The URL can be used to link to this page

Home My WebLink About202-193By Anne Prysunka at 1:26 pm, Sep 19, 2022 STATE OF ALASKA RECEIVED • AL A OIL AND GAS CONSERVATION COMM, JN • REPORT OF SUNDRY WELL OPERATIONS JAN 14 2015 1 Operations Abandon Repair Well Cl Plug Perforations ❑ Perforate file Other ❑ AOGCC Performed. Alter Casing❑ Pull Tubing ❑ Stimulate-Frac ❑ Waiver Time Extension❑ Change Approved Program❑ Operat Shutdown❑ Stimulate-Other ❑ Re-enter Suspended WE 2 Operator 4 Well Class Before Work 5 Permit to Dnll Number BP Exploration(Alaska),Inc Name. Development El Exploratory 202-193-0 3 Address P O Box 196612 Stratigraphic ❑ Service❑ 6.API Number: Anchorage,AK 99519-6612 50-029-22573-01-00 7 Property Designation(Lease Number) 8 Well Name and Number ADL0028314 PBU 14-44A 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 15280 feet Plugs measured None feet true vertical 9061 38 feet Junk measured 13350 feet Effective Depth measured 15280 feet Packer measured See Attachment feet true vertical 9061 38 feet true vertical See Attachment feet Casing Length Size MD TVD Burst Collapse Structural None None None None None None Conductor 80 20"91 5#H-40 28 5-108.5 28 5-108 5 1490 470 Surface 3259 10-3/4"45 5#NT-80 28-3287 28-3218 66 4560 1730 Intermediate None None None None None None Production 11581 08 7-5/8"29 7#L-80 25 8-11606 88 25 8-8435 86 6890 4790 Liner 1501 27 5-1/2"17#L-80 11460.61-12961 88 8353.32-8938 85 7740 6280 Perforation depth Measured depth 13226-13243 feet 13925-14563 feet 14718-14839 feet 14964-15278 feet True Vertical depth 9021 49-9027 73 feet 9051 43-9031 96 feet 9036.89-9038.17 feet 9042 24-9061.44 feet Tubing(size,grade,measured and true vertical depth) 4-1/2"12.6#L-80 23.54-11473 2 23 54-8360 5 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 i i 0 2 :r1 u, 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. 271 532 4213 1724 293 Subsequent to operation. 197 0 5300 1967 348 14 Attachments 15 Well Class after work Copies of Logs and Surveys Run Exploratory ❑ Development 2 Service ❑ Stratigraphic ❑ Daily Report of Well Operations X 16 Well Status after work Oil I] Gas ❑ WDSPL ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ❑ SUSP ❑ SPLUG ❑ 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C 0 Exempt N/A Contact Garry Catron Email Garry.CatronaBP.Com Printed Name Garry Catron Title PDC PE Signature //��J'1 .^,y`I Ca..) ------- Phone 564-4424 Date 1/14/2015 vii- 1/ 7/15- RBDMS.' JAN 1 6 2015 0.7 , ----- Form 10-404 Revised 10/2012 Submit Original Only Packers and SSV's Attachment ADL0028314 SW Name Type MD TVD Depscription 14-44A PACKER 4344 3997.57 2-7/8" Baker KB Packer 14-44A PACKER 4365 4010.19 2-7/8" Baker KB Packer 14-44A PACKER 11418 8328.52 4-1/2" Baker S-3 Perm Packer 14-44A PACKER 11473 8360.39 5-1/2" BAKER ZXP PACKER /k / // E N / £ o_ _ � Fs % 2 7 = co (.00_ \ % \ k N N % e § \ a \ _1 / w / / 0 - . N CE � // 1 r 2 0 f 0 1 § p / 0 . R 2 N -e1 w0O s_ / / < / m » O L I o \ k co- / co- � / /E o > I a ® co ƒ 0 _ � / / \ \ ? /_ + U/ 0 -I : $ cC ® e \ . ® o / /b 2 I a \ 7 = / \ CO y : R \ -§ I c a O < > ; \ e o » rcoI _ I a) y - < / \ \ \ ' / \ [ \ ± ƒ \ I ƒ \ a E \ \ / © 0)E >. zam0 ¥ / 91 / ¥ / $ [ ._ O H LT 2 O O = % 0 0 o e ▪■ co 2 ± O H E E _ / H\ o \ _? n z / \ 0 \ 7 k $ / R / \ / \ G H G \ 2 = LC) » 2 / 2 » o e w co E - / \ > ƒ \ 0 co 0 e . 5 a , \ $ \ \ 0 - $ / / .C $ / / \ $ / 2- _1 ± _i r •- 0 ' t r o a f 0 r > ? .\_ \ / ? .� z \ \ o ? Eo ? R .- - w E e A 2 : 0 z : 002 c : 0 O ƒ . \ / \ # # } N N N CO G 6 N N N N N N TREE= 4-1/16"CNV YIIELLFEA1) 13-5/8"RC 14-44A SAI NOTES:WELL ANGLE>70'@ 12286'. ACTUATOR= BAKER C NTIAL KB.ELE 72' BF.ELEV= 41' KOP= 11608 t ' [1 2192' 14-1/2"I-ES X PP,D=3.813" Max Angie= 98°@ 14515' ST MD TVD DEV TYPE VLV LATCH FORT DATE Datum MD= 12731' 1 3028 2993 26 KBG-2 DOME BK 16 10/08/12 Datum TVD= 8800'SS- 2 4352 4002 53 KBG-2 'RIMY BK 0 12/28/11 10-3/4'CSG,45.5#,NT-80-LI-E,D=9.953" H 3288' 3 6865 5496 54 KBG-2 DOME BK 16 10/08/12 4 8514 6494 52 KBG-2 DOME BK 16 10/08/12 4-1/2'BKR PATCH,D=2.40" — 4345'-4365' 5 9965 7390 51 KBG-2 DOME BK 16 10/08/12 6 11330 8276 53 KBG-2 SO BK 24 10/08/12 'STA#2=BB-IND BKR PATCH ' i--1 11397' —14-1/2"FES X PP,D=3.813" Minimum ID = 2.313" @ 11462' 4-1/2" X 2-7/8" NIP REDUCER Z X 11418' H 7-5/8"X 4-1/2'BKR S-3 FKR,D=3.875' ir--I 11441' H4 1i2"FfS X NP,D=3.813" 11462' —I4 1/2"HES XN NP,D=3.725" 11462' —4-1/2"X 2-7/8"NP REDCR,D=2.313"(10/9/12) 4-1/2"LNR,12.6#,L-80,0.0152 bpf,13=3.958' H 11473' 8 11474' —14-1/7 WLEG,D=3.958" 11473' —7-5/8"X 5-1/2"BKR ZXP LIP,0=4.910" II ' 1148V —BKR RS PACKOFF SEAL NP,D=4.875" 7-5/8"CSG,29.7#,USS-95,D=6.875' — —11650 r• • �j MLLOUT WNDOW (14-44A)11608'-11658' 12809' —+5-1/2-X 3-1/2"BKR ZXP LTP,D=2.92" 5-1/2'LM,17#,L-80,.0233 bpf,D=4.892" —I 12963' , PERFORATION SUMMARY T REF LOG: I I 13350'CTMD 1—FISH-SL TOOL STRING ((1-1/2"sPANGS, ANGLE AT TOP PERF:89°@ 13925' I STEM,2.25'CENT,ETC(13.8'OAL))-10/20/13 Note:Refer to Production DB for historical perf data I I SEE SPF INTERVAL Opn/Sqz SHOT SQZ 2' 6 13226-13243 0 12/26/14 I I I I 4-1/2" SLID 13925-14563 SLOT 11/07/02 I I 4-1/2" SLID 14718-14839 SLOT 11/07/02 I I I I 4-1/2" SLID 14964-15278 SLOT 11/07/02 I I I I I I I I I I 3-1/2'SLID LNR,9.2#,L-80,.0087 bpf,D=2.992' H 15280' ; DATE REV BY X*f.UITS DATE REV BY COMM M'S PRIDHOEBAY LNT 09/19/95 INITIAL COM PLET ON11/07/13 TJPJC FISH CORRECTION(10/20/13) WELL: 14-44A 11/08/02 DAV/KK SIDETRACK(14-44A) , MH-01/05/15 BLS/JMD PUSH FISH DWADPERFS(12/26/14) PERMIT No: 2021930 12/26/12 LECJJMD PULLED XX PLUG(12122/12) API No: 50-029-22573-01 09/25/13 JRD+PJC DATUM MD CORRECTIONS SEC 9,T1 ON,R14E,2451'FM_1617'FEL 09/25/13 PJC FRORFMT DRAWING 11/06/13 JTGIJMD SET FISH(10/20/13) BP Ecpioration(Alaska) ) ) 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. ét 0 J. - 1 c¡.3 Well History File Identifier Organizing (done) 0 Two-sided 1111111111111111111 ~scan Needed OVERSIZED (Scannable) 0 Maps: RESCAN Ølor Items: D Greyscale Items: DIGITAL DATA ~iskettes, No. Lt D Other, NolType: 0 Other Items Scannable by a Large Scanner D Poor Quality Originals: OVERSIZED (Non-Scannable) D Other: D Logs of various kinds: BY: Helen éria) D Other:); Date: I Î 3 {)5 Isl VVt ~ NOTES: BY: Helen ~ I Date: I 1.3.()s; Isl vt(Q Project Proofing Scanning Preparation [", x 30 = )JO + ¡. q =,TOTf-LPAGES ¡:J-J/ / (count, c.:>e,s nc: include cover sheet) iliA, J!) Date: I I ð f)$; 151 r v~,- I BY: Helen ~ Production Scanning Stage 1 Page Count from Scanned File: Î 30 (Count does include cover sheet) Page Count Matches Number in Scanning Preparation: / X'ES, Helen~ Date: I ~c¡ O.s- . YES NO NO "jJ 151 ~, BY: Stage 1 BY: If NO in stage 1, page(s) discrepancies were found: Helen Maria Date: 151 I I Date: 151 Quality Checked 1111111111111111111 Scanning is complete at this point unless rescanning is required. ReScanned BY: Helen Maria Comments about this file: RECEIVED STATE OF ALASKA AlikA OIL AND GAS CONSERVATION COMMON DEC 2 7 2012 REPORT OF SUNDRY WELL OPERATIONS AOGCC 1. Operations Abandon U Repair Well kJ Plug Perforations U Perforate Lf Other t4 Performed: Alter Casing ❑ Pull Tubing0 Stimulate - Frac ❑ Waiver ❑ Time Extension❑ Change Approved Program ❑ Operat. Shutdown❑ Stimulate - Other ❑ Re -enter Suspended Well❑ 2. Operator 4. Well Class Before Work: 5. Permit to Drill Number: Name: BP Exploration (Alaska), Inc Development In Exploratory ❑ - 202 -193 -0 3. Address: P.O. Box 196612 Stratigraphic❑ Service ❑ 6. API Number: Anchorage, AK 99519 -6612 50- 029- 22573 -01 -00 7. Property Designation (Lease Number): 8. Well Name and Number: ADL0028314 PBU 14-44A 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field /Pool(s): To Be Submitted PRUDHOE BAY, PRUDHOE OIL 11. Present Well Condition Summary: Total Depth measured 15280 feet Plugs measured 11445 feet true vertical 9061.55 feet Junk measured None feet Effective Depth measured 11445 feet Packer measured See Attachment feet true vertical 8344.36 feet true vertical See Attachment feet Casing Length Size MD TVD Burst Collapse Structural None None None None None None Conductor 80 20" 91.5# H -40 33 - 113 33 - 113 1490 470 Surface 3259 10 -3/4" 45.5# NT -80 32 - 3291 32 - 3222.07 4560 1730 Intermediate None None None None None None Production 12471 7 -5/8" 29.7# L -80 30 - 12501 30 - 8797.93 6890 4790 Liner 1501 5 -1/2" 17# L -80 11462 - 12963 8354.11 - 8939.16 7740 6280 Perforation depth Measured depth 13925 - 14563 feet 14718 - 14839 feet 14964 - 15278 feet True Vertical depth 9051.43 - 9031.96 feet 9036.89 - 9038.17 feet 9042.24 - 9061.44 feet Tubing (size, grade, measured and true vertical depth) See Attachment See Attachment See Attachment •• -:s 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): Treatment descriptions including volumes used and final pressure: SCANNED JAN 16 Z 013 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas -Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: 81 452 3056 740 262 Subsequent to operation: 0 0 0 0 0 14. Attachments: 15. Well Class after work: Copies of Logs and Surveys Run Exploratory❑ Development el - Service ❑ Stratigraphic ❑ Daily Report of Well Operations X 16. Well Status after work: Oil . ig Gas ❑ WDSPLU GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP ❑ SPLUG❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: N/A Contact Garry Catron Email Garry.Catront BP.Com Printed Name Garry Catron Title PDC PE Signature I/ a4-4.1 er.. Phone 564 -4424 Date 12/21/2012 a 4 urt, 4 3 LUE /1-- Z./112.s Form 10 -404 Revised 10/2012( 27491/2„..- Submit Original Only • • Packers and SSV's Attachment ADL0028314 SW Name Type MD TVD Depscription 14-44A PACKER 4344 3928.07 2 -7/8" Baker KB Packer 14-44A PACKER 4365 3940.69 2 -7/8" Baker KB Packer 14-44A PACKER 11418 8259.02 4 -1/2" Baker S -3 Perm Packer 14-44A PACKER 11473 8290.89 5 -1/2" BAKER ZXP PACKER Casing / Tubing Attachment ADL0028314 Casing Length Size MD TVD Burst Collapse CONDUCTOR 80 20" 91.5# H-40 33 - 113 33 - 113 1490 470 LINER 1501 5 -1/2" 17# L -80 11462 - 12963 8354.11 - 8939.16 7740 6280 PRODUCTION 12471 7 -5/8" 29.7# L -80 30 - 12501 30 - 8797.93 6890 4790 SURFACE 3259 10 -3/4" 45.5# NT -80 32 - 3291 32 - 3222.07 4560 1730 TUBING 11449 4 -1/2" 12.6# L -80 25 - 11474 25 - 8360.96 8430 7500 TUBING 26 2 -7/8" 6.5# L -80 4344 - 4370 3997.57 - 4013.19 10570 11160 • 1 1 • • • Daily Report of Well Operations ADL0028314 ACTIVITYDATE I SUMMARY INITIAL T /I /O = 400/350/0 RIH WITH 4 -1/2" x 26.21' BAKER PATCH (20.55' ELEMENT TO ELEMENT) PATCH SETTING DOWN BUT FALLING THRU AND DRAGGING APPROX 150 - 200# WHILE LOGGING UP PAST GLM #2 DURING CORRELATION PASS CORRELATED TO TBG TALLY DECISION MADE TO GO AHEAD WITH SETTING PATCH CURRENTLY PULLING INTO POSITION TO SET PATCH 11/19/2012 * ** JOB CONTINUED ON 20 -NOV -2012 * ** * ** JOB CONTINUED FROM 1 -NOV -2012 * ** SET PATCH OVER INTERVAL BETWEEN_ 4345' - 4365'. CCL TO TOP ELEMENT = 8.3'. CCL STOP AT 4336.7' TOP OF PATCH = 4343.5' POOH. FINAL T /I /O = 280/300/0. WELL SHUT IN ON DEPARTURE -� 11/20/2012 * ** JOB COMPLETED ON 20 -NOV -2012 * ** • TREE= 4- 1/16" CM/ ' • WB1F EAD = 13 -518' FMC SA. NOTES: WELL ANGLE a 70• 12288'. AcfuATOFZ = — BAKER c 14-44A IB. B- B/ = _ _ 69.5' KOP= 11608 I ' ' I I 2192' (--I4 -1/2" HES X IMP D= 3.813" I VIA — angle = 98 Dawn AD= 13234' ST ND TVD DEV TYPE VLV LATCH PORT DATE DatumTVD= 8955' SS 1 3028 2993 26 KBG-2 DONE BK 16 10/08/12 IL--- 2 4352 4002 53 KBG-2 'DAM BK 0 1228111 1 10.3/4" CSG, 45.5#, NT 80 -LFE, ID= 9.953" 3288' 3 6865 5496 54 KBG-2 DONE BK 16 10/08/12 4 8514 6494 52 KBG-2 DONE BK 16 10/08/12 '� 1~ I 5 9965 7390 51 KBG- DONE BK 16 1 0108/ 12 14 -1/2" BKR PATCH, D= 2.40' H 4346' - 4385.1 6 11330 8276 53 KBG-2 SO BK 24 10/08/12 s it 26 /1i •STA #2 = BB-M BKR P14TCH I I I 1139T H4 -1/2" HES X NP, D= 3.813" I Minimum ID = 2.313" @ 11462' 4 -112" X 2 -718" NIP REDUCER Z S` I 11418' H7- 5/8 " X4- 12"BKR S- 3PKR, ID= 3.875' I I I I 11441' H4-12" HESXNP, D= 3.813" I F I 11462' H4 -1/2" HES XN NP; 13= 3.725" I 11462' H 4-12° X 2 -718" NP RB3CR, 13= 2.313" (10/9 /12) 11462' H2-7/8" XX PLUG (10109112) I 14-12" LNR, 12.8#, L-80, 0.0152 bpf, D = 3.958' H 11473' I 1 11474' H4-1/2" WLEG, D = 3.958" I 11473' H7 -5/8' X 5-1/2' BKR ZXP LIP, D = 4.910' I 11481' H BKR RS PACKOFF SEAL PE', 1:4= 4.875" I i i c.fi • • • * AALLOUT WINDOW (14.44/0)11608 ' - 11658' �•�•�••• ••••• ••••• FES EZSV BP 11855' !i!i!i!i!i!i!i!•. ITOP of caarr H 12000 ,•,•,— - SO��j�j�j * . 12809' 5-12" X 3-1/T BKRZXP ■••• E LN2 TOP F'iffi, 0= 2.92' • 17 -518' CSG, 29.7#, UWS -95, ID= 6.875" H 12498• I 4.044 ��• IF X000004 "F *1 * 4 44 I 4-12" LN2, 12.61/, L-80, 0.0152 bpf, ID= 3.958' H 14638' I l L . . • • . . 5 . PERORATION SUAM ARI' • • REF LOG: • • ANGLE AT TOP FB3F: 89° 4 13925' I 5-1/2" LNZ, 17 #, L-80, .0233 bpf, D = 4.892' I—{ 12963' I s , Note: Refer 10 R DB for historical perf data ' s NIP SIZE SPF EtVAL Opn/Scg DATE y M 4-1/T SLID 13925 -14563 0 11 /07/02 // 4-12° SLID 14718 -14839 0 11/07/02 1 3-1/2" SLID LW, 92#, L -80, .0087 bpf, 13= 2.992" H 15280' I 4-12' SLID 14964 -15278 0 11 /07/02 DATE REV BY COMVENTS DATE REV BY COMLBJtS PRUDHOE BAY LINT 09/19/95 ORIGNAL COMPLETION 10/15/12 SWC/PJC GLV C/O (10/08/12) WELL: 14-44A 11/08/02 DAV/KK SDETRACK (14 -44A) 10/15/12 SWCIPJC SET NP HOCK! XX PLUG (10/9112) PT3W1T No: "2021930 1228102 THIKAK SLOTTED LNR CORRECTIONS 11/26/12 JCMJMD SET BKR PATO-MN D CORR (1120112; AR No: 50 -029- 22573 -01 04/01/08 CJNSV GLV CIO (04/01/08) SEC9, T1ON, R14E, 2451' FTL 1617' FE. 12/30/11 SWCIJMD SET PAN PLUG (1229/11) 01/02/12 SWCI PJC GLV CIO (1228/11) BP BcpIoration (Alaska) 31-JAN -2012 ' 2 s / Schtwnherger SCANNED FEB 2 5 2013 5885 Alaska Data & Consulting Services Company: State of Alaska 2525 Gambol! Street, Suite 400 Alaska 011 & Gas Cons Comm Anchorage, AK 99503 -2838 Attn: Christine Shartzer ATTN: Stephanie Pacillo 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Well Job # Log Description • • Date BL Color CD 01 -24A BINC -00093 INJECTION PROFILE 15- Jan -12 1 1 01 -25 BBSK-00105 INJECTION PROFILE 9- Jan -12 1 1 . 14-44A BUTT -00054 MEMORY LEAK DETECT LOG 28- Dec -11 1 1 01 -02 BVYC -00024 CROSSFLOW CHECK 30- Dec -11 1 1 V -212 BAUJ -00106 MEMORY INJECTION PROFILE 26- Dec -11 1 1 5 -110 BX69 -00018 USIT 7-Jan-12 1 1 01 -02 BYS4-00015 CROSSFLOW CHECK 4-Jan-12 1 1 • R -16 BG4H-00106 SBHPS 23- Dec -11 1 1 01-30 8088-00189 MEMORY INJECTION PROFILE 19- Dec -11 1 1 15-47 BG4H -00105 CEMENT BOND LOG SCMT 20- Dec -11 1 1 13 -12A BVYC -00018 ISOLATION SCANNER 30- Nov -11 1 1 MPI -18 BG4H -00107 ISOLATION SCANNER 25- Dec -11 1 1 NGI -10 BBSK -00102 USIT 16- Dec -11 1 1 • Z -118 BBSK-00104 ISOLATION SCANNER 22- Dec -11 1 1 V -222 BUTT-00051 MEMORY INJECTION PROFILE 26-Dec-11 1 1 V -106A BCRJ-00108 FSI 15- Aug -11 1 1 • I PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Alaska Data & Consulting Services Petrotechnical Data Center LR2 -1 2525 Gambell Street, Suite 400 900 E. Benson Blvd. Anchorage, AK 99503 -2838 BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB-20 Post Office Box 196612 Anchorage, Alaska 99519-6612 Dec 07, 2009 '' ~~s .~~tiri~~~ J~I~~ ~{ Mr. Tom Maunder Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage, Alaska 99501 Subject: Corrosion Inhibitor Treatments of GPB DS 14 Dear Mr. Maunder, • by _,~ ~?E~ 'LL `~ ~JJ9 ..~ai~e~~~iG ~. _ a4 ~~a Enclosed please find multiple copies of a spreadsheet with a list of wells from GPB DS 14 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, at 659-5102. Sincerely, Torin Roschinger BPXA, Well Integrity Coordinator • BP Exploration (Alaska) Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) DS-14 Date: 12/05/09 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 14-01A 1931850 500292031701 Sealed Conductor NA NA 14-02C 2071150 500292031803 Sealed Conductor NA NA 14-03A 1961290 500292031901 Sealed Conductor NA NA 14-04A 1961640 500292032001 Sealed Conductor NA NA 14-05A 1920010 500292032701 Sealed Conductor NA NA 14-O6A 2040360 500292032801 Sealed Conductor NA NA 14-07 1780660 500292032900 Sealed Conductor NA NA 14-08A 202 100 500292033001 Sealed Conductor NA NA 14-09B 1820340 500292053402 Sealed Conductor NA NA 14-10 1801300 500292052800 Sealed Conductor NA NA 14-11A 2051260 500292052901 Sealed Conductor NA NA 14-12 1811090 500292063100 Sealed Conduct r NA NA 14-13 1811010 500292062400 Seated Conductor NA NA 14-14 1811020 500292062500 Sealed Conductor NA NA 1a-15 1810840 500292061100 Sealed Conductor NA NA 14-16A 1971670 500292060801 Sealed Conductor NA NA 14-17A 2030010 500292056201 Sealed Conductor NA NA 14-186 2071290 500292055102 Sealed Conductor NA NA 14-19 1810450 500292057800 Sealed Conductor NA NA 1a-20 1810700 500292059800 Sealed Conductor NA NA 14-21A 2051070 500292075601 Sealed Conductor NA NA 14-22A 1921230 500292074701 Sealed Conductor NA NA 14-23A 2090200 500292075701 NA 4 NA 25.50 10/20/2009 14-24 1830910 500292097000 NA 0.6 NA 3.40 10/20/2009 14-25 1831020 500292098100 NA 2.1 NA 15.30 11/16/2009 14-26 1811100 500292063200 Sealed Conductor NA NA 14-27 1831700 500292104600 NA 3 NA 17.00 10/25/2009 14-28 1820120 500292070800 Sealed Conductor NA NA 14-29 1811680 500292068000 Sealed Conductor NA NA 14-30 2050940 500292067901 Sealed Conductor NA NA 14-31 1831110 500292098900 Sealed Conductor NA NA 14-32 1831220 500292099900 NA 0.6 NA 3.40 10/19/2009 14-33 1831250 500292100200 Sealed Conductor NA NA 14-34 1831330 500292101000 NA 7.3 NA 47.60 10/20/2009 14-35 1831420 500292101800 Sealed Conductor NA NA t4-36 1831630 500292103900 NA 0.7 NA 3.40 10/20/2009 t4-37 1880490 500292181000 NA 1.3 NA 5.10 10/20/2009 14-38 1881030 500292186200 NA 0.8 NA 3.40 10/24/2009 14-40A 2011350 500292187501 Sealed Conductor NA NA 14-41 1920960 500292229000 NA 0.8 NA 6.80 10/18/2009 14-43 1921080 500292229600 NA 1.4 NA 10.20 10/23/2009 14-44A 2021930 500292257301 NA 10 NA 88.40 11/24/2009 . . MICROFILMED 07/25/06 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE F:\LaserFiche\CvrPgs _ Inserts\Microfilm _ Marker.doc ) ) OCT 2 6 2005 WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Howard Okland 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 May 13,2004 RE: MWD Formation Evaluation Logs: I4-44A & I4-44A PBI, AK-MW-22I68 14-44A + PD1: -LI- / 7 f Digital Log Images: -H- ~ ~ L- I 50-029-22573-01, 71 1 CD Rom PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING THE ATTACHED COPIES OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Rob Kalish 6900 Arctic Blvd. Anchorage, Alaska 99518 BP Exploration (Alaska) Inc. Petro-technical Data Center, LR2-I 900 E. Benson Blvd. Anchorage, Alaska 99508 Date: :> (O~~lNr Signed: iLl lJiLJ '.~;.ii."tø... .."f-~I.~" ,-,,--...,"/.r ,,"""".~ ~þiIo.......,..,... ~.. StANNEC' OC1 3 1 ZDO~\ «. .- ~oÀ.-I'l~ K(~ '7 b~,- Á~'~ '-( DATA SUBMITTAL COMPLIANCE REPORT 12/29/2004 Permit to Drill 2021930 Well Name/No. PRUDHOE BAY UNIT 14-44A Operator BP EXPLORATION (ALASKA) INC API No. 50-029-22573-01-00 MD 15280 / -~------~._-_._-~_.~- -~------ NO 9060 /' Completion Date 11/7/2002 / Completion Status 1-01L ------,--------_._~--~-~.- ------~-- REQUIRED INFORMATION Mud Log No Samples No --_.-_.._--------~--------'~~--~~ -------------._--~-,.----~~-,--~.,,---- DATA INFORMATION Types Electric or Other Logs Run: Well Log Information: MWD, DIR, GR, RES, PWD Log/ Electr Data Digital Dataset !~_~edIFrmt _~umber Name ~ZD ~ .-1SIrectional Survey 8pt' " ,.-~Q 0 _J3Ð ...0 ...sD . æf R15( Fqqt/ Rp( /' Rpt -!;D' 0 Log Log Scale Media Run No 1 1 1 LIS Verification Vt4 663 US-Verification vði;ectional Survey """"Oirectional Survey J /\ t ,^"J ~\ Current Status 1-01L UIC N Directional Survey Directional Survey Directional Survey Directional Survey d,f662 ¡¡&.ve=rtf¡caiíõnl~ L~ ~, Directional Survey No (data taken from Logs Portion of Master Well Data Maint) Interval OH / Start Stop CH Received Comments 11606 14386 Open 12/6/2002 PB 1 11540 14319 Open 4/17/2003 PB1 11540 15229 Open 4/17/2003 11606 14386 Open 12/6/2002 MWD PB 1 13098 15280 Open 12/6/2002 MWD 13098 15280 Open 12/6/2002 MWD 11606 14386 Open 12/6/2002 MWD PB1 An H2S Measurement is required to be submitted. This record automatically created from Permit to Drill Module on: 9/18/2002. 11606 14386 Open 12/6/2002 PB1 13098 15280 Open 12/6/2002 11540 14319 Open 4/17/2003 PB1 A Directional Survey Log is required to be submitted. This record automatically created from Permit to Drill Module on: 9/18/2002. L9" ."Ò ,/Óirectional Survey 13098 15280 Open 12/6/2002 ..,.*,~~ ,..RPt LIS Verification 11540 15229 Open 4/17/2003 'J=D C Pdf ¿)I'2582. Raæ.œ.Perrë"frãtion J.-, ~t.... ;4, 11608 14386 Open 6/9/2004 ROP, DGR, EWR, MWD, GRAPHIC IMAGES ~b C Pdf (,,/12583 Rate-&f-PeT1'et'fãtion 1-~rt- 11608 15280 Open 6/9/2004 ROP, DGR, EWR, MWD, GRAPHIC IMAGES --~~.~------------~..-----~-~~ ~ DATA SUBMITTAL COMPLIANCE REPORT 12/29/2004 Permit to Drill 2021930 Well Name/No. PRUDHOE BAY UNIT 14-44A Operator BP EXPLORATION (ALASKA) INC API No. 50-029-22573-01-00 MD 15280 Well Cores/Samples Information: NO 9060 Name ADDITIONAL INFORMATION Y~ Chips Received? ..)?ffi/ ~. Well Cored? Analysis Received? Comments: -_._--------~~--------~- -~------------~-_._-~-~-~-- ~-. .~---_.~._------~------_.~~-- ---_.._--~- Compliance Reviewed By: Completion Date 11/7/2002 Completion Status 1-01L ~ I Interval Start Stop Sent Received Daily History Received? Formation Tops Current Status 1-01L Sample Set Number Comments @~ &N Date: UIC N .~ J o/Jc~ ~~J- -- "> I :2Ð). -- f'tS }ZSgr2 +83 WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Howard Okland 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 May 13,2004 RE: MWDFormationEvaluationLogs: 14-44A& 14-44APB1, AK-MW-22168 14-44A+PBl: Digital Log Images: 50-029-22573-01, 70 1 CD Rom PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING THE À"TACHED COPIES OF THE TRANS:MITTAL LETTER TO THE ATTENTION OF: ' Speny-Sun Drilling Services Attn: Rob Kalish 6900 Arctic Blvd. Anchorage, Alaska 99518 BP Exploration (Alaska) Inc. Petro-technical Data Center, LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Date: q/%cf s4ir!.¿J~ RECE'VED jU;\l 0 9 2004 AJaskaOU&GasCons,~¡ Alid'dage ) ) TR:æ= 4-1/16" OW WELLHEA D = 13-5/8" FMC "..m,.....,................. ...................................."................. . ACTUATOR = BAKERC .....u~"",.....~w......,.,.~"...'^w.u~u~..~..~.,~"...~~~..,"'".....~ KB. ELBI = 69.5' 'äF:'EC'EV~';'"-""'''''''''''''''''''''-'''41i 'ï<ö Þ"; m."",,,...-.".....".."......m"'1'1'608' ~~,~:E~~i~."~"~::"~.~~~~~::~~¥'~i: 'Dätum IvD = 13276' 'bätÚm iYb;' .."" 8955;"8'5 14-44A I ~ ~ SAFETY NOTES: 2192' 1-i4-1/2" rES X NIP, ID = 3.813" 1 GAS LIFT MANDRELS TVD DEV lYPE VLV LATŒi 2992 26 KBG-2 DMY BK 4001 53 KBG-2 RP BK 5494 54 KBG-2 DMY BK 6493 52 KBG-2 DMY BK 7388 51 KBG-2 DMY BK 8274 53 KBG-2 DMY BK FORT" DATE 0 11/07/02 11/07/02 0 11/07/02 0 11 /07/02 0 11/07/02 0 11/07/02 t'10-3I4" CSG, 45.5#, Nf-80-LHE, ID = 9.953" 1-1 3288' J ~ ST MD 1 3028 2 4352 3 6865 4 8514 5 9965 6 11330 L Minimum ID = 2.92" @ 12809' 5-112" X 3-1/2" BKR ZXP LNR TOP PKR . ~ I 1 11397' H4-1/2" HESX NIP, ID=3.813" 1 Z - 11418' 1-i7-5/8" X4-1/2" BKRS-3 A<R, ID = 3.875" 1 IHES EZSV IBP l-i 11855' TOPOFCB\AENT 1-1 12000' 1 ~ ~ ~ 1 11441' 1-14-1/2'HESXNP,'D=3.813" 1 1 11462' 1-14-1/2" HESXNNIP, ID= 3.725" 1 14-1/2' LNR, 12.6#, L-80, 0.0152 bpf, ID =3.958" H 11473' 1 I 11474' 1-i4-1/2"WLEG,ID= 3.958" I ---t 11473' 1-i7-5/8" X 5-1/2' BKRZXPLNRTOPPKR, ID=4.910" 1 11481' I-iBKRRS PAO<OFFSEAL NIP,ID =4.875" 1 MLLOUTWINDOW 11608' - 11658' ~ 17-5/8" CSG, 29.7#, USS-95, D = 6.875" l-t 12498' ~ 1- 5-1/2" X 3-1/2' BKR ZXP LNR TOPPKR, ID = 2.92" 1 4-1/2" LNR, 12.6#, L-80, 0.0152 bpf, ID = 3.958" l-i 14638' .... .... .... , , , , , , 1 5-1/2" LNR, 17#, L-80, .0233 bpf, ID = 4.892" l-i 12963' 1 , , , , , , , , , , , , , .. 7' 15280' 1 PERFORATION SUrvTv1ARY REF LOG: ANGLEA TTOP PERF: Note: Refer to Production DB for historical perf da1a SIZE SPF INTERVAL Opn/Sqz DA TE 4-1/2" SL 10 13925 - 14563 0 11/07/02 4-1/2" SL 10 14718 - 14839 0 11/07/02 4-1/2" SL 10 14964 - 15278 0 11/07/02 .... .... .... .... 1 3-1/2' SLTD LNR, 9.2#, L-80, .0087 bpf, D = 2.992" 1-1 DA TE REV BY COMIvENTS 09/19/95 ORlGIN.t\L COMR...EllON 11/08/02 DA V IKK RIG S DETRACK (14-44A) 12/28/02 TH'KAK SLOTTED LNR OJRREcrlONS DATE REV BY OJMrvENTS PRUDI-OE BAY lJ'J1T "" WELL: 14-44A ~ PERMT No: 2021930 API No: 50-029-22573-01 SEC 9, T1 ON, R14E, 531.28 FEL 626.96 FI\L 8P Exploration (Ala~ka) '>~ I ~O~-/9S II to 10 ;;¿ WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Corom. Attn.: Lisa Weepie 333 West 7th Avenue, Suite 100 Anchorage, Alaska April 01, 2003 RE: MWD Formation Evaluation Logs 14-44APBl, AK-MW-22168 1 LDWG fonnatted Disc with verification listing. ~I#: 50-029-22573-71 ~ PLEASE ACKNOWLEDGE RECEJPT BY SIGNING AND RETURNING A COpy OF THE TRANSMITTAL LETTER TO THE ATTENDON OF: Sperry-Sun Drilling Services Attn: Rob Kalish 6900 Arctic Blvd. Anchorage, Alaska 99518 BP Exploration (Alaska) Inc. Petro- Technical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Date: Si~ ~rJ RECEIVED APR 1 7 2003 Alaska Ofi & Gas Cons. Com . . Anchorage' mJMion '\ ;> ~œ-/93 / 10103 WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Corom. Attn.: Lisa Weepie 333 West 7th Avenue, Suite 100 Anchorage, Alaska April 01, 2003 RE: MWD Formation Evaluation Logs 14-44A, AK-MW-22168 1 LDWG formatted Disc with verification listing. ~I#: 50-029-22573-01 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COpy OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Rob Kalish 6900 Arctic Blvd. Anchorage, Alaska 99518 BP Exploration (Alaska) Inc. Petro-Technical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Date: Si~~.~~ RECE\Vt:D APR 1 7 2003 Alal~~ Ot1 8: Gas Cons. Gommi5sion Anchorage '" ') STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG ,. 1. Status of Well 181 Oil 0 Gas 0 Suspended 0 Abandoned 0 Service 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface ~;:;7:~;¡ ~~~pNO~~~~~i:~~ie~?' Og, T10N, R14E, UM .i.i:¡¡:::' ¡ I.~ 4678' SNL, 5251' WEL, SEC. 16, T10N, R14E, UM jl~.Z:~~,,.,j ~~~~;~," '~', ''''',~ At total depth, :'." ,',: ë?U .~ '~i "~J;:" ~"'''):'';;'~'' 1124' SNL, 4174' WEL, SEC. 21, T10N, R14E, UM ,;;".!~.._,..:,~~,,-",,:~~"?"é?<o""'"'?"~':~> 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. KBE = 69.5' ADL 028314 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp., or Aband. 10/18/2002 . 11/412002 ' 11n/2002 ' 17. Total Depth (MD+ND) 18. Plug Back Depth (MD+ND) 19. Directional Survey 15280 9060 FT 15280 9060 FT 181 Yes 0 No 22. Type Electric or Other Logs Run MWD, DIR, GR, RES, PWD 23. CASING SIZE 20" 10-3/4" 7-5/8" 5-1/2" 3-1/2" WT. PER FT. 91.5# 45.5# 29.7# 17# 9.2# Classification of Service Well 7. Permit Number 202-193 8. API Number 50- 029-22573-01 9. Unit or Lease Name Prudhoe Bay Unit 10. Well Number 14-44A 11. Field and Pool Prudhoe Bay Field / Prudhoe Bay Pool 15. Water depth, if offshore 16. No. of Completions NIA MSL One 20. Depth where SSSV set 21. Thickness of Permafrost (Nipple) 2192' MD 1900' (Approx.) '7/¿.J~o-.I //C,32-" ~þ " ~/.. , Jt, yV\ ?Y2';) GRADE H-40 NT80 L-80 L-80 L-80 CASING, LINER AND CEMENTING RECORD SETTING DEPTH HOLE Top BOTTOM SIZE CEMENTING RECORD Surface 110' 30"260 sx Arctic Set (Approx.) 29' 3288' 13-1/2" 1210 sx CS III, 375 sx 'G', 181 sx CSII 27' 11616' 9-7/8" 265 sx Class 'G' 11462' 12963' 6-3/4" 121 sx Class 'G' 12809' 15280' 4-3/4" Uncemented Slotted Liner 24. Perforations open to Production (MD+ TVD of Top and Bottom and interval, size and number) 3-1/2" Slotted Sections MD TVD 13925' - 14563' 9050' - 9032' 14718' - 14839' 9035' - 9037' 14964' - 15278' 9041' - 9060' 27. Date First Production November 13, 2002 Date of Test Hou rs Tested 12/19/2002 6.1 Flow Tubing Casing Pressure Press. 256 25. SIZE 4-1/2", 12.6#, L-80 19Cr MD TVD AMOUNT PULLED TUBING RECORD DEPTH SET (MD) 11474' PACKER SET (MD) 11418' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED Freeze Protect with 91 Bbls of Diesl PRODUCTION TEST Method of Operation (Flowing, gas lift, etc.) Gas Lift PRODUCTION FOR OIL-BBL TEST PERIOD 720 CALCULATED OIL-BBL 24-HoUR RATE GAs-McF 21 GAs-McF WATER-BBL 1,811 WATER-BBL CHOKE SIZE 84.310 OIL GRAVITY-API (CORR) GAS-OIL RATIO 29 CORE DATA Brief description of lijhology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit coRtt E I V E D No core samples were taken. 28. Form 10-407 Rev. 07-01-80 ,3r RBDMS 8FL DEC 2 7 2002 Naska Oil & Gas Cons. Commission I: ï' L Mchorage ~ r- Submit In Duplicate '\, ') 29. Geologic Markers 30. Formation Tests Marker Name Measured Depth True Vertical Depth Include interval tested, pressure data, all fluids recovered and gravity, GOR, and time of each phase. Sag River 12947' 8933' Shublik A 12988' 8944' Shublik B 13067' 8966' Shublik C 13145' 8988' Sadlerochit 13225' 9020' Sadlerochit 14717' 9035' Sadlerochit 14961' 9041' 31. List of Attachments: Summary of Daily Drilling Reports and Post-Rig Work, Surveys 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed Terrie Hubble ~~ ~ ~ Title Technical Assistant Date \~. Â 7. 0 ~ 14-44A '202-193 Prepared By Name/Number: Terrie Hubb/e, 564-4628 Well Number Drilling Engineer: Dave Wes/e", 564-5773 Permit NO.1 Approval No. J: 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 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. ITEM 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. ITEM 16 AND 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. ITEM 21: Indicate whether from ground level (GL) or other elevation (OF, KB, etc.). ITEM 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITEM 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, Other-explain. ITEM 28: If no cores taken, indicate 'none'. Form 10-407 Rev. 07-01-80 Legal Name: 14-44A Common Name: 14-44A Test Date 10/18/2002 10/24/2002 Test Type FIT FIT TestDepth(T~D) 11,678.0 (ft) 12,963.0 (ft) Test Depth (TVD) 8,474.0 (ft) 8,940.0 (ft) AMW 11.50 (ppg) 8.50 (ppg) Surface Pressure 715 (psi) 695 (psi) Leak Off Pressure (BHP) 5,777 (psi) 4,643 (psi) EMW 13.12 (ppg) 10.00 (ppg) ~--" ~~ Printed: 11/12/2002 10:36:52 AM ') ) Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 14-44A 14-44A REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 2ES Qate Frøm"T.b 'Hours' TasI<Côde,NPT" :Phase '. 10/8/2002 04:30 - 10:00 5.50 MOB P PRE 10:00 - 12:00 2.00 MOB P 12:00 - 17:30 5.50 MOB P 17:30 - 19:30 2.00 MOB P 19:30 - 21 :00 1.50 MOB P 21 :00 - 22:30 1.50 MOB P 22:30 - 00:00 1.50 MOB P 10/9/2002 00:00 - 04:30 4.50 RIGU P 04:30 - 05:00 0.50 RIGU P 05:00 - 06:30 1.50 PULL P 06:30 - 11 :00 4.50 PULL P 11 :00 - 11 :30 0.50 WHSUR P 11 :30 - 12:00 0.50 PULL P 12:00 - 13:30 1.50 WHSUR P 13:30 - 15:00 1.50 BOPSUR P 15:00 - 18:00 3.00 BOPSUR P 18:00 - 20:00 2.00 BOPSUR P 20:00 - 20:30 0.50 PULL P 20:30 - 21 :30 1.00 PULL P 21 :30 - 23:30 2.00 PULL P 23:30 - 00:00 0.50 PULL P 10/10/2002 00:00 - 02:30 2.50 PULL P PRE PRE PRE PRE PRE PRE PRE PRE DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP 02:30 - 03:30 1.00 PULL P DECOMP 03:30 - 04:30 1.00 BOPSUR P DECOMP 04:30 - 06:00 1.50 PULL P DECOMP 06:00 - 09:30 3.50 FISH P DECOMP 09:30 - 10:30 1.00 FISH P DECOMP 10:30 - 11 :00 0.50 FISH P DECOMP 11 :00 - 11 :30 0.50 FISH P DECOMP 11 :30 - 13:30 2.00 FISH P DECOMP 13:30 - 14:30 1.00 FISH P DECOMP 14:30 - 15:00 0.50 FISH P DECOMP 15:00 - 15:30 0.50 PULL P DECOMP 15:30 - 21 :30 6.00 PULL P DECOMP Start: 1 0/6/2002 Rig Release: 11/7/2002 Rig Number: 2ES Spud Date: 8/6/1995 End: 11/7/2002 , ~~~çriPti()q:'ofQp~re¡t~Pf}~:' RD floor. Blow down pits. Move shop. Unhook top drive and bridal up blocks. Lower pipe chute, derrick, and handrails on wind wall. Raise cellar doors and move sub off A-22. Hold PJSM with tool service, security, and CPS. Move sub base from A pad to OS 14. Raise and pin derrick. Pin pipe chute. Bridal down. Pin blocks to top drive. Secure bridal lines. Lay herculite. Spot and level sub base over 14-44. Wait on CPS. Move camp and pits from A pad to OS 14. Spot shop and pits. Hook up secondary annulus valve to tree. Lay Herculite for cuttings tank. Berm rig. Lay walk ways. Spot cuttings tank and hook up interconnect. Spot camp. Hold pre spud meeting and review well hazards. Take on seawater. Accept rig at 05:00 10/9/2002. RU DSM and pull BPV with lubricator. Hook up hoses and attempt to pump down inner annulus. Unable to pump due to SSSV closed. Swap hoses and pump down tubing at 4 bpm, 360 psi. Install TWC. Blow down and unhook hoses from tree. NO tree and adapter flange. Remove tree from cellar. Verify hanger threads with XO. Terminate control lines. NU BOPE. Test BOPE to 250 psi /3,500 psi for 5 minutes as per BP policy and AOGCC regulations. Witness of test waived by John Crisp of AOGCC. Pull TWC. RU casing equipment and Camco spooling unit. BOLDS. Pull hanger to rig floor. Monitor well. Tubing came free at 120 K. Tubing weight is 49K versus 131 K calculated weight to tubing cut at 11,950'. POH and LD 41/2", L-80, IBT-M tubing to 2,203'. LD SSSV. Recovered 56 of 57 SS bands. RD Camco spooling unit. Continue to LD 41/2" tubing. Recovered 123 joints of 4 1/2" tubing, 1 GLM, 56 SS bands, 1 SSSV. Coupling of joint # 124 pulled free from tube and was screwed onto the pin end of joint # 123. Top offish at-5,140'. RD tubing equipment. Clear floor. RU and test lower pipe rams to 250 psi / 3,500 psi. Install wear bushing. PU and MU overshot assembly, DCs, and HWDP. PU 4 3/4" DCs. RIH from 842' to 4,986'. Slip and cut drilling line. RIH to 5,184' and tag fish. PU=190K Latch onto fish and work same. Pulled tubing free at 240K. POH from 5,184' to 842'. Stand back HWDP and Des. LD overshot with fish. RU casing equipment. LD 41/2" tubing. Recovered a total of 282 joints, 5 GLMs, 1 SSSV, 19.08' of cut joint. Traces of cement on joints 208 - Printed: 11/12/2002 10:36:59 AM ,. ) Start: 10/6/2002 Rig Release: 11/7/2002 Rig Number: 2ES , ' ,Pl1ase Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 14-44A 14-44A REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 2ES Date From~TQ . HoÙrs',':Ia$k ,- GQdêNf'W', 10/1 0/2002 15:30 - 21 :30 6.00 PULL P 21 :30 - 22:00 0.50 PULL P 22:00 - 23:30 1.50 PULL P 23:30 - 00:00 0.50 PULL P 00:00 - 04:00 4.00 PULL P DECOMP DECOMP DECOMP DECOMP 10/11/2002 DECOMP 04:00 - 05:00 05:00 - 12:00 1.00 CLEAN P 7.00 CLEAN P DECOMP DECOMP 12:00 - 13:30 1.50 CLEAN P 13:30 - 17:30 4.00 CLEAN P 17:30 - 18:30 1.00 CLEAN P 18:30 - 19:00 0.50 CLEAN P 19:00 - 19:30 0.50 CLEAN P 19:30 - 23:30 4.00 CLEAN P 23:30 - 00:00 0.50 CLEAN P 10/12/2002 00:00 - 01 :00 1.00 CLEAN P 01 :00 - 05:00 4.00 STMILL P 05:00 - 05:30 0.50 STMILL P 05:30 - 06:00 0.50 STMILL P 06:00 - 07:30 1.50 STMILL P 07:30 - 08:00 0.50 STMILL P 08:00 - 14:30 6.50 STMILL P 14:30 - 17:30 3.00 STMILL P 17:30 - 23:00 5.50 STMILL P 23:00 - 00:00 1.00 STMILL P 10/13/2002 00:00 - 04:00 4.00 STMILL P DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP WEXIT WEXIT WEXIT WEXIT WEXIT WEXIT WEXIT WEXIT WEXIT WEXIT 04:00 - 04:30 0.50 STMILL P WEXIT 04:30 - 05:00 0.50 STMILL P WEXIT 05:00 - 09:00 4.00 STMILL P WEXIT 09:00 - 10:00 1.00 STMILL P WEXIT 10:00 - 10:30 0.50 STMILL P WEXIT 10:30 -11 :00 0.50 STMILL P WEXIT 11 :00 - 11 :30 0.50 STMILL P WEXIT 11 :30 - 15:30 4.00 STMILL P WEXIT 15:30 - 16:30 1.00 STMILL P WEXIT 16:30 - 17:00 0.50 STMILL P WEXIT 17:00 - 00:00 7.00 STMILL P WEXIT Spud Date: 8/6/1995 End: 11/7/2002 ,1D~~dptiqrlQt()pef'~tiôns ' 215. Hole in joint 126. Release overshot from fish and LD same. RD casing equipment and clear floor. RU eline and RIH wI 6.75 gauge ring, junk basket, CCL, and weight bar. Run 6.75" guage ring, junk basket, CCL, and weight bar to 11,428'. Unable to get past 11 ,428'. POH and rig down eline. Recovered pieces of 1/4" cement sheath in junk basket. Break overshot. MU 6.75" concave mill and casing scraper. RIH picking up 249 joints of 4" DP. RIH with stands. Work through resistance from 11,428' to 11,949' with 2-3K. Tag tubing stump at 11,949'. Set down 10K. Circulate high visco sweep at 10 bpm, 2130 psi. Sweep brought back chunks of cement. POH to 846'. Stand back HWDP and DCs. Clear floor. RU eline. MU HES EZSV bridge plug and RIH. Set EZSV at 11,855' WLM. RD eline. Pressure test casing to 3,000 psi for 30 minutes. PU Baker section milling BHA and RIH to 11,765'. Service top drive. RIH and tag EZSVat 11,854'. Displace well bore to 11.3 ppg LSND milling fluid. Spot 18.0 ppg balanced mud pill from 11,854' to 11,608'. POH to 11,608'. PU=230K, SO= 125K. Torque = 9K. Cut section in 7 5/8", 29.7# casing from 11,608' to 11,616'. Flow rate 300 gpm, 3000 psi. Weight ,on knives, 2-5K. Torque, 10K -13K. RPM, 75 - 85. Approximately 50% metal recovery. Cuttings bird nest down hole. Encountered resistance attempting to pull into casing. Circulate sweeps and work section. Section mill from 11,616' to 11,622'. Mill coupling at 11,621'. Milling slowed to zero progress. Circulate low visco sweep and work pipe. Section mill 7 5/8" casing to 11,624'. Milling progress very slow. Mill stopped milling. Pump low visco and high visco sweeps. Pull into casing wlo problems. RIH and attempt to mill. No progress. Pull 5 stands. Monitor well. Well static. Pump dry job. Service top drive. Repair Upper riser air boot. POH from 11,234' to 844'. Stand back BHA. Change out section mill. One cutting surface of the section mill was bent. Little wear on cutting structure. Pull and rerun wear ring. RIH w/ BHA. Change elevators. RIH to 11 ,582'. Slip and cut drilling line. RIH to 11,608'. Section mill from 11,624' to 11,640'. Printed: 11/1212002 10:36:59 AM ') Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 14-44A 14-44A REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 2ES Start: 10/6/2002 Rig Release: 11 n /2002 Rig Number: 2ES Spud Date: 8/6/1995 End: 11/7/2002 Date Frorn,-.To Hòur~,Tásk,Coç:le ,"N'PT 10/14/2002 00:00 - 05:30 05:30 - 09:30 5.50 STMlll P 4.00 STMlll P WEXIT WEXIT 09:30 - 10:00 0.50 STMlll P WEXIT 10:00 - 10:30 0.50 STMlll P WEXIT 10:30 - 14:30 4.00 STMlll P WEXIT 14:30 - 15:30 1.00 STMlll P WEXIT 15:30 - 16:00 0.50 STMlll P WEXIT 16:00 - 18:00 2.00 STMlll P WEXIT 18:00 - 22:00 4.00 STMlll P WEXIT 22:00 - 22:30 0.50 STMlll P WEXIT 22:30 - 00:00 1.50 STMlll P WEXIT 10/15/2002 00:00 - 00:30 0.50 STMlll P WEXIT 00:30 - 01 :30 1.00 REMCM-P WEXIT 01 :30 - 02:30 1.00 REMCM-P WEXIT 02:30 - 03:30 03:30 - 05:30 1.00 REMCM-P 2.00 REMCM-P WEXIT WEXIT 05:30 - 06:00 0.50 REMCM-P WEXIT 06:00 - 09:30 3.50 REMCM-P WEXIT 09:30 - 10:00 0.50 REMCM-P WEXIT 10:00 - 13:30 3.50 REMCM-P WEXIT Section mill to 11,658'. Circulate surface to surface volume with low visco / high visco sweep. Moderate amount of metal returned with sweep. Pump additonallow visco / high visco sweep. Second sweep returns clean. Monitor well. Well static. POH from 11,658' to 11,210'. Pump dry job. Blow down top drive. POH to 844'. lD HWDP and DCs. Clear floor. MU BOP flushing tool. Flush out BOP stack. Service wear bushing. Clean out under shakers. Install flow paddles. MU 4" mule shoe and RIH. Break circulation every 2,000' to 11,580'. Wash from 11,584' to 11,758'. Circulate and condition mud, 11 bpm, 3,300 psi. Hold PJSM with cementers. Pull Above Top Of Section And RIH To 11,758' Without Problems - Rig Up Head Pin And Cement Line - BreakCirculation With Rig - Batch Mix Cement Slurry Hold Pre-Job Safety Meeting With All Personal - Shut Down And Turn Over To Dowell - Pump 5 BBlS Of Water - Test Cement Lines To 4,000 PSI. - Pump 10 BBlS Of Water - 25 BBlS Of 17.0 PPG Class "G" Cement - 5 BBlS Of Water - Displace With 104 BBlS Of Mud - Cement In Place At 01 :30 Hours Pull Out Of Cement Plug At 4 Minutes Per Stand For First 6 Stands - Continue To Pull 7 More Stands At Normal Rate Circulate Bottoms Up While Monitoring Well For losses Close Annular And Preform Hesitiation Squeeze Barrels Pressure 1.7 1025 2.0 1130 Wait 10 Minutes 2.2 1330 Wait 10 minutes 2.6 1530 Wait 10 minutes 2.9 1730 Wait 20 minutes 3.3 1930 Hold Final Squeeze Pressure For 1 hour - Bleed Pressure To Psi. - 1 BBL. Pumped Away - Open Annular Element Pump Dry Job - Rig Down Surface Circulating Equipment Hold Pre-Job Safety Meeting - POH With 4" Drill Pipe - Break Off Mule Shoe And Clear Rig Floor Pull Wear Bushing -Install Test Plug - Rig Up Testing Equipment Hold Pre-Job Safety Meeting - Test BOP And Related Equipment - Witness Of BOP Test Waived By AOGCC Inspector Jeff Jones - Test Annular, Upper And lower Pipe Rams, Floor Safety Valve, Dart Valve, Top Drive Upper And Printed: 11/12/2002 10:36:59 AM ) ) legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 14-44A 14-44A REENTER+COMPlETE NABORS ALASKA DRilLING I NABORS 2ES Start: 10/6/2002 Rig Release: 11/7/2002 Rig Number: 2ES Spud Date: 8/6/1995 End: 11/7/2002 Date Ftom,~To Hòu:f$' " ,1'as:(' ,eOde, ,NPT . ':Pi;1ase ' " J:)~ç[jptit:)h'pt:'9pØr~ti()(1s 10/15/2002 10:00 - 13:30 3.50 REMCM-P WEXIT lower IBOP Valves At 250 Psi. low And 3,500 Psi. High - Test Pit PVT System And H2S And lEl Detectors - Perform Accumulator Test 13:30 - 14:00 0.50 REMCM-P WEXIT Rig Down BOP Testing Equipment - Pull Test Plug - Install Wear Bushing - Clear Rig Floor 14:00 - 16:30 2.50 REMCM-P WEXIT Hold Pre-Job Safety Meeting - Pick Up And Make Up Kick Off BHA - Surface Test Sperry Sun Mud Motor And MWD Tool 16:30 - 20:00 3.50 REMCM-P WEXIT RIH With 4" Drill Pipe From Mast To 11328' - Break Circulation At 3,000' Intervals 20:00 - 21 :30 1.50 REMCM-P WEXIT Connect Top Drive - Break Circulation Wash Green Cement To 11,505' - Weight On Bit 2K To 5K With Pump Rate At 50 Strokes Or 122 GPM - Pump Pressure At 1250 Psi. - Top Drive RPM At 35 - Torque At 11 K - String Rotating Weight At 148K - With Pump Off Drag Up At 21 OK And Drag Down At 115K Shut Down Top Drive And Reduce Pump Rate Slack Off On Drill String With Out Taking Weight - Check PH (11.4) At Shakers 21 :30 - 00:00 2.50 REMCM-P WEXIT Circulate Out Green Cement And Condition Mud 10/16/2002 00:00 - 07:30 7.50 REMCM-P WEXIT Blow Down Top Drive - Stand Back 3 Stands Of 4" Drill Pipe In Mast - Service Can Rig Top Drive - Adjust Draw Works Mechanical Brakes - Change Out Pump Liners And Swabs In Number 1 Emsco Mud Pump - While Waiting On Cement Plug To Obtain 1,000 Psi. Compressive Strength 07:30 - 08:00 0.50 REMCM-P WEXIT RIH From 11,141' To 11,505' With 4" Drill Pipe From Mast 08:00 - 09:00 1.00 REMCM-P WEXIT Connect Top Drive - Break Circulation Wash Green Cement From 11,505' To 11,761' - Weight On Bit 2K To 5K With Pump Rate At 85 Strokes Or 210 GPM - Pump Pressure At 2050 Psi. - Top Drive RPM At 25 - Torque At 11 K - String Rotating Weight At 148K - With Pump Off Drag Up At 210K And Drag Down At 115K 09:00 - 11 :30 2.50 REMCM-N CEMT WEXIT POH From 11,761' To 11,608' - Circulate Bottoms Up In Window 11 :30 - 16:00 4.50 REMCM-N CEMT WEXIT Pump Dry Job - Blow Down Top Drive - POH With 4" Drill Pipe Standing Back In Mast 16:00 - 18:00 2.00 REMCM-N CEMT WEXIT Down load Sperry Sun MWD Tools - Stand Back BHA 18:00 - 22:30 4.50 REMCM-N CEMT WEXIT Make Up Mule Shoe And RIH With 4" Drill Pipe To 11,608' 22:30 - 23:00 0.50 REMCM-N CEMT WEXIT Connect Top Drive And Wash Down From 11,608' To 11,758' 23:00 - 00:00 1.00 REMCM-N CEMT WEXIT Circulate Bottoms Up And Condition Mud - Rig Up Head Pin And Circulating Lines - Hold Pre-Job Safety Meeting Regarding Cement Job With Crew Coming On Tour - Batch Mix Cement 10/17/2002 00:00 - 00:15 0.25 REMCM-N CEMT WEXIT Continue To Circulate At 11,761' - 7.5 BPM 2,000 Psi. 00:15 - 01:15 1.00 REMCM-N CEMT WEXIT Shut Down And Turn Over To Dowell Schlumberger - Pump 5 BBlS Of Water - Test Cement Lines To 4,000 PSI. (Test Good) - Pump 10 BBlS Of Water - 25 BBlS Of 17.0 PPG Class "G" Cement - 5 BBlS Of Water - Displace With 104 BBlS Of Mud - Cement In Place At 01 :08 Hours 01:15 - 02:15 1.00 REMCM-N CEMT WEXIT Pull Out Of Cement Plug At 3 Minutes Per Stand For First 6 Stands - Continue To Pull 7 More Stands At Normal Rate To 10,550' 02:15 - 03:00 0.75 REMC~N CEMT WEXIT Circulate Bottoms Up At 10 BPM 3100 Psi. - While Monitoring Well For losses 03:00 - 04:00 1.00 REMCM-N CEMT WEXIT Close Annular And Preform Hesitiation Squeeze Printed: 11/1212002 10:36:59AM ) ') Start: 10/6/2002 Rig Release: 11/7/2002 Rig Number: 2ES , . Phase Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 14-44A 14-44A REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 2ES [)élte . FrOI'Tl,Tó. HoUts. . Task' CQcle::NPt. 10/17/2002 03:00 - 04:00 1.00 REMCM-N CEMT WEXIT 04:00 - 08:00 4.00 REMCM-N CEMT WEXIT 08:00 - 09:30 1.50 REMCM-N CEMT WEXIT 09:30 - 10:30 1.00 REMCM-N CEMT WEXIT 10:30 - 11 :30 1.00 REMCM-N CEMT WEXIT 11 :30 - 14:30 3.00 REMCM-N CEMT WEXIT 14:30 - 21 :30 7.00 REMCM-N CEMT WEXIT 21 :30 - 22:00 0.50 REMCM-N CEMT WEXIT 22:00 - 00:00 2.00 DRILL N CEMT WEXIT 10/18/2002 00:00 - 01 :00 1.00 DRILL N CEMT WEXIT 01 :00 - 01 :30 0.50 DRILL P LNR1 01 :30 - 02:30 1.00 DRILL P LNR1 02:30 - 06:00 3.50 DRILL P LNR1 06:00 - 07:30 1.50 DRILL N RREP LNR1 07:30 - 15:30 8.00 DRILL P LNR1 15:30 - 16:00 0.50 DRILL P LNR1 16:00 - 16:30 0.50 DRILL P LNR1 Spud Date: 8/6/1995 End: 11/7/2002 , QesqriptiQn,ofeper~tiC)"s . Barrels Pressure 1.5 920 2.0 1130 2.2 1330 2.6 1530 2.9 1640 Wait 10 Minutes 3.4 1890 Wait 15 Minutes 3.6 1910 Bleed Pressure To Psi. - 1 BBL. Squeezed Away - Open Annular Pump Dry Job - Rig Down Surface Circulating Equipment - Hold Pre-Job Safety Meeting - POH With 4" Drill Pipe - Lay Down Mule Shoe - Clear Rig Floor Hold Pre-Job Safety Meeting - Make Up BHA - Initialize MWD Tools - Surface Test MWD Tool And Mud Motor - Disconnect Top Drive And Blow Down Surface Equipment RIH With 4" Drill Pipe From Mast To 3,019' Hold Pre-Job Safety Meeting - Hang Traveling Blocks - Slip And Cut 1 1/4" Drilling Line Continue To RIH With 4" Drill Pipe To 10,487' - Break Circulation Every 3,000' Wait On Second Cement Balanced Plug - Clean And Service Rig Change Out High Pressure Hydraulic Filters Notified Of 1,000 Psi. Compressive Strength For Cement Plug - Continue To RIH With 4" Drill Pipe To 11,325' - Connect Top Drive And Break Circulation Wash From 11,325' - Tag Up On Hard Cement At 11,382' Drill Cement (4,000 Psi. Compressive Strength) From 11,382' To 11,545' - Weight On Bit 6K To 8K With Pump Rate At 82 Strokes Or 200 GPM - Pump Pressure At 1950 Psi. - Top Drive RPM At 30 - Torque Off Bottom At 11 K - Torque On Bottom At 13K - String Rotating Weight At 150K - With Pump Off Drag Up At 21 OK And Drag Down At 115K Drill Cement (4,000 Psi. Compressive Strength) From 11,545' To 11,608' - Weight On Bit 6K To 1 OK With Pump Rate At 82 Strokes Or 200 GPM - Pump Pressure At 1950 Psi. - Top Drive RPM At 30 - Torque Off Bottom At 11 K - Torque On Bottom At 13K - String Rotating Weight At 150K - With Pump Off Drag Up At 21 OK And Drag Down At 115K Survey And Orient MWD Tool - Slide From 11,608' To 11,613' Circulate Bottoms Up - Clean Up Well Bore Slide And Time Drill From 11,613' To 11,625' Mud Line Washed Out On 2" Demeo Valve Weld In Mud Pump Room - Repair Wash Out And Test To 5,000 Psi. Continue To Kick Off Cement Plug - Slide And Time Drill From 11,625' To 11,678' Circulate Bottoms Up And Condition Mud For Fit Test Hold Pre-Job Safety Meeting - Pull Bit In 7 5/8" Casing - Closed Pipe Rams And Performed FIT. Strokes Pmp'd Pressure Printed: 11/1212002 10:36:59 AM .') Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 14-44A 14-44A REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 2ES Start: 10/6/2002 Rig Release: 11/7/2002 Rig Number: 2ES Spud Date: 8/6/1995 End: 11/7/2002 Date Ffom:~'To 'HoÜrs,i:Task' (}Ode<NPT".,':Phase , . Qe~~ripti()t;1øf'()p~ratióflŠ 10/18/2002 16:00 -16:30 0.50 DRILL P LNR1 5 10 15 20 25 30 35 36 30 psi 47 psi 85 psi 208 psi 350 psi 575 psi 695 psi 715 psi Held Test F/1 0 minutes w/20 Psi. Pressure Loss. MW 11.5 ppg, Csg Shoe NO 8,474' Pressure psi = 13.1 ppg EMW. Bleed Pressure To 0 Psi. - Opened Pipe Rams. 16:30 - 18:00 1.50 DRILL P LNR1 Obtain Slow Pump Rates - Drill Ahead From 11,678' To 11,703' - Weight On Bit 8K To 13K - With Pump Rate At 82 Strokes Or 200 GPM - Off Bottom Pump Pressure At 1580 Psi. & On Bottom Pump Pressure At 1950 Psi. - Top Drive RPM At 0 To 90 - Off Bottom Torque At 11 K & On Bottom Torque At 13K - String Rotating Weight At 150K - Drag Up With On At 210K And Drag Down At 120K 18:00 -19:00 1.00 DRILL P LNR1 Circulate Hi-Vis Sweep - Shear Open Near Bit Reamer - Ream Open Hole Section From 11,678' To 11,703' 19:00 - 00:00 5.00 DRILL P LNR1 Directional Drill Ahead From 11,703' To 11,808' - Weight On Bit 15K To 24K - With Pump Rate At 114 Strokes Or 279 GPM - Off Bottom Pump Pressure At 2850 Psi. & On Bottom Pump Pressure At 3150 Psi. - Top Drive RPM At 0 To 95 - Off Bottom Torque At 10K & On Bottom Torque At 12K - String Rotating Weight At 150K - Drag Up With On At 210KAnd Drag Down At 120K 10/19/2002 00:00 -16:00 16.00 DRILL P LNR1 Directional Drill Ahead From 11,808' To 12,060' - Weight On Bit 15K To 24K - With Pump Rate At 114 Strokes Or 279 GPM - Off Bottom Pump Pressure At 2850 Psi. & On Bottom Pump Pressure At 3200 Psi. - Top Drive RPM At 0 To 95 - Off Bottom Torque At 10K & On Bottom Torque At 12K - String Rotating Weight At 150K - Drag Up With On At 21 OK And Drag Down At 120K 16:00 - 16:30 0.50 DRILL P LNR1 Monitor Well Bore (Static) - POH With 4" Drill Pipe From 12,060' To 11,605' With No Problems 16:30 - 17:00 0.50 DRILL P LNR1 Serviœ Can-Rig Top Drive And Traveling Blocks 17:00 - 19:15 2.25 DRILL P LNR1 RIH To 11,707' - Circulate 50 BBL. Lo-Vis Sweep Followed Up With 50 BBL. 12.4 PPG Weighted 10% Flow Lube Sweep For Torque Reduction In Casing 19:15 - 19:30 0.25 DRILL P LNR1 RIH From 11,707' To 11,980' With No Problems 19:30 - 20:00 0.50 DRILL P LNR1 Conect Top Drive And Break Circulation - Wash From 11,980' To 12,060' (2 Feet Of Fill) 20:00 - 21 :00 1.00 DRILL P LNR1 Drill Ahead From 12,060' To 12,071' - Prepare To POH Due To Slow Penetration Rate - Mix Dry Job 21 :00 - 22:00 1.00 DRILL P LNR1 Monitor Well Bore (Static) - POH From 12,071' To 11,605' No Problems - Pump Dry Job And Blow Down Top Drive 22:00 - 00:00 2.00 DRILL P LNR1 Continue To POH With 4" Drill Pipe Standing Back In Mast 10/20/2002 00:00 - 02:00 2.00 DRILL P LNR1 Hold Pre-Job Safety Meeting - Continue To POH With Bit NO.1 (Due To Slow Penetration Rate) Standing 4" Drill Pipe In Mast Printed: 11/1212002 10:36:59 AM ) ) Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 14-44A 14-44A REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 2ES , Date' From .~'Jo Hburs'.,J:äsk, ØQde NPJ, , -_Phase- 10/20/2002 02:00 - 03:30 1.50 DRILL P LNR1 03:30 - 05:00 1.50 DRILL P LNR1 05:00 - 10:00 5.00 DRILL P LNR1 10:00 - 00:00 14.00 DRILL P LNR1 10/21/2002 00:00 - 22:30 22.50 DRILL P LNR1 22:30 - 00:00 1.50 DRILL P LNR1 10/22/2002 00:00 - 00:30 0.50 DRILL P LNR1 00:30 - 01 :30 1.00 DRILL P LNR1 01:30 - 02:15 0.75 DRILL P LNR1 02: 15 - 03:00 0.75 DRILL P LNR1 03:00 - 05:30 2.50 DRILL P LNR1 05:30 - 12:00 6.50 DRILL P LNR1 12:00 - 14:30 2.50 DRILL P LNR1 14:30 - 15:15 0.75 CASE P LNR1 Start: 1 0/6/2002 Rig Release: 11/7/2002 Rig Number: 2ES Spud Date: 8/6/1995 End: 11/7/2002 .. " - - - ,P~qr¡ptic)n.~Øf,Q~1"êltit?f'1¡$ , Hold Pre-Job Safety Meeting - Lay Down Drilling Jars - Stand Back BHA - Down Load Sperry Sun MWD Tools - Break Off Bit And Near Bit Reamer - Clear Rig Floor Change Bend In Sperry Sun Mud Motor - Orient MWD Tool To Motor - Make Up 6/34" Bit - Initialize MWD Tool And RIH With BHA - Pick Up Drilling Jars - Surface Test MWD Tool RIH With 4" Drill Pipe From Mast Fill Drill String Every 4,000' - Wash Last Stand To Bottom Directional Drill Ahead From 12,071' To 12,544' - Weight On Bit 9K To 13K - With Pump Rate At 114 Strokes Or 279 GPM- Off Bottom Pump Pressure At 3000 Psi. & On Bottom Pump Pressure At 3380 Psi. - Top Drive RPM At 60 To 90 - Off Bottom Torque At 10K & On Bottom Torque At 12K - String Rotating Weight At 150K - Drag Up With On At 200K And Drag Down At 120K *NOTE* Pumping Nut Plug Sweeps And Rotating Drill String Off Bottom As Needed To Prevent Bit Balling Directional Drill Ahead From 12,544' To 12,963' Setting Depth For 51/2" Liner - Weight On Bit 9K To 13K - With Pump Rate At 114 Strokes Or 279 GPM - Off Bottom Pump Pressure At 3000 Psi. & On Bottom Pump Pressure At 3380 Psi. - Top Drive RPM At 60 To 90 - Off Bottom Torque At 12K & On Bottom Torque At 14K - String Rotating Weight At 150K - Drag Up With On At 200K And Drag Down At 120K *NOTE* Pumping Nut Plug Sweeps And Stringing In Glass Beads While Rotating Drill String Off Bottom As Needed To Prevent Bit Balling Circulate Sweep And Condition Mud For Wiper Trip Circulate Sweep And Condition Mud - Monitor Well Bore (Static) Hold Pre-Job Safety Meeting - POH (Wet) With 4" Drill Pipe Standing Back In Mast To 11,572' With "NO Problems" - Well Bore In Good Shape - 5K To 12K Above Normal Upward Drag Service Top Drive, Traveling Blocks, And Draw Works RIH With 4" Drill Pipe From Mast To 12,883' With "NO Problems" - Well Bore In Good Shape - 5K To 10K Below Normal Downward Drag - Connect Top Drive And Break Circulation - Wash Last Stand To Bottom At 12,963' (No Fill) Circulate Sweep And Condition Mud - Spot Liner Running Pill - Pump Dry Job Hold Pre-Job Safety Meeting - Blow Down Can-Rig Top Drive And POH Laying Down 44 Joints Of 4" Drill Pipe - Drop 2 3/8" Rabbit - Continue To POH With 4" Drill Pipe Standing Back In Mast (SLM) Hold Pre-Job Safety Meeting - Lay Down Drilling Jars And Flex Collars - Down Load Sperry Sun MWD Tool - Pull Pulser - Lay Down MWD Tools - Drain Mud Motor - Break Off 6 3/4" Bit - Lay Down Motor - Clear And Clean Rig Floor Hold Pre-Job Safety Meeting - Rig Up Casing Tools And Equipment Printed: 11/1212002 10:36:59 AM ') I' Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 14-44A 14-44A REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 2ES Start: 10/6/2002 Rig Release: 11/7/2002 Rig Number: 2ES Spud Date: 8/6/1995 End: 11/7/2002 Date - .: -. , Frôm+Tó '.: HQ~,irs:::]á$K';:ØOde, -NPT,' 10/22/2002 15:15 - 18:00 2.75 CASE P LNR1 18:00 - 18:30 0.50 CASE P LNR1 18:30 - 23:30 5.00 CASE P LNR1 23:30 - 00:00 0.50 CASE P LNR1 10/23/2002 00:00 - 00:30 0.50 CASE P LNR1 00:30 - 01 :30 1.00 CASE P LNR1 01 :30 - 09:00 7.50 CASE P LNR1 09:00 - 10:00 1.00 CEMT P LNR1 10:00 - 12:00 2.00 CEMT P LNR1 Hold Pre-Job Safety Meeting - Pick Up Shoe Track And Check Floats - Continue To RIH With A Total Of 36 Joints 51/2" 17 lb. L-80 Hydril 521 Casing Per Well Program - Change Elevators For 4" Drill Pipe - Pick Up Baker Flex-Lock Liner Hanger And ZXP Liner Top Packer With Running Tool - Verify That Liner Wiper Plug In Baker Liner Hanger Rig Down Casing Equipment And Clear Rig Floor - Pick Up 4" Pup Joint And Single Of Drill Pipe - Circulate 51/2" Liner Volume *NOTE* Liner Weight At 18K When Full Of Mud Continue To Run Liner With 4" Drill Pipe From Mast (SLOW) To 11,546' - Fill Every 10 Stands Connect Top Drive And Break Circulation - Circulate Drill Pipe And Liner Volume - Stage Pump Rate Up To 51/2 BPM At 1109 Psi. - Up Weight At 198K And Down Weight At 115K - Rotate Liner At 10,000 Foot Pounds Continue To Circulate Drill Pipe And Liner Volume - Stage Pump Rate Up To 5 1/2 BPM At 1109 Psi. - Up Weight At 198K And Down Weight At 115K - Rotate Liner At 10,000 Foot Pounds - Disconnect And Blow Down Top Drive Continue To RIH With 5 1/2" Liner Thru Open Hole Section To 12,950' (No Problems) - Pick Up Baker Plug Droping Head Install Manifold And Circulating Lines Break Circulation And Tag Bottom At 12,963' - Stage Up Pump Rate (Slowly) With Full Returns And NO Losses - Attempting To Pack Off Due To Thick Mud Returns - Condition Mud - Reduce Pump Rate And Reciprocate Liner While Continuing To Stage Up Pumps Pump Rate 0.5 BPM 1.0 BPM 1.5 BPM 2.0 BPM 2.5 BPM 3.0 BPM 3.5 BPM 4.0 BPM Pressure 430 550 650 740 824 939 959 1150 Flow 8% 13% 17% 19% 20% 22% 23% 25% Unable To Exceed 3.5 BPM Consistant With Out Packing Off Problems - When Pump Rate Reduced Well Bore Gives Back Fluids With No Losses - Consult With Anchorage Drilling Team Members - Adjust Cementing And Spacer Volumes Hold Pre-Job Safety Meeting Regarding 5 1/2" Liner Cement Operation - Batch Mix Mud Push And Tail Slurry Shut Down And Turn Over To Dowell - Pump 5 BBL Fresh Water - Pressure Test Surface Equipment At 4,000 Psi. (Test Good) - Pump 10 BBLS 12.5 PPG Mud Push XL Spacer At 2.9 BPM - 20 BBLS 15.8 PPG Class "G" Cement Slurry At 3.4 BPM - Drop Drill Pipe Wiper Plug And Pump 114.5 BBLS. (11.4 PPG Mud) With Rig Pumps At 3.5 BPM - Reduce Rate To 1.5 BPM And Observe Latch Up Of Liner Wiper Plug - Printed: 11/12/2002 10:36:59 AM \ J Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 14-44A 14-44A REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 2ES Date,' ,Frørn;;.lo<HòÙrs",1:ask' Code 'NP1:Phase 10/23/2002 10:00 - 12:00 2.00 CEMT P LNR1 12:00 - 13:30 1.50 CEMT P LNR1 13:30 - 14:00 0.50 CEMT P LNR1 14:00 - 15:00 1.00 DRILL P LNR1 15:00 - 16:00 1.00 DRILL P LNR1 16:00 - 16:30 0.50 DRILL P LNR1 16:30 - 18:30 2.00 DRILL P LNR1 18:30 - 23:00 4.50 DRILL P LNR1 23:00 - 00:00 1.00 BOPSURP LNR2 10/24/2002 00:00 - 04:00 4.00 BOPSURP LNR2 04:00 - 04:30 0.50 BOPSUR P LNR2 04:30 - 05:30 1.00 DRILL P LNR2 05:30 - 09:00 3.50 DRILL P LNR2 09:00 - 14:00 5.00 DRILL P LNR2 Start: 10/6/2002 Rig Release: 11/7/2002 Rig Number: 2ES Spud Date: 8/6/1995 End: 11/7/2002 " 'På$~~iptipn::()t:Qp~~tiørtS Continue With Displacement Pumping A Total Of 147.5 BBLS At 3.5 BPM - Bump Plug To 3000 Psi. - Slack Off 20K And Verify That Flex Lock Liner Hanger Set -Increase Pressure To 3800 psi, PU 5', Unable To Release Running Tool From Liner Hanger, Place Liner On Setting Depth And Pressure Up To 4200 Psi. - Slack Off 20K And Verify That Liner Hanger Set At 11483', Able To Release From Liner - Bleed Off Pressure And Check Floats (OK) - Pick Up 4 Feet And Clear The Rotating Dog Sub Above The Tie Back Sleeve - Slack Off To 70K(45K) And Set ZXP Packer At 11472' - Continue To Slack Off To 30K(70K) - Repeat Process With 15 RPM And 65K Down Weight - Cement In Place At 11 :05 Hours, Top Of Tieback Sleeve At 11461' Pressure Up To 500 Psi. Pick Up And Pull"RS" Pack Off Free Of Seal - Observe Pressure Drop - Circulate Bottoms Up At 11,461' -1300 Psi. At 10 BPM - No Cement Returns To Surface Hold Pre-Job Safety Meeting - Rig Down Baker Plug Droping Head, Manifold And Circulating Lines - POH To 11,368' *NOTE* Nabors President Jim Denny Held Safety Meeting With On Tour Personal Hold Pre-Job Safety Meeting - Test Casing And 5 1/2" Liner At 3,500 Psi. For 30 Minutes (Test Good) Hold Pre-Job Safety Meeting - Slip And Cut 1 1/4" Drilling Line Service Can-Rig Top Drive And Traveling Blocks Displace Well To 8.3 PPG Fresh Water At 12 BPM 1200 Psi.- Pump Dry Job - Blow Down Surface Equipment And Top Drive Hold Pre-Job Safety Meeting - POH With 4" Drill Pipe Standing Back In Mast - Clean And Lay Down Baker Liner Running Tool - Clear Rig Floor Pull Short Wear Ring And Install Test Plug - Rig Up BOP Testing Equipment Hold Pre-Job Safety Meeting - Test BOP And Related Equipment - Witness Of BOP Test Waived By AOGCC Inspector Chuck Scheve - Test Annular, Upper And Lower Pipe Rams, Floor Safety Valve, Dart Valve, Top Drive Upper And Lower IBOP Valves At 250 Psi. Low And 3,500 Psi. High - Perform Accumulator Test *NOTE* Tested 2 7/8" AOH And 4" HT -40 Safety Valves And Dart Valves Clean Out Suction Strainers On Emsco Mud Pumps Clean Mud System And Pits Rig Down BOP Testing Equipment - Pull Test Plug - Install Short Wear Bushing And Energize Lock Down Studs - Lay Down Test Joint - Clear Rig Floor Rig Up Casing Tools And Back Up Tongs - Change Elevators For 27/8" Drill Pipe Pick Up Bit NO.2 - Make Up 4 3/4" Drilling Assembly - Orient MWD Tool - Continue To Pick Up BHA - Surface Test MWD Tool At 3.7 BPM With 1685 Psi. Pick Up 123 Joints Of 27/8" Drill Pipe And RIH - Break Printed: 11/12/2002 10:36:59AM ) ") Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date' 14-44A 14-44A REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 2ES Tssk:;;,COde ", NPJ':... .\PhaSe 10/24/2002 09:00 - 14:00 5.00 DRILL P 4.00 DRILL P 0.50 DRILL P LNR2 14:00 - 18:00 LNR2 18:00 - 18:30 LNR2 18:30 - 20:30 2.00 DRILL P LNR2 20:30 - 21 :45 1.25 DRILL P LNR2 21:45-22:15 0.50 DRILL P LNR2 22: 15 - 23:30 1.25 DRILL P LNR2 23:30 - 00:00 0.50 DRILL P LNR2 10/25/2002 00:00 - 00:30 0.50 DRILL P LNR2 00:30 - 00:00 23.50 DRILL P LNR2 10/26/2002 00:00 - 10:30 10.50 DRILL P LNR2 Start: 10/6/2002 Rig Release: 11/7/2002 Rig Number: 2ES Spud Date: 8/6/1995 End: 11/7/2002 . . , , [)~$êr,þtic>r;¡'¡()f'Øþef'élti()~'~, ' Circulation Every 1000 Feet - Change Out Handling Equipment To Accept 4" Drill Pipe RIH With 4" Drill Pipe From Mast To 9,670' - Fill Drill String - Continue To RIH To 12,865' Connect Top Drive And Break Circulation - Increase Pump Rate To 3.5 BPM With 2,357 Psi. - Top Drive RPM 23 With 12K Torque - Wash Down To Landing Collar Tag Top Of Liner Wiping Rubbers At 12,876' Drill Wiper Rubbers And Insert (Landing Collar) - Continue To Drill Cement And Tag Top Of Float Collar At 12,916' - Drill Cement To Top Of Float Shoe At 12,958' *NOTE* While Drilling Shoe Track Displace Well To Flo-Pro Mud System - Pump 30 BBL. Hi-Vis Spacer, 50 BBLS. Water Followed Up With 8.5 PPG Flo Pro Mud System Continue To Displace Well To Flo Pro Mud System - Rotate And Reciprocate Drill String Shut Down Pumping - Clean Out Possom Belly And Under Shakers Break Circulation And Get Slow Pump Rates - Drill Float Shoe Bottom At 12,960' - Wash And Clean Out 6 3/4" Rat Hole To 12,963' - Continue To Drill 20' New 4 3/4" Hole To 12,983' Circulate Liner Volume To Move Cuttings Up Hole - Prepare To Preform Formation Integrity Test Hold Pre-Job Safety Meeting - Pull Bit In 5 1/2" Casing Shoe Closed Annular And Performed FIT Strokes Pmp'd Pressure 5 45 psi 10 120 psi 15 268 psi 20 427 psi 25 570 psi 29 690 psi Held Test F/10 minutes w/30 Psi. Pressure Loss. MW 8.5 ppg, Csg Shoe TVD 8,940' Pressure 695 psi = 10.00 PPG. EMW. Bleed Pressure To 0 Psi. - Open Pipe Rams Directional Drill Ahead From 12,983' To 13,428' - Weight On Bit 3K To 13K - With Pump Rate At 63 Strokes Or 155 GPM- Off Bottom Pump Pressure At 2250 Psi. & On Bottom Pump Pressure At 2700 Psi. - Top Drive RPM At 0 To 50 - Off Bottom Torque At 6K & On Bottom Torque At 7K - String Rotating Weight At 155K - Drag Up With On At 168K And Drag Down At 130K Directional Drill Ahead From 13,428' To 13,696' - Weight On Bit 3K To 13K - With Pump Rate At 63 Strokes Or 155 GPM- Off Bottom Pump Pressure At 2250 Psi. & On Bottom Pump Pressure At 2700 Psi. - Top Drive RPM At 0 To 50 - Off Bottom Torque At 6K & On Bottom Torque At 7K - String Rotating Weight At 155K - Drag Up With On At 168K And Drag Down At 130K Printed: 11/1212002 10:36:59AM ') ') ./ Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 14-44A 14-44A REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 2ES Start: 10/6/2002 Rig Release: 11/7/2002 Rig Number: 2ES Spud Date: 8/6/1995 End: 11/7/2002 10/26/2002 10:30 - 11 :00 0.50 DRILL P LNR2 Work Tight Hole At 13,696' 11 :00 -15:00 4.00 DRILL P LNR2 Directional Drill Ahead From 13,696' To 13,883' - Monitor Well Bore Taking Fluid At 25 Barrels In 15 Minutes 15:00 - 16:00 1.00 DRILL P LNR2 POH To 13,840' - Monitor Well Bore Losses 25 BPH With Pump Off (Static) 16:00 - 17:00 1.00 DRILL P LNR2 Spot 40 Bbl. Pill - 20 Pounds Per Barrel LCM 17:00 - 20:30 3.50 DRILL P LNR2 POH With 4" Drill Pipe Standing Back In Mast - Work Thru Tight Area At 13,696' - Continue To POH To 13,802' - Work Thru This Area - POH To 13,598' Work Thru This Area Well Bore Losses At This Point 36 BPH - Connect Top Drive And Attempt To Circulate (NO Good) Able To Work Drill String Out Of Hole To 13,520' - POH To 12,963' With NO Problems 20:30 - 22:00 1.50 DRILL P LNR2 Circulate Across Top Of Hole - Consult With Anchorage Drilling Superintendent And Drilling Engineer While Monitoring Losses At 44 BPH - Mix Second 40 Bbl. LCM Pill - 20 Pounds Per Barrel LCM 22:00 - 22:30 0.50 DRILL P LNR2 RIH With 4" Drill Pipe To 13,475' With No Problems 22:30 - 23:30 1.00 DRILL P LNR2 Spot Second 40 Bbl. LCM Pill - 20 Pounds Per Barrel LCM 23:30 - 00:00 0.50 DRILL P LNR2 POH (With No Problems) To Allow LCM Pill To Fall Into Thief Zone - Stand Back 15 Stands (12,065') *NOTE* Total Losses This 12 Hour Tour At 344 Barrels 10/27/2002 00:00 - 00:45 0.75 DRILL P LNR2 Hold Pre-Job Safety Meeting - Continue To POH (With No Problems) To Allow LCM Pill To Fall Into Thief Zone - Stand Back 15 Stands (12,065') 00:45 - 02:00 1.25 DRILL P LNR2 Allow LCM To Be Absorbed In Thief Zone Losses Slowed To 20 BPH 02:00 - 03:00 1.00 DRILL P LNR2 RIH To 13,475' With 4" Drill Pipe From Mast With No Problems - Losses Slowed To 10 BPH Static - Connect Top Drive And Wash To 13,570' With No Problems - Total Losses At 03:00 Hours 102 Barrels 03:00 - 04:30 1.50 DRILL P LNR2 Set Back 1 Stand - Build Volume In Pits Mix 50 Barrels Mud And Wait For Mud From Mud Plant To Arrive On Location Before Washing To Bottom 04:30 - 06:00 1.50 DRILL P LNR2 RIH With 4" Drill Pipe From Mast - Wash Thru 13,598' Previous Problem Section With No Problems - Continue To RIH Thru 13,696' Area With Little Problems - Wash To 13,772' Hole Attempting To Pack Off Work Thru This Area Three Times To Get Cleaned Up - Continue To Wash And Ream To Bottom At 13,883' 06:00 - 19:00 13.00 DRILL P LNR2 Directional Drill Ahead From 13,883' To 14,385' - Weight On Bit 3K To 13K - With Pump Rate At 63 Strokes Or 155 GPM- Off Bottom Pump Pressure At 1900 Psi. & On Bottom Pump Pressure At 2580 Psi. - Top Drive RPM At 0 To 85 - Off Bottom Torque At 6K & On Bottom Torque At 7K - String Rotating Weight At 150K - Drag Up With Pumps Off At 175K And Drag Down At 130K *NOTE* Well Bore Total Losses From 00:01 To 12:00 Hours At 518 Barrels 19:00 - 21 :00 2.00 DRILL P LNR2 Circulate Bottoms Up (Samples For Gelogist) 21 :00 - 23:00 2.00 DRILL P LNR2 Hold Pre-Job Safety Meeting - POH From 14,385' To 14,300'- Well Swabing - Connect Top Drive And Pump Out Of The Hole Printed: 11/12/2002 10:36:59 AM ') ) Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 14-44A 14-44A REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 2ES ,Date' 'Fr()rn<~To Hþurs, Ta$K:;:Code' 'N.ÅT ,Phase. 10/27/2002 21:00 - 23:00 2.00 DRILL P LNR2 23:00 - 00:00 1.00 DRILL P LNR2 10/28/2002 00:00 - 01 :00 1.00 DRILL C LNR2 01 :00 - 03:15 2.25 DRILL C LNR2 03: 15 - 04:00 04:00 - 06:00 0.75 DRILL C 2.00 DRILL C LNR2 LNR2 06:00 - 17:00 11.00 DRILL C LNR2 17:00 - 23:30 6.50 DRILL C LNR2 23:30 - 00:00 0.50 DRILL N FLUD LNR2 10/29/2002 00:00 - 02:00 FLUD PROD2 2.00 DRILL N 02:00 - 07:30 5.50 DRILL C PROD2 Start: 10/6/2002 Rig Release: 11/7/2002 Rig Number: 2ES Spud Date: 8/6/1995 End: 11/7/2002 , . . O~çri:þtiQnof.Q~~J:ë;iti~Q.~ - Work Thru Tight Spot At 13,873' Attempted To Pack Off - Continue To Pump Out Of The Hole Work Area At 13,705' With Little Problems - Continue To Pump Out Of The Hole To 13,490' - Well Bore Took Extra 47 Barrels Above Pipe Displacement On Trip Out Of The Hole To 13,490' Spot 42 Barrel LCM Pill (20 PPB) At 13,490' *NOTE* Well Bore Total Losses From 12:00 To 24:00 Hours At 334 Barrels Hold Pre-Job Safety Meeting - POH From 13,490' (With No Problems) In Open Hole Section - Pull Additional 15 Stands Of 4" Drill Pipe (11,560') To Allow LCM Pill To Fall Into Thief Zone While Servicing Rig Hold Pre-Job Safety Meeting - Cut And Slip 1 1/4" Drilling Line - Service Can-Rig Top Drive, Traveling Blocks, And Crown Sheaves - Circulate Across Top Of Hole And Monitor Well Bore Losses At 18 BPH RIH From 11,560' To 13,053' With 4" Drill Pipe From Mast Connect Top Drive And Break Circulation - Orient Mud Motor - Time Drill And Open Hole Side Track At 13,100' - Weight On Bit 2K To 3K - With Pump Rate At 63 Strokes Or 155 GPM - Off Bottom Pump Pressure At 1900 Psi. - Top Drive RPM At 0 - String Rotating Weight At 150K - Drag Up With Pumps Off At 175K And Drag Down At 130K Time Drilling From 13,111' - (1) Foot Per Hour For First 3 Feet - (2) Feet Per Hour Than Step Up To 4 Feet Per Hour There After To 13,146' With Good Seperation Directional Drill Ahead All Sliding From 13,146' To 13,296'- Weight On Bit 3K To 7K - With Pump Rate At 65 Strokes Or 161 GPM - Off Bottom Pump Pressure At 1900 Psi. & On Bottom Pump Pressure At 2187 Psi. - Top Drive RPM At 0 - Off Bottom Torque At 6K - String Rotating Weight At 150K - Drag Up With Pumps Off At 180K And Drag Down At 130K *NOTE* Well Bore Total Losses From 00:01 To 24:00 Hours At 678 Barrels Unable To Keep Good Tool Face Flo-Pro Mud Aired Up - Add Defoamer - And Continue To Trouble Shoot Problem Unable To Keep MWD Pulse Consistant - Add Defoamer To Mud And Shut Down Hopper And Other Equipment - Pump KCL Sweep And Clean Off Pulser Tool - Debris Traveled To Bit And For Brief Period Pump Pressure Went From 2,187 Psi. To 2,700 Psi. At 161 GPM - Pump Pressure Returned To Normal And Signal Returned. *NOTE* The Number (2) Emsco Mud Pump Was Used To Pump KCL Sweep And May Have Had LCM Settled Out In Suction Line - The Pump Suction Was Inspected And Some Flo-Vis Balls Were Found Directional Drill Ahead From 13,296' To 13,513' - Weight On Bit 3K To 7K - With Pump Rate At 65 Strokes Or 161 GPM- Off Bottom Pump Pressure At 1900 Psi. & On Bottom Pump Pressure At 2187 Psi. - Top Drive RPM At 0 - Off Bottom Printed: 11/1212002 10:36:59 AM ") ) Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 14-44A 14-44A REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 2ES , ' , Date, ' From'" To Hours tas,k',/,Øóôe' NP;T,';'8nase: 10/29/2002 02:00 - 07:30 5.50 DRILL C 07:30 - 11 :30 4.00 DRILL C 11 :30 - 12:00 0.50 DRILL C 12:00 - 17:00 5.00 DRILL C 17:00 - 18:00 1.00 DRILL C 18:00 - 19:00 1.00 DRILL C 19:00 - 19:30 0.50 DRILL C PROD2 PROD2 PROD2 PROD2 PROD2 PROD2 PROD2 19:30 - 00:00 4.50 DRILL C PROD2 10/30/2002 00:00 - 02:00 PROD2 2.00 DRILL P 02:00 - 03:00 1.00 DRILL N DFAL PROD2 03:00 - 04:00 1.00 DRILL N DFAL PROD2 04:00 - 06:00 2.00 DRILL N DFAL PROD2 06:00 - 11 :30 5.50 DRILL N DFAL PROD2 11 :30 - 14:30 3.00 DRILL N DFAL PROD2 14:30 -15:00 0.50 DRILL N DFAL PROD2 15:00 - 15:30 0.50 BOPSUR N DFAL PROD2 15:30 - 19:30 4.00 BOPSURN DFAL PROD2 19:30 - 20:00 0.50 BOPSUR N DFAL PROD2 20:00 - 22:30 2.50 DRILL N DFAL PROD2 22:30 - 00:00 1.50 DRILL N DFAL PROD2 10/31/2002 00:00 - 05:30 5.50 DRILL N DFAL PROD2 05:30 - 15:00 9.50 DRILL P PROD2 15:00 - 18:00 3.00 DRILL N DFAL PROD2 18:00 - 23:30 5.50 DRILL N DFAL PROD2 23:30 - 00:00 0.50 DRILL N DFAL PROD2 11/1/2002 00:00 - 05:00 5.00 DRILL N DFAL PROD2 Start: 10/6/2002 Rig Release: 11/7/2002 Rig Number: 2ES Spud Date: 8/6/1995 End: 11/7/2002 . ' , E:)~~çriptipn ;9fØp~r~ti(:)rïs Torque At 6K - String Rotating Weight At 150K - Drag Up With Pumps Off At 180K And Drag Down At 130K. Drill from 13,513' to 13,554'. Became momentarily detained while sliding. Pull to 230K. Trap 5 wraps in pipe with 8K ft*lbs. Work pipe and jar up at 230K several times and free pipe. Drill from 13,554' to 13,709'. Circulate for 15 minutes while rotating and reciprocating. Short trip from 13,709' to 12,960'. Intermittent over pulls of 45K from 13,709' to 13,241'. PU=185K, SO=135K. Service top drive. Inspect and tighten fittings. Static loss rate approx. 20 bbls per hour. RIH from 12,960' to 13,250'. Take check shot survey to verify bit is in new hole. RIH to 13,616'. Fill pipe and wash down to 13,709'. Drill from 13,709' to 13,895'. PU=180, SO=135K, RT=160K, TQ=6K off, 6-7K on bottom. Loss rate 25 - 30 bbls per hour. Drill to 13,909' w/1.5 deg mtr. ast.1 hrs, art .2 hrs. Attempt to slide. Not getting differential from motor. Attempt to rotate. Motor still not getting differential and will not drill off weight. Suspect motor drive shaft failure. Pump 25 bbllow vis KCI sweep at 4 bpm, 2050 psi. Pressure increased as sweep exited bit. Still unable to drill. Circulate sweep above 5 1/2" liner top. Monitor well, static. POH. Hole in good condition, no overpulls. Position pump out sub across 5 1/2" liner top. Drop dart and open pump out sub. Circulate bottoms up at 9 bpm, 3045 psi. Pump dry job. POH to 205'. Rack back 4" and 2 7/8" DP. LD BHA. Down load MWD. Clear floor. RU to test BOPE. Test BOPE to 250 psi /3,500 psi as per BP policy and AOGCC regulations. Witness of test waived by John Spalding of AOGCC. Install wear bushing. MU BHA. Upload to MWD. Surface test MWD at 160 gpm, 1075 psi. RIH w/2 7/8" DP to 3,535'. RIH from 3,525 to 13,906'. Break circulation at 51/2" shoe. Take check shot survey at 13,250' to confirm in new hole. Wash from 13,818' to 13,906'. Drill 4 3/4" hole from 13,906' to 14,235'. ART=4.0, AST=1.6. Pump pressure decreasing. Lost 400 psi. MWD quit pulsing. Trouble shoot MWD. Pump 35 bbl and 50 bbl KCI sweeps to clean up MWD tool. Check surface equipment. Pressure still down 400 psi. No signal from MWD. POH wet from 14,235' to 4,103' looking for washout. RU 2 /78" handling equipment. Continue to POH. Circulate through BHA at 3 bpm and check pump out sub. Pump out sub OK. LD jars and flex DCs. Found washout 1.45' down on MWD hang off collar, one 1/4" diameter hole and one 1/4" x 3/4" hole 180 degrees apart. Printed: 11112/2002 10:36:59 AM '') ) Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 14-44A 14-44A REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 2ES Start: 10/6/2002 Rig Release: 11/7/2002 Rig Number: 2ES Spud Date: 8/6/1995 End: 11/7/2002 11/112002 00:00 - 05:00 5.00 DRILL N DFAL PROD2 Washout on internals of MWD TM also, one pin hole and one 1/4" diameter hole 180 degrees apart. 05:00 - 07:00 2.00 DRILL N DFAL PROD2 Down load MWD. Change out MWD battery, pulser, gamma, TM, and HOC. Upload MWD. Check orientation. RIH to 221' and flow test MWD. 07:00 - 10:30 3.50 DRILL N DFAL PROD2 RIH to 7,461'. 10:30 - 12:00 1.50 DRILL N DFAL PROD2 Slip and cut drilling line. Service top drive. 12:00 - 16:00 4.00 DRILL N DFAL PROD2 RIH from 7,461' to 13,928'. Taking weight, 15K. Take check shot survey at 13,250'. 16:00 -17:00 1.00 DRILL N DFAL PROD2 Wash and ream from 13,928' to 13,958' and 14,115' to 14,235'. 17:00 - 23:00 6.00 DRILL P PROD2 Drill 4 3/4" hole from 14,235' to 14,387'. AST=1.5, ART=1.1. Spot glass beads to aid in sliding. Lost differential pressure from motor. No reactive torque. Unable to drill. 23:00 - 00:00 1.00 DRILL N DFAL PROD2 POH from 14,235' to 13,445'. 11/2/2002 00:00 - 01 :30 1.50 DRILL N DFAL PROD2 Continue to POH to 11 ,461'. 01 :30 - 03:00 1.50 DRILL N DFAL PROD2 Drop dart and open pump out sub. CBU at 6.5 bpm, 1,900 psi. 03:00 - 07:00 4.00 DRILL N DFAL PROD2 POH to 221'. 07:00 - 09:00 2.00 DRILL N DFAL PROD2 LD BHA. Broken drive shaft in motor. 09:00 - 11 :00 2.00 DRILL N DFAL PROD2 MU new motor and bit. Flow test MWD. 11 :00 - 18:30 7.50 DRILL N DFAL PROD2 RIH to 14,387'. Taking weight at 13,925', 20 K down. Wash and ream from 13,925' to 13,955'. Took 15K to 20K to wash through intervals. Lost 35 bbls while RIH. 18:30 - 00:00 5.50 DRILL P PROD2 Drill 4 3/4" hole from 14,387' to 14,547'. ART=1.3, AST=1.4. 11/3/2002 00:00 - 01 :00 1.00 DRILL N DFAL PROD2 Unable to read MWD pulses. Cycle pumps several times to toggle MWD tool from 1.2 Hz to 0.8 Hz. 01 :30 - 00:00 22.50 DRILL P PROD2 Drill from 14,547' to 15,015'. AST=9.6, ART=2.2 Sliding to drop angle. 11/4/2002 00:00 - 08:00 8.00 DRILL P PROD2 Drill from 15,015' to 15,280'. AST=3.0, ART=1.6. Loss rate increased up to 127 bph. 08:00 - 09:30 1.50 DRILL P PROD2 Circulate. Mix and spot LCM pill with 10 ppb mixll fine and 10 ppb SafeCarb 250 on bottom. 09:30 - 11 :30 2.00 DRILL P PROD2 POH from 15,280' to 12,960'. Pulled tight from 14,800' to 14,300'. Max pull was 225 K, 30 Kover PU weight. 11 :30 -12:00 0.50 DRILL P PROD2 Service top drive and crown. 12:00 - 14:00 2.00 DRILL P PROD2 RIH from 12,960' to 15,280'. Hole in good condition. 14:00 - 15:00 1.00 DRILL P PROD2 Spot liner running pill in open hole section at 4 bpm, 2,070 psi. 15:00 - 17:00 2.00 DRILL P PROD2 POH from 15,280' to 12,943'. 15K overpulls at 14,443', 14,419' - 13,565'. 17:00 - 17:30 0.50 DRILL P PROD2 Drop dart and pump dry job. 17:30 - 00:00 6.50 DRILL P PROD2 POH to 969'. LD 81 joints of 2/78" DP. 11/5/2002 00:00 - 03:00 3.00 DRILL P PROD2 LD BHA. Down load MWD. LD MWD, motor, and bit. 03:00 - 03:30 0.50 DRILL P PROD2 Clear rig floor. 03:30 - 04:30 1.00 CASE P COMP RU to run 3 1/2" liner. 04:30 - 06:30 2.00 CASE P COMP PJSM. Run 3 1/2" , 9.2 #, L-80, IBT-M liner. 35 joints slotted and 44 joints solid liner. 06:30 - 07:00 0.50 CASE P COMP Break circulation, 3 bpm, 160 psi. 07:00 - 12:00 5.00 CASE P COMP RIH w/liner on 2 7/8" x 4" DP to 12,962'. 12:00 - 12:30 0.50 CASE P COMP Circulate DP and liner volume at 3 bpm, 870 psi. Printed: 11/1212002 10:36:59 AM ) ) Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 14-44A 14-44A REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 2ES lDaìe ' FrÔm).4To' : HòUrs:,:Æask,' ;COde .NPT. " Pnase 11/5/2002 12:30 - 13:30 1.00 CASE P COMP 13:30 - 15:00 1.50 CASE P COMP 15:00 - 17:00 2.00 CASE P COMP 17:00 - 18:30 1.50 CASE P COMP 18:30 - 20:00 1.50 CASE P COMP 20:00 - 00:00 4.00 CASE P COMP 11/6/2002 00:00 - 02:00 2.00 CASE P COMP 02:00 - 02:30 0.50 CASE P COMP 02:30 - 03:30 1.00 RUNCOIVP COMP 03:30 - 04:00 0.50 RUNCOIVP COMP 04:00 - 13:00 9.00 RUNCOIVP COMP 13:00 - 14:00 1.00 RUNCOIVP COMP 14:00 - 14:30 0.50 RUNCOIVP COMP 14:30 - 16:30 2.00 RUNCOIVP COMP 16:30 - 19:00 2.50 RUNCOIVP COMP 19:00 - 19:30 0.50 RUNCOIVP COMP 19:30 - 21 :00 1.50 RUNCOIVP COMP 21 :00 - 22:30 1.50 RUNCOIVP COMP 22:30 - 23:30 1.00 RUNCOIVN COMP 23:30 - 00:00 0.50 RUNCOIVP COMP 1117/2002 00:00 - 00:30 0.50 RUNCOI\ P COMP 00:30 - 02:00 1.50 RUNCOIVP COMP 02:00 - 03:00 1.00 RUNCOI\P COMP 03:00 - 03:30 0.50 RUNCOIVP COMP 03:30 - 04:00 0.50 RUNCOIVP COMP Start: 10/6/2002 Rig Release: 11/7/2002 Rig Number: 2ES Spud Date: 8/6/1995 End: 11/7/2002 f;)~$çripti()n";:()f:,,:~~.ratiqos; RIH from 12,962' to 15,280'. No hole problems. PU=195K, SO=135K. Drop ball, set liner hanger with 2,000 psi. Pressure up to 3,540 and release from liner. Set 40K down to set liner top packer. Rotate and set 35K down on liner top packer. Displace well to seawater at 10 bpm, 2,440 psi. Monitor well. Static loss rate 55 bph. POH. Stand back 48 stands of 4" DP. Slip and cut drilling line. Service top drive and crown. POH and LD DP from 8,268' to 1,945'. LD 4" and 2 7/8" DP. LD liner running tool. Pull wear bushing and clear floor. RU to run 41/2" completion. PJSM. Run 41/2",12.6#, L-80, IBT-M completion. Space out tubing. Land tubing. RILDS. Reverse circulate seawater with corrosion inhibitor at 3 bpm, 500 psi. Drop ball/rod. LD landing joint. Pressure up to 3,500 psi to set packer. Test tubing for 30 minutes. Lost 450 psi in 30 minutes. Pressure up back side to 3,500 psi and hold for 30 minutes. Back side held and tubing pressure increased from 3,200 psi to 3,400 psi over 30 minutes. Suspect GL V or RP valve leaking. Install TWC and test from below to 3,000 psi. NO BOP. NU adapter flange and tree. Test flange to 5,000 psi. Attempt to test tree. Fluid leaking by TWC. Pull TWC with lubricator (BPV was installed instead of TWC). Install TWC and test tree to 5,000 psi. Pull TWC with lubricator. RD DSM lubricator. RU hot oil truck. PJSM. Pump 91 bbls of diesel down IA. U-tube diesel into tubing. Install BPV and test from below to 3,000 psi. Remove secondary annulus valve. Install gauges. Secure well. Release rig at 04:00 on 11/7/02. Printed: 11/1212002 10:36:59 AM Well: Field: API: Permit: .) ) 14-44A Prudhoe BayUnit 50-029-22573-01 202-193 Rig Accept: 10/09/02 Rig Spud: 10/18/02 Rig Release: 11/07/02 Drilling Rig: Nabors 2ES POST RIG WORK 11/07/02 ARRIVE LOCATION, MASTER VALVE FROZEN, HEATER APPLIED. 11/08/02 PULL RP SHEAR VLV. SET DGLV IN STA-2 @ 4352' MD. MITIA 3500# (PASSED). BLEED IA TO 0#. MIT TBG 3500# (PASSED) BLEED TBG TO 0#. PULLED B& R. PULLED STA# 2 & 3 DGLV'S. SET LGLV IN STA# 2. 11/09/02 SET OGLV-BK, GENERIC, 20/64" PORT IN STA-3 @ 6865' MD. PULL RHC-M PLUG BODY. DRIFT 3-3/8" DGUN TO 12826' SLM. WELL LEFT SI. ) cXDd-/Û 23-Nov-02 AOGCC 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 Re: Distribution of Survey Data for Well 14-44A Dear Dear Sir/Madam: Enclosed are two survey hard copies and 1 disk Tie-on Survey: 13,098.87' MD Window / Kickoff Survey 13,134.20' MD (if applicable) Projected Survey: 15,280.00 I MD Please call me at 273-3545 if you have any questions or concerns. Regards, William T. Allen Survey Manager RECEIVED DEC 06 2002 Attachment(s) Ala.a Oil & Gas Cons. Commia8ion Anchorage Sperry-Sun Drilling Services North Slope Alaska BPXA PBU_EOA DS 14 14-44A - Job No. AKZZ22168, Surveyed: 4 November, 2002 Survey Report 21 November, 2002 Your Ref: API 500292257301 Surface Coordinates: 5937881.65 N, 674885.74 E (70014' 09.5038" N, 148035' 16.5004" W) Grid Coordinate System: NAD27 Alaska State Planes, Zone 4 --' Surface Coordinates relative to Project H Reference: 937881.65 N, 174885.74 E (Grid) Surface Coordinates relative to Structure Reference: 1711.09 S, 694.93 E (True) Kelly Bushing: 69.50ft above Mean Sea Level Elevation relative to Project V Reference: 69.50ft Elevation relative to Structure Reference: 69.50ft 5pE!I'I'Y-SUI! Eff;t ïL L I, N[!i !5 ,15 Ft '!!" ç:: 15 5 A Halliburton Company Survey Ref: svy11373 Sperry-Sun Drilling Services Survey Report for PBU_EOA DS 14 - 14-44A Your Ref: API 500292257301 Job No. AKZZ22168, Surveyed: 4 November, 2002 BPXA North Slope Alaska Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Inct. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) C/1 OOft) 13098.87 76.600 184.910 8906.30 8975.80 7388.03 8 3609.06 W 5930411.91 N 671449.00 E 6656.67 Tie On Point 13134.20 70.620 185.170 8916.27 8985.77 7421.778 3612.03 W 5930378.10 N 671446.81 E 16.941 6689.40 Window Point 13165.19 65.800 184.310 8927.77 8997.27 7450.448 3614.41 W 5930349.39 N 671445.09 E 15.765 6717.23 13194.31 66.220 177.990 8939.62 9009.12 7477.028 3614.94 W 5930322.80 N 671445.18E 19.879 6743.33 13233.58 68.290 170.490 8954.82 9024.32 7513.02 8 3611 .29 W 5930286.90 N 671449.66 E 18.382 6779.41 ~4 13257.38 70.660 168.010 8963.16 9032.66 7534.91 8 3607.13 W 5930265.11 N 671454.33 E 13.942 6801.70 13286.48 75.320 164.610 8971.68 9041 .18 7561.94 8 3600.54 W 5930238.24 N 671461.55 E 19.524 6829.45 13317.18 78.450 162.320 8978.64 9048.14 7590.59 8 3592.03 W 5930209.79 N 671470.72 E 12.518 6859.14 13349.68 82.470 158.500 8984.03 9053.53 7620.778 3581.28 W 5930179.87 N 671482.16 E 16.950 6890.72 13382.41 88.460 156.380 8986.62 9056.12 7650.898 3568.77 W 5930150.05 N 671495.37 E 19.406 6922.54 13439.50 94.900 151.310 8984.94 9054.44 7702.07 8 3543.64 W 5930099.47 N 671521.68 E 14.351 6977.28 13475.94 95.640 150.720 8981.60 9051.1 0 7733.81 8 3526.06 W 5930068.14 N 671540.00 E 2.593 7011.58 13527.72 93.200 150.690 8977.61 9047.11 7778.83 8 3500.80 W 5930023.72 N 671566.29 E 4.713 7060.27 13569.99 90.490 151.810 8976.25 9045.75 7815.86 8 3480.48 W 5929987.17 N 671587.46 E 6.936 7100.25 13662.24 89.260 150.760 8976.45 9045.95 7896.778 3436.16 W 5929907.32 N 671633.65 E 1.753 7187.58 13711.66 88.270 155.920 8977.51 9047.01 7940.91 8 3414.00 W 5929863.70 N 671656.83 E 10.629 7234.87 13756.48 89.110 154.320 8978.54 9048.04 7981.55 8 3395.15 W 5929823.50 N 671676.62 E 4.031 7278.16 13804.65 88.330 153.520 8979.61 9049.11 8024.81 8 3373.97 W 5929780.75 N 671698.79 E 2.319 7324.41 13865.80 89.040 151.600 8981.02 9050.52 8079.068 3345.80 W 5929727.16 N 671728.21 E 3.347 7382.70 13989.52 89.350 145.960 8982.76 9052.26 8184.81 8 3281.71 W 5929622.93 N 671794.74 E 4.565 7497.90 14050.51 91.420 144.740 8982.35 9051.85 8234.98 8 3247.04 W 5929573.58 N 671830.56 E 3.940 7553.29 14142.39 90.800 145.800 8980.57 9050.07 8310.488 3194.70 W 5929499.32 N 671884.64 E 1.336 7636.67 14237.70 89.720 145.250 8980.13 9049.63 8389.048 3140.75 W 5929422.02 N 671940.39 E 1.272 7723.35 ,-",' 14330.93 89.940 146.700 8980.41 9049.91 8466.31 8 3088.59 W 5929345.99 N 671994.34 E 1.573 7808.44 14422.76 93.920 147.790 8977.32 9046.82 8543.48 8 3038.94 W 5929269.99 N 672045.76 E 4.493 7893.00 14515.08 98.320 144.890 8967.48 9036.98 8619.868 2988.09 W 5929194.81 N 672098.37 E 5.698 7976.99 14609.91 89.170 143.020 8961.29 9030.79 8696.28 8 2932.46 W 5929119.70 N 672155.75 E 9.847 8061.85 14657.56 85.430 145.110 8963.53 9033.03 8734.81 8 2904.54 W 5929081.83 N 672184.56 E 8.989 8104.61 14703.44 86.790 144.190 8966.65 9036.15 8772.148 2878.05 W 5929045.12 N 672211.91 E 3.576 8145.94 14797.02 90.520 143.500 8968.84 9038.34 8847.678 2822.87 W 5928970.89 N 672268.83 E 4.053 8229.84 14890.29 89.260 142.530 8969.02 9038.52 8922.178 2766.76 W 5928897.71 N 672326.65 E 1.705 8312.88 14924.50 87.030 141 .080 8970.13 9039.63 8949.048 2745.62 W 5928871.34 N 672348.41 E 7.774 8342.99 14955.17 85.830 140.110 8972.04 9041.54 8972.698 2726.19 W 5928848.15 N 672368.38 E 5.027 8369.63 14984.66 83.060 139.750 8974.89 9044.39 8995.158 2707.30 W 5928826.13 N 672387.79 E 9.471 8395.01 15076.02 85.420 141.710 8984.06 9053.56 9065.51 8 2649.77 W 5928757.12 N 672446.93 E 3.351 8474.22 21 November, 2002 - 10:41 Page2of4 DrillQuest 3.03.02.004 Sperry-Sun Drilling Services Survey Report for PBU_EOA DS 14 - 14-44A Your Ref: API 500292257301 Job No. AKZZ22168, Surveyed: 4 November, 2002 North Slope Alaska Measured Sub-Sea Vertical Local Coordinates Global Coordinates Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings (It) (It) (It) (It) (ft) (ft) (ft) 15104.60 85.290 141.570 8986.38 9055.88 9087.85 S 2632.09 W 5928735.20 N 672465.13 E 15170.60 86.190 140.940 8991.28 9060.78 9139.18S 2590.90 W 5928684.84 N 672507.50 E 15248.07 91.600 150.890 8992.78 9062.28 9203.23 S 2547.57 W 5928621.81 N 672552.30 E 15280.00 91 .600 150.890 8991.88 9061.38 9231.12 S 2532.04 W 5928594.29 N 672568.47 E All data is in Feet (US) 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). Vertical Section is from Well Reference and calculated along an Azimuth of 170.090° (True). Magnetic Declination at Surface is 26.099°(11-0ct-02) Based upon Minimum Curvature type calculations, at a Measured Depth of 15280.00ft., The Bottom Hole Displacement is 9572.08ft., in the Direction of 195.339° (True). Comments Measured Depth (ft) Station Coordinates TVD Northings Eastings (ft) (ft) (ft) Comment 13098.87 13134.20 15280.00 8975.80 8985.77 9061.38 7388.03 S 7421.77 S 9231 .12 S 3609.06 W 3612.03 W 2532.04 W Tie On Point Window Point Projected Survey 21 November, 2002 - 10:41 Page 3 of 4 Dogleg Rate (0/100ft) BPXA Vertical Section Comment 0.667 8499.27 1.663 8556.92 14.613 8627.47 0.000 8657.62 Projected Survey ",-,¿ ~ DrillQuest 3.03.02.004 Sperry-Sun Drilling Services Survey Report for PBU_EOA DS 14 - 14-44A Your Ref: API 500292257301 Job No. AKZZ22168, Surveyed: 4 November, 2002 BPXA North Slope Alaska Survey tool program for 14-44A From Measured Vertical Depth Depth (ft) (It) To Measured Vertical Depth Depth (It) (It) Survey Tool Description 0.00 11606.42 0.00 11606.42 8435.60 15280.00 8435.60 AK-1 BP _HG(14-44PB1) 9061.38 AK-6 BP _IFR-AK(14-44APB1) , ? ~ '~ 21 November, 2002.10:41 Page 4 of 4 DrillQuest 3.03.02.004 ) ) 23-Nov-02 AOGCC 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 Re: Distribution of Survey Data for Well 14-44A MWD Dear Dear Sir/Madam: Enclosed are two survey hard copies and 1 disk Tie-on Survey: 13,098.87' MD Window / Kickoff Survey 13,134.20' MD (if applicable) Projected Survey: 15,280.00' MD Please call me at 273-3545 if you have any questions or concerns. Regards, William T. Allen Survey Manager RECEIVED Attachment(s) DEC 06 2002 Alaska OH & Gas Cons. Commission Anchorage eXOd---/93 Sperry-Sun Drilling Services North Slope Alaska BPXA PBU_EOA DS 14 14..44A MWD .~' Job No. AKMW22168, Surveyed: 4 November, 2002 Survey Report 21 November, 2002 Your Ref: API 500292257301 Surface Coordinates: 5937881.65 N, 674885.74 E (70014' 09.5038" N, 148035' 16.5004" W) Grid Coordinate System: NAD27 Alaska State Planes, Zone 4 '-' Surface Coordinates relative to Project H Reference: 937881.65 N, 174885.74 E (Grid) Surface Coordinates relative to Structure Reference: 1711.09 S, 694.93 E (True) Kelly Bushing: 69.50ft above Mean Sea Level Elevation relative to Project V Reference: 69.50ft Elevation relative to Structure Reference: 69.50ft spe""'I'Y-5UI'1 f.\v'Ft'rC:~)N [5' ," . 5i e R v I c: ES !!i A Halliburton Company Survey Ref: svy11375 Sperry-Sun Drilling Services Survey Report for PBU_EOA DS 14 - 14-44A MWD Your Ref: API 500292257301 Job No. AKMW22168, Surveyed: 4 November, 2002 BPXA North Slope Alaska Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth IncI. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (°/1 OOft) 13098.87 76.600 184.900 8908.23 8977.73 7364.95 S 3644.45 W 5930434.16 N 671413.08 E 6627.85 Tie On Point 13134.20 70.620 185.660 8918.20 8987.70 7398.69 S 3647.57 W 5930400.36 N 671410.75 E 17.051 6660.54 Window Point 13165.19 65.800 184.730 8929.70 8999.20 7427.33 S 3650.17 W 5930371.66 N 671408.80 E 15.801 6688.31 13194.31 66.220 178.200 8941 .55 9011.05 7453.91 S 3650.85 W 5930345.07 N 671408.74 E 20.536 6714.38 13233.58 68.290 171.270 8956.74 9026.24 7489.94 S 3647.52 W 5930309.13 N 671412.91 E 17.104 6750.45 ~ 13257.38 70.660 168.990 8965.09 9034.59 7511.90 S 3643.69 W 5930287.27 N 671417.25 E 13.403 6772.73 13286.48 75.320 165.160 8973.60 9043.10 7539.00 S 3637.46 W 5930260.31 N 671424.11 E 20.365 6800.51 13317.18 78.450 162.610 8980.57 9050.07 7567.72 S 3629.16 W 5930231.80 N 671433.07 E 13.014 6830.22 13349.68 82.470 158.540 8985.96 9055.46 7597.93 S 3618.50 W 5930201.84 N 671444.43 E 17.477 6861.82 13382.41 88.460 155.480 8988.54 9058.04 7627.95 S 3605.76 W 5930172.13 N 671457.86 E 20.536 6893.58 13439.50 94.900 151.250 8986.87 9056.37 7678.92 S 3580.20 W 5930121.76 N 671484.60 E 13.492 6948.19 13475.94 95.640 150.140 8983.52 9053.02 7710.56 S 3562.44 W 5930090.54 N 671503.09 E 3.650 6982.42 13527.72 93.200 151 . 180 8979.53 9049.03 7755.56 S 3537.14 W 5930046.14 N 671529.42 E 5.120 7031.10 13569.99 90.490 152.130 8978.17 9047.67 7792.74 S 3517.09 W 5930009.43 N 671550.33 E 6.793 7071.17 13662.24 89.260 149.910 8978.37 9047.87 7873.43 S 3472.40 W 5929929.80 N 671596.88 E 2.751 7158.35 13711.66 88.270 155.850 8979.44 9048.94 7917.39 S 3449.88 W 5929886.38 N 671620.41 E 12.182 7205.53 13756.48 89.110 155.460 8980.46 9049.96 7958.21 S 3431.41 W 5929845.99 N 671639.82 E 2.066 7248.92 13804.65 88.330 153.470 8981.54 9051.04 8001.67 S 3410.65 W 5929803.04 N 671661.58 E 4.436 7295.30 13865.80 89.040 157.120 8982.94 9052.44 8057.19 S 3385.11 W 5929748.11 N 671688.41 E 6.079 7354.39 13989.52 89.350 144.950 8984.69 9054.19 8165.22 S 3325.31 W 5929641.50 N 671750.69 E 9.839 7471.10 14050.51 91.420 144.180 8984.28 9053.78 8214.91 S 3289.95 W 5929592.65 N 671787.19 E 3.621 7526.14 14142.39 90.800 149.590 8982.50 9052.00 8291.83 S 3239.79 W 5929516.92 N 671839.13 E 5.926 7610.54 14237.70 89.720 143.600 8982.06 9051.56 8371.35 S 3187.34 W 5929438.63 N 671893.41 E 6.386 7697.90 ~ 14330.93 89.940 147.480 8982.34 9051.84 8448.21 S 3134.60W 5929363.02 N 671947.92 E 4.168 7782.69 14422.76 93.920 152.160 8979.25 9048.75 8527.51 S 3088.48 W 5929284.81 N 671995.87 E 6.687 7868.74 14515.08 98.320 146.390 8969.40 9038.90 8606.37 S 3041.63 W 5929207.05 N 672044.53 E 7.830 7954.49 14609.91 89.170 143.190 8963.21 9032.71 8683.58 S 2987.12 W 5929131.12 N 672100.82 E 10.218 8039.93 14657.56 85.430 149.430 8965.46 9034.96 8723.16 S 2960.73 W 5929092.17 N 672128.11 E 15.253 8083.46 14703.44 86.790 147.350 8968.57 9038.07 8762.14 S 2936.74 W 5929053.76 N 672153.00 E 5.408 8125.99 14797.02 90.520 143.560 8970.77 9040.27 8839.17 S 2883.71 W 5928977.98 N 672207.81 E 5.681 8210.99 14890.29 89.260 142.890 8970.95 9040.45 8913.88 S 2827.87 W 5928904.59 N 672265.36 E 1.530 8294.19 14924.50 87.030 137.580 8972.05 9041.55 8940.15 S 2806.01 W 5928878.83 N 672287.83 E 16.827 8323.84 14955.17 85.830 140.220 8973.96 9043.46 8963.21 S 2785.89 W 5928856.24 N 672308.48 E 9.440 8350.02 14984.66 83.060 143.570 8976.82 9046.32 8986.30 S 2767.78 W 5928833.58 N 672327.12 E 14.698 8375.88 15076.02 85.420 146.280 8985.99 9055.49 9060.68 S 2715.56 W 5928760.42 N 672381.05 E 3.922 8458.14 21 November, 2002 - 10:43 Page2of4 DrillQuest 3.03.02.004 Sperry-Sun Drilling Services Survey Report for PBU_EOA DS 14 - 14-44A MWD Your Ref: API 500292257301 Job No. AKMW22168, Surveyed: 4 November, 2002 North Slope Alaska Measured Sub-Sea Vertical Local Coordinates Global Coordinates Depth IncI. Azim. Depth Depth Northings Eastings Northings Eastings (ft) (ft) (ft) (ft) (ft) (ft) (ft) 15104.60 85.290 144.370 8988.30 9057.80 9084.11 S 2699.35 W 5928737.38 N 672397.79 E 15170.60 86.190 140.380 8993.21 9062.71 9136.23 S 2659.18 W 5928686.21 N 672439.17 E 15248.07 91 .600 152.020 8994.71 9064.21 9200.46 S 2616.19 W 5928622.99 N 672483.64 E 15280.00 91.600 152.020 8993.82 9063.32 9228.65 S 2601.21 W 5928595.16 N 672499.26 E All data is in Feet (US) 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). Vertical Section is from Well Reference and calculated along an Azimuth of 170.090° (True). Magnetic Declination at Surface is 26.074°(04-Nov-02) Based upon Minimum Curvature type calculations, at a Measured Depth of 15280.00f1., The Bottom Hole Displacement is 9588.23f1., in the Direction of 195.741° (True). Comments Measured Depth (ft) Station Coordinates TVD Northings Eastings (ft) (ft) (ft) Comment 13098.87 13134.20 15280.00 8977.73 8987.70 9063.32 7364.95 S 7398.69 S 9228.65 S Tie On Point Window Point Projected Surveys 3644.45 W 3647.57 W 2601.21 W 21 November, 2002 - 10:43 Page 3 of 4 Dogleg Rate (0/100ft) BPXA Vertical Section Comment 6.677 8484.01 6.181 8542.26 16.561 8612.93 0.000 8643.28 Projected Surveys J ~' ~' DrillQuest 3.03.02.004 Sperry-Sun Drilling Services Survey Report for PBU_EOA DS 14 - 14-44A MWD Your Ref: API 500292257301 Job No. AKMW22168, Surveyed: 4 November, 2002 BPXA North Slope Alaska Survey tool program for 14-44A MWD Fro m Measured Vertical Depth Depth (ft) (ft) To Measured Vertical Depth Depth (ft) (ft) Survey Tool Description 0.00 11606.42 0.00 11606.42 8435.60 15280.00 8435.60 AK-1 BP _HG(14-44PB1) 9063.32 MWD Magnetic(14-44APB1 MWD) ~I ~ 21 November, 2002 - 10:43 Page 4 of 4 DrillQuest 3.03.02.004 , d,D~-{9 3 23-Nov-02 AOGCC 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 Re: Distribution of Survey Data for Well 14-44APB 1 Dear Dear Sir/Madam: Enclosed are two survey hard copies and 1 disk Tie-on Survey: 11,606.42 I MD Window / Kickoff Survey 11,631.97' MD (if applicable) Projected Survey: 14,386.00 I MD Please call me at 273-3545 if you have any questions or concerns. Regards, William T. Allen Survey Manager RECE\VED DEC 06 2002 Attachment(s) Alaska O~¡ & Gas Cons. Commission Anchorage Sperry-Sun Drilling Services North Slope Alaska BPXA PBU_EOA DS 14 14-44APB1 ~p Job No. AKZZ22168, Surveyed: 27 October, 2002 Survey Report 21 November, 2002 Your Ref: API 500292257371 Surface Coordinates: 5937881.65 N, 674885.74 E (70014' 09.5038" N, 148035' 16.5004" W) Grid Coordinate System: NAD27 Alaska State Planes, Zone 4 ~' Surface Coordinates relative to Project H Reference: 937881.65 N, 174885.74 E (Grid) Surface Coordinates relative to Structure Reference: 1711.09 S, 694.93 E (True) Kelly Bushing: 69.50ft above Mean Sea Level Elevation relative to Project V Reference: 69.50ft Elevation relative to Structure Reference: 69.50ft 5pe"""""'y-sul! D A I L L..:"n"rç;c'''''s¡"e R v I c::~!Ei A Halliburton Company Survey Ref: svy11372 Sperry-Sun Drilling Services Survey Report for PBU_EOA DS 14 -14-44APB1 Your Ref: API 500292257371 Job No. AKZZ22168, Surveyed: 27 October, 2002 BPXA North Slope Alaska Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (°/1 OOft) 11606.42 55.200 208.120 8366.10 8435.60 6070.56 S 3189.04 W 5931738.76 N 671838.35 E 5431.14 Tie On Point AK-6 BP _IFR-AK .. 11631.97 56.300 206.610 8380.48 8449.98 .... 6089.31 S 3198.75 W 5931719.79 N 671829.08 E 6.511 5447.95 Window Point 11666.38 58.740 204.610 8398.96 8468.46 6115.49 S 3211.28 W 5931693.33 N 671817.15 E 8.621 5471.58 11698.00 58.780 202.820 8415.36 8484.86 6140.24 S 3222.16 W 5931668.33 N 671806.85 E 4.842 5494.09 11760.41 61 .460 199.390 8446.45 8515.95 6190.71 S 3241.62 W 5931617.42 N 671788.57 E 6.414 5540.46 ) ~ 11791.20 61.780 197.760 8461.09 8530.59 6216.39 S 3250.24 W 5931591.55 N 671780.54 E 4.772 5564.27 11820.10 62.170 196.250 8474.67 8544.17 6240.79 S 3257.70 W 5931566.99 N 671773.65 E 4.806 5587.02 11854.25 62.890 196.790 8490.42 8559.92 6269.84 S 3266.32 W 5931537.75 N 671765.71 E 2.532 5614.15 11885.29 63.000 196.770 8504.54 8574.04 6296.30 S 3274.30 W 5931511.10 N 671758.34 E 0.359 5638.85 11913.52 64.200 197.120 8517.09 8586.59 6320.49 S 3281.67 W 5931486.75 N 671751.54 E 4.393 5661.40 12006.48 67.440 196.520 8555.16 8624.66 6401.66 S 3306.20 W 5931405.04 N 671728.90 E 3.535 5737.14 12099.15 67.91 0 196.880 8590.37 8659.87 6483.76 S 3330.84 W 5931322.38 N 671706.17E 0.622 5813.78 12192.46 68.840 197.810 8624.75 8694.25 6566.56 S 3356.70 W 5931239.01 N 671682.24 E 1.361 5890.89 12286.04 69.900 198.250 8657.72 8727.22 6649.84 S 3383.80 W 5931155.13 N 671657.07 E 1.215 5968.26 12375.16 70.760 198.390 8687.72 8757.22 6729.50 S 3410.18 W 5931074.87 N 671632.55 E 0.976 6042.20 12474.66 71.320 198.750 8720.05 8789.55 6818.70 S 3440.15 W 5930985.00 N 671604.66 E 0.659 6124.91 12567.57 72.190 199.560 8749.14 8818.64 6902.05 S 3469.11 W 5930901.00 N 671577.64 E 1.250 6202.03 12660.97 71.720 198.790 8778.07 8847.57 6985.93 S 3498.27 W 5930816.46 N 671550.43 E 0.931 6279.64 12749.33 71.470 199.070 8805.97 8875.47 7065.24 S 3525.47 W 5930736.55 N 671525.07 E 0.413 6353.08 12846.27 72.640 198.960 8835.84 8905.34 7152.43 S 3555.52 W 5930648.69 N 671497.06 E 1.212 6433.80 12877.53 72.710 199.140 8845.15 8914.65 7180.63 S 3565.26 W 5930620.26 N 671487.97 E 0.594 6459.91 12893.28 72.820 199.290 8849.81 8919.31 7194.84 S 3570.21 W 5930605.94 N 671483.35 E 1.147 6473.05 ~ 12979.08 74.440 192.620 8874.02 8943.52 7273.94 S 3592.81 W 5930526.34 N 671462.60 E 7.693 6547.08 13007.28 74.420 190.420 8881.59 8951.09 7300.56 S 3598.23 W 5930499.61 N 671457.79 E 7.515 6572.37 13037.67 73.110 188.070 8890.09 8959.59 7329.35 S 3602.92 W 5930470.71 N 671453.77 E 8.585 6599.93 13072.65 74.660 185.240 8899.80 8969.30 7362.73 S 3606.81 W 5930437.25 N 671450.66 E 8.947 6632.13 13098.87 76.600 184.910 8906.30 8975.80 7388.03 S 3609.06 W 5930411.91 N 671449.00 E 7.499 6656.67 13134.12 79.380 184.630 8913.64 8983.14 7422.38 S 3611 .92 W 5930377.50 N 671446.93 E 7.925 6690.02 13162.91 81.580 182.310 8918.40 8987.90 7450.72 S 3613.64 W 5930349.13 N 671445.87 E 11.025 6717.64 13193.23 83.120 183.290 8922.44 8991.94 7480.73 S 3615.11 W 5930319.09 N 671445.10 E 6.005 6746.95 21 November, 2002 - 10:41 Page 2 of 4 DrillQuest 3.03.02.004 Sperry-Sun Drilling Services Survey Report for PBU_EOA OS 14 -14-44APB1 Your Ref: API 500292257371 Job No. AKZZ22168, Surveyed: 27 October, 2002 BPXA North Slope Alaska Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (O/100ft) 13227.50 85.190 180.930 8925.93 8995.43 7514.80 S 3616.36 W 5930285.00 N 671444.64 E 9.133 6780.29 13258.13 85.740 176.290 8928.35 8997.85 7545.31 S 3615.62 W 5930254.51 N 671446.08 E 15.207 6810.48 13286.42 86.170 175.620 8930.35 8999.85 7573.46 S 3613.63 W 5930226.42 N 671448.73 E 2.809 6838.55 13321.67 85.900 175.520 8932.78 9002.28 7608.52 S 3610.91 W 5930191.43 N 671452.26 E 0.817 6873.56 13352.17 85.860 174.540 8934.97 9004.47 7638.83 S 3608.28 W 5930161.19 N 671455.59 E 3.207 6903.86 / '--" 13384.1 0 83.110 168.420 8938.05 9007.55 7670.24 S 3603.58 W 5930129.89 N 671461.02 E 20.930 6935.62 13415.89 81.240 164.770 8942.37 9011.87 7700.87 S 3596.28 W 5930099.44 N 671469.03 E 12.805 6967.05 13446.47 82.180 160.950 8946.79 9016.29 7729.78 S 3587.36 W 5930070.75 N 671478.61 E 12.738 6997.06 13478.80 82.770 158.770 8951.02 9020.52 7759.87 S 3576.33 W 5930040.92 N 671490.34 E 6.929 7028.60 13510.46 86.310 154.250 8954.03 9023.53 7788.76 S 3563.77 W 5930012.33 N 671503.57 E 18.081 7059.22 13540.60 87.750 152.210 8955.60 9025.10 7815.64 S 3550.21 W 5929985.78 N 671517.75 E 8.277 7088.03 13570.71 88.950 150.440 8956.46 9025.96 7842.04 S 3535.77 W 5929959.72 N 671532.80 E 7.100 7116.52 13601.33 89.750 151.450 8956.81 9026.31 7868.80 S 3520.90 W 5929933.30 N 671548.28 E 4.208 7145.45 13631.92 89.720 149.320 8956.95 9026.45 7895.40 S 3505.78 W 5929907.07 N 671564.01 E 6.964 7174.24 13664.17 89.110 1 51 . 180 8957.28 9026.78 7923.39 S 3489.78 W 5929879.45 N 671580.66 E 6.069 7204.58 13754.88 87.560 144.170 8959.92 9029.42 7999.96 S 3441.33 W 5929804.03 N 671630.87 E 7.911 7288.34 13847.66 87.840 143.250 8963.64 9033.14 8074.69 S 3386.46 W 5929730.60 N 671687.46 E 1.036 7371.39 13904.43 88.120 143.660 8965.64 9035.14 8120.27 S 3352.68 W 5929685.81 N 671722.29 E 0.874 7422.11 13940.35 88.740 143.800 8966.63 9036.13 8149.22 S 3331.44 W 5929657.36 N 671744.20 E 1.769 7454.28 13990.27 87.170 147.310 8968.41 9037.91 8190.35 S 3303.22 W 5929616.90 N 671773.36 E 7.698 7499.65 14034.51 86.170 145.890 8970.98 9040.48 8227.22 S 3278.91 W 5929580.60 N 671798.52 E 3.921 7540.16 14082.97 84.600 149.440 8974.88 9044.38 8268.02 S 3253.08 W 5929540.41 N 671825.29 E 7.988 7584.80 14125.92 84.610 148.620 8978.92 9048.42 8304.69 S 3231.08 W 5929504.26 N 671848.14 E 1.901 7624.70 '~ 14218.84 87.230 145.480 8985.53 9055.03 8382.44 S 3180.67 W 5929427.69 N 671900.33 E 4.394 7709.97 14268.27 83.780 147.970 8989.40 9058.90 8423.63 S 3153.64 W 5929387.14 N 671928.31 E 8.598 7755.20 14312.40 84.800 147.400 8993.79 9063.29 8460.74 S 3130.17 W 5929350.59 N 671952.64 E 2.645 7795.80 14342.53 84.960 147.150 8996.48 9065.98 8485.99 S 3113.94 W 5929325.73 N 671969.44 E 0.982 7823.46 14386.00 84.960 147.150 9000.30 9069.80 8522.36 S 3090.45 W 5929289.90 N 671993.77 E 0.000 7863.33 Projected Survey 21 November, 2002 - 10:41 Page 3 of 4 OrillQuest 3.03.02.004 Sperry-Sun Drilling Services Survey Report for PBU_EOA DS 14 -14-44APB1 Your Ref: API 500292257371 Job No. AKZZ22168, Surveyed: 27 October, 2002 BPXA North Slope Alaska All data is in Feet (US) 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). Vertical Section is from Well Reference and calculated along an Azimuth of 170.090° (True). Magnetic Declination at Surface is 26.098°(11-0ct-02) Based upon Minimum Curvature type calculations, at a Measured Depth of 14386.00ft., The Bottom Hole Displacement is 9065.41ft., in the Direction of 199.932° (True). ~ Comments Measured Depth (ft) Station Coordinates TVD Northings Eastings (ft) (ft) (ft) Comment 11606.42 11631.97 14386.00 8435.60 8449.98 9069.80 6070.56 S 6089.31 S 8522.36 S 3189.04 W 3198.75 W 3090.45 W Tie On Point Window Point Projected Survey Survey tool program for 14-44APB1 From Measured Vertical Depth Depth (ft) (ft) To Measured Vertical Depth Depth (ft) (ft) ~ Survey Tool Description 0.00 11606.42 0.00 8435.60 11606.42 14386.00 8435.60 AK-1 BP _HG(14-44PB1) 9069.80 AK-6 BP _IFR-AK(14-44APB1) 21 November, 2002 - 10:41 Page 4 of 4 DrillQuest 3.03.02.004 ) ) AOGCC 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 Re: Distribution of Survey Data for Well 14-44APB 1 MWD Dear Dear Sir/Madam: Enclosed are two survey hard copies and 1 disk Tie-on Survey: 11,606.42' MD Window / Kickoff Survey 11,631.97 I MD (if applicable) Projected Survey: 14,386.00 I MD Please call me at 273-3545 if you have any questions or concerns. Regards, William T. Allen Survey Manager Attachment(s) ¿1o;;Z-1 ~ 3 23-Nov-02 RECE\VED DEC 06 2002 A1as\œ at-, & Gas Cons. Commission Anchorage I<f Sperry-Sun Drilling Services North Slope Alaska BPXA PBU_EOA DS 14 14-44APB1 MWD '~ Job No. AKMW22168, Surveyed: 27 October, 2002 Survey Report 21 November, 2002 Your Ref: API 500292257371 Surface Coordinates: 5937881.65 N, 674885.74 E (70014' 09.5038" N, 148035' 16.5004" W) Grid Coordinate System: NAD27 Alaska State Planes, Zone 4 ~ Surface Coordinates relative to Project H Reference: 937881.65 N, 174885.74 E (Grid) Surface Coordinates relative to Structure Reference: 1711.09 S, 694.93 E (True) Kelly Bushing: 69.50ft above Mean Sea Level Elevation relative to Project V Reference: 69.50ft Elevation relative to Structure Reference: 69.50ft 5pe"""""'y-sUI! fiFiTi:: .::1' N G ' 5 IS", \:7"1 ë,:' e 5 A Halliburton Company Survey Ref: svy11374 Sperry-Sun Drilling Services Survey Report for PBU_EOA DS 14 - 14-44APB1 MWD Your Ref: API 500292257371 Job No. AKMW22168, Surveyed: 27 October, 2002 BPXA North Slope Alaska Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (0/100ft) 11606.42 55.200 208.120 8366.10 8435.60 6070.56 S 3189.04 W 5931738.76 N 671838.35 E 5431.14 Tie On Point MWD Magnetic 11631.97 56.300 205.090 8380.48 8449.98 6089.44 S 3198.49 W 5931719.67 N 671829.33 E 10.706 5448.12 Window Point 11666.38 58.740 257.770 8399.92 8469.42 6106.36 S 3220.01 W 5931702.26 N 671808.22 E 127.932 5461.08 11698.00 58.780 202.820 8417.28 8486.78 6122.58 S 3239.54 W 5931685.58 N 671789.07 E 146.949 5473.70 11760.41 61 .460 197.070 8448.39 8517.89 6173.43 S 3257.95 W 5931634.33 N 671771.84 E 9.068 5520.62 .~ 11791.20 61.780 199.240 8463.03 8532.53 6199.16 S 3266.39 W 5931608.40 N 671764.00 E 6.287 5544.52 11820.10 62.170 196.690 8476.61 8546.11 6223.43 S 3274.26 W 5931583.96 N 671756.70 E 7.905 5567.07 11854.25 62.890 197.270 8492.36 8561.86 6252.41 S 3283.11 W 5931554.78 N 671748.52 E 2.591 5594.09 11885.29 63.000 196.770 8506.48 8575.98 6278.84 S 3291.20 W 5931528.17 N 671741.05 E 1 .478 5618.74 11913.52 64.200 197.710 8519.03 8588.53 6302.99 S 3298.69 W 5931503.85 N 671734.11 E 5.193 5641.24 12006.48 67.440 197.000 8557.10 8626.60 6383.92 S 3323.98 W 5931422.35 N 671710.71 E 3.554 5716.61 12099.15 67.910 197.220 8592.31 8661.81 6465.85 S 3349.20 W 5931339.86 N 671687.40 E 0.553 5792.98 12192.46 68.840 198.510 8626.69 8696.19 6548.41 S 3375.81 W 5931256.71 N 671662.71 E 1.626 5869.72 12286.04 69.900 198.920 8659.66 8729.16 6631.35 S 3403.91 W 5931173.13 N 671636.54 E 1.205 5946.59 12375.16 70.760 199.130 8689.66 8759.16 6710.69 S 3431.27 W 5931093.19 N 671611.03E 0.990 6020.04 12474.66 71.320 199.470 8721.99 8791.49 6799.50 S 3462.37 W 5931003.68 N 671581.99 E 0.649 6102.17 12567.57 72.190 200.150 8751.08 8820.58 6882.52 S 3492.28 W 5930919.99 N 671554.02 E 1.166 6178.80 12660.97 71.720 199.340 8780.01 8849.51 6966.10 S 3522.28 W 5930835.73 N 671525.97 E 0.966 6255.97 12749.33 71.470 199.790 8807.91 8877.41 7045.10 S 3550.36 W 5930756.10 N 671499.73 E 0.560 6328.96 12846.27 72.640 199.660 8837.78 8907.28 7131.91 S 3581.48 W 5930668.59 N 671470.63 E 1.214 6409.12 12877.53 72.710 199.870 8847.09 8916.59 7159.99 S 3591.57 W 5930640.28 N 671461 .19 E 0.679 6435.05 12893.28 72.820 199.940 8851.75 8921.25 7174.14 S 3596.69 W 5930626.03 N 671456.40 E 0.817 6448.10 ~ 12979.08 74.440 198.500 8875.93 8945.43 7251.87 S 3623.79 W 5930547.69 N 671431 .11 E 2.481 6520.01 13007.28 74.420 196.010 8883.50 8953.00 7277.81 S 3631.85 W 5930521.57 N 671423.66 E 8.506 6544.17 13037.67 73.110 188.070 8892.01 8961.51 7306.32 S 3637.93 W 5930492.93 N 671418.24 E 25.451 6571.21 13072.65 74.660 185.990 8901.72 8971.22 7339.67 S 3642.04 W 5930459.49 N. 671414.90 E 7.230 6603.35 13098.87 76.600 184.900 8908.23 8977.73 7364.95 S 3644.45 W 5930434.16 N 671413.08 E 8.424 6627.85 13134.12 79.380 185.300 8915.57 8985.07 7399.29 S 3647.52 W 5930399.76 N 671410.81 E 7.964 6661.14 13162.91 81.580 182.690 8920.33 8989.83 7427.61 S 3649.49 W 5930371.40 N 671409.49 E 11.761 6688.70 13193.23 83.120 183.220 8924.36 8993.86 7457.62 S 3651.04 W 5930341.36 N 671408.64 E 5.366 6718.00 21 November, 2002 - 10:42 Page 2 of 4 DrillQuest 3.03.02.004 ~ Sperry-Sun Drilling Services Survey Report for PBU_EOA DS 14 - 14-44APB1 MWD Your Ref: API 500292257371 Job No. AKMW22168, Surveyed: 27 October, 2002 BPXA North Slope Alaska Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (0/100ft) 13227.50 85.190 181.300 8927.85 8997.35 7491.68 S 3652.39 W 5930307.28 N 671408.09 E 8.219 6751.32 13258.13 85.740 176.190 8930.28 8999.78 7522.20 S 3651.72 W 5930276.79 N 671409.46 E 16.727 6781.50 13286.42 86.170 175.560 8932.27 9001.77 7550.34 S 3649.69 W 5930248.69 N 671412.14 E 2.692 6809.57 13321.67 85.900 177.330 8934.71 9004.21 7585.44 S 3647.51 W 5930213.66 N 671415.14E 5.067 6844.52 13352.17 85.860 176.460 8936.90 9006.40 7615.82 S 3645.86 W 5930183.33 N 671417.49 E 2.848 6874.73 ~ 13384.10 83.110 169.790 8939.97 9009.47 7647.35 S 3642.06 W 5930151.89 N 671422.02 E 22.504 6906.44 13415.89 81.240 166.910 8944.30 9013.80 7678.19 S 3635.70 W 5930121.21 N 671429.09 E 10.731 6937.92 13446.47 82.180 160.190 8948.72 9018.22 7707.19 S 3627.14 W 5930092.41 N 671438.32 E 21.961 6967.96 13478.80 82.770 157.390 8952.95 9022.45 7737.07 S 3615.54 W 5930062.81 N 671450.61 E 8.778 6999.39 13510.46 86.310 153.620 8955.96 9025.46 7765.74 S 3602.48 W 5930034.45 N 671464.34 E 16.294 7029.88 13540.60 87.750 157.020 8957.53 9027.03 7793.08 S 3589.91 W 5930007.40 N 671477.53 E 12.237 7058.98 13570.71 88.950 152.670 8958.39 9027.89 7820.32 S 3577.12 W 5929980.47 N 671490.95 E 14.981 7088.01 13601.33 89.750 154.770 8958.74 9028.24 7847.77 S 3563.57 W 5929953.34 N 671505.14 E 7.339 7117.38 13631.92 89.720 153.480 8958.88 9028.38 7875.29 S 3550.22 W 5929926.14 N 671519.12 E 4.218 7146.79 13664.17 89.110 155.000 8959.21 9028.71 7904.34 S 3536.20 W 5929897.43 N 671533.81 E 5.078 7177.81 13754.88 87.560 145.080 8961.85 9031.35 7982.79 S 3490.98 W 5929820.04 N 671580.84 E 11 .064 7262.88 13847.66 87.840 143.300 8965.58 9035.08 8057.97 S 3436.74 W 5929746.14 N 671636.80 E 1.941 7346.27 13904.43 88.120 144.060 8967.58 9037.08 8103.68 S 3403.14 W 5929701.22 N 671671.46 E 1 .426 7397.09 13940.35 88.740 142.860 8968.56 9038. 06 8132.53 S 3381.76 W 5929672.88 N 671693.50 E 3.759 7429.18 13990.27 87.170 149.500 8970.35 9039.85 8173.95 S 3354.01 W 5929632.11 N 671722.20 E 13.659 7474.76 14034.51 86.170 148.390 8972.92 9042.42 8211.79 S 3331.23 W 5929594.81 N 671745.86 E 3.374 7515.95 14082.97 84.600 152.680 8976.82 9046.32 8253.83 S 3307.47 W 5929553.33 N 671770.58 E 9.400 7561.46 14125.92 84.610 147.740 8980.86 9050.36 8290.93 S 3286.23 W 5929516.74 N 671792.67 E 11 .451 7601.66 ~ 14218.84 87.230 144.830 8987.4 7 9056.97 8368.01 S 3234.80 W 5929440.87 N 671845.89 E 4.208 7686.44 14268.27 83.780 147.510 8991.34 9060.84 8408.93 S 3207.37 W 5929400.60 N 671874.26 E 8.827 7731.47 14312.40 84.800 146.900 8995.73 9065.23 8445.84 S 3183.58 W 5929364.25 N 671898.89 E 2.690 7771.92 14342.53 84.960 145.080 8998.42 9067.92 8470.72 S 3166.80 W 5929339.77 N 671916.25 E 6.040 7799.32 14386.00 84.960 145.080 9002.24 9071.74 8506.22 S 3142.01 W 5929304.85 N 671941.85 E 0.000 7838.56 Projected Survey 21 November, 2002 - 10:42 Page 3 of 4 DrillQuest 3.03.02.004 "" Sperry-Sun Drilling Services Survey Report for PBU_EOA DS 14 -14-44APB1 MWD Your Ref: API 500292257371 Job No. AKMW22168, Surveyed: 27 October, 2002 BPXA North Slope Alaska All data is in Feet (US) 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). Vertical Section is from Well Reference and calculated along an Azimuth of 170.090° (True). Magnetic Declination at Surface is 26.099°(11-0ct-02) '-' Based upon Minimum Curvature type calculations, at a Measured Depth of 14386.00ft., The Bottom Hole Displacement is 9067.97ft., in the Direction of 200.273° (True). Comments Measured Depth (ft) Station Coordinates TVD Northings Eastings (ft) (ft) (ft) Comment 11606.42 11631.97 14386.00 8435.60 8449.98 9071.74 6070.56 S 6089.44 S 8506.22 S 3189.04 W 3198.49 W 3142.01 W Tie On Point Window Point Projected Survey Survey tool program for 14-44APB1 MWD Fro m Measured Vertical Depth Depth (ft) (ft) To Measured Vertical Depth Depth (ft) (ft) ~ Survey Tool Description 0.00 11606.42 0.00 11606.42 8435.60 14386.00 8435.60 AK-1 BP _HG(14-44PB1) 9071.74 MWD Magnetic(14-44APB1 MWD) 21 November, 2002 - 10:42 Page 4 of 4 DrillQuest 3.03.02.004 ) ~7~~! :Jf fÆ~fÆ~lAfÆ AI,ASIiA OIL AND G~4¡ CONSERVAnONCO~SSION TONY KNOWLES, GOVERNOR 333 W. 7fH AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Bill Isaacson Senior Drilling Engineer BP Exploration (Alaska), Inc. PO Box 196612 Anchorage AK 99519-6612 Re: Prudhoe Bay Unit 14-44A (Revised) BP Exploration (Alaska), Inc. Pennit No: 202-193 Surface Location: 2829' NSL, 1617' WEL, Sec. 09, T10N, R14E, UM Bottomhole Location: 1014' SNL, 4316' WEL, Sec.21, T10N, R14E, UM Dear Mr. Isaacson: Enclosed is the approved application for pennit to redrill the above development well. . This pennit to redrill does not exempt you from obtaining additional pennits or approvals required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required pennits 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 tenns and conditions of this pennit may result in the revocation or suspension of the permit. Please provide at least twenty-four (24) hours notice for a representative of the Commission to witness any required test. Contact the Commission's North Slope petroleum field inspector at 659-3607 (pager). ~inc rely, ~ f ' 7' , Daniel T. Seamount, Jr. Commissioner BY ORDER OF T)JE COMMISSION DATED this ~ay of October, 2002 cc: Department ofFish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. \t--Í ßA¡-" 'f /2 Î I () L Hole 6-3/4" 4-3/4" "1'" STATE OF ALASKA \ ALASKA'_.' AND GAS CONSERVATION COMM__GION PERMIT TO DRILL Resubmittal Per W. Aubert change KOP 20 AAC 25.005 1 b. Type of well 0 Exploratory 0 Stratigraphic Test 1m Development Oil 0 Service 0 Development Gas 0 Single Zone 0 Multiple Zone 5. Datum Elevation (DF or KB) 10. Field and Pool Plan RKB = 69.50' Prudhoe Bay Field / Prudhoe 6. Property Designation Bay Pool ADL 028314 7. Unit or Property Name Prudhoe Bay Unit 8. Well Number '" 14-44A 9. Approximate spud date 10/01/02 / Amount $200,000.00 14. Number of acres in property 15. Proposed depth (MD and TVD) 2560 15137' MD /9035' TVD 17. Anticipated pressure {s~e 20 AAC 25.035 (e) (2)} 91 0 Maximum surface 24651 psig, At total depth (TVD) 8950' 13360 psig Setting Depth Top Bottom Lenath MD TVD MD TVD 1437' 11500' 8303' 12937' 8945' 2350' 12787' 8875' 15137' 9035' 11. Type Bond (See 20 AAC 25.025) 1 a. Type of work 0 Drill 1m Redrill 0 Re-Entry 0 Deepen 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 2829' NSL, 1617' WEL, SEC. 09, T10N, R14E, UM At top of productive interval 4716' SNL, 5276' WEL, SEC. 16, T10N, R14E, UM At total depth 1014' SNL, 4316' WEL, SEC. 21, T10N, R14E, UM 12. Distance to nearest property line 13. Distance to nearest well / ADL 047475,963' MD 14-44 is 2.09'away at 11698'MD 16. To be completed for deviated wells Kick Off Depth 11650' MD Maximum Hole Angle 18. Casin~ Program Specifications Size Casina Weiaht Grade Couolina 5-1/2" 17# L-80 Hydril521 3-1/2" 9.2# L-80 IBT Number 2S100302630-277 Quantitv of Cement (include staQe data) .212 sx Class 'G' / Uncemented Slotted Liner 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Structural Conductor Surface Intermediate Production Liner 14638 feet 9067 feet 14638 feet 9067 feet Length Plugs (measured) Junk (measured) See Diagram: Fish left in hole at approx. 12511' Size Cemented MD TVD 110' 20" 3259' 10-3/4" 12471' 7-5/8" 2260' 4-1/2" 260 sx Arcticset (Approx.) 1210 sx CS III, 375 sx 'G', 181 sx CSII 110' 3288' 110' 3220' 265 sx Class 'G' Uncemented Slotted Liner 12498' 8946' ~::1ê~t~' r 'ir~:l) 8881' - 9067' Perforation depth: measured Slotted Section: 12468' - 14615' '"I true vertical Slotted Section: 8930' - 9067' <¡, 20. Attachments 0 Filing Fee 0 Property Plat 0 BOP Sketch 0 Diverter Sketch 1m Drilling Program 1m Drilling Fluid Program 0 Time vs Depth Plot 0 Refraction Analysis 0 Seabed Report 0 20 AAC 25.050 Requirements Contact Engineer Name/Number: Dave Wesley, 564-5773 21. I hereby certify that t~E1 foregoing is true and correct to the bes. t of my ~nowl~~ge .. Signed Bill Isaacson U JL.. k r \...... - Title Senior Dnlllng Engineer , "',~.~..~::,", Permit Number API Number Awr~)fa~~¡le tJ.. See cover lett~r 202-193 I 50- 029-22573-01 '11 JfJ () v \ for other requirements Conditions of Approval: Samples Required 0 Yes 3 No Mud Log Requir d 0 Yes 551 No Hydrogen Sulfide Measures 181 Yes 0 No Directional Survey Required I2SI Yes 0 No Required Working Pressure for BOPE 0 2K 0 3K 0 4K 0 5K 0 10K 0 15K 0 3.5K psi for CTU Other: T e~ ,t.." {?;o P E.. .{:ð ~ CS (;2 ù p U , ,.' \IE:."Ç'Á.~;'oh..." \ ''''v by order of , :1't/I(,\I'rt.. v ti*"'.-L Approved By ". .'tðÌJfg¡~~~'-A\RQ T', ~o~eh L the commission Form 10-401 Rev. 12-01-85 ,~- rnOllQJ \ f i \J 1-\ Prepared By Name/Number: Terrie Hubble, 564-4628 Date S~rt /8, ZOo 1... Date oj ?f01- S&bm~~ Triplicate ) ) rWell Name: 114-44A Drill and Complete Plan Summary l Type of Well (service I producer I injector): I Horizontal Sidetrack Producer I AFE Number: I PBD4P2008 1 I Estimated Start Date: I 09/25/02 I 1 MD: 115,137' I i I TVD: 19,035' I Surface Location: Estimated Target Location: Ivishak Zone 48 Bottom Hole Location: x = 674,885.74 24511 FNL , 1617' FEL X = 671,420.00 564' FSL , 3' FWL X = 672,420.00 10141 FNL, 963' FWL Y = 5,937,881.65 Sec. 9, T10N, R14E Umiat Y = 5,930,255.00 TVDss 8955 Sec. 16, T10N, R14E Umiat Y = 5,928,700.00 TVDss 8965 Sec. 21, T1 ON, R14E Umiat I RiQ: I Nabors 2ES I OperatinQ days to complete: 122.5 I BF/MS: 141.00' 1 I I I RKB: 169.50' 1 I 1 I Well DesiQn (conventional, slimhole, etc.): I Horizontal Sidetrack I Objective: I Zone 4B CasinglTubing Program Hole Size Csgl WtlFt Grade/ Conn Length Top 8tm Tbg O.D. MDITVD MDITVD 6 3/4" 51/2" 17.0# L-80 Hydril 521 -1 ,437' 11 ,500' 1 8,303' 12,937' 1 8,945' 4 3/4" 3 Y2" 9.2# L-80 ISTI Spc. -2,350' 12,787' 1 8,894' 15,137'/9,035' slotted Clearance Tubing 4 Y2" 12.6# L-80 1ST -11,480 GL 11,480'/8,365 , Directional KOP: 111,650' MD Maximum Hole Angle: Close Approach Well: Survey Program: 14-44A Sidetrack -55.0° in original well bore at -6,150' MD. -91.0° in horizontal section of sidetrack from -13,703' to -14,573' MD. There is one close approach issue: The closest well to the 14-44A is 14-44 original well with a center-to-center distance of 2.09' and allowable deviation of -264' at the planned depth of 11,698' MD. IIFR 1 Cassandra from kick-off to TO. Page 1 ) Section Millin9 Mud Properties: LSND I Whip Stock Window 7 5/8" I Density (ppg) Viscosity PV YP tauO MBT pH API FI 11.3 45 - 55 18 - 45 5-9 8.5-9.0 5-6 Intermediate Mud Properties: LSND \63/4" hole section \ Density (ppg) Viscosity PV YP tauO MBT pH API FI 11.3 "/ 45 - 55 18 - 45 3-8 8.5 - 9.0 5-6 Production Mud Properties: Flo-Pro Drill-in I 4 3/4" hole section I Density (ppg) Viscosity PV YP tauO MBT pH API FI 8.6-8.7 N/A 7 -11 25 - 35 4-8 <6 9.0 - 9.5 N/A Logging Program 6 3/4" Intermediate: Sample Catchers - None Drilling: MWD Dir/GRlRes/PWD- Real time GR/Res throughout entire interval. Open Hole: None Cased Hole: None 4 314" Production: Sample Catchers - None Drilling: MWD Dir/GRlRes- Real time GR/Res throughout entire interval. Open Hole: None Cased Hole: None Cement Pro~ ram Casing Size 5 1/2" 17#, L-80 Intermediate Liner I Basis: Lead: None Tail: Based on 82' of 51/2" shoe track, 1287' of 51/2" X 7" open hole with 400/0 excess, 150' of 7 5/8" X 5 Y2" liner lap, and 200' of 4" drill pipe in 7 5/8" liner. Tail TOC: -11,500' MD (8,303'TVD). Fluid Sequence & Volumes: Pre 10bbls Water Flush Spacer Lead Tail 20bbls Alpha Spacer at 12.2ppg None 43.5 bbl I 244 fe I 212 sks of Halliburton 'G' at 15.9ppg and 1.15 cf/sk, BHST 2000 Casing Size 3 1/2", 9.2#, L-80 Slotted 1 Solid Production Liner Basis: Lead: None Tail: None. Uncemented solid I slotted liner Fluid Sequence & Volumes: Pre N/A Flush Spacer NI A Lead NI A Tail N/A 14-44A Sidetrack Page 2 ) ) Well Control Well control equipment consisting of 5000 psi working pressure pipe rams (2), blind/shear rams, and an annular preventer will be installed and is capable of handling maximum potential surface pressures. Based upon calculations below, BOP equipment will be tested to 3500 psi. ( BOPE and drilling fluid system schematics are currently on file with the AOGCC. Production Section- . Maximum anticipated BHP: ~360 psi @ 8950' TVDss - Z4 . Maximum surface pressure: -2465 psi @ surface (based upon BHP and a full column of gas from TO @ 0.10 psi/ft) . Planned BOP test pressure: Planned completion fluid: 3500 psi 8.6 ppg seawater / 7.2 ppg Diesel . . No annular injection in this well. Cuttings Handling: Cuttings generated from drilling operations will be hauled to grind and inject at D8-04. Any metal cuttings will be sent to the North Slope Borough. Fluid Handling: Haul all drilling and completion fluids and other Class 1\ wastes to D8-04 for injection. Haul all Class I wastes to Pad 3 for disposal. . . Formation Markers Formation Tops (Wp#6) MD TVDss Comments CM2 N/A 7213 CM1 N/A 7594 THRZ N/A 8027 BHRZ N/A 8187 TJE N/A 8222 TJC 11868 8500 TJB 12384 8685 \\~ TJA 12674 8785 T8AG 12922 8870 T8HU 12965 8885 T8AD / Z4B 13230 8950 Est. Pore Pressure 3360psi (-7.2ppg EMW) TZ4A Not penetrated GOC/MGOC Not present in this area MHOT N/A 8985 MOWC N/A 9015 TD Criteria: The well will reach TD according to well plan #06, or before IF water saturation is higher than , expected. The subsurface team will determine this. 14-44A Sidetrack Page 3 ) Sidetrack and Complete Procedure Summary Ria Operations: 1. MI/RU Nabors 2ES 2. Circulate out freeze protection and displace well to seawater. Set TWC. 3. Nipple down tree. Nipple up and test BOPE. I 4. Pull 4Y2" tubing from above pre-rig cut at 11,950' MD. 5. R/U E-line. RIH with a GR/JB and CCl to the tubing stump. Determine casing collar depths in preparation for upcoming section mill. POOH. 6. RIH and set 7 5/8" Bridge Plug, on E-line, at -11,950' MD, just above tubing stump. POOH. 7. Pressure test against the Bridge Plug to 3,OOOpsi for 30 minutes. 8. RI H with an SCMT. Obtain a cement bond log 4rom the bridge plug to -100 feet above top of cement. POOH. 9. P/U 4" drill pipe and M/U 7 5/8" section milling BHA. RIH and driJt down to the bridge plug. Displace well to -11.0ppg milling fluid. / 10. Mill a section in 7 5/8" casing from -11,660' MD to -11,705' MD. Circulate hole clean, monitor cuttings return. Verify weight of returned cuttings and determine cleaning efficiency. POOH. 11. RIH and lay a -500 ft., 17ppg cement kick off plug from the Bridge Plug to -11,450' MD. POOH. 12. Allow minimum of 12 hours curing time prior to dressing off cement with directional assembly. 13. RIH with a 6 %" Dir/Gr/Res/PWD assembly. Kick-off and drill the 6 3/4" X 7" NBR(Near Bit Reamer) to approximately 20 feet beyond the window and conduct an FIT to 12.7ppg EMW. 14. Drill the section, according to directional well plan, to the top of the Sag River at -12,937' MD. 15. Run and cement a 5 1/2", 17#, l-80 intermediate drilling liner. POOH. 16. Test the 7 5/8" casing X 5 Y2" liner from the landing collar to surface to 3,500psi for 30 minutes. 17. M/U and RIH with 4 3/4" Dir/Gr/Res assembly to the landing collar. Drill the float equipment to the shoe. ./ 18. Displace the well to -8.5ppg Flo-Pro mud system. 19. Drill out the 5 Y2" shoe, plus - 20 feet of new formation. Conduct an FIT to 1 O.Oppg EMW. 20. Drill the 4 3/4" production section, as per directional plan, to an estimated TD of 15,137' MD. POOH. 21. Run a 3 Y2", 9.2#, l-80 solid and slotted liner. / 22. Displace well to clean seawater. POOH. 23. Run a 4 1/2", 12.6#, l-80 completion tying into the 5 1/2" liner top. 24. Set packer and test the tubing and annulus to 3500 psi for 30 minutes. 25. Nipple down the BOPE. Nipple up and test the tree to 5000 psi. 26. Freeze protect the well to -2200' and secure the well. Rig down and move off. Post-Ria Work: 1. MIRU slick line. Pull the ball and rod I RHC plug from landing nipple below the production packer. Install gas lift valves. Estimated Pre-rig Start Date: 09/20102 Estimated Spud Date: 10101/02 14-44A Sidetrack Page 4 ) ) Job 1: MIRU Hazards and Contingencies )0> No wells will require shut-in for the rig move onto 14-44. However, 14-38 is -30' to the North, and 14-17 is -30' to the South. These are the closest neighboring wells. Care should be taken while moving onto the well. Spotters will be used at all times. )0> D5-14 is designated as an H2S site. Standard Operating Procedures for H2S precautions should be followed at all times. Recent H2S data from the pad is as follows: Closest SHL Wells: Closest BHL Wells: 14-22A 26ppm 14-08A 86ppm 14-44 39ppm 14-40 59ppm The maximum level recorded of H2S on the pad was 200ppm in 06/2002. ~ Post Permit to Drill and Summary of Drilling Hazards in the dog house and camp prior to spud Reference RP .:. "Drilling/Work-over Close Proximity Surface and Subsurface Wells Procedure" SOP :<x~,»:>:'x»}w.-:»>1m'_»¡,X'« J«>1X.x.1':'1':'_<:'}:<.JoJX:<»'¡':'»X"''»'>~'''-y._X'Jo»_-''»X»>':'x.y.«--_<o:' 'mx>x,},x.;>.:,¡.m:«"X~1'_»X),"»':«'~ Job 2: De-complete Well Hazards and Contingencies )0> The slotted liner interval/lower section of this well should be isolated by 2 barriers (the P&A cement plug and the seawater). The plug will be tested in the pre-rig operations. Monitor the well to ensure the fluid column is static, prior to pulling the completion. )0> NORM test all retrieved well head and completion equipment. )0> The existing wellhead is an FMC New Standard Slim Hole and has a tubing hanger with 4 1/2" NSCT landing thread. Utilize a 4" type 'H' BPV. Verify the hanger type and connection. Be prepared with necessary equipment to remove. Reference RP .:. "De-completions" RP ''''^"'''''^'''~~~,~~.~~~,-~~~,~~~,~~~~, Job 4: Section Mill Hazards and Contingencies )0> Once milling is complete, make sure all BOP equipment is operable. Wash out BOP stack to remove any metal cuttings, which may have settled there. Reference RP .:. "Section Milling to Sidetrack a Well" RP ~Y"^--.,_.v,--,v--_..._.._--,.~---_...._..._,.__.__...,_.,--.,...----wm..--,~._,.-,.,..--._- 14-44A Sidetrack Page 5 ) ) Job 5: Drill 6 3/4" Intermediate Hole Hazards and Contingencies ~ The well will kick off in mid-Kingak, and drill the remainder of the Kingak, into the Sag River formation. Previous DS 14 wells drilled the Kingak with 9.8 to 10.2ppg mud weights. For this well, due to the long tangent at 690+ inclination, maintain mud weight at 11.3ppg, minimally, to 5 1/2" liner point. Follow all shale drilling practices to minimize potential problems. ~ The Security Near Bit Reamer (NBR) will be utilized in drilling this intermediate section, to open the hole from 6 %" to 7" gauge. This should aid in getting the 5 }2" liner to setting depth, within the Sag River. ~ KICK TOLERANCE: In the worst-case scenario of 9.6ppg pore pressure at the Sag River depth, a fracture gradient of 11.6ppg at the 7 5/8" casing window, and 11.3ppg mud in the hole, the kick tolerance is infinite. Reference RP .:. "Shale Drilling, Kingak and HRZ" RP .:. "Prudhoe Bay Directional Guidelines" .:. "Lubricants for Torque and Drag Management" RP ~»:,:q,»m~1_~m_'¡111»»:>¡ ~~ ¡¡111>>''>>1X*1:<Y..¡¡¡1>>111¡¡1'w.>}1>>10111;.1N>>YÆ<11:-'11>> Job 6: Install 5 1/2" Intermediate Liner Hazards and Contingencies ~ Avoid high surge pressures with controlled running speeds and by breaking circulation slowly. High surge pressures could lead to losses to the Sag River or exacerbate Kingak instability problems. ~ Ensure the liner top packer is set prior to POOH. This may require going through the setting process twice. Slack off with rotation to the maximum allowable down weight, as per Baker representative. Reference RP .:. "Intermediate Casing Cementing Guidelines" RP .:. "Running and Cementing a Drilling Liner" RP Job 7: Drill 4 3/4" Production Hole Hazards and Contingencies ~ There is one anticipated fault crossing, while drilling 14-44A. It will be crossed within Zone 4B. The fault has a small throw, approximately 10 feet. While recently drilling the nearby X-09B sidetrack, a fault of similar orientation and throw was crossed within Zone 4B, and presented no problems. Reference RP .:. "Standard Operating Procedure: Leak-off and Formation Integrity Tests" .:. "Prudhoe Bay Directional Guidelines" .:. "Lubricants for Torque and Drag Management" RP 14-44A Sidetrack Page 6 ) Job 9: Install 3 Y2" Slotted Production Liner Hazards and Contingencies ~ The completion design is to run a 3 V2", 9.2#, L-80 slotted liner throughout the production interval. Solid liner will be placed across intervals of lower resistivity / higher water saturation, as determined by the subsurface team. ~ Differential sticking is a concern. The 8.6ppg Flo-Pro will be -600psi over balanced to the Ivishak formation. Minimize the time the pipe is left stationary while running the liner. ~ Ensure the liner top packer is set prior to POOH. Slack off with rotation to the maximum allowable down weight, as per Baker representative. ~ Sufficient 3 V2" liner will need to be run to extend -150' back up into the 5 1/2" intermediate liner, set at -12,937' MD. Reference RP .:. '~J.]Y'<:>¡~»:'h¡~»~~»>"h¡Y'¡:'~)~1:<;m»Y":')YÆ,)¡»}m¡~"w.....:,»»»1o.'»»¡}:»>>>-¡m1:»>1 Job 12: Run Completion Hazards and Contingencies ~ Diesel will be used to freeze protect the well. The diesel flash point is 1000 F. Diesel vapor pressure is - 0.1 psia at 1000 F. Reference RP .:. "Completion Design and Running" RP .:. "Tubing connections" RP -¡¡:<'>¡:<.¡:'»»:'m¡':<'»:<:"¡:<¡:'»:<:»>:<~m¡_»»~.~~ Job 13: ND/NU/Release Ria Hazards and Contingencies ~ There are two neighboring wells at 30 foot center spacing. Identify all potential hazards in a pre rig move meeting, and take every precaution to ensure good communication prior to beginning the rig move. Use spotters when moving the rig off the hole and about the pad. Reference RP .:. "Freeze Protecting an Inner Annulus" RP 14-44A Sidetrack Page 7 ö COMPANY I >1"1 All S REFERENCE INFORMA nON SURVEY PROGRAM Plan: 14-44A wp06 (14,44Il'lan 14-44A) UP Al1h\ÇO Ü..H..mUuat.:- (N'E) R~t~renc~: Well C~ntre: 14-44. True Nt'lfth V~rtical (IVO) Rd~reI1l:e: 695 69.50 Section (VS) Retèrenç~: Slot - 44 (O.OON.O.OOE) Measured [):pth Retèrence: 695 6950 Calculation M~lhod: Minimum C'urvahlæ o..:plh Fm Dðpth T {} SUfve-y/Plan Tool Created By: Ken Allen Checked: Date: 8/26/2002 CakuwtKHI M~lh\)(I: Minimum Curvature EmIr SYstem: ISCWSA Scan Method: Trav ('ylil1d~r Nonh Em}r Stlrln..:~: l:llir(k'III' Casing W.1minsz Mc:tll('I(I: Ru/t."'S Bast.'(f 11650.!XJ 15137,12 Planned: 14-44A wp06 V8 MWD WELL DETAILS Name .¡.N;.S -FI-W Northing Basting Latitudð LOl1gituœ Slot 14-44 -1713.32 696.26 5937880,76 674886.09 70"14'09.495N 148"35'16.49IW 44 TARGET DETAILS Sec MD lnc Nan~ fVD ~NI.S -Ei-W Northing Easting Sha~ 14-44A Db 9014.50 -8684.94 -2963.50 5929130,00 672124.99 Point 14-44A P,'ly 9019.50 -9302.35 .2652.72 5928520,00 672449.99 Polygon 14-44A Tlb 9024.50 .7543.81 .3642.26 5930255,00 671419.99 Point 14-441\ T2b 9029.50 .777039 -3577.50 5930030,00 671489.99 Point 14-44A T5. 9034.50 .9121.69 -2678.54 5928700,00 672419.99 Point SECTION DETAILS Azi TVD +N/-S +E/-W DLeg TFace VSec Target 207.77 8460.74 -6101.78 -3205.63 0.00 0.00 6757.76 206.34 8471.91 -6116.55 -3213.18 12.00 -30.00 6774.06 198,55 8634.45 -64 I 7.40 -3336.12 4.00 -30,38 7097.36 198.55 8958.53 -7256.54 -3617.75 0.00 0.00 7981.86 172.00 9024.50 -7543.8 I -3642.26 10.00 -63.24 8264.40 14-44A Tlb 169.95 9026,8 I -7584.78 -3635.76 10.00 -29.63 8301.87 169.95 9027.43 -7609.79 -363 I .32 0,00 0.00 8324.63 153.00 9029.50 -7770.39 -3577.50 10.00 -85.46 8463.55 14-44A T2b 145.45 9028.05 -7933.60 -3480.30 4.00 -83.40 8592.76 145.45 9014.82 -8650.09 -2986.86 0.00 0.00 9141.20 146.88 9014.50 -8684.94 -2963.50 4.00 121.28 9\68.06 14-44A T3b 146.88 9015.68 -8733.62 -2931.74 4.00 -179.92 9205.82 146.88 9034.50 -9\21.69 -2678.54 0.00 0.00 9506.83 14-44A T5a -- 'Y~ " ~ ,~+ " /' '~ ~ #ZJ' , "" ., v,-. I 11650.00 54.99 2 11670.00 57.08 3 12034.36 69.89 4 12976.96 69.89 5 13276.12 85.00 6 13317.67 88.61 7 13343.08 88.61 8 13513.10 90.00 9 13703.20 90.87 10 14573.27 90.87 1\ 14615.22 90.00 12 14673.37 87.67 \3 15137.12 87.67 FORMATION TOP DETAILS No. TVDPath MDPath Formation All TVD depths are ssTVD plus 69.5'for RKBE. I 2 3 4 5 6 8569.50 8754.50 8854.50 8939.50 8954.50 9019.50 11868.47 12383.54 12674.39 \2921.6\ 12965.24 13230.\ 0 TJC TJB TJA TSag TSHU TSAD/TZ4B 8400- 9000 ----- -_-..C~~~~~ ",- " '" :_-=-=:==--=-=~'~ ~ -', TIA ,.-, .__._,--",.. - ',~~ 5 1 '2" Start Dir 10/100' : 12976,96' MD, 8958.53'TVD _...._,,--,-_..__,..m"_"_'_-''''--'-~-'- ~-""""" -Sag '4 0 ~ TSHU 13000 ~ ~ ~.... I 00 . - "..",.~ ' - .T3AD\T~n - ~ 1'1 / / '~"" EndDlr: L,317..,7'!v'D,9026.8 'TV) I -, , , Sla 1 Dil 10/10)0', 33~?08' MD, ~027.43'T\'D - / - Sta"l DII.4/1O)': L.51J. 'MD, 90L9.5'TVD '. End Dir : 13 703,2' MD. 902';¡.05' TVD CASING DETAILS No. TVD MD Name Size 8944.50 12936.\6 5 112" 9034,50 15137.11 3112" 5.500 3.500 End Dir : 12034.36' MD, 8634.45' TVD ~ ~ 0 0 ~ 8700 .c Ã Ö ] '12 > ",-/ OJ = ~ End Dir : 14673.37' MD, 9015,68' TVD Start Dir4!IOO': 14573.27' MD, 9014.82'TVD \ \ , p-uui ::; J 1/2" I~OOO ~...... f TctalDcpth 15137.12 MD.9031.5'TVD 00 9300 6900 7200 7500 7800 8100 8400 Vertical Section at 196,360 [300ft/in] 8700 9000 9300 I 9600 bp 0 ('OMPANY IJI'IAIIS ('akulati\}1I M¡,:tlwd: Minimum ('lIr\'allll~ Fmlr S)'~tcm: IS( 'WSA Scan Method: 1m\' C"lind.::r North Emlr Surac\.~: 1~l1ipticål . Casìllg Wan,il!! M<d.xl: RIII<s ¡¡II"'oJ -6000- -6500 - 7000 14-44PB1 (lL-44P31) -8500 -9000 -4000 REFEIU'NCE INFORMATION HI' Amnco ('o-ordinaM(NiE¡ R~(ert.'nœ: W~ItC~nue: 14-44. Tru¿North Vcrtjçal (lVD) R~I~rence: 69569.50 ~c(illn (VS) Ref~renc~; Slot - 44 (O.OON.O.OOE) Ml.'asur~t Depth Reference: 695 69.50 Calculatilll1 Mcthod: Minimum CUf\änrre Start Dir 12/100' : 11650' MD, 8460.74'TVD -start Dir 4/100' : 11670' MD, 8471.91'TVD All TVD depths are ssTVD plus 69.5'for RKBE. ------~-- 2976.96' MD, 8958.53'TVD End Dir : 14673.37' MD, 9015.68' TVD 3 1/2" 14-44A wp06 -3500 - 3000 West(-)/East(+) [500ft/in] I -2500 I -2000 SURVEY PROGRAM Depth f111 [)çpth To Survcy;Plau 11650.00 15137.12 PlalUl<:d: 14-44Awp06V8 See I 11650.00 2 11670.00 3 12034.36 4 12976.96 5 13276.12 6 13317.67 7 13343.08 8 13513.10 9 13703.20 10 14573.27 II 14615.22 12 14673.37 13 15137.12 Plan: 14-44A wpn6 (14-44/PlanI4-44A) Tool Created By: Ken Allen Date: 8/26/2n02 MWD Cheçked: WELL DETAILS Name -;.-Nf-$ 'E!-W Easting Latituœ Longitude Slot Northing: 14-44 -1713.32 696.26 5937880,76 674886,09 70'14'09.495N 148'35'16.49IW 44 TARGET DETAILS MD Ine Name TV) ,N/-S ~Fj-W Northing Easting: Shape 14-44A Db 9014.50 -8684.94 .296350 5929130.00 672124.99 Point 14-44A 1','1)' 9019.50 .9302.35 .2652,72 5928520.00 672449.99 Polygon 14-44A Tlb 9024.50 -7543,81 -364226 5930255,00 671419.99 Poiin 14-44A T2b 9029.50 -7770.39 -3577.50 5930030.00 671489.99 Poi11l 14-44A T5. 9034.50 -9121.69 -2678.54 5928700.00 672419.99 Point SECTION DETAILS Azi TVD +N/-S +E/-W DLeg TFace VSec Target 207.77 8460.74 -6101.78 -3205.63 0.00 0.00 6757.76 206.34 8471.91 -6116.55 -3213.18 12.00 -30.00 6774.06 198.55 8634.45 -6417.40 -3336.12 4.00 -30.38 7097.36 198.55 8958.53 -7256.54 -3617.75 0.00 0.00 7981.86 172.00 9024.50 -7543.81 -3642.26 10.00 -63.24 8264.40 14-44A Tlb 169.95 9026.81 -7584.78 -3635.76 10.00 -29.63 8301.87 169.95 9027.43 -7609.79 - 3631.32 0.00 0.00 8324.63 ........".' 153.00 9029.50 -7770.39 -3577.50 10.00 -85.46 8463.55 14-44A T2b 145.45 9028.05 -7933.60 -3480.30 4.00 -83.40 8592.76 145.45 9014.82 -8650.09 -2986.86 0.00 0.00 9141.20 146.88 9014.50 -8684.94 -2963.50 4.00 121.28 9168.06 14-44A T3b 146.88 9015.68 -8733.62 -2931.74 4.00 -179.92 9205.82 146.88 9034.50 -9121.69 -2678.54 0.00 0.00 9506.83 14-44A T5a 54.99 57.08 69.89 69,89 85.00 88.61 88.61 90.00 90.87 90.87 90.00 87.67 87.67 CASING DETAILS FORMATION TOP DETAILS No. TVD MD Name Size No. TVDPath MDPath FOImation 8944.50 12936.16 5 1/2" 5.500 I 8569.50 11868.47 TJC 9034.50 15137.11 3 1/2" 3.500 2 8754.50 12383.54 TJB 3 8854.50 12674.39 TJA 4 8939.50 12921.61 TSag 5 8954.50 12965.24 TSHU 6 9019.50 13230.10 TSAD/TZ4B ~ ~ J:;,,_44^-frlh ~OOO g -7500 ~..:\ End Dr : 13317.57'MD,9026.81'TVD ~ - .. ,,' - " "..'-~Star.Ðir-Ø/HYJL:+3343.08' MD, 9027.43'TVD .<=,i -'_._--~, .-".-- ,- \ \ ~tart.Jlr4/IOO': 13513.I'MD,9029.5'TVD Z i---) i ~:~~~=:-==~7~",'.....'IA, ;lb~_- " \ End Dir : 13703.2' MD, 9028.05' TVD -8000 - ,..,-.,--_'.- ------------\ _.~--~\ -\~~ 1~4"A ~~ .....~ " ..... "":-:, ," 7- .. ,~ ~~ "Y, ) BP KW A Planning Report MAP ) çompany: Field: Site: Well: Wellpath: Field: BP Amoco Prudhoe Bay PB OS 14 14-44 Plan . 14-44A Prudhoe Bay North Slope UNITED STATES Map System:US State Plane Coordinate System 1927 Geo Datum: NAD27 (Clarke 1866) Sys Datum: Mean Sea Level Map Zone: Coordinate System: Geomagnetic Model: Alaska, Zone 4 Well Centre BGGM2002 PB OS 14 TR-10-14 UNITED STATES: North Slope Site Position: Northing: From: Map Easting: Position Uncertainty: 0.00 ft Ground Level: 0.00 ft Site: 5939577.43 ft 674150.48 ft Latitude: Longitude: North Reference: Grid Convergence: 70 14 26.346 N 148 35 36.726 W True 1.32 deg 14-44 14-44 Well Position: Well: Slot Name: 44 70 14 9.495 N 148 35 16.491 W +N/-S -1713.32 ft Northing: 5937880.76 ft +E/-W 696.26 ft Easting: 674886.09 ft Position Uncertainty: 0.00 ft Latitude: Longitude: Well path: Plan 14-44A Current Datum: Magnetic Data: Field Strength: Vertical Section: 69.5 Height 69.50 ft Drilled From: Tie-on Depth: Above System Datum: Declination: Mag Dip Angle: +E/-W ft 0.00 Plan: 14-44A wp06 Date Composed: Version: Tied-to: 14-44 11650.00 ft Mean Sea Level 26.18 deg 80.79 deg Direction deg 196.36 8/26/2002 8 From: Definitive Path 7/25/2002 57533 nT Depth From (TVD) ft 0.00 +N/-S ft 0.00 Principal: Yes Casing Points MD TVD Diameter Hole Size ft ft in in 12936.16 8944.50 5.500 6.750 51/2" 15137.11 9034.50 3.500 4.750 31/2" Formations MD TVD Formations Lithology Dip Angle Dip Direction ft ft deg deg 0.00 THRZ 0.00 0.00 0.00 BHRZ 0.00 0.00 0.00 TJE 0.00 0.00 11868.47 8569.50 TJC 0.00 0.00 12383.54 8754.50 TJB 0.00 0.00 12674.39 8854.50 TJA 0.00 0.00 12921.61 8939.50 TSag 0.00 0.00 12965.24 8954.50 TSHU 0.00 0.00 13230.10 9019.50 TSAD/TZ4B 0.00 0.00 Targets Map Map <- Latitude --> <-- Longitude -> Name Description TVD +N/-S +E/-W Northing Easting Deg Min See Deg Min Sec Dip. Dir. ft ft ft ft ft 14-44A T3b 9014.50 -8684.94 -2963.50 5929130.00 672124.99 70 12 44.073 N 148 36 42.518 W 14-44A Poly 9019.50 -9302.35 -2652.72 5928520.00 672449.99 70 12 38.001 N 148 36 33.490 W -Polygon 1 9019.50 -7669.38 -3835.24 5930125.00 671229.99 70 12 54.057 N 148 37 7.839 W -Polygon 2 9019.50 -7479.52 -3610.76 5930320.00 671449.99 70 12 55.925 N 148 37 1.324 W -Polygon 3 9019.50 -9094.25 -2567.86 5928730.00 672529.99 70 12 40.048 N 148 36 31.029 W -Polygon 4 9019.50 -9302.35 -2652.71 5928520.00 672449.99 70 12 38.001 N 148 36 33.490 W ) BP KW A Planning Report MAP ) Company: BP AmOco Field: Prudhoe Bay Site: PB OS 14 Well: 14-44 Wellpath: Plan t4~44A Targets Name Description Dip. Dir. 14-44A T1b 9024.50 -7543.81 -3642.26 5930255.00 671419.99 70 12 55.293 N 148 37 2.238 W 14-44A T2b 9029.50 -7770.39 -3577.50 5930030.00 671489.99 70 12 53.064 N 148 37 0.354 W 14-44A T5a 9034.50 -9121.69 -2678.54 5928700.00 672419.99 70 12 39.778 N 148 36 34.241 W Plan Section Information MD Incl Azhn TVD +N/-S +E/-W IlLS Build Turn TFO ft deg deg ft ft ft degl1 OOftdeg/10Oft . deg/tOOft deg 11650.00 54.99 207.77 8460.74 -6101.78 -3205.63 0.00 0.00 0.00 0.00 11670.00 57.08 206.34 8471.91 -6116.55 -3213.18 12.00 10.43 -7.15 -30.00 12034.36 69.89 198.55 8634.45 -6417.40 -3336.12 4.00 3.52 -2.14 -30.38 12976.96 69.89 198.55 8958.53 -7256.54 -3617.75 0.00 0.00 0.00 0.00 13276.12 85.00 172.00 9024.50 -7543.81 -3642.26 10.00 5.05 -8.88 -63.24 14-44A T1b 13317.67 88.61 169.95 9026.81 -7584.78 -3635.76 10.00 8.70 -4.94 -29.63 13343.08 88.61 169.95 9027.43 -7609.79 -3631.32 0.00 0.00 0.00 0.00 13513.10 90.00 153.00 9029.50 -7770.39 -3577.50 10.00 0.82 -9.97 -85.46 14-44A T2b 13703.20 90.87 145.45 9028.05 -7933.60 -3480.30 4.00 0.46 -3.97 -83.40 14573.27 90.87 145.45 9014.82 -8650.09 -2986.86 0.00 0.00 0.00 0.00 14615.22 90.00 146.88 9014.50 -8684.94 -2963.50 4.00 -2.08 3.42 121.28 14-44A T3b 14673.37 87.67 146.88 9015.68 -8733.62 -2931.74 4.00 -4.00 -0.01 -179.92 15137.12 87.67 146.88 9034.50 -9121.69 -2678.54 0.00 0.00 0.00 0.00 14-44A T5a Survey MD Incl Azim TVD Sys TVD ft deg deg ft ft 11650.00 54.99 207.77 8460.74 8391.24 5931706.68 671823.03 6757.76 0.00 Start Dir 12/100': 11650' MD. 11670.00 57.08 206.34 8471.91 8402.41 5931691.74 671815.84 6774.06 12.00 Start Dir 4/100' : 11670' MD. 11700.00 58.11 205.63 8487.99 8418.49 5931668.72 671805.27 6799.03 4.00 MWD 11800.00 61.60 203.35 8538.21 8468.71 5931589.23 671771.30 6884.62 4.00 MWD 11868.47 64.00 201.88 8569.50 8500.00 5931532.50 671749.20 6945.15 4.00 TJC 11900.00 65.12 201.23 8583.05 8513.55 5931505.78 671739.36 6973.51 4.00 MWD 12000.00 68.67 199.22 8622.29 8552.79 5931418.78 671709.60 7065.26 4.00 MWD 12034.36 69.89 198.55 8634.45 8564.95 5931388.14 671699.91 7097.36 4.00 End Dir : 12034.36' MD. 8634. 12100.00 69.89 198.55 8657.02 8587.52 5931329.27 671681.66 7158.96 0.00 MWD 12200.00 69.89 198.55 8691.40 8621.90 5931239.58 671653.85 7252.79 0.00 MWD 12300.00 69.89 198.55 8725.78 8656.28 5931149.90 671626.05 7346.63 0.00 MWD 12383.54 69.89 198.55 8754.50 8685.00 5931074.98 671602.82 7425.01 0.00 TJB 12400.00 69.89 198.55 8760.16 8690.66 5931060.21 671598.25 7440.46 0.00 MWD 12500.00 69.89 198.55 8794.54 8725.04 5930970.52 671570.44 7534.30 0.00 MWD 12600.00 69.89 198.55 8828.92 8759.42 5930880.84 671542.64 7628.13 0.00 MWD 12674.39 69.89 198.55 8854.50 8785.00 5930814.12 671521.96 7697.94 0.00 TJA 12700.00 69.89 198.55 8863.31 8793.81 5930791.15 671514.84 7721.97 0.00 MWD 12800.00 69.89 198.55 8897.69 8828.19 5930701.46 671487.03 7815.80 0.00 MWD 12900.00 69.89 198.55 8932.07 8862.57 5930611.78 671459.23 7909.64 0.00 MWD 12921.61 69.89 198.55 8939.50 8870.00 5930592.39 671453.22 7929.92 0.00 TSag 12936.16 69.89 198.55 8944.50 8875.00 5930579.35 671449.18 7943.57 0.00 51/2" 12965.24 69.89 198.55 8954.50 8885.00 5930553.26 671441.09 7970.86 0.00 TSHU 12976.96 69.89 198.55 8958.53 8889.03 5930542.75 671437.83 7981.86 0.00 Start Dir 10/100' : 12976.96' 13000.00 70.94 196.38 8966.25 8896.75 5930521.90 671431.80 8003.56 10.00 MWD 13050.00 73.30 191.75 8981.61 8912.11 5930475.51 671421.33 8051.08 10.00 MWD 13100.00 75.77 187.23 8994.94 8925.44 5930427.82 671414.51 8098.91 10.00 MWD 13150.00 78.32 182.82 9006.16 8936.66 5930379.22 671411.38 8146.67 10.00 MWD 13200.00 80.93 178.48 9015.17 8945.67 5930330.06 671411.97 8193.99 10.00 MWD Company: BP Amoco Field: Prudhoe Bay Site: PBDS14 Well: 14-44 WeUpath: Plan t4~44A Survey MD loci Azim ft d~g deg 13230.10 82.53 175.91 13250.00 83.59 174.21 13276.12 85.00 172.00 13300.00 87.08 170.82 13317.67 88.61 169.95 13343.08 88.61 169.95 13350.00 88.67 169.26 13400.00 89.07 164.27 13450.00 89.48 159.29 13500.00 89.89 154.31 13513.10 90.00 153.00 13600.00 90.40 149.55 13703.20 90.87 145.45 13800.00 90.87 145.45 13900.00 90.87 145.45 14000.00 90.87 145.45 14100.00 90.87 145.45 14200.00 90.87 145.45 14300.00 90.87 145.45 14400.00 90.87 145.45 14500.00 90.87 145.45 14573.27 90.87 145.45 14600.00 90.32 146.36 14615.22 90.00 146.88 14673.37 87.67 146.88 14700.00 87.67 146.88 14800.00 87.67 146.88 14900.00 87.67 146.88 15000.00 87.67 146.88 15100.00 87.67 146.88 15137.12 87.67 146.88 ) ') BP KW A Planning Report MAP Date: 8/26/2002 Time: 10:54:37 Co-ordinate(NE) Reference: Well: 14;'44, True North Ve~al'(TVD)Ref~renee: 69.5,69.5 $eetio~(VS)Referençe: W~U(O.OON.O.OOE, 19ß.36Azi) S..ryey C~leulatiønMethod: Minimum Curvatur~ Db: Oracle Page: 3 TVD Sys TVD MapN MapE VS DLS Tool/Comment ft ft ft ft ft degl1000 9019.50 8950.00 5930300.35 671414.12 8222.13 10.00 TSADITZ4B 9021.90 8952.40 5930280.72 671416.27 8240.53 10.00 MWD 9024.50 8955.00 5930255.00 671419.99 8264.40 10.00 14-44A T1b 9026.15 8956.65 5930231.54 671424.09 8286.00 10.00 MWD 9026.81 8957.31 5930214.20 671427.45 8301.87 10.00 End Dir : 13317.67' MD, 9026. 9027.43 8957.93 5930189.30 671432.46 8324.63 0.00 Start Dir 10/100' : 13343.08' 9027.59 8958.09 5930182.53 671433.87 8330.80 10.00 MWD 9028.58 8959.08 5930134.16 671446.43 8374.25 10.00 MWD 9029.21 8959.71 5930087.07 671463.15 8415.40 10.00 MWD 9029.49 8959.99 5930041.60 671483.91 8453.93 10.00 MWD 9029.50 8960.00 5930030.00 671489.99 8463.55 10.00 14-44A T2b 9029.20 8959.70 5929954.80 671533.50 8524.89 4.00 MWD 9028.05 8958.55 5929869.10 671590.94 8592.76 4.00 End Dir : 13703.2' MD, 9028.0 9026.58 8957.08 5929790.69 671647.67 8653.78 0.00 MWD 9025.06 8955.56 5929709.69 671706.27 8716.81 0.00 MWD 9023.54 8954.04 5929628.68 671764.88 8779.85 0.00 MWD 9022.02 8952.52 5929547.67 671823.48 8842.88 0.00 MWD 9020.50 8951.00 5929466.67 671882.08 8905.92 0.00 MWD 9018.98 8949.48 5929385.66 671940.69 8968.95 0.00 MWD 9017.45 8947.95 5929304.65 671999.29 9031.99 0.00 MWD 9015.93 8946.43 5929223.65 672057.89 9095.02 0.00 MWD 9014.82 8945.32 5929164.30 672100.83 9141.20 0.00 Start Dir 4/100' : 14573.27' M 9014.54 8945.04 5929142.51 672116.32 9158.22 4.00 MWD 9014.50 8945.00 5929130.00 672124.99 9168.06 4.00 14-44A T3b 9015.68 8946.18 5929082.07 672157.87 9205.82 4.00 End Dir : 14673.37' MD, 9015. 9016.76 8947.26 5929060.13 672172.92 9223.11 0.00 MWD 9020.82 8951.32 5928977.74 672229.44 9288.01 0.00 MWD 9024.88 8955.38 5928895.35 672285.97 9352.92 0.00 MWD 9028.94 8959.44 5928812.97 672342.49 9417.83 0.00 MWD 9032.99 8963.49 5928730.58 672399.01 9482.74 0.00 MWD 9034.50 8965.00 5928700.00 672419.99 9506.83 0.00 14-44A T5a Nail): 14-44 -171332 -160 -150 -125 -100 -75 -50 -25 -0 270 -25 -50 -75 -100 -125 -150 -160 WI] L DEIAII,S ANTI-COLLISION SETTINGS COMPANY DETA[LS 'N.S 'F.'-W hJ:illllg I-alitu{~ l.ollg:itud~ Slot BP AmtKO Nt\fthing Interpolation Method:MD Interval: 25,00 Depth Range From: 11650.00 To: 15137.12 Maximum Range: 1710.86 Reference: Pian: 14-44A wp06 Calculation Method: Minimum Curvature Error S\'stem: lSeWSA Scan f\.lethod: TmvCylínœr North Error S\lrfuc~: Elliptical..;- Casing Waming Mcthod: Rules Based 69(',26 59378'8'0.7(, 6748S6,OY 7("14'09.495N [48".J5'1(,,49IW 44 From 0 300 600 900 1200 1500 2000 2500 3000 3500 4000 4500 5000 0 6000 8000 11000 12000 SURVEY PROGRAM [)¿plh F111 Depth To Survey/Vlan T<.1ol 11650,00 15137,12 Plall""d: 14-44A wp06 V8' MWD WELLPA TH DETAILS Colour Plan 14-44.~ ToMD 300 600 900 1200 1500 2000 2500 3000 3500 4000 4500 5000 6000 8000 11000 12000 15000 Parent We1lpath: ne:- ou MD: 14-44 11650,00 Rig: ¡~[ Datum: 695 695011 Oriuin ~N:,S Origin ~Fj.\v Starting: From TVD V .Se~ti<.1n Angle 196.360 0,00 0,00 0,00 LEGlòND - 14-44 (14-44). NOERRORS 14-44PBl (l4-44PBI). NOERRORS - Plan 14-44A - 1444A "¡>O6 --....J 90 ~ SECTION DETAil,S See 1\10 Inc Azi IVD TNI-S ,¡Y-W DLeg fFace vSec Target 11650.00 54,99 207.77 8460.74 -6101.78 .3205.63 0,00 0,00 6757.76 11670,00 57.08 206.34 8471.91 -611655 -3213.[8 12,00 -30.00 6774.06 12034.36 69.89 19855 8634.45 -64[7.40 -3336, [2 4,00 -30.38 7097.36 4 12976.96 69.89 19855 895853 -725654 ,36[7.75 0,00 0.00 7981.86 < 13276,12 85.(() [72.(() 902450 .7543,81 -3642,26 IO,(() -6324 8264.40 14-44A Tlb 6 133[7.67 88,61 169,95 9026.81 .7584.78 -3635.76 1°,(() -29,63 8301.87 7 13343,08 88.61 [69.95 9027.43 .7(fJ9,79 -3631.32 0,00 o.(() 8324.63 8 13513.10 90.00 [53.(() 902950 -7770.39 -357750 10,00 -85.46 846355 14-44A 12b 9 1370320 90.87 [45.45 9028.05 -7933,(fJ -3480.30 4,00 -83.40 8592.76 10 1457327 90.87 [45.45 9014.82 -8650,09 ,2986,86 0,00 0,00 9141.20 II 146[522 9O.(() [46.88 9014.50 -8684.94 -2963.50 4,00 [2[28 9 [68.06 [4-44A 1'3b [2 14673.37 87.67 [46.88 9015,68 -8733.62 -2931.74 4,00 -179,92 9205,82 13 15137.12 87,67 [46.88 9034.50 -9121.69 -267854 0,00 0,00 9506,83 [4-44A T5a Travelling Cylinder SURVEY PROGRAM COMPANY DETAILS ANTI-COLLISION SETTINGS W¡:U, DE'I All,S Depth Fm Depth To SurvcyiPJan 11650.00 15137,12 Plann,-~1: 14-44A "p06 V8 Toot BP Amoc\) Long.itude Slt)1 Latitude ';Isting I':-W Nt\l1hing N-S N.-tllto: Interpolation Method:MD Interval: 100.00 Depth Range From: 28.50 To: 15137.12 Maximum Range: 1710.86 Reference: Plan: 14-44A wp06 MWD Cakulation Method: Minimum Curvature Em1r Svstem: ISCWSA Scan fllethod: lra\' Cylinder North Error Surface: Ellipticãl -.;.- Casing Warning M~thl..1d: Rules Based 674886,IW 71n4'09,495N 148°.15'16.49IW 44 :\I)H8Sfl.76 ()1){¡.26 14-44 .171.1..12 WEl.LPATH DETAilS Plan I4-44A Par.~nt W~llpath: Tic 011 MD: 14-44 11650,on 100 90 80 70 60 50 I I Rig: Ref Datum: 69.500 69.5 Starting From TVD V -Section Angle Orig"l ~Ni.S Origin ,IY.W 0,00 0.00 196.360 0,00 LEGEND - 14-44 (14-44). NOERRORS ~~- 14-44PBI (l4-44PBI). NOERRORS - Plan 14-44A - 14-44A "p06 '"2 ~ 0 N L...-.J s::: .S ~ \-; cd 0... () r:/1 ~ ~ () U 0 +-> ~ +-> s::: () U ......,; í 1 1- EqJivalent M::.gMt"c Dista:1ce r;--- J Ii 20 I ' t KOP 11650' MD -~ from 14-44. 10 7-7 --/ -- -Î 0 =~r-- 11750 12000 12250 12500 12750 13000 13250 13500 13750 14000 14250 14500 14750 15000 15250 15500 40 30 ~~ Measured Depth [500ft/in] SECTION DETAILS See MD 1nc Azi ND +Nf.s >Fl.W DLeg TFace 1 11650.00 54.99 207.77 8460.74 -6101.78 -3205.63 0.00 0,00 2 11670,on 57.08 20634 8471.91 -6116.55 -3213.18 12,00 .30,00 3 12034.36 69.89 19855 8634,45 -6417,40 -3.136,12 4.on .30.38 4 12976,96 69.89 198,55 895853 -7256.54 -3617.75 0,00 0,00 5 13276,12 85.0() 172,00 9024.50 -7543,81 -3642,26 10.00 -6324 6 13317,67 88.61 169,95 9026,81 -7584,78 -3635,76 10.00 .29,63 7 13343.08 88.61 169,95 9027.43 ,7609.79 -363132 0.00 0,00 8 135 I.1,1O 90.00 153,00 9029.50 -7770..19 .357750 10,00 .85,46 9 1370.1.20 90.87 145.45 9028,05 .7933.60 -3480.30 4,00 -83.40 10 1457.1,27 90.87 145,45 9014,82 .8650.09 .2986,86 0.00 0,00 II 1461522 90.on 146,88 9014.50 -8684,94 -2963.50 4.00 12128 12 1467..137 87.67 146,88 9015,68 -87.13.62 -2931.74 4,00 .179.92 I.1 15137.12 87.67 146,88 903450 -9121.69 -2678.54 0,00 0.00 VSCC Targ" 6757.76 6774,06 7CW7.36 7981.86 8264,40 14-44.'1. Tlb 8301.87 8324,6.1 846355 14-44A T2b 8592,76 9141.20 9168,06 14-44.'1. T3b 9205.82 9506,83 14-44A T5a ') BP Anticollision Report GLOBAL SCAN APPLIED: All wellpaths within 200'+ 100/1000 of reference - There artRH8iÐè...ells in thli~al Plan & PLANNED PROGRAM Interpolation Method: MD Interval: 25.00 ft Error Model: ISCWSA Ellipse Depth Range: 11650.00 to 15137.12 ft Scan Method: Trav Cylinder North Maximum Radius: 1710.86 ft Error Surface: Ellipse + Casing Survey Program for Definitive Wellpath Date: 8/16/2002 Validated: No Planned From To Survey ft ft 71.50 11650.00 11650.00 15137.12 Version: Toolcode Tool Name 1 : Schlumberger GCT multishot Planned: 14-44A wp06 V8 GCT -MS MWD Schlumberger GCT multishot MWD - Standard Casing Points MD ft 12936.16 15137.11 TVD Diameter Hole Size Name ft in in 8944.50 5.500 6.750 51/2" 9034.50 3.500 4.750 3 1/2" Summary <- Site Offset Wellpath -----------> Well Wellpath PB OS 14 PB OS 14 14-44 14-44PB1 14-44 V2 14-44PB 1 V3 11698.42 11700.00 11698.42 11700.00 2.09 352.50 -264.21 FAIL: Major Risk 2.09 352.50 -264.35 FAIL: Major Risk Site: PB OS 14 Well: 14-44 Rule Assigned: Major Risk Wellpath: 14-44 V2 Inter-Site Error: 0.00 ft Reference Offset Semi-lVIaj9f Mis Ctr.;Ctr,No-GO Allowable MD TVD MD TVD Ref Offset TF()+AZr TFO-HSCasiltg Dist-.mce ,. Area Deviation Warfting ft ft ft ft ft ft deg deg in ft ft ft 11673.48 8473.80 11675.00 8475.76 53.03 53.15 -0.10 153.64 0.61 352.00 -259.88 FAIL 11698.42 8487.15 11700.00 8490.20 53.02 53.30 356.67 151.01 2.09 352.50 -264.21 FAIL 11723.29 8500.15 11725.00 8504.69 53.00 53.44 356.47 151.39 4.05 353.00 -261.93 FAIL 11748.07 8512.78 11749.99 8519.24 52.98 53.57 357.21 152.70 6.46 353.45 -257.18 FAIL 11772.77 8525.06 11775.00 8533.86 52.97 53.73 357.42 153.47 9.36 353.96 -253.08 FAIL 11797.37 8536.95 11800.00 8548.47 52.95 53.87 357.76 154.35 12.65 354.43 -248.29 FAIL 11821.88 8548.49 11825.00 8562.94 52.93 54.03 358.03 155.15 16.11 354.97 -243.35 FAIL 11846.30 8559.65 11850.00 8577.33 52.91 54.16 358.43 156.08 19.83 355.42 -237.78 FAIL 11870.55 8570.41 11875.00 8591.85 52.89 54.28 358.41 156.57 24.16 355.79 -232.38 FAIL 11894.62 8580.77 11900.00 8606.47 52.87 54.39 358.20 156.87 29.05 356.18 -226.78 FAIL 11918.51 8590.74 11925.00 8621.19 52.85 54.50 358.14 157.29 34.41 356.59 -220.29 FAIL 11942.19 8600.30 11950.00 8635.99 52.83 54.61 357.94 157.57 40.30 356.95 -213.49 FAIL 11965.69 8609.47 11975.00 8650.73 52.81 54.74 357.56 157.66 46.55 357.39 -206.76 FAIL 11989.01 8618.26 12000.00 8665.33 52.79 54.88 356.96 157.52 53.09 357.83 -200.20 FAIL 12012.13 8626.66 12025.00 8679.85 52.77 55.01 356.30 157.31 59.96 358.27 -193.35 FAIL 12035.06 8634.69 12050.00 8694.41 52.75 55.11 355.72 157.17 67.27 358.64 -185.81 FAIL 12058.89 8642.88 12075.00 8709.00 52.78 55.27 355.46 156.91 74.80 359.22 -179.15 FAIL 12082.71 8651.07 12100.00 8723.67 52.82 55.42 355.33 156.77 82.39 359.80 -172.16 FAIL 12106.51 8659.25 12125.00 8738.43 52.85 55.57 355.29 156.74 90.04 360.42 -164.89 FAIL 12130.30 8667.43 12150.00 8753.25 52.89 55.73 355.28 156.73 97.74 361.02 -157.54 FAIL 12154.10 8675.61 12175.00 8768.04 52.93 55.91 355.28 156.73 105.40 361.68 -150.26 FAIL 12177.97 8683.82 12200.00 8782.61 52.97 56.11 355.22 156.67 112.83 362.38 -143.39 FAIL 12201.87 8692.04 12225.00 8797.06 53.01 56.30 355.12 156.57 120.15 363.15 -136.73 FAIL 12225.78 8700.26 12250.00 8811.45 53.06 56.48 354.97 156.42 127.46 363.84 -130.15 FAIL 12249.75 8708.50 12275.00 8825.61 53.11 56.68 354.78 156.22 134.53 364.58 -123.97 FAIL 12273.82 8716.78 12300.00 8839.42 53.16 56.88 354.52 155.97 141.25 365.33 -118.27 FAIL 112297.96 8725.08 12325.00 8852.93 53.21 57.08 354.19 155.63 147.71 366.06 -112.99 FAIL ) ') BP Anticollision Report ç()tnpany: BP Arnoco Field: PrudhoéBay Reference . Site: PB OS 14 Reference Well: 14-44 ReferenceWellpath: ,Plan 14-44A Site: PB OS 14 Well: 14-44 Rule Assigned: Major Risk Well path: 14-44 V2 Inter-Site Error: 0.00 ft Reference MD TVD ft ft 12322.08 8733.37 12350.00 8866.39 53.26 57.27 353.82 155.27 154.20 366.88 -107.79 FAIL 12346.19 8741.66 12375.00 8879.82 53.32 57.46 353.44 154.89 160.73 367.63 -102.58 FAIL 12370.28 8749.94 12400.00 8893.23 53.38 57.66 353.04 154.48 167.31 368.37 -97.38 FAIL 12394.36 8758.22 12425.00 8906.63 53.43 57.78 352.63 154.08 173.94 368.45 -91.18 FAIL 12418.42 8766.49 12450.00 8920.09 53.50 57.87 352.28 153.73 180.64 368.34 -84.46 FAIL 12442.47 8774.76 12475.00 8933.63 53.56 57.96 351.97 153.42 187.39 368.16 -77.56 FAIL 12466.51 8783.03 12500.00 8947.22 53.63 58.05 351.71 153.16 194.18 368.51 -70.78 FAIL 12490.82 8791.38 12525.00 8960.02 53.69 58.05 351.45 152.89 199.95 368.72 -65.71 FAIL 12515.48 8799.86 12550.00 8971.23 53.76 58.05 351.11 152.56 203.83 368.89 -62.72 FAIL 12540.34 8808.41 12575.00 8980.83 53.84 58.06 350.69 152.14 205.88 369.14 -61.76 FAIL 12565.27 8816.98 12600.00 8989.20 53.92 58.07 350.21 151.66 206.55 369.41 -62.34 FAIL 12590.20 8825.55 12625.00 8996.74 53.99 58.08 349.67 151.12 206.38 369.68 -63.93 FAIL 12615.11 8834.12 12650.00 9003.65 54.07 58.09 349.19 150.64 205.31 369.91 -66.28 FAIL 12640.01 8842.68 12675.00 9010.10 54.16 58.11 348.85 150.30 203.42 370.23 -69.14 FAIL 12664.90 8851.24 12700.00 9016.45 54.24 58.12 348.60 150.04 201.22 370.54 -72.09 FAIL 12689.80 8859.80 12725.00 9022.97 54.32 58.14 348.34 149.79 199.22 370.86 -74.84 FAIL 12714.67 8868.35 12750.00 9029.18 54.41 58.15 348.01 149.46 197.00 371.13 -78.02 FAIL 12739.41 8876.86 12775.00 9034.35 54.50 58.17 347.37 148.82 194.17 371.48 -82.59 FAIL 12763.93 8885.28 12800.00 9038.25 54.59 58.19 346.42 147.87 190.48 371.83 -88.84 FAIL 12788.08 8893.59 12825.00 9040.56 54.68 58.22 345.19 146.64 185.48 372.20 -97.11 FAIL 12811.78 8901.74 12850.00 9041.24 54.78 58.25 343.74 145.18 179.00 372.51 -107.47 FAIL 12835.29 8909.82 12875.00 9041.33 54.87 58.28 342.13 143.57 172.07 372.91 -118.71 FAIL 12858.70 8917.87 12900.00 9041.15 54.96 58.31 340.34 141.79 165.05 373.32 -130.50 FAIL 12882.06 8925.90 12925.03 9040.74 55.06 58.35 338.36 139.80 158.02 373.72 -142.82 FAIL 12905.30 8933.89 12950.00 9040.17 55.15 58.38 336.16 137.61 151.07 374.09 -155.56 FAIL 12928.54 8941.88 12975.00 9039.49 55.25 58.42 333.75 135.19 144.25 374.53 -168.66 FAIL 12951.75 8949.86 13000.00 9038.76 55.35 58.46 331.08 132.52 137.70 374.96 -181.98 FAIL 12975.08 8957.88 13025.00 9038.34 55.45 58.49 328.26 129.71 131.60 375.39 -194.99 FAIL 12994.68 8964.51 13050.00 9038.26 55.32 58.28 324.19 127.31 126.31 374.19 -204.70 FAIL 13014.16 8970.80 13075.00 9038.29 55.11 58.00 319.73 124.68 122.22 372.69 -213.02 FAIL 13033.76 8976.84 13100.00 9038.21 54.87 57.69 314.98 121.74 119.31 371.06 -220.15 FAIL 13050.00 8981.61 13125.00 9038.01 54.67 57.41 310.25 118.51 117.56 369.60 -226.40 FAIL 13073.19 8988.05 13150.00 9037.63 54.28 56.93 304.96 115.33 116.69 367.05 -229.66 FAIL 13093.06 8993.22 13175.00 9037.50 53.94 56.49 300.04 112.19 117.05 364.75 -231.33 FAIL 13113.03 8998.07 13200.00 9037.86 53.55 56.00 295.44 109.36 118.78 362.05 -230.27 FAIL 13133.00 9002.59 13225.00 9038.57 53.13 55.48 291.17 106.86 121.78 359.26 -226.91 FAIL 13150.00 9006.16 13250.00 9039.27 52.78 55.03 287.35 104.54 125.80 356.72 -222.52 FAIL 13172.63 9010.52 13275.00 9039.88 52.23 54.38 283.39 102.54 130.50 353.09 -215.42 FAIL 13192.19 9013.91 13300.00 9040.39 51.76 53.81 279.87 100.71 136.22 349.86 -207.54 FAIL 13211.53 9016.93 13325.00 9040.77 51.27 53.23 276.60 99.10 142.74 346.35 -198.44 FAIL 13230.59 9019.56 13350.00 9041.03 50.77 52.64 273.57 97.71 150.14 342.85 -188.14 FAIL 13250.00 9021.90 13375.00 9041.22 50.26 52.04 270.74 96.53 158.53 339.73 -176.51 FAIL 13267.71 9023.73 13400.00 9041.43 49.79 51.49 268.28 95.57 167.53 336.86 -164.33 FAIL 13286.61 9025.33 13425.00 9042.04 49.45 51.08 266.42 94.94 177.23 334.81 -151.80 FAIL 13305.89 9026.42 13450.00 9042.78 49.27 50.83 265.07 94.55 187.52 333.59 -139.18 FAIL 13326.27 9027.02 13475.00 9043.47 49.22 50.72 264.27 94.33 198.24 333.04 -127.28 FAIL 13347.30 9027.53 13500.00 9044.11 49.17 50.59 263.67 94.14 208.99 332.52 -116.03 FAIL 13363.54 9027.89 13525.00 9044.70 48.55 49.94 261.89 93.99 220.22 328.55 -100.43 FAIL 13379.33 9028.21 13550.00 9045.24 47.95 49.30 260.17 93.84 232.04 324.71 -84.22 FAIL 13400.00 9028.58 13575.00 9045.70 47.17 48.43 257.97 93.69 244.36 319.54 -65.96 FAIL 13409.56 9028.73 13600.00 9045.96 46.79 48.06 256.83 93.51 257.28 317.19 -50.54 FAIL ') ) BP Anticollision Report çOlnpany: BP Amoc:o Field: Prudhoe. Bay Referençe Site: PBDS14 Reference Well: 1444 Reference WeUpath: Plan 14-44A Site: PB OS 14 Well: 14-44 Rule Assigned: Major Risk Well path: 14-44 V2 Inter-Site Error: 0.00 ft Reference MD TV)) ft ft 13423.82 9028.93 13625.00 9046.01 46.24 47.47 255.19 93.30 271.07 313.56 -32.57 FAIL 13437.69 9029.09 13650.00 9045.94 45.69 46.90 253.60 93.09 285.20 310.45 -14.36 FAIL 13450.00 9029.21 13675.00 9045.78 45.21 46.41 252.17 92.88 299.73 307.87 3.56 Pass 13464.21 9029.33 13700.00 9045.46 44.65 45.84 250.54 92.67 314.58 304.63 22.74 Pass 13476.86 9029.41 13725.00 9044.95 44.16 45.34 249.05 92.44 329.83 301.70 41.81 Pass 13489.05 9029.46 13750.00 9044.34 43.69 44.86 247.62 92.22 345.59 298.83 61.28 Pass 13500.00 9029.49 13775.00 9043.72 43.26 44.44 246.32 92.02 361.91 296.27 80.89 Pass 13513.10 9029.50 13800.00 9043.08 42.77 43.94 244.83 91.83 378.62 293.13 101.73 Pass 13526.22 9029.49 13825.00 9042.44 42.62 43.78 244.14 91.66 395.44 292.50 119.41 Pass 13540.50 9029.47 13850.00 9041.78 42.46 43.60 243.41 91.50 412.44 291.37 137.86 Pass 13554.43 9029.43 13875.00 9041.23 42.31 43.42 242.73 91.37 429.75 290.25 156.62 Pass 13568.07 9029.38 13900.00 9041.36 42.16 43.25 242.16 91.34 447.31 289.15 175.74 Pass 13581.50 9029.31 13925.00 9041.96 42.01 43.08 241.66 91.37 464.97 288.05 195.03 Pass 13600.00 9029.20 13950.00 9042.85 41.80 42.84 240.98 91.44 482.89 286.50 215.28 Pass 13600.00 9029.20 13975.00 9043.65 41.80 42.89 241.04 91.49 501.20 287.10 233.00 Pass 13619.77 9029.04 14000.00 9044.28 41.61 42.64 240.28 91.51 519.61 285.78 253.78 Pass 13632.00 9028.93 14025.00 9044.87 41.49 42.51 239.81 91.54 538.18 285.07 273.76 Pass 13644.07 9028.81 14050.00 9045.68 41.37 42.37 239.38 91.58 556.81 284.37 293.84 Pass 13656.03 9028.68 14075.00 9046.75 41.25 42.24 238.97 91.65 575.43 283.66 313.95 Pass 13667.82 9028.54 14100.00 9048.07 41.13 42.12 238.59 91.74 594.11 282.97 334.13 Pass 13679.37 9028.39 14125.00 9049.54 41.02 42.00 238.23 91.84 612.95 282.28 354.45 Pass 13703.20 9028.05 14150.00 9051.03 40.78 41.71 237.37 91.92 632.33 280.75 376.90 Pass 13703.20 9028.05 14175.00 9052.56 40.78 41.75 237.46 92.02 651.96 280.86 396.53 Pass 13714.89 9027.87 14200.00 9053.91 40.85 41.80 237.54 92.09 672.05 281.58 415.83 Pass 13729.73 9027.65 14225.00 9055.17 40.94 41.85 237.60 92.15 692.16 281.95 435.52 Pass 13744.63 9027.42 14250.00 9056.44 41.03 41.90 237.66 92.21 712.22 282.32 455.17 Pass 13759.60 9027.19 14275.00 9057.71 41.12 41.95 237.72 92.27 732.23 282.69 474.74 Pass 13774.74 9026.96 14300.00 9058.86 41.21 42.00 237.76 92.32 752.11 283.06 494.18 Pass 13789.69 9026.74 14325.00 9059.86 41.30 42.05 237.79 92.35 772.15 283.43 513.74 Pass 13804.52 9026.51 14350.00 9060.79 41.39 42.10 237.82 92.37 792.27 284.24 532.88 Pass 13819.21 9026.29 14375.00 9061.63 41.49 42.15 237.83 92.39 812.50 284.63 552.58 Pass 13833.80 9026.07 14400.00 9062.35 41.58 42.20 237.84 92.39 832.80 285.03 572.35 Pass 13848.39 9025.84 14425.00 9062.99 41.68 42.26 237.84 92.40 853.10 285.42 592.11 Pass 13862.94 9025.62 14450.00 9063.80 41.77 42.31 237.85 92.41 873.43 285.80 611.91 Pass 13877.51 9025.40 14475.00 9064.77 41.87 42.35 237.87 92.43 893.74 286.18 631.74 Pass 13892.10 9025.18 14500.00 9065.84 41.97 42.40 237.90 92.46 914.04 286.56 651.54 Pass 13906.61 9024.96 14525.00 9066.78 42.07 42.46 237.92 92.47 934.39 287.40 670.87 Pass 13920.94 9024.74 14550.00 9067.27 42.17 42.51 237.91 92.46 954.88 287.81 690.76 Pass 13935.26 9024.52 14575.00 9067.29 42.27 42.57 237.87 92.42 975.36 288.23 710.60 Pass 13949.35 9024.31 14600.00 9067.17 42.37 42.60 237.83 92.38 996.00 292.53 726.20 Pass 13963.41 9024.09 14625.00 9067.04 42.47 42.62 237.78 92.34 1016.65 298.59 739.86 Pass 13970.73 9023.98 14638.00 9066.98 42.52 42.62 237.76 92.32 1027.39 301.97 746.97 Pass Site: PB OS 14 Well: 14-44PB 1 Rule Assigned: Major Risk Wellpath: 1444PB 1 V3 Inter-Site Error: 0.00 ft Reference Offset Semi-Major Axis Ctr-Ctr No-Go Allowable MD TVD MD TVD Ref Offset TFO+AZI TFO-HS Casing Distance Area Deviation Warning ft ft ft ft ft ft deg deg in ft ft ft 11673.48 8473.80 11675.00 8475.76 53.03 53.16 -0.33 153.41 0.61 352.00 -260.33 FAIL 11698.42 8487.15 11700.00 8490.20 53.02 53.30 356.61 150.95 2.09 352.50 -264.35 FAIL 11723.29 8500.15 11725.00 8504.69 53.00 53.44 356.44 151.35 4.05 353.00 -262.00 FAIL ~ ) ") BP Anticollision Report Company: BP Amoco Field: Prudhoe Bay Reference Site: £.OB DS14 Reference Well: 14-44 Reference, Wellpath:Plan ,14-44A Site: PB OS 14 Well: 14-44PB 1 Rule Assigned: Major Risk Wellpath: 14-44PB 1 V3 Inter-Site Error: 0.00 ft Reference MD TVD ft 11748.07 8512.79 11749.99 8519.24 52.98 53.58 357.19 152.67 6.46 353.45 -257.22 FAIL 11772.77 8525.06 11775.00 8533.86 52.97 53.73 357.41 153.45 9.36 353.96 -253.11 FAIL 11797.37 8536.95 11800.00 8548.47 52.95 53.87 357.75 154.33 12.65 354.44 -248.32 FAIL 11821.88 8548.49 11825.00 8562.94 52.93 54.03 358.02 155.15 16.11 354.98 -243.37 FAIL 11846.30 8559.65 11850.00 8577.33 52.91 54.16 358.43 156.07 19.83 355.42 -237.79 FAIL 11870.55 8570.41 11875.00 8591.85 52.89 54.28 358.41 156.56 24.16 355.79 -232.40 FAIL 11894.62 8580.77 11900.00 8606.47 52.87 54.39 358.20 156.86 29.05 356.18 -226.79 FAIL 11918.51 8590.74 11925.00 8621.19 52.85 54.50 358.13 157.28 34.41 356.59 -220.30 FAIL 11942.19 8600.30 11950.00 8635.99 52.83 54.61 357.94 157.57 40.30 356.95 -213.50 FAIL 11965.69 8609.4 7 11975.00 8650.73 52.81 54.75 357.56 157.66 46.55 357.39 -206.77 FAIL 11989.01 8618.26 12000.00 8665.33 52.79 54.88 356.96 157.52 53.09 357.83 -200.21 FAIL 12012.13 8626.66 12025.00 8679.85 52.77 55.01 356.29 157.31 59.97 35827 -193.36 FAIL 12035.06 8634.69 12050.00 8694.41 52.75 55.11 355.72 157.17 67.27 358.64 -185.81 FAIL 12058.89 8642.88 12075.00 8709.00 52.78 55.27 355.46 156.91 74.81 359.23 -179.15 FAIL 12082.71 8651.07 12100.00 8723.67 52.82 55.42 355.32 156.77 82.39 359.80 -172.16 FAIL 12106.51 8659.26 12125.00 8738.43 52.85 55.57 355.29 156.74 90.04 360.43 -164.90 FAIL 12130.30 8667.43 12150.00 8753.25 52.89 55.73 355.28 156.73 97.74 361.03 -157.54 FAIL 12154.10 8675.61 12175.00 8768.04 52.93 55.91 355.28 156.72 105.40 361.68 -150.26 FAIL 12177.97 8683.82 12200.00 8782.61 52.97 56.11 355.22 156.67 112.83 362.39 -143.39 FAIL 12201.87 8692.04 12225.00 8797.06 53.01 56.30 355.12 156.56 120.16 363.15 -136.74 FAIL 12225.78 8700.26 12250.00 8811.45 53.06 56.48 354.97 156.42 127.46 363.84 -130.16 FAIL 12249.75 8708.50 12275.00 8825.61 53.11 56.68 354.77 156.22 134.53 364.59 -123.97 FAIL 12273.82 8716.78 12300.00 8839.42 53.16 56.88 354.52 155.97 141.25 365.33 -118.27 FAIL 12297.96 8725.08 12325.00 8852.93 53.21 57.08 354.19 155.63 147.71 366.07 -113.00 FAIL 12322.08 8733.37 12350.00 8866.39 53.26 57.27 353.82 155.27 154.20 366.88 -107.80 FAIL 12346.19 8741.66 12375.00 8879.82 53.32 57.47 353.44 154.89 160.73 367.63 -102.59 FAIL 12370.28 8749.94 12400.00 8893.23 53.38 57.66 353.04 154.48 167.31 368.38 -97.38 FAIL 12394.36 8758.22 12425.00 8906.63 53.43 57.78 352.63 154.08 173.94 368.55 -91.35 FAIL 12418.42 8766.49 12450.00 8920.09 53.50 57.87 352.28 153.73 180.64 368.58 -84.87 FAIL 12442.47 8774.76 12475.00 8933.63 53.56 57.97 351.97 153.42 187.39 368.54 -78.20 FAIL 12466.51 8783.03 12500.00 8947.23 53.63 58.06 351.71 153.16 194.19 368.51 -71.38 FAIL 12490.54 8791.29 12525.00 8960.91 53.69 58.14 351.48 152.93 201.06 368.98 -64.70 FAIL 12514.54 8799.54 12550.00 8974.69 53.76 58.15 351.30 152.75 208.02 369.14 -58.27 FAIL 12538.51 8807.78 12575.00 8988.63 53.83 58.15 351.16 152.61 215.11 369.39 -51.60 FAIL 12562.44 8816.01 12600.00 9002.70 53.91 58.16 351.06 152.50 222.33 369.63 -44.73 FAIL 12586.34 8824.23 12625.00 9016.91 53.98 58.17 350.99 152.43 229.66 369.88 -37.65 FAIL 12610.21 8832.43 12650.00 9031.19 54.06 58.18 350.93 152.38 237.09 370.08 -30.46 FAIL 12634.05 8840.63 12675.00 9045.55 54.14 58.19 350.88 152.33 244.61 370.36 -23.18 FAIL 12657.86 8848.82 12700.00 9059.98 54.22 58.20 350.83 152.28 252.22 370.64 -15.79 FAIL 12681.66 8857.00 12725.00 9074.47 54.30 58.22 350.80 152.25 259.89 370.93 -8.31 FAIL 12705.45 8865.18 12750.00 9089.02 54.38 58.23 350.79 152.24 267.56 371.16 -0.77 FAIL 12729.24 8873.36 12775.00 9103.62 54.47 58.25 350.82 152.26 275.24 371.48 6.83 Pass 12753.03 8881.54 12800.00 9118.28 54.55 58.26 350.86 152.31 282.91 371.79 14.50 Pass 12776.82 8889.72 12825.00 9132.99 54.64 58.28 350.92 152.37 290.61 372.13 22.21 Pass 12800.59 8897.89 12850.00 9147.74 54.73 58.31 350.99 152.43 298.34 372.39 29.97 Pass 12824.35 8906.06 12875.00 9162.53 54.83 58.32 351.05 152.50 306.11 372.74 37.76 Pass 12848.10 8914.23 12900.00 9177.33 54.92 58.34 351.12 152.57 313.89 373.09 45.56 Pass i 12857.61 8917 .49 12910.00 9183.25 54.96 58.35 351.14 152.59 316.99 375.19 44.08 Pass . TREE = <, FMC WELLHEAD = CW U..........................,.'""""""',,,',,,,,,,,,,,,,,,',',.....,',',........,..,,,,,,'''.'''''''''''''''''''''''''''''''W''''.w.','....................w.........."...w..... ACTUATOR = BAKER C "^Ks:-ECEv -;-'-~'W"W^'W^.'-jF E~F~"^ËCË\r;-^'W^'W'"'W'W"wu==?, uKÕP~,"w""""w,w_u,w""w'^23:ri' 'Mãx7\:ngle",;","ww92"@T2987" 15ãtümMD;--'^"^--'~-12359ï Datum T\ï[:r;-~~ 8800' ss P. Jposed Pre-Rig 14L:>4 SðJÐY r\OTEB t-æzCNrAL V\Bl. 7CP @12f:ßS AN)OO> @12004' 110-3/4" CSG, 45.5#, NT-80-LHE, 10 = 9.953" l-i 3288' Minimum ID = 3.59" @ 5151' TIGHT SPOT LOGGED 06/16/00 Minimum ID = 3.55" @ 5151' Unable to swage 3.55" 07/01/00 Pre rig Tubing Cut @ - 11,950' Proposed Top of cement @ - 12,000' TOPOF 4-1/2" LNR l-i 12378' 14-1/2" TBG, 12.6#, L-80, 0.0152 bpf. 10 = 3.958" l-i 12379' 14-1/2" LNR, 12.6#, L-80, 0.0152 bpf, ID = 3.958" l-i 12426' 14-1/2" LNR, 12.6#, L-80, 0.0152 bpf, 10 = 3.958" l-i 12468' I TOP OF 4-1/2" LNR - SL TO l-i 12468' 17-5/8" CSG, 29.7#, USS-95. 10 = 6.875" l-i 12498' ÆRFORA TION SUMMARY REF LOG: BHCA ON 09/25/95 ANGLEATTOPPERF: 57 @ 12746' Note: Refer to Production DB for historical perf data I SIZE I SPF I INTERVAL opn/sqz\ DATE \ 4-1/2" SL TO 12468-14615 0 09/19/95 ~ 8 2196' 1-1 4-1/2" CAMTRCF-4A SSSV NIP, 10=3.813" I ~ ST MD 1VD 1 3131 3084 L - 2 6140 5065 3 8619 6560 4 10262 7579 5 11456 8351 ~~ .J- ~ -- --..~ GAS LIFT MANDR8.S DEV TY PE VL V LATCH PORT DA TE 28 ES- TMPC BK 55 ES- TMPC BK 52 ES- TMPC BK-5 50 ES- TMPC BK 51 ES- TMPC BK 12314' l-i 7-5/8" X 4-1/2" BAKER S-3 PKR, ID = 3.875" I 12358' 1-i4-1/2" HES XN NIP, 10 = 3.725" I 12378' 12379' 12379' 12426' ~ I 12511' l-i SLM PKR JUNK & 3 SLIP SEGMENTS I 1-i7-5/8" X 4-1/2" TW SS HA HGR PKR, ID = 3.89" 1-14-1/2" WLEG, 10 = 4.0" I l-i 8.MD TT 09/25/95 I 1-i4-1/2" PORTED JOINT (41.48'),10 = 3.94" I Proposed Base of cement @ - 13,100' I 14-1/2" LNR-SL TD, 12.6#, L-80. 0.0152 bpf, 10 = 3.958" l-i 14615' ~I I TOP OF 4-1/2" LNR l-i 14615' ~ .... ~ . - .~, ....,: ~:'.i~: :'-~:~~ ~\I,;øi':'; ,::Z -I ~~:~f.~ I .~w.~:~ I ~ iii, ';';:'J~~,':~, ;;~~~:: ~~ I" ",;~,/:",..., I 5<1 )'{;;:;r~':,'4,'~ - :;:",;:.,~~~. ..~ I :. .'~, .J~,-:--: , -I ~"".':""".. ,: I I ~ :""" "" '\.~, . . ~". I I '" '..... ~ 1 4-1/2" LNR, 12.6#, L-80, 0.0152 bpf, 10 = 3.958" l-i 14638' ~ .. DATE 09/19/95 01/10/01 02/22/01 10/31/01 09/17/02 COMM8'.JTS ORIGINAL COMPLETION SIS-QAA CONVERTED TO CANV AS SIS-LG REVISION RN/TP CORRECTIONS DEW Proposed Pre-Rig wark REV BY DA TE REV BY COMM8'.JTS PRUDHOE BAY UNIT WELL: 14-44 PERMIT No: 195-1030 API No: 50-029-22573-00 SEC 9, T10N, R14E, 531.28 FEL 626.96 FNL BP Exploration (Alaska) TOC@ -12,000' BOC@ - 13,100' DATE 09/19/95 01/10/01 02/22/01 10/31/01 09/17/02 Prop)sed Completion 11..~')¡4A I I 2200' l-i 4-1/2" 'X' Landing Nipple, 10 = 3.813" 1 110-3/4" CSG, 45.5#, NT-80-LHE, 10 = 9.953" l-i 3288' 1 ~ ~ GAS LIFT MANDRELS ST MD 1VD DEV TYPE VLV LATCH PORT DATE 1 TBD TBD L 2 TBD TBD 3 TBD TBD 4 TBD TBD 5 TBD TBD 1 r-¡ ~- - 7 5/8" X 51/2" Baker Flex-Lock Liner Hanger w / HR running tool, ZXP Liner Top Packer and TBR @ +/- 11 ,480' 11435' 11450' 11465' 11480' l-i 4-1/2" 'X' Ldg Nip. ID = 3.813" 1-i7-5/8" X 4-1/2" BAKER Production Packer l-i 4-1/2" 'X' Ldg Nip. ID = 3.813" 1 l-i 4-1/2" 'XN' Ldg Nip. 10 = 3.725" I z 11500' TREE = FMC WELLHEAD = CIW Äc-rUA TOR ,,;--~~ BAKER C -KRa-EV~-~~ 69.5&" "BF~ELEV";^W~W^~CBE;;4':f:'Õi 'KOp'W;^W~,w~w'=""""~-"-"11ß5õ' -MaxÄñgle';"'"-9T@13YÕ3~ -batù~m'MD =~_w~N'--1327šî' ''''''''''''''''''''''''''''''''''''''''W''''''''W'''''''''''''^'''''............,u.W''''''''''''~''''.........'.....v"""""",,,,,,,.......,...........,.w. Datum 1VD = 8955' SS / 11660' - Section mill from -11 ,660' MD to 11,705' MD, follow ing tubing de-completion. ~~ - r.";J:'~~' ~..,. :~ý, ..~~ ~ J: \'".'r~ .0- ~~::;t:.. ~...,.-:.,.. :~j ..... ÎIt"~'~'~'" ::~~~<~~~~- .(<-~:~. ~.. .: ,. ~. l/lci:\:: ., ..... 12787' 5 1/2" X 3 1/2" Baker HMC Liner Hanger w / ZXP Liner Top Packer @ +/- 12,787' ~ -I 12,937' l-i 51/2",17#, L-80 Liner; Hydril521 I ~ \ c::::::I c::::::I c::::::I c::::::I c::::::I c::::::I 17-5/8" CSG, 29.7#, USS-95, 10 = 6.875" l-i 12498' I 14-1/2" LNR-SL TO, 12.6#, L-80, 0.0152 bpf, 10 = 3.958" l-i 14615' I .. ~ I 4-1/2" LNR, 12.6#, L-80, 0.0152 bpf, 10 = 3.958" 1-1 14638' I COMMENTS ORIGINAL COMPLETION SIS-QAA CONVERTED TO CANVAS SIS-LG REVISION RNITP CORRECTIONS DEW Proposed Completion Wp06 REV BY DATE REV BY COMMENTS c::::::I c::::::I c::::::I c::::::I c::::::I c::::::I ) c::::::I c::::::I c::::::I c::::::I c::::::I c::::::I c::::::I c::::::I c::::::I 15,137' 31/2",9.2#, L-80 Slotted Liner; IBT w / special clearance collars PRUDHOE BAY UNIT WELL: 14-44A PERMIT No: API No: 50-029-22573-01 SEC9, T10N, R14E, 531.28 FEL 626.96 FNL BP Exploration (Alaska) 14-44A Kick Tolerance Wp06 Page 1 of 2 ) 9/18/2002 8:27 AM KICK TOLERANCE CALCULATOR For Vertical, Deviated or Horizontal Wells Well: Kick Zone Parameters: 1 Open hole Size? 2 Measured Depth? 3 Vertical Depth? 4 Horizontal Length (>87 deg) ? 5 Tangent Angle Above Horizontal? 6 Min Pore Pressure Gradient? 7 Max Pore Pressure Gradient? 8 Kick Zone Temperature? Weak Point Parameters: 9 Measured Depth? 10 Vertical Depth? 11 Section Angle «87 deg) ? 12 Min Fracture Gradient 1 EMW ? 13 Max Fracture Gradient 1 EMW 14 Weak Point Temperature? Other Parameters: 15 Drill Collar OD ? 16 Drill Collar Length? 17 Drillpipe OD ? 18 Surface Pressure Safety Factor? 19 Mud Weight in Hole? Annular Capacity Around BHA: Annular Capacity Around DP: At Min Fracture Gradient: Circulating MAASP Gas Gradient at Weak Point For Min Pore Pressure: Max Allowable Gas Height: Kick Tolerance: For Max Pore Pressure: Max Allowable Gas Height: Kick Tolerance: At Max Fracture Gradient: Circulating MAASP Gas Gradient at Weak Point For Min Pore Pressure: Max Allowable Gas Height: Kick Tolerance: For Max Pore Pressure: Max Allowable Gas Height: Kick Tolerance: Version 6.0, December 2000 (inch) (ft) (ft) (ft) (deg) (ppg) (ppg) (deg.F) (ft) (ft) (deg) (ppg) (ppg) (deg.F) (inch) (ft) (inch) (psi) (ppg) (bbl/ft) (bbl/ft) (psi) (psi/ft) (ft) (bbl) (ft) (bbl) (psi) (psi/ft) (ft) (bbl) (ft) (bbl) Units (UK/US): Input Error Messages: 12925 '8940 ' Non-Horizontal 11650 8460 11.300 0.02568 0.03205 Comments: 32 0.0791 3445 Extends above weak point Infinite 1617 Extends above weak point Infinite 866 0.0872 5172 Extends above weak point Infinite 3313 Extends above weak point Infinite 14-44A Kick Tolerance Wp06 Page 2 of 2 9/18/2002 8:27 AM I-tr-Min Fracture Grad ........o-Max Fracture Grad I 400 350 - 300 :ã .c ';' 250 u c ! 200 CD Õ I- 150 ~ u S2 1 00 50 0 0.00 2.00 4.00 6.00 Pore Pressure Gradient APPENDIX: ~ 8.00 10.00 12.00 Maximum Allowable Gas Influx Volume Based on Casing Burst & Surface Equipment Rating Max Allowable Surface Pressure? (psi) Near Surface Casing 10 ? (inch) Near Surface Annular Temperature? (deg.F) Gas Gradient at Max Surface Pres: (psi/ft) Near Surface Annular Capacity: (bbl/ft) At Minimum Pore Pressure Gradient: Max Allowable Gas Height at Surface: (ft) Max Allowable Gas Vol. on Shut-in: (bbl) At Maximum Pore Pressure Gradient: Max Allowable Gas Height at Surface: (ft) Max Allowable Gas Vol. on Shut-in: (bbl) - 2500 -r--- :ã .c - ~ 2000 " :s Õ > 1500 " ø œ CJ :Ë 1 000 ; 0 ;¡ 500 >< œ ::E 0 0.00 2.00 4.00 6.00 Pore Pressure Gradient 0.113 0.07549 Comments: 13955 Extends to hole TO infinite 11998 Extends to hole TO infinite I 0. '- v 8.00 10.00 12.00 . ,1ST THIS NOTICE IN THE DOGHOUSh ) 14-44A Rig site Summary of Drilling Hazards ../ Standard Operating Procedures for H2S precautions should be followed at all times. The highest concentration currently on record is 200 ppm, June 2002. ../ NORM test all retrieved well head and completion equipment. ../ All wells pass major risk criteria. The closest neighboring wells, at surface, are 14-17 and 14-38. Each is approximately 30' away. No shut-in should be required, but care should be taken during rig MIRU and RDMO. Use spotters as necessary. ../ Due to drilling at a 'higher' inclination, -69°, through the Kingak, mud weight will be maintained at 11.3ppg, minimally. Monitor ECD closely. ../ There is one fault crossing expected, during the drilling of the 4 3/4" production interval. The anticipated throw is -10'. No significant losses are expected, but due attention should be paid to the possibility. ../ Lost circulation may also be experienced while drilling. Though not expected to be a problem, potential lost circulation demands awareness. The SSD lost circulation tree should be followed if lost fluid returns are encountered. ../ Differential sticking may be encountered in this depleted reservoir. Overbalance is approximately 600 psi. Always follow established drilling and connection practices for stuck pipe prevention. ../ 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. CONSULT THE DS 14 PAD DATA SHEET AND THE WELL PLAN FOR ADDITIONAL INFORMATION. 14-44A ') ) Per Alaska Oil and Gas Conservation Commission Regulation 20 AAC 25.015 Changes to a Program in a Permit to Drill sub section (a) (1) submit and obtain the commission's approval of a new application for a Permit to Drill if the surface location is changed, if the bottom-hole location or the location of an objective formation is changed by more than 500 feet laterally or vertically, or if the change requires a spacing exception under 20 AAC 25.055; however, no additional fee is required ) TRANSMIT AL LETTER CHECK LIST CIRCLE APPROPRIATE LETTERIP ARAGRAPHS TO BE INCLUDED IN TRANSMITTAL LETTER WELL NAME PTD# CHECK WHAT APPLIES ADD-ONS (OPTIONS) MULTI LATERAL (If API number last two (2) digits are between 60-69) PILOT (PH) HOLE SPACING EXCEPTION DRY DITCH SAMPLE Rev: 07/10/02 C\jody\templates "CLUE" The permit is for a new wellbore segment of existing well Permit No, API No. Production should continue to be reported as a function' of the' original API number stated above. In accordance with 20 AAC 25.005(1), all records, data and logs acquired for the pilot hole must be clearly differentiated in both name (name on permit plus PH) and API number (50 70/80) from records, data and logs acquired for well (name on permit). . The permit is approved subject to full compliance with 20 AAC 25.055. Approval to peñorate and produce is contingent upon issuance of a conservation order approving a spacing exception. (Company Name) assumes the liability of any protest to the spacing exception that may occur. All dry ditch sample sets submitted to the Commission must be in no greater than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. ') ~7~1t ~[1~ !Æ~!Æ~:«fÆ ) AI,ASIiA. OIL AND GAS CONSERVAnONCO~SSION TONY KNOWLES, GOVERNOR 333 w. rm AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Bill Isaacson Senior Drilling Engineer BP Exploration (Alaska), Inc. PO Box 196612 Anchorage AK 99519-6612 Re: Prudhoe Bay Unit 14-44A BP Exploration (Alaska), Inc. Permit No: 202-193 Surface Location: 2829' NSL, 1617' WEL, Sec. 09, TI0N, RI4E, UM Bottomhole Location: 1014' SNL, 4316' WEL, Sec. 21, TI0N, RI4E, UM Dear Mr. Isaacson: Enclosed is the approved application for permit to redrill the above development well. . The permit to redrill does not exempt you from obtaining additional permits or approvals required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Please provide at least twenty-four (24) hours notice for a representative of the Commission to witness any required test. Contact the Commission's North Slope petroleum field inspector at 659-3607 (pager). Sincerely, ~~kL-! Cammy ~chsli Tayl~; lS- Chair BY ORDER OF THE COMMISSION DATED thisl:ilhday of September, 2002 cc: Department ofFish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. Hole 6-3/4" 4-3/4" ALASKA.-,} AND ~:~~g~S~~;~ON COMM.JION PERMIT TO DRILL 20 AAC 25.005 1 b. Type of well 0 Exploratory 0 Stratigraphic Test 181 Development Oil 0 Service 0 Development Gas 0 Single Zone 0 Multiple Zone 5. Datum Elevation (OF or KB) 10. Field and Pool Plan RKB = 69.50' Prudhoe Bay Field / Prudhoe 6. Property Designation Bay Pool ADL 028314 7. Unit or Property Name Prudhoe Bay Unit 8. Well Number / 14-44A 9. Approximate spud date, 09/25/02 7 Amount $200,000.00 14. Number of acres in property 15. Proposed depth (MD and TVD) 2560 150971 MD / 9035' TVD 0 17. Anticipated pressure {S~20 AAC 25.035 (e) (2)} 91 Maximum surface 2465 psig, At total depth (TVD) 8950' I 3360 psig Setting Depth Too Botom Length MD TVD MD TVD 25061 104501 7705' 12956' 8945' 2291' 12806' 8875' 15097' 9035' v..tGA- q I ¡~O'?- J.¡,r---c,( I~ (~ t. 1 a. Type of work 0 Drill 181 Redrill 0 Re-Entry 0 Deepen 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 2829' NSL, 1617' WEL, SEC. 09, T10N, R14E, UM At top of productive interval 4716' SNL, 52761 WEL, SEC. 16, T10N, R14E, UM At total depth 10141 SNL, 43161 WEL, SEC. 21, T10N, R14E, UM 12. Distance to nearest property line 13. Distance to nearest well / ADL 047475,963' MD 14-44 is 124'awayat13080'MD 16. To be completed for deviated wells Kick Off Depth 106001 MD Maximum Hole Angle 18. Casin9 Program Specifications Size Casina Weiaht Grade Couolina 5-1/2" 17# L-80 Hydril 521 3-1/2" 9.2# L-80 IBT 11. Type Bond (See 20 AAC 25.025) Number 2S100302630-277 Quantitv of Cement (include stage data) 141 sx Class 'G' /' . Uncemented Slotted Liner / 19. To be completed for Redrill, Re-entry, and Deepen Operations. . Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Structural Conductor Su rface Intermediate Production Liner 14638 feet 9067 feet 14638 feet 9067 feet Length Plugs (measured) Junk (measured) See Diagram: Fish left in hole at approx. 12511' / Size Cemented MD TVD 110' 20" 32591 10-3/4" 12471' 7-5/8" 2260' 4-1/2" 260 sx Arcticset (Approx.) 1210 sx CS 111,375 sx 'G', 181 sx CSII 110' 3288' 1101 3220' 265 sx Class 'GI Uncemented Slotted Liner 12498' 8946' 12378' - 14638' 8881' - 9067' Perforation depth: measured Slotted Section: 12468' - 14615' .<ECEIVtU SEP 1 0 2002 true vertical Slotted Section: 8930' - 9067' 20. Attachments A, "~k~ OU & GasCons.t;ommiSSiOf- 181 Filing Fee 0 Property Plat 0 BOP Sketch 0 Diverter Sketch I8I1DhØfföJØrogram 181 Drilling Fluid Program 0 Time vs Depth Plot 0 Refraction Analysis 0 Seabed Report 0 20 AAC 25.050 Requirements Contact Engineer NameINumber: Dave Wesley, 564-5773 Prepared By NameINumber: Terrie Hubble, 564-4628 21~¡~~;~;~¡~~,~~:gfT 'rue and COITem tO~SE=i~n~~:er .. Date SlPí 10 I 2hJ~ Permit Number API Number ApE.rova~ Date See cover letter 20"::>- - /~ 3 50- 029-22573-01 Vt,\110~ for other reQuirements Conditions of Approval: Samples Required 0 Yes ~ No Mud Log Required 0 Yes ~ No Hydrogen Sulfide Measures 181 Yes 0 No Directional Survey Required 'Is Yes 0 No Required Working Pressure for BOPE 0 2K 0 3K 0 4K 0 5K 0 10K 0 15K 0 3.5K psi for CTU Other: or~~fíígn~f E to 3 S 00 P! ,1, Cammy Oechsli T ayiof Approved By Form 10-401 Rev. 12-01-85 by order of the commission Date ~JJ1~~~nPlicate -) ) ( Well Name: 14-44A Drill and Complete Plan Summary I Type of Well (service I producer I injector): 1 Horizontal Sidetrack Producer I AFE Number: 1 PBD4P2008 1 I Estimated Start Date: 1 09/25/02 I I MD: 115,097' 1 I TVD: 19,035' 1 Suñace Location: Estimated Target Location: Ivishak Zone 48 Bottom Hole Location: x = 674,885.74 24511 FNL , 1617' FEL X = 671,420.00 564' FSL , 3' FWL X = 672,420.00 10141FNL, 963' FWL Y = 5,937,881.65 Sec. 9, T10N, R14E Umiat Y = 5,930,255.00 TVDss 8955 Sec. 16, T10N, R14E Umiat Y = 5,928,700.00 TVDss 8965 Sec. 21, T10N, R14E Umiat 1 BF/MS: 141.00' 1 1 I I RKB: 169.50' I I I I Rig: 1 Nabors 2ES I Operating days to complete: 122.5 /' ",/' I Well Design (conventional, slimhole, etc.): 1 Horizontal Sidetrack " I Objective: 1 Zone 4B Casing/Tubing Program Hole Size Csgl WtlFt Grade Conn Length Top Btm Tbg O.D. / MDITVD MDITVD 63/4" 51/2" 17.0# L-80 Hydril521 -2,506' 10,450' / 7,705' 12,956' / 8,945' 4 3/4" 3%" 9.2# L-80 IBT/ Spc. -2,291 ' 12,806' / 8,875' 15,097'/ 9,035' slotted Clearance Tubing 4%" 12.6# L-80 IBT -10,450 GL 10,450'/7,705' Tubing 3%" 9.2# L-80 IBT / Spc. -2,400' 10,450' / 7,705' -12,800' / 8,871' Clearance Directional KOP: 110,600' MD Maximum Hole Angle: Close Approach Well: Survey Program: 14-44A Sidetrack -55.0° in original well bore at -6,150' MD. -91.0° in horizontal section of sidetrack from -13,663' to -14,533' MD. There is one close approach issue: The closest well to the 14-44A is 14-44 original well with a center-to-center distance of 124' and allowable deviation of -227' at the planned depth of 13,080' MD. IIFR / Cassandra from kick-off to TO. Page 1 ) ) ,¡ Mud Program Window Milling Mud Properties: LSND I Whip Stock Window 7 5/8" I Density (ppg) Viscosity PV YP tauO MBT pH API FI 11.2 45 - 55 18 - 45 5-9 8.5-9.0 5-6 Intermediate Mud Properties: LSND I 6 3/4" hole section I Density (PP~, Viscosity PV YP tauO MBT pH API FI 11.2 45 - 55 18 - 45 3-8 8.5 - 9.0 5-6 Production Mud Properties: Flo-Pro Drill-in I 4 3/4" hole section I Density (ppg) Viscosity PV YP tauO MBT pH API FI 8.6-8.7 N/A 7 -11 25 - 35 4-8 <6 9.0 - 9.5 N/A Logging Program 7 5/8" Intermediate: Sample Catchers - None Drilling: MWD Dir/GRlRes- Real time GRlRes throughout entire interval. Open Hole: None Cased Hole: None 43/4" Production: Sample Catchers - None Drilling: MWD Dir/GRlRes- Real time GRlRes throughout entire interval. Open Hole: None Cased Hole: None Cement Proc ram "" Casing Size 5 1/2" 17#, L.80 Intermediate Liner I Basis: Lead: None Tail: Based on 82' of 5 1/2" shoe track and 1000' of 63/4" X 7" open hole with 40% excess. Tail TOC: -11,955' MD (8,472'TVD). Fluid Sequence & Volumes: Pre 5bbls Water Flush Spacer Lead Tail 25bbls Alpha Spacer at 12.2ppg None 29 bbl/162 fe 1141 sks of Halliburton 'G' at 15.9ppg and 1.15 cf/sk, BHST 1900 Casing Size 3 1/2", 9.2#, L.80 Slotted 1 Solid Production Liner Basis: Lead: None Tail: None. Uncemented solid I slotted liner Fluid Sequence & Volumes: Pre N/A Flush Spacer NI A Lead NI A Tail N/A 14-44A Sidetrack Page 2 ) Well Control Well control equipment consisting of 5000 psi working pressure pipe rams (2), blind/shear rams, and an annular preventer will be installed and is capable of handling maximum potential surf~ce pressures. Based upon calculations below, BOP equipment will be tested to 3500 psi. /' BOPE and drilling fluid system schematics are currently on file with the AOGCC. Production Section- . Maximum anticipated BHP: ~360 psi @ 8950' TVDss - Z4 . Maximum suñace pressure: -2465 psi @ suñace (based upon BHP and a full column of gas from TO @ 0.10 psi/ft) No annular injection in this well. Cuttings Handling: Cuttings generated from drilling operations will be hauled to grind and inject at DS-04. Any metal cuttings will be sent to the North Slope Borough. Fluid Handling: Haul all drilling and completion fluids and other Class II wastes to DS-04 for injection. Haul all Class I wastes to Pad 3 for disposal. . Planned BOP test pressure: Planned completion fluid: . . . . Formation Markers Formation Tops (Wp#5) CM2 CM1 THRZ BHRZ TJE TJC TJB TJA TSAG TSHU TSAD / Z4B TZ4A GOC/MGOC MHOT MOWC MD N/A N/A 11154 11494 11568 12159 12552 12764 12945 12978 13194 N/A N/A 3500 psi 8.6 ppg seawater /7.2 ppg Diesel TVDss 7213 7594 8027 8187 8222 8500 8685 8785 8870 8885 8950 Comments Est. Pore Pressure 3360psi (-7.2ppg EMW) Not penetrated Not present in this area 8985 9015 TD Criteria: The well will reach TD according to well plan #07, or before IF water saturation is higher than expected. The subsurface team will determine this. 14-44A Sidetrack Page 3 Sidetrack and Complete Procedure Summary Ria Operations: 1. MI/RU Nabors 2ES 2. Circulate out freeze protection and displace we~o seawater. Set TWC. 3. Nipple down tree. Nipple up and test BOPE. I 4. PuIl4}'2" tubing from above pre-rig cut at 10,750' MD. 5. P/U 4" drill pipe and M/U 7 5/8" window milling BHA. RIH and drift down to tubing stump. POOH. j 6. RIU E-line. RIH and set 7 5/8" Bridge Plug at -10,650' MD. Set as needed to avoid cutting a casing collar. 7. RIH with 7 5/8" Baker bottom-trip anchor whip stock assembl~Orient whip stock, as desired, and set on Bridge Plug. Mill window in 75/8" casing at:t 10,630' MD, plus an additional -20 feet of formation. Pull up into the 75/8" casing and conduct an FIT to 12.7ppg EMW. POOH. / 8. RIH with a 6 %" Dir/Gr/Res assembly. Kick-off and drill the 6 3/4" X 7" NBR(Near Bit Reamer) section to the top of the Sag River at -12,955~D. 8. Run and cement a 5 1/2", 17#, L-80 intermediate drilling liner. POOH. / 9. Test the 7 5/8" casing X 5 }'2" liner from the landing collar to surface to 3,500psi for 30 minutes. 10. M/U and RIH with 4 3/4" Dir/Gr/Res assembly to the landing collar. Drill the float equipment to the shoe. 11. Displace the well to -8.6ppg Flo-Pro mud system. 12. Drill out the 5 }'2" shoe, plus - 20 feet of new formation. Conduct an FIT to 10.0ppg EMW. 13. Drill the 43/4" production section, as per directional plan, to an estimated TD of 15,097' MD. POOH. 14. Run a 3 }'2", 9.2#, L-80 solid and slotted liner 15. Displace well to clean seawater. POOH. 16. Run a 4 1/2", 12.6#, L-80 completion tying into the 5 1/2" liner top. , 17. Set packer and test the tubing and annulus to 3500 psi for 30 minutes. /' 18. Nipple down the BOPE. Nipple up and test the tree to 5000 psi. 19. Freeze protect the well to -2200' and secure the well. 20. Rig down and move off. Post-Ria Work: 1. MIRU slick line. Pull the ball and rod I RHC plug from landing nipple below the production packer. Install gas lift valves. Estimated Pre-rig Start Date: 09/15/02 Estimated Spud Date: 10107102 14-44A Sidetrack Page 4 ") } Job 1: MIRU Hazards and Contingencies ~ No wells will require shut-in for the rig move onto 14-44. However, 14-38 is -30' to the North, and 14-17 is -30' to the South. These are the closest neighboring wells. Care should be taken while moving onto the well. Spotters will be used at all times. ~ DS-14 is designated as an HzS site. Standard Operating Procedures for H2S precautions should be followed at all times. Recent H2S data from the pad is as follows: Closest SHL Wells: Closest BHL Wells: 14-22A 26ppm 14-08A 86ppm 14-44 39ppm 14-40 59ppm The maximum level recorded of H2S on the pad was 200ppm in 06/2002. ~ Post Permit to Drill and Summary of Drilling Hazards 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 ~ The slotted liner interval/lower section of this well should be isolated by 2 barriers (the P&A cement plug and the seawater). The plug will be tested in the pre-rig operations. Monitor the well to ensure the fluid column is static, prior to pulling the completion. ~ NORM test all retrieved well head and completion equipment. ~ The existing wellhead is an FMC New Standard Slim Hole and has a tubing hanger with 4 1/2" NSCT landing thread. Utilize a 4" type 'H' BPV. Verify the hanger type and connection. Be prepared with necessary equipment to remove. Reference RP .:. "De-completions" RP Job 3: Run Whipstock Hazards and Contingencies ~ Once milling is complete, make sure all BOP equipment is operable. Wash out BOP stack to remove any metal cuttings, which may have settled there. Reference RP .:. "Whip stock Sidetracks" RP 14-44A Sidetrack Page 5 ') Job 5: Drill 6 3/4" Intermediate Hole Hazards and Contingencies ~ The well will kick off in the lower Colville Mudstone, and drill the remainder of the Colville, HRZ, and the entire Kingak, into the Sag River formation. Previous DS 14 wells drilled the Kingak with 9.8 to 10.2ppg mud weights. For this well, due to the long tangent at 600+ inclination, maintain mud weight at 11.2ppg, minimally, to 5 1/2" liner point. Follow all shale drilling practices to minimize potential problems. ~ The Security Near Bit Reamer (NBR) will be utilized in drilling this intermediate section, to open the hole from 6 %" to 7" gauge. This should aid in getting the 5 %" liner to setting depth, within the Sag River. ~ KICK TOLERANCE: In the worst-case scenario of 9.6ppg pore pressure at the Sag River depth, a fracture gradient of 11.5ppg at the 7 5/8" casing window, and 11.2ppg mud in the hole, the kick tolerance is infinite. Reference RP .:. "Shale Drilling, Kingak and HRZ" RP .:. "Prudhoe Bay Directional Guidelines" .:. "Lubricants for Torque and Drag Management" RP Job 6: Install 5 1/2" Intermediate Liner Hazards and Contingencies ~ Avoid high surge pressures with controlled running speeds and by breaking circulation slowly. High surge pressures could lead to losses to the Sag River or exacerbate Kingak instability problems. ~ Ensure the liner top packer is set prior to POOH. This may require going through the setting process twice. Slack off with rotation to the maximum allowable down weight, as per Baker representative. Reference RP .:. "Intermediate Casing Cementing Guidelines" RP .:. "Running and Cementing a Drilling Liner" RP Job 7: Drill 4 3/4" Production Hole Hazards and Contingencies ~ There is one anticipated fault crossing, while drilling 14-44A. It will be crossed within Zone 4B. The fault has a small throw, approximately 10 feet. While recently drilling the nearby X-09B sidetrack, a fault of similar orientation and throw was crossed within Zone 4B, and presented no problems. Reference RP .:. "Standard Operating Procedure: Leak-off and Formation Integrity Tests" 14-44A Sidetrack Page 6 ) .:. "Prudhoe Bay Directional Guidelines" .:. "Lubricants for Torque and Drag Management" RP Job 9: Install 3 Y2" Slotted Production Liner Hazards and Contingencies ~ The completion design is to run a 3 %", 9.2#, L-80 slotted liner throughout the production interval. Solid liner will be placed across intervals of lower resistivity / higher water saturation, as determined by the subsurface team. ~ Differential sticking is a concern. The 8.6ppg Flo-Pro will be -600psi over balanced to the Ivishak formation. Minimize the time the pipe is left stationary while running the liner. ~ Ensure the liner top packer is set prior to POOH. Slack off with rotation to the maximum allowable down weight, as per Baker representative. ~ Sufficient 3 %" liner will need to be run to extend -150' back up into the 5 1/2" intermediate liner, set at -12,956' MD. Reference 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 ",,"''''''''n_'\N'''JII_þIi~;,oo'''I'''''''''' Job 13: ND/NU/Release Ria Hazards and Contingencies ~ There are two neighboring wells at 30 foot center spacing. Identify all potential hazards in a pre rig move meeting, and take every precaution to ensure good communication prior to beginning the rig move. Use spotters when moving the rig off the hole and about the pad. Reference RP .:. "Freeze Protecting an Inner Annulus" RP 14-44A Sidetrack Page 7 ,.1ST THIS NOTICE IN THE DOGHOUSE ") 14-44A Rig site Summary of Drilling Hazards -/ Standard Operating Procedures for H2S precautions should be followed at all times. The highest concentration currently on record is 200 ppm, June 2002. -/ NORM test all retrieved well head and completion equipment. -/ All wells pass major risk criteria. The closest neighboring wells, at surface, are 14-17 and 14-38. Each is approximately 30' away. No shut-in should be required, but care should be taken during rig MIRU and RDMO. Use spotters as necessary. -/ Due to drilling at a 'higher' inclination, -620, through the HRZ and Kingak, mud weight will be maintained at 11.2ppg, minimally. Monitor ECD closely. -/ There is one fault crossing expected, during the drilling of the 4 3/4" production interval. The anticipated throw is -10'. No significant losses are expected, but due attention should be paid to the possibility. -/ Lost circulation may also be experienced while drilling. Though not expected to be a problem, potential lost circulation demands awareness. The SSD lost circulation tree should be followed if lost fluid returns are encountered. -/ Differential sticking may be encountered in this depleted reservoir. Overbalance is approximately 600 psi. Always follow established drilling and connection practices for stuck pipe prevention. -/ Diesel will be used to freeze protect the well. The diesel flash point is 1000 F. Diesel vapor pressure is - 0.1 psia at 1000 F. CONSULT THE DS 14 PAD DATA SHEET AND THE WELL PLAN FOR ADDITIONAL INFORMATION. 14-44A TREE = FMC ,WELLHEAD. = , "C:rN 'ÄCfUATOR';w'''' ~BXKËR~6 -KB~ELË\r~'^"-~-"~-~~7F BF~a:EV-;."""'N@__'"'""'~=-? "I<OP';;"^''' '''''''''"''''''W""''"'''''2'327'' -Ma'x''A'ngle-;'~'~'92"~@'1~r9ã7; "5atum^'M5w;'-"'"_'WMWW"~1W23591 [)'atüñî-iV~[r~N~-'8ã6¡Y^ss ') 14-44 ) SAFETY NOTES: HORIZONTAL WELL 70° @ 12585' AND 90° @ 12864' Minimum ID = 3.59" @ 5151' TIGHT SPOT LOGGED 06/16/00 L ST MD TVD ~ - 1 3131 3084 2 6140 5065 3 8619 6560 4 10262 7579 5 11456 8351 2196' l-i 4-1/2" CAM TRCF-4A SSSV NIP, 10 = 3.813" I GAS LIFT MANDRELS DEV TYÆ VLV LATCH 28 ES- TMPC BK 55 ES- TMPC BK 52 ES- TMPC BK-5 50 ES- TMPC BK 51 ES- TMPC BK PORT DATE 8 110-3/4" CSG, 45.5#, NT-80-LHE, 10 = 9.953" l-i 3288' ~ / :g: I :8:-1 12314' 1-i7-5/8" X 4-1/2" BAKERS-3 PKR, 10=3.875" 1 I 1 12358' 1-i4-1/2" HES XN NIP, 10 = 3.725" 1 I TOP OF 4-1/2" LNR l-i 12378' 1- ~ 14-1/2" TBG, 12.6#, L-80, 0.0152 bpf, ID = 3.958" l-i 12379' I 14-1/2" LNR, 12.6#, L-80, 0.0152 bpf, 10= 3.958" l-i 12426' 14-1/2" LNR, 12.6#, L-80, 0.0152 bpf, 10 = 3.958" l-i 12468' ~ -I 12378' 1-i7-5/8" x 4-1/2" TrN SS HA HGR PKR, 10 = 3.89" I - ~I 12379' H4-1I2"WLEG, D=4.0" I 12379' l-i ELMO TT 09/25/95 I TOP OF 4-1/2" LNR - SL TO l-i 12468' I~ ~ ....., I 12426' 1-i4-1/2" PORTED JOINT (41.48'),10 = 3.94" I 17-5/8" CSG, 29.7#, USS-95, 10 = 6.875" l-i 12498' ~ ~ :~: I~I I I I I 12511' l-i SLM PKR JUNK & 3 SLIP SEGMENTS I ÆRFORA TION SUMMARY REF LOG: BHCA ON 09/25/95 ANGLEATTOPÆRF: 57 @ 12746' Note: Refer to Production DB for historical perf data I SIZE \ SPF \ INTERVAL \opn/sqz\ DATE \ 4-1/2" SL TO 12468-14615 0 09/19/95 I 14-1/2" LNR-SL TO, 12.6#, L-80, 0.0152 bpf, 10 = 3.958" l-i 14615' ~I 1 TOP OF 4-1/2" LNR l-i 14615' ~ I 4-1/2" LNR, 12.6#, L-80, 0.0152 bpf, 10 = 3.958" l-i 14638' ~ ~ DATE 09/19/95 01/10/01 02/22/01 10/31/01 COMMENTS ORIGINAL COMPLETION SIS-QAA CONVERTED TO CANV AS SIS-LG REVISION RNlTP CORRECTIONS REV BY DATE REV BY COMMENTS PRUDHOE BAY UNIT WELL: 14-44 PERMIT No: 195-1030 APt No: 50-029-22573-00 SEC9, T10N, R14E, 531.28 FEL 626.96 FNL BP Exploration (Alaska) TREE = FMC WELLHEAD = cw 'ÄCTUATOFf;-"-.'SAKER-C' -KB~ä:N~^~^~--""'~-ff 'BF:~ä:Ë\T;;-~V'"'''"'-''w,,=?, 'RÕí5';'WMM'''^'UU " ""'-""""2327" '-Max'A"ñ9le'~-~'~92^@"T2^9ã7; Dã'!'ürñ'MÕ-;-' ,,,..,",_m""-"123'59";' Dâiun:1ÏŸD,;,vm~~-ããoõ;Mss P~ )posed Pre-Rig 14-) / SA.FETY I'DTES: I-æZCNrAL V\B..L 7CP@12f£ß MOW @1~ 110-3/4" CSG, 45.5#, NT-80-LHE, 10 = 9.953" 1-1 3288' I Minimum ID = 3.59" @ 5151' TIGHT SPOT LOGGED 06/16/00 Minimum ID = 3.55" @ 5151' Unable to swage 3.55" 07/01/00 Pre rig Tubing Cut @ - 10,750' Proposed Top of cement @ - 12,000' I TOP OF 4-1/2" LNR 1-1 12378' 14-1/2" TBG, 12.6#, L-80, 0.0152 bpf, 10 = 3.958" 1-1 12379' 14-1/2" LNR, 12.6#, L-80, 0.0152 bpf, 10 = 3.958" 1-1 12426' 14-1/2" LNR, 12.6#, L-80, 0.0152 bpf, 10 = 3.958" 1-1 12468' 1 TOP OF 4-1/2" LNR - SL TD 1-1 12468' 17-5/8" CSG, 29.7#, USS-95, 10 = 6.875" 1-1 12498' ÆRFORA TION SUMMARY REF LOG: BHCA ON 09/25/95 ANGLEATTOPÆRF: 57 @ 12746' Note: Refer to Production DB for historical perf data I SIZE I SPF I INTERVAL \ Opn/Sqz \ DATE \ 4-1/2" SL TO 12468-14615 0 09/19/95 ~~~ ~:~i¡,~~{:~~ -I "~ '-':9.. >.:i . "" P'~.F... ~!j 1 i¥~-;~':J 1 I~ ;!:;~';: "" 5<1 ..:,~:.~./:.~-~ I ~:t~-,~~'.~:~ I~ "'\~-~,:,~:~, 1 . <"'-'''- '-,fr/'f I ,~~'t.;~ ~ I~'':''i;t.';':'::?, ;'~:-(.>~ '~.' 1 I ..... ~ A (8 2196' 1-1 4-1/2" CAMTRCF-4A SSSV NIP, 10= 3.813" I ~ ST MD TVD 1 3131 3084 L - 2 6140 5065 3 8619 6560 4 10262 7579 5 11456 8351 GAS LIFT MANDRELS DEV TY PE VL V LATCH PORT DA TE 28 ES- TMPC BK 55 ES- TMPC BK 52 ES- TMPC BK-5 50 ES- TMPC BK 51 ES- TMPC BK ~ c:::::::--. ::::::: ...- ~ -----., ::::::- 12314' 1-17-5/8" X 4-1/2" BAKER S-3 PKR, 10 = 3.875" I 12358' 1-14-1/2" HES XN NIP, 10 = 3.725" I 12378' 12379' 12379' 12426' 1-17-5/8" X 4-1/2" TW SS HA HGR PKR, 10 = 3.89" 1-14-1/2" WLEG, ID = 4.0" 1 1-1 ELMO TT 09/25/95 1 1-14-1/2" PORTED JOINT (41.48'), 10=3.94" 1 ~ 1 12511' 1-1 SLM PKR JUNK & 3 SLIP SEGMENTS 1 Proposed Base of cement @ - 13,100' I 14-1/2" LNR-SL TD, 12.6#, L-80, 0.0152 bpf, 10 = 3.958" 1-1 14615' ~I 1 TOP OF 4-1/2" LNR 1-1 14615' /' 1 4-1/2" LNR, 12.6#, L-80, 0.0152 bpf, 10 = 3.958" l-i 14638' ~ .. REV BY DA TE REV BY DATE 09/19/95 01/10/01 02/22/01 10/31/01 09/04/02 COMMENTS ORIGINAL COMPLETION SIS-QAA CONVERTED TO CANVAS SIS-LG REVISION RN/TP CORRECTIONS DEW Proposed Pre-Rig work COMMENTS PRUDHOE BAY UNIT WELL: 14-44 PERMIT No: 195-1030 API No: 50-029-22573-00 SEC 9, T10N, R14E, 531.28 FEL 626.96 FNL BP Exploration (Alaska) 10-3/4... 45.5# j NT -80 BTRS 4-1/2",12.6.# L-80, IBT Production Tubing I Top of Window I +/- 10,630' MD I Bridge Plug set I @ +/- 10,650' I Tubing Cut I @ +/- 10,750' 17-5/8" x 4-1/2" Baker S-3 Packer (-5/B", 29.1# USS-95, 10 = 6.875" I I I I I 14-1/2",12.6#, L-80 ~ COMMENTS Proposed Sidetrack Revised for well plan 07 \ 8 ~ Ii IL ~ )roposed Complet~)n 14-44A I . I 'x' Nipple with 3.813" bore @ +/- 2200' MD I ~3288' Mol f 8 ~ --<:: >'t 112,315 MDI '~ 'w - ~112,498' I . I; I I I I I ~114,638' Mol DA TE REV BY 08/23/02 WDQ 09/05/02 DEVV 41/2" X 3 1/2" crossover 7-5/8" X 5-1/2" Baker Flex-Lock Liner Hanger w/ HR Running Tool, ZXP Liner Top Packer @ +/- 10,480' MD Station 6 5 4 3 2 1 3 1/2", 9.2.# L-80, IBT Sp.Clr. Production Tubing 5 1/2" X 3 1/2" Baker Production Packer 5-1/2" X 3-1/2" HMC Liner Hanger W/ZXP Liner Top Packer @ 12,806' MD TREE = FMC WELLHEAD= cr# 'ACTDATOR;~-**,^,,,v^''''£3AKER '*K¡r-ECE\r;..,..w-w__w~w~m,w''7'1' -BF:~Ëi:I~.v~;?-,,_wëBE"= 41~Õ' wK6p^,~~..._._~m___N232T """""""""'"N"""""""'''''''''''''~,"".v.-...........,......,~......~''''''''''''~'''''''''',~''''''- Max Angle = 91°@13,663' "5ãiu^'m"MÓW;NW"WN"-"N*-~r3:235;- ....',W.'W,'.vNN,'N-.w,",w.->"''''''''''''.',W,Wu.',.W.w...-.w''''''''''''''''''''''''''''',',,,,,w.'NN,',W,'"y,........"",,.'U Datum1VD= 8955'SS GLM Detail: MD TVD 3046' 3000' 4522' 4000' 6861' 5500' 8520' 6500' 9973 7400' 11300' 8250' Type Si7e 4-1/2"X1" 4-1/2"X1 4-1/2"X1 4-1/2"X1" 4-1/2"X1 " 4-1/2"X 1" RP Shear Packer/Tailpipe Detail: 10'Pup GLM #1 10'Pup 1 Full joint of tubing 10' Pup 'X' Nipple - 3.813" 10' Pup Packer 20' Pup 'X' Nipple - 3.813" 20' Pup 'XN' Nipple - 3.725" nogo 10' Pup WLEG 112,956 MD/8945' TVD I 115,097' MD /9,035' ND ==~~~-:~===~~~-:~===~~~-:~===~~-~~ I 5-1/2", 17#/ft I L-80, Hydril 521 COMMENTS PRUDHOE BAY UNrT WELL: 14-44A API No: 50-029-22573-01 BP Exploration (Alaska) 3-1/2", 9.2# Slotted Liner L-80, IBT w/ Special Clearance Collars (3.865") õ REFERENCE INFORMA nON Depth Fm Depth To Survey/Plan 10600,00 15096,62 Planned: 14-44A wp07 VIO Reviewed: COMPANY DETAil,S UP Anll.~u Co.-ordinate (NiE¡ Rderenœ: Well Centre: 14-44. True North Vert"al (1VD) R<ferenc<: 695 69.50 Seetinn (VS) Rderence: Slot - 44 (O,ooN,O,OOE) Ml.'asured Lkpth Reference: 69.5 69.50 Calculation Method: Minimum Curvanu'C Cakulalioli M~lhod: Minimum CUr\'i.lttln: l:rror Sysh."m: IS('WSA SÇ31\ M..:thod: 1m\' Cylind..:r Nonh Em1r Surliu:e: Elliplical -.- Casing Warni')" MeUllxl: Ruk" 11,,,-,1 All TVD depths are ssTVD plus 69.5'.(or RKBE. ~~~~~/ / /,/~~~~ /::;j~ >~ Ø~~/ ~ ;(i~~m¿ I /~~1'l~/ ~j//p~~ ~/ //J/ / " ~// ~// ~/'/~ ~/ ~ " " 1 101;01).00 2 1",,:'}.OO 3 1"":'..00 4 1 11'-1'..80 5 1."'''1.50 6 1 i: '-;.62 7 1'-' n.17 8 I' '''.!..58 9 1 ,-I ! -~.59 10 1 "",-~.70 II 1-1' \:..76 12 1-1' )~.72 13 Hr. '-~.86 14 1.'''''';.62 7600- Sec 8000 Start Dir 12/100': 10600' MD, 7803.81'TVD Start Dir4/IOO': 10620' MD, 7817.01'TVD End Dir : 11040.8' MD, 8043.23' TVD c ~ 0 0 ;:!, .<:: & 8400 0 '" u 'f > 1:1 I- 8800 9200 14-44P31 (14- 4P31) 6000 6400 6800 7200 7600 8000 Vertical Section at 196.360 [400ft/in] SURVEY PROGRAM Plan: 14.44A wp07 (14-44/Plan 14-44A) Date: 9/4/2002 Tool Created By: Ken Allen MWO MD WEll DETAILS Nan~ +-Ní-S ,Ej,W Northing Easting Latitude longitude Slot 1444 .1713.32 696.26 5937880.76 674886.09 70'14'09.495N 148'35'16,49IW 44 TARGET DETAILS Name lVD +N/.g +EI.W Northing FJlsting Shape 14-44A nb 901450 -8684.94 .2963.50 5929130,00 672124,99 Point 14-44A Poly 901950 -9302.35 .2652.72 5928520.00 672449.99 Polygon 14-44A Tlb 902450 .7543,81 -3642.26 5930255,00 671419,99 Point 14-44A T2b 9029.50 -7770.39 -3577.50 5931J030,OO 671489.99 Point 14-44A T5a 9034.50 -9121.69 -2678.54 5928700.00 672419.99 Point SECTION DETAILS Inc Azi TVD +N/-S +E/-W DLeg TFace 47.53 212.34 7803.81 -5397.81 -2790.91 0.00 0.00 49.85 211.53 78]7.01 -5410.56 -2798.85 12.00 -15.00 61.49 208.02 7985.94 -5625.43 -2921.17 4.00 -15.00 61.92 202.55 8043.23 -5721.56 -2966.56 4.00 -86.22 61.92 202.55 8942.08 -7277.67 -3612.76 0.00 0.00 85.00 1 72. 00 9024.50 -7543.81 -3642.26 13.00 -57.16 88.61 169.95 9026.81 -7584.78 -3635.76 10.00 -29.63 88.61 169.95 9027.43 -7609.79 -3631.32 0.00 0.00 90.00 153.00 9029.50 -7770.39 -3577.50 10.00 -85.46 90.87 145.45 9028.05 -7933.60 -3480.30 4.00 -83.40 90.87 145.45 9014.82 -8650.09 .2986.86 0.00 0.00 90.00 146.88 9014.50 -8684.94 -2963.50 4.00 121.28 87.67 146.88 9015.68 -8733.62 -2931.74 4.00 -179.92 87.67 146.88 9034.50 -9121.69 -2678.54 0.00 0.00 VSec Target 5965.47 5979.94 6220.57 6325.60 8000,73 8264.40 8301.87 8324.63 8463.55 8592.76 9141.20 9168.06 9205.82 9506.83 14-44A Tlb ~" 14-44A T2b 14-44A T3b 14-44A T5a FORMATION TOP DETAILS No. TVDPath MDPath Fonnation 1 8096.50 11153.97 THRZ 2 8256.50 11493.9] BHRZ 3 8291.50 11568.27 TJE 4 8569.50 12158.91 TJC 5 8754.50 12551.96 Till 6 8854.50 12764.42 TJA 7 8939.50 12945.01 TSag 8 8954.50 12977. 76 TSHU 9 9019.50 13193.52 TSAD/TZ4B CASING DETAILS No. TVD MD Start Dir 13/100' : 12950.5' MO, 8942.08'TVD Start Dir 10/1 00' : 13235.62' MD, 9024.5'TVD L EndDir: 13277.17'MD,9026.81'TVD End Dir : 13662.7' MD, 9028.05' TVD ,I I Start Dir 4/100' : 14532.76' MD, 9014.82'TVD I 3 1/2" ?:, 0 0 \ 14-44A wp07 '!Q. "'I I gg ~ " oJ': . I 'I -- I I - I I 40(0 -;; I I c.,uifJ SA J! I ~H' . T~,IfZLB J TS>\ )ff7:4R 1330258' \1D, 9027.43'TVD End Dir: 46~2.86' MD, Ç-015.68' TVJ I Star Dir 4/'00' 13472.59' \liD, 9029.5 TV ) 1 2 8944.50 12955.67 5 1/2" 9034.50 15096.61 3 1/2" Total Depth: 1~09t.62' MD, 904." TVD 8400 8800 9200 Name Size 5.500 3.500 ~---,/ \ 14-44 (14-44) I I 9600 bp 0 "2 ~ 0 0 ::£. - 7200 + :E 1:: 0 ~ :E :; 0 CI) CASING DETAILS FORMA nON TOP DETAILS No. TVD MD Name Size No. TVDPath MDPath Formation 8944.50 12955.67 5 1/2" 5.500 1 8096.50 11153.97 THRZ 9034.50 15096.61 3 1/2" 3.500 2 8256.50 11493.91 BHRZ 3 8291.50 11568.27 TJE 4 8569.50 12158.91 TJC 5 8754.50 12551.96 TJB 6 8854.50 12764.42 TJA 7 8939.50 12945.01 TSag 8 8954.50 12977.76 TSHU 9 9019.50 13193.52 TSAD/TZ4B COMPANY Dl'lAII.s REFERI'NCE [NFORMA T[ON SURVEY PROGRAM BPAI11\)4,;O C\)-ùrdinat~ tN'E) Rderellce; Well Centre: 14-44. True North Vertkal (lVD) Reference: 695 6950 ~¡;tion (V$) Ref¡:r~l1ce: Slot - 44 (O.OON.O.OOE) ~k>astlR.'(i Depth Rct~œncc: 69.5 69.50 Calculation Method: Minimum Curvature Depth Fm Depth To SurveyrPlan ("akuJ¡ltÎ¡)) M~lht1d: Minimum Cur,'üIUN I:m\[ System: ISC'WSA Scan M~thod: Trav ~'ylil1lkr North Em'r Surf.1ce: Elliptical ~ Casing Waminp MOlh..l: Rlllo, Basoli 10600.00 [5096.62 PlalUled: 14-44A "'p07 VIO -5400 All TVD depths are ssTVD plus 69.5'for RKBE. Dir 12/100': 10600' MD, 7803.81'TVD : 10620' MD, 7817.01'TVD -6000 See 1 Ifor:r\f).OO 2 1".,_"1.00 3 I{"~II.OO 4 11"~'.80 5 L".II.50 6 I,:, ;.62 7 1,:;7.17 8 1'111_:.58 9 I"~ 7 ~.59 10 1 "",.:.70 11 1.1' '.:.76 12 1.I'.7¡.72 13 I ~,. '-:.86 14 1'''''~,.62 -6600 - --~.._.- -- -_,_,_.n~"_-1J _.__,14-44PBL~44Plli,)_~ j Start .Jir 13/100': 295 ).5' MD, 8942.08'TVD Star~ Dir 10/100' : 132 \5.62' M.J, 9@24.5'TVD Sta'i Di! 10/100' : 13:"02.~8' 1v'.g,9œ.7.43'TVD ~art Dir "/100' : I ~472,59' \10, 9029.5'TVD -7800 -8400 S'art Dir 4/1 00' : 14532.76' MD, 9014.82'TVD End Dir : 14632.86' MD, 9015.68' TVD ~ Towl "'plh, 1509.0" MD, 9034.5' TVD 14-44A wp07 -9000 -4200 -3600 -3000 West(- )/East(+) [600ft/in] I -2400 I -1800 MD Plan: 14.44A wp01 (14-44/Plan 14-44A) Tool Created By: Ken Allen Date: 9/4/2002 MWD WELL DETAILS Name +N.'-S ,Fj,W Easting Latitude Longitude Slot Northing 14-44 -1713.32 696.26 593781;0.76 674886,09 70'14'09.495N 148'35'16.49IW 44 TARGET DETAILS Name TVD ~N!.s +E/.W Northing Easti"g Shape 14-44A Db 9014.50 .8684.94 -2963.50 5929130.00 672124.99 Point 14-44A Poly 9019.50 -9302.35 -2652.72 5928520,00 672449.99 Polv.on 14-44A Tlb 9024.50 -7543.81 .3642.26 5930255,00 671419.99 Poiñì 1444A T2b 9029.50 .7770.39 .3577.50 5930030,00 671489.99 Point 14-44A T5a 903450 .9121.69 -267g.54 5928700,00 672419.99 Point Ine SECTION DETAILS Azi TVD +N/-S +E/-W DLeg TFace VSee Target 212.34 71;111.81 -5397.81 -2790.91 0.00 0.00 5965.4 7 211.53 7~ 17.01 -5410.56 -2798.85 12.00 -15.00 5979.94 208.02 7u~).94 -5625.43 -2921.17 4.00 -15.00 6220.57 202.55 t'fI.U.23 -5721.56 -2966.56 4.00 -86.22 6325.60 202.55 t'õ'J42.08 -7277.67 -3612.76 0.00 0.00 8000.73 172.00 lJ1i2.t50 -7543.81 -3642.26 13.00 -57.16 8264.40 14-44A Tlb ~' 169.95 L!1I2/j.81 -7584.78 -3635.76 10.00 -29.63 8301.87 169.95 '}(J27.43 -7609.79 - 3631.32 0.00 0.00 8324.63 153.00 (1I~L).50 -7770.39 -3577.50 10.00 -85.46 8463.55 14-44A T2b 145.45 'JlI~~.05 -7933.60 -3480.30 4.00 -83.40 8592.76 145.45 4014.82 -8650.09 -2986.86 0.00 0.00 9141.20 146.88 L)014.50 -8684.94 -2963.50 4.00 121.28 9168.06 14-44A Db 146.88 'Jill ~.68 -8733.62 -2931.74 4.00 -179.92 9205.82 146.88 LJII34.50 -9121.69 -2678.54 0.00 0.00 9506.83 14-44A T5a 47.53 49.85 61.49 61.92 61.92 85.00 88.61 88.61 90.00 90.87 90.87 90.00 87.67 87.67 ~' '--., " ,'~?f ,~' 7"- ...~,' ", BP KW A Planning Report MAP ~) Prudhoe Bay North Slope UNITED STATES Map System :us State Plane Coordinate System 1927 Geo Datum: NAD27 (Clarke 1866) Sys Datum: Mean Sea Level Field: Map Zone: Coordinate System: Geomagnetic Model: Alaska, Zone 4 Well Centre BGGM2002 PB OS 14 TR-10-14 UNITED STATES: North Slope Site Position: Northing: From: Map Easting: Position Uncertainty: 0.00 ft Ground Level: 0.00 ft Site: 5939577.43 ft 674150.48 ft Latitude: Longitude: North Reference: Grid Convergence: 70 14 26.346 N 148 35 36.726 W True 1.32 deg Well: 14-44 14-44 Well Position: Slot Name: 44 70 14 9.495 N 148 35 16.491 W +N/-S -1713.32 ft Northing: 5937880.76 ft +E/-W 696.26 ft Easting: 674886.09 ft Position Uncertainty: 0.00 ft Latitude: Longitude: Well path: Plan 14-44A Plan: 14-44A wp07 Date Composed: Version: Tied-to: 14-44 10600.00 ft Mean Sea Level 26.18 deg 80.79 deg Direction deg 196.36 9/3/2002 10 From: Definitive Path Current Datum: Magnetic Data: Field Strength: Vertical Section: 69.5 7/25/2002 57533 nT Depth From (TVD) ft 0.00 Height 69.50 ft Drilled From: Tie-on Depth: Above System Datum: Declination: Mag Dip Angle: +E/-W ft 0.00 +N/-S ft 0.00 Principal: Yes Casing Points MD ft 12955.67 8944.50 5.500 7.000 51/2" 15096.61 9034.50 3.500 4.750 31/2" Formations MD TVD Formations Dip Angle DipØirection ft ft døg deg 0.00 CM1 0.00 0.00 11153.97 8096.50 THRZ 0.00 0.00 11493.91 8256.50 BHRZ 0.00 0.00 11568.27 8291.50 TJE 0.00 0.00 12158.91 8569.50 TJC 0.00 0.00 12551.96 8754.50 TJB 0.00 0.00 12764.42 8854.50 TJA 0.00 0.00 12945.01 8939.50 TSag 0.00 0.00 12977.76 8954.50 TSHU 0.00 0.00 13193.52 9019.50 TSADfTZ4B 0.00 0.00 Targets Map Map <- Latitude -> <-- Longitude --> Name Description TVD +N/-S +E/-W Northing Easting Deg Min Sec Deg Min See Dip. Dir. ft ft ft ft ft 14-44A T3b 9014.50 -8684.94 -2963.50 5929130.00 672124.99 70 12 44.073 N 148 36 42.518 W 14-44A Poly 9019.50 -9302.35 -2652.72 5928520.00 672449.99 70 12 38.001 N 148 36 33.490 W .Polygon 1 9019.50 -7669.38 -3835.24 5930125.00 671229.99 70 12 54.057 N 148 37 7.839 W -Polygon 2 9019.50 -7479.52 -3610.76 5930320.00 671449.99 70 12 55.925 N 148 37 1.324 W -Polygon 3 9019.50 -9094.25 -2567.86 5928730.00 672529.99 70 12 40.048 N 148 36 31.029 W I I ) BP KW A Planning Report MAP Targets Map Map <--Latitude ---> <-- Longitude ---> +N/-S +E/-W Nortbing Easting Deg , Min See Deg Min See ft ft ft ft -Polygon 4 9019.50 -9302.35 -2652.71 5928520.00 672449.99 70 12 38.001 N 148 36 33.490 W 14-44A T1b 9024.50 -7543.81 -3642.26 5930255.00 671419.99 70 12 55.293 N 148 37 2.238 W 14-44A T2b 9029.50 -7770.39 -3577.50 5930030.00 671489.99 70 12 53.064 N 148 37 0.354 W 14-44A T5a 9034.50 -9121.69 -2678.54 5928700.00 672419.99 70 12 39.778 N 148 36 34.241 W Plan Section Information 10600.00 47.53 212.34 7803.81 -5397.81 -2790.91 0.00 0.00 0.00 0.00 10620.00 49.85 211.53 7817.01 -5410.56 -2798.85 12.00 11.61 -4.06 -15.00 10920.00 61.49 208.02 7985.94 -5625.43 -2921.17 4.00 3.88 -1.17 -15.00 11040.80 61.92 202.55 8043.23 -5721.56 -2966.56 4.00 0.35 -4.53 -86.22 12950.50 61.92 202.55 8942.08 -7277.67 -3612.76 0.00 0.00 0.00 0.00 13235.62 85.00 172.00 9024.50 -7543.81 -3642.26 13.00 8.09 -10.72 -57.16 14-44A T1b 13277.17 88.61 169.95 9026.81 -7584.78 -3635.76 10.00 8.70 -4.94 -29.63 13302.58 88.61 169.95 9027.43 -7609.79 -3631.32 0.00 0.00 0.00 0.00 13472.59 90.00 153.00 9029.50 -7770.39 -3577.50 10.00 0.82 -9.97 -85.46 14-44A T2b 13662.70 90.87 145.45 9028.05 -7933.60 -3480.30 4.00 0.46 -3.97 -83.40 14532.76 90.87 145.45 9014.82 -8650.09 -2986.86 0.00 0.00 0.00 0.00 14574.72 90.00 146.88 9014.50 -8684.94 -2963.50 4.00 -2.08 3.42 121.28 14-44A T3b 14632.86 87.67 146.88 9015.68 -8733.62 -2931.74 4.00 -4.00 -0.01 -179.92 15096.62 87.67 146.88 9034.50 -9121.69 -2678.54 0.00 0.00 0.00 0.00 14-44A T5a Survey MD Inel Azbn TVD Sys TVD MapN MapE VS DLS Tool/Comment ft deg deg ft ft ft ft ft deg/1 000 10600.00 47.53 212.34 7803.81 7734.31 5932420.03 672221.30 5965.4 7 0.00 MWD 10620.00 49.85 211.53 7817.01 7747.51 5932407.10 672213.65 5979.94 12.00 MWD 10700.00 52.94 210.49 7866.92 7797.42 5932352.80 672182.71 6040.42 4.00 MWD 10800.00 56.82 209.31 7924.44 7854.94 5932280.97 672143.62 6119.93 4.00 MWD 10900.00 60.71 208.22 7976.28 7906.78 5932205.09 672104.25 6203.43 4.00 MWD 10920.00 61 .49 208.02 7985.94 7916.44 5932189.46 672096.36 6220.57 4.00 MWD 11000.00 61.75 204.39 8023.97 7954.4 7 5932125.62 672066.76 6289.91 4.00 MWD 11040.80 61.92 202.55 8043.23 7973.73 5932092.31 672053.20 6325.60 4.00 MWD 11100.00 61.92 202.55 8071.10 8001.60 5932043.62 672034.30 6377.53 0.00 MWD 11153.97 61.92 202.55 8096.50 8027.00 5931999.24 672017.06 6424.87 0.00 THRZ 11200.00 61.92 202.55 8118.16 8048.66 5931961.38 672002.36 6465.24 0.00 MWD 11300.00 61.92 202.55 8165.23 8095.73 5931879.14 671970.42 6552.96 0.00 MWD 11400.00 61.92 202.55 8212.30 8142.80 5931796.90 671938.49 6640.68 0.00 MWD 11493.91 61.92 202.55 8256.50 8187.00 5931719.67 671908.50 6723.05 0.00 BHRZ 11500.00 61.92 202.55 8259.37 8189.87 5931714.66 671906.55 6728.39 0.00 MWD 11 568.27 61.92 202.55 8291.50 8222.00 5931658.51 671884.75 6788.28 0.00 TJE 11600.00 61.92 202.55 8306.43 8236.93 5931632.42 671874.62 6816.11 0.00 MWD 11650.00 61.92 202.55 8329.97 8260.47 5931591.29 671858.65 6859.97 0.00 Start Dir 12/100' : 11650' MD, 11670.00 61.92 202.55 8339.38 8269.88 5931574.85 671852.26 6877.51 0.00 Start Dir 4/100' : 11670' MD, 11700.00 61.92 202.55 8353.50 8284.00 5931550.17 671842.68 6903.83 0.00 MWD 11800.00 61.92 202.55 8400.57 8331.07 5931467.93 671810.74 6991.55 0.00 MWD 11900.00 61.92 202.55 8447.64 8378.14 5931385.69 671778.81 7079.26 0.00 MWD 12000.00 61.92 202.55 8494.70 8425.20 5931303.45 671746.87 7166.98 0.00 MWD 12034.36 61.92 202.55 8510.88 8441.38 5931275.19 671735.90 7197.12 0.00 End Dir : 12034.36' MD, 8634. 12100.00 61.92 202.55 8541.77 8472.27 5931221.21 671714.94 7254.70 0.00 MWD 12158.91 61.92 202.55 8569.50 8500.00 5931172.76 671696.12 7306.37 0.00 TJC BP KW A Planning Report MAP Survey Incl Azim TVD Sys TVD MapN MapE VS DLS Tool/Comment deg deg ft ft ft ft ft deg/10OO 12200.00 61.92 202.55 8588.84 8519.34 5931138.97 671683.00 7342.41 0.00 MWD 12300.00 61.92 202.55 8635.91 8566.41 5931056.72 671651.06 7430.13 0.00 MWD 12400.00 61.92 202.55 8682.97 8613.47 5930974.48 671619.13 7517.85 0.00 MWD 12500.00 61.92 202.55 8730.04 8660.54 5930892.24 671587.19 7605.56 0.00 MWD 12551.96 61.92 202.55 8754.50 8685.00 5930849.50 671570.60 7651.14 0.00 TJB 12600.00 61.92 202.55 8777.11 8707.61 5930810.00 671555.25 7693.28 0.00 MWD 12700.00 61.92 202.55 8824.18 8754.68 5930727.76 671523.32 7781.00 0.00 MWD 12764.42 61.92 202.55 8854.50 8785.00 5930674.77 671502.74 7837.51 0.00 TJA 12800.00 61.92 202.55 8871.24 8801.74 5930645.51 671491.38 7868.71 0.00 MWD 12900.00 61.92 202.55 8918.31 8848.81 5930563.27 671459.45 7956.43 0.00 MWD 12945.01 61.92 202.55 8939.50 8870.00 5930526.25 671445.07 7995.92 0.00 TSag 12950.50 61.92 202.55 8942.08 8872.58 5930521.74 671443.32 8000.73 0.00 MWD 12955.67 62.29 201.91 8944.50 8875.00 5930517.47 671441.69 8005.27 13.00 51/2" 12975.00 63.68 199.57 8953.28 8883.78 5930501.23 671435.97 8022.44 )7.00 MWD 12976.96 63.82 199.33 8954.15 8884.65 5930499.56 671435.42 8024.20 13.00 Start Dir 10/100' : 12976.96' 12977.76 63.88 199.24 8954.50 8885.00 5930498.88 671435.20 8024.91 13.00 TSHU 13000.00 65.54 196.61 8964.00 8894.50 5930479.61 671429.46 8045.01 13.00 MWD 13025.00 67.45 193.75 8973.97 8904.47 5930457.36 671423.98 8067.93 13.00 MWD 13050.00 69.41 190.96 8983.17 8913.67 5930434.54 671419.54 8091.12 13.00 MWD 13075.00 71.42 188.25 8991.55 8922.05 5930411.24 671416.15 8114.50 13.00 MWD 13100.00 73.46 185.60 8999.09 8929.59 5930387.52 671413.83 8138.01 13.00 MWD 13125.00 75.54 183.00 9005.77 8936.27 5930363.47 671412.58 8161.57 13.00 MWD 13150.00 77.64 180.46 9011.57 8942.07 5930339.15 671412.42 8185.09 13.00 MWD 13175.00 79.77 177.95 9016.46 8946.96 5930314.66 671413.33 8208.51 13.00 MWD 13193.52 81.36 176.12 9019.50 8950.00 5930296.44 671414.70 8225.75 13.00 TSADITZ4B 13200.00 81.92 175.48 9020.44 8950.94 5930290.06 671415.31 8231.75 13.00 MWD 13225.00 84.08 173.03 9023.49 8953.99 5930265.44 671418.37 8254.74 13.00 MWD 13235.62 85.00 172.00 9024.50 8955.00 5930255.00 671419.99 8264.40 13.00 14-44A T1b 13250.00 86.25 171.29 9025.60 8956.10 5930240.87 671422.40 8277.43 10.00 MWD 13277.17 88.61 169.95 9026.81 8957.31 5930214.20 671427.45 8301.87 10.00 MWD 13302.58 88.61 169.95 9027.43 8957.93 5930189.30 671432.46 8324.63 0.00 MWD 13317.67 88.73 168.44 9027.78 8958.28 5930174.55 671435.63 8338.05 10.00 End Dir : 13317.67' MD, 9026. 13343.08 88.94 165.91 9028.29 8958.79 5930149.92 671441.84 8360.22 10.00 Start Dir 10/100' : 13343.08' 13350.00 88.99 165.22 9028.42 8958.92 5930143.26 671443.72 8366.17 10.00 MWD 13400.00 89.40 160.23 9029.12 8959.62 5930095.90 671459.66 8407.78 10.00 MWD 13450.00 89.81 155.25 9029.46 8959.96 5930050.09 671479.66 8446.83 10.00 MWD 13472.59 90.00 153.00 9029.50 8960.00 5930030.00 671489.99 8463.55 10.00 14-44A T2b 13500.00 90.13 151.91 9029.47 8959.97 5930006.01 671503.22 8483.30 4.00 MWD 13513.10 90.19 151.39 9029.43 8959.93 5929994.62 671509.71 8492.61 4.00 Start Dir 4/100' : 13513.1' MD 13600.00 90.58 147.94 9028.85 8959.35 5929920.68 671555.32 8552.19 4.00 MWD 13662.70 90.87 145.45 9028.05 8958.55 5929869.10 671590.94 8592.76 4.00 MWD 13700.00 90.87 145.45 9027.48 8957.98 5929838.89 671612.80 8616.27 0.00 MWD 13703.20 90.87 145.45 9027.44 8957.94 5929836.30 671614.68 8618.29 0.00 End Dir : 13703.2' MD, 9028.0 13800.00 90.87 145.45 9025.96 8956.46 5929757.88 671671.41 8679.31 0.00 MWD 13900.00 90.87 145.45 9024.44 8954.94 5929676.87 671730.01 8742.34 0.00 MWD 14000.00 90.87 145.45 9022.92 8953.42 5929595.87 671788.61 8805.38 0.00 MWD 14100.00 90.87 145.45 9021.40 8951.90 5929514.86 671847.22 8868.41 0.00 MWD 14200.00 90.87 145.45 9019.88 8950.38 5929433.85 671905.82 8931.45 0.00 MWD 14300.00 90.87 145.45 9018.36 8948.86 5929352.85 671964.42 8994.48 0.00 MWD 14400.00 90.87 145.45 9016.84 8947.34 5929271.84 672023.02 9057.52 0.00 MWD 14500.00 90.87 145.45 9015.32 8945.82 5929190.83 672081.63 9120.55 0.00 MWD 14532.76 90.87 145.45 9014.82 8945.32 5929164.30 672100.83 9141.20 0.00 MWD 14573.27 90.03 146.83 9014.50 8945.00 5929131.20 672124.17 9167.12 4.00 Start Dir 4/100' : 14573.27' M ') BP KW A Planning Report MAP ') Date: 9/3/2002 Time: 1 0:33:21 Co~rdinate(NE) Reference: Well: 14-44, True North Vertical (TVD) Reference: 69.5 69.5 Section (VS)Reference: Well (0.00N,O.00E,196.36Azi) Survey Calculation Method: Minimum Curvature Db: Oracle Page: 4 Survey 14574.72 90.00 146.88 9014.50 8945.00 5929130.00 672124.99 9168.06 4.00 14-44A T3b 14600.00 88.99 146.88 9014.72 8945.22 5929109.16 672139.29 9184.48 4.00 MWD 14632.86 87.67 146.88 9015.68 8946.18 5929082.07 672157.87 9205.82 4.00 MWD 14673.37 87.67 146.88 9017.32 8947.82 5929048.70 672180.76 9232.11 0.00 End Dir : 14673.37' MD, 9015. 14700.00 87.67 146.88 9018.40 8948.90 5929026.76 672195.82 9249.40 0.00 MWD 14800.00 87.67 146.88 9022.46 8952.96 5928944.37 672252.34 9314.30 0.00 MWD 14900.00 87.67 146.88 9026.52 8957.02 5928861.99 672308.86 9379.21 0.00 MWD 15000.00 87.67 146.88 9030.58 8961.08 5928779.60 672365.38 9444.12 0.00 MWD 15096.62 87.67 146.88 9034.50 8965.00 5928700.00 672419.99 9506.83 0.00 14-44A T5a -128 -120 -100 --80 --60 -40 -20 -0 -20 -40 --60 --80 -100 -120 -128 Nan}\; 14-14 -1713..12 WI'I,¡ DHAII,S ANTI-COLLISION SETTINGS Interpolation Method:MD Interval: 25.00 Depth Range From: 10600.00 To: 15096.62 Maximum Range: 1706.81 Reference: Plan: 14-44A wpO? ,OMPANY DETAILS OP Amoco Calculatitm Method; Minimum Curvature Error System: ISCWSA Scan Method: Trov Cylinder Nnrth Error Surfaœ: Ellíptìcal + Casing Warning Metbod: Rul~s Based N-S F!-W N~1r1hin~ 59J78S0,76 F...lsling I.alitudc Ll1ngitu(t: Slot 7Ir'14'09.495N 148"}5'16,49IW +I 696.2() 674886.09 270 From Colour 0 300 600 900 1200 = 1500 2000 ~ 2500 3000 3500 4000 4500 5000 0 6000 8000 11000 12000 SURVEY PROGRAM Date; &'16/2002 Validated: No Version: 1 Depth Fm Depth To SUlveyœlan Tool 7150 10600.00 I :SchlumbergcrGCTmultishot GCT-MS 10600,00 15096.62 Planned: 14-44A "1'07 VIO MWD WELLPA lH DEl AILS Plan I4-44A ToMD 300 600 900 1200 1500 2000 2500 3000 3500 4000 4500 5000 6000 8000 11000 12000 15000 14-14 10600.00 Parent Wellpatlt Tie on MD: Ri8: Ref. Damm: 695 6950ft Startin8 From TVD V.secliol1 Angle 196.36° Origin +N/-S 0.00 ÜJÍ¡,Ün +Et:W 0,00 0.00 LEGEND - 14-17 (14-17). Major Risk - 14-14 (14-44), NOERRORS ~~ 14-44PBI (14-14PBI), NOERRORS - Plan 14-44A - 14-44A wp07 90 "~ SECTION DETAlLS See MD Inc Azi 1VD .Nt-S +E/-W DU8 TFace vSec Target I 10600.00 4753 ; I: IJ 7803,81 -5397,81 -2790.91 0.00 0,00 5965,47 2 10620.00 49,85 '11"1 7817.01 -5410.56 -2798.85 12.00 -15,00 5979.94 3 10920.00 61.49 .'.,Jo" II: 7985.94 -5625,43 -2921.17 4.00 -15.00 6220.57 4 11040.80 61.92 8043.23 -5721.56 -2966.56 4.00 -8622 6325,60 5 12950.50 61.92 'II".' 8942,08 -7277.67 -3612.76 0.00 0.00 8000,73 6 13235.62 85,00 17: IIII 9024,50 -7543.8l -3642,26 13.00 -57.16 8264.40 14-44A Tlb 7 13277.17 88,61 I .," ...,~. 9026,81 -7584.78 -3635,76 10.00 -29.63 8301.87 8 1330258 88.61 .,"r.J 9027,43 -7609,79 -3631.32 0.00 0,00 8324,63 9 1347259 90,00 I",.IMI 9029,50 -7770.39 -3577.50 10,00 -85.46 8463.55 14-44A T2b 10 13662,70 90,87 I.P~ 9028,05 -7933,60 -3480.30 4,00 -83.40 8592,76 II 14532.76 90.87 I J', ~~ 9014,82 -8650,09 -2986.86 0.00 0.00 9141.20 12 14574.72 90.00 1-1..'10;:0<. 9014.50 -8684,94 -296350 4,00 12128 9168.06 14-44A Db 13 14632,86 87.67 1...1..).;)\ 9015.68 -8733,62 ~93I.74 4,00 .179,92 9205.82 14 15096,62 87.67 IJ',:\"'; 903450 -9121.69 -2678.54 0,00 0.00 9506.83 14-44A T5a TraveUing Cylinder ,......, .S ......... ~ 0 If) L...-, ¡:: 0 .~ ~ ro ~ Q) r:/:1 ~ Q) u 0 +-> ~ 1:1 Q) u WELl, DHAlI,g Nan;: N'.S L!-W N'\rthing E<isting I,alitud~ Longitu<k Slüt 14-44 .17i:U2 5~3788U,76 674886,(<) 7WI4'O~,4~5N 148'35' 16.491 W 44 MG.26 250 200 150 100 50 - KOP 10600' MD from 14-44. 11l1l!!lllllr 11000 11500 ANTI-COLLISION SETTINGS Interpolation Method:MD Interval: 25.00 Depth Range From: 10600.00 To: 15096.62 Maximum Range: 1706.81 Reference: Plan: 14-44A wp07 ff " / " " / 'v Eq-)ival~nt Magn~tic D~sß¡:1ce 12000 12500 13000 Measured Depth [ 500ft/in] 11111 COMPANY DETAILS BP AmDCO Calculatk1t1 Method: Minimum Curvantre Error System: ISCWSA Scan Method: Trav CyJimwr North Error Surface: Elliptì~al ->- Casing Warning Method: Ru1es Based 13500 SURVEY PROGRAM ~pth Fm Depth To Survey/Plan 10600,00 15096.62 Planned: 14-44A "1'07 VIO Pare~:~~IM~; Tool MWD WELLPATH DETAILS Plan 14-44A 14-44 10600,00 Rig: Ref. Datum: 69.5 69.50ft V .Section Origin Origin Starting Angle ~Ni_S +E!-W From TVD 196.36° 0,00 0.00 0,00 LEGEND - 14-17 (14-17), Major Risk - 14-44 (14-44), NOERRORS ~~ 14-44PBI (14-441'81), NOERRORS - Plan I4-44A - 14-44A wp07 14000 1450 SECTION DETAILS Sec MD !nc Azi TVD +N/-S +EI-W DLeg TFace I 1111.111'.00 47.53 21234 7803,81 -5397,81 -2790.91 0.00 0.00 2 It"..'IIJ)O 49.85 21153 7817,01 -5410.56 -2798,85 12.00 -15.00 3 1'l1~II.OO 61.49 208,02 7985,94 -5625,43 -2921.17 4,00 -15.00 4 111~1I.80 61.92 202.55 80H23 -5721.56 -296656 4,00 -8622 < I ~""1'.50 61.92 202.55 8942,08 -7277.67 -3612,76 0,00 0,00 (; Ii: ,'.62 85,00 172.00 902450 -7543,81 ,3642,26 13.00 -57.16 7 11::1.17 88.61 169,95 9026.81 -7584,78 -3635.76 10.00 -29,63 8 I ~ ¡1._'.58 88.61 169,95 9027.43 -7609,79 -363l.J2 0,00 0,00 9 I ,..¡ f~.59 90,00 153.00 902950 -7770.39 -3577.50 10.00 -85,46 10 """-'.70 90.87 145,45 9028.05 -7933.60 -3480.30 4,00 ,83.40 II J ',' ,76 90,87 145,45 9014,82 -8650.09 -2986.86 0.00 0.00 12 I"¡ . ~J,.72 90.00 146,88 901450 -8684,94 -2963.50 4,00 12128 13 ",..:,86 87.67 146,88 9015.68 -8733,62 -2931.74 4.00 -179,92 14 LI"";.62 87.67 146,88 9034,50 -9121.69 -2678.54 0,00 0,00 ~ ~ vSec Target 5965.47 5979.94 6220.57 6325,60 8000,73 8264,40 14-44A Tlb 8301.87 8324,63 846355 14-44A T2b 8592.76 9141.20 9168,06 14-44A T3b 9205.82 9506,83 14-44A T5a ') BP Anticollision Report ) GLOBAL SCAN APPLIED: All wellpaths within 200'+ 100/1000 of reference - There ar~crrells in thlilaetd14-44A wp07 & NOT PLANNED PRvGRA Interpolation Method: MD Interval: 25.00 ft Error Model: ISCWSA Ellipse Depth Range: 10600.00 to 15096.62 ft Scan Method: Trav Cylinder North Maximum Radius: 1706.81 ft Error Surface: Ellipse + Casing Casing Points 12955.67 8944.50 15096.61 9034.50 5.500 3.500 7.000 4.750 51/2" 3 1/2" Plan: 14-44A wp07 Date Composed: Version: Tied-to: 9/3/2002 10 From: Definitive Path Principal: Yes Summary PB OS 14 14-17 14-17 V1 Out of range PB OS 14 14-44 14-44 V2 13079.82 13200.00 124.17 363.00 -226.71 FAIL: Major Risk PB OS 14 14-44PB1 14-44PB1 V3 10648.43 10650.00 1.89 311.10 -219.28 FAIL: Major Risk Site: PB OS 14 Well: 14-44 Rule Assigned: Major Risk Wellpath: 14-44 V2 Inter-Site Error: 0.00 ft Ref TFO+AZI TFO-HS Casing Distance Area Deviation ft ft deg deg in ft ft ft 10623.49 7819.26 10625.00 7821.17 46.16 46.28 13.86 162.38 0.56 310.51 -218.92 FAIL 10648.43 7835.14 10650.00 7838.03 46.18 46.43 12.55 161.41 1.89 311.10 -219.19 FAIL 10673.31 7850.65 10675.00 7854.94 46.19 46.57 11.16 160.33 3.77 311.64 -219.05 FAIL 10698.11 7865.78 10700.00 7871.90 46.20 46.72 10.46 159.95 6.16 312.17 -217.60 FAIL 10722.82 7880.53 10725.00 7888.84 46.22 46.88 10.09 159.88 8.98 312.73 -215.26 FAIL 10747.43 7894.89 10750.00 7905.76 46.23 47.04 9.81 159.90 12.21 313.33 -212.38 FAIL 10771.92 7908.85 10775.00 7922.69 46.25 47.18 9.74 160.12 15.87 313.85 -208.71 FAIL 10796.28 7922.40 10800.00 7939.63 46.26 47.32 9.91 160.56 19.97 314.38 -204.28 FAIL 10820.52 7935.55 10825.00 7956.52 46.29 47.49 10.20 161.12 24.37 314.96 -199.32 FAIL 10844.67 7948.31 10850.00 7973.16 46.31 47.66 10.47 161.66 28.83 315.61 -194.36 FAIL 10868.77 7960.71 10875.00 7989.41 46.33 47.85 10.66 162.11 33.17 316.27 -189.59 FAIL 10892.81 7972.75 10900.00 8005.32 46.35 48.03 10.82 162.52 37.46 316.94 -184.91 FAIL 10916.73 7984.38 10925.00 8021.11 46.38 48.20 10.98 162.92 41.99 317.56 -179.87 FAIL 10940.92 7995.92 10950.00 8036.93 46.39 48.34 10.59 163.53 46.87 318.17 -174.81 FAIL 10965.09 8007.42 10975.00 8052.85 46.40 48.46 9.78 163.81 51.99 318.73 -169.99 FAIL 10989.18 8018.85 11000.00 8068.84 46.41 48.57 8.72 163.84 57.33 319.25 -165.29 FAIL 11013.17 8030.20 11025.00 8084.89 46.41 48.67 7.49 163.69 62.88 319.68 -160.62 FAIL 11037.05 8041.47 11050.00 8101.04 46.39 48.74 6.10 163.38 68.70 320.00 -155.86 FAIL 11061.23 8052.85 11075.00 8117.24 46.42 48.89 5.19 162.64 74.68 320.54 -151.31 FAIL 11085.52 8064.28 11100.00 8133.33 46.45 49.07 4.50 161.95 80.53 321.18 -146.86 FAIL 11109.85 8075.73 11125.00 8149.26 46.49 49.25 3.85 161.29 86.18 321.87 -142.60 FAIL 11134.22 8087.20 11150.00 8165.04 46.53 49.43 3.23 160.68 91.68 322.55 -138.45 FAIL 11158.60 8098.68 11174.99 8180.75 46.57 49.59 2.69 160.14 97.09 323.15 -134.22 FAIL 11182.98 8110.15 11200.00 8196.56 46.62 49.75 2.23 159.68 102.62 323.76 -129.77 FAIL 11207.36 8121.63 11225.00 8212.35 46.66 49.91 1.84 159.29 108.10 324.40 -125.25 FAIL 111231.79 8133.13 11250.00 8227.99 46.71 50.09 1.52 158.96 113.38 325.10 -120.94 FAIL 11256.29 8144.66 11275.00 8243.36 46.76 50.28 1.18 158.63 118.29 325.82 -117.02 FAIL 11280.85 8156.22 11300.00 8258.40 46.81 50.47 0.78 158.22 122.88 326.53 -113.54 FAIL 11305.43 8167.79 11325.00 8273.37 46.87 50.65 0.37 157.81 127.40 327.28 -110.18 FAIL 11330.00 8179.35 11350.00 8288.36 46.93 50.81 0.00 157.45 131.94 327.92 -106.59 FAIL ) BP Anticollision Report ') Date: 9/4/2002 Time: 09:16:52 Page: 2 Site: PB OS 14 Well: 14-44 Wellpath: 14-44 V2 Rule Assigned: Inter-Site Error: Major Risk 0.00 ft 11354.55 8190.91 11375.00 8303.46 46.99 50.95 -0.30 157.15 136.59 328.53 -102.79 FAIL 11379.12 8202.47 11400.00 8318.56 47.05 51.12 -0.53 156.92 141.18 329.21 -98.97 FAIL 11403.75 8214.06 11425.00 8333.47 47.11 51.31 359.32 156.77 145.43 329.99 -95.44 FAIL 11428.45 8225.69 11450.00 8348.08 47.18 51.50 359.15 156.60 149.29 330.78 -92.35 FAIL 11453.20 8237.34 11475.00 8362.38 47.25 51.70 358.96 156.41 152.79 331.57 -89.68 FAIL 11477.96 8248.99 11500.00 8376.53 47.32 51.89 358.75 156.20 156.13 332.36 -87.20 FAIL 11502.74 8260.66 11525.00 8390.53 47.39 52.08 358.48 155.93 159.35 333.18 -84.96 FAIL 11527.52 8272.32 11550.00 8404.52 47.46 52.24 358.21 155.66 162.59 333.87 -82.58 FAIL 11552.29 8283.98 11575.00 8418.58 47.54 52.38 357.97 155.42 165.89 334.54 -80.05 FAIL 11577.05 8295.63 11600.00 8432.78 47.62 52.53 357.78 155.23 169.33 335.21 -77.29 FAIL 11601.79 8307.28 11625.00 8447.07 47.70 52.68 357.59 155.04 172.88 335.92 -74.45 FAIL 11626.53 8318.92 11650.00 8461.38 47.78 52.85 357.44 154.89 176.43 336.68 -71.58 FAIL 11651.27 8330.57 11675.00 8475.76 47.87 53.00 357.33 154.78 180.03 337.38 -68.56 FAIL 11675.99 8342.20 11700.00 8490.20 47.95 53.15 357.20 154.65 183.74 338.11 -65.47 FAIL 11700.70 8353.83 11725.00 8504.69 48.04 53.32 357.09 154.54 187.50 338.88 -62.34 FAIL 11725.40 8365.46 11749.99 8519.24 48.13 53.47 357.02 154.46 191.28 339.62 -59.06 FAIL 11750.11 8377.09 11775.00 8533.86 48.22 53.65 356.95 154.40 195.13 340.43 -55.79 FAIL 11774.82 8388.72 11800.00 8548.47 48.32 53.82 356.92 154.37 198.94 341.22 -52.48 FAIL 11799.57 8400.37 11825.00 8562.94 48.41 54.01 356.92 154.36 202.49 342.07 -49.43 FAIL 11824.34 8412.02 11850.00 8577.33 48.51 54.18 356.95 154.40 205.88 342.92 -46.43 FAIL 11849.08 8423.67 11875.00 8591.85 48.61 54.33 356.97 154.41 209.45 343.68 -43.19 FAIL 11873.80 8435.31 11900.00 8606.47 48.71 54.49 356.98 154.43 213.18 344.46 -39.83 FAIL 11898.51 8446.94 11925.00 8621.19 48.81 54.64 357.03 154.48 216.96 345.22 -36.33 FAIL 11923.20 8458.56 11950.00 8635.99 48.92 54.80 357.08 154.53 220.87 346.05 -32.74 FAIL 11947.90 8470.18 11975.00 8650.73 49.03 54.99 357.10 154.55 224.75 346.93 -29.31 FAIL 11972.61 8481.81 12000.00 8665.33 49.14 55.18 357.07 154.52 228.52 347.83 -26.11 FAIL 11997.33 8493.45 12025.00 8679.85 49.25 55.36 357.01 154.46 232.25 348.70 -22.99 FAIL 12022.05 8505.08 12050.00 8694.41 49.36 55.51 356.97 154.42 236.02 349.54 -19.72 FAIL 12046.75 8516.71 12075.00 8709.00 49.48 55.68 356.92 154.37 239.84 350.37 -16.42 FAIL 12071.45 8528.34 12100.00 8723.67 49.59 55.83 356.90 154.35 243.71 351.18 -13.00 FAIL 12096.14 8539.96 12125.00 8738.43 49.71 55.98 356.91 154.36 247.65 351.99 -9.43 FAIL 12120.82 8551.57 12150.00 8753.25 49.83 56.15 356.92 154.37 251.63 352.86 -5.85 FAIL 12145.51 8563.19 12175.00 8768.04 49.95 56.33 356.94 154.39 255.58 353.77 -2.35 FAIL 12170.23 8574.83 12200.00 8782.61 50.08 56.52 356.93 154.38 259.28 354.73 0.79 Pass 12194.97 8586.47 12225.00 8797.06 50.20 56.72 356.90 154.35 262.88 355.68 3.79 Pass 12219.71 8598.12 12250.00 8811.45 50.33 56.90 356.85 154.30 266.46 356.65 6.72 Pass 12244.48 8609.78 12275.00 8825.61 50.46 57.10 356.76 154.21 269.80 357.64 9.30 Pass 12269.30 8621.46 12300.00 8839.42 50.59 57.30 356.63 154.08 272.77 358.64 11 .43 Pass 12294.13 8633.15 12325.00 8852.93 50.72 57.50 356.45 153.90 275.49 359.63 13.20 Pass 12318.96 8644.83 12350.00 8866.39 50.86 57.70 356.24 153.69 278.23 360.64 14.91 Pass 12343.78 8656.51 12375.00 8879.82 50.99 57.89 356.01 153.46 281.01 361.64 16.62 Pass 12368.59 8668.19 12400.00 8893.23 51.13 58.08 355.75 153.20 283.84 362.63 18.31 Pass 12393.39 8679.86 12425.00 8906.63 51.27 58.21 355.48 152.93 286.72 363.12 20.53 Pass 12418.18 8691.53 12450.00 8920.09 51.41 58.30 355.23 152.68 289.66 363.45 23.02 Pass 12442.97 8703.20 12475.00 8933.63 51.55 58.39 355.00 152.45 292.66 363.76 25.62 Pass 12467.76 8714.87 12500.00 8947.22 51.70 58.48 354.78 152.23 295.70 364.08 28.27 Pass 12492.65 8726.58 12525.00 8960.02 51.84 58.48 354.56 152.01 297.69 364.52 29.58 Pass 12517.60 8738.33 12550.00 8971.23 51.99 58.48 354.29 151.74 297.76 365.00 28.82 Pass 12542.48 8750.04 12575.00 8980.83 52.14 58.49 353.96 151.41 295.98 365.46 26.07 Pass 12567.20 8761.67 12600.00 8989.20 52.29 58.50 353.58 151.03 292.83 365.92 21.83 Pass 12591.78 8773.24 12625.00 8996.74 52.44 58.51 353.14 150.59 288.83 366.39 16.60 Pass ) '> BP Anticollision Report Date: 9/4/2002 Time: 09:16:52 3 Site: PB OS 14 Well: 14-44 Rule Assigned: Major Risk Wellpath: 14-44 V2 Inter-Site Error: 0.00 ft Ctr.;.Ctr No-GO Allowable TFO+AZI TFo-HS Casing Distance Area Deviation Warning ft deg deg in ft ft ft 12616.22 8784.74 12650.00 9003.65 52.59 58.52 352.75 150.20 283.96 366.90 10.56 Pass 12640.52 8796.18 12675.00 9010.10 52.74 58.54 352.45 149.90 278.28 367.39 3.94 Pass 12664.77 8807.59 12700.00 9016.45 52.90 58.55 352.21 149.66 272.32 367.87 -2.82 FAIL 12689.06 8819.03 12725.00 9022.97 53.05 58.57 351.96 149.41 266.54 368.36 -9.42 FAIL 12713.29 8830.43 12750.00 9029.18 53.21 58.58 351.65 149.10 260.55 368.89 -16.41 FAIL 12737.27 8841.72 12775.00 9034.35 53.36 58.60 351.09 148.54 253.96 369.40 -24.61 FAIL 12760.88 8852.83 12800.00 9038.25 53.52 58.62 350.29 147.74 246.52 369.90 -34.28 FAIL 12783.90 8863.67 12825.00 9040.56 53.67 58.65 349.26 146.71 237.82 370.42 -45.79 FAIL 12806.23 8874.18 12850.00 9041.24 53.81 58.67 348.04 145.49 227.72 370.95 -59.21 FAIL 12828.27 8884.55 12875.00 9041.33 53.96 58.71 346.68 144.13 217.17 371.48 -73.45 FAIL 12850.19 8894.87 12900.00 9041.15 54.11 58.74 345.16 142.61 206.54 372.00 -88.21 FAIL 12872.01 8905.14 12925.03 9040.74 54.26 58.77 343.44 140.89 195.88 372.53 -103.50 FAIL 12893.71 8915.35 12950.00 9040.17 54.41 58.81 341.51 138.96 185.31 373.06 -119.23 FAIL 12915.37 8925.55 12975.00 9039.49 54.55 58.85 339.33 136.78 174.88 373.62 -135.42 FAIL 12937.01 8935.73 13000.00 9038.76 54.70 58.89 336.87 134.32 164.71 374.16 -151.94 FAIL 12956.66 8944.96 13025.00 9038.34 54.79 58.86 333.77 131.98 155.06 374.29 -167.65 FAIL 12975.00 8953.28 13050.00 9038.26 54.76 58.68 329.61 130.04 146.60 373.52 -181.12 FAIL 12990.25 8959.91 13075.00 9038.29 54.67 58.48 325.29 127.54 139.45 372.38 -193.41 FAIL 13007.58 8967.11 13100.00 9038.21 54.53 58.21 320.45 124.72 133.66 371.13 -204.36 FAIL 13025.00 8973.97 13125.00 9038.01 54.35 57.88 315.30 121.55 129.19 369.63 -213.68 FAIL 13043.08 8980.70 13150.00 9037.63 54.09 57.49 309.88 118.15 125.97 367.74 -220.81 FAIL 13061.29 8987.05 13175.00 9037.50 53.78 57.03 304.47 114.74 124.23 365.53 -225.32 FAIL 13079.82 8993.07 13200.00 9037.86 53.43 56.52 299.26 111.53 124.17 363.00 -226.71 FAIL 13100.00 8999.09 13225.00 9038.57 53.00 55.90 294.23 108.64 125.71 360.02 -224.82 FAIL 13117.32 9003.81 13250.00 9039.27 52.58 55.36 289.68 105.89 128.50 357.20 -221.31 FAIL 13136.10 9008.45 13275.00 9039.88 52.09 54.73 285.32 103.45 132.32 353.93 -215.61 FAIL 13154.79 9012.58 13300.00 9040.39 51.58 54.09 281.26 101.29 137.35 350.47 -208.10 FAIL 13175.00 9016.46 13325.00 9040.77 51.00 53.37 277.41 99.46 143.39 346.55 -198.67 FAIL 13191.69 9019.22 13350.00 9041.03 50.50 52.78 274.15 97.85 150.44 343.09 -188.67 FAIL 13209.73 9021.74 13375.00 9041 .22 49.95 52.14 271.08 96.56 158.63 339.16 -176.85 FAIL 13227.50 9023.74 13400.00 9041.43 49.40 51.51 268.36 95.57 167.54 335.84 -164.06 FAIL 13246.10 9025.33 13425.00 9042.04 49.04 51.08 266.42 94.94 177.23 333.84 -151.33 FAIL 13265.39 9026.42 13450.00 9042.78 48.87 50.83 265.07 94.55 187.52 332.72 -138.83 FAIL 13285.76 9027.02 13475.00 9043.47 48.83 50.72 264.27 94.33 198.24 332.30 -127.05 FAIL 13302.58 9027.43 13500.00 9044.11 48.98 50.78 264.08 94.13 209.05 332.78 -117.05 FAIL 13323.04 9027.89 13525.00 9044.70 48.20 49.94 261.89 93.99 220.22 328.00 -100.35 FAIL 13338.83 9028.21 13550.00 9045.24 47.60 49.30 260.17 93.84 232.04 324.28 -84.28 FAIL 13350.00 9028.42 13575.00 9045.70 47.17 48.86 258.90 93.68 244.33 321.50 -69.06 FAIL 13369.06 9028.73 13600.00 9045.96 46.38 48.06 256.83 93.51 257.28 316.59 -50.48 FAIL 13383.31 9028.93 13625.00 9046.01 45.79 47.47 255.19 93.30 271.07 312.92 -32.57 FAIL 13400.00 9029.12 13650.00 9045.94 45.10 46.77 253.32 93.09 285.22 308.55 -13.49 FAIL 13410.63 9029.22 13675.00 9045.78 44.64 46.36 252.05 92.88 299.73 306.02 4.12 Pass 13423.70 9029.33 13700.00 9045.46 44.08 45.84 250.54 92.67 314.58 303.06 22.91 Pass 13436.36 9029.41 13725.00 9044.95 43.54 45.34 249.05 92.44 329.83 300.15 41.96 Pass 13450.00 9029.46 13750.00 9044.34 42.95 44.80 247.47 92.22 345.59 296.93 61.92 Pass 13460.24 9029.49 13775.00 9043.72 42.51 44.41 246.25 92.02 361.91 294.45 81.37 Pass 13472.59 9029.50 13800.00 9043.08 41.98 43.94 244.83 91.83 378.62 291.49 101.98 Pass 13485.72 9029.49 13825.00 9042.44 41.82 43.78 244.14 91.66 395.44 290.42 120.04 Pass 13500.00 9029.47 13850.00 9041.78 41.64 43.60 243.41 91.50 412.44 289.35 138.46 Pass 13513.93 9029.43 13875.00 9041.23 41.47 43.42 242.73 91.37 429.75 287.87 157.18 Pass 13527.57 9029.38 13900.00 9041.36 41.31 43.25 242.16 91.34 447.31 286.85 176.26 Pass ) BP Anticollision Report ') Compao)': BP Amoco Field: Prudhoe Bay Reference Site: PB OS 14 Reference Well: 14-44 ~efer~nce Wellpath: Plan 14-44A Site: PB OS 14 Well: 14-44 Wellpath: 14-44 V2 Date: 9/4/2002 Time: 09:16:52 Page: 4 Co-ordinate(NE) Reference: Vertical (TVD) Reference: Well:14~44 True North 69.5 69.5 Db: Oracle Rule Assigned: Inter-Site Error: Major Risk 0.00 ft 13541.00 9029.31 13925.00 9041.96 41.14 43.08 241.66 91.37 464.97 285.84 195.49 Pass 13554.14 9029.23 13950.00 9042.85 40.98 42.92 241.20 91.44 482.85 284.86 214.95 Pass 13566.84 9029.14 13975.00 9043.65 40.83 42.77 240.74 91.49 501.13 283.92 234.72 Pass 13579.26 9029.04 14000.00 9044.28 40.68 42.64 240.28 91.51 519.61 283.01 254.63 Pass 13600.00 9028.85 14025.00 9044.87 40.43 42.38 239.47 91.53 538.27 281.35 275.77 Pass 13600.00 9028.85 14050.00 9045.68 40.43 42.43 239.52 91.58 556.83 281.26 294.20 Pass 13615.52 9028.68 14075.00 9046.75 40.25 42.24 238.97 91.65 575.43 280.16 314.71 Pass 13627.32 9028.54 14100.00 9048.07 40.11 42.12 238.59 91.74 594.11 279.52 334.84 Pass 13638.87 9028.39 14125.00 9049.54 39.98 42.00 238.23 91.84 612.95 278.90 355.12 Pass 13650.01 9028.24 14150.00 9051.03 39.86 41.89 237.88 91.93 632.15 278.30 375.71 Pass 13662.70 9028.05 14175.00 9052.56 39.71 41.75 237.46 92.02 651.96 277.59 397.11 Pass 13674.39 9027.87 14200.00 9053.91 39.80 41.80 237.54 92.09 672.05 277.84 416.81 Pass 13689.23 9027.65 14225.00 9055.17 39.91 41.85 237.60 92.15 692.16 278.32 436.40 Pass 13704.12 9027.42 14250.00 9056.44 40.02 41.90 237.66 92.21 712.22 278.37 455.60 Pass 13719.10 9027.19 14275.00 9057.71 40.15 41.95 237.72 92.27 732.23 278.88 475.09 Pass 13734.24 9026.96 14300.00 9058.86 40.27 42.00 237.76 92.32 752.11 279.40 494.43 Pass 13749.19 9026.74 14325.00 9059.86 40.39 42.05 237.79 92.35 772.15 279.91 513.91 Pass 13764.02 9026.51 14350.00 9060.79 40.51 42.10 237.82 92.37 792.27 280.41 533.47 Pass 13778.71 9026.29 14375.00 9061.63 40.63 42.15 237.83 92.39 812.50 280.91 553.13 Pass 13793.30 9026.07 14400.00 9062.35 40.75 42.20 237.84 92.39 832.80 281.42 572.83 Pass 13807.88 9025.84 14425.00 9062.99 40.87 42.26 237.84 92.40 853.10 281.50 592.03 Pass 13822.44 9025.62 14450.00 9063.80 41.00 42.31 237.85 92.41 873.43 282.02 611.77 Pass 13837.00 9025.40 14475.00 9064.77 41.12 42.35 237.87 92.43 893.74 282.52 631.51 Pass 13851.60 9025.18 14500.00 9065.84 41.25 42.40 237.90 92.46 914.04 283.04 651.24 Pass 13866.11 9024.96 14525.00 9066.78 41.37 42.46 237.92 92.47 934.39 283.56 671.01 Pass 13880.44 9024.74 14550.00 9067.27 41.49 42.51 237.91 92.46 954.88 284.08 690.85 Pass 13894.75 9024.52 14575.00 9067.29 41.62 42.57 237.87 92.42 975.36 284.62 710.65 Pass 13908.84 9024.31 14600.00 9067.17 41.74 42.60 237.83 92.38 996.00 289.51 725.69 Pass 13922.91 9024.09 14625.00 9067.04 41.87 42.62 237.78 92.34 1016.65 296.10 739.29 Pass 13930.23 9023.98 14638.00 9066.98 41.94 42.62 237.76 92.32 1027.39 299.52 746.37 Pass Site: PB OS 14 Well: 14-44PB1 Rule Assigned: Major Risk Wellpath: 14-44PB 1 V3 Inter-Site Error: 0.00 ft Reference Offset S~mi-Majol' Axis Ctr..Ctr ... No-Gò Allowable MD TVD MD TVD Ref Offset TFO+AZI TFO..HS Casing Distance Area Deviation Warning ft ft ft ft ft ft deg d~g in ft ft ft 10623.49 7819.26 10625.00 7821.17 46.16 46.28 13.61 162.13 0.56 310.52 -219.20 FAIL 10648.43 7835.14 10650.00 7838.03 46.18 46.43 12.48 161.33 1.89 311.10 -219.28 FAIL 10673.31 7850.65 10675.00 7854.94 46.19 46.58 11.12 160.30 3.77 311.64 -219.10 FAIL 10698.11 7865.78 10700.00 7871.90 46.20 46.72 10.44 159.93 6.16 312.17 -217.63 FAIL 10722.82 7880.54 10725.00 7888.84 46.22 46.88 10.07 159.86 8.98 312.74 -215.28 FAIL 10747.43 7894.89 10750.00 7905.76 46.23 47.04 9.80 159.89 12.21 313.33 -212.40 FAIL 10771.92 7908.85 10775.00 7922.69 46.25 47.18 9.74 160.11 15.87 313.86 -208.73 FAIL 10796.28 7922.40 10800.00 7939.63 46.26 47.32 9.90 160.55 19.97 314.38 -204.29 FAIL 10820.52 7935.55 10825.00 7956.52 46.29 47.49 10.19 161.12 24.37 314.97 -199.33 FAIL 10844.67 7948.31 10850.00 7973.16 46.31 47.67 10.46 161.65 28.83 315.62 -194.37 FAIL 10868.77 7960.71 10875.00 7989.41 46.33 47.85 10.66 162.11 33.17 316.28 -189.60 FAIL 10892.81 7972.75 10900.00 8005.32 46.35 48.03 10.81 162.51 37.46 316.94 -184.92 FAIL 10916.73 7984.38 10925.00 8021.11 46.38 48.21 10.97 162.92 41.99 317.57 -179.88 FAIL 10940.92 7995.92 10950.00 8036.93 46.39 48.35 10.59 163.52 46.87 318.18 -174.81 FAIL 10965.09 8007.42 10975.00 8052.85 46.40 48.46 9.77 163.80 51.99 318.73 -169.99 FAIL ') BP Anticollision Report ') Company: Field: Reference Site: Reference Well: Date: 9/4/2002 Time: 09:16:52 Page: 5 Site: PB OS 14 Well: 14-44PB1 Wellpath: 14-44PB1 V3 Rule Assigned: Inter-Site Error: Major Risk 0.00 ft 10989.18 8018.85 11000.00 8068.84 46.41 48.57 8.72 163.84 57.33 319.25 -165.29 FAIL 11013.18 8030.20 11025.00 8084.89 46.41 48.67 7.48 163.69 62.88 319.68 -160.62 FAIL 11037.05 8041.47 11050.00 8101.04 46.39 48.74 6.10 163.38 68.70 320.00 -155.87 FAIL 11061.23 8052.85 11075.00 8117.24 46.42 48.89 5.19 162.64 74.68 320.55 -151.31 FAIL 11085.52 8064.28 11100.00 8133.33 46.45 49.07 4.50 161.94 80.53 321.18 -146.86 FAIL 11109.85 8075.73 11125.00 8149.26 46.49 49.25 3.84 161.29 86.19 321.87 -142.60 FAIL 11134.22 8087.20 11150.00 8165.04 46.53 49.43 3.23 160.68 91.69 322.55 -138.46 FAIL 11158.60 8098.68 11174.99 8180.75 46.57 49.59 2.69 160.14 97.09 323.15 -134.23 FAIL 11182.98 8110.15 11200.00 8196.56 46.62 49.75 2.23 159.67 102.62 323.76 -129.78 FAIL 11207.36 8121.63 11225.00 8212.35 46.66 49.91 1.84 159.29 108.10 324.40 -125.26 FAIL 11231.79 8133.13 11250.00 8227.99 46.71 50.09 1.51 158.96 113.38 325.11 -120.94 FAIL 11256.29 8144.66 11275.00 8243.36 46.76 50.28 1.18 158.63 118.29 325.82 -117.02 FAIL 11280.85 8156.22 11300.00 8258.40 46.81 50.47 0.77 158.22 122.88 326.53 -113.55 FAIL 11305.43 8167.79 11325.00 8273.37 46.87 50.66 0.36 157.81 127.40 327.29 -110.19 FAIL 11330.00 8179.35 11350.00 8288.36 46.93 50.81 0.00 157.45 131.94 327.92 -106.60 FAIL 11354.55 8190.91 11375.00 8303.46 46.99 50.95 -0.30 157.14 136.59 328.54 -102.79 FAIL 11379.12 8202.4 7 11400.00 8318.56 47.05 51.12 -0.53 156.92 141.18 329.22 -98.97 FAIL 11403.75 8214.06 11425.00 8333.47 47.11 51.31 359.32 156.76 145.43 329.99 -95.44 FAIL 11428.45 8225.69 11450.00 8348.08 47.18 51.50 359.15 156.60 149.29 330.78 -92.35 FAIL 11453.20 8237.34 11475.00 8362.38 47.25 51.70 358.96 156.41 152.79 331.57 -89.68 FAIL 11477.96 8249.00 11500.00 8376.53 47.32 51.89 358.75 156.19 156.13 332.37 -87.21 FAIL 11502.75 8260.66 11525.00 8390.53 47.39 52.08 358.48 155.93 159.35 333.18 -84.97 FAIL 11527.52 8272.32 11550.00 8404.52 47.46 52.24 358.21 155.65 162.59 333.88 -82.58 FAIL 11552.30 8283.98 11575.00 8418.58 47.54 52.39 357.97 155.42 165.89 334.55 -80.05 FAIL 11577.05 8295.63 11600.00 8432.78 47.62 52.53 357.78 155.22 169.33 335.22 -77.29 FAIL 11601.79 8307.28 11625.00 8447.07 47.70 52.68 357.59 155.04 172.88 335.93 -74.45 FAIL 11626.53 8318.92 11650.00 8461.38 47.78 52.85 357.44 154.89 176.43 336.68 -71.59 FAIL 11651.27 8330.57 11675.00 8475.76 47.87 53.00 357.33 154.78 180.03 337.39 -68.56 FAIL 11675.99 8342.20 11700.00 8490.20 47.95 53.15 357.20 154.65 183.74 338.11 -65.48 FAIL 11700.70 8353.83 11725.00 8504.69 48.04 53.32 357.09 154.53 187.50 338.88 -62.34 FAIL 11725.40 8365.46 11749.99 8519.24 48.13 53.47 357.01 154.46 191.28 339.62 -59.07 FAIL 11750.12 8377.09 11775.00 8533.86 48.22 53.65 356.95 154.40 195.13 340.43 -55.79 FAIL 11774.82 8388.72 11800.00 8548.47 48.32 53.82 356.92 154.37 198.94 341.23 -52.48 FAIL 11799.57 8400.37 11825.00 8562.94 48.41 54.01 356.92 154.36 202.49 342.08 -49.43 FAIL 11824.34 8412.03 11850.00 8577 .33 48.51 54.18 356.95 154.40 205.88 342.92 -46.43 FAIL 11849.08 8423.67 11875.00 8591.85 48.61 54.33 356.97 154.41 209.45 343.68 -43.20 FAIL 11873.80 8435.31 11900.00 8606.47 48.71 54.49 356.98 154.43 213.18 344.46 -39.84 FAIL 11898.51 8446.94 11925.00 8621.19 48.81 54.65 357.03 154.48 216.96 345.23 -36.33 FAIL 11923.21 8458.56 11950.00 8635.99 48.92 54.80 357.08 154.52 220.87 346.05 -32.74 FAIL 11947.90 8470.18 11975.00 8650.73 49.03 54.99 357.10 154.55 224.75 346.93 -29.32 FAIL 11972.62 8481.82 12000.00 8665.33 49.14 55.18 357.07 154.52 228.53 347.83 -26.12 FAIL 11997.34 8493.45 12025.00 8679.85 49.25 55.36 357.01 154.46 232.25 348.71 -22.99 FAIL 12022.05 8505.08 12050.00 8694.41 49.36 55.52 356.97 154.42 236.02 349.54 -19.72 FAIL 12046.75 8516.71 12075.00 8709.00 49.48 55.68 356.92 154.37 239.84 350.37 -16.43 FAIL 12071.45 8528.34 12100.00 8723.67 49.59 55.83 356.90 154.35 243.71 351.19 -13.00 FAIL 12096.14 8539.96 12125.00 8738.43 49.71 55.99 356.91 154.36 247.65 351.99 -9.43 FAIL 12120.82 8551.57 12150.00 8753.25 49.83 56.15 356.92 154.37 251.63 352.87 -5.85 FAIL 12145.51 8563.19 12175.00 8768.04 49.95 56.33 356.94 154.39 255.58 353.78 -2.36 FAIL 12170.23 8574.83 12200.00 8782.61 50.08 56.52 356.93 154.38 259.28 354.74 0.79 Pass 12194.97 8586.47 12225.00 8797.06 50.20 56.72 356.90 154.35 262.88 355.69 3.79 Pass ') BP Anticollision Report ) Company: BP Amoco Field: Prudhoe Bay ReterellceSite: PB OS 14 Refe..~neeWeU: 1444 Referenee,Wellpath: Plan 14-44A Site: PB OS 14 Well: 14-44PB1 Wellpath: 14-44PB1 V3 Date: 9/4/2002 Time: 09:16:52 Page: 6 Co-ordinate(NE) Reference: Vertical (TVD) Reference: Well: 14~44, True North 69.5 69.5 Db: Oracle Rule Assigned: Inter-Site Error: Major Risk 0.00 ft 12219.71 8598.12 12250.00 8811.45 50.33 56.90 356.85 154.30 266.46 356.65 6.72 Pass 12244.48 8609.78 12275.00 8825.61 50.46 57.10 356.76 154.21 269.80 357.65 9.30 Pass 12269.30 8621.46 12300.00 8839.42 50.59 57.31 356.63 154.08 272.78 358.65 11.43 Pass 12294.14 8633.15 12325.00 8852.93 50.72 57.50 356.45 153.90 275.49 359.63 13.20 Pass 12318.97 8644.83 12350.00 8866.39 50.86 57.70 356.24 153.69 278.23 360.65 14.91 Pass 12343.78 8656.52 12375.00 8879.82 50.99 57.89 356.01 153.46 281.01 361.64 16.62 Pass 12368.59 8668.19 12400.00 8893.23 51.13 58.09 355.75 153.20 283.84 362.63 18.31 Pass 12393.39 8679.86 12425.00 8906.63 51.27 58.21 355.48 152.93 286.72 363.19 20.45 Pass 12418.18 8691.53 12450.00 8920.09 51.41 58.30 355.23 152.68 289.66 363.60 22.84 Pass 12442.97 8703.20 12475.00 8933.63 51.55 58.40 355.00 152.45 292.66 364.00 25.34 Pass 12467.76 8714.87 12500.00 8947.23 51.70 58.49 354.78 152.23 295.72 364.39 27.94 Pass 12492.54 8726.53 12525.00 8960.91 51.84 58.57 354.58 152.03 298.83 364.80 30.60 Pass 12517.32 8738.19 12550.00 8974.69 51.99 58.58 354.41 151.86 302.05 365.29 33.22 Pass 12542.08 8749.85 12575.00 8988.63 52.14 58.58 354.26 151.71 305.41 365.76 36.04 Pass 12566.83 8761.50 12600.00 9002.70 52.29 58.59 354.14 151.58 308.89 366.22 39.05 Pass 12591.56 8773.14 12625.00 9016.91 52.44 58.60 354.03 151.48 312.50 366.70 42.23 Pass 12616.28 8784.77 12650.00 9031.19 52.59 58.61 353.94 151.39 316.21 367.22 45.50 Pass 12640.98 8796.40 12675.00 9045.55 52.75 58.62 353.85 151.30 320.01 367.72 48.89 Pass 12665.67 8808.02 12700.00 9059.98 52.90 58.63 353.76 151.21 323.91 368.22 52.37 Pass 12690.35 8819.64 12725.00 9074.47 53.06 58.65 353.68 151.13 327.87 368.72 55.94 Pass 12715.03 8831.25 12750.00 9089.02 53.22 58.66 353.63 151.08 331.83 369.27 59.55 Pass 12739.72 8842.87 12775.00 9103.62 53.38 58.68 353.60 151.05 335.80 369.80 63.23 Pass 12764.40 8854.49 12800.00 9118.28 53.54 58.70 353.59 151.04 339.77 370.33 66.96 Pass 12789.08 8866.10 12825.00 9132.99 53.70 58.72 353.59 151.04 343.77 370.88 70.74 Pass 12813.75 8877.72 12850.00 9147.74 53.86 58.74 353.60 151.05 347.80 371.46 74.55 Pass 12838.42 8889.33 12875.00 9162.53 54.03 58.76 353.62 151.07 351.86 372.01 78.43 Pass 12863.08 8900.94 12900.00 9177.33 54.20 58.78 353.64 151.08 355.93 372.57 82.32 Pass 12872.95 8905.58 12910.00 9183.25 54.27 58.78 353.64 151.09 357.56 373.97 81.30 Pass 14-44A Kick Tolerance ) Page 1 of 2 ) 9/9/2002 3:02 PM KICK TOLERANCE CALCULATOR For Vertical, Deviated or Horizontal Wells Version 6.0, December 2000 Units (UK/US): Well: Kick Zone Parameters: 1 Open hole Size? 2 Measured Depth? 3 Vertical Depth? 4 Horizontal Length (>87 deg) ? 5 Tangent Angle Above Horizontal? 6 Min Pore Pressure Gradient? 7 Max Pore Pressure Gradient? 8 Kick Zone Temperature? Weak Point Parameters: 9 Measured Depth? 10 Vertical Depth? 11 Section Angle «87 deg) ? 12 Min Fracture Gradient 1 EMW ? 13 Max Fracture Gradient 1 EMW 14 Weak Point Temperature? Other Parameters: 15 Drill Collar OD ? 16 Drill Collar Length? 17 Drillpipe OD ? 18 Surface Pressure Safety Factor? 19 Mud Weight in Hole? (inch) (ft) (ft) (ft) (deg) (ppg) (ppg) (deg.F) (ft) (ft) (deg) (ppg) (ppg) (deg.F) (inch) (ft) (inch) (psi) (ppg) (bbl/ft) (bbl/ft) Annular Capacity Around BHA: Annular Capacity Around DP: At Min Fracture Gradient: Circulating MAASP Gas Gradient at Weak Point For Min Pore Pressure: Max Allowable Gas Height: Kick Tolerance: For Max Pore Pressure: Max Allowable Gas Height: Kick Tolerance: (psi) (psi/ft) (ft) (bbl) (ft) (bbl) At Max Fracture Gradient: Circulating MAASP Gas Gradient at Weak Point For Min Pore Pressure: Max Allowable Gas Height: Kick Tolerance: For Max Pore Pressure: Max Allowable Gas Height: Kick Tolerance: (psi) (psi/ft) (ft) (bbl) (ft) (bbl) Input Error Messages: 12956 8945 Non-Horizontal , 10650 7830 11.200 0.02234 0.02871 Comments: 22 0.0776 3361 Extends above weak point Infinite 1518 Extends above weak point Infinite 510 0.0830 4375 Extends above weak point Infinite 2513 Extends above weak point Infinite 14-44A Kick Tolerance ) Page 2 of 2 ') 9/9/2002 3:02 PM -ã- Min Fracture Grad ......0- Max Fracture Grad I 300 250 - :c s. 200 Q) (,) c ~ 150 Q) Õ to- ~ 100 S2 50 0 0.00 2.00 4.00 6.00 Pore Pressure Gradient 8.00 10.00 12.00 APPENDIX: Maximum Allowable Gas Influx Volume Based on Casing Burst & Surface Equipment Rating Max Allowable Surface Pressure? (psi) Near Surface Casing 10 ? (inch) Near Surface Annular Temperature? (deg.F) Gas Gradient at Max Surface Pres: (psi/ft) Near Surface Annular Capacity: (bbl/ft) At Minimum Pore Pressure Gradient: Max Allowable Gas Height at Surface: (ft) Max Allowable Gas Vol. on Shut-in: (bbl) At Maximum Pore Pressure Gradient: Max Allowable Gas Height at Surface: (ft) Max Allowable Gas Vol. on Shut-in: (bbl) - 2500 :c s. ~ 2000 :J Õ =: 1500 as CJ ~ 1000 as ;: 0 ;æ 500 >< as :æ 0.113 0.07549 Comments: 14012 Extends to hole TO infinite 12033 Extends to hole TO infinite 0 0.00 2.00 4.00 6.00 Pore Pressure Gradient ~ Q I '/ 8.00 10.00 12.00 DATE INVOICE I CREDIT MEMO DESCRIPTION GROSS DATE CHECK NO. 8/01/02 H207044 VENDOR DISCOUNT NET $100.00 H ';f H 207044 08/01/02 CK073102K Permit To Drill Fee 14~L/L/j} PIs contact Sordra Stewman X4750 for check pickt.-p 8, '~ THE ATT'ACHED CHECK IS IN PAYMENT FOR ITEMS DESCRIBED ABOVE. TOTAL .... $100.00 SR' E?<PLORATIQN,','(\I.:ASt(.4().IN€, . P.O. BOX 19ß612 , ANCHORAGE,ALASKA995t9~6612 ***Allg. 1, ?OO/,*** *****$100.00****** NOT VALID AFTER 120 DAYS '-' TO THE ORDER OF III 2 0 ? 0 ~ ~ III I: 0... ~ 2 0 :¡ a q 5 I: 0 0 8 ...... ~ q III C':',: :": :.:::::>\:.:::::::-.:j~.:!.~.:.~~i~~::~.:~::::~::',::::F~ ,"" .;',: .... ':/"1 ~ ::,-::"""",,,.~:,,,,,::,,,,,~:,,,,, i£';:'f~t{~::;!:~;;~~;;{~~~;~::~~:;{ ") ) TRANSMIT AL LETTER CHECK LIST CIRCLE APPROPRIATE LETTERlPARAGRAPHS TO BE INCLUDED IN TRANSMITTAL LETTER WELL NAME ,~/.,f /~~ t:¡~A PTD# Zn~"" /13 CHECK WHAT APPLIES ADD-ONS (OPTIONS) MULTI LATERAL (If API number last two (2) digits are between 60-69) PILOT (PH) HOLE SPACING EXCEPTION DRY DITCH SAMPLE Rev: 07/1 0/02 C\jody\templates "CLUE" The permit is for a new wellbore segment of existing well Permit No, API No. Production should continue to be reported as a function' of the original API number, stated above. In accordance with 20 AAC 25.005(t), all records, data and logs acquired for the pilot hole must be clearly differentiated in both name (name on permit plus PH) and API number (50 70/80) from records, data and logs acquired for well (name on permit). The permit is approved subject to full compliance with 20 AAC 25.055. Approval to peñorate and produce is contingent upon issuance of a conservittion order approving a spacing exception. (Company Name) assumes the liability of any protest to the spacing exception that may occur. All dry ditch sample sets submitted to the Commission must be in no greater than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. WELL PERMIT CHECKLIST COMPANY FIELD & POOL ADMINISTRATION APPR DATE (Service Well Only) (Service Well Only) ENGINEERING APPR DATE ~ '/¿1{0'L (Service Well Only) GEOLOGY APPR DATE (Exploratory Only) Rev: 07/12/02 WELL NAME INIT CLASS 1. Permit fee attached. . . . . . . . . . . . . . . . . . . . . . . 2. Lease number appropriate. . . . . . . . . . . . . . . . . . . 3. Unique well name and number. . . . . . . . . . . . . . . . . 4. Well located in a defined pool.. . . . . . . . . . . . . . . . . 5. Well located proper distance from drilling unit boundary. . . . 6. Well located proper distance from other wells.. . . . . . . . . 7. Sufficient acreage available in drilling unit.. . . . . . . . . . . 8. If deviated, is well bore plat included.. . . . . . . . . . . . . . 9. Operator only affected party.. . ',' . . . . . . . . .. . . . . 10. Operator has appropriate bond in force. . . . . . . . . . . . . 11. Permit can be issued without conservation order. . . . . . . . 12. Permit can be issued without administrative approval.. . . . . 13. Well located w/in area & strata authorized by injection order#~ 14. All wells w/in y.¡ mile area of review identified. . . . . . . . .. 15. Conductor string provided. . . .. . . . . . . . . . . . . . . 16. Surface casing protects all known USDWs. . . . . . . . . . . 17. CMT vol ádequate to circulate on conductor & surf csg. . . . . 18. CMT vol adequate to tie-in long string to surf csg. . . . . . . . 19. CMT will cover all known productive horizons. . . . . . . .. . 20. Casing designs adequate for C, T, B& permafrost. . .. . . . 21. Adequate tankage or reserve pit.. . . . . . . . . . . . . . . . 22. If are-drill, has a 10-403 for abandonment been approved. . . 23. Adequate wellbore separation proposed.. . . . . .. . ; . . . 24. If diverter required, does it meet regulations. . . . . . . . . . 25. Drilling fluid program schematic & equip list adequate. . . . . 26. BOPEs, do they meet regulation. . . . . . . . . . . . . . . . 27. BOPE press rating appropriate; test to ~ SOO psig. 28. Choke manifold complies wlAPI RP-53 (May 84). . . . . . . . 29. Work will occur without operation shutdown. . . . . . . . . . . 30. Is presence of H2S gas probable... . . . . . . . . . . . . . . 31. Mechanical condition of wells within AOR verified. . . . . . . . 32. Permit can be issued w/o hydrogen sulfide measures. . . . . 33. Data presented on potential overpressure zones. . . . . . . . 34. Seismic analysis of shallow gas zones. . . . . . . . . . . . . 35. Seabed condition survey (if off-shore). . . . . . . . . . . . . . 36. Contact namelphone for weekly progress reports. . . . . . . . GEOLOGY: RPC PETROLEUM ENGINEERING: TEM RESERVOIR ENGINEERING JDH SFD- WGAVJ4A- G:\geology\perm its\checklist.doc PROGRAM: Exp - Dev - Redrll - Re-Enter - Serv - Wellbore seg - GEOL AREA UNIT# ON/OFF SHORE - Y N Y N Y N Y N Y N Y N Y N Y N Y N Y N Y N Y N Y N Y N -¥-N' ~NIA- ~ srd!eJ éfJN ~N @N -¥-N- A,((It.. &~ rY~ t41~~i ll.3 Pf1 <&~ ~-,f 2-L/fpç f?ÝZ" ~N ~.N'111- Y N Y N Y N Y N Y N ) ) UIC ENGINEER JBR MJW COMMISSIONER: COT DTS /'rJf t-/) ? /3 ~ ¿ Comments/lnstructions: WELL PERMIT CHECKLIST COMPANY AfJ,): WELL NAMEff/1;{ /$'-99AÞROGRAM: Exp - Dev ~ Redrll ~ Re-Enter - Serv - Wellbore seg- FIELD&POOL hý'o/>L"1 INITCLASS LÂu/ /-d~ï I' GEOLAREA fÇ'?r'} UNIT# /16,~~ ON/OFFSHORE~ ADMINISTRATION 1. Permit fee attached. . . . . . . . . . . . . . . . . . . . . . . Y N 2. Lease number appropriate. . . . . . . . . . . . . . . . . . . Y N 3. Unique well name and number. . . . . . . . . . . . . . . . . Y N 4. Well located in a defined pool.. . . . . . . . . . . . . . . . . Y N 5. Well located proper distance from drilling unit boundary. . . . Y N 6. Well located proper distance from other wells.. . . . . . . . . Y N APPR DATE 7. Sufficient acreage available in drilling unit.. . . . . . . . . . . Y N ß2.., ~4-:. 8. If deviated, is wellbore plat included.. . . . . . . . . . . . . . Y N ~ Uo.~..., 9. Operator only affected party.. . . . . . . . . . . . . . . . . . Y N 10. Operator has appropriate bond in force. . . . . . . . . . . . . Y N 11. Permit can be issued without conservation order. . . . . . . . Y N 12. Permit can be issued without administrative approval.. . . . . ,\) N (Service Well Only) 13. Well located w/in area & strata authorized by injection order#~' Y /, ,/I./14v (Service Well Only) 14. All wells wlin X mile area of review identified. . . . . . . . .. ./ N ' ENGINEERING 15. Conductor string provided. . . . . . . . . . . . . . . . . . . 4'--N- 16. Surface casing protects all known USDWs. . . . . . . . . . . -¥--N- . 17. CMT vol adequate to circulate on conductor & surf csg. . . . . -¥-N- ¡V / Æ 18. CMT vol adequate to tie-in long string to surf csg. . . . . . . . ¥---N-- ì, I 19. CMT will cover all know, n productive horizons. . . . . . . . . . ~ N Slot/ea, ~~: ~~:~~a~::~~~~;~~i~:~~~~ ~¡t:: ~ ~ :~r~~fr~~t.. : : : : : : 't) ~ ^' J, o'ýS Z IE S . 22. If a re-drill, has a 10-403 for abandonment been approved. . . fJ2. N q ((,10 L . 23. Adequate wellbore separation proposed.. . . . . . . . . . . . @ N 24. If diverter required, does it meet regulations. . . . . . . . . . -¥-N- tV/if- 25. Drilling fluid program schematic & equip list adequate. . . . . ~N ~Il fI-At ,M., k,( II. L )? P, ~ . 26. BOPEs, do they meet regulation. . . . . . . . . . . . . . . . N J~ f 27. BOPE press rating appropriate; test to 'S 5'00 psig. , N C ~C¡' ~c; '5500 f ç ¿ . I I 28. Choke manifold complies w/API RP-53 (May 84). . . . . . . . æ N UJ6A- ~ I ¿ O'L. 29. Work will occur without operation shutdown. . . . . . . . . . . W N 30. Is presence ofH2S gas probable.. . . . . . . . .. . . . . . . æ N 31. Mechanical condition of wells within AOR verified. . . . . . . . Y N N/It; Yði? nNA. APPR DATE (Service Well Only) GEOLOGY APPR DATE #- #Þz, (Exploratory Only) 32. Permit can be issued w/o hydrogen sulfide measures. . . . . 33. Data presented on potential overpressure zones. . . . . . . . 34. Seismic analysis of shallow gas zones. . . . . . . . . . . . . 35. Seabed condition survey (if off-shore). . . . . . . . . . . . . . 36. Contact name/phone for weekly progress reports. . . . . . . . GEOLOGY: RP~ UIC ENGINEER JBR COMMISSIONER: COT DTS ó{ )/710 2.. PETROLEUM ENGINEERING: TEM RESERVOIR ENGINEERING JDH .J~ Rev: 07/12/02 SFD- WGA w6k- MJW G:\geology\perm its\checklist.doc ) CommentslInstructions: ') ') Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process. but is part of the history fìle. To improve the readability of the Well History file and to simpHfy finding information, information of this nature is accumulated at the end of the file under APPEN.DIX. No special effort has been made to chronologically organize this category of information. ) aoa-IQ3 II ú:J 6(;) Sperry-Sun Drilling Services LIS Scan Utility $Revision: 3 $ LisLib $Revision: 4 $ Mon Mar 31 14:56:30 2003 Reel Header Service name.............LISTPE Date. . . . . . . . . . . . . . . . . . . . .03/03/31 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.................._..03/03/31 Origin...................STS Tape Name................UNKNOWN Continuation Number......01 Previous Tape Name.......UNKNOWN Comments.................STS LIS Writing Library. Scientific Technical Services Physical EOF Comment Record TAPE HEADER Prudhoe Bay Field MWD/MAD LOGS # WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: # JOB DATA 14-44A PBl 500292257371 BP Explration Sperry Sun 31-v]AR-03 (Alaska) Inc. JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 2 AK-MW-22168 J. SACK J. RALL MWD RUN 3 AK-MW-22168 P. ROGER J. RALL MWD RUN 4 AK-MW-22168 P. ROGER R. BORDES # SURFACE LOCATION SECTION: TO~^JNSHI P: R7lliGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: 9 ION l4E 2451 1617 .00 69.50 41.00 # WELL CASING RECORD 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 6.750 7.625 11608.0 4.750 5.500 12963.0 # REMARKS: 1. ALL DEPTHS ARE MEASURED DEPTHS (MD) UNLESS OTHERWISE NOTED. 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTHS (TVD) UNLESS OTHERWISE NOTED. 3. MWD RUN 1 DID NOT MAKE ANY FOOTAGE. NO DATA IS PRESENTED. ) ') 4. MWD RUNS 2-3 WERE DIRECTIONAL WITH DUAL GAMMA RAY (DGR) UTILIZING GEIGER-MUELLER TUBE DETECTORS. 5. MWD RUN 4 WAS DIRECTIONAL WITH DGR AND ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4). 6. DEPTH SHIFTING AND CORRECTION WAIVED PER THE E-MAIL OF 11/12/2002 FROM D. SCHNORR OF BP EXPLORATION (ALASKA) INC. 7. MWD RUNS 2-4 REPRESENT WELL 14-44A PBl WITH API # 50-029-22573-71. TI-HS WELL REACHED A TOT,AL DEPTH ('I'D) OF 14386' MD, 9070' TVD. SROP == SGRC == SEXP == SESP == SEMP == SEDP = SFXE == SLIDE $ SMOOTHED RATE OF PENETRATION liiJHILE DRILLING SMOOTHED GAMMA RAY COMBINED- GEIGER-MUl,LER TUBE DETECTORS SMOOTHED PHASE SHIFT DERIVED RESISTIVITY (EXTRl\ SHP,LLOW SPACING) SHOOTHED PHASE SHIFT DERIVED RESISTIVITY (SHALLOW SPACING) SMOOTHED PHASE SHIFT DERIVED RESISTIVITY (MEDIU11 SPACING) SMOOTHED PHASE SHIFT DERIVED RESISTIVITY (DEEP SPACING) SMOOTHED FORMATION EXPOSURE TIHE == NON-ROTATED INTERVALS REFLECTING BIT DEPTHS File Header Service name.............STSLIB.OOl Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......03/03/31 Maximum Physical Record..65535 File Type............... .LO Previous File Name.......STSLIB.OOO Comment Record FILE HEADER FILE NUMBER: EDITED HERGED MWD Depth shifted and DEPTH INCREHENT: # FILE SUMMARY PBU TOOL CODE GR ROP FET RPD RPH RPS RPX $ 1 clipped curves; all bit runs merged. .5000 START DEPTH 11540.0 11608.5 12940.0 12940.0 12940.0 12940.0 12940.0 STOP DEPTH 14319.0 14385.5 14328.5 14328.5 14328.5 14328.5 14328.5 # BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH $ # MERGED PBU MWD MWD MWD $ DATA SOURCE TOOL CODE BIT RUN NO MERGE TOP 2 11540.0 3 12015.5 4 12900.0 MERGE BASE 120ï1.0 12963.0 14385.5 # REMARKS: MERGED MAIN PASS. $ # 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 DEPT ROP GR RPX RPS RPM RPD FET MWD MWD MWD MWD MWD MWD MWD Units FT FT/H API OHMM OHMM OHMM OHM:M HOUR Size Nsam Rep 4 1 68 4 1 68 4 1 68 4 1 68 4 1 68 4 1 68 4 1 68 4 1 68 Code Channel 1 2 Service Order Offset 0 4 8 12 16 20 24 28 3 4 5 6 7 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 11540 14385.5 12962.8 5692 11540 14385.5 ROP MWD FT/H 0.05 253.38 50.1886 5555 11608.5 14385.5 GR MWD API 21.04 539.87 143.355 5470 11540 14319 RPX HWD OHMH 0.35 2000 44.7781 2778 12940 14328.5 RPS MWD OHM:M 0.1 2000 85.0673 2778 12940 14328.5 RPM MWD OHMM 0.48 2000 127 .156 2778 12940 14328.5 RPD MWD OHl'1M 1.11 2000 113.362 2778 12940 14328.5 FET MWD HOUR 0.73 76.82 4.13311 2778 12940 14328.5 First Read~ng For Entire Fi1e..........11540 Last Reading For Entire File_______.-__14385.5 File Trailer Service name.............STSLIB.001 Service Sub Level Name... Version Number...........1. 0.0 Date of Generation.......03/03/31 Maximum Physical Record..65535 File Tjrpe........ '" .. .. . 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.......03/03/31 Maximum Physical Record..65535 Fi 1 e 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 START DEPTH ROP 11540.0 GR 11540.0 $ 2 header data for each bit run in separate files. 2 .5000 STOP DEPTH 12071.0 12015.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): 19-0CT-02 Insite 66.37 Memory 12071. 0 ) TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY $ # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER! S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): 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 M.IJ..TRIX: 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 Uni ts . . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O 11550.0 12071.0 56.3 64.2 TOOL NUMBER 129046 6.750 11608.0 Water 11.40 60.0 9.8 380 4.4 Based .000 .000 .000 .000 .0 170.4 .0 .0 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 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 11540 12071 11805.5 1063 11540 12071 ROP MWD020 FT/H 0.05 119.23 30.1318 1063 11540 12071 GR MWD020 API 55.92 149.6 115.946 951 11540 12015 First Reading For Entire File..........11540 Last Reading For Entire File...........12071 File Trailer Service name.............STSLIB.002 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......03/03/31 ) Maximum Physical Record..65535 Fi 1 e Type................ LO Next File Name...........STSLIB.003 Physical EOF File Header Service name..........,.,. .STSLIB. 003 Service Sub Level Name... Version Number..... . . . . . .1.0.0 Date of Generation.......03/03/31 Maximum Physical Record..65535 File Type................ LO Previous File Name.......STSLIB.002 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE GR ROP $ 3 ') header data for each bit run in separate files. 3 .5000 START DEPTH 12015.5 12071.5 STOP DEPTH 12910.0 12963.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFT1iJARE 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 BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY $ # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): 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): 1f TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # 21-0CT-02 Insite 66.37 :¡V¡emory 12963.0 12071.0 12963.0 67.9 72.8 TOOL NUMBER 129046 6.750 11608.0 ¡^later 11.40 77.0 9.5 400 4.8 Based .000 .000 .000 .000 .0 190.0 .0 .0 ) REl--lARKS : $ # Data Format Specification Record Data Record Type..................O Data Specification Block Type.....O Logging Direction................ . Down Optical log depth units.. ........ . Feet Data Reference Point..............Undefined Frame Spacing.....................60 .1IN Max frames per record.............Undefined Absent value...................... -999 Depth Units.... . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O Name Service Order Units Size Nsam Rep Code Offset Channel DE PT FT 4 1 68 0 1 ROP }~iD030 FT/H 4 1 68 4 2 GR MWD030 API 4 1 68 8 3 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 12015.5 12963 12489.3 1896 12015.5 12963 ROP MWD030 FT/H 0.25 122.,96 47.,9996 1784 12071.5 12963 GR MWD030 API 54.34 163.46 132.292 1790 12015.5 12910 First Reading For Entire File..........12015.5 Last Reading For Entire File...........12963 File Trailer Service name.............STSLIB.OO3 Service Sub Level Name... Version Number...........l.0.0 Date of Generation.......03/03/31 Maximum Physical Record..65535 Fi 1 e Type................ LO Next File Name...........STSLIB.OO4 Physical EOF File Header Service name.............STSLIB.004 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation.......03/03/31 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 SUMl'1ARY VENDOR TOOL CODE GR RPD RPM RPS RPX FET ROP $ 4 header data for each bit run in separate files. 4 .5000 START DEPTH 12900.0 12940.0 12940.0 12940.0 12940.0 12940.0 12963.5 STOP DEPTH 14319.0 14328.5 14328.5 14328.5 14328.5 14328.5 14385.5 # LOG HEADER DATA ) DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): 'I'D DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: HAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE GM EWR4 $ BOTTOM) TOOL TYPE Dual GR 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 (OH~1) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL l'-ffiTRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type..................O Data Specification Block Type.....O Logging Direction.................Down Optical log depth units...........Feet Data Reference Point....... .......Undefined Frame Spacing.................... .60 .1IN Max frames per record.............Undefined Absent value...................... -999 Depth Units....................... Datum Specification Block sub-type...O 27-0C'I'-02 Insite 4.3 Memory 14386.0 12963.0 14386.0 73.1 89.8 TOOL NUMBER 129046 125631 4.750 12963.0 Flo Pro 8.60 58.0 9.0 10600 6.0 .350 .170 .230 .510 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 Name Service Unit DE PT FT ROP MWD040 FT/H Min 12900 2.31 Max 14385.5 253.38 Mean Nsam 13642.8 2972 60.2033 2845 ) 76.0 168.0 76.0 76.0 First Reading 12900 12963.5 Last Reading 14385.5 14385.5 . . ') ) GR MWD040 API 21. 04 539.87 159.639 2750 12900 14319 RPX MWD040 oHMM 0.35 2000 44.7781 2778 12940 14328.5 RPS MWD040 OHMM 0.1 2000 85.0673 2778 12940 14328.5 RPM MWD040 OHMM 0.48 2000 127.156 2778 12940 14328.5 RPD MWD040 OHMM 1.11 2000 113.362 2778 12940 14328.5 FET MWD040 HOUR 0.73 76.82 4.13311 2778 12940 14328.5 First Reading For Entire File..........12900 Last Reading For Entire File...........14385.5 File Trailer Service name.............STSLIB.004 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation.......03/03/31 Maximum Physical Record..65535 Fi 1 e Type................ LO Next File Name...........STSLIB.OO5 Physical EOF Tape Trailer Service name.............LISTPE Date. . . . . . . . . . . . . . . . . . . . .03/03/31 Origin. . . . . . . . . . . . . . . . . . . STS Tape Name................ UNKNOíriJN Continuation Number......01 Next Tape Name.... ,.., . ... UNKNOWN Comments. .. .. . . . . . .. . . . . . STS LIS Writing Library. Scientific Technical Services Reel Trailer Service name......_......LISTPE Da t e. . . . . . . . . . . . . . . . . . . . . 03/03/ 31 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 ') Sperry-Sun Drilling Services LIS Scan Utility $Revision: 3 $ LisLib $Revision: 4 $ Mon Mar 31 14:01:43 2003 Reel Header Service name.............LISTPE Date. . . . . . . . . . . . . . . . . . . . .03/03/31 Or i gin. . . . . . . . . . . . . . . . . . . ST S Reel Name................ UNKNOWN Continuation Number......01 Previous Reel Name.......UNKNOWN Comments.................STS LIS Tape Header Service name.............LISTPE Date. . . . . . . .. . . . . . . . . . .. . 03/ 03/31 Origin. . . . . . . .. . . . . . . . . . . STS Tape Name................UNKNOWN Continuation Number......01 Previous Tape Name.......UNKNOWN Comments.................STS LIS Physical EOF Comment Record TAPE HEADER Prudhoe Bay Field MWD/MAD LOGS # WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: # JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 2 AK-MW-22168 J. SACK J.RALL JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 5 AK-MW-22168 P. ROGER R. BORDES JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 8 AK-MW-22168 J. BOBBITT R. BORDES # SURFACE LOCATION SECTION: TOWNSHIP: R.~GE : FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LE\rEL: # WELL CASING RECORD Writing Library. Writing Library. 14-44A 500292257301 BP Exploration Sperry Sun 31-MAR-03 MWD RUN 3 AK-MW-22168 P. ROGER J. RALL MWD RUN 6 AK-MW-22168 S. LATZ R. BORDES 9 ION 14E 2451 1617 .00 69.50 41.00 ') Scientific Technical Services Scientific Technical Services (Alaska) Inc. MWD RUN 4 AK-MW-22168 P. ROGER R. BORDES MWD RUN 7 AK-M\-'V-22168 J-. BOBBITT R. BORDES OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) dOd-lCJ3 1110(03 ) ) 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING 6.750 4.750 7.625 5.500 11608.0 12963.0 # REMARKS: 1. ALL DEPTHS ARE MEASURED DEPTHS (MD) UNLESS OTHERWISE NOTED. 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTHS (TVD) UNLESS OTHERWISE NOTED. 3. MWD RUN 1 DID NOT MAKE ANY FOOTAGE. NO DATA IS PRESENTED. 4. MWD RUNS 2-3 WERE DIRECTIONAL WITH DUAL GAMMA RAY (DGR) UTILIZING GEIGER-MUELLER TUBE DETECTORS. 5. ~mD RUN 4 WAS DIRECTIONAL WITH GAMMA MODULE (GM) UTILIZING GEIGER-MUELLER TUBE DETECTORS, AND ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4). 6. THE DECISION WAS MADE TO OPEN HOLE SIDETRACK AT 13100' MD, 8976' TVD. THE OLD WELLBORE IS 14-44A PBI AND THOSE DATA ARE PRESENTED ELSEWHERE. 7. MWD RUNS 5-8 WERE DIRECTIONAL tiUTH GM l\ND EWR4. 6. DEPTH SHIFTING AND CORRECTION WAIVED PER THE E-MAIL OF 11/12/2002 FROM D. SCHNORR OF BP EXPLORATION (ALASKA) INC. 7. MWD RUNS 2-8 REPRESENT WELL 14-44A WITH API # 50-029-22573-01. THIS WELL REACHED A TOTAL DEPTH (TD) OF 15280' MD, 9061' TVD. SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING SGRC = SMOOTHED GAMMA RAY COMBINED - GEIGER-MULLER TUBE DETECTORS SEXP = SMOOTHED PHASE SHIFT DERIVED RESISTIVITY (EXTRA SHALLOW SPACING) SESP = SMOOTHED PHASE SHIFT DERIVED RESISTIVITY (SHALLOW SPACING) SEMP = SMOOTHED PW\SE SHIFT DERIVED RESISTIVITY (MEDIUM SPACING) SEDP = SMOOTHED PHASE SHIFT DERIVED RESISTIVITY (DEEP SPACING) SFXE = SMOOTHED FORMATION EXPOSURE TIME SLIDE NON-ROTATED INTERVALS REFLECTING BIT DEP'I'HS $ File Header Service name.............STSLIB.001 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation.......03/03/31 Maximum Physical Record..65535 File Type................ LO Previous File Name.......STSLIB.OOO Comment Record FILE HEADER FILE NUMBER: EDITED MERGED MWD Depth shifted and DEPTH INCREl'vlENT: # FILE SUMl'vll\RY PBU TOOL CODE SGRC SROP SFXE SEDP SEMP SESP SEXP $ 1 clipped curves; all bit runs merged. .5000 START DEPTH 11540.0 11608.0 12950.0 12950.0 12950.0 12950.0 12950.0 STOP DEPTH 15229.5 15279.5 15242.0 15242.0 15242.0 15242.0 15242.0 # BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (l'vlEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH $ # ) ) DATA SOURCE TOOL CODE MERGED PBU MWD MWD Mt^1D MWD M'¡r'JD IvIWD ~\¡D $ BIT RUN NO 2 3 4 5 6 7 8 MERGE TOP 11540.0 12015.5 12900.0 13034.0 13845.0 14169.0 14327.0 MERGE BASE 12071.0 12963.0 14328.5 13910.0 14238.0 14387.0 15280.0 # REMARKS: MERGED MAIN PASS. $ # 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 IvIax 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 OHM,H 4 1 68 24 7 FET MWD HOUR 4 1 68 28 8 Fi rst Last Name Service Unit Hin Hax Mean Nsam Reading Reading DEPT FT 11540 15279.5 13409.8 7480 11540 15279.5 ROP Mtr'JD FT/H 0.02 266.62 59.4273 7344 11608 15279.5 GR MWD API 14.91 509.16 101. 649 7224 11540 15229.5 RPX MWD OHMM 0.22 2000 34.7743 4585 12950 15242 RPS MWD OHMM 0.1 2000 47.3464 4585 12950 15242 RPM M\^ID OHMM 0.27 2000 49.1183 4468 12950 15242 RPD MWD OHMM 0.37 2000 166.494 4585 12950 15242 FET MWD HOUR 0.2904 83.1967 4.34107 4585 12950 15242 First Reading For Entire File..........11540 Last Reading For Entire File...........15279.5 File Trailer Service name.............STSLIB.OO1 Service Sub Level Name... Version Number. ..........1.0.0 Date of Generation.......03/03/31 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.......03/03/31 Haximum Physical Record..65535 File Type................ LO Previous File Name.......STSLIB.OO1 ) Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE GR ROP $ 2 ) header data for each bit run in separate files. 2 .5000 START DEPTH 11540.0 11608.0 STOP DEPTH 12015.0 12071.0 # 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 BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY $ # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH 1FT): # 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): ¡VIUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type..................O Data Specification Block Type.....O Logging Direction.................Down Optical log depth units...........Feet Data Reference Point..............Undefined Frame Spacing.....................60 .1IN Max frames per record.............Undefined Absent value..................... .-999 Depth Units....................... Datum Specification Block sub-type...O 19-0CT-02 Insite 66.37 Memory 12071. 0 11540.0 12071.0 56.3 64.2 TOOL NUMBER 129046 6.750 11608.0 Water 11. 40 60.0 9.8 380 4.4 Based .000 .000 .000 .000 .0 170.4 .0 .0 Name Service Order Units Size Nsam Rep Code Offset Channel ) ) DEPT ROP MWD020 GR MWD020 FT FT/H API 4 4 4 1 68 1 68 1 68 0 4 8 1 2 3 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 11540 12071 11805.5 1063 11540 12071 ROP MWD020 FT/H 0.05 102.01 23.6713 927 11608 12071 GR MWD020 API 55.92 149.6 115.946 951 11540 12015 First Reading For Entire File......... .11540 Last Reading For Entire File...........12071 File Trailer Service name.............STSLIB.002 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......03/03/31 Maximum Physical Record..65535 Fi 1 e TY'Pe................ LO Next File Name...........STSLIB.003 Physical EOF File Header Service name... ..........STSLIB.003 Service Sub Level Name... Version Number...........l.0.0 Date of Generation.......03/03/31 Maximum Physical Record..65535 File Type................ 1..0 Previous File Name.......STSLIB.002 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE GR ROP $ 3 header data for each bit run in separate files. 3 .5000 START DEPTH 12015.5 12071.5 STOP DEPTH 12910.0 12963.0 # LOG HEADER D~rA 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: 21-0CT-02 Insite 66.37 Memory 12963.0 12071.0 12963.0 67.9 72.8 # TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL G.ì.\MMA RAY $ TOOL NU¡V¡BER 129046 # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): 6.750 11608.0 ) ) # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: Based Water 11.40 77.0 9.5 400 4.8 .000 .000 .000 .000 .0 190.0 .0 .0 # NEUTRON TOOL M,ZI,.TRIX: IVlATRIX 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 DE PT FT 4 1 68 0 1 ROP MWD030 FT/H 4 1 68 4 GR MWD030 API 4 1 68 8 3 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 12015.5 12963 12489.3 1896 12015.5 12963 ROP MWD030 FT/H 0.25 122.96 47.9996 1784 12071.5 12963 GR MWD030 API 54.34 163.46 132.292 1790 12015.5 12910 First Reading For Entire File..........12015.5 Last Reading For Entire File...........12963 File Trailer Service name.............STSLIB.OO3 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......03/03/31 Maximum Physical Record..65535 File Type................ LO Next File Name...........STSLIB.004 Physical EOF File Header Service name.............STSLIB.OO4 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......03/03/31 Maximum Physical Record..65535 File Type................ LO Previous File Name.......STSLIB.003 Comment Record FILE HEADER FILE NUJ'-iBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE GR RPX RPS RPM RPD FET ROP $ 4 ) header data for each bit run in separate files. 4 .5000 STJ\RT DEPTH 12900.0 12900.0 12900.0 12900.0 12900.0 12900.0 12963.5 STOP DEPTH 14319.0 14328.5 14328.5 14328.5 14328.5 14328.5 13100.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE GM EWR4 $ BOTTOM) TOOL TYPE Dual GR ELECTROMAG. RESIS. 4 # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type..................O Data Specification Block Type.....O Logging Direction................ . Dovm Optical log depth units...........Feet Data Reference Point..............Undefined 27-0CT-02 Insite 4.3 Memory 13100.0 12963.0 13100.0 73.1 89.8 TOOL NUMBER 129046 125631 4.750 12963.0 Flo Pr:o 8.60 58.0 9.0 10600 6.0 .350 .140 .230 .510 76.0 204.0 76.0 76.0 ') ') Frame Spacing.....................60 .1IN Max frames per record.............Undefined Abs ent val ue. . . . . . . . . . . . . . . . . . . . . . - 999 Depth Units....................... Datum Specification Block sub-type...O Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD040 FT/H 4 1 68 4 2 GR MWD040 API 4 1 68 8 3 RPX MWD040 OHMM 4 1 68 12 4 RPS MWD040 OHMM 4 1 68 16 5 RPM MWD040 OHM:M 4 1 68 20 6 RPD MIi"VD040 OHM:M 4 1 68 24 7 FET MWD040 HOUR 4 1 68 28 8 First Last Name Service Un,i t Min Max Mean Nsam Reading Reading DEPT FT 12900 14328.5 13614.3 2858 12900 14328.5 ROP MWD040 FT/H 3.09 74.17 28.7327 274 12963.5 13100 GR MWD040 API 21. 04 539.87 159.639 2750 12900 14319 RPX MWD040 Om.1M 0.17 2000 43.8936 2858 12900 14328.5 RPS MWD040 OHMM 0.1 2000 102.968 2858 12900 14328.5 RPM MWD040 OHM:M 0.16 2000 141. 033 2858 12900 14328.5 RPD MWD040 OHJv!M 0.13 2000 139.983 2858 12900 14328.5 FET MHD040 HOUR 0.7316 76.8172 6.10987 2858 12900 14328.5 First Reading For Entire File_____.____12900 Last Reading For Entire File...........14328.5 File Trailer Service name.............STSLIB.004 Service Sub Level Name... Version Number...........l.0.0 Date of Generation.......03/03/31 Maximum Physical Record..65535 File Type................ LO Next File Name...........STSLIB.005 Physical EOF File Header Service name.............STSLIB.005 Service Sub Level Name... Version Number...........1. 0.0 Date of Generation.......03/03/31 Maximum Physical Record..65535 Fil e Type................ LO Previous File Name.......STSLIB.004 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREIvIENT: # FILE SUMMARY VENDOR TOOL CODE GR RPS FET RPD RPX RPIvI ROP $ 5 header data for each bit run in separate files. 5 .5000 START DEPTH 13034.0 13043.0 13043.0 13043.0 13043.0 13043.0 13100.5 STOP DEPTH 13844.5 13853.0 13853.0 13853.0 13853.0 13853.0 13910.0 ) LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DO\nJNHOLE SOFTWPI.RE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTE,RVAI, (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINH1UM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE GM EWR4 $ BOTTOM) TOOL TYPE Dual GR 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: lVIUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type.................. 0 Data Specification Block Type.....O Logging Direction................ . DOVin 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 ) 30-0CT-02 Insite 4.3 Memory 13910.0 13100.0 13910.0 65.8 95.6 TOOL NUMBER 12.9046 125631 4.750 12.963.0 FIo Pro 8.50 41. 0 8.8 17000 6.4 .350 .140 .230 .510 76.0 204.0 76.0 76.0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD050 FT/H 4 1 68 4 ') GR lVIWD050 API 4 1 68 8 3 RPX HWD050 OHMM 4 1 68 12 4 RPS MWD050 0 I-IHIvl 4 1 68 16 5 RPM MWD050 OHMM 4 1 68 20 6 RPD MWD050 OHMM 4 1 68 24 7 FET MWD050 HOUR 4 1 68 28 8 Name Service Unit DE PT FT Min 13034 Max 13910 Mean Nsam 13472 1753 First Reading 13034 Last Reading 13910 ) ') ROP M\ì'JD050 FT/H 0.02 200.34 75.1941 1620 13100.5 13910 GR MWD050 API 18.55 480.87 62.6936 1622 13034 13844.5 RPX MWD050 OHMM 0.22 1273.69 15.4327 1621 13043 13853 RPS MWD050 OHMM 0.25 1926.19 20.5876 1621 13043 13853 RPM M'il'JD050 OHMM 0.27 1827.92 22.6151 1621 13043 13853 RPD MWD050 OHMM 0.37 1480.09 21. 9493 1621 13043 13853 FET MWD050 HOUR 0.8193 83.6574 8.24888 1621 13043 13853 First Reading For Entire File..........13034 Last Reading For Entire File...........13910 File Trailer Service name.............STSLIB.005 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......03/03/31 Maximum Physical Record..65535 File Type................ LO Next File Name...........STSLIB.006 Physical EOF File Header Service name.............STSLIB.006 Service Sub Level Name... Version Number...........l.0.0 Date of Generation.......03/03/31 Maximum Physical Record..65535 File Type............... .LO Previous File Name.......STSLIB.005 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE GR FET RPD RPM RPS RPX ROP $ 6 header data for each bit run in separate files. 6 .5000 START DEPTH 13845.0 13850.0 13850.0 13850.0 13850.0 13850.0 13910.5 STOP DEPTH 14168.5 14185.0 14185.0 14185.0 14185.0 14185.0 14238.0 # 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: 31-0CT-02 Insite 4.3 Memory 14238.0 13910.0 14238.0 89.4 91. 4 # TOOL STRING (TOP TO VENDOR TOOL CODE GM EWR4 $ BOTTOM) TOOL TYPE Dual GR ELECTROMAG. RESIS. 4 TOOL NUMBER 72829 14 4955 # BOREHOLE AND CASING DATA ') ) OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): 4.750 12963.0 # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT IYIAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: FIo Pro 8.50 44.0 9.0 19000 6.0 .350 .150 .230 .510 76.0 186.0 76.0 76.0 # NEUTRON TOOL MATRIX: IYIATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type..................O Data Specification Block Type.....O Logging Direction.................Down Optical log depth units...........Feet Data Reference Point..............Undefined Frame Spacing.....................60 .1IN Max frames per record.............Undefined Absent value...................... -999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD060 FT/H 4 1 68 4 2 GR MWD060 API 4 1 68 8 3 RPX MWD060 OHMM 4 1 68 12 4 RPS MWD060 OHMM 4 1 68 16 5 RPH MWD060 OHMM 4 1 68 20 6 RPD MWD060 OHMM 4 1 68 24 7 FET MWD060 HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 13845 14238 14041. 5 787 13845 14238 ROP MWD060 FT/H 1.17 266.62 82.1298 656 13910.5 14238 GR MWD060 API 14.91 144.51 44.7141 648 13845 14168.5 RPX HWD060 OHMM 4.64 16.67 10.0642 671 13850 14185 RPS MWD060 OHMM 5.3 53.99 11.1635 671 13850 14185 RPM MWD060 OHMM 5.8 2000 17.3835 671 13850 14185 RPD MWD060 OHMM 4.88 36 12.0212 671 13850 14185 FET MWD060 HOUR 0.3995 31. 2321 6.64928 671 13850 14185 First Reading For Entire File..........13845 Last Reading For Entire File...........14238 File Trailer Service name............. STSLIB. 006 Service Sub Level Name... Version Number.. .........1.0.0 Date of Generation.......03/03/31 Maximum Physical Record..65535 File Type............... .LO Next File Name.... .... ...STSLIB.OO7 ') Physical EOF File Header Service name.............STSLIB.OO7 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......03/03/31 Maximum Physical Record..65535 File T'}rpe...... ..... . ... . LO Previous File Name.......STSLIB.OO6 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE GR RPS RPX RPM RPD FET ROP $ 7 ) header data for each bit run in separate files. 7 .5000 START DEPTH 14169.0 14185.5 14185.5 14185.5 14185.5 14185.5 14238.5 # LOG HEl\DER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE GM EWR4 $ STOP DEPTH 14327.0 14339.0 14339.0 14339.0 14340.0 14339.0 14387.0 BOTTOM) TOOL TYPE Dual GR 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 ]'vlATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # 01-NOV-02 Insite 4.3 Memory 14387.0 14238.0 14387.0 89.7 89.9 TOOL NUMBER 93091 144955 4.750 12963.0 Flo Pro 8.50 51.0 9.2 14000 7.2 .380 .140 .200 .550 73.0 204.0 73.0 73.0 ') ) TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type..................O Data Specification Block Type.. ...0 Logging Direction................. DOvm 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 MíÑD070 FT/H 4 1 68 4 2 GR MWD070 API 4 1 68 8 3 RPX MWD070 OHMM 4 1 68 12 4 RPS MWD070 OHMM 4 1 68 16 5 RPM MWD070 OHMM 4 1 68 20 6 RPD MWD070 OHMM 4 1 68 24 7 FET MWD070 HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 14169 14387 14278 437 14169 14387 ROP MWD070 FT/H 1.3 156.87 77.8554 298 14238.5 14387 GR MWD070 API 24.99 44.51 34.4679 317 14169 14327 RPX MWD070 Om"IM 6.22 17.9 12.3377 308 14185.5 14339 RPS MWD070 OHMM 8.57 18.61 14.1466 308 14185.5 14339 RPM MWD070 OHMM 10.75 21.09 15.0614 308 14185.5 14339 RPD M'iI'JD070 OHMM 12.53 20.23 15.3595 310 14185.5 14340 FET JvIWD070 HOUR 0.6384 28.5701 10.9238 308 14185.5 14339 First Reading For Entire File..........14169 Last Reading For Entire File.... .......14387 File Trailer Service name.............STSLIB.007 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.. .....03/03/31 Maximum Physical Record..65535 Fil e Type................ LO Next File Name...........STSLIB.008 Physical EOF File Header Service name...... .......STSLIB.008 Service Sub Level Name... Version Number....... ....1.0.0 Date of Generation.......03/03/31 Maximum Physical Record..65535 File Type............... .LO Previous File Name.......STSLIB.007 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: 8 header data for each bit run in separate files. 8 .5000 ) # FILE SUMMARY VENDOR TOOL CODE GR RPD RPM RPS RPX FET ROP $ START DEPTH 14327.0 14330.5 14330.5 14330.5 14330.5 14330.5 14387.5 STOP DEPTH 15229.5 15242.0 15242.0 15242.0 15242.0 15242.0 15280.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTW;Z:\RE VERSION: DOI~HOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TO DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: HAe'ZIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE GM EWR4 $ BOTTOM) TOOL TYPE Dual GR 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): HUD PH: HUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERHPERATURE: MUD FILTRATE AT MT: HUD CAKE AT HT: # 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.............Unde£ined .A.bsent value...................... - 9 9 9 Depth Units....................... Datum Specification Block sub-type...O ) 04-NOV-02 Insite 4.3 Jv!emory 15280.0 14387.0 15280.0 83.1 93.9 TOOL NUMBER 93091 14 4 955 4.750 12963.0 FIo Pro 8.50 51. 0 9.2 14000 '7.2 .400 .260 .380 .430 76.0 138.0 76.0 76.0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD080 FT/H 4 1 68 4 2 ) ) GR !v1WD080 API 4 1 68 8 3 RPX MWD080 OHMM 4 1 68 12 4 RPS MWD080 OHMM 4 1 68 16 5 RPM M1ì\TD 0 8 0 OHMM 4 1 68 20 6 RPD H\i'JD080 OHMM 4 1 68 24 7 FET MWD080 HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 14327 15280 14803.5 1907 14327 15280 ROP MWD080 FTíH 0.71 166.3 68.3833 1786 14387.5 15280 GR MWD080 API 24.39 509.16 135.374 1650 14327 15229.5 RPX MWD080 OHMM 0.67 2000 65.3563 1824 14330.5 15242 RPS MWD080 OHMM 0.69 2000 84.7484 1824 14330.5 15242 RPM MWD080 OHMM 0.81 2000 80.1232 1824 14330.5 15242 RPD MWD080 OHMM 1.39 2000 374.527 1824 14330.5 15242 FET IvIWD080 HOUR 0.2904 23.6706 2.93603 1824 14330.5 15242 First Reading For Entire File..........14327 Last Reading For Entire Fi1e...........15280 File Trailer Service name.............STSLIB.008 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......03í03í31 Maximum Physical Record..65535 File Type................ LO Next File Name...........STSLIB.009 Physical EOF Tape Trailer Service name.............LISTPE Date.....................03!03!31 Origin. . . . . . . . . . . . . . . . . . . STS Tape Name................UNKNOWN Continuation Number......01 Next Tape Name...........UNKNOWN Comments.................STS LIS Writing Library. Scientific Technical Services Reel Trailer Service name.............LISTPE Date. . . . . . . . .... . . .. . . . . . 03! 03! 31 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