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Home My WebLink About204-016 • � P77.7X04-0 /� Loepp, Victoria T (DOA) From: Heskin, Sara E <Sara.E.Heskin@conocophillips.com> Sent: Wednesday, March 14, 2018 10:39 AM To: Loepp,Victoria T(DOA) Subject: RE: [EXTERNAL]RE:CPAI KRU 3F-19A(PTD#204-016)Change in artificial lift Follow Up Flag: Follow up Flag Status: Flagged Hi Victoria, No worries,thanks for the guidance! I'll start working on the Sundry. Sincerely, Sara.if e4k ' Wells Engineer CPF3 &Wells Data Analytics SCANS ConocoPhillips Alaska Office: 907-265-1027 sara.heskin@conocophillips.com From: Loepp,Victoria T(DOA) [mailto:victoria.loepp@alaska.gov] Sent:Wednesday, March 14,2018 9:39 AM To: Heskin,Sara E<Sara.E.Heskin@conocophillips.com> Subject: [EXTERNAL]RE:CPAI KRU 3F-19A(PTD#204-016)Change in artificial lift Sara, I apologize for overlooking this. Please submit a 10-403 so we can track changes in artificial lift method in the well file. We can process this change(10-403)quickly. Thanx, Victoria From: Heskin,Sara E<Sara.E.Heskin@conocophillips.com> Sent:Wednesday, March 14, 2018 9:14 AM To: Loepp,Victoria T(DOA)<victoria.loepp@alaska.gov> Subject: RE:CPAI KRU 3F-19A(PTD#204-016) Hi Victoria, I just wanted to touch base and see if you have had time to review my question below about 10-404/10-403 Sundry requirements for installing a formation powered jet pump on E-line in a gas lifted producer. Thanks! 1 • SGWPV 4-Ee k(ds"v Wells Engineer CPF3 &Wells Data Analytics ConocoPhillips Alaska Office: 907-265-1027 sara.heskin@conocophillips.com From: Heskin,Sara E Sent:Tuesday, February 13, 2018 4:09 PM To: 'Loepp,Victoria T(DOA)'<victoria.loepp@alaska.gov> Subject:CPAI KRU 3F-19A(PTD#204-016) Hi Victoria, I have recently transitioned from my previous role as a Workover Engineer and have moved to the Wells group under Ty Senden. I am working on a well procedure to install a formation powered jet pump on Slick Line/E-Line in KRU producer 3F-19A(PTD#204-016).This well is currently producing via gas-lift with a high water cut and we would like to try and optimize production.After reviewing the Sundry Matrix, I am uncertain of the 10-403/10-404 requirements for installing a jet-pump off rig, in a well that has previously been on gas-lift.Could you please advise on what forms to submit? Sincerely, Sarcvli&an/ , Wells Engineer CPF3 &Wells Data Analytics ConocoPhillips Alaska Office: 907-265-1027 sara.heskinaconocophillips.com 2 • O be) L vw , � 5 hi H WOW CO O`w VI - . Oate. Y O N CV _ _ > Q p •C a- r U +O' > a u CO CO c c c o` 0 c `6 'c 4' 15 Qr: - p' c0 p C U v a CU < 0 < C7 CO 00 0o a0 CO 00 aO C 6 cm -.1 F- r Q O d C C C C C C C E a�-� ..0 -D O N vii ica cc as ra co ea w. m r M a �n CO aT c ro u t e a N r r r O +' i C VI 0 Q E' > -o UJ 1 , v O C f" ++ U '1' c0 0 00000000 c0 v 'o „, U ��II LU W W W W W W W W OA C F. LL LL LL LL LL LL LL LL N v Q J J J J J J J J a > t _v a Z Z Q Q Q Q Q Q Q Q .O 0 C }' `c Z Z Z Z Z Z C p UCO a p C LL LL LL LL LL LL LL LL CC II: N s UJ 4-d > C E (9. 4 >- cu 0°1 `0 p -0ff a s u a v u > .-- O c c p °' 44.-.. co IP: LU u c O • z F > U v o . 09 v > {,c tc° ,:„,/, m Q v CO a i,. 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CO °t U C F fp tn, o ! • a, u c x m N u 0 E \` I Q 0-0 fl au o L ' (V Zr C7NZ pp +-0 lo >. 03 �('➢ of Y O E ' r, N > 1- Y c) c r ro O to a) *- c6 Y rD ,L y _O u o o v a Q ❑ E O Q' m ❑ Q 'R 0 tO t0 CO CO CD t0 tD CD COO t0 CD t0 O CU L a) Ov L N Q �_ 0 > > > > > > > > O O O O O E 'O +' '6 ON Lu z z z z z z z z z z z z z C 0 co v 2 Z a N N t') C) I() t0 t- to 0 0 r N v) O O C vl Z a c„ v ; e e Image Project Well History File Cover Page XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. aQ £f - 0 1 (p Well History File Identifier Organizing (done) D Two-sided 1111111111111111111 D Rescan Needed /1111111//111/11111 RESCAN ~olor Items: D Greyscale Items: DIGITAL DATA ~iskettes, No. I D Other, Norrype: OVERSIZED (Scannable) D Maps: D Other Items Scannable by a Large Scanner D Poor Quality Originals: OVERSIZED (Non-Scannable) D Other: D Logs of various kinds: Date: 5/ a/00 f / Date: 6/a/00 , , a- X 30 = Date: Ò . D Other:: NOTES: BY: C MariO 151 me /111/111111111 "III Project Proofing BY: ~ 151 Scanning Preparation BY: +::J-CJ = TOTAL PAGES (Count does not include cover sheet) 151 Production Scanning Stage 1 Page Count from Scanned File: ~ (Count does include cover sheet) Page Count Matches Number in Scanning Preparation: V YES BY: ~ Date:5(ð/Ofo Stage 1 If NO in stage 1, page(s) discrepancies were found: YES 11111111I11111 "III NO 151 vvv P NO BY: Maria Date: 151 /1111111//111/ "II/ Scanning is complete at this point unless rescanning is required. ReScanned /1111111/11111 "III BY: Maria Date: 151 Comments about this file: Quality Checked 1111111111111111111 10/6/2005 Well History File Cover Page.doc L , MAY 102013 WELL LOG TRANSMITTAL AOG CC To: Alaska Oil and Gas Conservation Comm. u : , 0 Attn.: Makana Bender 2�, l 0* 333 West 7th Avenue, Suite 100 `L Anchorage, Alaska 99501 Z2.53' RE: Production Profile: 3F-19A Run Date: 4/11/2013 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Matthew Cook, Halliburton Wireline& Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 matthew.cook@halliburton.com 3F-19A Digital Data in LAS format, Digital Log Image file, Interpretation Report 1 CD Rom 50-029-22680-01 Production Profile Log 1 Color Log 50-029-22680-01 swam LIAR 1 3 2014 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline& Perforating Attn: Matthew Cook 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-273-3572 Fax: 907-273-3535 matthew.cook@halliburton.com Date: Gj Vo l3 Signed: NZA,,, • • WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. February 3, 2011 Attn.: Christine Mahnken 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 KAME MAR 0 201 RE: Leak Detection Log / SpectraFlow: 3F -19A Run Date: 2/1/2011 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Rafael Barreto, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 3F -19A Digital Data in DLIS /LAS format, Digital Log file 1 CD Rom 50- 029 - 22680 -01 SpectraFlow (Field print) 1 Color Log 50- 029 - 22680 -01 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Rafael Barreto 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907 - 273 -3527 c Oq— 0/ Fax: 907 - 273 -3535 rafael.barreto @halliburton.com 0 J7' Date: - Signed: DS, is) 30,1q -4Mtka DU • • ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510 -0360 February 14, 2011 c ( , b 7_E WEN'. . . Commissioner Dan Seamount FEB 17 2011 Alaska Oil & Gas Commission 333 West 7 Avenue, Suite 100 aGal Cees Conn ion Anchorage, AK 99501 ticnorape Commissioner Dan Seamount: 3 !C I /1 Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRU). Each of these wells was found to have a void in the conductor. These voids were filled with cement 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 treatments took place and meets the requirements of form 10 -404, Report of Sundry Operations. The corrosion inhibitor /sealant was pumped February 10 -12, 2011.The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please call MJ Loveland or Perry Klein at 907 - 659 -7043, if you have any questions. Sincerely, MJ Loveland ConocoPhillips Well Integrity Projects Supervisor • • ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top -off Report of Sundry Operations (10 -404) Kuparuk Field Date 211512011 1B,1D,1E,1Q,1Y / 3F,3G,3J PAD Corrosion 4 0itiattitIp ,Vol ril Bent Final top of Cement top off Corrosion inhibitor/ Well Name API # PTD # cement pumped cement date inhibitor sealant date ft bbls _ ft gal 1B -01 50029204650000 1800400 SF N/A 19" N/A 1.4 2/11/2011 1D-119 50029228360000 1972220 - 2" . ' , N /A+!_.:'°' • 23" N/A 4.2 2/10/2011 1E-117 50029232510000 2050260 12'. . N/A - 12" N/A 4.2 2/12/2011 1E -121 50029232380000 2042460 6" N/A 18" N/A 4.4 2/12/2011 1Q-21 50029225910000 1951330 _ 5" N/A 5" N/A 5.2 2/12/2011 10-22 50029225950000 1 951400 5" N/A 5" N/A 3.2 2/12/2011 1Y -06A 50029209580100 1971340 6" N/A 6" N/A 5.2 2/12/2011 1Y -08 50029209440000 1830620 6" N/A 6" N/A 3.3 2/12/2011 3F -19A 50029226800100 2040160 8" WA 8" WA 3.4 2/11/2011 3G -16 50103201350000 1901040 16" N/A 18" N/A 3 2/11 /2011 3J -17 50029227000000 1961460 SF N/A _ 19" - N/A 3.3 2/11/2011 WELL LOG S • TRANSMITTAL la= PROAcrivE DiAgNo ric SERVICES, INC. To: AOGCC Christine Mahnken 333 West 7th Avenue ti , . }i�` Suite 100 Anchorage, Alaska 99501 (907) 659 -5102 RE : Cased Hole /Open Hole /Mechanical Logs and/or Tubing Inspection(Caliper / MU) The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the following : ProActive Diagnostic Services, Inc. Attn: Robert A. Richey 130 West International Airport Road Suite C Anchorage, AK 99518 Fax: (907) 245 -8952 1) Leak Detection - WLD 05- Jan -11 3F-191' EDE 50 -029- 22680-01 2) urr-e t,ca4 - vh 1. iv . ii 3c,,� be .56 ra3 °x° - l - 61) 19 - otq 04605 �e�(l� e,e.)rou. „Jew . 0Y-1-U(0 2 76, 4 6+ HA IA Vow e� cxe) go-9-33 red u tA,d a cgaLe vt.3. 14 ¢ (o ( EC NED Signed : Da te R : `SAN 2011 Print Name: it NeSke & r PROACTIVE DIAGNOSTIC SERVICES, INC., 130 W. INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245 -8951 FAx: (907)245 -88952 E -MAIL : pdsanchoraae(Wmemorvloo.com WEBSITE : www.memorvlOa.com C:\Documents and Settings \Diane Williams \Desktop \Transmit_Conoco.docx i • WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. October 27, 2010 Attn.: Christine Shartzer 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Leak Detection Log: 3F -19A Run Date: 10/24/2010 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of. Klinton Wood, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 3F -19A Digital Data in LAS format, Digital Log Image file 1 CD Rom 50- 029 - 22680 -01 NOV 1 5 2010 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Klinton Wood 6900 Arctic Blvd. Anchorage, Alaska 99518 _ OW ( j Office: 907 - 273 -3527 Fax: 907 -2_73 3535 �Qa� klinton.wc d ' i button com t ..? Date: Signed: • • Page 1 of 1 Regg, James B (DOA) ~ ~~ ~~~ From: NSK Problem Well Supv [n1617@conocophillips.com] gl`t~'~ Sent: Tuesday, August 10, 2010 7:36 PM ~~'~~ To: Regg, James B (DOA); Maunder, Thomas E (DOA); Regg, James B (DOA) Subject: RE: 3F-19A (PTD 204-016) Report of failed TIFL Attachments: 3F-19A schematic.pdf; 3F-19A 90 day TIO plot.jpg Sorry about that, here are the attachments. Brent From: Regg, James B (DOA) [mailto:jim.regg@alaska.gov] Sent: Tuesday, August 10, 2010 2:31 PM To: NSK Problem Well Supv Subject: RE: 3F-19A (PTD 204-016) Report of failed TIFL nothing attached Jim Regg , 333 W.7th Avenue, Suite 100 Anchorage, AK 99501 907-793-1236 From: NSK Problem Well Supv [mailto:n1617@conocophillips.com] Sent: Saturday, August 07, 2010 3:18 PM To: Maunder, Thomas E (DOA); Regg, James B (DOA); Schwartz, Guy L (DOA) Cc: NSK Problem Well Supv Subject: 3F-19A (PTD 204-016) Report of failed TIFL Tom, Guy, Jim Kuparuk gas lifted producer 3F-19A (PTD 204-0~) failed a diagnostic TIFL on 8/06/10. The TIO prior to the test was 2260/1850/90. A leaking GLV is suspected. Slic c ine wi roubleshoot and repair if possible. Attached is a 90 day TIO plot and schematic. 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 8/11/2010 KRU 3F-19A PTD 2040160 8/10/2010 TIO Pressures Plot 3000. 200. 3000. 3000.. 3000. 0. 0. 0. 0. D. 0. 0. SC 3000 2700 2400 2100 1800 1500 1200 900 600 300 0 PLOT START TIME 04-MAY-10 12:20 TAG NINE WL3F-19-CHORE SCRATCH 61 SCRATCH_61 AI-P3F5002-19 SCRATCH_61 SCRATCH_61 MINOR TIMF, MAJOR TIME WEER DESCRIPTION FLOW TUBING CHORE FLOW TUBING PRESSURE FLOW TUBING TEMP GL CASING PRESSURE INNER ANNULUS PRES OUTER ANNULUS PRES PICK TINE: +02160:00:00 ggg02-AUG-10 12:2Ct ~ ~~ 0 09:St':~ ' ~T F LIIE LATEST "~`~~? DRILLSITE WELL 7?????? PREV WELL 3F 19 _ ??????? NEXT WELL 7777777 ??????? ENTRY TYPE OPERATOR ??????? ~ OPERATOR VERIFIED ??????? ~ ^Y:;TEM AUTO ENTRY ??????? ~ HOTH • • WELL NAME WLRRU3F-19 - r ~~ ~ ~"" ~~"-'~ ~ KUP 3F 19A - - _ -- ' CCNtOCi7~~li~~i~75 ~ ~ Well Attributes __ _ ___ ax Angle & MD 1TD _ ~' ~ ~./ c 115ment 2268001 KUPARU 29 (PPm UNDate Annota ioOn DEnd Date In471.94 nKB~ 41 8)00 K g 8/7/19 6)at "' ___ _ SS_SV. NIPPLE 90 11/29/2009 Last WO. ~iarm- _ __ _ _-~_ ~, - ___ Annotation Depth (RKB) Entl Date Annotation Last Mod By End Date Last Tay: SLM 8,126.0 1/272010 Rev Reason: ADD PERFS Imosbor 2/20/2010 Casing Strings _ _ __ String OD String {D Ir Set Depth Set D pth (TVD) String Wt St Ing r-..,__ n.. x.... IIn1 ~ Irnl ~ r..., rae nr I IRNHI ~ IRKB~ I G ede Sirinn Ten TFrr ~ HANGER, 27 -. SURFACE 75/8 6.750 30.0 3,974.0 3,214.0 29.70 L-80 PRODUCTION 51/2 4.950 29.0 7,612.0 5,785.3 15.50 L-80 BTC.MOD - ~ LINER 312 2.992 7,416.0 8,246.0 6,286.5 9.30 L$0 Hydri1511 Tubing Strings __ _ __ strip o0. strn ID 9 _ Set Depth (ND) St rig Wt St ~ setDe m ~ , ! y D e pt on ) (-) (i (hKB) (lbs/K) G d Str g T p Thrd Top (RKR) _ (RKB) - - __- coNDUCroR, i. TUBING - 31i2 2992 5.646.1 930 L 80 EUE81d Mod 270 743101, toe ,. ~----_ ~ ~ __ __ __ Other In Hole All Jewel Tubin Run & Retrievable, Flsh, etc.) -- ___ _.". _. __ _ ' mp Depm (ND) lop Incl NIPPLE. 484 ~~ Top (RKB) (RKB) (°I Description Comment Run Date ID (ln 27 27.0 0.50 HANGER FMC TUBING HANGER 2232004 3.SC 484 484.0 12.40 NIPPLE CAMCO'DS' NIPPLE 2/232004 2.87 r-" -~' ' 2,901 2,454.7 45.95 GAS LIFT CAMCO/KBG-2-9/1/GLV/INT/.156/1231/Comment: STA 1 2/8/2009 2.9C GAS LIFT, 2,901 ~ ,j 4,860 3,839.3 45.89 GAS LIFT CAMCO/KBG-2-9/1/OV/INT/.188//Comment: STA 2 2/82009 2.9C 6,063 4,669.6 47.78 GAS LIFT CAMCO/KBG-2-9/1/DMY/INT/// Comment: STA 3 922/2004 2.9C r i 6,894 5,251.2 43.83 GAS LIFT CAMCO/KBG-2-9/1/DMV/INT/// Comment: STA 4 9222004 2.9C 7,319 5,564.1 43.73 GAS LIFT CAMCO/KBG-2-9/1/DMY/INT/// Comment: STA 5 9222004 2.9C 7,369 5,600.2 42.91 NIPPLE CAMCO'DS' NIPPLE 2/232004 2.81 suRFACE, ~ ~ 7 412 632 1 5 42 20 LOCATOR BAKER NO GO LOCATOR 2/232004 2.95 3,974 LL I , . , . 7,413 5,632.8 42.18 SEAL ASSY BAKER SEAL ASSEMBLY 2/232004 2.91 7,430 5,645.4 41.90 WLEG BAKER WIRELINE GUIDE 2/23/2004 2.95 ~' 7.925 6,032.1 37.31 PBR UNIOUE POLISHED 80RE 2/232004 2.75 .' Perfora tions & Slots Shot Top (ND) Btm (ND) Dens GAS LIFT, a es s I.-j Top (RKB) Btm IttKB) (RKB) (RKB) Zone Date (ch.^ Type Comment , o ~_ -•'r t 7,762 7,780 5,904.1 5,918.3 C-1, 3F-19A 4/27/2004 6.0 APERF 2.5" HSD PJ, 60 deg ph r 7,828 7,838 5,955.9 5,963.7 C-1, A-6, A-5, 4272004 6.0 APER 2.5" HSD PJ, 60 deg ph GAS I F T , Fc=--_ 1 3F-19A fi O 6 3 ~ 7,gg2 8,002 6,077.4 6,090.9 A-3, 3F-19A 3/10/2004 6.0 IPERF 2.5" HC/Big Hole Chrgs, 60 deg phase, Orient 0 8,020 8,040 6,106.2 6,123.0 A-2, 3F-19A 2/9/2010 6.0 APERF _ 2.5" Millenium HMX, 60 deg phase __ cns68~ ~ ( Stimula tions & Treatme nts __ -- - - - Bonom _ Min Top Max Btm Top Depth Depth Depth Depth (ND) iND) (RKB) (RKB) (RKB) (RKB) Type Dete Comment 7 9$2.0 8 002.0 077.4 6 6 090.9 FRAC A-SAND 3/28/2004 PLACE 177,885# 16/20 CARBO-CITE, 10 PPG @ GAS LIFT, 7,318 ~ , , , , PERFS T ! Notes: General 8 Safety End Date Annotation NIPPLE, 7,369 ', 5/42003 NOTE: 2002 Workover on 3F-15 unsuccessful -lower old completion left below plug @7000' 2242004 NOTE: SIDETRACKED WELL LOCATOR, 7.412 i SEAL A6SV, ~ '. 7,413 _ ~...~~ WLEG, 7,430 PRODUCTION. 7,612 APERF, 7.762-7.780 - APER, 7 828-7,838 FR/ APERF, ~ 8.020-8,040 LINER, 8,246 TD (3F-19A), 8,254 • WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. Attn.: Christine Mahnken 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Production Profile: 3F-19A Run Date: 4/26/2010 • May 19, 2010 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Rafael Barreto, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 3F-19A Digital Data. in LAS format, Digital Log Image file, Interpretation Report 1 CD Rom 50-029-22680-01 Production Profile Log 1 Color Log 50-029-2268.0-01 ` ;_~ i ~ : ~ `i ~ r PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Rafael Barreto 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-273-3527 Fax: 907-273-3535 rafael.barreto@ { a, _.. Date: ~''j~' ,~ Signed: ~ l~ i~\ 4 '_ a J ~~q ' ~io'_ a n WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. Attn.: Christine Mahnken 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Perforating Record: 3F-19A Run Date: 2/9/2010 March 12, 2010 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Rafael Barreto, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 3F-19A Digital Data in LAS format, Digital Log Image file 50-029-22680-01 ~_ ~~~ j9L/5"~ 1 CD Rom PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Rafael Barreto 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-273-3527 Fax: 907-273-3535 rafael.barreto@liallburton.com '' Date: Signed: • STATE OF ALASKA ALASK~L AND GAS CONSERVATION COMMIS,N REPORT OF SUNDRY WELL OPERATIONS RECEfVED FEB ~ 5 ~01Q 1. Operations Performed: Abandon ~'"` Repair w ell Plug Pbrforations Stimulate ~""" Alaska 06a~s Gets. Gamm188~A~! Alter Casin Pull Tubin Perforate New Pbol Waiver 9 g ~ Time Extension~"fi ArA~ " " Cperat. Shutdow n Perforate Re-enter Suspended Well Change Approved Program 2. Operator Name: 4. Current WeII Status: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development ~ Exploratory ~ 204-016 3. Address: Stratigraphic I° Service ~~ 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-029-22680-01 7. Property Designation: 8. Well Name and Number: ADL 25632 3F-19A 9. Field/Pool(s): Kuparuk River Field /Kuparuk River Oil Pool 10. Present Well Condition Summary: Total Depth measured 8254 feet Plugs (measured) None true vertical 6281 feet Junk (measured) None Effective Depth measured 8147 feet Packer (measured) true vertical 6198 feet (true verucal) Casing Length Size MD TVD Burst Collapse CONDUCTOR 79 16 121 121 SURFACE 3956 7.625 3986 3211 PRODUCTION 7583 5.5 7612 5785 LINER 830 3.5 8246 6287 Perforation depth: Measured depth: 7762'-7780', 7828'-7838', 7982'-8002', 8020'-8040' True Vertical Depth: 5904'-5918', 5956'-5964', 6077'-6091', 6106'-6123 Tubing (size, grade; MD, and TVD) 3.5, L-80, 7431 MD, 5634 TVD Packers & SSSV (type, MD, and TVD) no packer Camco'DS' nipple, 484' MD, 484' TVD 11. Stimulation or cement squeeze summary: Intervals treated (measured): not applicable Treatment descriptions including volumes used and final pressure: 12. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 179 897 2749 -- 182 Subsequent to operation 144 1243 2782 -- 192 13. Attachments 14. Well Class after proposed work: Copies of Logs and Surveys run Exploratory Development ', Service ~` 15. Well Status after work: Oil °, Gas WDSPL Daily Report of Well Operations XXX GSTOR "" WAG ~`"; GASINJ ~" WINJ ~ SPLUG "' 16. 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 John Peirce ~ 265-6471 Printed Name John Peirce Title Wells Engineer Signature ~ _..- Phone: 265-6471 Date Z ~29~11~ ~~MS FEB 2 5 1010 ~~ Form 10-404 Revised 7/2009 ~Z •~. '~' Submit Original Only - .~ - °. °:~~ • 3F-19A Well Work Summary DATE SUMMARY 11/11/09 GAUGED TBG TO 2.78" TO 7889' SLM. ATTEMPTED DRIFT TBG WITH VARIOUS LENGTH 2.5" DRIFTS, NO SUCCESS. APPARENT SCALE BRIDGE @ 2887' SLM. IN PROGRESS. 11/12/09 FLOWED WELL TO CLEAN UP SCALE. DRIFTED TBG WITH 2.5" x 20' DUMMY GUN TO 8029' SLM. READY FOR E/L. 12/3/09 RAN IN HOLE WITH 20' 6-SPF PERF GUN TO A DEPTH OF 8025' AND COULD NOT REACH THE TARGET DEPTH OF 8040' TO PERFORATE. WITH ONLY 45 DEGREE'S OF INCLINATION /FILL WOULD BE APPERANT REASON FOR NOT REACHING TARGET DEPTH. 1/25/10 TAG @ 8057 CTMD.,CLEAN OUT FILL W/SLICK DIESEL & DIESEL GEL TO HARD TAG @ 8161' CTMD. (ADD PERF TARGET 8020' TO 8040' RKB) WELL IS READY FOR SLICKLINE D.GUN DRIFT & TAG. 1/27/10 TAGGED @ 8126' SLM. DRIFTED TBG WITH 20' x 2.5" TO 8126' SLM. READY FOR E/L. 2/9/10 COMPLETED PERFORATING A2 SAND OF 3F-19A. CCL TO TOP SHOT OFFSET = 7.5'. PERFOROATED INTERVAL OF 8020' - 8040' WITH A 20' 2.5" MILLENIUM HMX, 6 SPF DP, 60 DEG PHASING GUN. 1 KUP ~ 3F-19A Nell Attributes Max Angle & MD TD Velltwre APVU WI Fieltl Name (Well Sta[us Intl (") IMD (ft KB) Act Bfm (ft K6) 500292268001 KUPARUK N9JEF; UNIT PROD 4/.94 6039.30 $2540 merit H25 (ppml Date Annotation Entl Date KB-Grd (ft) Rig Release Date SSSV~ NIPPLE 90 11/29(2009 (Last WO: I 41.80 8/7/1996--_ ~nnotat on (Depth (ftK8) EntlD 1 AnnotationLast Mod By (End Date ast Tag' SLM 8.126.0 12 ~iYi Rev Reason' ADD PERFS Imosbor Il 2/20/2010 asing Strings _ _ _ SI frig OD Str q ID Set Depth Set Depth (ND) Siring Wt Cas n Descr ton (in) ( To flKB (ftK8 (ftK8 Ibs/ft) i G2de_ Siring Top ThN ONDUC fORp 16, 1 Oli2 p( 30.0 109.0 - _ )109.0 ( 62.50 String ~H-00 WELDED __:_ >URFACE 75/8 6]50 300 3,974.0 3,214.0 29.70L-SO I --_ 'RODUCTION 5112 4.950 29.0 7612.0 5,785.3 15.50 L-80 BTC.MOD INER 31/2 2.!.J2 7416.0 8,246.0 6.286.5 9.301 L-80 ~IHydn1511 __ tubing Strings String OD I Spring ID Set Depth Set Depth (ND) 'I String WI String ' Tubing Description (in) linj Top (flKB) (flK61 (liKe) (Ibslft) Grade Siring TOp Thrd UBING 31/2 25!92 27.0 7431.0 5,64G.1~ 9.30 L-80 IEUE Srd-Mod ether In Hole All Jewel : Tubin Run 8 Retrievable, Fish__,_etc.~_ _______-_ Top Depth (TVD) Topl I -op (ftK8) (ftK8) () D x ption Comment Run D t ID (in) 27 27.0 0 50 HAM3EF; FMC TUBING HANGER 2/23/2004 ! 350C 484 484.0 12.401 NIPPLE CAMCO'DS'NIPPLE 2/23/2004 ~ 2.875 2,901 2,454.7 45.951GAS LIF I CAMCO/KBG-2-9/1IGLVlINif.156/1231/ Comment: STA 1 2/8/2009 2.90C I l 4,860 3,839.3 45.89iGAS LIFI CAMCO/KBG-2-9/1/OV/INTl.i88//Comment STA2 _ 2!8/2009 2.90C 6063 46696 47.78 GAS LIF~I CAMCO/KBG-2-9/1/DMY/INT///Comment STA3 9/22/2004 2.90C 6,894 5,251.2 43.83 GAS LIF I CAMCO/KBG-2-9/1IDMY/INT//! Comment STA 4 9/22/2004 2.90C 7,319 5,564.1 ~ 43.73 GAS LIF I iCAMCO/KBG-2-9/1IDMY/INT/// Comment STA 5 9/22/2004 2.90C 7,369 5,600.21 42.91 NIPPLE ICAMCO'DS' NIPPLE 2/23/2004 2.812 7 412 5,632.1 ~I 4220 LOC,4 TOR BAKER NO GO LOCATOR 2123/2004 2.95C 7 413 5 632.8 42.18 SEAL ASSY BAKER SEAL ASSEMBLY 223/2004 2 97C 7,430 5,645.4 41.90 WLEG ,BAKER WIRELINE GUIDE 2/23/2004 2.95C .:.___. 7925 6032.1 37.31 PBR UNIQUE POLISIIED BORE 2/23/2004 275C Perforations 8 Slots I snot- Top (TVD) Bh>u {TV Dj Dens Fo (flKB) Btrn (ftK8) (ftK8) (HKEj Zone Date (~h... ~ Type Comment 7,762 7,780 5,904.1 5,918.3 C-1, 3F-19A 4/27/2004 6.0'APERF 25" HSD PJ, 60 deg ph 7,828 7,838 5,955.9 5,963! C-1, A-6, A-5, 4/27/2004 ~ 6.0 APER 25" HSD PJ, 60 deg ph 3F-19A 7,982 8,002 6,077 4 6:090.9 A-3, 3F-19A 3/10/2004 ~, 6.OIIPERF 25" HC/Big Hole Chrgs, 60 deg ' ~, phase, Orient 0 8,020 8,040 6,106 2 !5-123nS A-2 3F-19A 2/9/2010 ~ 6 O~APERF 2.5" Millenlum HMX, 60 deg phase Stimulations & Treatments B~mon Min Top Maz Btrn Top Depin Deptlr Depth Dapih (NDl (TVD} (ftK8) (flKB) (flKB) IftKEj Type Date Comment 7,982.0 8 002 0 6,077.4 r.~-.fi40a~o FRAC A-SAND 328/2004 PLACE 177,885ri 16/20 CARBO-CITE, 10 PPG ~ PERFS _..._ Notes: General 8 Safety__ _ _ '- End Date Annotation >/4/2003 NOTE: 2002 Wor4;~over on 3F-15 unsuccessful -lower old completion left below plug n~7000' ?/24/2004 NOTE: SIDETRACY.ED ~^/ELL SEAL ASSY,_ 7,413 WLEG. ].430 - PRODUCTION, ].612 APERF, ],)62-],]80 APER, ] 628-] 838 PBP.. ] ~i20 FRAC A-SAN J. ~r ].981 'o.~~~il APERF, 8,020-8,040 LINER, 8.246 TD (3F-19A). 8,256 • • ~. ,:~~- _~_ MICROFILMED 03/0112008 DO NOT PLACE ,~.,~.. ~n ' .may ANY NEW MATERIAL UNDER THIS PAGE F: ~LaserFiche\CvrPgs_Inserts~Microfilm_Marker. doc 07/12/07 ScblulDbel'ger RECE\"\JE,D NO. 4332 Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth dUL 2 5 Z007 AIMka Oil &. Gas Cons. Commission Company: Anchorage SCANNED JUL 2 7 2007 Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 c9if{ - 0/0 Field: Kuparuk Well Job# Color CD Log Description Date BL 1C-125 (REDO) N/A MEM INJECTION PROFILE 05/05/07 1 1 E-31 11629042 GLS 07/09/07 1 1R-20 11839632 LDL 07/06/07 1 3F-19A 11839634 PRODUCTION PROFILE 07/08/07 1 2L-309 11839633 GLS 07/07/07 1 1J-122 11629039 USIT 07/05/07 1 2N-342 11629036 FMI 07/04/07 1 /) Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. . . . . WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Cornm. Attn.: Librarian 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 November 14,2006 RE: MWD Formation Evaluation Logs: 1B-15A, 1C-21 L1 L2 L3, 1D-28 L1, 1F-01A, - - - - 3F-19A,3H-14B. The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Rob Kalish, Sperry Drilling Services, 6900 Arctic Blvd., Anchorage, AK 99518 lB-15A: d04/ -dS-(;, 'It ¡'-!¿'/:!D Digital Log Images: 50-029-23465-01 "6- / d '''''D~-034 90'$"'-/00 QOS -/01 I {)O - 0 <:;I )1 ILIL/3~/ 14435"" /4t../3fo 1'/L.-/3?- 1 CD Rom 1C-21 L1 L2 L3: - - - Digital Log Images: 50-029-23253-00, 60, 61, 62 1 CD Rom 1D-28 L1: Digital Log Images: 50-029-23237-00, 60 ;)6</ -g3"? /44(3;;;' goLf -.93'1r ¡¿./¿/33 1 CD Rom 1F-01A: dOS- -0;;;17 # 14L/87J Digital Log Images: 50-029-20889-01 1 CD Rom 3F-19A: éHY../ -Öl Co P-/Ljt.¡ 31 Digital Log Images: 50-029- 22680-01 scANt'ED f\:.B 0 12007 1 CD Rom 3H-14B: ()óf) -Odl :It 14t.!éA Digital Log Images: 50-103-20092-02 1 CD Rom I ( . ~ ConocoPhillips Alaska . P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 September 2, 2006 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West ih Avenue, Suite 100 Anchorage, AK 99501 SCANNED SEP 0 82006 o'iP a04''; Dear Mr. Maunder: Enclosed please find a spreadsheet with a list of wells trom the Kuparuk field (KRU) 3F Pad. Each of these wells was found to have a void in the conductor by surface casing annulus. The voids that were greater than 6 feet were first filled with cement to a level of 2.5 feet. The remaining volume, 2.5 to 6 feet of annular void respectively was coated with a corrosion inhibiter, RG2401, then filled with a viscous hydrocarbon based sealant, RG casing filler, 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 treatments took place and meets the requirements of form 10-404, Report of Sundry Operations. The cement top-fill operation was completed on August 14,2006 and is reported as follows. Schlumberger Well Services mixed 15.7 ppg Arctic set I in a blender tub. The cement was pumped into the conductor bottom and cemented up via a hose run to the existing top of cement. The corrosion inhibitor and sealant were pumped in a similar manner August 21-29,2006. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please call Jerry Dethlefs or myself at 907-659-704~,1{You have any questions. /~ Sincerely,#, ;/' /¿/i // 1 /~ y;~/4'/' /' /" . .0/' I /"/./]1'"7.___ /~~ f' /" /' {/f.ø"'.~ // f M.J.loveland ConocoPhillips Well Integrity Supervisor Attachment . . ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement and Sealant Top-off Kuparuk Field 8/31/2006 Well Name PTD# Cement Date 8/14/2006 8ì141ítJ;QQ.' .' 8/14/2006 ··.g/1412ÓØ'é: '.' 8t1:412QOô' ; 8/14/2006 3F-18 ,.,3~~t,9; ..' 3F-20 3F-Z1' . Sealant Date .'8/øt~Uíl~< 8/21/2006 . ..~ß/~Iï:ãl'.J.~~ 8/21/2006 $},i"ft:2f)t!$' . ·.8/21f2QÐ~ . 8/21/2006 8/21/2006 8'i43Æ~Qb:~ 8/23/2006 ..c~/2'gI2flO~( . ·.812~Z2.Ø(ß '. 8/23/2006 ·.8/~t2ø:t)í!io: . 8/23/2006 ; ;~fZ'/If.ttJêi;. 8/23/2006 . 8/21'12006 I ~ A..o~~ DATA SUBMITTAL COMPLIANCE REPORT 4/24/2006 s ~ J. t t=øl; 2..b 0 ..¡ Permit to Drill 2040160 Well Name/No. KUPARUK RIV UNIT 3F-19A Operator CONOCOPHILLlPS ALASKA INC API~. 50-029-22680-01-00 MD 8254 / TVD 6281 .,....- Completion Date 4/1/2004'-- Completion Status 1-01L Current Status 1-01L UIC N REQUIRED INFORMATION Directional su~ Mud Log No Samples No DATA INFORMATION Types Electric or Other Logs Run: GR/Res, SCMT (data taken from Logs Portion of Master Well Data Maint Well Log Information: . Electr Dataset Log Log Run Interval OH/ Number Name Scale Media No Start Stop CH Received Comments 12549 Induction/Resistivity 3930 8177 Open 4/16/2004 EWR4 GR ROP LIS Verification 4/16/2004 DSN 12549 Cement Evaluation 5 Col 7232 8116 Case 3/26/2004 Cement Bond Long - SCMT-CAlPresslTemp Pressure 5 Col 7232 8116 Case 3/26/2004 Cement Bond Long - SCMT -CAlPresslT emp Temperature 5 Col 7232 8116 Case 3/26/2004 Cement Bond Long - SCMT -CAlPresslT emp Perforation 5 Blu 7675 8086 Case 3/26/2004 Perforating Record and SBHP Pressure 5 Blu 7675 8086 Case 3/26/2004 Perforating Record and SBHP Directional Survey 3911 8254 3/25/2004 Directional Survey 3911 8254 3/25/2004 . Production 15 Blu 0 7995 Case 7/21/2004 PRODUCTION PROFILE, PSP, PRESS, TEMP, GRADIO, SPINS Perforation Blu 7296 7846 Case 5/27/2004 PERFORATING RECORD AND SBHP 13688 I nd uction/Resistivity 3974 8254 Open 2/22/2006 ROP DGR EWR plus I Graphics ___J Well Cores/Samples Information: Sample Interval Set Name Start Stop Sent Received Number Comments DATA SUBMITTAL COMPLIANCE REPORT 4/24/2006 Permit to Drill 2040160 Well Name/No. KUPARUK RIV UNIT 3F-19A Operator CONOCOPHILLlPS ALASKA INC MD 8254 TVD 6281 Completion Date 4/1/2004 Completion Status 1-01L Current Status 1-01L ADDITIONAL INFORMATION Well Cored? Y 0 Chips Received? ~ Daily History Received? GJN (!yN Formation Tops Analysis Received? ~ API No. 50-029-22680-01-00 UIC N Comments: {k Date: Compliance Reviewed By: ~g~~ò~þ . . . . WELL LOG TRANSMITTAL c204-0 I (p To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West ih Ave., Suite 100 Anchorage, Alaska 99501 February 16, 2006 r~p8~ RE: MWD Formation Evaluation Logs 3F-19A, The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Rob Kalish, Sperry Drilling Services, 6900 Arctic Blvd., Anchorage, AK 99518 907-273-3500 3F-19A: LAS Data & Digital Log Images: 50-029-22680-01 1 CD Rom ~ ~lg010w ... . Conoc;p.,illips Alaska . P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 Oct 19,2004 OCT 2 1 2004 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West ih Avenue, Suite 100 Anchorage, AK 99501 Dear Mr. Maunder: Enclosed please find a 10-404 Report of Sundry Well Operations for ConocoPhillips Alaska, Inc. well 2V -13 (PTD 204-016). The Sundry is a report of a Braidenhead weld repair job completed on 10/16/04. Please call MJ Loveland or me at 659-7224 if you have any questions. Sincerely, Ø/$£.! /;;Ø~ Marie McConnell Problem Well Supervisor Attachments O~tG\~lAL J . . O'[T '.. ,2 dH;lu} [W; ( '" D Repair Well [;2] Plug Perforations D Stimulate D OtherÇ, "ii,," 1. Operations Performed: Abandon Alter Casing D Pull Tubing D Perforate New Pool D Waiver D Time Extension t Change Approved Program D Operat. ShutdownD Perforate D Re-enter Suspended Well D 2. Operator Name: 4. Current Well Status: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development _ [;2] Exploratory D 204-016 3. Address: Stratigraphic D Service D 6. API Number: P. O. Box 100360 50-029-21293-00 7. KB Elevation (ft): 9. Well Name and Number: RKB 111' 2V-13 8. Property Designation: 10. Field/Pool(s): Kuparuk Oil Pool 11. Present Well Condition Summary: Total Depth measured 8733' feet true vertical 6204' feet Plugs (measured) Effective Depth measured feet Junk (measured) true vertical 6276' feet Casing Length Size MD TVD Burst Collapse Structural CONDUCTOR 110' 16" 110' 110' SUR. CASING 3428' 9-5/8" 3539' 2905' 3520 psi 2020 psi PROD. CASING 8576' 7" 8687' 6170' 4980 psi 4320 psi Perforation depth: Measured depth: 8236-8258; 8363-8370; 8379-8403; 8417-8470 true vertical depth: 5841-5857; 5932-5937, 5944-5961; 5971-6010 Tubing (size, grade, and measured depth) 3-1/2" , J-55, 8300' MD. Packers & SSSV (type & measured depth) pkr- BAKER 'HB' RETR. ; BAKER 'FB-1' PERM. pkr-= 8147'; 8277' sssv= SSSV sssv= 1894' 12. Stimulation or cement squeeze summary: Intervals treated (measured) NIA Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Met Water-Bbl Casing Pressure Tubino Pressure Prior to well operation 575 1088 3551 1350 220 Subsequent to operation 575 1088 3551 1350 220 14. Attachments 15. Well Class after proposed work: Copies of Logs and Surveys run _ Exploratory D Development [;2] Service D Daily Report of Well Operations_X 16. Well Status after proposed work: Oi I [;2] GasD WAGD GINJD WINJD WDSPLD 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A it C.O. Exempt: Contact Marie McConnell/MJ Loveland @ 659-7224 Printed Name Marie McConnell Title Problem Wells Supervisor Signature ~//.V#..¿£A~~A ~ Phone 907-659-7224 Date 10/18/2004 Preoared hv Sharon AI/sun-Drake 263-4612 Form 10-404 Revised 04/2004 \1/\ L WI itOri~ STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS ORiG1f~ ~ ~ \ . 2V-13 . DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary 10/16/2004ISeal welded braidenhead to repair leaking casing head threads. 10/17/2004IMITOA to 3000 psi passed. See attached form for details . . ConocoPhillips Alaska, Inc. KRU 2V-13 2V¡13 ...··...·iii in ii ....... ..·..i i..··....··....·..... ............................................ ..··.nn < API: 500292129300 Well TVDe: PROD AnQle @ TS: 44 deQ @ 8236 SSSV SSSV TVDe: TRDP Oria ComDletion: 5/9/1985 AnQle @ TD: 43 deQ @ 8733 (1894-1895, Annular Fluid: Last W/O: 10/21/1991 Rev Reason: GauQes Dulled OD:4.000) Reference Loa: Ref Loa Date: Last UDdate: 9/19/2004 Last Taa: 8600 TD: 8733 ftKB Last Taa Date: 5/14/2002 ~Š~~o.l.e Anale: 63 dE ~ä$Îñã$tÎ'Îijã+ÄCC$'1'!~JNGS ni" . ii' ...nn;n nn .. DescriDtion Size TOD Bottom TVD Wt Grade Thread CONDUCTOR 16.000 0 110 110 62.50 H-40 SUR. CASING 9.625 0 3539 2905 36.00 J-55 PROD. CASING 7.000 0 8687 6170 26.00 J-55 +IUISINIa' i nn ...;i...... i '..niIi iiIini'" ................ Size Top Bottom TVD Wt Grade Thread 4.000 0 4991 3868 11.00 J-55 DSS-HTC 3.500 4991 8127 5763 9.30 J-55 EUE 8RD AB-MOD 3.500 8127 8292 5881 9.30 L-80 EUE 8RD AB-MOD 3.500 8292 8300 5887 9.30 J-55 EUE 8RD AB-MOD .·.I··....·.i.·.·.. 'ii ... ... ·····...n i nn .ni?II;;....·..·.····· Interval TVD Zone Status Ft SPF Date TVDe Comment 8236 - 8258 5841 - 5857 C-4 22 12 6/17/1985 IPERF 2 1/8" TT 8363 - 8370 5932 - 5937 A-5 7 16 10/20/1991 RPERF 4 1/2" CSG GUN 8379 - 8403 5944 - 5961 A-4 24 16 10/20/1991 RPERF 4 1/2" CSG GUN 8417 - 8470 5971-6010 A-3 53 16 10/20/1991 RPERF 4 1/2" CSG GUN .""", nI ni ?in n St MD TVD Man Mfr Man Type V Mfr V Type VOD Latch Port TRO Date Run Vlv Cmnt 1 2933 2515 Cameo KBUG GLV 1.0 BK 0.250 1392 12/16/1992 2 4104 3278 Cameo KBUG GLV 1.0 BK 0.250 1398 12/16/1992 3 4620 3625 Cameo KBUG DMY 1.0 BK2 0.000 0 10/21/1991 4 5153 3972 Cameo ~ GLV 1.5 RK 0.313 1296 12/16/1992 5 5674 4316 Cameo ~ DMY 1.5 RK 0.000 0 10/21/1991 6 6192 4656 Cameo ~ GLV 1.5 RK 0.313 1297 12/14/1992 7 6777 5009 Cameo ~ DMY 1.5 RK 0.000 0 10/21/1991 8 7475 5341 Cameo ~ GLV 1.5 RK 0.313 1296 12/14/1992 9 8029 5694 Cameo ~ DMY 1.5 RK 0.000 0 10/21/1991 10 8082 5731 Cameo ~ OV 1.5 RK 0.313 0 10/2/1999 ........i..n? i ".iI?I"·Ii'I·i In i ·i;? St MD TVD Man Mfr Man Type VMfr V Type VOD Latch Port TRO Date Run Vlv Cmnt 11 8189 5807 Cameo MMG-W DMY 1.5 RKP 0.000 0 5/25/1999 IRKED\ PBR ,n ,êtê~I,,···'C\"'clniÞv i n. ·.·.·.·.·.ini (8134-8135, OD:3.500) DeDth TVD TVDe DescriDtion ID 1894 1791 SSSV Otis 'FMX'. FLAPPER BROKEN OFF 3.313 PKR 8134 5768 PBR Baker 3.000 (8147-8148, 8147 5777 PKR Baker 'HB' retr. 2.850 OD:6.151) 8268 5864 PUMP RC JET PUMP on 2.812 CSA Lock, set 6/15/2002 0.000 8268 5864 SLEEVE-O Cameo 'C-A-1' Sliding Sleeve - Sleeve opened 10/9/1999 2.812 SLEEVE TAKES A SPECIAL LOCK - USE CSA LOCK CS LOCK WILL NOT SET!) .. - - 8277 5870 PKR Baker 'FB-1' Derm. 4.000 Perf - - 8292 5881 NIP Cameo 'D' NiDDle NO GO 2.750 (8236-8258) - - 8299 5886 SOS Baker 2.992 - - 8300 5887 TTL 2.992 PUMP (8268-8269. OD:2.992) PKR (8277-8278, OD:6.151) TUBING (8127-8292, OD:3.500, 10:2.992) TUBING (8292-8300, OD:3.500, ID:2.992) Perf - - (8363-8370) - - = = Perf == == (8379-8403) == = Perf == == (8379-8403) Perf == = = (8417-8470) == == . , , MEC.ICAL INTEGRITY TEST lM.ORM WELL NO.: 2V-13 1 DATE: 110-17-04 WELL TYPE: I Prod AIL I i,e,: Prod, Prod AIL, MI, SWI, PWI MIT TEST TYPE: IMITOA I i.e., Tbg, IA / 9-5/8", OA /13-3/8", T x IA combo, etc. REQUIRED TEST PRESSURE: 11800 PSi. Note: Please consult the PWS if there's any question @ 7224, pager 909. FLUID TYPE(S) USED TO PRESSURE TEST: IDiesel R d II W IIh d P b f d d . T ecor a e ea ressures e ore an urine est. START TIME: 113:00 PRE MIT INITIAL MIT 15 MINUTE 30 MINUTE PASS T I PRESSURES PRESSURES PRESSURES PRESSURES OR E (PSI) (PSI) (PSI)' (PSI)" FAIL S TUBING 10 10 10 T IA / 9-5/8" 0 0 0 FAIL OA/13-3/8" 0 1800 1600 1 COMMENTS: 1 st test START TIME: 113:30 PRE MIT INITIAL MIT 15 MINUTE 30 MINUTE PASS T I PRESSURES PRESSURES PRESSURES PRESSURES OR E (PSI) (PSI) (PSI)' (PSI)" FAIL S TUBING 10 10 10 10 T IA / 9-5/8" 0 0 0 0 PASS OA/13-3/8" 1600 1800 1720 1680 2 COMMENTS: 2nd test PRE MIT INITIAL MIT 15 MINUTE 30 MINUTE PASS T START TIME: I PRESSURES PRESSURES PRESSURES PRESSURES OR E (PSI) (PSI) (PSI) (PSI) FAIL S TUBING T IA /9-5/8" OA/13-3/8" 3 COMMENTS: rSC COMMENTS: . Start the MIT over if press loss is = 5% @ 15 minutes. .* Repeat the MIT if press loss is = 10% @ 30 minutes. Note: Test must exhibit pressure stabilization - press loss second 15 min < 50% press loss first 15 min FINAL STEPS MUST BE COMPLETED AND CHECKED OFF!!! D -- FLAG THE CASING VALVE WITH LOAD AND TEST INFORMATION D -- FLAG THE WING VALVE IF SI AT TIME OF LOADING AND TESTING. D -- NOTIFY DSO OF TEST RESULTS, VOLUMES PUMPED AND STATUS OF WELL. Witness: I ArettJ /.5o..U J/all¡:7A IA . If cc: PWS 6/3/00 e ConocJP'hillips Alaska e P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 September 27, 2004 RECE\VED SEP 3 0 2004 c mmission . Oi\ & Gas Cons. .0 Masks ~nr..\1Orage Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 ;¿!~~, Dear Mr. Maunder: Enclosed please find 10-404 report notice for ConocoPhillips Alaska, Inc. we1l3F-19A. A cement OA squeeze was performed on this well 9/19/04 as a preemptive measure to prevent problems should the well develop a surface casing leak. Please call MJ Loveland or me at 659-7224 if you have any questions. Sincerely, 1>r-1-7D Brad Gathman Problem Well Supervisor Attachments OR\GU~A'L 1. Operations Performed: Abandon 0 Alter Casing 0 Change Approved Program 0 2. Operator Name: ConocoPhillips Alaska, Inc. 3. Address: P. O. Box 100360 7. KB Elevation (ft): RKB 85' 8. Property Designation: e -- STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS RECEIVED RepairWell 0 Pull Tubing 0 Operat. ShutdownD Stimulate 0 OtheÖEP ØJ ZUU4 r-- Waiver 0 Almixmr~ta~ons. Commission Re-enter Suspended Well. I 5. Permit to Drill Number: 204-016 6. API Number: 50-029-22680-01 Plug Perforations 0 Perforate New Pool 0 Perforate 0 4. Current Well Status: Development _ [2] Stratigraphic 0 Exploratory o o Service 9. Well Name and Number: 3F-19A 10. Field/Pool(s): Kuparuk Oil Pool 11. Present Well Condition Summary: Total Depth Effective Depth Casing Structural CONDUCTOR SURFACE PRODUCTION LINER Perforation depth: measured 8254' feet true vertical 6281' feet measured feet true vertical 6276' feet Length Size MD 109' 16" 109 3944' 7-5/8" 3974' 7583' 5-1/2" 7612' 830' 3-1/2" 8246' Plugs (measured) Junk (measured) TVD Burst Collapse Measured depth: true vertical depth: Tubing (size, grade, and measured depth) 3-1/2" , L-80, 7431' MD. Packers & SSSV (type & measured depth) no packer SSSV= NIP SSSV= 484' 12. Stimulation or cement squeeze summary: Intervals treated (measured) N/A Treatment descriptions including volumes used and final pressure: 13. R60MS ",,¡'\ ¡. St.\' /:ì¡ fJ ! '!', , Representative Daily Average Production or Injection Data Oil-Bbl Gas-Met Water-Bbl Casino Pressure Tubinn Pressure Prior to well operation Subsequent to operation 14. Attachments Copies of Logs and Surveys run _ 15. Well Class after proposed work: Exploratory 0 Development [2] Service 0 16. Well Status after proposed work: Oil [2] GasD WAG 0 GINJD WINJ 0 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: Daily Report of Well Operations_X Contact Printed Name Signature WDSPLD Brad Gathman/MJ Loveland @ 659-7224 Brad Gathman Title ¥4P Phone Problem Wells Supervisor . /. '/. 907 -659-7224 Date '7/ Z. ? /0 Y Pr..nared bv .c:hRrnn AII,"In-Drf'ke 21'13-4612 " o R\ G \ NA l~ Submit Original Only Form 10-404 Revised 04/2004 e 3F-19A DESCRIPTION OF WORK COMPLETED SUMMARY e Date Event Summary 9/19/2004 Pumped 30 bbls of tail cement down OA to cement shoe. Estimated top of cement at 3273' MD. e onocoPhillips Alaska, Inc.. lUBING (27-7431, OD:3.500, ID:2.992) 'RODUCTION (29-7612, OD:5.500, Wt:15.50) SURFACE (30-3974. OD:7.625. Wt:29.70) Gas Lift MandrelNalve 2 (4860-4861. Gas Lift MandrelNalve 3 (6063-6064, Gas Lift MandrelNalve 4 (6894-6895, Gas Lift MandrelNalve 5 (7319-7320, NIP (7369-7370, OD:4.520) SEAL (7413-7430, OD:4.130) WLEG (7430-7431, OD:4.130) Perf (7762-7780) LINER (7416-8246, OD:3.500, Wt:9.30) Perf (7828-7838) Perf (7982-8002) FRAC A-SAND (7982-8002) - - - - - - - - - - - I-- f-- f-- I-- f-- f-- I-- f-- f-- I-- I-- f-- IŒji@ii!i 'jij ~ ~ .. ~ API: 500292268001 SSSV Type: NIPPLE Annular Fluid: Reference Loa: Last Taa: 8095 Last Taa Date: 6/12/2004 Casino Strina - ALL STRINGS Description PRODUCTION SURFACE CONDUCTOR LINER Tublna'Strlno . TUBING Size I Top 3.500 I 27 Perforations Summarv Interval TVD 7762 - 7780 5893 - 5907 7828 - 7838 5944 - 5952 7982 - 8002 6066 - 6082 Size 5.500 7.625 16.000 3.500 I I e Well TVDe: PROD Orig 2/24/2004 ComDletion: Last w/o: 5/8/2002 Ref Loa Date: TD: 8254 ftKB Max Hole Anale: 48 ¿¡en¡¡:¡) 6039 ·,·,_,v~',,,, "'~ '" Top 29 30 30 7416 Bottom 7612 3974 109 8246 KRU Date 4/27/2004 4/27/2004 3/10/2004 3F-19A Analeraf TS: deo (â) Angle @ TD: 39 deg @ 8254 Rev Reason: TAG FILL Last UDdate: 6/21/2004 TVD 5774 3202 109 6275 Grade L-80 L-80 H-40 L-80 Thread BTC.MOD BTC-MOD WELDED Hvdril 511 Wt 15.50 29.70 62.50 9.30 .;; TVD I Wt I Grade T 5635 I 9.30 I L-80 I '. TVDe Comment APERF 2.5" HSD PJ 60 deo ph APER 2.5" HSD PJ 60 dea ph IPERF 2.5" HC/Big Hole Chrgs, 60 dea nhase Orient 0 I Comment I PLACE 177 885# 16/20 CARBO-LITE 10 PPG (â) PERFS . . . V Type V OD Latch Port TRO Date Vlv Run Cmnt 4/1/2004 4/1/2004 3/31/2004 3/3112004 3/31/2004 , I ID 3.500 2.875 2.812 2.950 2.970 2.950 2.750 Bottom I 7431 I Zone Ft SPF 18 6 10 6 20 6 Thread EUE 8rd-Mod Stimûlätions&'Tœâfl!ììiilts Interval Date I TVDe 7982 - 8002 3/28/2004 I FRAC A-SAND GaS¡'¡l!iftM8ndrêJRlåliles St MD TVD Man Man Type V Mfr Mfr 1 2901 2442 CAMeO 2 4860 3828 CAMeo 3 6063 4658 CAMeo 4 6894 5240 CAMeo 5 7319 5552 CAMCO Ottiernilìlíûâš··.iêåÚfã¡Lietc. Depth TVD TVDe 27 27 HANGER 484 483 NIP 7369 5589 NIP 7412 5621 LOCATOR 7413 5621 SEAL 7430 5634 WLEG 7925 6021 PBR GenêiiälNôtes Date Note 5/4/2003 WELL WAS PREVIOUSLY WORKED OVER IN 2002; LOWER OLD COMPLETION LEFT IN WELL BELOW PLUG (â) 7000' 2/23/2004 SIDETRACKED WELL 2/23/2004 TREE: FMC GEN IV SLIM HOLE (7-1/16" 5M x WKM 3-1/8" 5M) TREE CAP CONNECTION: OTIS S.75 4" ACME KBG-2-9 KBG-2-9 KBG-2-9 KBG-2-9 KBG-2-9 Status GLV GLV GLV GLV OV DescriDtion FMC TUBING HANGER CAMeO 'DS' NIPPLE CAMCO 'DS' NIPPLE BAKER NO GO LOCATOR BAKER SEAL ASSEMBLY BAKER WIRE LINE GUIDE 111.I11"'1111= POLISHED BORE 1.0 1.0 1.0 1.0 1.0 INT INT INT INT INT 0.156 0.188 0.188 0.188 0.188 cO' 1286 1323 1318 1309 o e - To: ]LL WG TRANSMITfAL State of Alaska April 12, 2004 Alaska Oil and Gas Conservati, n Comm. Attn.: Howard Okland 3 33 West 7th Avenue, Suite 100 Anchorage, Alaska RE: MWDFormationEvaluationLogs 3F-19A, AK-MW-2890968 1 LDWG formatted Disc with verification listing. API#: 50-029-22680-01 ,~ \~~ Î'<lIv(-ð\\J PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COpy OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Service Attn: Rob Kalish 6900 Arctic Blvd. Anchorage, Alaska 99518 _.-:>Date: J) J~~ ~O, ht ~, , Signed: 'U ötrw e ConocóP'hillips e Randy Thomas Kuparuk Drilling Team Leader Drilling & Wells P. O. Box 100360 Anchorage, AK 99510-0360 Phone: 907-265-6830 May 6, 2004 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West ih Avenue Suite 100 Anchorage, Alaska 99501 i Subject: Well Completion Reports for 3F-19 (APD # 196-102) and 3F-19A (204-016) Dear Commissioner: ConocoPhillips Alaska, Inc. submits the attached Well Completion Reports for the recent P&A operations on the Kuparuk well 3F-19 and the sidetrack operations on 3F-19A. If you have any questions regarding this matter, please contact me at 265-6830. Sincerely, ~~~ R. Thomas Kuparuk Drilling Team Leader CPAI Drilling and Wells RT/skad RECEI\/t" ~().'ll 0 2004 Alaska Oil & G\)¡i.,....ummission Anchorage ORIGINAL tit STATE OF ALASKA e ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1a. Well Status: Oil 0 Gas U Plugged D Abandoned D Suspended D WAGD 1b. Well Class: 20AAC 25.105 20AAC25.110 Development 0 Exploratory D GINJ 0 WINJ 0 WDSPL 0 No. of Completions Other Service 0 Stratigraphic Test 0 2. Operator Name: 5. Date Comp., SUjl' . / ¡ U~ 12. permit~1I Number: Ç;¡"ð. ConocoPhillips Alaska, Inc. ,0'1) f} Þ 204-016/304-014 or Aband.: ~ 2004 3. Address: 6. Date Spudded: 13. API Number: P. O. Box 100360, Anchorage, AK 99510-0360 February 7,2004 . 50-029-22680-01 4a. Location of Well (Govemmental Section): 7. Date TD Reached: ¿ 14. Well Name and Number: Surface: 37' FSL, 124' FEL, Sec. 19, T12N, R9E, UM February 20, 2004 3F-19A At Top Productive 8. KB Elevation (It): 15. Field/Pool(s): Horizon: 554' FNL, 712' FEL, Sec. 19, T12N, R9E, UM 30' RKB I 54' AMSL Kuparuk River Field Total Depth: 9. Plug Back Depth (MD + TVD): Kuparuk River Oil Pool 269' FNL, 817' FEL, Sec. 19, T12N, R9E, UM 8147' MD 16198' TVD 4b. Location of Well (State Base Plane Coordinates): 10. Total Depth (MD + TVD): 16. Property Designation: Surface: x-508376 l 5985860 " Zone- 4 8254' MD I 6281' TVD ,l ADL 25632 y- TPI: x- 507766 y- 5990548 Zone- 4 11. Depth where SSSV set: 17. Land Use Permit: Total Depth: x- 507660 V- 5990834 ". Zone-4 Landing Nipple @ 484' ALK 2565 18. Directional Survey: Yes 0 NoU 19. Water Depth, if Offshore: 20. Thickness of N/A feet MSL Permafrost: 1380' MD 21. Logs Run: ·7't''-';t'':~,..~u 3¿179 f //7 i::> ",j GR/Res, SCMT :ß2t:>(..I·7YD Sol 22. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 16" 62.5# H-40 Surface 121 ' 24" 260 sx AS I 7.625" 29.7# L-80 Surface 3986' 9.875" 1060 sx AS III, 330 sx Class G 5.5" 15.5# L-80 Surface 7612' 6.75" 168 sx Class G 3.5" 9.3# L-80 7416' 8246' 4.75" 82 sx Class G w/GasBlok 23. Perforations open to Production (MD + TVD of Top and Bottom 24. TUBING RECORD Interval, Size and Number; if none, state "none"): SIZE DEPTH SET (MD) PACKER SET (MD) 3.5" 7431' 7433' 25. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED 7982'-8002' MD 6066'-6082' TVD 6 spf 7982'-8002' 176885# 16/20 carbolite, 10 ppg @ perfs 7762'-7780' MD 5893'-5907' TVD 6spf 7828'-7838' MD 5944'-5952' TVD 6 spf 26. PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lilt, etc.) April 5, 2004 Flowing Date of Test Hours Tested Production for OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO 4/17/2004 12.5 hours Test Period --> 278 634 . . 365 176 bean 2518 Flow Tubing Casing Pressure Calculated OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY - API (corr) press. 208 psi 1310 24-Hour Rate -> 485 1221 680 240 27. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water (attach separate sheet, if necessary). RECEIVED Submit core chips; if none, state "none". CÜ!ij)L[l;·J:~ R80MSBFl MAY 13 200\ MAY 1 0 2004 !L/¡'~I NONE Alaska Oil & Gas Cons. Commisswr¡ V¡::.(~·u OR'~I~lAL Anchorage .út( Form 10-407 Revised 2/2003 CONTINUED ON REVERSE SIDE Submit in duplicate &(~ G 28. 29. GEOLOGIC MARKERS FORMATION TESTS NAME MD TVD Include and briefly summarize test results. List intervals tested, and attach detailed supporting data as necessary. If no tests were conducted, state "None". 3F-19A C4 Sands 7756' 5888' C1 Sands 7827' 5944' A3 Sands 7978' 6063' A2 Sands 8018' 6095' NIA 30. LIST OF ATTACHMENTS Summary of Daily Operations, Directional Survey, Schematic 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Kelly M1~l605~ ~ . ¡ . "1'f C \;V p~ntedNa~~ Title: KUDaruk Team Leader . q-~5-c1 :Ç/t1t.'( ---=- Phone -¿bS- 6"830 Date Signature Prepared by Sharon Allsup-Drake INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1a: Classification of Service wells: Gas injection, water injection, Water-Alternating-Gas Injection, salt water disposal, water supply for injection, observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 4b: TPI (Top of Producing Interval). Item 8: the Kelly Bushing elevation in feet abour mean low low water. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). Item 20: True vertical thickness. Item 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, Other (explain). Item 27: If no cores taken, indicate "none". Item 29: List all test information. If none, state "None". Form 1 0-407 Revised 2/2003 OR\G\N~L Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 3F-19 3F-19 ROT - SIDETRACK n1433@ppco.com Nordic 3 Start: 2/1/2004 Rig Release: 2/24/2004 Rig Number: Spud Date: 4/2/2002 End: 2/24/2004 Group: 2/1/2004 00:00 - 00:15 0.25 MOVE SFTY MOVE Held PJSM on moving rig over well and hazards with moving rig between 2 wells, cold weather and slick pad. NOTE: Moved rig from 10 pad to F pad 1-31-04 and cont to prep rig for acceptance while wells group removed 2 Thermo Syphons by well 00:15 - 01:30 1.25 MOVE OTHR MOVE Layed out liner around well and set in rigs cellar mats 01 :30 - 02:30 1.00 MOVE MOVE MOVE Moved rig 250' down F pad and spotted over well 3F-19A 02:30 - 09:00 6.50 MOVE RURD RIGUP Leveled rig, built berm and spotted cuttings box, took on seawater in pits, welder cont to build new door for mud pits 09:00 - 11 :30 2.50 WELCT OTHR RIGUP Held PJSM with crew and valve group, pulled VR plug, RU lubricator and pulled BPV, SITP 540 psi, SICP 540 psi, OA 500 psi 11 :30 - 14:00 2.50 MOVE RURD RIGUP RU circ lines in cellar and pressure tested lines to 3,500 psi, welder completed installing new door between mud pits and pump room 14:00 - 16:00 2.00 MOVE OTHR RIGUP Pressure tested mudline to 500/3,500 psi, had leak at 1,500 psi and replaced seal on 4" valve, retested and ck ok, pressure tested standpipe to 500/5,000 psi and ck ok 16:00 - 16:15 0.25 MOVE SFTY RIGUP Held PJSM, discussed with rig crew on the hazards of circ out diesel to tank, trapped pressures and spills. Use good communication 16:15 - 17:30 1.25 MOVE RURD RIGUP Blew air thru lines prior to circ out diesel and found 2 lines with ice plugs, thawed lines and rechecked lines 17:30 - 18:00 0.50 DRILL CIRC DECOMP RU & Circ out freeze protect diesel with seawater thru 3 1/2" kill string at 2,407', circ 1 1/2 x cap 18:00 - 19:00 1.00 DRILL OTHR DECOMP Allowed well to U-tube diesel from below kill string, Held Pre Spud/PJSM with rig crew on upcoming operations 19:00 - 20:00 1.00 DRILL CIRC DECOMP Circ an addition hole cap from 2,407' with seawater to help circ out diesel, blew down lines 20:00 - 20:30 0.50 WELCT DECOMP Installed BPV 20:30 - 22:00 1.50 WELCT DECOMP Held PJSM, ND tree and set outside cellar, NORM Tree & ck ok 22:00 - 22:30 0.50 WELCT DECOMP Installed FMC blanking plug 22:30 - 00:00 1.50 WELCT DECOMP Began NU 11" 5M BOP stack, installed 7 1/16" 5M x 11" 3M Spool and set on stack and cont NU BOPE 2/2/2004 00:00 - 05:00 NOTE: ACCEPTED RIG at 12:00 Hrs 2-1-04 5.00 WELCT NUND DECOMP Fin NU 11" 5M BOP stack on 7 1/16" 5M x 11" 3M Spool, found 1 stud too short on 11" flange on btm of stack and changed out 12:30 - 13:00 Note @ 06:00 was informed that a floorhand had hurt his foot while working on rig at 10 pad on 1-29-04, sent hand to KUP clinic and was treated as a first aid, hand then went to town on days off and was to see an doctor in town 7.50 WELCT BOPE DECOMP RU and tested all valves, manifold, rams and annular to 250 psi low and 3,000 psi high per AOGCC permit. At start of BOP test OA press 175 psi, IA 175 psi, bled OA to -0- and cont to monitor and bleed off, IA press increased to 250 psi while testing, bled off press and gained 8 gals with -0- press Note: John Crisp with AOGCC witnessed test 0.50 WELCT SFTY DECOMP Held safety meeting with rig crew and Tom Sanchez, CPAI safety rep and discussed importance of reporting accidents no matter how small as soon as they occur 1.00 WELCT OTHR DECOMP RD BOP testing equipment and blew down all lines and manifold 2.50 RIGMNT RGRP DECOMP Repaired leak on btm flange of riser 0.50 DRILL PULD DECOMP Pulled BPV, backed out LDS and PU 40K up wt and PU and unlande hanger, no problems 05:00 - 12:30 13:00 - 14:00 14:00 - 16:30 16:30 - 17:00 Printed: 4/15/2004 2:15:05 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 3F-19 3F-19 ROT - SIDETRACK n1433@ppco.com Nordic 3 Start: 2/1/2004 Rig Release: 2/24/2004 Rig Number: Spud Date: 4/2/2002 End: 2/24/2004 Group: 2/2/2004 17:00 - 18:00 1.00 DRILL CIRC DECOMP Circ out approx 10-20 bbls of diesel that had swapped while testing BOP's, circ hole clean with seawater, blew down lines and PU & LD Hanger, found riser had a slight leak at btm flange 18:00 - 21 :00 3.00 RIGMNT RGRP DECOMP Repaired riser flange, attempted to tighten with no success, removed flange and resealed and checked ok 21 :00 - 00:00 3.00 DRILL PULD DECOMP TIH with used 3 1/2" Kill string while PU new 3 1/2" 9.3# L-80 Tbg, TIH to 4,371', had calc displacement on TIH, OA bled down to -0- psi 2/3/2004 00:00 - 01 :30 1.50 DRILL CIRC DECOMP Washed down from 4,371' to 4,402', circ btms up at 3112 bpm, 400 psi, at btms up had gray water only, no cement or mud 01 :30 - 02:00 0.50 DRILL CIRC DECOMP Washed down from 4,402 and tagged hard cement at 4,435', set 15K down on plug 02:00 - 03:00 1.00 DRILL CIRC DECOMP Circ hole clean at 4,435' with seawater, circ 1.5 x hole cap at 4 bpm, 600 psi, st wt 52K, dn wt 45K 03:00 - 03:30 0.50 DRILL OBSV DECOMP Monitored well-static, OA -0-, keeping bled down thru bleed down tank with very little returns out OA 03:30 - 04:30 1.00 DRILL CIRC DECOMP Circ btms up with very little gray water at btms up, circ at 4 bpm 550 psi 04:30 - 08:00 3.50 DRILL TRIP DECOMP POOH with 31/2" tbg, strapped last 25 stds out, LD "DS" nipple 08:00 - 09:30 1.50 DRILL TRIP DECOMP MU Baker 51/2" retrievable bridge plug and RIH, set BP at 982', st wt up 29K, 27K dn 09:30 - 09:45 0.25 DRILL DEQT DECOMP Pressure tested BP to 1,000 psi for 15 min & ck ok 09:45 - 10:30 0.75 DRILL TRIP DECOMP POOH & LD Baker setting tool 10:30 - 12:00 1.50 WELCT BOPE DECOMP MU test plug on 5 1/2" test jt, RIH & set, pressure tested lower pipe rams to 250 psi low, 3,000 psi high, POOH & LD test jt and blew down lines 12:00 - 20:00 8.00 WELCT NUND DECOMP ND BOP's & 71/16" 5M x 11" 3M Spool, ND tbg head and removed same with no problems, removed 51/2" csg pack-off, tack welded slips to csg and dressed off 5 1/2" csg, installed new FMC pack-off 20:00 - 22:00 DECOMP NU 11" 3M x11" 5M spool, NU BOP's, choke and kill lines, unable to MU kill line, couldn't find 3" Grayloc seal ring for kill line 22:00 - 00:00 2.00 DECOMP Waiting on 3" Grayloc seal ring for kill line to be delivered to rig 2/4/2004 00:00 - 04:00 4.00 DECOMP Waited on new 3" Grayloc seal ring for kill line to arrive from Nordic rig 2 @ Endicott 04:00 - 05:30 1.50 WELCT DECOMP Fin NU kill line and riser, filled hole and seawater was coming out OA due to seals on pack-off not energized 05:30 - 07:00 1.50 WELCT DECOMP RU to circ, pumped down csg and around pack-off and energized pack-off 07:00 - 07:30 0.50 WELCT DECOMP Tested 11" 3M flange, choke and kill lines to 250 psi and 3,000 psi 07:30 - 09:00 1.50 DRILL DECOMP MU Baker retrieving tool and RIH to 982' and latched onto bridge plug and released, monitored well 15 min while allowing elements to relax and hole was static 09:00 - 10:00 1.00 DRILL TRIP DECOMP POOH and LD bridge plug and retrieving tool 10:00 - 10:15 0.25 LOG SFTY DECOMP Held PJSM with rig crew and Schlumberger wireline (SWS) on RU and running string shot and chemical cutter 10:15 - 12:15 2.00 LOG ELOG DECOMP RU SWS, MU 4.77" gauge ring/junk basket and RIH, tagged btm at 4,449' WL, POOH 12:15 - 14:15 2.00 LOG ELOG DECOMP MU 14' string shot and RIH, set off string shotfrom 4,163' to 4,177' to clean off ID of csg and POOH 14:15 - 17:00 2.75 LOG ELOG DECOMP MU 4 9/16" Pipe Recovery chemical cutter and RIH, cut 5 1/2" csg at 4,175', corr log back to perf log ran 1/28/04, saw both sets of perfs shot previously, POOH & RD OA -0- psi 17:00 - 18:00 1.00 FISH FISH DECOMP MU Baker 51/2" Csg spear with pack-off, RIH to 28' and speared 5 1/2" csg pack-off, POOH & LD pack-off 18:00 - 20:00 2.00 FISH FISH DECOMP RIH and speared 5 1/2" csg at 29', PU and began working 5 1/2" csg, Printed: 4/15/2004 2: 15:05 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 3F-19 3F-19 ROT· SIDETRACK n1433@ppco.com Nordic 3 Start: 2/1/2004 Rig Release: 2/24/2004 Rig Number: Spud Date: 4/2/2002 End: 2/24/2004 Group: 2/4/2004 18:00 - 20:00 2.00 FISH FISH DECOMP pulled slips up out of csg head, worked csg up to 300K up wt with no movement, +1- 67" of stretch, calc csg wt 65K, pressured up on csg staging press up to 1,000 psi with no drop in pressure, no change when working pipe with or without press, released spear, POOH and LD 20:00 - 22:15 2.25 FISH ELlN DECOMP RU SWS and RIH with 13' string shot and set off same at 4,074' to 4,087', POOH 22:15 - 00:00 1.75 FISH ELlN DECOMP MU 4 9/16' chemical cutter and RIH, cut 51/2" csg at 4,085', started POOH 2/5/2004 00:00 - 00:45 0.75 FISH ELlN DECOMP Fin POOH with e-line after chemical cutting 5 1/2" csg at 4,085' WL, RD SWS 00:45 - 02:00 1.25 FISH FISH DECOMP MU 5 1/2' csg spear, RIH to 29' and engaged csg, worked csg up to 300K up wt while working pump pressure up to 1,000 psi, worked csg free, pulled spear to rig floor with 90K up wt and found 1/2 of outer csg slips missing 02:00 - 02:30 0.50 FISH PULD DECOMP Released spear from 5 1/2" csg and LD 02:30 - 03:00 0.50 FISH RURD DECOMP RU GBR's tongs & elevators 03:00 - 04:00 1.00 FISH PULD DECOMP PU to 1st connection and recovered slip segement, LD cut piece with slips tack welded onto csg and MU safety valve on 5 1/2" csg, broke out spear, then MU pump in sub 04:00 - 07:30 3.50 FISH CIRC DECOMP Est circ at 1 bpm at 40 psi, (freeze protect diesel u-tbg), staged pump rate up to 4 bpm at 200 psi, circ 2x btms up with seawater, no heavy mud back at btms up, displaced hole from seawater to new 9.8 ppg LSND mud, circ hole at 4 bpm at 320 psi, reciprocated pipe with 78K up wt and 57K dn wt, circ till hole clean with 9.8 ppg mud in & out 07:30 - 16:00 8.50 FISH PULL DECOMP POOH LD 93 jts of 51/2" 15.5# L-80 EUE LTC csg, 1-cut piece and 17 stright blade centralizers, total pipe recovered 4,043.40', NORM csg and ck ok, didn't have thread protectors for LTC pipe, plugged both ends with absorbant then covered with plastic bags, backloaded csg onto truck and sent to Tuboscope, RD GBR's tools 16:00 - 18:00 2.00 CEMEN TRIP DECOMP MU 3 1/2" mule shoe and RIH with 31/2" tbg to PBTD 4,435' 18:00 - 20:30 2.50 CEMEN CIRC DECOMP Circ hole clean and conditioned mud to 9.8 ppg in & out, staged pump rate up to 5 bpm at 500 psi, mixed weighted hi vis pill 20:30-21:15 0.75 CEMEN CIRC DECOMP Pumped and spotted balanced 12 bbls of 12.1 ppg weighted hi vis pill 21:15 - 21:45 0.50 CEMEN TRIP DECOMP POOH from 4,435' to 4,298', LD 2 singles of 31/2' tbg 21 :45 - 22:45 1.00 CEMEN CIRC DECOMP Circ btms up monitoring for wt'd pill and didn't see any pill at btms up circ hole at 4 bpm at 350 psi, held PJSM with Dowell & rig crew on pumping cmt plug and batch mixed cmt 22:45 - 23: 15 0.50 CEMEN PUMP DECOMP Turned over to Dowell, pumped 5 bbls FW, tested lines to 3,500 psi, pumped add. 5 bbls FW, followed with 30 bbls, 168 sxs of 17.0 ppg, 1.0 yield class 'G' cmt with additives and 2.5 bbls FW behind, turned over to rig and displaced cement to balance plug with 24.5 bbls of 9.8 ppg mud, ave 4 bpm at 600 psi, slowed rate last 3 bbls, CIP at 23:15 hrs, calc TOC in gauge hole 3,538' 23:15 - 00:00 0.75 CEMEN TRIP DECOMP POOH slow from 4,298' to 3,615', plug balanced 2/6/2004 00:00 - 01 :30 1.50 CEMEN CIRC DECOMP Circ hole clean at 3,615' after setting balanced cement kick-off plug, staged pump rate up to 6 bpm at 450 psi, at btms up had 20 bbls of cement contaminated mud back, max wt 10.3 ppg, MW going in 9.8 ppg, blew down lines 01 :30 - 02:00 0.50 RIGMNT RGRP DECOMP Repaired middle boot on riser 02:00 - 06:30 4.50 DRILL PULD DECOMP POOH & stood back 9 stds of new 3 1/2' 9.3# L-80 EUE-M tbg (22 stds total in derrick) POOH LD 75 jts, 2,372' of used 3 1/2" 9.3# L-80 EUE-M tbg used for kill string, NORM tbg & ck ok 06:30 - 08:00 1.50 WELCT EORP DECOMP Installed test plug, changed out lower pipe rams from 5 1/2' csg to 4" Printed: 4/15/2004 2:15:05 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 3F-19 3F-19 ROT - SIDETRACK n1433@ppco.com Nordic 3 Start: 2/1/2004 Rig Release: 2/24/2004 Rig Number: Spud Date: 4/2/2002 End: 2/24/2004 Group: DP RU & tested lower 4" rams to 250 psi and 3,000 psi, RD RU & PU 146 jts of 4" HT 38 DP & stood back in derrick RU rig floor & top drive for 4" HT 38 DP, loaded 78 add. jts of 4" DP and 28 jts of spiral wt in pipe shed and strapped, Installed wear bushing 18:45 - 19:00 0.25 DRILL SFTY DECOMP Held PJSM with rig crew and Sperry-Sun on PU & MU BHA 19:00 - 00:00 5.00 DRILL PULD DECOMP PU & MU 6 3/4" BHA #1, orient and upload MWD and surface tested, blow down, RIH PU spiral wt DP to 500' 217/2004 00:00 - 01 :00 1.00 DRILL PULD DECOMP Fin MU BHA #1, PU 20 jts 3 1/2" spiral Wt DP RIH to 1,090' 01:00 - 04:15 3.25 DRILL TRIP DECOMP Cont RIH with BHA #1 PU 4" HT 38 DP, RIH to 3,551', est circ and washed down and tagged TOC at 3,612', (est TOC @ 3,615') 04:15 - 05:30 1.25 DRILL CIRC DECOMP Circ hole evening MW in & out at 9.8 ppg, circ at 325 gpm at 1,900 psi, rot wt 70K, up wt 80K, dn wt 65K 05:30 - 07:00 1.50 DRILL DEQT DECOMP RU and tested 7 5/8" csg to 3,000 psi for 30 min, good test, RD 07:00 - 11 :00 4.00 DRILL DRLG DECOMP Drilled hard cement inside csg from 3,612' to 3,979', 5' below csg shoe, drilled at 5K wob, 60 rpm's, 325 gpm at 2,000 psi 11 :00 - 14:15 3.25 DRILL DRLG DECOMP Time drilled to sidetrack well from 3,979' to 4,010', sidetracked well at 4,010' and drilled 25' of new formation to 4,035'MD/3,246'TVD for LOT, 2-4K wob, circ at 325 gpm, 2,300 psi 14:15 - 15:00 0.75 DRILL CIRC DECOMP Circ hole clean evening MW in & out at 9.7 ppg for LOT 15:00 - 16:30 1.50 DRILL LOT DECOMP RU and performed LOT to 13.3 ppg EMW with 600 psi at 3,202' TVD and 9.7 ppg MW, RD 16:30 - 00:00 7.50 DRILL DRLG INTRM1 Drilled 6 3/4" hole per directional plan from 4,035' to 4,685' MD/3,707' TVD (650') ART 3.6 hrs, AST .25 hrs, 2-5K wob, 60 rpm's, 133 spm, 325 gpm, off btm pressure 2,000 psi, on btm 2,200 psi, off btm torque 3K ft-Ibs, on btm 5K ft-Ibs rot wt 80K, up wt 85K, dn wt 75K, displaced out mud used to drill cmt with new 9.8 ppg LSND, pumped 1 weighted hi vis sweep at 2# over MW and had 20% increase in cuttings 2/8/2004 00:00 - 12:00 12.00 DRILL DRLG INTRM1 Drilled 63/4" hole per directional plan from 4,685' to 5,791' MD/4,470' TVD (1,106') ART 7.39 hrs, AST .83 hrs, 5-10K wob, 60-80 rpm's, 133 spm, 325 gpm, off btm pressure 2,550 psi, on btm 2,750 psi, off btm torque 9K ft-Ibs, on btm 10,500 ft-Ibs, rot wt 83K, up wt 115K, dn wt 70K, 9.8 ppg MW in & out, pumping weighted sweeps every 300-400' with 10-20% increase in cuttings 12:00 - 00:00 12.00 DRILL DRLG INTRM1 Drilled from 5,791' to 6,672' MDI 5,080' TVD (881 '), ART 6.21, AST .41 hrs, 5-8k wob, 80 rpm's, 130 spm, 320 gpm, off btm pressure, 2,800 psi, on btm 3,100 psi, off btm torque 12,200 ft-Ibs, on btm 13,300 ft-Ibs, rot wt 85K, up wt 125K, dn wt 75K, cont pumping wt'd sweeps with 10-20% increase in cuttings 2/9/2004 00:00 - 16:30 16.50 DRILL DRLG INTRM1 Drilled 63/4" hole per directional plan from 6,672' to 7,615' MD/5,776' TVD, (943') 51/2" csg pt, ART 7.08 hrs, AST 2.41 hrs, 5-10k wob, 80 rpms, 300 gpm, off btm pressure 2,900 psi, on btm 3,100 psi, off btm torque 8,200 ft-Ibs, on btm 10,100 ft-Ibs, raised MW to 10.5 ppg while drlg per mud program, added 1.3% lubricants to mud, rot wt 100K, up wt 11 OK, dn wt 92K, pumped sweeps every 3-400' with little to no increase in cuttings, changed out liners and swabs on #1 while drlg at a reduced circ rate 16:30 - 18:30 2.00 DRILL CIRC INTRM1 Pumped weighted hi vis sweep and circ hole clean, had no increase in cuttings at btms up, circ at 300 gpm, 2,900 psi and 80 rpm's Note: Held Pre-Tour safety mtg with new crew on rig while circ 18:30 - 22:30 4.00 DRILL WIPR INTRM1 Wiped hole to shoe with no problems, precautionary back reamed out 10 stds at drlg rate from 7,615' to 6,675', POOH 3 stds hole not taking calc fill, pumped out 3 stds then cont POOH on elevators wet, hole Printed: 4/1512004 2:15:05 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 3F-19 3F-19 ROT - SIDETRACK n1433@ppco.com Nordic 3 Start: 2/1/2004 Rig Release: 2/24/2004 Rig Number: Spud Date: 4/2/2002 End: 2/24/2004 Group: 2/9/2004 18:30 - 22:30 4.00 DRILL WIPR INTRM1 taking calc fill and no excess drag POOH to shoe. 22:30 - 23:30 1.00 RIGMNT RSRV INTRM1 Serviced top drive and rig, monitored well-static 23:30 - 00:00 0.50 DRILL WIPR INTRM1 RIH from 3,930' to 4,405' NOTE: Recieved 36 hr extension on BOP test from Jeff Jones with AOGCC 2/10/2004 00:00 - 03:00 3.00 DRILL WIPR INTRM1 Cont RIH after wiper trip to shoe from 4,405' to 7,525', washed 90' to btm, no problems RIH 03:00 - 06:45 3.75 DRILL CIRC INTRM1 Circ hole at a reduced rate of 1 1/2 bpm at 450 psi while thawing out cuttings shoot and changing out shaker screens 06:45 - 08:30 1.75 DRILL CIRC INTRM1 Pumped 25 bbl weighted hi vis sweep and circ hole clean, at btms up had no increase in cuttings from sweep, circ hole at 300 gpm, 2,700 psi, circ a total of 3X btms up, rot wt 109K, up wt 125K, dn wt 94K 08:30 - 08:45 0.25 DRILL OBSV INTRM1 Monitored well-static 08:45 - 13:00 4.25 DRILL TRIP INTRM1 POOH on elevators from 7,615' to 3,960', (75/8' csg shoe), no problems in open hole 13:00 - 13:30 0.50 DRILL OBSV INTRM1 Monitored well at shoe-well static, pumped dry job 13:30 - 15:30 2.00 DRILL TRIP INTRM1 POOH from 3,960' to BHA at 1,090' 15:30 - 20:30 5.00 DRILL PULD INTRM1 POOH standing back Spiral Wt DP, LD flex De's, downloaded MWD and fin. LD BHA #1, Note: found a rock on top of pulser and seat of pulser was washed 20:30 - 21 :00 0.50 DRILL PULD INTRM1 Pulled wear bushing and installed test plug 21 :00 - 23:00 2.00 WELCT EaRP INTRM1 Changed out btm set of 4' pipe rams over to 5 1/2' csg rams and tested door seals to 1,500 psi, pulled test plug 23:00 - 00:00 1.00 CASE RURD INTRM1 Began RU rig floor to run 5 1/2' csg 2/11/2004 00:00 - 02:00 2.00 CASE RURD INTRM1 Fin RU GBR 5 1/2" csg handling equpment, changed out elevator bales and MU Franks fill-up tool 02:00 - 02:15 0.25 CASE SFTY INTRM1 Held PJSM with rig crew & GBR on running csg 02:15 - 10:00 7.75 CASE RUNC INTRM1 Ran 51/2" 15.5# L-80 BTC-M Csg to 3,926', MU, 5 1/2" Weatherford sure seal Float shoe, 2 jts csg, sure seal float collar, thread locked conn below float collar and pumped thru same & ck ok, cont RIH wth 90 jts (92 total) of 5 1/2" csg to 3,926' with full returns NOTE at 08:00 hrs Phase 3 was called field wide, held safety meeting with crew and decision was made to cont RIH at a slower speed 10:00 - 13:30 3.50 CASE CIRC INTRM1 Circ and cond mud at shoe, staged pump rate up to 5 bpm at 720 psi, up wt 75K, dn wt 58K, 10.7 mw in & out 13:30 - 15:30 2.00 CASE RUNC INTRM1 RIH with 5 1/2" csg from 3,926' to 4,995' 15:30 - 16:30 1.00 CASE CIRC INTRM1 Circ hole at 4,995', staged pump up to 4.5 bpm at 480 psi, up wt 85K, dn wt 67K 16:30 - 17:30 1.00 CASE RUNC INTRM1 RIH with 5 1/2" csg from 4,995' to 5,300' 17:30 - 19:30 2.00 CASE CIRC INTRM1 Circ hole while rig crew made crew change at CPF-3 during phase 3, staged pump rate up to 4 bpm at 450 psi, up wt 85K, dn wt 65K 19:30 - 20:00 0.50 CASE SFTY INTRM1 Held safety mtg with crew coming on tour on running csg, circ hole during safety mtg 20:00 - 00:00 4.00 CASE RUNC INTRM1 Cont RIH slow with 5 1/2" csg from 5,300' to 7,250', no problems RIH (170 of 178 jts in hole) Phase 3 in Effect 2/12/2004 00:00 - 01 :00 1.00 CASE RUNC INTRM1 Cont RIH during phase 3 with 5 1/2" csg from 7,250' to 7,586', MU landing jt and washed down to 7,612', Ran a total of 178 jts of 51/2" 15.5# L-80 BTC-M csg 7,585.61' including float equipment, no problems RIH 01 :00 - 02:00 1.00 CASE CIRC INTRM1 Circ btms up thru fill up tool, circ at 1.5 bpm at 775 psi, reciprocated pipe 115K up wt, 02:00 - 02:30 0.50 CASE RURD INTRM1 RD Franks fill-up tool and MU Dowell cement head Printed: 4/15/2004 2:15:05 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 3F-19 3F-19 ROT - SIDETRACK n1433@ppco.com Nordic 3 Start: 2/1/2004 Rig Release: 2/24/2004 Rig Number: Spud Date: 4/2/2002 End: 2/24/2004 Group: 2/12/2004 02:30 - 15:45 13.25 CEMEN CIRC INTRM1 Est circ at 2 bpm at 450 psi and RIH, tagged btm at at 7,615', PU to 7,612' and cont to work pipe and circ hole staging pumps up to 4 bpm at 700 psi, circ a total of 3x btms up and mud conditioned for cementing, 10.7 ppg MW in & out with 16 YP, slowed rate to 2 bpm at 425 psi waiting on Phase 3 to lift, Phase 3 lifted at 11 :00 hrs, called out Dowell and vac trucks, cont to circ at 2 bpm till 13:00 hrs, then increased rate to 4 bpm at 650 psi, circ 7x btms up at 4 bpm with full retums 15:45 - 16:00 0.25 CEMEN SFTY INTRM1 Held PJSM with rig crew and Dowell on cementing csg 16:00 - 17:00 1.00 CEMEN CIRC INTRM1 Loaded plugs in cement head and cont to circ hole at 4 bpm, 650 psi while batch mixing cement, csg st wt up 115K, dn wt 70K 17:00 - 17:30 0.50 CEMEN PUMP INTRM1 Turned over to Dowell, pumped 5 bbls CW100 at 8.3 ppg, pressure tested lines to 3,500 psi, pumped add. 5 bbls CW100 (10 total), followed with 20 bbls of 12.0 ppg MUDPUSH, shut down, dropped btm plug then pumped 28.5 bbls, 138 sxs of class "G" cmt at 15.8 ppg, 1.16 yield with additives, shut down and dropped top plug, dowell pumped 5 bbls water 17:30 - 18:00 0.50 CEMEN DISP INTRM1 Rig displaced cement with 10.7 ppg mud, ave 4 bpm, initial press, 540 psi, final pressure 850 psi, slowed rate last 20 bbls to 3 bpm and bumped plug on calc displacement, pressured up to 1,350 psi on plugs, bled off and floats held, reciprocated pipe throughout job, up wt 115K, dn wt 70K, CIP at 18:00 hrs, Landed csg with float shoe at 7,612' and float collar at 7,523', Calc TOe 6,600'. 18:00 - 22:00 4.00 CASE NUND INTRM1 RU & ND BOPE, unhooked flowline, scoped down riser and PU on stack, LD mousehole 22:00 - 00:00 2.00 CASE NUND INTRM1 Set 5 1/2" x 11" C-21 csg slips with 92K st wt, made rough cut and LD landing jt, set stack back down 2/13/2004 00:00 - 01 :30 1.50 CASE RURD INTRM1 Rd csg handling equipment, LD cement head and changed out elevator bales 01 :30 - 03:30 2.00 CASE NUND INTRM1 ND riser, set back stack and ND DSA 03:30 - 05:30 2.00 DRILL RIRD INTRM1 RU rig floor to LDS 4" DP, prepared pipe shed for 2 7/8" DP 05:30 - 12:00 6.50 CASE OTHR INTRM1 MU Baker 51/2" csg spear, Speared csg and PU to 140K and released c-21 slips, found bolt had sheared on outer body of slips, prepared new set of slips and set with 92K st wt, FMC rep informed Co. man that wrong slips were used, PU to 160K and removed slips, waited 2 hrs to recieve new slips, then re-installed proper slips with 92K st wt. released spear and LD 12:00 - 16:00 4.00 CASE NUND INTRM1 Made final cut on 51/2" csg, installed pack-off, NU rebuilt 71/16" 5M x 11" 3M tbg head, pressure tested pack-off to 3,000 psi for 10 min & ck ok 16:00 - 00:00 8.00 WELCT NUND INTRM1 RU slings, Re-installed riser landing, PU & NU BOP stack, choke, kill lines, riser & flowline, changed out lower pipe rams from 4' to 2 7/8" and checked bolts tbg head after setting on stack NOTE: Approx. 04:30 an APC super sucker while departing location left a trail of mud dots off location, est to be 1 gal. or less, notified security and APC 2/14/2004 00:00 - 01 :30 1.50 CASE NUND INTRM1 Fin NU riser and centering stack 01 :30 - 01 :45 0.25 DRILL SFTY INTRM1 Held PJSM on LD 4" DP from Derrick 01 :45 - 09:00 7.25 DRILL PULD INTRM1 LD 29 jts spiral wt DP, Jars and 84 jts of 4" DP from derrick, (138 jts of 4" Dp left in derrick to LD) 09:00 - 09:15 0.25 WELCT SFTY INTRM1 Held PJSM on Testing BOP's 09:15 - 12:00 2.75 WELCT BOPE INTRM1 RU and began testing BOP's, tested annular to 250 psi and 3,500 psi, tested upper 2 7/8" x 5' VBR's and wouldn't test, test btm 2 7/8' rams to Printed: 4/15/2004 2:15:05 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 3F-19 3F-19 ROT - SIDETRACK n 1433@ ppco.com Nordic 3 Start: 2/1/2004 Rig Release: 2/24/2004 Rig Number: Spud Date: 4/2/2002 End: 2/24/2004 Group: 12:00 - 15:00 INTRM1 15:00 - 16:00 INTRM1 16:00 - 18:00 INTRM1 18:00 - 21 :00 INTRM1 21 :00 - 00:00 INTRM1 2/15/2004 5.00 WELCT BOPE INTRM1 00:00 - 05:00 05:00 - 15:00 15:00 - 16:00 16:00 - 00:00 10.00 DRILL 1.00 DRILL 8.00 DRILL PULD INTRM1 RIRD INTRM1 PULD INTRM1 2/16/2004 00:00 - 01 :00 1.00 DRILL RIRD INTRM1 01 :00 - 03:00 2.00 RIGMNT RSRV INTRM1 03:00 - 15:00 12.00 DRILL PULD INTRM1 15:00 - 17:00 2.00 DRILL CIRC INTRM1 17:00 - 18:00 1.00 DRILL TRIP INTRM1 1S:00 - 1S:30 0.50 DRILL SFTY INTRM1 1S:30 - 22:30 4.00 DRILL TRIP INTRM1 22:30 - 00:00 1.50 DRILL PULD INTRM1 2/17/2004 00:00 - 03:00 3.00 DRILL PULD INTRM1 03:00 - 04:00 1.00 DRILL CIRC INTRM1 04:00 - 05:30 1.50 DRILL TRIP INTRM1 05:30 - OS:OO 2.50 DRILL PULD INTRM1 08:00 - 09:00 1.00 DRILL DEQT INTRM1 09:00 - 11 :00 2.00 DRILL PULD INTRM1 11 :00 - 12:00 1.00 RIGMNT RSRV INTRM1 12:00 - 12:30 0.50 DRILL PULD INTRM1 12:30 - 17:00 4.50 DRILL TRIP INTRM1 250/5,000 and tested ok, attempted to re-test upper VBR's and still no test, pulled test plug and drained stack Removed top set of VBR's and installed new 27/8" x 5" inserts and seals and re-installed rams Attempted to re-test upper VBR's and still would not test Removed top set of VBR's again and checked inserts and seals and looked ok, re-installed Tested blind rams, choke manifold and floor valves to 250 psi and 5,000 psi, had 2 manifold valves fail #1 & #6, all other valves tested ok Attempted to re-test upper VBR's with 2 7/S" test test jt and wouldn't test, changed out test jt to 31/2" and VBR's tested ok to 250 psi and 5,000 psi, LD 31/2" test jt and PU 2 7/S" and attempted to re-test and still no test, decision made to change out VBR's to 2 7/8" solid body rams Chuck Scheve with AOGCC on location to witness test Changed out upper rams from 2 7/S" x 5" VBR's to 2 7/8" DP rams, greased #1 & 6 valves on choke manifold, tested IBOP, manual and Hyd to 250 psi low and 5,000 psi high, tested 2 7/8" pipe rams, HCR and man kill valve and valves #1 & 6 on choke manifold to 250/5,000 & ck ok, RD Test tools LD remaining 138 jts of 4" DP from derrick and loaded out RU in cellar for LOT on 5 1/2" x 7 5/S" Annulus for LOT Loaded and strapped pipe shed with 249 jts of 27/8" AOH, 10.4# S-135 DP. LD 4" Handling Tools and changed over top drive to 2 7/8" DP SIM-OP: Performed LOT on OA to 13.9 ppg EMW with 10.7 ppg MW, 535 psi at 3,202' TVD, Flushed with 290 bbls fresh water and freeze protected with 36 bbls diesel, shut in with 600 psi Bring 2 7/8" handling tools to rig floor & RU Slip & cut 48' of drlg line, serviced top drive and drawworks PU 198 jts of 2 7/8"" DP and RIH open ended to 6,230', rabbit DP with 1.96" drift Circ out thick mud and circ hole clean and to clear DP of any scale, circ at 5 bpm at 2,700 psi, then at 6 bpm at 3,600 psi, blew down top drive POOH 19 stds of 2 7/S" DP to 4,440' Note: Held Pre-Spud Mtg in camp on Placer #1 with new crew coming on tour Held pre-tour/operations mtg with new crew coming on tour POOH with 44 stds of 2 7/8" DP and stood back, 66 stds DP in derrick PU 20 jts of 2 7/8" spiral wt DP & RIH to 600' PU 51 joints of 2 7/8" DP, drift to 1.96, RIH. Circ to clean out dp. Circ 140 bbls. Hold spill drill. POOH, stand back 17 stands 2 7/S" dp and 6 stands of 2 7/S" spiral weight drill pipe. PUIMU BHA f/4 3/4" hole. Bit, mtr, stab, x-o, MWD. Uplaod and shallow test MWD @ 2.2 bpm & 3 bpm. Blow down top drive. Continue to MU BHA. RIH w/2 7/8" spiral weight drill pipe. PU x-o and jars. Drift 2 joints of spiral wt to 1.96 and PU f/ pipe shed. Change out dies in grabber f/ top drive. Service rig. UD joint # 20 spiral weight drill pipe, UD joint # 199 of 2718" drill pipe. Replace joint # 199. Trip in hole w/ BHA #2 and 2 7/8" dp f/ derrick. 56 stands 2 7/8" in hole. Printed: 4/15/2004 2: 15:05 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 3F-19 3F-19 ROT - SIDETRACK n1433@ppco.com Nordic 3 Start: 2/1/2004 Rig Release: 2/24/2004 Rig Number: Spud Date: 4/2/2002 End: 2/24/2004 Group: 2/17/2004 12:30 - 17:00 4.50 DRILL TRIP INTRM1 PU wt 85k. SO wt 50k 17:00 - 18:00 1.00 DRILL SFTY INTRM1 PJSM on stripping drill and well kill drill to crew. Install floor safety valve, shut valve, installlBOP, shut annular, MU stand of drill pipe. 18:00 - 20:00 2.00 DRILL SFTY INTRM1 PJSM on stripping drill and well kill drill to crew. Adjust pressure on annular, open annular, remove IBOP, remove floor safety valve. 20:00 - 21 :30 1.50 DRILL TRIP INTRM1 RIH 10 stands 2 7/8" dp to stand 66 in hole. PU wt 95k. SO wt 55k 21 :30 - 23:30 2.00 DRILL CIRC INTRM1 Circulate and condition mud prior to performing stripping drill. PU wt 95k. SO wt 55k. Circ @ 2bpm wI 1460 psi. 23:30 - 00:00 0.50 DRILL OTHR INTRM1 Break off top drive. Blow down top drive. 2/18/2004 00:00 - 02:30 2.50 RIGMNT RGRP INTRM1 Repair grabber box on top drive, Change out saver sub. 02:30 - 07:00 4.50 WELCT SFTY INTRM1 Perform stripping & well kill drill with crews, Blow down top drive, POOH & retrieve dart and TIW valves. 07:00 - 08:00 1.00 DRILL TRIP INTRM1 RIH & tag cement @ 7,491', Stand back 1 stand, Pick up 1 single. 08:00 - 09:00 1.00 DRILL CIRC INTRM1 Circ & condo 10.7 ppg mud. 09:00 - 10:15 1.25 DRILL RIRD INTRM1 Lay down single, Blow down top drive, Rig to test 5-1/2" casing. 10:15 - 12:00 1.75 DRILL DEOT INTRM1 Test 5-1/2' casing to 3500 psi for 30 min. -OK. 12:00 - 13:00 1.00 DRILL RIRD INTRM1 Rig down testing equip., Blow down kill & choke lines. 13:00 - 15:00 2.00 RIGMNT OTHR INTRM1 Set make up and drilling torque values on top drive (Make up 5700 ftIIb - Drill 8800 ftllb). 15:00 - 17:00 2.00 CEMEN DSHO INTRM1 Drill out cement, Float collar, Shoe and cement to 7,615'. 17:00 -18:00 1.00 DRILL DRLG INTRM1 Drill 20' of new hole to 7,635' ART= 0.75 hrs., WOB 3/4K, 35 RPM, 135 GPM @ 3480 psi. 18:00 - 22:00 4.00 DRILL CIRC INTRM1 Circ & cond mud for FIT, Change over to 11.8 ppg LSND mud. 22:00 - 23:00 1.00 DRILL FIT INTRM1 Rig & perform 16.0 ppg FIT wI 1267 psi, 11.8 ppg mud, 5773' TVD, Held PJSM w/ crew on drilling new hole section. 23:00 - 00:00 1.00 DRILL DRLG PROD Drill f/7,635' to 7,660' ART = 1.0 hrs, WOB 3I4K, 40 RPM, 135 GPM @ 3750 psi, Raise mud weight to 12.1 ppg while drilling. 2/19/2004 00:00 - 12:00 12.00 DRILL DRLG PROD Drill fl7,660' to 7,819' ART= 10.75 hrs, WOB 4/14K, 60 RPM, 129 GPM @ 4250 psi, UP 80K, DN 63K, ROT 70K, TO on btm 4000 ftllb I off 3500 ftllb, Raise mud weight from 12.1 ppg to 12.5 ppg, No mud lost. 12:00 - 00:00 12.00 DRILL DRLG PROD Drill fl7,819' to 8,143' ART = 9.5 hrs, WOB 4/15K, 65 RPM, 129 GPM @ 4250 psi, UP 85K, DN 75K, ROT 72K, TO on btm 3150 ftllb I off 2450 ftllb, No mud lost. 2/20/2004 00:00 - 08:15 8.25 DRILL DRLG PROD Drill f/8,143' to 8,254' ART= 6.0 hrs, WOB 4/15K, 65 RPM, 129 GPM @ 4250 psi, UP 85K, DN 65K, ROT 74K, TO on btm 3150 ftllb I off 2450 ftllb, No mud lost. 08:15 - 10:30 2.25 DRILL CIRC PROD Pump Hi-vis sweep, Circ hole clean & condition mud wI rate of 129 GPM @ 3525 psi. 10:30 - 12:15 1.75 DRILL WIPR PROD Back ream out to shoe wI 98 GPM @ 2800 psi& 35 RPM (Hole in good shape). 12:15 - 14:00 1.75 RIGMNT RSRV PROD Blow down top drive, Held BOP Drill, Monitor well- Static, Service top drive. 14:00 - 15:00 1.00 DRILL WIPR PROD RIH to 8,254'- No problems. 15:00 - 17:30 2.50 DRILL CIRC PROD Pump Hi-vis sweep, Circ hole clean & condition mud wI rate of 129 GPM @ 3525 psi, Monitor well. 17:30 - 19:30 2.00 DRILL TRIP PROD Drop rabbit, Pump out to shoe @ 7,612'- Hole in good shape. 19:30 - 20:00 0.50 DRILL CIRC PROD Monitor well, Pump dry job, Blow down top drive. 20:00 - 00:00 4.00 DRILL TRIP PROD POOH to HWDP. 2/21/2004 00:00 - 01 :00 1.00 DRILL TRIP PROD POOH & set back HWDP. 01 :00 - 01 :30 0.50 DRILL PULD PROD Lay down NMDC's & Jars. 01 :30 - 02:00 0.50 DRILL PULD PROD Down load MWD/LWD. 02:00 - 04:00 2.00 DRILL PULD PROD Lay down Sperry-Sun tools & BHA. Printed: 4/15/2004 2:15:05 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 3F-19 3F-19 ROT - SIDETRACK n1433@ppco.com Nordic 3 Start: 2/1/2004 Rig Release: 2/24/2004 Rig Number: Spud Date: 4/2/2002 End: 2/24/2004 Group: 2/21/2004 04:00 - 05:00 1.00 CASE RURD PROD Rig to run 3-1/2" liner. 05:00 - 11 :30 6.50 CASE PULR PROD PJSM, Pick up 25 jts 3-1/2',9.3#, L-BO, Hydril511 liner, Pick up liner hanger. 11 :30 - 12:00 0.50 CASE CIRC PROD Pick up 1 stand drill pipe, Cire liner volume at rate of 3 bprn @ 100 psi, UP 70K, DN 24K, Blocks 20K. 12:00 - 14:15 2.25 CASE RUNL PROD RIH wI liner to 1,783', Liner floating due to centralizers. 14:15 - 14:45 0.50 CASE CIRC PROD Circ 45 bbls at rate of 3 bpm @ 180 psi. 14:45 - 16:30 1.75 CASE RUNL PROD RIH wlliner to 2,730', Fill pipe with hose @ 2,257'. 16:30 - 17:30 1.00 RIGMNT RGRP PROD Trouble shoot pumps due to unable to eire, Repair pop off valve on pump #1. 17:30 - 19:00 1.50 CASE CIRC PROD Circ at rate of 3 bpm @ 650 psi. 19:00 - 00:00 5.00 CASE RUNL PROD RIH wI liner to 7,538 at 60 ftImin, Fill pipe with hose every 10 stands, Break circ 500 stroke every 20 stands. 2/22/2004 00:00 - 01 :00 1.00 CASE CIRC PROD Circ btm's up and condition mud @ 7,538' at rate of 2 bpm @ 1079 psi. 01 :00 - 01 :30 0.50 CASE RURD PROD Pick up Baker cement head, Make up pup joint on top and single on btm. 01 :30 - 02:00 0.50 CASE RUNL PROD RIH wI liner & tag btm @ 8,254', UP 105K, DN 55K. 02:00 - 03:00 1.00 CEMEN PULD PROD Pick up Baker cement head, Make up cement lines. 03:00 - 04:30 1.50 CEMEN CIRC PROD Break circ, Stage rate up from 1 bpm to 2.5 bpm @ 1770 psi and Liner hanger prematurely set 8' off btm, Continue to circ and condition mud at 3 bpm @ 2400 psi, No mud lost, Btm's up showed no gas cut mud, Held PJSM, Batch mix cement. Note; Shoe @ 8,246', Float collar @ 8,180', Landing collar @ 8,147', Top of liner @ 7,415'. 04:30 - 05:15 0.75 CEMEN PUMP PROD Turn over to Dowell, Dowell pumped 5 bbls 8.3 ppg CW1 00 at rate of 2.5 bpm @ 1840 psi, Shut down and test lines to 4500 psi, Continue pumping 5 more bbls CW100, 15 bbls 13.0 ppg MudPUSH at rate of 3.0 bpm @ 2280 psi Followed by 17.0 bbls (82 sxs) 15.8 ppg GasBLOK cement wI .200%D46, 0.45%B155, .400%D65, 2.00%D600G, Pumped at rate of 3.0 bpm @ 2120 psi, Shut down, Wash lines to rig floor, Drop Baker wiper dart, Dowell kicked out dart w/1 0 bbls fresh water, Switch to rig pumps and finish displacing cmt w/ total of 31.8 bbls 12.5 ppg mud at rate of 3 bpm @ 2000 to 2590 psi, Slowed rate down to 2 bpm @ 1650 psi for last 6 bbls, Bumped plug w 3900 psi, Had full circ thru out job, No mud lost, Unable to reciprocate liner due prematurely setting prior to cementing, CI P @ 05: 10 hrs 2/22/2004. 05:15 - 05:45 0.50 CASE OTHR PROD Slack off to 25K to release setting tool, Bleed off drill pipe pressure and check floats-OK, Pressure drill pipe to 500 psi, Pick up out of seals, Start pumping at 3 bpm @ 2600 psi & pick up 8', Slow rate down to 1 bpm and Slack off while rotating to 25K to set ZXP Packer, Had good indication of packer setting. 05:45 - 06:45 1.00 CEMEN CIRC PROD Rig & reverse out est. 6 bbls cement, MudPUSH & CW100 at rate of 3 bpm @ 3500 psi, Reversed out 2 pipe volumes. 06:45 - 07:15 0.50 DRILL DEQT PROD Rig & test casing to 3500 psi for 15 min.-OK. 07:15 - 09:30 2.25 DRILL CIRC PROD Flush all surface equip. wI fresh water, Change well over to fresh water at rate of 4.7 bpm @ 2100 psi, Monitor well- OK. 09:30 - 11 :30 2.00 DRILL PULD PROD Clean out mud from riser and drip pan, Break and lay down Baker cement head, Rig to circ. 11 :30 - 13:00 1.50 DRILL CIRC PROD Continue to circ fresh water to clean well at rate of 4.7 bpm @ 2100 psi. 13:00 - 15:00 2.00 DRILL CIRC PROD Change well over to seawater at rate of 4.7 bpm @ 2100 psi, Monitor well- OK, Blow down all equip., Rig down circ equip. 15:00 - 00:00 9.00 DRILL PULD PROD POOH & Lay down 2-7/8' drill pipe. 2/23/2004 00:00 - 01 :00 1.00 DRILL PULD PROD Continue to UD 2 7/8" DP. Printed: 4/15/2004 2: 15:05 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 3F-19 3F-19 ROT - SIDETRACK n1433@ppco.com Nordic 3 Start: 2/1/2004 Rig Release: 2/24/2004 Rig Number: Spud Date: 4/212002 End: 2/24/2004 Group: UD Baker running tool. RIH w/6 stands of 2 7/8" spiral wt and 4 stands of 27/8" dp fl derrick! UD 4 stands of 2 7/8" dp and 6 stands of spiral wt dp. Change out top pipe rams to 31/2". Pull wear bushing. Install test plug. Test 3 1/2" rams to 250 psi low and 5000 psi high. 1.00 CMPL TN OTHR CMPL TN Load out MWD tools, mise equip and test joint fl pipe shed. RU to run 3 1/2" tubing. 4.00 CMPL TN RUNT CMPL TN PJSM on running 3 1/2" completion. When checking rabbit size used to drift tubing, it was stamped 2.876", but measured 2.81? Decided to try and rabbit pipe in derrick using a steel 2.876 rabbit; would not drift (cold/snow in pipe). Steam boxes as RIH with 31/2" tbg. Drop 2.876" rabbit. POOH and stand back 22 stds. RlU for tubing. 07:00 - 08:00 08:00 - 12:00 12:00 - 14:30 2.50 CMPL TN RUNT CMPL TN 14:30 - 15:00 0.50 CMPL TN RUNT CMPL TN 15:00 - 16:00 1.00 CMPL TN RUNT CMPL TN 16:00 - 00:00 8.00 CMPL TN RUNT CMPL TN 2/24/2004 00:00 - 01 :30 1.50 CMPL TN RUNT CMPL TN 01 :30 - 02:00 0.50 CMPL TN SOHO CMPL TN 02:00 - 03:30 1.50 CMPLTN OTHR CMPL TN 03:30 - 04:30 1.00 CMPL TN SOHO CMPL TN 04:30 - 06:00 1.50 CMPL TN DEOT CMPL TN 06:00 - 06:30 0.50 CMPL TN NUND CMPL TN 06:30 - 12:00 5.50 CMPL TN NUND CMPL TN 12:00 - 15:30 3.50 CMPL TN NUND CMPL TN 15:30 - 16:30 1.00 CMPL TN FRZP CMPL TN 16:30 - 19:00 2.50 CMPL TN FRZP CMPL TN 19:00 - 22:00 3.00 CMPL TN OTHR CMPL TN P/U seal assembly. Safety meeting with Connoco Phillips safety department. Both crews. RIH w/3 1/2" tubing assembly. Ran seal assembly, DS nipple, 5 GLM, to 6931 '. RIH with 3 1/2" completion string. SO = 80 K, PU = 60 K Tag PBR with 60 K slack off and 150 psi at 1 bpm . Enter PBR with no difficulty and space out. M/U space out pups and tubing hanger. Spot 100 bbl ConOor corrosion inhibitor at 0.55 gallbbl and displace to annulus with 60 bbl sea water. Land tubing and RILDS. RlU to test tubing. Test tubing to 3500 psi for 30 min. Test OK. Test Annulus to 3500 psi for 30 min with 1700 psi on tubing. Test OK. Bleed tubing and shear DCK-3 shear valve. Annulus pressure bleed down seemed slow. Pump 1 bbl sea water at 1 bpm and 300 psi down annulus to confirm shear out. Circulation OK. Flow check well & set BPV. PJSM. NID cellar hoses and BOP. Change BOP rams to VBR in upper and 4" in lower cavity. P/U production tree and orient to flowline. NIU tree, pull BPV and run test plug. Test tree to 250/5000 psi OK. Test Pack off to 5000 psi 10 min OK. Pull test plug. RID test equip. RlU hot oil truck. Attempt to pump hot oil. Thaw ice plug. Pump 50 bbl diesel in annulus. Rig annulus to tubing and let diesel u-tube. Load MWD tools for next well in Pipe shed. RID u-tubing. Check pressures. I.A. = 0 psi. TBG = 0 psi. Set BPV. Blow down cellar heaters and secure cellar for move. Back off well slot. Release rig at 22:00 2/24/04 Printed: 4/15/2004 2: 15:05 PM e e 3F-19A Well Events Summary Date Summary 01/21/04 DRIFT TREE, TAGGED @ TUBING HANGER. CONFIRMED BPV IN HANGER. IN PROGRESS.O [Tag] 01/22/04 PULLED BPV FROM TBG HANGER. TAGGED APPARENT FROZEN MUD @ 2383' WLM, RECOVERED SAMPLE ICE / MUD. BLED TBG FROM 1100 TO 700 PSI, 15 MIN.TEST, TBG @ 760 PSI (OA & IA VR PLUGs INSTALLED 5/5/02).0 [Tag] 01/25/04 RIH TO TO 3500'CTMD NO SIGN OF HYDRATES POOH F/P WELL SET INJ ON DECKo [Hydrates-Ice] 01/26/04 CLEANED OUT WELL TO 6890' CTMD CHASED CIBP UP AND DOWN THE HOLE FINALLY GOT IT STUCK AT 6830' CTMD LAYED IN CEMENT TO 4200' CLEANED OUT TO 4000' CTMD WELL WAS FREEZE PROTECTED FROM 3000' WITH DIESEL AND LEFT SHUT IN. 01/28/04 MIT TO 1950 PSI PASSED.TAGGED PBTD AT 4435' WITH 10' X 21/2" DUMMY GUN- PERFORATED: 4390'-4392'. UNABLE TO CIRCULATE TO OA THROUGH THESE PERFS. ADDED PERFS: 4180'-4182', SLIGHT RETURNS (1/8 BPM) FROM OA AT SURFACE WHILE PUMPING DOWN TUBING AT 1.0 BPM. 03/04/04 TAG SOFT BTM W/ 2.72" G. RING @ 8056' SLM. DRIFT TBG W/ 20' X 2.5" D. GUN TO 8026' SLM. REPLACE 1" SOY @ 7319' RKB W/ DV. MIT TBG TO 3000 PSI, GOOD. MITIA TO 3500 PSI, GOOD.O [PT Tbg-Csg, Tag, GLV] 03/09/04 CLEAN OUT MUD IN LINER TO PBTD AT 8,118' CTMD USING SLICK SEAWATER. LEAVE WELL FREEZE PROTECTED WITH 60/40 METHANOL TO 3000' CTMD. 0 [FCO] 03/10/04 03/28/04 03/30/04 03/31/04 04/01/04 04/27/04 LOGGED SCMT FROM 8116' TO 7232', CEMENT QUALITY WAS EXCELLENT FROM 8116' TO 7992' AND 7754' TO 7546', CEMENT WAS FAIR - GOOD FROM 7992' TO 7754' AND 7546 TO 7457', CEMENT TOP AT 7422' -- TAGGED TD AT 8130' -- PERFORATED: 7982'- 8002',6 SPF POWERFLOW. FRAC A SAND FRACTURE TREATMENT. 2706 BBL WATER, 192,040 16/20 ON LOCATION. PUMP BREAKDOWN, SCOUR STAGE AND DATAFRAC. PUMPED FRACTURE TREATMENT @ 20 BPM USING 30# X-LINK GEL, FLUSHED WELL WITH 40 BBLS WATER AND 20 BBLS DIESEL, 181055 # 16/20 CARBO-LITE PUMPED WITH 176,885# AND 10 PPA IN PERFS. 4200# LEFT IN WELLBORE. FISHED TREE SAVER RUBBER. TAG REAL SOFT BTM @ 8012' RKB. ATTEMPT TO RUN 2.81" CATCHER SUB BUT RUN SPEED WAS LESS THAN 40 FPM. WE DISCUSS DISPLACEMENT IN THE MORNING. IN PROGRESS. SET 2.81" CATCHER SUB @ 7369' RKB. PULLED 1" DV'S @ 4860',6063',6894' & 7319' RKB. SET GLV'S @ 6063' & 6894' RKB; OV @ 7319' RKB. POCKET @ 4860' RKB IS OPEN. IN PROGRESS.O [GLV] PULLED 1" DV @ 2901' RKB. SET 1" GLV'S @ 2901' & 4860' RKB. ALL VALVES TESTED BY BLEEDING IA TO CREATE 800 PSI DP. PULLED CATCHER SUB @ 7369' I RKB. GAS LIFT INSTALL COMPLETE. 0 [GLV] PERFORATED: 7762'-7780' & 7828'-7838', 2 1/2" HSD, 6 SPF POWERJET -- SBHP AT 7800'= 3337.7 PSIA, TEMP= 155.6 DEGFo [Perf, Pressure Data] v' / KRU 3F-19A API: 500292268001 Well Tvoe: PROD Anole (Õ) TS: deq@ TUBING SSSV Type: NIPPLE Orig 2/2412004 Angle @ TD: 39 deg @ 8254 Comoletion: Annular Fluid: Last W/O: ~02 Rev Reason: PERF f.-B~tei?nCe Loa: 30' RKB B_ef Loq Date: LastUpdate: 4/30/2004 _ Last Taq: 8012 TD: 8254 ftKB ~te: 3/3112004 Max HOle~6039 Descriotion Size Top~ _Bottom TVD Thread "RODUCTION PRODUCTION 5.500 29 7612 5774 15.50 BTC.MOD SURFACE 7.625 30 3974 3202 29.70 BTC-MOD CONDUCTOR 16.000 30 109 109 62.50 \AI¡::; "'\ LINER Too ~ttom 7416 8246 6275 9.30 Hvdril511 Size I I TVD I Thread SURFACE ---..-- 3.500 I 27 I 7431 I 5635 0 I EUE 8rd-Mod Interval TVD - Zone Stat SPF Date Tvne Comment 7762 - 7780 5893 - 5907 6 412712004 APERF 2.5" HSD PJ, 60 deq oh 7828 - 7838 5944 - 5952 6 4/27/2004 APER 2.5" HSD PJ, 60 deq ph Gas Lift- . 7982 - 8002 6066 - 6082 6 3110/2004 IPERF 2.5" HC/Big Hole Chrgs, 60 MandrelNa!ve e Orient 0 2 (4860-4861. m~' T", I Comment I FRAC A-SAND Gas Lift St MD TVD Man Man Type V Mfr MandrellValve Mfr Run Cmnt 3 1 2901 2442 CAMCO KBG-2-9 GLV 1.0 INT 0.156 1286 41112004 (606%064, -~ 4860 3828 CAMCO KBG-2-9 GLV 1.0 INT 0,188 1323 4/112004 3 6063 4658 CAMCO KBG-2-9 GLV 1.0 INT 0.188 1318 3/3112004 4 6894 5240 CAM~ KBG:2-9 GLV 1.0 INT 0.188 1309 3/31/2004 Gas Lift- 5 7319~ KBG-2~ OV 1.0 INT O. 3/31/2004 Mandre!Nalve 4 Deoth T (6894-6895 ID 27 27 HANGER 3.500 484 483 NIP .. ~AIVICU Y::) 1\1 2.875 7369 5589 NIP ~AIVlCU . .R. ''I 2.812 Gas Lift - 7412 5621 LOCATOR BAKER NO I UK 2.950 MandrelNalve 5 7413 5621 SEAL BAKER SEAL .-. - 2.970 (7319-7320. ~ WLEG BAKER WIRELlNE GUIDE 2.950 PBR UNIQUE "(ìl I<:<I-I¡::r BORE 2.750 NIP- Date Note 514/2003 WELL WAS PREVIOUSLY WORKED OVER IN 2002; LOWER OLD COMPLETION LEFT IN WELL BELOW PLUG @ 7000' -~-~~.. 2/2312004 SIDETRACKED WELL SEAL - -- 2/2312004 TREE: FMC GEN IV SLlMHOLE (7-1116" 5M x WKM 3-118" 5M) (7413-7430, 004 130) TREE CAP CONNECTION:._OTIS S75,4" ACME -----~~-"~----_. WLEG - (7430-7431. 00'4130) Perf - (7762-7780) .- - LINER -.-- (7416-6246, .-- --- 00:3.500, = .- Wt·9.30) - Perf --.- -. (7828-7838) -- -.- --- --- -- -.- .-- ---- -. n¡;r",'Si4iì ,¡:¡¡¡ Perf ~ --; (7982-6002) =:: FRAC ; A-SAND ~ (7982-6002) -f -- .,j e It !!)CfI-O/0 20-Mar-04 AOGCC Lori Taylor 3016 Porcupine Drive Anchorage, AK 99501 DEFINITIVE Re: Distribution of Survey Data for Well 3F-19A Dear Lori Taylor Enclosed are two survey hard copies and one disk Tie-on Survey: Window / Kickoff Survey: Projected Survey: 3,911.71' MD 3,979.00' MD 8,254.00' MD (if applicable) PLEASE ACKNOWLEDGE RECEIPT BY SENDING AN EMAIL TO CARL.ULRICH@HALLlBURTON.COM OR SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Carl Ulrich 6900 Arctic Blvd. Anchorage, AK 99518 Signed \:~ (:''\ \ ~ '"""-..,,"........ """"'",> \J ~c\ C"\:. ~ r--JY'.... Date ,~ Please call me at 273-3545 if you have any questions or concerns. Regards, William T. Allen Survey Manager RECEIVED Attachment(s) r·i'~!) 2 r- f)n04 ',n!" J Lli F1"...~ rrlÞG t"_ '-,,;;¡;.,..fJ IJL t;;: " as WI,S. Comrnisafar¡ t¡1~1"iI'MA ~".,I;i!~"'l¥ ~~~~r'n, C'~ .. DEFINITIVE Halliburton Sperry-Sun Western North Slope ConocoPhillips Kuparuk 3F 3F-19A e Job No. AKMW2890968, Surveyed: 20 February, 2004 Survey Report 16 March, 2004 Your Ref: API 500292268001 Surface Coordinates: 5985860.32 N, 508376.20 E (70022' 21.3219" N, 149055'54.9176" W) Grid Coordinate System: NAD27 Alaska State Planes, Zone 4 e Surface Coordinates relative to Project H Reference: 985860.32 N, 8376.20 E (Grid) Surface Coordinates relative to Structure: 126.18 N, 285.99 W (True) Kelly Bushing Elevation: 84.50ft above Mean Sea Level Kelly Bushing Elevation: 84.50ft above Project V Reference Kelly Bushing Elevation: 84.50ft above Structure !I~E!I"""I"""Y-!lU:1'1 C.RIL.LING· SERVICES A Halliburton Company Survey Ref: svy2071 Halliburton ::,perry-Sun Survey Report for Kuparuk 3F - 3F-19A Your Ref: API 500292268001 Job No. AKMW2890968, Surveyed: 20 February, 2004 ConocoPhí/lips Western North Slope Measured True Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (0/100ft) 3911.71 44.640 357.540 3073.64 3158.14 2051.34 N 35.20 W 5987911.62 N 508338.70 E 2037.44 Tie On Point k 3979.00 44.690 357.050 3121.50 3206.00 2098.59 N 37.43 W 5987958.87 N 508336.42 E 0.517 2084.56 Window Point 4057.30 44.350 352.930 3177.34 3261.84 2153.26 N 42.22 W 5988013.53 N 508331.57 E 3.714 2139.37 4153.64 44.640 347.830 3246.08 3330.58 2219.78 N 53.50 W 5988080.04 N 508320.21 E 3.722 2206.81 4245.09 44.410 342.990 3311.30 3395.80 2281.81 N 69.64 W 5988142.05 N 508304.01 E 3.719 2270.44 4339.80 44.260 343.220 3379.04 3463.54 2345.14 N 88.88 W 5988205.36 N 508284.70 E 0.232 2335.78 4432.59 44.820 345.290 3445.18 3529.68 2407.77 N 106.53 W 5988267.97 N 508266.98 E 1.677 2400.22 e 4527.25 45.510 343.380 3511.93 3596.43 2472.40 N 124.66 W 5988332.58 N 508248.77 E 1.606 2466.70 4621.65 45.990 342.560 3577.80 3662.30 2537.05 N 144.46 W 5988397.21 N 508228.90 E 0.804 2533.43 4716.33 46.170 343.830 3643.47 3727.97 2602.34 N 164.18 W 5988462.47 N 508209.11 E 0.985 2600.77 4811.00 45.860 344.760 3709.22 3793.72 2667.91 N 182.62 W 5988528.02 N 508190.59 E 0.779 2668.23 4905.65 46.040 344.230 3775.03 3859.53 2733.46 N 200.81 W 5988593.55 N 508172.34 E 0.445 2735.63 5003.21 46.350 345.050 3842.56 3927.06 2801.35 N 219.45 W 5988661.43 N 508153.61 E 0.685 2805.41 5097.37 46.850 346.290 3907.26 3991.76 2867.64 N 236.38 W 5988727.69 N 508136.61 E 1.094 2873.37 5192.04 46.540 347.360 3972.19 4056.69 2934.71 N 252.09 W 5988794.75 N 508120.83 E 0.885 2941.95 5283.59 46.930 348.930 4034.94 4119.44 2999.95 N 265.78 W 5988859.97 N 508107.06 E 1.319 3008.44 5381.42 46.570 349.190 4101.97 4186.47 3069.92 N 279.30 W 5988929.92 N 508093.46 E 0.416 3079.59 5474.02 46.420 349.520 4165.72 4250.22 3135.92 N 291.71 W 5988995.91 N 508080.98 E 0.305 3146.66 5568.03 45.870 350.010 4230.85 4315.35 3202.63 N 303.76 W 5989062.61 N 508068.86 E 0.695 3214.39 5659.63 45.390 350.540 4294.91 4379.41 3267.17 N 314.82 W 5989127.14 N 508057.73 E 0.668 3279.83 5754.86 46.750 350.420 4360.97 4445.47 3334.81 N 326.16 W 5989194.76 N 508046.31 E 1.431 3348.37 5850.23 46.070 351.030 4426.73 4511.23 3402.98 N 337.30 W 5989262.92 N 508035.10 E 0.850 3417.42 5943.63 45.330 351.550 4491.96 4576.46 3469.05 N 347.42 W 5989328.98 N 508024.90 E 0.887 3484.26 6039.31 47.940 349.760 4557.66 4642.16 3537.67 N 358.74 W 5989397.59 N 508013.50 E 3.048 3553.78 e 6134.63 47.300 349.630 4621.91 4706.41 3606.95 N 371.33 W 5989466.85 N 508000.83 E 0.679 3624.12 6231.81 46.590 349.530 4688.25 4772.75 3676.79 N 384.17 W 5989536.68 N 507987.91 E 0.734 3695.05 6326.56 46.090 349.360 4753.67 4838.17 3744.17 N 396.73 W 5989604.05 N 507975.28 E 0.543 3763.51 6421.62 45.520 350.120 4819.93 4904.43 3811.24 N 408.87 W 5989671.10 N 507963.06 E 0.830 3831.60 6514.60 45.180 349.840 4885.28 4969.78 3876.38 N 420.38 W 5989736.22 N 507951.48 E 0.424 3897.69 6610.38 45.120 349.730 4952.83 5037.33 3943.20 N 432.42 W 5989803.04 N 507939.36 E 0.103 3965.53 6705.10 44.750 349.580 5019.88 5104.38 4009.02 N 444.44 W 5989868.84 N 507927.28 E 0.406 4032.37 6798.44 44.180 349.150 5086.49 5170.99 4073.28 N 456.50 W 5989933.08 N 507915.14 E 0.691 4097.66 6895.06 43.830 349.250 5155.99 5240.49 4139.21 N 469.08 W 5989999.00 N 507902.49 E 0.369 4164.69 6986.70 43.080 348.070 5222.51 5307.01 4201.01 N 481.47 W 5990060.79 N 507890.03 E 1.206 4227.59 7083.59 42.170 348.130 5293.80 5378.30 4265.21 N 495.00 W 5990124.97 N 507876.43 E 0.940 4293.03 16 March, 2004 - 16:47 Page 20f4 DrillQuest 3.03.06.002 Halliburton ::iperry-Sun Survey Report for Kuparuk 3F - 3F-19A Your Ref: API 500292268001 Job No. AKMW2890968, Surveyed: 20 February, 2004 ConocoPhillips Western North Slope Measured True Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (0/100ft) 7178.17 41.870 348.470 5364.07 5448.57 4327.20 N 507.84 W 5990186.95 N 507863.52 E 0.398 4356.19 7272.89 43.090 349.290 5433.92 5518.42 4389.97 N 520.17 W 5990249.71 N 507851.12 E 1.414 4420.04 7366.42 42.950 349.170 5502.31 5586.81 4452.66 N 532.09 W 5990312.38 N 507839.13 E 0.173 4483.76 7461.20 41.390 345.680 5572.56 5657.06 4514.74 N 545.91 W 5990374.45 N 507825.24 E 2.969 4547.15 7552.17 38.690 341.440 5642.21 5726.71 4570.86 N 562.41 W 5990430.55 N 507808.68 E 4.218 4604.97 7619.77 37.270 339.680 5695.50 5780.00 4610.09 N 576.24 W 5990469.76 N 507794.80 E 2.642 4645.70 e J711.87 37.410 340.720 5768.72 5853.22 4662.64 N 595.16 W 5990522.30 N 507775.82 E 0.702 4700.33 ·~7808.16 39.100 339.150 5844.33 5928.83 4718.63 N 615.63 W 5990578.26 N 507755.29 E 2.025 4758.56 7900.76 37.820 340.200 5916.84 6001.34 4772.64 N 635.64 W 5990632.24 N 507735.22 E 1.552 4814.76 7996.17 36.930 339.440 5992.66 6077.16 4827.00 N 655.62 W 5990686.58 N 507715.18 E 1.051 4871.32 8091.16 36.420 340.280 6068.85 6153.35 4880.26 N 675.15 W 5990739.82 N 507695.59 E 0.753 4926.73 8184.85 38.990 338.950 6142.97 6227.47 4933.96 N 695.13 W 5990793.50 N 507675.55 E 2.877 4982.62 <-^ 8254.00 38.990 338.950 - 6196.72 6281.22 ~ 4974.56 N 710.75 W ~. 5990834.09 N ~507659.88 E 0.000 5024.96 Projected Survey All data is in Feet (US Survey) unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well. Northings and Eastings are relative to Well. Global Northings and Eastings are relative to NAD27 Alaska State Planes, Zone 4. The Dogleg Severity is in Degrees per 100 feet (US Survey). Vertical Section is from Well and calculated along an Azimuth of 352.270° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 8254.0Oft., The Bottom Hole Displacement is 5025.08ft., in the Direction of 351.869° (True). e 16 March, 2004 - 16:47 Page 3 of4 DrillQuest 3.03.06.002 Halliburton Sperry-Sun Survey Report for Kuparuk 3F - 3F-19A Your Ref: API 500292268001 Job No. AKMW2890968, Surveyed: 20 February, 2004 Western North Slope ConocoPhillips Comments Measured Depth (ft) Station Coordinates TVD Northings Eastin9s (ft) (ft) (ft) Comment 3911.71 3979.00 8254.00 3158.14 3206.00 6281.22 2051.34 N 2098.59 N 4974.56 N 35.20 W 37.43 W 710.75 W Tie On Point Window Point Projected Survey e Survey tool program for 3F-19A From Measured Vertical Depth Depth (ft) (ft) To Measured Vertical Depth Depth Survey Tool Description (ft) (ft) 0.00 0.00 8254.00 6281.22 MWD Magnetic (3F-19) e 16 March, 2004 - 16:47 Page 4 of4 DrillQuest 3.03.06.002 03/18/04 Sc~lIIIblPgøp NO. 3131 Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Company: Alaska Oil & Gas Cons Comm Attn: Lisa Weepie 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Kuparuk e Well Job# Log Description Date BL Color CD 3F-19Ax.t)J ,()} ( 10696856 PERF RECORD & SBHP 03/10/04 1 2P-419~tì, "'1) i- 10696852 PERF RECORD & SBHP 03/06/04 1 2P-449 tJ)(ji..., -r.:'~{ 10696851 PERF RECORD & SBHP 03105/04 1 2K-04 . i9, _ I\c 10696845 PRODUCTION PROFILE 02/28/04 1 2P-419 ln~/"()J 10696852 SCMT 03106/04 1 3F-19A; V))..} -tH I 0 10696856 SCMT 03/1 0/04 1 ~.. ~-'-ä\1E- '"' .. .. ..... .) J ..- - e SIGNE~:'~)(~ ~~"\,Q c"'--.:.~"^~ - ... ....... t ' .. n '1 6 0:\04 I ':;'~;'\": L L~t} DATE: ¡aªkt1 Œ! 8: Gas Cons. Commisakm i3, :1!"~""'age ,~ .." ~<.;HtJl' ' Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. ~~~{Yt~ Re: 3F-19A sidetrack (Hearing Status) . e Subject: Re: 3F-19A sidetrack (Hearing Status) From: Thomas Maunder <tom _ maunder@admin.state.ak.us> Date: Wed, 03 Mar 200416:21:49 -0900 To: "Schwartz, Guy L" <Guy.L.Schwartz@conocophillips.com> CC: Steve Davies <steve_davies@admin.state.ak.us> ¿),OL~-O t ~ Guy, The hearing was vacated. Any order granting the exception has been drafted. We are awaiting one thing, a notice/message of non-objection from DNR. Sharon Alsup-Drake had apparently sent a note to Bill van Dyke at DNR and she has not heard from him. I don't expect that he will object. Once we have that the order can be finalized. Tom Schwartz, Guy L wrote: Tom, Any word on the hearing scheduled for yesterday (3-2-04) in regards to the lease line issue?? We are ready to move forward in completing the well. Thanks, Guy Schwartz Drilling and Wells Engineer office: 907-265-6958 ATO-1548 1 of 1 2/11/2005 9:24 AM . rm l U} -) . n r~@rv(® Lb LnJ cQ) U\~ L#~ FRANK H. MURKOWSKI, GOVERNOR AI.ASIiA OIL AND GAS CONSERVATION COMMISSION 333 W. 7'" AVENUE, SUITE 100 ANCHORAGE. ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Randy Thomas Kuparuk Team Leader ConocoPhillips (Alaska), Inc. PO Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field 3F-19A ConocoPhillips (Alaska), Inc. Permit No: 204-016 Surface Location: 37' FSL, 124' FSL, Sec. 19, T12N, R9E, UM Bottomhole Location: 302' FNL, 816' FEL, Sec. 19, T12N, R9E, UM Dear Mr. Thomas: Enclosed is the approved application for permit to drill the above referenced exploration well. This permit to drill does not exempt you from obtaining additional permits or approvals required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. The permit is approved subject to full compliance with 20 AAC 25.055. Approval to perforate and produce is contingent upon issuance of a conservation order approving a spacing exception. ConocoPhillips assumes the liability of any protest to the spacing exception that may occur. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Please provide at least twenty-four (24) hours notice for a representative of the Commission to witness any required test. Contact the Commission's North Slope petroleum field inspector at 659-3607 (pager). ::~R2~' Chair BY ORDER OF THE COMMISSION DATED this-"l day of January, 2004 cc: Department ofFish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. Co e Post Office Box 100360 Anchorage, Alaska 99510-0360 Randy Thomas Phone (907) 265-6830 Fax: (907) 265-1535 Email: randy.l.thomas@conocophillips.com RECEIVED January 16, 2004 JAN 1 ~ ~D04 .-. ()i & Gal Cooi. (M¡¡¡ '1,',,,,, A~ Alaska Oil and Gas Conservation Commission 333 West ih Avenue Suite 100 Anchorage, Alaska 99501 (907) 279-1433 Re: Application for Permit to Drill, Rotary Sidetrack, Producer 3F-19A Dear Mr. Maunder As per your request I have included a procedure detailing the steps ConocoPhillips will take to ensure proper testing of the BOP equipment is completed to a pressure above the MASP prior to penetrating the productive zones during the drilling process. If you have any questions or require any further information, please contact Kelly McLure at 265-6059. Sincerely, Randy Thomas GKA Drilling Team Leader 1a. Type of Work: . STATE OF ALASKA tit ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL ~~Iq kft tp Drill[.:d Re-entry 0 I Redrill gb 1b. Current Well Class: Stratigraphic Test 0 2. Operator Name: ConocoPhillips Alaska, Inc. 3. Address: P.O. Box 100360 Anchorage, AK 99510-0360 4a. Location of Well (Govemmental Section): Surface: 37' FSL, 124' FEL, Sec. 19, T12N, R9E, UM Top of Productive Horizon: 520' FNL, 704' FEL, Sec. 19, T12N, R9E, UM Total Depth: 302' FNL, 816' FEL, Sec. 19, T12N, R9E, UM ,( 4b. Location of Well (State Base Plane Coordinates): Surface: x- 508376' y- 5985860'/ Zone- 16. Deviated wells: Kickoff depth: ~ 18. Casing Program Size Hole Casing 6.75" 5.5" 4.75" 3.5' 19 Total Depth MD (It): 8132' Casing Structural Conductor \. Surface Production Liner ft. Maximum Hole Angle: Specifications Weight Grade Coupling 15.5# 9.3# L-80 L-80 BTC-M Hydril 511 / 46° Length 7675' 645' PRESENT WELL CONDITION SUMMARY Total Depth TVD (It): Plugs (measured) 6290' 7000' - R. Thomas <:~~~ Length Size 80' 16" 3890' 7.625" 7453' 5.5" 578' 3.5" 20 AAC 25 005 ExploratoryD Development Oil 0 Multiple Zone 0 Service 0 Development Gas 0 Single Zone 0 5. Bond: 0 Blanket D Single Well 11. Well Name and Number: Bond No. 59-52-180 3F-19A 6. Proposed Depth: 12. Field/Pool(s): MD: 8242' ./ TVD: 6281' ,/ Kuparuk River Field 7. Property Designation: IIP~5632 J'b 8. Land Use Permit: Kuparuk Oil Pool 13. Approximate Spud Date: ADL 2565 9. Acres in Property: 2448 - 2/1/2004 14. Distance to Nearest Property: 4464' 10. KB Elevation 15. Distance to Nearest 4 Well within Pool: 3F-13 , 400' RKB 30' / 54' AMSL 17. Anticipated Pressure (see 20 AACy.035) .-/ Max. Downhole Pressure: 3942 psig / Max. Surface Pressure: 3388 psig Setting Depth Quantity of Cement Top Bottom c. f. or sacks MD TVD MD TVD (including stage data) 30' 7555' 7705' 8242' 5824' 6281' 30' 5698' 110 sx Class G 70 sx Class G (To be completed for Redrill and Re-Entry Operations) Effective Depth MD (It): Effective Depth TVD (It): Junk (measured) 7867' 6080' 7480' MD TVD 121' 121' 3986' 3214' 7549' 5834' 8127' 6286' Cement Volume 260 sx AS I 1060 sx AS III, 330 sx Class G 250 sx Class G included above Perforation Depth MD (ft): 7644'-7654',7852'-7872' 20. Attachments: Filing Fee 0 BOP Sketch 0 Property Plat 0 Diverter Sketch 0 21. Verbal Approval: Commission Representative: 22. I hereby certify that the foregoing is true and correct to the best of my knowledge. Printed Name Signature \ Permit to Drill . . I /. Number: ;2.L)7,-Olb API Number: 50- D Z!t- Z2-?>r;()-D / Samples required 0 Yes NNO Hydrogen sulfide measures .ø Yes 0 No I~\~,c..\ '&J~ .~"')-\ ~v~ '\ 'Ðt. ~,~~\j. Origina1 signed By Sarah Palin Conditions of approval : Other: Approved by: Commission Use Only Permit Approval See cover letter I V J bL I _ f2.!:2ther r~i~e.ments ~i~:~~:n::U~:.. y r.~:;''''. :~=,,~. ~I~ ~;: Ù ~OO'-J r>\ s..~,~~/t..¡ ~ rl ~ 2004 i-\QOO ~.....'. ~~~/rnl\ a~to s Conmìssion Dat~nChlaþ' II/) Si1 I '<C. I Drilling Program0 Seabed Report 0 Perforation Depth TVD (ft): 5908'-5915',6069'-6084' Time v. Depth Plot 0 Shallow Hazard Analysis U Drilling Fluid Program 0 20 AAC 25.050 requirements 0 Date: Contact Kelly McLure @ 265-6059 Title Kuparuk Team Leader Phone US- b'ë5' 3ð Date \ (( '7 (0 'f ~ ~ haron AI/~lIn-nff"la" Date: COMMISSIONER BY ORDER OF THE COMMISSION Form 1 0-401 Revised 3/2003 . ORIGINAL Submit in duplicate e .PPlication for Permit to Drill, We1l3F-19A Revision No.O Saved: 13-Jan-04 Permit It - Kuparuk Well 3F-19A Application for Permit to Drill Document MoximizE W~II Volin Table of Contents 1. Well Name ...... ............... ....... ......... ........ ... ....................... .... ......... ..... ................ ........ 2 Requirements of 20 MC 25.005 (f) ....................................................................................................... 2 2. Location Sum mary ... ....... ..... ........... ................. ..... .......... ........ ............ ........ .............2 Requirements of 20 AAC 25. 005(c)(2).......... ..... ........... .......... ....... .................. ........ ................ ......... ..... 2 Requirements of 20 MC 25. 050(b) ....... ............ ....... .................... ................ ...................... ..... .............. 2 3. Blowout Prevention Equipment Information..........................................................3 Requirements of 20 AAC 25. 005(c)(3)..... ........... ....................... ............... ........ ...... ............... .......... ...... 3 4. Dri II i ng Hazards Information ........ ........................ ............... ............... ....... .............. 3 Requirements of 20 MC 25.005 (c)(4) .................................................................................................. 3 5. Procedure for Conducting Formation Integrity Tests ...........................................3 Requirements of 20 AAC 25.005 (c)(5) .................................................................................................. 3 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)(l) .......... ......... ...... ......... ....................... ..... ......... ..................... ....... 4 8. Dri II i n9 FI u id Program ....... ......... .......... ... ............................... ..... ...... ............... ........ 4 Requirements of 20 AAC 25.005(c)(B)....................... ...... ...... ........ ....... ........................ ................ .... ..... 4 9. Abnormally Pressured Formation Information ......................................................5 Requirements of 20 MC 25.005 (c)(9) .................................................................................................. 5 1 O. Seismic Analysis ...... ....... ........ .............. ........................... ...... ..... ........ ...... ........ ....... 5 Requirements of 20 AAC 25.005 (c)(1 0) ................................................................................................ 5 11. Seabed Condition Analysis .....................................................................................5 Requirements of 20 MC 25.005 (c)(11) ................................................................................................ 5 12. Evidence of Bondi ng ..... ....... .............. ............................. ...... ............. ........ ... .... .......5 Requirements of 20 AAC 25.005 (c)(12) ................................................................................................ 5 13. Proposed Dri Iii n9 Program ............. ............................... ...... ..... .... ... ............... ......... 5 ORIGINAL 3F-19A PERMIT /T.DOC Page 1 016 Printed: 13-Jan-04 e .PPlication for Permit to Drill, Well 3F-19A Revision No.O Saved: 13-Jan-04 Requirements of 20 AAC 25.005 (c)(13) ................................................................................................ 5 14. Discussion of Mud and Cuttings Disposal and Annular Disposal.......................5 Requirements of 20 AAC 25.005 (c)(14) ................................................................................................ 5 15. Attach ments.............................................................................................................. 5 Attachment 1 Drilling Program ...................... ... ....... ....... .......... .... .............. .... ...................... ........... ...... 5 Attachment 2 Directional Plan..... ...... ..................................................................................6 Attachment 3 Well Schematic ................................................ ............ ....... ..........................6 Attachment 4 BOP Stack Schematic.................................................................................... 6. 1. Well Name Requirements of 20 AAC 25.005 (f) Each well must be identified by a unique name designated by the operator and a unique API number assigned by the commission under 20 AAC 25. 040(b}. For a well with multiple well brancheS; each branch must similarly be identified by a unique name and API number by adding a suffix to tIle 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 3F-19A./ 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 item~ except for an item already on file with the commission and identified in the application: (2) a plat identifying the property and the property's owners and showing (A)the coordinates of the proposed location of the well at the surface, at the top of each objective formation, and at total depth, referenced to governmental section lines. (B) the coordinates of the proposed location of the well at the surface, referenced to the state plane coordinate system for this state as maintained by the National Geodetic Survey in the National Oceanic and Atmospheric Administration; (C) the proposed depth of the we/I at the top of each objective formation and at total depth; Location at Surface NGS Coordinates Northings: 5,985,860 137' FSL 124' FEL. Sec 19, T12N I Eastings: 508,376 / I R9E UM I' RKB Elevation I Pad Elevation I 30.3' AMSL 54.2' AMSL Location at Top of Productive Interval Ku aruk C-4 Sand NGS Coordinates Northings: 5,990,582 520' FNL, 704' FEL, Sec 19, T12N, R9E, UM ... Eastings: 507,773 Measured De th RKB: Total Vertical De th RKB: Total Vertical De th 55: 7777' 5884' 5800' Location at Total De 302' FNL 816' FEL NGS Coordinates Northings: 5,999,796 Eastings: 507,687 Sec 19 T12N R9E UM' Measured De th RKB: Total Vertical De th RKB: Total Vertical De th 55: 8242' \/ 6281' y 6197' and (D) other information required by 20 MC 25.050(b); Requirements of 20 AAC 25.050(b) If a we/I is to be intentionally deviate4 the application for a Permit to Drill (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 the proposed well; Please see Attachment 2: Directional Plan ORIGINAL 3F-19A PERMIT IT. DOC Page2of6 Printed: 13-Jan-04 e AApplication for Permit to Drill, We1l3F-19A ., Revision No.O Saved: 13-Jan-04 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 record~ and show that each named operator has been furnished a copy of the application by certified mail; or (B) state that tile applicant is the only affected owner: The Applicant is the only affected owner. 3. Blowout Prevention Equipment Information Requirements of 20 AAC 25.005(c)(3) An application for a Permit to Odll must be accompanied by each of the following item~ except for an item already on file wIth the commission and identified in the application: (3) a diagram and description of the blowout prevention equipment (BOPE) as required by 20 MC 25.030 20 MC 25.036, or 20 MC 25.03/; as applicable;, Please see attached reference BOP schematic for Nordic 3. 4. Drilling Hazards Information Requirements of 20 AAC 25.005 (c)(4) An application for a Permit to Onll must be accompanied by each of the following item~ except for an item already on file with the commission and identified in the application: (4) information on drilling hazard~ including (A) the maximum downhole pressure that may be encounter~ criteria used to determine it and maximum potential surface pressure based on a methane gradient;, BHP data on offset injectors indicates that the current reservoir pressure for 3F-19A the bottom A sand is 3950 /' .¡ psi at 6160' 1VD, 0.64psi/ft or 12.3 ppg EMW. -- The maximum potential surface pressure (MPSP) while drilling 3F-19A is calculated using the above maximum reservoir pressure from A sand, a gas gradient of 0.09 psi/ft, and the A sand target at 6160' 1VD: MPSP =(6160 ft)*(0.64 - 0.09 psi/ft) = 3388 psi ..-' (B) data on potential gas zones;, KOP is in the C-l00 shale. The well bore is not expected to penetrate any gas zones between KOP and TD. 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; 1. The first potential hazard is the LOT at the kickoff point. It is planned to cement the open hole with enough class "G" cement to cover and seal this section of the open hole from the original well bore where casing was cut and pulled. Once that is achieved, a LO~ZFIl"0f...~~.I.~ë.!~t 14.5 epg should be attained. . 5. Procedure for Conducting Formation Integrity Tests Requirements of 20 AAC 25.005 (c)(5) An application for a Permit to Odll must be accompanied by each of the following item~ except for an item already on file with the commission and identified in the application: (5) a description of the procedure for conducting formation integrity tests, as required under 20 MC 25.030(f); A procedure is on file with the commission for performing LOT's. For 3F-19A the procedure will be followed after kicking off. The formation at the kickoff depth (C-l00 shale) will be pressured until leak-off occurs or to .! 14.5 ppg EMW, which ever comes first. ORIGIN.AL 3F-19A PERMIT IT. DOC Page 3 of 6 Printed: 13-Jan-04 e AApplication for Permit to Drill, We1l3F-19A .. Revision No.O Saved: 13-Jan-04 6. Casing and Cementing Program Requirements of 20 AAC 25.005(c)(6) 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: (6) a complete proposed casing and cementing program as required by 20 AAC 25.030, and a description of any slotted linet; pre- perforated linet; or screen to be installed; CasinCl and Cementing Program I Hole Top Btm CsglTbg Size Weight Lengt MDfTVD MDfTVD OD (in) (in) (Ib/ft) Grade Connection h (ft) (ft) Cement Program (ft) 7-5/8" 8-1/2 29.7# L-80 BTC-Mod 30'/30' 3974'/3202' Returns to surface- original well bore 6-3/4 15.5# L-80 BTC-Mod 30'/30' 7705'/5824' 110 sxs 15.8 ppg Class G, 5-1/2" 1.17 tt3/sk 3-1/2" 4-3/4" 9.3# L-80 Hydril 511 /081' 7555/5698 8242'/6281' 70 sx 15.8 Class G, 1.17 Liner tt3/sk 3-1/2 9.3# L-80 8RD EUE 28'/28' 7555'/5698' Packer/PBR w/ wireline entry Tubinq MOD quide stunq Inside ZXP 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 on file with the commission and identified in the application: (7) a diagram and description ofthe diverter system as required by 20 AAC 25.03~ unless this requirement is waived by the commission under 20 AAC 25.035(h)(2); This rotary sidetrack will cut and pull the existing 5.5" casing at ± 4350'. BOPE will be installed prior to cutting v" and pulling the casing, and therefore, no diverter is required. 8. Drilling Fluid Program Requirements of 20 AAC 25.005(c)(B) 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: (8) a drilling fluid program, induding a diagram and description of the drilling fluid system, as required by 20 AAC 25. 033; Drilling will be done using a LSND mud systems having the following properties: S·d t k H I d rt· I e rac oemu prope les Int Hole & Top set Prod Hole Drill Top c4 Top c1 Top A3 Top A2 Out Density (ppg) 9.8 - 10.5 11.5 11.5 12.0 12.3 12.3-12.5 Funnel Viscosity 40-55 42-58 42-58 45-58 42-58 42-58 Yield Point (cP) 20-25 25 - 30 25 - 30 25 - 30 25 - 30 25 - 30 Plastic Viscostiy (lb/100 sf) 8-15 8-15 8-15 8-16 8-18 15-25 10 second Gel Strength (lb/100 sf) 3-6 3-6 3-6 3-6 4-7 4-8 10 minute Gel Strength (lb/100 sf) 7-10 7-12 7-12 7-15 7-15 8-16 pH 9-9.5 9-9.5 9-9.5 9-9.5 9-9.5 9-9.5 API Filtrate(cc) <6 <6 <6 <6 <4 <4 Solids (%) 5-11 1 0-15 10-15 13.2 -17 14 - 17 15-19 ./ See attached for a Diagram of the Nordic 3 Mud System. Drilling fluid practices will be in accordance with appropriate regulations stated in 20 MC 25.033. ORIGINAL 3F-19A PERMIT IT. DOC Page 4 of 6 Printed: 13-Jan-04 e _Application for Permit to Drill, Well 3F-19A . Revision No.O Saved: 13-Jan-04 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 followlilg ¡tem~ except for an Item already on file with the commission and identified in the application: (9) for an exploratory or stratigraphic test well, a tabulation setting out the depths of predicted abnormally gee-pressured strata as required by 20 AAC 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 Item~ except for an Item already on file with the commis..<;ion and identified in the application: (10) for an exploratory or stratigraphic test well, a seismic refraction or reflection analysis as required by 20 MC 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 must be accompanied by each of the following item~ except for an item already on file with the commission and identified in the application: (11) for a well drilled from an offshore platform, mobile bottom-founded structure, jack-up rig,. or floating drilling vessel, 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 item~ except for an item already on file with the commission and identified in the application: (12) evidence showing that tile requirements of 20 MC 25.025 {Bonding}have been met/ Evidence of bonding for ConocoPhillips Alaska, Inc. is on file with the Commission. " 13. Proposed Drilling Program Requirements of 20 AAC 25.005 (c)(13) 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: 1. See attachment 1, and refer to Attachment 3, Well Schematics. 14. Discussion of Mud and Cuttings Disposal and Annular Disposal Requirements of 20 AAC 25.005 (c)(14) An application for a Permit 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 during the drilling process will be disposed of at KRU's, 1R-18 Class II disposal well. All cuttings will be hauled to the Prudhoe Bay Field for temporary storage and eventual processing for injection at the G & I facility on DS-04. 15. Attachments : Attachment 1 Drilling Program Attachment 2 Directional Plan Attachment 3 Well Schematics Attachment 4 BOP Schematics ORIGINAL 3F-19A PERMIT IT. DOC Page 5 of 6 Printed: 13-Jan-04 e 3F- 19A Drillina Hazards Summary 6-3/4" Hole / 5-1/2" Casino Interval Event Broach of Conductor Risk Level Low Gas Hydrates Low <' Gravel/Sand Sloughing Low Hole SwabbingjTight Hole on Low Tri s Lost Circulation due to weak area Moderate from sidetrack kickoff and Shale stability in HRZ, K-l '-\ ) / ~\' _ 6~ole / 3-1/2" Liner Interval Event Shale stabili in roduction hole High ECD and swabbing with higher MW's required Risk Level Low Moderate Barite Sa Differential Sticking Low Moderate Abnormal Reservoir Pressure Moderate / Lost Circulation Moderate e Miti ation Strate Monitor cellar continuously during interval. If observed - control drill, reduce pump rates, reduce drillin fluid tem ratures, Additions of Drilltreat. Increase mud weight / viscosity, High viscosity sweeps. Monitor fill on connections Circulate hole clean prior to trip. Proper hole fill (use of tri sheets, Pum in out of hole as needed. Prevent by keeping hole clean. If losses occur - reduce pump rates and mud rheology, use LCM Mitigation Strate Control with MW and ro er drillin ractices. Condition mud prior to trips. Monitor ECD's with PWD tool while drilling across pay interval. Pump and rotate out on tri s as a last resort. Good drillin ractices as documented in well Ian. Periodic wiper trips. Do not leave pipe static for extended riod of time. Follow mud weight schedule and do not fall behind. Stripping Drills, Shut-in Drills, Increased mud weight as needed. Ensure adequate kick tolerance prior to drilling a interval. Use PWD to monitor hole cleaning. Reduced pump rates, Mud rheology, LCM. Use GKA LC decision tree. 3F-19A Drilling Hazards Summary. doc prepared by Kelly McLure 01/11/04 ORIGINAL Page 1 of 1 e _ry to Re-enter and Abandon. Well 3F-19A ., Revision No.O Saved: 13-Jan-04 3F-19A Drillina Proaram Pre-Rig Well Work: 1. Check all lock down screws on the 7-1/16" x 5M tubing head flange. Test the packoffs on the 5.5" casing. 2. File Sundry notice - plug back. Notify AOGCC field inspector 24 hours before commencing work. 3. RIH and and perforate the 5.5" casing at 4360' MD. 4. Circulate kill weight fluid and clean up the annulus Rig Work: 1. Notify the AOGCC field inspector 24 hours before prior to spud and BOP test. MI/RU Nordic 3. Install blanking plug on top of the back pressure valve. 2. NU and test the l1"x 5K" BOPE to 250# / 3500# --~ 3. Engage the 3-1/2" tubing with a spear. LID the tubing hanger. 4. P/U and run a storm packer, hang off in the 5-1/2" casing. 5. N/D BOP's. Remove tubing head adapter and packoff. Tack weld the slips/packoff to the 5.5" casing. Install the doughnut to be used as a packoff for testing. 6. NU Bop's to the 11", 3000 psi flange & test 7. POOH w/ storm packer & rack back 900' of the 3-1/2" tubing for the cmt stinger. RU wireline set a CIBP inside the 5.5" casing at 4375' MD. POOH. 8. PU & RIH with a chemical cutter and cut the 5.5" casing at 4350' MD. Run spear & pull the 5-1/2" casing and LID the casing. ~<\- S§ /0' 'Y. Displace the hole with new LSND mud. '!>or' ~ 10. RIH w/ 3-1/2" tubing string and to spot a 500' balanced cement plug on top of the CIBP with the TOC inside the 7-5/8" shoe at approximately 3875' MD. POOH 3 stands and circulate above the cement plug. 11. POOH and LD 3-1/2" tubing. I i ! ~ 13. Drill the Intermediate hole section with an 6-3/4" bit to the top of the C4 sand and top set at approximately 7705' with 5.5", 15.5#, L-80 casing. . C'"\ Á . . ' -r:Q ~ -.J ~~ .-\-..) ~ '\ i'.'::.. "Cc...~U '::1f"~-=:.-\- \Sa\' -\-0 '--\ooa p> \ '( \ ~ ~\!)14. P/U a 4-3/4" PDC bit, MWD, LWD, non-mag flex collars, jars, and DP as required. W'\, ~\~I . ~~a 15. Test casing to 3500 psi, drill cmt, float equip, drill 20' new hole. Perform LOT = 14.5 ppg. J\.J 12. PU BHA, 4.0" DP, and RIH to TOC. Check for cement hardness and PU 2 stands if cement is not hard and wait on cement. 16. Drill ahead, (Sperry Sun Directional Program attached). Maintain the LSND mud properties as per the MI program. The MW should be 11.5 ppg at the Top/C4: 7777' MD/5884' TVD. ORIGINAL 3F-19A DRILLING PROGRAM.doc Page 1 of 2 Printed: 13-Jan-04 e _ry to Re-enter and Abandon, Well 3F-19A . Revision No.O Saved: 13-Jan-04 17. Continue drilling into the Miluveach Shale to give ± 200' of rat hole below the base of the Kuparuk A. The proposed TD is ± 8242' MD, 6281' ìVD. At TD, circulate bottoms and make a wiper trip. RIH to TD. Circulate and condition the hole to run the liner. POOH. f ",/ 18. R/U and run the 3-1/2" liner to TD. The required overlap is ~ 150': TOL = 7555' MD. Reciprocate the liner while circulating and cementing. R/U Dowell and prepare to cement the liner. 19. Cement liner as per cement program. Release from liner. Set ZXP. 20. Displace the well above the TOL with seawater (± 115 bbl) and until the returns are clean. Check for flow. POOH. LD/DP. RIH with the DP from the derrick and then LD/DP. 21. R/U and RIH with the 3-1/2" tubing tag the TOL. Set packer & shear out of PBR. Space out and land. RILDs. Test tubing, PBR and liner to 3500 psi with the IA open. Bleed the tubing down to 2000 psi. Test the lA, PBR and TOL to 3500 psi. Bleed off all pressures. 22. Install a TWC. ND BOPE. NU and test the 4-1/16" (5M) tree to 5000 psi with the IA open. Pull the TWC. Pressure up the IA to ± 2500 psi and shear the "RP" valve. Displace the well with diesel freeze protect fluid through the "RP" valve (114 bbl). Install a BPV. R/D and M/O Nordic 3. Post-Rig Well Work: 1. Pull the BPV. R/U SLU. Drift and tag to PBTD. 2. Dummy-off the GLM. R/D SLU. 3. R/U E-Line. Run cement bond log inside the liner. 4. Perforate the Kuparuk as directed. R/D E-Line. 5. Install new "s" riser and replace the well house(s). 3F-19A DRILLING PROGRAM.doc Page 2 of 2 o RIG I N A L Printed: 13-Jan-04 e e 3F-19A Drilling Program Pre-Rig Well Work: 1. Check all lock down screws on the 7-1/16" x 5M tubing head flange. Test the packoffs on the 5.5" casing. 2. File Sundry notice - plug back. Notify AOGCC field inspector 24 hours before commencing work. 3. RIH and and perforate the 5.5" casing at 4360' MD. 4. Circulate kill weight fluid and clean up the annulus Rig Work: 1. Notify the AOGCC field inspector 24 hours before prior to spud and BOP test. MI/RU Nordic 3. Install blanking plug on top of the back pressure valve. 2. NU and test the 11"x 5K" BOPE to 250# / 3500# 3. Engage the 3-1/2" tubing with a spear. LID the tubing hanger. 4. PjU and run a storm packer, hang off in the 5-1/2" casing. 5. N/D BOP's. Remove tubing head adapter and packoff. Tack weld the slips/packoff to the 5.5" casing. Install the doughnut to be used as a packoff for testing. 6. NU Bop's to the 11",3000 psi flange & test 250 psi & 3000 psi. (only testing to 3000 psi because plan top set 7. POOH w/ storm packer & rack back 900' of the 3-1/2" tubing for the cmt stinger. RU wireline set a CIBP inside the 5.5" casing at 4375' MD. POOH. 8. PU & RIH with a chemical cutter and cut the 5.5" casing at 4350' MD. Run spear & pull the 5-1/2" casing and LID the casing. 9. Displace the hole with new LSND mud. 10. RIH w/ 3-1/2" tubing string and to spot a 500' balanced cement plug on top of the CIBP with the TOC inside the 7-5/8" shoe at approximately 3875' MD. POOH 3 stands and circulate above the cement plug. 11. POOH and lD 3-1/2" tubing. 12. PU BHA, 4.0" DP, and RIH to TOe. Check for cement hardness and PU 2 stands if cement is not hard and wait on cement. 13. Drill the Intermediate hole section with an 6-3/4" bit to the top of the C4 sand and TOP Set at approximately 7705' with 5.5", 15.5#, l-80 casing. 14. Cement the 5.5" casing, install tubing head assembly, NU BOP and test to 250 psi and 5000 psi (MASP = 3388 psi at productive interval) and will fulfill BOP testing requirements. 15. PjU a 4-3/4" PDC bit, MWD, lWD, non-mag flex collars, jars, and DP as required. 16. Test casing to 3500 psi, drill cmt, float equip, drill 20' new hole. Perform lOT = 14.5 ppg. 17. Drill ahead, (Sperry Sun Directional Program attached). Maintain the LSND mud properties as per the MI program. The MW should be 11.5 ppg at the Top/C4: 7777' MD/5884'TVD. 18. Continue drilling into the Miluveach Shale to give ± 200' of rat hole below the base of the Kuparuk A. The proposed TD is ± 8242' MD, 6281' TVD. At TD, circulate bottoms and make a wiper trip. RIH to TD. Circulate and condition the hole to run the liner. POOH. 19. RjU and run the 3-1/2" liner to TD. The required overlap is ~ 150': TOl = 7555' MD. Reciprocate the liner while circulating and cementing. RjU Dowell and prepare to cement the liner. 20. Cement liner as per cement program. Release from liner. Set ZXP. e e 21. Displace the well above the TOL with seawater (± 115 bbl) and until the returns are clean. Check for flow. POOH. LD/DP. RIH with the DP from the derrick and then LD/DP. 22. R/U and RIH with the 3-1/2" tubing tag the TOL. Set packer & shear out of PBR. Space out and land. RILDs. Test tubing, PBR and liner to 3500 psi with the IA open. Bleed the tubing down to 2000 psi. Test the lA, PBR and TOL to 3500 psi. Bleed off all pressures. 23. Install a TWC. ND BOPE. NU and test the 4-1/16" (5M) tree to 5000 psi with the IA open. Pull the TWC. Pressure up the IA to ± 2500 psi and shear the "RP" valve. Displace the well with diesel freeze protect fluid through the "RP" valve (114 bbl). Install a BPV. R/D and M/O Nordic 3. Post-Rig Well Work: 1. Pull the BPV. R/u SLU. Drift and tag to PBTD. 2. Dummy-off the GLM. R/D SLU. 3. R/U E-Line. Run cement bond log inside the liner. 4. Perforate the Kuparuk as directed. R/D E-Line. 5. Install new "s" riser and replace the well house(s). *NOTE: Even though we will run the completion prior to rig release, we do not intend to produce or test the well until we receive the spacing exception. 3F-19APROpAED SIDETRACK COMPLETION Top of Cement plug set @ +-3875' MD 7-5/8" 29.7# L80 casing @ 3974' MD I 3202' TVD Depth adjusted for Nordic 3 RKB Sidetrack KOP @ +1- 4224' MD, +- 3380" TVD 5-Yz" 15.5# Casing Cut @+-4350' MD Baker "K-1" CIBP @ +1- 4375' MD Baker "K-1" CIBP @ +1- 7000' MD Original Wellbore 3- Yz" X 5- Yz" Long String 8127' MD TD e Co s 3-1/2" 5M FMC Gen IV tubing hanger with 3-1/2" L-80 EUE 8rd pin down 3-1/2",9.3#, L-80 EUE 8rd tubing to surface- all special drift 2.91" 3-1/2" Camco 'DS'landing nipple with 2.875" ID No-Go profile set at +1-500' MD GLM Placement: 3-1/2" 9.3# L-80 EUE 8rd Mod tubing to GLM Valves #1-4: 3-Yz" x 1" KBG2-9 mandrels with DV and 6 Ft. handling pups instlled on top and bottom Place gas-lift mandrels at the following depths: TVD Approx MD Valve 2450 2912 1.00 3825 4864 1.00 4675 6087 1.00 5250 6914 1.00 5685 7530 1.00 3-1/2" 9.3# L-80 EUE 8rd Mod tubing as necessary Top liner set at 7555' MDI 5824' TVD PACKER ASSEMBLY Baker Slim Line 80-4012 Ft. PBR wI K anchor. Baker 5-Yz" SABL permanent packer wI 2.78" ID 110ft. Pup joint 3-Yz" 9.3# L-80 EUE-Mod 8 Rd 2.75 Halliburton "X" Nipple with RHC Plug Installed (high pressure) 110ft. Pup joint 3-Y:z" 9.3# L-80 EUE-Mod 8 Rd 3-Yz" WLEG with 3-Yz" EUE-Mod Box up 2.81" Cameo D LINER ASSEMBLY 5-Yz" Flex-Lock Liner Hanger Packer 3-Y:z" X 5-Yz" HMC Hydraulic Liner Hanger 3-Yz" IBT-Mod or EUE-Mod Liner as needed 3-Yz" Landing Collar One Joint 3-Yz" IBT-Mod or EUE-Mod Tubing 3- Y:z" Float Collar Two Joints 3-Yz" IBT-Mod or EUE-Mod Tubing 3-Yz" Float Shoe Top set 5.5" csg at 7705' MDI 5824' TVD I C4 & C1 sands Estimated BHA 3950 psi 8242' MD/6281' TVD ". A3 & A2 sands e Conocó'Pt.illips ConocoPhillips Alaska Inc. Kuparuk River Unit Kuparuk 3F Pad 3F-19 3F-19A ¡Plan: 3F-19A (wp05) Standard Planning Report 08 January, 2004 ORIGINAL e SITE DETAILS l Site Centre 5985734.460 508662.330 Kuparuk 3F Pad Water Depth: 0.00 Positional Uncertainty: 0.00 Convergence: 0.066 Wel>tH/East(~} IHtOOWinJ w120 N_ 3F.9 WELL NolUiJq¡ Easliq¡ -286.015985860.320 508376.200 Interpolation Method:MD Depth Range Front 84.50 Maximum Range: 1015.80 ANTI-COLLISION SEmNGS Intervat 50.00 To: 8246.07 Reference: Plan: 3F.19A(wp05) Lalitudc Lo~ Skit 70"22'21.322N JO·SS'S4.918W N/A ····239 o 270 120 "'239 SECTIONDETAll.S See MD Inc Azi TVD +NI~S +EI-W DLeg TFace VSee Target I 4224.50 45.036 355.008 3383.50 2263.12 -48.52 0.00 0.000 2249.08 2 4352.92 46.136 347.981 3473.42 2353.72 -62.12 4.00 -80.113 2340.69 3 7354.53 46.136 347.981 5553.39 4470.40 -51276 0.00 0.000 4498.74 4 7780.89 31.924 332765 5884.50 4722.82 -596.98 4.00 -151.755 4760.20 3F-19A TgtC4 5 7780.90 31.924 332764 5884.51 472283 -596.98 4.00 -34.970 4760.21 6 7845.36 31.924 332764 5939.23 4753.14 ·61258 0.00 0.000 479234 7 7846.86 31.875 332829 5940.50 4753.84 -612.94 4.00 145.031 4793.09 3F-19A TgtC1 8 7849.12 31.959 332892 5942.42 4754.91 -613.49 4.00 21.550 4794.21 9 7966.23 31.959 332.892 6041.77 4810.08 -641.73 0.00 0.000 4852.69 10 7991.71 31.013 332.167 6063.50 4821.89 -647.87 4.00 -158.503 4865.21 3F-19A TgtAJ II 8029.04 31.013 332.167 6095. 50 4838.90 ·656.85 0.00 0.000 4883.28 3F-19A Tgt A2 12 8246.07 31.013 332.167 6281.50 4937.78 -709.06 0.00 0.000 4988.28 Travelling Cylinder Azimuth (TFO+ AZI) [deg] vs Centre to Centre Separation [ft] 07 w200 150 wI 00 50 0 270 50 100 150 w200 07 COMPANY DETAILS WEWA HDET Pllln3F·19A ConocOPhillips Alaska Inc. Engineering Alpine ParentWenpatb: Tie on MD: 3F-19 4224.50 Calculation Method: Minimum Curvature ErrorSy.¡tem rSCWSA Scan Method: TtuvCylinderN;¡rth ErrorSulfaçe: E16ptkal+Casing WamingMethod: Rules &sed Rig: Ref. Datum JF-19A 84.50ft V.Section Origin Origin Starting ,,,,. +NI-S +E/-W FromTVD 352270" 000 000 84.50 o o 3F-19 (3F-I 9) Travelling Cylinder Azimuth (TFO+ AZI) [deg] vs Centre to Centre Separation [100ft/in] 3F-19A (wp05) Approved Plan -48 -24 o 270 24 48 180 SECTION DETAILS Sec MD Ine M TVD +N/-S +£I-W DLeg TF.ace 0.00 4.00 0.00 4J){} 4.00 0.00 4.00 4.00 0.00 4.00 0.00 0.00 VSec Targe! I 2 3 4 5 6 7 8 9 10 II 12 3F- !9A Tg1 C4 3F-J9A TgtCI Travelling Cylinder Azimuth (TFO+ AZI) [deg] vs Centre to Centre Separation [ft] 0.7 20.0 15.0 10.0 -5.0 ~O 27 5.0 --10.0 15.0 ~20.0 0.7 84.50H OJ}(} 30.30 18a- . Travelling Cylinder Azimuth (TFO+AZI) [deg] vs Centre to Centre Separation [10ft/in] ToMD 300 400 500 750 1000 1250 1500 1750 2000 2500 3000 3500 4000 4500 5000 5500 6500 7500 8500 9500 10000 10500 11000 Il000 13000 SITE DETAILS FIELD DETAILS Kuparuk 3F Pad Site Centre Northing: 5985ß4,460 Easting: 508662.330 Water Depth: 0,00 Positional,IJl1certainty: 0.00 Convergence: 0.066 Kupamk Rivet Unit Nortb Slope Alaska United States Geodetic System: US State PI~"e Coordinate ""stem 1927 EUij)$oíd: NAD27 (Clarke 1866) , Zone: AI~ska, l.one 4 Magnetic Model: BGGM2002 WELL mCI'A1LS System Datum:: lVIßíill Se} Level l./oeal North: True North Name- +N/-S +EI-W Northing Ems:t~l1g Latitude Lonb>Ítude Slot " ~ ; :¡: ~ j W('sIHIJÚ¡sl{+) (U)ofif{/inj SEC'flON IIETAfLS See MO 1m.' A:tl TVO +N/~S +EI-W DLeg l'li'ace VSec T:iR:rget 1 4224,50 45.064 3380.12 2271.24 -49.28 0.00 0.000 2 4350.18 45.986 3468.23 2359.80 -62.69 4.00 -81.877 3 7354.53 45.986 5555.75 4472.89 -513.48 0.00 0.000 4501.31 4 7777.39 31.924 5884.50 4722.82 '596,98 4.00 -151.555 4760.20 :~ll·· -1% Tgt C4 5 7777.41 31.924 5884.51 4722.83 -596.98 4.00 -34.970 4760.21 6 7841.87 31.924 5939,23 4753.14 -612.58 0.00 0.000 4792.34 7 7843.37 31.875 5940,50 4753.84 ·612.94 4.00 145Æ1 479:~.09 :'1"·1% Tgt Cl 8 7845.63 31.959 5942.42 4754.91 ·613.49 4.00 21.550 4794.21 9 7962.'-' 31.959 6041.77 4810.00 -641.73 0.00 0.000 4852,69 10 7988.21 .H.lU3 6063.50 4821.89 -647.87 4.00 -158.503 4865.21 Tgt A3 n 8025.55 31.013 6095.50 4838.90 -656.85 0.00 0.000 4883.28 Tgt A2 12 8242.57 3J.013 6281.50 4937.78 -709.06 0.00 0.000 4988.28 iOO ~ ~ ~ g 600 FIELD DETAILS Kuparuk River Unit North Slope Alasl<a United Staws "'II_ hi Geodetic System: US State- Plane Coordinate System 1927 Ellipsoid: NAD27 (Clarke 1866) Zone: Alaska, Zone 4 Magnetic Model: BGGM2002 SITE DETAILS Syst.e,m Datum: Mean Sea Leve,} LOéal North: True North Kuparnk 3F Pad Siw Centre Nortlúng: 5985734.460 Easting: 508662.330 Water Depth: 0.00 Position"i Uncertainty: OJ!O Convergenc€: 0.066 WELL DETAILS Name +N/·S +E/·W Northing Easting Latitude Longitude Slot 3F·19 126.20 ·286.01 5985860.320 508376.200 7{P22i21.322N 149°55'54.918W N/A 5721.50 5813.50 5880.50 5884.50 5940.50 6063.50 6095.50 6181.50 7843.37 c1 7988.21 a3 8025.55 a2 8125.89 Miluveach I 600/} 8000 1:21)01} ~6000 ·4000 ·2000 201)1} 41}0fI 10000 SECTION DETAILS Vertkal Seetjuu- at 352.27" [2ßOOftJin} Se.('. MD Ine AÛ TVD +NI·S +E/·W DLeg TFae< VSec Target 1 4224.50 45.064 354.886 3380.12 2271.24 ·49.28 0.00 0.000 2257.23 2 4350.18 45.986 347.957 3468.23 2359.80 ·62.69 4.00 ·81.877 2346.79 3 7354.53 45.986 347.957 5555.75 4472.89 ·513.48 0.00 0.000 4501.31 4 7777.39 31.924 332.765 5884.50 4722.82 ·596.98 4.00 ·151.555 4760.20 3F·19A TgtC4 5 7777.41 31.924 332.764 5884.51 4722.83 ·596.98 4.00 ·34.970 4760.21 6 7841.87 31.924 332.764 5939.23 4753.14 ·612.58 0.00 0.000 4792.34 7 7843.37 31.875 332.829 5940.50 4753.84 ·612.94 4.00 145.031 4793.09 3F·19A TgtC1 8 7845.63 31.959 332.892 5942.42 4754.91 ·613.49 4.00 21.550 4794.21 9 7962.73 31.959 332.892 6041.77 4810.68 ·641.73 0.00 0.660 4852.69 10 7988.21 3L613 332.167 6063.56 4821.89 ·647.87 4.66 -158.503 4865.21 3F-19A TgtA3 11 8025.55 31Æ3 332.167 6695.56 4838.90 ·656.85 0.00 6.1)01) 4883.28 3F·19A Tgt A2 12 8242.57 31.013 332.167 6281.50 4937.78 ·769.06 0.00 ¡W06 4988.28 ttalliburton Sperry-sun· Planning Report !!&p&!I.....,.,y...SU"I ql'tlL..LINØ Sè¡AVIè:&~ .. nllt-uøu,,"b:'; QIWØ<.,,,,,- Field: Kuparuk River Unit North Slope Alaska United States Map System: US State Plane Coordinate System 1927 Geo Datum: NAD27 (Clarke 1866) Sys Datum: Mean Sea Level Map Zone: Coordinate System: Geomaguetic Model: Alaska, Zone 4 Well Centre BGGM2002 Site: Kuparuk 3F Pad Site Position: Northing: 5985734.460 ft Latitude: 70 22 20.081 N From: Map Easting: 508662.330 ft Lougitude: 149 55 46.550 W Position Uncertainty: 0.00 It North Reference: True Grouud Level: 0.00 ft Grid Convergence: 0.07 deg Well: 3F-19 Slot Name: Surface Position: +N/-S 126.20 ft Northing: 5985860.320 It Latitude: 70 22 21.322 N +EI-W -286.01 ft Easting : 508376.200 It Lougitude: 149 55 54.918 W Position Uncertainty: 0.00 ft Reference Point: +NI-S 126.20 ft Northing: 5985860.320 ft Latitude: 70 22 21.322 N +EI-W -286.D1 ft Easting : 508376.200 ft Longitude: 149 55 54.918 W Measured Depth: 84.50 ft Inclination: 0.000 deg Vertical Depth: 84.50 ft Azimuth: 0.000 deg Wellpath: 3F-19A Drilled From: 3F-19 Tie-on Depth: 4224.50 ft Current Datum: 3F-19A Height 84.50 ft Above System Datum: Mean Sea Level Magnetic Data: 1/6/2004 Declination: 25.00 deg Field Strength: 57496 nT Mag Dip Angle: 80.74 deg Vertical Section: Depth From (TVD) +N/-S +EI-W Direction ft ft ft deg 84.50 0.00 0.00 352.270 PIan: 3F-19A (wp05) Date Composed: 1/6/2004 Version: 18 Principal: Yes Tied-to: From: Delinitive Path PIan Section Information 4224.50 45.064 354.886 3380.12 2271.27 -49.52 0.00 0.00 0.00 0.00 4350.08 45.985 347.963 3468.16 2359.76 -62.90 4.00 0.73 -5.51 -81.88 7354.44 45.985 347.963 5555.72 4472.87 -513.49 0.00 0.00 0.00 0.00 7777.33 31.924 332.765 5884.50 4722.82 -596.98 4.00 -3.33 -3.59 -151.55 3F-19A Tgt C4 7777.35 31.924 332.764 5884.51 4722.83 -596.98 4.00 3.28 -4.34 -34.97 7841.81 31.924 332.764 5939.23 4753.14 -612.58 0.00 0.00 0.00 0.00 7843.31 31.875 332.829 5940.50 4753.84 -612.94 4.00 -3.28 4.34 145.03 3F-19A Tgt C1 7845.57 31.959 332.892 5942.42 4754.91 -613.49 4.00 3.72 2.78 21.55 7962.67 31.959 332.892 6041.77 4810.08 -641.73 0.00 0.00 0.00 0.00 7988.15 31.013 332.167 6063.50 4821.89 -647.87 4.00 -3.71 -2.84 -158.50 3F-19A TgtA3 8025.49 31.013 332.167 6095.50 4838.90 -656.85 0.00 0.00 0.00 0.00 3F-19ATgtA2 8242.51 31.013 332.167 6281.50 4937.78 -709.06 0.00 0.00 0.00 0.00 Survey SHL 37'FSL & 124'FEL; S 7 5/8" Csg @ 3975'MD Sidetrack @ 422$' MD, MWD MWD 4350.18 45.985 347.963 3468.23 2359.83 -62.92 2346.85 0.00 0.00 0.00 Begin Hold @ 4350' MD, 4 4400.00 45.985 347.963 3502.84 2394.87 -70.39 2382.58 0.00 0.00 0.00 MWD ORIGINAL ~alliburton Sperry-Sun· Planning Report &pIIf""I""y..SU"1 ~lU~I"ING Sl!I!l'IVlces II. nUII.~tII'".'M (~...... 4500.00 45.985 347.963 3572.33 2465.21 -85.39 2454.29 0.00 0.00 0.00 MWD 4600.00 45.985 347.963 3641.81 2535.54 -100.39 2526.00 0.00 0.00 0.00 MWD 4700.00 45.985 347.963 3711.30 2605.88 -115.38 2597.72 0.00 0.00 0.00 MWD 4800.00 45.985 347.963 3780.78 2676.21 -130.38 2669.43 0.00 0.00 0.00 MWD 4900.00 45.985 347.963 3850.27 2746.55 -145.38 2741.14 0.00 0.00 0.00 MWD 5000.00 45.985 347.963 3919.75 2816.88 -160.38 2812.86 0.00 0.00 0.00 MWD 5100.00 45.985 347.963 3989.24 2887.22 -175.37 2884.57 0.00 0.00 0.00 MWD 5200.00 45.985 347.963 4058.72 2957.55 -190.37 2956.28 0.00 0.00 0.00 MWD 5300.00 45.985 347.963 4128.20 3027.89 -205.37 3027.99 0.00 0.00 0.00 MWD 5400.00 45.985 347.963 4197.69 3098.22 -220.37 3099.71 0.00 0.00 0.00 MWD 5500.00 45.985 347.963 4267.17 3168.56 -235.36 3171.42 0.00 0.00 0.00 MWD 5600.00 45.985 347.963 4336.66 3238.89 -250.36 3243.13 0.00 0.00 0.00 MWD 5700.00 45.985 347.963 4406.14 3309.23 -265.36 3314.85 0.00 0.00 0.00 MWD 5800.00 45.985 347.963 4475.63 3379.56 -280.36 3386.56 0.00 0.00 0.00 MWD 5900.00 45.985 347.963 4545.11 3449.90 -295.36 3458.27 0.00 0.00 0.00 MWD 6000.00 45.985 347.963 4614.60 3520.23 -310.35 3529.98 0.00 0.00 0.00 MWD 6100.00 45.985 347.963 4684.08 3590.56 -325.35 3601.70 0.00 0.00 0.00 MWD 6200.00 45.985 347.963 4753.57 3660.90 -340.35 3673.41 0.00 0.00 0.00 MWD 6300.00 45.985 347.963 4823.05 3731.23 -355.35 3745.12 0.00 0.00 0.00 MWD 6400.00 45.985 347.963 4892.53 3801.57 -370.34 3816.84 0.00 0.00 0.00 MWD 6500.00 45.985 347.963 4962.02 3871.90 -385.34 3888.55 0.00 0.00 0.00 MWD 6600.00 45.985 347.963 5031.50 3942.24 -400.34 3960.26 0.00 0.00 0.00 MWD 6700.00 45.985 347.963 5100.99 4012.57 -415.34 4031.97 0.00 0.00 0.00 MWD 6800.00 45.985 347.963 5170.47 4082.91 -430.33 4103.69 0.00 0.00 0.00 MWD 6900.00 45.985 347.963 5239.96 4153.24 -445.33 4175.40 0.00 0.00 0.00 MWD 7000.00 45.985 347.963 5309.44 4223.58 -460.33 4247.11 0.00 0.00 0.00 MWD 7100.00 45.985 347.963 5378.93 4293.91 -475.33 4318.83 0.00 0.00 0.00 MWD 7200.00 45.985 347.963 5448.41 4364.25 -490.32 4390.54 0.00 0.00 0.00 MWD 7300.00 45.985 347.963 5517.89 4434.58 -505.32 4462.25 0.00 0.00 0.00 MWD 7354.44 45.985 347.963 5555.72 4472.87 -513.49 4501.29 0.00 0.00 0.00 MWD 7354.53 45.985 347.963 5555.78 4472.93 -513.50 4501.36 0.00 0.00 0.00 Begin Dir @ 7355'MD; 4°/1 7400.00 44.390 346.722 5587.83 4504.41 -520.56 4533.49 4.01 -3.51 -2.73 MWD 7500.00 40.939 343.733 5661.36 4569.93 -537.78 4600.73 4.00 -3.45 -2.99 MWD 7578.08 38.306 341.099 5721.50 4617.39 -552.79 4649.78 4.00 -3.37 -3.37 Upper Kalubik 7600.00 37.578 340.304 5738.79 4630.11 -557.24 4662.99 4.00 -3.32 -3.63 MWD 7692.43 34.573 336.643 5813.50 4680.74 -577.15 4715.83 4.00 -3.25 -3.96 Lower Kalubik 7700.00 34.332 336.319 5819.74 4684.66 -578.86 4719.95 4.00 -3.18 -4.28 MWD 7705.76 34.149 336.070 5824.50 4687.63 -580.16 4723.07 4.00 -3.17 -4.33 51/2" Csg PI @ 7706'MD 7772.61 32.068 332.995 5880.50 4720.60 -595.84 4757.84 4.00 -3.11 -4.60 d 7777.33 31.924 332.765 5884.50 4722.82 -596.98 4760.20 4.00 -3.05 -4.88 3F-19A Tgt C4 7777.39 31.924 332.764 5884.55 4722.85 -596.99 4760.23 1.15 0.94 -1.25 End Dir @ 7777' MD with 3 7800.00 31.924 332.764 5903.74 4733.48 -602.46 4771.50 0.00 0.00 0.00 MWD 7841.81 31.924 332.764 5939.23 4753.14 -612.58 4792.34 0.00 0.00 0.00 MWD 7843.31 31.875 332.829 5940.50 4753.84 -612.94 4793.09 4.00 -3.28 4.34 3F-19A Tgt C1 7845.57 31.959 332.892 5942.42 4754.91 -613.49 4794.21 4.00 3.72 2.78 MWD 7900.00 31.959 332.892 5988.60 4780.55 -626.62 4821.39 0.00 0.00 0.00 MWD 7962.67 31.959 332.892 6041.77 4810.08 -641.73 4852.69 0.00 0.00 0.00 MWD 7988.15 31.013 332.167 6063.50 4821.89 -647.87 4865.21 4.00 -3.71 -2.84 3F-19A Tgt A3· 8000.00 31.013 332.167 6073.65 4827.29 ·650.72 4870.95 0.00 0.00 0.00 MWD 8025.49 31.013 332.167 6095.50 4838.90 -656.85 4883.28 0.00 0.00 0.00 3F-19A Tgt A2. 8100.00 31.013 332.167 6159.36 4872.85 -674.78 4919.33 0.00 0.00 0.00 MWD 8125.83 31.013 332.167 6181.50 4884.62 -680.99 4931.83 0.00 0.00 0.00 Miluveach 8200.00 31.013 332.167 6245.06 4918.41 -698.83 4967.72 0.00 0.00 0.00 MWD ORIGINAL _ e Halliburton Sperry-Sun Planning Report !IpIIï.....y..s;u-1 DI'!'IL.I"ING S.AVIC:&lS !Õ.tuJí.tM'''''W''''~~''''' 3F-19A Tgt C4 5884.50 4722.82 -596.98 5990582.000 507773.999 70 23 7.770 N 149 56 12.394 W -Circle (Radius: 50) -Plan hit target 3F-19A Tgt C1 5940.50 4753.84 -612.94 5990613.000 507757.999 70 23 8.075 N 149 56 12.861 W -Circle (Radius: 50) -Plan hit target 3F-19A Tgt A3 6063.50 4821.89 -647.87 5990681.000 507722.999 70 23 8.744 N 149 56 13.884 W -Circle (Radius: 50) -Plan hit target 3F-19A TgtA2 6095.50 4838.90 -656.85 5990698.000 507713.999 70 23 8.911 N 149 56 14.147 W -Circle (Radius: 50) -Plan hit target Casing Points 7578.08 5721.50 Upper Kalubik 0.000 0.000 7692.43 5813.50 Lower Kalubik 0.000 0.000 7772.61 5880.50 d 0.000 0.000 7777.33 5884.50 c4 0.000 0.000 7843.31 5940.50 c1 0.000 0.000 7988.15 6063.50 a3 0.000 0.000 8025.49 6095.50 a2 0.000 0.000 8125.83 6181.50 Miluveach 0.000 0.000 Annotation 4224.50 3380.12 Sidetrack @ 4225' MD, Begin 4°/1001t 4350.18 3468.23 Begin Hold @ 4350' MD, 46° inc 7354.53 5555.78 Begin Dir @ 7355'MD; 4°/100' 7777.39 5884.55 End Dir @ 7777' MD with 32° inc through targets 84.50 84.50 SHL37'FSL& 124'FEL; Sec19-T12N-R9E 7777.33 5884.50 TGT C4 520'FNL & 704'FEL; Sec19-T12N-R9E 7988.15 6063.50 TGT A2 ...404'FNL & 763'FEL; Sec19-T12N-R9E 8242.57 0.00 TD... 302'FNL & 816'FEL; Sec19-T12N-R9E OR\G\NAL ANTI-COLLISION SETTINGS L/t!illJde LN1&ìUldt ToMD 300 400 500 750 IOOO 1250 48 72 96 IOO Se<..~ MD 1nç SECTION DErAILS +FJ·W 3F·!9A TgtC! Azi TVD VSe,c Target 1 o 3 .¡ 5 6 7 8 9 to 11 12 3P·!9A TgtC4 Trave1ling Cy1ìnder Azimuth (TFO+AZIJ [deg] vs Centre to Centre Separation [ft j ~15.0 ~lO.O -5.0 0 27( "5.0 ~lO.O l'" ~. , .' 20.0 20.7 (wpOS) 3F·j9A 3F·19 4224.50 Rtf. D¡¡~~~; :·,p·19A 84.S0ft ùricifJ rNï:.S 0.00 +°Éi~t ~~~~¥VD 0.00 3030 18\; . Trave1ling Cylinder Azimuth (TFO+AZI) [degj vs Centre to Centr" Separll!iolJ [lOt1Iin] -- lIalliburton Sperry-Sun Anticollision Report ~Y-&U"'I DRIL.I"ING S¡SAVIC:I!IS ~ "Ui.~.1i':'~ «N!Ii',\,,'" ORIGINAL 'alliburton Sperry-Sun · GeoReport liip&!r....,y..!5U"'1 Dllfll...LíNG ~EAVléES ..nu.¡~'Ið'~{1j~''';''· Company: Engineer: Tool: Tied-to: Survey 84.50 0.000 0.000 84.50 0.00 0.00 0.00 5985860.320 508376.200 SHL 37'FSL & 124'FEL; Sec 3974.50 44.685 357.085 3202.80 3118.30 2095.46 -37.50 5987955.531 508336.354 75/8" Csg @ 3975'MD /4224.50 45.064 354.886 3380.12 3295.62 2271.27 -49.52 5988131.308 508324.147 Sidetrack @ 4225' MD, Begi 4300.00 45.568 350.697 3433.23 3348.73 2324.50 -56.26 5988184.526 508317.347 4350.08 45.985 347.963 3468.16 3383.66 2359.76 -62.90 5988219.775 508310.662 4350.18 45.985 347.963 3468.23 3383.73 2359.83 -62.92 5988219.846 508310.646 Begin Hold @ 4350' MD, 46° 4400.00 45.985 347.963 3502.84 3418.34 2394.87 -70.39 5988254.875 508303.136 4500.00 45.985 347.963 3572.33 3487.83 2465.21 -85.39 5988325.186 508288.061 4600.00 45.985 347.963 3641.81 3557.31 2535.54 -100.39 5988395.496 508272.986 4700.00 45.985 347.963 3711.30 3626.80 2605.88 -115.38 5988465.807 508257.912 4800.00 45.985 347.963 3780.78 3696.28 2676.21 -130.38 5988536.118 508242.837 4900.00 45.985 347.963 3850.27 3765.77 2746.55 -145.38 5988606.429 508227.762 5000.00 45.985 347.963 3919.75 3835.25 2816.88 -160.38 5988676.740 508212.687 5100.00 45.985 347.963 3989.24 3904.74 2887.22 -175.37 5988747.051 508197.612 5200.00 45.985 347.963 4058.72 3974.22 2957.55 -190.37 5988817.362 508182.537 5300.00 45.985 347.963 4128.20 4043.70 3027.89 -205.37 5988887.672 508167.463 5400.00 45.985 347.963 4197.69 4113.19 3098.22 -220.37 5988957.983 508152.388 5500.00 45.985 347.963 4267.17 4182.67 3168.56 -235.36 5989028.294 508137.313 5600.00 45.985 347.963 4336.66 4252.16 3238.89 -250.36 5989098.605 508122.238 5700.00 45.985 347.963 4406.14 4321.64 3309.23 -265.36 5989168.916 508107.163 5800.00 45.985 347.963 4475.63 4391.13 3379.56 -280.36 5989239.227 508092.088 5900.00 45.985 347.963 4545.11 4460.61 3449.90 -295.36 5989309.538 508077.014 6000.00 45.985 347.963 4614.60 4530.10 3520.23 -310.35 5989379.849 508061.939 6100.00 45.985 347.963 4684.08 4599.58 3590.56 -325.35 5989450.159 508046.864 6200.00 45.985 347.963 4753.57 4669.07 3660.90 -340.35 5989520.470 508031.789 6300.00 45.985 347.963 4823.05 4738.55 3731.23 -355.35 5989590.781 508016.714 6400.00 45.985 347.963 4892.53 4808.03 3801.57 -370.34 5989661.092 508001.639 6500.00 45.985 347.963 4962.02 4877.52 3871.90 -385.34 5989731.403 507986.564 6600.00 45.985 347.963 5031.50 4947.00 3942.24 -400.34 5989801.714 507971.490 6700.00 45.985 347.963 5100.99 5016.49 4012.57 -415.34 5989872.025 507956.415 6800.00 45.985 347.963 5170.47 5085.97 4082.91 -430.33 5989942.335 507941.340 6900.00 45.985 347.963 5239.96 5155.46 4153.24 -445.33 5990012.646 507926.265 7000.00 45.985 347.963 5309.44 5224.94 4223.58 -460.33 5990082.957 507911.190 7100.00 45.985 347.963 5378.93 5294.43 4293.91 -475.33 5990153.268 507896.115 7200.00 45.985 347.963 5448.41 5363.91 4364.25 -490.32 5990223.579 507881.041 7300.00 45.985 347.963 5517.89 5433.39 4434.58 -505.32 5990293.890 507865.966 7354.44 45.985 347.963 5555.72 5471.22 4472.87 -513.49 5990332.168 507857.759 7354.53 45.985 347.963 5555.78 5471.28 4472.93 -513.50 5990332.230 507857.745 Begin Dir @ 7355'MD; 4°/10 7400.00 44.390 346.722 5587.83 5503.33 4504.41 -520.56 5990363.690 507850.647 7500.00 40.939 343.733 5661.36 5576.86 4569.93 -537.78 5990429.184 507833.358 7578.08 38.306 341.099 5721.50 5637.00 4617.39 -552.79 5990476.624 507818.299 Upper Kalubik 7600.00 37.578 340.304 5738.79 5654.29 4630.11 -557.24 5990489.340 507813.830 7692.43 34.573 336.643 5813.50 5729.00 4680.74 -577.15 5990539.944 507793.872 Lower Kalubik 7700.00 34.332 336.319 5819.74 5735.24 4684.66 -578.86 5990543.865 507792.160 7705.76 34.149 336.070 5824.50 5740.00 4687.63 -580.16 5990546.829 507790.848 51/2" Csg Pt @ 7706'MD 7772.61 32.068 332.995 5880.50 5796.00 4720.60 -595.84 5990579.777 507775.141 d 7777.33 31.924 332.765 5884.50 5800.00 4722.82 -596.98 5990582.000 507773.999 3F-19A Tgt C4 7777.39 31.924 332.764 5884.55 5800.05 4722.85 -596.99 5990582.028 507773.985 End Dir @ 7777' MD with 32 7800.00 31.924 332.764 5903.74 5819.24 4733.48 -602.46 5990592.651 507768.501 ORIGINAL 'alliburton Sperry-Sun· GeoReport lSpEIr'......y..SiiLn DRII-I.IMB S&FlVIC:ES ~ n.\UJ.~JI)'M ¡;~"'''' 7841.81 31.924 332.764 5939.23 5854.73 4753.14 -612.58 5990612.295 507758.362 7843.31 31.875 332.829 5940.50 5856.00 4753.84 -612.94 5990613.000 507757.999 3F-19A Tgt C1 7845.57 31.959 332.892 5942.42 5857.92 4754.91 -613.49 5990614.062 507757.453 7900.00 31.959 332.892 5988.60 5904.10 4780.55 -626.62 5990639.691 507744.297 7962.67 31.959 332.892 6041.77 5957.27 4810.08 -641.73 5990669.201 507729.149 7988.15 31.013 332.167 6063.50 5979.00 4821.89 -647.87 5990681.000 507722.999 3F-19A TgtA3 8000.00 31.013 332.167 6073.65 5989.15 4827.29 -650.72 5990686.394 507720.143 8025.49 31.013 332.167 6095.50 6011.00 4838.90 -656.85 5990698.000 507713.999 3F-19A Tgt A2 8100.00 31.013 332.167 6159.36 6074.86 4872.85 -674.78 5990731.925 507696.039 8125.83 31.013 332.167 6181.50 6097.00 4884.62 -680.99 5990743.687 507689.812 Miluveach 8200.00 31.013 332.167 6245.06 6160.56 4918.41 -698.83 5990777 .456 507671.934 /8242.51 31.013 332.167 6281.50 /6197.00 4937.78 -709.06 5990796.812 507661.687 Wellpath: 3F-19A Drilled From: 3F-19 Tie-on Depth: 4224.50 11 Current Datum: 3F-19A Height 84.50 It Above System Datum: Mean Sea Level Magnetic Data: 1/6/2004 Declination: 25.00 deg Field Strength: 57496 uT Mag Dip Angle: 80.74 deg Vertical Section: Depth From (TVD) +N/-S +EI-W Direction It It It deg 84.50 0.00 0.00 352.270 Targets 3F-19A Tgt C4 5884.50 4722.82 -596.98 5990582.000 507773.999 70 23 7.770 N 149 56 12.394 W -Circle (Radius: 50) -Plan hi11arget 3F-19A Tgt C1 5940.50 4753.84 -612.94 5990613.000 507757.999 70 23 8.075 N 149 56 12.861 W -Circle (Radius: 50) -Plan hit targe1 3F-19A Tgt A3 6063.50 4821.89 -647.87 5990681.000 507722.999 70 23 8.744 N 149 56 13.884 W -Circle (Radius: 50) -Plan hit targe1 3F-19A Tgt A2 6095.50 4838.90 -656.85 5990698.000 507713.999 70 23 8.911 N 149 56 14.147 W -Circle (Radius: 50) -Plan hit target Annotation 4224.50 4350.18 7354.53 7777.39 84.50 7777.33 7988.15 8242.57 3380.12 3468.23 5555.78 5884.55 84.50 5884.50 6063.50 0.00 Sidetrack @ 4225' MO, Begin 4°/10011 Begin Hold @ 4350' MO, 46° inc Begin Dir @ 7355'MD; 4°/100' End Dir @ 7777' MO with 32° inc 1hrough targets SHL37'FSL& 124'FEL; Sec19-T12N-R9E TGT C4 520'FNL & 704'FEL; Sec19-T12N-R9E TGT A2 ...404'FNL & 763'FEL; Sec19-T12N-R9E TO... 302'FNL & 816'FEL; Sec19-T12N-R9E ORIGINAL e e Conversion Results For: 3F-19A Surface Location ASP Zone 4: 508376.25985860.32 i/ 70.37258941 149.93192155 UTM Zone 6 X=390117.515945 Y=7809899.048512 Meridian: U T12N R9E Section 19 5242.87FNL 37. 13FSL" 123.68FEL 4715.85FWL 70 deg 22 min 21.322 see 149 deg 55 min 54.918 see Conversion Complete Conversion Results For: TGT C4 ASP Zone 4: 5077745990582 70.38549164 149.93677610 UTM Zone 6 X=390005.162757 Y=7811345.298762 Meridian: U T12N R9E Section 19 520.23FNL 4759.76FSL 703.92FEL 4115.90FWL 70 deg 23 min 7.770 see 149 deg 56 min 12.394 see Conversion Complete ORIGINAL e e Conversion Results For: TGT A2 ASP Zone 4: 5077145990698 70.38580875 149.93726309 UTM Zone 6 X=389988.642797 Y=7811381.508838 Meridian: U T12N R9E Section 19 404. 17FNL 4875.83FSL 763.38FEL 4055.95FWL 70 deg 23 min 8.911 see 149 deg 56 min 14.147 see Conversion Complete Conversion Results For: TD ASP Zone 4: 507661.11 5990800.25 70.38608826 149.93769238 UTM Zone 6 X=389974.080395 Y=7811413.426805 Meridian: U T12N R9E Section 19 /301.87FNL 4978. 13FSL 815.80FEL 4003.11FWL 70 deg 23 min 9.918 see 149 deg 56 min 15.693 see Conversion Complete ORIGINAL 3F-19A ~ro" .,:== Formatio n X Y Poros~v Perm i Net Pov Anole 19 22() :;" ¡)"i 2" )2'3 )74 )0 21 19 ~ ,':;:;;:, ,&:t:; ª,qel2 Preferred Formatio Z Tar. n X y rVD.SS Porositv Perm Net Pav Annie -- ~ ,,:;:::~, .'gel 3 Preferred. Formatio Z Tar. n X Y TVD~SS PQrosit.v Perm Net Pav Ano'e ~= ==~ -..- a .~~. ; Respüfl$ib!e; Mark Scheìhing ~ 60 Y ~ () ~ 0 Ü D I 715 I !,B'" II?A 10,,", GrHifH n 'HAl -D 1Giro 0 2!i1 0 so Ü\,"Bdl om, - F Responsjble: .. Crn~¡¡re!j e e 8 1 . 11" 5,000 PSI Single Hydril Type V with Pipe rams, 3 Ys" 5,000 PSI side outlets and manual locks 2. 11" 5,000 PSI Drilling spool with 2 eo 3" 5,000 PSI flanged outlets. 3. 3" 5,000 PSI Hydraulic Gate 7 Valve " ü 4. 3" 5,000 PSI Manual Gate f) 0 Valve 3 4 6 5. 3" 5,000 PSI Manual Gate 5 Valve 0 2 0 6. 3" 5,000 PSI Manual Gate ø Valve 0 Choke Line Kill Line 7. 11" 5,000 PSI Double Shaffer SL with Pipe rams on top and " blind rams on bottom, 3 Ys" " 5,000 PSI side outlets with 0 manual locks " 8. 11" 5,000 PSI Hydril GK annular preventer 1MII~-.ø.1D_CllUl'l'AtarVlDEln""'.ICIPTCCN'ØDI11IIL_ _ 'aIICI.I: .. f'M'TIM. ua: .. -..utATDiI rat ,.,... øna _ TMIIE ...... ... _ CM.DTA ..-vICa D ~y ........ vmarr ..... \/IIIT11:N ~ CI" __ CM.ØTA IÞVaI CAD rILE Cl/rlLE Dertel Ðec,f'Ibe" 30, 2003 FDRMAT-At: \VELL CONTROL N° NOR20031230-001 Rig#3 Nordk:-Cahto SI..wc. :.=~.=-..... 1 11' BOP STACK (007) .., 7... a-rra-ngeMent MJT ~CAlE U.C~EE DRA\VING NUMBER 1/1 r' s s- " 1611 DIV~TER SCHEMATIC - f1rdic Rig 3 6 ___9!?~Il._+ I I r------Þ- To Accumulator I Closed ,'"1... ..______...1 : '--À I I f I 1 : From ~ - - -. Accumulator I I I I J I I Closed f I I t __:t : : Open ._----~ Maintenance & ODeratiof) -1_ I 3(; - . G~ ". t 65' .v -L 'v 4 1. Upon initial installation: - Close v~lve and fill preventer with water to ensure no leaks - Close preventer to verify operation and that the valve opens immediately 2. Close annular preventer in the event that an influx of wellbore fluids or gas is detected. Open valve to achieve diversion 2 DO NOT SHUT-IN DIVERTER AND VALVE AT SAME TIME UNDER ANY CIRCUMSTANCES 1 1. 16" Conductor 2. 16-3/4~ 2000 psi Slip-on Weld Starting Head (Quick Connect) 3. 16-3/4" x 21 -'/4· 2000 psi, Double-Studded Adapter Flange 4. 16- Diverter Spool with API 21-1/4" 2000 psi Flanges 5. 21-1/4" x 13-5/8" 5000 psi, Double Studded Adapter Flange 6. 13-5/8" Hydril GK 5000 psi Annular Preventer. c ~ a\ II... H'fdl.\ M!)(»;)..G'C·() ,,:..":¡: AM\A.\c.:..A. 7. 16~ Knife Valve. The valve opens automatically upon closure of annular preventer. 8. 16" Diverter Line ,..6\~; "::t'\E:¡io.,\'s:it \ ¡":t 'S....~p\;eJ. ~1 o~~'>.:\.\<:c... ORIGINAL 3 2 e 4 5 e 1. 16 %" x 21 ~" 2,000 PSI, double studded adapter flange 2. 16" Diverter spool with 21 ~" API 2,000 PSI flanges 3. 21~" Hydril MSP 2,000 PSI Annular preventer 4. 16" Knife valve 5. 16" Diverter line 'nØ IIICUImff ___ 1'U IIIIInE CM.BTA IØYIIZI " ...,. . Ia'T ~ ,.. N#I \IICI..I: .. I"IIIiImIIL '* .. ..ucATDiI rut ...-ala anD _ ,..... XfØMfCI .... .... CoII&.DTA IDYICD IS ~y ........ \IIftGIt ,... var1IN ~ IF "-"::~AIOYICI:I CAD rILE CI/F'ILE Do.tl' hCIPlbeI"' 301 2003 F'ORHAT-AS \.IELL CONTROL N° NOR20031230-003 Rig#3 Nordlc-can.to SeMen 4700 bin... park blvd, auite 1 _..... 00!503 (007) .., 7408 16' Diverter o.rro.ngeMent tÐT ~CAlE U.C::EE DRA \.lING NUMBER 1/1 1111 500fPSi BOP Stack -- Nor~ Rig 3 1. 2. 7 3. 4. Accumulator Capacítv Test Check and fill accumulator reservoir to proper level with hydrauiic fluid. Assure that accumulator pressure is 3000 psi with 1500 psi downstream of the regulator. Observe time, then close all units simultaneously and record the time and pressure remaining after all units are closed with the charging pump off. Record on the IADC report. The acceptable lower limit is 45 seconds closing time and 1200 psi remaining pressure. BOP Stack Test 1. Fill BOP stack and manifold with water. 2. Check that all hold-down screws are fully retracted. Predetermine depth that test plug will seat and seat in wellhead. Run in lock-down screws in head. 3. Close annular preventer, chokes, and bypass valves on the manifold. All others open. 4. Test all components to 250 psi and hold for 3 minutes. Increase pressure to 3000 psi and hold for 3 minutes. Bleed back to zero psi. 5. Open annular preventer and manual kill and choke line valves. 6. Close top pipe rams and HCR valves on kill and choke lines 7. Test to 250 psi and 3000 psi as in step 4. Continue testing all valves, lines, and chokes with a 250 psi low and 3000 psi high. Test as in step 4. Do not pressure test any choke that is not a full closing positive seal choke. a. Open top pipe rams and close bottom pipe rams. Test bottom rams to 250 psi and 3000 psi for 3 minutes. 9'. Open pipe rams. Back off running joint and pull out of hole. Close blind rams and test to 250 low and 3000 psi high for 3 minutes. Bleed to zero psi. 10. Open blind rams and recover test plug. Make sure manifold and lines are full of arctic diesel and all valves are set in the drilling position. 11. Test standpipe valves to 3000 psi for 3 minutes. 12. Test kelly cocks and inside BOP to 3000 psi with BOP test pump. 13. Record test information on blowout preventer test form. Sign and send to drilling supervisor. 14. Perform BOPE test once per week and functionally operate BOPE daily. 1. 2. 3. 4. 5. ~ 6. 7. 16" Starting Head :J- C' - \ 11" 5000 psi Horizontal Tubing Head (!)~R ~? ~ e.á 11" 5000 psi Double Flange AdapterlSpacer Spool 11" 5000 psi Hydril Type V Single Pipe Rams. 3-1/8" 5000 psi Side Outlets wi manual locks 11" 5000 psi Drilling Spool with Choke and Kill Unes. 2 Choke valves - one 3" 5000 psi Hydraulic gate and one 3" 5000 psi Manual gate. 2 Kill vaíves - each are 3" 5000 psi gate 11" 5000 PSi~ouble Ram with Pipe Rams on Top and Blind Rams on "S'~Fi?..e. tJl.9'& ~ . Bottom, 3-1/Š~eOutlets wi Manual Locks 11" 5000 psi Hydril Annular Preventer ORIGINAL () KRU 3F...19A Proposed Prod Injection Post Office Box 100360 Anchorage, Alaska 99510-0360 Randy Thomas Phone (907) 265-6830 Fax: (907) 265-1535 Email: rlthomas@ppco.com RECEIVED JAN 1 6 2004 1-tM 5i11l e"1 S. .f\fVl.Tz. pob ç::. Sìt;Ve tY1 conOC~iUiPS e Alaska Oil & Gas Cons. Commission Anchorage January 16, 2004 Sarah Palin, Chair Alaska Oil and Gas Conservation Commission 333 West 7'h Avenue Suite 100 Anchorage, Alaska 99501 (907) 279-1433 \:70~-O\ G Re: Application for Spacing Exception, producer sidetrack 3F-19A Dear Commissioner Palin: ConocoPhillips Alaska, Inc. hereby applies for a Spacing Exception an onshore production well, KRU 3F- 19A, a development well. The proposed 3F-19A is designed as an infill Kuparuk A and C sand producer. This new well will recover A and C Sand waterflood and enhanced oil recovery (EOR) reserves that are located in a fault isolated area. Combined incremental Kuparuk A and C Sand reserves are 1.79 MMSTBO, where 129 MSTBO are incremental EOR recovery. The waterflood and EOR reserves cannot be recovered until we add an active producing well to the well pattern configuration. The requested exception refers to the well spacing requirements specified in Rule 3 of Conservation Order 432B, which states: "Not more than one well may be drilled on any governmental quarter section...", because the prospective pay interval in 3F-19A will lie within the NE 1/4 of Section 19, T 12N, R9E, U.M., and that 3F-19A will be the second well drilled within that particular quarter section (the other well being the existing 3F-13A production well). Property line considerations do not apply, as the 3F-19A well bore will be in the main portion of the Kuparuk River Unit, and therefore will be more than 500 feet from a property line where ownership or landownership changes. Offset well distance requirements do no apply because the 3F-19A well bore will lie more than 1000 feet from other wells completed within the pool. The 3F-19A sidetrack targets Section 19, T12N, R9E in order to potentially produce unswept A-sand oil on the Westside of the injection pattern. We believe A-sand oil is trapped against a north-south trending fault located on the west side of the injection pattern. Adjusting the directional profile to move the productive interval completely out of the northeast quarter of Section 19, T12N, R9E will compromise the original purpose of drilling this infill producer. Moving the contacted productive interval into either Section 18 (to the north) or Section 20 (to the east) will cause the well to potentially intercept mapped fault zones in those areas, resulting in faulted out pay intervals and/or loss of pressure support from 3F-20 due to fault isolation. Even though we will run the completion prior to rig release, we do not intend to produce or test the well until we receive the spacing exception. Please find attached for the review of the Commission the information required by 20 AAC 25.055 (d). We have included a plat showing the location of 3F-19A, all other completed and drilling wells on the property, and all adjoining wells within 1,000 feet. Also included is a copy of the notices sent by certified mail to our co-owners and the affidavit verifying that all facts are true. If you have any questions or require any further information, please contact Kelly McLure at 265-6059. Sincerely, ~~~ Randy Thomas GKA Drilling Team Leader e tit CHECKLIST - SPACING EXCEPTION APPLICATION OPERATOR ConocoPhillips Alaska PROPERTY ID/ LEASE S: ADL 2565 Inc Kuparuk River/Kuparuk Oil PI/BH: ADL 2565 3F-19A FIELD/POOL WELL NAME VERTICAL EXPLORATORY GAS DEVIATED DELINEATION OIL X DEVELOPMENT X SURFACE LOCATION PRODUCTIVE INTERVALS (Top and Bottom) BOTTOM HOLE 37' FSL, 124' FEL, Sec 19, T12N, R9E, UM 520'FNL,704'FEL,Sec19,T12N,R9E,UM 377 FNL, 778 FEL Sec 19, T12N, R9E, UM 302' FNL, 816' FEL, Sec 19, T12N, R9E, UM Check applicable reason(s) for spacing exception per 20 AAC 25.055(a): (1) to drill a well for oil within 500 feet of a property line where ownership or landownership chan es, (2) to drill a well for gas within 1500 feet of a property line where ownership or landownershi chan es, X (3) to drill and complete more than one oil well in a governmental quarter section; or to drill and complete an oil well closer than 1000' to any well drilling to or ca able of roducin from the same 001, 4 to drill and com lete more than one as well in a overnmental section; or or to drill and complete a gas well closer than 3000' to any well drilling to or ca able of roducin from the same 001. Does the application contain: A brief ex lanation for wh the 0 erator has chosen to drill the s ecified location. A plat drawn to a scale of one inch equaling 2,640 feet or larger, showing the location of the well or portion of the well for which the exception is sought, all other completed and drilling wells on the property, and all adjoining properties and wells within 1,000 feet of a well or portion of the well requiring the spacing exception that is drilling for oil or within 3,000 feet of a well or portion of the well requiring the spacing exception that is drilling for as. The names of all owners, landowners, and operators of all properties within 1,000 feet of a well or portion of the well requiring the spacing exception that is drilling for oil or within 3,000 feet of a well or portion of the well requiring the spacing exception that is drilling for as. A copy of the notice sent by certified mail to the owners, landowners and operators described above, the date of mailin , and the addresses to which the notice was sent. An affidavit by a person acquainted with the facts verifying that all facts are true and that the lat correctl ortra s ertinent and re uired data. If the operator requests a variance from the notice requirements of 20AAC25.055(d), sufficient information to demonstrate that it is not feasible to comply with the notice re uirements because of the com lexit of ownershi within the notice area. 20000 FEET I 10000 I FEET 0 I 5000 METERS I e 2W-IO e 3B-04 3B-02 q000 I 1*q8000 2000 3000 , 1000 I METERS 0 I 3F-16A 3F-16 '+ 3A 03A 0~ Plat Scale 1" = 2640' Section 18 Section 19 Section 17 Section 20 e 3F -05 I q¡. 3F -06 I~ e Top C4 Sand in well METERS ø . Top A 1 Sand in well FEET I lØ¡Ø . 3F-19A bottom hole location ItSØØØ søø 2ØØØ 3ØØØ 4ØØØ søøø FEET I I I I e e Top C4 Sand in well . FEET ø 1 øøø 2ØØØ 3ØØØ 4ØØØ søøø FEET Top A 1 Sand in well I ,I I I I I . 3F-19A bottom hole location Faults ~ mapped at top Kuparuk e e AFFIDA VIT TO THE ALASKA OIL AND GAS CONSERVATION COMMISSION AFFIDAVIT OF KELLY A. MCLURE STATE OF ALASKA THIRD JUDICIAL DISTRICT I, Kelly A. McLure, declare and affirm as follows: 1. 1. My name is Kelly A. McLure. I am over 19 years old and have personal knowledge of the matters set forth herein. 2. 2. I am a Drilling Engineer for the well operator, ConocoPhillips Alaska, Inc. 3. 3. I am acquainted with the facts associated with the drilling of the 3F-19A well. 4. 4. I have reviewed the application submitted for the exception to 20 AAC 25.055 and all facts herein are true. 5. 5. I have reviewed the plat attached and it correctly portrays pertinent and required data. 16 1'}I DATED at Anchorage, Alaska this _ day of January, 2004. tJ1~ A.1f)~ Kel y A. McLure SUBSCRIBED AND AFFIRMED before me at Anchorage, Alaska this 2004. /6 rH day of January, t\IU£ a., ~\\\~"m..51/111¿ -# ~~~Y..~:e:k~ ~ ..'$ ~y:..~",,", ¡"'~'.~0<%r";;.~ :::$ .'t"T ~';"" -~ ~ ~ .., r~, I, A 1"<... ~....~ ~ ::: ~... ~v· .y J-. .~~ - := : <~ 11\ :: E, \. ~~; ~'~ } ; ~ 'rA'~"'~ SE~~\ fOil fiII:!r¡", -::~:.,~f *'...."'f£:1 t ~':!t.~.,.4:'~ ~ ~'...rCH'''' ,..\'. )..[ ~""A í'" .f,~1f~3.~~:: j <.1-'/)/" ~e OJ A\ '1'##,.. . .\..-. ~'-lljj£ j'~i\ '\ l//fl/l-- -- NOTARY PUBLIC tN AND FOR THE STATE OF ALASKA My commission expires íJ1 f)¡Z..e-/+ /2 / 2 ð t 6 / COn()(~illips . Post Office Box 100360 Anchorage, Alaska 99510-0360 Randy Thomas Phone (907) 265-6830 Fax: (907) 265-1535 Email: randy.l.thomas@conocophillips.com December 29, 2003 Alaska Oil and Gas Conservation Commission 333 West th Avenue Suite 1 00 Anchorage, Alaska 99501 (907) 279-1433 Re: Application for Permit to Drill, Rotary Sidetrack, Producer 3F-19A Dear Commissioner: ConocoPhillips Alaska, Inc. hereby applies for a Permit to Drill/Sidetrack an onshore Producer well, KRU 3F-19A, a development well. / Note: it is planned to abandon the original wellbore by setting a permanent castiroJi1 bridge plug in the 5.5" casing at 4375' MD and cutting and pulling the 5.5" casing from a depth of 4350' MD, just below the 7-5/8" casing shoe. A 500' cement plug will then be placed on top of the cast iron bridge plug with the top of cement inside the 7-5/8" casing (approximately 125'). The cement plug will then be used as a kick off plug for sidetracking the well bore to a new bottom hole location. The wellbore will be top set above the productive sands and then a 4-3/4" hole section will be drilled with a 3-1/2" liner run and cemented. The top of cement will be above the liner top. This well is to be completed as a 3-1/2" mono-bore producer. The liner portion of the mono-bore will be cemented top-to-bottom using a liner hãnger~---'~ Please find attached for the review of the Commission the information required by 20 ACC 25.005 (c). The spud date is expected to be approximately 02/01/04. If you have any questions or require any further information, please contact KellY McLure at 265-6059. Sincerely, ,---~ ----.l- _ ( ~~'" \.. ~ -~ Randy Thomas GKA Drilling Team Leader RECEIVED JAN 1 4 2004 Alaska Oil & Gas Cons. Commission Anchorage OR\G\NAL SHARON K. ALLSUP-DRAKE CONOCOPHILLlPS 3760 PERENOSA ANCHORAGE AK 99515 1019 { ;/i" ~. DATE 1'-7 j d /1. Vt!-i ZøÚ1h-4/311 ;\' PAY TO THE f o /1-c6c C ~/ . /;C¡;, $ /CO. CO ¡:::;, ,.,~"""",,. uuLLARS l!J ~::':::.,,,, > ~h ~... CHASE Cha.. Manhattan Bank USA. N.A. Valid Up T. 05000 Dollars . , . 1110 White Clay Center Dr.. Newark. or 19711.. '. .' ., . '. '. ¡ ,. ~/ I~//;"~ -.,,-'" ,- /. . . - ,. .'.0 ;> r 1'14 _~~I../i¿_l:h-_~;: 572__g__~ I: 0 :I * * 0 0 * ~ ~ I: 2 * a ~ 7 * q 0 7 q 2 7 bill * 0 * q RECEIVED JAN .1. 4 2004 Alaska ail & G as Cons C . Aflch . ornrmSSiOfl orage e e TRANSMlT AL LETTER CHECKLIST CIRCLE APPROPRJATELETTERlPARAGRAPHS TO BE INCLUDED IN TRANSMITTAL LETTER WELL NAME Kf?¿~ '3É- 1/ /l PTD# 2dI- ()/~ CHECK WBA T APPLIES ADD-ONS (OPTIONS) MULTI LATERAL (If API number last two (2) digits are between 60-69) Pn,OT (PH) "CLUE" The permit is for a new wellbore segment of existing well Permit No, API No. Production should continue to be reported as a function' of tbe original API number. stated above. HOLE In accordance with 20 AAC 25.005(f), all records, data and logs acquired for the pilot hole must be clearly differentiated in both name (name on permit plus PH) and API Dum ber (50 70/80) from records, data and logs acquired for wen (name on permit). SPACING J1:.XCEPTJ ON DRY DITCH SAMPLE Rev: 07/] 0/02 C\j ody\templates The permit is approved subject ,to full compliance with 20 AAC 25.055. Approval to perforate and produce is contingent upon issuance of a conservation or~er ap . a spacing . exception. G~ (C· u (Company Name) assumes tbe )jab ·ty oU-ny protest to tbe spacing . exception that may occur. All dry ditcb sample sets submitted to tbe Commission must be in no greatertban 30' sample intervals from below tbe permafrost or from wbere samples are first caught and 10' sample intervals tbrough target zones. 00 I /~;! r ~ Date ~ Geologic Commissioner: Engineering Commissioner: Date Public Commissioner SPACING EXCEPTION REQUIRED 35 36 37 38 39 _S~abed _condition survey CQntact name[ptloneJor we~~ly progress reports [exploratory 9nlyl No _y~s NA NA NA Appr SFD Date 1/15/2004 f _S~i$mic_analysjs_ Qf sbaJlow gas zones P~rmit _D_ata presented on_ potential overpressure _zones off-sh_ore) 3F'-19. mea_sured 58 ppm HZS on 12/25[OD~ 3F_- 13A_measured 15_0ppmH2s On j ZIZ5J03~ Otfs_et wells indicate pressure is '1 Z.3 ppg. EMW; will be drilled with 12,5_ppg rn_ud Geology Appr Date '~'612004 18 19 20 21 22 23 24 25 26 27 28 29 30 31 32 33 34 c_ao be issued wlo hydeogen s_ulfide meas_ures Js presence Qf MeçbanicaLcondjUon o{ H2S gas_ probable wells within f\OB yerified (for s_e(Vice well only) to _Choke_manifold cQmplies w/APJ RF'-53 (May 84) Work will occ_ur withoytoperation _sbutdo_wn _BOPEpress _BOPEs, do Jhey meet regulation ra_tiog appropriate; test (puJ psig in _comments) Kdiverter required, does it meet regulations_ _Drilliog flujd program sd1ematic& eC1-uip JistadeC1-uat~ l(are-drilL bas_a_ 10:403 for abandonme_nt Adequate wellbore separatjo_n _proposed be~n approved AdequateJankageor re_SeIYe pit CMTwill coyeraJl _C_asiog desigos adequa_te for CJ, B_&_permafwst koown _pro_ductiYe borizons _CMT v_ol adequate to tie-in long string to_surf ~g_ CMT v_oj adeQuate_ to cìrc_uJate_ o_ncond_uctor_ & su_rfcsg Yes NA Y_es No_ Yj'!s Y~s Yj'!s Y~s Yj'!s NA Yes Yj'!s Yj'!s Yes Yj'!s No NA Mud should pœclude_ H2S_ o_nJbe_ rig, Rjg. is eQujpped with sensors and _alarms. MAS!' cqlcuJate_dat 3388 psi, <40QOp_slappcopriate_. CP_AJ usuaUyJests to ~OOO_ps Sideteack of existing We Max expected_BHP 12.3 EMW._ Surface casiog in place. PJaonedMW '1 Z.3-1 Z.5 .at 10. pro~imity: analysis Pertorme_d, 2_close approaches idj'!otified. 304:014 recommended for approval, Big jse_quippedwitb steelpits. No rese_rve_pjtplanoed, Wa_steto approved Class_ I disposal well(sL Casjn9 ~7.jQ2 _cemented_ to syrface in _original wellborj'!, Engineering Appr e Date Leasj'! number appropriate Administration 2 3 4 5 6 7 8 9 10 11 12 13 14 5 6 7 _C_oodu_ct_or _S_urface _casing protects all known USOWs stÖng provided ACMP_ F'inding of Con_si$teocyhas beenjssued_ forJbis pcoject J(deviated, js_ weJlbore plaUocJuded _Opecator Qnly: affected party _ _Qpeeator bas_appropriate_bond jnJorce P~rmit cao be issued witbout conservation order pj'!rmit cao be issued wjtbout Can permit Well AJI welJs_ within J [4_mile _areaßf reyiew jd_eot[fied (Foe seNjc_e well only:) Pre-produced iojector; duration_of pre-production Jess than_ 3 montbs (For seIYice well onJy) 5-day wait IQcat~d within area and strata _authorized by lojectioo Ordj'!r # (puUO# incomrnj'!ots) (For be approved before ad_ministeatÌlle_ approvaJ _Sufficient acreag.e_ayailable in_driUiog. unit _Unique welt n_arn~ _and oumb_er Well Jocatj'!d ina d_efine_d _pool_ WellJQcat~d proper _distance_ from driJling unitb_ound_ary_ WellJocatj'!d pr_oper _distance_ from otber weUs INC KUPARUK RIVER, KUPARUK RV OIL 490100 Initial ClasslType Yj'!s Yj'!s _Yj'!s Yj'!s Y~$ Y~s No_ Yj'!s Y~s Yj'!s No Yj'!s No NA _NA NA NA Set jn_ original wellbwe_. M aquifers ex_empted,40 _CFR 1 (b)-<3) Be-drj of exis_tiog welt Nearest in _zone_ we_ SI'ACING _EXCEPTION RE_QUJREQ by_ CQ 432B; Jbis will (the others_ being the_Kup Asaod perfs be in_ 3F: 13Aand 3F'-ZO). in KupA sands (-'112_5' away) the tbiedwell a_ndKup Csands -<--:1300' away). deill~d tONE 1<4 of Section 19_ js_3F:13Awitb perts Kuparuk Hivee Well Name: KUPARUK RIV UNIT 3F-19A DEV LPEND GeoArea 890 Qil!'ool, governj'!d by: CO ~32B. Unit Program DEV 11160 On/Off Shore Dn Well Annular Disposal bore seg o o e e Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify fìnding infonnation, information of this nature is accumulated at the end of the fìle under APPENDIX. No special effort has been made to chronologically organize this category of information. e e p- r-'¡ q Sperry-Sun Drilling Services LIS Scan Utility $Revision: 3 $ LlsLlb $Revlslon: 4 $ Mon Apr 12 13:51:08 2004 ~ ~v{- ùl (0 Reel Header Service name.............LISTPE Date. . . . . . . . . . . . . . . . . . . . . 04/04/12 Origin. . . . . . . . . . . . . . . . . . . STS Reel Name................UNKNOWN Continuation Number......01 Previous Reel Name.......UNKNOWN Comments.................STS LIS Writing Library. Scientific Technical Services Tape Header Service name.............LISTPE Date.....................04/04/l2 Origin...................STS Tape Name................UNKNüWN Continuation Number......01 Previous Tape Name.......UNKNOWN Comments.................STS LIS Writing Library. Scientific Technical Services Physical EOF Comment Record TAPE HEADER Kuparuk MWD/MAD LOGS # WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: # JOB DATA 3F-19A 500292268001 ConocoPhillips Alaska, Inc. Sperry-Sun Drilling Services 12-APR-04 JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 1 MW0002890968 P. SMITH P. WILSON MWD RUN 2 MW0002890968 P. SMITH G. RIZEK # SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: 19 12N 9E 37 124 MSL 0) 84.50 54.20 # WELL CASING RECORD 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING OPEN HOLE BIT SIZE (IN) 6.750 4.750 CASING SIZE (IN) 7.625 5.500 DRILLERS DEPTH (FT) 3974 . 0 7612.0 # REMARKS: 1. ALL DEPTHS ARE MEASURED DEPTH (MD) UNLESS OTHERWISE NOTED. THESE DEPTHS ARE BIT DEPTHS. 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTH (TVD). e e 3. THIS SIDETRACK KICKED-OFF OF A CEMENT PLUG AT 3974'MD/3202'TVD. 4. MWD RUNS 1 & 2 COMPRISED DIRECTIONAL WITH DUAL GAMMA RAY (DGR) UTILIZING GEIGER-MUELLER TUBE DETECTORS, AND ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4). 5. DEPTH SHIFTING/CORRECTION OF MWD DATA WAS WAIVED PER PHONE CALL FROM LISA WRIGHT, CONOCOPHILLIPS ALASKA, INC., TO BUSTER BRYANT (SSDS) ON 4/12/2004. MWD DATA ARE CONSIDERED PDC. 6. MWD RUNS 1 & 2 REPRESENT WELL 3F-19A WITH API#: 50-029-22680-01. THIS WELL REACHED A TOTAL DEPTH (TD) OF 8254'MD/6281'TVD. SROP SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRC SMOOTHED GAMMA RAY COMBINED. SEXP SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (EXTRA SHALLOW SPACING) . SESP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (SHALLOW SPACING) . SEMP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (MEDIUM SPACING) . SEDP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (DEEP SPACING) . SFXE = SMOOTHED FORMATION EXPOSURE TIME (SEDP). SLIDE = NON-ROTATED INTERVALS REFLECTING BIT DEPTHS. $ File Header Service name.............STSLIB.OOl Service Sub Level Name... Version Number...........l.O.O Date of Generation.......04/04/12 Maximum Physical Record..65535 Fi 1 e Type................ LO Previous File Name.......STSLIB.OOO Comment Record FILE HEADER FILE NUMBER: EDITED MERGED MWD Depth shifted DEPTH INCREMENT: # FILE SUMMARY PBU TOOL CODE GR RPD RPM RPS RPX FET ROP $ 1 and clipped curves; all bit runs merged. .5000 START DEPTH 3930.0 3934.0 3934.0 3934.0 3934.0 3979.5 3981. 0 STOP DEPTH 8177.5 8190.5 8190.5 8190.5 8190.5 8190.5 8254.0 # BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH $ # MERGED DATA SOURCE PBU TOOL CODE MWD MWD $ BIT RUN NO 1 2 MERGE TOP 3930.0 7615.0 MERGE BASE 7615.0 8254.0 # REMARKS: MERGED MAIN PASS. è e e # Data Format Specification Record Data Record Type..................O Data Specification Block Type.....O Logging Direction.................Down Optical log depth units...........Feet Data Reference Point..............Undefined Frame Spacing....... ..............60 .1IN Max frames per record.............Undefined Absent value..................... .-999 Depth Units....................... Datum Specification Block sub-type...O Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD FT/H 4 1 68 4 2 GR MWD API 4 1 68 8 3 RPX MWD OHMM 4 1 68 12 4 RPS MWD OHMM 4 1 68 16 5 RPM MWD OHMM 4 1 68 20 6 RPD I1\^JD OHMM 4 1 68 24 7 FET MWD HOUR 4 1 68 28 8 First Last Name Service Unit Min l1ax Mean Nsam Reading Reading DEPT FT 3930 8254 6092 8649 3930 8254 ROP MWD FT/H 0.22 996.01 141. 683 8547 3981 8254 GR MWD API 36.26 551.3 130.249 8496 3930 8177.5 RPX MWD OHMM 0.44 665.03 4.01974 8514 3934 8190.5 RPS MWD OHMM 0.1 2000 6.89934 8514 3934 8190.5 RPI1 MWD OHMM 0.1 2000 9.99671 8514 3934 8190.5 RPD lÆWD OHMlvI 0.03 2000 18.1693 8514 3934 8190.5 FET MWD HOUR 0.1964 225.195 3.65288 8423 3979.5 8190.5 First Reading For Entire File..........3930 Last Reading For Entire Fi1e...........8254 File Trailer Service name......_......STSLIB.001 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......04/04/12 Maximum Physical Record..65535 File Type................ LO Next File Name...........STSLIB.002 Physical EOF File Header Service name.............STSLIB.002 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......04/04/12 l1aximum Physical Record..65535 File Type............... .LO Previous File Name.......STSLIB.001 Comment Record FILE HEADER FILE NUI1BER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREI1ENT: # FILE SUMHARY VENDOR TOOL CODE GR RPX 2 header data for each bit run in separate files. 1 .5000 START DEPTH 3930.0 3934.0 STOP DEPTH 7561. 5 7568.5 e RPD RPS RPM FET ROP $ 3934.0 3934.0 3934.0 3979.5 3981. 0 7568.5 7568.5 7568.5 7568.5 7615.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: Da~HOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR RFAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MA..XIMUM 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 (F"l'): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type.................. 0 Data Specification Block Type.....O Logging Direction.................Down Optical log depth units...........Feet Data Reference Point..............Undefined Frame Spacing.....................60 .1IN Max frames per record.............Undefined Absent value...................... -999 Depth Units................ . . . . . . . Datum Specification Block sub-type...O e 09-FEB-04 Insite 66.37 Memory 7615.0 3974.0 7615.0 38.7 47.9 TOOL NUMBER 91360 156401 6.750 3974.0 Water Based 10.70 48.0 10.0 2000 5.0 2.400 70.0 1.310 133.5 1.600 70.0 2.800 70.0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD010 FT/H 4 1 68 4 2 GR MWD010 API 4 1 68 8 3 RPX MWD010 OHMM 4 1 68 12 4 RPS MWD010 OHMM 4 1 68 16 5 RPM MWD010 OHMM 4 1 68 20 6 RPD MWD010 OHMM 4 1 68 24 7 e e FET MWD010 HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 3930 7615 5772.5 7371 3930 7615 ROP HWD010 FT/H 0..34 996.01 159.837 7269 3981 7615 GR MWD010 API 36.26 551.3 135.797 7264 3930 7561. 5 RPX MWD010 OHMM 0.44 7.86 3.00153 7270 3934 7568.5 RPS MWD010 OHMM 0.37 2000 3.48897 7270 3934 7568.5 RPM MWD010 OHMM 0.36 2000 5.47939 7270 3934 7568.5 RPD MWD010 OHMM 0.29 2000 16.8351 7270 3934 7568.5 FET MWD010 HOUR 0.1964 5.1911 0.731875 7179 3979.5 7568.5 First Reading For Entire File..........3930 Last Reading For Entire File...........7615 File Trailer Service name.............STSLIB.002 Service Sub Level Name... Version Number...........l.O.O Date of Generation.......04/04/12 Maximum Physical Record..65535 File Type............... .LO Next File Name...........STSLIB.003 Physical EOF File Header Service name.............STSLIB.003 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......04/04/12 Maximum Physical Record..65535 Fi 1 e Type................ LO Previous File Name...... .STSLIB.002 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE GR RPD RPM RPS RPX FET ROP $ 3 2 .5000 START DEPTH 7562.0 7569.0 7569.0 7569.0 7569.0 7569.0 7615.5 STOP DEPTH 8177.5 8190.5 8190.5 8190.5 8190.5 8190.5 8254.0 # 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: 20-FEB-04 Insite 4.3 Memory 8254.0 7615.0 8254.0 36.4 39.1 # e TOOL STRING (TOP TO VENDOR TOOL CODE DGR EWR4 :;; BOTTOM) TOOL TYPE DUAL GAMMA RAY ELECTROMAG. RESIS. 4 # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (1'1'1'): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type.................. 0 Data Specification Block T}~e.....O Logging Direction................ . Down Optical log depth units...........Feet Data Reference Point..............Undefined Frame Spacing.....................60 .1IN Max frames per record.............Undefined Absent value..................... .-999 Depth Units....................... Datum Specification Block sub-type...O e TOOL NUMBER 171170 17117C 4.750 7612.0 Water 12.60 52.0 9.5 500 3.6 Based 2.500 1.290 1.800 3.500 72.0 145.8 72.0 72.0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD020 FT/H 4 1 68 4 2 GR MWD020 API 4 1 68 8 3 RPX MWD020 OHMM 4 1 68 12 4 RPS MWD020 OHMM 4 1 68 16 5 RPM MWD020 OHMM 4 1 68 20 6 RPD MWD020 OHMM 4 1 68 24 7 FET HWD020 HOUR 4 1 68 28 8 First Last Name Service Unit Mit! Max Mean Nsam Readit!g Reading DEPT FT 7562 8254 7908 1385 7562 8254 ROP MWD020 FT/H 0.22 87.24 38.4318 1278 7615.5 8254 GR MWD020 API 43.52 215.48 97.5335 1232 7562 8177.5 RPX MWD020 OHMM 1.11 665.03 9.97024 1244 7569 8190.5 RPS MWD020 OHMM 0.1 1722.5 26.8298 1244 7569 8190.5 RPM MWD020 OHMM 0.1 2000 36.3962 1244 7569 8190.5 RPD M~'JD020 OHMM 0.03 1669.21 25.9659 1244 7569 8190.5 FET MWD020 HOUR 0.994 225.195 20.5097 1244 7569 8190.5 First Reading For Entire l"ile..........7562 Last Reading For Entire File...........8254 File Trailer e tit Service name.............STSLIB.003 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......04/04/12 Maximum Physical Record..65535 File Type................ LO Next File Name...........STSLIB.004 Physical EOF Tape Trailer Service name.............LISTPE Date.................... .04/04/12 Origin. . . . . . . . . . . . . . . . . . . STS Tape Name................UNKNOWN Continuation Number......01 Next Tape Name...........UNKNOMi Comments.................STS LIS Writing Library. Scientific Technical Services Reel Trailer Service name_____________LISTPE Date.. ...................04/04/12 Origin. . . . . . . . . . . . . . . . . . . STS Reel Name................UNKNOWN Conti nuat~ion Number...... 01 Next Reel Name...........UNKNOWN Comments.................STS LIS Writing Library. Scientific Technical Services Physical EOF Physical EOF End Of LIS File