10944' Datum TVD = 8800'SS 3009' 3-12" X 4-12' XO, D = 2.992" I 13 -3/8" CSG, 6811, NT-80, D =12.415' H 2689' GAS LFT MANDRELS 4-1/2' TBG,12.6S,13CR -80 VA TOP, 3009' 1/ ST MD TVD OEV TYPE VLV LATCH FORT GATE .0152 f D = 3.958' 6 3062 3062 6 10610.2 DMY RI( 0 04/18/04 ' 5 4129 4061 30 I-2 DOME E ' 16 10/17/06 4 6452 5761 45 MA0-2 DOME RK ' 16 10/17/06 Minimum ID = 2.750" @ 10569' 3 8275 7056 44 89110 -2 SO RK ' 24 10/17/06 3 -1/2" HES XN NIPPLE 2 9688 8054 43 1040-2 OW RK ' 0 04/18/04 1 10378 8526 52 164V40-2 01W RK 0 04/18/04 9809' 9-5/8' X T BKR TEBACK, D = 7.50' I 1 9-5/8' CSG, 470, NT -80-S , D = 8.681" H ' 1 8816' H9 -5/8' X T BKR LIP & HGR D = 626' I ROLLOUT WINDOW (S-27B) 9973' - 9989' ' I 10600' H 3- 1/2'H9;X NIP, D= 2.813' I 10621' H4-112' X 3-1/2' XO, D = 2190' I — 5( 10523 j--17* X 4-12 R, D ' SKR S3 PK = 3.875' I `` 10627' H3-12" X 4-12' XO, D = 2.990" I ' ' I 10548' H3- 12' HESX NP, D= 2.813" I 10669' I-13-1/2' FLOW TH R SUB (04/21/13) I ,--I 10569' H3-1/2" H'S XN NP, D = 2.750'1 wii 11 H T X 5-1/2" BKR LNR D IEM = 2.2. CK, 1 5.25' I 2' 3-1 TBG, 12.60,13CR 89 VAM ACE, r 10580' ' I— I4- 12' -12' X O, 992' .0152 bpf, D = 2.992' I r 1 Qbar H4-1/2" WLBG, I) = 3.958 I 10686' Hr X 4-12' BKR ZXP LTP w /I.NR HGR, D = 4.430' I 17" L1 R, 260, L -80 BTC-M, 0383. bpf, D = 6276" H 10740' !y I" PERFORATION SUMWIRY REF LOG: SPERRY SW AVID ON 11/28/03 - 12/15/03 ANGLE AT TOP PERF: 82° 0 11642 Note: Refer to Production DB for historical pert data I 11896' I—I4 -1/2' W(04/18/13) I SIZE SPF INTERVAL Opn!Sgz SHOT SOZ 2" 6 11642 -11672 0 04/17/13 2" 6 11682 -11712 0 04/17/13 I I 2-1/2' 6 11729 -11754 0 08/26/04 I 2-1 2" 6 11970 -12995 0 08/26/04 4-12" SLOT 14439 -16699 SLID 12/12/03 I I _ 11697' PBTD I4 -1n ' 2 D 26#, L-80 BTC, 0.152 bpf , = 6276' H 16700' I J L-- DATE REV BY COM9U41S DATE REV BY COLSENTS PRUDHOE BAY U4T 11/11/90 OR G1NAL COMPLETION 04/30/13 K18/ PJC CEP/ AD:IMF (04/17/13) W8.1.: 5-276 11/20/95 PAB SIDETRACK(S27A) 0430113 PJC DRAWNG F 0RMAT PHUT No: "2031680 12/21/03 JDM/WC RIG SIDETRACK (5-278) AR Na: 50. 029 - 22057-02 10/20/04 GRC/TLH KB & BF B`EV CORRECTIONS SEC 35, T12N, T12E, 1633' FM. & 4048' FEL 10/20/06 JRPIPAG GLV CJ0 (10/17/06) 04/30/13 SUIPJC SET FLOW 'MU (4/21/13) BP B ploratlon (Alaska) ~ BP Exploration (Alaska) Inc. Attn: Well Integriry Coordinator, PRB-20 Post Office Box 196612 Anchorage, Alaska 99519-6612 June 25, 2009 Mr. Tom Maunder Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage, Alaska 99501 Subject: Corrosion Inhibitor Treatments of S-Pad Dear Mr. Maunder, ~ ~ ~ ~uL o ~ 2oos ~~~ska ~il ~ Gas C~nsa Comm~~sio~ At~~~~rag~ a~3-1~~ ,S -. a~ ,~ Enclosed please find a spreadsheet with a list of wells from S-Pad that were treated with corrosion inhibitor in the surface casing by conductor annulus. The corrosion inhibitor is engineered to prevent water from entering the annular space and causing external corrosion that could result in a surface casing leak to atmosphere. The attached spreadsheet represents the well name, 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, Anna Dube, at 659-5102. Sincerely, ~~;~~~~ ~i~; ~~~ ;, 20~~~ Torin Roschinger BPXA, Well Integrity Coordinator ~ BP Exploration (Alaska ) Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operetions (10-404) S-pad i~ oAtA 6/25/2009 Well Name PTD N Initial top at cemeM Vol. of cement um ed Final top of cement Cement top off da[e Cortosian inhibitor Corrosion inhibitod sealant date it bbls ft na al S-01B 1952020 025 NA 025 NA 2.6 5/30/2009 S-02A 1941090 0.25 NA 025 NA ~.7 5/25/2009 S-03 7811900 1325 NA 1325 NA 92.65 5/20/2009 5-04 1830790 0 NA 0 NA 0.9 5/25/2009 S-OSA 1951890 0 NA 0 NA 0.9 5/26/2009 S-06 1821650 0 NA 0 NA 0.9 5/26/2009 S-07A 1920980 0 NA 0 NA 0.9 5/26/2009 S-OBB 2070520 0 NA 0 NA 0.85 5/27/2009 S-09 1821040 1.5 NA 1.5 NA 9.4 5/37/2009 S-10A 1911230 0.5 NA 0.5 NA 3.4 5/31I2009 5-116 1990530 0.25 NA 025 NA 1.7 5/27/2009 S-72A 1851930 0.25 NA 025 NA 1.7 6/1/2009 S-~3 1821350 8 NA 8 NA 55.3 6/i/2009 S-15 1840170 025 NA 025 NA 3 6/2/2009 S-17C 2020070 025 NA 025 NA 2.6 6/1/2009 S-18A 2021630 0.5 NA 0.5 NA 3 6/2/2009 5-19 1861160 0.~5 NA 0.75 NA 22 5/19/2009 S-20A 2010450 025 NA ~ 025 NA 1.3 5/19/2009 5-21 1900470 0.5 NA 0.5 NA 3.4 5/25/2009 S-22B 1970510 0.75 NA 0.75 NA 3 5/19/2009 5-23 1907270 025 NA 025 NA 1.7 5/25/2009 S-24B 2031630 0.5 NA 0.5 NA 2.6 5/25/2009 S~25A 1982140 0.5 NA 0.5 NA 2.s 5/25/2009 5-26 1900580 0.75 NA 0.75 NA 3.4 5/26/2009 -278 2037680 0.5 NA 0.5 NA 2.6 5/31/2009 S-28B 2030020 0.5 NA 0.5 NA 2.6 5/37/2009 S-29AL1 1960120 0 NA 0 NA 0.85 5/27/2009 S30 7900660 0.5 NA 0.5 NA 5.1 5/31/2009 S-31A 1982200 0.5 NA 0.5 NA 3.4 5/26/2009 S-32 7907490 0.5 NA 0.5 NA 3.4 5/31/2009 S33 1921020 0.5 NA 0.5 NA 4.3 5/26/2009 S-34 1921360 0.5 NA 0.5 NA 3.4 5/31/2009 S-35 1921480 0 NA 0 NA .BSin 5/31/2009 S-ss 1921160 0.75 NA 0.75 NA a.25 5/27I2009 5-37 1920990 1.25 NA 125 NA 11.9 5/27/2009 5-38 1921270 0.25 NA 0.25 NA 102 5/27/2009 5-41 1960240 1.5 NA 1.5 NA 11.1 5/30/2009 S-42 1960540 0 NA 0 NA 0.9 5/30/2009 S-43 19~0530 0.5 NA 0.5 NA 1.7 5/28/2009 5-44 1970070 025 NA 025 NA 1.7 5/28/2009 S-100 2000780 2 NA 2 NA 21.3 5/29/2009 5-107 2001150 125 NA 125 NA 11.9 5/29/2009 S-102Lt 2031560 125 NA 125 NA 11.1 5/31/2009 S-103 2001680 1.5 NA 1.5 NA 17.9 5/18/2009 S-104 2001960 1.75 NA 1.75 NA 15.3 5/20/2009 5-105 2001520 4 NA 4 NA 32.7 5/20/2009 5-106 2010120 1625 NA 1625 NA 174.3 6/2/2009 S-107 2011130 225 NA 225 NA 28.9 5/18/2009 S-~OS 2011000 3.5 NA 3.5 NA a0 5/30/2009 S-109 2022450 2 NA 2 NA 21.3 5/30/2009 5-110 2011290 11.75 NA 11.75 NA 98.8 5/30/2009 S-111 2050510 2 NA 2 NA 19.6 5/30/2009 S-112 2021350 0 NA 0 NA 0.5 5/30/2009 5-113 2021430 1.75 NA 1.75 NA 22.1 5/1A/2009 S174A 2021980 125 NA 125 NA 102 5/30/2009 S-~75 2022300 2.5 NA 2.5 NA 272 5/29/2009 S-116 2037810 1.5 NA 1.5 NA 13.6 5/28/2009 5-177 2030120 1.5 NA 1.5 NA 15.3 5/29/2009 S-7~s 2032000 5 NA 5 NA 76.5 5/28/2009 S-119 2041620 1 NA 1 NA 52 5/30/2009 5-120 2031980 5.5 NA 5.5 NA 672 5/29/2009 5-121 2060410 4.5 NA 4.5 NA 53.6 5/28l2009 5-122 2050810 3 NA 3 NA 21.3 5/29/2009 S-723 2041370 1.5 NA 1.5 NA 20.4 5/26/2009 S-724 2061360 1.75 NA 1.75 NA 11.9 5/26I2009 S-725 2070830 2.25 NA 225 NA 20.4 5/28/2009 5-126 20710970 125 NA 125 NA 15.3 6/1/2009 5-200 1972390 125 NA 725 NA 74.5 5/28l2009 5-201 ~2001840 0 NA 0 NA 0.85 6/19/2009 5-213A 2042130 2 NA 2 NA 13.6 5/29/2009 5-275 2021540 2 NA 2 NA ~8.7 6/1/2009 5-216 2001970 4.75 NA 4.75 NA 51 5/29/2009 S-217 2070950 025 NA 025 NA 1.7 6/1/2009 5-400 2070740 2 NA 2 NA 9.4 5/28/2009 S-aot 2060780 16 NA 16 NA 99.5 6/2/2009 S-50a 0 NA 0 NA 0.85 5/28/2009 ~ • • -~-~~__ MICROFILMED 03/01/2008 DO NOT PLACE s.. ~.. #t: ANY NEW MATERIAL UNDER THIS PAGE F:\LaserFiche\CvrPgs_Inserts\Microfilm Marker.doc DI.~,:'¿¿E':~ C/' f; M\lf:,E f1 , '11\ ,i /' t",......, II \' IL., 11._- OCT 1 0 2006 10/06106 Sc~lumberger Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth D03-/~15 i~ª Oill~, G~~ Gon~" Cf1mmi~f:kìlì: NCr3982 ' . .Aij]çOOr~ Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay Well Job# Log Description Date BL 3-29/J-32 11414759 SBHP SURVEY 09/04/06 1 L4-10 11285941 MEM PROD PROFILE 09/15/06 1 L2-21A 11421023 LDL 09/11/06 1 C-18A 11285934 MEM PROD & INJECTION 07/29/06 1 Y-24 N/A INJECTION PROFILE 09/03/06 1 Z-31 11414379 INJECTION PROFILE 09/04/06 1 S-27B 11285940 MEM PROD PROFILE 09/14/06 1 P-13 11414277 INJECTION PROFILE 09/03/06 1 X-33 11421024 LDL 09/12/06 1 Z-19A N/A MDT 09/08/06 A-17 11414381 USIT 09/07/06 X-01 11422961 USIT 09/09/06 H-04A 11285942 SCMT 09/17/06 15-39A 11212888 SCMT 09/16/06 C-09A 11209608 MCNL 06/16/06 C-18A 11285934 MCNL 07/29/06 Z-14B 40013765 OH EDIT OF MWD/LWD 07131/06 Color CD 1 1 1 1 1 ( Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 ~ÇANNED GCl 3 1 Z005 Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth e e WELL LOG TRANSMITTAL B D3-/l.Pß To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West ih Ave., Suite 100 Anchorage, Alaska 99501 February 17, 2006 J 3LQLCLp RE: MWD Formation Evaluation Logs S-27B, 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 S-27B: LAS Data & Digital Log Images: 50-029-22057 -02 1 CD Rom ~ ;ì/9-r;rloLD (8 J"y\ DATA SUBMITTAL COMPLIANCE REPORT 1/3/2006 Permit to Drill 2031680 Well Name/No. PRUDHOE BAY UNIT S-27B Operator BP EXPLORATION (ALASKA) INC J!'tA,¿ / kl...JJ D j API No. 50-029-22057-02-00 MD 16700 _ TVD 8994 ~ Completion Date 12/18/2003 - Completion Status 1-01L Current Status 1-01L UIC N REQUIRED INFORMATION Mud Log No Samples No Directional Survey ~_ DATA INFORMATION Types Electric or Other Logs Run: DIR, GR, RES, ABI Well Log Information: Log/ Electr Data Digital Dataset Type Med/Frmt Number Name (data taken from Logs Portion of Master Well Data Maint Log Log Run Scale Media No Interval OH / Start Stop CH . Received Comments Name Interval Start Stop 9956 16700 1/13/2004 9956 16700 1/13/2004 MWD 2-7 9858 16665 2/12/2004 GR, EWR4, ROP 2-7 9858 16665 2/12/2004 GR, EWR4, ROP 2-7 9858 16665 2/12/2004 GR, EWR4, ROP 2-7 9858 16665 2/12/2004 GR, EWR4, ROP Sample Set Sent Received Number Comments . Daily History Received? &>N Formation Tops Q)N Rpt Directional Survey Rpt Directional Survey vb D Las 12401 Induction/Resistivity D Las 12401 RaL" of P'eneLrcl!iulJ (,tL . J (..Jtv " < l~ct~/R.."i"tivi\y t..- I ~ 1It.V'~ .. BI2L-- Rate of f'e,'Ie'L,dI.;UII Well Cores/Samples Information: ADDITIONAL INFORMATION Well Cored? Y f9 Chips Received? v I þ, Analysis ~ Received? --- Comments: DATA SUBMITTAL COMPLIANCE REPORT 1/3/2006 Permit to Drill 2031680 Well Name/No. PRUDHOE BAY UNIT S-27B Operator BP EXPLORATION (ALASKA) INC API No. 50-029-22057-02-00 MD 16700 C~ Date -~~ TVD 8994 12/18/2003 Completion Status 1-01L Current Status 1-01L JJ UIC N Date: -I Øv>-.. ~ ~ Compliance Reviewed By: . . '... 1. Operations Performed: Abandon D Alter Casing 0 Change Approved Program 0 2. Operator Name: 3. Address: . STATE OF ALASKA . RECE' ALAS~IL AND GAS CONSERVATION CO jSSION· ,IVED REPORT OF SUNDRY WELL OPERATIONSr 132004 Repair Well 0 Pull Tubing 0 Operation Shutdown 0 S· I Jlaska Oil R. ~;mC"n^ C .. tlmu ate U ~'LJ VIIi>. omm¡SSIGrI WaiverO Time Exten~~rage Re-enter Suspended Well 0 5. Permit to Drill Number: 203-1680 6. API Number 50-029-22057-02-00 Pluq PerforationsD Perforate New Pool D Perforate IK] 4. Current Well Class: Development 00 BP Exploration (Alaska), Inc. true vertical 8994.1 feet measured 16700 feet true vertical 8994.1 feet Length Casing Conductor Liner Liner Liner Liner Production Surface Perforation deDth: Measured depth: 11729 -11754,12970 -12995,14439 -16656 True vertical depth: 9022.49 - 9024.92, 9064.96 - 9064.36, 9001.92 - 8997.52 Tubing ( size, grade, and measured depth): Packers & SSSV (type & measured depth): P.O. Box 196612 Anchorage, Ak 99519-6612 7. KB Elevation (ft): 65.30 8. Property Designation: ADL-028261 11. Present Well Condition Summary: Total Depth measured 16700 Effective Depth 80 22 909 27 6098 9945 2661 Exploratory 0 StratigraphicD ServiceO 9. Well Name and Number: S-27B 10. Field/Pool(s): Prudhoe Bay Field / Prudhoe Oil Pool feet Size Plugs (measured) None Junk (measured) None MD TVD Burst Collapse 30 110 30.0 110.0 1490 470 9809 - 9831 8143.3 - 8159.7 6870 4760 9831 - 10740 8159.7 - 8742.6 7240 5410 10574 - 10601 8643.6 - 8659.8 7240 5410 10601 - 16699 8659.8 - 8994.2 8430 7500 28 - 9973 28.0 - 8265.1 5020 2270 29 - 2690 29.0 - 2690.0 5020 2270 20" 91.5# H-40 9-5/8" 47# L-80 7" 26# L-80 7" 26# L-80 4-1/2" 12.6# L-80 13-3/8" 68# NT80CYHE 13-3/8" 68# NT-80 4-1/2" 12.6# 13Cr80 3-1/2" 9.2# 13Cr80 4-1/2" 12.6# 13Cr80 3-1/2" 9.2# 13Cr80 4-1/2" 12.6# 13Cr80 4-1/2" Baker ECP Packer 4-1/2" Baker S-3 Perm Packer 4-1/2" Baker ZXP Packer 7" Baker ZXP Liner Top Packer @ 26 @ 3011 @ 10521 @ 10526 @ 10580 @ @ @ @ 3011 10521 10526 10580 10582 14371 10523 10585 9816 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Garry Catron Printed Name Garry Catron Signature J1~ C ~ Form 10-404 Revised 4/2004 13 Prior to well operation: Subsequent to operation: 14. Attachments: Copies of Logs and Surveys run_ Daily Report of Well Operations _ ! Oil-Bbl 413 ReDresentative Dailv AveraQe Production or Iniection Data Water-Bbl Casing Pressure 2048 1429 Tubing Pressure 254 904 Gas-Met 0.4 Well Shut-In 15. Well Class after proposed work: ExploratoryD 16. Well Status after proposed work: OilŒ] GasD DevelopmentŒ ServiceD WAG D GINJD WINJD WDSPLD Prepared by Garry Catron (907) 564-4657. SUndry Number or N/A if C.O. Exempt: N/A Title Production Technical Assistant Phone 564-4657 Date 10/11/04 ~ ~5 . . S-27B DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY 08/26/04 Perforate 12970'-12995' 6 SPF FLUIDS PUMPED BBLS 17 50/50 Methonal/Water 122 Diesel 139 TOTAL Page 1 1REE = 4" CIN WELLHEAD = F~ Acï'lJð. TOR~= oils KB. 8..EV = 56.04' BF. a.Ev = 28.36' KOP = ,u§973' rV'axÄ ngléU~9T @141"23' ~tum t,,{);;; ·~·10838; ~ .A__~~A~ _~A_A'_ I);¡tum 1V D = 8800' SS . 5-278 13-3/8"CSG, 68#, NT-80, 10= 12.415" H I / ~~ L - 2689' \4-1/2' TBG, 12.6#, 13-CR, H .0152 bpf, ID = 3.958" I 3009' IMinimum ID = 2.750" @ 10569' I 3-112" HES XN NIPPLE . SAFETY NOTES: 3" FLOWLINE IN SKID. PORTIONS OFTHS WELL'S FLOWUNEARE 3". ORIGINAL WELLBORE NOT SHOWN ON THIS DIAGRAM. ***CHROMETBG & LNR*** 2193' H4-1/2" I-ES X f\IIP, ID = 3.813" 3009' H3-1/2" X4-1/Z' XO, ID= 2.992" I ST MD 6 3062 5 4129 4 6452 3 8275 2 9688 1 10378 GAS LIFT MA.tÐR8..S DEV lYÆ VLV LATCH R>RT DATE 6 WMG-2 DMY RK 0 04/18/04 30 WMG-2 DOME RK 16 04/18/04 45 WMG-2 DOME RK 16 04/18/04 44 WMG-2 SO RK 20 04/18/04 43 WMG-2 DMY RK 0 04/18/04 52 WMG-2 DMY RK 0 04/18/04 TVO 3061 4061 5760 7056 B054 8526 g g -- 9816' H 9-5/8" X T' BKR ZXP LNR TOP A<R I 12-7/8" LNR, 6.16#, .0058 bpf, ID = 2.372" H 11220' 13-3/4" Ha...EH 11315' J----! 14-1/Z' TBG, 12.6#, 13-CR, .0152 bpf, ID= 3.958" H 10581' I Ir' LNR, 26#, L-80, 0383. bpf, ID = 6.276" H 10740' ÆRFORA TION SUWMARY REF LOG: SPERRY SLN IvWD ON 11/28/03 - 12/15/03 ANGLE AT TOP PERF: @ 11729' Note: Refer to Production DB for historical perf data SIZ E SPF INTERII AL Opn/Sqz [}!I.1E 2-1/2" 6 11729 - 11754 0 08/26104 2-1/2" 6 11970 - 12995 0 08/26104 SL TO 14439 - 16699 0 12/12/03 9-5/8" CSG, 47#, NT-BO-S , ID = 8.681" H 10635' ~ MILLOur WINOOW 9973' - 9989' ~ 10500' H3-1/2"HESXNIP, ID=2.813" I 10521' H4-1/2" X 3-1/2" XO, ID = 2.990" I 1 0523' ~"X 4-1/2" BKR S3 A<R, ID = 3.875" I 10527 H3-1/2"X 4-1/Z' XO, ID=2.900" 10548' H3-1/2" HES X NIP, ID = 2.813" I I 10569' H3-1/2"HESXNNlP, D=2.750" 10580' H4-1/Z' X 3-1/2" XO, 10 = 2.99Z' I 10582' H 4-1/2" WLEG I 10585' Hr' X4-1/2" BKRZXP I I LNR TOP PKR ... ... ... ... ... ... ... ~ ... ... , , 14_1/2" LNR, 26#, L-BO, 0383. bpf, ID = 6.276" H 14439' 4-1/2"SLTOLNR, 26#, L-80, ID=6.276" H 16699' ... ... /' [}!I.TE 11/11/90 11/20/95 12/21/03 01/14/04 04/18/04 08/26/04 REV BY COfvtv1ENTS ORIGINAL COMPLETION PAB SIDETRACK (S27A) JDM/KK RIG SIDETRACK (S-27B) DAV/KK GLV C/O JLJlKAK GL V C/O KCF/TLP ADD PERFS DA1E REV BY COMI'vENTS PRLOI-OE BA Y LNIT WELL: S-27B PERMrr No: 2031680 AR No: 50-029-22057-02 SEC 35, T12N, T12E, 1633' FI'I.. & 4048' FEL BP Exploration (Alaska) . ð03-ILoS' . WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Howard Okland 333 West 7th Avenue, Suite 100 Anchorage, Alaska January 27, 2004 RE: MWD Formation Evaluation Logs S-27B, AK-MW-2796082 1 LDWG formatted Disc with verification listing. API#: 50-029-22057-02 ::#) é) '-10 ( PLEASE ACKNOWLEDGE RECEIFf 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 Date: < Signed~)\.~v~·~;,v-, RECEIVED r"""; 1 " f),'\ i"I4 . . _.- ~-. . ~ ì I ··..u ~. cu0 J~Jðska OJ! 8; Gas Cons. Comrnfs.ian ffl,(¡r;hïJrage ~~\\\.~ _ STATE OF ALASKA . ALAS~ AND GAS CONSERVATION COM ION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1a. Well Status: 181 Oil 0 Gas 0 Plugged 0 Abandoned 0 Suspended 0 WAG 20AAC 25.105 20AAC 25.110 CASING, LINER AND CEMENTING ReCORD SEtTING ~Fr1'HMD SErnNG DePTH TvO BotrÔM lOP BOTToM' 110' Surface 110' 2689' Surface 2689' 9973' Surface 8265' 10740' 8143' 8743' 16699' 8644' 8994' o GINJ 0 WINJ 0 WDSPL No. of Completions 2. Operator Name: BP Exploration (Alaska) Inc. 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 4a. Location of Well (Governmental Section): Surface: 1633' SNL, 4048' WEL, SEC. 35, T12N, R12E, UM Top of Productive Horizon: 1725' SNL, 812' WEL, SEC. 03, T11 N, R12E, UM Total Depth: 3000' SNL, 4676' WEL, SEC. 03, T11 N, R12E, UM 4b. Location of Well (State Base Plane Coordinates): Surface: x- 619393' y- 5979855 Zone- ASP4 TPI: x- 617442 y- 5974455 Zone- ASP4 Total Depth: x- 613602 y- 5973120 ~ Zone- ASP4 18. Directional Survey 181 Yes 0 No 21. Logs Run: DIR, GR, RES, ABI 22. 20" 13-3/8" 68# NT80CYHE 9-5/8" 47# NT80 7" 26# L-80 4-1/2" 12.6# L-80 Surface Surface Surface 9809' 10574' 23. Perforations open to Production (MD + TVD of Top- and Bottom Interval, Size and Number; if none, state' none"): 4-1/2" Slotted Section MD TVD MD TVD 14439' - 16656' 9002' - 8998' 26. Date First Production: One Other 5. Date Comp., Susp., or Aband. 12/18/2003 6. Date Spudded 12/1/2003 7. Date T.D. Reached 12/14/2003 8. KB Elevation (ft): 65.3' 9. Plug Back Depth (MD+ TVD) 16700 + 8994 10. Total Depth (MD+TVD) 16700' + 8994' 11. Depth where SSSV set (Nipple) 2193' MD 19. Water depth, if offshore N/A MSL 17-1/2" 12-1/4" 8-1/2" 6-1/8" 24. 1 b. Well Class: 181 Development 0 Exploratory o Stratigraphic Test 0 Service 12. Permit to Drill Number 203-168 13. API Number 50- 029-22057-02-00 14. Well Name and Number: PBU 8-27B 15. Field / Pool(s): Prudhoe Bay Field / Prudhoe Bay Pool Ft Ft 16. Property Designation: ADL 028261 17. Land Use Permit: 20. Thickness of Permafrost 1900' (Approx.) -'-1¡.J~éJrl4.,) C¡C1'73 'nIL> RECORD 3296 cu ft Arcticset III & II 2393 cu ft Class 'G' 263 cu ft Class 'G' 696 cu ft Class 'G' SIZE DEPTH SET (MD) PACKER SET (MD) 4-1/2", 12.6#, 13Cr80 x 3-1/2",9.2#, 13Cr80 ~ 10582' 10523' F~C;TURE, .CEMEITSQÜ~gE;,~1"Ç. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED Freeze Protect with 151 Bbls Diesel PRODUCTION TEST Method of Operation (Flowing, Gas Lift, etc.): Date of Test Hours Tested PRODUCTION FOR TEST PERIOD ... Flow Tubing Casing Pressure CALCULATED ...... Press. 24-HoUR RATE""" 27. Brief description of lithology, porosity, fractures, apparent~~;: ~-;~resence of oil, gas or water a¡; ~~L\lt;Qnecessary). Submit core chips; ifnq"'~;..:.·~.'~."i,.¡i'f1Plne"'. .. ...... JAN 9, 6 2.004 i ',;.",^ .'ì\\nh fJ None ¡ 11..1'~:ö3 ' ~~.......,.....-'.-. ..ITIliE.·.... ,"L fEB \rÑ" . . '. . ,,_ .. r _·i;;:~,:;·.~;:j-·I t1\1~f!\J\'!1=' ~- Alaska Oil & Gas COI1S.!,;O¡fh¡,¡.)S¡on !_-'-~__ ¡ Anchorage Form 10-407 Revised 12/2<0:~~"~ CONTQERJ ~1J~6 L OIL-BBL OIL-BBL GAs-McF W A TER-BBL GAs-McF W A TER-BBL CHOKE SIZE I GAS-OIL RATIO OIL GRAVITY-API (CORR) 28. GEOLOGIC MARKER. 29. eRMATION TESTS Include and briefly summarize test results. List intervals tested, and attach detailed supporting data as necessary. If no tests were conducted, state "None". NAME MD rvD Sag River 10740' 8743' None Shublik 10805' 8781' Sadlerochit 10980' 8885' Sadlerochit 11595' 9005 RECE'\/E JAN 2 6 2004 Alaska Oil & Gas Cons. Anchorage 30. List of Attachments: Summary of Daily Drilling Reports, WelfSchematic Diagram, Surveys 31. I ~erebY certify that the fOreg"g i~ true and correct to the best of my knowledge. Signed Terrie Hubble ~ flÆ/l.(..( J ~ Title Technical Assistant Date 01- ';{l.,-DLf PBU S-27B 203-168 Prepared By Name/Number: Terrie Hubble, 564-4628 Well Number Drilling Engineer: Phil Smith, 564-4897 Permit No. / Approval 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-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. 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 iNerval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). ITEM 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, or Other (explain). ITEM 27: If no cores taken, indicate "None". ITEM 29: List all test information. If none, state "None". Form 10-407 Revised 12/2003 Legal Name: S-27 Common Name: S-27B Test Date -.---...-....---....-..--.....-...-.-...-----...... Test Type -.--.---..- -. 11/30/2003 FIT 12/4/2003 FIT .1'---- ! Test Depth (TMD) 9,973.0 (ft) 10,741.0 (ft) BP EXPLORATION Leak-Off Test Summary -... .......... .--......-.-- Test Depth (TVD) ._____ - _.. u" ........ 8,265.0 (ft) 8,743.0 (ft) AMW 11.10 (ppg) 8.40 (ppg) Surface Pressure . ............----- 630 (psi) 728 (psi) Leak Off Pressure (BHP) 5,396 (psi) 4,543 (psi) Page 1 of 1 EMW 12.57 (ppg) 10.00 (ppg) . . Printed: 12/22/2003 9:17:17 AM ..... . BP EXPLORATION Operations Summary Report *NOTE* Rig Accepted For Well Work On S-27B At 16:30 On 11-26-2003 Hold Pre-Spud And Environmental Meeting With All Personal Regarding S-27B Well Operations Install Secondary Annulus Valve - Rig Up Circulating Lines And Test Same To 3,500 Psi. (Test Good) Attempt To Circulate String Pressured Up - Pressure Up And Shift Open Hydraulic Valve Pump Safe-Kleen Sweep And Circulate Out Freeze Protection To Cuttings Tank At 5 BPM With 930 Psi. - Tubing And Annulus Pressure At 0 Psi. Blow Down Circulating Lines And Rig Down Hoses Dry Rod In TWC And Test From Below To 1,000 Psi. (Test Good) Bleed SSSV Control Lines - Nipple Down Production Tree, Tubing Head Adapter And Remove From Cellar Area - Inspect And Verify 4 1/2" TDS Lifting Threads On Tubing Hanger In Good Condition DECOMP Nipple Up BOP And Related Equipment DECOMP Rig Up BOP Testing Equipment DECOMP Fill BOP Equipment With Water - Test BOP And Related Equipment Witness Of BOP Test Waived By AOGCC Inspector John Crisp - Test Annular, Upper And Lower Pipe Rams, Blind Rams, Manual And HCR Valves On Choke And Kill Lines, Floor Safety Valve, Dart Valve, Top Drive Upper And Lower IBOP Valves At 250 Psi. Low And 3,500 Psi. High - Perform Accumulator Test Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: S-27 S-27B REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 2ES I Date i From - To Hours Task Code NPT Phase ___..._1---_._ . 11/24/2003 22:30 - 00:00 1.50 MOB P PRE 11/25/2003 00:00 - 03:30 3.50 MOB P PRE 03:30 - 14:00 10.50 MOB P PRE 14:00 - 21 :00 7.00 MOB N RREP PRE 21 :00 - 00:00 3.00 MOB P PRE 11/26/2003 00:00 - 08:00 8.00 MOB P PRE 08:00 - 12:00 4.00 MOB P PRE 12:00 - 16:30 4.50 RIGU P PRE 16:30 - 17:00 0.50 WHSUR P DECOMP 17:00 - 19:00 2.00 WHSUR P DECOMP 19:00 - 20:00 1.00 WHSUR P DECOMP 20:00 - 00:00 4.00 WHSUR P DECOMP 11/27/2003 00:00 - 00: 15 0.25 WHSUR P DECOMP 00: 15 - 00:45 0.50 WHSUR P DECOMP 00:45 - 03:30 2.75 WHSUR P DECOMP 03:30 - 08:00 08:00 - 08:30 08:30 - 15:00 4.50 BOPSURP 0.50 BOPSURP 6.50 BOPSUR P Page 1 of 15 Start: Rig Release: Rig Number: Spud Date: 7/12/1990 End: 12/18/2003 11/24/2003 12/18/2003 Description of Operations ..... - ....... ______. Rig Down Rig Floor And Can-Rig Top Drive - Load Up Truck Shop Blow Down And Disconnect Utilities Between Pit Complex And Sub Base - Move Cuttings Tank - Lower Cattle Shoot - Lay Mast Over And Pull Sub Base Off Of Well - Have Pre-Job Safety Meeting With Security, CPS, And Rig Team Move Sub Base From DS 13-30A To J-Pad Problems With Columbia Moving System Trouble Shoot And Change Out Hydraulic Drive Motor Move Sub Base From J-Pad To S-Pad Having Trouble Getting Over Rig Mats Move Sub Base From J-Pad To Kuparuk River - Use Cats Coming Out Of Base Of River And Continue To S-Pad Lay Herculite And Spot Sub Base Over Well S-27B And Level - Raise Mast And Cattle Shoot - Rig Up Rig Floor - Move Camp Unit And Pit Complex From DS 13-30A To S-Pad Lay Herculite And Position Pit Complex - Hook Up Utilities And Service Lines From Sub Base To Pit Complex - Spot Truck Shop And Welding Shop -Bridal Down And Pick Up Can-Rig Top Drive - Set Cutting Tank And Berm *NOTE* Two Failures During The BOP Test: Lower Pipe Ram Door Seal And Gland Packing Nut - The Door Seal And Packing Were Replaced And Tested Good DECOMP Rig Down BOP Testing Equipment - Pull TWC With DSM - 15:00 - 16:00 1.00 WHSUR P Printed: 12/22/2003 9:17:26 AM ...,. . BP EXPLORATION Operations Summary Report Start: Rig Release: Rig Number: Phase DECOMP Clear Rig Floor DECOMP Rig Up Power Tongs, Control Line Spooler, Casing Tools And Equipment DECOMP Pick Up Joint Of 4" Drill Pipe, And Cross Overs - Slack Off And Make Up Landing Joint To Tubing Hanger - Back Out Lock Down Studs - Clear Rig Floor And Pick Up On 41/2" Tubing String - Unseat Tubing Hanger From Profile - Maximum Up Weight Pulled 130,000 Ibs. - Normal Up Weight At 130,000 Ibs. - Work Tubing Hanger To Rig Floor Thru BOP Stack - Monitor Well Bore (Static) Set Slips And Terminate Control Lines Break Out And Lay Down Hanger - Install Full Opening Safety Valve - Break Out Cross Overs And Lay Down Landing Joint POH Laying Down 4 1/2" Completion String From Chemical Cut Joint At 10,290' To SSSV - Terminate Control Lines Break Out And Lay Down SSSV Rig Down Camco Control Line Spooling Unit And Clear Rig Floor POH Laying Down 41/2" Completion String From 8,150' To 4,223' POH Laying Down 41/2" Completion String From 4,223' 1 FMC Tubing Hanger And Pup 1 Flow Coupling & SSSV With Pup Joint Top And Bottom 2 Stainless Steel Bands 27 Rubber Clamps And Pins SHOULD HAVE BEEN 29 (2 CLAMPS AND PINS LEFT IN HOLE) 257 Joints Of 4 1/2" Tubing 4 GLM With Pup Joints Top And Bottom 1 Cut Off Joint 4 1/2" Tubing 30.10' Long DECOMP Rig Down Tubing Tongs And Equipment - Clear And Clean Rig Floor DECOMP Make Up 9 5/8" Pack Off Pulling Tool And Cross Overs To 4" Drill Pipe - Check 9 5/8" X 13 3/8" Casing - Pressure Gauge Showing 0 Psi. Back Out Gauge To Verify OA Static - Some Pressure On OA Install New Gauge Showing 50 Psi. - Rig Up Bleed Off Line To Cuttings Tank And Bleed Off Pressure - 23 Barrels Diesel And Dead Crude Flowed To Cuttings Tank - Monitor Back Side (Static) Slack Off And Engage Pack Off With Pulling Tool - Back Out Lock Down Studs And Pull Pack Off To Rig Floor - Install New Pack Off And Run In Lock Down Studs Torque To 450 ftllbs. Rig Up And Test Pack Off To 5,000 Psi. (Test Good) - Rig Down Testing Equipment - Pick Up Cellar Area Install Wear Bushing And Energize LDS Rig Up Floor Area - Load Pipe Shed And Bring BHA No.1 To Floor Pick Up BHA No.1 - Pick Up Dailey Drilling Jars Make Up Bumper Sub, Upper Mill, Lower Mill, And Starter Mill - RIH Make Up Float Sub, And Pick Up (9) Steel Drill Collars, (18) 5" Legal Well Name: S-27 Common Well Name: S-27B Event Name: REENTER+COMPLETE Contractor Name: NABORS ALASKA DRILLING I Rig Name: NABORS 2ES i Date I From - To Hours Task Code NPT I 11/27/2003 15:00-16:00 16:00 - 16:30 1.00 WHSUR P 0.50 PULL P 16:30 - 17:30 1.00 PULL P 17:30 - 18:30 1.00 PULL P DECOMP 18:30 - 20:45 2.25 PULL P DECOMP 20:45 - 21:15 0.50 PULL P DECOMP 21 :15 - 00:00 2.75 PULL P DECOMP 11/28/2003 00:00 - 03:30 3.50 PULL P DECOMP 03:30 - 04:30 1.00 PULL P 04:30 - 07:30 3.00 WHSUR P 07:30 - 10:00 2.50 WHSUR P DECOMP 10:00 - 11 :00 1.00 WHSUR P DECOMP 11:00 -11:30 0.50 WHSUR P DECaMP 11:30 -13:00 1.50 STWHIP P WEXIT 13:00 -15:30 2.50 STWHIP P WEXIT Page 2 of 15 11/24/2003 12/18/2003 Spud Date: 7/12/1990 End: 12/18/2003 Description of Operations ____ _n___n"____ "NOTE" Items Recovered During Decompletion: Printed: 12/22/2003 9:17:26AM . . Page 3 of 15 BP EXPLORATION Operations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: I Date 'From - To S-27 S-27B REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 2ES Hours Task I Code NPT I Start: Rig Release: Rig Number: Phase HWDP, And Cross Over To 886' RIH With BHA NO.1 Picking Up 5" Drill Pipe From 886' To 6,604' Change Out Handling Equipment For 4" Drill Pipe - Make Up Cross Over Sub And RIH With BHA No.1 Picking Up 4" Drill Pipe From 6,606' To 8,009' RIH With BHA NO.1 Picking Up 4" Drill Pipe From 8,009' Tag Tubing Stub At 10,285' (DPM) Held PJSM With Truck Drivers, Drilling Crews, And Service Personal Regarding Mud Displacement - Pumped 30 Barrel Hi-Vis Spacer Followed Up With 11.2 PPG LSND Mud At 12.6 BPM With 860 Psi. Monitor Well Bore (Static) - Pump Dry Job - Blow Down Surface Equipment POH With BHA NO.1 From 10,285' To 886' Handle BHA No.1 From 886' - Stand Back (18) Joints 5" HWDP, (9) Steel Drill Collars - Lay Down Daily Drilling Jars, Bumper Sub, Upper, Lower, And Starter Mill - Clear Rig Floor Hold Pre-Job Safety Meeting - Rig Up Schlumberger Wire Line Services - Make Up Logging Tools - Logging Run No.1 RIH With CCL-CPST And Haliburton EZSV Packer To 10,285' Tag Tubing Stub - Log Up And Set Top Of EZSV At 9,996' WLM - Log Up 100 Feet - RIH Tag EZSV Confirm Setting Depth- POH With Logging Tools - Rig Down Schlumberger And Clear Rig Floor WEXIT Held PJSM - Test 9 5/8" Casing At 3,500 Psi. Record On Circle Chart For 30 Minutes (Test Good) RREP WEXIT Work On Iron Ruffneck WEXIT Pick Up BHA No.2 - Pick Up 1 Joint 5" HWDP Make Up Upper Mill, Lower Mill, And Starter Mill - RIH Make Up Float Sub, MWD, And UBHO Sub - Install Pulser Orient And Surface Test - Pick Up Slide And Whipstock Trip Anchor Attach With 45,000 lb. Brass Lug Bolt - Pick Up Bumper Sub And RIH With (9) Steel Drill Collars, (18) 5" HWDP From Mast To 941' RIH With BHA No.2 Whipstock And Milling Assembly On 5" Drill Pipe From 941' To 6,660' Change Out Handling Equipment For 4" DP - Install Cross Over And RIH With BHA NO.2 From 6,660' To 9,929' Pick Up Single Of 4" Drill Pipe - Install Top Drive Blower Hose - Recorded Slow Pump Rates - String Weight Up 205,000#, String Weight Down 165,000# - Worked String To Orient Whipstock Slacked Off And Tripped Anchor With 32,000# - Tagged Bridge Plug With Bottom Of Whipstock At 9,997' Set At 6 Degrees Right Of High Side - Picked Up On String 10,000# Above Neutral Weight to Verify That Whipstock Set - Slacked Off 45,000# And Sheared Retaining Bolt. WEXIT Milled Window in 9-5/8" Casing From 9,973' To 9,989' - Cement At Shakers While Milling At 9,983' - Exited Window At 9,989' And Continued To Mill Formation From 9,989' To 10,005' - String Weight Up 205,000#, String Weight Down 165,000#, String Rotating Weight 185,000#, Pump Rate 488 GPM, 2,132 Psi. RPM 80 To 100, Torque 10,000 ft /Ibs- 13,000 ftllbs. .._._.... ". _"..__. __ . . ._. u.__ __u___n__ ..__..___~__ .. 11/28/2003 13:00 - 15:30 2.50 STWHIP P WEXIT 15:30 - 22:30 7.00 STWHIP P WEXIT 22:30 - 00:00 1.50 STWHIP P WEXIT 11/29/2003 00:00 - 01 :30 1.50 STWHIP P WEXIT 01 :30 - 03:30 2.00 STWHIP P WEXIT 03:30 - 04:00 0.50 STWHIP P WEXIT 04:00 - 07:00 3.00 STWHIP P WEXIT 07:00 - 08:00 1.00 STWHIP P WEXIT 08:00 - 13:30 5.50 STWHIP P WEXIT 13:30 - 14:30 1.00 EVAL P 14:30 - 15:00 15:00 - 18:30 0.50 STWHIP N 3.50 STWHIP P 18:30-22:15 3.75 STWHIP P WEXIT 22:15 - 00:00 1.75 STWHIP P WEXIT 11/30/2003 00:00 - 01 :00 1.00 STWHIP P WEXIT 01 :00 - 07:30 6.50 STWHIP P 11/24/2003 12/18/2003 Spud Date: 7/12/1990 End: 12/18/2003 Description of Operations _'___n_o.___. Printed: 12/22/2003 9: 17:26 AM . . Page 4 of 15 BP EXPLORATION Operations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: S-27 S-27B REENTER+COMPLETE Start: NABORS ALASKA DRILLING I Rig Release: NABORS 2ES Rig Number: From - To I Hours Task Code NPT! Phase ; Recovered 150 Ibs. Of Metal During Milling Operation WEXIT Rotate And Reciprocate While Working Mills Thru Whipstock Window - Pump MIDF Super Sweep At 12.5 BPM EWith 2,300 Psi. LNR1 Pulled BHA Into Casing To 9,959' - Closed Upper Pipe Rams and Preformed FIT To 12.5 PPG EMW Strokes Pmp'd Pressure 5 190 psi 10 320 psi 15 450 psi 20 570 psi 23 630 psi Date ----".---------.-.--.. ..--....-.-- _. 11/30/2003 01 :00 - 07:30 6.50 STWHIP P WEXIT 07:30 - 09:00 1.50 STWHIP P 09:00 - 09:30 0.50 EVAL P 09:30 - 10:30 1.00 DRILL P LNR1 10:30 - 11 :30 1.00 DRILL P LNR1 11 :30 - 12:00 0.50 DRILL P LNR1 12:00 - 14:15 2.25 DRILL P LNR1 14:15 - 16:00 1.75 DRILL P LNR1 16:00 - 17:00 1.00 BOPSURP LNR1 17:00 - 18:00 1.00 DRILL N RREP LNR1 18:00 - 20:30 2.50 DRILL P LNR1 20:30 - 00:00 3.50 DRILL P LNR1 12/1/2003 00:00 - 01 :00 1.00 DRILL P LNR1 01 :00 - 01 :45 0.75 DRILL P LNR1 01 :45 - 02:00 02:00 - 15:00 0.25 DRILL P 13.00 DRILL P LNR1 LNR1 11/24/2003 12/18/2003 Spud Date: 7/12/1990 End: 12/18/2003 Description of Operations ...-------------- -------- Held Test F/10 minutes w/50 psi Pressure Loss. MW 11.1 ppg, Window TVD 8,265' Pressure 630 psi = 12.57 PPG. EMW. Bled Pressure To 0 Psi. - Opened Pipe Rams Monitor Well Bore (Static) - Pump Dry Job - Blow Down Top Drive POH With BHA NO.2 From 9,959' To 6,726' Slip And Cut 102 Feet Of 1 1/4" Drilling Line Service Top Drive, And Traveling Blocks POH With BHA NO.2 From 6,726' To 916' Handle BHA No.2 From 916' - Stand Back (18) Joints 5" HWDP, (9) Steel Drill Collars - Lay Down Bumper Sub, UBHO Sub, MWD Tools, Float Sub, (1) Joint 5" HWDP, Upper, Lower, And Starter Mill - Clear Rig Floor - Inspect And Gauge Upper String Mill At 8.5" O.D. Remove Wear Bushing - Pick Up Johnny Wacker And Flush Out BOP Stack - Lay Down Flushing Tool - Install Wear Bushing And Energize Lock Down Studs Rig Repair - Trouble Shoot And Repair Lay Down Machine Camera Monitor Make Up BHA NO.3 - Pick Up Sperry Sun Motor, Make Up 8 1/2" Hughes HCM 605 PDC Bit - Pick Up MWD/LWD Tools, String Stabilizer, Float Sub - Orient And Initialize MWD/LWD Tools - Pick Up (3) Flex Drill Collars - Surface Test Sperry Sun Equipment - RIH With (9) Steel Drill Collars, (12) Joints 5" HWDP - Pick Up Daily Hydraulic Jars, (11) Joints 5" HWDP To 1,171' RIH With BHA NO.3 Directional Assembly On 5" Drill Pipe From 1,171' To 6,890' - Change Out Handling Equipment For 4" DP - Install Cross Over And RIH From 6,890' To 8,106' RIH With BHA NO.3 Directional Assembly On 4" Drill Pipe From 8,106' To 9,785' -Install Top Drive Blower Hose Orient Tool Face To 6 Degrees Right Of High Side, Shut Down Mud Pumps - Madd Pass Log For Tie In At 300' Per Hour From 9,785' To 9,993' - Slide Thru Whipstock Window 9,973' To 9,989' With No Problems Ream Out Under Gage Hole From 9,993' To 10,005' Drilled 8 1/2" Directional Hole By Rotating And Sliding From - 10,005' to 10,741' WOB Rotating 5,000# - 20,000#, WOB Printed: 12/22/2003 9:17:26 AM .... . ,0 BP EXPLORATION Operations Summary Report Page 5 of 15 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: S-27 S-27B REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 2ES Start: Rig Release: Rig Number: 11/24/2003 12/18/2003 Spud Date: 7/12/1990 End: 12/18/2003 Date From - To Hours Task Code NPT Phase Description of Operations _____.__n._ _.____._ .._u_ ... __...._. 12/1/2003 02:00 - 15:00 13.00 DRILL P LNR1 Sliding 5,000# To 15,000#, RPM 50 To 100, Motor RPM 178, Torque Off Bottom 14,000 ft /Ibs - On Bottom 17,000 ft /Ibs, Pump Rate 540 gpm, SPP Off Bottom 2,880 psi, On Bottom 3,140 psi. String Weight Up 225,000#, String Weight Down 160,000#, String Weight Rotating 194,000# - ART = 5.28 Hrs. - AST = 4.20 Hrs. 15:00 - 16:00 1.00 DRILL P LNR1 Circulate Sweep Around At 12.8 BPM With 2,880 Psi. While Rotating And Reciprocating Drill String 16:00 - 17:00 1.00 DRILL P LNR1 Monitor Well Bore (Static) - Wiper Trip With BHA NO.3 Thru 81/2" Hole Section From 10,741' To 9,880' With No Problems 17:00 - 18:00 1.00 DRILL P LNR1 Service Top Drive, And Traveling Blocks - Change Out Top Drive Saver Sub (Threads Galled) 18:00 - 18:45 0.75 DRILL P LNR1 RIH With BHA NO.3 From 9,880' To 10,648' With No Problems As Precaution Wash Last Stand To Bottom From 10,648' To 10,741' (No Fill) 18:45 - 20:30 1.75 DRILL P LNR1 Circulate Sweep Around At 12.8 BPM With 2,900 Psi. While Rotating And Reciprocating Drill String - Monitor Well Bore (Static) - Spot Liner Running Pill - Pump Dry Job - Drop Sperry Sun ESS Tool - Blow Down Top Drive - Work Drill String And Allow Time To Fall And Seat In Hang Off Collar 20:30 - 21 :00 0.50 DRILL P LNR1 POH From 10,741' To 9,880' With No Problems - Take Surveys At 10652', 10560', And 10465' During Trip To Window 21:00-21:15 0.25 DRILL P LNR1 Monitor Well Bore (Static) - Remove Blower Hose 21:15-00:00 2.75 DRILL P LNR1 POH With Directional BHA NO.3 From 9,880' To 6,890' - Change Out Handling Equipment For 5" Drill Pipe - POH From 6,890' To 3,602' 12/2/2003 00:00 - 01 :00 1.00 DRILL P LNR1 POH With Directional BHA NO.3 From 3,602' To 1,172' 01 :00 - 05:00 4.00 DRILL P LNR1 POH Laying Down Directional BHA NO.3 From 1,172' - Lay Down (23) Joints 5" HWDP, Daily Drilling Jars, (9) Steel Drill Collars, (3) Flex Drill Collars - Down Load Sperry Sun MWD/LWD Tools - Retrieve Sperry Sun ESS - Flush Out BHA With Fresh Water - Lay Down Hang Off Collars, MWD/LWD Tools, String Stabilizer, And Float Sub - Remove Smith 8 1/2" PDC Bit And Lay Down Mud Motor - Clear Rig Floor 05:00 - 06:00 1.00 BOPSURP LNR1 Change Out 31/2" By 6" Variables Pipe Rams In Top BOP Gate To 7" Rams 06:00 - 07:00 1.00 BOPSURP LNR1 Pull Wear Bushing And Install Test Plug - Rig Up Testing Equipment - Test 7" Rams To 250 Psi. Low And 3,500 Psi. High (Good Test) - Rig Down Testing Equipment And Pull Test Plug - Install Wear Bushing And Energize Lock Down Studs 07:00 - 08:00 1.00 CASE P LNR1 Rig Up Power Tongs - Casing Tools And Equipment 08:00 - 09:30 1.50 CASE P LNR1 Pick Up And RIH With Shoe Track - Baker Lock Connections To Insert Landing Collar Joint NO.3 - Verify Floats Holding - RIH With 22 Joints Of 7" BTC-M 26 lb. L-80 Casing To 908' - Make Up To Mark Torqued To 9,500 ftllbs. 09:30 - 10:00 0.50 CASE P LNR1 Change Out Handling Equipment To 5" DP Elevators - M / U Baker HMC Liner Hanger, ZXP Packer, Liner Tie Back Sleeve, And Running Tool - RIH w/1 Stand 5" Drill Pipe From Mast 10:00 - 10:30 0.50 CASE P LNR1 Circulate 7" Liner Volume At 220 GPM With 170 Psi. - Liner Weight At 24,000# 10:30 - 16:30 6.00 CASE P LNR1 RIH With 22 Joints Of 7" BTC-M 26 lb. L-80 Liner On 5" And 4" Drill Pipe From 1,037' To 9,973' - Pick Up Pup Joint And Single Of 4" Drill Pipe - Fill Drill Pipe Every 10 Stands Printed: 12/22/2003 9:17:26AM . . Page 6 of 15 BP EXPLORATION Operations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: S-27 S-27B REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 2ES i i Date From - To i Hours Task Code NPT I Phase 12/2/2003 16:30 - 17:30 1.00 CASE P LNR1 17:30 -18:30 1.00 CASE P LNR1 18:30 - 20:00 1.50 CASE P LNR1 20:00 - 23:00 3.00 CEMT P LNR1 Start: Rig Release: Rig Number: Spud Date: 7/12/1990 End: 12/18/2003 11/24/2003 12/18/2003 Description of Operations _._________u ._______ ____ Circulate Drill Pipe And 7" Liner Volume At 252 GPM With 1,000 Psi. - Blow Down Top Drive RIH With 7" BTC-M 26 lb. L-80 Liner On 4" Drill Pipe From 9,973' To 10,444' - 7" Liner Taking Weight Work Liner From 10,444' To 10,723' - Pick Up Baker Cement Head - Install Manifold And Circulating Lines - Establish Circulation At 1 BPM With 440 Psi And Full Returns - Wash To Bottom At 10,741' Stage Up Pumping Rates From 1 BPM With 440 Psi. To 4.0 BPM With 800 Psi. - Condition Mud With No Pipe Movement And Full Returns - Very Soon After Reaching 4.0 BPM Well Bore Packed Off, Bleed Off Pressure And Work Pipe, Regain Circulation With 7" Casing Shoe At 10,740' Stage Pump Rates Up To 3.0 BPM With No Problems, Increase Rate To 3.5 BPM With Well Bore Starting To Pack Off Again, Reduce Pumping Rate To 3.0 BPM And 680 Psi. Held PJSM With All Personal Regarding Cementing Operation - Shut Down And Turn Over To Dowell - Pump 5 BBLS Water- Test Surface Lines And Equipment To 4,500 Psi. (Test Good) - Clear Lines With Mud Push Prior To Going Down Hole - Pump 25 BBLS 12.2 PPG Mud Push, Followed With 46.8 BBLS (226 Sacks) 15.8 PPG Class "G" Tail Cement At 3.0 BPM - Wash Up Lines To Floor - Drop Dart And Start Displacement With 11.2 PPG LSND Mud At 6.1 BPM And 188 Psi. - Catch Cement With 16.9 BBLS Pumped Away And Slow Rate To 3.0 BPM - Attempting To Pack Off With 20 BBLS Pumped Slow Rate To 2.0 BPM With 2,065 Psi. - At 30 BBLS Pumped Pressure Decreased To 142 Psi. Increase Rate To 3.0 BPM With 375 Psi. And Full Returns And Continue To 132.6 BBLS Away When 12.2 PPG Mud Push At Liner Hanger Well Started To Pack Off Again Reduce Rate To 2.0 BPM With 2,577 Psi. And Partial Returns - Latch Liner Wiper Plug With 141.5 BBLS Pumped Away - Continue Displacement At 2.0 BPM And 2,950 Psi. With Partial Returns - At 171 BBLS Pumped Reduce Rate To 1 BPM And 2,806 Psi For Final Circulating Pressure - Bump Plug With A Total Of 174.3 BBLS Pumped Increase Pressure To 4,000 Psi. To Set Baker Liner Hanger - Bleed Off Pressure And Check Floats (Floats Held) - Cement In Place At 21 :48 Hours - Rotate 15 Turns To The Right And Release From Liner - Pressure Up Down Drill Pipe To 1,000 Psi. - Pick Up To Release Pack Off From Seals And Expose Running Tool Dogs As Pressure Decreases Ramp Up Pumps To Maximum Rate At 12.7 BPM With 3,264 Psi. And Circulate 35 BBLS - Reduce Pump Rate To 6.0 BPM With 1,379 Psi. Slack Off String With 70,000 Ibs. To Set Baker ZXP Packer Rotate And Repeat Process Several Times (Clear Surface Indication That Packer Set) - Increase Pump Rate At 12.8 BPM With 3,285 Psi. And Continue To Circulate - Trace Of Cement Estimated At 3 BBLS. To Surface Strung Out With Increase In PH - Top Of Liner At 9,808', Insert Landing Collar At 10,656', Float Collar At 10,695', Float Shoe At 10,738' *NOTE* Had Wash Out In Flow Tee On Cement Line, When Bottoms Up Reached Surface (Good Timing) Printed: 12/22/2003 9:17:26 AM .~ .. Page 7 of 15 BP EXPLORATION Operations Summary Report Break Down Cement Circulating Lines And Lay Down Baker Cementing Head - Pump Dry Job Blow Down Top Drive POH With 4" x 5" Drill Pipe And Baker 7" Liner Running Tool From 9,808' To 9,100' POH With 4" x 5" Drill Pipe And Baker 7" Liner Running Tool From 9,100' To 5,730' Lay Down 5" Drill Pipe From 5,730' To 2,420' Lost Power To Rig Floor - Trouble Shoot Problem - Change Out Circuit Breaker POH With Baker 7" Liner Running Tool From 5,730' - Inspect Running Tool Brass Pins Were Sheared Indicating That The ZXP Packer Did Set - Lay Down Running Tool And Clear Rig Floor Pull Wear Bushing And Install Test Plug - Rig Up Testing Equipment Change Out 7" Pipe Rams In Top BOP Gate To 3 1/2" By 6" Variables Test BOP And Related Equipment - Witness Of BOP Test Waived By AOGCC Inspector Jeff Jones - Test Annular, Upper And Lower Pipe Rams, Blind Rams, Manual And HeR Valves On Choke And Kill Lines, Choke Manifold, Floor Safety Valve, Dart Valve, Top Drive Upper And Lower IBOP Valves At 250 Psi. Low And 3,500 Psi. High - Perform Accumulator Test PROD1 Pull Test Plug - Install Wear Bushing And Energize LDS - Blow Down Choke Manifold And Kill Lines - Clear Rig Floor PROD1 Make Up BHA No.4 - Pick Up Sperry Sun Motor, Make Up 6 1/8" Hughes STX 09 Insert Bit, Pick Up MWD/LWD Tools- Orient And Initialize MWD/LWD Tools - Pick Up (1) Flex Drill Collar - Surface Test Sperry Sun Equipment - Pick Up (2) Flex Drill Collars, Daily DNT Jars, Circulating Sub, (5) 3 1/2" HWDP, And Cross Over Sub To 373' RIH With BHA No.4 Picking Up 4" Drill Pipe From 373' To 4,002' Slip And Cut 73 Feet Of 1 1/4" Drilling Line Service Top Drive, And Traveling Blocks - Adjust Draworks Mechanical Brakes Test 9 5/8" Casing, 7" Liner Top Packer, And 7" Casing At 3,500 Psi. Record On Circle Chart For 30 Minutes (Test Good) RIH With BHA No.4 Picking Up 4" Drill Pipe From 4,002' To 6,068' RIH With BHA No.4 Picking Up 4" Drill Pipe From 6,068' To 9,522' RIH With 4" Drill Pipe From Mast To 10,656' - Install Top Drive Blower Hose Tag Baker Liner Wiper Plug And Insert Landing Collar At 10,656' - Drill Landing Collar And Wiper Plugs - Cement To Float Collar At 10,695' - Cement To 10,737' - WOB 15,000# To 20,000#, Motor RPM 30, Torque On Bottom 9,000 ft /Ibs- Pump Rate 220 gpm, SPP Off Bottom 1,900 psi, On Bottom 2,050 psi. String Weight Up 225,000#, String Weight Down 125,000#, String Weight Rotating 175,000# PROD1 Displace Well To Flo-Pro Mud System - Pump 150 Barrels Fresh Water, 30 Barrels EP Mud Lube Pill, 50 Barrels Hi-Vis Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date S-27 S-27B REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 2ES 12/2/2003 From - To Hours Task ¡code NPT Phase 23:00 - 23:30 0.50 CEMT P LNR1 23:30 - 00:00 0.50 CEMT P LNR1 00:00 - 01 :30 1.50 CASE P LNR1 01 :30 - 04:00 2.50 CASE P LNR1 04:00 - 05:00 1.00 CASE N RREP LNR1 05:00 - 06:30 1.50 CASE P LNR1 12/3/2003 06:30 - 07:30 1.00 BOPSURP PROD1 07:30 - 08:30 1.00 BOPSURP PROD1 08:30 - 11 :30 3.00 BOPSUR P PROD1 11:30-12:00 0.50 BOPSURP 12:00 - 15:00 3.00 DRILL P 15:00 - 19:00 4.00 DRILL P PROD1 19:00 - 20:00 1.00 DRILL P PROD1 20:00 - 21 :00 1.00 DRILL P PROD1 21 :00 - 22:00 1.00 EVAL P PROD1 22:00 - 00:00 2.00 DRILL P PROD1 12/4/2003 00:00 - 02:00 2.00 DRILL P PROD1 02:00 - 03:00 1.00 DRILL P PROD1 03:00 - 05:00 2.00 DRILL P PROD1 05:00 - 08:00 3.00 DRILL P Start: Rig Release: Rig Number: Spud Date: 7/12/1990 End: 12/18/2003 11/24/2003 12/18/2003 Description of Operations Printed: 12/22/2003 9: 17:26 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date 12/4/2003 12/5/2003 12/6/2003 . . BP EXPLORATION Operations Summary Report Page 8 of 15 S-27 S-27B REENTER+COMPLETE Start: NABORS ALASKA DRILLING I Rig Release: NABORS 2ES Rig Number: From - To I Hours Task Code NPT' Phase 05:00 - 08:00 08:00 - 08:30 08:30 - 09:00 09:00 - 09:30 09:30 - 21 :30 21 :30 - 00:00 00:00 - 00:30 00:30 - 07:00 07:00 - 07:30 07:30 - 00:00 00:00 - 00:30 11/24/2003 12/18/2003 Spud Date: 7/12/1990 End: 12/18/2003 Description of Operations --..------.. -... 3.00 DRILL P 0.50 DRILL P PROD1 Spacer, Followed With 700 Barrels 8.4 ppg Flo-Pro Mud PROD1 Drill Cement From 10,737' And Float Shoe At 10,741- Drill New 61/8" Formation From 10,741' To 10,761' PROD1 Held Pre-Job Safety Meeting - Pulled BHA Into Casing Closed Upper Pipe Rams and Preformed FIT To 10.0 PPG EMW Strokes Pmp'd Pressure 4 110 psi 9 220 psi 13 340 psi 17 430 psi 21 540 psi 25 620 psi 29 710 psi 30 730 psi 0.50 DRILL P 0.50 DRILL P 12.00 DRILL P Held Test F/1 0 minutes w/45 psi Pressure Loss. MW 8.4 ppg, Csg Shoe TVD 8,743' Pressure 728 psi = 10.00 PPG. EMW. Bled Pressure To 0 Psi. - Opened Pipe Rams PROD1 Record Base Line Readings For Sperry Sun PWD Tool PROD1 Drilled 6 1/8" Directional Hole By Rotating And Sliding From 10,761' To 11,135' (8,900' TVD) WOB Rotating 20,000#- 25,000#, WOB Sliding 25,000#, RPM 80, Motor RPM 80, Torque Off Bottom 5,000 ft /Ibs - On Bottom 6,000 ft /Ibs, Pump Rate 269 gpm, SPP Off Bottom 1,900 psi, On Bottom 2,020 psi. String Weight Up 182,000#, String Weight Down 153,000#, String Weight Rotating 170,000# - ART = 6.51 hrs. - AST = 4.46 hrs. PROD1 Lost Returns Static Losses At 250 Barrels Per Hour - POH To 7" Casing Shoe At 10,740' - Pump 50 Barrel LCM Pill At 40 PPB Into Annulus While Waiting On Second Load Of Mud To Arrive On Location - Let Fluid Level Fallin Annulus While Pumping 30 BPH Into Annulus PROD1 RIH From 10,740' To 11,135' With No Problems PROD1 Drilled 6 1/8" Directional Hole With No Returns By Rotating And Sliding From 11,135' To 11,155' - Drill Ahead With Partial Returns While Adding LCM From 11,155' To 11,268' Losses Slowed To 50 BPH - WOB Rotating 20,000# - 25,000#, WOB Sliding 25,000#, RPM 80, Motor RPM 80, Torque Off Bottom 5,000 ft /Ibs - On Bottom 6,000 ft /Ibs, Pump Rate 269 gpm, SPP Off Bottom 1,900 psi, On Bottom 2,020 psi. String Weight Up 182,000#, String Weight Down 153,000#, String Weight Rotating 170,000# - ART = .83 hrs. - AST = 3.21 hrs. PROD1 Lost Circulation - Pick Off Bottom And Establish Static Loss Rate At 205 Barrels Per Hour PROD1 Drilled 61/8" Directional Hole With With Partial Returns By Rotating And Sliding From 11,268' To 11,558' - Losses Slowed To 67 BPH - WOB Rotating 20,000# - 25,000#, WOB Sliding 25,000#, RPM 85, Motor RPM 80, Torque Off Bottom 5,000 ft / Ibs - On Bottom 7,000 ft /Ibs, Pump Rate 269 gpm, SPP Off Bottom 1,800 psi, On Bottom 1,920 psi. String Weight Up 180,000#, String Weight Down 150,000#, String Weight Rotating 172,000# - ART = 8.98 hrs. - AST = 3.80 hrs. PROD1 Drilled 6 1/8" Directional Hole With With Partial Returns By 2.50 DRILL P 0.50 DRILL P 6.50 DRILL P 0.50 DRILL P 16.50 DRILL P 0.50 DRILL P Printed: 12/22/2003 9:17:26 AM '\ . .... BP EXPLORATION Operations Summary Report Page 9 of 15 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: S-27 S-27B REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 2ES Start: Rig Release: Rig Number: 11/24/2003 12/18/2003 Spud Date: 7/12/1990 End: 12/18/2003 Date From - To Hours Task Code NPT Phase Description of Operations -----.--- -.. -------- 12/6/2003 00:00 - 00:30 0.50 DRILL P PROD1 Sliding From 11,558' To 11,561' 00:30 - 01 :00 0.50 DRILL P PROD1 Circulate (3) Open Hole Volumes While Rotating And Reciprocating Drill String - Monitor Well Bore (Static) 01 :00 - 01 :30 0.50 DRILL P PROD1 POH With Directional BHA No.4 From 11,561' Work Thru Area At 11,135' (Loss Circulation Zone) POH To 10,740' 01 :30 - 02:15 0.75 DRILL P PROD1 Drop Dart And Open Circulation Sub - Circulate Bottoms Up At 12.7 BPM With 1,280 Psi. - Remove Blower Hose 02:15 - 02:45 0.50 DRILL P PROD1 Monitor Well - Static Loss Rate At 84 bbls/hr - Spot LCM Pill 52 Barrel LCM Pill At 70 PPB Consisted Of The Following Additives: 10 PPB MI Nut Plug Medium 10 PPB MI Seal Fine 10 PPB MI Mix II Medium 10 PPB MI Mica Medium 30 PPB Mix II Fine 02:45 - 03:00 0.25 DRILL P PROD1 POH Above LCM Pill From 10,740' To 9,996' 03:00 - 03:30 0.50 DRILL P PROD1 Pump Dry Job And Blow Down Surface Equipment 03:30 - 07:00 3.50 DRILL P PROD1 POH With Directional BHA NO.4 From 9,996' to 6,798' Monitor Well Bore Static Losses Slowed To 12 BPH - POH From 6,798' To 373' 07:00 - 09:00 2.00 DRILL P PROD1 Handle BHA No.4 - Stand Back (5) 3 1/2" HWDP, Dailey DNT Jars, Circulating Sub, And (3) Flex Drill Collars - Flush Out BHA With Fresh Water And Blow Down Surface Equipment - Down Load Sperry Sun MWD/LWD Tools - Lay Down Hang Off Collars, MWD/LWD Tools, And Float Sub - Remove Hughes 6 1/8" STX 09 Insert Bit And Lay Down Mud Motor - Clear Rig Floor 09:00 - 11 :30 2.50 DRILL P PROD1 Make Up BHA NO.5 And RIH To 375' - Pick Up 5" Sperry Sun Motor, Make Up 61/8" Security FM 2643 PDC Bit, Pick Up Float Sub, And MWD / LWD Tools - Orient And Initialize MWD/LWD Tools - RIH Out Of Mast With (3) Flex Drill Collars, Dailey DNT Jars, Circulating Sub, (5) 31/2" HWDP, And Cross Over Sub - Surface Test Sperry Sun Equipment (Test Good) 11 :30 - 14:30 3.00 DRILL P PROD1 RIH With Directional Drilling Assembly BHA NO.5 Picking Up 4" Drill Pipe From 375' To 3,591' 14:30 - 17:30 3.00 DRILL P PROD1 RIH With Directional BHA NO.5 From 3,591' To 11,525' With No Problems - As Precaution Wash To Bottom From 11,525' To 11,561' 17:30 - 00:00 6.50 DRILL P PROD1 Drilled 6 1/8" Directional Hole By Rotating And Sliding From 11,561' To 12,045' WOB Rotating 5,000# - 10,000#, WOB Sliding 5,000# To 8,000#, RPM 80, Motor RPM 227, Torque Off Bottom 7,000 ft /Ibs - On Bottom 8,000 ft /Ibs, Pump Rate 294 gpm, SPP Off Bottom 1,850 psi, On Bottom 2,300 psi. String Weight Up 180,000#, String Weight Down 145,000#, String Weight Rotating 170,000# - ART = 4.55 hrs. - AST = .20 hrs. 12/7/2003 00:00 - 18:00 18.00 DRILL P PROD1 Drilled 6 1/8" Directional Hole By Rotating And Sliding From 12,045' To 13,555' (9,051 TVD) WOB Rotating 5,000#- 10,000#, WOB Sliding 5,000# To 8,000#, RPM 100, Motor RPM 238, Torque Off Bottom 9,000 ft /Ibs - On Bottom 11,000 ft /Ibs, Pump Rate 308 gpm, SPP Off Bottom 1,950 psi, On Printed: 12/22/2003 9:17:26AM ..... . Page 10 of 15 BP EXPLORATION Operations Summary Report Start: Rig Release: Rig Number: NPT : Phase I I PROD1 Bottom 2,550 psi. String Weight Up 195,000#, String Weight Down 135,000#, String Weight Rotating 172,000# - ART = 9.60 hrs. - AST = 2.94 hrs. DPRB PROD1 With 61/8" Bit On Bottom At 13,555' Work Tight Pipe - Pick Up On Drill String Dailey Jars Hit Twice At 275,000 Ibs. Work To Cock Jars - Torque And Slump String With 11,000 ftllbs. - Circulate Lube Sweep Around BHA At Slow Rate - Jar Up On String With 325,000 Ibs. Repeat Process 10 +/- Times Getting Good Jar Action - Lock In 14,000 ftllbs Torque With Top Drive Brake, Pick Up 100,000 Ibs. Above Normal Upward Drag And Hold - Slack Off On String To Netural Weight And Release Torque "String Free" - Pick Up Above Tight Spot - Keep Drill String Moving And Prepare To POH POH With Directional BHA NO.5 From 13,555' To 10,740' With No Problems - Slight Increase In Drag 15K At 12,461' And 11,135' Drop Dart And Open Circulation Sub - Circulate Bottoms Up At 12.5 BPM With 1,210 Psi. - Remove Blower Hose Monitor Well - Static Loss Rate At 184 bbls/hr - Spot LCM Pill Monitor Well Bore Static Losses At 30 Barrels Per Hour - 109 Barrel Total Losses From Midnight To 05:30 Minus Steel Calculated Displacement PROD1 Make Up BHA NO.6 And RIH To 374' - Pick Up 5" Sperry Sun Motor, Make Up 6 1/8" HTC HCM 406 PDC Bit, Pick Up (2) Float Subs, And MWD / LWD Tools - Orient And Initialize MWD/LWD Tools - RIH Out Of Mast With (3) Flex Drill Collars, Dailey DNT Jars, Circulating Sub, (5) 3 1/2" HWDP, And Cross Over Sub - Surface Test Sperry Sun Equipment (Test Good) -Blow Down Surface Equipment PROD1 RIH With Directional BHA NO.6 Picking Up Singles Of 4" Drill Pipe From 374' To 1,140' PROD1 RIH With Directional BHA NO.6 From 1,140' To 2,187' Legal Well Name: S-27 Common Well Name: S-27B Event Name: REENTER+COMPLETE Contractor Name: NABORS ALASKA DRILLING I Rig Name: NABORS 2ES í : Date . From - To Hours! Task Code .--...--.--.....--,. ._._.~_.__. --"- w..__....i..... ..----.. 12/7/2003 00:00 - 18:00 18.00 DRILL P 18:00 - 19:30 1.50 DRILL N 19:30 - 21 :00 1.50 DRILL P PROD1 21 :00 - 22:00 1.00 DRILL P PROD1 22:00 - 22:45 0.75 DRILL P PROD1 22:45 - 23:00 0.25 DRILL P PROD1 23:00 - 00:00 1.00 DRILL P PROD1 12/8/2003 00:00 - 02:15 2.25 DRILL P PROD1 02:15 - 03:00 0.75 DRILL P PROD1 03:00 - 05:30 2.50 DRILL P PROD1 05:30 - 08:00 2.50 DRILL P 08:00 - 08:45 0.75 DRILL P 08:45 - 09:00 0.25 DRILL P 11/24/2003 12/18/2003 Spud Date: 7/12/1990 End: 12/18/2003 Description of Operations ". ----.-.".--. 120 Barrel LCM Pill At 75 PPB Consisted Of The Following Additives: 25 PPB MI Nut Plug Medium 25 PPB MI Seal Fine 25 PPB MI Mix II Medium Pump Dry Job And Blow Down Surface Equipment POH With Directional BHA NO.5 From 10,740' To 7,982' - At 7,982' With LCM Pumped Monitor Well Bore Static Losses Slowed From 184 BPH To 24 BPH POH With Directional BHA NO.5 From 7,982' To 1,141' With Mast Full Lay Down 4" Drill Pipe From 1,141' To 375' Handle BHA NO.5 From 375' - Stand Back (5) 31/2" HWDP, Change Out Dailey DNT Jars, Rebuild Circulating Sub, Stand Back (3) Flex Drill Collars - Flush Out BHA With Fresh Water And Blow Down Surface Equipment - Down Load Sperry Sun MWD/LWD Tools - Lay Down Hang Off Collars, MWD/LWD Tools, And Float Sub - Remove Security FM 2643 PDC Bit And Lay Down Mud Motor - Clear Rig Floor Printed: 12/22/2003 9:17:26 AM --- . "~I Page 11 of 15 BP EXPLORATION Operations Summary Report Pick Up Cross Over Subs, (13) 31/2" HWDP, Dailey Hydraulic Jars, (5) 3 1/2" HWDP, Dailey Accelerators, And Cross Over Sub From 2,187' To 2,807' RIH With Directional BHA NO.6 From 2,807' To 10,651' - Fill Drill String Every 3,000 Feet Slip And Cut 100 Feet Of 1 1/4" Drilling Line Service Top Drive And Traveling Blocks RIH With Directional BHA No.6 Thru Open Hole Section From 10,651' To 13,451' - With No Problems Due To LCM Pill As Precaution Wash To Bottom From 13,451' To 13,555' Drill 6 1/8" Directional Hole By Rotating And Sliding With Tool Face At 90 To 124 Degrees Right Of High Side From 13,555' To 13,667' (9,049 TVD) - Attempting To Turn Right To Stay In Poloygon And Down Or Hold Flat At 9,055' TVD To 9,065' TVD - Very Very Difficult Sliding, Stacking Weight With Little Differential Pressure Transfered To Motor - Add Lubricants To Flo-Pro Mud System At 5% To 6% And Pump Bead Sweeps - Average ROP At 12 To 14 FPH - Average Losses To Well Bore At 100 To 125 BPH - WOB Rotating 5,000# - 8,000#, WOB Sliding 5,000# To 25,000#, RPM 100, Motor RPM 230, Torque Off Bottom 8,000 ft /Ibs - On Bottom 10,000 ft /Ibs, Pump Rate 299 gpm, SPP Off Bottom 1,900 psi, On Bottom 2,350 psi. String Weight Up 205,000#, String Weight Down 135,000#, String Weight Rotating 170,000# - ART = .10 hrs. - AST = 2.65 hrs. PROD1 Drill 6 1/8" Directional Hole By Sliding From 13,667' To 13,882' - Attempting To Turn Right To Stay In Poloygon And Down Or Hold Flat At 9,055' TVD To 9,065' TVD. AST 7.74 hrs, ART 0 hrs. P/U - 190K, S/O - 145K, RT - 170K, TQ - 8K, Loses at 120 BPH POH from 13,882' to 10,651' without problems. P/U - 200K Open up the circ sub and circulate @ 12.5 bpm, 1,450 psi. Spot 140 bbls, 100# LCM Pill. POH from 10,651' to 2,807'. Changeout the handling equipment. Static Loss Rate 0 bph. UD BHA from 2,807' to 2,187'. C/O elevators. POH w/ DP from 2,187' to 1,140'. Mast is full of pipe. UD DP in singles from 1,140' to 374'. C/O elevators. UD BHA from 374' to 91'. PJSM with all personnel. Flush MWD tools with 30 bbls of fresh water. Blow Down surface equipment. Download MWD tools. UD BHA from 91'. Clear the floor. Static Loss Rate 15 bph. Pull wear ring. M/U test joint. Set wear ring. Test BOPE and all related equipment to 250 psi low and 3500 psi high. BOP test witness waived by Chuck Shieve. Pull Test Plug. RID Test Joint. Set Wear Ring. Blow Down Surface equipment. Loss Rate - 7 bph PJSM. M/U BHA to 91'. Upload MWD Tools M/U BHA from 91' to 220'. Shallow test the MWD tools. 250 gpm @ 1150 psi. Test okay. Blow down surface equipment. RIH from 220' to 10,045'. Fill pipe every 3,000'. Loss Rate - 5 bph. Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: S-27 S-27B REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 2ES , Date From - To : Hours Task Code NPT Phase - u_____.__ _ 12/8/2003 09:00 - 09:30 0.50 DRILL P PROD1 09:30 - 13:00 3.50 DRILL P PROD1 13:00 - 14:00 1.00 DRILL P PROD1 14:00 - 14:30 0.50 DRILL P PROD1 14:30 - 15:30 1.00 DRILL P PROD1 15:30 - 16:00 0.50 DRILL P PROD1 16:00 - 00:00 8.00 DRILL P PROD1 12/9/2003 00:00 - 17:30 17.50 DRILL P 17:30 - 19:00 1.50 DRILL P PROD1 19:00 - 21:00 2.00 DRILL P PROD1 21 :00 - 00:00 3.00 DRILL P PROD1 12/10/2003 00:00 - 02:00 2.00 DRILL P PROD1 02:00 - 03:00 1.00 DRILL P PROD1 03:00 - 03:30 0.50 DRILL P PROD1 03:30 - 04:00 0.50 BOPSURP PROD1 04:00 - 06:00 2.00 BOPSURP PROD1 06:00 - 06:30 0.50 BOPSUR P PROD1 06:30 - 08:00 1.50 DRILL P PROD1 08:00 - 08:30 0.50 DRILL P PROD1 08:30 - 12:00 3.50 DRILL P PROD1 Start: Rig Release: Rig Number: Spud Date: 7/12/1990 End: 12/18/2003 11/24/2003 12/18/2003 Description of Operations Printed: 12/22/2003 9: 17:26 AM L'" ... . BP EXPLORATION Operations Summary Report Page 12 of 15 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: S-27 S-27B REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 2ES Start: Rig Release: Rig Number: 11/24/2003 12/18/2003 Spud Date: 7/12/1990 End: 12/18/2003 Date From - To Hours Task Code NPT Phase Description of Operations --..----....--... 12/10/2003 12:00 - 12:30 0.50 DRILL P PROD1 RIH from 10,045' to 10,740'. Loss Rate - 4 bph. 12:30 - 13:30 1.00 DRILL P PROD1 Service Top Drive. Loss Rate - 2 bph. 13:30 - 16:00 2.50 DRILL P PROD1 Pump EP Mud Lube Pill around. Loss Rate - 30 bph. Prior to puming sweep: P/U - 180K, S/O - 150K, RT - 170K, TQ - 5-6K After sweep: P/U - 175K, S/O - 155K, RT - 168K, TQ - 4-5K 16:00 - 17:30 1.50 DRILL P PROD1 UD BHA from 2,801' to 2,181'. C/O elevators. POH w/ DP from 2,181' to 1,140'. Mast is full of pipe. UD DP in singles from 1,140' to 374'. C/O elevators. UD BHA from 374' to 91'. 17:30 -18:00 0.50 DRILL P PROD1 PJSM with all personnel. Flush MWD tools with 30 bbls of fresh water. Blow Down surface equipment. Download MWD tools. 18:00 - 00:00 6.00 DRILL P PROD1 UD BHA from 91'. Clear the floor. Static Loss Rate 15 bph. 12/11/2003 00:00 - 12:00 12.00 DRILL P PROD1 Directional Drill from 14,170' to 14,655'. Seeing some magnetic interference in the azmuthal surveys. Discuss with town. Decision made to use IIFRlCaz corrections. P/U - 190K, S/O - 135K, RT - 165K, TQ - 7-8K off. TQ - 9-10K on. AST- 4.59 hrs, ART - 3.92 hrs. Loss Rate Avg. 0000-0640 = 85 bph. Loss Rate Avg. 0640 - 1200 = 150 bph. Increase in the loss rate occured @ 14350' MD. Pumping Lubricant and Glass Bead sweeps as needed for sliding. 12:00 - 00:00 12.00 DRILL P PROD1 Directional Drill from 14,655' to 15,368'. P/U - 195K, S/O- 135K, RT - 167K, TQ - 8-9K off. TQ - 9-10K on. AST - 2.36 hrs, ART - 6.43 hrs. Loss Rate Avg. - 166 bph. Pumping Lubricant and Glass Bead sweeps as needed for sliding. Phase 2 Weather conditions. 12/12/2003 00:00 - 08:00 8.00 DRILL P PROD1 Directional Drill from 15,368' to 15,582. P/U - 195K, S/O - 130K, RT - 167K, TQ - 8-9K off. TQ - 9-10K on. Loss Rate Avg. - 130 bph. Pumping Lubricant and Glass Bead sweeps as needed for sliding. Phase 2 Weather conditions. AST - 5.75 hrs. 08:00 - 10:30 2.50 DRILL P PROD1 POH from 15,582' to 10,701' without incident. Average loss rate - 50 bph. 10:30 - 12:00 1.50 DRILL P PROD1 CBU @ 12 bpm, 1200 psi. Mix and spot 100 bbl, 100 #/bbl LCM pill. Average loss rate - 80 bph. 12:00 -15:30 3.50 DRILL P PROD1 POH from 10,701' to 92' without incident. Average loss rate- 25 bph. 15:30 - 16:30 1.00 DRILL P PROD1 PJSM. UD bit. Download MWD tools. LID PWD tool. 16:30 - 17:30 1.00 DRILL P PROD1 Upload MWD tools. M/U bit to 92'. M/U BHA from 92' to 209'. Average loss rate - 25 bph 17:30 - 18:00 0.50 DRILL P PROD1 Shallow pulse test the MWD tools @ 209'. 250 gpm, 1100 psi. Blow down surface equipment. 18:00 - 18:30 0.50 DRILL P PROD1 Pick up Drill Pipe in singles from 209' to 1,071'. Loss rate 11 bph. 18:30 - 21 :00 2.50 DRILL P PROD1 RIH with Drill Pipe from 1,071' to 10,710' while breaking circulation every 3,000'. Loss rate - 11 bph. 21 :00 - 22:30 1.50 DRILL P PROD1 Cut and slip drilling line. Static loss rate - 0 bph. Service Top Drive. Break circulation. Install blower hose. 22:30 - 00:00 1.50 DRILL P PROD1 RIH from 10,710' to 15,378'. Loss rate - 11 bph. 12/13/2003 00:00 - 00:30 0.50 DRILL P PROD1 Continue RIH from 15,378' to 15,471'. Wash and ream from 15,471' to 15,582'. Loss rate -11 bph 00:30 - 12:00 11.50 DRILL P PROD1 Directional Drill from 15,582' to 15,816'. Loss Rate average - Printed: 12/22/2003 9:17:26 AM ~ . Page 13 of 15 BP EXPLORATION Operations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: S-27 S-27B REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 2ES Start: Rig Release: Rig Number: I Phase I Date From - To ¡ Hours Task Code NPT --... ..----. ...-----.--.--..-.-----.. 12/13/2003 00:30 - 12:00 11.50 DRILL P PROD1 12:00 - 00:00 12.00 DRILL P PROD1 12/14/2003 00:00 - 07:30 7.50 DRILL P 07:30 - 10:00 2.50 DRILL P 10:00 - 11 :30 1.50 DRILL P 11 :30 - 13:00 1.50 DRILL P 13:00 - 18:30 5.50 DRILL P 18:30 - 20:00 1.50 DRILL P PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 12/15/2003 20:00 - 21 :00 1.00 DRILL P 21 :00 - 00:00 3.00 DRILL P 00:00 - 02:30 2.50 DRILL P 02:30 - 04:30 2.00 CASE P 04:30 - 09:30 5.00 CASE P 09:30 - 10:30 1.00 CASE P 10:30 - 15:30 5.00 CASE P 15:30 - 16:00 0.50 CASE P 16:00 - 17:00 1.00 CASE P 17:00 - 17:30 0.50 CASE P 17:30 - 20:00 2.50 CASE P 20:00 - 20:30 0.50 CASE P 20:30 - 23:30 3.00 CASE P 23:30 - 00:00 0.50 CEMT P 00:00 - 00:30 0.50 CEMT P 00:30 - 02:30 2.00 CEMT P COMP PROD1 PROD1 PROD1 COMP COMP COMP COMP COMP COMP COMP COMP COMP COMP 12/16/2003 COMP COMP 11/24/2003 12/18/2003 Spud Date: 7/12/1990 End: 12/18/2003 Description of Operations --------- - 98 bph. ART -1.61 hrs, AST - 6.14 hrs, P/U -190K, DN- 130K, ROT - 165K. TQ on - 12K, TQ off - 7K. Pumping Lubricant and Glass Bead sweeps as needed for sliding. Phase 2 Weather conditions slope wide. Directional Drill from 15,816' to 16,280'. Loss Rate average- 120 bph. ART - 2.01 hrs, AST -7.14 hrs, P/U -190K, DN- 125K, ROT - 160K. TQ on - 12-13K, TQ off - 8-9K. Pumping Lubricant and Glass Bead sweeps as needed for sliding. Phase 1 Spine Road, Phase 2 conditions access roads and pads. Winds are forecasted to diminish over the next 24 hours. Directional Drill from 16,280' to 16,700' - TD. Loss Rate average - 143 bph. P/U - 190K, DN - 125K, ROT - 160K. TQ on -12K, TQ off -7-8K. ART - 5.6hrs, AST - 0.17hrs Circulate bottoms up - 275gpm, 2,560psi, 92 bph losses. Short Trip from 16,700' to 15,500' and run back to TD. No evidence of fill. Loss of 61 bbls. Spot Liner Running Pill @ 16,700' in the open hole = 275gpm, 2,500psi. Monitor well - 1 Om in static loss rate of 24bph. Blow down surface equipment. Lay down drill pipe from 16,700' to 10,803' wet. No problems. Drop dart. Loss rate - 11 Obph. POH to 10,710'. Circulate bottoms up -13bpm @ 1300psi. Reciprocate and rotate while circulating. Slug the pipe. Blow down surface equipment. Loss rate - 110bph. Monitor well. Cut drilling line. Loss rate - 50bph. POH from 10,710' to 209'. Loss rate - 105bph. PJSM. Lay down BHA from 209'. Upload MWD/LWD. Flush MWD/LWD with fresh water. Loss rate - 67 bph PJSM. Rig up casing handling equipment. RIH with 4.5", 12.6# Solid/Slotted "Banzai" Liner to 6,094'. Loss rate - 87 bph. PJSM. Changeout casing handling equipment. RlU false rotary table. M/U cup assembly tool. P/U 2-7/8" DP inner string and RIH to 3,751'. Loss rate - 55 bph Locate indication profile. RID false rotary table. P/U - 54K,S/O - 52K. M/U Hanger assembly, RD tubing handling equipment. Up Wt 117 k, Dn Wt 114 k RIH 1 stand, Circ 1 liner volume at 6230' w/ 3 bpm, 300 psi, Loss rate - 65 bph RIH w/4 1/2" Liner Assy on 4" DP to 10740', Loss rate - 85 bph Circ 1 DP and Liner volume at 10740' w/3 bpm, 450 psi. Up WT 180 k, Dn Wt 150 k RIH to bottom at 16700', no problems, MU cement head pin and hose, Loss rate 75 bph Break Circ Circ at 16700' w/3.5 bpm, 1000 psi. Up wt 190 k, Dn wt 150 k, RU cement lines Pressure test lines to 5000 psi, install 2 stage plug, Displaced plug w/ cementers, 8.4 ppg Flo-Pro mud to catcher sub at 1.8 bpm, 677 psi; sheared inner plug with 1025 psi after pumping 96 bbls, 9 bbls earlier then calculated, continued displacing Printed: 12/22/2003 9: 17:26 AM --- . Page 14 of 15 BP EXPLORATION Operations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: S-27 S-27B REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 2ES i Date ! From - To Hours Task· Code NPT Phase 12/16/2003 00:30 - 02:30 2.00 CEMT P COMP 02:30 - 03:00 0.50 CEMT P COMP 03:00 - 03:15 0.25 CEMT P COMP 03:15 - 03:45 03:45 - 05:00 0.50 CEMT P 1.25 CEMT P COMP COMP 05:00 - 06:00 1.00 CEMT P COMP 06:00 - 08:00 2.00 CEMT P COMP 08:00 - 08:30 0.50 CEMT P COMP 08:30 - 11 :00 2.50 CEMT P COMP 11 :00 - 11 :30 0.50 CEMT P COMP 11 :30 - 18:00 6.50 CEMT P COMP 18:00 - 23:30 5.50 CEMT P COMP 23:30 - 00:00 0.50 RUNCOMP COMP 12/17/2003 00:00 - 02:00 2.00 RUNCOMP COMP 02:00 - 14:30 12.50 RUNCOMP COMP 14:30 - 15:00 0.50 RUNCOMP COMP 15:00 - 19:00 4.00 RUNCm.,p COMP 19:00 - 20:00 1.00 RUNCOMP COMP 20:00 - 20:30 0.50 RUNCOMP COMP 20:30 - 21 :00 0.50 RUNCOMP COMP Start: Rig Release: Rig Number: 11/24/2003 12/18/2003 Spud Date: 7/12/1990 End: 12/18/2003 Description of Operations ..----- ------ inner plug to btm w/ an add'l 20 bbls.Total displacement 116 bbls. Pressured up to 1800 psi, set hgr at 10573', slacked off, hanger taking weight, increased pressure to 2500 psi, Bled off pressure, PU and released from hanger, closed Pressure Port Isolation Tool (PPIT), verified with 1000 psi, release pressure. Top of Tie-Back Sleeve at 10573'. Guide Shoe on solid joint f/ 16699' to 16655 Slotted Liner From 16655' to 14438'. PU 16' to ECP indicator sub, inflate ECP with 1/3 bbl of mud with cement unit. Staged up from 1000 to 1500 psi. Top of ECP at 14391', Bottom of ECP at 14394' PU 23', locate HMCV indicator, pressure up to 1300 psi, hold 2 minutes to release HMCV closing sleeve safety, increase pressure to 1980 psi, opened HMCV, pumped 5 bbls to confirm valve open. Circ while batch mixing cement, Loss rate 240 bph Pump cement job. 15bbls CW1 00, 25bbls Mudpush @ 9.4ppg, 124 Class G (GASBLOK) cement @ 15.8ppg. Displace with 115 bbls 8.4ppg mud. 90 bbls fluid returned during the cement job. P/U and shut HMCV. Pressure test the HMCV to 3,250 psi. Set down and set the ZXP Packer. Saw surface verification of packer set. Close the bag and reverse circulate to clear the pipe. Shear the drain valve with 4,500 psi. Circulate out the cement with the rig pumps the long way. Circulate out cement. 130spm @ 3400 psi. Recovery estimated at 40 bbls. Clean out the flowline. Set Down 50K to verify the liner top packer has set. Test same to 1000 psi for 5 minutes - good. Displace well to Seawater. 130 spm @ 3500 psi. 175K up and 140K down. Monitor losses - 30bph. Blow down surface equipment. Rig down head pin and hoses. Clean under shakers. LDDP from 14,400' to 3,751'. Loss rate - 15bph Rig up 2-7/8" equipment. Lay down running tool. Lay down 2-7/8" tubing from 3,751'. Lay down cup assempbly and 2-7/8" equipment. Clear the floor. Pull wear ring. Loss rate - 9bph. Rig up tubing handling equipment. PJSM. RIH with 3.5" 9.2# Vam Ace for the 3.5" x 4.5" 13Cr80 completion to 7,584'. Loss rate - 8 bph. Torque to 2,820 ft-Ibs. Change over tubing handling equipment to 4.5". Loss rate - 10 bph. PJSM. RIH with 4.5" 12.6# Vam Top for the 3.5" x 4.5" 13Cr80 completion from 7,584' to 10,494'. Loss rate - 10 bph. Torque to 4,440 ft-Ibs. Spaceout and M/U FMC Tubing Hanger. P/U - 11 OK, S/O - 100K. Land tubing hanger and run in the lock down screws. Loss rate -10 bph. RIU circulating lines and test lines to 3,500psi. Printed: 12/2212003 9:17:26AM --- . Page 15 of 15 BP EXPLORATION Operations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: S-27 S-27B REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 2ES i !Code Date From - To Hours ¡Task NPT Phase "- --. 12/17/2003 21 :00 - 00:00 3.00 RUNCOMP COMP 12/18/2003 00:00 - 01 :30 1.50 RUNCOMP COMP 01 :30 - 02:00 0.50 RUNCOMP COMP 02:00 - 03: 15 1.25 RUNCOMP COMP 03: 15 - 04:30 1.25 WHSUR P COMP 04:30 - 07:00 2.50 WHSUR P COMP 07:00 - 10:30 3.50 WHSUR P COMP 10:30 - 11 :30 1.00 WHSUR P COMP 11 :30 - 15:00 3.50 WHSUR P COMP 15:00 - 15:30 0.50 WHSUR P COMP 15:30 - 16:30 1.00 WHSUR P COMP 16:30 - 17:30 1.00 WHSUR P COMP Start: Rig Release: Rig Number: Spud Date: 7/12/1990 End: 12/18/2003 11/24/2003 12/18/2003 Description of Operations -------.-.-.--.. Reverse circulate seawater and corrosion inhibitor. 3 bpm @ 200 psi. Loss rate - 10 bph Continue reverse circulation of seawater and corrosion inhibitor @ 3bpm and 200 psi - 140 degrees Drop 1-5/16" ball and rod and wait for it to seat in RHC profile of the XN nipple. Rig up to pressure test the tubing. Pressure up on the tubing and set the packer. Continue to pressure up to 3500psi and hold for 30 minutes. Good test. Bleed off pressure to 1500psi. Pressure up on annulus to 3500 psi and hold for 30 minutes. Good test. Bleed off tubing pressure to zero. Observed surface indication of the DCR valve shearing at - 500 psi on the tubing while bleeding off. With pressure equallizing, continue to bleed off pressure on both sides to zero. Install TWC valve and test to 1000 psi from below. Test good. Blow down surface equipment and rig down the circulation lines. Nipple Down BOP's. Remove upper pipe and blind rams. Nipple up tree and adapter flange. Test to 5,000psi - good. Pull TWC with DSM. Rig up LRHOS. Hold PJSM. Test injection line against annular valve to 3,000psi. Test u-tube line to 3,000 psi. Pump down tubing annulus 151 bbls diesel @ 140 degrees - 2 bpm, 225psi. U tube diesel. FMC dry rod BPV. Test from below to 1 ,000psi - good. Rig up LRHOS to 9-5/8 x 13-3/8 annulus. Test lines to 2000psi. Pump 35 bbls diesel @ 60 degrees. Final circ pressure 1050psi@OAbpm. Rig down LRHOS. Secure tree. Remove secondary annulus valve. Release rig @ 1730 hrs to 07-29C. Printed: 12/22/2003 9:17:26 AM TREE = 4" Ct.fV WELLHEAD = FfIIC AéTUÄ tÕ-R = ·611S KR B- EV = -56.04' BF. B-EV~;_·_·^m^ 28.36' 'kòAþ--;A .m._.__ --"9~f73' mMaxmAng¡e;~9T@ 14123; [)atum MD~;mm.m 1083i3"' ~,_~.~~u~ 'A_'.'_.__.~_~ _ Datum 1V 0 = 8800' SS . 5-278 13-3/8"CSG, 68#, NT-80, 10= 12A15" H i/ ~~ L - 2689' l4-lIZ' TBG, 12.6#, 13-CR, H .0152 bpf, 10 = 3.958" 1- 3009' I Minimum ID = 2.750" @ 10569'1 3-112" HES XN NIPPLE - SAFETY NOTE:>.,,' R.OW UNE IN SKID. PORTIONS OF THIS WB.L'S R.OWUNEARE3". ORlGINALWELLBORE NOT SHOWN ON THIS DIAGRAM. ***CHROMETBG & LNR*- 2193' H4-1/2" f-ES X NIP, 10 = 3.813" I 3009' H3-1/2" X4-1/Z' XO, 10= 2.992" I ST MD 6 3062 5 4129 4 6452 3 8275 2 9688 1 10378 GAS LIFT MANDRB-S DEV 1YÆ VLV LATCH FORT DATE 6 MllAG-2 DMY RK 0 12/19/03 30 MllAG-2 DOME RK 16 01/14/04 45 MllAG-2 DOME RK 16 01/14/04 44 MllAG-2 DOME RK 16 01/14/04 43 MllAG-2 DOME RK 16 01/14/04 52 MllAG-2 SO RK 24 01/14/04 TVD 3061 4061 5760 7056 8054 8526 :8: :8: --I 9816' H 9-5/8" X T' BKR ZXP LNR TOP R<R 1 19-518" CSG, 47#, NT-80-S ,10 = 8.681" H 10635' I-- MILLOUT WINDOW 9973' - 9989' .. 10500' H3-1/Z' f-ESX NIP, D =2.813" 1 10521' H4-112" X3-1/2"XO, 10= 2.990" I 10523' H7" X 4-1/2" BKR S3 R<R, 10 =3.875" 1052T H3-1/2"X 4-1/Z' XO, 10=2.990" 1 10548' H3-1/Z'HESXNIP, 10=2.813" I I 10569' H3-1/2" HES XN NIP, D = 2.750" I 10580' H4-1/Z' x 3-1/2" XO, 10 = 2.992" 1 10582' H4-1/2"WLEG 1 10585' HT' X4-112" BKRZXP I I LNR TOP PKR 12-7/B"LNR,6.16#,.0058bpf,ID=2.372" H 11220' 13-3/4" HOLEH 11315' 14-1/2"TBG, 12.6#, 13-CR, .0152 bpf, D=3.958" H 10581' 1 , , ... ... , , ... , ~ ... ... / , ... I /' IT' LNR, 26#, L-80, 0383. bpf, 10 = 6.276" H 10740' 1 14-1/2"LNR, 26#,L-80, 0383. bpf, 10=6.276" H 14439' 14-1/2" SLOTTED Lt\R, 26#, L-80, 10 = 6.276" H 16699' DATE 11/11/90 11/20/95 12/21/03 01/14/04 REV BY COMfl/ENTS ORIGINAL COMPLETION PAB SIDETRACK (S27A) JDM/KK RIG SIDETRACK (5-27B) DA V/KK GL V C/O DATE RBI BY co MIlA ENTS ffiUDHOE SA Y UNIT WB-L: S-27B ÆRMITNo: 2031680 API No: 50-029-22057-02 SEe 35, T12N, T12E, 1633' FNL & 4048' FEL BP Exploration (Alaska) . AOGCC Howard Okland 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 . Re: Distribution of Survey Data for Well S-278 Dear Dear Sir/Madam: Enclosed are two survey hard copies. Tie-on Survey: Window / Kickoff Survey: Projected Survey: 9,955.97' MD 9,973.00' MD 16,700.00' MD (if applicable) 803 -J !.J;?I 31-Dec-03 Please call me at 273-3545 if you have any questions or concerns. Regards, William T. Allen Survey Manager Attachment(s) RECEIVED ~ ~ 1 "\ ')30.1 ...;. ',.j '..1 I- "T. /J,ll2mœ Oil & Gas Cons. Commision 'I"'000rage .>~~,~ ': :' )Y ~;;~, Halliburton Sperry-Sun North 510pe Alaska BPXA PBU WOA 5 Pad 5-27B Job No. AKZZ2796082, Surveyed: 14 December, 2003 Survey Report 30 December, 2003 Your Ref: API 500292205702 Surface Coordinates: 5979855.00 N, 619393.00 E (70021'12.9431" N, 149001'49.7480" W) Grid Coordinate System: NAD27 Alaska State Planes, Zone 4 Surface Coordinates relative to Project H Reference: 979855.00 N, 119393.00 E (Grid) Surface Coordinates relative to Structure Reference: 1024.63 S, 1460.14 E (True) Kelly Bushing Elevation: 65.30ft above Mean Sea Level Kelly Bushing Elevation: 65.30ft above Project V Reference Kelly Bushing Elevation: 65.30ft above Structure Reference SPE!!r"'r"'Y-SUf1 DFUL.LING se...vrc:es A Halliburton Company DEFINITIVE . . Survey Ref: svy4146 Halliburton Sperry-Sun Survey Report for PBU_WOA S Pad - S-27B Your Ref: AP/500292205702 Job No. AKZZ2796082, Surveyed: 14 December, 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) (o/100ft) 9955.97 42.280 204.200 8187.20 8252.50 4210.74 S 1256.60 W 5975624.77 N 618203.66 E 4018.90 Tie On Point AK-6 BP _IFR-AK 9973.00 42.380 204.190 8199.79 8265.09 4221.20 S 1261.30 W 5975614.23 N 618199.13 E 0.588 4029.91 Win.dow Point 10014.38 45.080 205.820 8229.69 8294.99 4247.12 S 1273.40 W 5975588.13 N 618187.45 E 7.070 4057.48 10044.51 46.880 207.780 8250.63 8315.93 4266.45 S 1283.17W 5975568.64 N 618177.98 E 7.587 4078.53 . 10076.21 47.560 208.130 8272.16 8337.46 4287.00 S 1294.08 W 5975547.92 N 618167.41 E 2.293 4101.24 10107.35 48.850 209.230 8292.91 8358.21 4307.37 S 1305.22 W 5975527.38 N 618156.59 E 4.909 4123.97 10141.43 50.890 210.390 8314.88 8380.18 4329.97 S 1318.17 W 5975504.57 N 618143.99 E 6.527 4149.57 10171.32 51.600 211.380 8333.59 8398.89 4349.98 S 1330.14 W 5975484.38 N 618132.35 E 3.509 4172.55 10200.17 51.670 212.270 8351.49 8416.79 4369.20 S 1342.07 W 5975464.97 N 618120.73 E 2.431 4194.92 10292.63 52.690 215.110 8408.20 8473.50 4429.95 S 1382.58 W 5975403.58 N 618081.18 E 2.665 4267.43 10387.40 52.020 216.870 8466.08 8531.38 4490.66 S 1426.67 W 5975342.17 N 618038.07 E 1.632 4342.24 10481.53 53.640 215.930 8522.95 8588.25 4551.04 S 1471.18 W 5975281.10 N 617994.53 E 1.896 4417.05 10574.45 52.880 216.120 8578.53 8643.83 4611.26 S 1514.97 W 5975220.18 N 617951.71 E 0.834 4491.29 10667.69 53.680 213.490 8634.29 8699.59 4672.62 S 1557.62 W 5975158.15 N 617910.04 E 2.418 4565.65 1 0691 .18 53.540 212.330 8648.23 8713.53 4688.50 S 1567.89 W 5975142.11 N 617900.02 E 4.020 4584.39 10764.74 53.510 212.650 8691.95 8757.25 4738.39 S 1599.66 W 5975091.72 N 617869.05 E 0.352 4642.97 10858.55 51.970 211.990 8748.75 8814.05 4801.48 S 1639.58 W 5975028.00 N 617830.14 E 1.734 4716.88 10953.47 54.560 214.660 8805.52 8870.82 4865.01 S 1681.39 W 5974963.81 N 617789.35 E 3.539 4792.34 10986.52 59.340 216.180 8823.54 8888.84 4887.57 S 1697.45 W 5974941.00 N 617773.65 E 14.967 4819.93 11017.63 63.300 216.820 8838.47 8903.77 4909.51 S 1713.68 W 5974918.81 N 617757.77 E 12.856 4847.15 11046.33 63.790 216.630 8851.26 8916.56 4930.10 S 1729.05 W 5974897.97 N 617742.74 E 1.807 4872.79 . 11078.18 67.250 214.650 8864.45 8929.75 4953.66 S 1745.93 W 5974874.15 N 617726.23 E 12.248 4901.67 11110.24 70.290 214.630 8876.06 8941.36 4978.24 S 1762.91 W 5974849.30 N 617709.64 E 9.482 4931.39 11139.67 72.050 213.970 8885.56 8950.86 5001.25 S 1778.61 W 5974826.04 N 617694.32 E 6.346 4959.09 11172.58 74.180 214.320 8895.12 8960.42 5027.31 S 1796.28 W 5974799.70 N 617677.06 E 6.552 4990.38 11204.63 77 .440 213.450 8902.97 8968.27 5053.10 S 1813.60 W 5974773.64 N 617660.15 E 10.506 5021.25 11232.88 81.520 214.770 8908.13 8973.43 5076.09 S 1829.18 W 5974750.40 N 617644.95 E 15.155 5048.84 11267.45 85.860 215.370 8911.93 8977.23 5104.21 S 1848.91 W 5974721.97 N 617625.66 E 12.672 5083.04 11326.67 88.830 215.750 8914.67 8979.97 5152.33 S 1883.31 W 5974673.31 N 617592.03 E 5.056 5141.98 11420.26 85.000 213.200 8919.71 8985.01 5229.35 S 1936.20 W 5974595.46 N 617540.38 E 4.914 5234.90 30 December, 2003 - 10:01 Page 20f6 DrillQuest 3.03.05.005 Halliburton Sperry-Sun Survey Report for PBU_WOA S Pad - S-27B Your Ref: API 500292205702 Job No. AKZZ27960B2, Surveyed: 14 December, 2003 BPXA North Slope Alaska Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastin9s Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (0/100ft) 11484.72 84.620 214.000 8925.54 8990.84 5282.82 S 1971.73 W 5974541 .43 N 617505.71 E 1.369 5298.63 11509.96 83.130 216.150 8928.23 8993.53 5303.35 S 1986.15 W 5974520.67 N 617491.62 E 10.324 5323.61 11552.95 81.760 216.610 8933.89 8999.19 5337.66 S 2011.42 W 5974485.96 N 617466.89 E 3.359 5366.12 11600.47 81.640 216.400 8940.75 9006.05 5375.46 S 2039.40 W 5974447.72 N 617439.52 E 0.505 5413.03 11645.57 82.020 216.360 8947.15 9012.45 5411 .40 S 2065.88 W 5974411.36 N 617413.62 E 0.847 5457.56 . 11739.55 84.440 215.720 8958.23 9023.53 5486.86 S 2120.78 W 5974335.04 N 617359.93 E 2.662 5550.60 11833.03 85.120 214.080 8966.74 9032.04 5563.21 S 2174.04 W 5974257.86 N 617307.89 E 1.892 5643.24 11926.02 84.680 214.660 8975.00 9040.30 5639.66 S 2226.32 W 5974180.58 N 617256.83 E 0.781 5735.34 12019.96 85.300 213.890 8983.21 9048.51 5716.99 S 2279.03 W 5974102.42 N 617205.37 E 1.050 5828.38 12112.64 85.300 213.770 8990.80 9056.10 5793.72 S 2330.45 W 5974024.88 N 617155.17 E 0.129 5920.12 12206.93 86.480 212.970 8997.56 9062.86 5872.26 S 2382.18 W 5973945.53 N 617104.70 E 1.511 6013.45 12298.84 87.350 212.590 9002.51 9067.81 5949.42 S 2431.87 W 5973867.58 N 617056.25 E 1.033 6104.40 12393.36 88.640 213.550 9005.81 9071.11 6028.57 S 2483.41 W 5973787.62 N 617005.97 E 1.701 6198.07 12485.51 89.510 213.470 9007.30 9072.60 6105.40 S 2534.28 W 5973709.99 N 616956.34 E 0.948 6289.53 12578.62 89.690 213.950 9007.95 9073.25 6182.85 S 2585.95 W 5973631 .73 N 616905.91 E 0.551 6381.99 12671.81 91.050 214.490 9007.35 9072.65 6259.90 S 2638.36 W 5973553.85 N 616854.74 E 1.570 6474.62 12763.76 91.790 214.620 9005.07 9070.37 6335.61 S 2690.49 W 5973477.32 N 616803.81 E 0.817 6566.05 12860.21 91.300 210.090 9002.47 9067.77 6417.03 S 2742.08 W 5973395.08 N 616753.53 E 4.722 6661.48 12950.56 91.600 209.420 9000.18 9065.48 6495.45 S 2786.90 W 5973315.97 N 616709.96 E 0.812 6750.22 13044.88 90.930 207.440 8998.10 9063.40 6578.37 S 2831.79 W 5973232.34 N 616666.40 E 2.216 6842.44 13137.07 91.300 206.500 8996.31 9061.61 6660.51 S 2873.59 W 5973149.54 N 616625.91 E 1.096 6932.06 13230.15 90.680 206.480 8994.70 9060.00 6743.81 S 2915.11 W 5973065.59 N 616585.73 E 0.666 7022.37 . 13324.23 90.930 205.020 8993.38 9058.68 6828.53 S 2955.97 W 5972980.23 N 616546.22 E 1.574 7113.35 13417.63. 91.600 203.890 8991.31 9056.61 6913.53 S 2994.63 W 5972894.62 N 616508.92 E 1 .406 7203.11 13476.05 92.040 203.090 8989.46 9054.76 6967.08 S 3017.90 W 5972840.71 N 616486.51 E 1.562 7258.95 13508.66 92.780 206.950 8988.09 9053.39 6996.60 S 3031.68 W 5972810.97 N 616473.20 E 12.042 7290.35 13541.74 92.220 210.680 8986.64 9051.94 7025.55 S 3047.61 W 5972781.77 N 616457.74 E 11.391 7322.71 13568.44 91.730 211.620 8985.72 9051.02 7048.39 S 3061.41 W 5972758.72 N 616444.30 E 3.968 7349.04 13603.49 91.230 213.680 8984.82 9050.12 7077 .89 S 3080.31 W 5972728.92 N 616425.87 E 6.046 7383.75 13634.91 90.740 215.290 8984.28 9049.58 7103.78 S 3098.10 W 5972702.75 N 616408.50 E 5.355 7414.99 13663.71 90.930 218.750 8983.86 9049.16 7126.77 S 3115.43W 5972679.49 N 616391.53 E 12.031 7443.73 13695.96 90.120 222.760 8983.56 9048.86 7151.20 S 3136.48 W 5972654.73 N 616370.88 E 12.685 7475.98 13727.73 88.520 224.910 8983.94 9049.24 7174.11 S 3158.48 W 5972631.47 N 616349.24 E 8.435 7507.69 13756.63 88.950 226.220 8984.58 9049.88 7194.34 S 3179.11W 5972610.92 N 616328.94 E 4.770 7536.46 13789.89 89.570 229.180 8985.01 9050.31 7216.72 S 3203.71 W 5972588.15 N 616304.70 E 9.092 7569.45 30 December, 2003 - 10:01 Page 3 of6 DrillQuest 3.03.05.005 Halliburton Sperry-Sun Survey Report for PBU_WOA S Pad - S-27B Your Ref: API 500292205702 Job No. AKZZ2796082, Surveyed: 14 December, 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) 13812.70 90.370 229.920 8985.02 9050.32 7231.51 S 3221.06 W 5972573.07 N 616287.58 E 4.778 7591.98 13842.66 90.680 231.060 8984.74 9050.04 7250.57 S 3244.18 W 5972553.65 N 616264.78 E 3.943 7621.48 13872.17 90.560 231.940 8984.43 9049.73 7268.94 S 3267.27 W 5972534.91 N 616241.98 E 3.009 7650.44 13902.74 92.960 234.840 8983.49 9048.79 7287.16 S 3291.79 W 5972516.31 N 616217.75 E 12.310 7680.22 13936.88 95.620 239.090 8980.93 9046.23 7305.72 S 3320.32 W 5972497.30 N 616189.52 E 14.655 7712.85 . 13963.32 97.120 243.150 8978.00 9043.30 7318.41 S 3343.33 W 5972484.24 N 616166.72 E 16.281 7737.43 13990.96 97.050 247.150 8974.59 9039.89 7329.93 S 3368.21 W 5972472.32 N 616142.02 E 14.363 7762.35 14028.84 96.370 251.670 8970.16 9035.46 7343.16 S 3403.42 W 5972458.54 N 616107.03 E 11.986 7795.27 14056.83 96.800 255.610 8966.95 9032.25 7350.99 S 3430.09 W 5972450.28 N 616080.49 E 14.068 7818.53 14087.82 96.560 259.650 8963.34 9028.64 7357.58 S 3460.15 W 5972443.21 N 616050.54 E 12.971 7843.06 14122.53 97.180 264.390 8959.19 9024.49 7362.36 S 3494.27 W 5972437.89 N 616016.50 E 13.675 7868.84 14153.55 96.190 268.580 8955.57 9020.87 7364.25 S 3525.01 W 5972435.51 N 615985.79 E 13.790 7890.23 14181.67 95.940 272.270 8952.60 9017.90 7364.04 S 3552.97 W 5972435.27 N 615957.83 E 13.079 7908.22 14215.92 96.120 273.840 8949.00 9014.30 7362.23 S 3586.98 W 5972436.55 N 615923.80 E 4.589 7928.91 14247.55 94.320 278.360 8946.12 9011.42 7358.88 S 3618.29 W 5972439.39 N 615892.44 E 15.326 7946.69 14275.92 93.460 281.370 8944.20 9009.50 7354.03 S 3646.17 W 5972443.80 N 615864.48 E 11.011 7961.10 14298.92 93.400 282.510 8942.82 9008.12 7349.28 S 3668.63 W 5972448.19 N 615841.95E 4.955 7972.06 14368.27 92.900 285.100 8939.01 9004.31 7332.76 S 3735.87 W 5972463.64 N 615774.45 E 3.798 8003.13 14460.86 90.370 290.510 8936.37 9001.67 7304.47 S 3823.95 W 5972490.52 N 615685.94 E 6.448 8038.78 14494.91 87.220 292.760 8937.08 9002.38 7291.92 S 3855.59 W 5972502.56 N 615654.10 E 11.367 8049.77 14526.26 86.790 293.620 8938.72 9004.02 7279.59 S 3884.37 W 5972514.43 N 615625.13 E 3.064 8059.07 14554.64 86.600 294.410 8940.36 9005.66 7268.06 S 3910.25 W 5972525.55 N 615599.07 E 2.859 8067.09 . 14648.74 86.420 295.520 8946.09 9011.39 7228.42 S 3995.40 W 5972563.83 N 615513.30 E 1.193 8092.20 14740.67 84.750 297.490 8953.16 9018.46 7187.52 S 4077.41 W 5972603.42 N 615430.64 E 2.804 8114.32 14834.88 85.800 301.780 8960.93 9026.23 7141.10 S 4159.00 W 5972648.53 N 615348.33 E 4.673 8131.96 14927.33 85.800 304.040 8967.70 9033.00 7091.01 S 4236.40 W 5972697.38 N 615270.14 E 2.438 8144.09 15021.39 86.420 305.830 8974.08 9039.38 7037.28 S 4313.33 W 5972749.88 N 615192.36 E 2.010 8153.14 15113.63 87.160 305.400 8979.25 9044.55 6983.65 S 4388.20 W 5972802.31 N 615116.65 E 0.927 8160.94 15207.65 87.290 306.540 8983.80 9049.10 6928.49 S 4464.20 W 5972856.25 N 615039.78 E 1.219 8168.31 15270.85 87.410 307.670 8986.72 9052.02 6890.40 S 4514.55 W 5972893.53 N 614988.83 E 1.796 8172.01 15300.92 87.220 306.820 8988.13 9053.43 6872.22 S 4538.46 W 5972911.33 N 614964.63 E 2.893 8173.70 15333.4 7 87.590 303.000 8989.60 9054.90 6853.62 S 4565.12 W 5972929.50 N 614937.68 E 11.779 8176.85 15365.12 87.720 302.150 8990.90 9056.20 6836.59 S 4591.77 W 5972946.10 N 614910.76 E 2.715 8181.20 15393.39 87.410 301.080 8992.10 9057.40 6821.79 S 4615.82 W 5972960.52 N 614886.47 E 3.937 8185.54 15426.71 87.780 297.390 8993.50 9058.80 6805.53 S 4644.87 W 5972976.32 N 614857.17 E 11 .120 8192.03 30 December, 2003·10:01 Page 4 of 6 DrillQuest 3.03.05.005 Halliburton Sperry-Sun Survey Report for PBU_WOA S Pad - S-27B Your Ref: API 500292205702 Job No. AKZZ2796082, Surveyed: 14 December, 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) (°/1 DOft) 15457.56 87.590 297.370 8994.74 9060.04 6791.35 S 4672.24 W 5972990.05 N 614829.58 E 0.619 8199.01 15486.46 86.850 294.010 8996.15 9061.45 6778.84 S 4698.25 W 5973002.15 N 614803.38 E 11.891 8206.37 15513.56 87.220 290.160 8997.55 9062.85 6768.67 S 4723.32 W 5973011.92 N 614778.14 E 14.253 8214.91 15532.00 88.150 288.720 8998.29 9063.59 6762.54 S 4740.69 W 5973017.78 N 614760.67 E 9.291 8221.52 15562.93 88.640 286.450 8999.16 9064.46 6753.20 S 4770.16 W 5973026.65 N 614731.06 E 7.505 8233.54 . 15591.59 89.380 284.770 8999.66 9064.96 6745.49 S 4797.76 W 5973033.92 N 614703.34 E 6.404 8245.59 15625.91 89.320 280.890 9000.05 9065.35 6737.87 S 4831.22 W 5973041.00 N 614669.77 E 11 .306 8261.51 15656.75 90.310 280.010 9000.14 9065.44 6732.27 S 4861.54 W 5973046.11 N 614639.36 E 4.295 8276.93 15684.37 92.220 277.230 8999.53 9064.83 6728.13 S 4888.84 W 5973049.81 N 614612.00 E 12.209 8291.50 15777.26 93.710 273.600 8994.73 9060.03 6719.38 S 4981.18 W 5973057.09 N 614519.53 E 4.219 8344.77 15870.43 91.360 272.080 8990.61 9055.91 6714.77 S 5074.13 W 5973060.22 N 614426.52 E 3.003 8401.60 15962.97 91.360 272.720 8988.41 9053.71 6710.90 S 5166.56 W 5973062.62 N 614334.04 E 0.691 8458.64 16056.73 93.770 272.160 8984.22 9049.52 6706.91 S 5260.14 W 5973065.12 N 614240.41 E 2.639 8516.34 16150.01 95.380 273.160 8976.78 9042.08 6702.59 S 5353.02 W 5973067.95 N 614147.47 E 2.030 8573.34 16243.66 95.810 274.570 8967.64 9032.94 6696.31 S 5446.00 W 5973072.75 N 614054.40 E 1.567 8628.92 16335.25 95.630 274.400 8958.52 9023.82 6689.19 S 5536.86 W 5973078.43 N 613963.44 E 0.270 8682.47 16428.99 95.000 275.960 8949.83 9015.13 6680.76 S 5629.81 W 5973085.37 N 613870.37 E 1.788 8736.39 16522.22 94.200 276.910 8942.36 9007.66 6670.34 S 5722.15 W 5973094.32 N 613777.87 E 1.330 8788.40 16615.41 94.450 278.320 8935.33 9000.63 6658.03 S 5814.26 W 5973105.16 N 613685.58 E 1.532 8838.81 16633.21 94.390 278.490 8933.96 8999.26 6655.44 S 5831.81 W 59731 07.48 N 613667.99 E 1.010 8848.23 - 16700.00 94.390 278.490 8928.84 8994.14 6645.60 S 5897.68 W 5973116.26 N .' 613601.97 E 0.000 8883.50 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 220.470° (True). Magnetic Declination at Surface is 25.315° (28-Nov-03) Based upon Minimum Curvature type calculations, at a Measured Depth of 16700.00ft., The Bottom Hole Displacement is 8885.19ft., in the Direction of 221.588° (True). 30 December, 2003 - 10:01 Page 50f6 DrillQuest 3.03.05.005 Halliburton Sperry-Sun Survey Report for PBU_WOA S Pad - S-27B Your Ref: API 500292205702 Job No. AKZZ2796082, Surveyed: 14 December, 2003 North Slope Alaska BPXA Comments Measured Depth (ft) Station Coordinates TVD Northings Eastings (ft) (ft) (ft) Comment 9955.97 9973.00 16700.00 8252.50 8265.09 8994.14 4210.74 S 4221.20 S 6645.60 S 1256.60 W 1261.30 W 5897.68 W Tie On Point Window Point Projected Survey . Survey tool proflram for S-27B From Measured Vertical Depth Depth (ft) (ft) To Measured Vertical Depth Depth Survey Tool Description (ft) (ft) 0.00 9955.97 0.00 9955.97 8252.50 16700.00 8252.50 BP High Accuracy Gyro (S-27) 8994.14 AK-6 BP _IFR-AK (S-27B) . 30 December, 2003 - 10:01 Page 6 of6 DrillQuest 3.03.05.005 . AOGCC Howard Okland 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 Re: Distribution of Survey Data for Well S-278 MWD Dear Dear Sir/Madam: Enclosed are two survey hard copies. Tie-on Survey: Window / Kickoff Survey: Projected Survey: 9,957.97' MD 9,973.00' MD 16,700.00' MD (if applicable) . Please call me at 273-3545 if you have any questions or concerns. Regards, William T. Allen Survey Manager Attachment(s) OlD3 ~ 108: 31-Dec-03 RECEIVED II. '.1 1 "\ "004 ....;.:. ¡ ,,,. I- Alaska Oil & Gas Cons. Commision Anooorage Halliburton Sperry-Sun North 510pe Alaska BPXA PBU WOA 5 Pad 5-27B MWD . Job No. AKMW2796082, Surveyed: 14 December, 2003 Survey Report 30 December, 2003 Your Ref: API 500292205702 Surface Coordinates: 5979855.00 N, 619393.00 E (70· 21'12.9431" N, 149· 01' 49.7480" W) Grid Coordinate System: NAD27 Alaska State Planes, Zone 4 . Surface Coordinates relative to Project H Reference: 979855.00 N, 119393.00 E (Grid) Surface Coordinates relative to Structure Reference: 1024.63 S, 1460.14 E (True) Kelly Bushing Elevation: 65.30ft,above Mean Sea Level Kelly Bushing Elevation: 65.30ft above Project V Reference Kelly Bushing Elevation: 65.30ft above Structure Reference SP'E!r""r""):I-SU:1'1 DRIL.LINS seRVices A Halliburton Company Survey Ref: svy4147 Halliburton Sperry-Sun Survey Report for PBU _WOA S Pad - S-27B MWD Your Ref: API 500292205702 Job No. AKMW2796082, Surveyed: 14 December, 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) (o/100ft) 9955.97 42.280 204.200 8187.20 8252.50 4210.74 S 1256.60 W 5975624.77 N 618203.66 E 4018.90 MWD Magnetic 9957.97 42.292 204.199 8188.68 8253.98 4211.97 S 1257.15 W 5975623.53 N 618203.13 E 0.588 4020.19 Tie On Point 9973.00 42.380 204.190 8199.79 8265.09 4221.20 S 1261.30W 5975614.23 N 618199.13 E 0.588 4029.91 Window Point 10014.38 45.080 205.820 8229.69 8294.99 4247.12 S 1273.40 W 5975588.13 N 618187.45 E 7.070 4057.48 10044.51 46.880 208.030 8250.63 8315.93 4266.43 S 1283.21 W 5975568.66 N 618177.94 E 7.969 4078.54 . 10076.21 47.560 208.470 8272.16 8337.46 4286.93 S 1294.22 W 5975547.99 N 618167.26 E 2.375 4101.28 10107.35 48.850 207.220 8292.91 8358.21 4307.45 S 1305.06 W 5975527.30 N 618156.74 E 5.110 4123.93 10141.43 50.890 209.950 8314.88 8380.18 4330.32 S 1317.54 W 5975504.23 N 618144.64 E 8.563 4149.42 10171.32 51.600 211.050 8333.59 8398.89 4350.41 S 1329.37 W 5975483.96 N 618133.13 E 3.725 4172.38 10200.17 51.670 212.640 8351.50 8416.80 4369.62 S 1341.30 W 5975464.56 N 618121.50 E 4.328 4194.74 10292.63 52.690 215.030 8408.20 8473.50 4430.28 S 1381.97 W 5975403.26 N 618081.80 E 2.321 4267.28 10387.40 52.020 217.140 8466.08 8531.38 4490.92 S 1426.16 W 5975341.93 N 618038.59 E 1.899 4342.10 10481.53 53.640 216.070 8522.95 8588.25 4551.13S 1470.88 W 5975281.01 N 617994.83 E 1.945 4416.93 10574.45 52.880 216.330 8578.54 8643.84 4611.22 S 1514.86 W 5975220.23 N 617951.82 E 0.848 4491.18 10667.69 53.680 213.620 8634.29 8699.59 4672.45 S 1557.68 W 5975158.32 N 617909.97 E 2.483 4565.56 10691.18 53.540 212.680 8648.23 8713.53 4688.29 S 1568.02 W 5975142.32 N 617899.89 E 3.276 4584.32 10764.74 53.510 212.990 8691.96 8757.26 4737.99 S 1600.09 W 5975092.12 N 617868.61 E 0.341 4642.94 10858.55 51.970 212.360 8748.75 8814.05 4800.83 S 1640.41 W 5975028.64 N 617829.31 E 1.726 4716.92 10953.47 54.560 215.040 8805.53 8870.83 4864.08 S 1682.63 W 5974964.72 N 617788.10 E 3.544 4792.44 10986.52 59.340 216.670 8823.55 8888.85 4886.52 S 1698.86 W 5974942.03 N 617772.23 E 15.041 4820.04 11017.63 63.300 217.610 8838.47 8903.77 4908.27 S 1715.34 W 5974920.02 N 617756.10 E 13.002 4847.29 11046.33 63.790 217.370 8851.26 8916.56 4928.66 S 1730.97 W 5974899.38 N 617740.79 E 1.864 4872.95 . 11078.18 67.250 215.540 8864.46 8929.76 4951.97 S 1748.19 W 5974875.80 N 617723.95 E 12.056 4901.85 11110.24 70.290 215.060 8876.06 8941.36 4976.36 S 1765.45 W 5974851.14 N 617707.07 E 9.584 4931.61 11139.67 72.050 213.560 8885.56 8950.86 4999.37 S 1781.15 W 5974827.88 N 617691.74 E 7.683 4959.31 11172.58 74.180 213.050 8895.12 8960.42 5025.69 S 1798.44 W 5974801.29 N 617674.87 E 6.640 4990.55 11204.63 77.440 212.850 8902.98 8968.28 5051.76 S 1815.34 W 5974774.96 N 617658.39 E 10.190 5021.35 11232.88 81.520 213.620 8908.13 8973.43 5074.98 S 1830.56 W 5974751.49 N 617643.55 E 14.689 5048.90 11267.45 85.860 215.580 8911.93 8977.23 5103.26 S 1850.07 W 5974722.91 N 617624.49 E 13.760 5083.07 11326.67 88.830 216.020 8914.68 8979.98 5151.23 S 1884.67 W 5974674.39 N 617590.66 E 5.070 5142.02 11420.26 85.000 213.230 8919.71 8985.01 5228.11 S 1937.76 W 5974596.68 N 617538.80 E 5.060 5234.96 11484.72 84.620 214.540 8925.54 8990.84 5281.40 S 1973.55 W 5974542.82 N 617503.87 E 2.108 5298.73 11509.96 83.130 216.300 8928.24 8993.54 5301.85 S 1988.09 W 5974522.14 N 617489.65 E 9.106 5323.73 11552.95 81.760 216.870 8933.89 8999.19 5336.07 S 2013.49 W 5974487.52 N 617464.80 E 3.447 5366.25 11600.47 81.640 216.580 8940.75 9006.05 5373.76 S 2041.61 W 5974449.39 N 617437.29 E 0.655 5413.17 30 December, 2003 - 10:19 Page 2 of6 DrillQuest 3.03.05.005 Halliburton Sperry-Sun Survey Report for PBU_WOA S Pad - S-27B MWD Your Ref: API 500292205702 Job No. AKMW2796082, Surveyed: 14 December, 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) (o/100ft) 11645.57 82.020 216.630 8947.16 9012.46 5409.60 S 2068.23 W 5974413.13 N 617411.24 E 0.850 5457.71 11739.55 84.440 216.080 8958.24 9023.54 5484.75 S 2123.54 W 5974337.11 N 617357.13 E 2.640 5550.79 11833.03 85.120 214.420 8966.74 9032.04 5560.77 S 2177.27 W 5974260.24 N 617304.62 E 1.912 5643.49 11926.02 84.680 215.130 8975.01 9040.31 5636.85 S 2230.10 W 5974183.33 N 617253.01 E 0.896 5735.65 12019.96 85.300 214.380 8983.21 9048.51 5713.74 S 2283.44 W 5974105.60 N 617200.90 E 1.034 5828.77 . 12112.64 85.300 214.230 8990.81 9056.11 5790.04 S 2335.50 W 5974028.48 N 617150.06 E 0.161 5920.60 12206.93 86.480 213.540 8997.56 9062.86 5868.11 S 2387.93 W 5973949.58 N 617098.88 E 1 .449 6014.03 12298.84 87.350 213.080 9002.51 9067.81 5944.81 S 2438.33 W 5973872.09 N 617049.71 E 1.070 6105.09 12393.36 88.640 213.700 9005.82 9071.12 6023.68 S 2490.32 W 5973792.40 N 616998.99 E 1.514 6198.83 12485.51 89.510 213.610 9007.30 9072.60 6100.37 S 2541.38 W 5973714.91 N 616949.16 E 0.949 6290.31 12578.62 89.690 213.820 9007.95 9073.25 6177.82 S 2593.06 W 5973636.65 N 616898.72 E 0.297 6382.77 12671.81 91.050 213.790 9007.35 9072.65 6255.25 S 2644.91 W 5973558.40 N 616848.11 E 1.460 6475.33 12763.76 91.790 214.250 9005.07 9070.37 6331.44 S 2696.33 W 5973481.40 N 616797.90 E 0.948 6566.67 12860.21 91.300 210.400 9002.47 9067.77 6412.89 S 2747.88 W 5973399.13 N 616747.66 E 4.022 6662.09 12950.56 91.600 209.750 9000.19 9065.49 6491.06 S 2793.14 W 5973320.26 N 616703.65 E 0.792 6750.93 13044.88 90.930 207.670 8998.10 9063.40 6573.75 S 2838.44 W 5973236.85 N 616659.68 E 2.316 6843.24 13137.07 91.300 206.640 8996.31 9061.61 6655.77 S 2880.50 W 5973154.18 N 616618.93 E 1.187 6932.94 13230.15 90.680 206.980 8994.70 9060.00 6738.83 S 2922.48 W 5973070.46 N 616578.28 E 0.760 7023.37 13324.23 90.930 205.240 8993.38 9058.68 6823.30 S 2963.88 W 5972985.34 N 616538.23 E 1.868 7114.50 13417.63 91.600 204.210 8991.32 9056.62 6908.11 S 3002.93 W 5972899.91 N 616500.53 E 1.315 7204.37 13476.05 92.040 203.610 8989.46 9054.76 6961.49 S 3026.60 W 5972846.16 N 616477.72 E 1.273 7260.34 13508.66 92.780 207.340 8988.09 9053.39 6990.90 S 3040.61 W 5972816.54 N 616464.18 E 11.651 7291.80 . 13541.74 92.220 210.990 8986.65 9051.95 7019.75 S 3056.71 W 5972787.43 N 616448.54 E 11.153 7324.21 13568.44 91.730 212.300 8985.73 9051.03 7042.47 S 3070.71 W 5972764.49 N 616434.90 E 5.236 7350.57 13603.49 91.230 213.850 8984.82 9050.12 7071.83 S 3089.83 W 5972734.83 N 616416.25 E 4.645 7385.32 13634.91 90.740 216.080 8984.28 9049.58 7097.57 S 3107.84 W 5972708.81 N 616398.66 E 7.266 7416.59 13663.71 90.930 218.650 8983.86 9049.16 7120.46 S 3125.31 W 5972685.64 N 616381.55 E 8.947 7445.34 13695.96 90.120 222.150 8983.57 9048.87 7145.01 S 3146.21 W 5972660.76 N 616361.05 E 11.139 7477.58 13727.73 88.520 224.680 8983.94 9049.24 7168.08 S 3168.04 W 5972637.34 N 616339.59 E 9.422 7509.31 13756.63 88.950 226.220 8984.58 9049.88 7188.35 S 3188.63 W 5972616.75 N 616319.33 E 5.531 7538.09 13789.89 89.570 229.530 8985.01 9050.31 7210.66 S 3213.29 W 5972594.05 N 616295.02 E 10.124 7571.06 13812.70 90.370 230.330 8985.02 9050.32 7225.34 S 3230.75 W 5972579.09 N 616277.80 E 4.960 7593.56 13842.66 90.680 231.310 8984.75 9050.05 7244.27 S 3253.97 W 5972559.80 N 616254.89 E 3.431 7623.03 13872.17 90.560 232.480 8984.43 9049.73 7262.48 S 3277.19 W 5972541.22 N 616231.96 E 3.985 7651.96 13902.74 92.960 235.530 8983.49 9048.79 7280.43 S 3301.91 W 5972522.88 N 616207.53 E 12.691 7681.66 30 December, 2003 - 10:19 Page 3 of6 DrillQuest 3.03.05.005 Halliburton Sperry-Sun Survey Report for PBU_WOA S Pad - S-27B MWD Your Ref: API 500292205702 Job No. AKMW2796082, Surveyed: 14 December, 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) 13936.88 95.620 238.580 8980.94 9046.24 7298.94 S 3330.47 W 5972503.91 N 616179.27 E 11.835 7714.28 13963.32 97.120 243.770 8978.00 9043.30 7311.61 S 3353.48 W 5972490.88 N 616156.46 E 20.316 7738.85 13990.96 97.050 247.430 8974.59 9039.89 7322.94 S 3378.45 W 5972479.16 N 616131.67 E 13.143 7763.68 14028.84 96.370 251.830 8970.16 9035.46 7336.03 S 3413.71 W 5972465.50 N 616096.62 E 11.675 7796.52 14056.83 96.800 256.180 8966.95 9032.25 7343.69 S 3440.44 W 5972457.42 N 616070.03 E 15.515 7819.69 . 14087.82 96.560 260.840 8963.34 9028.64 7349.82 S 3470.59 W 5972450.81 N 616039.97 E 14.955 7843.93 14122.53 97.180 266.310 8959.19 9024.49 7353.67 S 3504.82 W 5972446.41 N 616005.81 E 15.747 7869.08 14153.55 96.190 270.390 8955.58 9020.88 7354.56 S 3535.61 W 5972445.03 N 615975.04 E 13.447 7889.74 14181.67 95.940 271.630 8952.61 9017.91 7354.07 S 3563.57 W 5972445.08 N 615947.08 E 4.474 7907.51 14215.92 96.120 276.660 8949.01 9014.31 7351.60 S 3597.53 W 5972447.00 N 615913.08 E 14.614 7927.68 14247.55 94.320 274.670 8946.13 9011.43 7348.50 S 3628.87 W 5972449.61 N 615881.69 E 8.464 7945.66 14275.92 93.460 277.810 8944.20 9009.50 7345.42 S 3657.00 W 5972452.24 N 615853.51 E 11.451 7961.58 14298.92 93.400 283.200 8942.83 9008.13 7341.24 S 3679.57 W 5972456.06 N 615830.89 E 23.394 7973.04 14368.27 92.900 280.570 8939.01 9004.31 7326.98 S 3747.32 W 5972469.24 N 615762.91 E 3.855 8006.17 14460.86 90.370 287.030 8936.37 9001.67 7304.91 S 3837.15 W 5972489.87 N 615672.75 E 7.490 8047.68 14494.91 87.220 293.160 8937.09 9002.39 7293.22 S 3869.10 W 5972501.05 N 615640.61 E 20.235 8059.53 14526.26 86.790 293.850 8938.72 9004.02 7280.74 S 3897.81 W 5972513.07 N 615611.71 E 2.591 8068.66 14554.64 86.600 294.750 8940.36 9005.66 7269.08 S 3923.63 W 5972524.32 N 615585.70 E 3.236 8076.55 14648.74 86.420 295.820 8946.09 9011.39 7228.96 S 4008.56 W 5972563.08 N 615500.15 E 1.151 8101.15 14740.67 84.750 297.720 8953.17 9018.47 7187.68 S 4090.38 W 5972603.05 N 615417.67 E 2.747 8122.86 14834.88 85.800 301.940 8960.93 9026.23 7140.99 S 4171.81 W 5972648.44 N 615335.51 E 4.601 8140.19 14927.33 85.800 304.220 8967.70 9033.00 7090.67 S 4249.07 W 5972697.52 N 615257.47 E 2.460 8152.05 . 15021.39 86.420 306.020 8974.08 9039.38 7036.68 S 4325.82 W 5972750.28 N 615179.86 E 2.020 8160.80 15113.63 87.160 305.270 8979.25 9044.55 6983.01 S 4400.66 W 5972802.75 N 615104.18 E 1.141 8168.55 15207.65 87.290 306.370 8983.80 9049.10 6928.05 S 4476.81 W 5972856.49 N 615027.17 E 1.177 8176.16 15270.85 87.410 307.950 8986.72 9052.02 6889.92 S 4527.12 W 5972893.81 N 614976.25 E 2.505 8179.80 15300.92 87.220 307.070 8988.13 9053.43 6871.63 S 4550.94 W 5972911.72 N 614952.14 E 2.991 8181.35 15333.47 87.590 303.380 8989.61 9054.91 6852.88 S 4577.50 W 5972930.05 N 614925.28 E 11.382 8184.33 15365.12 87.720 302.510 8990.90 9056.20 6835.68 S 4604.04 W 5972946.82 N 614898.47 E 2.777 8188.47 15393.39 87.410 301.050 8992.10 9057.40 6820.81 S 4628.05 W 5972961.31 N 614874.23 E 5.275 8192.73 15426.71 87.780 297.470 8993.50 9058.80 6804.54 S 4657.09 W 5972977.11 N 614844.94 E 10.792 8199.21 15457.56 87.590 297.670 8994.75 9060.05 6790.27 S 4684.41 W 5972990.94 N 614817.39 E 0.894 8206.09 15486.46 86.850 293.970 8996.15 9061.45 6777.70 S 4710.39 W 5973003.10 N 614791.21 E 13.041 8213.39 15513.56 87.220 290.190 8997.55 9062.85 6767.53 S 4735.47 W 5973012.87 N 614765.98 E 13.996 8221.92 15532.00 88.150 291.830 8998.30 9063.60 6760.92 S 4752.67 W 5973019.20 N 614748.68 E 10.218 8228.06 30 December, 2003 - 10:19 Page 4 of 6 DrillQuest 3.03.05.005 Halliburton Sperry-Sun Survey Report for PBU_WOA S Pad - S-27B MWD Your Ref: AP/500292205702 Job No. AKMW2796082, Surveyed: 14 December, 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) 15562.93 88.640 289.270 8999.16 9064.46 6750.07 S 4781.61 W 5973029.59 N 614719.56 E 8.424 8238.59 15591.59 89.380 287.430 8999.66 9064.96 6741.05S 4808.81 W 5973038.17 N 614692.22 E 6.919 8249.38 15625.91 89.320 283.130 9000.05 9065.35 6732.01 S 4841.91 W 5973046.69 N 614658.99 E 12.530 8263.99 15656.75 90.310 280.450 9000.15 9065.45 6725.71 S 4872.09 W 5973052.51 N 614628.70 E 9.264 8278.79 15684.37 92.220 279.190 8999.54 9064.84 6721.00 S 4899.30 W 5973056.78 N 614601.42 E 8.284 8292.86 . 15777.26 93.710 276.790 8994.73 9060.03 6708.10 S 4991.16 W 5973068.21 N 614509.38 E 3.038 8342.67 15870.43 91.360 274.680 8990.61 9055.91 6698.81 S 5083.76 W 5973076.03 N 614416.64 E 3.388 8395.70 15962.97 91.360 274.640 8988.41 9053.71 6691.29 S 5175.97 W 5973082.08 N 614324.32 E 0.043 8449.83 16056.73 93.770 274.500 8984.22 9049.52 6683.83 S 5269.33 W 5973088.05 N 614230.85 E 2.575 8504.75 16150.01 95.380 275.600 8976.78 9042.08 6675.64 S 5361.94 W 5973094.76 N 614138.12 E 2.088 8558.64 16243.66 95.810 277.220 8967.65 9032.95 6665.24 S 5454.56 W 5973103.69 N 614045.34 E 1.782 8610.84 16335.25 95.630 277.280 8958.52 9023.82 6653.74 S 5544.97 W 5973113.74 N 613954.77 E 0.207 8660.76 16428.99 95.000 277.810 8949.83 9015.13 6641 .48 S 5637.50 W 5973124.52 N 613862.06 E 0.877 8711.50 16522.22 94.200 278.890 8942.36 9007.66 6627.99 S 5729.44 W 5973136.55 N 613769.91 E 1 .439 8760.90 16615.41 94.450 280.050 8935.33 9000.63 6612.70 S 5821.09 W 5973150.38 N 613678.02 E 1.270 8808.76 16633.21 94.390 278.990 8933.96 8999.26 6609.76 S 5838.60 W 5973153.03 N 613660.47 E 5.947 8817.89 16700.00 94.390 278.990 8928.85 8994.15 6599.36 S 5904.37 W 5973162.39 N 613594.54 E 0.000 8852.67 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 220.470° (True). . Magnetic Declination at Surface is 25.315° (28-Nov-03) Based upon Minimum Curvature type calculations, at a Measured Depth of 16700.00ft., The Bottom Hole Displacement is 8855.12ft., in the Direction of 221.819° (True). 30 December, 2003 - 10:19 Page 50f6 DriflQuest 3.03.05.005 Halliburton Sperry-Sun Survey Report for PBU_WOA S Pad - S-27B MWD Your Ref: API 500292205702 Job No. AKMW2796082, Surveyed: 14 December, 2003 BPXA North Slope Alaska Comments Measured Depth (ft) Station Coordinates TVD Northings Eastings (ft) (ft) (ft) Comment 9957.97 9973.00 16700.00 8253.98 8265.09 8994.15 4211.97 S 4221.20 S 6599.36 S 1257.15 W 1261.30 W 5904.37 W Tie On Point Window Point Projected Survey . Survey tool program for S-27B MWD From Measured Vertical Depth Depth (ft) (ft) To Measured Vertical Depth Depth Survey Tool Description (ft) (ft) 0.00 9955.97 0.00 9955.97 8252.50 16700.00 8252.50 BP High Accuracy Gyro (S-27) 8994.15 MWD Magnetic (S-27B MWD) . 30 December, 2003 - 10:19 Page 60f6 DrillQuest 3.03.05.005 -- . ~~!Æ ~ E mJ !..~:~!::~ / ffiAAKH.MURKO~KI.GO~RNOR CONSERVATION COMMISSION / 333 W. 7'" AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 William Isaacson Senior Drilling Engineer BP Exploration (Alaska), Inc. PO Box 196612 Anchorage AK 99501 Re: Prudhoe Bay Unit S-27B BP Exploration (Alaska), Inc. Permit No: 203-168 Surface Location: 1633' SNL, 4048' WEL, Sec. 35, TI2N, RI2E, UM Bottomhole Location: 3090' SNL, 4522' WEL, Sec. 03, TllN, RI2E, UM Dear Mr. Isaacson: Enclosed is the approved application for permit to redrill the above development well. This permit to redrill does not exempt you from obtaining additional permits or approvals required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. 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, R.c-eI) ~ ~ Randy Ruedrich Commissioner BY ORDER OF THE COMMISSION DATED this 08 day of October, 2003 cc: Department ofFish & Game, Habitat Section wlo encl. Department of Environmental Conservation wlo encl. Exploration, Production and Refineries Section ~ (o,!\- \ 1) lì {7..00"5 o Drill II Redrill 1 a. Type of work 0 Re-Entry 2. Operator Name: BP Exploration (Alaska) Inc. 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 4a. Location of Well (Governmental Section): Surface: 1633' SNL, 4048' WEL, SEC. 35, T12N, R12E, UM Top of Productive Horizon: 1494' SNL, 663' WEL, SEC. 03, T11N, R12E, UM Total Depth: 3090' SNL, 4522' WEL, SEC. 03, T11 N, R12E, UM 4b. Location of Well (State Base Plane Coordinates): Surface: X-619393 y-5979855 Zone-ASP4 16. Deviated Wells: Kickoff Depth 18. Casing Program Size Casing 7" _ STATE OF ALASKA . ALASKA O"'AND GAS CONSERVATION COM . SION PERMIT TO DRILL 20 MC 25.005 1b. Current Well Class 0 Exploratory o Stratigraphic Test 0 Service 5. Bond: 1m Blanket 0 Single Well Bond No. 2S100302630-277 6. Proposed Depth: MD 16445 TVD 9009 7. Property Designation: ADL 028261 II Development Oil 0 Multiple Zone o Development Gas 0 Single Zone 11. Well Name and Number; PBU 5-27B "-. 12. Field / Pool(s): Prudhoe Bay Field / Prudhoe Bay Pool 9. Acres in Property: 2560 13. Approximate Spud Date: 11/10/03 14. Distance to Nearest Property: 11800' 8. Land Use Permit: 10. KB Elevation Plan KBE 15. Distance to Nearest Well Within Pool (Height above GL): = 64' feet S-29A is 500' away 17. Anticipated pressure (see 20 AAC 25.035) ,/ 10000 ft Maximum Hole Angle 960 Max. Downhole Pressure: 3500 psig. Max. Surface Pressure: 2600 psig Settjngi()åpth· Qu~ntityof Cement Top..··.i..>.. Bottom (c;f¡or sacks) MD TVD MD TVD ~r cluding stage data) 9850' 8174' 10775' 8764' 241 cu 'p.r:- ." 10625' 8674' 16445' 9009' 795cuftC ~îl\tt:D UCT 0 (; 200J 'i~1 D~~;~~D (ft) ~~:~::::~j':~~\î~)¡Tr~~r~:~I~:~~~~ . size . w~~n~\(()I¡m!!l Hole 8-1/2" 6-1/8" 4-1/2" Weight 26# 12.6# Grade L-80 L-80 Coupling Length BTC-M 925' IBT-M 5820' Structural Conductor 110' 20" 110' 110' Surface 2689' 13-3/8" 3296 cu ft Arcticset III & II 2689' 2689' Intermediate 10635 ' 9-5/8" 2393 cu ft Class 'G' 10635' 8745' Production Liner 286' 7" 280 cu ft Class 'G' 10363' - 10649' 8548' - 8755' Liner 810' 2-7/8" 39 cu ft Class 'G' 10410' - 11220' 8582' - 8917' 20. Attachments 1m Filing Fee 0 BOP Sketch o Property Plat 0 Diverter Sketch IPerfOration Depth TVD (ft): 8897' - 8912' 1m Drilling Program 0 Time vs Depth Plot 0 Shallow Hazard Analysis o Seabed Report 1m Drilling Fluid Program 1m 20 AAC 25.050 Requirements Date: Perforation Depth MD (ft): 10920' - 11140' 21. Verbal Approval: Commission Representative: 22. I hereby certify that the foregoing is true and correct to the best of my knowledge. Printed Name Bill Isaacson Title Senior Drilling Engineer Signature 1 J.j~. 1. ~ AH Contact Phil Smith, 564-4897 Permit To Drill I API Number: Number: 20.~ - /¡:::;If 50-029-22057-02-00 Conditions of Approval: Samples Required Hydrogen Sulfide Measures Other: Test- gaPE to SSoo ,')Ç.¡. Phone 564-5521 Commission Use Only I Permit Approv¡1 I I See cover letter for Date: I () / ~ D'S other requirements Mud Log Required - D Yes ~No Directional Survey Required 18'1 Yes D No Date 10/ e) 03 Prepared By Name/Number: Terrie Hubble, 564-4628 DYes ~ No ~Yes D No Approved By: ~ Form 10-401 Revised 3/2003 tf:---~~o(r I¡~.\tSSI.ONER KrGth3AI BY ORDER OF THE COMMISSION I f),/ C> 8.03 Date 7' 7 .... Submit In Duplicate e e I Well Name: 18-278 Drill and Complete Plan Summary I Type of Well (service I producer I injector): 1 Horizontal Sidetrack Producer Surface Location: x = 619,393.3 Y = 5,979,855.7 1635' FNL 1231' FWL Sec. 35, T12N, R12E Umiat .,/ X = 617,588.0 Y = 5,974,688.0 TVDss 8942' . 1494'FNL 663'FEL Sec.3,T11N,R12E Umiat ",.... X = 613,757.0 Y = 5,973,033.0 TVDss 8945' ,/ 3090' FNL 758' FWL Sec. 3, T11 N, R12E Umiat Target Location: Ivishak Zone 4A148 Bottom Hole Location: l AFE Number: I PBD4P2148 1 I Rig: I Nabors 2ES / 1 Estimated Start Date: 111/10/2003 1 ,. I Operating days to complete: 126.7 I MD: 116,445' 1 I TVD: 19,009' 1 I GL: 135.5' 1 I KB: 128.5' 1 I KBE: 164.0' I Well Design (conventional, slim hole, etc.): 1 Two String Horizontal Sidetrack I Objective: 1 Ivishak Zone 4A/4B Formation Markers Formation Tops (wp06) TVDss TVD MD Comments TJ -7540 7604 JF -7680 7644 JE -7910 7974 JD -8100 8164 9837 JC -8410 8474 10,293 JB -8535 8600 10,501 JA -8620 8684 10,642 SAG RIVER -8700 8764 10,775 Casing Point SHUBLIK -8740 8804 10,841 TOP SADLEROCHIT -8840 8904 11,008 3350 psi @ 8800 TZ43SB DL -8920 8984 11 ,195 1 ST TROUGH -9015 9079 12,532 TSAD INVERT -8919 8983 14,512 TSAD AT TD -8945 9009 16,445 HOT -8990 9054 12,313 TD Criteria: The TD criteria of 2000' cross-cut in Zone 4 is primary. Secondary is 1000' into main fault block west of S-29A for efficient sweep of hydrocarbons. Well should be drilled to TD depth unless extreme circumstances prohibit. \ \, "1- S-27B Permit to Drill Page 1 e Directional - Sperry wp06 KOP: 110,000' MD Maximum Hole Angle: e Close Approach Wells: Survey Program: Nearest Property Line: Nearest Well within Pool: -53.0° in the 8-1/2" intermediate section (at section TD; 43° at KOP) _960 in the 6-1/8" horizontal section All wells pass major risk criteria MWD Standard North 11,800' to the nearest PBU property line S-29A is 500' away from planned well S-27B ,/ CasingfTubing Program Hole Size CsgfTbg Wt/Ft Grade Co,," Length Top Btm O.D. / MDITVD MDITVD 8-1/2" 7" 26# L-80 BTC-M 925' 9850'/8,174' 10,775'/8,764' 6-1/8" 4 Y2" 12.6# L-80 IBT-M 5820' 10,625'/8,674' 16,445'/9,009' Tubing 4 Y2" 12.6# 13Cr-80 Vam Ace -10,600' GL 3000'/3000' Tubing 3 Y2" 9.2# 13Cr-80 Vam Ace -7600' 3000'/3000' 10,625'/8,674' Mud Program Section Millin¡ Mud Properties: LSND Density (ppg) Viscosity I PV 11.2 50 - 65 15-25 Intermediate Mud Properties: LSND Der).Sity\PP.¡g) I Viscosity I PV L~) 45 - 55 12-15 Production Mud Properties: FloPro Density (ppg) I Viscosity I PV 8.4 - 8.5 45-55 10 Logging Program 8-1/2" Intermediate: Sample Catchers - None Drilling: Dir/GR- Real time Open Hole: None Cased Hole: None I Whip Stock Window 9-5/8",47# I YP I TauO I APIFL 40+ 5-9 4-6 PH 9.0-9.5 1 8-1/2" hole section YP I TauO 22-28 3-7 I APIFL PH 5-6 9.0 YP MBT 30 <3 pH 9.0-9.5 I API FII 4-6 6-1/8" Production: Drilling: Open Hole: Cased Hole: Sample Catchers - over entire interval, samples described Dir/GRlRes/ABI - Real time None None S-27B Permit to Drill Page 2 e e Cement Program I Casing Size I 7" 26#, L-80 Intermediate Liner Basis: Lead: None Tail: Based on 80' shoe track, 775' of 7" X 8-1/2" open hole with 40% excess, 150' 7" X 9-5/8" lap, and 200' of 9-5/8" X 4" DP excess. ./ Tail TOC:~MD-(Top of Linor) Lu6k I Total Cement Volume: ?er£0l'spacer 125 bbls MudPuS~12.2 ppg r¡ Tail 43 bbls, 241 ft3e8þacks Class G @ 15.8 ppg,~J18/sack I Casing Size I 4.5" 12.6#, L-80 Production Liner Basis: Lead: None Tail: Based on 80' shoe track, 5670' of 4-1/2" X 6-1/8" open hole with 40% excess, 150' 4-1/2" X 7" Liner Lap, and 200' of 7" X 4" DP exceS$. Tail TOC: 10,625' MD (Top of Liner) .,/ I Total Cement Volume: Preflush 15 bbls CW-100 Spacer 25 bbls MudPush a~ ppg Tail 142 bbls, 795 ft3~sacks Class G @ 15.8 ppg@/sack Well Control Well control equipment consisting of 5000 psi working pressure pipe rams(2), blind/shear rams, and annular preventer will be installed and is capable of handling maximum potential surface pressures. Diverter, BOPE and drilling fluid system schematics on file with the AOGCC. Intermediate Interval Maximum anticipated BHP Maximum surface pressure Kick tolerance Planned BOP test pressure 9-5/8" Casing Test Integrity Test - 8-1/2" hole Production Interval Maximum anticipated BHP Maximum surface pressure Kick tolerance Planned BOP test pressure 9-5/8" Casing/7" Liner Test Integrity Test - 6-1/8" hole Planned completion fluids 3500 psi @ 8400' TVDss (8.0 ppg EMW) 2600 psi (.10 psi/ft gas gradient to surface) Infinite with a 12.5 ppg FIT /" Rams test to 3,500 psi/250 psi. ./ Annular test to 2,500 psi/250 psi 3500 psi surface pressure 12.5 ppg FIT after drilling 20' from middle of window 3350 psi @ 8800' TVDss (7.3 ppg EMW) 2470 psi (.10 psi/ft gas gradient to surface) Infinite with a 10.5 ppg FIT Rams test to 3,500 psi/250 psi. /' Annular test to 2,500 psi/250 psi 3500 psi surface pressure 10.0 ppg FIT after drilling 20' from middle of window 8.4 ppg Seawater / 7.2 ppg Diesel Disposal . No annular injection in this well. · Cuttings Handling: Cuttings generated from drilling operations will be hauled to grind and inject at DS-04. Any metal cuttings will be sent to the North Slope Borough. · Fluid Handling: Haul all drilling and completion fluids and other Class II wastes to DS-04 for injection. Haul all Class I wastes to Pad 3 for disposal. S-27B Permit to Drill Page 3 tit e Pre-Riq Operations: 1. Pull the SSSV. Drift the tubing and 2 7/8" liner to maximum hole angle (±10,900'MD). 2. Replace any live GLVs with dummy GLVs. 3. Load the OA and IA and perform MITIA. Bleed both IA and OA to zero. 4. Function tubing hanger and casing lock-down screws. Remove one 9 5/8" packoff LOS and flush out any plastic packing in the void. Retest packoff. 5. P&A the liner and perforations with cement. 6. Chemical cut the tubing. 7. Circulate to seawater and freeze protect. Bleed well pressures to zero. 8. Set a BPV. Remove wellhouse and flow lines. Complete handover to 2ES. Riq Operations: 1. MIRU Nabors 2ES 2. Circulate out freeze protection and displace well to seawater. Set TWC. 3. Nipple down tree. Nipple up and test BOPE to 3,500psi. ./ 4. Pull 4 W' tubing from the cut. 5. M/U 8 W' milling BHA. RIH and drift down to the remaining tubing stump. Change the well over to 11.2 ppg LSND milling/drilling fluid. 6. RIH with 9-5/8" bridge plug on wireline and set at 10,030 MD. Test 9-5/8" casing back to surface to ,/ verify integrity. 7. Replace and test the 9 5/8" mandrel hanger packoff to 5000 psi. 8. RIH with 9-5/8" Baker bottom trip whipstock assembly. Orient whipstock and set on bridge plug. 9. Mill window in 9-5/8", 47# casing at 10,000' MD. Drill 20' past middle of window. Perform FIT to 12.5 ppg EMW. POOH 10. MU 8-1/2" drilling assembly with Dir/GR and RIH. Kick off and drill the 8-1/2" intermediate interval to top Sag River at an estimated depth of 10,775' MD. Drop ESS, POH. 11. Run and cement a 7" drilling liner throughout the 8-1/2" hole and back into the 9-5/8" casing to 9,850' MD. Displace cement with mud. POOH. 12. MU 6-1/8" BHA with Dir/GR/Res/ABI and RIH. 13. Drill the shoe tract and swap the well over to 8.4 ppg Drill-In fluid. Drill 20' new formation and perform FIT to 10.0 ppg. 14. Drill the 6-1/8" production interval building at 10°1100' to horizontal, targeting Z4A/B Ivishak. 15. Pick up PDC, drill ahead to an estimated TO of 16,445' MD. / 16. Run and cement a 4 W', 12.6#, L-80 production liner. POOH. 17. Test the 9 5/8" X 7" X 4 W' liner to 3,500psi for 30 minutes. 18. R/U and RIH with Schlumberger DPC perforating guns. Perforate ±1000' at hydrostatic overbalance. Circulate well to seawater, POOH. 19. Run a 4 1/2" x 3 W' 13-Cr completion, locating into the 4 W' liner top. 20. Set the 7" production packer, test the tubing and annulus to 3,500psi for 30 minutes. 21. Nipple down the BOPE. Nipple up and test the tree to 5,000psi. 22. Freeze protect the well to -2,100' and secure the well. 23. Rig down and move off. .,/ /' / / Post-Riq Work: 1. MIRU slickline. Pull the ball and rod I RHC plug from landing nipple below the production packer. Install gas lift valves. 2. Install well house and instrumentation. S-27B Permit to Drill Page 4 e e 8-278 Drilling Program Job 1: MIRU Hazards and Contingencies ~ S-27 is positioned in the center of the main E-W row of wells. No wells will require well house removal or shut-in for the rig move onto S-27. The closest neighboring wells are S-05 at 37' center to the west and S-28 at 37' to the east. ~ S-Pad is not designated as an H2S site. However, Standard Operating Procedures for H2S precautions should be followed at all times. Recent H2S data from the pad is as follows: #1 Closest SHL #2 Closest SHL #1 Closest BHL #2 Closest BHL Well Name S-28B S-05A S-27 A S-02A H2S Reading 10 ppm 70 ppm No Data 10 ppm Date 4/3/2003 2/9/2003 4/9/2003 The maximum last-measurement H2S reading on S-pad is 70 ppm ~ Post Permit to Drill in the dog house and camp prior to spud Reference RP .:. "Drilling/Work-over Close Proximity Surface and Subsurface Wells Procedure" SOP ",^----~ ~"~--~--~< Job 2: De-complete Well Hazards and Contingencies ~ S-27A is currently Shut-in. Pre-Rig operations will include P&Aing the perforations in the 2-7/8" liner with cement. After the cement work and tubing cut, the wellbore will be fluid packed, pressure tested and freeze protected. ~ The 9 5/8" pack-off failed a 5000 psi pressure test on 9/19/03. All indications are that the tubing and the casing have integrity. The pack-off will be change out after setting and testing the bridge plug. ~ Note and record required PU weight to pull tubing at cut point. ~ NORM test all retrieved well head and completion equipment. ~ Verify the hanger type and connection. Be prepared with necessary equipment to remove. Reference RP .:. "De-completions" RP Job 4: Window Mill Hazards and Contingencies ~ Once milling is complete, make sure all BOP equipment is operable. Wash out BOP stack to remove any metal cuttings, which may have settled there. Reference RP .:. "Whipstock Sidetracks" RP S-27B Permit to Drill Page 5 e e Job 5: Drill 8-1/2" Intermediate Hole Hazards and Contingencies ~ The intermediate section will kick off in the Kingak shale package and TO at the top of Sag River. Since S-27B will be at _530 inclination, maintain mud weight at minimum 11.2 ppg to interval TO. Follow all shale drilling practices to minimize potential problems. ~ There are no fault crossings in the intermediate section. Lost circulation is not anticipated. Follow the lost circulation decision tree should LC become problematic. ~ KICK TOLERANCE: In the worst-case scenario of 8.8 ppg pore pressure at the Sag River depth, a fracture gradient of 12.5 ppg at the 9-5/8" casing window, and 9.8 ppg mud in the hole, the kick tolerance is Infinite. Reference RP .:. "Shale Drilling, Kingak and HRZ" RP .:. "Prudhoe Bay Directional Guidelines" .:. "Lubricants for Torque and Drag Management" RP .:. "Standard Operating Procedure: Leak-off and Formation Integrity Tests" Job 6: Install 7" Intermediate Liner Hazards and Contingencies ~ Avoid high surge pressures with controlled running speeds and by breaking circulation slowly. High surge pressures could lead to losses to the Sag River or exacerbate Kingak instability problems. ~ Ensure the liner top packer is set prior to POOH. This may require going through the setting process twice. Slack off with rotation to the maximum allowable down weight, as per Baker representative. Reference RP .:. "Intermediate Casing Cementing Guidelines" RP .:. "Running and Cementing a Drilling Liner" RP Job 7: Drill 6-1/8" Production Hole Hazards and Contingencies ~ Five fault crossings have been identified for this hole section. The first will be crossed near the top of zone 4 (base Shublik) the latter four are planned to be crossed in the HOfT to minimze loss potential: Formation MD Intersect TVDSS Intersect Est. Throw Throw Direction Uncertainty Fault #1 - Z4B 11365' - 8942' 80' U/D SW +1- 170' Fault #2 - Z4B/HOT 12490' - 9013' 25' UID S +1- 170' Fault #3 - Z4B/HOT 13200' - 8996' 25-30' DIU NE +1- 200' Fault #4 - Z4B/HOT 13680' - 8981 ' 40' DIU NNE +1- 200' Fault #5 - Z4B/HOT 15500' - 8998' 20' U/D W +1- 170' S-27B Permit to Drill Page 6 e e ~ Original well S-27 A had losses associated with fault crossings. The first fault at 11 ,300'MD initially lost 700-bbls of fluid and had lost circulation of 40bbls/hr on average. The S-27A fault crossing is north of a large NW trending fault; it was not mapped in the S-27A well plan. Faults at the end of the well plan are newly mapped and have unknown characteristics. ~ All polygon lines should be considered hard lines - there are either adjacent faults, or the polygon is constrained to cross a fault at the most optimal location. ~ Be prepared with LCM products as per LCM decision tree and try to cross fault on first BHA. All drilling BHAs should include a circulation sub to help place LCM if required. ~ KICK TOLERANCE: In the worst-case scenario of 8.3 ppg pore pressure in the Ivishak, a fracture gradient of 9.5 ppg at the 7" casing window, and 8.5 ppg mud in the hole, the kick tolerance is Infinite. / Reference RP .:. "Standard Operating Procedure: Leak-off and Formation Integrity Tests" .:. "Prudhoe Bay Directional Guidelines" .:. "Lubricants for Torque and Drag Management" RP Job 9: Install 4-1/2" Solid Production Liner Hazards and Contingencies ~ Differential sticking is a concern. The 8.5 ppg mud will be -500psi over balanced to the Ivishak formation. Minimize the time the pipe is left stationary while running the liner. ~ Reduce losses as much as feasible prior to cement job and pump excess cement as per loss rate. Evaluate alternative cement options based upon conditions. Hydraulic set packer may be required if losses exist prior to running liner. ~ Ensure the liner top packer is set prior to POOH. Slack off with rotation to the maximum allowable down weight, as per Baker representative. ~ Sufficient 4-1/2" liner will need to be run to extend -150' back up into the 7" intermediate liner. Þ- Condition mud after casing is on bottom prior to pumping cement. A quality cement job is required for zonal isolation. Reference RPs .:. "Production Liner/Casing and Cementing Guidelines" .:. Schlumberger Cement Program Job 10: DPC Perforate Production Casinq Hazards and Contingencies ~ Observe Schlumberger's safety procedures while running in and out of hole with perf guns. Confirm all parties understand their responsibilities during pre-job safety meetings. Reference RPs .:. Follow Halliburton perforating practices and recommendations. .:. "DPC Perforating" RP ,.""""""^-- S-27B Permit to Drill Page 7 e e Job 12: Run Completion Hazards and Contingencies ~ Diesel will be used to freeze protect the well. The diesel flash point is 1000 F. Diesel vapor pressure is - 0.1 psia at 1000 F. Reference RP .:. "Completion Design and Running" RP .:. "Tubing connections" RP À._ Job 13: ND/NUlRelease Riq Hazards and Contingencies ~ No wells will require shut-in for the rig move off of 8-278, though offset wells are at 37' centers. Use spotters while moving the rig. Reference RP .:. "Freeze Protecting an Inner Annulus" RP 8-278 Permit to Drill Page 8 TREE = 4" erN WELLHEAD = FMC ACTUATOR = OTIS KB. Elèi~~' """'" '~'···~·~·~"56.04' BF. ELEV = 28.36' .. ,.. m~w...,...,.M~~~.~~mm_UM__'U.. m...' KOP= 3182' M~.o"_,"m~.~" Max Angle = 90 @ 11023' ~,.,,~.,..M...~U~U w " u, ."",,,....__........ Datum MD = 10838' Datum TVD = 880iTss e 5-27 A ./ ~Y NOTES: 3" FLOWLINE IN SKID PORTIONS _HIS Wa.L '5 FLOWLINE ARE 3" AND SUBJUCT . 70· @ 10887' AND 90· @ 11023' . 2122' 1-14-1/2" OTIS SSSV NIP, ID = 3.813" I 113-3/8" CSG, 68#, NT-80, ID= 12.415" -i 2689' ~ ~ GAS LIFT MANDRELS ST MD TVD DEV TYÆ VLV LATCH PORT DATE L 5 3163 3104 8 CAMeO RK Minimum Ie = 2.372" @ 10410' 4 5659 5142 45 CAMeO RK TOP OF 2-7/8" LNR 3 8089 6865 43 CAMeO RK 2 10047 8263 43 CAMCO RK 1 10309 8454 44 CAMCO RK I 10338' -i4-1/2" PARKERSWS NIP, ID=3.813" ~ 10349' H BAKER TBG ANCHOR I r--: 10350' H 9-5/8" BARKER SB-3 PKR, ID = 3.99" 1 I TOP OF 7" LNR -i 10363' I 10402' -i4-1/2" PARKER SWS NIP, ID = 3.813" I I TOP OF 2-7/8" LNR -i 10410' 1 . 10423' H4-1/2" PARKERSWS NIP, ID = 3.813" 14-1/2" TBG, 12.6#, L-80 0.0152 bpf, ID = 3.958" -i 10434' I \. 10434' -i4-1/2" W/LEG 1 10448' -i ELMD TT LOGGED 11/17/95 1 19-518" CSG, 47#, NT-80-S NSCC, ID = 8.681" -i 10635' ~ I~ MILLOUT WINDOW 10649' - 10655' I PBTD -i 11190' 1 ~ 11635' ~ 11220' I~ 1# 2 WHIPSTOCK H 10644' 1 ~.. 17" LNR, 29#, L-80, TC-4S, 0.0371 bpf, ID = 6.184" -i 11315' -i3-3/4" HOLE 1 PERFORA TION SUMMARY REF LOG: ATLAS BHCS ON 07/26/90 ANGLEATTOPPERF: 74@ 10920' Note: Refer to Production DB for historical perf data SIZE SPF INTERV AL Opn/Sqz DATE 2" 4 10920 - 11140 0 11/95 12-718"LNR,6.16#,FL4S,.00579bpf,ID=2.372" -i 11220' I DATE 11/11/90 11/20/95 03/14/01 03/02/02 REV BY PAB SIS-MH RN/TP COMMENTS ORIGINAL COMPLETION SIDETRACK COMPLETION CONVERTED TO CANVAS CORRECTIONS DATE REV BY COMMENTS PRUDHOE BA Y UNIT WELL: S-27A PERMIT No: 195-1000 API No: 50-029-22057-01 SEe 35, T12N, T12E BP Exploration (Alaska) 8-278 .oposed Comple8>n (wp06) I -14-1/2" x 31/2", 13Cr80, VAM ACE L II 3000'MD I TREE = 4" erN WELLHEAD = FMC ACTUA TOR;;;~M~M··-ÕTîS KB. ELEV = 56.04' ~...m"","...._..m.'M.....mmm.. '" ".,,,.,.,~~ BF. ELEV = 28.36' m~"".'m.~__'m~M_M~m_@M " KOP= 3182' ...m...__.'.__.................·._ ,'" ______________.____________,__w.,__wu ..f'::1ax. An.~I¡:¡..~.90 @ 11023' Datum MD = 10838' Datum 1VD = 8800' SS . . 2689'~ ~ 13-3/8",68#, NT-80 \ 9850' 9-5/8" X 7" Liner Hanger and ZXP Liner Top Packer 7",29#, L-80 @ 11,635' / 1 0000' 10030' 10350' :8: 10363' I z 7" X 4-1/2" Premier Permanent Packer @10,550' 7" X 4-1/2" HMC Liner Hanger with ZXP Liner Top Packer andTBR @ 10600' ./ 7",26#, L-80, BTC-M @ 10,775' / 10410' 10434' 10635' .41 ~ 9-5/8", 47#, NT80S . 4-1/2", 12.6#, L-80, IBT-M @ 16,445'/ .. 2-7/8", 6.16# Liner @ 11,220' Date 9/2/03 Rev By Comments PGS Proposed Completion Design PRUDHOE BAY UNIT WELL: 5-27B API NO: Permit NO: GPB Rotary Drilling bp COMPANY DETAILS REFERENCE INFORMA nON SURVEY PROGRAM Plan: Plan S-27 B Wp 6 (S-27/Plan S-27B) SP Amoco Co-ordinate (NÆ) Reference: Well Centre: S-27, True North Vertical (1VD) Reference: 2ES@28.5+35.50GL64.00 Section (VS) Reference: User Defmed(-4238.62N,-1269.14E) Mea~a~uf~;::~:::1~ ~~¡~~~~ GL 64.00 Depth Fm Depth To Survey/Plan Tool Created By: Ken Allen Checked: Date: 9/4/2003 Calculation Method; Minimum Curvature Error System: ISCWSA Scan Method: Trav Cylinder North Error Surface: Elliptical + Casing Wamin~ Method; Rules Based 10000.00 16445.06 Planned: Plan S-27 B Wp 6 V30 MWD D,'" Reviewed; Date l I I I I " -I ;i' .I l l, , #~ ~# ;< -/~ ~ "' ~ "'~ --...J1 , /' "' -~ ., "" WELL DETAILS N=, +N!-S +E/·W Northing Easting ùúi""" Longitude Slot S-27 -1022.00 1457.61 5979855.69 619393.31 70"ZI'12.950N 149°01'49.739W 27 TARGET DETAILS N~ TVD +N/-S +EI·W Northing Easting S"pe S-278 T6.2 8983.00 -7268.28 -3949.97 5972526.00 615559.99 Point ~~l8 '?¡tto1y 8999.00 -5158.70 -1887.92 5974668.00 617587.99 Polygon 9006.00 -5158.70 -1887.92 5974668.00 617587.99 Point S-278 T9 WP 3 9009.00 -6732.56 -5744.82 5973033.00 613756.99 Point S-27BT2.l 9025.00 -5799.85 -2326.23 5974020.00 617159.99 Point 8-278T4.2 9044.00 -7136.48 -3182.71 5972670.00 616324.99 Point 8·27BT8WP3 9064.00 -6807.27 -4822.81 5972973.00 614679.99 Point 8-278 T3 WP 3 9079.00 -6130.15 -2562.54 5973686.00 616928.99 Point SECTION DETAILS Sec MD Inc Azi TVD +N/-S +E/-W DLeg TFace VSec Target 1 10000.00 42.54 204.18 8284.67 -4238.62 -1269.14 0.00 0.00 0.00 2 10020.00 44.94 204.18 8299.12 -4251.24 -1274.80 ...1-2.00 0.00 11.09 3 10209.06 52.97 214.83 8423.36 -4374.50 -1345.49 6.00 48.63 132.83 e 4 10984.81 52.97 214.83 8890.53 -4882.83 -1699.24 0.00 0.00 689.28 5 11344.28 88.91 214.00 9006.00 -5158.70 -1887.92 10.00 -1.42 988.38 S-27B Tl.l 6 11346.82 88.92 214.25 9006.05 -5160.80 -1889.35 10.00 87.20 990.65 7 12048.59 88.92 214.25 9019.25 -5740.75 -2284.28 0.00 0.00 1617.93 8 12121.34 82.00 216.50 9025.00 -5799.85 -2326.23 10.00 162.15 1683.34 S-27B T2.1 9 12128.64 81.27 216.44 9026.06 -5805.65 -2330.52 10.00 -175.56 1689.92 10 12423.18 81.27 216.44 9070.75 -6039.85 -2503.46 0.00 0.00 1954.98 11 12531.57 90.00 209.99 9079.00 ·6130.15 ·2562.54 10.00 -36.70 2050.55 S-27B T3 WP 3 12 12548.29 91.67 209.96 9078.76 -6144.63 -2570.90 10.00 -0.87 2064.89 13 13517.44 91.67 209.96 9050.48 -6983.88 -3054.75 0.00 0.00 2896.07 14 13717.71 92.00 230.00 9044.00 -7136.48 -3182.71 10.00 88.75 3082.13 S-27B T4.2 15 14083.80 95.83 266.50 9018.15 -7269.74 -3516.02 10.00 82.92 3438.15 16 14337.22 95.83 266.50 8992.43 -7285.1l -3767.66 0.00 0.00 3665.45 17 14521.34 90.00 284.00 8983.00 -7268.28 -3949.97 10.00 107.85 3816.51 S-27B T6.2 18 14758.46 84.22 302.10 8995.05 -7176.07 -4166.92 8.00 108.05 3961.15 19 15286.58 84.22 302.10 9048.23 -6896.87 -4612.04 0.00 0.00 4214.07 20 15517.14 88.00 284.00 9064.00 -6807.27 -4822.81 8.00 -78.90 4354.57 S-27B T8 WP 3 21 15719.28 94.06 273.49 9060.36 -6776.59 -5022.19 6.00 -60.03 4513.81 22 16445.06 94.06 273.49 9009.00 -6732.56 -5744.82 0.00 0.00 5123.61 S-27B T9 WP 3 Start Dir 6/100' : 10020' MD, 8299. 12'TVD End Dir : 10209.06' MD, 8423.36' TVD FORMATION TOP DETAILS No. TVDPath MDPath F onnation 1 8164.00 9837.28 TJD 2 8474.00 10293.14 TIC 3 8599.00 10500.71 TJB 4 8684.00 10641.86 TJA 5 8764.00 10774.70 TSag 6 8804.00 10841.12 TShu 7 8904.00 11007.79 TSad e 8 8984.00 11195.50 TZ43SB SL 9 9054.00 12312.77 HOT 8400 All TVD depths are ssTVD plus 64'for RKBE. CASING DETAILS No. TVD MD Name Size 1 8764.00 10774.70 7" 7.000 2 9009.00 16445.05 4112" 4.500 .¡; " " o Start Dir 10/100" 10984.81' MD, 8890.53'TVD ¿End DIf 1134682' MD, 9006.05' TVD 7" I Start DIf 10/100' 1204859' MD, 9019 25'TVD End DIf . 12128.64' MD, 9026 06' TVD .1'- II Start DIf 10/100': 12423.18' MD, 9070 75'TVD ."i"~ : . . . f::.1DII 1:'''.1Q:''}'\fD ~""""Q""r,'T'.'D : .. t,'::: . . Ili'..·/·..···L. sr......·.. ::-.:i.:;o.,t"l I":' .".",,- Start Dir 8/100' : 15286.58' MD, 9048.23'TVD I Start Dir 6/100' : 15517.14'MD, 9064'TVD I fEnd Dir : 15719.28' MD, 9060.36' TVD , [,'1.11 rkpth: 16445.06'MD, 9009' TVD ~:¡.. ~I"" ~-:!7 B WI' 6 ~ d ~ o o t:. -¡;¡ <.) 1: >- ')1(,:; ~ f-< 1·1.... \ . _...............1".. 1!,·.,(:..... ... II:" o 700 1400 2100 2800 3500 Vertical Section at 240.87° [700ft/in] 4200 4900 I I I 5600 I I I I I I I , I ' 6300 bp COMPANY DETAILS REFERENCE INFORMATION SURVEY PROGRAM Plan: Plan S·27 B Wp 6 (S-27/Plan S-27B) SP Amoco Co-ordinate (NÆ) Reference: Well Centre: S-27, Tme North Depth Fm Depth To Stuvey/Plan Tool Vertical (TVD) Refeænce: 2ES@28.5 + 35.50 GL 64.00 Created By: Ken Allen Date: 9/4/2003 Calculation Method: Minimum Curvature Section (VS) Reference: User Defined (-4238.62N,-1269.l4E) 10000.00 16445.06 Planned: Plan S-27 B Wp 6 V30 MWD Checked: Date Error System: ISCWSA Measured Depth Reference: 2ES@28.5+35.50GL 64.00 Scan Method: Trov Cylinder North Calculation Method: Minimum Curvature Reviewed: Date Error Surface: Elliptical + Casing Wamjn~ Method: Rules Based FORMATION TOP DETAILS WELL DETAILS SECTION DETAILS N,= +N/-S +E/-W Northing Easting Latitude Longitude Slol See MD Ine Azi TVD +N/-S +E/-W DLeg TFaee VSee Target No. TVDPath MDPath Formation 5-27 -1022.00 1457.61 5979855.69 61939331 70021'12.950N 149°01'49.739W 27 1 10000.00 42.54 204.18 8284.67 -4238.62 -1269.14 0.00 0.00 0.00 1 8164.00 9837.28 TID TARGET DETAILS 2 10020.00 44.94 204.18 8299.12 -4251.24 -1274.80 12.00 0.00 11.Q9 2 8474.00 10293.14 TIC 3 10209.06 52.97 214.83 8423.36 -4374.50 -1345.49 6.00 48.63 132.83 3 8599.00 10500.71 TJB N~, lVD +N/-S +E!-W Northing Basting Shap" 4 10984.81 52.97 214.83 8890.53 -4882.83 -1699.24 0.00 0.00 689.28 4 8684.00 10641.86 TJA S-27BT6.2 8983.00 -7268.28 -3949.97 5972526.00 615559.99 Point 5 11344.28 88.91 214.00 9006.00 -5158.70 -1887.92 10.00 -1.42 988.38 S-27B T1.1 5 8764.00 ! 0774.70 TSag Wp 3 Goo-poly 8999.00 -5158.10 -1881.92 5914668.00 617587.99 Polygon S-27B Tl.1 9006.00 -5158.70 -1887.92 5974668.00 617581.99 Point 6 11346.82 88.92 214.25 9006.05 -5160.80 -1889.35 10.00 87.20 990.65 6 8804.00 10841.12 TShu S-21B T9 WP 3 9009.00 -6732.56 -5144.82 5913033.00 613156.99 Point 7 12048.59 88.92 214.25 9019.25 -5740.75 -2284.28 0.00 0.00 1617.93 7 8904.00 11007.79 TSad S-21BT2.1 9025.00 ·5799.85 -2326.23 5974020.00 617159.99 Point 8 12121.34 82.00 216.50 9025.00 -5799.85 -2326.23 10.00 162.15 1683.34 S-27B T2.! 8 8984.00 11195.50 TZ43SB SL S-21B T4.2 9044.00 ·7136.48 -3182.71 5972670.00 616324.99 Point S-278 T8 WP 3 9064.00 -6801.21 -4822.81 5972913.00 614619.99 Point 9 12128.64 81.27 216.44 9026.06 -5805.65 -2330.52 10.00 -175.56 1689.92 9 9054.00 12312.77 HOT 8-278 T3 WP 3 9079.00 -6130.15 -2562.54 5913686.00 616928.99 POÎnt 10 12423.18 81.27 216.44 9070.75 -6039.85 -2503.46 0.00 0.00 1954.98 11 12531.57 90.00 209.99 9079.00 -6130.15 -2562.54 10.00 ·36.70 2050.55 S-27B T3 WP 3 CASING DETAILS 12 12548.29 91.67 209.96 9078.76 -6144.63 -2570.90 10.00 -0.87 2064.89 13 13517.44 91.67 209.96 9050.48 -6983.88 -3054.75 0.00 0.00 2896.07 No. TVD MD Name Size 14 13717.71 92.00 230.00 9044.00 -7136.48 -3182.71 10.00 88.75 3082.13 S-27B T4.2 All TVD depths are 15 14083.80 95.83 266.50 9018.15 -7269.74 -3516.02 10.00 82.92 3438.15 8764.00 10774.70 7" 7.000 16 14337.22 95.83 266.50 8992.43 -7285.11 -3767.66 0.00 0.00 3665.45 9009.00 16445.05 4112" 4.500 ssTVD plus 64'for RKBE. 17 14521.34 90.00 284.00 8983.00 -7268.28 -3949.97 10.00 107.85 3816.51 S-27B T6.2 e 18 14758.46 84.22 302.10 8995.05 -7176.07 -4166.92 8.00 108.05 3961.15 19 15286.58 84.22 302.10 9048.23 -6896.87 -4612.04 0.00 0.00 4214.07 20 15517.14 88.00 284.00 9064.00 -6807.27 -4822.81 8.00 -78.90 4354.57 S-27B T8 WP 3 21 15719.28 94.06 273.49 9060.36 -6776.59 -5022.19 6.00 -60.03 4513.81 22 16445.06 94.06 273.49 9009.00 -6732.56 -5744.82 0.00 0.00 5123.61 S-27B T9 WP 3 -4500 Start Dir 121100' : 10000' MD, 8284.67'TVD Start Dir 6/100': 10020' MD, 8299.l2'TVD d Dir : 10209.06' MD, 8423.36' TVD ../ -7200 I I I .I I I ~ I ~ l ,I, ", " :< '/~ , " Iff ,~ "' " -~ ., ~, -27 (S-27 A) -5400 Æ ¢: 0 0 ~ +' :á t:: 0 ~ :á :; -ú:1.11, ... ..... 0 I '" I I I I I I I I I I I I I I I I I I I I I I L I I L I I I I I I I I I I I I I I I I -900 I I I I I I J I ·6300 -5400 ·4500 -3600 -2700 West(-)lEast(+) [900ft/in] -1800 e BP KW A Planning Report Com pan)': Hcld: SUc: \hll: W(~lIpalh: BP Amoco Prudhoe Bay PB 8 Pad S-27 Plan S-27B DUll': 9/4/2003 Timc: 10:54:00 I'a¡:c: Co-ordirmlc(:\E) I{cfcrcllcc: Well: S-27. True North \'l'rtical (T\'D) I{cfcrcllcc: 2ES @ 28.5 + 35.50 GL 64.0 SI'I·tiOIl (\'S) RcfcrCIlCI': User (-4238.62N.-1269.14E,240.87Azi) Sur\"C~' Calculalion \Iclhod: Minimum Curvature Dh: Oracle 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: Site: PB S Pad TR-12-12 UNITED STATES: North Slope Site Position: Northing: From: Map Easting: Position Uncertainty: 0.00 ft Ground Level: 0.00 ft 5980854.54 ft 617919.92 ft Latitude: 70 21 Longitude: 149 2 North Reference: Grid Convergence: e Alaska, Zone 4 Well Centre bggm2003 23.002 N 32.343 W True 0.90 deg Well: S-27 Slot Name: 27 S-27 Well Position: +N/-S -1022.00 ft Northing: 5979855.69 ft Latitude: 70 21 12.950 N +E/-W 1457.61 ft Easting : 619393.31 ft Longitude: 149 1 49.739 W Position Uncertainty: 0.00 ft Wellpath: Plan S-27B Drilled From: Tie-on Depth: 64.00 ft Above System Datum: Declination: Mag Dip Angle: +E/-W ft -1269.14 Current Datum: Magnetic Data: Field Strength: Vertical Section: 2ES @ 28.5 + 35.50 GL 6/19/2003 57552 nT Depth From (TVD) ft 28.50 Height +N/-S ft -4238.62 Plan: Plan 8-27 B Wp 6 Date Composed: Version: Tied-to: Principal: Yes Casing Points S-27 10000.00 ft Mean Sea Level 25.50 deg 80.85 deg Direction deg 240.87 8/29/2003 30 From: Definitive Path MD TVD Diamctcr Hole Size Name ,... ft ft in in ............................-.¥ 10774.70 8764.00 7.000 8.500 7" 16445.05 9009.00 4.500 6.125 41/2" Formations ...................--....--..... MD TVD :, Formations Lithology Dip Angle Dip Direction ft ft deg deg ----...--".- ·......_.·._·_·___·...__.·_._...w·.·_·_ 9837.28 8164.00 TJD 0.00 0.00 10293.14 8474.00 TJC 0.00 0.00 10500.71 8599.00 TJB 0.00 0.00 10641.86 8684.00 TJA 0.00 0.00 10774.70 8764.00 TSag 0.00 0.00 10841.12 8804.00 TShu 0.00 0.00 11007.79 8904.00 TSad 0.00 0.00 11195.50 8984.00 TZ43SB SL 0.00 0.00 12312.77 9054.00 HOT 0.00 0.00 Targets _Ah....._.___h._.._.__._......... Map Map <--- Latitude ---> <--- Longitll¡Je ---> ¡ Name Description TVI) +N/-S +E/-W Northing Easting De~ Min Sec Deg Min' Sec Dip. Dir. ft ft ft ft ft .....-.. ...---.---..-------..- S-27B T6.2 8983.00 -7268.28 -3949.97 5972526.00 615559.99 70 20 1.457 N 149 3 45.081 W Wp 3 Geo-poly 8999.00 -5158.70 -1887.92 5974668.00 617587.99 70 20 22.212 N 149 2 44.883 W -Polygon 1 8999.00 -4719.97 -1425.83 5975114.00 618042.99 70 20 26.528 N 149 231.388 W -Polygon 2 8999.00 -4542.93 -1489.02 5975290.00 617977.00 70 20 28.269 N 149 2 33.235 W -Polygon 3 8999.00 -5858.58 -2595.22 5973957.00 616891.99 70 20 15.327 N 149 3 5.536 W -Polygon 4 8999.00 -7121.09 -3332.49 5972683.01 616175.00 70 20 2.907 N 149 3 27.052 W e BP KW A Planning Report e Company: Field: Site: Well: Wellpath: Targets BP Amoco Prudhpe Bay PB S'Þad S-27/' PlanS-27B Date: 9/4/2003 Time: 10:54:00 Page: 2 Co-ordinate(NE) Reference: Well: S-27, True North' Vertical (fVDfReference:> 2ES @ 28.5+t:35.50 GL 64.0,·· Section (VS) Reference:, User (-423&{j2N,-1269.14E;Zi'l:O.87Azi) .. Surv¢y Calcuhîflon Methód: Minimum Curvature Db'; Oracle, Ma;p Map <-- LI~titude ---> <-":';;:,Longitude ~c*', Name Description TVD +N/-S +E/-W Northing Itášting Deg Miii'· 'Sec .. DegMin Sec Dip. Dir. ·ft ft ft ft ft .-..-. -Polygon 5 8999.00 -7159.37 -3692.18 5972639.00 615815.99 70 20 2.529 N 149 337.555 W -Polygon 6 8999.00 -6530.03 -5023.43 5973247.00 614475.00 70 20 8.711 N 149 4 16.442 W -Polygon 7 8999.00 -6545.90 -5909.87 5973217.00 613589.00 70 20 8.549 N 149 4 42.329 W -Polygon 8 8999.00 -6845.65 -5929.65 5972917.00 613574.00 70 20 5.600 N 149 4 42.900 W -Polygon 9 8999.00 -6864.22 -4764.70 5972917.00 614739.00 70 20 5.426 N 149 4 8.880 W -Polygon 10 8999.00 -7586.33 -4014.05 5972207.00 615500.99 70 19 58.328 N 149 3 46.948 W -Polygon 11 8999.00 -7613.46 -3253.32 5972192.00 616262.00 70 19 58.065 N 149 3 24.734 W -Polygon 12 8999.00 -6769.92 -2836.79 5973042.00 616665.00 70 20 6.363 N 149 3 12.581 W 8-27B T1.1 9006.00 -5158.70 -1887.92 5974668.00 617587.99 70 20 22.212 N 149 2 44.883 W 8-27B T9 WP 3 9009.00 -6732.56 -5744.82 5973033.00 613756.99 70 20 6.714 N 149 437.505 W S-27B T2.1 9025.00 -5799.85 -2326.23 5974020.00 617159.99 70 20 15.905 N 149 2 57.680 W S-27B T4.2 9044.00 -7136.48 -3182.71 5972670.00 616324.99 70 20 2.757 N 149 3 22.678 W S-27B T8 WP 3 9064.00 -6807.27 -4822.81 5972973.00 614679.99 70 20 5.986 N 149 4 10.578 W 8-27B T3 WP 3 9079.00 -6130.15 -2562.54 5973686.00 616928.99 70 20 12.656 N 149 3 4.579 W Plan Section Information ........................-.. .........................A.~_..... ...._.... MD Incl Azim TVD +N/-S +E/-W DLS 8uild Turn TFO Target ft deg deg ft ft ft . .. . deg/1 000 deg/100ft deg/100ft deg '.. .-..--------... 10000.00 42.54 204.18 8284.67 -4238.62 -1269.14 0.00 0.00 0.00 0.00 10020.00 44.94 204.18 8299.12 -4251.24 -1274.80 12.00 12.00 0.00 0.00 10209.06 52.97 214.83 8423.36 -4374.50 -1345.49 6.00 4.25 5.64 48.63 10984.81 52.97 214.83 8890.53 -4882.83 -1699.24 0.00 0.00 0.00 0.00 11344.28 88.91 214.00 9006.00 -5158.70 -1887.92 10.00 10.00 -0.23 -1.42 S-27B T1.1 11346.82 88.92 214.25 9006.05 -5160.80 -1889.35 10.00 0.49 9.99 87.20 12048.59 88.92 214.25 9019.25 -5740.75 -2284.28 0.00 0.00 0.00 0.00 12121.34 82.00 216.50 9025.00 -5799.85 -2326.23 10.00 -9.52 3.09 162.15 S-27B T2.1 12128.64 81.27 216.44 9026.06 -5805.65 -2330.52 10.00 -9.97 -0.78 -175.56 12423.18 81.27 216.44 9070.75 -6039.85 -2503.46 0.00 0.00 0.00 0.00 12531.57 90.00 209.99 9079.00 -6130.15 -2562.54 10.00 8.05 -5.95 -36.70 8-27B T3 WP 3 12548.29 91.67 209.96 9078.76 -6144.63 -2570.90 10.00 10.00 -0.15 -0.87 13517.44 91.67 209.96 9050.48 -6983.88 -3054.75 0.00 0.00 0.00 0.00 13717.71 92.00 230.00 9044.00 -7136.48 -3182.71 10.00 0.16 10.00 88.75 S-27B T4.2 14083.80 95.83 266.50 9018.15 -7269.74 -3516.02 10.00 1.04 9.97 82.92 14337.22 95.83 266.50 8992.43 -7285.11 -3767.66 0.00 0.00 0.00 0.00 14521.34 90.00 284.00 8983.00 -7268.28 -3949.97 10.00 -3.16 9.50 107.85 S-27B T6.2 14758.46 84.22 302.10 8995.05 -7176.07 -4166.92 8.00 -2.44 7.63 108.05 15286.58 84.22 302.10 9048.23 -6896.87 -4612.04 0.00 0.00 0.00 0.00 15517.14 88.00 284.00 9064.00 -6807.27 -4822.81 8.00 1.64 -7.85 -78.90 S-27B T8 WP 3 15719.28 94.06 273.49 9060.36 -6776.59 -5022.19 6.00 3.00 -5.20 -60.03 16445.06 94.06 273.49 9009.00 -6732.56 -5744.82 0.00 0.00 0.00 0.00 S-27B T9 WP 3 e BP e KW A Planning Report -~.~~----"-'-'-'- Company: BP Amoco Date: 9/4/2003 Time: 10:54:00 Page: 3 Field: Prudhoe Bay Co-ordinâte(NEJl~,eference: Well: S-27, True North", Site: PB S<P¡.¡d . Vertical (TVD) Ileference: .... 2ES @ 2Ø~~F+35.'50 GL 64,0 Well: S-27.>" Section (VS) Reference: User (-42~Ø.62N,-1269': 14E,240.87 Azi) Wellpath: Plan Sc2713 Survey ,çalculation 'Metho!l: MinimuirtCurvature Db: Oracle,. Survey ¡yID . Incl Azim TVD·" Sys TVD MapN MapE VS DLS TFO Too .."'!.! deg deg . ft' ft ft. ft ft deg/1 OOft deg - ...........~..._..._.....-_... 9837.28 41.92 204.09 8164.00 8100.00 5975698.04 618235.04 -87.49 0.00 0.00 TJD 10000.00 42.54 204.18 8284.67 8220.67 5975597.74 618191.99 0.00 0.38 5.62 MWD 10020.00 44.94 204.18 8299.12 8235.12 5975585.04 618186.52 11.09 12.00 360.00 MWD 10050.00 46.14 206.05 8320.13 8256.13 5975565.51 618177.74 28.46 6.00 48.63 MWD 10100.00 48.22 209.01 8354.12 8290.12 5975532.74 618161.30 59.10 6.00 47.31 MWD 10150.00 50.36 211.78 8386.73 8322.73 5975499.77 618142.64 91.76 6.00 45.30 MWD 10200.00 52.57 214.38 8417.88 8353.88 5975466.68 618121.82 126.36 6.00 43.50 MWD 10209.06 52.97 214.83 8423.36 8359.36 5975460.68 618117.82 132.83 6.00 41.88 MWD 10293.14 52.97 214.83 8474.00 8410.00 5975404.98 618080.36 193.14 0.00 0.00 TJC 10300.00 52.97 214.83 8478.13 8414.13 5975400.44 618077.30 198.06 0.00 0.00 MWD 10400.00 52.97 214.83 8538.35 8474.35 5975334.20 618032.76 269.79 0.00 0.00 MWD 10500.00 52.97 214.83 8598.57 8534.57 5975267.96 617988.21 341.52 0.00 0.00 MWD 10500.71 52.97 214.83 8599.00 8535.00 5975267.49 617987.89 342.03 0.00 0.00 TJB 10600.00 52.97 214.83 8658.79 8594.79 5975201.71 617943.66 413.26 0.00 0.00 MWD 10641.86 52.97 214.83 8684.00 8620.00 5975173.99 617925.01 443.28 0.00 0.00 TJA 10700.00 52.97 214.83 8719.01 8655.01 5975135.47 617899.11 484.99 0.00 0.00 MWD 10774.70 52.97 214.83 8764.00 8700.00 5975085.99 617865.84 538.57 0.00 0.00 TSag 10800.00 52.97 214.83 8779.24 8715.24 5975069.23 617854.57 556.72 0.00 0.00 MWD 10841.12 52.97 214.83 8804.00 8740.00 5975041.99 617836.25 586.21 0.00 0.00 TShu 10900.00 52.97 214.83 8839.46 8775.46 5975002.99 617810.02 628.45 0.00 0.00 MWD 10984.81 52.97 214.83 8890.53 8826.53 5974946.81 617772.24 689.28 0.00 0.00 MWD 11000.00 54.49 214.79 8899.52 8835.52 5974936.65 617765.41 700.28 10.00 358.58 MWD 11007.79 55.27 214.77 8904.00 8840.00 5974931.35 617761.85 706.01 10.00 358.61 TSad 11050.00 59.49 214.65 8926.75 8862.75 5974901.82 617742.09 737.91 10.00 358.62 MWD 11100.00 64.49 214.52 8950.22 8886.22 5974865.10 617717.63 777.4 7 10.00 358.68 MWD 11150.00 69.49 214.40 8969.76 8905.76 5974826.76 617692.21 818.67 10.00 358.74 MWD 11195.50 74.03 214.30 8984.00 8920.00 5974790.71 617668.40 857.33 10.00 358.79 TZ43SB SL 11200.00 74.49 214.29 8985.22 8921.22 5974787.09 617666.02 861.20 10.00 358.82 MWD 11250.00 79.48 214.19 8996.48 8932.48 5974746.41 617639.26 904.74 10.00 358.82 MWD 11300.00 84.48 214.09 9003.45 8939.45 5974705.01 617612.14 948.94 10.00 358.85 MWD 11344.28 88.91 214.00 9006.00 8942.00 5974668.00 617587.99 988.38 10.00 358.86 S-27B T1.1 11346.82 88.92 214.25 9006.05 8942.05 5974665.88 617586.60 990.65 10.00 87.20 MWD 11400.00 88.92 214.25 9007.05 8943.05 5974621.46 617557.38 1038.18 0.00 0.00 MWD 11500.00 88.92 214.25 9008.93 8944.93 5974537.94 617502.43 1127.57 0.00 0.00 MWD 11600.00 88.92 214.25 9010.81 8946.81 5974454.42 617447.49 1216.95 0.00 0.00 MWD 11700.00 88.92 214.25 9012.69 8948.69 5974370.90 617392.54 1306.34 0.00 0.00 MWD 11800.00 88.92 214.25 9014.57 8950.57 5974287.38 617337.59 1395.72 0.00 0.00 MWD 11900.00 88.92 214.25 9016.45 8952.45 5974203.86 617282.64 1485.11 0.00 0.00 MWD 12000.00 88.92 214.25 9018.33 8954.33 5974120.34 617227.70 1574.49 0.00 0.00 MWD 12048.59 88.92 214.25 9019.25 8955.25 5974079.75 617201.00 1617.93 0.00 0.00 MWD 12050.00 88.79 214.30 9019.27 8955.27 5974078.58 617200.22 1619.19 10.00 162.15 MWD 12100.00 84.03 215.84 9022.40 8958.40 5974037.30 617172.22 1664.10 10.00 162.15 MWD 12121.34 82.00 216.50 9025.00 8961.00 5974020.00 617159.99 1683.34 10.00 162.05 S-27B T2.1 12128.64 81.27 216.44 9026.06 8962.06 5974014.13 617155.80 1689.92 10.00 184.44 MWD 12200.00 81.27 216.44 9036.89 8972.89 5973956.73 617114.81 1754.13 0.00 0.00 MWD 12300.00 81.27 216.44 9052.06 8988.06 5973876.30 617057.37 1844.13 0.00 0.00 MWD 12312.77 81.27 216.44 9054.00 8990.00 5973866.03 617050.04 1855.62 0.00 0.00 HOT 12400.00 81.27 216.44 9067.24 9003.24 5973795.87 616999.94 1934.12 0.00 0.00 MWD 12423.18 81.27 216.44 9070.75 9006.75 5973777.22 616986.63 1954.98 0.00 0.00 MWD 12450.00 83.43 214.83 9074.32 9010.32 5973755.38 616971.49 1979.02 10.00 323.30 MWD 12500.00 87.45 211.86 9078.30 9014.30 5973713.33 616944.77 2023.20 10.00 323.51 MWD 12531.57 90.00 209.99 9079.00 9015.00 5973686.00 616928.99 2050.55 10.00 323.75 S-27B T3 WP 3 12548.29 91.67 209.96 9078.76 9014.76 5973671.39 616920.87 2064.89 10.00 359.13 MWD e BP e KW A Planning Report Com pall)': BP Amoco DIlle: 9/4/2003 Time: 10:54:00 I)~'~e: 4 Fil'ld: Prudhoe Bay (:o-ordimlll~(:'IiE) I{derellel~: Well: S-27, True North Sill': PB S Pad \'{'rtieal (T\'D) Referellel~: 2ES @ 28.5 + 35.50 GL 64.0 Well: S-27 Section (\'S) nefl'rellee: User (-4238.62N,-1269.14E,240.87Azi) Wellpath: Plan S-27B Slll"'e~' Calc Illation :\Iethod: Minimum Curvature nb: Oracle Survey '''~'__'_'''._R_''_'___ TFO Tool MD Ine! Azim TVn Sys TVD,'< i\1apN MåþE VS DLS I ft deg deg ft ft ft ft .. ... ft deg/10OO deg i .---.-.....-- .-- 12600.00 91.67 209.96 9077 .25 9013.25 5973626.21 616895.77 2109.24 0.00 0.00 MWD 12700.00 91.67 209.96 9074.33 9010.33 5973538.83 616847.24 2195.01 0.00 0.00 MWD 12800.00 91.67 209.96 9071.41 9007.41 5973451.46 616798.70 2280.77 0.00 0.00 MWD 12900.00 91.67 209.96 9068.50 9004.50 5973364.09 616750.17 2366.53 0.00 0.00 MWD 13000.00 91.67 209.96 9065.58 9001.58 5973276.71 616701.63 2452.29 0.00 0.00 MWD 13100.00 91.67 209.96 9062.66 8998.66 5973189.34 616653.10 2538.06 0.00 0.00 MWD 13200.00 91.67 209.96 9059.74 8995.74 5973101.97 616604.56 2623.82 0.00 0.00 MWD 13300.00 91.67 209.96 9056.83 8992.83 5973014.59 616556.03 2709.58 0.00 0.00 MWD 13400.00 91.67 209.96 9053.91 8989.91 5972927.22 616507.49 2795.35 0.00 0.00 MWD 13500.00 91.67 209.96 9050.99 8986.99 5972839.85 616458.96 2881.11 0.00 0.00 MWD 13517.44 91.67 209.96 9050.48 8986.48 5972824.61 616450.49 2896.07 0.00 0.00 MWD 13550.00 91.74 213.22 9049.51 8985.51 5972796.62 616433.89 2924.45 10.00 88.75 MWD 13600.00 91.83 218.22 9047.95 8983.95 5972755.61 616405.37 2969.67 10.00 88.84 MWD 13650.00 91.91 223.23 9046.32 8982.32 5972717.23 616373.39 3016.57 10.00 89.00 MWD 13700.00 91.98 228.23 9044.62 8980.62 5972681.80 616338.19 3064.79 10.00 89.16 MWD 13717.71 92.00 230.00 9044.00 8980.00 5972670.00 616324.99 3082.13 10.00 89.33 S-27B T4.2 13750.00 92.39 233.21 9042.76 8978.76 5972649.57 616300.03 3113.96 10.00 82.92 MWD 13800.00 92.99 238.18 9040.41 8976.41 5972620.77 616259.25 3163.69 10.00 83.04 MWD 13850.00 93.56 243.15 9037.55 8973.55 5972595.64 616216.14 3213.59 10.00 83.27 MWD 13900.00 94.11 248.13 9034.20 8970.20 5972574.35 616171.05 3263.29 10.00 83.56 MWD 13950.00 94.63 253.12 9030.39 8966.39 5972557.07 616124.31 3312.41 10.00 83.89 MWD 14000.00 95.11 258.12 9026.15 8962.15 5972543.93 616076.27 3360.57 10.00 84.27 MWD 14050.00 95.55 263.12 9021.50 8957.50 5972535.04 616027.31 3407.41 10.00 84.70 MWD 14083.80 95.83 266.50 9018.15 8954.15 5972531.46 615993.87 3438.15 10.00 85.16 MWD 14100.00 95.83 266.50 9016.50 8952.50 5972530.22 615977.81 3452.68 0.00 0.00 MWD 14200.00 95.83 266.50 9006.35 8942.35 5972522.57 615878.63 3542.37 0.00 0.00 MWD 14300.00 95.83 266.50 8996.20 8932.20 5972514.93 615779.45 3632.07 0.00 0.00 MWD 14337.22 95.83 266.50 8992.43 8928.43 5972512.08 615742.53 3665.45 0.00 0.00 MWD 14350.00 95.43 267.73 8991.17 8927.17 5972511.24 615729.84 3676.86 10.00 107.85 MWD 14400.00 93.87 272.49 8987.11 8923.11 5972510.54 615680.03 3720.33 10.00 107.97 MWD 14450.00 92.29 277.24 8984.43 8920.43 5972513.98 615630.24 3761.71 10.00 108.35 MWD 14500.00 90.69 281.98 8983.13 8919.13 5972521.54 615580.85 3800.69 10.00 108.61 MWD 14521.34 90.00 284.00 8983.00 8919.00 5972526.00 615559.99 3816.51 10.00 108.73 S-27B T6.2 14550.00 89.29 286.18 8983.18 8919.18 5972533.02 615532.21 3837.05 8.00 108.05 MWD 14600.00 88.05 289.99 8984.34 8920.34 5972547.77 615484.46 3871.00 8.00 108.03 MWD 14650.00 86.83 293.80 8986.57 8922.57 5972565.65 615437.84 3902.42 8.00 107.94 MWD 14700.00 85.61 297.62 8989.87 8925.87 5972586.56 615392.56 3931.15 8.00 107.77 MWD 14750.00 84.42 301.45 8994.21 8930.21 5972610.41 615348.84 3957.05 8.00 107.52 MWD 14758.46 84.22 302.10 8995.05 8931.05 5972614.73 615341.62 3961.15 8.00 107.19 MWD 14800.00 84.22 302.10 8999.23 8935.23 5972636.13 615306.26 3981.04 0.00 0.00 MWD 14900.00 84.22 302.10 9009.30 8945.30 5972687.64 615221.16 4028.93 0.00 0.00 MWD 15000.00 84.22 302.10 9019.37 8955.37 5972739.16 615136.05 4076.82 0.00 0.00 MWD 15100.00 84.22 302.10 9029.44 8965.44 5972790.67 615050.94 4124.71 0.00 0.00 MWD 15200.00 84.22 302.10 9039.51 8975.51 5972842.19 614965.83 4172.60 0.00 0.00 MWD 15286.58 84.22 302.10 9048.23 8984.23 5972886.79 614892.14 4214.07 0.00 0.00 MWD 15300.00 84.43 301.04 9049.56 8985.56 5972893.59 614880.66 4220.60 8.00 281.10 MWD 15350.00 85.22 297.10 9054.07 8990.07 5972917.09 614836.77 4246.84 8.00 281.21 MWD 15400.00 86.03 293.18 9057.89 8993.89 5972937.54 614791.32 4275.95 8.00 281.56 MWD 15450.00 86.86 289.25 9060.99 8996.99 5972954.85 614744.53 4307.79 8.00 281.86 MWD 15500.00 87.71 285.34 9063.36 8999.36 5972968.93 614696.63 4342.21 8.00 282.11 MWD 15517.14 88.00 284.00 9064.00 9000.00 5972973.00 614679.99 4354.57 8.00 282.29 S-27B T8 WP ~ 15550.00 88.99 282.29 9064.86 9000.86 5972979.96 614647.89 4378.88 6.00 299.97 MWD e BP e KW A Planning Report ..--..--..- Cömpany: BP Amoco Date: 9/4/2003 Tinië: 10:54:00 .'·Page;,."., 5 Field: Prudhþe Bay Co-ordinate(NE) Reference: Well: 8-27, True North" Site: PB S,Þad Vertical (TVD) Reference: 2E8 @ 28.5 + 35.50 GLQ~.O...,... , Well: S-27'; Section (VS) Reference: User (-4238.62N,-1269.14E;2!1-0.87Azi) Wellpath: Plan'$-27B Survey Calculation Method: Minimum Curvatl,lre ;'Db: Oracle -_..~-_.._._.._._- Survey MD lncl Azim TVD Sys TVD MapN Map'<; VS DLS " ,TFO Too ft deg deg ft ft ft ft ft deg/10OO dE!g .. .--- .-.--.--.--.-- 15600.00 90.49 279.69 9065.09 9001.09 5972988.71 614598.68 4417.11 6.00 300.01 MWD 15650.00 91.99 277.10 9064.02 9000.02 5972995.22 614549.12 4456.75 6.00 300.03 MWD 15700.00 93.48 274.49 9061.63 8997.63 5972999.47 614499.37 4497.69 6.00 299.97 MWD 15719.28 94.06 273.49 9060.36 8996.36 5973000.50 614480.16 4513.81 6.00 299.85 MWD 15800.00 94.06 273.49 9054.65 8990.65 5973004.12 614399.73 4581.63 0.00 0.00 MWD 15900.00 94.06 273.49 9047.57 8983.57 5973008.59 614300.09 4665.65 0.00 0.00 MWD 16000.00 94.06 273.49 9040.50 8976.50 5973013.07 614200.45 4749.67 0.00 0.00 MWD 16100.00 94.06 273.49 9033.42 8969.42 5973017.55 614100.81 4833.69 0.00 0.00 MWD 16200.00 94.06 273.49 9026.34 8962.34 5973022.03 614001.17 4917.71 0.00 0.00 MWD 16300.00 94.06 273.49 9019.27 8955.27 5973026.51 613901.53 5001.73 0.00 0.00 MWD 16400.00 94.06 273.49 9012.19 8948.19 5973030.99 613801.89 5085.75 0.00 0.00 MWD 16445.06 94.06 273.49 9009.00 8945.00 5973033.00 613756.99 5123.61 0.00 0.00 S-27B T9 WP 3 P055145 DATE 8/22/2003 INV# PR082003G INVOICE 1 CREDIT MEMO e DESCRIPTION GROSS PERMIT TO DRILL ~EE S· ?-7S THE ATTACHED CHECK IS IN PAYMENT FOR ITEMS DESCRIBED ABOVE. TOTAL ~ BP EXPLORATION, (ALASKA) INC. PRUDHOE BAY UNIT PO BOX 196612 AK99519-6612 PAY: TO THE ORDER OF: NATIONAL. CITY BANK Ashland, Ohio e DATE 8/22/2003 I I CHECK NO. 055145 VENDOR DISCOUNT NET 56·389 412 No. P 05514~ CONSOLIDATED COMMERCIAL ACCOUNT AMOUNT August 22,2003 I *******$100.00*******1 NOT VJ\LlDf\~~R~~O J?AY~. . ' . _" .. .. .. ~~\:~:<.:.::::·:~·:::~s:~:~:.~:.::·:s:" ..;~~~~~::'~~:}:~,}~ ........... '''' .........._~.._. '..... ..... ~.\./~:: .., '7::'; '~"'. ~\. :~ :::\~¡ ~~>\t:::>::~::;~.. .:f;~:~i}li;·~~}¡~~~::~:·¡>~~i~·::\~:··~ ALASKA OIL & GAS 333 W 7TH AVENUE SUITE 100 ANCHORAGE, AK 99501-3539 III 0 5 5 ~ L. 5 III I: 0 L. ~ 2 0 ~ B c¡ 5 I: 0 ~ 2 7 B c¡ b III · e TRANSMIT AL LETTER CHECK LIST CIRCLE APPROPRIATE LETTERIP ARAGRAPHS TO BE INCLUDED IN TRANSMITTAL LETTER WELL NAME PTD# CHECK WHAT APPLIES ADD-ONS (OPTIONS) MULTI LATERAL (If API number last two (2) digits are between 60-69) Pll.-OT (PH) "CLUE" The permit is for a new wellbore segment of existing weD ~ Permit No, API No. Production should continue to be reported as a function· of the original API number. stated above. HOLE In accordance with 20 AAC 25.005(1), all records, data and logs acquired for the pilot hole must be clearly differentiated in both name (name on permit plus PH) and API number (50 70/80) from records, data and logs acquired for well (name on permit). SPACING EXCEPTION DRY DITCH SAMPLE Rev: 071] 0102 C\jody\templates The permit is approved subject to fuD compliance with 20 AAC 25.055. Approval to perforate and produce is contingent upon issuance of a conservation order approving a spacing exception. (Companv Name) assumes the liability of any protest to the spacing . exception that may occur. All dry ditch sample sets submitted to the Commission must be in no greater than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. ."vELL P;ERMIT CHECKLIST Company BP EXPLORATION (ALASKA) INC Well Name: PRUDHOE BAY UNIT S-27B Program DEV Well bore seg 0 PTD#: 2031680 Field & Pool PRUDHOE BAY, PRUDHOE OIL - 640150 Initial ClasslType DEV /1-0IL GeoArea 890 Unit 11650 On/Off Shore ~ Annular Disposal 0 Administration 1 PßcmiUee attachep_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yß$ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 2 _LeasßnUl)1ber _apQrOQriate_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yß$ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 3 _U_nlque weltn_a!T1ß_aod Ol!mb_er _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yß$ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 4 WellJQcatßd In_a_d_efinep-pool _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yß$ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 5 WeUJQcatßd pmper _dIstance from driJIing unilb_ound_ary_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yß$ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 6 WelUQcatßd proper _dlstance_ from other wells_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Xes _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 7 _S_ufficientjicrea9-e_aYailjible Indrilli09 l!njL _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yß$ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 8 Jtdßviated, js_ weJ/bQre platincJuded _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yß$ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 9 _O-pe(ator onl}' affected party _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yß$ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 10 _O-pe(ator has_approprlate_bond InJorce _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yß$ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 11 Pßcmit ~ao be IS$l!ed wjthQut conservation order _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yß$ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Appr Date 12 Pßcmitc_ao be IS$l!ed wjthQut admÌlJist(atille_approval _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yß$ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ RPC 10/7/2003 13 Can permit be approved before 15-day wait Yes 14 WeJUQcaled wIthin area and_strata authorIzed by_lojectioo Ordßc # (putlO# in_c_o!T1!T1_eots)(For_ _NA _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 15 AJI we IIs_ witÞln Jl4JIJile_area_of ceyiew jdßotlfied (Fou~e[Vjc_ewell on I}') _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _NA _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 16 Pre-produ_cecl iojeçtor; puratio_n_of pre--propuctioo Iß$~ than 3 l)1onths_ (For_servlce well onJy) _ _NA _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 17 ACMPJ:ïndjngof Conslsteocy_h_as beeRi~sued_ forthis p(oject_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _NA _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 18 _COodu_ct9r stcing_prQvlded _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _NA _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 19Sulfaœ _ca~ingpJQte~t~ alLknown USQWs _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _NA _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 20 _CMT v_ol adeC:¡l!ateto çirc_ulateoncond_uctoU!, $uJtcsg _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ NA _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 21 _CMT v_ol adec:¡u_ateto tie-lnJQng _striog tosulf C&g_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _NA _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 22 _CMTwill coyeraJl know_n_pro_ductiye hQrilon_s_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yß$ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 23 _C_asiog desigos ad_e(ua_te foc C,T, B_&_p-ermafr9$t _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yß$ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 24 ApequateJan_kage_or re_serve pit _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yß$ _ _ _ _ _ _ _ l'.Iabws_2_ES, _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 25 JtaJe-pcilL has_a_ to,.403 fQr abandonment beßO aQPJoved _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yß$ _ 10/7/2003. _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 26 _MequateweJlbore ~eparatjon_pro-posed _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yß$ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 27 Jtdjverter Jectuired, dQes jt meet reguJations_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _NA _ _ _ _ _ _ _ $idetcack. _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 28DJilliog flujd_p-rQQ[am $~hel)1atic_&ectuipJistadequate_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yßs _ _ _ _ _ _ _ Max MWJ1,2_ppg._ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 29 _B_OPEs,_dothey meet reguJation _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yß$ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 30 _BOPEpress ra_tiog appropciate:_testlo(put psig In_cOl)1l)1ents)_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yß$ _ _ _ _ _ _ Test to_3500p-sLMS~ 26_00 psi._ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 31 _Choke manifold cQmpJies_ w/APt R~-53 (May 84L _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yß$ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 32 WQrk will occ_uc withoutoperatjon_shl!tdown_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yß$ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 33 J~ preseoce_ Qf H2$ gas_ p-rob_able _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ No_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 34 Meçba_nlcaLcoodjtloo otwells wIthin ~OR yerifiecl (For_s_ervjc:e welJ onM _ _ _ _ _ _ _ _ _ _ _ _ _ _NA _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Engineering Appr Date WGA 1 on /2003 Geology Appr RPC Date 10/7/2003 Geologic Commissioner: Dre;, - e 35 Pecmit~aobels$l!edwlo_hYd(ogen_~ulfidel)1easjJœs_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ No_ _ _ _ _ _ _ _ _ _ _ _ _ _ __ 36 _D_atapreseotecl on_ Qote_ntial overQres_surezones _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _NA 37Selsmlc_analysjs oJ shaJlow gaszooes _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _NA _ 38 _Sßabed _condjtioo $l!rvey(if off-shoce) _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _NA _ _ _ _ _ _ _ _ _ _ _ _ _ 39 _ CQnta_ct namelpÞoneJor_weekly progre~HeQort$ [exploratory _ooly] _ _ _NA _ ~ - - - - - - - - - - - - - - - - - - - - - ~ - - - - - - - - -- - - - - - - - - - - - - -- - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - -- - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - -- - - - - - - - - - -- - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - -- - - - - - - - - - - - - - - - - - - - - - - - - - - ~ - - - - - ~ - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - -- - - - - - - - - - - - Date: Engineering co~er: Date " o ~~ c...,JJ Public " _____ Commissioner ~~~ ¡oj 7( 3 e e Well History File APPENDIX Information of detailed nature that is not particularly gennane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. . . &03 ~/ lDg }dv'10[ Sperry-Sun Drilling Services LIS Scan Utility $Revision: 3 $ LisLib $Revision: 4 $ Fri Jan 23 11:27:16 2004 Reel Header Service name.............LISTPE Date. . . . . . . . . . . . . . . . . . . . .04/01/23 Origin. . . . . . . . . . . . . . . . . . . STS Reel Name................ UNKNOWN Continuation Number......01 Previous Reel Name.......UNKNOWN Comments.................STS LIS Writing Library. Scientific Technical Services Tape Header Service name.............LISTPE Date.....................04/01/23 Origin. . . . . .. . . . . . . . . . . . . STS Tape Name................UNKNOWN Continuation Number......01 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 S-27B 500292205702 BP Exploration (Alaska), Inc. Sperry-Sun Drilling Services 23-JAN-04 JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 2 MW0002796082 J. SACK J. RALL 1 D. MWD RUN 3 MW0002796082 J. BOBBITT R. BORDES 1 MWD RUN 4 MW0002796082 T. GALVIN R. BORDES 1 JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 5 MW0002796082 T. GALVIN R. BORDES 1 MWD RUN 6 MW0002796082 J. SACK R. BORDES 1 MWD RUN 7 MW0002796082 T. GALVIN R. BORDES 1 # SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: 35 12N 12E 1635 1231 65.30 36.79 RECEIVED # WELL CASING RECORD 1 ,. ":'\04 ¿. L:t" I 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING OPEN HOLE BIT SIZE (IN) 8.500 6.125 CASING SIZE (IN) 9.625 7.000 DRILLERS DEPTH (FT) 9808.0 10738.0 f'1j~,k~Œt ~(Gas Cons.Comm_n A.f;0~Ofage # REMARKS: ~~~\\\.~ . . 1. ALL DEPTHS ARE BIT DEPTHS UNLESS OTHERWISE NOTED. THESE DEPTHS ARE MEASURED DEPTH (MD). 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTH (TVD). 3. THIS WELL WAS EFFECTED BY MEANS OF A WHIPSTOCK PLACED IN THE S-27A WELL BORE. THE TOP OF THE WHIPSTOCK WAS AT 9973'MD, AND THE BOTTOM WAS AT 9989'MD. 4. MWD RUN 1 WAS DIRECTIONAL ONLY TO MILL THE WINDOW AND IS NOT PRESENTED. 5. MWD RUN 2 COMPRISED DIRECTIONAL AND DUAL GAMMA RAY (DGR), UTILIZING GEIGER-MUELLER TUBE DETECTORS. 6. MWD RUNS 3 - 6 COMPRISED DIRECTIONAL WITH DGR; ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4); AT-BIT INCLINATION (ABI); AND PRESSURE WHILE DRILLING (PWD). 7. MWD RUN 7 COMPRISED DIRECTIONAL WITH DGR; EWR4; AND ABI. 8. LOG AND DIGITAL DATA (LDWG) ONLY WERE BLOCK SHIFTED DOWNWARD 18.5 FEET, PER E-MAIL FROM K. COONEY (SIS), DATED 1/19/04. LOG HEADER DATA RETAIN ORIGINAL DRILLERS' DEPTH REFERENCES. 9. MWD RUNS 1 - 7 REPRESENT WELL S-27B WITH API#: 50-029-22057-02. THIS WELL REACHED A TOTAL DEPTH (TD) OF 16700'MD/8994'TVD. SROP SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRC SMOOTHED GAMMA RAY COMBINED. SEXP SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (EXTRA SHALLOW SPACING). SESP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (SHALLOW SPACING) . SEMP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (MEDIUM SPACING) . SEDP ~ SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (DEEP SPACING) . SFXE = SMOOTHED FORMATION EXPOSURE TIME. SLIDE = NON-ROTATED INTERVALS REFLECTING BIT DEPTHS. $ File Header Service name.............STSLIB.OOl Service Sub Level Name... Version Number...........l.0.0 Date of Generation.......04/01/23 Maximum Physical Record..65535 File Type................LO Previous File Name.......STSLIB.OOO Comment Record FILE HEADER FILE NUMBER: EDITED MERGED MWD Depth shifted and DEPTH INCREMENT: # FILE SUMMARY PBU TOOL CODE GR ROP FET RPD 1 clipped curves; all bit runs merged. .5000 START DEPTH 9858.5 10024.0 10743.5 10743.5 STOP DEPTH 16665.5 16718.5 16672.5 16672.5 RPM RPS RPX $ . . 10743.5 10743.5 10743.5 16672.5 16672.5 16672.5 # BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH 9858.5 16718.5 $ # MERGED DATA SOURCE PBU TOOL CODE MWD MWD MWD MWD MWD MWD $ # REMARKS: GR 9840.0 16700.0 BIT RUN NO 2 3 4 5 6 7 MERGE TOP 9840.0 10741.0 11561. 0 13555.0 13882.0 15582.5 MERGE BASE 10741.0 11561. 0 13555.0 13882.0 15582.5 16700.0 MERGED MAIN PASS. $ # 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 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 2 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 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 9858.5 16718.5 13288.5 13721 9858.5 16718.5 ROP MWD FT/H 0.72 1248.86 93.5031 13390 10024 16718.5 GR MWD API 14.01 601. 06 53.2962 13615 9858.5 16665.5 RPX MWD OHMM 0.58 2000 105.857 11859 10743.5 16672.5 RPS MWD OHMM 0.28 2000 94.5979 11859 10743.5 16672.5 RPM MWD OHMM 0.5 2000 54.6942 11859 10743.5 16672.5 RPD MWD OHMM 0.42 2000 78.2124 11859 10743.5 16672.5 FET MWD HOUR 0.21 66.39 2.06481 11859 10743.5 16672.5 First Reading For Entire File..........9858.5 Last Reading For Entire File...........16718.5 File Trailer Service name.............STSLIB.OOl Service Sub Level Name... Version Number...........l.O.O Date of Generation.......04/01/23 Maximum Physical Record..65535 Fìl e Type................ LO Next File Name...........STSLIB.002 . Physical E01" 1"ile Header Service name.............STSLIB.002 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......04/01/23 Maximum Physical Record..65535 1"ile Type................ LO Previous 1"ile Name.......STSLIB.001 Comment Record tILE HEADER tILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # tILE SUMMARY VENDOR TOOL CODE GR ROP $ 2 . header data for each bit run in separate files. 2 .5000 START DEPTH 9840.0 10005.5 STOP DEPTH 10704.5 10741. 0 # LOG HEADER DATA DATE LOGGED: S01"TWARE SUR1"ACE S01"TWARE VERSION: DOWNHOLE S01"TWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (1"T): TOP LOG INTERVAL (1"T): BOTTOM LOG INTERVAL (1"T): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE DGR $ BOTTOM) TOOL TYPE DUAL GAMMA RAY # 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): 1"LUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEG1") 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 STAND01"1" (IN): EWR 1"REQUENCY (HZ): # REMARKS: $ # Data Format Specification Record 01-DEC-03 Insite 66.37 Memory 10741.0 10005.0 10741.0 45.1 53.7 TOOL NUMBER 149206 8.500 9808.0 LSND 11.10 52.0 10.3 2600 3.6 .000 .000 .000 .000 .0 150.0 .0 .0 . . 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 Absent value...................... -999 Depth Units....................... Datum Specification Block sub-type...O Name Service Order DEPT ROP MWD020 GR MWD020 Code Offset o 4 8 Channel 1 2 3 Units FT FT/H API Size 4 4 4 Nsam 1 1 1 Rep 68 68 68 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 9840 10741 10290.5 1803 9840 10741 ROP MWD020 FT/H 3.69 225.96 89.3861 1472 10005.5 10741 GR MWD020 API 39.71 162.7 109.449 1730 9840 10704.5 First Reading For Entire File..........9840 Last Reading For Entire File...........l0741 File Trailer Service name.............STSLIB.002 Service Sub Level Name... Version Number...........l.O.O Date of Generation.......04/0l/23 Maximum Physical Record..65535 File 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.......04/0l/23 Maximum Physical Record..65535 Fi 1 e Type................ LO Previous File Name.......STSLIB.002 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE GR RPS RPX RPM RPD FET ROP $ 3 header data for each bit run in separate files. 3 .5000 START DEPTH 10705.0 10725.0 10725.0 10725.0 10725.0 10725.0 10741.5 STOP DEPTH 11509.5 11516.5 11516.5 11516.5 11516.5 11516.5 11561. 0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: 06-DEC-03 Insite 66.37 . 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: # TOOL STRING (TOP TO VENDOR TOOL CODE DGR EWR4 $ BOTTOM) TOOL TYPE DUAL GAMMA RAY Electromag Resis. 4 # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type..................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 Absent value..................... .-999 Depth Units....................... Datum Specification Block sub-type...O . Memory 11561.0 10741.0 11561.0 52.0 88.8 TOOL NUMBER 91360 156401 6.125 10738.0 FLO-PRO 8.40 54.0 8.3 2250 6.2 2.000 1.140 2.000 1.900 68.0 130.0 68.0 68.0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD030 FT/H 4 1 68 4 GR MWD030 API 4 1 68 8 3 RPX MWD030 OHMM 4 1 68 12 4 RPS MWD030 OHMM 4 1 68 16 5 RPM MWD030 OHMM 4 1 68 20 6 RPD MWD030 OHMM 4 1 68 24 7 FET MWD030 HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 10705 11561 11133 1713 10705 11561 ROP MWD030 FT/H 0.72 290.82 41.7896 1640 10741.5 11561 GR MWD030 API 17.85 601.06 101.15 1610 10705 11509.5 RPX MWD030 OHMM 0.58 2000 674.405 1584 10725 11516.5 RPS MWD030 OHMM 0.28 2000 631. 701 1584 10725 11516.5 RPM MWD030 OHMM 0.51 2000 343.411 1584 10725 11516.5 . . RPD MWD030 OHMM 0.42 2000 487.602 1584 10725 11516.5 FET MWD030 HOUR 0.6 66.39 3.68381 1584 10725 11516.5 First Reading For Entire File..........10705 Last Reading For Entire File...........11561 File Trailer Service name.............STSLIB.003 Service Sub Level Name... Version Number...........l.0.0 Date of Generation.......04/01/23 Maximum Physical Record..65535 Fi 1 e Type................ LO Next File Name...........STSLIB.004 Physical EOF File Header Service name.............STSLIB.004 Service Sub Level Name... Version Number...........l.0.0 Date of Generation.......04/01/23 Maximum Physical Record..65535 Fi 1 e Type................ LO Previous File Name.......STSLIB.003 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE GR RPS FET RPM RPX RPD ROP $ 4 header data for each bit run in separate files. 4 .5000 START DEPTH 11510.0 11514.0 11514.0 11517.0 11517.0 11517.0 11561. 5 STOP DEPTH 13501. 0 13507.5 13507.5 13507.5 13507.5 13507.5 13555.0 # 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: 07-DEC-03 Insite 66.37 Memory 13555.0 11561.0 13555.0 81. 6 91. 8 # TOOL STRING (TOP TO VENDOR TOOL CODE DGR EWR4 $ BOTTOM) TOOL TYPE DUAL GAMMA Electromag RAY Resis. 4 TOOL NUMBER 91360 156401 # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): 6.125 10738.0 # 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: 8.40 44.0 8.5 2000 10.0 2.000 1.160 2.000 1.900 70.0 125.6 70.0 70.0 # 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 Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD040 FT/H 4 1 68 4 2 GR MWD040 API 4 1 68 8 3 RPX MWD040 OHMM 4 1 68 12 4 RPS MWD040 OHMM 4 1 68 16 5 RPM MWD040 OHMM 4 1 68 20 6 RPD MWD040 OHMM 4 1 68 24 7 FET MWD040 HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 11510 13555 12532.5 4091 11510 13555 ROP MWD040 FT/H 2.02 251. 71 142.708 3988 11561. 5 13555 GR MWD040 API 14 .01 348.88 39.5547 3983 11510 13501 RPX MWD040 OHMM 1.67 2000 35.0973 3982 11517 13507.5 RPS MWD040 OHMM 1.62 2000 19.4898 3987 11514 13507.5 RPM MWD040 OHMM 0.5 2000 14.5124 3982 11517 13507.5 RPD MWD040 OHMM 0.72 2000 26.7846 3982 11517 13507.5 FET MWD040 HOUR 0.21 19.89 1. 01163 3987 11514 13507.5 First Reading For Entire File..........11510 Last Reading For Entire File...........13555 File Trailer Service name.............STSLIB.004 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......04/01/23 Maximum Physical Record..65535 Fi 1 e Type................ LO Next File Name...........STSLIB.005 Physical EOF . File Header Service name.............STSLIB.005 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......04/01/23 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: # FILE SUMMARY VENDOR TOOL CODE GR FET RPD RPM RPS RPX ROP $ 5 . header data for each bit run in separate files. 5 .5000 START DEPTH 13501. 5 13508.0 13508.0 13508.0 13508.0 13508.0 13555.5 STOP DEPTH 13828.5 13836.0 13836.0 13836.0 13836.0 13836.0 13882.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE DGR EWR4 $ BOTTOM) TOOL TYPE DUAL GAMMA RAY Electromag Resis. 4 # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: " 09-DEC-03 Insite 66.37 Memory 13882.0 13555.0 13882.0 88.5 92.8 TOOL NUMBER 160796 148574 6.125 10738.0 FLO PRO 8.40 55.0 8.9 350 10.0 1.900 1. 040 2.000 2.000 68.0 129.2 68.0 68.0 . . # 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 Uni ts . . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD050 FT/H 4 1 68 4 2 GR MWD050 API 4 1 68 8 3 RPX MWD050 OHMM 4 1 68 12 4 RPS MWD050 OHMM 4 1 68 16 5 RPM MWD050 OHMM 4 1 68 20 6 RPD MWD050 OHMM 4 1 68 24 7 FET MWD050 HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DI';PT FT 13501.5 13882 13691.8 762 13501. 5 13882 ROP MWD050 FT/H 1.38 237.67 48.1929 654 13555.5 13882 GR MWD050 API 15.89 59.91 25.9654 655 13501. 5 13828.5 RPX MWD050 OHMM 3.65 10.33 7.25773 657 13508 13836 RPS MWD050 OHMM 3.02 8.1 5.69893 657 13508 13836 RPM MWD050 OHMM 2.79 6.41 4.71087 657 13508 13836 RPD MWD050 OHMM 3.07 5.47 4.4181 657 13508 13836 FI';T MWD050 HOUR 1. 72 23.76 6.55009 657 13508 13836 First Reading For I';ntire File..........13501.5 Last Reading For I';ntire File...........13882 File Trailer Service name.............STSLIB.005 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......04/01/23 Maximum Physical Record..65535 Fi 1 e Type................ LO Next File Name...........STSLIB.006 Physical I';OF File Header Service name.............STSLIB.006 Service Sub Level Name... Version Number...........l.O.O Date of Generation.......04/01/23 Maximum Physical Record..65535 File Type............... .LO Previous File Name.......STSLIB.005 Comment Record FILl'; HEADI';R FILl'; NUMBI';R: RAW MWD Curves and log BIT RUN NUMBI';R: DI';PTH INCRI';MENT: # FILl'; SUMMARY VENDOR TOOL CODE GR RPM 6 header data for each bit run in separate files. 6 .5000 START DEPTH 13829.0 13836.5 STOP DEPTH 15529.5 15536.5 . RPS RPD FET RPX ROP $ 13836.5 13836.5 13836.5 13836.5 13882.5 15536.5 15536.5 15536.5 15536.5 15582.5 # 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 MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE DGR EWR4 $ BOTTOM) TOOL TYPE DUAL GAMMA RAY Electromag Resis. 4 # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type.................. 0 Data Specification Block Type.....O 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 . 12-DEC-03 Insite 66.37 Memory 15582.0 13882.0 15582.0 84.8 97.2 TOOL NUMBER 156435 156404 6.125 10738.0 FLO-PRO 8.40 47.0 9.5 250 10.4 5.800 2.880 4.000 4.300 68.0 143.6 68.0 68.0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD060 FT/H 4 1 68 4 2 GR MWD060 API 4 1 68 8 3 RPX MWD060 OHMM 4 1 68 12 4 RPS MWD060 OHMM 4 1 68 16 5 RPM MWD060 OHMM 4 1 68 20 6 RPD MWD060 OHMM 4 1 68 24 7 . . FET MWD060 HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 13829 15582.5 14705.8 3508 13829 15582.5 ROP MWD060 FT/H 0.94 366.43 79.1028 3401 13882.5 15582.5 GR MWD060 API 14.69 113.25 29.5812 3402 13829 15529.5 RPX MWD060 OHMM 3.02 27.27 6.95782 3401 13836.5 15536.5 RPS MWD060 OHMM 2.88 27.94 6.76534 3401 13836.5 15536.5 RPM MWD060 OHMM 2.99 28 6.91762 3401 13836.5 15536.5 RPD MWD060 OHMM 3.16 25.7 7.17429 3401 13836.5 15536.5 FET MWD060 HOUR 0.36 28.57 1.73107 3401 13836.5 15536.5 First Reading For Entire Fi1e..........13829 Last Reading For Entire File...........15582.5 File Trailer Service name.............STSLIB.006 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......04/01/23 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...........1.0.0 Date of Generation.......04/01/23 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 RPD RPM RPS RPX FET ROP $ 7 header data for each bit run in separate files. 7 .5000 START DEPTH 15530.0 15537.0 15537.0 15537.0 15537.0 15537.0 15583.0 STOP DEPTH 16647.0 16654.0 16654.0 16654.0 16654.0 16654.0 16700.0 # 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: 14-DEC-03 Insite 66.37 Memory 16700.0 15582.0 16700.0 86.5 95.8 . TOOL STRING (TOP TO VENDOR TOOL CODE DGR EWR4 $ BOTTOM) TOOL TYPE DUAL GAMMA RAY Electromag Resis. 4 # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type................. .0 Data Specification Block Type.....O 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 . TOOL NUMBER 156435 156404 6.125 10738.0 FLO-PRO 8.40 55.0 8.9 250 10.4 5.800 2.630 4.000 4.300 68.0 158.0 68.0 68.0 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 RPX MWD070 OHMM 4 1 68 12 4 RPS MWD070 OHMM 4 1 68 16 5 RPM MWD070 OHMM 4 1 68 20 6 RPD MWD070 OHMM 4 1 68 24 7 FET MWD070 HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 15530 16700 16115 2341 15530 16700 ROP MWD070 FT/H 1.27 1248.86 81. 5347 2235 15583 16700 GR MWD070 API 14.04 158.28 43.955 2235 15530 16647 RPX MWD070 OHMM 2.2 43.52 8.46242 2235 15537 16654 RPS MWD070 OHMM 2.16 36.16 8.51289 2235 15537 16654 RPM MWD070 OHMM 2.03 34.2 9.05829 2235 15537 16654 RPD MWD070 OHMM 2.27 34.05 9.4859 2235 15537 16654 FET MWD070 HOUR 0.31 20.42 2.02532 2235 15537 16654 First Reading For Entire File..........15530 Last Reading For Entire File...........16700 File Trailer . . Service name.............STSLIB.007 Service Sub Level Name... Version Number...........l.O.O Date of Generation.......04/01/23 Maximum Physical Record..65535 File Type................LO Next File Name...........STSLIB.008 Physical EOF Tape Trailer Service name.............LISTPE Date.....................04/01/23 Origin...................STS Tape Name. . . . . . .. . . . . . . . . UNKNOWN Continuation Number......Ol Next Tape Name...........UNKNOWN Comments.................STS LIS Writing Library. Scientific Technical Services Reel Trailer Service name.............LISTPE Date.....................04/01/23 Origin...................STS Reel Name................UNKNOWN Continuation Number......Ol Next Reel Name...........UNKNOWN Comments.................STS LIS Writing Library. Scientific Technical Services Physical EOF Physical EOF End Of LIS File