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Home My WebLink About201-121MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Monday, June 13, 2022 SUBJECT:Mechanical Integrity Tests TO: FROM:Austin McLeod P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL ConocoPhillips Alaska, Inc. 1C-117 KUPARUK RIV U WSAK 1C-117 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 06/13/2022 1C-117 50-029-23027-00-00 201-121-0 W SPT 3686 2011210 1500 1138 1139 1138 1137 4YRTST P Austin McLeod 5/15/2022 Monobore. MITIA 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-117 Inspection Date: Tubing OA Packer Depth 190 1920 1800 1770IA 45 Min 60 Min Rel Insp Num: Insp Num:mitSAM220515191255 BBL Pumped:1.7 BBL Returned:1.7 Monday, June 13, 2022 Page 1 of 1 9 9 9 9 9 99 9 9 9 James B. Regg Digitally signed by James B. Regg Date: 2022.06.14 09:42:49 -08'00' Originated: Schlumberger PTS - PRINTCENTER 6411 A Street Anchorage, AK 99518 (907)273-1700 main (907)273-4760fax Delivered to: + AOGCC ATTN: Natural Resources Technician II Alaska Oil & Gas Conservation Commision 333 W. 7th Ave, Suite 100 --oh Anchorage, A K 99501 303 1 TRANSMITTAL DATE 9 TRANSMITTALk 0r` ' ' 1B-102 50-029-23167-00 ORDER EOSH-00015 r r KUPARUK RIVER • WL r r • Caliper Vert r. FINAL FIELD D • D 1 -Jan -19 r 1 1J-10 1H-719 3H -31A 50-029-23010-00 50-029-23591-00 50-103.20205-01 EOSH-00017 EOSH-00018 EOSH-00019 KUPARUK RIVER KUPARUK RIVER KUPARUK RIVER WL WL WL Caliper [PROF LDL FINAL FIELD FINAL FIELD FINAL FIELD 17Jan-19 16 -Jan -19 19-19 1 1 1 3M-19 1H-116 1C-117 50-029-21737-00 50-029-23594-00 50-029-23027.00 EOSH-00020 EOSH-00021 EOSH-00022 KUPARUK RIVER KUPARUK RIVER KUPARUK RIVER WL WL WL LDL (PROF RST-WFL FINAL FIELD FINAL FIELD FINAL FIELD 20Jan-19 21 -Jan -19 22 -Jan -19 1 1 1 IAN 3 0 9019 AQG- 7 f A Transmittal Receipt signature confirms that a package (box, OI'2,�/ envelope, etc.) has been received and the contents of the X (�f package have been verified to match the media noted above. The P nt Signature Date specific content of the CDs and/or hardcopy prints may or may not have been verified for correctness or quality level at this Please retur via courier or sign/scan and email a copy t Sc lumberger and CPAI. point. Schlumberger -Private • MEMORANDA State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg I DATE: Wednesday,May 16,2018 P.I.Supervisor l� q 174 (16 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA,INC. 1C-117 FROM: Austin McLeod KUPARUK RIV U WSAK 1C-117 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry NON-CONFIDENTIAL Comm Well Name KUPARUK RIV U WSAK 1C-117 API Well Number 50-029-23027-00-00 Inspector Name: Austin McLeod Permit Number: 201-121-0 Inspection Date: 5/12/2018 Insp Num: mitSAM180513194958 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 1C 117 ;'Type Inj W -TVD 3686 - Tubing 926 ' 927 927 " 927 PTD 2011210 ;Type Test SPT 'Test psi 1500 IA 0 1800 1670 1650 BBL Pumped 3.2 BBL Returned: 1.7 OA Interval 4YRTST P/F P ✓ Notes: MIT-IA.Surface casing-8.625"x7.625"at 142'-no OA. SCANNED JUN 0 12013 Wednesday,May 16,2018 Page 1 of 1 ( Image Project Well History File Cover Page XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. dOL - 1 ~ 1 Well History File Identifier Organizing (done) 0 Two-sided 1111111111111111111 ~can Needed 1111111111111111111 R:?CAN u6' Color Items: ,~ Greyscale Items: 0 Poor Quality Originals: DIGITAL DATA OVERSIZED (Scannable) D Maps: D Diskettes, No. D Other, NolType: D Other Items Scannable by a Large Scanner OVERSIZED (Non-Scannable) D Other: 0 Logs of various kinds: NOTES: BY: Helen ~ l....!v!~ma.... J 0 Other:: ¡ , Date: Jb ¡ 01' Scanning Preparation ¡;L x 30 = too /5/ V11P 1111111111111111111 /5/ v11 P + '1 = TOTAL PAGES 7 Z' (COunt/does noÛinclude cover she t) ~A A-Ý) Date: . Ó I 64' /s/ vytr , I 1111111111111111111 Date: to ( , ütf Project Proofing BY: Helen Maria BY: Helen Maria Production Scanning Stage 1 Page Count from Scanned File: 7 ß (Count does include cover sheet) Page Count Matches Number in Scanning Preparation: V YES ¡ Helen@ Date: 101 , D'f If NO in stage 1 page(s) discrepancies were found: YES NO BY: NO /5/ m r Stage 1 BY: Helen Maria Date: /5/ Scanning is complete at this point unless rescanning is required. 1111111111111111111 ReScanned 1111111111111111111 BY: Helen Maria Date: /5/ Comments about this file: Quality Checked 1111111111111111111 8/24/2004 Well History File Cover Page.doc ~~ MEMORANDUM To: JimRegg ~~~`~ ~~Z~11~ 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-117 KUPARUK RIV U WSAK IC-117 Src: Inspector NON-CONFIDENTIAL • Reviewed By: P.L 5uprv ~J~' - Comm Well Name: KUPARUK RIV U WSAK 1C-117 API Well Number: 50-029-23027-00-00 Inspector Name: John Crisp Insp Num: mitJCr100523171612 Permit Number: 201-121-0 Inspection Date: 5/21/2010 Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well 1C-1~Type Inj. W TVD 3686 Ip to ~ zzoo / 2000 ~ 2000 ~ zooo '~ P.T.D, 2011210 TypeTest SPT Test psi 1500 ~ QA ~ ~ ~ _ ~ ~ Interval avRTST p~F P ~ Tubing llso ]]so usb Ils6 lls6 Notes: 4.8 bbls pumped for test. Monobore injector. No problems witnessed. Tuesday, May 25, 2010 Page 1 of 1 • STATE OF ALASKA • ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS ~~~~~~ ,.~, o rw„~ f nnc_ ~0(I1Cf11SStt1n 1. Operations Performed: Abandon ^ Repair Well ^ Plug Perforations ^ Stimulate ^ Other QIl&a~~ Alter Casing ^ Pull Tubing ^ Perforate New Pool ^ Waiver ^ Time Extension ^ Change Approved Program ^ Operat. Shutdown^ Perforate Q Re-enter Suspended Well ^ 2. Operator Name: 4. Well Class Before Work: 5. Permit to Dri11 Number: ConoCOPhillipS Alaska, InC. Development ^ Exploratory ^ 201-121 / r 3. Address: Stratigraphic ^ Service Q 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-029-23027-00 7. KB Elevation (ft): 9. Well Name and Number: RKB 40.3' 1C-117 8. Property Designation: 10. Field/Pool(s): ADL 25649 ~ ukRiGe ~/West Sak Oil Pool 11. Present Well Condition Summary: Total Depth measured 5000' feet true vertical 4215' feet Plugs (measured) Effective Depth measured 4888' feet Junk (measured) true vertical 4104' feet Casing Length Size MD TVD Burst Collapse Structural CONDUCTOR 158' 16" 158' 158' SURFACE 32' 8-5/8" x 134' 134' SURFACE 4853' 7-5/8" 4987' 4210' ('~ ~~ ' ' ' ' ' ' ` Perforation depth: Measured depth: -4710', 4718 , 4730 -4750 4508'-4546', 4572 -4592', 4620'-4640', 4656'-4672', 4678 -4750 ~ ~ true vertical depth: 3732'-3768', 3794'-3813', 3841'-3860', 3876'-3892', 3898'-3929', 3937-3968', 3949'-3968' Tubing (size, grade, and measured depth) 3-1/2" , L-80, 4602' MD. Packers & SSSV (type 8~ measured depth) Baker Premier pkr @ 4460', Baker S-3 pkr @ 4550', Baker FB1 retainer prod pkr @ 4604' Camco DS landing nipple @ 515' 12. Stimulation or cement squeeze summary: Intervals treated (measured) not applicable Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casin Pressure Tubin Pressure Prior to well operation na SI -- Subsequent to operation na 213 -- 14. Attachments 15. Well Class after work: Copies of Logs and Surveys run _ Exploratory ^ Development ^ Service 0 Daily Report of Well Operations _X 16. Well Status after work: Oil^ Gas ^ WAG ^ GINJ ^ WINJ ~ WDSPL ^ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or Nia if C.O. Exempt: none contact John Peirce @ 26 5-6471 Printed Name John Peirce Title Wells Engineer Signature /, q ;!~ Phone: 265-6471 Date ~"25~0~ /Nt N/ Pre aced b Sharon All -rake 263-4612 Form 10-404 Revised 04/2006 , - i ~> ,~ ;°i~ ~ ~ " ~ ~ ~ L~QQ ~~ S y C.Pc-~..C ;:4 ~' Subs mit Oygina~l O`ly~p ~'~ '~G/ ~/ °'r' ConocoPhillips Ahisk:'I 4rx;. TD. 5,000 KUP • 1 C-117 s Max Angle 8 MD e ttn ute Wellbore APVUWI (Field Name Well Status ~Prod/lnj Type Incl (°) MD (ftKB) ~TD ,,Act Bhn (ftKB) - ~'.WESI SAK INJ ~PWI 48.96 ~ 2,697 soozs2so2/oo I 5.000 Comment NYS (ppm) Data Annotation End Date KB-Grd (tt) Rig Release Date SSSV: NIPPLE i 0 I 7/1/2008 (Last WO: I I 45.70 I 7/5/2001 'Annotation (Depth (ftKB) (End Data Annotation End Date last lag: SLM ''i 4,851 11/24/2009 Rev Reason: PERFS I 2/26/2009 ICasing Strin s Stritg OD String ID Set Depth Set Depth (ND) String Wt String Casing D escription (inl (in) Top (ftKB) (ftK8) (ftKB) (Ibs/R) Grad e String Top Thrd ICONDUC TOR '~ 16 15.062 ~ 0 158 158.0 62.50 H-00 WELDED .SURFACE - 86/8 7.825 0 134 134.Oi 36.00 N-80 511 Hydril iSURFACE i 7518 6.875 134 4,987 4,201.9', 29.70 L-80 IBTC-MOD (Tubing Strings String ID Sat Depth Set Depth (ND) ~. String WI String 'String OD i ~ Tubing Description t (in) (in) Top (ftKB) (ftKB) (ftKB) (Ibs/ft) Grade String Top Thrtl ~~TUBING I 31/2 ~ 2.992 0 4602 3,8231 9.30~L-80 IEueBrdMad I Other I n Hole ( Fish, etc.) All Jewelry: Tubing Run & Retrievable Top Depth 1 , _ ~ (TVD) i Top Incl TOp (ftKB) (ftKB) (°) Description Comment ~ Run Date ~ID (in) 515 515.0 CAMCO US LANDING NIPPLE 0.65 Satery Valve 8/1/2002 ~ 2.875 4,407 3,634.8 18.27 GAS LIFT (CAMCO/MMG/1.6/DMY/RK/. 188// Comment: STA 1 2/5/2003 i 2.920 4,460 3,6854 16.56 PACKER (BAKER PREMIER PACKER 8/1/2002 3.875 4.512 3,735.61 15.07 GAS LIFT CAMCO/MMG/t5/DMY/RK/// Comment: STA 2 8/1/2002 2.920 4,533 3,755.81 14.37jSLEEVE-C BAKER CMU SLIDING SLEEVE W/2812" DS PROFILE 8/1/2002 2.812 (CLOSED 11/7/2008) 4,550 3,772.21 13.80 PACKER BAKERS-3 PACKER 8/1/2002 3.875 4,569 3,790.7.1 13.17 GAS LIFT CAMCO/MMG/1.5/DMY/RKl// Comment: STA 3 2/812003 2.920 4,585 3,806.3 12.64 SLEEVE-C BAKER 2.75" D PROFILE CMU SLIDING SLEEVE 8/1/2002 i 2.750 (CLOSED 11(7/2008) ~ 4,601 3,822.0 LOCATOR BAKER 80-00 NO GO LOCATOR 12. t0 8/1/2002 3.000 4,602 3,823.0 12.07 SEAL BAKER 80-00 SEAL ASSEMBLY with 12" MULE SHOE 8/1/2002 3.980 4,604 3,824.9 12.00 PACKER BAKER F81 RETAINER PRODUCTION PACKER 8172002 4.000 4,607 3,827.9 11.90 EXTENSION BAKER MILLOUT EXTENSION 8/1/2002 4.500 4,612 3,832.5( 11.74 XO - 8/1/2002 i 2390 4,617 3,837.7 iL57~NIPPLE CAMCODNIPPLE 8/1/2002 I~ 2.250 4,618 'Perfora 3 838.6 tions & 11.54' WLEG BAKER WIRELINE ENTRY GUIDE _-____ Slots 8/1/2002 1 2.380 111.._- - _- -- Shot Top (ND) Btm (ND) 'Dens Top (ftKB) Btm (flKe) (ftK8) (ftK8) Zone Data (sh-. Typa_. ____ _ _ _ Commend 4,508 4,546 3,731.8 3,768.4 W S D, WSC, 8!1/2002 4.0 IPERF 3 3/8" HSD i C-117 4,572 4,592 3,793.6 3,813.2 WS B, 1C-117 8/1/2002 4.0 IPERF 3 3/8" HSD 4,620 4,640 3,840.6 3,860.2 WS A4, 1C-117 7/31/2002 4.0 IPERF 3 3/8" HSD 4,656 4,672 3,875.9 3 891.6 WS A3, 1C-117 7/31/2002 4.0 IPERF 3 318" HSD 4,678 4,708 1 3,837.5 3,927.0 WSA3, 1C-117 J/312002 4.0 IPERF 33/8"HSD 4,690 4,710 3,909.3 3,929.0 WSA2, 1C-117 1225/2009 40RPERF 22/8"EnerJet,O deg phase 4,718 4,750 3,936.9 3968.4 WS A2, 1C-117 71312002 4.0 IPERF 3 3/8" HSD 4,730 4,750 3,948.7 3,968.4WS A2, iC-117 12/25/2009 4.0 APERF 22/8"EnerJet,Odeg phase 1C-117 Well Work Summary DATE SUMMARY 2/25/09 PERFORATED FROM 4690'-4~AND FROM 4730'-4750' WITH 2 1/8" P~R ENERJET 4 SPF 0 DEGREE PHASING GUNS. N0.4914 ~ ~',, __, ; Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Well Job # Log Description Company: Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Kuparuk Date BL Color CD 10/14/08 iL-23 - 12097405 SBHP SURVEY / 07/17/08 1 1 2A-17 11975793 PRODUCTION PROFILE 9 .- JC. p L 09/10/08 1 1 3G-25X 12080437 LDL ~ - ~j L((o 09/21/08 1 1 2C-04 12100444 INJECTION PROFILE C C ( 09/14/08 1 1 3M-13 12096541 LDL - (~L( ( (~C..( 09/10/08 1 1 2Z-13A 12100446 LDL Q(o- ~ ~} O ~U 09/15/08 1 1 1 F-06 12096510 PRODUCTION PROFILE 07/17/08 1 1 3C-14A 12080436 SCMT - S-'oL 09/22/08 1 1 iC-111 12100451 INJECTION PROFILE -t 09/20/08 1 1 30-15 12100452 LDL ~j(- ~ 5Q 09/21/08 1 1 1C-117 12100453 INJECTION PROFILE o ~ 09/23/08 1 1 iR-11 11966277 SBHP SURVEY 5 - (~ 09/25/08 1 1 1 R-35 11966279 SBHP SURVEY p 09/25/08 1 1 1 R-14 11966286 LDL ( 09/29/08 1 1 2X-18 12080443 PRODUCTION PROFILE _ 09/30/08 1 1 1R-34 12080444 GLS gC - 10/01/08 1 1 2A-13 12096547 PRODUCTION PRO ILE .: L ~~~/ 10/02/08 1 1 1 D-01 12097422 GLS 10/03/08 1 1 1 R-07 12097425 PRODUCTION PROFILE ter: '~-- ( 10/06/08 1 1 iH-19 12096548 INJECTION PROFILE LJ 10/03/08 1 1 1 B-16 12097426 GLS C~ _ =' 10/07/08 1 1 3B-09 12100442 PRODUCTION PROFILE 09/12/08 1 1 3K-103 12096550 USIT 10/06/08 1 1 2X-05 12096551 INJECTION PROFILE - ~~ 10/07/08 1 1 1 B-04 12096552 INJECTION PROFILE -- ~ 10/08/08 1 1 1A-02 12096553 INJECTION PROFILE ~ 10/09/08 1 1 i B-16 12096554 PRODUCTION PROFILE q C- 10/10/08 1 1 2D-15 12096555 PRODUCTION PROFILE ,~$C , 10/11/08 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. • • . . ConocÓPhillips Afaska RECEIVED AUG .2 9 2007 A'aska Oi' & Gas Cons. Commission Anchorage P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 August 23, 2007 Mr. Tom Maunder Alaska Oil & Gas Commission SCANNEt) SEP 0 6 2007 333 West 7th Avenue, Suite 100 Anchorage, AK. 99501 ,~\ dj)\- \ Dear Mr. Maunder: Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRU). Each of thesè wens was fõund to have a void in the conductor. These voids were filled with a cOITÒsion inhibitor, engineered to prevent water from entering the annular space. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treatments took place and meets the requirements of form 10-404, Report of Sundry Operations. The corrosion inhibitor/sealant was pumped between August 19 & 21, 2007. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please call me at 907-659-7043, if you have any questions. ~~~~ M.J.¿el~d ConocoPhiIlips Well Integrity Projects Supervisor . . ConocoPhillips Alaska Inc. Suñace Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) Kuparuk Field Date 8/21/2007 Corrosion Initial top of Vol. of cement Final top of Cement top off Corrosion inhibitor/ Well Name PTO# cement pumped cement date inhibitor sealant date .- ft bbls ft Qal 1 0-28 204-237 18" N/A N/A N/A 10 8/19/2007 1 0-30 200-104 24" N/A N/A N/A 6.5 8/19/2007 1 0-34 200-143 14" N/A N/A N/A 4 8/19/2007 10-12 199-084 1" N/A N/A N/A 1.7 8/20/2007 10~14 199-089 2" N/A N/A N/A 3.4 8/20/2007 10-140 200-136 29'9" 3.4 12" 12/16/2006 14.5 8/20/2007 10-141 200-112 SF N/A N/A N/A 0.5 8/20/2007 . 1C-11 199-172 - SF NA NA NA 0.5 8/21/2007 1C-12 196-177 SF NA NA NA 0.5 8/21/2007 1C-15 198-229 SF NA NA NA 0.5 8/21/2007 1C·16 198-246 22" NA NA NA 8 8/21/2007 1C-17 198-224 17" NA NA NA 1.7 8/21/2007 1C-18 199-005 SF NA NA NA 0.5 8/21/20Q7 1c.24 201-248 20" NA NA NA 11 8/21/2007 1 C-26 199-051 3" NA NA NA 0.85 8/21/2007 1 C-27 199-043 4" NA NA NA 1.7 8/21/2007 1 C-28 205-104 SF NA NA NA 0.5 8/21/2007 1C-117 201-121 26" NA NA NA 12.3 8/21/2007 01/24107 Scblumbel'gep SCANNED JAN 3 0 2007 NO. 4121 Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 A TTN: Beth ~I!\~\ 2. 9 Z007 Company: Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 it, u . \ c.- gO I - I d / Field: Kuparuk Well Job # Date BL Color CD Log Description 1 C-111 11415647 RST WFL 10/29/06 1 2B-01 11536780 PROD PROFILE 01/04/07 1 2H-11 11539477 PROD PROFILE 01/04/07 1 2B-02 11538781 PROD PROFILE 01/05/07 1 3N-19 11538782 PROD PROFILE 01/06/07 1 2W-06 11538784 PROD PROFILE 01/08/07 1 1C-28 L 1 N/A GLS 01/16/07 1 2M-06 11628958 INJECTION PROFILE 01/20/07 1 1C-117 11628954 INJECTION PROFILE 01/18/07 1 2K-16 11638814 PRODUCTION PROFILE 01/22/07 1 1Y-22 11638815 PRODUCTION PROFILE 01/23/07 1 2N-337 A N/A SBHP SURVEY 01/21/07 1 2M-26 N/A SBHP SURVEY 01/21/07 1 2M-03 N/A INJECTION PROFILE 01/22/07 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'\ . . . . WELL LOG TRANSMITTAL ProActive Diagnostic Services, Inc. To: AOGCC Howard Okland 333 West 7th Avenue Suite 1 00 Anchorage. Alaska 99501 (907) 659-5102 .~ .;~. .. r",\1i<cUÞ:;;O-\ ,..,,1': ')~.~1!"~j!¡;¡.,r;)1 l::;;?\õi;ó:7il ....... ""r f\ ':-0 RE : Cased Hole/Open Hole/Mechanical Logs and / or Tubing Inspection(Ca/iper / MIT) The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention of : ProActive Diagnostic Services. Inc. Attn: Robert A. Richey 130 West International Airport Road Suite C Anchorage. AI< 99518 Fax: (907) 245-8952 r~ 15 u ~JHg~ CO(i§. 1) 1 Report 2) 1 Report 3) 1 Report 4] 1 Report 5J 1 Report 6J 1 Report 7J Signed: Print Name: 1C - 111 MTT Log 1C - 117 MTT Log 1 C - 127 MTT Log 1 C - 133 MTT Log 10-114 MTT Log 10-117 MTT Log 10- Dec ~6 U"I Q.. êìot - Ie;)'&- 11-Dec~6 UTC-dOI-ISI 11- Dec ~6 u ..ie-dO 1- (I(I 12- Oec 06 U r c- 86l - 6--=ì-? 08- Dec ~6 u:fC.r lq~ - t5'ì 09- Dee ~6 LJ:.re.. \ q 1 -éJ31- ê.j~ th r:-Øi /ltO~ /YI(), h VI Ý-.P1/1 Date: J[} / 12(1()~ ~ " PRoACTIVE DIAGNOSTIC SERVICES, INC., 130 w. INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245-8951 FAX: (907)245-8952 E..MAIL: ?_-:,3_~\:"¡G;""iG?,--~;;;,,;:,;ê)~/iE~\jO~'fL-::,3~GC'NJ WEBSITE : 'Ni,'N.:,1:::,·;<:;2Y'-Y2.G.o:n 0:\00_ PDSA"IC-2006\Z _ W ordlDistríbutionlTraIJsIlÚttaJ _Sheets \ TraJ15IlÚt_ Onginal.doc I I I I I I I I I I I I I I I I I I I . . Memory Magnetic Thickness Tool Log Results Summary Company: ConocoPhillips Alaska, Inc. Well: 1C-117 Log Date: December 11, 2006 Field: Kuparuk Log No. : 8080 State: Alaska Run No.: 1 API No.: 50-029-23027-00 Pipe1 Desc.: 3.5" 9.3 Ib EUE 8rd Top Log Intv!.: Surface Pipe1 Use: Tubing Bot Log Intv!.: 191 Ft (MD) Pipe2 Desc.: 7.625" 29.7 Ib Top Log Intvl.: 134 Ft (MD) Pipe2 Use: Production Casing Bot Log Intvl.: 191 Ft (MD) Pipe3 Desc.: 8.625" 36 Ib Top Log Intv!.: Surface Pipe3 Use: Production Casing Bot Log Intvl.: 134 Ft (MD) Pipe4 Desc.: 16" 62.5 lb. Top Log Intvl.: Surface Pipe4 Use: Conductor Pipe Bot Log Intvl.: 158 Ft (MD) Inspection Type: Assess External Co"osive Damage (Metal Loss) to Production Casing. COMMENTS: This MTT data is tied into the Mandrel 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 metal thickness of the 3.5" tubing, 7.625" and 8.625" production casings, 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 (60'), 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, 8.625" casing, and 16" conductor pipe. The MTT recordings indicate less metal volume over the interval of 8.625" casing relative to the interval of 7.625" casing. The tool appears to have recorded an inverted response (indicating less metal) at the cross- over between the 8.625" and 7.625" casing at 97', which has been noted when the volume of metal surrounding the tool exceeds the tool's capacity. We believe this to be the case at this point, where the extra metal in the cross-over is exceeding the tool's capabilities and causing an inversion in the tool's normal response. Above this cross-over and throughout the interval of 8.625" casing, the tool continues to indicate less metal relative to the interval of 7.625" casing, but there are no obvious signal inversions at tubing collars throughout this interval. This points to the possibility that the extra distance from the tool sensors (of the 8.625" casing relative to the 7.625" casing) may be overriding the effects of the additional 6 Ibltt of pipe weight - resulting in an indication of less metal volume. The tool's response over the interval of the top 3.5" tubing joint generally indicates more metal than that in the pup joints and second full joint of 3.5" tubing. There are no noted casing changes within this interval, pointing to the possibility that the top joint of 3.5" tubing may have different metallurgic properties than the tubing joints below it There is no apparent metal loss recorded within the interval of the top 3.5" tubing joint No other areas of significant metal loss are indicated throughout the logged interval. Details of the tool recordings are included in this report. ProActive Diagnostic Services, Inc. / P.O. Box 1369, Stafford, TX 77497 Phone: or (888) 565-9085 Fax: (281) 565-1369 E-mail: PDS@memoryiog.com Prudhoe Bay Fjeld Office Phone: 659-2307 Fa>:: 659-231.4 UI"e.- gol- l~l I I . . INTERPRETATION OF MTT LOG RESULTS: I I I I The MTT log results cover the interval 0' -191'. A log plot of the entire log interval is included in this report The Delta Metal Loss (%) curve in these plots refers to total metal surrounding the MTT tool. No significant metal loss is recorded in the interval logged. I I I I I I I I I I I I I Field Engineer: R. Richey Analyst: M. Tahtouh & J. Burton Witness: C. Fitzpatrick I ProActive Diagnostic Services! 1369/ Stafford, TX 7ì497 t-ma¡:; ì-õX: 659-231 ,:1 I I I I I I I I I I I I I I I I I I I I cI;2 jS Magnetic Thickness I (10Hz Pass) ,.. prt<>ÁCif\IE DIAqNCI5TÌc SERviCE>, INC. Database File: d\warrior\data\1 c-117\1 c-11 T db Dataset Pathname: 10hz.1 Presentation Format: 18SCAL -1 Dataset Creation: Tue Dee 12 11 :26:35 2006 by Calc Sondex Warrior VT 0 Charted by: Depth in Feet scaled 1150 -100 Delta Metal Thickness (%) 100 1.8 MTTP01 (rad) 1 0 Line Speed (fUmin) -200 -7 MTTP12 (rad) 3 I I 11. I I J I , I , - -20 - ~ - ~~ I- ~, Tree i Har:,ger , Pup Jt ~ ~. ,----. -~ ~ I 5" Collar- f-- ~ , r- - I 1--- --- ~ - , 3.5" Jt 1 :¡.. - ;-:; I "-...-. i 20 r - i--. I - L· S ~5" Collar I Ii Ine, r:x¡:e ¡; If -_. -I- I I A 40 !. ..- 3.5" Collar -~ Pup Jt _. -~---- Pup Jt -~ f4 Pup Jt ---- 60 I T ::=1 _. "3.5" Collar 1: I -~~ ,,- -~ --~..- i-~ ~~ j---'- ----JE:+-- -- - I~ -~----- ---- 'Iw I :11:.1 I 11: I I I I I I I I I I I I I I I I I I I 1 I 80 -~ 3.5" I Jt 2 3.5" CollaL .I =tj m of 8. 625" ~ == 100 I ~.- ~ ... , I--- 3.5" ; I--- : +-- Jt 3 I--- --- I -1- -- ..~ J--- ----" - i !--Bottom of 16" Conductor 7 i I--- 120 l I--- ... ~. .-- _3.5" CollaL~ 1--1 1 -.. 3.5" @ t ----¡ ...; ... Jt 4 -; ~ I " 1 140 #~ > .C'·· ~ (- &;;: _1625" Collar ~ f---. - f- 1 J . I f- , ¡ f- C ~ , I ~ I 1 ~ I r= I ) ··1·- 35" Collar I--- 160 f-- ___m .-.- 1--- 3.5" ) Jt 5 -- ( \ I ) f--- ..J -ft¥F 180 ( f ..~ L::ø",,_~ .EndofLog J 1J!:: ~ I~ I .=-= -100 Delta Metal Thickness (%) 100 1.8 MTTP01 (rad) 11.8 0 Line Speed (ftlmin) -200 -7 MTTP12 (rad) 3 ~,-,------_.._._-- ---'---~~-~------,---"~ --~._--- - ----~._-- ~.--, ----~-~._'_.~-_._._---~ I I TUBING ( 0-4602, 00:3.500, 10:2.992) I I I I Perf (4508-4646) I I I I I I I Perf (4572-4592) SEAl (4602-4608, 00:4.000) I I I I I I JOINT (4613-4617, OD:3690) KRU 1C-117 rTt~111 API: 500292302700 SSSV Type: Nipple Well Tvpe: INJ Orig 7/812001 Comcletion: Last W/O: Ref Log Date: Anale (â) TS: den (â) Angle @ TO: 10 deg @ 5000 Annular Fluid: Reference Log: LasH ag: 4606' RKB Last Tag 10/18/2006 Date: Rev Reason: TAG FILL Last Update: 1 0/28/2006 TO: 5000 ftKB Max Hole 49 deg @ 2697 Anale: ." I -~.~ - .- - - - - .-- Descriotion CONDUCTOR SURF/PROD SURF/PROD '::I':UDlna(""""~';'::;"- Size I 3,500 I Thread Eue8rdMod Size TOD 16.000 0 8.625 0 7.625 134 Bottom 158 134 4987 TVD 158 134 4202 Wt 62.50 36.00 29.70 Grade Thread H-40 WELDED N-80 511 Hvdril L-80 BTC-MOD Top o I Bottom I I 4602 I I 1M I Grade I I 9.30 I L-80 I TVD 3823 - --- ._~ - -~- - Interval TVD Zone status Ft SF'!' Date TVDe Comment 4508 - 4546 3732 - 3768 WS 38 4 8/1/2002 IPERF 33/8" HSD D,WSC 4572 - 4592 3794 - 3813 WS B 20 4 8/1/2002 IPERF 3 3/8" HSD 4620 - 4640 3841 - 3860 WS A4 20 4 131/200 IPERF 33/8" HSD 4656 - 4672 3876 - 3892 WS A3 16 4 1311200 IPERF 33/8" HSD 4678 - 4708 3898 - 3927 WS A3 30 4 131/200 IPERF 33/8" HSD 4718 - 4750 3937 - 3968 WS A2 32 4 1311200 IPERF 33/8" HSD Ga:(l..iff St MD TVD Man Man Type V Mfr V Type V DD latch Port TRO Date Vlv Mfr Run Cmnt 1 4407 3635 CAMCO MMG DMY 1. 5 RK 0.188 0 2/5/2003 2 4512 3736 CAMCO MMG DMY 1.5 RK 0.000 0 8/112002 3 4569 3791 CAMCO MMG DMY 1.5 RK 0.000 0 2/8/2003 uWlI::ret.r U::UI!!DV DeDth TVD Tvpe Description ID 515 515 NIP CAMCO OS LANDING NIPPLE 2.875 4460 3685 PACKER BAKER PREMIER PACKER 3.875 4533 3756 SLEEVE-C BAKER CMU SLIDING SLEEVE W/2.812" OS PROFILE 2.812 4550 3772 PACKER BAKER S-3 PACKER 3.875 _ 4585 3806 SLEEVE-O BAKER 2.75" 0 PROFILE CMU SLIDING SLEEVE - SLEEVE 2.750 -- OPEN 2/8/2003 - 4601 3822 LOCATOR BAKER 80-40 NO GO LOCATOR 3.000 - 4602 3823 SEAL BAKER 80-40 SEAL ASSEMBLY with 1/2" MULE SHOE 3.980 - 4604 3825 PACKER BAKER FBi RETAINER PRODUCTION PACKER 4.000 4607 3828 Extension BAKER MILLOUT EXTENSION 4.500 4612 3833 XO 2.390 4613 3834 JOINT 2.441 4617 3838 PLUG 2.25" CA-2 PLUG set 1218/2004 0.000 4617 3838 NIP CAMCO 0 NIPPLE 2.250 4618 3839 WLEG BAKER WI RELINE GUIDE 2.380 - - - - - - I---- I,-,.~ 1--.- 1.-- - -- ~-- - - -- -,- MEMORANDUM e State of Alaska e Alaska Oil and Gas Conservation Commission TO: Jim Regg .<7 P.l. Supervisor K t? . elz .., I ct1 7{"/') {)(.¿;. DATE: Monday, May 22, 2006 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC iC-117 KUPARUKRIV U WSAK IC-117 &,0\ - \ð-\ FROM: Jeff Jones Petroleum Inspector Src: Inspector Reviewed By: P.l. Suprv.:Tf?i2-- Comm NON-CONFIDENTIAL Well Name: KUPARUK RIV U WSAK IC-II7 API Well Number 50-029-23027-00-00 Inspector Name: Jeff Jones Insp Num: miúJ060508182118 Permit Number: 201-121-0 Inspection Date: 5/8/2006 ReI Insp Num Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. --, IType Inj. i W : TVD I - Well i IC-1I7 i 3685 IA 120 1700 1650 1620 i ! : P.T. I 2011210 iTypeTest ¡ SPT I Test psi i 1500 OA I i i -- Interval 4YRTST P/F P Tubing I 977 i 977 974 975 i - -. Notes 2 bbls diesel pumped. I well house inspected; no exceptions noted. Monobore injector. '~f~t\·~~\'tJ,· ,<,~~,.;r~, '~ , _ t<.:.. {:;, Monday, May 22, 2006 Page I of I e e ConocoPhillips Alaska, Inc. KRU 1C-117 1C-117 API: 500292302700 Well TVDe: INJ Anale (â) TS: dea (â) TUBING SSSV Type: Nipple Orig 7/8/2001 Angle @ TD: 10 deg @ 5000 (0-4602, 00:3.500, Completion: 10:2.992) Annular Fluid: Last W/O: Rev Reason: PULL PLUG Reference Loa: Ref Loa Date: Last Update: 8/8/2005 Last Taa: 4784 TD: 5000 ftKB Last Taa Date: 9/1/2003 Max Hole Anale: 49 dea (â) 2697 CasinQ StrinQ - ALL STRINGS Description Size Top Bottom TVD Wt Grade Thread CONDUCTOR 16.000 0 158 158 62.50 H-40 WELDED SURF/PROD 8.625 0 134 134 36.00 N-80 511 Hvdril SURF/PROD 7.625 134 4987 4202 29.70 L-80 BTC-MOD TubinQ StrinQ - TUBING Size I Top I Bottom I TVD I Wt I Grade I Thread 3.500 I 0 I 4602 I 3823 I 9.30 I L-80 I Eue8rdMod - f-- Perforations Summary Perf (4508-4546) - r-- Interval TVD Zone Status Ft SPF Date TVDe Comment - ~ 4508 - 4546 3732 - 3768 WS D,WS 38 4 8/1/2002 IPERF 3 3/8" HSD - ~ C - - 4572 - 4592 3794 - 3813 WSB 20 4 8/1/2002 IPERF 3 3/8" HSD - - 4620 - 4640 3841 - 3860 WSA4 20 4 7/31/2002 ¡PERF 3 3/8" HSD - - 4656 - 4672 3876 - 3892 WSA3 16 4 7/31/2002 IPERF 3 3/8" HSD - - 4678 - 4708 3898 - 3927 WSA3 30 4 7/31/2002 IPERF 3 3/8" HSD - 4718 - 4750 3937 - 3968 WSA2 32 4 7/31/2002 IPERF 3 3/8" HSD - Gas Lift MandrelslValves - St MD TVD Man Man Type V Mfr V Type VOD Latch Port TRO Date Vlv - - Mfr Run Cmnt - 1 4407 3635 CAMCO MMG DMY 1.5 RK 0.188 0 215/2003 - 2 4512 3736 CAMCO MMG DMY 1.5 RK 0.000 0 8/1/2002 - 3 4569 3791 CAMCO MMG DMY 1.5 RK 0.000 0 218/2003 Other rpluQs, eauip., etc.) - JEWELRY Depth TVD Tvpe Description ID 515 515 NIP CAMCO DS LANDING NIPPLE 2.875 4460 3685 PACKER BAKER PREMIER PACKER 3.875 4533 3756 SLEEVE-C BAKER CMU SLIDING SLEEVE W/2.812" DS PROFILE 2.812 4550 3772 PACKER BAKER S-3 PACKER 3.875 4585 3806 SLEEVE-O BAKER 2.75" D PROFILE CMU SLIDING SLEEVE - SLEEVE OPEN 2.750 218/2003 4601 3822 LOCATOR BAKER 80-40 NO GO LOCATOR 3.000 - 4602 3823 SEAL BAKER 80-40 SEAL ASSEMBLY with 1/2" MULE SHOE 3.980 Perf - 4604 3825 PACKER BAKER FB1 RETAINER PRODUCTION PACKER 4.000 (4572-4592) 4607 3828 Extension BAKER MILLOUT EXTENSION 4.500 - 4612 3833 XO 2.390 - - 4613 3834 JOINT 2.441 - 4617 3838 PLUG 2.25" CA-2 PLUG set 1218/2004 0.000 - 4617 3838 NIP CAMCO D NIPPLE 2.250 - 4618 3839 WLEG BAKER WIRELlNE GUIDE 2.380 - . - - - SEAL (4602-4608, 00:4.000) JOINT (4613-4617, 00:3.690) IXI - - Perf - - (4620-4640) - - Perf - -, (4656-4672) - ~ Perf - (4678-4708) - Perf - ---1 14718-4750\ e e MICROFILMED 07/25/06 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE F:\LaserFicbe\CvrPgs _lnserts\Microfilm _ Marker.doc ) ) STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test OPERATOR: FIELD I UNIT I PAD: DATE: OPERATOR REP: AOGCC REP: Email to:Tom_Maunder@admin.state.ak.US;BobJleCkenstein@admin.state.ak.US;Jim_Regg@admin.state.ak.US1(1. 1 ß /3 ) D<: :);\ ~: 1::';;';' " 11/;,;e')I'I,/!Jj~, ' c5(;:@;::·f:W' ,,' "'~ ConocoPhillips Alaska Inc. West Sak 1 KRU/1 C 08103/05 Rogers - AES Waived by John Crisp Packer Depth Well 1C-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 Well 1C-121 Type Inj. N TVD 3,561' Tubing 1900 1900 Interval 0 P.T.D. 2010800 Type test P T est 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 1C-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' A1JG 0 ~~ 2.005 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 0:: Other (describe in notes) MIT Report Form Revised: 06/19/02 2005-0803_MIT _KRU_1 C-117 _MITT.xls Schlumberger Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 A TTN: Beth Well /8'1.- )./1 1 F-02 195 <ÞÐ2'L 2T-23 'y- 2W-12 1~t{..lZlf 2Z-19 I f8 -I'j() 1 C-111 )J;1--/2.. <g 1 C-117 )...e(- /2. r 3F-14 /8'5. ;1..72 2K-07 2Z-12A ¡<ic¡.., 071 {'15- /cf<t Job # 10922513 10952507 10942806 10922502 10922504 10922505 10922499 10922503 10922501 Log Description Date INJECTION PROFILE LEAK DETECTION LOG PRODUCTION PROFILE LEAK DETECTION LOG INJECTION PROFILE INJECTION PROFILE PRODUCTION PROFILE PRODUCTION PROFILE LEAK DETECTION LOG J4~ 12/14/04 12108/04 12/15/04 12/04/04 12/06/04 12/06/04 12/03/04 12/05/04 12/04/04 <' ,<', ~ (',['(',U,t; < ... i == <=. J\ P Q ¡ ~ L J ~ SCAN r'd::l , F·' ., ok {j 12/23/04 NO. 3292 Company: Alaska Oil & Gas Cons Comm Attn: Helen Warman 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Kuparuk "-' BL CD Color 1 1 1 1 1 1 1 1 1 ~. DATE: 5- W'-~~i DATA SUBMITTAL COMPLIANCE REPORT 9/7/2004 Well Name/No. KUPARUK RIV U WSAK 1C-117 f I~.t)o~ MD 5000 /' TVD 4214 /' Completion Date ~ ~ Completion Status 1WINJ Current Status 1WINJ API No. 50-029-23027-00-00 ~. ::--- ~ ~~-_:= Permit to Drill 2011210 Operator CONOCOPHILLlPS ALASKA INC REQUIRED INFORMATION Mud Log No Samples No Directional Survey - .~ 'j~-~---- ---~. DATA INFORMATION Types Electric or Other Logs Run: GR/Res Well Log Information: (data taken from Logs Portion of Master Well Data Maint) Log/ Data Type ~g ~.C W ~ ~ ~ ./ ;;( ~ Electr Digital Dataset Med/Frmt Number Name Gamma Ray ~/ LIS Verification Induction/Resistivity j../\ 1.\ Gamma Ray L8óÍ1ic ,~(..., US) r Log Log Run Interval OH/ Scale Media No Start Stop CH Received Comments ---------_.~---.~~-- ~ 25 Blu 1 158 5000 Open 5/2/2003 158 5000 Open 5/2/2003 25 Blu 158 5000 Open 5/2/2003 25 Blu 1 158 5000 Open 5/2/2003 5 -ßhj (ø( 1 2990 4836 Case 25 Blu 1 158 5000 Open 5/2/2003 1 158 5000 Open 5/2/2003 5 Blu 1 4345 4608 Case 7/23/2003 Injection Profile - Pressu re/T emperature/Spi n ners 5 Blu 4345 4608 Case 7/23/2003 Injection Profile - Pressure/T emperature/Spin ners 5 Blu 4345 4608 Case 7/23/2003 Injection Profile - Pressu re/T emperatu re/Spin ners 5 Blu 4345 4608 Case 7/23/2003 Injection Profile - Pressu re/T emperature/Spin ners ~- ~~_._~ ---~-----_._-- Induction/Resistivity n/ ß LIS Verification L!.Rjéêtion Profile L~- ~re ~/- ~rature ~.. (..§PiM'ér Well Cores/Samples Information: Name Interval Start Stop Sent Received Sample Set Number Comments Permit to Drill 2011210 MD 5000 TVD 4214 ADDITIONAL INFORMATION Well Cored? Y /0) Chips Received? - Y / N------' Analysis Received? ~ Comments: Compliance Reviewed By: DATA SUBMITTAL COMPLIANCE REPORT 9/7/2004 Well Name/No. KUPARUK RIV U WSAK 1C-117 Operator CONOCOPHILLIPS ALASKA INC Completion Date 8/5/2002 Completion Status 1WINJ Daily History Received? Formation Tops ~ I API No. 50-029-23027-00-00 Current Status 1WINJ rVN rJ/N Date: UIC Y ~-------~~--------~---- ~-~-~---~_._------ .-.."" cJ.q ~~\-f) l{_-e= ,~, Transmittal Form INTEQ To: AOGCC 333 West 7th Ave, Suite 100 Anchorage, Alaska 99501 Attention: Lisa Weepie Reference: 1 C-117 I Contains the following: 1 LDWG Compact Disc (Includes Graphic Image files) 1 LDWG lister summary 1 blueline - MPR Measured Depth Log , 1 blueline - MPR TVD Log LAC Job#: 160394 Sent By: Glen Borel -" \.LJ c- n- Received ~~ Ú Vf2JJ(l^'.....J aO/-)Q)j II Î 's '&1. BAKER -Y. _:.."'~ ., ~i HUGHES I!n1tM. I~JIW T Ð:! '.':1- ....- .. n -... Anchorage GEOScience Center :'Y. - ... ~, :"', ::::::: :i'i- ~ r - ~-~~ !. ~....-II .......- ¡ Date: May 2, 2003 Date: PLEASE ACKNOWLEDGE RECEIPT BY SIGNING & RETURNING OR FAXING YOUR COpy FAX: (907) 267-6623 Baker Hughes INTEQ 7260 Homer Drive Anchorage, Alaska 99518 Direct: (907) 267-6612 FAX: (907) 267-6623 RECE\VEO MAY 02 2003 A\amta Oil & Gas Ançh0mg6 -'_._--,_._._'~ [Fwd: 1 C-117 Reservoir Fluid Samples] Subject: [Fwd: lC-117 Reservoir Fluid Samples] Date: Mon, 18 Nov 2002 09:51 :36 -0900 From: Tom Maunder <tom_maunder@admin.state.ak.us> To: Winton GAubert <winton_aubert@admin.state.ak.us> ( ~O J -- I ~ I Winton, Here is a message I received from Kuparuk regarding preproducing a West Sak injector to get samples. They say the well has not injected. There is a requirement to submit sundries for injectors, but in this case this notice may be sufficient. I know that in discussions with McMains, he has indicated that if production is for less than a month he sees no need for a sundry. Torn Subject: 1 C-117 Reservoir Fluid Samples Date: Mon, 18 Nov 200209:19:31 -0900 From: "NSK Problem Well Supv" <n 1617@conocophillips.com> To: tom_maunder@admin.state.ak.us CC: "NSK Full Field Prod Engr" <nI638@ppco.com>, "Scott B Rennie" <srennie@ppco.com> Torn, In order to improve the quality of geochemical data used in allocating West Sak production splits in the 1C area, it is desired to retrieve oil samples individually from the A, Band D sands from 1C-117 a permitted West Sak injector, PTD # 2011210, before placing the well on injection. In October, some work was done to swab oil samples to surface, but the job was suspended due to the slow progress. We would like to resume the sampling program with a new plan which is outline below. The work is fairly high priority since surface hookup should be complete by the end of the month and we will not place the well on injection until the sampling has been completed. (See attached file: 1C-117.pdf) The proposed procedure is: 1. RU to provide gas lift to the 7-5/8" casing of 1C-117. 2. RU to take production off the 3-1/2" tubing of 1C-117. 3. RU SL and place a 3/16" OV in GLM #1 at 44071 RKB. 4. Flow the A sand to production for -1 day and retrieve a 10 gallon oil sample. Freeze protect tubing and surface lines. 5. RU SL. Set a plug in the 2.25" D nipple at 46171 RKB to isolate the A sand. Open the CMU sliding sleeve at 45851 RKB to open the B sand. 6. Flow the B sand to production for -1 day and retrieve a 10 gallon oil sample. Freeze protect tubing and surface lines. 7. RU SL. Close the CMU sliding sleeve at 45851 RKB to isolate the B sand. Open the CMU sliding sleeve at 4533' RKB to open the D sand. 8. Flow the D sand to production for -1 day and retrieve a 10 gallon oil sample. Freeze protect tubing and surface lines. The greatest risk here is that even with gas assist, the well will not surface fluids. For this reason, the flow periods will be monitored closely and the oil sample taken as early as good oil is observed. After step 8, the sampling procedure will be complete and we can prep the well for injection. 9. 10. Pull a DV 11. Rig down gas lift and temporary production setup. RU SL. Open the CMU sliding sleeve at 45851 RKB to open the B sand. the OV from GLM #1. Load the IA with corrosion inhibited brine. Set in GLM #1. PT IA to 1500 psi. Place the well on injection. Torn, do I need to submit a 10-403 to proceed with this plan. Please call if you have any questions [Fwd: 1 C-117 Reservoir Fluid Samples] ( Peter Nezaticky ConocoPhillips Alaska Inc. (907) 659-7224 : ,Name:lC-117.pdf r ~ lC-117.pdfB Type: Portable Document Fonnat (application/pdf)¡~ ~ ~Encoding: base64 !: }'............w.~........,................,..................'.......................,........................................,..'..'.'..'...'.'...'..'.w.."""."...'...'...".""......',.......,.w.'.............'.........,....'...........w......"..'.'...'.'..'..'...................' 1 ,----------- --. _-._n- -- ----- ---- - - - -- ----------- ------- ---------------- ------. -- - ----.-------------- ---- ------ ----- --- ----- -- -- = i Toml\.launder <tonl_maunden,ä'admm.state.ak.us> ~ Sr. Petroleum Engineer Alaska Oil and Gas Conservation Commission ( .PHILLlPS Alaska, Inc. ~ A Subsidiary of PHilLIPS PETHOlEUM COMPANY TUBING (4G-4602, 00:3.500, 10:2.992) P~rl H ~ÜI3-1 ~46) P~r1 \..\5~2--1592) ~,EAL (..\602--1608, 00..\ (00) JOIIJT (4613-161 ì, 00' 3 690) :;~~ -' -" . --+... i ~. -,- -'... ~... ~I. I~ )! I ":14 I : I f' I, I 'I' r-i ., .... ~ --I 1= ~IIII~ I illil ~ -.~... ..~ I I E ..1- i= t- : . ,iIiiJO API: 500292302700 SSSV Type: Nipple Annular Fluid: Reference Log: Last Tag: Date: ( KRU 1 C-117 Well Type: INJ Orig 7/8/2001 Completion: Last W/O: Ref Log Date: TO: 5000 ftKB 49 2697 Angle ~ TS: deg @ Angle @ TO: 10 deg @ 5000 Rev Reason: New Well by ImO Last Update: 8/16/2002 Max Hole Description CONDUCTOR SURF/PROD SURF/PROD Size 16.000 8.625 TVD 158 134 4202 Wt Grade Thread 62.50 H-40 WELDED 36.00 N-80 511 Hydril 29.70 L-80 BTC-MOD Top 0 0 134 Bottom 158 134 4987 Size Top Bottom TVD I Wt Grade Thread 3.500 40 4602 3823 9.30 L-80 Eue8rdMod Interval TVD Zone Status Ft SPF Date Type Comment 4508 - 4546 3732 - 3768 WS D,WS 38 4 8/1/2002 IPERF 3 3/8" HSD C 4572 - 4592 3794 - 3813 WSB 20 4 8/1/2002 IPERF 33/8" HSD 4620 - 4640 3841 - 3860 WSM 20 4 7/31/2002 IPERF 33/8" HSD 4656 - 4672 3876 - 3892 WSA3 16 4 7/31/2002 IPERF 3 3/8" HSD 4678 - 4708 3898 - 3927 WSA3 30 4 7/31/2002 IPERF 3 3/8" HSD 4718 - 4750 3937 - 3968 WSA2 32 4 7/31/2002 IPERF 3 3/8" HSD St MD TVD Man Man V Mfr V Type VOD Latch Port TRO Date Vlv Mfr Type Run Cmnt 4407 3635 CAMCO MMG SOV 1.5 RK 0.000 0 8/1/2002 (1) w/RP 2 4512 3736 CAMCO MMG DMY 1.5 RK 0.000 0 8/1/2002 3 4569 3791 CAMCO MMG DMY 1.5 RK 0.000 0 8/1/2002 1. Depth TVD 515 515 4460 3685 4533 3756 4550 3772 4585 3806 Type NIP PACKER SLEEVE-O PACKER SLEEVE-O 4601 3822 LOCATOR 4602 3823 SEAL 4604 3825 PACKER 4607 3828 Extension 4612 3833 XO 4613 3834 JOINT 4617 3838 NIP 4618 3839 WLEG Description CAMCO DS LANDING NIPPLE BAKER PREMIER PACKER BAKER CMU SLIDING SLEEVE W/2.812" DS PROFILE BAKER S-3 PACKER BAKER 2.75" D PROFILE CMU SLIDING SLEEVE W2.75" CAMCO C-LOCK W/RHC PLUG BAKER 80-40 NO GO LOCATOR BAKER 80-40 SEAL ASSEMBLY with 1/2" MULE SHOE BAKER FB1 RETAINER PRODUCTION PACKER BAKER MILLOUT EXTENSION ID 2.875 3.875 2.812 3.875 2.750 3.000 3.980 4.000 4.500 2.390 2.441 2.250 2.380 CAMCO 0 NIPPLE W/RHC SLEEVE W/2.25" ID BAKER WIRELlNE GUIDE ( ( STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG Oil D Gas D Suspended D Abandoned D Service 0 2. Name of Operator ~lOOA~ 3. :~~~ Alaska, Inc. ¡ ~j P. O. Box 100360, Anchorage, AK 99510-0360 ~'SufT~!:J 4. Location of well at surface [cor¡PLETlON --I ~ tt W~~~~ 1555' FNL, 799' FWL, Sec. 12, T11N, R1OE, UM .:... C/~Z- IE. ~.' ,,;J.r,.. (ASP: S61806, 596à68~;. ~, At Top Producing Interval . 0 <;S -- f ~:~~~~~~~321' FEL, Sec. 11, T11N, R1OE, UM ,:.; ~j (ASP: 559683,5969058) 1144' FNL, 1379' FEL, Sec. 11, T11N, R10E, UM (ASP: 559625, 5969074) 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. RKB 40.3 feet ADL 25649 ALK 467 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. Or Aband. July 2, 2001 July 5, 2001 August 2, 2002 17. Total Depth (MD + TVD) 18. Plug Back Depth (MD + TVD) 19. Directional Survey 5000' MD 14214' TVD 4888' MD 14104' TVD YES 0 No D 22. Type Electric or Other Logs Run GR/Res 23. 1. Status of well CASING SIZE GRADE H-40 N-80 L-80 16" WT. PER FT. 62.5# 36# 29.7# 8.625" X 7.625" CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD TOP BOTTOM Surface 158' Surface 134' 134' 4987' HOLE SIZE 24" 9.875" 9.875" 24. Perforations open to Production (MD + TVD of Top and Bottom and interval, size and number) 4508' - 4546' MD 4572' - 4592' MD 4620' - 4640' MD 4656' - 4672' MD 4678' - 4708' MD 4718' - 4750' MD 3732' - 3768' TVD 3794' - 3813' TVD 3841' - 3861' TVD 3876' - 3892' TVD 3898' - 3927' TVD 3937' - 3968' TVD 27. Date First Production N/A Date of Test N/A Hours Tested Flow Tubing press. Psi 28. Casing Pressure 25. SIZE 4 spf 4 spf 4 spf 4 spf 4 spf 4 spf Classification of Service Well Water Injector 7. Pennit Number 201-121 1301-189 I 302-228 8. API Number 50-029-23027-00 9. Unit or Lease Name Kuparuk River Unit 10. Well Number 1C-117 11. Field and Pool West Sak Oil Pool Kuparuk River Field 15. Water Depth, if offshore NI A feet MSL 20. Depth where SSSV set Landing Nipple @ 500' 16. No. of Completions 1 21. Thickness of Permafrost 1927' CEMENTING RECORD 270 sx AS 1 AMOUNT PULLED 530 sx AS Lite, 380 sx Class G included above 3.5" TUBING RECORD DEPTH SET (MD) 4602' PACKER SET (MD) 4460' & 4550' & 4604' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED CONTINUED ON REVERSE SIDE W A TER-BBL CHOKE SIZE GAS-OIL RATIO N/A W A TER-BBL OIL GRAVITY - API (corr) PRODUCTION TEST Method of Operation (Flowing, gas lift, etc.) Injector Production for OIL-BBL Test Period> Calculated GAS-MCF OIL-BBL GAS-MCF Brief description of lithology, porosity, fractures, apparent dips and pressence of oil, gas or water. Submit core chips. N/A Form 10-407 Rev. 7-1-80 24-Hour Rate> CORE DATA -'" G'v- LRBDMS BFl Submit in duplicate AUG 2 9 2002 29. ( 30. GEOLOGIC MARKERS FORMATION TESTS MEAS.DEPTH TRUE VERT. DEPTH Include interval tested, pressure data, all fluids recovered and gravity. GOR. and time of each phase. NAME Top D Sand Top B Sand Base B Sand Top A4 Sand Top A1 Sand 4502' 4566' 4607' 4607' 4824' 3727' 3787' 3827' 3827' 4041' Annulus left open - freeze protected with diesel. 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. Questions? Call Vern Coyner 265-6074 Signe~ ~.,->--- -. Ran~y ~omas IIÞ1L ~~("-h"\~ D.t-c ({~ ~<:::--lJ=......",,~e.r- Title <-DrillilllJ Ellyillt:erill~ ~uporvioor Date 2 f'2...::a 10 L- Prepared by Sharon Allsup-Drake INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1: Classification of Service wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for 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 ~ ~ ~ "II ~ ~ (-.. T¡rjI ~ PHILLIPS ALASKA INC. Operations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 C-117 1 C-117 ROT - DRILLING n1268@ppco.com Nabors 245 Date 7/2/2001 7/3/2001 7/4/2001 7/5/2001 7/6/2001 Sub From- To Hours Code Code Phase 07:00 - 11 :00 4.00 MOVE MOVE MOBMIR 11 :00 - 16:00 5.00 WELCTL NUND PROD 16:00 - 16:30 0.50 RIGMNT RSRV PROD 16:30 - 17:30 1.00 DRILL SFTY PROD 17:30 - 18:00 0.50 WELCTL BOPE PROD 18:00 - 23:00 5.00 DRILL PULD PROD 23:00 - 00:00 1.00 DRILL DRLG PROD 00:00 - 02:00 2.00 DRILL DRLG PROD 02:00 - 02:30 0.50 DRILL CIRC PROD 02:30 - 15:30 13.00 DRILL DRLG PROD 15:30 - 17:00 1.50 RIGMNT OTHR PROD 17:00 - 00:00 7.00 DRILL DRLG PROD 00:00 - 02:00 2.00 DRILL DRLG PROD 02:00 - 02:30 0.50 DRILL CIRC PROD 02:30 - 04:00 1.50 DRILL WIPR PROD 04:00 - 05:00 1.00 DRILL WIPR PROD 05:00 - 14:30 9.50 DRILL DRLG PROD 14:30 - 15:30 1.00 DRILL DRLG PROD 15:30 - 00:00 8.50 DRILL DRLG PROD 00:00 - 19:00 19.00 DRILL DRLG PROD 19:00 - 20:00 1.00 DRILL CIRC PROD 20:00 - 21 :00 1.00 DRILL OBSV PROD 21 :00 - 00:00 3.00 DRILL TRIP PROD 00:00 - 01 :00 1.00 DRILL TRIP PROD 01 :00 - 03:30 2.50 DRILL OTHR PROD Start: 7/2/2001 Rig Release: 8/2/2002 Rig Number: 245 Qescription otOþerätions Page 1 of 6 Spud Date: 7/2/2001 End: 8/2/2002 Group: Raise cellar box" Jackup utility module, the n drill module. Move fI 1C-127 to 1C-117 (1 50' away from CPM). Repair chain pin and ro Iler on # 3 Lampson main drive chain. Accep trig @ 1100 hrs 07/02/2001. NU 21 114" Annular and diverter system. Service top drive. Pre spud meeting with Phillips co. rep and a II personnel Function test diverter and accumulator unit. Fill hole check for leaks. Witness of divert er test waived by AOGCC rep. John Crisp. PU Navidrill and adjust to 1.5 deg. PU BHA, orient and program same. Safety meeting/ diverting shallow gas drill. Drill fI 158' to 180' (22') ADT 0.3 hrs. Directiional drill 9 7/8" hole fI 180' to 271' (91') ART.5 hrs Circulate & Condition mud. Raise vis f/ 75 t 0 250. Maintain vis to 180+. Directional drill 9 7/8" hole fl 271' to 1183' (912') ART= 6.5 hrs AST = 4.1 hrs Discflow pumps plugged. Clean out discflow tank. Circ slow, hydrates to surface, 6.4 pp g lowest reported mud wt. Directional drill 97/8" hole fl 1183' to 182 0' (637') ART = 1.3 hrs AST = 3.6 hrs Directional drill 9 7/8" hole fI 1820' to 2022 '(202') ART = .6 hrs AST = .7 hrs Circulate sweep and monitor hole. S h 0 r t t rip t 0 1 8 4 '. Pull D P s ere en. M o.n i tor well, no problems. Trip in hole to 1929'. Precautionary ream to 2022'. No problems. No fill. Directional drill 9 7/8" hole fI 2022' to 2955 '(933') ART 4.44 hrs AST = 1.22 hrs Depth tracking problem with Baker Hughes I nteq Equipment in MWD Unit. Software probl em. Directional drill 9 7/8" 91' (936') ART = 4.1 Directional drill 9 7/8" '(1109') TVD 4214' T= 5.19 hrs. Circulate and condition mud and hole. Pum p Hi-vis sweep. Monitor well for flow prior to pumping dry jo b. POOH @ TD' for 9 7/8" hole opener. Continue POOH @ TD for 9 7/8" hole opener hole from 2955' to 38 hrs AST 1.43 hrs hole fI 3891' to 5000 ART = 9.85 hrs. AS Download MWD/LWD. LID BHA. Clean up rig f 100 r. Printed: 8/23/2002 1 :31 :54 PM (' ~,~ ~ ~ Page 2 of 6 PHilliPS ALASKA INC. Operations Summary Report Legal Well Name: 1 C-117 Common Well Name: 1 C-117 Event Name: ROT - DRILLING Contractor Name: n1268@ppco.com Rig Name: Nabors 245 Date Frol11~ To Hours Code Sub Phase Code 7/6/2001 03:30 - 04:00 0.50 DRILL PULD PROD 04:00 - 05:00 1.00 RIGMNT RSRV PROD 05:00 - 08:30 3.50 DRILL TRIP PROD 08:30 - 11 :30 3.00 DRILL CIRC PROD 11 :30 - 14:30 3.00 DRILL TRIP PROD 14:30 - 16:30 2.00 DRILL PULD PROD 16:30 - 17:30 1.00 CASE RURD PROD 17:30 - 18:30 1.00 CASE SFTY PROD 18:30 - 21 :30 3.00 CASE RUNC PROD 21 :30 - 22:00 0.50 CASE CIRC PROD 22:00 - 00:00 2.00 CASE RUNC PROD 7/7/2001 00:00 - 01 :00 1.00 CASE RUNC PROD 01 :00 - 02:00 1.00 CASE RUNC PROD 02:00 - 07:00 5.00 CEMENTCIRC PROD 07:00 - 09:30 2.50 CEMENT PUMP PROD 09:30 - 10:30 1.00 CEMENT DISP PROD 10:30 - 11 :00 0.50 CEMENT NFL T PROD 11 :00 - 14:30 14:30 - 15:30 3.50 WELCTL NUND PROD 1.00 WELCTL NUND PROD 15:30 - 17:30 2.00 WELCTL NUND PROD 17:30 - 18:30 18:30 - 20:00 1.00 RIGMNT RSRV PROD 1.50 CEMENT COUT PROD 20:00 - 00:00 4.00 CEMENT COUT PROD 7/8/2001 0.50 CEMENT COUT PROD 2.50 CEMENT COUT PROD 00:00 - 00:30 00:30 - 03:00 03:00 - 05:00 2.00 CEMENT COUT PROD Spud Date: 7/2/2001 End: 8/2/2002 Group: . Start: 7/2/2001 Rig Release: 8/2/2002 Rig Number: 245 Description of Operations PU 8 7/8" hole opener and new BHA. Service rig and top drive. RIH wI 9 7/8" hole opener. Hole a little tigh t @ 3539' & 4565'. PU 3 singles, RIH to 500 0' . No fill. Fill pipe & break circulation. CBU. Pump hi vis/density sweep. Monitor well. LID 3 singles. POOH wI 9 7/8" hole opener f or 7 5/8" casing. PJSM. LID BHA. PJSM. RU casing crew. PJSM wI Rig supervisor and all personel!. Run 7 5/8" 29.7 # casing to 2170'.50 joints in h 0 Ie. Circ surface to surface. Continue to run 7 5/8" casing. 94 joints casi ng in hole @ midnight. Fisnsh running 7 5/8" casing to joint # 113 ( 4848') L/D fill up tool, change elevators & slips. PU 2 crossovers and 2 joints 8 5/8" casing, ha nger and 8 5/8" landing joint. Land casing. RU cementing equipment. Break circ slowly. 2BPM @ 725 psi. Increas e rate as hole would allow to 6 1/2 BPM and 300 psi final pressure. Schlumberger/Dowel1 cement according to w ell plan. Rig dispalce w/ mud pump 206 bbls 2041 str okes mud and bump plug. CIP 1032 hrs 7/761 2001 Inflate ECP packer, top @ 4605.46'). Packer opened at 2600 psi. Took .6 bbls fluid. ND Diverter system. Wash out same. Install Vetco Gray wellhead and orient same . Set wear bushing. NU Riser, flow nipple, turnbuckles, fill up an d trip tank lines. Service top drive. PJSM, PU BHA to drill cement inside of 7 51 8". RIH wI 3 1/2" drill pipe and BHA to 4492'. C alculated top of cement @ 4471' after pumpi ng .6 bbl cement into inflatable packer. Soft cement and I or cement stringers to 4582'. Slight indication of cement @ 4582'. Wash with bit and motor f/ 4492' to 4582'. Drill soft cement fl 4582' to 4645'. Hard ce ment @ 4645'. Drill to 4888'. CBU + (2008 strokes/202 bbls) til clean. Pu mp 32 bbls Barazan pill, follow wI 50 bbls w ater @ 6BPM, Drop bar/open circ sub, pump 150 bbls water @ 12 BPM, pump 290 bbls se Printed: 8/23/2002 1:31:54 PM ~þ TfTiI ,~ Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date 7/8/2001 7/29/2002 7/30/2002 Page 3 of 6 PHilliPS ALASKA INC. Operations Summary Report 1 C-117 1 C-117 ROT - DRILLING n1268@ppco.com Nabors 245 . Sub From~.To . Hours. Code Code Phase 03:00 - 05:00 05:00 - 05:30 05:30 - 06:30 06:30 - 08:30 08:30 - 10:30 10:30 - 13:30 13:30 - 14:30 14:30 - 15:00 15:00 - 19:30 19:30 - 20:30 20:30 - 21 :00 21 :00 - 21 :30 04:00 - 12:00 12:00 - 00:00 00:00 - 04:00 04:00 - 09:00 09:00 - 12:00 2.00 CEMENT COUT PROD 0.50 WELLSR FRZP PROD 1.00 WELLSR FRZP PROD 2.00 CEMENTTRIP PROD 2.00 CEMENTTRIP PROD 3.00 WELCTL NUND PROD 1.00 WELCTL NUND PROD 0.50 WELCTL OTHR PROD 4.50 DRILL TRIP PROD 1.00 RIGMNT RURD PROD 0.50 RIGMNT RSRV PROD 0.50 RIGMNT SFTY PROD 8.00 MOVE MOVE MOVE 12.00 MOVE MOVE MOVE 4.00 MOVE MOVE MOVE 5.00 MOVE MOVE MOVE 3.00 WELCTL OTHR CMPL TN Spud Date: 7/2/2001 End: 8/2/2002 Group: Start: 7/2/2001 Rig Release: 8/2/2002 Rig Number: 245 Desqription Of Operations awater @ 6 BPM. Monitor well, OK. RU to pump diesel for freeze protection. Pump 80 bbls diesel @ 2.5 bpm. Allow diese I to U-Tube. Monitor well. PJSM. POOH, stand back 48 stands 3 1/2" drill pip e on driller's side. LID BHA. Used another 33 bbls diesel to fill hole on trip out. Total of 113 bbls diesel in to well for freeze protection. Blow down all surface equipment. PJSM. ND r i s e r. NU Swab valve. Clean and secure cellar area. PJSM. LID 5" drill pipe from derrick. 42 sta n d s. Slip and cut 130' drilling line. Service top drive. Safety meeting wI all hands on moving rig. Rig released @ 2130 hrs 7/8/2001 Prepare rig for move to 1C-117. Pick up rig set on crib blocks. Raise cellar, set rig mat s. Wait on wireine work on 1c-117. Perform Rig maintenance, Change out equalizer val v es in mud pits, work 01') mud pumps, remove shaker screens in CPM. Wait on wireline work on on 1c-117. Perform rig maintenance, Clean rig. Give Hhot Oil 1 45 bbls 9.3 brine to pump down 1c-117 to cl ean up well bore. Wait on wireline work on 1c-117. Perform ri g maintenance (top drive and shaker mainte nance), Clean rig. Send GBR equipment and 4 1/2" IF subs down f/ rig floor. Move rig f/ 1C-104 to 1C-117 (210') toward s CPM. Rig accepted @ 0900 hrs 7/30/2002. MU tubing hanger(top connection on hanger= 4.909 MCA, 10.75" OD, with 4 1/2" 12.6#/ft NSCT pup below) with BPV installed on Ian ding joint. RIH, Engage LDS. Nipple down 7 1/6" big bore valve. NU 13 5/8" 5m BOPE. Pull tubing hanger, Set test plug. Rig up rig floor to test BOPE. Witness of BOPE test waived by AOGCC insp ector Lou Grimaldi. Test plug leaking. PU C hange out seal, still no test. Test BOPE. 13 5/8" Riser leaked. Tighten ri ser. Test BOPE. Test plug leaking again. Change out Vetco test plug. Witness of BOPE test waived by AOGCC insp ector Lou Grimaldi. Test all rams and all val ves @ 250 psi and 5000 psi. Test annular @ 250 psi and 3500 psi. All test held f/ 5 min 12:00 - 15:00 3.00 WELCTL NUND CMPL TN 15:00 - 16:00 1.00 WELCTL OTHR CMPL TN 16:00 - 17:00 1.00 WELCTL BOPE CMPL TN 17:00 - 19:00 2.00 WELCTL BOPE CMPL TN 19:00 - 19:30 0.50 WELCTL BOPE CMPL TN 19:30 - 23:30 4.00 WELCTL BOPE CMPL TN Printed: 8/23/2002 1 :31 :54 PM ~.~ TjTfi ~ Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date 7/30/2002 7/31/2002 From-To 19:30 - 23:30 23:30 - 00:00 00:00 - 01 :00 01 :00 - 03:00 03:00 - 05:00 05:00 - 07:00 (' Page 4 of 6 PHilliPS ALASKA INC. Operations Summary Report 1 C-117 1 C-117 ROT - DRILLING n1268@ppco.com Nabors 245 - ... ... ....-Sub HOlJfS Cocie. Code Phase 4.00 WELCTL BOPE CMPL TN 0.50 WELCTL OTHR CMPL TN 1.00 WELCTL OTHR CMPL TN 2.00 CMPL TN TRIP CMPL TN 2.00 CMPLTN TRIP CMPLTN 2.00 CMPL TN CIRC CMPL TN 07:00 - 07:30 0.50 CMPL TN OBSV CMPL TN 07:30 - 08:00 0.50 CMPL TN TRI P CMPL TN 08:00 - 08:30 0.50 CMPL TN OTHR CMPL TN 08:30 - 09:30 1.00 CMPLTN TRIP CMPL TN 09:30 - 10:00 0.50 CMPLTN TRIP CMPL TN 10:00 - 14:00 4.00 CMPL TN PERF CMPL TN 14:00 - 15:00 1.00 CMPL TN PERF CMPL TN 15:00 - 17:30 2.50 CMPL TN PERF CMPL TN 17:30 - 19:00 1.50 CMPL TN PERF CMPL TN 19:00 - 20:30 1.50 CMPL TN PERF CMPL TN 20:30 - 21 :00 0.50 CMPL TN PERF CMPL TN 21 :00 - 22:30 1.50 CMPL TN PERF CMPL TN 22:30 - 23:00 0.50 CMPL TN PERF CMPLTN Spud Date: 7/2/2001 End: 8/2/2002 Group: Start: 7/2/2001 Rig Release: 8/2/2002 Rig Number: 245 Description of Operations . Tested accumulator. Tested all rams, all valves to 250 psi Iowan d 5000 psi high. Test annular to 250 psi low and 3500 psi high. Hold all tests 5 min. Te sted accumulator. RID BOPE test equip. Blow down choke line and kill line. R/U to take returns to open to p tank fl annulus. MU 6 1/8" bit, 7 5/8" casing scraper, bit sub and (6) 4 3/4" DC's. RIH (SLM- no correction)wl scraper assembl y to top of FB-1 packer (4598' DPM = 4604' WLM) PUwt148K SOwt=118K R ot weight 133 K Displace 9.3 ppg and 7 ppg diesel fl well @ 4598'. Circ 95 deg. 8.5 ppg seawater total 0 f 210 bbls to vac truck f/ annulus valve of w ell @ avg. 5.4 bpm with 490 psi. Then take r eturns to active pit system @ 9 bpm & 900 P si. Pumped total of 487 bbls, including wha t was pumped to vac truck. Monitor well. Ok. SPR @ 4598' wI 8.5 ppg s eawater. # 1 pump @ 30 spm = 125 psi. # 2 pump @ 45 spm = 270 psi. POOH wI 7 5/8" casing scraper assembly to 4068' . Test 8 5/8" x 7 5/8" casing to 900 psi fI 10 min. Took 2.5 bbls to pressure up. Good tes t. POOH wI 7 5/8" casing scraper assembly to 1 90'. Continue to POOH @ DC's. Set back 4 3/4" DC's, 7 5/8" csg scraper and 6 1/8" bit. RU Schlumberger wireline to perf West Sak B & D zones. Test Schlumberger wire line lubricator and a nd packoff to 500 psi. Test no-good. Change out "0" rings on lubricator union. C hange out WL packoff rubbers. Lay down lub ricator and remove packoff sub. Trouble sho oting problem while another is headed this d irection. Wait on another Schlumberger packoff sub. MU Schlumberger packoff sub. Rig lubricator back up. Test lubricator to 500 psi f/ 5 min. OK. RIH wI 20' Schlumberger 3 3/8" OD, 4 spf gu ns, wI CCL and gamma. RIH to 4570'. Tie- in pulling back to 4300' wI CCL & GR. Distan ce CCL to top shot 6'. With GCL @ 4566' an d top shot @ 4572, perf 4572' to 4592' WLM @ 22:30 hrs 7/31/02 POOH after perf. All shots fired. Well is sta Printed: 8/23/2002 1 :31 :54 PM ~þ TjTf1 ~ Page 5 of 6 PHilliPS ALASKA INC. Operations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 C-117 1 C-117 ROT - DRILLING n1268@ppco.com Nabors 245 Sub Hours ...Code....Cöde Phase Date From.~To 7/31/2002 22:30 - 23:00 23:00 - 00:00 0.50 CMPL TN PERF CMPL TN 1.00 CMPL TN PERF CMPL TN 8/1/2002 00:00 - 01 :00 1.00 CMPL TN PERF CMPL TN 01 :00 - 02:00 1.00 CMPL TN PERF CMPL TN 02:00 - 03:00 1.00 CMPL TN PERF CMPL TN 03:00 - 03:30 0.50 CMPL TN PERF CMPL TN 03:30 - 04:00 0.50 CMPL TN PERF CMPL TN 04:00 - 07:30 3.50 CMPLTN OTHR CMPL TN 07:30 - 08:00 0.50 CMPL TN TRIP CMPL TN 08:00 - 10:30 2.50 RIGMNT RGRP CMPL TN 10:30 - 12:00 1.50 CMPL TN TRIP CMPL TN 12:00 - 12:30 0.50 CMPL TN TRI P CMPL TN 12:30 - 13:00 0.50 CMPLTN CIRC CMPL TN 13:00 - 15:00 2.00 CMPLTN TRIP CMPL TN 15:00 - 15:30 0.50 CMPL TN OTHR CMPL TN 15:30 - 16:00 0.50 CMPL TN RUNT CMPL TN 16:00 - 22:00 6.00 CMPL TN RUNT CMPL TN 22:00 - 23:00 1.00 CMPL TN CIRC CMPL TN 23:00 - 00:00 1.00 CMPL TN OTHR CMPL TN 8/2/2002 00:00 - 02:00 2.00 CMPL TN OTHR CMPL TN 02:00 - 04:00 2.00 CMPLTN OTHR CMPL TN Spud Date: 7/2/2001 End: 8/2/2002 Group: Start: 7/2/2001 Rig Release: 8/2/2002 Rig Number: 245 Description of Operations tic. MU 18' Schlumberger 3 3/8" OD, 4 spf guns , wI CCL & GR. Test lubricator to 500 psi. OK. RIH wI 18' S chi umberger 3 3/8" OD, 4 spf guns, wI CCL and gamma. RIH to 4570'. Tie- in. Distance CCL to top shot 8'. With CCL @ 4520' and to p shot @ 4528', perf 4528' to 4546' WLM @ 00:45 hrs 8/1/2002. POOH wI Schlumberger WL and perf guns. AI I shots fired. Hole static. MU 20' Schlumberger 3 3/8" OD, 4 spf guns , wI CCL and gamma.Test lubricator to 500 p si. RIH wI 20' Schlumberger 3 3/8",4 spf gu ns, wI CCI and GR. RIH to 4570. Tie in. Dist ance CCL to top shot 6'. With CCL @ 4502' and top shot @ 4508', perf 4508' to 4528' W LM @ 02:45 hrs 8/1/2002. POOH wI Schlumberger WL and perf guns. AI I shots fired. Hole static. RID Schlumberger. RID Riser. Monitor well. Monitor well. Hole static. Waiting on tools t 0 MU cleanout assembly to clean below FB-1 packer. PU/MU assebly to cleanout below FB-1 pack er (into mill out extension). Replace upper jaw cylinder on iron roughnec k. RIH wI assembly to cleanout below FB-1 pac ker (mill out extension). RIH to 4557'. Continue to RIH ro top of FB-1 packer set @ 4604' WLM. No-go crossover tag up on top @ 4598'. Circ 8.5 ppg seawater, 100 degree temp., @ 100 spm (10.1 bpm) with 1100 psi. Warm up fluid in hole- clean out debris in mill out e xtension below WL set packer. POOH wI cleanout assembly. LID stiner, scr aper, junk basket and crossover. Pull wear bushing fl wellhead. RU to run 3 1/2" completion assembly. Pre j ob safety meeting. Run 142 joints of 31/2",9.3 #/ft, eue-mod, tubing wI accessories to 4567'. MU headpin. Circ 120 bbls, 97 deg, 8.5 ppg seawater, 2.5 bpm with 150 psi. Slack off while circ @ 5 spm, to locate. MU joint 143, circ 5 spm, tag @ 7.65' in on join t # 143. Measure 11 space out. Locate 3 1/2" space out pups that will rabbit to 2.91. RU lines to pump and test to set p ackers. M U 3 1 I 2 ", 9. 3 # 1ft, E U E 8 r d mod pups. Pup s Printed: 8/23/2002 1 :31 :54 PM ~8.~ TfTiI ~ Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date 8/2/2002 Page 6 of 6 PHILLIPS ALASKA INC. Operations...SummaryReport 1 C-117 1 C-117 ROT - DRILLING n1268@ppco.com Nabors 245 Sub From ~To . Hours Code Code 02:00 - 04:00 04:00 - 04:30 04:30 - 05:00 05:00 - 05:01 05:01 - 06:00 06:00 - 06:30 06:30 - 08:00 08:00 - 11 :30 11 :30 - 12:00 12:00 - 12:30 12:30 - 14:00 14:00 - 14:30 14:30 - 15:00 15:00 - 15:01 Phase 2.00 CMPL TN OTHR CMPL TN 0.50 CMPL TN OTHR CMPL TN 0.50 CMPL TN PCKR CMPL TN 0.02 CMPL TN PCKR CMPL TN 0.98 CMPL TN OTHR CMPL TN 0.50 CMPL TN OTHR CMPL TN 1.50 WELCTL NUND CMPL TN 3.50 WELCTL NUND CMPL TN 0.50 CMPL TN OTHR CMPL TN 0.50 CMPL TN FRZP CMPL TN 1.50 CMPL TN FRZP CMPL TN 0.50 WELCTL OTHR CMPL TN 0.50 WELCTL OTHR CMPL TN 0.02 MOVE OTHR MOVE Spud Date: 7/2/2001 End: 8/2/2002 Group: Start: 7/2/2001 Rig Release: 8/2/2002 Rig Number: 245 Description. of Operations selected 8.12', 8.14', 8.17', & 0.80', then MU joint # 140, x-o, 4 1/2" pup on hngr, the n hanger, then landing joint. Land tubing wI mule shoe @ 4608.7' WLM. RILDS. Pressure test pumping lines to 4000 psi. Pump 9 strokes down tubing to 4000 psi. S-3 set @ 2500 psi. Premier packer set @ 4000 psi. Hold pressure f/ 15 min. Chart test. G ood test. Bleed pressure on tubing to 1,000 psi. With 1000 psi left on tubing, pressure 7 5/8 " x 3 1/2" annulus to 2500 psi with 20 strok es-- to test premier packer. Tubing pressu re increased to 1350 psi with compression. Held test f/ 30 min. Chart test. Good test RID pumping lines. LID landing joint.Test up per & lower ports (between seals on hanger) to 5000 psi fl 10 min. on tubing head. Pull sleeve out of tubing hanger. Set 4" BPV. Nipple down 13 5/8" BOP stack. NU Vetco Gray 4 1/8" 5m tree. Set two way check. Test tree and void to 250 psi Iowan d 5000 psi f/ 10 min each. Chart test. Good test. Pull Two way check. RU to test tubing and annulus. Test 3 1/2" tubing to 1000 psi. Hold tubing pressure while pressuring up 7 5/8" x 3 1/2" ann to 2700 psi. Hold f/ 5 min. Bleed off tu bing pressure and shear RP valve in GLM @ 4407' WLM. Freeze protect well by pumping 100 bbls die sel down 7 5/8" x 3 1/2" annulus. "U" tube d iesel to tubing. Blow down lines. RID lines. Set Vetco Gray BPV. Secure well. Clean up cellar area. Rig released @ 1500 h rs 8/2/2002 to move to 1C-127. 1C-127 is 1 50' away f/ 1 C-117--towards the utility modu Ie. Rig released fl 1C-117 f/ 150' move towards utility module to 1C-127. Waiting f/ pre rig work to be completed on 1C-127. Printed: 8/23/2002 1 :31 :54 PM Date 10/05/01 1 0/06/01 07/21/02 07/23/02 07/24/02 07/25/02 07/26/02 07/27/02 07/28/02 07/29/02 1 C-117 Event H ¡story Comment DRIFTED CSG (2.76") & TAGGED FILL @ 4855' WLM. [TAG] PERFORMED A USIT LOG; GOOD CEMENT FROM 4640' TO 2990', FAIR CEMENT FROM 4836' TO 4640'. NO PROBLEMS RIH. [CEMENT-USIT LOG] DRIFT 7" CSG & TAG STICKY BTM @ 4860' SLM. [TAG] WAITING FOR 7-1/16" FULL BORE VALVE TO ARRIVE FROM MILNE PT. VALVE & CAP ARRIVE, NIPPLE DN STD VALVE, NIPPLE UP FULL BORE VALVE. PT TO 2500 PSI. STAB ON ELINE 7" PUMP IN SUB AND BOPE'S. RIH W/ 3-3/8" HSD GUNS LOADED 4SPF, 120 DEG PHASED, BIG HOLE CHARGES. PERFORATED 4620'- 4640',4656'-4672',4678'-4708',4718'-4750'. STAND BACK UNIT FOR THE NIGHT. [PERF] SWS DISCOVERS THAT 6.5" WILL NOT DRIFT 7" LUBRICATOR OR BOPE STACK. ATTEMPT TO ASSEMBLE 7-5/8" RISER. DELIVER FLANGES TO COBURN, 7-5/8" CSG JT TO GBR WELDING. DISCUSS W/ MACHINIST & WELDER. RISER DELIVERED AND PT TO 1000 PSI. TEST GOOD. RUN PKR TOMMOROW RAN JUNK BASKET GAUGE RING 6.625" TO 4620 AND SET BAKER MODEL FB-1 PACKER TOP AT 4604'. FOUND 250 PSI ON WELL AFTER 1.5 HRS. PT PKR TO 1000 PSI, BLED TO 500 PSI IN 10 MIN. PKR FAILED PT. BAILED UNKNOWN FILL & PULLED 2.25" A-2 PLUG EQ. PRONG & BODY FROM BAKER PKR @ 4584' SLM.STAND BY FOR WELL TO BE DISPLACED W/ 9.2 BRINE. JOB IN PROGRESS. LRS PUMPED 250 BBLS OF 9.3# BRINE DOWN CSG. SET 2,25" A-2 PLUG IN BAKER PKR @ 4585' SLM. PT TO 1750 PSI, GOOD. BLEED TO 0 PSI Page 1 of 1 8/23/2002 ~--'\ = 'NTEQ SURVEY CALCULATION AND FIELD WORKSHEET Company 'pHILLIPS ALAS~~_!~<:?~--------------_d_----- Well Name & No. PAD 1 C/117 ----'---"--- .-_. --_.._._-_._.-----_._------'-"~-- - -~... ----..-.- Target TVD --------- --~T) Target Description Target Direction --- Date Survey Survey Tool. Depth Type (Fl) 0.00 03-JUL-01 MWD 03-JUL-01 MWD 03-JUL-01 MWD 03-JUL-01 MWD 03-JUL-01 MWD 03-JUL-01 MWD 03-JUL-01 MWD 03-JUL-01 MWD 03-JUL-01 MWD 03-JUL-01 MWD 158.00 200.90 291.96 382.84 473.14 564.12 654.66 745.70 836.34 927.14 (DO) Job No. 0450-00093 ---- Rig Contractor & No. Nabors AK Drilling - #~5E __.dO- ----- Survey Section Name Definitive Survey ------""- WELL DATA Target Coord. N/S Slot Coord. NIS Target Coord. E/W Slot Coord. E/W Build\Walk\DL per: 10Oft~ 30mD 10mD Vert. Sec. Azim. Incl. Hole Angle Direction (DO) (DO) 0.00 0.00 0.00 0.35 0.62 0.70 0.53 0.79 2.90 8.70 9.76 9.84 03-JUL-01 MWD 1017.26 13.27 03-JUL-01 MWD 1112.12 17.05 03-JUL-01 MWD 1204.26 21.36 03-JUL-01 MWD 1298.00 23.82 ----- _._-_.__._-_.~...._- _...._-- ---- 03-JUL-01 MWD 1390.66 26.19 03-JUL-01 MWD 1483.10 30.23 03-JUL-01 MWD 1576.90 34.01 03-JUL-01 MWD 1670.00 37.44 03-JUL-01 MWD 1764.86 41 .57 '--"~--'-"-------'---'----'-----'--'--~-- 03-JUL-01 MWD 1858.44 45.97 13.55 5.82 320.47 261.76 249.45 241.72 241 .37 244.18 242.77 251.21 262.46 267.03 272.30 276.17 277.58 280.39 281.09 282.15 -. -------------------"---.'-'--"--'- 04-JUL-01 MWD 1950.96 46.32 04-JUL-01 MWD 2044.24 46.41 . ...--_.. __.n.-___-'- - -- - 04-JUL-01 MWD 2137.55 47.99 282.50 .- -'-""'-"---~"_._'-'-"'''''- 282.85 - - ..-._. --...-.--------. -"-. --. 286.01 Course Length (Fl) 0.00 2.30 158.00 42.90 91.06 90.88 90.30 90.98 90.54 91.04 90.64 90.80 90.12 94.86 92.14 93.74 92.66 92.44 93.80 93.10 94.86 93.58 TVD (Fl) 0.00 158.00 200.90 291.96 382.83 473.13 564.10 654.59 745.13 834.59 924.07 1012.35 1103.90 1190.92 1277.47 1361.45 _._- 1442.90 1522.33 1597.90 1671.08 ----...-- --- 1738.64 -___.._n.- -_. ",-._'. --...-.-". ..----~--- -.-- 1802.74 92.52 93.28 93.31 1867.11 1930.52 SURVEY DATA Vertical Section 0.00 0.00 0.02 0.04 0.06 0.43 1.34 3.89 11.22 22.48 34.67 49.01 69.71 97.42 132.03 170.44 213.84 263.59 317.91 378.24 442.95 509.64 0.. -- U_'---','-.-'U""__d 577.11 -.--. --.-.-----_____.nu__'-'-- 645.41 -1555.00 799.00 280.73 Grid Correction Magn. Declination Magn. to Map Corr. Total Coordinate Build Rate N(+) I S(-) E(+) I W(-) DL Build (+) (Fl) (Fl) (Per 100 Fl) . Drop (-) 0.00 0.00 -8.87 -15.94 -24.03 -33.49 -40.05 -43.27 -43.42 -40.10 -34.10 -25.56 -14.30 - ----.-- -1.24 --"---~' 13.00 0.89 1.92 2.79 3.02 2.13 -1.94 0.00 0.13 0.00 0.01 0.13 0.30 0.09 -0.80 -3.56 -11.78 -24.57 -38.30 -54.44 -77.30 -106.74 -142.58 -181.71 -225.25 -274.74 -328.41 -387.68 -451.07 -516.24 - ------------- ----~._--_..- -582.11 27.81 0.00 0.82 0.31 0.13 0.55 0.75 2.36 6.41 1.17 0.53 3.82 4.60 6.15 3.22 3.51 4.80 4.11 4.08 4.38 4.77 .-- -- -------.----- 0.47 _'_n.___-'"---- 0.29 -"~------'-'---'-'-'-- -.-. 3.01 44.89 -648.39 0.00 0.82 0.30 0.09 -0.19 0.29 2.33 6.37 1.17 0.09 3.81 3.98 4.68 2.62 2.56 4.37 4.03 3.68 4.35 4.70 0.38 0.10 - --.-.--.---- 0.000 26.210 ._n_...n. -- --.-.-- 26.210 Walk Rate Right (+) Left (-) ---~-- ..-.---.-- - ----------- --- -.----------- 1.69 Sidetrack No. Page -~ of 3 Field KUPARUK RIVER UNIT --------.-- ---------- "'--"-"-.- .-' .-- - - --_. BHI Rep. DOUG BALLOU --------..- --- Depths Measured From: RKB gJ MSLD SSD Calculation Method MINIMUM CURVATURE Map North to: OTHER Comment TIE IN POINT .--""" -8.49 -0.39 3.09 -1.56 8.90 12.21 .~ 4.88 5.69 4.19 1.50 3.02 0.74 --- _u"--...... - -.u- '--.------ --...-..--. -.--... 1.13 0.38 . -.-.--------- 0.38 - -.-----..--..------ 3.39 SURVEY CALCULATION AND FIELD WORKSHEET = INTEQ Company PHILLIPS ALASKA, INC. Well Name & No. PAD 1 C/117 ---..---.... Target NO -------- -------------- (FT) Target Description --------~-----~ Target Direction - (DO) --'------'---~'----'-- .. ~'._-'------ Job No. 0450-00093 Rig Contractor & No. Nabors AK Drilling - #245E Survey Section Name Definitive Survey ---_.._-.---- WELL DATA Target Coord. NIS Slot Coord. NIS Target Coord. E/W Slot Coord. E/W Build\Walk\DL per: 10Oft~ 30mD 10mD Vert. Sec. Azim. Survey Survey Incl. Hole Tool. Qepth Angle Direction Type (FT) (DO) (DO) 04-JUL-01 MWD 2231.28 47.37 285.31 Date 04-JUL-01 'MWD 2323.35 46.58 04-JUL-01 MWD 2417.13 47.29 04-JUL-01 MWD 2511.37 47.46 04-JUL-01 MWD 2603.12 47.37 04-JUL-01 MWD 2696.54 48.96 04-JUL-01 MWD 2790.89 48.52 04-JUL-01 MWD 2883.73 47.90 04-JUL-01 MWD 2978.36 47.37 04-JUL-01 MWD 3070.60 47.29 04-JUL-O1 MWD 3164.25 46.67 04-JUL-01 MWD 3256.43 46.49 04-JUL-O1 MWD 3350.63 46.41 04-JUL-01 MWD 3445.66 43.77 04"JUL-01 MWD 3539.58 40.08 -----.--.----.- 04-JUL-01 MWD 3633.33 39.46 ------------ 04-JUL-01 MWD 3726.26 37.35 04-JUL-01 MWD 3820.06 34.28 05-JUL-01 MWD 3913.10 31.90 05-JUL-01 MWO 4007.35 28.74 ---- 05-JUL-01 MWD 4100.98 26.02 ----.--...-..- ~_._----- 05-JUL-01 MWD 4194.95 23.55 . ---...--.---.-- 05-JUL-01 MWD 4288.16 21 :27 05-JUL-01 r MWD -- - 4382.-00 - 19.07 285.31 285.66 284.61 283.55 282.50 283.20 282.85 283.55 282.85 282.85 282.50 282.50 282.85 283.55 282.85 283.55 284.26 283.55 284.26 282.15 277 .93 Course Length (FT) 93.73 92.07 93.78 94.24 91.75 93.42 94.35 92.84 94.63 92.24 93.65 92.18 94.20 95.03 93.92 93.75 92.93 93.80 93.04 94.25 93.63 93.97 .. ----.-----....----.----.-- - . 93.21 278.98 .. "--"------'-'"_"._-n- - 279.69 93.84 TVD (FT) 1993.62 2056.44 2120.48 2184.30 2246.38 2308.69 2370.91 2432.78 2496.55 2559.07 2622.96 2686.32 2751.22 2818.31 2888.17 2960.23 3033.05 3109.11 3187.05 3268.40 3351.54 3436.85 ---.----.- SURVEY DATA Vertical Section 714.46 781.55 849.83 918.96 986.40 1055.94 1126.82 1195.98 1265.84 1333.59 1402.02 1468.93 1537.17 1604.43 1667.11 1727.03 1784.70 1839.50 1890.21 1937.71 1980.72 2020.09 -1555.00 799.00 280.73 Grid Correction Magn. Declination Magn. to Map Corr. Total Coordinate Build Rate N(+) I S(-) E(+) I W(-) DL Build (+) (FT) (FT) (Per 100 FT) Drop (-) 63.60 -715.12 0.86 -0.66 81.37 99.67 117.77 134.20 149.88 165.65 181.26 197.22 212.71 227.93 242.63 257.40 272.16 286.48 300.17 313.35 326.52 338.74 350.16 360.03 366.96 -780.04 -846.06 -913.00 -978.52 -1046.33 -1115.48 -1182.92 -1250.99 -1317.02 -1383.77 -1449.10 -1515.75 -1581.41 -1642.49 -1700.88 -1757.08 -1810.36 -1859.66 -1905.84 -1947.75 -1986.50 3523.01 .- "'''._--_._-'-'_-_m'._,__-~~----- .. --- . .'--------'.- -- -'-'-"'~'-~. .~.- - 3611.09 2055.59 '-.....----- -'-'. _.. -.----..¥ ---- 2087.93 372.17 ~.- .-.-..--..----..-- 377.40 -2021.64 -2053.57 0.86 0.80 0.84 0.86 1.90 0.73 0.72 0.78 0.56 0.66 0.34 0.08 2.79 3.96 0.82 2.32 3.30 2.59 3.37 3.08 3.23 2.48 2.36 -0.86 0.76 0.18 -0.10 1.70 -0.47 -0.67 -0.56 -0.09 -0.66 -0.20 -0.08 -2.78 -3.93 -0.66 -2.27 -3.27 -2.56 -3.35 -2.91 -2.63 -2.45 -2.34 0.000 26.210 26.210 Walk Rate Right (+) Left (-) -0.75 0.00 ---.---- Sidetrack No. Page --~..- of 3 Field KUPARUK RIVER UNIT BHI Rep. DOUG BALLOU '-.----- -.--- Depths Measured From: RKB ~ MSLD SSD Calculation Method MINIMUM CURVATURE Map North to: OTHER _._~--- Comment 0.37 -1.11 -1.16 -1.12 0.74 -0.38 0.74 -0.76 0.00 -0.38 0.00 0.37 0.75 -0.75 0.75 0.76 -0.76 0.75 - -...-.---..---..-. "-- -2.25 -4.49 . . .....'''-- -.---- 1.13 0.76 -.- ......."-"'-'---'----- . . . . . . . .-------------=-=-=- SURVEY CALCULATION AND FIELD WORKSHEET Job No. 0450-00093 Sidetrack No. Page 3 of 3 = INTEQ Compan~' .P~:LLlPS _A_l!\S~_~~-------_._----_...._---- . Well Name & No. PAD 1 C/117 -------------- ~.-.- Rig Contractor & No. Nabors AK Drilling-=-~~45E ------ Field KUPARUK RIVER ~~IT -_..-----..----- Survey Section Name Definitive Survey BHI Rep. DOUG BALLOU WELL DATA --.----------'...--------.--..-. -----.- ------ ------------ . ~-.__... _n'____.... ~-_._- (DD) Target Coord. NIS Slot Coord. NIS Target Coord. E/W Slot Coord. E/W Build\Walk\DL per: 10Oft~ 30mO 10mO Vert. Sec. Azim. SURVEY DATA -1555.00 799.00 Grid Correction Magn. Declination 0.000 26.210 26.210 Depths Measured From: RKB ~ MSLO SSO Calculation Method MINIMUM CURVATURE Map North to: OTHER Target TVD - Target Description (Fl) Target Direction 280.73 Magn. to Map Corr. Survey Survey Incl. Hole Course Vertical Total Coordinate Build Rate Walk Rate Date Tool Depth Angle Direction Length TVD Section N(+) I S(-) E(+) I W(-) DL Build (+) Right (+) Comment Type (Fl) (DD) . (DD) (Fl) (Fl) (Fl) (Fl) (Per 100 Fl) Drop (-) Left (-) 05-JUL-01 MWD 4475.11 16.08 283.91 93.11 3699.85 2116.02 383.07 -2081.09 3.49 -3.21 4.53 05-JUL-01 MWD 4566.20 13.27 288.83 91.09 3787.97 2138.97 389.47 -2103.23 3.37 ~3.08 5.40 05-JUL-01 MWD 4657.93 10.20 288.48 91.73 3877.77 2157.45 395.45 -2120.91 3.35 ~3.35 -0.38 05-JUL-01 MWD 4751.79 9.76 287.07 93.86 3970.21 2173.59 400.42 -2136.39 0.54 -0.47 -1.50 05-JUL-01 MWD 4846.09 9.84 284.61 94.30 4063.13 2189.57 404.80 -2151.83 0.45 0.08 -2.61 05-JUL-01 MWD 4925.48 10.11 283.55 79.39 4141.32 2203.30 408.14 -2165.17 0.41 0.34 -1.34 05-JUL-01 MWD 5000.00 10.11 283.55 74.52 4214.68 2216.37 411 .20 -2177.89 0.00 0.00 0.00 Projection to TO ---- "..--.--- --....- ------ ..----- --- -------~~ '. ----------.- ~-~-- .. .----...-...-.---..- - - --.. ---- --.-.--.--------.......----.- -. - - ..- - ~.__. --"-- -----_._-------- --..---"- -- --.-._.~_...- -- -..-.- - -_.~... -..--- - -.. .--.-.---.-.. .-.--..-..., . "~"--'---"-'-------'--'-' -...--- -.-- - -.....-.- ....----. -'..----.----- --.-- -.----- ---- ----.---.-.- ---.-- --'..------- (' ~;Hï@ps\ Jt~,.~ PHilliPS Alaska, Inc. ~/;1~~~ 1 A Subsidiary of PHILLIPS PETROLEUM COMPANY . Post Office Box 100360 Anchorage, Alaska 99510-0360 R. Thomas Phone (907) 265-6830 Fax: (907) 265-6224 July 17, 2002 Ms. Cammy Oechsli Taylor Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 W. 7th Avenue, Suite 100 Anchorage, Alaska 99501 Subject: Application for Sundry Approvals for 1 C-117 Dear Commissioner: Phillips Alaska, Inc. submits the attached Application for Sundry Approvals for 1 C-117 . We are requesting approval to change the approved program for this well. If you have any questions regarding this matter, please contact Vem Coyner at 265-6074. Sincerely, .\.~\~. R. Thomas Kuparuk Team Leader PAl Drilling -:::::.::::::.. RT/skad 6C- r) iî\, E~ r: t JUL 222002 .Ataska Oil & Gm11ffi¡SSIOn Anchorage STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of request: Abandon - Suspend - Alter casing - Repair wel,V..:... Change approved program _X / 2. Name of Operator Phillips Alaska, Inc. 3. Address P. O. Box 100360 Anchorage, AK 99510-0360 4. Location of well at surface 1555' FNL, 799' FWL, Sec. 12, T11 N, R10E, UM At top of productive interval 1151' FNL, 1338' FEL, Sec. 11, T11N, R10E, UM At effective depth 1150'FNL, 1343'FEL,Sec. 11,T11N, R10E,UM At total depth 1150'FNL, 1343'FEL,Sec. 11,T11N, R10E, UM 12. Present well condition summary Total depth: measured true vertical Effective depth: 6620 6029 6620 6029 measured true vertical Casing Conductor Surface Size 16" Length 117' 4858' 8.625" X 7.625" Perforation depth: measured No Perforations true vertical No Perforations Tubing (size, grade, and measured depth No Tubing Run Packers & SSSV (type & measured depth) No Packers or SSSV"s 13. Attachments Description summary of proposal f-XX 14. Estimated date for commencing operation I July 26, 2002 16. If proposal was verbally approved Operational shutdown - Plugging - Pull tubing - 5. Type of Well: Development - Exploratory Stratigraphic 7 Service _X (asp's: 561931, 5968597) (as proposed) (as proposed) (as proposed) feet feet feet feet Plugs (measured) Junk (measured) Cemented 9 cu yds High Early 530 sx AS III, 360 sx Class G ( iN 6Æ- Ms 7/ L2-10 L Î/w/~ 7/ZZS Re-enter suspended well - Time extension - Stimulate - Variance - Periorate - 6. Datum elevation (DF or KB feet) RKB 41.2 feet above pad, 102' above MSL 7. Unit or Property name Other - Kuparuk River Unit 8. Well number 1C-117 9. Permit number / approval number 201-121/301-189 10. API number 50-029-23027 -00 11. Field I Pool Kuparuk River Field/W est Sak Oil Pool Measured Depth 158' 4979' True vertical Depth 158' 4178' L 1('''' E"~ I \/E"'" l: t., """ ;¡ 1""" II II t) ~j LI.Jn0? .........:.... (.1.._' .."._^ Alaska &: Detailed operations program 15. Status of well classification as: BOP sketch - Oil- Name of approver Date approved Service _XX 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~~ ,~ Randy Thomas "\c.- - La. ,..( c. r- Title: Drilling enginecring Suporvioor Gas- Suspended - Questions? Call Vern Coyner 265-6074 7/t '/'ð7 Date Prepared by Sharon Allsup-Drake FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so represenlaJive may witness Plug integrity - P9P Test ~ Location clearance - j I 1 Mechanical Integrity Test JS. Subsequent form required 10- ,0 T~s t- B.?() E -to ~SOO rsG. M.J::\ ""7""': I"tJ "no..... to> ¡ ~ ~...A:¡'...... . 1. ~ /h. ' . Approved by order of the Commission Onglnal Signed By Commissioner Date ~ f I ð ~ Cammy OecnSII 1 aylqr I Form 10-403 Rev 06/15/88 . ORIGINAL Approval no. 2 .., ç... 302.. ~o SUBMIT IN TRIPLICATE 1C -117 Completion Procedure Well Geometrv (see diaaram): Conductor 16" 62.58# H-40 GL - 117' Surface Casing 7-5/8" 29.7# L-80 RKB - 4988' MD Wellhead is VETCO "Horizontal" wI 11" (5M) Tubing Head flange. Swab Valve: there is a 7-1/16" (5M), full bore valve on the wellhead Baker "ECP" set at 4602.5' - 4635.7' MD (Rig Talley) (4610' - 4642' Schlumberger) Maximum angle is 49° at 2697' MD Maximum Dog Leg is 6.4°/100' at 746' MD BH P is estimated to be .$. 1600 psi Kill Weight Brine = Seawater Perforations (Pre-Rig): 4620'-4640',4656'-4672',4678'-4708',4718'-4750' MD 3841 '-3860', 3876'-3892', 3897'-3927', 3937-3968' TVD Perforations (On the Rig): 4508'-4546',4572'-4592' MD 3732'-3768',3794'-3813' TVD Pre-ria Work: (Test all surface equipment with diesel) 1. Drift and Tag: done 10105/209"1. 2. USIT log: done 10106/2001. 3. RU SLU. Run a 6.625" drift to :!: 4770' to check for ice, fill etc. RD SLU. 4. RU E-Line, W/L BOP's, Lubricator and Packoff on the swab valve. Test to 1500 psi with diesel. Perforate the West Sak "A" with 3-3/8" guns, 4 spf as follows: West Sak "A" 4620' - 4640' MD 4656' - 4672' MD 4678' - 4708' MD 4718' - 4750' MD Keep the hole full with heated diesel (unless the fill rate gets too high). 5. Run a 6.625" gage ring and junk basket to :!: 4620' MD. Set a Baker "FB-1" packer with tail pipe (incl pump out plug) in the casing pup joint above the ECP. Set the top of the packer at 4604' MD (as per the CCUGR on the USIT log 10106/01). Test the packer to 1000 psi. Secure the well. RD E-Line. The packer assembly is as follows (top-down): FB-1 packer (:!: 4'),5-1/2" sub (:!: 4'), X/O (:!: 1 '), 2-7/8" pup jnt (:!: 4'), DS nipple (:!: 1 '), WLEG wI pump out plug (:!: 1 '). Estimated total length is 15' plus the setting tools, CCL, etc. 7/18/02 VMC Version 1 RiQ Work: 1. MIRU Nabors Rig #245 from 1C-104 with 5800' of 4" drill pipe in the derrick. Check the well to be sure it's dead. Pick up a 7-5/8" storm packer. Run it through the swab valve and set it ,/ in the casing. Test the storm packer to 1000 psi. ND the swab valve and NU BOP's. Set a test plug in th, wellhead and mark the landing joint at the rotary table. Test the BOP's to 250/3500 psi. Pull the test plug. Measure the length from the rotary table to the bottom of the test plug for future use. Retrieve the storm packer. Minimum 24 hours notification to AOGCC is reauired prior to nipplinq up and testinQ 2. Pick up a 6-3/4" bit, casing scraper and (6) 4-3/4" DC's. RIH on 4" DP to the FB-1 packer at :!: 4600' MD and displace the diesel freeze protect fluid (113 bbl) to a tank and circulate the casing clean with heated seawater (~130° F) to ''warm up" the wellbore. POOH and rack back the 4" drill pipe and the BHA for use on the next well. 3. RU Schlumberger with a riser and pack off . Test to 1000 psi. Perforate the West Sak "B" / and "D" with 3-3/8" guns, 4 spf as follows: West Sak B: 4572' - 4592' MD West Sak D: 4508' - 4546' MD (3792' - 3813' TVD) (3728' - 3764' TV D) 4. Keep the hole full (if possible) and/or keep track of the fluid additions (bbl/hr) and fluid level between perforating runs. RD E-Line. 6. RIH with the locator seal assembly for the FB-1 packer, the straddle packer assembly and the new 3-1/2", 9.3#, L-80, EUE-Mod tubing. Space out will be difficult but critical for the S- 3 packer. The S-3 must be set between 4546' and 4560' MD. There is a casing collar at 4657'. Do not set a packer element across a casing collar. RIH (bottom - up) as follows: 6' 6' 6' 6' 6' 6' 6' 6' 5' 6' 6' 6' 6' 6' 6' 6' 6' 30' 6' 5' 7/18/02 Baker Locator 3-1/2", 9.3#, L-80, EUE-Mod pup joint 3-1/2", 9.3#, L-80, EUE-Mod pup joint Baker, CMU (2.750" Bore) wI RHC sleeve 3-1/2", 9.3#, L-80, EUE-Mod pup joint 3-1/2", 9.3#, L-80, EUE-Mod pup joint 3-1/2" x 1-1/2" Cameo GLM with DGLV 3-1/2",9.3#, L-80, EUE-Mod pup joint 3-1/2", 9.3#, L-80, EUE-Mod pup joint Baker, 5-3 Packer (Sets at 2500 psi) 3-1/2",9.3#, L-80, EUE-Mod pup joint 3-1/2", 9.3#, L-80, EUE-Mod pup joint Baker, CMU (2.813" Bore) 3-1/2", 9.3#, L-80, EUE-Mod pup joint 3-1/2",9.3#, L-80, EUE-Mod pup joint 3-1/2", 9.3#, L-80, EUE-Mod pup joint 3-1/2" x 1-1/2", Cameo GLM with DGLV 3-1/2", 9.3#, L-80, EUE-Mod pup joint 3-1/2",9.3#, L-80, EUE-Mod tubing joint 3-1/2",9.3#, L-80, EUE-Mod pup joint Baker, Premier Packer (Sets at 4000 psi) (4604' MD) (4585' MD) (4567' MD) (4550' MD) (4532' MD) (4508' MD) (4461' MD) 2 1C-117, Version 1 1 ' 6' 30' 6' 6' 6' :!: 3900' 6' l' 6' :!: 470' ( ( X-O 3-1/2", 9.3#, L-80, EUE-Mod pup joint 3.1/2",9.3#, L-80, EUE-Mod Tubing Joint 3-1/2",9.3#, L-80, EUE-Mod pup joint 3-1/2 x 1-1/2"", Cameo GLM with RP Shear valve (2500 psi) 3-1/2", 9.3#, L-80, EUE-Mod pup joint 3-1/2",9.3#, L-80, EUE-Mod tubing 3-1/2",9.3#, L-80, EUE-Mod pup joint 3-1/2", Cameo "DS" nipple (ID = 2.875") 3-1/2", 9.3#, L-80, EUE-Mod pup joint (special drift) 3-1/2", 9.3#, L-80, EUE-Mod tubing (special drift) (4412' MD) (500' MD) Note: - Drift all the 3-1/2" tubing below 500' to 2.867" except the CMU's - Drift all the 3-1/2" tubing above 500' to 2.875" - Verify that all drifts are accounted for prior to RIH. - Record OD's and ID's of all auxiliary equipment on tubing detail. - Drain BOP stack before landing tubing. 6. Carefully tag the FB-1 packer. PU and circulate the well with heated seawater (~1300) (if circulation is possible) to warm up the tubing. Space out the tubing string such that the seal nipple is stung into the FB-1 packer but the GBH-22 locator is :t 2' above the FB-1 PKR. This allows for downward movement when setting the other two packers. Use the measurement from step #1 to help space out correctly. Install the tubing hanger. 7. After the tubing is warmed up and the space out is correct, sting into the FB-1 packer, land the tubing hanger and RILD's. Pressure up on the tubing and blow the pump out plug below the FB-1 packer. Drop the RHC ball/rod. 8. Pressure up on the tubing and set the S-3 packer at :t 2500 psi. Increase the pressure to :!:. 4000 psi and set the Premier Packer. Hold the 4000 psi on the tubing for 15 minutes and then bleed it off to 1000 psi. Test the annulus and the Premier packer to 2500 psi for 15 minutes. Bleed off the annulus and then bleed off the tubing. Flow check. 9. Lay down the landing joint and install BPV. ND BOP's and NU tree. Pull the BPV. Install test plug. Test tree to 250 and 3500 psi. Pull the test plug. / 10. Pressure up the tubing to 1000 psi. Test the IA to 2500 psi for 30 minutes on chart. Bleed off the tubing and pressure up the IA further (if necessary) to shear the RP shear valve. Circulate the tubing and IA with diesel to freeze protect. Set a BPV & VR plug. 11. Move the rig to 1 C-127 with the 4" drill pipe in the derrick. Post-ri~ Work: 1. 2. 3. 4. 5. 6. Pull the BPV and VR plug. RU Slickline. Replace the RP shear valve with a DGLV. Retrieve the RHC sleeve, ball/rod. Connect flow lines, etc. Swab Fluid samples as directed. Set the well house. 7/18/02 3 1C-117, Version 1 ( Well # 1C-117, AFE #AK0172 West Sak Planned Completion Schematic 16" Conductor @ +/- 158' MD ~ .~ 7 -5/8" 29.7# L-80 Casing ! . I t¡ lj' 0 ~ - tf 5"ftJ I I t,fS77, n- LIt; ~ z L/ b '¿,¡() , - ~ ~ ~ ~ I I t{ 1~ 0 I I I j PHilliPS Alaska, Inc. A Subsidiary of PHilLIPS PETROLEUM COMPANY 500' of 3-%" EUE-Mod Tubing & Pups I 2.875" Cameo D nipple with 3-%" EUE-Mod and ~ Ft. Pups installed on top and bottom xx Joints of 3-%" EUE-Mod Tubing Cameo 3-1/2" X 1" Gas Lift Mandrel 1 Joint of 3-%" EUE-Mod Tubing 7-5/8" Premier Packer with 3-%" EUE-Mod Box '-I~~/' x pin down 3-%" EUE-Mod Tubing Pups Cameo 3-1/2" X 1" Gas Lift Mandrel 3-%" EUE-Mod Tubing Pups Baker 3-%" CMU Sliding Sleeve. profile with 3-1/2" EUE-Mod 3-%" EUE-Mod Tubing Pups 2.81 Cameo 7-5/8" S-3 with 3-%" EUE-Mod Box x pin 'iSS 0 I 3-%" EUE-Mod Tubing Pups Cameo 3-1/2" X 1" Gas Lift Mandrel 3-%" EUE-Mod Tubing Pups Baker 3-%" CMU Sliding Sleeve. 2.75 Cameo profile with 3-1/2" EUE-Mod 3-1/2" EUE-Mod Tubing Pups Baker, 7 Ft 80-40 Locator Seal Assembly Baker 7-5/8" FB-1 Packer '-I Co rp!.{ , 5- %" x 4' Pup Joint + X-Q TD 9-7/8" Hole: Plug Back TD 4,979' MD /4,178' TVD @ +/- 4,897' MD 1C-117 Completion Schematic Prepared by Jose /guaz Checked by Skip Coyner a 0 )- I d } Phillips Alaska, Inc. Pad IC 117 slot #117 Kuparuk River Unit North Slope, Alaska SUR V E Y LIS TIN G by Baker Hughes INTEQ Your ref: MWD <0-5000'> Our ref: svy6556 License: Date printed: 1-Aug-2001 Date created: 3-Jul-2001 Last revised: 13-Jul-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 29.879,w149 29 55.802 Slot Grid coordinates are N 5968679.822, E 561805.176 Slot local coordinates are 1555.00 S 799.00 E Projection type: alaska - Zone 4, Spheroid: Clarke - 1866 Reference North is True North Phillips Alaska, Inc. SURVEY LI8TING Page 1 Pad 1C,117 Your ref: MWD <0-5000'> Kuparuk River Unit, North 8lope, Alaska Last revised: 13-Jul-200l Measured Inclin Azimuth True Vert RECTANGULAR Dogleg Vert G RID COORD8 Depth Degrees Degrees Depth COO R DIN ATE S Deg/l00ft 8ect Easting Northing 0.00 0.00 0.00 0.00 O.OON O.OOE 0.00 0.00 561805.18 5968679.82 158.00 0.00 0.00 158.00 O.OON O.OOE 0.00 0.00 561805.18 5968679.82 200.90 0.35 2.30 200.90 0.13N O.OlE 0.82 0.02 561805.18 5968679.95 292.96 0.62 13.55 292.96 0.90N O.13E 0.31 0.04 561805.30 5968680.72 382.84 0.70 5.82 382.83 1.92N 0.30E 0.13 0.06 561805.46 5968681.74 473.14 0.53 320.47 473.13 2.79N 0.09E 0.55 0.43 561805.25 5968682.61 564.12 0.79 261 . 7 6 564.10 3.02N 0.80W 0.75 1. 34 561804.36 5968682.84 654.66 2.90 249.45 654.59 2.13N 3.56W 2.36 3.89 561801.60 5968681.92 745.70 8.70 241.72 745.13 1.958 11.79W 6.41 11.22 561793.41 5968677.78 836.34 9.76 241.37 834.59 8.888 24. 57W 1.17 22.48 561780.69 5968670.75 927.14 9.84 244.18 924.07 15.948 38.31W 0.53 34.67 561767.01 5968663.57 1017.26 13.27 242.77 1012.35 24.038 54 . 44W 3.82 49.01 561750.94 5968655.35 1112.12 17.05 251. 21 1103.90 33.508 77 . 30W 4.60 69.71 561728.16 5968645.70 1204.26 21. 36 262.46 1190.92 40.068 106. 74W 6.15 97.42 561698.77 5968638.90 1298.00 23.82 267.03 1277 . 47 43.288 142.58W 3.22 132.03 561662.97 5968635.39 1390.66 26.19 272.30 13 61. 45 43.438 181. 71W 3.51 170.45 561623.85 5968634.92 1483.10 30.23 276.17 1442.90 40.108 225.25W 4.80 213.85 561580.28 5968637.89 1576.90 34.01 277 .58 1522.33 34.108 274.75W 4.11 263.60 561530.74 5968643.49 1670.00 37.44 280.39 1597.90 25.568 328.41W 4.08 317.91 561477.02 5968651. 59 1764.86 41.57 281.09 1671.08 14.308 387.68W 4.38 378.24 561417.66 5968662.37 1858.44 45.97 282.15 1738.64 1. 258 451.07W 4.77 442.95 561354.18 5968674.91 1950.96 46.32 282.50 1802.74 13 . OON 516.24W 0.47 509.64 561288.89 5968688.62 2044.24 46.41 282.85 1867 .11 27. 81N 582.11W 0.29 577.11 561222.91 5968702.90 2137.55 47.99 286.01 1930.52 44. 89N 648.39W 3.01 645.42 561156.50 5968719.43 2231.28 47.37 285.31 1993.62 63.60N 715. 12W 0.86 714.46 561089.63 5968737.60 2323.35 46.58 285.31 2056.44 81. 37N 780.04W 0.86 781.55 561024.58 5968754.84 2417.13 47.29 285.66 2120.48 99. 66N 846.07W 0.80 849.83 560958.41 5968772.59 2511.37 47.46 284.61 2184.30 117.77N 913.00W 0.84 918.97 560891.34 5968790.15 2603.12 47.37 283.55 2246.38 134. 20N 978.52W 0.86 986.40 560825.69 5968806.05 2696.54 48.96 282.50 2308.69 149.88N 1046.33W 1.90 1055.95 560757.76 5968821.18 2790.89 48.52 283.20 2370.91 165.65N 1115.48W 0.73 1126.82 560688.49 5968836.38 2883.73 47.90 282.85 2432.78 181.25N 1182.92W 0.72 1195.99 560620.93 5968851.44 2978.36 47.37 283.55 2496.55 197.22N 1250.99W 0.78 1265.84 560552.74 5968866.84 3070.60 47.29 282.85 2559.07 212. 70N 1317 . 02W 0.56 1333.60 560486.60 5968881.79 3164.25 46.67 282.85 2622.96 227.93N 1383. 77W 0.66 1402. 02 560419.73 5968896.48 3256.43 46.49 282.50 2686.32 242.62N 1449.10W 0.34 1468.93 560354.29 5968910.63 3350.63 46.41 282.50 2751. 22 257. 40N 1515.75W 0.08 1537.17 560287.53 5968924.87 3445.66 43.77 282.85 2818.31 272.16N 1581.41W 2.79 1604.43 560221.76 5968939.09 3539.58 40.08 283.55 2888.17 286.47N 1642.50W 3.96 1667.11 560160.56 5968952.91 3633.33 39.46 282.85 2960.23 300.17N 1700.88W 0.82 1727.03 560102.07 5968966.13 3726.26 37.35 283.55 3033.05 313.35N 1757.08W 2.32 1784.70 560045.77 5968978.84 3820.06 34.28 284.26 3109.11 326.52N 1810.36W 3.30 1839.50 559992.40 5968991. 59 3913.10 31.90 283.55 3187.05 338.74N 1859.66W 2.59 1890.21 559943.00 5969003.40 4007.35 28.74 284.26 3268.40 350.16N 1905. 84W 3.37 1937.71 559896.73 5969014.44 4100.98 26.02 282.15 3351.54 360.03N 1947.75W 3.08 1980.72 559854.75 5969023.97 4194.95 23.55 277 . 93 3436.85 366.96N 1986.50W 3.23 2020.09 559815.95 5969030.58 4288.16 21. 27 278.98 3523.01 372.16N 2021. 64W 2.48 2055.59 559780.77 5969035.50 4382.00 19.07 279.69 3611.09 377.40N 2053.57W 2.36 2087.93 559748.80 5969040.48 4475.11 16.08 283.91 3699.85 383.06N 2081.09W 3.49 2116.02 559721.24 5969045.92 4566.20 13.27 288.83 3787.97 389.47N 2103.24W 3.37 2138.97 559699.05 5969052.15 All data in feet unless otherwise stated. Calculation uses minimum curvature method. Coordinates from slot #117 and TVD from RKB 102' (N-245E) (102.00 Ft above mean sea level). Bottom hole distance is 2216.37 on azimuth 280.69 degrees from wellhead. Vertical section is from wellhead on azimuth 280.73 degrees. Grid is alaska - Zone 4. Grid coordinates in FEET and computed using the Clarke - 1866 spheroid Presented by Baker Hughes INTEQ Phillips Alaska, Inc. Pad lC,117 Kuparuk River Unit,North Slope, Alaska SURVEY LISTING Page 2 Your ref: MWD <0-5000'> Last revised: 13-Jul-2001 Measured Inclin Azimuth True Vert RECTANGULAR Dogleg Vert G RID COORDS Depth Degrees Degrees Depth COO R DIN ATE S Deg/100ft Sect Easting Northing 4657.93 10.20 288.48 3877 .77 395.45N 2120.91W 3.35 2157.45 559681.33 5969057.98 4751.79 9.76 287.07 3970.21 400.42N 2136. 39W 0.54 2173.59 559665.80 5969062.82 4846.09 9.84 284.61 4063.13 404.79N 2151. 83W 0.45 2189.57 559650.33 5969067.07 4925.48 10.11 283.55 4141.32 408.14N 2165.17W 0.41 2203.30 559636.97 5969070.31 5000.00 10.11 283.55 4214.68 411.20N 2177 . 89W 0.00 2216.37 559624.23 5969073.27 All data in feet unless otherwise stated. Calculation uses minimum curvature method. Coordinates from slot #117 and TVD from RKB 102' (N-245E) (102.00 Ft above mean sea level). Bottom hole distance is 2216.37 on azimuth 280.69 degrees from wellhead. Vertical section is from wellhead on azimuth 280.73 degrees. Grid is alaska - Zone 4. Grid coordinates in FEET and computed using the Clarke - 1866 spheroid Presented by Baker Hughes INTEQ Phillips Alaska, Inc. Pad lC,117 Kuparuk River Unit, North Slope, Alaska SURVEY LISTING Page 3 Your ref: MWD <0-5000'> Last revised: 13-Jul-2001 Comments in well path ---------- ---------- MD TVD Rectangular Coords. Comnent ----------------------------------------------------------------------------------------------------------- 5000.00 4214.68 411. 20N 2177.8gw PROJECTION 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.OOE 4988.00 4202.87 410.71N 2175.84W 7 5/8" Casing Targets associated with this wellpath ------------------ ------------------- Target name Geographic Location T.V.D. Rectangular Coordinates Revised ----------------------------------------------------------------------------------------------------------- WS 1C H4 (5-DEC-00) 559661.000,5969068.000,0.0000 3860.00 405.64N 2141.15W 8-Jan-2001 SC~._"18P Schlumberger Technology Corporation, by and through is Geoquest Division 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 A TTN: Sherrie Well 1 C-117.;}ð 1:-/~1 1 C-119 dO}- ':30, 2K-27 ~O/-1foC 2N-302~ D I-lIS .3K20 Job # 21439 21438 21440 21437 :}ot~~ Log Description Date USIT ~ SCMT V SCMT / SCMT "/ '56MT 10/06/01 09/20/01 10/03/01 09/01/01 ~07:/Ø')O/01 SIGNED:~(~ DATE: NO. 1566 10/24/2001 Company: Alaska Oil & Gas Cons Comm AUn: Lisa Weepie 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: BL Sepia Kuparuk CD Color 1 1 1 1 ~ RECEIVED OCT 30 2001 Please sign and return one copy of this transmittal to Sherrie at the above address or fax to (907) 561-8317. Æ~Øœr&'Gas Cons. Commission Anchorage tPHIWPS'~ ~ ~~st~~J~~I~~~~~~J~~~ ~ Post Office Box 100360 Anchorage, Alaska 99510-0360 Randy Thomas Phone(907)265~O Fax: (907) 265-1535 July 6, 2001 Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 (907) 279-1433 Re: Application for Sundry Approvals, West Sak Dual Purpose WelllC-117. Permit to Drill # 201-121 API # 50-029-23027-00 Dear Commissioners: Further to a change in drilling procedure authorized by Tom Maunder earlier today, Phillips Alaska, Inc. hereby requests a Sundry Approval for a well in the West Sak Oil Pool, designated #lC-117. Please find attached for the review of the Commission Form 10-403, and two attachments: -a copy of the e-mail from Tom Maunder, authorizing the change in procedure. -a copy of the Proposed Drilling Program which was submitted with the Application for Permit to Drill, with approved changes shown. If you have any questions or require any further information, please contact me at 265-6830 or Steve McKeever at 265-6826. Sincere.l.y,. ~... \i:?f. . ;Il,a ~Á ÓCW~/~l,.-- .~.I.. Randy Thomas GKA Drilling Team Leader Ç¡ R~n~ 'jl; d¡/VlC..L~~ RECEIVED JUL 0 6 2001 Alaska Oil & Gas Cons. Commission Anchorage ORIGINAL . , ( ~h)- (g1 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS Name of approver Tom Maunder 7/06/01 Date approved Service- i 17. I herebY. certify that the.., f~ng Is true. and correct to the best of my knowledge. j . 3l\1t(~ ~ . Signed. ;!/.'. /J .-r-I. Title: GKA Drilling Team Leader Randy Thomas Î 7 ,< , ¡I¡ crN~ FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness Plug integrity -- BOP Test - Location clearance- Mechanical Integrity Test - Subsequent form required 10- 4,0'\ ORIGINAl. SIGNEt) BY - ---App_~~'{~-~-~y--~~~t~~- ?_f t~-~-ç~!Ð_~[~~!~!I----------------------------------~:--~ '--~~~-~----------------------_m___----------------~~_'!I_~!~ si o_~_~r --------------------------Q~!~-- 1. Type of request Abandon - Suspend - Alter casing - Repair well - Change approved program X ¡ , 2. Name of Operator : Phillips Alaska, Inc. t ii, 3. Address P. O. Box 100360 Anchorage, AK 99510-0360 , 4. Location of well at surface 1555' FNL, 799' FWL, Section 12, T11 N, R10E, UM At top of productive interval 1151' FNL, 1338' FEL, Section 11, T11N, R10E, UM At effective depth 1150' FNL, 1343' FEL, Section 11, T11 N, R10E, UM At total depth 1150' FNL, 1343' FEL, Section 11, T11 N, R10E, UM 12. Present well condition summar Total depth: measured true vertical Effective depth: 6620 6029 6620 6029 measured true vertical Casing Conductor Length 117' Size 16" Surface proposed 4858' 8.625" X 7.625" Perforation depth: measured No Perforations true vertical No Perforations ITUblng (size, grade, and measured depth No Tubing Run I Packers & SSSV (type & measured depth) No Packers or sssV"s 1 13. Attachments Description summary of proposal- 14. Estimated date for commencing operation July 7, 2001 16. If proposal was verbally approved Form 10-403 Rev 06/15/88. Operational shutdown - Plugging - Pull tubing - 5. Type of Well: Development X Exploratory - Stratigraphic - Re-enter suspended well - Time extension - Stimulate - Variance - Perforate - 6. Datum elevation (DF or KB feet) RKB 41.2 feet above pad, 102' above MSL 7. Unit or Property name Other - Service - Kuparuk River Unit 8. Well number 1C-117 9. Permit number / approval number 201-121 10. API number 50-029-23027 -00 11. Field / Pool Kuparuk River Field I West Sak Oil Pool feet feet feet feet Plugs (measured) Junk (measured) Cemented 9 cu. Yds High Early Measured Depth 158' True vertical Depth 158' 530 sx AS III, 360 sx Class G 4979' 4178' RECEIVED JUL 0 6 2001 Alaska Oil & G as Coos C '. AnChorag~ ommlSS/OO Detailed operations progra~ 15. Status of well classification as: BOP sketch - Oil- Gas- Suspended! Questions? Call Steve McKeever 265-6826 Date Prepared by Steve McKeever I Approval n°2Dt -l fq n1 i~jJl- / ORIGINAL SUBMIT IN TRIPLICATE (~ Tom Maunder dom_maunder@admin.state.ak.us> 07/06/01 02:00 PM To: Steve McKeever/PPCO@Phillips cc: Subject: [Fwd: [Fwd: Request for Procedural Change on 1 C-127]] Steve, Here is the note that Jane sent to Mark. This note confirms approval to change the procedure to cleanout using only a riser. In the procedure you attached to your note, you caution the rig that if there is any doubt as to the isolation achieved with the cement job that it may be necessary to use a BOP. This is a sound caution. Good luck. Tom Maunder, PE Sr. Petroleum Engineer AOGCC ----- Message from Jane Williamson <Jane_Williamson@admin.state.ak.us> on Sat, 30 Jun 2001 21 :08:29 -0800 ----- To: Thomas E Maunder <tom_maunder@ admin. state. ak. us> Subject: [Fwd: Request for Procedural Change on 1 C-127] ----- Message from Jane Williamson <Jane_Williamson@admin.state.ak.us> on Fri, 29 Jun 2001 15:16:50 -0800 ----- To: Mark A Chambers <mchambe2@ppco.com> cc: "AOGCC Prudhoe Bay (E-mail)..<aogcc_prudhoe_bay@admin.state.ak.us>. Julie M Heusser <julie _heusser@ admin. state. ak. us> Subject: Re: Request for Procedural Change on lC-127 Mark, I have talked with John Crisp. The only problem he had wi this was swapping over to seawater after CIO without testing casing. If you have to do a top job through the Tam Collar, you will have to N/U BOP's to test casing. Assuming that is not the case, you have approval to proceed. You do need to follow up on this well with a 403 sundry for changes in planned drilling operations per 20AAC25.015 (c) (2) . For remaining wells for which we have 401s here (lC-111 and 1C-117), it would be easiest if ammend your 401 application per (20AAC25.005(c) (1). You do not have to send the $100 fee for this change. Good luck with your program, Mark, and thank you for the call. Jane Williamson Petroleum Engineer > Jane: > > > > > > Under the Proposed Drilling Program section (13) of the 1C-127 Approved Permit to Drill it states that after cementing the 8-5/8" x 7-5/8" tapered casing string and inflating the ECP we intend to nipple down the 21-1/4" diverter, nipple up the dual completion wellhead and 13-5/8" 5000 psi BOP and test to 5000 psi. A cleanout assembly would then be picked up and the > well would be cleaned out to +/- 50' below the proposed bottom A-Sand > perforation. Following the cleanout the well would be displaced to > seawater, freeze protected, the BOPE would be nippled down, a 7-1/16" valve > would be installed on top of the wellhead and Nabors 245e would rig down > and move off the well. > > Nabors 245e will move back over the well at a later date to perforate and ~ > install the dual completion. > > Since we do not intend to drill out the shoe or perforate the well at this > time, we would like to change our Proposed Drilling Plan to the following: > > 1. Run and cement the 8-5/8" x 7-5/8" tapered casing string to surface > (cement to be displaced w/ Kill Weight Mud) . > 2. Inflate ECP > 3. Bleed off pressure and confirm floats are holding. > 4. Nipple down 21-1/4" diverter. > 5. Nipple up Vetco Gray 11" 5000 Tubing Head and Flow Riser. > 6. Run in hole with cleanout assembly and cleanout well to +/- 50' below > proposed bottom A-Sand perforation. > 7. Displace well to seawater (confirm well is dead) and freeze protect. > 8. Nipple down riser. > 9. Nipple up 11" 5000 psi flange and 7-1/16" valve. > 10. Rig down Nabors 245e and move off well. > > This revision eliminates the nipple up / nipple down of the 13-5/8" BOPE. > This same request was recently approved and performed on well 1C-123 > without incident. > > If you have > > Thank you, > > > > > any questions please feel free to give me a call. Mark Chambers Drilling Engineer 265-1319 Work 240-5868 Cell tom_maunder.vcf Þ( :ltion for Sundry Permitl, Well 1 C-117 Revision No.O Saved: 6-Jul-01 Proposed Drilling Program Requirements of 20 AAC 25.005 (c)(13) An application for a Permit to Drill must be accompanied by each of the following item~ except for an item already on file with the commission and identified in the application: The proposed drilling program is listed below. 1. Excavate cellar, install cellar box, set and cement 16". Weld landing ring on conductor. 2. MIRU Nabors Rig 245e. Install diverter & function test same. 3. Spud and directionally drill 9-7/8" hole to desired target through West Sak interval to the base of the A- Sand. Run MWD I LWD I PWD logging tools in drill string as required for directional monitoring and formation data gathering. 4. Perform wiper trip. Circulate and condition hole to run casing. Run hole opener if required. POOH. 5. Run and cement 8-5/8" x 7-5/8" tapered casing string to surface. Displace cement with mud and perform stage job or top job if required. Note: ECP to be inflated as part of primary cement job. Note: 7-5/8" Port Collar to be installed @ +1- 1,000' TVD. 6.Nipplc down 21--1/1f' divertcr, nipple up dUQ completion well head and 13 5/8 x 5000 psi blowout prcventcr stack t:md test to 5,000 psi. 6. Nipple down 21-1/4" diverter, nipple up dual completion well head and flow riser. 7. RIH with drill bit and cleanout well to 50' below bottom A-Sand Perf. 8. Displace well to seawater and POOH. While POOH stop and displace top 2000' with diesel to freeze protect. Continue POOH backfilling wI seawater. 9.Nipplc down BOPE Qnd install 7..1/16" x 5,000 psi full bore valve atopwcHhcad. 9. Nipple down flow riser and install 7-1/16" x 5,000 psi full bore valve atop wellhead. 10. RD Nabors Rig 245e and move off location. 11. RU E-Line Unit. Complete cement bond log. RD E-line unit, 12. MIRU Nabors Rig 245e. 13. ND full bore valve, nipple up 5,000 psi BOPE and test to 5,000 psi. 14. Pressure casing to 3,000 psi for 30 minutes. 15. RIH with drill bit and casing scrapers. 16. Displace well to filtered brine and perform caustic wash and pickle. POOH. 17. RU E-line unit and RIH with 4-1/2" guns. Perforate A2 I A3-Sands. RD E-Line unit. 18. RIH with workstring (open ended) and perform A-Sand frac. 7/6/01 Sundry Application A(' tion for Sundry Permitl, We1l1C-117 Revision No.O Saved: 6-Jul-01 19. RIH and clean out frac sand and perforation debris. POOH. 20. PU tubing conveyed perforating guns. RIH and re-perforate the A-Sand as required. POOH. 21. RIH and set bridge plug +/- 15' below bottom perforation. POOH. 22. PU gravel pack assembly. RIH and tag top of bridge plug. Set packer and perform gravel pack of A sand as designed. POOH. 23. RU slick line unit. RIH and set nipple reducer in XN Nipple below gravel pack packer. RD slick line unit. 24. RIH, set packer plug and spot sand on top of packer to catch perforation debris. POOH. 25. RU E-line unit and RIH with 4-1/2" guns. Perforate B / D-Sands. RD E-Line Unit. 26. RIH, circulate sand off top of packer and retrieve packer plug. POOH. 27. PU and RIH with dual string completion assembly as designed. 28. RIH to just above top of gravel pack packer. 29. RU and circulate into top of SBE. PU and perform space out. With seal assembly unstung from SBE, freeze protect the tubing x 7-5/8" annulus and the 2-3/8" x 3-1/2" tubing strings. Land tubing. 30. RU Slick Line Unit. RIH and set plug in XN Nipple below gravel pack packer. 31. Set completion packers as per Service Representative on location. 32. Retrieve plug from XN Nipple. RD slick line unit. 33. ND BOPE, NU Dual Tree and pressure test. 34. RD Nabors 245e and move off. After the rig has moved off a jet pump will be landed in a nipple in the 3-1/2" tubing string and tied back to surface with 2" coil tubing. 'A' sand production will occur up the 2" coil by 3-1/2" tubing annulus when. jet pump power fluid is pumped down the 2" coil tubing. 7/6/01 Sundry Application ~7~~¡ ( : f ~~!Æ~~~~!Æ / / TONY KNOWLES, GOVERNOR AlASKA. OIL AlVD GAS CONSERVATION COMMISSION 333 W. "JTH AVENUE. SUITE 100 ANCHORAGE. ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Randy Thomas GKA Drilling Team Leader Phillips Alaska Inc. PO Box 100360 Anchorage AK 99510 Re: Kuparuk River Unit 1 C-11 7 Phillips Alaska Inc. Permit No: 201-121 Sur Loc: 1555' FNL, 799' FWL,SEC 12, T11N, RIOE, UM Btmhole Loc. 1150' FNL, 1343' FEL, SEC. 11, TI1N, R10E, UM Dear Mr. Thomas: Enclosed is the approved application for permit to drill the above referenced well. The permit to drill does not exempt you from obtaining additional permits required by law ITom other governmental agencies, and. does not authorize conducting drilling operations until all other required permitting determinations are made. Annular disposal has not been requested as part of the Permit to Drill application for KRU 1 C- 117. Based on our current records, no annuli are currently approved for disposal on 1 C pad. Annular disposal of drilling wastes will not be approved for this well until sufficient data is submitted to ensure that the requirements of 20 AAC 25.080 are met. Annular disposal of drilling waste will be contingent on obtaining a well cemented surface casing confirmed by a valid Formation Integrity Test (FIT). Cementing records, FIT data, and any CQLs must be submitted to the Commission for approval on form 10-403 prior to the start of disposal operations. Please note that any disposal of fluids generated from this drilling operation which are pumped down the surface/production casing annulus of a well approved for annular disposal on Kuparuk River Unit 1C must comply with the requirements and limitations of20 AAC 25.080. Approval of this permit to drill does not authorize disposal of drilling waste in a volume greater than . 35,000 barrels through the annular space of a single well or to use that well for disposal purposes for a period longer than one year. Pennit No: 201-121 Page 2 of2 ( .~. 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. BY ORDER OF T~ COMMISSION DATED this 2/ day of June, 2001 jjclEnc10sures cc: Department ofFish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. (' ( Á/\\ STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 1a. Type of work: Drill 0 Redrill U Re-entry 0 Deepen 0 2. Name of Operator Phillips Alaska, Inc. 3. Address P.O. Box 100360 Anchorage, AK 99510-0361 4. Location of well at surface 1555' FNL, 799' FWL, Section 12, T11 N, R10E, UM : At top of productive interval 1151' FNL, 1338' FEL, Section 11, T11N, R10E, UM At total depth 1150' FNL, 1343' FEL, Section 11, T11N, R1OE, UM 12. Distance to nearest property line I 13. Distance to nearest well 3937' @ TO feet 1 C-1 0 37' , 16. To be completed for deviated wells ¡ Kickoff depth: 550 M 0 18. Casing program size 1b. Type of well. Service 0 20 AAC 25.005 Exploratory U Stratigraphic Test U Development Gas 0 Single Zone 0 5. Datum elevation (OF or KB) RKB = 102 feet AMSL feet 6. Property Designation AOL 25649 ALK 467 7. Unit or property Name 11. Type Bond (see 20 AAC 25.0251) Kuparuk River Unit Statewide 8. Well number Number 1 C-117 #59-52-180 9. Approximate spud date Amount June 30,2001 $200,000 14. Number of acres in property 15. Proposed depth (MD and TVD) 2560 5179' MD 14280' TVD 17. Anticipated pressure (see 20 AAC 25.035 (e)(2)) Maximum surface 1498 psig At total depth (TVO) 1969 psig Setting Depth Development Oil b!J Multiple Zone 0 10. Field and Pool Kuparuk River Field West Sak Oil Pool Maximum hole angle 57 deg Hole 24" 9.875" 9.875" Casing 16" 8.625" 7.625" Weight 62.5# 36# 29.7# Specifications Grade Coupling H-40 Weld N-80 Hyd 511 L-80 BTCM Length 120' 79' 5059 Top Bottom Quantity of Cement MD TVD MD TVD (include stage data) 41.2' 41.2' 158' 158' 225 cf AS 1 41.2' 41.2' 120' 120' 535 sx AS III L & 385 sx Class G 120' 120' 5179' 4280' Tapered String - Cemented above 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total Depth: measured true vertical feet feet Plugs (measured) Effective Depth: measured true vertical feet feet Junk (measured) Casing Conductor Surface 0 Length Size Cemented Measured depth True Vertical depth RECEIVED JUN 1 8' 2001 Perforation depth: measured true vertical Alaska Oil & Gas Cons. Commission Anchorage 20. Attachments Filing fee 0 Property Plat 0 BOP Sketch 0 Diverter Sketch 0 Drilling program 0 Drilling fluid program 0 Time vs depth plot 0 Refraction analysis 0 Seabed report 0 20 AAC 25.050 requirements 0 21. I hereby certify that the foregoing is true and correct to the best of my knowledge Questions? Call Steve McKeever 265-682t Signed ~~ . \.\.-...:-> ... Title: GKADrillíngTeamLeader Date '1i"ß~f Randy Thomas' Prenared hv Steve McKeever Permit Number / API number .2ð/ - /:..2, / 50- ð 2...? - Z. 3 02-7 Conditions of approval Samples required 0 Yes B No Hydrogen sulfide measures 0 Yes 181 No Required working pressure for BOPE 0 2M; ~M; 0 Other: c.~~~ -~, \-\-, \c,- ~ ""' \ "' .... -V OR1GINAl.. SIGNED BY 0 Taylor Seamount Commission Use Onl) , I Approval date If Btf.f) Mud log required' , Directional survey required 181 Yes 5M; 0 10M;D 0 I See cover letter for other requirements 0 Yes ~ No 0 No Approved by Commissioner by order of the commission c.e ~\/ð f o.~ G N.~.. Date Form 10-401 Rev. 12/1/85. Submit in triplicate A¡.',...-"cation for Permit to Drill, Well 1 C-117 .. Revision No.O , Saved: 18-Jun-01 Permit It - West Sak Well #1 C-117 Application for Permit to Drill Document MoximizE Well VQI~E¡ 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) Requirements of 20 AAC 25.050(b) 2 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 ........................................... 4 Requirements of 20 AAC 25.005 (c)(5) 4 6. Casing and Cementing Program .............................................................................4 Requirements of 20 AAC 25.005(c)(6) 4 7. Diverter System Information .... ...... .......... ........ ...... ...... ... ....... .......... ......... ..............4 Requirements of 20 AAC 25.005(c)(7) 4 8. Dri II i ng FI u id 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. Seism ic Analysis.... ........ .............. ....... ..... ....... ........ ........... ... ......... ........ .................. 5 Requirements of 20 AAC 25.005 (c)(10) 5 11. Seabed Condition Analysis .....................................................................................5 Requirements of 20 AAC 25.005 (c)(11) 5 12. Evidence of Bond i ng...... ............. ... ......... ........ ...... ............... ...... ........ ..... ..... ....... .....5 Requirements of 20 AAC 25.005 (c)(12) 5 1C-117 PERMIT IT. DOC U H , l;f I IV;. :rinred:~~~~:!o~ ( Þf..... "cation for Permit to Drill, We1l1C-117 , Revision No.O Saved: 18-Jun-01 13. Proposed Dri Iii ng Program.. ........ ....... ......... ....... ....... ...... .... ........ ........ ..... ..... ..........6 Requirements of 20 AAC 25.005 (c)(13) 6 14. Discussion of Mud and Cuttings Disposal and Annular Disposal....................... 7 Requirements of 20 AAC 25.005 (c)(14) 7 15. Attachments ...... ... ...... ....... ........... ... ....... ...... .... ........... ....... ... ..... ......... ......... ...... ...... 8 Attachment 1 Directional Plan (10 pages) Attachment 2 13-5/8" 5k x 11" 5k BOP System, Nabors Rig 245e (1 page) Attachment 3 Drilling Hazards Summary (1 page) Attachment 4 Cement Loads and CemCADE Summary (1 page) Attachment 5 Well Schematic (3 pages) 1. Well Name Requirements of 20 AAC 25.005 (f) Each well must be identified by a unique name designated by ttie operator and a unique API number assigned by the commission under 20 AAC 25.040{b). For a i'vell with multiple well branches; each branch must similarly be identifìed by a unique name and APi number by adding a suffix to the name designated fòr the well by the operator ðnd to the number assigned to the well by the commis"5ion The well for which this Application is submitted will be designated as lC-117. 2. Location Summary Requirements of 20 AAC 25.005(c)(2) An application for ð 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: (2) a plat identifying the property and the property's owners and showing (A)ihe coordinates of the proposed location of the well at the swface/, at the top of each objective formatiorJ" and at total depth referenced to governmental section lines: (8) the coordinates of'the proposed location of the well at the sUlface/ ref'erenæd to the state plðne coordinate ::J}/stem for thIs state ðS maintained by the National Geodetic Swvey in the NatIonal Oceanic and Atmospheric AdministratkJn/ (C) the proposed depth of the well at the top of each objectIve formation and at total depth; Location at Surface NGS Coordinates Northings: 5,968,680.39 Eastings: 561,805.95 1555' FNL, 799' FWL, Section 12, T11N, R10E, UM RKB Elevation 102.0' AMSL Pad Elevation 60.8' AMSL Location at Top of Productive Interval (West Sak "D" Sand) NGS Coordinates Northings: 5,969,067 1151' FNL, 1338' FEL, Section 11, T11N, Rl0E, UM Eastings: 559,666 Measured Depth, RKB: Total Vertical Depth, RKB: Total Vertical Depth, 55: 4618 3719 3617 Location at Total Depth NGS Coordinates Northings: 5,969,068 Eastings: 559,661 1150' FNL, 1343' FEL, Section 11, Tl1N, Rl0E, UM Measured Depth, RKB: 5180 Total Vertical Depth, RKB: 4280 Total Vertical Depth, 55: 4178 and 1C-117 PERMIT IT. DOC 0.: . G N A :rinte:~~~~:-~~ Af....' .. ';Gation for Permit to Drill, Well 1 C-117 ~ Revision No.O Saved: 18-Jun-01 (D) otl1er information required by 20 MC 25.050(bì: Requirements of 20 AAC 25.050(b) If a well is to be intentionally deviate~ the application for a Permit to Drill (Form 10-401) must (1) include a plat drawn to a suitable scale, showing the path of the proposed we!lbore, including aH adjacent wellbores within 200 feet of any portion of the proposed well; Please see Attachment 1: Directional Plan and (2) for all wells within 200 feet of the proposed wellbore (A) list the names of the operators of those well~ to the extent that those names are knm'In or discoverable in public records; and show tlJat each named operator has been furnished a copy of the application by certified mai¿' 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 {or a Permit to Drill must be accompanied by each of the following item0 except for an item already on file with the commission and Identified in the application: (3) a diagram and desaiption of the blowout prevention equipment (BOPE) as required by 20 MC 25.03!i 20 AAC 25.036; or 20 MC 2.5.037- as appJicable/ Two different configurations of blowout prevention equipment will be used during rig operations on Well 1C-117. For casing clean out operations an API 13-5/8" x 5,000 psi BOP stack will be used. A diagram of this stack is on file with the Commission. 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 WeIl1C-133, dated April 26th, 2001. During completion operations, a BOP stack combining API 13-5/8" x 5,000 psi preventers with API 11" x 5,000 psi preventers will be used. Please refer to Attachment 2: "13-5/8" 5k x 11" 5k BOP System, Nabors Rig 245e". 4. Drilling Hazards Information Requirements of 20 AAC 25.005 (c)(4) An application for a Permit to Drill must be ar.:r;ompanied by each of the following ítem~ except for an item already on file with the commis!>1on and Identified in the application: (4) information on drilling hazards; including (A) the maximum downhole pressure that may be encountered, criteria used to determkle it; and max/mum potential surface pressure based on a methane gradient; The expected reservoir pressures in the West Sak sands in the 1C 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 1498 psi, calculated thusly: MPSP =(4280 ft)(0.46 - 0.11 psi/ft) =1498 psi (8) data on potential gas zones/ The well bore is not expected to penetrate any gas zones. and (C) data concerning potentia! causes of hole problems such as abnormally geo-pressured strata/ lost circulation zone0 and zones that have a propen!>1ty for differential sticking; Please see Attachment 3: Drilling Hazards Summary. 1C-117 PERMIT IT. DOC O~, G VI ~ Printe:~Z~~:-~~ 11...;" '¡cation for Permit to Drill, Well 1 C-117 , Revision No.O Saved: 18-Jun-01 5. Procedure for Conducting Formation Integrity Tests Requirements of 20 AAC 25.005 (c)(5) An application for a Pem7it 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: (5) a descríption of the procedure for conducting formation integrity 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 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 welllC-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 commi!:>:;ion and Identified in the application: (6) a complete proposed casing and cementing program as required by 20 AAC 25.030.. and a description of any slotted Jine0 pre- perforated line0 or screen to be installed; CasinCl and Cementing Program Hole Size (in) 24 8-5/8 7-5/8 Cement Program Cemented to surface with 225 cf ArcticSet 1 Tapered String Cemented to Surface with 535 sx ASLite Lead, 385 sx Class G Tail Additionally, the 'A' Sand will be completed by perforating through the 7-5/8" casing, and then gravel packing between the casing and a set of screens and excluders inside the casing. See also Attachment 4: Cement Loads and CemCADE Summary, and Attachment 5: Completion Schematic Weight (Ib/ft) 62.5 Grade H-40 Connection Welded Length (ft) 117 Top MD/TVD (ft) 41/41 Btm MD/TVD (ft) 158 / 158 Csg/Tbg 00 (in) 16 29.7 L-80 Hyd 511 STCM 79 41/41 120 / 120 120 / 120 5180/4280 9-7/8 9-7/8 36 N-80 5060 7. Diverter System Information Requirements of 20 AAC 25.005(c)(7) An application for a Permit to Drill must be accompanied by ead7 of the following item.'i¡ except for an item already on file with the commission and identified in the application: (7) a diagram and description of the diverter system as required by 20 AAC 25:03~ unless this requirement /." waived by the commission under 20 AAC 25:035(h){2J' 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 welllC-133, dated April 26th, 2001. 8. Drilling Fluid Program Requirements of 20 AAC 25.005(c)(B) An applicatìon for a Permit to Drill must be accompanied by each of the folJowing item~ except for an item already on tHe with the commission and Identified in the application: (13) a drilling flUId program/ includìng a diagram and description of the drilling fluid system/ as requìred by 20 AAC 25.033; Drilling will be done with a bentonite slurry having the following properites over the listed intervals: 1C-117 PERMIT IT.DOC 0 ... G '\1 ' L Page40fB . I V. . Printed: 1B-Jun-01 ~....r '¡cation for Permit to Drill, Well 1 C-117 , Revision No.O Saved: 18-Jun-01 Spud to Base of Permafrost Initial Value Final Value Density (ppg) 8.5 9.4 - 9.6* Funnel Viscosity 150-200 150-200 (seconds) Yield Point 30-60 30-60 (cP) Plastic Viscostiy 8-15 11- 22 (lb/100 sf) 10 second Gel 15-30 10-25 Strength (lb/100 sf) 10 minute Gel 25-55 25-55 Strength (lb/100 sf) pH API Filtrate(cc) 8-15 6 Solids (%) 5-8 5-8 Base of Permafrost to Total Depth Initial Value Final Value 9.4 9.4 150 75 25-45 25-45 11- 22 11- 22 15-30 15-30 25-55 25-55 8-9 8-9 5-6 5-6 5-8 6-11 *9.8 ppg if hydrates are encountered Drilling fluid practices will be in accordance with appropriate regulations stated in 20 MC 25.033. 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-VT- 5 Centrifuges, Degassers, PVT System with visual and audio alarms, Trip Tank, Flow Sensor, and Fluid Agitators. Please see "Diagram of Mud System, Nabors Rig 245e", placed on file with the Commission with the Application for Permit to Drill for well lC-133, dated April 26th, 2001 9. Abnormally Pressured Formation Information Requirements of 20 AAC 25.005 (c)(9) An application for a Permit to Drill must be accompanied by eaä¡ of tfle following items~ except for an Item already on file with the commls..sion and identifled in tile application: (9) for an exploratOlY or stratigraphic test well a tabulation setting out the depths of predicted abnormally £leo-pressured strata as required by 20 MC 25. 033(f),' 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 a Permit to Drill must be accompanied by each of the following item~ except for an item already 017 file with the commi.-:;sion and identified in the application: (10) f..ryr an exploratory or stratigrapNc test well a seismic refraction or reflection analysis as required by 20 MC 25.06.1(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 Olill must be accompanied by each of the following ¡tems~ except for an item already on ¡¡Ie vlith the commis"Sion and Identified in the app!ícatíon: (11) for a well dr/lied from an offshore platfOlm¡ mobile bottom-founded sfructure/ jack-up rig¡ or floating dnlling ves:;;-el an analysis of seabed conditions as requJÌ-ed by 20 MC 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 Dtill mU!:>7 be accompanied by eadì of the foJlowing 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 25:025 {Bonding}have been met~. 0.- 'G -'NAc...117PERMITIT.DOC Page 5 of 8 Printed: 18-Jun-01 , - Ä£........ ';çation for Permit to Drill, We1l1C-117 , Revision No.O Saved: 18-Jun-01 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 item~ 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 5, Well Schematic. 1. Excavate cellar, install cellar box, set and cement 16". Weld landing ring on conductor. 2. MIRU Nabors Rig 245e. Install diverter & function test same. 3. Spud and directionally drill 9-7/8" hole to desired target through West Sak interval to the base of the A- Sand. Run MWD / LWD / PWD logging tools in drill string as required for directional monitoring and formation data gathering. 4. Perform wiper trip. Circulate and condition hole to run casing. Run hole opener if required. POOH. 5. Run and cement 8-5/8" x 7-5/8" tapered casing string to surface. Displace cement with mud and perform stage job or top job if required. Note: ECP to be inflated as part of primary cement job. Note: 7-5/8" Port Collar to be installed @ +/- 1,000' TVD. 6. Nipple down 21-1/4" diverter, nipple up dual completion well head and 13-5/8 x 5000 psi blowout preventer stack and test to 5,000 psi. 7. RIH with drill bit and cleanout well to 50' below bottom A-Sand Perf. 8. Displace well to seawater and POOH. While POOH stop and displace top 2000' with diesel to freeze protect. Continue POOH backfilling w/ seawater. 9. Nipple down BOPE and install 7-1/16" x 5,000 psi full bore valve atop wellhead. 10. RD Nabors Rig 245e and move off location. 11. RU E-Line Unit. Complete cement bond log. RD E-line unit, 12. MIRU Nabors Rig 245e. 13. ND full bore valve, nipple up 5,000 psi BOPE and test to 5,000 psi. 14. Pressure casing to 3,000 psi for 30 minutes. 15. RIH with drill bit and casing scrapers. 16. Displace well to filtered brine and perform caustic wash and pickle. POOH. 17. RU E-line unit and RIH with 4-1/2" guns. Perforate A2 / A3-Sands. RD E-Line unit. 18. RIH with workstring (open ended) and perform A-Sand frac. 1 C-117 PERMIT IT. DOC 0, ~, "G, ' Nt ~ Printe:~~~~n~~~ ;¡i.r- 'ication for Permit to Drill, Well 1 C-117 \ Revision No.O Saved: 18-Jun-01 19. RIH and clean out frac sand and perforation debris. POOH. 20. PU tubing conveyed perforating guns. RIH and re-perforate the A-Sand as required. POOH. 21. RIH and set bridge plug +/- 15' below bottom perforation. POOH. 22. PU gravel pack assembly. RIH and tag top of bridge plug. Set packer and perform gravel pack of A sand as designed. POOH. 23. RU slick line unit. RIH and set nipple reducer in XN Nipple below gravel pack packer. RD slick line unit. 24. RIH, set packer plug and spot sand on top of packer to catch perforation debris. POOH. 25. RU E-line unit and RIH with 4-1/2" guns. Perforate B / D-Sands. RD E-Line Unit. 26. RIH, circulate sand off top of packer and retrieve packer plug. POOH. 27. PU and RIH with dual string completion assembly as designed. 28. RIH to just above top of gravel pack packer. 29. RU and circulate into top of SBE. PU and perform space out. With seal assembly unstung from SBE, freeze protect the tubing x 7-5/8" annulus and the 2-3/8" x 3-1/2" tubing strings. Land tubing. 30. RU Slick Line Unit. RIH and set plug in XN Nipple below gravel pack packer. 31. Set completion packers as per Service Representative on location. 32. Retrieve plug from XN Nipple. RD slick line unit. 33. ND BOPE, NU Dual Tree and pressure test. 34. RD Nabors 245e and move off. After the rig has moved off a jet pump will be landed in a nipple in the 3-1/2" tubing string and tied back to surface with 2" coil tubing. 'A' sand production will occur up the 2" coil by 3-1/2" tubing annulus when jet pump power fluid is pumped down the 2" coil tubing. 14. Discussion of Mud and Cuttings Disposal and Annular Disposal Requirements of 20 AAC 25.005 (c)(14) An application for a Pe¡mit to Drill mustc be accompanied by each of the following ¡temSr except for an Item already on file with the commission and Identified in the applìcation: (14) a general desaiption of how the operator plans to dispose of drilling mud and cuttings and a statement of whether the operator Intends to request authorization under 20 MC 25. 080 for an annular disposal operation In the we/I,/' 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 processed through the ball mill (part of the drilling rig) and injected down a permitted annulus or approved disposal well, or stored temporarily on site, then hauled to the Prudhoe Bay Field for 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. 1C-117 PERMIT IT. DOC Or;¡ IIG lNA I Page70fB III' I . Printed: 1B-Jun-01 ~...~. 'ication for Permit to Drill, Well 1 C-117 ~. Revision No.O . Saved: 18-Jun-01 15. Attachments Attachment 1 Directional Plan (11 pages) Attachment 2 13-5/8" 5k x 11 II 5k BOP System, Nabors Rig 245e (1 page) Attachment 3 Drilling Hazards Summary (1 page) Attachment 4 Cement Loads and CemCADE Summary (1 page) Attachment 5 Well Schematic (3 pages) 1C-117 PERMIT IT.DOC Page 8 of 8 O. ?' G. 'AA ~ Printed: t8~un-01 200 - 400 - 600 - BOO - 1000 - 1200 - 1400 - ,......... +- 1 600 - Q) Q) - "-/ 1BOO- ..c: +- 0.. Q) 0 2000 - 0 C,) 2200 - :;: !o.... Q) > 2400 - Q) :J !o.... I- 2600 - I V 2BOO - 3000 - 3200 - 3400 - 3600 - 3BOO - 4000 - 4200 - 4400 0 ~ ! Phillips Alaska, Inc. Structure: Pad 1 C Well: 117 RKB ELEVATION: 102' Field: Kuparuk River Unit Location: North Slope, Alaska KOP .. 3.00 .. 6.00 280.73 AZIMUTH 2179' (TO TARGET) 9.00 12.00 DLS: 3.00 deg per 100 ft ***Plane of Proposal*** Begin Bld/Trn 16.80 20.83 25.20 DLS: 5.00 deg per 100 ft 29.76 34.43 39.17 43.97 48.79 53.64 Base Permafrost EOC TANGENT ANGLE 57.39 DEG 57.00 54.00 51.00 48.00 45.00 42.00 39.00 36.00 33.00 30.00 27.00 24.00 Ugnu C 21.00 18.00 15.00 12.00 9.00 .. 6.00 .. ~ 3.00 TARGET ANGLE "VERTICAL" Ugnu B Ugnu A K-13 Top W Sak D C B A4 Target-A3-EOC A2 A 1 Base Pay Base W Sak TD - Csg pt Ll 0 200 600 BOO 1000 1200 1400 1600 Vertical Section (feet) -> Azimuth 280.73 with reference 0.00 N, 0.00 E from slot #117 400 1 BOO 2000 2200 2400 ~Hn~LlP~ ra Created by finch For: S McKeever Dote plotied : 25-l.4oy-2001 Plot Reference is 117 Version 14. Coordinates are in fMt reference slot 1117. True Vertical Depths Qre reference RKB 102' (N-245E). lEi. UIŒ8 - ~ DLS: 3.00 deg per 100 ft 0 ~ G N.,- c ::c ......... ~ ......... :æ: ):::a. r- Phillips Alaska, Inc. Created by finch For S McKeever Date platted: 25-May-2DD1 Plot Reference is 117 Version #4. Coordinates ore in feet reference slot 1117. True Vertical Depths cre reference RKB 102' (N-245E). III¡¡II BAI(- tIUGIIES INTEQ Structure: Pad 1 C Well: 117 Field: Kuparuk River Unit Location: North Slope. Alaska <- West (feet) 2200 2100 1900 1600 2000 1800 1700 1500 1400 1300 1200 1100 1000 900 800 700 600 500 400 ç"- cf"o, <y()ú /.;f "'<;) '!! o,lò ",r§ I TARGET/TO LOCATION: I 1150' FNL, 1343' FEL SEC. 11, T11N, R10E TOP W SAK 0 LOCATION: 1151' FNL, 1338' FEL SEC. 11, T11N, R10E 280.73 AZIMUTH 2179' (TO TARGET) ***Plone of Proposol*** , TRUE ~HI~LlP5' tmI 300 100 200 100 0 600 .~~> - 500 - 400 ^ - 300 I z 0 .., - 200 ...- ::r --- ........ - 100 <D Iá þ..'L <D ...- ",bO "-/ ~ - 0 "'~<:- ~ò\ - 100 <Q çf <Q'li - 200 .-, SURFACE LOCATION: 1555' FNL. 799' FWL SEC. 12, T11N, R10E Phillips Alaska, Inc. . . - Created by finch For S McKeever Structure: Pad 1 C Well: 117 ~I PHilLIPS Dole plaUed ; 25-May-2001 Plot Rehtrence is 117 Version '4. Field: Kuparuk River Unit Location: North Slope, Alaska lD Coordinates are in feet reference slot # 117. True Vertical Deplhs ore reference RKB 102' (N-245E). Bill .... I Nn:Q ==== PROF~LE COMMENT DATA ===== ----- Point ----- MO Inc Oir TVO No rt h East V. Sect Oeg/100 ~, KOP 550.00 0.00 245.00 550.00 0.00 0.00 0.00 0.00 Begin Bld/Trn 1050.00 15.00 245.00 1044.31 -27.50 -58.98 52.83 3.00 Base Permafrost 1934.55 55.32 283.32 1759.00 9.78 -540.81 533.18 5.00 EOC 1977.07 57.39 283.90 1 782.56 18. 11 -575.21 568.53 5.00 Begin Drop 2846.68 57.39 283.90 2251 .19 194.08 -1286.30 1299.95 0.00 K-15 2904.36 55.66 283.90 2283.00 205.64 -1333.00 1347.98 3.00 Ugnu C 4022.56 22.12 283.90 3141 .00 371.88 -2004.76 2038.95 3.00 Ugnu B 4319.85 13.20 283.90 3424.00 393.52 -2092.20 2128.88 3.00 Ugnu A 4352.65 12.21 283.90 3456.00 395.25 - 2099.20 2136.09 3.00 K-13 4518.08 7.25 283.90 3619.00 401.97 -2126.34 2164.00 3.00 Top W Sak 0 4618.60 4.23 283.90 3719.00 404.38 -2136.10 2174.04 3.00 ~> C 4658.68 3.03 283.90 3759.00 404.99 -2138.56 2176.57 3.00 B 4678.70 2.43 283.90 3779.00 405.22 -2139.49 2177.52 3.00 A4 4713.72 1.38 283.90 3814.00 405.50 -2140.62 2178.69 3.00 C Target-A3-EOC 4759.73 0.00 283.90 3860.00 405.64 -2141.15 2179.24 3.00 ::t:J A2 4830.73 0.00 283.90 3931 .00 405.64 -2141.15 2179.24 0.00 ........ ~ A1 Base Pay 4929.73 0.00 283.90 4030.00 405.64 -2141.15 2179.24 0.00 ........ §: Base W Sak 5024.73 0.00 283.90 4125.00 405.64 -2141.15 2179.24 0.00 TO - Csq pt 5179.73 0.00 283.90 4280.00 405.64 -2141.15 2179.24 0.00 ........ ( Phillips Alaska, Inc. Pad 1C 117 slot #117 Kuparuk River Unit North Slope, Alaska PRO P 0 S ALL I S TIN G by Baker Hughes INTEQ Your ref: 117 Version #4 Our ref: prop4381 License: Date printed: 25-May-2001 Date created: 8-Jan-2001 Last revised: 25-May-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 29.879,w149 29 55.802 Slot Grid coordinates are N 5968679.822, E 561805.176 Slot local coordinates are 1555.00 S 799.00 E Projection type: alaska - Zone 4, Spheroid: Clarke - 1866 Reference North is True North OR'G, ^'A~ Grid Repc Page 1 of Phillips Alaska, Inc. PROPOSAL LISTING Page 1 Pad lC,117 Your ref: 117 Version #4 Kuparuk River Unit,North Slope, Alaska Last revised: 25-May-2001 Measured Inclin Azimuth True Vert R E C TAN G U L A R G RID COO R D 8 G E 0 G RAP H I C Depth Degrees Degrees Depth COO R DIN ATE 8 Easting Northing COO R DIN ATE 8 0.00 0.00 245.00 0.00 O.OON O.OOE 561805.18 5968679.82 n70 19 29.88 w149 29 55.80 500.00 0.00 245.00 500.00 O.OON O.OOE 561805.18 5968679.82 n70 19 29.88 w149 29 55.80 550.00 0.00 245.00 550.00 O.OON O.OOE 561805.18 5968679.82 n70 19 29.88 w149 29 55.80 650.00 3.00 245.00 649.95 1.118 2.37W 561802.81 5968678.70 n70 19 29.87 w149 29 55.87 750.00 6.00 245.00 749.63 4.428 9.48W 561795.73 5968675.32 n70 19 29.84 w149 29 56.08 850.00 9.00 245.00 848.77 9.948 21. 31W 561783.95 5968669.71 n70 19 29.78 w149 29 56.42 950.00 12.00 245.00 947.08 17.648 37.82W 561767.50 5968661.88 n70 19 29.71 w149 29 56.91 1050.00 15.00 245.00 1044.31 27.508 58.98W 561746.43 5968651.84 n70 19 29.61 w149 29 57.52 1100.00 16.80 251. 33 1092.40 32.558 71.69W 561733.76 5968646.69 n70 19 29.56 w149 29 57.90 1200.00 20.83 260.56 1187.05 40.108 102.95W 561702.57 5968638.89 n70 19 29.49 w149 29 58.81 1300.00 25.20 266.81 1279.08 44.208 141. 78W 561663.78 5968634.47 n70 19 29.44 w149 29 59.94 1400.00 29.76 271.29 1367.78 44.838 187.88W 561617.69 5968633.47 n70 19 29.44 w149 30 01.29 1500.00 34.43 274.66 1452.48 41. 988 240.90W 561564.65 5968635.89 n70 19 29.47 w149 30 02.83 1600.00 39.17 277.30 1532.54 35.668 300.44W 561505.07 5968641.72 n70 19 29.53 w149 30 04.57 1700.00 43.97 279.46 1607.33 25.948 366.05W. 561439.39 5968650.91 n70 19 29.62 w149 30 06.49 1800.00 48.79 281. 27 1676.31 12.888 437.22W 561368.11 5968663.39 n70 19 29.75 w149 30 08.56 1900.00 53.64 282.83 1738.93 3.42N 513.42W 561291.79 5968679.07 n70 19 29.91 w149 30 10.79 1934.55 55.32 283.32 1759.00 9.78N 540.81W 561264.35 5968685.20 n70 19 29.98 w149 30 11.59 1977.07 57.39 283.90 1782.56 18 . 11N 575.21W 561229.89 5968693.25 n70 19 30.06 w149 30 12.59 2000.00 57.39 283.90 1794.91 22.75N 593.97W 561211.10 5968697.74 n70 19 30.10 w149 30 13.14 2500.00 57.39 283.90 2064.36 123.93N 1002.82W 560801.48 5968795.58 n70 19 31.10 w149 30 25.07 2846.68 57.39 283.90 2251.19 194.08N 1286.30W 560517.46 5968863.43 n70 19 31.79 w149 30 33.35 2859.73 57.00 283.90 2258.26 196. 72N 1296.95W 560506.80 5968865.97 n70 19 31.81 w149 30 33.66 2904.36 55.66 283.90 2283.00 205.64N 1333. OOW 560470.67 5968874.60 n70 19 31.90 w149 30 34.71 2959.73 54.00 283.90 2314.89 216.51N 1376.94W 560426.66 5968885.11 n70 19 32.01 w149 30 35.99 3059.73 51. 00 283.90 2375.76 235.57N 1453.94W 560349.51 5968903.54 n70 19 32.20 w149 30 38.24 3159.73 48.00 283.90 2440.70 253.83N 1527.74W 560275.56 5968921.20 n70 19 32.38 w149 30 40.40 3259.73 45.00 283.90 2509.53 271 . 26N 1598.15W 560205.03 5968938.05 n70 19 32.55 w149 30 42.45 3359.73 42.00 283.90 2582.05 287.79N 1664.96W 560138.09 5968954.04 n70 19 32.71 w149 30 44.40 3459.73 39.00 283.90 2658.09 303.39N 1728. OOW 560074.93 5968969.13 n70 19 32.86 w149 30 46.24 3559.73 36.00 283.90 2737.41 318.01N 1787.09W 560015.74 5968983.27 n70 19 33.01 w149 30 47.97 3659.73 33.00 283.90 2819.82 331. 62N 1842.06W 559960.66 5968996.42 n70 19 33.14 w149 30 49.57 3759.73 30.00 283.90 2905.07 344.17N 1892.77W 559909.85 5969008.56 n70 19 33.26 w149 30 51. 05 3859.73 27.00 283.90 2992.94 355.63N 1939.09W 559863.45 5969019.64 n70 19 33.38 w149 30 52.40 3959.73 24.00 283.90 3083.19 365.97N 1980.87W 559821.58 5969029.64 n70 19 33.48 w149 30 53.62 4022.56 22.12 283.90 3141. 00 371.88N 2004.76W 559797.65 5969035.36 n70 19 33.54 w149 30 54.32 4059.73 21. 00 283.90 3175.57 375.16N 2018.02W 559784.37 5969038.53 n70 19 33.57 w149 30 54.71 4159.73 18.00 283.90 3269.82 383.18N 2050.42W 559751.91 5969046.29 n70 19 33.65 w149 30 55.65 4259.73 15.00 283.90 3365.69 390.00N 2077.98W 559724.29 5969052.88 n70 19 33.71 w149 30 56.46 4319.85 13.20 283.90 3424.00 393.52N 2092.20W 559710.05 5969056.28 n70 19 33.75 w149 30 56.87 4352.65 12.21 283.90 3456.00 395.25N 2099.20W 559703.03 5969057.96 n70 19 33.77 w149 30 57.08 4359.73 12.00 283.90 3462.92 395.61N 2100.64W 559701.59 5969058.30 n70 19 33.77 w149 30 57.12 4459.73 9.00 283.90 3561. 23 399.99N 2118. 33W 559683.87 5969062.54 n70 19 33.81 w149 30 57.64 4518.08 7.25 283.90 3619.00 401.97N 2126.34W 559675.85 5969064.45 n70 19 33.83 w149 30 57.87 4559.73 6.00 283.90 3660.37 403.12N 2131.00W 559671.17 5969065.57 n70 19 33.84 w149 30 58.01 4618.60 4.23 283.90 3719.00 404.38N 213 6 . lOW 559666.07 5969066.79 n70 19 33.86 w149 30 58.15 4658.68 3.03 283.90 3759.00 404.99N 213 8 . 56W 559663.60 5969067.38 n70 19 33.86 w149 30 58.23 4659.73 3.00 283.90 3760.05 405.01N 2138.61W 559663.55 5969067.39 n70 19 33.86 w149 30 58.23 4678.70 2.43 283.90 3779.00 405.22N 2139. 49W 559662.67 5969067.60 n70 19 33.86 w149 30 58.25 4713.72 1. 38 283.90 3814.00 405.50N 2140.62W 559661.54 5969067.87 n70 19 33.87 w149 30 58.29 01 G NA- Grid Repc Page 2 of All data in feet unless otherwise stated. Calculation uses minimum curvature method. Coordinates from slot #p 7 and TVD from RKB 102' (N-245E) (102.00 Ft a:Qove mean sea level) . Bottom hole Î mce is 2179.24 on azimuth 280.73 degrees f(f "I'lellhead. ~. cal Dogleg for wellpath is 118.74 degrees. Vertical section is from wellhead on azimuth 280.73 degrees. Grid is alaska - Zone 4. Grid coordinates in FEET and computed using the Clarke - 1866 spheroid Presented by Baker Hughes INTEQ Phillips Alaska, Inc. PROPOSAL LISTING Page 2 Pad 1C,117 Your ref : 117 Version #4 Kuparuk River Unit,North Slope, Alaska Last revised: 25-May-2001 Measured Inclin Azimuth True Vert R E C TAN G U L A R 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 4759.73 0.00 283.90 3860.00 405.64N 2141.15W 559661.00 5969068.00 n70 19 33.87 w149 30 58.30 4830.73 0.00 283.90 3931. 00 405.64N 2141.15W 559661.00 5969068.00 n70 19 33.87 w149 30 58.30 4929.73 0.00 283.90 4030.00 405.64N 2141.15W 559661.00 5969068.00 n70 19 33.87 w149 30 58.30 5000.00 0.00 283.90 4100.27 405.64N 2141.15W 559661.00 5969068.00 n70 19 33.87 w149 30 58.30 5024.73 0.00 283.90 4125.00 405.64N 2141.15W 559661.00 5969068.00 n70 19 33.87 w149 30 58.30 5179.73 0.00 283.90 4280.00 405.64N 2141.15W 559661.00 5969068.00 n70 19 33.87 w149 30 58.30 All data in feet unless otherwise stated. Calculation uses minimum curvature method. Coordinates from slot #117 and TVD from RKB 102' (N-245E) (102.00 Ft above mean sea level). Bottom hole distance is 2179.24 on azimuth 280.73 degrees from wellhead. Total Dogleg for wellpath is 118.74 degrees. Vertical section is from wellhead on azimuth 280.73 degrees. Grid is alaska - Zone 4. Grid coordinates in FEET and computed using the Clarke - 1866 spheroid Presented by Baker Hughes INTEQ Phillips Alaska, Inc. Pad 1C,117 Kuparuk River Unit,North Slope, Alaska MD TVD Rectangular Coords. PROPOSAL LISTING Page 3 Your ref: 117 Version #4 Last revised: 25-May-2001 Comments in wellpath -------------------- -------------------- ----------------------------------------------------------------------------------------------------------- Comment 550.00 1050.00 1934.55 1977.07 2846.68 2904.36 4022.56 4319.85 4352.65 4518.08 4618.60 4658.68 4678.70 4713.72 4759.73 4830.73 4929.73 5024.73 5179.73 550.00 1044.31 1759.00 1782.56 2251.19 2283.00 3141. 00 3424.00 3456.00 3619.00 3719.00 3759.00 3779.00 3814.00 3860.00 3931.00 4030.00 4125.00 4280.00 Top MD Top TVD O.OON 27.50S 9.78N 18 . 11N 194.08N 205.64N 371.88N 393.52N 395.25N 401.97N 404.38N 404.99N 405.22N 405.50N 405.64N 405.64N 405.64N 405.64N 405.64N O.OOE 58.98W 540.81W 575.21W 1286.30W 1333.00W 2004.76W 2092.20W 2099.20W 2126.34W 2136.10W 2138.56W 2139.49W 2140.62W 2141.15W 2141.15W 2141.15W 2141.15W 2141.15W Rectangular Coords. KOP Begin Bld/Trn Base Permafrost EOC Begin Drop K-15 Ugnu C Ugnu B Ugnu A K-13 Top W Sak D C B A4 WS 1C H4 (5-DEC-00) A2 A1 Base Pay Base W Sak TD - Csg pt Casing positions in string 'A' ------------------------------ ------------------------------ Bot MD Bot TVD Rectangular Coords. Casing o,=rGINt Grid Repo Page 3 of Î" ,. 0.00 ----------------------------------------------------------------------------------------------------------- ( 2141.1SW 7 5/8" Casing Target name 0.00 O.OON," ~ O.OOE 5179.73 4280.00 405.64N Geographic Location T.V.D. Targets associated with this wellpath ------------------------------------- ------------------------------------- Revised 40s.64N Rectangular Coordinates 8-Jan-2001 ----------------------------------------------------------------------------------------------------------- WS lC H4 (5-DEC-00) 559661.000,5969068.000,0.0000 3860.00 2141.1sW 0 ~ G ^A. Grid RepoJ Page 4 of f ( "'"""" .. r- For: S McKeever Oat, plotted : 25-1oIaf-2001 Structure: Pad 1 C Well: 117 tPHILuP~ ~ ~ Phillips Alaska, Inc. Pk)t R.f~ is 117 v.rMn 14. Field: Kuparuk River Unit Location: North Slope. Alaska Cooniincrtea ore in feel. rwlerenc:e aIct 1117. True yeftÏCOl DepthS CII"'tI refetence ~ 102' (N-2.t:1E). lB. IIAIŒR - INTI'./) ~G\ TRUE NORTH G G\ ~ ~ ~ ~'l c::=J \ \ 350130 0 340 \ I ;gg \ \ I 330 t no~ I \ \ \ \ \ \ \ . \ 1\ \ I \ I 10 260 $~ ~\, \ ~ \ '/, \ I - \ I 280 80 270 90 100 250 110 240 230 130 / / 220 // / / // 210 ,,'1700 / / / / / / 11500/ 200/ /1~00 / l 190 f!J~ @ Normal Plane Travelling Cylinder - Feet All depths shown are Measured depths on Reference Well 160 \ \ \ \ 180 170 @ ~ OR G.AA- <:::) :::J::J ---. r;-:) ---- c::: ~ r--- Phillips Alaska, Inc. Created by finch For S McKeever Well: 117 Structure: Pad 1 C Dote ploUed : 25-Moy-2001 Plol Reference is 117 Version 114. Coordinates ore in feet reference slot #117. Field: Kuparuk River Unit Location: North Slope, Alaska True Verticol Depths ore reference RKB 102' (N-245E). R.. BAKER HUGHES INTEQ 380 140 360 <- West (feet) 140 0 20 340 300 260 180 160 120 I 100 i w ~ 80 I I ~ 60 40 20 320 280 240 220 200 ~ e ,f. 400 6300 ~- / -$- ----.....1000 //"'500 120 - - - - - - ;~O 800 - - -""-600 --<l§]¡- - - - -...- - - ---700 1 00 - - - - - . 1.1 00 - ~ 300 ------- 1000 /....-500 - -.. - - - - - - - - 900 800 - ....--6ÚO .._-----~----_...~ ^ I \ \ \ \ \ \ \ \ \ \ .. 800 \ \. 1 000 \ \ \ \ '\ 800 \ \ \ '- 900 \ \ Þ300 \... 800 \700 \ .. 600 ~300 \ \ 700 .. 700 \. 600 \ ~ \ \ - -0.J- :$- 300 \ \ - - ",_1300 ""/500 \ 500 \. 600 - .. 800 / \ \ - - - /""600 \ - / ~300 \ - - - - - - / /"";00 \ 500 - - - -.. J ~O_O - 80g... ~ÔO -$-300 - - - - - 11 00 - / /' - - -.... - 1 000 .. - - - - - - - - - -«- - - - - - - 900 1800 80 - 60 - ,,--., +- Q) Q) - '--" 40 - ..!: +- !I.- 0 Z 20 - 0 - ,,--., +- Q) Q) - '--" - --- ---..... 800 --- --- --- '" 900 ......--- - --- --- 1 000 - - - - .-..--- 1~ 00 - --1 WO 1100 i3 . /' 400 / / 500 - /" 600 / /. 700 .... --- - - - --- / 800 - - - - - - ... 900 - -"fOOD 20 - CJJ1J.- - -..1 600 - - - - - - - - - - - - - - - 1 500 ---....------ /~OO - / "'500 - / /. 600 .- / / 700 - / ..../ 800 ....- --- / - /' --- /' - 900 - --- - - --- - "'1000 ..!: +- :J 0 (/) I V 40 - 60 - / @- 60 / 1J /700 / /'--800 /' /""900 & ~ 000 80 - 11 00 - - - - -~--------------_____~3~~____---------;~~--------------- 100 - 120 - 140 380 I 360 I 340 I 300 I 260 I 60 I 20 I 0 , 20 I 320 I 280 I 240 I 200 I 160 I 140 I 120 I 100 I 80 I 40 I 220 I 180 <- West (feet) . 'PHilLIPS' ~ ~ 40 4 - I 40 140 60 ¡!þ-100 ,/"800 - 120 &' 60 140 - 120 - 100 - 80 - 60 ^ I Z 0 ., -t- :::T - 40 - 20 ,,--., ..... CD CD -t- '--" - 0 - 20 (j) 0 C -t- :::T 40 ,,--., ..... CD CD -t- '--" ~, I V - 80 0 :x:J - C) - ::æ: ):::. r- ^ I ,.--.... -I- (1) (1) - '--" ...c -I- L 0 Z 200 - 300 - 400 - 500 - Created by finch For S McKeever Well: 117 ~'PHILLlP~ ~ ~ Phillips Alaska, Inc. Structure: Pad 1 C Dote plotted: 25-May-2001 Plot Reference is 117 Version #4. Coordinates ore in feet reference slot #117. True Verticol Depths ore reference RKB 102' (N-245E), _e BAlCER HUGHES INTEQ Field: Kuparuk River Unit Location: North Slope, Alaska <- West (feet) 2500 800 2400 2300 2200 2100 1900 1700 2000 1800 1600 1500 1400 1300 1200 1100 1000 900 800 700 600 500 400 300 800 Q@., CZ&,~, ~ ..... ..... ..... .......... '\ ¡.. ..... ....... ..... ....... \ / \, ............ ......... ............ \, I '\ , " 2100 ' , ' " 1 500 ... < 1900\ '$, ..... ..... I, \, , , , ' '" 1900 '- '- )Ii 35'Op ... ... , , ' ....... ....... ..... f ..... \, \, , , , , ", 2900;... 170Ò'" ....... ..... ..... I \....... '\ ....... ..... I '\...... \, , '-, 1900 ' , I '- '2JOÐ ...... ....... ....... ....... ""..... .... / '\ \ 1 ..... -., [!].. , , , " , "'... 1 300 3700 - - -..- - ' , - - :', , "'..."'... " ,2300 3300 -..... - '- , ... 1700 ..."', 3100 - - ... - - - '- - -JI , , , "'... 1 300 15Ò(} , 2900 - - ... - ' ' .. ~ 700 , , ... 1500... 1100- 2700 - - - - I ' - ' , " , ... ~ - 300 - -...... - J 3700 -', ' ...", - ~ 2500 - - - - - - I' , -', "1100 "', 1300 - 200 -~ --..._-- / -,'-';.,,1500', '~- 200 ~ - - - - 2300 2300 - - - - I '- ~ - 1300 -. ~O ~'o/ - - - - - - - .....- - - - - - - - - -...... / 15;;;"- , -.. 130Ò', ?> - - - - - - - - - - - - - - - ..} 1 00 21 00 - : - - - - - - - ' , , , ~ - - - '~ 1 00 - - - - - - - ¡ - - - -. 1900 ' , - - - - - - - - - - - -.1:~0- - : - - - - - - - - - 13ÒO~- - - - - - - - - I - 1 700 - - - -. J ?.O~ - 0 ¡r -----.- -:::<JIi , - - - - - - - - - - 1500 2~~ :3500 .~~- - --@- 100 ,~ 3300 3100 , , 381 3 JS1!:';- 200 I ~ ~ . --- - I - - .. í 500 --$ I - - - ~ J:;.9 - 300 : - - - - - - " " " 0'1 500 I ~--- // I .....-- -- / : - - - - - 1 700 " " " - - " _...------- : /// r§ir - ,00 & 700 - ~ ... ... ... ... ... ... ... ... ... ... ... ... ... , 600 - 500 - 400 - 300 - 100 - 0 - 100 - Œ:\ 6500 ~OO 5300 4900 4700 4500 4300 4100 3900 3700 f!Þ - 400 " rfj5" 2500 2400 2300 2200 2100 2000 1900 1800 1700 1600 1500 1400 1300 1200 1100 1000 900 800 700 600 500 400 300 < - West (feet) ~'" - 700 - 600 - 500 ^ I z 0 ., -+ ::r ,.--.... - CD CD -+ '--" ~ - 500 (' Phillips Alaska, Inc. Pad 1C 117 slot #117 Kuparuk River Unit North Slope, Alaska ( SUM MAR Y C LEA RAN C ERE P 0 R T by Baker Hughes INTEQ Your ref: 117 Version #4 Our ref: prop4381 License: Date printed: 25-May-2001 Date created: 8-Jan-2001 Last revised: 25-May-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 29.879,w149 29 55.802 Slot Grid coordinates are N 5968679.822, E 561805.176 Slot local coordinates are 1555.00 S 799.00 E Projection type: alaska - Zone 4, Spheroid: Clarke - 1866 Object wellpath GMS <0-9700'>, ,3,Pad 1C GMS <0-7753'>,,5,Pad 1C GMS <0-10243'>, ,6,Pad 1C GMS <0-9784'>,,7,Pad 1C Unknown Data"WS1,Pad 1C PMSS <0-8677'>, ,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 <0-14630'>,,26,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 PGMS <0-9002'>,,10GI,Pad 1C PMSS <0 - 8095'>,,18,Pad 1C PMSS <0-13910'>,,27,Pad 1C PMSS <0 - 10969'),,17,Pad 1C Reference North is True North Closest approach with 3-D Last revised Distance 18-Dec-1998 366.9 18-Dec-1998 199.2 18-Dec-1998 186.8 18-Dee-1998 243.0 2-Nov-1998 5751.9 1-Dec-1998 182.5 8-Jan-1999 181.8 2-Jan-1998 215.6 13-Jul-1999 489.4 8-Jun-1999 489.4 4-Jun-1999 543.3 24-Aug-1999 559.7 11-Mar-1999 588.0 17-Dec-1998 447.0 18-Mar-1998 340.2 18-Dee-1998 270.0 17-Dec-1997 11135.3 18-Dec-1998 335.6 19-Mar-1997 367.0 7-Jan-1998 353.5 18-Dec-1998 474.6 18-Dec-1998 37.1 22-Feb-1999 223.6 1-Jan-1999 574.3 2-Dec-1998 285.1 Minimum Distance method M.D. Diverging from M.D. 572.2 572.2 20.0 540.0 500.0 500.0 400.0 400.0 4741.3 4741.3 120.0 120.0 120.0 120.0 1563.6 1563.6 20.0 20.0 20.0 20.0 420.0 420.0 20.0 20.0 550.0 550.0 120.0 120.0 120.0 120.0 20.0 5179.7 1136.4 5179.7 20.0 4608.8 280.0 280.0 400.0 400.0 550.0 550.0 1154.5 1154.5 340.0 5179.7 20.0 20.0 100.0 100.0 0 R SG1lÄaI~:e~e~~r; 13-5/811 5k x( 111 5k BOP System, N{I"ors Rig 245e West Sak Dual Purpose Wells, Running Completion -6 c:L 9 ~ 5 ~ Þ 8 S Þ ~ L, ~ 7 ~ 6 ~ ~ ~ 5 Þ [ ] 4 [ ] 3 ~ ~[ ] Top of Vetco Gray 2 11-5K Tubing Head ) 11 1 . I I I I I I 8-5/8" Casing ¡ ¡ "I 16' Casing ~ ~ KEY: 1. Landing Ring, 16" x 13-5/8", Vetco Gray, with 8-5/8" x 7-5/8" Casing Landed, Vetco Gray. 2. Tubing Head, 10-3/4" Vetco Gray Quick Connect Bottom x API 11" 5000 psi Flange Up, Vetco Gray. 3. Double Studded Adapter I Spacer Spool, 11" x 13-5/8" 5000 psi, Nabors. 4. Spacer Spool(s), 13-5/8" 5000 psi x 13-5/8" 5000 psi, Nabors. 5. Single Ram BOP, 13-5/8" x 5000 psi, with pipe rams, Nabors Tvpical Accumulator Capacity Test 1. Check and fill accumulator reservoir to proper level with hydraulic fluid. 2. Assure that accumulator pressure is 3000 psi with 1500 psi downstream of the regulator. 3. Observe time, then close all units simultaneously and record the time and pressure remaining after all units are closed with the charging pump off. 4. Record on the IADC report. The acceptable lower limit is 45 seconds closing time and 1200 psi remaining pressure. Tvpical BOP Stack Test 1. Fill BOP stack and manifold with water. 2. Check that all hold-down screws are fully retracted. Predetermine depth that test plug will seat and seat in wellhead. Run in lock-down screws in head. 3. Close annular preventer, chokes, and bypass valves on the manifold. All others open. 4. Test all components to 250 psi and hold for 3 minutes. Increase pressure to 5000 psi and hold for 3 minutes. Bleed back to zero psi. 5. Open annular preventer and manual kill and choke line valves. 6. Close top pipe rams and HCR valves on kill and choke lines 7. Test to 250 psi and 5000 psi as in step 4. Continue testing all valves, lines, and chokes with a 250 psi low and 5000 psi high. Test as in step 4. Do not pressure test any choke that is not a full closing positive seal choke. 8. Open top pipe rams and close bottom pipe rams. Test bottom rams to 250 psi and 5000 psi for 3 minutes. 9. Open pipe rams. Back off running joint and pull out of hole. Close blind rams and test to 5000 psi for 3 minutes. Bleed to zero psi. 10. Open blind rams and recover test plug. Make sure manifold and lines are full of Arctic diesel and all valves are set in the drilling position. 11. Test standpipe valves to 5000 psi for 3 minutes. 12. Test kelly cocks and inside BOP to 5000 psi. 13. Record test information on blowout preventer test form. Sign and send to drilling supervisor. 14. Perform BOPE test once per week and functionally operate BOPE daily. 6. Drilling Spool, 13-5/8" x 5000 psi, w/2 Side Outlets, Nabors 7. Adapter Flange, 13-5/8 x 5,000 psi bottom, 11" X 5,000 PSI top 8. Double Ram BOP, 11" x 5000 psi, with Dual Offset Pipe Rams 01 Top and Blind Rams on Bottom, Nordic 9. Annular BOP, 11" x 5000 psi, Hydril GK, Nordic 10. Choke Valve, Manual Operation, 4-1/16" x 5,000 psi, Nabors 11. Choke Valve, Hydraulically Operated, 4-1/16" x 5,000 psi, Nabors 12. Kill Line Valve, Manual Operation, 3-1/8" x 5,000 psi, Nabors 13. Kill Line Valve, Hydraulically Operated, 3-1/8" x 5,000 psi, Nabors OR G '^ A' prepared by . I Steve McKeever , , .... 6n/01 ( ( lC-117 Drillinq Hazards Summary (SEE WELL PLAN FOR DETAILED DISCUSSION OF THESE RISKS) 9-7/8" Open Hole / 8-5/8" x 7-5/8" Casina Interval Hazard Broach of Conductor Risk Level I Mitigation Strategy Low Monitor cellar continuously during interval. Gas Hydrates Low Running Sands and Gravels Moderate Abnormal Reservoir Pressure Lost circulation Hole swabbing on trips Low Low Moderate Control drill, Reduced pump rates, Reduced drilling fluid temperatures, Additions of Driltreat. Maintain planned mud parameters, Increase mud weight, use weighted sweeps, run gravel isolation string. Diverter drills, increased mud weight. Reduced pump rates, mud rheology, LCM Trip speeds, Proper hole filling, pumping out 1C-133 Drilling. Hazards Summary 0 RreO~d. ~~N.. la~r, C. .1ambers 2/18/01 I ,I , t¡" 'j a. West Sak lC-117 Dual (urpose Welt, Cement Loads and CemCA( ~ Summary. 35% Excess Below permafrost, 250% Above permafrost with 50 bbls to surface. 9-7/8" Openhole. TD @ 5174 MD. 7-5/8", 29.7# Casing. Base of permafrost @ 1916' MD. Port collar for no cement to surface contingency. Port Collar @ 1000' MD Tail Slurry TOC @ 4113' MD (500' above D Sand). ECP at 4708' MD. Volume Cales: Pump 40 bbls CW preflush, 50 bbls MudPUSH XL @ 10.2 ppg. Cement from TD to 4113' MD with Class G + adds @ 15.8 ppg, and from 4113' to surface with AS Lite @ 10.7 ppg. Leave cement in casing for ECP inflation. Lead Slurry Requirements: AS Lite @ 10.7 ppg, Class G + 50% D124, 3.5% D44, 0.4% D46, 30% D53, 1.5% Sl, 1.5% D79 - 4.44 ft3/sk (4113' - 1916') x 0.2148 f13/ft x 1.35 (35% excess) 1916' x 0.2148 x 3.5 (250% excess) 50 bbls cement to surface Total 2358.28 f13/4.44 ft3/sk = 637.08 ft3 = 1440.45 ft3 = 280.75 ft3 = 2358.28 f13 = 531.14 sks Round upto 535 sks Tail Slurry Requirements: Expanding Cement @ 15.8 ppg, Class G + 0.45% D65, 0.3% Ml17, 2.0 gps D600G, 0.1 % D135, 0.2% D47, 3.0% D174 - 1.2 ft3/sk (5174' - 4113') x 0.2148 ft3/ft x 1.35 (35% excess) 80' (shoe joints) x 0.2578 f13lft (5094' - 4708') x 0.2578 f13/ft (5 bbls above ECP) Total 455.87 ft3/1.2 f13/sk = 307.66 ft3 = 20.62 ft3 = 99.51 ft3 = 28.08 ft3 = 455.87 ft3 = 379.9 sks Round upto 385 sks CemCADE* Summary: Fluid sequence: Establish circulation using FW. 40 bbl CW100 preflush, Drop Bottom Plug, 50 bbls 10.2 ppg MudPUSH XL spacer, 535 sks (423 bbls) AS Lite Lead, 275 sks (59 bbls) Class G + adds, Drop Bottom Plug, Pump additional 100 sks (21 bbls) Class G+ adds on top of the plug. Displacement is approximately 216 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. Estimated maximum surface pressure during the job is 850 psi. 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 < 12, Ty < 12, as thin and light as possible for effective mud removal. 04-27 -2001 AT O~, G, ^'A~ (! Well # 1C-117, AFE #AK0172 West Sak Dual Purpose Well Completion Schematic Sheet 1 of 3: Casing String Details Tubing Head, Vetco-Gray Horizontal for Dual Completion, AP111" 5000 psi Flange up x Vetco 13-5/8" Female Overshot Bottom Landing Ring: Vetco-Gray, 16" Weld on Bottom x 13-5/8" Male Overshot Top 16" Conductor ~ @ +/-158' MD \ I ~ I I ( PHilliPS Alaska, Inc. A Subsidiary of PHilLIPS PETROLEUM COMPANY Nabors Rig 245 RKB @ 0' Eastings: 561,805.95 Northings: 5,968,680.39 Elevation: 102.0' AMSL ~Casing Hanger: ~ Vetco-Gray, with 8-5/8", 36#, Hydril511 pin down x Acme box up (2) Joints Casing: . 8-5/8",36#, N-80, Hydril 511 I ~ Crossover: 8-5/8", 36#, N-80 Hydril 511 Box by 7-5/8",29.7#, L-80, BTC Pin Port Collar: TAM, 7-5/8", 29.7#, L-80, BTC Pin Set @ +/- 1000' MD / 998' TVD ~(x) Joints Casing: 7-5/8",29.7#, L-80, BTCM External Casing Packer ~ Baker Model CTC 'Payzone', 30 ft length, 7-5/ ~ 81" 29.7#, L-80, BTCM, with 8 ft handling pup above and 3 ft handling pup below. Set at depth to isolate 'B' Sand from' A' Sand ~(X) Joints Casing: 7-5/8",29.7#, L-80, BTCM . Float Collar: Weatherford 7-5/8", 29.7#,BTCM (2) Joints Casing: 7-5/8",29.7#, L-80, BTCM . ~ ~ Float Shoe: ~ Weatherford 7-5/8", 29.7#,BTCM TD 9-7/8" Hole: 5,180' MD / 4,280' TVD 1 C-117 Completion Schematic Sheet 1 of 3: Casing String Details prepared by Steve McKeever June 16, 2001 o.~"G NAL ( Well # 1C-117, AFE #AK0172 West Sak Dual Purpose Well Completion Schematic Sheet 2 of 3: 'A' Sand Completion Details See Sheet 3 for 'B' and 'D' Sand Completion Details <J <J <], <J "C s::: co U) co ,.. . -.::t ,.. } ~ (,) co c.. ã) > co ... CJ , A' Sand Perforations -<: <q <q Plug Back TD @ +/- 4,980' MD ;çi ... ,. \J -i ; ~;. .~; ~..i 11'1111 '1',1,1 ',11',1 1,'1'1' 1,',1,1 11',1,1 1,111,1 111111' 1"11,1 11'1111 'lilli' ',11'1' 11'111' 1I11111 111,11' '111',1 1,11111 11'11,' 11'1111 11'1111 ( '11,11' 1111111 1,11'11 1,'111' 1111111 111,111 111,111 ( PHILLIPS Alaska, Inc. A Subsidiary of PHilLIPS PETROLEUM COMPANY Packer: Baker Model SC-1, w/ 80-40 Seal Bore Extension and Sliding Sleeve. Set Above Top A-Sand Perforation. Gravel Pack Extension: Baker Model "S", Size 80-40 with Sliding Sleeve and lower extension, 5-1/2",18#, SLHT Pin x 5" 18# SLHT Pin XO: 5",18#, SLHT Box by 4",9.5#, SLHT Pin Tubing Pup: 4 ft long, 4", 9.5#, SLHT Box x Pin Nipple: 'XN', , 2-3/8", with 1 .875" Polished Bore and 1.791" No-Go, installed into nipple reducer of 4" 'XN' Nipple Nipple: 'XN', ,4",9.5#, SLHT Box x Pin, with 3.313" Polished Bore and 3.135" No-Go, with nipple reducer XN lock installed. Shear Out Safety Joint: Baker Model GPR-24, 4", 9.5#, SLHT Box x Pin Excluder: Baker 2000, 4", 9.5#, SLHT Box x Pin Screen: Bakerweld 140,4",9.5#, SLHT Box x Pin Bull Plug: Baker, 4", 9.5#, SLHT Box up . .. I:: ~ Bridge Plug: .,. Baker Model N-1, 7-5/8", 29.7#, Size 4AA . ., Set +/- 10 feet below bottom perforation. r:",;;" :> .~.:... 7-5/8", 29.7#, L-80 casing @ 5,180' MD / 4,280' TVD 1 C-117 Completion Schematic Sheet 2 of 3: :4' Sand Gravel Pack Details prepared by Steve McKeever June 16,2001 )H. G.-NA~ ( Well # 1C-117, AFE #AK0172 West Sak Dual Purpose Well Planned Completion Schematic Sheet 3 of 3: 'B' & 'D' Completion Details Wellhead & Tree: ABB Vetco Gray, Dual Horizontal with Coil Hanger II. . ~~, - - 3-1/2 Tubmg, 9.2#, L-80, Hydnl 511 ¡~ ) Landing Nipple: for Weatherford Jet Pump, with 5' x 2.813" Polished Bore and No-Go at Top. 211 Coil Tubing: Jet Pump: Weatherford, for 2.813" Polished Bore, and connection to 2" Coil 2-3/811 Tubing 4.6#, L-80, Hydril 511 Gaslift Mandrel: Camco Model KBMM, 2-3/8", with 6' Handling Pups top and bottom 2-3/811 Tubing Pups 4.6#, L-80, Hydril 511 Telescoping Swivel: Baker, with 2 ft stroke, 2-3/8", 4.6# with XO on bottom from 2-3/8" NU 10rd to Hydril511pin 2-3/811 Tubing 4.6#, L-80, Hydril 511 Sliding Sleeve: Baker Model Slim line eMU, 2-3/8" x 1.875",with XO's top and bottom from 2-3/8" RTS-8 to Hydril 511, Set above Top Perforation. 2-3/811 Tubing: 4.6#, L-80, Hydril511 Landing Nipple: Halliburton 'X' , 2-3/8", 1.875" Polished Bore, Hydril 511 Box and Pin Waterflood Mandrel: Camco Model KBMGW, 2-3/8", with 6' Handling Pups top and bottom Polished Bore Receptacle: Baker, 2-3/8" x 1.875" Bore, 2-3/8", Hydril 511 Tubing Joint: 30 ft long, 2-3/8", 4.6#, L-80, Hydril511 Landing Nipple: Halliburton 'XN' ,2-3/8", 1.875" Polished Bore, 1.791" No-Go, Hydril511 Box and Pin PHilliPS Alaska, Inc. A Subsidiary of PHILLIPS PETROLEUM COMPANY -"" ... 3-1/211 Tubing, 9.2#, L-80, Hydril 511 Xo: 3-1/2" 9.2#, L-80, Hydril 511 Box by 2-3/8" 4.6# L-80 Hydriol 511 Pin 2-3/811 Tubing, 4.6#, L-80, Hydril 511 Tubing Anchor: Baker Parallel K22, 2-3/8" x 2.688", wI XO's above to 2-3/8" Hydril 511 box ScoopHead: Baker, Size 470, 2-3/8" x 2.688", with XO's below to Hydril 511, Made up in long string. 2-3/811 Tubing Pups, 4.6#, L-80, Hydril 51' Dual Packer @ +1- 4950' (Top of 'O'): Baker Model 4704 GT, wI XO's above & below to Hydril 511 from NU 10rd pins top & bottom. 2-3/811 Tubing, 4.6#, L-80, Hydril 511 Blast Joints: 2-3/8", 4.6#, Hydril 511, Spaced out to be opposite the Slidign Sleeve 2-3/811 Tubing, 4.6#, L-80, Hydril 511 Blast Joints: 2-3/8", 4.6#, Hydril 511, Spaced out to be opposite the Gas Lift mandrel 2-3/811 Tubing, 4.6#, L-80, Hydril 511 ~ Dual Packer @ +1- 4669' (Mid 'C' Shale): Baker Model 4704 GT, wI XO's above & below to Hydril 511 from NU 10rd pins top & btm. 2-3/811 Tubing, 4.6#, L-80, Hydril 511 Blast Joints: 2-3/8", 4.6#, Hydril 511 2-3/811 Tubing, 4.6#, L-80, Hydril 511 Seal Assembly: Baker, 80-40 with Snap Latch, Indexing Mule Shoe, 14 ft long, wI 6 foot handling pup (2-3/8", 4.6#, Hydril 511) Packer @ +/- 4714' (Top 'A-4' Sand) Baker Model SC-1, wI 80-40 Seal Bore Extension and Sliding Sleeve. Set Above Wireline Entry Guide:, -g Top A-Sand Perforation prior to 'A' Sand 2-3/8",4.6#, Hydril511 box Jf :::: ~, : gravel pack. 7-518" External Casing Packer ~ ':: . I ~ ~ S Sh f" S ~ 1C-117PJannedCompJetion Schematic ee eet 2 or A and I ~ Sheet 3 of 3: '8' and '0' Sand Completion Details Completion Details ~ prepared by Steve McKeever 0 ~. 'G 'n?:2001 Tubing Pup Joint: 10 ft long, 2-3/8", 4.6#, L-80, Hydril 511 ( /PHI~PS'~ TfI7I !:~st~~!~~,~~~~~d~~~ ~ Post Office Box 100360 Anchorage. Alaska 99510-0360 Randy Thomas Phone(907)265~O Fax: (907) 265-1535 June 18, 2001 Alaska Oil and Gas Conservation Commission 333 West ih Avenue Suite 100 Anchorage, Alaska 99501 (907) 279-1433 Re: Application for Permit to Drill, West Sak Dual Purpose WelllC-117. Dear Commissioners: PhillipS Alaska, Inc. hereby applies for a Permit to Drill an onshore well in the West Sak Oil Pool, #lC- 117. This well will be completed with two strings of tubing, with one string being used for injection to provide pressure support for production from the West Sak "0" and "8" sands, and the other string being used for oil production from the West Sak "A" sand. The expected spud date for this well is June 30, 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 265-6830 or Steve McKeever at 265-6826. Sincerely, T<<,~ ...'~ <. "---- Randy Thomas GKA Drilling Team Leader ------ RECEIVED JUN 1 82001 Alaska Oil & Gas Cons. Commission Anchorage ORIGINAL ( TRANSMIT AL LETTER CHECK LIST CIRCLE APPROPRIATE LETTER/PARAGRAPHS TO BE INCLUDED IN TRANSNUTTAL LETTER CHECK 1 STANDARD LETTER DEWLOPJ DEVELOPMENT REDRlLL EXPLORATION INJECTI07 INJECTION WELL REDRILL WELL NAME CHECK WHAT APPLIES ADD-ONS (OPTIONS) MULTI LATERAL (If api number last two (2) digits are between 60-69) PILOT HOLE (PH) ANNULAR DISPOSAL <->NO ANNULAR DISPOSAL <-> YES ANNULAR DISPOSAL THIS WELL "CLUE" The permit is for a new wellbore segment of existing well --' Permit No, API No. Production should continue to be reported as a function of the original API number stated above. In accordance with 20 AAC 25.005(f), all records, data and logs acquired for the pilot hole must be. clearly differentiated in. both name (name on permit. plus PH) and API number (50 -70/80) from records, data and logs acquired for well (name on permit). Annular disposal has not been requested. . . Annular Disposal of drilling wastes will not be approved. .. Annular Disposal of drilling wastes will not be approved. . . DISPOSAL INTO OTHER Please note that an disposal. of fluids generated... ANNULUS. /.... œYES+ þ-u- ~~,~~.fo ~4- ~L...-k' SPACING EXCEPTION Enclosed is the approved application for permit to drill the above referenced well. The permit is approved subject to full compliance with 20 AAC 25.055. Approval to perforate and produce is contingent upon issuance of a conservation order approving a spacing exception. (Companv Name) will assume the liability of any protest to the spacing exception that may occur. 'T~\:~ '\S ö. ~~~\ v0<t\" ~~0:r~~~II\.-\- ~~<tN1~<C Templates are located m drive\jody\templates '. '... -. . . . :: '.: ':'~~'>:':/:~':~;:~:~~: }.:':::::~;. ::':--; >. :~:., Americëllt Expresse ~._-.- ~-'-- """'-"-- 'Cash Advance>Draft 142 DATE l8~re,.)~2/æ)( 82-1011021 ~î~if'~~~JrSN~ð£.lI-k. ~F&- / .4~~.c.. ~.;....i.........;.i.¡........1.(~~íoo.O() I - ..Oú.¿LL..fd,~ --f/,è.. ~...... . DOLLARS Issued by Integrated Payment System, Inc. Englewood. Co/Qrado rXv.....;.~.A.....=di..o.....R.....A....... MO.......................~S6~~~ /'þ;"--!ff~- bfa~ . III 0 . 7 5000 5 :1 b III 0 .1. 2 Payable at Norwest Bank Of Grand Junction - Downtown. NA Grand Junction. Colorado PERIOD ENDING Ie. ll7 I: .0 2.001.001: :1 5 . -----,,~.--../ . ~~~~¡ { :} !Æ~~~~~~ ~ AI1ASIiA. OIL AND GAS CONSERVATION COMMISSION TONY KNOWLES, GOVERNOR 333 W. 7rH AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 James Trantham Drilling Engineer Supervisor . Phillips Alaska, Inc. P.O. Box 100360 Anchorage AK. 99510-0360 Re: Kuparuk River Unit 1 C-127 Phillips Alaska, Inc. Permit No: 201-114 SurLoc: 1642' FSL, 924' FWL,SEC 12, TIIN, RI0E, UM Btmhole Loc. 338' FSL, 1339' FEL, SEC 11, TI1N, RI0E, UM Dear Mr. Trantham: Enclosed is the approved application for permit to drill the above referenced well. The permit to drill does not exempt you. from obtaining additional. permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all. other required permitting determinations are made. Annular disposal has not been requested as part of the Permit to Drill application for KRU .1-G-Jt \c-Ill ~ Based on our current records, no annuli are currently approved for disposal on lCpad. The blowout prevention equipment (BOPE) must be tested in accordance with 20AAC 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 performed 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. . aniel T. Seamount, Jr. Commissioner BY ORDER OF THE COMMISSION DATED this .} s+t'day of June, 2001 jjcÆnclosures cc: Department ofFish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. !f.l!.?t WELL PERMIT CHECKUST COMPANY /'4':#, /S WELL NAME I G - /J;7 PROGRAM: exp - dev 2Š- redrll- serv X- wellbore seg _anl1. disposal para req- FIELD & POOL 1t.'fo/~o INITCLASS LJ~¿/ /-~~~-GEOLAREA F''7crl UNIT# ///Gò ON/OFFSHORE ~AJ ADMINISTRATION 1. Permittee attached. . . . . . . .. . . . . . . . . . . . . . . Y N 2. Lease number appropriate. . . . . . . . . . . . . . . . . . . Y N -d.,l . j/ . ~ / . . / /r 3. Unique well ~ame and number. .. . . . . . . . . . . .' " . . Y N a.. r Y"~ J t9-/Y <5 &f'-- /¿~ ~_C>~/ /'1-//6 /.:V) 4. Well locatedlna defined pool.. . . . . . . . . . . . . . . . . Y N !. / / I r b) '/)y// 5.. Well located proper d~stance from drilling unit boundary. . . . Y N a - < 5:1.~ / .. l ¿¿.;~ '- J-t}G - <0. (... . ..' ð~..... 6. Well located proper distance from other wells.. . . . . . . . . Y N ~¿ I (/ - r J / tu. / J / / . / /;/ 7. Suffic~ent a~eage a. vailabl~'in drilling unit.. . ; . . . . . . . . Y N. v'T'/d/'l<r 07 /J...tÓ'¡ ('.Jd/I.ï. n<ß/I'/r /'1' ¡.'-< Jr>.Tco/ --if?rJ' 8. If deviated, IS wellbore plat Included.. . . . . . . . . . . ... . Y N J/ Vb' J /) .Á (/ r 9. Operatoronlyaffeded party.. . . . . . . . . . . . . . . . . . Y N 14'-- ~T£,~/""4/u//P;"~¿'¿~./ OJ r 10. Operator has appropriate bond in force. . . . . .. . . . . . . Y N / 11. Permit can be issued without conservation order. . . . . . . . Y N AWB ~~T~/ 12. Permit can.be issued without administrative approval.. . . . . Y N /7C- éýlñ'¡ê>/ 13. Can permit be approved before 15-day wait.. . .. . . . . . . Y N ENGINEERING 14. Condudor string provided . . . . . .. . .. . . . . . . .. . ~ N 15. Surface casing proteds all known USDWs. . .. . .. . . . . N 16. . CMT vol adequate to circulate on conductor & surf csg. . . . . N . 17. CMTvol adequate to tie-in long string to surf csg. . . . . . . . ;'-N \..)~ - ~~~~~ ~c;.' "'=>~'C'-.\J 18. CMT will cover all known produdive horizons. . . . . .. . . . . ~ N 19. Casing designs adequate for C,T, 8 & permafrost. . . . . . . . N , \ 20. Adequate tankage or reserve pit.. . . . . . . . . . . . . .. . N O$.\?\\ ~S~ c. I "O'\"1è.S<c."-J~ .t>\ ~ 21. If a re-drill, has a 10-403 for abandonment been approved. . . ~ ~ ..:J ~ t,f'. ~ \ 22. Adequate wellbore separation proposed.. . . . . . . . . . . . N <- \c~ CJ.. ~~~~\\~~~\«.è=\ . 23. If diverter required, does it meet regulations. . . . . . . . . . N 24. Drilling .fluid program schematic & equip list adequate. . ~ . . Y N . 25. 80PEs, do they meet regulation. . . . . . . . . . . . . . . . N. ~ ~ Q.. ~ - ~ " I .~ ~ '- '5>f:JDf'.v...-. (- ~. . . ~ IE . 26. BOPE press rating appro. priate; test to 7.f>OO psig. N\-A..""S.~ =~"'" - \5:>u\"",'. Cß!>\ "'s. s \ '>. ~ ' ICY-~// t ' II <ï. 27. Choke manifold compliesw/API RP-53 (May 84). . . . . . . . N ?Vc...(:) c\~'I'..~ \Ð. ~s-\-~ ~~~\ . 28. Work will occur without operation shutdown. . . . . . . . . . .)i., . , 29. Is presence ofH2S gas probable.. . . . . . . . . . . . . . . . Y <.!V~ ~ '\s ~'f'..\:\~\'t ' \<.J~\?~~û\~ ~fS:.~~~~~Q\o...~~ GEOLOGY. 30. Permit can be issued w/o hydrogen sulfide measures. . . ... )(N . 31. Data presented on potential overpressure zones. . .. . . ., Y /J I /7 32. Seismic analysis of shallow gas zones. . . . . . . . . . '.' . Y / l/, 'I ' A~R ..-Dj}T9' 33. Seabed condition survey (if off-shore). . . . . . . . . . . . . N . . n¿. F-:f' It! d 34. Contad name/phone for weekly progress reports [exploratory onl Y N ~ . .. D \0."-. --\0 ~ ~Q. t 0. t'\~~C> ().<'-,,~ \ ~c;... ~t'... \ '- <::) "-. \<a. ~~ ~ \,)..jCè. \ \ . ANNULAR DISPOSAL35. With proper cementing records, this plan. \-,,"'_~_'-I t)'bL. ,4 G14 bH''1"~D <...... ':( . . HL'^ I L ."""é~ WAA (A) will contain waste in a suitable receiving zone; . . . , . . . Y N p~- ) U . ~ ~ Cl:::., 0""> .~ í-?P\¿ c.,û ~T I' - . -, APPR DATE (8) will not contaminate freshwater; or cause drilling waste. .. Y N to surface; (C) will not impair mechanical integrity of the well used for disposal; Y N (D) will not damage producing formation or impair recovery from a Y N pool; and (E) will not circumvent 20 AAC 25.252 or 20 AAC 25.412. Y N GEOL~Y: ENGINEERING: UIC/Annular COMMISSION: ~~f/YÍ ¿ Flm WM 8~s (rrr T~M)$J'l1Y1 C:>(c, JMH cJ1tU{ ~(zj61 J /þ) c 0 Z 0 -t ~ ;U -t m Z -t :t: en :Þ ;U ) m :Þ Commentsllnstructions: c:\msoffice\wordian\diana\checklist (rev. 11/01/100) ( Well H ¡story File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPEN.DIX. No special 'effort has been made to chronologically organize this category of information. c!ds, Memory Multi-Finger Caliper Log Results Summary Company: Log Date: Log No. : Run No.: Pipe1 Desc.: Pipe1 Use: ConocoPhillips Alaska, Inc. August 8, 2005 7514 1 3.5" 9.3Ib. L-80 Tubing Well: 1 C-117 Field: Kuparuk State: Alaska API No.: 50-029-23027-00 Top Log IntvI1.: Surface Bot. Log IntvI1.: 4,583 Ft. (MD) Inspection Type : Corrosive & Mechanical Damage Inspection COMMENTS: This caliper data is tied into the Sliding Sleeve @4,533' (Driller's Depth). This log was run to assess the condition of the 3.5" tubing with respect to corrosive and mechanical damages. The 3.5" tubing logged appears to be in good to fair condition with respect to corrosive damage, with the exception of a maximum wall penetration of 43% in pup joint 141.1 (4,568'). The damage appears in the form of scattered, isolated pitting, often in a line between joints 105 and 140 (3,350' - 4,583'). No significant areas of cross-sectional wall loss or I.D. restrictions are recorded throughout the tubing 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: Corrosion Line of Corrosion Line of Pits Line of Pits Isolated Pits ( 43%) ( 40%) ( 27%) ( 26%) ( 22%) Jt. Jt. Jt. Jt. Jt. 141.1 @ 141.3 @ 140.7 @ 140.6 @ 140 @ 4,568 Ft. (MD) 4,581 Ft. (MD) 4,548 Ft. (MD) 4,538 Ft. (MD) 4,502 Ft. (MD) MAXIMUM RECORDED CROSS-SECTIONAL METAL lOSS: No significant areas of cross-sectional wall loss (> 9%) are recorded throughout the tubing logged. MAXIMUM RECORDED ID RESTRICTIONS: No significant I.D. restrictions are recorded throughout the tubing logged. ':' "''",'' ""r\¡'-'~", nUG ') C) "1!l[It: ,~~l",I'-\~'B ~t:u 11 ] t~.J Ie, t.,-, _ J I Field Engineer: L. Mills-Dawson Analyst: M. Tahtouh Witness: T. Senden I ProActive Diagnostic Services, Ine. I P.O. Box 1369, Stafford, TX T/497 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 > :2. ~ \- I J... \. ck3s". Well: Field: Company: Coun try: 1 C-11 7 Kuparuk ConocoPhillips Alaska, Inc. USA I Tubing: Nom.OD 3.5 ins Weight 9.3 ppf Grade & Thread L-80 Penetration and Metal loss (% wall) _ penetration body 200 !IiI\R metal loss body 150 ~ 100 SO 0 ,-, I ¡ o to 1 to 10 to 20 to 40 to over 1% 10% 20% 40% 85% 85% Number of joints analysed (total = 159) pene. 0 6 1 46 6 1 loss 9 1 SO 0 0 0 o o Damage Configuration ( body) 150 100 - so o isolated pitting general line ring hole / poss corrosion corrosion corrosion ible hole Number of joints damaged (total = 149) 113 4 32 0 0 PDS Report Overview Body Region Analysis Survey Date: Tool Type: Tool Size: No. of Fingers: Analyst: Nom.lD 2.992 ins August 08/ 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) ~ metal loss body SO _ penetration body o 1 GLM 1 GLM2 GLM3 100 45 95 Bottom of Survey = 141.4 Analysis Overview page 2 ~ PDS KEPORT JOINT TABULATION SHEET Pipe: 3.5 in 9.3 ppf L-80 Well: 1 C-11 7 Body Wall: 0.254 in Field: Kuparuk Upset Wall: 0.254 in Company: ConocoPhillips Alaska, Inc. Nominal 1.0.: 2.992 in Country: USA Survey Date: August 08, 2005 Joint Jt. Depth Pen. Pen. Pen. Metal Min. Damage Profile No. (Ft.) Upset Body % Loss 1.0. Comments (% wall) (Ins.) (Ins.) % (Ins.) 0 50 100 1 46 0 0.04 15 4 2.94 Shallow corrosion. 1.1 77 0 0.02 8 0 2.94 PUP 1.2 78 0 0.03 11 .2 2.94 PUP 1.3 86 0 0.04 15 ') 2.92 PUP Shallow pitting. j 1.4 95 0 0.04 14 1 2.93 PUP Shallow pitting. 2 103 0 0.05 19 6 2.93 Shallow pitting. 3 134 0 0.04 17 4 2.94 Shallow pitting. 4 166 0 0.04 18 7 2.94 Shallow pitting. 5 197 0 0.03 13 3 2.94 Shallow pitting. 6 227 0 0.04 15 6 2.94 Shallow pitting. 7 259 0 0.03 13 5 2.94 Shallow pitting. 8 290 0 0.04 16 5 2.95 Shallow pitting. 9 322 0 0.04 17 5 2.94 Shallow pitting. 10 353 0 0.04 14 4 2.95 Shallow pitting. 11 383 0 0.03 13 .2 2.94 Shallow pitting. 12 415 0 0.04 15 .2 2.93 Shallow pitting. 13 446 0 0.04 16 4 2.91 Shallow pitting. 14 477 0 0.03 12 4 2.94 14.1 509 0 0.03 13 .2 2.92 PUP Shallow pitting. 14.2 515 0 0 0 0 2.81 OS Nipple 14.3 517 0 0.03 12 .2 2.92 PUP Shallow pitting. Lt. Deposits. 15 523 0 0.05 18 5 2.94 Shallow pitting. 16 554 0 0.04 16 5 2.94 Shallow pitting. 17 585 0 0.04 15 5 2.94 Shallow pitting. 18 617 0 0.04 14 5 2.94 Shallow pitting. 19 647 0 0.04 16 6 2.94 Shallow pitting. 20 679 0 0.04 16 6 2.95 Shallow pitting. 21 710 0 0.03 11 4 2.94 22 741 0 0.04 15 .2 2.94 Shallow pitting. 23 772 0 0.03 13 3 2.93 Shallow pitting. 24 804 0 0.04 17 4 2.92 Shallow pitting. 25 835 0 0.03 13 4 2.93 Shallow pitting. 26 867 0 0.04 15 6 2.93 Shallow pitting. 27 898 0 0.04 18 4 2.95 Shallow pitting. 28 929 0 0.03 13 2 2.93 Shallow pitting. 29 961 0 0.03 13 2 2.91 Shallow pitting. 30 992 0 0.04 15 4 2.93 Shallow pitting. 31 1023 0 0.03 13 3 2.94 Shallow pitting. 32 1055 0 0.04 17 2 2.94 Shallow pitting. 33 1086 0 0.04 16 4 2.95 Shallow pitting. 34 1117 0 0.03 13 6 2.93 Shallow pitting. 35 1149 0 0.03 13 3 2.92 Shallow pitting. 36 1180 0 0.04 14 2 2.95 Shallow pitting. 37 1212 0 0.04 14 2 2.94 Shallow pitting. 38 1243 0 0.03 13 5 2.92 Shallow pitting. 39 1274 0 0.03 12 4 2.94 Shallow pitting. 40 1306 0 0.03 13 1 2.94 Shallow pitting. 41 1337 0 0.04 14 6 2.94 Shallow pitting. 42 1368 0 0.03 13 5 2.94 Shallow pitting. 43 1400 0 0.03 13 2 2.94 Shallow pitting. I Penetration Body !\~J! Metal Loss Body Page 1 PDS(KEPORT JOINT TABULATION( SHEET Pipe: 3.5 in 9.3 ppf L-80 Well: 1 C-ll 7 Body Wall: 0.254 in Field: Kuparuk Upset Wall: 0.254 in Company: ConocoPhillips Alaska, Inc. NominaII.D.: 2.992 in Country: USA Survey Date: August 08, 2005 Joint Jt. Depth Pen. Pen. Pen. Metal Min. Damage Profile No. (Ft.) Upset Body DID Loss I.D. Comments (% wall) (Ins.) (Ins.) o,{, (Ins.) 0 50 100 44 1431 0 0.03 13 5 2.94 Shallow pitting. 45 1463 0 0.04 14 4 2.93 Shallow pitting. 46 1494 0 0.04 16 3 2.92 Shallow pitting. 47 1525 0 0.05 19 4 2.93 Shallow pitting. 48 1557 0 0.03 13 , 2.93 Shallow pitting. .J 49 1588 0 0.03 12 3 2.93 Shallow pitting. 50 1620 0 0.04 16 6 2.94 Shallow pitting. 51 1651 0 0.04 16 6 2.93 Shallow pitting. 52 1682 0 0.04 15 2 2.93 Shallow pitting. 53 1714 0 0.03 13 3 2.95 Shallow pitting. 54 1745 0 0.04 15 7 2.93 Shallow pitting. 55 1777 0 0.04 15 4 2.94 Shallow pitting. 56 1808 0 0.04 15 5 2.94 Shallow pitting. 57 1839 0 0.04 14 2 2.92 Shallow pitting. 58 1871 0 0.04 17 2 2.92 Shallow pitting. 59 1902 0 0.03 12 2 2.90 60 1934 0 0.03 13 6 2.91 Shallow pitting. 61 1965 0 0.04 16 4 2.93 Shallow pitting. 62 1996 0 0.04 14 3 2.93 Shallow pitting. 63 2028 0 0.04 17 3 2.93 Shallow pitting. 64 2059 0 0.03 13 0 2.91 Shallow pitting. 65 2090 0 0.04 14 2 2.91 Shallow pitting. 66 2122 0 0.04 15 6 2.94 Shallow pitting. 67 2153 0 0.04 17 3 2.94 Shallow pitting. 68 2185 0 0.04 14 5 2.92 Shallow pitting. 69 2216 0 0.04 16 2 2.93 Shallow pitting. 70 2247 0 0.04 16 4 2.92 Shallow pitting. 71 2279 0 0.03 13 7 2.94 Shallow pitting. 72 2310 0 0.04 15 6 2.94 Shallow pitting. 73 2341 0 0.05 18 2 2.93 Shallow pitting. 74 2373 0 0.04 16 1 2.92 Shallow pitting. 75 2404 0 0.03 12 2 2.92 Shallow pitting. 76 2436 0 0.04 14 5 2.95 Shallow pitting. 77 2466 0 0.03 13 6 2.93 Shallow pitting. 78 2497 0 0.04 14 5 2.91 Shallow pitting. 79 2529 0 0.03 13 2 2.93 Shallow pitting. 80 2557 0 0.04 16 4 2.94 Shallow pitting. 81 2588 0 0.04 17 4 2.93 Shallow pitting. 82 2620 0 0.03 13 3 2.92 Shallow pitting. 83 2651 0 0.04 15 3 2.92 Shallow pitting. Lt. Deposits. 84 2682 0 0.04 15 2 2.93 Shallow pitting. 85 2714 0 0.03 13 8 2.93 Shallow pitting. 86 2745 0 0.04 14 9 2.91 Shallow pitting. 87 2777 0 0.04 18 3 2.94 Shallow pitting. 88 2808 0 0.04 15 4 2.93 Shallow pitting. 89 2839 0 0.04 16 4 2.89 Shallow pitting. Lt. Deposits. 90 2871 0 0.04 15 1 2.90 Shallow pitting. 91 2902 0 0.04 17 6 2.94 Shallow pitting. 92 2933 0 0.03 13 2 2.93 Shallow pitting. 93 2965 0 0.05 18 8 2.94 Shallow pitting. I Penetration Body r:::;/.: Metal Loss Body Page 2 1\ '~ PDSKEPORT JOINT TABULATION SHEET Pipe: 3.5 in 9.3 ppf L-80 Well: lC-117 Body Wall: 0.254 in Field: Kuparuk Upset Wall: 0.254 in Company: ConocoPhillips Alaska, Inc. N ominaII.D.: 2.992 in Co u ntry: USA Survey Date: August 08, 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 94 2996 0 0.05 19 7 2.94 Shallow pitting. 95 3028 0 0.04 15 ") 2.94 Shallow pitting. Lt. Deposits. .:> 96 3059 0 0.04 14 6 2.94 Shallow pitting. 97 3089 0 0.04 16 4 2.92 Shallow pitting. 98 3121 0 0.03 13 .3 2.92 Shallow pitting. 99 3151 0 0.04 15 4 2.93 Shallow pitting. 100 3182 0 0.03 13 4 2.90 Shallow pitting. 101 3213 0 0.04 14 :2 2.90 Shallow pitting. 102 3245 0 0.03 13 :2 2.88 Shallow pitting. 103 3276 0 0.04 14 2 2.93 Shallow pitting. 104 3308 0 0.03 13 ") 2.93 Shallow pitting. .:> 105 3339 0 0.04 15 7 2.93 Shallow pitting. 106 3370 0 0.04 17 .3 2.92 Line of shallow pits. 107 3402 0 0.04 17 8 2.92 Line of shallow pits. 108 3433 0 0.04 17 :2 2.92 Line of shallow pits. 109 3464 0 0.04 16 .3 2.90 Line of shallow pits. 110 3496 0 0.04 17 4 2.92 Line of shallow pits. 111 3527 0 0.03 13 4 2.93 Line of shallow pits. 112 3558 0 0.04 17 6 2.93 Shallow pitting. 113 3590 0 0.04 16 5 2.93 Line of shallow pits. 114 3621 0 0.05 18 8 2.93 Line of shallow pits. 115 3653 0 0.04 17 4 2.92 Line of shallow pits. 116 3684 0 0.03 12 :2 2.92 Line of shallow pits. 117 3715 0 0.04 14 4 2.92 Line of shallow pits. 118 3747 0 0.04 17 6 2.93 Line of shallow pits. 119 3778 0 0.04 16 .3 2.93 Line of shallow pits. 120 3809 0 0.04 15 .3 2.90 Line of shallow pits. 121 3841 0 0.04 15 7 2.92 Shallow pitting. 122 3872 0 0.04 15 7 2.92 Line of shallow pits. 123 3904 0 0.04 14 4 2.92 Line of shallow pits. 124 3934 0 0.04 15 :2 2.92 Line of shallow pits. 125 3965 0 0.03 13 .3 2.90 Line of shallow pits. 126 3996 0 0.04 16 .3 2.93 Line of shallow pits. 127 4027 0 0.04 15 6 2.91 Line of shallow pits. 128 4058 0 0.05 20 5 2.92 Shallow corrosion. 129 4090 0 0.04 17 4 2.93 Shallow pitting. 130 4121 0 0.04 17 2 2.91 Line of shallow pits. 131 4153 0 0.04 17 .3 2.91 Line of shallow pits. 132 4184 0 0.04 15 4 2.93 Line of shallow pits. 133 4215 0 0.04 16 6 2.92 Line of shallow pits. 134 4247 0 0.04 17 7 2.92 Line of shallow pits. 135 4278 0 0.06 22 3 2.91 Line of pits. 136 4309 0 0.05 19 6 2.93 Line of shallow pits. 137 4340 0 0.05 19 2 2.93 Line of shallow pits. 138 4371 0 0.03 13 :2 2.92 Line of shallow pits. 138.1 4402 0 0.02 8 4 2.88 PUP 138.2 4407 0 0 0 0 N/A GLM 1 (Latch @ 3:30) R 138.3 4416 0 0.04 14 2 2.88 PUP Shallow pitting. Lt. Deposits. 139 4422 0 0.04 15 7 2.94 Line of shallow pits. 139.1 4454 0 0.01 2 :2 2.92 PUP I Penetration Body 1j'!:'~, Metal Loss Body Page 3 ,,: ~ PDS KEPORT JOINT TABULATION SHEET Pipe: 3.5 in 9.3 ppf l-80 Well: 1 C-11 7 Body Wall: 0.254 in Field: Kuparuk Upset Wall: 0.254 in Company: ConocoPhillips Alaska, Inc. Nominal 1.0.: 2.992 in Country: USA Survey Date: August 08, 2005 Joint Jt. Depth Pen. Pen. Pen. Metal Min. Damage Profile No. (Ft.) Upset Body 0/0 loss 1.0. Comments (% wall) (Ins.) (Ins.) (X> (Ins.) 0 50 100 139.2 4459 0 0 0 0 N/A PACKER ~ 139.3 4469 0 0.02 9 1 2.91 PUP 140 4475 0 0.06 22 3 2.94 Isolated pitting. 140.1 4506 0 0.04 14 4 2.92 PUP Shallow pitting. 140.2 4512 0 0 0 0 N/A GlM 2 (latch 6:30) 140.3 4521 0 0.04 14 1 2.90 PUP Shallow pitting. 140.4 4527 0 0.01 2 1 2.94 PUP 140.5 4533 0 0 0 0 2.81 Sliding Sleeve 140.6 4537 0 0.07 26 ... 2.95 PUP Line of pits. .;) 140.7 4543 0 0.07 27 3 2.91 PUP Line of pits. It. Deposits. 140.8 4549 0 0 0 0 N/A PACKER 140.9 4557 0 0.05 21 :2 2.91 PUP Isolated pitting. 141.1 4563 0 0.11 43 5 2.90 PUP Corrosion. It. Deposits. 141.2 4569 0 0 0 0 N/A GlM 3 (latch 1 :00) 141.3 4577 0 0.10 40 3 2.92 PUP Line of orrosion. It. Deposits. 141.4 4583 0 0.01 3 :2 2.90 End of log 'Penetration Body tj\s Metal loss Body Page 4 cId······· -'..~....---. -'-..... .....~ - , . tS -. . I" Well: Field: Company: Country: Tubing: PDS Report Cross Sections 1 C-" 7 Kuparuk ConocoPhillips Alaska, Inc. USA 3.5 ins 9.3 ppf L-80 Survey Date: Tool Type: Tool Size: No. of Fingers: Analyst: August 08, 2005 MFC 24 No. 00387 1.69 24 M. T ahtouh Cross Section for Joint 141.1 at depth 4567.76 ft Tool speed = 55 NominallD = 2.992 Nominal 00 = 3.500 Remaining wall area = 98 % Tool deviation = 1 8 0 Finger , 5 Penetration = 0.'09 ins Co rrosion 0.11 ins = 43% Wall Penetration HIGH SIDE = UP Cross Sections page 1 cia. .-.. c.·.·.ru-.. ~...,...:-. .. .. ....... .- ··LS II· Well: Field: Company: Country: Tubing: PDS Report Cross Sections 1 C-ll 7 Kuparuk ConocoPhillips Alaska, Inc. USA 3.5 ins 9.3 ppf L-80 Survey Date: Tool Type: Tool Size: No. of Fingers: Analyst: August 08, 2005 MFC 24 No. 00387 1.69 24 M. T ahtouh Cross Section for Joint 141.3 at depth 4580.66 ft Tool speed = 39 Nominal 10 = 2.992 Nominal 00 = 3.500 Remaining wall area = 97 % Tool deviation = 1 7 0 Finger 10 Penetration = 0.101 ins Line of Corrosion 0.10 ins = 40% Wall Penetration HIGH SIDE = UP Cross Sections page 2 TUBING (0-4602, OD:3.500, ID:2.992) Perf (4508-4546) Perf (4572-4592) SEAL (4602-4608, OD:4.000) JOINT (4613-4617, OD:3.690) ConocoPhillips Alaska, Inc. 4572 - 4592 3794 - 3813 4620 - 4640 3841 - 3860 4656 - 4672 3876 - 3892 4678 - 4708 3898 - 3927 4718 - 4750 3937 - 3968 Gas Lift MandrelslValves st MD TVD Man Man Type Mfr 1 4407 3635 CAMCO MMG 2 4512 3736 CAMCO MMG 3 4569 3791 CAMCO MMG Other (plugs, equip., etc.) - JEWELRY Depth TVD Type 515 515 NIP 4460 3685 PACKER 4533 3756 SLEEVE-O 1C-117 API: 500292302700 SSSV Type: Nipple Annular Ruid: Reference Log: Last Tag: 4784 Last Tag Date: 9/1/2003 Casing String - ALL STRINGS Description CONDUCTOR SURF/PROD SU RF/PROD Tubing String - TUBING Size I Top 3.500 0 Peñorations Summary Interval TVD 4508 - 4546 3732 - 3768 4550 3772 PACKER 4585 3806 SLEEVE-O 4601 3822 LOCATOR 4602 3823 SEAL 4604 3825 PACKER 4607 3828 Extension 4612 3833 XO 4613 3834 JOINT 4617 3838 NIP - 4617 3838 PLUG 4618 3839 WLEG . ~ KRU 1C-117 Well Type: INJ Orig Completion: 7/812001 Last w/o: Ref Log Date: TO: 5000 ftKB Max Hole Angle: 49 deg ~ 2697 Angle ~ TS: deg ~ Angle (Bl TD: 10 deg @ 5000 Rev Reason: Correct TBG top Last Update: 12127/2004 Size 16.000 8.625 7.625 Top Bottom TVD Wt Grade Th read 0 158 158 62.50 H-40 WELDED 0 134 134 36.00 N-80 511 Hydril 134 4987 4202 29.70 L-80 BTC-MOD TVD Wt Grade Th read 3823 9.30 L-80 Eue8rdMod Status Ft SPF Date Type Comment 38 4 8/1/2002 IPERF 3 318" HSD Bottom 4602 Zone WS D,WS C WS B WSA4 WSA3 WSA3 WSA2 20 20 16 30 32 4 4 4 4 4 8/1/2002 IPERF 3 318" HSD 7/31/2002 IPERF 3 318" HSD 7/31/2002 IPERF 3 318" HSD 7/31/2002 IPERF 3318" HSD 7/31/2002 IPERF 3318" HSD V Mfr VOD Latch Port TRO 1.5 RK 0.188 0 1.5 RK 0.000 0 1.5 RK 0.000 0 Description ID 2.875 3.875 2.812 DMY DMY DMY Date Run 2/5/2003 8/1/2002 2/8/2003 Vlv Cmnt V Type CAMCO DS LANDING NIPPLE BAKER PREMIER PACKER BAKER CMU SLIDING SLEEVE W/2.812" DS PROFILE - OPENED 2/812003 BAKER S-3 PACKER BAKER 2.75" D PROFILE CMU SLIDING SLEEVE - SLEEVE OPEN 2/812003 BAKE R 80-40 NO GO LOCATOR BAKER 80-40 SEAL ASSEMBLY with 1/2" MULE SHOE BAKER FB1 RETAINER PRODUCTION PACKER BAKER MILLOUT EXTENSION 3.875 2.750 3.000 3.980 4.000 4.500 2.390 2.441 2.250 0.000 2.380 CAMCO D NIPPLE 2.25" CA-2 PLUG set 12/8/2004 BAKER WIRELlNE GUIDE ~D/-I d I / 17 /5 **** REEL HEADER **** LDWG 03/05/02 AWS 01 **** TAPE HEADER **** LDWG 03/05/02 01 *** LIS COMMENT RECORD *** ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! TAPE HEADER WEST SAK UNIT MWD /MAD LOGS # WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: # JOB DATA LDWG File Version 1.000 Extract File: LISTAPE.HED lC-117 500292302700 Phillips Alaska, Inc. BAKER HUGHES INTEQ 02-MAY-03 JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 1 1 S. FRANK D. WESTEN MWD RUN 2 MWD RUN 3 # SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION(FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: 12 IlN 10E 102.00 # WELL CASING RECORD OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING 24.000 9.875 16.000 158.0 5000.0 # REMARKS: 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' 12.887" LONG: W149 DEG 30' 56.800" LOG MEASURED FROM D.F. AT 102.0 FT. ABOVE PERM. DATUM (M. S . L. ) . BAKER HUGHES INTEQ RUN 1 UTILIZED MULTIPLE PROPAGATION RESISTIVITY (MPR) SERVICES IN A STEERABLE ASSEMBLY FROM 158 - 5000' MD (158 - 4214' TVD). PER PAl GEOSCIENCE REQUEST, RESULTS FROM MPRTEQ POST PROCESSING (RESISTIVITY) ARE INCLUDED HERE. THESE CURVES ARE INVERTED (RESOLUTION MATCHED), COMPEN- SATED, AND BOREHOLE CORRECTED. THE INCLUDED CURVES ARE RADI, RPDI, RPSI, & RPXI & ARE PRESENTED FOR THE INTERVAL FROM 158 - 5000' MD. 1) 16" CASING DEPTH - LOGGER: 158' MD (158' TVD) 16" CASING DEPTH - DRILLER: 158' MD (158' TVD) 2) RESISTIVITY DATA RECORDED OVER THE INTERVAL FROM 158 - 1916 FEET MD (158 - 1779' TVD) IS ERRATIC DUE TO THE PRESENCE OF PERMAFROST. 3) THE INTERVAL FROM 1972 TO 2022 FEET MD (1817-1852' TVD) WAS LOGGED UP TO 3.5 HOURS AFTER BEING DRILLED DUE TO A WIPER TRIP. 4) THE INTERVAL FROM 4950 - 5000' MD (4166 - 4214' TVD) WAS NOT LOGGED DUE TO SENSOR-BIT OFFSET AT TD. $ Tape Subfile: 1 72 records... Minimum record length: Maximum record length: 8 bytes 132 bytes **** FILE HEADER **** LDWG .001 1024 *** LIS COMMENT RECORD *** ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! LDWG File Version 1.000 Extract File: FILE001.HED FILE HEADER FILE NUMBER: EDITED MERGED MWD Depth shifted and DEPTH INCREMENT: # FILE SUMMARY PBU TOOL CODE MWD $ 1 clipped curves; all bit runs merged. .5000 START DEPTH 158.0 STOP DEPTH 5000.0 # BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH $ # MERGED PBU MWD $ DATA SOURCE TOOL CODE BIT RUN NO MERGE TOP 1 158.0 MERGE BASE 5000.0 # 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. PER PAl GEOSCIENCE REQUEST, RESULTS FROM MPRTEQ POST PROCESSING (RESISTIVITY) ARE INCLUDED HERE. THESE CURVES ARE INVERTED (RESOLUTION MATCHED), COMPEN- SATED, AND BOREHOLE CORRECTED. THE INCLUDED RESIS- TIVITY CURVES ARE RADI, RPDI, RPSI, & RPXI & ARE PRESENTED FOR THE INTERVAL 158 - 5000' MD. MPRTEQ CURVE GLOSSARY: RADI - DEEP INVERTED ATTENUATION RESISTIVITY (OHMM) RPDI - DEEP INVERTED PHASE RESISTIVITY (OHMM) RPSI - SHALLOW INVERTED PHASE RESISTIVITY (OHMM) RPXI - EXTRA SHALLOW INVERTED PHASE RESIS. (OHMM) $ # *** INFORMATION TABLE: CONS MNEM VALU ------------------------------ WDFN LCC CN WN FN COUN STAT lcl17 5.xtf 150 Phillips Alaska, Inc. lC-117 West Sak North Slope Alaska *** INFORMATION TABLE: CIFO MNEM CHAN DIMT CNAM ODEP ---------------------------------------------------- GR GR GRAM 0.0 RPD RPD RPD 0.0 RPM RPM RPM 0.0 RPS RPS RPS 0.0 RPX RPX RPX 0.0 RADI RADI RALI 0.0 RPDI RPDI RPLI 0.0 RPSI RPSI RPHI 0.0 RPXI RPXI RPSHI 0.0 ROP ROP ROPS 0.0 FET FET RPTH 0.0 MTEM MTEM TCDM 0.0 * FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame Size is: 52 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: 19 1 ( FRAME SPACE = 0.500 * F ONE DEPTH PER FRAME Tape depth ID: F 12 Curves: Name Tool Code Samples Units Size Length 1 GR MWD 68 1 GAP I 4 4 2 RPD MWD 68 1 OHMM 4 4 3 RPM MWD 68 1 OHMM 4 4 4 RPS MWD 68 1 OHMM 4 4 5 RPX MWD 68 1 OHMM 4 4 6 RADI TEQ 68 1 OHMM 4 4 7 RPDI TEQ 68 1 OHMM 4 4 8 RPSI TEQ 68 1 OHMM 4 4 9 RPXI TEQ 68 1 OHMM 4 4 10 ROP MWD 68 1 FPHR 4 4 11 FET MWD 68 1 HR 4 4 12 MTEM MWD 68 1 DEGF 4 4 ------- 48 Total Data Records: 510 Tape File Start Depth Tape File End Depth Tape File Level Spacing = Tape File Depth Units = feet 158.000000 5000.000000 0.500000 **** FILE TRAILER **** Tape Subfile: 2 570 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 START DEPTH MWD 103.0 $ LDWG File Version 1.000 Extract File: FILE011.HED 2 log header data for each bit run in separate files. 1 .2500 STOP DEPTH 5000.0 # 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: # BOTTOM) TOOL TYPE DIRECTIONAL MULT. PROP. GAMMA RAY TOOL STRING (TOP TO VENDOR TOOL CODE DIR MPR GRAM $ # 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: 05-JUL-01 MSB 18655 6.75 MPR MEMORY 5000.0 103.0 4957.0 0 .0 49.0 TOOL NUMBER DAS 2160 MPR 6245 SRIG 5313 9.875 158.0 FW GEL 9.25 .0 .0 100 .0 .000 .000 .000 .000 .0 81.0 .0 .0 .00 .000 .0 0 BIT RUN 1 (MWD RUN 1). GR/MPR. CURVE GLOSSARY: GRAM - GAMMA RAY APPARENT (MWD-API) RPCL - DEEP PHASE RESISTIVITY (OHMM) RPSL - MEDIUM PHASE RESISTIVITY (OHMM) RPCH - SHALLOW PHASE RESISTIVITY (OHMM) RPSH - EXTRA SHALLOW PHASE RESISTIVITY (OHMM) RACL - DEEP ATTENUATION RESISTIVITY (OHMM) RASL - MEDIUM ATTENUATION RESISTIVITY (OHMM) RACH - SHALLOW ATTENUATION RESISTIVITY (OHMM) RASH - EXTRA SHALLOW ATTENUATION RES IS. (OHMM) RADI - DEEP INVERTED ATTENUATION RESISTIVITY (OHMM) RPDI - DEEP INVERTED PHASE RESISTIVITY (OHMM) RPSI - SHALLOW INVERTED PHASE RESISTIVITY (OHMM) RPXI - EXTRA SHALLOW INVERTED PHASE RES IS. (OHMM) ROPS - RATE OF PENETRATION (FPHR) RPTH - FORMATION EXPOSURE TIME (MIN) TCDM - BOREHOLE TEMPERATURE (DEGF) RPSI - SLIDING INDICATOR @ MPR MEASURE POIN~ $ # *** INFORMATION TABLE: CONS MNEM VALU ------------------------------ WDFN LCC CN WN FN COUN STAT 1cl17.xtf 150 Phillips Alaska, Inc. 1C-117 West Sak North Slope Alaska *** INFORMATION TABLE: CIFO MNEM CHAN DIMT CNAM ODEP ---------------------------------------------------- GRAM GRAM GRAM 0.0 RPCL RPCL RPD 0.0 RPSL RPSL RPM 0.0 RPCH RPCH RPS 0.0 RPSH RPSH RPX 0.0 RACL RACL RACLM 0.0 RASL RASL RACSLM 0.0 RACH RACH RACHM 0.0 RASH RASH RACSHM 0.0 RADI RADI RALI 0.0 RPDI RPDI RPLI 0.0 RPSI RPSI RPHI 0.0 RPXI RPXI RPSHI 0.0 ROPS ROPS ROPS 0.0 RPTH RPTH RPTHM 0.0 TCDM TCDM TCDM 0.0 RSI RSI RPSI 0.0 * FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame Size is: 72 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: 14 1 FRAME SPACE = 0.250 * F ONE DEPTH PER FRAME Tape depth ID: F 17 Curves: Name Tool Code Samples Units Size Length 1 GRAM MWD 68 1 GAP I 4 4 2 RPCL MWD 68 1 OHMM 4 4 3 RPSL MWD 68 1 OHMM 4 4 4 RPCH MWD 68 1 OHMM 4 4 5 RPSH MWD 68 1 OHMM 4 4 6 RACL MWD 68 1 OHMM 4 4 7 RASL MWD 68 1 OHMM 4 4 8 RACH MWD 68 1 OHMM 4 4 9 RASH MWD 68 1 OHMM 4 4 10 RADI TEQ 68 1 OHMM 4 4 11 RPDI TEQ 68 1 OHMM 4 4 12 RPSI TEQ 68 1 OHMM 4 4 13 RPXI TEQ 68 1 OHMM 4 4 14 ROPS MWD 68 1 FPHR 4 4 15 RPTH MWD 68 1 MINS 4 4 16 TCDM MWD 68 1 DEGF 4 4 17 RSI MWD 68 1 4 4 ------- 68 Total Data Records: 1400 Tape File Start Depth Tape File End Depth Tape File Level Spacing = Tape File Depth units = feet 103.000000 5000.000000 0.250000 **** FILE TRAILER **** Tape Subfile: 3 1505 records... Minimum record length: Maximum record length: 8 bytes 4124 bytes **** TAPE TRAILER **** LDWG 03/05/02 01 **** REEL TRAILER **** LDWG 03/05/02 AWS 01 Tape Subfile: 4 2 records... Minimum record length: Maximum record length: 132 bytes 132 bytes