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U 0 0 p p 0 0 0 0 0 0 0 0 GJ E O O O O O W Ca V n r- r) (h r) rn N N N N12 U 0 o ❑ o = _ = o 0 o o O @ a- 1.1.1 L o>C'` N C'! 3 rn N co u)W W. 000000000 ❑ ❑ @ cn w Ln\ CC 0 O O O O O O O O O O '� O O O O O O O O 0 0 O oo Cr e-M (0 O N 1.0 CO n0 CO CO 1l) It7L 0 m N M N O (0 W et 1() (O (O O U N N N N N N N N N N N N L. : O O co T W O O) tT co T tr 4! 0 NCNNCNCNNNCNNNCN I- 0) O O O O o O O O O O O 3 6 0 0 0 0 0 0 0 0 0 0 �+ O v Cm 00 C M) I() U) U) I() 11) 1/) U) Il) U) 1l) Q U '' aa C: z Q�1 £ .w.,.. cc c O W Y p W c MI Z ✓ 4! O Z t-0 ,_ e- C - in N N O O O co C i F_ o' = oc In to r� di J, 6 .1 Y Y LL = [0 m E to a c m d < a N M M M M H Z G1 t0 VI Y 00 ^O i C .i Vl r--I U O 0 CIA a I3 Q m H a v r0 d Q · . 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. ~ () y. - ~ () 0 Well History File Identifier Organizing (done) D Two-sided 1111111111111111111 D Rescan Needed 11I111111111111I111 RESCAN ~Olor Items: D Greyscale Items: DIGITAL DATA OVERSIZED (Scannable) D Maps: D Other Items Scannable by a Large Scanner D Diskettes, No. D Other, Norrype: D Poor Quality Originals: OVERSIZED (Non-Scannable) o Other: o Logs of various kinds: NOTES: o Other:: BY: ~ Dal. / Ldo La 7 t I 151 (\110 BY: ~ Dal. 1/&/07 D x 30 = 0/ () + III 11111I111111111I 151 Me Project Proofing Scanning Preparation BY: Date: 1111111111111111111 Production Scanning Stage 1 Page Count from Scanned File: ---Q..Q- (Count does include cover sheet) Page Count Matches Number in Scanning Preparation: V YES BY: ~ Date: II d-.J 07 NO Stage 1 If NO in stage 1, page(s) discrepancies were found: YES 151 V\1 P NO BY: Maria Date: 151 1111111111111111111 Scanning is complete at this point unless rescanning is required. ReScanned 11111111111111 1I1II BY: Maria Date: 151 Comments about this file: Quality Checked 11111111111I1111111 10/6/2005 Well History File Cover Page.doc STATE OF ALASKA • ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Abandon r Repair w ell ❑ Plug Perforations [7 Stimulate L7 Other W Pull A SAND IBP Alter Casing ❑ Pull Tubing ❑ Perforate New Pool ❑ Waiver ❑ Time Extension ❑ Change Approved Program ❑ Operat. Shutdow n ❑ Perforate ❑ Re -enter Suspended Well ❑ 2. Operator Name: 4. Well Class Before Work: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development Q Exploratory ❑ 7 204 -200 3. Address: 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 Stratgraphic ❑ Service 17 - 50 029 - 23230 - 00 7. Property Designation (Lease Number): 8. Well Name and Number: ALK 25651 r 25648 1E-168 9. Field /Pool(s): Kuparuk River Field / West Sak Oil Pool 10. Present Well Condition Summary: Total Depth measured 13477 feet Plugs (measured) None true vertical 3763 feet Junk (measured) None Effective Depth measured 13439 feet Packer (measured) 469, 6943, 6982, 6983 true vertical 3763 feet (true verucal) 467, 3446, 3453, 3454 Casing Length Size MD TVD Burst Collapse CONDUCTOR 80 20 108 108 0 0 SURFACE 4387 10.75 4415 2477 0 0 D -SAND WIND01 12 7.625 7043 3466 0 0 D -SAND LINER L 352 6.54 7328 "3531 - 0 0 B -SAND WINDO% 14 7.625 7367 3538 0 0 PRODUCTION 8131 7.625 8158 3714 0 0 Perforation depth: Measured depth: 8571'- 13438' � True Vertical Depth: 3725' -3762' � �� kFCO E- NOV - A ZU* Tubing (size, grade, MD, and TVD) 4.5, L -80, 6982 MD, 3453 TVD �a Oil di Gas Cons. Ctm3sion Packers & SSSV (type, MD, and TVD) NIPPLE - DB NIPPLE, 3.875 @ 469 MD and 467 TVD Anchorap NIPPLE - DB -6 NIPPLE / 3.812 @ 6943 MD and 3446 TVD LOCATOR - LOCATOR SUB @ 6982 MD and 3453 TVD SEAL ASSY - GBH -22 LOCATING SEAL ASSY (26.62 FT) @ 6983 MD and 3454 TVD 11. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 12. Representative Daily Average Production or Injection Data Oil -Bbl Gas -Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation 600 111 176 790 260 Subsequent to operation 144 462 700 859 273 13. Attachments 14. Well Class after work: Copies of Logs and Surveys run Exploratory ❑ Development r E Service ❑ Stratigraphic n r G STOR Well Status after work: _Oil Gas ❑ WDSPL [] Daily Report of Well Operations X ❑ WINJ [ WAG ❑ GINJ ❑ SUSP [' SPLUG ❑ 16. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: NIA Contact Darrell Humphrey /Bob Christensen Printed Name Darrell R. Humphrey Title Production Engineering Specialist Signature Phone: 659 -7535 Date '-// >/ ® R.B.9ims No & 77T o ` Form 10 -404 Revised 10/2010 /// ..1�Submit Original Only 1 E -168 DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary 11/03/10 PULLED ISO SLEEVE FROM D -LAT @ 7046' CTMD, PULLED IBP FROM A -LAT @ 7458' CTMD,WELL LEFT SHUT IN, RETURN IN THE AM TO RE- INSTALL ISO SLEEVE (IN PROGRESS) 11/06/10 SET ISO SLEEVE IN B -LAT LEM @ 7391' CTMD, WELL LEFT SHUT IN, TURN OVER TO DSO (COMPLETE) i y , KUP 1 E -168 COroca illip5 eii Attributes Max Angle & MD TD WeIISWNs Incl MD 11KB Act 1 RKB Alaska, Inc. Wellbore API /UWI Field Name () ( ) 1 ) 500292323000 WEST SAK PROD 92.87 11,113.42 13,477.0 Comment H25 (ppm) Dale Annotation End Date KB-Ord (R) Rig Release Date Wellc.na -1E -1 .11 Ml,07:33:51AM SSSV:NIPPLE 65 8/6/2009 Last WO: 2/10/2007 34.69 1126/2004 Scnematb- Nal Annotation Oepth ((tN8) End Date Annotation Last Mod By End Date Last Tag: Rev Reason: Set ISO SLV B Lateral, Pull IBP Imosbor 1116/2010 MANGER, 23 Casing Strings Casing Description String 0... String ID ... Top (RKB) Set Depth IF Set Depth (TVD) ... String Wt... String ... String Top Thrd CONDUCTOR 20 19.124 28.0 108.0 62.50 H-40 WELDED Casing Description String C... String ID ... Top (IRKS) Set Depth IF Set Depth (TVD) ... String Wt... String ... String Top Thrd i SURFACE 103/4 9.794 27.6 4,414.5 2,477.6 45.50 L-80 BTC Casing Description String 0... String ID ... Top IRKS) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd PRODUCTION 7518 6.875 27.0 8,157.6 29.70 L-80 BTGM CONDUCTOR, Caning Description String 0... String 10 ... Top (IRKS) Set Depth (t... Set Depth (TVD) ... String Wt... String ... String Top Thrd 29-109 DSAND Window 7 5/8 6.000 7,031.0 7,043.0 3,466.0 29.70 L -80 NIPPLE, 469 Casing Description String 0... String ID ... Top r1KB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd BSAND Window 75/8 6.000 1 7,353.0 1 7,367.0 1 3,538.2 29.70 L -80 Casing Description String 0... String ID ... Top (RKB) Set Depth if Set Depth (TVD) ... String Wt... String ... 1 1string Top Thrd GAS LIFT, D -SAND LINER LEM 41/2 3.870 6,976.2 7,328.0 3,531.6 12.60 L -SO IBT 4 ' 270 Liner Details SURFACE, 28 -1,115 Top Depth GAS LIFT, (TVD) NIPPLE, 8,913 Top lncl Nomi... 8'708 Tap (Po(B) (RKB) ( °) Item Description Comment ID (,n) LOCATOR, 6,976.2 3,452.4 79.27 PACKER HRD ZXP LINER TOP PACKER wIHD SLIPS 3.870 6,982 SEAL ASSY, 6,995.2 3,456.0 79.17 SBE CASING SEAL BORE EXTENSION 3.940 D -SAND 7,020.1 3,461.0 78.47 HANGER LEM HOOK HANGERS 3.930 wind.. 7p31 -7.043 7,282.3 3,526.7 82.09 SEAL ASSY NON- LOCATING SEAL ASSEMBLY 3.870 D -SAND LINER LEM, Casing Description String 0... String ID ... Tap (f1K8) Set Depth (f... Set Depth (TVD) ... String vin String ... String Top Thrd 6.976 -7,328 BSAND LINER LEM 4 112 3.958 7,296.8 7,479.9 12.60 L -80 IBT SLEEVE, 7,353 BSAND winnow, Liner Details 7,353.7,367 Top Depth B -SAND LINER (TVD) Top Incl Noml... LEM, Top (ttKB) (RKB) ( °) Item Description Comment ID (In) 7,297 -7,480 _ PRODUCTION, 7,296.8 3,527.9 81.47 PACKER ZXP LINER TOP PACKER 6.230 27-8 IPERF, 7,315.9 3,530.0 80.65 SBR 109-47 CASING SEAL BORE RECEPTACLE 4.750 9,571 ERF, 7,334.7 3,532.6 79.84 XO BUSHING XO BUSHING 5.5x4.5 3.910 9,129 -9,436 IPERF, 7,346.3 3,534.4 79.35 HANGER LEM ABOVE HOOK HANGER 4.020 9,527 -9,653 IPERF, 7,353.1 3,535.6 79.05 HANGER LEM INSIDE HOOK HANGER 4.020 9,954- 10.712 IPERF, 7,404.2 3,546.01 77.82 NIPPLE ICAMICID 'DB -6 NIPPLE 3.562 10,961 - 11.096 IPERF, 7,476.7 1 JSEALAS5`f I BAKER SEAL ASSEMBLY 3.890 11,335- 11.830 B -SAND Casing Description 3tr,ng 0... String ID ... Top (fella) Sat Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Third LINER, ASAND LINER 4 1/2 3.958 7,437.2 13,473.0 3,763.1 12.60 L -80 DWC 7,35311,927 o -SAND LINER, Liner DetaNs 7,029 - 11.937 Top Depth (TVD) Top Inc, Nom,... Top (RKB) IRKS) (a) Item Description Comment ID (In) 7,437.2 3,553.1 77.30 PACKER HRD ZXP LINER TOP PACKER 4.970 7,456.2 3,557.2 76.99 NIPPLE RS PACKOFF SEAL NIPPLE 4.875 7,459.1 3,557.9 76.95 HANGER FLEXLOCK LINER HANGER 4.853 7,468.9 SBE 190-47 CASING SEAL BORE EXTENSION 4.750 7,487.9 XO BUSHING XO BUSHING 5.5 "x43" 3.830 Tubing Strings Tubing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd TUBING 4 1/2 3.958 23.1 6,983.4 3,453.8 12.30 L -80 IBT Mod Completion Details Top Depth (TVD) Top Inc, Nomi... Top India) IRKS) 11 Item Description Comment ID (in) 23.1 HANGER Tbg Hgr, Vetco Gray, 4.909 MCA Top 4.500 468.9 NIPPLE DB Nipple, 3.875 3.875 6,943.2 3,446.5 79.44 NIPPLE DBS Nipple / 3.812 0.000 6,981.7 3,453.5 79.24 LOCATOR Locator Sub 3.880 6,983.4 3,453.8 79.23 SEAL ASSY GBH-22 Locating Sea( Assy (26.62 ft) 3.880 Perforations & Slots snot Top (TVD) Btm (TVD) Dens Top(RKB) St. IRKS) (RKB) (RKB) Zone Data (sh... Type Comment 8,571.0 8,819.0 3,725.4 WS A2, 1 E -168 11/112004 32.0 IPERF All ASand Slotted Liner PERFS 2.5" Long x .125" Wide, 4 circumf rows, 3" centers staggered 18 deg. 9,129.0 9,436.0 3,718.7 3,708.7 WS A2, 1E -168 11/112004 32.0 IPERF 9,527.0 9,653.0 WS A2, 1E -168 11/112004 32.0 IPERF 9,964.0 10,712.0 3,744.2 WS A2, 1E -168 11/1112004 32.0 IPERF 10,961.0 11,086.0 3,741.0 WS A2, 1E -168 11/11/2004 32.0 IPERF 11,335.0 111,1130.01 3,729.91 WS A2, tE -168 11/112004 32.0 IPERF 11,923.0 12,851.0 3,748.6 3,769.7 WS A2, 1E -168 11/112004 32.0 IPERF 13,006.0 13,130.0 3,770.61 WS A2, 1E -168 11/112004 32.0 IPERF 13,343.0 13,436.01 3,760.81 3,762.5 WS A2, 1E -168 11/112004 32.0 IPERF Notes: General & Safe End Date I Annotation 12/23/2004 1 NOTE: TRI- LATERAL WELL: 1E- 168(A- SAND), 1E- 1681-1(BSAND), 1E- 168L2(D -SAND) _ 2242009 NOTE: VIEW SCHEMATIC w /Alaska Schema1Jc9.0REV IPERF, 11, M12,851 PERF, 13,006- 13.130 Mandrel Details Top Depth Top Port IPERF, (TVD) Do V.1- Latch Size TRO Run 13,31313,436 - Stn Top(RKS) IRKS) I ° ) Make Model (in) Sera Type Type (in) (psi) Run Date Com... ASAND 1 4,270.2 2,423.4 66.45 CAMCO KBMG 1 GAS LIFT GLV BKS 0.188 1,531.0 2202004 LINER, 7,137-13,653 2 6,708.2 CAMCO KBMG 1 GAS LIFT OV BKS 0.250 0.0 2/20/2007 TD 11 13 477 13,657 • 0 WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. October 26, 2010 Attn.: Christine Shartzer 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Bottom Hole Pressure Survey: 1E -168 Run Date: 10/21/20 10 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Klinton Wood, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 1E -168 Digital Data in LAS format, Digital Log Image file 1 CD Rom 50- 029 - 23230 -00 Bottom Hole Pressure Survey Log 1 Color Log 50- 029 - 23230 -00 NOV 1 201D PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Klinton Wood 6900 Arctic Blvd. 22 U Anchorage, Alaska 99518 (� J Office: 907 - 273 -3527 Fax: 907 - 273 -3535 klinton.wo(t lMbri Ecn Date: Signed: JJ - j) o' WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. October 21, 2010 Attn.: Christine Shartzer 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Bottom Hole Pressure Survey: 1E -168 Run Date: 10/10/2010 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of. Klinton Wood, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 1E -168 Digital Data in LAS format, Digital Log Image file 1 CD Rom 50- 029 - 23230 -00 Bottom Hole Pressure Survey Log 1 Color Log 50- 029 - 23230 -00 N� 2(�� PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Klinton Wood 6900 Arctic Blvd. �f Anchorage, Alaska 99518 �C)@ Office: 907 - 273 -3527 Fax: 907 - 273 -3535 klinton.wood :cn Date: Signed: vi • Con P'° oco hill~ps Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 November 27, 2008 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7~' Avenue, Suite 100 Anchorage, AK 99501 Dear Mr. Maunder: • 4/Y iYY~D 1iir~ tom.-~b`~ Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRU). Each of these wells was found to have a void in the conductor. These voids were filled with cement if needed and corrosion inhibitor, engineered to prevent water from entering the annular space. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treatments took place and meets the requirements of form 10-404, Report of Sundry Operations. Cement was pumped October 30, 2008 and the corrosion inhibitor/sealant was pumped November 7 and Novemberl7, 2008. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please call MJ Loveland or Perry Klein at 907-659-7043, if you have any questions. ConocoPhillips Well Integrity Projects Supervisor • • ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) Kuparuk Field .._._ ~a~` Well Name TD # Initial top of cement Vol. of cement um ed Final top of cement Cement top off date Corrosion inhibitor Corrosion inhibitor/ sealant date ft bbls ft al 1F-18A 204-167 15' S" 2.50 44" 10/30/2008 27.2 11/7/2008 1E-16$ 204-200 15" NA 15" NA 3.4 11/7/2008 1E-17 205-074 13" NA 13" NA 5.53 11/7/2008 1J-12a 207-070 15" NA 15" NA 3.4 11/7/2008 1 J-14 200-200 16" NA 16" NA 1.27 11/7/2008 1 J-152' 206-016 3' NA 3' NA 19.55 11 /17/2008 1 J-158 207-054 6' NA 6' NA 27.2 11 R/2008 1J-162 2 7-080 15" NA 15" NA 2.55 11/7/2008 1J-166 205-198 12" NA 12" NA 8.5 11/7/2008 1J-168 205-060 10" NA 10" NA 3.82 11/7/2008 1 J-170 206-062 8" NA 8" NA 1 11 /7/2008 1 J-174 207-143 24" NA 24" NA 17 11 /7/2008 1J-178 207-121 12" NA 12" NA 5.95 11/7/2008 Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Well Job # d''~ j' e~ r~l l~,~1 , ~~~ _~ 05/22/08 NO. 4717 Company: Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 ~~ -~~~ E' ~: 2t~t~ Field: Kuparuk Log Description Date BL Color CD iJ-180 11964605 INJECTIO 1 E-168 11964601 N PROFILE - ( GLS 05/19/08 1 1 1J-160 1A-01 11964603 11996636 ~- INJECTION PROFILE _ PRODUCTION PROFILE w/FSI l- 05/15/08 05/17/08 05/14/08 1 1 1 1 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. • • Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Well Job # u~ ~~~~~~ ,1U~~ ~~ 200 ~. /_ w ~ ~ r: I: 11{Cf Log Description NO. 4707 Company: Ataska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Kuparuk Date BL Color CD 05/15/08 1F-12 11996623 PRODUCTION PROFILE / ~ 05/01/08 1 1 3J-11 11996624 PRODUCTION PROFILE - - C.<<( 05/02/08 1 1 3K-102 11963094 MEM PROD PROFILE ap"~ - '~ 05/09/08 1 1 iJ-152 11996632 GLS ( C 05!09/08 1 1 1 E-166 11994665 GLS - 05/11/08 1 1 1 E-165 11994665 GLS - 05/10/08 1 1 111-01 11996626 PRODUCTION PROFILE W/FSI ~ (o / 05/10/08 1 1 2X-15 11996634 PRODUCTION PROFILE W/FSI - ~ 05/12/08 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. • • • • ... :-, .~ ~ " . MICROFILMED 03101/2008 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE F:\LaserFiclu\C~rPgs_Inseits\Microfilm Agarker.doc 03/20/07 Schlumbergel' '\ j} / O~ NO. 4193 Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth SCANNED APR 0 3- 2007 !vj,l\F( ~; 2. ZOO? Company: Alaska Oil & Gas Cons C'Dmm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Kuparuk éJOZ/- <9é.Û Well Job # Log Description Date Color CD BL 1C-03 11632674 PRODUCTION PROFILE 03/03/07 1 1 C-02 11632676 PRODUCTION PROFILE 03/05/07 1 1A-12 11638832 SBHP SURVEY 03/08/07 1 1 E-20 11638833 GLS 03/09/07 1 1E-168 11626470 PRODUCTION PROFILE 03/12/07 1 1 E-117 11626471 INJECTION PROFILE 03/14/07 1 1Q-09 11638839 INJECTION PROFILE 03/16/07 1 3$-22 N/A INJECTION PROFILE 03/16/07 1 3M-23 11638840 LDL 03/17/07 1 1 C-1 0 11638841 INJECTION PROFILE 03/18/07 1 2A-23 11628986 INJECTION PROFILE 03/18/07 1 1 H-21 11638842 GLS 03/19/07 1 1D-42 11638843 SBHP SURVEY 03/19/07 1 2L-323 11628988 INJECTION PROFILE 03/20/07 1 Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. 16/ . . REPORT OF SUNDRY WELL OPERATIONS Ancho~ 1. Operations Performed: Abandon 0 Repair Well 0 Plug Perforations 0 Stimulate 0 Other ßl Alter Casing 0 Pull Tubing 0 Perforate New Pool 0 Waiver 0 Time Extension o rt~\ua Change Approved Program 0 Ope rat. ShutdownD Perforate 0 Re-enter Suspended Well o ~~1M 2. Operator Name: 4. Current Well Status: 5. Permit to Drill Number: ·'\,0 ConocoPhillips Alaska, Inc. Development 0 Exploratory 0 204-200 1 . 3. Address: Stratigraphic 0 Service 0 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-029-23230-00 7. KB Elevation (ft): 9. Well Name and Number: RKB 28' 1E-168 . 8. Property Designation: 10. Field/Pool(s): ALK 25651/25648 Kuparuk River Field 1 West Sak Oil Pool' 11. Present Well Condition Summary: . Total Depth measured 13477' feet true vertical 3763' . feet Plugs (measured) Effective Depth measured 13439' feet Junk (measured) true vertical 3763" feet Casing Length Size MD TVD Burst Collapse Structural CONDUCTOR 80' 20" 108' 108' SURFACE 4387' 10-3/4" 4415' 2477' PRODUCTION 8130' 7-5/8" 8158' 3715' . . ~""'.'" SLOTTED LINER 6036' 4-1/2" 13473' 3763' Perforation depth: Measured depth: slotted liner from 8571'-13436' true vertical depth: 3725'-3762' SCANNED JUL 11 2D07 Tubing (size, grade, and measured depth) 4-1/2" , L-80, 6983' MD. Packers & SSSV (type & measured depth) HRD lXP liner top pkr @ 7437' Cameo DB nipple @ 469' 12. Stimulation or cement squeeze summary: Intervals treated (measured) not applicable I reatment deSCriptions inCluding volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casinq Pressure Tubinq Pressure Prior to well operation 680 . 269 197 -- 185 Subsequent to operation 528 . 291 636 . -- 295 14. Attachments 15. Well Class after proposed work: . Copies of Logs and Surveys run _ Exploratory 0 Development 0 Service 0 Daily Report of Well Operations _X 16. Well Status after proposed work: Oil0 . GasD WAGD GINJD WINJD WDSPL D 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: n/a Contact Jill Long @ 265-1102 Printed Name Jill Long Title Wells Group Engineer 03/01101 Signature Q;,O ~^"~ Phone Date ( J \01 PreDared bv Sharon AlIsuD-Drake 263-4612 G' o R~ G ¡ N RBDMS BFl MAR 0 6 Ln 1J-;/Ç Form 10-404 Revised 04/2004 Submit Original Only . . . STATE OF ALASKA ALASKA Oil AND GAS CONSERVATION COMMISSION AL I ..... "'" ..... MAR 0 2 2007 Alaska Oil & Gas Cons. Commission )\ ':lJ1 :t"2i67 ..,¿b j. 2.. 07 . . KRU 1E-168 ConocoPhillips Alaska, Inc. .:tE~168 ~ TUBING (0-6983, 00:4.500, 10:3.958) Hanger L2 (7029-7030, 00:7.625) Packer L 1 (7297-7316, 00:7.625) SBRL1 (7316-7335, 00:6.260) PUP L1 (7336-7353, 00:4.500) ~ .. II ~ P'1 I'll' . II;~ I I · · ==" I .~ = · · f= ~ I = = = · · = I ..=:=.=== == · · = = I !::::= == · · == ~ I - ~ · · ~ = I == == · · = == I "~"m = = · · = - I - ~... .~ API: 500292323000 SSSVType: NIPPLE Angle @ TS: deQ (q) Angle@ TD: 89 deg @ 13477 Well Tvpe: PROD Orig 11/26/2004 Completion: Annular Fluid: Last w/o: 2/10/2007 Reference LOQ: 28' RKB Ref LOQ Date: LastTaç¡: TD: 13477ftKB LastTaç¡ Date: Max Hole Anç¡le: 93 dM11113 DescriDlion Size Too Bottom TVD PRODUCTION 7.625 0 8158 3714 CONDUCTOR 20.000 0 108 108 SURFACE 10.750 0 4415 2478 ma 'J1IINlãlie'.IIIIfåø.em IâI'íRZSløtœil,.âsi* %3., Description Size Top Bottom TVD I Wt I Grade I Thread SLOTTED LINER I 4.500 I 7437 13473 3763 I 12,60 I L-BO DWC !lliti"iÐQI~-mîf . "ill, : : IN~· " . . .¿%# Size Too I Bottom I TVD I Wt I Grade I Thread 4,500 0 I 6983 I 3454 I 12,60 , L-80 I IBT -_atiøÀšlifHmòa Interval TVD 8571- 8819 3725- 3725 Rev Reason: WORKOVER Last Update: 2/15/2007 Wt 29.70 62.50 45.50 Grade L-80 H-40 L-80 Thread BTC-M WELDED BTC Zone WSA2 Status Ft SPF Date Type 248 32 11/11/2004 ¡PERF Comment All A-Sand Slotted Liner PERFS 2.5" Long x .125" Wide, 4 circumf rows, 3" centers staaaered 18 deQ. 9129-9436 3718 - 3709 WSA2 307 32 11/11/2004 IPERF 9527 - 9653 3709 - 3711 WSA2 126 32 11/11/2004 IPERF 9964 - 10712 3718 - 3744 WSA2 748 32 11/11/2004 IPERF 10961 - 11086 3745-3741 WSA2 125 32 11/11/2004 I PERF 11335 - 11830 3734 - 3741 WSA2 495 32 11/11/2004 IPERF 11923 -12851 3748 - 3770 WSA2 928 32 11/11/2004 IPERF 13006 - 13130 3771 - 3768 WSA2 124 32 11/11/2004 ¡PERF 13343 - 13436 3762 - 3762 WSA2 93 32 11/11/2004 IPERF ~aSllli.~ølte_alll~jl,. h~'" ,:, ":~~ 'b %<ffij;b~.L ' J, j~fl St MD TVD Man Mfr Man Type VMfr V Type VOD latch Port TRO Date Run vtv Cmnt 1 4270 2423 CAMCO KBMG SOY 2 6708 3384 CAMCO KBMG DMY -Ie !rltual . '. _1\..,MIIIINElIIIIIIII. Depth TVD Type 469 467 NIP 6943 3446 NIP 6983 3454 SEAL 7029 3463 Hanger L2 7031 3464 Window L2 7297 3525 Packer L 1 7316 3528 SBR L1 7335 3532 BushinQ L 1 7336 3532 PUP L 1 7346 3534 Hanç¡er L 1 LEM ABOVE HOOK HANGER FOR B-SAND L 1 7353 3535 Window L 1 B-SAND L 1 WINDOW 7353 3535 HanQer L 1 LEM INSIDE HOOK HANGER FOR B-SAND L 1 BeE\ inlUDS \ieUuiíft¡¡¡eIÐ~.j¡l_m¡IlliINI31!111!l.· Depth TVD Type 7437 3553 PACKER 7459 3558 HANGER 7469 3560 SBE 7488 3564 BUSHING 'ÌSsRsral11liiif . . Date I Note 1/25/20M NOTE: TRI-LATERAL WELL: 1E-168lA-SAND), 1E-168L 1 (B-SAND), 1E-168L2(D-SAND\ 1.0 1.0 BK-5 BK-5 0.000 0.000 o o 2/9/20Œ 2/9/20Œ Description ID 3.875 3.875 3.880 4.500 0.000 5,500 4,750 4.500 3.875 4.500 0.000 4.750 CAMCO DB NIPPLE 2/9/2007 CAMCO DB-6 NIPPLE 2/9/2007 GBH-22 LOCATING SEAL ASSEMBLY & LOCATOR SUB 2/9/2007 BAKER MODEL B1 FLANGE HOOK HANGER FOR D-SAND L2 D-SAND L2 WINDOW ZXP LINER TOP PACKER FOR B-SAND L 1 190-97 CASING SEAL BORE RECEPTACLE FOR B-SAND L 1 XO BUSHING FOR B-SAND L 1 Description HRD ZXP LINER TOP PACKER FLEXLOCK LINER HANGER 190-47 CASING SEAL BORE EXTENSION XO BUSHING HYDRIL ID 5,500 5.500 4.750 4.500 " . . 'iIIW/' ConocoPhillips Wellv/ew Web Reporting Time Log Summary 02/02/2007 00:00 16:00 16.00 MIRU MOVE MOB P Rig released from 3K-32 @ 24:00 hrs on 2/01107. Move rig from 3K-32 to 1E-168, rig move 13.5 miles, derrick up. With a two hour wait at CPF-3 for crew chan e. 16:00 18:00 2.00 MIRU MOVE PSIT P Rig on location @ 1 E-pad. Load out 11" BOP stack and pick-up 13 5/8" BOP stack. Position rig, spot rig over wellhead, level u . 18:00 20:00 2.00 MIRU MOVE RURD P Accept rig @ 18:00 hrs on 2/02/07. Rig-up drop tarps, berm, spot tanks, equipment, hook up communication lines. 20:00 20:30 0.50 COMPZ RPCOr-. RURD P Rig-up Vetco Gray and pull BPV. Check pressures TBG 700 psi, IA 900 si, OA 950 si. 20:30 00:00 3.50 COMPZ RPCOr-. RURD P Rig-up cellar for well kill, load pits with 560 bbls of 6% KCL seawater, PT circulating equipment and lines to 1500 si. 02/03/2007 00:00 05:00 5.00 COMPZ WELC1 CIRC P Circulate 100 degree 6 % KCL seawater down tubing taking returns out IA to return tanks. Starting pressures tbg 700 psi IIA 900 psi I OA 150 psi. Pumped total of 260 bbls down tubing without returns. Pump additional 250 bbls down IA. Pump rate throughout circulation was 3 BPM. After circulating tubing was on vacuum, IA ressure zero. 05:00 08:00 3.00 COMPZ WELC1 OWFF P Shut-in well and monitor pressuresl appears stable. Run fluid level shot, TOF in IA at 1000'. 08:00 09:30 1.50 COMPZ WELC1 CIRC P Pump 15 bbs down tbg and 35 bbls down IA wI charge pump at 40 psi. Monitor well, fluid level at 35'. 09:30 11:00 1.50 COMPZ WELC1 OTHR P PJSM, Load ESP Spooler & Equipment on rig floor. Continue to monitor well. 11:00 13:00 2.00 COMPZ WELC1 CIRC P RD Circulating lines, RU to fill lA, pump 10 bbls dn lA, no returns, monitor well. RU to offload water from ri its to trucks. 13:00 15:00 2.00 COMPZ WELC1 OTHR P Set BPV, dress BOP's wI proper size rams, offload pits to jack rig for installation of BOP stack. . . ND tree, install dart in BPV, NU BOPE. Flood stack & Choke manifold wI water and cavity test all 250 I 2500 psi. John Crisp wI AOGCC on location to witness BOPE test. 20:00 23:00 3.00 P Hold PJSM for lubricate and bleed technique for gas removal. At start had 80 psi on IA. Pump 10 bbls IA and wait 5 min, bleed gas out of IA to 40 psi. Pump 10 bbls, wait, bleet ot 10 psi, pump 10 bbls, wait 5 min and bleed all to 0 psi. Monitor well, no build up, no flow, no returns at surface while um in . monitor well. 23:00 00:00 1.00 COMPZ WELCT OTHR P RD hoses and blow down to tiger tank. Finish RU to test BOPE. Notified by AOGCC inspector to proceed wI test wlo witness as presence required on another ro·ect. 02/04/2007 00:00 05:00 5.00 COMPZ WELCT BOPE P Test all BOPE 250 I 2500 psi. Witness of test waived by John Crisp wI AOGCC. 05:00 05:30 0.50 WELCT BOPE P Pull BPV 05:30 08:30 3.00 RPCOII. DHEQ P RIU ESP Sheave, Spooler, Set Landing Jt, Back out LDS. Hold PJSM, pull hanger to floor, pulled 130K to unseat. RID fill line to lA, UD Hanger and Landing Jt. PU w1 on tbg 110K. 08:30 12:00 3.50 COMPZ RPCOII. PULD P Thread ESP cable through sheeve and tie in to spooler. POOH and stand back tubing while spooling ESP cable. Pumping 10 bbls brine down tbg annulus every 20 minutes to keep gas down. 12:00 13:30 1.50 COMPZ RPCOII. PULD P Continue Pulling tubing to 3615'. Shut down to shoot fluid level. Fluid at 900' in tb and annulus. 13:30 18:00 4.50 RPCOII. PULD P RD fluid shooters, contnue POOH and la down 'ewel 18:00 20:30 2.50 RPCOII. PULD P POOH, Break down motor, RD ESP cable s ooler. 20:30 23:30 3,00 RPCOII. PULD P PJSM wI crane and rig personnel. Remove ESP spool, and equipment from rig floor. RD ESP Sheave and load out motors, sheaves and other ESP related e ui ment. 23:30 00:00 0.50 COMPZ RPCOII. PULD P RU 3 1/2" Test jt to test plug and set same. Test VBRs on 3 1/2" DP to 250/2500. 02105/2007 00:00 02:00 2.00 COMPZ RPCOII. RURD P Set wear ring, clear floor, load tools for make up of clean-out BHA run. RIU floor for runnin DP. . . Continue POOH wI clean-out BHA. LD clean-out BHA PJSM. PU and MU LEM running BHA assembl . RIH LEM on 3-1/2 DP to 7233 ft. Fluid level avera e 300 ft, Fill as needed. Test run, stab seal assy, 120 up, 69 dn. Circ 4 bpm I 500 psi. Orientate with MWD. Tag top of hook hgr with seal assy. Tag top ofseal bore with seal assy, Increased drag with seals in seal bore every time we ran in and pulled out. Saw 25K overpull to snap out of hook hgr. Rotated LEM 90 deg and LEM rotated back to previous reading. Each time LEM was landed, it oriented in the range of 56 to 59.5 de to ri ht of hi hside, COMPZ RPCOII. CIRC P Circ, re-fill pits from vac truck. 05:00 08:00 3.00 P 08:00 11 :30 3.50 P 11:30 12:30 1.00 P 12:30 13:30 1.00 P 13:30 15:00 1.50 P 15:00 21:00 6.00 P 21:00 00:00 3.00 P 02/06/2007 00:00 09:30 9,50 P 09:30 10:00 0.50 P 10:00 11 :00 1,00 P 11:00 12:00 1.00 12:00 13:00 1.00 RIH wI DC's and DP - 2023'. POOH and stand back in derrick. Continue pumping 10 bbls 6% KCL every 15 minutes into wellbore to maintain fluid level. Hold PJSM, MU Clean-Out BHA and PU 2 7/8" PAC DP. RIH wI BHA and PD stands. Continue RIH wI picking DP off rack, RIH to 6984ft. Continue to RIH wI pumping, unable to circulate due to wellbore taking fluid. While pumping down back side wI charge pump, RIH and tag no-go at 7339ft. Pumped total 210 bbls water wI no returns. ID of B-Iateral ZXP packer seal bore receptacle clear to 7339ft. POOH wI clean out assembly to 6917ft. Slip and cut drill line on rig. COMPZ RPCOII. WOOR P Confer with engineering I Anch. Decision to set pkr. Note that we were concerned because whipstock orientation was reported to be 17 deg left of highside prior to setting it. We do not have an orientation of hook hgr when it was landed. We decided that since the LEM equip is all functioning as designed, (snap out and orientation), and that since we found the hook hgr at the expected depth, we should go ahead and set the LEM. Baker reps in town and at the rig a reed with this decision. . . PJSM, set ZXP pkr 6974 ft, 124 up, 70 dn rior. 13:30 15:30 2.00 T Attempt test pkr I csg. Repair leaking flan e I wellhead valve. 15:30 16:00 0.50 P PJSm, test ZXP pkr 17-5/8 X 3-112 ann 2100 psi I 5 min. Test successful, no re-tests. 16:00 23:00 7.00 P PJSM, POH 3-1/2 DP 23:00 00:00 1.00 P LD LEM Running assembly and BHA. 02/07/200700:00 02:30 2.50 P Finish LD DC's and BHA. Pull wear ring, RD spinners, RU Eckels, RU sheave for heat trace, move additional tbg into pipeshed, inspect and strap, prepare floor and tools for running com letion. 02:30 05:30 3.00 COMPZ RPCOr.. RCST P PJSM" MU seal assembly and RIH tI 3940' w/4 1/2" Production String wI GLM's and Ni les. 05:30 06:30 1,00 COMPZ RPCOr.. RCST P String heat trace through sheave in derrick, bring installation tools for installation to ri floor. 06:30 12:00 5.50 COMPZ RPCOr.. RCST P Continue RIH w/4 1/2" Production String, Start installing heat trace at 3000 ft wI Cannon Clam s, 12:00 18:00 6.00 COMPZ RPCOr.. RCST P Continue RIH w/4 1/2" Production String. Installing heat trace to surface. 18:00 00:00 6.00 COMPZ RPCOr.. RCST T At space out, heat trace failed meg test, cut cable and re-test, start pulling tubing in attempt to locate source of problem. Order out replacement spool while pulling tubing, Continue POOH wI tbg and inspect trace. Noted momentary increase in hookload at 2 stands out, then normal. At 18 stds, noted armor wore through. At 20 + sngle, trace cable parted and balled up, Noted numerous Cannon clamps mangled, also 2 pins and part of hin e missin on one. 02/08/2007 00:00 04:00 4.00 T Continue POOH. TOH wI all tubing to fish hardware discovered missing from Heat Trace cable clam s. 04:00 11 :00 7,00 T Order out fishing magnets and slickline for fishing operations, Locate and order out lubricator for slickline o erations. 11:00 12:00 1.00 T PJSM, RU slickline for fishing o erations. 12:00 13:00 1.00 T RIH w/5 1/2" Magnet on slickline to 6933', recover cannon clamp hinge ins. slickline x 2, recover cannon clamp hinge door on run 1, hinge pins on run 2. 17:00 18:00 1,00 COMPZI RPCOI\ SLKL T RIH w/3 1/2" magnet on slickline to 6990', recover cannon clamp hinge ~ns. 18:00 19:30 1.50 COMPZI RPCOI\ SLKL T RIH wI wirebrush and gauge to 7010', no obstructions. 19:30 23:30 4.00 COMPZr RPCOfI SLKL T RD slick-line, PHSM, RU ESP Spooler, Load ESP spool and move Heat trace spool on rig floor. RU additional sheave and RU for running ESP and Heat Trace. 23:30 00:00 0.50 COMPZr RPCOI\ RCST T PU Seal Assembly and RIH w/4 1/2" Tbg to 258'. 02/09/2007 00:00 01:30 1.50 COMPZI RPCOI\ RCST T Cont RIH 4-1/2 tbg to 4013 ft. 01:30 03:30 2.00 COMPZI RPCOI\ RCST T Attempt connect heat trace cable. No go. Type clamps used will not clamp securely. Decision made not to run heat trace equip. 03:30 05:30 2.00 COMPZI RPCOI\ RCST T PJSM, flow check. Continued losses approx 80 bph. Resume RIH 4-1/2 tbg to 6980 ft. 05:30 06:00 0.50 COMPZI RPCOI\ HOSO P PJSM, sting in to SBR with seal assy, tag no go at 6988 ft. Test annulus to 500 psi. 06:00 08:30 2.50 COMPZI RPCOI\ HOSO P Pick up two ft, space out, record measurements for pups. MU pups, tbg hgr. Lower tbg hgr into stack. 08:30 10:00 1.50 COMPZI RPCOI\ OTHR P Clear floor of cable spools while wait on delayed comp fluids. 10:00 11:30 1.50 COMPZI RPCOI\ CIRC P PJSM, flow check. Pump inhibitor to GLM #1 (6% KCL inhibited seawater, 1% CRW-132) Momentary returns, then incur losses. 11:30 12:00 0,50 COMPZI RPCOI\ HOSO P Land hgr while stab into SBR. Correct space out I sting in. Land hgr with 65K on hgr. 12:00 13:00 1,00 COM PZ~ RPCOI\ OTHR P Vetco Gray prep tbg hd I lock dn hgr, while conduct spud meeting with Anch engineering. 13:00 15:00 2,00 COM PZ~ RPCOI\ DHEQ P PJSM, RU to test annulus I pkr I seal assy. 15:00 16:00 1.00 COMPZ~ RPCOI\ DHEQ P PJSM, Test IA to 1000 psi 130 min, attempt build to 1500 psi. SOV shear at 1400 psi. Circ 10 bbl, confirm open. 16:00 00:00 8.00 COMPZ~ RPCOI\ NUND P PJSM, set BPV, commence ND BOPE, NU tree, test tree 250 I 5000 I psi. 30 min, OK. 02/10/2007 00:00 01:00 1.00 COMPZI RPCOI\ NUND P RU flow lines on tree for freeze protect operations. W/O Hot Oil. . . . . . . 05:00 06:00 1.00 COMPZ RPCOII. RURD RU Hot Oil service for freeze protect ops. Pump 65 bbls diesel down lA, 100 - 400 psi while pumping 4 bbls/min. 0 psi at pump stop. Pump 40 bbls diesel down tbg, tubing on vacuum for duration. Fluid pack OA w/8 bbls diesel, 150 psi at start, 150 psi at conclusion. PRe-install BPV, RD pump service lines, reinstall flanges and gauges on OA and lA, vac back fluids and release hot oil. Clear lines in cellar for ri move. ;;(. to t::>~ '- DATA SUBMITTAL COMPLIANCE REPORT 11/27/2006 Permit to Drill 2042000 Well Name/No. KUPARUK RIV U WSAK 1E-168 Operator CONOCOPHILLlPS ALASKA INC TVD 3763 - Completion Date 11/26/2004 __ Completion Status 1-01L Current Status 1-01L 5J '¿fO~AA~ API:c. 50·029·23230-00-00 UIC N MD 13477 /' REQUIRED INFORMATION Mud Log No Samples No DATA INFORMATION Types Electric or Other Logs Run: GR/Res Well Log Information: Electr Dataset Number Log/ Data Digital i~. Med/Frmt ~Pt . Log Log Scale Media Name Directional Survey Directional Survey I nd uction/Resistivity 25 Blu I nd uction/Resistivity 25 Blu C Lis 13159 I nd uction/Resistivity 13159 LIS Verification C Las 13172 I nd uction/Resistivity 13172 LIS Verification I nd uction/Resistivity 25 Blu Well Cores/Samples Information: Name Interval Start Stop Sent ADDITIONAL INFORMATION Well Cored? Y ß Chips Received? ~ Analysis ~ Received? ~-~._---~-~ Directional~ (data taken from Logs Portion of Master Well Data Maint Run Interval OH / No Start Stop CH ~---_._- 11659 13477 o 12073 108 13477 108 13477 108 13477 Open 108 13477 Open 108 12073 Open 108 12073 Open 108 12073 Open Received 1/5/2005 1/5/2005 6/10/2005 6/10/2005 6/10/2005 6/10/2005 6/14/2005 6/14/2005 Received Sample Set Number Comments Daily History Received? ~ Formation Tops Comments . PB1 Multiple Propagation Resistivity/Gamma Ray Multiple Propagation Resistivity/Gamma Ray MPR/GR MPR/GR RWD-GRlMPR-PB 1 RWD-GR/MPR-PB 1 Multiple Propagation Resistivity GR PI$I ---~---~ . Comments: Permit to Drill 2042000 MD 13477 ~~~~_.- Compliance Reviewed By: DATA SUBMITTAL COMPLIANCE REPORT 11/27/2006 Well Name/No. KUPARUK RIV U WSAK 1E-168 Operator CONOCOPHILLlPS ALASKA INC API No. 50·029-23230-00-00 TVD 3763 Completion Date 11/26/2004 Completion Status 1-01L Current Status 1-01L UIC N to -,----~ D~t;-~ .~~ ~---== . . . . Tom, Here is the well orientation plot for the 1320 requested on 1E-114. Also, included are the cementing reports for each one of these wells. Six wells were seen to intersect the 1320 plot: ; v. .:'\ IE.. 168 ~è~- ';)-Qu f\. lE-123/ Jù4-0'l \ ...<ê:1J0\ÇjQ~J <¿çJ~-O~ 1D-116'/ \C{;.s- \. ~'\.J 1D-113 ~ \~~- \''L C6 1D-112./ \<;..~_. \<;ê;~ ~ c 1D-103 ,;:)0 ð-Oq (..;;; -(¿~\ùc..:\xc:) 1./, s -0 ~ All the wells had good cementing operations with the exception of 1D-103. This was the well drilled two years ago and failed to get returns to surface. The bond log was suspect and we went ahead and performed a squeeze. The squeeze only took 9 bbls with fairly high squeeze pressures which told me that the cement was there but I think we may have run the bond log way to soon after the cementing operation (+/-48 hours, SLB recommends 72 hours). If you have any questions give me a call. Steve 263-4620 'T~~'\5- ~o<:.û~c.."\~ ~ú.(? \f~"ç\ 0\ -\ ~ fA<-\((£ \- o.~""Sfè.s ~(f2~ ~Çð \ \-'\""L\ \:[ ·~O\·· \ t:.. - \ \ ~ t- L~\.._~. ---- Ld~ 1\-.&: '\ :6'\ '-> \~~ ~ \ ~Q\,- ~cù~~~ k>- '-> \")<Lt.-c'- ~ \0.(£2)\ ",\-\¡-.e ~S.F\\v~, ,ç~ \ ~.. c.. ~- t \ ~~Q.\\.> \J'-.) c.\ctc¿)Q ~<:\--tv(\ I~J .-\-Ð \'O-~~ Cß-CCt;:f'klÞ \G; \\'-:~J~E~· , ~2f1¡v¿~ ~ ~I t('-O '..:> · / / / / / / / / / / ""'. ../ I Kuparuk lD Pad, lD-103, lD-I03 VI I I Kul Kuparuk IE Pad, IE-123, lE-123 V2 I 7000 ANTI-COLLISION SETTINGS ConocJ'Phillips 3538 3598 InterpoLadoo Method:TVD Interval: 1.000 Depth Range From: 3478.000 To: 3788.250 Maximum Range: 1376.290 RefereDce: Definitive Survey o Ku aruk IE Pad IE-168 6000 5000 4000 '2 ~ 0 0 0 ~ 3000 +' ~ 0 ~ ~ 0 !ZJ 2000 3718 1000 Circles of 1320' Radius -1000 -2000 3000 4000 5000 W est( - )/East( +) [1000ftlin] 6000 7000 8000 !!ipI!!!r"'.....y-!5LJn a...LLJNGI .."VIE:._ ~ ","-"~""~" ............" / C' -- J~J X ." ""-" "" TMD 4,425.0 SUPERVISOR AUTH MD D Gladdenl P Wilson 13,521.0 0 CURRENT STATUS DAILY INT W/O MUD Stuck 10 3/4" Cs Off Btm, Set Emer enc 0 24 HR FORECAST DATE OF LAST SAFETY MEETING DAILY TOTAL Weld on Head, NU Wellhead & BOPs & Test, PU 4" DP & BHA 10/30/2004 339,152 LITHOLOGY JAR HRS OF SERVICE BHA HRS SINCE INSP LEAKOFF AFE AUTH. 10043228 BIT XTRIC STC 1 1.25 13.500 MOTOR M1XP 1 29.00 8.000 SHORT NMDC 1 9.95 8.062 2.875 NM STAB 1 5.65 8.000 2.625 SHORT NMDC 1 5.00 8.000 2.875 NM DBL PIN XIO 1 0.83 7.750 2.875 CLOSURE SUB 1 2.57 8.250 2.875 MWD 1 37.11 8.000 NMXO 1 1.65 8.000 2.875 NMCSDP 1 31.00 6.750 2.875 NMCSDP 1 30.94 6.750 2.875 NMCSDP 1 30.98 6.750 2.875 NMXO 1 2.48 8.000 2.875 HWDP-3 3 92.61 5.000 3.000 JARS 1 30.25 6.250 2.250 HWDP-26 26 797.46 5.000 3.000 GHOST REAMER 1 7.13 6.875 2.625 "G-105" DP 5.000 4.281 Printed: 2/4/2005 2:46:41 PM DRLG SURFAC Drilled 13 1/2" hole per directional plan from 4,361' to 4,425' MD/2,481' TVD (64') (Csg Pt) ART .3 hrs, AST -0- hrs, 10-25K wob, 110 rpm's, 165 spm, 700 gpm, off btm pressure 2,400 psi, on btm 2,600 psi, off btm torque 11 K ft-Ibs, on btm 13K ft-Ibs, rot wt 100K, up wt 150K, dn wt 63K, 9.4 ppg MW, 160 Vis SURFAC Circ hole to clear BHA, circ at 700 gpm, 2,400 psi SURFAC Monitored well-static SURFAC Backreamed out of hole from 4,425' to BHA at 1,115', backreamed out at 110 rpm's, 550 gpm at 1,700 psi, last 2 stds pulled slower to circ hole clean, no problems POOH SURFAC Monitored well at BHA-static, LD ghost reamer, POOH standing back HWDP, LD std of NM flex DC's, MWD, motor and bit, cleared rig floor SURFAC RU Doyons 103/4" csg equipment with Franks fill up tool SURFAC Held PJSM with rig crew and tong operator on running of csg SURFAC MU 103/4" float shoe, 2 jts 103/4" 45.5# L-80, BTC csg and fit collar, thread locked conn below FC and circ thru shoe track, RIH with 103/4" csg to 2,030' (49 Jts & 1-10' pup jt), st wt up 117K, dn wt 77K SURFAC RIH circ csg down from 2,030' to 2,301' circ out heavy mud, circ hole clean while RIH, staged pump rate up to 6 bpm at 375 psi SURFAC Cont RIH with 103/4" csg, MU hanger and landed csg with float shoe at 4,419' and float collar at 4,335', no problems RIH, Ran a total of 106 jts (4,373') of 45.5#, L-80, BTC csg and 1-10' pup jt, total including float equip, csg and hanger, 4,389', ran 15 bow spring centralizers and 2 stop rings per well plan, st wt up 215K, dn wt 62K SURFAC Began to circ and cond mud thru fill up tool, circ at 4 bpm 350 psi SURFAC While reciprocating pipe, csg hanger snagged riser causing the riser to PU out of diverter causing 4 bbls of mud to spill into cellar, cleaned up cellar and reinstalled riser SURFAC Cont to circ and condition mud thru fill up tool, staged pump rate up to 7 bpm at 490 psi, circ 2X btms up, st wt up 195K dn wt 66K SURFAC LD Franks fill up tool, blow down top drive and MU Dowell cement head SURFAC Fin circ and cond mud for cementing, circ at 7 bpm, 450 psi, conditioned mud from 9.6 ppg, 83 vis, PV 23, YP 41 to 9.3 ppg, 39 vis, PV 14, YP 12, Hanger was tagging 1" high, pulled hanger to rig floor and looked ok with small area of scarring, held PJSM with Dowell, APC vac truck drivers and rig crew while circ hole PUMP SURFAC Turned over to Dowell and pumped 10 bbls of CW 100 at 8.3 ppg, pressure tested lines to 3,500 psi, pumped add. 40 bbls of CW 100 (50 bbls Total), then pumped 50 bbls of 10.5 ppg XL Mudpush, ave 5 bpm at 200 psi, shut down and dropped btm plug, began mixing and pumping lead cement, at report time have pumped 200 bbls of 570 bbls of 10.7 ppg Arctic set lite cement, st wt up 195K, dn wt 67K 24 HR SUMMARY: Drilled 13 1/2" hole F/4,361' to 4,425' (Csg Pt), Backreamed Out of Hole to HWDP, POOH & LD BHA #2, RU & Ran 106 Jts of 103/4" Csg, MU Hanger & Landed Csg @ 4,419', Circ & Cond Mud FI Cmtg & Began Pumping Lead Cmt 00:00 00:15 0.25 DRILL P 00:15 00:30 0.25 DRILL P CIRC 00:30 00:45 0.25 DRILL P OBSV 00:45 05:45 5.00 DRILL P REAM 05:45 09:00 3.25 DRILL P PULD 09:00 10:45 1.75 CASE P RURD 10:45 11:00 0.25 CASE P SFTY 11:00 14:15 3.25 CASE P RUNC 14:15 15:45 1.50 CASE P RUNC 15:45 18:30 2.75 CASE P RUNC 18:30 18:45 0.25 CEMENT CIRC 18:45 19:15 0.50 CEMENT OTHR 19:15 20:30 1.25 CEMENT CIRC 20:30 21:00 0.50 CEMENT RURD 21:00 22:45 1.75 CEMENT CIRC 22:45 00:00 1.25 CEMENT Printed: 2/4/2005 2:46:41 PM Printed: 2/4/2005 2:46:41 PM SUPERVISOR D Gladdenl P Wilson CURRENT STATUS Finish PU & Standin Back 4" DP 24 HR FORECAST MU 97/8" BHA #3, TIH, Test Cs ,Drill Out, LOT& Drill LrrHOLOGY JAR HRS OF SERVICE 01 :00 01: 15 0.25 CEMENT DISP 01 :15 01:45 0.50 CEMENT OTHR 01:45 05:00 3.25 WELCTL EQRP 05:00 06:00 1.00 CEMENT RURD 06:00 09:00 3.00 WELCTL NUND 09:00 12:00 3.00 WELCTL EQRP 12:00 13:45 1.75 DRILL P RIRD 13:45 14:30 0.75 RIGMNT P RSRV 14:30 15:30 1.00 WELCTL NUND 15:30 18:15 2.75 WELCTL NUND 18:15 23:00 4.75 WELCTL BOPE 23:00 23:30 0.50 DRILL P OTHR TMD 4,425.0 AUTH MD 13,521.0 DAILY INT w/o MUD o DATE OF LAST SAFETY MEETING DAILY TOTAL 10/31/2004 287,697 LEAKOFF AFE AUTH. 10043228 LAST BOP PRES TEST 10/31/2004 SURFAC Cont to cement 10 3/4" csg, pumped an additional 370 bbls of lead cmt (570 bbls total, 720 sxs) at 10.7 ppg and 4.45 yield with additives, ave 7 bpm at 150 psi, followed with 97 bbls, 220 sxs of tail cmt at 12.0 ppg and 2.49 yield with add. ave 6 bpm at 320 psi, shut down and dropped top plug. NOTE: while reciprocating pipe and after pumping 475 bbls of lead cmt and with 50 bbls of lead cmt out of shoe, pipe stuck off hanger 1', attempted to work pipe down with no success, was able to PU on pipe, but was unable to get back down into hanger, PU on pipe 5' to get hanger and pup jt above landing ring, Landed csg with fit shoe at 4,414' with fit collar at 4,330' SURFAC Dowell pumped 20 bbls FW and turned over to rig and rig displaced cmt with 398 bbls of 9.4 ppg mud, ave 7 bpm, initial pressure 550 psi, max pressure 800 psi, slowed to 4 bpm and bumped plugs on calc displacement to 1,400 psi, ck floats and floats held, CIP at 01:15, Had 178 bbls of 10.7 ppg lead cmt back to surface NOTE: Had 1 Hr time change SURFAC Flushed CMT out of diverter system and flowline SURFAC ND diverter line and lifted up riser, diverter and starting head, set 103/4" emergency slips with 50K Ibs string wt, made rough cut on 103/4" csg and set diverter back down SURFAC RD cement head, LD landing jt with hanger and cut-off piece of 103/4" csg SURFAC ND diverter and starting head, used crane to set out dverter system over flow line of well 1 E-28. DSO had well shut in during operation. SURFAC Made final cut on 103/4" csg and GBR welder welded on Vetco/Gray csg head adapter per Vetco/Gray procedure. VetcoGray rep present for complete operation. SURFAC Changed out saver sub, bell guide and grabber on top drive to 4" SURFAC Serviced top drive and drawworks while allowing well head to cool down, tested weld on adapter head to 2,000 psi for 10 min and ck ok SURFAC Oriented and NU Vetco/Gray 13 5/8" 5M# MB 222 wellhead, tested btm wellhead sub to 5,000 psi for 10 min and ck ok SURFAC NU BOP stack SURFAC RU and tested BOPE, choke manifold, 4" and 5" floor valves, rams including 7 5/8" csg rams to 250 psi low and 3,500 psi high, annular to 250 psi low and 2,800 psi high, John Crisp with AOGCC waived witnessing of test SURFAC Installed wear bushing Printed: 2/4/2005 2:47:25 PM 24 HR SUMMARY: Fin Cmtg 103/4" Csg, Stuck Csg Off Btm W/Cmtg, Bumped Plugs & Floats Held, Had 178 bbls Cmt Back to Surface, PU Diverter & Set Emergency Slips, Cut Off Csg, ND Diverter, Welded on Csg Head Adapter, NU Wellhead & BOPE and Tested BOP'S Printed: 2/4/2005 2:47:25 PM TMD 8,158.0 SUPERVISOR AUTH MD M Thornton! P Wilsonl D 13,521.0 CURRENT STATUS DAILY INT W/O MUD PU & Standin Back S iral Wt & HWDP 0 24 HR FORECAST DATE OF LAST SAFETY MEETING DAILY TOTAL PU 6 3/4" BHA #5 & 4" DP, RIH, Drill Out, LOT, Drill Ahead 11/5/2004 475,821 LITHOLOGY JAR HRS OF SERVICE BHA HRS SINCE INSP LEAKOFF AFE AUTH. 10043228 LAST BOP PRES TEST 10/31/2004 00:00 01:15 1.25 CASE P RUNC INTRM1 RIH with 7 5/8" csg from 1,140' to 2,002' 01:15 01:45 0.50 CASE P CIRC INTRM1 Circ a csg capacity at 2,002', circ at 3 bpm at 300 psi 01:45 04:15 2.50 CASE P RUNC INTRM1 RIH with 7 5/8" csg from 2,002' to 4,380' to above 103/4" csg shoe 04:15 05:30 1.25 CASE P CIRC INTRM1 LD Franks fill up tool, MU circ swedge and circ a csg capacity at shoe, staged pump rate up to 5 bpm at 350 psi, st wt up 11 OK, dn wt 75K, changed out rubber cup on fill up tool and made tool back up 05:30 10:15 4.75 CASE P RUNC INTRM1 Fin RIH with 7 5/8" csg, RIH to btm at 8,158' with no problems. Landed 7 5/8" csg at 8,157' MD/3,715' TVD with float collar at 8,026', ran a total of 189 jts 7 5/8",29.7#, L-80 BTC-M csg with 5-pup jts (Total 8,165.95'), ran 58 tandem rise cent on 58 stop rings per well plan, 3/2 jts (every 30'), did not use hanger, will use emergency slips 10:15 11 :15 1.00 CEMENT CIRC INTRM1 Circ btms up thru Franks fill up tool while conditioning mud, staged pump rate up to 6 bpm, 525 psi, st up wt 190K, dn wt 80K 11 :15 11 :45 0.50 CEMENT RURD INTRM1 LD Franks fill up tool and MU Dowells cement head 11:45 13:30 1.75 CEMENT CIRC INTRM1 Cont to circ and cond mud for cementing, circ at 6 bpm at 425 psi, st wt up 200K, dn 85K, initial MW out, 9.6 ppg, 78 vis, PV 32, YP 40, Conditioned mud to final MW out of 9.2 ppg, 41 vis, 11 YP and 14 PV, Held PJSM with Dowell, APC vac truck drivers and rig crew on cementing csg while circ. 13:30 15:00 1.50 CEMENT PUMP INTRM1 Dowell pumped 10 bbls CW 100 at 8.3 ppg, Pressure tested lines to 3,500 psi, Then pumped 40 add. bbls of CW 100, Pumped 50 bbls of MudPush at 10.5 ppg, Dropped btm plug then pumped 168.2 bbls, (422 sxs) of DeepCrete cmt at 12.5 ppg, 2.26 yield with additives, ave 6.5 bpm at 250 psi, Reciprocated pipe with full returns, shut down, Washed up and dropped btm plug. 15:00 16:15 1.25 CEMENT DISP INTRM1 Rig displaced cement with 9.3 ppg OBM, Bumped plug on calc displacement after pumping 368.3 bbls OBM (96% pump eff.) ave 7.0 bpm while displacing cmt, Max pressure 1100 psi, Slowed pump rate to 3 bpm with 3 bbls left to pump and bumped plug to 1,600 psi, ck floats and held CIP at 16:10 hrs, Reciprocated pipe until 73.0 bbls cmt was around shoe when hole began getting tight and stopped reciprocating wI Shoe @ 8,157', Float Collar @ 8.026', Calc TOC @ 4,786', Had full returns thru out job. 16:15 17:00 0.75 CASE P DEQT INTRM1 Tested 75/8" csg to 3,000 psi for 30 min, good test 17:00 17:30 0.50 CEMENT RURD INTRM1 RD cement head and used rig vacuum to drain landing jt 17:30 18:15 0.75 CASE P NUND INTRM1 ND & PU on BOP stack 18:15 20:30 2.25 CASE P OTHR INTRM1 Set 7 5/8" csg slips with 135K block wt, 100K st wt, made rough cut using cold cut saw and LD cut piece, made final cut and installed pack-off, Tested same Printed: 2/4/2005 2:47:46 PM 18:15 20:30 2.25 CASE P OTHR INTRM1 to 3800 psi f/1 0 min. 20:30 21 :15 0.75 CASE P NUND INTRM1 NU BOP stack and choke line 21:15 22:45 1.50 CASE P RURD INTRM1 RD Doyons 7 518" csg equipment, changed out elevator bales and installed wear bushing NOTE: at 21 :30 Pumped 30 bbls fresh water down 7 5/8" x 10 3/4" annulus, ave 1 bpm at 720 psi 22:45 23:00 0.25 WELCTL BOPE INTRM1 Tested choke line at 250 psi and 3,500 psi, due to breaking flange on stack to set slips 23:00 00:00 1.00 DRILL P OTHR INTRM1 Loaded pipe shed with 4" XT-39 DP and strapped 24 HR SUMMARY: RIH WI7 5/8" Csg to 4,380', Circ Btms Up, RIH W/Csg to Btm @ 8,158' WINo Problems, Circ & Cond Mud for Cmtg, Cemented Csg W/Full Returns or Problems, ND & Set Emergency Slips, Installed Pack-Off & NU Stack, Loaded Pipe Shed W/4" DP ConocoPhillips Company Doyon Drilling 'nc Baker Hughes Inteq Baker Hughes Inteq - D Doyon Universal Service M-I Drilling Fluids APC - Alaska Petroleum PRA - Petroleum Resour Swaco 2 1 1 2 Printed: 2/4/2005 2:47:46 PM Hole Size: 9.875 (in) Hole Size: Hole Size: Hole Size: TMD Set: 8,157 (ft) sa TMD: (ft) TMD Set: Top Set: (ft) Date Set: 11/5/2004 sa Date: Date Set: BTM set: (ft) Csg Type: Intermediate CasinglLi sa Type: Csg Type: Plug Date: Csg Size: 7.625 (in.) sa TMD: Plug Type: sa Date: Drilled Out: Cmtd. Csg: Intermediate Casing/Li Cmtd. Csg: Cmtd. Csg: Cmtd. Csg: Cement Co: Dowell Schlumberger Cementer: Jerry Culpepper Pipe Movement: Reciprocating Type: Cement Casing Volume Excess %: 25.00 Meas. From: 0 Time Circ Prior To Cementing: 2.75 Mud Circ Rate: 252 (gpm) Mud Circ Press: 525 (psi) Start Mix Cmt: 14:30 Start Slurry Displ: 14:30 Start Displ: 15:00 End Pumping: 16:10 End Pump Date: 11/5/2004 Top Plug: Y Bottom Plug: Y Disp Avg Rate: Disp Max Rate: Bump Plug: Press Prior: Press Bumped: Press Held: Float Held: 7.00 (bbl/min) 7.00 (bbl/min) y 1,100 (psi) 1,600 (psi) 3 (min) Y Returns: 100 Total Mud Lost: (bbl) Cmt Vol to Surf: (bbl) Ann Flow After: N Mixing Method: On Fly Density Meas By: Densometer Slurry Data Fluid Type: CW 100 Slurry Interval: 3,515.00 (ft)To: Water Source: Test Data Thickening Time: Free Water: (%) Fluid Loss: (cc) Fluid Loss Pressure: (OF) Description: 2,255.00 (ft) Cmt Vol: (bbl) Slurry Vol: (sk) Temperature: (OF) Temperature: (OF) Temperature: (OF) Density: 8.30 (ppg) Water Vol: (bbl) Class: Yield: (ft3/sk) Other Vol: () Purpose: Chemical Was Mix Water: (gal) Foam Job: N Time Compressive Strength 1: Compressive Strength 2: Temp (OF) (OF) Pressure (psi) (psi) Printed: 2/4/2005 2:48: 19 PM Slurry Data Fluid Type: MUDPUSH XL Slurry Interval: 4,786.00 (ft)To: Water Source: Test Data Thickening Time: Free Water: (%) Fluid Loss: (cc) Fluid Loss Pressure: (OF) Description: MUDPUSH XL Class: 3,515.00 (ft) Cmt Vol: (bbl) Density: 10.50 (ppg) Yield: (ft3/sk) Slurry Vol: (sk) Water Vol: (bbl) Other Vol: 0 Purpose: SPACER Mix Water: (gal) Foam Job: N Temperature: (OF) Temperature: (OF) Temperature: (OF) Time Compressive Strength 1: Compressive Strength 2: Pressure (psi) (psi) Temp (OF) (OF) Slurry Data Fluid Type: TAIL Slurry Interval: 8,157.00 (ft)To: Water Source: Test Data Thickening Time: Free Water: (%) Fluid Loss: (cc) Fluid Loss Pressure: (OF) Description: DeepCrete 4,786.00 (ft) Cmt Vol: 168.2 (bbl) Slurry Vol:422 (sk) Class: Density: 12.50 (ppg) Yield: 2.24 (ft3/sk) Water Vol: 74.0 (bbl) Other Vol: 0 Purpose: TAIL Mix Water: 7.40 (gal) Foam Job: N Temperature: (OF) Temperature: (OF) Temperature: (OF) Time Compressive Strength 1: Compressive Strength 2: Pressure (psi) (psi) Temp (OF) (OF) DEFOAMER Printed: 2/4/2005 2:48: 19 PM Test Press: 3,000 (psi) For: 30 (min) Cement Found between Shoe and Collar: N Pressure: (ppge) Tool: N Open Hole: (ft) Hrs Before Test: Liner Lap: Pos Test: (ppge) Neg Test: (ppge) Hrs Before Test: Cement Found on Tool: N Tool: N Tool: N CBL Run: N Under Pressure: (psi) Bond Quality: Cet Run: N Bond Quality: Temp Survey: N Hrs Prior to Log: Cement Top: (ft) How Determined: TOC Sufficient: N Job Rating: If Unsuccessful Detection Indicator: Remedial Cementing Required: N Number of Remedial Squeezes: Cont to circ and cond mud for cementing, circ at 6 bpm at 425 psi, st wt up 200K, dn 85K, initial MW out, 9.6 ppg, 78 vis, PV 32, YP 40, Conditioned mud to final MW out of 9.2 ppg, 41 vis, 11 YP and 14 PV, Held PJSM with Dowell, APC vac truck drivers and rig crew on cementing csg while circ. Dowell pumped 10 bbls CW 100 at 8.3 ppg, Pressure tested lines to 3,500 psi, Then pumped 40 add. bbls of CW 100, Pumped 50 bbls of MudPush at 10.5 ppg, Dropped btm plug then pumped 168.2 bbls, (422 sxs) of DeepCrete cmt at 12.5 ppg, 2.26 yield with additives, ave 6.5 bpm at 250 psi, Reciprocated pipe with full returns, shut down, Washed up and dropped btm plug. Rig displaced cement with 9.3 ppg OBM, Bumped plug on calc displacement after pumping 368.3 bbls OBM (96% pump eff.) ave 7.0 bpm while displacing cmt, Max pressure 1100 psi, Slowed pump rate to 3 bpm with 3 bbls left to pump and bumped plug to 1,600 psi, ck floats and held CIP at 16:10 hrs, Reciprocated pipe until 73.0 bbls cmt was around shoe when hole began getting tight and stopped reciprocating wI Shoe @ 8,157', Float Collar @ 8.026', Calc TOC @ 4,786', Had full retums thru out job. Printed: 2/4/2005 2:48:19 PM Hole Size: 13.500 (in) Hole Size: Hole Size: Hole Size: TMD Set: 4,415 (ft) sa TMD: (ft) TMD Set: Top Set: (ft) Date Set: 10/30/2004 sa Date: Date Set: BTM set: (ft) Csg Type: Surface Casing sa Type: Csg Type: Plug Date: Csg Size: 10.750 (in.) sa TMD: Plug Type: sa Date: Drilled Out: Cmtd. Csg: Surface Casing Cmtd. Csg: Cmtd. Csg: Cmtd. Csg: Cement Co: Dowell Schlumberger Cementer: Kevin Anderson Pipe Movement: Stuck while cmt Type: Cement Casing Volume Excess %: Meas. From: 178 Time Circ Prior To Cementing: 3.00 Mud Circ Rate: 294 (gpm) Mud Circ Press: 450 (psi) Start Mix Cmt: 23:25 Start Slurry Displ: 23:25 Start Displ: 01 :00 End Pumping: 01:15 End Pump Date: 10/31/2004 Top Plug: Y Bottom Plug: Y Disp Avg Rate: Disp Max Rate: Bump Plug: Press Prior: Press Bumped: Press Held: Float Held: 7.00 (bbl/min) 7.00 (bbl/min) Y 800 (psi) 1 ,400 (psi) 3 (min) Y Returns: 100 Total Mud Lost: (bbl) Cmt Vol to Surf: 178.00 (bbl) Ann Flow After: N Mixing Method: Fly Density Meas By: Densometer Slurry Data Fluid Type: CW100 Slurry Interval: (ft) To: (ft) Water Source: Test Data Thickening Time: Free Water: (%) Fluid Loss: (cc) Fluid Loss Pressure: (OF) Description: Cmt Vol: (bbl) Slurry Vol: (sk) Temperature: (OF) Temperature: (OF) Temperature: CF) Density: 8.30 (ppg) Water Vol: (bbl) Class: Yield: (ft3/sk) Other Vol: 0 Time Compressive Strength 1: Compressive Strength 2: Purpose: Chemical Was Mix Water: (gal) Foam Job: N Temp (OF) (OF) Pressure (psi) (psi) Printed: 2/4/2005 2:48:30 PM Slurry Data Fluid Type: MUDPUSH Slurry Interval: (ft) To: (ft) Water Source: Test Data Thickening Time: Free Water: (%) Fluid Loss: (cc) Fluid Loss Pressure: (OF) Description: MUDPUSH XL Class: Cmt Vol: (bbl) Density: 10.50 (ppg) Yield: (ft3/sk) Slurry Vol: (sk) Water Vol: (bbl) Other Vol: 0 Temperature: (OF) Temperature: (OF) Temperature: (OF) Time Compressive Strength 1: Compressive Strength 2: Temp (OF) (OF) Purpose: SPACER Mix Water: (gal) Foam Job: N Pressure (psi) (psi) Slurry Data Fluid Type: LEAD Slurry Interval: 3,419.00 (ftyro: (ft) Water Source: Test Data Thickening Time: Free Water: (%) Fluid Loss: (cc) Fluid Loss Pressure: (OF) Description: AS Lite Cmt Vol: 570.0 (bbl) Slurry Vol:720 (sk) Class: Density: 10.70 (ppg) Yield: 4.45 (ft3/sk) Water Vol: 345.0 (bbl) Other Vol: 0 Purpose: Mix Water: 20.15 (gal) Foam Job: N Pressure (psi) (psi) Slurry Data Fluid Type: TAIL Slurry Interval: 4,414.00 (ftyro: Water Source: Test Data Thickening Time: Free Water: (%) Fluid Loss: (cc) Fluid Loss Pressure: (OF) Temperature: (OF) Temperature: (OF) Temperature: rF) Time Compressive Strength 1: Compressive Strength 2: Temp (OF) (OF) %BWOC %BWOC %BWOC %BWOC %BWOC %BWOC Description: DeepCrete 3,414.00 (ft) Cmt Vol: 97.0 (bbl) Slurry Vol:220 (sk) Class: Density: 12.00 (ppg) Yield: 2.49 (ft3/sk) Water Vol: 42.4 (bbl) Other Vol: 0 Temperature: (OF) Temperature: (OF) Temperature: (OF) Time Compressive Strength 1: Compressive Strength 2: Temp (OF) (OF) Purpose: TAIL Mix Water: 8.10 (gal) Foam Job: N Pressure (psi) (psi) Printed: 2/4/2005 2:48:30 PM Test Press: (psi) For: (min) Cement Found between Shoe and Collar: Pressure: (ppge) Tool: Open Hole: (ft) Hrs Before Test: Liner Lap: Pos Test: (ppge) Neg Test: (ppge) Hrs Before Test: Cement Found on Tool: Tool: Tool: CBL Run: Under Pressure: (psi) Bond Quality: Cet Run: Bond Quality: Temp Survey: Hrs Prior to Log: Cement Top: (ft) How Determined: TOC Sufficient: Job Rating: If Unsuccessful Detection Indicator: Remedial Cementing Required: Number of Remedial Squeezes: 10/30104 Began to circ and cond mud thru fill up tool, circ at 4 bpm 350 psi While reciprocating pipe, csg hanger snagged riser causing the riser to PU out of diverter causing 4 bbls of mud to spill into cellar, cleaned up cellar and reinstalled riser Cont to circ and condition mud thru fill up tool, staged pump rate up to? bpm at 490 psi, circ 2X btms up, st wt up 195K dn wt 66K LD Franks fill up tool, blow down top drive and MU Dowell cement head Fin circ and cond mud for cementing, circ at 7 bpm, 450 psi, conditioned mud from 9.6 ppg, 83 vis, PV 23, YP 41 to 9.3 ppg, 39 vis, PV 14, YP 12, Hanger was tagging 1" high, pulled hanger to rig floor and looked ok with small area of scarring, held PJSM with Dowell, APC vac truck drivers and rig crew while circ hole Turned over to Dowell and pumped 10 bbls of CW 100 at 8.3 ppg, pressure tested lines to 3,500 psi, pumped add. 40 bbls of CW 100 (50 bbls Total), then pumped 50 bbls of 10.5 ppg XL Mudpush, ave 5 bpm at 200 psi, shut down and dropped btm plug, began mixing and pumping lead cement, at report time have pumped 200 bbls of 570 bbls of 10.7 ppg Arctic set lite cement, st wt up 195K, dn wt 67K 10/31/04 Cont to cement 103/4" csg, pumped an additional 370 bbls of lead cmt (570 bbls total, 720 sxs) at 10.7 ppg and 4.45 yield with additives, ave 7 bpm at 150 psi, followed with 97 bbls, 220 sxs of tail cmt at 12.0 ppg and 2.49 yield with add. ave 6 bpm at 320 psi, shut down and dropped top plug. NOTE: while reciprocating pipe and after pumping 475 bbls of lead cmt and with 50 bbls of lead cmt out of shoe, pipe stuck off hanger 1', attempted to work pipe down with no success, was able to PU on pipe, but was unable to get back down into hanger, PU on pipe 5' to get hanger and pup jt above landing ring, Landed csg with fit shoe at 4,414' with fit collar at 4,330' Dowell pumped 20 bbls FW and turned over to rig and rig displaced cmt with 398 bbls of 9.4 ppg mud, ave 7 bpm, initial pressure 550 psi, max pressure 800 psi, slowed to 4 bpm and bumped plugs on calc displacement to 1 ,400 psi, ck floats and floats held, CI P at 01 : 15 (NOTE: Had 1 Hr time change) Had 178 bbls of 10.7 ppg lead cmt back to surface Printed: 2/4/2005 2:48:30 PM ... Printed: 2/4/2005 2:48:30 PM . ~ ConocoPhillips . Randy Thomas Kuparuk Drilling Team Leader Drilling & Wells P. O. Box 100360 Anchorage, AK 99510-0360 Phone: 907-265-6830 December 16, 2004 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West ¡th Avenue Suite 100 Anchorage, Alaska 99501 Subject: Well Completion Reports for 1 E-168, 1 E-168L 1, 1 E-168L2 Dear Commissioner: ConocoPhillips Alaska, Inc. submits the attached Well Completion Reports for the recent drilling operations of the Kuparuk wells 1 E-168, 1 E-168L 1 and 1 E-168L2. If you have any questions regarding this matter, please contact me at 265-6830 or Steve Shultz at 263-4620. Sincerely, ~~ R. Thomas Kuparuk Drilling Team Leader CPAI Drilling RT/skad RECEIVED DEC 2 2 2004 Alaska Oil & Gas Cons. Commission Anchorage I STATE OF ALASKA- Al KA Oil AND GAS CONSERVATION CO'-SSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1a. Well Status: Oil 0 Gas U Plugged D Abandoned D Suspended D WAG 0 1b. Well Class: 20AAC 25.105 20AAC 25.110 Development 0 Exploratory 0 GINJ 0 WINJ 0 WDSPL 0 No. of Completions _ Other - Service 0 Stratigraphic Test 0 2. Operator Name: 5. Date Comp.. Susp.. 12. Permit to Drill Number: , ConocoPhillips Alaska. Inc. or Aband.: November 26. 2004 204-200 3. Address: 6. Date Spudded: , 13. API Number: P. O. Box 100360. Anchorage. AK 99510-0360 October 28. 2004 50-029-23230-00 4a. Location of Well (Govemmental Section): 7. Date TD Reached: J 14. Well Name and Number: Surface: 207' FNL. 640' FEL, Sec. 21, T11 N, R1OE, UM November 10, 2004 1 E-168 At Top Productive 8. KB Elevation (ft): 15. Field/Pool(s): Horizon: 374' FNL, 1595' FEL, Sec. 22, T11 N, R1OE, UM 28' RKB Kuparuk River Field Total Depth: 9. Plug Back Depth (MD + TVD): West Sak Oil Pool AD 184' FSL, 1156' FEL, Sec. 10, T11N. R10E, UM 13439' MD 13763' TVD \ 'Æ ,1' 5.."f.M..o:L /4.~( t· 7 .0;'" 4b. Location of Well (State Base Plane Coordinates): 10. Total Depth (MD + TVD): 16. Property Designation: Surface: x- 549890 , y- 5959380 , Zone-4 ' 13477' MD I 3763' TVD / ALK 25651/25648 TPI: x-554216 y- 5959243 Zone- 4 11. Depth where SSSV set: 17. Land Use Permit: Total Depth: x- 554603 y- 5965083 Zone- 4 nIa ADL 469/466 18. Directional Survey: Yes 0 NoU 19. Water Depth, if Offshore: 20. Thickness of NIA feet MSL Permafrost: 1895' MD 21. Logs Run: GRlRes 22. '. CASING. LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTH TVD HOLE AMOUNT CEMENTING RECORD CASING SIZE WT. PER FT. GRADE TOP BOTTOM TOP BOTTOM SIZE PULLED 20" 62.58# H-40 28' 108' 28' 108' 42" 250 sx AS I 10.75" 45.5# L-80 28' 4415' 28' 2477' 13.5" 720 sx AS Lite. 220 sx DeepCrete 7.625" 29.7# L-80 28' 8158' 28' 3715' 9.875" 422 sx DeepCrete 4.5" 12.6# L-80 7437' 13473' 3553' 3763' 6.75" slotted liner 23. Perforations open to Production (MD + TVD of Top and Bottom 24. TUBING RECORD Interval. Size and Number; if none. state "none"): SIZE DEPTH SET (MD) PACKER SET 4.5" 6158' 7437' & 17 constrictors packers run slots in linerfrom 8571 '-8819', 9129'-9436', 9527'-9653', 25. ACID. FRACTURE. CEMENT SQUEEZE, ETC. 9964'·10712', 10961 '-11 086', 11335'-11830', 11923'-12851', DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED 13006'·13130',13343'-13436' n/a 32 slots /ft 26. PRODUCTION TEST Date First Production Method of Operation (Flowing. gas lift. etc.) December 12, 2004 Gas Lift oil - production shared with 1 E-168L 1 and 1 E-168L2 Date of Test Hours Tested Production for OIL-BBL GAS-MCF W A TER-BBL CHOKE SIZE GAS-Oil RATIO 12/12/2004 7 hours Test Period --> 693 382 13 25 Bean Flow Tubing Casing Pressure Calculated OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY - API (corr) press. 463 psi not available 24-Hour Rate -> 2323 1400 46 not available 27. CORE DATA Brief description of lithology. porosity. fractures. apparent dips and presence of oil, gas or water (attach separate sheet, if necessary). Submit core chips; if none. state "none". r~--· RBDMS 8Ft JAN 0 '¡ 2005 ..1(. zL. : r>:i RECEIVED NONE ie'" ". ".,,' . DEC 2 2 2004 ..Ii> ,,~< ORJGif~AL Alaska Oil & Gas Caris. CommissIOn }, '''R¡'~'''~^ .. Form 10-407 Revised 12/2003 CONTINUED ON REVERSE 28. 29. GEOLOGIC MARKERS FORMATION TESTS NAME MD TVD Include and briefly summarize test results. List intervals tested, and attach detailed supporting data as necessary. If no tests were conducted, state "None". 1E-168 West Sak A 7603' 3590' NIA 30. LIST OF ATTACHMENTS Summary of Daily Operations, Directional Survey 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Steve Shultz @ 263-4620 Printed N~V ThL>mas Signature -\ \ ~ Title: "-- --=::::..phone KUDaruk DrillinQ Team Leader ur '''i'~ Date tÚ2..l..J<s 'f' Prepared by Sharon Allsup-Drake INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1a: Classification of Service wells: Gas injection, water injection, Water-Alternating-Gas Injection, salt water disposal, water supply for injection, observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 4b: TPI (Top of Producing Interval). Item 8: the Kelly Bushing elevation in feet abour mean low low water. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). Item 20: True vertical thickness. Item 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, Other (explain). Item 27: If no cores taken, indicate "none". Item 29: List all test information. If none, state "None". Form 10-407 Revised 2/2003 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 E-168 1E-168 ROT - DRILLING n1334@ppco.com Doyon 141 Start: Rig Release: Rig Number: 10/27/2004 11/26/2004 Spud Date: 10/28/2004 End: 11/26/2004 Group: Blow down steam and water lines, disconnect service loops and prepare to move rig Moved rig off 1 E-114 and moved to 1 E-168 Spotted sub base over well, set in rig complex's and RU, hooked up service loops and completed rig acceptance checklist Accepted Rig @ 12:00 hrs 10/27104 NU 21 114" 2M diverter system with 16" line, began mixing spud mud and loading pipe shed with 5" DP & HWDP Changed over top drive and iron roughneck from 4" to 5" DP Slip and cut 106' of drlg line and serviced top drive PU and stood back in derrick 38 stds of 5" DP and 10 stds of 5" HWDP and Jars Function test diverter system and checked ok, Chuck Scheeve W/AOGCC waived witnessing of test Began PU 13 1/2" BHA #1 to rig floor MU 131/2" bit, mud motor with 1.8 deg bend on BHA #1and tagged ice at 85' Flooded conductor checking lines for leaks and pressure tested surface equipment Cleaned out ice and cement inside conductor from 85' to 108' Spudded well and drilled 13 1/2" hole from 108' to 231', ART 1 hr POOH to 53', MU MWD and oriented, then MU UBHO sub and oriented, PU 3- NM flex DC's RIH to 231' Drilled 13 1/2" hole per directional plan from 231' to 900' MD/865' TVD (669') ART 1.7 hrs, AST 2.3 hrs, 1 0-15K wob, 40-60 rpm's, 140 spm, 592 gpm, off btm pressure 1,300 psi, on btm 1,400 psi, off btm torque 2K ft-Ibs, on btm 4K ft-Ibs, rot wt 85K, up wt 85K, dn wt 83K, took 2-gyro surveys on slickline at 279' and 369' 10.00 DRILL DRLG SURFAC Drilled 13 1/2" hole per directional plan from 900' to 2,034' MD/1 ,602' TVD (1,134') ART 2.6 hrs, AST 4.5 hrs, 10-20K wob, 60 rpm's, 140 spm, 592 gpm, off btm pressure 1,600 psi, on btm 1,850 psi, off btm torque 4K ft-Ibs, on btm 6K ft-Ibs, rot wt 80K, up wt 95K, dn wt 82K Monitored well-static Circ to clear BHA and pumped out of hole from 2,034' to HWDP at 1 ,110', pumped out at 300 gpm at 500 psi, monitored well at HWDP-static POOH on elevators from 1,110' to 650' to change out motor per directional plan, no problems POOH Fin POOH, stood back HWDP and MWD, LD 1.8 deg bend MM and bit MU RR bit and 1.2 deg bend MM and oriented, RIH with MWD and HWDP, MU ghostreamer RIH to 1,115' RIH from 1,115'to 1,951', washed 83'to btm at 2,034 with no problems Drilled 13 1/2" hole per directional plan from 2,034' to 3,061' MD/1,972' TVD (1,027') ART 4.2 hrs, AST.7 hrs, 5-25K wob, 110 rpm's, 165 spm, 700 gpm, off btm pressure 2,250 psi, on btm 2,350 psi, off btm torque 5K ft-Ibs, on btm 9K ft-Ibs, rot wt 86K, up wt 103K, dn wt 76K, 9.4 ppg MW, 200 Vis 12.00 DRILL DRLG SURFAC Drilled 13 1/2" hole per directional plan from 3,061' to 4,361' MD/2,459' TVD (1,300') ART 6.2 hrs, AST 1.7 hrs, 10-25K wob, 110 rpm's, 165 spm, 700 gpm, off btm pressure 2,400 psi, on btm 2,600 psi, off btm torque 11K ft-Ibs, on btm 14K ft-Ibs, rot wt 98K, up wt 147K, dn wt 63K, 9.4 ppg MW, 180 Vis Began seeing gas hydrates at 3,800' MD/2,236' TVD 10/27/2004 00:00 . 02:00 2.00 MOVE DMOB MOVE 02:00 - 06:00 4.00 MOVE MOVE MOVE 06:00 - 12:00 6.00 MOVE RURD MOVE 12:00 - 14:30 2.50 WELCT NUND SURFAC 14:30 - 17:00 2.50 DRILL RIRD SURFAC 17:00 - 18:30 1.50 RIGMNT RSRV SURFAC 18:30 - 23:00 4.50 DRILL PULD SURFAC 23:00 - 23:30 0.50 WELCT BOPE SURFAC 23:30 - 00:00 0.50 DRILL PULD SURFAC 1 0/28/2004 00:00 - 01:15 1.25 DRILL PULD SURFAC 01:15 - 01:45 0.50 DRILL CIRC SURFAC 01 :45 - 02:00 0.25 CEMEN COUT SURFAC 02:00 - 03:15 1.25 DRILL DRLG SURFAC 03:15 - 05:00 1.75 DRILL TRIP SURFAC 05:00 - 12:00 7.00 DRILL DRLG SURFAC 12:00 - 22:00 22:00 - 22:15 0.25 DRILL OBSV SURFAC 22:15 - 23:30 1.25 DRILL TRIP SURFAC 23:30 . 00:00 0.50 DRILL TRIP SURFAC 10/29/2004 00:00 - 02:00 2.00 DRILL TRIP SURFAC 02:00 - 03:30 1.50 DRH±-- PULD SURFAC 03:30 - 04:00 0.50 DRILL TRIP SURFAC 04:00 - 12:00 8.00 DRILL DRLG SURFAC 12:00·00:00 Printed: 12/10/2004 2:59:08 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1E-168 1E-168 ROT - DRILLING n1334@ppco.com Doyon 141 Start: Rig Release: Rig Number: 10/27/2004 11/26/2004 Spud Date: 10/28/2004 End: 11/26/2004 Group: 0.25 DRILL DRLG SURFAC Drilled 13 1/2" hole per directional plan from 4,361' to 4,425' MD/2.481· TVD (64') (Csg Pt) ART .3 hrs, AST -0- hrs, 1 D-25K wob, 110 rpm's, 165 spm, 700 gpm. off btm pressure 2.400 psi, on btm 2,600 psi. off btm torque 11 K ft-Ibs, on btm 13K ft-Ibs, rot wt 100K, up wt 150K, dn wt 63K, 9.4 ppg MW. 160 Vis Circ hole to clear BHA, circ at 700 gpm, 2.400 psi Monitored well-static Backreamed out of hole from 4,425' to BHA at 1,115', backreamed out at 110 rpm's. 550 gpm at 1,700 psi. last 2 stds pulled slower to circ hole clean, no problems POOH Monitored well at BHA-static, LD ghost reamer. POOH standing back HWDP, LD std of NM flex DC's. MWD. motor and bit, cleared rig floor RU Doyons 10314" csg equipment with Franks fill up tool Held PJSM with rig crew and tong operator on running of csg MU 10314" float shoe. 2 jts 10314" 45.5# L-BO. BTC csg and fit collar, thread locked conn below FC and circ thru shoe track. RIH with 103/4" csg to 2,030' (49 Jts & 1-10' pup jt), st wt up 117K, dn wt 77K RIH circ csg down from 2,030' to 2,301' circ out heavy mud, circ hole clean while RIH, staged pump rate up to 6 bpm at 375 psi Cont RIH with 103/4" csg, MU hanger and landed csg with float shoe at 4,419' and float collar at 4.335'. no problems RIH. Ran a total of 106 jts (4,373') of 45.5#, L-BO, BTC csg and 1-10' pup jt. total including float equip, csg and hanger, 4.389'. ran 15 bow spring centralizers and 2 stop rings per well plan, st wt up 215K, dn wt 62K Began to circ and cond mud thru fill up tool. circ at 4 bpm 350 psi While reciprocating pipe, csg hanger snagged riser causing the riser to PU out of diverter causing 4 bbls of mud to spill into cellar, cleaned up cellar and reinstalled riser Cont to circ and condition mud thru fill up tool, staged pump rate up to 7 bpm at 490 psi. circ 2X btms up, st wt up 195K dn wt 66K LD Franks fill up tool, blow down top drive and MU Dowell cement head Fin circ and cond mud for cementing. circ at 7 bpm. 450 psi. conditioned mud from 9.6 ppg. 83 vis, PV 23, YP 41 to 9.3 ppg. 39 vis, PV 14, YP 12, Hanger was tagging 1" high, pulled hanger to rig floor and looked ok with small area of scarring. held PJSM with Dowell. APC vac truck drivers and rig crew while circ hole 1.25 CEMEN PUMP SURFAC Turned over to Dowell and pumped 10 bbls of CW 100 at 8.3 ppg, pressure tested lines to 3.500 psi. pumped add. 40 bbls of CW 100 (50 bbls Total), then pumped 50 bbls of 10.5 ppg XL Mudpush. ave 5 bpm at 200 psi, shut down and dropped btm plug. began mixing and pumping lead cement, at report time have pumped 200 bbls of 570 bbls of 10.7 ppg Arctic set lite cement. st wt up 195K, dn wt 67K 1.00 CEMEN PUMP SURFAC Cont to cement 10 3/4" csg. pumped an additional 370 bbls of lead cmt (570 bbls total, 720 sxs) at 10.7 ppg and 4.45 yield with additives. ave 7 bpm at 150 psi. followed with 97 bbls. 220 sxs of tail cmt at 12.0 ppg and 2.49 yield with add. ave 6 bpm at 320 psi. shut down and dropped top plug. NOTE: while reciprocating pipe and after pumping 475 bbls of lead cmt and with 50 bbls of lead cmt out of shoe. pipe stuck off hanger 1', attempted to work pipe down with no success, was able to PU on pipe, but was unable to get back down into hanger. PU on pipe 5' to get hanger and pup jt above landing ring, Landed csg with fit shoe at 4.414' with fit collar at 4.330' 10/30/2004 00:00 - 00:15 00:15 - 00:30 0.25 DRILL CIRC SURFAC 00:30 - 00:45 0.25 DRILL OBSV SURFAC 00:45 - 05:45 5.00 DRILL REAM SURFAC 05:45 - 09:00 3.25 DRILL PULD SURFAC 09:00 - 10:45 1.75 CASE RURD SURFAC 10:45 - 11 :00 0.25 CASE SFTY SURFAC 11:00 -14:15 3.25 CASE RUNC SURFAC 14:15 - 15:45 1.50 CASE RUNC SURFAC 15:45 - 18:30 2.75 CASE RUNC SURFAC 18:30 - 18:45 0.25 CEMEN CIRC SURFAC 18:45 - 19:15 0.50 CEMEN OTHR SURFAC 19:15 - 20:30 1.25 CEMEN CIRC SURFAC 20:30·21:00 0.50 CEMEN RURD SURFAC 21 :00 - 22:45 1.75 CEMEN CIRC SURFAC 22:45 - 00:00 10/31/2004 00:00 - 01:00 Printed: 12/10/2004 2:59:08 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 E-168 1 E-168 ROT - DRILLING n1334@ppco.com Doyon 141 Start: 10/27/2004 Rig Release: 11/26/2004 Rig Number: Spud Date: 10/28/2004 End: 11/26/2004 Group: 01:15 - 01:45 0.50 CEMEN SURFAC 01 :45 - 05:00 3.25 WELCT SURFAC 05:00 - 06:00 SURFAC 06:00 . 09:00 3.00 WELCT SURFAC 09:00·12:00 3.00 WELCT SURFAC 12:00 - 13:45 1.75 DRILL RIRD SURFAC 13:45 - 14:30 0.75 RIGMNT RSRV SURFAC 14:30 - 15:30 1.00 WELCT SURFAC 15:30 - 18:15 2.75 WELCT SURFAC 18:15·23:00 4.75 WELCT SURFAC 23:00 - 23:30 0.50 DRILL OTHR SURFAC 23:30 - 00:00 0.50 DRILL PULD SURFAC 11/1/2004 00:00 - 00:30 0.50 DRILL RIRD SURFAC 00:30 . 04:00 3.50 DRILL PULD SURFAC 04:00 - 07:15 3.25 DRILL PULD SURFAC 07:15 - 07:45 0.50 DRILL RIRD SURFAC 07:45 . 11 :00 3.25 DRILL PULD SURFAC 11 :00 - 11 :30 0.50 DRILL TRIP SURFAC 11 :30 - 12:00 0.50 DRILL SFTY SURFAC 12:00 - 12:15 0.25 RIGMNT RGRP SURFAC 12:15 - 13:15 1.00 DRILL TRIP SURFAC 13:15 - 14:00 0.75 DRILL DEQT SURFAC 14:00 - 15:00 1.00 DRILL TRIP SURFAC 15:00 - 16:00 1.00 DRILL TRIP SURFAC 16:00 - 16:30 0.50 DRILL CIRC SURFAC 16:30 - 17:30 1.00 CASE DEQT SURFAC 17:30 - 20:45 3.25 CEMEN DSHO SURFAC Dowell pumped 20 bbls FW and tumed over to rig and rig displaced cmt with 398 bbls of 9.4 ppg mud, ave 7 bpm, initial pressure 550 psi, max pressure 800 psi, slowed to 4 bpm and bumped plugs on calc displacement to 1,400 psi, ck floats and floats held, CIP at 01 :15, Had 178 bbls of 10.7 ppglead cmt back to surface NOTE: Had 1 Hr time change Flushed CMT out of diverter system and flowline ND diverter line and lifted up riser, diverter and starting head, set 10 3/4' emergency slips with 50K Ibs string WI, made rough cut on 103/4" csg and set diverter back down RD cement head, LD landing it with hanger and cut-off piece of 10 3/4' csg ND diverter and starting head, used crane to set out dverter system over flow line of well 1 E-28. DSO had well shut in during operation. Made final cut on 103/4' csg and GBR welder welded on Vetco/Gray csg head adapter per Vetco/Gray procedure. VetcoGray rep present for complete operation. Changed out saver sub, bell guide and grabber on top drive to 4" Serviced top drive and drawworks while allowing well head to cool down, tested weld on adapter head to 2,000 psi for 10 min and ck ok Oriented and NU Vetco/Gray 13 5/8' 5M# MB 222 wellhead, tested btm wellhead sub to 5,000 psi for 10 min and ck ok NU BOP stack RU and tested BOPE, choke manifold, 4' and 5" floor valves, rams including 7 5/8" csg rams to 250 psi low and 3,500 psi high, annular to 250 psi low and 2,800 psi high, John Crisp with AOGCC waived witnessing of test Installed wear bushing RIH with 4 stds of 5' DP from derrick and POOH LD same Changed out 5' handling tools over to 4" DP PU and RIH with 72 its (24 stds) of 4' XT·39 DP, POOH and stood back PU and RIH with 63 its (21 stds) of 4' XT-39 DP, POOH and stood back Changed out 4' handling tools over to 5', cleaned rig floor MU 97/8" BHA #3 with Autotrak tool, MPS, stop sub and float sub, uploaded Autotrak, PU 3-NM flex Dc's & RIH with HWDP and jars, MU ghost reamer RIH with BHA #3 from 1,077' to 2,007' with 5' DP Held tripping drill with rig crew and post drill discussion Worked on Iron roughneck, top door latch wouldn't close, hydraulic ram broke POOH from 2,007' to BHA at 1,077' checking connections to ghost reamer due to iron roughneck hydraulic ram breaking and ck ok RIH to 1,160' and shallow tested Autotrak tool, staged pump rate up to 550 gpm, had MWD pulse but no confirmation RI H from 1,160' to 2,007' RIH from 2,007' to 4,324' Circ hole evening MW in & out at 9.3 ppg for csg test, circ at 595 gpm, 2,400 psi, rot WI 90K, up WI 142K, dn WI 62K, 12K ft-Ibs torque at 60 rpm's RU and tested 103/4" csg to 3,000 psi for 30 min, good test RIH and tagged plugs above float collar, drilled out plugs, float collar at 4,330', shoe track, float shoe at 4,414' and cleaned out to btm at 4,425', drilled 20' of new formation to 4,445' MD/2,488' TVD, 5-30K wob, 60-90 Printed: 12/1012004 2:59:08 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1E-168 1E-168 ROT - DRILLING n1334@ppco.com Doyon 141 Start: Rig Release: Rig Number: 10/27/2004 11/26/2004 Spud Date: 10/28/2004 End: 11/26/2004 Group: 1111/2004 17:30·20:45 3.25 CEMEN DSHO SURFAC rpms, 595 gpm at 2,300 psi, ADT .2 hrs 20:45 ·21 :45 1.00 DRILL CIRC SURFAC Displaced out 9.3 ppg spud mud in hole with reconditioned 9.0 ppg LSND 21 :45 . 23:00 1.25 DRILL LOT SURFAC RU & performed LOT to 10.7 ppg EMW at 2,447' TVD with 9.3 ppg MW and 220 psi, downlinked Autotrak and discussed LOT with town and decision was made to drill ahead 23:00 - 00:00 1.00 DRILL DRLG INTRM1 Drilled 9 7/8" hole from 4,445' to 4,511' MD/2,512' TVD (66') ADT .4 hrs, 5-15K wob, 80 rpm's, 551 gpm, 1,900 psi, off btm torque 14K ft-Ibs, on btm 14K ft-Ibs, rot wt 94K, up wt 160K, dn wt 57K, while drilling out of shoe GRlResistivity tool failed on Autotrak tool. 11/212004 00:00 - 01 :00 1.00 DRILL CIRC INTRM1 Circ btms up while POOH from 4,511' to 4,414' to csg shoe, circ at 550 gpm, 1,900 psi and 40 rpm's 01:00·01:15 0.25 DRILL OBSV INTRM1 Monitored well at shoe-static, pumped dry job 01:15 - 02:00 0.75 DRILL TRIP INTRM1 POOH from 4,414' to 3,861', decision was made to RIH and drill ahead thru curve section with Autotrak tool then POOH and PU mud motor and MWD, back-up RNT/DIR tool had dead battery and would not be able to use with Autotrak tool and also would allow time to put tools in pipe shed to warm up 02:00 - 03:00 1.00 DRILL TRIP INTRM1 RIH from 3861' to 4,421', washed 90' to btm at 4,511' and downlinked Autotrak to ribs on 03:00 - 12:00 9.00 DRILL DRLG INTRM1 Drilled 9 7/8" hole per directional plan from 4,511' to 5,542' MD/2,970' TVD (1,031') ADT 5.3 hrs, 5-15K wOb, 120 rpm's, 138 spm, 585 gpm, off btm pressure 2,550 psi, on btm 2,600 psi, off btm torque 6K ft-Ibs, on btm 7K ft-Ibs, rot wt 99K, up wt 120K, dn wt 82K, with 9.0 ppg mud, clean hole ECD was 9.6 ppg, while drlg with 9.1 ppg mud, ECD ave 10.3 ppg, added 2"10 lubricants to mud, rig and camp off highline at 08:30 hrs 12:00 - 23:00 11.00 DRILL DRLG INTRM1 Drilled 9 7/8" hole from 5,542' to 6,941' MD/3,445' TVD (1,399') ADT 6.4 hrs, 5-20K wob, 120 rpm's, 585 gpm, off btm pressure 3,075 psi, on btm 3,125 psi, off btm torque 6K ft-Ibs, on btm 8K ft-Ibs, rot wt 100K, up wt 128K, dn wt 84K, 9.2 ppg mud, ECD ave 11.0 ppg with no mud loss, preparing to POOH to LD Autotrak tool, rig and camp back on highline at 13:45 hrs 23:00 . 23:30 0.50 DRILL CIRC INTRM1 Circ for survey and clear BHA, downlinked Autotrak tool to backreaming mode (steering mode w/-O- force), monitored well-static 23:30 - 00:00 0.50 DRILL REAM INTRM1 Began backreaming out of hole from 6,941' to 6,564', backreaming out at 120 rpm's, 585 gpm at 3,100 psi with no problems 11/3/2004 00:00 - 03:45 3.75 DRILL REAM INTRM1 Backreamed out of hole from 6,564' to 5,448', backreamed at 120 rpm's, 585 gpm, 3,000 psi, pumped out of hole from 5,448' to 4,327' to inside 103/4' esg, pumped out at 585 gpm, 2,500 psi 03:45·04:15 0.50 DRILL CIRC INTRM1 Circ hole clean at 4,327', circ at 585 gpm, 2,400 psi 04:15·04:30 0.25 DRILL OBSV INTRM1 Monitored well-static, pumped dry job 04:30 - 05:45 1.25 DRILL TRIP INTRM1 POOH from 4,327' to BHA #3 at 1,077' 05:45 - 06:15 0.50 RIGMNT RGRP INTRM1 Repaired hydraulic leak on iron roughneck 06:15·08:30 2.25 DRILL PULD INTRM1 Stood back HWDP, jars and NM flex DC's, download MWD/Autotrak and LD same 08:30 - 11 :15 2.75 DRILL PULD INTRM1 MU 9 7/8" BHA #4, 6 3/4" mud motor with 1.1 deg bend, MAP/MPR and MWD, oriented and uploaded MWD, RIH with NM flex DC's, HWDP, jars and ghost reamer to 1,113' 11:15-12:00 0.75 DRILL TRIP INTRM1 RIH from 1,113' to 2,041' 12:00 - 12:15 0.25 DRILL DEQT INTRM1 Shallow tested MWD at 2,041', circ at 490 gpm at 2,100 psi and tool ck ok 12:15 - 13:15 1.00 DRILL TRIP INTRM1 RIH from 2,041' to 4,360', st wt up 115K, dn wt 76K Printed: 12/10/2004 2:59:08 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 E-168 1 E-168 ROT - DRILLING n1334@ppco.com Doyon 141 Start: 10/27/2004 Rig Release: 11/26/2004 Rig Number: Spud Date: 10/28/2004 End: 11/26/2004 Group: 1113/2004 13:15 - 14:15 1.00 RIGMNT RSRV INTRM1 Slip and cut 65' of drlg line and serviced top drive 14:15 - 15:45 1.50 DRILL TRIP INTRM1 RIH from 4,360' to 6,885', washed down 56' to btm at 6,941' with no problems 15:45 - 17:30 1.75 DRILL DRLG INTRM1 Drilled 9 7/8" hole per directional plan from 6,941' to 7,149' MD/3,490' TVD (208') ADT 1.1 hrs, 5-10K wob, 120 rpm's, 138 spm, 585 gpm, off btm pressure 3,150 psi, on btm 3,250 psi, off btm torque 9K ft-Ibs, on btm 9K ft-Ibs, rot WI 101K, up WI 135K, dn WI 78K 17:30 - 18:30 1.00 RIGMNT RGRP INTRM1 Changed out swivel packing on top drive 18:30 - 00:00 5.50 DRILL DRLG INTRM1 Drilled 97/8" hole per directional plan from 7,149' to 7,630' MD/3,595' TVD (481') ADT 3.3 hrs, 5-20K wob, 90-120 rpm's, 138 spm, 585 gpm, off btm pressure 3,250 psi, on btm 3,300 psi, off btm torque 12K ft-Ibs, on btm 11 K ft-Ibs, rot WI 100K, up WI 137K, dn WI 75K, 9.3 ppg MW, ave ECD 10.2 ppg, ave BGG 175 units, max gas 350 units Est top of West Sak "D" at 7,029' MD/3,463' TVD, Est top of "B" sand at 7,353' MD/3,535' TVD 11/4/2004 00:00 - 06:00 6.00 DRILL DRLG INTRM1 Drilled 9 7/8" hole per directional plan from 7,630' to 8,158' MD/3,715' TVD (528') ART 1.4 hrs, AST 2.1 hrs, 5-15K wob, 90 rpm's, 138 spm, 585 gpm, off btm pressure 3,300 psi, on btm 3,400 psi, off btm torque 10K ft-Ibs, on btm 9K ft-Ibs, rot WI 100K, up wt 135K, dn wt 80K, 9.3 ppg MW, ave ECD 10.2 ppg, ave BGG 175 units, max gas 350 units 06:00 - 06:15 0.25 DRILL OBSV INTRM1 Monitored well-static 06:15 - 08:00 1.75 DRILL REAM INTRM1 Backreamed out from 8,158' to 7,072', backreamed out at 120 rpm's, 585 gpm, 3,300 psi with no problems 08:00 - 10:30 2.50 LOG DLOG INTRM1 Backreamed out and logged up from 7,072' to 6,250' to above K-13 top, logged at 5-10'/min, 120 rpm's, 585 gpm 3,300 psi 10:30 - 13:15 2.75 DRILL REAM INTRM1 Cont to backream out of hole from 6,250' to 5,577', till ghost reamer was at csg shoe then pumped out of hole from 5,577' to 4,360', 120 rpm's, 585 gpm, 2,750 psi, st WI up 128K, dn WI 77K 13:15 - 14:15 1.00 DRILL CIRC INTRM1 Circ hole clean at 4,360', circ at 585 gpm, 2,400 psi, 80 rpm's and 7K ft-Ibs torque, circ 2X btms and was clean at shakers 14:15 - 15:00 0.75 DRILL CIRC INTRM1 POOH 1 std to 4,267' and hole taking proper fill, pumped 40 bbl EMI 920 lubricant pill and spotted in hole to 500' 15:00 - 18:00 3.00 DRILL PULD INTRM1 Dropped 5" DP wiper dart and POOH LD 102 jts of 5" DP 18:00 - 20:30 2.50 DRILL PULD INTRM1 POOH LD 5" HWDP, jars and ghost reamer, downloaded MWD and LD BHA #4, cleared rig floor and pulled wear bushing 20:30 - 21 :30 1.00 CASE RURD INTRM1 RU Doyons 7 5/8" csg equipment with Franks fill up tool 21 :30 - 22:00 0.50 CASE SFTY INTRM1 Held PJSM with rig crew and tong operator on running of 7 5/8" csg 22:00 - 00:00 2.00 CASE RUNC INTRM1 RIH with 75/8", 29.7#, L-80, BTC-M csg to 1,140', MU 7 5/8" Float shoe, 3 jts csg and float collar, thread locked btm 4 conn's and circ thru float equip and ck ok, RIH with 22 add. its along with pup jts for spacing outto 1,140' 11/5/2004 00:00 - 01:15 1.25 CASE RUNC INTRM1 RIH with 7 5/8" csg from 1,140' to 2,002' 01:15-01:45 0.50 CASE CIRC INTRM1 Circ a csg capacity at 2,002', circ at 3 bpm at 300 psi 01 :45 - 04:15 2.50 CASE RUNC INTRM1 RIH with 7 5/8" csg from 2,002' to 4,380' to above 103/4" csg shoe 04:15 - 05:30 1.25 CASE CIRC INTRM1 LD Franks fill up tool, MU circ swedge and circ a csg capacity at shoe, staged pump rate up to 5 bpm at 350 psi, st wt up 11 OK, dn WI 7SK, changed out rubber cup on fill up tool and made tool back up 05:30 - 10:15 4.75 CASE RUNC INTRM1 Fin RIH with 75/8" csg, RIH to btm at 8,158' with no problems. Landed 75/8" csg at 8,157' MD/3,715' TVD with float collar at 8,026', ran a total of 189 jts 75/8",29.7#, L-80 BTC-M csg with 5-pup jts (Total 8,165.95'), ran 58 tandem rise cent on 58 stop rings per well plan, 3/2 jts (every 30'), did not use hanger, will use emergency slips 10:15 - 11 :15 1.00 CEMEN CIRC INTRM1 Circ btms up thru Franks fill up tool while conditioning mud, staged Printed: 12/10/2004 2:59:08 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 E-168 1 E-168 ROT - DRILLING n1334@ppco.com Doyon 141 Start: Rig Release: Rig Number: 10/27/2004 11/26/2004 Spud Date: 10/28/2004 End: 11/26/2004 Group: 11/512004 10:15-11:15 1.00 CEMEN CIRC INTRM1 pump rate up to 6 bpm, 525 psi, st up wt 190K, dn wt 80K 11 :15 - 11 :45 0.50 CEMEN RURD INTRM1 LD Franks fill up tool and MU Dowells cement head 11 :45 - 13:30 1.75 CEMEN CIRC INTRM1 Cont to circ and cond mud for cementing, circ at 6 bpm at 425 psi, st wt up 200K, dn 85K, initial MW out, 9.6 ppg, 78 vis, PV 32, YP 40, Conditioned mud to final MW out of 9.2 ppg, 41 vis, 11 YP and 14 PV, Held PJSM with Dowell, APe vac truck drivers and rig crew on cementing csg while circ. 13:30 - 15:00 1.50 CEMEN PUMP INTRM1 Dowell pumped 10 bbls CW 100 at 8.3 ppg, Pressure tested lines to 3,500 psi, Then pumped 40 add. bbls of CW 100, Pumped 50 bbls of MudPush at 10.5 ppg, Dropped btm plug then pumped 168.2 bbls, (422 sxs) of DeepCrete cmt at 12.5 ppg, 2.26 yield with additives, ave 6.5 bpm at 250 psi, Reciprocated pipe with full returns, shut down, Washed up and dropped btm plug. 15:00 - 16:15 1.25 CEMEN DISP INTRM1 Rig displaced cement with 9.3 ppg OBM, Bumped plug on calc displacement after pumping 368.3 bbls OBM (96% pump eff.) ave 7.0 bpm while displacing cmt, Max pressure 1100 psi, Slowed pump rate to 3 bpm with 3 bbls left to pump and bumped plug to 1,600 psi, ck floats and held CIP at 16:10 hrs, Reciprocated pipe until 73.0 bbls cmt was around shoe when hole began getting tight and stopped reciprocating wI Shoe @ 8,157', Float Collar @ 8.026', Calc TOC @ 4,786', Had full returns thru out job. 16:15 - 17:00 0.75 CASE DEQT INTRM1 Tested 7 5/8" csg to 3,000 psi for 30 min, good test 17:00 - 17:30 0.50 CEMEN RURD INTRM1 RD cement head and used rig vacuum to drain landing jt 17:30 - 18:15 0.75 CASE NUND INTRM1 ND & PU on BOP stack 18:15 - 20:30 2.25 CASE OTHR INTRM1 Set 7 5/8" csg slips with 135K block wt, 100K st wt, made rough cut using cold cut saw and LD cut piece, made final cut and installed pack-off, Tested same to 3800 psi f/10 min. 20:30-21:15 0.75 CASE NUND INTRM1 NU BOP stack and choke line 21:15-22:45 1.50 CASE RURD INTRM1 RD Doyons 7 5/8" csg equipment, changed out elevator bales and installed wear bushing NOTE: at 21 :30 Pumped 30 bbls fresh water down 7 5/8" x 10 3/4" annulus, ave 1 bpm at 720 psi 22:45 - 23:00 0.25 WELCT BOPE INTRM1 Tested choke line at 250 psi and 3,500 psi, due to breaking flange on stack to set slips 23:00 - 00:00 1.00 DRILL OTHR INTRM1 Loaded pipe shed with 4" XT-39 DP and strapped 11/6/2004 00:00 - 02:00 2.00 DRILL OTHR INTRM1 Con!. to load 4" DP into pipe shed and strap, Pumped 10 bbls add. water down 7 5/8" x 10 3/4" annulus at 1 bpm, 680 psi 02:00 - 08:00 6.00 DRILL PULD INTRM1 PU and stood back 4 stds 4 3/4" DC's, 9 stds hybrid push pipe (2-dc's, 1 hwdp), 11 stds of 4" HWDP NOTE: Finished flushing 7 5/8" x 103/4" annulus with 135 bbls water (175 total) after CIP 12 1/2 hrs and surface cement was hard, initial rate 1 bpm at 720 psi, final rate 2 bpm at 700 psi 08:00 - 10:30 2.50 DRILL PULD INTRM1 MU 63/4" BHA #5 with 4 3/4" MM with 1.2 deg bend and MWD, oriented and uploaded MWD, MU 3-NM flex DC's and std of HWDP with jars RIH to 251'. NOTE: Little Red freeze protected 7 5/8" x 10 3/4" annulus with 90 bbls diesel 10:30 - 14:45 4.25 DRILL TRIP INTRM1 RIH with BHA #5 from 251' to 4,835', PU singles of 4" XT-39 DP from pipe shed, shallow tested MWD at 1,185' 14:45 - 15:15 0.50 RIGMNT RSRV INTRM1 Serviced top drive and inspected saver sub 15:15·17:30 2.25 DRILL TRIP INTRM1 Cont RIH with BHA #5 from 4,835' PU DP from pipe shed, tagged plugs above float collar at 8,026' 17:30·18:00 0.50 CEMEN DSHO INTRM1 Drilled out float collar at 8,026', shoe track, float shoe at 8,157' and 20' Printed: 12/1012004 2:59:08 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1E-168 1E-168 ROT - DRILLING n1334@ppco.com Doyon 141 Start: Rig Release: Rig Number: 10/27/2004 11/26/2004 Spud Date: 10/28/2004 End: 11/26/2004 Group: 11/6/2004 17:30 - 18:00 0.50 CEMEN DSHO INTRM1 of new formation to 8,178' MD/3,716' TVD, ADT.1 hrs, 5-15K wob, 70 rpm's, 255 gpm, 2,200 psi, rot wt 84K, up wt 119K, dn wt 65K 18:00 - 19:30 1.50 DRILL CIRC INTRM1 PU till bit was up into csg and circ hole clean evening MW in and out at 9.1 ppg, circ at 297 9pm, 2,350 psi, circ 2X btms up 19:30 - 20:15 0.75 DRILL LOT INTRM1 RU and performed LOTto 14.8 ppg EMW, 1,110 psi at 3,715' TVD and 9.1 ppg OBM 20:15 - 00:00 3.75 DRILL DRLG PROD Drilled 6 3/4" hole in "A" sand lateral from 8,178' to 8,500' MD/3,722' TVD, (322') ART 1.5 hrs, AST .4 hrs, 2-5K wob, 120 rpm's, 73 spm, 310 gpm, off btm pressure 2,450 psi, on btm 2,500 psi, off btm torque 7K ft-Ibs, on btm 6K ft-Ibs, rot wt 85K, up wt 137K, dn wt 53K, clean hole ECD with 9.1 ppg OBM was 10.5 ppg, drlg with 9.1 ppg OBM, ave ECD 10.8 ppg, Est top of West Sak "A" 8,357' MD/3,719' TVD 11/7/2004 00:00 - 12:00 12.00 DRILL DRLG PROD DirectionaUy drilled 6 3/4" hole in "A' sand lateral from 8,500' to 9,778' MD/3, 711' TVD (1,278') ART 5.1 hrs, AST 1.7 hrs, 2-5K wob, 120 rpm's, 73 spm, 310 gpm, off btm pressure 2,550 psi, on btm 2,650 psi, off btm torque 8K ft-Ibs, on btm 7K ft-fbs, rot wt 85K, up wt 140K, dn wt 51 K, 9.0+ ppg OBM, ave ECD 10.9 ppg, ave BGG 250 units, max gas 650 Units from 8,500' 12:00 - 00:00 12.00 DRILL DRLG PROD Directionally drilled 6 3/4" hole in 'A' sand lateral from 9,778' to 11,136' MDI 3,739' TVD (1,358') ART 6.1 hrs, AST 1.1 hrs, 2-15K wob, 120 rpm's, 75 spm, 318 gpm, off btm pressure 2,900 psi, on btm 3,050 psi, off btm torque 9K ft-Ibs, on btm 7K ft-Ibs, rot wt 84K, up wt 160K, dn wt 35K (blk wt, -0- dn wt), pumped weighted hi vis sweep at 10,900' and had 10% increase in cuttings back, 9.1 ppg OBM, ave ECD 11.4 ppg, max ECD 11.8 during sweep ave BGG 175 units, max gas 350 units, on last stand unable to slide due to -0- dn wt, preparing to backream out of hole 15 stds, and RIH with 5 stds HWDP 11/8/2004 00:00 - 03:00 3.00 DRILL WIPR PROD Backreamed out of hole 15 stds to wipe hole from 11,136' to 9,781', backreamed at 120 rpm's 318 gpm 2,700 psi, pulled 1st 13 stds to get a btms up, pulled last 2 stds slow to get add. btms up and clean at shakers 03:00 - 03: 15 0.25 RIGMNT RGRP PROD Changed out hi-low drum clutch control valve on drillers console 03:15 - 04:00 0.75 DRILL TRIP PROD RIH with 10 stds 4' DP then RIH with 5 stds HWDP to 11,078' and washed 58' to btm, no problems, st up wt 150K, dn wt 57K 04:00 - 12:15 8.25 DRILL DRLG PROD Directionally drilled 6 3/4" hole in "A' sand lateral from 11,136' to 11,927' (791 '), ART 2.9 hrs, AST 1.4 hrs, 2-7K wob, 120 rpm's, 318 9pm, off btm pressure 3,150 psi, on btm 3,500 psi, off btm torque 8.5K ft-Ibs, on btm 7.5K ft-Ibs, rot wt 92K, up wt 160K, dn wt 49K, 9.0+ OBM, ave ECD 11.3 ppg, ave BGG 150 units, max gas 300 units, attempted to slide and was unable to get wt to bit 12:15 -12:45 0.50 DRILL TRIP PROD Pumped out of hole 3 stds of 4' DP from 11,927' to 11,700', RIH with 3 stds hybrid push pipe 12:45 - 14:15 1.50 DRILL DRLG PROD Directionally drilled 6 3/4" hole in 'A" sand lateral from 11,927' to 12,073' MD/3,723' TVD (146'), ART .4 hrs, AST .4 hrs, 2-7K wob, 120 rpm's, 318 gpm, off btm pressure 3,300 psi, on btm 3,500 psi, off btm torque 9K ft-Ibs, on btm 7.5K ft-Ibs, rot wt 100K, up wt 177K, dn wt 40K, 9.1 + OBM, ave ECD 11.5 ppg, ave BGG 75 units, max 150 units 14:15 - 14:45 0.50 DRILL CIRC PROD Circ hole and evaluate logs for geology, decision made to backream out of hole to shoe to wipe hole and PU Lo-Tads for add. st wt and appears we drilled out of formation and will do a open hole sidetrack at +1- 11,725' 14:45 - 20:30 5.75 DRILL WIPR PROD Backreamed out of hole from 12,073' to 8,100' to inside 7 5/8' csg, backreamed out at 120 rpm's, 318 gpm, 3,050 psi, no problems Printed: 12/10/2004 2:59:08 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 E-168 1 E-168 ROT - DRILLING n1334@ppco.com Doyon 141 Start: Rig Release: Rig Number: 10/27/2004 11/26/2004 Spud Date: 10/28/2004 End: 11/26/2004 Group: 11/812004 20:30 - 21 :45 1.25 DRILL CIRC PROD Pumped weighted hi vis sweep and circ hole clean at S, 100', had no increase in cuttings back from sweep and circ an add btms up and clean at shakers, circ at 318 gpm, 2,450 psi, 80 rpm's and 6K ft-Ibs torque 21 :45 - 23:00 1.25 DRILL TRIP PROD Monitored well-static, POOH wet from 8,100' to 6,698' to PU Lo-Tads, cleaned rig floor 23:00 . 00:00 1.00 RIGMNT RSRV PROD Slip and cut 74' of drlgline 11/9/2004 00:00 - 00:30 0.50 RIGMNT RSRV PROD Service top drive and drawworks 00:30 - 05:30 5.00 DRILL TRIP PROD RIH from 6,698' to 11,725' installing Lo-Tads on 4' DP and HWDP (PU 61 Lo-Tads) 06:00 - 08:15 2.25 DRILL DRLG PROD Oriented to low side, time drilled and open hole sidetrack 6 3/4' hole from 11,725' to 11,765' and drilled to 11,809', AST 1.4 hrs, 2-5K wob, 318 gpm, 3,250 psi 08:15 - 09:15 1.00 DRILL CIRC PROD Setting up MWD database for sidetrack 09:15 - 12:15 3.00 DRILL DRLG PROD Con!. to sidetrack well, drilling 6 3/4' hole from 11,809' to 12,073' MD/3,753' TVD (At orig. hole depth) ART 1.1 hrs, AST .7 hrs, 2-5 k wob, 120 rpm's 75 spm, 318 gpm, off btm pressure 3,100 psi, on btm 3,250 psi, off btm torque 7.5K ft-Ibs, on btm 7.5K ft-Ibs, rot wt 89K, up wt 145K, dn wt 55K, 9.0 ppg OBM, ave ECD 11.35 ppg, ave BGG 75 units, max gas 200 units 12:15 - 00:00 11.75 DRILL DRLG PROD Directionally drilled 6 3/4' hole in "A' sand lateral from 12,073' to 13,106' MD/3,767' TVD (1,033'), ART 4.6 hrs, AST 1.6 hrs, 2-8K wob, 120 rpm's, 318 gpm, off btm pressure 3,600 psi, on btm 3,800 psi, off btm torque 8.5K ft-Ibs, on btm 8K ft-Ibs, rot wt 105K, up wt 183K, dn wt 40K, 9.1 OBM, ave ECD 11.55 ppg, ave BGG 150 units, max gas 325 units, 11/10/2004 00:00 - 03:45 3.75 DRILL DRLG PROD Directionally drilled 6 3/4" hole in "A' sand lateral from 13,106' to 13,477 MD/3,763' TVD (371'), (T.D.) ART 2.5 hrs, AST .1 hrs,5-11K wob, 120 rpm's, 318 gpm, off btm pressure 3,850 psi, on btm 4,050 psi, off btm torque 9K ft-Ibs, on btm SK ft-Ibs, rot wt 107K, up wt 174K, dn wt 50K, 9.0+ OBM, ave ECD 11.6 ppg, ave BGG 200 units, max gas 375 units, pumped weighted hi vis sweep on last std 03:45 - 04:00 0.25 DRILL CIRC PROD Fin circ out weighted hi vis sweep and to clear BHA, had no increase in cuttings from sweep, circ at 318 gpm, 4,000 psi and 120 rpm's 04:00 - 04:15 0.25 DRILL OBSV PROD Monitored well-static 04:15 - 11 :15 7.00 DRILL REAM PROD Backreamed out of hole from 13,477' to 8,145' (75/8' csg shoe), backreamed out at 120 rpm's, 318 gpm, 3,SOO psi with no problems 11 :15 - 12:45 1.50 DRILL CIRC PROD Pumped weighted hi vis sweep and circ hole clean, had no increase in cuttings back from sweep and circ an add btms up and was clean at shakers, circ at 318 gpm, 2,450 psi, 80 rpm's with 6K ft-Ibs torque, rot wt 89K, up wt 113K, dn wt 75K 12:45 - 16:00 3.25 DRILL TRIP PROD RIH from 8,145' to 13,379', washed 98' to btm at 13,477', while RIH set down at 11,735', rotated string 180 deg and went thru spot, no other problems RIH 16:00 - 18:30 2.50 DRILL CIRC PROD Circ btms up at 13,477' then displaced out 9.1 ppg MOBM with 9.1 ppg SFMOBM, circ at 300 gpm, 3,600 psi, 120 rpm's and 10K ft-Ibs torque, rot wt 107K, up wt 164K, dn wt 69K 18:30 - 18:45 0.25 DRILL OBSV PROD Monitored well-static 18:45 - 00:00 5.25 DRILL TRIP PROD Dropped 1 3/4" rabbit and began POOH on elevators from 13,477' to 6,511' with no problems, monitored well at shoe-static, removed 11 Lo-tads from HWDP to be installed on 11 stds of 4" XT -39 DP 11/11/2004 00:00 - 04:00 4.00 DRILL TRIP PROD POOH wet on elevators from 6,511' to BHA #5 at 67', stood back NM flex DC's and installed 11 Lo-Tads on DP on trip out Printed: 12/10/2004 2:59:08 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 E-168 1 E-168 ROT - DRILLING n1334@ppco.com Doyon 141 Start: Rig Release: Rig Number: 10/27/2004 11/26/2004 Spud Date: 10/28/2004 End: 11/26/2004 Group: 11/11/2004 04:00 - 05:45 1.75 DRILL PULD PROD Downloaded MWD and LD MWD and MM, cleaned rig floor, calc fill on trip out of hole 91 bbls, actual fill 121 bbls with 9.1 ppg SFMOBM in hole 05:45 - 06:15 0.50 CASE RURD CMPL TN RU Doyon's 4 1/2" liner running equipment 06:15 - 06:30 0.25 CASE SFTY CMPL TN Held PJSM on running of liner 06:30 . 12:00 5.50 CASE PULR CMPL TN PU and ran 41/2" liner per well program to 5,980', ran 4 1/2" ROT silver bullet guide shoe with no float, 192 jts, (5,943.11 ') of 4 1/2" 12.6#, L-80, DWC liner, placed blank liners across shale sections per geology, ran 89 jts (2,751.19') of blank liner and 103 jts (3,191.92') of slotted liner, ran 64- 41/2" x 61/4" spiralglide centralizers 1/jt jt #1 to Jt #54 and on jts with restrictor packers, then ran 108, 4 1/2" x 53/4" straight blade centralizers 1/Jt on jts #55 thru #172 (csg shoe) ran 17 restrictor packers placed on blank liner to isolate shale sections per geology. 12;00 - 12:45 0.75 CASE PULR CMPL TN MU Baker 190-47 seal bore eX!, 5 1/2" x 7 5/8" Flexlock liner hanger with, "RS" pack-off seal nipple and "HRD" ZXP liner top packer and RIH to 6,047' 12;45 - 14:00 1.25 CASE RUNL CMPL TN RIH with liner on 4" DP to 8,073' (csg shoe) est circ at 2.5 bpm, 200 psi, then rotated liner at 20 rpm's with 4K ft-Ibs torque, rot wt 80K, up wt 98K, dn wt 65K 14:00 - 18:00 4.00 CASE RUNL CMPL TN Cont to run 41/2" liner in open hole, RIH from 8,073' and tagged btm at 13,477' with no problems, PU to 13,473', st wt up 172K, dn wt 67K Note: RIH with 4" DP with Lo-Tads, HWDP, 4 stds 4 3/4" DC's and Push Pipe to run and set 4 1/2" liner 18:00 - 18:45 0.75 CASE OTHR CMPL TN Dropped 1 3/4" ball and pumped down to seat, pumped at 2 bpm at 400 psi, with ball on seat pressured up to 2,000 psi to set Flexlock hanger, slacked off 30K, cont to set packer, pressured up to 3,900 psi and set ZXP packer, no problems setting hangerlpacker, set "A" sand liner with TOL @ 7,437' MD/3,553' TVD and shoe at 13,473' MD 3,763' TVD, st wt up after setting liner 140K, lost 32K st wt 18:45 - 19:00 0.25 CASE DEQT CMPL TN RU & tested annulus above ZXP packer to 1,000 psi for 5 min and ck ok 19:00 - 20;00 1.00 DRILL CIRC CMPL TN PU out of SSE 45' to 7,392' and circ btms up, circ at 7.5 bpm at 2,550 psi 20:00 - 20: 15 0.25 DRILL OBSV CMPL TN Monitored well-static 20:15 - 00:00 3.75 DRILL TRIP CMPL TN POOH wet from 7,392' and LD Baker setting tool, cleaned rig floor, clac fill on trip out of hole 59 bbls, actual 64.5 bbls 11/12/2004 00:00 - 02;30 2.50 WINDO CMPL TN MU Baker 7 5/8" whipstock assembly BHA #6 and RIH to 560', MU milling assembly and LD same, PU seal assembly, locator sub, 3 1/2" DP pup jt, unloader sub, then PU 1 jt of 3 1/2" DP for space out and RIH with seal assembly, MU whipstock, milling assembly with MWD, oriented and uploaded MWD and RIH with 4 stds 4 3/4" DC's to 560' 02:30 - 07;45 5.25 WINDO CMPL TN RIH with whipstock assembly from 560' to 6,440' 07:45 - 08;15 0.50 WINDO CMPL TN Made MADD pass from 6,440' to 6,466' (6,320' to 6,346' sensor depth) and correlated MWD to K-13 sand 08:15 - 09;15 1.00 WINDO CMPL TN RIH with whipstock from 6,466' to 7,400', st wt up 135K, dn wt 90K 09;15 - 09:45 0.50 WINDO CMPL TN Oriented whipstock to 15 deg left of high side, RIH, tagged TOL at 7,437', set whipstock and sheared off from same, top of whipstock at 7,355' 09:45 - 10;30 0.75 WINDO CMPL TN Displaced out 9.1 ppg solids free MOBM with reconditioned 9.1 ppg MOBM, 10:30 - 15:00 4.50 WINDO CMPL TN Milled window in 7 5/8" csg for "B" Lateral, top of window at 7,355', btm of window at 7,367', drilled 6 3/4" hole to 7,386' MD/3,542' TVD (31'), 2-10K wob, 70-120 rpm's, 295-315 gpm, 2,840 psi, rot wt 103K, up wt Printed: 12/10/2004 2:59:08 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 E-168 1 E-168 ROT - DRILLING n1334@ppco.com Doyon 141 Start: Rig Release: Rig Number: 10/27/2004 11/26/2004 Spud Date: 10/28/2004 End: 11/26/2004 Group: 12:00 - 00:00 132K, dn wt 92K, 5-8K ft-Ibs torque, pumped weighted hi vi sweep Circ out weighted hi vis sweep and circ hole clean, had 5% increase in cuttings from sweep, circ at 340 gpm at 3,200 psi, worked mills thru window with no problem Monitored well-static, pumped dry job POOH from 7,386' to 80', stood back 4 3/4' DC's LD MWD and milling assembly and upper mill was in gauge, cleaned rig floor Pulled wear bushing and flushed out BOP stack RU and began testing BOPE, valves, choke manifold and rams to 250 psi low and 3,500 psi high, tested annular to 250 psi and 2,800 psi, test witnessed by Chuck Scheve W/AOGCC Fin testing BOPE to 250 psi low and 3,500 psi high, test witnessed by Chuck Scheve with AOGCC Installed wear bushing and cleared rig floor MU 6 3/4' BHA #7, 4 3/4" motor with 1.2 deg bend and MWD, oriented and uploaded MWD, RIH to 251' RIH from 251' to 7,338', (above window at 7,355') shallow tested MWD at 1,652' and tool ck ok Slip and cut 72' of drlg line and serviced top drive Changed out XT -39 saver sub on top drive Oriented and RIH thru window and washed 18' to btm at 7,386' with no problems Directionally drilled 63/4' hole in "B" sand lateral from 7,386' to 8,886' MD/3,551' TVD (1,500'), ART 7.1 hrs, AST 1.7 hrs, 2-10K wob, 120 rpm's, 73 spm, 310 gpm, off btm pressure 2,450 psi, on btm 2,500 psi, off btm torque 7K ft-Ibs, on btm 7K ft-Ibs, rot wt 85K, up wt 120K, dn wt 60K, 9.0 ppg MOBM, ave ECD 10.8 ppg, ave BGG 250 units, max gas 475 units 12.00 DRILL DRLG PROD2 Directionally drilled 6 3/4" hole in "BH sand lateral from 8,886' to 10,139' MD/3,553' TVD (1,253'), ART 5.8 hrs, AST 1.2 hrs, 2-14K wOb, 120 rpm's, 73 spm, 310 gpm, off btm pressure 2,700 psi, on btm 2,750 psi, off btm torque 8K ft-Ibs, on btm 7.5K ft-Ibs, rot wt 81K, up wt 125K, dn wt 58K, 9.0+ ppg MOBM, ave ECD 11.0 ppg, ave BGG 275 units, max gas 430 units 12.00 DRILL DRLG PROD2 Directionally drilled 6 3/4" hole in "B" sand lateral from 10,139' to 11,145' MD/3,566' TVD (1,006'), ART 4.7 hrs, AST 2.1 hrs, 2-10K wOb, 120 rpm's, 73 spm, 310 gpm, off btm pressure 2,800 psi, on btm 2,900 psi, off btm torque 8K ft-Ibs, on btm 8K ft-Ibs, rot wt 90K, up wt 150K, dn wt 48K, 9.0+ ppg MOBM, ave ECD 11.2 ppg, ave BGG 200 units, max gas 420 units, Note: Drilled out of "B" sand from approx. 10,675' to 10,835' and drilled thru calcite stringers 8.25 DRILL DRLG PROD2 Directionally drilled 6 3/4' hole in "B" sand lateral from 11,145' to 11,969' MD/3,583' TVD (824') (T.D.), ART 3.9 hrs, AST .7 hrs, 2-14K wob, 120 rpm's, 73 spm, 310 gpm, off btm pressure 3,500 psi, on btm 3,600 psi, off btm torque 9.5K ft-Ibs, on btm 9K ft-Ibs, rot wt 104K, up wt 151 K, dn wt 67K, 9.0 ppg MOBM, ave ECD 11.45 ppg, ave BGG 200 units, max gas 420 units. T.D. well using hybrid wt pipe, NOTE Phase 3 weather condition field wide at 00:30 hrs 1.50 DRILL CIRC PROD2 Pumped weighted hi vis sweep and circ out, had 10% increase in cuttings back from sweep, circ at 310 gpm, 3,500 psi, 120 rpm's 0.25 DRILL OBSV PROD2 Monitored well-static 6.00 DRILL REAM PROD2 Backreamed out of hole from 11,969' to 7,330' ( Above window at 16:00 - 16:15 CMPL TN 16:15 - 19:00 CMPL TN 19:00 - 20:00 CMPL TN 20:00 - 21 :30 CMPL TN 21 :30 - 00:00 CMPL TN 11/13/2004 00:00 - 01 :30 CMPL TN 01 :30 - 02:00 0.50 DRILL OTHR CMPL TN 02:00 - 03:15 1.25 DRILL PULD PROD2 03:15 - 07:30 4.25 DRILL TRIP PROD2 07:30 - 08:30 1.00 RIGMNT RSRV PROD2 08:30 - 09:45 1.25 RIGMNT RSRV PROD2 09:45 - 10:00 0.25 DRILL REAM PROD2 10:00 - 00:00 14.00 DRILL DRLG PROD2 11/14/2004 00:00 - 12:00 11/15/2004 00:00-08:15 08:15 - 09:45 09:45 - 10:00 10:00 - 16:00 Printed: 12/10/2004 2:59:08 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1E-168 1 E-168 ROT - DRILLING n1334@ppco.com Doyon 141 Start: Rig Release: Rig Number: 10/27/2004 11/26/2004 Spud Date: 10/28/2004 End: 11/26/2004 Group: 11/15/2004 10:00 - 16:00 6.00 DRILL REAM PROD2 7,355'), no problems, back reamed out at 120 rpm's, 310 gpm, initial circ pressure 3,300 psi, final pressure 2,200 psi, NOTE: Phase 3 lowered to Phase 2 at 11 :30 hrs 16:00 - 17:30 1.50 DRILL CIRC PROD2 Pumped weighted hi vis sweep and circ out, had no increase in cuttings back from sweep, circ additional btms up and clean at shakers, circ at 310 gpm, 2,200 psi, rot wt 85K, upwt 90K, dn wt 70K 17:30 - 20:30 3.00 DRILL TRIP PROD2 RIH from 7,330' to btm at 11,969' with no problems 20:30 - 00:00 3.50 DRILL CIRC PROD2 Circ hole 2 X btms up then displaced out 9.0 ppg MOBM to 9.1 ppg SFMOBM, circ at 70 spm, 300 gpm, 3,400 psi, 100 rpm's, rot wt 100K, up wt 150K, dn wt 60K, Phase 2 in effect 11/16/2004 00:00 - 08:45 8.75 DRILL TRIP PROD2 Monitor well. Static. POOH on elevators. Monitor well at window. Static. No problems POOH. No tight hole noted. At TD, UP wt 165K, DN wt 65K. 08:45 - 09:45 1.00 DRILL PULD PROD2 UD BHA. Download MWD. Clear rig floor. Hycalog 6-3/4' DSX146 rated O-O-NO-A-X-I-ER- TD. 09:45 - 10:30 0.75 FISH PULD CMPL T2 P/U Baker Whipstock retrieving assembly. BHA # 8: Retrieving hook, 1 jt 3-1/2' HWDP, FS, BS, Oil Jars, 4 stds 4-3/4" DC's, & XO. 10;30 - 12:00 1.50 FISH TRIP CMPL T2 TIH to 2363' MD. 12;00 - 14:00 2.00 FISH TRIP CMPL T2 Continue TIH to 7360' MD. Drill string above BHA: 54 stds 4" OP wI Lo-Tads, 11 stds 4" HWDP, & 7 stds Hybrid Push Pipe. 14:00 - 15:30 1.50 FISH FISH CMPL T2 Latch & retrieve whipstock. Trip anchor sheared at 65K over. 15;30 - 16:30 1.00 FISH CIRC CMPL T2 PU 1 std & CBU @ 75 spm at 2250 psi. - Had a 2 ppg gas cut bubble @ BU - Circu until fluid uniform out and in 9.1 ppg. 16:30 - 21 :30 5.00 FISH TRIP CMPL T2 Observe well. Static. POOH to Whipstock retrieving assembly. 21 :30 - 23:30 2.00 FISH PULD CMPL T2 UD Baker Whipstock retrieving assembly, whipstock, debris barrier sub, US, shear disconnect, btm trip anchor, DP XO, 1 jt 3-1/2' HWDP, US, 3-1/2" pup jt, LS, & seal assembly. 23:30 - 00:00 0.50 FISH OTHR CMPL T2 Clear & wash rig floor. Prep to run 4-1/2" B-Lat Liner. 11/17/2004 00:00 - 00:30 0.50 CASE RURD CMPL T2 RIU equipment to run 4-1/2' liner. 00:30 - 01 :00 0.50 CASE SFTY CMPL T2 Held PJSM on running 4-1/2" liner wi rig crew, casing hand, and company rep. 01 :00 - 04:45 3.75 CASE RUNC CMPL T2 PU & ran 4-1/2' liner per program to 4,542'. Ran 3-1/2' Baker guide shoe, 3-1/2' bent jt, XO, 4-1/2" pup jt, Baker packoff bushing, XO, 145 jts (4,500.46') of 41/2" 12.6#, L-80, DWC liner. Placed blank liner across shale sections per geology, ran 137 jts (4,250.50') of slotted liner and 8 jts (249.96') of blank liner. Ran (141) 41/2" x 61/4" spiralglider centralizers 1/jt jt except on the 2 jts with constrictor packers (#34 & #39). Ran 2 constrictor packers placed on blank liner to isolate shale sections per geology f/1 0,678' MD to 10,833' MD. Up wt 66K, dn wt 54K. 04:45 . 05:00 0.25 CASE RUNC CMPL T2 M/U Baker Model B1 Flanged Hook Hanger & running tool. Up wt 70K, On wt 55K. 05:00 - 05:45 0.75 CASE CIRC CMPL T2 RIH 1 std of DP & break circulation. ROT WT 63K, TQ 2K ft-Ibs torque. 05:45 - 12:30 6.75 CASE RUNL CMPL T2 RIH with liner on 4" DP to csg shoe at 7,355' MD. Up wt 95K, On wt 65K. Cont to run 4 1/2" liner in open hole. RIH from 7,355' to 11,927' seeing 75% of centralizers exiting window fl 8,934' MD to 10,435' MD (set dwn 15K maxi. Hook hanger on window on 2nd attempt. Unhook and rehook to verify. Up wt 160K, dn wt 80K. Orop 1-3/4" ball & pump to seat @ 3 BPM at 425 psi. Pressure up to 3500 psi to release running tool. Liner Running String - 53 stds 4" OP with Lo-Tads, 11 stds 4" HWDP, 4 stds 4-3/4" DC's, & 9 stds Hybrids. Printed: 12/10/2004 2:59;08 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1E-168 1 E-168 ROT - DRILLING n1334@ppco.com Doyon 141 Start: Rig Release: Rig Number: 10/27/2004 11/26/2004 Spud Date: 10/28/2004 End: 11/26/2004 Group: 11/1712004 12:30 - 13:30 1.00 CASE CIRC CMPL T2 PU to verify release of liner & CBU @ 7.5 BPM at 2500 psi. Shut down & Monitor well. Static. 13:30 - 17:00 3.50 DRILL TRIP CMPL T2 POOH f/11,831' MD. 17:00 - 17:30 0.50 CASE RURD CMPL T2 UD liner running tool & clear rig floor. 17:30 - 18:30 1.00 CMPL TN PULD CMPL T2 MIU LEM assembly. 18:30 - 22:30 4.00 CMPL T RUNT CMPL T2 TIH wI LEM assembly tl7480' MD. Up wt 140K, dn wt 95K. Latch LEM & slack-off 60K. PU & pull 10K over to verify latch. 22:30 - 23:00 0.50 CMPL TN CIRC CMPL T2 Drop 1-314" ball & pump to seat at 3 BPM at 375 psi. Pressure up to 4000 psi to release LEM. Pusher tool sheared at 2400 psi, ZXP set at 2800 psi, & pusher tool neutrilized at 3400 psi. Bleed off pressure & PU to verify release of running tool. Top of LEM at 7297' MD. 23:00 - 23:30 0.50 CMPL T DEQT CMPL T2 Close Hydril & pressure test annulus (ZXP) to 1500 psi for 15 min. Held OK. 23:30 - 00:00 0.50 DRILL TRIP CMPL T2 Blow down top drive. Monitor Well. Static. 11/18/2004 00:00 - 03:45 3.75 DRILL TRIP CMPL T2 POOH f/7,297' MD. 03:45·04:15 0.50 DRILL PULD CMPL T2 Make service breaks and UD Baker running tool & hydraluic setting tool. 04:15 - 04:45 0.50 DRILL OTHR CMPL T2 Clear rig floor to run Whipstock. 04:45 - 07:00 2.25 WINDO ULD CMPL T2 MIU Baker 75/8" whipstock assembly. M/U seals & no-go, 3-1/2" pup, US, 7 its 3-1/2" DP, DP XO, btm trip anchor, shear disconnect, US, debris barrier, 7-5/8" whipstock, starting mill, lower mill, flex it, upper mill, 1 it 3-1/2" HWDP, FS, Orient & Upload MWD, jars, 4 stds 4-3/4" DC, XO, & RIH to 742'. 07:00 - 07:45 CMPL T2 RIH with whipstock assembly to 830' & shallow test MWD. OK. 07:45 - 12:00 CMPL T2 Continue to RIH to 6,568' MD. Break circulation @ 7 BPM & 2100 psi. 12:00 - 12:30 CMPL T2 Made MADD pass from 6,619' MD to 6,643' MD and correlated MWD to K-13 shale. Continue to RIH to 7,291' MD. 12:30 - 13:00 CMPL T2 RIH to 7,291' MD. Orient and set Whipstock. Sheared off same. Top of Whipstock at 7,031' MD. 13:00 - 13:45 CMPL T2 Displaced out 9.1 ppg solids free MOBM with reconditioned 9.1 ppg MOBM @ 7 BPM at 2100 psi. 13:45 - 18:00 CMPL T2 Milled window in 7 5/8" csg for "D" Lateral. Top of window at 7,031', btm of window at 7,043'. Drilled 6 3/4" hole to 7,061' MD 13,468' TVD (31'), 2-10K WOB, 70-120 RPM, 295-315 GPM, 2000-2200 psi, 5-8K ft-Ibs torque. 18:00 - 19:00 Pump hi vis sweep and circ hole clean. Circulate @ 7 BPM at 2100 psi. Worked mills thru window with no problem. Monitor Well. Static. 19:00 - 22:00 CMPL T2 POOH f/7,061' MD to BHA at 476' MD. 22:00 - 22:30 CMPL T2 UD Milling Assembly BHA. UD 4 stds 4-3/4' DC, jars, MWD, FS, 1 jt 3-1/2" HWDP, upper mill, flex jt, lower mill, & starting mill. 22:30 - 23:00 0.50 WINDO CMPL T2 Clear rig floor & pull wear ring. 23:00 - 00:00 1.00 WINDO CMPL T2 RIU & flushed BOP stack. 11/19/2004 00:00 - 00:30 0.50 WINDO THR CMPL T2 Install wear bushing & clear rig floor. 00:30 - 02:00 1.50 RIGMNT RSRV CMPL T2 Inspect saver sub, shim grabbers, & service top drive. 02:00 - 02:30 0.50 DRILL PULD PROD3 M/U 6-3/4" D-Lat BHA #10. P/U 6-3/4' bit, 1.2 deg motor, & MWD. 02:30 . 03:00 0.50 DRILL PULD PROD3 Upload MWD & Orient. 03:00 - 07:00 4.00 DRILL TRIP PROD3 RIH tl1, 185' MD & shallow test MWD. Continue to RIH t/6947' MD filling pipe every 10 stds. 07:00 - 08:00 1.00 RIGMNT RSRV PROD3 Slip & cut 70' drilling line. Printed: 12/10/2004 2:59:08 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 E-168 1 E-168 ROT - DRILLING n1334@ppco.com Doyon 141 Start: 10/27/2004 Rig Release: 11/26/2004 Rig Number: Spud Date: 10/28/2004 End: 11/26/2004 Group: 11119/2004 08:00 - 08:30 0.50 DRILL TRIP PROD3 Orient & pass thru window with no problems. Wash & ream f/7046' MD to 7061' MD. 08:30 - 12:00 3.50 DRILL DRLG PROD3 Drill 6-3/4" Lateral 'D' Section f/7,061' to 7,470' MD 13,498' TVD (409'), ART 1.3 hrs, AST 0.8 hrs, UP 125K, DN 55K, Rot 83K, TO onloff 6K/6K, 310 gpm @ 2400 psi, 2-10K WOB, 120 RPM, avg ECD's 10.8 ppg, Max gas 210 units. 12:00 - 16:00 4.00 DRILL DRLG PROD3 Drill 6-3/4" Lateral 'D' Section f/7,470' to 7,913' MD 13,489' TVD (443'), ART 0.6 hrs, AST 2.3 hrs, UP 125K, DN 55K, Rot 83K, TO on/off 6K/6K, 310 gpm @ 2300 psi, 2-10K WOB, 120 RPM, avg ECD's 10.7 ppg, Max gas 290 units. Geologist advised that after crossing fault @ 7475' MD we had not been able to stay in the sand and had come out the top @ 7640'. After conferring with the engineers in town the decision was made to back up and do an OH side track. 16:00 - 16:30 0.50 DRILL DRLG PROD3 Pump out of hole t/7431' MD to sidetrack well. 16:30 - 19:00 2.50 DRILL DRLG PROD3 Perform OH sidetrack 117,431' MD to 7,555' MD, ART 0.6 hrs, AST 2.3 hrs, UP 123K, DN 55K, Rot 82K, TO onloff 5.5K/6K, 310 gpm @ 2450 psi, 0-2K WOB, 120 RPM, avg ECD's 11.6 ppg, Max gas 190 units. 19:00 - 20:00 1.00 DRILL DRLG PROD3 Running shale at 7,555' MD. Circulate hole clean @ 310 gpm at 1475 psi while recip & rot string. Max ECD 11.1 ppg, Max gas 180 units. 20:00 - 00:00 4.00 DRILL DRLG PROD3 Drill 6-3/4" Lateral 'D' Section 117,555' to 7,913' MD 13,508' TVD (358'), ART 1.9 hrs, AST 3.1 hrs, UP 115K, DN 65K, Rot 81 K, TO on/off 6K/6.5K, 310 gpm @ 2300 psi, 2-10K WOB, 120 RPM, avg ECD's 10.9 ppg, Max gas 260 units. 11/2012004 00:00 - 12:00 12.00 DRILL DRLG PROD3 Drill 6-314' Lateral 'D' Section f/7,913' MD to 9,074' MD 13,504' TVD (1161 '), ART 5.8 hrs, AST 1.6 hrs, UP 117K, DN 63K, Rot 82K, TO onloff 7K17.5K, 305 gpm @ 2400 psi, 0-15K WOB, 100-120 RPM, avg ECD's 11.0 ppg, Max gas 405 units. 12:00 - 00:00 12.00 DRILL DRLG PROD3 Drill 6-314' Lateral 'D' Section f/9,074' MD' to 10,663' MD 13,499' TVD (1589'), ART 9.0 hrs, AST 0.0 hrs, UP 125K, DN 55K, Rot 85K, TO on/off 9K/9K, 304 gpm @ 2400 psi, 0-5K WOB, 120 RPM, avg ECD's 11.5 ppg, Max gas 440 units. (NOTE: DWS costs 1rom 11/8 to 11/18 were updated on today's report. ) 11/21/2004 00:00 - 12:00 12.00 DRILL DRLG PROD3 Drill 6-3/4" Lateral 'D' Section f/10,633' MD to 11,683' MD (1,050'), ART 6.7 hrs, AST 1.0 hrs, UP 145K, DN 60K, Rot 97K, TO on/off 10K/9K, 305 gpm @ 3200 psi, 0-15K WOB, 120 RPM, avg ECD's 11.6 ppg, Max gas 430 units. 12:00 - 15:00 3.00 DRILL DRLG PROD3 Drill 6·3/4' Lateral 'D' Section f/11,683' MD to TD at 11,960' MD I 3,515' TVD (277'), ART 1.1 hrs, AST 1.0 hrs, UP 150K, DN 65K, Rot 100K, TO onloff 10K/10K, 305 gpm @ 3300 psi, 2-10K WOB, 120 RPM, avg ECD's 11.8 ppg, Max gas 280 units. Pump weighted Hi-vis sweep on last connection. 15:00 - 16:00 1.00 DRILL CIRC PROD3 Pump sweep & circulate hole clean @ 70 spm at 3500 psi. 16:00 - 22:30 6.50 DRILL REAM PROD3 Back Ream out of hole at drilling rates t/7,140' MD. Pull thru window with no problems. 22:30 - 23:00 0.50 DRILL OBSV PROD3 POOH to 6,947' MD. Monitor Well. Static. 23:00 - 00:00 1.00 DRILL CIRC PROD3 Pump sweep & circulate hole clean @ 72 spm at 2250 psi. 11/22/2004 00:00 - 03:00 3.00 DRILL TRIP PROD3 Observe well. Static. TIH to 11,867' MD (fill DP at 9752'). Wash last std to btm at 11,960' MD. 03:00 - 05:30 2.50 DRILL CIRC PROD3 CBU @ 305 gpm at 3700 psi & 120 RPM. Displace entire mud system to 9.0 ppg Solids-Free OBM @ 305 gpm at 3700 psi. Printed: 12/10/2004 2:59:08 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 E-168 1E-168 ROT - DRILLING n 1334@ppco.com Doyon 141 Start: Rig Release: Rig Number: 10/27/2004 11/26/2004 Spud Date: 10/28/2004 End: 11/26/2004 Group: 11/22/2004 05:30 - 12:00 6.50 DRILL TRIP PROD3 Shut down & monitor well. Static. Blow Down Top Drive. POOH wet on elevators f/11 ,960' MD to 2,493' MD. 12:00 - 13:00 1.00 DRILL TRIP PROD3 Continue POOH fl 2,493' MD to BHA. 13:00 - 15:00 2.00 DRILL PULD PROD3 UD BHA & Download MWD. UD all tools. Rerun Hycalog 6-3/4" DSX146 rated 0-1-CT-G-X-I-NO-TD. 15:00 - 15:30 CMPL T3 Clear floor & P/U Whipstock retrieving assembly. P/U retrieving hook, 1 jt 3-1/2" HWDP, FS, bumber jar, oil jar, 4 stds 4-3/4" DC, & XO. 15:30 - 18:30 CMPL T3 RIH wI Whipstock retrieving assembly. Run 50 stds 4" DP wI Lo-Tads, 11 stds 4" HWDP, & 9 stds Hybrid Push Pipe. 18:30 - 19:00 CMPL T3 Hook whipstock on 2nd attempt & on depth. Sheared bolt at 35K over & Pull 60K over to unseat btm trip anchor. UP 140K, DN 88K. 19:00 - 20:00 1.00 WINDO CMPL T3 CBU @ 40 spm at 900 psi. Monitor well. Static. 20:00 - 00:00 4.00 WINDO CMPL T3 POOH wI D-Lat whipstock to retrieving assebmly at 692'. 11/23/2004 00:00 - 03:00 3.00 WINDO CMPL T3 POOH standing back 4 stds 4 3/4" dc's and LD whipstock anchor assembly, cleaned rig floor 03:00 - 03:30 0.50 CASE RURD CMPL T3 RU Doyon's 4 1/2" liner running equipment 03:30 - 03:45 0.25 CASE SFTY CMPL T3 Held PJSM on running of liner 03:45 - 08:30 4.75 CASE PULR CMPL T3 PU & ran 4-1/2" liner per program to 4,875'. Ran 3-1/2" Baker guide shoe, 3-1/2" bent jt, XO, 4-1/2" pup jt, Baker packoff bushing, XO, 156 jts (4,834.08') of 4 1/2" 12.6#, L-80, DWC liner, ran 154 jts (4,773.06') of slotted liner and 2 jts (61.02') of blank liner. Ran (154) 41/2" x 6 1/2" spiralglider centralizers, 1/jt on slotted liner none on blank liner 08:30 - 09:00 0.50 CASE PULR CMPL T3 MIU Baker Model B1 Flanged Hook Hanger & running tool. RIH 1 std and broke circ, Up wt 69K, Dn wt 58K. 09:00 - 10:15 1.25 CASE RUNL CMPL T3 RIH with 4 1/2'Iiner on 4" DP from 4,919' to 7,326' and tagged up on no go on "B" lat 10:15 - 11 :00 0.75 CASE OTHR CMPL T3 PU to 7,017' and re-oriented and after 3rd attempt, RIH thru window with bent jt and liner 11 :00 - 14:00 3.00 CASE RUNL CMPL T3 RIH with liner from 7,326' to 11,937' with no problems, st wt up 150K, dn wt 75K 14:00 - 17:00 3.00 CASE RUNL CMPL T3 Hooked hanger on window on 1st attempt at 7,046'. Unhook and rehook to verify setting 35K st wt down. Hooked window 3 times, unhooked and went past window 10' then rehooked 4 more times Up wt 150K, dn wt 75K. Drop 1-3/4" ball and pumped to seat @ 4 BPM at 900 psi, staged pump pressure up 3500,3700,4000, to 4,700 psi working pipe per Baker rep procedure to release running tool with no sign liner was released, rotated liner to safety off & release running tool, appeared running tool was not released, Shut down and conferred with town engineer and team leader. The decision was made to TOH and replace Hook Hanger, After confrence call we PU and running tool had released, st wt after releasing running tool 135K up and 90K dn wt. Liner Running String - 50 stds 4" DP with Lo-Tads, 11 stds 4' HWDP, 4 stds 4-3/4' DC's and 9 stds Hybrids, TOL at 7,029' with shoe at 11,937'. Went back down and tagged liner at setting depth Top. 17:00 - 18:00 1.00 CASE CIRC CMPL T3 POOH 1 std to 6,936' and circ hole clean, circ at 8 bpm at 2,600 psi, st wt up 135K, dn wt 90K 18:00·18:15 0.25 DRILL OBSV CMPL T3 Monitored well-static 18:15 - 20:30 2.25 DRILL PULD CMPL T3 POOH with running tool from 6,936' to 5,736', LD hybrid push pipe and 4 3/4" DC's 20:30 - 23:00 2.50 DRILL TRIP CMPL T3 POOH from 5,736' to Baker running tool 23:00 - 00:00 1.00 CASE RURD CMPL T3 LD Baker running tool and cleared rig floor, NOTE: Running tool appears to have released when safety released and not from pressure 11/24/2004 00:00 - 00:45 0.75 DRILL RIRD CMPL T3 RU to LD DP from mousehole Printed: 12/10/2004 2:59:08 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 E-168 1 E-168 ROT - DRILLING n1334@ppco.com Doyon 141 Start: Rig Release: Rig Number: 10/27/2004 11/26/2004 Spud Date: 10/28/2004 End: 11/26/2004 Group: 11124/2004 11/25/2004 LD 18 stds 4" DP from derrick Slip and cut 78' of drlg line and serviced top drive Worked on pipe skate, got skate back into operation, will need to change out electric switch on skate Fin LD 4" DP & HWDP from derrick, LD an additional 87 stds of 4" DP, 61 stds with Lo-Tads and 11 stds of 4" HWDP Clear and clean rig floor RU to PU and stand back 41/2" completion tubing PU & RIH with 130 its of 41/2', 12.6#, L-80 IBTM tbg to 4,000' Fin PU and RIH with 41/2",12.6#, L-80 IBTM-SCC tbg, RIH from 4,000' to 5,930' (PU a total of 192 its) POOH and stood back 64 stds of 41/2" tbg, changed out seal rings on trip out Pulled wear bushing RU Centrilift to run ESP completion assembly Held PJSM with rig crew and Centrilift on running of ESP completion PU Centrilift's ESP motor assembly, tandem seal section with screen intake, filled motor with oil and connect ESP cable and checked same, Installed 1/4" control line for pump gauge Repaired Centrilift's protectorlizer clamp, clamp was used and had to change out bolts RIH with ESP assembly to 131', PU 2 its 41/2",12.6#, L-80, IBTM SCC tbg and MU well discharge pressure sub Repaired Centrilift's air supply system for banding and clamping tools Connected 1/4" controllìne to discharge pressure sub and checked cable continuity RIH slow with ESP completion assembly from 131' to 4,900', running cable and installing cannon clamps on every other it and checking cable conductivity every 1,000' 2.00 CMPL T RUNT CMPL T3 Cont to RIH slow with ESP completion assembly from 4,900' to 6,168', running cable and installing cannon clamps on every other it and checking cable conductivity every 1,000' 4.00 CMPL TN RUNT CMPL T3 MU Hanger and Landing it with TWC, spliced ESP Cable and MU to tbg hanger, landed hanger and RILDS, Land string as per detail wI Tail @ 6,220', Pump guage @ 6,216', Motor @ 6,182', Seal Section @ 6,168', screen intake @ 6,157' ( 68.3 deg), GLM #1 @ 5,390' MD ( 2,901' TVD), GLM #2 @ 4,195' MD (2,396' TVD), GLM #3 @ 138' (138' TVD), GLM #4 @ 89' (89' TVD), ran a total of 195 jts (6,024.66') of 4 1/2" 12.6#, L-80, IBTM tbg with special clearance collars, st WI up 90K, dn WI 61 K Parts used on ESP cable; 3 - Protectolizer guards= OD 5.875" 2 - Flat guards= OD 5.625" 14 - Flat stainless steel bands 106 - Cannon clamps= 6.75" ND BOP stack NU Vetco Gray tree and tested adapter void and tree to 250 psi low and 5,000 psi high Checked continuity on ESP cable and perform MEG test on penetrator and checked ok Pulled TWC and rig freeze protect well with 255 bbls diesel, Pumping down 41/2" tbg thru screen intake @ 6,157' with returns up 7 5/8" annulus, Had good diesel to surface. circ at 6 bpm at 800 psi 00:45 - 02:15 1.50 DRILL PULD CMPL T3 02:15 - 03:45 1.50 RIGMNT RSRV CMPL T3 03:45 - 06:45 3.00 RIGMNT RGRP CMPL T3 06:45 - 18:30 11.75 DRILL PULD CMPL T3 18:30 - 19:30 1.00 DRILL OTHR CMPL T3 19:30 - 20:15 0.75 CMPLTN RURD CMPL T3 20:15 - 00:00 3.75 CMPLTN RUNT CMPL T3 00:00 - 01 :30 1.50 CMPL T PULD CMPL T3 01 :30 - 05:00 CMPL T3 05:00 - 05:30 0.50 CMPL T OTHR CMPL T3 05:30 - 07:45 2.25 CMPL TN RURD CMPL T3 07:45 - 08:00 0.25 CMPL TN SFTY CMPL T3 08:00 - 13:30 5.50 CMPL TN PULD CMPL T3 13:30 - 14:00 0.50 RIGMNT RGRP CMPL T3 14:00 - 15:00 1.00 CMPL TN PULD CMPL T3 15:00 - 15:30 0.50 RIGMNT RGRP CMPL T3 15:30 - 16:30 1.00 CMPL TN PULD CMPL T3 16:30 - 00:00 7.50 CMPL TN RUNT CMPL T3 11/26/2004 00:00 - 02:00 02:00 - 06:00 06:00 - 07:45 1.75 WELCT NUND CMPL T3 07:45 - 09:45 2.00 WELCT NUND CMPL T3 09:45 - 10:15 0.50 CMPL TN DEQT CMPL T3 10:15 - 12:30 2.25 CMPL T FRZP CMPL T3 Printed: 12/10/2004 2:59:08 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 E-168 1 E-168 ROT - DRILLING n1334@ppco.com Doyon 141 Start: 10/27/2004 Rig Release: 11/26/2004 Rig Number: Spud Date: 10/28/2004 End: 11/26/2004 Group: 15:30· 16:30 16:30 . 18:00 RU scaffolding and lubricator, installed BPV, RD lubricator and scaffolding CMPL T3 Installed actuator valve on tree and secured well CMPL T3 Used crane and changed out Baker Inteq's MWD shack to Sperry Sun and fin cleaning mud pits. RELEASED RIG @ 18:00 Hrs 11/26/04 to move to 1E-104 Printed: 12/10/2004 2:59:08 PM ~ ConocoPhillips Altt, Inc.,Slot #168 Pad 1 E, Kuparuk River Unit,North Slope, Alaska wel.e: 168 Wellpath: MWD wI Mag-Sag<11725 - 13477'> Date Printed: 16-Dec-2004 .¡. BAKER IIUG1IES INTEQ )ò -02<1' .2 ~'¡'3 Q- Ò ò ;} D Ll-ÆO ò Wellbore Name . Created I Last Revised j 16ª--_~_________~___--.L10-NQv-20~________~_______12±1'LQY::2.ºº1..____~___________J Well Name 168 I Govemment ID .. I Last Revised I 1-0ct-2004 i ! I Slot Name Slot #168 Latitude I N70 17 59.2815 Lon itude I W149 35 45.4169 East i 639.66W tl"lstallåtiô... Name Pad 1 E i Eastin~ Northì~ Coord ~m Name North Alianment I 550528.194L- 5959591.109 AK-4 on NORTH AMERICAN DATUM 1927 datu TrueJ ~- Field Name Ku aruk River Unit Eastin 487754.6208 All data is in Feet unless otherwise stated Coordinates are from Slot MO's are from Rig and TVO's are from Rig ( Datum #2 98.4ft above mean sea level) Vertical Section is from O.OON O.OOE on azimuth 4.43 degrees Bottom hole distance is 7398.54 Feet on azimuth 39.95 degrees from Wellhead Calculation method uses Minimum Curvature method Prepared by Baker Hughes Incorporated ~lIips ConocoPhillips AI!., Inc.,Slot #168 Pad 1E, Kuparuk River Unit, North Slope, Alaska Well ath Grid MO[ft] Ilnc[deg] __-1-_ ~~8~~-----ª-!U!~_ 11725.05 I 88.60 1.77 3733.31 3926.96N 117562º-L--ªº~ 0.94 _~_234.9L~_39ºª.62f'L 11850.35 I 84.45 0.96 1 3743.24 . 4051.83N 11948.22 187.65 - --4.17-T~49.98-T-4149.34N 12039.70 1 89.06 7.51 1 3752.61 ! 4240.29N -12134~7-¡-- 89.86- -~9-T~53.50T-4333.74N 12229.06 89.16 8.32 3754.31 4427.51N 12323.21 87.19 7.45 3757.31 4520.71N 12417.74 88.05 5.97 3761.23 4614.51N 12510.61 89.09 4.27 . 3763.5~4706.98N 12601.84 89.13 3.55 3764.97 I 4797.98N 12691.77 89.22 3.32' 3766.26 I 4887.74N 12781.56 -r- -ª.8.62 3.40 t 3767.95 t-.~977.36N 12872.68] 88.54 3.90 i 3770.20 L~068.27~ 12957.63T90:t1 '·5.08 . 3771.20 I 5152.95N 13051.5~_91.4Eì__---º,-8JL-+_ 3769.91 ! 5246.75N ...1:tl41.93 I_...JJ.L~ 3.03 -+_R67.54 -t- 5337.00N 13232.~+-- 92.~ 1.73 i 3764.4L+-.l?42L.53N 13323.26 90.84 2.27 3761.98 5518.11N 13416.42 89.00 358.37 L-3762.11 .~1.24N 13477.00 89.00 358.37· 3763.16 5671.79N well.: 168 Wellpath: MWD wI Mag-Sag<11725- 13477'> Date Printed: 16-Dec-2004 IIi. BAKER HUGHES INTEQ Easting Northing _ 55449Ui.1...l_ 5963272.02_~ 4631.17E 2.03 4272.57 554494.54 5963337.23 ._~:U.92LJ._.-10.3~_-L-.A.304..1.L 554495.08 1 5963368.89 _4633.46L..L_-.1.03__L...1397.2L 554496.00.L 5963462.09_~ 4637.84E 4.63 4494.80 554499.73 5963559.63 4647.14E 1 3.96.. I 4586.20 554508.431 5963650.63J -4660.94E-:-2:07 ---¡- 4680.43- - 554521.60-15963744:16 ' 4675.46E 1.26 4775.04 554535.50 5963838.01 4688.37E 2.29 4868.97 554547.79 5963931.29 4699.41E 1.81 1 4963.34 554558.20 5964025.15 4707.69E 2.15..L 5056.17 554565.87] 5964117.66 4713.91E 0.79 ¡ 5147.38· -554571.49 j~-5964208.70 4719.30E 0.27 5237.29 554576.28 I 5964298.48 4724.56E I _Qß6 _.J~27.05 554580.95 I 5964388.12 , 4730.3§..E -r-..Q.,56_.J_541JL~_ 554586.14 I 5964479.0L~ 4737.01E 1 2.31 ] 5503.07 554592.23 -t_5964563.ZZ_i 4741.90E I 4.68 I 5596.97 554596.50 I 5964657.59.----i 4744.99E +_...l,n..... ! 5687.19 554598.99 j 596474~ ~748.75L . 1.67 ! 5777.74. 554602.15 I 5964838.40--.J 4751.92E T 1.74 ! 5868.29 554604.71 5964928.98 4752.44E i ..1...~-+- 5961.19 554604.61 +_~965022.J.L...j 4750.71E~ 0.00 ! 6021.42 554602.49 5965082.64' All data is in Feet unless otherwise stated Coordinates are from Slot MO's are from Rig and TVO's are from Rig ( Oatum #2 98.4ft above mean sea level) Vertical Section is from O.OON O.OOE on azimuth 4.43 degrees Bottom hole distance is 7398.54 Feet on azimuth 39.95 degrees from Wellhead Calculation method uses Minimum Curvature method Prepared by Baker Hughes Incorporated ~ ConocoPhil/ips Altt, Inc.,Slot #168 Pad 1 E, Kuparuk River Unit, North Slope, Alaska wel.e: 168 Wellpath: MWD wI Mag-Sag<11725 - 13477'> Date Printed: 16-Dec-2004 .¡. BAKER IIUGIB INTEQ Hole Sections Start MO ft -1 108.00 ! 4425.00 8158.00 12073.00 Wellbore 168 PB1 168 PB1 168 PB1 168 I i ì I ~ I I ! Name Top Top Top Top Shoe Shoe Shoe Shoe Wellbore I MOfft! TVmf!L___ N-ºIthff!~ East[fll MQfftL~~ TVQff!L__ NorthfftL EastfftJ I 20" Conductor I 0.00 0.00 --ºJLQl\L_-L---º-00~ 1jJ8.00 108.00 O.OON O.OOE 168 PB1 I I .~~ 103/4" CasinQ_ ¡ 0.00 0.00 O.OON I O.OOE 4419.00 2479.18 1818.52S 2647.81E 168 PB1 ¡ 7 5/8" Casin T I I 0.00 0.00 O.OON O.OOE 8157.00 3714.22 371.36N 4373.61E 168 PB1 I 4 1/2" liner I 7029.00 3462.61 723.10S 4280.64E 11937.00 3513.63 4163.90N 4664.77E 168L2 ~ 4 1/2" liner I 7297.00 3524.46 462.92S 4296.85E 11927.00 3582.50 4143.32N 4699.43E 168 L 1 I 4 1/2" liner 7437.00 3552.95 326.36S 4308.63E 13473.00 3763.09 5667.79N 4750.83E 168 All data is in Feet unless otherwise stated Coordinates are from Slot MO's are from Rig and TVO's are from Rig ( Datum #2 98.4ft above mean sea level) Vertical Section is from O.OON O.OOE on azimuth 4.43 degrees Bottom hole distance is 7398.54 Feet on azimuth 39.95 degrees from Wellhead Calculation method uses Minimum Curvature method Prepared by Baker Hughes Incorporated ~illips ConocoPhillips AI., Inc.,Slot #168 Pad 1 E, Kuparuk River Unit, North Slope, Alaska wellbo.68 PB1 Wellpath: GSS <0-260'>MWD w/Mag-Sag<403-12073'> Date Printed: 16-Dec-2004 IIi. BAKE. HUGHES INTEQ J ûL/-À-G ~ Wellbore Name 1"º-a PB1 Created .l29-0cJ=-2Q.QL~~~_ I Last Revised ! 12-Nov-2004 Well Name 168 Government ID Last Revised i 1-0ct-2004 Slot Name Slot #168 17 59.2815 35 45.4169 Inslallatiót1 Name Pad 1E Field Name Ku aruk River Unit ----, Eastin 487754.6208 All data is in Feet unless otherwise stated Coordinates are from Slot MD's are from Rig and TVD's are from Rig ( Datum #2 98.4ft above mean sea level) Vertical Section is from O.OON O.OOE on azimuth 4.43 degrees Bottom hole distance is 6316.11 Feet on azimuth 47.41 degrees from Wellhead Calculation method uses Minimum Curvature method Prepared by Baker Hughes Incorporated <:onocri'Phillips ConocoPhilJips All., Inc.,Slot #168 Pad 1 E, Kuparuk River Unit, North Slope, Alaska wellb.168 PB1 Wellpath: GSS <0-260'>MWD w/Mag-5ag<403-12073'> Date Printed: 16-Dec-2004 .¡. BAKER IlUGlIES INTEQ Wellpath (Grid) Report I MD[ft] Inc[deg] Azi[deg] TVD[ft] 8tation Station I Dogleg 8everi~ ~ertical Easting Northing I PositionN) I Position(X) Sectionrftl 0.00-t- 0.00 0.00 1 0.00 O.OON O.OOE ¡ 0.001 0.00__ c-. 549890.00 I 5959380.00 1 0.00 i 108.00 i O.OON -- -O.OOE¡-o:oO--¡-- 0.00 1 108.00 I 0.00 549890.00 ! 5959380.00 172.00 ¡ 0.90 73.0~---.J 72,º-~-----.!l1PJ-.___ ------º'--4§.E.-+_..L.~--+-__º.18 __ ~890.48 I 5959380.15 1 _260.0º-L 1.80 86.00 1 259.97 1 0.45N f-- 2.52E I 1.07 1 0.64 c-_ 549892.52 i 5959380.46 I 403.04 i 7.49 111.24-----r 402.49 I 2.788 I ! 549903.48 I 5959377.31 1 13.46E I 4.13 -1.73 -~~~L 13.29 124.08 493.52 1 JQ.938 27.91E I 6.71 I -8.75__ ,-----549917.98 I 5959369.25 I 586.09 17.95 123.08 580.63 24.388 48.22E --r 5.16 r-~.59 549938.37 I 5959355.94 677.23 21.08 125.96 T 666.53 41.678 73.26E 1 3.59 I -35.90 549963.53 5959338.82 I 768.56 25.57 129.77 750.38 63.948 101.72E 5.18 : -55.90 549992.13 5959316.74 860.23 27.11 130.60 i 832.53 I 90.198 132.79E ! 1.73 -79.68 550023.37 5959290.70 ! 952.09 I 27.82 130.77 914.03 117.818 164.91 E 1 0.78 I -104.73 550055.67 5959263.30 1 I 1 1045.23 31.25 129.84 995.06 147.498 199.93E 1 3.72 -131.62 550090.89 I 5959233.86 L__.-1.t37.10 ! 36.41 129.68 I 1071.35 180.198 239.24E 5.62 I -161.19 550130.41 5959201.43 1230.00 i 38.37 128.34 I 1145.16 215.68S 283.08E 2.28 -+----193.20 550174.48 _1_ 5959166.23 1322.55~8.59 I ¡ 128.15 1 1417.61 251.338 328.31E 0.27 1 -225.25 550219.94 ~959130.88 I 1416.58 40.53 128.36 1290.10 I 288.41S 375.33E I 2.07 ¡ -258.59 550267.20 I 59590~~ 1508.17 49.16 126.98 1354.98 I 327.798 426.44E I 9.48 I -293.91 550318.57 I 5959055.08 1606.94 52.61 125.48 f 1417.28 I 373.06S 488.26E 1 3.69 1 -334.27 550380.68 1 5959010.23 I i 1693.73 57.48 124.71 ] 1466.99 413.938 546.45E I 5.66 -370.53 550439.13 5958969.75 1786.91 62.63 123.85 1513.49 459.388 613.15E f 5.58 1 -410.70 550506.13 5958924.75 1879.31 68.80 122.62 1551.47 505.49S 683.58E I 6.79 I -451.25 550576.85 I 5958879.10 ~ 1972.37 71.09 126.19 1583.39 554.898 755.67E 4.36 1 -494.93 550649.26 I 5958830.19 2076.76 70.79 125.61 1617.48 612.75S 835.59E 0.60 -546.45 550729.56 5958772.87 2164.19 70.13 . 124.16 1646.73 I 659.878 903.18E 1.74 -588.22 550797.45 5958726.20 2259.00 69.65 123.26 1679.33 709.28S 977.24E 1.03 -631.77 550871.83 5958677.29 2350.66 69.35 124.78 1711.43 757.318 1048.40E 1.59 I -674.17 550943.30 5958629.74 2442.70 68.53 125.05 1744.50 806.47S 1118.83E 0.93 I -717.75 551014.04 5958581.05 2535.80 67.06 125.20 1779.68 856.078 1189.32E 1.59 -761.75 551084.86 5958531.93 2627.97 68.18 124.88 1814.78 905.00S 1259.10E 1.26 -805.16 551154.96 5958483.47 1 2720.91 69.17 122.97 1848.58 953.318 1330.94E 2.19 -847.78 551227.11 5958435.64 ~ 2813.78 68.86 121.59 1881.84 999.62S 1404.25E I 1.43 I -888.29 551300.71 5958389.83 -I 2907.21 68.79 122.78 1915.59 1046.028 1477.98E 1.19 I -928.87 551374.74 i 5958343.92 ì 2999.00 68.80 121.10 I 1948.79 1 1091.29S 1550.59E f 1.71 I -968.40 551447.65 5958299.13 1 3091.69 69.18 125.25 1982.04 1138.638 1623.00E 4.20 -1010.01 551520.36 5958252.28 3184.86 69.51 122.86 2014.91 í 1187.44S 1695.22E 2.43 I -1053.11 551592.90 5958203.95 3277.09 70.01 122.01 2046.81 1233.86S 1768.26E 1.02 I -1093.75 551666.23 5958158.03 3370.57 69.45 122.38 2079.20 1280.58S 1842.46E 0.70 I -1134.61 551740.74 5958111.81 3463.91 66.59 123.82 2114.13 1327.838 1914.97E 3.38 -1176.12 551813.55 5958065.05 I 3555.24 68.59 123.04 2148.95 I 1374.34S 1985.43E 2.33 T -1217.06 551884.31 5958019.01 3649.52 69.90 122.27 2182.36 1421.90S 2059.66E 1.59 -1258.75 551958.85 5957971.94 3740.86 68.91 122.85 2214.49 1467.928 2131.72E 1.24 -1299.07 552031.21 5957926.41 3833.75 67.60 120.30 2248.91 1513.108 2205.21E 2.91 -1338.45 552104.99 5957881.73 3927.19 66.59 122.89 2285.28 1558.18S 2278.52E 2.77 -1377.74 552178.59 5957837.14 4020.59 66.83 124.50 2322.21 1605.778 2349.89E 1 1.60 -1419.68 552250.27 5957790.02 4113.68 I 66.03 125.75 2359.43 1654.86S 2419.68E 1.50 -1463.24 552320.37 5957741.40 I 4206.31 65.52 126.13 2397.44 1704.44S 2488.07E I 0.67 -1507.39 552389.08 5957692.28 1 4298.54 66.86 125.79 I 2434.67 1753.998 2556.37E I 1.49 -1551.52 552457.70 I 5957643.20 4361.90 68.83 125.63 2458.57 1788.248 2604.02E ¡ 3.12 -1582.00 552505.57 5957609.27 i 4464.88 I 68.88 122.14 2495.72 1841.78S 2683.74E I 3.16 1 -1629.22 552585.64 5957556.26 I 4556.83 69.95 118.85 2528.06 1885.448 2757.90E 3.55 I -1667.04 552660.08 5957513.10 i 4650.65 I 69.17 112.64 2560.85 1923.62S 2837.03E _L_ 6.26 i -1698.99 552739.46 i 595747ML.J All data is in Feet unless otherwise stated Coordinates are from Slot MD's are from Rig and TVD's are from Rig ( Datum #2 98.4ft above mean sea level) Vertical 8ection is from O.OON O.OOE on azimuth 4.43 degrees Bottom hole distance is 6316.11 Feet on azimuth 47.41 degrees from Wellhead Calculation method uses Minimum Curvature method Prepared by Baker Hughes Incorporated ~lIips ConocoPhillips AI., Inc.,Slot #168 Pad 1E, Kuparuk River Unit, North Slope, Alaska wellb.168 PB1 Wellpath: GSS <0-260'>MWD w/Mag-5ag<403-12073'> Date Printed: 16-Dec-2004 IIi. BAKER HUGHES INTEQ WellDath (Grid) Report I MD[ft] Inc[deg] Azi[deg] TVD[ft] Station Station Dogleg Severi Vertical Easting Northing I PositionN\ Position(X) 5ectionfftl _A744.58 1~7.05 __ ------1Q6.73 2595.90 i----~2.99~_ r---2919.03E 1_~_~21.95 552821.64 i 5957446.63 I I I 4838.70 ¡ 65.05 100.21 ¡ 2634.14 I 1973.05S 3002.61E· 6.68 j -1735.50 552905.34 I 5957427.13 I f---A931.27 -I--- 64.65 96.32 2673.49 I 1985.09S 3085.51 E ---+- 3.83 I -1741.11 552988.31 --L~57415~ ~25.3ª--L 61.69 89.89 I 2716.00 j 1989.70S 3169.29~ 6.86 I -1739.24__ 553072.12 I. 5957411.58 i I 5118.79 I 59.30 85.39 I 2762.021 1986.39S 3250.48E ¡ 4.91 i -1729.68 ---s53153.28I-5957415.431 ~J2.46 I 59.10 78.05 I 2810.03 1974.825 3330.02E I 6.73 I -1712~~ _ß53232.73 I 5957427.53 I i I i ~ 5306.07 I 59.89 70.12 I 2857.60 1952.715 3407.48E 7.35 -1683.99 553310.03 5957450.15 ! 5399.00 I 60.87 63.02 I 2903.58 1920.605 3481.53E I 6.72 I -1646.26 553383.85 5957482.75 5493.02 I 63.45 57.13 2947.51 i 1879.115 3553.50E I 6.18 -1599.34 553455.55 5957524.71 5586.72 64.99 52.48 2988.28 1830.48S 3622.41E 4.76 I -1545.54 553524.12 I 5957573.79 I ¡ 5680.14 i 67.32 49.69 3026.05 1776·805 3688.87E 3.70 +~1486.89 553590.22 5957627.90 I 5773.79 68.27 48.39 3061.44 j 1719.965 3754.34E 1.64 . -1425.17 553655.30 5957685.17 5866.68 I 68.24 47.54 3095.86 1662.19S 3818.42E 0.85 -1362.63 553719.00 5957743.36 I 5960.50 L 67.73~ I I I _47.70 3131.03 1603.565 3882.67E I 0.57 -1299.22 553782.85 5957802.~ f-- 6054.04 I 67.42 48.51 I 3166.71 1545.825 3947.04E 0.87 I -1236.69 553846.82 5957860.57 I 6147.73 1 68.32 46.47 i 3202.01 1487.185 4011.00E I 2.23 I -1173.28 553910.39 5957919.63 , 6240.95 170.07 41.62 ~35.13 1424.565 4071.55E -1- 5.21 -1106.17 553970.51 i 5957982.65 I 6334.64 71.24 36.99 3266.18 1356.175 4127.51E I 4.83 -1033.67 554026.02 5958051.40 ! 6427.56 71.52 30.50 3295.88 1282.995 4176.40E I 6.63 I -956.94 554074.41 5958124.89 6521.21 71.88 23.37 3325.32 1203.78S 4216.63E 7.24 I -874.86 554114.11 5958204.36 6614.67 71.98 15.21 3354.35 I 1120.00S 4245.95E 8.30 -789.07 554142.88 5958288.32 i 6707.90 71.20 7.80 3383.83 1033.40S 4263.60E 7.59 -701.36 554159.94 5958375.03 6801.91 72.86 1.59 i 3412.86 944.335 4270.89E 6.53 -612.00 554166.64 5958464.14 6892.77 i 78.00 2.29 I 3435.71 I 856.475 4273.87E 5.71 -524.17 554169.04 I 5958552.01 6995.10 I 79.17 3.30 I 3455.96 756.295 4278.76E 1.50 -423.91 554173.27 5958652.21 7088.26 I 76.57 2.97 3475.54 665.35S 4283.74E 2.81 -332.86 554177.64 I 5958743.17 I 7183.49 74.48 3.66 3499.34 573.30S 4289.07E 2.30 -240.68 554182.36 5958835.24 7276.00 79.11 4.25 3520.47 483.48S 4295.29E 5.04 -150.64 554187.98 5958925.09 7368.82 78.38 5.07 I 3538.58 392.75S 4302.68E 1.17 -59.61 554194.77 5959015.86 I 7463.35 76.88 5.21 I 3558.83 300.795 4310.95E 1.59 32.72 554202.43 5959107.87 7556.48' 77.26 5.92 i 3579.67 210.455 4319.76E 0.85 123.47 554210.63 5959198.26 7650.10 75.53 6.31 I 3601.69 I 119.97S 4329.45E 1.89 214.42 _.554219.72 5959288.78 7742.32 75.63 5.72 3624.66 I 31.155 4338.81E 0.63 I 303.70 554228.49 I 5959377.66 I ¡ 7837.15 74.29 5.07 I 3649.27 60.02N 4347.42E 1.56 395.26 554236.50 I 5959468.87 I 7930.08 74.81 4.39 i 3674.02 I 149.29N 4354.81E 0.90 ! 484.83 554243.29 5959558.18 I 8023.15 77.74 5.19 I 3696.10 I 239.37N 4362.36E 3.26 575.23 554250.24 5959648.30 ! 8084.31 81.57 4.95 3707.08 I 299.29N 4367.67E 6.27 635.38 554255.16 5959708.25 8137.52 85.83 4.60 3712.92 351.99N 4372.07E 8.03 688.26 554259.21 5959760.97 8230.44 89.00 3.96 3717.11 444.54N 4379.00E 3.48 781.07 554265.52 5959853.56 j 8324.14 I 89.12 2.70 3718.65 538.07N 4384.44E 1.35 874.74 554270.34 5959947.11 8417.24 I 88.57 2.74 3720.53 631.04N 4388.86E 0.59 967.78 554274.14 5960040.10 8510.06 88.08 1.94 I 3723.24 723.75N 4392.65E 1.01 1060.50 554277.31 5960132.82 8603.10 88.94 0.63 3725.66 816.73N 4394.73E 1.68 1153.36 554278.78 5960225.80 _ª697.84 90.72 3.01 3725.94 911.41N 4397.74E 3.14 1248.00 554281.16 5960320.49 8789.91 I 89.83 6.04 3725.50 1003.18N 4405.01E 3.43 1340.05 554287.81 5960412.30 8884.49 i 90.88 5.23 3724.91 1097.30N 4414.29E i 1.40 1434.61 554296.47 5960506.47 8977.26 i 91.77 2.27 i 3722.76 1189.83N 4420.36E I 3.33 L 1527.33 554301.92 5960599.03 9070.28 91.61 5.66 3720.02 1282.58N 4426.79E 3.65 1620.30 554307.73 5960691.81 9164.40 91.70 4.91 3717.30 1376.26N 4435.45E 0.80 1714.37 554315.78 I 5960785.53 -1 9257.52 I 91.86 6.28 3714.41 1468.89N 4444.53E 1.48 1807.42 554324.24 5960878.21 9351.97 92.04 5.26 I 3711.20 1562.80N 4454.02E 1.10 I 1901.79 554333.10 I 5960972.18 All data is in Feet unless otherwise stated Coordinates are from Slot MD's are from Rig and TVD's are from Rig ( Datum #2 98.4ft above mean sea level) Vertical 5ection is from O.OON O.OOE on azimuth 4.43 degrees Bottom hole distance is 6316.11 Feet on azimuth 47.41 degrees from Wellhead Calculation method uses Minimum Curvature method Prepared by Baker Hughes Incorporated ~1Iips ConocoPhillips Alia, Inc., Slot #168 Pad 1 E, Kuparuk River Unit, North Slope, Alaska wellb.168 PB1 Wellpath: GSS <0-260'>MWD w/Mag-Sag<403-12073'> Date Printed: 16-Dec-2004 II.. 8AKR HUGlES INTEQ Wellpath (Grid) Report I I MD[ft] Inc[deg] Azi[deg] TVO[ft] Station Station Dogleg seve~ Vertical Easting Northing I PositionN\ Position{X\ Sectionrftl I ~_ 9444.67 I 91.33 6.20 ~ 3708.47 I 1655.00N 4463.27E I 1.27 ) 1994.42 554341.74 I 5961064.43 ~ 9538.14 I 88.33 7.40 I 3708.75 I 1747.80N 4474.33E 3.46 -r-2087.80 554352.19 ~961157.29~ I 9632.04 i 89.22 5.42 I 3710.76 I 1841.08_L _.4484.81E I 2.31 I 2181.62 554362.05 t--5961250.63 ~+- I I 9724.93 I 88.85 3.67 I 3712.32 I 1933.66N _.4492.17E I 1.93 2274.49 554368.79 _-+ 5961343.25 I ~----r-- 5.30 ~ 3713.78 I 9820.68 i 89.40 I 2029.11N 4499.66E I 1.80 I 2370.22 554375.64 I 5961438.73 9912.16 I 87.81 6.21 I 3716.01 --1-----£120.09N 4508.8~_~",ºº----+- 2461.65 554384.21 5961529.77 i 10007.09 88.23 5.44 3719.29 ì 2214.48N 4518.46E 0.92 I 2556.49 554393.21 i 5961624.20 10099.08 I 87.93 4.24 3722.37 2306.09N 4526.21 E 1.34 I 2648.43 554400.36 I 5961715.85 10191.82 I 86.67 5.12 3726.74 I 2398.41N 4533.77E I 1.66 I 2741.06 554407.30 I 5961808.22 10285.82 87.99 4.00 I 3731.12 I 2492.01N 4541.24E I 1.84 2834.95 554414.14 5961901.85 10378.77 I 89.43 2.98 I 3733.21 2584.76N 4546.89E I 1.90 2927.86 554419.18 5961994.63 10472.88 87.83 6.18 3735.46 2678.53N 4554.40E I 3.80 3021.93 554426.07 5962088.44 I 10566.80 I 87.84 6.16 3739.01 2771.84N 4564.49E 0.02 ¡ 3115.74 554435.54 5962181.80 10659.13 87.96 5.85 3742.39 2863.60N 4574.14E 0.36 3207.97 554444.58 5962273.62 I 10752.41 88.08 6.57 ~745.62 2956.27N 4584.23E 0.78 3301.15 554454.05 5962366.35 10846.91 I 90.02 4.72 3747.18 3050.29N 4593.52E I 2.84 3395.61 554462.71 5962460.42 10939.93 91.67 1.87 3745.81 3143.14N i 3.54 I 3488.59 554467.44 5962553.29 11034.17 I 91.77 1.72 I 3742.98 3237.29N 4598.87E I 0.19 3582.69 554469.77 i 5962647.45 4601.82E 11113.42 I 92.87 358.19 3739.77 I 3316.46N 4601.76E 4.66 3661.62 554469.18 5962726.61 11204.90 91.61 0.49 3736.20 3407.86N 4600.70E 2.87 3752.66 554467.52 I 5962817.98 11295.13 90.54 3.97 3734.50 3497.99N 4604.21E 4.03 3842.79 554470.43 I 5962908.13 I 11386.20 91.55 2.82 3732.84 3588.88N 4609.60E 1.68 3933.83 554475.22 5962999.04 11477.66 90.20 4.59 3731.45 3680.13N 4615.52E 2.43 4025.27 554480.52 5963090.33 11568.60 89.40 4.93 3731.76 3770.76N 4623.06E 0.96 4116.20 554487.47 5963180.99 11659.80 89.80 2.33 3732.40 3861.76N 4628.83E 2.88 4207.38 554492.64 5963272.02 11753.02 90.26 2.24 3732.35 I 3954.91N 4632.55E 0.50 I 4300.54 554495.73 I 5963365.18 11846.92 91.98 2.74 3730.52 4048.70N 4636.63E 1.91 4394.36 554499.19 5963458.99 11931.33 I 92.04 3.53 3727.55 I 4132.93N 4641.24E I 0.94 4478.70 554503.24 I 5963543.24 12019.67 i 91.30 3.64 3724.98 4221.06N 4646.76E 0.85 4566.99 554508.18 5963631.39 12073.00 i 91.80 3.64 3723.54 4274.26N 4650.15E 0.94 4620.30 554511.21 5963684.61 All data is in Feet unless otherwise stated Coordinates are from Slot MO's are from Rig and TVO's are from Rig ( Oatum #2 98.4ft above mean sea level) Vertical Section is from O.OON O.OOE on azimuth 4.43 degrees Bottom hole distance is 6316.11 Feet on azimuth 47.41 degrees from Wellhead Calculation method uses Minimum Curvature method Prepared by Baker Hughes Incorporated · Conoc~illips ConocoPhillips Alia, Inc.,Slot #168 Pad 1 E, Kuparuk River Unit,North Slope, Alaska wellb.168 PB1 Wellpath: GSS <0-260'>MWD w/Mag-Sag<403-12073'> Date Printed: 16-Dec-2004 III. BAKER HUGIIIS INTEQ EastfftL- Comment 4650.15E Pro'ected Data - NO SURVEY , _~_____------1 Hole Sections Start MOft I 10B.00 I 4425.00 8158.00 Wellbore 13 1/2 971B 63/4 168 PB1 168 PB1 168 PB1 ----1 i Casinas Name Top Top Top Top Shoe Shoe Shoe Shoe Wellbore MDrftl TVDrftl Northfftl Eastfftl MQ[ftl TVDrftl Northlftl Eastrftl 20" Conductor 0.00 0.00 O.OON O.OOE 108.00 108.00 I O.OON O.OOE 168 PB1 103/4" Casino 0.00 0.00 O.OON O.OOE 4419.00 2479.18 1818.52S 2647.81E 168 PB1 7 51B" Casin~ i 0.00 0.00 O.OON O.OOE 8157.00 3714.22 371.36N __ _'t373.61E 168 PB1 4 1/2" Liner 7029.00 3462.61 723.10S 42BO.64E 11937.00 3513.63 4163.90N 4664.77E 16BL2 4 1/2" Liner 7297.00 3524.46 462.928 4296.85E 11927.00 3582.50 4143.32N 4699.43E 168 L 1 4 1/2" Liner 7437.00 3552.95 326.36S 4308.63E 13473.00 3763.09 5667.79N 4750.83E 16B All data is in Feet unless otherwise stated Coordinates are from Slot MO's are from Rig and TVO's are from Rig ( Datum #2 98.4ft above mean sea level) Vertical Section is from O.OON O.OOE on azimuth 4.43 degrees Bottom hole distance is 6316.11 Feet on azimuth 47.41 degrees from Wellhead Calculation method uses Minimum Curvature method Prepared by Baker Hughes Incorporated ~OV-09-2004 17:36 P.01 .'d-é)l.{~' òlO()'· .'~Ofl?cOÞhÎlJips Ata$k~: 'Cementinš" Rep~rt Legal Well Name: 1E-168PB1 Common Well Name: 1E·168PB1 Event Name: ROT ~ DRILLING Report #; Start: 2 10/27/2004 ". "q~me~.t,~Ob Typ~: pri~a;i)"... . ,', ," ,Prima Hole Size: 9.875 (in) TMD Set: 8.157 (ft) (ft) Date Set: 11/5/2004 Csg Type: Intermediate Casjl"lg/Li Csg Size: 7.625 On.) Cmtd. C$g: Intermediate Casing/Li Cmtd. CS9; Cement Co: DoweJI $chJumbergel' Rot Time Start: ; Rec Time Start: 1 0:15 . , Page;1/f 3 Spud Dat~!;''''1 Q12812004 Report Dâter,d~Q4 End: .~~ PIU Hole Size: TMD Sat: Date Set Csg Type; SO TMD: SO Date: Cmtd. esg: Hole Size: Top Set: (ft) BTM Get (ft) Plug Date: Plug Type: DrIJ/ed Out: Cmtd. Csg: Pipe Movenient: Reciprocating Cementer: Jerry Culpepper , . Time End: : Time End; 16:00 RPM: SPM; "Pipe Movement Inn Torque: (ft-Ibf) Stroke Length: 8.0 (n) Avg Torque: (ft-Ibf) Max Torque: (ft-Ibf) Drag Up; 190,000 (Ibs) Drag Down: 80,000 (Ibs) Type: Cement Casing Volume Excess %: 25.00 Me¡¡s. From: 0 Time Circ Prior To Cementing; 2.75 MUd Circ Rate: 252 (gpl'!'\) Mud Circ Press; 525 (psi) Stage Nò:' 1 of 1 Stan Mix Omt: 14:30 Start Slurry Displ: 14:30 Start Displ: 15:00 End Pumping: 16:10 End Pump Datè; 11/5/2004 Top Plug: Y 6ottom Plug; Y D;sp Avg Rate: Disp Max Rate: Bump Plug: Press Prior: Press Bumped: Press Held: Float Held: 1.00 (bb/lmin) 7.00 (bbllmin) Y 1,100 (psi) 1,600 (p$i) 3 (min) Y Returns: 100 Total Mud Lost: (bbl) Cmt Vol to Surf: (bbl) Ar'ln Row After: N Mixing MethOd: On Fly Density Meas By: Densometer Type; L.SND Density: 9.2 (ppg) Vise: 78 ($/qt) Bottom Hole Circulating Temperature;?1 (OF) Displacement Fluid Type:Other PVIYP; 14 (cp)/10 (lb/100ft2) Gels 10 see: IS (lb/100~) Gels 10 min;? (lb/100lt~) Bottom Hole Static Temperature: 82 (OF) Density: 9.3 (ppg) Volume; 368.30 (bbl) .. T .. , ., . , . Stage No: 1 Slurry No: 1 of 3 . Slurry Data Fluid Type: CW 100 Slurry Interval; 3.515.00 (ft]ro: Water Source: Test Data Thickening Time: Free Water: (%0) Fluid Loss: (cc) Fluid Loss Pressure: (OF) DescrÎption: 2,255.00 (ft) Cmt Vol: (bbl) Slurry Vol: (sk) Tem~rature: (OF) Temperature: (OF) Temperature: (oF) . . . Muc;t þata Density; 8.30 (ppg) Water Vol: (bbl) Class: Yield: (ft~/sk) Other Vol: () Purpose: Chemical Wa$ Mix Water; (gal) Foam Job: N Temp (OF) (OF) Prasstlre (psi) (pSi) TIme CompreSSive Strength 1: CQmpressive Strength 2: '\~~~~,,-(è.--..)~\\')Q~cft) ~ \" \ e -\ OL-t ~Otè A2..~ \l!t~·-o1 Printed; 11/10/i004 5;16:24 PM NDV-09-2004 17:36 DRLG / WELLS Legal Well Name: 1E-168PS1 Gommon Well Name: 1E-168PB1 Event Name: ROT - DRILLING Slurry Data Fluid Type: MUDPUSH XL Slurry Interval: 4.786.00 (ft)To: Water Source: Test Data Thickening Time: Free Water: (%) Fluid Loss; (cc) Fluid Loss Pressure: ("F) Slurry Data Fluid Type: TAIL Slurry Interval: 8,157.00 (ft)To: Water Source: Te$t Data Thickening Time: Free Water: (%) Fluid Loss: (cc) Fluid Loss Pressure: (OF) Trade Namë D·186 0-46 D167 D 160 907 265 1336 e ...ConöcoPhillipsAlaska .. Cementing'Report· . . , .' . P.02 . . .. Pagè2 of 3 Report #: Start: Spud Date: , 0/28/2004 2 Report Date: 11/5/2004 10/27/2004 End: Stage No: 1 Slurry No: 201 3 DeSCription: MUDPUSH XL Class: 3,515.QO (ft) Cmt Vol: (bbl) Density: 10.50 (ppg) Yield; (ft3/sk) Slurry Vol: (sk) Water VOl: (bb/) Other Vol: 0 Temperature: (OF) Temperature; (OF) Temperature: (OF) Time Compressive Strength 1: Compressive Strength 2: Temp (OF) (OF) . . . . .. . stage NO: } Slurry No: 3 of 3 . Description: DeepCrete 4,786.00 (ft) Cmt Vol: 168.2 (bbl) Slurry VoIA22 (sk) Temperature; (OF) Temperature: (OF) Temperature: (OF) Class: Density: 12.50 (ppg) Yield: 2.24 (ft3/sk) Water VOl; 74.0 (bbl) Other VQI; () Time Compressive Strength 1: Compressive Strength 2: Temp ("F) (DF) Stage No: 1 Slurry No:.3 of 3 .. Additives DEFOAMER Purpose: SPACER Mix Water: (gal) Foam Job: N Pressure (psi) (pSi) Purpose: TAIL Mix Water; 7.40 (gal) Foam Job; N Pressure (psi) (psi) T e Units . Units Concentration %BWOC %BWOC %BWOC Printed; 11/10l:i¡004 5:16;~4 PM ~OV-09-2004 17:37 e 907 265 1336 P.03 · ··ConoþoPhilHps AIØska ... · ... Cel11"ntil1gReþórt.·· . .. Pag~3 .of 3 legal Well Name: 1E-168PB1 Common Well Name: 1E-168P81 Event Name: ROT· DRILLING Report #: Start: SpUd Date: 10/28/2004 2 Report Date: 11/5/2004 10/27/2004 End: Casing Test Test Press: 3,000 (psi) For: 30 (min) Cement Found between Shoe and Collar: N Shoe Test . ... ··.··liner.TopTest· Pre6$Ure: (ppge) Tool: N Open Hole; (ft) I-Ir$ Before Test: Liner Lap: Pos Test (ppge) Neg Test: (ppge) HIS Before lest: Cement found on ToOl: N Tool: N Tool: N . . . log/Survey Evaluation . . . . . '. . InterpretationSùmmary CBl Aun: N Under Pressure: (psi) 80nd Quality: Cet Aun: N Bond QlJatlty: Temp SUJ'Vey: N I-Irs Prior to Log: Cement Top; (ft) I-Iow Determined: TOC Sufficient N Job Rating: If Unsuccessful Detection Indicator: Remedial C¡¡,menting Required: N Number of Remedial Sql,leszes: Àemarks Cont to circ and cond mud for cementing, clrc at 6 bpm at 425 psi, st wt up 200K, dn 85K, initial MW out 9.6 PÞ9. 78 vis, PV 3:2, YP 40, Conditioned mud to final MW out of 9.2 PPg, 41 vis, 11 YF> and 14 PV, Held PJSM with Oowell, APC vac truck drivers and rig crew on cementing csg while eire. Dowell pumped 10 bb/s CW 100 at 8.3 PPg, Pressure tested lines to 3,500 psi, Then pumped 40 add. bbls of CW 100, Pvmped 50 bbls of MudPush at 10.5 ppg, Dropped btm plug then þumped 168.2 bbls¡ (422 sX$) of DeepCrete cmt at 12.5 ppg, 2.26 yield with additives, ave a.s bpm at 250 P$i. Reciprocated pipe with full returns, $l'Iut down, Washed up and dropped blm plug. Rig displaced cement with 9.3 ppg OeM, E3umped plug on calc displacement after pumping 368.3 bbls OSM (96% pump eft.) ave 7.0 bpm while displadng emt, Max pressure 1100 psi, Slowed pump rate to :3 bpm with 3 bbl$ left to pump and bumped plug to 1,600 psi, ck floats and held CIP at 16:10 hrs, Reciprocated pipe unti 73.0 bbrs cmt was around shoe when hole began getting tight and stopped reciprocating wI Shoe @ 8,157', Float Collar @ 8.026', Calc TOC @ 4,786', Had fuIJ returns thru out job. Printed: t tll 0/2004 5: 16:24 PM NOV-09-2004 17:37 DI / WELLS Conocó'Phlllips 907 265 1336 P.04 e Drill and Complete Procedure west Sak Well #IE-168 A2/B/D Trilateral Welll!lan Summa!J( Formation Markers and Directional Waypoints Main Wellbore, .~ ~ 118"& HOH Sand Lateral HUSumd Hole Dogleg True Depth HoløAng/e AZ;muth Sevet1ty(dég I Ve~1 True Vertical Oeséription (RKB feet) (degrees) (degrees) 100') Depth (RKB Depth (SS feet) feet) Dovon 141 Rig 0 0 0 0 0 98.4 Roor KOP 300 0 0 0 300 202 Base Permafrost 1895 68.2 125 0 1510.4 1412 Top T-3 2547 68.2 125 0 1752.4 1654 TOD K-15 3392 68.2 125 0 2066.4 1968 103/4 SURFACE 4450 67.6 122.8 5 2459.4 2361 TOD Uanu C 5286 63.2 76.8 5 2823.4 2725 Too Uanu B 5859 68.2 47.8 0 3061.4 2963 TOD Uanu A 6007 68.2 47.8 0 3116.4 3018 K13 6490 70.3 25.8 5 3290.4 3192 TOD West Sak D 7008 75 4.4 0 3442.4 3344 Top West sak B 7326 80 4.4 3 3514.4 3416 TOD West Sak A 7643 80 4.4 0 3569.4 3604 7 5/8 CSG pt, 8409 80.8 4.4 4 3702.4 3604 "A" Sand Toe 13521 88.7 4.3 0 3771.4 3673 Target,. TD, Casing Poìnt "8" Sand Toe 12016 88.7 3.5 0 3560.4 3462 Target, TD, Casing Point "0" Sand Toe 12009 89 3.5 0 3500.4 3402 Target, TO, Casing Point profose~ irt ¡Jell; ~ Steve Shultz Issued 10(21/2004 Page 5 TOTAL P.04 L.-Ü. lJ!VI~Her Lme Length IE-168 . . dO L.\_ a-{JCJ Subject: RE: Diverter Line Length lE-168 From: Doyon 141 Company Man <n1334@conocophillips.com> Date: Wed, 20 Oct 2004 11 :30:42 -0800 To: Thomas Maunder <tom_maunder@admin.state.ak.us> CC: "Shultz, Steven M" <Steven.M.Shultz@conocophillips.com>, "McKeever, Steve" <Steve.McKeever@conocophillips.com>, "Greener, Mike R." <Mike.R.Greener@conocophillips.com>, "Thomas, Randy L" <Randy.L. Thomas@conocophillips.com> Yes Sir it will. Until we get away from this pad that has the old reserve pit I think the safest way to run the system is with the 60' length and our weight stand as close to the end as possible. Thanks Dearl W. Gladden -----Original Message----- From: Thomas Maunder [mailto:tom maunder@admin.state.ak.us] Sent: Wednesday, October 20, 2004 10:41 AM To: Doyon 141 Company Man Cc: Jim Regg; AOGCC North Slope Office; Bob Fleckenstein; Thomas, Randy L; rig141@doyondrilling.com Subject: Diverter Line Length lE-168 Dearl, We do not object to your proposal to shorten the diverter line. Will the shorter line be necessary for other wells on IE pad?? Please respond with any questions. Tom Maunder, PE AOGCC -------- Original Message -------- Subject: Request Date: Wed, 20 Oct 2004 08:48:59 -0800 From: Doyon 141 Company Man <n1334@conocophillips.com> To: aogcc prudhoe bay@admin.state.ak.us, bob flecke~stein@admin.state.ak.us, ~m regg@admin.state.ak.us, rig141@doyondrilling.com, "Thomas, Randy L" <~andy.L.Thomas~~~?cophillips.com> I would like to request a waiver to cut down the length of the diverter relief line to 60' on the next well we will be drilling IE - 168. If we run the 75' it runs out over the old reserve and cannot be properly secured. By using 60' of 16" diverter line we are able to install our weight system at the end of the line which gives us very good stability of the line. Thanks Dearl W. Gladden Dearl Gladden / Mike Thornton Doyon 141 Company Man 907-659-7170 I of 1 1118/2004 2:50 PM · ~~~~Œ lID~ ~~~~[ß~ / A.,ASIiA OIL A5D GAS / CONSERVATION COMMISSION .. FRANK H. MURKOWSKI, GOVERNOR 333 W. 7'" AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Randy Thomas Kuparuk Drilling T earn Leader ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, Alaska 99510-0360 Re: Kuparuk lE-168 ConocoPhillips Alaska, Inc. Permit No: 204-200 Surface Location: 207' FNL, 640' FEL, SEC. 21, TIIN, RIOE, UM Bottomhole Location: 5096' FNL, 1127' FEL, SEC. 10, TIIN, RlOE, UM Dear Mr. Thomas: Enclosed is the approved application for permit to drill the above referenced development well. This permit to drill does not exempt you from obtaining additional permits or approvals required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Please provide at least twenty-four (24) hours notice for a representative of the Commission to witness any required test. Contact the Commission's petroleum field inspector at (907) 659-3607 (pager). BY ORDER OF THE COMMISSION DATED thislL day of October, 2004 ce: Department ofFish & Game, Habitat Section w/o enc!. Department of Environmental Conservation w/o ene!. . Ã(% . STATE OF ALASKA . . ALASKA OIL AND GAS CONSERVATION COMMISSIORECEIVED PERMIT TO DRILL 20 AAC 25.005 OCT 0 82004 1a. Type of Work: Drill 0 RedrillU 1b. Current Well Class: ExploratoryU Alm.cØn.& Ui8~ons. Zone 0 Re-entry 0 Stratigraphic Test D ServiceD Development Amilidrage Single Zone 0 2. Operator Name: 5. Bond: ~ Blanket U Single Well 11. Well Name and Number: ConocoPhillips Alaska, Inc. Bond No. 59-52-180 1 E-168 3. Address: 6. Proposed Depth: 12. Field/Pool(s): P.O. Box 100360 Anchorage, AK 99510-0360 MD: 13521' TVD: 3771' Kuparuk River Field 4a. Location of Well (Govemmental Section): 7. Property Designation: Surface: 207' FNL, 640' FEL, Sec. 21, T11 N, R1OE, UM ALK 25651/25648 West Sak Pool Top of Productive Horizon: 8. Land Use Permit: 13. Approximate Spud Date: 4911' FNL, 1529' FEL, Sec. 15, T11N, R1OE, UM ADL 469/466 10/25/2004 Total Depth: 9. Acres in Property: 14. Distance to 5096' FNL, 1127' FEL, Sec. 10, T11N, R1OE, UM 2560 Nearest Property: 9031' 4b. Location of Well (State Base Plane Coordinates): 10. KB Elevation 15. Distance to Nearest Surface: x- 549890 y- 5959380 Zone- 4 (Height above GL): 28 feet Well within Pool: 1150' @ 1E-114, 16. Deviated wells: 17. Anticipated Pressure (see 20 AAC 25.035) Kickoff depth: 300 ft. Maximum Hole Angle: 92.7° Max. Downhole Pressure: 1546 psig I Max. Surface Pressure: 1141 psig 18. Casing Program Setting Depth Quantity of Cement Size SDecifications Top Bottom c. f. or sacks Hole Casing Weight Grade Coupling Length MD TVD MD TVD (including stage data) 42" 20"x34" 94# K-55 Welded 80' 28' 28' 108' 108' 260 cf ArcticCrete 13.5" 10.75" 45.5# L-80 BTC 4422' 28' 28' 4450' 2459' 710 sx AS Lite, 205 sx DeepCrete 9-7/8" 7-5/8" 29.7# L-80 BTCM 8381' 28' 28' 8409' 3702' 510 sx DeepCrete 6.75" 4.5" 12.6# L-80 DWC 6051' 7470' 3535' 13521 ' 3771' slotted liner 19 PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re-Entry Operations) Total Depth MD (It): Total Depth TVD (It): Plugs (measured) Effective Depth MD (ft): Effective Depth TVD (ft): Junk (measured) Casing Length Size Cement Volume MD TVD Structural Conductor Surface Intermediate Production Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): 20. Attachments: Filing Fee 0 BOP SketchW Drilling Program ~ Time v. Depth Plot W Shallow Hazard Analysis Q Property Plat D Diverter Sketch D Seabed Report D Drilling Fluid Program 0 20 AAC 25.050 requirements 0 21. Verbal Approval: Commission Representative: Date: 22. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Steve Shultz @ 263-4620 Printed Name Randy Thomas Title Kuparuk Drilling Team Leader Signature ?euJl.. Yl1~~... .J.. \ Phone Date IOI/Jr/1J:;>c>4 PreDared bv Sh"rnn AI _n~ . , Commission Use Only Permit to Drill API Number: Permit Approval See cover letter Number: ;)..04- dOO 50- 0 ð-C\- d ~ if- 30-a () Date: IO~lloc.¡ for other requirements Conditions of approval : Samples required D Yes ~o Mud log required DYes g No nen sulfide measures D Yes ~o Directional survey required ~Yes 0 No ~ \'-\ Ð~'í> Other: {í; ~~' ~,,-\-<>.<> ~ \ù-......£ð. \<jj~ ·~S \-\ " ~ ~C~\ /ð¡;llðcf App~,db. ~ BY ORDER OF ~ COMMISSIONER THE COMMISSION Date: V ~ - , , , Form 10-401 Revised 3/2003 . ORIGINAL Submit in duplicate .- ConocoPhillips Alaska . Post Office Box 100360 Anchorage, Alaska 99510-0360 Randy Thomas Phone (907) 265-6830 Email: Randy.L.Thomas@conocophillips.com RECEIVED OCT 0 5 Z004 October 1, 2004 Alaska Oil & Gas Cons.. Commi$sioll Anchorage Alaska Oil and Gas Conservation Commission 333 West ih Avenue Suite 100 Anchorage, Alaska 99501 Re: Applications for Permit to Drill, West Sak Producer, 1E-168, 1E-168 L1 and 1E-168 L2 Dear Commissioners: ConocoPhillips Alaska, Inc. hereby applies for Permits to Drill for an onshore production well, a multilateral horizontal well in the West Sak "A", "8" and "D" sands. The main bore of the well will be designated 1E-168, and the lateral bore of the well will be designated 1E-168L1 ("8" Sand) and 1E-168L2 ../ CD" Sand) Please find attached for the review of the Commission a Form 10-401 and the information required by 20 ACC 25.005 for each of these well bores. The expected spud date of 1E-168 is 10/25/2004. If you have any questions or require any further information, please contact Steve Shultz at 263-4620. Sincerely, ",......"" ~ I.~'~ Randy Thomas Greater Kuparuk Area Drilling Team Leader ORIGINAL · STATE OF ALASKA "~~~t\.RECE'ioo¥ ALASKA OIL AND GAS CONSERVATION COMMISSION 4 PERMIT TO DRILL OCT 0 5'- 20 AAC 25005 AI........ nil it f.jusCons. CommISSion ExploratoryU Development OilB Anthora~ltiPle Zone 0 Service 0 Development Gas 0" Single Zone 0 5. Bond: ~ Blanket TISingleWell 1~.WeIlNameandNumber. Bond No. 59-52-180 / 1E-168 6. Proposed Depth: , / 12. FieJdlPool(s): MD: 13521" TVD: 3771' / Kuparuk River Field 7. Property Designation: /1 ALK 25651/25648 / West Sak Pool 8. Land Use Permit: .. ;1 13. Approximate Spud Date: ADL 469/466 ,// 1 0/25/2004 ~ 9. Acres in Property: // 14. Distance to 25ßù Nearest Property: ___._.__._....1g:'Sê..sl!3,.II.¡¡t,i.9D.,L.....____ 15. Distance to Nearest 4 (Height above GL):l ?8 ---··teet-...... Well within Pool: 1150' @ 1E-114, 17. AnticipaYd Pressure (see 20 AAC :5.035) ________ ./ Max. Do}\'hhole Pressure: 1546 psig I Max. Surface Pre~ 1141 psig -; Setting Depth Quantity of Cemeflt... Topl Bottom c. f. or sacks '\ MD TVD MD TVD (including stage data) 28' i,. 28' / 108' 108' 260 cf ArcticCrete 21:1[ \. I~ 4182' 2295' 718 sx ASLite, 189 sx DeepCr te 28' '\:i }28V 8780' 3733' 508 sx DeepCrete I =.à'NJ0' 3733' 11870' 3808' slotted liner / j\ / PRESENT WELL CONDITION SUMMARY' ( ,(tV (To be completed for Redrill and Re-Entry Operations) , Total Depth TVD (It): Plugs (measu,re~ctive Depth MD (It): Effective Depth TVD (It): Junk (me/d) Length Size r' Cement Volume ~ TVD / (P' ___ / / v / / 1a. Type of Work: Drill [;2] Re-entry 0 2. Operator Name: ConocoPhillips Alaska, Inc. 3. Address: RedrillU 1b. Current Well Class: Stratigraphic Test 0 Filing Fee 0 / BOP SketchU Property Plat 0 /Diverter Sketch 0 21. Verbal Approval: Commission Repre~ntative: 22. I hereby certify that the foreg~ing i rue and correct to the best of my knowledge. Printed Name R dy Thomas Signature \ .. ~ 7 I / I Pennit to Drill., _ ... r I / . API Number: Number: ~f ZCéJ 50- 02- C¡~¿:32-3()-Cú conditiO'7'S of ap oval: Samples required 0 Yes (&lNO Hydrogen sulfide measures 0 Yes 19..NO Other: P.O. Box 100360 Anchorage, AK 99510-0360 4a. Location of Well (Govemmental Section): Surface: 207' FNL, 640' FEL, Sec. 21, T11 N, R10E, UM Top of Productive Horizon: 4911' FNL, 1529' FEL, Sec. 15, T11N, R1OE, UM Total Depth: 5096'FNL,1127'FEL,Sec.10,T11N,R10E,UM 4b. Location of Well (State Base Plane ~o..?~J!l~ Surface: x- 549890:__-""-·""- y- 5959380 .. 16. Deviated w~ Kickoff deptV 300" ft. Maximum Hole Angle: 18. Cafng Program Size H~ Ie Casing Dri en 20" 13 " 9-7 " 6.7! " 10.75" 7-5/8" Weight 94# 45.5# 29.7# 12.6# Soecifications Grade Coupling K-55 Welded L-80 BTC L-80 BTCM L-80 DWC 4.5" 19 Total De th MD (It): Casing ~uctural Co~or Surface Intermediate Production Liner Perforation Depth MD (ft): / 20. Attachments: Approved by: Zone- 92.7° Length 80' 4154' 8752' 3090' Drilling Program 0 Seabed Report 0 9031' - Perforation Depth TVD (ft): Time v. Depth Plot 0 Drilling Fluid Program 0 Date: Shallow Hazard Analysis Q 20 AAC 25.050 requirements 0 Contact Steve Shultz @ 263-4620 Title Kuparuk Drilling Team Leader Phone 7..."5'"6-030 Date \.0(.., (or Prpn"fi .. -. fi nAil - Commission Use Only Pennit Approval Date: See cover letter for other requirements Mud log required Directional survey required o Yes ~ I2Y Yes 0 No No COMMISSIONER BY ORDER OF THE COMMISSION Date: Form 10-401 Revised 3/2003 . ORIGINAL Submit in duplicate .' A.lion for Permit to Drill, Well 1 E-168 Revision No.O October 1, 2004 Permit It - West Sak Well #1 E-168 ("A" Sand) Application for Permit to Drill Document M(lxUnizE We-II ....QIU ~ Table of Contents 1. Well Name .....................................................................................................................2 Requirements of 20 AAC 25.005 (f) ....................................................................................................2 2. Location Summary....................................................................................................... 2 Requirements of 20 AAC 25.005(c)(2) ................................................................................................2 Requirements of 20 AAC 25.050(b) ...... ...... ............. ...... ......... .... ........ ........ ..... ...... ..... ....... ......... ........ 3 3. Blowout Prevention Equipment Information ............................................................3 Requirements of 20 AAC 25. 005(c)(3) ................................................................................................ 3 4. Drilli ng Hazards Information ...................................................................................... 3 Requirements of 20 AAC 25.005 (c)(4) ...............................................................................................3 5. Procedure for Conducting Formation Integrity Tests .............................................3 Requirements of 20 AAC 25.005 (c)(5) ...............................................................................................3 6. 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. Drill i ng Fluid Program................................................................................................. 5 Requirements of 20 AAC 25.005(c)(B) . ........ ........ ............. ....... ...... ....... ....... ..... ...... ...... ........ .............. 5 Lateral Mud Program (MI FloPro NT) ..................................................................................................5 9. Abnormally Pressured Formation Information ........................................................ 5 Requirements of 20 AAC 25.005 (c)(9) ...............................................................................................5 10. Seismic Analysis.......................................................................................................... 5 Requirements of 20 AAC 25.005 (c)(10) ............................................................................................. 5 11. Seabed Condition Analysis .............. ........................ .................................................. 5 Requirements of 20 AAC 25.005 (c)(11) ............................................................................................. 5 12. Evidence of Bonding ................................................. ..................................... ............. 6 Requirements of 20 AAC 25.005 (c)(12) ............................................................................................. 6 ORIGINAL PERMIT IT (Producer) RevO.doc Page 1 of 8 Printed: October 1,2004 · A.tion for Permit to Drill, Well 1 E-168 Revision No.O October 1, 2004 13. Proposed Drilling 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 .. ....... ..... ....... ........ .... ........ ....... ...... ........ ...... ..... ...... ........ .... ......... ........ 8 Attachment 2 Drilling Hazards Summary....... ........ ...... ....... ............ ....... ........ ..... ....... ...... ..... ......... ...... 8 Attachment 3 Cementng Data ....... ...... ...... ........ ..... ........ ...... ....... ...... ....... ............ ...... ....... ..... ........ ..... 8 Attachment 4 Well Schematic ........ ..... ....... ....... ..... ....... ........ .... ......... ...... ...... .............. .... ......... ......... 8 1. Well Name Requirements of 20 AAC 25.005 (f) Each well must be identified by a unique name designated by the operator and a unique API number assigned by the commission under 20 AAC 25.040(b). For a well with multiple well branches, each branch must similarly be identified by a unique name and API number by adding a suffix to the name designated for the well by the operator and to the number assigned to the well by the commission. The well for which this Application is submitted will be designated as 1E-168. 2. Location Summary Requirements of 20 AAC 25.005(c)(2) An application for a Permit to Drill must be accompanied by each of the following item~ except for an item already on file with the commission and identified in the application: (2) a plat identifying the property and the property's owners and showing (A)the coordinates of the proposed location of the well at the surface, at the top of each objective formation, and at total depth, referenced to governmental section lines. (8) the coordinates of the proposed location of the well at the surface, referenced to the state plane coordinate system for this state as maintained by the National Geodetic Survey in the National Oceanic and Atmospheric Administration; (C) the proposed depth of the well at the top of each objective formation and at total depth; Location at Surface ASP Zone 4 NAD 27 Coordinates Northings: 5,959,380' Eastings: 549,890 ; I FNL:207', FEL:640', See 21, T11N/R10E, UM I RKB Elevation I I Pad Elevation I 98.4' AMSL 70.4' AMSL / Location at Top of Productive Interval FNL:4911', FEL:1529, See 15, T11N/RIOE, UM (VVestSak~A"Sand) ASP Zone 4 NAD 27 Coordinates Measured Depth, RKB: 7470' Northings:5,959,986 Eastings: 554,275 Total Vertical Depth, RKB: 3535' Total Vertical Depth, 55: 3610.0' Location at Total Depth I FNL:5096', FEL: 1127', See 10, TUN/R10E, UM ASP Zone 4 NAD 27 Coordinates Measured Depth, RKB: 13521' ; Northings:5,965,083 Eastings: 554,632 Total Vertical Depth, RKB: 3771' Total Vertical Depth, 55: 3673.0' and (D) other information required by 20 MC 25.050(b); ORIGINAL PERMIT IT (Producer) RevO.doc Page 2 of 8 Printed: October 1, 2004 · A.tion for Permit to Drill, Well 1 E-168 Revision No.O October 1, 2004 Requirements of 20 AAC 25.050(b) If a well is to be intentionally deviatefi the application for a Permit to Drill (Form 10-401) must (1) include a plat, drawn to a suitable scale, showing the path ofthe proposed wellbore, including all 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 wells, to the extent that those names are known or discoverable in public records, and show that each named operator has been furnished a copy of the application by certified mail,' or (B) state that the applicant is the only affected owner. The Applicant is the only affected owner. 3. Blowout Prevention Equipment Information Requirements of 20 AAC 25.005(c)(3) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (3) a diagram and description ofthe blowout prevention equipment (BOPE) as required by 20 MC 25.035, 20 AAC 25.03~ or 20 MC 25.037, as applicable; An API 13-5/8" x 5,000 psi BOP stack (RSRRA) will be utilized to drill and complete welllE-168. Please see information on Doyon 141 blowout prevention equipment placed on file with the Commission. 4. Drilling Hazards Information Requirements of 20 AAC 25.005 (c)(4) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (4) information on drilling hazards, including (A) the maximum downhole pressure that may be encounterefi criteria used to determine it, and maximum potential surface pressure based on a methane gradient,· The expected reservoir pressures in the West Sak sands in the 1E-168 area vary from 0.46 to 0.44 psi/ft, ./ or 8.8 to 8.5 ppg EMW (equivalent mud weight). These pressures are predicted based on actual bottom hole pressure data from the nearby West Sak wells. The maximum potential surface pressure (MPSP) based on the above maximum pressure gradient, a methane gradient (0.11) and the deepest planned vertical depth of the West Sak B sand formation is 1141.336 psi, calculated thusly: MPSP =(3514.4 ft)(0.44 - 0.11 psi/ft) = 1141.336 psi ,/ Since the estimated pore pressure is well below the rating of a 3,000 psi BOPE system, we would like to request permission to operate our 5,000 psi system as a 3,000 psi system which would allow us to maintain a set of casing rams in the second pipe ram cavity and also permit us to test to only 3500 psi. (8) data on potential gas zones; The well bore is not expected to penetrate any gas zones. / and (C) data concerning potential causes of hole problems such as abnormally geo-pressured strata, lost circulation zones, and zones that have a propensity for differential sticking; Please see Attachment 2: Drilling Hazards Summary. 5. Procedure for Conducting Formation Integrity Tests Requirements of 20 AAC 25.005 (c)(5) An applícation for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: ORIGINAL PERMIT IT (Injector) RevO.doc Page 3 of 8 Printed: October 1, 2004 · Aation for Permit to Drill, Well 1 E-168 Revision No.O October 1 , 2004 (5) a description of the procedure for conducting formation integrity test~ as required under 20 MC 25. 030(fl' The parent wellbore,lE-168, will be completed with 75/8" intermediate casing landed in the West Sak A- Sand. The casing shoe will be drilled out and a formation integrity test will be performed in accordance with the "Formation Integrity Test Procedure" that ConocoPhillips Alaska placed on file with the Commission. 6. Casing and Cementing Program Requirements of 20 AAC 25.005(c)(6) An application for a Permit to Drill must be accompanied by each of the following item~ except for an item already on file with the commission and identified in the application: (6) a complete proposed casing and cementing program as required by 20 MC 25.030, and a description of any slotted liner, pre- perforated liner, or screen to be installed/ Casing and Cementing Program See also Attachment 3, APO for 1E-168: Cement Summa/) Hole Top Btm Csg/Tbg Size Weight Length MO/TVO MO/TVO 00 (in) (in) (Iblft) Grade Connection (fl) (ft> (ft> Cement Program 20 X 34 42 94 K55 Welded 80 28 / 28 108 / 108 Cemented to surface with 260 cf ArcticCRETE 10 3/4 13 1/2 45.5 L-80 BTC 4422 28 / 28 4450 /2459 Cemented to Surface with 710 sx AS Lite Lead, 205 sx OeepCRETE Tail 7 5/8 97/8 29.7 L-80 BTCM 8381 28 / 28 8409 / 3702 Cement Top planned @ 4786' MO / 2595' TVO. Cemented w/ 510 sx OeeoCRETE 41/2 63/4" 12.6 L-80 OWC 6051 7470/3535 13521/3771 Slotted- no slotted "A" Lateral cement (lE-168) 41/2 63/4" 12.6 L-80 OWC 4689 7326/3514 12015/3560 Slotted- no slotted "B" Lateral cement ( 1E-168 L1) 41/2 6 3/4 12.6 L-80 OWC 5001 7008/3442 12009/3500 Slotted-no slotted "0" Lateral cement (1E-168 L2) 7. Diverter System Information Requirements of 20 AAC 25.005(c)(7) An application for a Permit to Drill must be accompanied by each of the following item~ 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 MC 25. 035, unless this requirement is waived by the commission under 20 MC 25. 035(h)(2l' ORIGINAL PERMIT IT (Producer) RevO.doc Page 4 of 8 Printed: October 1,2004 · A.tion for Permit to Drill, Well 1 E-168 Revision No.O October 1, 2004 A 21-1/4",2000 psi annular with a 16" diameter diverter line will be the diverter system used in the drilling of 1E-126. Please see diagrams of the Doyon 141 diverter system on file with the Commission. Drilling Fluid Program Requirements of 20 AAC 25.005(c)(8) 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: (8) a drilling fluid program, including a diagram and description of the drilling fluid system, as required by 20 MC 25.033; Drilling will be done with mud having the following properties over the listed intervals: Lateral Mud Program (VersaPro, Oil Base Mud) Properties Surface Intermediate Production Density (ppg) 8.6-9.0 9 9.1 Funnel 150-300 45-55 30 Viscosity (seconds) Yield Point 30-70 26-30 18-28 (cP) Electric Stability NA NA 650-900 Chlorides (mg/I) <500 <500 40000 pH 8.5-9.0 9.0 N/A API filtrate <6 <6 <4 (cc / 30 min) **HTHP filtrate <10 <10 <10 (cc /30 min) MBT (/b / gal) NA NA / Drilling fluid practices will be in accordance with appropriate regulations stated in 20 AAC 25.033. Please see information on file with the Commission for diagrams and descriptions of the fluid system of Doyon 141 Abnormally Pressured Formation Information Requirements of 20 AAC 25.005 (c)(9) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (9) for an exploratory or stratigraphic test well, a tabulation setting out the depths of predicted abnormally geo-pressured strata as required by 20 MC 25.033(f); Not applicable: Application is not for an exploratory or stratigraphic test well. 8. Seismic Analysis Requirements of 20 AAC 25.005 (c)(10) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (10) for an exploratory or stratigraphic test well, a seismic retradion or reflection analysis as required by 20 AAC 25.061(a); ( Not applicable: Application is not for an exploratory or stratigraphic test well. / 9. Seabed Condition Analysis Requirements of 20 AAC 25.005 (c)(11) An application for a Permit to Drill must be accompanied by each of the following item~ except for an item already on file with the commission and identified in the application: (11) for a well drilled from an offshore platform, mobile bottom-founded structure, jack-up rig, or floating drilling vessel, an analysis of seabed conditions as required by 20 AAC 25.061(b); Not applicable: Application is not for an offshore well. / PERMIT IT (Producer) RevO.doc Page 5 of 8 Printed: October 1, 2004 ORIGINAL · Aation for Permit to Drill, Well 1 E-168 Revision No.O October 1, 2004 10. Evidence of Bonding Requirements of 20 AAC 25.005 (c)(12) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (12) evidence showing that the requirements of 20 AAC 25.025 {Bonding}have been met; Evidence of bonding for Phillips Alaska, Inc. is on file with the Commission. 11. Proposed Drilling Program Requirements of 20 AAC 25.005 (c)(13) An application for a Permit to Drill must be accompanied by each of the following Items, except for an item already on file with the commission and identilied in the application: The proposed drilling program for lE-168 is listed below. Note: Previous operations are covered under the lE-168 Application for Permit to Drill 1. Excavate cellar, install cellar box, set and cement 20" x 34" insulated conductor to +1- 108' RKB. Install landing ring on conductor. 2. Move in 1 rig up Doyon 141. Install 21-1/4" Annular with 16" diverter line and function test. 3. Spud and directionally drill 13 1/2" hole to casing point at +1- 4450' MD 1 2459' ND as per directional plan. Run MWD tools as required for directional monitoring. 4. Run and cement 103/4",45.5#, L-80, BTC casing to surface. Displace cement with mud and, pressure test casing to 2500 psi for 30 minutes and record results. Perform top job if required. 5. Remove diverter system, install and test 13-5/8" x 5,000 psi BOP's and test to 5000 psi (annular preventer to 3500 psi) Notify AOGCC 24 hrs before test. ,/ 6. PU 9 7/8" bit and drilling assembly, with MWD, LWD & PWD. RIH, clean out cement to top of float equipment. Re-test casing if cement is tagged more than 100 feet above the float collar. 7. Drill out cement and between 20' and 50' of new hole. Perform formation integrity test to leak off, recording results. 8. Directionally drill to 7 5/8" casing point at 8409 MD 1 3702'ND. 9. Run 7 5/8"¡ 29.7# L-80¡ BTCM Mod casing to surface. Pump cement and displace with mud and pressure test casing to 3¡000 psi for 30 minutes and record results. 10. Install wellhead 7 5/8" packoff and test to 5000 psi. 11. Flush 103/4" x 7 5/8" annulus with water¡ followed by diesel. / 12. PU 6 3/4" Bit and drilling assembly, with MWD¡ and LWD logging tools. RIH¡ clean out cement to top of float equipment. Re-test casing if cement is tagged more than 100 feet above the float collar 13. Drill out cement and between 20' and 50' of new hole. Displace hole to lateral drilling mud. Perform formation integrity test to leak off, recording results. 14. Directionally drill 63/4" hole to TD at +1- 13521' MD 1 3771'ND as per directional plan. 15. POOH¡ back reaming out of lateral. POOH. 16. PU and run 4 1/2" slotted liner. 17. Land liner, set liner hanger. Displace liner annulus and liner to weighted brine. T~\ ':> ~~~VO'-.J Q. \ . POOH. Note: Remaining operations are covered under the lE-168L1 Application for Permit to Drill, and are provided here for information only. 18. Run and set Baker WindowMaster whipstock system¡ at window point of 7326' MD 1 3514'ND, the top of the B sand. ORIGINAL PERMIT IT (Producer) RevO.doc Page 6 of 8 Printed: October 1,2004 · Aetion for Permit to Drill, We1l1E-168 Revision No.O October 1, 2004 19. Mill 63/4" window. POOH. 20. Pick up drilling assembly with LWD and MWD and PWD. RIH. 21. Displace to new drilling mud at ppg. Drill to TD of B sand lateral at 12015' MD / 3560' lVD, as per directional plan. 22. POOH, back reaming out of lateral. POOH. 23. RIH with whipstock retrieval tool. Retrieve whipstock and POOH. 24. PU and run 4 1/2" slotted liner. 25. RIH, until liner hanger is just above window. Orient hanger to window and land hanger. 26. Release hanger running tool, POOH. 27. PU Lateral Entry Module "LEM", RIH and latch unit into hook hanger, shear off POOH Note: Remaining operations are covered under the 1E-168L2 Application for Permit to Drill, and are provided here for information only. 28. Run and set Baker WindowMaster whipstock system, at window point of 7008' MD / 3442' lVD, the top of the D sand. 29. Mill 63/4" window. POOH. 30. Pick up drilling assembly with LWD and MWD and PWD. RIH. 31. Drill to TD of D sand lateral at 12009' MD /3500' lVD, as per directional plan. 32. POOH, back reaming out of lateral. POOH. 33. RIH with whipstock retrieval tool. Retrieve whipstock and POOH. 34. PU and run 4 1/2" slotted liner. 35. RIH, until liner hanger is just above window. Orient hanger to window and land hanger. 36. Release hanger running tool, POOH. 37. Make up ESP drive section (motor only, no pump), other completion equipment and tubing as required and RIH to depth. Land tubing, Set BPV. 38. Nipple down BOPE, nipple up tree and test. 39. Pull BPV and move rig off. 40. Freeze protect well with diesel by pumping into 4 1/2"" X 7 5/8" annulus, taking returns from tubing and allowing to equalize. 41. Rig up wire line unit. 42. Set gas lift valves in mandrels. Operate well on gas lift for +/- 180 days. 43. Replace gas lift valves with blank dummy valves. 44. Run ESP through tubing. 45. Operate well with ESP 12. Discussion of Mud and Cuttings Disposal and Annular Disposal Requirements of 20 AAC 25.005 (c)(14) An application for a Permit to Drill mustc be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (14) a general description of how the operator plans to dispose of drilling mud and cuttings and a statement of whether the operator intends to request authorization under 20 AAC 25. 080 for an annular disposal operation in the well.; ORIGINAL PERMIT IT (Producer) RevO.doc Page 7 of 8 Printed: October 1,2004 · A.tion for Permit to Drill, Well 1 E-168 Revision No.O October 1, 2004 Waste fluids generated during the drilling process will be disposed of either by pumping authorized fluids into a permitted annulus on lE Pad, or by hauling the fluids to a KRU Class II disposal well. All cuttings generated will be disposed of either down a permitted annulus on lE Pad, hauled to the Prudhoe Bay Grind and Inject Facility for temporary storage and eventual processing for injection down an approved disposal well, or stored, tested for hazardous substances, and (if free of hazardous substances) used on pads and roads in the Kuparuk area in accordance with a permit from the State of Alaska. 13.Attachments Attachment 1 Directional Plan Attachment 2 Drilling Hazards Summary Attachment 3 Cementing Data Attachment 4 Well Schematic ORIGINAL PERMIT IT (Producer) RevO.doc Page 8 of 8 Printed: October 1, 2004 · . lE-168 Drilling Hazards Summarï 131/2" Open Hole /103/4" Casing Interval Hazard Risk Level Mitigation Strategy Broach of Conductor Low Monitor cellar continuously during interval. Gas Hydrates Low Control drill, Reduced pump rates, Reduced / drilling fluid temperatures, Additions of Driltreat. Running Sands and Moderate Maintain planned mud parameters, Gravels Increase mud weight, use weighted sweeps. Hole swabbing on trips Moderate Trip speeds, Proper hole filling (use of trip sheets), pumping out 9 7/8" Open Hole / 7 5/8" Casing Interval Hazard Running Sands and Gravels Risk Level Moderate Stuck Pipe Low Abnormal Reservoir Pressure Lost circulation Hole swabbing on trips Low Low Moderate ../ Miti ation Strate Maintain planned mud parameters, Increase mud weight, use weighted swee s. Good hole cleaning, Pretreatment with Lost Circulation Material, stabilized BHA, Decreased mud wei ht BOP training and drills, increased mud wei ht. Reduced um rates, mud rheolo , LCM Trip speeds, Proper hole filling (use of trip sheets um in out 63/4" Open Hole / 4 1/2" Liner Interval Hazard Abnormal Reservoir Pressure Stuck Pipe Risk Level Low Low Lost Circulation Hole Swabbing on Trips Moderate Low J Miti ation Strate Stripping drills, Shut-in drills, Increased mud wei ht. Good hole cleaning, PWD Tools, Hole o ener Decreased mud wei ht Reduced um rates, Mud rheolo LCM Trip speeds, Proper hole filling (use of trip sheets , Pum in out ORfGINAL 1E-168 Drí/ling Hazards Summary prepared by Steve Shultz 9/1/2004 4:27 PM Tie-In 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 19 20 21 22 23 24 25 26 27 28 29 30 31 32 33 34 35 36 37 38 39 40 41 42 43 44 45 46 47 48 49 50 51 52 53 54 55 64.79 256Q.62 552730.37 1936.718 56 63.99 2603.87 552816.83 1962.718 57 63.41 2648.20 552904.82 1980.218 58 63.04 2693.27 552993.65 1989.068 59 62.90 2738.75 553082.67 1989.208 60 62.97 2784.28 553171.18 1980.638 61 63.22 2823.40 553246.74 1966.268 62 63.27 2829.52 553258.53 1963.428 63 63.79 2874.13 553344.03 1937.698 64 64.51 2917.76 553427.05 1903.658 65 65.44 2960.08 553506.95 1861.548 66 66.56 3000.77 553583.12 1811.708 67 67.86 3039. 553654.98 1754.508 68 68.20 3048.47 553671 .45 1739.798 69 68.20 3061 .40 553695.25 1718.078 70 68.20 3068.11 553707.59 1706.818 71 68.20 3076.73 553723.46 1692.328 72 68.20 3113.88 553791.81 1629.948 73 68.20 3116.40 553796.46 1625.708 74 68.20 3142.39 553844. 1582.058 75 68.24 3151.01 553860.00 1567.388 76 68.52 3187.88 553923.92 1500.37S 77 68.97 3224.16 553981.41 1427.468 78 69.59 3259.56 554032.03 1349.208 79 70.28 3290.40 554071.33 1274.828 80 70.37 3293.82 554075.40 1266.19S 81 71.29 3326.68 554111.18 1179.068 82 72.36 3357.88 554139.11 1088.478 83 73.57 3387.19 554158.96 995.128 84 74.89 3414.39 554170.60 .718 85 75.00 3416.52 554171.19 891.838 86 75.00 3440.28 554177.44 803.418 87 75.00 3442.40 554178.00 795.538 88 75.00 3466.17 554184.25 707.118 89 75.00 3471.91 554185.77 685.748 90 76.52 3484.40 554189.24 .658 91 78.00 3495.25 554192.62 .818 92 80.00 3508.00 554197.25 .428 93 80.00 3509. 554198.01 512.628 94 80.00 3514. 554199.81 487.238 95 80.00 3527 554204.96 414.438 96 80.00 3544. 554211.90 316.248 97 80.00 3562.01 554218.85 218.058 98 80.00 3569.40 554221.81 176.24S 99 80.00 3579.37 554225.79 119.878 100 80.00 3596.73 554232.74 21.688 101 80.00 3614.10 554239.69 76.51 N 102 80. 3631.46 554246.63 174.69N 103 80. 3632.40 554247.01 179.99N 104 80. 3648.83 554253.58 272.88N 105 80.00 3666.19 554260.52 371.07N 106 80.00 3683.56 554267.47 469.26N 107 80.00 3699.06 554273.67 556.91 N 108 80.43 3700.88 554274.41 567.45N 109 80.80 3702.40 554275.06 576.60N 110 84.43 3714.06 554281.40 666.26N 111 88.43 3720.28 554288.44 765.75N 112 92.43 3719.53 554295.49 865.43N 113 92.73 3719.2 554296.02 .92N 114 92.73 3714.79 554302.54 965.02N 115 92.73 3710.03 554309.59 1064.61N 116 92.73 3708.40 554312.00 1098.72N 117 90.76 3706.4 554316.63 1164.24N 118 89.49 3706.31 554319.61 1206.34N 119 89.49 3706.83 554323,68 1263.94N 120 89.49 3707.72 554330.73 1363.64N 121 89.49 3708.61 554337.78 1463.33N 122 89.49 3709.50 554344.82 1563,03N 123 89. 3710.40 554351.87 1662.73N 124 89.49 371129 554358.92 1762.43N 125 89.49 3712.18 554365,97 1862,13N 126 89.49 3713.07 554373,01 1961.83N 127 89.49 3713.96 554380.06 2061.52N 128 89.49 3714, 554387.11 216122N 129 89.49 3715.75 554394.15 60.92N 130 89.49 3716,64 55440120 62N 131 89.49 3717.53 554408.25 ,32N 132 89.49 3718.42 55441529 .02N 133 89.49 3719,32 554422.34 2659.72N 134 89.49 3720.21 554429,39 2759.41N 135 89.49 3721.10 554436.44 2859,11N 136 89.49 3721.99 554443.48 2958.81 N 137 89.49 3722.88 554450.53 3058.51 N 138 89.49 3723.78 554457.58 3158.21N 139 89.49 3724.67 554464.62 3257,91N 140 89.49 372556 554471.67 ,60N 141 89.49 3726.45 554478.72 3457.30N 142 89.49 3721.34 554485.77 3557.00N 143 89.49 3728.24 554492.81 3656.70N 144 89.49 3729.13 554499.86 3756.40N 145 89.49 3729.40 554502.00 3786.67N 146 88.72 3729.80 554503.79 3812,36N 147 88.72 3730.78 554506.81 09N 148 88.72 3733, 554513.68 3955.78N 149 88.72 3735.2 554520.55 4055.47N 150 88.72 3737.47 554527.43 4155.16N 151 88.72 373~no 554534.30 4254.85N 152 88.72 3741.93 554541.17 4354.54N 153 88.72 3744.16 554548.05 445423N 154 88.72 3746.39 554554.92 4553.93N 155 88.72 3748.62 554561 ,79 4653.62N 156 88.72 3750.85 554568.67 4753.31N 157 88.72 3753.08 55457554 .OON 158 88.72 3755.31 554582.41 .69N 159 88.72 3757.54 554589 5052.38N 160 88.72 3759.77 554596,16 5152.07N 161 88.72 3762.00 554603,03 525U6N 162 88.72 3764.23 554609,90 5351.45N 163 88.72 3766.46 554616.78 5451.14N 164 88.72 3768.69 554623,65 5550.83N 165 88.72 3770,92 554630,52 5650.52N 166 88.72 3771.40 554632.00 5671.95N 167 ~aker Hughes Incorporatl Anticollision Report GLOBAL SCAN APPLIED: All wellpaths within 200'+ 100/1000 of reference Interpolation Method: MD Interval: 25.00 ft Depth Range: 0.00 to 13521.48 ft Maximum Radius: 5280.00 ft Reference: Error Model: Scan Method: Error Surface: Principal Plan & PLANNED PROGRAM ISCWSA Ellipse Trav Cylinder North Ellipse + Casing Survey Program for Definitive Well path Date: 12/10/2003 Validated: No Planned From To Survey ft ft 0.00 800.00 Planned: 1E-168 Vers#2 V14 800.00 13521.50 Planned: 1E-168 Vers#2 V14 Version: 4 Toolcode Tool Name CB SS GYRO MWD+SAG Camera Based Single Shot Gyro MWD + Sag correction Casing Points Pad 10 103 10-103 V1 13514.52 8350.00 1250.46 457.19 793.27 Pass: Major Risk Pad 1 E 104 104 VO Plan: 1E-'104 VE 11910.21 6925.00 919.75 393.14 526.61 Pass: Major Risk Pad 1 E 105 1 E-1 05 Plan V1 Plan: 1 374.86 375.00 729.05 7.58 721.48 Pass: Major Risk Pad 1 E 105 1E-105L1 Plan V1, Plan: 374.86 375.00 729.05 7.47 721.59 Pass: Major Risk Pad 1 E 105 1E-105L2 Plan VO Plan: 374.86 375.00 729.05 7.47 721.59 Pass: Major Risk Pad 1 E 112 1E-112V6 5941.50 6250.00 461.22 133.04 328.18 Pass: Major Risk Pad 1 E 112 1E-112L1 V3 5844.87 6375.00 473.91 154.30 319.62 Pass: Major Risk Pad 1 E 112 1E-112L2 V2 5758.16 6475.00 439.25 174.68 264.57 Pass: Major Risk Pad 1 E 112 1 E-112PB1 V1 5941.50 6250.00 461.22 133.01 328.21 Pass: Major Risk Pad 1 E 114 1 E-114 Vers#2 VB Plan: 464.31 450.00 511.39 10.65 500.74 Pass: Major Risk Pad 1 E 117 117 A2-Lateral VO Plan 1711.38 1600.00 107.87 39.06 68.81 Pass: Major Risk Pad 1 E 117 117 B-Lateral VO Plan: 1711.38 1600.00 107.87 39.06 68.81 Pass: Major Risk Pad 1 E 117 117 D-Lateral VO Plan: 1711.38 1600.00 107.87 39.06 68.81 Pass: Major Risk Pad 1 E 119 119 VO Plan: 1E-119 Ve 1647.66 1575.00 77.86 47.99 29.87 Pass: Major Risk Pad 1 E 121 121 B-Lateral VO ,:>Ian: 13519.78 7650.00 1553.13 510.93 1042.20 Pass: Major Risk Pad 1 E 121 121 D-Lateral VO Plan: 13499.38 7625.00 1558.15 494.82 1063.33 Pass: Major Risk Pad 1 E 123 1E-123L1V2 12579.66 7825.00 231.47 153.86 77.61 Pass: Major Risk Pad 1 E 123 1E-123V18 12850.26 8100.00 185.72 171.54 14.18 Pass: Major Risk Pad 1 E 123 1 E-123PB1 V1 12850.26 8100.00 185.72 171.56 14.15 Pass: Major Risk Pad 1 E 126 1E-126 V5 6865.28 6600.00 243.43 199.08 44.35 Pass: Major Risk Pad 1 E 126 1E-126L1 V2 6865.28 6600.00 243.43 199.08 44.35 Pass: Major Risk Pad 1 E 126 1E-126L2 V3 6865.28 6600.00 243.43 199.08 44.35 Pass: Major Risk Pad 1 E 166 1 E-166 V14 570.32 575.00 58.21 12.68 45.52 Pass: Major Risk Pad 1 E 166 1E-166L1 V8 570.32 575.00 58.21 12.68 45.52 Pass: Major Risk Pad 1 E 166 1E-166L 1PB1 V1 570.32 575.00 58.21 12.68 45.52 Pass: Major Risk Pad 1 E 166 1E-166L2 V6 570.32 575.00 58.21 12.68 45.52 Pass: Major Risk Pad 1 E 168 1 E-168L 1 Ver#2 V2 Plan 25.00 25.00 0.06 1.29 -1.23 FAIL: Major Risk Pad 1 E 168 1 E-168L2 Ver#2 V2 Plan 25.00 25.00 0.06 1.28 -1.22 FAIL: Major Risk Pad 1 E 170 170 A2-Lateral VO Plan 299.99 300.00 40.62 5.67 34.95 Pass: Major Risk Pad 1 E 170 170 B-Lateral VO Plan: 299.99 300.00 40.62 5.67 34.95 Pass: Major Risk Pad 1 E 170 170 D-Lateral VO ,:>Ian: 299.99 300.00 40.62 5.67 34.95 Pass: Major Risk Pad 1 E 20 1 E-20 VO 691.07 700.00 746.00 13.63 732.37 Pass: Major Risk Pad 1 E 22 1 E-22 VO 1467.40 1450.00 669.72 42.82 626.90 Pass: Major Risk Pad 1 E 26 1 E-26 VO 1425.56 1500.00 288.40 33.81 254.59 Pass: Major Risk Pad 1 E 26 1 E-26A VO 1425.56 1500.00 288.40 33.81 254.59 Pass: Major Risk Pad 1 E 27 1 E-27 VO 778.91 775.00 84.66 15.58 69.08 Pass: Major Risk Pad 1 E 28 1 E-28 VO 349.70 350.00 21.11 6.55 14.56 Pass: Major Risk Pad 1 E 29 1 E-29 VO 371.84 375.00 140.62 7.02 133.59 Pass: Major Risk Pad 1 E 3 1 E-03 V1 363.28 375.00 621.36 6.85 614.52 Pass: Major Risk Pad 1 E 33 1 E-33 VO 810.38 775.00 524.18 17.49 506.70 Pass: Major Risk Pad 1 E 33 1E-33PB1 VO 810.38 775.00 524.18 17.49 506.70 Pass: Major Risk Pad 1 E 35 1 E-35 V1 1118.68 1200.00 144.83 22.36 122.46 Pass: Major Risk ORIGINAL tkaker Hughes Incorporatl Anticollision Report ORIGINAL . . ~ill¡ps ConocoPhillips Alaska, Inc.,Slot #168 Pad 1 E, Kuparuk River Unit,North Slope, Alaska PROPOSAL LISTING Page 1 Well bore: 168 Well path: 168 Ver#2 Date Printed: 29-Sep-2004 .1. ... INTEQ 487754.6208 All data is in Feet unless otherwise stated Coordinates are from Slot MO's are from Rig and TVO's are from Rig ( Datum #1 98.4ft above mean sea level) Vertical Section is from O.OON O.OOE on azimuth 4.43 degrees Bottom hole distance is 7417.66 Feet on azimuth 40.12 degrees from Wellhead Calculation method uses Minimum Curvature method Prepared by Baker Hughes Incorporated ORIGINAL . . ~ill¡ps ConocoPhillips Alaska, Inc.,Slot #168 Pad 1 E, Kuparuk River Unit, North Slope, Alaska PROPOSAL LISTING Page 2 Wellbore: 168 Wellpath: 168 Ver#2 Date Printed: 29-Sep-2004 INTEQ ..-.... .- ..... . ...... .. .....> It. .... ...... ..... .... .. ........ ..... ....... IMD[ftl. IÅzìr <iéar. TVD(ft¡ Eå$t[ftl l$t.åtiôn· . r~ta#QIJ. Vertitål. ..........,~, ........ .... ...... ...... '.. 7~""" » . > ¡"",9' ......... > ...... Ir\Jnrth\ IF::í~t\ 001-...· tf ." ... ... ..... 0.00 0.00 0.00 0.00 -98.40 O.OON O.OOE 5959380.00 549890.00 0.00 0.00 Tie on 100.00 0.00 0.00 100.00 1.60 O.OON O.OOE 5959380.00 549890.00 0.00 0.00 200.00 0.00 0.00 200.00 101.60 O.OON O...oOE 5959380~-ºº- 549890.00 0.00 0.00 300.00 0.00 0.00 300.00 201.60 O.OON O.OOE 5959380.00 549890.00 0.00 000 KOP End of Hold 400.00 3.00 125.00 399.95 30155 1.50S 2.14E 5959378.51 549892.15 3.00 -1.33 500.00 6.00 125.00 499.63 401.23 6.008 8.57E 5959374.06 549898.61 3.00 -532 600.00 9.00 125.00 598.77 500.37 13.498 19.26E 5959366.64 549909.35 3.00 -11.96 633.33 10.00 125.00 631.64 533.24 16.64S 23.77E 5959363.52 549913.88 3.00 -14.76 Build 4/100 End of BuildlTurn 733.33 14.00 125.00 729.44 631.04 28.578 40.80E 5959351.71 549930.98 4.00 -25 33 833.33 18.0_º- ----12!L~ ~.5<1_ c---Z-2.7.15 44.378 63.37E 5959336.05 549953.66 4.00 -:~9.35 883.33 20.00 J25.00 872.82 774.42 53.718 76.70E 5959326.81 54996705 4.00 -47.63 Build 6/100 End of Build --- 983.33 26.00 125.00 964.83 866.43 76.118 108.70E 5959304.62 549999.19 6.00 -67.50 1083.33 32.00 125.00 1052.25 953.85 ~~91S 148.39E 5959277.09 550039.06 6.00 -92.15 .. 1183.33 38.00 125.00 1134.13 1035.73 136.798 195.351;; 5959244.52 550086.24 6.00 -121.31 1283.33 44.00 125.00 1209.56 11.11.16 174.408 249.07E 5959207.27 550140.20 6.0Q_ ~...66 138333 50.00 125.00 1277.73 1179.33 216.33S 308.95E 5959165.75 550200.35 6.00 -191.85 1483.33 56.00 125.00 1337.89 1239.49 262.128 37434E 5959120.40 550266 04 6.00 -232.45 1583.33 62.00 125.00 1389.37 1290.97 311.268 444.53E 5959071.73 550336.54 6.00 -276.04 -~ 1683.33 68.00 125.00 1431.61 1333.21 363.228 518.73E 5959020.27 550411.08 6.00 -322.12 1686.63 68.20 125.00 143284 1334.44 364.988 521.24E 5959018.53 __550413.60 6.00 -323.67 EOC End of Build 1700.00 68.20 125.00 1437.80 1339.40 372.10S 531.41E 5959011.48 550423.81 M-º-- -329.99 1800.00 68.20 125.00 1474.94 1376.54 425.358 607.46E 595895~t 73 550500.21 0.00 -377.21 1895.47 68.20 125.00 1510.40 1412.00 476.198 680.07E 5958908.38 550573.15 0.00 -422.30 Base Permafrost 1900.00 68.20 125.00 1512.08 1413.68 478.618 683.52E 5958905.99 550576.61 0.00 -424.44 2000.00 68.20 -.12Q,QQ 1549.22 1450.82 531.868 759.58E 5958853.25 550653.01 0.00 -471.67 2100.00 68.20 125.00 1586.36 1487.96 58.5.128 835.631;; 5958800.50 550729AL 0.00 -518.90 2200.00 68.20 125.00 1623.50 1525. UL ...§.38.378 r--911.69E 5958747.76 550805.81 0.00 -566.13 2300.00 68.20 125.00 1660.64 1562.24 691.638 987.74E 5958695.02 550882.21 0.00 -613.35 2400.00 68.20 125.00 1697.78 159938 744.888 1063.80E 5958642.27 550958.61 0.00 -660.58 2500.00 68.2_º- -----12.5.00 1734.92 1636.52 798.13S 1139.86E 5958589.53 551035.02 0.00 -- -707.81 2547.05 68.20 125.00 1752.40 1654.00 823.198 1175.64E 5958564.71 551070.96 0.00 -730.03 Top T-3 2600.00 68.20 ----125~-ºº-- e.L772.06 1673.66 851.398 ~.91.E 5958536 79 551111.42 I----Q.OO -755.04 2700.00 68.20 125.00 1809.20 1710.80 904.648 1291.97E 5958484.04_ _.551187.82 0.00 -802.27 1----.-. 2800.00 68.20 125cºº-.. ..1l!~6. 34 1747.94 957.908 1368.02E 5958431.30 -- 551264.22 000 -849.50 2900.00 68.20 125.00 1883.48 1785.08 101116S 1444.08E 5958378.55 551340.62 0.00 -896.72 3000.00 68.20 125.00 1920.62 1822.22 1064.418 1520.14E 5958325.81 551417.02 0.00 -943.95 3100.00 68.20 12500 1957.76 1859.36 1117.67S 1596.19E 5958273.07 551493.42 0.00 -991.18 ~Q.OO 68.20 ~QO 1994.91 1896.50 1170.92S 1672.25E 5958220.32. 551569.82 0.00 -1038.41 3300.00 68.20 125.00 2032.05 1933.64 1224.18S 1748.30E 5958167.58 551646.22 0.00 -1085.64 3392.50 68.20 125.00 2066.40 1968.00 1273.44S 1818.66E 5958118.79 551716.89 0.00 -1129.32 Top K-15 3400.00 68.20 125.00 2069.18 1970.78 1277.43S 1824.36E 5958114.84 551722.62 0.00 -1132.87 3500.00 68.20 125.00 2106.32 2007.92 1330.688 1900.42E 5958062.09 551799.02 0.00 -1180.09 --- 3600.00 68.20 125.00 2143.47 2045.06 1383.948 1976.47E 5958009.35 551875.42 0.00 -122732 3700.00 68.20 125.00 2180.61 2082.20 1437.198 2052.53E 5957956.60 551951.82 000 -1274.55 3800.00 68.20 125.00 2217.74 211 ~..M.... ...1.490.458 2128.58E 5957903.86 552028.22 0.00 -1321.78 --- 3900.00 68.20 125.00 2254.89 2156.48 1543.70S 2204.64E 59578~..1..,j£ _552104.62 0.00 -1369.01 4000.00 68.20 125.00 2292.03 2193.62 1596.968 2280.70E 5957798.37 552181.02 ........QJ1Q. -1416.24 -- 4100.00 68.20 125.00 2329.17 2230.76 1650.21S 235675E 5957745.63 552257.42 0.00 -1463.46 4200.00 68.20 12500 2366.30 2267.90 1703.478 2432.81E 5957692.89 552333.82 000 -1510.69 4300.00 68.20 125.00 2403.45 2305.04 1756.728 2508.86E 5957640.14 552410.22 000 -1557.92 All data is in Feet unless otherwise stated Coordinates are frorn 810t MD's are from Rig and TVD's are from Rig ( Datum #1 98.4ft above mean sea level) Vertical 8ection is from O.OON O.OOE on azimuth 4.43 degrees Bottom hole distance is 7417.66 Feet on azimuth 40.12 degrees from Wellhead Calculation method uses Minimum Curvature method Prepared by Baker Hughes Incorporated ORIGINAL . . -..' ConocoPhillips ConocoPhillips Alaska, Inc.,Slot #168 Pad 1 E, Kuparuk River Unit, North Slope, Alaska PROPOSAL LISTING Page 3 Wel/bore: 168 Wel/path: 168 Ver#2 Date Printed: 29-Sep-2004 INTEQ , .. ... .... ..- ...... ..... .... <. ... .... .. < < .... .... « ............... .... IMDlft] . 'Tvt>[ftl\ rV~rtjç¡¡r····· IËàst{ftl ..... I~tátt~n ISt~ti(¡ri .. ..... -,- -"". .. .< , D··..."· ........ ..... ........... North\ ..... ....... 1¡:::::J~t\ ...... ref t1 ...... ......... < i/ 4400.00 68.20 125.00 2440.59 234218 1809.988 2584.92E ~~7.4Q. ¡---Q52486.62 0.00 -1605.15 . 4407.77 68.20 125.00 2443.47 2345.07 1814.128 2590.83E 5957583.30 552492.56 0.00 -1608.82 Beain Curve 3DX8 Kick off Point 4450.11 67.61 122.80 2459.40 2361.00 1836.008 262339E 5957561.64 552525.26 5.00 -1628.12 10 3/4" Casina Pt. 4500.00 66.96 120.20 2478.67 2380.27 1860.04S 2662 62E 5957537.86 552564.64 5.00 -1649.07 4600.00 65.78 114.89 2518.78 2420.38 1902.408 2743.80E 5957496.04 552646.10 5.00 -1685.04 4700.00 64.79 109.50 2560.62 2462.22 .Jß36. 71 S 2827.8§!; -.Q957462.29 552730.37 500 -1712.76 4800.00 63.99 104.02 2603.87 2505.47 1962.718 29141(iç 29574368Z. r-552816.~ ¡.......5.00 -1732.02 _4.900.00 63.41 98.48 2648.20 2549.80 1980.218 3002.03E 5957419.96 552904.82 500 -174268 5000.00 63.04 92.89 2693.27 2594.87 1989.068 3090.82E 5957411.70 552993.65 5.00 -1744.66 5100.00 62.90 87.28 2738.75 2640.35 1989.208 3179.85E 5957412.1Q 553082.67 5.00 ..:1nL~ _. 5200.00 62.97 81..9L- ..27_84.28 268p~ c-1980.63S 3268.43E 5957421d1.. 553171.18 5.00 -1722.55 5286.40 63.22 76.83 2823.40 2725.00 1966.268 3344.10E 5957436.18 553246.74 5.00 -1702.39 Too Uanu C - 5300.00 63.27 76.07 2829.52 2731.12 1963.428 ~~90E 5957439.10 553258.53 5.00 -169~ 5400.00 63.79 ¡--.70.52 2874.13 2775.73 1937.69S 3441.59E 59574~ 553344.03 5.00 -1666.38 ~O~ºº- 1--_64.51 65.02 2917.76 2819.36 1903.65S 3524.8:4E 5957499.98 553427.05 5.00 -1626.02 5600.00 65.44 59.60 296008 2861.68 1861.54S 3605.03E 5957542.61 553506.95 5.00 -1577.85 5700.00 66.56 54.26 3000.77 2902.37 1811.708 3681.54E 5957592.96 553583.12 5.00 -1522.26 5800.00 67.86 49.03 3039.53 2941.13 1754.508 3753.79E 5957650.63 553654.98 5.-ºº-. .=1459.&1 5823.89 68.20 47.79 3048.47 2950.07 1739798 3770.36E 5957665.45 553671.45 5.00 -1443.71 EOC End of DroDlTurn ~58. 72 68.20 47.79 3061.40 2963.00 1718.07S 3794.30E _.p957687.33 553695.25 0.00 -1420.20 Too Uanu B 5876.77 68.20 47.79 3068.11 2969.71 1706.818 3806.72E 5957698.67 553707.59 0.00 -1408.02 Start 200' PYJDQ Tanaent 5900.00 68.20 47.[~ ~76.73 2978.33 1692.32S 3822.69E 5957713.26 553723.46 0.00 -1392.34 6000.00 68.20 47.79 3113.88 3015.48 1629.948 3891.46E 59.57776. 1 0 ~379181 0.00 -1324.84 6006.80 68.20 47.79 3116.40 3018.00 1625.708 3896.14E 5957780.37 553796.46 0.00 -1320.25 Too Uanu A 6076.77 68.20 47.79 3142.39 3043.99 1582.05S 3944.26E 5957824.33 553844.28 0.00 -1273.01 End 200' Pump Tangent-Begin Curve, . c-. -- ---- End of Hold 6100.00 68.24__ ....4Q,;ï4 3151.01 3052.6.1.. 1567.388 3960.0[E 1--5957839.10 553860.00 5.00 ~1257.17 -~.,--~._" 6200.00 68.52 41.17 3187.88 3089.48 1500378 4024.45E ~57906.53 55392392 5.00 ..:11B5.AQ -- 6300.00 68.97 35.83 3224.16 3125.76 1427.468 4082.43E 595797982 553981.41 5.00 -1108.23 6400.00 69.59 30.52 3259.56 3161.16 c-1349.208 4133.57E 5958058.40 55403203 5.00 -1026.26 6489.85 70.28 25.79 3290.40 3192.00 1274.828 4173.38E 5958133.04 554071.33 5.00 -949.02 K-13 6500.00 70.37 25.26 3293.82 3195.42 1266.198 4177.50E 5958141.,.'ZQ 554075.40 5.00 -9ÆL11. 6600.00 71.29 20.06 3326.68 3228.28 1179.068 4213.86E 5958229.06 554111.18 5.00 -850.43 6700.00 72.36 14.92 3357.88 3259.48 1088.478 4242.40E 595831913.2. ,..._554139.11 5.00 -757.91 -~ _Q800.0.o. 73.57 __It 84 3387.19 ~8.?ß.. ~5.12..s... A2~ 595841 :L:ID.. ¡---554158.96 5.00 -6ß.2Q. \-----.~----~- 6900.00 74.89 4.83 341439 331599 899.71S 4275.15E 5958508.78 554170.60 5.00 -567.18 6908. 19 75.00 4.43 3416.52 3318.12 891838 4275.79E 5958516.66 . 554171.19 5.00 -559.28 EOC. End of BuildlTurn 7000.00 75.00 4.43 3440.28 3341.88 803.418 4282.63E ~5958605.12 55417:zA.4 0.00 -470.59 7008.18 75.00 4.43 3442.40 3344 00 795.538 4283.24E 5958613.00 554178.00 000 -462.69 TopWest8akD, W8 1EC5 D TOP . -- -. j------ ~D090204. End of Hold 7100.00 75.00 4.43 3466 17 3367. 76 707.11S 4290.08E 5958701.46 554184.25 0.00 -374.00 -L122~W. ¡--l5.00 4.43 3471.91 3373.51 685.74S 4291.73E 5958722.83 554185.77 0.00 -352.5.8 Build 3/100 End of Hold 7172.98 76.52 4.43 3484.40 3386.00 636.658 4295.53E 595877194 554189.24 3.00 -303.34 C 7222.18 78.00 4.43 3495.25 3396.85 588.81S 4299.23E 5958819.80 554192.62 3.00 -255.35 7289.00 80.00 4.43 3508.00 3409.60 523.428 4304.:lQE ~888~ .....Q.541gUQ. _3<-ºº-- ...::..189.76 EOC End of Build 7300.00 80.0JL ___ 4.43 3509.91 3411.51 512.628 4305.13E 5958896.03 554198.01 000 -178.93 7325.86 80.00 4.43 3514.40 341600 487.238 4307:.10E . 5958921,42. 554199.81 000 -153.47 B --..-.--- 7400.00 80.00 4.43 3527.28 3428.88 414.438 4312.73E 5958994.25 554204.96 0.00 -80.45 7500.00 80.00 4.43 3544.64 3446.24 316.248 43203~ ¡.......5959092.48 554211.90 0.00 18.03 7600.00 80.00 4.43 3562.01 3463~ºº-...218. 058 4327.9~ 5959~ 554218.85 0.00 11E.>51 -~ All data is in Feet unless otherwise stated Coordinates are from 810t MD's are from Rig and TVD's are from Rig ( Datum #1 98.4ft above mean sea level) Vertical Section is from O.OON O.OOE on azimuth 4.43 degrees Bottom hole distance is 7417.66 Feet on azimuth 40.12 degrees from Wellhead Calculation method uses Minimum Curvature method Prepared by Baker Hughes Incorporated ORIGINAL . . ~ill¡ps ConocoPhillips Alaska, Inc.,Slot #168 Pad 1 E, Kuparuk River Unit, North Slope, Alaska PROPOSAL LISTING Page 4 Well bore: 168 Wellpath: 168 Ver#2 Date Printed: 29-Sep-2004 « INTEQ n.' ... ,.- . ...... , ...... '" < - .. .. ...... ...... .. .« , MPtftl ..... I~it~agl IT\l9[ftl< IV~rticaf· jE.ast{ft C~ati"n IStatfoni .. ... .... .. fç:t";"¡x'" , ... .... ........ ..... .... .. ¡,'. North) Ê~st) IÒttf 'ü . i\ ...... .. 7642.59 80.00 4.43 3569.40 3471.00 176.24S 4331.16E 5959232.54 554221.81 0.00 158.45 A-4 7700.00 80.00 4.43 357937 3480.97 119.87S 4335.52E 5959288.93 554225.79 0.00 214.99 r-Z800~ºº- ~cOO 4.43 ~596.73 3498..33 21.68S 4343.12E 5959387.16 í54232.74 O.OQ_ 313.48 7900.00 80.00 4.43 3614.10 3515.70 76.51N 4350.72E 5959485.38 554239.69 0.00 411.96 8000.00 80.00 4.43 3631.46 353306 174.69N 4358.32E 5959583.61 554246.63 0.00 510.44 8005.39 80.00 4.43 3632.40 3534.00 179.99N 4358. 73.E 5959588.90 554247.01 0.00 515.75 A-3 8100.00 80.00 4.43 3648.83 3550.43 272. 88.N_ ~65.92E 5959681.83 554253.58 0.00 608.92 . 8200.00 80.00 4.43 3666.19 3567.79 371.07N ~~~ 595!:¡78006 554260.52 0.00 707.40 8300.00 80.00 4.43 3683.56 3585.16 469.26N 4381.11 E 5959878.28 554267.47 0.00 805.88 8389.27 80.00 4.43 3699.06 3600.66 556.91N 4387.90E 59599~QJIT.. 554273.67 0.00 893 7~L ..I2Yi!.çj. 4/1 Oº,- End of Hold 8400.00 80.43 4.43 3700.88 3602.48 567.45N 4388.71E 5959976.52 554274.41 4.00 904.37 8409.30 80.80 4.43 3702.40 3604.00 576.60N 4389.42E 5959985.67 554275.06 4.00 91354 A-2 - 7 5/8" Casino pt. 8500.00 84.43 4.43 3714.06 3615.66 666.26N 4396.36E 5960075.37 554281.40 4.00 1003.47 8600.00 88.43 4.43 3720.28 3621.88 765.75N 4404.06E 5960174,90 t-- 554288.44 4.00 1103.26 -. 8700.00 92.43 4.43 371953 362113 865.43N 4411.77E 59602]4.6.L .....Q.54295.49 4.00 1203.24 8707.52 92.73 4.43 3719.20 3620.80 87292N 4412.35E 5960282.11 554296.02 4.00 1210.75 EOC SIC Kick off Point 8800.00 92.73 4.43 3714.79 3616.39 965.02N 4419.48E 5960374.24 554302.54 0.00 1303.12 8900.00 92.73 4.43 3710.03 3611.63 1 064.61 N 4427.19E 5960473.87 554309cQ!L ,..-O.OQ_ 1403.Q1 _. 8934.26 92.73 4.43 3708.40 3610.00 1098.72N 4429.83E 5960508.00 554312.00 0.00 1437.23 Drop 3/100, WS 1E C5 A2-MDPT#2 RVSD090204 3DJ Kick off Poin.~ 9000.00 90]6 4.42 3706..4Q 3608.00 _1164.24N 4434.90E 5960573..5A.. r--25431663 3.00 1502.94 ....illM2.23 89.49 4.42 3706.31 3607.91 120634N 4438.16E 5960615.66 1-.554~~ 300. 1-1545.17 EOD End of DroPlTurn ..JilOO.OO ~ 4.42 3706.83 3608.43 1263.94N 4442.61 E 5960673.28 554323.68 0.00 1602.94 9200.00 89.49 4.42 3707.72 3609.32 1363.64N 4450.32E 5960773.01 554330.73 0.00 1702.93 9300.00 89.49 4.42 3708.61 3610.21 1463.33N 4458.03E 5960872.75 554337.78 0.00 18.~ -. -- 9400.00 89.49 4.42 3709.50 3611.10 15Q.~ .A465.74.ç ~.972.49 554344.82 0.00 1902.92 9500.00 89.~ ¡----4.42_ 3710.40 3Q12.º-º- 1662.73N 4473.45E 5961072.23 554351.87 0.00 2002.92 9600.00 89.49 4.42 3711.29 3612.89 1762.43N 4481.16E 5961171.96 1--554358.92 0.00 2102.92 9700.00 89.49 4.42 3712.18 3613.78 1862.13N 448887E 5961271.70 554365.97 0.00 2202.91 ~QP- ---ª.9.49 4.42 371307 361467 1961.83N 4496.58E 5961371.44 554373.01 0.00 2302.91 9900.00 89.49 4.42 3713.96 361556 2061.52N 4504.29E 5961471.18 554380.06 0.00 2402.90 10000.00 89.49 4.42 37:14.86 3616& ¡-2.161.22N 4512.00E 5961570.91 _55438[,11.. 000 2502.90 10100.00 89.49 4.42 3715.75 3617.35 2260.92N 4519.71E 5961670.65 554394~ ...J).OO 2602.90 -- 10200.00 89.49 4.42 3716.64 3618.24 2360.62N 4527.42E 5961770.39 554401.20 0.00 2702.89 '- ...1Q.~00 00 89.49 4.42 3717.53 3619.13 2460.32N 4535.13E 5961870.13 554408.25 000 2802.89 10400.00 89.49 4.42 3718.42 3620.02 2560.02N 4542.84E 5961969.86 554415.29 0.00 2902.88 10500.00 89.49 4.42_ ~71932 3620.92 2659.72N 4550.55E 5962069.60 554422.34 0.00 3002.88 ..J.0600.00 89.49 4.42 3720.21 ~~21.81 2759.41 N 4558.26E 5962169.34 554429.39 0.00 3102.88 -- _10700.00 89.49 4.42 3721.10 3622.70 2859.11N 4565.97E 596226~Jill. _554436.44 c---Mº 3202.87 -- 10800.00 89.49 4.42_ ~21.99 362:t.Q9.. 2958.81 N 4573.º-~ ~962368.81 ......§54443.48 0.00 3302.87 10900.00 89.49 4.42 3722.88 3624.48 3058.51N 4581.39E 5962468.55 554450.53 000 3402.86 11000.00 89.49 4.42 3723.78 362538 3158.21N 4589.10E 5962568.29 554457.58 1--.0.00 3502.86 11100.00 89.49 4.42 3724.67 3626.27 3257.91N 4596.81E 596266803 554464.62 0.00 3602.86 11200.00 89.49 4.42 372556 3627.16 3357.60N 4604.52E 5962767.76 554471.67 0.00 3702.85 11300.00 89.49 4.42 3726.45 3628.05 3457.30N 4612.23E 5962867"QQ. . 554478.72 0.00 3802.85 11400.00 89.49 4.42 3727.34 3628.94 3557.00N 4619.94E 5962967.24 __554485.77 0.00 3902.84 11500.00 89.49 4.42 3728.24. _~29.84 3656.70N 4627.65E 5963066.98 554492.81 000 4002.84 -~ 11600.00 89.49 4.42 3729.13 3630.73 3756.40N 4635.36E 5963166.71 55449986 0.00 4102.84 11630.37 89.49 4.42 3729.40 3631.00 3786.67N 4637.70E 5963197.00 554502.00 0.00 4133.20 Drop 3/100, WS 1 E C2 A2-MDPT#3 ~. RVSD090204 3DJ Kick off Point All data is in Feet unless otherwise stated Coordinates are from Slot MD's are from Rig and TVD's are from Rig ( Datum #1 98.4ft above mean sea level) Vertical Section is from O.OON O.OOE on azimuth 4.43 degrees Bottom hole distance is 7417.66 Feet on azimuth 40.12 degrees from Wellhead Calculation method uses Minimum Curvature method Prepared by Baker Hughes Incorporated ORIGINAL . . ConocÒPhillips ConocoPhiJlips Alaska, Inc.,Slot #168 Pad 1 E, Kuparuk River Unit, North Slope, Alaska PROPOSAL LISTING Page 5 Well bore: 168 Wellpath: 168 Ver#2 Date Printed: 29-Sep-2004 ... ... IN'TEQ ¡ I.... .. . ..... . ... ..... .. .... ...... ..... .......... ... > .. .< IMDfft] "",lDfftl X~~~Q~ .".....c....., Eá$~ftJ ISt!¡tion. St!¡tioh ?ogle!;1 Ve¡rtlC¡¡'1 i< .~r -,. INorth) E'8st\) iffi~··.. t1> < .......... .... < ... ..... / ...... 11656.13 88.72 4.32 3729.80 3631.40 3812.36N 4639.67E 596322;2~ _.554503JJL _3.00 4158.97 EOD. End of DroplTurn 11700.00 88.72 4.32 3730.78 3632.38 3856.09N 4642.97E 5963266.45 554506.81 0.00 4202.82 11800.00 88.72 f-----4.32 3733.01 3634.61 3955.78N 4650.51E ~Q336617 554513.68 0.00 4302.80 11900.00 88.72 4.32 3735.24 3636.84 4055.47N 4658.04E 5963465.90 554520.55 0.00 4402.77 12000.00 88.72 4.32 3737.47 3639.07 4155.16N 4665.58E 5963565.63 554527.43 000 4502.75 12100.00 88.72 4.32 3739.70 3641.30 4254.85N 4673.11E 5963665.36 554534.30 ~_OO 4602.72 µ2?JW.OO ~.72 4.32 3741.93 3643.53 4354.54N 4680.65E 5963765.09 554541.17 0.00 4702.70 12300.00 88.72 4.32 3744.16 3645.76 4454.23N 4688.18E 5963864.82 554548.05 0.00 4802.67 12400.00 88.72 4.32 3746.39 3647.99 4553.93N 4695.72E 5963964.55 554554.92 0.00 4902.65 12500.00 88.72 4.32 3748.62 3650.22 4653.62N 4703.26E 5964064.28 554561.79 0.00 5002.62 12600.00 88.72 4.32 3750.85 3652.45 4753.31N Æ10,NÇ ~96416400 554568.67 0.00 5102.60 12700.00 88.72 432 3753.08 3654.68 4853.00N 4718.33E 5964263.73 554575.54 0.00 5202.57 12800.00 88.72 4.32 3755.31 3656.91 4952.69N 4725.86E 5964363.46 554582.41 QOO 5302.55 f-J2900.00 ~'-z;2_ _432 3757.54 3659.14 5052.38N 4733.40E 5964463.19 554589.28 000 5402.52 13000.00 88.72 4.32 3759.77 3661.37 5152.07N 4740.94E 5964562.92 554596 16 0.00 5502.50 13100.00 88.72 4.32 376200 3663.60 5251.76N 4748.47E 5964662.65 554603.03 0.00 5602.47 13200.00 88.72 4.32 3764.23 3665.83 5351.45N 4756.01E 5964762.38 554609.90 0.00 5702.45 13300.00 88.72 4.32 3766.46 3668.06 5451.14N 4763.54E 59648J~£..1Q.. ¡--..554616.78 0.00 5802.42 13400.00 88.72 4.32 3768.69 3670.29 5550.83N 4771.08E 5964961.83 55462365 0.00 5902.40 13500.00 88.72 432 3770.92 367Z~ ....QQpO.52N 4778.61E r--i5.96506156 554630.52 000 6002.37 13521.50 88.72 432 3771.40 3673.00 5671.95N 4780.23E 5965083.00 554632.00 0.00 6023.86 TD- 4112" Casing Pt., WS 1E C5 A2 TOE RVSD090204, 4 112in Casing, End .. of Hold .-- All data is in Feet unless otherwise stated Coordinates are from Slot MD's are from Rig and TVD's are from Rig ( Datum #1 98.4ft above mean sea level) Vertical Section is from O.OON O.OOE on azimuth 4.43 degrees Bottom hole distance is 7417.66 Feet on azimuth 40.12 degrees from Wellhead Calculation method uses Minimum Curvature method Prepared by Baker Hughes Incorporated ORIGINAL . . ~illips ConocoPhillips Alaska, Inc.,Slot #168 Pad 1 E, Kuparuk River Unit, North Slope, Alaska PROPOSAL LISTING Page 7 Well bore: 168 Wellpath: 168 Ver#2 Date Printed: 29-Sep-2004 'II: INTEQ WS 1 E C2 3786.67N 4637.70E 3729.40 N70 18 36.5090 W149 33 30.1475 554502.00 5963197.00 A2-MDPT#3 RVSD090204 WS 1 E C5 1098.72N 4429.83E 3708.40 N70 18 10.0746 W149 33 362567 554312.00 5960508.00 A2-MDPT#2 RVSD090204 WS 1 E C5 D TOP 795.53S 428324E 3442.40 N70 17 51.4456 W149 33 40.5624 554178.00 5958613.00 RVSD090204 WS 1E C5 A2 TOE 5671.95N 4780.23E 3771.40 N70 18 550497 W149 33 25.9552 554632.00 5965083.00 RVSD090204 --~ --- 647707 Planned All data is in Feet unless otherwise stated Coordinates are from Slot MD's are from Rig and TVD's are from Rig ( Datum #1 98.4ft above mean sea level) Vertical Section is from O.OON O.OOE on azimuth 4.43 degrees Bottom hole distance is 7417.66 Feet on azimuth 40.12 degrees from Wellhead Calculation method uses Minimum Curvature method Prepared by Baker Hughes Incorporated ORIGINAL . . ConocJ'Pt,ilfips ConocoPhillips Alaska, Inc.,Slot #168 Pad 1 E, Kuparuk River Unit, North Slope, Alaska PROPOSAL LISTING Page 6 Well bore: 168 WeIJpath: 168 Ver#2 Date Printed: 29-Sep-2004 'II: INTEQ .....- .... ... .... . ....... ...... II ..... ....> .. IMotftl t\lbfftl Ëåsffftl· ",''',,'''''' > ...» > .. ............. 300.00 .3.00.00 O.OOE O.OON KOP 633.33 631.64 23 77E 16.648 _~~Id 4/100 -- 88333 872.82 76.70E 53.718 Build 6/100 1686.63 1432.84 521.24E 364.988 EOC 1895.47 1510.40 680.07E 476.198 Base Permafrost 2547.05 1752.40 1175.64E 823.198 Too T-3 3392.50 2066.40 1818.66E 1273.448 Too K-15 4407.77 2443.47 2590.83E 1814.128 Beain Curve 4450. 11 2459.40 2623.39E 1836.008 103/4" Casina pt -- 5286.40 2823.40 '- 3344.10E 1966.268 - Too Uanu C 5823.89 3048.47 3770.36E 1739.798 EOC 5858.72 3061.40 3794.30E 171ª,Q7~ cIQQJ&I}I.J.ß....--~--~ 5876.77 3068. 11 3806.72E 1706.818 8tart 200' Pump Tanoent 6006.80 3116.40 3896.14E 1625.708 Too Uonu A L-_ 6076"~ 3142.39 3944.26E__ ------.J.~82.058 End 200' PumpIÊ.~nt-Beain Curve 6489.85 3290.40 4173.38E 1274.82S K-13 -- 6908.19 3416.52 4275.79E 891.838 EOC 7008.18 3442.40 4283.24E 795.538 Ton West 8ak D 7122.18 3471.91 4291.73E 685.748 Build 3/100 ......2172.~ _~3484AO 4295.53E 636.658 C 7289.00 3508.00 4304.30E 523.42S EOC 7325.86 3514.40_ _4307.10E 487.238 B _.~. 7642.59 3569.40 4331.16E: 176.248 A-4 -- 8005.39 3632.40 4358.73E 179.99N A-3 8389.27 3699.06._ ..........A.38790E 556.91N Build 4/100 8409.30 3702.40 4389.42E 576.60N A-2 - 7 518" Casina pt 8707.52 3719.20 4412.35E 872. 92N__ ~C__ 8934.26 3708.40 442983F 1098.72N ~100 . . 9042.23 3706.31 4438.16E 1206.34N EOD 11630.37 3729.40 4637.70E 3786.67N Drop 3/100 11656.13 3729.80 4639.67E 3812.36N EOD ~521.50 3771.40 4780.23E__ ~- 5671.95N TO- 4 112" Casino pt All data is in Feet unless otherwise stated Coordinates are from Slot MD's are from Rig and TVD's are from Rig ( Datum #1 98.4ft above mean sea level) Vertical Section is from O.OON O.OOE on azimuth 4.43 degrees Bottom hole distance is 7417.66 Feet on azimuth 40.12 degrees from Wellhead Calculation method uses Minimum CUNature method Prepared by Baker Hughes Incorporated ORIGt~lA. ConocöPhillips Alaska, Inc. Kuparuk River Unit Installation: 1 E Weilbore: Refwellpath is 168 Ver#2. Coordinate-s are in feet refere-nce Slot#168. True Vertical Depths are reference Rig Datum. Mea~ured Depths are reference Rìg Datum. Rig Datum: Datum #1 Rig Datum to mean sea level: 98.40 It 260 300 350 o 1000 340 30 320 40 50 270 100 250 110 240 120 230 1900 220 140 o 150 160 170 Normal Plane Travelling Cylinder - Feet All depths shown are M"asured depths on Reference Well ¢:: 0 Lt) -300 ~ /I E () 0 Q) ro () (f) 300 600 900 _ 1200 - G) .! ::;;- 1500 - Q. G) C 1800 ëõ 0 1:: 2100 ~ G) 2400 ::s ~ l- I V 2700 3000 3300 3600 3900 4200 In. -=- ïN'ï'-EQ ---- ConocoPhillips Alaska, Inc. Conoc;';hiUips Location: North Slope, Alaska Field: Kuparuk River Unit Installation: Pad 1E Slot: Slot #168 Well: 168 Wellbore: 168 ":::-<1 Begin Curve 103/4" Casing PI. ~ 65.78 DLS: 5.00 deg/100ft 64. 7~3.41 62.90 62.97 TOR Ugnu C 63'65.44 EOC Top Ugnu B End 200' Pump Tangent-Begin Curve 69'K~13 EOC RKB Elevation: 98.4' KOP 6.00 Build 4/100 18.00 Build 6/100 32.00 44.00 DLS: 6.00 deg/100ft 68.00EOC Base Permafrost -300 0 300 Scale 1 cm = 150 ft 600 900 1200 1500 1800 2100 2400 2700 3000 3300 3600 3900 4200 4500 4800 5100 5400 5700 6000 Vertical Section (feet) -> Azimuth 86.50 with reference 0.00 N, 0.00 E from Slot #168 Created by : lanner Date lotted: 1-0ct-2oo4 Plot reference is 168. Refwellpath Is 168 Ver#2. Coordinates are in feet reference Siot #168. True Vertical Depths are reference Rig Datum. Measured Depths are reference Rig Datum. Rig Datum: Datum #1 Rig Datum to mean sea level: 98.40 ft, Plot North is all ned to TRUE North. - . . IIiIW ... INTf;Q - Scale 1 cm = 250 ft -1000 -500 -0 500 . .'\ ConocoPhillips Alaska, Inc. Location: North Slope, Alaska Field: Kuparuk River Unit Installation: Pad 1E Slot: Slot #168 Well: 168 Well bore: 168 ConocJPhillips East (feet) -> 1000 Created by: Planner Date plotted: 1-Oct-2004 Plot reference is 168. Ref wellpath is 168 Ver#2. Coordinates are in feet reference Slot #168. True Vertical Depths are reference Rig Datum. Measured Depths are reference Rig Datum. Rig Datum: Datum #1 Rig Datum to mean sea level: 98.40 ft. Plot North is aligned to TRUE North. 1500 2000 2500 3000 3500 4000 4500 5000 5500 6000 6500 1E-168 TD LOCATION: 183' FSL, 1127' FEL SEC. 10, T11N, R10E / 1E-168L1 and L2 TD LOCATIONS: 1302'FNL,1249'FEL SEC. 15,T11N,R10E t! (.yJ-Þ ~. ...<.-<3. ¡ L 1 ". - D, {.Iµ fb ,0' f; . I "" 10 f€ l-- SURFACE LOCAjJ0N: /} 207' FNL,~EL SEC21, 111N, R10E -~---~- \)\) O<? b.\'\.\)\) ~ ~òò'ò\ «) ~~ «) EOC Base Permafrost End Milled Hole Base Whipstock Face Top Whipstock Face End Milled Hole Base Whipstock Face Top Whipstock Face Top T-3 Top K-15 168 4 112" Casing pt. 168L 1 168L2 EOO Drop 3/100 EOD Drop 3/100 EOC 1E-168 TOP WEST SAKA2 LOCATION: 368' FSL, 152g FEL SEC. 15, T11N, R10E ì Build 4/100 r A-2 - 7 5/8" Casing pt. A-3 1E-168 TOP WEST SAK B LOCATION: 696'FNL, 161~FEL SEC. 22, T11N, R10E A-4 B EOC C Build 3/100 Top West Sak D EOC K-13 End 200' Pump Tangent-Begin Curve Top Ugnu A Stai1200' Pump Tangent EÒ'lJ Ugnu B Top Ugnu C 1 E-168 TOP WEST SAK D LOCATION: 1004' FNL, 1639' FEL SEC. 22,T11N,R10E ~Begin Curve 103/4" Casing Pt~ ORIGINAL 6500 6000 5500 5000 4500 4000 3500 3000 2500 ^ I 2000 Z 0 ;::¡. :r 1500 -::¡; (1) (1) .... - 1000 500 0 -500 -1000 -1500 en 0 -2000 II) CD 0 3 -2500 II N 01 0 -3000 ;::I! '" <;0 <;0 N " § ~ '" ~ ø 2400 - .... ø .e 2800 - ConocoPhillips Alaska, Inc. Slot: Slot #168 Well: 168 Wellbore: 168 ¡r-TEQ Location: North Slope, Alaska Field: Kuparuk River Unit Installation: Pad 1E ~,\dJ i9 ~ Conoc;PhiUips Planner 1-001-2004 Slot#168. Datum. TO· 41/2" Casing PI. Alaska, Installation: Well: 168 Wellbore: 168 350 o 10 260 300 1000 340 30 320 40 50 270 250 240 230 130 1900 220 140 210 150 160 170 Normal Plane Travelling Cylinder - Feet All depths shown are Measured depths on Reference Well Rig: Doyon 141 Location: West Sak Client: ConocoPhillips Alaska, Inc. Revision Date: 9/29/2004 Prepared by: Mike Martin Location: Anchorage, AK Phone: (907) 265-6205 Mobile: (907) 229-6266 email: martin13@slb.com Previous Csg. < 10 3/4", 45.5# casing at 4,450' MD < Top of Tail at 4,786' MD < 75/8",29.7# casing in 9 718" OH TO at 8,409' MD (3,702' TVD) SchlulblPl81' Preliminary Job Design based on limited input data For estimate purposes only. Volume Calculations and Cement Systems Volumes are based on 45% excess. Tail slurry is designed for 500' MD above top of Ugnu C Sand - (3623' MD annular length). Tail Slurrv Minimum thickening time: 200 min. (Pump time plus 90 min.) DeepCRETE @ 12.5 ppg - 2.26 ft3fft 0.2148 ft3fft x 3623' x 1.45 (45% excess) = 0.2578 ft3fft x 80' (Shoe Joint) = 1128.4 ft3 + 20.6 ft3 = 1149.0 ft3f 2.26 ft3fsk = Round up to 510 sks 1128.4 ft3 20.6 ft3 1149.0 ft3 508.4 sks BHST = 87°F, Estimated BHCT = 74°F. (BHST calculated using a gradient of 2. 6°F f1 00 ft. below the permafrost) PUMP SCHEDULE Stage Pump Rate (bpm) Stage Volume Cumulative Stage Time Time (min) (bb!) (min) CW100 5.0 10.0 2.0 2.0 Pressure test lines 0.0 0.0 10.0 12.0 CW100 5.0 30.0 6.0 18.0 Drop bottom plug 0.0 0.0 5.0 23.0 MUDPUSH II 6.0 40.0 6.7 29.7 WS DeepCRETE 6.0 204.6 34.1 63.8 Drop top plug 0.0 0.0 5.0 68.8 Mud 7.0 367.4 52.5 121.2 Slow & bump plug 3.0 15.0 5.0 126.2 MUD REMOVAL Recommended Mud Properties: 9.0 ppg, Pv < 15, Ty < 20. As thin and light as possible to aid in mud removal during cementing. Spacer Properties: 10.5 ppg MudPUSH* II, Pv = 20 - 24, Ty = 24 - 28 Recommended Centralizers: 1 bow spring per joint across each Ugnu sand, 1 tandem rise centralizer per joint from shoe track to +1- 500' above "D" sand and 2 tandem rise per joint on shoe track. OR\G\NAL Rig: Doyon 141 Location: West Sak Client: ConocoPhillips Alaska, Inc. Revision Date: 9/29/2004 Prepared by: Mike Martin Location: Anchorage, AK Phone: (907) 265-6205 Mobile: (907) 229-6266 email: martin13@slb.com < TOC at Surface Previous Csg. < 20", 91.5# casing at 108' MD < Base of Permafrost at 1,895' MD (1,510' TVD) < Top of Tail at 3,450' MD < 10 3/4", 45.5# casi ng in 131/2" OH TD at 4,450' MD (2,459' TVD) Mark of Schlumberger Schl_blPgllP Preliminary Job Design based on limited input data. For estimate purposes only. Volume Calculations and Cement Systems Volumes are based on 250% excess in the permafrost and 30% excess below the permafrost. The top of the tail slurry is designed to be at 3,450' MD. Lead Slurrv Minimum pump time: 260 min. (pump time plus 90 min.) ARCTICSET Lite @ 10.7 ppg - 4.45 ft3/sk 1.3644 ft3/ft x (108') x 1.00 (no excess) ::: 3 0.3637 ft 1ft x (1895' - 108') x 3.50 (250% excess) = 3 0.3637 ft 1ft x (3450' - 1895') x 1.30 (30% excess) = 147.4 ft3 + 2274.8 ft3+ 735.2 ft3 = 3157.4 ft3 14.45 ft3/sk = Round up to 710 sks 147.4 ft3 2274.8 ft3 735.2 ft3 3157.4ft3 709.5 sks Have 290 sks of additional Lead on location for Top Out stage, if necessary. Tail Slurrv Minimum pump time: 180 min. (pump time plus 90 min.) DeepCRETE @ 12.0 ppg - 2.52 ft3/sk 3 0.3637 ft 1ft x (4450' - 3450') x 1.30 (30% excess) = 0.5400 ft3/ft x 80' (Shoe Joint) = 472.8 ft3 + 43.2 ft3 = 516 ft31 2.52 ft3/sk = Round up to 210 sks 472.8 ft3 43.2 ft3 516 ft3 204.8 sks BHST = 55°F, Estimated BHCT = 68°F. (BHST calculated using a gradient of 2. 6°F/1 00 ft. below the permafrost) PUMP SCHEDULE Stage Pump Rate (bpm) Stage Volume Cumulative Stage Time Time (min) (bb!) (min) CW100 5.0 10.0 2.0 2.0 Pressure test lines 0.0 0.0 10.0 12.0 CW100 5.0 40.0 8.0 20.0 MUDPUSH II 6.0 50.0 8.3 28.3 Drop bottom plug 0.0 0.0 5.0 33.3 ASL 7.0 567.4 81.1 114.4 DeepCRETE 5.0 95.1 19.0 133.4 Drop top plug 0.0 0.0 5.0 138.4 Water 5.0 20.0 4.0 142.4 Switch to rig pump 0.0 0.0 5.0 147.4 Mud 7.0 385.3 55.0 202.4 Slow & bump plug 3.0 15.0 5.0 207.4 MUD REMOVAL Recommended Mud Properties: 8.8 ppg, As thin and light as possible to aid in mud removal during cementing. Spacer Properties: 10.5 ppg MudPUSW II, Pv = 17-21, Ty = 20-25 Centralizers: Recommend 1 per joint throughout tail slurry to aid in isolation ORIGINAL 'Tubing Head Assy, 11" X 4-112" 'Insulated Conductor, 20" X 30" (2) Gas Lift Mandrels, 4-112" X 1" KBG-2 ¡II ips West Sak 1 E-168 Producer 7 -5/8" Tri-Lateral Completion Tubing String: 4-1/2" 12.6#, L-80, 18TM, Spec, Clearance Couplings, (4,920" OD) 10-3/4" Casing, 40.6#, L-80, BTC set @ +/- 4460' MD, 246$' TVD, 13-112" hole 5-112" X 7-5/8" ZXP Liner Top Packer with HoJd Downs Electric Submersible Pump, Centralift 418 HP Motor, rCSOOO WL Deployed Pump D-sand Window at +/- 7008' MD, 3442' TVD 4-112" 12.6#, L-SO, DWe, Slotted Liner Every Joint (.t25" X 2.5", 32 sepf, 5.9% open area) 6-3/4" Lateral TD @ 12009' MD, 3500' TVD S-sand Window /" +¡. "26' MD, 3514' TVD Casing, 7-5/8" 29.7#, L-SO, STCM, Set @ +1- 8409' MD, 3702' TVD, Set @ 80 deg, 9-7/S" Hole. Bak"rOilTools ¡¡·3/4" Lateral TD @ 12016' MD, 3680' TVD 4-1J21! 12.6#. L-80, DWC, slats: aver sandI blank over shales, constrictors for isolation. (.125" X 2.5" slots. 32spf, 5.9% open or",,) ¡¡·314" Lateral 13621' MD, RE: Question on KRU 1£-168 Surface Location . . Steve - the as-built for 1E-168 shows the surface location as 640' FEL, Sec. 21. The Baker Hughes directional plat is not correct. Thanks, Sharon office phone: 263-4612 fax: 265-6224 -----Original Message----- From: Stephen Davies [mailto:steve davies@admin.state.ak.us] Sent: Tuesday, October 05, 2004 1:43 PM To: Allsup-Drake, Sharon K Subject: Question on KRU 1E-168 Surface Location Sharon, The Surface Location on the 401 form for 1E-168 and listed as being 640' FEL, Sec. 21, but on the Baker plat for 1E-168, it is given as 340' FEL, Sec. 21. see which one is correct? its laterals is Hughes directional Could you check to Thanks, Steve Davies 1 of 1 10/5/2004 2:58 PM UAn SFD 1 · SHARON K. ALLSUP-DRAKE CONOCOPHILLlPS ATO 1530 700 G STREET ANCHORAGE AK 99501 1072 DATE 1~~62-141311 e PAY TO THE ORDER OF 5ífl1& cF A-Uf-ScÆ It $ ICO.OO " uvd.ARS &I ~... CHASE Chase Manhattan Bank USA, N.A. Valid Up To 5000 Dollars ~, 200 While Clay Center Dr., Newark, DE 19711 . ...0 1€-lbB .Sk~¿f~~íd~L I: 0 3 ¡. ¡. 0 0 ¡. ~ ~ I: 2 ¡. 8 ~ ? ¡. ~ 0 ? ~ 2 ? b II· .0 ? 2 I . . TRANSMIT AL LETTER CHECK LIST CIRCLE APPROPRIATE LETTER/P ARAGRAPHS TO BE INCLUDED IN TRANSMITTAL LETTER ¡¿Rd /E-16?? 2D C('~ ZOO WELL NAME PTD# V Development Service Exploration Stratigraphic CHECK WHAT ADD-ONS ~'CLUE n. APPLŒS (OPTIONS) MULTI Tbe permit is for a new wellboresegment of LATERAL existing weD . Permit No, API No. . (1f API Dum ber Production. sbould continue to be reponed as last two. (2) digits a function· of tbe original API number. stated are between 60-69) above. Pn.,OT HOLE In accordance witb 20 AAC 25.005(f), aJ] (PH) records, data and logs acquired for tbe pilot bole must be clearly differentiated In botb name (name on permit plus PH) .' and API number (50 - 70/80) from records, data and logs acquired for we)) (name on permit). SPACING The permit is approved subject ·to fuD EXCEPTION .' compliance witb 20 AAC 25.0S5~ Approval to perforate and produce is contingent upon issuance of ~ conservation order approving a spacing e:J ception. (Company Name) assumes tbe liability of any pro1 est to the spacing .exception tbat may occur. DRY DITCH All dry ditch sample sets su bmitted to tbe SAMPLE Commission must be in no greater 1han 30' sample intervals from below tbe permafrost or from wbere samples are first caught and 10' sample iDter-vaJs tbrough target zones. o o Well bore seg Annular Disposal On Program DEV On/Off Shore 111_60 E-lM Unit Well Name: KUPARV.KRIV UWSA~ DEV LPEND_ _GeoArea ß~Q goyerned. by.Gonsel"lo'atiQn. QrderNo, 4Q6A ~RU West Sa( Oil Pool, 10 .açr~s. the pool is t>lorninal spa.cing withilJ .' Yes Yes YJ3S YJ3S YJ3S YJ3S YJ3S Yes YJ3S YJ3S Yes YJ3S Yes NA .NA NA NA Initial ClasslType KUPARUK RIVER. WEST SAK OIL - 490150 c O~HjLLIES ALASKA .leasenumber .appropriatJ3 narlle .aod lJumb.er We.1 JocatJ3d in.a d.efilJe.d pool We.IIJocat~d prope.r ßistance. from drijling unit We.ll Jocated pr.operdistance. from QtbeJ w~lJs .U.nique well b.ound.ary Sufficient .acr~élQe.aYailable inßrillilJQ unit Jtd~viated, .Op~rator only affect~d party .Qpßr.ator has. appropriate. bond inJQrce. is weJlbore plaUlJcJu.ded Permit <;<10 be issued without conserva.tion order PJ3rmit <;<10 be issu.ed without ad.milJistratÏ\le.apprpval Can permit be approved before 15-day wait We.IIJocated within area and. strata authorized by.lojectiolJ Order # (put 10# .AJI wells. within servjc.eweU (For in c.omlJl.eots). only) (For.service well only) .1l4.mile.are.a.of reyißW idJ3lJtified ßuratioRof pre-proJ:luctiolJ less than 3 montbs. (Fpr iojector PJe.-produ.ced. 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 Administration Date 10/5/2004 Appr SFD be drilled fJQm an exisiioQ paJ:l. WelJwi All aquife.rs exempled,A.O .CFR 1-47.1 021b)(3). hydrocarbo.n. Sufficjent cemeolp.ulJlPed to cOller alt SloUe.d Jiner .completion plaoned.. No rese.l"Io'e.pitplanlJe.d. All wç¡ste toapproveJ:l.anlJuJUSOJ dispo$al welJS. Rig js e.quippe.dwith steelpits. Trç¡veJilJg cylinder. plot jnclude.d, .Gyro$ possible. !?rp>5:il)1ity C!nSJlysis pe.rf.orme.d. Çlose apPJoacbe.s jdentjfiJ3d ppg. OJ - SI:IE' expected betwe.eo 8..5.- 8.8EMW. PIç¡lJn.ed MW 9.0 e F-'Ianned teslpres$ure 35QO.pst psj MASF-' cqIGulate.d.atl141 Rigis equipped withselJs.ors.and alarms, 1:12S not prese.nt in .offset wells. Yes NA Yes No. No. Yes Yes NA YJ3S Yes Yes Yes Yes .Yes Yes No .NA .AÇMP finding .of Con.si$teocy. has bee.n Js.sued for. this pr.ojeet .C.oodu.ctor .Sw:faceC<lsing. pJotects alLknown USDWs .CMT vol adec¡u.ate. to eirc.ulate. on .cOlJductor & SUJt csg .CMT vol ad~c¡ uate to tie-in Jong .string tosud ~g. .CMTwil! coyeraJl (lJownproduct;ye horil:on.s string.PJQvided C..T, B&. permafrost .C.asiog de.sigos ad.eQuate. for beelJ ç¡PPJoved re.seI"Ye pit Jta.re-drilt has.a. 10A03 for abandQnmeflt Adequate .wellbor~ ~ep;'lratjo.n -Proposed Jtdjverter Jequired, does iLmeet regulatiolJs_ .DJiLling flujd. prQgram schematic.& eCluip Jist adequOile (put psig in.comments) , (May 84) .operç¡tjon .sh l!tllown 10 .C.hoke manifold complies. w/API Rf>-5;~ Work will pcc.ur without .BOPEs,.dothey meelreguJation .BOPEpre.ss rating appropriate; .test 18 19 20 21 22 23 24 25 26 27 28 29 30 31 32 33 34 Engineering .Adequate .tankage OJ Date 10/7/2004 Appr TEM &DývJ\ \Oh Jecorded in .offset wells. .8.8.ppg EMW; wi tl2S Expected. reservojr pre$sure ;s8.5 t>lo signjflcç¡nt onJy) Js preseoce. of H2S gas. prollable Meçba.nicç¡LCOlJdjlloo of wells within AOR yerified (Foaerv¡c~ welJ be .dril!ed wjtb 8.69.1.ppg mud. Yes Yes NA .NA .NA c.ao be iS$l!ed w/o hydrogen sulfide measures Permit .D.ata.pJeselJted on Rote.ntial oveJpressure .zOlJe$ 35 36 37 38 39 Geology Date 10/5/2004 Appr SFD Sei$mic.a!1alysjs Qf shallow gas.zones (if off-sh.ore) Seabed .conditiolJ Sl!rvey Conta.ct West Sak Pool "A" sand horizontal wel Date -r0'y namelphoneJorweekly progre~s.reports [exploratory .only] Date Engineering Commissioner 1-- Date: I i 10 Geologic Commissioner Vis . . Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding infomlation, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. **** REEL HEADER **** LDWG 05/06/02 AWS 01 **** TAPE HEADER **** LDWG 05/06/02 01 *** LIS COMMENT RECORD *** . . J<tJc.f- 2,00 J )'>1<;'9. !!!!!!!!!!!!!!!!!!! LDWG File Version 1.000 !!!!!!!!!!!!!!!!!!! Extract File: LISTAPE.HED TAPE HEADER KUPARUK RIVER UNIT MWD/MAD LOGS # WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: # JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 4 4 G. SUTING D. GLADDEN # SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION(FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: # WELL CASING RECORD 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING # REMARKS: OPEN HOLE BIT SIZE (IN) 42.000 13.500 9.875 6.750 lE-168 500292323000 ConocoPhillips Alaska, Inc. BAKER HUGHES INTEQ 02-Jun-05 MWD RUN 5 5 S. DRAKE P. WILSON 21 UN 10E 98.40 70.40 CASING SIZE (IN) 20.000 10.750 7.625 MWD RUN DRILLERS DEPTH (FT) 148.0 4414.0 8152.0 13477.0 PER CONOCOPHILLIPS ALASKA STANDING ORDER, 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 THE WELL SITE. SURFACE LOCATION: LAT: N 70 DEG 17' 59.2815" LONG: W149 DEG 35' 45.4169" LOG MEASURED FROM D.F. AT 98.4 FT. ABOVE PERM. DATUM (M.S.L.) . COMMENTS: 1) Baker Hughes INTEQ runs 1 & 2 utilized an 8" directional only tool to drill from 148 to 4425 feet MD (148 to 2481 feet TVD). 2) Baker Hughes INTEQ run 3 utilized a 6.75" ATK 2.5 to drill from 4425 to 6941 feet MD (2481 to 3445 feet TVD). The FE (Formation Evaluation) section of the tool failed due to extremely high torque values while drilling out the 10 3/4" casing shoe. No MWD data was acquired on this run. 3) Baker Hughes INTEQ run 4 utilized a 6.75" directional tool with a Multiple Propagation Resistivity (MPR) , Gamma Ray, along with Annular Pressure, to drill from 6941 to 8158 feet MD (3445 to 3714 feet TVD). 4) Baker Hughes INTEQ run 5 utilized a 4.75" directional tool with a Multiple Propagation Resistivity (MPR) , Gamma Ray, along with Annular Pressure, to drill from 8158 to 13477 feet MD (3714 to 3763 feet TVD). This wellbore included an openhole sidetrack at 11725 feet MD (3733 feet TVD) from lE-168PBl during run 5. REMARKS : 1) Data from 6220 to 6842 feet MD (3228 to 3424 feet TVD) was acquired with a MAD pass. 2) Depth of 7 5/8" Casing Shoe - Driller: 8152 feet MD (3714 feet TVD). Depth of 7 5/8" Casing Shoe - Logger: 8158 feet MD (3714 feet TVD). 3) The interval from 13447 to 13477 feet (3763 to 3763 feet TVD) was not logged due to sensor offsets at TD. $ Tape Subfile: 1 82 records... Minimum record length: Maximum record length: 8 bytes 132 bytes **** FILE HEADER **** LDWG .001 1024 *** LIS COMMENT RECORD *** ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! !! ! ! !!!!!!!!!!!!!!!!!! ! FILE HEADER FILE NUMBER: EDITED MERGED MWD Depth shifted DEPTH INCREMENT: # FILE SUMMARY PBU TOOL CODE MWD $ LDWG File Version 1.000 Extract File: FILEOOl.HED 1 and clipped curves; all bit runs merged. .5000 START DEPTH 6200.0 STOP DEPTH 13477.0 # BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- . . BASELINE DEPTH $ # MERGED DATA SOURCE PBU TOOL CODE MAD MWD MWD $ BIT RUN NO 4 4 5 MERGE TOP 6200.0 6842.0 8147.0 MERGE BASE 6842.0 8147.0 13477.0 # REMARKS: MERGED PASS. NO DEPTH SHIFTS WERE APPLIED AS THIS LOG IS THE DEPTH REFERENCE FOR THIS WELL. $ # *** INFORMATION TABLE: CONS MNEM VALU ------------------------------------ WDFN LCC CN WN FN COUN STAT le-168 5.xtf 150 ConocoPhillips Alaska, Inc. lE-lG8 Kuparuk River 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 ROP ROP ROP 0.0 FET FET RPTH 0.0 * FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame Size is: 32 bytes Logging direction is down (value= 255) Optical Log Depth Scale Units: Feet Framé spacing: 0.500000 Frame spacing units: [F ] Number of frames per record is: 31 One depth per frame (value= 0) Datum Specification Block Sub-type is: 1 FRAME SPACE = 0.500 * F ONE DEPTH PER FRAME Tape depth ID: F 7 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 ROP MWD 68 1 FPHR 4 4 7 FET MWD 68 1 HR 4 4 . . ------- 28 Total Data Records: 470 Tape File Start Depth Tape File End Depth Tape File Level Spacing Tape File Depth Units 6200.000000 13477 . 000000 0.500000 feet **** FILE TRAILER **** Tape Subfile: 2 513 records... Minimum record length: Maximum record length: 8 bytes 4124 bytes **** FILE HEADER **** LDWG .002 1024 *** LIS COMMENT RECORD *** !!!!!! !!!! !!!!!!!!! LDWG File Version 1.000 !!!! !!!!!!!!!!!!!!! Extract File: FILEOll.HED FILE HEADER FILE NUMBER: RAW MWD Curves and BIT RUN NO: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE MWD $ 2 log header data for each bit run in separate files. 4 .2500 START DEPTH 120.0 STOP DEPTH 8147.0 # 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: 04-NOV-04 MSB 18704 6.75 MPR MEMORY 8158.0 120.0 8147.0 o 74.5 85.8 # TOOL STRING (TOP TO VENDOR TOOL CODE DIR PRES MPR GRAM $ BOTTOM) TOOL TYPE DIRECTIONAL PRESSURE MULT. PROP. GAMMA RAY RES. TOOL NUMBER 90424 100009727 97378 5309 # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): 9.875 4414.0 # . 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): # . F.W. Spud 9.10 .0 .0 200 .0 .000 .000 .000 .000 96.0 .0 .0 .0 .00 .000 .0 o BIT RUN 4 (MWD Run 4). MPR/GR. The ROP curve from surface runs is included here for the sake of data completeness. Approximately 25 feet of valid Gamma Ray data was recorded from 4270 - 4295' and is also included here. The Gamma Ray and Resistivity data from 6220 - 6842 feet was recorded as a MAD pass at the beginning of this run. Data from 6842 - 8147 is MWD data from this bit run. CURVE GLOSSARY: GRAM - GAMMA RAY APPARENT (MWD-API) ROPA - RATE OF PENETRATION (FPHR) RPCL - DEEP PHASE RESISTIVITY (OHMM) RPSL - MEDIUM PHASE RESISTIVITY (OHMM) RPCH - SHALLOW PHASE RESISTIVITY (OHMM) RPSH - EXTRA SHALLOW PHASE RESISTIVITY (OHMM) RPTH - FORMATION EXPOSURE TIME (MIN) $ REMARKS: # *** INFORMATION TABLE: CONS MNEM VALU -------------------------------- WDFN LCC CN WN FN COUN STAT le-168.xtf 150 ConocoPhillips Alaska, I lE-168 Kuparuk River 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 ROPA ROPA ROP 0.0 RPTH RPTH RPTHM 0.0 * FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame Size is: 32 bytes . . Logging direction is down (value= 255) Optical Log Depth Scale units: Feet Frame spacing: 0.250000 Frame spacing units: [F J Number of frames per record is: 31 One depth per frame (value= 0) Datum Specification Block Sub-type is: 1 FRAME SPACE = 0.250 * F ONE DEPTH PER FRAME Tape depth ID: F 7 Curves: Name Tool Code Samples Units Size Length 1 GRAM MWD 68 1 GAP I 4 4 2 RPCL MWD 68 1 OrIMM 4 4 3 RPSL MWD 68 1 OrIMM 4 4 4 RPCH MWD 68 1 OrIMM 4 4 5 RPSH MWD 68 1 OrIMM 4 4 6 ROPA MWD 68 1 FPHR 4 4 7 RPTH MWD 68 1 MINS 4 4 ------- 28 Total Data Records: 1036 Tape File Start Depth Tape File End Depth Tape File Level Spacing Tape File Depth Units 120.000000 8147.000000 0.250000 feet **** FILE TRAILER **** Tape Subfile: 3 1128 records... Minimum record length: Maximum record length: 8 bytes 4124 bytes **** FILE HEADER **** LDWG .003 1024 *** LIS COMMENT RECORD *** !!!!!!!!!!!!!!!!!! ! !!!!!!!!!!!!!!!!!! ! LDWG File Version 1.000 Extract File: FILE012.HED FILE HEADER FILE NUMBER: RAW MWD Curves and BIT RUN NO: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE MWD $ 3 log header data for each bit run in separate files. 5 .2500 START DEPTH 8147.0 STOP DEPTH 13477.0 # LOG HEADER DATA .. . DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG) MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE DIR MPR GRAM PRES $ BOTTOM) TOOL TYPE DIRECTIONAL MULT. PROP. RES. GAMMA RAY PRESSURE # 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): # . 10-NOV-04 MSB 18704 4.75 MPR MEMORY 13477.0 8147.0 13477.0 o 84.5 92.9 TOOL NUMBER 1490 106032 5058 100646543 6.750 8152.0 OBM 9.15 .0 .0 5000 .0 .000 .000 .000 .000 107.0 .0 .0 .0 .00 .000 .0 o BIT RUN 5 (MWD Run 5). MPR/GR. CURVE GLOSSARY: GRAM - GAMMA RAY APPARENT (MWD-API) ROPA - RATE OF PENETRATION (FPHR) RPCL - DEEP PHASE RESISTIVITY (OHMM) RPSL - MEDIUM PHASE RESISTIVITY (OHMM) RPCH - SHALLOW PHASE RESISTIVITY (OHMM) RPSH - EXTRA SHALLOW PHASE RESISTIVITY (OHMM) RPTH - FORMATION EXPOSURE TIME (MIN) $ REMARKS: # *** INFORMATION TABLE: CONS MNEM VALU -------------------------------- WDFN LCC CN WN FN COUN STAT 1e-168.xtf 150 ConocoPhillips Alaska, I 1E-168 Kuparuk River 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 ROPA ROPA ROP 0.0 RPTH RPTH RPTHM 0.0 * FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame Size is: 32 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: 31 One depth per frame (value= 0) Datum specification Block Sub-type is: 1 FRAME SPACE = 0.250 * F ONE DEPTH PER FRAME Tape depth ID: F 7 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 ROPA MWD 68 1 FPHR 4 4 7 RPTH MWD 68 1 MINS 4 4 ------- 28 Total Data Records: 688 Tape File Start Depth Tape File End Depth Tape File Level Spacing Tape File Depth Units 8147.000000 13477.000000 0.250000 feet **** FILE TRAILER **** Tape Subfile: 4 773 records... Minimum record length: Maximum record length: 8 bytes 4124 bytes **** TAPE TRAILER **** LDWG 05/06/02 01 ~ , . **** REEL TRAILER **** LDWG 05/06/02 AWS 01 Tape Subfile: 5 Minimum record length: Maximum record length: . . 2 records... 132 bytes 132 bytes