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200-022
(e,c( 31-1 -/ ( A- Pisb Regg, James B (DOA) Z.Vo©z zo From: Jones, Jeffery B (DOA) !� Sent: Thursday, April 13, 2017 6:31 AM h 57.,5(I7 To: Regg, James B (DOA) Subject: FW: DR report &.photo CPAI KRF 3H-16 Attachments: Deficiency Report 3H-16 OA handle 04-02-17.pdf; 3H-16 OA valve .pdf FYI: DR completed. Thanks, Jeff B.Jones Petroleum Inspector Alaska Oil &Gas Conservation Commission �E® it 1. 4 N. Slope Ofc: 907-659-2714 S 2-017 Mobile: 907-744-4446 CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Jeff B. Jones at 907-659-2714 or jeff.jones@alaska.gov. From: NSK Prod Engr Specialist [mailto:n1139@conocophillips.com] Sent:Sunday, April 02, 2017 3:57 PM To:Jones,Jeffery B (DOA) <jeff.jones@alaska.gov> Subject: RE: DR report&.photo CPAI KRF 3H-16 Jeff, here are the reports for the deficiency noted on 3H-16 OA valve handle Darrell Humphrey/ Matthew Raiche Production Engineering Specialist ConocoPhillips Alaska Ph:907.659.7535 I Pg:924 Mail: NSK 69 From:Jones,Jeffery B (DOA) [mailto:jeff.jones@alaska.gov] Sent:Tuesday, March 28, 2017 6:00 PM To: NSK Prod Engr Specialist<n1139@conocophiliips.com> Subject: [EXTERNAL]FW: DR report &.photo CPAI KRF 3H-16 1 • Hello Matt, Please sign & return to me. Thanks, Jeff B.Jones Petroleum Inspector Alaska Oil &Gas Conservation Commission N. Slope Ofc: 907-659-2714 Mobile: 907-744-4446 CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Jeff B. Jones at 907-659-2714 or jeffjones@alaska.gov. From:Jones,Jeffery B(DOA) Sent:Tuesday, March 28, 2017 5:51 PM To:Jones,Jeffery B (DOA) <jefflones@alaska.gov> Subject: DR report&.photos CPAI KRF 3H-16,3H-22 Matt, please sign & return. Thanks, Jeff Jones AOGCC Petroleum Inspector 907 659 2714 - Office 907 744 4446- Mobile 2 • . State of Alaska Oil and Gas Conservation Commission Deficiency Report Location: N. Slope KRF well 3H-16A- Date: 3/27/17 PTD: 2000220 Operator: CPAI Type Inspection: SVS test Operator Rep: Matt Raische Inspector: Jeff Jones Position: SVS test Supervisor Op.Phone: 907 659 7535 Correct by(date): To be determined Op.Email:NSKProdEngrSpecialist<n1139@conocophillips. Fnliow Up Req'd: .yes— x4151,1 COM I • Detailed Description of Deficiencies Date Corrected The outer annulus valve has no handle,&appears to inoperable,requiring repair. 31 .)7 Attachments: well head photo (1) ^, 41-\‘—'401-1e1Operator Rep 3rd 8-t� Signatures: � �9I�.42 AOGCC Inspector *After signing,a c y is form is a left with the operator. Follow-up instructions Return a copy of this Deficiency Report to AOGCC(Attention:Inspection Supervisor)within 7 days of receipt. Include the"Date Corrected"and attach supporting documentation for each corrective action implemented to address the deficiencies. If a follow-up inspection was performed by AOGCC,include the date and name of Inspector. Extensions for corrective actions taking longer than the"correct by"date must be requested and accompanied by justification(Attention:Inspection Supervisor).Documentation of deficiences that are outside of AOGCC regulatory jurisdiction will be forwarded to the appropriate authority for follow-up action. Revised 2/2016 A- • K4L4 j. P71 7c°° • C1)A 1j(ieti rr�C T� c(4- fur teP5p7 ��� 2 -5(Z—ii,7 o, ! : i .1. . ... t„okitl . ,,, - 't ;: it.„ ,..., ,'.' 1,. '.' . 1 '''.+:.%:...1'114.',-,''''' w a 4� , 1-1"-' ti oy , 'fi.... * aim ^ 7 7 a .f --t�al�1^ �'.o} !i 5 L J a % i' t '! '� 4:':-;..<11111f-!;- Erb + .. c«e' rv'f '''.. ',::)''''''‘.:111.11 p' C` cr 8, j6s:'' 11 °' . rte"` 9y 7r _ -., - . ',741fr7",l 'i -,....,..... - n 1 ' -. ., -:111110*.ALfale:/1 .,, . : h . ill. x + 1F . .. cr, r40, ,y � e fir d ; x t- a,"t fc,pn -40,,,,, � kfN -',,-I 0� _, r- ,--'� s EEt] k 4, . . ., . ,,...„„, . _ 1 L 1t 1 2.00-o 22. WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. June 15, 2015 Attn.: Makana Bender 333 West 7th Avenue, Suite 100 4 L C E I' E D DATA LOGGED Anchorage, Alaska 99501 .iK BENDER JUN 18 21.1. ADO C RE: Multi Finger Caliper(MFC): 3H-16A Run Date: 5/31/2015 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Fanny Sari, Halliburton Wireline &Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 FRS_ANC@halliburton.com 3H-16A Digital Data(LAS), Digital Log file, Casing Inspection Report, 3D Viewer 1 CD Rom 50-103-20096-01 SCANNED ) �� PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline &Perforating Attn: Fanny Sari 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-275-2605 Fax: 907-273-3535 FRS_ANC@halliburton.com Date: Signed ✓av V��N'�'"t -- .-, ~ Image I .-oject Well History File Cover Page XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. c2o 0 - Q -2 ~ 'Well History File Identifier DAlE'#DIf Isl Ji=- x 30 = / J.() + ~."c¡:¡- = TOTAL PAGES /39' DATES J.16if I'" VV¡p I Production Scanning Stage 1 PAGE COUNT FROM SCANNED FILE: IS q // PAGE COUNT MATCHES NUMBER IN SCANNING PREPARATION: dYES - .i:JY l~ DATE: 1/t'/0+ /5/ Stage 2 IF NO IN STAGE 1, PAGE(S) DISCREPANCIES w::~ FOUND: - YES Organizing (dolle) 0 Two-Sided ""1111111'" II III RESCAN DIG~LDATA 7 Color items: q ~ Diskettes, No. J 0 Other, NofType 0 Grayscale items: 0 Poor Quality Originals: 0 Other: NOTES: BY: BEVERLY ROBIN VINCENT SHERY@INDY Project Proofing BY: BEVERLY ROBIN VINCENT SHERYt@'NDY Scanning Preparation BY: BEVERLY ROBIN VINCENT SHERY~A3WINDY BY: BY: (SCANNING IS COMPLETE AT THIS POINT UNLESS SPECIAL ATTENTION IS REQUIRED ON AN INDIVIDUAL PAGE BASIS DUE TO QUALITY. GRAYSCALE OR COLOR IMAGES) ReScanned (imi/e/dual p,lgry !t.!wcial ,1t!úl,tionj !'c,)i ning wmplntod) ¿scan Needed '" 11111111" 111111 OVERSIZED (Scannable) 0 Maps: Other items scannable by large scanner 0 OVERSIZED (Non-Scannable) 0 Logs of various kinds 0 Other o",5þs!ð1f loJ vwP 1111111111111111111 V11f _NO _NO DATE: /51 1111111111111111'" "'"11111111111111 General Notes or Comments about this file: RESCANNEDBr: BEVERLY ROBIN VINCENT SHERYL MARIA W~9'(_~d"9A-'fE~'-'. ,. '/5/ Quality Checked (done) 1111111111111111111 SCANNED JUL 1 6 2004 12/10/02Rev3NOTScanned.wpd • Page 1 of 1 Regg, James B (DOA) ~ 2.FL~- oZ.z- From: NSK Problem Well Supv [n1617@conocophillips.com] n ~ ~~ ~ L~ j ~ Sent: Saturday, April 17, 2010 5:25 AM ` j ~~ 1 To: Maunder, Thomas E (DOA); Regg, James B (DOA); Schwartz, Guy L (DOA) Cc: NSK Problem Well Supv Subject: 3H-16A (PTD 200-022) Report of failed TIFL Attachments: 3H-16A schematic.pdf Tom, Guy, Jim Kuparuk gas lifted producer 3H-16A (PTD 200-022) failed a diagnostic TIFL on 04/14/10. The TIO prior to the test was 300/1050/750. A leaking GLV is suspected. Slickline will trou eshoo a leak and repair if possible. Attached is a schematic and a 90 day TIO plot. Please let me know if you have any questions. Brent Rogers/Martin Walters Problem Wells Supervisor ConocoPhillips Alaska, Inc. Desk Phone (907) 659-7224 Pager (907) 659-7000 pgr. 909 %' ti ~ ... 4/19/2010 KRU 3H-16A PTD 200-022 4/ 17/2010 Tin Prescnres Plnt TRN_pNNL TRt~PNNL,I N I T ANNULUS PRESSURE TRE NDS SnQ. sc r,,~r~ z~IAr~~ WLKRU 3H-16 3000. 3000 - _ . - _ _ - __ _ -- Z00. ~ 9000. 3ilJD- 2700 I ;~'rl, 3000 2400 ~ ~ ~ . 2100 1800 Ic't,~r , ~;' ~ I ~ 1500 - _ _~ -- "~ ~ __`- i _. i 1200 ,r 1 ~1~ _.. 900 ~ - ', ~ ' 0. s< I i ~ ' ~ I 0 600 ' ~;~ ( ~ 0, 300 / 0 -------------------------------------------------- --------------------------------------- -------------- ------------------------~ D' PLOT START TIME MINOR TIME PT-OT D[IRATION PLAT END TIME 17-JAN-10 05:17 MAJOR TIME WEEK +02160: QOOD aR5 1T=APR-SO 05e17 Plcx rlHt 17-A PR-10 05:12:51 ~;~ TAG H~HE DESCRIPTION •~ tt ~Ir ,~1TF.!"ST WL3H-16-CHOKE FLOW TUBING CHOKE ?-~-`~~'% ~` SCRATCH 5 FLOW TUBING PRESSURE ??????? ~ SCRATCH_5 FLOW TUBING TEMP ??????? ~ AI-P3H50D2-16 GL CASING PRESSURE ??????? ?????a? ??????? SCRATCH_5 INNER ANNIIL[JS E'RF.S '~-A^ ?'?7777? SCRATCH_5 OUTER ANNULUS PRES ~%,4 ??????? ~~~~~ DRILLSITE WELL PREY WELL 3 tl 16 NEXT WELL rr^~''~ 'I"~°~`~~: OPERATOR ~ OPERATOR VERIFIED ~ ,~YSTEM A[ITO ENTRY BOTH • ~~ J . ~ KUP ~ ~ ~ 3H-16A ~ COt"tOCOP~'ii~~l~35 ~ , Well Attributes ' _ ___ _ _ Max Angle & MD TD ~ t " ~ ~ Wellbore AP{IUWI Field Name Well Status In~l(I 1D (ttKB) Act Btm (ttKB) - " ' `d' J 501032009601 KUPARU K RIVER UNIT PRODUCING 94.73 10,448.03 10,972.0 Comment H2S (ppm) Date Anno tation End Date KB-Card (ft) Rig Reloase Dab SSSV: NIPPLE 480 3/1Y2008 LastWO: 2/10/2008 42.01 3/23/1988 weu coos -3n-l nA en lreoos 7:28.1-nM Sc eTat'~c-Aauai Ann~t:ir;,,, Depth (RKB) End Date Annotation Last Mod By End Date Last ~ , ~, iLM 9 ,301.0 4/19/2009 Rev Reason: SURF CSG set depth Imosbor __ 6/11/2009 Casing atn~s_ _ _ _ _ - - HANGER 27 ~ --'-_-' Caain Desert 9 ption String 0... String ID ... Top (RKB) Se[ Depth (f... Set Depth (TVD) ... String WL.. Slring .- String Top Thrd , - --- CONDUCTOR 16 15.062 42.0 121.0 121.0 62.58 H-40 WELD Casing Descriptlon String 0... String ID ... Top (RKB) Set Depth (t... Set Depth (ND) ... String Wt... String... String Top Thrd SURFACE 9 5/8 8.765 33.0 3,943.0 2,870.0 36.00 J-55 i ~ Casing Description String 0... String ID ... lop (RKB) Set Depth (f... Sat Depth (ND) ... String Wt... String ... String Top Thrd I ) ' PRODUCTION 7 6.151 33.0 8,991.0 5,731.6 26.00 J-55 BTCM • ', ~ Casing DeacripRon String 0... String ID ... Top (ttKB) Set Depth (f... Sat Depth (ND) ... String Wt... String ... String Top Thrd - ~~-' WINDOW 7 6.151 8,991.0 8,992.0 5,733.3 ' - ~ Casing Description String 0... String ID ... Top (ttKB) Set Depth (L.. Set Depth (ND) ... String Wt... String ... String Top Thrd conloucroR. ~ LINER 3.5" 31/2 2.992 8,R355 9,698.0 5.973.1 9.30 L-80 SLHT a2az1 s ----- Liner Details --- -'--- ~----~- NIPPLE, 476 ,P~",,, Top Depth ~ ---- -~~ - (ND) Top Incl Top (RKB) (RKB) (°) It em Description Comment ID (ir ' 8,835.5 5,642.1 54.83 P ACKER ZXP HR PACKER -THIS IS ISOLATED BY THE SEAL ASSEMBLY 4.4( Gns uFT. 3.165 _ :_• i -, _~ STABBED INTO IT l 8,853.6 5,652.6 54.84 N IPPLE 'RS' NIPPLE w/XO 4.2: suRFACE, 1 8,856.3 5,654.1 54.84 H ANGER BAKE 5x7 FLEX-LOCK HYDRAULIC LINER HANGER 4.4~ 33-3.9a3 J 8,866.3 5,659.9 54.84 S BE BAKER 80-40 SBE 4.0( ' ~ 8,885.5 5,670.9 54.85 X 05.5x3.5 2.9~ GAS LIFT, s 5ae _ ,~" ~ Casing Das crlpdon String 0.. . String ID ... Top (RKB Sat Depth (f... Set Depth (ND) ... String Wt... String ... String Top Thrd , ~ ,~~ LINER 2 7/8" 23/8 1.995 9,553'1 10,943.0 5,965.9 4.43 L-80 STL Tubing Strin s _ ~ Tubing Description St ing 0... Str ng ID ._ 5et Depth (f.. Set D pth AND) .. String Wt... St - g ... Top (RKB Siring Top Thrd TUBING 3 V2 2.992 26.7 8 824 0 5 f 35.5 9.30 L 80 8rd EUE GAS LIFT, zozs `~ - Com Ietion Details --- -- - ' " ToP Depth _ -__._ _.____ '-'} (ND) Top Incl Top (RKB) (RKB) (°) It em Description Comment ID (h ' 26.7 26.7 0.05 H ANGER 7"x3.5" Tubing Hanger w/3.62' pup 3.0: GASeI~ ~. ~ ~ 476.3 476.3 7.14 N IPPLE 2.875"'DS Nipple Camco 2.81 I 8 727.3 5,579.9 54.86 S EAL ASSY PBR 80/40 Seal Assembly w/2' spaced off 2.9E , 8,742.6 5,588.8 54.87 P ACKER Baker3l/2"x7"FHLPacker 3.0( - 8,785.3 5,613.3 54.93 N IPPLE 2.812" Camco'DS' Nipple w/ RHC-M Plug wNCR-Lock 2.8' GAS LIFT, e.641 .- ~ J ~' ~ 8,817.7 5,631.9 54.83 O VERSHOT 3.5" Po-Boy OS w 3 5/8" ID (Length 12.68', Swallow) 3.6i ~ Tubing Description String 0.. . String ID ... 8 epth It... Set Depth (rvD) ... string Wt... String ... Top (RKB) Sat String Top Thrd ~ TUBING-Original 3 1/2 2.992 ,854,7 5,653.2 9.30 L-80 8.806.8 EUE8RD _ I Completion Details SEAL ASSY, I ~p lio flR 8,727 (ND) Top Incl PACKER, 8,743 To (RKB (RKB) (°) I lem Description Commenl ID (II (- -~ 8,844.2 5,647.2 54.84 N IPPLE HES'X' NIPPLE 2.8' ~; 8,851.5 5,651.3 54.84 L OCATOR BAKER LOCATOR 3.0( NIPPLE. 8,765 !_~ 8,852.7 5,652.0 54.84 S EAL ASSY BAKER SEAL ASSEMBLY w/NO GO TUBING TAIL 3.01 ~ Perforations & Slots _.~ __ 1 ° __ _ ____ ~ _ .__ _ Shot _ OVERSHOT, ~ ~ ~ - Top (ND) Btm (ND) Dens 8,818 - ~ Top (RKB) Btm (RKB) (RKB) IRKS) Zone Date (sh... Type Com ment NIPPLE, 8,844 1 LG(:ATOR, - -~ 8,851 1 SEAL ASSY, _(_ 8,853 3 APERF, 9,327-9,337 f~ ( i l r LINER 3 5", 8.8368.698 SLOTS, 9,611-10,909 1 r i, LINER 27/8", 9,553.10,943 TD (3H-i6A), 10,972 9,327 9,337 5,914.9 5,919.0 C-4, 3H-16 5/6/2009 6.0 APERF 2" PowerJETomega HSD, 60degPh 9,611 10,909 5,967.3 5,965.0 Miluveach, 4/19/2002 4.0 SLOTS 2.375" Perforated liner (4 ea 3H-16A 0.375" holes/fot) Mandrel Details __ _ _ __ Top Depth Top Port (ND) InclT OD TIII Valve Latch Size TRO Run Rfn Tnn rRKRI (RKB) (°) I Make Metlel (ini I Serv Type Type (in) (pal) RUn Date COm... 5, ~ Conoc P ' ' o hillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 August 11, 2009 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7~' Avenue, Suite 100 Anchorage, AK 99501 ,,.~ _~ . .'~4~~ttv~s,,,.a.,u '^~ . ~. Jj+.~.J Dear Mr. Maunder: ~ ~pp-- b ~~ ~~ ~ ~~ Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRLn. Each of these wells was found to have a void in the conductor. These voids were filled with cement if needed and corrosion inhibitor, engineered to prevent water from entering the annular space. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treatrnents took place and meets the requirements of form 10-404, Report of Sundry Operations. The cement was pumped July 30~' 2009 and the corrosion inhibitor/sealant was pumped August 8~', 9~' and 10~' 2009. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please call Perry Klein or MJ Loveland at 907-659-7043, if you have any questions. Sincerely, v~~~y ( MJ Lov land ConocoPhillips Well Integrity Projects Supervisor ~ ~ ConocoPhillips Alaska Inc. Surtace Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) Kuparuk Field Date 08/11/09 ~~ ~~ ~~ e ~., ~_~ Well Name API # PTD # Initial top of cement Vol. of cement um ed Final top of cement Cement top off date Corrosion inhibitor Corrosion inhibitorJ sealant date bbls al 3G-12 50103201310000 1900730 24' 4.00 20" 7/30/2009 4.25 8/10/2009 3G-13 50103201370000 1901160 17" n/a 17" n/a 2.97 8/10/2009 3G-15 50103201390000 1901210 18" n/a 18" n/a 2.97 8/10/2009 3G-23 50103201440000 1901320 17" n/a 17" n/a 1.27 8/10/2009 3H-02 50103200830000 1871070 21" n/a 21" n/a 3.82 8/8/2009 3H-06 50103200780000 1870780 8'5" 2.00 18" 7/30/2009 5.52 8!8/2009 3H-07 50103200790000 1870790 17" n/a 17" n/a 2.97 8/8/2009 3H-09 50103200860000 1871120 17" n/a 17" n/a 5.52 8/8/2009 3H-10B 50103200870200 2031600 16" n/a 16" n/a 2.55 8/8/2009 3H-12 50103200880000 1871290 2'7" n/a 2'7" n/a 8.92 8/9/2009 3H-15 50103200820000 1871030 19" n/a 19" . n/a 3.4 8/9/2009 3H-16A 50103200960100 2000220 15' 2.75 17" 7l30/2009 1.7 8/9/2009 3H-18 50103200950000 1880090 SF n/a 17" n/a 5.52 8/9/2009 3H-20 50103200930000 1871340 16' 3.75 16" 7/30/2009 2.25 8/9/2009 3H-22 50103200970000 1880110 27'6" 4.25 21" 7/30/2009 8,5 8/9/2009 3H-25 50103202030000 1990400 30" n/a 30" n/a 7.65 8/9/2009 3H-26 50103202080000 1940290 SF n/a 9" n/a 2.12 8/9/2009 3H-28A 50103202360100 1960370 SF n/a 18" n/a 5,1 8/9/2009 3H-32 50103203220000 2000010 90" n/a 10" Ma 1.27 8/9/2009 3K-102 50029233786000 2071650 n/a n/a 5" n/a 1.27 8!8/2009 3Q-01 50029222200000 1911250 15'7" 2.00 17" 7/30/2009 4.25 8/8/2009 3Q-02 50029216880000 1870040 41' 4.75 21" 7/30/2009 5.52 8/8/2009 3Q-04 50029222190000 1911240 4'10" 1.50 16" 7/30/2009 4.25 8/8/2009 3Q-07 50029216820000 1861940 6" n/a 6" n/a 1.7 8/9/2009 3Q-12 50029216770000 1861890 7" n/a 7" n/a 2.97 8/8/2009 3Q-13 50029216640000 1861760 44'6" 5.00 21" 7/30/2009 8.92 8/8/2009 3Q-15 50029216660000 1861780 49'5" 4.50 20" 7/30/2009 9.35 8/8/2009 3Q-16 50029216670000 1861790 46' 5.25 30" 7/30/2009 8,5 8/8/2009 • STATE OF ALASKA • ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: AbandOn ^ Repair Well ^ Plug Perforations ~ Stimulate ^ Other ^ Alter Casing ^ Pull Tubing ^ Pertorate New Pool ~ Waiver ^ Time Extension ^ Change Approved Program ^ Operat. Shutdown^ Perforate Q• Re-enter Suspended Well ^ 2. Operator Name: 4. Well Class Before Work: 5. Permit to Drill Number: ConoCOPhllllps AIBSka, InC. Development ^~ ' Exploratory ^ 200-022 /• 3. Address: Stratigraphic ^ Service ^ 6. API Number: P. O. Box 100360, Anchora e, Alaska 99510 50-103-20096-01 • 7. KB Elevation (ft): 9. Well Name and Number: RKB 69' ' 3H-16A . 8. Property Designation: 10. Field/Pool(s): ADL 025532 . Kuparuk River Field / Kuparuk River Oil Pool 11. Present Well Condition Summary: Total Depth measured 10943' • feet true vertical 5959' • feet Plugs (measured) Effective Depth measured 9447' feet Junk (measured) true vertical 5947' feet Casing Length Size MD ND Burst Collapse Stractural CONDUCTOR 121' 16" 121' 121' ~;~~~ ~ ` J~,jL ~~ ~ 2~~~ SURFACE 3874' 9-5/8" 3943' 2863' PRODUCTION 8922' 7" 8991' . 5724' LINER 861' 3.5" 9696' S966' LINER ~5~~~ 1365' 2.375" 10943' 5959' ~~ ~ F~ECEIV~D Perforation depth: Measured depth: 9327'-9337', 9611'-10909' (slotted liner) ~"~~"~N ~~~Q~~ true vertical depth: 5915'-5919', 5967'-5965' d~lask~ Oit 8~ Ca~ Cvns. C~mrt~is~ior~ Tubing (size, grade, and measured depth3 3.5", L-80, 8855~ nno. Anchorags Packers & SSSV (type & measured depth) Baker FHL pkr, ZXP HR pkr @ 8743', 8836~ Camco'DS' nipple @ 476' 12. Stimulation or cement squeeze summary: Intervals treated (measured) not applicab/e Treatment descriptions including volumes used and final pressure : 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casin Pressure Tubin Pressure Prior to well operation 68 ' 402 1033 -- 160 Subsequent to operation 84 - 261 712 - 150 14. Attachments 15. Well Class after work: Copies of Logs and Surveys run _ Exploratory ^ Development ~~ Service ^ Daily Report of Well Operations _X 16. Well Status after work: Oil~ ` Gas^ WAG~ GINJ^ WINJ ^ WDSPL^ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: none contact ,lohn Peirce @ 26 5-6471 Printed Name John Peirce Title Wells Engineer Signature ~f / ~ Phone: 265-6471 /~ Date cp "' ~~"~ ~ '~J Pre ar h r n Allsu -Drak 263-4612 ~ Form 10-404 Revised 04/2006 ~ ` . : I~~. :3i~i, ~~ 2 ?o~~ ~~ c~~~~~ Submit Original Only > ~.~6~~~ 3H-16A Well Work Summary DATE SUMMARY 5/6/09 PERFORATE WITH 2" POWE OMEGA HSD LOADED 6 SPF/60 DEG~ASING FROM 9327'-9337'. ' KUP ~,, ~O~'jd[Q~~~~Ip$ ~ 5 Well Attributes _. _. ~ : ~~~K~} ~+~. ~ WellOOreAPVUWI FieldName ~ ~ I ~ ~~Well ~ 501032009601 . ... iKUPARUKRNERUNIT ~PRC B Date H25lFVm) Annolatio~ ic env2 .....~SSSV NIPPLE ao~ Y?; -~~ ~ - I I 480 3/1l2008 I Last W0~ _.._WGi, o^ g y_},sq __ _ Sdiern:yc AcW ~ Annotation I~Depth(%KB) IEnd~a~e IMnotation ~ Last 7ag~ SLM '~, 9.301 0 ~ 4I79/2009 ~Rev Reason~ SURF CSG Casing Strings MANGER,27-~ ~ ~ ~CasingDescription ~~StringO... ~StringlD... Top((iK8) SatDapth((. ~CONDUCIOR I 16 15062 420 121.0 Casing Description String 0... Sbing ID ... Top (ftK8) Sat Depth (i. ~~ SURFACE 9 S/8 8J65 ~ 33.0 3,943.0 _ _ _ _ _ _ . - ~', Casing Description String 0... String ID... Top (ftKB) Sat Dapth (i. .. ~~~~~~:.y:;'~~~. ~ ' ~; PRODUCIION 6.751 7 -~ 33.0 8,991.0 ~~ .9.-~ I g ption Casin Dasc ri 9 Strin 0... IStringlD... Top(ftK6) SetDepth(f. , WINDOW 7 ', 6.151 8.991.0 8,992.0 -~ 'iCasing Description t5tring 0... ~~String ID... Top (ftKB) Sat Depth (i. CoNOUCioa, - LWER35' 1 31/2 ~ 2.992 8,835.5 9,698.0 a2-12t D il Li t _ -~- ~ NIPPLE,d76 ~ - - ner e a s ~TOp Depih I ~ (ND) Top Incl Top (flK8) (nKg~ (°) Hem Description 8,835-5 5,642.1 ~ 54.g3 PACKER ZXP HR PACKER - TH ~~~~FT, . I STABBED WTOIT GAS LIFT, 5,589 GAS LIFT, _ ]p25 GAS LIFT, 8,053 SEALASSY, e.]2] PACKER, 8 ]13 - --- NIPPLE, 8.785 ------ OVERSHOT,_ 8.818 NIPPLE, 8,8M -- LOCATOR, . _ B,851 SEALASSV APERF. 9.327~9.337 LMER3.5', 8,836-9.fi98 SLOTS, 9.fi11-10.909 Inc Destription 8.852. 3H-16A 8MD ~TD KB) ~Ad Btrn (ftK8) 1.448 03 10.972.0 rtl (ft) Rig Ralease Dat 42.07 323/1988 Aod By ,IEnd Data nosbor 6/17/2009 SLHT KB) Sat Depth (t... Sat Depth (ND) ... String Wt._ String . _ String Top Thi i3.1 70,943A 5 965.9 4 43 L-80 STL _ . . .. . . .. .. . . ..._ ..... .. _ p ( I ( ~...''. 9 String ... IString Top Thi Set o rv0 5tri i... ... ~~~ K 1 ~ .~ l 8,824.O 5 835 9 30 .~ L-80 7 _ l I 8rd EUE . Commerrt ID .5" Tubing Hangerw/3.62' pup 3 S"'OS Nipple Camco 2 ~. 80/40 Seal Assembly w/2' spaced off ~ 2 tr 3 1/2" z 7" FHL Packer 3 2" Camco'DS' Nipple wl RHC-M Plug w/"CR- Lock ~~ ~ 2 Po-Boy OS w 3 5/8" ID (Length 12.68', Swallow) , 3 1... Set D ND) ... Stri . ... 5 Lo Sa . Strin 7hi 80 )6 S 8,854 7 S 65 9 30 I I I I EUES I RD . . _ _....__. _ . . . ..___ Comme~rt ' ID 'X' NIPPLE 2 ERLOCATOR I3 ER SEAL ASSEMBLY wlNO GO TUBING TAIL I 3 . ___.. ._.__- _. . -~ I y.tilll lU.'3U`JI S,`36/.SI S.'1(iS.UIMHI16ACh. I911'J/LUUL I 4.UISLUIS I0.375'h01CS/fOt~llfle~(4ea(~ I 1 TIC w/Alaska I , lake Modal ( MCO MMG 1 MCO MMG 1 MCO MMG 1 MCO MMG 1 MCOIMMG 1 Porl Value Latch 5¢e TRO Run ~ Type I. Type ~(~~I ~i (PS~) Run Data I Com... LINER 27/8'. 9.553-10.9C3 ~ TD (3H-t8A), 10.9]P • ~ STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION F~~C~~ ~~' y~.: MAR 2 ~ ciJ~u REPORT OF SUNDRY WELL OPERATIO~~,,•,i, ~ ~~ ~,,~,,.~, ~-•,z,.y,,,.....~;~.~ 1. Operations Performed: Abandon ^ Repair Well ^ Plug Perforations ^ Stimulate ^ Other a . ~ n~ wrvr ' r v Alter Casing ^ Pull Tubing Q Perforate New Pool ^ ^ Waiver ^ Time Exten i on s Change Approved Program ^ Operat. Shutdown^ Perforate ^ Re-enter Suspended Well ^ 2. Operator Name: 4. Well Class Before Work: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development ~ Exploratory ^ 200-022 / • 3. Address: Stratigraphic ^ Service ^ 6. API Number: P. O. Box 100360, Anchora e, Alaska 99510 50-103-20096-01 7. KB Elevation (ft): 9. Well Name and Number: RKB 69' ~ 3H-16A 8. Property Designation: 10. FieldlPool(s): ADL 025532 • ~Kuparuk River Field / Kuparuk Oil Pool • 11. Present Well Condition Summary: Total Depth measured 10943' feet true vertical 5959' feet Plugs (measured) 8969' Effective Depth measured 9447' feet Junk (measured) true vertical 5947' feet Casing Length Size MD TVD Burst Collapse Structural CONDUCTOR 121' 16" 121' 121' SURFACE 3874' 9-5/8" 3943' 2863' PRODUCTION 8922' 7" 8991' 5724' LINER 861' 3.5" 9696' 5966' LINER 1365' 2.375" 10943' 5959' Pertoration depth: Measured depth: 9696'-10909' true vertical depth: 5966'-5958' ~ APR ~. 2Qp$ Tubing (size, grade, and measured depth) 3-1/2" , L-80, 8855' MD. Packers & SSSV (type & measured depth) Baker FHL pkr, ZXP HR pkr @ 8743', 8836' Camco DS landing nipple ~ 476' 12. Stimulation or cement squeeze summary: Intervals treated (measured) not applicable Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casin Pressure Tubin Pressure Prior to well operation SI Subsequent to operation 67 532 1573 -- 150 14. Attachments 15. Well Class after work: Copies of Logs and Surveys run _ Exploratory ^ Development ^~ Service ^ Daily Report of Well Operations _X 16. Well Status after work: Oil^~ ~ Gas^ WAG^ GINJ^ WINJ ^ WDSPL^ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: none Contact Brett Packer Printed Name Brett Packer ~,~ ° Title Wells Group Engineer 7`Z ~( d~ Signature ~~ ~.~li*~ Phone: 265-6845 Date Pre red b haron Allsu Drake 263-4612 Ir'~Y/ r--~'' ~ ~ ` `~ ~<'C?yy-'"~--- }~„~„ '7 i'S~'g 4~ 1, ~ Form 10-404 Revised 04/2006 Ka "` (` Submit Ori final Onl • 3H-16A Pre and Post Rig Summary • DATE Summary 12/31/07 PULLED GLV'S @ 3492', 5577', 7005', 8027', AND 8798' RKB. SET DGLV @ 3492' RKB. PULLED 3 1/2 XX PLUG @ 8844' RKB. (( IN PROGRESS )). 1/1/08 DRIFT TBG. AND SET 3 1/2 WRP PLUG @ 8969' RKB. 1/2/08 SET 3 1/2 CATCHER SUB (63" OAL) ONTOP OF WRP @ 8969' RKB. SET DGLV'S @ 5577', 7005', AND 8021' RKB. (( WELL STILL NEEDS TO HAVE CMIT Tx IA AND BE CIRCULATED W/ BRINE )). 1/6/08 T & IC POT/PPPOT -PASSED, FUNCTION TEST LDS, (PRE-RWO) T FL @ SF, IA FL @ SF, CMIT T X IA -PASSED 1/21/08 TUBING PUNCH /STRING SHOT /CHEMICAL CUT: TUBING PUNCH INTERVAL 8785.3'-8787.3', 3' ABOVE COLLAR /STRING SHOT: SINGLE STRAND INTERVAL 8815'-8827' / 2-5/8" CHEMICAL CUT AT 8826', 12' BELOW TOP COLLAR OF FIRST FULL JOINTABOVE'ZXP' PACKER. 1/22/08 CIRCULATE 460 BBLS 9.6 BRINE DOWN IA RETURNS UP TUBING TO ~ `~ NEIGHBORING FLOWLINE. FOLLOW W/ 90 BBLS DIESEL DOWN IA, U-TUBE WITH TUBING FOR FP. **VALVE CREW TO SET BPV"" 2/20/08 PULLED BALL & ROD @ 8785' RKB. PULLED 1.5" RKSOV IN STA #5 @ 8642' RKB. PULLED 1.5" RKDV FROM STA #3 @ 7025' RKB AND STA #1 @ 3465' RKB. SET 1.5" RKLGV (3/16" PORT, 1260# TRO) IN STA #1. JOB IN PROGRESS. LDFN. " " ' " ~~ 2/21/08 SET 1.5 RKLGV (3/16 RKDV PORT, 1260# TRO) IN STA #3 @ 7025 RKB. SET 1.5 (1/4" PORT) IN STA #5 @ 8642' RKB. TESTED TBG TO 2500 PSI, GOOD. PULLED RHC PLUG BODY @ 8785' RKB. TAGGED FILL @ 8825' SLM. JOB SUSPENDED. 2/25/08 REMOVE SCALE/DEBRIS FROM 8825' SLM DOWN TOP OF WRP @ 8975' CTMD.LEFT WELL SHUT IN AND LOADED WITH SLICK-DIESEL FOR SLICKLINE TO PULL PLUG.JOB COMPLETE '~l • ~onQ~c~l~~t~N~~p~ AI~~lca~, r~~. • KRU 3H-16A --- ---- --- --- - - APL i 501(Yi'lfID9RD'I i Well Tvne• i PROD ~ Anale t5) TSB i dea ray I r1 ConocoPhillips Time Log Summary Wellvlew Web ReporYing __ . - _._ . Well Name: 3H-16 Job Type: RECOMPLETION - - --- - Time Lo_c„~s__^_ Date From To Dur S. De th E De th Phase Code 5u code T COM _ 02/06/2008 16:00 00:00 8.00 MIRU MOVE MOB P Moving rig from 1J pad to 3H-16. Mob started 1600 hrs. 02/07/2008 00:00 06:00 6.00 MIRU MOVE MOB P Moving rig, stop at KCS "Y" for traffic. 06:00 07:00 1.00 MIRU MOVE MOB P Stop at "Y"and wait foram field crew C/O and traffic. 07:00 12:00 5.00 MIRU MOVE MOB P Cont move rig f/ KCS "Y" to 3B access Rd. 12:00 16:00 4.00 MIRU MOVE MOB P C/O crew, PJSM, move rig f/ 36 access rd to 3H ad. 16:00 17:30 1.50 MIRU MOVE RURD P Load 11" 5M BOP in cellar and stand back. 17:30 18:30 1.00 MIRU MOVE PSIT P Move rig over well, align, spot and level ri . 18:30 19:00 0.50 MIRU MOVE RURD P Berm up cellar area. Rig accepted at 1900 hrs. 19:00 20:00 1.00 COMPZ RPCO NUND P Spot rock washer, PU Lubricator, re are to ull BPV. 20:00 21:30 1.50 COMPZ RPCOti NUND P Pull BPV w/ lubricator, well dead. 21:30 23:30 2.00 COMPZ RPCOh NUND P Set BPV, ND tree. 23:30 00:00 0.50 COMPZ RPCOti NUND P NU BOP. 02/08/2008 00:00 08:00 8.00 COMPZ RPCOh NUND P Nipple up BOP's. 08:00 14:30 6.50 COMPZ WELCT BOPE P Test BOPE 250/3500 psi 14:30 17:00 2.50 COMPZ WELCT BOPE P Pull HP BPV and test dart. Trouble latching onto dart, trash on top of test dart. 17:00 18:00 1.00 COMPZ WELCT OTHR P RU to pressure test hard line. Line frozen, thawed out and tested to 2500 si. 18:00 20:00 2.00 COMPZ WELCT CIRC P PU & MU landing jt. BOLDS, Unseat hanger w/ 105k1bs, PU. PU 4', circ around 9.5+ ppg brine, circulate out , diesel freeze rotect into kill tan . 20:00 00:00 4.00 COMPZ RPCOti PULD P PJSM, POOH w/ 3 1/2" Tbg f/ 8826' - 6594'. Spool and remove SSV control line. 02/09/2008 00:00 08:00 8.00 COMPZ RPCO PULD P POOH w! laying & strapping 3 1/2" completion string. LD 14' stub, chem cut looks ood, smooth ed es. f~~e 1 s~f 3 r~ Time Logs Date _ From___ To Dur S. De th E_ Dg~th_ Phase Code Subcode T COM 02/09/2008 08:00 12:00 4.00 COMPZ RPCOti PULD P Remove all tubing etc from pipe shed. Load pipe shed with new 3.5' 9.3# L-80 8rd EUE tubing, strap and drift. Load new tbg head & adapter flange in cellar. 12:00 18:30 6.50 COMPZ RPCOh PULD P PJSM, R&T 285 jts new 3 1/2" 9.3# 8rd EUEMod L-80 tb & 'ewel 18:30 00:00 5.50 COMPZ RPCOh RCST P PJSM, RIH w/ new 3 1/2" cmplt string w! picking up singles and jewelry from i e shed. 02/10/2008 00:00 05:00 5.00 COMPZ RPCO RCST P Continue RIH w/pick up new 3 1/2" 9.3# 8rd EUEMod L-80 to 8400'. 05:00 06:00 1.00 COMPZ RPCOb PACK P PU /install Baker storm acker, RIH 100ft w/ cm Itn strin and han off. 06:00 08:30 2.50 COMPZ RPCOh PACK P Set storm packer, attempt to press test to 2500 psi and would not hold. Released and ran down 31' and set again but would not hold press. II storm acker and wait for re lacement acker. 08:30 10:30 2.00 COMPZ WELCT OTHR T RIH with replacement storm packer to 100ft and set. Press test to 2500 psi, held for 5 min. 10:30 17:30 7.00 COMPZ WELC EQRP P Bleed 250 si off OA. ND BOP.Replace tubing head and tC packoffs. Energize packoffs and PT void to 3000 si. 17:30 21:30 4.00 COMPZ WELC NUND P NU BOP. 21:30 22:30 1.00 COMPZ WELCT BOPE P Set test plug, cavity test bop at break fo 250 10 / 3500 si hi h. 22:30 00:00 1.50 COMPZ RPCOti RCST P PJSM, RIH and latch onto RTTS. 02/11/2008 00:00 02:00 2.00 COMPZ RPCO PULD P Remove storm packer from string and la out. 02:00 03:30 1.50 COMPZ RPCO RCST P PU 2 jts, install flow nipple, RIH w/ picking up remaining tubing. TIH t/ 8786, stack out on fill. 03:30 07:00 3.50 COMPZ RPCO CIRC P RU and reverse circulate from 8786 t/ 8826, tag top of stump. Noted positive .shear action w/ Poor Bo oversh t. Returns loaded w/ scale. @ TD, PU 1 ft and continue reverse w/ vis pill to clean out remaining scale debris. Mix inhibited brine pill for spotting prior to set acker. 07:00 07:30 0.50 COMPZ RPCOb CIRC P Mix and pump 20 bbls of corrosion inhibited 9.6 ppg brine in the IA from the bottom of the po0boy overshot to above the SOV in he GLM #5. 07:30 08:00 0.50 COMPZ RPCO PACK P Engage tubing stub again leaving overshot 1 foot above fully located. Dro ed ball & rod and set acker w/2500 si. Held for 5 min. Bleed ress down to 1500 psi Sheared out of PBR, U wt 90K Dwn wt 70 si. ~~sJe 2 cif 3 Time Logs _ _ _ Date_ From To D_ur S De th E. De th Phase Code Subcode T COM _ 02/11/2008 08:00 ___ 09:30 1.50 COMPZ RPCO HOSO P Marked pipe and pull seals out of PBR. Space out final completion w/space out pups below 1 jt of tubing below the tubing hanger and the seals 2' from fully located. MU Landing jt in han er and land han er. RILDS 09:30 11:00 1.50 COMPZ RPCOh DHEQ P RU, test 3.5" tubing to 2500 psi. Monitor annulus for returns. Bled down pressure in tubing to 1750 psi. Pressured test the IA to 2500 psi fro 30 and charted. Bled down tulbing pressure to 0 and sheared SOV. Monitor well. 11:00 15:30 4.50 COMPZ WELC NUND P ND lines, pull landing jt. Set BPV, ND stack. Set and NU tree. 15:30 17:00 1.50 COMPZ WELCT OTHR P Test adapter void t/ 5000 psi. Test tree to 250 to / 5000 si hi, OK. 17:00 19:00 2.00 COMPZ RPCO FRZP P Pull two-way check, RU and freeze protect well w/ 90 bbls diesel down annulus and tbg. Pump at 2 bpm, 700 psi ICP, 1050 psi FCP, SI and rig down um , RU balance lines. 19:00 20:00 1.00 COMPZ RPCOh FRZP P Allow well to U-tube to balance diesel /brine head evenly across top of well IA & Tb . 20:00 00:00 4.00 COMPZ RPCO SFEQ P Set BPV, Secure Well /offload remaining fluids from pits. RD lines, lift tarps, pull off well. Rig Released this date at 2400 hrs. ~ ~~~--~ --- Page 3 of 3 F:\LaserFiche\CvrPgs _ Inserts\Microfilm _ Marker. doc MICROFILMED 04/01/05 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE Re: Request to test 3H-16 (PTD 200-022) ~ ~ Subject: Re: Request to test 3H-16 (PTD 200-022) From: Thomas Maunder <tom - maunder@admin.state.ak.us> Date: Wed, 26 May 200410:25:38 -0800 To: NSK Problem Well Supv <n1617@conocophillips.com> Marie, Putting the well on gas lift should likely reduce the IA pressure below the SICP thresholds. The efficiency of your gas lifting will depend on where the holes might be. You have approval to place the well in production for the diagnostics you describe. Please keep us informed regarding the operations. Tom Maunder, PE AOGCC NSK Problem Well Supv wrote: Tom, Approval is requested to produce 3H-16 (PTD 200-022) for 2 to 3 weeks with known tubing leaks for diagnostic data pre-RWO. The well is a Trouble Well S1 since 4/2003 and secured with a tbg tail plug due to multiple tbg holes. The well is a coiled tubing A sand only horizontal sidetrack. Due to the sustained high watercut post CTD sidetrack, a behind pipe channel is suspected from the C sand to the A sand. We propose the following plan: 1. Pull TTP 2. Produce the well with gas lift for 1-2 weeks to draw down the formation. 3. Run a water flow log while producing the well looking for water flow behind pipe from the C sand down to the A sand. 4. Shut in well waiting on TxIA communication repair. Thank You, Marie McConnell Problem Well Supervisor 659-7224 I of} 5/26/2004 II: 12 AM Permit to Drill 2000220 MD 10943 ,-" REQUIRED INFORMATION DATA INFORMATION ;2 oM') ^ CI 0 i.{ DATA SUBMITTAL COMPLIANCE REPORT 4/29/2004 Well Name/No. KUPARUK RIV UNIT 3H-16A TVD 5959 Completion Date 4/20/2002 ~. Mud Log No Types Electric or Other Logs Run: Well Log Information: Log/ Electr Data Digital Dataset Type Med/Frmt Number Name I Rpt Log -Ef) C v11225 Log ...eo C ¡/{1589 .ED D 10728 .-ED C Tf {J2061 Rpt ¿, /ED C Pdf 12061 -"ED C Pdf ~061 -'[og ¡J-2061 kog ~061 Rpt Well Cores/Samples Information: Name Interval Start Stop Operator CONOCOPHILLIPS ALASKA INC S¡1~ À I {lJt, u ~~~ I AP} No. 50-103-20096-01-00 Completion Status Samples No Log Log Run Scale Media No 1 25 Blu 1 25 Blu 5 5 5 5 Blu Blu '.J 1'-,; Sent 1-01L Current Status 1-01L UIC N Directional Survey -#I'::Y--(I' ......... (data taken from Logs Portion of Master Well Data Maint) Interval OHI ) Start Stop CH Received Comments 9810 10943 Case 1/29/2003 9810 10943 Case 1/29/2003 8964 9698 Case 7/212002 9810 10943 Case 1/29/2003 9810 10943 Case 1/29/2003 8963 9645 Open 3/13/2002 8963 10457 Open 8/26/2003 8963 10457 Open 8/26/2003 9698 10457 Open 8/26/2003 MWD- Gamma Ray - MD 9698 10457 Open 8/26/2003 )'v1WD- Gamma Ray - TVD 9698 10457 Open 8/26/2003 4vlWD- Gamma Ray - MD 9698 1 0457 Open 8/26/2003 1íÍrwD- Gamma Ray - TVD I ) 0 8825 Case 10/6/2003 Memory Multi-Finger Caliper Log Received Sample Set Number Comments Permit to Drill 2000220 MD 10943 TVD 5959 ADDITIONAL INFORMATION Well Cored? yQ]) Chips Received? "'I""1"N- Analysis Received? '¥+f'r. Comments: Compliance Reviewed By: DATA SUBMITTAL COMPLIANCE REPORT 4/29/2004 Well Name/No. KUPARUK RIV UNIT 3H-16A Operator CONOCOPHILLIPS ALASKA INC Completion Date 4/20/2002 Completion Status 1-01L Current Status 1-01L Daily History Received? (ÐN ~/N Formation Tops \~ Date: API No. 50-103-20096-01-00 UIC N ) 1C{~~~1 ) lr3s CÆJ " . ~ WELL LOG TRANSMITTAL ProActive Diagnostic Services, Inc. To: State of Alaska AOGCC 333 W. 7th Street Suite 700 Anchorage, Alaska 99501 RE: Distribution - Final Print[ s) ............ [)CO~dà~ The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention of : Joey Burton / Jeni Thompson ProActive Diagnostic Services, Inc. P. O. Box 1369 Stafford, TX 77497 WEll LOG TyPE DATE Open Hole Res. Eva!. CH Mech. CH 3H-16A 5-31-03 Caliper Survey Signed: ~\_\..',-,y~~(1~t---. '~Y\ Print Name: DIGITAL OR CD-ROM 1 1 Date: MYLAR / SEPIA FilM 1 1 BLUE LINE PRINT[S) 1 1 ocr 0/. , ,) REPORT OR BLUE LINE 1 Rpt or 2 Color " U Phone:(28l) 565-9085 Fax:(28l) 565-1369 PRoACTivE DiAGNOSTic SERviCES, INc., PO Box 1 ~b9 STAffoRd TX/i:.,.~"¡; ":,,,ùm¡j~J~1~n {;~,¡;f\~i!"'J5l) E-mail: pds@memorylog.com ~,~ ~- \~~'.......... \f'\i\ ~ Website: www.memOJ:ylog.com c~ ~ 1) 00 -00 f9-. - Memory Multi-Finger Caliper Log Results Summary Company: Log Date: Log No. : Run No.: Pipe1 Desc.: Pipe1 Use: ConocoPhillips Alaska, Inc. May 31, 2003 5091 1 3.5" 9.3 lb. L-80 Tubing Well: Field: State: API No.: Top Log Intvl1.: Bot. Log IntvI1.: 3H-16A Kuparuk Alaska 50-103-20096-01 Surface 8,825 Ft. (MD) Inspection Type: Patch Candidate Inspection COMMENTS: This log is tied into GLM 5 @ 8,798' (Driller's Depth). This log was run to assess the condition of the tubing with respect to corrosive and mechanical damages to determine potential patch candidacy. The caliper recordings indicate that the interval of 3.5" tubing logged is in good to poor condition with respect to corrosive penetrations. Multiple Holes are recorded in 5 joints from 5,600' - 6,150'. Maximum cross-sectional wall loss of from 15% to 20% is recorded throughout this same location. Wall penetrations from 20% to 85% are recorded throughout the remainder of the tubing logged. The damage appears in the form General Corrosion with deeper Line Corrosion and Isolated Pitting. Deposits restrictthe I.D. to 2.72" injoint231 @ 7,337'. The distribution of maximum recorded penetrations is illustrated in the Body Region Analysis Page of this report. MAXIMUM RECORDED WAll PENETRATIONS: Hole in Area of Corrosion (100%) Jt. 183 @ 5,813 Ft. (MD) Hole in Area of Corrosion (100%) Jt. 192 @ 6,108 Ft. (MD) Hole in Area of Corrosion (100%) Jt. 193 @ 6,135 Ft. (MD) Hole in Area of Corrosion (100%) Jt. 187 @ 5,946 Ft. (MD) Hole in Area of Corrosion (100%) Jt. 177 @ 5,638 Ft. (MD) MAXIMUM RECORDED CROSS-SECTIONAL METAL lOSS: Corrosion (20%) Jt. 183 @ 5,813 Ft. (MD) Corrosion ( 18%) Jt. 197 @ 6,262 Ft. (MD) Corrosion ( 17%) Jt. 198 @ 6,298 Ft. (MD) Corrosion ( 15%) Jt. 187 @ 5,946 Ft. (MD) Corrosion ( 15%) Jt. 188 @ 5,988 Ft. (MD) MAXIMUM RECORDED ID RESTRICTIONS: Lt. Deposits Minimum I.D. = 2.72" Jt. 231 @ 7,337 Ft. (MD) Lt. Deposits Minimum I.D. = 2.73" Jt. 247 @ 7,863 Ft. (MD) Lt. Deposits Minimum I.D. = 2.73" Jt. 242 @ 7,702 Ft. (MD) Lt. Deposits Minimum I.D. = 2.74" Jt. 230 @ 7,333 Ft. (MD) Lt. Deposits Minimum I.D. = 2.74" Jt. 248 @ 7,896 Ft. (MD) I Field Engineer: D. Cain Analyst: M. Lawrence Witness: T. Johnson ProActive Diagnostic Services, Inc. / P.O. Box 1369, Stafford, TX 77497 ¡'""'" -." '" ", Phone: (281) or (888) 565-9085 Fax: (281) 565-1369 E-mail: PDs@memOrYIOg.c<KI-CEIVED Prudhoe Bay Field Office Phone: (907) 659-2307 Fax: (907) 659-2314 . ""= 0" ?I'¡rn OCT" 0 ._\. vJ Alaska S\ Gems. Commission ¡.\nchorsge ~~~ ~ ~ ~'\" \'\¡'\ '--~ - ~ Q. Well: Field: Company: Country: 3H-16A Kuparuk ConocoPhillips Alaska, Inc. USA I Tubing: Nom.oD 3.5 ins Weight 9.3 ppf Grade & Thread L-80 Penetration and Metal loss (% wall) - penetration body 250 - 200 - metal 1055 body 150 - If! 100 Ib!i 50 0 II 0 to 1 to 10 to 20 to 40 to over 1% 10% 20% 40% 85% 85% Number of joints analysed (total = 292) pene.O 2 90 113 81 1055 32 217 43 0 0 6 0 Damage Configuration ( body) 200 150 100 50 0 isolated pitting general line ring hole / poss corrosion corrosion corrosion ible bole Number of joints damaged (total = 286) 88 165 26 1 6 ~ PDS Report Overview Body Region Analysis Survey Date: Tool Type: Tool Size: No. of Fingers: Analyst: Nom.lD 2.992 ins May 31,2003 MFC 24 No. 00387 2.75 24 M. Lawrence Upper len. 1.2 ins Lower len. 1.2 ins Nom. Upset 3.5 ins Damage Profile (% wall) - penetration body 0 1 , .. metal 1055 body 50 100 48 GLM 1 :£ GLM2 GLM 3 GlM4 ~ r.1 ~A <; ~ Bottom of Survey = 277 Analysis Overview page 2 - Pipe: Body Wall: Upset Wall: Nominal 1.0.: Joint No. /~ .~ PDS REPORT JOINT TABULATION SHEET 3.5 in 9.3 ppf L-80 0.254 in 0.254 in 2.992 in Depth (Ft.) 1 1.1 1.2 1.3 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 19 20 21 22 23 24 25 26 27 28 29 30 31 32 33 34 35 36 37 38 39 40 41 42 43 44 45 46 47 20 51 61 64 66 99 130 162 193 224 255 287 318 349 381 414 445 476 507 538 569 601 632 663 695 726 757 787 818 849 880 911 942 974 1005 1036 1068 1099 1130 1162 1193 1225 1256 1288 1320 1351 1382 1414 1445 1477 Pen. Upset (Ins.) 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 0 0 0 0 0 0 0 0 0 0 0 0 0 0 Pen. Body (Ins.) 0.04 0.04 0.02 0.03 0.04 0.03 0.02 0.04 0.05 0.03 0.03 0.04 0.04 0.03 0.04 0.04 0.04 0.04 0.04 0.03 0.03 0.04 0.04 0.05 0.04 0.04 0.04 0.04 0.04 0.05 0.04 0.04 0.04 0.04 0.03 0.04 0.04 0.03 0.04 0.04 0.04 0.04 0.04 0.04 0.03 0.04 0.05 0.04 0.04 0.04 Pen. Metal % Loss % 14 17 9 13 15 13 9 17 20 13 12 17 17 13 14 14 17 15 17 11 12 17 14 20 15 16 15 17 14 18 17 17 16 14 13 14 17 13 17 14 17 14 15 15 13 17 19 16 15 18 4 2 0 2 4 4 3 7 5 2 4 6 4 2 2 2 4 5 4 2 2 5 4 7 4 2 4 7 4 7 6 6 3 5 6 3 5 6 8 6 5 2 4 5 5 6 2 9 7 6 Min. 1.0. (Ins.) 2.92 2.88 2.90 2.90 2.92 2.92 2.92 2.92 2.93 2.92 2.93 2.93 2.91 2.90 2.92 2.90 2.92 2.91 2.91 2.92 2.92 2.91 2.92 2.93 2.94 2.93 2.93 2.94 2.92 2.92 2.94 2.93 2.92 2.93 2.91 2.92 2.92 2.93 2.95 2.93 2.92 2.92 2.93 2.93 2.94 2.89 2.90 2.93 2.95 2.95 Well: Field: Company: Country: Survey Date: 3H-16A Kuparuk ConocoPhillips Alaska, Inc. USA May 31, 2003 Comments Shallow corrosion. PUP Shallow pitting. Lt. Deposits. PUP PUP Shallow pitting. Shallow corrosion. Shallow corrosion. Lt. Deposits. Shallow corrosion. Corrosion. Shallow corrosion. Shallow corrosion. Shallow corrosion. Shallow corrosion. Shallow pitting. Shallow pitting. Shallow corrosion. Shallow corrosion. Shallow pitting. Shallow corrosion. Lt. Deposits. Shallow pitting. Shallow pitting. Corrosion. Shallow pitting. Shallow pitting. Shallow pitting. Shallow pitting. Shallow pitting. Shallow pitting. Shallow pitting. Shallow corrosion. Lt. Deposits. Shallow pitting. Shallow pitting. Shallow pitting. Shallow pitting. Shallow corrosion. Shallow Corrosion. Shallow corrosion. Shallow pitting. Shallow pitting. Shallow corrosion. Shallow corrosion. Lt. Deposits. Shallow pitting. Shallow pitting. Shallow pitting. Lt. Deposits. Shallow pitting. Shallow corrosion. Shallow pitting. Shallow corrosion. Page 1 Damage Profile (%wall) 0 50 100 I I ! I ) I III ~ \ 1 i: ~ \ I \ I , ~ . 1 \ 1 i I 'I ~ \ I ~ ~ l~ I;¡'; ~ ~: æ I Penetration Body Metal Loss Body - Pipe: Body Wall: Upset Wall: NominaILD.: joint No. 48 49 50 51 52 53 54 55 56 56.1 56.2 56.3 57 58 59 60 61 62 63 64 65 66 67 68 69 70 71 72 73 74 75 76 77 78 79 80 81 82 83 84 85 86 87 88 89 90 91 92 93 94 ~ PDS REPORT JOINT TABULATION She iT ~ 3.5 in 9.3 ppf l-80 0.254 in 0.254 in 2.992 in Depth (Ft.) 1508 1540 1571 1603 1634 1665 1696 1728 1760 1791 1802 1806 1815 1847 1878 1910 1941 1973 2004 2036 2067 2099 2130 2161 2192 2223 2255 2286 2317 2349 2381 2412 2444 2475 2506 2537 2569 2600 2632 2664 2695 2726 2758 2789 2821 2852 2884 2915 2947 2978 Pen. Upset (Ins.) 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 0 0 0 0 0 0 0 0 0 0 0 0 0 0 Pen. Body (Ins.) 0.04 0.04 0.03 0.04 0.05 0.04 0.04 0.07 0.03 0.04 0 0.03 0.04 0.07 0.07 0.05 0.06 0.12 0.07 0.07 0.08 0.09 0.07 0.07 0.07 0.06 0.06 0.09 0.07 0.07 0.11 0.09 0.08 0.09 0.09 0.05 0.06 0.04 0.05 0.04 0.03 0.04 0.04 0.05 0.04 0.04 0.05 0.06 0.04 0.04 Pen. Metal % loss % 14 16 13 15 19 14 16 29 13 15 0 12 17 26 27 19 23 48 29 29 31 35 30 28 29 22 24 35 28 28 42 35 33 34 36 21 25 15 18 17 13 15 15 19 16 14 19 22 15 16 3 4 5 2 5 4 3 10 3 2 0 2 2 6 4 3 5 3 7 6 5 2 3 5 3 4 2 3 2 4 4 6 7 6 4 4 6 4 5 3 1 2 2 5 4 7 3 3 5 5 Min. I.D. (Ins.) 2.96 2.95 2.93 2.94 2.94 2.96 2.94 2.93 2.94 2.90 2.81 2.92 2.93 2.92 2.91 2.92 2.94 2.91 2.94 2.93 2.90 2.89 2.89 2.92 2.91 2.91 2.89 2.88 2.89 2.92 2.88 2.91 2.92 2.91 2.90 2.91 2.91 2.92 2.89 2.90 2.91 2.88 2.87 2.92 2.92 2.92 2.92 2.90 2.89 2.93 Well: Field: Company: Country: Survey Date: 3H-16A Kuparuk ConocoPhillips Alaska, Inc. USA May 31, 2003 Comments Shallow pitting. Shallow pitting. Shallow pitting. Shallow corrosion. Shallow pitting. Shallow pitting. Shallow corrosion. Corrosion. Shallow corrosion. PUP Shallow pitting. SSSV PUP Shallow pitting. Shallow pitting. Corrosion. Corrosion. Shallow pitting. Isolated pitting. Isolated pitting. Isolated pitting. Isolated pitting. Isolated pitting. Isolated pitting. Corrosion. Isolated pitting. Corrosion. Isolated pitting. Corrosion. Isolated pitting. It. Deposits. Corrosion. Corrosion. Isolated pitting. Isolated pitting. Isolated pitting. Isolated pitting. Isolated pitting. Corrosion. Corrosion. Shallow corrosion. Shallow corrosion. It. Deposits. Shallow pitting. Shallow pitting. Shallow pitting. Shallow pitting. Shallow corrosion. Shallow pitting. Shallow corrosion. Shallow pitting. Isolated pitting. Shallow corrosion. Shallow pitting. Page 2 Damage Profile (% wall) 0 50 100 \ I J I II I I ~ .1 l ~: ' II I ~ I, t:: I I I I I II I 1..1 I ~~ I I I I ¡ I I , . I I I I I ~. r;;; I I I I ' I i I I III ' 1 \ I \ I ~ ~ t: I I Penetration Body Metal loss Body - ,~ ~ PDS REPORT JOINT TABULATION SI-tt:tT Pipe: 3.5 in 9.3 ppf L-80 Well: 3H-16A Body Wall: 0.254 in Field: Kuparuk Upset Wall: 0.254 in Company: ConocoPhillips Alaska, Inc. NominaII.D.: 2.992 in Country: USA Survey Date: May 31, 2003 joint Depth Pen. Pen. Pen. Metal Min. Damage Profile No. (Ft.) Upset Body % Loss I.D. Comments (% wall) (Ins.) (Ins.) % (Ins.) 0 50 100 95 3010 0 0.04 14 3 2.92 Shallow corrosion. \: \ 96 3041 0 0.04 17 5 2.90 Shallow pitting. 97 3072 0 0.07 27 6 2.91 Isolated pitting. ~ 98 3104 0 0.04 15 2 2.92 Shallow pitting. 99 3135 0 0.04 14 2 2.90 Shallow pitting. 100 3167 0 0.05 19 4 2.91 Shallow corrosion. 101 3198 0 0.06 24 2 2.89 Isolated pitting. 102 3230 0 0.07 29 5 2.92 Corrosion. 103 3261 0 0.07 26 4 2.92 Corrosion. 104 3292 0 0.10 39 5 2.90 Corrosion. 105 3324 0 0.04 16 3 2.90 Shallow corrosion. 106 3356 0 0.04 16 3 2.90 Shallow pitting. 107 3388 0 0.04 15 5 2.91 Shallow pitting. 108 3419 0 0.04 16 4 2.91 Shallow pitting. 109 3450 0 0.06 22 2 2.92 Isolated ittin. 109.1 3481 0 0.03 12 0 2.85 PUP 109.2 3487 0 0 0 0 N/A GLM 5 (Latch @ 2:30) 109.3 3496 0 0.03 12 2 2.78 PUP Lt. Deposits. I 110 3502 0 0.06 23 4 2.88 Isolated pitting. II I 111 3533 0 0.05 21 3 2.88 Isolated pitting. . I I 112 3564 0 0.07 28 2 2.91 Isolated pitting. ~ 1\ 113 3596 0 0.09 36 5 2.92 Isolated pitting. 114 3627 0 0.04 17 2 2.90 Shallow corrosion. 115 3657 0 0.08 31 4 2.89 Corrosion. rr 116 3689 0 0.09 36 7 2.90 Isolated pitting. 117 3720 0 0.05 21 3 2.89 Isolated pitting. 118 3751 0 0.04 16 3 2.89 Shallow pitting. 119 3783 0 0.07 27 4 2.87 Corrosion. Lt. Deposits. t I I 120 3815 0 0.12 48 5 2.89 Isolated pitting. I I I 121 3846 0 0.09 33 5 2.90 Corrosion. I I I 122 3877 0 0.11 43 4 2.90 Corrosion. f'1 123 3909 0 0.10 38 7 2.08 Corrosion. Deposits. I I I 124 3940 0 0.14 54 5 2.87 Corrosion. : : ¡ ¡' 125 3972 0 0.14 55 5 2.88 Isolated pitting. Lt. Deposits. 126 4003 0 0.07 28 3 2.88 Corrosion. 127 4035 0 0.09 35 5 2.88 Isolated pitting. I I I 128 4065 0 0.12 48 5 2.86 Isolated pitting. I I I I 129 4096 0 0.12 46 4 2.88 Isolated pitting. I I I I 130 4128 0 0.10 40 6 2.89 Corrosion. I I I' 131 4159 0 0.09 35 4 2.84 Corrosion. I II 132 4191 0 0.10 38 6 2.83 Corrosion. . I I 133 4222 0 0.06 23 4 2.90 Isolated pitting. 134 4253 0 0.09 35 4 2.87 Isolated pitting. L: I 135 4284 0 0.13 50 4 2.88 Isolated pitting. . I I I 136 4316 0 0.11 41 4 2.90 Isolated pitting. I I I I \ 137 4347 0 0.09 35 4 2.90 Isolated pitting. 1'" 138 4378 0 0.10 41 5 2.89 Corrosion. I I I I 139 4410 0 0.09 37 5 2.89 Corrosion. I I I 140 4441 0 0.11 41 4 2.88 Corrosion. I I I I 141 4473 0 0.11 45 6 2.90 Corrosion. I I I I I Penetration Body Metal Loss Body Page 3 - ..~ ,~ PDS REPORT JOINT TABULATION SHEET Pipe: 3.5 in 9.3 ppt L-80 Well: 3H-16A Body Wall: 0.254 in Field: Kuparuk Upset Wall: 0.254 in Company: ConocoPhillips Alaska, Inc. NominaII.D.: 2.992 in Country: USA Survey Date: May 31, 2003 Joint Depth Pen. Pen. Pen. Metal Min. Damage Profile No. (Ft.) Upset Body % Loss 1.0. Comments (%wall) (Ins.) (Ins.) % (Ins.) 0 50 100 142 4504 a 0.13 50 6 2.89 Corrosion. I I I I I 143 4534 a 0.13 52 5 2.84 Isolated pitting. 144 4566 a 0.15 60 9 2.87 Corrosion. 145 4597 a 0.12 48 8 2.88 Corrosion. Lt. Deposits. 146 4628 a 0.11 44 6 2.88 Corrosion. 147 4660 a 0.11 42 6 2.90 Corrosion. Lt. Deposits. 148 4691 a 0.11 42 6 2.87 Line corrosion. Lt. Deposits. 149 4723 a 0.14 54 10 2.84 Line corrosion. Lt. Deposits. 150 4754 a 0.13 50 7 2.83 Corrosion. 151 4786 a 0.15 60 8 2.89 Line corrosion. 152 4817 a 0.13 50 7 2.84 Corrosion. It. Deposits. 153 4848 a 0.18 72 11 2.84 Corrosion. Lt. Deposits. 154 4879 a 0.19 73 11 2.86 Corrosion. Lt. Deposits. 155 4910 a 0.15 60 8 2.85 Line corrosion. Lt. Deposits. 156 4942 a 0.11 44 6 2.89 Corrosion. Lt. Deposits. 157 4973 a 0.12 48 6 2.88 Line corrosion. Lt. Deposits. 158 5005 a 0.09 35 5 2.90 Isolated pitting. 159 5035 a 0.10 40 7 2.88 Corrosion. Lt. Deposits. 160 5066 a 0.14 54 9 2.87 Line corrosion. Lt. Deposits. 161 5098 a 0.13 50 7 2.88 Corrosion. 162 5130 a 0.17 65 13 2.85 Corrosion. Lt. Deposits. 163 5161 a 0.13 51 9 2.80 Corrosion. Lt. Deposits. 164 5193 a 0.12 49 8 2.81 Corrosion. 165 5224 a 0.15 57 9 2.86 Corrosion. 166 5255 a 0.15 58 9 2.86 Corrosion. Lt. Deposits. 167 5287 a 0.11 44 6 2.86 Corrosion. Lt. Deposits. 168 5318 a 0.13 53 7 2.87 Corrosion. Lt. Deposits. 169 5349 a 0.09 35 5 2.90 Corrosion. Lt. Deposits. 170 5381 a 0.16 64 12 2.88 Corrosion. Lt. Deposits. 171 5412 a 0.10 40 7 2.86 Line corrosion. Lt. Deposits. 172 5444 a 0.13 51 9 2.85 Corrosion. Lt. Deposits. 173 5475 a 0.13 51 9 2.88 Line corrosion. Lt. Deposits. ~ 174 5506 0 0.15 57 11 2.87 Line corrosion. Lt. Deposits. 175 5537 0 0.24 94 13 2.87 Probable Hole! 175.1 5569 0 0.03 13 0 2.86 PUP Shallow pitting. II 175.2 5575 0 0 0 0 N/A GlM 2 (Latch @ 10:00) 175.3 5584 0.06 0.04 14 1 2.86 PUP Shallow pitting. 176 5590 0 0.14 56 8 2.90 Line corrosion. Lt. Deposits. I I I I 177 5621 0 0.27 100 14 2.86 Multiple Holes! I I I I I 178 5653 0 0.18 69 13 2.87 Corrosion. Lt. Deposits. 179 5684 0 0.17 67 15 2.85 Corrosion. Lt. Deposits. 180 5715 0 0.17 69 11 2.84 Corrosion. Lt. Deposits. I I I I I 181 5747 0 0.19 76 13 2.86 Corrosion. Lt. Deposits. I I I II I 182 5779 0 0.17 69 12 2.90 Line corrosion. Lt. Deposits. I I I I I 183 5809 0 0.72 100 20 2.87 Hole! I I I I I 184 5840 0 0.19 76 13 2.86 Corrosion. Lt. Deposits. II II I 185 5872 0.04 0.17 68 11 2.87 Corrosion. It. Deposits. II I I I 186 5904 0 0.19 75 12 2.90 Corrosion. It. Deposits. I I I I I I 187 5935 0 0.39 100 15 2.91 Hole! II I I I I III 188 5966 0 0.20 80 15 2.86 Corrosion. Lt. Deposits. I I I I I I I Penetration Body Metal loss Body Page 4 - ~. ,,~ - PDS REPORT JOINT TABULATION SHEET Pipe: 3.5 in 9.3 ppf L-80 Well: 3H-16A Body Wall: 0.254 in Field: Kuparuk Upset Wall: 0.254 in Company: ConocoPhillips Alaska, Inc. Nominal \.D.: 2.992 in Country: USA Survey Date: May 31, 2003 Joint Depth Pen. Pen. Pen. Metal Min. Damage Profile No. (Ft.) Upset Body % Loss \.D. Comments (%wall) (Ins.) (Ins.) % (Ins.) 0 50 100 189 5997 0 0.22 85 14 2.88 Corrosion. Lt. Deposits. I I I I : : I 190 6028 0 0.18 72 11 2.85 Corrosion. Lt. Deposits. I I I I 191 6059 0.06 0.18 72 10 2.86 Corrosion. Lt. Deposits. I I I I I 192 6091 0 0.42 100 10 2.86 Multiple Holes! I I I I I I I I I I 193 6123 0 0.39 100 13 2.87 Hole! I I I I I 194 6153 0.03 0.18 69 12 2.86 Corrosion. Lt. Deposits. I I I I I 195 6186 0 0.17 65 15 2.82 Corrosion. Lt. Deposits. I I I I 196 6217 0 0.17 68 15 2.84 Corrosion. Lt. Deposits. I I I I 197 6248 0 0.19 73 18 2.86 Corrosion. Lt. Deposits. I I I I I I 198 6280 0.02 0.20 80 17 2.86 Corrosion. Lt. Deposits. 199 6311 0 0.14 57 12 2.84 Corrosion. Lt. Deposits. 200 6343 0 0.13 52 12 2.86 Corrosion. Lt. Deposits. 201 6374 0 0.13 49 13 2.88 Corrosion. Lt. Deposits. 202 6405 0 0.15 60 12 2.82 Corrosion. Lt. Deposits. 203 6437 0 0.13 50 13 2.84 Corrosion. Lt. Deposits. 204 6468 0 0.16 61 12 2.86 Corrosion. Lt. Deposits. 205 6500 0.05 0.12 46 11 2.89 Corrosion. Lt. Deposits. 206 6529 0 0.18 69 15 2.86 Corrosion. Lt. Deposits. 207 6561 0 0.10 41 12 2.86 Corrosion. Lt. Deposits. 208 6593 0.04 0.14 54 10 2.87 Corrosion. Lt. Deposits. 209 6623 0 0.12 49 10 2.87 Corrosion. Lt. Deposits. 210 6655 0 0.13 51 11 2.86 Line corrosion. Lt. Deposits. 211 6687 0 0.10 37 9 2.84 Corrosion. Lt. Deposits. 212 6719 0 0.09 37 11 2.86 Corrosion. Lt. Deposits. 213 6749 0 0.09 34 10 2.84 Corrosion. Lt. Deposits. 214 6781 0 0.12 46 6 2.87 Corrosion. Lt. Deposits. 215 6813 0 0.09 34 10 2.86 Line corrosion. Lt. Deposits. 216 6843 0 0.07 28 10 2.85 Corrosion. Lt. Deposits. 217 6874 0 0.06 22 8 2.86 Isolated pitting. 218 6906 0.06 0.07 29 9 2.87 Line corrosion. Lt. Deposits. 219 6937 0 0.06 24 6 2.87 Corrosion. Lt. Deposits. 220 6967 0 0.05 21 3 2.86 Corrosion. 220.1 6999 0 0.08 31 11 2.91 PUP Corrosion. Lt. Deposits. 220.2 7006 0 0 0 0 N/A GLM 3 (Latch @ 11 :30) 220.3 7013 0 0.05 18 4 2.87 PUP Shallow pitting. I 221 7020 0 0.06 23 4 2.86 Corrosion. Lt. Deposits. . I I 222 7051 0.04 0.08 33 2 2.82 Corrosion. Lt. Deposits. I 223 7084 0.06 0.09 35 7 2.80 Corrosion. Lt. Deposits. 224 7115 0.07 0.11 44 8 2.80 Corrosion. Lt. Deposits. 225 7145 0 0.10 39 12 2.81 Line corrosion. Lt. Deposits. 226 7177 0.06 0.07 29 8 2.80 Corrosion. Lt. Deposits. 227 7208 0 0.09 35 7 2.79 Corrosion. Lt. Deposits. 228 7239 0.08 0.08 32 9 2.80 Line corrosion. Lt. Deposits. ~ II 229 7270 0.02 0.09 33 1 2.81 Corrosion. Lt. Deposits. I I . 230 7302 0.06 0.11 44 1 2.74 Corrosion. Lt. Deposits. ~ 231 7333 0 0.10 38 1 2.72 Corrosion. It. Deposits. I I I I 232 7363 0 0.08 31 1 2.78 Corrosion. Lt. Deposits. 233 7396 0.05 0.11 43 13 2.78 Corrosion. Lt. Deposits. 234 7427 0.09 0.10 38 1 2.77 Corrosion. Lt. Deposits. 235 7458 0.09 0.10 39 1 2.76 Line corrosion. Lt. Deposits. I I I I I Penetration Body Metal Loss Body Page 5 - ~, ,~ PDS REPORT JOINT TABULATION SHEET Pipe: 3.5 in 9.3 ppf L-80 Well: 3H-16A Body Wall: 0.254 in Field: Kuparuk Upset Wall: 0.254 in Company: ConocoPhillips Alaska, Inc. NominaII.D.: 2.992 in Country: USA Survey Date: May 31, 2003 joint Depth Pen. Pen. Pen. Metal Min. Damage Profile No. (Ft.) Upset Body % Loss I.D. Comments (% wall) (Ins.) (Ins.) % (Ins.) 0 50 100 236 7490 0.04 0.07 29 1 2.76 Corrosion. Lt. Deposits. I I I I 237 7521 0.07 0.09 37 0 2.75 Corrosion. Lt. Deposits. 238 7552 0 0.08 33 14 2.76 Line corrosion. Lt. Deposits. 239 7584 0.08 0.07 28 1 2.80 Corrosion. Lt. Deposits. 240 7615 0 0.07 28 1 2.75 Corrosion. Lt. Deposits. 241 7647 0.07 0.08 32 11 2.76 Corrosion. Lt. Deposits. 242 7676 0 0.10 40 1 2.73 Corrosion. Lt. Deposits. 243 7707 0.06 0.10 39 9 2.74 Corrosion. Lt. Deposits. 244 7739 0 0.09 35 6 2.74 Corrosion. Lt. Deposits. 245 7770 0.04 0.10 39 10 2.74 Corrosion. Lt. Deposits. 246 7802 0.07 0.09 35 12 2.76 Corrosion. Lt. Deposits. 247 7833 0.08 0.10 37 8 2.73 Corrosion ring. Lt. Deposits. 248 7863 0.07 0.09 36 7 2.74 Corrosion. Lt. Deposits. 249 7896 0.06 0.11 42 10 2.77 Line corrosion. Lt. Deposits. 250 7927 0.07 0.11 42 1 2.77 Corrosion. Lt. Deposits. r I I II 251 7958 0.08 0.11 43 1 2.77 Corrosion. Deposits. I I I I I 252 7990 0.07 0.12 46 2 2.77 Corrosion. Deposits. I I I 252.1 8022 0.05 0.07 27 0 2.76 PUP Corrosion. Deposits. !! I 252.2 8027 0 0 0 0 N/A GLM 4 (Latch @ 3:00) 252.3 8035 0.06 0.05 18 2 2.77 PUP Shallow corrosion. Lt. Deposits. 253 8042 0 0.08 30 8 2.87 Line corrosion. Lt. Deposits. ~ II 254 8073 0.04 0.08 33 1 2.78 Corrosion. Lt. Deposits. II : : 255 8104 0.06 0.09 37 1 2.77 Corrosion. Lt. Deposits. 256 8135 0 0.10 39 1 2.74 Line corrosion. Lt. Deposits. . 257 8166 0.08 0.09 37 9 2.76 Line corrosion. Lt. Deposits. 258 8196 0.06 0.09 36 1 2.77 Corrosion. It. Deposits. 259 8228 0 0.11 45 1 2.77 Corrosion. It. Deposits. I I I I 260 8260 0 0.07 28 1 2.78 Corrosion: Lt. Deposits. \ I I 261 8290 0.05 0.09 36 1 2.78 Corrosion. Lt. Deposits. I I I I 262 8323 0.04 0.08 33 1 2.78 Corrosion. Lt. Deposits. i I I I 263 8354 0.06 0.06 24 1 2.79 Corrosion. Lt. Deposits. I I I 264 8385 0.03 0.09 34 1 2.79 Corrosion. Lt. Deposits. ¡ I I I 265 8417 0 0.10 39 2 2.78 Corrosion. Lt. Deposits. II I I 266 8447 0.05 0.05 20 1 2.78 Corrosion. Lt. Deposits. II I 267 8480 0 0.08 31 1 2.78 Corrosion. Lt. Deposits. ~: 268 8511 0.05 0.08 30 7 2.80 Line corrosion. Lt. Deposits. 269 8541 0 0.06 24 5 2.81 Corrosion. Lt. Deposits. 270 8574 0.05 0.07 26 5 2.81 Corrosion. Lt. Deposits. I I 271 8604 0.06 0.08 31 5 2.82 line corrosion. It. Deposits. Ii I I I 272 8636 0 0.07 26 1 2.86 line corrosion. It. Deposits. ~ I I 273 8668 0.09 0.09 34 3 2.82 line corrosion. Lt. Deposits. I I I 274 8699 0.05 0.10 39 2 2.81 Corrosion. Lt. Deposits. ~ II 275 8730 0.08 0.09 35 6 2.83 Corrosion. Lt. Deposits. I I I 276 8760 0.07 0.08 33 4 2.81 Corrosion. Lt. Deposits. t ! ! i 276.1 8793 0 0.09 35 5 2.83 PUP Corrosion. Lt. Deposits. 276.2 8798 0 0 0 0 N/A GLM 5 (Latch @ 11 :30) 276.3 8807 0.03 0.08 30 4 2.88 PUP Corrosion. It. Deposits. 277 8813 0 0.08 31 2 2.89 Corrosion. It. Deposits. \ I I I IPenetration Body Metal loss Body Page 6 I Jas. PDS Report Cross Sections Well: Field: Company: Country: Tubing: 3H-16A Kuparuk ConocoPhillips Alaska, Inc. USA 3.5 ins 9.3 ppf L-80 Survey Date: Tool Type: Tool Size: No. of Fingers: Analyst: May 31, 2003 MFC 24 No. 00387 2.75 24 M, Lawrence Cross Section for joint 183 at depth 5812.8 ft Tool speed = 58 Nomina) JD = 2.992 Nominal 00 = 3.500 Remaining wall area = 80 % Tool deviation = 56 0 Finger 23 Penetration = 0.719 ins Hole! ) ) 20% Cross-Sectional Wall Loss HIGH SIDE = UP Cross Sections page 1 I cIas . PDS Report Cross Sections Well: Field: Company: Col,mtry: Tubing: 3H-16A Kuparuk ConocoPhillips Alaska, Inc. USA 3.5 ins 9.3 ppf L-80 Survey Date: Tool Type: Tool Size: No. of Fingers: Analyst: May 31,2003 MFC 24 No. 00387 2.75 24 M. Lawrence Cross Section for joint 192 at depth 6108.25 ft Tool speed = SO NominallD = 2.992 Nominal aD = 3.500 Remaining wall area = 90 % Tool deviation = 61 0 Finger 3 Penetration = 0.417 ins Hole in Area of Corrosion ) ) 0.42 ins = 100% Wall Penetration HIGH SIDE = UP Cross Sections page 2 .:>---, Transmittal Form INTEQ To: AOGCC 333 West ih Ave, Suite 100 Anchorage, Alaska 99501 Attention: Lisa Weepie Reference: 3H-16APBl Contains the following: 0\9\ 1 LDWG Compact Disc \& (Includes Graphic Image files) 1 LDWG lister summary 1 blue line - GR/DIR Measured Depth Log 1 blueline - GRiDIR TVD Log LAC Job#: 271269 Sent By: Glen Borel Received B~~~~~ ~ ("co -o~à r~íll BAKER HUGHES II. ":M,';~.:~:':f -""""";;,;.;~":-'..¡;¡-"-""" -, - ~ .. -, . .. -, - -., -.. ." ... .. , - Anchorage GEOScience Center:",~: ~:::;:.._, - Date: Aug 25, 2003 Date: PLEASE ACKNOWLEDGE RECEIPT BY SIGNING & RETURNING OR FAXING YOUR COpy FAX: (907) 267-6623 Baker Hughes INTEQ 7260 Homer Drive Anchorage, Alaska 99518 Direct: (907) 267-6612 FAX: (907) 267-6623 t:>r=C- J=~V',~'U'~' r~~ .""""U =, I. If_" 2 l '" (\ :" "0 hv'.J 0 ¿iN,) A!aeÌ'.a Œ ~ '. .. 4t¡'i¡({::-J~Jn ..~.. "" , """" ",-- . ",.,,~ I . """"-".........." _"n_' _-----m___--- ... --.. ¡-- '^", ,,-'" éj.OO"'Oâ;;1 t (5~CJ Transmittal Form ".- BAKER HUGHES ,_. - ,."'.;; ~ -, ',> .. . - -.- ~~-, INTEQ '". '" .. . .. Anchorage GEOScience Center." "" _.' To: AOGCC 333 West 7th Ave, Suite 100 Anchorage, Alaska 99501 Attention: Lisa Weepie Reference: 3H-16A Contains the following: ~- 1 LDWG Compact Disc (Includes Graphic Image files) 1 LDWG lister summary 1 blueline - GRiDIR Measured Depth Log 1 blue line - GRiDIR TVD Log -------, ------------,--- ,- "--- -"",,- .. , ------- - - Sent BY:;e~ Received By. ~ Date: Jan 28, 2003 - i - - - - , --i-:-- ; ~, --ïz- -f-,"- .. ~ 1 ~- ¡r: [t~:- . ;j-:--- :bi LAC Job#: 271269 *4:- :t~~:' PLEASE ACKNOWLEDGE RECEIPT BY SIGNING & RETURNING L;1~;;f' OR FAXING YOUR COpy C FAX: (907) 267-6623 ~:....¡_... REcE,vEJ~l, ~..:¿ JAN 29 2003 [-, AIaeta Oif " Gea Cona. ConInIaeiøn ~ Date: Baker Hughes INTEQ 7260 Homer Drive Anchorage, Alaska 99518 Direct: (907) 267-6612 FAX: (907) 267-6623 ~. ~ a Cv-Od.~ J/~S WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Corom. Attn.: Lisa Weepie 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 July 01,2002 RE: MWD Formation Evaluation Logs 3H-16A, AK-MM-11192 The technical data listed below is being subnùtted herewith. Please address any problems or concerns to the attention of: Rob Kalish, Sperry-Sun Drilling Services, 6900 Arctic Blvd., Anchorage, AK 99518 3H-16A: Digital Log Images 50-103-20296-01 1 CD Rom ~ RECEIVED JUL 2 2002 Alaska OU & Gas Cons. Commission Anchorage ,r---\ ,~ STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well a Oil 0 Gas 0 Suspended 0 Abandoned 0 Service 2. Name of Operator ,DI ' I' 1\ r J , ~ ,.. 7. Permit Number -'èJ;- !;xplo[!^tinn (AI~!':ka) Inc. 1 ~"\-I ( \ lf~ ,fb \ rL(t;A ~~ 200-022 3. Address ""- 8. API Number P.O. Box 196612, Anchorage, Alaska 99519-6612 50-103-20096-01 4. Locati~n of well a! surface ïœ\~" ,; cDMPmiOül 9. Unit or Lea~e Nam.e 1107 FNL, 4997 FEL, Sec. 12, T12N, R08E, UM " ' , " .1JAT5¡ 'I" Kuparuk River Unit At top of productive interval I ¡ II iIZð/,o2- L 1682' FNL, 1264' FEL, Sec. 10, T12N, R08E, UM"_,,' 'il~1 V~¡W",¡, 10. Well Number Att~taldepth , ,$, , ,)'1'" ,.,; ...,: 3H-16A 2277 FNL, 2312 FEL, Sec. 10, T12N, R08E, UM ì,1w":",~':" d L~__,....."!I, . 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designatio~ and Serial No. 11. F~~~a~~~ ~~r Field / Kuparuk Oil Pool KBE = 68.72' ADL 025532 12. Date Spudded 113. Date T.D. Reached 114. Date Comp., Susp., or Aband. 115. Water depth, if offshore 116. No. of Completions 11/21/2001 4/19/2002 4/20/2002 N/AMSL One 17. Total Depth (MD+ TVD) 118. Plug Back Depth (MD+ TVD) 119. Directional Survey 120. Depth where SSSV setl21. Thickness of Permafrost 10943 5959 FT 10943 5959 FT a Yes 0 No (Nipple) 1809' MD 1600' (Approx.) 22. Type Electric or Other Logs Run MWD, LWD 23. CASING SIZE 16" 9-5/8" 7" Classification of Service Well WT. PER FT. 62.5# 36# 26# 9.3# 4.43# GRADE H-40 J-55 J-55 L-80 L-80 CASING, liNER AND CEMENTING RECORD SETTING DEPTH HOLE Top BOTTOM SIZE CEMENTING RECORD Surface 110' 24" ,200 sx Arcticset I Surface 3943' 12-1/4" 1600 sx AS III, 400 sx Class 'G' Surface 8991' 8-1/2" 400 sx Class 'G', 175 sx AS I 8836' 9698' 6-1/8" 164 sx Class 'G' 9578' 10943' 3" Uncemented Slotted Liner AMOUNT PULLED 3-1/2" 2-3/8" 24. Perforations open to Production (MD+ TVD of Top and Bottom and interval, size and number) 2-3/8" Slotted Liner MD TVD MD 9611'-10909' 5960' - 595~ E eEl V E D SIZE 3-1/2", 9.3#, L-80 TUBING RECORD DEPTH SET (MD) 8855' PACKER SET (MD) 8836' 25. TVD JUN 0 6 2002 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 2500' Freeze Protect with 80 Bbls of Diesel 27. Date First Production April 27, 2002 Date of Test Hours Tested 4/27/2002 2.8 Alaska Oil & Gas Cons. GommlSSlor AnC'.hnr::lgf! PRODUCTION TEST Method of Operation (Flowing, gas lift, etc.) Gas Lift PRODUCTION FOR TEST PERIOD OIL-BBL 62 OIL-BBL GAs-McF 81 GAs-McF WATER-BBL 1045 WATER-BBL CHOKE SIZE 1 GAS-OIL RATIO 10 1306 OIL GRAVITY-API (CORR) Flow Tubing Casing Pressure CALCULATED Press. 24-HoUR RATE 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. No core samples were taken. 0 l~ f . ,i..- Form 10-407 Rev. 07-01-80 ê?Ý R8DMS 8FL JUN I Þ 2O&tbmit In Duplicate ,--., J~. 29. Geologic Markers 30. Formation Tests Marker Name Measured Depth True Vertical Depth Include interval tested, pressure data, all fluids recovered and gravity, GOR, and time of each phase. Top Upper Kalubik 8986' 5722' Top Lower Kalubik (K-1) 9174' 5827' Top D 9308' 5898 Top C4 9320' 5904' Top A2 9450' 5947' Top A1 9582' 5959' RECEIVED JUN 0 6 2002 Alaska Oil & Gas Cons. CommissIon Anchorage 31. List of Attachments: F.I.T. for 11/19/01, Summary of Daily Drilling Reports and Non-Rig Work, Surveys 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed Terrie Hubble ~~ ~ Title Technical Assistant 3H-16A 200-022 Well Number Permit No. / Approval No. Date O~ '0(0. Ô~ Prepared By NameINumber: INSTRUCTIONS GENERAL: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. ITEM 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. ITEM 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. ITEM 16 AND 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. ITEM 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). ITEM 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITEM 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, Other-explain. ITEM 28: If no cores taken, indicate 'none'. Form 10-407 Rev. 07-01-80 CASING TEST and FORMATION INTEGRITY TEST .-t 0 0 t§I Date: 11/1912001 Supervisor: R W Bowie Well Name: 3H-16A 0 Initial Casing Shoe Test Reason(s) for test: 0 Formation Adequacy for Annular Injection 0 Deep Test Open Hole Adequacy for Higher Mud Weight Casing Size and Description: r x 26 ppf xJ55 Casing Setting Depth: 8988' Hole Depth: 9,012' TMD 5,738' TVD Mud Weight: 11.0 ppg Length of Open Hole Section: #VALUEI EMW= Leak-off Press. + Mud Weight = 620 psi + 11.0 ppg 0.052 x TVD 0,052 x 5,738' EMW for open hole section = 13.1 ppg Pump output = 0.0583 bps Fluid Pumped = 0.6 bbl I><f ...:: ~ .-t N 1100 psi 3,000 psi ~,9IIIIp.s1 ~,øoopol 2,7DOpsl MOQplil 2J;OOpli 2.4oopsi 2.3OOp$l 2.2IXI pol 2.100 pol 2,oX) pol W l,9OCIpsl II: 1,800 psi :;) J,700PGI (/) l,tIIIOpsl 13 1.5UU psi a:: 1,400 þIi a. 1,300 pol . l,2oop~ Moopl1 1,000pli -- ::: /- .- mopsi æ1psi - 9Xlpøl ---r 400 I' :m~1 í - I 2OQpell'" ..ì 100 pel .-.. -- )1 Ðpsl '" - ~ ~ I I .,'" .to.i- ¿ ... -'- :I. J, 1t.IM~;~lJ':I.§~~-f,;;;;g~1 / . dÑiHjUNUTE. flti(if: r I_. - ~~LEAK-OFFTEST :" I """CAS!N.G TEST ~' I --LOT SHUT IN TIME ,.. -Ir-CASING TEST SHUT IN1UAE -+- TIME LINE .;r .. .-t 0 <') .-t 0 N '- 0 <') \~ 0 i !! ~ ! ::! STROKES NOTE: STROKES TURN TO MINUTES DURING "SHUT IN TIME":see Ume lìne above LEAK-OFF DATA CASING TEST DATA "'INUTES FOR LOT STROKES PßESSURE --.. - - - - _.'\--- -_..-.-_.....-- --- - --. _...¡. -9..st~-_.~.....!!..es.L ._~ ~_....--_..!.I!!.~.. '.n~~_!!__- ~---_._---_.i!t.~ _.!!!.p..sLJ '_..._m__~___5 s!~!..__!~~...2!!_j .....-- --... _!..!. ~~-j.~! 9.J!!L.f ~-_u---_._! stk!...~-2.~9.P.!L.J . - -- ...- 00 .:..lt~k!.., ..~ J?!~ --~ MINUTES FOR CSGTEST STROIŒS PRESSURE .-- - ------r -.--... =t-- --- -... "'\ ,.-._..._..--~ st~ .._~-~S;,L_...I : 7 stks 190 psi . ~~~=~~= 1t!nœ~~~~!3!~i .~ : ' 22 stks: 900 psi j -----...----'-------... -------- '---------- -_EiO !!_~.. ....!!~?9_e!'.!... ._n__.____.~8 ~1!L__1!!!40 E!!U , : 45 elks : 2,010 psi - r---"-- >_..._----oJ-----_... '._--_.__-:Æ._!t~----~!O..E!~ ~ -.---........1.. 4H!.!~_.~~!O.._~!L' L... ..---....: -. !!-!~.!!!.._: -1~~.e!J)-1 ) ~_._------------- --.-.--..-- L. .--.. .--..~. _.-- -... -- .._-, : , , --..- -- ....+. - - ------.. ....:...._--- -.---- J c:~=~~~-::=:::=~:=~:=::=i . ~_..:::=--=:: ~::=::= ~:==--=--==, ------.--.4----------. ------------~ ~--------- ~_..._u..+.--------_.' ;----..--------.--. ---_..----.~ -------..-----------.-.,.....--.------. : : : '---.-------.--.--------..--..... f--..---".""----------' --------....... . ... _u_.. ..!.._--......-----...---- n._.r ~ ..--.....-L. - .-..---.; - --. -.--.- . ' '!--------- -------- --.----( - ----. .-- --...:-..- .-- "._-~--"'-': :- ... -- _n- T". --_...~._---_.. .-- r.- _00 ----- :-"" - --..-: -. - ..-- ---.. , -----_'..":"--"-"'--~--------_..'""1 "__.00__- i---..-----t..---..-.---.: ,--'...----¡'-'---.' ....-....--¡ : SHUT IN TIME' SHUTIN PflESSURE ~ -_.--- ---.,.--- "-... .--- - '..' .--.- -.... ----....-------- .--n L---------...--------...L---"--l )..._<.>:0 fl'!.i~......_..._; .2~~'i ro.-----.. ~ : .--i:g ~:~ _J_---_..~--;~;gr.J-1 r----- -'...------.00<.----.-----:-1' ..!~!!.!!!...'!-'.~------_....!~~~~.~E L_";'~_~~!L ----_....-+.~~~~.P.!U ~ ..Jl~~.!!!!r'...~-_..___~__..620 _P!L... _..1B-~~!!__l_n.___.L~!~O .I!!L --L~_'!.!!!!..___...- ...~O P!LJ l._?,0 f!!.i!!..~-_._...____..i.2~!QJJ.si _.1 ~..~~_IJ1.~-----------._..!!~!-J ~-~ß ml!!._~---__._! --~ OZ~i -. ~_. 3.0 -1)l.!~...L--_.._~-.!~.9_P!i .: ~...?:~_mln...:..-__u__.__~~9M.P.~!... ..- 4.0 1!1.!~--~--------_.....!!~,ps~ ~-~..~- ml,L --_..--_.J._!Y~~L ~__~~9 mi!1---...___~--J-. 61~'ps-!'~ .__.~~-~~!,-_..._--_~~O.I!!L.( ~_~~9 mi~__~_------ : --- 61 0 'p_!~--' .__J 0.0 _~l!'- ~-----_.-......:.~~O I!!U '.2~9_'!I.!!!..1_.-__- 4..___"--' ;_1.5.0 ~.!!!_~---____.L~.Q.I~S) .i -1~ ~ -~ ~-.-- ---- - -. -~n... - - -.' _?ç; Q!I..1l.t!._--- -.--: ..! ~~~ .P.~.!.. ~.-~.r..'1!~~---__...._L___...__-- ..!§~~ min -~...__.---...:__!~~.E!L L.1 O'~_I!I.!n.__..._--_._---_..._._- :.- 30:~_~1!!... _..._..._~~20_psL ) NOTE: TO CLEAR DATA, HIGHLIGHT AND PRESS THE DELETE KEY r---. ,~ Well: Field: API: Permit: 3H-16A Kuparuk 50-103-20096-01 200-022 NON-RIG WORK 01/05/01 TAGGED FILL AT 9501' RKB, EST. 110' RATHOLE. MEASURED BHP AT 9350' RKB: 3939 PSI. 01/16/01 DRIFTED TUBING WI 2.792" SWAGE. DRIFTED 'D' NIPPLE WI 2.74" GAUGE RING; SBHP - 4033 PSI AT 9350',4009 PSI AT 9250' AND 3971 PSI AT 9100' RKB. 01/20/01 MITIA PASSED AT 3000 PSI, PRE CTD. 02/06/01 PREP FOR P&A SQUEEZE. BULLHEAD 150 BBL 130 DEG SW. TAG TD AT 9604' CTM, CORRECT +10' TO 9614' RKB. 02/07/01 PUMP 44 BBLS 17 PPG CLASS 'G' CEMENT, 35 BBLS WITH 20 PPB AGGREGATE. PUMP ALL CEMENT BEHIND PIPE. ZERO PSI SQUEEZE PRESSURE. WASHED AND JETTED TO 9400' RKB, POOH TO REMOVE BALL. PUMPED SECOND 34 BBL PLUG. BUILT ABOUT 400 PSI SQUEEZE PRESSURE. CLEANED TOC TO 9245'. FREEZE PROTECTED WELL FROM 2200'. LEFT 1470 PSI ON THE WELL HEAD. 02/08/01 TESTED CEMENT SQUEEZE, BROKE DOWN AT 2000 PSI. TAGGED CEMENT AT 9368' RKB. 02/11/01 PUMPED 38 BBLS 17# CLASS 'G' CEMENT. 32 BBLS BEHIND PIPE, PLUG TOP AT APPROXIMATELY 9125'. NO SQUEEZE PRESSURE ACHIEVED. 02/13/01 TAGGED CEMENT WI 2.27" SWAGE AT 8683' RKB. PERFORM MIT ON TUBING TO 2500 PSI, HELD FOR 30 MINUTES, GOOD TEST. 10/21/01 DRIFTED TUBING TO 8981' WLM WI 12' X 2.745" DRIFT. 10/22/01 OBTAINED JEWELRY LOG 8600' - 9042', TAGGED FISH AT 9042'. LEFT WELL SI. 11/09/01 PRE-RIG DIAGNOSTICS, POT-T PASSED. PPPOT-T FAILED. POT-IC PASSED, PPOT-IC FAILED. MITT FAILED. MITIA PASSED. MITOA PASSED. )--... ~\ 3H-16A, Rotary & Coil Tubing Drilling Page 2 11/10/01 TUBING PUNCHED 3.5" TUBING WITH 8 TOTAL SHOTS (20 ES CHARGES) AT 9019' - 9021' IN FIRST FULL JOINT ABOVE FISH. TUBING PASSED MIT TO 2500 PSI PRIOR TO ElL RU. DISPLACED TUBING AND IA TO SEAWATER WI 2500' DIESEL CAP ON BOTH. 11/11/01 SET 2.81" X 10' FRAC SLEEVE ACROSS FLAPPER AT 1804' RKB. 12/01/01 PERFORMED A FCO TO 9579.1' CTMD. WASHED MANDRELS ON WAY TO SURFACE. WELL FREEZE PROTECTED TO 4000'. 12/02/01 REPLACED 1.5" OCR AT 8798' RKB WI 1.5" DV. PT VALVE WI 600 PSI DP. LOST TOOL STRING ON FLAPPER. 12/03/01 RECOVERED TOOL STRING AT 6955' SLM. DRIFTED TUBING 2.765" TO X NIPPLE AT 8844' RKB. TESTED IA TO 2500 PSI, TEST GOOD. 02/28/02 DAMAGED COIL TUBING. CUT OFF 1800' ON LOCATION. PREP FOR RE-START IN THE MORNING. MAJOR OPERATIONAL FAILURE. BEARING PIECE FOUND IN CHAINS. 03/01102 ATTEMPTED TO RIH FOR MILLING OF FLOAT SHOE WQUIPMENT. TAGGED GLM #4 AT 8007.8' CTMD. TAGGED OBSTRUCTION AT 8024' WLM WI 2.785" LIB. 03/02/02 PULLED DV AT 8027' RKB. GAUGED TUBING TO 2.79" TO 8844' WLM. SET DV AT 8027' RKB. GAUGED TUBING TO 2.79" TO 8040' WLM. 03/03/02 PERFORMED MILLING OPERATIONS, FOR PRE-COILED TUBING DRILLING OPERATIONS, FROM 9590.6' CTMD TO 9628.8' CTMD. ROP BEGAN TO SLOW DOWN. 03/04/02 PERFORMED A MILL OUT OPERATION FROM 9628.8' TO 9665' CTMD. AVERAGE ROP = 5.56'. RETURNS 1- 1. APPROXIMATELY 39-25' LEFT TO FINISH. 03/05/02 MILLED CEMENT TO 9683' CTM UPWEIGHT (9696' RKB) USING 2.80" DIAMOND SPEED MILL I 2-1/8" WEATHERFORD MOTOR. NO CLEAR SIGN OF EXITING SHOE. WELL LEFT FREEZE PROTECTED, JOB ONGOING. NOTE: CORRECTED DEPTH TO 'X' NIPPLE AT 8831' CTM UPWEIGHT WHICH WE TAGGED WHILE RIH. .~ 3H-16A, Rotary & Coil Tubing D..",ng Page 3 ~ 03/06/02 MILLED TO 9690' CTM (APPROX. 9708' RKB) WI 2.80" DIAMOND SPEED MILL I 2-1/8" WEATHERFORD MOTOR. NEVER SAW ANY CLEAR INDICATION OF EXITING SHOE. UNABLE TO MILL DEEPER OR STALL MOTOR, APPEARED TO BE SITTING AND SIMPLY SPINNING MOTOR WIO ANY MOTOR WORK. HAD DIFFICULTIES PUTTING SUFFICIENT WOB. INSPECTION OF MILL SHOWED WEAR ON CENTER BUTTONS, SLIGHT WEAR ON REMAINDER. MONITORED SITP FOR 1 HOUR ONCE OOH, 0 PRESSURE. INCREASE. WELL LEFT LOADED WI SW, DIESEL CAP TO 2500'. 03/15/02 WELLHEAD PRESSURE TEST PRE CTD. 04/23/02 DRIFTED TUBING 2.735" TO 9515' RKB. MEASURED BHP AT 9529' RKB: 3569 PSI. SET 2.81" X PLUG AT 8844' RKB. TOP EXIT OV SET AND TESTED AT 8789' RKB. 04/24/02 SET AND TESTED GLVS AT 3492',5577',7005' AND 8028' RKB. PULLED 2.81" X PLUG AT 8844' RKB. 04/25/02 POT-T PASSED, PPPOT-T PASSED. /~--...., .~ Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 3H-16 3H-16 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Start: 2/23/2001 Rig Release: 4/20/2002 Rig Number: Spud Date: 4/9/2002 End: 2/22/2001 17:00 - 00:00 7.00 RIGU P PRE RU to install new piping and drilling choke maifold 2/23/2001 00:00 - 00:00 24.00 CONS P PRE Fab new mud manifold and standpipe manifold lines. RU DOD choke assy. Cut return lines and install choke assy 2/24/2001 00:00 - 00:00 24.00 CONS P PRE Continue installation of mud manifold, pump lines, and drilling choke manifold. 2/25/2001 00:00 - 16:00 16.00 CONS P PRE Installed new circulating piping. 16:00 - 21 :30 5.50 CONS P PRE Wait on Xray crew. 21 :30 - 00:00 2.50 CONS P PRE X-ray welds. 2/26/2001 00:00 - 03:30 3.50 CONS P PRE X-Ray welds 03:30 - 05:00 1.50 CONS P PRE RU test pump, PT new mud line, leak in pipe at 1500 psi. 05:00 - 17:00 12.00 CONS P PRE Remove old line, install same and X-Ray. 17:00 - 20:30 3.50 CONS P PRE Wait on X-Ray results. 20:30 - 00:00 3.50 CONS P PRE X-Ray welds. 2/27/2001 00:00 - 05:00 5.00 CONS P PRE X-Ray welds-Mag Particle welds 05:00 - 07:00 2.00 CONS P PRE Wait on Xray results 07:00 - 11 :30 4.50 CONS P PRE PJSM, Tested MP to 4800 psi, PT mud line to 250 psi and 7500 psi. 11 :30 - 12:00 0.50 CONS P PRE Blow down mud lines, Freeze protest test pump 12:00 - 13:00 1.00 CONS P PRE Prepare to mobilize CTD unit to Kuparuk. 13:00 -14:00 1.00 CONS P PRE Wait on security escort. 14:00 - 00:00 10.00 CONS P PRE Mobilize CTD unit, S-pad turn off at 00:00 hrs. 2/28/2001 00:00 - 06:00 6.00 MOB P PRE Mobilization of Nordic CTD to Kuparuk 3H-16a, West Eleen Exit 06:00 - 23:30 17.50 MOB P PRE Travel from West Eleen Exit to Kuparuk 3H-16a location (331/2 hrs) 23:30 - 00:00 0.50 MOB P PRE Spot rig on location and relax jacks. 3/1/2001 00:00 - 07:00 7.00 RIGU P PRE Rig on Standby at midnight. Installing hydraulic choke, and extension to mousehole. 07:00 - 08:30 1.50 RIGU P PRE Pre spud meeting at CPF-3 with CPF3 supervisor, lead tech, PE. 08:30 - 09:00 0.50 RIGU P PRE Pre move in walk around with the 3H pad operator. 09:00 - 14:00 5.00 RIGU P PRE Continue rigging up hardline to new chokes, and welding mousehole extension. 14:00 - 15:50 1.83 RIGU P PRE 6" pipe on location for mousehole extension. Continue fabracating hardline. 15:50 - 00:00 8.17 RIGU P PRE Hardline trailor on location, continue with mousehole modifications and choke rig up. 3/2/2001 00:00 - 01 :00 1.00 RIGU P PRE Finish RU Choke manifold, wait on tree sppol 01 :00 - 02:40 1.67 RIGU P PRE Install tree spool, Shut 3H 28 in and move CTD unit over well 02:40 - 08:00 5.33 RIGU P PRE NU BOPE and associated outside equipment, Placed 3H 28 back on production. Rig accepted at 0300 hrs 3-2-01 AOGCC John Crisp Wavered witnessing BOP test 08:00 - 12:00 4.00 RIGU P PRE Swab valve leaking, call for grease crew. Also, request that CPF3 SI and Freeze protect 3H-28. It is too close to rig, and there is a hazard if it remains on production. 12:00 - 14:00 2.00 RIGU P PRE Grease Crew on location, grease master and swab valves. 14:00-21:15 7.25 RIGU P PRE Resume BOP testing. Valves holding. Also, 3H-28 shut in and FP'd with 60/40. Master closed, VR plug set in AI valve. Pressure bled off of AI line. Needle valves taken off of control lines and blocked. Not possible to rig up BPV due to rig over well, no clearance for lubricator. 21:15-21:34 0.32 RIGU P PRE Held JSA on removing BPV 21 :34 - 00:00 2.43 RIGU P PRE RU and remove BPV WHP at 650 psi (air). Tried 5 times to Printed: 4/221.2002 11:43:21 AM ,~ ,~ Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 3H-16 3H-16 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Start: 2/23/2001 Rig Release: 4/20/2002 Rig Number: Spud Date: 4/9/2002 End: 3/2/2001 21 :34 - 00:00 2-43 RIGU P PRE retrieve BPV and was unable to retrieve. 3/3/2001 00:00 - 01 :00 1.00 RIGU P PRE Load CT with seawater to cleanup on top of BPV, Cleaned up on top of BPV at 2.8 bpm at 2500 psi 01 :00 - 02:00 1.00 RIGU P PRE Retrieve BPV, RD BPV crew 02:00 - 02:35 0.58 RIGU P PRE JSA concerning Wireline and pressure deployment of BHA 02:35 - 06:00 3-42 RIGU P PRE RU WL machine and PU BHA#1 Working to space out tool string with 60 ft lubricator 06:00 - 08:30 2.50 RIGU P PRE Waiting on additional jt of lubricator from service unit #2. 08:30 - 11 :30 3.00 RIGU P PRE Lubricator on location. Hold Pre deployment safety meeting and process review. 11:30 -16:00 4.50 RIGU P PRE First pressure deployment. BHA #1, with 2.72" PDC bit, 0 deg motor and complete MWD/pressure package. Deployment went very good. Two minor problems to be rectified. 16:00 -18:30 2.50 RIGU P PRE Run in hole with BHA #1.Tagged and stall PDC at 8773' 18:30 - 19:20 0.83 RIGU P PRE Drilling weak cement from 8773' Taking lots of wt to get it to drill, Pumping 5 bbl biozn pills as sweeps 19:20 - 23:00 3.67 RIGU P PRE Drilling cement, Wt at 1300# to 500# as seen on wt indicator. At 2300 hrs, PDC at 8874' 23:00 - 00:00 1.00 RIGU P PRE Drilling Cement from 8874' Fell out of hard cement at 8880'. W/R in the hole to 8900' Some hard cmt stringers. Qp = 1.7 bpm at 2900 psi offbtm pressure 3/4/2001 00:00 - 00:18 0.30 RIGU P PRE Stall at 8925' Drilling cement 00:18-01:00 0.70 RIGU P PRE PUH at 8928' and pump Biozan sweep, RIH stall at 8889', PU, RIH. Stall at 8907' PU, RIH. Having trouble getting back to bottom at 8928' 01:00 - 01:25 0.42 RIGU P PRE Drilled cement to 8943' 01:25-02:15 0.83 RIGU P PRE Circulate wellbore clean Qp = 1.7 bpm at 3100 psi 02:15 - 03:51 1.60 RIGU P PRE Back to drilling cement. Sweep at 8966' 03:51 - 04:30 0.65 RIGU P PRE Pump 5 bbl sweep at 9011' Drilling cement, Wt at 700# 04:30 - 05:15 0.75 RIGU P PRE Pump 2-5 bbl biozan sweeps. Driling cement, stacking, working CT to keep from stacking 05:15 - 06:00 0.75 RIGU P PRE Drilling cement (negative string wt at times) Qp = 1.7 bpm at 3027 psi. 5 bbl sweep at 9027' 06:00 - 07:45 1.75 RIGU P PRE 07:45 update. 9040', Drilling hard cement. 1.6 bpm, 1 for 1 returns, 2640 psi tubing pressure. Milling cement at 20 fph. Pumping 5 bbls bio sweeps every 50 bbls. 07:45 - 08:30 0.75 RIGU P PRE 08:30 Update. 9051', Drilling hard cement. 1.7 bpm, 1 for 1 returns, 2750 psi CTP. 08:30 - 09:30 1.00 RIGU P PRE 09:30 Update. 9084', Picking up for a short trip to top of cement. Clean pickup. Up weight=26klbs. 09:30 - 10:30 1.00 RIGU P PRE 10:30 Update. 9106',1.7 bpm, 1 for 1 returns. ROP about 40 fph. 10:30 - 11 :30 1.00 RIGU P PRE 11:30 Update. 9133',1.7 bpm, 1 for 1 returns, ROP 23fpm. 11 :30 - 11 :50 0.33 RIGU P PRE Continue milling. 11:50-12:10 0.33 RIGU N STUC PRE 9134', Stalled, picked up 15', got bit stuck on pickup. PuIIlSlackoff/Pull, no success. Pumps down, can't get free. Pull up, can't pump. Stuck at 9124'. 12:10 - 12:20 0.17 RIGU N STUC PRE Need to establish circulation, or freeze coil, attempt to rupture burst disk. Pressured coil up to 4500 psi, and got circulation back. Attempt to pick up, pull free, stuck again at 9107'. CTP up to 4500 psi. Trips kept tripping. Unable to reach 5100 psi (Shear disk set pressure). We need the ability to exceed 5000 psi to shear burst disk in disconnect, and can not do it! Printed: 4/22/2002 11 :43:21 AM ,~, .~ Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 3H-16 3H-16 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Start: 2/23/2001 Rig Release: 4/20/2002 Rig Number: Spud Date: 4/9/2002 End: 3/4/2001 12:20 - 12:50 0.50 RIGU N STUC PRE Established circulation again, still stuck. Motor free, burst disk has apparently not ruptured. Motor spinning. pumping at 1.1 bpm, 2926 psi. Pump 8 bbls 3# bio sweep. Bio in coil, pumping at 1.3 bpm, 3900 psi CTP, 1 for 1 returns. 12:50 - 13:15 0.42 RIGU N STUC PRE Sweep 8 bbls of bio around BHA, work pipe. Still stuck. Can't go up or down. Apply WHP with choke. Attempt to pressure up backside to 2000 psi. Still stuck. 13:15 - 14:30 1.25 RIGU N STUC PRE Circulate while forming plan. Perform stretch calculation on DP. Found stuck calculations showing stuck at 1983'. (Cameo TRDP SSSV at 1803'). Possibly stuck on cement chunks in SSSV? Checked SSSV control line pressure. Is at 5500 psi. Checked gauge on control line. Gauge good. SSSV did not bleed shut. Still stuck. 14:30 -16:00 1.50 RIGU N STUC PRE Call for acid pumpers from DS. Call for hardline crew from APC, with choke skid and shower trailer. Contact acting BP CTD superintendent, contact Ted Stagg BP Engineer and Dan Venhaus Phillips Engineer. 16:00 - 17:30 1.50 RIGU N STUC PRE Hard line crew on location, begin rigging up Tiger tank, choke skid and hard line. Rigging up hard line directly to tree. Bypassing all rig piping. Will take returns directly to tiger tank crosswind from the rig. 17:30 -18:15 0.75 RIGU N STUC PRE DS pumpers here with acid. 10 bbls of 15% HCL. Waiting on hardline rig up, and hot water Vac truck. 18:15 - 19:30 1.25 RIGU N STUC PRE Pumped 10 bbl Biozan and worked CT 64k to -5k, Some CT movement Pumped 2 10 bbl pills and recovered small particles of cement 19:30-21:19 1.82 RIGU N STUC PRE Wait on Vac truck with fresh water 21:19-21:30 0.18 RIGU N STUC PRE Mix neutralizer in Vac truck and put in frac tank 21:30 - 21:50 0.33 RIGU N STUC PRE Held JSA on pumping acid and flow back hazards. 21 :50 - 22:30 0.67 RIGU N STUC PRE PT frac tank surface lines and RU to spot acid. Bleed IA P down from 450 psi to 100 psi. 22:30 - 22:50 0.33 RIGU N STUC PRE PT DS surface lines to 3500 psi. Pump 2 bbl water, 10 bbl 15% HCL wit H2S scavenger A255, 2 bbl water, SD DS and switch to Biozan 10 bbl pill Qp= 1.5 bpm @ 3800 psi. 22:50 - 23:05 0.25 RIGU N STUC PRE Pumped a total of 43 bbl (1 outside) SD 23:05 - 23:15 0.17 RIGU N STUC PRE Allow 1 bb115% HCL to soak 23:15 - 23:25 0.17 RIGU N STUC PRE Pumped 1/2 bb115% HCL and allow acid to soak with -8.4k down 23:25 - 23:40 0.25 RIGU N STUC PRE Pump 1/2 bb115% HCL (2 bbl outside) Work CT 23:40 - 23:55 0.25 RIGU N STUC PRE Pumped 1/2 bb115% HCL (2-1/2 outside) Allow to soak 23:55 - 00:00 0.08 RIGU N STUC PRE Pump 1/2 bb115% HCL (4 outside) 3/5/2001 00:00 - 00:10 0.17 RIGU N STUC PRE Allow 15% HCL to soak (4-1/2 bbl outside) 00:10 - 00:20 0.17 RIGU N STUC PRE Pumped 1/2 bbI15%HCL (5 outside) and work CT between 64kto-10k 00:20 - 00:30 0.17 RIGU N STUC PRE Pump 1/2 bb115% HCL (5-1/2 bbl outside) 00:30 - 00:45 0.25 RIGU N STUC PRE Pumped 1/2 bb115% HCL (6 bbl outside) Worked CT 00:45 - 00:55 0.17 RIGU N STUC PRE Pump another 1/2 bbl and work CT 00:55 - 01 :05 0.17 RIGU N STUC PRE Pump 1 bbl (temperature) 7-1/2 bbl outside 01:05 - 01:20 0.25 RIGU N STUC PRE Pumped 1/2 bbI15%, work CT 01:20 - 01:35 0.25 RIGU N STUC PRE Pump 1/2 bb115% HCL, 8-1/2 bbl outside 01:35 - 01:54 0.32 RIGU N STUC PRE Pump 1/2 15% HCL, 9 bbl outside, Work CT 01 :54 - 02:15 0.35 RIGU N STUC PRE Pump 1/2 15% HCL 9-1/2 bbl outside Work CT 02:15 - 02:36 0.35 RIGU N STUC PRE Pumped 1/2 bbl, (10 outside) no movement, Inc Qp to 1.5 bpm Printed: 4/22/2002 11 :43:21 AM ,~ :---'" Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 3H-16 3H-16 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Start: 2/23/2001 Rig Release: 4/20/2002 Rig Number: Spud Date: 4/9/2002 End: 3/5/2001 02:15 - 02:36 0.35 RIGU N STUC PRE and work CT at higher flowrate. Place CT fishing tools in pipe shed 02:36 - 03:10 0,57 N STUC PRE Transfer spent 15% acid to frac tank with 50 bbl neutralizing fluid, Qp = 1 bpm @ 1700 psi, Vp = 41 bbl to frac tank. 03:10 - 03:45 0.58 RIGU N STUC PRE Drop (5/8") ball to open Cir sub @ 1.5 bpm, Vp= 40 bbl open CS 03:45 - 04:08 0.38 RIGU N STUC PRE Cir and drop HDC ball (3/4") TOF at 9021' and BOF @ 9103', Len of fish = 80' 04:08 - 04:30 0.37 RIGU N STUC PRE Displace 3/4" ball to disconnect Vp = 36 bbl Pressure up to 4500 psi, Worked CTP up to 5000 psi and disconnect from BHA, TOF at 9021' 04:30 - 05:45 1.25 RIGU N STUC PRE POOH with CT 05:45 - 06:00 0.25 RIGU N STUC PRE OOH and stand back injector head, PU BOT BHA #1 2.25 "GS" 06:00 - 06:45 0.75 RIGU N STUC PRE Make up fishing BHA G spear, UID jars, accelerator, wt bars. 06:45 - 08:25 1.67 RIGU N STUC PRE RIH BHA #2, to fish motor and MWD. 08:25 - 09:20 0.92 RIGU N STUC PRE 8950', Weight check up=23klbs. Kick on pumps at 1.4 bpm, CTP=2930 psi. Stab into top of fish ok. SI pumps, pick up to 30k Ibs. Confirm that we are in fish. Commence down jarring. Cocking jars to 30klbs. Stacking -7000 Ibs on jars for down lick. 09:20 - 10:05 0.75 RIGU N STUC PRE Hit 50 down jar licks with no observed movement. Begin hitting up licks. Start at 10k over (neutral wt = 24k Ibs) hit 5 licks, go to 15k over hit 10 licks, go to 20k over hit 6 licks pulled free. Up weight now 26k Ibs, was 23k at initial check. Appears to have pulled fish free. 10:05 - 12:00 1.92 RIGU N STUC PRE POOH 12:00 -12:30 0.50 RIGU N STUC PRE Check for fish. Did not recover. Will RIH with same tool string to see if we can grab it again. 12:30 - 14:00 1.50 RIGU N STUC PRE RIH with same BHA to attempt fishing. 14:00 - 14:27 0.45 RIGU N STUC PRE Weight check at 9000'=24klbs. Pick on pumps, wash down onto fish. SI pumps, tag top of fish at 9036'. SI pumps, pick up. Did not get a good indication of fish. PU tag three times. No overpulls. Tag again, pick up to neutral wt. Let jars bleed open. POH. UP wt=27klbs. 14:27 -15:40 1.22 RIGU N STUC PRE POOH. 15:40 - 16:20 0.67 RIGU N STUC PRE Tag up at surface, rig down lubricator, no fish recovered. 16:20 - 20:30 4.17 RIGU N STUC PRE Call town, make plan forward. Call for slickline unit to run LIB and take picture of fishing neck. Waiting on slickline unit. 20:30 - 23:00 2.50 RIGU N STUC PRE RU WL and RIH and tagged the tubing hanger, POOH and slushie. 23:00 - 00:00 1.00 RIGU N STUC PRE RD WL and RU CT to RIH and warm up tubing RIH to 1000' and circulated wellbore warm. 3/6/2001 00:00 - 03:00 3.00 RIGU N STUC PRE RU WL and RIH with 2.7 LIB. Tagged LIB at 9067' POOH and review impression. 03:00 - 04:30 1.50 RIGU N STUC PRE PU nozzle and RIH to turn well over to new fluid and FP top 2000' while waiting on way forward from town 04:30 - 05:10 0.67 RIGU N STUC PRE Circulate clean seawater to nozzle. 05:10 - 06:30 1.33 RIGU N STUC PRE Seawater to nozzle, POOH laying in water at 50%. 06:30 - 08:00 1.50 RIGU N STUC PRE Standby at 2000', circulating seawater, waiting on town. 08:00 - 18:00 10.00 RIGU N STUC PRE Decision made to use burn over shoe to dress top of fish, and continue fishing. Notify Baker TT. Waiting on eq from Deadhorse to be fabricated and delivered. Held dynamic choke class. Simulated several well control issues. Functions Printed: 4/221.2002 11:43:21 AM ..~ ~ Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 3H-16 3H-16 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Start: 2/23/2001 Rig Release: 4/20/2002 Rig Number: Spud Date: 4/9/2002 End: 3/6/2001 08:00 - 18:00 10.00 RIGU N STUC PRE properly 18:00 -19:00 1.00 RIGU N STUC PRE PU washouver BHA 19:00 - 20:36 1.60 RIGU N STUC PRE RIH with Burn shoe BHA wt check at 8900' = 24k 20:36 - 20:55 0.32 RIGU N STUC PRE Tagged TOF at 9041.1 with 1000# down. PUH to 9026.1 and painted flag 20:55 - 22:00 1.08 RIGU N STUC PRE Start Pump, WR to top of fish Tagged the top of the fish at 9038.3' Qp = 1.1 bpm 1343 psi. Pressure inc to 1458 psi. Washed from 9038.3 ' to 9043.2' (4.90' is the bottom out depth). Washed over fish 2nd time at 1.5 bpm and tagged the stop at 9043.2' (Pressure inc to 1600 psi. Pumped 7 bbl biozan sweep during this operation. 22:00 - 23:30 1.50 RIGU N STUC PRE POOH. 23:30 - 00:00 0.50 RIGU N STUC PRE Change out BHA. Severe wear to outside of wash over pipe, Spiral grooves cut into wall over total length of pipe, indicating tubing problems at depth of fish. Bottom 8 tattel tells were broken inside wash over pipe, indicating pipe was over fish. 3/7/2001 00:00 - 00:10 0.17 FISH N STUC DECaMP M/U fishing BHA with Baker overshot and grapple. 00:10 - 02:00 1.83 FISH N STUC DECaMP RIH with fishing BHA. Correct to Flag, [ + 1 ft]. 02:00 - 02:50 0.83 FISH N STUC DECaMP Sat down on fish 3 times, latch on fourth try. Jar up with 10K over, 10 times. Jar up with 15K over, 5 times. Jar up with 20K over, 5 times. 02:50 - 03:10 0.33 FISH N STUC DECaMP Jar up and overshot released from fish. Attempt to re-Iatch 4 times with no success. 03:10 - 05:00 1.83 FISH N STUC DECOMP POOH to inspect overshot and grapple. 05:00 - 08:30 3.50 FISH N STUC DECaMP At surface, grapple left in hole, bowl that holds grapple swelled allowing grapple to pull out. Baker trying to assemble another overshot and grapple. 08:30 - 09:00 0.50 FISH N STUC DECaMP PU as wit 2-125" Sprial grapple. Stab injector 09:00 - 10:30 1.50 FISH N STUC DECaMP RIH with as 10:30 - 10:45 0.25 FISH N STUC DECaMP Wt check at 8990' = 23.9k. Tagged top of Fish at 9041.8' Latch up. Jarred 12 times at 25k over, jars shaking the rig. On hit 12, pulled off fish. 10:45-11:54 1.15 FISH N STUC DECaMP POOH to look at as. Informed town of Jarring results. 11:54-12:15 0.35 FISH N STUC DECaMP Stand back injector, Look at as 12:15 -12:30 0.25 FISH N STUC DECaMP PU Hip-Tripper BHA 12:30 - 14:08 1.63 FISH N STUC DECaMP RIH with Hip Tripper BHA 14:08 - 15:00 0.87 FISH N STUC DECOMP Hip Trippin using 1.3 bpm at 3600 psi 13000# WOHT 15:00 - 16:00 1.00 FISH N STUC DECaMP POOH to FP tubing Stopped at 2000' pumped 20 bbl MEOH and then POOH laying in 1:1 16:00 -17:10 1.17 FISH N STUC DECaMP OOH and LD BHA 17:10-21:00 3.83 FISH N STUC DECaMP Clean rig pits. 21 :00 - 22:00 1.00 FISH N STUC DECaMP Cut off 15 ft of CT. Weld on new CT connector. 22:00 - 23:00 1.00 FISH N DECOMP Safety Meeting. Viewed Kuparuk Safety video and took test, 6 people. 23:00 - 00:00 1.00 FISH N STUC DECaMP Rig down hard line to tiger tank, move tank, move berm, vac green tank. 3/8/2001 00:00 - 02:00 2.00 FISH N STUC DECaMP N/D BOPE. 02:00 - 03:00 1.00 FISH N STUC DECOMP N/U tree cap and press test. Reverse pump 3 bbls MEOH into CT. Blow down kill and choke lines. Freeze protect mud line with MEOH. RELEASED RIG AT 03:00 HRS, 03/08/01. 03:00 - 00:00 21.00 MOB N WAIT PRE Rig on Standby, Wait to move rig until well prep is more Printed: 4/22/2002 11 :43:21 AM , ,.-., ,~, Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 3H-16 3H-16 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Start: 2/23/2001 Rig Release: 4/20/2002 Rig Number: Spud Date: 4/9/2002 End: 3/8/2001 03:00 - 00:00 21.00 MOB N WAIT PRE complete on 3K-221 well. Printed: 4/22/2002 11:43:21 AM .~ ~. Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 3H-16 3H-16 ROT - SIDETRACK n1433@ppco.com Nordic 3 Start: 11/14/2001 Rig Release: Rig Number: 3 Spud Date: 11/16/2001 End: Group: 11114/2001 12:00 - 00:00 12.00 ABANDI\ OTHR MOVE 11/15/2001 00:00 - 02:00 2.00 MOVE POSN MOVE 02:00 - 06:00 4.00 MOVE RURD MOVE 06:00 - 07:30 1.50 ABANDI\ OTHR ABANDN 07:30 - 10:00 2.50 ABANDI\ SFTY ABANDN 10:00 - 12:00 2.00 ABANDI\ NUND ABANDN 12:00 - 15:00 3.00 ABANDI\ NUND ABANDN 15:00 -18:30 3.50 WELCTL BOPE ABANDN 18:30-19:00 0.50 RIGMNT RGRP ABANDN 19:00 -19:30 0.50 ABANDI\ TRIP ABANDN 19:30 - 20:30 1.00 ABANDI\ PULD ABANDN 20:30 - 00:00 3.50 WAlTON EQIP ABANDN 11/16/2001 00:00 - 02:30 2.50 ABANDI\ PULD ABANDN 02:30 - 05:30 3.00 ABANDI\ TRIP ABANDN 05:30 - 09:00 3.50 ABANDI\ TRIP ABANDN 09:00 - 12:00 3.00 ABANDI\ OTHR ABANDN 12:00 - 17:00 5.00 ABANDI\ TRIP ABANDN 17:00 - 20:00 3.00 ABANDI\ CIRC ABANDN Moving from 1F-16a to 3H-16A, incomplete, Rig not accepted. Rig on location @ 0030 hrs. Set liner over rig footprint, set in matts & load tree in cell a r. . Spot & level rig, berm up around cellar, ru h ard lines, pull vr plug, bp valve. Ru cir line s for displacement to aux tnk. pt lines wi a ir to 120 psi. NOTE: rig accepted @ 0230 hrs. Service rig, slip, cut drlg line & load pits wi sea water. NOTE: Held ops I planning meeting 0700 hrs PJSM [well kill I circulation of well to sea w ater]. Displace well wi 400 bbl sw @ 6 bpm 11170 psi. Si & monitor for 15 min well st a ti c. RD hard lines & circulation lines. Set bp va Ive, nd tree. Threads worn on hanger [order out spear for pulling hanger I tbg]. Nu bope. Change lower pipe rams from 2 7 18" to 3 1/2". Test bope low I high 250 I 4000 psi, annular 2500 psi high. Retrieve Bp valve. Noted hydraulic leak in upper pipe ram hing e pin. Close blind rams. Replace O-Ring in upper hinge block. Make up spear forcatc hing tbg below hanger. Open pipe rams. Rih wi spear dressed for 3.5" x 9.6 ppf tbg, catch tbg, pu to 114 Ibs @ tbg. Tbg stuck, work tbg 15 minutes. Ld spear, mu Idg it to damaged hanger. clo se pipe rams & install open tiw valve in tbg Wo wire line unit. Terminate .230" e-line. Make surfacem che cks on firing system for gun. PJSM Make up string shor, rih wi 10" strin g shot loaded wi 30' of 80 gr rdx primer cor d & shoot 9031 - 9041'. Rih wi 2.31" Chemical cutter, stacked out @ sssv [1803']. Pooh Confirm id of sssv frac sleeve 2.31" from part # . NOTE: Ops I planning meeting held @ 0715hrs Pu 2.25" chern cutter. Parts had been pirat ed from rebuild kit & not possibe to build up shooting system, this is a size cutter no st ocked & replace parts not available. Order out 2.125" chern cutter. PJSM RIH wi 2.125" chern cutter to locate c ut @ 9035'. Cut & pooh wi tools, no surf ind i of shot - good indication in sch unit. Work pipe up to 114k Ibs sgtring over pull. Printed: 111812002 8:40:59 AM ~ ".-.., Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 3H-16 3H-16 ROT - SIDETRACK n1433@ppco.com Nordic 3 Start: 11/14/2001 Rig Release: Rig Number: 3 Spud Date: 11/16/2001 End: Group: 11116/2001 17:00 - 20:00 20:00 - 23:00 3.00 ABANDI\ CIRC ABANDN 3.00 WELCTL EaRP ABANDN 23:00 - 00:00 1.00 WELCTL EaRP ABANDN 11/17/2001 00:00 - 02:00 2.00 ABANDI\ RURD ABANDN 02:00 - 06:00 4.00 ABANDI\ CUTP ABANDN 06:00 - 06:30 06:30 - 07:30 07:30 - 08:30 08:30 - 09:00 09:00 - 19:30 19:30 - 20:00 20:00 - 00:00 11/18/2001 00:00 - 02:30 02:30 - 04:00 04:00 - 09:00 09:00 -11:30 0.50 ABANDI\ PULD ABANDN 1.00 ABANDI\ TRIP ABANDN 1.00 WELCTL BOPE ABANDN 0.50 WELCTL TRIP ABANDN 10.50 WELCTL TRIP ABANDN 0.50 ABANDI\ TRIP ABANDN 4.00 ABANDI\ TRIP ABANDN 2.50 ABANDI\ TRIP ABANDN 1.50 ABANDI\ CIRC ABANDN 5.00 ABANDI\ TRIP 2.50 ABANDI\ TRIP ABANDN ABANDN Cir hole due to freezing considerations duri ng time period. Sea water initial temp out = 38?F, final 50. Set bp valve. Nd bop, pu stack & set on st ump. R & R control line port, install contro I line & apply 5000 psi opening pressure to s s sv. Nu bop, pull bp valve, rigging up Sch as ops permit. Incomplete @ rpt time. Continue to ru sch wI 2.375" chem cutter & make surface checks. Rih wI 2.375" chem cutter [16" of gas grain generator], correlate & shoot in same locati on [9035'] as pervious shot wI 20k Ibs pick up. Good indication of shot on rig floor & i n unit. Pooh wI tools. Layout tools & rd Schlumberger. Cut good, pull hanger to floor & remove sss v control line, plugging port in hanger & low er hanger to well hd profile. Close pipe rams on 3.5" tbg & test break to low I high 250 14000psi 15 minuites [chart]. Bleed off pressure. Pooh laying down hanger & one jt 3.5" bt&c tbg. Ru to recover sssv control line. Pooh wI a total 239jts + 7.9' cut off [3.5" x bt&c] as per tally. Recovered 29 of 31 cabl e clamps [large # broken but recovered all sections]. No evidence of where the missin g 2 clamps had been sheared from string. D utchman shows one 180? radial cut 10" abov e good 360? cut. NOTE: Pre job & planni ng meeting @ 1600 hrs. Police floor & ru to run whipstock milling as smby as clean out tools. [lead, middle & upp er mill od, = 5.675 I 5.685 I 6.151", from Ie ad mill to upper mill full gage = < 8.0'] Bp will be set in csg passed wI 6.151" mill. Tih wI clean out assmby. Incomplete rpt Um e. Complete tih to tag td of 9026 rkb Nordic 3, correlates wI previous depth of cut @ 9035' Cir con @ td, work 6.157" mill across bp set ting area. [ initial temp out = 42?F, final 48 ] . Pooh wI clean out assembly. Make junk basket run [gage ring 5.875"] to t d of 9025' rkb Nordic 3, correlates wi previo us depth of 9035' based on original rkb dept h Doyan 14. NOTE: recovered 2 cable band s noted as missing when completion was pul led. Printed: 1/18/2002 8:40:59 AM ,""""', r--.; Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 3H-16 3H-16 ROT - SIDETRACK n1433@ppco.com Nordic 3 Start: 11/14/2001 Rig Release: Rig Number: 3 Spud Date: 11/16/2001 End: Group: 11/18/2001 11 :30 - 13:30 13:30 - 17:00 17:00 - 18:00 18:00 - 19:00 19:00 - 22:00 22:00 - 00:00 11/19/2001 00:00 - 00:30 00:30 - 02:30 02:30 - 03:00 03:00 - 08:30 08:30 - 09:30 09:30 - 11 :00 11:00 -18:00 18:00 - 19:30 19:30 - 20:00 20:00 - 21 :00 21 :00 - 00:00 11/20/2001 00:00 - 04:30 04:30 - 07:30 07:30 -10:00 2.00 ABANDf\ SURV ABANDN 3.50 ABANDf\ PLUG ABANDN 1.00 WELCTL OTHR ABANDN 1.00 WELCTL EaRP ABANDN 3.00 WELCTL EaRP ABANDN 2.00 WELCTL EaRP ABANDN 0.50 WELCTL EaRP PROD 2.00 DRILL PULD PROD 0.50 DRILL PROD TRIP 5.50 DRILL TRIP PROD 1.00 DRILL PROD 1.50 DRILL CIRC PROD 7.00 DRILL DRLG PROD 1.50 DRILL CIRC PROD 0.50 DRILL TRIP PROD 1.00 WELCTL OTHR PROD 3.00 DRILL PROD TRIP 4.50 DRILL PROD TRIP 3.00 DRILL OTHR PROD 2.50 DRILL PULD PROD Trip ccl w/ gr & log bottom 300' of hole for correlation. Trip Baker C.!. Bridge Plug & correlate to s et @ 9004' RKB Nordic 3. This is 22' below the collar above & 45' below the HRZ {@ 89 59'}. {When the whipstock is set this will pi ace the window @ 8987-8999'}. Test csg to 3000 psi / 30 min , initial press = 3030, final 3020 psi. Nd bops & set back. Replace 9 5/8" x 7" spool & replace packof f installing new spool. Test pack off / spool to 3000 psi /15 min [chart]. Nu 11 x 5k Bope. Set test plug & test bop b reak 250 /4000 psi 10 minutes. Retrieve tes t pi u g. Pull test plug & set wear bushing. Mu whipstock bha. Rih to mwd & upload sa me. Scribe tools. Pu / rih w/ remaining bha & conduct shallow test. Tih to 90' above bp [8915']. Mu tds to strin g. Bring on pump @ 5.8 bpm /1300 psi. Orient tool face to 75? left of high side. Ck up & down wts of 135K / 82k Ibs. RIH to tag bp @ 9009' [5' deep]. Set down 17k Ibs over st ring weight setting anchor. Ck set w/ 10k Ib s overpull. Set down 37k Ibs & shear tie in bolt. Pu to neutral wt of 120k Ibs. Disp hole 11.0 ppg gem mud @ 6.5 bpm /24 00 psi. Commence milling window @ 8991' { bottom of window @ 9003} Stage up gradually to 5.9 bpm / 2900 psi, 262 total rpms, 8 - 10 k ft-Ibs torque ,wob = 8-10k Ibs. Drill open hole 9003 - 9015' {5738' TVD}. Cir cond, work 6.151 mill trrough window 10 x + rotating & no-rotating. LD single, & drain up tds. Conduct F.!.T. to 13.0 ppg emw. Pumped 3 1 gallons fluid, recovered approx 25 gallons Calculations: EMW ={610psi / [5738 x .052]} + 11.0 ppg 2.0 + 11.0 = 13 ppg emw Pooh w/ milling string. @ end of circulati on Had recovered 160 of 156 cal Ibs of steel from milling ops. Complete tooh laying down de & organize for next bha. Flush stack, kill & choke lines-service top d rive-change out grabber dies & clean floor. Make up bha #3-upload mwd-orient bit to mw Printed: 1/1812002 8:40:59 AM !~ ~, Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 3H-16 3H-16 ROT - SIDETRACK n1433@ppco.com Nordic 3 Start: 11/14/2001 Rig Release: Rig Number: 3 Spud Date: 11/16/2001 End: Group: 11120/2001 07:30 - 10:00 10:00 - 14:00 14:00 - 23:30 11/21/2001 23:30 - 00:00 00:00 - 04:30 04:30 - 07:30 07:30 - 08:00 08:00 - 09:00 09:00 - 11 :00 11:00 -15:30 15:30 - 16:00 16:00 -16:30 16:30 - 21 :30 11/22/2001 21 :30 - 00:00 00:00 - 10:00 10:00 - 11 :30 11:30 -12:30 12:30 - 22:30 11/23/2001 22:30 - 00:00 00:00 - 00:30 00:30 - 01 :30 01 :30 - 03:30 03:30 - 12:00 12:00 - 15:00 15:00 - 19:00 11/24/2001 19:00 - 20:00 20:00 - 21 :00 21 :00 - 00:00 00:00 - 01 :30 01:30 - 12:00 12:00 - 15:30 2.50 DRILL 4.00 DRILL 9.50 DRILL 0.50 DRILL 4.50 DRILL 3.00 DRILL 0.50 DRILL 1.00 DRILL 2.00 DRILL 4.50 DRILL 0.50 DRILL 0.50 DRILL 5.00 DRILL 2.50 DRILL 10.00 DRILL 1.50 DRILL 1.00 DRILL 10.00 DRILL 1.50 DRILL 0.50 DRILL 1.00 DRILL 2.00 DRILL 8.50 DRILL 3.00 DRILL 4.00 DRILL 1.00 DRILL 1.00 DRILL 3.00 DRILL 1.50 DRILL 10.50 DRILL 3.50 DRILL PULD PROD TRIP PROD DRLG PROD TRIP PROD TRIP PROD PULD PROD OTHR PROD OTHR PROD PULD PROD TRIP TRIP PROD PROD OTHR PROD REAM PROD DRLG PROD DRLG PROD CIRC TRIP CIRC TRIP TRIP TRIP CIRC TRIP PROD PROD PROD PROD PROD PROD PROD PROD PULD PROD OTHR PROD OTHR PULD TRIP TRIP REAM CIRC PROD PROD PROD PROD PROD PROD d. RIH wI drlg. assembly. Orient-run thru window-drlg. & surveys from 9015' to 9260'. POH =MWD Failure-not reading surveys. POH wI BHA for MWD Failure. Download & lay down MWD-short in connecti ons between Iwd-mwd & pwd. Service rig & top drive-check saver sub. Slip & cut drlg. line. Pick up bha #4-orient motor-mwd & shallow t est same. RIH wI bha #4 to window @ Run thru window-tight spot top drive-wash pipe failure. Replace washpipe. RIH-tight @ 9110'-wash & work pipe to 9248' -packing off-tight-work back to shoe to reco ver circ.-tight @ shoe-work same loose & ri h to bottom after cleaning up hole. Drlg. from 9260 to 9331'. Drilling from 9331 to 9698' TD (5965' TVD) up wt. 120k dn wt. 65k-rot wt. 75k- torque 8 k ft. Ibs. Circ.-rotate & reciprocate while pumping sw eep around. POH to window slow-monitor well @ window- well flowing-rih to bottom-gain 20 bbls. No t ight hole in or out. Shut in well-180# on choke--circ. while brin ging mud wt. to 11.9#-recovered some forma tion water wI mud cut to 9.5 -Production inj ecting in well #3H-15-production lost some pressure when we had pit gain. POH -monitor well @ shoe. Pulling out of hole for hole opener. (hole no t taking right amount of fluid.) RIH to bottom. Circ. condition mud to 12.1# for 90# overbal an c e. POH for hole opener-hole swabbing-pull slo w-partialy pump out. Lay down bha-download mwd. Drain stack-pull wear ring-set test plug-test bope 250-4000#. Pull test plug-set wear rin g. Change out wash pipe & service rig. Make up hole opener assembly. RIH wI hole opener assembly. RIH wI hole opener. Wash & Ream hole from 9084' to 9696'-tight spots @ 9084'-9278'-9466' & 9450'. Pump sweep & circ. hole clean-Monitor well 8991' . @ 9110-make up POH to shoe. Printed: 1/18/2002 8:40:59 AM .f"'" .~. Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 3H-16 3H-16 ROT - SIDETRACK n1433@ppco.com Nordic 3 Start: 11/14/2001 Rig Release: Rig Number: 3 Spud Date: 11/16/2001 End: Group: 11124/2001 12:00 - 15:30 15:30 - 22:00 22:00 - 23:00 23:00 - 00:00 3.50 DRILL 6.50 DRILL 1.00 DRILL 1.00 DRILL CIRC PROD TRIP PROD PULD PROD RIRD PROD 11/25/2001 00:00 - 03:30 3.50 DRILL OTHR PROD 03:30 - 06:30 3.00 DRILL TRIP PROD 06:30 - 09:30 3.00 DRILL CIRC PROD 09:30 - 16:30 7.00 DRILL TRIP PROD 16:30 - 00:00 7.50 CASE RUNL PROD 11/26/2001 00:00 - 03:30 3.50 CASE RUNL PROD 03:30 - 04:30 1.00 CASE CIRC PROD 04:30 -11:00 6.50 CASE CIRC PROD 11/27/2001 11:00-13:00 2.00 CEMENT PUMP PROD 13:00 - 16:30 3.50 CEMENTCIRC PROD 16:30 - 17:30 1.00 CMPL TN TRIP PROD 17:30 - 19:30 2.00 CMPL TN TRIP PROD 19:30 - 20:00 0.50 CMPL TN OTHR PROD 20:00 - 00:00 4.00 CMPLTNTRIP PROD 00:00 - 02:00 2.00 CMPL TN TRIP PROD 02:00 - 03:00 1.00 CMPL TN OTHR PROD 03:00 - 06:00 3.00 CMPL TN RUNT PROD 06:00 - 07:00 1.00 CMPL TN OTHR PROD 07:00 - 13:30 6.50 CMPL TN RUNT PROD 13:30 - 16:30 3.00 CMPLTN CIRC PROD 16:30 - 17:30 1.00 CMPL TN SOHO PROD 17:30 - 19:30 2.00 CMPL TN DEOT PROD 19:30 - 22:00 2.50 CMPL TN NUND PROD 22:00 - 00:00 2.00 CMPL TN NUND PROD 00:00 - 01 :30 1.50 CMPL TN NUND CMPLTN 01 :30 - 04:00 2.50 CMPL TN FRZP CMPLTN 04:00 - 06:00 2.00 CMPL TN OTHR CMPL TN 11/28/2001 & spot pill on bottom. POH-swabbing-pump out. Lay down bha & send out. Clean floor-rig up to run liner. (while riggin g up-had 1.5 bbl. pit gain-well flowing-shut blinds-pressure built to 50#-called cpf 3-the y put injector well on @ 1900 hrs. -had them shut it down. Well pressure 50# on choke-Monitor same w hen production shut down injector well-blee d 6.5 bbls. thru choke & shut in-50# on chok e after 4 mins. shut in. RIH wI hole opener to 9698'. ( 8 bbls. gain while RIH.) Circ. @ 3.25 bpm wI no losses while recipro cate & rotate-circ. out influx. Monitor well. Well stable-pump out of open hole-poh & lay down bha. Rig up to pick up liner-PJSM-running liner i n h 0 Ie. Running 3 1/2' liner to 8900'. Circ. capacity of liner & dp-rig up cement h ead. Run liner to TD @ 9689 & circ.-condition hol e for cementing liner. Rotate & reciprocate I iner @ 20 RPM-98k up 87k down. Cement liner as per program-bump olug & se t hanger & packer-release from liner. Pull 10'-circ. out cement-recovered mud pus h & contaminated mud wI cement. PJSM-Mix & pump dry job. Laying down 3 1/2' dp. Safety meeting on pinch points. Laying down 3 1/2" dp. Laying down 3 1/2" dp. Pull Wear Ring & rig up to run completion. PJSM-Run completion as per program. Change crews=PJSM=Service rig. Finish running completion. Displace well to seawater & test same to 25 00# OK. Space out-make up hanger-tie in control line & set hanger. Test tbg. & annulus to 2500#-shear dcr val v e @ 2700#-rig down & install BPV. PJSM-Nipple down bope. Nipple up tree. Nipple up tree & test same to 5000#. Pull BPV-rig up & pump100 bbls. diesel to fr eeze protect well-U-Tube diesel. & rig down lines. Install BPV-rig down manifold-secure cellar & Release rig @ 0600-11-28-2001. Printed: 1/18/2002 8:40:59 AM ,~ .~ Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 3H-16 3H-16 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Start: 4/9/2002 Rig Release: 4/20/2002 Rig Number: Spud Date: 4/9/2002 End: 4/20/2002 4/612002 23:00 - 00:00 1.00 MOB P PRE On standby while converting rig to 2" coil + e-line for KRU drilling project. 4/7/2002 00:00 - 09:00 9.00 MOB P PRE On standby while converting rig to 2" coil + e-line for KRU drilling project. 09:00 - 10:00 1.00 MOB P PRE PJSM. Lower windwalls. 10:00 - 11 :30 1.50 MOB P PRE PJSM. Scope down & tilt down derrick. 11:30-12:00 0.50 MOB P PRE PJSM. Jack-up rig. Meanwhile move camp to 3H-16. 12:00 - 13:30 1.50 MOB P PRE Pull off well & move rig to edge of pad. 13:30 -14:00 0.50 MOB P PRE W.O. Security. 14:00 - 14:30 0.50 MOB P PRE Pre-move safety meeting with CPS, Security, Tool Services & Peak. 14:30 - 16:00 1.50 MOB N WAIT PRE W.O. Nordic-1 Superintendent blessing to move rig. Rig on zero rate. 16:00 - 00:00 8.00 MOB P PRE Move rig & equipment to KRU. 4/8/2002 00:00 - 06:30 6.50 MOB P PRE Continue moving rig to Milne point turnoff. Lower rig. 06:30 - 08:00 1.50 MOB P PRE PJSM. Tilt & scope up derrick. 08:00 - 09:00 1.00 MOB P PRE PJSM. Raise windwalls. 09:00 - 10:00 1.00 MOB P PRE PJSM. Retract tilt rams. 10:00 - 10:30 0.50 MOB P PRE PJSM. Raise rig. 10:30 -12:45 2.25 MOB N WAIT PRE Standby to allow access for Milne pt noon crew changes. 12:45 - 13:00 0.25 MOB P PRE Pre-move safety meeting with KRU Security. 13:00 - 17:00 4.00 MOB P PRE Move rig from Milne pt turnoff to KOC. 17:00 - 19:00 2.00 MOB P PRE Standby to allow access for crew changes. 19:00 - 00:00 5.00 MOB P PRE Continue moving rig to KRU 3H-16. 4/9/2002 00:00 - 03:30 3.50 MOB P PRE Continue moving rig to KRU 3H-16. 03:30 - 05:00 1.50 MOB P PRE Arrive 3H-16. Prep pad. Install cellar berm & adjust beaver slide. 05:00 - 10:30 5.50 MOB N WAIT PRE W.O. the installation of SSSV control panel. 10:30-11:00 0.50 MOB P PRE PJSM. Attempt to move-in rig over well. Observe IiiUle clearance between 3H-17 wellhouse and rig edge under the doghouse. Move-out rig & standby. 11:00-13:00 2.00 MOB N WAIT PRE W.O. the removal of adjacent well house. 13:00 - 13:30 0.50 MOB P PRE PJSM. Attempt to move-in rig over well. Observe platform on 3H-15 wellhead obstructing rig's beaver slide. Move-out rig & standby. 13:30 - 15:30 2.00 MOB N WAIT PRE W.O. the removal of adjacent well platform. 15:30 - 16:30 1.00 MOB P PRE PJSM. Move-in rig over well. Lower rig. 16:30 - 20:30 4.00 BOPSURP DECOMP Accept rig at operating rate at 16:30 hrs 4/9/021. NIU BOPE. Meanwhile spot & berm flowback tanks & slop tank. Prep for BOPE test. 20:30 - 00:00 3.50 BOPSURP DECOMP Perform initial BOPE pressure / function test. Swab and master valves leaked, so had grease crew grease lock valves again. 2" combi rams leaked, change out horseshoe seals. Press test to 4000 psi as per drilling permit. Jeff Jones of AOGCC witnessed BOPE testing. 4/10/2002 00:00 - 06:00 6.00 BOPSURP DECOMP Perform initial BOPE pressure 1 function test. Send test report to AOGCC. BOPE Test witnessed by Jeff Jones, AOGCC inspector. 06:00 - 12:15 6.25 RIGU P PRE BOP pressure test completed. All passed OK. Continue with RU operations. PU injector, MIU guide arch and stab pipe. 12:15 -13:45 1.50 RIGU P PRE Check insulation and continuity of internal wireline and check electrical collector. 13:45 -16:15 2.50 RIGU P PRE Build eline head. Printed: 6/51.2002 9:31:49 AM /"", ~ Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 3H-16 3H-16 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Start: 4/9/2002 Rig Release: 4/20/2002 Rig Number: Spud Date: 4/9/2002 End: 4/20/2002 4/10/2002 16:15-21:00 4.75 RIGU P PRE Install slickline machine. M/U lubricator pack-off and lifting slings. 21 :00 - 22:00 1.00 RIGU P PRE RIU line to reverse circulate coil for Eline slack management. 22:00 - 22:15 0.25 STWHIP P WEXIT SAFETY MEETING. Review reverse circulating procedure and safety considerations with all crew. 14 on sign in sheet. 22:15 - 00:00 1.75 STWHIP P WEXIT Reverse circulate and fill coil with FloPro. Reverse circulate 2 coil volumes, 80 bbls with 9.9 ppg FloPro. 2.6 bpm, 3600 psi. Tested BHI CoilTrak circ sub, open and closed with no problem. Used as surface test of electric disconnect. 4/11/2002 00:00 - 01 :30 1.50 STWHIP P WEXIT Cut off 165 ft of CT to find end of 5/8" E-Line after reverse circ. Installed new hard drive for DS main computer. 01 :30 - 02:00 0.50 STWHIP P WEXIT M/U BHI E-Line CTC. Frz Prot exposed CT with 2 bbls diesel. 02:00 - 05:30 3.50 STWHIP P WEXIT Pull test CTC with 20K. MIU BHI Quick connect [Electric XO] and test. M/U 60 ft lubricator with hyd packoff. Press test lubricator with 1500 psi. 05:30 - 08:30 3.00 STWHIP P WEXIT Pull test slickline with wt cell. 1000 Ibs at 115 psi air press. Pull mouse hole and cut off end cap, to allow use of rat hole for BHA make-up. M/U 5 ft riser below injecter head for BHA space out. 08:30 - 09:15 0.75 STWHIP P WEXIT Call for crew to pull BPV @ 08:30, continue to work on rat hole modification. 09:15 -10:30 1.25 STWHIP P WEXIT Safety meeting. Discuss pre job hazards unique to this will. Review pressure deployment proceedure in detail. 10:30-11:15 0.75 STWHIP P WEXIT Practice with SL equipment prior to picking up BHA. Measure length of SL eq. 11:15 -11:30 0.25 STWHIP P WEXIT Safety meeting with Valve crew prior to pulling BPV. 11:30-12:45 1.25 STWHIP P WEXIT Pull BPV. 12:45 - 13:20 0.58 STWHIP P WEXIT Pump 1 coil volume at 2.5 bpm down coil to complete second half of SWS slack management SOP. 13:20-14:15 0.92 STWHIP P WEXIT Pull VR plug from 7". 14:15 - 14:30 0.25 STWHIP P WEXIT Safety meeting prior to being deployment of BHA. 14:30 - 17:30 3.00 STWHIP P WEXIT Begin pressure deployment of milling BHA. 17:30 - 20:00 2.50 STWHIP N SFAL WEXIT BHA deployment aborted. No-Go plate hung up at every little upset change on BHA. Could not get jars or BHI power sub thru no-go plate. Examination of new No-Go plate shows it is significantly different than one used last year. Thin cross section with no bevel allows plate to fit into any OD change of BHA. Call Nabors 3S, and attempt to borrow old no-go and plate, no-go sized for larger ID lubricator. Manufacture new plate on rig with 6" long 3-1/8" ID profile to correct hang up problem. 20:00 - 21 :30 1.50 STWHIP P WEXIT Review Pressure Deployment Procedure with crew. Review hazards and mitigation. 21 :30 - 23:30 2.00 STWHIP P WEXIT Perform Pressure Deployment of Milling BHA #1. Flag slickline at 3 positions as per procedure. 23:30 - 00:00 0.50 STWHIP P WEXIT RIH with Milling BHA #1, 2.80" Parabolic diamond mill, straight motor and jars. pump 0.2 bpm, 520 psi. 4/12/2002 00:00 - 01 :30 1.50 STWHIP P WEXIT RIH with Milling BHA. WHP = 0 psi, indicating shoe is not milled thru. Printed: 61.51.2002 9:31 :49 AM r'- ,~ Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 3H-16 3H-16 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Start: 4/9/2002 Rig Release: 4/20/2002 Rig Number: Spud Date: 4/9/2002 End: 4/20/2002 4/12/2002 00:00 - 01 :30 1.50 STWHIP P WEXIT 01 :30 - 02:00 0.50 STWHIP P WEXIT 02:00 - 03:30 1.50 STWHIP P WEXIT 03:30 - 04:30 1.00 STWHIP P WEXIT 04:30 - 06:15 1.75 STWHIP P WEXIT 06:15 - 07:00 0.75 STWHIP P WEXIT 07:00 - 07:20 0.33 STWHIP P WEXIT 07:20 - 08:15 0.92 STWHIP P WEXIT 08:15 - 08:30 0.25 STWHIP P WEXIT 08:30 - 09:15 0.75 STWHIP P WEXIT 09:15 - 09:40 WEXIT 0.42 STWHIP P 09:40 - 11 :35 WEXIT 1.92 STWHIP P 11:35-12:15 0.67 STWHIP P WEXIT 12:15 -15:45 3.50 STWHIP P WEXIT 15:45 -16:15 0.50 STWHIP P WEXIT 16:15 - 17:20 1.08 STWHIP P WEXIT 17:20 - 17:30 0.17 STWHIP P WEXIT 17:30 -18:00 0.50 STWHIP P WEXIT 18:00 - 19:00 1.00 STWHIP P WEXIT 19:00 - 20:30 1.50 STWHIP P WEXIT 20:30 - 00:00 3.50 STWHIP N SFAL WEXIT pump 0.2 bpm, 500 psi. Up wt at 9000 ft = 27K, Dwn wt = 6K, RIH at 30 fpm, 1.5 bpm, 3100 psi, with FloPro all around. Tag PBTO at 9692 ft. Correct depth to 9698 ft. [+6']. Milling on 3-1/2" Baker Float Shoe. 500# WOB, 300 psi motor work, 1.5 bpm, 3500 psi. 3100 psi free spin. Inc. WOB slowly to 2000#. Milled to 9700 ft. Milled thru shoe at 9700 ft. Milling formation at 12 FPH. 2000# WOB, 1.5 bpm, 3380 psi, 3100 psi free spin. Order 300 bbls Formate FloPro. ROP at end of milling = 40 FPH. Milled formation to 9720 ft. Back Ream shoe track up thru float cllr at 9631 ft. No motor work. 1.5 bpm, 3000 psi. Ream down to TO clean. Back ream to 9625'. POOH to 9500 ft. Stop pump. Trap 430 psi WHP. RIH at 2 fpm, no pump. Wait on WHP to stabilize. Final WHP=528 psi. Safety meeting with choke operator, CT Driller, BHI hands. Discuss choke schedule, drilling and tripping techniques. Kick pumps on, precautionary ream float eq up and down a couple of times. No drag or motor work observed. Dry tag at 9720', no drag observed thru float eq. Shift circ sleeve on EDC to open position. Begin circulating thru circ sleeve. Wash float eq. to clean any debris while pumping at 2.0 bpm, 3300 psi. Also, practice co-ordination between CT driller and choke hand. Start mud swap. Taking clean used standard 10 ppg flo pro to clean vac truck for return to MI. Pumping 10.3 ppg Formate mud. Mud to bit, POOH with BHA #1. Some crude staining on mud at one point while POOH. Possibly from "practice" session between choke operator and CT driller. Also lost some mud during trip OOH. Possibly due to using 1000 psi as choke schedule final pressure. We will fine tune choke schedule for next trip OOH. Tag up at surface with BHA #1. Circ min rate. Position at deployment position. 2.5' down from tag up. Hold PJSM to discuss undeployment. Undeploy BHA #1 as per proceedure. Minor problems during recovery, nothing major. Practice makes perfect. Recovered all BHA. Mill and string reamer in gauge. (2.80") Repair "out" micro motion, calibrate and check. Work on slickline lubricator, rehead slickline. Remove tape from packoff and upper sheave. Brief safety meeting prior to picking up BHA #2. Begin making up BHA #2. Shut down for crew change and PJSM prior to continuing to deploy BHA #2. Load 200 BBL 12.1 PPG Kill Brine in upright tank. Pressure deploy CoilTrak BHA #2 with 1.0 deg motor and Bit #2. SIWHP = 400 psi. Surface test CoilTrak found short in BHA. Pressure Undeploy BHA. Inspect BHA. Found short somewhere in electric cable. Printed: 61.5/2002 9:31:49 AM ~ ,~ Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 3H-16 3H-16 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Start: 4/9/2002 Rig Release: 4/20/2002 Rig Number: Spud Date: 4/9/2002 End: 4/20/2002 4/12/2002 20:30 - 00:00 3.50 STWHIP N SFAL WEXIT Check collector at reel for short. Found end of conductor wire at collector bulkhead was flooded with KCL water from pumping E-Line into coil. About 2 drips per minute out of end of conductor wire. 4/13/2002 00:00 - 05:00 5,00 STWHIP N SFAL WEXIT KCL water dripping out of end of E-line copper multi-wire conductor. Water accumulation in boot at collector bulkhead caused short. Vac end of conductor while getting vacuum pump from DS shop. 05:00 - 06:30 1.50 STWHIP N SFAL WEXIT Rig up DS vacuum pump on end of conductor wire and pump vacuum on cable to draw out water. [-12 in HG, approx. 1/3 ATM, or -5 psi.] 06:30 - 10:00 3.50 STWHIP N SFAL WEXIT Vacuum continues to show water drops exiting cable. Contact DS Deadhorse office to confer with slope specialists. Review options. Continue to watch vacuum pump. Call for technician to come from Deadhorse to repair damaged electrical bulkhead. Continue to wait. 10:00 - 14:00 4.00 STWHIP N SFAL WEXIT Consultation with SWS in Deadhorse, on rig, and BHI rig hands. Best option of repairing situation as is, is with the rig personnel. Enlist BHI help in repairing SWS components. Begin installation of new pigtail to end of "wet" SWS eline. Had guidance of SWS eline specialist from eline unit working on 3C-04. Gave BHI and SWS-CT hands direction into possible fix without resorting to pumping more cable out of coil. 14:00 - 14:25 0.42 STWHIP N SFAL WEXIT Wet connect back together. Test electrically. BHI reports it is satisfactory. 14:25 - 14:40 0.25 STWHIP P WEXIT Safety meeting prior to completing tool deployment. 14:40 - 15:10 0.50 STWHIP P WEXIT Test tool at surface, Passed ok. 15:10 -15:30 0.33 STWHIP P WEXIT MU lubricator, PT, equalize, open rams. 15:30 - 16:00 0.50 STWHIP P WEXIT RIH to check BHA again. Shallow hole test at 200', Pumping at 1.5 bpm. As close to bottom hole conditions as we can make it. Cycle orienter. All BHA works ok. 16:00 - 17:40 1.67 STWHIP P WEXIT RIH with BHA #2. Our fingers crossed. 17:40 -17:55 0.25 STWHIP P WEXIT BHA continues to work, with the exception of pressure data. Evidently the downhole pressure informaiton does not work with the standard BHI surface computer software. They can read pressure with an alternate software. Downhole tool appears to be working. All other sensors working fine, ie tool face, gamma ray, azimuth, inclination. Continue RIH to get some drilling done. 17:55 - 18:45 0.83 STWHIP P WEXIT Log tie in pass down. Pump rate 0.3 bpm. Make -4' correction. RIH to 9600 ft. 18:45 - 00:00 5.25 STWHIP N SFAL WEXIT BHI software communication problems. Very slow information transfer between computers, unable to operate with present situation. BHI software engineer working on problem. 4/14/2002 00:00 - 03:30 3.50 STWHIP N SFAL WEXIT BHI working on computer communication problem. De-bugging software to enable interpretation of data from downhole. 03:30 - 04:45 1,25 STWHIP P WEXIT Tag TD at 9718 ft. Start drilling. Free spin = 3580 psi, 1.5 bpm, TF = lOR. 1000# WeB. 30-60 FPM. Drilled to 9753 ft. Stacking wt. Adding 1 % Lubetex to system for better weight transfer. Losing 0.1 bpm to formation. 88 deg incl. 04:45 - 06:00 1.25 STWHIP P WEXIT Drilling, TF = 70R, 1.5/1.3 bpm, 3800 psi, Wt transfer Printed: 61.51.2002 9:31:49 AM Î' ~. Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 3H-16 3H-16 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Start: 4/9/2002 Rig Release: 4/20/2002 Rig Number: Spud Date: 4/9/2002 End: 4/20/2002 4/14/2002 04:45 - 06:00 1.25 STWHIP P WEXIT problem. Adding Lubetex. Losing 0.2 bpm to formation. 90 deg incl. Drilled to 9786 ft. 06:00 - 07:30 1.50 DRILL P PROD1 Drilling at 110 fph, TF85R, 1.5/1.4/3840 psi. Better weight transfer with lubtex added. 07:30 - 08:25 0.92 DRILL P PROD1 9900', wiper trip to shoe. Clean pickup off bottom at 24000 Ibs. Pull to shoe at 30 fpm, and 1.5 bpm. At shoe open EDC, and pull to 9200'. 08:25 - 09:40 1.25 DRILL P PROD1 Begin logging pass down to capture data missing from gap between old wellbore and new. Note free spin with EDC open is 3050 psi. 09:40 -11:00 1.33 DRILL P PROD1 Resume drilling. Pit vol=281 bbls. 1.5/1.5/3850 psi. TF=120R. 11:00-12:40 1.67 DRILL P PROD1 9960', drilling 110 api rock. Geo reports we are on plan and Gamma is as expected. Pits=276 bbls. Lost 5 bbls in last 1 :20 hours. Have an additional 125 bbls on location. 12:40 - 13:40 1.00 DRILL P PROD1 10050', Wiper trip to shoe. Pit level 271 bbls. Lost 5 bbls in last 1 :40 hours. Play the EDC CS game at the casing shoe. Swap BHI computer to alternate mode, and check pressure tool. Ann press=3925 psi, Inn press=4136 psi, Depth=9840'. 13:40 -15:00 1.33 DRILL P PROD1 Resume drilling. Pit level 266 bbls. Lost 5 bbls in last hour while tripping. 1.5/1.4/3700, ROP 100 fph, Free spin down to 3400 psi. 15:00 - 16:00 1.00 DRILL P PROD1 10095', wiper trip to shoe to evaluate logs and confer with town. 16:00 -17:00 1.00 DRILL P PROD1 Resume drilling. TF 120R. Plan to drop angle, and reduce TVD. Town and slope geologist both in agreement. 1.5/1.5/3450 psi. Top pits off. ROP slowed down. Appear to be weight transfer problem. Pits vol=345. 17:00 - 18:00 1.00 DRILL P PROD1 Pump 30 bbls of 5% lubetex pill to see if ROP picks up. No change. Still difficult drilling. Drilled to 10,104 ft. 18:00 - 19:15 1.25 DRILL P PROD1 Make wiper trip up to 9200'. Open EDC CS at shoe. RIH to TD. 19:15 - 20:45 1.50 DRILL P PROD1 Drilling, TF = 100R, 1.5/1.4 bpm, 3460 psi, Drilling break at 10,104 ft. 100 fph for 12 ft and back to 20 fph, very thin sand not seen on GR. Back to slow drilling, 20 fph. Drilled to 10,158 ft. 20:45 - 23:00 2.25 DRILL P PROD1 Drilling, TF = 90R and 90L, 1.5/1.4 bpm, 3460 psi, 87 incl, Drilled to 10,270 ft. 23:00 - 00:00 1.00 DRILL P PROD1 Wiper trip to 9100', Clean hole. RIH to TD. 4/15/2002 00:00 - 02:00 2.00 DRILL P PROD1 Drilling, TF = 90L, 1.5/1.5 bpm, 3600 psi, 88 deg incl. Drilled to 10347' 02:00 - 04:00 2.00 DRILL P PROD1 Drilling, TF = 10L, 1.5/1.5 bpm, 3600 psi, 90 deg incl. Drilled to 10390' Slow drilling in shale, decide to drill back up thru A sand. 04:00 - 06:00 2.00 DRILL P PROD1 Drilling, TF = 80L, 1.5/1.5 bpm, 3600 psi, 93 deg incl. Drilled to 10415'. Drilling back up thru slow drilling shale. 06:00 - 07:00 1.00 DRILL P PROD1 10436', Update at 07:00 AM. 1.5/1.5/3780 psi. 93 deg, TF=280 deg. Pit vol=287 bbls. ROP 10-20 fph. 07:00 - 08:35 1.58 DRILL P PROD1 Continuing to drill. 1.5/1.5/3730 psi. TF 290. Pit vol=283 bbls. 08:35 - 09:30 0.92 DRILL P PROD1 10457', wiper trip to shoe. Clean PU off bottom at 21klbs. No drag or motor work on trip up. Open EDC CS at shoe. 09:30-11:15 1.75 DRILL C PROD1 POOH to pick up open hole side track BHA. Call for Smith bit. They do not make an M09 in 2.75". Call for 2.75" M07 bit. Printed: 61.51.2002 9:31:49AM r'"'.. l~ Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 3H-16 3H-16 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Start: 4/9/2002 Rig Release: 4/20/2002 Rig Number: Spud Date: 4/9/2002 End: 4/20/2002 4/15/2002 11:15-11:35 0.33 DRILL C PROD1 11 :35 - 11 :55 0.33 DRILL C PROD1 11:55-14:00 2.08 DRILL C PROD1 14:00 - 14:30 0.50 STKOH C PROD1 14:30 - 16:15 1.75 STKOH C PROD1 16:15 - 16:30 0.25 STKOH C PROD1 16:30 - 18:00 1.50 STKOH C PROD1 18:00 -18:30 0.50 STKOH C PROD1 18:30 - 19:30 1.00 STKOH X SFAL PROD1 19:30-20:15 0.75 STKOH C PROD1 20:15 - 20:30 0.25 STKOH X DFAL PROD1 20:30 - 21 :45 1.25 STKOH X DFAL PROD1 21 :45 - 22:00 0.25 STKOH X DFAL PROD1 22:00 - 00:00 2.00 STKOH X DFAL PROD1 4/16/2002 00:00 - 00:45 0.75 STKOH X DFAL PROD1 00:45 - 02:30 1.75 STKOH C PROD1 02:30 - 02:45 0.25 STKOH C PROD1 02:45 - 06:00 3.25 STKOH C PROD1 06:00 - 07:15 1.25 STKOH C PROD1 07:15 - 08:00 0.75 STKOH C PROD1 08:00 - 09:00 1.00 STKOH C PROD1 09:00 - 10:00 1.00 STKOH C PROD1 10:00 - 10:20 0.33 STKOH C PROD1 Tag up at surface, Safety meeting prior to pressure undeployment. Lay down BHA #2, lateral section BHA. This undeployment went much smoother than previous attempt. There is still room for more efficient operations yet. Change AKO to 1.9 deg. Install Smith M07 bit. During rig down of BHA #2, found chunks of black rubber (about a coffee cup), possibly from rig annular bag. Blew stack down and inspected bag for damage. Perform pressure test of annular against test rod. Passed ok. Some small amount of damage visible to the top of the annular bag. All in all it appears to be in generally good shape. Confirm with Nordic, SWS and BP town. Plan to carry on with sidetrack run, then examine more thoroughly at tom morrows BOP test. Possibly change out for new one. Note - Bag has been in service for about 1 year. Safety meeting prior to deployment of BHA #3 - sidetrack BHA. Pressure deploy BHA #3. RIH with BHA #3. BHI working on software to communicate with downhole tools. RIH with BHA hold 440 psi WHP. pump 0.1 bpm. RIH to 6200'. Stop for bad communication to BHA again. BHI working on software to communicate with downhole tools again. POOH to change out BHI Orienter and Directional Sub. Bump up, RIH 3.5 ft. close pipe/slips, push / pull against slips. Bleed Down. SAFETY MEETING. Review Pressure Undeployment / Deployment Procedure. Press Undeploy BHA. C/O BHI tools. Pressure Deploy OH Sidetrack BHA. 1.9 Deg motor, 2.75" M07 Bit. RIH with BHI sidetrack BHA. Log Tie-in with GR. Added 2 ft to CTD. Open hole Sidetrack Operations. Flag CT at 9800 ft. Original Hole TF = 70-80R. Back ream trough at 135L at 0.5 FPM. 1.4 /1.3 bpm, 3700 psi, Ream down from 9780-9800' at 0.5 fpm. Back ream 15 ft at 135L. Ream down at 0.1 fpm at 135L TF to 9800 ft. Stop at 9800' for 15 min. Time drill from 9800' at 0.1ft /6 min. for 1 ft, 9801', Time drill ahead at 2'/hr, (.1 ft/3min), No motor work observed as yet. Free spin 3500 psi. 1.4/1.3, Pit volume=219 bbls. 9803.0', Time drill ahead at 3'/hr (.1 '/2 min), No motor work observed as yet. 1.4/1.3/3530 psi, Pit vol=210 bbls at 08:15 AM. 9806', Drill at 6'/hr (0.1'/1 min), Some motor work Qbserved at end of last hour. Getting 30 Ibs motor work for every 0.1', with drilloffs. Atempt to stack weight and verify we have a sidetrack. Jumped lip, and followed the old wellbore. Need to begin Printed: 6/51.2002 9:31:49AM í"'-. .~ Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 3H-16 3H-16 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Start: 4/9/2002 Rig Release: 4/20/2002 Rig Number: Spud Date: 4/9/2002 End: 4/20/2002 4/16/2002 10:00 -10:20 0.33 STKOH C PROD1 process again. Not getting great weight transfer. We time drill, but the coil is hanging up then slipping down. Not the best way to sidetrack. 10:20-11:15 0.92 STKOH C PROD1 Start at 9750, make a down troughing pass at 100 fph. 11:15 -12:15 1.00 STKOH C PROD1 Start 9812', time drilling down at .1'/3 minutes. 12:15 - 15:00 2.75 STKOH C PROD1 Seeing the same weight profile as last attempt We stack weight slowly, then get it all back at once. Continue to time mill. Mill.1 '/1 min from 9817 to 9823. Increase ROP to 15fph, unable to get any difference in WeB or motor work, still tracking old hole. 15:00 - 18:45 3.75 STKOH C PROD1 Begin another trough starting at 9750. Trough at 80fph down at a more aggressive TF at 165Left, slow down to 50fph at 9800 to 9825. Trough a 2nd time. (200bbls of new 10ppg mud on locatoin) Trough 3rd time from 9800 -9825' at 30'/hr. 18:45 - 20:45 2.00 STKOH C PROD1 Start time milling sequence at 9825', 1'/hr. 1.5/1.4 3750 Get to 9828.1' and had gradual stacking the whole time. PU w/1 Ok overpull (diff stuck). PVT 315 20:45 - 21 :15 0.50 STKOH N SFAL PROD1 Ease back to KOP and lost 750 psi CTP and 0.3 bpm. Investigate and determine probable pump problem. Swap to pump #1 21 :15 - 00:00 2.75 STKOH C PROD1 Ease back to KOP and begin drilling 0.1 'Imin 1.5/1.4 3630 210 deg. Have to keep moving or stacks. Add 3 drums lubetex and slides better, but not getting motor differential. Drill to 9830'. PVT 297 4/17/2002 00:00 - 00:20 0.33 STKOH C PROD1 Continue trying to start OH ST, but not getting motor diff 00:20 - 01 :45 1.42 STKOH C PROD1 Open EDC. POOH to check BHA 1.5/3000 01:45-10:15 8.50 STKOH N RREP PROD1 At 2724' reel quit moving due to failed gearbox problem on off-driller side. DS mechanics remove same from Rocky 2 at DS shop and transport to location. Continue to circ at 1.5/3150 wI 300 psi WHP while WO mechanics. 10:15 - 14:30 4.25 STKOH N RREP PROD1 DS Mechanics arrive. Changeout failed gearbox with replacement from Rocky 2. 14:30 - 15:15 0.75 STKOH C PROD1 Continue POOH Sidetrack BHA#3. 15:15-15:45 0.50 STKOH C PROD1 Tag up @ surface & choke-in 450 psi. Shut in SSSV. Bleed off choke pressure & SI. Observe no wellhead pressures after 30m ins. SSSV holding up. 15:45 - 16:00 0.25 STKOH C PROD1 PJSM on LID BHA. Wellhead pressure 0 psi. 16:00 - 17:00 1.00 STKOH C PROD1 Break riser, dog collar BHA & breakout quick connect. RIB injector. P/U BHA on tugger, reset motor bend to 2.6 degs & RBIH on tugger - went in with a little resistance thus had had to work bend in with wrench. P/U, drain & LID BHA #3. Plan to MU/RIH next sidetrack BHA with SSSV SL SI master and swab 17:00 - 21:00 4.00 STKOH C PROD1 RIU & changeout annular preventer element. Perform RA on opening 2-3/8" combi doors to inspect slips and determinded that it couldn't be done since platform had been removed to fit mouse hole. Grease crew service swab, master and choke maifold 21 :00 - 00:00 3.00 STKOH C PROD1 Weekly BOPE test. Witness waived by AOGCC 4/18/2002 00:00 - 02:30 2.50 STKOH C PROD1 Finish BOP test including inner reel valve. Test mud pump #2 02:30 - 03:00 0.50 STKOH C PROD1 Open master and swab-no press, hole full Safety mtg: deployment wo pressure 03:00 - 03:30 0.50 STKOH C PROD1 PU BHA pre made up from catwalk. Install bit. Set in Printed: 61.51.2002 9:31:49 AM r. .~. Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 3H-16 3H-16 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Start: 4/9/2002 Rig Release: 4/20/2002 Rig Number: Spud Date: 4/9/2002 End: 4/20/2002 4/18/2002 03:00 - 03:30 0.50 STKOH C PROD1 handslips wi DC. Stab on injector (20 min). Set depths, open EDC 03:30 - 04:00 0.50 STKOH C PROD1 RIH w/ BHA #4 (2.6 deg motor, DPI bit) to 1500'. Test MP #2 at drilling rate 1.5/2840 04:00 - 04:50 0.83 STKOH C PROD1 Pressure tbg above closed SSSV to 600 psi. Pad operator open SSSV. Couldn't see SSSV open (no definite pressure loss) due to FL properties of mud. RIH thru SSSV to 1900', then pull back thru to 1750', clean 04:50 - 06:30 1.67 STKOH C PROD1 Continue RIH with sidetrack BHA#4 to 9140'. 06:30 - 07:00 0.50 STKOH C PROD1 Log Tie-in with GR. Added 4 ft to CTD. 07:00 - 07:15 0.25 STKOH C PROD1 Continue RIH with sidetrack BHA#4 to 9750'. 07:15 - 07:20 0.08 STKOH C PROD1 Orient TF to 195 degs. 07:20 - 08:00 0.67 STKOH C PROD1 Scribe/trough & survey from 9750' to 9835' @ 185-210TF, 1.5/1.4bpm, 3520psi, & 30fph ROP. Call for 500bbls of fresh mud. Inclination @ 9800'/9805' - 91.6/92.14 degs. 08:00 - 08:55 0.92 STKOH C PROD1 Back ream trough from 9835' to 9795' @ 185-195TF, 1.5/1.4bpm, 3520psi, & 50fph ave ROP. TF holding OK. 08:55 - 10:05 1.17 STKOH C PROD1 Scribe/trough & resurvey from 9795' to 9818' @ 185-195TF, 1.5/1.4bpm, 3540psi, & 30fph ROP. 100psi motorwork @ 9810' with @ 1k WOB. Looks like we had a bite from 9810'. Trough on to 9830'. Incl. @ 9800'/9805' - 89.67/87.56 degs. Surveys indicate departure. 10:05-10:15 0.17 STKOH C PROD1 SID pump & stack 4k wt @ 9830' - holding. PUH 5'. RBIH & tag up @ 9830'. 10:15 - 10:25 0.17 STKOH C PROD1 Drill sidetrack to 9835' @ 195-225TF, 1.5/1.4bpm, 3700/3850psi, 2k WeB & 30fph ROP. 10bbls mud losses in 1.7hrs - 6bph loss rate. PWD showing ¡P/AP of 3998/4457psi. However DWOB needs software modification to corect wrong data. 10:25 -10:40 0.25 STKOH C PROD1 Orient & drill sidetrack to 9842' @ 275TF, 1.5/1.4bpm, 3700/3850psi, 1 k WeB & 30fph ROP. 6bph losses. 10:40 - 11 :30 0.83 STKOH C PROD1 Orient around & drill to 9865' (end of sidetrack) @ 30-15TF, 1.5/1.4bpm, 3500/3850psi, 3k WeB & 40fph ROP. 11:30-14:30 3.00 STKOH C PROD1 Back ream with slight motor work from 9865' to 9825' @ 15TF, 1.5/1.4bpm, & 50fph ave ROP. RBIH to 9865' (motor work @ 9842'). Back ream to 9793'. Orient TF to 210 degs & RBIH @ 16fpm & tag up @ 9867'. Back ream I RBIH twice from 9865' to 9800' until no motor work. Drift in/out twice from 9790' to 9865' without pumps. Meanwhile swap over to new fresh 9.7ppg SFFP mud & observe 1:1 returns. 14:30 - 16:15 1.75 STKOH C PROD1 Open EDC. POOH @ 1.5bpm/2950psi for lateral BHA. Compensating for reduction in mud wt with additional 1 00 psi choke pressure schedule. 16:15-16:45 0.50 STKOH C PROD1 Tag up @ surface & choke-in 600 psi. Shut in SSSV. Bleed off choke pressure & SI. Observe no wellhead pressures after 30mins. SSSV holding up. Meanwhile held PJSM on BHA changeout with 0 psi wellhead pressure. 16:45 -17:30 0.75 STKOH C PROD1 Changeout BHA to lateral assy #5 with 0.8 deg motor & 2.7 x 3" Hycalog bicenter bit. 17:30 - 17:45 0.25 STKOH C PROD1 Surface test coiltrack - OK. 17:45 - 18:20 0.58 STKOH C PROD1 Pressure tubing above closed SSSV to 600 psi. Pad operator open SSSV. Open EDC 18:20 - 20:10 1.83 STKOH C PROD1 RIH wi BHA #5. 50' recip thru SSSV area, clean Printed: 61.5/2002 9:31:49 AM r"'. ~ Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 3H-16 3H-16 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Start: 4/9/2002 Rig Release: 4/20/2002 Rig Number: Spud Date: 4/9/2002 End: 4/20/2002 4/18/2002 20:10 - 20:25 0.25 STKOH C PROD1 20:25 - 20:40 0.25 STKOH C PROD1 20:40 - 22:10 1.50 STKOH C PROD1 22:10 - 00:00 1.83 STKOH C PROD1 4/19/2002 00:00 - 00:20 0.33 STKOH C PROD1 00:20 - 00:35 0.25 STKOH C PROD1 00:35 - 01 :25 0.83 STKOH C PROD1 01 :25 - 01 :35 0.17 STKOH C PROD1 01 :35 - 01 :55 0.33 STKOH X SFAL PROD1 01 :55 - 03:00 1.08 STKOH C PROD1 03:00 - 05:30 2.50 STKOH C PROD1 05:30 - 06:05 0.58 STKOH C PROD1 06:05 - 07:20 1.25 STKOH C PROD1 07:20 - 09:00 1.67 STKOH C PROD1 09:00 - 10:00 1.00 STKOH C PROD1 10:00-11:00 1.00 DRILL P PROD1 11:00-12:00 1.00 DRILL P PROD1 12:00 -13:10 1.17 DRILL P PROD1 13:10 - 14:40 1.50 DRILL P PROD1 14:40 - 16:00 1.33 DRILL P PROD1 16:00 -18:00 2.00 DRILL P PROD1 18:00 - 19:50 1.83 DRILL P PROD1 Close EDC at 9730' Orient TF to 210 deg, bring pump to rate. Tie-in to flag -3' at 9800'. Precautionary slow ream to TD 1.5/1.53475 psi PVT 358 Tag TD at 9865' wi TF @ 75 deg. Begin drilling PWD tool works (PWD annulus 3950 psi), WOB has software problem-no data Drilling at 9930' (5900' TVD) in target area, but no sand. . . 100 api stuff. Motor seems to stall w/900# diff. Wiper to 9865'. Drill to 10030' (5899' TVD). PVT 356 Drilling from 10030' (5899' TVD) 1.5/1.5/3500 85R PVT 356. Drill to 10061' Wiper while geo's fax log and discuss. Penetration rate has picked up last 20' to 90'/hr Open EDC @ 9720'. PUH to log. Log tie-in down at 9170', add 2.0'. RIH, close EDC at 9720' Precautionary ream to TD. RIH thru sidetrack area, clean. Tag TD at 10061' BHI work wi software to get TF moved from 90L to 90R Drilling at 90'/hr from 10061' 1.5/3500 125R PVT 353 into 60 api rock. Drill to 10126' where penetration slowed to 10-30'/hr. Drill to 10150' Drill at 50'/hr avg from 10150' looking for the elusive sand PVT 350. Got back in it at 10200'. Drill to 10250' PVT 347 Wiper to shoe, clean Resume drilling from 10250' @ 60'/hr, 1.5/3530 135R PVT 337. Drilled +/- 85 api sand to 10345' Wiper clean to 9100' to allow correlations by geologist. Open EDC in csg & saw annular mud wt on MM go from 10ppg to 9.85ppg (cuttings offload). RBIH, tag up @ 10340' & correct back to 10345' CTD. Orient & drill to 10405' @ 90-65TF, 1.5/1.5bpm, 3600/3900psi & 60fph ave ROP. PVT 331 bbls. Aiming for 94 degs & RH turn to intercept upper +/- 75 api A1 sands. Drilling break @ 10405'. Continue drilling to 10520' @ 1.5/1.4bpm, 3600/3900psi. PVT 324bbls. Drill thru @ 75api sand & renter sand @ 10480'. Mud wt from mud balance - 9.78ppg. Wiper to shoe. Hole clean. Drill to 10670' @ 1.5/1.5bpm, 3500/3900psi & 125fph ave ROP. PVT 319bbls. Drilling +/-75api sand. Wiper to 9100'. Hole clean. RBIH, tag up @ 10665' & correct back to 10670' CTD. Loosing @ 3-4bph in sand. PVT 282bbls. AP - 4000psi. Drill to 10800' @ 1.5/1.4bpm, 3600/3900psi. 3.5bph losses. Drill +1-75api sand @ 120fph ave ROP to 10765' & start dropping trajectory to encounter lower A 1 sand. Wiper to 9100'. Hole clean. Tie-in to GR marker & add 11' to CTD. RBIH, tag up @ 10811' PVT 267 Drill to 10870' @ 1.5/1.4 3580 psi 135R continuing drop to lower sand. Found it at 10860-80', but blew thru it. Try to correct and get back in it before hard line TD (10972') at 30R, but not. Drill rathole 120 api shale below 10890' and start stacking. Cuss and discuss wI geo and call it a well. Prelim Printed: 61.5/2002 9:31:49AM r ~. Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 3H-16 3H-16 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Start: 4/9/2002 Rig Release: 4/20/2002 Rig Number: Spud Date: 4/9/2002 End: 4/20/2002 4/19/2002 18:00 - 19:50 1.83 DRILL P PROD1 TD at 10943'. PVT 256 19:50 - 20:25 0.58 DRILL P PROD1 Wiper to tie-in, clean 20:25 - 21 :25 1.00 DRILL P PROD1 Open EDC at 9720'. PUH and tie-in at 9170', add 6.0'. RBIH to 9720' and close EDC 21:25 - 22:10 0.75 DRILL P PROD1 Precautionary ream to TD and tag at 10942.3'. Drill off at 10943' (official TD) PVT 244 (losses have increased due to solids in mud which have weighted the system up to nearly 10.0 ppg) 22:10 - 22:50 0.67 DRILL P PROD1 Wiper to shoe, clean 22:50 - 00:00 1.17 DRILL P PROD1 Open EDC @ 9720', POOH for liner. 10k overpull at 8860'. Paint flag at 8000' EOP. 3k overpulls at 8000',7000' (GLM's) 4/20/2002 00:00 - 00:45 0.75 DRILL P PROD1 Continue POOH for liner 00:45 - 01 :00 0.25 DRILL P PROD1 Tag up wi 600 psi whp. Close EDC. Close SSSV. Bleed off WHP. PVT 199 01:00 - 01:15 0.25 DRILL P PROD1 Safety mtg re: undeploy wlo press. Monitor for flow-none 01:15-02:00 0.75 DRILL P PROD1 LD 10' lub. Circ FW thru tools. LD BHI drilling BHA 02:00 - 02:30 0.50 CASE P CaMP Set injector on legs. Standback 60' lubricator in injector bay. RU tools to run liner 02:30 - 02:45 0.25 CASE P CaMP Safety mtg re: slotted liner 02:45 - 03:55 1.17 CASE P CaMP MU 42 jts 2-3/8" 4.35# L-80 STL slotted liner wI guide shoe and O-ring sub Kick drill wi safety jt 03:55 - 04:40 0.75 CASE P CaMP MU Baker CTLRT. MU BHI EDC. Stab on wI injector. Open EDC, begin circ 04:40 - 04:50 0.17 CASE P CaMP RIH wI liner on CT to 1750' holding 550 psi WHP 04:50 - 05:05 0.25 CASE P CaMP WO Pad operator to open SSSV 05:05 - 06:35 1.50 CASE P CaMP RIH wi liner. See flag at 9405' (15' deep), did not correct 06:35 - 07:20 0.75 CASE P CaMP 21.2k, 4.6k @ 9700'. RIH in open hole thru sidetrack pt without bobbles. Had few bobbles from 10780' to 10943' & had to work thru. Finally tagged up @ 10944'. P/U & retagged @ same depth. Call it good. 07:20 - 07:30 0.17 CASE P CaMP Close EDC. Pressure up to 4100 psi @ 1.3bpm, pump hydraulic GS open & release from liner. P/U & confirm liner release with 18.3k up wt. 07:30 - 09:00 1.50 CASE P CaMP Open EDC. POOH LRT @ 1.5bpm/2943psi. 09:00 - 09:30 0.50 CASE P CaMP Tag up @ surface with 600 psi whp. Close EDC. Close SSSV. Bleed off WHP. PVT 184. 09:30 - 10:00 0.50 CASE P CaMP PJSM for undeploying with Opsi WHP. Monitor well - 0 psi WHP after 15 mins. 10:00 - 10:45 0.75 RIGD P CaMP Flush & UD LRT BHA. Pull off mousehole for further modifications. M/U stinger & nozzle. 10:45-12:30 1.75 RIGD P COMP DSO open up SSSV. RIH & tag TOL @ 9579' (Tally TOL - 9578'). 12:30 - 13:00 0.50 RIGD N WAIT CaMP W.O. Seawater truck. 13:00 - 14:45 1.75 RIGD P COMP Displace out formate mud with 8.5ppg seawater @ 1.5bpm/1.5bpm. With 5bbls out of nozzle, POOH to 2500' chasing formate mud & compensating for reduction in mud wt with additional pressures on schedule. Send 300bbls used mud toMI. 14:45 - 16:00 1.25 RIGD P CaMP FP well from 2500' with 80F diesel. POOH & shut TRSV. Observe well dead. Close master & swab valve (19 turns). Secure well. 16:00-16:15 0.25 RIGD P CaMP RIB injector & UD BHA. Printed: 61.5/2002 9:31:49 AM .~ ,~ Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 3H-16 3H-16 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Start: 4/9/2002 Rig Release: 4/20/2002 Rig Number: Spud Date: 4/9/2002 End: 4/20/2002 4/20/2002 16:15 - 17:00 0.75 RIGD P CaMP Blow back reel & lines with air. Drain stack. Meanwhile move camp & mise loads to 3C-04. Cleanout tanks & send 200bbls unused KW mud to MI. 17:00 - 17:15 0.25 RIGD P CaMP PJSM. N/D BOP 17:15-19:30 2.25 RIGD P CaMP ND BOPE. Close SSV. NU Tree cap and PT @ 4000 psi 19:30- 0.00 RIGD P CaMP RREL @ 1930 hrs 4/20/02 Move off location 2115 hrs Printed: 61.51.2002 9:31:49 AM ~. ~. 27-Dec-O1 AOGCC 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 Definitive Re: Distribution of Survey Data for Well 3H-16A Dear Dear Sir/Madam: Enclosed are two survey hard copies and 1 disk Tie-on Survey: Window / Kickoff Survey Projected Survey: 8,892.72' MD 8,991.00' MD 9,698.00 MD (if applicable) Please call me at 273-3545 if you have any questions or concerns. Regards, William T. Allen Survey Manager RECEIVED DEC 2 8 2001 Ala~¡(a Oil & Gas Cons. CommISSj(j¡ Anchorage Attachment(s) \.-.- I "-- ,. ~ Kuparuk River Unit North Slope, Alaska Kuparuk 3H, Slot 3H-16 3H-16A Job No. AKMM11192, Surveyed: 22 November, 2001 SURVEY REPORT 27 December, 2001 DEFINITIVE ') Your Ref: API 501032009601 Surface Coordinates: 6000550.46 N, 498655.47 E (70024' 45.8564" H, 150000' 39.4175" W) Kelly Bushing: 68. 72ft above Mean Sea Level sper-'r-'y-sul1 OFULL.ING SENVICSS A H.lllburton Comp.ny ) Survey Ref: svy9743 . ". Sperry-Sun Drilling Services (I Survey Report for 3H-16A Your Ref: API 501032009601 Job No. AKMM11192, Surveyed: 22 November, 2001 North Slope, Alaska Kuparuk River Unit Kuparuk 3H Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northlngs Eastlngs Northlngs Eastlngs Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (0/100ft) 8892.72 54.850 260.720 5599.10 5667.82 184.13 S 6406.04 W 6000367.48 N 492249.40 E 5259.07 Tie On Point ) 8991.00 54.880 260.460 5655.66 5724.38 197.27 S 6485.33 W 6000354.35 N 492170.10 E 0.218 5330.62 Window Point '....... 9038.00 56.560 253.340 5682.15 5750.87 206.09 S 6523.11 W 6000345.54 N 492132.32 E 13.014 5366.23 9074.00 56.000 247.970 5702.15 5770.87 216.00 S 6551.35 W 6000335.64 N 492104.08 E 12.503 5394.83 9107.40 55.810 243.020 5720.88 5789.60 227.46 S 6576.50 W 6000324.18 N 492078.93 E 12.285 5421.87 9136.21 55.450 235.830 5737.16 5805.88 239.54 S 6596.96 W 6000312.10 N 492058.47 E 20.633 5445.49 9171.29 54.960 229.620 5757.19 5825.91 256.97 S 6619.86 W 6000294.68 N 492035.56 E 14.602 5474.28 9217.45 55.670 222.090 5783.48 5852.20 283.39 S 6647.06 W 6000268.27 N 492008.36 E 13.499 5511.85 9244.61 56.790 218.070 5798.58 5867.30 300.66 S 6661.59 W 6000251.00 N 491993.83 E 12.975 5533.80 9279.97 59.410 213.380 5817.27 5885.99 325.03 S 6679.09 W 6000226.64 N 491976.32 E 13.477 5562.37 9343.18 67.590 211.160 5845.46 5914.18 372.83 S 6709.23 W 6000178.83 N 491946.17 E 13.316 5615.03 9378.28 70.500 210.340 5858.01 5926.73 401.00 S 6725.99 W 6000150.67 N 491929.41 E 8.573 5645.26 9410.63 71.990 209.820 5868.41 5937.13 427.51 S 6741.34 W 6000124.17 N 491914.05 E 4.851 5673.37 9439.13 75.580 209.130 5876.37 5945.09 451.33 S 6754.80 W 6000100.35 N 491900.58 E 12.809 5698.36 9486.84 82.600 207.510 5885.39 5954.11 492.55 S 6777.01 W 6000059.13 N 491878.37 E 15.086 5740.72 9506.93 85.130 208.570 5887.54 5956.26 510.17 S 6786.40 W 6000041.51 N 491868.98 E 13.642 5758.75 9537.38 89.630 211.130 5888.93 5957.65 536.55 S 6801.53 W 6000015.14 N 491853.84 E 16.997 5786.61 9570.22 88.890 210.940 5889.35 5958.07 564.68 S 6818.46 W 5999987.00 N 491836.91 E 2.326 5816.95 9602.25 86.310 211.450 5890.70 5959.42 592.06 S 6835.04 W 5999959.63 N 491820.33 E 8.211 5846.56 ) 9631.03 86.120 210.420 5892.60 5961.32 616.69 S 6849.80 W 5999935.00 N 491805.56 E 3.632 5873.08 9698.00 86.120 210.420 5897.13 5965.85 674.31 S 6883.63 W 5999877.39 N 491771.72 E 0.000 5934.55 Projected Survey All data is in Feet (US) unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to RKB = 68.72' (MSL). Northings and Eastings are relative to 1107' FNL & 281' FWL. Magnetic Declination at Surface is 25.827° (20-Nov-01) The Dogleg Severity is in Degrees per 100 feet (US). Vertical Section is from 1101' FNL & 281' FWL and calculated along an Azimuth of 233.500° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 9698.00ft., The Bottom Hole Displacement is 6916.58ft., in the Direction of 264.405° (True). -.-.-.-..---...-......... -. ..---. .... .,,---------.----,._u_.,,--.------.--.- .-------....-- 27 December, 2001 - 14:00 Page2of3 Dril/Quest 2.00.08.005 r, Kuparuk River Unit Comments ',-- Measured Depth (ft) 8892.72 8991.00 9698.00 Sperry-Sun Drilling Services Survey Report for 3H-16A Your Ref: AP/501032009601 Job No. AKMM11192, Surveyed: 22 November, 2001 8' 184.13 S 197.27 S 674.31 S Survey tool program for 3H-16A North Slope, Alaska Kuparuk 3H Station Coordinates TVD Northlngs Eastlngs (ft) (ft) (ft) 5667.82 5724.38 5965.85 From Measured Vertical Depth Depth (ft) (ft) 0.00 ~ 0.00 27 December, 2001 - 14:00 To Measured Vertical Depth Depth (ft) (ft) 9698.00 5965.85 Comment ) 6406.04 W 6485.33 W 6883.63 W Tie On Point Window Point Projected Survey Survey Tool Description MWD Magnetic (3H-16A) ) Page30f3 DrillQuest 2.00.08.005 ..r---- .~, " Phillips Alaska, Inc. Pad 3H 16A slot #16A Kuparuk River Unit North Slope, Alaska SUR V E Y LIS TIN G by Baker Hughes INTEQ Nordl-a., 1. c-ìD Your ref: PMSS <9810-10943'> Our ref: svy6749 License: API# 500292102901 Date printed: 3-May-2002 Date created: 2-May-2002 Last revised: 2-May-2002 Field is centred on n70 16 18.576,w150 5 56.536 Structure is centred on n70 24 56.740,w150 0 47.688 Slot location is n70 24 45.853,w150 0 39.451 Slot Grid coordinates are N 6000550.093, E 498654.336 Slot local coordinates are 1107.00 S 281.00 E Projection type: alaska. Zone 4, Spheroid: Clarke - 1866 Reference North is True North /"...--...., '" . Phillips Alaska. Inc. SURVEY LISTING Page 1 Pad 3H.16A Your ref: PMSS <9810-10943'> Kuparuk River Unit.North Slope. Alaska Last revised: 2.May.2002 Measured Inclin Azimuth True Vert R E C TAN G U LA R Dogleg Vert G RID COO R D 5 Depth Degrees Degrees Depth COO R DIN ATE S Deg/100ft Sect Easting Northing 9698.00 86.12 210.42 5965.21 674.69S 6882.86W 0.00 6298.07 491772.02 5999876.97 9700.00 86.24 210.63 5965.35 676.41S 6883.87W 12.07 6299.81 491771.01 5999875.25 9735.42 88.65 202.94 5966.93 707.97S 6899.80W 22.73 6329.39 491755.07 5999843.70 9771.87 90.74 206.76 5967.12 741. 04S 6915.12W 11.95 6359.18 491739.75 5999810.64 9799.30 91. 57 210.32 5966.57 765.12S 6928.22W 13.32 6382.57 491726.65 5999786.56 9810.00 91.80 212.55 5966.25 774.255 6933.79W 20.90 6391.96 491721. 07 5999777.43 9837.99 78.46 211.04 5968.62 797.905 6948.46W 47.98 6416.49 491706.40 5999753.79 9863.52 90.65 212.56 5971. 04 819.45S 6961. 83W 48.11 6438.84 491693.03 5999732.24 9895.34 91.51 211.10 5970.44 846.48S 6978.60W 5.32 6466.89 491676.25 5999705.22 9931.36 89.57 208.93 5970.10 877.67S 6996.62W 8.08 6498.08 491658.23 5999674.04 9965.03 91.23 212.66 5969.87 906.585 7013.85W 12.13 6527.47 491640.99 5999645.13 9998.26 90.68 215.93 5969.31 934.03S 7032.57W 9.98 6557.40 491622.26 5999617.69 10032.87 89.69 217 . 88 5969.20 961.70S 7053.35W 6.32 6589.23 491601.48 5999590.02 10062.76 90.83 220.64 5969.07 984.845 7072.27W 9.99 6617.18 491582.56 5999566.89 10092.36 90.12 223.89 5968.82 1006.745 7092.17W 11.24 6645.37 491562.66 5999544.99 10120.77 90.74 227.69 5968.61 1026.555 7112.53W 13.55 6672.91 491542.29 5999525.20 10150.10 93.41 228.75 5967.54 1046.085 7134.38W 9.79 6701.60 491520.44 5999505.68 10188.81 92.36 230.47 5965.60 1071.13S 7163.83W 5.20 6739.62 491490.99 5999480.63 10225.52 92.33 234.44 5964.09 1093.47S 7192.91W 10.81 6775.98 491461. 91 5999458.30 10253.25 91.41 235.34 5963.19 1109.415 7215.58W 4.64 6803.58 491439.24 5999442.36 10283.04 91.26 237.70 5962.49 1125.84S 7240.42W 7.94 6833.31 491414.40 5999425.94 10313.19 91.56 241.58 5961. 75 1141. 075 7266.42W 12.90 6863.44 491388.39 5999410.72 10353.35 90.49 242.99 5961.03 1159. 75S 7301. 96W 4.41 6903.56 491352.85 5999392.05 10383.23 91.69 246.95 5960.47 1172.38S 7329.03W 13.85 6933.32 491325.79 5999379.42 10417.85 94.48 247.96 5958.60 1185.64S 7360.95W 8.57 6967.59 491293.86 5999366.18 10448.03 94.73 250.29 5956.18 1196.365 7389.06W 7.74 6997.29 491265.76 5999355.47 10478.44 93.43 252.84 5954.01 1205.955 7417.83W 9.39 7027.00 491236.98 5999345.88 10508.89 92.73 255.26 5952.38 1214.305 7447. 06W 8.26 7056.50 491207.75 5999337.54 10538.81 92.40 257.31 5951.04 1221.395 7476. lOW 6.93 7085.19 491178.72 5999330.46 10568.90 91. 96 261.49 5949.89 1226.92S 7505.65W 13.96 7113.54 491149.17 5999324.93 10603.35 90.71 265.49 5949.09 1230.825 7539.86W 12.16 7145.12 491114.96 5999321. 04 10633.23 90.15 268.54 5948.87 1232.385 7569.70W 10.38 7171.74 491085.13 5999319.49 10663.25 89.91 270.44 5948.85 1232.64S 7599.71W 6.38 7197.87 491055.11 5999319.23 10693.37 89.39 273.49 5949.04 1231. 615 7629.81W 10.27 7223.41 491025.02 5999320.27 10723.20 88.13 275.52 5949.68 1229.27S 7659.54W 8.01 7247.99 490995.29 5999322.62 10753.15 88.65 278.14 5950.52 1225.71S 7689.26W 8.92 7271. 95 490965.58 5999326.18 10795.31 88.80 282.89 5951.46 1218.02S 7730.69W 11.27 7303.98 490924.15 5999333.88 10825.61 87.61 284.74 5952.41 1210.79S 7760. lOW 7.26 7325.84 490894.75 5999341.12 10856.36 86.69 288.47 5953.94 1202.015 7789.53W 12.48 7346.93 490865.33 5999349.90 10884.15 85.95 290.07 5955.72 1192.86S 7815.70W 6.33 7365.03 490839.15 5999359.05 10914.14 87.79 292.25 5957.36 1182.055 7843.63W 9.50 7383.81 490811.24 5999369.87 10943.00 89.60 294.40 5958.02 1170.63S 7870.12W 9.74 7401. 04 490784.75 5999381.29 All data in feet unless otherwise stated. Calculation uses minimum curvature method. Coordinates from slot #16A and TVD from wellhead (68.72 Ft above mean sea level). Bottom hole distance is 7956.70 on azimuth 261.54 degrees from wellhead. Vertical section is from 50.00 W 0.00 on azimuth 240.00 degrees. Grid is alaska. Zone 4. Grid coordinates in FEET and computed using the Clarke. 1866 spheroid Presented by Baker Hughes INTEQ .> I~ Phillips Alaska. Inc. Pad 3H,16A Kuparuk River Unit,North Slope, Alaska MD TVD -"""'--"""--"""--"""-'-""-'--"""-""""-"""---""-"""'-""""-"""'-"""'-' 9810.00 5966.25 Top MD Top TVD Rectangular Coords. Comments in wellpath Comment ~ SURVEY LISTING Page 2 Your ref: PMSS <9810.10943'> Last revised: 2.May-2002 Rectangular Coords. Bot MD Bot TVD Casing positions in string 'A' Rectangular Coords. 0.00 0.00 -.---...----.....----.-.-----..-------...---..........""""'--"""'-"""""""-""""-""-'---- Casing Target name 774.25S 6933.79W Tie.in Point 1170.63S 7870.12W 2-3/8" Geographic Location T.V.D. Targets associated with this wellpath Rectangular Coordinates Revised '-'-""-'--""'-"""-""---""--""'-"""-'-'",-""-,-",,,,""""""-""'---""-----""-- 8.Jan-2002 O.OON O.OOE 10943.00 5958.02 3H.16B BHL Rvsd 07.J 490709.000,5999285.000,2.0000 5915.72 1266.95S 7945.85W .. ,~ " ~ Phillips Alaska. Inc. Pad 3H 16APB1 slot #16A Kuparuk River Unit North Slope. Alaska SUR V E Y LIS TIN G by Baker Hughes INTEQ r/b wi.;t j.. tTb Your ref: PMSS <9700-10457'> Our ref: svy6746 License: Date printed: 3-May-2002 Date created: 17-Apr-2002 Last revised: 2-May-2002 Field is centred on n70 16 18.576.w150 5 56.536 Structure is centred on n70 24 56.740.w150 0 47.688 Slot location is n70 24 45.853.w150 0 39.451 Slot Grid coordinates are N 6000550.093. E 498654.336 Slot local coordinates are 1107.00 S 281.00 E Projection type: alaska - Zone 4. Spheroid: Clarke - 1866 Reference North is True North .. ~ ~ ',' . Phillips Alaska, Inc. SURVEY LISTING Page 1 Pad 3H,16APB1 Your ref: PMSS <9700-10457'> Kuparuk River Unit,North Slope, Alaska Last revised: 2-May-2002 Measured Inclin Azimuth True Vert R E C TAN G U LA R Dogleg Vert G RID COO R D S Depth Degrees Degrees Depth COO R DIN ATE S Deg/100ft Sect Easting Northing 9698.00 86.12 210.42 5965.21 674.69S 6882.86W 0.00 6298.07 491772.02 5999876.97 9700.00 86.24 210.63 5965.35 676.41S 6883.87W 12.07 6299.81 491771.01 5999875.25 9735.42 88.65 202.94 5966.93 707.975 6899.80W 22.73 6329.39 491755.07 5999843.70 9771.87 90.74 206.76 5967.12 741. 045 6915.12W 11.95 6359.18 491739.75 5999810.64 9799.30 91.57 210.32 5966.57 765.125 6928.22W 13.32 6382.57 491726.65 5999786.56 9825.98 92.15 215.87 5965.70 787.455 6942.77W 20.90 6406.34 491712.09 5999764.23 9856.48 94.03 222.20 5964.06 811.105 6961.94W 21.62 6434.77 491692.92 5999740.59 9886.32 93.90 226.46 5961. 99 832.395 6982.74W 14.25 6463.42 491672.12 5999719.31 9915.88 94.24 231.84 5959.89 851.675 7005.03W 18.19 6492.37 491649.82 5999700.04 9946.82 91.93 237.08 5958.23 869.625 7030.16W 18.49 6523.11 491624.69 5999682.09 9976.54 91.45 242.37 5957.35 884.595 7055.81W 17.86 6552.80 491599.04 5999667.13 10009.81 89.94 248.05 5956.94 898.535 7086.00W 17.66 6585.92 491568.85 5999653.20 10038.12 91.50 254.78 5956.59 907.555 7112.81W 24.40 6613.65 491542.04 5999644.19 10069.03 90.65 256.72 5956.01 915.155 7142. 76W 6.85 6643.39 491512.09 5999636.59 10109.09 89.47 263.39 5955.97 922.075 7182.20W 16.91 6681.00 491472.65 5999629.68 10143.01 88.51 266.90 5956.56 924.945 7215.99W 10.73 6711.70 491438.87 5999626.82 10171.92 88.15 270.77 5957.41 925.535 7244.87W 13.44 6737.01 491409.99 5999626.24 10204.76 87.54 276.39 5958.64 923.485 7277.61W 17.20 6764.34 491377 . 25 5999628.29 10240.49 86.75 274.64 5960.42 920.055 7313.13W 5.37 6793.38 491341.74 5999631.73 10271. 42 88.10 271.18 5961.81 918.485 7343.98W 12.00 6819.32 491310.89 5999633.30 10300.82 87.64 267.54 5962.91 918.81S 7373.36W 12.47 6844.92 491281.52 5999632.98 10330.71 87.67 263.21 5964.13 921.225 7403.12W 14.47 6871.90 491251.76 5999630.58 10360.79 88.89 258.18 5965.03 926.085 7432.78W 17.20 6900.01 491222.10 5999625.73 10392.22 93.01 256.07 5964.51 933.08S 7463.41W 14.73 6930.04 491191.47 5999618.74 10421. 33 93.04 250.39 5962.97 941.465 7491.23W 19.49 6958.32 491163.65 5999610.36 10457.00 94.00 244.00 5960.78 955.255 7524.03W 18.08 6993.63 491130.85 5999596.58 All data in feet unless otherwise stated. Calculation uses minimum curvature method. Coordinates from slot #16A and TVD from wellhead (68.72 Ft above mean sea level). Bottom hole distance is 7584.43 on azimuth 262.76 degrees from wellhead. Vertical section is from 50.00 W 0.00 on azimuth 240.00 degrees. Grid is alaska - Zone 4. Grid coordinates in FEET and computed using the Clarke - 1866 spheroid, Presented by Baker Hughes INTEQ ,.. I" . "" . ~ ,~ Phillips Alaska, Inc. Pad 3H,16APB1 Kuparuk River Unit,North Slope, Alaska SURVEY LISTING Page 2 Your ref: PMSS <9700.10457'> Last revised: 2.May.2002 MD Rectangular Coords. Comments in wellpath Comment TVD 10457.00 5960.78 7524.03W PROJECTED DATA to TD """""-"""-""""-"""""""""""-"""'--"""""""""""""""""""""""" 955.25S Targets associated with this wellpath Target name Geographic Location Rectangular Coordinates T.V.D. Revised 3H.16B BHL Rvsd 07.J 490709.000,5999285.000,2.0000 5915.72 7945.85W """""'-"""""""""'-'-"""-"""""'".....-.............................-....--......,.... 8.Jan.2002 1266.95S r\ ..-........ c]OQ-Uè);? WELL LOG TRANSMITf AL To: State of Alaska Alaska Oil and Gas Conservation COtnm. Attn.: Lisa Weepie 333 West 7th Avenue, Suite 100 Anchorage, Alaska March 12, 2002 RE: MWD Formation Evaluation Logs 3H-16A, AK-MM-11192 1 LDWG formatted Disc with verification listing. PlPI#: 50-103-20096-01 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COpy OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Service Attn: Jim Galvin 6900 Arctic Blvd. Anchorage, Alaska 99518 Date: Si~.~~ "^--) RECEIVED M,' R .... - ') r:í-\', I ~¡ LOO2 Alaska Oil & Gas Cons. Commission AnchOl'8 Je KRU þermits to BP office .. r----, ,~. Subject: KRU permits to BP office Date: Thu, 7 Mar 2002 15:19:05 -0900 From: "Dan Venhaus" <dvenhaus@ppco.com> To: tom_maunder@admin.state.ak.us CC: JohnsoMO@bp.com, "Michael B Mooney" <mmooney@ppco.com>, "R Marty Lemon" <rmlemon@ppco.com> Tom, The Kuparuk CTD program starting up in April consists of 3 well~ 3C-04A, and 3M-29A. Well 3H-16A's permit was submitted by P~has been approved. This well is a combination rotary/CTD sidetrack with the rotary part completed in November 2001 with Phillips' Nordic 3 rig. Wells 3C-04A, 3M-29A (and the 3H-16A extension) are to be drilled solely with BP's Nordic 1 CTD unit. BP's CT drilling services are being provided to the operator Phillips via a Shared Service operation. As such, Phillips authorizes the delivery of 3C-04A and 3M-29A permits to BP (Terry Hubble). Phitlips does request that BP provide a copy of the approved permits. If you need anything else, let me know. Dan Venhaus Phillips Alaska, Inc. CT Drilling Engineer 263-4372 work 230-0188 cell -- Forwarded by Dan Venhaus/PPCO on 03/07/2002 02:36 PM ---- "Johnson, Mark 0" <JohnsoMO@BP.com> 03/06/200207:14 AM To: Dan Venhaus/PPCO@Phillips cc: Subject: KRU permits to BP office Dan, I was talking to Tom Maunder this morning. It does not look like he can make a DOCTD meeting today and he will get back with me on an alternate date. Tom needs a e-mail from you authorizing delivery of the Phillips operated well permits to the BP office (even though they originated from me) Content 1) Please send KRU CTD sidetrack permits to BP office (normal Terrie Hubble address) 2) Background on why they need to go to BP. (CTD is a shared service (ap & Phillips) with the rigs operated by BP, but sidetracking KRU wells.) 10f2 dOD-ð;l ~ 3/7/02 4:52 PM KRU permits to BP office ~ r--- ~ 3) Three well program in 2002 (list well names). Thx MOJ 20f2 3/7/024:52 PM ..'-" r-"" Notice of Public Hearing STATE OF ALASKA . Alaska Oil and Gas Conservation Commission Re: Kuparuk River Unit 3H-16A ADL #25531 & 25532 Section 10, T12N, R08E, UM Kuparuk River Field Phillips Alaska, Inc. by letter dated November 8, 2001 has requested an order allowing a spacing exception in accordance with 20 AAC 25.055. The projected bottomhole location may fall within 500 feet of the property line of the Kuparuk Participating Area. The surface location of the well is 11 04' FNL, 4997' FEL, Section 12, Tl2N, R08E, UM. A person may submit written comments regarding the requested revision prior to December 18, 2001 at the Alaska Oil and Gas Conservation Commission at 333 West 7th Avenue, Suite 100, Anchorage, Alaska 99501. In addition, the Commission has tentatively set a public hearing on December 18, 2001 at 9:00 am at the Alaska Oil and Gas Conservation Commissi(i)n at 333 West 7th Avenue, Suite 100, Anchorage, Alaska 99501. A person may request that the tentatively scheduled hearing be held by filing a written request with the Commission prior to December 3, 2001. If a request for a hearing is not timely filed, the Commission will consider the issuance of an order without a hearing. To learn if the Commission will hold the public hearing, please call 793-1221. If you are a person with a disability who may need a special modification in order to comment or to attend the public hearing, please contact Jody Colombie at 793-1221 before December 11, 2001. ~ ~ C~YIOr, Chair Oil and Gas Conservation Commission Published November 20,2001 ADN AO #02214015 ,-., .~ ,-.. ;- ~~~~E TI F ~~~~~~~ ALAS HA 0 IL AND GAS CONSERVATION COMMISSION TONY KNOWLES, GOVERNOR 333 W. 7'" AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Chuck Mallary Drilling Engineering Supervisor Phillips Alaska, Inc. PO Box 100360 Anchorage, AK 99510-0360 Re: Kuparuk River Unit 3H-16A Revision 2 Phillips Alaska, Inc. Permit No: 200-022 Sur Loc: 1107' FNL, 4997' FEL, Sec. 12, Tl2N, R8E, UM Btmhole Loc. 2378' FNL, 2387' FEL, Sec. 10, Tl2N, R8E, UM Dear Mr. Mallary: Enclosed is the approved revised application for permit to drill the above referenced well. This is the 2nd revision of this authorization. This revision is for a second change in bottom-hole location and acknowledgement of your planning to drill a portion of the well with a rotary rig and complete the remainder with coil tubing. This approval covers operations for both the rotary rig and coil tubing rig. No sundry is required when rotary operations are completed. Please provide notice to the North Slope Inspector when the coil unit moves on so that the BOP test may be witnessed or waived. The permit to drill 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. In your application, you have applied for a spacing exception for the proposed bottom-hole location. The necessary notice for that application will be started shortly. In the interim your operations may proceed, however proceeding is at Phillips' sole risk and the well may not be produced without the necessary exception in place. Annular disposal of drilling wastes has not been requested for 3H-16A. It is further noted that according to Commission records, there is no well on 3H pad presently approved for annular disposal. In your application you indicated that drilling waste would be disposed of in an approved Class II disposal well. 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. Sincerely, c~~.~ Chair BY ORDER OFlHE COMMISSION DA TED this~ day of November, 2001 ]c/Enclosures cc: Department ofFish & Game, Habitat Section w/o ¡;:ncl. Department of Environmental Conservation w/o encl. PHILLIr) '~Iaska, Inc. A Subsidiary òfPH4LLlPS PETROLEUM COMPANY ,-- .-, Post Office Box 100360 Anchorage, Alaska 99510-0360 C. Mallary Phone (907) 263-6434 Fax: (907) 265-1535 November 8, 2001 RECE IVED Cammy Oechsli Taylor, Chair Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 (907) 279-1433 NOV 0 9 2001 Alaska Oil & Gas Cons. Commission Anchorage Re: Application for Permit to Drill, Kuparuk Sidetrack Well 3H-16A. Dear Commissioner Taylor: Phillips Alaska, Inc. hereby applies for a Permit-to-Drill a sidetrack from well 3H-16 to the Kuparuk interval. The well is designed to penetrate and develop the production potential of the Kuparuk A-sands with a single horizontal penetration. This application for the Permit to Drill encompasses both the rotary rig section of the well, which includes sidetracking and topsetting in the A-sand, and the coil tubing drillout of the horizontal section. ("<L \.~~J~ ~ s~ ~Q. ~. ~ c.. ~ A standing Permit-to-Drill, #200-022, was issued earlier this year for a coil-only sidetrack of well 3H-16. This sidetrack was attempted in March 2001 but had difficulties inside the production tubing resulted in leaving junk in the tubing and operations were halted. Drilling operations had not commenced and the well is still P&A'd (reference Form 10-407, Well Completion Report, signed 3/12/01). Phillips Alaska, Inc. is requesting closure of permit #200-022, and replacing it with this new permit. Decompletion, completion, and the directional plan have changed considerably since issuance of the last permit. The completion will consist of topsetting a 3-1/2" intermediate liner in the A-sand and tieback to 3-1/2" tubing. Coil drilling will mill through float equipment and drill "'1400' of 3" horizontal hole. Horizontal will be completed with 2-3/8" slotted liner. The rotary setup will be drilled and completed using Nordic 3 with an expected spud date of November 15, 2001. The coil drilling segment will be drilled and completed using Nordic 1. Expected spud date for coil is second quarter 2002. The proposed BHL for the coil tubing horizontal section is within 500' of the KPA (Kuparuk Participating Area) unit boundary. Phillips Alaska Inc. requests an exception to rule 20 MC 25.055. (Please see attached letter). Affected adjacent landowners are to be notified and it is understood that approval of the Permit to Drill does not guarantee that the said exception will be approved. Please find attached for the review of the Commission Form 10-401 and the information required by 20 ACC 25.005. If you have any questions or require any further information, please contact me at 263-4372. Sincer Iy, h7 ?/,t¿¿~;éd ~'t ~~ C. Mallary ('7 Drilling Engineering Supervisor cfvr L. (ý/,¿,/bry 9. Approximate spud date Amount November 15,2001 $200,000 14. Number of acres in property 15. Proposed depth (MD and TVD) 2560 10965' MD /5916' TVD 17. Anticipated pressure (see 20 AAC 25.035 (e)(2)) Maximum surface 2615 psig At total depth (TVD) 3270 psig Setting Depth ~ ~ STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 1b. Type of well. Exploratory U Stratigraphic Test U Service 0 Development Gas 0 Single Zone 0 5. Datum elevation (DF or KB) 76' RKB 6. Property Designation ADL 25531 & 25532 7. Unit or property Name Kuparuk River Unit 8. Well number 3H-16A 1a. Type of work: Drill U Aedrill b!J Ae-entry 0 Deepen 0 2. Name of Operator Phillips Alaska, Inc. 3. Address P.O. Box 100360 Anchorage, AK 99510-0360 4. Location of well at surface 1107' FNL, 4997' FEL, Sec. 12, T12N, R8E, UM At top of productive interval 1547' FNL, 1188' FEL, Sec. 10, T12N, R8E, UM At total depth 2378' FNL, 2387' FEL, Sec. 10, T12N, R8E, UM 12. Distance tQ nearest property line I 13. Distance to nearest well 1188' @ Target feet none 16. To be completed for deviated wells Kickoff depth: 8995 MD 18. Casing program size ALK 2658 feet Maximum hole angle 94° Hole Specifications Grade Coupling TVD Top Bottom MD TVD MD Length Casing Weight 6.125" 3.5" 2-3/8" L-80 L-80 8845' 9484' 9584' 10965' 5955' 5916' 5640' 5953' EUE 8rd FL4S 750' 1480' 3" 9.3# 4.6# 19. To be completed for Aedrill, Ae-entry, and Deepen Operations. Present well condition summary Total Depth: measured 9770 feet Plugs (measured) true vertical 6178 feet Effective Depth: measured 9042 feet Junk (measured) true vertical 5757 feet Casing length Size Cemented Measured depth Conductor 110' 16" 200 sx AS I 110' Surtace 3867' 9-5/8" 1600 sx AS III & 400 sx Class G 3943' Production 9632' 7" 400 sx Class G & 175 sx AS I 9708' Perforation depth: measured to be squeezed off: 9315'- 9391', 9440' - 9460' true vertical 5913' - 5956', 5984' - 5996' ~'l tL~ ( Development Oil b!J Multiple Zone 0 10. Field and Pool Kuparuk River Field Kuparuk Oil Pool 11. Type Bond (see 20 AAC 25.0251) Statewide Number #59-52-180 Quantity of Cement (include stage data) 35 bbls Class G N/A RECEIVCD NOV 0 9 2001 Alaska Oil & Gas Cons. Commission Anchorage True Vertical depth 110' 2866' 6142' 20. Attachments Filing fee 0 Property Plat 0 BOP Sketch 0 Diverter Sketch 0 Drilling program 0 Drilling fluid program 0 Time vs d h plot DAefraction analysis 0 Seabed report 0 20 AAC 25.050 requirements 0 21. I hereby ~~. rti . t the 'it: is tr. u n. d corre~...the best of my knowledge Questions? Call Dan Venh¡ ~63-437. Signed ¡~V-í-¿;I ¡;~£ Y~'St- ¿~ ¡11?/(C(7 Title: DriHingEngineeringSupervisor Date O~ /[.,iJV' ;?:;o? c. Mal/ary i7 PreDared bv Sharon Al/suD-DrakE Commission Use Onl} Permit Number I API number I Approval date 2Oo-d2'2.- 50- /CJ3-.2.dO?6-C>/ Conditions of approval Samples required 0 Yes ~ No Mud log required Hydrogen sulfide measures ;¿g Yes 0 No Directional survey required Aequired working pressure for BOPE D2M; 0 3M; 0 5M; 0 10M;D Other: see cover letter for other requirements 0 Yes.g No DYes..1ð3 No œlYOaa ~<);\ \5.ö~ -\-~<>~ Approved by Original Signed By Cammy Oechsli by Qrder Qf I the commission. ,,"', , ~at: ! I (~ / Ö J 0 R ¡ \;4', IV A L Submit in triplicate Commissioner Form 10-401 Rev. 12/1/85. - ~ Applic.~ for Permit to Drill, We1l3H-16A ,~ Revision No.O Saved: 8-Nov-O1 Permit It - Kuparuk Well 3H-16A Application for Permit to Drill Document Mo)ximizE Well Vglue Table of Contents 1. Well Name ................................................................................................................. 2 Requirements of 20 AAC 25.005 (f)........................................................................................................2 2. Location Summary ...................................................................................................2 Requirements of 20 AAC 25.005(c)(2) """""""""""""""""""""""""""""""""""""',........................2 Requirements of 20 AAC 25. 050(b)........................................................................................................2 3. Blowout Prevention Equipment Information ......................................................... 3 Requirements of 20 AAC 25. 005( c)(3) .................. ................................................. ......... ....................... 3 4. Drilling Hazards Information ................................................................................... 3 Requirements of 20 AAC 25.005 (c)( 4) ......................... ....................... ..................................................3 5. Procedure for Conducting Formation Integrity Tests ........................................... 4 Requirements of 20 AAC 25.005 (c)(5) ..".... .................. ........................................................................4 6. Casing and Cementing Program.............................................................................4 Requirements of 20 AAC 25.005(c)(6) .........................................................................................;......... 4 7. Diverter System Information ...................................................................................4 Requirements of 20 AAC 25.005(c)(7) ................................................................................................... 4 8. Drilling Fluid Program .............................................................................................4 Requirements of 20 AAC 25. 005( c)(B) .... .................... ............. ......................................... ..................... 4 9. Abnormally Pressured Formation Information ...................................................... 5 Requirements of 20 AAC 25.005 (c)(9) .................................................................................................. 5 10. Seismic Analysis ......................................................................................................5 Requirements of 20 AAC 25.005 (c)(1 0) ................................................................................................ 5 11. Seabed Condition Analysis ..................................................................................... 5 Requirements of 20 AAC 25.005 (c)(11) ........................... ................. ............................. ....................... 5 12. Evidence of Bonding................................................................................................5 Requirements of 20 AAC 25.005 (c)(12) ............................................... .......... .................... ...... ............. 5 13. Proposed Drilling Program......................................................................................5 3H-16A PERMIT IT. DOC OR/G' Page 1 0(6 . ¡IV A L Printed: 8-Nov-O1 .~ Appli~n for Permitto Drill, We1l3H-16A Revision No.O Saved: 8-Nov-O1 5. Procedure for Conducting Formation Integrity Tests Requirements of 20 AAC 25.005 (c)(5) An application for a Pel7rJ1t to Drill must be accompanied by each of the following items¡ exæpt for an item already on file with the commi5sion and identified in the application: (5) z¡ description of the proædUle for conducting fomlation integrity test,,~ z¡s requited under 20 MC 25.030(f)/ Perform FIT test to 13.0 ppg (expected ECD at window for 11.0 ppg LSND mud with safety factor) in accordance with the Kuparuk LOT I FIT procedure, that Phillips Alaska has on file with the Commission. 6. Casing and Cementing Program Requirements of 20 AAC 25.005(c)(6) An application for a Permit to Dnll must be accompanied by each of the to/lowing Items¡ except for an item already on file with the commission and identified in the application: (6) a complete proposed casing and cementing program as required by 20 MC 25.030, and a description of any slotted liner; pre- pelf orated liner; or screen to be instal/ert. Casing and Cementing Program Hole Top 8tm Csgffbg Size Weight Length MDffVO MOffVO 00 (in) (in) (Ib/ft) Grade Connection (ft) (ft) (ft) Cement. Program 3-1/2 6-1/8 9.3 L-80 EUE 8rd 750' 8845' I 5640' 9584' I 5955' 35 bbl Class G wi additives* 2-3/8" 3 4.6 L-80 FL4S 1480' 9484' I 5953' 10965' I 5916' N/a *Cement volume sufficient to bring TOC 150' above liner top. 7. Diverter System Information Requirements of 20 AAC 25.005(c)(7) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already 017 file with the commi:":iion and Identified in the application: (7) a diagram and description of the diverter system as required by 20 MC 25. 03~ unless this requirement is waived by the commission under 20 MC 25.035(h)(2),' NI A - Sidetrack out of 7" with BOP installed. 8. Drilling Fluid Program Requirements of 20 AAC 25.005(c)(B) An application f..ryr a Permit to Drill must be accompanied by each of the following item,,~ except for an item already on file witll the commis",'ion and identified in the application: (8) a drilling fluid program, including a diagram and de.saiptiorJ of the ddlling flUId !Jystem, as required by 20 MC 25. 033; Mud Density (ppg) Funnel Viscosity(sec) Yield Point (cP) Plastic Viscosity (lb/l00 sf) Nordic 37" window milling LSND/GEM 11.0 45-60 25-30 13-24 Nordic 3 rotary drill to 3-1/2" intermediate liner LSND/GEM 11.0 45-60 20-25 13-24 Nordic 1 Coil Tubing drill out for 1380' horizontal FLO-PRO 9.0-10.0 35K (LSRV) 22-28 7-9 Nordic 1 CT drilling will utilize dynamically overbalanced drilling techniques to minimize overbalance on the formation and address high reservoir pressures should they occur. An underbalanced drilling fluid (9- 0 R ,. G I ¡;,VA3HL-16A PERNJ!~~ :f;;~ / Printed: a-Nov-a1 .~ ,.--., Appli~n for Permit to Drill, We1l3H-16A Revision No.O Saved: 8-Nov-O1 , 10 ppg) in combination with annular friction losses and applied surface pressure will maintain overbalanced reservoir conditions. Nordic 3 rotary will drill using the standard overbalanced mud system. Diagram of Nordic 3 Mud System on file. Drilling fluid practices will be in accordance with appropriate regulations stated in 20 MC 25.033. 9. Abnormally Pressured Formation Information Requirements of 20 AAC 25.005 (c)(9) An application for a Permit to Drill must be accompanied by each of the following item~ except for an item already on file with the commission and identified in the application: (9) for an exploratory or stratigrapl1ic test well a tabulation setting out the depths of predicted abnormally pea-pressured "trata as required by 20 MC 25.033(f); N/ A - Application is not for an exploratory or stratigraphic test well. 10. Seismic Analysis Requirements of 20 AAC 25.005 (c)(10) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already 0/7 file with the commission and identified in the application: (10) for an exploratory or stratigraphic test well a seL<;mic refractiO/7 or reflection analysis as required by 20 AAC 25. 061 (a); N/ A - Application is not for an exploratory or stratigraphic test well. 11. Seabed Condition Analysis Requirements of 20 AAC 25.005 (c)(11) An application for a Permit to Drill mu!>-t be accompanied by each of tlie following item,,~ except for an item already on file with tile commissIon and Identified in tlie application: (11) for a well dn!led from an offshore platfOfm, mobile bottom-founded structure, jack-up rig, or floating dn!/ing vesse¿ an analysis of seabed conditIons as requIred by 20 MC 25. 061 (b); N/A - Application is not for an offshore well. 12. Evidence of Bonding Requirements of 20 AAC 25.005 (c)(12) An applIcation for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commissIon and identified in the application: (12) evidence showing that the requirements of 20 MC 25.025 {Bonding}have been met; Evidence of bonding for Phillips Alaska, Inc. is on file with the Commission. 13. Proposed Drilling Program Requirements of 20 AAC 25.005 (c)(13) An applicatIon for a Penmt to Drill must be accompanied by each of the following Items¡ except for an item already on file v,¡ith the commission and identifìed in the application: The proposed drilling program is listed below. Please refer as well to Attachment 2, Well Schematic. 1. MIRU Nordic 3. Lay hard-line to tree. Pull BPV and VR plug. 2. Circulate well to seawater through tubing punch holes at 9011' MD. Verify well is dead. 3. Set BPV. ND tree. NU and test BOPE. 4. Screw in landing joint. Pull tubing hanger to rig floor. POOH laying down all tubing and jewelry. 5. PU 7" Casing Scraper on DP and run through Bridge Plug setting depth. 6. RU E-line Unit. RIH and set Bridge Plug at 9020' MD. Test bridge plug/7" casing to 3000 psi. 7. PU Baker 7" Window Master Bottom Trip Whipstock, MWD, etc and RIH. Circulate well to 11.0 ppg milling fluid, orient and set whipstock w/ MWD. Shear off whipstock bolt and mill window in 7" casing and 20' formation. Perform FIT test to 13.0 ppg (expected ECD plus SF at window for 11.0 ppg LSND mud). POOH and LD milling assembly. Note: If unable to obtain adequate FIT, squeeze window with cement, redrill and test again. 0 R I G INtt-16A PERMIT IT.DOC L PageS 0(6 Printed: 8-Nov-01 I""~ Appl~n for Permit to Drill, We1l3H-16A Revision No.O Saved: 8-Nov-O1 :: 8. RIH w/ 6-1/8" bit, MWD / LWD, and steerable drilling assembly. Slide out window, kick-off and directionally drill to total depth as per directional plan (TD in A-sand target at 90 deg). Short trip to window in casing. POOH and lay down drilling assembly. 9. Run 3-1/2" liner to TD w/ 150' of overlap above top of milled window. 10. Cement liner in place, set liner hanger and liner top packer, circulate out excess cement and POOH. 11. Pressure test casing and liner lap to 1500 psi for 10 min. 12. RIH w/ 3-1/2" completion assembly and sting into Seal Bore Extension below liner top packer. Space out. Displace well to seawater and land tubing. Test annulus and liner lap to 3000 psi (chart test for State). 13. ND BOPE. NU and test tree. Freeze protect well with diesel. RDMO Nordic 3. 14. Post-rig pressure test tubing and liner to 3000 psi. 15. MIRU Nordic 1 coil tubing drilling rig. 16. NU BOPE above swab valve (see aD BOP diagram) and test. 17. Mill out 3-1/2" casing shoe. Drill 3" horizontal hole to TD ("'1380') according to directional plan. Perform open hole logging as required. Note: Nordic 1 a drilling will utilize dynamically overbalanced drilling techniques to minimize overbalance on the formation and address high reservoir pressures should they occur. An underbalanced drilling fluid (9-10 ppg) in combination with annular friction losses and applied surface pressure through a dedicated choke will maintain overbalanced reservoir conditions. Using this technique requires deployment of the BHA under trapped wellhead pressure. Deployment will be accomplished using the upper BOP pipe/slips (2-3/8" rams, see attached BOP configuration). The annular preventer will act as a secondary containment during deployment and not as a stripper. Lower BOP rams will be used only for primary well control. At least two times hole volume of kill weight fluid will be on location as a contingency. 18. Run 2-3/8" 4.6# L-80 FL4S liner with 100' overlap inside 3-1/2" intermediate casing. 19. ND BOPE. Freeze protect well with diesel. RDMO Nordic 1. 14. Discussion of Mud and Cuttings Disposal and Annular Disposal Requirements of 20 AAC 25.005 (c)(14) An application for a Pelmlt to Drill mustc be accompanied by each of the following Item~ except for an Item already on file with the commission and identified in the application: (14) a general description of how the operator plans to dispose of drilling mud and cuttings and a statement of whether the operator intends to request authorization under 20 MC 25.080 for an annular disposal operation in the well.,' Waste fluids generated while drilling the sidetrack will be hauled to a KRU Class II disposal well. All cuttings generated will be hauled to the Prudhoe Bay Field for temporary storage and eventual processing for injection down an approved disposal well. Phillips Alaska does not intend to request authorization for annular disposal operations in this well. 15. Attachments Attachment 1 Directional Plan Attachment 2 Well Schematic. Attachment 3 Nordic 1 BOP schematic Attachment 4 Exception Request to Rule 20 AAC 25.055 0 RIG IN Ãr ~:~:¡Ú!~ C) ::0 --- t;") --- ~ r-- ... '. ) PROPOSAL REPORT 6 November, 2001 ) Your Ref: Per Dan Venhaus & Tony Hillegeist (wI Phillips) Surface Coordinates: 6000550.46 H, 498655.47 E (70024' 45.8564" H, 150000' 39.4175" W) Surface Coordinates relative to Project H Reference: 1000550.46 H, 1344.53 W (Grid) Surface Coordinates relative to Structure: 439.73 H, 0.05 W (True) Kelly Bushing: 69.00ft above Mean Sea Level ~--" ~r"I""'V-&L.r1 ~:::S:~"IC. ... ffiIIkl:Ntlm c..m,,*,,~ Proposal Ref: pr09680 .. Sperry-Sun Drilling Services Proposal Report for Plan: 3H-16A Your Ref: Per Dan Venhaus & Tony Hillegeist (wi Phillips) Revised: 6 November, 2001 Kuparuk River Unit Measured Sub-Sea Vertical Local Coordinates Depth Incl. Azim. Depth Depth Northings Eastings Section Comment (ft) (ft) (ft) (ft) (ft) 3H-16 0.00 0.000 0.000 -69.00 0.00 498655.47 E 0.00 100.00 0.049 284.062 31.00 100.00 498655.42 E 0.049 0.03 200.00 0.070 271.709 131.00 200.00 498655.36 E 0.025 0.07 300.00 0.869 257.124 231.00 300.00 498654.70 E 0.802 0.68 400.00 4.051 256.430 330.89 399.89 498650.57 E 3.182 4.60 500.00 7.894 260.156 430.33 15.14 W 6000547.32 N 498640.33 E 3.860 14.04 600.00 11.110 262.671 528.94 31.46 W 6000544.91 N 498624.01 E 3.242 28.59 700.00 14.376 265.123 626.46 53.42 W 6000542.57 N 498602.05 E 3.309 47.64 800.00 17.289 269.489 722.67 80.61 W 6000541.45 N 498574.86 E 3.145 70.16 900.00 20.933 269.420 817.13 113.38W 6000541.16 N 498542.08 E 3.644 96.69 1000.00 23.825 9.97 S 151.45W 6000540.52 N 498504.02 E 2.906 127.68 1100.00 26.655 11.02 S 194.05 W 6000539.48 N 498461.42 E 2.831 162.54 1200.00 29.930 12.03 S 241.49 W 6000538.47 N 498413.98 E 3.283 201.28 1300.00 32.136 12.62 S 293.00 W 6000537.89 N 498362.47 E 2.224 243.03 1400.00 35.14 13.50 S 348.34 W 6000537.03 N 498307.13 E 3.052 288.04 AiL 1336.84 1405.84 15.57 S 408.53 W 6000534.96 N 498246.94 E 3.829 337.66 1412.73 1481.73 18.96 S 473.54 W 6000531.59 N 498181.93 E 3.434 391.93 1484.87 1553.87 22.15 S 542.70 W 6000528.41 N 498112.77 E 3.261 449.43 1551.99 1620.99 23.39 S 616.77 W 6000527.18 N 498038.70 E 4.796 509.71 1614.60 1683.60 23.07 S 694.74 W 6000527.51 N 497960.73 E 2.451 572.19 C) 2000.00 54.926 269.878 1673.76 1742.76 22.87 S 775.35 W 6000527.73 N 497880.12 E 2.523 636.87 :::x:. 2100.00 56.082 270.208 1730.25 1799.25 22.86 S 857.86 W 6000527.76 N 497797.61 E 1.188 703.19 --- 2200.00 54.489 271.499 1787.26 1856.26 21.65 S 940.01 W 6000528.98 N 497715.46 E 1.914 768.51 C") 2300.00 54.114 272.881 1845.65 1914.65 18.52 S 1021.12 W 6000532.12 N 497634.34 E 1.183 831.85 --- 2400.00 54.577 273.721 1903.92 1972.92 13.83 S 1102.25 W 6000536.83 N 497553.22 E 0.825 894.28 ~ r-- ) ) 6 November, 2001-15:00 Page 2 of9 DrillQuest 2.00.09.006 t-. Sperry-Sun Drilling Services ,- Proposal Report for Plan: 3H-16A Your Ref: Per Dan Venhaus & Tony HilTegeist (wi PhilTips) Revised: 6 November, 2001 Kuparuk River Unit Measured Sub-Sea Vertical Local Coordinates Depth Incl. Azim. Depth Depth Northings Eastings Section Comment (ft) (ft) (ft) (ft) (ft) 2500.00 54.682 274.315 1961.81 2030.81 8.12 S 0.496 956.27 2600.00 54.812 275.135 2019.50 2088.50 1.42 S 0.682 1017.73 2700.00 54.253 276.513 2077.50 2146.50 6.83N 1.254 1077.96 2800.00 53.408 278.031 2136.59 2205.59 17.11 N 1.488 1136.17 ) 2900.00 53.930 278.050 2195.82 2264.82 28.38 N 0.522 1193.59 3000.00 54.077 278.087 2254.59 497069.53 E 0.149 1251.25 3100.00 54.207 278.500 2313.19 496989.36 E 0.359 1308.70 3200.00 54.768 277.428 2371.30 496908.76 E 1.038 1366.81 3300.00 55.693 277.162 2428.29 496827.26 E 0.951 1426.14 3400.00 56.008 277.472 2484.42 496745.17 E 0.407 1485.86 3500.00 56.105 1992.55 W 6000645.49 N 496662.94 E 0.278 1545.41 3600.00 55.862 2074.66 W 6000656.92 N 496580.83 E 0.266 1604.63 3700.00 55.315 2156.51 W 6000667.27 N 496498.98 E 1.228 1664.28 3800.00 54.553 2237.79 W 6000676.84 N 496417.71 E 0.786 1723.93 3900.00 54.149 2318.46W 6000686.68 N 496337.03 E 0.434 1782.93 2896.49 145.37 N 2398.58 W 6000696.26 N 496256.92 E 0.746 1841.64 2955.79 154.27 N 2478.60 W 6000705.17 N 496176.90 E 0.545 1900.68 3015.74 160.58 N 2558.38 W 6000711.50 N 496097.12 E 2.406 1961.06 3076.18 164.14 N 2637.96 W 6000715.07 N 496017.54 E 1.012 2022.91 3135.30 166.09 N 2718.59 W 6000717.04 N 495936.91 E 1.751 2086.56 3123.58 3192.58 167.15 N 2800.55 W 6000718.11 N 495854.95 E 1.100 2151.82 ) 3179.57 3248.57 167.93 N 2883.40 W 6000718.91 N 495772.10 E 0.726 2217.95 C) 4700.00 56.761 270.512 3234.71 3303.71 168.67 N 2966.82 W 6000719.66 N 495688.68 E 0.460 2284.57 4800.00 57.120 270.247 3289.20 3358.20 169.33 N 3050.67W 6000720.34 N 495604.84 E 0.422 2351.58 ::x:J 4900.00 56.334 268.024 3344.10 3413.10 167.99 N 3134.23 W 6000719.01 N 495521.27 E 2.018 2419.55 --- ~ 5000.00 56.120 267.547 3399.70 3468.70 164.76 N 3217.29 W 6000715.79 N 495438.21 E 0.451 2488.24 5100.00 56.107 267.494 3455.45 3524.45 161.17 N 3300.23 W 6000712.22 N 495355.27 E 0.045 2557.05 --- 5200.00 55.933 267.424 3511.35 3580.35 157.48 N 3383.06 W 6000708.55 N 495272.43 E 0.183 2625.82 ~ 5300.00 55.966 267.484 3567.34 3636.34 153.80 N 3465.84 W 6000704.89 N 495189.66 E 0.060 2694.55 5400.00 55.906 267.544 3623.34 3692.34 150.21 N 3548.61 W 6000701.31 N 495106.89 E 0.078 2763.22 r-- 6 November, 2001-15:00 Page30f9 DrilTQuest 2.00.09.006 "- Sperry-Sun Drilling Services Proposal Report for Plan: 3H-16A Your Ref: Per Dan Venhaus & Tony Hillegeist (wi Phillips) Revised: 6 November, 2001 Kuparuk River Unit Measured Sub-Sea Vertical Local Coordinates Depth Incl. Azim. Depth Depth Northings Eastings Section Comment (ft) (ft) (ft) (ft) (ft) 5500.00 55.717 267.603 3679.54 3748.54 146.71 N 0.195 2831.74 5600.00 55.662 267.593 3735.90 3804.90 143.28 N 0.055 2900.12 5700.00 55.385 266.809 3792.48 3861.48 139.32 N 0.703 2968.68 5800.00 54.807 264.772 3849.74 3918.74 133.22 N 1.767 3038.02 ) 5900.00 54.900 264.530 3907.30 3976.30 125.59 N 0.219 3108.01 6000.00 54.941 264.377 3964.80 494614.75 E 0.132 3178.17 6100.00 55.518 264.042 4021.83 494533.03 E 0.640 3248.79 6200.00 56.068 263.656 4078.05 494450.80 E 0.635 3320.16 6300.00 56.613 263.460 4133.48 494368.09 E 0.569 3392.20 6400.00 57.188 263.324 4188.06 494284.86 E 0.587 3464.85 6500.00 57.309 263.225 4454.15 W 6000622.97 N 494201 .34 E 0.146 3537.84 6600.00 57.400 263.024 4537.76 W 6000612.90 N 494117.72 E 0.192 3611.06 6700.00 57.010 262.935 4621.17W 6000602.65 N 494034.30 E 0.397 3684.22 6800.00 57.234 262.709 4704.47 W 6000592.18 N 493951.01 E 0.293 3757.41 6900.00 58.408 262.427 4788.40 W 6000581.23 N 493867.07 E 1.198 3831.40 4578.62 18.60 N 4873.21 W 6000569.94 N 493782.27 E 0.686 3906.29 4630.89 8.03N 4957.79 W 6000559.38 N 493697.68 E 1.308 3980.58 4683.60 1.92 S 5042.19W 6000549.44 N 493613.28 E 0.426 4054.35 4735.72 12.09 S 5126.92 W 6000539.30 N 493528.54 E 0.200 4128.50 4789.97 21.59 S 5210.38 W 6000529.81 N 493445.09 E 2.698 4201.24 4776.88 4845.88 30.20 S 5292.84 W 6000521.22 N 493362.62 E 0.303 4272.65 ) 4832.38 4901.38 38.76 S 5375.59 W 6000512.67 N 493279.87 E 0.324 4344.26 4888.79 4957.79 47.98 S 5457.63 W 6000503.46 N 493197.83 E 1.691 4415.70 4949.02 5018.02 57.59 S 5536.86 W 6000493.87 N 493118.60 E 3.426 4485.10 . ---.-- -.. .-- ------- 5011.40 5080.40 67.46 S 5614.40 W 6000484.01 N 493041.06 E 0.304 4553.30 CJ ::0 8000.00 52.202 262.408 5073.17 5142.17 77.73 S 5692.36 W 6000473.75 N 492963.09 E 0.731 4622.08 8100.00 52.664 262.104 5134.14 5203.14 88.42 S 5770.90 W 6000463.08 N 492884.55 E 0.521 4691.57 -- 8200.00 53.163 261.875 5194.44 5263.44 99.53 S 5849.89 W 6000451.98 N 492805.56 E 0.531 4761.68 C') 8300.00 53.740 261.667 5253.97 5322.97 111.04 S 5929.41 W 6000440.49 N 492726.04 E 0.601 4832.45 --- 8400.00 53.892 261.499 5313.01 5382.01 122.86 S 6009.26 W 6000428.68 N 492646.19 E 0.204 4903.66 ~ r-- 6 November, 2001 - 15:00 Page4of9 DrillQuest 2.00.09.006 )" Sperry-Sun Drilling Services .. Proposal Report for Plan: 3H-16A Your Ref: Per Dan Venhaus & Tony Hillegeist (wI Phillips) Revised: 6 November, 2001 Kuparuk River Unit Measured Sub-Sea Vertical Local Coordinates Depth Incl. Azim. Depth Depth Northings Eastings Section Comment (ft) (It) (It) (It) (It) 8500.00 54.077 261.469 5371 .82 5440.82 134.83 S 0.186 4975.08 8600.00 54.457 261.314 5430.22 5499.22 146.98 S 0.401 5046.83 8700.00 54.828 261 .222 5488.08 5557.08 159.36 S 0.378 5118.99 8800.00 54.924 260.962 5545.60 5614.60 172.02 S 0.234 5191.49 ) 8900.00 54.852 260.702 5603.13 5672.13 185.06 S 0.225 5264.16 8971.02 54.873 260.517 5644.00 5713.00 492186.45 E 0.215 5315.85 Base HRZ !Top U. Kalubik 8995.00 54.884 260.455 5657.80 5726.80 492167.10 E 0.217 5333.33 Top of Whipstock (800L HS in 7" Casing); Begin Dir @ 15.9°/100ft : 8995.00ft MD, 5726.80ft TVD 7" Casing Window Plan: 3H-16A (wp06) 9000.00 55.026 259.499 6492.36 W 6000353.14 N 492163.07 E 15.900 5337.00 9007.00 55.237 258.167 6498.00 W 6000352.03 N 492157.44 E 15.900 5342.19 Begin Rathole @ 55.2° : 9007.00ft MC 5733.67ft TVD 9025.00 55.237 6512.47 W 6000349.00 N 492142.96 E 0.000 5355.62 Begin Dir @ 14.3°/100ft (in 6" Hole) : 9025.00ft MD, 5743.93ft TVD 5787.14 221.90 S 6570.53 W 6000329.75 N 492084.90 E 14.300 5413.76 5826.00 250.19 S 6617.93 W 6000301.46 N 492037.50 E 14.300 5468.69 K1/Top L. Kalubik 5775.27 5844.27 267.21 S 6638.58 W 6000284.45 N 492016.84 E 14.300 5495.41 5828.63 5897.63 332.30 S 6692.10 W 6000219.37 N 491963.31 E 14.300 5577.15 5831.00 5900.00 335.79 S 6694.21 W 6000215.88 N 491961.20 E 14.300 5580.92 Continue Dir @ 14.5°/100ft : 93047') MD, 5900.000 TVD 9314.94 61.419 210.209 5836.00 5905.00 343.47 S 6698.72 W 6000208.19 N 491956.69 E 14.500 5589.12 Top C4 9400.00 73.280 206.535 5868.71 5937.71 412.46 S 6735.86 W 6000139.21 N 491919.54 E 14.500 5660.00 <:::) 9428.71 77.299 205.411 5876.00 5945.00 437.42 S 6748.01 W 6000114.25 N 491907.38 E 14.500 5684.63 TopA1 ::t:J 9500.00 87.294 202.749 5885.54 5954.54 501.84 S 6776.78 W 6000049.84 N 491878.60 E 14.500 5746.07 -- 9519.28 90.000 202.043 5886.00 5955.00 519.66 S 6784.12 W 6000032.02 N 491871.25 E 14.500 5762.57 Land Horizontal in A 1 ... Continue Dir I C') 14.5°/100ft: 9519.28ft MD, 5955.000 TVD -- 9584.28 90.491 211.455 5885.72 5954.72 577.64 S 6813.35 W 5999974.05 N 491842.02 E 14.500 5820.55 Begin Dir @ 10.0°/1000 (TF @ 88° R ::::: 9584.29ft MD, 5954.72ft TVD :t:=. 3-1/2" Liner 9600.00 90.529 213.026 5885.58 5954.58 590.93 S 6821.73 W 5999960.76 N 491833.63 E 10.000 5835.19 r-- 6 November, 2001-15:00 Page50f9 DrillOuest 2.00.09.006 Kuparuk River Unit Measured Sub-Sea Vertical Depth Incl. Azim. Depth Depth (ft) (ft) (ft) 9700.00 90.759 223.024 5884.45 5953.45 9800.00 90.966 233.023 5882.95 5951.95 9900.00 91.143 243.023 5881.10 5950.10 10000.00 91 .286 253.024 5878.98 5947.98 10100.00 91 .390 263.027 5876.64 5945.64 10166.28 91.435 269.657 5875.00 5944.00 10200.00 91 .475 266.266 5874.14 10300.00 91.560 256.208 5871.49 10400.00 91 .598 246.150 5868.73 10500.00 91.587 236.092 5865.94 10600.00 91.527 226.034 10608.14 91.520 225.216 10700.00 10714.14 5926.16 5851.64 5920.64 5847.00 5916.00 Sperry-Sun Drilling Services Proposal Report for Plan: 3H-16A Your Ref: Per Dan Venhaus & Tony Hillegeist (wI Phillips) Revised: 6 November, 2001 Local Coordinates Northings Eastings (ft) (ft) Global Coordinat, Northings (ft) 10.000 10.000 10.000 10.000 10.000 491356.77 E 10.000 5999699.00 N 491323.09 E 10.054 5999683.81 N 491224.41 E 10.054 5999651.62 N 491129.91 E 10.054 5999603.42 N 491042.48 E 10.054 5999540.69 N 490964.82 E 10.054 5999535.00 N 490959.00 E 10.054 ~ ::.1::.) -"- C") -- ~ r-- 669.60 S 736.39 S 789.27 S 826.64 S 847.36 S 851.58 S 7690.47 W 7696.29 W 1086.47 S 7756.01 W 5999465.39 N 490899.27 E 10.000 1098.00 S 7764.18 W 5999453.85 N 490891.09 E 10.000 1164,72 S 7818.01 W 5999387.15 N 490837.25 E 10.070 1231.18 S 7892.35 W 5999320.70 N 490762.89 E 10.070 1266.89 S 7946.24 W 5999285.00 N 490709.00 E 10.070 All data is in Feet (US) unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to RKB = 69' (MSL). Northings and Eastings are relative to 1107' FNL & 281' FWL. The Dogleg Severity is in Degrees per 100 feet (US). Vertical Section is from 1107' FNL & 281' FWL and calculated along an Azimuth of 233.500° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 10964.85ft., The Bottom Hole Displacement is 8046.60ft., in the Direction of 260.941 ° (True). 6 November, 2001-15:00 Page6of9 5931.44 6030.85 6130.39 6227.05 6317.89 6373.53 6401.32 6489.68 6584.80 6683.75 6783.49 6791.56 6880.98 6894.41 6977.36 7076.66 7141.22 " North Slope, Alaska Kuparuk 3H Comment ) Continue Dir @ 10.05°/1O0ft (TF @ 9( L): 10166.28ft MD, 5944.000 TVD PBHL (500' from Lease Lines) : 10608.14ft MD, 5932.00ft TVD Target - PBHL (3H-16A), Current Targ Continue Dir @ 10.07°/1O0ft (TF @ 8: R): 10714.14ft MD, 5929.21ftTVD Contingent PBHL (250' from Lease Lines): 10964.85ft MD, 5916.000 TV) 2-7/8" Liner Target - Contingent (250 BHL), CUll' Target DrillQuest 2.00.09.006 <:::) :x:J --. C') --. ~ r-- Kuparuk River Unit Comments Measured Depth (ft) 8995.00 9007.00 9025.00 9304.72 9519.28 9584.28 9584.29 10166.28 10608.14 10714.14 10964.85 Formation Tops For (B Sub-Se (ft) 5644.00 5757.00 5836.00 5876.00 6 November, 2001 -15:00 Sperry-Sun Drilling Services Proposal Report for Plan: 3H-16A Your Ref: Per Dan Venhaus & Tony Hillegeist (wI Phi//ips) Revised: 6 November, 2001 Station Coordinates TVD Northings Eastings (ft) (ft) (ft) 5726.80 5733.67 5743.93 5900.00 5955.00 5954.72 5954.72 5944.00 5932.00 5929.21 5916.00 0.000 359.990 0.000 359.990 0.000 359.990 0.000 359.990 Comment 197.78 S 199.60 S 202.63 S 335.79 S 519.66 S gin Dir @ 15.9°/100ft : 8995.00ft MD, 5726.80ft TVD I, 5733.67ft TVD e) : 9025.000 MD, 5743.93ft TVD 04.72ft MD, 5900.00ft TVD A1 ..\;'Continue Dir @ 14.5°/100ft : 9519.28ft MD, 5955.00ft TVD 6488.33 W 6498.00 W 6512.47 W 6694.21 W 6784.12 W Liner Point: 9584.28ft MD, 5954.72ft TVD ... Drill out 3" Hole (w/ Coil) ,Dir @ 10.0°/1 OOft (TF @ 88° R): 9584.29ft MD, 5954.72ft TVD ue Dir @ 10.05°/1 OOft (TF @ 90° L): 1 0166.28ft MD, 5944.00ft TVD PBHL (500' from Lease Lines) : 1 0608.14ft MD, 5932.00ft TVD Continue Dir @ 10.07°/10Oft (TF @ 82° R): 10714.14ft MD, 5929.21ft TVD Contingent PBHL (250' from Lease Lines) : 10964.85ft MD, 5916.00ft TVD Profile Penetration Poi n t easured Vertical Sub-Sea Depth Depth Depth Northings Eastings Formation Name (ft) (ft) (ft) (ft) (ft) 8971.02 5713.00 5644.00 194.53 S 6468.99 W Base HRZ/Top U. Kalubik 9167.59 5826.00 5757.00 250.19 S 6617.93 W K1/ Top L. Kalubik 9314.94 5905.00 5836.00 343.47 S 6698.72 W Top C4 9428.71 5945.00 5876.00 437.42 S 6748.01 W TopA1 Page 70f9 ,. North Slope, Alaska Kuparuk 3H ) ) DrillQuest 2.00.09.006 Target Name Sperry-Sun Drilling Services Proposal Report for Plan: 3H-16A Your Ref: Per Dan Venhaus & Tony Hillegeist (wI Phillips) Revised: 6 November, 2001 Kuparuk River Unit North Slope, Alaska Kuparuk 3H Casing details From Measured Vertical Depth Depth (ft) (ft) To Measured Vertical Depth Depth (ft) (ft) Casing Detail <Surface> 8800.00 <Surface> <Surface> 5614.60 <Surface> 8995.00 9584.28 10964.85 5726.80 5954.72 5916.00 7" Casing Window 3-1/2" Liner 2-7/8" Liner ) Targets associated with this well path PB Target Entry Coordinates TVD Northings Eastings Target Target (ft) (ft) (ft) Shape Type 5955.00 519.68 S 6784.38 W Point Mean Sea LeveVGlobal Coordinates: 5886.00 6000032.00 N 491871.00 E Geographical Coordinates: 70024' 40.7146" N 150003' 58.3008" W 5916.00 1266.89 S 7946.24 W Point Current Target Mean Sea Level/Global Coordinates: 5847.00 5999285.00 N 490709.00 E Geographical Coordinates: 700 24' 33.3540" N 150004' 32.3374" W 5932.00 1016.85 S 7696.29 W Polygon Current Target Mean Sea Level/Global Coordinates: 5863.00 5999535.00 N 490959.00 E ) Geographical Coordinates: 70024' 35.8159" N 150004' 25.0183" W Target Boundary Point #1 5932.00 516.85 S 7696.38 W #2 5932.00 1016.85 S 7696.29 W #3 5932.00 1016.76 S 7196.29 W #4 5932.00 1016.85 S 7696.29 W A1 Target (3H-16A) C) ::x::. ---- C') ---- <: :t::::.. r-- 6 November, 2001 - 15:00 Page 8 of9 DrillQuest 2.00.09.006 C) :::J:J -""", ~) --- S r-- Sperry-Sun Drilling Services Proposal Report for Plan: 3H-16A Your Ref: Per Dan Venhaus & Tony Hillegeist (wI Phillips) Revised: 6 November, 2001 Kuparuk River Unit Target Name Targets associated with this well path (Continued) 6 November, 2001- 15:00 Page90f9 60ÖÕO35.00 N 5999535.00 N 5999535.00 N 5999535.00 N 490959.00 E 490959.00 E 491459.00 E 490959.00 E 70024' 40.7338" N 150004' 25.0361" W 70024' 35.8159" N 150004' 25.0183" W 70024' 35.8217" N 150004' 10.3619" W 70024' 35.8159" N 150004' 25.0183" W .... .. North Slope, Alaska Kuparuk 3H Target Shape Target Type ) ) DrillQuest 2.00.09.006 ~ ~ " Sperry-Sun Drilling Services Proposal Data - Plan: 3H-16A - Plan: 3H-16A (wpO6) 6 November, 2001 - 14:29 - 1 - 0 RIG IN A L DrillQuest (' 4111 LlIP~ -8100 I Scale: 1 inch = 300ft -7800 I -7500 I Eastings -7200 I I~ Phillips Alaska, Inc. North Slope, Alaska Kuparuk River Unit -150- 3H-16A (wpO6) -6900 I -6600 I Top of Whipstock (80'LHS in 7" Casing); Begin Dir @ 15.9'1.1oolt: 8995.00II MD, 5726.801t TVD Begin Rathole @ 55.2' : 9007.00II MD, 5733.67ft TVJ;( \ Begin Dir@14.3'/100ll(in6"Hole):9025.OOItMD. 5743.93ft ~ ~ \,' ----~~ - -150 -450 - Land Horizontal in A1 ... Continue Dir @ 14.5'/10011: 9519.28ft MD,5955.OOItTVD ------.. ~ '"" '", ~ - -450 Reference is TRUE North Well: Horizontal Coordinates: Ref. Global Coordinates: Ref. Structure: Ref. Geographical Coordinates: Plan: 3H-16A (/) C> c 1: 1:: 0 Z $-1/2" Uner Point: !15M. 28ft MD, 5954.7211 TV!)... Drill. out 3" Hole (w! CoN) Begl.n Vir @ 1(J,(nI0Oft (TF '" 88' A): 9584.29/t MD. 5954. 72ft TVD (1688' FNL II< 1253' FEL, SI"C. 1(J-Tt2N-R8E) Current Well Properties -750 - Continue Dir @ 10.05'1.1001t (TF @ 90' L): 1 0166.28ft MD, 5944.0011 TVD \ ) RKB Elevation: North Reference: Units : 6000550.46 N, 498655.47 E 439.73 N. 0.05 W 70' 24' 45.8564" N, 150' 00' 39.4175" W 1107' FNL&281' FWL, SEC. 12.T12N-R8E 69.00ft above Mean Sea Level True North Feet (US) - -750 -F8r"r"V-.U1 ÖAIL,),.,~Nt3, '$f!J~vrè:@ ~ "IWII~ ~ -1050 - - -1050 CD ~ cr: <::::::i 5800 ::J:f ~ ~ --..;> ;ë:: ~ 6000- r-- ~~<;;J .~, A?,'i>'? _\<;;J ...CJ~'i>'--<;;J."" A~'\' ~<;;J ",' ~.... :1~:O' çJ?J~ ",v.'i> ~",<;:J ._<;;J.'" ",1~'!o. ,...~r;) ~"'/j r;¡~"" ~<;;J. ,^'i>~ov' cg\\r;) . ",ç¡C1' ",<;:J~ ~~" \",. 1: . ",<:$I) <,rJl° Q~@) @)""". ov.o""'" -1350 '1>0""'" ,<-~'S'ð-0 ~"",'ij <¡,è" -S\\r;) '~~~.", ~<fJ9/ .' Q~@)\~' ,;.",t'-- <¡'0~" 2.7/8' LIner 10964.8ft MD 5916.0ftTVD Scale: 1 inch = 300ft - -1350 5600 - <J\\r;¡~~<;;J \~. ()~ Q"@) Q¡<:§J'iJ ~",-,>0 ~p.'3 v~~~~~ <J\\ç¡C'I¡." \~. Q"@) vrfi'"",.:f' ~\"I'-\;Ò'l¡.~ r:f-<J> """". v.°~:V ~ .""" \7>,,1> ?,ç,~ ~ /"'<0\"" l /' çfS "",. ~(\~@ r;¡<J\\ç¡:;~~<;;J \". ç¡C'I¡. Q\' @ """~~' vo~Ij"~~;ç,'I¡. ~<;;J. \,,\'<r / \9~d>9 . -8100 -7800 -7500 -7200 -6900 /' .... , -6600 / ~" ö'~. / > rt ~- / ,.'" , / """",j.'O/ @'b /' ,;";,\\",-".,,,'¡'\ ~; .'?' , <J' "",'>"vW / / ,~<§, . . ,)/ ..§>'f'-_,<;) /,'~~ ,~d \\,~\,.~:..' \V'~ '" / '\' ,,- \ v è." ~~ ^ / //~",\,,'þ"'v)\~""i,);'/ ""~ "-,,,,- / "'\~'9"IJ-~ (ii" ",t~" \\\"\",,.,\,';,/ @"",d,'Þ' .è<$"""'I::~\')'Y '\1..,ß'/' Q~-~' /.ø'\\"""~;';\'þ,,{,/, ..: \,':'/ /', .,," ~",. ( (.."~ .:, \~ ".". / \ ;y.\>; / C,o<!-~""~ \ " . ~\'o/ .. ",<fJ9 '/ .....r;¡ '\"'" .' \<þ<fJ9 0/ .:'1 \9#9' . ..:A. 3H-16A (wpO6) ..;j' ) ,@f'9 . ""'" 3-1/2" Liner 95B4,3ft MD 5954.711 TVD 5300 5500 Scale: 1 inch = 200ft 5700 5900 6100 6300 6500 6700 6900 7100 DriliQuest 2.00.09.006 .. ,,> Phillips Alaska, Inc. 3H-16A (wpO6) MD Inc Azim. SSTVD TVD N/S EIW Y X DLS V.S. Comment ) (ft) (Deg) (Deg) (ft) (ft) (ft) (ft) (ft) (ft) (0/100ft) (ft) 0,00 0.00 0,00 -69.00 0.00 0.00 N 0,00 E 6000550.46 N 498655,47 E 0.00 0.00 ~l~R~=~ryM,&L~~~~ 8971.02 54.87 260,52 5644,00 5713.00 194.53 S 6468.99 W 6000357,09 N 492186,45 E 0.22 5315.85 Base HRZ í Top U. Kalubik 8995.00 54.88 260.46 5657.80 5726.80 197.78 S 6488.33 W 6000353.85 N 492167.10 E 0.22 5333.33 Top of Whipstock (800L HS in 7" Casing) 9007.00 55.24 258.17 5664.67 5733.67 199.60 S 6498.00 W 6000352.03 N 492157.44 E 15.90 5342.19 Begin Rathole @ 55.2° 9025.00 55.24 258.17 5674.94 5743.94 202.63 S 6512.47 W 6000349.00 N 492142.96 E 0.00 5355.63 Begin Dir @ 14.3°/100ft (in 6" Hole) 9167.59 55.34 233.30 5757.00 5826,00 250.19 S 6617.93 W 600030 î.46 N 492037.50 E 14.30 5468.69 K1 í Top L. Kalubik 9304.72 60.00 210.70 5831.00 5900.00 335.79 S 6694.21 W 6000215.88 N 491961.20 E 14.30 5580.92 Continue Dir @ 14.5°/100ft 9314.94 61.42 210.21 5836.00 5905.00 343.47 S 6698,72 W 6000208.19 N 491956.69 E 14.50 5589.12 Top C4 9428.71 77.30 205.41 5876.00 5945.00 437.42 S 6748.01 W 6000114.25 N 491907,38 E 14,50 5684.63 Top Ai 9519.28 90.00 202.04 5886.00 5955.00 519.66 S 6784,13 W 6000032.02 N 491871.25 E 14,50 5762.57 Land Horz in Ai '" Continue Dir @ 14.5"!100ft 9584.28 90.49 211.46 5885.72 5954.72 577.64 S 6813.35 W 5999974.05 N 491842.02 E 14.50 5820.55 3-1/2" Liner; Drill 3" Hole (wI Coil) @ 10.00/100ft (TF 88°R) 10166.28 91.44 269.66 5875.00 5944.00 851.58 S 7298.55 W 5999700.19 N 491356.77 E 10.00 6373.53 Continue Dir @ 1 0.05°/1 OOft (TF @ 90° L) '!O608.14 91.52 225.22 5863.00 5932.00 tO16.85 S 7696,29 W 5999535.00 N 490959,00 E 1005 6791.56 PBHL (500' from Lease Lines) 10714.14 91.49 214.61 5860.21 5929.21 î 098.01 S 7764.18 W 5999453.85 N 490891.09 E 10.00 6894.41 Continue Dir @ 1 0.07°/1 OOft (TF @ 82° R) 10964,85 94.45 239.72 5847.00 5916.00 1266.89 S 7946,24 W 5999285.00 N 490709.00 E 10.07 7141.22 Contingent PBHL (250' from Lease Lines) ) C) ::t:J -....... ~ -- ~ r-- ': , Company: Field: Reference Site: Reference Well: Reference Wellpath: ,-..., Sperry-Sun Anticollision Report Phillips Alaska Inc. Kuparuk River Unit Kuparuk 3H Pad 3H-16 3H-16A Date: 11/6/2001 Co-ordinate(NE) Reference: Vertical (TVD) Reference: GLOBAL SCAN APPLIED: All wellpaths within 200'+ 100/1000 of reference Interpolation Method: MD Interval: 50.00 ft Depth Range: 8995.00 to 10964.85 ft Maximum Radius: 1293.45 ft Survey Program for Definitive Well path Date: 10/29/2001 Validated: No Planned }'rom To Survey ft ft 69.00 8995.00 8995.00 10964.85 Casing Point~ 3H-16 Planned: 3H-16A (wp06) V1 MD TVD Diameter Hole Size ft ft in in 8992.00 5725.07 7.000 8.500 9577.84 5954.77 3.500 6.000 10958.37 5916.46 2.875 3.000 7" 3-1/2" 2-7/8" Summary <--______m_mmm- Offset Wellpath ----------------------> Site Well Wellpath Kuparuk 3H Pad Kuparuk 3H Pad Kuparuk 3H Pad Kuparuk 3H Pad Kuparuk 3H Pad Kuparuk 3H Pad Kuparuk 3H Pad Kuparuk 3H Pad Kuparuk 3H Pad Kuparuk 3H Pad Kuparuk 3H Pad Kuparuk 3H Pad Kuparuk 3H Pad Kuparuk 3H Pad Kuparuk 3H Pad Kuparuk 3H Pad Kuparuk 3H Pad Kuparuk 3H Pad Kuparuk 3H Pad Kuparuk 3H Pad Kuparuk 3H Pad Kuparuk 3H Pad Kuparuk 3H Pad Kuparuk 3H Pad Kuparuk 3H Pad Kuparuk 3H Pad Kuparuk 3H Pad Kuparuk 3H Pad Kuparuk 3H Pad Kuparuk 3H Pad Kuparuk 3H Pad Kuparuk 3H Pad Kuparuk 3H Pad 3H-06 3H-08 3H-09 3H-10 3H-11 3H-12 3H-13 3H-13 3H-14 3H-14 3H-14 3H-15 3H-16 3H-17 3H-18 3H-19 3H-20 3H-21 3H-22 3H-23 3H-23 3H-24 3H-25 3H-25 3H-25 3H-25 3H-26 3H-28 3H-28 3H-28 3H-31 3H-32 3H-32 3H-06 V1 3H-08 V1 3H-09 V1 3H-10 V1 3H-11 V1 3H-12 V1 3H-13 V2 3H-13A V1 3H-14 V1 3H-14A PB1 VO 3H-14A PB2 VO 3H-15 V1 3H-16 V1 3H-17 V1 3H-18 V1 3H-19 V1 3H-20 V1 3H-21 V1 3H-22 V1 3H-23 V1 3H-23A VO 3H-24 V2 3H-25 V1 3H-25A PB1 VO 3H-25A PB2 V1 3H-25A V4 3H-26 V1 3H-28 VO 3H-28A VO 3H-28PB1 VO 3H-31 V2 3H-32 VO 3H-32PB1 VO Version: Toolcode GCT-MS MWD Name Reference MD It 9000.00 2 Offset MD It 9000.00 Reference: Error Model: Scan Method: Error Surface: r-\ Time: 15:13:54 Well: 3H-16, True North 3H-16A @ 69.069.0 Page: 1 Db: Oracle Principal Plan & PLANNED PROGRAM ISCWSA Ellipse Trav Cylinder North Ellipse + Casing Tool Name Schlumberger GCT multishot MWD - Standard Ctr-Ctr No-Go Distance Area It It Allowable Deviation It 0.03 -0.44 0.47 Warning Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range FAIL: No Errors Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out 01 range Out 01 range Out of range Out of range Out 01 range Out 01 range ORIGINAL " !rl, ; il',! ! q¡¡¡ . j' Ii' ~ 'J II' ¡I., . " ¡!,I!! 'HI :,Jj ¡ I' HJ lUll ¡! ¡ , I , If! " H !, H ~ J n~j L-¡ H.. L~~ qu OJ ,¡ " ! ! 11 ip ¡ ¡ í! 'I II " Ii .., ",......, ~~~mmm~ !I ¡ I iI/II ¡ m~mmm ^ ,.-., \ò' ~ ~ ..::. ¡ I mmm¡¡¡¡ . """""'" 'T""""" ~!,!;mmm - .§ ~ '1::1 ~ .. E: ~ ~ I:::::::::::::: !!mmmm '¡mmmm 'mmm:m ,--"_....,,.. â ~ - 'i .- ~ Ii 3 . ð , ~ ~ ~ ~ ~ ~ ~ J ,! III ¡ ¡¡ ¡ ¡ i ¡¡ ¡ j í ~ " . I í OR/G/^AL ,,-.., KRU 3H-16A Prod,,-~er Proposed Completion " -- 9-518" 36# J-55 @ 3943" Liner top and Whipstock Depth's are based on Original RKB to the hanger from the 7" Csg Detail. These depths need to be converted to Nordic RKB. 4-1/2" liner top @ +/-8850' MD Top of Whipstock & KOP at +/-9002' MD Window in 7" Bridge Plug at +/-9020' MD Baker PBR at 9146' MD Abandoned Perfs C-Sand Perfs """ A-Sand Perfs -=<, 7" 26# J-55 @ ~ 9707 MD' ~ J PHilliPS Alaska, Inc. A Subsidiary of PHILLIPS PETROLEUM COMPANY H. 3-1/2" 5M McEvoy tubing hanger with 3-1/2" L-80 EUE 8rd pin down. G. 3-1/2" 9.3# L-80 EUE 8rd Mod Tubing to surface. iii F. 3-1/2" Cameo TAM' SSSV set at +1-1800' MD, 2.813" ID E. 3-1/2" 9.3# L-80 EUE 8rd Mod tubing to 'X' landing nipple wI 3-1/2" x 1" Cameo 'KBUG' mandrels wI DV's, spaced out as follows: .. GLM# MD TVD 1 3365' 2537' 2 6664' 4403' 3 8697' 5558" Note: Each GLM should have 6' L-BO handling pups installed on top and bottom. D. 3-1/2" x 1-1/2" Cameo 'MMG' Mandrel at +1-8815' MD wI DCA Dump Kill Valve (3000 psi casing to tubing shear). 6' L-80 handling pups installed on top and bottom of mandrel. C. 1 joint 3-1/2" 9.3# L.80 EUE 8rd Mod Tubing -- B. 3-1/2" HES 'X'selective landing nipple with 2.813" ID (necessary for 2.8" CTD mill/bits) A. Baker 3-1/2" 'GBH-22' Tubing Seal Assembly wI 17' of effective seals and special locator to locate in liner tie back sleeve. Locator 5.125" OD, seals 4.0" OD. 6' L-80 Handling Pup Joint installed. Liner TOD Baker 5" x 7" 'C-2 ZXP' Liner Top Isolation Packer and 6' setting sleeve wI 5" BTC Box Down. Baker 5" x 7" 'Flex-Lock' Hydraulic Liner Hanger wI 5" BTC Pin x Pin. Baker '80-40' SBE (20' Length wI 4" ID seal bore). 3.1/2" NSCT pin down. Solid Liner 3-1/2" 9.3# L-80 EUE 8rd Mod from Liner Hanger to Landing Collar. 3-1/2" EUE 8rd Mod Baker Landing Collar. 1 joint 3-1/2" L-BO EUE 8rd Mod. 3-1/2" EUE 8rd Mod Baker Float Collar. 2 joints 3-1/2" L-BO EUE 8rd Mod tubing. 3-1/2" EUE 8rd Mod Baker Float Shoe. §¡ C-Sand 2-3/8" liner top @ 9484' md '-- ~ III 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 D , 3-1/2" shoe @ 9,584' md A-Sand CTD 3" hole to +1-10,960' md. Complete wI 2-3/8" pre-drilled liner .... DEV 11/06/01 ORIGINAL ~ "" ~ Nordic CTD BOP Detail '- I I ~ t=e= HCR I ~ J 7-1/16" ID, 5000 psi working pressure Jr= Ram Typ" O"al Gale BOPE I TOT ~ Manual over Hydraulic I' I XO Spool as necessary \ / I I @) I I ~ ffUI I f Methanol Injection blLð gtis 7" WLA Quick I' onnect - I 7-1/16" ID, 5000 psi working pressure If Ram Type Dual Gate BOPE Manual over Hydraulic TOT Flanged Fire Resistant Kelly Hose to Dual Choke Manifold Swab Valve DEV 02114/01 I °'\l \ -CT Inlector Head -- Stuffing Box (Pack-Off), 10,000 psi Working Pressure """- - 7" Riser , I I I " Annular BOP (Hydril),7-1/16" ID 5000 psi working pressure .J I I ~' , 1 Blind/Shear I @ ., I 2" Comb' PipelSllp I 1lØa1EBJ ít ~ ralve Fire resistant Kelly Hose to Flange by Hammer up 1/4 Turn Valve on DS Hardline to Standpipe / manifold I 23/8" Combi Pipe/Slip I 2" Combi Pipe/Slip I I 2 flanged gate valves Production Tree ORIGIIVAL . ,- . P1fllU~ ".-...., W PHilliPS A.dska, Inc. A Subsidiary of PHILLIPS PETROLEUM COMPANY .,-" " ~ , P. O. BOX 100360, ATO-1482 ANCHORAGE, ALASKA 99510-0360 Telephone 907- 263-4076 Facsimile 907- 263-4966 Paul K. Wharton Sr. Landman November 8, 2001 via Certified Mail Return Receipt Requested Chairman Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage, Alaska 99501 Re: Request for Exception to 20 AAC 25.055 3H-16A Kuparuk River Unit Dear Chairman: Phillips Alaska, Inc. ("Phillips" or IIPAIII) hereby applies for an exception to the provisions of 20 AAC 25.055 for the drilling of the Kuparuk River Unit (IIKRUII) well 3H-16A (the "Well"). This application is made by Phillips in its capacity as Unit Operator on behalf of itself and the other working interest owners, BP Exploration (II Alaska") Inc. ("BPX"), Union Oil Company of California ("Unocalll), ExxonMobil Production Inc. ("ExxonMobil" or "EMAplI), and Chevron U.S.A. Inc. ("Chevronll). The Well will be drilled as a directional hole having the following locations: Suriace Location: Target Location: Bottomhole Location: 1104' FNL, 4997' FEL, Section 12, T12N, R08E, UM; 1547' FSL, 1188' FEL, Section 10, T12N, R08E, UM; 2378' FNL, 2387' FEL, Section 10, T12N, R08E, UM. The suriace location is within ADL 25531. The target location and bottomhole location are all located within ADL 25532. The projected bottom hole location may fall within 500 feet of the property line of the Kuparuk Participating Area ("KPA") within Section 10, T12N, R08E, U.M. ,Alaska. The ownership of the lease ADL 25532 is as follows: PAl: BPX: 55.293767% 39.282233% Phillips Alaska Inc. is a Subsidiary of Phillips Petroleum Company ORIGINAL " . Alaska Oil and Gas Conserv"""-"'î Commission November 8, 2001 Page 2 Unocal: EMAP: Chevron: total: ~ , ,. , ~~ 04.950600% 00.364800% 00.108600% 100.000000% The ownership of the KP A is as follows: PAl: BPX: Unocal: EMAP: Chevron: total: 55.166700% 39.102000% 04.950600% 00.582100% 00.108600% 100.000000% The attached Exhibit 1 shows a Plat of the location of the Well and all other adjoining governmental quarter sections and wells. There are no other completed or drilling wells on the property. The names and addresses of all owners and operators of the governmental quarter sections directly and diagonally offsetting the Well are set forth in the attached Exhibit 2. These owners have been notified of even date herewith by mailing a copy of this application to the owners via certified mail at their addresses as stated on Exhibit 2. The attached Exhibit 3 is the verification required by the referenced code provisions. Well completion is expected to occur within the Second Quarter of 2002. Please call the undersigned with any questions you may have. ~ truly yours, . {,)j IJ ÍAI~1Ø-v 9a utKw tfa rt 0 n Senior Landman Attachments ORIGINAL . .. ;' Alaska Oil and Gas Conserv~ Commission .. November 8, 2001 Page 3 .-.. ..~ EXHIBIT 2 List of all owners and operators of governmental quarter sections directly and diagonally offsetting the KRU 3H-16A. Operator: Phillips Alaska, Inc. 700 G Street P.O. Box 100360 Anchorage, Alaska 99510-0360 Non-Operators: BP Exploration (Alaska) Inc. 900 E. Benson Blvd P.O. Box 196612 (MB4-2) Anchorage, Alaska 99519-6612 Union Oil Company of California 909 West Ninth Avenue P.O. Box 196247 Anchorage, Alaska 99519-6247 ExxonMobii Alaska Production Inc. 3301 C Street, 4th Floor P.O. Box 196601 Anchorage, Alaska 99519-6601 Chevron U.S.A. Inc. P.O. Box 36666 Houston, Texas 77236 Royalty: State of Alaska Department of Natural Resources Division of Oil and Gas 3601 C Street, Suite 1380 Anchorage, AK 99503-5948 ORIGINAL --~._--"-----"--..--_. - " ."... Alaska Oil and Gas Conse~n Commission November 8, 2001 Page 4 - -., " ~ .. EXHIBIT 3 TO THE ALASKA OIL AND GAS CONSERVATION COMMISSION Before the Commissioners of the Alaska Oil and Gas Conservation Commission in the Matter of the Request of Phillips Alaska, Inc. for an Exception to the Provisions of 20 MC 25.055 for Kuparuk River Unit well 3H.16A STATE OF ALASKA VERIFICATION OF FACTS AND AFFIDAVIT OF John Golden §§ THIRD JUDICIAL DISTRICT John Golden, being first duly sworn, upon oath, deposes and states as follows: 1.My name is John Golden. I am over 19 years old and have personal knowledge of the matters set forth herein. 2. 3. I am a Surveillance Engineer for the well operator, Phillips Alaska, Inc. ("PAl"). I am acquainted with the facts associated with the drilling of Kuparuk River Unit well 3H-16A. 4. I have reviewed the application submitted for the exception to 20 MC 25.055. To the best of my knowledge and belief all facts therein are true and accurate. 5. I have reviewed the plat attached as Exhibit "1" and it correctly portrays pertinent and required data. 6. Pursuant to 20 MC 25.055 (b), PAl, the well operator, prepared a Notice of Request for Exception to the Provision of 20 MC 25.055. A copy of this notice is attached hereto. 7. On November 8, 2001, pursuant to 20 MC 25.055 (b), PAl sent a copy of said notice by certified mail to the last known address of all owners and operators of governmental quarter sections directly and diagonally offsetting the governmental quarter section of the proposed location of PAl's Kuparuk River Unit well 3H-16A. These names and addresses are set forth on Exhibit 2 attached to PAl's Request for Exception to Provisions of 20 MC 25.055 dated November 8, 2001. Subscribed and sworn to this 8 day of November, 2001.~ -M...~ðø& JUin Golden ~~EOFALASKA ) ) §§ ) ) THIRD JUDICIAL DISTRICT This instrument was acknowledged before me this 8th day of November, 2001, by John Golden. '4<.a:t y.I- XQ.. 8o-u- Notary ~Ul5lic, State- o~laska (. / If/ól..OC> 3 ~\\\\\\\III/ 11/ III/!I,. ~- \-\. ~ "";~~,. ~I ~ """"""',~.ð '~.i:'.~ ~ ~,"~1S8/01)i-.',,7G-\:>:. § ,C; '1i>. ' ~- ~/:F \\~ = f NOTARY 1 == ~... \. PUBLIC ./ .~ ~ cJ'I', v! ,'::;:: ~ :?'.'"lIl)es ~",.1.~ ~ ~ -1l';':"";""'~C:J~ ~ ~ ç OF þ..\..f' ~ '1111111/1/ II\I\\\\\\~ My Commission Expires: ORIGINAL o,-'h---___-.--. ~ ~ .. ""~ .~ .- Þ.. 3M-28 3M-21 . .... 3M-22 3M-29 . . 3H-24 .... 3H-3 ~ 38.21 Å . Å 3H-22 Å 3H-~~P.l 3H-28A 3H-23A . . 3H-19 3H-17 3H-20 3H-23 . .... . ... ... ... 3H-13A 3H-14 3H-25 3H-18 3H-15 3H-13. 3H-12 ... .. Å þq .. Å 3H-16 . 3H-16A BHL . 3H-06 Å 3H-O8 . 3H-IO ... 3H-ll . 3H.;26 . KALUB; CREE. 1 3H-....O7 3H-O5 . 3H-O9 Å 3H-04 . ADL-25532 ADL-25531 3G-24 .... 3H-Ol . 3H-O2 þq 3H-O3 . KP A Boundary ~ 3G-17 3G-25X . . 3G-IO Å 3G-2"J . 3a-~ . I 3G-15 3G-ll . 3G.oS . 1*6000 FEET 0 5000 FEET ~ METERS 0 I 1000 J 20130 METERS I ~----..........., ..~~~~~~ ~"" '"~OS'" 8H=J ORIGINAL Re: 3H.16A kUI-weight fluid ~ 1""""'0, Subject: Re: 3H-16A kill-weight fluid O.te: Tue, 27 Feb 200110:24:34 -0800 From: Tom Maunder <tom_maunder@admin.state.ak.us> To: IfVenhaus, Dan Elf <VenhauDE@BP.com> Dan, Your proposal does make sense. I appreciate your consideration of "delaying" situations that could affect timely delivery of the proper kill weight fluid to the rig. Good luck with the operations. Tom Maunder "Venhaus, Dan E" wrote: > Tom, > > Per our telephone discussion today, the following request is approved: > > During the 3H*16A pre-spud meeting last week, we discussed how to better > plan for kill-weight fluid on location. Past experience over the last 5 ' > Kuparuk wells has shown that reservoir pressures somewhat different from > expected have resulted in large amounts of wasted kill*weight fluid. The > coil rigs are unable to make large comwtions in fluid weight. Also, the > use of highly overbalanced kill-weight fluid on 3A-03A, may be a > contributing to its inability to flow. > > Our request to alleviate some of this problem is to delay having KWF on > location until the milling BHA has breached the casing/cement, thereby > giving us a current formation pressure. This well, 3H-16, and offset > injectors have been shut-in since the last static pressure survey to drop > the pressure. This information is now 3 weeks old. > > We plan on having a dedicated vac truck on standby at the MI Mud plant when > milling begins. Once the formation pressure is known, the fluids can be > properly weighted and delivered to the rig in a timely manner. Per your > request, milling operations wiJI not begin if weather conditions will > prevent the truck from getting to location. > > Current status of Nordic 1.. the rig is finishing modifications and plans to > move sometime tomorrow to the 3H pad. > > Thank you. > > Dan Venhaus > 263-4372 PAl > 564-5273 bP > 230-0188 cell Tom Maunder <tom maunder@admin.state.ak.us> Petroleum Engineer Alaska Oil and Gas Conservation Commission 1 of2 2I271O111:38AM 1-.. ,-ì. !? !e '-"-' lID~!Æ ~ !Æ~:~!Æ J I ,I I I I / J í ¡ TONY KNOWLES, GOVERNOR AltASIiAOILAND GAS CONSERVATION COMMISSION 333 W. 7'" AVENUE. SUITE 100 ANCHORAGE. ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Lamar Gant Coil Tubing Drilling Engineer Phillips Alaska, Inc. POBox 100360 ~chorage,AJ( 99510-0360 Re: Kuparuk River Unit 3H-16A Revised Phillips Alaska, Inc. Permit No: 200-022 Sur Loc: 1104'FNL, 4997'FEL, Sec. 12, T12N, R8E, UM Btmhole Loc. 752'FNL, 3188'FEL, Sec. 10, TI2N, R8E, UM Dear Mr. Gant: Enclosed is the approved revised application for permit to drill the above referenced well. The revision is for a change in bottom-hole location. The provisions of the original approved permit dated March 22, 2000, are in effect for this reVISIon. Sincerely, Ju-cCU 1IA I ~(.V~ Julie M. Heusser Commissioner BY ORDER OF THE COMMISSION DATED this '1~ day of February, 2001 dlfÆnclosures cc: Department ofFish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. bp ,?-, ,"""", .~~ ,\If.'II. ...,~ ~#... ~..- ~..-- 4'~ ¡:,~ .'I~.li\~ ". BP Exploration (Alaska) Inc, 900 East Benson Boulevard P.O, Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 January 4,2001 Julie Heusser, Dan Seamount, & Cammy Oechsli Taylor Alaska Oil & Gas Conservation Commission 333 West ih Avenue Suite 100 Anchorage, AK 99501 Fax 276-7542 Dear Commissioners: Re: 3H-16A Revised Permit to Drill (permit #200-022) Originally, a 3H-16A Permit to Drill was submitted to the AOGCC and approved on 3/22/2000. Since then, the proposed TD of the well has changed to a new location. I have resubmitted the permit with attachments to reflect that change for your review and approval. If you have any questions concerning this revision, please don't hesitate to call me at 564-5799 or E-mail me at raufpc@bp.com. ~:~~ 4( Paul C. Rauf Technical Assistant, BPXA Alaska Drilling & Wells RECEIVED JAN 0 5 2001 Alaska O" & Gas Cons. Commission Anchorage ;--., , .. ..-, STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 1a. Type of work: Drill D Redrill 0 Re-entry D Deepen D 2. Name of Operator Phillips Alaska, Inc. 3. Address P.O. Box 100360 Anchorage, AK 99510-0360 4. Location of well at surface 1104' FNL, 4997' FEL, Sec. 12, T12N, R8E , UM At top of productive interval 1348' FNL, 1178' FEL, SEC. 10, T12N, R8E, UM At total depth 752' FNL, 3188' FEL, Sec 10, T12N, R8E, UM 12.[1~~/.!'-~to.n,earßst prope~y line I 13. Distance to nearest well O'¿:5"3~ßDL~ 51í4~-fÞ TO 311ß feet No Close Approach , 16. To be completed for deviated wells Kickoff depth: 9320' MD 18. Casing program size £ v;} 0.. ðM ~ V\1/ Revised 1/5/2001 1b. Type of well. Exploratory D Stratigraphic Test D Service D Development Gas D Single Zone 0 5. Datum elevation (DF or KB) RKB 76 feet 6. Property Designation «>'2..5531 &. ADL 25532 of ~ 2658 7. Unit orpropertý"mme Kuparuk Unit 8. Well number 3H-16A 9. Approximate spud date February 1, 2001 14. Number of acres in property 25C40 17. Anticipated pre~~~ee~35 (e)(2)) Maximum surface ~pslg .tr~ít~t~1 depth (TVD) Setting Depth Top Bottom TVD MD TVD 5844' 11642' 5949' Maximum hole angle Hole 2-3/4" Specifications Grade Coupling L-80 FL4S Length 2447' Casing 2-3/8" Weight 4.6 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condnion summary Total Depth: measured 9770 feet true vertical 6178 feet Effective Depth: measured 9496 feet true vertical 6017 feet Casing CONDUCTOR SUR. CASING PROD. CASING Length 110' 3867' 9632' 7" Size 16" feet 91° MD 9195' Plugs (measured) Development Oil 0 Multiple Zone Ii] .41:> 10. Field and Pool Kuparuk Field Kuparuk Oil Pool 11. Type Bond (see 20 AAC 25.0251) Statewide Number #U~ 57 $'2.. /80 Amount -<-'1> $200,000 15. Proposed depth (MD and TVO) 11642 MD / 5949 TVD 3975 psig @ 5921' Quanmy of Cement (include stage data) 15 bbls Tagged PBTD @ 9496' MD on 3/28/1998. Junk (measured) 9-5/8" Cemented 200 Sx AS I 1600 Sx AS III & 400 Sx Class G 400 Sx Class G & 175 Sx AS I Measured depth 110' 3943' 9708' Perforation depth: measured 9315' - 9391'; 9440' - 9460'. true vertical 5913' - 5956'; 5984' - 5996'. True Vertical depth 110' 2866' 6142' RECEIVED JAN 0 5 2001 Alaska Oil & Gas Cons. Commission Anchorage 20. Attachments Filing fee 0 Property Plat D BOP Sketch 0 Diverter Sketch D Drilling program 0 Drilling fluid program Time vs depth plot D Refraction analysis D Seabed report D 20 AAC 25.050 requirements D 21. I hereby certify that the for oi ue and correct to the best of my knowledge Questions? Call Dan Venhaus @ 253-4372 (office) /230-0188 (cell). Signed . t/ ~ Title: Coil Tubing Drilling Engineer Date I - 5 -ð I Lamar Gantt f) 1J2.K... ~ L,L. ¿,~ Prepared by Paul Raul 564-5799 Commission Use Only I ApprovaJ..gate ~-~_tPO Mud log required Directional survey required D 10M;D , Permit Number I API number 200-022 50-103-20096-01 Conditions of approval Samples required D Yes ~ No Hydrogen sulfide measures ŒI Yes 0 No Required working pressure for BOPE D 2M; 0 3M; D 5M; Other: Approved by ORIGINAL SIGNED BY J. M. Heusser I See cover letter for other requirements 0 Yes ~ No [81 Yes 0 No ~~ L\~CJC) ~~\ ~.~ ~\-- Commissioner by order of the commission Form 10-401 Rev. 12/1/85. 0 R" ¡I G' ¡ ¡ \ '.. \ . l \ \Ì Date d-1-tJ/ Submit in triplicate ,---- .~ .. ' KRU 3H-16A CT Sidetrack and Completion Intended Procedure REVISED Objective: P&A well with 17 ppg cement. Mill window from cement plug. Directionally drill a horizontal well from the existing wellbore. Complete with 2-3/8" cemented liner. Perforate appropriate intervals. Intended Procedure: . P&A existing perfs with 17 ppg cement. . Mill window from cement in 7" casing at 93201 md. . Directionally drill a 2-3/4" (3" bi-center) well using dynamically overbalanced drilling techniques. Planned TO is 11641' md. . Run 2-3/8" blank liner to TO, cement in place. . Perforate, place on production. Drilling fluids will be injected into a dedicated Class II disposal well. Dynamically overbalanced drilling techniques will be employed to address high reservoir pressure. Plans are to use -10 ppg drilling fluid in combination with annular friction losses and applied surface pressure to maintain overbalanced reservoir conditions. A hydraulic choke for regulating surface pressure will be installed between the BOPE choke manifolding and the mud pits and will be independent of the BOPE choke. Using this technique with an underbalanced mud weight requires deployment of the BHA under trapped wellhead pressure. Deployment will be accomplished utilizing the upper BOP pipe/slips (2-3/8" rams, see attached BOP configuration). The annular preventer will act as a secondary containment during deployment and not as stripper. Lower BOP rams will be used only for primary well control. At least two times hole volume of kill weight fluid will be on location as a contingency. RECEIVED JAN 0 5 2001 Alaska Oil & Gas Cons. Commission Anchorage January 5, 2001 ~ ~ ,-\: Kuparuk 3H-16A Potential Drilling Hazards POST ON RIG . Please perform pre-job Hazard ID and Safety meetings prior to every change in work scope during the operation. At any stage in the operation, if things don't look right shut- down the operation and discuss the situation before making the next move. SAFETY FIRST. . H2S is approximately 100 ppm in the Kuparuk produced water injection stream. The 3H pad is a designated H2S area. H2S procedures must be followed according to the AK Safety Handbook and Shared Services Drilling H2S SOP. Ensure H2S monitoring equipment is functional. All personnel must be supplied with required prE and H2S certified. Influxes of reservoir fluid could result in H2S in pit area, although KRU CTD sidetracks in the past have not seen this. . AlC sand BHP: 4181 psi @ 5989' TVD, 5913'ss (13.4 ppg EMW) Aug '00 Offset injector 3H-18 AlC sand BHP = 3974 psi @ 5921 'ss (12.9 ppg EMW) Jan '00 Reservoir frac gradient is -0.73 psi/ft or 14.0 EMW, 4372 psi. . Plans are to start drilling with less than kill-weight fluid (10.0 ppg Flo-Pro). While circulating at least 1.5 bpm, BHP will still underbalance reservoir pressure and will require 400 psi surface pressure to maintain overbalance. When circulation is shut down, the reservoir will be underbalanced by -1050 psi assuming an 13.4 ppg reservoir. Maintain at least 1250 psi WHP when not circulating to prevent reservoir in-flux and maintain formation stability close to circulating pressures seen during drilling. Adjust SIWHP accordingly when BHP increases are seen on the downhole APS sub. Increases will occur from higher-than-expected friction pressures and/or reservoir pressures. Refer to the PWD BHP vs Depth chart to determine if deviations occur. Monitor return-line flow rate and pit volume continuously. If crude enters the circulating system, divert those returns to an outside tank. . Directional plan does not cross any known faults yet some pressure differential may be seen between the A and C sands. . Maximum anticipated WHP w/ full column of gas: -3582 psi (BHP = 4181 psi @ 5989' TVD) assuming 0.1 psilft gas gradient. . No gas saturated intervals are expected. RECEIVED JAN 0 5 2001 Alaska Oil & Gas Cons. Commission Anchorage January 5,2001 "---'" '" KRU CTD BOP Detail ~ '-- I I , , K ' I 2 3/8" Slips I r=c= @ 123/8" Pipes I HCR I I 0 II -Wò-: I l 7-1/16"ID,5000psiworkingpressure ~ 2"Sid@eOUtiets §if I Blind/Shear I Ram Type Dual Gate BOPE I TOT I cJ1---- 0 Manual over Hydraulic ~~ I 2" Combi Pipe/Slip xo Spool 3 1/8" x 7 1/6" \ or as necessary I I 2 flanged gate valves Single or Double ~ Manual Master Valves @ , , dYUI I ? Methanol Injection ~ 8tis 7" WLA Quick I' onnect - I I r 7-1/16" ID, 5000 psi working pressure Ram Type Dual Gate BOPE Manual over Hydraulic Hydril Model B Flanged Fire Resistant Kelly Hose to Dual Choke Manifold 'I THA L Tubing Spool MOJ 9/16/00 í I I °'\l \ ~ CT Injector Head -- Stuffing Box (Pack-Off), 10,000 psi Working Pressure -.",. - 7" Riser , I I I , Annular BOP (Hydril),7-1/16" ID 5000 psi working pressure ..) I Fire resistant Kelly Hose to Flange by Hammer up 1/4 Turn Valve on DS Hardline to Standpipe / manifold I Î~ -, I 1Q)~ 7" Annulus 9 5/8" Annulus RECEIVED JAN 0 5 2001 Alaska Oil & Gas Coos. Commission Anchorage BP Amoco LEGEND - 3H.16 (3H-16) - Pld33H-I6A T I^\ M )" '\::7-" g",", ¡"'..Doe, Azimuths to True North We"path, (3H.I6/Pla",," 3H-IGA) Magnetic North: 26,12' "'eoted By: Brij Poto', Dole: 12120/2000 Magnetic Field S&~R~~I~; ¿ó:'7'J Date: 121.201.2000 Model: BGGM2000 C"nl,,'" Inl<""",,(.,.,. WELLPATH DETAILS Plan#33H-16A 501032009601 Parent Wellpath: 3H-16 Tie on MD: 9320.00 No. v,¡e%~~1 ~~~~~~ ~~gl~; ~~~~ÕO!O.OO.O,OO) Rig: Depth Reference: 3H-16 Rig 76.0011 REFERENCE INFORMATION Co-ordinate (N/E) Reference: Weli Centre: 3H-16, True North Vertical (TVD) Reference: System: Mean Sea Level Section (VS) Reference: Siot - (0.00.0,00) Measured Depth Reference: 3H-16 Rig 76.0 Calculation Method: Minimum Curvature ANNOTATIONS NO ~. ~~~- ::::~m.m;m~ .::;~ ¡:::~ ::1:: TVD MO Anno~tion 5771.13 9200.00 T..'oPoiol 5839.76 9320.00 "'ok.off Poiol 5900,00 9521.71 1 5900,00 9871.71 2 5893.99 10611.73 3 5872.98 11641.60 TO <5 54°o-? Q. ^ Gl550^ Q ¡¡ 560u ^ I,) :: :e 5700-: GI :: >58' - GI :=I .. ... ! I tl",,¡i¡tr¡-"¡'¡"Iiiqi"'" 6800 6900 7000 7100 7200 7300 7400 7500 7600 7700 7800 7900 8000 Vertical Section at 285.00. [100ft/in] Plot 12/20/2000 ,. ) ) ~ ! ::0 2 '- m 20 :Þ () G) z »1 C> m §' CJl - !'> < §> /'...} C) m = 2. --- 0 ~. g 10:42 AM /~ ,~ k. BP Amoco Baker Hughes INTEQ Planning Report ..........."""".",.-.""""" [NTßQ Kuparuk River Unit North Slope UNITED STATES I Map System:US State Plane Coordinate System 1927 Geo Datum: NAD27 (Clarke 1866) Sys Datum: Mean Sea Level Field: Map Zone: Coordinate System: Geomagnetic Model: Alaska. Zone 4 Well Centre BGGM2000 ~ Site: KRU 3H Pad UNITED STATES: North Slope Site Position: Northing: From: Map Easting: Position Uncertainty: 0,00 ft Ground Level: 0,00 ft 6001657.06 ft 498373,50 ft Latitude: 70 24 56.740 N Longitude: 150 0 47.691 W North Reference: True Grid Convergence: -0.01 deg Well: 3H-16 Slot Name: Well Position: +N/-S -1106.61 ft Northing: +E/-W 282.26 ft Easting: Position Uncertainty: 0.00 ft 6000550.50 ft 498655.50 ft Latitude: Longitude: 70 24 45,857 N 150 0 39.417 W Wellpath: Plan#33H-16A 501032009601 Current Datum: 3H-16 Rig Magnetic Data: 12/20/2000 Field Strength: 57414 nT Vertical Section: Depth From (TVD) ft 0.00 Plan: Plan #3 Date Composed: Version: Tied-to: 3H-16 9320,00 ft Mean Sea level 26.12 deg 80.70 deg Direction deg 285.00 12/20/2000 1 From: Definitive Path Height 76.00 ft Drilled From: Tie-on Depth: Above System Datum: Declination: Mag Dip Angle: +E/-W ft 0.00 +N/-S ft 0.00 Principal: Yes Targets Annotation 9200.00 9320.00 9521.71 9871.71 10611,73 11641.60 5771.13 5839.76 5900,00 5900.00 5893.97 5873.00 Tie-in Point Kick-off Point 1 2 3 TD JAN 0 5 2001 Alaska Oil & Gas Cons. Commission Anchorage Plan Section Information 9200.00 55.19 260.17 5771.13 -225.28 -6648,36 0.00 0.00 0.00 0.00 9300.00 55.07 260.16 5828.31 -239.29 -6729.20 0.12 -0.12 -0.01 183.91 9320.00 55.02 260.08 5839.76 -242.10 -6745.35 0.41 -0.25 -0.40 232.65 9521.71 90.00 280.00 5900.00 -238.69 -6933.64 19.64 17.34 9.88 32.30 9871.71 90.00 315.00 5900.00 -79.58 -7239.29 10.00 0.00 10.00 90.00 10611.73 90.80 241.00 5893.97 16.42 -7922.19 10.00 0.11 -10.00 270.83 11641.60 90.87 344.08 5873.00 360.00 -8750.00 10.01 0.01 10.01 88.92 I ,~ ~. --. BP Amoco Baker Hughes INTEQ Planning Report II ..~....._.__.......... LNTEQ Survey 9200.00 55.19 260.17 5771.13 -225.28 -6648.36 6000326.44 492007.76 0.00 6363.52 0.00 MWD 9225.00 55.19 260.17 5785.41 -228.78 -6668.58 6000322.94 491987.54 0.00 6382.14 0.00 MWD 9250.00 55.13 260.17 5799.69 -232.29 -6688.79 6000319.44 491967.33 0.24 6400.76 183.91 MWD 9275.00 55.10 260.16 5813.99 -235.79 -6709.00 6000315.94 491947.13 0.12 6419.37 183.91 MWD 9300.00 55.07 260.16 5828.31 -239.29 -6729.20 6000312.45 491926.93 0.12 6437.98 183.91 MWD 9320.00 55.02 260.08 5839.76 -242.10 -6745.35 6000309.64 491910.78 0.41 6452.85 232.65 MWD 9325.00 55.85 260.71 5842.60 -242.79 -6749.41 6000308.95 491906.72 19.64 6456.59 32.30 MWD 9350.00 60.06 263.71 5855.86 -245.64 -6770.40 6000306.10 491885.73 19.64 6476.12 31.94 MWD 9375.00 64.32 266.46 5867.52 -247.53 -6792.42 6000304.22 491863.71 19.64 6496.91 30.35 MWD 9400.00 68.63 269.02 5877.50 -248.42 -6815.32 6000303.33 491840.82 19.64 6518.80 29.07 MWD 9425.00 72.98 271.43 5885.72 -248.32 -6838.92 6000303.43 491817.22 19.64 6541.62 28.04 MWD 9450.00 77.36 273.73 5892.12 -247.23 -6863.06 6000304.53 491793.09 19.64 6565.22 27.25 MWD 9475.00 81.76 275.96 5896.64 -245.15 -6887.55 6000306.61 491768.60 19.64 6589.41 26.66 MWD 9500.00 86.17 278.13 5899.27 -242.10 -6912.21 6000309.67 491743.94 19.64 6614.02 26.26 MWD 9521.71 90.00 280.00 5900.00 -238.69 -6933.64 6000313.08 491722.51 19.64 6635.60 26.01 MWD 9525.00 90.00 280.33 5900.00 -238.11 -6936.88 6000313.66 491719.27 10.00 6638.88 90.00 MWD 9550.00 90.00 282.83 5900.00 -233.09 -6961.37 6000318.68 491694.79 10.00 6663.84 90.00 MWD 9575.00 90.00 285.33 5900.00 -227.01 -6985.61 6000324.77 491670.54 10.00 6688.83 90.00 MWD 9600.00 90.00 287.83 5900.00 -219.88 -7009.57 6000331.91 491646.59 10.00 6713.82 90.00 MWD 9625.00 90.00 290.33 5900.00 -211.71 -7033.20 6000340.08 491622.97 10.00 6738.75 90.00 MWD 9650.00 90.00 292.83 5900.00 -202.51 -7056.44 6000349.28 491599.72 10.00 6763.59 90.00 MWD 9675.00 90.00 295.33 5900.00 -192.31 -7079.27 6000359.48 491576.91 10.00 6788.27 90.00 MWD 9700.00 90.00 297.83 5900.00 -181.13 -7101.62 6000370.67 491554.55 10.00 6812.76 90.00 MWD 9725.00 90.00 300.33 5900.00 -168.98 -7123.47 6000382.82 491532.71 10.00 6837.01 90.00 MWD 9750.00 90.00 302.83 5900.00 -155.89 -7144.77 6000395.91 491511.42 10.00 6860.97 90.00 MWD 9775.00 90.00 305.33 5900.00 -141.88 -7165.47 6000409.92 491490.72 10.00 6884.59 90.00 MWD 9800.00 90.00 307.83 5900.00 -126.98 -7185.55 6000424.82 491470.65 10.00 6907.84 90.00 MWD 9825.00 90.00 310.33 5900.00 -111.23 -7204.95 6000440.58 491451.25 10.00 6930.66 90.00 MWD 9850.00 90.00 312.83 5900.00 -94.64 -7223.65 6000457.17 491432.55 10.00 6953.02 90.00 MWD 9871.71 90.00 315.00 5900.00 -79.58 -7239.29 6000472.23 491416.92 10.00 6972.02 90.00 MWD 9875.00 90.00 314.67 5900.00 -77.26 -7241.62 6000474.55 491414.59 10.00 6974.87 270.83 MWD 9900.00 90.04 312.17 5899.99 -60.08 -7259.78 6000491.74 491396.44 10.00 6996.86 270.83 MWD 9925.00 90.08 309.67 5899.96 -43.70 -7278.67 6000508.11 491377.55 10.00 7019.34 270.83 MWD 9950.00 90.11 307.17 5899.92 -28.17 -7298.25 6000523.65 491357.97 10.00 7042.28 270.83 MWD 9975.00 90.15 304.67 5899.87 -13.50 -7318.50 6000538.32 491337.73 10.00 7065.63 270.82 MWD 10000.00 90.18 302.17 5899.79 0.27 -7339.36 6000552.09 491316.87 10.00 7089.35 270.82 MWD 10025.00 90.22 299.67 5899.70 13.11 -7360.81 6000564.94 491295.43 10.00 7113.39 270.81 MWD 10050.00 90.25 297.17 5899.60 25.01 -7382.79 6000576.84 491273.45 10.00 7137.70 270.80 MWD 10075.00 90.29 294.67 5899.48 35.94 -7405.27 6000587.77 491250.97 10.00 7162.25 270.79 MWD 10100.00 90.32 292.17 5899.35 45.88 -7428.21 6000597.71 491228.04 10.00 7186.97 270.78 MWD 10125.00 90.36 289.67 5899.20 54.80 -7451.56 6000606.64 491204.70 10.00 7211.84 270.76 MWD 10150.00 90.39 287.17 5899.04 62.70 -7475.28 6000614.54 491180.98 10.00 7236.79 270.75 MWD 10175.00 90.42 284.67 5898.86 69.56 -7499.31 6000621.40 491156.95 10.00 7261.79 270.73 MWD 10200.00 90.45 282.17 5898.67 75.36 -7523.63 6000627.21 491132.64 10.00 7286.77 270.72 MWD 10225.00 90.48 279.67 5898.47 80.10 -7548.17 6000631.95 491108.10 10.00 7311.71 270.70 MWD 10250.00 90.51 277.17 5898.26 83.76 -7572.90 6000635.62 491083.37 10.00 7336.54 270.68 MWD 10275.00 90.54 274.67 5898.03 86.34 -7597.76 6000638.20 491058.51 10.00 7361.22 270.66 MWD 10300.00 90.56 272.17 5897.79 87.84 -7622.72 6000639.70 491033.56 10.00 7385.71 270.63 MWD 10325.00 90.59 269.67 5897.54 88.24 -7647.71 6000640.11 491008.57 10.00 7409.96 270.61 MWD 10350.00 90.62 267.17 5897.27 87.55 -7672.70 6000639.42 490983.59 10.00 7433.92 270.58 MWD 10375.00 90.64 264.67 5897.00 85.77 -7697.63 6000637.65 490958.66 10.00 7457.54 270.56 MWD 10400.00 90.66 262.17 5896.71 82.91 -7722.46 6000634.79 490933.83 10.00 7480.78 270.53 MWD 10425.00 90.68 259.67 5896.42 78.97 -7747.15 6000630.86 490909.14 10.00 7503.61 270.50 MWD RECLIVLD JAN 0 5 2001 Alaska Oil & ~~ Cons. Commission .~ .~. .~ < BP Amoco Baker Hughes INTEQ Planning Report INTEQ Survey 10450.00 90.70 257.17 5896.12 73.95 -7771.63 6000625.84 490884.66 10.00 7525.96 270.47 MWD 10475.00 90.72 254.67 5895.81 67.87 -7795.88 6000619.77 490860.41 10.00 7547.81 270.44 MWD 10500.00 90.74 252.17 5895.49 60.74 -7819.84 6000612.64 490836.46 10.00 7569.10 270.41 MWD 10525.00 90.75 249.67 5895.16 52.57 -7843.46 6000604.48 490812.83 10.00 7589.81 270.38 MWD 10550.00 90.77 247.17 5894.83 43.38 -7866.70 6000595.29 490789.59 10.00 7609.88 270.35 MWD 10575.00 90.78 244.67 5894.49 33.18 -7889.52 6000585.10 490766.77 10.00 7629.28 270.31 MWD 10600.00 90.79 242.17 5894.15 22.00 -7911.88 6000573.92 490744.42 10.00 7647.98 270.28 MWD 10611.73 90.80 241.00 5893.97 16.42 -7922.19 6000568.34 490734.11 10.00 7656.50 270.35 MWD 10625.00 90.82 242.33 5893.78 10.12 -7933.87 6000562.05 490722.43 10.01 7666.15 88.92 MWD 10650.00 90.87 244.83 5893.41 -1.00 -7956.25 6000550.93 490700.04 10.01 7684.89 88.94 MWD 10675.00 90.91 247.33 5893.02 -11.13 -7979.10 6000540.80 490677.19 10.01 7704.34 88.98 MWD 10700.00 90.96 249.84 5892.61 -20.26 -8002.37 6000531.68 490653.93 10.01 7724.45 89.01 MWD 10725.00 91.00 252.34 5892.19 -28.36 -8026.02 6000523.59 490630.28 10.01 7745.20 89.06 MWD 10750.00 91.04 254.84 5891.74 -35.42 -8049.99 6000516.53 490606.31 10.01 7766.53 89.10 MWD 10775.00 91.07 257.34 5891.29 -41.43 -8074.25 6000510.53 490582.05 10.01 7788.41 89.14 MWD 10800.00 91.11 259.85 5890.81 -46.37 -8098.75 6000505.59 490557.55 10.01 7810.79 89.19 MWD 10825.00 91.14 262.35 5890.32 -50.24 -8123.44 6000501.73 490532.86 10.01 7833.64 89.24 MWD 10850.00 91.17 264.85 5889.82 -53.03 -8148.28 6000498.95 490508.02 10.01 7856.91 89.29 MWD 10875.00 91.20 267.35 5889.30 -54.72 -8173.22 6000497.25 490483.09 10.01 7880.56 89.34 MWD 10900.00 91.22 269.86 5888.77 -55.33 -8198.20 6000496.65 490458.11 10.01 7904.53 89.39 MWD 10925.00 91.25 272.36 5888.24 -54.85 -8223.19 6000497.14 490433.12 10.01 7928.79 89.44 MWD 10950.00 91.27 274.86 5887.69 -53.27 -8248.13 6000498.72 490408.18 10.01 7953.29 89.49 MWD 10975.00 91.28 277.37 5887.13 -50.61 -8272.98 6000501.38 490383.34 10.01 7977.99 89.55 MWD 11000.00 91.30 279.87 5886.57 -46.87 -8297.69 6000505.13 490358.63 10.01 8002.82 89.60 MWD 11025.00 91.31 282.37 5886.00 -42.05 -8322.21 6000509.96 490334.11 10.01 8027.76 89.66 MWD 11050.00 91.33 284.88 5885.42 -36.16 -8346.50 6000515.85 490309.83 10.01 8052.74 89.72 MWD 11075.00 91.33 287.38 5884.84 -29.22 -8370.51 6000522.79 490285.82 10.01 8077.73 89.78 MWD 11100.00 91.34 289.88 5884.26 -21.23 -8394.19 6000530.78 490262.15 10.01 8102.67 89.83 MWD 11125.00 91.34 292.39 5883.67 -12.22 -8417.50 6000539.79 490238.84 10.01 8127.52 89.89 MWD 11150.00 91.34 294.89 5883.09 -2.20 -8440.40 6000549.82 490215.95 10.01 8152.23 89.95 MWD 11175.00 91.34 297.39 5882.50 8.81 -8462.83 6000560.83 490193.52 10.01 8176.75 90.01 MWD 11200.00 91.34 299.89 5881.91 20.79 -8484.76 6000572.81 490171.59 10.01 8201.03 90.07 MWD 11225.00 91.33 302.40 5881.33 33.71 -8506.15 6000585.74 490150.21 10.01 8225.04 90.13 MWD 11250.00 91.32 304.90 5880.75 47.56 -8526.96 6000599.59 490129.41 10.01 8248.72 90.19 MWD 11275.00 91.31 307.40 5880.18 62.30 -8547.13 6000614.34 490109.23 10.01 8272.02 90.24 MWD 11300.00 91.30 309.91 5879.61 77.91 -8566.65 6000629.95 490089.72 10.01 8294.92 90.30 MWD 11325.00 91.28 312.41 5879.05 94.36 -8585.47 6000646.40 490070.91 10.01 8317.35 90.36 MWD 11350.00 91.26 314.91 5878.50 111.62 -8603.55 6000663.65 490052.83 10.01 8339.28 90.41 MWD 11375.00 91.24 317.42 5877.95 129.64 -8620.86 6000681.68 490035.53 10.01 8360.66 90.47 MWD 11400.00 91.21 319.92 5877.42 148.41 -8637.36 6000700.45 490019.03 10.01 8381.46 90.52 MWD 11425.00 91.19 322.42 5876.89 167.88 -8653.03 6000719.92 490003.36 10.01 8401.64 90.58 MWD 11450.00 91.16 324.93 5876.38 188.02 -8667.84 6000740.06 489988.56 10.01 8421.15 90.63 MWD 11475.00 91.13 327.43 5875.88 208.78 -8681.75 6000760.82 489974.66 10.01 8439.96 90.68 MWD 11500.00 91.09 329.93 5875.40 230.13 -8694.74 6000782.17 489961.67 10.01 8458.04 90.73 MWD 11525.00 91.06 332.43 5874.93 252.03 -8706.79 6000804.07 489949.63 10.01 8475.34 90.78 MWD 11550.00 91.02 334.94 5874.47 274.43 -8717.87 6000826.47 489938.55 10.01 8491.84 90.83 MWD 11575.00 90.98 337.44 5874.03 297.30 -8727.96 6000849.34 489928.47 10.01 8507.51 90.87 MWD 11600.00 90.94 339.94 5873.61 320.58 -8737.04 6000872.63 489919.39 10.01 8522.31 90.92 MWD 11625.00 90.90 342.43 5873.21 344.24 -8745.10 6000896.28 489911.33 9.95 8536.22 90.97 MWD 11641.60 90.87 344.08 5873.00 360.00 -8750.00 6000912.04 489906.44 9.95 8545.03 91.01 MWD RECEIVED JAN 0 5 2001 Alaska Oil & Gas Cons. Commission Anchorage . A # 3-1/2" x 7" Baker FHL Packer @ 9160' .~. ~ KRU 3H-16J, ROPOSED CT HORIZONTA. 31DETRACK -..M -"'" SSSV @ 1804' ~ ~ 9-5/8" Shoe @ 3943' J ?-- 3-1/2",9.3#, J-55 Production Tubing to Surface J J Top of 2-3/8" Liner @ 9195' (proposed) J :8: 3-1/2" TUbing/ Tail to 9229' Top of P&A Cement @ 9275' Mill Window in T Casing from 17 ppg Cement Plug @ 9320' 2-3/8" FL4S 4.6# Liner Cemented & Perforated 7" Liner & Perfs P&A'd with 17.0 ppg Cement TO @ 11642' ~ RECEIVED JAN 0 5 2001 Alaska Oil & Gas Cons. Commission Anchorage PCR 1/4/2001 ,~ Subject: Re: CTD BOP stack for KRU wells ~ Date: Wed, 27 Set )0 14:37:12 -0800 From: Blair Wondzel1 <blair_wondzell@admin.state.ak.us> Organization: State of Alaska, Dept of Admin, Oil & Gas To: "Johnson, Mark 0" <JohnsoMO@bp.com> /"'~, 200 '>O~'2 Mark, I re-read your original E-mail. We accept these changes for the 5 wells you listed. Thanks for including the PTD numbers. That makes our life a little easier. Thanks, Blair Wondzell, 9/27/00. "Johnson, Mark 0" wrote: > Blair, I could not save the visio drawing in xls, pdf, or txt. I saved > it in jpg which I think you will be able to open. I also faxed over a > copy. Thx MOJ 240-8034 '> > Good Morning Mark, > We can read the attached vsd file. > .doc, > .txt. or a paint brush file or fac to me at 276-7542 or both. > Thanks, Blair Wondzell > > "Johnson, Mark 0" wrote: > > > > > > > > > > > > > > > > > > > > > > > > > > > > > > Can you please send it in xis, pdf, > Blair, > > > > > > A drawing of the proposed BOP stack is attached. > > The primary difference in this stack compared to what is in the KRU drilling > permits is how the ram type BOPs stack up. We want to put the 2" coil > tubing pipe rams below the mud cross. In the unlikely event of a mud cross > leak, this configuration would allow us to isolate the leak by closing the > pipe rams on the coiled tubing during the drilling phase. > > A risk assessment was performed on this BOP configuration and results were > favorable. > > The five sidetrack wells will be drilled with CTD using the dynamically > overbalanced drilling technique, as per the permits. The wells and approved > drilling permit numbers are as follows: > > > > > > We would like to make a change to the BOP stack configuration in five (5) KRU CTD drilling permits. The drilling permits were approved by AOGCC in 3/00. Please approve this change for those drilling permits listed below. Well 1R-03Ai 3K-22Ai 3H-10Ai 3H-14A Permit # 200-021 200-026 200-041 200-020 > > 3H-16A > > > > «KRU BOP Stack.vsd» > > > > FYI, a new drilling permit request for the sidetrack of lR-OlBi will also > > include this BOP stack. > > > > Thanks, > > > > ------------------------------------------------------------------------ > > Name: KRU BOP Stack.vsd > > KRU BOP Stack.vsd Type: > application/x-unknown-content-type-vsd_auto_file ~--~~~-~. h~~~~A 200-022 Mark O. Johnson 564-5666 (office), 240-8034 (cell) ~ '" " .~ .~ C:\Transfer\KRU BOP Stackjpg.jpg (local) - Microsoft Internet Explorer Page 1 of 1 KRUCTDBOPDelail .%/................0.'...............>..'....., D..". r O~. I....-CT InJector He¡ (/I' I I .. . ~ , ~ -----StuffingBoK(PaCk-Off), 10,000 ~. "~ Methanol Injection Mð ... .... . ., O.......ti,S7.".'.W,t...'.LAOU..i.c....k I..' Conne.c . - . r I r -- 7" Riser 1'1 I ""'I . Annular BOP (Hydril),7-1116" ID 5000 psi working pressure 7-1/16 "10,5000 psiworki ng pressure RamTypePuaiGate80PE . Manual ()ver Hydraulic ..... . . I. I Hydru,. ~.. . ... ,.'b=I\23I8JiP¡peS MOdeIB' 'I"C= ~Þ 23/S"SIiPS I HCR ..: " M!ilnualvalves ~. ~ï¡"'~r'Ve J I þ~~8ii:~6~~~:~~lpre~s¡"~dT'.I~'....'........."i"@....t. r1.'.,.. ..1.,....8.......1...1."...'...d....'...S. Ä.'. e.....a. ,........1 Manual o~r Hydraulic Xð~~~~~~:~,;I>~12'~:::::.5 .~ I \ œ ~."'HA'~I LT¥ro~ll~ T' Annulus r ~. I k~ 95£" Ann"lu, ./ I.. . I FlangedFireRe.sistant KellyHoseto Dual Choke Manifold . \ Single orDouble ManÜålMaster Valves MOJ 9/16100 9/27/00 2:26:24 PM í~1 r l~\ IF ~ i): '. ' -, ! '¡ ... - ._-- in': !:- /,~ !,,! !,,^\ (~!,'Vi ff\\ '...i¡" "'¡¡\l~\/Ü\ - - ~..-= - -.,~ ~::.) u '2 L~J. /'""'; - TONY KNOWLES. GOVERNOR ALASKA OIL AlÐI GAS CONSERVATION COMMISSION 3001 PORCUPINE DRIVE ANCHORAGE. ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 Bruce E. Smith, P,E. AAI Coiled Tubing Drilling Supervisor ARCa Alaska, Inc, P a Box 100360 Anchorage, AK 99510-0360 Re: Kuparuk Unit 3H-16A ARCO Alaska, Inc. Permit No: 200-022 Sur. Loc. 1104'FNL, 4997'FEL, Sec. 12, Tl2N, R8E, UM Btmhole Loc. 832'FNL, 544'FEL, Sec. 10, TI2N, R8E, UM Dear Mr. Smith: 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 25035. 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. ~ Robert N. Christenson, P.E. Chair BY ORDER OF T~ COMMISSION DA TED this 2"2.- day of March, 2000 dlf/Enclosures cc: Department of Fish & Game. Habitat Section w/o encl. Department of En\'Ìronmental Conservation "do enel. 1b. Type of well. Exploratory 0 Stratigraphic Test 0 Service 0 Development Gas 0 Single Zone 0 5. Datum elevation (DF or KB) RKB 76 feet 6. Property Designation ~SS~ A. Kuparuk Field ADL ~ / ALK 2658 ~ SS ~ \ Kuparuk Oil Pool 7. Unit or property Name ~~ 11. Type Bond (see 20AAC 25.0251) Kuparuk Unit Statewide 8. Well number Number 3H-16A #U-63061 0 9. Approximate spud date Amount April 7, 2000 $200,000 14. Number of acres in property 15. Proposed depth (MD and TVD) 2400 11187 MD / 5986 TVD 17. Anticipated pressure (see 20 AAC 25.035 (e)(2)) Maximum surface 3380 psig At total depth (TVD) 3975 psig @ 5921' Setting Depfh ,~ ,------. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 MC 25.005 1a. Type of work: Drill 0 Redrill 0 Re-entry 0 Deepen 0 2. Name of Operator ARCO Alaska, Inc. 3. Address P.O. Box 100360 Anchorage, AK 99510-0360 4. Location of well at surface 1104' FNL, 4997' FEL, Sec. 12, T12N, R8E, UM At top of productive interval 1348' FNL, 1178' FEL, SEC. 10, T12N, R8E, UM At total depth 832' FNL, 544' FEL, Sec 10, T12N, R8E, UM 12. Distance to nearest property line I 13. Distance to nearest well ADL 25631, 544' @ TD feet No Close Approach 16. To be completed for deviated wells Kickoff depth: 9320' MD 18. Casing program size feet Maximum hole angle 93° Hole 2-3/4' Casing 2-3/8' Specifications Grade Coupling L.80 FL4S Length 1992' Top Bottom MD TVD 11187' 5986' MD 9195' Weight 4.6 TVD 5844' 19. To be completed for Redrlll, Re-entry, and Deepen Operations. Present well condition summary Total Depth: measured 9770 feet true vertical 6178 feet Effective Depth: measured 9496 feet true vertical 6017 feet Plugs (measured) Tagged PBTD @ 9496' MD on 3/28/1998. 931&-939", "'.. "'" 0 R \ G \ N ~ keENED . .::~ 2. 5 2.()()O (¡Ul Gae¡ ConS. comm\se\Ot' 20. Attachments Filing fee ø Property Plat 0 BOP Sketch 0 Divert~ U AAd\89I..ogram 0 Dlilling fluid program Time vs depth plot 0 Refraction analysis 0 Seabed report 0 20 AAC 25.050 requirements 0 21. I hereby certify that the foregoing is true and correct to the best of my knowledge Questions? Call Dan Kara @ 263-4837. Signed P-r~.MA I'r'Amlt,p.. -Þt ~R.Q""C'" 1\1itle: AAI Coil Tubing Drilling Supervisor Date dzì'ZÇ/ðO ~ co . 'šm'i17îÝ.r. ()\ UJ;.- q/Il f"'t't\ Prepared by Paul Rauf 263-4990 Commission Use Only Permit Number I API number I Approval date ë)CJ:::>-Odd- 50. \t)~- dÖ~C;~ -(::)\ .1,;)..;;;"...<00 Conditions of approval Samples required 0 Yes KI No Mud log required Hydrogen sulfide measures 0 Yes ~ No Directional survey required Required working pressure for BOPE D2M; 0 3M; 0 5M; 0 10M;D Other: Junk (measured) Casing CONDUCTOR SUR. CASING PROD. CASING Length 110' 3867' 9632' Size 16' 9-5/8' Cemented 200 Sx AS I 1600 Sx AS III & 400 Sx Class G 400 Sx Class G & 175 Sx AS I Measured depth 110' 3943' 9708' 7' Perforation depth: measured true vertical 5913'. 5956'; 5984'.5996'. -ö ~ ~ - -...... Development Oil 0 Multiple Zone 0 10. Field and Pool Quantity of Cement (include stage data) 15 bbls True Vertical depth 110' 2866' 6142' ðee cover letter for other requirements Yes g No lg Yes 0 No 0 3500psiforCTU V Approved by ORIGINAL SIGNED BY Robert N. Christenson Commissioner by order of the commission Form 10-401 Rev. 12/1/85. Date~- d--d-Ct) Submit in triplicate , " ~ Appli~ for Permit to Drill, We1l3H-16A Revision No.O Saved: 8-Nov-01 Please see Attachment 1: Directional Plan and (2) for all wells within 200 feet of the proposed wellbore (A) list the names of the operators of those well~ to the extent that those names are known or discoverable in public records~ and show that each named operator has been flimished a copy olthe application by certified mai~' or (B) state that the applicant is the only affeded owne¡: The proposed BHL is within 500' of the KPA unit boundary. A request for exception to rule 20 AAC 25.055 is attached. 3. Blowout Prevention Equipment Information Requirements of 20 AAC 25.005(c)(3) An application for a Permit to Drill must be accompanied by each of the fol/owing item~ except for an item already on file with the commission and identified ill the application: (3) a diagram and des-cliption of the blowout prevention equipment (BOPE) as required by 20 MC 2S. 035,- 20 AAC 25.036, or 20 MC 25.037, as applicabfe/ Please reference BOP schematics on file for Nordic 3. See attached Nordic 1 BOP schematic. 4. Drilling Hazards Information Requirements of 20 AAC 25.005 (c)(4) An application far a Permit to Drill must be accompanied by each of the following item~ except for an item already on file with the camm!"<:,7on and identified in the application: (4) information on drilling hazard~ including (A) the maximum downlJOle pressure that may be encountered, criteria used to determine if; and maximum potential surface pressure based on a methane gradient:: The expected reservoir pressure in the Kuparuk A1 and C sands for the 3H-16A well bore replacement sidetrack is 3267 psi at 5951' tvd, 0.55 psi/ft or 10.6 ppg EMW (equivalent mud weight). This pressure was obtained from offset pressure data for the Kuparuk A/C sands. Well 3H-16 was P&A'd February 11, 2001, therefore, no current pressure data is available from this well bore. Low risk that reservoir pressure could be high as 11.3 ppg. The maximum potential surface pressure (MPSP) while drilling the sidetrack is calculated using above reservoir pressure, a gas gradient of 0.11 psi/ft, and top of the A1 sand target at 5945' tvd: MPSP =(5945 ft)*(0.55 - 0.11 psi/ft) = 2615 psi (B) data on potential gas zones/ The well bore is not expected to penetrate any gas zones. and (C) data concerning potential causes of hole problems such as abnormally geo-pressured strata, lost circulatIon zone.$¡ and zones that have a propensity for differential sticking/ ~ H2S is approximately 100 ppm in the Kuparuk produced water injection stream. The 3H pad is a designated H2S area. Approved hydrogen sulfide contingency measures will be in effect during the drilling of 3H-16A. ~ Kalubik shale stability is a moderate risk. The mitigation strategy is as follows: · Hole angle < 70 degrees through shale · Maintain mud weights> 11.0 ppg · Glycol additive in mud to reduce ECD and enhance shale stability · Top setting 3-1/2" liner prior to horizontal drilling . ._, ~"'r."·· ..,. ~,-. SCANNED JUL. 1 6 2004 3H-16A PERMIT IT. DOC 0"'", " " ' , ,:' L Page3af6 , t1' , VI i ; V A Printed: 8-Nav-01 ~ APpli(>"'\p for Permit to Drill, We1l3H-16A Revision No.O Saved: 8-Nov-01 , .... Requirements of 20 AAC 25.005 (c)(13) ................................................................................................ 5 14. Discussion of Mud and Cuttings Disposal and Annular Disposal....................... 6 Requirements of 20 AAC 25.005 (c)(14) ......................................................................................... ....... 6 15. Attachments .......... ................................................................... ......... ...... ..... ............ 6 Attachment 1 Directional Plan.......................................................··....······......···..··············..·····....·····.... 6 Attachment 2 Well Schematic.......................................········..···········································..6 Attachment 3 Nordic 1 BOP schematic..............................................·........·....·......·..............·..........·..· 6 Attachment 4 Exception Request to Rule 20 AAC 25.055 .................................................................... 6 1. Well Name Requirements of 20 AAC 25.005 (f) Each well must be identified by a unique name desì.qnated by the operator and a unique API number assigned by the commission under 20 MC 25~040(b). For a well with multiple well branche~ each branch must similarly be identified by a unique name and API number by adding a suffix to the name designated for the well by the operator and to the number assigned to the well by the commission. The well for which this Application is submitted will be designated as 3H-16A. 2. Location Summary Requirements of 20 AAC 25.005(c)(2) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already 017 tile wittl the commission and Identified in the application: (2) a plat identifying the property and tIle property's owners and showing (A)the coordinates of the proposed location of the well at the sudace¡ at the top of each objective formation and at total depth referenced to governmental section fines. (B) the coordinates of the proposed location of the well at the surface, referenced to the state plane coordinate system f..0r this state as maintained by the National Geodetic Survey in the National Oceanic and Atmospheric Administration; (C) the proposed depth of the well at the top of each objective formation and at total depth/ Location at Surface NGS Coordinates Northings: 6,000,550 11104' FNL, 4997' FEL, I Eastings: 498,655 I Sec 12, T12N, R8E UM RKB Elevation I Pad Elevation 1 69.0' AMSL 38.7' AMSL Location at Top of Productive Interval Ku aruk "Al" Sand NGS Coordinates Northings: 6,000,114.25 1547' FNL, 1188' FEL, Sec 10, T12N, R8E, UM Eastings: 491,907.38 9429' 5945' 5876' Location at Total De th NGS Coordinates Northings: 5,999,285.00 2378' FNL, 2387' FEL, Sec 10, T12N, R8E, UM Measured De th RKB: Eastings: 490,709.00 Total Vertical De th RKB: Total Vertical De th 55: 10965' 5916' 5847' and (D) other infOrmation required by 20 AAC 25.0S0(b)/ Requirements of 20 AAC 25.050(b) If a well is to be intentionally deviated, the application for a Permit to Dn!1 (Form 10-401) must (1) include a plat:, drawn to a suitable scale, showing the path of the proposed wellbore, including all adjacent wellbores within 200 feet of any portion of tl¡e proposed well; 3H-16A PERMIT IT. DOC OR I GINA L Prin,;al~,~~ ,.......-........, ~ -' KRU 3H-16A CT Sidetrack and Completion Intended Procedure Objective: P&A well with 17 ppg cement. Mill window from cement plug. Directionally drill a horizontal well from the existing wellbore. Complete with 2-3/8" cemented liner. Perforate appropriate intervals. Intended Procedure: · P&A existing perfs with 17 ppg cement. · Mill window from cement in 7" casing at 9320' md. Drill 10' of formation and perform leak-off test to 13.4 ppg, 0.5 ppg above the highest anticipated equivalent mud weight. · Directionally drill a 2-314" (3" bi-center) well using dynamically overbalanced drilling techniques. Planned TD is 11187' md. · Run 2-3/8" blank liner to TD, cement in place. · Perforate, place on production. Drilling fluids will be injected into disposal welllR-18. Dynamically overbalanced drilling techniques will be employed to address high reservoir pressure. Plans are to use -10 ppg drilling fluid in combination with annular friction losses and applied surface pressure to maintain overbalanced reservoir conditions. A hydraulic choke for regulating surface pressure will be installed between the BOPE choke manifolding and the mud pits and will be independent of the BOPE choke. At least two times hole volume of kill weight fluid will be on location as a contingency. Frequent monitoring and rolling of the kill weight fluid will be done to ensure proper weight distribution. RECe\VED rEB 18 2QOO~ HllkaQi1'GalQø..~ ... February 14,2000 .~ r-'\ Kuparuk 3H-16A Potential Drilling Hazards POST ON RIG . No H2S production is anticipated. . BHP: 3975 psi @ 5921' TVD (12.9 ppg EMW) estimated pressure. Reservoir frac gradient is estimated at -0.85 psilft or 16.3 EMW, 5030 psi . Plans are to drill with less than kill-weight fluid, or dynamically overbalanced. 10 ppg mud will result in a hydrostatic pressure that is -900 psi less than reservoir pressure. Maintain at least 900 psi WHP for well control when not circulating. Pressure loss associated with circulating (ECD) is expected to be -900 psi so applied WHP is not necessary while circulating. Monitor return-line flow rate and pit volume continuously. If crude enters the pits, take all returns to an outside tank first. . Have on location at least two times wellbore volume, 12.9 ppg Kill Weight Fluid. Frequent monitoring and rolling of the kill weight fluid is required to ensure proper weight distribution. . Maximum anticipated WHP wI full column of gas: -3380 psi assuming 0.1 psilft gas gradient. However, no gas saturated intervals are anticipated. RECE'VED FE8 182000 A18Ika 0i1 & Gas CÐns. commiIion AndtOdII February 14,2000 LJ~ ~v [7~L\O ~[3ffi [X]~[X][30 JIN1fIEcçp 5300 - ~ ã; ~ ~ 5400 - 5500- .<:: Õ. Q) 0 5600 - - 0 Ow ,,~ .- .0 1;Ji > 5700- Ti,-in Point 5800 - Kick-off Point ~" 4 5 /' ~~ ~"i.~o," 3/ / ,~,<o / "'-("'-( / / Q) :::¡ .:: 5900 - . 0," ~" ,<0 6000 - "'-( I V 6100 5500 5400 5300 5200 RECE\VED FEB 1 8 2.000 HfI/t.a Oi' Gas Ct'JRs. eommiteiOn Andd'II' 5100 ARGO Plan.xll ARca Alaska, Inc. Structure, Pad 3H Well, 3H-16A Plan. 50-103-20096-01 F;eld , Location' Noeth Rive' Unit <- West (feet) 7500 6900 6600 6800 6700 7400 7300 noD 7100 'ODD 3H-16 13 90 . fP 3H-16 T2 90 . / TO 5000 4700 4200 4000 4100 4500 4400 4300 4900 4800 4600 Vertical Section (feet) -> Azimuth 47.00 with reference 0.00 N, 0.00 E from 3H-16 Prepared by BHI 02/12/00 Alaska 0"',""'" H,4-00" """""""","-""""",, Cw",",""" '" ",' ",."",, ,"-" 0.,,", ". ,,",,"" '" -"" - " n- ",.. "O"" "'" --- 6500 6400 6100 6300 6200 - 400 3H-16 T5 TO - TD 3900 3700 3500 3600 3BOO 6000 3400 5900 700 - 600 ) - 500 - 300 ^ I z 0 :l. ;:,- - 200 - 100 ~ ct ~ - 0 100 - 200 - 300 - 400 ) 3300 ~ r------ 3H-16Av2npd.xls RECEIVED Company: Arco Alaska Inc. Well: 3H-16A Version#2 FEB 1 8 200(} Calculation Method: Minimum Curvature Vertical Sect. Plane: 47.00 .. Oil , G8I r..$.. ComniIeion Measured Depth from: RKB 76.00 ~ MD Inc Azi TVD (BRT) TVD (MSL) X Y NS EW DLS VSEC 9200.00 55.19 260.17 5847.13 5771.13 492007.72 6000326.70 -225.27 -6648.39 0.00 -5015.96 9225.00 55.16 260.17 5861.41 5785.41 491987.50 6000323.20 -228.77 -6668.61 0.12 -5033.14 9250.00 55.13 260.17 5875.70 5799.70 491967.29 6000319.70 -232.28 -6688.83 0.12 -5050.31 9275.00 55.10 260.16 5890.00 5814.00 491947.09 6000316.21 -235.78 -6709.03 0.12 -5067.48 9300.00 55.07 260.16 5904.31 5828.31 491926.89 6000312.71 -239.28 -6729.23 0.12 -5084.64 9320.00 55.02 260.08 5915.76 5839.76 491910.74 6000309.90 -242.09 -6745.38 0.41 -5098.37 9325.00 55.86 260.72 5918.60 5842.60 491906.68 6000309.21 -242.78 -6749.44 19.81 -5101.81 9350.00 60.10 263.74 5931.86 5855.86 491885.69 6000306.37 -245.63 -6770.44 19.81 -5119.10 9375.00 64.40 266.51 5943.49 5867.49 491863.65 6000304.50 -247.50 -6792.47 19.81 -5136.50 9400.00 68.75 269.09 5953.43 5877.43 491840.74 6000303.64 -248.37 -6815.39 19.81 -5153.85 9425.00 73.14 271.52 5961.59 5885.59 491817.12 6000303.77 -248.24 -6839.01 19.81 -5171.04 9450.00 77.56 273.83 5967.91 5891.91 491792.97 6000304.91 -247.11 -6863.16 19.81 -5187.93 9475.00 81.99 276.07 5972.35 5896.35 491768.47 6000307.04 -244.98 -6887.67 19.81 -5204.40 9500.00 86.44 278.26 5974.87 5898.87 491743.80 6000310.15 -241.88 -6912.34 19.81 -5220.32 9520.00 90.00 280.00 5975.49 5899.49 491724.07 6000313.33 -238.71 -6932.07 19.81 -5232.59 9525.00 90.09 280.97 5975.49 5899.49 491719.15 6000314.24 -237.80 -6936.99 19.50 -5235.57 9550.00 90.51 285.83 5975.36 5899.36 491694.85 6000320.04 -232.00 -6961.30 19.50 -5249.40 9575.00 90.94 290.69 5975.04 5899.04 491671.12 6000327.87 -224.18 -6985.03 19.50 -5261.42 9600.00 91.36 295.54 5974.54 5898.54 491648.14 6000337.68 -214.37 -7008.01 19.50 -5271.53 9625.00 91.76 300.40 5973.86 5897.86 491626.08 6000349.40 -202.65 -7030.08 19.50 -5279.68 9650.00 92.16 305.27 5973.00 5897.00 491605.10 6000362.95 -189.10 -7051.06 19.50 -5285.79 9675.00 92.54 310.13 5971.98 5895.98 491585.35 6000378.23 -173.83 -7070.82 19.50 -5289.83 9700.00 92.90 315.00 5970.79 5894.79 491566.97 6000395.11 -156.95 -7089.21 19.50 -5291.76 9725.00 92.59 320.01 5969.59 5893.59 491550.11 6000413.52 -138.54 -7106.07 20.04 -5291.54 9750.00 92.26 325.01 5968.54 5892.54 491534.92 6000433.34 -118.73 -7121.27 20.04 -5289.14 9775.00 91.91 330.01 5967.63 5891.63 491521.51 6000454.40 -97.66 -7134.68 20.04 -5284.58 9800.00 91.54 335.01 5966.87 5890.87 491509.98 6000476.56 -75.50 -7146.21 20.04 -5277.90 9825.00 91.17 340.01 5966.28 5890.28 491500.43 6000499.65 -52.41 -7155.77 20.04 -5269.14 9850.00 90.78 345.01 5965.86 5889.86 491492.93 6000523.48 -28.58 -7163.28 20.04 -5258.38 9875.00 90.39 350.00 5965.60 5889.60 491487.53 6000547.88 -4.18 -7168.69 20.04 -5245.70 9900.00 90.00 355.00 5965.51 5889.51 491484.27 6000572.66 20.60 -7171.95 20.04 -5231.18 9925.00 90.00 0.00 5965.51 5889.51 491483.19 6000597.62 45.56 -7173.04 20.00 -5214.95 9950.00 90.00 5.00 5965.51 5889.51 491484.29 6000622.59 70.53 -7171.95 20.00 -5197.13 9975.00 90.00 10.00 5965.51 5889.51 491487.55 6000647.36 95.31 -7168.68 20.00 -5177.84 10000.00 90.00 15.00 5965.51 5889.51 491492.97 6000671.76 119.71 -7163.28 20.00 -5157.25 10025.00 90.00 20.00 5965.51 5889.51 491500.49 6000695.59 143.55 -7155.76 20.00 -5135.49 10050.00 90.00 25.00 5965.51 5889.51 491510.05 6000718.68 166.64 -7146.20 20.00 -5112.75 10075.00 90.00 30.00 5965.51 5889.51 491521.60 6000740.84 188.80 -7134.66 20.00 -5089.19 10100.00 90.00 35.00 5965.51 5889.51 491535.03 6000761.91 209.88 -7121.23 20.00 -5065.00 10125.00 89.34 39.96 5965.66 5889.66 491550.24 6000781.74 229.71 -7106.02 20.01 -5040.35 10150.00 88.68 44.92 5966.09 5890.09 491567.10 6000800.18 248.16 -7089.16 20.01 -5015.44 10175.00 88.03 49.88 5966.81 5890.81 491585.50 6000817.08 265.06 -7070.77 20.01 -4990.46 10200.00 87.40 54.85 5967.80 5891.80 491605.27 6000832.32 280.31 -7050.99 20.01 -4965.60 10225.00 86.79 59.82 5969.07 5893.07 491626.29 6000845.79 293.78 -7029.98 20.01 -4941.04 10250.00 86.20 64.80 5970.60 5894.60 491648.37 6000857.37 305.38 -7007.89 20.01 -4916.98 10275.00 86.83 66.17 5972.12 5896.12 491671.08 6000867.72 315.73 -6985.19 6.02 -4893.32 10300.00 87.46 67.54 5973.37 5897.37 491694.04 6000877.53 325.54 -6962.23 6.02 -4869.83 10325.00 88.10 68.90 5974.34 5898.34 491717.23 6000886.79 334.81 -6939.03 6.02 -4846.55 10350.00 88.73 70.27 5975.03 5899.03 491740.65 6000895.50 343.53 -6915.61 6.02 -4823.47 10375.00 89.36 71.64 5975.44 5899.44 491764.28 6000903.65 351.69 -6891.99 6.02 -4800.63 10400.00 90.00 73.00 5975.58 5899.58 491788.10 6000911.24 359.28 -6868.17 6.02 -4778.03 10425.00 89.95 74.46 5975.59 5899.59 491812.09 6000918.24 366.28 -6844.17 5.83 -4755.70 Page 1 of 2 /~, .~ 3H-16Av2npd.xls MD Inc Azi TVD (BRT) TVD (MSL) X V NS EW DLS VSEC 10450.00 89.90 75.91 5975.63 5899.63 491836.26 6000924.62 372.68 -6820.00 5.83 -4733.67 10475.00 89.85 77.37 5975.68 5899.68 491860.58 6000930.39 378.45 -6795.68 5.83 -4711.94 10500.00 89.80 78.83 5975.76 5899.76 491885.04 6000935.54 383.61 -6771.22 5.83 -4690.54 10525.00 89.75 80.29 5975.86 5899.86 491909.63 6000940.07 388.14 -6746.63 5.83 -4669.46 10550.00 89.70 81.74 5975.98 5899.98 491934.32 6000943.97 392.04 -6721.94 5.83 -4648.74 10575.00 89.65 83.20 5976.12 5900.12 491959.10 6000947.24 395.32 -6697.16 5.83 -4628.38 10600.00 89.60 84.66 5976.29 5900.29 491983.96 6000949.87 397.96 -6672.30 5.83 -4608.40 10625.00 89.55 86.12 5976.48 5900.48 492008.87 6000951.88 399.97 -6647.38 5.83 -4588.81 10650.00 89.50 87.57 5976.69 5900.69 492033.83 6000953.25 401.35 -6622.42 5.83 -4569.61 10675.00 89.45 89.03 5976.92 5900.92 492058.82 6000953.98 402.09 -6597.43 5.83 -4550.83 10700.00 89.40 90.49 5977.17 5901.17 492083.81 6000954.08 402.19 -6572.43 5.83 -4532.48 10725.00 89.35 91.95 5977.44 5901.44 492108.80 6000953.55 401.66 -6547.44 5.83 -4514.56 10750.00 89.30 93.40 5977.73 5901.73 492133.77 6000952.38 400.50 -6522.47 5.83 -4497.10 10775.00 89.26 94.86 5978.05 5902.05 492158.70 6000950.57 398.69 -6497.54 5.83 -4480.09 10800.00 89.21 96.32 5978.38 5902.38 492183.57 6000948.13 396.26 -6472.66 5.83 -4463.55 10825.00 89.16 97.78 5978.74 5902.74 492208.38 6000945.06 393.19 -6447.85 5.83 -4447.50 10850.00 89.12 99.23 5979.11 5903.11 492233.10 6000941.36 389.50 -6423.13 5.83 -4431.94 10875.00 89.07 100.69 5979.51 5903.51 492257.71 6000937.03 385.17 -6398.51 5.83 -4416.89 10900.00 89.03 102.15 5979.92 5903.92 492282.21 6000932.07 380.22 -6374.01 5.83 -4402.34 10925.00 88.98 103.61 5980.36 5904.36 492306.57 6000926.50 374.65 -6349.64 5.83 -4388.32 10950.00 88.94 105.06 5980.81 5904.81 492330.79 6000920.31 368.47 -6325.43 5.83 -4374.83 10975.00 88.90 106.52 5981.28 5905.28 492354.83 6000913.50 361.66 -6301.37 5.83 -4361.88 11000.00 88.85 107.98 5981.78 5905.78 492378.70 6000906.08 354.25 -6277.50 5.83 -4349.48 11025.00 88.81 109.44 5982.28 5906.28 492402.37 6000898.06 346.23 -6253.83 5.83 -4337.63 11050.00 88.77 110.89 5982.81 5906.81 492425.83 6000889.44 337.62 -6230.37 5.83 -4326.35 11075.00 88.73 112.35 5983.36 5907.36 492449.06 6000880.23 328.41 -6207.13 5.83 -4315.64 11100.00 88.69 113.81 5983.92 5907.92 492472.05 6000870.42 318.61 -6184.14 5.83 -4305.50 11125.00 88.66 115.27 5984.49 5908.49 492494.78 6000860.04 308.23 -6161.41 5.83 -4295.96 11150.00 88.62 116.73 5985.09 5909.09 492517.23 6000849.08 297.27 -6138.94 5.83 -4287.00 11175.00 88.58 118.18 5985.70 5909.70 492539.41 6000837.56 285.75 -6116.77 5.83 -4278.64 11187.04 88.57 118.89 5986.00 5910.00 492549.98 6000831.80 280.00 -6106.19 5.83 -4274.82 RECE\VEO fEe 1 8 2.000 "QII"=~ Page 2 of 2 ~ " .~, C T Drilling BOPE I I """ Annular BOP (Hydril),7-1/16" ID -- 5000 psi WP "- ..) I I Alignment Guide Flange '=. ,.!.- 0.29' (3.5") 7-1/16", 5M Ram Type Dual - ~ ==:Þ=I Cutters or Gate BOPE ¡--t..- ~ ' Combination Cutter/Blinds ~ ~ ~ Slip/Pipe Rams Flanged Fire Resistant HCR MantJaïVaïve --------. Kelly Hose to Dual I Choke ManH~ ~ ~ Valves D~~ni.1S:~: ~~1.16" 5M I I J.r-- 2" Pump-In ~ F ~ Fire resistant Kelly Hose to J1-- . ~ I v~~;~~ ~S H~;:~~~ ~~ ~~:~;~e l \ ,/ Tubing Hanger manifold IlL ~ Inner Ann"l"s -, I ~ Outer Annulus ¿YUI I Methanollnjection ~ Otis 7" WLA . Quick Connect - I I I r Manual over Hydraulic Ram Type Dual Gate BOPE 7-1/16" ID with Pipe/Slip Rams r I I O~ \ - CT Injector Head -- Stuffing Box (Pack-Off), 10,000 psi Working Pressure ..."". - 7" Riser , I '\ RECEIVED F:¿B 18 2000 A1a8ka Oil & Gas Cons. Commi88ion AndøaIe ~~ ~, KRU 3H-16A ROPOSED CT HORIZONTAl.õIDETRACK = II SSSV @ 1804' .. ~ 9-5/8" Shoe @ 3943' J ?-- 3-1/2",9.3#, J-55 Production Tubing to Surface J J ~ Top of 2-3/8.liner @ 9195' (proposed) ,I 3-1/2" X 7" Baker FHL 8 Packer @ 9160' 3-1/2" TUbing/ Tail to 9229' Top of P&A Cement @ 9275' Mill Wìndow in 7" Casìng from 17 ppg Cement Plug @ 9320' 2-3/8" FL4S 4.6# Liner Cemented & Perforated 7" Liner & Perfs P&A'd with 17.0 ppg Cement TD @ 11187' 7" Shoe @ 9708' RECe\VED f~6 18 2000 **,Oil& GøCons. Comm\teiOn ~ PCR 2/17/2000 /""'. ~. ARca Alaska, Inc. 3H-16 ....~ ~". Kuparuk API: 501032009600 SSSV Type: Camco'TRDP-1A-SSA' Annular Fluid: Last Tag: 9506 Rev Reason: New Schem Elevations Grd 134 ft Casing String - CONDUCTOR Item 16.000 in CONDUCTOR Casing String - SURFACE Item 9.625 in SUR CASING Casing String - PRODUCTION Item 7.000 in PROD. CASING Tubing String - TUBING Item I Top 1 3.500 in TUBING 33 Perforations Interval Izone 9,440 - 9,460 A-1 9,315 - 9,391 C-4,A-2 Gas Lift MandrelsNalves Stn MD TVD Man Mfr 1 3,365 2,537 Camco 2 6,664 4,403 Camco 3 8,697 5,558 Camco 4 9,100 5,790 CamcQ Well Type: INJ PBTD: 9,770 ftKB Orig Completion: 3/23/88 TD: 9,770 ftKB Last W/O: Max HQle Angle: 59 deg @ 7000 Last Tag Date: 3/5/98 Angle @ TS: 55 deg @ 9314 Last Update: 3/15/98 Angle@TD: 54 deg @9770 I Original Rig RKB 131 ft Btm 1101 Jnts Wt I Grd Thd 62.50 H-40 Btm 3,9431 Jnts Wt I Grd Thd 36.00 J-55 Btm 9,7081 Jnts Wt I Grd Thd 26.00 J-55 Len I Jnts I Wt 1 Grd I 9,196 9.30 J-55 Thd BTC AB MOD ¡Status I Feetl sPFIDate 20 4 5/21/88 76 12 8122/88 IType 4 1/2" UltraPak 2 1/8" EnerJet ¡Comment 120 deg. phasing 60 deg. phasing Man Type 3112X 1 KBUG 31/2X 1 KBUG 31/2 X 1 KBUG 31/2X11/2MMG- 2 Other (plugs, equip., etc.) - JEWELRY Depth Type Description 1,804 SSSV Camco'TRDP-1A-SSA' 9,146 PBR Baker 9,160 PKR Baker'FHL' 9,197 NO GO CamcQ 'D' Nipple 9,228 SHEAR OUT Brown 9,229 TUBING TAIL Mfr Type Latch DV BK DV BK-2 DV BK-2 DV RK Port 0.000 0.000 0.000 0.000 TRO 0.0 0.0 0.0 0.0 Run 9/1/94 8/31/94 5121188 9/1/94 ID 2.810 4.000 2.992 2.750 2.992 2.992 ({ P f~\ C'Rl.~:b +c, r ~ ¡b.. ~A ~ . ~,.~-h ~J.~d<- 1'\ CUL~j cd:. Iq,:; LJ.) I 1-c \\)\ ß11, J'fC>-~~(~'J - ~IV\~ IS- ~~I.s 0+ ~I.. 'l'.d þ{OV\d e.. - M\\~ 2.. ßC" Wlr-dl~ If' - \) \rt ¿ l(N\ð...~ J f-\ \ \ 0 vUr-6 c..J. ~~d ~\fl\ 2, ~/ð " FL4Ô l.t ~e.r. <1. YÑt~{ ~ ~N'C"J~ RECEIVED FE8 18 2000 AI8a Oil & Gas C'41s. Commi8eion AndIora¡e 3H-16 SSSV ~ TUBING PROD. CASING - SUR. CASING ~ r- uì M"",,",~::~ -. ~ Gas Lift ----,J' MandreVDummy Valve \, 2 . . Gas Lift ----,J~ MandrellDummy Valve l ., 3 ' Gas Lift -----.» MandrellDummy Valve i'." .', 4 , PBR PKR -. NOGO ..., SHEAR OUT \ ~ I TUBING TAIL Perf r: Perf "ARca Alaska, Inc. <> ~ PRUDHOE BAY UNIT DISBURSEMENT AC JNT P.O. BOX 102776 , ANCHORAGE, AK 99510-2776 1111"1111"11"'11'11"1"11'1'"1"11"'11"1111"111"11"1 [:~: III!I 1III11I111 11111 ""1 !II! 'II! PAGE 1 OF 1 FEBRUARY 2, 2000 TRACE NUMBER: 225126819 CHECK NUMBER: 225126819 "51"'" STATE OF ALASKA ALASKA OIL & GAS CONSERVATION COMMI 3001 PORCUPINE DRIVE ANCHORAGE AK 99501 AMOUNT PAID: $100.00 PAY ENTITY: 0201 VENDOR NO: NOO072020221 INQUIRIES: (907) 263-4422/4988 (FAX) P.O. BOX 103240 ANCHORAGE, AK 99510-3240 INVOICE NUMBER VR012800SJD03 NET AMOUNT $100.00 -_."._-".__._'--~~-_._._.._. ._.__.,"._._~. .~ .r--.. 1. Type of request: \ ~~.b.!.andon_X Suspend- Alter casing - Repair well - Change approved program - /-'\ STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 2. Name of Operator ARCO Alaska, Inc. 3. Address ~ : P. O. Box 100360 Anchorage, AK 99510-0360 4. Location of well at surface 1104' FNL, 4997' FEL, Sec. 12, T12N, R8E , UM At top of productive interval 1348' FNL, 1178' FEL, SEC. 10, T12N, R8E, UM At effective depth At total depth 1411' FNL, 1544' FEL, Sec. 10, T12N, R8E, UM 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Length 110' 3867' 9632' 7" Size 16" 9-5/8" Casing CONDUCTOR SUR. CASING PROD. CASING Perforation depth: Operational shutdown- Plugging _X Pull tubing - 5. Type of Well: Development - Exploratory - Stratigraphic - Service_X (asp's 498656,6000551) (asp's 491917,6000317) (asp's 491550, 6000248) 9770 feet 6178 feet 9496 feet 6017 feet Plugs (measured) Junk (measured) Cemented 200SxAS I 1600 Sx AS III & 400 Sx Class G 400 Sx Class G & 175 Sx AS I Re-enter suspended well- Time extension - Stimulate - Variance - Per1orate - 6. Datum elevation (DF or KB feet) RKB 76 feet 7. Unit or Property name Other - Kuparuk Unit 8. Well number 3H-16i 9. Permit number / approval number 187-129 10. API number 50-229-20096 11. Field / Pool Kuparuk Oil Pool Tagged PBTD @ 9496' MD on 3/28/1998. Measured Depth 110' 3943' 9708' measured 9315' - 9391'; 9440' - 9460'. RECEiVED true vertical 5913' - 5956'; 5984' - 5996'. -- .:. = 'ì 8 lOOO . - .~ .-a ~ & Gas Cons. Commiteion And\oréIÐe Tubing (size, grade, and measured depth 3-1/2",9.3#, J-55 Tbg @ 9229' MD. Packers & SSSV (type & measured depth) BAKER FHL Packer @ 9160' MD. CAMCO TRDP-1A-SSA SSSV @ 1804' MD. 13. Attachments Description summary of proposal-2< Detailed operations program- 14. Estimated date for commencing operation 15. Status of well classification as: March 7, 2000 16. If proposal was verbally approved Oil- Name of approver Date approved 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Service Gas- True vertical Depth 110' 2866' 6142' ORiS/' I IVJj ¿ BOP sketch_X Suspended - Water Injector Questions? Call Dan Kara @ 263-4837. Signed ~~ ,0"4,, - - .y::: I (:,. f~ 5'/11"7;+ Title: AAI Coil Tubing Drilling Supervisor Bruce E:. Smith, ~ FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness Plug integrify - BOP Test - Location clearance - Mechanical Integrity Test - Subsequent form required 10- . Approved by order of the Commission Form 10-403 Rev 06/15/88. Date ;)//8-/00 tK" Prepared by Paul Rauf 263-4990 Commissioner I Approval no. ~. 0 .- 1{h- 7'5- - - Date SUBMIT IN TRIPLICATE nu WELL PERMIT CHECKLIST COMPANY /Lï!fv WELL NAME 3#.. ICA PROGRAM: exp - dev - redrll ~serv - wellbore sag _ann. disposal para req- j FIELD & POOL /"7,:.., /f"I ~ INIT CLA~-S 4-./ /-oJ1 GEOL AREA If''7~ UNIT# all / ~r'") ON/OFF SHORE otV ADMINISTRATION 1. Permitfeeattached. . . . . . . . . . . . . . . . . . . . . . . Y (!j)Â.A1' /"ë:h/V~ -,,>$; /*./e. /,._:( ~-'~(:', -1'~ ¡ 2. Lease number appropriate. . . . . . . . . . . . . . . . . . . rD 3.Uniquewellnameandnumber.................. ~ 4. Well located in a defined pool.. . . . . . . . . . . . . . . . . <:::y> N I / I '/J) / / ,., V' /J ~ 5. Well located proper d~stance from drilling unit boundary. . . . Y A .:;p:;;.-~IIJ; ¡O,X'" ~ÒN <1..1// óa- /c--$'<!!.v rc:-4 ""'1' 77?1,r -'<.Jf"//. 6. Well located proper distance from other wells.. . . . . . . . . N / ~ V L.- Vj . 7. Suffident acreage avaBabie in drilling unk.. . . . . . . . . . . ~ 0 /'":'¡':.~1 ;;:" ~/ ~:,f k :-k.:t.. ß p;.. -4 ~/" 8. If deviated, is wellbóre plat induded.. . . . . . . . . . . . .. ~~~. /, / ¿; J .-/ J I ß / / 9. Operator only affected party.. . . . . . . . . . . . . . . . . . Nr.......1"] ~ ./..[".Ç,¿,,"--1~. U/c-- ,~ø/ ~~~ ~~- ð /fi/7;Jj¡;.-1'n . 10. Operator has appropriate bond in force. . . . . . . . . . . . . N .I I ~ . 11. Permit can be issued without conservation order. . . . . . . . . ~& ~ hi þ/ .4-/i,I - #;~, J' 5 A ~ (y ~ Z/ 4-- 7--~ 12. Permit can.be issued without administrative approval.. . . . . CJJ N As A/' ~.Æ::- /' ...J 13. Can permit be approved before 15-day wait.. . . . . . . . . . - 14. Conductor string provided .. . . . . . . " . . . . . . . . . y N~ 15. Surface casing protects all known USDWs. . . . . . . . . .. . Y N ~~Ct..\~~~~~~~ ~q 16. CMT vol adequate to circulate on conductor & suñ csg. . . . . Y N ~ 17. CMT vol adequate to tie-in long string to suñ csg. . . . . . . . Y N . .,.~ r-.... 18. CM~ will co.ver all known productive horizons. . . . .'. . . .. . j<N5 c;. ~ \. \. Nè.. ~ ~ \~'i'.~ ) 19. CaslngdeslgnsadequateforC,T,B&permafrost. """ . N... I .,.. 2.°. Adequate tankage or reserve pit.. . . . . . . . . . . . . . . . .. N <è~~~ ~~ ~("') ~S<è...~ 'Çi.--\- 21. If a re-drill, has a 10-403 for abandonment been approved. . . N:::> . "' 22. Adequate well bore separation proposed.. . . . . . . . . . . . N 23. If diverter required, does it meet regulations. . . . . . . . . . if~ ~ - \.. . \ - , { 24. Drilling fluid program schematic & equip list adequate. . . . . N 't-)i~"""'\;;.<=- ~e~. ,\Q...N..,",- v..; ~~ . 25. BOPEs, do they meet regulation. . . . . . . . . . . . . . . . N 26. BOPE press rating appropriate; test to ~ psig. . N . 27. Choke ,:"anifold C?mplies w/A~I RP-53 (May 84). . . . . . . . N . ~ . 28. Work WIll occur without operation shutdbwn. . . . . . . . . . . Y lL ~ ~ (\. Cl \.~..,. - ~ I c6' 29. IspresenceofH:zSgasprobable................. Y~'-9"'~':::'\..c.J~\~Ò\.X:)q~C;~~~ ~~~C,)..~~~"P\~ ~(51it~"'~ 30. Permit can be issued wlo hydrogen sulfide measures. . . .. Y N 31. Data presented on potential overpressure zones. . . . . . . Y 32. Seismic analysis of shallow gas zones. . . . . . . . . . . . . A~ _~Tji! 33. Seabed condition survey (If off-shore). . . . . . . . . . . . . ~ ff76/ 34. Contact name/phone for weekly progress reports [explorat°fY, ANNULAR DISPOSAL35. With proper cementing records, this plan . (A) will contain waste in a suitable receiving zone; . . . . . . . (B) will not contaminate freshwater; or cause drilling waste. " to suñace; (C) will not impair mechanical integrity of the well used for disposal; Y N (0) will not damage producing formation or impair recovery from a Y N pool; and (E) will not circumvent 20 MC 25.252 or 20 MC 25.412. Y N GEO~GY: ENGINEERING: UIC/Annular COMMISSION: ~~ J ~~ wM---.... 8~s J J{)/ I TEM1.~l1 '~(~ JMH/~~F tlll3-IO( \ A~ -P~!'Ÿ- ¡~~ $(5'/6/ . ENGINEERING WRiM/I DATE . .~..!IV ( 1l/1 ~ GEOLOGY APPR DATE c 0 Z 0 , ) -I :E ::0 - -I m - z -I :I: - en » ::0 m ~. » ) Y N Y N ~ c::... ~~ ~ ~ ~ \ \. , þ,..~~ \ ~ .1.r\'R: ~\.:r~~~~~-\-\r-..~ u-Jè l\. Com mentsllnstructi ons: c:\msoffice\wordian\diana\checklist (rev. 11/01/100) K~t.f WELL PERMIT CHECKLIST COMPANY ~/ / 1~.5. WELL NAME 31-1- /c:>A PROGRAM: exp - dev - redrll V serv - well bore seg _ann. disposal para req - FIELD & POOL '-I"7b/l)é} INliCLASS ~¡/ lnlL GEOLAREA 8'1() UNIT# ()/IIc'() ON/OFFSHORE bP1 ADMINISTRATION 1. Permitfeeattached. .: . . ..' . . . . . ",' ... . . . , : ..' Nil ..1¡'--N-. Æ!-LV'IS,irx. +~a..,.. .a..~../S--h';"<~Ytt'f.-Io dr 'l/- 73f1'f- ./.J:z..6 t::Á.,4A9<1, 2. Le~senumberappropnate:-*..~.~~¡"~).ID:-YQ/. éÞ N b"{ ~1i-ðD"(;.,~, "'-r~s. .ðee;, :fL~ 2700 dLJ,e .Iv, L'$rf, fo/' <17.~tðU'\~~ ~~ 3. Unique well name and number. .. . . . . . . . . . . . . . . . ,N 15ø;~",¿e kca.,4.~"J/ ~e ;'101 ~VI rc...d 4!$ c~ olf~cY~ 4. Well located in a defined pool.. . . . . . . . . . . , . . . . . N F-'¡g.,... ~-( ,oJ. ("illt^<. ~":t*íc.-;...s. "gð . 5. Well located proper d~stance from drilling unit boundary. . . . N ~ ..:S Vr~ I ""ÇAv, ~ Vk... flXSt:'. .:-t')z.,ç,~ ( , -kæ rrrodt./G~fX:- 6. Welll?cated proper dl~tan~ fr°f!1.other~ells.. . . . . . . . . N 1./ItI.'¡"¿" v"'t ~ -n:,..¡q ( cb-~ 1{0#2. .:Ä, Al:>I!. e:rzgS-3Z1lf- 4D 7. Sufficient acreage available In dniling Unit.. . . . . . . . . . . N 8. If deviated. is wall bore plat included.. . . . . . . . . . . .. . N 9. Operator only affected party.. . . . . . . " . . . . , . . ~~ . N " ,- I £J i / 10. Operator has appropriate bond in force..~ .C,: ~'~~ . ?. Ið-I¡c N ~.'t' ¡;¡~ 4Þ7't.d ~~~/O lOlL!> Cßt-.lAU!..l'lC-d I, 3.,61. O.Þ(~ t:;H>7? J 11. Permit can be issued without conservation order. . . . . . . . N ¡1UJ~ 16> .phtll~s FfI-tslc"L).'XI1è...'s 5'9 S'2. /Be>. .ßÞ 12. Permit can be issued without administrative approval.. . . , . N 13. Can permit be approved before 15-day wait.. . . . . . . . . . D N , 14. Conductor string provided .. . . . . . . . . . . . . . . . . . Y N~ r '-\ 15. Surface casing protect saliknownUSDWs. . . . . . . . . . . Y N ,,>~Q~~<:,,\..d<;-Q:~~~\~~ ~ 16. CMT vol adequate to circulate on conductor & surf csg. . . . . Y N 17. CMT vol adequate to tie-in long string to surf csg. . . . . . . . ~ N 18. CMT will cover all known productive horizons. . . . . . . . . . N 19. Casing designs adequate for C. T. B & permafrost. . . . . . . . N 20. Adequate tankage or reserve pit.. . . . . , . . . . , . . . . . N 21. Ifare-drill,hasa10-403forabandonmentbeenapproved... N ~(:)C)-(J4<:' , 22. Adequate wellbore separation proposed.. . . . . . . . . . . . (J) N c:...\().,.,<t.">~ ~~\\ '\ c;. (:)~<:.\<N:>.. \ ~\\~ 23. If diverter required, does it meet regulations. . . . . . . . , . . Y N ~ P:... ~ \ I>.. ~ ~ \ ~ 24. Drilling fluid program schematic & equip list adequate. . . . . ~ N V \ö." ~ 00 \\ <::J'f "<:1I1'1\..\c:... "1 ~~ )Q.Ç'"'{)o..\o.."~c:) '^' I d- "'o~ ~c\~~,> 25. BOPEs. do they meet regulation. . . . . . . . . . . . . . . . Ç'D N \ '- e::Æ \J.... ~ 1No.. ~~'~" ~CL~ .~ADATE ,26. BOPEpress rating appropriate; test to L..\OOcJ psig. 1- N 'Kt.&~ ~,\.'-. }<Ò()O~~\. ' ~~/vL'I;J...\ 27.Choke'!1anifoldC?mpliesw/A~IRP~53(May84)........ NÐ~\.\.."I."""~~O\LR:Ù~~~~~ , Q¿ l.. . I 'ø.! 28. Work will occur without operation shutdown. . . . . . . . . . '-~ \~ ~'~ ~~r\,. ~t-- "u.~ ~'t,;~~~1 ~ ~ 29. Is presenceofH2S gas probable.. . . . . . . . . . . . . . . . Y\t!J~~\'S.~~~,\:>:C'C.'b~q:~~~~~\6\:::)6rO~Ctl"" ~ o.~~ <""'-cu\cJ \>'~~ 30. Permit can be issuedw/o hydrogen sulfide measures. . . . . y1Ñ) ~~~J. ~ A.~./e.J ~~S . 31. Da~a ~resente~ on potential overpressure zones -. . . . . . . ó?~ LlC',;'" ~5~ .~è...,~, ,', Þ /3: V ¡P~ . ,- . 32. Selsmlcanal~~lsofshallo~9aszones, . . . . . . . . . . . . J *~ ~f:r7"d-ñl"-7f~¿;.v.6Æk~ y-,~n(þþt¡-J!/.JJ:!?-Ah// APPR DATE 1 33. Seabed condition survey (if off-shore). . . . . . . . .:',:"'..:d::::/,-"J Y N fj!¿. ¡;¿.~_.....J .£1:> J t/ /{J) í' I], D 34. Contact name/phone for weekly progress reports [ex.fJP'"dtory only] Y N ... . ANNULAR DISPOSAL35. With proper cementing records, this plan . (A) will contain waste in a suitable receiving zone; . . . . . . . (B) will not contaminate freshwater; or cause drilling waste. .. to surface; (C) will not impair mechanical integrity of the well used for disposal; Y N (D) will not damage producing formation or impair recovery from a Y N pool; and (E) will not circumvent 20 AAC 25.252 or 20 AAC 25.412. Y N GEO~GY: ENGINEERING: UIC~nnular COMMISSION: HÞ8V"Y- ~ðìr WM ~-- K~S Co¡- ~ TE~7fJ1ll ~ JMH ~* z/'iJ'ID¡ AP~,P. DATE I, b lit,.O ENGINEERING c 0 Z 0 -f :E :::a ) -f m APPR DATE Y N Y N ~ ~~ / ~ C1.""~\o,\~~~\ö" ~~\> Gc::.~ ?\~""' \o~~~ <-,\~c:;.~ ~ ~\\.~ ~ Z -f :t - en » :::a m » ) GEOLOGY Commentsllnstructions: c:\msoffice\wordian\diana\checklist (rev. 11/011100) /1 KJPI.1 WELL PERMIT CHECKLIST COMPANY ~¡?eD WELL NAME3H -/G4 PROGRAM: exp - dev J' redrll ~ serv - wellbore ~g _ann. disposal para req- FIELD & POOL L(c.¡O /01') INIT CLASS "-:Þev 101 L GEOL AREA B90 UNIT# /::) III it? ( J ON/OFF SHORE OF) ADMINISTRATION 1. Permitfeeattached. . . . . .: . . . . . . . . . 'C' . . . " 'Ÿ N (3ð1.~ ~ rk4 >6l!'7P4//lf~cL d~4'¡;1'41 '7ßejè!'I'¡'~~ 2. Le~se number appropriate,~. $.e..¿, . c."'!" ~Tl;~. ~.Þ.- o/D I. N:fIE- ,~r~ ó~c-4ch~. /Ídh ~ 7IÆ.~ /f""Þš;f/ Z-~3/;{/ r~--=t (.J(::O7 f 3. Umquewellnameandnumber.................. N 1J1~¡,/4( /(tf!.~ tol-l-It.'n 1"17::>"- ~S-s-3z.-r7. ~J) 4.Welllocatedinadefinedpool.................. N 5. Well located proper distance from drilling unit boundary. . . . N 6. Well located proper distance from other wells.. . . . . . , . . N 7. Sufficient acreage available in drilling unit.. . . . . . . . . . . Y N 8. If deviated, is well bore plat included.. . . . . . . . . . . . . . N 9. Operator only affected party.. . . . . . . . . . . . . . . . . . N 10. Operator has appropriate bond in force. . . . . . . . . . . . . Y N 11. Permit can be issued without conservation order. . . . . . . . APM DATE 12. Permit ca~ be issued without administrativ~ approval.. . . . . ex< N AÐ- z.. . Z:¿.¿::t> 13. Can permit be approved before 15-day walt.. . . . . . . . . . C!) N ENGINEERING 14. Conductor string provided. . . . . . . . . . . . . . . . . . . Y N~ 15. Surface casing protects all known USDWs. . . . . . . . . . . Y N e:;;.~~e-\..o~ cu.h-\\,,-c "'-.)0.\\ 16. CMT vol adequate to circulate on conductor & surf csg. . . . . Y N .:> 17. CMT vol adequate to tie-in long string to surf csg. . . . . . . . Y N 18. CMTwill coverall known productive horizons. . . . . . . . . . m N 19. Casing designs adequate for C, T, B & permafrost. . . . . . . N 20. Adequate tankage or reserve pit.. . . . . . . . . . . . . . , . N 21. If a re-drill, has a 10-403 for abandonment been approved. . . 'N ç,.~~~~~ \ ~~~ \ t'~ '3C)'IJ. a,", S" 22. Adequate wellbore separation proposed.. . . . . . . , . . . . N 23. If diverter required, does it meet regulations. . . . . . . . . . -¥-N' ~ Þ. ~ ~ 24. Drilling fluid program schematic & equip list adequate. . . . . i N <:).~ \~C>.....),. d- ~\'-'-'(>-'\'-"or-^..lè.c" ~ \d-..<::." .ç\d'~) \-=- ~\c-l~'N:è} o~<;.~~~~ ~ 25. BOPEs, do they meet regulation. . . . . . . . . . . . . . . . '( N ~ DATE 26. BOPE press rating appropriate; test to š...S'Ot:') psig. N c'-- c:---... ~/' ( 3/~ -t:>Ò 27. Choke manifold complies w/API RP-53 (May 84). . . . . . . . N ,>r. \\ ,\,,~ c...~'u. ~\,),~ 'Ðou.)~~-\,~CJ..(v\.. 28. Work will occur without operation shutdown. . . . . . . . . . . N ¡... 29. Is presence of H2S gas probable.. . . . . . . . . . . . . . . . Y ~ \-\~ ~ 'Ie,. ~~..:\,,~~ ~<l:..~ ~~~oC)~.. ~~~ ~c,. ~~~~ o.~~<:;,... GEOLOGY 30. Permit can be issuedw/o hydrogen sulfide measures. . . . " /I n'~ A/',;,.k: A.n/I /1:.,' dr;/Þ¿?L/t~6A/~. . ~ "/?>41z¡f 31. Data presented on potential overpressure zones. . . . . ¿/ à ~ N "-::¡;¿ r// /t--rz; #::( ~ 5> l' ~~~ . ~b 32. Seismic analysis of shallow gas zones. . . . . . . . . . . ~ A Y N' ./.J A~ DATE 33. Seabed condition survey (if off-shore). . . . . . . . . . . ~ X~ N ~.J,.) 2.. 22. . OD 34. Contact name/phone for weekly progress reports [exploratory only] Cf) N ANNULAR DISPOSAL35. With proper cementing records, this plan (A) will contain waste in a suitable receiving zone; . . . . . . . (B) will not contaminate freshwater; or cause drilling waste. .. to surface; (C) will not impair mechanical integrity of the well used for disposal; (D) will not damage producing formation or impair recovery from a pool; and (E) will not circumvent 20 AAC 25.252 or 20 AAC 25.412. Y N GEOLOGY: ENGINEERING: UIC/Annular COMMISSION: ~crW"-.... WM "--- §~~ t121 ;$//1 TEM /filrr¡ Vfö~ CO t"ó3/1D c 0 Z 0 -t ~ ::0 '\ ( , I -t m DATE YN~ Y N t-....'\Ð ('"".....~\c.",\~,\~("~c;:)~ , Y N ~~~.. ~ \o..~ -\0 -..)":>C'L \ \è- Y N Z -t :I: - (J) » ::0 m » ,J' APPR Comments/Instructions: ~~8.F c:\msoffice\wordian\diana\checklist (rev. 02/17/00) ~ ~ 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. ~ ~ sperry-Sun Drilling Services LIS Scan Utility $Revision: 3 $ LisLib $Revision: 4 $ Mon Mar 04 08:53:03 2002 Reel Header Service name...... .......LISTPE Date.....................02/03/04 Origin.................. .STS Reel Name................UNKNOWN Continuation Number......Ol Previous Reel Name.......UNKNOWN Comments.................STS LIS Tape Header Service name.. ...........LISTPE Date.....................02/03/04 Origin...................STS Tape Name................UNKNOWN Continuation NLimber......Ol Previous Tape Name.......UNKNOWN Comments.................STS LIS Physical EOF Comment Record TAPE HEADER KLiparuk River Unit MWD/MAD LOGS # WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: # JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 2 AK-MM-ll192 R. FRENCH R. BOWIE # SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: MSL 0) # WELL CASING RECORD OPEN HOLE BIT SIZE (IN) 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING # REMARKS: Writing Library. Sçientific Technical Services Writing Library. Scientific Technical Services 3H-16A 501032009601 PHILLIPS Alaska, Inc. Sperry Sun 04-MAR-02 MWD RUN 3 AK-MM-11192 J. SACK D. HElM 12 12N 8E 1107 4998 .00 68.72 38.70 CASING SIZE (IN) 16.000 9.625 7.000 DRILLERS DEPTH (FT) 110.0 8943.0 8991.0 1. ALL DEPTHS ARE MEASURED DEPTHS (MD) UNLESS OTHERWISE STATED. 2. MWD RUN 1 IS DIRECTIONAL ONLY FOR SETTING WHIPSTOCK AND IS NOT PRESENTED. ~()ó -UJ.:J.- fO7d- ð ~ ,--... 3. MWD RUNS 2 AND 3 ARE DIRECTIONAL WITH DUAL GAMMA RAY (DGR) UTILIZING GEIGE MUELLER TUBE DETECTORS AND ELECTROMAGNETIC WAVE RESISTIVITY PHASE 4 (EWR4) . 4. MWD DATA IS CONSIDERED PDC PER THE E-MAIL FROM D. SCH!t\lARTZ Of' PHILLIPS ALASKA, INC. DATED 01/04/02. AUTHORIZED BY GKA GEOSIENCE GROU MWD DATA NOT SHIFTED TO PARENT WELL IN POST PROCESSING. THIS WELL KICKS OFF FROM 3H-16 AT 8991' MD, 5724' TVD (TOP OF WHIPSTOCK). ALL MWD LOG HEADER DATA RETAINS THE ORIGINAL DRILLER'S DEPTH REFERENCES. 5. MWD RUNS 2 AND 3 REPRESENT WELL 3H-16A WITH API # 50-029-20096-01. THIS WELL REACHED A TOTAL DEPTH OF 9698' MD, 5966' TVD. SROP = SMOOTHED RATE OF PENETRATION SGRC = SMOOTHED GAMMA RAY COMBINED SEXP = SMOOTHED PHASE SHIFT DERIVED RESISTIVITY ( EXTRA SHALLOW SPACING) SESP = SMOOTHED PHASE SHIFT DERIVED RESISTIVITY ( SHALLOW SPACING) SEMP = SMOOTHED PHASE SHIFT DERIVED RESISTIVITY ( MEDIUM SPACING) SEDP = SMOOTHED PHASE SHIFT DERIVED RESISTIVITY ( DEEP SPACING) SFXE = SMOOTHED FORMATION EXPOSURE TIME $ File Header Service name.............STSLIB.OOl Service Sub Level Name... Version Number...... .....1.0.0 Date of Generation.......02/03/04 Maximum Physical Record..65535 File Type................LO Previous File Name.......STSLIB.OOO Comment Record FILE HEADER FILE NUMBER: EDITED MERGED MWD Depth shifted and DEPTH INCREMENT: # FILE SUMMARY PBU TOOL CODE GR FET RPD RPM RPS RPX ROP $ 1 clipped curves; all bit runs merged. .5000 START DEPTH 8963.5 8981.0 8981.0 8981. 0 8981.0 8981. 0 9015.0 STOP DEPTH 9645.0 9652.0 9652.0 9652.0 9652.0 9652.0 9697.5 # BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH $ # HERGED PBU MWD MWD $ DATA SOURCE TOOL CODE BIT RUN NO MERGE TOP 2 8963.5 3 9260.5 MERGE BASE 9260.0 9697.5 # ~ ~ REMARKS: MERGED MAIN PASS. $ # Data Format Specification Record Data Record Type..................O Data Specification Block Type.....O Logging Direction.................Down Optical log depth units...........Feet Data Reference Point..............Undefined Frame Spacing.....................60 .1IN Max frames per record.............Undefined Absent value......................-999 Depth U!ìÍts....................... Datum Specification Block sub-type...O Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD FT!H 4 1 68 4 2 GR MWD API 4 1 68 8 3 RPX MWD OHMM 4 1 68 12 4 RPS MWD OHMM 4 1 68 16 5 RPM MWD OHMM 4 1 68 20 6 RPD MWD OHMM 4 1 68 24 7 FET MWD HR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 8963.5 9697.5 9330.5 1469 8963.5 9697.5 ROP MWD FT!H 3.63 349.25 67.9075 1366 9015 9697.5 GR MWD API 52.29 257.79 106.661 1364 8963.5 9645 RPX MWD OHMM 1. 58 1660.13 15.5601 1343 8981 9652 RPS MWD OHMM 1. 62 1660.25 17.8786 1343 8981 9652 RPl'j HWD OH¡V¡¡Vj 0.09 2000 27 . 6831 1343 8981 9652 RPD Hl'JD OHMM 0.69 2000 28.0687 1343 8981 9652 FET MWD HR 0.7 31. 09 4.28701 1343 8981 9652 First Reading For Entire File..........8963.5 Last Reading For Entire File...........9697.5 File Trailer Service name.............STSLIB.OOl Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......02!03!04 Maximum Physical Record..65535 File Type................LO Next File Name...........STSLIB.002 Physical EOF File Header Service name. """ ......STSLIB.002 Service Sub Level Name... Version Number...........l.0.0 Date of Generation.......02!03!04 Haximum Physical Record..65535 File Type................LO Previous File Name.......STSLIB.OOl Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE 2 header data for each bit run in separate files. 2 .5000 START DEPTH STOP DEPTH ~ GR RPX FET RPD RPS RPM ROP $ 8963.5 8981. 0 8981. 0 8981.0 8981.0 8981. 0 9015.0 9208.0 9214.5 9214.5 9214.5 9214.5 9214.5 9260.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): 'I'D DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR EWR4 $ DUAL GAMMA RAY ELECTROMAG. RESIS. 4 # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING 'I'ERMPERA'I'URE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type..................O Data Specification Block Type.....O Logging Direction.................Down Optical log depth Llnits...........Feet Data Reference Point..............Undefined Frame Spacing.....................60 .IIN Max frames per record.............Undefined Absent value......................-999 Depth Units....................... Datum Specification Block sub-tò~e...O ~ 20-NOV-01 Insite 4.05.5 66.16 Memory 9260.0 54.9 56.0 TOOL NUMBER PB02291HAGR4 PB02291HAGR4 6.125 Water 11. 00 55.0 9.3 750 3.0 Based 1.100 70.0 .631 127.0 .800 70.0 1. 400 70.0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWDO20 FT/H 4 1 68 4 2 GR MWD020 API 4 1 68 8 3 RPX MWD020 OHMM 4 1 68 12 4 RPS MWD020 OHMM 4 1 68 16 5 r----.. ...-, RPM RPD FET MWD020 MWD020 MWD020 OHMM OHMM HR 4 4 4 1 1 1 68 68 68 20 24 28 6 7 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 8963.5 9260 9111. 75 594 8963.5 9260 ROP MWD020 FT/H 3.63 349.25 55.6066 491 9015 9260 GR MWD020 API 90.44 257.79 132.345 490 8963.5 9208 RPX MWD020 OHMM 1. 58 1660.13 9.2241 468 8981 9214.5 RPS MWD020 OHMM 1. 62 1660.25 15.539 468 8981 9214.5 RPM MWD020 OHMM 0.09 2000 44.2233 468 8981 9214.5 RPD M\\JD020 OHMM 0.69 2000 41.0519 468 8981 9214.5 FET MWD020 HR 0.95 31. 09 5.16532 468 8981 9214.5 First Reading For Entire File..........8963.5 Last Reading For Entire File...........9260 File Trailer Service name.............STSLIB.002 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation. ......02/03/04 Maximum Physical Record..65535 File Type................LO Next File Name...........STSLIB.003 Physical EOF File Header Service name... .... ......STSLIB.003 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......02/03/04 Maximum Physical Record..65535 File Type................LO Previous File Name.......STSLIB.002 Comment Record FILE HElmER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE GR RPD RPM RPS RPX 3 header data for each bit run in separate files. 3 .5000 FET ROP $ START DEPTH 9208.5 9215.0 9215.0 9215.0 9215.0 9215.0 9260.5 STOP DEPTH 9645.0 9652.0 9652.0 9652.0 9652.0 9652.0 9697.5 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TO DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 22-NOV-Ol Insite 4.05.5 66.37 Memory 9698.0 55.7 ~ MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE DGR EWR4 $ BOTTOM) TOOL TYPE DUAL GAMMA RAY ELECTROMAG. RESIS. 4 # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C31: RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REM,z'.RKS : $ # Data Format Specification Record Data Record Type..................O Data Specification Block Type.....O Logging Direction.................Down Optical log depth Llnits...........Feet Data Reference Point..............Undefined Frame Spacing.....................60 .1IN Max frames per record.... .........Undefined Absent value......................-999 Depth Units....................... Datum Specification Block sub-tj~e...O .~ 89.6 TOOL NUMBER PB02282FGRV4 PB02282FGRV4 6.125 Water 11.00 53.0 9.1 750 2.6 Based 1.000 .544 1. 300 1.700 72.0 138.0 72.0 72.0 Name Service Order Units Size Nsam Rep Code Offset Charmel DEPT FT 4 1 68 0 1 ROP I-MD030 FT/H 4 1 68 4 2 GR MWD030 API 4 1 68 8 3 RPX MWD030 OHMM 4 1 68 12 4 RPS MWD030 OHMM 4 1 68 16 5 RPM MWD030 OHMM 4 1 68 20 6 RPD MWD030 OHMM 4 1 68 24 7 FET MWD030 HR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 9208.5 9697.5 9453 979 9208.5 9697.5 Rap MWD030 FT/H 6.49 269.71 74.8101 875 9260.5 9697.5 GR MWD030 API 52.29 160.88 92.2608 874 9208.5 9645 RPX MWD030 OHMM 2.3 112.6 18.9489 875 9215 9652 RPS MWD030 OHMM 2.36 102.69 19.13 875 9215 9652 RPM MWD030 OHMM 2.49 87.1 18.8365 875 9215 9652 kt'D M\~D030 OHMM 2.51 88.7 21.1246 875 9215 9652 FET MWD030 HR 0.7 24.6 3.81725 875 9215 9652 First Reading For Entire File..........9208.5 Last Reading For Entire File...........9697.5 ~, File Trailer Service name.............STSLIB.OO3 Service Sub Level Name... Version Number...........l.O.O Date of Generation.......02/03/04 Maximum Physical Record..65535 File Type................LO Next File Name...........STSLIB.OO4 Physical EOF Tape Trailer Service name............ .LISTPE Date.................... .02/03/04 Origin...................STS Tape Name................UNKNOWN Continuation Number......Ol Next Tape Name...........UNKNOWN Comments.................STS LIS Writing Library. Reel Trailer Service name.... .... .....LISTPE Date.....................O2/03/04 Origin...................STS Reel Name........ ........UNKNOWN Continuation Number......Ol Next Reel Name...........UNKNOWN Comments.................STS LIS Writing Library. Physical EOF Physical EOF End Of LIS File ~ Scientific Technical Services Scientific Technical Services ,~, ~ **** REEL HEADER **** MWD 03/08/25 BHI 01 LIS Customer Format Tape **** TAPE HEADER **** MWD 03/08/25 271269 01 2 3/8" CoilTrak *** LIS COMMENT RECORD *** !!!!!!!!!!!!!!!!!!! Remark File Version 1.000 !!!!!!!!!!!!!!!!!!! Extract File: ldwg.las ~Version Information VERSo WRAP. ~Well Information Block #MNEM.UNIT Data Type #--------- ------------- STRT.FT 8963.5000: STOP.FT 10457.5000: STEP.FT 0.5000: NULL. -999.2500: COMPo COMPANY: WELL. WELL: FLD. FIELD: LOC. LOCATION: CNTY. COUNTY: STAT. STATE: SRVC. SERVICE COMPANY: TOOL. TOOL NAME & TYPE: DATE. LOG DATE: API. API NUMBER: ~Parameter Information Block #MNEM.UNIT Value #--------- ------------------------- SECT. 12 TOWN.N T12N RANG. R8E PDAT. MSL EPD .F 0 LMF . RKB FAPD.F 68.72 DMF KB EKB .F 68.72 EDF .F N/A EGL .F N/A CASE.F N/A OSl . DIRECTIONAL -Remarks (1) All depths are Measured Depths (MD) unless otherwise noted. 1. 20: NO: CWLS log ASCII Standard -VERSION 1.20 One line per frame Information ------------------------------- t) CO- () d ;;;< J J )-& \ Starting Depth Ending Depth Level Spacing Absent Value Phillips Alaska, Inc. 3H-16APB1 Kuparuk River Unit 70 deg 24' 45.857" N 150 deg 0' 39.417" W North Slope Alaska Baker Hughes INTEQ 2 3/8" CoilTrak 15-Apr-02 501032009670 Description ------------------------------- Section Township Range Permanent Datum Elevation Of Perm. Datum Log Mea~ured from Feet Above Perm. Datum Drilling Measured From Elevatión of Kelly Bushing Elevation of Derrick Floor Elevation of Ground Level Casing Depth Other Services Line 1 ~~~\Y'\~ RECEIVED AUG 26 LOO3 Alaska 0;1 if: Gas Conti. CommiMn Am.'ttorage /~ ,~ (2) (3) (4) All depths are Bit Depths unless otherwise noted. All Garrnna Ray data (GRCX) presented is real time data. Well 3H-16APB1 was drilled as a sidetrack to Well 3H-16 and was kicked off at 9698' MD. (5) Baker Hughes INTEQ utilized CoilTrak downhole tools and Advantage sutface system. (6) Wells 3H-16A and 3H-16APB1 were drilled as e~tensions of a previous sidetrack attempt logged by Sperry Sun. The PDC for these boreholes is Sperry Sun Garrnna Ray (Authorized by CPA Geoscience). Per CPA Geoscience request, the shallower Sperry Sun GR was spliced at 9644' MD to the' INTEQ GR below. Due to a lack of marker beds in the short overlap section between the two GR curves, no depth shifts were applied prior to splicing. (7) The data presented here is final and has not been depth shifted. This final spliced GR is the PDC for future logs in the lower borehole (Per CPA Geoscience). (8) Garrnna Ray detector type: scintillator. (9) Interval from 10433' MD (5893' SSTVD) to 10457' MD (5891' SSTVD) was not drilled due to sensor bit offset at TD. MNEMONICS: GRCX -> Garrnna Ray MWD-API [MWD] (MWD-API units) ROPS -> Rate of Penetration, feet/hour TVD -> True Vertical Depth, feet/hour SENSOR OFFSETS: RUN GAMMA 2 23.89 ft. DIRECTIONAL 23.74 ft. Tape Subfile: 1 64 records... Minimum record length: Maximum record length: 14 bytes 132 bytes **** FILE HEADER **** MWD .001 1024 *** INFORMATION TABLE: CONS MNEM VALU ------------------------------ WDFN LCC CN WN FN COUN STAT mwd.xtf 150 Phillips Alaska, Inc. 3H-16APB1 Kuparuk River Unit North Slope Alaska *** LIS COMMENT RECORD *** !!!!!!!!!!!!!!!!!!! Remark File Version 1.000 1. The data presented has been edited from the field raw data. 2. Wells 3H-16A and 3H-16APB1 were drilled as extensions of a previous sidetrack attempt logged by Sperry Sun. The PDC for these boreholes is the Sperry Sun Garrnna Ray (Authqrized by CPA Geoscience). Per CPA Geoscience request, the shallower Sperry Sun GR was spliced at 9644 ft MD to the INTEQ GR þelow. Due to a lack of marker beds in the short overlap section þetween the two GR curves, no depth shifts were applied prior to splicing. 3. The data presented here is final and has not been depth shifted. This final spliced GR is the PDC for future logs in the lower borehole (Per CPA Geoscience). ,~ *** INFORMATION TABLE: CIFO MNEM CRAN DIMT CNAM ODEP GR ROP GR ROP GRCX ROPS ---------------------------------------------------- * FORMAT RECORD (TYPE# 64) Data record type is: a Datum Frame Size is: 12 bytes Logging direction is down (value= 255) Optical Log Depth Scale units: Feet Frame spacing: 0.500000 Frame spacing units: [F ] Number of frames per record is: One depth per frame (value= 0) Datum Specification Block Sub-type is: FRAME SPACE = 0.500 * F ONE DEPTH PER FRAME Tape depth ID: F 2 Curves: Name Tool Code Samples units 1 2 68 68 1 1 API F/HR GR ROP MWD MWD Total Data Records: 36 Tape File Start Depth 8963.500000 Tape File End Depth 10457.500000 Tape File Level Spacing = 0.500000 Tape File Depth Units = feet **** FILE TRAILER **** Tape Subfile: 2 45 records... Minimum record length: Maximum record length: 54 bytes 4124 bytes **** FILE HEADER **** MWD .002 1024 *** INFORMATION TABLE: CONS MNEM VALU ------------------------------ 0.0 0.0 84 Size 1 Length 4 4 4 4 ------- 8 ~ /--.., WDFN LCC CN WN FN COUN STAT raw.xtf 150 Phillips Alaska, Inc. 3H-16APB1 Kuparuk River Unit North Slope Alaska *** LIS COMMENT RECORD *** !!!!!!!!!!!!!!!!!!! Remark File Version 1.000 The data contains the unedited field raw data. *** INFORMATION TABLE: CIFO MNEM CHAN DIMT CNAM ODEP GRCX ROPS GRCX ROPS 0.0 0.0 ---------------------------------------------------- GRCX ROPS * FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame Size is: 12 bytes Logging direction is down (value= 255) Optical Log Depth Scale Units: Feet Frame spacing: 0.250000 Frame spacing units: [F ] Number of frames per record is: One depth per frame (value= 0) Datum Specification Block Sub-type is: 84 FRAME SPACE = 0.250 * F ONE DEPTH PER FRAME Tape depth ID: F 2 Curves: Name Tool Code Samples Units Size 1 2 68 68 API F/HR 1 1 GRCX ROPS MWD MWD Total Data Records: 46 Tape File Start Depth 9501.000000 Tape File End Depth 10457.500000 Tape File Level Spacing = 0.250000 Tape File Depth Units = feet **** FILE TRAILER **** Tape Subfile: 3 55 records... Minimum record length: Maximum record length: 54 bytes 4124 bytes **** TAPE TRAILER **** MWD 03/08/25 1 Length 4 4 4 4 ------- 8 ~ 271269 01 /~ **** REEL TRAILER **** MWD 03/08/25 BHI 01 Tape Subtile: 4 Minimum record length: Maximum record length: ~ 2 records... 132 bytes 132 bytes Tape Subtile 2 is type: LIS DEPTH 8963.5000 8964.0000 9000.0000 9050.0000 9100.0000 9150.0000 9200.0000 9250.0000 9300.0000 9350.0000 9400.0000 9450.0000 9500.0000 9550.0000 9600.0000 9650.0000 9700.0000 9750.0000 9800.0000 9850.0000 9900.0000 9950.0000 10000.0000 10050.0000 10100.0000 10150.0000 10200.0000 10250.0000 10300.0000 10350.0000 10400.0000 10450.0000 10457.5000 GR 174.6200 173.7500 114.4000 142.8400 135.7600 136.0600 130.3200 130.9500 142.9100 65.3100 69.8900 81. 4200 79.5100 100.4300 70.1300 31. 5703 50.6815 55.7088 51. 9241 35.5107 56.9290 50.8502 52.8596 56.8949 53.3183 58.5966 49.6185 51. 5007 65.2359 53.5893 60.1411 -999.2500 -999.2500 Tape File Start Depth Tape File End Depth Tape File Level Spacing = Rap -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 0.0000 2.6000 28.4600 118.0250 6.1600 62.5200 58.1333 26.7976 6.8000 42.0000 10.3000 42.5400 70.4400 93.6750 13.1000 18.0000 0.9400 8963.500000 10457.500000 0.500000 ," Tape File Depth Units ,------.. é------" = feet ~ Tape Subfile 3 is type: LIS DEPTH 9501.0000 9501. 2500 9550.0000 9600.0000 9650.0000 9700.0000 9750.0000 9800.0000 9850.0000 9900.0000 9950.0000 10000.0000 10050.0000 10100.0000 10150.0000 10200.0000 10250.0000 10300.0000 10350.0000 10400.0000 10450.0000 10457.5000 GRCX 42.4959 40.6647 37.4204 30.8056 31. 5703 50.6815 55.7088 51. 9241 35.5107 56.9290 50.8502 52.8596 56.8949 53.3183 58.5966 49.6185 51. 5007 65.2359 53.5893 60.1411 -999.2500 -999.2500 /~ ROPS -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 0.0000 2.6000 28.4600 118.0250 6.1600 62.5200 58.1333 26.7976 6.8000 42.0000 10.3000 42.5400 70.4400 93.6750 13.1000 18.0000 0.9400 Tape File Start Depth 9501.000000 Tape File End Depth 10457.500000 Tape File Level Spacing = 0.250000 Tape File Depth Units = feet .~ a C:ö -oÕ) ~ It 5~? ~ **** REEL HEADER **** MWD 03/01/22 BHI 01 LIS Customer Format Tape **** TAPE HEADER **** MWD 03/01/21 217269 01 2 3/8" CoilTrak *** LIS COMMENT RECORD *** !! !! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! !! ! ! ! ! ! ! ! ! ! ! ! ! ! !! ! ! Remark File Version 1.000 Extract File: ldwg.las -Version Information VERSo WRAP. -Well Information Block #MNEM.UNIT Data Type #--------- ------------- STRT.FT 8963.0000: STOP.FT 10943.0000: STEP.FT 0.5000: NULL. -999.2500: COMPo COMPANY: WELL. WELL: FLD . FIELD: LOC . LOCATION: CNTY. COUNTY: STAT. STATE: SRVC. SERVICE COMPANY: TOOL. TOOL NAME & TYPE: DATE. LOG DATE: API. API NUMBER: -Parameter Information Block #MNEM.UNIT Value #--------- ------------------------- 1. 20: NO: CWLS log ASCII Standard -VERSION 1.20 One line per frame Information ------------------------------- Starting Depth Ending Depth Level Spacing Absent Value Phillips Alaska, Inc. 3H-16A Kuparuk River Unit 70 deg 24' 45.853" N 150 deg 0' 39.451" W North Slope Alaska Baker Hughes INTEQ 2 3/8" CoilTrak 19-Apr-02 501032009601 ------------------------------- Description SECT. TOWN.N RANG. PDAT. EPD .F LMF . FAPD.F DMF EKE .F EDF .F EGL .F CASE.F OSl . -Remarks 12 T12N R8E MSL 0 RKB 68.72 KB 68.72 N/A N/A N/A DIRECTIONAL Section Township Range Permanent Datum Elevation Of Perm. Datum Log Measured from Feet Above Perm. Datum Drilling Measured From Elevation of Kelly Bushing Elevation of Derrick Floor Elevation of Ground Level Casing Depth Other Services Line 1 9810'MD sutface (6) previous boreholes is Geoscience the INTEQ section splicing. (7) This was not ,~ ~ (1) (2) (3) (4 ) All depths are Measured Depths (MD) unless otherwise noted. All depths are Bit Depths unless otherwise noted. All Gamma Ray data (GRCX) presented is realtime data. Well 3H-16A was drilled as a sidetrack to Well 3H-16APB1 at (5) (5897' SSTVD) on Run 5. Baker Hughes INTEQ utilized CoilTrak downhole tools and Advantage system. Wells 3H-16A and 3H-16APB1 were drilled as extensions of a sidetrack attempt logged by Sperry Sun. The PDC for these Sperry Sun Gamma Ray (Authorized by CPA Geoscience). Per CPA request, the shallower Sperry Sun GR was spliced at 9644' MD to GR below. Due to a lack of marker beds in the short overlap between the two GR curves, no depth shifts were applied prior to The data presented here is final and has not been depth shifted. (8) (9) final spliced GR is the PDC for future logs in the lower borehole (Per CPA Geoscience). Gamma Ray detector type: scintillator. Interval from 10919' MD (5888' SSTVD) to 10943' MD (5888' SSTVD) drilled due to sensor bit offset at TD. MNEMONICS: GRCX -> Gamma Ray MWD-API [MWD] (MWD-API units) ROPS -> Rate of Penetration, feet/hour TVD -> True Vertical Depth, feet/hour SENSOR RUN 4 5 6 OFFSETS: GAMMA 23.89 ft. 23.84 ft. 23.09 ft. DIRECTIONAL 23.74 ft. 23.70 ft. 23.94 ft. CURVE SHIFT DATA BASELINE, MEASURED, N/A N/A EOZ END Tape Subfile: 1 DISPLACEMENT N/A 72 records... Minimum record length: Maximum record length: 10 bytes 132 bytes MWD **** FILE HEADER **** .001 1024 *** INFORMATION TABLE: CONS MNEM VALU ,~ ~ ---------------------------- WDFN LCC CN WN FN COUN STAT mwd.xtf 150 Philips Alaska Inc. 3H-16A Kuparuk River Unit North Slope Alaska *** LIS COMMENT RECORD *** !!!!!!!!!!!!!!!!!!! Remark File Version 1.000 1. The data presented has been edited from the field raw data. 2. Wells 3H-16A and 3H-16APBl were drilled as extensions of a previous sidetrack attempt logged by Sperry Sun. The PDC for these boreholes is the Sperry Sun Gamma Ray (Authorized by CPA Geoscience). Per CPA Geoscience request, the shallower Sperry Sun GR was spliced at 9644 ft MD to the INTEQ GR below. Due to a lack of marker beds in the short overlap section between the two GR curves, no depth shifts were applied prior to splicing. 3. The data presented here is final and has not been depth shifted. This final spliced GR is the PDC for future logs in the lower borehole (Per CPA Geoscience). *** INFORMATION TABLE: CIFO MNEM CHAN DIMT CNAM ODEP GR ROP ---------------------------------------------------- GRCX ROPS GR ROP 0.0 0.0 * FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame Size is: 12 bytes Logging direction is down (value= 255) Optical Log Depth Scale Units: Feet Frame spacing: 0.500000 Frame spacing units: [F ] Number of frames per record is: One depth per frame (value= 0) Datum Specification Block Sub-type is: 84 1 FRAME SPACE = 0.500 * F ONE DEPTH PER FRAME Tape depth ID: F 2 Curves: Name Tool Length Code Samples Units Size 1 2 68 68 1 1 GR ROP 4 4 4 4 MWD MWD API F/HR ------- 8 Total Data Records: 48 Tape File Start Depth 8963.500000 Tape File End Depth 10943.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = feet ,~ **** FILE TRAILER **** Tape Subfile: 2 57 records... Minimum record length: Maximum record length: 54 bytes 4124 bytes **** FILE HEADER **** MWD .002 1024 *** INFORMATION TABLE: CONS MNEM VALU ---------------------------- WDFN LCC CN WN FN COUN STAT raw.xtf 150 Philips Alaska Inc. 3H-16A Kuparuk River Unit North Slope Alaska *** LIS COMMENT RECORD *** ~ !!!!!!!!!!!!!!!!!!! Remark File Version 1.000 The data contains the unedited field raw data. *** INFORMATION TABLE: CIFO MNEM CHAN DIMT CNAM ODEP GRCX ROPS GRCX ROPS GRCX ROPS ---------------------------------------------------- * FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame Size is: 12 bytes Logging direction is down (value= 255) Optical Log Depth Scale Units: Feet Frame spacing: 0.250000 Frame spacing units: [F ] Number of frames per record is: One depth per frame (value= 0) Datum Specification Block Sub-type is: FRAME SPACE = 0.250 * F ONE DEPTH PER FRAME Tape depth ID: F 2 Curves: Name Tool Code Samples Units 1 68 1 MWD API GRCX 0.0 0.0 84 Size 1 Length 4 4 2 ROPS ~, MWD 68 Total Data Records: 1 69 F/HR Tape File Start Depth 9501.000000 Tape File End Depth 10943.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = feet Tape Subtile: 3 **** FILE TRAILER **** 78 records... Minimum record length: Maximum record length: 54 bytes 4124 bytes **** TAPE TRAILER **** MWD 03/01/21 217269 01 **** REEL TRAILER **** MWD 03/01/22 BHI 01 Tape Subtile: 4 2 records... Minimum record length: Maximum record length: 132 bytes 132 bytes Tape Subtile 1 is type: LIS Tape Subtile 2 is type: LIS DEPTH 8963.5000 8964.0000 9000.0000 9100.0000 9200.0000 9300.0000 9400.0000 9500.0000 9600.0000 9700.0000 9800.0000 9900.0000 10000.0000 10100.0000 10200.0000 10300.0000 10400.0000 10500.0000 GR 174.6200 173.7500 114.4000 135.7600 130.3200 142.9100 69.8900 79.5100 70.1300 52.1861 52.7368 78.2356 80.3892 37.1474 51.0097 66.7303 63.1888 37.9132 ROP -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 0.0000 28.4600 59.2500 65.1900 88.8400 69.8400 77.7267 53.1100 132.7200 4 ------- .~ 4 8 10600.0000 10700.0000 10800.0000 10900.0000 10943.0000 ~. 49.6320 57.3634 74.1334 81.2644 -999.2500 ....--.., 149.7240 101.4900 19.5000 77.5400 34.5900 Tape File Start Depth 8963.500000 Tape File End Depth 10943.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = feet Tape Subfile 3 is type: LIS DEPTH 9501.0000 9501. 2500 9600.0000 9700.0000 9800.0000 9900.0000 10000.0000 10100.0000 10200.0000 10300.0000 10400.0000 10500.0000 10600.0000 10700.0000 10800.0000 10900.0000 10943.0000 GRCX 44.2033 40.9547 30.3931 52.1861 52.7368 78.2356 80.3892 37.1474 51.0097 66.7303 63.1888 37.9132 49.6320 57.3634 74.1334 81. 2644 -999.2500 Raps -999.2500 -999.2500 -999.2500 0.0000 28.4600 59.2500 65.1900 88.8400 69.8400 77.7267 53.1100 132.7200 149.7240 101. 4900 19.5000 77.5400 34.5900 Tape File Start Depth 9501.000000 Tape File End Depth 10943.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = feet Tape Subtile 4 is type: LIS
