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Home My WebLink About201-080Originated: Delivered to:2-Sep-25Alaska Oil & Gas Conservation Commiss02Sep25-NR !"#$$%$ !&$$'($)*%+ ($)*%,-.WELL NAME API #SERVICE ORDER #FIELD NAMESERVICE DESCRIPTIONDELIVERABLE DESCRIPTION DATA TYPE DATE LOGGEDCD4-24 50-103-20602-00-00 209-097 Colville River WL RBP FINAL FIELD 3-Aug-251E-36 50-029-22927-00-00 198-213 Kuparuk River WL WFL FINAL FIELD 5-Aug-252F-18 50-029-22720-00-00 196-178 Kuparuk River WL SCMT FINAL FIELD 6-Aug-251E-36 50-029-22927-00-00 198-213 Kuparuk River WL RST FINAL FIELD 7-Aug-251C-121 50-029-23015-00-00 201-080 Kuparuk River WL IPROF FINAL FIELD 8-Aug-252V-16 50-029-21296-00-00 185-033 Kuparuk River WL PPROF FINAL FIELD 9-Aug-252X-01 50-029-20963-00-00 183-084 Kuparuk River WL HEX-PLUG FINAL FIELD 10-Aug-251R-22A 50-029-22206-01-00 199-049 Kuparuk River WL PPROF FINAL FIELD 11-Aug-251C-121 50-029-23015-00-00 201-080 Kuparuk River WL IPROF FINAL FIELD 13-Aug-251B-08A 50-029-20635-01-00 197-112 Kuparuk River WL IPROF FINAL FIELD 22-Aug-25Transmittal Receipt//////////////////////////////// 0///////////////////////////////// + ! 1Please return via courier or sign/scan and email a copy to Schlumberger."2"3 +45 %TRANSMITTAL DATETRANSMITTAL #1 67 8" ! - +"8#!(3 . 8)"3 8#!9 3 : 8" +868 8 "8#!;" " 3 - 3" 3""+ 3 + <+3!% T40840T40841T40842T40841T40843T40844T40845T40846T40843T408471C-12150-029-23015-00-00201-080Kuparuk RiverWLIPROFFINAL FIELD8-Aug-251C-12150-029-23015-00-00201-080Kuparuk RiverWLIPROFFINAL FIELD13-Aug-25Gavin GluyasDigitally signed by Gavin Gluyas Date: 2025.09.03 08:58:49 -08'00' MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Friday, December 9, 2022 SUBJECT:Mechanical Integrity Tests TO: FROM:Austin McLeod P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL ConocoPhillips Alaska, Inc. 1C-121 KUPARUK RIV U WSAK 1C-121 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 12/09/2022 1C-121 50-029-23015-00-00 201-080-0 W SPT 3562 2010800 1500 748 748 749 750 4YRTST P Austin McLeod 10/10/2022 MITIA. Monobore 30 MinPretestInitial15 Min Well Name Type Test Notes: Interval P/F Well Permit Number: Type Inj TVD PTD Test psi API Well Number Inspector Name:KUPARUK RIV U WSAK 1C-121 Inspection Date: Tubing OA Packer Depth 200 1835 1775 1775IA 45 Min 60 Min Rel Insp Num: Insp Num:mitSAM221010190651 BBL Pumped:0.8 BBL Returned:0.8 Friday, December 9, 2022 Page 1 of 1           5HJJ-DPHV%2*& )URP:HOO,QWHJULW\6SHFLDOLVW&3) &3)Q#FRQRFRSKLOOLSVFRP! 6HQW:HGQHVGD\0D\30 7R5HJJ-DPHV%2*&:DOODFH&KULV'2*&%URRNV3KRHEH/2*&'2$$2*&&3UXGKRH%D\ 6XEMHFW.58&3DGQRQZLWQHVVHG0,7,$V $WWDFKPHQWV0,7.58&3$'6,7HVWV[OV[ ůů͕ ZĞĐĞŶƚŶŽŶǁŝƚŶĞƐƐĞĚD/d/ƐŽŶϭͲWĂĚ͘WůĞĂƐĞůĞƚŵĞŬŶŽǁŝĨǇŽƵŚĂǀĞĂŶǇƋƵĞƐƚŝŽŶƐ͘ ZĞŐĂƌĚƐ͕ -DQ%\UQH :HOO,QWHJULW\6SHFLDOLVW &RQRFR3KLOOLSV$ODVND,QF 2IILFHSKRQH &HOOSKRQH &$87,217KLVHPDLORULJLQDWHGIURPRXWVLGHWKH6WDWHRI$ODVNDPDLOV\VWHP'RQRWFOLFNOLQNVRURSHQ DWWDFKPHQWVXQOHVV\RXUHFRJQL]HWKHVHQGHUDQGNQRZWKHFRQWHQWLVVDIH .58& 37' Submit to: OOPERATOR: FIELDD // UNITT // PAD: DATE: OPERATORR REP: AOGCCC REP: Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD 2011280 Type Inj N Tubing 605 745 740 730 Type Test P Packer TVD 3644 BBL Pump 0.6 IA 215 1830 1765 1760 Interval 4 Test psi 1500 BBL Return 0.5 OA N/A N/A N/A N/A Result P Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD 2010800 Type Inj N Tubing 340 430 415 405 Type Test P Packer TVD 3564 BBL Pump 0.5 IA 450 1830 1770 1760 Interval 4 Test psi 1500 BBL Return 0.4 OA N/A N/A N/A N/A Result P Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD 2011140 Type Inj N Tubing 665 705 690 685 Type Test P Packer TVD 3669 BBL Pump 1.0 IA 60 1820 1795 1785 Interval 4 Test psi 1500 BBL Return 0.8 OA N/A N/A N/A N/A Result P Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD 2030030 Type Inj NTubing50505050 Type TestP Packer TVD 3833 BBL Pump 1.1 IA 230 1810 1720 1715 Interval 4 Test psi 1500 BBL Return 0.8 OA N/A N/A N/A N/A Result P TYPE INJ Codes TYPE TEST Codes INTERVAL Codes Result Codes W = Water P = Pressure Test I = Initial Test P = Pass G = Gas O = Other (describe in Notes) 4 = Four Year Cycle F = Fail S = Slurry V = Required by Variance I = Inconclusive I = Industrial Wastewater O = Other (describe in notes) N = Not Injecting ConocoPhillips Alaska Inc, Kuparuk / KRU / 1C Pad N/A Miller 05/10/22 Notes: Notes: 1C-111 1C-121 1C-190 Notes: 1C-127 Notes: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION MMechan i call In t eg r i t yy Tes t jim.regg@alaska.gov;AOGCC.Inspectors@alaska.gov;phoebe.brooks@alaska.gov chris.wallace@alaska.gov Form 10-426 (Revised 01/2017)2022-0510_MIT_KRU_1C-pad_4wells $2*&&ZDLYHGZLWQHVVMEU -5HJJ 9 9 9 9 9 9 9 1C-121 05/10/22 $2*&&ZDLYHGZLWQHVVMEU Originated: Schlumberger PTS - PRINT CENTER 6411 A Street Anchorage, AK 99518 (907) 273-1700 main (907)273-4760fax Delivered to: rr •� >ti% AOGCC ., ATI -N. Natural Resources Technician II Alaska Oil & Gas Conservation Commision 333 W. 7th Ave, Suite 100 n1*& Anchorage, AK 99501 201080 TRANSMITTALDATE TRANSMITTAL p . WELL NAME API H SERVICE •r - ORDER 4 FIELD r NAME SERVICE DESCRIPTION DELIVERABLE DESCRIPTION DATA TYPE Color DATELOGGED Prints - CD's 11-1-114 1H-111 1H-105 1H-113 1H-116 3M-19 3G -07A 1 50429-2358400 50.029-23581.00 50.029-20727.01 50-029-23588-00 50-029-23594-00 50-029-21737.00 50-103.20127-01 EOSH-00071 EA18.00022 E118.00075 E118-00076 E118-00077 E118-00078 E118-00079 KUPARUK RIVER KUPARUK RIVER KUPARUK RIVER KUPARUK RIVER KUPARUK RIVER KUPARUK RIVER KUPARUK RIVER WL WL WL WL WL WL WL IPROF IPROF-WFL IPROF-WFL IPROF•WFL IPROF-WFL Caliper PPROF FINAL FIELD FINAL FIELD FINAL FIELD FINAL FIELD FINAL FIELD FINAL FIELD FINAL FIELD 15 -Jul -19 17 -Jul -19 19 -Jul -19 20 -Jul -19 21-J.1.19 22 -Jul -19 23 -Jul -19 1 1 1 1 1 1 1 3G-11 50-103-20133-00 E118-00081 KUPARUK RIVER WL IPROF FINAL FIELD 2 5 -Jul -19 1 3M-13 18-16AL1 1A-17 1C-121 3N -14A 3G-08 50-029-21720-00 50.029-22457.60 50-029-22102-00 50-029.23015-00 50-029-21589-01 50-103.20128-00 E718-00084 EDEA -00009 E118-00085 E118-00086 EOSH-00074 EOSH-00075 KUPARUK RIVER KUPARUK RIVER KUPARUK RIVER KUPARUK RIVER KUPARUK RIVER KUPARUK RIVER WL Memory WL WL WL WL Caliper PPROF LDL (PROF LDL,Caliper LDL,Caliper FINAL FIELD FINAL FIELD FINAL FIELD FINAL FIELD FINAL FIELD FINAL FIELD 28-Jul•19 28•Jul-19 29 -Jul -19 1 -Aug -19 2 -Aug -19 3-Aug•19 1 1 1 1 1 1 2N-317 50.103-20266-00 EOSH-00076 KUPARUK RIVER WL LDL FINAL FIELD 4 -Aug -19 1 2019 15 -------"` X ATransmittal Receipt signature confirms that package (box, envelope, etc.) has been received and the contents of the V-� �q not have been verified for correctness or quality level at this package have been verified to match the media noted above. The Pr t ame Sign toe Date specific content of the CDs and/or hardcopy prints may or may Please return via courier or sign/scan and email a copy to Sc?Iuberger and CPAI. point. SCANNEDSchlumberger-Private AUG 0 7 2019 MEMORANDUM • State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg ! DATE: Wednesday,May 16,2018 � I P.I.Supervisor 5 u I lP SUBJECT: Mechanical Integrity Tests K � CONOCOPHILLIPS ALASKA,INC. IC-121 FROM: Austin McLeod KUPARUK RIV U WSAK 1C-121 Petroleum Inspector Src: Inspector Reviewed By: �� P.I.Supry je -- NON-CONFIDENTIAL Comm Well Name KUPARUK RIV U WSAK 1C-121 API Well Number 50-029-23015-00-00 Inspector Name: Austin McLeod Permit Number: 201-080-0 Inspection Date: 5/12/2018 Insp Num: mitSAM180513200327 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 1C-121 Type Inj W f TVD 3562 Tubing 976 " 922 - 927 • 977 PTD 2010800 Type Test SPT Test psi 1500 IA 260 1810 - 1770 - 1765 • 1- ---- --_ -- --- BBL Pumped: 0.6 BBL Returned: 0.6 OA Interval 4YRTST P/F P J Notes: MIT-IA.No OA - %AWED JUN O 4IJ1 y 16,Wednesday, Ma 2018 Page 1 of 1 MEMORANDUM • TO: Jim Regg ~~ ~~~ ~ l0 P.I. Supervisor ~( FROM: John Crisp Petroleum Inspector • State of Alaska Alaska Oil and Gas Conservation Commission DATE: Tuesday, May 25, 2010 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 1C-12] KUPARUK RIV U WSAK 1C-121 Src: Inspector NON-CONFIDENTIAL Reviewed By: P.1. Suprv J ~- Comm Well Name: KUPARUK RIV U WSAK 1C-121 API Well Number: 50-029-23015-00-00 Inspector Name: John Crisp Insp Num: mitJCr100523172547 Permit Number: 201-080-0 Inspection Date: 5/21/2010 Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well T 1at21 Type Inj. N TVD X3562 ~ IA 30 ! - - a- - - P.T.D zoloaoo TypeTest sPT ,Test psi ]soo ~~ OA_ ~ 22ao ~ _~ 2160 21ao - Interval 4~TST p/F P ~ Tubing 3~0 aoo aoo sus _ Notes: 2.4 bbls pumped for test. Monobore injector. Mandrel hanger off seat from conductor casing with WAG flowline hanging from tree with no support. Casing in sideways bind. .--- --- ~ r~~ ~ a~~ c,~~~~~ ~`'"~a''~ j y .'t ... 'IG St hSs t~ ~ Tuesday, May 2s, 2010 Page 1 of 1 Page 1 of 1 Regg, James B (DOA) ~ • __ __ _ _ _ _ _ _ _ _ From: Regg, James B (DOA) ~~~ ~'2~ I ~ o tc-~z~ Sent: Friday, June 25, 2010 2:17 PM 1 7 ~-u-~(- To: NSK Well Integrity Proj; NSK Problem Well Supv Cc: DOA AOGCC Prudhoe Bay; Maunder, Thomas E (DOA) Q~ ~ l- ~3~ Subject: ANSI 1500 Flanges Inspectors have been finding ANSI 1500 flanges installed on the IA of some wells when out to witness MITs. The rated working pressure for these flanges is 3700psi. If I understand the situation correctly, the ANSI 1500 flange is installed on the IA and would either be directly exposed to test pressure approaching the rated working pressure, or could be exposed to excessive injection pressures in the case of TxIA communication (e:g., high injection pressures on gas injectors or via thermal expansion). During witnessed MITs in late May 2010, ANSI 1500 fllanges were found on West Sak gas injectors KRU 1C-25 and 1C-27. In both occurances, CPAI was advised these are deficiencies. API defines the rated working pressure of equipment to be the maximum internal pressure that the equipment is designed to contain or control, and further notes that rated working pressure should not be confused with testing presssure (I read that to say it is inappropriate to justify operating equipment at pressure exceeding rated work pressure just because it was tested to the higher pressure). Exceeding the rated working pressure represents an inappropriate risk to field personnel attending to the wells. Inspectors have not been able to field verify if ANSI 1500 flanges have been hydrotested to proposed higher test pressure, and even if the flange was tested, we question how you would account for the history (exposure to extreme temps, harsh chemicals, corrosive fluids, etc.). We are interested in understanding CPAI's safe operating practices regarding ANSI 1500 flanges. We are also interested in reviewing any CPAI test policy that allows for the pressure rating of equipment to be exceeded. Other deficiencies noted during the KRU 1 C-pad inspections in late May: - Two instances of tree flange adapters made up to tubing spool without full engagement of the nuts on the studs (1 C-10, 1 C-15) - KRU 1C-119 and 1 C-121 were noted to have mandrel hangers off seat from conductor casing; WAG injection lines were hanging from tree without support, placing the casings in a sideways bind. - KRU 1 C-174 was observed to have orifice meter wrapped in absorbent and an oily waste bag; use and condition of the orifice meter here needs to be explained. Please address these items. Jim Regg AOGCC 333 W.7th Avenue, Suite 100 Anchorage, AK 99501 907-793-1236 6/25/2010 Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth NO.4947 1~~!;~~; ~ .s nr~r-y. Well Job # Log Description 1 ~,V' L% Company: Alaska Oil & Gas Cons I;omm Attn: Christine Mahnkein 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Kuparuk Date BL Color CD 10/29/08 3S-08C 12066554 MEM PRODUCTION PROFILE (~ - '~' 10/14/08 1 1 1C-26 11978487 SBHP SURVEY -b ~ 10/15/08 1 1 iC-119 11978488 INJECTION PROFILE ~} 10/16/08 1 1 3H-15 12080445 INJECTION PROFILE .. ~C,/ 10/16/08 1 1 1C-121 11978490 INJECTION PROFILE 10/17/08 1 1 3H-18 12080446 INJECTION PROFILE ~ - p 10/17/08 1 1 1J-159 12097431 PRODUCTION PROFILE ~ v' 10/13/08 1 1 iF-10 12080453 INJECTION PROFILE 10/27/08 1 1 1C-121 11978490 INJECTION PROFILE 10/17/08 1 1 • Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. /~ ~ r ~.,~ 1_. 1 ~~~~~~~ Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth ~~~ r~ e Well Job # Log Description NO. 4947 Company: Alaska Oil & Gas Cons Gomm Attn: Christine Mahnkein 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Kuparuk Date BL Color CD 10/29/08 3S-08C 12066554 MEM PRODUCTION PROFILE (~ - ~' 10/14/08 1 1 iC-26 11978487 SBHP SURVEY ( ~ej ~ 10/15/08 1 1 iC-119 11978488 INJECTION PROFILE ~ 10/16/08 1 1 3H-15 12080445 INJECTION PROFILE - -~C/ 10/16/08 1 1 C-121 11978490 INJECTION PROFILE ~ 10/17/08 1 1 3H-18 12080446 INJECTION PROFILE `~ - ' J 10/17/08 1 1 1J-159 12097431 PRODUCTION PROFILE ~ ~ 10/13/08 1 1 1 F-10 12080453 INJECTION PROFILE 10/27/08 1 1 1C-121 11978490 INJECTION PROFILE (- 10/17/Og 1 1 Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. • . . Conoc~illips Alaska RECEIVED APR 1 8 Z007 Alaska OU & Gas Cons. Commission Anchorage P.O. BOX 100360 ANCHORAGE, ALA5KA 99510-0360 April 16, 4007 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 aO\-D~() Dear Mr. Maunder: Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRU). Some of these wells were found to have a void in the conductor by surface casing annulus. The voids that were greater than 3 feet were first filled with cement to a level of approx. 1.0 foot. The remaining volume of annular void subsequently was filled with a corrosion inhibiter 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. Please call Jerry Dethlefs or M.J. Loveland at 907-659-7043, if you have any questions. Sincerely, ~~~ ConocoPhillips Well Integrity Project Supervisor . . ConocoPhillips Alaska Inc. Suñace Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off ~prl , Corrosion Initial top of Vol. of cement Final top of Cement top off Corrosion inhibitor/ Well Name PTD# cement pumped cement date inhibitor sealant date ft bbls ft Qal 1 C-25 119-031 9'4" 0.8 14" 4/14/2007 3.8 4/15/2007 1C-119 201-139 25'6" 4.8 16" 4/14/2007 5.4 4/15/2007 1C-121 201-080 11' 2.0 18" 4/8/2007 8.6 4/15/2007 1C-131 201-185 12' 1" 1.8 16" 4/8/2007 6.8 4/1512007 1C-135 201-220 11' 1.3 10" 4/8/2007 2.4 4/15/2007 1 C-172 203-095 10' 8" 1.5 18" 4/14/2007 6.6 4/15/2007 1 H-02 193-008 14'6" 2.0 4/5/2007 3.3 4/15/2007 1 H-09 193-029 11" n/a 11" n/a 4.9 4/15/2007 1 H-17 192-130 20" n/a 20" n/a 7.5 4/15/2007 Kuparuk Field A 116 2007 ~/d--/ 03/05/07 Schlumberger NO. 4173 Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 A TTN: Beth Company: Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite '100 Anchorage, AK 99501 t11\R !j) ~, 10m CÜ'il1rn\~$iQ8CANNED MAR;} 0 2007 Ù:}:C-.. [)O l- o~ò Field: Kuparuk Well Job# BL Color CD Log Description Date 2G-03 11638824 INJECTION PROFILE 02/15107 1 1R-08 11628971 INJECTION PROFILE 02/15/07 1 1 F-17 11638827 SBHP SURVEY 02/17/07 1 1 F-14 11638826 SBHP SURVEY 02/17/07 1 1 F-19 11638828 SBHP SURVEY 02/19/07 1 1C-13 11628977 SBHP SURVEY 02/19/07 1 1 C-02 11628978 SBHP SURVEY 02/19107 1 2M-02 11628979 INJECTION PROFILE 02/20/07 1 3S-26 11638813 INJECTION PROFILE 01/21/07 1 1 C-121 11665391 INJECTION PROFILE 02/05/07 1 1 J-180 11665390 USIT 02/06/07 1 3J-14 11638825 PROD PROFILE 02/16/07 1 1 J-118 11665392 US IT 02/22/07 1 1 D-11 11665393 INJECTION PROFILE 02/24/07 1 2M-OS 11665400 INJECTION PROFILE 03/01/07 1 2M-04 11665399 INJECTION PROFILE 03/01/07 1 1 F-13 11665401 INJECTION PROFILE 03/02/07 1 Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. 1'71" c . . · RECEiVED . MAR 1 3 2007 ConocJPhillips Alaska Oil & Gas Cons. Commission Anchorage Robert Buchholz / Robert Christensen Production Engineering Tech. Greater Kuparuk Unit, NSK-69 PO Box 196105 ~chorage,AJC 99519-6105 Phone: (907) 659-7535 Fax: 659-7314 March 9, 2007 Tom Maunder, P.E. Senior Petroleum Engineer State of Alaska, Oil & Gas Conservation Commission 33 W. ih Ave. Ste. 100 Anchorage,AJC 99501 REC~/\/¡:::/) Dear Mr. Maunder, ConocoPhillips Alaska, Inc. has completed the West Sak EaR Pilot Project. Enclosed you will find 10-404 Report of Sundry Well Operation for ConocoPhillips Alaska, Inc. welllC-121 (pTD 201-080). The report records the change of well status from WAG Injection to Water Injection Service. If you have any questions regarding this matter, please contact myself or Robert Buchhloz at 659-7535. SCANNED MAR 2 0 2007 Robert D. Christensen Attachments STATE OF ALASKA . MAR 1 3 2007 ALASKA OIL AND GAS CONSERVATION COMMISSION Alaska Oil & G C . . REPORT OF SUNDRY WELL OPERATIONS .. as on5. CommissIon o WAGIN to WlNJ Time Extension D Re-enter Suspended Well D . 1. Operations Performed: Abandon D Alter Casing D Repair Well D Pull Tubing D Operat. ShutdownD Change Approved Program D 2. Operator Name: ConocoPhillips Alaska, Inc. 3. Address: P. O. Box 100360, Anchora e, Alaska 99510 7. KB Elevation (ft): RKB 102' 8. Property Designation: Kuparuk River Unit Â J>. L ~S"" 'I" ,,¢j) 3·1'(;.·':> 7 11. Present Well Condition Summary: Total Depth 6876' 4228' < measured true vertical Effective Depth measured true vertical Casing Structural CONDUCTOR PRODUCTION PRODUCTION Size Length 121' 6062' 720' 16" 5-1/2" 3-1/2" Perforation depth: Measured depth: true vertical depth: 3650 Tubing (size, grade, and measured depth) 3-1/2" , L-80, 6155' MD. RECEIVED Plug Perforations D Perforate New Pool D Stimulate D Waiver D Other Perforate D 4. Current Well Status: 5. Permit to Drill Number: 201-080 1 . 6. API Number: 50-029-23015-00 Development D Stratigraphic D Exploratory D Service 0 9. Well Name and Number: 1C-121 10. Field/Pool(s): Kuparuk River Field 1 West Sak Oil Pool feet feet feet feet Plugs (measured) Junk (measured) MD TVD Collapse Burst 6252 121' 121' 6164' 3570' 6884' 4236' L\~\~CJ ~b..C=:>\.~\I"cL\-'D~ c..-.,)\,:-af\~~ t:>, ~\ 0 ðß .Cyo \.. \-<:i.~\.,,",l.. '\ ")<tl:...~~ ,\"V\) .\-" ,,~ ~ \ \ "is' I a'-\ fa. \> \C ~ <:t:c....-\ C-.c"-C..\~~ ~~ þ...-:s~~ -\- ~,ao <0.. þ.-.J\\--b f\ \---l-\-o \ ~~L~ S~~ft..i-\>'\~ ~l~,-o~.. ~\\":>~~'> ~~'C'..~ e. \-0 \ "'-.) '\ "'~ (L -G\-~L~'-.JQ. <:::t, l- 0 L. / M ~(()'"O Packers & SSSV (type & measured depth) no packer no SSSV no SSSV 12. Stimulation or cement squeeze summary: Intervals treated (measured) Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Met Water-Bbl Casin Pressure Tubin Pressure Prior to well operation 242 10 1057 Subsequent to operation 242 10 1057 14. Attachments 15. Well Class after proposed work: Copies of Logs and Surveys run _ Exploratory D Development D Service 0 Daily Report of Well Operations _ 16. Well Status after proposed work: OilD GasD WAGD GINJD WINJ 0 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: N/A Contact Printed Name Signature Form 10-404 Revised 04/2004 np\r: ~,! \,_,....Î ~\~ '¡ \: "C,.-;; ~:\j Title Phone 659-7535 Production Engineering Technician Date '$ R8DMS 8Ft MAR ] 9 Z007 f) "AJ> "'1.~G.. -°7 Submit Original Only ~#6;6r MEMORANDUM . State of Alaska . Alaska Oil and Gas Conservation Commission TO: Jim Regg P.l. Supervisor DATE: Wednesday, August 09, 2006 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC ]C-121 KUPARUK RIV U WSAK lC-121 tßO r'O ')P FROM: Chuck Scheve Petroleum Inspector Src: Inspector Reviewed By: P.t Suprv :J1?f?--- Comm NON-CONFIDENTIAL Well Name: KUPARUK RIV U WSAK IC-121 API Well Number 50-029-23015-00-00 Insp Num: mÍtCS060803183619 Permit Number: 201-080-0 Rei Insp Num Inspector Name: Chuck Scheve Inspection Date: 8/3/2006 Packer Depth -- I 3561 I 1500 I --- Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. -- Well i 1C-121 IType Inj. ¡ W ¡ TVD IA ~ 1000 i 1790 I i P.T. I 2010800 iTypeTest I SPT : Test psi I OA . i : I Interval OTHER P/F P TubingL 800 I 800 800 I 800 I ---~-- Notes Well is a single casing string (monobore) design that had a casing leak. The casing has been repaired by excavating around wellhead and patching from the outside. 1760 ¡ 1760 -~_.- -- I SCANNED AUG 2,.4 20GB Wednesday, August 09, 2006 Page I of I MIT KRU lC-131&121 08-03-06.xls e e «MIT KRU 1C-131&121 08-03-06.xls» Attached are the results from the State Witnessed MITIA's on post surface casing patch wells 1C-121 -'2Q1100f» and 1C-131 ~ (: dC)\-C)<6(J de::> \ - \ <iÇ ~ These MIT's also fulfill the 4 year MIT requirement and will reset the clock. In addition, they will be removed from the Monthly failed MIT report. Let me know if you have any questions MJ Loveland ";1" ~ ",j¡,I;;.t, ¡,,;...~..~. 'C,",;...t t· -"\ 1.2 Ie) <0; ConocoPhillips Alaska Well Integrity Project Supervisor Office (907) 659-7043; Cel (907) 448-3114 .. MIT KRU lC-131&121 Content-DescriptIOn: 08-03-06.xls MIT KRU lC-131&121 08-03-06.xls Content-Type: Content-Encoding: application/vnd.ms-excel base64 1 of 1 8/4/20067:42 AM e e STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Email to:Bob_Fleckenstein@admin.state.ak.us;Jim_Regg@admin.state.ak.us;Tom_Maunder@admin.state.ak.us OPERATOR: FIELD / UNIT / PAD: DATE: OPERATOR REP: AOGCC REP: ConocoPhillips Alaska Inc. West Sak / KRU /1 C 08/03/06 Rogers / Ferreira Chuck Scheve Packer Depth Pretest Initial 15 Min. 30 Min. We1l11C-131 I Type Inj. I w TVD I 3,705' Tubing 900 900 900 900 Interval I 0 p.T.D.12011850 I Type test I P Test psil 1500 Casing 650 1760 1740 1740 P/FI P Notes: Post SC patch OA na na na na Well1C-121 I Type Inj. I w TVD I 3,561' Tubing 800 800 800 800 Interval I 0 P.T.D.12010800 I Type test I P Test psil 1500 Casing 100 1790 1760 1760 P/FI P Notes: Post SC patch OA na na na na Weill I Type Inj.1 TVD I Tubing Interval I p.T.D.1 I Type testl Test psil Casing P/FI Notes: OA Weill I Type Inj.1 TVD I Tubing Interval p.T.D.1 I Type testl Test psi I Casing P/FI Notes: OA Weill I Type Inj.1 TVD I Tubing Interval I P.T.D.I I Type test I Test psi I Casing P/FI Notes: OA TYPE INJ Codes D = Drilling Waste G=Gas I = Industrial Wastewater N = Not Injecting W = Water MIT Report Form BFL 9/1/05 TYPE TEST Codes M = Annulus Monitoring P = Standard Pressure Test R = Internal Radioactive Tracer Survey A = Temperature Anomaly Survey D = Differential Temperature Test INTERVAL Codes I = Initial Test 4 = Four Year Cycle V = Required by Variance T = Test during Workover 0= other (describe in notes) MIT KRU 1C-131&121 08-03-06-1.xls e e WELL LOG TRANSMITTAL PRoAcrivE DiAGNOSlie SERvicES, INC. To: AOGCC. Attn: Ceresa Tolley 333 West 7th Avenue Suite 1 00 Anchorage, Alaska 99501-3539 RE : Cased Hole/Open Hole/Mechanical Logs and/ or Tubing Inspection(Caliper / MTTJ The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to : ProActive Diagnositc Services, Inc. Attn: Robert A. Richey 130 West International Airport Road Suite C Anchorage, AK 99518 Fax: (907) 245 - 8952 1 J 1C-119 MTT Report 1 6-May-06 ÂOI- o8~ 2) 1 C - 121 MTT Report 16-May-06 3) 1C-131 MTT Report 14-Jun-06 4J 10 - 127 MTT Report 14-Jun-06 5J 10 - 121 MTT Report 14-Jun-06 6) 1 0 - 109 MTT Report 1 5-Jun-06 7J 1 0 - 120 MTT Report 1 5-Jun-06 8J 10-111 MTT Report 15-Jun-06 Signed: M-wJ. öiJJ Print Name: µ D ~ (}...V'À~ Okltt~¿' Date: 1/ Ju~ ~ ~ ~ PRoAcTivE DiAGNOSTic SERVicES, INC., I ~o W. INTERNATioNAl AiRpoRT Rd SUiTE C, ANCItORAGE, AK 99~ 18 PItONE: (907)24~~89~ 1 FAX: (907)24~~89~2 E~MAil: pd~AÍ'.Jd;oRAGE@i\'1Hlonv¡oq.UJM WEbsiTE: MEMoRyIOG.coM c:\My Documents\ W ork\ DistributionLablesNew\ Transmit_ Original.doc I I I I I I I I I I I I I I I I I I I Company: Log Date: Log No. : Run No.: Pipe1 Desc.: Pipe1 Use: Pipe2 Desc.: Pipe2 Use: Pipe3 Desc.: Pipe3 Use: e e Memory Magnetic Thickness Tool Log Results Summary J.\) \' tJ e¡¡1J ConocoPhillips Alaska, Inc. May 16, 2006 8024 2 3.5" 9.2 Ib EUE Tubing 5.5" 15.5 Ib BTC-M Production Casing 16" 62.6 lb. H-40 Conductor Pipe Well: 1 C-121 Field: Kuparuk State: Alaska API No.: 50-029-23015-00 Top Log Intvl.: Surface Bot. Log Intvl.: 194 Ft. (MD) Top Log Intvl.: Surface Bot. Log Intvl.: 194 Ft. (MD) Top Log Intvl.: Surface Bot. Log Intvl.: 116 Ft. (MD) Inspection Type: Assess External Corrosive Damage (Metal Loss) to Production Casing. COMMENTS: This MTT data is tied into the Tubing Hanger @ 0' Depth. This is the first log of this well with the 12 Arm Magnetic Thickness Tool (MTT). The Magnetic Thickness Tool responds to the total thickness of metal of the 3.5" tubing, 5.5" production casing, and 16" conductor pipe within the logged interval. Due to the concentric pipe strings in the log interval, the MTT response is qualitative - indicating an overall increase or decrease in metal surrounding the tool, but not distinguishing in which pipe string the change in metal thickness occurs. In this log, the MTT was calibrated down hole (100'), where the readings are assumed to represent undamaged tubing, casing and conductor pipe. All other readings are relative to this reference point, which include influences from the 3.5"" tubing, 5.5" casing, and 16" conductor pipe. INTERPRETATION OF MTT LOG RESULTS: The MTT log results cover the interval 0' - 194'. A log plot of the entire log interval, plus detailed sections of intervals showing metal loss are included in this report. The Delta Metal Loss (%) curve in these plots refers to total metal surrounding the MTT tool and the results show two intervals of metal loss. A maximum of (7%) circumferencial metal loss is recorded in the interval between 4' and 10'. A maximum of (-5%) circumferencial metal loss is recorded in the interval between 48' and 62'. An increasing amount of metal loss, from 0% to 7%, is indicated between 10' and 4' in this well. A 3.5" tubing collar is located at 4', which could be masking a continued escalation of metal loss over the interval 4' to 2' below the tubing hanger. ProActive Diagnostic Services, Inc. ¡ P.O. Box 1369f Stafford, TX 77497 Phone: (281) or (888) 565-9085 i=ax: (281) 565-1369 E-maí!: PDS@memorylog.com Prudhoe Bay Field Office Phone: (907) 659-2307 Fax: (907) 659-2314 ¿;1.J))- ð ß ~ \.j \ (, I e e I The metal loss indicated between 48' and 62' appears to be related to the 3.5" pup joints rather than the 5.5" production casing. The MTT response near the top of 3.5" Pup Jt. 1.2 is showing increased metal due to an apparent 5.5" casing collar at this location. Disregarding this reading, both Pup Jt. intervals 1.2 and 1.3 show a relatively consistent lower volume of metal than the remainder of the pipe. This may be due to either external metal loss to these Pup Jts. or these two Pup Jts. may have slightly different metal characteristics than the remainder of the 3.5" tubing in the log interval. I I I The percent circumferencial metal loss expressed in this summary is a percentage of the total metal that the tool is responding to, which may include influences from the 3.5", 5.5" and 16" pipe. If all of the metal loss is specific to the 5.5" production casing, the percent metal loss from that pipe alone is probably higher than the numbers expressed. Some of the metal loss indicated could be from either the 3.5" tubing or 16" conductor. I I I I I I I I I I I I I Field Engineer: R. Richey & G. Chipman Analyst: M. Tahtouh & J. Burton Witness: T. Sendon I I I ProActive Diagnostic Services, Inc P.O. Box 1369, Stafford, TX 77497 Phone: (281) or (888) 565-9085 Fa:.:; (281) 565-1369 E-mail: PDS@memoryiog.com Prudhoe Bay Field Office Phone: (907) 659-2307 Fax: (907) 659-2314 I I I I I I I I I I I I I I I I I I I cSs. II\jIj... .£:- . . --- M___\ ¡\lI....1 II I~I II 111\..1\1 n::;;:);:) I D..¡;).¡;)J ->;;;II ~ DÌ"G......Tic SERviCE!;, ¡....,. Database File: u. WVOI , ,~ '"'21\1c121.db Dataset Pathname u IL !!lU¡1 ,/¡:.,a"",,.·0, 1 ..... Format: Dataset Creation Wed 1712:22422006 Calc Sondex WarrÎor V70 Charted in Feet scaled 1150 Delta Metal r' (%) (%) 50 125 MTTP01 (rad) 125 0 line Speed (ftJrI1in) -200 -6.3 MTTP12 (rad) 3.7 ~ Tree L I( I \. I I > I J Pup Jt. 0.1 I I 3.5" Collar 7% Metal Loss - - < 3.5" Jt 1 - c--- - - c--- - f----. 20 ¡-- - 1- - '--- I:---- r- - ¡-- - \ c--- ~ J I I 3.5" Collar 3.5" ( Jr. 1.1 40 3,5" Collar ~I I I r Jt. 1.2 ¡ ~" Metal Loss 3.5" Collar' I I +% Metal Jt. 1.3 I 60 3.5" Collar ~ l \ 3.5" I Jt 2 80 . - - ¡---- - c--- 1$ I r--- ~55" 2~~,,1" Collar I I I It , , , I I I I I I I I I I I I j I ~ 8- 35" Collar """""'II ::: 100 3.5" Jt 3 { ,+ ¡... Bottom of 16" - - 120 -.- I-- t--- ~ ~ I-- ;;;;;-55" Gas¡ng Collar " 5" Jt 4 -- -.. - 140 I - -- ~ -- 160 - (I l 3.5" = '- Jt 5 '-- ...- _.. ~5" Caslf!9 Collar '-- ) 180 ( ¡ ---. GI ~ - - -50 Delta Metal I ¡ II\.;KII\:::::;::; (%) (%) 50 2.5 MTTP01 (rad) 12.5 0 Line Speed (ft/min) -200 ~6..3 MTTP12 (rad) 3.7 I I I I I I I I I I I I I I I I I I I I I I I I I I cIrk nAt~il IIJI_À ,I I n~~ ~-¿'i - 1 - I ~ DiAq......Tlc SERvicES, INC. Database File: '-'...va, ,,, ,~v,v"c121\1c121.db Dataset Pathname: . .,., ,urv,,",' ,¡u.1 , Format: Creation Wed 1712:22422006 Calc Sondex Warrior V70 c;narrea În Feet scaled 125 -50 Delta Metal ~. . (%) 50 25 MTTP01 (rad) 12.5 0 Line Speed (ftlmin) -200 -6.3 IV! ! ! !-'1:L (rad) 3.7 \ TREE ,- - Hang - t,,,, <\ ·t~ (~ I\~( <::¡.., ( ( r'--. " ~ ~ ,'"..,., '- ~((' ('(~., I" D~p Jt 0 1 1", J': J' ~()/ 1..1" .-J tr' V ¿ ( =- 3.5" Colla, - I I þ S:::'~ II 7% Metal Loss I(y Ii ') í ( 4'. c if I) 3.5" , \' ') Joint 1 < > t J :> :> < ( ,1 (':> :" ) L 10 ) I ; , ì I I) -50 Delta Metal ~. . (%) 50 2.5 MTTP01 (rad) 12.5 0 Line Speed (ft/mín) -200 -6.3 MTTP12 (rad) 37 I I I I I I I I I I I I I I I I I I I clrk r ., ... II 'I n~~ ~..u u~ ~~ - - ~-.. ~1vE DiAq""",,1c SE""le"", INC, ~ File: ,- ':' ,~ l¿l \lCl2' .db ~ , ,,.~ , ~ r-dt! II 1<:11 r I~ "r ¡¡µ:ISS I u.1 - ,. VI" Icn. - Wed 17 1?'??'4? 2006 Calc 8v, 'YCA Warrior V7.0 ):::;r""""",r 'I. ~, in Feet scaled 150 c;nan:ea -50 Delta Metal IllIvK! !~SS (%) 50 2.5 MTTP01 (rad) 12.5 0 Line Speed {Íll! I iii I} -200 -6,3 2 (rad) 3.7 \ ~ , 40 lê I> ~ ~ ~ i ?:-. 3.5" $ - Jt 1.1 ~ \ - 1 3.5" Collar I ,I I ~ ) ) "<" 5.5" CasínJ Collar lJ/ 1/// ,,~ 50 3+% Metal Loss 35" f-- 'Pup Jt 12 -,--~ .- -. ...- '< .- - ".-.. 3.5" Collar: I ¡ f--- ~ 3.5" \ Jt 1.3 " ., 60 ) !_./. ¡~\ ~ r-- - y;; '-.. 3.5"1... ""'1 I ~ ¡,., '~ j ~ ~ ~ !, 1 > ¡ ) -50 Metal I! !lvK! It:SS (%) 50 25 IV! I ¡ l-'Ul (rad) 12.5 0 Ur~ C'~~'"' (ft/min) -200 -6.3 IV! ¡ I!-' :; (rad) 3.7 I 1 I ~ 1C~121 r-' API: 500292301500 Well Tvoe: INJ Anale @ TS: dea@ TUBING SSSV Type: None Orig 6112/2001 Angle @ TD: 22 deg @ 6876 (0-6155, Completion: 00:3.500. 10:2.992) Annular Fluid: Last W/O: Rev Reason: FORMAT 'ROOUCTlON CHANGE (0-6164, Reference Lo!:!: Ref LOQ Date: Last Uodate: 3128/2006 00:5.500, Last TaQ: 6693 .- TD: 6884 ftKB Wt:15.50) ~ 11/5/2001 MaxHOle~2054 ~ Description Size Top Bottom TVD WI Grade NIP- PRODUCTION 5.500 0 6164 3571 15.50 L-80 (6115-6116, CONDUCTOR 16.000 0 121 121 62.58 H-40 WELD I 00:4.480) PRODUCTION ~@9~ L-80 EUE8RD I I Too I I TVD I Thread 3.500 I 0 I Zone Status Ft SPF Date Type EUE8RD SBE interval TVD Comment (6153-6154, 6252 - 6296 3650 - 3691 WSD 44 4 11/2/2001 ¡PERF 2.5" HSD, BH Chgs, 60 deg 00:5.000) ohasina 6322 - 6360 3715 - 3750 WS C,WS 38 4 1112/200 1 ¡PERF 2.5" HSD, BH Chgs, 60 deg B ohasinç¡ 6370 - 6396 3759 - 3764 WSA4 26 4 11/2/2001 ¡PERF 2.5" HSD, BH Chgs, 60 deg ohasino 6418 6430 3804 - 3815 WSA3 12 4 1112/2001 ¡PERF 2.5" HSD, BH Chgs, 60 deg SEAL ohaslna (6155-6167, 6438 - 6466 3823 - 3649 WSA3 28 4 11/212001 IPERF 2.5" HSD, BH Chgs, 60 deg 00:4.000) I ohasina ¡G':~fI53ß _~3913· WSA2 ~ ~ 4 111412001 '~~ SEAL TAIL - ~ Ms" T,pel V M> I V Type I V 00 I Latch RO Ro" Cm'" (6157-5168, KBG-2-9 I~ DMY I 1.0 liNT I 0.000 I 0 16114/2001 I 00:4.000) Depth TVD Type Descrlotiol1 ID 6115 3527 NIP CAMCO 'OS' NIPPLE WINO GO PROFILE 2.812 6153 3561 SBE BAKER SBE 4.000 6154 3562 NIP CAMCO NO GO SUB 3.000 'RODUCTION 6155 3563 SEAL BAKER SEAL ASSEMBLY 3.000 (6164-6884, 00:3.500, 6163 3570 XO 5.5" x 3.5" 3.500 Wt:9.30) 6167 3573 SEAL TAIL 3.000 6228 3628 PLUG WRP set 8/6/2005 0.000 6362 3752 PLUG WiRELlNE RETRIEVABLE PLUG SET@6362'ELM 0.000 Perf -- f----- 6864 6864 SHOE 3.000 (6252-6296) - f---- Date I Note 11/4/2001/ LOST 2.5" X 1/4" ROLLER WHEEL, I=R STEM; MAYBE AT BOTTOM OF HOLE OR MAY Perf - - BE IN GLM @ 6072' (6322-6360) ----- -_. PLUG (6352-6363, OD:3.500) Perf -- f----- (8370-6395) --- '-- Perf --- -- (6418-5430) ---- _. Perf -- ---- (6438-6466) -- ---- Perf -- --- I .--.. -- (6506-6536) -- -...-. .....all ~ ~--~._._~'~----~~~-~~.~-_._.__.~~~..._..._._--~--_._.-----~_.,._._-_._-~~~ I I I I I I I I I I I I I I I I I Change Approved Program 0 2. Operator Name: ConocoPhillips Alaska, Inc. 3. Address: P. O. Box 100360, Anchora e, Alaska 99510 7. KB Elevation (ft): RKB 102' 1. Operations Performed: e RECEIVED e STATE OF ALASKA JUL 1 8 2006 ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERA TIONeska Oil & Gas Cons. Commission Other nc age Abandon 0 Alter Casing 0 Repair Well 0 Pull Tubing 0 Operat. ShutdownD Re-enter Suspended Well 5. Permit to Drill Number: 201-0801 6. API Number: 50-029-23015-00 . Stimulate 0 Waiver 0 Plug Perforations 0 Perforate New Pool 0 Perforate 0 4. Current Well Status: Development 0 Stratigraphic 0 Time Extension 0 o Exploratory 0 o Service 9. Well Name and Number: 1C-121 8. Property Designation: Kuparuk River Unit Ab L o~'" ý, ß 7 .z./. 0" 11. Present Well Condition Summary: 10. Field/Pool(s): Kuparuk River Field 1 West Sak Oil Pool Total Depth Effective Depth Casing Structural CONDUCTOR PRODUCTION-tapered PRODUCTION-tapered Perforation depth: measured 6876' feet true vertical 4228' . feet measured 6228 feet true vertical 3628 feet Length Size MD 121' 16" 121' 6062' 5-1/2" 6164' 720' 3-1/2" 6884' Plugs (measured) Junk (measured) 6228 TVD Burst Collapse 121' 3571' 4235' Measured depth: 6252 true vertical depth: ~;-' J.áJi,¡r';;¡f)! ¡ 11 .~ ,,1 20 D13 ~.<w~¡:,.,"i......,...;¡,io" \,,' v ~.... h 3650 Tubing (size, grade, and measured depth) 3-1/2" , L-80, 6155' MD. Packers & SSSV (type & measured depth) no packer no SSSV no SSSV 12. Stimulation or cement squeeze summary: Intervals treated (measured) Treatment descriptions including volumes used and final pressure: NA RBDMS 8FL JUl 2 4 2008 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casin Pressure Tubin Pressure Prior to well operation NA Subsequent to operation NA 14. Attachments 15. Well Class after proposed work: Copies of Logs and Surveys run _ Exploratory 0 Development 0 Service 0 Daily Report of Well Operations _X 16. Well Status after proposed work: oilD GasD WAG 0 GINJD WINJ 0 WDSPL 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: 306-093 Contact Printed Name Signature MJ Loveland / Marie McConnell Marie McConnell Problem Wells Supervisor 659-7224 Date Title Phone 7/17/2006 Form 10-404 Revised 04/2004 ORIGINAL e e 1 C-121 DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary 7/4/2006 7/6/2006 7/12/2006 7/14/2006 Removed 11' of conductor. Cement was removed from around the 5 1/2" casing. A hole in this casing was located at 6' 1/2" from top of mandrel hanger flutes. See photo#l Notified AOGCC State Insp. (Jeff Jones) @ 11:30 a.m. that the conductor has been cut, Waived visual Inspection @ 5:45 pm Weld SC patch, Seal weld 4' mandrel hanger pup threads to ABB Vetco gray mandrel hanger. Install 116" long, 51/2" X65 pipe, .375 wall thickness SC patch. Total length of damaged SC from top of mandrel hanger to lower section of vis able corrosion repaired is 112". Total / length of SC patch from upper weld located at bottom of Mandrel hanger to very lower most weld is 120 1/2" (10' 1/2") See photo #2 MITIA - Passed (see attached), Wrap SC with Denso corrosion resistant tape, Patched conductor with a 129" long section of 16",62.5#, API 5L Gr B Casing Conductor wil be topped off with cement and a corrosion inhibited waterproof sealant at a later date. \ ' Je ( \ /e \ Calculations Char ,--' ?roduc-hDJ1 C Q 51;....?! /) 5:.1 c - 12.1. Sleeve- KeJ'czír By ,AA /' , / ;'"'//?///l.k'oV¿C-Þ! Sheet number .i of.:L /78.r0 & Subject File Date .. 5eal weld I:::Ae. Co. Go ¡rt ø- /; h re Cf.J $ -. wellhead .. G/Vot./e.. L<../e./J5 c,y¡J 1:¡ï/et UA2-1d$ &-ð_ F'1'1 a tc h i,h /~Æ Y1~ß2 .of cð/!qr/s/eevé!; ~ - ~l:/;;'1 p) · ñét: ..Sleeve Cot/au- >"'1- -/::o,-/:;/e ,'r1&D t:-I,e / R btJe. 0+ -I::. h.~ . _ .5¿<::t! wgld .. LDC.Ct fe. .slee tie. C.o 110.f:$ ./¿/i:éh/f/1, ~L£ fhe Skeve hand~ 1~ f'5fC:;~;¿&./d ¡!;Dclef~~r4~. /~?~Á ·Pmdae-. f'DI1 ..c.aG¡';.¡# # 1/ 1/ /5 S /,2. ð D . Co. r t I ..~/$.:.jn7 fi · ,~L a $./:J:1.[} Ci(J//qC /I " ?f...~e. ...0 A..E} .£ 4..)( - X to S' o. 2& )~pfre.::...f.o.r the _".sLeeve collar;; .. tI'5e ~ "./l? / S'L'X - X r;,,s- ___ t). ZED II .W(:L1Lp:;~-ftnlÍ?L '_ _for -tAe sleeve. ø OverÇfj I ..s../e..ev.e.. Je,Y¡j fA J I" ..,., ~ Q-'8 ~_¡ .;;;;> _...J . - S.ee ur 5Æet~h ~r < de-ta./I'f> . f/lle.f:'weld.$ :t: <:>' ~·c::d:.::h c o.Ü a..c.1 ~le.~v..e.: I:::: hiGkYle$5 (t'1P) . , . . I Î. M 'ð(p. I I I I >-1 . "-'-1 I I I f I r ~. I ~... /---, F·~-·'".> -= .. f./ .~ - ~ ~.-.', ~ t "~., .... >;. ~ f-·~ '~li~)'V e e STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Email to:Bob_Fleckenstein@admin.state.ak.us;Jim_Regg@admin.state.ak.us;Tom_Maunder@admin.state.ak.us OPERA TOR: FIELD 1 UNIT I PAD: DATE: OPERA TOR REP: AOGCC REP: ConoeoPhillips Alaska Inc. West Sak I KRU /1C-121 07/14/06 Jon Arend/Dennis Sauvageau - ASRC àO\" O~O Packer Depth Pretest Initial 15 Min. 30 Min. Well11C-121 I Type Inj. I W TVD I 3,561' Tubing 0 0 0 0 IntervaT 0 P.T.D.12010800 I Type test I P Test psil 1500 Casing 0 3000 2990 2990 p/FI P Notes: Post SC patch OA Weill I Type Ini. I TVD I Tubin~ Intervall P.T.D.I I Type test I Test psil Casing p/FI Notes: OA Weill I Typelni.l TVD I Tubin~ Intervad P.T.D.I I Type tes~ Test psil Casing P/FI Notes: OA Weill I Type Inj.l TVD I Tubing Intervall P.T.D.I I Type tes~ Test psil Casing p/FI Notes: OA Weill I Type Inj.1 TVD I Tubing Intervad P.T.D.I I Type tesrl Test psil Casing P/FI Notes: OA TYPE INJ Codes D = Drilling Waste G=Gas I = Industrial Wastewater N = Not Injecting W = Water MIT Report Form BFL 9/1/05 TYPE TEST Codes M = Annulus Monitoring P = Standard Pressure Test R = Internal Radioactive Tracer Survey A = Temperature Anomaly Survey 0= Differential Temperature Test INTERVAL Codes I = Initial Test 4 = Four Year Cycle V = Required by Variance T = Test during Workover 0= Other (describe in notes) MIT KRU 1C-121 7-14-06 RE: KRU 1 C-121 & 1 C-131 Passing MIT data e e Tom, Going very well. The 1C-121 & 1C-131 repairs were the best executed yet. These are a lot of work as it involves several groups from construction for scaffolding and shoring box, roads and pads group for excavation and backfill, drill site operations for safety work permits, OHD prep and N2 purge support, Well Integrity Engineering project management (MJ, Jerry, myself), welders to remove conductor landing ring and fab and install both surface casing and conductor patches, insulators to install den so anti corrosion coating, and wellwork to set and pull plugs. We are planning to break ground on the next 2 wells, the first ones at 1 D, 1 D-1 09 and 1 D-111, on Sat 7/22. If all goes well, the conductor will be removed at the end of July and welding repairs will be completed the first week of August. Even with the efficiencies gained by doing 2 wells side by side, they will probably take 3 to 4 weeks per set of two as we work down the list Jerry sent last month rather than 2 every 2 weeks. These are very interesting projects from an engineering prospective, so they are fun to work even with all the extra workload. Marie -----Original Message----- From: Thomas Maunder [mailto:tom_maunder@admin.state.ak.us] Sent: Tuesday, July 18, 2006 8:03 AM To: NSK Problem Well Supv Subject: Re: KRU lC-121 & lC-131 Passing MIT data Thanks Marie. How goes the "big dig"? Tom NSK Problem Well Supv wrote, On 7/17/2006 10:40 PM: Tom, Jim, & Bob, Attached are MITs for 1C-121 (PTD 2010800) & 1C-131 (PTO 2011850) post single casing excavation welded sleeve patch repair. The repairs were completed on 7/12 and 7/13. 10-404's are in the mail reporting completed repair operations under sundry approvals 306-093 & 306-178. Both wells will be schedule for witnessed MITIAs after BOI and thermally equalized, tentatively planned for August 2006. Once witnessed MITIAs pass, the wells will be removed from the failed MITIA report. Please let me know if there are any questions. «MIT KRU 1C-121 7-14-06.xls» «MIT KRU 1C-131 7-14-06.xls» Marie McConnell 7/19/2006 9:09 AM KRU 1 C-121 & 1 C-131 Passing MIT data e e Tom, Jim, & Bob, Attached are MITs for 1C-121 (PTD 2010800) & 1C-131 (PTD 2011850) post single casing excavation welded sleeve patch repair. The repairs were completed on 7/12 and 7/13. 10-404's are in the mail reporting completed repair operations under sundry approvals 306-093 & 306-178. Both wells will be schedule for witnessed MITIAs after BOI and thermally equalized, tentatively planned for August 2006. Once witnessed MITIAs pass, the wells will be removed from the failed MITIA report. Please let me know if there are any questions. «MIT KRU 1C-121 7-14-06.xls» «MIT KRU 1C-131 7-14-06.xls» Marie McConnell Problem Well Supervisor 659-7224 KRU IC-121 Content-Description: MIT KRU 1C-121 7-14-06.x1s Content-Type: app1icationlvnd.ms-excel Content-Encoding: base64 KRU IC-131 Content-Description: MIT KRU 1C-131 7-14-06.x1s Content-Type: app1icationlvnd.ms-exce1 Content-Encoding: base64 1 of 1 7/18/20068:01 AM e e STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Email to:Bob_Fleckenstein@admin.state.ak.us;Jim_Regg@admin.state.ak.us;Tom_Maunder@admin.state.ak.us OPERATOR: FIELD I UNIT I PAD: DATE: OPERATOR REP: AOGCC REP: ConoeoPhillips Alaska Inc. West SakI KRU 11C-121 07/14/06 Jon ArendlDennis Sauvageau - ASRC }~ot - 030 ~ 'l e--I1-/ Packer Depth Pretest Initial 15 Min. 30 Min. We1l11C-121 I Type Inj. I W TVD I 3,561' Tubing 0 0 0 0 Interval 0 PTD.12010800 I Type test I P Test psil 1500 Casing 0 3000 2990 2990 P/FI P Notes: Post SC patch OA Weill I Type Inj. I TVD I Tubing Intervall P.T.D.I I Type test I T est psi! Casing P/FI Notes: OA Weill I Type Inj.1 TVD I Tubing Interval I p.T.D.1 I Type testl Test psil Casing P/FI Notes: OA Weill I Type Inj.1 TVD I Tubing Intervall PTD.I I Type testl Test psil Casing P/FI Notes: OA Weill I Type Inj.1 TVD I Tubing Interval I PTD.I I Type testl Test psil Casing P/FI Notes: OA TYPE INJ Codes D = Drilling Waste G=Gas I = Industrial Wastewater N = Not Injecting W = Water MIT Report Form BFL 9/1/05 TYPE TEST Codes M = Annulus Monitoring P = Standard Pressure Test R = Internal Radioactive Tracer Survey A = Temperature Anomaly Survey D = Differential Temperature Test INTERVAL Codes I = Initial Test 4 = Four Year Cycle V = Required by Varianèe T = Test during Workover 0= other (describe in notes) MIT KRU 1C-121 7-14-06.xls lrwu: ~UIlUL:UrIllllljJ~ CXL:aVallUll (X, 1'..c;jJal1 rlVJC;~lJ ~. "- Subject: [Fwd: ConocoPhillips Excavation & Repair Project] From: Thomas Maunder <tom _ maunder@admin.state.ak.us> Date: Tue, 20 Jun 2006 07:00:24 -0800 To:tou Grimaldi <Iou _grimaldi@admin.state.ak.us>, John Spaulding 6jPlfu _ spaulding@admin.state.ak.us>, John· Crisp <john _ crisp@adrnin.state.ak.us>~]eff Jones . ;.gefUones@admin.state.ak.us>, Chuck Scheve <chuck _ scheve@admin.state.ak.us>, Jim Regg <ji111.-regg@adnùn.state.ak.us> All, Enclosed, FYI and scheduling, is a message from Problem Wells regarding the "big dig" project they will be starting soon. Jerry has also included a copy of the SPE paper he/they prepared regarding causes and repairs. Tom Subject: Date: From: To: CC: -------- Original Message -------- ConocoPhillips Excavation & Repair Project Mon, 19 Jun 2006 14:06:18 -0800 NSK Well Integrity proj <N1878@conocophillips.com> tom maunder@admin.state.ak.us Ñ-sKwe-fi--Integrity --Proj <N1878@conocophillips . com> , aogcc prudhoe bay@admin.state.ak.us 5CANNEO JUN 272005 \<:-\ð\ d\J \ -()R-O Tom: I donlt remember how much of our plans we have shared with you on excavating and repairing wells at lC & ID pads. We have been submitting a lot of 10-403s for the work and there is a reason for that. Starting in the next two weeks we will focus on this project, which is pretty ambitious. The attached spreadsheet lists the wells we intend to excavate. Some of these were determined this last year to have surface casing leaks. Others we have chosen to "pro-activelyll excavate and inspect to get a better understanding of the level of damage to be expected for the other single casing wells. At any point in time we will have two wells in progress, and hope to continue for the bulk of the summer. A couple of them we will intentionally target late in the year when the ground has less water encroachment problems. We have submitted Sundry requests for all but one well, three of which are in the mail to you today. Like the others, we expect that you agree inspections and repairs on these wells are important and will approve those as well. As we go through the project we will keep the Inspectors notified of our progress so they can see these casings exposed. However, we will be under a tight timeline and will not hold excavations open longer than is necessary. Hopefully they can arrange to inspect them in the several day period that each of them is exposed. If you have any questions about our project please let us know. The SPE paper we wrote on the subject is a good primer on the mechanism involved. I have attached a copy in case there is interest in your shop. Talk to you soon. «lC and ID Casing Repair List AOGCC.xls» «SPE-I00432-PP SC Corrosion West Region 2006 Final.doc» Jerry Dethlefs Problem Well Supervisor ConocoPhillips Alaska 907-659-7043 Content-Type: application/vnd.ms-excel 1 C and ID Casing Repair List AOGCC.xls Content-Encoding: base64 SPE-I00432-PP SC Corrosion West Region 2006 Final.doc Content-Type: application/msword 10f2 6/26/20067:51 AM PRIORITY NAME JO\-01>O --,. 1 ~ 1C-121 1 C-131 10-109 _._. '_.'__."..".",,_.,.,_m_ 1 0-111 1 0-120 .. ~"'---' - . - 1 0-121 t:D....1;27. 1 0-132 1Q-136 1 D-137 1 D-138 ...- . "_.....~..._._,--_..__..,,,...-.-,,.-.,..- 1D-139 1 C-119 - -1:c:tå$- . ··1 ····················-····1·P:1:35-·'..·····..··:··..·-··· ~.,-_._--_._..._..,_..,..:-.__......c.__.._..~._._..-1... 1D-141 I 2 3 4 ) 5 6 7 8 9 10 11 12 13 14 15 16 Notes: ConocoPhillips Alaska, Inc. 1 C and 1 D Suñace Casing Corrosion Repair Candidates TYPE INJ INJ INJ INJ INJ Gas Lift Gas Lift INJ INJ INJ INJ INJ INJ Jet Pump ESP Gas Lift COMMENTS I STATUS prD# LEAK DEPTH (ft) 201-080 4 201-185 7 - _._ .·_._____m________._ - 197 -235 5* - .-----.-"'-----.-...-.- 198-166 5* -.- 197-221 7 197-181 None 198-109 None 198-121 5 200-046 None 200-047 None 200-048 8 200-049 None 201-139 16 ----- - 201-220 None - -"'-.--.-....-.--...-- 197-184 None - 200-112 None Proactive dig Proactive dig Proactive dig Proactive dig Proactive dig Proactive dig Proactive dig, backup candidate (has 5001 casing) Proactive dig backup candidate. 1. Repairs will be performed in the priority order as listed, two repairs in progress simultaneously. 2. 10-135 and 1 0-141 are backup options in case excavations cannot be made on other wells. 3. List is a combination of wells with known leaks (8) and proactive inspections (2 injectors and 3 producers). 4. Proactive inspections are scheduled for wells that are currently shut-in and should not have rate impacts except 1 C-135 Jet Pump producer. 5. Rate impacts may be encountered if neighboring wells are shut-in during excavator activities or if additional flowlines need removal. 6. If excavations cannot be completed prior to rig arrival then SIMOPS operations will be considered or delays will be encountered. NSK Problem Well Supervisor 6/26/2006 e e dO\-C~Ò tŒCRÞ~ICAL INTEGRITY REPORT ........ -~UD ~.~- ~:-,,, iJ :;,~ .:...:. : '4 ~-O\ .. \'/õ\-O\ OPER & FIELD <.. \7 ~ -s:- ~\-S<:.l~ ~Ž:LL NUM:B ER \ c... - \ if \ :. ~ G 2 S ~ .:: ;~ S.:: : ',·d:..LL DATÞ_ TD: <o<6-'t<':'MJ)q 4ðð~ TVD; ?ETD: b <6oò MD ~ \(,Ò TVD Cê.sÜ;g: ~~-. _ -,-.j e:. .. S\/J Shoe: G, ,<o~ HD 3\/"J Shoe: (,~G HD S~Q 1'\.....""'1.. -=-'JO i.:; g : 3\b. Packer \ç) ~.J-:"ill ::ole Size ,"'1<6 ê.na TVD i DV: MD ·TVù Tift; :CP: ~ ,~S- ~·m See ê.C G:,tS-~- <O~S if co '-53 ~ ~\~ \~~~\ -:~;ìJ TVu í Pe:r£3 :-:::::C?..Þ.lr~:c':-L INTEGRITY - P .filiT /1 ,,,~.... Annulus Press Test: îP : 15 min ; 30 min .. \ Cowoents: ~'?~~ -\-~'II'.(~ ¢I..C\. ~Saoa ~..;\ ~\-.c.~(..c:;~~~\eJ ,,'\.\"\'\ ~~s~~ "?> /"'" -Ö .ç- /' COO ~b~~'4<':'~~~\~ \ r 1 Co') s'"" (<ts-O\'~\~\ C s g \ ; DV .. '-:'P-H)~\"'" c'-~~\\ sá'\<:..\~f\.~ \ö ca~\- ~ l(~' ~CHÞ~IC;l INTEGRITY - PMZT 12 Ce:nenc Volume.s:· Þ..mt. Liner C~c ~ol to cover ùe:r=s 'l"heorecical TOC (\ 50 \.:J ~ \.~ Q \- ceo t;,",,(~_,,- \-- ~~'> è R.~ '0. ~ à d (ßL-~(hr ""l(lO-o\ Ceme-nt Bond Log (Yes or NO)1(t'7 i In AOGCC File. '<.ês. CEL :::valuation, ::one ê.Dove perfs ~t-(' 'Ù~~'\Ci.\,)\Q- 'où\.~-.:s~('.\f'\- ~ ~~t ~\Ct.<>~ù\(è \(O-~<:> "-.J I '?,.C~Q: \",~~~...\r Production Log: !ype i Evaluat:i.on CONCLUSIONS: C\ ? ar; t 1 : \J,::C ~(.,. '::. ~. fV'ö~ ~k~{j µ~"... \~~tv-~0'--;(fl , ..- ~ 0·0 ?JIVl ~lj?J--Ô ~ ?ar:: ;2: '" " ~ ¡ e e (ill FRANK H. MURKOWSKI. GOVERNOR A. 1',A.SIiA. OIL AND GAS CONSERVATION COMMISSION 333 W. 7'" AVENUE. SUITE 100 ANCHORAGE. ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 MJ Loveland Problem Wells Supervisor ConocoPhillips Alaska, Inc. PO Box 100360 Anchorage, AK 99510-0360 Re: Kuparuk River Field, West Sak Oil Pool, 1C-121 Sundry Number: 306-093 ðO ðlOV-~ Ou Dear Mr. Loveland: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Sincerely, DATED this~day of March, 2006 Encl. e e ConocJÃ,illips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 March 16, 2006 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 ào\- b8b Dear Mr. Maunder: Enclosed please find 10-403 Application for Sundry Approval to repair a surface casing leak for ConocoPhillips Alaska, Inc. wells 1C-119 (PTD # 201-139), 1D-109 (PTD # '-197-'7.35), 1C-12l PTD (201-080). ~lease call Mane McConnell or me at 659-7224 if you have any questions. Sincerely, Problem Well Supervisor Attachments · C(J p. A RECEIVED STATE OF ALASKAP}s ')¡-(5I/£ ~6o MAR 2 0 2006 ALASKA OIL AND GAS CONSERVATION COMMISSION . . APPLICATION FOR SUNDRY APPROV Al.!'laska Oil & Gas Cons. CommisSion 20 MC 25.280 Anchorage o Suspend 0 Operational Shutdown 0 Perforate 0 Waiver 0 Other 0 o Repair well 0 Plug Perforations 0 Stimulate 0 Time Extension 0 o Pull Tubing 0 Perforate New Pool 0 Re-enter Suspended Well 0 5. Permit to Drill Number: 201-080 6. API Number: 50-029-23015-00 9. Well Name and Number: 1C-121 1. Type of Request: Abandon Alter casing Change approved program 2. Operator Name: ConocoPhillips Alaska, Inc. 3. Address: P. O. Box 100360, Anchorage, Alaska 99510 7. KB Elevation (ft): RKB 102' 4. Current Well Class: Development 0 Stratigraphic 0 Exploratory 0 Service 0 8. Property Designation: 10. Field/Pool(s): Kuparuk River Field / West Sak Oil Pool 11. PRESENT WELL CONDITION SUMMARY Total depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 6876' 4228' 6228 3628 6228 Casing Length Size MD TVD Burst Collapse CONDUCTOR 121' 16" 121' 121 PRODUCTION 6062' 5-1/2" 6164' 3571 PROD LINER 720' 3-1/2" .... 6884'· 4235 Plug Integrity 0 BOP Test 0 Other: <...O,,~\- I~~c~~\'C~~C\" ~ .~\\-~>"> ~, , \:.~ ~~C-~M.~~'~ ~r-.., Or;. te.c..~ ~c..o.\.\~t'--~ ~~\\' Perforation Depth MD (ft): 6252 Packers and SSSV Type: no packer no SSSV 12. Attachments: Description Summary of Proposal 0 Detailed Operations Program 0 BOP Sketch 0 14. Estimated Date for Commencing Operations: 16. Verbal Approval: Commission Representative: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Printed Name MJ Lovel nd Perforation Depth TVD (ft): Tubing Size: 3650 3-1/2" Packers and SSSV MD (ft) Date: no SSSV 13. Well Class after proposed work: Exploratory 0 Development 0 15. Well Status after proposed work: Oil 0 Gas 0 WAG 0 GINJ 0 Contact: Title: Phone 659-7224 Signature Commission Use Only Conditions of approval: Notify Commission so that a representative may witness Mechanical Integrity Test 0 Location Clearance 0 Approved by: Subsequent Form Required: APPROVED BY THE COMMISSION MA , ~ Tubing Grade: L-80 Tubing MD (ft): 6155' Service 0 Plugged 0 WINJ 0 Abandoned 0 WDSPL 0 MJ Loveland / Marie McConnell Problem Wells Supervisor Date Date: 3 -2-0,06 /$b, 3·Zè)·¿)6 Submitin Duplicate ./Þ//f 1Jbo/~t e e ConocoPhillips Alaska, Inc. Kuparuk WelllC-121(PTD 201-080) SUNDRY NOTICE 10-403 APPROVAL REQUEST February 27,2006 This application for Sundry approval for Kuparuk well 1 C-I21 is for the repair of a production casing leak. This well is a single casing injector; it has no surface casing. It was completed in June 2001. On August 03,2005, the well failed an MITIA. A leak rate could not be established but the leak depth has been estimated at 4' below the production casing annular valve corresponding to the top of cement in the conductor. Since the mode of failure is suspected to be the same as other wells with similar construction, it is requested to inspect and repair the production casing near surface on this well. With approval, repair of the production casing will require the following general steps: 1. Notify AOGCC Field Inspector of repair operation so they may witness the event. 2. Safe-out the well with plugs amUoadthe tubing and IA with seawater and diesel freeze protection cap. 3. Remove the floor grate and equipment from around the wellhead. 4. Install nitrogen purge equipment for the IA and conductor so that hot work may be conducted in a safe manner. 5. Cut away the conductor casing and remove cement around surface casing for inspection. Approximately the top ten feet of conductor will be removed to provide access to the production casing. 6. CP Al Mechanical Engineers will determine appropriate patch and/or repair to return the casing to operational integrity. 7. QA/QC the repair and MIT-IA for a final integrity check. 8. Install anti-corrosion coating as specified by CP Al Corrosion Engineer. 9. Replace the conductor and fill the void with cement and top offwith sealant. 10. Backfill as needed with gravel around the wellhead. 11. Remove plugs and return the well to production. 12. File 10-404 with the AOGCC post repair. NSK Problem Well SupelVÎsor 05/07/05 ... 20 ¡ Failed MITIA Subject: IC·12] (PTD 201-080) Failed M!TlA From: NSK Prob!¢m Wen Supv <nI617@co!1ocophíHìps.com> Dat~: 07:19: 17 .0800 To: James Regg Tom, Last night during our Mono annulus testing, psi Incremental pressure step (1500 psi) when on Injection well1C-121 (PTD 201-080) felled with liquid to was observed rising in the conductor. up the conductor. The IA was 5 mlnut"s Into the 3rd 500 The MIT· T passed to 2000 psi and the well Is 81 and secured with a TTP. Planned actíons Include pulling the TTP, running a caliper and then resetting a TTP The well will remain SI until a 10-403 and repair plan Is In place. The well will be added to the failed MIT report. I have attached a 6 month TIO and a well bore schematic. The MIT form will be sent under a separate message. Let me know If you have any questions. MJ Loveland ConocoPhilllps Problem Well Supervisor 659--7224 «1C·121.pdf» Content-Description: lC-12Lpdf Content-Type: applìcationJoctet-stream Content-Encoding: base64 ~~f~1._A___~___ PROO LINER - (6164-<>884, 00:3.500, Wt:9.30) Perf (6252-8296) Perf (6322-8360) PLUG - (6362-8363, 00:3.500) Perf (6370-8396) Perf (6418-6430) Perf (6436-6466) Perf (6506-8536) SHOE (6864-<>865, 003.500) NIP- (6154-8155, 00:4.500) SEAL - :6155-6167 00:4.000 SBE- (6153-6154, 00:5.000) ¡. V Type"--"'V OD CAI\i1.Ç.9 _.. ... 1 ~ 9..__._.. INT Port TRO 0.0"00 ¡ 0 Date Run 6/.1 ~/200 1 Man Type V'Mfr IPERF Latch Vlv Cmnt NIP- (6115-8116, 00:4.480) TUBING - (O.Q155, 00:3.500, 10:2.992) 'ROOUCTION - (0-8164, 00:5.500, Wt:15.50) I f Annular Fluid: Reference Log: . Last Tag:, 669~_. Last Tag Date:.:.1 Y§/2001 Casing S.~~'ng.~ ALL STRI~G.ª...... .I?e.~cription on. . Size CONDUCTOR 16.000 PRODUCTIÒ'N . 5.500 PROD LlNËR"" : 3.500· :Tïi¡¡j~iiª~r!!1g.~.WBIN·G··.·.-·:·=:=~~____... .. . I Size .... __. Top . ~Q!tom : 3.500 0 6155 : p..flIrfQrat¡õI1s Summary . . : Interval TVD : 6252 - 6296 3650 - 3691 . 6322 - 6360 3715 - 3750 6370 - 6396 6418 - 6430 6438 - 6466 39Ù- 3759 - 3784 3804 - 3815' 3823 - 3849 6506 - 6536 ¡ 3886 Gas Lift MandrelsNalves St . MD . TVD- ""Man Mfr 1 : 6072 3489 CAMCO KBG-2-9 DMY ottïëï::(plugs. e.quip'.,._~~ç,f-··:fËWELRY___._.. ._.___ _... n.... .Q.epth . TVD. Type . .... . . . Description ID _ . 6115 3527, NIP CAMCO 'DS' NIPPLE WINO GO PROFILE 2.812 i 6153 : 3561! SBE'" - - BAKER SBE ... n.. . ÙOO ' 6154 . 3562 ' NIP'" CAMCO NO GO SUB - un_ 3.000 6155 . 3563 SEAL ,-BÃKER SEAL ASSEM'BL Y 8040 GBH-2i- 3.000 , 6167 3573 SEAL TAIL··.. " ...-.. . 3.000 ¡ 6362 3752: - 'PLUG . WIR~.L.lÑE RETRIEVAI?~~ þLUG SET @ 63~?:. !=LM 8/7/2002 0.090 .- 6864 : 6864 SHOE , 3.000 .nerl!i.~q!es .. '.' ....n:__.:.....___........:. :.. .. no.. . . _....__._.: :....:.':'::"--~::~: __.___. .. . ...__n . n._. _.. - _. _...... ; Date . Note : 11/4/2001; LOST 2.5;; X 1/4" ROLLER WHEEL FROM ROLLE'R STEM; MAY BE'AT BOTTOM OF HOLE OR MAY-·... BE IN GLM 6072' WSA2 WS C.wS B WS A.4 WSA3 WS A3 30 Status ...- Ft SPF Daië:: .:: .:.... Ty'pe 44 4 11/212001 IPERF 3'8 4 11/212001 .. IPERF '; 26 .____. I 4 11/212001 . ¡PERF I 12 4 1112/2001 ¡PERF 28 4 11/212001 IPERF 4 11/412001 . Comment 2.5"·HSD. BH Chgs, 60 deli' phasing .. 2.5" HSD. BH Chgs. 60 deg phÐsing .. 2.5" HSD, BH Chgs. 60 deg phÐsing . . . 2.5" HSD. BH Chgs, 60 deg phasing .. . 2 5" HSD. BH Chgs. 60 deg phasing. . . 2.5" HSD. BH Chgs. 60 deg phasi':1g Zone WSD ----.----.- - TVD . .._ 3~6:r--- Top o o .~.1p'4 Bottoni ... -T-' 121'- ·-·-t.... ''6'164 ' --6884 TVD 121 3571 ...__~884 ·~_:_·G¡;ade 9 -.39.__.1... ï.:=-so' ¡ Wt 6i58 15.50 .~.~Q. --_. ï3radë- 1-1:40'" L-80 L~SO - .-.. Thre-ã'if" EUE8RD ... ..... ....... Thread \IY~LD'" BTC-MOD EUE8RD ·-1 Ref Log Date~~".-": TO: 6884 ftKB .M~:x}joleAngle: ?9_q~g:·@ 2054 .! Last Updat!'!. Reformat. show perfs 3/5/2004.._. ~ i 1C-121 ~--... API: SSSV Type: 5Ó029i3Õ"1500 None Well Type: INJ . ..... Orig 6/12/2001 Completion: _.. Last W/O: e ConocoPhillips Alaska. Inc. e KRU 1 C-121 - I - AngiE! @ TS: deg @ Angle @ TO: 22 deg @ 6876 ; Rev Reason: e e MICROFILMED 07/25/06 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE F:\LascrFiclte\CvrPgs _ Inserts\Microfihn _ Marker. doc ) ) STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Email to:Tom_Maunder@admin.state.ak.us;Bob_Fleckenstein@admin.state.ak.us;Jim_Regg@admin.state.ak.us OPERA TOR: FIELD I UNIT I PAD: DATE: OPERATOR REP: AOaCC REP: ConocoPhillips Alaska Inc. West Sak 1 KRU/1 C 08103/05 Rogers - AES Waived by John Crisp 1('~1 0/3 )DÇ' ~ ~\\,¡, ~:a¡::,_q'e't70' ,;~\!ifj!!ir"'w" Packer Depth Well 1 C-121 Type Inj. N TVD 3,561' Tubing ~ P.T.D.2010800 Type test P Test psi 1500 Casing ~-, Notes: Mono-Annulus Integrity Verification MITT with plug in tbg. Pretest o o Initial 15 Min. 30 Min. 2000 1950 1930 000 Interval P/F o P We1l1C-121 Type Inj. N TVD 3,561' Tubing 1900 1900 Interval 0 P.T.D. 2010800 Type test P Test psi 1500 Casing 0' 1500 P/F F Notes: Mono-Annulus Integrity Verification MITIA with plug in tbg. Fluid came to surface up conductor after 5 min of 1500 psi on IA Well 1 C-117 Type Inj. N TVD 3,685' Tubing 0 2050 2000 2000 Interval 0 P.T.D.2011210 Type test P T est psi 1500 Casing 0 0 0 0 P/F P Notes: Mono-Annulus Integrity Verification MITIA with plug in tbg. Well 1 C-117 Type Inj. N TVD 3,685' Tubing P.T.D. 2011210 Type test P Test psi 1500 Casing Notes: Mono-Annulus Integrity Verification MITT with plug in tbg. Well P.T.D. Notes: Type Inj. Type test TVD Test psi 2,000 2,000 2,000 2,000 Interval 0 0 2,510 2,400 2,360 P/F P Interval P/F Tubing Casing Test Details: SCANNED AUG 0 ~ f..Omi TYPE INJ Codes F = Fresh Water Inj G = Gas Inj S = Salt Water Inj N = Not Injecting TYPE TEST Codes M = Annulus Monitoring P = Standard Pressure Test R = Internal Radioactive Tracer Survey A = Temperature Anomaly Survey D = Differential Temperature Test INTERVAL Codes I = Initial Test 4 = Four Year Cycle V = Required by Variance T = Test during Workover o = Other (describe in notes) MIT Report Form Revised: 06/19/02 2005-0803_MIT _KRU_1 C-117 _MITT.xls fOpèrationsPerformed: Abandon STATE OF ALASKA ALASKA Oil AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS D$uspèl1d .0.... ()peratioriShlJtdown 0 . . 0 . Rèþaii'\lVéll Dmpl~!i¡:>ørtöÏ'å~()n$. 0 0 Pull Tubing 0 Perforate New Pool 0 4. Current Well Status: Development D Stratigraphic D 6tJî~f0 w]:,Vj ~ ¿J II- Pe¡fôrate ...0 . . StimÛlateD. . AltetGa;sihg Change Approved Program 2. Operator Name: ConocoPhillips Alaska, Inc. 3. Address: P. O. Box 100360 7. KB Elevation (ft): RKB 102' Variance. . 0 <AnÞ\Jlâr[)i~~.D Timé EXtension D. Re-enter Suspended Well D 5. Permit to Drill Number: 201-080 / 6. API Number: 50-029-23015-00 Exploratory 0 Service 0 9. Well Name and Number: 1 C-121 8. Property Designation: Kuparuk River Unit 11. Present Well Condition Summary: Total Depth Effective Depth Casing Structural CONDUCTOR PRODUCTION PROD LINER Perforation depth: 10. FieldlPool(s): West Sak Oil Pool measured 6876' feet true vertical 42281 feet measured 6800 feet true vertical 4160 feet Length Size MD 1211 16" 121' 60621 5-1/2" 61641 7201 3-1/2" 6884' Plugs (measured) Junk (measured) TVD Burst Collapse 121' 3570' 42361 Measured depth: 6252-6296; 6322-6360; 6370-6396; 6418-6430; 6438-6466; 6506-6536 RECEIVED true vertical depth: 3650-3691; 3715-3750; 3759-3784; 3804-3815; 3823-3849; 3886-3913 Tubing (size, grade, and measured depth) 3-1/2" , L-80, 6155' MD. MAtt 1 2 2004 AIaIka Oil & Gas Cons. Commission Anchorage Packers & SSSV (type & measured depth) no packer no SSSV no SSSV 12. Stimulation or cement squeeze summary: Intervals treated (measured) . N/A . 13. Treatment descriptions including volumes used and final pressure: Prior .to well operation Subsequent to operati.on 14. Attachments . Copies of Logs and Surveys run - Daily Report of Well Operations _X 135 15. Well Class after proposed work: Exploratory 0 Development 0 Service 0. 16. Well Status after proposed work: oilD GasD WAG0 GINJD WINJ D 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or Nt A if C.O. Exempt: Oil-Bb Representativ~ Daily Average Production or Injection Data as- cf Wat r.Bbl 222 1367 2232 WDSPL 0 MAR 15 200~""': \~~,'~,,, ;1 . .ÖQntaot... Signatur . Title ..... ~h6hé øønu-~ Bfl Form 1 0-404 R~~t'Jt13 . ,'S~.i'.'~;Ji~~r\:JiEr:) MJ~~~ 1 5 2fU1~ -..~\ :1 'SeeMIT IN DUPLICATE ,I' \ r 1C-121 DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary 02127/04 QØrnmêncedWAGEORln~ection " ~ 4f1" 12/08/03 Schlumberger Well Job# Log Description NO. 3057 Company: Alaska Oil & Gas Cons Comm Attn: Lisa Weepie 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Kuparuk Date BL Color CD 11/24/03 1 11/26/03 1 11/27/03 1 11/30/03 1 10/31103 I 1 10/22/03 I 1 11/21/03 1 11/16/03 I 1 Schlumberger Technology Corporation, by and through is Geoquest Division 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Beth 3B-01 1 L-09 1 C-119 1 C-121 ~'-Q3~ 1 D-110A f)ðo-J4 1D-140L1 2P-432 )cól-Cfi. \ 2P-432 \\ -()7£~ 10687658 nLr;;L f\ IJ::1t"\ ~ -:---. . "'-. --- SIGNED: ~ \.' -----, , é. t \ /\1"-. -\ ,,\. C 0 ' . -"'- ~ /v""'" , DATE: DEC 12 2003 Alaska Oii & Gas Cons. (;ommls~n . .. Anchorage Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. ~~~ ~/~ ~ 3~ DATA SUBMITTAL COMPLIANCE REPORT 11/25/2003 Permit to Drill 2010800 Well Name/No. KUPARUK RIV U WSAK 1C-121 Operator CONOCOPHILLlPS ALASKA INC API No. 50-029-23015-00-00 MD 6876-- ND 4228""- Completion Date 11/2/2001 r-- Completion Status 1WINJ Current Status 1 WI NJ REQUIRED INFORMATION Mud log No Samples No Directional Survey - -N6- 1~-' DATA INFORMATION Types Electric or Other Logs Run: Well log Information: log/ Data Digital Type Med/Frmt I log ¡ED C ¡log ~ i I~ I~ I (data taken from logs Portion of Master Well Data Maint) ~~- Electr Dataset Number Name -t1'@Üct¡OrtlB~si$tiY¡ty.. . c/f1257 ;Líàv~i¡fiÇèiìQn . -1ø~¥r1]ØR~Y. . _....~............................................................ "'1:1SVeríficatioh . Log Log Run Interval OHI Scale Media No Start Stop CH Received Comments 25 Blu 1-4 161 6876 aÄ.Case- 11/6/2002 -- ----I 6834 "¿¡slt 11/6/2002 I 1 161 i I 25 Blu 1-4 161 6876 Case 11/6/2002 I 161 6834 Case 11/6/2002 I -1-£1 6876 Cä::>t:: 11/0/2002 - I) '.)of,) fl'}" 1 . 5 FINAL 6038 6706 Case 8/3/2001 6038-6706 Color Print I () f_!_~~LJ Sample Set Sent Received Number Comments Well Cores/Samples Information: Name Interval Start Stop Well Cored? ADDITIONAL INFORMATION Y/~ Chips Received~ Daily History Received? GJ/N cPN Analysis Received? Formation Tops ~ Comments: ff\J' \'1- :¡- VI. If J\l-J. ~ L 1'11\ ; t..~'L u -. ý} lI',d~~ L ~ S" flil./ 1-- ~I ~u J. ;.. ~ J(t{- ^ Ú~ À.. Compliance Reviewed By: ~ Date: ~Co I'ù ~~ ~~~--~- Transmittal Form "~i. BAKER HUGHES INTEQ Anchorage GEOScience Center To: AOGCC 333 West 7th Ave, Suite 100 Anchorage, Alaska 99501 RECEIVED Attention: NOV 06 2002 Lisa Weepie Reference: Al88ka o.~ & Gas Cons. Commission Anchorage lC-121 w::=.:=:c~::.-=:=::::.::-=-:::.-:::.-=--=:=:;:::==~:::;:-,:.-.:::==c==c:=_:::.::::;=-=---::::::_:=-=::::-:=.=:o:_~:;'--=~:=-':::':'=;:::::"-=::-':~:'-::::;:-':;;::::::-¡i Ii ContaIns the followIng: Ii Ii :: II Ii i¡ 1 LDWG Compact Disc !i Ii (Includes Graphic Image files) [¡ 'I 1 LDWG lister summary H I¡ II I 1 blueline - MPR Measured Depth Log II 1 blueline - MPR TVD Log ¡i Ii ¡II ! i II 11 , II ! Ii I II II Ii II LAC Job#: 160406 II I L_____..------::=-------------.--------.----------.-..--------------.------.------.-----------J i Sent By: Glen Borel Received B~ (~ Chqe. J Date: Nov 5, 2002 Date: PLEASE ACKNOWLEDGE RECEIPT BY SIGNING & RETURNING OR FAXING YOUR COPY FAX: (907) 267-6623 Baker Hughes INTEQ 7260 Homer Drive Anchorage, Alaska 99518 Direct: (907) 267-6612 FAX: (907) 267-6623 c9oJ-01Sð I/.~ 6-7 ~~ .---..----.- --~~--~.,,~---- ---,-~-_._--_.-. mtl.1fL'I:!I-I.~JIU~1't&:J ..." - -- .. -.. -- .. ..~ --. i . .. , -- .. .. --- -- ... ."1 1":'Wo. ..... .". -. . ... .. ..... . -------""--'---~'----"---'-- -""" ~ .... ¡,., ....~ ~....'~..., u '.... - ---------------------- ..-.".,,---.-.-..-..-.----..-- dO)-O~O ó\ù}- ,qq I ~_O (D l ~-I/{P y-oQ3 1 '{t-O <tJtJ dOI-~ ;15 Scblußlberger NO. 1759 Schlumberger Technology Corporation, by and through is Geoquest Division 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Sherrie Company: Alaska Oil & Gas Cons Comm Attn: Lisa Weepie 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Kuparuk Well BL Sepia Color CD Job # Log Description Date 1C-121 INJECTION PROFILE 01/20/02 1 1 1C-125 PRESSURE STATION PBMS 12/28/01 1 1 1 L-14 INJECTION PROFILE 01/22/02 1 1 1 Y -26A PRODUCTION PROFILE WIDEFT 01/20/02 1 1 1Y-32 - PRODUCTION PROFILE WIDEFT 01/09/02 1 1 3M-19 PRODUCTION PROFILE - 01/21/02 1 1 3N-19 22030 SCMT 01/12/02 1 ~....^.. It.\.t 'F.., '~u~1 V~U SIGNED~0J2u~ FEB 0 1 2002 DATE: Alaska Oil & Gas ConS. Commissfor, Anchorage Please sign and return one copy of this transmittal to Sherrie at the above address or fax to (907) 561-8317. Thank you. 01/29/02 ~----""- { (" 2-01-080 PHilliPS Alaska, Inc. A Subsidiary of PHILLIPS PETROLEUM COMPANY Post Office Box" 00.360 Anchorage, Alaska 99510-0360 C. Mallary Phone (907) 265-6434 Fax: (907) 265-6224 January 3, 2002 Commissioner Cammy Oechsli Taylor State of Alaska Alaska Oil & Gas Conservation Commission 333 West ih Avenue Suite 100 Anchorage, Alaska 99501 Subject: Completion Report for 1C-121 (201-080) Dear Commissioner: Phillips Alaska, Inc. submits the attached Completion Report for the drilling operations on the West Sak well1C-12l. If you have any questions regarding this matter, please contact Steve McKeever at 265-6826. Sincerely, cf~~ C. Ma11~ -v. (] Drilling Engineering Supervisor P AI Drilling CM/skad RECEIVED JAN 04 2002 ORIGi~~~~ I" " 1.,-' , --" ¡ '~ " '1 -- - \ - I....,) ~ l'~1 t, Alaska Oil & Gas CÔ'ns. Commission ,Anchorage { STATE OF ALASKA ( ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of well Classification of Service Well Oil 0 Gas 0 Suspended 0 Abandoned 0 Service 0 Water Injector 2. Name of Operator 7. Permit Number Phillips Alaska, Inc. ~.f)C -A11ÕÑSt 201-080 1 3. Address -y~, 8. API Number ,-.-...._0. .'--. .. . - ~.. ,.... P. O. Box 100360, Anchorage, AK 99510-0360 '; '".,'.. . " t 50-029-23015-00 4. Location of well at surface ~ . :'~,.. - -, - -~.1_'" 9. Unit or Lease Name 1589' FNL, 849' FWL, Sec. 12, T11N, R10E, UM 1/L'C(?:,_C;:L ~ (ASP: 561856, 596 "'.v .. Kuparuk River Unit AtTop Producing Interval ~ 10. Well Number 2316' FSL, 1893' FWL, Sec. 11, T11N, R1OE, UM.,. . ''''':::''i, .. (ASP: 557633, 5967238) 1 C-121 At Total Depth . 11. Field and Pool 2145' FSL, 1853' FWL, Sec. 11, T11N, R10E, UM , (ASP: 557595, 5967067) West Sak Oil Pool 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. Kuparuk River Field RKB 102' AMSL ADL 25649 ALK 467 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. Or Aband. 15. Water Depth, if offshore 16. No. of Completions June 4, 2001 June 9, 2001 June 12,2001 N/A feet MSL 1 17. Total Depth (MD + TVD) 18. Plug Back Depth (MD + TVD) 19. Directional Survey 20. Depth where SSSV set 21. Thickness of Permafrost 6876' MD 1 4228' TVD 6800' MD 14160' TVD YES 0 No 0 N/A feet MD 2378' 22. Type Electric or Other Logs Run GR/Res, SCMT 23. 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 161' 24" 332 sx AS 1 5.5" 15.5# L-80 Surface 6165' 7.875" 590 sx AS III Lite, 367 sx Class G 3.5" 9.3# L-80 6165' 6866' 7.875" tapered string - cemented above 24. Perforations open to Production (MD + TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 3.5" 6169' None 6252' - 6296' MD 3650' - 3691' TVD 4 spf 6322' - 6360' MD 3715' - 3 O'TVD 4 spf 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. 6370' - 6396' MD 3760' - 37 4' TVD 4 spf DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 6418' - 6430' MD 3804' - 381 'TVD 4 spf NIA 6438' - 6466' MD 3823' - 38 TVD 4 spf 6506' - 6536' MD 3886' - 3 14' TVD 4 spf 27. PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) Injector Date of Test Hours Tested Production for OIL-BBL GAS-MCF W A TER-BBL CHOKE SIZE GAS-OIL RATIO Test Period> Flow Tubing Casing Pressure Calculated OIL-BBL GAS-MCF W A TER-BBL OIL GRAVITY - API (corr) 24-Hour Rate> 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and pressence of oil, gas or water. Submit core chips. N/A RECEIVED - ,JAN 04 2002 ORIGINAL. Af&Waœ a GasCôns. CoJnmiM ~ OJ Form 10-407 Rev. 7-1-80 CON~1Ymf~ 1JrrSE SIDE RBDMS 8Fl JAN I , 2002 b Y JAN 7 2002 Submit in duplicate 29. I , GEOLOGIC MARKERS 30. i " FORMATION TESTS NAME MEAS.DEPTH TRUE VERT. DEPTH Include interval tested, pressure data, all fluids recovered and gravity. GOR, and time of each phase. West Sak D West Sak A3 West Sak Base , 6254' 6410' 6710' 3652' 3797' 4075' Annulus left open - freeze protected with diesel. .. RECEIVED . JAN 04 2002 31. LIST OF ATTACHMENTS Summary of Daily Operations, Directional Survey 32. I hereby certify that the following is true and correct to the best of my knowledge. Alaska Oil & Gas Cons. CommiSSion Anchorage Questions? Call Steve McKeever 265-6826 (! /) 11. 1Jf) Signed ,,¡¿.~~ (I V Title Drillina Enaineerina SUDervisor Dale 03 ~_LA- ();)... C. Mal/ary Prepared by Sharon AI/sup 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 1: Classification of Service wells: Gas injection, water injection, stéam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Iterr116 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). 'Item 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 1 0-407 0 r~ ~ ('"'" [! It"\l()t II L ( Page 1 of 3 PHilliPS ALASKA INC. Operations Summary Report Legal Well Name: 1 C-121 Common Well Name: 1 C-121 Event Name: ROT - DRILLING Contractor Name: Nabors Rig Name: Nabors 245 Date From - To Hou rs Code Sub Phase Code 6/3/2001 13:00 - 17:30 4.50 MOVE MOVE SURFAC 17:30 - 00:00 6.50 DRILL OTHR SURFAC 6/4/2001 00:00 - 03:00 3.00 DRILL OTHR SURFAC 03:00 - 03:30 0.50 DRILL OTHR SURFAC 03:30 - 06:00 2.50 DRILL PULD SURFAC 06:00 - 07:30 1.50 DRILL PULD SURFAC 07:30 - 08:30 1.00 DRILL PULD SURFAC 08:30 - 09:00 0.50 RIGMNT RSRV SURFAC 09:00 - 11 :30 2.50 DRILL PULD SURFAC 11 :30 - 14:00 2.50 RIGMNT SFTY SURFAC 14:00 - 15:00 1.00 RIGMNT SFTY SURFAC 15:00 - 17:30 2.50 DRILL PULD SURFAC 17:30 - 18:30 1.00 DRILL DRLG SURFAC 18:30 - 19:00 0.50 DRILL CIRC SURFAC 19:00 - 00:00 5.00 DRILL DRLG SURFAC 6/5/2001 00:00 - 04:00 4.00 DRILL DRLG SURFAC 04:00 - 04:30 0.50 DRILL CIRC SURFAC 04:30 - 07:00 2.50 DRILL TRIP SURFAC 07:00 - 07:30 0.50 DRILL DEOT SURFAC 07:30 - 09:00 1.50 DRILL TRIP SURFAC 09:00 - 12:00 3.00 DRILL DRLG SURFAC 12:00 - 14:00 2.00 DRILL DRLG SURFAC 14:00 - 00:00 10.00 DRILL DRLG SURFAC 6/6/2001 00:00 - 14:30 14.50 DRILL DRLG SURFAC 14:30 - 16:30 2.00 DRILL CIRC SURFAC 16:30 - 21 :00 4.50 DRILL TRIP SURFAC 21 :00 - 21 :30 0.50 DRILL PULD SURFAC 21 :30 - 22:30 1.00 DRILL DEOT SURFAC 22:30 - 23:30 1.00 RIGMNT RSRV SURFAC 23:30 - 00:00 0.50 DRILL TRIP SURFAC 6/7/2001 00:00 - 04:00 4.00 DRILL TRIP SURFAC 04:00 - 05:00 1.00 DRILL CIRC SURFAC 05:00 - 11 :00 6.00 DRILL DRLG SURFAC 11 :00 - 13:00 2.00 DRILL CIRC SURFAC 13:00 - 15:30 2.50 DRILL TRIP SURFAC 15:30 - 16:00 0.50 DRILL DEOT SURFAC 16:00 - 18:00 2.00 DRILL PULD SURFAC 6/3/2001 Spud Date: 6/4/2001 End: Group: Start: Rig Release: Rig Number: 245 Description of. Operations PJSM. PU & secure cellar box. JU & Load drill module and utility module on crib blocks. Move rig 180' away from CPM to weIl1C-121. Nipple up diverter system and function test. Function test waived by AOGCC inspector Chuck Sheeve. Continue NU Diveter system--Riser, fillup line. Install turnbuckles &, hydraulic lines. Install mouse hole and ready floor. Function test diverter system. AOGCC inspector Chuck Sheeve waived witness of test. PJSM. Pickup drillpipe from pipe shed & stand back in derrick. PJSM wI Baker Hughes Inteq. Pickup BHA. While picking up battery pack from pipe shed, tools parted. Repair/replace. Attempt to pick up again on skate of pipe handling machine. Broke again. Service rig and top drive. Replace/repair and test battery pack. Use 5-1/2" casing as a shuck, install tools in casing and bring to rig floor. Orient MWD. Clean and pickup loose items around rig. Prespud meeting with drilling crew, T.P., Co Rep." directional driller,MWD hands, mud engr. PU 3 DC's, Tag ice @ 120'. Wash to bottom @ 161'. Drill from 161' to 207'. While drilling w/ thick mud, circ up gravel, plastic and trash. Drill f/ 207' to 585' (378') ART = 2.4 hrs AST = 1.8 hrs Drill from 585" to 906' MD. Circ. bottoms up TOOH to mud motor, had tight spot at 221 , took 25K over pull, wipe out tight spot Down load MWD information Adjust mud motor to 1.5 degree bend and RIH, had to ream thru tight spot at 245', washed last stand to bottom, from 816' to 906' Drill from 906' to 1178', had a 10 degree dog leg at this survey Pull bit up to 1081" and time drill to 1178', to undercut dogleg, resurvey, dogleg now at 6.2 degrees Drill from 1178' to 2209' Drill from 2209' to 4014' Circ., pump sweep, check for flow TOOH, had tight spot at 1083', M/U topdrive and ream out hole from 1076' to 1088', finish TOOH Break out bit and make up bit #2, adjust motor to 1.2 degrees Check out tools and down load MWD info. Rig service and service top drive TIH, test MWD at shoe, TIH TIH, work thru tight spots at 1085' and 1158', tag up and had to kelly up at 3098' and wash to bottom at 4014', would not go without pumping on it. Circ. bottoms up, MWD had a week signal, but seems to be getting better as we circ. Drill from 4014' to 4489', MWD quit working, no pulse Circ. and cond hole while trying to get MWD to start working POOH Download MWD info. Change out pulsar in MWD tool, found piece of wood stuck in tool, 3/4" dia X 21/2" 10ng.Test MWD Printed: 7/17/2001 11 :19:03 PM i (' .... ...... ~ , 6HILLlPS ~ PHILLIPS ALASKA INC. Page 2 of 3 lœ Operations Summary Report Legal Well Name: 1 C-121 Common Well Name: 1 C-121 Spud Date: 6/4/2001 Event Name: ROT - DRILLING Start: 6/3/2001 End: Contractor Name: Nabors Rig Release: Group: Rig Name: Nabors 245 Rig Number: 245 Date From - To Hours Code Sub Phase Description of Operations Code 6n/2001 18:00 - 18:30 0.50 RIGMNT RSRV SURFAC Service TDS 18:30 - 19:00 0.50 RIGMNT RGRP SURFAC Adjust Bail kicker on elevator so elevators do not touch monkey board while tripping pipe 19:00 - 22:00 3.00 DRILL TRIP SURFAC TIH, check MWD at 270', wash 90' to bottom 22:00 - 00:00 2.00 DRILL DRLG SURFAC Drill from 4489' to 4676' 6/8/2001 00:00 - 00:00 24.00 DRILL DRLG SURFAC Drilling from 4676' to 6470' 6/9/2001 00:00 - 05:00 5.00 DRILL DRLG SURFAC Drill from 6470' to 6876' TMD, 4228' TVD 05:00 - 07:00 2.00 DRILL CIRC SURFAC Circ. sweep and cond hole, check for flow, pump slug 07:00 - 12:30 5.50 DRILL TRIP SURFAC POOH, tight @6101', 5062', 4967',1842', hung up at 660', had to screw into top drive and ream out of this spot, finish POOH 12:30 - 13:00 0.50 DRILL DEOT SURFAC Download MWD info. 13:00 - 14:30 1.50 DRILL PULD SURFAC UD MWD tool, DC's and Motor 14:30 - 15:30 1.00 DRILL PULD SURFAC P/U 7 7/8" hole opener and RIH with BHA 15:30 - 16:30 1.00 RIGMNT RURD SURFAC Slip and cut 110' of drill line 16:30 - 17:00 0.50 RIGMNT RSRV SURFAC Service rig and TDS 17:00 - 00:00 7.00 DRILL TRIP SURFAC TIH, hit bridge at 660', wash and ream thru, wash and ream tight spots from 4675' to 5864', stuck pipe at 6225', had good circ. worked loose and wiped out tight spot, continue to RIH washing and ream tight spots to 6787' 6/10/2001 00:00 - 00:30 0.50 DRILL REAM SURFAC Wash and ream 90' to bottom 6876' 00:30 - 03:30 3.00 DRILL CIRC SURFAC Circ. and condo hole, pump sweep 03:30 - 07:00 3.50 DRILL TRIP SURFAC POOH to HWDP, no drag 07:00 - 10:00 3.00 DRILL PULD SURFAC UD 35 jts of HWDP and BHA 10:00 - 12:00 2.00 CASE RURD SURFAC Clear rig floor, R/U to P/U 3 1/2" tubing, hold pre-job safety meeting 12:00 - 14:00 2.00 CASE PULR SURFAC P/U 33 jts. of 31/2" tubing and stand in the derrick, to be used if we have to open Tam port collar 14:00 - 15:00 1.00 CASE RURD SURFAC R/U to run 31/2" casing, hold pre-job meeting 15:00 - 17:00 2.00 CASE RUNC SURFAC Run 22 jts. 3 1/2" casing 17:00 - 18:00 1.00 CASE RURD SURFAC R/U to run 5 1/2" casing 18:00 - 19:00 1.00 CASE RUNC SURFAC P/U and run Baker seal bore ext. and 1 jt of 5 1/2" casing and break circ. 19:00 - 21 :30 2.50 CASE RUNC SURFAC Run 65 jts. 5 1/2" casing to 3485' 21:30 - 22:00 0.50 CASE CIRC SURFAC Circ. casing volumn 22:00 - 00:00 2.00 CASE RUNC SURFAC Run 51/2" casing from 3485' to 5579' 6/11/2001 00:00 - 00:30 0.50 CASE RUNC SURFAC RIH W/5 1/2" casing to 6142', string started taking excess weight going down 00:30 - 01 :00 0.50 CASE CIRC SURFAC Circ. bottoms up 01 :00 - 02:30 1.50 CASE RUNC SURFAC RIH with 5 1/2" casing, no drag after circ., set at 6866' Total pipe in hole 22 jts. 3 1/2" 9.3# L-80 EUE-MOD 143 jts. 5 1/2" 15.5# L-80 BTC-MOD Top of Baker seal bore ext. at 6152' (locator shoulder) Plug back TD (top of wiper plugs)= 6766' 02:30 - 06:00 3.50 CEMEN" CIRC SURFAC Circ. and cond mud for cement job 06:00 - 08:30 2.50 CEMEN" PUMP SURFAC Flush lines to rig floor with water, pump 5 bbls CW 100, test lines to 4000 psi, pump 55 bbls CW 100, drop bottom plug, pump 50 bbls MUDPUSH XL with red dye, pump 590 sx (469 bbl) artic set light lead cement mixed at 10.7 ppg. and 367 sx (72.4 bbl) CI. G expanding cement mixed at 15.8 ppg. 08:30 - 09:30 1.00 CEMENl DISP SURFAC Flush lines with water to cement head, drop top plug, displace cement with sea water using the rig pump. Plug bumped at calulated strokes of displacement. Pressure to 2500 psi and hold for 5 mins. Release pressure, floats held OK. We circulated back 50 bbls excess cement to Printed: 7/17/2001 11:19:03 PM , ( .... ....... .... ~~PHILLlPS) PHILLIPS ALASKA INC. Page 3 of 3 11Zm) Operations Summary Report -r- Legal Well Name: 1 C-121 Common Well Name: 1 C-121 Spud Date: 6/4/2001 Event Name: ROT - DRILLING Start: 6/3/2001 End: Contractor Name: Nabors Rig Release: Group: Rig Name: Nabors 245 Rig Number: 245 Date From - To Hours Code Sub Phase Description of Operations Code 6/11/2001 08:30 - 09:30 1.00 CEMENl DISP SURFAC surface 09:30 - 14:30 5.00 WELCTL NUND SURFAC UD landing jt., N/D diverter system 14:30 - 15:00 0.50 WELCTL NUND SURFAC Install Vetco Grey well head and test same 15:00 - 20:00 5.00 WELCTL NUND SURFAC N/U BOP's 20:00 - 21 :00 1.00 WELCTL SFTY SURFAC Hold prejob safety meeting and rig up test equipment 21 :00 - 00:00 3.00 WELCTL BOPE SURFAC Test BOP's 250 psi low and 5000 psi high, test annular to 3500 psi high. Had leak in lower spool and had to retighten, before it tested. Presently 50% done with test. 6/12/2001 00:00 - 03:00 3.00 WELCTL BOPE CMPL TN Finish BOP test 250 psi low and 5000 psi high 03:00 - 03:30 0.50 WELCTL NUND CMPL TN RID test equip., blow down choke, kill line and choke manifold 03:30 - 12:30 9.00 CMPL TN RUNT CMPL TN RlU tubing handling equipment, hold pre-job meeting, P/U Baker seal assembly, DS nipple and gas lift mandrel and RIH on 31/2" tubing to Seal bore. 12:30 - 15:00 2.50 CMPL TN SOHO CMPL TN Establish circ., sting into seal bore, space out with 28" of pup jts. 15:00 - 16:30 1.50 CMPL TN CIRC CMPL TN P/U and circ. 109 bbls clean sea water at 3 bbl per min. 16:30 - 17:30 1.00 CMPL TN CIRC CMPL TN Pump 70 bbls diesel down tubing and U-tube back to annulus for freeze protection 17:30 - 18:00 0.50 CMPL TN SOHO CMPL TN Land seal assembly in seal bore, run in lock down screws on hanger. Total tubing in hole 194 jts 31/2" 9.3# L-80 EUE-MOD Space out pups 1 jt below hanger 2 - 10' and 1 - 8' locator on sea lassembly at 6152' DS nipple w/ 2.812" No-Go Profile @ 6112' Camco KBG-2-9 w/ DK-1latch 2.9 ID. at 6068' 18:00 - 20:30 2.50 CMPL TN DEOT CMPL TN R/U and test tubing to 3000 psi for 30 mins., RU and test annulus to 3000 psi for 30 mins. had to repair leak on pump in flange and retest annulus, everything held OK. 20:30 - 21 :00 0.50 CMPL TN NUND CMPL TN Set back pressure valve in tubing hanger 21 :00 - 00:00 3.00 WELCTL NUND CMPL TN N/D BOP's Printed: 7/17/2001 11:19:03 PM SENT BY: ., .Date 07/09101 07/10101 '1102/01 11/03101 11/04101 1-11- 2 :10:28AM : PHILLIPS AK INC~ ( ( 1 C-121 ,Event Histo'ry :# 2/ 3 Commem . TAGGED FILL 0 6661'WLMf DRIFTED TUBING WITH 221 X 2.625- SPENT HOLLOW CARRIER TO SAME DEPTH. [TAG] .' seMr LOG COMPLETED. LOG MAIN PASS FAOM TD TO 6100 FT WITH WHP: OPSI. LOG A SECONO MAIN PASS AND ^ REPEAT PASS WITH WHP: 2000PSI. TO TAG AT 6706 FT. . : PERFORATED 0 (64181-6430'), (63761-6396'),63701-6376') W/2.5" HSD. BH. 4 SPF GUNS. DID NOT TAG TO & LEFT WELL SI. JOB IN PROGRESS. [PERF)' , PERFORATED @ (64181-64301), (63761-6396'), 6370'-6376') W/2.5" HSD,-Bt\ 4 SPF GUNS. 'DID NOT TAG TD & LEFT WELL 81. JOB IN PROGRESS. [PERF] , . .' PERFORATED 0 (63401-63601), (6322'-63401), (6272'-62961), (62521-62721), WI2.5. Hsb, BH, 4 SPF. 010 _. NOT TAG TO, LEFT WELL 51. JOB IN PROGRESS. [PERF] Page', of 1 RECEIVED JAN .1 1 2001. Alaska Oil & Gas Coos. Commission Anchorage 12118!2QOl (I ( Page 1 of2 Well Service Report ¡Well IIJob Scope I¡Job Number I 11C-121 IIDRILLING SUPPORT-CAPITAL 110708011706.10 Date IIDaily Work IIUnit Number I 11/04/2001 DRILLING SUPPORT-CAPITAL: FINISH PERF. 2.5" HSD 4 12128 I SPF, 4 RUNS IDay I I Field I ? ¡Init Tbg Press I 200 0 IIOperation Complete IISuccessful II False II False IIAFC# Ilcc# IIDaily Cost II AK0177 II 25WSIC8CG II 35264 I¡Key Person II SWS-DROPIK IIAccum Cost II 122810 IISupervisor II CHANEY IISigned II I I I I ¡IFinal Outer Ann I II 0 ? IIFinal Tbg Press IIInit Inner Ann IIFinal Inner Ann IIInit Outer Ann II 100 II 0 II 0 II 0 Daily Summary PERFORATED @ (6340'-6360'), (6322'-6340'), (6272'-6296'), (6252'-6272'), W/2.5" HSD, BH, 4 SPF. DID NOT TAG TD, LEFT WELL SI. JOB IN PROGRESS. [Perf] ITime IILog Entry I I 07:15 I ARRIVE LOCATION SWS UNIT2128, ENG. DROPIK, PJSM, RU, TEST SAFE SYSTEM. I 08:45 IPT LUBE TO 3000# I I 09:10 IRIH WI 2.5" HSD, BH, 4 SPF, GUN #7 I SLOW GOING DUE TO DEVIATION. I I 10:55 IlpOSITION & SHOOT GUN #7,6340'-6360', GOOD SHOT INDICATION, POOH. I 12:05 IloOH, CHANGE TO GUN #8. I I 12:30 IRIH WI GUN #8, FALLING BETTER BUT STILL SLOW THROUGH DEVIATION. I 13:45 IlpOSITION & SHOOT GUN #8 @ 6322'-6340', GOOD SHOT INDICATION, POOH I I 14:20 IIOOH, CHANGE TO GUN #9 I I 14:45 IIRlH, WI GUN #9 I I 15:55 IlpOSITION & SHOOT GUN #9, 6272'-6296', GOOD SHOT INDICATION, POOH. I I 16:20 IloOH, CHANGE TO GUN #10 I I 16:55 IRlH WI GUN #10 I I 17:45 IlpOSITION & SHOOT GUN #10, 6252'-6272', GOOD SHOT INDICATION, POOH I 1 18:30 I OOH, RIG DOWN, LEA VB UNIT SPOTTED UP TO RUN STATIC BHPT IN THE AM. I 19:30 IIRDFN. WELL SECURED. I IIDanYCostREŒimd II 2~:~~~~~Z ~I II Alaska Oil & ~ ConI. Commission I Anchorage http://www.ak.ppco.com/wells/wsr/content/atdbworklog.asp?ID=1C1211142001085934&Field=K...1/11/2002 ¡Service Company - Service IAPC EQPT - SURFACE - RENTAL ¡PHILLIPS PAl SUPERVISION ISCHLUMBERGER SERVICES - ELINE I ~: Page 2 of2 ISCHLUMBERGER MISC - SWS INCENTIVE IMISC-INDIRECTS ¡Total Field Estimate II II II 1,332.0011 5,877.0011 35,264.0011 ?I ?I ?I http://www.ak.ppco.com/wells/wsr/content/atdbworklog.asp?ID=lC1211142001085934&Field=K...1/11/2002 -. - - - - - - - - - - - - - - - - - = SURVEY CALCULATION AND FIELD WORKSHEET Job No. 0450-00089 Sidetrack No. Page ~ of 4 - - Company PHILLIPS ALASKA, INC. Rig Contractor & No. Nabors Alaska Drlng- Rig: #245E Field KUPARUK RIVER UNIT Well Name & No. PAD 1 C/121 Survey Section Name Definitive Survey BHI Rep. L HENSLEY ,NTEQ WELL DATA . --c- Target TVD (FT) Target Coord. N/S Slot Coord. N/S -1589.00 Grid Correction 0.000 Depths Measured From: RKB g] MSL 0 SSD Target Description Target Coord. E/W Slot Coord. E/W 849.00 Magn. Declination 26.220 Calculation Method MINIMUM CURVATURE Target Direction (DO) Build\Walk\DL per: 1 OOft~ 30mD 10mD Vert. Sec. Azim. 251 .66 Magn. to Map Corr. 26.220 Map North to: OTHER . SURVEY DATA Survey Survey Inc!. Hole Course Vertical I Total Coordinate Build Rate Walk Rate Date Tool Depth Angle Direction Length TVD . Section I N(+) / S(-) E(+) I W(-) DL Build (+) I Right( +) Comment Type (FT) (DO) (DO) (FT) (FT) (FT) (FT) (Per 100 FT) Drop (-) Left (-) 0.00 0.00 0.00 0.00 0.00 0.00 0.00 TIE IN POINT -.., 04-JUN-01 MWD 161.00 0.00 0.00 161.00 161.00 0.00 0.00 0.00 0.00 0.00 04-JUN-01 MWD 203.74 0.26 104.27 42.74 203.74 -0.08 -0.02 0.09 0.61 0.61 04-JUN-01 MWD 294.82 0.53 178.80 91.08 294.82 -0.13 -0.50 0.30 0.58 0.30 04-JUN-01 MWD 384.02 2.02 209.38 89.20 383.99 1.15 -2.28 -0.46 1.78 1.67 04-JUN-01 MWD 475.43 4.13 222.04 91 .41 475.27 5.21 -6.13 -3.45 2.41 2.31 04-JUN-01 MWD 563.37 5.54 229.77 87.94 562.89 11.90 -11 .22 -8.82 1.76 1.60 8.79 - 05-JUN-01 MWD 655.39 8.61 234.70 92.02 654.20 22.61 -18.07 -17.83 3.40 3.34 5.36 05-JUN-01 MWD 746.38 12.39 238.21 90.99 743.65 38.63 -27.15 -31 .69 4.21 4.15 3.86 05-JUN-01 MWD 837.75 15.38 241.73 91.37 832.35 60.10 -38.06 -50.70 3.40 3.27 3.85 05-JUN-01 MWD 928.05 17.31 241.38 90.30 918.99 85.12 -50.17 -73.04 2.14 2.14 -0.39 05-JUN-01 MWD 1019.08 23.55 243.84 91.03 1004.26 116.49 -64.69 -101.28 6.92 6.85 2.70 05-JUN-01 MWD 1110.30 28.92 248.06 91.22 1086.06 156.59 -80.97 -138.13 6.23 5.89 4.63 ~ 05-JUN-01 MWD 1201.33 32.78 249.81 91.03 1164.19 203.20 -97.71 -181.69 4.35 4.24 1.92 - 05-JUN-01 MWD 1297.14 34.63 250.17 95.81 1243.90 256.35 -115.90 -231 .64 1.94 1.93 0.38 05-JUN-01 MWD 1392.00 38.50 251.57 94.86 1320.07 312.84 -134.38 -285.03 4.17 4.08 1.48 . 05-JUN-01 MWD 1487.40 45.18 253.33 95.40 1391 .11 376.43 -153.50 -345.69 7.11 7.00 1.84 05-JUN-01 MWD 1581.57 52.38 254.38 94.17 1453.12 447.16 -173.15 -413.69 7.69 7.65 1.11 05-JUN-01 MWD 1676.48 56.16 255.09 94.91 1508.54 524.08 -193.42 -488.01 4.03 3.98 0.75 . 05-JUN-01 MWD 1771 .82 62.31 255.79 95.34 1557.28 605.78 -213.99 -567.26 6.48 6.45 0.73 05-JUN-01 MWD 1865.43 64.42 256.84 93.61 1599.25 689.18 -233.78 -648.56 2.47 2.25 1.12 05-JUN.01 MWD 1960.16 69.79 257.20 94.73 1636.09 776.03 -253.36 -733.57 5.68 5.67 0.38 . 05-JUN-01 MWD 2054.22 70.31 256.14 94.06 1668.18 864.10 -273.75 -819.60 1.19 0.55 -1.13 .05-JUN-01 MWD 2143.52 70.14 255.79 89.30 1698.39 947.90 -294.13 -901.12 0.42 -0.19 -0.39 ..~. ..~... .. - - - - - - - SURVEY CALCULATION AND FIELD WORKSHEET Job No. 0450-00089 Sidetrack No. Page 2 of 4 - Company PHILLIPS ALASKA, INC. Rig Contractor & No. Nabors Alaska Dring - Rig: #245E Field KUPARUK RIVER UNIT Well Name & No. PAD 1 C/121 Survey Section Name Definitive Survey BHI Rep. L HENSLEY INTEQ WELL DATA . Target ìVD (FT) Target Coord. N/S Slot Coord. N/S -1589.00 Grid Correction 0.000 Depths Measured From: RKB ~ MSLO SSO Target Description Target Coord. EJW Slot Coord. EIW 849.00 Magn. Declination 26.220 Calculation Method MINIMUM CURVATURE Target Direction (DD) Build\Walk\DL per: 100ft~ 30mO 10mO Vert. Sec. Azim. 251.66 Magn. to Map Corr. 26.220 Map North to: OTHER . SURVEY DATA Survey Survey Incl. Hole Course Vertical Total Coordinate Build Rate Walk Rate Date Tool Depth Angle Direction Length ìVD Section N(+) / S(-) E(+) /W(-) DL Build (+) Right (+) Comment Type (FT) (DD) (DD) (FT) (FT) (FT) (FT) (Per 100 FT) Drop (-) Left (-) 06-JUN-01 MWD 2239.30 69.52 255.44 95.78 1731.42 1037.59 -316.46 -988.21 0.73 -0.65 -0.37 -'-. . 06-JUN-01 MWD 2333.73 69.17 255.09- 94.43 1764.73 1125.78 -338.94 -1073.66 0.51 -0.37 -0.37 . 06-JUN-01 MWD 2429.58 67.59 255.79 95.85 1800.04 1214.69 -361.34 -1159.91 1.78 -1.65 0.73 . 06-JUN-01 MWD 2521 .75 67.68 255.44 92.17 1835.12 1299.72 -382.52 -1242.47 0.36 0.10 -0.38 06-JUN-01 MWD 2615.40 67.59 255.09 93.65 1870.75 1386.15 -404.55 -1326.23 0.36 -0.10 -0.37 06-JUN-01 MWD 2709.41 67.59 256.14 94.01 1906.59 1472.86 -426.14 -1410.41 1.03 0.00 1.12 06-JUN-01 MWD 2804.67 67.59 254.74 95.26 1942.91 1560.73 -448.28 -1495.65 1.36 0.00 -1.47 06-JUN-01 MWD 2899.06 68.03 255.44 94.39 1978.56 1647.97 -470.76 -1580.10 0.83 0.47 0.74 C6-JUN-01 MWD 2994.57 68.20 255.44 95.51 2014.16 1736.40 -493.04 -1665.88 0.18 0.18 0.00 06-JUN-01 MWD 3089.85 68.20 255.09 95.28 2049.54 1824.69 -515.54 -1751.44 0.34 0.00 -0.37 06-JUN-01 MWD 3184.08 66.36 255.09 94.23 2085.93 1911.45 -537.91 -1835.43 1.95 -1.95 0.00 C6-JUN-01 MWD 3279.47 68.91 254.74 95.39 2122.23 1999.52 -560.87 -1920.59 2.69 2.67 -0.37 06-JUN-01 MWD 3375.28 69.17 255.09 95.81 2156.50 2088.84 -584.15 -2006.98 0.44 0.27 0.37 ~-, 06-JUN-01 MWD 3470.38 69.26 254.74 95.10 2190.25 2177.61 -607.29 -2092.83 0.36 0.09 -0.37 06-JUN-01 MWD 3564.28 69.43 255.79 93.90 2223.37 2265.30 -629.64 -2177.80 1.06 0.18 1.12 06-JUN-01 MWD 3659.58 69.61 257.55 95.30 2256.72 2354.23 -650.22 -2264.67 1.74 0.19 1.85 06-JUN-01 MWD 3755.41 69.61 256.14 95.83 2290.11 2443.69 -670.66 -2352.13 1.38 0.00 -1.47 06-JUN-01 MWD 3850.05 68.91 256.84 94.64 2323.62 2531.88 -691.34 -2438.19 1.01 -0.74 0.74 . 06-JUN-01 MWD 3945.21 69.52 257.20 95.16 2357.39 2620.45 -711.32 -2524.88 0.73 0.64 0.38 07-JUN-01 MWD 4040.91 68.73 257.90 95.70 2391 .49 2709.40 -730.60 -2612.20 1.07 -0.83 0.73 07-JUN-01 MWD 4135.10 67.50 257.20 94.19 2426.60 2796.34 -749.44 -2697.54 1.48 -1.31 -0.74 . 07-JUN-01 MWD 4230.45 65.65 257.90 95.35 2464.51 2883.36 -768.30 -2782.97 2.05 -1.94 0.73 07-JUN-01 MWD 4326.54 65.92 256.49 96.09 2503.92 2970.59 -787.73 -2868.42 1.37 0.28 -1.47 07-JUN-01 MWD 4419.82 64.42 258.25 93.28 2543.09 3054.82 -806.24 -2951.02 2.35 -1.61 1.89 SURVEY CALCULATION AND FIELD WORKSHEET ~ ,NTECl Company PHILLIPS ALASKA. INC. Well Name & No. PAD 1 C/121 Target TVD Target Description (FT) Target Direction (DD) Job No. 0450-00089 Rig Contractor & No. Nabors Alaska Dring - Rig: #245E Survey Section Name Definitive Survey WELL DATA Target Coord. N/S Slot Coord. N/S Target Coord. E/W Slot Coord. E/W Build\Walk\DL per: 100ft~ 30mO 10mO Vert. Sec. Azim. SURVEY DATA Date Survey Survey Incl. Hole rT 001 Depth Angle Direction ype (Fl) (DO) (DO) 07-JUN-01 I MWD 4514.12 66.18 256.48 07-JUN-01 66.09 08-JUN-01 66.80 08-JUN-01 66.18 08-JUN-01 65.39 08-JUN-01 65.57 08-JUN-01 62.67 08-JUN-01 59.50 08-JUN-01 57.39 08-JUN-01 53.70 08-JUN-01 51 .33 08-JUN-01 49.39 08-JUN-01 46.05 08-JUN-01 40.96 08-JUN-01 35.33 08-JUN-01 30.67 08-JUN-01 29.44 08-JUN-01 27.77 08-JUN-01 24.43 08-JUN-01 21 .88 08-JUN-01 22.06 09-JUN--01 21.80 09-JUN-01 22.06 09-JUN-01 I MWD I 6687.74 I 22.32 255.79 255.09 255.44 255.44 255.09 254.74 252.98 249.81 248.76 245.60 243.13 243.49 243.49 238.21 233.29 226.96 219.23 211 .85 201 .65 198.13 192.86 192.86 192.16 Course Length ~ 94.30 93.31 95.59 94.89 95.66 94.66 93.17 94.59 94.00 95.00 95.00 95.65 93.83 93.13 95.78 95.85 95.56 94.06 92.55 93.87 91.25 95.31 96.13 94.78 TVD ~ 2582.50 2620.25 2658.45 2696.30 2735.54 2774.82 2815.49 2861.22 2910.42 2964.16 3021 .97 3083.00 3146.11 3213.64 3288.96 3369.33 3452.07 3534.67 3617.79 3704.13 3788.76 3877.18 3966.35 4054.11 Vertical Section 3140.06 3225.13 3312.56 3399.40 3486.46 3572.41 3656.09 3738.81 3818.89 3897.14 3972.28 4045.33 4114.00 4177.44 4235.52 4285.71 4330.19 4369.70 4402.62 4428.78 4449.90 4469.70 4488.30 4506.66 -1589.00 849.00 251.66 Grid Correction Magn. Declination Magn. to Map Corr. Total Coordinate Build Rate N(+) ¡ S(-) E(+) ¡W(-) DL Build (+) (Fl) (FT) (per 100 FT) Drop (-) -824.99 -3034.61 2.53 1 .87 -845.44 -867.47 -889.60 -911.53 -933.44 -955.25 -978.24 -1003.77 -1031.46 - -1060.66 -1092.50 - -1123.68 -1152.29 -1180.92 -1210.15 - -1240.76 -1273.52 - -1306.50 -1339.26 - -1371.35 -1405.62 -1440.62 -1475.57 -3117.46 -3202.27 -3286.42 - -3370.86 -3454.15 - -3535.08 -3614.60 -3690.51 -3763.77 -3833.24 -3899.65 -3961.66 -4019.01 - -4070.70 -4113.89 - -4150.60 -4181.37 -4205.11 -4221.82 - -4233.42 -4242.93 -4250.92 -4258.68 0.68 1.00 0.74 0.83 0.39 3.13 3.73 3.65 3.99 3.63 2.84 3.57 5.47 6.79 5.60 3.56 4.31 5.03 5.05 1.46 2.08 0.27 0.39 -0.10 0.74 -0.65 -0.83 0.19 -3.11 -3.35 -2.24 -3.88 -2.49 -2.03 -3.56 -5.47 -5.88 -4.86 -1.29 -1.78 -3.61 -2.72 0.20 -0.27 0.27 0.27 0.000 - 26.220 ----- Sidetrack No. Page -~ (Jf 4 - Field KUPARUK RIVER UNIT BHI Rep. L HENSLEY 26.220 Depths Measured From: RKB ~ MSLD ssD Calculation Method MINIMUM CURVATURE Map North to: OTHER Walk Rate Right (+) Left (-) -1.88 -0.74 Comment .- -0.73 0.37 0.00 -0.37 -0.38 -1.86 -3.37 -1.11 -3.33 -2.58 0.38 ---.,¡ 0.00 -5.51 --I -5.13 -6.62 -8.22 -7.97 -10.87 -3.86 -5.53 0.00 -0.74 ------------------ = SURVEY CALCULATION AND FIELD WORKSHEET JobNo.045Q-00089 Sidetrack No. ~ Page~ of ~ . . Company PHILLIPS ALASKA, INC. Rig Contractor & No. Nabors Alaska Dring - Rig: #245E Field KUPARUK RIVER UNIT Well Name & No. PAD 1C/121 Survey Section Name Definitive Survey BHI Rep. L HENSLEY ,NI"EQ. . WELL DATA . TargetTVD (FT) Target Coord. N/S Slot Coord. N/S -1589.00 Grid Correction 0.000 Depths Measured From: RKB ~ MSLD SSD Target Description Target Coord. E¡W Slot Coord. E¡W 849.00 Magn. Declination 26.220 Calculation Method MINIMUM CURVATURE Target Direction (DD) Build\Walk\DL per: 1 00ft~ 30mD 10mD Vert. Sec. Azim. 251.66 Magn. to Map Corr. 26.220 Map North to: OTHER SURVEY DATA Survey Survey IncL Hole I Course Vertical Total Coordinate Bui~d Rate W~lk Rate Date Tool Depth Angle Direction Length TVD Section N(+) / S(-) I E(+) /W(-) DL BUild (+) Right (+) Comment Type (FT) (DD) (DD) (FT) (FT) (FT) (FT) (Per 100 FT) Drop (-) Left (-) 09-JUN-01 MWD 6782.96 22.15 192.86 95.22 4142.25 4525.13 -1510.74 -4266.48 0.33 -0.18 0.74 ---., 09-JUN-01 MWD 6806.99 22.15 192.51- 24.03 4164.51 4529.80 -1519.58 -4268.47 0.55 0.00 -1.46 09-JUN-01 MWD 6876.00 22.15 192.51 69.01 4228.43 4543.15 -1544.98 -4274.11 0.00 0.00 0.00 Projected Data- NO SURVEY . ,..-..~" . . . Date 07/09/01 07/10/01 11/02101 11/03/01 11/04/01 ( ( 1C-121 Event History Comment TAGGED FILL @ 66611WLM, DRIFTED TUBING WITH 221 X 2.625" SPENT HOLLOW CARRIER TO SAME DEPTH. [TAG] SCMT LOG COMPLETED. LOG MAIN PASS FROM TD TO 6100 FT WITH WHP: OPSI. LOG A SECOND MAIN PASS AND A REPEAT PASS WITH WHP: 2000PSI. TD TAG AT 6706 FT. PERFORATED @ (64181-64301), (63761-63961),63701-63761) W/2.5" HSD, BH, 4 SPF GUNS. DID NOT TAG ... TD & LEFT WELL SI. JOB IN PROGRESS. [PERF] PERFORATED @ (64181-64301), (63761-63961),63701-63761) W/2.5" HSD, BH, 4 SPF GUNS. DID NOT TAG TD & LEFT WELL SI. JOB IN PROGRESS. [PERF] PERFORATED @ (63401-6360'), (6322'-63401), (62721-6296'), (62521-62721), W/2.5u HSD, BH, 4 SPF. DID . NOT TAG TD, LEFT WELL SI. JOB IN PROGRESS. [PERF] Page 1 of 1 12/18/2001 ~. OUI/ CJS' C,) ( Phillips Alaska, Inc. Pad 1C 121 slot #121 Kuparuk River Unit North Slope, Alaska SUR V E Y LIS TIN G by Baker Hughes INTEQ Your ref: MWD <0-6876'> Our ref: svy6538 License: Date printed: 11-Jul-2001 Date created: 5-Jun-2001 Last revised: 20-Jun-2001 Field is centred on n70 16 18.576,w150 5 56.536 Structure is centred on n70 19 45.173,w149 30 19.124 Slot location is n70 19 29.545,w149 29 54.343 Slot Grid coordinates are N 5968646.233, E 561855.446 Slot local coordinates are 1589.00 S 849.00 E Projection type: alaska - Zone 4, Spheroid: Clarke - 1866 Reference North is True North ( Phillips Alaska, Inc. 5URVEY LI5TING Page 1 Pad lC,121 Your ref: MWD <0-6876'> Kuparuk River Unit,North 51ope, Alaska Last revised: 20-Jun-2001 Measured Inclin Azimuth True Vert RECTANGULAR Dogleg Vert G RID COO R D 5 Depth Degrees Degrees Depth COO R DIN ATE 5 Deg/100ft 5ect Easting Northing 0.00 0.00 0.00 0.00 O.OON O.OOE 0.00 0.00 561855.45 5968646.23 161. 00 0.00 0.00 161. 00 O.OON O.OOE 0.00 0.00 561855.45 5968646.23 203.74 0.26 104.27 203.74 0.025 0.09E 0.61 -0.08 561855.54 5968646.21 294.82 0.53 178.80 294.82 0.505 0.30E 0.58 -0.13 561855.75 5968645.74 384.02 2.02 209.38 383.99 2.285 0.46W 1. 78 1.15 561855.01 5968643.95 475.43 4.13 222.04 475.27 6.135 3.45W 2.41 5.21 561852.04 5968640.08 563.37 5.54 229.77 562.89 11.225 8.82W 1. 76 11. 90 561846.72 5968634.94 655.39 8.61 234.70 654.20 18.075 17.83W 3.40 22.61 561837.76 5968628.02 746.38 12.39 238.21 743.65 27.155 31. 69W 4.21 38.63 561823.98 5968618.83 837.75 15.38 241.73 832.35 38.065 50.70W 3.40 60.10 561805.06 5968607.77 928.05 17.31 241.38 918.99 50.175 73.04W 2.14 85.12 561782.82 5968595.48 1019.08 23.55 243.84 1004.26 64.695 101.28W 6.92 116.49 561754.70 5968580.73 1110.30 28.92 248.06 1086.06 80.975 138.13W 6.23 156.59 561718.00 5968564.15 1201.33 32.78 249.81 1164.19 97.715 181.69W 4.35 203.20 561674.58 5968547.06 1297.14 34.63 250.17 1243.90 115.905 231.64W 1. 94 256.35 561624.77 5968528.47 1392.00 38.50 251.57 1320.07 134.385 285.03W 4.17 312.84 561571.54 5968509.55 1487.40 45.18 253.33 1391.11 153.505 345.69W 7.11 376.43 561511.05 5968489.94 1581. 57 52.38 254.38 1453.12 173.155 413.69W 7.69 447.16 561443.22 5968469.74 1676.48 56.16 255.09 1508.54 193.425 488.01W 4.03 524.08 561369.08 5968448.87 1771. 82 62.31 255.79 1557.28 213.995 567.26W 6.48 605.78 561290.00 5968427.66 1865.43 64.42 256.84 1599.25 233.785 648. 56W 2.47 689.18 561208.87 5968407.22 1960.16 69.79 257.20 1636.09 253.365 733.57W 5.68 776.03 561124.03 5968386.94 2054.22 70.31 256.14 1668.18 273.755 819.60W 1.19 864.10 561038.18 5968365.86 2143.52 70.14 255.79 1698.39 294.135 901.12W 0.42 947.90 560956.83 5968344.82 2239.30 69.52 255.44 1731.42 316.465 988.21W 0.73 1037.59 560869.94 5968321.78 2333.73 69.17 255.09 1764.73 338.945 1073.66W 0.51 1125.78 560784.68 5968298.61 2429.58 67.59 255.79 1800.04 361.345 1159.91W 1.78 1214.69 560698.63 5968275.51 2521.75 67.68 255.44 1835.11 382.525 1242.47W 0.36 1299.72 560616.25 5968253.67 2615.40 67.59 255.09 1870.75 404.545 1326.23W 0.36 1386.15 560532.68 5968230.96 2709.41 67.59 256.14 1906.59 426.145 1410.41W 1.03 1472.86 560448.68 5968208.69 2804.67 67.59 254.74 1942.91 448.275 1495.65W 1.36 1560.73 560363.64 5968185.86 2899.06 68.03 255.44 1978.56 470.765 1580.10W 0.83 1647.97 560279.38 5968162.69 2994.57 68.20 255.44 2014.16 493.045 1665.88W 0.18 1736.40 560193.79 5968139.71 3089.85 68.20 255.09 2049.54 515.545 1751. 44W 0.34 1824.69 560108.42 5968116.52 3184.08 66.36 255.09 2085.93 537.915 1835.43W 1. 95 1911.45 560024.63 5968093.48 3279.47 68.91 254.74 2122.23 560.865 1920.59W 2.69 1999.52 559939.66 5968069.83 3375.28 69.17 255.09 2156.50 584.155 2006.98W 0.44 2088.84 559853.47 5968045.84 3470.38 69.26 254.74 2190.25 607.295 2092.83W 0.36 2177.61 559767.83 5968022.01 3564.28 69.43 255.79 2223.37 629.645 2177.80W 1.06 2265.30 559683.04 5967998.97 3659.58 69.61 257.55 2256.72 650.225 2264.67W 1. 74 2354.23 559596.36 5967977.69 3755.41 69.61 256.14 2290.11 670.665 2352.13W 1.38 2443.69 559509.07 5967956.54 3850.05 68.91 256.84 2323.62 691.345 2438.19W 1.01 2531.88 559423.19 5967935.16 3945.21 69.52 257.20 2357.39 711. 325 2524.88W 0.73 2620.45 559336.67 5967914.48 4040.91 68.73 257.90 2391. 49 730.605 2612.20W 1.07 2709.40 559249.52 5967894.49 4135.10 67.50 257.20 2426.60 749.445 2697.54W 1.48 2796.34 559164.34 5967874.96 4230.45 65.65 257.90 2464.50 768.305 2782. 97W 2.05 2883.36 559079.08 5967855.41 4326.54 65.92 256.49 2503.92 787.735 2868.42W 1.37 2970.59 558993.80 5967835.29 4419.82 64.42 258.25 2543.09 806.245 2951.02W 2.35 3054.82 558911.36 5967816.10 4514.12 66.18 256.49 2582.50 824.985 3034.61W 2.52 3140.06 558827.93 5967796.69 4607.43 66.09 255.79 2620.25 845.425 3117.46W 0.69 3225.13 558745.26 5967775.58 All data in feet unless otherwise stated. Calculation uses minimum curvature method. Coordinates from slot #121 and TVD from RKB 102' (N-245E) (102.00 Ft above mean sea level) . Bottom hole distance is 4544.77 on azimuth 250.13 degrees from wellhead. Vertical section is from wellhead on azimuth 251.66 degrees. Grid is alaska - Zone 4. Grid coordinates in FEET and computed using the Clarke - 1866 spheroid Presented by Baker Hughes INTEQ II ( Phillips Alaska, Inc. SURVEY LISTING Page 2 Pad lC,121 Your ref : MWD <0-6876'> Kuparuk River Unit,North Slope, Alaska Last revised: 20-Jun-200l Measured Inclin Azimuth True Vert RECTANGULAR Dogleg Vert G RID COO R D S Depth Degrees Degrees Depth COO R DIN ATE S Deg/100ft Sect Easting Northing 4703.02 66.80 255.09 2658.45 867.45S 3202.27W 1.00 3312.56 558660.64 5967752.86 4797.91 66.18 255.44 2696.30 889.59S 3286.42W 0.74 3399.40 558576.68 5967730.05 4893.57 65.39 255.44 2735.54 911.52S 3370.86W 0.83 3486.45 558492.43 5967707.43 4988.23 65.57 255.09 2774.82 933.42S 3454.15W 0.39 3572.41 558409.33 5967684.85 5081.40 62.67 254.74 2815.49 955.23S 3535.08W 3.13 3656.09 558328.59 5967662.39 5175.99 59.50 252.98 2861. 22 978.23S 3614.61W 3.73 3738.81 558249.26 5967638.75 5269.99 57.39 249.81 2910.42 1003.75S 3690.51W 3.65 3818.89 558173.57 5967612.61 5364.99 53.70 248.76 2964.15 103l.44S 3763.77W 3.99 3897.14 558100.54 5967584.33 5459.99 51.33 245.60 3021.97 1060.64S 3833.25W 3.63 3972.28 558031.32 5967554.57 5555.64 49.39 243.13 3083.00 1092.48S 3899.65W 2.84 4045.33 557965.18 5967522.19 5649.47 46.05 243.49 3146.11 1123.66S 3961.66W 3.57 4114.00 557903.43 5967490.51 5742.60 40.96 243.49 3213.64 1152.27S 4019.02W 5.47 4177.44 557846.31 5967461. 44 5838.38 35.33 238.21 3288.95 1180.90S 4070.70W 6.79 4235.51 557794.87 5967432.39 5934.23 30.67 233.29 3369.33 1210.14S 4113. 89W 5.60 4285.70 557751.92 5967402.81 6029.79 29.44 226.96 3452.06 1240.74S 4150.60W 3.56 4330.18 557715.46 5967371.91 6123.85 27.77 219.23 3534.67 1273 . 51S 4181.37W 4.31 4369.70 557684.97 5967338.90 6216.40 24.43 211.85 3617.79 1306.48S 4205.12W 5.03 4402.61 557661.49 5967305.73 6310.27 21.88 201.65 3704.13 1339.25S 4221.82W 5.05 4428.78 557645.05 5967272.84 6401.52 22.06 198.13 3788.76 1371.34S 4233.43W 1.46 4449.89 557633.71 5967240.66 6496.83 21.80 192.86 3877.18 1405.60S 4242.94W 2.08 4469.70 557624.48 5967206.32 6592.96 22.06 192.86 3966.35 1440.60S 4250.93W 0.27 4488.30 557616.78 5967171.26 6687.74 22.32 192.16 4054.11 1475.55S 4258. 68W 0.39 4506.66 557609.31 5967136.25 6782.96 22.15 192.86 4142.25 1510.73S 4266.49W 0.33 4525.13 557601.79 5967101.02 6806.99 22.15 192.51 4164.51 1519.57S 4268.48W 0.55 4529.80 557599.87 5967092.16 6876.00 22.15 192.51 4228.43 1544.97S 4274 .11W 0.00 4543.14 557594.44 5967066.72 All data in feet unless otherwise stated. Calculation uses minimum curvature method. Coordinates from slot #121 and TVD from RKB 102' (N-245E) (102.00 Ft above mean sea level) . Bottom hole distance is 4544.77 on azimuth 250.13 degrees from wellhead. Vertical section is from wellhead on azimuth 251.66 degrees. Grid is alaska - Zone 4. Grid coordinates in FEET and computed using the Clarke - 1866 spheroid Presented by Baker Hughes INTEQ ~' I( Phillips Alaska, Inc. Pad lC,121 Kuparuk River Unit,North Slope, Alaska SURVEY LISTING Page 3 Your ref: MWD <0-6876'> Last revised: 20-Jun-2001 Comments in wellpath Me TVD Rectangular Coords. Comment ----------------------------------------------------------------------------------------------------------- 6876.00 4228.43 1544.97S 4274.11W Projected Data - NO SURVEY Casing positions in string 'A' ------------------------------ -------------- Top Me Top TVD Rectangular Coords. Bot Me Bot TVD Rectangular Coords. Casing ----------------------------------------------------------------------------------------------------------- 0.00 0.00 O.OON O.OOE 6866.00 4219.16 1541.29S 4273.29W 5 1/2" Casing Targets associated with this wellpath ===================================== Target name Geographic Location T.V.D. Rectangular Coordinates Revised ----------------------------------------------------------------------------------------------------------- WS 1C K2 (5-DEC-00) 557638.000,5967210.000,0.0000 3817.00 1402.03S 4229.39W 8-Jan-2001 0 I B5-ILI 1 ~ --aLl I ¡9'j-OS 1 ~\-OSo /1ß-zcH Sc~lullbepger NO. 1325 Schlumberger Technology Corporation, by and through is Geoquest Division 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Sherrie 7/26/2001 Company: Alaska Oil & Gas Cons Comm Attn: Lisa Weepie 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Kuparuk Well Job# Log Description Date BL Sepia CD Color 2A-16 PRODUCTION PROFILE 07/16/01 1 1 2F-11 PRODUCTION PROFILE 07/16/01 1 1 2T -30 PRODUCTION PROFILE 07/15/01 1 1 1 C-121 21344 SCMT 07/10/01 1 2N-335 21343 SCMT 07/09/01 1 5IG~zÅ/J~ I DATE: Please sign and return one copy of this transmittal to Sherrie at the above address or fax to (907) 561-8317. Thank you. -~- ---- RECEIVED AUG 0 3 2001 Na8ka Oil & Gas Cons. ComIniI8ion Ançborage { ( AT¡ASIiA. ORAND GAS CONSERVATION COMMISSION TONY KNOWLES, GOVERNOR ~V~VŒ lID~ ~~~~~~ 333 W. "JTH AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 J ames Trantham Drilling Engineering Supervisor Phillips Alaska, Inc. PO Box 100360 Anchorage, AK 99510 Re: Kuparuk River Unit 1 C-121 Phillips Alaska, Inc. Pennit No: 201-080 Sur. Loc. 1589' FNL, 849' FWL, Sec 12, TIIN, RI0E, UM Btmhole Loc. 2241' FSL, 1757' FWL, Sec. 11, TIIN, RI0E,UM Dear Mr. Trantham: Enclosed is the approved application for pennit to drill the above referenced well. The pennit to drill does not exempt you from obtaining additional pennits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required pennitting detenninations are made. The blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25.035; and the mechanical integrity (MI) of the injection wells must be demonstrated under 20 AAC 25.412 and 20 AAC 25.030(g)(3). Sufficient notice (approximately 24 hours) of the MI test before operation, and of the BOPE test perfonned before drilling below the surface casing shoe, must be given so that a representative of the Commission may witness the tests. Notice may be given by contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. Sincerely, ~ M~ f.k(,~~ Julie M. Heusser Commissioner BY ORDER OWE COMMISSION DATED this ~day of May 2001. jjc/Enclosures cc: Department ofFish & Game, Habitat Section wloencl. Department of Environmental Conservation wlo enol. ( ( ~( 4s¡~ PP'-f O'~/ ,/d 7 ( STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 1 a. Type of work: Drill ~ Redrill U 1b. Type of well. Exploratory 0 Stratigraphic Test U Development Oil U Re-entry 0 Deepen 0 Service ø Development Gas 0 Single Zone 0 Multiple Zone 0 2. Name of Operator 5. Datum elevation (DF or KB) 10. Field and Pool Phillips Alaska, Inc. RKS = 102 feet AMSL Kuparuk River Field 3. Address 6. Property Designation West Sak Oil Pool P.O. Box 100360 Anchorage, AK 99510-0361 ADL 25649 ALK 467 4. Location of well at surface 7. Unit or property Name 11. Type Bond (see 20 AAC 25.0251) 1589' FNL, 849' FWL, Sec. 12, T11 N, R10E, UM Kuparuk River Unit Statewide At top of productive interval 8. Well number Number 2304' FSL, 1958' FWL, Sec. 11, T11 N, R10E, UM 1C-121 #59-52-180 At total depth 9. Approximate spud date Amount 2241' FSL, 1757' FWL, Sec. 11, T11N, R10E, UM May 18, 2001 $200,000 12. Distance to nearest property line 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) 1757' @ TD feet 1C-10, 69 feet 2560 6740' MD 14228' TVD 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035 (e)(2)) Kickoff depth: 300' MD Maximum hole angle 64 deg Maximum surface 1459 psig At total depth (TVD) 1919 psig 18. Casing program Settinq Depth size Specifications Top Bottom Quantity of Cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include staqe data) 24" 16" 62.5# H-40 Weld 120' 41.2' 41.2' 161' 161' 225 cf AS 1 7.875" 5.5" 15.5# L-80 STCM 6006' 41.2' 41.2' 6047' 3585' 550 sx AS III L & 340 sx Class G 7.875" 3.5" 9.3# L-80 EUE 8rd M 693' 6047' 3585' 6740' 4228' Tapered String - Cemented above 5.5" Csg 3.5" 9.3# L-80 EUE 8rd M 6006' 41.2' 41.2' 6047' 3585' (Tubing String) 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total Depth: measured feet Plugs (measured) true vertical feet Effective Depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented Measured depth True Vertical depth Conductor Surface 0 RECEIVED Perforation depth: measured MA y O"í 2001 true vertical Alaska Oil & Gas Cons. Commission Anchorage 20. Attachments Filing fee ø Property Plat 0 BOP Sketch 0 Diverter Sketch 0 Drilling program ø Drilling fluid program ø Time vs depth plot 0 Refraction analysis 0 Seabed report 0 20 AAC 25.050 requirements ø 21. I hereby certify that the foregoing is true and correct to the best of my knowledge QuestIons? Call steve McKeever 265-682t Si~~~ Title: Drilling Engineering Supervisor Date ~(IO( ~ hv,C;tpvp ... /- Commission Use Onl\ Permit Number API number Approval d~ / l 0 I See cover letter 2D1-f'f?o 50- CJ¿ 9-- 2.. )ð/S" for other requirements Conditions of approval Samples required 0 Yes IXI No Mud log required 0 Yes 31 No Hydrogen sulfide measures I2SI Yes 0 No Directional survey required U Yes 0 No Required working pressure for BOPE 0 2M; ''Ill@ 0 5M; 0 10M;D 0 Other: \-1\L~*, C9-~~-\ 1Q..~~\\~'l \..~~ by order of Approved by ORM31NAl SiGNED BY Commissioner the commission Date ~ ) I () J ,j). M. Heusser Form 10-401 Rev. 12/1/85. ORIGINAL Submit in triplicate ~ ( APJ. ~don for Permit to Drill, We1l1C-121 ( Revision No.O . Saved: 27-Apr-01 Permit It - West Sak Well #1 C-121 Application for Permit to Drill Document Ml)ximizE Well ValUE; Table of Contents 1. Well Name................................................................................................................. 2 Requirements of 20 AAC 25.005 (f)... ............................. ....... ........... ..... ................. ...... ................ ..........2 2. Location Summary....... ...... ..... ....... ...... ........ ...... ....... ... .... ........ ........... ........... ....... ...2 Requirements of 20 AAC 25.005(c)(2) .................................. ................ .................................................2 Requirements of 20 AAC 25. 050(b) .............................. ......... .................. ........................,............ .......... 3 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 AAC 25.005 (c)( 4) ....... ............ ..... .......................... ........ ..... ........ ........................... 3 5. Procedure for Conducting Formation Integrity Tests ........................................... 3 Requirements of 20 AAC 25.005 (c)(5) ...................... ..... ...... ........... ................. ............. ............ ....... ..... 3 6. Casi ng and Cementi ng Program..... .... ..... ...... ... ..... ....... ..... ........ ..... .......... ..... ...... ... 4 Requirements of 20 AAC 25.005(c)(6) .................. ............. .......... ........... ........................... ........... .........4 7. Diverter System Information ..... ...... ...... ............. ........ ...... .... ...... ...... .......... ..... ........4 Requirements of 20 AAC 25.005(c)(7) . ............... ......... ......................... .................................. ...............4 8. Dri II ing FI uid Program .. ......... ........... ...... ..... ...... .......... .... ...... .... .............. ....... ...... ...4 Requirements of 20 AAC 25.005(c)(B) ... ................... ..... ......... ......... ............. ............................... .......... 4 9. Abnormally Pressured Formation Information ...................................................... 5 Requirements of 20 AAC 25.005 (c)(9) .................................................................................................. 5 10. Seismic Analysis ............. .................. ...... ..... ........ ........ ...... ........ ...... ...... ... ....... ........ 5 Requirements of 20 AAC 25.005 (c) (1 0) ..... .............. ................. ....... ..................................... .... ............5 11. Seabed Condition Analysis .....................................................................................5 Requirements of 20 AAC 25.005 (c)(11) ................................................................................................ 5 12. Evidence of Bondi ng............................... ..... ......... ........... ........... .................... .........5 Requirements of 20 AAC 25.005 (c)(12) ....................:........................................................................... 5 1C-121 PERMIT IT. DOC Page 1 of 7 0 RIG I N A L Printed: 27-Apr-OI ( f AP~' dtion for Permit to Drill, We1l1C-121 ~ Revision No.O Saved: 27-Apr-01 13. Proposed Drilli ng Program..... .......... .......... ... .................. ......... ....... ................ ........5 Requirements of 20 AAC 25.005 (c)(13) '"''''''''''''''''''''''''''''''''''''''''''''''''''''''''''''''''''''''''''''''''''''''.......5 14. Discussion of Mud and Cuttings Disposal and Annular Disposal....................... 6 Requirements of 20 AAC 25.005 (c)(14) ................................................................................................ 6 15. Attachments............................................................................................................. 7 Attachment 1 Directional Plan (10 pages) ..... ............. ................................................ ........... ....... ......... 7 Attachment 2 Drilling Hazards Summary (1 page) ................................................................................ 7 Attachment 3 Cement Loads and CemCADE Summary (1 page)......................................................... 7 Attachment 4 Well Schematic (1 page) ''''''''''''''''''''''''''''''''''''''''''''''''''''''''''''''''''''''''''''''''''''............. 7 1. Well Name Requirements of 20 AAC 25.005 (f) Eacl1 well must be identified by a unique name designated by the operator and a unique API number assigned by the commission under 20 MC 25.040(b). For a well with multiple well branches¡ each branch must simHarly be identified by a unique name and API number by adding a suffix to the name designated for the well by the operator and to the number assigned to the well by the commission The well for which this Application is submitted will be designated as lC-12l. 2. Location Summary Requirements of 20 AAC 25.005(c)(2) An application for a Permit to Dnll must be accompanied by each of the following items¡ 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 sUlface/ at the top of each objedive formation, and at total depth, referenced to governmental sedion lines. (8) the coordinates of the plVposed 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 well at the top of each objective formation and at total depth; Location at Surface 11589' FNL, 849' FWL Sec 12, TllN Rl0E, UM NGS Coordinates RKB Elevation I 102.0' AMSL Northings: 5,968,646.69 Eastings: 561,856.18 Pad Elevation I 60.8' AMSL Location at Top of Productive Interval West Sak "D" Sand NGS Coordinates Northings: 5,967,229 2304' FSL, 1958' FWL, Section 11, TllN, R1DE, UM Eastings: 557,696 6147 3673 3571 Location at Total De th NGS Coordinates Northings: 5,967,164 Eastings: 557,496 and (0) other infom1atio17 required by 20 MC 25.050(b); ORIGINAL 1C-121 PERMIT IT. DOC Page20f 7 Printed: 27-Apr-01 ~ ( APt, -:ation for Permit to Drill, We1l1C-121 ~ Revision No.O Saved: 27-Apr-01 Requirements of 20 AAC 25.050(b) If a well is to be intentionally deviated, the application for a Permit to Drill (Form 10-401) must (1) include a plat drawn to a suitable scalel showing the path of the proposed wellborel including all adjacent wellbores within 200 feet of any portion of the proposed wel¿. Please see Attachment 1: Directional Plan and (2) for all wells within 200 feet of the proposed wellbore (A) list the names of the operators of those wells, to the extent that those names are known or discoverable in public recordsl and show that each named operator has been furnished a copy of the application by certified ma/~' or (8) state that the 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 Drill mllst be accompanied by each of the following items, 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 25.03~ 20 MC 25.036, or 20 AAC 25.03~ as applicable; Please see \\Diagram and Description of the Blowout Prevention Equipment for Nabors Rig 245e", placed on file with the Commission with the Application for Permit to Drill for welllC-133, dated April 26th, 2001. 4. Drilling Hazards Information Requirements of 20 AAC 25.005 (c)(4) An application fvr a Permit to Dn/I must be accompanied by each of the fbllowing items, except for an item already on file with the commission and Identified in the application: (4) infvrmation on dlilling hazard!;.~ ineluding (A) the maximum downhole press"lIre that may be encountere(~ C/1te/1a lIsed tv detel1Tline it and maximum potential surface pressure based on a methane gradient; The expected reservoir pressures in the West Sak sands in the lC pad area vary from 0.43 to 0.46 pSi/ft, or 8.2 to 8.8 ppg EMW (equivalent mud weight). These are pressures obtained from actual well test data from the nearby WS1-01 well. The maximum potential surface pressue (MPSP) based on the above maximum pressure gradient, a methane gradient (0.11) and the vertical depth of the expected base of the West Sak formation is 1459 psi, calculated thusly: MPSP =(4171 ft)(0.46 - 0.11 psi/ft) =1459 psi (8) data on potential gas zones; The well bore is not expected to penetrate any gas zones. and (C) data concerning potential causes of hole problems such as abnormally geo.-pressured strata/ lost circulation zones, and zones that have a propensity for differential sticking/' Please see Attachment 2: Drilling Hazards Summary. 5. Procedure for Conducting Formation Integrity Tests Requirements of 20 AAC 25.005 (c)(5) 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: (5) a description of the procedure for conducting formation integnty tests, as required under 20 AAC 25.030(f); As the well will be completed with a single casing string that will not be drilled out, no formation integrity tests are planned. In the unlikely event that it does become necessary to drill out a casing string with ORIGINAL 1C-121 PERMIT IT. DOC Page 3 of 7 Printed: 27-Apr-O 1 ( ( APt ..00 for Permitto Drill, We1l1C-121 ( Revision No.O . Saved: 27-Apr-01 blowout prevention equipment installed, a formation integrity test will be performed in accordance with the \\Formation Integrity Test Procedure" that Phillips Alaska placed on file with the Commission with the Application for Permit to Drill for we1l1C-133, dated April 26th, 2001. 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 item~ except for an item already on file with the commission and Identified in the application: (6) a complete proposed casing and cementing program as required by 20 MC 25.030~ and a description of any slotted liner, pre- perforated liner, or screen to be installed; Casing and Cementing Program Hole Top Btm Csg/Tbg Size Weight Length MD/TVD MD/TVD 00 (in) (in) (lbllt) Grade Connection (It) (It) (It) Cement Proqram 16 24 62.5 H-40 Welded 120 41/41 161 / 161 Cemented to surface with 225 cf ArcticSet 1 5-1/2 7-7/8 15.5 L-80 BTC,AB 6006 41/41 6047/3585 Cemented to Modified Surface with 3-1/2 7-7/8 9.3 L-80 EUE 8rd, 693 6047 / 3585 6740 / 4228 550 sx ASLite AB Lead, 340 sx Modified Class G Tail See also Attachment 3: Cement Loads and CemCADE Summary. 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 de!:J""Criptiol7 of the diverter system as requked by 20 AAC 2.'i. 03.'i~ unless this requirement if:) waived by tht:? commission under 20 MC 25.035(h)(2); Please see "Diagram And Description of the Diverter System For Nabors Rig 245e", placed on file with the Commission with the Application for Permit to Drill for we1l1C-133, dated April 26th, 2001. 8. Drilling Fluid Program Requirements of 20 AAC 25.005(c)(B) An application {'Or a Permit to Drill mu.!:tt be accompanied by each of tile following item~ except for an item already on file with the commission and identified in the application: (8) a drilling fluid programl including a diagrz~m and description of the drilling fluid sys'teml as required by 20 MC 25.033~' Drilling will be done with a bentonite slurry having the following properites over the listed intervals: Spud to Base of Permafrost Base of Permafros to Total Depth Initial Value Final Value Initial Value Final Value Density (ppg) 8.5 9.4 - 9.6* 9.4 9.4 Funnel Viscosity 150-200 150-200 150 75 (seconds) Yield Point 30-60 30-60 25-45 25-45 (cP) Plastic Viscostiy 8-15 11-22 11- 22 11- 22 (lb1100 sf) 10 second Gel 15-30 10-25 15-30 15-30 Strength (lb1100 sf) ORIGINAL 1C-121 PERMIT IT. DOC Page 4 of 7 Printed: 27-Apr-O 1 ( ( APr~( ation for Permit to Drill, We1l1C-121 Revision No.O Saved: 27-Apr-01 10 minute Gel 25-55 25-55 25-55 25-55 Strenqth (lb/100 sf) pH 8-9 8-9 API Filtrate(cc) 8-15 6 5-6 5-6 Solids (%) 5-8 5-8 5-8 6-11 *9.8 ppg if hydrates are encountered Please see "Diagram of Mud System, Nabors Rig 245e", placed on file with the Commission with the Application for Permit to Drill for welllC-133, dated April 26th, 2001 This drilling fluid system of Nabors Rig 245e consists of: (3) Continental Emsco FB-1600 Mud Pumps, Steel Mud pits with 1100 barrel capacity, Pill Pit, Trip Tank, (3) Derrick Flo-line Shale Shakers (rated at 600 gpm), Brandt Model SRS-2 Desander, Derrick Model 58S Mud Cleaner, (2) Alpha-Laval Model 418-vr- 5 Centrifuges, Degassers, PVT System with visual and audio alarms, Trip Tank, Flow Sensor, and Fluid Agitators. Drilling fluid practices will be in accordance with appropriate regulations stated in 20 AAC 25.033. 9. Abnormally Pressured Formation Information Requirements of 20 AAC 25.005 (c)(9) An application for a Permit to Drill mU!:Jt be accompanied by each of the tollowing items, except for an item already on file with the commission and identified in the application: (9) for an exploratOlY or stratigrap/7ic te5t well, a tabulation setting out the depths of predicted abnormally geo-pressured strata as required by 20 AAC 25. 033(t)/ Not applicable: Application is not for an exploratory or stratigraphic test well. 10. Seismic Analysis Requirements of 20 AAC 25.005 (c)(10) An application for ,7 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: (10) f'Or an exploratory or strat¿qraphic test well, a .~eismic refraction or reflection analysis as required by 20 AAC 2S:061(a); Not applicable: 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 Dríll must be accompanied by each of the following item~~ except for an item already on file with the commi!:>"Siofl and Identified in the applicatiofl: (11) for a well dnlled from an offshore platform/ mobile bottom-founded structure/ jack-up ria or floatiflg dlilliflg vessel, an analysis of"seabed conditions as required by 20 AAC 25.061(b}; Not applicable: 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 tbe following Items, except for an item already on file with the commission and identified in the application: (12) evidence showing that the requirements of 20 AAC 25.02S {Bonding}have been met,- Evidence of bonding for Phillips Alaska, Inc. is on file with the Commission. 13. Proposed Drilling Program Requirements of 20 AAC 25.005 (c)(13) An application for a 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: The proposed drilling program is listed below. Please refer also to Attachment 4, Well Schematic. ORIGINAL 1C-121 PERMIT IT. DOC Page 5 of 7 Printed: 27-Apr-O 1 I( A~~ 'ation for Permit to Drill, We1l1C-121 { Revision No.O Saved: 27-Apr-01 ~, { 1. Excavate cellar, install cellar box, set and cement 16" conductor. Weld landing ring on conductor. 2. MIRU Nabors Rig 245e. Install diverter and function test same. 3. Spud and directionally drill 7-7/S" hole to desired targets through West Sak interval. Run MWD/LWD logging tools in drill string as required for directional monitoring and formation data gathering. 4. Circulate and condition hole to run open hole logs. POOH. 5. Run Schlumberger Platform Express logging suite: AIT / GR/ N / D / CMR. 6. RIH. Circulate and condition hole to run casing. 7. Run and cement 5-1/2" 15.5# L-SO BTCM x 3-1/2" 9.3# L-SO EUE Srd tapered casing string to surface. Displace cement with mud and perform stage job or top job if required. Note: 5-1/2" Port Collar to be installed @ +/- 1,000' TVD. S. Nipple down diverter and install wellhead. Nipple up BOP stack and pressure test to 5,000 psi. 9. PU and RIH with 3-1/2" tubing to just above seal bore extension and displace well to clean awater. 10. Sting into seal bore extension and space out. 11. Unsting seal assembly, and freeze protect well with diesel. 12. Sting back into seal bore extension and land tubing. 13. Using diesel, pressure test tubing and annulus to 3,000 psi. Record results. Install back pressure valve. 14. Nipple down BOP stack. Install production tree and pressure test same. 15. Secure well and release Nabors Rig 245e. A cement bond log will be run after the rig has moved off the well. 14. Discussion of Mud and Cuttings Disposal and Annular Disposal Requirements of 20 AAC 25.005 (c)(14) An rJpplication for a Permit to 01711 mustc be accompanied by eðc!7 of the following items, 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 dispo!:i""e of drilling mud and cuttings and a statement of whether the operator intend.ç to request authorization linder 20 MC 25:080 f'Or an annular disposal operation in the well..: Waste fluids generated during the drilling process will be disposed of either by pumping authorized fluids into a permitted annulus on lC pad, or by hauling the fluids to a KRU Class II disposal well. All cuttings generated will be either stored temporarily on site or hauled to the Prudhoe Bay Field for temporary storage and eventual processing for injection down an approved disposal well. Phillips Alaska does not intend to request authorization for the use of this well for annular disposal operations. ORIGINAL 1C-121 PERMIT IT. DOC Page 6 of 7 Printed: 27-Apr-01 ~ ~' API.' .dtion for Permit to Drill, Well 1 C-121 ~ Revision No.O Saved: 27-Apr-01 15. Attachments Attachment 1 Directional Plan (10 pages) Attachment 2 Drílling Hazards Summary (1 page) Attachment 3 Cement Loads and CemCADE Summary (1 page) Attachment 4 Well Schematic (1 page) ORIGINAL 1C-121 PERMIT IT. DOC Page 70f 7 Printed: 27-Apr-O 1 G~id Lat Long Report Page 1 of 4 " It .~ ~' Phillips Alaska, Inc. Pad lC 121 slot #121 Kuparuk River Unit North Slope, Alaska PRO P 0 S ALL I S TIN G by Baker Hughes INTEQ Your ref: 121 Version #2 Our ref: prop4379 License: Date printed: 29-Mar-200l Date created: 8-Jan-200l Last revised: 29-Mar-200l Field is centred on n70 16 l8.576,w150 5 56.536 Structure is centred on n70 19 45.173, w149 30 19.124 Slot location is n70 19 29.545,w149 29 54.372 Slot Grid coordinates are N 5968646.225, E 561854.446 Slot local coordinates are 1589.00 S 848.00 E Projection type: alaska - Zone 4, Spheroid: Clarke - 1866 Reference North is True North ORIGINAL { Gri~ Lat Long Report ( ~' Page 2 of 4 Phillips Alaska. Inc. PROPOSAL LISTING Page 1 Pad lC,12l Your ref : 121 Version 11-2 Kuparuk River Unit,North Slope, Alaska Last revised: 29-Mar-2001 Measured Inclin Azimuth True Vert RECTANGULAR G RID COO R D S G E 0 G RAP H I C Depth Degrees Degrees Depth COO R DIN ATE S Easting Northing COO R DIN ATE S o.OO 0.00 236.00 0.00 O.OON O.OOE 561854.45 5968646.23 n70 19 29.54 w149 29 54.37 300.00 0.00 236.00 300.00 O.OON O.OOE 561854.45 5968646.23 n70 19 29.54 w149 29 54.37 400.00 3.00 236.00 399.95 1. 46S 2.17W 561852.29 5968644.74 n70 19 29.53 w149 29 54.44 500.00 6.00 236.00 499.63 5. 85S 8.67W 561845.82 5968640.30 n70 19 29.49 w149 29 54.63 600.00 9.00 236.00 598.77 13 .15S 19. 49W 561835.06 5968632.92 n70 19 29.42 w149 29 54.94 700.00 12.00 236.00 697.08 23.34S 34. 60W 561820.04 5968622.61 n70 19 29.32 w149 29 55.38 800.00 15.00 236.00 794.31 36.39S 53. 95W 561800.80 5968609.40 n70 19 29.19 w149 29 55.95 900.00 19.78 240.90 889.71 51. 87S 79 . 48W 561775.39 5968593.72 n70 19 29.03 w149 29 56.69 1000.00 24.65 243 .94 982.26 69. 27S 113 .03W 561742.00 5968576.04 n70 19 28.86 w149 29 57.67 1100.00 29.56 246.02 1071.25 88.47S 154. 33W 561700.86 5968556.51 n70 19 28.67 w149 29 58.88 1200.00 34.50 247.56 1156.01 109. 32S 203 .07W 561652.29 5968535.27 n70 19 28.47 w149 30 00.30 1300.00 39.44 248.75 1235.88 131.66S 258. 89W 561596.66 5968512.48 n70 19 28.25 w149 30 01. 93 1400.00 44.40 249.71 1310.26 155.32S 321.35W 561534.40 5968488.32 n70 19 28.02 w14 9 30 03.75 1500.00 49.37 250.52 1378.58 180.12S 389. 98W 561465.98 5968462.96 n70 19 27.77 w14 9 30 05.76 1600.00 54.34 251. 22 1440.33 205. 87S 464.26W 561391. 92 5968436.61 n70 19 27.52 w149 30 07.92 1700.00 59.31 251. 83 1495.03 232.37S 543. 63W 561312.78 5968409.46 n70 19 27.26 w149 30 10.24 1800.00 64.29 252.38 1542.28 259.43S 627.47W 561229.17 5968381. 73 n70 19 26.99 w149 30 12.69 1802.20 64.40 252.40 1543.23 260. 03S 629.36W 561227.28 5968381.11 n70 19 26.99 w149 30 12.74 2000.00 64.40 252.40 1628.70 313 .98S 799.39W 561057.72 5968325.79 n70 19 26.46 w149 30 17.71 2276.07 64.40 252.40 1748.00 389.28S 1036.69W 560821.06 5968248.57 n70 19 25.72 w149 30 24.63 2500.00 64.40 252.40 1844.77 450.36S 1229.17W 560629.09 5968185.93 n70 19 25.12 w149 30 30.25 3000.00 64.40 252.40 2060.83 586.73S 1658. 96W 560200.47 5968046.08 n70 19 23.77 w149 30 42.79 3428.51 64.40 252.40 2246.00 703.61S 2027.30W 559833.13 5967926.23 n70 19 22.62 w149 30 53.54 3500.00 64.40 252.40 2276.89 723.11S 2088. 75W 559771.84 5967906.23 n70 19 22.43 w149 30 55.34 4000.00 64.40 252.40 2492.96 859.49S 2518. 54W 559343.22 5967766.38 n70 19 21. 09 w149 31 07.88 4500.00 64.40 252.40 2709.02 995.86S 2948. 33W 558914.59 5967626.52 n70 19 19.75 w149 31 20.42 5000.00 64.40 252.40 2925.08 1132. 24S 3378 .12W 558485.97 5967486.67 n70 19 18.41 w149 31 32.96 5182.98 64.40 252.40 3004.16 1182.15S 3535.40W 558329.11 5967435.49 n70 19 17.91 w149 31 37.55 5200.00 63.72 252.40 3011. 60 1186. 78S 3549.99W 558314.56 5967430.74 n70 19 17.87 w149 31 37.98 5300.00 59.72 252.40 3058.97 1213. 40S 3633.91W 558230.87 5967403.44 n70 19 17.61 w149 31 40.43 5346.37 57.86 252.40 3083.00 1225. 40S 3671.71W 558193.17 5967391.14 n70 19 17.49 w149 31 41. 53 5400.00 55.72 252.40 3112 . 37 1238. 97S 3714.48W 558150.52 5967377 .22 n70 19 17.35 w149 31 42.78 5500.00 51. 72 252.40 3171.54 1263.34S 3791.29W 558073.91 59673 52.22 n70 19 17.11 w149 31 45.02 5600.00 47.72 252.40 3236.18 1286. 41S 3863.99W 558001.41 5967328.57 n70 19 16.89 w149 31 47.14 5700.00 43.72 252.40 3305.99 1308. 06S 3932.22W 557933.37 5967306.37 n70 19 16.67 w149 31 49.13 5753.05 41. 59 252.40 3345.00 1318. 93S 3966.47W 557899.21 5967295.22 n70 19 16.57 w149 31 50.13 5800.00 39.72 252.40 3380.62 1328.18S 3995.63W 557870.13 5967285.73 n70 19 16.48 w149 31 50.98 5814.73 39.13 252.40 3392.00 1331. 01S 4004. 55W 557861.23 5967282.83 n70 19 16.45 w149 31 51. 24 5900.00 35.72 252.40 3459.71 1346. 68S 4053. 93W 557811.99 5967266.76 n70 19 16.29 w149 31 52.68 6000.00 31. 72 252.40 3542.87 1363.46S 4106. 83W 557759.23 5967249.55 n70 19 16.13 w149 31 54.23 6007.19 31.43 252.40 3549.00 1364.60S 4110. 42W 557755.65 5967248.38 n70 19 16.12 w149 31 54.33 6036.25 30.27 252.40 3573.94 1369.11S 4124. 62W 557741.49 5967243.76 n70 19 16.07 w149 31 54.75 6100.00 27.72 252.40 3629.70 1378. 45S 4154. 07W 557712.12 5967234.18 n70 19 15.98 w149 31 55.60 6136.25 26.27 252.40 3662.00 1383.43S 4169. 75W 557696.48 5967229.08 n70 19 15.93 w149 31 56.06 6177 .22 24.63 252.40 3699.00 1388.75S 4186. 53W 557679.74 5967223.62 n70 19 15.88 w149 31 56.55 6200.00 23.72 252.40 3719.78 1391.57S 4195. 42W 557670.88 5967220.73 n70 19 15.85 w149 31 56.81 6204.61 23.53 252.40 3724.00 1392.13S 4197.18W 557669.12 5967220.15 n70 19 15.85 w149 31 56.86 6241. 49 22.06 252.40 3758.00 1396.45S 4210. 80W 557655.54 5967215.72 n70 19 15.80 w149 31 57.26 6292.90 20.00 252.40 3805.98 1402. 03S 4228.38W 557638.01 5967210.00 n70 19 15.75 w149 31 57.77 6292.92 20.00 252.40 3806.00 1402. 03S 4228.39W 557638.00 5967210.00 n70 19 15.75 w149 31 57.77 All data in feet unless otherwise stated. Calculation uses minimum curvature method. Coordinates from slot #121 and TVD from Est. RKB 91' (91. 00 Ft above mean sea level). Bottom hole distance is 4603.96 on azimuth 251.68 degrees from wellhead. Total Dogleg for wellpath is 109.51 degrees. Vertical section is from wellhead on azimuth 251.66 degrees. Grid is alaska - Zone 4. Grid coordinates in FEET and computed using the Clarke - 1866 spheroid Presented by Baker Hughes INTEQ ORIGINAL It I~ ~' G~id Lat Long Report Page 3 of 4 ~. \ Phillips Alaska, Inc. PROPOSAL LISTING Page 2 Pad lC,121 Your ref : 121 Version 12 Kuparuk River Uni t, North Slope, Alaska Last revised : 29-Mar-2001 Measured Inclin Azimuth True Vert RECTANGULAR G RID COO R D S G E 0 G RAP H I C Depth Degrees Degrees Depth COO R DIN ATE S Easting Northing COO R DIN ATE S 6368.47 20.00 252.40 3877.00 1409. 85S 4253. 02W 557613 .43 5967201.99 n70 19 15.67 w149 31 58.49 6479.15 20.00 252.40 3981. 00 1421.29S 4289.10W 557577.45 5967190.25 n70 19 15.56 w149 31 59.55 6500.00 20.00 252.40 4000.59 1423. 45S 4295. 90W 557570.67 5967188.03 n70 19 15.54 w149 31 59.74 6574.92 20.00 252.40 4071. 00 1431. 20S 4320. 32W 557546.31 5967180.09 n70 19 15.46 w149 32 00.46 6729.15 20.00 252.40 4215.93 1447.15S 4370. 60W 557496.17 5967163.73 n70 19 15.30 w149 32 01.92 All data in feet unless otherwise stated. Calculation uses minimum curvature method. Coordinates from slot #121 and TVD from Est. RKB 91' (91.00 Ft above mean sea level). Bottom hole distance is 4603.96 on azimuth 251.68 degrees from wellhead. Total Dogleg for well path is 109.51 degrees. Vertical section is from wellhead on azimuth 251.66 degrees. Grid is alaska - Zone 4. Grid coordinates in FEET and computed using the Clarke - 1866 spheroid Presented by Baker Hughes INTEQ ORIGINAL .~. ," \~ "I Gr,d Lat Long Report Page 4 of 4 (' Phillips Alaska, Inc. Pad 1C .121 Kuparuk River Unit,North 5lope, Alaska PROP05AL LI5TING Page 3 Your ref: 121 Version t2 Last revised: 29-Mar-2001 Comments in wellpath -------------------- -------------------- MD TVD Rectangular Coords. Comment ----------------------------------------------------------------------------------------------------------- 300.00 300.00 O.oON o.OoE KOP 800.00 794.31 36.395 53 .95W Begin Bld/Trn 1802.20 1543.23 260.035 629.36W EOC 2276.07 1748.00 389.285 lo36.69W Base Permafrost 3428.51 2246.00 703.615 2027.30W K-15 5182.98 3004.16 1182.155 3535.40W Begin Drop 5346.37 3083.00 1225.405 3671. 71W Ugnu C 5753.05 3345.00 1318.935 3966.47W Ugnu B 5814.73 3392.00 1331.015 4004. 55W Ugnu A 6007.19 3549.00 1364.605 4110. 42W K-13 6036.25 3573.94 1369.115 4124. 62W Casing x/o pt 6136.25 3662.00 1383.435 4169. 75W Top W 5ak D 6177.22 3699.00 1388.755 4186. 53W C 6204.61 3724.00 1392.135 4197.18W B 6241.49 3758.00 1396.455 4210. 80W A4 6292.90 3805.98 1402.035 4228.38W Target-A3 -EOC 6292.92 3806.00 1402.035 4228.39W W5 1C K2 (5-DEC-00) 6368.47 3877.00 1409.855 4253 .02W A2 6479.15 3981. 00 1421. 295 4289.1OW A1 Base Pay 6574.92 4071. 00 1431. 205 4320. 32W Base W 5ak 6729.15 4215.93 1447.155 4370. 60W TD - Casing pt Casing positions in string 'A' - --- - - - -- - - - - --- ---- -- - - -- - - - - ----- -- - - - - -- - - - ---- -- -- - - - -- - Top MD Top TVD Rectangular Coords. Bot MD Bot TVD Rectangular Coords. Casing ----------------------------------------------------------------------------------------------------------- 0.00 0.00 O.ooN O. ODE 6729.15 4215.93 1447.155 437o.6oW 3 1/2" Casing Targets associated with this wellpath - - - ---- -- - - -- -- ---- - - -- --- - --- - - - ---- - - ---- --- - --- -- --- - - - - - --- - --- - - - ---- Target name Geographic Location T.V.D. Rectangular Coordinates Revised ----------------------------------------------------------------------------------------------------------- W5 1C K2 (5-DEC-00) 557638.000,5967210.000,0.0000 3806.00 1402.035 4228.39W 8-Jan-2001 ORIGINAL 0 300 600 900 1200 ,--... -- Q) Q) '+- 1500 "'-./ ..£: -- Q.. 1800 Q) 0 - 2100 0 .~ -- L Q) 2400 > Q) :J 2700 L I-- I V 3000 3300 C) 3600 ::0 ---- 3900 c-> ---- 4200 ~ r-- Begin Drop 63.72 Ugnu C 55.72 47.72 43.72 Ugnu B 39.72 Ugnu A 35.72 31.72 K-13 27.72 C 23.72 B A4 A2 Phillips Alaska, Ine 8 Structure: Pad 1 C Well: 121 ESTIMATED RKB Elevation: 91' Field: Kuparuk River Unit Location: North Slope. Alaska KOP 3.00 6-00 9.00 12.00 Begin Bld/Trn 19.78 24.65 29.56 DLS: 5.00 deg per 100 ft 34.50 39.44 44.40 49_37 59.3tOC DLS: 3.00 deg per 100 ft 251.66 AZIMUTH 4455' (TO TARGET) ***Plane of Proposal*** TANGENT ANGLE 64.4 DEG TARGET ANGLE 20 DEG DLS: 4.00 deg per 100 ft Casing X/O pt Top W Sak D Target-A3-EOC A 1 Bose Pay Bose W Sak TO - Casing pt 4500 0 300 600 900 1200 1500 1800 2100 2400 2700 3000 3300 3600 3900 4200 Vertical Section (feet) -> Azimuth 251.66 with reference 0.00 N, 0.00 E from slot # 121 4500 4800 Created by bmichoel For: S McKeever Dote ploUed : 29-Mor-2001 Plot Reference is 121 Version #2. Coordinates ore in feet reference slol 1121- True Vertical Depths ore reference Est. RKB 91'- =-~ 8fILs INUQ -~- ~~ ~-7;, ~~o. C> :::c - c-:> - :æ: ):> r-- Phillips Alaska, Inc. Created by bmichael For: S McKeever Dote plotted: 29-Mar-2001 Plot Reference is 121 Version #2- Coordinates ore in feet reference slot # 121. True Vertical Depths ore reference Est. RKB 91'. ulI}= HUGIH Structure: Pad 1 C Well: 121 Field: Kuparuk River Unit Location: North Slope, Alaska II""!];\) 44-00 4-000 4-200 TARGET LOCATION: 2288' FSL, 1897' FWL SEC. 11. T11 N, R1 DE v~ C'(/-,9" "v {, \S)o- 7 (, çy 'Ò & -------..--: çy0<> l? if -<1 ,O.s-",-<17-<1þ-;57 &1:-: c ~& g~ <>4° <>-5'/ æ.!'! "', O^'t- ",9 ¿~ ,0 '1J', ,.. ?t- ('°C' TO LOCATION: 2242' FSL, 1755' FWL SEC. 11, T11 N, R1 DE <- West (feet) 3800 3600 3000 2600 2400 2200 2000 1600 14-00 1800 3400 3200 2800 251.66 AZIMUTH 4455' (TO TARGET) ***Plone of Proposol*** ~ TRUE 1200 1000 800 ESTIMATED SURFACE LOCATION: 1589' FNL. 848' FWL SEC. 12, T11N, R1DE 600 400 200 0 200 0 200 400 600 (J) 0 C -+ 800 :::y ........... - Ct> 1000 Ct> -+ '---'" I 1200 V 1400 1600 1800 2000 -.. ~- -"- ~-. (, Su~mary Clearance Report Page 1 of 1 (' Phillips Alaska, Inc. Pad lC 121 slot 11121 Kuparuk River Unit North Slope, Alaska SUM MAR Y C LEA RAN C ERE P 0 R T by Baker Hughes INTEQ Your ref: 121 Version #2 Our ref: prop4379 License: Date printed: 29-Mar-2001 Date created: 8-Jan-2001 Last revised: 29-Mar-2001 Field is centred on n70 16 18.576,w150 5 56.536 Structure is centred on n70 19 45.173,w149 30 19.124 Slot location is n70 19 29.545,w149 29 54.372 Slot Grid coordinates are N 5968646.225, E 561854.446 Slot local coordinates are 1589.00 S 848.00 E Projection type: alaska - Zone 4, Spheroid: Clarke - 1866 Object wellpath GMS <0-7753'>,,5,Pad 1C GMS <0-10243'>, ,6,Pad 1C GMS <0-9784'>, ,7,Pad 1C Unknown Data, ,WS1,Pad 1C PMSS <0 - 10969'),,17, Pad 1C PMSS <0-8677'>,,13,Pad 1C PMSS <0 - 11918'>, ,16,Pad 1C MSS <0-7000' >, ,9GI. Pad 1C PMSS <0-6529'>, ,23 PB1,Pad 1C PMSS <1840-13975>" 23A, Pad 1C PMSS <0-10140'>,,25,Pad 1C PMSS <0-13910'>, ,27,Pad 1C PMSS <0-14630'>, ,26,Pad 1C PMSS <0 - 8095'>,,18,Pad 1C GMS <0-7780'>, ,1,Pad 1C PMSS <0-9390' >, ,15, Pad 1C PMSS <0-10980' >, , 14, Pad 1C GMS <0-7575'>, ,4,Pad 1C MMS <6948-7570'>, ,WS#24, Pad 1C GMS <0-9600'>,,8,Pad 1C PMSS <0-11300'>,,11,Pad 1C PMSS <0-17089'>,,12,Pad 1C GMS <0-7615'>, ,2,Pad 1C GMS <0-9700'>, ,3,Pad 1C PGMS <0-9002'>, ,10GI,Pad 1C Reference North is True North Closest approach with 3-D Minimum Distance method Last revised Distance M.D. Diverging from M.D. 18-Dec-1998 184.5 0.0 0.0 18-Dec-1998 208.9 300.0 300.0 18-Dec-1998 286.4 300.0 300.0 2-Nov-1998 6808.1 4240.0 4240.0 2-Dec-1998 344.8 100.0 100.0 1-Dec-1998 198.5 100.0 100.0 8-Jan-1999 188.5 100.0 100.0 2-Jan-1998 332.8 1136.4 1136.4 13-Jul-1999 434.8 0.0 0.0 8-Jun-1999 434.8 0.0 0.0 4-Jun-1999 488.3 322.2 322.2 1-Jan-1999 518.3 0.0 0.0 24-Aug-1999 503.8 0.0 0.0 22-Feb-1999 195.4 300.0 300.0 11-Mar-1999 531.9 300.0 300.0 17-Dec-1998 393.6 100.0 100.0 18-Mar-1998 291.9 100.0 6118.1 18-Dec-1998 230.2 0.0 6440.0 17-Dec-1997 11183.4 890.9 6580.0 18-Dec-1998 387.4 0.0 6192.4 19-Mar-1997 420.0 280.0 280.0 7-Jan-1998 406.0 377.8 377.8 18-Dec-1998 420.4 300.0 300.0 18-Dec-1998 317.1 300.0 6729.1 18-Dec-1998 68.7 1145.5 1145.5 ORIGINAL For: S c, Structure: Pod 1 C Well: 121 Field: Kuporuk River Unit Location: North Slope, Vers>on #2 TRUE NORTH 2 0 @ 700 330 0 40 290 70 280 80 270 2 90 260 -10,n !UU 250 110 120 " '*,,1100 , 230 13Q ~ ')~n L.LU 210 150 * 2300 , , , , , , 200 190 160 70 0. \i!) Normo; Plane Travelli 9 Cylinder Feet Ail depths show are Measured de ns on rence We I Structu re : Field: Kuparuk River Unit Location: North Slope. feet reference Vertical Depths ore reference #121 RKB 91 <- West (feet) 400 2)80 360 340 320 :\00 280 260 24-0 220 200 180 L_____L____L_____L - -----L--- -_--1_----_--1_-_-L_~--_-L_-_----L_-_~____l____J - -- 1- - - ~ _.L ~~j - ~ _~L~._.,~-- - L___-l_----J-----~ 100 1000 160 140 --- --- 0~ @/j 1500 1400 1100 11 120 100 80 60 40 iTüO . / . BOO 800 / . 700 _'V.g'ÓO 1200 "",,/.-9ÕO ///...fÓOO #~ÔO 1300 1200 /1100 IJOO ----- -------.-"oc / / / '" --13ÓO ///////// 00 ",-1200 / . ~ 300 @ 800 / .1000 / / . -gOO / ;/ 1 100 dY 20 0 20 (f /" 600 /' 800 . ~OO / . 1000 & 40 40 20 0 20 40 (/) 0 60 C --+- ::r ~ 80 --+, CD CD -+ '--/ 100 I V 120 140 (j7 160 180 200 by bmichoel Dote plotted For: S McKeever 29-Mor-.2001 Field: Kuparuk River Unit Reference 121 Version #2. Coordinates arc in feet reference sial #121 Vertical Depths are reference Est. RKB iNTE:;,) 4400 4200 4000 3800 3600 ,(~ .---___---"-3100 ..- - \- - 3400 r; - - - 3700) l.~.: / Location: North Slope, Alaska 3400 2600 <- West (feet) 1800 ~ - - "1- - --"(600 í 600 -- -- .- --- ---JI¡-' - / - / - - -'-900 - - :600 - - "'2500 - - --2800 ,)200 3000 2800 2400 2200 2000 4600 1600 1400 1200 1000 800 4300 4000 00 [illL 2200 @ 1900 600 I v / / /1600 VJ 0 C --+ :r r--., -+. CD CD --+ '----" ( ( ( ( lC-121 Drilling Hazards Summal"¥ (SEE WELL PLAN FOR DETAILED DISCUSSION OF THESE RISKS) en Hole Hazard Broach of Conductor Risk Level Moderate Gas Hydrates Moderate Running Sands and Gravels Moderate Abnormal Reservoir Pressure Lost circulation Hole swabbing on trips Low Low Moderate 2" Casin Interval Miti ation Strate Monitor cellar continuously during interval. Control drill, Reduced pump rates, Reduced drilling fluid temperatures, Additions of d ri Itreat. Maintain planned mud parameters, Increase mud weight, use weighted swee s run ravel isolation strin . Diverter drills, increased mud weight. Reduced um rates mud rheolo LCM Trip speeds, Proper hole filling, pumping out 1C-121 Drilling Hazards Summary 0 RIG I N A L prepared by Steve MC:;~;;; ~ ( " West Sak lC-121 MoÎ~ .Jore Injector, Cement Loads and Cet_~ADE Summary. 45 % Excess Below permafrost, 300 % Above. 7-7/8" Open hole. TD @ 6740' l\1D. Single Stage Design. 5-112" X 3-112" Tapered String. 5-112" X 3-112" Cross over @ 6047'MD. Tail Slurry TOC @ 5547' MD. (500' above Cross Over) Port collar for no cement to surface contingency. Port Collar @ 1000' MD Base of permafrost @ 2287' l\1D. Volume Cales: Pump 40 bbls CW preflush, 50 bbls MudPUSH XL @ 10.2 ppg. Cement from TD to 5547' MD with Class G + adds @ 15.8 ppg, and from 5547' to surface with ASLite @ 10.7 ppg. Lead Slurrv Reauirements: ASLite @ 10.7 ppg, Class G + 50% D124, 3.5% D44, 0.4% D46, 30% D53, 1.5% S 1, 1.5% D79 - 4.44 ft3/sk (5547' - 2287') x 0.1733 ft3/ft x 1.45 (45% excess) 2287' x 0.1733 x 4 (300% excess) 819.18 ft3 + 1585.34 ft3 2404.52 ft3/4.44 ft3/sk = 819.18 ft3 = 1585.34 ft3 = 2404.52 ft3 = 541.5 sks Round upto 550 sks Tail Slurrv Reauirements: Expanding Cement @ 15.8 ppg, Class G + 0.3% D65, 0.2% D800, 2.0 gps D600G, 0.15% D35, 0.2% D47, 4.5% D174 - 1.22 ft3/sk (6740' - 6047') x 0.2714 ft3/ft x 1.45 (45% excess) (6047' - 5547') x 0.1733 ft3/ft x 1.45 (45% excess) 80' (shoe joints) x 0.0488 ft3/ft 272.71 ft3 + 125.64 ft3 + 3.90 ft3 402.25 ft3/1.22 ft3/sk = 272.71 ft3 = 125.64 ft3 = 3.90 ft3 = 402.25 ft3 = 329.7 sks Round upto 340 sks CemCADE* Summary: Fluid sequence: Establish circulation using FW. 40 bbl CWI00 preflush, Drop Bottom Plug, 50 bbls 10.2 ppg MudPUSH XL spacer, 550 sks (435 bbls) ASLite Lead, 340 sks (74 bbls) Class G + adds. Drop Bottom Plug. Displacement is approximately 150 bbls. Circulation: Circulation and cementing at or less than 6 bpm is within safe ECD to avoid breaking down the formation. Recommend dropping the rate below 3 bpm for the last 20 bbls of displacement for bumping the plug as well as maintaining returns. Run dye marker in the spacer to provide insight into the decision to open port collar or performing a top job. Recommended Conditioned Mud Properties: 9.6 ppg, PV < 15, Ty < 15, as thin and light as possible for effective mud removal. 04-10-2001 AT ORIGINAL ~ Well # 1 C-1~ I, AFE #AK xxxx West Sak ( nobore Injector 5-1/211 x 3-1/211 Tapered String Planned Completion Schematic v1.0 PHilliPS Alaska, Inc. A Subsidiary of PHILLIPS PETROLEUM COMPANY Christmas Tree: Vetco-Gray, API5K 7-1/16. Flange Bottom x API5K 3-1/8" Valves, with Otis 3-1/8" 5K Tree Top Tubing Head: Vetco-Gray, 10-3/4" Gray Quick Connect Bottom x API 5K 7-1/16" Flange Top 1611 Conductor @ +1-161' MD Port Collar @ 1000' MD: TAM 5-1/2" BTC Box x Pin Production Tubing: 3-1/2" 9.3# L-80 EUE 8rd, AB Modified. Production Casing 5-1/2" 15.5# L-80 BTCM XO / SBE to surface Set XO / SBE +/- 100' above top Perforation Production Casing 3-1/2" 9.3# L-80 EUE 8RD-Mod TD to XO / SBE TD 7-7/811 Hole 6740' MD, 4228' TVD Tubing Hanger: 3-1/2" Vetco-Gray wI 3-1/2" pup (EUE 8rd, AB Mod pin> down x 3.725" MCA box up . Casing Hanger: 5-1/2" Vetco-Gray wI 5-1/2" pup (BTCM pin) down x 7.790" MCA box up Nabors Rig 245 RKB @ 0' Eastings: 561 ,856.18 Northings: 5,968,646.69 Elevation: 102.0' AMSL Landing Ring: Vetco-Gray, 16" Weld on Bottom x 13-5/8" Male Overshot Top Gas Lift Mandrel: 3-1/2" x 1" Cameo 'KBG-2-9' w/ dummy valve, IBT special clearance box up x IBT special clearance box down, with 6- foot tubing handling pups (XO to EUE 8rd) installed on top and bottom. (1) Joint Tubing: 3-1/2", 9.3#, L-80, EUE 8rd AB Mod Landing Nipple: 3-1/2" Cameo 'DS' w/ 2.812" No-Go Profile. (1) Joint Tubing: 3-1/2", 9.3#, L-80, EUE 8rd AB Mod Locator Seal Assembly: 3-1/2" Baker GBH-22 '80-40' wi 12' of Seals and Locator, 3-1/2" x 6' L-80 Handling Pup installed on top. EUE 8rd AB Mod Box up. -+-- Casing Bore Receptacle Assembly @ +1- 6047' MD, 3585' TVD: [Baker 5-1/2" XO / Handling Pup, BTC x LTC Baker XO Coupling w/ locator shoulder, LTC x SSE Baker 5" OD x 4" ID Seal Bore Extension 12' Baker XO, SBE x 3-1/211 EUE 8rd (x) Joints Tubing: 3-1/2",9.3#, L-80, EUE 8rd AB Mod, from Landing Sleeve to Seal Bore Extension Landing Sleeve: 3-1/2" Weatherford, installed in top of joint #3. (1) Joint Tubing: 3-1/2",9.3#, L-80, EUE 8rd AB Mod Float Collar: 3-1/2" Weatherford w/ 3-1/2" EUE 8rd Box x Pin. (2) Joints Tubing: 3-1/2",9.3#, L-80, EUE 8rd AB Mod Float Shoe: 3-1/2" Weatherford w/ 3-1/2" EUE 8rd Box Up. ORIGINAL 1C.121 Schematic prepared by Steve McKeever 04/27/01 PHILLlr S Alaska, Inc. A Subsidiary of PHILLIPS PETROLEUM COMPANY ( Post Office Box 100360 Anchorage, Alaska 9951 Q..0360 James Trantham Phone(907)265~ Fax: (907) 265-1535 Email: jtranth@ppco.com April 30, 2001 Daniel T. Seamount, Jr., Chairman Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 (907) 279-1433 Re: Application for Permit to Drill, West Sak Injector lC-121. Dear Commissioner Seamount: Phillips Alaska, Inc. hereby applies for a Permit to Drill an onshore service well, #lC-121, an injector well to provide pressure support for West Sak production. The expected spud date for this well is May 18, 2001. Please find attached for the review of the Commission Form 10-401 and the information required by 20 ACC 25.005. If you have any questions or require any further information, please contact me at 263-6434 or Steve McKeever at 265-6826. Sincerely, /fi.~.tL ~ iLL- /'f/rJZ,-/-( ¿!,II/lh ð$¡e.5 ~)Z T #/7¿:S T ,Æ./);¿7/7/;#/-? ) James Trantham Drilling Engineering Supervisor Operator I Field I i !DIU IPBU !DiU ¡DIU iPBU iPBU ¡DIU jPBU IPBU 'PBU iPBU ¡PBU LEê!:! IPBU iPBU !PBU ¡DIU ¡DIU ¡DIU 'PBU ,PBU iPBU :PBU 'PBU iGPT ¡KRU iKRU ~ :KRU ;KRU iKRU iKRU !KRU ~ 'KRU :KRU :KRU KRU :KRU ,KRU ,KRU :KRU !KRU iKRU :KRU KRU !KRU ,KRU BPX BPX BPX BPX AAI AAI BPX AAI AAI AAI AAI AAI AAI AAI AAI AAI BPX BPX BPX AAI AAI AAI AAI AAI Unocal AAI AAI AAI AAI AAI AAI AAI AAI AAI AAI AAI AAI AAI AAI AAI AAI PAl PAl PAl PAl PAl PAl PAl PAl PAl PAl PAl PAl AAI Well Name ¡1-03/P-16 111-38 11-19/1-18 11-23/0-15 ! 12-35 !12-36 i 1-33/M-23 ! 13-36 ! 14-44 i 15-42 i 15-43 ¡ 15-45 ! 15-46 ! 15-47 115-48 : 15-49 ~-24 ¡ 1-61/Q-20 ! 1-65/N-25 ¡ 18-30 ¡ 18-31 ¡ 18-32 i 18-33 118-34 i 18742 28RD2 j1C-11 !1C-12 ! 1C-13 11C-14 I1C-15 ! 1C-16 ¡ 1C-17 !1C-18 ! 1C-21 i 1C-23 ¡ 1C-25 i1D-õ9 ! 10-10 110-11 !1O-12 ¡ 10-130 110-14 [ 10-140 ! 10-30 , 10-32 : 10-34 110-36 '10-37 KRU : 10-38 ! KRU ¡ 10-39 : KRU : 10-40 ! KRU ; 1O-40A : KRU 10-42 ; KRU 1 E-31 Annular log .---- 1 July 25, 1995-present ! Annular Disposal Approval Log -- - Original Subsequent PTD or Sundry Sundry Total Sundry Approval Approval Volume Approval. Date Dates Injected I Comments , PTD 0 ! 11/6/95 so¡;¡-- 9 !1/19/97 ~ 3 :8/17/95 PTD -8 ¡ 1/13/95 ,~ O ! 10127/95 ~ '8 ¡ 11121/95 ~ 7 ! 10/4/95 ~ 7! 12124/95 ,PTD 3 19/15/95 ~ 5l1717t96 PTD 3 ! 5125/96 PTD -9 ¡ 5/4/96 ~ . 1 16120/96 ~ '4 11218/95 ~ - 8 13/11/96 PTD 4 !4f7196 ~ 2 12121/96 ~ .. -2 i 12116/94 ~ .8 11126/96 .~ '1 ¡ 7126/95 ~ .9 i 9/9/95 PTD '4 i 10/5/95 ~ '--3 ! 10/29/95 .~ '.4 11214/95 PTD 7 i 8/16/95 ~ "2 11/14/97 ~ '7 11129/97 ~ '1 12113/98 ~ 7 !3/17/98 ~ ~9 i 12/30/98 .~ ,~~6 ! 12/31/98 ~ ~4 i 12/2/98 ~ 15 14/2199 ~ ~ ~ ;4 i 5/21/99 ~ \1 15127/99 ~ i5 i 613/98 .~ 19 14/12/98 ~ '2 i 1 0/26/99 ~ 14 i 9/20/99 ~ -13 ¡ 11f7197 ~ \9 ¡ ~ ~ ~ 04 : ~ 73[ SUN 43: ~ 30 ¡ ~ , ~04 ; SUN : 200-077 . SUN 1200-216 ! SUN : 200-119 i SUN SUN PTD 97-138 :8120/97 -- ;N/A , N NO: Never utilized . Y N ¡ 0: Never utilized. no sundry filed - - - - -- - N Y N 2/28/97! 8960: Approval fax from SEW; from SPXA 1995 & 1996 corrected summaries . N Y Y 2126/97 i 32084 ¡ From BPXA Annular Injection Data Entry Screen; frclm1-ß3/Q2(),_.i-40/S22, 1-031P16 : N Y Y 216/96 i 3723: From BPXA Annular Injection Data Entry Screell- N Y Y 2128/97: 4002,from BPXA 1995 & 1996 corrected summaries - - - - - - -- - ,N Y N 2/28/97 ¡ 9879' Letter approval fax; surface broach; volume fr°!ll B'p2<f. 1995 & 1 ¡96 CQ.rrected summaries N Y N 2/28/97) 4137:fromBPXA1995&1996correctedsummaries___- . N Y 12114/98 ¡ 3974. From BPXA Annular Injection Data Entry Screen N N nla i 0 Never utilized : N N nla I 0 ¡ Never utilized ; N Y Y 7/2196 [ 1882 ' Broach to surface - downsqueeze annulus 5/5/96 : N N nla I 0 I Never utilized .N Y N 2/28/97; 3002;trom BPXA 1995 & 1996 corrected summaries--_- : N Y Y 4/11/96 i 3385; From BPXA Annular Injection Data Entry Screen N Y Y 2128/971 4669 'from BPXA 1995 & 1996 corrected summaries ,N N nla i 0: Never utilized---~ =- :-- -- - -- N Y 12114/981 25228' From BPXA Annular Injection Data En!rï Scre_en;.!rom 2-48/013..1-§.5/N25 N N nla I 0' Never utilized ----- - . N Y 12114/98 i 2266: From BPXA Annular Injection Data Entry Screen N Y 12/14/98: 6086'From BPXAAnnular Injection Data Entry Scre~- N Y Y 1/5/96! 3311 . From BPXA Annular Injection Data Entry Screen; from 18-32 N Y Y 1/16/96! 5215: From BPXA Annular Injection Data Entry Screen N N nla i 0 Never utilized .N N Y Y 'y Y ~ Y N ,--, - IN/A :N/A .N/A N/A N/A N/A N/A 'N/A N/A .N/A ,N/A IN/A :N/A 'N/A N/A 'N/A N/A N/A N/A :N/A N/A .N/A N/A 1118/96 ,N/A N/A N/A 118/99 --- - - - --- -- - -- - - -- - . --- - - 4/9/97 ¡ 34985: from AAI report submitted 2/26/99 4/9/99 ¡ 35095: from AAI report submitted 2/26/99 4/9/991 26900. from AAI report submitted 2/26/99 i contingent on data submittal, data not in wellJi.l01T ioJ~.o 7127/99! 48990. permission granted 4/22199 to exceed 35.00°.t~bll!mil?!ion- 0 hydrate problems, broaching, no 10-403- in well file..: - - contingent on 10-403, annular denied 12/23~13. _approved 3/18/99 Approval # 399-070 Expired PTD -- - --- - - - - 34570 from AAI 10/5/99 report, leller approwlto exceed volul11e Jif11it grante.ct 8-'11/99 34936 . from AAI1 0/5/99 report 32640 from AAI report submitted 2/26/99 -- - 35573 contingent on data submillal - in v.ell file; from ~l ~eport submilled 2/26/99 235. w/request later-info not provided 32891 from AA110/1312000 report - auth. expired - 0' contingent on data submittal, LOT data in well file; Ne"er utilized - - 35504 notified commission of exceedence, from PPCO 1 Q/13/2000 quarteny report Y Y Y N --- -- - : 14.9, 14_1 N !13.8 Y Y Y Y Y Y N N Y Y N N 10/13/00 : 3/18/99 6/11/99 - 5128/99 4130/99 717198 N/A 10/5/99 ¡ 7/27/99 ' r""-=-. 9/29/99 N/A - - 10/5/00 N Y Y Y 12115/97, 31722 from PPCO 1/19/2001 quarteny report - 23599 from PPCO 4/24/01 quarter1y report, source w~~~:1D-39 32233 LOT to 13_1. 11.4 for annular. Sundry approval #300-280 30204 from PPCO 1/1912001 quarter1y report w/request when well completed lost rtrns during cmt'g, found TOC '740', top job- LOT @shoe 14.9, deep test 13.5; total from PPCO 34007 10/13/2000 quarteny report ~ãilili:iiar at later date-not w/~d.- . plugged back for sit before annular injection w/request annular at later date-not w/ptd.. - - 32405 from PPCO 4124/2001 quarteny report. source wells: 1 D-37. 1 D--39 - - 33745. contingent on data submittal - in v.ell file; from AAI reoort submilled 2/26/99. 4/9/99 7/28/00 N/A Page 1 American Expresse Cash Advance.Draft 128 -f DATE~('/¿t>, 2£)O! .82-4011021 (. .. . , ~~~:~~:E 11/¿r.Jú >Þ--Þ- {J-é¡i ~ /â~t¿ S/co'DO I !J Issued by Intearated Payment System. Inc. En¡lewood. Colorado PERIOD ENDING NOT VALID FORAMOUNT OVER $1000 /ffl)..... ..SHAR..... ..~.....:'.-.-......~.....................8..........U. i......~.................'.'............'....... /. . ~ .. ;)~!. ~ 1110 .? 5000 5~bll.O. 28 . Payable at Norwest Bank of Grand Junction - Downtown. NA Grand Junction. Colorado .: .0 2 .00 1..00.: ~ 5 "-~ A WELL PERMIT CHECKLIST COMPANY WELL NAME / c ~/.2..J PROGRAM: exp - dev - redrll- serv X wellbore seg _ann. disposal para req- FIELD & POOL "i' '1 f'"JJ [; r=;) INIT CLASS GEOL AREA 77 rT UNIT# /// ¡:;,6 ON/OFF SHORE ~ ADMINISTRATION 1. Permit fee attached. . . . . . . . . . . . . . . . . . . . . . . N 2. Lease number appropriate. . . . . . . . . . . . . . Y N 3. Unique well name and number. .. . . . . . . . . . . . . . . . Y N 4. Well located in a defined pool.. . . . . . . . . . . . . . . . . Y N 5. Well located proper distance from drilling unit boundary. . . . Y N 6. Well located proper distance from other wells.. . . . . . . . . Y N 7. Sufficient acreage available in drilling unit.. . . . . . . . . . . Y N 8. If deviated, is well bore plat included.. . . . . . . . . . . . . . Y N 9. Operator only affected party.. . . . . . . . . . . . . . . . . . Y N 10. Operator has appropriate bond in force. . . . . . . . . . . . . Y N 11. Permit can be issued without conservation order. . . . . . . . Y N ~R DATE 12. Permit can be issued without administrative approval.. . . . . Y N ~ ) 13. Can permit be approved before 15-day wait.. . . . . . . . . . Y N ENGINEERING 14. Conductor string provided. . . . . . . . . . . . . . . . . . . N 15. Surface casing protects all known USDWs. . . . . . . . . . . N 16. CMT vol adequate to circulate on conductor & surf csg. . . . . N 17. CMT vol adequate to tie-in long string to surf csg. . . . . . . . '-"¥-N- ~~ ç"..~~~ Cu.~ '\ ~\:. c ~ ~ 18. CMT will cover all known productive horizons. . . . . . . . . . ~ N ( 19. Casing designs adequate for C, T, B & permafrost. . . . . . . N 20. Adequate tankage or reserve pit.. . . . . . . . . . . . . . . . N Q'-l't<:>\\"', ,,'\. '- ) ~ ~~Nc:t; ~,,~~ 21. If a re-drill, has a 10-403 for abandonment been approved. . . \.::)~ ~ ..::::. 22. Adequate wellbore separation proposed.. . . . . . . . . . . . Y N 23. If diverter required, does it meet regulations. . . . . . . . . . N 24. Drilling fluid program schematic & equip list adequate. . . . . N 25. BOPEs, do they meet regulation. . . . . . . . . . . . . . . . N 26. BOPE press rating appropriate; test to ~'DOCJ psig. N H..~~~-\~\'-'t(.:,é\~"::~ ~ ~~~ \>\G.,,~~~c::;..--\ ~ S(:)Da?~\, "?:>~ÖCJ \'=> 27. Choke r:nanifold c?mplies w/A~I RP-53 (May 84). . . . . . . . N \VIO\<t.~~ ~Œ~~~.. 28. Work will occur without operation shutdown. . . . . . . . . . . ~. r} .- ....~ D . ð~ '..).Jl"c:.rr"'-~:\<.:... B. 1(u,'1'-\..-'-- 29. Is presence of H2S gas probable.. . . . . . . . . . . . . . . . Y @ ,....~ '\ <:.etcy-\ \ \>-CJ ~. ~ ,.. ~ ~ "(" ;~. :;e~mit can bt ~ssued ~/Ot hydrogen sulfide measures. . . . . Ä~ N ¿ 32. Seismic analysis of shallow gas zones. . . . . . . . . . . . . N ~/If v APPR D}T~ 33: s:a:::e::d:tiO:nS:::~ ;::;-::::)sur~ ~~n~s : : : : : : : N ~ 34. Contact name/phone for weekly progress reports [exploratory 0.. 1 Y N ANNULAR DISPOSAL35. With proper cementing records, this plan. (A) will contain waste in a suitable receiving zone; . . . . . . . (B) will not contaminate freshwater; or cause drilling waste. .. to surface; (C) will not impair mechanical integrity of the well used for disposal; Y N (D) will not damage producing formation or impair recovery from a Y N pool; and E will not circumvent 20 AAC 25.252 or 20 MC 25.412. Y N GEOLOGY: ENGINEERING: UIC/Annular COMMISSION: ~~~ WM 8~s~ ----- ~ JM~ A~ QATE q'LfI{ ~ -- GEOLOGY APPR DATE -- -- Y N Y N ~~,~~.\t) G*r ~~~ ~~'t~ko C\",.~?~~d \~ C\.~,,-....) \~~ e:." c..lC1.~~ a:. ~t \ LJ>~7 AfJ.Pf:.A ,L.70 . Ðé,l\foJi LUt..tl~ rt.-'f"" ''''~ ~d.\clœ-~ t'O~~t1.~<L c.t~ o..",,,-ù\~~ f'" Com mentsllnstructions: c:\msoffice\wordian\diana\checklist (rev. 11/011100) c 0 Z 0 -I ~ ::0 -I m Z -I :I: en » ( ::0 m » Nt, ;( Well History File APPENDIX Information of detailed nature that is not particularty germane to the Well Permitting Process but is part of the history file. . To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. . .' No special' effort has been made to chronologically . . organize this category of information. ·ids ~ I Memory Multi-Finger Caliper Log Results Summary Company: Log Date: Log No. : Run No.: Pipe1 Desc.: Pipe1 Use: CONOCOPHILLlPS ALASKA, INC. August 6, 2005 7512 1 3.5" 9.3Ib. L-80 Tubing & Liner Well: 1C-121 Field: Kuparuk State: Alaska API No.: 50-029-23015-00 Top Log IntvI1.: Surface Bot. Log IntvI1.: 6,192 Ft. (MD) Inspection Type: Corrosive & Mechanical Damage Inspection COMMENTS: This caliper data is tied into the Seal Tail @ 6,167' (Driller's Depth). This log was run to assess the condition of the 3.5" tubing and liner with respect to corrosive and mechanical damages. The 3.5" tubing and liner logged appear to be in good to fair condition with respect to corrosive damage, with a maximum wall penetration of 34% in joint 36 (1,158'). The damage appears in the forms of general corrosion and isolated pitting, at times appearing as a line of pits. No significant areas of cross- sectional wall loss or 1.0. restrictions are recorded throughout the tubing and liner logged. Cross-sectional drawings of the most significant events recorded are included in this report. The distribution of maximum recorded penetrations is illustrated in the Body Region Analysis Page of this report. MAXIMUM RECORDED WALL PENETRATIONS: Isolated Pitting Isolated Pitting Corrosion Isolated Pitting Corrosion ( 34%) ( 25%) ( 24%) ( 24%) ( 24%) Jt. Jt. Jt. Jt. Jt. 36 @ 21 @ 181 @ 182 @ 162 @ 1,158 Ft. (MD) 691 Ft. (MD) 5,722 Ft. (MD) 5,753 Ft. (MD) 5,102 Ft. (MD) MAXIMUM RECORDED CROSS-SECTIONAL METAL LOSS: No significant areas of cross-sectional wall loss (> 8%) are recorded throughout the tubing and liner logged. MAXIMUM RECORDED ID RESTRICTIONS: No significant 1.0. restrictions are recorded throughout the tubing and liner logged. S...r....J~N'...'E-I-" f\I'IG C1 9 ¡DOte:" ,: .....I"'\b~" !.".I /..1[ l; J Z (,; (_ <.. J I Field Engineer: L. Mills-Dawson Analyst: M. Tahtouh Witness: T Senden I ProActive Diagnostic Services, Inc. I P.O. Box 1369, Stafford, TI< 77497 Phone: (281) or (888) 565-9085 Fax: (281) 565-1369 E-mail: PDS@memorylog.com Prudhoe Bay Field Office Phone: (907) 659-2307 Fax: (907) 659-2314 ~ Gl-\)~ G l ck3s,. Well: Field: Com pany: Country: I Tubing: Nom.OD 3.5 ins lC-121 Kuparuk CONOCOPHILLlPS ALASKA, INC. USA Weight 9.3 ppf Grade & Thread L-80 Penetration and Metal loss (% wall) _ penetration body 200 150 100 50 k1 1 to 10% o 0 to 1% !11m metal loss body - 10 to 20 to 40 to over 20% 40% 85% 85% Number of joints analysed (total = 202) pene. 0 8 184 10 0 0 loss 4 1 98 0 0 0 0 200 Damage Configuration ( body) 150 100 50 o isolated general line ring hole / poss pitting corrosion corrosion corrosion ible hole Number of joints damaged (total = 177) 161 13 3 0 0 PDS Report Overview Body Region Analysis Survey Date: Tool Type: Tool Size: No. of Fingers: Analyst: Nom.lD 2.992 ins August 06, 2005 MFC 24 No. 00387 1.69 24 M. Tahtouh Nom. Upset 3.5 ins Upper len. 1.2 ins Lower len. 1.2 ins Damage Profile (% wall) ~'\!'e metal loss body 50 _ penetration body o 01 100 GLM 1 Bottom of Survey = 194.5 Analysis Overview page 2 ;.( It PDS KEPORT JOINT TABULATION sHEET Pipe: 3.5 in 9.3 ppf L-80 Well: lC-121 Body Wall: 0.254 in Field: Kuparuk Upset Wall: 0.254 in Company: CONOCOPHILLlPS ALASKA, INC. NominaII.D.: 2.992 in Country: USA Survey Date: August 06, 2005 Joint Jt. Depth Pen. Pen. Pen. Metal Min. Damage Profile No. (Ft.) Upset Body % Loss I.D. Comments (% wall) (Ins. ) (Ins.) %) (Ins.) 0 50 100 .1 31 0 0.03 12 2 2.93 PUP 1 36 0 0.04 15 5 2.93 Shallow corrosion. 1.1 67 0 0.03 13 2 2.90 PUP Shallow corrosion. 1.2 77 0 0.03 11 1 2.90 PUP 1.3 87 0 0.03 13 1 2.91 PUP Shallow pitting. 2 95 0 0.04 17 4 2.93 Shallow pitting. 3 127 0 0.03 13 3 2.94 Shallow pitting. 4 157 0 0.04 15 4 2.93 Shallow pitting. 5 189 0 0.04 14 2 2.93 Shallow pitting. 6 220 0 0.04 14 4 2.92 Shallow pitting. 7 252 0 0.03 13 4 2.92 Shallow pitting. 8 283 0 0.04 14 5 2.92 Shallow pitting. 9 314 0 0.03 13 4 2.93 Shallow pitting. 10 346 0 0.03 13 4 2.94 Shallow pitting. 11 376 0 0.04 17 4 2.93 Shallow pitting. 12 407 0 0.03 13 3 2.92 Shallow pitting. 13 439 0 0.04 14 4 2.94 Shallow pitting. 14 470 0 0.03 12 5 2.94 15 501 0 0.03 13 6 2.92 Shallow pitting. 16 533 0 0.04 14 7 2.93 Shallow pitting. 17 564 0 0.03 13 4 2.91 Shallow pitting. 18 595 0 0.03 12 3 2.92 Shallow pitting. 19 627 0 0.04 14 4 2.94 Shallow pitting. 20 658 0 0.05 18 3 2.93 Shallow pitting. 21 690 0 0.06 25 4 2.94 Isolated pitting. 22 721 0 0.05 20 6 2.92 Shallow pitting. 23 752 0 0.04 14 5 2.94 Line of shallow pits. 24 784 0 0.04 14 6 2.94 Line of shallow pits. 25 814 0 0.04 16 4 2.92 Line of shallow pits. Lt. Deposits. 26 846 0 0.04 15 3 2.92 Shallow corrosion. 27 878 0 0.04 14 7 2.92 Shallow pitting. 28 907 0 0.05 21 5 2.92 Isolated· pitting. 29 939 0 0.04 17 5 2.91 Shallow pitting. 30 970 0 0.05 21 2 2.92 Corrosion. Lt. Deposits. 31 1001 0 0.05 19 3 2.90 Shallow pitting. 32 1033 0 0.03 13 4 2.92 Shallow corrosion. 33 1064 0 0.05 18 5 2.95 Shallow corrosion. 34 1095 0 0.05 20 4 2.94 Shallow pitting. 35 1127 0 0.04 15 5 2.93 Shallow pitting. 36 1158 0 0.09 34 5 2.90 Isolated pitting. 37 1190 0 0.04 16 6 2.93 Shallow pittin~. 38 1221 0 0.04 17 3 2.91 Shallow pitting. 39 1252 0 0.04 17 6 2.93 Shallow pitting. 40 1284 0 0.04 15 4 2.94 Shallow pitting. 41 1315 0 0.04 15 6 2.93 Shallow pitting. 42 1346 0 0.04 16 3 2.93 Shallow corrosion. Lt. Deposits. 43 1378 0 0.03 12 6 2.94 44 1409 0 0.04 14 4 2.91 Shallow pitting. 45 1441 0 0.04 17 4 2.92 Shallow pitting. 46 1472 0 0.04 16 4 2.91 Shallow pitting. Lt. Deposits. I Penetration· Body I>'!, Metal Loss Body Page 1 PDS'(KEPORT JOINT TABULATION( ~HEET Pipe: 3.5 in 9.3 ppf L-80 Well: lC-121 Body Wall: 0.254 in Field: Kuparuk Upset Wall: 0.254 in Company: CONOCOPHILLlPS ALASKA, INC. NominaII.D.: 2.992 in Country: USA Survey Date: August 06, 2005 Joint Jt. Depth Pen. Pen. Pen. Metal Min. Damage Profile No. (Ft.) Upset Body % Loss I.D. Comments (% wall) (Ins.) (Ins.) OJ (Ins.) 0 50 100 10 47 1503 0 0.04 16 -, 2.91 Shallow pitting. .) 48 1535 0 0.04 16 4 2.92 Shallow pitting. 49 1566 0 0.03 13 6 2.94 Shallow pitting. 50 1598 0 0.04 16 3 2.94 Shallow pitting. 51 1629 0 0.04 15 2 2.93 Shallow pitting. 52 1661 0 0.04 15 5 2.93 Shallow pitting. 53 1692 0 0.04 15 4 2.94 Shallow pitting. 54 1724 0 0.04 16 4 2.95 Shallow pitting. 55 1754 0 0.04 16 7 2.94 Shallow pitting. 56 1785 0 0.03 13 6 2.94 Shallow pitting. 57 1817 0 0.04 16 :2 2.91 Shallow pitting. 58 1848 0 0.04 17 :2 2.91 Shallow pitting. Lt. Deposits. 59 1880 0 0.05 18 :2 2.92 Shallow pitting. 60 1911 0 0.04 15 4 2.93 Shallow pitting. 61 1942 0 0.04 14 6 2.94 Shallow pitting. 62 1974 0 0.04 15 6 2.92 Shallow pitting. 63 2005 0 0.03 13 2 2.92 Shallow pitting. 64 2037 0 0.03 12 2 2.93 65 2068 0 0.04 14 4 2.91 Shallow pitting. 66 2100 0 0.04 16 3 2.92 Shallow corrosion. 67 2131 0 0.04 15 3 2.88 Shallow pitting. 68 2163 0 0.04 16 4 2.92 Shallow pitting. 69 2194 0 0.04 16 5 2.93 Shallow pitting. 70 2226 0 0.03 13 3 2.93 Shallow pitting. 71 2257 0 0.04 14 3 2.91 Shallow pitting. 72 2288 0 0.05 19 4 2.92 Shallow pitting. 73 2320 0 0.03 12 5 2.89 74 2351 0 0.03 13 4 2.89 Shallow pitting. Lt. Deposits. 75 2380 0 0.04 14 2 2.88 Shallow pitting. Lt. Deposits. 76 2410 0 0.04 14 3 2.91 Shallow pitting. 77 2440 0 0.04 17 5 2.93 Shallow pitting. 78 2472 0 0.04 16 4 2.93 Shallow pitting. 79 2504 0 0.04 16 4 2.91 Shallow pitting. 80 2535 0 0.04 15 4 2.90 Shallow pitting. 81 2567 0 0.03 13 3 2.91 Shallow pitting. 82 2598 0 0.04 15 3 2.91 Shallow pitting. 83 2629 0 0.04 15 5 2.93 Shallow pitting. 84 2658 0 0.04 14 6 2.92 Shallow pitting. 85 2690 0 0.03 11 6 2.91 86 2721 0 0.04 16 3 2.89 Shallow pitting. 87 2751 0 0.05 19 4 2.92 Shallow pitting. 88 2783 0 0.05 18 4 2.91 Shallow pitting. 89 2814 0 0.03 13 4 2.91 Shallow pitting. 90 2846 0 0.04 17 4 2.93 Shallow pitting. 91 2877 0 0.03 13 3 2.93 Shallow pitting. 92 2908 0 0.04 14 5 2.91 Shallow pitting. 93 2940 0 0.04 15 7 2.92 Shallow pitting. 94 2971 0 0.04 14 2 2.93 Shallow pitting. 95 3002 0 0.03 12 3 2.89 96 3034 0 0.03 11 3 2.91 I Penetration Body ¡:¡':Ii; Metal Loss Body Page 2 í ~ PDSKEPORT JOINT TABULATION SHEET Pipe: 3.5 in 9.3 ppf L-80 Well: 1 C-121 Body Wall: 0.254 in Field: Kuparuk Upset Wall: 0.254 in Company: CONOCOPHILLlPS ALASKA, INC. NominaII.D.: 2.992 in Country: USA Survey Date: August 06, 2005 Joint Jt. Depth Pen. Pen. Pen. Metal Min. Damage Profile No. (Ft.) Upset Body % Loss I.D. Comments (% wall) (Ins.) (Ins.) % (Ins.) 0 50 100 97 3065 0 0.04 15 6 2.91 Shallow pitting. 98 3096 0 0.04 15 4 2.93 Shallow pitting. 99 3128 0 0.03 13 -. 2.89 Shallow pitting. J 100 3159 0 0.04 16 -. 2.91 Shallow pitting. J 101 3191 0 0.04 15 .1 2.90 Shallow pitting. 102 3221 0 0.03 12 3 2.91 Shallow pitting. 103 3252 0 0.04 16 4 2.92 Shallow pitting. 104 3284 0 0.05 18 3 2.92 Shallow pitting. 105 3315 0 0.03 13 .1 2.89 Shallow pitting. 106 3347 0 0.02 9 .1 2.85 107 3377 0 0.03 13 4 2.92 Shallow pitting. 108 3409 0 0.04 16 5 2.93 Shallow corrosion. 109 3440 0 0.03 11 6 2.94 110 3471 0 0.03 13 3 2.94 Shallow pitting. 111 3503 0 0.03 13 4 2.94 Shallow pitting. 112 3534 0 0.03 13 .1 2.92 Shallow pitting. 113 3565 0 0.05 20 4 2.95 Corrosion. 114 3597 0 0.03 11 5 2.93 115 3628 0 0.04 14 5 2.93 Shallow pitting. 116 3660 0 0.03 12 .1 2.90 Shallow pitting. 117 3691 0 0.04 17 3 2.91 Shallow pitting. Lt. Deposits. 118 3722 0 0.03 10 6 2.93 119 3754 0 0.04 14 6 2.93 Shallow pitting. 120 3785 0 0.04 15 .1 2.92 Shallow pitting. 121 3816 0 0.04 15 4 2.92 Shallow pitting. 122 3847 0 0.04 15 4 2.93 Shallow pitting. Lt. Deposits. 123 3877 0 0.03 13 6 2.92 Shallow pitting. 124 3909 0 0.03 10 .1 2.94 125 3941 0 0.03 12 6 2.92 126 3972 0 0.04 16 4 2.90 Shallow pitting. 127 4004 0 0.04 16 .1 2.92 Shallow pitting. 128 4035 0 0.04 15 2 2.91 Shallow pitting. 129 4066 0 0.04 14 4 2.91 Shallow pitting. 130 4098 0 0.03 13 2 2.88 Shallow pitting. 131 4129 0 0.02 9 2.91 132 4161 0 0.05 18 2 2.90 Shallow pitting. , 133 4191 0 0.04 14 3 2.90 Shallow pitting. 134 4222 0 0.03 10 2 2.93 135 4253 0 0.03 10 .1 2.95 136 4285 0 0.04 17 8 2.93 Shallow pitting. 137 4316 0 0.04 17 3 2.91 Shallow pitting. 138 4348 0 0.05 20 6 2.88 Shallow pitting. 139 4379 0 0.04 16 4 2.93 Shallow pitting. 140 4410 0 0.03 11 3 2.93 141 4440 0 0.04 15 .1 2.93 Shallow pitting. 142 4472 0 0.05 19 4 2.91 Shallow pitting. 143 4503 0 0.03 12 4 2.91 144 4534 0 0.04 14 6 2.89 Shallow pitting. 145 4566 0 0.04 14 5 2.94 Shallow pitting. 146 4597 0 0.04 14 5 2.91 Shallow pitting. I Penetration Body :1!h Metal Loss Body Page 3 Ii' i ~ . PDSKEPORT JOINT TABULATION SHEET Pipe: 3.5 in 9.3 ppf L-80 Well: 1C-121 Body Wall: 0.254 in Field: Kuparuk Upset Wall: 0.254 in Company: CON OCOPH I LLI PS ALASKA, IN C. NominaII.D.: 2.992 in Country: USA Survey Date: August 06, 2005 Joint Jt. Depth Pen. Pen. Pen. Metal Min. Damage Profile No. (Ft.) Upset Body 0/0 Loss I.D. Comments (% wall) (Ins.) (Ins.) 01<) (Ins.) 0 50 100 147 4629 0 0.03 13 .2 2.90 Shallow pitting. 148 4660 0 0.04 17 4 2.92 Shallow pitting. 149 4692 0 0.03 12 .2 2.94 150 4723 0 0.04 17 3 2.93 Shallow pitting. 151 4755 0 0.04 16 .2 2.90 Shallow pitting. 152 4786 0 0.03 12 .2 2.93 153 4818 0 0.04 14 4 2.90 Shallow pitting. 154 4849 0 0.04 14 .2 2.94 Shallow pitting. 155 4880 0 0.04 15 6 2.92 Shallow pitting. 156 4912 0 0.04 15 4 2.93 Shallow pitting. 157 4942 0 0.04 17 .2 2.89 Shallow pitting. 158 4974 0 0.04 14 4 2.91 Shallow pitting. 159 5005 0 0.05 21 3 2.91 Isolated pitting. 160 5036 0 0.04 15 3 2.91 Shallow pitting. 161 5068 0 0.04 15 2 2.91 Shallow pitting. 162 5099 0 0.06 24 .2 2.91 Corrosion. 163 5131 0 0.05 18 .2 2.90 Shallow pitting. 164 5162 0 0.04 15 6 2.91 Shallow pitting. 165 5193 0 0.05 21 4 2.92 Isolated pitting. 166 5224 0 0.04 16 4 2.91 Shallow pitting. 167 5254 0 0.04 14 3 2.87 Shallow pitting. Lt. Deposits. 168 5285 0 0.04 15 3 2.88 Shallow pitting. 169 5316 0 0.04 15 2 2.86 Shallow pitting. Lt. Deposits. 170 5348 0 0.04 17 4 2.85 Isolated pitting. Lt. Deposits. 171 5379 0 0.03 13 2 2.91 Shallow pitting. 172 5410 0 0.04 17 .2 2.93 Shallow pitting. 173 5442 0 0.04 14 2 2.92 Shallow pitting. 174 5473 0 0.04 15 4 2.92 Shallow pitting. 175 5504 0 0.04 17 6 2.95 Shallow pitting. 176 5536 0 0.03 13 7 2.93 Shallow pitting. 177 5567 0 0.04 15 5 2.93 Shallow pitting. 178 5597 0 0.04 17 3 2.95 Shallow corrosion. 179 5628 0 0.04 15 6 2.91 Shallow pitting. 180 5660 0 0.04 16 5 2.91 Shallow pitting. 181 5691 0 0.06 24 4 2.89 Corrosion. Lt. Deposits. 182 5723 0 0.06 24 5 2.89 Isolated pitting. 183 5754 0 0.04 17 5 2.91 Shallow pitting. 184 5785 0 0.06 23 4 2.92 Isolated pitting. .185 5816 0 0.03 13 7 2.94 Shallow pitting. 186 5848 0 0.03 12 6 2.91 187 5879 0 0.04 16 4 2.92 Shallow pitting. 188 5911 0 0.04 15 2 2.94 Shallow pitting. 189 5942 0 0.05 18 6 2.94 Shallow pitting. 190 5973 0 0.04 16 6 2.92 Shallow pitting. 191 6004 0 0.04 15 3 2.95 Shallow pitting. 192 6036 0 0.05 20 .2 2.91 Corrosion. 192.1 6068 0 0.04 18 6 2.92 PUP Shallow pitting. 192.2 6072 0 0 0 0 N/A GLM (Latch @ 6:00) 192.3 6080 0 0.04 14 6 2.91 PUP Shallow pitting. 193 6085 0 0.03 13 4 2.94 Shallow corrosion. I Penetration Body ¡:]~!t: Metal Loss Body Page 4 ;1' l \ PDS KEPORT JOINT TABULATION SHEET Pipe: 3.5 in 9.3 ppf L-80 Well: lC-121 Body Wall: 0.254 in Field: Kuparuk Upset Wall: 0.254 in Company: CON OCOPH I LLI PS ALASKA, IN C. Nominal 1.0.: 2.992 in Country: USA Survey Date: August 06, 2005 Joint Jt. Depth Pen. Pen. Pen. Metal Min. Damage Profile No. (Ft.) Upset Body % Loss 1.0. Comments (% wall) (Ins.) (Ins.) 01<) (Ins.) 0 50 100 193.1 6116 0 0 0 0 2.81 OS Nipple ~ 194 6117 0 0.04 15 8 2.93 Shallow pitting. 194.1 6149 0 0.01 3 1 2.96 PUP 194.2 6155 0 0 0 0 4.00 SBE 194.3 6169 0 0 0 0 3.00 SEAL 1 94.4 6179 0 0.02 8 :2 2.96 PUP r 1 94.5 6191 0 0 0 0 3.00 Seal Tail 'Penetration Body Ii' Metal Loss Body Page 5 cII3.. ....__.~..,. ""-. ""lS . II- PDS Report Cross Sections Well: Field: Company: Country: Tubing: 1 C-121 Kuparuk CONOCOPHILLlPS ALASKA, INC. USA 3.5 ins 9.3 ppf L-80 Survey Date: Tool Type: Tool Size: No. of Fingers: Analyst: August 06, 2005 MFC 24 No. 00387 1.69 24 M. Tahtouh Cross Section for Joint 36 at depth 1158.347 ft Tool speed = 50 Nominal 10 = 2.992 Nominal 00 = 3.500 Remaining wall area = 99 % Tool deviation = 27 0 Finger 2 Penetration = 0.087 ins Isolated Pitting 0.09 ins = 34% Wall Penetration HIGH SIDE = UP Cross Sections page 1 ~. .>. ..........__.~-. .. .. ..... ·-··6 - . If· PDS Report Cross Sections Well: Field: Company: Country: Tubing: 1 C-121 Kuparuk CONOCOPHILLlPS ALASKA, INC. USA 3.5 ins 9.3 ppf L-80 Survey Date: Tool Type: Tool Size: No. of Fingers: Analyst: August 06, 2005 MFC 24 No. 00387 1.69 24 M. Tahtouh Cross Section for Joint 21 at depth 690.55 ft Tool speed = 49 Nominal 10 = 2.992 Nominal 00 = 3.500 Remaining wall area = 99 % Tool deviation = 11 0 ,-£~----~, finger 24 Penetration = 0.064 ins Isolated Pitting 0.06 ins = 25% Wall Penetration HIGH SIDE = UP Cross Sections page 2 TUBING (0-6155, 00:3.500, 10:2.992) ::>ROOUCTlON (0-6164, 00:5.500, Wt15.50) NIP (6115-6116, 00:4.480) ~. ConocoPhillips AlaSka, Inc. 1C-121 Ii { KRU 1C-121 API: 500292301500 SSSV Type: None Well Type: INJ Orig 6/12/2001 Completion: LastW/O: Angle @ TS: deg @ Angle @ TD: 22 deg @ 6876 Annular Fluid: Rev Reason: Reformat, show perfs Last Update: 3/5/2004 Reference Log: Last Tag: 6693 Last Tag Date: 11/5/2001 Casing String - ALL STRINGS Description CONDUCTOR PRODUCTION PROD LINER Tubing String - TUBING Size I Top 3.500 0 Perforations Summary Interval TVD 6252 - 6296 3650 - 3691 Ref Log Date: TD: 6884 ftKB Max Hole Angle: 70 deg @ 2054 Size Top Bottom TVD Wt Grade Thread 16.000 0 121 121 62.58 H-40 WELD 5.500 0 6164 3571 15.50 L-80 BTC-MOD 3.500 6164 6884 6884 9.30 L-80 EUE8RD Bottom TVD Wt Grade Thread 6155 3563 9.30 L-80 EUE8RD Zone WSD Status Ft SPF Date Type Comment 44 4 11/2/2001 IPERF 2.5" HSD, BH Chgs, 60 deg phasing 38 4 11/2/2001 IPERF 2.5" HSD, BH Chgs, 60 deg phasing 26 4 11/2/2001 IPERF 2.5" HSD, BH Chgs, 60 deg phasing 12 4 11/2/2001 IPERF 2.5" HSD, BH Chgs, 60 deg phasing 28 4 11/2/2001 IPERF 2.5" HSD, BH Chgs, 60 deg phasing 30 4 11/4/2001 ¡PERF 2.5" HSD, BH Chgs, 60 deg phasing SBE 6322 - 6360 3715 - 3750 WS C,WS (6153-6154, 00:5.000) B 6370 - 6396 3759 - 3784 WSA4 NIP 6418 - 6430 3804 - 3815 WSA3 (6154-6155, 00:4.500) 6438 - 6466 3823 - 3849 WSA3 SEAL (6155-6167, 00:4.000) 6506 - 6536 3886 - 3913 WSA2 PROD LINER (6164-6884, 00:3.500, Wt:9.30) Perf (6252-6296) Perf (6322-6360) PLUG (6362-6363, 00:3.500) Perf (6370-6396) Perf (6418-6430) Perf (6438-6466) Perf (6506-6536) SHOE (6864-6865, 00:3.500) Gas Lift MandrelsNalves St MD TVD Man Man Type V Mfr V Type V OD Latch Port TRO Date ~ Roo 1 6072 3489 CAMCO KBG-2-9 CAMCO DMY 1.0 INT 0.000 0 6/14/2001 Other (plugs, equip.. etc.) - JEWELRY Depth TVD Type 6115 3527 NIP 6153 3561 SBE 6154 3562 NIP 6155 3563 SEAL 6167 3573 SEAL TAIL 6362 3752 PLUG WIRELlNE RETRIEVABLE PLUG SET @ 6362' ELM 8n/2002 6864 6864 SHOE General Notes Date Note 11/4/2001 LOST 2.5" X 1/4" ROLLER WHEEL FROM ROLLER STEM; MAY BE AT BOTTOM OF HOLE OR MAY BE IN GLM @ 6072' Vlv Cmnt Description CAMCO 'DS' NIPPLE WINO GO PROFILE BAKER SBE CAMCO NO GO SUB BAKER SEAL ASSEMBLY 8040 GBH-22 ID 2.812 4.000 3.000 3.000 3.000 0.000 3.000 **** REEL HEADER **** LDWG 02/11/05 AWS 01 **** TAPE HEADER **** LDWG 02/11/05 01 *** LIS COMMENT RECORD *** ( ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! LDWG File Version 1.000 Extract File: LISTAPE.HED ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! TAPE HEADER WEST SAK UNIT MWD /MAD LOGS # WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: # JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: # SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION(FT FROM KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: # WELL CASING RECORD 1ST STRING 2ND STRING MWD RUN 1 1 M. BELAVADI G. RIZEK MWD RUN 4 2RR R. MADARAPU G. RIZEK MSL 0) 1C-121 500292301500 Phillips Alaska, Inc. BAKER HUGHES INTEQ 05-Nov-02 MWD RUN 2 1RR R. RODRIGUEZ G. RIZEK MWD RUN 5 12 11N 10E 102.00 MWD RUN 2 S. FRANK G. RIZEK MWD RUN OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) :;,~ () 1- () '6(:i , I (~"S -7 3 6 ( # REMARKS: 3RD STRING PRODUCTION STRING 161. 0 6876.0 Tape Subfile: 1 24.000 7.875 16.000 PER PHILLIPS ALASKA STANDING ORDER FOR WEST SAK, THE GAMMA RAY CURVE FROM THIS LOG IS THE DEPTH REFERENCE FOR THIS WELL. AS SUCH, NO DEPTH SHIFTS HAVE BEEN APPLIED. INDIVIDUAL MWD RUN DATA WAS MERGED IN THE FIELD PRIOR TO DELIVERY FROM WELL SITE. SURFACE LOCATION: LAT: N70 DEG 19' 29.550" LONG: W149 DEG 29' 54.321" LOG MEASURED FROM D.F. AT 102.0 FT. ABOVE PERM. DATUM (M. S .L.) . BAKER HUGHES INTEQ RUNS 1 THROUGH 4 UTILIZED MULTIPLE PROPAGATION RESISTIVITY (MPR) SERVICE IN A STEERABLE ASSEMBLY FROM 161 - 6876' MD (161 - 4228' TVD). PER PAl GEOSCIENCE REQUEST, THE CURVE "RS60", A 60" FIXED DEPTH OF INVESTIGATION RESISTIVITY RESULT FROM INTEQ'S POST PROCESSING ROUTINE (MPRTEQ), IS INCLUDED IN THIS LDWG OUTPUT. MPRTEQ PROCESSING WAS REQUESTED OVER AND IS ONLY PRESENTED FOR THE INTERVAL 5550 - 6750 MD. 1) 16" CASING DEPTH - LOGGER: 161' MD (161' TVD) 16" CASING DEPTH - DRILLER: 161' MD (161' TVD). RESISTIVITY DATA RECORDED OVER THE INTERVAL 161 - 2430' MD (161 - 1800' TVD) IS ERRATIC DUE TO THE PRESENCE OF PERMAFROST. 2) THE INTERVAL FROM 860 TO 908 FEET MD (854-900' TVD) WAS LOGGED UP TO 5.8 HOURS AFTER BEING DRILLED DUE TO A TRIP OUT OF THE HOLE TO ADJUST THE BEND IN THE MUD MOTOR. 3) THE INTERVAL FROM 3966 TO 4014 FEET MD (2365 - 2382' TVD) WAS LOGGED UP TO 14.6 HOURS AFTER BEING DRILLED DUE TO A TRIP OUT OF THE HOLE TO CHANGE THE BIT. 4) THE INTERVAL FROM 4442 TO 4490 FEET MD (2553 - 2572' TVD) WAS LOGGED UP TO 12.1 HOURS AFTER BEING DRILLED DUE TO A TRIP OUT OF THE HOLE TO CHANGE A PARTIALLY PLUGGED MWD PULSER. 5) THE INTERVAL FROM 6834 - 6876' MD (4190 - 4228' TVD) WAS NOT LOGGED DUE TO SENSOR-BIT OFFSET AT TD. $ 84 records... Minimum record length: Maximum record length: 8 bytes 132 bytes LDWG .001 **** FILE HEADER **** 1024 *** LIS COMMENT RECORD *** ! ! ! ! ! ! ! ! ! ! ! ! ! !! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! FILE HEADER FILE NUMBER: EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. LDWG File Version 1.000 Extract File: FILE001.HED 1 ( ( DEPTH INCREMENT: # FILE SUMMARY PBU TOOL CODE MWD $ .5000 START DEPTH 161.0 STOP DEPTH 6834.0 # BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH $ # MERGED PBU MWD MWD MWD MWD $ DATA SOURCE TOOL CODE BIT RUN NO 1 1R 2 2R MERGE TOP 161.0 859.0 3966.0 4442.0 MERGE BASE 859.0 3966.0 4442.0 6834.0 # REMARKS: MERGED PASS. PER PHILLIPS ALASKA STANDING ORDER FOR WEST SAK, THE GAMMA RAY CURVE FROM THIS LOG IS THE DEPTH REFERENCE FOR THIS WELL. AS SUCH, NO DEPTH SHIFTS HAVE BEEN APPLIED. THE CURVE "RS60" IS THE 60" FIXED DEPTH OF INVESTIGA- TION RESISTIVITY RESULT FROM INTEQ'S MPRTEQ POST PROCESSING ROUTINE. IT IS PRESENTED OVER THE INTERVAL FROM 5550 - 6750' MD ONLY. $ # *** INFORMATION TABLE: CONS MNEM VALU ------------------------------ WDFN LCC CN 1iilN FN COUN STAT 1c121 5.xtf 150 Phillips Alaska, Inc. 1C-121 West Sak North Slope Alaska *** INFORMATION TABLE: CIFO MNEM CHAN DIMT CNAM ODEP ---------------------------------------------------- GR GR GRAM RAD RAD RAD RPD RPD RPD RPS RPS RPS RPX RPX RPX RS60 RS60 RES60 ROP ROP ROPS FET FET RPTH MTEM MTEM TCDM * FORMAT RECORD (TYPE# 64) 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 Data record type is: 0 Datum Frame Size is: 40 bytes Logging direction is down (value= 255) Optical Log Depth Scale Units: Feet ~, ( Frame spacing: 0.500000 Frame spacing units: [F ] Number of frames per record is: One depth per frame (value= 0) Datum Specification Block Sub-type is: 25 1 FRAME SPACE = 0.500 * F ONE DEPTH PER FRAME Tape depth ID: F 9 Curves: Name Tool Code Samples Units Size Length 1 GR MWD 68 1 GAP I 4 4 2 RAD MWD 68 1 OHMM 4 4 3 RPD MWD 68 1 OHMM 4 4 4 RPS MWD 68 1 OHMM 4 4 5 RPX MWD 68 1 OHMM 4 4 6 RS60 TEQ 68 1 OHMM 4 4 7 ROP MWD 68 1 FPHR 4 4 8 FET MWD 68 1 HR 4 4 9 MTEM MWD 68 1 DEGF 4 4 ------- 36 Total Data Records: 538 Tape File Start Depth Tape File End Depth Tape File Level Spacing = Tape File Depth units = feet 161.000000 6876.000000 0.500000 **** FILE TRAILER **** Tape Subfile: 2 590 records... Minimum record length: Maximum record length: 8 bytes 4124 bytes **** FILE HEADER **** LDWG .002 1024 *** LIS COMMENT RECORD *** ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! FILE HEADER FILE NUMBER: RAW MWD Curves and BIT RUN NO: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE LDWG File Version 1.000 Extract File: FILEOll.HED 2 log header data for each bit run in separate files. 1 .2500 START DEPTH STOP DEPTH ( MWD $ 150.0 859.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG) MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE DIR MPR GRAM $ BOTTOM) TOOL TYPE DIRECTIONAL COLLAR MULT. PROP. RESIST. GAMMA RAY # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TEMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # ( 05-JUN-01 MSB 18655 4.75 MPR MEMORY 908.0 150.0 859.0 0 .0 15.4 TOOL NUMBER 304858 MPR 1032 5195 7.875 161. 0 FW SPUD 9.45 .0 .0 200 .0 1.270 .000 .000 .000 62.0 64.0 .0 .0 .00 .000 .0 0 BIT RUN 1 (MWD RUN 1) . GR/MPR. CURVE GLOSSARY: GRAM - GAMMA RAY APPARENT (MWD-API) RACL - DEEP ATTENUATION RESISTIVITY (OHMM) RPCL - DEEP PHASE RESISTIVITY (OHMM) RPCH - SHALLOW PHASE RESISTIVITY (OHMM) RPSH - EXTRA SHALLOW PHASE RESISTIVITY (OHMM) ROPS - RATE OF PENETRATION (FPHR) RPTH - FORMATION EXPOSURE TIME (MIN) TCDM - BOREHOLE TEMPERATURE (DEGF) $ REMARKS: # *** INFORMATION TABLE: CONS MNEM VALU ~" ------------------------------ WDFN LCC CN WN FN COUN STAT lc121.xtf 150 Phillips Alaska, Inc. lC-121 West Sak North Slope Alaska *** INFORMATION TABLE: CIFO MNEM CHAN DIMT CNAM ODEP ---------------------------------------------------- GRAM GRAM GRAM 0.0 RACL RACL RACLM 0.0 RPCL RPCL RPCLM 0.0 RPCH RPCH RPCHM 0.0 RPSH RPSH RPCSHM 0.0 ROPS ROPS ROPS 0.0 RPTH RPTH RPTHM 0.0 TCDM TCDM TCDM 0.0 * FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame Size is: 36 bytes Logging direction is down (value= 255) Optical Log Depth Scale Units: Feet Frame spacing: 0.250000 Frame spacing units: [F ] Number of frames per record is: One depth per frame (value= 0) Datum Specification Block Sub-type is: 28 1 FRAME SPACE = 0.250 * F ONE DEPTH PER FRAME Tape depth ID: F 8 Curves: Name Tool Code Samples Units Size Length 1 GRAM MWD 68 1 GAP I 4 4 2 RACL MWD 68 1 OHMM 4 4 3 RPCL MWD 68 1 OHMM 4 4 4 RPCH MWD 68 1 OHMM 4 4 5 RPSH MWD 68 1 OHMM 4 4 6 ROPS MWD 68 1 FPHR 4 4 7 RPTH MWD 68 1 MINS 4 4 8 TCDM MWD 68 1 DEGF 4 4 ------- 32 Total Data Records: 102 Tape File Start Depth Tape File End Depth Tape File Level Spacing = Tape File Depth Units = feet 150.000000 859.000000 0.250000 **** FILE TRAILER **** Tape Subfile: 3 188 records... Minimum record length: Maximum record length: 8 bytes 4124 bytes **** FILE HEADER **** LDWG .003 1024 *** LIS COMMENT RECORD *** ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! !!!!!!!!!!!!!!!!!!! FILE HEADER FILE NUMBER: RAW MWD Curves and BIT RUN NO: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE MWD $ LDWG File Version 1.000 Extract File: FILE012.HED 3 ~ log header data for each bit run in separate files. 1R .2500 START DEPTH 859.0 STOP DEPTH 3966.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG) MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE DIR MPR GRAM $ BOTTOM) TOOL TYPE DIRECTIONAL MULT. PROP. GAMMA RAY COLLAR RESIST. # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TEMPERATURE: MUD FILTRATE AT MT: 06-JUN-01 MSB 18655 4.75 MPR MEMORY 4014.0 859.0 3966.0 0 15.4 69.5 TOOL NUMBER 304858 MPR 1032 5195 7.875 161. 0 FW GEL 9.25 .0 .0 200 .0 1.340 .000 .000 61. 0 72.0 .0 MUD CAKE AT MT: .000 .0 # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): .00 .000 # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): .0 0 # REMARKS: BIT RUN 1RR (MWD RUN 2). GR/MPR. CURVE GLOSSARY: GRAM - GAMMA RAY APPARENT (MWD-API) RACL - DEEP ATTENUATION RESISTIVITY (OHMM) RPCL - DEEP PHASE RESISTIVITY (OHMM) RPCH - SHALLOW PHASE RESISTIVITY (OHMM) RPSH - EXTRA SHALLOW PHASE RESISTIVITY (OHMM) ROPS - RATE OF PENETRATION (FPHR) RPTH - FORMATION EXPOSURE TIME (MIN) TCDM - BOREHOLE TEMPERATURE (DEGF) $ # *** INFORMATION TABLE: CONS MNEM VALU ------------------------------ WDFN LCC CN WN FN COUN STAT 1c121. xtf 150 Phillips Alaska, Inc. 1C-121 West Sak North Slope Alaska *** INFORMATION TABLE: CIFO MNEM CHAN DIMT CNAM ODEP ---------------------------------------------------- GRAM GRAM GRAM 0.0 RACL RACL RACLM 0.0 RPCL RPCL RPCLM 0.0 RPCH RPCH RPCHM 0.0 RPSH RPSH RPCSHM 0.0 ROPS ROPS ROPS 0.0 RPTH RPTH RPTHM 0.0 TCDM TCDM TCDM 0.0 * FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame Size is: 36 bytes Logging direction is down (value= 255) Optical Log Depth Scale Units: Feet Frame spacing: 0.250000 Frame spacing units: [F ] Number of frames per record is: One depth per frame (value= 0) Datum Specification Block Sub-type is: 28 1 FRAME SPACE = 0.250 * F ONE DEPTH PER FRAME ;i!- Tape depth ID: F 8 Curves: Name Tool Code Samples Units Size Length 1 GRAM MWD 68 1 GAP I 4 4 2 RACL MWD 68 1 OHMM 4 4 3 RPCL MWD 68 1 OHMM 4 4 4 RPCH MWD 68 1 OHMM 4 4 5 RPSH MWD 68 1 OHMM 4 4 6 ROPS MWD 68 1 FPHR 4 4 7 RPTH MWD 68 1 MINS 4 4 8 TCDM MWD 68 1 DEGF 4 4 ------- 32 Total Data Records: 444 Tape File Start Depth Tape File End Depth Tape File Level Spacing = Tape File Depth Units = feet 859.000000 3966.000000 0.250000 **** FILE TRAILER **** Tape Subfile: 4 530 records... Minimum record length: Maximum record length: 8 bytes 4124 bytes **** FILE HEADER **** LDWG .004 1024 *** LIS COMMENT RECORD *** ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! FILE HEADER FILE NUMBER: RAW MWD Curves and BIT RUN NO: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE MWD $ LDWG File Version 1.000 Extract File: FILE013.HED 4 log header data for each bit run in separate files. 2 .2500 START DEPTH 3966.0 STOP DEPTH 4442.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): 07-JUN-Ol MSB 18655 4.75 MPR MEMORY 4490.0 3966.0 BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG) MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE DIR MPR GRAM $ BOTTOM) TOOL TYPE DIRECTIONAL COLLAR MULT. PROP. RESIST. GAMMA RAY # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TEMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # :~, 4442.0 0 65.9 68.7 TOOL NUMBER 304858 MPR 1032 5195 7.875 161.0 FW GEL 9.30 .0 .0 240 .0 .000 .000 .000 .000 .0 74.0 .0 .0 .00 .000 .0 0 BIT RUN 2 (MWD RUN 3) . GR/MPR. CURVE GLOSSARY: GRAM - GAMMA RAY APPARENT (MWD-API) RACL - DEEP ATTENUATION RESISTIVITY (OHMM) RPCL - DEEP PHASE RESISTIVITY (OHMM) RPCH - SHALLOW PHASE RESISTIVITY (OHMM) RPSH - EXTRA SHALLOW PHASE RESISTIVITY (OHMM) ROPS - RATE OF PENETRATION (FPHR) RPTH - FORMATION EXPOSURE TIME (MIN) TCDM - BOREHOLE TEMPERATURE (DEGF) $ REMARKS: # *** INFORMATION TABLE: CONS MNEM VALU ------------------------------ WDFN LCC CN WN FN COUN STAT 1c121.xtf 150 Phillips Alaska, Inc. 1C-121 West Sak North Slope Alaska ~, ~ *** INFORMATION TABLE: CIFO MNEM CHAN DIMT CNAM ODEP ---------------------------------------------------- GRAM GRAM GRAM 0.0 RACL RACL RACLM 0.0 RPCL RPCL RPCLM 0.0 RPCH RPCH RPCHM 0.0 RPSH RPSH RPCSHM 0.0 ROPS ROPS ROPS 0.0 RPTH RPTH RPTHM 0.0 TCDM TCDM TCDM 0.0 * FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame Size is: 36 bytes Logging direction is down (value= 255) Optical Log Depth Scale Units: Feet Frame spacing: 0.250000 Frame spacing units: [F ] Number of frames per record is: One depth per frame (value= 0) Datum Specification Block Sub-type is: 28 1 FRAME SPACE = 0.250 * F ONE DEPTH PER FRAME Tape depth ID: F 8 Curves: Name Tool Code Samples Units Size Length 1 GRAM MWD 68 1 GAP I 4 4 2 RACL MWD 68 1 OHMM 4 4 3 RPCL MWD 68 1 OHMM 4 4 4 RPCH MWD 68 1 OHMM 4 4 5 RPSH MWD 68 1 OHMM 4 4 6 ROPS MWD 68 1 FPHR 4 4 7 RPTH MWD 68 1 MINS 4 4 8 TCDM MWD 68 1 DEGF 4 4 ------- 32 Total Data Records: 69 Tape File Start Depth Tape File End Depth Tape File Level Spacing = Tape File Depth Units = feet 3966.000000 4442.000000 0.250000 **** FILE TRAILER **** Tape Subfile: 5 155 records... Minimum record length: Maximum record length: 8 bytes 4124 bytes **** FILE HEADER **** LDWG .005 1024 *** LIS COMMENT RECORD *** ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! !! ! ! ! ! ! ! ! ! FILE HEADER FILE NUMBER: RAW MWD Curves and BIT RUN NO: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE MWD $ LDWG File Version 1.000 Extract File: FILE014.HED 4 ( log header data for each bit run in separate files. 2R .2500 START DEPTH 4442.0 STOP DEPTH 6834.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG) MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE DIR MPR GRAM $ BOTTOM) TOOL TYPE DIRECTIONAL MULT. PROP. GAMMA RAY COLLAR RESIST. # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TEMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: BIT RUN 2RR (MWD RUN 4) . 09-JUN-Ol MSB 18655 4.75 MPR MEMORY 6876.0 4442.0 6834.0 0 21.8 66.8 TOOL NUMBER 304858 MPR 1032 5195 7.875 161.0 FW GEL 9.35 .0 .0 240 .0 .000 .000 .000 .000 .0 96.0 .0 .0 .00 .000 .0 0 ( GR/MPR. CURVE GLOSSARY: GRAM - GAMMA RAY APPARENT (MWÐ-API) RACL - DEEP ATTENUATION RESISTIVITY (OHMM) RPCL - DEEP PHASE RESISTIVITY (OHMM) RPCH - SHALLOW PHASE RESISTIVITY (OHMM) RPSH - EXTRA SHALLOW PHASE RESISTIVITY (OHMM) RS60 - MPRTEQ 60" FIXED DEPTH OF INVEST. RES IS. ROPS - RATE OF PENETRATION (FPHR) RPTH - FORMATION EXPOSURE TIME (MIN) TCDM - BOREHOLE TEMPERATURE (DEGF) $ (OHMM) # *** INFORMATION TABLE: CONS MNEM VALU ------------------------------ WDFN LCC CN WN FN COUN STAT lc121.xtf 150 Phillips Alaska, Inc. lC-121 West Sak North Slope Alaska *** INFORMATION TABLE: CIFO MNEM CHAN DIMT CNAM ODEP ---------------------------------------------------- GRAM GRAM GRAM 0.0 RACL RACL RACLM 0.0 RPCL RPCL RPCLM 0.0 RPCH RPCH RPCHM 0.0 RPSH RPSH RPCSHM 0.0 RS60 RS60 RES60 0.0 ROPS ROPS ROPS 0.0 RPTH RPTH RPTHM 0.0 TCDM TCDM TCDM 0.0 * FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame Size is: 40 bytes Logging direction is down (value= 255) Optical Log Depth Scale Units: Feet Frame spacing: 0.250000 Frame spacing units: [F ] Number of frames per record is: One depth per frame (value= 0) Datum Specification Block Sub-type is: 25 1 FRAME SPACE = 0.250 * F ONE DEPTH PER FRAME Tape depth ID: F 9 Curves: Name Tool Code Samples Units Size Length 1 GRAM MWD 68 1 GAP I 4 4 2 RACL MWD 68 1 OHMM 4 4 3 RPCL MWD 68 1 OHMM 4 4 { 4 RPCH MWD 68 1 OHMM 4 4 5 RPSH MWD 68 1 OHMM 4 4 6 RS60 TEQ 68 1 OHMM 4 4 7 ROPS MWD 68 1 FPHR 4 4 8 RPTH MWD 68 1 MINS 4 4 9 TCDM MWD 68 1 DEGF 4 4 ------- 36 Total Data Records: 390 Tape File Start Depth Tape File End Depth Tape File Level Spacing = Tape File Depth Units = feet 4442.000000 6876.000000 0.250000 **** FILE TRAILER **** Tape Subfile: 6 478 records... Minimum record length: Maximum record length: 8 bytes 4124 bytes **** TAPE TRAILER **** LDWG 02/11/05 01 **** REEL TRAILER **** LDWG 02/11/05 AWS 01 Tape Subfile: 7 2 records... Minimum record length: Maximum record length: 132 bytes 132 bytes