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Home My WebLink About204-2227. Property Designation (Lease Number): 1. Operations Performed: 2. Operator Name: 3. Address: 4. Well Class Before Work:5. Permit to Drill Number: 6. API Number: 8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071): 10. Field/Pool(s): Susp Well Insp Install Whipstock Mod Artificial Lift Perforate New Pool Perforate Plug Perforations Coiled Tubing Ops Other Stimulate Fracture Stimulate Alter Casing Pull Tubing Repair Well Other: Change Approved Program Operations shutdown 11. Present Well Condition Summary: Casing Length Size MD TVD Burst Collapse Exploratory Stratigraphic Development Service 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 16. Well Status after work: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. OIL GAS WINJ WAG GINJ WDSPL GSTOR Suspended SPLUG Authorized Name and Digital Signature with Date: Authorized Title: Contact Name: Contact Email: Contact Phone: PBU 15-14A Hilcorp North Slope, LLC 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 204-222 50-029-20682-01-00 13237 Conductor Surface Intermediate Liner Liner 8910 80 2544 8546 1522 3458 10820 20" 13-3/8" 9-5/8" 7" 4-1/2" 8997 29 - 109 28 - 2572 27 - 8573 8410 - 9932 9779 - 13237 29 - 109 28 - 2572 27 - 7231 7105 - 8368 8240 - 8910 13144 520 2670 4760 5410 7500 10820 1530 4930 6870 7240 8430 10674 - 13150 4-1/2" 12.6# 13Cr80 24 - 9781 8946 - 8913 Structural 4-1/2" Baker S3 Packer 9302 7845 Bo York Operations Manager Jerry Lau jerry.lau@hilcorp.com 907-564-5280 PRUDHOE BAY, PRUDHOE OIL Total Depth Effective Depth measured true vertical feet feet feet feet measured true vertical measured measured feet feet feet feet measured true vertical Plugs Junk Packer Measured depth True Vertical depth feet feet Perforation depth Tubing (size, grade, measured and true vertical depth) Packers and SSSV (type, measured and true vertical depth) 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13a.Representative Daily Average Production or Injection Data Oil -Bbl Gas-Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: Subsequent to operation: 15. Well Class after work: Exploratory Development Service StratigraphicDaily Report of Well Operations Copies of Logs and Surveys Run Electronic Fracture Stimulation Data Sundry Number or N/A if C.O. Exempt: ADL 0028306 24 - 8242 N/A N/A 566 1057 58665 21020 32 5 0 0 1031 762 N/A 13b. Pools active after work:PRUDHOE OIL No SSSV Installed 9302, 7845 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS Sr Pet Eng: Sr Pet Geo: Form 10-404 Revised 10/2022 Submit in PDF format to aogcc.permitting@alaska.gov Sr Res Eng: Due Within 30 days of Operations By Grace Christianson at 11:04 am, Aug 28, 2025 Digitally signed by Bo York (1248) DN: cn=Bo York (1248) Date: 2025.08.28 08:53:42 - 08'00' Bo York (1248) RBDMS JSB 090425 DSR-9/11/25J.Lau 11/4/25 ACTIVITY DATE SUMMARY 8/15/2025 T/I/O = 2485/940/50 (TFS Unit 1 Assist E-Line w/ Pump Down) Pumped 163 bbls Crude down TBG for load. E-Line able to get to depth without pump. YellowJacket E-line in control of well upon TFS departure FWHPS = 150/940/50 8/15/2025 ***WELL S/I ON ARRIVAL*** (PUMP DOWN TO ADPERF) RIG UP YJ ELINE. PT PCE 300 PSI LOW /3000 PSI HIGH THUNDERBIRD LOAD THE WELL WITH 160 BLS PERFORATE INTERVAL 10757'-10777 WITH 2.75'' GEO RAZOR 6spf 60 DEG PHASE CCL TO TOP SHOT=10.' CCL STOP DEPTH= 10747'. CONFIRM SHOTS FIRED GAMMA RAY CCL CORRELATE TO SPERRY SUN MWD GAMMA-RAY, LOG DATED 12-JAN-05 LAID DOWN LUBRICATOR FOR THE NIGHT ***JOB CONTINUE ON 8/16/2025*** 8/16/2025 ***JOB CONTINUE FROM 8/15/2025*** (PUMP DOWN TO SET CIBP AND ADPERF) PT PCE 300 PSI LOW /3000 PSI HIGH SET 3.50'' CIBP AT 10820' CCL TO MID ELEMENT=15.1' CCL STOP DEPTH=10804.9' PERFORATE INTERVAL 10674'-10691' WITH 2.75'' GEO RAZOR 6spf 60 DEG PHASE CCL TO TOP SHOT=11.' CCL STOP DEPTH=10663' . CONFIRM SHOTS FIRED GUN AND PLUG GAMMA RAY CORRELATE TO SPERRY SUN MWD GAMMA- RAY, LOG DATED 12-JAN-05 JOB COMPLETE ***WELL S/I ON DEPARTURE*** Daily Report of Well Operations PBU 15-14A Nolan Vlahovich Hilcorp Alaska, LLC Geotech 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 564-4558 E-mail: nolan.vlahovich@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: Date: 7/15/2025 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20250715 Well API #PTD #Log Date Log Company Log Type AOGCC E-Set# KBU 32-06 50133206580000 216137 7/1/2025 AK E-LINE PPROF BCU 14B 50133205390200 222057 6/20/2025 AK E-LINE Perf BR 03-87 50733204370000 166052 6/15/2025 AK E-LINE Perf BRU 211-35 50283201890000 223050 6/2/2025 AK E-LINE Perf BRU 213-26 50283201920000 223069 6/23/2025 AK E-LINE Perf BRU 221-24 50283202020000 225027 6/4/2025 AK E-LINE Perf BRU 221-24 50283202020000 225027 6/22/2025 AK E-LINE Perf BRU 221-24 50283202020000 225027 6/12/2025 AK E-LINE PPROF BRU 241-23 50283201910000 223061 6/10/2025 AK E-LINE Cement/Perf BRU 241-23 50283201910000 223061 6/19/2025 AK E-LINE CIBP BRU 241-23 50283201910000 223061 6/21/2025 AK E-LINE Perf BRU 241-23 50283201910000 223061 6/4/2025 AK E-LINE PlugPerf KBU 43-07Y 50133206250000 214019 6/17/2025 AK E-LINE Perf KU 41-08 50133207170000 224005 6/24/2025 AK E-LINE Plug Perf LIS L5-26 50029220790000 190110 6/21/2025 AK E-LINE Patch MRU M-25 50733203910000 187086 6/17/2025 AK E-LINE CIBP PBU 15-14A 50029206820100 204222 6/3/2025 BAKER SPN PBU 18-15C 50029217550300 211172 6/12/2025 AK E-LINE CBL/Perf PBU F-38B 50029220930300 225029 6/12/2025 BAKER MRPM SRU 241-33B 50133206960000 221053 5/25/2025 AK E-LINE CIBP Please include current contact information if different from above. T40659 T40660 T40661 T40662 T40663 T40664 T40664 T40664 T40665 T40665 T40665 T40665 T40666 T40667 T40668 T40669 T40670 T40671 T40672 T40673 PBU 15-14A 50029206820100 204222 6/3/2025 BAKER SPN Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2025.07.16 10:52:24 -08'00' 7. Property Designation (Lease Number): 1. Operations Performed: 2. Operator Name: 3. Address: 4. Well Class Before Work:5. Permit to Drill Number: 6. API Number: 8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071): 10. Field/Pool(s): Susp Well Insp Install Whipstock Mod Artificial Lift Perforate New Pool Perforate Plug Perforations Coiled Tubing Ops Other Stimulate Fracture Stimulate Alter Casing Pull Tubing Repair Well Other: Change Approved Program Operations shutdown 11. Present Well Condition Summary: Casing Length Size MD TVD Burst Collapse Exploratory Stratigraphic Development Service 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 16. Well Status after work: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. OIL GAS WINJ WAG GINJ WDSPL GSTOR Suspended SPLUG Authorized Name and Digital Signature with Date: Authorized Title: Contact Name: Contact Email: Contact Phone: PBU 15-14A Mill CIBP Hilcorp North Slope, LLC 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 204-222 50-029-20682-01-00 13237 Conductor Surface Production Liner Liner 8910 80 2543 8546 1522 3458 13194 20" 13-3/8" 9-5/8" 7" 4-1/2" 8911 29 - 109 28 - 2571 27 - 8573 8410 - 9932 9779 - 13237 29 - 109 28 - 2571 27 - 7231 7105 - 8368 8240 - 8910 13144 520 2670 4760 5410 7500 none 1530 4930 6870 7240 8430 10775 - 13150 4-1/2" 12.6# 13Cr80 24 - 9781 8987 - 8913 Structural 4-1/2" Baker S-3 Perm , 9302 , 7845 9302 7845 Bo York Operations Manager Eric Dickerman Eric.Dickerman@hilcorp.com 907.564.4061 PRUDHOE BAY, PRUDHOE OIL Total Depth Effective Depth measured true vertical feet feet feet feet measured true vertical measured measured feet feet feet feet measured true vertical Plugs Junk Packer Measured depth True Vertical depth feet feet Perforation depth Tubing (size, grade, measured and true vertical depth) Packers and SSSV (type, measured and true vertical depth) 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13a.Representative Daily Average Production or Injection Data Oil -Bbl Gas-Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: Subsequent to operation: 15. Well Class after work: Exploratory Development Service StratigraphicDaily Report of Well Operations Copies of Logs and Surveys Run Electronic Fracture Stimulation Data Sundry Number or N/A if C.O. Exempt: ADL 0028306 24 - 8242 567 502 51948 45120 13 84 0 0 1087 1117 N/A 13b. Pools active after work:PRUDHOE OIL STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS Sr Pet Eng: Sr Pet Geo: Form 10-404 Revised 10/2022 Submit in PDF format to aogcc.permitting@alaska.gov Sr Res Eng: Due Within 30 days of Operations By Samantha Carlisle at 8:02 am, Jan 17, 2023 Digitally signed by Eric Dickerman (4002) DN: cn=Eric Dickerman (4002), ou=Users Reason: Signed for Bo York with Approval Date: 2023.01.16 12:48:26 -09'00' Eric Dickerman (4002) DSR-1/17/23 RBDMS JSB 012623 Sundry Number Mill CIBP N/A PRUDHOE BAY, PRUDHOE OIL WCB 11-1-2023 204-222 PBU 15-14A ACTIVITYDATE SUMMARY 12/19/2022 LRS CTU #2 2.0" Blue Coil 0.156" wall. Job Objective: Mill CIBP MIRU & MU 2-7/8" YJ milling BHA w/ 3.69" 5-blade junk mill. ***Job in Progress*** 12/20/2022 LRS CTU#2 2.0" Blue Coil 0.156 wall. Job Objective: Mill CIBP Push CIBP to 13144' CTM, POOH and freeze protect CT and well. Blow down reel for pipe swap. RDMO. ***Job Complete*** Daily Report of Well Operations PBU 15-14A New WBS, below, shows CIBP fish at correct depth. -WCB · . 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. ~ (J Lf- - ~ J. ~ Well History File Identifier Page Count from Scanned File: (p 7 (Count does include cover sheet) Page Count Matches Number in SCanning/preparation: L YES ~ Date3/rs 07 If NO in stage 1, page(s) discrepancies were found: YES Organizing (done) o Two-sided ""1111111" 111111 RESCAN ~olor Items: o Greyscale Items: DIGITAL DATA ~skettes, NO.~ o Other, NolType: o Poor Quality Originals: o Other: NOTES: Date 3 Jib / D 7 I Date3/ß J 07 d- IPo+ BY: ~ Project Proofing BY: ~ Scanning Preparation BY: Date: Production Scanning Stage 1 BY: Stage 1 BY: Maria Date: Scanning is complete at this point unless rescanning is required. o Rescan Needed III II 1/1111 II "1111 OVERSIZED (Scannable) o Maps: o Other Items Scannable by a Large Scanner OVERSIZED (Non-Scannable) o Logs of various kinds: o Other:: mP 151 (p 1111111111111111111 tl1f fo(P 151 = TOTAL PAGES (Count does not include cover sheet) 151 11111111111111" III NO 151 VV1 F NO 151 III 11111111I111111I ReScanned BY: Maria Date: 151 Comments about this fife: 11111111111111 ,,11/ Quality Checked III 11111111I 1111111 10/6/2005 Well History File Cover Page. doc STATE OF ALASKA RECEIVED • k ACA OIL AND GAS CONSERVATION COMM. dON OF C 19 2013 REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon U Repair Well Plug Perforations U, Perforate 1 . Other 11 `� °ACC Performed: Alter Casing ❑ Pull Tubing❑ Stimulate-Frac ❑ Waiver ❑ Time Extension❑ Change Approved Program ❑ Operat.Shutdown❑ Stimulate-Other El Re-enter Suspended WOO `y�,� 2.Operator 4.Well Class Before Work: 5.Permit to Drill Number: Name: BP Exploration(Alaska),Inc Development 0 Exploratory ❑ 204-222-0 • 3.Address: P.O.Box 196612 Stratigraphit❑ Service ❑ 6.API Number: Anchorage,AK 99519-6612 50-029-20682-01-00 ' 7.Property Designation(Lease Number): 8.Well Name and Number: ADL0028306 • PBU 15-14A ' 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): PRUDHOE BAY,PRUDHOE OIL . 11.Present Well Condition Summary: Total Depth measured 13237 feet Plugs measured 12000 feet true vertical 8909.72 feet Junk measured None feet Effective Depth measured 12000 feet Packer measured See Attachment feet true vertical 8967.83 feet true vertical See Attachment feet Casing Length Size MD TVD Burst Collapse Structural None None None None None None Conductor 80 20"94#H-40 29-109 29-109 1530 520 Surface 2543 13-3/8"72#N-80 28-2571 28-2570.78 4930 2670 Intermediate None None None None None None Production 8546 9-5/8"47#L-80 27-8573 27-7230.83 6870 4760 Liner See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Perforation depth Measured depth 10775-10800 feet 10885-10910 feet 10980-11005 feet 11070-11150 feet 11250-11370 feet 11500-11600 feet 11650-11960 feet 12210-12390 feet 12550-13150 feet True Vertical depth 8987.1-8993.31 feet 9002.45-9002.07 feet 8998.57-8997.83 feet 8995.13-8987.28 feet 89.81.86-8976.13 feet 8972.61-8969.36 feet 8969.84-8967.7 feet 8966.85-8957.47 feet 8946.5-8912.72 feet Tubing(size,grade,measured and true vertical depth) 4-1/2"12.6#13Cr80 24-9781 24-8241.76 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): SCANNED '12'f\' .. 1 Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 812 56387 6 0 1001 Subsequent to operation: 0 0 0 0 0 14.Attachments: 15.Well Class after work: Copies of Logs and Surveys Run Exploratory❑ Development 0 • Service❑ Stratigraphic ❑ Daily Report of Well Operations X 16.Well Status after work: Oil U. Gas U 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 Garry Catron Email Garry.CatronBP.Com Printed Name Garry Catron Title PDC PE Signature ..kia■Ltt Phone 564-4424 Date 12/19/2013 VLG X- r R9T ; 6 ; DEC 2 0 24 7g// Form 10-404 Revised 10/2012 Submit Original Only Packers and SSV's Attachment ADL0028306 SW Name Type MD TVD Depscription 15-14A PACKER 8410 7047.21 7" Baker ZXP Packer 15-14A PACKER 9302 7786.97 4-1/2" Baker S-3 Perm Packer 15-14A PACKER 9791 8191.92 5" Baker ZXP Top Packer m Q,O00000 O D r-- O Q -N LO to 0 •. C) MNccc m a- rs CO CD CO N CO CO CO rs CO N- O co C)) O O M 0) N to N CO co I- N CO CA (A CO O N O N N a- N Co CD N OOMN � LOC�o 0) M lt) co 0) S CA Co N CA 0 „"Cl COCOCI rn ° � � aov CO N N N- N N N C co▪ 0 3▪ J Q o o o co co co Co J Z C d = J CCOO „ N y N *k N Cfl co N - c0 M N r CA co N 4 t C O N to to Ccoto totoN- J e- CO CO N a) Ce O O w U ZQ Z Z CC D j OJJ0- U) F- _ c m ca -0 O O -C'•a d C - Q O (0 o n m = c ° U c °o ° O U � C UO J a) -0 45 ED- o_ 0- C E °) co N O 0 C (6 o O N b ct cn co a) r Y 1 O ct � 0 wm M � rn U) a o cow rn a) N LC) a) c O ID a n2 E_ rn Q Q U oa o U p EL E (B O N + O ° N- ° Q (0 E Q CO 0) a) O O O as a 7 LE N -O 2 > ,- c -° ~ 0 c 3 a) c I o ) o° Q C v- D a) E C co U (0 O b c6 U) o O a) -C 0) H °) c a) Q N- C L N c U tg ,C O C o o O (0 a) (N ° c cu O 0) 0) U Q O * c C ° a all n O * J * L CO n MF- v o * M U . X ° a oU N A ° n � 2 v o M N- � y 0) bX v) 't i� u) o a) U) n C M O U V p - (vl CD 2 O Q C N = r-) O (n H EN N � .0 ) I 0 \ 0 C N p Q 2 'L N Q� a c CO X O L N Y (n L _ CD N � c E w = c �� ! -C E0 � � > Q E ca O a) cA u) E a) 3 N °o a o (O E ° ° a (nom O � E Q 2 L oio0N E - -° a) Mo n3 E Q a 3DN . `n o °��° (co CO 73 a (6 = = al 0 a N 70 OL LL ° a) 2 (0 _ O N 9-9- N a) a)0 Ora ca ° � II QE � u1 `_ * Q� Cam * Ocs-) N C m a C O Q) 41 a * C C , C * C N X (B J c °) n o° a s •c Q ccC a U = O cc c c\i c O Q U °) a) 0 Q n oho E � n w .E m � A 0 11 c n -c N O a�i oo * U U c rn�co A Q v J 3 a - co V co -° C U M Q }, U a) M U m > N 0 a .- co > 7 (n 09 v x- V O - f/2 CO * a) o � aM ° U2 E o c7 v a U b N � Eo c6 m n � o N 6- N E Z ° ' `t = O c a) _ � C v C c a) c o w c U c Q� c o) a) .E Y � a a '(Q cA Q-U 0 c LL ..--� _ C -� m .En ,- o ,_ a) co ,- 6 © •O Cl D a) °) n o - a Do �' -° = r O o CO 0 - O -J N ° - 2 m N o Q ° - o N co U °).- p n 0 0 O a (° U o c a3 o 0 a 2 c a) o a Q aa) � 'o c (,,- ° "'c _11 ) `(3 II 0- c ti ~ L m ctia en 1.n o . ','c to c c 4= to 0 O 0 0 O }C C ° E ° U O Q O= fl- N I-- CL U = o m U 0 Y N ID O 0*k (n .0 N D O *k W a co O It L N 0 O 41 (n m N _0 *k •c .Q N O _a * c a) • _o D � c -° Y v D -0 Eo vi) v D .( = c v � Q c rn� -J c E `t ,- -, cY a) D U � U ccu2 v U � U - av OU u) v U -3c Q* Hong)o o cow * UU2 .EU * tll Qco co co co co co O O O CD O O IF� N N CO N N N N N (p � N N N N N N 0 Q o a) v 0 o N- N J M co U as V � J LL F— 0 m ▪ I- Q O J Z Q 0 C Z O o- L U O O U Q. O 0_ co O O 0 O 0 G1 ccoo u H 0 N O 0 0 O < m II O J z 0 Q t Q ~ o� 0 aco Q II Q a> II Q- QUO E O >, E 0 -O > > O 2 0 > > o) 0 0 CD o CD CO M O c) U O ON co II © II II U Q .0 Q 0 II F Cn M M r r O O N N (Y) CO r � N N � r • TREE= 5X7 FMC 120S ViL LHFAD= FMC GEV1 15-14 A SAFE. ,O :W NGLE>—70° 10750'. ' S gG► ACTUATOR= BAKER C INITIAL KB.EL_E 59.5' BF.E LEV= KOP= 8573' 25' —15-1/T X 4-1/2"XO,D=3.958" Max Angle= 97°@ 11083' Datum ND= 10528' Datum ND= 8800'SS I ( 2167' H4-1/2"HES X NP,D=3.813" GAS LFT M4MJI S 13-3l8"CSG,72#,L-80,D=12.347" H 2572' ST ND ND DE V TY FE VLV LATCH PORT DATE I 4 3276 3268 15 NAG DONE RK 16 02/12/05 3 5479 5009 44 NMG SO RK 20 02/12/05 2 7466 6402 45 MMG DMY RK 0 01/25/05 Minimum ID =3.725" @ 9769 1 9087 7661 29 KBG2 DMY BK 0 01/25/05 4-1/2" HES XN NIPPLE l ...-( 840g' H9-5/8"X 7'ZXP LNR TOP PKR w/HGR I MIL LOUT WUM3OW (15-14A)8573'-858W 9281' I--14-1/2"FES X NP,D=3.813" (WHPSTOCK(01!12/05) 8573' I IEZSV(01/13/05) --I 8874' xvl 9302' —7"X 4 1/2"BKR S-3 PKR D=3.875" i e //1� 9328' 1--I4-1/2"HES X NP,D=3.813" 7J ' ■ • ( ■ ES 9769' 1—I4-1/2"H XN N�D=3.725' •[9-5/8"CSG,47#,L-80,D=8.681" H 10152' ® I . — 9780' 17"X 5"BKR ZXP LW w/TEBK SLV,D=4.440" 4-1/2"TBG,12.6#,13-CR 80 VAIN TOP,.0152 bpf,D=3.958" H 9781' IA 9781' —14-1/2"WLEG I7"LNR,26#,L-80 BIC-MOD,.0383 bpf,D=6.276"H 9932' 9802' 7"X 5"BKR MAC HGR PERFORATION SUMMARY ■ D=4.420" REF LOG:NM(01/23/05) ANGLE AT TOP F F:74°@ 10775' Note:Refer to Roduction DB for historical pert data ' SIZE SPF INTERVAL Opn/Sqz SHOT SQZ 2-7/8" 6 10775-10800 ' 0 11/27/13 ' 2-7/8" 6 10885-10910 0 11/27/13 ' 2-7/8" 6 10980-11005 0 11/26/13 2-1/2" 6 11070-11150 0 01/25/05 ' 2-1/2" 6 11250-11370 0 01/25/05 2-1/2" 6 11500-11600 O 01/25/05 2-1/T 6 11650-11960 0 01/25/05 I 12000' —14-1/2"BKR CBP(11/24/13) 2-1/2" 6 12210-12390 C 01/25/05 or 2-1/2" 6 12550-13150 C 01/25/05 PBTD — 13194' 444444 4-1/2"LNR,12.6#,L-80 BT-M,.0152 bpi,D=3.958" H 13237' �;�;�;MA DATE REV BY COTS DATE REV BY CONVENTS PRIUHOE BAY UNIT 12/22/81 _ MME3't ORIGINAL COMPLETION 12/03/13 JCF/JMD SET CIBP&ADFE RFS(11/24-27/13) WELL: 15-14A 01/27/05 N2ES _SIDETRACK(A) PERMIT No: 2042220 02/12/06 JPK/PJC GLV C/O AR No: 50-029-20682-01 11/13/06 TVVCIPJC DREG DRAFT CORRECTIONS SEC 22,T11 N,R14E,2349'FNL&1522'FWL 11/13/06 RAF/PJC DRLG DRAFT CORRECTIONS 12/17/11 SET/PJC GLV CORRECTIONS BP Exploration(Alaska) • BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB-20 Post Office Box 196612 Anchorage, Alaska 99519-6612 January 1, 2010 ~~~~; ~~~: JAS ~ ~'' 2~'`~` Mr. Tom Maunder ~'~ Alaska Oil and Gas Conservation Commission 0 ~ - ~,., 333 West 7t" Avenue /1 Anchorage, Alaska 99501 ~ ,.~ ~~ ~ 1-1 Subject: Corrosion Inhibitor Treatments of GPB DS 15 Dear Mr. Maunder, Enclosed please find multiple copies of a spreadsheet with a list of wells from GPB DS 15 that were treated with corrosion inhibitor in the surface casing by conductor annulus. The corrosion inhibitor is engineered to prevent water from entering the annular space and causing external corrosion that could result in a surface casing leak to atmosphere. The attached spreadsheet represents the well name, API and PTD numbers, top of cement depth prior to filling and volumes of corrosion inhibitor used in each conductor. As per previous agreement with the AOGCC, this letter and spreadsheet serve as notification that the treatments took place and meet the requirements of form 10-404,. Report of Sundry Operations. If you require any additional information, please contact me or my alternate, Anna Dube. Sincerely, Torin Roschinger BPXA, Well Integrity Coordinator a ~ BP Exploration (Alaska) Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) DS-15 Date: 01 /05/10 Well Name PTD # API # Initial top of cement Vol. of cement um ed Final top of cement Cement top off date Corrosion inhibitor Corrosion inhibitor/ sealant date ft bbls ft na al 15-01B 2042570 50029206960200 NA Sealed NA 15-02B 2060720. 50029206970200 NA Sealed NA 15-03 1820300 50029207220000 NA Sealed NA 15-048 2071380 50029207260200 NA Sealed NA 15-05A 1950340 50029207310100 NA Sealed NA 15-06A 1982540 50029207420100 NA 6.7 NA 40.8 11/7/2009 15-07C 2030970 50029211660300 NA 5 NA 34.0 11/10/2009 15-08C 2050050 50029211800300 NA 6.5 NA 45.9 11!28/2009 15-09A 1931380 50029212010100 NA 0.9 NA 5.1 11/11/2009 15-10A 1880850 50029205010100 NA Sealed NA 15-11 B 2041460 50029206530200 NA Sealed NA 15-12B 2060870 50029206650200 NA Sealed NA 15-13A 1991240 50029206450100 NA Sealed NA 15-14A 2042220 50029206820100 NA Sealed NA 15-15C 2081820 50029206910300 NA Sealed NA 15-16A 2011920 50029211150100 NA 0.3 NA 3.4 11/7!2009 15-17 1840890 50029211260000 NA 14.7 NA 132.6 12/4/2009 15-18A 2080830 50029222740100 NA 0.4 NA 1.7 11/11/2009 15-19A 1990990 50029218290100 NA surface NA 15-20C 2050930 50029211330300 NA 17 NA 120.7 12/2/2009 15-21A 1990290 50029205030100 NA Sealed NA 15-22 1800970 50029205090000 NA Sealed NA 15-23A 2031110 50029222250100 NA 0.7 NA 3.4 10/7/2009 15-24 1911280 50029222230000 NA 1.3 NA 10.2 10/7/2009 15-25B 2080240 50029218420200 NA 0.8 NA 6.8 11/12/2009 15-26B 2041590 50029222350200 NA 0.3 NA 1.7 10/8/2009 15-27 1920060 50029222430000 NA 0.3 NA 1.7 10/8/2009 15-28A 2031240 50029222470100 NA 0.5 NA 8.5 11/9/2009 15-296 2090380 50029222590200 NA 0.1 NA 1.7 11/10/2009 15-30A 2020890 50029222820100 NA 0.8 NA 5.1 11/11/2009 15-31B 2050860 50029222850200 NA 1.2 NA 3.4 11/11/2009 15-32A 2011840 50029224620100 NA 1.5 NA 10.2 10/7/2009 15-336 2031940 50029224480200 NA 1.6 NA 10.2 11/29/2009 15-34A 2001370 50029224740100 NA 1.4 NA 8.5 11/10/2009 15-35 1940880 50029224880000 NA 1.8 NA 15.3 11/10/2009 15-36B 2060730 50029224800200 NA 1 NA 5.1 11/10/2009 15-376 2040190 50029224850200 NA 1.3 NA 10.2 11/9/2009 15-38A 2030160 50029224960100 NA Sealed NA 15-39A 2060860 50029225030100 NA 0.3 NA 1.7 11/9/2009 15-40A 1980980 50029225110100 NA 1 NA 5.1 11/9/2009 15-41B 2011460 50029224920200 NA 1.2 NA 6.8 11/9/2009 15-42B 2090730 50029226240200 NA 1.5 NA 11.9 11/11/2009 15-44 1961100 50029226830000 NA 3.5 NA 30.6 12/17/2009 15-456 2071790 50029226710200 NA 1.7 NA 11.9 11 /8/2009 15-46 2041030 50029226650000 NA 1.9 NA 17.0 11 /912009 15-47 1951740 50029226170000 NA 1.5 NA 10.2 10/9/2009 15-486 2051660 50029226350200 NA 1.2 NA 10.2 10/8/2009 15-496 2090640 50029226510200 NA 7.3 NA 51.0 11/8/2009 • • _~r~_~, -• ~ o3io~~zoos DO NOT PLACE „_- ~1~,, ~,= __ ANY NEW MATERIAL UNDER THIS PAGE F:~LaserFiche\C~rPgs_InsertsuVlicrafilm Marker.doc )... ? F~~ DATA SUBMITTAL COMPLIANCE REPORT 1/30/2007 Permit to Drill 2042220 Well Name/No. PRUDHOE BAY UNIT 15-14A Operator BP EXPLORATION (ALASKA) INC MD 13227 Completion Date 1/27/2005 Completion Status 1-01L Current Status 1-01L TVD 8910 ----_.,._--------,-~ --~--------- St (,..d. Ii J~ ~e \J j- API No. 50-029-20682-01-00 --~---"~~._,~-_.._.~ -~-_._._----'-----~~~--~_.~-_.._'~._-_...__.---'--'..-- UIC N ----~._-------~ --~" REQUIRED INFORMATION Mud Log No Samples No -..'-~--~-.----~--~-.------~-~~--"--~~..--~-----~..-~-.---...-- Directional Survey Yes --~--. ------~_.._---"-------_._-_._-~--~---_..._---------_..----.. --~--~._._-- DATA INFORMATION Types Electric or Other Logs Run: DIR / GR / RES, PEX, DIR / GR / RES / NEU / ASI, SWC's Well Log Information: (data taken from Logs Portion of Master Well Data Maint Interval OH / Start Stop CH Received Comments --- 849S-13237-0pen2ì3/2005-'MWD-- ---..------------ -------1 8498 13237 Open 2/3/2005 IIFR I 8493 13167 Open 3/16/2005 GRlEWR4/ASIICNP/SLD/R ¡ OP j GR/EWR4/ABIICNP/SLD/R I OP I PEX-DSI-AIT Formation ' Eval AIT-DSI-TLD-CNL- I GPIT \ PEX-DSI-AIT Formation Eval AIT-DSI-TLD-CNL- I GPIT I ROP DGR EWR SLD CTN plus Graphics Log/ Electr Data Digital Dataset Type Med/Frmt Number ffo-OAsc--- ~. D Asc he; D Lis I I ~Pt I I Log Log Scale Media Run No Name Directional Survey Directional Survey _....~-~_.~..__._-----,.._----- 13078 Induction/Resistivity 8493 13167 Open 3/16/2005 8583 9916 Open 7/14/2005 8583 9916 Open 7/14/2005 8573 13237 Open 2/22/2006 13078 LIS Verification ~. Induction/Resistivity 25 Blu I t'D C Lis I J'ED C Lis l.__._____.._.._______~______._.._~_______________._.._..__-...__ 13235 Induction/Resistivity 13712 Induction/Resistivity . -- ~---~'-'---.----- i _____..______ .._..__.._.__.....__.. ....._ -...I . ----.-.-- Well Cores/Samples Information: Name Interval Start Stop Sample Set Number Comments Sent Received ADDITIONAL INFORMATION Well Cored? ~/N )w~~...~ a vv~ Chips Received? T I 14 , .. a l.... )t.{c.v'\..~to_ f"\N \)Jt.$Ul'uvHn........ "^- \. N-o Analysis b...-I- \..:,.)N _~~~~~? ________~!i.0_~~~~~~ V\.-L_____ Daily History Received? Y/N ~/N Formation Tops ---~--_.,---_._---~---- ._~--~~-----~------- -~~~~_.~..._-~_._~-------_._..- -- -_._---~-~-~._- Comments: DATA SUBMITTAL COMPLIANCE REPORT 1/30/2007 Permit to Drill 2042220 Well Name/No. PRUDHOE BAY UNIT 15-14A Operator BP EXPLORATION (ALASKA) INC MD 13227 TVD 8910 Completion Date 1/27/2005 Completion Status 1-01L Current Status 1-01L ~mp;a~':":VI":'d~Y~ _ jJo ... ~-.. - API No. 50-029-20682-01-00 UIC N Date: J~---=~ i==-= ---ð- . . L . . WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West ih Ave., Suite 100 Anchorage, Alaska 99501 February 16, 2006 131\~ RE: MWD Fonnation Evaluation Logs 15-14A, 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 15-14A: LAS Data & Digital Log Images: 50-029-20682-01 :JD4- ~ 'c}.~ 1 CD Rom ~1{ì 9'/~!J fat? 07/14/05 Schlumbergor NO. 3433 Alaska Data & Consulting Services 2525 Gambe" Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Company: State of Alaska Alaska Oil & Gas Cons Comm AUn: Helen Warman 333 West 7th Ave. Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay WI J b# D . I D t BL CI CD . e I 0 Loa escrlPt on ae o or 1-31/M-21 I .., 5' - 07 J. 10980540 RST (REVISED)* 04/14/05 1 I Ll ~J" 07 -34A C C . Oì 3 11001051 RST (REVISED)* 04/26/05 1 . LA" Y 15·14A ;' 04- Al~ 10913003 PEX-DSI-AIT 01/16/05 1 1 i? J. ) )-- y -23B ~ (J J .. i It; '1 10913024 PDC-GR . . 06/09/05 1 11 ;¿ J ,. N·08A J. \¡ 0.- ¿ (: q 10919802 LDL 09/24/04 1 K-08A À<:'~~ ~ í'"'iC, 10942219 MEM PPROF 06/24/05 1 W-26A I c\ '\ - C!l. \ 11051066 LDL 06/23/05 1 L5-09 ,('n;~ Ll.l.Î 11051037 RST 04/27/05 1 1 ¡ ~ J 7 OWDW-NW í cc '.. J..;'¡ ~ 10980537 RST . . 03/26/05 1 1 I' ). rR C-34 ¡9S' olr 10831309 RST 07/09/04 1 1 I ,2 c¡ 01-12A 2(.)....ll.ll 10928620 MCNL 04/03/05 1 1 , ).'-1 l \ DS 05-41A :l\::¡ >.- I It:. 10715377 MCNL . 01/21/04 1 1 j ¡ \..j I 02-26C ,:). l:;, \; - l'i \ q 10928619 MCNL 03/20/05 1 1 I ,141 'REVISED TO CORRECT API# ON DIGITAL DATA . PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COpy EACH TO: BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Date Delivered: ") \ '~ J.;,J 1 ..- Alaska Data & Consulting Services 2525 Gambe" Street, Suite 400 Anchorage. AK 99 03 2838 ATTN: Beth ; ~ oitJ M~,-·· Received by: . . ~ZJ'I- .22. O· r;..' CJ r-( --- Â ^ 1- -# I )01~ WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Helen Wannan 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 March 11, 2005 RE: MWD Fonnation Evaluation Logs: 15-14A, AK-MW-3494195 1 LDWG fonnatted Disc with verification listing. API#: 50-029-20682-01 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry Drilling Services Attn: Rob Kalish 6900 Arctic Blvd. Anchorage, Alaska 99518 BP Exploration (Alaska) Inc. Petro-Technical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Date: ¡{ufos Signdl¥l£4W~ v' . STATE OF ALASKA .. ALASK L AND GAS CONSERVATION COM~ION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1a. Well Status: a Oil 0 Gas 0 Plugged 0 Abandoned 0 Suspended 0 WAG 20AAC 25.105 20AAC 25.110 One Other 5. Date Comp., Susp., or Aband. 1/27/2005 6. Date Spudded 1/14/2005 21. Logs Run: DIR / GR / RES, PEX, DIR I GR / RES / NEU / ABI, SWC's GASING, LINER AND CEMENTING RECORD SETTING EPTH Me I SETTING I EPTH TVD HOLE GRADE lOP BOTTOM lOP BOTTOM SIZE H-40 Surface 80' Surface 80' 30" L-80 Surface 2572' Surface 2572' 17-1/2" L-80 / S0095 Surface 8573' Surface 7231' 12-1/4" L-80 8410' 9932' 7105' 8368' 8·1/2" L-80 9779' 13237' 8240' 8910' 6·1/8" 26. PRODUCTION TEST Date First Production: Method of Operation (Flowing, Gas Lift, etc.): February 13, 2005 Flowing Date of Test Hours Tested PRODUCTION FOR Oll-BBl 2/28/2005 6.1 TEST PERIOD ... 753 Flow Tubing Casing Pressure CALCULATED + Oll-BBl Press. 984 740 24-HOUR RATE 2,961 27. o GINJ 0 WINJ 0 WDSPL 2. Operator Name: BP Exploration (Alaska) Inc. 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 4a. Location of Well (Governmental Section): Surface: 2349' SNL, 1522' EWL, SEC. 22, T11N, R14E, UM Top of Productive Horizon: 870' SNL, 904' WEL, SEC. 28, T11N, R14E, UM Total Depth: 3794' SNL, 640' WEL, SEC. 21, TUN, R14E, UM 4b. Location of Well (State Base Plane Coordinates): Surface: x-_ 6774~_ y- 5959168 Zone- ASP4 TPI: x- 675154 y- 5955312 Zone- ASP4 Total Depth: x- 675358 y- 5957672 Zone- ASP4 - -- - - - - -- 18. Directional Survey a Yes 0 No No. of Completions 2. CASING SIZE 20" 13-3/8" 9-518" 7" 4-1/2" Wr.PER Fr. 91.5# 72# 47# 26# 12.6# 23. Perforations open to Production (MD + TVD of Top and Bottom Interval, Size and Number; if none, state "none"): 2-1/2" Gun Diameter, 6spf 2-7/8" Gun Diameter, 6 spf MD TVD MD TVD 11070' - 11150' 8995' - 8987' 12210' - 12390' 8967' - 8957' 11250' - 11370' 8982' - 8976' 12550' -13150' 8947'·8913' 11500' - 11600' 8973' - 8969' 11650' - 11960' 8970' - 8968' .4"'1'\ .~. "', DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 2200' Freeze Protected with 155 Bbls of Diesel 7. Date T.D. Reached 1/22/2005 8. KB Elevation (ft): 58.18' 9. Plug Back Depth (MD+ TVD) 13152 + 8913 10. Total Depth (MD+TVD) 13237 + 8910 11. Depth where SSSV set (Nipple) 2143' MD 19. Water depth, if offshore NI A MSL 24. SIZE 4-1/2", 12.6#, 13Cr80 25. GAs-McF 6,949 GAs-McF 27,340 WATER-BBl -0- WATER-BBl -0- RECEIVED MAR 08 2005 AI..". ".. 1 b. Well Class~ ..." Of fil' Cant. C r)mr.. > a Development []~r.~t0r1°""'1 S,lor o Stratigraphic 0 'sëPIHtwe 12. Permit to Drill Number 204-222 13. API Number 50- 029-20682-01-00 14. Well Name and Number: PBU 15-14A 15. Field I Pool(s): Prudhoe Bay Field / Prudhoe Bay Pool Ft Ft 16. Property Designation: ADL 028306 17. Land Use Permit: 20. Thickness of Permafrost 1900' (Approx.) AMOUNT PULLED .... 300 sx Permafrost II 300 sx Fondu, 400 sx Permafrost 'C' 00 sx Class 'G' 00 sx Class 'G' 13 sx Class 'G' "TIIA''''~ DEPTH SET (MD) 9757' PACKER SET (MD) 9278' ,... ETC. CHOKE SIZE 48 Oil GRAVITy-API (CORR) GAS-Oil RATIO 9,232 CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water (attach separate sheet, if necessary). Submit core chips; if none, state "none". None ri;6,;X;f?~¡¡~;Ñ 1 '. fj""\ '% ~ . '\,.,',~, '1 ..... ~ ~ { ¡ V":'1:F'ED . ì.' Vt:jJ!1 ! . JÍL-~ -. Form 1 0-407 Revised 12/2003 t"""", f ), , I ,_J IO'~'I\L j lJ I ¡'\1 /-, CONTINUED ON REVERSE SIDE RBDMS 8FL MAR 0 4 2aO~ G~ 28. GEOLOGIC MARKERS 29. ORMATION TESTS NAME MD TVD Include and briefly summarize test results. List intervals tested, and attach detailed supporting data as necessary. If no tests were conducted, state "None". Shublik 9985' 8413' None Sadlerochit 10062' 8480' Top CGL Base CGL 10243' 10325' 8631' 8699' 23SB / Zone 2B 10404' 8764' 22TS 10458' 8806' 21TS / Zone 2A 10548' 8872' Zone 1 B 10640' 8927' TDF / Zone 1A 10721' 8968' 30. List of Attachments: Summary of Daily Drilling Reports. Side Wall Core Summary, Well Schematic Diagram, Surveys 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed Terrie Hubble Title Technical Assistant Date 03 ..0 Z"'QS" PBU 15-14A Well Number Prepared By Name/Number: Drilling Engineer: Terrie Hubb/e, 564-4628 Phil Smith, 564-4897 204-222 Permit No. / A roval No. INSTRUCTIONS GENERAL: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. ITEM 1a: Classification of Service Wells: Gas Injection, Water Injection, Water-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 interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). ITEM 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection. Gas Injection, Shut-In, or Other (explain). ITEM 27: If no cores taken, indicate "None". ITEM 29: List all test information. If none, state "None". Form 1 0-407 Revised 12/2003 Submit Original Only Legal Name: 15-14 Common Name: 15-14 1/7/2005 1/13/2005 1/18/2005 FIT FIT FIT (ft) 8,605.0 (ft) 9,932.0 (ft) (ft) 7,250.0 (ft) 8,385.0 (ft) (ppg) 10.50 (ppg) 8.40 (ppg) (psi) 565 (psi) 696 (psi) (psi) 4,520 (psi) 4,355 (psi) 10.05 (ppg) 12.00 (ppg) 10.00 (ppg) Printed: 1/31/2005 8:00:34 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 15-14 15-14 REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 2ES Start: Rig Release: Rig Number: 1/7/2005 1/27/2005 Spud Date: 11/30/1981 End: 1/27/2005 1/7/2005 16:00 - 22:45 6.75 MOB P PRE Rig released from 05-20B @ 1600. Lower Derrick. RDMO 05-20B. 22:45 - 00:00 1.25 MOB P PRE Move Sub from 05-20B to 15-14A. 1/8/2005 00:00 - 12:30 12.50 RIGU P PRE Move sub to 15-14A. Spot sub over the well. Move camp, pits and shop. Lay Herculite. Raised derrick. RlU on rig floor. Bridle down. Spot shop and cuttings tank. Rig accepted 1230 hrs 1/8/05. 12:30 - 13:00 0.50 WHSUR P DECOMP Held Pre-Spud safety and environmental meeting. 13:00 - 15:00 2.00 WHSUR P DECOMP Install secondary annular valve. RlU DSM and pulled BPV. 15:00 - 17:30 2.50 WHSUR P DECOMP Test lines to 4000 psi. Pump down annulus and recover diesel freeze protect. Pump down tubing and displace well to 8.4 ppg seawater. Well is dead. 17:30 - 18:00 0.50 WHSUR P DECOMP Installed BPV. Tested to 1000 psi. RID. 18:00 - 00:00 6.00 WHSUR N WAIT DECOMP Shut down rig operation due to phase 3 weather as per recommendation by BP safety. 1/9/2005 00:00 - 00:00 24.00 WHSUR N WAIT DECOMP Wait on Weather. Phase 3 conditions. Change out crews at 1200 hrs as allowed by IMT. 1/10/2005 00:00 - 00:00 24.00 WHSUR N WAIT DECOMP Phase 3 weather conditions. Circulate well thru BPV @ 1bpm. 1/11/2005 00:00 - 06:00 6.00 WHSUR N WAIT DECOMP WOW. Continued to circulate @ 1 bpm. Field went to Phase 2 with Phase 3 on access roads and pads at 5:15am. Received permission to start cleaning out access road and return to work @ 5:45am. 06:00 - 07:00 1.00 WHSUR P DECOMP Test BPV from below to 1,000 psi. Blow down surface equipment. 07:00 - 10:00 3.00 WHSUR P DECOMP NO tree and adapter flange. Function the lock down screws. Install blanking plug. 10:00 - 13:00 3.00 BOPSU P DECOMP NU BOPE. 13:00 - 20:00 7.00 BOPSU P DECOMP MU test joint. Test pipe rams and related valves to 250 psi I 3,500 psi. Test annular preventer to 250 psi 12,500 psi. Witness of the BOP test was wavied by John Spaulding of the AOGCC. RD test joint. 20:00 - 21 :00 1.00 PULL P DECOMP RU DSM lubricator and and pull BPV. RD lubricator. 21 :00 - 21 :30 0.50 PULL P DECOMP MU Baker double grapple spear and RIH. Engage tubing. 21 :30 - 22:30 1.00 PULL P DECOMP BOLDS and pull hanger to the rig floor - max pull - 160K. LD hanger. 22:30 - 23:00 0.50 PULL P DECOMP RD spear. Clear the floor. 23:00 - 00:00 1.00 PULL P DECOMP RU tubing handling equipment. RU control line spooling unit. 1/12/2005 00:00 - 02:00 2.00 PULL P DECOMP POH with 2,128' of 5-1/2" 17#, L-80, 8rd AB-Mod PC tubing while spooling two control lines with Camco Spooling unit. Recovered 25 Clamps, 25 Pins and 2 Stainless Steel Bands 02:00 - 02:30 0.50 PULL P DECOMP RD Camco Spooling unit. 02:30 - 08:30 6.00 PULL P DECOMP LD SSSV. POH with remaining 5-1/2" tubing. RID 5.5" handling equip. Clear and clean rig floor. Recovered, 206 jts 5.5" tbg, 21.21' cut jt. 08:30 - 10:00 1.50 BOPSU P DECOMP R/U 4" test equip. Attempt to test BOPS. Test plug failure, pull test plug, install wear ring. 10:00 - 15:30 5.50 PXA P WEXIT PJSM, RU Schlumberger, RIH with 8.5" GRlJB, tag tbg stub @ 8620'. POH. RIH with EZSV and set @ 8529'. POH with running tool, rig down Schlumberger. Clear and clean rig floor. 15:30 - 16:00 0.50 PXA P WEXIT Test EZSV and 9 5/8" csg to 3500 for 30 min. chart and hold. Blow down surface equip. 16:00 - 18:00 2.00 BOPSU P WEXIT Pull wear rig. Make up test jt. Test rams to to 250 and 3500 psi. Printed: 1/31/2005 8:00:40 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 15-14 15-14 REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 2ES Start: Rig Release: Rig Number: 1/7/2005 1/27/2005 Spud Date: 11/30/1981 End: 1/27/2005 Test annular to 2500. RID test equip. Set wear ring. PJSM. MIU, orient and upload MWD tools. Shallow test MWD @ 525 GPM @ 650 PSI. Blow down surface equip. MIU whipstock and RIH to 1048'. Change out handling equip. Clear floor. Note: BHA = btm trip anchor, Whipstock, starting mill, lower string mill, upper string mill, 1 x 5" HWDP, float sub, MWD, UBHO sub, bumper sub, 9 x DCs, 21 x 5" HWDP, XO 23:00 - 00:00 1.00 STWHIP P WEXIT Pick up 4" drill pipe from 1048' to 1982' 1/13/2005 00:00 - 06:30 6.50 STWHIP P WEXIT Pick up 4" drill pipe from 1982' to 8480. Fill pipe every 3000'. 06:30 - 07:30 1.00 STWHIP P WEXIT Service top drive, brake links and drawworks. Install blower hose. 07:30 - 08:30 1.00 STWHIP P WEXIT Lift sub base, open cellar doors and remove tree from cellar. [Tree left in cellar due to high wind conditions during nipple down.] Put cellar back together. 08:30 - 11 :00 2.50 STWHIP P WEXIT Fill pipe and orient whipstock 45 degrees LHS. RIH from 8480' to 8597' [68' deep], tag EZSV 11 :00 - 12:00 1.00 STWHIP P WEXIT Pump 45 bbl high vis sweep, displace well to 10.5 PPG LSND mud. Pump @ 13 BPM @ 1600 PSI. 12:00 - 12:30 0.50 STWHIP P WEXIT Set whipstock 47 degrees LHS top of window @ 8573', bottom of window @ 8589'. 12:30 - 18:00 5.50 STWHIP P WEXIT Milling window and new formation from 8573' to 8605'. PU-180K, SO-145K, ROT - 160K, TO off -8K, TO on -10K 18:00 - 19:30 1.50 STWHIP P WEXIT Pump high vis sweep @ 8605'. CBU 500 GPM @ 2100 PSI. Work window clean and pull into casing. 19:30 - 20:30 1.00 STWHIP P WEXIT Perform FIT W 110.5 PPG mud to 12.0 PPG-565 PSI surface pressure. Monitor well. Pump dry job. Blow down surface equip. Remove blower hose. 20:30 - 23:00 2.50 STWHIP P WEXIT POH from 8605' to 1048' 23:00 - 00:00 1.00 STWHIP P WEXIT Stand back BHA F/1048' T/100'. Handle BHA to 44'. 1/14/2005 00:00 - 01 :00 1.00 STWHIP P WEXIT LD BHA, upper string mill [full gauge] Clear rig floor. 01 :00 - 02:00 1.00 BOPSU P WEXIT Pull wear ring. Flush and function BOPS. Install wear ring. 02:00 - 04:30 2.50 STWHIP P WEXIT MU 8.5" BHA to 106'. Upload and surface test MWD @ 485 GPM @ 920 PSI. MU BHA to 1186' 04:30 - 05:30 1.00 STWHIP P WEXIT CO handling equip. PU 4" DP from 1186 to 2585'. 05:30 - 08:00 2.50 STWHIP P WEXIT RIH from 2585' to 8467'. Fill pipe @ 3000' intervals. 08:00 - 08:30 0.50 STWHIP P WEXIT Fill pipe. Orient TF 45 LHS. Install blower hose on Top Drive. Check slow pump rates @ 8467'. Slide through window to 8592'. Ream undergauge hole to 8605'. 08:30 - 00:00 15.50 DRILL P INT1 Drill 8.5" hole directionally from 8605' to 9307'. PU wt = 195K, SO wt = 140K, ROT = 170K, TO on = 9K, TO off = 8K. AST = 7.02, ART = 4.05. 1/15/2005 00:00 - 09:30 9.50 DRILL P INT1 Drill 8.5" hole directionally from 9307' to 9909'. PU wt = 230K, SO wt = 155K, ROT = 185K, TO on = i0/14K, TO off = 7/9K. AST - 1.43, ART - 4.90. 09:30 - 16:30 7.00 DRILL P INn Drill 8.5" hole from 9909' to 9914'. Circ. up sample for Geologist. Drill to 9920', circ. up sample. Drill to 9926', circ. up sample. Drill to TO @ 9932', circ up sample. 16:30 - 17:30 1.00 DRILL P INT1 POH from 9932' to 9 518" csg @ 8561 '. [Short trip] 17:30 - 18:30 1.00 DRILL P INn Cut 109' drill line. 18:30 - 19:00 0.50 DRILL P INTi Service Top Drive 19:00 - 20:00 1.00 DRILL P INT1 RIH from 8561' to btm @ 9932'. [Short trip] Printed: 1/31/2005 8:00:40 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 15-14 1 5-14 REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 2ES Start: Rig Release: Rig Number: Spud Date: 11/30/1981 End: 1/27/2005 1/7/2005 1/27/2005 1/15/2005 20:00 - 21 :30 1.50 DRILL P INT1 21 :30 - 00:00 2.50 DRILL P INT1 1/16/2005 00:00 - 02:00 2.00 DRILL P INT1 02:00 - 06:00 4.00 DRILL P INT1 1/17/2005 00:00 - 04:30 4.50 CASE P LNR1 04:30 - 08:30 4.00 CASE P LNR1 08:30 - 09:30 1.00 CASE P LNR1 09:30 - 10:00 0.50 CASE P LNR1 10:00 - 10:30 0.50 CEMT P LNR1 10:30 - 11 :30 1.00 CEMT P LNR1 11 :30 - 13:00 1.50 CEMT P LNR1 Circ. high vis sweep around, @ 520 GPM @ 3100 psi. Spot 100 bblliner running pill, pump dry job. Drop 2.25" drift down drill pipe. POH from 9932' to 5294' for Platform Experss logs and side wall cores. POH from 5294' to 1186'. PJSM. LD BHA from 1186'. Clean and clear floor. Dims Daily Report continued on Well 15-14, Re-enter and Complete 1/16/2005 Logging - AFE PBD4P2332 Dims Daily Report continued from Well 15-14, Re-enter and Complete 1/16/2005 Logging - AFE PBD4P2332 PJSM with all hands. Rig up casing tools and RIH with 7" 26# BTC-M L-80 liner. Circ. liner capacity & RIH with liner on 4" DP to 8510', Fill pipe @ 10 std intervals. Circ. 1.5 times liner and DP cap. @ 4.5 BPM @ 780 PSI. 7 BPM @ 960 PSI. 8 BPM @ 1180 PSI. PU = 21 OK, SOW = 125K RIH through open hole from 8510' to 9908' MU cmt head and single of DP. Tag btm @ 9932' Break circ @ .5 BPM @ 570 PSI, stage up @ 4 BPM @ 780, 5.5 BPM @ 1075 & 6 BPM @ 1180 PSI. PU = 210K, SOW = 125K RU Schlumberger Cementers. Pump 5 bbls of water ahead through "T" Shut Down and test lines to 4,500 psi. Bleed pressure. Mix 11.5 ppg Mudpush Spacer. Pump 2 bbls of 11.5 ppg Mudpush through "T" to flush water from the lines. Pump 25 bbls 11.5 ppg Spacer @ 3 bpm, 800 psi initial, 700 psi final. Shut down. Mix 15.8 ppg Slurry. Pump 62 bbls 15.8 ppg Class G + adds Tail Slurry @ 4 bpm, 1000 psi initial, 300 psi final. Shut down. Flush cement through "T" with 10.5 ppg mud Drop Dart. Start Displacement with Dowell Pump Unit using 10.5 ppg mud @ 6 bpm, 770 psi initial. Catch falling cement @ 43 bbls into displacement At 69 bbls displacement, slow rate to 2 bpm to pick up plug Observe dart latch into plug @ 81 bbls displacement pumped. Increase rate to 6 bpm and continue displacement. Drop rate to 3 bpm to bump the plug - final pressure prior to bump was 1200 psi. Bump plug @ 138 bbls pumped with 4,500 psi. and hold for 5 minutes - pressure holding. Bleed off pressure and check floats - holding. CIP @ 12:40 hours 1/17/2005. Observed good lift pressure and retum flow line indication throughout the entire job. Printed: 1/31/2005 8:00:40 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 15-14 15-14 REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 2ES Start: Rig Release: Rig Number: 1/7/2005 1/27/2005 Spud Date: 11/30/1981 End: 1/27/2005 1/17/2005 13:00 - 14:30 1.50 CEMT P LNR1 Circ. excess cmt to surface [trace of cmt in returns] Pump @ 11 BPM @ 2700 PSI, pump dry job. 14:30 - 18:30 4.00 CEMT P LNR1 LD cmt head, POH W/DP from 8409' to running tool. LD running tool. 18:30 - 21 :00 2.50 DRILL P PROD1 MU BHA to 361 '. Orient MWD, upload. Surface test MWD @ 235 GPM @ 1120 PSI. CO handling equip. 21 :00 - 23:30 2.50 DRILL P PROD1 PU DP from 361' to 4286' 23:30 - 00:00 0.50 CASE P LNR1 Break circ. Test 7" X 9 5/8" csg to 3500 psi for 30 min. OK. 1/18/2005 00:00 - 00:30 0.50 CASE P LNR1 Test 7" X 9 5/8" csg to 3500 psi for 30 min. OK. Blow down surface equipment. 00:30 - 02:30 2.00 DRILL P PROD1 RIH with 4" DP and 6.125 BHA from 4286' to 9702', fill pipe, remove air slips. 02:30 - 04:30 2.00 DRILL P PROD1 Wash from 9702' to landing collar @ 9846'. Drill cement, float equipment & cement to 9929' [top of shoe] 30 RPM, 10K WOB, 8K TO 04:30 - 08:30 4.00 DRILL P PROD1 Pump 100 bbl fresh water, 42 bbl spacer & displace well to 8.4 ppg FloPro mud. Clean possum bellys & troughs. 08:30 - 09:00 0.50 DRILL P PROD1 Drill shoe @ 9932' & 20' new hole to 9952'. 09:00 - 09:30 0.50 DRILL P PROD1 Perform FIT to 10.0 ppg EMWT with 8.4 ppg mud. 09:30 - 00:00 14.50 DRILL P PROD1 Directionaly drill from 9952' to 10356'. RWT = 170K, UWT = 185K, DWT = 150K ART = 4.13 hrs AST = 7.1 hrs. Torque on btm = 5400. Motor bend set @ 1.83 1/19/2005 00:00 - 14:30 14.50 DRILL P PROD1 Drill and slide from 10356' to 10774'. GPM = 256/1689 psi. WOB = 10 to 15 K. Bit RPM = 124. On btm TO = 5/7K. UWT = 195K, RWT = 175K, DWT = 150K. 14:30 - 15:00 I 0.50 DRILL P PROD1 POH 2 stands of drill pipe, inspect derrick for ice or snow build up, OK. RIH. 15:00 - 21 :00 6.00 DRILL P PROD1 Drill from 10744' to 10916'. 21 :00 - 21 :30 0.50 DRILL P PROD1 Pump hi vis sweep up to 7" csg, rotate & recip. 255 GPM @ 1600 PSI> 21 :30 - 22:00 0.50 DRILL P PROD1 POH from 10916' to 9885'. Hole in good shape. 22:00 - 23:00 1.00 DRILL P PROD1 Drop dart & open circ sub. CBU @ 470 GPM @ 1320 PSI. Pump dry job, blow down surface equip. 23:00 - 00:00 1.00 DRILL P PROD1 POH for bit & BHA from 9885' to 7648' 1/20/2005 00:00 - 02:30 2.50 DRILL P PROD1 POH with BHA #3 to 361' 02:30 - 04:00 1.50 DRILL P PROD1 Break bit, down load MWD, LD MWD & mud motor 04:00 - 07:00 3.00 DRILL P PROD1 PU mud motor & MWD, orient, PU nuetron density tool. MU & install pulsar. Up load. Install sources & MU BHA to 387' 07:00 - 10:30 3.50 DRILL P PROD1 RIH from 387' to 9915', fill @ 3000' intervals. Install blower hose. Pass shoe @ 9932', RIH to 10848' 10:30 - 12:00 1.50 DRILL P PROD1 Wash & ream from 10848' to btm @ 10916'. [hole in good shape] MADD pass from 10916' to 10755' @ 225 FPH, rotating @ 6 RPMs & pumping @ 95 GPM @ 600 PSI. TO = 5/6K. Pump up surveys on connections. 12:00 - 17:00 5.00 DRILL P PROD1 MADD pass from 10755' to 10320' @ 255 FPH rotating @ 6 RPMs & pumping @ 320 GPM @ 2250 PSI. RIH to 10916' re-Iog from 10916' to 10720' RIH to btm @ 10916' 17:00 - 00:00 7.00 DRILL P PROD1 Drill 6 1/8" hole from 10916' to 11083'. ART = 0, AST = 4.35 hrs. TVD = 8995'. UWT = 190K, DWT = 150K, RWT = 175K, TO off btm = 6K, TO on = 7K. WOB = 10K, RPM @ bit = 290, pump = 2300 PSI @ 325 GPM. 1/21/2005 00:00 - 00:00 24.00 DRILL P PROD1 Drill 6 1/8" hole from 11083' to 12405', PDC bit, Nuetron Printed: 1/31/2005 8:00:40 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 15-14 15-14 REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 2ES Start: Rig Release: Rig Number: 1/7/2005 1/27/2005 Spud Date: 11/30/1981 End: 1/27/2005 1/21/2005 00:00 - 00:00 24.00 DRILL P PROD1 density tools. WOB = 7/15K, Rot @ 80 RPM, Pump @ 2650 PSI @ 325 GPM. UWT = 195K, DWT = 135K, RWT = 170K. TO on btm = 9K, TO off btm = 7K. Pump high vis sweeps as required. Hole in good shape. 1/22/2005 00:00 - 11 :30 11.50 DRILL PROD1 Drill 6 1/8" hole from 12405' toTO @ 13237'. Pump weighted sweep. @ 12660'. Diffacult to slide, lube = 4%. WOB = 15K, pump = 66 SPM @ 2600 PSI, Rotate @ 80 RPM, HWT = 200K, DWT = 125K, RWT = 165K, TO = 9K. TVD = 8910' 11 :30 - 13:30 2.00 DRILL PROD1 Pump Hi-vis sweep @ 225 GPM @ 2200 PSI. Pump dry job. Monitor well. 13:30 - 15:00 1.50 DRILL PROD1 POH from 13237' to 9915' max pull = 225K 15:00 - 16:30 1.50 DRILL PROD1 Remove dwks drum guard, replace glycol fitting. Cut & slip 100' drill line. 16:30 - 17:00 0.50 DRILL PROD1 Service top drive & crown. 17:00 - 18:30 1.50 DRILL PROD1 RIH from 9915' to 13180', break circ, tag btm @ 13237' Max down wt == 110K 18:30 - 21 :00 2.50 DRILL PROD1 Pump sweep & circ out @ 350 GPM @ 2250 PSI. Rotate & reciprocate. Spot liner pill with dry job. 21 :00 - 00:00 3.00 DRILL PROD1 POH from 13237' to 9915', hole in good shape. Remove blower hose, install air slips. Drop dart & open circ sub. POH for 4.5" production liner. 1/23/2005 00:00 - 03:00 3.00 P PROD1 POH with 6 1/8" PDC bit & BHA for 4.5" production liner. Well TO @ 13237', TVD @ 8910'. Liner pill spotted on bottom. Hole in good shape. POH to 378' 03:00 - 04:00 1.00 DRILL P PROD1 LD HWDP, JARS & DCs. Unload nukes. 04:00 - 05:30 1.50 DRILL P PROD1 Down load MWD 05:30 - 06:30 1.00 DRILL P PROD1 LD MWD & subs LD bit & mud motor. Clear rig floor 06:30 - 07:30 1.00 CASE P RUNPRD Rig up casing tools, hold PJSM. 07:30 - 12:00 4.50 CASE P RUNPRD RIH with 4.5", 12.6# L-80 BTC-M liner, PU packerlhanger & fill liner top with gel. 12:00 - 13:00 1.00 CASE P RUN PRO Pack liner top with gel. Circ liner volume. Adjust link tilt arm. 13:00 - 16:30 3.50 CASE P RUNPRD MU 5' DP pup & RIH with 4.5" liner on drill pipe to 9915'. Fill pipe @ 10 std intervals. 16:30 - 17:00 0.50 CASE P RUN PRO Circ. DP & liner volume. Stage pump up. 3 BPM @ 320 PSI, 4 BPM @ 390, 5 BPM @ 440, 6 BPM @ 530 PSI. UWT == 163K, DWT == 135K. 17:00 - 19:00 2.00 CASE P RUN PRO RIH from 9915' to 13216'. MU cement head & jt. of DP. Wash down to btm @ 13237' 19:00 - 21 :00 2.00 CEMT P RUNPRD Circ & reciprocate, stage pump up to 6 BPM @ 1090 PSI. Max UWT == 225K, DWT = 130K, Hold PJSM with 2ES crew, Baker, Schlumberger & Veco. Batch up. 21 :00 - 00:00 3.00 CEMT P RUNPRD Pump 5 BBL of H20 & test lines to 4500 PSI. Pump 15 BBLs of 15.8 preflush, 30 BBLs of 9.5 spacer & 80 BBLs of 15.8 PPG latex cement. Wash up to tee on rig floor. Kick out wiper plug with perf pill, displace with Dowell. Bump plug. CIP @ 23:00 hrs. Press. up to 2700 PSI & set hanger, slack off to verify set. Check floats. Press. up to 3500 PSI, bleed off press. PU & set packer, saw 1 shear indication. Rotate @ 15 RPM, set down on packer, no further indication of set. Press. up to 1000 psi & unsting. Displace cement to surface. 1/24/2005 00:00 - 01 :30 1.50 CASE P RUNPRD Circ. cement off top of 4.5" liner, 13 BBLs back. Break down cement head. 01 :30 - 04:00 2.50 CASE P RUN PRO Displace well to seawater, clean shakers, possum bellys and Printed: 1/31/2005 8:00:40 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 15-14 15-14 REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 2ES Start: Rig Release: Rig Number: 1/7/2005 1/27/2005 Spud Date: 11/30/1981 End: 1/27/2005 lines. POH, with 4" drill pipe & 4.5" liner running tool. Pull wear ring, test BOP to 250/3500 PSI. Test annular preventer to 250/2500, test with 4" & 4.5" test jts. Witness of test waived by Lou Grimalde 10:30 - 11 :00 RUN PRO Pull test plug, LD test jt, set wear ring & blow down lines. 11 :00 - 11 :30 RUNPRD RU & test Top Drive valves to 2501 3500 PSI. 11 :30 - 12:30 RUN PRO RU & test 4.5" liner to 3500 PSI for 30 min. OK, blow down lines 12:30 - 14:00 1.50 OTHCMP PJSM, RU to run perf. guns 14:00 - 17:00 3.00 OTHCMP PJSM, PU 2 7/8" perf guns & 6 jts of 2 7/8" PAC drill pipe 17:00 - 18:00 1.00 OTHCMP Wait on Schlumberger sub/xo for 2 1/2" guns. (Had the wrong size for the 2 1/2" guns) 18:00 - 20:30 2.50 OTHCMP PU 2 1/2" perf guns, 2 7/8" PAC drill pipe & 10 HT-40 drill pipe & pup jt, RIH to 3540' UWT = 60K, DWT = 60K. 20:30 - 00:00 3.50 OTHCMP RIH with perf guns on 4" drill pipe to 13070' 1/25/2005 00:00 - 00:30 0.50 OTHCMP PJSM to fire guns. Pressure to 3000 psi to fire guns. Perf 131501 12550 : 12390/1221 0: 11960/11650: 11600/11500: 11370/11250: 11150/11070 00:30 - 01 :30 1.00 OTHCMP POHF13150t011015 01 :30 - 02:00 OTHCMP Monitor well for losses 2 bbls loss in 15 minutes 02:00 - 06:30 OTHCMP POH & LD DP TO 3527' 06:30 - 08:00 1.50 PERFO OTHCMP R/U & LD 2 7/8" DP 08:00 - 11 :00 3.00 PERFO OTHCMP RU & LD 21/2" guns (all guns fired) 11 :00 - 11 :30 0.50 PERFO OTHCMP UD 6 jts 2 7/8" DP 11 :30 - 12:00 0.50 PERFO OTHCMP CO handling equipmet to LD 2 7/8*" guns 12:00 - 16:00 4.00 PERFO OTHCMP UD 2 7/8" guns (all guns fired) 16:00 - 18:00 2.00 RUNCO RUNCMP M/U mule shoe & RIH with 4" DP 18:00 - 22:00 4.00 RUNCO RUNCMP UD 4" DP 22:00 - 00:00 2.00 RUNCO RUNCMP Pull WR & RU to run 4.5 tubing 1/26/2005 00:00 - 13:30 13.50 RUNCO RUNCMP Run 4 1/2" tubing. Space out 13:30 - 15:00 1.50 RUNCO RUNCMP Rig down compensator. MIU landing joint & hanger. Land tuning and real ease. Pull landing joint and LD same. 15:00 - 19:00 4.00 RUNCMP Rig up to circulate. Circulate 92 BBls inhibited sea water and displace with SW (497 BBL's) 19:00 - 21 :00 2.00 RUNCMP Install Landing Jt, drop ball & rod. LD landing joint. Close blind rams & pressure up to 3500 psi and set packer. Test tubing to 3500 psi 30 minute. Test tubing annular to 3500 psi, tested OK. Bleed off and shear DCK 21 :00 - 22:00 1.00 RUNCMP Drain Stack, install TWC and test to 1000 psi, break and blow down lines. 22:00 - 23:00 1.00 BOPSU RUNCMP NID BOP and blow down all mud lines 23:00 - 00:00 1.00 BOPSU RUNCMP NU well head adapter. 1/27/2005 00:00 - 00:30 0.50 RUNCO RUNCMP NU Tree & Flange 03:00 - 02:30 23.50 RUNCO RUNCMP NIU tree and test to 5000 psi. 02:30 - 05:00 2.50 RUNCO RUNCMP Rig up lubricator and pull TWC. Test Tree to 5000. Rig down lubricator. 05:00 - 08:30 RUNCMP Rig up Hot Oil and freeze protect. Pressure test lines to 2500 psi. Pump freeze protect to 2200 feet and U-tube 08:30 - 09:30 RUNCMP Set Back Pressure Valve and test from below to 1000 psi. Printed: 1/31/2005 8:00:40 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 15-14 15-14 REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 2ES Start: 1/7/2005 Rig Release: 1/27/2005 Rig Number: Spud Date: 11/30/1981 End: 1/27/2005 Rig down Hot Oil, all lines and hoses. Remove annular valve and secure well. Rig Released at 11 :00 hours Printed: 1/31/2005 8:00:40 AM . . 15-14A Sidewall Core Summary Jeff Pietras, 2/18/2005 Shot and recovered 34 of 45 sidewall cores. 4 from the Kingak Fonnation, 9372' -939365.5' MD 7 from the Put River Sandstone, 9365' -9361' MD, no fluorescence 21 from the Kalubik Formation (upper shale), 9360.5' -9334' MD 2 from the HRZ Shales, 9332'-9328' MD . . Description Core Measured Bullet Core Core Visual Number Depth Shot? Recovered? Length Rock Type Fluorescence 1 9376 yes no 2 9374 yes no 3 9372 yes ves 1.3 Sh blk no 4 9370 yes no 5 9368 yes ves 1.1 Sh blk sslty pyr no 6 9366 yes ves 1.1 Sh blk sslty pyr no 7 9365.5 yes ves 1 Sh dk brn-blk slty silly sdy no 8 9365 yes ves 0.6 Sd fg slily slty slily shy no 9 9364.5 yes ves 1.1 Sd fg slily slty slily shy no 10 9364 yes ves 0.8 Sd fg slily slty slily shy no 11 9363.5 yes ves 0.5 Sd fg slily slty slily shy no 12 9363 yes no 13 9362.5 yes no 14 9362 yes ves 0.8 Sd fg slily slty slily shy no 15 9361.5 yes ves 0.5 Sst vtg slty shy no 16 9361 yes ves 0.4 Sst vtg slty shy no 17 9360.5 yes ves 0.4 Mudcake no 18 9360 yes ves 1.4 Sh blk slty no 19 9359.5 yes ves 1.2 Sh blk slty no 20 9359 yes no 21 9358.5 yes no 22 9358 yes ves 1.1 Sh blk slily slty no 23 9357.5 yes no 24 9357 yes ves 1 Sh blk slily slty no 25 9356.5 yes ves 0.9 Sh blk slily slty no 26 9356 yes ves 0.7 Sh blk slty no 27 9355 yes ves 1 Sh blk sslty no 28 9354 yes ves 0.7 Sltst slily sdy vshy no 29 9353 yes ves 1.1 Sh dk brn-blk slily slty no 30 9352 yes ves 0.9 Sh blk slty no 31 9351 yes ves 0.9 Sh blk slty no 32 9350 yes ves 1.1 Sh blk slty no 33 9349 yes ves 0.9 Sh blk slty no 34 9348 yes ves 0.9 Sh blk slty pyr no 35 9347 yes no 36 9346 yes ves 1.1 Sh dk brn-blk sslty no 37 9344 yes ves 1.1 Sh dk brn-blk sslty no 38 9342 yes ves 0.6 Sst brn shy vslty no 39 9340 yes ves 0.8 Sst dk brn vt-cg shy slty no 40 9338 yes no 41 9336 yes ves 0.6 Sh blk slty lam no 42 9334 yes ves 0.8 Sh blk slty lam no 43 9332 yes ves 0.6 Sh blk no 44 9330 yes no 45 9328 yes ves 0.4 Sh blk slty slily no Sidewall Core Record for 15-14A (Put River Ss) 7-Jan-05 Run 1 of 1 DEFINITIVE BPXA North Slope Alaska BPXA 15-14A . Job No. AKZZ3494195, Surveyed: 22 January, 2005 Survey Report 27 January, 2005 Your Ref: API 500292068201 Surface Coordinates: 5959167.86 N, 677483.20 E (70017' 38.2116" N, 148033'46.4231" Grid Coordinate System: NAD27 Alaska State Planes, Zone 4 . Survey Ref: svy4485 W) 58. 18ft above Mean Sea Level SPE!f"'If"'IY-SUf1 DAn_J.,..IN~ SeAVrc:es A Halliburton Company Kelly Bushing Elevation: BPXA Survey Report for 1S-14A Your Ref: APIS00292068201 Job No. AKZZ349419S, Surveyed: 22 January, 200S North Slope Alaska BPXA Measured True Sub-Se¡¡ 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) 8498.68 39.750 213.000 7115.43 7173.61 3026.98 S 1768.41 W 5956099.97 N 675786.75 E 3241.74 Tie On Point MWD+IIFR+MS 8573.00 39.750 213.000 7172.57 7230.75 3066.84 S 1794.29 W 5956059.51 N 675761.82 E 0.000 3286.49 Window Point 8685.25 37.560 207.490 7260.25 7318.43 3127.31 S 1829.65 W 5955998.22 N 675727.90 E 3.633 3351.27 8778.53 33.280 202.190 7336.27 7394.45 3176.27 S 1852.45 W 5955948.74 N 675706.26 E 5.644 3399.09 8870.45 29.810 195.770 7414.61 7472.79 3221.63 S 1868.20 W 5955903.01 N 675691.59 E 5.249 3439.12 . 8964.21 29.470 189.810 7496.12 7554.30 3266.80 S 1878.46 W 5955857.62 N 675682.40 E 3.163 3474.67 9057.41 28.720 191.220 7577.56 7635.74 3311.35 S 1886.73 W 5955812.88 N 675675.19 E 1.090 3508.26 9150.54 30.490 196.950 7658.55 7716.73 3355.91 S 1897.97 W 5955768.07 N 675665.00 E 3.583 3544.23 9229.49 32.300 200.010 7725.94 7784.12 3394.90 S 1911.03 W 5955728.78 N 675652.86 E 3.054 3578.25 9336.92 33.770 200.290 7816.00 7874.18 3449.88 S 1931.21 W 5955673.34 N 675633.99 E 1.376 3627.63 9430.43 35.500 200.250 7892.94 7951.12 3499.73 S 1949.62 W 5955623.07 N 675616.76 E 1.850 3672.50 9523.47 34.950 200.500 7968.94 8027.12 3550.04 S 1968.30 W 5955572.34 N 675599.27 E 0.611 3717.87 9616.85 33.750 200.510 8046.03 8104.21 3599.39 S 1986.76 W 5955522.56 N 675581.98 E 1 .285 3762.47 9709.87 32.670 199.540 8123.86 8182.04 3647.25 S 2004.21 W 5955474.30 N 675565.67 E 1 .294 3805.37 9803.47 33.590 199.480 8202.24 8260.42 3695.47 S 2021.29 W 5955425.69 N 675549.73 E 0.984 3848.19 9846.54 33.150 198.800 8238.21 8296.39 3717.85 S 2029.06 W 5955403.14 N 675542.49 E 1.341 3867.94 9868.41 32.870 198.510 8256.55 8314.73 3729.14 S 2032.87 W 5955391.76 N 675538.95 E 1.4 70 3877.82 9938.32 32.470 195.170 8315.41 8373.59 3765.24 S 2043.81 W 5955355.41 N 675528.87 E 2.641 3908.41 9968.25 32.410 193.690 8340.67 8398.85 3780.79 S 2047.81 W 5955339.77 N 675525.23 E 2.660 3921.02 9997.94 30.830 192.150 8365.95 8424.13 3795.96 S 2051.29 W 5955324.52 N 675522.11 E 5.976 3932.99 10032.78 29.020 194.130 8396.14 8454.32 3812.88 S 2055.23 W 5955307.51 N 675518.57 E 5.918 3946.38 10062.91 29.860 200.920 8422.39 8480.57 3826.98 S 2059.70 W 5955293.31 N 675514.44 E 11.416 3958.48 . 10098.25 31.920 208.130 8452.73 8510.91 3843.45 S 2067.25 W 5955276.67 N 675507.28 E 11.978 3974.47 10127.10 33.100 214.190 8477.06 8535.24 3856.69 S 2075.27 W 5955263.24 N 675499.57 E 12.002 3988.88 10161.40 34.120 223.280 8505.64 8563.82 3871.45 S 2087.14 W 5955248.21 N 675488.06 E 14.956 4007.27 10193.03 34.340 233.700 8531.82 8590.00 3883.20 8 2100.42 W 5955236.14 N 675475.05 E 18.527 4024.96 10219.64 34.400 242.150 8553.80 8611.98 3891.168 2113.12 W 5955227.89 N 675462.54 E 17.917 4039.88 10254.17 34.380 252.160 8582.31 8640.49 3898.71 S 2131.04 W 5955219.92 N 675444.81 E 16.360 4058.71 10284.59 34.450 255.130 8607.41 8665.59 3903.55 8 2147.54 W 5955214.69 N 675428.43 E 5.522 4074.76 10312.65 34.540 257.050 8630.54 8688.72 3907.37 8 2162.96 W 5955210.51 N 675413.10 E 3.888 4089.34 10346.59 34.870 261.540 8658.44 8716.62 3910.96 S 2181.94 W 5955206.48 N 675394.22 E 7.593 4106.60 10376.80 35.420 266.450 8683.15 8741.33 3912.77 S 2199.22 W 5955204.25 N 675376.98 E 9.529 4121.44 10404.98 35.960 272.090 8706.04 8764.22 3912.97 S 2215.64 W 5955203.66 N 675360.57 E 11.829 4134.63 10437.11 37.830 276.060 8731.74 8789.92 3911.59 S 2234.87 W 5955204.59 N 675341.31 E 9.426 4149.08 10469.88 40.410 284.760 8757.18 8815.36 3907.82 S 2255.16 W 5955207.88 N 675320.94 E 18.493 4162.92 27 January, 2005 - 14:37 Page 2 of 5 DrillQuest 3.03.06.008 BPXA Survey Report for 1S-14A Your Ref: APIS00292068201 Job No. AKZZ349419S, Surveyed: 22 January, 200S North Slope Alaska BPXA Measured True Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (0/100ft) 10498.53 42.660 289.070 8778.63 8836.81 3902.28 S 2273.32 W 5955212.99 N 675302.66 E 12.692 4174.00 10531.40 46.320 294.590 8802.09 8860.27 3893.69 S 2294.67 W 5955221.08 N 675281.11 E 16.194 4185.77 10562.66 50.130 299.930 8822.92 8881 .1 0 3882.99 S 2315.36 W 5955231.28 N 675260.17 E 17.624 4195.73 10591.84 53.530 305.500 8840.96 8899.14 3870.58 S 2334.63 W 5955243.23 N 675240.61 E 18.993 4203.53 10625.61 54.500 307.840 8860.80 8918.98 3854.26 S 2356.54 W 5955259.03 N 675218.32 E 6.300 4211.06 10656.65 55.720 308.750 8878.55 8936.73 3838.48 S 2376.52 W 5955274.34 N 675197.97 E 4.608 4217.38 . 10685.20 60.680 311.300 8893.60 8951.78 3822.87 S 2395.08 W 5955289.50 N 675179.05 E 18.957 4222.67 10718.84 65.450 314.690 8908.83 8967.01 3802.42 S 2417.00 W 5955309.43 N 675156.66 E 16.784 4227.69 10749.81 69.120 319.010 8920.80 8978.98 3781.57 S 2436.51 W 5955329.81 N 675136.65 E 17.490 4230.57 10777.56 74.060 321.170 8929.56 8987.74 3761.38 S 2453.39 W 5955349.60 N 675119.30 E 19.272 4231.75 10809.75 79.080 321.510 8937.03 8995.21 3736.94 S 2472.95 W 5955373.57 N 675099.18 E 15.629 4232.48 10840.88 83.380 322.700 8941.78 8999.96 3712.67 S 2491.84 W 5955397.39 N 675079.72 E 14.320 4232.78 10872.32 88.520 323.350 8944.00 9002.18 3687.62 S 2510.69 W 5955421.99 N 675060.28 E 16.478 4232.58 10896.00 90.800 324.800 8944.14 9002.32 3668.45 S 2524.59 W 5955440.83 N 675045.94 E 11.410 4232.00 10929.59 93.270 327.140 8942.94 9001.12 3640.63 S 2543.37 W 5955468.19 N 675026.50 E 10.126 4230.07 10961.16 93.090 331.040 8941 . 19 8999.37 3613.59 S 2559.56 W 5955494.84 N 675009.68 E 12.348 4226.55 10989.10 91.850 336.400 8939.99 8998.17 3588.57 S 2571.91 W 5955519.56 N 674996.74 E 19.673 4221.20 11024.56 90.310 342.240 8939.32 8997.50 3555.42 S 2584.43 W 5955552.41 N 674983.44 E 17.029 4211.05 11056.37 94.200 344.910 8938.07 8996.25 3524.94 S 2593.41 W 5955582.67 N 674973.74 E 14.828 4199.71 11083.49 97.480 350.010 8935.31 8993.49 3498.62 S 2599.27 W 5955608.85 N 674967.26 E 22.274 4188.40 11118.41 94.690 354.040 8931.60 8989.78 3464.24 S 2604.08 W 5955643.10 N 674961.64 E 13.982 4171.38 11149.84 94.690 357.820 8929.03 8987.21 3433.00 S 2606.31 W 5955674.28 N 674958.68 E 11.986 4154.21 11177.63 94.200 358.800 8926.88 8985.06 3405.31 S 2607.12 W 5955701.95 N 674957.21 E 3.933 4138.06 . 11211.23 91.970 358.980 8925.07 8983.25 3371.76 S 2607.77 W 5955735.46 N 674955.77 E 6.658 4118.24 11242.19 92.280 358.310 8923.92 8982.10 3340.83 S 2608.51 W 5955766.37 N 674954.30 E 2.383 4100.07 11271.22 92.530 358.000 8922.70 8980.88 3311.84 S 2609.44 W 5955795.33 N 674952.69 E 1.371 4083.23 11304.21 92.780 358.150 8921.18 8979.36 3278.91 S 2610.55 W 5955828.23 N 674950.80 E 0.883 4064.14 11335.52 93.520 357.320 8919.46 8977.64 3247.67 S 2611.78W 5955859.43 N 674948.83 E 3.549 4046.18 11364.03 92.040 358.580 8918.07 8976.25 3219.21 S 2612.80 W 5955887.85 N 674947.14 E 6.814 4029.73 11396.15 91.110 356.440 8917.19 8975.37 3187.14 S 2614.19W 5955919.89 N 674944.99 E 7.262 4011.39 11427.71 90.800 354.670 8916.66 8974.84 3155.68 S 2616.64 W 5955951.28 N 674941.80 E 5.693 3994.26 11455.62 91.670 354.180 8916.06 8974.24 3127.91 S 2619.35 W 5955978.98 N 674938.43 E 3.577 3979.57 11495.69 92.650 356.750 8914.55 8972.73 3087.99 S 2622.52 W 5956018.80 N 674934.33 E 6.860 3957.88 11549.42 91.600 356.580 8912.56 8970.74 3034.39 S 2625.64 W 5956072.32 N 674929.94 E 1.980 3927.86 11583.63 91.970 357.640 8911.49 8969.67 3000.24 S 2627.36 W 5956106.42 N 674927.41 E 3.280 3908.53 27 January, 200S· 14:37 Page 3 of S DrillQuest 3.03.06.008 BPXA Survey Report for 1S-14A Your Ref: API S00292068201 Job No. AKZZ349419S, Surveyed: 22 January, 200S North Slope Alaska BPXA Measured True Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (o/100ft) 11615.37 89.630 0.120 8911.05 8969.23 2968.52 8 2627.98 W 5956138.12 N 674926.04 E 10.742 3889.78 11642.72 88.770 0.030 8911.43 8969.61 2941.178 2627.95 W 5956165.46 N 674925.43 E 3.162 3873.17 11693.70 89.690 359.760 8912.12 8970.30 2890.20 8 2628.04 W 5956216.42 N 674924.13 E 1.881 3842.33 11737.65 90.370 0.600 8912.09 8970.27 2846.25 S 2627.90 W 5956260.36 N 674923.23 E 2.459 3815.57 11787.61 90.860 0.120 8911.56 8969.74 2796.29 S 2627.59 W 5956310.31 N 674922.37 E 1.373 3785.03 11829.81 91.170 359.970 8910.81 8968.99 2754.10 S 2627.56 W 5956352.49 N 674921.40 E 0.816 3759.42 . 11880.48 90.560 4.040 8910.05 8968.23 2703.47 8 2625.78 W 5956403.14 N 674921.98 E 8.121 3727.31 11923.40 90.620 4.630 8909.60 8967.78 2660.688 2622.54 W 5956446.00 N 674924.21 E 1.382 3698.78 11972.83 89.630 7.920 8909.50 8967.68 2611.55 S 2617.14 W 5956495.24 N 674928.45 E 6.951 3664.69 12016.51 90.310 8.600 8909.52 8967.70 2568.33 S 2610.86 W 5956538.60 N 674933.71 E 2.202 3633.49 12058.18 88.090 10.280 8910.10 8968.28 2527.23 8 2604.03 W 5956579.85 N 674939.57 E 6.681 3603.14 12110.13 90.120 10.670 8910.91 8969.09 2476.158 2594.59 W 5956631.13 N 674947.80 E 3.979 3564.65 12158.19 91.970 11.350 8910.04 8968.22 2428.99 S 2585.41 W 5956678.50 N 674955.86 E 4.101 3528.76 12203.21 91.300 10.720 8908.75 8966.93 2384.82 S 2576.80 W 5956722.86 N 674963.43 E 2.042 3495.12 12255.66 92.280 11.570 8907.11 8965.29 2333.39 8 2566.66 W 5956774.52 N 674972.35 E 2.473 3455.88 12296.45 92.710 13.230 8905.34 8963.52 2293.59 S 2557.91 W 5956814.52 N 674980.15 E 4.200 3424.78 12345.96 94.760 17.470 8902.11 8960.29 2245.96 8 2544.84 W 5956862.44 N 674992.10 E 9.496 3385.51 12389.85 92.780 18.870 8899.22 8957.40 2204.35 S 2531.19 W 5956904.36 N 675004.77 E 5.521 3349.42 12438.08 93.830 23.220 8896.44 8954.62 2159.428 2513.90 W 5956949.68 N 675020.99 E 9.264 3308.43 12481.29 94.570 24.760 8893.28 8951.46 2120.058 2496.38 W 5956989.46 N 675037.57 E 3.945 3270.62 12530.49 93.950 24.690 8889.62 8947.80 2075.49 8 2475.86 W 5957034.49 N 675057.04 E 1 .268 3227.28 12575.29 94.380 24.560 8886.37 8944.55 2034.87 8 2457.24 W 5957075.54 N 675074.69 E 1.003 3187.84 12622.86 95.130 24.500 8882.43 8940.61 1991.748 2437.56 W 5957119.12 N 675093.35 E 1.582 3146.04 . 12668.72 96.000 25.140 8877.98 8936.16 1950.318 2418.40 W 5957160.99 N 675111.52 E 2.351 3105.68 12724.37 95.930 26.610 8872.20 8930.38 1900.52 S 2394.25 W 5957211.34 N 675134.50 E 2.630 3056.28 12762.07 93.390 28.570 8869.13 8927.31 1867.228 2376.84 W 5957245.04 N 675151.11 E 8.499 3022.25 12811.35 93.580 29.050 8866.14 8924.32 1824.128 2353.14 W 5957288.69 N 675173.79 E 1.046 2977 .27 12855.45 94.200 28.540 8863.15 8921.33 1785.56 8 2331.95 W 5957327.74 N 675194.06 E 1.819 2937.03 12901.21 94.260 28.370 8859.77 8917.95 1745.448 2310.20 W 5957368.36 N 675214.85 E 0.393 2895.41 12948.59 90.800 29.340 8857.68 8915.86 1703.99 8 2287.36 W 5957410.34 N 675236.71 E 7.584 2852.12 12996.14 91.300 28.030 8856.81 8914.99 1662.28 8 2264.54 W 5957452.57 N 675258.54 E 2.948 2808.68 13040.22 90.060 24.840 8856.28 8914.46 1622.82 S 2244.92 W 5957492.49 N 675277.22 E 7.764 2769.15 13090.53 90.620 25.090 8855.99 8914.17 1577.21 S 2223.69 W 5957538.58 N 675297.37 E 1.219 2724.61 13134.82 91.970 25.890 8854.98 8913.16 1537.24 S 2204.64 W 5957578.99 N 675315.48 E 3.543 2685.22 13190.75 91.980 26.360 8853.06 8911.24 1487.06 S 2180.02 W 5957629.74 N 675338.90 E 0.840 2635.22 27 January, 200S - 14:37 Page 4 of 5 DrillQuest 3.03.06.008 BPXA Survey Report for 15-14A Your Ref: API 500292068201 Job No. AKZZ3494195, Surveyed: 22 January, 2005 North Slope Alaska Measured True Sub-Sea Vertical Depth Incl. Azim. Depth Depth (ft) (ft) (ft) 13237.00 91.980 26.360 8851.46 8909.64 Local Coordinates Northings Eastings (ft) (ft) Global Coordinates Northings Eastings (ft) (ft) 5957671.63 N 675358.44 E 1445.64 S 2159.50 W 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 232.6700 (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 13237.00ft., The Bottom Hole Displacement is 2598.71ft., in the Direction of 236.2000 (True). Comments Measured Depth (ft) Station Coordinates TVD Northings Eastings (ft) (ft) (ft) Comment 8498.68 8573.00 13237.00 7173.61 7230.75 8909.64 Tie On Point Window Point Projected Survey 3026.98 S 3066.84 S 1445.64 S 1768.41 W 1794.29 W 2159.50 W Survey tool program for 15-14A From Measured Vertical Depth Depth (ft) (ft) To Measured Vertical Depth Depth Survey Tool Description (ft) (ft) 0.00 8498.68 0.00 7173.61 7173.61 BP Conventional Gyro - CB-GYRO-MS (15-14) 8909.64 MWD+IIFR+MS (15-14A) 8498.68 13237.00 Dogleg Vertical Rate Section (o/100ft) BPXA Comment 0.000 2593.78 Projected Survey . . 27 January, 2005 - 14:37 Page 5 of 5 DrillQuest 3.03.06.008 BPXA North Slope Alaska BPXA 15-14A (mwd) . Job No. AKMW349419S, Surveyed: 22 January, 200S Survey Report 27 January, 2005 Your Ref: API S00292068201 Surface Coordinates: 59S9167.86 N, 677483.20 E (70017' 38.2116" N, 148033'46.4231" W) Grid Coordinate System: NAD27 Alaska State Planes, Zone 4 . Kelly Bushing Elevation: 58. 18ft above Mean Sea Level spE!l"""l......y-SUf1 OAtt..:..t..:.tNG SEAVICES A Halliburton Company Survey Ref: svy4486 BPXA Survey Report for 1S-14A (rowd) Your Ref: API S00292068201 Job No. AKMW349419S, Surveyed: 22 January, 200S North Slope Alaska BPXA Measured True Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (0/100ft) 8498.68 39.750 213.000 7115.43 7173.61 3026.98 S 1768.41 W 5956099.97 N 675786.75 E 3241.74 Tie On Point MWD Magnetic 8573.00 39.750 213.000 7172.57 7230.75 3066.84 S 1794.29 W 5956059.51 N 675761.82 E 0.000 3286.49 Window Point 8685.25 37.560 207.490 7260.25 7318.43 3127.31 S 1829.65 W 5955998.22 N 675727.90 E 3.633 3351.27 8778.53 33.280 205.180 7336.25 7394.43 3175.72S 1853.67 W 5955949.26 N 675705.03 E 4.807 3399.73 8870.45 29.810 196.030 7414.62 7472.80 3220.54 S 1870.73 W 5955904.04 N 675689.04 E 6.423 3440.47 . 8964.21 29.470 190.200 7496.13 7554.31 3265.65 S 1881.25 W 5955858.70 N 675679.58 E 3.095 3476.19 9057.41 28.720 191.030 7577.57 7635.75 3310.19 S 1889.59 W 5955813.97 N 675672.29 E 0.914 3509.84 9150.54 30.490 197.410 7658.56 7716.74 3354.71 S 1900.95 W 5955769.20 N 675661.99 E 3.879 3545.86 9229.49 32.300 200.300 7725.95 7784.13 3393.62 S 1914.26 W 5955729.99 N 675649.60 E 2.981 3580.04 9336.92 33.770 200.740 7816.01 7874.19 3448.46 S 1934.79 W 5955674.68 N 675630.37 E 1.386 3629.63 9430.43 35.500 200.280 7892.95 7951.13 3498.24 S 1953.41 W 5955624.47 N 675612.94 E 1.871 3674.61 9523.47 34.950 200.370 7968.95 8027.13 3548.56 S 1972.05 W 5955573.72 N 675595.49 E 0.594 3719.95 9616.85 33.750 200.540 8046.04 8104.22 3597.93 S 1990.46 W 5955523.94 N 675578.25 E 1.289 3764.53 9709.87 32.670 199.670 8123.87 8182.05 3645.77 S 2007.98 W 5955475.70 N 675561.87 E 1.269 3807.47 9803.47 33.590 199.550 8202.25 8260.43 3693.96 S 2025.14 W 5955427.12 N 675545.84 E 0.985 3850.34 9846.54 33.150 198.580 8238.22 8296.40 3716.35 S 2032.88 W 5955404.55 N 675538.63 E 1.606 3870.07 9868.41 32.870 198.740 8256.56 8314.74 3727.63 S 2036.70 W 5955393.18 N 675535.09 E 1.341 3879.95 9938.32 32.470 195.170 8315.42 8373.60 3763.72 S 2047.70 W 5955356.84 N 675524.94 E 2.815 3910.58 9968.25 32.410 193.690 8340.68 8398.86 3779.26 S 2051.70W 5955341.21 N 675521.30 E 2.660 3923.19 9997.94 30.830 192.440 8365.96 8424.14 3794.42 S 2055.23 W 5955325.97 N 675518.14 E 5.761 3935.18 10032.78 29.020 193.970 8396.15 8454.33 3811.34 S 2059.19 W 5955308.96 N 675514.58 E 5.638 3948.59 10062.91 29.860 200.470 8422.40 8480.58 3825.47 S 2063.58 W 5955294.73 N 675510.52 E 10.959 3960.65 . 10098.25 31.920 208.420 8452.74 8510.92 3841.93 S 2071.11 W 5955278.09 N 675503.39 E 12.925 3976.62 10127.10 33.100 214.260 8477.07 8535.25 3855.16 S 2079.17 W 5955264.69 N 675495.63 E 11.618 3991.05 10161.40 34.120 222.720 8505.65 8563.83 3869.97 S 2090.98 W 5955249.59 N 675484.18 E 13.963 4009.42 10193.03 34.340 233.260 8531.83 8590.01 3881.84 S 2104.16 W 5955237.42 N 675471.29 E 18.739 4027.10 10219.64 34.400 242.430 8553.81 8611.99 3889.81 S 2116.84 W 5955229.15 N 675458.79 E 19.441 4042.02 10254.17 34.380 257.500 8582.35 8640.53 3896.45 S 2135.04 W 5955222.09 N 675440.76 E 24.602 4060.52 10284.59 34.450 258.420 8607.45 8665.63 3900.04 S 2151.86W 5955218.10 N 675424.03 E 1.725 4076.06 10312.65 34.540 259.330 8630.58 8688.76 3903.10 S 2167.45 W 5955214.67 N 675408.52 E 1.864 4090.32 10346.59 34.870 260.090 8658.48 8716.66 3906.55 S 2186.46 W 5955210.77 N 675389.59 E 1.603 4107.53 10376.80 35.420 267.400 8683.19 8741.37 3908.44 S 2203.72 W 5955208.48 N 675372.38 E 14.041 4122.40 10404.98 35.960 269.980 8706.08 8764.26 3908.81 S 2220.15 W 5955207.72 N 675355.96 E 5.674 4135.69 10437.11 37.830 273.450 8731.78 8789.96 3908.22 S 2239.43 W 5955207.85 N 675336.68 E 8.711 4150.66 10469.88 40.410 283.920 8757.23 8815.41 3905.06 S 2259.79 W 5955210.53 N 675316.24 E 21.617 4164.93 27 January, 2005 - 14:33 Page 2 of 5 DríllQuest 3.03.06.008 BPXA Survey Report for 15-14A (rowd) Your Ref: API 500292068201 Job No. AKMW3494195, Surveyed: 22 January, 2005 North Slope Alaska BPXA Measured True Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (0/100ft) 10498.53 42.660 287.910 8778.68 8836.86 3899.84 S 2278.05 W 5955215.32 N 675297.87 E 12.119 4176.28 10531.40 46.320 296.200 8802.14 8860.32 3891.15 S 2299.34 W 5955223.50 N 675276.38 E 20.872 4187.94 10562.66 50.130 298.760 8822.96 8881.14 3880.39 S 2320.00 W 5955233.78 N 675255.46 E 13.631 4197.85 10591.84 53.530 307.300 8841.02 8899.20 3867.87 S 2339.18 W 5955245.84 N 675236.00 E 25.775 4205.51 10625.61 54.500 308.790 8860.86 8919.04 3851.03 S 2360.70 W 5955262.17 N 675214.09 E 4.582 4212.41 10656.65 55.720 309.930 8878.61 8936.79 3834.88 S 2380.38 W 5955277.84 N 675194.03 E 4.952 4218.27 . 10685.20 60.680 310.580 8893.65 8951.83 3819.20 S 2398.89 W 5955293.08 N 675175.15 E 17.480 4223.48 10718.84 65.450 315.690 8908.90 8967.08 3798.69 S 2420.74 W 5955313.07 N 675152.83 E 19.602 4228.41 10749.81 69.120 320.770 8920.86 8979.04 3777.39 S 2439.75 W 5955333.92 N 675133.32 E 19.215 4230.61 10777.56 74.060 323.610 8929.62 8987.80 3756.59 S 2455.87 W 5955354.33 N 675116.71 E 20.276 4230.82 10809.75 79.080 324.230 8937.10 8995.28 3731.29 S 2474.31 W 5955379.19 N 675097.69 E 15.707 4230.13 10840.88 83.380 324.370 8941.84 9000.02 3706.31 S 2492.25 W 5955403.73 N 675079.15 E 13.820 4229.26 10872.32 88.520 325.120 8944.06 9002.24 3680.71 S 2510.35 W 5955428.90 N 675060.46 E 16.521 4228.12 10896.00 90.800 325.400 8944.20 9002.38 3661.25 S 2523.84 W 5955448.03 N 675046.51 E 9.701 4227.05 10929.59 93.270 327.140 8943.01 9001 .19 3633.34 S 2542.48 W 5955475.50 N 675027.22 E 8.993 4224.95 1 0961 .16 93.090 331.040 8941.26 8999.44 3606.30 S 2558.67 W 5955502.15 N 675010.39 E 12.348 4221.42 10989.10 91.850 336.660 8940.05 8998.23 3581.25 S 2570.97 W 5955526.90 N 674997.51 E 20.580 4216.01 11024.56 90.310 342.610 8939.38 8997.56 3548.03 S 2583.30 W 5955559.82 N 674984.40 E 17.329 4205.67 11056.37 94.200 346.860 8938.13 8996.31 3517.38 S 2591.67 W 5955590.27 N 674975.31 E 18.103 4193.74 11083.49 97.480 351.000 8935.37 8993.55 3490.91 S 2596.85 W 5955616.60 N 674969.50 E 19.412 4181.81 11118.41 94.690 355.620 8931.67 8989.85 3456.44 S 2600.89 W 5955650.97 N 674964.65 E 15.391 4164.11 11149.84 94.690 358.960 8929.10 8987.28 3425.16 S 2602.37 W 5955682.21 N 674962.43 E 10.591 4146.32 11177.63 94.200 0.440 8926.94 8985.12 3397.45 S 2602.51 W 5955709.91 N 674961.63 E 5.595 4129.63 . 11211.23 91.970 0.150 8925.13 8983.31 3363.90 S 2602.34 W 5955743.45 N 674961.01 E 6.693 4109.15 11242.19 92.280 359.980 8923.99 8982.17 3332.96 S 2602.30 W 5955774.38 N 674960.32 E 1.142 4090.36 11271.22 92.530 359.090 8922.77 8980.95 3303.96 S 2602.54 W 5955803.37 N 674959.40 E 3.182 4072.96 11304.21 92.780 359.460 8921.24 8979.42 3271.01 S 2602.96 W 5955836.30 N 674958.20 E 1.353 4053.31 11335.52 93.520 357.780 8919.52 8977.70 3239.76 S 2603.71 W 5955867.53 N 674956.71 E 5.856 4034.96 11364.03 92.040 358.990 8918.14 8976.32 3211.29 S 2604.51 W 5955895.97 N 674955.24 E 6.702 4018.34 11396.15 91.110 357.090 8917.25 8975.43 3179.20 S 2605.61 W 5955928.02 N 674953.38 E 6.584 3999.75 11427.71 90.800 355.410 8916.73 8974.91 3147.72 S 2607.67 W 5955959.45 N 674950.58 E 5.412 3982.30 11455.62 91.670 355.130 8916.13 8974.31 3119.91 S 2609.98 W 5955987.19 N 674947.62 E 3.275 3967.27 11495.69 92.650 356.750 8914.62 8972.80 3079.97 S 2612.81 W 5956027.06 N 674943.84 E 4.723 3945.30 11549.42 91.600 356.580 8912.62 8970.80 3026.37 S 2615.93 W 5956080.57 N 674939.45 E 1.980 3915.28 11583.63 91.970 355.300 8911.56 8969.74 2992.26 S 2618.35 W 5956114.61 N 674936.23 E 3.893 3896.52 27 January, 2005 - 14:33 Page 3 of 5 DrillQuest 3.03.06.008 BPXA Survey Report for 15-14A (rowd) Your Ref: API 500292068201 Job No. AKMW3494195, Surveyed: 22 January, 2005 North Slope Alaska BPXA Measured True Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (°/1 DOft) 11615.37 89.630 357.160 8911.12 8969.30 2960.60 S 2620.44 W 5956146.22 N 674933.39 E 9.417 3878.98 11642.72 88.770 358.200 8911.50 8969.68 2933.27 S 2621.55 W 5956173.51 N 674931.64 E 4.934 3863.29 11693.70 89.690 359.070 8912.18 8970.36 2882.31 S 2622.76 W 5956224.42 N 674929.23 E 2.484 3833.35 11737.65 90.370 0.390 8912.16 8970.34 2838.36 S 2622.97 W 5956268.35 N 674927.98 E 3.378 3806.87 11787.61 90.860 359.200 8911.62 8969.80 2788.41 S 2623.15 W 5956318.29 N 674926.62 E 2.576 3776.72 11829.81 91.170 359.720 8910.88 8969.06 2746.22 S 2623.55 W 5956360.46 N 674925.23 E 1 .434 3751.45 . 11880.48 90.560 2.970 8910.11 8968.29 2695.57 S 2622.36 W 5956411 .12 N 674925.22 E 6.525 3719.79 11923.40 90.620 3.430 8909.67 8967.85 2652.72 S 2619.96 W 5956454.01 N 674926.60 E 1.081 3691.90 11972.83 89.630 8.170 8909.56 8967.74 2603.56 S 2614.97 W 5956503.28 N 674930.44 E 9.796 3658.12 12016.51 90.310 8.960 8909.58 8967.76 2560.37 S 2608.46 W 5956546.61 N 674935.92 E 2.386 3626.75 12058.18 88.090 10.000 8910.16 8968.34 2519.28 S 2601.60 W 5956587.86 N 674941.81 E 5.883 3596.38 12110.13 90.120 10.560 8910.98 8969.16 2468.17 S 2592.33 W 5956639.17 N 674949.87 E 4.054 3558.02 12158.19 91.970 11.780 8910.10 8968.28 2421.03 S 2583.02 W 5956686.52 N 674958.06 E 4.611 3522.03 12203.21 91.300 11 .000 8908.82 8967.00 2376.92 S 2574.14 W 5956730.83 N 674965.91 E 2.283 3488.21 12255.66 92.280 12.160 8907.18 8965.36 2325.56 S 2563.61 W 5956782.42 N 674975.21 E 2.894 3448.70 12296.45 92.710 13.880 8905.40 8963.58 2285.86 S 2554.43 W 5956822.33 N 674983.45 E 4.343 3417.33 12345.96 94.760 18.000 8902.17 8960.35 2238.36 S 2540.87 W 5956870.13 N 674995.89 E 9.279 3377.74 12389.85 92.780 19.420 8899.29 8957.47 2196.89 S 2526.82 W 5956911.92 N 675008.95 E 5.547 3341 .42 12438.08 93.830 23.610 8896.51 8954.69 2152.10 S 2509.17 W 5956957.11 N 675025.55 E 8.942 3300.23 12481.29 94.570 25.150 8893.34 8951.52 2112.85 S 2491.38 W 5956996.77 N 675042.40 E 3.945 3262.28 12530.49 93.950 25.850 8889.69 8947.87 2068.57 S 2470.26 W 5957041.54 N 675062.47 E 1.898 3218.63 12575.29 94.380 24.880 8886.43 8944.61 2028.20 S 2451.12 W 5957082.36 N 675080.66 E 2.363 3178.93 12622.86 95.130 24.990 8882.49 8940.67 1985.21 S 2431.13 W 5957125.80 N 675099.62 E 1.593 3136.97 . 12668.72 96.000 25.460 8878.04 8936.22 1943.92 S 2411.68 W 5957167.54 N 675118.09 E 2.154 3096.46 12724.37 95.930 26.920 8872.26 8930.44 1894.25 S 2387.25 W 5957217.77 N 675141.34 E 2.612 3046.92 12762.07 93.390 29.120 8869.20 8927.38 1861.09 S 2369.60 W 5957251.34 N 675158.20 E 8.900 3012.77 12811.35 93.580 29.430 8866.20 8924.38 1818.18 S 2345.55 W 5957294.80 N 675181.24 E 0.737 2967.63 12855.45 94.200 28.730 8863.21 8921.39 1779.73 S 2324.16 W 5957333.75 N 675201.71 E 2.118 2927.31 12901.21 94.260 28.280 8859.83 8918.01 1739.63 S 2302.38 W 5957374.36 N 675222.53 E 0.989 2885.67 12948.59 90.800 28.960 8857.74 8915.92 1698.08 S 2279.72 W 5957416.42 N 675244.21 E 7.442 2842.45 12996.14 91.300 28.160 8856.87 8915.05 1656.33 S 2256.99 W 5957458.71 N 675265.95 E 1.984 2799.06 13040.22 90.060 24.960 8856.35 8914.53 1616.91 S 2237.28 W 5957498.58 N 675284.72 E 7.785 2759.49 13090.53 90.620 25.140 8856.05 8914.23 1571.33 S 2215.98 W 5957544.65 N 675304.94 E 1.169 2714.91 13134.82 91.970 25.800 8855.05 8913.23 1531.35 S 2196.94 W 5957585.06 N 675323.03 E 3.393 2675.53 13190.75 91.980 25.630 8853.12 8911.30 1480.99 S 2172.69 W 5957635.98 N 675346.09 E 0.304 2625.71 27 January, 2005 - 14:33 Page 4 of 5 DriJ/Quest 3.03.06.008 BPXA Survey Report for 15-14A (mwd) Your Ref: API 500292068201 Job No. AKMW3494195, Surveyed: 22 January, 2005 North Slope Alaska Measured True Sub-Sea Vertical Depth Incl. Azim. Depth Depth (ft) (ft) (ft) 13237.00 91.980 25.630 8851.52 8909.70 Local Coordinates Northings Eastings (ft) (ft) Global Coordinates Northings Eastings (ft) (ft) 1439.32 S 2152.69 W 5957678.11 N 675365.09 E 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 232.670° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 13237.00ft., The Bottom Hole Displacement is 2589.54ft., in the Direction of 236.233° (True). Comments Measured Depth (ft) Station Coordinates TVD Northings Eastings ~ ~ ~ Comment 8498.68 8573.00 13237.00 3026.98 S 3066.84 S 1439.32 S Tie On Point Window Point Projected Survey 1768.41 W 1794.29 W 2152.69 W 7173.61 7230.75 8909.70 Survey too/prOf/ram for 15-14A (mwd) From Measured Vertical Depth Depth (ft) (ft) To Measured Vertical Depth Depth Survey Tool Description (ft) (ft) 0.00 8498.68 8498.68 13237.00 7173.61 BP Conventional Gyro - CB-GYRO-MS (15-14) 8909.70 MWD Magnetic (15-14A (mwd») 0.00 7173.61 Dogleg Vertical Rate Section (0/100ft) BPXA Comment 0.000 2584.54 Projected Survey . . 27 January, 2005 - 14:33 Page 5 of 5 DríllQuest 3.03.06.008 15-14 on . AOGCC Helen Warman 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 DEFINITIVE Re: Distribution of Survey Data for Well 15-14A Dear Dear Sir/Madam: Enclosed is one disk with the *.PTT and *.PDF files. Tie-on Survey: Window / Kickoff Survey: Projected Survey: 8,498.68' MD 8,573.00' MD 13,237.00' MD (if applicable) . 28-Jan-05 PLEASE ACKNOWLEDGE RECEIPT BY SENDING AN EMAIL TO CARL.ULRICH@HALLlBURTON.COM OR SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Carl Ulrich 6900 Arctic Blvd. Anchorage, AK 99518 Date ) rJ, Àð'-t r Signed :Wû~ I Please call me at 273-3545 if you have any questions or concerns. Regards, Carl Ulrich Survey Manager Attachment(s) >~a ~-Ä2:L . . AOGCC Helen Warman 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 Re: Distribution of Survey Data for Well 15-14A MWD Dear Dear Sir/Madam: Enclosed is one disk with the *.PTT and *.PDF files. Tie-on Survey: Window / Kickoff Survey: Projected Survey: 8,498.68' MD 8,573.00' MD 13,237.00' MD (if applicable) PLEASE ACKNOWLEDGE RECEIPT BY SENDING AN EMAIL TO CARL.ULRICH@HALLlBURTON.COM OR SIGNING AND RETURNING A COpy OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Carl Ulrich 6900 Arctic Blvd. Anchorage, AK 99518 Date 'j v<t? ~\}'-\\ D Signed /1/ /~¡ ill .OlJ ".., Please call me at 273-3545 if you have any questions or concerns. Regards, Carl Ulrich Survey Manager Attachment(s) 28-Jan-05 /~ t vi - À À ~ . ~Tf~TfŒ (ID~ ~~!Æ~æ~ . AI,ASIiA OIL AND GAS CONSERVATION COMMISSION Bill Isaacson Senior Drilling Engineer BP Exploration (Alaska), Inc. PO Box 196612 Anchorage, AK 99519 FRANK H. MURKOWSKI, GOVERNOR 333 W. 7'" AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279·1433 FAX (907) 276-7542 Re: PBU 15-14A BP Exploration (Alaska), Inc. Permit No: 204-222 Surface Location: 2349' SNL, EWL, Sec. 22, TIIN, RI4E, UM Bottomhole Location: 4094' SNL, 768' WEL, Sec. 21, Tl1N, RI4E, UM Dear Mr. Isaacson: Enclosed is the approved application for permit to drill the above referenced development well. This permit to drill 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 petroleum field inspector at (907) 65 607 (pager). cc: ~\.i 61\- 101 Zql2.o0f . STATE OF ALASKA _ ALASKA ~ AND GAS CONSERVATION COJ'v7'llWrSSION PERMIT TO DRILL , 20 AAC 25.005 OCT 2 7 2004 1a. Type of work o Drill 181 Redrill r b. Current Well Class o Exploratory iii DeK~lo'p'm~ttQili ..E3 ~uJüPI~n~ i'Sf,'~t-:r ORe-Entry o Stratigraphic Test o Service o DeV~AèAt;GðS:·· S~e 'if 2. Operator Name: 5. Bond: 181 Blanket o Single Well 11. Well Name tmd'Nlft'tlJ)èr: BP Exploration (Alaska) Inc. Bond No. 2S100302630-277 PBU 15-14A 3. Address: 6. Proposed Depth: 12. Field I Pool(s): P.O. Box 196612, Anchorage, Alaska 99519-6612 MD 13033 TVD 8943 Prudhoe Bay Field I Prudhoe Bay 4a. Location of Well (Governmental Section): 7. Property Designation: Pool Surface: ADL 028306 2349' SNL, 1522' EWL, SEC. 22, T11N, R14E. UM 8. Land Use Permit: 13. Approximate Spud Date: Top of Productive Horizon: 742' SNL, 1107' WEL, SEC. 28, T11N, R14E. UM January 5. 2005 Total Depth: 9. Acres in Property: 14. Distance to Nearest Property: 4094' SNL. 768' WEL, SEC. 21, T11 N, R14E, UM 2560 26,000' 4b. Location of Well (State Base Plane Coordinates): 10. KB Elevation 15. Distance to Nearest Well Within Pool Surface: x-677483 y- 5959168 Zone- ASP4 (Height above GL):Plan 58.2 feet 15-47 is 123' away at 12331' MD 16. Deviated Wells: Kickoff Depth: 8500 feet 17. Maximum Anticipated Pressures in psig (see 20 AAC 25.035) Maximum Hole Angle: 92 degrees Downhole: 3250 Surface: 2370 18;Ç~$ingPrQgram: ...... ..T(:f:)ttiry9~~~~bt om {.lÜ~l"\tity~ Size ..((::J;ol' i Hole Casina Weiaht Grade Couclina Lenath MD TVD MD TVD (includina staae data) 8-1/2" 7" 26# L-80 BTC-M 1664' 8350' 7058' 10014' 8392' ~42 sx Class 'G' 6-1/8" 4-1/2" 12.6# L-80 IBT-M 3162' 9870' 8276' 13032' 8943' 324 sx Class 'G' -' 19, PRE$f;NTWf;LL· CONDrnPN SÜMMARY.(To. beCOrnpleteqf~RedriIIAND.Re;;entry.o~rø*ióh$) Total Depth MD (ft): Total Depth TVD (ft): Plugs (measured): Effective Depth MD (ft): Effective Depth TVD (ft): Junk (measured): 11200 9123 10705 10705 8760 None Gasing· 1.ength .... SiZe/i··.. .... i. iC '/1 Ci NlD TVP Structural C:onrlur.tnr 80' 20" 300 sx Permafrost II 80' 80' Surface 2572' 13-3/8" 2300 sx Fondu. 400 sx Permafrost 'C' 2572' 2572' Inb:¡rmp.rfi~te 10152' 9-5/8" 500 sx Class 'G' 10152' 8384' Production Linp.r 1421' 7" 350 sx Class 'G' 9779' - 11200' 8125' - 9123' Perforation Depth MD (ft): Below Sand Plug perfOration Depth TVD (ft): NIA . . 20. Attachments 181 Filing Fee, $100 o BOP Sketch 181 Drilling Program o Time vs Depth Plot o Shallow Hazard Analysis o Property Plat o Diverter Sketch o Seabed Report 181 Drilling Fluid Program 18120 AAC 25.050 Requirements 21. Verbal Approval: Commission Representative: Date: 22. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Phil Smith. 564-4897 Printed Name Bil/Isaacson Title Senior Drilling Engineer L. /-JL 1O!t.tr./OI. Prepared By Name/Number: Signature " ".. Phone S''''·5S"ll Date Terrie Hubble, 564-4628 ....... i< i ". ... :,. ...... iC. .. i iCc c. iC ............. > ....... iC Permit To Drill I API Number: I Permit APp,ro/~ I ~ee cover letter for Number:20 q -;2 2-2 50- 029-20682-01-00 Date: 1)/1 oÇ/ other requirements Conditions of Approval: Samples Required 0 Yes ~~o Mud Log Required o Yes ~~o ~ ~ffide M~sur~ ~V~~: No Directional Survey Required fiYes 0 No Other:T€ S. "f)O f . ÇOO p~/ , ._ KfPféJile d , {J~~ 1- ~r,C; (k \(1) ,ecd:0''th ~of'L- l s ~V!tt1 0" , ,,' , , ,/;/rJf \1' ..~ ., ,,- ., \. t Q , '~1 \....... APPROVED BY Aocroved B . ~ . THE COMMISSION Date Form 10-401 ~ed Ol~ '----- Submit In Duplicate e e G To: Winton Aubert - AOGCC Date: October 18, 2004 From: Phil Smith - BPXA GPB Rotary Drilling Subject: Reference: DS15-14 Application for Sundry Approval - P&A for Sidetrack Operations API # 50-029-20682-00 Approval is requested for the proposed P&A of PBU well DS15-14. With TxlA communication and no wellwork or RWO options, 15-14 is of limited value; the sidetrack will access Zone 1 reserves south of DS15. The area targeted is a synclinal depression to the south of 15-47 and west of 07-29C. DS15-14A will replace the 15-47 off take point in Z1A complementing the recent 07-29C RST. The sidetrack is currently scheduled for Nabors rig 2ES, beginning around January 5th, 2004. This well, however, may move up on the schedule if currently scheduled wells do not gain approval. The pre-rig work for this sidetrack will begin at the Well's Group earliest convenience after sundry approval. Current Condition: v' Tubing patch above cement sheath in tubing from 9475' to tubing tail. v' Perforations covered with 140' of sand and capped with 5 gallons Latex 9/3/2003 v' Confirmed TxlA communication, though 5/29/2003 caliper indicates good to fair tubing. Scope Pre-RiQ Work: 1. R/U slick-line. Drift the 5 W' tubing to at least 8,600' md to confirm clear to the required cut depth. Drift the cement sheath to 2.25", or as required for the coiled tubing cement plug abandonment. 2. Fluid pack the well as necessary. RU coiled tubing and cap the sand plug with 10 bbls (260') of class G cement. Combo pressure test the casing to 3500 psi fl 30 minutes. 3. R/U E-line. RIH with chemical cutter and severe the 5 W' tubing in the center of the full joint of tubing at -8,600' md. 4. Displace the well to clean seawater by circulating down the tubing through the tubing cut. Continue to circulate until clean seawater returns to surface. Combo pressure test the well to 2500 psi. Freeze protect to -2,100' MD with diesel. 5. Bleed casing and annulus pressures to zero. 6. Cycle the tubing hanger LOS and test the 9 5/8" mandrel packoff to 5000 psi. 7. Set a BPV and test to 1000 psi from tubing annulus. Secure the well. Level the pad as necessary. RiQ Operations: S ..Qß-- e· 4 \A!~~ 1. MI I RU Nabors rig 2ES 2. Circulate out diesel freeze protection and displace the well to seawater. Set BPVrrWC. 3. Nipple down tree. Nipple up and test BOPE to 3,500psi. Pull BPVrrWC. 4. R/U. Pull 5 W' tubing from the cut at -8,600' MD and above. 5. RIH wi 8 W' gauge ring / junk basket to top of tubing stub. 6. RIH with HES EZSV and set bridge plug as required to avoid cutting casing collar and place top of whip stock at -8500. POOH. RID E-line. _I t. , .,' I Pressure-test the 9 5/8" casin to 3,500 si for 30 minutes. Record test. i M ~ 10 ,4 ol a.f'fHov", , P and Wit 9 5 8' Baker bottom-trip anchor whip stock assembly. Orient whip stock, as desired, and set on bridge plug. Shear off of whip stock. DS15-14 Application for Sundry e e 9. Displace the well to 10.2 ppg lSND based milling fluid. Completely displace the well prior to beginning milling operations. 10. Mill window in 9 5/8" casing at ± 8,500' MD, plus approximately 20' beyond middle of window. Circulate well bore clean. 11. Pull up into 9 5/8" casing and conduct an FIT to 12.0 ppg EMW. POOH. 12. M/U 8 Y2" Dir/GRlRes assembly. RIH, kick off and drill the 8 1/2" intermediate section to the top of the Sag River, per directional proposal. Circulate well clean, short trip to window. POOH. 13. Run and cement a 7", 26.0#, l-80 intermediate drilling liner. 14. Test the 9 5/8" casing X 7"liner to 3,500psi for 30 minutes. Record the test. 15. M/U 61/8" Dir/GRlRes/ABI assembly. RIH to the landing collar. 16. Drill out the 7" liner float equipment and cement to the shoe. 17. Displace the well to 8.4 ppg FIe-Pro drilling fluid. 18. Drill out the 7" shoe plus drill-20' new formation; pull up into the shoe and conduct an FIT to 10.0 ppg EMW. Drill ahead to horizontal landing point. POOH for bit I BHA change. PU Neu/Den. 19. RIH, drill horizontal section to planned TD, short trip as necessary. 20. Circulate, short trip, spot liner running pill, POOH. 21. Run and cement a 4 Y2", 12.6#, l-80 solid production liner. POOH UD all drill pipe. 22. RIH with 2 7/8" perf guns and perforate ±1000'. 23. RIU and run 41/2", 12.6#, 13Cr-80 completion tubing. land the tubing RllDS. 24. Set a TWC and test to 1000 psi 25. Nipple down the BOPE. Nipple up the tree and test to 5,OOOpsi. 26. Reverse circulate inhibited seawater to the packer depth. Set packer and individually test the tubing and annulus to 3,500psi 30 minutes. Record each test. 27. Shear the DCK valve and freeze protect the well to -2,100'. Secure the well. 28. Rig down and move off. Post-Ria Work: 1. Install well house and instrumentation 2. Mil RU slick-line. Pull the ball and rod I RHC plug from landing nipple below the production packer. Install gas lift valves. 3. POP well to test unit until cleaned up. Estimated Pre-rig Start Date: 11/01/04 Estimated Spud Date: 01/05/05 Phil Smith Operations Drilling Engineer 564-4897 DS15-14 Application for Sundry TREE = W8...LHEAD = ACTUATOR = KB. 8...EV = SF. 8...EV = KOP= Max Angle = Datum MD = Datum TVD = FMC GEN 2 FMC AX8...S0N OLD 60' 15-14 SAFErY NOTES: SCAB LINæ CfM ENTED IN PLACE 9482' TO 9707'. MILLEDCfMENT 2.25". 3100' 48 @ 10400' 10843' 8800' SS . 2128' -1 5-1/2" OTIS RQM SSSV NIP, ID = 4.562" I 13-3/8" CSG, 72#. L-80. ID = 12.347" I TOPOF 3-1/2" LNR-SCAS 9475' - 9729' 2.80" CEMENT DONUT 3-1/2" LNR -SCAB. 9.5#, L-80, .0087 bpf. ID = 2.992" 970T PERFORATION SUMMARY REF LOG: SHeS ON 12/17/81 ANGLEAT TOP PERF: 44 @ 10848 Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 3-3/8 4 10848 - 10868 C 08/30/97 3-1/8 4 10890 - 10930 S 07/09/88 3-1/8 4 10944 - 10954 S 07/09/88 3-1/8 4 10968 - 10984 S 07/09/88 3-3/8 4 10984 - 10998 C 08/08/88 3-3/8 4 11003-11010 C 08/08/88 3-3/8 6 11022-11047 C 07/25/88 3-3/8 6 11054 - 11076 C 07/25/88 3-3/8 6 11084 - 11100 C 07/25/88 3-3/8 6 11100-11103 S 07/09/88 9708' 5-1/2" BOT PBR ASSY Minimum ID = 2.25" @ 9729 . 9868' CEMENT DONUT 9-5/8" X 5-1/2" BOT A<R CEMENT DONUT. [) = 2.25" 5-1/2" X 4-1/2" XO I 5-1/2" TBG-PC. 17#, L-80. .0232 bpf, [)= 4.892" TOP OF 4-1/2" TBG 9799' 4-1/2" OTIS XN NIP. ID = 3.725" 4-1/2" TBG-PC. 12.6#. N-80, .0152 bpf, ID = 3.958" 9802' 4-1/2" BOT SHEA ROUT SUB 4-1/2" TUBING TAIL BOTIOM OF CEMENT I 8...MD TI LOGGED 06/27/82 9-5/8" CSG. 47#. L-80. ID = 8.681" 10705' -i SAND R..UG (08/28/03) I DATE 12/22/81 06/27/01 08/23/03 08/29/03 REV BY COMMENTS ORIGINAL COMPLETION RN/TP CORRECTIONS BJM'KK CEMENT DONUT (04/11/99) JLGffLH SAND R..UG DATE REV BY COMMENTS PRUDHOE BAY UNrr W8...L: 15-14 PERMrr No: 1811700 API No: 50-029-20682-00 SEe 22, T11N, R14E, 1522.29' F8... & 1460.69' FNL BP Exploration (Ataska) TREE = WELLHEAD = ACTUATOR = KB. ELEV = BF. ELEV = KOP= Max Angle = Datum MD = DatumTVD= FMC GEN 2 FMC AXELSON OLD 60' 1Se4A Proposed I SAFEr_TES: 2100' H4-1/2" X Nipple 10 = 3.813" 8800' SS 13-3/8" CSG, 72#, L-80, 10 = 12.347" I ST MD TVD 4 3 2 1 GAS LIFT MANDRELS DEV TYÆ VLV LATCH PORT DATE DCK DMY DMY DMY I Proposed chemical cut - 8700' 8500' H 9 5/8" Window I 41/2" 12.6# 13Cr-80, ID = 3.958" H 10190' I -J4 1/2" X Nipple (3.813" 10) 1-i7" x 4 1/2" Baker S3 Packer I H4 1/2" X Nipple (3.813" 10) I 41/2" XN Nipple (3.725" 10) 4 1/2" Hanger /Iiner top packer 4 1/2" WLEG 14-1/2" TBG, 12.6#, 13Cr-80, .0152 bpf, 10 = 3.958"H 9870' I 10,014' H7" 26# L-80 (6.276" ID) I TOP OF 7" LNR 9779' 141/2" 12.6# L-80 Liner PBTD H 12,950' 141/2" 12.6# (3.958" 10) 0.0152 bpf H 13,032' 9-5/8" CSG, 47#, L-80, ID = 8.681" I ÆRFORA TION SUMMARY REF LOG: 10705' -i SAND PLUG (08/28/03) I ANGLE AT TOP ÆRF: Note: Refer to Production DB for historical perf data SIZE SPF INTERV AL Opn/Sqz DA TE 7" LNR, 29#, L-80, .0371 bpf, 10 = 6.184" I 11200' DATE 12/22/81 06/27/01 08/23/03 08/29/03 09/22/04 REV BY COMMENTS ORIGINAL COMPLETION RNlTP CORRECTIONS BJMlKK CEMENT DONUT (04/11/99) JLGITLH SAND PLUG PGS Proposed Sidetrack Completio DATE REV BY COMMENTS PRUDHOE BA Y UNIT WELL: 15-14A ÆRMITNo: 1811700 API No: 50-029-20682-01 see 22, T11N, R14E. 1522.29' FEL & 1460.69' FNL BP Exploration (Alaska) e e I Well Name: 15-14A Drill and Complete Plan Summary I Type of Well (service I producer I injector): 1 Horizontal Sidetrack Producer Surface Location: X = 677,483.2 Y = 5,959,167.9 // Estimated 2349' FNL 1522' FWL Sec. 22, T11 N, R14E Umiat Target Location: X = 674,948.0 Y = 5,955,435.0 TVDss 8948' Ivishak Zone 1 A 742' FNL 1107' FEL Sec. 28, T11N, R14E Umiat Bottom Hole Location: X = 675,238.0 Y = 5,957,370.0 TVDss 8885' 4094' FNL 768' FEL Sec. 21, T11N, R14E Umiat 7 I AFE Number: I PBD4P2300 I I Estimated Start Date: 101/05/05 [MQJ 13,033' I I TVD: 18,943' I I Rig: I Nabors 2ES /' I Operating days to complete: 1.16.5 I GL: 129.7' 1 I KB: 128.5' 1 1 KBE: 158.2' I Well Design (conventional, slimhole, etc.): J Two String Horizontal Sidetrack I Objective: ¡Ivishak Zone 1 A Formation Markers Formation Tops (wp02) MD TVD TVDss Comments CM2 6698 -6640 ABOVE KICKOFF CM! 8699 7333 -7275 THRZ 9142 7689 -7631 LCU 9367 7871 -7813 TJD 9367 7871 -7813 TJC 9556 8023 -7965 TJB 9745 8175 -8117 TJA SAG RIVER 10,014 8392 -8334 SHUBLIK TSAD 10,102 8464 -8406 TCGL 10,314 8645 -8587 3150 PSI @ 8800' TVD = 6.9 pp~ EMW ' BCGL 10,393 8712 -8654 TZlB 10,734 8940 -8882 TDF 10,869 8988 -8930 BSAD 9033 -8975 Not Penetrated TD 13,033 8943 -8885 TD Criteria: Reach planned TD unless drilling conditions deteriorate. 10.1.. 15-14A Permit to Drill Page 1 e Directional - Sperry wp02 e KOP: I 8500' MD Maximum Hole Angle: _400 in the 8-1/2" intermediate section (at KOP) -920 in the 6-1/8" horizontal section Close Approach Wells: Several close approach wells have been identified for this well, but pas/ minor risk (1 :200) criteria: DS7-14; 886' ctr-ctr at 10,116' planned depth (abandoned wellbore) DS7-28A; 569' ctr-ctr at 11,913' planned depth (reservoir section) DS7-29B; 162' ctr-ctr at 9530' planned depth (abandoned wellbore) DS7-29C; 145' ctr-ctr at 9535' planned depth (may require shut-in) DS15-01 A; 528' ctr-ctr at 12,857' planned depth (reservoir section) DS15-47; 123' ctr-ctr at 12,331' planned depth (well shut in with sand plug across perforations due to severe tubina corrosion) Survey Program: MWD Standard + IIFR / Cassandra Nearest Property Line: 26,000' to the nearest PBU property line Nearest Well within Pool: DS15-47; 123' ctr-ctr at 12,331' planned depth ram Wt/Ft Grade Conn Length Top Btm /' ./ MDrrVD MDrrVD 8-1/2" 7" 26# L-80 BTC-M 1664' 8,350'/7,058' 10,014'/8,392' / 6-1/8" 4-1/2" 12.6# L-80 IBT-M 3162' 9870'/8276' 13,032'/8943' Tubin 4-1/2" 12.6# 13Cr-80 V AM To -10,260' GL 9870'/8276' FloPro PV <10 Lo Pro ram 8-1/2" Intermediate: Sample Catchers - None Drilling: Dir/GRlRes Open Hole: None Cased Hole: None 6-1/8" Production: Sample Catchers - over entire interval, samples described Drilling: Dir/GRIRes/Neu/ABI Open Hole: None Cased Hole: None 15-14A Permit to Drill Page 2 e e 69 acks Class G @ 15.8 ppg t3/sack Size 4.5" 12.6#, l-80 Production liner lead: None Tail: Based on 80' shoe track, 3018' of 4-1/2" X 6-1/8" open hole with 40% excess, 150' 4-1/2" X 7" Liner lap, an ~O' of 7" X 4" OP excess. Tail TOC: . ,87. MO (Top of Liner) Total Cement Volume: Tail 79.4 bbls, 376 ft3 32 t3/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. Oiverter, BOPE and drilling fluid system schematics on file with the AOGCC. Intermediate Interval Maximum antici ated BHP Maximum surface ressure Kick tolerance Planned BOP test pressure Production Interval Maximum antici ated BHP Maximum surface ressure Kick tolerance Planned BOP test pressure Disposal · No annular injection in this well. · Cuttings Handling: Cuttings generated from drilling operations will be hauled to grind and inject at OS-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 OS-04 for injection. Haul all Class I wastes to Pad 3 for disposal. 15-14A Permit to Orill Page 3 e e Sidetrack and Complete Procedure Summar'l Current Condition: ,/ Tubing patch above cement sheath in tubing from 9475' to tubing tail. ,/ Perforations covered with 140' of sand and capped with 5 gallons Latex 9/3/2003 ,/ Confirmed TxlA communication, though 5/29/2003 caliper indicates good to fair tubing. Scope Pre-Ria Work: 1. R/U slick-line. Drift the 5 W' tubing to at least 8,600' md to confirm clear to the required cut depth. Drift the cement sheath to 2.25", or as required for the coiled tubing cement plug abandonment. 2. Fluid pack the well as necessary. RU coiled tubing and cap the sand plug with 10 bbls (260') of class G cement. Combo pressure test the casing to 3500 psi f/30 minutes. 3. R/U E-line. RIH with chemical cutter and severe the 5 W' tubing in the center of the full joint of tubing at -8,600' md. 4. Displace the well to clean seawater by circulating down the tubing through the tubing cut. Continue to circulate until clean seawater returns to surface. Combo pressure test the well to 2500 psi. Freeze protect to -2,100' MD with diesel. 5. Bleed casing and annulus pressures to zero. 6. Cycle the tubing hanger LDS and test the 9 5/8" mandrel packoff to 5000 psi. 7. Set a BPV and test to 1000 psi from tubing annulus. Secure the well. Level the pad as necessary. Ria Operations: 1. MI I RU Nabors rig 2ES 2. Circulate out diesel freeze protection and displace the well to seawater. Set BPVfTWC. 3. Nipple down tree. Nipple up and test BOPE to 3,500psi. Pull BPVfTWC. 4. R/U. Pull 5 W' tubing from the cut at -8,600' MD and above. 5. RIH w/8 W' gauge ring I junk basket to top of tubing stub. 6. RIH with HES EZSV and set bridge plug as required to avoid cutting casing collar and place top of whip stock at -8500. POOH. RID E-line. -I'" l 4 (' .1)" "I { 7. Pressure-test the 9 5/8" casin to 3,500 si for 30 minutes. Record test. Il-vt SO'" 0 ¥ I ' Ií II ~ . 8. P/U and R wit 9 5 8" Baker bottom-trip anchor whip stock assembly. Orient whip stock, as desired, and set on bridge plug. Shear off of whip stock. 9. Displace the well to 10.2 ppg LSND based milling fluid. Completely displace the well prior to beginning, milling operations. 10. Mill window in 9 5/8" casing at ± 8,500' MD, plus approximately 20' beyond middle of window.· Circulate well bore clean. 11. Pull up into 9 5/8" casing and conduct an FIT to 12.0 ppg EMW. POOH. / 12. M/U 8 W' Dir/GR/Res assembly. RIH, kick off and drill the 81/2" intermediate section to the top of the Sag River, per directional proposal. Circulate well clean, short trip to window. POOH. 13. Run and cement a 7", 26.0#, L-80 intermediate drilling liner.· / 14. Test the 9 5/8" casing X 7" liner to 3,500psi for 30 minutes. Record the test. 15. M/U 6 1/8" Oir/GR/Res/ABI assembly. RIH to the landing collar. 16. Drill out the 7" liner float equipment and cement to the shoe. ' 17. Displace the well to 8.4 ppg Flo-Pro drilling fluid. 18. Drill out the 7" shoe plus drill -20' new formation; pull up into the shoe and conduct an FIT to 10.0 ppg ~- EMW. Drill ahead to horizontal landing point. POOH for bit I BHA change. PU Neu/Den. . 19. RIH, drill horizontal section to planned TO, short trip as necessary. 20. Circulate, short trip, spot liner running pill, POOH. 21. Run and cement a 4 W·. 12.6#, L-80 solid production liner. pOOH UO all drill pipe. / 22. RIH with 2 7/8" perf guns and perforate ±1000'. / 15-14A Permit to Orill Page 4 e e 23. R/U and run 41/2",12.6#, 13Cr-80 completion tubing. Land the tubing RILDS. // 24. Set a TWC and test to 1000 psi 25. Nipple down the BOPE. Nipple up the tree and test to 5,OOOpsi. 26. Reverse circulate inhibited seawater to the packer depth. Set packer and individually test the tubing and annulus to 3,500psi 30 minutes. Record each test. 27. Shear the DCK valve and freeze protect the well to -2,100'. Secure the well. 28. Rig down and move off. Post-Ria Work: 1. Install well house and instrumentation 2. MI / RU slick-line. Pull the ball and rod / RHC plug from landing nipple below the production packer. Install gas lift valves. 3. POP well to test unit until cleaned up. 15-14A Drilling Program Job 1: MIRU Hazards and Contingencies > 15-14 is on the southern (entrance) end of the pad with 15-13A and 15-15B on 120' centers north and south, respectively. No well houses will require removal or shut-in for the rig move onto 15-14. > D515 is not designated as an Hß site. Recent H2S data from the pad is as follows: ~ #1 Closest SHL #2 Closest SHL #1 Closest BHL #2 Closest BHL Well Name 15-15B 15-13A 07-10A 07 -32B Date 9/20/2003 2/3/2002 2/11/2001 8/22/2004 Most Wf!JS). ...s have more than 10 - 20 ppm H2S recorded. The maximum on the pad is DS15- /' 21A at~pm ~ 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 > 15-14 is a vertical well originally drilled in December 1981. In the fall of 1995, T x IA communication was noted. Following an acid stim, a patch was set in the 5-1/2" tubing, and 15-14 continued to produce full-time. The well continued full-time production until mid 1998 when the tubing patch began to leak and required replacement. Despite repeated efforts, the bottom packer element of the patch was not successfully retrieved, so a scab liner was set in the tubing. During the setting of the scab, a substantial amount of cement was left in the tubing. Several attempts were made to mill the cement, but were unsuccessful in milling to the fulllD of the scab liner (which would have allowed CTD tiny tools drilling). What remained after milling was a functional well (in terms of T x IA communication) that had a cement ring (2.25" ID) in the bottom 150' of tubing. When 15-14 was brought online after the scab liner job, it produced as a cycle well, and did so until 2003, when the well again succumbed to T x IA communication. 15-14A Permit to Drill Page 5 e e > A 2003 caliper log indicates good to fair tubing with isolated pitting, general corrosion, and line corrosion 20-38%. The cross-sectional wall loss, however, is less than 10% therefore the maximum overpull can remain at the standard 80% of tensile strength for the 4 112" tubing. > 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. > The 9 5/8" casing was cemented with 500 sx (-100 bbls) of class Gat 15.8 ppg. At gauge hole KOP would be at approximately TOC. Expect little cement at the window depth. Reference RP .:. "Whipstock Sidetracks" RP Job 5: Drill 8-1/2" Intermediate Hole Hazards and Contingencies > The intermediate section will kick off in the Colville (lower CM2) and TO at the top of Sag River. Since 15-14A will start at 40° inclination and hold 36° until section TO. 10.2 ppg mud weight will be adequate to maintain wellbore stability though the Kingak shale 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 8.4 ppg pore pressure at the Sag River depth, a fracture gradient_~j5.. - ppg at the 9-5/8" casing window, and 11.5 ppg mud in the hole, the kick tolerance is i~e. 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. 15-14A Permit to Drill Page 6 - e ~ 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 ~ The well is planned to land about 5' above the HOfT. Check the projection early and trip for a motor change if necessary to avoid drilling too deep. Slight undulation of wellbore through Zone 1 A sands is desirable to maximise vertical permeability. ~ The polygon is designed to avoid faults on the west, and the 15-47 wellbore on the northeast. The polygon is designed to avoid faults on the west, and the 15-47 wellbore on the northeast. ~ Only two small faults are expected in this interval: 15-20' throw at 11,250' MD and 5-10' throw at 11,900. þ> KICK TOLERANCE: In the worst-case scenario of 8.3 ppg pore pressure in the Ivishak, a fracture grad.I:~~.t 9.5 ppg at the 7" casing shoe, and 8.5 ppg mud in the hole, the kick tolerance iS~. 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 -750psi 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. ~ 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 15-14A Permit to Drill Page 7 e e Job 10: DPC Perforate Production Casina 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 Schlumberger perforating practices and recommendations. .:. "DPC Perforating" RP Job 12: Run Completion Hazards and Contingencies ~ Diesel will be used to freeze protect the well. The diesel flash point is 100° F. Diesel vapor pressure is - 0.1 psia at 100° F. Reference RP .:. "Completion Design and Running" RP .:. "Tubing connections" RP Job 13: ND/NUlRelease Ria Hazards and Contingencies ~ No wells will require well house removal or shut-in for the rig move off of 15-14A. See MIRU section for nearest well. ~ 4-1/2" x 9-5/8" packer will be set above the Put River TVD to allow for potential future perforating into the Put horizon. Set packer above -9300' MD. Top Put is at 9413' in parent well. Reference RP .:. "Freeze Protecting an Inner Annulus" RP 15-14A Permit to Drill Page 8 TREE = WB.LHEAD = ACTUATOR = KB. B.EV = BF. B.EV = KOP= Max Angle = Datum MD = DatumTVD= FMC GEN 2 FMC AXB.SON OLD 60' 15-14/ SAFETY NOTES: SCAB LINER CEMENTs) IN PLACE 9482' TO 9707'. MILLS) CEMENT 2.25". 3100' 48 @ 10400' 10843' 8800' SS . 2128' 5-1/2" OTIS RCMSSSV NIP,ID=4.562" 13-3/8" CSG, 72#, L-80,1D= 12.347" I TOPOF 3-1/2" LNR-SCAB I 9475' . 9729' 2.80" CEMENT DONUT ÆRFORA TION SUMMARY REF LOG: BHes ON 12/17/81 ANGLEATTOPÆRF: 44@ 10848 Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 3-3/8 4 10848 - 10868 C 08/30/97 3-1/8 4 10890 - 10930 S 07/09/88 3-1/8 4 10944 - 10954 S 07/09/88 3-1/8 4 10968 - 10984 S 07/09/88 3-3/8 4 10984 - 10998 C 08/08/88 3-3/8 4 11003 - 11010 C 08/08/88 3-3/8 6 11022 - 11047 C 07125/88 3-3/8 6 11054 - 11076 C 07125/88 3-3/8 6 11084 - 11100 C 07125/88 3-3/8 6 11100 - 11103 S 07/09/88 970T 9708' -1 5-1/2" BOT PBR ASSY I 3-112" LNR -SCAB, 9.5#, L-80, .0087 bpf, ID = 2.992" Minimum ID = 2.25" @ 9729 .. 9868' CEMENT DONUT 9728' 9-5/8" X 5-112" BOT PKR 9729' . 9868' -f CEMENT DONUT, ID = 2.25" 9739' 5-1/2" x 4-1/2" XO 5-1/2"1BG-PC, 17#, L·80, .0232 bpf, II) = 4.892" TOP OF 4-1/2" TBG 9799' 4-112" OTIS XN NIP, ID = 3.725" I 14-1/2" TBG-PC, 12.6#, N-80, .0152 bpf, ID = 3.958" I 9802' 4·1/2" BOT SHEA ROUT SUB 4-112" TUBING TAIL I BOTTOM OF CEMENT I 8.MD TT LOGGED 06/27/82 9-5/8" CSG, 47#, L-80, ID = 8.681· I 10705' -f SAND RUG (08128/03) I DATE 12/22/81 06127/01 08/23/03 08/29/03 REV BY COMMENTS ORIGINAL COMPLETION RNlTP CORRECTIONS BJMlKK CBIAENT DONUT (04/11/99) JLGfTLH SAND RUG DATE REV BY COMMENTS PRUDHOE BAY UNrr W8.L: 15-14 PERMrrNo: 1811700 API No: 50-029-20682-00 SEe 22, T11N, R14E, 1522.29' FB. & 1460.69' FNL BP Exploration (Alas ka) TREE = WELLHEAD = A CTUA TOR = KB. ELEV = BF. ELEV = KOP= Max Angle = Datum MD = Datum TVD = FMC GEN 2 FMC AXELSON OLD 60' 1se4A Proposed f-ÆAFWOTES: 2100' H4-1/2" X Nipple 10 = 3.813" 8800'SS 13-3/8" CSG, 72#, L-80, 10 = 12.347" I ST MD TVD 4 3 2 1 GAS LIFT MANDRELS DEV TYÆ VLV LATCH PORT DATE DCK DMY DMY DMY I Proposed chemical cut Ii 8700' . 8500' H 9 5/8" Window H4 1/2" X Nipple (3.813" 10) I l-i 7" x 4 1/2" Baker S3 Packer I H4 1/2" X Nipple (3.813" ID) I 4 1/2" XN Nipple (3.725" 10) 4 1/2" Hanger /Iiner top packer 41/2" WLEG I 41/2" 12.6#13Cr-80,ID=3.958" H 10190' 14-1/2" TBG, 12.6#, 13Cr-80, .0152 bpf, ID = 3.958"H 9870' I 10,014' H7" 26# L-80 (6.276" 10) I TOP OF 7" LNR I 9779' 141/2" 12.6# L-80 Liner PBTD H 12,950' I 141/2" 12.6# (3.958" 10) 0.0152 bpf H 13,032' I / 9-5/8" CSG, 47#, L-80, 10 = 8.681" I ÆRFORA TION SUMMARY REF LOG: A NGLE AT TOP PERF: Note: Refer to Production DB for historical perf data SIZE SPF INTERV AL Opn/Sqz DA TE 10705' -1 SAND PLUG (08/28/03) I 7" LNR, 29#, L-80, .0371 bpf, 10 = 6.184" I 11200' DATE 12/22/81 06/27/01 08/23/03 08/29/03 09/22/04 REV BY COMMENTS ORIGINAL COMPLETION RNlTP CORRECTIONS BJMlKK CEMENT DONlIT (04/11/99) JLGITLH SAND PLUG PGS Proposed Sidetrack Completio DATE REV BY COMMENTS PRUDHOE BA Y UNIT WELL: 15-14A PERMIT No: 1811700 API No: 50-029-20682-01 SEC 22, T11 N, R14E, 1522.29' FEL & 1460.69' FNL BP Exploration (Alaska) COMPANY DETAILS REFERENCE l!\;rORMATION Co-ordinate (NIE) lWfenmce' Vertica] (1VD) Reference' SC.::!iÚ.l!{VS) Reference' Measured Deptb RcfereJ1ce' CaJcuJatiOfJMethod- TrucNmih SURVEY PROGRAM Plan: 15-14A \'\!p02 (J5-14/Plan 15-14A) Depth FID Depth To Survey/Plan Too' Created By: Troy Jilibosky Date: 9/2112004 a500.00 13032_65 Planned: 15-14A wp02 VIS MWD Checked Oak Reviewed' ---~ Date: WELL DETAILS Name .¡..Nl~S '>-EI-W Northing Easting Lmitude Lo11gitude Slot 15-14 302.61 1193.72 5959161.86 671483.20 70017'38-.212N 14S"33'46.423W 14 SECTION DETAILS Sec MD Iue Azi TVD +N/-S +EI-W DLeg TFace VSec Target 1 8500.00 39.75 213.00 7174.93 -3026.98 -1768.41 0.00 0.00 3241.81 2 8520.00 40.02 209.28 7190.28 -3037.96 -1775.04 12.00 -85.00 3253.74 3 8620.30 36.31 201.60 7269.17 -3093.74 -1801.77 6.00 -131.02 3308.82 4 W073.51 36.31 201.60 8440.25 -3893.77 -2118.57 0.00 0.00 4045.89 5 11003.33 90.00 330.00 9006.18 -3672.19 -2622.81 12.00 122.56 4312.45 15-14A Tl Rev 1 6 11246.49 91.68 359.14 9002.55 -3440.35 -2686.82 12.00 86.56 4222.75 7 11890.{)9 91.68 359.14 8983.73 -2797.10 -2696.53 0.00 0.00 3840.37 8 12237.71 92.09 20.00 8972.18 -2456.39 -2639.10 6.00 88.52 3588.09 15-14A 1"2 9 12350.75 92.09 26.79 8968.05 -2352.78 -2594.28 6.00 89.88 3489.61 10 13032.65 92.09 26.79 8943.18 -1744.46 -2287. I 7 0.00 0.00 2876.51 15-14A T3 HPAmOl.-'ú- CaJcuJationMeibod' Errm-System' Scan f>kthml E!TOfSurfiI\:~' WarnJ:ogMethoo' CAS1NG DETAILS No. TVD MD Name Size 8392.18 10013.86 7" 8943.20 13032.00 4 l/2" 7.000 4.500 FORMATION TOP DETAILS No. TVDPath MDPath Formation 8392.18 10013.86 TSGR " ~ ~ .<: iJ. 80 c¡ <ii " 12 " >- 2 f-- TARGET DETAILS Name TVD +N/-S +EI-W Northing Easting Shape 15-14A T3 8943.18 -1744.46 -2287.17 5957370.00 675238.00 Point 15-14A T2 8972.18 -2456.39 -2639.10 5956650.00 674903.00 Point 15-14A Tl Rev 1 9006.18 -3672.19 -2622.81 5955435.00 674948.00 Point 15-14 (15-14) 2800 3200 3600 4000 4400 6000 4800 5200 5600 Vertical Section at 232.67° [400ftlin) - SURVEY PROGRAM Plan: 15~14A wp02 (15-14/P¡an 15~14A) [},;:ptb Fm Depth To SUIVI..'}'¡PJ:an Tool Created By: Troy Jaka.bosky Date: 9/2112004 8.500.00 .65 ¡>Ianru."d; 15·14A wp02 VH MWD . - Name ---N!-$ ---U-W Nffiiliing F..AAting Latitude Longìtud~ SID! !5-14 - Name lVD +N/-S +EI-W Northing Easting Shape 15-14A T3 8943.18 - 1 744.46 -2287.17 5957370,00 675238.00 Poin 15-14A T2 8972.18 -2456.39 -2639.10 5956650.00 674903.00 Poiu 15-14A T! Rev I 9006.18 -3672.19 -2622.81 5955435,00 674948,00 POÎflI SECTION DETAILS Azi TVD +N/-S +E/-W DLeg Tface vSec Target 7174.93 0.00 7190.28 12.00 7269.17 6.00 8440.25 0,00 9006.18 /12.00 15-14A T1 Rev 9002.55 12.00 8983.73 0.00 8972.18 6.00 15-14A T2 8968.05 6.00 8943.18 0.00 15-14A T3 CASING DETAILS No. TVD MD Name Size .18 10013.86 7" .20 13032.00 4 1I2" No. TVDPath MDPath Formation 8392.18 10013.86 TSGR COMPM"Y DETAI I " £i '" '" ::1 +' :E 15 ~. :E 15 " en e BP BP Planning Report e Field: Prudhoe Bay North Slope UNITED STATES Map System: us State Plane Coordinate System 1927 Ceo Datum: NAD27 (Clarke 1866) Sys Datum: Mean Sea Level Map Zone: Coordinate System: Geomagnetic Model: Alaska, Zone 4 We/I Centre bggm2004 Site: PB OS 15 TR-11-14 UNITED STATES; North Slope Site Position: Northing: From: Map Easting: Position Uncertainty: 0.00 ft Ground Level: 0.00 ft 5958837.36 ft 676296.98 ft Latitude: 70 17 Longitude: 148 34 North Reference: Grid Convergence: 35.236 N 21.213 W True 1.34 deg Well: 15-14 Slot Name: 14 15-14 Well Position: +N/-S 302.61 ft Northing: 5959167.86 ft Latitude: 70 17 38.212 N +E/-W 1193.72 ft Easting : 677483.20 ft Longitude: 148 33 46.423 W Position Uncertainty: 0.00 ft Casing Points Formations Targets 15-14A T3 8943.18 -1744.46 -2287.17 5957370.00 675238.00 70 17 21.052 N 15-14A T2 8972.18 -2456.39 -2639.10 5956650.00 674903.00 70 17 14.049 N 148 35 3.313 W 15-14A T1 Rev 1 9006.18 -3672.19 -2622.81 5955435.00 674948.00 70 17 2.091 N 148 35 2.826 W Plan Section Information 8500.00 39.75 213.00 7174.93 -3026.98 -1768.41 0.00 0.00 0.00 0.00 8520.00 40.02 209.28 7190.28 -3037.96 -1775.04 12.00 1.34 -18.60 -85.00 8620.30 36.31 201.60 7269.17 -3093.74 -1801.77 6.00 -3.70 -7.65 -131.02 10073.51 36.31 201.60 8440.25 -3893.77 -2118.57 0.00 0.00 0.00 0.00 11003.33 90.00 330.00 9006.18 -3672.19 -2622.81 12.00 5.77 13.81 122.56 15-14A T1 Rev 1 11246.49 91.68 359.14 9002.55 -3440.35 -2686.82 12.00 0.69 11.98 86.56 11890.09 91.68 359.14 8983.73 -2797.10 -2696.53 0.00 0.00 0.00 0.00 12237.71 92.09 20.00 8972.18 -2456.39 -2639.10 6.00 0.12 6.00 88.52 15-14A T2 12350.75 92.09 26.79 8968.05 -2352.78 -2594.28 6.00 0.00 6.00 89.88 13032.65 92.09 26.79 8943.18 -1744.46 -2287.17 0.00 0.00 0.00 0.00 15-14A T3 e BP BP Planning Report e 39.75 213.00 7174.93 7116.75 -3026.98 -1768.41 0.00 5956100.16 675786.86 Start Dir 12/10 40.02 209.28 7190.28 7132.10 -3037.96 -1775.04 12.00 5956089.04 675780.50 Start Dir 6/100 37.02 203.26 7252.89 7194.71 -3082.54 -1797.14 6.00 5956043.94 675759.45 MWD 36.31 201.60 7269.17 7210.99 -3093.74 -1801.77 6.00 5956032.64 675755.10 End Dir : 8620 36.31 201.60 7333.40 7275.22 -3137.62 -1819.14 0.00 5955988.37 675738.76 MWD 8800.00 36.31 201.60 7413.98 7355.80 -3192.67 -1840.94 0.00 5955932.82 675718.27 MWD 8900.00 36.31 201.60 7494.57 7436.39 -3247.72 -1862.74 0.00 5955877 .27 675697.78 MWD 9000.00 36.31 201.60 7575.15 7516.97 -3302.78 -1884.54 0.00 5955821.72 675677.28 MWD 9100.00 36.31 201.60 7655.74 7597.56 -3357.83 -1906.34 0.00 5955766.17 675656.79 MWD 9200.00 36.31 201.60 7736.32 7678.14 -3412.88 -1928.14 0.00 5955710.63 675636.30 MWD 9300.00 36.31 201.60 7816.91 7758.73 -3467.93 -1949.94 0.00 5955655.08 675615.80 MWD 9400.00 36.31 201.60 7897.50 7839.32 -3522.98 -1971.74 0.00 5955599.53 675595.31 MWD 9500.00 36.31 201.60 7978.08 7919.90 -3578.04 -1993.54 0.00 5955543.98 675574.82 MWD 9600.00 36.31 201.60 8058.67 8000.49 -3633.09 -2015.34 0.00 5955488.43 675554.33 MWD 9700.00 36.31 201.60 8139.25 8081.07 -3688.14 -2037.14 0.00 5955432.89 675533.83 MWD 9800.00 36.31 201.60 8219.84 8161.66 -3743.19 -2058.95 0.00 5955377.34 675513.34 MWD 9900.00 36.31 201.60 8300.42 8242.24 -3798.24 -2080.75 0.00 5955321.79 675492.85 MWD 10000.00 36.31 201.60 8381.01 8322.83 -3853.30 -2102.55 0.00 5955266.24 675472.35 MWD 10013.86 36.31 201.60 8392.18 8334.00 -3860.93 -2105.57 0.00 5955258.54 675469.51 T' 10073.51 36.31 201.60 8440.25 8382.07 -3893.77 -2118.57 0.00 5955225.41 675457.29 Start Dir 12/10 10100.00 34.69 206.31 8461.82 8403.64 -3907.82 -2124.80 12.00 5955211.22 675451.39 MWD 10200.00 30.55 227.33 8546.30 8468.12 -3950.70 -2156.22 12.00 5955167.60 675421.00 MWD 10300.00 30.41 251.12 8632.80 8574.62 -3976.21 -2199.01 12.00 5955141.09 675378.83 MWD 10400.00 34.31 272.44 8717.53 8659.35 -3983.22 -2251.30 12.00 5955132.85 675326.72 MWD 10500.00 41.11 288.70 8796.80 8738.62 -3971.44 -2310.81 12.00 5955143.23 675266.95 MWD 10600.00 49.61 300.66 8867.13 8808.95 -3941.37 -2374.94 12.00 5955171.77 675202.13 MWD 10700.00 59.05 309.80 8925.46 8867.28 -3894.32 -2440.88 12.00 5955217.24 675135.10 MWD 10800.00 69.02 317.25 8969.23 8911.05 -3832.37 -2505.76 12.00 5955277.65 675068.78 MWD 10900.00 79.28 323.74 8996.53 8938.35 -3758.20 -2566.73 12.00 5955350.35 675006.08 MWD 11000.00 89.65 329.80 9006.17 8947.99 -3675.07 -2621.14 12.00 5955432.16 674949.73 MWD 11003.33 90.00 330.00 9006.18 8948.00 -3672.19 -2622.81 12.00 5955435.00 674948.00 15-14A T1 Rev 1 11100.00 90.69 341.58 9005.60 8947.42 -3584.17 -2662.38 12.00 5955522.06 674906.36 MWD 11200.00 91.38 353.56 9003.79 8945.61 -3486.71 -2683.86 12.00 5955618.98 674882.58 MWD 11246.49 91.68 359.14 9002.55 8944.37 -3440.35 -2686.82 12.00 5955665.25 674878.53 End Dir : 1124 11300.0Q 91.68 359.14 9000.98 8942.80 -3386.87 -2687.63 0.00 5955718.70 674876.46 MWD 11400.00 91.68 359.14 8998.06 8939.88 -3286.92 -2689.13 0.00 5955818.57 674872.59 MWD 11500.00 91.68 359.14 8995.14 8936.96 -3186.98 -2690.64 0.00 5955918.45 674868.73 MWD 11600.00 91.68 359.14 8992.21 8934.03 -3087.03 -2692.15 0.00 5956018.32 674864.86 MWD 11700.00 91.68 359.14 8989.29 8931.11 -2987.09 -2693.66 0.00 5956118.20 674860.99 MWD 11800.00 91.68 359.14 8986.37 8928.19 -2887.14 -2695.17 0.00 5956218.08 674857.12 MWD 11890.09 91.68 359.14 8983.73 8925.55 -2797.10 -2696.53 0.00 5956308.06 674853.64 Start Dir 6/1 00 11900.00 91.69 359.73 8983.44 8925.26 -2787.19 -2696.62 6.00 5956317.95 674853.31 MWD 12000.00 91.83 5.73 8980.36 8922.18 -2687.40 -2691.86 6.00 5956417.82 674855.71 MWD 12100.00 91.96 11.73 8977.05 8918.87 -2588.66 -2676.70 6.00 5956516.89 674868.54 MWD 12200.00 92.06 17.74 8973.55 8915.37 -2492.05 -2651.29 6.00 5956614.06 674891.66 MWD 12237.71 92.09 20.00 8972.18 8914.00 -2456.39 -2639.10 6.00 5956650.00 674903.00 15-14A T2 12300.00 92.09 23.74 8969.90 8911.72 -2398.64 -2615.92 6.00 5956708.28 674924.81 MWD 12350.75 92.09 26.79 8968.05 8909.87 -2352.78 -2594.28 6.00 5956754.64 674945.36 End Dir : 1235 12400.00 92.09 26.79 8966.25 8908.07 -2308.84 -2572.10 0.00 5956799.08 674966.50 MWD 12500.00 92.09 26.79 8962.61 8904.43 -2219.63 -2527.06 0.00 5956889.33 675009.41 MWD 12600.00 92.09 26.79 8958.96 8900.78 -2130.42 -2482.03 0.00 5956979.57 675052.33 MWD 12700.00 92.09 26.79 8955.31 8897.13 -2041.21 -2436.99 0.00 5957069.81 675095.24 MWD 12800.00 92.09 26.79 8951.67 8893.49 -1952.00 -2391.95 0.00 5957160.05 675138.16 MWD · e BP BP Planning Report e 12900.00 92.09 26.79 8948.02 8889.84 -1862.79 -2346.91 13000.00 92.09 26.79 8944.37 8886.19 -1773.58 -2301.88 13032.00 92.09 26.79 8943.20 8885.02 -1745.03 -2287.47 13032.65 92.09 26.79 8943.18 8885.00 -1744.46 -2287.17 0.00 5957250.30 0.00 5957340.54 0.00 5957369.42 0.00 5957370.00 675181.07 MWD 675223.99 MWD 675237.72 41/2" 675238.00 15-14A T3 SONDRA D STEW MAN BP EXPLORATION AK INC PO BOX 196612 MB 7-5 ANCHORAGE, AK 99519-6612 89-6/1252 116 "Mastercard Check" il DATE I, PAY TO THE /'li;""····v· ....! " ORDER OF /,';'" A ,.+:;:,( (1,. --,.. $ \1 t"'\(..,;, ¡'\.: I I~ t.Y. /0 I." DOLLARS e -: . 2 5 2000 b 0 -: qq. ~ III b 2 2 ? III . 5 b ~ II- 0.. b e . . TRANSMIT AL LETTER CHECK LIST CIRCLE APPROPRIA IE LETTERJP ARAGRAPHS TO BE INCLUDED IN TRANSMITTAL LETTER WELL NAME ß0 ~r-/9A PTD# 2o-ry - ¿ _7_~ X DeveJopment Service Exploration Stratigraphic CHECK WHAT ADD-ONS ~'CLUE ". APPLJES (OPTIONS) MULTJ Tbe permit is for a new weUbore ·segment of LATERAL existing weD . Permit No, API No. . (If ÄP] number Production. should continue to be reponed as last two. (2) digits a function ·of tbe original API number. stated are between 60-69) above. Pfi,OT HOLE 1n accordance witb . 20 AAC 25.005(f), an (PH) records, data and logs acquired .for tbe pilot bole must be dearly differentiated 1n botb name (name OD permit plus PH) .. and API Dumber (SO - 70/80) from records, data and logs acquired for well (name on permit). SPACING Tbe permit is approved subject ·to fuD EXCEPT10N .. compJiance witb 20 AAC 25..055~ Approval to perforate aDd produce is contingent upon issuance of S! conservation order approving a spa dng ex ception. (Company Name) assumes tbe Jiability of any protest to tbe spacing .e:Jception tbat may occur. DRY DITCH AU dry ditcb sampJe sets submitted to tbe SAMPLE Commission must be in DO greater tban 30' .. sample intervaJs from beJow tbe permafrost or from where sampJes are first caugbt and ] 0' sampJe biter-vaJs tbrougb target :Lones. .. - e oJ.. .."~.",IL" J....._. .òL, Field & Pool PRUDHOE BAY. PRUDHOE OIL - 640150 Well Name: PRUDHOE BAY UNIT 15-14A Program DEV Well bore seg 0 PTD#: 2042220 Company BP EXPLORATION (ALASKA) INC Initial Classrrype DEV 11-01L GeoArea 890 Unit 11650 On/Off Shore On Annular Disposal 0 Administration 1 Permit fee attactJe~t - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - Ye'$. . - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - -- . . - - - - - - - - - - - - - 2 L~as.e.nllmber.appropriate. . . . . . . - - - - - - - - - - - - - ......... Ye'$...... - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - 3 .U.n[qlle weltnam.e.and Ol!mQer . _ _ . . . . . . . . . . _ _ . . . . _ . . . . _ _ _ . . . . _ . . . . . . _Y~'$ . . . . _ _ _ . . . . . _ . . . . _ _ . . . . _ _ . . . . . _ _ . . . . . _ . . . . _ . . . . . _ _ . . . . . . _ _ . . . . _ _ . . . _ _ . . . . . _ 4 WeIlJQC<lt~d in ad.efjlJe.d pool. . . - - - - - - - - - - - - - - - - . . ......... Ye'$..... - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - . . . - - - - - - - - - - 5 WellJoc¡¡ted proper .distaJ1ce. from driJliJ1g unitQound.al)' _ . . . . _ . . - - - - _.... yes.... - - - - - - - - - - - -- - - - - - - - - - - - - - - - - - - - - - - - - - - - - - . . - - - - - - - - - - - 6 WellJoc¡¡ted pr.oper .distaJ1ce. from otber w~lJs. . . . . - - - - - - - - - - - - ..... Y~'$...... - - - - - - - - - - -- - - - - - - - - - - - . . . - - - - - -- - - - - - - - - - - - - - - - - - - . . . 7 .Sufficientacr~age.aYaitable jn.drilliog unjt . . . . . . . . . . . - - - - - - - - - - - ...... Y.e'$................. - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - 8 -'fd~vi<lted. is. weJlbQre platilJcJuded . . . . . . . . - - - - - - - - - . . . . . . . . . . . . . . Y.e'$. . . . . . . . - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - 9 .Qpe(ator only affeçted party. . . . . . . . . . . - - - - - . . . . . . . . . . . . . . Yes. . - - - - - - - . . . - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - 10 _Qpe(ator bas.apprppriate.boJ1d inJorçe _ . . . . _ . . . . . _ . . . . _ _ _ . . . . . _ . . . . . . _ . Ye'$ . _ . . . . . . _ . . . . . _ _ . . . . . _ _ . . . . _ _ . . . . . _ . . . . . _ . . . . . _ . . . . . _ _ _ . . . . _ . . . . . _ _ . . . . _ . . . 11 P~rmit call be is'$l!ed .""itbQut co.n'$ervatiOIJ order. . . . . . . . . . . . . - - - - - - - - - - - · Ye'$. - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - Appr Date 12 P.el1lJit Gall be [s'$l!ed .""itbQut ad.mioi$tratÍ\le. appr.ova.1 . . . . - - - - - - - - - - - · . . . . . .Y~'$. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . - - - -- - - - - - - - - - - - - - - - - - - - - - - - RPC 10/28/2004 13 Can permit be approved before 15-day wait Yes 14 Well JQcat~d wittJilJ area and. strata authorized by.lnjectioo Ord.er # (put loti in. commellts) (For. .NA . . . . . . . . . - - - - - - - - - -- - - - - - - - - - - - . . . - - - - - - - - - - - - - - - - - - - - - - - - - - 15 AJI~lJs.within.1l4.n:tile.aJea.ofreYi~wid~otifi~d(Fpr$ervj~.I/\Ie!lolJly)........ _...... .NA.. _ _ _............ _...... _..... _ _ _............... _. _. _'. _ _ _... _ _............ 16 PJe-produ.ced illj~çtor; .durationof pr~-.pro.duçtiplJ tess. than. 3 mOlJtbs. (ForseMce well only) . .NA . . . . . - - - - - - - - -- - - - - - - - - - -- - - - - - - - - - - - - - - - - - - - - - - - - - - -- - - - - - 17 ACMP. F:indin9 .of Con.sistency. h.a'$ been is.slled. for tbi'$ p(oject . . - - - - - ....... .NA.. - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - Engineering 18 .Coodu.ctor $tdr¡gprQvid~d . - - - - - - - - - -- - - - - - - - - - - - - - - - - - - - - - ..NA_... - . - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - 19 S.urfa~ca$in9- pJQtects. all known USDW$ . . . . . . . . - - - - - - - - - - - - - - - NA._.... - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - 20 C.MTv.olad~Ql!atetoçirc.ulate.o.n.conduçtpr.&$l!rfC$g.. . . . . . . . . . . . . . . · . . .NA.... . - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - . . . - - - - - - - - - - - - 21 .CMT vol adeQl!ate. to tie-inJong .string to.surf C$g. . . - - - - - - - - - - ...NA_.... - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - -- - - - - - - - - - - -- - - - - - - - 22 .CMT will coYer.all Mown.pJQductiYe borizons. . . - - - - - - - - - - - - - - - . . . . . Ye'$. . . . . . . . . . - - - - - - - - - - - - - - - -- - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - 23 C.asillg design$ <ldequa.te {or C,. T. B& permélf(os!. . . - - - - - - - - - - . . . . . Yes. . . . . . . . . . - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - -- - - - - - - - - - - - - - - - 24 Adequate.tan.k<lge.or re.selYe pit. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Y~'$. . . . . . . Nab.ors.2.ES, . . . . . - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - '. . 25 Jfare-.drilL has.a. 10-403fQr abélndor¡ment be~1l aPPJQv~d . - - - - - . . ... Y~'$....... *.. - - - -- - - - - - - - - - - - - - - - . . . - - - - - -- . . - - - - - - - -- - - - - - 26 Adequate.l/\le!lboJ~ $epªratjoJl.propo$eß. . . . . _ . . . . . _ . . . . . _ _ . . . . . _ _ . . . . . _ . Ye'$. _ _ _ . . . . . . . . . . . _ . . . . . . _ . . . . . . _ _ . . . . . _ . . . . . . . . _ . . . . _ _ . . . . . _ . . . . . . . . . . . . _ . . . . 27 -'fdiv~rterrequiJed, dQes itmeet r~guJa.tiolJs. . . . . . . . . - .. . . . . . . . . . . .NA . . . . . . . Sidet(ack.. . . . . _ . . . . . . . . . . . . . . . . . - - - - - - - - - - - - - - - - - - - - - - - - - -- - - - - - - Appr Date 28 .DJilIillg flujd. program sçhematjc.& eq.uip Jistadequate. . . . . . . . - - - - - - - - - - · Y~s. . . . . Max MW.t02ppg.. . . . - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - WGA 10/29/2004 29 BDPE'$,. dottJey meet r~gl!la.tiolJ . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Y.e'$. . . - - - - - - - - - - - - - - - - - - - - - - - - - - - -- - - - - - - - - - - - - - - - - - - - - - -- - - - - - - - - - 30 B.QPEpres'$ ratiog appropriC!te:test to.(put p$ig i.n.comm~lJt$). . - - - - - - - - - - . . Ye'$ . . . . . . Testto.3500 psi..MSF' 23.70 P$i.. . - - - - - - - - - - - - - - - - - - - -- - - - - - - - - - - - - - - - - - - . . . 31 Choke.l11C!nifold çomplies. w/APtRF'-53 (May 64) - - -- - - - - - - - - - - - · _ . . . . Y~s. . . - - - - - - - - - - - - - - -- - - - - - - - - - - - - - -- - - - - - - - -- - - - - - - - - - - - - - - - - - - - - - - 32 Work will pcc.U( withou!.operatjonshl!tdQwn. . . . . . . . . . . . . - - - - -- - - - - . . Ye'$. - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - -- - - - - - - - - - - - - - - - - - - - - - - - - - 33 Is. presence. Qf H2S gas proQable. . . . . . - - - - - - - - - - - - - - - - - - - - - · Ye'$. . . . . . 5Q ppm Qn.pad.. . . . . . . . . . . . - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - -- .. . 34 .Me~ba.n¡C<llcood.itioll p{ wells wittJilJ Jl.OR yerified (FO( s.ervj~ .",,~IJ only) . . . . . . . . . . . . .NA . . . . . . . . . . - - - - - - - - - - - - - - - - - - - - - - - -- - - - - - - - - - - - - - - - - - - - - . . . . . . . . . . . . Geology 35 P.ermit GaO be is'$ued .",,/Q tJyd(ogen. s.ulfide m~as.ures. . . . . . . . . . . . . . . . . . . . . . . . . No. . . . . - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - 36 .D.ata. pres~oted or¡ potentiC!1 overpressllre .zone~. . . . . . . . . . . . . . . . . . . . . . . . . . . _ .NA . . . . . . - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - -- - - - - - Appr Date ~ :~:::~::~~::~s~ o;~s~:;~; ~;~$~:~~s: . : : : : : : : . : : : : : : : . . : : : . . . . : . : : . : . : .~; : : : : : : . . : : . : : _ . . . . : : . . . . : : . . . _ . : : : . : : : : . . : . : . : : . : : : : . . : : . . : . . : : . . . . : : . . . . . . RPC (J1~fù~ 39 . Conta.ct r¡ameLphoneJor.weekly prpgre$s.report'$ (exploratol)'.onIYl . . . . .. . _ . . .NA . . . . . . . . . . . . . . . .. ....... ........... _. . . . . . . . . . .. ...... .... ..... Geologic Date: Engineering Date ftß- Date Commissioner: Commissioner: o . ioner DTS 11) ) I+- 1,/ 1 ~ . . Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify fìnding infom1ation, information of this 1ature is accumulated at the end of the fìle under APPENDIX. No special effort has been made to chronologically organize this category of information. . Sperry-Sun Drilling Services LIS Scan Utility . ~¿)1- 2 ¿ 0 }, ~ ~ - ;L'L-1- $Revision: 3 $ LisLib $Revision: 4 $ Thu Mar 10 14:33:40 2005 '/3679 Reel Header Service name.... ....... ..LISTPE Date. . . . . . . . . . . . . . . . . . . . .05/03/10 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. . . . . . . . . . . . . . . . . . . . .05/03/10 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 PBU MWD/MAD LOGS # WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: # JOB DATA 15-14A 500292068201 BP Exploration Sperry Drilling Services 10-MAR-05 JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 2 MW0003494195 D. RICHARDSO J. FRANKS MWD RUN 3 MW0003494195 D. RICHARDSO J. FRANKS MWD RUN 4 MW0003494195 N. WHITE M. MONNIN # SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: 22 llN 14E 2349 1522 58.18 29.68 # WELL CASING RECORD 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) 8573.0 9930.0 # REMARKS: . . 1. ALL DEPTHS ARE BIT DEPTHS UNLESS OTHERWISE NOTED. THESE DEPTHS ARE MEASURED DEPTH (MD). 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTH (TVD). 3. MWD RUN 1 WAS DIRECTIONAL ONLY TO POSITION THE WHIPSTOCK; MILL THE WINDOW; AND DRILL A BIT OF RAT HOLE. THE TOP OF THE WHIPSTOCK WAS AT 8S73'MD/7230'TVD. NO DATA ARE PRESENTED FOR RUN 1. 4. MWD RUNS 2 - 4 COMPRISED DIRECTIONAL; DUAL GAMMA RAY (DGR) UTILIZING GEIGER-MUELLER TUBE DETECTORS; AND ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4). RUNS 3 & 4 INLCLUDED AT-BIT INCLINATION (ABI). RUN 4 ALSO INCLUDED COMPENSATED THERMAL NEUTRON POROSITY (CTN) AND STABILIZED LITHO- DENSITY (SLD). MAD PASS SLD DATA WERE ACQUIRED FROM 10840'MD - 10243.5'MD, WITHIN THE RUN 3 INTERVAL. THESE MAD DATA WERE REPROCESSED IN AN ATTEMPT TO REDUCE SPIKINESS. THEY WERE THEN MERGED WITH THE RUN 4 MWD DATA. THE SNP2 DATA OVER THIS INTERVAL ARE NOT REPROCESSED. 5. DEPTH SHIFTING OF MWD DATA WAS WAIVED PER E-MAIL, DATED 1/27/05, FROM D. DORTCH (SIS/BP) TO R. KALISH (SSDS), QUOTING AUTHORIZATION FROM TED CAHALANE. HOWEVER, lS-14A DATA WERE TIED-IN TO A GAMMA RAY RUN IN 15-14, PROVIDED BY D. DORTCH. THIS TIE-IN RESULTED IN A BLOCK SHIFT OF ABOUT 7' UPWARD. THESE CORRECTED MWD DATA ARE CONSIDERED PDC. 6. MWD RUNS 1 - 4 REPRESENT WELL lS-14A WITH API#: 50-029-20862-01. THIS WELL REACHED A TOTAL DEPTH (TD) OF 13237'MD/8910'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 (SEDP). TNPS = SMOOTHED THERMAL NEUTRON POROSITY (SANDSTONE MATRIX, FIXED HOLE SIZE) . CTFA SMOOTHED AVERAGE OF FAR DETECTOR'S COUNT RATE. CTNA = SMOOTHED AVERAGE OF NEAR DETECTOR'S COUNT RATE. SBD2 = SMOOTHED BULK DENSITY-COMPENSATED (LOW-COUNT BIN) . SC02 = SMOOTHED STANDOFF CORRECTION (LOW-COUNT BIN) . SNP2 = SMOOTHED NEAR DETECTOR ONLY PHOTOELECTRIC ABSORPTION FACTOR (LOW-COUNT BIN) . SLIDE = NON-ROTATED INTERVALS REFLECTING BIT DEPTHS. SLDSLIDE = NON-ROTATED INTERVALS REFLECTING SENSOR DEPTHS. . . PARAMETERS USED IN POROSITY LOG PROCESSING: HOLE SIZES: 6.125" MUD WEIGHT: 8.5 PPG MUD SALINITY: 2800 - 4500 PPM CHLORIDES FORMATION WATER SALINITY: 10994 PPM CHLORIDES FLUID DENSITY: 1.0 G/CC MATRIX DENSITY: 2.65 G/CC LITHOLOGY: SANDSTONE $ File Header Service name... ..........STSLIB.001 Service Sub Level Name... Version Number......... ..1.0.0 Date of Generation...... .05/03/10 Maximum Physical Record. .65535 File Type............... .LO Previous File Name. ......STSLIB.OOO Comment Record FILE HEADER FILE NUMBER: EDITED MERGED MWD Depth shifted DEPTH INCREMENT: # FILE SUMMARY PBU TOOL CODE GR RPX RPS RPM RPD FET ROP FCNT NPHI NCNT DRHO RHOB PEF $ 1 and clipped curves; all bit runs merged. .5000 START DEPTH 8493.5 8555.5 8555.5 8555.5 8555.5 8555.5 8598.0 10221.0 10222.0 10222.0 10236.0 10236.0 10236.0 STOP DEPTH 13167.5 13174.5 13174.5 13174.5 13174.5 13174.5 13229.5 13139.5 13139.5 13139.5 13154.5 13154.5 13154.5 # BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH ------- BASELINE DEPTH 8502.5 8509.5 8516.0 8524.0 8527.5 8531. 0 8538.5 8544.5 8547.0 8557.5 8567.0 8570.5 8573.5 13229.5 $ # MERGED DATA SOURCE PBU TOOL CODE MWD GR 8509.0 8515.0 8522.5 8530.0 8533.5 8538.0 8546.0 8550.0 8552.5 8564.0 8574.0 8576.0 8581.0 13237.0 BIT RUN NO MERGE TOP 2 8500.0 MERGE BASE 9932.0 . MWD MWD $ 3 4 9932.0 10916.0 10916.0 13237.0 . # REMARKS: MERGED MAIN PASS. $ # Data Format Specification Record Data Record Type....... ...........0 Data Specification Block Type... ..0 Logging Direction...... ...........Down Optical log depth units... ....... .Feet Data Reference Point. ....... ..... . Undefined Frame Spacing.. ....... ...... ..... .60 .1IN Max frames per record.. ..... ......Undefined Absent value.. ......... ...........-999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD FT/H 4 1 68 4 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 NPHI MWD PU-S 4 1 68 32 9 FCNT MWD CNTS 4 1 68 36 10 NCNT MWD CNTS 4 1 68 40 11 RHOB MWD G/CM 4 1 68 44 12 DRHO MWD G/CM 4 1 68 48 13 PEF MWD BARN 4 1 68 52 14 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 8493.5 13229.5 10861.5 9473 8493 . 5 13229.5 ROP MWD FT/H 0.24 822.6 119.643 9264 8598 13229.5 GR MWD API 14.04 518.33 83.7116 9349 8493.5 13167.5 RPX MWD OHMM 0.26 2000 29.8305 9239 8555.5 13174.5 RPS MWD OHMM 0.23 2000 36.9406 9239 8555.5 13174.5 RPM MWD OHMM 0.17 2000 47.764 9239 8555.5 13174.5 RPD MWD OHMM 0.23 2000 61.1301 9239 8555.5 13174.5 FET MWD HOUR 0.29 72 .22 2.1023 9239 8555.5 13174.5 NPHI MWD PU-S 12.16 40.56 24.0153 5836 10222 13139.5 FCNT MWD CNTS 261.04 1325.93 629.255 5838 10221 13139.5 NCNT MWD CNTS 18679.2 36867.2 28819.5 5836 10222 13139.5 RHOB MWD G/CM 1.822 3.119 2.35483 5834 10236 13154.5 DRHO MWD G/CM -0.273 10.942 0.0726755 5834 10236 13154.5 PEF MWD BARN 0.57 7.56 2.2543 5838 10236 13154.5 First Reading For Entire File....... ...8493.5 Last Reading For Entire File......... ..13229.5 File Trailer Service name............ .STSLIB.001 Service Sub Level Name... Version Number....... ....1.0.0 Date of Generation... ....05/03/10 Maximum Physical Record..65535 File Type.............. ..LO Next File Name.......... .STSLIB.002 . Physical EOF File Header Service name. .......... ..STSLIB.002 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation..... ..05/03/10 Maximum Physical Record..65535 File Type. . . . . . . . . . . . . . . .LO Previous File Name...... .STSLIB.001 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE GR RPM RPS RPX RPD FET ROP $ 2 . header data for each bit run in separate files. 2 .5000 START DEPTH 8500.0 8562.0 8562.0 8562.0 8562.0 8562.0 8605.5 STOP DEPTH 9896.0 9888.0 9888.0 9888.0 9888.0 9888.0 9932.0 # 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. RES IS. 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: 15-JAN-05 Insite 66.37 Memory 9932.0 8573.0 9932.0 28.7 39.8 TOOL NUMBER 053519 121079 8.500 8573.0 FlowPro 10.50 51.0 9.3 2600 3.8 1.320 .660 .940 1.390 68.0 143.6 60.0 68.0 . . # 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 MWD020 FT/H 4 1 68 4 2 GR MWD020 API 4 1 68 8 3 RPX MWD020 OHMM 4 1 68 12 4 RPS MWD020 OHMM 4 1 68 16 5 RPM MWD020 OHMM 4 1 68 20 6 RPD MWD020 OHMM 4 1 68 24 7 FET MWD020 HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 8500 9932 9216 2865 8500 9932 ROP MWD020 FT/H 0.24 220.72 93.1687 2654 8605.5 9932 GR MWD020 API 37.44 458.38 160.993 2793 8500 9896 RPX MWD020 OHMM 0.37 1780.62 3.40287 2653 8562 9888 RPS MWD020 OHMM 0.45 1780.99 3.3765 2653 8562 9888 RPM MWD020 OHMM 0.41 1641.12 3.34009 2653 8562 9888 RPD MWD020 OHMM 0.5 2000 16.6451 2653 8562 9888 FET MWD020 HOUR 0.3 6.4 0.891772 2653 8562 9888 First Reading For Entire File......... .8500 Last Reading For Entire File...... .... .9932 File Trailer Service name............ .STSLIB.002 Service Sub Level Name... Version Number.... ...... .1.0.0 Date of Generation...... .05/03/10 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..... ..05/03/10 Maximum Physical Record..65535 File Type.............. ..LO Previous File Name...... .STSLIB.002 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE FET RPD RPM RPS RPX GR ROP $ 3 . header data for each bit run in separate files. 3 .5000 START DEPTH 9888.5 9888.5 9888.5 9888.5 9888.5 9896.5 9932.5 STOP DEPTH 10861. 5 10861. 5 10861. 5 10861. 5 10861.5 10854.5 10916.0 # 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): 19-JAN-05 Insite 66.37 Memory 10916.0 9932.0 10916.0 29.0 88.6 TOOL NUMBER 160788 156404 6.125 9930.0 Flow Pro 8.40 46.0 9.2 4400 7.2 .850 .000 1. 960 1.920 90.0 118.4 90.0 90.0 . . EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type......... ...... ...0 Data Specification Block Type.. ...0 Logging Direction............... ..Down Optical log depth units... ... .....Feet Data Reference Point........... ...Undefined Frame Spacing................... ..60 .1IN Max frames per record........... ..Undefined Absent value.................... ..-999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type. ..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 2 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 9888.5 10916 10402.3 2056 9888.5 10916 ROP MWD030 FT/H 1.18 190.02 51.0767 1968 9932.5 10916 GR MWD030 API 14.04 518.33 50.093 1917 9896.5 10854.5 RPX MWD030 OHMM 0.26 1767.44 40.675 1947 9888.5 10861. 5 RPS MWD030 OHMM 0.23 1884.61 57.2069 1947 9888.5 10861. 5 RPM MWD030 OHMM 0.17 2000 104.854 1947 9888.5 10861. 5 RPD MWD030 OHMM 0.23 2000 139.003 1947 9888.5 10861. 5 FET MWD030 HOUR 0.86 72 .22 5.1969 1947 9888.5 10861. 5 First Reading For Entire File........ ..9888.5 Last Reading For Entire File.......... .10916 File Trailer Service name............ .STSLIB.003 Service Sub Level Name... Version Number. ... ...... .1.0.0 Date of Generation... ....05/03/10 Maximum Physical Record..65535 File Type............... .LO Next File Name.......... .STSLIB.004 Physical EOF File Header Service name............ .STSLIB.004 Service Sub Level Name... Version Number.. ........ .1.0.0 Date of Generation...... .05/03/10 Maximum Physical Record. .65535 File Type............... .LO Previous File Name.. .... .STSLIB.003 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE FCNT NPHI NCNT PEF RHOB DRHO GR RPM RPS RPD FET RPX ROP $ . 4 . header data for each bit run in separate files. 4 .5000 START DEPTH 10228.5 10229.5 10229.5 10243.5 10842.5 10842.5 10855.0 10862.0 10862.0 10862.0 10862.0 10862.0 10916.5 # 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 SLD CTN EWR4 $ # STOP DEPTH 13147.0 13147.0 13147.0 13162.0 13162.0 13162.0 13175.0 13182.0 13182.0 13182.0 13182.0 13182.0 13237.0 BOTTOM) TOOL TYPE DUAL GAMMA RAY STABILIZED LITHO DEN COMP THERMAL NEUTRON 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): # 22-JAN-05 Insite 66.37 Memory 13237.0 10916.0 13237.0 88.5 97.5 TOOL NUMBER 160788 10597832 116332 156404 6.125 9930.0 Flo Pro 8.40 47.0 9.3 2900 6.6 2.400 1. 260 2.200 1. 990 70.0 140.0 70.0 70.0 . . TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type........ .... ......0 Data Specification Block Type.. ...0 Logging Direction............... ..Down Optical log depth units.......... .Feet Data Reference Point............. .Undefined Frame Spacing.................... .60 .1IN Max frames per record.. ...... ... ..Undefined Absent value........... ...........-999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type. ..0 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 NPHI MWD040 PU-S 4 1 68 32 9 FCNT MWD040 CNTS 4 1 68 36 10 NCNT MWD040 CNTS 4 1 68 40 11 RHOB MWD040 G/CM 4 1 68 44 12 DRHO MWD040 G/CM 4 1 68 48 13 PEF MWD040 BARN 4 1 68 52 14 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 10228.5 13237 11732.8 6018 10228.5 13237 ROP MWD040 FT/H 0.37 822.6 163.849 4642 10916.5 13237 GR MWD040 API 17.17 122.6 51. 0678 4641 10855 13175 RPX MWD040 OHMM 13.03 2000 40.7585 4641 10862 13182 RPS MWD040 OHMM 15.84 2000 47.9921 4641 10862 13182 RPM MWD040 OHMM 17.82 2000 49.5367 4641 10862 13182 RPD MWD040 OHMM 20.59 2000 53.4146 4641 10862 13182 FET MWD040 HOUR 0.29 22.53 1. 49551 4641 10862 13182 NPHI MWD040 PU-S 12.16 40.56 24.0153 5836 10229.5 13147 FCNT MWD040 CNTS 261. 04 1325.93 629.255 5838 10228.5 13147 NCNT MWD040 CNTS 18679.2 36867.2 28819.5 5836 10229.5 13147 RHOB MWD040 G/CM 1. 822 3.119 2.36109 4640 10842.5 13162 DRHO MWD040 G/CM -0.273 10.942 0.0730203 4640 10842.5 13162 PEF MWD040 BARN 0.57 7.56 2.2543 5838 10243.5 13162 First Reading For Entire File...... ... .10228.5 Last Reading For Entire File........ ...13237 File Trailer Service name............ .STSLIB.004 Service Sub Level Name... Version Number........ ...1.0.0 Date of Generation...... .05/03/10 Maximum Physical Record. .65535 File Type.... ......... ...LO Next File Name......... ..STSLIB.005 . . Physical EOF Tape Trailer Service name............ .LISTPE Date. . . . . . . . . . . . . . . . . . . . .05/03/10 Origin. . . . . . . . . . . . . . . . . . . STS Tape Name. . . . . . . . . . . . . . . .UNKNOWN Continuation Number..... .01 Next Tape Name......... ..UNKNOWN Comments.... ....... ......STS LIS Writing Library. Scientific Technical Services Reel Trailer Service name. ............LISTPE Date. . . . . . . . . . . . . . . . . . . . .05/03/10 Origin. . . . . . . . . . . . . . . . . . . STS Reel Name.............. ..UNKNOWN Continuation Number..... .01 Next Reel Name.......... .UNKNOWN Comments................ .STS LIS Writing Library. Scientific Technical Services Physical EOF Physical EOF End Of LIS File