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192-123
XHVZE Pages NOT Scanned in this Well History File This page identifies those items that were not scanned during the initial scanning project. They are available in the original file and viewable by direct inspection. /~_/"/~ File Number of Well History File PAGES TO DELETE Complete RESCAN [] Color items - Pages: Grayscale, halftones, pictures, graphs, charts- Pages: Poor Quality Original - Pages: [] Other- Pages: DIGITAL DATA [] Diskettes, No. [] Other, No/Type OVERSIZED .~ [] Logs-of various kinds . -: Other COMMENTS: Scanned by: Bevedy Diann~~>athan Lowell _ _ [] TO RE-SCAN Notes: Re-Scanned by: Bevedy Dianna Vincent Nathan Lowell Date: Is/ • • by BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB-20 Post Office Box 196612 Anchorage, Alaska 99519-6612 Dec 07, 2009 ~~G ~ : 2019 Mr. Tom Maunder Alaska Oil and Gas Conservation Commission ~ ~= ~~ '~~` ~ ~~'°:~~:°~sl~~ 333 West 7t~ Avenue ~ "`~' ' ~'~~' Anchorage, Alaska 99501 ~ ~~-- jai Subject: Corrosion Inhibitor Treatments of GPB DS 14 ~ nn ~' ~ ~T Dear Mr. Maunder, 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-OSA 2022100 500292033001 Sealed Conductor NA NA 1a-09B 1820340 500292053402 Sealed Conductor NA NA 14-t0 1801300 500292052800 Sealed Conductor NA NA 14-11A 2051260 500292052901 Sealed Conductor NA NA to-12 1811090 500292063100 Sealed Conductor NA NA 14-13 1811010 500292062400 Sealed Conductor NA NA 14-14 1811020 500292062500 Sealed Conductor NA NA 14-15 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 14-20 1810700 500292059800 Sealed Conductor NA NA t4-21A 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 14-36 1831630 500292103900 NA 0.7 NA 3.40 10/20/2009 14-37 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 1 r~ E ~._. Schluherger N0.4903 Alaska Data & Consulting Services , , ~, ~~•{{ - I r•. ~ {fir; Company: State of Alaska 2525 Gambell Street, Suite 400 L.~+'wMd'~+~L4R~ `~~~r ~~ _ ~t~~#~ Alaska Oil & Gas Cons Comm Anchorage, AK 99503-2838 Attn: Christine Mahnken ATTN: Beth 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Wnll Inh u ~ _ 09/23/08 L-216 10687773 MDT -- -- -- _-- 05/09/04 v 1~. 1 L-204 11212880 MDT ~ a ~ 07/24/06 1 1 14-22A 11999036 PPROF W/FLOW SCAN IMAGER / '3(0 08/17/08 1 1 H-11 12017507 USIT 08/09/08 1 1 D-22C 11963190 USIT _ "1 ;~ (a 08/20/08 1 1 NK-10 12066549 MEM I~lJECTION PROFILE C) - ( j g'~ 09/11/08 1 1 09-28A 12031499 RST - 08/01/08 1 1 N-10A 12005225 MCNL ~ ~ 08/20/08 1 1 05-236 40016995 OH MWD/LWD EDIT 05/27/08 2 1 n~ cwc.c wnvur.u.. r.~..r .-..- ..r...~ .... ...... ...... ...~ ~--.._..._._ _.._ ___-- -_ __. __ _.-__ .._..........~.....~ ......~.. . .... .,.........a e...v nom. vn.~u~~a VI\G VVf ~ oha.n i v: BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Date Delivered: Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-283 ATTN: Beth Received by: ~ ~~ • b~~ os/2~oa ~~ ~c~tun~berger Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth wpu Inh ~ N0.4843 Company: State of Alaska Alaska Oil & Gas Cons Comm ~~~~N~~ S r ~ ~ ~ ~~~~ Attn: Christine Mahnken 13t C 333 West 7th Ave, Suite 100 Anchorage, AK 99501 1 A. H-31 11999035 USIT ~} G - -~G- ~ - _-- 08/16/08 v 1v 1 14-22A 11999036 PPROF W/FSI - 08/17/08 1 1 13-34 11676963 USIT a - _ 08/18/08 1 1 H-35 11970840 RST ., , G( 3 08/12/08 1 1 G-16 11982438 RST _ ~ C( 06/21/08 1 1 L1-09 12017501 CH EDIT (SONIC SCANNER) '~ 06/06/08 1 1 . ~~..~~..~...... ..rrr.wr .•.-vr•• • r• v~.••~••~M ~,~~•1GI Vf11~11•V V19G VVri GF\Vfi 1V: BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 ~,, 900 E. Benson Blvd. n Anchorage, Alaska 99508 :. Date Delivered: AR !C' c~p '7 ~t~c~S~(:t Ci)1 it ~'ai~S 1,~f7r~7. ~.C>trltrilSSlOr! ;~I~Gh~arage Alaska Data & Consulting Services 2525 Gambell Street, Suite 4 Anchorage, AK 99503-2838 ATTN: Beth Received by: • • i~ RE: UNDER EVALUATION: 14-22A (PTD #1921230) TxIA Communication and sustai... Page 1~~~ • Regg, James B (DOA) From: NSU, ADW Well Integrity Engineer [NSUADWWeIIlntegrityEngineer@BP.com] Sent: Wednesday, July 02, 2008 7:29 PM 1 ~~ To: Regg, James B (DOA); Maunder, Thomas E (DOA); GPB, Area Mgr Central (GC1/3/FS3); GPB, FS3 OTL; GPB, FS3 DS Ops Lead; Engel, Harry R; NSU, ADW Well Operations Supervisor; GPB, Wells Opt Eng; GPB, EOC Specialists; Cooper, Katrina N Cc: Roschinger, Torin T.; NSU, ADW Well Integrity Engineer Subject: RE: UNDER EVALUATION: 14-22A (PTD #1921230) TxIA Communication and sustained casing pressure Attachments: 14-22 TIO plot.BMP; 14-22A.pdf All, Well 14-22A (PTD #1921230) is now being reported to the AOGCC for sustained casing pressure on the IA. The wellhead pressures were tubing/IA/OA equal to 192!2120/200 on 7/1/08. The plan continues to change out the gas lift valve and re-TIFL. A TIO plot and wellbore schematic have been included for reference. «14-22 TIO plot.BMP» «14-22A.pdf» Thank you, Anna ~u6e, ~1'. E. Well Integrity Coordinator ~~~.~~~~ ~~~ .t ~ zQ~~ GPB Wells Graup Phane; {907) 659-5102 Pager; (907} 659-5100 x1154 From: NSU, ADW Well Integrity Engineer Sent: Tuesday, June 24, 2008 8:56 PM To: GPB, Area Mgr Central (GC3/3/FS3); GPB, FS3 OTL; GPB, FS3 DS Ops Lead; Engel, Harry R; NSU, ADW WeII Operations Supervisor; GPB, Wells Opt Eng; GPB, EOC Specialists; Cooper, Katrina N Cc: NSU, ADW Well Integrity Engineer; Roschinger, Torin T.; Holt, Ryan P (ASRC) Subject: UNDER EVALUATION: 14-22A (PTD #1921230) TxIA Communication Ali, Well 14-22A (PTD #1921230) failed a TIFL on 06/24/08 when the IA inflowed 3,472'. Because the IA fluid level started at the S/O, we plan on performing gas lift valve work. The well has been classified as Under Evaluation and placed on a 28-day clock. The plan forward is as follows: 1. D: TIFL -FAILED 2. S: Change out S/O 3. D: Re-TIFL Please call with any questions or concerns. Andrea Hughes 8/29/2008 • d O ~ ~ d O O O l T y T ~ ~ Q N N .-~ N ~ ~ N ~ ~ .-~ ,__, Q Qa F'^ as • '~t M C*1 r ~ TREE = FMC WELLHEAD GRAY ACTUATOR =~~ ~ ~ BAKER! KB. ELEV = 71' BF. ELEV - _ KOP = 2300' Max Angle= 56 @7000' Datum MD = 12066' Datum TVD = 8800' SS~ • 9-5/8" CSG, 47#, L-80, ID = 8.681" ~ 59' TOP OF 7-5/8" LNR 60' s-518° CSG cur 130 13-3t8" CSG. 72#, L-80, ID = 12.347" --f 259 Minimum ID = 3.725" @ 11825' 4-112" PARK SWN NIPPLE 7-5/8" LNR; 29.7#; L-80, 0.0459 bpf, ID = 6.875" PERFORATION SUMMARY REF LOG: BHCS ON 12!06/92 ANGLEATTOPPERF: 33 @ 12017' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL OpnlSgz DATE 3-3/8" 4 12017-12027 O 04127!95 3-318" 4 12032-12042 O 04127/95 3-318" 4 12099-12115 O 07/31/93 3-318" 4 12103-12123 S 07/20/93 3-318" 4 12116-12123 S 05/11193 3-318" 4 12136-12141 S 07/20193 3-318" 4 12155-12159 S 07120193 3-318`° 4 12201-12209 S 05/11/93 14-22A 9-518" CSG, 47#, L-80, ID = 8.681 " ~-~ 10775' r 9-518" BP 10855' 4-1i2" TBG, 12.6#, 13CR, 0.0152 bpf, ID = 3.958" 1183T CEMENT BACK (PBTD) ~-C 12135. 7" LNR, 26#, 13CR, 0.0383 bpf, ID = 6.276" 12464' 11837' -~4-1i2" WLEG, !D = 3.958" , 11$05' ELMD Tr LOGGED 01108!93 DATE REV BY COMMENTS DATE REV BY COMMENTS 06182 ORIGINAL COMPLETION 01102!93 RIG SIDETRACK 10129/01 RN1TP CORRECTIONS 09/10/07 KSBJPJC GLV ClO 06/25!08 RJtPJC WELLHEAD UPDATE (06106108} PRUDHOE BAY UNIT WELL: 14-22A PERM(f Na: X1921230 API No: 50-029-20747-01 SEC 9; T10N; R14E, 3783.24 FEL 3733.64 FNL BP Exploration (Alaska} SAFETY NOTES: CHROM E TBG AND LNR 59' -~9-518" x 7-518" XO, ID = 6.875" I 207T 4-1/2" CAMCO BAL-O SSSV NIP, ID = 3.812" GA S LIFT MANDRELS ST MD TV D DEV TYPE V LV LATCH PORT DATE 1 3782 3568 49 KBMG DOME BK-2 16 09/10107 2 7510 5795 55 KBMG DOME BK-2 16 09(10107 3 9305 6878 50 KBMG DMY BK-2 0 11/12!97 4 10250 7483 50 KBMG DMY BK-2 0 01102193 5 10502 7648 48 KBMG SO BK-2 20 09110107 10559' -j4-1/2" PKR SWS NiP, ID = 3.813" 10571' 7-518" X 4-112" BKR S-3 PKR, ID = 3.875" 10635' 7-5/8° x r' xo~ 10$29' BKR TIEBACK SLV, ID =~ 10636' 7" SEAL STEM NO-GO 10637' 9-518" X 7" BKR LNR TOP PKR, ID = ? 10641' 9-518" X 7" BKR LNR HGR, ID = ? 0 9-5/8" WINDOW 14-22A) 10775' - 10835' ~ ~ 117$0' 7" X 4-1/2" BKR S-3 PKR, ID = 3.875" 11$05' 4-1i2" OTIS X NIP, ID= 3.813" 11825' 4-112" PKR SWN NIP. ID = 3.725" 14-22A (PTD #1921230) UNDER WLUATION for sustained casing pressi- TxIA communication Page 1 of 1 Regg, James B (DOA) From: 'rztt1 ~ Vilt>1 NSU, ADWWelllntegrity Engineer [NSUADWWelllntegrityEngineer@BP.com] Sunday, August 19,20076:52 AM Regg, James B (DOA); Maunder, Thomas E (DOA); Rossberg, R Steven; Engel, Harry R; GPB, Area Mgr Central (GC1/3/FS3); NSU, ADW Well Operations Supervisor; GPB, Wells Opt Eng; GPB, EOC Specialists Cc: NSU, ADW Well Integrity Engineer; Holt, Ryan P (ASRC) Subject: 14-22A (PTD #1921230) UNDER EVALUATION for sustained casing pressure - TxlA communication Attachments: 14-22A.pdf Sent: To: All, Well 14-22A (PTD #1921230) has been found to have sustained casing pressure on the IA. The TIO pressures were 2180/2020/52 psi on 08/16/07 at which time the well failed a TIFL. The well has been classified as Under Evaluation and placed under a 28-day clock. The plan forward for this well is as follows: 1. D: TIFL - FAILED 2. S: C/O GL Vs 3. D: Re-TIFL A well bore schematic has been included for reference. «14-22A.pdf» Please call with any questions or concerns. sCANNED S£P 1 1 2007 Thank you, Andrea Hughes Well Integrity Coordinator Office: (907) 659-5102 Pager: (907) 659-5100 x1154 8/29/2007 . . TREE GRAY GEN2 I I WB...LHEAD - GRAY SAFETY NOTES: CI-ROMETBG ANDLI'\R A CfUA TOR = AXELSON 14-22A KB. ELEV - 71' BF. ELEV = KOP= 2300' ? 59' H 9-5/8" x 7 -5/8" XO I Max Angle = 56 @ 7000' Datum MD = 12066' r~ Datum ND - 8800'SS I 9-5/8" CSG, 47#, L-80, ID = 8.681" I 59' / 2077' H 4-lIZ' CAMCO BAL-O SSSV NIP, ID = 3.812" I ITOP OF 7-5/8" LNR 60' (j . r------ GAS LIFT I'#.NDRB...S 9-5/8" CSG cur 130' t' ST MO ND DE:\! TYÆ VLV LA TCH PORT DATE 1 3782 3568 47 KBMG BK-2 I 13-3/8" CSG, 72#, L-80, ID = 12.347" I 2598' 1----4 .. 2 7510 5795 55 KBMG BK-2 3 9305 6878 50 KBMG BK-2 ~ 4 10250 7483 50 KBMG BK-2 5 10502 7648 48 KBMG BK I Minimum ID = 3.725" @ 11825'1 . 1-14-1/2" I¥. RKER SWS NIP, ID - 3.813" I 4-1/2" PARK SWN NIPPLE I 10559' ~ .-: 10571' 7-518" X 4-1/2" BAKER SABL-3 I I'- '-' PERM A<R, ID = 3.875" I 7-5/8" LNR, 29.7#, L-80, 0.0459 bpf, ID = 6.875" 10635' I-- f- r/~ 10635' 7-518" x 7" XO I ,1 10629' BAKERTI6-BACKSLEEVE I PERFORATION SUMMARY If REF LOG: BHCS ON 12/06/92 10636' H7" SEAL STEM NO-GO I t:8 LX~ ANGLEATTOPÆRF: 33 @ 12017' "I 10637 9-518" X 7" BKR LNR TOPPKR Note: Refer to Production DB for historical perf data SIZE SPF INTER\! AL OpnlSqz DUE 'I 1 0641' 9-518" X 7" BKR LNR HGR 3-3/8" 4 12017-12027 0 04/27/95 ~~ 3-3/8" 4 12032-12042 0 04/27/95 9-5/8" WINDOW 3-3/8" 4 12099-12115 0 07/31/93 10775' - 10835' 3-3/8" 4 12103-12123 S 07/20/93 3-3/8" 4 12116-12123 S 05/11/93 I 11780' 7" X 4-1/2" BAKERSABL-3 A<R, ID = 3.875" I 3-3/8" 4 12136-12141 S 07/20/93 3-3/8" 4 12155-12159 S 07/20/93 11805' 1-14-lIZ' 01lSX NIP, ID=3.813" I 3-3/8" 4 12201-12209 S 05/11/93 1 9-5/8" CSG, 47#, L-80, ID = 8.681" 10775' r 1 11837' 4-1/2" WLEG, ID= 3.958" I I 9-518" BP I I ELMO TT I 10955' LOGGED 01/08/93 4-1/2"TBG, 126#, 13-CR, 0.0152 bpf, D=3.958" 11836' I Ar:1:1 tk \I:t~~ I 7"LNR, 26#, 13-CR, 0.0383 bpf, ID=6.276" 1 2464' J~ [}II. TE RE:\! BY COMM8IJTS [}II.TE REV BY COMMENTS PRUDHOE BA Y UNIT 06182 ORGI~L COMPLETION WELL: 14-22A 01/02/93 RIG SIDETRACK PERMrr No: 1921230 01/10/00 SIS-QAA CON\! ERTED TO CA N\! AS AA No: 50-029-20747-01 02/22/01 SIS-LG REVISION SEC 9, T10N, R14E, 3783.24 ÆL 3733.64 FNL 10/29/01 RN'TP CORRECTIONS BP Exploration (Alaska) ~ -~- ~tA_S BEEN oN gEFO ....... STATE OF ALASKA AL,.-,_.,A OIL AND GAS CONSERVATION COMMISSIOI, REPORT OF SUNDRY WELL OPERATIONS 11. Operations performed: Operation Shutdown_ StimulateX Plugging _ Perforate _ Pull tubing_ Alter casing _ Repair well _ Other_ 2. Name ct Operator: 5. Type of Well: 6. Datum of elevation (DF or KB feet): ARCO Alaska, Inc. Development_X 71' RKB 3. Address: Exploratory_ 7. Unit or Property: P.O. Box 100360 Stratagrapic_ Anchorage, AK 99510-0360 Service_ Prudhoe Bay Unit 4. Location of well at surface: 8. Well number: 2598' SNL, 1586' WEL, Sec 9, T10N, R14E, UM. 14-22A At top of productive interval: 9. Permit number/approval number: 3644' SNL, 3927' WEL, Sec 15, T10N, R14E, UM. 92-123 At effective depth: 10. APl number: 50-029-20747-01 At total depth: 11. Field/Pool: 3735' SNL, 3746' WEL, Sec 15, T10N, R14E, UM. Prudhoe Bay Oil Pool 12. Present well condition summary Total Depth: measured 12475 feet Plugs (measured) Sand Plug @ 12075' MD (12/13/97). true vedical 9218 feet Effective Depth: measured 12075 feet Junk (measured) true vedical 8881 feet Casing Length Size Cemented Measured depth True verllcal depth Conductor 81' 20" 400 Sx Permafrost 81' 81' Surface 2527' 13-3/8" 2475 Sx AS III & 2598' 2587' 400 Sx AS I 59' 9-5/8" 59' 59' Liner 10582' 7-5/8" 595 cu ft Class G 10641' 7738' Liner 1823' 7" 590 cu fl Class G 12464' 9209' Perforation Depth measured 12018- 12028'; 12033- 12043'; 12100- 12116' true vertical 8833 - 8841'; 8846 8854'; 8902 - 8916' Tubing (size, grade, and measured depth) 4-1/2", 12.6#, 13 CR, Tbg @ 11837' MD. A~aS~a 0,'7A~;ash ,,CrJt~s" ~, i~or/~r.,l'$sio,. . Packersand SSSV(type and measured depth) Baker SABL-3 Packer @ 10571' MD; Baker SABL-3 Perm Packer @ 11780' MD; 4-1/2" Camco BaI-O SSSV @ 2077' MD. 13. Stimulation or cement squeeze summary Intervals treated (measured) see attached Intervals treated (measured) 14. Representitive Daily Average Production or Injection Data OiI-Bbl Gas-Mcr Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 335 1147 318 - 214 Subsequent to operation 641 1509 59 - 247 15. Attachments 16. Status of well classification as: Copies of Logs and Surveys run _ Daily Report of Well Operations _X Oil _X Gas _ Suspended _ Service _ 17. I hereby cedify that the foregoing is Irue and correct to the best of my knowledge. Signed ~~\ (~, ,/~~~/~ ~[}1 ¢/o,~ Title: Engineering Supervisor Date //~_../,.~) Form 10-404 Rev 06/15/88 SUBMIT IN DUPLICATE 14-22A DESCRIPTION OF WORK COMPLETED FRACTURE TREATMENT OF SAG RIVER 11/27/97: RIH &tagged PBTD at 12114' MD. 12/3/97: MIRU CTU & PT equipment. RIH w/CT & tagged PBTD. PU & pumped gelled sand slurry containing 1100 lbs of 20/40 mesh sand to place an isolation sand plug across the lower open perforations located at: 12100- 12116' MD (Z4) Ref. Log: BHCS 12/6/92. Tagged final TOS at 12072' MD. POOH w/CT. RD. 12/5/97: RIH & tagged TOS at 12170' MD. 12/9/97: MIRU & PT equipment to 7200 psi. Pumped a Data Frac followed by a Hydraulic Fracture Treatment using 20/40 mesh proppant, through the open perforation intervals located above the sand plug at: 12018- 12028' MD (Sag) Ref. Log: BHCS 12/6/92. 12033- 12043' MD (Sag) Pumped Data Frac: a) 350 bbls Pre Pad @ 5 - 30 bpm, followed by b) Shutdown. ISIP @ 2220 psi. Resumed pumping Fracture Treatment: c) 495 bbls 40# Crosslinked Pad @ 30 bpm, followed by d) 447 bbls Cross Linked Slurry w/proppant concentrations @ 1 - 8 ppg, followed by e) 31 bbls Flush, followed by f) Shutdown. Placed a total of 30,400 lbs of proppant into the formation. RD. 12/13/97: RIH w/CT & jetted a proppant & sand plug fill cleanout to 12075' MD. Placed well on production w/gas lift & obtained a valid production test. GeoQuest 500 w. International Airport Road Anchorage, AK 99518-1199 A'I-rN: Sherrie NO. 9806 Company: 10/13/95 Alaska Oil & Gas Cons Comm Attn: Larry Grant 3001 Porcupine Drive Anchorage, AK 99501 Field: Prudhoe Bay Floppy Well Job if., Log Description Date BL RF Sepia DIR MWD Disk D.S. 1-14~7.~,~_ G '7~ PERFORATION RECORD 950929 I 1 D.S, 1-22A ~'~ ! .~-~"~ PERFORATION RECORD 951002 1 1 D.S, 4-35 [ (~ 3~ PRODUCTION PROFILE 950930 1 1 D,S, 5-16A / ~_¢~ PERFORATING RECORD 951 001 1 1 D,S, 9-29 I ~ {~ PERFORATION RECORD 951002 1 1 D,S. 14-22A ~"?~ I?~ INFLATABLE BRIDGE PLUG 951001 1 1 D,S. 15-12 ~' I- I~(~ DUAL BURST TDT-P 950930 1 1 , ,., PFFCl\/F.Q SIGNED: Please sig OCT 1 5 1995 GeoQuest 500 W. International Airport Road Anchorage, AK 99518-1199 A'FI'N: Sherrie NO. 9623 Company: Alaska Oil & Gas Cons Comm Attn: Larry Grant 3001 Porcupine Drive Anchorage, AK 99501 8/7/95 Field: Prudhoe Bay Floppy Well Job # Log Description Date BL RF Sepia DIR MWD Disk D.S 5-6A ~i~"L~r:,'' pERF RECORD " g 50'7'18' i 1 ..... D.S. 6-2 ..... ,"'"~'"'[- ~ '~,~RO.D PROFILE, "~5 ~7'1 ~ "1 ........... :'i :,,",,, ':', ...... ,., D:S..,,7-23 ~/~'t~. ---'~'~- (4 ~/~UAL ,POROS! ,TY- cNT, G 950720 I I ; D.S. 11-3A C((--{~'~- CEE-GR" 950718.,, I 1 D.S. ,,!,2-11 ~'1 .--'7 '~ STATIC BHP SuRvEy .... 950717 I I ..... D.S. 14-10 ch/~-13~ PROD PROFILE 950716 I 1 , '14-22A ,,~"~.--[,~_~ PRoD PRoFILE' ' 95,0717 1 1 D'S' '7-23' ~I~,o'''V''~ 95258 '.DUAL P'o'RC~SITY .CNTG ............ , ..... " 1 D.S.. ....... - [ ~,'"'~, '"/__\ 950720 ,,, ,, ,, SIGNED: · Please sign and copy of this transmittal to Sherrie at the above address. Thank you. GeoQuest 500 W. International Airport Road Anchorage, AK 99518-1199 ATTN: Sherrie NO. 9471 Company: 5/23/95 Alaska Oil & Gas Cons Comm Attn: Larry Grant 3001 Porcupine Drive Anchorage, AK 99501 Field: Prudhoe Bay Floppy Well Job # Log Description Date BL RF Sepia DIR MWD Disk D.S. 2-31 ~ ! -- t O~-~TBG cLrn'ER RECORD 0 43 0 95 1 1 D.S. 3-06 ~ ~o- ~, O U.l. INJEC LOG 0 421 95 I 1 D.S. 3-31 ~ ~-~ Z.. CEE 050295 I 1 D.S. 7-32 ~ ~-/~'O !~RFRE~RD 042895 I 1 D.S. 9-8 ~ ~ - ~O PERF RE,RD 0 429 95 1 1 : D.S. 9-12 ~~ ~ INJEC PRORLE 0503 95 I 1 ID.S. 11-16 ST1 ~-7~ PERFRE~RD 042995 I 1 D.S. 11-23A ~'~I PERFRE~R~ 0S0~ I 1 D.S. 11-28 ~-~O LEAK DETECTION 042895 I 1 D.S. 11-38 ~ q-~ CNL 0S02~S, I 1 O.S. 11-36~'9-~ DUAL BUST TDT-P 050195= I 1 D.S, 11-36 ~-~ RST 042195 I 1 D.S. 14-5A ?~- / PERFRE~R9 042795 I 1 D.S, 14-22A ~- /~ PERFRE~RD 042795 I 1 D.S. 14-28 ~- ~- LEAK DETECTION 042995 I I , O'S. 14-33 ~-/~ CNL 042795 I 1 D.S. 14-43 ~ ~- J ~ DUAL BURST TDT-P 042795 I 1 D,S. 16-12 ~ ~-~ TBGC~ERRECOR9 043095 I 1 D.S. 18-02A ~5-~O PERFRE~RD 050295 I 1 D.S. 15-19 ' 95176 OUALBURSTTDT-P 050495 1 SIGNED: Please sign and return one copy of this transmittal to Sherrie at the above address. Thank you. RECEIVED DATE: ,,, ,, ~w~ 2~ 1995 Alaska 0il & Gas Cons. Commission Anchorage STATE OF ALASKA ALASKA' .AND GAS CONSERVATION CC ,,IlSSION REPORT SUNDRY WELL OPE. rtATIONS 1. Operations performed' Operation shutdown Stimulate Plugging Perforate X Pull tubing Alter casing Repair well Other 2. Name of Operator ARCO Alaska, Inc. 3. Address P.O. Box 100360, Anchorage, AK 99510-0360 4. Location of well at surface 2598' SNL, 1586' WEL, Sec. 9, T10N, R14E, UM At top of productive interval 3644' SNL, 3927' WEL, Sec. 15, T10N, R14E, UM At effective depth At total depth 3735' SNL, 3746' WEL, Sec. 15, T10N, R14E, UM 5. Type of Well Development Exploratory Stratigraphic Service 6. Datum of elevation(DF or KB) 71 RKB 7. Unit or Property Prudhoe Bay Unit 8. Well number 14-22A RECEIVED MAY 2 b 1995 0il & Gas Cons. Commission Anchor~:,,~ feet 9. Permit number/approval number 92-123 10. APl number 50 - 029-20747-01 11. Field/Pool Prudhoe Bay Oil Pool 12. Present well condition summary Total depth: measured 12475 feet Plugs(measured) Tag PBTD @ 12111' M D (4/24/95) true vertical 9218 feet Effective depth: measured 12136 feet true vertical 8933 feet Junk(measured) Casing Length Size Cemented Measured depth True vertical depth Conductor 81' 20" 400 sx Permafrost 81' 81' Sudace 2527' 13-3/8" 2475 sx AS III & 400 sx AS I 2598' 2587' Production 59' 9-5/8" 59' 59' Liner 10582' 7-5/8" 595 cuft CIG 10641' 7738' Liner 1823' 7" 590 cuft CIG 12464' 9209' Perforation depth: measured 12018-12028" 12033-12043'; 12100-12116' true vertical 8833-8841 '; 8846-8854'; 8902-8916' Tubing (size, grade, and measured depth) 4-1/2", 12.6#, 13 CR, Tbg @ 11837' MD Packers and SSSV (type and measured depth) Baker SABL-3 Packer @ 10571' MD' Baker SABL-3 Perm Packer @ 11780' MD; 4-1/2" Camco BaI-O SSSV @ 2077' MD 13. Stimulation or cement squeeze summary Intervals treated(measured) See Attached Treatment description including volumes used and final pressure 14. Prior to well operation Subsequent to operation Representative Daily Average Production or Iniection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure 694 1400 1244 749 1811 1323 Tubing Pressure 261 255 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 16. Status of well classification as: Oil ~ Gas Suspended Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. · Signed ,.~¢-z,¢~ (_- . -~ Title Form 10-404 Rev 06/15/88 cc: KZ, JWP Engineering Supervisor SUBMIT IN DUPLICATE_~'~'~. 14-22A PERFORATING OPERATIONS DESCRIPTION OF WORK COMPLETED 4/24/95: RIH & tagged PBTD at 12111' MD. 4/27/95: MIRU & PT equipment. Added Perforations: 12018 - 12028' MD (Sag) 12033- 12043' MD (Sag) RIH w/perforating gun & shot 20' of add perforations as follows: Ref. Log' BHCS 1/31/92. Used a 3-3/8" carrier & shot 4 spf at 180 degree phasing at underbalanced pressures. POOH w/perf gun. Noted all shots fired. Rigged down. Returned the well to production w/gas lift & obtained a valid welltest. RECEIVED MAY 2 ;5 1995 /~laska 0il & Gas Cons. Commission Anchors, -' PERMIT DATA OGCC Individual Well Gec~ogical Materials Inventor~ T DATA_PLUS Page' 1 Date' 01/03/95 RUN DATE_RECVD 92-123 5516 92-123 SURVEY 92-123 SURVEY 92-123 DWOP 92-123 407 92-123 SSTVD 92-123 PROD 92-123 PITS 92-123 PITS 92-123 PERF 92-123 PERF 92-123 PERF 92-123 PERF 92-1~ PERF 92-123 PERF 92-123 GR/CL 92-123 DLL/MLL/GR 92-123 CNL/GR 92-123 BHP 92-123 BHC/AC/GR T 10602-12425 DLL/MLL/AC/CN R 10760-11728 ANADRILL R 10760-11728 ANDRILL R 11/25/92-01/03/93 R COMP DATE:01/08/93 L 10765-12425 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 L 12000-12150 L 11900-12183 L 11880-12272 L 11750-12100 L 11700-12158 L 11880-12160 L 11940-12260 L 11935-12240 L 11850-12250 L 10450-12394 L 11900-12425 L 10688-12345 L 10765-12425 L 11900-12402 02/01/93 03/02/93 02/01/93 03/02/93 03/02/93 12/30/92 03/26/93 07/30/93 04/27/93 09/13/93 08/31/93 07/30/93 06/28/93 04/27/93 03/26/93 03/26/93 12/30/92 12/30/92 12/30/92 12/30/92 Are dry ditch samples required? yes ~And received? Was the well cored? yes ~no//Analysis & description received? Are well tests required?/~z~es/~/~ ~ Received? yes ~ Well is in compliance//~--~ Initial COMMENTS yes ~ ARCO Alaska. Inc. P.O.Box 100360 Anchorage, Alaska 99510 DATE: 8-10-93 REFERENCE: ARCO CASED HOLE FINALS 1-6 7-31-93 1-12 7-27-93 1-29 7-27-93 /3-20A 8-1-93 ~3-20A 8-1-93 6-6 7-26-93 6-13 7-30-93 11-13A 7-28-93 12-26 7-29-93 13-7 7-30-93 14-22A 7-31-93 15-4 7-27-93 15-6 8-2-93 15-24 7-27-93 15-25 8-3-93 16-6 7-30-93 17-1 17-7 Production log _ii,,- 1, Production Log~'~~~'," 1, Pe~Record~qz-q~to R-n 1, uc on ~,.1 ~t ~ ~~ 1, Pe~ Record ~-Iz%%~ R,m 1, Pe~Record~q~~o R-n 1, Pe~ Record~o -~ ~ R~ 1, Pe~ Record l~-I11~% R-n 1, Pe~ Record ~-l~o R-n 1, Pe~Record~Sv-lzt~O R-n 1, ~1 B~t ~ R-n 1, 8-1-93 Production Log" 8-3-93 Production Log ;' 5" 10~0~ ~7~ch 5" Sch 2"&5" 5"~5~-~ ~5~Sch 5" Sch 5" Sch 5" Sch 5" Sch 5" Sch 5" ~eh 5,,T~I/0- lo~ h I~,.1 Burst TDTP Run 1, CNL ~-%~9 R,m 1, 5" Sch Dual Burst TDTP ~zoo -~Rnn 1, 5" e~ Sch Production Log~~!~I~un 1, 2"&5"z~-Sch un 1, 2"&5"~-~o-Sch~ Run 1, l"&5"zco-Sch ~l-qD 17-9 8-2-93 Production Log ~' R,,- 1, 2"&5"lw-Sch ~ Please s~ ~d' retm ~e at~ch~ cope ~ receipt of ~. RECEIVED BY_~~~ ~~ ~ve A Nice ~y! ;~ ~. /~ ~n~ W~ce APPROVED ~ ~**a ~) ATO- 1529 ~s$ 93~-' -,%2o,~ ~ o ~ CENT~ F~ ~ ~T.~ ~4 ~ C~~ON ~ ~ F~ ~ CLOT C~~ ~ B~ ~ E~ON ~ ~A~ OF ~~ ~THON ~ ~ MOB~ The correct API# for ll-13tis 50-029-21229-01 not 50~12~21229-01. The correct API# for 14-22A is 50-029-20747-01. The API# for 16-6 is 50-029120584. ARCO Alaska~ Inc. P.O.Box 100360 Anchorage, Alaska 99510 DATE: 8-10-93 REFERENCE: 1-30 ~-30 ~ ~_~_5_~4-1 ~4-40 ~?_.~7~..~ 9-13 ~9.~_~9- 26 -42 1-12 1-18 1-22 ~-1 ~~-~0 ' ~7-1~ 7-14-93 7-5-93 7-11-93 7-17-93 7-17-93 7-10-93 7-6-93 7-6-93 7-8-93 7-11-93 7-3-93 7-3-93 7-9-93 7-4-93 7-4-93 7-8-93 7-2-93 7-16-93 7-16-93 7-5-93 7-6-93 7-9-93 7-13-93 7-12-93 Completion Record liun I, 5 Sch Perf Record ~)0~zf5 Rim 1, 5" Sch InJ Profile ~ ~-~c~ Rl~n 1, 5" Sch Perf RecordlG~-l~'~> R~_m 1, 5" Sch Prod Profile ~llso-~l~5~ R~m 1, 5" Sch ~ucflon ~g ~R~ I Sch P~/~J ~offieaU~m~~ 1; 5" Sch ~ucflon ~g~~R~ 1, 1"&5" Sch ~mpleflon Record R!!n 1, 5"~~555Sch Pe~ Record ~~q5 R~m 1, 5" Sch Pe~ Record )z~_~ ~ R~m 1, 5" ~h Pe~ Record%~~ R~m 1, 5" Sch ~~t, ct~-'~ R, ml, 5" ~ ~mpleflon Record R.n 1, 5" q~m~ ~ ~tect R~m 1, 2" o- ~5 Sch ~ ~ct ~~o Ri~n 1, 2"&5" Sch ~ Brat ~ R~m 1, 5"~-~ch Pe~ Record ~-~z~Sl R~ 1, 5" Sch ~e-~ ~g- ~P ~oa%~~m 1, 5" Sch ~ ~tect ~-%~o R~ 1, 2" Sch Pe~ Record ~a~~ R~ 1, 5" Sch ~j ~~/~ ~c R~m 1, 5'~ ~- ~ ~zSch Pe~Record l~10~l R~n 1, 5" Sch ~ ~tect ~-iot~ R~m 1, 2" Sch Please sign and return the attached copy ~s receipt of data. RECEIVED BY ' .~__~ Have A Nice Day! Sonya Wallace APP R OV E D_ _ff~______~°~ ATO- 1529 Trans# 93081 # CENTRAL FILES # CHEVRON # CLINT CHAPMAN # BPX # EXXON # STATE OF ALASKA # MOBIL * The correct top logged Interval for 11-22 is 380 feet. STATE OF ALASKA ALASKA "--'. AND GAS CONSERVATION CC '- ~IlSSION ~ REPORT SUNDRY WELL OPEHATIONS 1. Operations performed: Operation shutdown Stimulate X Plugging Perforate X ~/J/~"~ Pull tubing Alter casing ~ Repair well Other X ¢.~ 5. Type of Well 6. Datum of elevation(DF Development X 71 RKB 2. Name of Operator ARCO Alaska, Inc. 3. Address P.O. Box 100360, Anchorage, AK 99510-0360 Stratigraphic Service 4. Location of well at surface 2598' SNL, 1586' WEL, Sec. 9, T10N, R14E, UM At top of productive interval 3644' SNL, 3927' WEL, Sec. 15, T10N, R14E, UM At effective depth RECEIVED A U G 2 0 1993 Alaska 0il & Gas Cons. Commission At total depth 3735' SNL, 3746' WEL, Sec. 15, T10N, R14E, UM Anchorage 7. Unit or Property Prudhoe Bay Unit 8. Well number 14-22A 9. Permit number/approval number 92-123 10. APl number 50 - 029-20747-01 11. Field/Pool Prudhoe Bay Oil Pool 12. Present well condition summary Total depth: measured true vertical 12475 feet 9218 feet Plugs(measured) Tag PBTD @ 12136' MD (8/2/93) Effective depth: measured 12136 feet true vertical 8933 feet Junk(measured) Casing Length Size Cemented Measured depth True vertical depth Conductor 81' 20" 400 sx Permafrost 81' 81' Surface 2527' 13-3/8" 2475 sx AS III & 400 sx AS I 2598' 2587' Production 59' 9-5/8" 59' 59' Liner 10582' 7-5/8" 595 cu ft CIG 10641' 7738' Liner 1823' 7" 590 cu ft CIG 12464' 9209' Perforation depth: measured 12100-12116' true vertical 8902-8916' Tubing (size, grade, and measured depth) 4-1/2", 12.6#, 13 Cr, Tbg @ 11837' MD Packers and SSSV (type and measured depth) Baker SABL-3 Perm Packer @ 11780' MD; 4-1/2" Camco BaI-O SSSV @ 2077' MD 13. Stimulation or cement squeeze summary Intervals treated(measured) See attached. Treatment description including volumes used and final pressure 14. Prior to well operation Subsequent to operation Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure 1093 1097 107 2462 ¢'' 2362 2063 Tubing Pressure 235 229 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 16. Status of well classification as: Oil x Gas Suspended__ Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed Title Engineering Supervisor Form 10-404 Rev 06/15/88 Date SUBMIT IN DUPLICATE 1031/4 GSS/MJB cc: SW, JWP 14-22A DESCRIPTION OF WORK COMPLETED CTU CEMENT SQUEEZES & FRACTURE TREATMENT OF ZONE 4 3/19/93: RIH & tagged bottom at 12393' MD. 3~23/93: MIRU & PT equipment to 4000 psi. Loaded the wellbore w/Hot Seawater, then RIH w/CT & reciprocated a pre-squeeze acid wash across the open perforation intervals at: 12100 - 12124' MD (Z4) Ref. Log: BHCS 12/6/92. Jetted 25 bbls 15% HCl w/10% Xylene, followed by 17 bbls Seawater. Shutdown for soak. Displaced acid from rathole w/100 bbls Seawater down CT backside, then pumped 29 bbls of Liquid Latex 'G' cement, and squeezed the perforations to 2100 psi max pressure. Couldn't hold squeeze above 1100 WHP due to frac gradient. Held 1100 psi for 2 hours. Placed 4 bbls of cement behind pipe. Contaminated cement & jetted out contaminated cement down to 12393' MD. POOH w/CT. RD. 4/2/93: Reperforated: 12100 - 12124' MD (Z4) Ref. Log: BHCS 1 2/6/92. 5/7/93: Added perforations: 12200 - 12208' MD (Z4) Ref. Log: BHCS 12/6/92. 5/11/93: MIRU & PT equipment to 4100 psi. Loaded the wellbore w/Hot Seawater, then RIH w/CT and reciprocated a pre-squeeze acid wash across the open perforation intervals (listed above). Jetted 53 bbls 12% HCl w/10% Xylene, followed by 56 bbls 6% HCl - 1.5% HF, followed by 98 bbls 1% NH4Cl Water. Displaced rathole w/Seawater down CT backside, then pumped 18 bbls of Micro Matrix cement, followed by 16 bbls Latex Acid Resistive cement. Squeezed the perforations to 2500 psi max pressure, then held squeeze at 1800 WHP for 2 hours. Placed 17 bbls of cement behind pipe. Contaminated cement & jetted out contaminated cement to 12180' MD. 5/23/93: Reperforated: 12104 - 12124' MD (Z4) Ref. Log: BHCS 7/16/93: Added perforations: 12137 - 12142' MD (Z4) 12156 - 12160' MD (Z4) Ref. Log: BHCS POOH w/CT. Rigged down. 12/6/92. u G 2 0 Alaska 0ii & Gas Cons. Commission 1 2/6/92. Anchorage 7/20~93: MIRU & PT equipment to 4000 psi. Loaded the wellbore w/Hot Seawater, then RIH w/CT & cement squeezed the open perforation intervals (listed above). Pumped 8 bbls of Superfine Micro cement, followed by 25 bbls Latex Acid Resistive cement. Squeezed the perforations to 3500 psi max pressure, then held squeeze at 3150 WHP for 45 minutes. Placed a total of 15 bbls of cement behind pipe. Contaminated cement & jetted cement to 12132' MD. POOH w/CT. Rigged down. 14-22A DESCRIPTION OF WORK COMPLETED CTU CEMENT SQUEEZES & FRACTURE TREATMENT OF ZONE 4 7/21/93: RIH & tagged PBTD at 12147' MD, indicating some squeezed perfs were not covered by cement. 7/27~93: MIRU CTU & PT equipment. RIH w/CT & dump bailed 0.75 bbl Latex Acid Resistive cement mixed w/1 bbl Bentonite (1.75 bbls total) across uncovered squeezed perforations (above). POOH w/CT. Left cement in the lower wellbore to 12127' MD. Rigged down. 7/28/93: RIH & broached cement down to 12073' MD. 7/29/93: RIH w/underreamer & underreamed cement to 12145' MD. POOH w/underreamer. Rigged down. 7/30/93: MIRU CTU & PT equipment. w/Bentonite. POOH w/CT. RIH w/CT & dump bailed I bbl Latex Acid Resistive cement mixed Left cement in the lower wellbore to 12125' MD. Rigged down. 7/31/93: Reperforated: 12100 - 12116' MD (Z4) Ref. Log: BHCS 12/6/92. 8/1/93: MIRU & PT equipment to 7500 psi. Pumped a Data Frac followed by a Hydraulic Fracture Treatment using 16/20 mesh proppant, through the open perforations (listed above). Pumped Data Frac: a) 250 bbls 20# Gelled Pre Pad @ 35 bpm, followed by b) Shutdown. ISIP @ 2000 psi. Resumed pumping Data Frac: c) 100 bbls 40# Gelled Pad w/FLA @ 35 bpm, followed by d) 190 bbls 20# Flush @ 35 bpm, followed by e) Shutdown. ISIP @ 1753 psi. A U G 2 0 1993 ~laska Oil & Gas Cons. Commissio~ ;Anchorage Resumed pumping Fracture Treatment: f) 50 bbls 40# Crosslinked Pad @ 35 bpm, followed by g) 194 bbls Cross Linked Slurry w/proppant concentrations @ 1 - 10 ppg, followed by h) 186 bbls Flush, followed by i) Shutdown. Placed a total of 36,690 lbs of proppant into the formation. Rigged down. 8/3/93: RIH & tagged proppant fill at 12136' MD. Placed well on production w/gas lilt & obtained a valid production test. ARCO .~1~=~, Inc. P.O2~ox 100360 Anchorage, .Aln=ir~, 99510 DATE: 7-20-93 REFERENCE: ARCO CASED HOLE FINALS 3_18A~~9~ 5-18-93 5-13 77- ~ 5-28-93 5-24~/-/~ 5-22-93 5-32 ~ I-?~ 5-27-93 6-12A ~-~ 5-29-93 6-14A 4~75-19-93 7-147~! 5-25-93 9-3 5-18-93 9-3 ?~ ~- 5-24-93 * 9-4A ~-~ ? 5-26-93 9-5A ~-~ ~ 5-30-93 ** 9-28A ~-~ 5-28-93 9-3 lA 7~35-19-93 9-32 ~/~5-30-93 12-15 ~-~z 5-27-93 12-23 ~ ~- ~5-27-93 14-22 .~ 5-23-93 x A~I- 1 _ .~ ~q ~-20-0~ A~I- 1 ~* ~-20-0~ A~I-~ ~-2~-0~ Pe~ R~eord Completion Record R-n 1, 5" Sch TDTP (Borax) Run 1, 5" Sch GR/Collar Run 1, 5" Atlas TDTP (Borax) Run 1, 5" Sch TDTP (Borax) Run 1, 5" Sch Production Log Run 1, 5" Sch Prod Profile R.n 1.5" Sch Perf Record Run 1, 5" Sch Prod Profile R-n 1, 5" Sch Production Log Run 1, 5" Sch Completion Record R.n 1, 5" Sch Production Log R-~ 1, 5" Sch CBT Run 1, 5" Sch Completion Record R-n 1, 5" Sch Completion Record Run 1, 5" Sch ' Leak Detection R-n 1, 2" Sch Perf Record Run 1, 5" Sch PITS Rim 1, 5" Sch Perf Record Run 1, 5" Sch Jewelry R~_m 1, 5" Sch Perf Record Run 1, 5" Sch Jewelry R-_n 1, 5" Sch R-~ 1, 5" Sch R-n 1, 5" Sch Run 1, 5" Sch R~_m 1, 5" Sch ~~Ec~iSvig~E~d ~turn ~che~ as receipt °f data' ~C~/ Have A Ntce~~~~~ V~D Sonya Wallace AT0-1529 # ~'i'iiAL Fr~ # CHEVI~0N #HPX # STATE OF ALASKA The correct well name for this log is 9-4A. The correct API# for 9-28A is 50-029-21292-01. ARCO Alaska, Inc. P.O.Box 100360 Anchorage, Alaska 99510 DATE: 6-9-93 REFERENCE: ARC0;,/ ~ ~O~~~~~~ IIA 14-i19-~A 17-19 17-21 1.8-2 5-6-93 Static Pressure Run 1, 5" Sch 5-8-93 Prod Profile Run 1, 5" Sch 5-10-93 Production Run 1, I~' Sch 5-11-93 CBT/New TBG/Jewelry Run 1, ~' Sch 5-10-93 Leak Detect/Spin/Temp/Press l~m 1, 2" & ~' Sch 5-4-93 USIT (Cement & Corrosion) (Color) Run 1, 5" Sch 5-3-93 InJ Proflle/Spln/Temp/Press Run 1, [~' Sch 5-2-93 lnj Profile/PITS Run 1, ~' Sch 4-24-93 Leak Detect/Spin/Temp/Press Run 2, 5" Sch 5-7-93 D,_~! Burst/TDT-P (Borax) Run 1, 5" Sch 5-6-93 Vertilog l~m 1, 5" Atlas 5-8-93 GR/CoI!~r Run 1, 5. Atlas 5-6-93 Peri Record - l~m 1, 5" Sch 5-7-93 GR/CCL l~m 1, 5" Sch 5-10-93 CNL Run 1, 5" Sch 5-11-93 Leak Detect Run 1, 2" & f~' Sch 5-7-93 Peri' Record Run 1, ~' Sch 5-9-93 TDT-P (Borax) Run 1,/~' Sch 5-3-93 Leak Detect/Spin/TempfPress l~m 1, 5" Sch 5-3-93 Peff Record Run 1, 5" Sch 54-93 Production Run 1, ~' Sch 5-5-93 CCL/PerfRecord l~m 1, ~' Atlas 5-8-93 SBT/GR/CCL Run 1, 5" Atlas Run 1, 5" Sch Run 1, 5" Sch Run 1, 5" Sch l~m L 2" & 5" Atlas a7~~I4 5-7-93 GR/CCL (Color) ~0~.~AGI-5 5-10-93 GR/CCL (Color) ~/~i~I4 5-10-93 GR/CCL (color) ~AGI-8 5-3-93 SBT/GR/CCL Please sign and return the attached copy as receipt of data~ RECEIVED BY__~~J~ Have A Nice Day! ~/)<~/ ~ Sonya Wallace ~ ~. ~"~" APPROVED iT0-1529 ~/,~*~ c/~/~ C/~.~si 9306~ ..... ~ E~ON ~ MOBm # STATE OF ~KA ARCO Alaska, Inc. P.O.Box 1007~0 Anchorage, Alaska 99510 DATE: 4-22-93 REFERENCE: ARCO CASED HOLE FINALS 1-9 3-29-93 1-11 '7'~-~"/ 4-2-93 1-19 3-22-93 1-22 ~--I-~ 4-6-93 1-29 4-6-93 1-33 ~©-I~ 4-4-93 2;8 3-27-93 2--11 ~~ 4-9-93 3-8 3-28-93 70 ~ 4-2 3-20-93 4-29 ~ ~- ~--3-26-93 4-33 3-25-93 5-11 '77--~0 3-29-93 6-3 4-5-93 6-9 ~--7~ 4-5-93 6-18 3-30-93 6-22 ~'~\ 3-26-93 -4A -~-4A 4-3-933'22'93 ~--9-35A 4-1-93 --11-13A 4-9-93 12-11~9~ 3-31-93 14-15 ~l-~q 3-30-93 gg----~.."'~J. 4-22A 4-2-93 ----------.-.-.~ 4-22A 4-2-93 16-30 ~--"~[~:, 3-21-93 '%17-20 4-3-93 ~$.--d)~_./½s-26 3-23-93 .g-------"'-x~8-26 3-24-93 18-27 18-27 3-23-93 3-24-93 Leak Detect Run 1, 1",5"&25" Sch Production Run 1, ~' Sch Production Run 1, iF' Sch Perf Record Run 1, ~' Sch Production Run 1, ~' Sch Perf Record Run 1, iF' Sch lnJ Profile Run 1, iF' ich Perf Record Run 1, iF' Sch Production Run 1, ~' Sch Tubing Puncher Run 1, iF' Sch CNL Run 1, iF' Sch Static Pressure Run I, iF' Sch Press/Temp/Spin Run 1, 2'&5" Sch Static Pressure Run 1, iF' Sch Production/Gas Entry Run 1, iF' Sch Perf Record Run 1, iF' Sch Leak Detect Run 1, 1"&5" Sch Production Run 1, iF' Sch Perf Record Run I, iF' Sch Perf Record Run 1, iF' Sch Static Pressure Run 1, iF' Sch Perf Record Run 1, iF' Sch Production Run 1, iF' Sch Perf Record Run 1, iF' Sch Production Run 1, iF' Sch PITS Run 1, iF' Sch Perf Record Run 1, iF' Sch Perf Record Run 1, iF' Sch Perf Record Run 1, iF' Sch Perf Record Run 1, iF' Sch Static Pressure Run 1. iF' Sch GR/CCL Run 1, iF' Sch Static Pressure Run 1, iF' Sch GR/CCL Run 1, iF' Sch Please sign and rettwn th~ attached copy as receiPtpf data, RECEIVED BY _~._~./~/~ _ , --" f".,~~_~-//.~'~/ . Havea~c~ Sonya Wallace ~~,~,,% [..~ APPROVED ATO-15~9 ~ rrans# 93050 # EXXI~ -~.,'.~/~ # STATE OF ALASKA ARCO Alaska, Inc. P.O.Box 100360 Anchorage, Alaska 99510 DATE: 3-22-93 REFERENCE: ARCO CASED HOLE FINALS ....~.~1-30 * -11 · ?,-13 -31 -35 ~~4-22 ~- 16-25 ~6-28 - ' ~** ~6-29A ~6-30 1-31-93 Perf Record 1-4-93 Perf Record 1-10-93 Perf Record 1-11-93 Perf Record 11-12-92 Perf Record 11-8-92 Perf Record 11-28-92 Perf Record 1-29-93 Perf Record 11-15-92 Perf Record 11-19-92 Perf Record 11-6-92 Perf Record 11-27-92 Perf Record 11-18-92 Perf Record 1-2-93 Perf Record 1-1-93 Perf Record 3-1-93 Perf Record 1-9-93 Perf Record 11-18-92 Perf Record 11-15-92 Perf Record 1-3-93 DSN 1-8-93 Perf Record 11-2-92 Collar (Inflatable Packer) 11-16-92 Collar (To spot Jet cutter) 1-8-93 Perf Record 11-14-92 Perf Record 12-2-92 Perf Record 11-29-92 Perf Record 13-31-92 Perf Record 11-29-92 Perf Record 1-5-93 Perf Record 11-17-92 Perf Record Please sign and return the attached copy as receipt of data. Have A Nice Dayt Run 1, Run 1, Run 1, Run 1, Run 1, Run 1, Run 1, Run 1, Run 1, Run 1, Run 1, Run 1, Run 1, Run 1, Run 1, Run 1, Run 1, Run 1, Run 1, Run 1, Run 1, Run 1, Run 1, Run 1, Run 1, Run 1, Run 1, Run 1, Run 1, Run 1, Run 1, Sonya Wallace ATO-1529 HIS HIS HIS HIS HIS HIS HIS HIS HL8 HIS HIS HIS HL8 HL8 HIS HL8 HIS HIS HIS HL8 HIS HIS HIS HLS HLS HL8 HLS HIS HIS HIS HIS # PHIIJAPS PB~ FII2/8 #I/PX # STATE OF ALASKA RECEIVED These logs were mn in 1993 not 1992. The correct API# for 4-14A is 50-029-203104)0. The correct API# for 1~-29A is 50-023-22272~01, Oil & Gas Cons. Commission Anchorage ARCO .~l~slr~, Inc. P.O.Box 100360 Anchorage, Alaska 99510 DATE: 3-22-93 REFERENCE: ARCO CASED HOLE FINALS ~ ~_~~.I-IB 2-9-93 Prod Profile l~m 1, ~~_1-25 2-9-93 Prod Profile Run 1, ~~~0 2-21-93 Prod Profile Run 1, 1-22-93 Leak Detect Run 1, :~'&t~' ~~~ 2-22-93 Leak Detect/Noise/Temp Run 1, ~'&l~' 2-23-93 Prod Profile Run 1, 1-24-93 Alpha Patch CCL Run 1, 2-21-93 GR/CoII~r l~m 1, 2-21-93 InJ Profile ' l~_m 1, 1-25-93 Static Temp Run 1, ~~4-~ 2-20~93 GR/Collar ~_mRUn 1,1' 51 2-20-93 Prod Profile ' ' 4ST 2-11-93 Prod Profile Run 1, 22A~..._.__~/~jZ.~_ _ 2-19-93 Prod Profile Run 1, Please sign and return the attached copy as receipt of data. Have A Nice Dayl Sonya Wallace ATO-1529 APPROVED ~) Trans# 9304~'-~ --- Calnco C,J~_mco Camco Camco Camco Camco Camco Camco Camco Camco Camco Camco # CENTRAL FH~S # CHEVRON D&M # LUCILLE JOHNSTON # EXXON MARATHON # MOBIL # PHILLIPS PB WELL FILES R&D # BPX # STATE OF ALAS~ TEXACO The correct well name for t_h_is log is l-lB. RECEIVED MAR 2 6 199~ Alaska 011 & Gas Cons. Commission Anchorage ARCO Alaska, Inc. P.O.Box 100360 Anchorage, Alaska 99510 DATE: 3-22-93 REFERENCE: ARCO CASED HOI.~ FINALS ~5~9-36 ~~_9-42 ?~ 11-1A ~1-1A. l-13A 1-16ST 7q__~_~2-8 1-8-93 InJ Profile -17 1-10-93 Gas Entry -5 11-23-92 Prod Profile - 14t 1-9-93 InJ Profile ---12~q~ 4-40 11-24-92 PITS Prod Profile 12-4-92 20 11-19-92 Inj Profile 11-22-92' Pump-in Profile 1-12-93 Collar/Tubing Patch 12-3-92 GR/Collar 12-3-92 Prod Profile 12-3-92 GR/Collar 12-6-92 PITS Rim 1, 5" R~!n 1, 5" Run 1, 5" Run 1, 5" R~m 1, 5" Run 1, 5" Run 1, 5" R-n 1, 5" Ru_n 1, 5' Run 1, 5" Run 1, 5" Rl]n 1, 5" Rim 1, 5" Calnco Camco Camco Camco Camco Camco Camco Camco Camco Camco Camco Camco Camco i.~ 2-7A 10-92 CCL/Jewelry ~~4 22A 12- ~ 12~~1 - 1-8-93 GR/Collar ~Z~l~_~~1_4-28 1-8-93 ~od ~offie Run 1, 7-1~ 11-22-92 S~flc TemPemt~e R~ 1, Plebe s~ ~d retm ~e at~ched copy ~ receipt of ~. RECEIVED B~___~~~ R!!n 1, 5" Run 1, 5" 11 C411nco Camco Camco Camco Have A Nice Dayl Sonya Wallace ATO-1529 APPROVED_ff~? Trans# 93037 # CENTRAL FILES # CHEVRON D&M # LUCILLE JOHNSTON # EXXON MARATHON # MOBIL # PHILLIPS PB WELL FILES R&D # BPX # STATE OF ALASKA_ RE CEIVED The correct APl# for 4-14A is 50-029-20310-00. A/aska 011 & Gas Cons. (;ornrnleslol3 Anchorage STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSIC~/~)/.-. WELL COMPLETION OR RECOMP LETION REPORI".A¢i' G OIL [] GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number ARCO Alaska,/nc. 92-123 3. Address ~. APl Number P. O. Box 196612, Anchora~le, A/aska 99519-6612 50- 029-20747-01 4. Location of well at surface ~ , . _ 9. Unit or Lease Name 2598'SNL, 1586' WEL, SEC. 9, TION, R14E ' :~"~ ....... ; ..... '~ t LOC^'flC~$11 Prudhoe Bay Unit At Total Depth ' -'¢~. !~. !(L~'~ 11.PrudhoeField andBayPOOIFie/d/Prudhoe Bay Pool 3735' SNL, 3746' WEL, SEC. 15, TION, R14E 5. Elevation in feet (indicate KB, DF, etc.) 16. Lease Designation and SedaJ No. KBE = 71' I ADL 28314 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. 115. Water Depth, if offshore 116. No. of Completions 11/29/92 1/1/93 1/8/93I N/A feet MSL I One 17. Total Depth (MD+TVD) !18. Plug Back Depth (MD+TVD)19. Directional Survey J20. Depth where SSSV set 121. Thickness of Permafrost 12475'MD/9218' TVD 12426' MD/9176' TVD YES [] r~ []! 2077'feet MD ! 1900'(Approx.) I 22. Type Electric or Other Logs Run ML L/A C/D L L/ C N L/G R 23. CASING, LINER AND CEMENTING ~ SET"rING DEPTH MD CASING SiZE WT. PER FT. GRADE TOP BO'i-rOM HOLE SIZE CEMENT3',~ RECORD AMO~ PULLED 20" 91.5# H-40 Surface 81' 30" 400 sx Permafrost 13-3/8" 72# L-80 Surface 2598' 17-1/2" 2475 sx AS III& 400 sx AS 1 9-5/8" 47# L-80/SO0-95 Surface 59' 12-1/4" 7-5/8" 29. 7# L-80 59' 10641' 12-1/4" 595 cuft Class "G" 7" 26# L-80/13CR 10641' 12464' 8-1/2" 590 cuft Class "G" 24. Pedorations open to Production (MD+TVD of Top and Bottom and 25. TLJ~r,,K~ REC, ORD interval, size and number)x~_¢ SiZE DEPTH SET (MD) PACKER SET (MD) Gun Diarneter 3-3,/8" "*~/~ 4-1/2", 13CR 11837' 10571' & 1i'780' MD 12100'- 12124' 8837-8857' ~26. ACID, FRACTURE, CEMENT SQUFF-7'F. ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIALUSED 27. PRODUCTION TEST Date First Production IMethod of Operation (Flowing, gas lilt, etc.) 1/8/93 I Gas Lift Date o! Test Hours Tested PRODUCTK:~ FOR OIL-BBL GAS-MCF WATER-BBL ~SIZE IGAS-OIL RATIO TEST PERIOD ~ Flow Tubing Casing Pressure 3,ALCULATED OIL-BBL GAS-MCF WATER-DB/ OIL GRAVITY-APl (corr) Press. 24.-HOU R RATE ~ 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips, and presence of oil, gas or water. Submit core chips. Form 10-407 Submit in duplicate Rev. 7-1-80 C,O{'~ED ON REVERSES~DE 29. 30. GEOLOGK~ MARKERS i-~,-~MATION TESTS NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Sag River 12011' 8830' Shublik 12029' 8846' Sadlerochit 12100' 8908' A. iaska Oil & 8. as Cons. Commission 31. LIST OF A'FrACHMENT8 32. I hereby certify that the foregoing is true and correct to the besl of my knowledge Signed '" Title Drilling Engineer Suoervisor Date INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and Icg 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 (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift,. Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10-407 DAILY OPERATIONS BP/A3%I SHARED SERVICE PAGE: 1 WELL: DS 14-22A BOROUGH: NORTH SLOPE UNIT: PRUDHOE BAY FIELD: PRUDHOE BAY LEASE: API: 500292074701 PERMIT: APPROVAL: ACCEPT: 11/24/92 08:30 SPUD: RELEASE: 01/02/93 08:00 OPERATION: DRLG RIG: NABORS 2ES WO/C RIG: NABORS 2ES 11/25/92 ( 1) TD: 12509 PB: 12466 11/26/92 (2) TD:12509 PB: 12466 NU BOPS MW: 8.5 Seawater RELEASE RIG FROM DS ll-13A @ 0830 HRS. MOVE TO DS 14. ACCEPT RIG ON DS 14-22A @ 2030 HRS 11/24/92. PHASE 1 MOVING RIG. PHASE 2 WHILE RU. GUSTS TO 45 MPH. RU AND BLEED 350 PSI OFF ANNULUS (TRAPPED FROM PRE-RIG CIRCULATING). NO GAS. HANDOVER FORM INDICATES CEMENT OT 11,724' (20' ABOVE LINER TOP). RU LUBRICATOR TO PULL 5-1/2" BPV. PUMP OPEN SURFACE SAFETY VALVE. PULL BPV. CIRCULATE 48 BBLS DIESEL FROM TUBING. SWITCH LINES AND RECOVER 127 BBLS FROM ANNULUS. CONTINUE CIRCULATING HOLE VOLUME AROUND W/ SW. OBSERVE WELL: BALANCED. TEST 9-5/8" PACKOFF TO 2500 PSI - OKAY. CHECK LDS. PLUG CONTROL LINE PORTS. NU BOPS. MU BAKER 9-5/8 BP ON DP MW: 8.5 Seawater TEST BOP. LD 4-1/2. PREP TO RUN BAKER 9-5/8 BP TO 10960. 11/27/92 ( 3) TD:12509 PB:12466 RIH W/SERVCO SECTION MILL RIH & SET BRIDGE PLUG AT 10955' MW: 9.9 KC1 RIH W/BHA#1. 11/28/92 ( 4) TD:12509 PB:12466 RIH W/MULESHOE FOR CEMENT KO G MW: 9.8 RIH W/SECTION MILL. CUT SECTION TO 10835'_ CIRC. PUMP SWEEP TO SURFACE. POOH W/BHA#1. RIH W/4-1/2 MULE SHOE. KCl 11/29/92 ( 5) TD:12509 PB:12466 DRILLING CEMENT KO PLUG AT 105 MW: 9.9 KC1 RIH W/4-1/2 MULESHOE. TOP OF SECTION AT 10775'. TEST CEMENT LINES. PUMP WATER & CEMENT. POOH. TEST BOP. RIH. 11/30/92 ( 6) TD: 12509 PB: 12466 MW: 9.9 KC1 11/30/92 ( 7) TD:l1067' ( o) DRILLING 8-1/2 HOLE MW: 9.6 VIS: 53 DRILL SOFT CEMENT TO 10677' DRILLED FIRM CEMENT TO -- 10780'. DRILLIG AHEAD AT 11067' WELL : DS 14-22 OPERATION: RIG : NABORS 2ES PAGE: 2 12/01/92 ( 8) TD:11384' ( 317) 12/02/92 (9) TD: 11521' ( 137) 12/03/92 (10) TD:l1790' ( 269) 12/04/92 (11) TD: 11935' ( 145) 12/05/92 (12) TD: 12400' ( 465) 12/06/92 (13) TD:12464 PB:12420 12/07/92 (14) TD:12464 PB:12466 12/08/92 (15) TD:12464 PB:12466 12/09/92 (16) TD:12509 PB:12466 12/10/92 (17) TD:12509 PB:12466 POOH W/BHA#2 MW: 9.7 VIS: 47 DRILLING TO 11067' CIRC. DROP SINGLE SHOT SURVEY. SHORT TRIP. SLIP & CUT DRILL LINE. DRLG 8-1/2" HOLE MW:10.0 VIS: 53 POH LD MTR, CHG BHA, TEST MWD. RIH, WASH & REAM TO 11235. DRILL TO 11396. WORK PIPE HOLE CAVING REAM 11' TO BTTM. MADE CONNECTION REAM TO BTTM. CONT DRLG TO 11521. TRIP FOR BIT & BHA MW:10.0 VIS: 62 CONT DIRCTIONAL DRLG TO 11790. PUMP OPEN HOLE VOL DROP SURV. POH, PUMP DRY JOB. CONT POH, LD MRT & MWD, PU BHA #4. DRILLING 8-1/2 HOLE MW:10.0 VIS: 65 RIH TO 3285'. RIH W/BHA#4. DRILL 8-1/2 HOLE TO 11809' DRILL TO 11935' DRILL AHEAD MW: 9.8 VIS: 63 CONT DRLG. CIRC, LOST TOTAL RETRNS. MIX PILL & CONT DRLG. CIRC. DRLG @ REDUCED RATE TO 12400. COMP E-LOGS. MW: 9.9 KC1 DRLG TO 12464' CIRC. POOH TO SHOE. CIRC. RIH. CIRC. POOH TO SHOE. CIRC. POOH. L/D BHA. R/U ATLAS. LOG RUN: MLL/AC/DLL/CNL/GR. L/D DP. P/U BHA. MW: 8.5 Seawater R/D ATLAS. R/U CSG CREW. RIH W/ 7" LNR ON DP. CIRC. RIH. CIRC. PUMP 25 BBLS ARCO SPACER, 25 BBLS PREFLUSH, 105 BBLS (500 SX) 'G' CMT. DISP CMT. BUMP PLUG W/ 2000 PSI. SET HGR, PKR W/ 4000 PSI. RELEASE F/ HGR. REV CIRC. POOH. LOOKING FOR LEAK IN 9-5/8 CSG MW: 8.5 Seawater CONT LDDP. CLEAR FLOOR, SCRAPER & BIT RUN TO 12420. RV CIRC, CHG TO SW. TEST CSG, POH. PU RETRV BRIDGE PLUG, RIH. SET & TEST, POH. TEST PKR. RIH, TEST ANNULUS, TEST DP, LOOKING FOR LEAK. FREEZE PROTECT MW: 8.5 Seawater SET TEST PKR, TEST ANNULUS & DP. PKR HANGING UP, REV CIRC. SET PKR, TEST DP, TEST ANNULUS. WOO, POH & LD BHA. RIH, PU KELLY, SET BRIDGE PLUG & TEST. POH LDDP, CHG OUVER TO DIESEL. RIG RELEASED. MW: 8.5 Seawater F/PO WELL W/ DIESEL. POOH. L/D DP. P/U TBG HGR, 1 JT TBG. LAND TBG HGR. SET BPV. N/D BOPE. N/U TREE. TEST TREE. OK. SECURE WELL. RIG RELEASED @ 15:00 HRS, 12/9/92. WELL : DS 14-22 OPERATION: RIG : NABORS 2ES PAGE: 3 12/27/92 (18) TD:12464 PB:12420 12/28/92 (19) TD:12464 PB:12420 RIH W/TEST PACKER & RBP RETRID MW: 8.6 Seawater ACCEPT RIG ON 14-22A AT 1530 HRS. 12/26/92. ND TREE. NU BOPS. TEST KELLEY./ PULL TUBING HANGER. CIRC. & RECOVERED DIESEL. RIH W/BHA#1. POOH W/DUMMY SEAL ASSY MW: 8.6 Seawater SET TEST PACKER. CBU. POOH. RIH W/MILL. REVERSE CIRC. POOH W/BHA#3. 12/29/92 (20) TD:12464 PB:12420 12/30/92 (21) TD:12464 PB:12420 12/31/92 (22) TD:12464 PB:12420 01/01/93 (23) TD:12475 PB:12426 01/02/93 (24) TD:12475 PB:12426 PULL PACKOFF. MW: 8.6 Seawater POOH. L/D BHA. RIH W/ TEST PKR. SET @ 10662' TOL @ 10640'. TEST BELOW PKR. OK. SET @ 10652' (LNR TOP PKR) . TEST BELOW PKR. LEAK. SET @ 10656' (LNR HGR) . TEST BELOW. OK. POOH. L/D TEST PKR. RIH W/ RBP. SET @ 4946'. TEST. OK. POOH. RIH W/ RBP SET @ 1500' TEST. POUR 20/40 SAND ON RBP. RIH W/ TSA M~CH CUTTER TO i30' C/O TO DIESEL. ATTEMPT TO CUT. NO GO. POOH. RIH W/ TSA MULTI CUTTER. CUT CSG 3RD JT BELOW HGR. ATTEMPT TO CIRC OUT ARCTIC PACK. NO GO. POOH. L/D BHA. PULL PACKOFF. RIH W/ TIEBACK. MW: 8.6 Seawater PULL PACKOFF. RIH W/ TSA SPEAR. PULL 9-5/8" CSG. RIH TO 120' CIRC. RIH TO 1460' REV CIRC OUT SAND. LATCH RBP. RELEASE SAME. POOH. L/D RBP. RIH TO 4941' CIRC. POOH W/ RBP. TEST BOPE. RIH W/ 7-5/8" X 9-5/8" TIEBACK CSG. ATTEMPT TO DRILL/PUSH PLUG. MW: 8.6 Seawater RIH W/ 7-5/8" X 9-5/8" TIEBACK LNR. STAB IN @ 10640'. CBU. PUMP 40 BBLS DIESEL, 10 BBLS WATER, 106 BBLS (520 SX) 'G' CMT. DISP W/ SEAWATER. NO BUMP PLUG. N/D BOPE. SET SLIPS. CUT CSG. N/U BOPE. TEST BOPE. RIH W/ BIT, CSG SCRAPERS. DRLG WIPER PLUG & PUSH TO 9882' L/D 3-1/2" DP MW: 8.6 Seawater CONTINUE TO DRILL & PUSH 5/8" TOP CEMENT PLUG DOWN OLE. CIREC. SLIP & CUT DRILLING LINE 80' POOH. P/U 6" RR BIT. SEAL ASSY. RIH TO 12426' DPM. POOH L/D 3-1/2" DP. MW: 8.6 Seawater CONTINUE L/D 3-1/2" DP & BHA. PULL WEAR RING. R/U TO RUN 13CR COMP. P/U & RUN 4-1/2" 01/03/93 (25) TD:12475 PB:12426 RIG RELEASED MW: 8.6 Seawater CONTINUE RUNNING COMPLETION. LAND TUBING AND SET BPV. ND BOP'S TEST HANDER SEAL~ SET BAKER PACKERS. PUMPED 92 BBL'S DIESEL. CLEAN TANKS. REALEASE RIG @ 2000 HRS 1/2/93. SIGNATURE: (drilling superintendent) DATE: :;.: iN F'OiNT(TiF') = RECEIVED .Oil & Gas Cons. Commission /b~chora~e ORIGINAL ft !..7:,760, O0 i :.' 02<--',' ~' /£ i i* '-""- '?'-' 11315:? 11367:-54 ;!437,73 -.%2+£ ........ ._ 33,70 6,0.:' £ + 3424,17 8450, I'-:' 8474:55 8553,6.7 ,_-,.:---,~." ~ 14 ASg9 30:5 _-,,,:,.,_.., .,.,o .:x,TE, iii.: 3"-.'. 270,5,34 - O,_'."-iO ~. OC. 5 CC.-,?, f~,?._-: ~, ::~ i ! 6, ,5~ ........ '"' ?7:qA, 75 .z.,: .-' ,' z 117,17 -c, zo,.,, z~ .....o..' _,,,,:,- ,,.-~, .:;.-', :.-., : ~,.-:.:,. -6231,&3 2757,13 3, E.-7. 6:.25 3,53 2,57 2 C7i,2i ; z _.,.'-; ~ ~ 4,t ," A784,4-.'; '5 ;, 35 O, E.7 .. , ~ A797,, ,' ~.:.o, '; ..-', i 6,f., i¢ __. ~! ;., 662:,37 isA, t4 .3,7.-7.- 161.,~.0 ~ ~r, RECEIVED FEB O 1 1993 Alaska Oil & Gas Cons. 6ommis¢i¢~ Anchorage , ,- $2,5 .~:";i,f,,6':'. 47Sr_. ~- · -,-. . ,1,*.'>, .d'...' 4~2 47A'-7 ,, :. ~,37,,.',5 i42,55 -w',~.~ 480'.:", 95 .-z Si 141.,02 .......... -: ¢, .... 'OV., ..: i,.- r 4~2A '"" 36.,'" ...... " w ~.,-~ - · ,.~ ..-.:, 18 13~ .: '.~< -,:.iv i ,5" · h. ~.., ~., :,-. O~,./U i d.'t'-- .: ../"' ',~, ~..C. 4 :''~ ? .d .d 4,':-:3~', 30 ,:,:'"' ,- <..,"'" i 35. Ob -6137, ~2 . ,:,:., ~/ !.:,', '6'.-" 50, '~-" .,, .,v',,._~ i?.. S".-; · .~;. * - i ...... 5022 .... ~ 117 ~' "-"""' e'~ 5C ~-~-'" ~ .... ., _,/z 117, - 506Z,,~4 '} 2,9-0 i 16~ 53 - Z705.,34 ^77~ ,21 '~' "' · ... , .,. .,_.,, .:,.: ~'"" "= 6797,72 ~" "' £,,' ,.'.C ~ / J '~'~=1 ,.r'7 A,~I 0,,°':-' "~' 17 ~, ,' .2 ,-','. -. .,.-' J. J' 0 ~., ,' .r ~ i..3 ,.,, £.20 ~ . iO::Y t ,-1 2', $3 + 'v'7 ..,' ,, 43 :5.':"?(:' 1,47 4,72 O, 6,- i, 16 d+,' Z: 240, .NNABARLOOP ANCHORAGE, ALASKA 99507 (907) 349-6575 December 4, 1992 Prudhoe Bay Unit P.O. Box 196612 Anchorage, AK 99519-6612 Attention: Larry Parnell Dear Larry, I have compiled a summary of Anadrill's performance on DS 14-22A, Nabors 2ES. SERVICES PROVIDED Directional MWD with DWOB and DTOR were picked up on 28-NOV-92 to kick off the well. After drilling about 220' of cement we began kicking off at 10780'. On Nov 30/92 we slid and rotated to 11383' and then tripped for a bit. The kickoff was continued with a new bit and 1 1/4 degree motor on 01-DEC-92 until we locked a cone on the bit at 11792' on 02-DEC-92. Tripped out of the hole and laid down MWD and motor on 03-DEC-92. .IOB PERFORMANCE DSS with downhole weight on bit and downhole torque were used to side track DS 14- 22A. The DWOB was used effectively to assist in the sidetrack process. The 2" MEL (mechanical efficiency log) indicated that the bit was in new formation at 10810'. The cement plug was a good hard plug making the kickoff routine. On the first bit run we began to see XSTQ (excess torque) around 11250' which indicated an under gauged bit. MEL gave a teeth wear of 4. When we pulled the bit for for a motor change the bit was a T4, SF, with two loose cones. A 1 1/4 degree motor was picked up because the 1 degree was not turning the well fast enough. On the seCond run the bit balled up when we first getting on bottom. After it was unballed the run went well until the end of bit run where we stopped getting good reaction from our slides, and the bit was pulled due to ROP. MEL indicated an under gauge bit and on the surface the bit had a locked cone and was found to be under gauged. Of the 96 surveys taken 8 were used by the directional driller and 24 were good surveys. The final survey calculation gives the following · SURVEY DEPTH: 10728' TRUE VERTICAL DEPTH' 8589.36' SOUTH: 6232.67' EAST: 2756.73' SECTION: 5062.22' For your convenience 1 have included a hard copy of the surveys, a SPIN log and a MEL log. Anadrill appreciates the opportunity to supply services on your well and we look forward to continuing a healthy business relationship. Thank you, Dan Bordelon Manager Alaska ~lley'~/ Field Service Manager check off or list data as it is receiv~d.*list, , received date for 407'. if not required list as NFl 40? I * ~!~'i¢~"~ drilling history V/' survey! ~ ! well tests ~ ! core descriPtio~U~ ,co,red interval,s core analysis rfol0., dry ditch intervals digital data LOG TYPE RUN INTERVALS SCALE NO. [to thc neare~t,footJ [inchl100'1 , 9) ~~ ~ ~t, i i i , 131 ~ ~ ll~~l~t~ ,,~ , "~41 ~~ . I ~ ~ ~o-~oo i I I I I I II I I I I I I I I I I ARCO Alaska, Inc. P.O.Box 100360 Anchorage, Aluka 99510 DATE: 12-21-92 REFERENCE: ARCO DIRECTIONAL DATA ~-'l[,~ -!I-13A 11-9-92 MWD Directional Survey Ana - ~Z~2-~_..14-22A 11-29-92 ~,~ Directional Survey An-, 7-20 10/4-15/92 MWD Directional Survey J*ob~ 1149 Teleco 7-21 12-3-92 MWD Directional Survey dob~ 1153 Teleco ~tf.,./8-22 11-30-92 MW'D Directional Survey Job#AK-MW'-20092 Sperry "-~AGI-1 11-23-92 MWD Directional Survey Job~ 1152TAK Teleco r~~~I-2 12-1592 MWD Directional Survey Jot~ 1156 Tel~ Please sign and return tl~e attached copy u receipt of data. ATO-1529 CENTRAL F~ CHEVRON D&M # EXTENSION EXPLORATION # EXXON MARATHON MOBIL PHILL~ # PB WELL FILES R&D # BPX # ST. OF AK. (2 COPIES) IY. XACO RECEIVED. FEB 0 1 199~ ~aska Oil & Gas Cons. Commls.s~_ri _Anchorage. ~.RCO Al~ka, Inc. P.O.llox 100360 Ancho~ge, Alaska 99510 DATE: Ja~uaxy 25,1993 }3EFERENCE: 1-24A 12-224)2 ARCO MAGNETIC TAPE(5) WITH LISTINGS ~,l~CiCalOR v~ i ~.~ l ~C l Cr~ l aR ~lv~i~ VI~ISV~IC~rH Run I Job~5822 Run I Job~5578 Run1 J~37 Run I Job~93033 Run I Job~5605 Please sign and return, th/~ attac~~ copy as receipt of dat~ Ilave A Nice Day! CHEVRON D&M BOB OCANA~ (OH/G~) F. JiCXON I~/ARATHON MOB~ C~nya W~llace ATO-1529 APPROVED_ff~__ Trans# 93016 TgX~CO The correct well na~e for this 1-24A not 1-24ST. This taa revised tape, please replace previous tape. The correct APl# for 14-22A is 50-029-20747-01. Atlas Atlas 8ch Sch Atlas ARCO Alaska, Inc. P. OJ3ox 100360 Anchorage, Alaska 99510 DATE: 12-18-92 RE~~~: ARCO OPEN HOLE FINAI~ ~14-23A 14-33A 14-23A 14-22A '17-21 17-21 17-21 17-21- 17-21- AGI- 1 13-6-92 9STVD 12-8-92 DLL/M/,L/GR 12-6-92 BHCA/GR 12-8-93 CNL/GR 12-~-92 BH ~o~e 11/3~12/1/92 D~/~n 11/3o. 13/1/~3 DPR/G~ ~ 11/30-12/1/92 Den Poro/G~ ~ ~rr~ 11/3o-12/1/~3 ~P~/~ro/GR 11/lS-So/o~ aWD: D~R/~/~X~ 11/18-~o/92 11/18-3o/99 lX/1~-3o/~ 11/18-3o/~ ZZ/lS-So/~ 11/~o-~/~ 11/~o-~s/~ Rum 1, l"&3" Atlas Run 1, 3"&BY Atlas Run 1, 3"&5' Atlas Run 1, ~'Sd~' Atlas Run 1, ~' Atlas Run 8, :r'&~MD Teleco Run 8, 3~'&~D Teleco Run 8, 3"&~M]) Teleco Run 8, 5'~D Teleco Run 8, 3"&5'~l'v'D Teleco Run 8, :r'&5'~l~v'D Teleco Run 8, 3~'&5'~-D Teleco Runs 7-14, :F'&5"MD Sperry Runs 7-14, 5"MD Sperry Runs 7-14, 2"&5"MD Sperry Runs 7-14, 3~'&S'~v'D Sperry Runs 7-14, 5'~l'v'D 8perry Run~ 7-14, ~"&5'Tv'D Sperry Run 5, 3"&~I) Teleco Run 5, 3"&5'~D Teleco Please sign and return the attached copy a~ receipt of dam. Have A Nice Dayi Sonya Wallace AT0-1529 # CENTRAL FILES # CHEVRON #D&M # EXTENSION EXPLORATION # EXXON MARATHON # MOBIL # ~-T.TPS # PB WELL FILES R&D #BPX # STATE OF ALASKA #TEXACO MEMORANDUM STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION to: Gri~,,,,, ¢..('~ (", ~ Leigh Commissioner date: file: thru: Blair E Wondzell Sr Petr Engineer from: Lou Grimaldi Petr Inspector subject: December 28, 19'92 LOU1281.DOC RIG/BOP Inspection Nabors Rig #2-ES Arco Well #14-22 I~ Prudhoe Bay Unit PTD 92-123 Tuesday, December 8, 1992: I made a RIG/BOPE Inspection on Nabors Rig #2ES which was performing a redrill on Arco's Well 14-22 in the Prudhoe Bay Unit. The rig and its surrounding area had been kept clean and orderly as is the usual case with this rig. Don Wester (Arco Rep.) and Charles Henley (Nabors Toolpusher) accompanied me on my tour of the rig. I found all equipment to be in place and having evidence of regular maintenance. This rig is scheduled to move to drillsite #1; I shall return to this rig for its initial BOP Tests on Arco's Well PBU 1-24. SUMMARY: I made a RIG/BOPE Inspection Nabors Rig 2-ES on Arco's Well 14-22. There were no non-compliances noted. () () () () () () () 1.() 2.() 3.() e.() " 6.() ,. ., / ~.'7, () STATE OF ALASKA AL~KA OIL AND C~$ CONSERVATION COMH. ON RIg/BOPE In, parc*on Report Wkvr ,_~ U I'C line sz & length lfne ¢onn& anchored bifurcated & dwn wind 90* target, ed turn~ vlvs: auto & simultineou~ annular peck*off oo~itlon B. BOP STA~ ~11heed flg wkg pre~ stack wkg press annular preventer pipe rams blind ram, ( ) stack anchored ( ) chke/kt11 11ne ,z ( ) gOo turns targeted (chke & ktll ln) ( ) HCR yty$ (cbOe & kill) ( ) manual ylvs (chke & kt11) ( ) connection, {flgd, whd, clmpd) ( ) dr1 spool ' ( ) 1flow nipple ( ) flow monitor ' ( )' control lines fire prote~ted C, CLOSINC UNITS 7: : ~ _ -. :-__ ( ) wkg pres~ ( ) flutd level ( ) oprtg pres, ( ) press ( ) sufficient vlv$ ( ) regulator bypass ( ) blind handle cove~ ( ) arJller.contro1 panel ( ) remote control penal .... -:..: IN COMPL I ANCE~ 33. ~ ( ) ( ) ft~e~il 34,~ ( ) ( ) nttrogen po.er source (back-v~ ~5. ( ) ( ) condition (leaks, beset, e~c' D, h~LO SYSTEM ( ) ( ) pit level floats irs~alle~ 37. '~/ ( ) ( ) flow ,~ 38, ~ ~ ) ( ) mud 9~s separator ~1, ( ) ( ) gas s~n,or q2. ~ [ ) ()chke In corm ~3, ) ( ) ~rtp tank E, RIG FLOOR ~4, (l ( ) ( ) kell>, cock, (upper,lo~er,lBC, P} ~5, (~-~ ]~?'( ) ( ) 71oo. ,.lv, (d~?t ~G, (~)~ ( ) ( ) k~lly ~ floor ~1o¥, rate ~nd~cator~ p:% 'a., ~ndtcators, gaugc, s ) ~8, ( ) ( ) ktll ~heet up-to-date (H & ~thene ) '~ ( ) ( ) hydr chke pan~i 50, 51, ~ ( ) ( ) chke ~.'an~fold 5~,~ ( ) ( } 90~ ~urn~ se. (/.~ () sr.() () (d?(n strm choke ,(~ rese"' ~ pit t~nkage ( ) personnel protecti'e (Z~H2 ;or procedures pr9Oe$ ( ) rig housekeeping Date of les~ BOP inspection: ~ Date of las~ BOP test! ' Non*~pll~nce~ not corrected ? ',,' Date corrections will be completed; BOP re,t; & reiul~ properly entered on daily record? '<, ." ' I nsp~tor ....... -,_. Ktll sheet current? WALTER J. HICKEL, GOVERNOR ALASKA OIL AND GAS CONSERVATION COMMISSION 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 TELECOPY: (907) 276-7542 November 24, 1992 Michael Zanghi Drilling Engineer Supervisor ARCO Alaska, Inc. P O Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Unit DS 14-22A ARCO Alaska, Inc. Permit No. 92-123 Sur. Loc. 2598'SNL, 1586'WEL, Sec. 9, T10N, R14E, UM Btmnhole Loc. 3665'SNL, 3764'WEL, Sec. 15, T10N, R14E, UM Dear Mr. Zanghi: Enclosed is the approved application for permit to redrill the above referenced well. The permit to redrill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25 035. Sufficient notice (approximately 24 hours) must be given to allow a representative of the Commission to witness a test of BOPE installed prior to drilling new hole. Notice may be given by contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. Chairman BY ORDER OF THE COMMISSION dlf/Enclosures CC: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 2O AAC 25.005 la. Type of work Drill [] Redrill Eillb. Type of well· Exploratory[] Stratigraphic Test [] Development Oil [] Re-Entry [] Deepenl-'11 Service [] Development Gas [] Single Zone [] Multiple Zone [] 12. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool ARCO Alaska, inc. KBE =71' feet Prudhoe Bay Field/Prudhoe 3. Address 6. Property Designation Bay Pool p, O. Box 196612. Anchorac~e. Alaska 99519-6612 ADL 28314 4. Location of well at surf-ace 7. Unit or property Name 11. Type Bond(see 20 ^^c 2s.o2s) 2598' SNL, 1586' WEL, SEC. 9, TION, R14E Prudhoe Bay Unit At top of productive interval 8. Well number Number 3590'SNL, 3930' WEL, SEC. 15, TION, R14E DS 14-22A U-630610 At total depth 9. Approximate spud date Amount 3665' SNL, 3764' WEL, SEC. 15, TION, R14E 12/1/92 $200,000.00 12. Distance to nearest 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD a,d TVD) property line ADL 28312- 3665' feet No Close Approach feet 2560 12412' MD/9171' TVDfeet i16. To be completed for deviated wells 17. Anticipated pressure (sm 20 AAC 25.035 :Kickoff depth ~o76ofeet Maximum hole angle ,~5.5 o Maximum surface 3330ps~g At total depth ('rVD) 18. Casing program Setting Depth s~.ze Specifications Top Bottom Quantity of cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) 8-1/2" 7" 26# L-80/ TDS/Fox 1802' 10610' 7704' 12412' 9171' 388 cu ft Class "G" 13CR i19. To be completed for Redrill, Re-entry. and Deepen Operations. "~' ~! ~ ~ I ~,~¢ ~ Present well condition summary Total depth' measured 12509feet Plugs (measured)i',;r'i/", ;,._) v"'- 0" ~ C"O r*~ ,,~.~ true vertical 9202feet Ai~S!.~ 0JJ & Ga:; Coi~$. Effective depth: measured 12466feet Junk (measured) true vertical 9167feet Casing Length Size Cemented Measured depth True Vertical depth Structural Conductor 81' 20" 400 sx PF fl 81' 81' Surface 2598' 13-3/8" 2475 sx AS ill & 2598' 2587' Intermediate 400 sx AS I P re d u ct io n 12066' 9-5/8" 500 ¢x AS ~/~,300 ~x ,~S ~ 12066' 8845' Liner 765' 7" 300 sx Class "G" 11744'-12509' ~2240'-12252' Perforation depth: measured 12032'-12047', 12070'-12100', 12118'-12151', 12158'-12178', 12182'-12236', 12240'-12252' true vertical 8818'-8830'~ 8848'-8873'~ 8887'-8914'~ 8919'-8935', 8939'-8982'~ 8985'-8995' 20. Attachments Filing fee [] Property plat [] BOP Sketch [] Diverter Sketch [] Drilling program ITl Drilling] fluid pro~lram [] Time vs depth pict [] Refraction analysis[] Seabed report[] 20 AAC 25·050 requirements[] 21 I hereby · certify~that th.e foregoing is true and corr~the best of my knowledge Si~ned {" '~ ~ Title Drillin~ En~lineerSupervisor Date/'[~ . Commission L~se Only Permit Number IAPI number ~'~Y~pproval date ISee cover letter ~ |/?-~'~¢-~',~...~lfor other requirements !Conditions of approval Samples requir.ed [] Yes ,,~['No Mud Icg required i-lYes ~ No Hydrogen sulfide measures [] Yes ~ No Directional survey required .,~ Yes [] No Required working pressure for BOPE FI2M; 1-13M; ~5M; I-]10M; FI15M; Other: Origins! Sioned By by order of - Approved by David W. Johnston Commissioner ,ne comm.ssion Date -- Form 10-401 Rev. 12-1-85 Submit in triplicate PRELIMINARY WELL INFORMATION WELL' DS 14-22 A Redrill PBU EOA APl N~.: 50-029-20747-00 (on the original 14-22 well) LOCATION' Surface: 2598' FNL, 1586' FEL, Sec. 9, T10N, R14E Target: 3590' FNL, 3930' FEL, Sec. 15, T10N, R14E @ 8820' ss BHL: 3665' FNL, 3764' FEL, Sec. 15, T10N, R14E @ 9100' ss Original KBE: 71' AMSL ESTIMATED START: 1 December, 1992 OPR. DAYS TO COMPLETE: 15 CONTRACTOR- Nabors Rig #2 ES DIRECTIONAL: Kickoff at ~ 10760' MD with a 4°/100' constant curvature drop / turn to 33° inclination on an azimuth of S 66° E. Max angle' 45.5° (at KOP). No close approaches. WELLBORE: Item . KOP TOP SAG RIVER TOP SHUBLIK TOP SADLEROCHIT TOTAL DEPTH LOGGING PROGRAM' TVD(BKB) MD(BKB) Mud Wt. 7825' 10760' 9.4 8797' 11965' 9.5 8831' 12006' 9.5 8881' 12066' 9.5 9171' 12412' 9.5 RECIEIV D NOV - 5 1997~ Alaska 0il & Gas Cons. 6on~rnissi¢ 8-1/2" Hole' Atlas GR / SP / DLL / BCS / CNL by electric line. Anchorage MUD PROGRAM' The milling / drilling fluid program will consist of a 9.4 - 9.6 ppg Biozan polymer / KCI water based mud in the 8-1/2" hole. DEPTH DENSITY ('I-VD) (PPG) KOP' 9.4 to to TD' 9.6 PV YP INT 10 MIN FL OIL SOLIDS MUD (CP) (#/FT) GEL GEL (~c,./30min (%) (%) TYPE 10 10 5 7 8 0 5 Water to to to to to to to Base 1 6 1 8 1 0 1 5 5 0 7 ' Mud MUD WEIGHT CALCULATIONS / WELL CONTROL: Est. Pore Press. Sag River: Est. Pore Press. Sadlerochit: 4130 psi/8740' ss TVD. 3600 psi/8800' ss TVD. Mud Wt.' 8-1/2" Hole = 9.5 ppg. Overbalance Sag River: 181 psi. Overbalance Top Sadlerochit' 747 psi Well control equipment consisting of 5000 psi W.P. pipe rams, blind rams, and annular preventer will be installed and will be capable of handling "worst case" situations as follows: Maximum possible bottomhole pressure is 4390 psi at 8800' TVDss based upon original reservoir pressure. Maximum possible surface pressure is 3400 psi based upon a gas column to surface from 8800' TVDss with no oil column. Fluids incidental to the drilling of a well will be removed by truck and disposed down CC-2A. LINER DETAILS' CASING DEPTH 7" 26# L-80 TDS / 13Cr-80 Fox · "10610' - 12412' MD BURST 00LLAPSE TENSILE 7240 psi 5410 psi 604 klbs CEMENT CALCULATIONS' 7" LINER' Measured Depth: Basis: 10100'MD (Hanger)- 11790'MD (Shoe) 40% open hole excess, 40' shoe joint, 150' liner lap and 200' excess above liner with DP. Total Cement Vol: 388 cuft or 335 sxs of Class G blend @ 1.16 Cu ft/Sk TUBING DETAILS: 4-1/2" 12.6# 13CR-80 Fox (Surface- 11850' MD) ,~Jaska .0JJ & Gas Cons..~;orr~missior~ ;~.~chorage NABORS RIG NO. 2ES MUD SOLIDS CONTROL EQUIPMENT 2 - Continental Emsco Fl000 Mud Pumps 1 - Derrick FIoLine Cleaner Shale Shaker 1 - Mud Cleaner 1 - DRECOGas Buster 1 - Pioneer Sidewinder Mud Hopper 1 - 5 HP Flash Mixer Agitator . 3 - Abcor 10 HP Agitators 1 - 50 bbl. Trip Tank 1 - Recording frilling fluid pit level indicator with both visual and audio warning devices at driller's console. 1 - Drilling fluid flow sensor with readout at driller's console RE E VE NOV - Alaska 0ii & (;as Cons. Anchorage DS 14-22 A Objective: The primary objective the 14-22 A redrill is to achieve water shut-off and optimize wellbore placement. A new hole will be ddlled starting from deep within the existing wellbore to a location about 500' northeast of the current BHL. The redrill is designed to move away from a 22' fault that intersects the current wellbore in the Shublik "C". This fault is suspected to be a conduit to the aquifer and responsible for the high water cut from the current wellbore. Well 14-22 is currently producing with a high water cut (85-95 %) and a slight leak to gas only in the 9-5/8" casing. An annular communication waiver (2000 psi maximum) allows continued production since current conditions are well within the restrictions of the waiver. Further diagnostic work is planned in an attempt to isolate the leak, but no remedial work is planned at this time. Scope: The scope of the 14-22 A redrill is as follows: Plug and abandon the original perforations and pull the existing 4-1/2" tubing completion. Mill a 60' section in the 9-5/8" casing starting at 10700' MD. Lay a cement plug across the section, kickoff and drill a new 8-1/2" hole to a target about 500' northeast of the original wellbore. Obtain E-line logs. Run and cement a 7" 26# L-80 / 13CR liner. Clean out to the landing collar. Recomplete with 4-1/2" 13 Cr tubing and prepare well for post-rig perforation. Remedial work for annular communication is not within the scope of this program. Timing: This redrill is presently scheduled for Nabors Rig 2ES upon completion of activity on DS 11 in late November / early December, 1992. The redrill should take approximately 15 days. ,Oil 8, Gas Cons. rjorr~n~issio;~ ~,r~chorage LAP Pa.qe 1 10/22/92 REDRILL SUMMARY DS 14-22 A PROCEDURE: RECEIVED N 0¥ ~ 5 !99~ ,4iaska 0il & Gas Cons. 60mr~ission Anchorage I . . Pre-dg work: Kill well. Lay cement plug across perforations to at least 100' above top perforation. Cut 4-1/2" tubing just above the packer PBR. Freeze protect and set a BPV. Move in workover dg. Test 9-5/8" intermediate casing pack-off if not done during pre-rig work. 3. Pull 5-1/2" BPV. Circulate freeze protection cap from well. 4. Set a two-way check valve and remove the production tree. 5. Install BOP's and test to 5000 psi. Remove the two-way check valve. 6. Pull and lay down the 4-1/2" tubing. 7. Run 9-5/8" casing corrosion Icg (Schlumberger USIT)if needed . . 10. 11. 12. 13. 14. 15. 16. 17. Set a drillable bridge plug in the 9-5/8" casing at 10900' MD or 200' MD below the top of the proposed section. Spot a 17 ppg pill on bottom and cut a 60' section in the 9-5/8" casing from about 10700' to 10760' MD. Spot a balanced cement kick-off plug (170 cubic feet minimum) from 100' below the base of the section to 200' above the top of the section. Replace the 9-5/8" casing pack-off as needed. Run in with an 8-1/2" steerable drilling assembly and dress the cement to 5' below the section top. Kickoff and directionally drill to align well with target. Follow with an 8-1/2" packed hole assembly and drill to the target at 150' MD below the OOWC of -8957' ss (see directional plan for more details). Run wireline conveyed open hole (GR/DIL/CNL/BHCS) logs. If a DLL is used in place of the DIL, a micro-resistivity Icg will be required. Run a 7" 26 # L-80 / 13Cr liner assembly to bottom in the 8-1/2" hole. Space the liner hanger and top isolation packer about 150' up inside the 9-5/8" casing. Cement the liner in place with the total cement volume based upon 40 % open- hole enlargement plus the shoe volume, lap volume and 200' excess on top of the liner with drillpipe in the hole. Re-test the 9-5/8" casing pack-off and replace as needed. LAP Pa.qe 3 10/22/92 DS 14-22 A 18. 19. 20. 21. 22. 23. 24. 25. Clean out the liner to the landing collar and test to 3500 psi. Displace well to filtered and inhibited seawater. Run a 4-1/2" 13CR completion string and 7" packer. Space out, land tubing hanger and set packer. The packer should be set at about xxxx' ss with the tubing tail above any future objective.. Test tubing to 4000 psi. Test tubing by casing annulus to 3500 psi. Set two-way check valve. Remove BOP's. Install and test the production tree to 5000 psi with diesel. Pull the two-way check valve. Shear RP valve in the upper GLM and freeze protect the well. Set a BPV. Release workover rig. Complete appropriate documentation and hand-over to Production for perforation. Anticipated BHP: 8.1 ppg equiv. Drilling Fluid: 9.5 ppg Workover Fluid: 8.5 ppg. Alaska OJJ & GaS Coris. 6or¢.missio~'~ Anchorage LAP Page 4 10/22/92 FROM:GREAT LAND DIR.DRILLI,bLc, TO:BP E×PLOR DRILL.lNG OCT 14, 1992 12:51PM .. G~AT LAND DIRECTIONAL DRILLING, INC. Corporate Office 1111 Mast 80th Avenue Anchorage, AK 99518 (907) 349-4511 Fax 349-2487 DIRECTIONAL W~LL PLAN for PRUDMOE BAY DRILLING Well ......... : DS 14-22A (Pi) Field ........ : PRUDMOE BAY DRILL SITE 14 computation..: MINIMUM CURVATURE LEGAL DESCRIpTIoN Surface ...... : 2598 FNL 1586 FEL S09 T10N R14E UM Tie-in ....... : 3107 FNL 4484 P~L S15 T10N R14E UM Target ....... : 3590 FNL 3930 FEL S15 T10N R14E UM BHL .......... : 3665 FNL 3764 PEL S15 T10N R14E UM Prepared ..... : 10/14/92 Section at...: $,65.89,E KB elevation.: 71.00 X ASP ZONE 4 Y 674920.49 5937735.31 677449.65 5932003.80 678016.00 5931534.00 678183.91 5931463.57 PROPOSED WELL PROFILE STATION IDENTIFICATION TIE-IN MEAS INCLN DEPTH ANGLE VERT-DEPTHS SECT BKB SUB-S DIST 10760 45.50 7825 7754 10800 44.48 7853 7782 10900 42.08 7926 7855 11000 39.83 8001 7930 11100 37.86 8079 8008 DIRECTION REL-COORDINATES DL/ BEARING FROM-WELLHEAD 100 4551 S 18.41E 4570 S 20.15 E 4620 S 24.79 E 4671 S 29.87 E 4723 S 35.42 E 5789 S 2395 E <TIE 5816 S 2404 E 4.0 5879 S 2430 E 4.0 5938 S 2460 E 4.0 5990 S 2494 E 4.0 BASE HRZ PUT RIVER 11140 37.18 8111 8040 11200 36.16 8159 8088 11300 34.79 8241 8170 11400 33.79 8323 8252 11500 33.18 8407 8336 4745 S 37.82 4777 S 41.44 4831 S 47.92 4885 S 54.80 4940 S 61.97 6010 S 2508 E 4.0 6038 S 2531 E 4.0 6079 S 2572 E 4.0 6114 S 2616 ~ 4.0 6143 S 2663 E 4.0 END OF CURVE SAG RIVER SHUBLIK GOC SADLEROCHIT Z4 11554 33.03 8452 8381 11965 33.03 8797 8726 12006 33.03 8831 8760 12066 33.03 8881 8810 12066 33.03 8881 8810 4969 S 65.89 5194 S 65.89 5216 S 65.89 5248 S 65.89 5248 S 65.89 6156 S 2689 E 4.0 6247 S 2894 E 0.0 6256 S 2914 E 0.0 6270 S 2944 ~ 0.0 6270 S 2944 E 0.0 TARGET OWC MOT SADLEROCHIT Z3 TD 12078 33.03 8891 8820 12137 33.03 8941 8870 12205 33.03 8998 8927 12367 33,03 9134 9063 12412 33.03 9171 9100 5255 S 65.89 5287 S 65.89 5-324 S 65.89 5413 S 65.89 5437 S 65.89 6272 S 2950 E 0.0 6286 S 2979 E 0.0 6301 S 3013 E 0.0 6337 S 3094 E 0.0 6347 S 3116 E 0.0 SADLEROCHIT Z2 SADLEROCHIT KAVIK Aiaska Oii & Gas Cons. t.~¥c~~-issi°~''' Anchorage 9222 9151 9462 9391 9527 9456 (CLOD (c)92 DS1&22^ I~1,S6 11:~7 AH 2) FROM:GREAT LAND DIR.DRILL!kL~ TO:BP EXPLOR DRILLING ,~-OCT 14, 1992 12:51PM P.03 PRUDHOE BAY DRILLIN8 B) END OF CURVE lt554 8452 4969 33.03 C) TARGET ~2078 8BgJ 5255 33,03 D) TO t2412 9~?~ 5437 33,03 DS 14-22A (Pl) VERTICAL SECTION VIEW ........ .-~ ..... i i i i ~!~ i Section at: S 65 89 E TVO Scale' I inch = 300 feet Oep Scale.' t ~nch - 300 feet [\iOV ~,~ !~,? Drawn ' 10/14/92 Alaska Oil ~ Gas Cons. ..... UUL~l~ Great Land Directional DrjJIJng 4200 4350 4500 4650 4800 4950 5]00 525O Section Departure 5400 5550 5700 5850 BOOO 6~50 6300 · IIm,m~mL..m.I- ....... i i iSSiOr..- FROM:GREAT LAND DIR.DRILLI~G~ -i-.--, ........ h Il il .............. ~ark~r Identtfic~l~on Al TIE-iN B) END OF CURVE TO: BP EXPLOR DR ILL I NG PRUDHOE II I I 14D N/S E/w J0760 5789 1t554 6t58 ~268§2295 12078 62?2 12412 6347 ~ 31t62950 OCT 14, 1992 12: 52PM BAY ....b"RIL'LING ----im ~ ........... DS 4-22A PLAN VIEW ]'L]]_ __ - - -- I I In, II I I I CLOSURE ' 7070 ft at S 25.t5 E DECLINATION,' BO.O0 E SCALE ....... : I inch - 1200 feet DRAWN ....... : 10/14/92 NOV - R .mt~,~ Oil & 6as Cons. Commissior~ Anchorage u · Il I.Illl i ............. Sreat Land £lroctiono] DrJlJlng II P. 04 600 0 600 <- WEST · EAST -> 1800 lBO0 2400 3000 3600 il lull 4200 4800 5400 6000 6600 7200 lilt':".'_ - I i i,illUl, i, , 7800 NABORS 2ES 1 0' 4.95' 4; 17' 4.85' 1.68' 1.88' 1.50' 2.17' 1.42' GROUND LEVEL 13 5/8" 5,000 psi Stack r,- RKB 1 DRIP PAN KB TO BF RI i FLO HYDRIL PIPE RAM 12.19' BLIND RAM MUD CROSS PIPE RAM I I MUD CROSS TBG SPOOL I ~ASE FLG ~ / 16.37' 18.25' 22.20' I24.68' 26.85' V - 5 !992 Gas Cor~s. Corr~rnission Anchoracje 28.25' Page '1 State: Alaska Borough: Well: DS 14-22A Field: Prudhoe Bay St. Perm ~92-123 Dale 11110/92 Engr: M. Minder DS14-22A.XLS Casing Interval Interval Size Botlom Description Description Description Tension Top Length lA 7 9171 7704 1802 ZA 0 0 0 0 3A 0 0 0 0 4A 0 0 0 0 5A 0 0 0 0 6A 0 0 0 0 7A 0 0 0 0 8A 0 0 0 0 9A 0 0 0 0 10A 0 0 0 0 Lbs Grade Thread Lbs 26 L-80 TDS/FO× 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 lB 3B 4B 5B 619 7B 8B 9B 10B Mud Hydraulic Wieght Gradient ppg psi/ft 9.6 0.499 0.0 0.000 0.0 0.000 0.0 0.000 0.0 0.000 0.0 0.000 0.0 0.000 0.0 0.000 0.0 0.000 0.0 0.000 Maximum Minimum Pressure Yield psi psi BDF 4390 7240 1.6 0 0 #DIV/O! 0 0 #DIVi0! 0 0 #DIViO! 0 0 #DIVI0! 0 0 #DIM/0! 0 0 #DIVI0! 0 0 #DIV/O! 0 0 #DIVI0! 0 0 #DIV/0! Tension Strength K/Lbs 1C 46,852 2C 0 3C 0 4C 0 5C 0 6C 0 7C 0 8C 0 9C 0 10C 0 K/Lbs TDF 604 12.89 0 #DIV/O! 0 #DIV/O! 0 #DIVIO! 0 # DIVIO.I 0 #DIV/O! 0 #DIVIO! 0 # DIViO.I 0 #DIV/O! 0 #DIV/0.1 Collapse Collapse Pr-Bot-Psi Resist. CDF 4578 5410 1.182 0 0 #DN/0! 0 0 #DIV/0! 0 0 #DIVI0! 0 0 # DIV/0.1 0 0 #DIV/0! 0 0 #DIVIO! 0 0 #DIV/0! 0 0 #DIVI0! 0 0 #DIV/0! ITEM (1) F~ (2) Loc ** CHECK LIST FOR NEW WELL PERMITS ** APPROVE DATE h u '8 ] ' (3) Admin ~ fx~/~z~ 9. '[~9 ~hru 'i3'3 / 10. [10 $ 13] (4) Casg [14 thru 22] [23 thru 28] Company YES 1. Is permit fee attached ............................................... ~ 2. Is well to be located in a defined pool ............................. ~ 3. Is well located proper distance from property iine 4. Is well located proper distance from other wells.. . Lease S We l l ~ ~Z ~,~,~, ? ~ / /,,~2~,~,/, NO REMARKS 5. Is sufficient undedicated acreage available in this pool ............. ~_ 6. Is well to be deviated & is well bore plat included ................... ~ 7. Is operator the only affected party .................................. /~ Can permit be approved before 15-day wait ............................ ~ Does operator have a bond in force ................................... Is a conservation order needed ....................................... Is administrative approval needed .................................... 12. Is lease n~nber appropriate .......................................... ~_ 13. Does well have a unique name & n~nber ................................ 14. Is conductor string provided ......................................... X 15. Will surface casing protect all zones reasonably expected to 16. Is 17. Wil 18. Wil 19. Wi 1 serve as an underground source of drinking water .................. enough cement used to circulate on conductor & surface ............ 1 cement tie in surface & intermediate or production strings ...... 1 cement cover all known productive horizons ..................... 1 all casing give adequate safety in collapse, tension, and burst. 10-403 ............. eemeeeeeeeeeeeeeeee pment adequate ..... & BOPE attached .... Does BOPE have sufficient pressure rating -- test to ~O~ psig ..... Does choke manifold comply w/API RP-53 (May 84) ...................... Is presence of H2S gas probable ...................................... 20. Is well to be kicked off from an existing wellbore 21. Is old wellbore abandonment procedure included on 22. Is adequate wellbore separation proposed .......... 23. Is a diverter system required ..................... 24. Is drilling fluid program schematic & list of equi 25. Are necessary diagrams & descriptions of diverter 26. 27. 28. (6) Other ~/_ ru3~~] 29. '~2~ th 30. (7) Contact ~' 32. -- ~32] FOR EXPLORAT6RY & STRATIGRAPHIC WELLS: Are data presented on potential overpressure zones ................... Are seismic analysis data presented on shallow gas zones ............. If offshore loc, are survey results of seabed conditioms o~sented... Name and phone n~nber of contact to supply weekly progress data ...... 33. Additional requirements ............................................. INITIAL GEOL UNIT ON/OFF POOL CLASS STATUS AREA ~ SHORE geology' e~:Lc2i neer i ng: LAG__~' ' rev 08/18/92 jo/6.011 Additional remarks' m z Well History File APPENDIX Information of detailed nature that is not particularlY'germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file. and to simplify finding information, information, of this nature is accumulated at the end of the file under APPENDIX. No special 'effort has been made to chronologically organize this category of information. O ALASKA INC D.S. 14 - 22A~~~~ PRUDHOE BAY I MICI OFILME Run 1' 06 - December - 1992 DLL/MLL/AC/CN/GR 10602 2425 Tape Subfile 2 is type: LIS TAPE HEADER PRUDHOE BAY UNIT OPEN HOLE WIRELINE LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION(FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING REMARKS: D.S. 14 - 22A 500292074700 ARCO ALASKA INCORPORATED ATLAS WIRELINE SERVICES 17-DEC-92 RUN 1 5805.00 BRAD ESARY WESTER/RUT/ RUN2 CHEN RUN3 9 i0N 14E 2598 1586 71.00 70.00 34.00 OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 8.500 9.625 10775.0 DLL/MLL/AC/CN/GR CIRCULATION STOPPED: 14:30 05-DEC-92. LOG TIED TO CASED HOLE CN DATED 06-JUN-82. CALIPER VERIFICATIONS PERFORMED IN CASING. DRILLER'S CASING KOP = 10775' - 10835'. DID NOT ATTEMPT REPEAT BECAUSE OF STICKY HOLE CONDITIONS. CHLORIDES = 30K PPM. NOTE: CALIPER'S MAXIMUM OPENING IS 16". CN POROSITY IS CALIPER CORRECTED. CHISM FILTERING IS NOT ACTIVE. NO CASING CORRECTIONS APPLIED. $ FILE HEADER FILE NUMBER: 1 EDITED OPEN HOLE MAIN PASS Ail tool strings; hole data. DEPTH INCREMENT: FILE SUMMARY PBU TOOL CODE GR BCS 2435 DLL $ BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA depth shifted and clipped curves; 0.5000 START DEPTH STOP DEPTH 10765.0 12339.0 11900.0 12402.0 10765.0 12345.5 11900.0 12425.0 GR (MEASURED DEPTH) BASELINE DEPTH DT 10765.0 10765.0 10769.0 10797.0 10807.5 10821.5 10827.0 10869.5 10877.0 10891.5 10917.5 10938.0 10940.5 10945.5 10970.5 10991.0 11043.5 11064.5 11078.5 11085.5 11107.5 11115.5 11122.0 11134.0 11160.0 11172.5 11182.5 11266.5 11318.5 11438.0 11704.0 11731.5 11759.5 11807.5 11837.0 11863.0 11909.5 11922.0 11922.5 11923.0 11940.0 11922.5 EQUIVALENT UNSHIFTED DEPTH NPHI MLL LL3 10765.0 10765.0 10765.0 10769.0 10797.0 10807.0 10821.0 10826.5 10870.0 10877.5 10891.5 10917.5 10938.5 10941.5 10946.0 10970.5 10991.0 11043.5 11064.5 11079.0 11085.5 11107.5 11115.5 11121.5 11134.0 11159.5 11172.5 11182.5 11266.5 11318.5 11438.0 11704.0 11732.0 11759.5 11807.5 11837.0 11863.0 11923.0 11909.5 11922.5 11922.5 11940.0 all runs merged; LLD 10765.0 11923.5 11940.0 no case 12005. 12010. 12011. 12011. 12012. 12027. 12028. 12031. 12033. 12037. 12038. 12041. 12042. 12046. 12046. 12049. 12055. 12057. 12060. 12066. 12069. 12074. 12076. 12084. 12086. 12086. 12088. 12096. 12097. 12100. 12104. 12113. 12126. 12141. 12143. 12143. 12144. 12145. 12148. 12149. 12178. 12178. 12203. 12226. 12228. 12230. 12232. 12233. 12238. 12239. 12240. 12243. 12246. 12251. 12251. 12267. 12268. 12273. 12283. 12287. 12011.5 12038.0 12065.5 12076.5 12084.0 12126.5 12140.0 12143.0 12148.5 12178.5 12202.5 12228.0 12240.0 12241.0 12243.0 12267.5 12273.5 12012.0 12029.5 12037.5 12113.0 12143.0 12148.5 12178.5 12227.5 12233.0 12283.0 12005.0 12030.0 12041.5 12048.5 12084.0 12086.5 12126.5 12142.5 12178.0 12228.0 12233.0 12251.0 12267.5 12288.5 12010.0 12030.5 12041.0 12045.0 12057.5 12069.5 12075.0 12086.5 12088.0 12104.0 12143 . 0 12238.0 12246.5 12251.0 12010.5 12026.0 12030.5 12045.5 12055.0 12057.5 12060.0 12069.5 12075.0 12086.0 12088.0 12096.0 12097.5 12100.0 12104.0 12230.0 12251.5 12290.5 12291.0 12295.0 12295.5 12298.0 12304.0 12305.0 12311.0 12311.5 12315.5 12317.5 12319.0 12330.5 12331.0 12346.5 12367.0 12445.0 $ MERGED DATA SOURCE PBU TOOL CODE GR BCS 2435 DLL $ REMARKS: CN WN FN COUN STAT 12291.5 12295.0 12445.0 12310.0 12329.5 12319.0 12320.5 12290.5 12296.0 12298.5 12306.0 12312.0 12331.0 12445.0 12445.0 12445.0 12290.0 12298.5 12305.0 12316.0 12330.5 12347.0 12367.0 12445.0 RUN NO. PASS NO. MERGE TOP 1 5 10765.0 1 5 11900.0 1 5 10765.0 1 5 11900.0 MERGE BASE 12339.0 12402.0 12345.5 12425.0 FUCT & NUCT WERE SHIFTED WITH NPHI. TENS, TEND, MTEM, & CALl WERE SHIFTED WITH MLL. SP WAS SHIFTED WITH LLD. $ : ARCO ALASKA INCORPORATED : D.S. 14 - 22A : PRUDHOE BAY : NORTH SLOPE : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 13 Curves: Name Tool Code Samples Units Size Length API API API API Log Crv Crv Typ Typ Cls Mod 1 GR BCS 2 DT BCS 3 TEND BCS 4 TENS BCS 5 NPHI 2435 6 NUCT 2435 7 FUCT 2435 8 MLL DLL 9 LL3 DLL 10 LLD DLL 68 1 GAPI 68 i US/F 68 1 LB 68 1 LB 68 1 PU-S 68 1 CPS 68 1 CPS 68 1 OHMM 68 1 OHMM 68 1 OHMM 67 465 06 6 84 653 71 5 20 789 90 0 20 789 90 0 98 211 23 1 98 211 23 1 98 211 23 1 30 739 95 0 30 739 95 0 30 739 95 0 11 SP DLL 68 1 MV 4 12 CALl DLL 68 1 IN 4 13 MTEM DLL 68 1 DEGF 4 * DATA RECORD (TYPE# 0) 1014 BYTES * Total Data Records: 187 4 30 739 95 4 30 739 95 4 30 739 95 52 Tape File Start Depth = 12445.000000 Tape File End Depth = 10765.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 47055 datums Tape Subfile: 2 390 records... Minimum record length: Maximum record length: 62 bytes 1014 bytes Tape Subfile 3 is type: LIS FILE HEADER FILE NUMBER: 2 EDITED CASED HOLE MAIN PASS Depth shifted and clipped curves for open hole logs run into casing. PASS NUMBER: 5 DEPTH INCREMENT: 0.5000 FILE SUMMARY PBU TOOL CODE START DEPTH GRCH 10602.0 2435 10688.0 $ BASELINE CURVE FOR SHIFTS: GRCH CURVE SHIFT DATA (MEASURED DEPTH) BASELINE DEPTH 10413.0 10702.0 10705.5 10710.0 10718.5 10720.0 10724.0 10731.5 10737.0 10757.5 10759.5 10765.0 $ NPHI 10413.0 10701.5 10704.5 10709.0 10717.5 10719.0 10724.5 10731.5 10737.0 10757.0 10759.5 10765.0 REMARKS: CN WN FN COUN STAT STOP DEPTH 10765.0 10765.0 EQUIVALENT UNSHIFTED DEPTH FUCT, NUCT, TENS, & TEND WERE SHIFTED WITH NPHI. NO CASING CORRECTIONS APPLIED TO CN. $ : ARCO ALASKA INCORPORATED : D.S. 14 - 22A : PRUDHOE BAY : NORTH SLOPE : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 6 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod GRCH 2435 68 1 GAPI NPHI 2435 68 1 PU-S NUCT 2435 68 1 CPS FUCT 2435 68 1 CPS 4 08 501 10 0 4 98 211 23 1 4 98 211 23 1 4 98 211 23 1 5 TEND 2435' 68 1 LB 4 6 TENS 2435 68 1 LB 4 * DATA RECORD (TYPE# 0) 1014 BYTES * Total Data Records: 20 4 98 211 23 4 98 211 23 24 Tape File Start Depth = 10765.000000 Tape File End Depth = 10413.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 4936 datums Tape Subfile: 3 59 records... Minimum record length- Maximum record length' 62 bytes 1014 bytes Tape Subfile 4 is type: LIS FILE HEADER FILE NUMBER: 3 RAW OPEN HOLE MAIN PASS Curves and log header data for each run and tool string in separate files; Tool String #1 for Sadlerochit run presented first (primary depth control string used to depth shift the Sadlerochit interval) followed by files for other main pass tool strings per run. RUN NUMBER: 1 TOOL STRING NUMBER: 1 PASS NUMBER: 5 DEPTH INCREMENT: 0.2500 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 10602.0 AC 11900.0 2435 10688.0 DLL 11900.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME CIRCULATION ENDED: TIME LOGGER ON BOTTOM: TD DRILLER (FT) : TD LOGGER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT) : LOGGING SPEED (FPHR): TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE CHT TEMP GR CN PCM KNJT KNJT MIS DLL FTS FTS MIS AC KNJT KNJT CAL MLL $ STOP DEPTH 12355.0 12419.0 12362.0 12442.0 CABLEHEAD TENSION TEMPERATURE GAMMA RAY COMPENSATED NEUTRON PULSE CODE MODULATOR KNUCKLE JOINT KNUCKLE JOINT MASS ISOLATION SUB DUAL LATEROLOG FEED THROUGH SUB FEED THROUGH SUB MASS ISOLATION SUB BHC ACOUSTILOG KNUCKLE JOINT KNUCKLE JOINT i-ARM CALIPER MICRO LATEROLOG 06-DEC-92 FSYS REV. J001 VER. 1.1 1430 05-DEC-92 308 06-DEC-92 12464.0 12429.0 10602.0 12425.0 1200.0 TOOL NUMBER 3974XA 2806XA 1309XA 2435XA 3506XA 3921NA 3921NA 3967XA 1229EA/1229MA 3967XA 1609EA/1603MA 3921NA 3921NA 1233XA 1233XA BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE(IN) ' DRILLER'S CASING DEPTH (FT) : LOGGER'S CASING DEPTH (FT) : 8,500 10775.0 10765.0 BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: FLUID LOSS (C3): MAXIMUM RECORDED TEMPERATURE (DEGF): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT BOTTOM HOLE TEMPERATURE (BHT): MUD FILTRATE AT MT: MUD FILTRATE AT BHT: MUD CAKE AT MT: MUD CAKE AT BHT: KCL 9.80 63.0 9.0 5.8 201.7 0. 142 0.039 0.142 0.000 0.274 0.000 50.0 201.7 50.0 0.0 50.0 0.0 NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): THERMAL SANDSTONE 0.00 0.000 TOOL STANDOFF (IN) : 0.0 REMARKS: MAIN PASS. NOTE: NO REPEAT PASS ATTEMPTED DUE TO HOLE PROBLEMS. $ CN WN FN COUN STAT : ARCO ALASKA INCORPORATED : D.S. 14 - 22A : PRUDHOE BAY : NORTH SLOPE : ALASKA * FORMAT RECORD (TYPE~ 64) ONE DEPTH PER FRAME Tape depth ID: F 20 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 GR AC 68 1 GAPI AC AC 68 1 US/F ACQ AC 68 1 CHT AC 68 1 LB TTEN AC 68 1 LB SPD AC 68 1 F/MN CNC 2435 68 1 PU-S CN 2435 68 1 PU-L SSN 2435 68 1 CPS LSN 2435 68 1 CPS RMLL MLL 68 1 OHMM CAL MLL 68 1 IN RS DLL 68 1 OHMM RD DLL 68 1 OHMM ES DLL 68 1 MV 4 06 969 49 6 4 48 852 89 1 4 81 285 47 0 4 95 558 30 1 4 95 558 30 1 4 61 094 30 1 4 98 211 23 1 4 52 326 75 5 4 83 368 34 1 4 84 023 70 1 4 71 857 46 1 4 90 132 02 1 4 40 514 81 0 4 39 859 45 0 4 30 739 95 0 16 ED DLL ' 68 1 MV 4 17 IS DLL 68 1 A 4 18 ID DLL 68 1 A 4 19 SP DLL 68 1 MV 4 20 TEMP DLL 68 1 DEGF 4 * DATA RECORD (TYPE# 0) 1014 BYTES * Total Data Records: 678 4 30 739 95 4 30 739 95 4 30 739 95 4 23 415 80 4 84 503 82 80 Tape File Start Depth = 12445.000000 Tape File End Depth = 10413.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary- Rep Code: 68 217765 datums Tape Subfile: 4 767 records... Minimum record length' Maximum record length- 44 bytes 1014 bytes Tape Subfile 5 is type: LIS 92/12/17 01 **** REEL TRAILER **** 92/12/18 01 Tape Subfile: 5 2 records... Minimum record length: 132 bytes Maximum record length: 132 bytes End of execution: Fri 18 DEC 92 9:lla Elapsed execution time = 53.06 seconds. SYSTEM RETURN CODE = 0
