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Home My WebLink About204-256Originated: Delivered to:26-Aug-25Halliburton Alaska Oil and Gas Conservation Comm.Wireline & Perforating Attn.: Natural Resource TechnicianAttn: Fanny Haroun 333 West 7th Avenue, Suite 1006900 Arctic Blvd. Anchorage, Alaska 99501Anchorage, Alaska 99518Office: 907-275-2605FRS_ANC@halliburton.comThe technical data listed below is being submitted herewith. Please address any problems orconcerns to the attention of the sender aboveWELL NAME API # SERVICE ORDER # FIELD NAME JOB TYPE DATA TYPE LOGGING DATE PRINTS # DIGITAL # E SET#1 1A-23 50-029-22131-00 910219324 Kuparuk River Plug Setting Record Field- Final 4-Aug-25 0 12 1A-27 50-029-22124-00 910219038 Kuparuk River Plug Setting Record Field- Final 4-Aug-25 0 13 1B-15A 50-029-22465-01 910203865 Kuparuk River Multi Finger Caliper Field & Processed 5-Aug-25 0 14 1C-153 50-029-23549-00 910180480 Kuparuk River Leak Detect Log Field- Final 19-Jul-25 0 15 1C-153 50-029-23549-00 910181004 Kuparuk River Packer Setting Record Field- Final 28-Jul-25 0 16 1G-02 50-029-20813-00 910151017 Kuparuk River Packer Setting Record Field- Final 9-Jul-25 0 17 1J-122 50-029-23359-00 910180477 Kuparuk River Plug Setting Record Field- Final 18-Jul-25 0 18 1L-09 50-029-22025-00 910180917 Kuparuk River Leak Detect Log Field- Final 17-Jul-25 0 19 1L-09 50-029-22025-00 910180917 Kuparuk River Multi Finger Caliper Field & Processed 14-Jul-25 0 110 1L-09 50-029-22025-00 910180917 Kuparuk River Packer Setting Record Field- Final 26-Jul-25 0 1PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF:Fanny Haroun, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518FRS_ANC@halliburton.comDate:Signed:Transmittal Date:T40821T40822T40823T40824T40824T40825T40826T40827T40827T40827191-009190-180204-256215-116182-138207-070190-0348/27/2025Gavin GluyasDigitally signed by Gavin Gluyas Date: 2025.08.27 12:29:56 -08'00'1B-15A50-029-22465-01 910203865Kuparuk RiverMulti Finger CaliperField & Processed5-Aug-2501204-256 C:\Users\grgluyas\AppData\Local\Microsoft\Windows\INetCache\Content.Outlook\4MY18Q6V\2025-07-17_22651_KRU_1B-15A_VividLeakDetect_Transmittal.docx DELIVERABLEDISCRIPTION Ticket # Field Well # API # Log Description Log Date 22651 KRU 1B-15A 50-029-22465-01 VIVID Leak Detect 17-Jul-25 DELIVERED TO Company & Address DIGITAL FILE # of Copies LOG PRINTS # of Prints CD’s # of Copies 1 AOGCC Attn:NaturalResourcesTechnician 333W.7thAve.,Suite100 Anchorage,Ak.99501Ͳ3539 DeliveredBy:CPAISharefile ___________________________________________________________________ DatereceivedSignature ____________________________________________________________________ PLEASE RETURN COPY VIA EMAIL TO: DIANE.WILLIAMS@READCASEDHOLE.COM READ CASED HOLE, INC., 4141 B STREET, SUITE 308, ANCHORAGE, AK 99503 PHONE: (907)245-8951 E-MAIL : READ-Anchorage@readcasedhole.com WEBSITE : WWW.READCASEDHOLE.COM 204-256 T40680 7/24/2025 Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2025.07.24 09:37:31 -08'00' Originated: Delivered to:8-Jul-25Halliburton Alaska Oil and Gas Conservation Comm.Wireline & Perforating Attn.: Natural Resource TechnicianAttn: Fanny Haroun 333 West 7th Avenue, Suite 1006900 Arctic Blvd. Anchorage, Alaska 99501Anchorage, Alaska 99518Office: 907-275-2605FRS_ANC@halliburton.comThe technical data listed below is being submitted herewith. Please address any problems orconcerns to the attention of the sender aboveWELL NAME API # SERVICE ORDER # FIELD NAME JOB TYPEDATA TYPE LOGGING DATE PRINTS # DIGITAL # E SET#1 1B-04 50-029-20595-00 910151309 Kuparuk River Plug Setting Record Field- Final 30-Jun-25 0 12 1B-05 50-029-20237-00 910106098 Kuparuk River Multi Finger Caliper Field & Processed 19-Jun-25 0 13 1B-05 50-029-20237-00 910106098 Kuparuk River Plug Setting Record Field- Final 21-Jun-25 0 14 1B-11 50-029-20657-00 910151309 Kuparuk River Multi Finger Caliper Field & Processed 1-Jul-25 0 15 1B-11 50-029-20657-00 910149873 Kuparuk River Plug Setting Record Field- Final 1-Jul-25 0 16 1B-15A 50-029-22465-01 910106169 Kuparuk River Plug Setting Record Field- Final 20-Jun-25 0 17 1D-101 50-029-22988-00 910151308 Kuparuk River Packer Setting Record Field- Final 6-Jul-25 0 18 1H-103 50-029-23593-00 910082841 Kuparuk River Multi Finger Caliper Field & Processed 21-Jun-25 0 19 1L-24 50-029-22170-00 910151023 Kuparuk River Packer Setting Record Field- Final 28-Jun-25 0 110 2A-16 50-103-20042-00 910150862 Kuparuk River Plug Setting Record Field- Final 27-Jun-25 0 1PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF:Fanny Haroun, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518FRS_ANC@halliburton.comDate:Signed:Transmittal Date:181-065177-001181-136204-256200-183218-003191-066185-147T40642T40643T40643T40644T40644T40645T40646T40647T40648T406497/9/202561B-15A50-029-22465-01910106169Kuparuk RiverPlug Setting RecordField- Final20-Jun-2501Gavin GluyasDigitally signed by Gavin Gluyas Date: 2025.07.09 09:29:07 -08'00' ORIGINATED TRANSMITTAL DATE: 11/14/2024 ALASKA E-LINE SERVICES TRANSMITTAL #: 5160 42260 Kenai Spur Hwy PO BOX 1481 - Kenai, Alaska 99611 FIELD Kuparuk PH: (907) 283-7374 FAX: (907) 283-7378 DELIVERABLE DESCRIPTION TICKET # WELL # API # LOG DESCRIPTION DATE OF LOG 5160 1B-15A 50029224650100 Production Profile (PPROF) 9-Nov-2024 RECIPIENTS Conoco DIGITAL FILES PRINTS CD'S 1 FTP Transfer 0 0 USPS Attn: NSK-69 Richard.E.Elgarico@conocophillips.com 700 G Street Anchorage, AK 99503 Received By: Received By: Signature Signature AOGCC DIGITAL FILES PRINTS CD'S 1 ShareFile 0 0 USPS Attn: Natural Resources Technician II abby.bell@alaska.gov Alaska Oil & Gas Conservation Commision aogcc.data@alaska.gov 333 W. 7th Ave, Suite 100 - Anchorage, AK 99501 Received By: Received By: Signature Signature 204-256 T39765 Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2024.11.14 11:33:28 -09'00' DNR DIGITAL FILES PRINTS CD'S 1 SharePoint Link 0 0 USPS Attn: Natural Resource Tech II DOG.Redata@alaska.gov 550 West 7th Ave, Suite #802 - Anchorage, AK 99501 Delivery Method: USPS Received By: Received By: Signature Signature Please return via e-mail a copy to both: AR@ake- line.com AKGGREDTSupport@ConocoPhillips.onmicrosoft.com ORIGINATED TRANSMITTAL DATE: 11/12/2024 ALASKA E-LINE SERVICES TRANSMITTAL #: 5160 42260 Kenai Spur Hwy PO BOX 1481 - Kenai, Alaska 99611 FIELD Kuparuk PH: (907) 283-7374 FAX: (907) 283-7378 DELIVERABLE DESCRIPTION TICKET # WELL # API # LOG DESCRIPTION DATE OF LOG 5160 1B-15A 50029224650100 0 9-Nov-2024 RECIPIENTS Conoco DIGITAL FILES PRINTS CD'S 1 FTP Transfer 0 0 USPS Attn: NSK-69 Richard.E.Elgarico@conocophillips.com 700 G Street Anchorage, AK 99503 Received By: Received By: Signature Signature AOGCC DIGITAL FILES PRINTS CD'S 1 ShareFile 0 0 USPS Attn: Natural Resources Technician II abby.bell@alaska.gov Alaska Oil & Gas Conservation Commision aogcc.data@alaska.gov 333 W. 7th Ave, Suite 100 - Anchorage, AK 99501 Received By: Received By: Signature Signature 204-256 T39765 Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2024.11.12 10:04:52 -09'00' DNR DIGITAL FILES PRINTS CD'S 1 SharePoint Link 0 0 USPS Attn: Natural Resource Tech II DOG.Redata@alaska.gov 550 West 7th Ave, Suite #802 - Anchorage, AK 99501 Delivery Method: USPS Received By: Received By: Signature Signature Please return via e-mail a copy to both: AR@ake- line.com AKGGREDTSupport@ConocoPhillips.onmicrosoft.com Originated: Schlumberger PTS - PRINT CENTER 6411 A Street Anchorage, AK 99518 (907)273-1700 main (907)273-4760fax Delivered to: AOGCC -. ATTN: Natural Resources Technician II Alaska Oil & Gas Conservation Commision 333 W. 7th Ave, Suite JO0 -" Ilij Anchorage, AK 99501 TRANSMITTALDATE TRANSMITTAL # 2e!- 2 56 30388 WELL NAME 1R-26 3M-26 IR -01B 1R-04 API # 50-029-22193-00 50.029-22431-00 50-029.21404.02 50-029-21407-00 ORDERSERVICE DWUJ-00077 DWUJ-00078 DWUJ-00079 DWUJ-00080 FIELD NAME DESCRIPTION KUPARUK RIVER KUPARUK RIVER KUPARUK RIVER KUPARUKRIVER WL WL WL WLt DELIVERABLE DESCRIPTION EMIT Caliper EMIT EMIT DATA TYPE FINAL FIELD FINAL FIELD FINAL FIELD FINAL FIELD DATELOGGED Prints 2 -Feb -19 4 -Feb -19 5 -Feb -79 6 -Feb -19 r 1 1 1 1F-07 1B -15A 1R-17 50-029.20830-00 50-029-22465-01 50-029-22212-00 E9KH-00003 EA77-00001 EA77-00006 KUPARUK RIVER KUPARUK KUPARUK RIVER WL WL WL PPROF PPROF IP PROF FINAL FIELD FINAL FIELD FINAL FIELD 9 -Feb -19 12 -Feb -19 13 -Feb -19 1 1 1 7 A Transmittal Receipt signature confirms that a package (box, lIJ o LLL/// envelope, etc.) has been received and the contents of the X package have been verified to match the media noted above. The Print Nam Signature Date specific content of the CDs and/or hardcopy prints may or may Please return via courier or sign/scan and email a col o Schlumberger and CPAI. nthave been verified for correctness or quality level at this ,,._ _ _ point. Schlumberger -P r ivat: �G •• csi 0 ... ,..1.r: - a, y A CC cu ,Z v C WV W CU v O 7 N Z a Q _ Q W '4 a) a) O -J m In w C _c c < y O C Q) ro 1-r _ V a u N E �; O Q c �O p o 76 Ci ( 0 fl_ Q Lu (o m (o (o m 0 (0 s o v E s CO 0 +J ^ 4-, `� + C C C C C ' y N O +' .„ — a _. Q f6 c C 7 c 7 7 3 L C C (p _ 2.. W -0 •- Q > V1.. F- M CV ..... 0) N CO 0) CNIN N `= ? (/'f Z:' Q N C M O Q N Q g` OU Q) E UU 4 1:2 76 ~'sii ...et 7 N 4- f0 7 to0 0 0 0 0 0 0 0 0 c}o• N u a J J J J J J J J J C i 4-, I- ' }} W W W W W W W LU W on c co 0 0 .-- F LL LL LL LL LL LL LL LL LL V) N E - N o < J J J J J J J J J a O C E0 ;- - Q Q Q Q Q Q Q Q Q Z Q Z Z Z Z Z Z Z Z Z V N- , U .. O) p LL LL LL LL LL LL LL LL LL N -C u N tS N CO 0 > i-. O OO z E a N O 0 RS o O C v V I. 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N N N r N 0 0 •V) 0 .N.. a N N N N N N N N v F.: Q O O O O O O M M 0 p - N N N N N N0 0 N 01 0 0- 0 0 0 O 0) `� 0 0 0 0 0 0 0 O -,..Y• N O in in U) N N N c a Er, Q� iii roQ o c Q1 y > v aa W Y W c 9 4 2 n c < Iry � mMQQNmY p a E u f F3.7 u W M M •r N U N z h Y IP ca c f0 rn 8 L 1 v rp t- a a a S • STATE OF ALASKA • ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon fl Rug Perforations r Fracture Stimulate r Pull Tubing r Operations shutdow n r Performed. Suspend r Perforate fl Other Stimulate r Alter Casing rChange Approved Program Rug for Redrill r Perforate New Pool r Repair Well r Re-enter Susp Well r Other: Tubing patch 17 2.Operator Name: 4.Well Class Before Work: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Development 1 Exploratory 1' 204-256 3.Address: 6.API Number: Stratigraphic f Service '°" P. O. Box 100360,Anchorage,Alaska 99510 50-029-22465-01 7.Property Designation(Lease Number): 8.Well Name and Number: ADL0025648 KRU 1B-15A 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pool(s): N/A Kuparuk River Field/Kuparuk River Oil Pool 11.Present Well Condition Summary: Total Depth measured 8621 feet Plugs(measured) None true vertical 6607 feet Junk(measured) None Effective Depth measured 8452 feet Packer(measured) 7891, 8119 true vertical 6452 feet (true vertical) 5988, 6168 Casing Length Size MD TVD Burst Collapse CONDUCTOR 85 16 121 121' SURFACE 4150 9.625 4191 4138' PRODUCTION 4368 7 4405 4324' scAtNED DEC 0 G 2616 E Perforation depth: Measured depth: 8408'-8417', 8432'-8452' '�'�l 0 I True Vertical Depth: 6412'-6420', 6434'-6452' A.OG CC Tubing(size,grade,MD,and TVD) 3.5, L-80, 8119 MD, 6168 TVD 26' Retrievable TTS PIIP patch from 7818' -7844' Packers&SSSV(type,MD,and TVD) TRDP-CAMCO TRM-5E SSSV @ 1484 MD and 1483 TVD PACKER-BAKER SAB-L3 PACKER @ 7891 MD and 5988 TVD SEAL ASSY-BAKER BULLET SEAL ASSEMBLY @ 8119 MD and 6168 TVD 12.Stimulation or cement squeeze summary: N/A Intervals treated(measured): Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation _ _ N/A N/A N/A N/A N/A Subsequent to operation N/A N/A N/A N/A N/A 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations r Exploratory fl Development 17 Service r Stratigraphic Copies of Logs and Surveys Run 16.Well Status after work: Oil Gas r WDSPL fl Printed and Electronic Fracture Stimulation Data n GSTOR r WINJ r WAG r GINJ f SUSP r SPLUG 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 Brent Rogers/Kelly Lyons Email: N1617(a,conocophillips.com Printed Name Brent Rogers Title: Problem Well Supervisor SignatureOdPhone:659-7224 Date: June 06,2016.../4,/ic,-- 1171" :/f/ It Form 10-404 Revised 5/2015 7 . ��6 RBDMS V' JUN 0 8 2016 Submit Original Only • ConocoPhiIIips Alaska P.O. BOX 100360 RECEIVED ANCHORAGE,ALASKA 99510-0360 _}U N 0 8 2016 Ac June 6, 2016 Ms. Cathy Foerster Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Dear Commissioner Foerster, Enclosed please find the 10-404 Report of Sundry Operations for ConocoPhillips Alaska, Inc. KRU well 1B-15A (PTD 204-256). This report is for a 26' retrievable patch set to repair a tubing leak above the top packer. Please call Kelly Lyons or myself at 659-7224 or Dusty Freeborn/Jan Byrne at 659- 7126 if you have any questions. Sincerely, 14)//47 Brent Rogers Problem Well Supervisor Attachments • • 1B-15A DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary 05/28/16 PULLED CATCHER &2.75"XX PLUG © 8034' RKB; BRUSH & FLUSH TBG f/7800' - 7880' RKB. DRIFT TBG W/24' x 2.74" DMY PATCH DRIFT TO 7850' SLM. READY FOR E/L. 06/04/16 SET 2.72" PARAGON II LOWER PACKER (ser#cpp35071) @ 7844' RKB.SET TTS TEST TOOL IN LOWER PACEKR © 7844' RKB.LRS PERFORMED CMIT TO 2500 PSI,PASSED.PULLED TEST TOOL FROM 7844' RKB.SET 2.72" UPPER PARAGON II PACKER (ser#cpp 35075) W/21.52" SPACER PIPE &SNAP LATCH INTO LOWER PACKER @ 7818' RKB.JOB IN PROGRESS. PRE MIT T/I/0=490/190/200 INITIAL T/I/0=2500/2160/220 15 MINS T/I/0=2460/2130/220 30 MINS T/I/0=2450/2120/220 06/05/16 SET TTS TEST TOOL @ 7818' RKB.LRS PERFORMED MIT-T TO 2500 PSI,PASSED.R/U ON IA FOR CMIT TO 2500 PSI,PASSED.PULLED TTS TEST FROM 7818' RKB.WELL READY TO POP. PRE MIT T/I/0=1650/100/200 INITIAL T/I/0=2500/100/200 15 MINS T/I/0=2450/100/200 30 MINS T/I/0=2430/100/200. CMIT PRE MIT T/I/0=2430/100/200 INITIAL T/I/0=2625/2500/200 15 MINS T/I/0=2600/2450/200 30 MINS T/I/0=2580/2450/200 Summary Set a 26' retrievable TTS Paragon Patch from 7818' -7844'. All of the components were tested and passed upon installation and the passing CMIT TxIA once the patch was set proved up patch integrity. KUP PROD • 1B-15A I", r ConocoPhilhips t Well Attributes Max Angle&MD TD Alaska,Inc. Wellbore API/UWI Field Name Wellbore Status ncl(°) MD(ftKB) Act Btm(ftKB) - „;,,....,m 500292246501 KUPARUK RIVER UNIT PROD 70.89 5293.60 8,621.0 ..- Comment 1/20(ppm) Date Annotation End Date KB-Grd(ft) 'Rig Release Date 18-151/,6/620162.17:36 PM SSSV:TRDP 100 11/8/2014 Last WO: 9/2/2005 41.01 4/15/1994 Vertical schematic(actual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date HANGER 31 s 1 I J Last Tag:SLM 8,237.0 8/15/2015 Rev Reason:SET 2 PACKERS pproven 6/6/2016 .. w„„,,,,, Casing Strings Ad,/ _ r h.r ( )CONDUCTORion OD in 16 ID(1)5.062 Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread 36.0 121.0 121.0 62.50 H-40 WELDED Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)...Wt/Len(I...Grade Top Thread CONOUCTOR;36.0-1210-I j SURFACE 95/8 8.835 41.0 4,190.5 4,138.4 40.00 L-80 BTC Casing Description OD(in) ID On) Top(ftKB) Set Depth(ftKB) Set Depth(ND)...Wt/Len(I...Grade Top Thread PRODUCTION 7 6.276 37.0 4,405.0 4,3242 26.00 L-80 BTC-M SAFETY VLV;1,483.8 1 POST S/T Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...WtlLen(I...Grade Top Thread ----- L3 WINDOW 6 5.000 8,227.0 8,235.0 6,263.4 18.00 Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread GAS LIFT,2,6332 L2 WINDOW 6 5.000 8,289.0 8,296.0 6,315.1 18.00 Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread L1 WINDOW 6 5.000 8,340.0 8,347.0 6,358.8 18.00 Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread GAS LIFT;3,9047 - ',.; LINERATOP 51/2 4.950 4,234.6 8,350.0 6,361.3 15.50 L-80 Hydril511 Liner Details Nominal ID 1 Top(ftKB) Top(VD)(ftKB) Top Incl(°) Item Des Com (in) 4,234.6 4,176.7 29.93 TIE BACK BAKER LINER TIEBACK SLEEVE 5.500 SURFACE;410-4,190.5 • 4,241.0 4,182.2 29.94 PACKER BAKER'CHP'LINER TOP PACKER 4.870 4,245.4 4,186.0 29.94 HANGER BAKER'HMC'LINER HANGER 4.920 I ] Casing Description IOD(in) IID(in) Top(ftKB) lSet Depth(ftKB) I Set Depth(ND)...I WtlLen(I...I Grade ITop Thread LINERA BTM 31/2 2.897 8121.1 8,621.0 9.20 L-80 Hydril511 PRODUCTION POST Sir; Liner DetaIIS 37.0-4,405.0 Nominal ID '--' Top(ftKB) Top(TVD)(ftKB) Top Incl r) Item Des Com (in) GAS LIFT;5,0047 -- 8,121.1 6,169.7 35.69 TIE BACK BAKER LINER TIE-BACK SLEEVE 4.130 Ig 8,139.5 6,184.7 35.49 PACKER BAKER ZXP LINER TOP PACKER 3.410 8,147.9 6,191.5 35.40 PBR POLISH BORE NIPPLE 3.230 GAS LIFT;6,979.3 8,152.0 6,194.9 35.36 HANGER BAKER'HMC'LINER HANGER 2.920 Tubing Strings Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft..Set Depth(TVD)(...Wt(Ib/ft) Grade Top Connection TUBING WO 2005 31/2 2.992 31.5 8,081.4 6,137.6 9.30 L-80 IBT GAS LIFT;7,823.6 Completion Details PATCH;7,817.2 Nominal ID Top(ftKB) Top(ND)(ftKB) Top Inc'(°) Item Des Com (in) PATCH;7,844.0 I I 31.5 31.5 0.06 HANGER FMC GEN IV TUBING HANGER 2.992 1,483.8 1,483.3 1.59 SAFETY VLV CAMCOTRM-5ESSSV-2.81 XPROFILE 2.812 PBR;7,876.5 WI 7,876.5 5,977.5 43.10 PBR BAKER 80-40 PBR 3.000 PACKER;7,890.5 - 7,890.5 5,987.8 42.33 PACKER BAKER SAB-L3 PACKER 2.800 8,033.6 6,099.1' 36.78 NIPPLE HES'X'NIPPLE 2.750 NIPPLE;8,0338 8,078.1 6,134.9 36.15 OVERSHOT BAKER POOR BOY OVERSHOT,SWALLOWED 6'OF 3.870 ORIGINAL COMPLETION TUBING STUB Tubing Description !String Ma...I ID(in) Top(81/0) 1Set Depth 18..1 Set Depth(ND)I...I Wt(Ib/ft) (Grade Top Connection TUBING Original 31/2 2.992 8,081.3 8,134.8 6,180.9 9.30 L-80 EUESrd OVERSHOT;8,078.1 i? Completion.Details €i Nominal ID Top(ftKB) Top(ND)(ftKB) Top Incl(°) Item Des Corn (in) LOCATOR;8,118.8 8,118.9 6,167.9 35.71 LOCATOR BAKER NO GO LOCATOR 2.970 SEAL ASSY;8,119.4 1););;;;. 8,119.4 6,168.3 35.71'SEAL ASSY BAKER BULLET SEAL ASSEMBLY 2.990 Am Other In,Hole(Wireline retrievable',plugs,valves,pumps,fish,etc.) 1 Top(ND) Top Incl Top(ftKB) (ftKB) (°) Des Com Run Date ID(in) 7,817.2 5,935.5 46.49 PATCH 2.72"UPPER PARAGON II PACKER(ser#cpp 6/4/2016 1.625 35075)W/21.52"SPACER PIPE&SNAP LATCH t, D INTO LOWER PACKER i i 7818'RKB(OAL=26.88) 7,844.0 5,954.2 44.96 PATCH 2.72"PARAGON II LOWER PACKER(ser# 6/4/2016 1.625 N ) cpp35071) (OAL=4.01') L3 WINDOW;8,227.0-8,235.0 IA 8,292.0 6,311.7 31.48 L2 Whipstock L2 LXS FLOW-THRU WHIPSTOCK 10/13/2005 1.992 8,343.0 6,355.3 30.93 L1 Whipstock'L1 LSC FLOW-THRU WHIPSTOCK TO L1 9/27/2005 - 1.992 8,498.0 6,493.8 23.61 RETAINER 3.5"LINER HES 3.5"EZ DRILL RETAINER 3/3/2005 c; D Perforations&Slots Shot . Dens L2 Whipstock 8,292.0 Top(ND) Btm(ND) (shots/f s. Top(MB) Btm(ftKB) (ftKB) (ftKB) Zone Date t) Type Com L2 WINDOW;8,289.0-8,296.0 lk8,408.0 8,417.0 6,412.0 6,420.0 A-5,1B-15 7/25/2005 6.0 IPERF 2.5"HMX PJ,60 deg phase r'i iI 8,432.0 8,452.0 6,433.6 6,451.8 A-4,1B-15 3/28/2005 6.0 PERF Alternating PJ&PF charges I Stimulations&Treatments LINER AL1;8,334.1-9,700.0 Min Top Max Btm L1 Whipstock 8,343.0 Depth Depth Top(TVD) Btm(TVD) (8KB) (ftKB) (ftKB) (ftKB) Type Date Coo L1 WINDOW;8,340.0-8,347.0 8,432.0 8,452.0 6,433.6 6,451.8 FRAC 5/14/2005 FRAC w/180,000#16/20 LINER A TOP;4,234.6-8.3500 Mandrel Inserts St !PERF;8,408.0-8,417.0 I ati FRAC;8,4320 on Top(ND) Valve Latch Port Size TRO Run PERF;8,432.0-8,4520 N Top(RKB) _ (ftKB) Make Model OD(in) Sery Type Type (in) (psi) Run Date Com �- I 1 2,633.2 2,632.2 CAMCO KBUG- 1 GAS LIFT GLV BK 0.156 1,279.0 4/27/2016 M 2 3,904.7 3,882.5 CAMCO KBUG- 1 GAS LIFT GLV BK 0.156 1,258.0 4/27/2016 M RETAINER;8,4980 II 'i. 3 5,094.7 4,792.3 CAMCO KBG-2- 1 GAS LIFT GLV INT 0.188 1,287.0 4/27/2016 LINER A BTM;8,121.1-8,621.0 I 9 SLOTS;8,449.0-8,957.0 LINER AL2;8,258.1-10,895.0 _ GA WELL LOG TRANSMITTAL# DATA LOGGED 2.1 l /201$ K.BENDER To: Alaska Oil and Gas Conservation Comm. January 8, 2016 Attn.: Makana Bender 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Production Profile: 1B-15A Run Date: 10/19/2016 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Fanny Sari, Halliburton Wireline &Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 FRS_ANC@halliburton.com 1B-15A Digital Data in LAS format, Digital Log Image file, Interpretation Report 1 CD Rom 50-029-22465-01 Production Profile Log 1 Color Log 50-029-22465-01 ' PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline &Perforating Attn: Fanny Sari 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-275-2605 Fax: 907-273-3535 FRS_ANC@halliburton.com Date: Signed: I5ecttMdz 'e'er · . 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. Q Q l.t - ~50 Well History File Identifier Organizing (done) o Two-sided 11111111111111" III o Rescan Needed 11111111111 II 11I111 RESCAN ~olor Items: o Greyscale Items: DIGITAL DATA yØ'6iskettes, No. 1 o Other, No/Type: OVERSIZED (Scannable) o Maps: o Other Items Scannable by a Large Scanner o Poor Quality Originals: o Other: OVERSIZED (Non-Scannable) o Logs of various kinds: NOTES: BY: ~ o Other:: Date If-l ri'J / 0 7 III 11111111111 111/1 Date lJ-j /ó 107 /,/ mp L~ x 30 = C¡D + d... = TOTAL PAGES J 1/ Dale L/-j/3f 0 7 (Count does not ;~~ude cov", 'heel) Y11 f III 11111111111111/1 151 mf Project Proofing BY: ~ Scanning Preparation BY: ~ Production Scanning Stage 1 Page Count from Scanned File: I d- (Count does include cover sheet) Page Count Matches Number in Scanning Preparation: V YES ~ Dale 4-/13/07 If NO in stage 1, page(s) discrepancies were found: YES NO Stage 1 151 rv¡ f NO BY: BY: Maria Date: 151 1/11111111111111111 Scanning is complete at this point unless rescanning is required. ReScanned 1111111111111111111 BY: Maria Date: 151 Comments about this file: Quality Checked 1111111111111111111 10/6/2005 Well History File Cover Page.doc ConocoPhillips P.O. BOX !00360 ANCHORAGE, ALASKA 99510-0360 August 27, 2008 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7~' Avenue, Suite 100 Anchorage, AK 99501 Dear Mr. Maunder: ~o~ 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 a corrosion inhibitor, engineered to prevent water from entering the annular space. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treatments took place and meets the requirements of form 10-404, Report of Sundry Operations. The cement top jobs were performed between June 23, 2008 and August 24, 2008. The corrosion inhibitor/sealant was pumped on August 27, 2008. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please call me at 907-659-7043, if you have any questions. Sincerely, // i~~~~ M.J. oveland ConocoPhillips Well Integrity Projects Supervisor ~~.1V~~ SAP 0 ~ 20a8 REC~~ N ~~ SEP 0 2 2008 Alaska Cif & Gas Cons. Commission Anchorage ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) a®~ Date ~~ Kuparuk Field 8/27/2007 Well Name PTD # 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 1A-23 191-009 12" na 12" na 6.80 8/27/2008 1A-24 200-1'81 6" na 6" na 2.55 8/27/2008 1A-28 191-002 8" na 8" na 1.70 8/27/2008 1 B-13 194-055 24" na 24" na 8.50 8/27/2008 1 B-15a 204-256 SF na SF na 8.50 8/27!2008 1 B-16 194-037 21' 8" 4.00 25" 8/24/2008 6.80 8/27/2008 1 B-17 194-045 6' S" 1.00 28" 8/24/2008 5.10 8/27/2008 1 D-134 198-111 SF na SF na 2.55 8/27/2008 1D-135 197-184 SF na SF na 1.70 8/27/2008 1 D-141 a 208-016 16' 1.40 3' 6/23/2008 9.35 8/27/2008 • • u.., ~:~r. MICRt~FILMED 03/01 /2008 DO N4T PLACE ANY NEW MATERIAL UDDER THIS PAGE F:\I.aserFiche\CtirPgs_Inserts\Microfiltn Mazker.t~c . . WELL LOG TRANSMITTAL ~-~-~._....:.;:..,;~ ' , ProActive Diagnostic Services, Inc. To: AOGCC Christine Mahnken 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 (907) 659-5102 RE : Cased Hole/Open Hole/Mechanical Logs and / or Tubing Inspection(Caliper / MTI) The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention of : ProActive Diagnostic Services. Inc. Attn: Robert A. Richey 130 West International Airport Road Suite C Anchorage. AK 99518 Fax: (907) 245-8952 1 R<#JUT"1. 1G"0£ 18-15A Magnetic Thickness 17-May-07 1) 2) 3) 4) 5) 6) 7) 5GANNED MAY 2 9 2007 .;;) cff - dE; ro -tf is,S-::;' ~--_.' ""- . Signed: C-v&}~ Date : 1!. Print Name: (\~ r~~-H IA p 1l^.ø-1A 't If ~Lq PRoAcTIVE DIAGNOSTIC SERVICES, INC., 130 W. INTERNATIONAL AIRPORT Ro SUITE C, ANCHORAGE, AK 99518 PHONE: (901)245-8951 FAX: (901)245-8952 E-MAIL: ?DS.~NCHCRi~GEtWMEMORYt(lG.COM WEBSITE: ~:}PJ\r\P}.;J1Er~lCR'Y~~'::G.C{),¡¡¡ì D:lMasrer _Copy _00_ PDSANC-2Oxx\Z_ W ord\Dístribution\Transmittal_ Sheets\TrnnsmiC OriginaI.doc \ ~ VVlÅ DATA SUBMITTAL COMPLIANCE REPORT 3/12/2007 Permit to Drill 2042560 Well Name/No. KUPARUK RIV UNIT 1 B-15A Operator CONOCOPHILLlPS ALASKA INC MD 8621 TVD 6607./ Completion Date 2/16/2005 Completion Status i-OIL Current Status i-OIL . - - ------~--------- . -,. .~ ~_. ---_.--- . ~~- - -- -- .------ ---------- ----------------.----- REQUIRED INFORMATION SfZ~.l J0 J"" ~ \~ API No. 50-029-22465-01-00 UIC N - - ---------------------- ---~-------- Dir_ectiona~~_urvey_~ . ________.__________n__ Mud Log No Samples No ~-----~ ..------- DATA INFORMATION Types Electric or Other Logs Run: GR/Res, SCMT Well Log Information: (data taken from Logs Portion of Master Well Data Maint ROP DGR EWR DGR EWR plus Graphics cememt bond log/slim cement map tool G R/EWR4/ AS I/CN P /S LD/R OP/MWD G R/EWR4/ AB I/CN P /S LD/R OP/MWD CEMENT BOND LOG/SLIM CEMENT MAP TOOL 4375 8621 Open 1/29/2007 LIS Veri, GR, DRHO, FET, NPHI, RHOS, NCNT, ROP w/Graphics Log/ Data Digital ¡ÿ!~p_ DMed/Frmt Asc ~. C Lis Electr Dataset Number Log Log Run Interval OH/ Scale Media No Start Stop CH Received -----""". 4166 8621 Open 4/27/2005 4405 8621 Open 2/22/2006 Name Directional Survey 13693 Induction/Resistivity 'jog Cement Evaluation Col 5 7990 8540 2/28/2005 4375 8565 Open 3/16/2005 4375 8565 Open 3/16/2005 7970 8476 4/28/2005 ~ Lis 13080 Induction/Resistivity ~ 13080 LIS Verification Cement Evaluation 5 Col ~.. C Las 14430 Induction/Resistivity .n~_ __. ~~______ Well Cores/Samples Information: Name Interval Start Stop Sample Set Number Comments Sent Received ADDITIONAL INFORMATION Well Cored? Y /~ Chips Received?, V / M Daily History Received? WN (9/N Formation Tops Analysis Received? x:..L.bL- - Comments - - ------------------- it Permit to Drill 2042560 DATA SUBMITTAL COMPLIANCE REPORT 3/12/2007 Well Name/No. KUPARUK RIV UNIT 1B-15A API No. 50-029-22465-01-00 MD 8621 TVD 6607 Comments: - ____..________._u___ , __ _____________._,._ Compliance Reviewed By:_______ Operator CONOCOPHILLlPS ALASKA INC Completion Date 2/16/2005 Completion Status i-OIL Current Status i-OIL UIC N n/io- _ _ _________.._ m.·..___.____________.... ----~-----~----- - -----------...---" - --------lJ:-;;---------- Date: ---LQ_L~¿-~7 -- e . . WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Corom. Attn.: Librarian 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 November 14, 2006 RE: MWD Formation Evaluation Logs: IB-15A, lC-21_Ll_L2_L3, ID-28_L1, IF-OlA, 3F-19A,3H-14B. The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Rob Kalish, Sperry Drilling Services, 6900 Arctic Blvd., Anchorage, AK 99518 IB-15A: dùt.../ -d5"0 11: 1'-!¿..1:3D Digital Log Images: 50-029-23465-01 ~- IDd. /)D6"'-034 f)OS'" -I DO. 90S -I 0 I Î 90 - cI I ¡ I'-ILI ~/-/ 1443f) 1'-/'-/310 1~/t.13?- 1 CD Rom lC-21 Ll L2 L3: - - - Digital Log Images: 50-029-23253-00, 60, 61, 62 1 CD Rom ID-28 Ll: Digital Log Images: 50-029-23237-00, 60 ;)6</ -~37 / '-/L.¡(3'd f}O'! -.;)3'1> /4.1t./33 1 CD Rom IF-OIA: dOS- -0;;;9 d /4L/f}?) Digital Log Images: 50-029-20889-01 3F-19A: {)()I..( -ÖlCo P-/L¡t.¡ 31 Digital Log Images: 50-029-22680-01 1 CD Rom 1 CD Rom 3H-14B: 066 -Odl ;tt 14¿/¿;fì Digital Log Images: 50-103-20092-02 1 CD Rom I( . . WELL LOG TRANSMITTAL ;]04 - 2~lL, To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West ih Ave., Suite 100 Anchorage, Alaska 99501 February 16, 2006 )3 U1i3 RE: MWD Formation Evaluation Logs IB-15A, The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Rob Kalish, Sperry Drilling Services, 6900 Arctic Blvd., Anchorage, AK 99518 907-273-3500 IB-lSA: LAS Data & Digital Log Images: 50-029-22465-01 1 CD Rom 4(% ~19'9'ID0 . . Jim Ennis Wells Group Engineer Drilling & Wells ConocÓÂ,illips P. O. Box 100360 Anchorage, AK 99510-0360 Phone: 907-265-1544 October 25, 2005 R12C O 'l2lv~r~ Cr 2'<>""" 4/aska Oil 6 2005 & Gas Coo>:> An h "0 c oragG Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Subject: Reports of Sundry Well Operations for 1 B-15A Dear Commissioner: ConocoPhillips Alaska, Inc. submits the attached Reports of Sundry Well Operations for the recent workover on the Kuparuk well 1 B-15A. If you have any questions regarding this matter, please contact me at 265-1544. Sincer~,., ¿~ \:.~~ J. Ennis Wells GroLp Engineer CPAI Drilling and Wells J E/skad 1. Operations Performed: . RECEIVED STATE OF ALASKA OCT Z005 ALASKA OIL AND GAS CONSERVATION COMMISSION 2 6 REPORT OF SUNDRY WELL OPERA TIONSaska Oil & Gas Cons. Commission Stimulate 0 Other AncMrage Waiver 0 Time Extension 0 Re-enter Suspended Well 0 . Abandon 0 Alter Casing 0 Repair Well 0 Pull Tubing 0 Operat. ShutdownD Change Approved Program 0 2. Operator Name: ConocoPhillips Alaska, Inc. 3. Address: P. O. Box 100360, Anchorage, Alaska 99510 7. KB Elevation (ft): RKB 34' 8. Property Designation: ADL25648, ALK 466 11. Present Well Condition Summary: Total Depth Effective Depth Casing Structural CONDUCTOR SURFACE PRODUCTION LINER LINER feet feet 8432' feet feet MD 121' 4190' 4405' 8350' 8621' measured 8621' 6607' 7" Plug Perforations 0 Perforate New Pool 0 Perforate 0 4. Current Well Status: Development 0 Stratigraphic 0 Exploratory Service o o 5. Permit to Drill Number: 204-256 / 6. API Number: 50-029-22465-01 true vertical measured true vertical Length Size 9. Well Name and Number: 1B-15A 10. Field/Pool(s): Kuparuk River Field / Kuparuk Oil Pool Plugs (measured) retainer @ 8498' Junk (measured) TVD Burst Collapse 80' 4156' 4324' 4116' 500' 16" 9-5/8" 121' 4138' 4324' 6361' 6607' Perforation depth: Measured depth: 8208'-8218',8281'-8296',8305'-8307', 8506'-8510' (cement squeezed) 8408'-8417',8432'-8452' (production perfs) true vertical depth: 6241'-6249',6302'-6315',6323'-6325',6501'-6505' 6412'-6420',6434'-6452' Tubing (size, grade, and measured depth) 3-1/2" , L-80, 8121' MD. 5-1/2" 3-1/2" Packers & SSSV (type & measured depth) Baker 'CPH' liner top pkr and Baker 'ZHP' liner top pkr@ 4241',8140' SSSV= Cameo TRM-4E Safety Valve @ 1833' 12. Stimulation or cement squeeze summary: Intervals treated (measured) 13. Treatment descriptions including volumes used and final pressure: nla RBDMS BFL OCT 2 6 2005 Representative Daily Average Production or Injection Data Gas-Mef Water-Bbl 1645 13 844 580 15. Well Class after proposed work: Exploratory 0 Development 0 Service 0 16. Well Status after proposed work: Oil0 GasD WAG 0 GINJD WINJ 0 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. I Sundry Number or N/A if C.O. Exempt: Oil-Bbl 368 1445 Prior to well operation Subsequent to operation 14. Attachments Copies of Logs and Surveys run _ Daily Report of Well Operations _X Contact Jim Ennis @ 265-1544 Printed Name EIS Signature . '- ;.. Form 10-404 eVlsed 04/2004 Casing Pressure Tubing Pressure 147 173 WDSPL 0 Title Phone Wells Group Engineer ~ i Date ., 0 J.. '5'. d ('" Preoared bv S aron A suo-Drake 263-4612 Submit Original Only URIGINAL . . Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 18-15 18-15 WORKOVER/RECOMP Nabors 3S Start: Rig Release: Rig Number: 8/19/2005 9/2/2005 Spud Date: 9/28/2005 End: 9/2/2005 Group: 8/20/2005 00:00 - 02:00 2.00 MOVE DMOB MOVE Continue to prep rig for move. 02:00 - 10:30 8.50 MOVE MOB MOVE Rig left 2T-23 at 02:00 hrs moving to 1 B-15, arrived on pad @ 10:30 hrs. 10:30 -16:30 6.00 MOVE POSN MOVE Attempt to spot rig over well. Flow line, wing valve on adjacent well and well house support had to be moved. 16:30 - 18:00 1.50 MOVE POSN MOVE Pull rig off wellhead, set rig mats, lay herculite, stage BOP's behind rig. 18:00 - 19:00 1.00 MOVE POSN MOVE Spot sub, pits, and mats under same 19:00 - 22:00 3.00 MOVE POSN MOVE Lay herculite and berm around pits & sub,work on leveling jack. 22:00 - 00:00 2.00 MOVE POSN MOVE Level sub and spot pipe shed, hook up lines 8/21/2005 00:00 - 01 :30 1.50 MOVE RURD MOVE Raise derrick, piant line on tree, tubing head adapter, and tubing head Take pictures of tree position for reference at end of workover. Accept Rig @ 01 :30 hrs. 8/21/2005. 01 :30 - 05:00 3.50 MOVE RURD MOVE Ready pits for brine, load pits with 200 bbls of 9.7 brine. Check well for press. ND wellhead, Inspect lift threads and MU blanking 05:00 - 12:30 7.50 WELCTL NUND DECOMP Start NU BOP, Function test BOPE. Pressure test rams to 250 /3000 psi, annular to 250 / 2500 psi. Witnessing waived by AOGCC (John Krisp). 12:30 - 15:30 3.00 WELCTL NUND DECOMP RD test tools. Pull blanking plug. Pull BPV. BOLDS. 15:30 - 19:00 3.50 WELCTL NUND DECOMP Unland tubing hanger, Attempted to pull tubing from PBR. Staged our way up to 165K with no movement. Repeated this effort for 1 hr. RD head pin and prep for E-line to run chemical cutter. Pulled 10k over string weight, set slips. 19:00 - 00:00 5.00 WELLSR OTHR WRKOVR E-line on location, held pre- job safety meeting, begin rigging up E-line for chemical cut. 8/22/2005 00:00 - 00:45 0.75 WELLSR OTHR WRKOVR Continue rigging up E-Line 00:45 - 02:30 1.75 WELLSR OTHR DECOMP RIH w/ tool assembly/ 2.125" chemical cutter to 8065' cut depth, 15' up full joint of tubing above "D" nipple, fire cutter, all indicators were good, POOH w/ cutter 02:30 - 04:00 1.50 WELLSR OTHR DECOMP Hung up btm two GLM's, able to work free, started hanging up in collars at 3200', work free, hung up in Frac sleeve @ 1810' 04:00 - 06:00 2.00 WELLSR OTHR DECOMP Pump down tubing at 2 bpm, unable to free tools, try reverse circulate, unable to free tools, pull on E-line in stages to 3600#, pull out of rope socket, on surface with wire. 06:00 - 07:00 1.00 WELLSR NUND DECOMP Rig down E-line. Install head pin in TIW valves. 07:00 - 07:30 0.50 CMPL TN PULL DECOMP Picked up on tubing to string wi. tubing not cut completelly. Picked up to 115K and pulled free. 07:30 - 08:30 1.00 CMPLTN CIRC DECOMP Pulled hanger to rig floor and circulated 9.7 ppg brine bottoms up. Rig I up control line spooler. 08:30 - 21 :30 13.00 CMPLTN CIRC DECOMP NO hanger and began pulling and standing back completion tubing in derrick drifting as we pull, spooling up control line. LD SSSV, NORM tested and sent to Cameo for re-build. Continue pulling out of hole. On surface tubing. Chemical cut @ 16.80 of full joint of tubing below GLM 5#. Good clean cut. 21 :30 - 23:30 2.00 WELLSR SUN DECOMP Begin rigging up slickline to fish E-Line tool string with cutter. 23:30 - 00:00 0.50 WELLSR SUN DECOMP RIH w/ slickline to fish E-line cutter I Fish E-line toolstring with chemical cutter @ 8040', full recovery. 8/23/2005 00:00 - 01 :30 1.50 WELLSR SUN DECOMP 01 :30 - 02:00 0.50 WELLSR SUN DECOMP Rig down slickline 02:00 - 05:00 3.00 FISH RURD DECOMP Install wear ring, MU BHA assembly (overshot,jars,bumper sub, drill collars) 05:00 - 12:30 7.50 FISH TRIP DECOMP RIH w/ workstring (L-80) and fishing BHA to 8064' 12:30 - 13:00 0.50 FISH TRIP DECOMP Tag top of liner top packer. Rotate to make it by. Worked pipe several times while utilizing floor slips locked into rotary table. 13:00 - 17:30 4.50 FISH TRIP DECOMP Continue to RIH. I Printed: 10/20/2005 3:40:04 PM . . Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 8-15 1 8-15 WORKOVER/RECOMP Nabors 3S Start: 8/19/2005 Rig Release: 9/2/2005 Rig Number: Spud Date: 9/28/2005 End: 9/2/2005 Group: 8/23/2005 17:30 - 18:15 0.75 FISH CIRC DECOMP Circulate well volume prior to fish engagement. 18:15 - 00:00 5.75 FISH JAR DECOMP Up weight 52K. Engage tubing stub. Begin jarring on fish at 90k. Staging jar weight up to 105K. Staging straight pull up to 165K. Move fish initally approximately 4'. No movement last several hours. Performed derrick inspection. 8/24/2005 00:00 - 01 :00 1.00 FISH JAR DECOMP Continue jarring on tubing stub, no movement. 01 :00 - 03:00 2.00 FISH CPBO DECOMP Rig down head pin, Release overshot from tbg stub 03:00 - 07:00 4.00 FISH TRIP DECOMP POOH w/ L-80 tubing string standing back 07:00 - 08:45 1.75 FISH TRIP DECOMP Change of scope. Begin laying down 3 1/2" 8rnd EUE production pipe from this point. Plan is to re-complete well with SC 3 1/2" IBT production tubing in the 5.5" liner for future work. Strapping PH-6 work string in pipe shed for fishing program. This will also leave enough room in the derrick for standing back work string. 08:45 - 09:15 0.50 FISH TRIP DECOMP Lay down machine KO finger broke. Begin manual operations after calling out welder from Prudhoe. Down time on rig 30 min. 09:15 - 12:15 3.00 FISH TRIP DECOMP Continue to pooh in manual mode on lay down machine. 12:15 - 13:50 1.58 FISH PULD DECOMP Begin standing back BHA. Begin breaking jars and lower BHA. 13:50 - 14:10 0.33 FISH OTHR DECOMP OOH. Load pipe shed with remaining PH-6. Strap and drift. 14:10 - 17:00 2.83 FISH OTHR DECOMP Strap and drift PH-6. Unable to perform this due to laying dwn sideways while POOH. 17:00 - 00:00 7.00 RIGMNT RGRP DECOMP Pipe handler repair. Welder on location for repair. 8/25/2005 00:00 - 02:00 2.00 RIGMNT RGRP DECOMP Continue with repairs to pipe handling skate. (((CODE 8))) 02:00 - 03:50 1.83 FISH PULD DECOMP Make up fishing BHA 03:50 - 09:40 5.83 FISH TRIP DECOMP RIH w/ PH-6 work string and fishing BHA 09:40 - 15:00 5.33 FISH TRIP DECOMP Continue to RIH with fishing string of 411/16" cut lip guide, 4 11/16" overshot bowl w/spiral graple, 4 11/16" XIO bushing, 4.5" washpipe extension, 4.5" drive sub, 3.75" bumper sub, 33/4" oil jar, 33/8" drill collars 9 ea., 33/4" accel, 4 516" XIO sub, and 7,767' of PH-6 work stri ng. 15:00 - 17:30 2.50 FISH FISH DECOMP Begin jarring operations. Step rate jar licks from 10K over string wt @ 72K. Own wt 55K. Max pull while jarring is 125K. Straight pull max 235K. Performed derrick inspection. 17:30 - 00:00 6.50 FISH JAR DECOMP After 2.5 hours no proof of movement. Back off grapple and POOH stand work string back for washover run. Performed trip drill. 8/26/2005 00:00 - 02:30 2.50 FISH TRIP DECOMP Continue OOH w/ PH-6 work string and fishing BHA 02:30 - 04:00 1.50 FISH PULD DECOMP Lay down fishing BHA 04:00 - 10:00 6.00 FISH RURD DECOMP Make up stripping head assembly, Run lines for power swivel. 10:00 - 11 :00 1.00 FISH PULD DECOMP Pick up washover string of 43/4" washover shoe w/3 3/4" 10, 2 joints of 4 1/2" wash pipe, 4 1/2" drive sub, 3 3/4" bumper sub, 33/4" hydraulic jar, 3 3/8" drill collars X 8, 4 5/16" cross over w 7,730' of PH-6 P11 0 work string to begin washover operations. 11 :00 - 14:30 3.50 FISH TRIP DECOMP Rih with PH-6 P11 0 14:30 - 16:30 2.00 RIGMNT RSRV DECOMP Slip drill line 120'. 16:30 - 20:30 4.00 FISH TRIP DECOMP On bottom with BHA 20:30 - 00:00 3.50 FISH RURD DECOMP Rig-up power swivel and associated equipment. Install seal in stripper head. 8/27/2005 00:00 - 01 :30 1.50 FISH RURD DECOMP Continue rigging up power swivel and stripping head. 01 :30 - 02:30 1.00 FISH CIRC DECOMP Establish circulating and torque rate before engaging tubing stub. 02:30 - 03:30 1.00 FISH WASH DECOMP Engage tubing stub @ 8050'. PU another joint of tubing. Begin washing over tubing to 8064'. Locate lower collar of chemical cut tubing joint. 03:30 - 07:00 3.50 FISH WASH DECOMP Begin washing over tubing collar. 07:00 - 10:05 3.08 FISH WASH DECOMP Reversing at 340 PSI. Time drilling at 2,200-3,000 ftIlb torque. 75 up, 55 dwn. Printed: 10120/2005 3:40:04 PM . . Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 18-15 1 8-15 WORKOVER/RECOMP Nabors 3S Start: Rig Release: Rig Number: 8/19/2005 9/2/2005 Spud Date: 9/28/2005 End: 9/2/2005 Group: 8/27/2005 07:00 - 10:05 3.08 FISH WASH DECOMP Pit 1 = 105, pit 2 = 108, pit 3 = 68 Several cycles up an ddown over fish to assist in ROP. 10:05 - 12:35 2.50 FISH WASH DECOMP Witness torque drill off of 1,500 pound swings. However not making hole. Pulled off fish and re-engaged for effect. torque = 1600-2800 ftIlb. 12:35 -17:15 4.67 RIGMNT OTHR DECOMP After working on power swivel to fix and or tighten packing, decided to rebuild power swivel. 17:15 - 22:00 4.75 FISH WASH DECOMP Pick up joint 250 and prepare to finish washing over fish. Set down on something (cement?) work through tight spot @ 8086'. Continue washing to 8095'. Unable to make hole after 3 hours of milling. Pump sweep to surface. Small amount of metal shaving in shakers. Still unable to make hole. PU off fish cleanly. 22:00 - 00:00 2.00 FISH RURD DECOMP Lay down two joints of tubing and power swivel. PU power tongs. 8/28/2005 00:00 - 01 :00 1.00 FISH RURD DECOMP Remove rubber seal from stripper head. 01 :00 - 09:27 8.45 FISH TRIP DECOMP POOH w/ PH-6 and washover BHA standing back. 09:27 - 10:00 0.55 WELCTL OBSV DECOMP Currently at the BHA. Monitor well for flow. 10:00 - 12:00 2.00 FISH PULD DECOMP OOH with washover string BHA. No fish stuck in BHA. Washover shoe measured out at 4 3/4" O.D. by 3 3/4" 10. Slight taper in entrance of shoe. 12:00 - 14:00 2.00 FISH RURD DECOMP Pull striping head and re-set pitchin nipple. Clear rig floor for current operations. 14:00 - 15:15 1.25 WAlTON EQIP DECOMP Unable to locate wear ring with J-Iatch retrieval tool. Call out spear from Deadhorse. 15:15-16:15 1.00 FISH FISH DECOMP Wear ring OOH. one ear slightly rolled over. Prepare for BOP test. 16:15 - 19:00 2.75 WELCTL BOPE DECOMP Begin BOP test. Function test BOPE, pressure test rams to 250/3000 psi, annular to 250/2500 psi. Witnessing waived by AOGCC (Jeff Jones) 19:00 - 20:00 1.00 WELCTL OBSV DECOMP Monitor well and prep to pick up BHA. 20:00 - 21 :00 . 1.00 RIGMNT RSRV DECOMP Test gas alarms 21 :00 - 00:00 3.00 WAlTON EQIP DECOMP Replace hydraulic block valve on drillers control panel. (((CODE 8))) 8/29/2005 00:00 - 08:00 8.00 WAlTON EQIP DECOMP Continue making repairs to hydraulic block valve on drillers control panel. (((CODE 8))) 08:30 - 11 :00 2.50 FISH PULD DECOMP Begin picking up BHA. Bypassed the valve that has been given us issues, Rig drillers consul back up. 11 :00 - 19:00 8.00 FISH TRIP DECOMP Begin picking up drill pipe. PH-6 p110. Monitor well conditions while RIH w/ fishing BHA to 8050'. 19:00 - 19:01 0.02 FISH OTHR DECOMP Main engine appears to have blown the top end. Utilize secondary engine for continuation of program. Only difference is clutch and throttle is now manually performed. This slows lows us down a little until the rhythm is picked up by crew. 19:01 - 21 :00 1.98 FISH FISH DECOMP Attempt to engage tubing stub. Had to PU off fish and circulate. 21 :00 - 21 :30 0.50 FISH FISH DECOMP Engage fish while rotating. No increase in string weight while pulling off bottom. POOH to 8030'. 21 :30 - 23:00 1.50 FISH CIRC DECOMP Lay down one joint. Circulate bottoms up. 23:00 - 00:00 1.00 FISH CIRC DECOMP Wet pipe. Mix and pump dry job. 8/30/2005 00:00 - 02:50 2.83 FISH TRIP DECOMP POOH w/ work string standing back in derrick. 02:50 - 04:30 1.67 FISH TRIP DECOMP Continue OOH w/ work string 90 stands out of 124. 04:30 - 06:00 1.50 FISH TRIP DECOMP Continue OOH w/ work string 06:00 - 07:00 1.00 FISH PULD DECOMP Lay down BHA 07:00 - 09:00 2.00 FISH PULD DECOMP OOH with fish. Fish consist of 15.69'. This includes the chemical cut 3.5" production pipe, .99' Cameo OS nipple, with the 0&0 hole finder wedged inside the nipple. Pipe will be norm tested and sent to Baker for cut out of Grapple and D&D. Called for spear to re-aquire fish. Printed: 10/20/2005 3:40:04 PM . . Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 8-15 1 8-15 WORKOVER/RECOMP Nabors 3S Start: Rig Release: Rig Number: 8/19/2005 9/2/2005 Spud Date: 9/28/2005 End: 9/2/2005 Group: 8/30/2005 09:00 - 10:00 1.00 FISH TRIP DECOMP Begin running BHA in hole. 2 13/16" Spear w/3" grapple, 2 1/2" extension, two crossover subs 3 1/8" & 3 3/8"" OD, 3 3/4" Bumper sub, 3 3/4" jar, 6 ea. drill collars at 3 3/8", 4 5/16" crossover w 7,861' of 3 1/2" PH6 P110 work string. 10:00 - 15:15 5.25 FISH TRIP DECOMP 52k dwn wt. 70K up wt. Pick up JT 251, 18' pup jt, and a 31' 3 1/2" drill pipe jt for fishing opertations. Install head pin. change out elevators. 15:15 - 16:40 1.42 FISH FISH DECOMP Stab into top of fish. Insert 5' to bottom of NO-GO. Pick up initial string wt to 70K ease wt up to 120,000#. Breaks not holding on draw works. 16:40 - 19:45 3.08 RIGMNT RGRP DECOMP Fix failing breaks on draw works. Cat mechanic decided that engine #1 is good. However transmission has failed. Repair to happen prior to next well. 19:45 - 23:30 3.75 FISH JAR DECOMP Begin Jarring operations to attempt to pull Baker Bullet seal assembly and tubing stub. Pulled up 170K working pipe for 3 hours, set off jars lightly on several occasions, (120K up weight). Up weight and down weight changed 2 hours into operation to up 90K and down 70K we appeared to have 1 ft of movement. Fish would not come free and did not appear to move anymore. Disengage fish pulled one joint and circulated bottoms up prior to pulling out of hole laying down PH-6 work string in preparation for running completion with a overshot. 23:30 - 00:00 0.50 FISH CIRC DECOMP Circulate bottoms up 8/31/2005 00:00 - 01 :50 1.83 FISH CIRC DECOMP Circulate bottoms up and pump a dry job 01 :50 - 06:00 4.17 FISH PULL DECOMP Pull PH-6 out of hole laying down work string in preparation of running completion. Fish is still in the hole plan to run overshot on completion. 06:00 - 07:00 1.00 FISH PULL DECOMP Pre Tower meeting and continue Pulling PH-6 out of hole laying down work string. Pulling wet pipe, prepare a dry job. 07:00 - 08:15 1.25 WELCTL COND DECOMP Pump dry job after reversing. Suspect solids in viscus fluid plugging off BHA. Will monitor. Continue to POOH. 08:15 - 18:00 9.75 FISH PULL DECOMP Continue to pull out of hole with fishing string, to surface no fish in grapple. Work string in good shape laid down sideways. Pre tower operations and safety meeting tower objective is to run completion. 18:00 - 20:00 2.00 CMPL TN PULD CMPL TN Pick up completion equipment and rig up floor to run completion. 20:00 - 00:00 4.00 CMPL TN RUNT CMPL TN Picked up Overshot, X Nipple, spacer pipe, SABL3 Packer, Gas Uft Mandrel and 29 joints of IBT tubing, new seal rings on all joints using Jet Lube pipe dope 9/1/2005 00:00 - 06:00 6.00 CMPL TN RUNT CMPL TN Continue to run completion 06:00 - 08:00 2.00 RIGMNT RGRP CMPL TN Tower meeting Rig service co/ safety line at crown. 08:00 - 14:15 . 6.25 CMPL TN RUNT CMPL TN Continue to run completion currently running 3.5" EUE 8rd from stands in the derrick. Breaking stands apart and inserting new sea rings. 14:15-14:45 0.50 CMPL TN DEQT CMPL TN Pressure test SSSV for 15 minutes to 14:45 - 16:13 1.47 CMPL TN RUNT CMPL TN Continue to RIH w/completion. Pulled 12 jts of 9.3# IBT tubing from pipe shed and set across from camp. 2 extra joints were already on rack.. Now total is 14 on rack. 16:13 - 19:00 2.78 CMPLTN RUNT CMPL TN Completion in the hole with 3 joints of 3.5" EUE left on surface. 40K down weight 52K up. 10K positive indication on tattle tale. Spaced out PBOS 2' and landed 22' down on joint 125 of the 3.5" EUE. Pulled two joints spaced out with 3 pups 6.04',10.04',10.08' joint 1242.04' pup (to be removed to space out PBR) and hanger @ 4.14'. 19:00 - 00:00 5.00 CMPL TN CIRC CMPL TN Rig up and circulate down the tubing up IA clean 9.7 brine taking returns to tank farm. Pump 150 bbls 9.7 brine 20 bbls inhibited 9.7 brine and displace with 65 bbls 9.7 brine this will place 15 inhibited brine behind pipe and 5 in the tubing. Tubing is set @ 7,874' ready to land and set packer. Max pressure and rate 1000 psi and 3 bpm. 9/2/2005 00:00 - 02:00 2.00 CMPL TN PCKR CMPL TN Land Hanger (Landed to insure that tubing will not jump and cause Printed: 10/20/2005 3:40:04 PM . . Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 8-15 1 8-15 WORKOVER/RECOMP Nabors 3S Start: 8/19/2005 Rig Release: 9/2/2005 Rig Number: Spud Date: 9/28/2005 End: 9/2/2005 Group: 9/2/2005 00:00 - 02:00 2.00 CMPL TN PCKR CMPL TN injury or damage), dropped Rod and Ball, Pressure up to2500 psi 3500 psi and 4500 psi bleeding down to 0 psi between stages, with LRS to set packer. 4.00 CMPL TN DEQT CMPL TN Un-land hanger shear PBR pull up to floor to remove 2.04' pup below the hanger to give us our 2' PBR space out. Re-Iand hanger test tubing to 2500 psi chart for 30 min. bleed down to 1500 psi and test IA to 2500 psi chart for 30 min. Bleed tubing down to shear SOV bleed well down and run BPV 6.00 CMPL TN NUND CMPL TN Tour meeting ND BOP's NU tree 3.00 CMPL TN NUND CMPL TN Install tree and pressure test. Rig released at 15:009-2-2005 02:00 - 06:00 06:00 - 12:00 12:00 - 15:00 Printed: 1012012005 3:40:04 PM . 1 B-15A Well Events Summary . Date Summary 07/16/05 RAN 2.5" PERF GUN 10' (9' LOADED) TOTAL LENGTH OF TOOLSTRING 35.8'. DESCENDEDTO 8375' WHERE IT STOPPED FALLING & ON PICK UP FOUND GUN TO BE STUCK. WORKED CABLE FOR 1-1/2 HRS WITH INCREASING WEIGHTS UNTIL GUN CAME FREE WITH A 2850# OVERPULL. 07/17/05 DRIFT W /20' 2.5" DUMMY GUN TO 8366' SLM (8396' RKB) OBTAINED SAMPLE @ 8398' RKB EST 16' FILL ABOVE TARGET DEPTH OF 8417' RKB. JOB SUSPENDED FOR CTU. [Tag] 07/19/05 PERFORMED A FILL CLEAN OUT TO TOP OF RETAINER @ 8493' RKB USING 2.125" DSP2 TOOL & 2.3" JET SWIRL NZL. SMALL AMOUNT OF SAND TO SURFACE. [FCO] 07/22/05 TAGGED @ 8487' RKB, EST. 23' FILL. DRIFTED WITH 2.6" X 11' DUMMY GUN TO 8429' RKB. PROPOSED PERFS 8408' - 8417'. [Tag] 07/26/05 PERFORATED:8408' TO 8417',6 SPF. GUN:2 1/2 HSD, 6 SPF, 60 DEG PHASE, RANDOM ORIENT POWERJET CHARGES: 2506 POWERJET, 10.5 GR HMX, PENT=25.2", EH=.32" TAGGED BOTTOM AT 8432' [Perf] 07/28/05 Pre CTD POT & PPPOT-T & IC passed, function test LDS's (all functioned properly) 07/30/05 TESTED SSSV, GOOD. PULLED OV FROM 8037', GLVs FROM 5364', 3939', AND 2573' RKB. SET DVs AT 3939' & 5364' RKB. IN PROGRESS. 07/31/05 SET DV @ 2573' RKB. SET CAT SV @ 8080' RKB. LOADED TBG & IA WITH SW & DSL FREEZE PROTECT. PULLED CAT SV & SET DV @ 8037' RKB MITIA 2500 PSI, PASSED. [MIT] 08/01/05 PUMPED A 15 BBL CAC03 PILL, ATTEMPTED TO SQUEEZE, PRESSURED UP TO 900 PSI, SLOW BLEED OFF. 08/01/05 Pre- CTD drawdown on Swab passed, PT on MV and Swab failed [ANN COM ISSUES, WH Maintenance] 08/02/05 ATTEMPTED TO MIT SWAB AND MASTER ( FAILED). TAG CAC03 PILL ( PLUG) @ 8441' RKB (91' BELOW WINDOW). PUMPED 17.5 BBL OF DIESEL DOWN TBG.STILL ON VAC. 08/02/05 Pre CTD PT MW and Swab valve failed [ANN COM ISSUES, WH Maintenance] 08/03/05 PUMPED 9 BBLS PILL, 10 PPG CAC03 SLURRY TO COVER PERFORATIONS FROM 8408-8441'. DISPLACED WITH 5 BBLS SW AND 62.6 BBLS DIESEL. PRESSURED UP TO 1500 PSI WITH BLED BACK TO 1430 IN 15 MIN. [Workover prep] 08/04/05 TAGGED TOP OF SAND PLUG @ 8363' SLM (8368' RKB) DUMPED 2 GALLONS OF LATEX SAND CAP SLURRY @ 8368' RKB. PERFORMED REPEATED TESTS ON TBG TO 3000 PSI AND ALL FAILED. ESTABLISHED A SLOW LEAK COMMUNICATION TBG TO IA. PRESSURED UP fA & TBG TO 2500 PSI AND TBG HELD SOLID. 08/05/05 SET D&D HOLE FINDER @ 8161' SLM, PT TBG TO 2500 PSI W/ 150 PSI ON lA, HELD SOLID. UNSEATED HOLE FINDER & TEST TBG TO 2500 PSI. TBG DROPPED 600 PSI W/ IA INCREASING 200 PSI IN 10 MINUTES. THERE IS AN APPARENT LEAK IN THE PACKER AREA @ 8149' RKB. D&D HOLE FINDER IS HUNG IN D NIPPLE @ 8080' RKB. . 1B-15A Well Events Summary . 08/06/05 MADE SEVERAL ATTEMPTS TO RECOVER D&D HOLE FINDER FROM D NIPPLE @ 8080' RKB, NO SUCCESS. [Fish] 08/09/05 PT TBG TO 2500 PSI W/200 PSI ON lA, HELD SOLID CONFIRMING D&D HOLE FINDER IS HOLDING PRESSURE. MITIA TO 2500 PSI, PASSED. LEAK IN TBG IS ONE WAY, TBG TO CSG. PULLED 1" DV @ 8037' RKB. POCKET OPEN. [Pressure Data, GL V] 08/15/05 SET FRAC SLEEVE @ 1811' RKB (641/2" OAL W/I.D. OF 2.30). READY TO LOAD WELL. IN PROGRESS. [SSSV Work] 08/18/05 Circulate well out with seawater, load with 9.7 ppg Sodium Chloride brine, set BPV [Workover prep] 08/22/05 FISH E-LlNE CHEMICAL CUTTER. IN PROGRESS. [Fish] 08/23/05 FISHED E-LlNE CHEMICAL CUTTER FROM 8040' WLM. [Fish] 09/04/05 PULLED BALL & ROD AND 2.75" RHC PLUG BODY @ 8032' RKB. PULLED 1" SOV @ 7822' RKB. CIRCULATE SEAWATER W/2500' DIESEL CAPS & RECOVERED 9.7 BRINE INTO TANK # 7. DRIFT TBG W/2.5" X 20' DUMMY GUN TO 8341' SLM. 09/05/05 TWO 2.5" HSD PJ 2506 HMX 10.5G 6 SPF GUNS WERE FIRED: GUN #1 PERFORATION INTERVAL WAS 8281-8296'. GUN #2 PERFORATION INTERVAL WAS 8208'-8218'. ALL SHOTS WERE FIRED. TAGGED TD @ 8340'. [Perf] 09/06/05 PUMPED 8 BBLS. LARC CEMENT, SQUEEZED TO 3500 PSI WITH 0.5 BBLS. BEHIND PIPE, CLEANED OUT TO 8160'. IN PROGRESS. [Cement-Poly Squeeze] 09/07/05 MILLED CEMENT FROM 8165' TO 8338', CLEANED OUT SAND TO 8498', TAGGED EZ DRILL. CIRCULATED BIO THROUGHOUT JOB WITH MI SKID. [FCO] 09/08/05 UNDER REEMED 8160' TO 8480', SSW AND 2500' OF DIESEL LEFT IN WELL. [FCO] 09/08/05 ATTEMPTED TO DRIFT TBG W/11' X 2.74" DUMMY WHIPSTOCK ( ONLY ABLE TO DRIFT DOWN TO 5050' SLM). BRUSHED TBG FROM 4700' SLM TO 5100' SLM AND DRIFTED DOWN TO 8450' SLM W/3 1/2 BRUSH AND 2.71 GUAGE RING. RECOVERED SMALL PIECES OF METAL IN GAUGE RING AND BRUSH. 09/09/05 DRIFT TBG. W/11' X 2.74 DUMMY WHIPSTOCK AND TAG @ 8075' SLM (NOTE: HAD TO WORK THROUGH DOGLEG @ 5000' RKB & 5675' RKB / NOT A CLEAN DRIFT ). . . Mike Mooney Wells Group Team Leader Drilling & Wells Conoc6Phillips P. O. Box 100360 Anchorage, AK 99510-0360 Phone: 907-263-4574 June 6, 2005 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West th Avenue Suite 100 Anchorage, Alaska 99501 ;¡o.,,) tr [::C" ~ ¿~n. lIE. -I v.""", JUN - .L; J ' 0 6 2005 11;1 & r., 0;'1,') Subject: Report of Sundry Well Operations for 1 B-15A (APD # 204-256) Dear Commissioner: ConocoPhillips Alaska, Inc. submits the attached Report of Sundry Well Operations for the recent stimulation operations on the Kuparuk well 1 B-15A. If you have any questions regarding this matter, please contact me at 263-4574. Sincerely, )¡f.~ M. Mooney Wells Group Team Leader CPAI Drilling and Wells MM/skad ()R\G\NAL . . H JUN 0 f} 200S STATE OF ALASKA ALASKA Oil AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Abandon D Alter Casing D Change Approved Program D 2. Operator Name: ConocoPhillips Alaska, Inc. 3. Address: P. O. Box 100360, Anchorage, Alaska 7. KB Elevation (ft): RKB 34' 8. Property Designation: ADL 25648, ALK 466 11. Present Well Condition Summary: Repair Well D Pull Tubing D Ope rat. ShutdownD Plug Perforations D Perforate New Pool D Perforate D 4. Current Well Status: Development 0 Stratigraphic D Total Depth measured 8621' feet true vertical 6607' feet measured 8270' feet true vertical feet Length Size MD 121' 16" 121' 4156' 9-5/8" 4190' 4371' 7" 4405' 4116' 5-1/2" 8350' 500' 3-1/2" 8621' Effective Depth Casing Structural CONDUCTOR SURFACE PRODUCTION PROTECTION LlI PRODUCTION LI Perforation depth: Measured depth: 8305'-8307', 8432'-8452', 8506'-8510' true vertical depth: 6323'-6325',6434'-6452',6501'-6505' Tubing (size, grade, and measured depth) 3-1/2" , L-80, 8121' MD. Packers & SSSV (type & measured depth) Baker 'CPH' packer, Baker 'ZXP' packer 4241',8140' Cameo TRM-4E SSSV 1833' 12. Stimulation or cement squeeze summary: Intervals treated (measured) 8432-8452' Treatment descriptions including volumes used and final pressure: (., a Stimulate 0 Waiver D Other D D D Time Extension Re-enter Suspended Well Exploratory D Service D 5. Permit to Drill Number: 204-256 / 6. API Number: 50-029-22465-01 9. Well Name and Number: 1B-15A 10. Field/Pool(s): Kuparuk River Field / Kuparuk Oil Pool Plugs (measured) Junk (measured) TVD Burst Collapse 121' 4139' 4324' 6361' 6607' 13Ft ¡UN 0 . >-, 62005 180,000# 16/20 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mct Water-Bbl CasinQ Pressure TubinQ Pressure Prior to well operation 55 948 2 140 Subsequent to operation 778 1945 48 169 14. Attachments 15. Well Class after proposed work: Copies of Logs and Surveys run _ Exploratory D Development 0 Service D P&A Daily Report of Well Operations _X 16. Well Status after proposed work: Oil0 GasD WAGD GINJD WINJ D WDSPLD 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. I Sundry Number or N/A it C.O. Exempt: Contact Mike Mooney @ 263-4574 Mike Mooney ;¡J- Þ/~ OR \ G\ NAL Printed Name Signature Title Phone Form 10-404 Revised 04/2004 Wells Group Team Leader 907-263-4574 Date ~Þ/ð5 Preoared bv Sharon AI/suo-Drake 263-4612 Submit Original Only TUBING (0-8121, 00:3.500, 10:2.992) LOCATOR (8118-8119, 00:4.260) Perf (8305-8307) FRAC (8432-8452) Perf (8432-8452) Perf (8506-8510) . ConocoPhillips Alaska, Inc. :: l ,-r...- J..t ~ ~ ~ . 1 B-15A KRU 1B-15A API: 500292246501 SSSV Type: TRDP Annular Fluid: Well Type: PROD Orig Completion: 2/16/2005 Last W/O: Angle @ TS: 34 deg @ 8206 Angle @ TD: 24 deg @ 8621 Rev Reason: TAG, PERF, FRAC, GLV design Last Update: 5/26/2005 Reference Log: 34' RKB Last Tag: 8270 Last Tag Date: 5/18/2005 Casing string - ALL STRINGS Description CONDUCTOR SURFACE PRODUCTION Protection Liner Production Liner Ref Log Date: TO: 8621 ftKB Max 71 5294 Size 16.000 9.625 7.000 5.500 3.500 Top Bottom TVD Wt Grade Thread 0 121 121 62.50 H-40 0 4190 4138 40.00 L-80 0 4405 4324 26.00 L-80 BTC-M 4234 8350 6361 15.50 L-80 Hydril511 8121 8621 8621 9.20 L-80 511 Size Top 3.500 0 Perforations Summary Interval TVD 8305 - 8307 6323 - 6325 TVD 6170 Zone Status Ft SPF Date UNITB 2 4 3/2/2005 A-4 20 6 3/28/2005 A-3 4 6 3/2/2005 Type SQZ PERF PERF SQZ PERF Comment 1 9/16" Gun, Small charges for cement squeeze on back side Altemating PJ & PF charges 2.5" HSD Powerflow 60 deg phase for cement squeeze on back side 8432 - 8452 8506 - 8510 6434 - 6452 6501-6505 Stimulations & Treatments· Interval I Date I 8432 - 8452 5/14/2005 FRAC Gas Lift MandrelšValves St MD TVD Man Mfr Man Type V Mfr Comment V Type V OD Latch Port TRO Date Run Vlv Cmnt 1 2573 2572 CAMCO KBUG-M GLV 1.0 BK 2 3939 3914 CAMCO KBUG-M GLV 1.0 BK 3 5364 4888 CAMCO KBG-2-9 GLV 1.0 BTM 4 7263 5615 CAMCO KBG-2-9 DMY 1.0 INT 5 8037 6102 CAMCO KBG-2-9 OV 1.0 INT mlhør[plug$,eqUip;¡':"'etc.) . UEWELR¥ Depth TVD Type Description 30 30 HANGER FMC GEN IV TBG HANGER 1833 1832 SSSV CAMCOTR~ESAFETYVALVE 8080 6136 NIP CAMCO 'D' LANDING NIPPLE 8118 6167 LOCATOR BAKER NO GO LOCATOR 81196168 SEAL BAKER BULLET SEAL ASSEMBLY GffiøiJ'(PI"UQš¡::eqûlp.,· êttMir~rõteQtløn·'l1llnêiJtlêwêll\Y; Depth TVD Type Description 4235 4177 TIE BACK BAKER LINER TIE BACK SLEEVE SLV 4241 4182 PACKER BAKER 'CPH' LINER TOP PACKER 4245 4186 HANGER BAKER 'HMC' LINER HANGER 8177 6215 Centralizer WEATHERFORD IN-LINE CENTRALIZER 8221 6252 Centralizer WEATHERFORD IN-LINE CENTRALIZER 8224 6255 COLLAR 5.5" JOINTw/INSERT LANDING COLLAR 8264 6288 Centralizer WEATHERFORD IN-LINE CENTRALIZER 8309 6326 Centralizer WEATHERFORD IN-LINE CENTRALIZER Gffièr:i(plft;:eqûlp:,,,.êtê:rZProCluctlón..!lnêi!ilJ.êwlêry Depth TVD Type Description 8121 6170 TIE BACK BAKER LINER TIE BACK SLEEVE SLV 8140 6185 PACKER BAKER 'ZXP' LINER TOP PACKER 8148 6192 PBR POLISHED BORE NIPPLE SL-HT 8152 6195 HANGER 3.5" x5.5" BAKER 'HMC' LINER HANGER 8498 6494 RETAINER HES 3.5" EZ DRILL RETAINER 8556 6547 COLLAR BAKER 3.5" LANDING COLLAR GêñêJiå'·NotØ$ Date Note 2/13/2005 TREE: GMC / GEN IV/3-1/8" 5M TREE CAP CONECTION: 5.75 OTIS QUICK CONNECT 2/13/2005 WELL SIDETRACKED 0.188 0.200 0.188 0.000 0.188 1300 1270 1245 o o 5/17/2005 5/17/2005 5/17/2005 4/23/2005 5/16/2005 ID 3.500 2.812 2.750 2.970 2.990 ID 5.500 4.870 4.920 4.850 4.850 4.950 4.850 4.850 ID 4.130 3.410 3.230 2.920 0.000 2.993 . 1B-15A Well Events Summary . Date Summary 04/22/05 SET 2.75"CA-2 BLANKING PLUG @ 8080' RKB. IN PROGRESS. [Open-Close A Sand] 04/23/05 PRE FRAC INSTALLED DV'S IN STA #'S 1 - 4. LEFT STA# 5 OPEN. IN PROGRESS. [GLV] 04/24/05 DISPLACED TBG & IA W/ SEAWATER & DIESEL CAP. SET DV @ 8037' RKB. PT IA 1500#. PULLED 2.75" CA-2 @ 8080' RKB. SET FRAC SLEEVE @ 1833' RKB. [PT Tbg-Csg, GL V, Frac-Refrac] 05/14/05 PUMP "A" SAND FRACTURE TREATMENT AT 20 BPM USING 50# DELAYED X-LINK GEL AND 16/20 CERAMIC PROPPANT. PUMPED TOTAL OF 181,051# OF PROPPANT . SCREENED OUT 59 BBLS INTO FLUSH, PLACING 180,637# OF PROPPANT BEHIND PIPE WITH 10 PPA ON PERFS. RECOVERED ALL TREE SAVER CUPS. 05/14/05 PULLED FRAC SLEEVE @ 1809' WLM 1833' RKB [SSSV Work] 05/15/05 CLEANED OUT FILL TO HARD TAG AT MID-PERF (8425' CTM) W/1.75 JETSWIRL NOZZLE USING SLICK SEAWATER AND DIESEL GEL, UNABLE TO GET DEEPER. RBIH AND MILL TO 8492' CTMD WITH 2.7" JUNK MILL. GETTING RETURNS OF FRAC BALLS. HELD 1:1 RTNS ON WAY OUT OF HOLE. WELL LEFT FREEZE PROTECTED AND SHUT-IN. 05/16/05 TAGGED FILL @ 8280' RKB. EST. 192' FILL. SET CATCHER @ 8050' RKB. INSTALLED 1"OV @ 8037' RKB. IN PROGRESS. [Tag, GLV] 05/17/05 INSTALLED GLV'S IN STA#'S 1,2 & 3. PULLED CATCHER SUB @ 8080' RKB. IN PROGRESS. [GL V] 05/18/05 UNABLE TO PUMP INTO WELL. TAGGED FILL @ 8270' RKB. EST 202' FILL. [Tag] OS/21/05 COMPLETED A REVERSE FILL CLEAN OUT TO 8485' CTD IN 3-1/2" LINER. PUMPED SEAWATER USING A 2.0" BALL DROP NZL WITH SIDE JETS. GOOD RETURNS TO TANKS WITH HEAVY SAND. ENCOUNTERED HARD SAND BRIDGE @ 8257'; SWAPPED OVER TO PUMP DOWN THE CT & ABLE TO WASH THROUGH. WELL SI FOR SLlCKLlNE WORK, FREEZE PROTECTED WITH DIESEL TO 3000'. OS/22/05 DRIFT FOR POST FILL CLEAN OUT TAG 8464' SLM (8490' RKB) APPROX 20' FILL CTU CLEAN OUT TO 8485' CTM./SET CATCHER/ ATTEMPT TO PULL STA#4 NO GOOD FRAC SAND SUSPECTED IN MANDREU PULL CATCHER PRODUCE WELL TO CLEANUP. [Tag] . ConocóP'hillips . Randy Thomas Kuparuk Drilling Team Leader Drilling & Wells ' P. O. Box 100360 Anchorage, AK 99510-0360 Phone: 907-265-6830 April 28, 2005 RECEIVED APR 2 9 2005 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West ih Avenue Suite 100 Anchorage, Alaska 99501 Alaska Oil & Gas Cons. Commission AnchorBge Subject: Well Completion Report for 1 B-15A (204-256) Dear Commissioner: ConocoPhillips Alaska, Inc. submits the attached Well Completion Report for the recent drilling operations of the Kuparuk well 1 B-15A. If you have any questions regarding this matter, please contact me at 265-6830 or Jake Flora at 265-6040. Sincerely, .~\~ R. Thomas Kuparuk Drilling Team Leader CPAI Drilling RT /skad ! f\ r A\ L. ~ í\ \j .. · STATE OF ALASKA 'I ALASKAOILAND GAS CONSERVATION COM SSION Rr=~t='\/¡;:D WELL COMPLETION OR RECOMPLETION REPORtÄNtt'COG"··· Gas U Plugged D Abandoned U Suspended D WAG D 1 b. Well cARR 2 ~ l 005 20AAC 25.105 20AAC 25.110 DeveIOpmen,! ~ .' ...... .... EXPlorato;, '.' D No. of Completions_ Other Alask§e¡lU: rm t;¡¡n::'Stratigf"aphi¡';T~åtD 5. Date Comp., Susp., 12. Permit to IþjI~f::Ij.¡I!IÞ~\;~i or Aband.: February 16, 2005'/ 204-256/ 6. Date Spudded: 13. API Number: January 30, 2005 / 50-029-22465-01 7. Date TD Reached: 14. Well Name and Number: 1 a. Well Status: Oil 0 GINJ D WINJ D WDSPL D 2. Operator Name: ConocoPhillips Alaska, Inc. 3. Address: P. O. Box 100360, Anchorage, AK 99510-0360 4a. Location of Well (Governmental Section): Surface: 500' FNL, 484' FEL, Sec. 9, T11N, R10E, UM At Top Productive Horizon: 2324' FSL, 1844' FWL, Sec. 9, T11 N, R10E, UM 4b. Location of Well (State Base Plane Coordinates): Surface: x- 549955 j y- TPI: x- 547085 y- Total Depth: x- 547025 y- 18. Directional Survey: Yes 0 NoD 5969647 ¡ 5967223 5967172 February 11, 2005 ,. 8. KB Elevation (ft): 34' RKB 9. Plug Back Depth (MD + lVD): 8588' MD / 6576' TVD 10. Total Depth (MD + lVD): ,. 8621' MD /6607' TVD ,. Total Depth: 2375' FSL, 1904' FWL, Sec. 9, T11 N, R10E, UM 21. Logs Run: GRlRes, SCMT 22. CASING SIZE wr. PER FT. 16" 62.5# 9-5/8" 40# 7" 26# 5.5" 15.5# 3.5" 9.2# GRADE H-40 L-80 L-80 L-80 L-80 Zone- 4 Zone- 4 11. Depth where SSSV set: 1833' Zone- 4 19. Water Depth, if Offshore: N/A feet MSL CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTH lVD TOP BOTTOM TOP BOTTOM Surf. 121' Surf. 121' Surf. 4190' Surf. 4139' Surf. 4405' Surf. 4324' 4234' 8350' 417' 6361' 8121' 8621' 6170' 6607' 23. Perforations open to Production (MD + lVD of Top and Bottom Interval. Size and Number; if none, state "none"): 8305'-8307' MD 8506'-8510' MD 8432'-8452' MD 4 spf 6 spf 6 spf 26. Date First Production April 3, 2005 Date of Test Hours Tested 4/5/2005 Flow Tubing press. 140 psi 27. 12 hours Casing Pressure 992 24. SIZE 3.5" 12.25" 6.125" 6.125" 1B-15A 15. Field/Pool(s): Kuparuk River Field Kuparuk Oil Pool 16. Property Designation: ADL 25648 17. Land Use Permit: ALK 466 20. Thickness of Permafrost: -;::7 .w.J~ 1558' MD .:I<:/o'S'P?Þ !9>., Ÿ32V' 'rvl> ~ í¿'<:< 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". HOLE SIZE CEMENTING RECORD AMOUNT PULLED 24" 200 sx AS I 900 sx AS III, 400 sx Class G 350 sx Class G 383 sx Class G 55 sx Class G bridge plug @ 4423' TUBING RECORD DEPTH SET (MD) 8121' PACKER SET 4235',8140' 4241' 8.5" 25. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED plug from 4521'-4230' 57 sx Class G cement sqz from 8200' 10 bbls 15.8 ppg Class G PRODUCTION TEST Method of Operation (Flowing, gas lift, etc.) Production for Test Period --> Calculated 24-Hour Rate -> Gas Lift Oil WATER-BBL OIL-BBL GAS-MCF 29 473 OIL-BBL GAS-MCF 55 948 CORE DATA WATER-BBL 2 RBDMS 8FL MA Y 1 2 2005 NONE ~... '·6J~~·,I;\;Ci:.\:\ð ¡~:"'t \~~~. \..~.t:\) '.' ¡ of_ -\ 1_ - ....:;:J {__""'rrc.....;;-.- ,_. Form 10-407 Revised 12/2003 CONTINUED ON REVERSE CHOKE SIZE 176 Bean OIL GRAVITY - API (carr) 24° IGAS-OIL RATIO 17324 GV 6 28. GEOLOGIC MARKERS. 29. . 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". 1B-15A Kuparuk A4 8427' 6429' RECEIVED APR 2 9 2005 N/A Alaska Oil & Gas Cons. Commissior Anchorage 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: Jake Flora @ 265-6040 Printed Na~ _ Ra~dV Thon:as Title: Greater Kuparuk Area Drillina Team Leader Signature \ --¡ \ ~ Phone ~bS-·6.g .> ö Date '"-1' (¿€ ¡'oS 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 12/2003 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 8-15 1 8-15 ROT - SIDETRACK d 14cm@conocophillips.com Doyon 14 Start: Rig Release: Rig Number: Alaska O~~ 1~~~t~?S1 ~W~]¡ð~on 1/27 /2005 Enlncnorag~/16/2005 2/16/2005 Group: 1/26/2005 19:00 - 20:00 1.00 MOVE SKID MOVE Prepare rig to skid rig floor - SKid rig floor from drlg position to move position 20:00 - 21 :00 1.00 MOVE MOVE MOVE Move off well 1 D-28 21 :00 - 23:00 2.00 MOVE MOVE MOVE Move rig from 1 D-Pad to 1 B-pad 23:00 - 00:00 1.00 MOVE POSN MOVE Spotting rig overwell1B-15A 1/27/2005 00:00 - 01 :30 1.50 MOVE ,POSN MOVE Spot rig over 1 B-15A well - Shim and level rig 01 :30 - 02:00 0.50 MOVE ISKID RIGUP Skid rig floor from move position to drlg position 02:00 - 03:00 1.00 MOVE RURD RIGUP Rig up rig floor - Set rock washer - Spot tiger tand - Accept rig 03:00 hrs on 1/27/2005 03:00 - 06:00 3.00 DRILL OTHR DECOMP Set bleed off tank - Set skid mounted choke - Rig up hard line from tree to choke to bleed off tank 06:00 - 09:00 3.00 WELCTL BOPE DECOMP Open surface safety valve - Pull VR plug in annulus valve - Pull BPV 09:00 - 11 :00 2.00 WELCTL BOPE DECOMP Low pressure test circ lines to 250 - Displace well with 8.8 brine - 3 bpm - PP 230 to 700 11 :00 - 12:00 1.00 WELCTL BOPE DECOMP Install TWC - Test to 500 psi 12:00 - 18:00 6.00 WELCTL NUND DECOMP PJSM - Nipple down tree - Nipple up BOP stack - Change out choke line spool 18:00 - 00:00 6.00 WELCTL BOPE DECOMP Test BOP's Annular 250 low 3500 high 5 mins each test Top rams 250 low 5000 high 5 mins each test Lower rams not tested due to blanking plug on top of BPV - ~teat lower r81'111S when -out of hole with 3 1/2" tubing Choke manifold 250 low 5000 high 5 mins each test HCR Choke - Kill 250 low - 5000 high 5 mins each test Manual Choke - Kill valves 250 low - 5000 high 5 mins each test Floor safety valves 250 low 5000 high 5 mins each test Upper IBOP 250 low 5000 high 5 mins each test - Failed low test - Grease valve retest valve - No test failed low test pressure Lower IBOP 250 low 5000 high 5 mins each test - Preform Accumulator test Lay down test joint - Blanding plug backed out - Run back in - Reinstall Blanking plug - Lay down test joint ,Test blind ram 250 low 5000 high 5 mins each test Jeff Jo,. with AOOCC waived witness of BOP test 1/28/2005 00:00 - 04:30 4.50 DRILL OTHR DECOMP PJSM - Change out Upper IBOP valve 04:30 - 05:30 1.00 WELCTL BOPE DECOMP Retest Upper IBOP valve - 250 low - 5000 high - 5 mins each test - Test good 05:30 - 18:00 12.50 DRILL OTHR DECOMP PJSM - Thaw kelly hose - Make up to Top drive 18:00 - 19:00 1.00 DRILL OTHR DECOMP Check annulus for pressure - Vac out stack - Mud cuttings and debris on top TWC - Pull TWC 19:00 - 20:00 1.00 DRILL PULD DECOMP PJSM - Make XO subs on joint 4" drill pipe - Screw into hanger- BOLDS - Pull hanger to rig floor - PU 1 05K - SO 100 - Block weight 50K 20:00 - 21 :00 1.00 DRILL CIRC DECOMP Circ @ GPM 255 - PP 520 - Rig up HOWCO control line spooler - Tubing handling equipment 21 :00 - 21 :30 0.50 DRILL ISFTY DECOMP PJSM - CO Rep - Hòwco - Rig Crew - (laying down tubing) - Rig down I circ equipment - Blow down top drive - 21 :30 - 23:30 2.00 DRILL PULD DECOMP Laying down 3 1/2" tubing - Lay down from 6625' to 4800' 23:30 - 00:00 0.50 DRILL RIRD DECOMP Rig down control line spooler - Lay down beaver slide - 29 steel bands recovered 1/29/2005 00:00 - 00:30 0.50 DRILL PULD DECOMP PJSM - Con't Lay down Howco spooler and equipment 00:30 - 06:00 5.50 DRILL PULD DECOMP Con't lay down 3 1/2" tubing - Retrieved Hanger Printed: 2122/2005 1 :50:22 PM L Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 8-1 5 1 8-15 ROT - SIDETRACK d 14cm@conocophillips.com Doyon 14 Start: 1/27/2005 Rig Release: 2/16/2005 Rig Number: Anchorage Spud Date: 1/28/2005 End: 2/16/2005 Group: 1/29/2005 00:30 - 06:00 5.50 DRILL PULD DECOMP 1 SSSV 5GLM 1 pup joint 210 joints tubing 1 cut off joint (18.5 long) 06:00 - 07:00 1.00 DRILL RIRD DECOMP Rig down tubing tools 07:00 - 09:00 2.00 WELCTL BOPE DECOMP Rig up to têst lower rims - XO test plug assembly under test joint too long to fit under rams for test - Work on alternative method for test 09:00 - 10:30 1.50 RIGMNT RSRV DECOMP Cut drlg line - Service top drive 10:30-11:00 0.50 WELCTL BOPE DECOMP Pull te$t plug - tnstat! wear ring - Open annulus valVe - Rig up test equipment i 11 :00 - 14:00 3.00 RIGMNT PULD DECOMP Pick up 4" drill pipe from pipe shed - Stand back in derrick 14:00 - 15:00 1.00 WELCTL BOPE DECOMP Pull wear ring - Install test plug - Open annulus valve 15:00 - 15:30 0.50 WELCTL BOPE DECOMP Teet IðWer pipe rams to 250 low 5000 /1igh for 5 mlns each test 15:30 - 16:00 0.50 WELCTL BOPE DECOMP Rig down test equipment - Pul'test plug - Install weer ring - close annulus valve 16:00 - 18:00 2.00 DRILL PULD DECOMP Make up 6" mill -2 junk baskets - 7" casg scraper - bit sub - 4 3/4" DC's - 3 1/2" HWDP 18:00 - 23:00 5.00 DRILL PULD DECOMP RIH picking up 4" DP from pipe shed to 6400' 23:00 - 00:00 1.00 DRILL CIRC DECOMP Break Clrc - Circ 20 bbls - POOH 6400' to 5920' - Circ hole - Prepare to work on tugger sheave 1/30/2005 00:00 - 03:00 3.00 DRILL OTHR DECOMP Circ - BPM 5 - PP 810 psi - Work on tugger line that was swedged in i tugger line sheave 03:00 - 05:30 2.50 DRILL TRIP DECOMP POOH - Lay down Bit sub - Junk baskets - 7" casg scraper - 6" mill 05:30 - 08:00 2.50 WINDOWPULD INTRM1 PJSM - Rig up Schlumberger tools \ß-lS 08:00 - 09:30 1.50 WINDOWELlN INTRM1 RIH with Baker bridge plug - Set plug @ 4425' WLM - POH with running tools ,09'30 - 10'00_ o 50 WINDOI/VPULD INTRM1 RiQ down and lay down Schlumberoer tools 10:00 - 10:30 0.50 CASE MIT INTRM1 Test casing to 3000 psi - Hold for 15 mins - Test good 10:30 - 13:30 3.00 WINDOWPULD INTRM1 Make up Baker Whipstock assy - Orient to UBHO sub - Surface test \'6-\S~ MWD - Good test- RIH with 4 3/4" DC's - 31/2" HWD - Change out handling tools 13:30 - 16:00 2.50 WINDOWTRIP INTRM1 RIH from 951' to 4370' - Filling pipe every 25 stands - RIH at reduced trip speed for whipstock - Tag bridge plug 4423' DP measurement 16:00 -17:00 1.00 WINDOWSETW INTRM1 Orient Whipstock to 14 degree to right of high side - PU 120 - SO 117- Set bottom trip anchor with 20K SO - PU to 125K - To verify anchor set - SO to 83K to shear from whipstock - PU to free point - Rotate to verify shear off 17:00 - 17:30 0.50 WINDOWCIRC INTRM1 Pump Hi-Vis sweep - Displace 8.8 ppg brine with 9.2 ppg LSND drilling fluid 17:30 - 23:00 5.50 WINDOWSTWP i INTRM1 : Milling window - TØ/il4405' - BOW 4417' - Drill from 4417 to 4443'- ,- WOM 2 to 4K 1st 7 feet milled - then 1 to 2k for next 31 feet milled- RPM 110 - TQ 2 to 5K 1 st 17 feet milled then 2k for next 21 feet - GPM 250 - PP 1250 23:00 - 00:00 1.00 WINDOWCIRC INTRM1 Pump Hi-Vis sweep - Work through window rotating - Attempt to slide ! through window with out rotating - Set down 25K @ 4412' - Work : window from 4404' to 4430' Pump Hi-Vis sweep - Attempt to slide through window with out rotating set down 15 to 20k from 4411' to 4420' Con't working window 1/31/2005 00:00 - 01 :00 1.00 WINDOWCIRC INTRM1 Con't work window - GPM 250 - PP 1300 - RPM 110 - TQ 2K - Slide through window with pump (no rotary) and with out pump (no rotary) - From 4403' to 4443' - taking weight 5 to 7K @ 4411 to 4420 - with pump and with out pump - Flow check - Well static Printed: 212212005 1 :50:22 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 18-15 1 8-15 ROT - SIDETRACK d 14cm@conocophillips.com Doyon 14 Start: 1/27/2005 Rig Release: 2/16/2005 Rig Number: nchorûge Spud Date: 1/28/2005 End: 2/16/2005 Group: 1/31/2005 01 :00 - 02:30 1.50 WINDOWTRIP IINTRM1 Flow check - Well static - Pump dry job - POOH from 4400' to BHA @ 953' 02:30 - 05:00 2.50 WINDOWPULD INTRM1 Stand back 3 stands 3 1/2" HWD - Lay down 4 3/4" DC's - 8 joints 3 1/2" HWD - Down load MWD - LD same - LD Baker Whipstock running assy 05:00 - 05:30 0.50 WINDOWOTHR INTRM1 Flush BOP stack - Clear rig floor 05:30 - 08:00 2.50 DRILL PULD INTRM1 MU Directional Drilling BHA - Up load MWD - Load Nukes 08:00 - 09:00 1.00 DRILL PULD INTRM1 Suirface test MWD - GPM 200 - PP 860 psi - Make up rest of BHA 09:00 - 10:30 1.50 DRILL TRIP INTRM1 TIH from 570' to 4300' 10:30-11:00 0.50 DRILL TRIP INTRM1 Orient 14 degree to right of high side - Slide through window to 4427' 11:00 -11:30 0.50 DRILL CIRC INTRM1 CBU - 200 GPM @ 1550 psi 11 :30 - 13:00 1.50 DRILL FIT INTRM1 Rig up to.prefotm FIT - MD o1M43 . TVD 4328 - ~ PJ8SSUI1t 740 psi - ÞIMIt:2 '"' 12.5 FIT - Rig down test lines - Blow down choke - kill ,lines - Conduct SPR's 13:00 - 16:30 3.50 DRILL DRLG INTRM1 Directional Drill from 4443' to 4521' - Attempt to build angle - Not building 116:30 - 17:00 0.50 DRILL TRIP INTRM1 Pump out to 4521 to 4436' - Pull through window with out pumping or rotating to 4400' - Flow check well - well static - Pump dry job - Blow down top drive 17:00 - 19:00 2.00 DRILL TRIP INTRM1 POH from 4400' to 570' 19:00 - 20:30 1.50 DRILL URM INTRM1 Stand back 31/2" HWD - 4 3/4" Flex DC's - PJSM nuke sources - Pull nuke sources - Download MWD - LD same - Break reamer and bit off - LD motor - Reamer balled - Bit balled - Two diamond cutters busted off two blades on reamer - Indication that reamer had opened up 20:30 - 21 :00 0.50 DRILL OTHR INTRM1 Clear rig floor 21 :00 - 21 :30 0.50 DRILL RIRD INTRM1 Rig up to run 3 1/2" tubing to set balanced plug from 4521' to 4230'- , Moblize cement string in pipe shed 21 :30 - 23:00 1.50 DRILL PULD INTRM1 Pick up muleshoe joint - 29 joints of 3 1/2" 1-809.3# EUE 8 rd Tubing - total length 938.86 - Make up XO 3 1/2" EUE 8 rd pin X 3 1/2" IF box by '31/2" IF pin by 4" HT 38 pin 23:00 - 00:00 1.00 DRILL TRIP INTRM1 Con't RIH from 941' to 4400' with 4" dp to 3050' 2/1/2005 00:00 - 01 :00 1.00 DRILL TRIP INTRM1 Continued running in hole with cementing assmebly to 4405' (top of whipstock). 01 :00 - 01 :30 0.50 DRILL RIRD INTRM1 Made up floor valve on pup joint. Finished in hole anc;t~edJ:,)t;)ttom at 4521'. 01 :30 - 02:30 1.00 DRILL CIRC INTRM1 Circulate and condition mud for open hole plug. 250 gpm at 720 psi. Reciprocate pipe. PU 100K SO 100K 02:30 - 04:00 1.50 DRILL CIRC INTRM1 Dowell Schlumberger blender would not start. Had to put heater on blender to warm it up before it would start. 04:00 - 05:00 1.00 CEMENT PUMP INTRM1 Pt.Imp I!IIanced plug, 5 bbIs CW1OO, test lines to 2500 psi, 1 0 bbls CW 100,10 bbIs cement 17PPG Class G, 5 bbls CW1OO, DISplace with rig pump, 36 bbls, 6 bbls min., 700 psi, plug top 4230 to 4521 05:00 - 05:30 0.50 DRILL TRIP INTRM1 Trip out with 10 stands to 3532' 05:30 - 07:30 2.00 DRILL CIRC INTRM1 Pump nut plug sweep to scour cement from pipe, 6 bbls min 480 psi 07:30 - 10:30 3.00 DRILL PULD INTRM1 Poh, lay down 3.5 tubing, and tubing Equipment 10:30 -11 :00 0.50 DRILL PULD INTRM1 I Make up new BHA# 4 11:00 -12:00 1.00 DRILL TRIP INTRM1 Trip in to 3532' 12:00 - 13:30 1.50 DRILL REAM INTRM1 Wash 3521' to 4320',250 Gpm, 780 psi, 80 rpms, tag top of cement 4320' 13:30 - 14:30 1.00 DRILL OTHR INTRM1 Drilling cement 4320' to 4427' with 8K WOB, 40 RPM 2-4K torque, went thru window with no problems 14:30 - 15:30 1.00 DRILL TRIP INTRM1 Pooh to 4400', circ and condo mud, rotate and reciprocate, 250 gpm, 800 psi, 80 rpms Printed: 2/22/2005 1 :50:22 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 18-15 1 8-15 ROT - SIDETRACK d 14cm@conocophillips.com Doyon 14 Start: Rig Release: Rig Number: 1/27/2005 2/16/2005 Anchorage Spud Date: 1/28/2005 End: 2/16/2005 Group: 2/1/2005 15:30 - 17:00 1.50 DRILL TRIP INTRM1 Pooh 17:00 - 17:30 0.50 DRILL PULD INTRM 1 Change out handing tools, stand back BHA, lay down bit, bit sub 17:30 - 19:00 1.50 DRILL PULD INTRM1 Pick up new BHA#5 19:00 - 21 :00 2.00 DRILL PULD INTRM1 Upload MWD and load Nuclear sources 21 :00 - 23:00 2.00 DRILL TRIP INTRM1 RIH to top of whipstock, Orient to 14 deg right. of high side, slide thru window with out pumping of rotating 23:00 - 23:15 0.25 DRILL DRLG INTRM1 Drill 4227 to 4228.9, lost MWD signal, started to pickup, pump pressure came up, kicked out pumps,Slacked off, pull up 50 Kover 23:15 - 00:00 0.75 DRILL OTHR INTRM1 Wor.~__5Ok overpull, tried with out pump, wouldn't pull free, tried with slow pump 15 sk per min. 800 psi, app 300 psi over slow pump rate. so we had some packing off, We tried to turn pipe, it wouldn't turn, so had to be hung up above bit and reamer,cement block ? kicked out pump working pipe with trap torque, pull free with 65k over pull, pulled above whipstock, pipe turn free and no increase of slow pump rate rate. tried to get tool face MWD tool failed 2/2/2005 00:00 - 01 :00 1.00 DRILL CIRC INTRM1 Circ, trying to get MWD tool working, slug pipe 01 :00 - 03:00 2.00 DRILL TRIP INTRM1 POH 03:00 - 04:00 1.00 DRILL PULD INTRM1 Remove Nukes, down load MWD 04:00 - 05:00 1.00 DRILL PULD INTRM1 Pulser bad, replace same, check bit and reamer, both in good shape 05:00 - 06:00 1.00 DRILL PULD INTRM1 Upload MWD, load Nukes,test MOW 06:00 - 07:30 1.50 DRILL TRIP INTRM1 Trip in to 4300' 07:30 - 08:30 1.00 DRILL TRIP INTRM1 Orient to right of high side, slide thru window,wash to bottom, some packing off,rot slow to cleaned up hole 08:30 - 00:00 15.50 DRILL DRLG INTRM1 Drilling 4428 to 4882 with 15 bit wt.,80 RPMS, 250 GPM 2150 psi, From 4428' to 4538' bit balling up, pumping nut plug sweeps, helping some, AST 8.79, ART 1.50, Tq 3K 2/3/2005 i 00:00 - 02:00 2.00 DRILL DRLG INTRM1 Drilling 4882 to 4962 with 15 bit wt.,80 RPMS, 250 GPM 2150 psi, not I getting build out of BHA, AST 1.75, Tq 3K 02:00 - 03:00 1.00 DRILL CIRC INTRM1 Circ. 1.5 bottoms up 50 spm, 1470 psi 70 rpms 03:00 - 03:30 0.50 DRILL TRIP INTRM1 Pumping out to 4450 with full drilling rate 03:30 - 05:00 1.50 DRILL TRIP INTRM1 Slug pipe, pull thru window with out pumping, Poh 05:00 - 05:30 0.50 DRILL PULD INTRM1 Stand back BHA 05:30 - 08:30 3.00 DRILL PULD INTRM1 'Unload Nukes, down load MWd, Drop off NBR 08:30 - 10:30 2.00 DRILL PULD INTRM1 Up load MWD, Change out TM Electronics, up load MWD, Test MWD 10:30 - 12:00 1.50 DRILL TRIP INTRM1 Trip in to 4400' 12:00 - 12:30 0.50 DRILL TRIP INTRM1 Orient, Slide thru window, with out pumping, RIH to 4881 ,wash 4881 to 4962 12:30 - 17:30 5.00 DRILL DRLG INTRM1 Drill 4962 to 5149' , 80 rpms, 15k bit wt., 2280 psi, 61 spm, build angle to 68 degrees, bit balling, pumping nut plug sweeps, ART 17:30 - 18:30 1.00 DRILL TRIP INTRM1 Pumping ot to 4497, with full drilling rate, pull thru whipstock with out pumping 18:30 - 20:30 2.00! DRILL TRIP INTRM1 Tripping out 20:30 - 22:00 ! 1.50 DRILL PULD INTRM1 Stand back BHA, pull nuclear sources, break off bit, bit balled up, 22:00 - 22:30 0.50 DRILL PULD INTRM1 Down load MWD 22:30 - 23:00 0.50 DRILL PULD INTRM1 install NBR and bit 23:00 - 00:00 1.00 DRILL PULD INTRM1 Up load MWD 2/4/2005 00:00 - 00:30 0.50 DRILL PULD INTRM1 Load Nukes 00:30 - 02:30 2.00 DRILL TRIP INTRM1 Trip in to 4400' 02:30 - 04:00 1.50 RIGMNT RSRV INTRM1 Slip and cut Drilling line, Service topdrive 04:00 - 04:30 0.50 DRILL TRIP INTRM1 Trip in to 4950' 04:30 - 06:00 1.50 DRILL REAM INTRM1 Shear NBR with 250 gals min, Reaming hole 4950 to 5149 06:00 - 00:00 18.00 DRILL DRLG INTRM1 Drilling 5149' to 5937' with 300 gals per min., 3200 psi, 10-15K bit wt., 80 rpms, AST 4.24, ART 8.32, Tq 3k Printed: 2/22/2005 1 :50:22 PM In Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 8-15 18-15 ROT - SIDETRACK d 14cm@conocophillips.com Doyon 14 Sta rt: Rig Release: Rig Number: 1/27/2005 2/16/2005 Spud Date: 1/28/2005 End: 2/16/2005 Group: 2/5/2005 00:00 - 00:00 24.00 DRILL DRLG INTRM1 Drilling 5937' to 7330' with 300 gals per min., 3200 psi, 10-15K bit wi., 80 rpms, AST 3.74, ART 15.02, Tq 3k 2/6/2005 00:00 - 22:00 22.00 DRILL DRLG INTRM1 Drilling 7330' to 8350' TO with 300 gals per min., 3200 psi, 1D-15K bit wi., 80 rpms, AST 10.46, ART 8.44, TO 5K 22:00 - 00:00 2.00 DRILL CIRC INTRM1 Circ., 3 bottoms up with 300 gpm 3000 psi, 80 rpms 2/7/2005 00:00 - 03:00 3.00 DRILL TRIP INTRM1 Pump out to 4450 with full drilling rate, flow check. 03:00 - 04:30 1.50 DRILL TRIP INTRM1 RIH to 8350' 04:30 - 06:30 2.00 DRILL CIRC INTRM1 Circ 3 bottoms up 300 gal min. 3100 ps, 85 rpms 06:30 - 09:30 3.00 DRILL TRIP INTRM1 Pump out to 4450 with full drilling rate 09:30 - 11 :00 1.50 DRILL CIRC i INTRM1 Circ 300 gals min 2800 psi, 80 rpms, till shakes clean up, flow check well, slug pipe 11 :00 - 12:30 1.50 DRILL TRIP INTRM1 POH to 570' 12:30 - 13:30 1.00 DRILL PULD INTRM1 lay down 3.5 HWP and flex DC 13:30 - 15:00 1.50 DRILL PULD INTRM1 Pull nuclear sources, down load MWD 15:00 - 16:30 1.50 DRILL TRIP INTRM1 Lay down MWD,bit and motor 16:30 - 17:30 1.00 DRILL RIRD INTRM1 Clear rig floor of tools, rig up to pickup 5.5 liner 17:30 - 18:30 1.00 DRILL SFTY INTRM1 'PJSMonpiCkll'lgup Iiner,Make up shoe tra'ék, check floats 18:30 - 00:00 5.50 CASE PULR INTRM1 Piokjng up 5.5 liner aliò per running program to 2540' 2/8/2005 00:00 - 04:30 4.50 CASE PULR ' INTRM1 Picking up 5.5 15.5# L-8Ö liner as per running program to 4120" total of 1 00 jts 04:30 - 05:00 0.50 CASE PUTB INTRM1 I Picking up Baker Liner hanger and liner top packer 05:00 - 13:00 8.00 CASE RUNL INTRM1 Tripping in with liner to 8130' hit bridge @ 8130 13:00 - 15:00 2.00 CASE RUNL INTRM1 Break circ. 2 bbls min 950 psi, wash thru bridge, trip to bottom 8350' 15:00 - 15:30 0.50 CASE RUNL INTRM1 Picking up Cementing head and circ lines 15:30 - 17:00 1.50 CASE CIRC INTRM1 Circ and work pipe 10-15 ft., 3 bbls min. 920 psi, full returns 17:00 - 19:00 I 2.00 CEMENT PUMP INTRM1 Cement w/ Schlumberger 10 bbls CW100, test lines to 4000 psi, 20 I bbls CW100, 30 bbls Mudpush @ 11.5, Batch mix, 80 bbls Class G 383 sxs w .2% gal per sx 0047, .03% B155,.3% 0065, 2 gal per sx D600G, mix @ 15.8, wash out lines, kicked out plug w/5 bbls water, Displace with rig pumps 137 bbls mud, bump plug with 3000 to set hanger,bleed pressure off floats held,rotate 15 turns to right, pressure up to 1000 psi and pull out of liner 19:00 - 20:30 1.50 CEMENT DISP INTRM1 Circ out cement and clabbered mud, total of 10 bbls of good cement to surface. 20:30 - 21 :00 0.50 CASE MIT INTRM1 Test liner top packer to 500 psi for 5 min. 21 :00 - 22:00 1.00 CEMENT RURD INTRM1 Service break cement head and lay down same, rearrange DP in derrick for 27/8 pocket 22:00 - 00:00 2.00 DRILL TRIP INTRM1 Pull 4 stands, laying down excess 4" pipe 2/9/2005 00:00 - 01 :30 1.50 DRILL PULD INTRM1 Laying down excess 4" pipe 01 :30 - 02:30 1.00 DRILL PULD INTRM1 Break and lay down liner running tools 02:30 - 03:30 1.00 WELCTL BOPE INTRM1 Pull wear ring, rig up to test BOPS 03:30 - 07:30 4.00 WELCTL BOPE INTRM1 TeötjngBOPS and Manifold 25().;5000 psi 5 min. per test, Hydril 250-35QØ;PSi 5 mÎn. per test;thè 'right to witness test was wavier by ChuCk Scheve AOGCC 07:30 - 08:00 0.50 DRILL RIRD INTRM1 Install new wear ring 08:00 - 09:00 1.00 DRILL PULD INTRM1 Mobilize 27/8 Equipment and tools 09:00 - 13:00 4.00 DRILL PULD INTRM1 Picking up 2 7/8 drill pipe, 138 jts 13:00 - 14:00 1.00 DRILL CIRC INTRM1 Circ thru 2 7/8 7 bbls min. 3300 psi 14:00 - 16:00 2.00 DRILL TRIP INTRM1 Standing 2 7/8 back in derrick 16:00 - 17:00 1.00 DRILL PULD 'INTRM1 ,Picking up 3 3/4 Spiral HWD, pumped thru same 17:00 - 17:30 0.50 DRILL TRIP INTRM1 stand HWD in derrick 17:30-21:00 3.50 DRILL PULD INTRM1 Picking up BHA # 9, up load MWD 21 :00 - 00:00 3.00 DRILL TRIP INTRM1 RIH to 4450 with 2 7/8 pipe, fill pipe @ 22504150 I I I Printed: 2/22/2005 1: 50: 22 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 18-15 18-15 ROT - SIDETRACK d 14cm@conocophillips.com Doyon 14 Start: 1/27/2005 Rig Release: 2/16/2005 Rig Number: Spud Date: 1/28/2005 End: 2/16/2005 Group: 2/10/2005 00:00 - 00:30 0.50 RIGMNTI RSRV PROD Service rig and top drive 00:30 - 02:30 2.00 DRILL TRIP PROD IRIHt08181 02:30 - 03:00 0.50 DRILL CIRC PROD Break circ. and Establish drlg parameters 03:00 - 04:00 1.00 CASE MIT PROD Test Csg to 3,500 psi for 30 min., good test 04:00 - 05:30 1.50 CEMEN DSHO PROD Drilling shoe tract to 8349 to top of shoe 05:30 - 14:00 8.50 DRILL CIRC PROD Circ. pump hivis sweeps, pumping EP- sweeps, displace csg with new 11.6 LSND mud, wi up to 11.8+ , all pumping done @ 149 gal min. 3400 psi 14:00 - 15:00 1.00 CEMENT DSHO PROD Drill out shoe and new hole to 8371' 15:00 - 16:00 1.00 DRILL CIRC PROD Circ for FIT 16:00 - 17:30 1.50 DRILL DEQT PROD FIT Witblf.8mud, Tvd 6361,1390 psi," 16.0 EMW 17:30 - 00:00 6.50 I DRILL DRLG PROD Drìlling 8371 to 8467 with 5-10 bit wi. 30 rpms, 140 gpm, 3400 psi, AST I 4.04,ART .67, TQ 3K 2/11/2005 ! 00:00 - 14:30 14.50 DRILL IDRLG ,PROD Drilling 8467 to 8621 with 5-10 bit wi. 30 rpms, 140 gpm, 3400 psi,AST I 10,ART 13.61 14:30 - 15:00 0.50 DRILL TRIP PROD Short Trip out to 8350 and back to bottom 15:00 - 16:00 1.00 DRILL CIRC PROD Circ 1.5 bottoms up with 150 gpm. 3400 psi, 30 rpms 16:00 - 16:30 0.50 DRILL TRIP PROD Pump out to 8350 16:30 - 17:30 1.00 DRILL CIRC 'PROD Drop dart open circ. sub, circ. with 260gpm 3700 psi, drop 1.91 drift, slug pipe 117:30 - 22:30 5.00 DRILL TRIP PROD Tripping out for liner 22:30 - 00:00 1.50 DRILL PULD PROD Laying down BHA,Down load MWD 2/12/2005 1.00:00 - 01 :00 1.00 DRILL ITRIP PROD Laying down BHA ! 01 :00 - 02:00 1.00 CASE SFTY CMPL TN PJSM,rig Up to pickup 3.5 liner 02:00 - 04:00 2.00 I CASE PULR CMPL TN Pickup 14 jts 3.5 hydrill 511 1-809.2#, Baker HMC liner hanger,Baker I ZXP liner top packer, circ liner vol. 04:00 - 09:00 5.00 CASE RUNL I CMPL TN í Trip in with liner 8343' 09:00 - 10:00 1.00 CASE CIRC CMPL TN Circ @ 8343', one drill pipe vol. 2 bbl min 1020 psi 10:00 - 10:30 0.50 CASE RUNL CMPL TN Trip in to 8621 with liner, make up cement head 10:30 - 12:00 1.50 CASE CIRC CMPL TN Circ with 2 bbl. min 1020 psi, worked liner 15 ft. P/U 140K, SIO 11 OK, 2.00 I CEMENrUMP Liner wi. 4K 112:00 - 14:00 CMPL TN Cement wI Schlumberger 5 bbls water, test lines 4,000 psi, 10 bbls CW100, 3 bbls, 13.5# mud push, 10 bbls 55 sxs 15.8# class G cement, washed out lines,drop dart, 5 bbls water, 66 bbls 11.9 mud, over displace 4 bbls, still didn't bump plug, saw pressure in crease to 2200 psi when cement started out shoe, think that is when liner released. i liner top should be @ 8116 14:00 - 20:00 6.00 I DRILL TRIP CMPL TN Tripping out with liner running tool 20:00 - 21 :00 1.00 DRILL PULD CMPL TN I Picking up 4 3/4 mill, float sub and 6 SWDP ,21 :00 - 00:00 3.00 DRILL TRIP CMPL TN Tripping in with 4 3/4 mill to 5000 2/13/2005 00:00 - 01 :30 1.50 DRILL TRIP CMPL TN Trip in to 7100' 01 :30 - 03:30 2.00 DRILL REAM CMPL TN Wash down 7100 to 7650, stringer cement 7650 to 7850, drill hard I cement 7880 7950, no cement 7950 to top of liner 8121',235 gls min. I 3300 psi, 30 rpms 03:30 - 05:00 1.50 I CASE CIRC CMPL TN Circ 2 bottoms up 235 gpm 3300 psi 05:00 - 09:30 4.50 DRILL I TRIP CMPL TN Tripping out lay down 33 jts 2 7/8, lay down 4 3/4 mill 09:30 - 10:30 I 1.00 RIGMNT RSRV CMPL TN , Clear floor, Service rig 10:30 - 17:00 6.50 DRILL TRIP 'CMPL TN I Pickup dummy seals,32 jts SWDP, Tripping in hole 17:00 - 17:30 0.50 CASE PTCH CMPL TN Attemp to sting dummy seals into tie back @ 8121', unsuccessful, 168 gpm, 2200 psi 17:30 - 18:30 1.00' CASE CIRC CMPL TN ,Circ bottoms up, slug pipe, 168 gpm, 2200 psi 18:30 - 23:00 4.50 DRILL TRIP CMPL TN ¡Tripping out, Lay down seal assy. 123:00 - 00:00 1.00 DRILL iPULD CMPL TN I Picking up 4" mill, 17 ft. Extention,4 3/4 stab.,5 .5 Csg scaper, i I I Printed: 212212005 1 :50:22 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 8-15 1 8-15 ROT - SIDETRACK d 14cm@conocophillips.com Doyon 14 Start: 1/27/2005 Rig Release: 2/16/2005 Rig Number: Anchorage Spud Date: 1/28/2005 End: 2/16/2005 Group: 2/14/2005 00:00 - 00:30 0.50 RIGMNT RSRV CMPL TN 00:30 - 04:30 4.00 DRILL TRIP CMPL TN 04:30 - 05:30 1.00 CASE PTCH CMPL TN 05:30 - 07:00 1.50 CASE CIRC CMPL TN 07:00 - 08:00 1.00 DRILL TRIP CMPL TN 08:00 - 11 :00 3.00 RIGMNT RSRV CMPL TN 11 :00 - 14:00 3.00 DRILL TRIP CMPL TN 14:00 -15:00 1.00 DRILL PULD CMPL TN 15:00 - 16:00 1.00 CASE MIT CMPL TN 16:00 - 16:30 0.50 DRILL PULD CMPL TN 16:30 - 20:00 ' 3.50 DRILL TRIP 'CMPL TN 20:00 - 21 :00 1.00 CASE MIT CMPL TN 21 :00 - 22:00 I 1.00 CASE CIRC CMPL TN 22:00 - 00:00 2.00 CMPL TN TRIP CMPL TN 2/15/2005 , 00:00 - 00:30 0.50 CMPL TN TRIP CMPL TN 00:30 - 02:00 1.50 CMPL TN TRIP CMPL TN 02:00 - 04:00 2.00 CMPL TN TRIP CMPL TN 04:00 - 05:30 1.50 CMPL TN RURD CMPL TN 05:30 - 06:30 1.00 CMPL TN RURD CMPL TN ì 06:30 - 07:00 0.50 CMPL TN' RUNT CMPL TN 07:00 - 13:30 6.50 CMPL TN RUNT CMPL TN 13:30 - 15:00 1.50 CMPL TN RUNT CMPL TN 15:00 - 17:00 2.00 CMPL TN RUNT CMPL TN 17:00 - 21 :00 4.00 CMPL TN, SOHO CMPL TN 21 :00 - 23:00 2.00 CMPL TN CIRC CMPL TN 23:00 - 23:30 0.50 CMPL TN CIRC CMPL TN 23:30 - 00:00 0.50 CMPL TN SOHO CMPL TN 2/16/2005 00:00 - 01 :45 1.75 CMPL TN PULD CMPL TN 01 :45 - 02:00 0.25 CMPL TN OTHR CMPL TN 102:00 - 02:10 0.17 CMPLTN SFTY CMPL TN 02: 1 0 - 04:00 1.83 CMPL TN NUND I CMPL TN 04:00 - 06:00 2.00, CMPL TN NUND CMPL TN 06:00 - 07:30 1.50 CMPlTN NUND CMPL TN 07:30 - 09:30 2.00 CMPL TN DEQT ! CMPL TN 09:30 - 10:45 1.25 CMPL TN FRZP CMPL TN Service rig and top drive Finish picking up 4" mill and Csg scraper BHA, trip in to 8100 Circ and mill out tieback sleeve, total 17 ft,8121 to 8138' took wt on the first ft after that it was clean., attempt to set packer with 45K, it didn't shear. Circ bottoms up Tripping out with 4" mill to 6000' Slip on new Drilling line Tripping out with mill to bha Laying down BHA Test(ì.i(i wiäl3.õOOpai for 30 min. Picked up Seal assy Trip in to 8121 with Seal assy Est. Circ., Sting into Tie back @ 8121, 15 ft.with 30000# , Test backside with 3500 psi 10 min., Test down drill pipe to 3,500psi for 10 min., un sting from tie back Circ bottoms up,slug pipe and blow down topdrive Laying down drill pipe Rig service - Change out handling equipment to 2 7/8" from 4" Lay down 2 7/8" drill pipe Lay down 2 7/8" SWDP - Service break and lay down seal assembly Pull wear ring - Lay down all vendors tools - Clear rig floor I Rig up to run completion string - Make up LOG jt with XO - floor valve and head pin - PJSM - Make up tail assembly Con't RIH with 3 1/2" completion string to 6275' Make up SSSV - Rig up control line - Test same to 5000 psi 20 mins Con't RIH with 3 1/2" completion string to 8121 Tag top of tie back sleeve - Make up landing joint - Pump down tubing @ 1 bpm 690 psi verify top Tie back sleeve - PU 104 - SO 84 - Space out - Lay down landing joint - make up pup joint - 1 joint tubing - hanger - Hook up control line - Test to 5000 psi 10 mins - Make up landing joint Displace well to seawater - Displace tubing vol - Shut down flow check well for 10 mins - Well static - Con't displacing well to sea water 2 X - 6 bpm - ICP 2120 psi FCP 1150 psi - flow check for 15 mins - well static Pump corrosion inhibitor @ 6 bpm - 1530 psi - spot with sea water Drain stack - Land hanger - PU 1 07K - SO 97K - Block weight 50K - 33 stainless steel bands used on control line I PTSM, Back out and lay down landing jt. Clear rig floor of all handling tools. Install BPV. Held PJSM for NID BOPE. I Nipple Down BOPE. Nipple up adapter flange and tree. PT adapter flange to 5,000 psi. Function test SSSV. Install tree test plug. PT tree to 5,000 psi. RIU circulating lines on tree. PT to 4,000 psi. Pull tree test plug. i PT tbg to 3,500 psi for 30 min., OK, Bleed down tbg pressure to 1,600 psi. PT tbg x csg annulus to 3,500 psi for 30 min, OK. Bleed off tbg pressure shear out DCK valve in GLM # 1. Pump 75 bbls freeze protect diesel down tbg x csg annulus at 1.9 bpm 2,000 psi. Printed: 2/2212005 1 :50:22 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 8-15 18-15 ROT - SIDETRACK d 14cm@conocophillips.com Doyon 14 Start: 1/27/2005 Rig Release: 2/16/2005 Rig Number: Anchorage Spud Date: 1/28/2005 End: 2/16/2005 Group: 2/16/2005 10:45 - 11 :40 11 :40 - 12:00 12:00 - 13:00 , I 0.92 CMPL TN FRZP ì CMPL TN U-tube diesel. 0.33 CMPL TN OTHR CMPL TN Install BPV, RID circulating lines. ¡ 1.00 CMPL TN OTHR CMPL TN Secure wellhead and tree. Finish cleaning mud pits. Prepare rig for / move. Release rig from operations on well1B-15A at 13:00 hrs on 2/16/2005. Printed: 2/22/2005 1 :50:22 PM Sidetrack KOP @ +1- 4400' MD, +1- 4320 TVD Original Wellbore Tapered Production CSG - 7" 26# L-80 CSG to 6660' MD x 5" 18.0# L-80 to 7432'MD P&A cmt plug 1 B-15A Finall-Built 02/16/20 Co~c6Phillips ~ rr U n ~ I h u ~ ~ ~ . ~ I ~ ~ ~ ~ ~ ~ ~ . U ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ L ~. ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ( ~ ~ ~ 1 ~ ~ ~ ~ 1 3-1/2" 5M FMC Gen IV tubing hanger with 3-1/2" L-80 EUE 8rd pin down 3-1/2",9.3#, L-80 EUE 8rd tubing to surface 3-1/2" Cameo TRM-4E SSSV at 1833' MD, 2.812" min 10 RECEIVED APR 2 9 2005 -y1 U n U U II ~ I n I ~ ~ ~ ~ I U U U U n 9-5/S" LSO casing ~ ~ @4190' MD 14139 ~ TVD ~ ~ ~ ~ ~ I ~ ~ I!! ~ ~ ~ I ~ ~ ~ ~ I ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ I ~ ~ ~ I ¡ r Baker "K-1" CIBP @ ~ ~ +1- 4423' MD óI , ~ - - ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ I ~ ~ ~ ~ ~-%" tbg cut and pulled ~ ~ from +1- 50' above the I ~ packer . .1 I ~ ~ ~ ~ ~ ~ ~ \ = I Kup C ,and 8205' M015239' TVD -- 3-1/2" 9.3# L-80 EUE 8rd Mod tubing to GLM 3-1/2" 9.3# L-80 EUE 8rd Mod tubing as necessary Alaska Oil &. Gas Cons. CommissiQIì Anchorsge Top of 7"x5-%" Liner Tie Back Sleeve @ 4234' MD 3 %" X 1" Cameo mandrels Place gas-lift mandrels at the following planned depths- adjust accordingly at TD MD Valve Type 2573 1.00 KBUGM 3938 1.00 KBUGM 5364 1.00 KBG2-9 7262 1.00 KBG2-9 8036 1.00 KBG2-9 1 2 3 4 5 3 %" Cameo 'DS' nipple wI 2.75" No-Go profile, @ 8080' MD Top of 3-%"x5-%" Liner Tie Back Sleeve @ 8121 Btm of 3- %"x5- %" Liner Tie Back Sleeve @ 8139 5-%" Liner CSG point @ 8350' MDI 6350' TVD Kup A sand Target 8427' MD/6429f TV TO @ 8621' MO/6361' TVO Drawn by MDK 11/1104 TUBING (0-8121, OD:3.500, ID:2.992) LOCATOR (8118-8119, ODA.260) PACKER (8140-8141, ODA.670) PBR (8148-8149, ODA.350) Perf (8305-8307) Perf (8506-8510) ConocoPhilUps AI.a, Inc. 1B-15A i: :Ie .. = . S-15A KRU API: 500292246501 SSSV Type: TRDP Annular Fluid: Well Type: PROD Orig Completion: Last W/O: TS: deg @ TD: deg @ 8621 TAG, PERF SOZ, GL V design Last Update: 4/2/2005 Reference Log: 34' RKB Last Tag: 8470 Last Tag Date: 3/23/2005 Casing String- ALL STRINGS Description Size CONDUCTOR 16.000 SURFACE 9.625 PRODUCTION 7.000 Protection Liner 5.500 Production Liner 3.500 Tubing String - TUBING Size I Top 3.500 0 Perforations Summary Interval TVD Zone 8305 - 8307 8305 - 8307 Ref Log Date: TD: 8621 ftKB Max Hole Angle: 0 Top Bottom TVD 0 121 121 0 4190 4190 0 4405 4405 4234 8350 8350 8121 8621 8621 Grade Thread L-80 EUE8rd Status Ft SPF 2 4 Date 3/2/2005 Type Comment SOZ 1 9/16" Gun, Small charges for PERF cement squeeze on back side SOZ 2.5" HSD Powerflow 60 deg PERF phase for cement squeeze on back side Port TRO Date Vlv Run Cmnt 0.156 1295 3/30/2005 0.188 1322 3/30/2005 0.188 1309 3/30/2005 0.188 1295 3/30/2005 0.188 0 3/30/2005 8506 - 8510 8506 - 8510 4 6 3/2/2005 Gas Lift MandrelsNalves St MD TVD Man Mfr Man Type V Mfr V Type V OD Latch 1 2573 2573 CAMCO KBUG-M GLV 1.0 BK-5 2 3939 3939 CAMCO KBUG-M GLV 1.0 BK-5 3 5364 5364 CAMCO KBG-2-9 GLV 1.0 INT 4 7263 7263 CAMCO KBG-2-9 GLV 1.0 INT 5 8037 8037 CAMCO KBG-2-9 OV INT Other -'plugs, equip., etc.) - JEWELRY Depth TVD Type Description 30 30 HANGER FMC GEN IV TBG HANGER 1833 1833 SSSV CAMCO TRM-4E SAFETY VALVE 8080 8080 NIP CAMCO 'D' LANDING NIPPLE 8118 8118 LOCATOR BAKER NO GO LOCATOR 8119 8119 SEAL BAKER BULLET SEAL ASSEMBLY Other ,(plugs. equip., etc.) - Protection Liner Jewelry Depth TVD Type Description 4235 4235 TIE BACK BAKER LINER TIE BACK SLEEVE SLY 4241 4241 PACKER BAKER 'CPH' LINER TOP PACKER 4245 4245 HANGER BAKER 'HMC' LINER HANGER 8177 8177 Centralizer WEATHERFORD IN-LINE CENTRALIZER 8221 8221 Centralizer WEATHERFORD IN-LINE CENTRALIZER 8224 8224 COLLAR 5.5" JOINT w/INSERT LANDING COLLAR 8264 8264 Centralizer WEATHERFORD IN-LINE CENTRALIZER 8309 8309 Centralizer WEATHERFORD IN-LINE CENTRALIZER Other ~plugs. eqúip., etc.) - Production Liner Jewlery Depth TVD Type Description 8121 8121 TIE BACK BAKER LINER TIE BACK SLEEVE SLY 8140 8140 PACKER BAKER 'ZXP' LINER TOP PACKER 8148 8148 PBR POLISHED BORE NIPPLE SL-HT 8152 8152 HANGER 3.5" x 5.5" BAKER 'HMC' LINER HANGER 8498 8498 RETAINER HES 3.5" EZ DRILL RETAINER 8556 8556 COLLAR BAKER 3.5" LANDING COLLAR General Date Note 2/13/2005 TREE: GMC/GENIV/3-1/8"5M TREE CAP CONECTION: 5.75 OTIS OUICK CONNECT 2/13/2005 WELL SIDETRACKED ID 3.500 2.812 2.750 2.970 2.990 10 5.500 4.870 4.920 4.850 4.850 4.950 4.850 4.850 ID 4.130 3.410 3.230 2.920 0.000 2.993 RECE\VED - APR 2 9 Z005 CQmmíssiol1 0'\ & Gas Cons. . Maska I Anchorage RECEIVED Date Summary APR 2 9 2005 02/18/05 MILLED OUT CEMENT FROM 8019' CTM TO 8537' CTM USING WF 2-3/8 MHA, 2-1/4 JARS, 2-3/8 MOTOR, & 2.70 X 2.92 BI-CENTER BIT. ENCOUNTERED MAIf'lúltSka Oil & Gas Cons. Commission "STRINGERS". MADE 2ND RUN W/ SAME TS- SWAPPED BIT W/2-1/8" REEVES Anchorage UNDERREAMER (2.95 BLADES FULL-OPEN). 02/19/05 DRIFT & TAG W/10 X 2.125" TO 8541' SLM. DRIFTED 20' X 2.5" DUMMY GUN TO 8541' SLM, HOWEVER HAD A COUPLE TIGHT SPOTS @ 5465' & 5716' SLM. [Tag] 02/22/05 ATTEMPT TO LOG SCMT FAILED WHEN TOOLSTRING BECAME STUCK. TOOLS SAT DOWN HARD AT 8130' (ELMD). LIKELY SCENARIO IS THAT ROLLERS (2.62") ARE STUCK IN 'D' NIPPLE AT 8080' DRILLERS DEPTH. PULLED 3300 LB TENSION AT SURFACE TO BREAK WEAKPOINT. FISH DESCRIPTION: 52' OVERALL LENGTH. . 1B-15A Well Events Summary . 02/23/05 RETRIEVED 52' E-LlNE FISH FROM 8066' RKB (TOP OF FISH. FISH WAS INTACT WITH NO IRREGULARITIES SHOWING.. DRIFTED TBG. W/2.74 SWAGE DOWN TO TD ( TAG) @ 8549' RKB. [Fish, Tag] 02/24/05 RAN SCMT IN 3 1/2" LINER: FOUND LITTLE OR NO CEMENT BEHIND THE 3 1/2" LINER FROM 8540' TO 8156' 02/26/05 PULLED SOV & SET DMY @ 8037' RKB. PULLED & RESET DMY @ 7263' RKB. MITIA 1500 PSI, GOOD.[GLV, PT Tbg-Csg] 03/02/05 SHOT SQUEEZE PERFS: PERFORATED 8305' - 8307', 4 SPF SMALL TBG PUNCHER CHARGES AND 8506' - 8510', 6 SPF 2 1/2" POWERFLOW CHARGES -- WILL SET CEMENT RETAINER ON 3/3/05 03/03/05 SET HES 31/2" EZ DRILL SVB SQUEEZE PACKER WITH TOP AT 8498' 03/17/05 PERFORMED A CEMENT SQUEEZE WITH 10 BBLS OF 15.8 PPG CEMENT; 5 BBLS PLACED BELOW THE RETAINER & INTO THE 3-1/2" X 5-1/2" ANNULUS,S BBLS OF CEMENT LAYED ON TOP OF RETAINER @ 8480' CTD. GOOD COMMUNICATION BETWEEN THE PERFS WHEN PUMPING BELOW RETAINER. TOC DEPTH @ 8200' CTD. WELL SI AND FREEZE PROTECTED FROM 2500' WITH DIESEL. 03/18/05 TAG CEMENT TOP @ 8204' WLM, (CTU WASHED TO 8200 CTD. RETAINER @ 8480' CTD) W/2.5" CENT, SB, SOLID [Tag] 03/19/05 MILLED OUT 145' OF CEMENT TO 8338' CTD WITH A 2.2" WEATHERFORD MHA & 2.70" X 2.92" BI-CENTER BIT. TOOL INSPECTION ON SURFACE SHOWED EXCESSIVE WEAR, PDC BUTTONS ON ORBITAL LOBE CHIPPED & FRACTURED. JOB WILL BE CONTINUED IN THE AM WITH A NEW MILL, 145' OF CEMENT REMAINING, FREEZE PROTECTED WITH DIESEL. 03/20/05 MILLED OUT CEMENT FROM 8340' TO RETAINER @ 8477' CTM USING 2-1/8" WEATHERFORD MHA, CIRC SUB, JARS, MOTOR & 2.70" 5-BLADE JUNK MILL. MADE 2ND RUN WITH SAME TS, SWAPPED BIT FOR 2-1/8" UNDERREAMER WITH 2.95" FULL OPEN BLADES. MADE 2 PASSES FROM 8200' - 8477' CTM THROUGH CEMENTED AREA OF LINER 03/23/05 DRIFT W/2.50" X 10' DUMY GUN TO 8470' WLM, 8477' RKB, NO PROBLEMS, AFTER CLEANING UP CEMENT @ 7266' WLM, [Tag] 03/27/05 RAN POST SQUEEZE SCMT: CEMENT WAS GOOD FROM 8476' TO 8305' (TOP SQZ PERFS AT 8305-8307), FAIR CEMENT FROM 8305' TO 8240' AND POOR CEMENT FROM 8240' TO 8160' -- TAGGED BOTTOM AT 8490' [Perf] . 1B-15A Well Events Summary . 03/28/05 PERFORATED: 8432' - 8452',6 SPF ALTERNATING POWERJET AND POWERFLOW CHARGES -- STUCK GUN STRING AFTER FIRING AND LOGGING OFF FROM SECOND GUN RUN -- PULLED OUT OF WEAK POINT -- TOP OF FISH AT 8203', LENGTH= 34.3', WEIGHT= 350 LBS, MAX 00 2.66" AT BURRS ON FIRED GUN. 03/29/05 FISHED 34.5' SCHLUMBERGER PERF GUN ASS'Y FROM 8430' SLM. MEASURED BHP @ 8442' RKB: 3115 PSI. [Fish, Pressure Data] 03/30/05 PULLED DVs @ 8037' & 7263' RKB. IN PROGRESS. [GLV] 03/31/05 PULLED DVs @ 5364',3939',2573' RKB. INSTALLED NEW GLVs IN STATIONS 1-5. [GLV] RECEIVED APR 2 9 Z005 Alaska Oil & Gas Cons. (:o!11mis$ìon Anchorage Halliburton Sperry-Sun Western North Slope ConocoPhillips 1 B-15A Job No. AKMW3499847, Surveyed: 11 February, 2005 Survey Report 7 March, 2005 ,/ Your Ref: API 500292246501 Surface Coordinates: 5969647.05 N, 549955.18 E (70019'40.2606" N, 149035'41.5237" W) Grid Coordinate System: NAD27 Alaska State Planes, Zone 4 Kelly Bushing Elevation: 95.00ft above Mean Sea Level SpE!I""'I""'Y-SU:1'1 bAIL-L.ING·· SeRVICeS A Halliburton Company DEFINITIVE . . RECEIVED APR 2 9 Z005 AI~~kª Oil & Gas Cons. Commission . Anchorage Survey Ref: svy2120 Halliburton Sperry-Sun Survey Report for 1B-15A Your Ref: API 500292246501 Job No. AKMW3499847, Surveyed: 11 February, 2005 ConocoPhillips Western North Slope Measured True Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (O/100ft) 4166.56 29.890 218.910 4022.67 4117.67 301.07 S 200.48 W 5969344.65 N 549756.71 E 347.10 Tie On Point MWD+SAG ... 4405.00 30.040 218.170 4229.24 ",.-: 4324.24 .; 394.22 S 274.68 W 5969251.01 N 549683.13 E 0.167 463.82 Window Point 4430.86 31.620 219.320 4251.45 4346.45 404.55 S 282.98 W 5969240.62 N 549674.90 E 6.521 476.82 4526.97 38.520 223.590 4330.07 4425.07 445.78 S 319.63 W 5969199.15 N 549638.53 E 7.616 531.39 . 4622.76 41.830 221.290 4403.26 4498.26 491.40 S 361.29 W 5969153.26 N 549597.17 E 3.786 592.63 4717.73 44.550 222.530 4472.49 4567.49 539.75 S 404.71 W 5969104.61 N 549554.07 E 3.000 656.97 4814.06 49.540 223.670 4538.11 4633.11 591.19 S 452.89 W 5969052.85 N 549506.24 E 5.252 726.94 4910.17 51.250 224.200 4599.38 4694.38 644.51 S 504.27 W 5968999.19 N 549455.22 E 1.829 800.58 5006.25 57.790 229.020 4655.14 4750.14 698.11 S 561.16 W 5968945.22 N 549398.68 E 7.936 878.61 5102.71 65.930 232.240 4700.60 4795.60 751.94 S 626.90 W 5968890.96 N 549333.30 E 8.936 963.57 5198.06 69.060 233.940 4737.10 4832.10 804.82 S 697.33 W 5968837.61 N 549263.22 E 3.673 1051.52 5293.61 70.890 234.510 4769.82 4864.82 857.30 S 770.17 W 5968784.65 N 549190.74 E 1.996 1141.04 5390.15 69.970 235.600 4802.15 4897.15 909.40 S 844.73 W 5968732.05 N 549116.53 E 1 .428 1231.65 5485.98 68.320 236.590 4836.27 4931.27 959.35 S 919.04 W 5968681.60 N 549042.54 E 1.974 1320.69 5581.70 69.000 236.530 4871.10 4966.10 1008.48 S 993.44 W 5968631.97 N 548968.48 E 0.713 1409.26 5676.66 69.710 230.840 4904.61 4999.61 1061.09 S 1065.00 W 5968578.89 N 548897.27 E 5.657 1497.89 5772.67 69.970 229.260 4937.70 5032.70 1118.96 S 1134.09 W 5968520.56 N 548828.57 E 1.568 1588.02 5868.95 69.250 231.110 4971.24 5066.24 1176.75 S 1203.40 W 5968462.32 N 548759.64 E 1.950 1678.26 5965.19 69.770 230.900 5004.93 5099.93 1233.48 S 1273.47 W 5968405.12 N 548689.95 E 0.578 1768.40 6061.50 69.040 232.360 5038.81 5133.81 1289.44 S 1344.15W 5968348.69 N 548619.65 E 1.609 1858.51 > 6157.85 68.190 234.360 5073.95 5168.95 1342.98 S 1416.13 W 5968294.67 N 548548.03 E 2.125 1948.07 m :xJ. C/O 6253.80 66.520 236.120 5110.89 5205.89 1393.47 S 1488.87 W 5968243.70 N 548475.62 E 2.428 2036.24 :JO:'" DJ 6349.77 66.920 236.430 5148.82 5243.82 1442.41 S 1562.19 W 5968194.27 N 548402.63 E 0.512 2123.87 9 6446.04 68.050 236.030 5185.68 5280.68 1491.85 S 1636.11 W 5968144.34 N 548329.04 E 1.235 2212.28 » m f20 " 6542.68 68.180 235.210 5221.71 5316.71 1542.49 S 1710.12 W 5968093.21 N 548255.37 E 0.799 2301.52 >G") ;;0 () ::J I» 6639.07 66.590 235.620 5258.77 5353.77 1592.99 S 1783.37 W 5968042.22 N 548182.45 E 1.696 2390.10 g.cn ~ m Q ("") .... (C 6735.22 65.030 235.070 5298.17 5393.17 1642.86 S 1855.52 W 5967991.87 N 548110.64 E 1.704 2477.42 S» 0 - ::I 6831.82 65.900 235.040 5338.28 5433.28 1693.20 S 1927.55 W 5967941 .06 N 548038.94 E 0.901 2564.96 co f<t f'...) < CD c::> 6925.85 64.890 235.330 5377.43 5472.43 1742.01 S 1997.74 W 5967891.78 N 547969.08 E 1.110 2650.10 ("") c::> m 547897.50 E 0.354 2737.19 0 U1 7022.31 65.230 235.290 5418.11 5513.11 1791.79S 2069.66 W 5967841.52 N 3 CJ 3 ¡;. In ëï -:::! 7 March, 2005·13:16 Page 2 of 4 DrillQuest 3.03.06.008 Halliburton Sperry-Sun Survey Report for 1B-15A Your Ref: API 500292246501 Job No. AKMW3499847, Surveyed: 11 February, 2005 Western North Slope Measured True Sub-Sea Vertical Local Coordinates Global Coordinates Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings (ft) (ft) (ft) (ft) (ft) (ft) (ft) 7117.59 65.090 233.950 5458.13 5553.13 1841.85S 2140.15 W 5967790.99 N 547827.34 E 7213.98 64.840 235.180 5498.92 5593.92 1892.48 S 2211.31 W 5967739.89 N 547756.52 E 7309.53 63.050 235.540 5540.89 5635.89 1941.27 S 2281.93 W 5967690.63 N 547686.23 E 7406.10 58.370 235.150 5588.12 5683.12 1989.15 S 2351.19 W 5967642.29 N 547617.28 E 7501.81 53.790 233.060 5641.52 5736.52 2035.66 S 2415.53 W 5967595.35 N 547553.25 E 7598.03 51.670 230.230 5699.80 5794.80 2083.15 S 2475.58 W 5967547.47 N 547493.52 E 7693.38 51.030 230.140 5759.35 5854.35 2130.83 S 2532.78 W 5967499.41 N 547436.64 E 7789.41 48.080 230.330 5821.64 5916.64 2177.57 S 2588.95 W 5967452.29 N 547380.79 E 7886.00 42.560 231.320 5889.53 5984.53 2220.96 S 2642.15 W 5967408.55 N 547327.88 E 7982.37 37.510 233.990 5963.30 6058.30 2258.60 S 2691.36 W 5967370.58 N 547278.92 E 8080.33 36.120 234.440 6041.72 6136.72 2292.93 S 2738.98 W 5967335.93 N 547231.53 E 8175.52 35.110 233.590 6119.10 6214.10 2325.50 S 2783.83 W 5967303.07 N 547186.89 E 8270.12 31.710 231.730 6198.06 6293.06 2357.05 S 2825.26 W 5967271.24 N 547145.68 E 8362.64 30.720 232.150 6277.18 6372.18 2386.61 S 2863.01 W 5967241 .43 N 547108.13 E 8393.94 27.940 231.500 6304.47 6399.47 2396.09 S 2875.06 W 5967231.87 N 547096.13 E 8434.54 24.650 230.930 6340.86 6435.86 2407.35 S 2889.08 W 5967220.52 N 547082.19 E 8530.43 23.080 230.350 6428.55 6523.55 2431.94 S 2919.08 W 5967195.72 N 547052.36 E 8585.57 23.860 230.590 6479.13 6574.13 2445.92 S 2936.02 W 5967181.63 N 547035.51 E 8621.00 23.860 230.590 6511.53 ... 6606.53 2455.02 S 2947.09 W 5967172.46 N 547024.50 E All data is in Feet (US Survey) unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well. Northings and Eastings are relative to Well. Global Northings and Eastings are relative to NAD27 Alaska State Planes, Zone 4. The Dogleg Severity is in Degrees per 100 feet (US Survey). Vertical Section is from Well and calculated along an Azimuth of 230.000° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 8621.00ft., The Bottom Hole Displacement is 3835.68ft., in the Direction of 230.205° (True). 7 March, 2005 - 13:16 Page 3 of 4 ConocoPhillips Dogleg Vertical Rate Section Comment (0/100ft) 1.285 2823.37 1.185 2910.42 1.904 2995.88 4.859 3079.72 5.116 3158.91 . 3.214 3235.43 0.675 3309.89 3.076 3382.96 5.761 3451.61 5.534 3513.50 1 .445 3572.04 1.182 3627.34 3.753 3679.36 1.096 3727.28 8.940 3742.60 8.127 3760.58 1.655 3799.37 1 .425 3821.33 0.000 3835.66 Projected Survey > . ï» en "'" QI ;U 9 » Qo \) m ::ÞG') ::::0 () :::J Q) g..C4 ~ 0 C") m .... c ~ w :1 - cc ~ '" < CD <=> C"') <=> m CI U1 3 3 0 ¡;- .. êt' :::t DrillQuest 3.03.06.008 Western North Slope Comments Measured Depth (ft) 4166.56 4405.00 8621.00 Halliburton Sperry-Sun Survey Report for 1B-15A Your Ref: API 500292246501 Job No. AKMW3499847, Surveyed: 11 February, 2005 Station Coordinates TVD Northings Eastings (ft) (ft) (ft) 4117.67 4324.24 6606.53 Comment 301.07 S 394.22 S 2455.02 S 200.48 W 274.68 W 2947.09 W Tie On Point Window Point Projected Survey Survey tool program for 1 B-15A From Measured Vertical Depth Depth (ft) (ft) 0.00 4166.56 7 March, 2005 - 13:16 0.00 4117.67 To Measured Vertical Depth Depth Survey Tool Description (ft) (ft) 4166.56 8621.00 4117.67 MWDMagnetic(1B-15) 6606.53 MWD+SAG (1B-15A) þ œ c,o, ;IÇ'" C» S? QO :J>", ::I c» £..CI> o n Q; § ~ r> n o 3 3 Q;' In Õ ,~ ConocoPhillips . ;u. m () m - ~< ~m o » ""'U ;::0 ~ ~ Page 4 of4 DrillQuest 3.03.06.008 . AOGCC Helen Warman 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 DEFINITIVE Re: Distribution of Survey Data for Well 1 B-15A Dear Dear Sir/Madam: Enclosed is one disk with the *.PTT and *.PDF files. Tie-on Survey: Window / Kickoff Survey: Projected Survey: 4,166.56' MD 4,405.00' MD 8,621.00' MD (if applicable) . 19-Apr-05 PLEASE ACKNOWLEDGE RECEIPT BY SENDING AN EMAIL TO CARL.ULRICH@HALLlBURTON.COM OR SIGNING AND RETURNING A COpy OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Carl Ulrich 6900 Arctic Blvd. Anchorage, AK 9951 ~ 1/ A ð J Date Ä 1 fJp).cYrJ. Signed ~ D~ Please call me at 273-3545 if you have any questions or concerns. Regards, Carl Ulrich Survey Manager Attachment( s) ~ ~ r... ;Ì ')-(0 . . dOY- -"7" C S <..., WELL LOG TRANS MITT AL To: State of Alaska Alaska Oil and Gas Conservation COmIll. Attn.: Helen Warman 333 West ih Avenue, Suite 100 Anchorage, Alaska March 2, 2005 RE: MWD Formation Evaluation Logs IB-15A, AK-MW-3499847 1 LDWG formatted Disc with verification listing. API#: 50-029-22465-01 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry Drilling Services Attn: Rob Kalish 6900 Arctic Blvd. Anchorage, Alaska 99518 Date: ¥~5 ~~¿ ...L Schlumberger NO. 3357 Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth ¿;? V c( - ¡Ä,S- ~ 02/28/05 Company: Alaska Oil & Gas Cons Comm Attn: Helen Warman 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: . Well Job# Log Description Date BL i~5 '(J5C 2V-12 10942845 PROD PROFILE/DEFT 02/16/05 1 t8t.f-153 2D-03 10922538 PROD PROFILE/DEFT 02/06/05 1 ¡;z Ü"O - Ái t.? 1 D·39 10942838 INJECTION PROFILE 02/11/05 1 I~- -C~~ 2V-10 10942846 PROD PROFILEIDEFT 02/17/05 1 JOt- J:33 1 C-131 10942848 INJECTION PROFILE 02/19/05 1 190 - /~/ 1 A-19 10942839 PRODUCTION PROFILE 02/12/05 1 /19 _0/0 2N-308 10942843 PRODUCTION PROFILE 02/14/05 1 ~;~~~h 1 L-17 10942850 INJECTION PROFILE 02/21/05 1 1B-15A 10922540 SCMT 02/24/05 ft / -- tJfv (p 1 L-24 (REDO) 10942834 RST WFL & PPROF 01/26/05 1 . Kuparuk Color CD 1 SIGNd4~! (~,~ DATE, 4sÞ- Plene ,;gn and ,etu,Le copy ofth;s "an,mltial to Beth a\the above add",,, odax to (907) 561-8317. Thank you. . @~JA\"'?rc r¡)ì1: @l . ~V7 ® ® _ Lru L 'J: lW J fru ~ ~ ~~f.nj . AI4ASIiA. OIL AND 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 Greater Kuparuk Area Drilling Team Leader ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, Alaska 99510-0360 Re: Kuparuk IB-15A ConocoPhillips Alaska, Inc. Permit No: 204-256 Surface Location: 500' FNL, 484' FEL, SEC. 9, TIIN, RIOE, UM Bottomhole Location: 2975' FNL, 3455' FEL, SEC. 9, TIIN, RIOE, UM Dear Mr. Thomas: Enclosed is the approved application for permit to redrill the above development well. This permit to redrill . 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. PI e provide at least twenty-four (24) hours notice for a representative of the Commission wi :ness any required test. Contact the Commission's petroleum field inspector at (907) 659- 607 ::>ager). DATED thisL~ of January, 2005 cc: Department ofFish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. RE: lB-15A . . Subject: RE: 1B-15A From: "Flora, J acobM" <J acob.M.Flora@conocophillips.com> Date: Wed, 05 Jan 200508:29:15 -0900 To: Thomas Maunder <tom_maunder@admin.state.ak.us> Here's what I have currently for XS Liner Cap Liner Lap Annular Vol Shoe Vol 25.5ft^3 7.5ft^3 406ft^3 12ft^3 Using 0.1 023ft^3/ft (7" OH - 5.5" Liner)x(8735'-4400') Total 451ft^3 Mike has 454ft^3 total- this is only 0.66% XS This is what it should be: Liner Cap 25.5ft^3 Liner Lap 7.5ft^3 Annular Vol (406ft^3 x 1.4) = 568.4 ft^3 Shoe Vol 12ft^3 TOTAL 613ft^3 Sacks 613ft^3/1.1 -'---"524.27 sks Need 525 Sacks Let me know if I'm missing something. Thanks, Jake -----Original Message----- From: Thomas Maunder [mailto:tom_maunder@admin.state.ak.us] Sent: Wednesday, January 05,20058:04 AM To: Flora, Jacob M Subject: Re: lB-15A Hi Jake, Did you get the XS sorted out?? Tom Flora, Jacob M wrote: To follow up on your cement question- Mike used the 160% XS to compensate for the 7" hole instead of the 6.125" hole in his computer program. Sort of a glitch/quirk that he has to work around- that being said I'll calculate the XS again to see what it really is. Jake -----Original Message----- From: Thomas Maunder rmailto:tom maunder@admin.state.ak.us] 10f3 1/5/2005 8:42 AM RE: lB-15A . . Sent: Monday, January 03, 2005 10:05 AM To: Flora, Jacob M Subject: Re: 1B-15A Jake, I was checking the work I had done looking at the cement volume. On the well diagram, are all the perfs below 6819' squeezed?? From the way I read the perf infonnation on the diagram it appears that there are perfs open to 7159'. Thanks, Tom Maunder, PE AOGCC Flora, Jacob M wrote: Tom, I've added a postable drilling hazards section to the permit- it was in the well plan already but didn't make it over. I'm working with our directional planner to make the Anti-Collision report include full offset data for 1 8-01 & 1 8-18. I looked into the cement XS and found that a 6.125" OH was used instead of the 7" OH we are going to drill- this brings our cement requirements to 1102 cu-ft and 942 sks. Looks like the plan to use the hole opener came after the cement calcs. Liner Cap 0.1276ft^3/ft x 200' = 25.5 ft^3 Liner Lap 0.0498ft^3/ft x (4400'-4250) = 7.5 ft^3 Annular Volume 0.1023ft^3/ft x (8375'-4400') x 2.6(160% XS) = 1057.3 ft^3 Shoe Volume 0.1336ft^3/ft x 80' = 12 ft^ 3 Total = 1102.3 ft^3 I've also attached my cement volume cals for the P&A_ I took over this well from Kelly McClure who recently resigned with this being the first pennit I've put together. Any advice on fonnat and content would be very helpful. Let me know if you need me to submit another signed pennit for these changes or if I can email the corrected version over. Also if you want the cement cales included in the pennit. «1 8-15A Cement Cales. doc» Thanks, Jake Jake Flora 2 of3 1/5/2005 8:42 AM RE: lB-15A . . Drilling Engineer Conoco Phillips Alaska Inc. Office: 907 265-6040 30f3 1/5/2005 8:42 AM RE: lB-15A . . Subject: RE: IB-15A From: "Flora, Jacob M" <Jacob.M.Flora@conocophillips.com> Date: Mon, 03 Jan 200508:39:19 -0900 To: Thomas Maunder <tom_maunder@admin.state.ak.us> Here's what I have for Drilling Hazards Data. Thanks, Jake -----Original Message----- From: Thomas Maunder [mailto:tom_maunder@admin.state.ak.us] Sent: Monday, January 03, 2005 8:08 AM To: Flora, Jacob M Subject: Re: lB-15A Thanks Jake. No, you do not have to submit a new permit application but I would appreciate if you would email me a copy of the hazards section. On receipt, I will add that to the permit package. I will put copies of our messages in the file. Call or message with any questions. Tom Maunder, PE AOGCC Flora, Jacob M wrote: Tom, I've added a postable drilling hazards section to the permit- it was in the well plan already but didn't make it over. I'm working with our directional planner to make the Anti-Collision report include full offset data for 18-01 & 18-18. I looked into the cement XS and found that a 6.125" OH was used instead of the 7" OH we are going to drill- this brings our cement requirements to 1102 cu-ft and 942 sks. Looks like the plan to use the hole opener came after the cement calcs. Liner Cap 0.1276ft^3/ft x 200' = 25.5 ft^3 Liner Lap 0.0498ft^3/ft x (4400'-4250) = 7.5 ft^3 Annular Volume 0.1 023ft^3/ft x (8375'-4400') x 2.6(160% XS) = 1057.3 ft^3 Shoe Volume 0.1336ft^3/ft x 80' = 12 ft^3 Total = 1102.3 ft^3 I've also attached my cement volume cals for the P&A. I took over this well from Kelly lof2 1/3/20059:58 AM RE: IB-15A . . McClure who recently resigned with this being the first permit I've put together. Any advice on fonnat and content would be very helpful. Let me know if you need me to submit another signed permit for these changes or if I can email the corrected version over. Also if you want the cement cales included in the pennit. «1 B-15A Cement Cales. doc» Thanks, Jake Jake Flora Drilling Engineer Conoco Phillips Alaska Inc. Office: 907 265-6040 IB-15A Hazard Content-Description: IB-15A Hazard Data.doc Content-Type: application/msword Content-Encoding: base64 µo.l£>-~ c:,~'-ê'" ~. \ _ (\ f"\t~~ ",,\-C\S6ø'\~ ~ 20f2 1/3/2005 9:58 AM FW: IB-15A Anti-Collision . . Subject: FW: IB-15A Anti-Collision From: "Flora, Jacob M" <Jacob.M.Flora@conocophillips.com> Date: Mon, 03 Jan 200508:40:06 -0900 To: tom _ maunder@admin.state.ak.us Tom, Sperry Sun has clarified the anti-collision report and included full data on 18-01, 18-05, & 18-18. Please see the following response from Dennis Hartwig and attached report. Jake -----Original Message----- From: Hartwig, Dennis D Sent: Thursday, December 30, 2004 6:49 PM To: Flora, Jacob M Subject: lB-15A Anti-Collision Jake, Attached is the revised Anti-Collision report derived only from Sidetrack Pt of 4400'MD down to TD. Items of Note- Minimum Distances to the following wells are as listed 18-01 Minimum Ctr to Ctr distance is 993' at Approximately 7782' MD 18-05 Minimum Ctr to Ctr distance is 553' at Approximately 4401' MD (18-05 is a Straight Well) 18-18 Minimum Ctr to Ctr distance is 459' at Approximately 4401 'MD Mr Maunder was correct ,as seen from the attached 3-D view, that the 1 8-15A does indeed pass underneath the 18-01 and gets as close as 993'. The 18-05 and the 18-18 are closest at the KOP then quickly diverge from the 18-15A. ** The Anti-Collision Travelling Cylinder plot was scanned from 4400' MD to TD ** I started the scan for the report from 3600' MD for the specific reason to show how the distance from the 18-01 stays fairy constant at around 1850' from the 1 8-15A from 3624'MD to around 5448' MD (Note the jump in Measured Depth from 3624 to 5448). Since our scan should rightfully start at 4400'MD please disregard any information on the report which is above 4400'MD. Thx and please let me know if questions or concerns arise....Dennis «18-15Aßnti_Collision.pdf» Content-Description: IB-l Content- Type: application/octet-stream Content-Encoding: base64 1 of 1 1/3/2005 9:58 AM Name ~Ni-$ +J:'J_W Northing. -2..156 497.0!4 -Jl15 1000 33 - 0 270 1000 -IJl5 o Jl ]5 ]80 LEGEND Travel1ing Cylinder Azimuth (TFO+AZI) [deg] vs Centre to Centre Separation [500ft/in] 90 ê;' <? (: ~ !!Þ ToMD 4450 4500 4600 4700 4800 5050 5300 5550 5800 6050 6550 7050 7550 8050 8550 8750 COMPANYDETAILS Vs..,"l'o¡¡. 'mP" -30.0 25.0 . 20.0 15.0 10.0 5.0 - 0 270 5.0 10.0 15.0 , 20.0 '25.0 -30.0 180>VV Travelling Cylinder Azimuth (TFO+AlJ) [deg] vs Centre to Centre Separation [15ft/in] SECTION DETA!!,S Se<.' MD !ne 1\71 S!:O.1Í!>;\ Fmm1VD 5800 7050 7550 8050 90 1000 2000 3000 ~OOO 5000 5000 8000 <:.:::::> . . Halliburton Company Anticollision Report Company: Fietd: Reference Site: Reference Well: Reference Wellpath: ConocoPhillips Alaska Inc. Kuparuk River Unit Kuparuk 18 Pad 18-15 Plan: 18-15A Date: 12/30/2004 Time: 18:13:21 Page: Co-ordinate(NE) Reference: Well: 18-15, True North Vertical (TVD) Reference: 18-15102.0 NO GLOBAL SCAN: Using user defined selection & scan criteria Interpolation Method: MD Interval: 25.000 ft Depth Range: 3600.000 to 8737.649 ft Maximum Radius:20000.000 ft Reference: Error Model: Scan Method: Error Suñace: Db: Orade Plan: Plan: 1 8-15A (wp03) & NOT PLANI\E> PRI ISCWSA Ellipse Trav Cylinder North Ellipse + Casing Casing Points MD TVD Diameter Hole Size Name ft ft in in 4400.000 4320.858 7.000 8.500 7" 8737.649 6687.000 5.500 6.125 5112" Plan: Plan: 18-15A (wp03) Date Composed: 12/29/2004 Version: 2 Principat: Yes Tied-to: From: Definitive Path Summary < Offset Wellpath Reference Offset Ctr-Ctr No-Go Atlowable Site Well Wellpath MD MD Distance Area Deviation Warning ft ft ft ft ft Kuparuk 18 Pad 18-01 18-01 V5 7782.112 6650.000 993.635 144.606 849.029 Pass: Major Risk Kuparuk 18 Pad 18-05 18-05 V3 3622.360 3650.000 168.166 44.661 123.505 Pass: Major Risk Kuparuk 18 Pad 18-18 18-18 VO 3610.276 3650.000 272.355 50.301 222.054 Pass: Major Risk Site: Kuparuk 18 Pad Well: 18-01 Rule Assigned: Major Risk Wellpath: 18-01 V5 Inter-Site Error: 0.000 ft Reference Offset Semi-Major Axis Ctr-Ctr No-Go Allowable MD TVD MD TVD Ref Offset TFO+AZI TFO-HS CasingIHS>istance Area Deviation Warning ft ft ft ft ft ft deg deg in ft ft ft 3603.500 3593.542 3725.000 3171.580 2.104 11.326 226.619 10.937 9.625 1844.011 50.109 1793.902 Pass 3624.842 3614.298 3750.000 3190.067 2.160 11.445 226.571 10.814 9.625 1855.970 50.455 1805.515 Pass 5448.719 4924.230 3775.000 3208.535 18.461 11.007 231.285 358.085 9.625 1851.471 71.497 1779.974 Pass 5470.725 4932.474 3800.000 3226.985 18.768 11.123231.136 357.936 9.625 1840.623 71.754 1768.868 Pass 5492.743 4940.722 3825.000 3245.414 19.075 11.239 230.985 357.785 9.625 1829.815 72.016 1757.800 Pass 5514.783 4948.978 3850.000 3263.808 19.382 11.356 230.832 357.632 9.625 1819.067 72.282 1746.785 Pass 5536.844 4957.242 3875.000 3282.166 19.691 11.473 230.677 357.477 9.625 1808.381 72.551 1735.831 Pass 5558.927 4965.515 3900.000 3300.486 19.999 11.591 230.520 357.320 9.625 1797.758 72.822 1724.936 Pass 5581.028 4973.794 3925.000 3318.771 20.308 11.708 230.360 357.160 9.625 1787.194 73.095 1714.099 Pass 5603.125 4982.072 3950.000 3337.037 20.617 11.825 230.196 356.996 9.625 1776.668 73.368 1703.300 Pass 5625.214 4990.346 3975.000 3355.283 20.926 11.942 230.028 356.828 9.625 1766.178 73.645 1692.533 Pass 5647.295 4998.618 4000.000 3373.511 21.235 12.059229.856 356.656 9.625 1755.725 73.925 1681.800 Pass 5669.376 5006.890 4025.000 3391.715 21.544 12.177229.679 356.479 9.625 1745.317 74.208 1671.108 Pass 5691.501 5015.178 4050.000 3409.867 21.854 12.295229.502 356.302 9.625 1734.996 74.497 1660.499 Pass 5713.677 5023.485 4075.000 3427.963 22.164 12.413229.325 356.125 9.625 1724.770 74.791 1649.980 Pass 5735.904 5031.811 4100.000 3446.002 22.476 12.532229.147 355.947 9.625 1714.638 75.089 1639.549 Pass 5758.171 5040.153 4125.000 3463.998 22.788 12.650228.970 355.770 9.625 1704.582 75.388 1629.194 Pass 5780.425 5048.489 4150.000 3482.020 23.100 12.768228.790 355.590 9.625 1694.508 75.690 1618.818 Pass 5802.657 5056.818 4175.000 3500.079 23.412 12.886228.609 355.409 9.625 1684.400 75.996 1608.405 Pass 5824.869 5065.138 4200.000 3518.177 23.723 13.004 228.426 355.226 9.625 1674.260 76.306 1597.953 Pass 5847.069 5073.455 4225.000 3536.299 24.035 13.122228.241 355.041 9.625 1664.104 76.623 1587.481 Pass 5869.311 5081.787 4250.000 3554.376 24.347 13.241 228.056 354.856 9.625 1654.026 76.945 1577.082 Pass 5891.603 5090.137 4275.000 3572.397 24.660 13.359227.871 354.671 9.625 1644.041 77.273 1566.769 Pass 5913.944 5098.506 4300.000 3590.361 24.974 13.478227.686 354.486 9.625 1634.149 77.606 1556.543 Pass 5936.333 5106.893 4325.000 3608.267 25.288 13.599227.501 354.301 9.625 1624.350 77.952 1546.397 Pass 5958.771 5115.299 4350.000 3626.117 25.603 13.722227.316 354.116 9.625 1614.641 78.310 1536.331 Pass 5981.257 5123.722 4375.000 3643.909 25.919 13.845227.131 353.931 9.625 1605.025 78.674 1526.351 Pass 6003.790 5132.163 4400.000 3661.643 26.236 13.967226.947 353.747 9.625 1595.499 79.044 1516.455 Pass 6026.368 5140.621 4425.000 3679.325 26.553 14.091 226.763 353.563 9.625 1586.057 79.420 1506.637 Pass 6048.974 5149.090 4450.000 3696.983 26.871 14.215226.580 353.380 9.625 1576.661 79.801 1496.860 Pass . . Halliburton Company Anticollision Report Company: ConocoPhillips Alaska Inc. Date: 12/30/2004 Time: 18:13:21 Page: 2 Fietd: Kuparuk River Unit Reference Site: Kuparuk 1 B Pad Co-ordinate(NE) Reference: Well: 1B-15, True North Reference Well: 18-15 Vertical (TVD) Reference: 18-15102.0 Reference Wellpath: Plan: 1B-15A Db: Orade Site: Kuparuk 1 B Pad Well: 1 B-01 Rule Assigned: Major Risk Wellpath: 1 B-01 V5 Inter-Site Error: 0.000 ft Reference Offset Semi-Major Axis Ctr-Ctr No-Go Atlowable MD TVD MD TVD Ref Offset TFO+AZI TFO-HS CasingIHiÐistance Area Deviation Warning ft ft ft ft ft ft deg deg in ft ft ft 6071.607 5157.568 4475.000 3714.622 27.189 14.339226.397 353.197 9.625 1567.303 80.189 1487.115 Pass 6094.265 5166.056 4500.000 3732.242 27.508 14.463 226.214 353.014 9.625 1557.984 80.582 1477.402 Pass 6116.942 5174.551 4525.000 3749.842 27.827 14.587 226.031 352.831 9.625 1548.705 80.979 1467.726 Pass 6139.604 5183.040 4550.000 3767.424 28.146 14.711 225.841 352.641 9.625 1539.471 81.382 1458.089 Pass 6162.243 5191.521 4575.000 3784.986 28.464 14.835 225.643 352.443 9.625 1530.287 81.796 1448.491 Pass 6184.858 5199.993 4600.000 3802.529 28.783 14.959 225.437 352.237 9.625 1521.154 82.221 1438.933 Pass 6207.455 5208.458 4625.000 3820.049 29.101 15.083225.223 352.023 9.625 1512.077 82.658 1429.418 Pass 6230.067 5216.928 4650.000 3837.532 29.419 15.208 225.007 351.807 9.625 1503.070 83.107 1419.962 Pass 6252.699 5225.406 4675.000 3854.976 29.738 15.333224.787 351.587 9.625 1494.135 83.566 1410.569 Pass 6275.350 5233.892 4700.000 3872.381 30.057 15.457 224.565 351.365 9.625 1485.274 84.036 1401.238 Pass 6298.020 5242.384 4725.000 3889.763 30.376 15.582224.341 351.141 9.625 1476.463 84.516 1391.947 Pass 6320.701 5250.880 4750.000 3907.211 30.695 15.707224.122 350.922 9.625 1467.575 85.000 1382.575 Pass 6343.391 5259.380 4775.000 3924.738 31.015 15.832 223.910 350.710 9.625 1458.589 85.489 1373.100 Pass 6366.088 5267.882 4800.000 3942.343 31.335 15.957223.704 350.504 9.625 1449.503 85.981 1363.522 Pass 6388.789 5276.387 4825.000 3960.001 31.655 16.082 223.502 350.302 9.625 1440.349 86.476 1353.873 Pass 6411.502 5284.895 4850.000 3977.601 31.975 16.207223.294 350.094 9.625 1431.300 86.983 1344.318 Pass 6434.224 5293.407 4875.000 3995.124 32.295 16.332 223.077 349.877 9.625 1422.386 87.504 1334.882 Pass 6456.956 5301.922 4900.000 4012.568 32.615 16.457222.851 349.651 9.625 1413.610 88.043 1325.567 Pass 6479.697 5310.441 4925.000 4029.938 32.936 16.583222.617 349.417 9.625 1404.965 88.602 1316.363 Pass 6502.455 5318.967 4950.000 4047.265 33.257 16.711 222.380 349.180 9.625 1396.402 89.179 1307.224 Pass 6525.234 5327.500 4975.000 4064.552 33.578 16.838222.139 348.939 9.625 1387.915 89.767 1298.148 Pass 6548.031 5336.040 5000.000 4081.799 33.899 16.966 221.896 348.696 9.625 1379.503 90.370 1289.134 Pass 6570.845 5344.586 5025.000 4099.018 34.221 17.093221.650 348.450 9.625 1371.153 90.984 1280.169 Pass 6593.658 5353.132 5050.000 4116.267 34.543 17.221 221.404 348.204 9.625 1362.780 91.607 1271.174 Pass 6616.468 5361.677 5075.000 4133.556 34.864 17.348221.158 347.958 9.625 1354.373 92.240 1262.132 Pass 6639.275 5370.220 5100.000 4150.885 35.186 17.475220.912 347.712 9.625 1345.929 92.884 1253.045 Pass 6662.078 5378.762 5125.000 4168.244 35.508 17.602220.666 347.466 9.625 1337.463 93.536 1243.927 Pass 6684.875 5387.302 5150.000 4185.591 35.829 17.729220.413 347.213 9.625 1329.046 94.204 1234.843 Pass 6707.666 5395.840 5175.000 4202.918 36.151 17.855220.155 346.955 9.625 1320.692 94.890 1225.803 Pass 6730.450 5404.375 5200.000 4220.225 36.472 17.982 219.889 346.689 9.625 1312.402 95.595 1216.807 Pass 6753.233 5412.910 5225.000 4237.510 36.794 18.109219.618 346.418 9.625 1304.178 96.323 1207.855 Pass 6776.048 5421.456 5250.000 4254.758 37.116 18.238219.347 346.147 9.625 1296.023 97.068 1198.954 Pass 6798.897 5430.016 5275.000 4271.966 37.438 18.366219.075 345.875 9.625 1287.934 97.826 1190.109 Pass 6821.782 5438.589 5300.000 4289.135 37.761 18.495218.804 345.604 9.625 1279.914 98.594 1181.319 Pass 6844.703 5447.175 5325.000 4306.267 38.085 18.624218.534 345.334 9.625 1271.954 99.377 1172.577 Pass 6867.662 5455.775 5350.000 4323.377 38.409 18.755218.266 345.066 9.625 1264.024100.169 1163.854 Pass 6890.660 5464.391 5375.000 4340.468 38.734 18.885218.003 344.803 9.625 1256.117100.969 1155.148 Pass 6913.695 5473.020 5400.000 4357.538 39.059 19.016217.743 344.543 9.625 1248.232101.773 1146.459 Pass 6936.762 5481.661 5425.000 4374.588 39.384 19.146217.486 344.286 9.625 1240.374 102.584 1137.790 Pass 6959.830 5490.302 5450.000 4391.618 39.710 19.277217.224 344.024 9.625 1232.577 103.413 1129.164 Pass 6982.893 5498.942 5475.000 4408.628 40.036 19.408216.954 343.754 9.625 1224.849 104.264 1120.585 Pass 7005.952 5507.580 5500.000 4425.618 40.361 19.539216.678 343.478 9.625 1217.190 105.180 1112.010 Pass 7029.013 5516.219 5525.000 4442.585 40.687 19.670216.397 343.197 9.625 1209.598 106.108 1103.490 Pass 7052.115 5524.873 5550.000 4459.515 41.013 19.802216.118 342.918 9.625 1202.054 107.045 1095.008 Pass 7075.262 5533.544 5575.000 4476.405 41.340 19.934 215.844 342.644 9.625 1194.551 107.987 1086.564 Pass 7098.453 5542.231 5600.000 4493.255 41.668 20.066215.574 342.374 9.625 1187.089 108.934 1078.156 Pass 7121.677 5550.931 5625.000 4510.075 41.996 20.198 215.306 342.106 9.625 1179.663 109.958 1069.705 Pass 7144.866 5559.618 5650.000 4526.926 42.323 20.330215.029 341.829 9.625 1172.254 110.938 1061.315 Pass 7168.012 5568.288 5675.000 4543.818 42.650 20.462214.741 341.541 9.625 1164.862 111.953 1052.909 Pass 7191.111 5576.942 5700.000 4560.750 42.976 20.594 214.440 341.240 9.625 1157.491 113.002 1044.489 Pass 7214.179 5585.583 5725.000 4577.707 43.302 20.726214.130 340.930 9.625 1150.149 114.161 1035.989 Pass . . Halliburton Company Anticollision Report Company: ConocoPhillips Alaska Inc. Date: 12/3012004 Time: 18:13:21 Page: 3 Field: Kuparuk River Unit Reference Site: Kuparuk 1 B Pad Co-ordinate(NE) Reference: Well: 1B-15. True North Reference Well: 18-15 Verticat (TVD) Reference: 18-15102.0 Reference Wellpath: Plan: 18-15A Db: Orade Site: Kuparuk 1 B Pad Well: 1 B-01 Rute Assigned: Major Risk Wellpath: 1 B-01 V5 Inter-Site Error: 0.000 ft Reference Offset Semi-Major Axis Ctr-Ctr No-Go Allowable MD TVD MD TVD Ref Offset TFO+AZI TFO-HS CasingIH!Ðistance Area Deviation Warning ft ft ft ft ft ft deg deg in ft ft ft 7237.290 5594.241 5750.000 4594.617 43.629 20.859 213.822 340.622 9.625 1142.869115.252 1027.618 Pass 7260.456 5602.919 5775.000 4611.466 43.956 20.991 213.519 340.319 9.625 1135.655 116.348 1019.307 Pass 7283.675 5611.617 5800.000 4628.255 44.284 21.124 213.221 340.021 9.625 1128.503117.447 1011.056 Pass 7306.935 5620.330 5825.000 4644.999 44.613 21.256 212.926 339.726 9.625 1121.402118.622 1002.780 Pass 7330.165 5629.032 5850.000 4661.789 44.941 21.389212.624 339.424 9.625 1114.289119.755 994.534 Pass 7353.355 5637.719 5875.000 4678.640 45.269 21.521 212.313 339.113 9.625 1107.156120.918 986.237 Pass 7376.505 5646.391 5900.000 4695.552 45.596 21.654 211.993 338.793 9.625 1100.005122.114 977.891 Pass 7392.194 5652.297 5925.000 4712.516 45.791 21.791 211.668 338.468 9.625 1092.886123.182 969.703 Pass 7400.000 5655.298 5950.000 4729.490 45.877 21.927 211.357 338.156 9.625 1085.942124.193 961.749 Pass 7400.000 5655.298 5975.000 4746.465 45.877 22.059 211.058 337.857 9.625 1079.378 125.064 954.314 Pass 7429.616 5667.131 6000.000 4763.439 46.106 22.206 210.787 337.585 9.625 1072.491 125.917 946.575 Pass 7442.318 5672.420 6025.000 4780.413 46.205 22.345 210.525 337.323 9.625 1066.036 126.728 939.308 Pass 7455.103 5677.873 6050.000 4797.404 46.304 22.485 210.260 337.057 9.625 1059.860 127.551 932.309 Pass 7467.964 5683.487 6075.000 4814.416 46.403 22.625 209.989 336.785 9.625 1053.981 128.390 925.591 Pass 7480.900 5689.265 6100.000 4831.447 46.504 22.766209.712 336.508 9.625 1048.402 129.244 919.157 Pass 7500.000 5698.035 6125.000 4848.492 46.652 22.910209.431 336.226 9.625 1043.154 130.116 913.038 Pass 7500.000 5698.035 6150.000 4865.522 46.652 23.043209.156 335.951 9.625 1038.160 131.042 907.118 Pass 7520.202 5707.617 6175.000 4882.532 46.806 23.189208.891 335.685 9.625 1033.384 131.865 901.519 Pass 7533.480 5714.084 6200.000 4899.522 46.907 23.331 208.634 335.427 9.625 1028.924 132.674 896.250 Pass 7546.838 5720.726 6225.000 4916.500 47.009 23.472 208.384 335.177 9.625 1024.731 133.466 891.264 Pass 7560.262 5727.537 6250.000 4933.511 47.111 23.614208.139 334.932 9.625 1020.769134.250 886.520 Pass 7573.750 5734.516 6275.000 4950.562 47.214 23.756 207.898 334.690 9.625 1017.035135.025 882.009 Pass 7600.000 5748.485 6300.000 4967.652 47.414 23.906207.659 334.449 9.625 1013.671 135.787 877.884 Pass 7600.000 5748.485 6325.000 4984.774 47.414 24.040 207.429 334.220 9.625 1010.260 136.628 873.632 Pass 7600.000 5748.485 6350.000 5001.884 47.414 24.173207.199 333.989 9.625 1007.475 137.403 870.072 Pass 7628.306 5764.115 6375.000 5018.973 47.624 24.326 206.984 333.773 9.625 1004.616 138.083 866.534 Pass 7642.091 5771.936 6400.000 5036.043 47.725 24.469 206.771 333.560 9.625 1002.251 138.789 863.462 Pass 7655.927 5779.923 6425.000 5053.092 47.828 24.613206.566 333.354 9.625 1000.186 139.482 860.704 Pass 7669.813 5788.076 6450.000 5070.122 47.930 24.758 206.373 333.160 9.625 998.398 140.153 858.245 Pass 7683.746 5796.393 6475.000 5087.132 48.033 24.904 206.191 332.977 9.625 996.883 140.797 856.086 Pass 7700.000 5806.265 6500.000 5104.122 48.153 25.051 206.021 332.807 9.625 995.645141.406 854.239 Pass 7700.000 5806.265 6525.000 5121.097 48.153 25.186 205.860 332.646 9.625 994.789 142.105 852.684 Pass 7725.768 5822.290 6550.000 5138.087 48.334 25.339205.713 332.497 9.625 993.947 142.602 851.345 Pass 7739.828 5831.223 6575.000 5155.098 48.433 25.484 205.570 332.353 9.625 993.480143.134 850.346 Pass 7753.907 5840.301 6600.000 5172.128 48.532 25.629205.435 332.217 9.625 993.265 143.648 849.617 Pass 7768.002 5849.522 6625.000 5189.171 48.631 25.774 205.308 332.089 9.625 993.306 144.142 849.164 Pass 7782.112 5858.883 6650.000 5206.180 48.730 25.920 205.194 331.975 9.625 993.635 144.606 849.029 Pass 7800.000 5870.936 6675.000 5223.150 48.856 26.068 205.094 331.873 9.625 994.268 145.020 849.249 Pass 7800.000 5870.936 6700.000 5240.079 48.856 26.203205.006 331.785 9.625 995.262 145.541 849.721 Pass 7824.480 5887.762 6725.000 5256.979 49.017 26.357 204.936 331.713 9.625 996.355 145.826 850.529 Pass 7838.598 5897.638 6750.000 5273.910 49.109 26.503 204.875 331.652 9.625 997.743146.147 851.597 Pass 7852.709 5907.631 6775.000 5290.881 49.202 26.650 204.826 331.601 9.625 999.320 146.438 852.881 Pass 7866.809 5917.739 6800.000 5307.892 49.294 26.796 204.787 331.562 9.625 1001.084 146.701 854.383 Pass 7880.893 5927.955 6825.000 5324.935 49.387 26.942 204.761 331.535 9.625 1003.045 146.934 856.111 Pass 7900.000 5942.004 6850.000 5341.965 49.512 27.092 204.747 331.519 9.625 1005.279147.105 858.174 Pass 7900.000 5942.004 6875.000 5358.975 49.512 27.227 204.745 331.518 9.625 1007.797 147.409 860.388 Pass 7922.995 5959.196 6900.000 5375.965 49.650 27.380 204.759 331.530 9.625 1010.453 147.452 863.001 Pass 7936.964 5969.787 6925.000 5392.943 49.734 27.526 204.786 331.556 9.625 1013.411 147.533 865.878 Pass 7950.901 5980.464 6950.000 5409.958 49.818 27.671 204.834 331.602 9.625 1016.463 147.562 868.901 Pass 7964.801 5991.221 6975.000 5427.014 49.901 27.816204.904 331.672 9.625 1019.585 147.532 872.053 Pass 7978.660 6002.051 7000.000 5444.109 49.984 27.961 204.997 331.763 9.625 1022.779147.443 875.336 Pass . . Halliburton Company Anticollision Report Company: ConocoPhillips Alaska Inc. Date: 12/30/2004 Time: 18:13:21 Page: 4 Field: Kuparuk River Unit Reference Site: Kuparuk 1 B Pad Co-ordinate(NE) Reference: Well: 1B-15, True North Reference Well: 1B-15 Vertical (TVD) Reference: 1B-15102.0 Reference Wellpath: Plan: 1B-15A Db: Orade Site: Kuparuk 1 B Pad Well: 1 B-01 Rule Assigned: Major Risk Wellpath: 1 B-01 V5 Inter-Site Error: 0.000 ft Reference Offset Semi-Major Axis Ctr-Ctr No-Go AlIowabte MD TVD MD TVD Ref OffsetTFO+AZI TFO-HS CasingIHS>istance Area Deviation Wamiag ft ft ft ft ft ft deg deg in ft ft ft 8000.000 6018.930 7025.000 5461.240 50.112 28.110 205.107 331.871 9.625 1026.119 147.244 878.876 Pass 8000.000 6018.930 7050.000 5478.410 50.112 28.243 205.222 331.986 9.625 1029.629 147.234 882.395 Pass 8019.949 6034.926 7075.000 5495.620 50.219 28.390205.340 332.102 9.625 1033.376 146.992 886.385 Pass 8033.609 6045.997 7100.000 5512.869 50.292 28.532 205.458 332.219 9.625 1037.411 146.804 890.608 Pass 8047.211 6057.117 7125.000 5530.153 50.365 28.673 205.580 332.339 9.625 1041.690146.606 895.085 Pass 8060.750 6068.275 7150.000 5547.442 50.437 28.815205.714 332.472 9.625 1046.165 146.373 899.791 Pass 8074.219 6079.466 7175.000 5564.731 50.509 28.956 205.861 332.618 9.625 1050.827 146.102 904.724 Pass 8100.000 6101.127 7200.000 5582.020 50.647 29.105206.019 332.773 9.625 1055.809 145.675 910.134 Pass 8100.000 6101.127 7225.000 5599.305 50.647 29.238206.195 332.948 9.625 1060.727 145.488 915.239 Pass 8100.000 6101.127 7250.000 5616.573 50.647 29.371 206.370 333.124 9.625 1066.221 145.283 920.938 Pass 8127.335 6124.432 7275.000 5633.821 50.774 29.522 206.560 333.309 9.625 1071.653144.714 926.939 Pass 8140.404 6135.692 7300.000 5651.049 50.835 29.663 206.750 333.498 9.625 1077.539144.306 933.233 Pass 8153.383 6146.950 7325.000 5668.263 50.895 29.804 206.946 333.692 9.625 1083.688 143.881 939.807 Pass 8166.275 6158.204 7350.000 5685.493 50.955 29.944207.152 333.897 9.625 1090.008 143.427 946.581 Pass 8179.079 6169.450 7375.000 5702.743 51.014 30.085 207.368 334.111 9.625 1096.484 142.942 953.543 Pass 8200.000 6187.970 7400.000 5720.013 51.111 30.229207.594 334.333 9.625 1103.175142.326 960.849 Pass 8200.000 6187.970 7425.000 5737.298 51.111 30.361 207.830 334.569 9.625 1109.932141.957 967.974 Pass 8200.000 6187.970 7450.000 5754.587 51.111 30.493 208.067 334.807 9.625 1117.162 141.572 975.591 Pass 8229.364 6214.258 7475.000 5771.875 51.225 30.640 208.321 335.055 9.625 1124.140 140.713 983.426 Pass 8241.688 6225.390 7500.000 5789.163 51.272 30.778 208.575 335.307 9.625 1131.572 140.095 991.476 Pass 8253.913 6236.487 7525.000 5806.464 51.320 30.915208.833 335.563 9.625 1139.205 139.461 999.745 Pass 8266.059 6247.567 7550.000 5823.852 51.367 31.051 209.091 335.818 9.625 1146.984 138.822 1008.162 Pass 8278.130 6258.629 7575.000 5841.338 51.413 31.186209.347 336.G72 9.625 1154.897138.184 1016.713 Pass 8300.000 6278.799 7600.000 5858.921 51.498 31.325 209.601 336.320 9.625 1163.024 137.397 1025.627 Pass 8302.042 6280.691 7625.000 5876.593 51.505 31.454 209.857 336.576 9.625 1171.115 136.908 1034.207 Pass 8313.866 6291.669 7650.000 5894.312 51.545 31.586210.120 336.836 9.625 1179.379136.234 1043.146 Pass 8329.408 6306.159 7675.000 5912.070 51.604 31.716210.392 337.106 9.625 1187.718 135.630 1052.089 Pass 8352.287 6327.503 7700.000 5929.866 51.701 31.843210.670 337.384 9.625 1195.976 135.165 1060.811 Pass 8375.177 6348.856 7725.000 5947.699 51.798 31.969 210.951 337.665 9.625 1204.118134.694 1069.423 Pass 8398.085 6370.226 7750.000 5965.569 51.895 32.094 211.232 337.946 9.625 1212.198 134.229 1077.969 Pass 8421.010 6391.612 7775.000 5983.478 52.013 32.219 211.510 338.224 9.625 1220.225 133.800 1086.425 Pass 8443.952 6413.015 7800.000 6001.424 52.132 32.345 211.787 338.501 9.625 1228.200 133.366 1094.834 Pass 8466.906 6434.428 7825.000 6019.398 52.252 32.470212.063 338.777 9.625 1236.133 132.938 1103.195 Pass 8489.839 6455.822 7850.000 6037.343 52.371 32.595212.339 339.053 9.625 1244.092132.514 1111.577 Pass 8512.747 6477.192 7875.000 6055.250 52.491 32.721 212.616 339.330 9.625 1252.086132.099 1119.987 Pass 8535.628 6498.538 7900.000 6073.119 52.610 32.846212.893 339.607 9.625 1260.116131.668 1128.448 Pass 8558.488 6519.864 7925.000 6090.960 52.730 32.971 213.171 339.885 9.625 1268.172 131.239 1136.933 Pass 8581.361 6541.202 7950.000 6108.831 52.849 33.096213.447 340.161 9.625 1276.185130.814 1145.371 Pass 8604.251 6562.556 7975.000 6126.739 52.969 33.221 213.722 340.436 9.625 1284.147 130.406 1153.741 Pass 8627.158 6583.925 8000.000 6144.686 53.089 33.346 213.995 340.709 9.625 1292.057 129.990 1162.067 Pass 8650.077 6605.306 8025.000 6162.668 53.208 33.470 214.268 340.982 9.625 1299.902 129.577 1170.325 Pass 8672.991 6626.682 8050.000 6180.675 53.328 33.592 214.548 341.262 9.625 1307.612 129.149 1178.463 Pass 8695.894 6648.047 8075.000 6198.702 53.448 33.715214.835 341.549 9.625 1315.180128.703 1186.477 Pass 8718.781 6669.399 8100.000 6216.746 53.567 33.837215.130 341.844 9.625 1322.607 128.245 1194.362 Pass ·' . Halliburton Company Anticollision Report Company: ConocoPhillips Alaska Inc. Date: 12/30/2004 Time: 18:13:21 Page: 5 Fietd: Kuparuk River Unit Reference Site: Kuparuk 1 B Pad Co-onlinate(NE) Reference: Well: 1B-15, True North Reference Well: 18-15 Vertical (TVD) Reference: 18-15102.0 Reference Wellpatb: Plan: 1B-15A Db: Orade Site: Kuparuk 1 B Pad Well: 1 B-05 Rule Assigned: Major Risk Wellpath: 1 B-05 V3 Inter-Site Error: 0.000 ft Reference Offset Semi-Major Axis Ctr-Ctr No-Go Allowable MD TVD MD TVD Ref Offset TFO+AZI TFO-HS CasingIHS>istance Area Deviation Warning ft ft ft ft ft ft deg deg in ft ft ft 3622.360 3611.884 3650.000 3649.897 2.153 2.568 21,958 166.210 9.625 168.166 44.661 123.505 Pass 3646.346 3635.208 3675.000 3674.896 2.217 2.551 22.484 166.546 9.625 173.946 44.879 129.067 Pass 3670.048 3658.239 3700.000 3699.893 2,279 2.534 23.020 166.832 9.625 179.863 45.090 134.773 Pass 3693.692 3681.195 3725.000 3724.890 2.342 2.518 23.560 167.129 9.625 185.918 45.302 140.616 Pass 3717.292 3704.090 3750.000 3749.886 2.404 2.503 24.082 167.415 9.625 192.067 45.516 146.552 Pass 3739.551 3725.654 3775.000 3774.882 2.478 2.488 24.577 167.909 9.625 198.354 45.729 152.625 Pass 3760.935 3746.301 3800.000 3799.878 2.558 2.473 25.053 168.503 9.625 204.957 45.947 159.010 Pass 3782.154 3766.713 3825.000 3824.875 2.637 2.461 25.513 169.069 9.625 211.891 46.172 165.719 Pass 3803.199 3786.879 3850.000 3849.870 2.716 2.454 25.961 169.613 9.625 219.162 46.403 172.759 Pass 3824.057 3806.787 3875.000 3874.865 2.799 2.447 26.393 170.222 9.625 226.770 46.630 180.139 Pass 3844.717 3826.424 3900.000 3899.860 2.895 2.440 26.789 171.074 9.625 234.710 46.871 187.839 Pass 3865.192 3845.804 3925.000 3924.854 2.991 2.441 27.158 171.862 9.625 242.977 47.130 195.847 Pass 3885.484 3864.927 3950.000 3949.849 3.086 2.450 27.494 172.584 9.625 251.549 47.407 204.142 Pass 3905.591 3883.790 3975.000 3974.844 3.181 2.459 27.797 173.244 9.625 260.418 47.681 212.736 Pass 3924.963 3901.873 4000.000 3999.840 3.283 2.468 28.100 173.477 9.625 269.594 47.945 221.650 Pass 3943.830 3919.378 4025.000 4024.836 3.388 2.453 28.408 173.530 9.625 279.123 48.150 230.973 Pass 3962.451 3936.546 4050.000 4049.832 3.493 2.414 28.712 173.601 9.625 289.000 48.294 240.706 Pass 3980.822 3953.372 4075.000 4074.828 3.595 2.375 29.012 173.687 9.625 299.221 48.435 250.786 Pass 3998.941 3969.854 4100.000 4099.825 3.697 2.337 29.307 173.785 9.625 309.777 48.571 261.206 Pass 4018.100 3987.174 4125.000 4124.821 3.814 2.319 29.635 173.573 9.625 320.631 48.776 271.855 Pass 4037.501 4004.630 4150.000 4149.817 3.936 2.322 29.977 173.286 9.625 331.704 49.039 282.665 Pass 4056.709 4021.831 4175.000 4174.813 4.058 2.325 30.322 173.031 9.625 342.992 49.298 293.694 Pass 4075.722 4038.776 4200.000 4199.809 4.177 2.328 30.667 172.805 9.625 354.492 49.552 304.940 Pass 4094.539 4055.463 4225.000 4224.806 4.296 2.331 31.014 172.606 9.625 366.202 49.802 316.400 Pass 4113.272 4071.995 4250.000 4249.802 4.423 2.334 31.318 172.718 9.625 378.107 50.054 328.054 Pass 4131.855 4088.320 4275.000 4274.798 4.552 2.337 31.602 172.903 9.625 390.199 50.309 339.890 Pass 4150.263 4104.414 4300.000 4299.794 4.680 2.341 31.876 173.082 9.625 402.475 50.561 351.913 Pass 4168.495 4120.280 4325.000 4324.790 4.806 2.322 32.141 173.256 9.625 414.931 50.763 364.167 Pass 4188.977 4138.040 4350.000 4349.787 4.946 2.282 32.380 173.518 9.625 427.520 50.956 376.564 Pass 4210.375 4156.589 4375.000 4374.783 5.092 2.242 32.600 173.803 9.625 440.121 51.176 388.944 Pass 4231.771 4175.134 4400.000 4399.779 5.238 2.202 32.806 174.075 9.625 452.726 51.397 401.329 Pass 4253.167 4193.676 4425.000 4424.775 5.383 2.170 32.999 174.335 9.625 465.335 51.636 413.700 Pass 4274.562 4212.215 4450.000 4449.771 5.529 2.145 33.181 174.583 9.625 477.948 51.891 426.056 Pass 4295.956 4230.750 4475.000 4474.768 5.675 2.121 33.353 174.821 9.625 490.562 52.147 438.415 Pass 4317.350 4249.283 4500.000 4499.764 5.820 2.096 33.515 175.049 9.625 503.179 52.403 450.776 Pass 4338.742 4267.813 4525.000 4524.760 5.966 2.073 33.668 175.267 9.625 515.798 52.663 463.135 Pass 4360.135 4286.340 4550.000 4549.757 6.112 2.051 33.809 175.474 9.625 528.420 52.928 475.492 Pass 4381.527 4304.864 4575.000 4574.754 6.257 2.029 33.939 175.669 9.625 541.045 53.192 487.853 Pass 4401.202 4321.898 4600.000 4599.751 6.391 2.008 34.059 175.847 9.625 553.677 53.426 500.251 Pass 4409.878 4329.345 4625.000 4624.749 6.453 1.982 34.180 175.970 9.625 566.605 53.462 513.143 Pass 4427.207 4344.062 4650.000 4649.748 6.585 1.952 34.290 176.080 9.625 579.828 53.548 526.279 Pass 4442.614 4357.108 4675.000 4674.748 6.705 1.922 34.463 175.792 9.625 593.085 53.697 539.387 Pass 4456.978 4369.180 4700.000 4699.748 6.818 1.893 34.644 175.466 9.625 606.500 53.834 552.666 Pass 4471.160 4381.010 4725.000 4724.747 6.929 1.869 34.825 175.164 9.625 620.085 53.979 566.106 Pass 4485.121 4392.567 4750.000 4749.746 7.039 1.852 35.018 174.897 9.625 633.916 54.132 579.785 Pass 4500.000 4404.785 4775.000 4774.746 7.155 1.835 35.230 174.636 9.625 648.006 54.294 593.712 Pass 4512.355 4414.852 4800.000 4799.745 7.261 1.817 35.440 174.465 9.625 662.343 54.419 607.923 Pass 4525.631 4425.588 4825.000 4824.743 7.375 1.800 35.665 174.292 9.625 676.922 54.565 622.357 Pass 4538.703 4436.076 4850.000 4849.741 7.487 1.782 35.887 174.134 9.625 691.710 54.708 637.002 Pass 4551.575 4446.322 4875.000 4874.741 7.598 1.764 36.104 173.987 9.625 706.696 54.847 651.849 Pass 4564.251 4456.330 4900.000 4899.740 7.706 1.746 36.316 173.850 9.625 721.877 54.984 666.893 Pass . . Halliburton Company Anticollision Report Company: ConocoPhillips Alaska Inc. Date: 12/3012004 Time: 18:13:21 Page: 6 Field: Kuparuk River Unit Reference Site: Kuparuk 1 B Pad Co-onlinate(NE) Reference: Well: 1B-15, True North Reference Well: 18-15 Vertical (TVD) Reference: 18-15102.0 Reference Wellpath: Plan: 1B-15A Db: Ora de Site: Kuparuk 1 B Pad Well: 1 B-05 Rule Assigned: Major Risk Wellpath: 1 B-05 V3 Inter-Site Error: 0.000 ft Reference Offset Semi-Major Axis Ctr-Ctr No-Go Allowable MD TVD MD TVD Ref Offset TFO+AZI TFO-HS Cøsing/H!Ðistance Area Deviation Warning ft ft ft ft ft ft deg deg in ft ft ft 4576.733 4466.105 4925.000 4924.740 7.813 1.727 36.523 173.723 9.625 737.246 55.122 682.124 Pass 4600.000 4484.111 4950.000 4949.740 8.013 1.708 36.790 173.388 9.625 752.921 55.391 697.529 Pass 4600.000 4484.111 4975.000 4974.739 8.013 1.688 36.926 173.524 9.625 768.514 55.362 713.152 Pass 4613.045 4494.082 5000.000 4999.738 8.138 1.669 37.134 173.407 9.625 784.401 55.509 728.893 Pass 4624.775 4502.969 5025.000 5024.738 8.250 1.668 37.334 173.322 9.625 800.463 55.675 744.788 Pass 4636.298 4511.627 5050.000 5049.737 8.360 1.687 37.529 173.243 9.625 816.741 55.871 760.870 Pass 4647.611 4520.057 5075.000 5074.736 8.468 1.706 37.720 173.169 9.625 833.236 56.063 777.173 Pass 4658.718 4528.263 5100.000 5099.734 8.575 1.725 37.905 173.101 9.625 849.945 56.253 793.693 Pass 4669.625 4536.254 5125.000 5124.732 8.679 1.762 38.086 173.038 9.625 866.856 56.468 810.388 Pass 4680.347 4544.044 5150.000 5149.730 8.781 1.818 38.266 172.983 9.625 883.933 56.709 827.224 Pass 4700.000 4558.150 5175.000 5174.728 8.969 1.874 38.498 172.795 9.625 901.245 57.058 844.187 Pass 4700.000 4558.150 5200.000 5199.726 8.969 1.930 38.615 172.912 9.625 918.553 57.143 861.411 Pass 4700.000 4558.150 5225.000 5224.724 8.969 1.994 38.728 173.025 9.625 936.209 57.265 878.944 Pass 4721.487 4573.313 5250.000 5249.721 9.195 2.068 38.974 172.827 9.625 953.762 57.664 896.099 Pass 4731.354 4580.185 5275.000 5274.718 9.299 2.142 39.145 172.800 9.625 971.576 57.918 913.658 Pass 4741.061 4586.887 5300.000 5299.715 9.401 2.215 39.314 172.776 9.625 989.524 58.167 931.357 Pass 4750.611 4593.425 5325.000 5324.711 9.501 2.294 39.479 172.755 9.625 1007.603 58.421 949.183 Pass 4760.001 4599.800 5350.000 5349.707 9.600 2.379 39.644 172.739 9.625 1025.815 58.678 967.137 Pass 4769.236 4606.016 5375.000 5374.704 9.697 2.463 39.806 172.727 9.625 1044.157 58.931 985.226 Pass 4778.317 4612.077 5400.000 5399.700 9.792 2.548 39.967 172.718 9.625 1062.625 59.179 1003.446 Pass 4800.000 4626.338 5425.000 5424.696 10.020 2.615 40.204 172.559 9.625 1081.356 59.539 1021.817 Pass 4800.000 4626.338 5450.000 5449.692 10.020 2.664 40.310 172.664 9.625 1099.936 59.621 1040.314 Pass 4800.000 4626.338 5475.000 5474.688 10.020 2.714 40.412 172.766 9.625 1118.759 59.680 1059.079 Pass 4800.000 4626.338 5500.000 5499.684 10.020 2.763 40.511 172.865 9.625 1137.815 59.763 1078.052 Pass 4821.549 4640.215 5525.000 5524.681 10.265 2.779 40.750 172.723 9.625 1156.702 60.033 1096.669 Pass 4829.786 4645.440 5550.000 5549.677 10.359 2.762 40.903 172.733 9.625 1175.831 60.100 1115.731 Pass 4837.895 4650.540 5575.000 5574.675 10.451 2.745 41.057 172.748 9.625 1195.053 60.166 1134.887 Pass 4845.878 4655.519 5600.000 5599.672 10.542 2.728 41.210 172.765 9.625 1214.365 60.231 1154.134 Pass 4853.739 4660.382 5625.000 5624.670 10.631 2.706 41.363 172.787 9.625 1233.762 60.287 1173.476 Pass 4861.493 4665.138 5650.000 5649.668 10.719 2.678 41.516 172.811 9.625 1253.223 60.334 1192.889 Pass 4869.144 4669.791 5675.000 5674.665 10.806 2.651 41.669 172.838 9.625 1272.742 60.381 1212.361 Pass 4876.693 4674.344 5700.000 5699.662 10.892 2.624 41.822 172.868 9.625 1292.318 60.427 1231.892 Pass 4900.000 4688.157 5725.000 5724.659 11.157 2.618 42.075 172.748 9.625 1312.155 60.687 1251.469 Pass 4900.000 4688.157 5750.000 5749.655 11.157 2.632 42.178 172.852 9.625 1331.762 60.704 1271.058 Pass 4900.000 4688.157 5775.000 5774.651 11.157 2.647 42.277 172.951 9.625 1351.566 60.721 1290.845 Pass 4900.000 4688.157 5800.000 5799.648 11.157 2.662 42.371 173.045 9.625 1371.559 60.712 1310.847 Pass 4900.000 4688.157 5825.000 5824.644 11.157 2.671 42.460 173.134 9.625 1391.729 60.721 1331.007 Pass 4900.000 4688.157 5850.000 5849.640 11.157 2.674 42.548 173.222 9.625 1412.043 60.721 1351.322 Pass 4926.276 4703.284 5875.000 5874.637 11.477 2.677 42.817 173.083 9.625 1431.970 61.032 1370.939 Pass 4932.923 4707.034 5900.000 5899.633 11.558 2.680 42.952 173.117 9.625 1452.256 61.115 1391.141 Pass 4939.471 4710.699 5925.000 5924.629 11.637 2.665 43.086 173.152 9.625 1472.609 61.173 1411.436 Pass 4945.919 4714.278 5950.000 5949.625 11.716 2.632 43.219 173.189 9.625 1493.036 61.208 1431.828 Pass 4952.268 4717.774 5975.000 5974.621 11.793 2.599 43.350 173.226 9.625 1513.535 61.243 1452.292 Pass 4958.521 4721.189 6000.000 5999.618 11.869 2.566 43.481 173.264 9.625 1534.106 61.278 1472.828 Pass 4964.676 4724.524 6025.000 6024.614 11.944 2.523 43.610 173.303 9.625 1554.749 61.297 1493.452 Pass 4970.729 4727.777 6050.000 6049.611 12.018 2.469 43.738 173.343 9.625 1575.475 61.302 1514.174 Pass 5000.000 4743.136 6075.000 6074.608 12.374 2.415 44.016 173.202 9.625 1596.678 61.606 1535.072 Pass 5000.000 4743.136 6100.000 6099.605 12.374 2.361 44.104 173.290 9.625 1617.398 61.538 1555.860 Pass 5000.000 4743.136 6125.000 6124.603 12.374 2.309 44.191 173.377 9.625 1638.250 61.471 1576.779 Pass 5000.000 4743.136 6150.000 6149.601 12.374 2.258 44.274 173.460 9.625 1659.235 61.405 1597.830 Pass 5000.000 4743.136 6175.000 6174.600 12.374 2.208 44.355 173.542 9.625 1680.347 61.340 1619.007 Pass . . Halliburton Company Anticollision Report Company: ConocoPhillips Alaska Inc. Date: 12/3012004 Time: 18:13:21 Page: 7 Field: Kuparuk River Unit Reference Site: Kuparuk 1 B Pad Co-ordinate(NE) Reference: Well: 1B-15. True North Reference Well: 18-15 Vertical (TVD) Reference: 18-15102.0 Reference Wellpath: Plan: 1B-15A Db: Oracle Site: Kuparuk 1 B Pad Well: 1 B-05 Rule Assigned: Major Risk Wellpath: 1 B-05 V3 Inter-Site Error: 0.000 ft Reference Offset Semi-Major Axis Ctr-Ctr No-Go Allowable MD TVD MD TVD Ref Offset TFO+AZI TFO-HS CasingIHSDistance Area Deviation Warning ft ft ft ft ft ft deg deg in ft ft ft 5000.000 4743.136 6200.000 6199.599 12.374 2.158 44.434 173.620 9.625 1701.581 61.275 1640.306 Pass 5000.000 4743.136 6225.000 6224.598 12.374 2.118 44.511 173.697 9.625 1722.933 61.223 1661.710 Pass 5000.000 4743.136 6250.000 6249.597 12.374 2.089 44.586 173.772 9.625 1744.394 61.183 1683.211 Pass 5000.000 4743.136 6275.000 6274.596 12.374 2.059 44.659 173.845 9.625 1765.960 61.144 1704.816 Pass 5025.895 4756.205 6300.000 6299.596 12.706 2.030 44.917 173.743 9.625 1787.164 61.449 1725.715 Pass 5030.914 4758.681 6325.000 6324.596 12.771 1.998 45.026 173.784 9.625 1808.737 61.477 1747.260 Pass 5035.829 4761.088 6350.000 6349.596 12.834 1.966 45.135 173.825 9.625 1830.399 61.503 1768.896 Pass 5040.641 4763.427 6375.000 6374.595 12.896 1.933 45.244 173.869 9.625 1852.150 61.528 1790.623 Pass 5045.350 4765.700 6400.000 6399.595 12.956 1.900 45.353 173.915 9.625 1873.989 61.553 1812.437 Pass 5049.961 4767.909 6425.000 6424.593 13.016 1.886 45.462 173.961 9.625 1895.912 61.594 1834.318 Pass 5054.489 4770.062 6450.000 6449.590 13.074 1.890 45.568 174.007 9.625 1917.906 61.651 1856.256 Pass 5058.936 4772.163 6475.000 6474.587 13.131 1.895 45.672 174.051 9.625 1939.970 61.706 1878.263 Pass 5063.305 4774.212 6500.000 6499.584 13.187 1.899 45.773 174.094 9.625 1962.100 61.761 1900.339 Pass 5067.599 4776.212 6525.000 6524.580 13.242 1.904 45.872 174.136 9.625 1984.293 61.817 1922.476 Pass 5071.830 4778.170 6550.000 6549.577 13.296 1.908 45.969 174.178 9.625 2006.529 61.874 1944.655 Pass 5100.000 4790.856 6575.000 6574.573 13.658 1.911 46.231 174.073 9.625 2029.184 62.264 1966.921 Pass 5100.000 4790.856 6600.000 6599.569 13.658 1.915 46.299 174.141 9.625 2051.379 62.262 1989.117 Pass 5100.000 4790.856 6625.000 6624.565 13.658 1.917 46.365 174.208 9.625 2073.641 62.257 2011.384 Pass 5100.000 4790.856 6650.000 6649.559 13.658 1.917 46.432 174.274 9.625 2095.999 62.251 2033.748 Pass 5100.000 4790.856 6675.000 6674.550 13.658 1.916 46.498 174.341 9.625 2118.453 62.245 2056.208 Pass 5100.000 4790.856 6700.000 6699.539 13.658 1.916 46.565 174.407 9.625 2141.001 62.241 2078.760 Pass 5100.000 4790.856 6725.000 6724.524 13.658 1.916 46.631 174.473 9.625 2163.632 62.239 2101.393 Pass 5100.000 4790.856 6750.000 6749.511 13.658 1.917 46.695 174.537 9.625 2186.302 62.239 2124.063 Pass 5100.000 4790.856 6775.000 6774.499 13.658 1.919 46.758 174.600 9.625 2209.006 62.239 2146.767 Pass 5100.000 4790.856 6800.000 6799.487 13.658 1.921 46.819 174.661 9.625 2231.757 62.239 2169.517 Pass 5100.000 4790.856 6825.000 6824.476 13.658 1.924 46.879 174.721 9.625 2254.555 62.240 2192.315 Pass 5100.000 4790.856 6826.500 6825.975 13.658 1.924 46.883 174.725 9.625 2255.924 62.240 2193.684 Pass Site: Kuparuk 1 B Pad Well: 1B-18 Rule Assigned: Major Risk Wellpath: 1B-18 VO Inter-Site Error: 0.000 ft Reference Offset Semi-Major Axis Ctr-Ctr No-Go Allowabte MD TVD MD TVD Ref Offset TFO+AZI TFO-HS CasingIHSDistance Area Deviation Warning ft ft ft ft ft ft deg deg in ft ft ft 3610.276 3600.132 3650.000 3627.154 2.122 3.620 100.497 244.791 272.355 50.301 222.054 Pass 3634.440 3623.632 3675.000 3650.014 2.185 3.751 101.551 245.741 275.617 51.062 224.555 Pass 3658.017 3646.551 3700.000 3672.741 2.247 3.882 102.642 246.580 278.974 51.802 227.172 Pass 3681.552 3669.411 3725.000 3695.345 2.310 4.026 103.754 247.447 282.434 52.574 229.859 Pass 3705.053 3692.220 3750.000 3717.838 2.372 4.172 104.878 248.333 285.972 53.345 232.627 Pass 3728.442 3714.900 3775.000 3740.217 2.436 4.317 106.011 249.277 289.597 54.124 235.473 Pass 3751.237 3736.947 3800.000 3762.479 2.522 4.464 107.114 250.512 293.350 54.944 238.405 Pass 3774.072 3758.948 3825.000 3784.586 2.607 4.622 108.187 251.704 297.323 55.792 241.531 Pass 3796.936 3780.887 3850.000 3806.521 2.693 4.780 109.235 252.860 301.543 56.635 244.908 Pass 3819.844 3802.772 3875.000 3828.277 2.779 4.938110.256 253.988 306.004 57.485 248.519 Pass 3843.479 3825.250 3900.000 3849.852 2.890 5.108 111.227 255.486 310.667 58.426 252.241 Pass 3867.178 3847.679 3925.000 3871.245 3.001 5.285112.166 256.909 315.475 59.382 256.092 Pass 3890.943 3870.056 3950.000 3892.451 3.112 5.462113.074 258.264 320.418 60.335 260.083 Pass 3914.596 3892.209 3975.000 3913.466 3.225 5.639113.957 259.482 325.492 61.298 264.194 Pass 3936.847 3912.912 4000.000 3934.361 3.349 5.799114.824 260.037 330.707 62.225 268.483 Pass 3959.210 3933.566 4025.000 3955.242 3.474 5.958115.600 260.528 336.017 63.149 272.868 Pass 3981.675 3954.150 4050.000 3976.107 3.600 6.115116.288 260.953 341.404 64.075 277.328 Pass 4004.202 3974.619 4075.000 3996.959 3.727 6.263 116.893 261.299 346.857 65.006 281.851 Pass . . Halliburton Company Anticollision Report Company: ConocoPhillips Alaska Inc. Date: 12/30/2004 Time: 18:13:21 Page: 8 Fietd: Kuparuk River Unit Reference Site: Kuparuk 1 B Pad Co-ordinate(NE) Reference: Well: 1B-15. True North Reference Well: 1B-15 Vertical (TVD) Reference: 18-15102.0 Reference Wellpath: Plan: 18-15A Db: Orade Site: Kuparuk 1 B Pad Well: 1 B-18 Rute Assigned: Major Risk Wellpath: 18-18 VO Inter-Site Error: 0.000 ft Reference Offset Semi-Major Axis Ctr-Ctr No-Go Allowable MD TVD MD 1VD Ref Offset TFO+AZI TFO-HS CasingIH!Ðistance Area Deviation Warning ft ft ft ft ft ft deg deg in ft ft ft 4025.902 3994.204 4100.000 4017.810 3.863 6.385117.472 261.155 352.503 65.861 286.643 Pass 4047.572 4013.659 4125.000 4038.667 4.000 6.506 117.992 260.984 358.406 66.714 291.692 Pass 4069.203 4032.975 4150.000 4059.529 4.136 6.626118.456 260.787 364.558 67.567 296.991 Pass 4090.786 4052.141 4175.000 4080.397 4.272 6.745 118.865 260.564 370.951 68.418 302.533 Pass 4113.267 4071.991 4200.000 4101.265 4.423 6.885119.187 260.587 377.543 69.396 308.147 Pass 4136.269 4092.186 4225.000 4122.123 4.583 7.033119.446 260.724 384.214 70.401 313.813 Pass 4159.266 4112.258 4250.000 4142.970 4.742 7.181 119.664 260.824 390.951 71.407 319.544 Pass 4182.740 4132.633 4275.000 4163.806 4.904 7.333 119.835 260.953 397.746 72.509 325.237 Pass 4207.017 4153.678 4300.000 4184.631 5.069 7.492119.980 261.173 404.541 73.561 330.980 Pass 4231.303 4174.728 4325.000 4205.445 5.235 7.652 120.122 261.391 411.320 74.614 336.707 Pass 4255.598 4195.782 4350.000 4226.248 5.400 7.811 120.261 261.605 418.084 75.666 342.418 Pass 4279.903 4216.842 4375.000 4247.040 5.565 7.971 120.397 261.816 424.832 76.719 348.113 Pass 4304.216 4237.906 4400.000 4267.821 5.731 8.131 120.531 262.024 431.564 77.771 353.793 Pass 4328.518 4258.957 4425.000 4288.537 5.896 8.334 120.672 262.240 438.339 78.929 359.410 Pass 4352.780 4279.970 4450.000 4309.110 6.062 8.541 120.836 262.478 445.237 80.092 365.145 Pass 4376.998 4300.942 4475.000 4329.539 6.226 8.749 121.021 262.738 452.261 81.251 371.010 Pass 4401.010 4321.732 4500.000 4349.821 6.390 8.953 121.227 263.014 459.410 82.404 377.007 Pass 4423.205 4340.665 4525.000 4369.953 6.554 9.127 121.390 263.180 466.764 83.360 383.405 Pass 4444.112 4358.372 4550.000 4389.935 6.717 9.308 121.620 262.896 474.332 84.468 389.864 Pass 4463.747 4374.837 4575.000 4409.763 6.871 9.477 121.862 262.452 482.231 85.491 396.740 Pass 4483.248 4391.022 4600.000 4429.435 7.024 9.643 122.084 262.024 490.465 86.506 403.958 Pass 4502.609 4406.917 4625.000 4448.949 7.178 9.807 122.287 261.612 499.029 87.581 411.448 Pass 4521.822 4422.517 4650.000 4468.303 7.342 9.968 122.473 261.213 507.920 88.615 419.305 Pass 4540.882 4437.817 4675.000 4487.495 7.506 10.126 122.642 260.827 517.133 89.641 427.492 Pass 4559.794 4452.820 4700.000 4506.558 7.668 10.296 122.792 260.448 526.632 90.694 435.938 Pass 4578.577 4467.542 4725.000 4525.581 7.829 10.469 122.911 260.062 536.336 91.753 444.583 Pass 4597.227 4481.980 4750.000 4544.569 7.989 10.638 123.001 259.669 546.240 92.806 453.435 Pass 4615.735 4496.127 4775.000 4563.522 8.163 10.805 123.062 259.269 556.342 93.973 462.369 Pass 4634.096 4509.979 4800.000 4582.439 8.339 10.968 123.099 258.864 566.640 95.053 471.587 Pass 4652.303 4523.532 4825.000 4601.321 8.513 11.128 123.111 258.453 577.132 96.123 481.009 Pass 4670.351 4536.784 4850.000 4620.167 8.686 11.286 123.101 258.037 587.817 97.182 490.635 Pass 4688.239 4549.735 4875.000 4638.989 8.857 11.420 123.069 257.616 598.679 98.182 500.498 Pass 4705.995 4562.408 4900.000 4657.851 9.032 11.531 123.011 257.182 609.621 99.245 510.375 Pass 4723.618 4574.802 4925.000 4676.765 9.217 11.640 122.926 256.736 620.627 100.214 520.413 Pass 4741.101 4586.915 4950.000 4695.730 9.401 11.747 122.816 256.278 631.700 101.171 530.529 Pass 4758.440 4598.744 4975.000 4714.746 9.583 11.851 122.683 255.809 642.839 102.115 540.724 Pass 4775.628 4610.287 5000.000 4733.812 9.764 11.953 122.529 255.330 654.049 103.046 551.002 Pass 4792.660 4621.543 5025.000 4752.927 9.943 12.053 122.354 254.841 665.329 103.964 561.365 Pass 4809.530 4632.512 5050.000 4772.091 10.128 12.142122.160 254.345 676.685 105.001 571.684 Pass 4826.199 4643.170 5075.000 4791.301 10.318 12.197 121.947 253.839 688.203 105.814 582.389 Pass 4842.643 4653.507 5100.000 4810.553 10.505 12.251 121.716 253.327 699.925 106.608 593.317 Pass 4858.859 4663.526 5125.000 4829.849 10.689 12.303 121.469 252.808 711.853 107.384 604.470 Pass 4874.841 4673.230 5150.000 4849.188 10.871 12.355 121.207 252.283 723.987 108.139 615.848 Pass 4890.586 4682.622 5175.000 4868.569 11.050 12.406 120.931 251.754 736.328 108.875 627.453 Pass 4906.091 4691.706 5200.000 4887.993 11.231 12.456 120.643 251.221 748.876 109.763 639.114 Pass 4921.353 4700.486 5225.000 4907.459 11.417 12.506 120.344 250.686 761.633110.483 651.150 Pass 4936.370 4708.967 5250.000 4926.967 11.600 12.556 120.036 250.149 774.598111.181 663.417 Pass 4951.140 4717.155 5275.000 4946.517 11.779 12.605119.719 249.611 787.771 111.857 675.914 Pass 4965.661 4725.055 5300.000 4966.109 11.956 12.653119.395 249.D73 801.152112.509 688.643 Pass 4979.935 4732.674 5325.000 4985.742 12.130 12.709119.064 248.536 814.742113.157 701.585 Pass 5000.000 4743.136 5350.000 5005.366 12.374 12.764 118.776 247.962 828.560114.021 714.539 Pass . . Halliburton Company Anticollision Report Company: ConocoPhillips Alaska Inc. Date: 12/30/2004 Time: 18:13:21 Page: 9 Field: Kuparuk River Unit Reference Site: Kuparuk 1 B Pad Co-onlinate(NE) Reference: Well: 1B"15. True North Reference Well: 18-15 Vertical (TVD) Reference: 18-15102.0 Reference Wellpath: Plan: 18-15A Db: Orade Site: Kuparuk 1 B Pad Well: 1B-18 Rule Assigned: Major Risk Wellpath: 1B-18VO Inter-Site Error: 0.000 ft Reference Offset Semi-Major Axis Ctr-Ctr No-Go Allowable MD TVD MD TVD Ref Offset TFO+AZI TFO-HS CasingIHS>istance Area Deviation Warning ft ft ft ft ft ft deg deg in ft ft ft 5000.000 4743.136 5375.000 5024.960 12.374 12.913 118.355 247.541 842.559 114.505 728.053 Pass 5021.432 4753.987 5400.000 5044.522 12.649 12.958 118.082 246.970 856.673 115.402 741.271 Pass 5034.840 4760.605 5425.000 5064.052 12.821 13.040117.763 246.466 871.026 116.056 754.970 Pass 5048.039 4766.990 5450.000 5083.551 12.991 13.122117.447 245.972 885.562 116.688 768.874 Pass 5061.033 4773.148 5475.000 5103.018 13.158 13.203117.136 245.487 900.280117.300 782.980 Pass 5073.823 4779.087 5500.000 5122.454 13.322 13.284 116.830 245.G12 915.176117.891 797.285 Pass 5086.412 4784.812 5525.000 5141.857 13.484 13.365 116.528 244.546 930.247 118.463 811.785 Pass 5100.000 4790.856 5550.000 5161.229 13.658 13.440 116.240 244.082 945.493 119.044 826.449 Pass 5110.998 4795.645 5575.000 5180.568 13.806 13.527 115.940 243.641 960.907 119.639 841.268 Pass 5123.001 4800.766 5600.000 5199.876 13.966 13.608 115.653 243.203 976.489 120.046 856.442 Pass 5134.773 4805.681 5625.000 5219.273 14.124 13.682 115.361 242.763 992.234 120.415 871.819 Pass 5146.268 4810.376 5650.000 5238.894 14.277 13.757115.052 242.311 1008.140120.759 887.381 Pass 5157.483 4814.859 5675.000 5258.733 14.427 13.833 114.728 241.848 1024.206 121.079 903.127 Pass 5168.418 4819.134 5700.000 5278.786 14.574 13.909 114.389 241.376 1040.429121.374 919.055 Pass 5183.825 4824.999 5725.000 5299.049 14.780 13.961 114.073 240.873 1056.826121.700 935.126 Pass 5192.991 4828.433 5750.000 5319.519 14.908 14.094 113.631 240.431 1073.328 122.170 951.159 Pass 5209.699 4834.692 5775.000 5340.190 15.141 14.226113.185 239.985 1089.910123.049 966.862 Pass 5226.268 4840.898 5800.000 5361.045 15.371 14.340 112.737 239.537 1106.543123.657 982.887 Pass 5242.785 4847.086 5825.000 5381.997 15.599 14.435 112.294 239.094 1123.209124.206 999.003 Pass 5259.265 4853.259 5850.000 5403.030 15.828 14.531 111.856 238.656 1139.906124.748 1015.158 Pass 5275.707 4859.418 5875.000 5424.143 16.055 14.626 111.424 238.224 1156.633 125.282 1031.351 Pass 5292.110 4865.563 5900.000 5445.336 16.283 14.721 110.998 237.798 1173.389 125.808 1047.581 Pass 5308.474 4871.693 5925.000 5466.607 16.510 14.817110.577 237.377 1190.174 126.528 1063.646 Pass 5324.799 4877.809 5950.000 5487.956 16.737 14.912110.161 236.961 1206.989 127.042 1079.947 Pass 5341.084 4883.909 5975.000 5509.383 16.963 15.007 109.750 236.550 1223.833 127.548 1096.285 Pass 5357.345 4890.001 6000.000 5530.821 17.189 15.120 109.349 236.149 1240.752 128.092 1112.660 Pass 5373.610 4896.094 6025.000 5552.168 17.415 15.236 108.967 235.767 1257.813128.644 1129.169 Pass 5389.878 4902.188 6050.000 5573.422 17.641 15.351 108.603 235.403 1275.011 129.199 1145.812 Pass 5406.178 4908.294 6075.000 5594.573 17.868 15.479 108.258 235.058 1292.313 129.983 1162.330 Pass 5422.730 4914.495 6100.000 5615.558 18.099 15.622 107.932 234.732 1309.529 130.621 1178.908 Pass 5439.575 4920.804 6125.000 5636.360 18.334 15.765 107.627 234.427 1326.612 131.273 1195.339 Pass 5456.705 4927.222 6150.000 5656.974 18.572 15.908 107.340 234.140 1343.551 131.939 1211.613 Pass 5474.018 4933.707 6175.000 5677.409 18.814 16.053 107.072 233.872 1360.439132.625 1227.814 Pass 5491.199 4940.143 6200.000 5697.718 19.053 16.198 106.821 233.621 1377.587 133.319 1244.268 Pass 5508.223 4946.520 6225.000 5717.898 19.291 16.344 106.589 233.389 1395.008 134.207 1260.801 Pass 5525.083 4952.837 6250.000 5737.944 19.526 16.490 106.373 233.173 1412.694134.907 1277.787 Pass 5541.777 4959.090 6275.000 5757.851 19.759 16.636106.174 232.974 1430.637 135.610 1295.027 Pass 5558.300 4965.280 6300.000 5777.613 19.990 16.782 105.992 232.792 1448.828 136.315 1312.513 Pass 5574.647 4971.404 6325.000 5797.226 20.219 16.928 105.825 232.625 1467.258 137.022 1330.236 Pass 5590.815 4977.460 6350.000 5816.684 20.445 17.074 105.673 232.473 1485.921 137.732 1348.189 Pass 5606.806 4983.451 6375.000 5835.988 20.668 17.220 105.535 232.335 1504.800 138.637 1366.163 Pass 5622.774 4989.432 6400.000 5855.227 20.892 17.367 105.405 232.205 1523.727139.366 1384.361 Pass 5638.772 4995.425 6425.000 5874.436 21.116 17.514 105.280 232.080 1542.643 140.098 1402.545 Pass 5654.803 5001.430 6450.000 5893.614 21.340 17.662105.160 231.960 1561.547140.832 1420.715 Pass 5670.865 5007.447 6475.000 5912.761 21.565 17.809 105.044 231.844 1580.438 141.568 1438.870 Pass 5686.959 5013.476 6500.000 5931.877 21.790 17.956 104.932 231.732 1599.316 142.306 1457.010 Pass 5703.084 5019.517 6525.000 5950.963 22.016 18.104 104.824 231.624 1618.179143.233 1474.946 Pass 5719.254 5025.574 6550.000 5969.998 22.242 18.261 104.721 231.521 1637.021 144.003 1493.019 Pass 5735.487 5031.655 6575.000 5988.951 22.470 18.420 104.625 231.425 1655.831 144.780 1511.050 Pass 5751.785 5037.760 6600.000 6007.823 22.698 18.579 104.535 231.335 1674.606145.563 1529.043 Pass 5768.145 5043.889 6625.000 6026.613 22.928 18.738 104.450 231.250 1693.346 146.351 1546.994 Pass · . Halliburton Company Anticollision Report Company: Fietd: Reference Site: Reference WeD: Reference Wellpatb: ConocoPhillips Alaska Inc. Kuparuk River Unit Kuparuk 1 B Pad 1B-15 Plan: 18-15A Site: Well: Wellpatb: Kuparuk 1 B Pad 1B-18 1B-18 VO Date: 12/3012004 Time: 18:13:21 Page: 10 Co-onlinate(NE) Reference: Well: 1 B-15. True North Vertical (TVD) Reference: 18-15102.0 Db: Orade Reference MD TVD ft ft Offset MD TVD ft ft Rule Assigned: Inter-Site Error: Semi-Major Axis Ctr-Ctr No-Go Ref Offset TFO+AZI TFO-HS CasingIHSDistance Area ft ft deg deg in ft ft Major Risk 0.000 ft Altowabte Deviation Warning ft 5784.568 5050.041 6650.000 6045.319 23.158 5801.053 5056.217 6675.000 6063.942 23.389 5817.600 5062.415 6700.000 6082.481 23.621 5834.196 5068.632 6725.000 6100.944 23.854 5850.785 5074.847 6750.000 6119.372 24.087 5867.362 5081.056 6775.000 6137.768 24.320 5883.927 5087.262 6800.000 6156.132 24.552 5900.478 5093.462 6825.000 6174.464 24.784 5917.018 5099.658 6850.000 6192.765 25.017 5933.544 5105.849 6875.000 6211.034 25.249 5950.058 5112.035 6900.000 6229.272 25.481 5966.623 5118.240 6925.000 6247.531 25.714 5983.280 5124.480 6950.000 6265.850 25.948 6000.030 5130.755 6975.000 6284.227 26.183 6016.872 5137.064 7000.000 6302.661 26.420 6033.804 5143.407 7025.000 6321.152 26.658 6050.826 5149.783 7050.000 6339.698 26.897 6067.938 5156.193 7075.000 6358.298 27.138 6085.137 5162.636 7100.000 6376.952 27.380 6102.424 5169.112 7125.000 6395.659 27.623 6119.798 5175.621 7150.000 6414.418 27.867 6137.258 5182.161 7175.000 6433.229 28.113 6154.803 5188.734 7200.000 6452.089 28.360 6172.433 5195.338 7225.000 6470.999 28.608 6190.146 5201.973 7250.000 6489.957 28.857 6207.941 5208.640 7275.000 6508.963 29.108 6225.818 5215.337 7300.000 6528.016 29.359 6243.777 5222.064 7325.000 6547.115 29.612 6261.815 5228.821 7350.000 6566.258 29.866 6279.933 5235.608 7375.000 6585.446 30.121 6298.130 5242.425 7400.000 6604.677 30.377 6316.403 5249.270 7425.000 6623.950 30.635 6334.688 5256.120 7450.000 6643.288 30.892 6352.933 5262.955 7475.000 6662.706 31.149 6371.139 5269.775 7500.000 6682.204 31.406 6389.306 5276.580 7525.000 6701.782 31.662 6407.432 5283.370 7550.000 6721.440 31.917 6425.518 5290.145 7575.000 6741.176 32.172 6443.563 5296.905 7600.000 6760.990 32.427 6461.566 5303.649 7625.000 6780.881 32.680 6479.527 5310.377 7650.000 6800.850 32.933 6497.445 5317.090 7675.000 6820.895 33.186 6515.321 5323.786 7700.000 6841.017 33.438 6533.153 5330.466 7725.000 6861.213 33.690 6550.968 5337.140 7750.000 6881.438 33.941 18.897104.371 231.171 19.056 104.298 231.098 19.215104.230 231.030 19.377 104.167 230.967 19.540104.107 230.907 19.704 104.050 230.850 19.868 103.996 230.796 20.032 103.944 230.744 20.196 103.895 230.695 20.360 103.848 230.648 20.523 103.804 230.604 20.674 103.759 230.559 20.825 103.712 230.512 20.977 103.663 230.463 21.128103.611 230.411 21.280 103.558 230.358 21.431 103.502 230.302 21.582 103.444 230.244 21.734 103.383 230.183 21.885103.321 230.121 22.037 103.257 230.057 22.188 103.192 229.992 22.339103.124 229.924 22.491 103.054 229.854 22.642 102.983 229.783 22.794 102.910 229.710 22.945 102.835 229.635 23.097 102.758 229.558 23.248 102.680 229.480 23.399 102.601 229.401 23.551 102.519 229.319 23.701 102.436 229.236 23.831 102.352 229.152 23.961 102.265 229.065 24.092 102.177 228.977 24.222 102.088 228.888 24.352 101.996 228.796 24.483 101.903 228.703 24.613 101.809 228.609 24.744 101.713 228.513 24.874101.615 228.415 25.005101.516 228.316 25.135 101.416 228.216 25.267101.314 228.114 25.407 101.213 228.013 6568.784 5343.814 7775.000 6901.664 34.192 25.548 101.112 227.912 6586.599 5350.487 7800.000 6921.889 34.443 25.688 101.014 227.814 6603.702 5356.894 7824.000 6941.306 34.684 25.823100.920 227.720 1712.049 147.145 1564.904 1730.714 148.128 1582.586 1749.341 148.933 1600.408 1767.938 149.751 1618.187 1786.548150.574 1635.973 1805.175151.399 1653.776 1823.821 152.225 1671.595 1842.483 153.237 1689.247 1861.163154.066 1707.097 1879.860154.897 1724.963 1898.572 155.725 1742.847 1917.238 156.515 1760.723 1935.812 157.304 1778.508 1954.296158.276 1796.020 1972.687 159.065 1813.621 1990.985159.854 1831.131 2009.190 160.642 1848.549 2027.302161.428 1865.873 2045.319162.214 1883.104 2063.241 163.182 1900.059 2081.067 163.968 1917.100 2098.798 164.752 1934.046 2116.432 165.535 1950.897 2133.969 166.317 1967.651 2151.408167.098 1984.310 2168.749 168.060 2000.689 2185.992 168.840 2017.152 2203.136169.618 2033.518 2220.180 170.395 2049.785 2237.125 171.171 2065.954 2253.969 171.945 2082.024 2270.713172.894 2097.820 2287.428173.598 2113.830 2304.165 174.297 2129.868 2320.925 174.991 2145.934 2337.708 175.679 2162.029 2354.514 176.542 2177.972 2371.343 177.221 2194.121 2388.194 177.895 2210.299 2405.068 178.563 2226.505 2421.966179.226 2242.739 2438.886 179.884 2259.002 2455.829 180.715 2275.114 2472.795181.365 2291.430 2489.775 182.031 2307.743 2506.762 182.697 2324.065 2523.757 183.362 2340.395 2540.079 184.177 2355.902 Pass Pass Pass Pass Pass Pass Pass Pass Pass Pass Pass Pass Pass Pass Pass Pass Pass Pass Pass Pass Pass Pass Pass Pass Pass Pass Pass Pass Pass Pass Pass Pass Pass Pass Pass Pass Pass Pass Pass Pass Pass Pass Pass Pass Pass Pass Pass Pass Re: [Fwd: Re: Proposed P&A IE-IS] . . Subject: Re: [Fwd: Re: Proposed P&A 1B-15] From: Thomas Maunder <tom_maunder@admin.state.ak.us> Date: Thu, 30 Dee 2004 09:18:17 -0900 To: "Allsup-Drake, Sharon K" <Sharon.K.Allsup-Drake@conocophillips.com> Sharon, As noted, I did get the fax. I don't have Jake's email, so would you forward this to him. I note as I am reviewing the 1B-15A application that there is not a postable drilling hazards sheet included. You might look at some of the other permit applications and prepare one for this well. As I have researched the old file, it appears that the original had a tapered (7 x 5-112") production casing run rather than a casing with a liner. The well drawing shows this, but the "formal" drawing with the sundry calls it a liner. It is semantics since I don't think whoever prepared the formal drawing may have known the difference. On the proximity analysis I find a report/listing for 1B-01, but not for 1B-18_ From the numbers it appears that 1B-01 starts about 500' away and then moves to about 1000' and stays there. It appears that 1B-15A has a deep crossing above 1B-01. Is it still about 1000' away?? On 1B-18, frornthe plot appears to be closest at the proposed KOP and then diverges. Have I got that correct?? On your drilling liner cement design, do you have sufficient XS?? The numbers I run only show 12%. With only a 2000' vertical column, there shouldn't be a lost circulation risk. Thanks in advance for looking into these questions/comments. Tom Maunder, PE AOGCC Thomas Maunder wrote: Sharon, Why don't you fax it. Thanks. Tom Allsup-Drake, Sharon K wrote: Tom - I can fax over the description or I can email it to you or send it through the snail-mail. Which do you prefer? Thanks, Sharon office phone: 263-4612 fax: 265-6224 -----Original Message----- From: Thomas Maunder [mailto:tom maunder@admin.state.ak.us] Sent: Wednesday, December 29, 2004 1:44 PM To: Allsup-Drake, Sharon K Subject: [Fwd: Re: Proposed P&A 18-15] lof2 1/312005 10: 19 AM Re: [Fwd: Re: Proposed P&A IE-I5] . . Sharon, Here is that message I attempted to send to Kelly on IB-15. I did not get a "non-deliverable" reply. Tom -------- Original Message -------- Subject: Re: Proposed P&A IB-15 Date: Wed, 29 Dec 2004 09:56:13 -0900 From: Thomas Maunder <tom maunder@admin.state.ak.us> ..--........................................................-........-- ..................................... Organization: State of Alaska To: Kelly Mclure .~..I.<:.~_~)X .A. McLur~@conocophíll:i.ps. com> References: <41D2FD95.7030308@admin.state.ak.us> Also, when do propose to do the work. The form says November 15. Thomas Maunder wrote: Kelly, I just received the sundry for the P&A of this well. Could you please send some additional information with regard to where plugs are proposed, volumes, if this is P&A for sidetrack or what. Normally a procedure is included with these applications. In its present form, I can't process the application. Thanks. Tom Maunder, PE AOGCC 20f2 1/3/2005 10:19 AM Conoc~illipS . Post Office Box 100360 Anchorage, Alaska 99510-0360 Randy Thomas Phone (907) 265·6830 Fax: (907) 265-1535 Email: randy.l.thomas@conocophillips.com RECEIVED DEC 2 92004 December 28, 2004 Alaska Oil & Gas Cons. Commission Anchorage Alaska Oil and Gas Conservation Commission 333 West yth Avenue Suite 100 Anchorage, Alaska 99501 (907) 279-1433 Re: Application for Permit to Drill, Rotary Sidetrack, Producer 1B-15A Dear Commissioner: ConocoPhillips Alaska, Inc. hereby applies for a Permit to Drill/Sidetrack an onshore Producer well, KRU 1 B-15A, a development well. It is planned to abandon the original wellbore then set a CIPB at 4423' MD and place a permanent whipstock on top of the CIBP with the whipstock at 4400' MD. We will then cut and mill a window in the existing 7" production casing with a planned KOP point from the 7" casing is +/- 4400' MD. The existing 7.0" casing cement job from the original wellbore did not bring the top of cement up as high as the window. The current plan is to mill the window and perform a FIT tesV Leak off, which ever comes first, with a required minimum of 12.5 ppg EMW. ** If the FIT/LOT is too low, a squeeze cement job will be performed placing cement on top of the whipstock and in the milled window and a second FIT/LOT will be performed. After a successful FIT/LOT test the intermediate section will be drilled with a 4-3/4" pilot bit and a 7.0" hole opener down through the Kuparuk C sand and stop to top set above the Kuparuk A sand at approximately 8375' MD/6350 TVD for a planned top set. A LOT/FIT test will be performed to 15.0 ppg EMW to test the 5.5" shoe and then drill out using 2-7/8" DP and a 4- 3/4" bit. The mud weight will be a minimum of 11.8 ppg MW at drill out increasing the mud weight as the hole dictates the need up to an anticipated maximum of 12.4 ppg at total depth of 8737' MD/6443' TVD. Then run a 3- 1/2" short liner from total depth up above the top of the Kuparuk C sand hanging off inside the 5.5" flush joint liner. The logging program will consist of a Triple Combo: Gamma Ray/ Resistivity/ Density/ Neutron for the / intermediate hole and a Gamma Ray/ Resistivity production hole of this well. The spud date is expected to be approximately 01-27-2005 If you have any questions or require any further information, please contact Jake Flora at 265-6040. Sincerely, --~-,..~ ~ Randy ThO~ GKA Drilling Team Leader .-. . k RECEIVED lj S DEC 2 9 2004 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 1a. Type of Work: Driltif Re-entrI] / Redril~pJ1b. Current Well Class: t:~'1 Stratigraphic Test 0 20 MC 25.005 2. Operator Name: ConocoPhillips Alaska, Inc. 3. Address: ExploratorU ServicD 5. Bond: l.:d Blanket U Bond No. 59-52-180 6. Proposed Depth: MD: 8737' .' DeVelO~iI,,~¡¡ & Gd:¡ C,mí,Jf¡g~Î(m Development GO Am:hon~ge Single Z0 Single We 11. Well Name and Number: 1B-15A 12. Field/Pool(s): Kuparuk River Field P.O. Box 100360 Anchorage, AK 99510-0360 4a. Location of Well (Governmental Section): Surface: 500' FNL, 484' FEL, Sec. 9, T11 N, R10E, UM . Top of Productive Horizon: 2919' FNL, 3379' FEL, Sec. 9, T11 N, R10E, UM Total Depth: 2975'FNL, 3455'FEL, Sec. 9, T11N, R10E,UM 4b. Location of Well (State Base Plane Coordinates): TVD: 6687' 7. Property Designation: ADL 25648 8. Land Use Permit: Kuparuk Oil Pool . 13. Approximate Spud Date: 1/27/2005 ALK 466 9. Acres in Property: 2560 14. Distance to Nearest Property: 2305' 10. KB Elevation 15. Distance to Nearest Surface: x- 549955 16. Deviated wells: Kickoff depth: 4400' 18. Casing Program Size y- 5969647 Zone- 4 (HeightaboveGL): 55.7' AMSL Well within Pool: 1B-01, 495' @ 521' 17. Maximum Anticipated Pressures in psig (see 20 Me 25.035) ft. Maximum Hole Angle: 68° Downhole: 3995 psig Surface: 3285 psig Setting Depth Quantity of Cement Specifications Top Bottom c. f. or sacks Grade Coupling Length MD TVD MD TVD (including stage data) L-80 Hydril 511 4125' 4250' 8375' 6350' .~'S."f. ~,~, }96 sx Class G L-80 Hydril 511 539' 8198' 8737' 6687' 49 sx Class G Hole Casing Weight 7" 5.5" 15.5# 4.5" 3.5" 9.3# 19 Total Depth MD (ft): PRESENT WELL CONDITION SUMMARY Total Depth TVD (ft): Plugs (measured) 6949' 7450' Casing Structural Conductor Surface Intermediate Production 6620' 7" 350 sx Class G 6660' 6268' Liner 5" 7432' 6933' Perforation Depth MD (ft): I Perforation Depth TVD (ft): 6754'-6794', 6799'-6807', 6812'-6814', 6870'-6888', 7119'-7159' 6348'-6383', 6387'-6394', 6398'-6400', 6448'-6464', 6663'-6698' 20. Attachments: Filing Fee 0 BOP Sket<O Drilling Progr<0 Time v. Depth 0 Shallow Hazard Analo Property Plat 0 Diverter SketeD Seabed RepeD Drilling Fluid Progr0 20 MC 25.050 requirem0 Length Size 80' 16" 4149' 9-5/8" (To be completed for Redrill and Re-Entry Operations) I Effective Depth MD (ft): Effective Depth TVD (ft): Junk (measured) 6819' Cement Volume MD TVD 200 sx AS I 121 ' 4190' 121' 4139' 900 sx AS III, 400 sx Class G 21. Verbal Approval: Commission Representative: 22. I hereby certify that the foregoing is true and correct to the best of my knowledge. Printed Name Date: Signature Randy Thomas ~.~\~ Contact Jake Flora @ 265-6040 Title Greater Kuparuk Area Drilling Team Leader Phone "Z. 6 . _. ~ Date \ z... íli (0'1 . } b-6 $0 Preoared bv Sharon AllsuD-Drake ~ Other: ' Commission Use Only Permit to Drill I API Number: . I Permit Approval . / Number: ð û Y - ð S- G 50- Cà" - ~J L{ <OS -0 \ Date: 1/ /?/ tJ~ Conditions of approval: S les required 0 Yes ~NO Mud log required 0 Yes ~ No ydr gen sulfide measures ~Yes 0 ~o Directional survey required ~ Yes 0 ~ , ~~~.\-O-C;~\.Q~\"C~, \ ~'1 ~~\ß\\~~\\J"~.\ ~~\'\)\'~ ~ \\.~G\- ~ AD ~:EO~~::~:'ON -tfj1/j/,;ç . í\ r GIN A L sult i~~uPlicate I See cover letter for other requirements . Drilling Hazards Intermediate Hole Interval Drillina Hazards High ECD and swabbing with Low higher MW's required Barite Sag Low Differential Sticking HIGH Abnormally LOW Reservoir Pressure HIGH Lost Circulation Moderate Production Interval Drillina Hazards High ECD and swabbing with Moderate higher MW's required Barite Sag HIGH Differential Sticking LOW Abnormal Reservoir Pressure Moderate Lost Circulation Low . 1 B-15A Sidetrack Doyon 14 Condition mud prior to trips. Monitor ECD's with PWD tool while drilling across pay interval. Pump and rotate out on trips as a last resort. Use Good drilling practices as documented in well plan and keep track of mud properties in line with mud program. Do not leave pipe static for extended period of time across the C sand. Proper drilling practices and keep connection time to minimum. The C sand should pressure is expected to be very low +/- 2350 psi. Increased mud weight ONLY as needed let hole dictate use well plan as guide. Keep it as light as possible. Reduced pump rates, Mud rheology, LCM. Use GKA LC decision tree as needed. Drill 7" hole (use hole opener to lower ECD's and help minimize lost circulation). Condition mud prior to trips. Pump and rotate out on trips as a last resort. Use good drilling practices. High if we top set. Use Good drilling practices as documented in well plan and keep track of mud properties in line with mud program. Do not leave pipe static for extended period of time. Proper drilling practices and keep connection time to minimum. Only for the A sand should pressure be higher. Stripping Drills, Shut-in Drills, Increased mud weight as needed let hole dictate use well plan as guide. Use PWD to monitor hole cleaning. Reduced pump rates, Mud rheology, LCM. Use GKA LC decision tree. Drills to be peñormed: · 'Stripping' drill should be held with rig crews prior to drill out, unless each crew on tour has completed this drill within the past 3 months. Document drill and record on morning report. · A Well Kill' drill - prior to drill out, unless each crew on tour has completed this within the past 3 months. Document drill and record on morning report. · A well kill sheet shall be posted in the doghouse and updated each tour. . . Application for Permit to Drill, Well 1 B-15A Revision No.O Saved: 14-Dec-04 Permit It - Kuparuk Well 1 B-15A Application for Permit to Drill Document MoximizlÔ Well Value Table of Contents 1. Well Name .. ....... ........................ ......... ........ ...... ....... ...... ........................... ..... ........... 2 Requirements of 20 AAC 25.005 (f)........................................... ........ .................. ...................... ............. 2 2. Location Summary ............................... ............ ...... ... ....................... ........ ....... ........ 2 Requirements of 20 AAC 25. 005( c)(2) ................................................................................................... 2 Requirements of 20 AAC 25. 050(b)........................................................................................................ 2 3. Blowout Prevention Equipment Information ......................................................... 3 Requirements of 20 AAC 25.005(c)(3) ................................................................................................... 3 4. Drill i n9 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. Dri II i ng FI u id Program......................... ............. ............... ..... .............................. ..... 4 Requirements of 20 AAC 25.005(c)(B) .... ......... ...................................................................................... 4 9. Abnormally Pressured Formation Information ..................................................... 5 Requirements of 20 AAC 25.005 (c)(9) ..................................................................................................5 10. 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 ............................................................................................... 5 Requirements of 20 AAC 25.005 (c)(12) ................................................................................................ 5 13. Proposed Drilling Program ..................................................................................... 6 Requirements of 20 AAC 25.005 (c)(13) ................................................... ............... .............................. 6 14. Discussion of Mud and Cuttings Disposal and Annular Disposal...................... 8 ORIGINAL 1B-15A PERMIT IT. DOC Page 1 of 6 . . Application for Permit to Drill, Well1B-15A Revision No.O Saved: 14-Dec-04 Requirements of 20 AAC 25.005 (c)(14) ................................................................................................ 8 15. Attachments ........ ....... .......... .............................. ...... .......... ........... .................... ....... 8 Attachment 1 Directional Plan................................................................... ..........................6 Attachment 2 Well Schemaics........................................................................................... ..6 1. Well Name Requirements of 20 AAC 25.005 (f) Each well must be identified by a unique name designated by the operator and a unique API number assigned by the commission under 20 AAC 25<040(b). For a well with mu/tiple welf branches, each branch must similal1y 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 wel! by the commission. The well for which this application is submitted will be designated as 1 B-15A. 2. Location Summary Requirements of 20 AAC 25.005(c)(2) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (2) a plat identifying the property and the property's owners and showing (A)the coordinates of the proposed location of the well at the surface, at the top of each objective formation, and at total depth, referenced to governmental section lines. (B) the coordinates of the proposed location of the well at the surface, referenced to the state plane coordinate system for this state as maintained by the National Geodetic SUlVey in the National Oceanic and Atmospheric Administration; (C) the proposed depth of the well at the top of eacl) objective formation and at total depth; Location at Surface I 499' FNL, 485' FEL, Sec 9, T11 N, R10E, UM NGS Coordinates I RKB Elevation I Northings: 5,969,647 ,f Eastings: 549,954 . Pad Elevation Location at Top of Productive Interval (Kuparuk A-4 Sand) NGS Coordinates Northings: 5,967,209 2919' FNL, 3379' FEL, Sec 9, T11N, R10E, UM Eastings: 547,082 Measured Depth, RKB: Total Vertical Depth, RKB: Total Vertical Depth, SS: Location at Total Depth 12975' FNL, 3455' FEL, NGS Coordinates Northings: 5,967,152 Eastings: 547,006 Sec 9, T11 N, R1OE, UM Measured Depth, RKB: Total Vertical Depth, RKB: Total Vertical Depth, SS: and (D) other information required by 20 AAC 25.050(b); 55.7' AMSL 27.7' AMSL 8476 6443 6341 8737' 6687' 6585' «" Requirements of 20 AAC 25.050(b) If a welf is to be intentionally deviated, the application for a Permit to Drill (Form 10-401) must (1) include a plat, drawn to a suitable scale, showing the path of the proposed wellbore, including alf adjacent welfbores wittJin 200 feet of any portion of the proposed well; Please see Attachment 2: Directional Plan And (2) for all wells within 200 feet of the proposed weifbore IA) list the names of the operators of those weifs, to the extent that those names are known or discoverable in pubHc records. and show that each named operator has been fumished 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. ORIGINAL 1B-15A PERMIT IT. DOC Page 2 of 6 ·. . Application for Permit to Drill, Well1B-15A Revision No.O Saved: 14-Dec-04 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 lor an item already on fìle with the commission and identified in the application: (3) a diagram and description of the blowout prevention equipment (SOPE) as required by 20 AAC 25.035, 20 AAC 25.036, or 20 AAC 25.037, as applicable; Please reference BOP schematics on file for Doyon 14. 4. Drilling Hazards Information Requirements of 20 AAC 25.005 (c)(4) An application for a Permit to Drìf! must be accompanied by each of the following items, except for an item already on fìle with the commission and identified in the applícation: (4) information on drilling hazards, including (A) the maximum downhole pressure that may be encountered, criteria used to determine it, and maximum potential surface pressure based on a methane gradient; BHP data on offset injectors indicates that the current reservoir pressure for 1 B-15A is :S 4000 psi at 6443' TVD, 0.62 psi/ft or 11.9 ppg EMW. ,/ The maximum potential surface pressure (MPSP) while drilling 1 B-15A is calculated using above maximum reservoir pressure, a gas gradient of 0.11 psi/ft, and the Kuparuk A sand target at 6443' TVD: MPSP = (6443 ft)*(0.62 - 0.11 psi/ft) = 3285 psi v"- (8) data on potential gas zones; KOP is Colville Group right below the base of the West Sak, between the base of the West Sak and the K-10 marker mudstones. And (C) data concerning potential causes of hole problems such as abnormallv geo-pressured strata, lost circulation zones, and zones that have a propensity for differential sticking: 1. Attaining LOT/FIT of at least 12.5 ppg at window. 2. Mud losses in the C sand due to low reservoir pressure, could also have problems while tripping and running the liner with differential sticking. 5. Procedure for Conducting Formation Integrity Tests Requirements of 20 AAC 25.005 (c)(5) An app!ícation for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (5) a description of the procedure for conducting formation integrity tests, as required under 20 AAC 25.030(f): A procedure is on file with the commission for performing LOT's. For 1 B-15A the procedure will be followed after milling the window, with one exception. The formation at the wiindow depth will be pressured until leak-off occurs or to 15.0 ppg EMW is reached, which ever comes first. ORIGINAL 1B-15A PERMIT IT DOC Page 3 of 6 . . Application for Permit to Drill, Well1B-15A Revision No.O Saved: 28-Dec-04 6. Casing and Cementing Program Requirements of 20 AAC 25.005(c)(6) An application for a Permit to Dríll must be accompanied by each of the following items, except for an item already on me 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 I I Hole Top Btm CsgfTbg Size I Weight I I I Length I MD/TVD MD/TVD 00 (in) (in) (Ib/ft) Grade Connection (ft) (ft) (ft) Cement Program Oringial Wellbore 1 B-15 9-5/8" 12-1/4 40 L-80 surface 4190/4139 7" 8-1/2 26 L-80 BTC- surface 6660'/6268 Original TOC = 5900' MD Mod 5.0" liner 8-1/2" 18.0 L-80 EUE 8 6660 7432/6933 RD 3-1/2 8-1/2" 9.3 L-80 8RD 6676 7432 Packer/PBR wI wireline entry Tubing EUE guide stung below the Baker FB-1 MOD 1B-15A Sidetrack Plan Window 8-1/2" 26 L-80 BTC- 4400'1 4420' Squeeeze shoe if insufficient LOT In the 7" Mod Casing 5.5" flush 7" 15.5# L-80 Hydril 4125' 4250' MD 8375'/6350' 390 sx 15.8 Class G, 1.17 ft;;/sk jt 511 (TOC 150' above top of liner) 3-1/2" 4.75" 9.3# L-80 Hydril 539' 8198' MD 8737'/6686' 49 sx 15.8 Class G, 1.17 fe/sk liner 511 (TOC 150' above top of C sand) (TOL 50' MD above C sand top) 3-1/2 4.75" 9.3# L-80 8RD surface 8198' MD Packer/PBR wI wireline entry Tubing EUE guide stung below the ZXP MOD 7. Diverter System Information Requirements of 20 AAC 25.005(c)(7) An application for a Permit to Drill must be accompanied by each of the following items. except for an item already on file with the commission and identified in the application: (7) a diagram and description of the diverter system as required by 20 AAC 25.035, uniess this requirement is waived by the commission under 20 AAC 25.035(h)(2): This rotary sidetrack will exit pre-existing casing at ± 4400' MD. BOPE will be installed prior to exiting the casing, and therefore, no diverter is required. 8. Drilling Fluid Program Requirements of 20 AAC 25.005(c)(8) An application for a Permit to Drm must be accompanied by each of the following items, except for an item aiready on file with the commission and identified in the appiication: (8) a drilling fluid program, including a diagram and description of the driliing fluid system, as required by 20 AAC 25.033; ORIGINAL 1B-15A PERMIT IT.DOC Page 4 of 6 . . Application for Permit to Drill, Well 1 B-15A Revision No.O Saved: 14-Dec-04 Drilling will be done using a LSND mud systems having the following properties: Sidetrack Hole mud :>roperties Initial Drillout Top Set Depth KOP 8375' MDI 6350'TVD Depth MD/ TVD 4400 MD 8248 MD Density (ppg) 9.2 10.2 Funnel Viscosity (seconds) 44-55 44-55 Yield Point 11-15 11-15 (cP) Plastic Viscostiy (lb/100 sf) 6-12 6-12 10 second Gel Strength 2-5 2-5 (1b/1 00 sf) 10 minute Gel Strength 2-5 2-5 (1b/1 00 sf) pH 9.0 - 9.5 9.0 - 9.5 API Filtrate(cc) <6 <6 Solids (%) 6-11 6-11 Diagram of Doyon 14 Mud System on file with AOGCC. 4-314" hole Top Kuparuk A Target TO 8476 MDI 6443' TVD 11.8 42-58 20-25 8737 MDI 6687' TVD 12.0- 12.4 / 42 - 58 20-25 15 - 25 4-8 8-16 9.0 - 9.5 <4 15-19 15 - 25 4-8 8-16 9.0 - 9.5 <4 15-19 Drilling fluid practices will be in accordance with appropriate regulations stated in 20 AAC 25.033. 9. Abnormally Pressured Formation Information Requirements of 20 AAC 25.005 (c)(9) An application for a Permit to Drill must be accompanieä by each of the following items, except for an item alreaäy on file with the commission anä identified in the application: (9) for an exploratory or stratigraphic test weil, a tt.bulation setting out the depths of predicted abnormally geo-pressured strata as required by 20 AAC 25.033(f); N/A - Application is not for an exploratory or stratigraphic test well. 10. Seismic Analysis Requirements of 20 AAC 25.005 (c)(10) An appíication for a Permit to Driii must be accompanied by each of the foHowing items, except for an item already on fife with the commission and identified in the application: (10) for an exploratory or stratigraphic test well, a seismic refraction or reflection analysis as required by 20 AAC 25.061 (a); N/A - Application is not for an exploratory or stratigraphic test well. 11. Seabed Condition Analysis Requirements of 20 AAC 25.005 (c)(11) An application for a Permit to Dri!! must be accompanied by each of the following items, except for an item already on fiie with the commission and identified in the application: (11) for a well drílled from an offshore platform. mobile bottom-founded structure, Jack-up rig, or floating drilling vessei, an anaiysis of seabed conditions as required by 20 AAC 25. 061 (b); N/A - Application is not for an offshore well. 12. Evidence of Bonding Requirements of 20 AAC 25.005 (c)(12) An application for a Permit to Driil must be accompanied by each of the foilowÜ¡g 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 ConocoPhillips Alaska, Inc. is on file with the Commission. ORIGINAL 1B-15A PERMIT IT. DOC Page 5 of 6 . . Application for Permit to Drill, Well1B-15A Revision No.O Saved: 21-Dec-Q4 13. Proposed Drilling Program Requirements of 20 AAC 25.005 (c)(13) An application for a Permit to Orm must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: Pre-Rig Well Work: NOTE: test IA +/- 2 weeks prior to rig moving - Wells to supervise that work h\ ~'^ 7>0 1. Notify the AOGCC field inspector 24 hours prior to commencing pre-rig work. 2. RU CTU RIH with Inflatable bridge plug and set at 6700' MD with the top perforations at 6754'. 3. Squeeze off perforations. Pull above and lay in 50' of cement above plug. 4. Wait 24hrs..... RU Slickline and tag cement plug, pull OV, load IA and tubing with seawater. 5. CMIT against cement plug. (AOGCC present as witness) 6. Freeze protect well with diesel to 2500' MD. 6. RU E-line and chemical cut tubing at 6600' (below bottom GLM) 7. Set BPV and VR plug. t Current Wellhead: FMC Gen IV, 11"x 3K, 7-1/16" x 5K t 1. Æ~~ ~- >< ~ 2. ~> Rig Work: Take on 8.8 ppg Brine in Brine pits. Pull BPV. RU on tree and circulate 8.8 ppg Brine. Circ through the choke until clean brine returns are observed at the surface. Run and set BPV. Notify the AOGCC field inspector 24 hours before prior to spud and BOP test. MIIRU Doyon 14. Install blanking plug on top of the back pressure valve. 3. NU and test the 11"x 5K" BOPE to 250# /3500# (**FMC will have double stud adapter). 4. Engage the 3-1/2" tubing with a spear. UD the tubing hanger and pull all 3-1/2" tubing. 5. Set storm packer. '"\~C>-i ~Oy ~~,~x\~~ 6. N/D BOP's. Remove FMC Gen IV tubing head and replace it with a 11 "x 3M x 11 "x 5M spool. O~~~ 7. NU Bop's to the 11", 5000 psi flange on the FMC Gen IV system & test 250 psi & 5000 psi. 8. PU mill, casing scraper, and 4" DP (type TBD) and RIH to +/- 4500' MD. C&C. POOH. 9. RU wireline set a CIBP inside the 7" casing at +/- 4423' MD based on casing collar depth. (Note: CIBP must be ~ 2.0' above a casing collar and ~ 20' below a casing collar) POOH, RD SWS. Test 7" casing and CIBP to 3000 psi and hold for 15 min. Test okay. POOH with wireline. (If not contact Engineer- discuss will have to get packer and RIH and attempt to find hole in casing.) 10. PU and RIH with Baker's "WindowMaster' whipstock system & window mill, bottom trip anchor, MWD, and UBHO on drill pipe from the derrick. Whipstock to be set on top of CIBP set at 4423' MD. 11. Orient whipstock 25 degrees Right of high side, shear off, and POOH. 12. Displace 8.8 ppg Brine from hole with 9.2 ppg LSND new mud to mill window. Mill window and drill 20' new formation. Dress window. Pump super sweep pill. 13. Perform FIT/LOT to 12.5 ppg EMW. POOH and LD window mill etc. \ '--\ ~ Q i \?i)Q \-c;-\-- <t)~ ,'\. ~~ A- ~'::.<c 0Qe:~-\~\ 14. PU Intermediate bit & hole opener, BHA, 4.0" DP, and RIH. 15. Drill the Intermediate hole section to just below C sand +/- 8375' MD/6350' TVD for top set depth. The MW should be approximately 10.0-10.2 ppg at the top set. O.,. ¡' R ''"'0· f N A L .ßP~\~ II· 1B-15A PERMIT IT. DOC Page 6 of 6 . . Application for Permit to Drill, WeIl1B-15A Revision No.O Saved: 14-Dec-04 16. POOH run 5.5" flush joint liner and tie back 150' inside the 7" window (The required overlap is ~ 150': TOL = 4250' MD). 17. Reciprocate the liner while circulating and cementing. R/U Dowell and prepare to cement the liner. Cement the liner bringing cement on top of the liner. 18. Release from liner. Set CPH packer. 19. POOH. LD/DP. 20. Change rams in BOP to 2-7/8 x 5" VBR's and test to 250 psi and 5000 psi. 21. PU 2-7/8" DP, 4-3/4" bit, BHA. 22. TIH. Tag cmt. Drill out and perform an FIT/LOT to 15.0 ppg EMW. If FIT/LOT is sufficient drill ahead. 23. Using 11.8 ppg LSND, drill ahead through the A sand interval. Increase MW only as needed to TD to handle cuttings and possible gas. 24. Continue drilling into the Miluveach Shale to give ± 200' of rat hole below the base of the Kuparuk A. The proposed TD is ± 8737' MD, 6443' TVD. At TD, circulate bottoms and make a wiper trip. 25. RU to run a 3.5" hydril 511 liner from TD up to 50' above the estimated top of C sand (as per Geologist pick). Reciprocate the liner while circulating and cementing. R/U Dowell and cement 3-1/2" hydril511 liner. 26. Release from liner. Set ZXP or equivalent packer. 27. Displace the well above the TOL with seawater until the returns are clean. Check for flow. POOH. LD/DP. 28. Set storm packer and change out the 11"x3 by 7-1/16" x 5M spool and then re-run the tbg head. 29. R/U and RIH with the 3-1/2" tubing tag the TOL. Space out and land. RILDs. Test tubing, PBR and liner to 3500 psi with the IA open. Bleed the tubing down to 2000 psi. Test the lA, PBR and TOL to 3500 psi. Bleed off all pressures. 30. Install a TWC. ND BOPE. NU and test the 3-1/8" (5M) tree to 5000 psi with the IA open. Pull the TWC. Pressure up the IA to ± 2500 psi and shear the "RP" valve. Displace the well with diesel freeze protect fluid through the "RP" valve (114 bbl). Install a BPV. R/D and M/O Doyon Rig 14. Post-Rig Well Work: 1. Pull the BPV. R/U SLU. Drift and tag to PBTD. 2. Dummy-off the GLM. R/D SLU. 3. R/U E-Line. Run cement bond log inside the liner. 4. Perforate the Kuparuk as directed. R/D E-Line. 5. Install new "S" riser and replace the well house(s). OR'G\NAL 1 ß-15A PERMIT IT. DOC Page 70f6 . . Application for Permit to Drill, Well1B-15A Revision No.O Saved: 14-Dec-04 14. Discussion of Mud and Cuttings Disposal and Annular Disposal Requirements of 20 AAC 25.005 (c)(14) An application for a Permit to Drill mustc be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (14) a geneml 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.: Doyon rig 14 has a rock washer. There is no ultra-sonic processor or ball mill. The liquid waste fluids generated during the drilling process will be taken to one of the KRU's Class II disposal wells, and the solids will go to 05-4 in Prudhoe (G&I facility). 15. Attachments : Attachment 1 Directional Plan Attachment 2 Well Schematic ORIGINAL 1B-15A PERMIT IT. DOC Page 8 of 6 1B-15A PROPOSED SID.CK Producer COMPLETION -n n u U ~ I i i d n n Ii n 111 9-S/8" L80 casing i @4190' MD 14139 ~ TVD ~ ~ ~ ~ ~ ~ ~ i I i d 5.5" X 7" Liner Top I ~- 4250' MD 14250' TVD i ~ i ~ ~ ~ ~ ~ ~ J ~ J ~ ~ ~ J ~ ~ ~ ~ ~ ~ i ~ I Baker "K-1" CIBP @ ~ ~ +1- 4423' MD ~...L:._!I"""··-.~ ! ~ ~ ~ I i ~ I ~ '- ~ I ~ ~ ~ ~ ~ ~ ~ I l ~ 3-Yz" tbg cut and pulled i ~ l 7 from +1- 50' above the i i packer 1 -..'\/ I ~ - ~ ~ I i ~ ~ \=1 -- Sidetrack KOP @ ,/ +1- 4400' MD, +1- 4320 TVD Original Wellbore 7" 26# L-80 shoe at 6660' MOl 6268' TVD P&A cmt plug Original Wellbore 5.0" liner 18.0# L-80 7432' M D - 6933' TVD n ~ I n n n n n ~ s n n n I S U ~ I n ~ s I S I ~ ~... -- ~ IIIIIIII!IIIIII ~ ~ ~ ~ ~ .. ~ ~ ~ ~ ~ ~ I ~ , I - l -J ~ ~ --=1 ~ ~ ~ ~ ~ j Co£C~hillips 3-1/2" 5M FMC Gen IV tubing hanger with 3-1/2" L-80 EUE 8rd pin down SPECIAL DRIFT TO 2.91" 3-1/2",9.3#, L-80 EUE 8rd tubing to surface SPECIAL DRIFT TO 2.91" 3-1/2" Camco 'DS'landing nipple with 2.875" 10 No-Go profile set at +1-500' MD 3-1/2" 9.3# L-80 EUE 8rd Mod tubing to GLM 3-1/2" 9.3# L-80 EUE 8rd Mod tubing as necessary Planned Gas Lift Mandrels 3 %" x 1" Cameo 'KBG-2-9' mandrels 3 W x 6' L-80 handling pups installed above & below. EUE 8RD Mod Place gas-lift mandrels at the following planned depths- adjust accordingly at TD TVD MD GL Valve 2600 2601 1.00 3925 3953 1.00 4900 5493 1.00 5615 7447 1.00 6115 8138 1.00 1 2 3 4 5 3-%" tbg will tie into the 4"x5-%" ZXP liner Hanger packer Intermediate Hole Logging - Triple Combo 5-%" x 7"" LINER ASSEMBLY 5-1/2" X 7" CPH Liner Hanger Packer 5-1/2" X 7" HMC Hydraulic Liner Hanger 5-%" Hydril 511 Liner as needed 5-Yz" Landing Collar One Joint 5-%" Hydril511 Casing 5-%" Float Collar Two Joints 5-%" Hydril 511 Casing 5- Yz" Float Shoe Kup C Sand 8248' MD/6232' TVD Estimated BHP < 3000 psi TOP SET DEPTH 6247' TVDSSI 8375' MDI 6350' TVD Kup A sand Target 8476' MD/6443' TVD Estimated BHP +1- 4000 psi .. 3 Yz" Cameo 'DS' nipple wI 2.81 " No-Go profile, handling pups installed top and bottom Bullet Seal Stem with 4-1/8" OD seals 3-112" LINER ASSEMBLY **4" X S-1/2" ZXP Liner Hanger Packer wI HR Profile and 4-118" ID TieBack Sleeve w/1S' stroke 3-1/2" X 5-1/2" HMC Liner Hanger 3-%" Hydril 511 Liner as needed 2.75" 10 Seal Bore 3-%" Landing Collar One Joint 3-Yz" Tubing 3- Yz" Float Collar Two Joints 3-%" 3-Yz" Float Shoe "Balded Item has to be ordered minimum 2 weeks prior Production Hole Logging - Gamma Rayl Resitivity TD @ 8737' MD I 6687' TVD .r Drawn by MDK 11/1/04 ORIGINAL v . . ConocoPhillips Alaska Inc. (Kuparuk) Kuparuk River Unit Kuparuk 18 Pad 1 B-15 1 B-15A eonocÓPhUlips Plan: Plan: 1 B-15A (wp03) Standard Planning Report 11 November, 2004 ORIGINAL Uli Kuparuk Calculation Method: Minimum Curvature Error System: ISCWSA Scan Method: Elliptical Conic Error Surface: Rules Based Warning Method: Trav. Cylinder North o l.() :::!. -1125 -±. -£ o Z -1350 ";- £' :::¡ o (f) -1575 0- -225-----~ -450~~ -675 -900- -1800 -2025 -2475-~- I I I I -2700 I I I ) , ( I " -2925 -1350 , I, -1125 ¡ I I I I I I I , I ' -675 , , I I I I I , -2250 ( I I ' -2025 I !! I!! -1800 I I I' -1575 I I ¡ I I I -900 West(-)/East(+) (450 ftlin) Conoc;Pt,illips Engineering Kuparuk Calculation Method: Minimum Curvature Error System: ISCWSA Scan Method: Trav. Cylinder North Error Surface: Elliptical Conic Warning Method: Rules Based o o o ~ 5000 ëB ~ ~ 6500 () :;:¡ ~ 7000 9000 1 I I I I I I I -1500 -1000 I I I -500 I I I I I I I I I 1 I { ! ! ! ¡ I ! t ¡! ! I ! ¡ I I I I I I I I [ " 4500 I I [ 5000 I [ [ 2000 2500 3000 3500 4000 SECTION DET AU . Co~illips . SPERRY_SUN HES Planning Report EDM 2003.11 Single User Db ConocoPhillips Alaska Inc. (Kuparuk) Kuparuk River Unit Kuparuk 1 B Pad 1B-15 1B-15A Plan: 1B-15A (wp03) We1l1B-15 1B-15 @ 102.0000 (1B-15) 1 B-15 @ 102.0000 (1B-15) True Minimum Curvature Projeçt Kuparuk River Unit, North Slope Alaska, United States Map System: Geo Datum: Map Zone: US State Plane 1927 (Exact solution) NAD 1927 (NADCON CONUS) Alaska Zone 04 System Datum: Mean Sea Level Using Well Reference Point Using geodetic scale factor Site Kuparuk 1 B Pad 0.000 I! Northing: Easting: Slot Radius: 5,969,646.7201! 549,457.400 I! 0" Latitude: Longitude: Grid Convergence: 70019' 40.290" N 1490 35' 56.056" W 0.380 Site Position: From: Position Uncertainty: Map -~-~ ~--~- Well 1B-15 Position Uncertainty 0.000 I! 0.000 I! 0.000 I! Northing: Easting: Wellhead Elevation: 5,969.647.64û I! 549,954.370 I! I! , Latitude: Longitude: Ground Level: 70019'40.266" N 149035' 41.547" W 0.000 I! Well Position +N/-S +E/-W ~-~--~ Wellbore 1B-15A Magnetics Model Name sample Date BGGM2004 1 0/28/2004 24.56 80.76 57,578 ~~-- Design Audit Notes: Version: Plan: 1 B-15A (wp03) Phase: PLAN Tie On Depth: 4,400.000 Vertical Section: +N/-S 1ft) 0.000 230.129 -~~. Plan Sections MeasUred Depth 1ft) 4,400.000 30.029 218.213 4,320.858 -389.585 -270.544 0.00 0.00 0.00 0.00 4,412.476 31 .900 218.210 4,331.556 -394.629 -274.515 15.00 15.00 -0.02 359.96 4,429.996 31 .900 218.210 4,346.430 -401 .903 -280.241 0.00 0.00 0.00 0.00 5,183.821 68.000 233.200 4,824.996 -781.534 -698.461 5.00 4.79 1.99 23.09 7,383.821 68.000 233.200 5,649.130 -2,003.425 -2,331.797 0.00 0.00 0.00 0.00 8,321.597 21.111 233.286 6,298.870 -2,386.429 -2,844.215 5.00 -5.00 0.01 179.96 8,476.097 21.111 233.286 6,443.000 -2,419.696 -2,888.824 0.00 0.00 0.00 0.00 1B-15A Tgt 1 8,737.652 21.111 233.286 6,687.000 -2,476.015 -2,964.342 0.00 0.00 0.00 0.00 11/11/2004 1:02:07PM Page 2 of 5 COMPASS 2003.11 Build 41 OR\G\~tAL- . eonocòPhillips . SPERRY_SUN HES Planning Report Oatabase: Company: Project: Site: Well: Wellbore: Design: EDM 2003.11 Single User Db ConocoPhillips Alaska Inc. (Kuparuk) Kuparuk River Unit Kuparuk 1 B Pad 1B-15 1B-15A Plan: 1 B-15A (wp03) We1l1B-15 1 B-15 @ 102.000ft (1B-15) 1 B-15 @ 102.000ft (1B-15) True Minimum Curvature 200.000 0.245 282.41 0 200.000 0.045 -0.204 0.128 0.00 0.00 0.00 300.000 0.495 282.41 0 299.998 0.184 -0.835 0.523 0.25 0.25 0.00 400.000 0.744 282.410 399.992 0.416 -1.890 1.184 0.25 0.25 0.00 500.000 0.989 265.168 499.980 0.665 -3.376 2.164 0.35 0.24 -17.24 600.000 1.641 231.098 599.955 -0.307 -5.350 4.303 0.99 0.65 -34.07 700.000 2.060 220.407 699.896 -2.757 -7.733 7.703 0.54 0.42 -10.69 800.000 2.036 214.386 799.832 -5.591 -9.901 11.184 0.22 -0.02 -6.02 900.000 2.034 208.287 899.769 -8.620 -11.746 14.540 0.22 0.00 -6.10 1,000.000 2.056 202.249 999.706 -11.842 -13.266 17773 0.22 0.02 -6.04 1,100.000 1.947 202.202 1,099.644 -15.099 -14.570 20.862 0.11 -0.11 -0.05 1,200.000 1.818 203.156 1,199.590 -18.131 -15.836 23.777 0.13 -0.13 0.95 1 ,300.000 1.690 204.256 1,299.543 -20.934 -17066 26.517 0.13 -0.13 1.10 1,400.000 1.577 204.575 1,399.503 -23.510 -18.257 29.083 0.11 -0.11 0.32 1,500.000 1.565 199.195 1,499.465 -26.052 -19.278 31.496 0.15 -0.01 -5.38 1,600.000 1.567 193.781 1 ,599.428 -28.670 -20.053 33.770 0.15 0.00 -5.41 1,700.000 1.583 188.430 1,699.390 -31.365 -20.581 35.903 0.15 0.02 -5.35 1,800.000 1.621 185.254 1,799.351 -34.138 -20.882 37.912 0.10 0.04 -3.18 1,900.000 1.674 185.338 1,899.310 -37001 -21.148 39.950 0.05 0.05 0.08 2,000.000 1.727 185.416 1,999.266 -39.956 -21.426 42.058 0.05 0.05 0.08 2,100.000 1.781 185.490 2,099.219 -43.003 -21.717 44.235 0.05 0.05 0.07 2,200.000 1.834 185.560 2,199.169 -46.142 -22.021 46.481 0.05 0.05 0.07 2,300.000 1.810 185.619 2,299.118 -49.327 -22.332 48.761 0.02 -0.02 0.06 2,400.000 1.754 185.678 2,399.070 -52.422 -22.638 50.980 0.06 -0.06 0.06 2,500.000 1698 185.741 2,499.024 -55.419 -22.938 53.131 0.06 -0.06 0.06 2,600.000 1.641 185.808 2,598.982 -58.317 -23.231 55.214 0.06 -0.06 0.07 2,700.000 1.518 183.064 2,698.944 -61.066 -23.449 57.144 0.14 -0.12 -2.74 2,800.000 1.398 179.767 2,798.911 -63.609 -23.514 58.824 0.15 -0.12 -3.30 2,900.000 1.283 175.865 2,898.884 -65.946 -23.429 60.256 0.15 -0.11 -3.90 3,000.000 1 .440 182.901 2,998.860 -68.133 -23.243 61.516 0.23 0.16 7.04 3.100.000 3.546 207.024 3,098.782 -71.740 -24.378 64.700 2.31 2.11 24.12 3,200.000 7.250 215.750 3,198.291 -79.928 -29.587 73.946 3.78 3.70 8.73 3,300.000 9.855 222.471 3,297.161 -91.540 -38.966 88.589 2.79 2.60 6.72 3,400.000 11 .953 224.372 3,395.317 -105.073 -52.422 107.591 2.13 2.10 1.90 3,500.000 13.172 218.449 3,492.881 -121.373 -67.071 129.284 1.77 1.22 -592 3,600.000 13.481 215.670 3,590.139 -140.164 -80.772 151.845 0.71 0.31 -2.78 3,700.000 14.001 216.494 3,687317 -159.243 -94.640 174.719 0.56 0.52 0.82 3,800.000 16.875 216.362 3,783.819 -180.261 -110.227 200.156 2.87 2.87 -0.13 3,900.000 20.417 214.650 3,878.553 -206.268 -128.825 231.102 3.58 3.54 -1.71 4,000.000 25.014 215.533 3,970.814 -237.813 -150.896 268.264 4.61 4.60 0.88 4,100.000 27.949 218.528 4,060.290 -273.413 -177.805 311.738 3.22 2.94 2.99 4,200.000 29.906 218.828 4,147.596 -311.424 -208.328 359.531 1.96 1.96 0.30 4,300.000 29.967 218.520 4,234.254 -350.385 -239512 408.441 0.17 0.06 -0.31 4,400.000 30.029 218.213 4,320.858 -389.585 -270.544 457.388 0.17 0.06 -0.31 Begin Dir @ 15.00DlS: 4400.010ft MD,4320.867ft TVD 4,412.476 31.900 218.210 4,331.556 -394.629 -274.515 463.668 15.00 15.00 -0.02 End Dir, Start Sail @31.900: 4412.480ft MD, 4331.559ft TVD 4,423.000 31.900 218.210 4,340.490 -398.998 -277.955 469.109 0.00 0.00 0.00 Begin Dir @O.OODLS: 4423.000ft MD,4340.490ft TVD 4,429.996 31.900 218.210 4,346.430 -401.903 -280.241 472. 727 0.00 0.00 0.00 4,500.000 35.143 220.594 4,404.785 -431.745 -304.800 510.706 5.00 4.63 3.41 4,600.000 39.843 223.401 4,484.111 -476.904 -345.565 570.942 5.00 4.70 2.81 4,700.000 44.598 225.703 4,558.149 -524.727 -392.734 637.801 5.00 4.76 2.30 4,800.000 49.393 227.645 4,626.337 -574.851 -445.947 710.774 5.00 4.79 1.94 11/11/2004 1:02:07PM Page 3 of 5 COMPASS 2003.11 Build 41 OR'GINAL . eonocJ'Phillips . SPERRY_SUN HES Planning Report EDM 2003.11 Single User Db ConocoPhillips Alaska Inc. (Kuparuk) Kuparuk River Unit Kuparuk 1 B Pad 1B-15 1B-15A Plan: 1B-15A (wp03) 4,900.000 54.215 229.326 4,688.156 -626.894 -504.800 789.306 5,000.000 59.059 230.814 4,743.134 -680.460 -568.844 872.798 5,100.000 63.917 232.157 4,790.855 -735.143 -637.592 960.617 5,183.821 68.000 233.200 4,824.996 -781.534 -698.461 1,037.073 End Dir, Start Sail @ 68.000: 5183.830ft MD, 4824.999ft lVD 5,200.000 68.000 233.200 4,831.056 -790.520 -710.473 1,052.052 5,300.000 68.000 233.200 4,868.517 -846.060 -784.716 1,144.637 5,400.000 68.000 233.200 4,905.978 -901.601 -858.958 1 ,237.223 5,500.000 68.000 233.200 4,943.438 -957.141 -933.201 1 ,329.808 5,600.000 68.000 233.200 4,980.899 -1,012.682 -1,007.443 1,422.393 5,700.000 68.000 233.200 5,018.360 -1,068.222 -1,081.686 1,514.978 5,800.000 68.000 233.200 5,055.820 -1,123.763 -1,155.928 1,607.563 5,900.000 68.000 233.200 5,093.281 -1,179.303 -1,230.171 1,700.149 6,000.000 68.000 233.200 5,130.742 -1 ,234.844 -1,304.413 1 ,792.734 6,100.000 68.000 233.200 5,168.202 -1,290.384 -1,378.656 1,885.319 6,200.000 68.000 233.200 5,205.663 -1 ,345.925 -1 ,452.898 1 ,977.904 6,300.000 68.000 233.200 5,243.124 -1 ,401 .465 -1,527.141 2,070.490 6,400.000 68.000 233.200 5,280.584 -1,457.006 -1,601.383 2,163.075 6,500.000 68.000 233.200 5,318.045 -1,512.546 -1,675.626 2,255.660 6,600.000 68.000 233.200 5,355.506 -1,568.087 -1,749.868 2,348.245 6,700.000 68.000 233.200 5,392.966 -1,623.627 -1,824.111 2,440.831 6,800.000 68.000 233.200 5,430.427 -1,679.168 -1,898.353 2,533.416 6,900.000 68.000 233.200 5,467.888 -1,734.708 -1 ,972.596 2,626.001 7,000.000 68.000 233.200 5,505.348 -1,790.249 -2,046.838 2,718.586 7,100.000 68.000 233.200 5,542.809 -1,845.789 -2,121.081 2,811.172 7,200.000 68.000 233.200 5,580.270 -1 ,901 .330 -2,195.323 2,903.757 7,300.000 68.000 233.200 5,617.730 -1 ,956.870 -2,269.566 2,996.342 7,383.821 68.000 233.200 5,649.130 -2,003.425 -2,331.797 3,073.948 Begin Dir @ S.OODLS: 7383.830ft MD,5649.134ft lVD 7,400.000 67.193 233.201 5,655.297 -2,012.385 -2,343.774 3,088.884 7,500.000 62.193 233.205 5,698.033 -2,066.517 -2,416.141 3,179.127 7,600.000 57.193 233.209 5,748.483 -2,118.207 -2,485.254 3,265.307 7,700.000 52.193 233.215 5,806.263 -2,167.061 -2,550.587 3,346.768 7,800.000 47.193 233.220 5,870.934 -2,212.707 -2,611.642 3,422.889 7,900.000 42.193 233.227 5,942.002 -2,254.799 -2,667.956 3,493.093 8,000.000 37.193 233.236 6,018.928 -2,293.015 -2,719.099 3,556.844 8,077.258 33.328 233.244 6,082.000 -2,319.702 -2,754.823 3,601.369 HRZlKalubik 8,100.000 32.193 233.246 6,101.125 -2,327.066 -2,764.683 3,613.657 8,141.919 30.095 233.252 6,137.000 -2,340.036 -2,782.052 3,635.303 Kalubik 8,200.000 27.193 233.260 6,187.968 -2,356.691 -2,804.360 3,663.100 8,248.980 24.742 233.269 6,232.000 -2,369.517 -2,821 .545 3,684.512 C4 8,300.000 22.193 233.280 6,278.797 -2,381.665 -2,837.828 3,704.797 8,321 .597 21.111 233.286 6,298.870 -2,386.429 -2,844.215 3,712.753 End Dir, Start Sail @21.111: 8321.600ft MD, 6298.872ft lVD 8,321.737 21.111 233.286 6,299.000 -2,386.459 -2,844.256 3,712.803 B 8,400.000 21.111 233.286 6,372.010 -2,403.311 -2,866.852 3,740.949 8,450.370 21.111 233.286 6,419.000 -2,414.157 -2,881 .396 3,759.064 AS 8,457.874 21.111 233.286 6,426.000 -2,415.772 -2,883.562 3,761.763 AS 8,476.097 21.111 233.286 6,443.000 -2,419.696 -2,888.824 3,768.316 Target (1) : 8476.100ft MD, 6443.003ft lVD, (2919ft FNL, 3379ft FEL, Sec9-T11N-R10E - A4 -1B-1SA Tgt 1 8,500.000 21.111 233.286 6,465.299 -2,424.843 -2,895.725 3,776.913 11/11/2004 1 :02:07PM Page 4 of 5 ORIGINAL 5.00 4.82 1.68 5.00 4.84 1.49 5.00 4.86 1.34 5.00 4.87 1.24 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 000 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 4.99 -4.99 0.00 5.00 -5.00 0.00 5.00 -5.00 0.00 5.00 -5.00 0.01 5.00 -5.00 0.01 5.00 -5.00 0.01 5.00 -5.00 0.01 5.00 -5.00 0.01 4.99 -4.99 0.01 5.00 -5.00 0.01 5.00 -5.00 0.01 5.00 -5.00 0.02 5.00 -5.00 0.02 5.01 -5.01 0.03 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 COMPASS 2003.11 Build 41 . . Conoc~illips SPERRY_SUN HES Planning Report EDM 2003.11 Single User Db ConocoPhillips Alaska Inc. (Kuparuk) Kuparuk River Unit Kuparuk 18 Pad 18-15 18-15A Plan: 1 8-15A (wp03) Well 18-15 18-15@ 102.000ft (18-15) 18-15@ 102.000ft (18-15) True Minimum Curvature ~~-~~ 0.00 0.00- 0.00 3,791.832 3,800.313 0.00 0.00 0_00 3,812.876 0.00 0.00 0.00 3,848.839 0.00 0.00 0.00 3,862.380 0.00 0.00 0.00 8,541.486 21.111 233.286 6,504.000 -2,433_776 -2,907.704 A3 8,565.068 21.111 233.286 6,526.000 -2,438.854 -2,914.513 Miluveach 8,600.000 21.111 233.286 6,558.587 -2,446.376 -2,924.598 8,700.000 21.111 233.286 6,651.875 -2,467_908 -2,953.471 8,737.652 21.111 233.286 6,687.000 -2,476.015 -2,964.342 BHL TD: 8737.600ft MD, 6686.952ft lVD, (2975ft FNL, 3455ft FEL, Sec:9-T11N-R10E 18-15A Tgt 1 - plan hits target - Point (ft) 8,077.258 8,141.919 8,248.980 8,321.737 8,450_370 8,457.874 8,476_097 8,541.486 8,565.068 Plan Annotations Measured Depth (ft) 4,400.010 4,412480 4,423.000 5,183.830 7,383.830 8,321.600 8,476.100 8,737.600 11/11/2004 1:02:07PM --'-~- Dip Dir. e) 0.00 547,082.000 70· 19' 16.463" N 149· 37' 05.852" W 0.00 6,443.000 -2,419.696 -2,888.824 5,967,209.000 --- ~~--~-~ ~_.- 6 1/8" Open Hole 6-1/8 6-118 6,082_000 HRZlKalubik 0.00 6,137.000 Kalubik 0.00 6.232.000 C4 0.00 6,299.000 8 0.00 6,419.000 A6 0.00 6,426_000 A5 0.00 6,443.000 A4 0.00 6,504.000 A3 0_00 6,526_000 Miluveach 0.00 Vertical Depth (ft) 4,320.867 4,331.559 4,340.490 4,824_999 5,649.134 6,298.872 6,443.003 6,686.952 ¡nates +EI-W (ft) -270_547 -274.516 -277.955 -698.468 -2,331_803 -2,844.216 -2,888_825 -2,964_328 Begin Dir@ 15.00DLS: 4400.0100 MD,432O.867ft TVD End Dir, Start Sail @31_900: 4412.4800 MD, 4331.559ft TVD Begin Dir @ O.ooDLS: 4423.000ft MD,4340.49OO TVD End Dir, Start Sail @ 68.000: 5183.8300 MD, 4824.999ft TVD Begin Dir @ 5.ooDLS: 7383_83Oft MD,5649.134ft TVD End Dir. Start Sail @ 21.111: 8321.6000 MD, 6298.872ft TVD Target (1): 8476.100ft MD, 6443.003ft TVD, (2919ft FNL, 3379ft FEL, Sec9- T1' BHL TD : 8737.600ft MD, 8886.952ft TVD, (2975ft FNL, 3455ft FEL, Sec9- T11 ~ Page 5 of 5 COMPASS 2003.118uild41 ORIGINAL WELLDETAlLS: 1&15A 0.000 A~COLUmoNSETnNGS +w..s TEI.W Northir¡g Eastlng Latlrtude Longitude Interpolation Method: MD Interval: 25S!ations Depth Range From: 4400 To 8887.50082770702 Maximum Range:1078.5500827707 0.000 5969647.640 540054.370 7if19'40.266N 149".'15'4-1.S47W Engineering Kuparuk Calculation Method: Error System: Scan Method: Error Surlace: Warning Method: Plan: Plan: 1S-15A(wp03} Reference: o 1375 18-18/18-18 90 From Colour To MD · . eonocÓPhillips ConocoPhillips Alaska Inc. (Kuparuk) Kuparuk River Unit Kuparuk 18 Pad 18-15 18-15A Plan: 1 8-15A (wp03) Travelling Cylinder Report 11 November, 2004 ORJG'~fAL . Co~illips . SPERRY_SUN HES Anticollision Report Reference ConocoPhillips Alaska Inc. (Kuparuk) Kuparuk River Unit Kuparuk 1 B Pad 0.000f! 1B-15 0.0000 1 B-15A Plan: 1B-15A (wp03) Plan: 1 B-15A (wp03) Wel11 B-15 18-15 @ 102.000ft (1 B-15) 1 B-15 @ 102.00Oft (1B-15) True Minimum Curvature 1.00 sigma EDM 2003.11 Single User Db Offset Datum Filter type: Interpolation Method: Depth Range: Results Limited by: NO GLOBAL FILTER: Using user defined selection & filtering criteria MD Interval 25.000ft Error Model: Unlimited Scan Method: Maximum center-center distance of 1,078.550ft Error Surface: ISCWSA Trav. Cytinder North Elliptical Conic 470.340 4,400.000 4,400.000 1 B-15 (1 B-15) 8,737.652 Plan: 1B-15A(wp03) (1B-15A) MWD MWD MWD - Standard MWD - Standard - WellbOre - Design Kuparuk 1 B Pad 1 B-01 - 1 B-01 - 18-01 18-18-18-18-1B-18 521.036 500.000 3,023.709 3,025.000 494.685 208.402 6.44 36.71 488.244 Pass - Major Risk 171.692 Pass - Major Risk CC - Min centre to center distance or covergent point, SF - min separation factor, ES - min ellipse separation 11/11/2004 1:03:47PM Page 20f12 COMPASS 2003.11 Build 41 ORIGINAL . Co~illips . SPERRY_SUN HES Anticollision Report 102.000 102.000 90.000 90.000 0.000 0.000 -89.72 2.389 -497.013 0.510 497.019 0.51 496.508 Pass - Major Risk 112.216 112.216 100.000 100.000 0.006 0.007 -89.72 2.389 -497.013 0.510 497.017 0.64 496.372 Pass - Major Risk 137.757 137.757 125.000 125.000 0.020 0.040 -89.73 2.389 -497.013 0.510 496.992 1.02 495.970 Pass - Major Risk 163.298 163.298 150.000 150.000 0.035 0.073 -89.73 2.389 -497.013 0.510 496.941 1.40 495.540 Pass - Major Risk 188.839 188.639 175.000 175.000 0.050 0.106 -89.73 2389 -497.013 0.510 496.862 1.78 495.063 Pass - Major Risk 214.380 214.379 200.000 200.000 0.064 0.139 -89.73 2.389 -497.013 0.510 496.756 2.16 494.599 Pass - Major Risk 239.920 239.919 225.000 225.000 0.079 0.173 -89.73 2.389 -497.013 0.510 496.622 2.53 494.087 Pass - Major Risk 265.460 265.458 250.000 250.000 0.093 0.206 -89.74 2.389 -497.013 0.510 496.462 2.91 493.549 Pass - Major Risk 290.999 290.997 275.000 275.000 0.108 0.239 -89.74 2.389 -497.013 0.510 496.274 3.29 492.963 Pass - Major Risk 316.538 316.535 300.000 300.000 0.122 0.272 -89.75 2.389 -497.013 0.510 496.059 3.67 492.390 Pass - Major Risk 342.077 342.072 325.000 325.000 0.137 0.305 -89.75 2.389 -497.013 0.510 495.817 4.05 491 .770 Pass - Major Risk 367.615 367.609 350.000 350.000 0.153 0.338 -89.76 2.389 -497.013 0.510 495.548 4.43 491.123 Pass - Major Risk 393.152 393.144 375.000 375.000 0.168 0.372 -89.77 2.389 -497.013 0.510 495.251 4.80 490.448 Pass - Major Risk 418.689 418.678 400.000 400.000 0.183 0.405 -89.78 2.389 -497.013 0.510 494.927 5.18 489.748 Pass - Major Risk 444.225 444.212 425.000 425.000 0.197 0.412 -89.79 2.319 -497.097 0.510 494.660 5.49 489.169 Pass - Major Risk 469.761 469.745 450.000 449.997 0.212 0.418 -89.83 2.109 -497.348 0.510 494.532 5.80 488.731 Pass - Major Risk, CC 495.397 495.378 475.000 474.991 0.231 0.425 -89.87 1.758 -497.765 0.510 494.541 6.12 488.420 Pass - Major Risk 521.036 521.013 500.000 499.980 0.250 0.432 -89.93 1.267 -498.350 0.510 494.685 6.44 488.244 Pass - Major Risk, ES, SF 546.675 546.647 525.000 524.960 0.270 0.417 -89.98 0.625 -499.092 0.510 494.953 6.70 488.249 Pass - Major Risk 572.314 572.279 550.000 549.932 0.289 0.402 -90.04 -0.180 -499.980 0.510 495.336 6.97 488.368 Pass - Major Risk 597.953 597.909 575.000 574.891 0.308 0.387 -90.11 -1.147 -501.015 0.510 495.834 7.23 488.602 Pass - Major Risk 623.592 623.535 600.000 599.838 0.328 0.372 -90.19 -2.277 -502.196 0.510 496.447 7.50 488.951 Pass - Major Risk 649.228 649.155 625.000 624.763 0.347 0.362 -90.28 -3.691 -503.498 0.510 497.149 7.77 489.377 Pass - Major Risk 673.866 673.778 650.000 649.658 0.355 0.353 -90.42 -5.509 -504.895 0.510 497.941 8.01 489.929 Pass - Major Risk 698.407 698.304 675.000 674.514 0.362 0.344 -90.59 -7.731 -506.386 0.510 498.854 8.25 490.605 Pass - Major Risk 722.917 722.798 700.000 699.325 0.370 0.336 -90.82 -10.355 -507.971 0.510 499.892 8.49 491.407 Pass - Major Risk 747.405 747.270 725.000 724.104 0.378 0.341 -91.06 -13.228 -509.629 0.510 501.036 8.76 492.280 Pass - Major Risk 771.882 771 .732 750.000 748.868 0.386 0.346 -91.32 -16.194 -511.342 0.510 502.265 9.02 493.240 Pass - Major Risk 796.348 796.182 775.000 773.617 0.394 0.352 -91.58 -19.254 -513.108 0.510 503.580 9.29 494.286 Pass - Major Risk 820.802 820.621 800.000 798.350 0.402 0.359 -91.88 -22.408 -514.929 0.510 504.982 9.56 495.420 Pass - Major Risk 845.240 645.044 825.000 823.062 0.411 0.385 -92.14 -25.675 -516.849 0.510 506.518 9.88 496.637 Pass - Major Risk 869.656 869.444 850.000 847743 0.419 0.410 -92.43 -29.074 -518.912 0.510 508.235 10.20 498.035 Pass - Major Risk 894.048 893.820 875.000 872.394 0.428 0.436 -92.73 -32.606 -521.120 0.510 510.135 10.52 499.618 Pass - Major Risk 918.413 918.171 900.000 897012 0.437 0.463 -93.05 -36.271 -523.471 0.510 512.219 10.83 501.385 Pass - Major Risk 942.758 942.500 925.000 921.603 0.446 0.496 -93.37 -40.069 -525.886 0.510 514.409 11.17 503.241 Pass - Major Risk 967.086 966.813 950.000 946.175 0.455 0.529 -93.70 -44.001 -528.288 0.510 516.629 11.50 505.128 Pass - Major Risk 991.399 991.110 975.000 970.726 0.464 0.563 -94.05 -48.066 -530.674 0.510 518.880 11.83 507.047 Pass - Major Risk 1,015.730 1,015.425 1,000.000 995.257 0.471 0.596 -94.41 -52.265 -533.046 0.510 521.164 12.16 509.003 Pass - Major Risk 1,040.311 1,039.991 1,025.000 1,019.747 0.488 0.638 -94.77 -56.625 -535.538 0.510 523.611 12.49 511.123 Pass - Major Risk 1,064.836 1,064.501 1,050.000 1,044.176 0.486 0.679 -95.16 -61.173 -538.285 0.510 528.355 12.81 513.541 Pass - Major Risk 1.089.301 1,068.951 1,075.000 1 ,068.539 0.463 0.721 -95.56 -65.908 -541.286 0.510 529.397 13.14 516.259 Pass - Major Risk 1,113.700 1,113.336 1,100.000 1,092.832 0.481 0.762 -95.97 -70.829 -544.542 0.510 532.742 13.46 519.281 Pass - Major Risk 1,138.019 1,137.641 1,125.000 1,117.039 0459 0.815 -96.41 -76.007 -548.035 0.510 536.384 13.81 522.579 Pass - Major Risk 1,162.239 1,161.849 1,150.000 1,141.141 0.457 0.868 -96.87 -81.513 -551.748 0.510 540.320 14.15 526.173 Pass - Major Risk 1,186.355 1,185.952 1,175.000 1,165.130 0.455 0.920 -9736 -87.345 -555.682 0.510 544.557 14.49 530.070 Pass - Major Risk 1,210.358 1,209.943 1,200.000 1,189.001 0.453 0.973 -97.87 -93.502 -559.835 0.510 549.099 14.82 534.276 Pass - Major Risk 1,234.258 1,233.831 1,225.000 1,212.765 0.451 1.033 -98.40 -99.950 -564.161 0.510 553.904 15.17 538.735 Pass - Major Risk 1,258.066 1,257.628 1,250.000 1,236.434 0.450 1.093 -98.95 -106.654 -568.614 0.510 558.928 15.51 543.416 Pass - Major Risk CC - Min centre to center distance or covergent point, SF - min separation factor, ES - min ellipse separation 11/11/2004 1 :03:47PM Page 3 of 12 COMPASS 2003.11 Build 41 ORIGINAL . eonocÓPhillips SPERRY_SUN HES Anticollision Report . 1,281.777 1,281.328 1.275.000 1,260.0.0.4 0..448 1.152 -99.52 -113.615 -573.194 0..510. 564.175 15.85 548.323 Pass - Major Risk 1,305.387 1,304.928 1,300.0.00 1 ,283.473 0..447 1.212 -10.0..10. -120..830 -577.899 0..510. 569.650. 16.19 553.462 Pass - Major Risk 1,328.848 1,328.378 1,325.0.00 1,30.6.788 0..446 1.282 -10.0..69 -128.357 -582.872 0..510. 575.510. 16.54 558.973 Pass - Major Risk 1.352.10.3 1,351.625 1,350..0.00 1,329.891 0..444 1.351 -10.1.30. -136.249 -588.252 0..510. 581.90.8 16.88 565.0.28 Pass - Major Risk 1,375.140. 1,374.653 1,375.0.00 1,352769 0..443 1.420 -10.1.93 -144.5æ -594.036 0..510. 588.850 17.22 571.631 Pass - Major Risk 1.397.845 1,397.349 1,400..0.00 1,375.40.9 0..446 1.490. -10.2.57 -153.113 -600..221 0..510. 596.339 17.57 578.772 Pass - Major Risk 1,420.454 1,419.949 1,425.000 1,398.0.43 0..453 1.553 -10.3.19 -161.700 -60.6.460 0..510. 6æ.959 17.90. 586.0.57 Pass - Major Risk 1,443.268 1,442.755 1,450..0.00 1 ,420..904 0..459 1.617 ·10.3.76 -169.886 -612.40.7 0..510. 611.277 18.24 593.0.37 Pass - Major Risk 1,466.278 1,465.756 1,475.0.00 1,443.979 0..466 1.681 -10.4.29 -177.667 -618.0.60. 0..510. 618.276 18.58 599.699 Pass - Major Risk 1,489.473 1,488.942 1,500..0.00 1,467.259 0..473 1.744 -10.4.78 -185.0.38 -623.416 0..510. 624.944 18.92 606.0.28 Pass - Major Risk 1,512.546 1,512.007 1,525.0.00 1,490..411 0..479 1.816 -10.5.27 -192.665 -628.957 0.510. 631.916 19.27 612.650 Pass - Major Risk 1,535.161 1,534.613 1,550..0.00 1,513.0.72 0..466 1.887 -10.5.81 -201.202 -635.159 0..510. 639.836 19.61 620..229 Pass - Major Risk 1,557.262 1.556.70.6 1,575.0.00 1,535.188 0..493 1.959 -106.41 -210..628 -642.008 0..510. 648.70.2 19.94 628.765 Pass - Major Risk 1,578. 796 1,578.232 1,600..000 1 ,556.70.6 0..499 2.æ1 -10.7.0.4 -220..921 -649.486 0..510. 658.509 20.25 638.254 Pass - Major Risk 1,599.896 1,599.324 1,625.0.00 1,577.770. 0..505 2.126 -10.7.68 -231.738 -657.50.5 0..510. 669.0.85 20.61 648.476 Pass - Major Risk 1,620.721 1,620..141 1,650..0.00 1,598.552 0..511 2.222 -10.8.30. -242.742 -665.986 0..510. 680.253 20.96 659.297 Pass - Major Risk 1,641.260. 1,640..672 1,675.0.00 1,619.0.42 0..517 2.318 -108.91 -253.934 -674.924 0..510. 692.0.06 21.30 670..70.7 Pass - Major Risk 1,661.50.1 1,660..906 1,70.0..0.00 1,639.229 0..523 2.413 -109.50 -285.305 -684.314 0..510. 70.4.333 21.64 682.698 Pass - Major Risk 1,681.455 1.680.853 1,725.0.00 1,659.121 0..529 2.518 -110..08 -276.950 -693.992 0..510. 717.10.9 21.97 695.140 Pass - Major Risk 1,70.1.135 1,70.0..525 1,750.000 1,678.729 0..535 2.624 -110..67 -288.967 -70.3.795 0..510. 730.215 22.30. 70.7.919 Pass - Major Risk 1 ,720.532 1,719.914 1,775.0.00 1,698.0.47 0..541 2.729 -111.25 -301.350 -713.718 0..510. 743.651 22.61 721.æ7 Pass - Major Risk 1,739.640. 1,739.0.15 1,800..0.00 1,717.0.66 0..547 2.834 -111.84 -314.0.95 -723.759 0..510. 757.417 22.93 734.491 Pass - Major Risk 1,761.280. 1,760..646 1,825.0.00 1,735.90.7 0..553 2.945 -112.42 -327.0.66 -733.847 0..510. 771.40.5 23.27 748.139 Pass - Major Risk 1,777.763 1,777.123 1,850..0.00 1,754.694 0..586 3.0.55 -112.99 -340..130 -743.915 0..510. 785.482 23.57 761.910. Pass - Major Risk 1,796.957 1,796.309 1,875.0.00 1 ,773.427 0..580. 3.165 -113.54 -353.287 -753.964 0..510. 799.655 23.91 775.747 Pass - Major Risk 1,816.104 1,815.448 1,900..000 1,792.106 0..595 3.275 -114.08 -366.535 -763.992 0..510. 813.919 24.24 789.678 Pass - Major Risk 1,835.256 1,834.592 1,925.0.00 1,810..785 0..610. 3.383 -114.60 -379.784 -774.0.21 0..510. 828.251 24.56 803.689 Pass - Major Risk 1,854.465 1,853.794 1,950..0.00 1,829.518 0..625 3.490 -115.10. -392.941 -784.0.69 0..510. 842.626 24.88 817.743 Pass - Major Risk 1,873.730. 1,873.051 1,975.0.00 1,848.30.5 0..639 3.598 -115.57 -406.0.05 -794.138 0..510. 8570.37 25.20 831.835 Pass - Major Risk 1,893.0.52 1,892.365 2,000..0.00 1,867146 0..654 3.70.5 -116.02 -418.976 -80.4.226 0..510. 871.478 25.52 845.959 Pass - Major Risk 1,912.290. 1,911.595 2,025.0.00 1,885.890 0..669 3.815 -116.49 -432.289 -814.0.42 0..510. 885.881 25.85 860..0.31 Pass - Major Risk 1,931.284 1,930..580. 2.050.000 1,90.4.364 0..684 3.925 -117.00 -446.367 -823.285 0..510. 90.0..179 26.17 874.0.10. Pass - Major Risk 1,950.0.0.4 1,949.293 2,0.75.0.00 1,922.541 0..699 4.0.35 -117.55 -461.186 -831.941 0..510. 914.369 26.48 687.894 Pass - Major Risk 1,968.422 1,967.70.2 2,10.0..0.00 1,940..391 0..713 4.145 -118.14 -476.723 -839.995 0..510. 928.454 26.77 901.685 Pass - Major Risk 1,986.682 1,985.953 2,12S.Doo 1 ,958.0.69 0..727 4.262 -118.75 -492.612 -847.745 0..510. 942.537 27.09 915.447 Pass - Major Risk 2,0.04.947 2,0.04.21 0. 2,150..0.00 1,975.746 0..741 4.380 -119.33 -508.500 -855.494 0..510. 956.719 27.41 929.310. Pass - Major Risk 2,0.23.217 2,0.22.472 2,175.0.00 1,993.424 0..756 4.497 ·119.90 -524.389 -863.243 0..510. 970..996 27.73 943.270. Pass - Major Risk 2,0.41.493 2,040..740. 2,200.0.00 2,0.11.10.2 0..770. 4.615 -120..45 -540..278 -870..993 0..510. 985.364 28.0.4 957.323 Pass - Major Risk 2,0.59.80.4 2,059.042 2,225.0.00 2,0.28.808 0..785 4.730. -120..98 -556.157 -878.695 0..510. 999.772 28.35 971.420 Pass - Major Risk 2,0.78.177 2,0.77.407 2,250.0.00 2,0.46.573 0..799 4.845 -121.50 -572.0.17 -886.303 0..510. 1,0.14.172 28.66 985.511 Pass - Major Risk 2,0.96.613 2,0.95.834 2,275.0.00 2,064.395 0..814 4.960 -122.0.1 -587.857 -893.817 0..510. 1,0.28.560. 28.97 999.592 Pass - Major Risk 2,115.111 2,114.323 2,300..0.00 2,082.274 0..828 5.0.75 -122.51 -603.677 -901 .237 0..510. 1,042.933 29.27 1,0.13.659 Pass - Major Risk 2,133.70.9 2,132.911 2,325.000 2,10.0..251 0..843 5.187 -122.98 -619.343 -90.8.746 0..510. 1,057.369 29.57 1,027.799 Pass - Major Risk 2,152.441 2,151.634 2,350.0.00 2,118.365 0..858 5.299 -123.42 -634.718 -9·16.524 0..510. 1,0.71.935 29.87 1,042.0.66 Pass - Major Risk 7,399.970. 5,655.285 5,975.0.00 4,742.613 44.212 22.870. -149.08 -2,593.783 -2,440..228 0..510. 1,0.76.364 122.43 953.935 Pass - Major Risk 7,435.692 5,669.643 6,000..0.00 4,759.585 44.502 23.0.0.2 -149.34 -2,606.418 -2,4!53.543 0..510. 1,0.69.345 123.39 945.951 Pass - Major Risk 7,448.436 5,675.011 6,025.0.00 4,776.566 44.605 23.135 -149.60 -2,618.989 -2,466.90.7 0..510. 1,0.63.0.15 124.21 938.802 Pass - Major Risk 7,461.257 5,680.541 6,050..000 4,793.567 44.70.9 23.267 -149.87 -2,631.664 -2,480..148 0..510. 1,056.981 125.05 931.933 Pass - Major Risk CC - Min centre to. center distance or co.vergent point, SF - min separation factor, ES - min ellipse separation 11/11/2004 1 :03:47PM Page 4 af 12 COMPASS 2003.11 Build 41 nR f r; f ~I.J~ L .../ ¡ \ I 1875 I I 1500 I ¡ 125 I 375 I ·375 ¡Iii' I I I I I I I' I -3375 -3000 -2625 -2250 -1875 -1500 -4125 -4875 750- 375- ·375- -750- -1125- ·3000- ·3375- -3750- -4125- . . '.-. '~-II- Conocu.-III. IPS ConocoPhillips Alaska Inc. (Kuparuk) Kuparuk River Unit Kuparuk 1 B Pad 1B-15 1B-15A Plan: Plan: 1 B-15A (wp03) Standard Planning Report - Geographic 11 November, 2004 nn j! ~ ~:" '{ . eonocó'Phillips SPERRY_SUN HES Planning Report - Geographic . EDM 2003.11 Single User Db ConocoPhillips Alaska Inc. (Kuparuk) Kuparuk River Unit Kuparuk 1 B Pad 1B-15 1B-15A Plan: 1B-15A (wp03) Well1B-15 1B-15@ 102.0ooft(1B-15) 1B-15 @ 102.0ooft (1B-15) True Minimum Curvature Projeèt Map System: Geo Datum: Map Zone: Kuparuk River Unit, North Slope Alaska, United States US State Plane 1927 (Exact solution) NAD 1927 (NADCON CONUS) Alaska Zone 04 System Datum: Mean Sea Level Using Well Reference Point Using geodetic scale factor Site. Kuparuk 1 B Pad Site Position: From: Map Position Uncertainty: 0.000 ft Northing: Easting: Slot Radius: 5,969,646.720ft 549,457.400 ft 0" Latitude: Longitude: Grid Convergence: 70° 19' 40.290" N 149° 35' 56.056" W 0.38 ° Well 1B-15 Well Position +N/-S +E/-W Position Uncertainty 0.000 ft 0.000 ft 0.000 ft Northing: Easting: Wellhead Elevation: 5,969,647.640 ft 549,954.370 ft ft Latitude: Longitude: Ground Level: 70° 19' 40.266" N 149° 35' 41.547" W 0.000 ft Welloore. 1 B-15A BGGM2004 10/28/2004 24.56 80.76 57,578 Design Audit Notes: Version: Plan: 1 B-15A (wp03) Phase: PLAN Tie On Depth: 4,400.000 230.129 4,400.000 30.029 218.213 4,320.858 -389.585 -270.544 0.00 0.00 0.00 0.00 4,412.476 31 .900 218.210 4,331.556 -394.629 -274.515 15.00 15.00 -0.02 359.96 4,429.996 31.900 218.210 4,346.430 -401.903 -280.241 0.00 0.00 0.00 0.00 5,183.821 68.000 233.200 4,824.996 -781.534 -698.461 5.00 4.79 1.99 23.09 7,383.821 68.000 233.200 5,649.130 -2,003.425 -2,331.797 0.00 0.00 0.00 0.00 8,321 .597 21.111 233.286 6,298.870 -2,386.429 -2,844.215 5.00 -5.00 0.01 179.96 8,476.097 21.111 233.286 6,443.000 -2,419.696 -2,888.824 0.00 0.00 0.00 0.00 1B-15A Tgt 1 8,737.652 21.111 233.286 6,687.000 -2,476.015 -2,964.342 0.00 0.00 0.00 0.00 11/11/2004 1 :02:33PM Page 2 of 5 COMPASS 2003.11 Build 41 o R! G I.~\fj^ . Co~illips . SPERRY_SUN HES Planning Report - Geographic EDM 2003.11 Single User Db CönocoPhillips Alaska Inc. (Kuparuk) Kuparuk River Unit Kuparuk 1 B Pad 1B-15 1 B-15A Plan: 1 B-15A (wp03) Well 18-15 18-15 @ 102.000ft (18-15) 18-15 @ 102.000ft (18-15) True Minimum Curvature 4,400.000 30.029 218.213 4,320.858 -389.585 -270.544 5,969,256.300 549,686.452 70° 19' 36.435" N 149° 35' 49.445" W Begin Dir @ 15.00DlS: 4400.010ft MD,4320.867ft TVD 4,412.476 31.900 218.210 4,331.556 -394.629 -274.515 5,969,251.231 549,682.515 70° 19' 36.385" N 149° 35' 49.561" W End Dir, Start Sail @ 31.900: 4412.480ft MD, 4331.559ft TVD 4,423.000 31.900 218.210 4,340.490 -398.998 -277.955 5,969,246.839 549,679.105 70° 19' 36.342" N 149° 35' 49.661" W Begin Dir @ O.OODLS: 4423.000ft MD,4340.490ftTVD 4,429.996 31.900 218.210 4,346.430 -401.903 -280.241 5,969,243.919 549,676.838 70° 19' 36.314" N 149° 35' 49.728" W 4,500.000 35.143 220.594 4,404.785 -431.745 -304.800 5,969,213.917 549,652.481 70° 19' 36.020" N 149° 35' 50.445" W 4,600.000 39.843 223.401 4,484.111 -476.904 -345.565 5,969,168.493 549,612.021 70° 19' 35.576" N 149° 35' 51.635" W 4,700.000 44.598 225.703 4,558.149 -524.727 -392.734 5,969,120.361 549,565.176 70° 19' 35.106" N 149° 35' 53.011" W 4,800.000 49.393 227.645 4,626.337 -574.851 -445.947 5,969,069.889 549,512.303 70° 19' 34.613" N 149° 35' 54.565" W 4,900.000 54.215 229.326 4,688.156 -626.894 -504.800 5,969,017.460 549,453.804 70° 19' 34.101" N 149° 35' 56.282" W 5,000.000 59.059 230.814 4,743.134 -680.460 -568.844 5,968,963.474 549,390.124 70° 19' 33.574" N 149° 35' 58.152" W 5,100.000 63.917 232.157 4,790.855 -735.143 -637.592 5,968,908.340 549,321.748 70° 19' 33.036" N 149° 36' 00.158" W 5,183.821 68.000 233.200 4,824.996 -781 .534 -698.461 5,968,861.549 549,261.195 70° 19' 32.580" N 149° 36' 01 .935" W End Dir, Start Sail @ 68.000: 5183.830ft MD,4824.999ft TVD 5,200.000 68.000 233.200 4,831.056 -790.520 -710.473 5,968,852.484 549,249.245 70° 19' 32.491" N 149° 36' 02.286" W 5,300.000 68.000 233.200 4,868.517 -846.060 -784.716 5,968,796.456 549,175.381 70° 19' 31 .945" N 149° 36' 04.452" W 5,400.000 68.000 233.200 4,905.978 -901 .601 -858.958 5,968,740.428 549,101.517 70° 19' 31.399" N 149° 36' 06.619" W 5,500.000 68.000 233.200 4,943.438 -957.141 -933.201 5,968,684.400 549,027.653 70° 19' 30.852" N 149° 36' 08.786" W 5,600.000 68.000 233.200 4,980.899 -1,012.682 -1,007.443 5,968,628.372 548,953.789 70° 19' 30.306" N 149° 36'10.953" W 5,700.000 68.000 233.200 5,018.360 -1,068.222 -1,081.686 5,968,572.344 548,879.925 70° 19' 29.760" N 149° 36'13.120" W 5,800.000 68.000 233.200 5,055.820 -1,123.763 -1,155.928 5,968,516.316 548,806.061 70° 19' 29.213" N 149° 36' 15.287" W 5,900.000 68.000 233.200 5,093.281 -1,179.303 -1,230.171 5,968,460.287 548,732.197 70° 19' 28.667" N 149° 36'17.453" W 6,000.000 68.000 233.200 5,130.742 -1,234.844 -1,304.413 5,968,404.259 548,658.333 70° 19' 28.121" N 149° 36'19.620" W 6,100.000 68.000 233.200 5,168.202 -1,290.384 -1,378.656 5,968,348.231 548,584.470 70° 19' 27.574" N 149° 36' 21.787" W 6,200.000 68.000 233.200 5,205.663 -1,345.925 -1 ,452.898 5,968,292.203 548,510.606 70° 19' 27.028" N 149° 36' 23.953" W 6,300.000 68.000 233.200 5,243.124 -1,401.465 -1,527.141 5,968,236.175 548,436.742 70° 19' 26.482" N 149° 36' 26.120" W 6,400.000 68.000 233.200 5,280.584 -1,457.006 -1,601.383 5,968,180.147 548,362.878 70° 19' 25.935" N 149° 36' 28.287" W 6,500.000 68.000 233.200 5,318.045 -1,512.546 -1,675.626 5,968,124.119 548,289.014 70° 19' 25.389" N 149° 36' 30.453" W 6,600.000 68.000 233.200 5,355.506 -1,568.087 -1,749.868 5,968,068.090 548,215.150 70° 19' 24.842" N 149° 36' 32.620" W 6,700.000 68.000 233.200 5,392.966 -1,623.627 -1,824.111 5,968,012.062 548,141.286 70° 19' 24.296" N 149° 36' 34.786" W 6,800.000 68.000 233.200 5,430.427 -1,679.168 -1,898.353 5,967,956.034 548,067.422 70° 19' 23.750" N 149° 36' 36.953" W 6,900.000 68.000 233.200 5,467.888 -1,734.708 -1 ,972.596 5,967,900.006 547,993.558 70° 19' 23.203" N 149° 36' 39.119" W 7,000.000 68.000 233.200 5,505.348 -1,790.249 -2,046.838 5,967,843.978 547,919.695 70° 19' 22.657" N 149° 36' 41 .285" W 7,100.000 68.000 233.200 5,542.809 -1,845.789 -2,121.081 5,967,787.950 547,845.831 70° 19' 22.110" N 149° 36' 43.452" W 7,200.000 68.000 233.200 5,580.270 -1,901.330 -2,195.323 5,967,731.922 547,771.967 70° 19' 21 .564" N 149° 36' 45.618" W 7,300.000 68.000 233.200 5,617.730 -1,956.870 -2,269.566 5,967,675.893 547,698.103 70° 19' 21.017" N 149° 36' 47.784" W 7,383.821 68.000 233.200 5,649.130 -2,003.425 -2,331.797 5,967,628.930 547,636.189 70° 19' 20.559" N 149° 36' 49.600" W Begin Dir @ 5.00DLS: 7383.830ftMD,5649.134ft TVD 7,400.000 67.193 233.201 5,655.297 -2,012.385 -2,343.774 5,967,619.892 547,624.273 70° 19' 20.471" N 149° 36' 49.950" W 7,500.000 62.193 233.205 5,698.033 -2,066.517 -2,416.141 5,967,565.284 547,552.275 70° 19' 19.939" N 149° 36' 52.061" W 7,600.000 57.193 233.209 5,748.483 -2,118.207 -2,485.254 5,967,513.140 547,483.515 70° 19'19.430" N 149° 36' 54.078" W 7,700.000 52.193 233.215 5,806.263 -2,167.061 -2,550.587 5,967,463.857 547,418.515 70° 19' 18.949" N 149° 36' 55.984" W 7,800.000 47.193 233.220 5,870.934 -2,212.707 -2,611.642 5,967,417.810 547,357.771 70° 19' 18.500" N 149° 36' 57.765" W 7,900.000 42.193 233.227 5,942.002 -2,254.799 -2,667.956 5,967,375.348 547,301.744 70° 19' 18.086" N 149° 36' 59.408" W 8,000.000 37.193 233.236 6,018.928 -2,293.015 -2,719.099 5,967,336.796 547,250.861 70° 19'17.710" N 149° 37' 00.901" W 8,077.258 33.328 233.244 6,082.000 -2,319.702 -2,754.823 5,967,309.875 547,215.319 70° 19'17.447" N 149° 37' 01 .943" W HRZ/Kalubik 8,100.000 32.193 233.246 6,101.125 -2,327.066 -2,764.683 5,967,302.446 547,205.510 70° 19'17.375" N 149° 37' 02.230" W 8,141.919 30.095 233.252 6,137.000 -2,340.036 -2,782.052 5,967,289.361 547,188.229 70° 19' 17.247" N 149° 37' 02.737" W Kalubik 8,200.000 27.193 233.260 6,187.968 -2,356.691 -2,804.360 5,967,272.561 547,166.035 70° 19'17.083" N 149° 37' 03.388" W 8,248.980 24.742 233.269 6,232.000 -2,369.517 -2,821.545 5,967,259.622 547,148.937 70° 19' 16.957" N 149° 37' 03.889" W C4 8,300.000 22.193 233.280 6,278.797 -2,381.665 -2,837.828 5,967,247.366 547,132.737 70° 19' 16.838" N 149° 37' 04.364" W 11/1112004 1:02:33PM Page 3 of 5 COMPASS 2003.11 Build 41 OR'G'~Jl~,t Co~illips . . SPERRY_SUN HES Planning Report - Geographic Well 1 B-15 1B-15@ 102.000fl(1B-15) 1B-15@ 102.000fl (1 B-15) True Minimum Curvature 8,321.597 21.111 233.286 6,298.870 -2,386.429 -2,844.215 5,967,242.561 End Dir,StartSail @21..111: 8321.60011 MO, 6298.87211 TVD 8,321.737 21.111 233.286 6,299.000 -2,386.459 -2,844.256 5,967,242.530 547,126.342 70° 19'16.790" N B 8,400.000 8,450.370 A6 8,457.874 A5 8,476.097 21.111 233.286 6,443.000 -2,419.696 -2,888.824 5,967,209.000 547,082.000 70° 19'16.463" N Target (1) : 8476;10011 MO, 6443.00311 TVO,(291911 FNL, ·337911 FEL, Sec9.T11N-R10E - A4 -1B-1SA Tgt 1 8,500.000 21.111 233.286 6,465.299 -2,424.843 -2,895.725 5,967,203.808 547,075.134 70° 19'16.413" N 8,541.486 21.111 233.286 6,504.000 -2,433.776 -2,907.704 5,967,194.796 547,063.216 70° 19'16.325" N A3 8,565.068 Miluveach 8,600.000 21.111 233.286 6,558.587 -2,446.376 -2,924.598 5,967,182.086 8,700.000 21.111 233.286 6,651.875 -2,467.908 -2,953.471 5,967,160.364 8,737.652 21.111 233.286 6,687.000 -2,476.015 -2,964.342 5,967,152.185 BHL TO: 8737.60011 MO, 6686.95211 TVD, (297511 FNL, 345511 FEL, Sec9cT11N~R10E 547,126.382 70° 19'16.791" N 149° 37' 04.551" W 149° 37' 04.552" W 21.111 21.111 233.286 233.286 6,372.010 -2,403.311 -2,866.852 6,419.000 -2,414.157 -2,881.396 5,967,225.530 5,967,214.588 547,103.860 547,089.390 70° 19' 16.625" N 70° 19'16.518" N 149° 37' 05.211" W 149° 37' 05.636" W 21.111 233.286 6,426.000 -2,415.772 -2,883.562 5,967,212.958 547,087.235 70° 19' 16.502" N 149° 37' 05.699" W 149° 37' 05.852" W 149° 37' 06.054" W 149° 37' 06.403" W 21.111 233.286 6,526.000 -2,438.854 -2,914.513 5,967,189.674 547,056.442 70° 19'16.275" N 149° 37' 06.602" W 547,046.407 547,017.681 547,006.865 70° 19'16.201" N 70° 19' 15.989" N 70° 19' 15.909" N 149° 37' 06.896" W 149° 37' 07.738" W 149° 37' 08.055" W 1B-15A Tgt 1 - plan hits target - Point 0.00 0.006,443.000 -2,419.696 -2,888.824 5,967,209.000 547,082.000 70° 19'16.463" N 149° 37' 05.852" W 6 1/8" Open Hole 6-1/8 6-1/8 6,082.000 6,137.000 6,232.000 6,299.000 6,419.000 6,426.000 6,443.000 6,504.000 6,526.000 HRZ/Kalubik Kalubik C4 B A6 A5 A4 A3 Miluveach 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 11/1112004 1 :02:33PM Page 4 of 5 COMPASS 2003.11 Build 41 . Co~illips . SPERRY_SUN HES Planning Report - Geographic 4,400.010 4,412.480 4,423.000 5,183.830 7,383.830 8,321.600 8,476.100 8,737.600 4,320.867 4,331.559 4,340.490 4,824.999 5,649.134 6,298.872 6,443.003 6,686.952 -389.589 -394.630 -398.998 -781.539 -2,003.430 -2,386.429 -2,419.697 -2,476.004 -270.547 -274.516 -277.955 -698.468 -2,331.803 -2,844.216 -2,888.825 -2,964.328 Begin Dír @ 15.000LS: 4400.01 Oft MD,4320.867ft rvD End Dir, Start Sail @ 31.900: 4412.480ft MD, 4331.559ft rvD Begin Dir @ O.OODLS: 4423.0ooft MD,4340.49Oft TVD End Dir, Start Sail @ 68.000: 5183.830ft MD, 4824.999ft rvD Begin Oir @ 5.00DLS: 7383.830ft MD,5649.134ft TVD End Dir, Start Sail @ 21.111: 8321.600ft MD, 6298.872ft rvD Target (1) : 8476.1 OOft MD, 6443.003ft TVD, (2919ft FNL, 3379ft FEL, S( BHL TO : 8737.600ft MD, 6686.952ft TVD, (2975ft FNL, 3455ft FEL, See 11/1112004 1 :02:33PM Page 5 of 5 COMPASS 2003.11 BuDd 41 Of?IG/NAl . . Surface Location IB-IS IB-ISA Tgt I ORrGI~~AL . . BHL IB-15A ORIGtNAL . GEOLOGIC SUMMARY: Target 1 (NAD 27) Resp: Dirk Seifert Formation Z (TVD.SS) Porosity 5980' Perm X 547,294 HRZ (Fault Crossing) y 5,967,245 Target Shape: Remarks: Target 2 (NAD 27) 0 Not Applicable Formation X Y Z (TVD.SS) Porosity Perm C4 547,098 5,967,084 6130' Target Shape: Remarks: Target 3 (NAD 27) 0 Not Applicable Formation X Y Z (TVD.SS) Porosity Perm A4 547,082 5,967,209 6,341' 0.22 127 Target Shape: Remarks: we expect 1-5 ft of ankerite. . 1 B-15,ST o Complete Preferred Tar. Angle Net Pay Approx Stepout: Preferred Net Pay Tar. Angle Approx Stepout: Net Pay 21' Preferred Tar. Angle near vertical Approx Stepout: Geologic Prognosis: Responsible: Dirk Seifert 0 Complete Formation X Y Z (TVD.SS) MD Gross Net Pay Net to Thickness Gross Permafrost 1660' HRZ/Fault Crossing 5980' Kalubik 6035' 95' Kuparuk C4 6130' 67' Kuparuk B 6197' 120' Kuparuk A6 6317' 7' 0' 0 Kuparuk A5 6324' 17' 5' 0.29 Kuparuk A4 6341' 61' 21' 0.34 Kuparuk A3 6402' 22' 0' 0 Miluveach 6424' Remarks: Geologic Discussion: Responsible: Dirk Seifert 0 Complete Kick off will be above the Kuparuk interval at 4220' TVDSS (4400' MD), The top Kuparuk (C4) exists in 1 B-15 at 6246' TVDSS (6756' MD), but is expected in the target area at about 6139' TVDSS. In the target area, the C-sand and B-sections are expected to be about 70' and 130' thick. Between the B and the A5-sand, there are about 7' of A6. A-Sand characteristics for the prospect area are very good. The well will be nearly vertical once it reaches the target area and will cross-cut the A5 and A4 sands. The A5 is expected to have about 5' of net pay. Average porosity is expected to be 19% and exhibit a permeabilily of about 54 mD and an average Sw of about 23% (Sw is based only on 1 B-01 & 1 B-20). The A4 is expected to have about 21' of net pay. Average porosity is expected to be 22% and exhibit a permeability of about 127 mD and an average Sw of about 19% (Sw is based only on 1 B-01 & 1 B-20). More detail and pictures are in the AFC document. ;0.. . R·. f hl~" h ' ~ ....' " ~ 'I KRU 1 SA Proposed 1-011 2042560 () 00 . . II ~ I ~ . SHARON K. ALLSUP-DRAKE 1 CONOCOPHILLlPS t~~gt::E AK99501 DATE~k~~Jro311 ~~r'cJlrt: !~¡oe I ~~c: a~ ~.... C HA· SE _._~.-"""' V"~"PT05000"""".. .1 U ~.~--,._.,"" ~"'" ...JJ£, ."0 ~~~~~~~~~~ ~ .: 0 ~ . .00 . I.. 1...: 2 . a I.. 7 . '10 7 '1 2 7 bill .0 a b ~,¡iØ;'~.é\'g~~~Ii'¡{'U;~"'~~~""'~ . . TRANSMIT AL LETTER CHECK LIST CIRCLE APPROPRIATE LETTER/P ARAGRAPHS TO BE INCLUDED IN TRANSMITTAL LETTER \LQ.v WELL NAME \ ß-\S- A d-t) '-\ - if-S-G::, 'I' Development ~n t\ Service PTD# CHECK WßA T APPLIES ADD-ONS (OPTIONS) MULTI LATERAL (If API number last two. (2) digits are between 60-69) Exploration Stratigraphic ·'CLUE"· Tbe permit is for a new wellbore 'segment of existing weD,. . Permit No, .' API No. Production. sbould continue to be reported as a function 'of tbe original API number. stated above. . HOLE )n accordance witb 20 AAC 25.005(1), aU records, data and logs acquired .for tbe pilot bole must be dearly differentiated In botb name (name on permit plus PH) and API Dumber (50 70/80) from records, data and logs acquired for well (name on permit). Pll.OT (PH) SPACING EXCEPTION DRY DITCH SAMPLE Tbe permit is approved subject ·to fuD compliance witb 20 AAC 25..055~ Approval to perforate and produce is contingent upon issuance of ~ conservation order approving a spacing e:sception. (Company Name) assumes tbe liability of any protest to tbe spacing .e:sception tbat may occur. AU dry ditch sample sets submitted to tbe Commission must be in no greater 1han 30' sample intervals from below tbe permafrost or from where samples are first caught and ] 0' sample iIiter:vaJs through target zones. «« "Field & Pool KUPARUK RIVER, KUPARUK RV OIL - 490100 Well Name: KUPARUK RIV UNIT 1B-15A Program DEV Well bore seg Company CONOCOPHILLlPS ALASKA INC Initial Class/Type DEV Ii-OIL GeoArea 890 Unit 11160 On/Off Shore On Annular Disposal 1 P~rmitfee qttaçhe~L . . . . . . . . Y~s . . . . . . . . . . . . . . 2 leqs.e .number .appropriate . . . . . . . . . . . . . . . . . . . Yes. . . . Top productive interv.al 8< TD inAQL. 02564.8. . . . . . . . . . . 3 .U.nique weltn.am~.and oumb.er . . . . . . . . . . . . . . . . . . _ . . . . . _ . . . . . . . . . . . _ . Y~s . _ _ . . . . . . _ . . . . . . . . . . . . . . . . . . . . . . _ . . . . . . . .. . _ . . . . . . . . . _ . . . . _ . . . . _ . . . . . . . . . . . 4 WeJI Jocat~d in.a. d.efjnedpool.. ....... . Yes. . Kuparul< River Qil F'ool. gov.ern~d by Conseryqtioo Ord.er NO. 432C . . . . . . . . . . 5 WellJocat~d proper .distance. from driJling unitbound.ary . . . . . . . Yes. . . . . . . . . . . . . . . . . . . . . . . _ _ _ _ . _ 6 WellJoc¡¡t~d proper _distance_ from otber welJs . _ _ _ _ . _ _ Y~s _ _ _ _ NO interweJl restrictio.ns.moJe than 500~ from exte_roaJ bounda.ry. _ 7 _S_uffiçienlaçreqg.e.ayqilable in.drilliog. unit. _ _ _ _ _ _ _ . _ _ _ _ . _ _ _ _ . . . . Yes _ . _ _ . . _ _ _ _ . . _ _ _ _ _ . _ _ _ . . . . _ _ _ _ . . . _ 8 Jf.d~viated. js weJlbore plaUncJu.ded _ _ _ _ _ _ . . . Y~s. _ _ . . _ _ _ _ _ _ . _ _ _ . _ . _ _ _ _ . . _ _ . _ _ . . . . 19 _O.perator only qffeçted party _ . . . - - - _ . . . . - - _ . - - Yes - - - - . . - - - - - . - . . - . - . - - - - . . 10 .O.perator bas.appropriate.Qond inJorce . . . . _ _ . . . . . . _ . _ . . _ _ . . . .. ...... _ . Y~$ _ . . . . . _ . . . . . . . . . . . . . . . . . _ _ . . . . . . . . . . . _ _ . . . . _ _ . . . . . . . . . . . _ . . . . . . . . . . _ . . . _ 11 P~rmit can be issued witbout co.nserva_tion order _ . _ _ _ _ . . . _ _ _ . . _ . _ . . Yes _ _ _ . . . _ _ _ _ _ . _ . _ _ _ _ . _ _ 12 P~rmitcan be issued witbout qdministratilteß'pprovaJ _ _ _ _ _ _ . . . . Y~s _ . . _ _ . . . _ _ _ _ _ . . _ _ _ . . . _ _ _ . . _ _ 13 Can permit be approved before is-day wait Yes 14 WellJoc¡¡t~d within qreq <!nd.strataauthorized by_lojectioo Ord~r # (puUOif: in comm.eots) (For. .NA _ _ _ . . _ 15 _AJlwelJs.within.1[4.mile.area_ofreyiewid~otified(Forservjc.e.wetlonly)....... _..... _ .NA....... _ _.... _...... _............... _...... _............ _.. _.. _............ 16 Pre-produced injector; dl,lration.of pre-.production I~ss th<!n 3 months (for.servtce well onJy). NA _ _ _ . . _ . _ _ . . . _ 17 ACMP_FindingofCon.sistencyh.as been.issued.for.tbis pr.ojeçt _ NA . _ _ _ . . _ _ _ _ . . _ . . _ _ . . _ . _ _ _ . . _ _ _ _ _ . . . . _ _ _ . . . ._~ 18Condu.ctor string provided _ _ _ _ . . . . . _ _ . _ . _ _ . . _ _ .NA . . Conductor .seUo original well, 18.-15 (:194-051) . . _ 19Sud'ace.casingpJotects alLknown USQWs . _ _ _ _ _ . . . . _ NA,ð.1l aquifers ex~mpted 40 cm 147.102(b)(3), . 20 _CMTv.oladeQuate.to çirculate.on.conduçtor& surf.csg . _ _ _ . . _ . _ _ . _ . _ NA _ Surtace casing seUnoriginalwell.. . 21CMT vol adequate. to tie-in Jong .string to.sud' ~g_ _ _ _ _ _ . . . _ NA _ produ.ction casing set in.orgir¡aJ well, oew drjlling Jioer to be fully .cemented, _ _ _ _ _ . . . 22 .CMTwilJ coyer.aJll<oown_pro.ductiye borizons _ . . _ _ _ _ . . _ . Y~s _ _ . New produ_ctionJinerwillbeJully .cemented, . 23 .C_asing designs qd_ec¡ua_te for C,T, B.&.permafr.ost _ _ _ . . _ . Y~s . _ _ _ . . _ _ _ _ _ . . . . _ _ _ . . . _ _ _ _ . . 24 _Adequate.tankage.orreseryepit _ _ _ _ _ _.. _ _.... _ _ . _ _ _ _. . Y~s _ _ _Rigise.quippe.d_witbsteelpitS..Noreserve.pjt.planoed, All waste to apprO\led dispos.alwells_. . _ __ 25 Jfare-drill. basa 10:4.03 for abandonme.nt be~o apPJoved _ _ Yes. . .304-4.91 apPJoved 12129J04, _ _ _ _ _ _ . . _ _ _ _ . . _ _ _ . . _ _ _ _ _ _ . . . _ _ _ . _ _ 26 .Adequi3tewellboresepªr¡¡tion.pro.Posed............. _..... _ _ _.... ...... Yes.. _.. .pro~imit)'.ani3lysisper(orme.d, Jrayelingc)'.lioderploUocJu.ded..Neare.stwell.segmenti.s.1B:15.. _ _... _...._ 27 Jf.divecter req.uired, does ilmeet reguJations. . . . _ _ _ . . _ . _ . . . _NA _ _ _ . . eOF' stack will qlr.e¡¡dybejn plªc.e, .. . _ _ _ . . _ _ _ . . . _ . _ . . . . . _ 28 Drilliog fluid. program sc.hemallc& equip Jistadequate_. .. _ _ . . _ Y~s . . Mªximum expected forma_tion pressureJ j .~EMW. MW pJanned_ 11,8. -.12Ajn Kuparu_k .targe.!.. 29 B.OPES,do they meet reguJa.tion _ . . Yes _ . _ _ . . . . _ . _ _ _ . . . _ _ _ _ . . . 30B0PE.press rating qp.propriate;.test to (pu_t psig in_comments) _ . . . _ . _ Y~s. . M,ð.SF' calcuJate_d.at 3285 psi, 30QO.initiaJ testd.ue tocsg..heªd, 5000.tberqft.er plªnned.. 31 Choke. manifold compJies w/APtRP-53 (May 84) _ _ . . _ _ _ _ _ . . _ y~s _ _ _ _ . . . _ 32 Work will occur withoutoperationsbutdown. _ . _ _ . _ . . _ _ _ _ . . . _ Yes _ 33 .Is presence of H2S gqS prob.able _ . _ _ . _ _ . . _ . _ . . . . No_ 34 Mecba.nicalcpodillon of wells within ,ð.OR yerified (For. s.e(Vjce welJ onl)'.) _ _ NA _ PTD#: 2042560 Administration o D Appr Date SFD 1/4/2005 Engineering Appr Date TEM 1/5/2005 tft4W{ Geology Appr SFD Date 1/4/2005 Geologic Commissioner: Þr~ - - - - - - ~ . - - - - - - - - - - - - - - - - - - -- - - - - - - - - - - - - - - - - - - . - - - - - - _ _ _ Mud shol,lld preclude. H2S on.tbe. rig, .Rjg is eQujp.ped with sensors and alarms. . - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - 35 P~rmit c.a[1 be issued wlo hydrogen sulfide measures. . 36 _D.ata.preseoted on. pote_ntial oveJpressurezones. . 37 .S~ism¡c.anª'ysis of sbaJlow gas.z.ooes 38 .Seabed .conditioo survey.(if Off-sh.ore) . . . . . . . 39 _ Contact nam.e[phoneforweelsly prpgressreports [exploratory.o[1ly] . . 18-15 mea.sured 12Q ppm H2S on8J3012004.. . . . . . . . . . . . . . I;xpected reservoir 'pre.ssuJe is .11.9 ppg EMW; wi]l be drj/led with 1.2,0. -.12,Appg mud. - - - - - - . No. ... _.' Yes. ~ - - - - - ~ - - - - ~ - - - - - - - - - - - - ~ - - - - - - - - ~ NA. .NA __ NA - - - - - ~ ~ ~ - - - - - - - - - - - ~ - - - - - - - - - - - - - ~ - - - - - ~ - - - - - - - - - - - - - - - - - ~ - - - - - - - - - - - - - -- - - - - - ~ - - - - - - - ~ - - - - - - - - - - - - - - - Date: Engineering Commissioner: ~ ~/ )f~r Date //C/u . . 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 infonnation, infoffilation of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. . Sperry-Sun Drilling Services LIS Scan Utility . ;<of-Ä5~ $Revision: 3 $ LisLib $Revision: 4 $ Wed Mar 02 07:58:00 2005 11 J)âa Reel Header Service name............ .LISTPE Date. . . . . . . . . . . . . . . . . . . . .05/03/02 Origin. . . . . . . . . . . . . . . . . . . STS Reel Name............... .UNKNOWN Continuation Number.... ..01 Previous Reel Name. .... ..UNKNOWN Comments.... .... ....... ..STS LIS Writing Library. Scientific Technical Services Tape Header Service name............ .LISTPE Date. . . . . . . . . . . . . . . . . . . . .05/03/02 Origin. . . . . . . . . . . . . . . . . . . STS Tape Name.......... ... ...UNKNOWN Continuation Number.... ..01 Previous Tape Name..... ..UNKNOWN Comments................ .STS LIS Writing Library. Scientific Technical Services Physical EOF Comment Record TAPE HEADER Kuparuk MWD/MAD LOGS # WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: # JOB DATA 1B-15A 500292246501 ConocoPhillips Alaska, Inc. Sperry-Sun Drilling Services 02-MAR-05 JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 4 MW0003499847 J. BOBBITT E. VAUGHN MWD RUN 5 MW0003499847 R. FRENCH E. VAUGHN MWD RUN 6 MW0003499847 J. BOBBITT E. VAUGHN JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 7 MW0003499847 R. FRENCH D. GREEN # SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: 9 11N 10E 500 484 95.00 61.30 # WELL CASING RECORD OPEN HOLE CASING DRILLERS 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING . BIT SIZE (IN) 6.125 4.750 SIZE (IN) DEPTH (FT) 6.800 4234.0 5.500 8348.0 . # REMARKS: 1. ALL DEPTHS ARE BIT DEPTHS UNLESS OTHERWISE NOTED. THESE DEPTHS ARE MEASURED DEPTH (MD). 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTH (TVD). 3. THIS WELLBORE EXITS 1B-15 BY MEANS OF A WHIPSTOCK, THE TOP OF WHICH WAS AT 4405'MD/4329'TVD. 4. MWD RUN 1 WAS DIRECTIONAL ONLY TO POSITION THE WHIPSTOCK. RUNS 2 & 3 ENCOUNTERED TOOL AND HOLE PROBLEMS. NO DATA ARE PRESENTED FOR RUNS 1-3. 5. MWD RUNS 4-7 COMPRISED DIRECTIONAL; DUAL GAMMA RAY (DGR) UTILIZING GEIGER- MUELLER TUBE DETECTORS; AND ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4) MWD RUNS 4-6 ALSO INCLUDED COMPENSATED THERMAL NEUTRON POROSITY (CTN); STABILIZED LITHO-DENSITY (SLD); AND AT-BIT INCLINATION (ABI). 6. DEPTH SHIFTING OF MWD DATA WAS WAIVED PER E-MAIL, DATED 12/16/04, FROM M. WERNER (CPAI) TO R. KALISH (SSDS). MWD DATA ARE CONSIDERED PDC. 7. MWD RUNS 4-7 REPRESENT WELL 1B-15A WITH API#: 50-029-22465-01. THIS WELL REACHED A TOTAL DEPTH (TD) OF 8621'MD/6607'TVD. SROP SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRC SMOOTHED GAMMA RAY COMBINED. SEXP SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (EXTRA SHALLOW SPACING) . SESP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (SHALLOW SPACING) . SEMP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (MEDIUM SPACING) . SEDP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (DEEP SPACING) . SFXE = SMOOTHED FORMATION EXPOSURE TIME (DEEP SPACING) . TNPS = SMOOTHED THERMAL NEUTRON POROSITY (SANDSTONE MATRIX, FIXED HOLE SIZE) . CTFA SMOOTHED AVERAGE OF FAR DETECTOR'S COUNT RATE. CTNA = SMOOTHED AVERAGE OF NEAR DETECTOR'S COUNT RATE. SBD2 = SMOOTHED BULK DENSITY-COMPENSATED (LOW-COUNT BIN) . SC02 = SMOOTHED STANDOFF CORRECTION (LOW-COUNT BIN) . SNP2 = SMOOTHED NEAR DETECTOR ONLY PHOTOELECTRIC ABSORPTION FACTOR (LOW-COUNT BIN) . SLIDE = NON-ROTATED INTERVALS REFLECTING BIT DEPTHS. SLDSLIDE = NON-ROTATED INTERVALS REFLECTING SENSOR DEPTHS. PARAMETERS USED IN POROSITY LOG PROCESSING: HOLE SIZES: 6.125" . MUD WEIGHT: 9.3 - 10.2 PPG MUD FILTRATE SALINITY: 300 FORMATION WATER SALINITY: FLUID DENSITY: 1.0 G/CC MATRIX DENSITY: 2.65 G/CC LITHOLOGY: SANDSTONE $ . - 1300 PPM CHLORIDES 25,000 PPM CHLORIDES File Header Service name............ .STSLIB.001 Service Sub Level Name. . . Version Number......... ..1.0.0 Date of Generation.. .....05/03/02 Maximum Physical Record..65535 File Type. .............. .LO Previous File Name...... .STSLIB.OOO Comment Record FILE HEADER FILE NUMBER: EDITED MERGED MWD Depth shifted DEPTH INCREMENT: # FILE SUMMARY PBU TOOL CODE GR DRHO RPX RPS RPM RPD FET NPHI FCNT RHOB PEF NCNT ROP $ 1 and clipped curves; all bit runs merged. .5000 START DEPTH 4375.0 4400.0 4400.0 4400.0 4400.0 4400.0 4400.0 4400.0 4400.0 4400.0 4400.0 4400.0 4429.5 STOP DEPTH 8565.0 8273.0 8577.5 8577.5 8577.5 8577.5 8577.5 8258.5 8258.5 8273.0 8273.0 8258.5 8621.0 # BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH ------. BASELINE DEPTH $ # MERGED DATA SOÙRCE PBU TOOL CODE MWD MWD MWD MWD $ # REMARKS: BIT RUN NO 4 5 6 7 MERGED MAIN PASS. $ MERGE TOP 4375.0 4962.5 5149.0 8350.0 MERGE BASE 4962.5 5149.0 8350.0 8621.0 # Data Format Specification Record Data Record Type..................O Data Specification Block Type... ..0 Logging Direction. . . . . . . . . . . . . . . . . Down Optical log depth units....... ... .Feet Data Reference Point............. .Undefined Frame Spacing.................... .60 .1IN Max frames per record... ....... ...Undefined Absent value. .................... .-999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O . . Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD FT/H 4 1 68 4 2 GR MWD API 4 1 68 8 3 RPX MWD OHMM 4 1 68 12 4 RPS MWD OHMM 4 1 68 16 5 RPM MWD OHMM 4 1 68 20 6 RPD MWD OHMM 4 1 68 24 7 FET MWD HOUR 4 1 68 28 8 NPHI MWD PU-S 4 1 68 32 9 FCNT MWD CNTS 4 1 68 36 10 NCNT MWD CNTS 4 1 68 40 11 RHOB MWD G/CM 4 1 68 44 12 DRHO MWD G/CM 4 1 68 48 13 PEF MWD BARN 4 1 68 52 14 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 4375 8621 6498 8493 4375 8621 ROP MWD FT/H 0.06 1141.7 79.576 8384 4429.5 8621 GR MWD API 35.05 505.58 141.283 8381 4375 8565 RPX MWD OHMM 0.7 1836.18 5.29422 8356 4400 8577.5 RPS MWD OHMM 0.1 2000 13.9414 8356 4400 8577 .5 RPM MWD OHMM 0.37 2000 16.1563 8356 4400 8577 . 5 RPD MWD OHMM 0.05 2000 23.0804 8356 4400 8577.5 FET MWD HOUR 0.31 92 .42 2.52079 8356 4400 8577.5 NPHI MWD PU-S 18.93 60.96 38.3507 7718 4400 8258.5 FCNT MWD CNTS 101.15 753.85 249.978 7718 4400 8258.5 NCNT MWD CNTS 13860.6 37001.1 20080.6 7718 4400 8258.5 RHOB MWD G/CM 0.614 3.208 2.35199 7747 4400 8273 DRHO MWD G/CM -4.281 0.475 0.0474213 7747 4400 8273 PEF MWD BARN 1. 76 14.8 3.33682 7747 4400 8273 First Reading For Entire File......... .4375 Last Reading For Entire File.......... .8621 File Trailer Service name. ........... .STSLIB.001 Service Sub Level Name. . . Version Number..... ..... .1.0.0 Date of Generation...... .05/03/02 Maximum physical Record. .65535 File Type............ ... .LO Next File Name.... ...... .STSLIB.002 Physical EOF File Header Service name..... ..... ...STSLIB.002 Service Sub Level Name. . . Version Number.......... .1.0.0 Date of Generation...... .05/03/02 Maximum Physical Record. .65535 File Type............ ... .LO Previous File Name.......STSLIB.001 Comment Record FILE HEADER FILE NUMBER: 2 RAW MWD Curves and log header data for each bit run in separate files. . BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE GR RPX RPS RPM RPD FET FCNT NCNT RHOB DRHO PEF NPHI ROP $ 4 .5000 START DEPTH 4375.0 4400.0 4400.0 4400.0 4400.0 4400.0 4400.0 4400.0 4400.0 4400.0 4400.0 4400.0 4429.5 # 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: # STOP DEPTH 4907.0 4915.0 4915.0 4915.0 4915.0 4915.0 4871.0 4871.0 4885.0 4885.0 4885.0 4871.0 4962.5 TOOL STRING (TOP TO VENDOR TOOL CODE DGR CTN EWR4 SLD $ BOTTOM) TOOL TYPE DUAL GAMMA RAY COMP THERMAL NEUTRON Electromag Resis. 4 STABILIZED LITHO DEN # 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 TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: . 03-FEB-05 Insite 66.37 Memory 4963.0 4429.0 4963.0 31.6 51.3 TOOL NUMBER 156436 110041 90518 64082 6.125 4234.0 LSND 9.40 52.0 10.5 1400 7.4 1.800 1. 400 1.500 1. 800 68.0 89.6 68.0 68.0 . . $ # Data Format Specification Record Data Record Type..................O Data Specification Block Type.....O Logging Direction..... ........... . Down Optical log depth units.... .......Feet Data Reference Point... ........ ...Undefined Frame Spacing.................... .60 .1IN Max frames per record............ .Undefined Absent value..................... .-999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD040 FT/H 4 1 68 4 2 GR MWD040 API 4 1 68 8 3 RPX MWD040 OHMM 4 1 68 12 4 RPS MWD040 OHMM 4 1 68 16 5 RPM MWD040 OHMM 4 1 68 20 6 RPD MWD040 OHMM 4 1 68 24 7 FET MWD040 HOUR 4 1 68 28 8 NPHI MWD040 PU-S 4 1 68 32 9 FCNT MWD040 CNTS 4 1 68 36 10 NCNT MWD040 CNTS 4 1 68 40 11 RHOB MWD040 G/CM 4 1 68 44 12 DRHO MWD040 G/CM 4 1 68 48 13 PEF MWD040 BARN 4 1 68 52 14 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 4375 4962.5 4668.75 1176 4375 4962.5 ROP MWD040 FT/H 0.18 175.82 69.3077 1067 4429.5 4962.5 GR MWD040 API 47 144.7 101.838 1065 4375 4907 RPX MWD040 OHMM 0.79 848.91 5.72844 1031 4400 4915 RPS MWD040 OHMM 1. 02 1094.12 6.06651 1031 4400 4915 RPM MWD040 OHMM 1.17 2000 21.1445 1031 4400 4915 RPD MWD040 OHMM 0.05 957.5 9.61134 1031 4400 4915 FET MWD040 HOUR 0.42 10.11 1.9498 1031 4400 4915 NPHI MWD040 PU-S 28.79 60.96 37.8025 943 4400 4871 FCNT MWD040 CNTS 101. 15 406.57 239.801 943 4400 4871 NCNT MWD040 CNTS 13860.6 25035.2 19206.5 943 4400 4871 RHOB MWD040 G/CM 0.614 2.939 2.24594 971 4400 4885 DRHO MWD040 G/CM -4.281 0.342 -0.00770649 971 4400 4885 PEF MWD040 BARN 2.24 14.8 3.3432 971 4400 4885 First Reading For Entire File...... ....4375 Last Reading For Entire File.......... .4962.5 File Trailer Service name............ .STSLIB.002 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation.. .... .05/03/02 Maximum Physical Record. .65535 File Type............... .LO Next File Name........ ...STSLIB.003 Physical EOF File Header . service name............ .STSLIB.003 service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .05/03/02 Maximum Physical Record. .65535 File Type......... ... ....LO Previous File Name..... ..STSLIB.002 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE NCNT NPHI FCNT RHOB PEF DRHO GR RPD FET RPX RPS RPM ROP $ 3 . header data for each bit run in separate files. 5 .5000 START DEPTH 4871.5 4871.5 4871.5 4885.5 4885.5 4885.5 4907.5 4915.5 4915.5 4915.5 4915.5 4915.5 4963.0 # 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: # STOP DEPTH 5060.5 5060.5 5060.5 5075.0 5075.0 5075.0 5096.5 5104.0 5104.0 5104.0 5104.0 5104.0 5149.0 TOOL STRING (TOP TO VENDOR TOOL CODE DGR CTN EWR4 SLD $ BOTTOM) TOOL TYPE DUAL GAMMA RAY COMP THERMAL NEUTRON Electromag Resis. 4 STABILIZED LITHO DEN # 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): 03-FEB-05 Insite 66.37 Memory 5149.0 4963.0 5149.0 51.3 57.8 TOOL NUMBER 151107 110041 148579 64082 6.125 4234.0 LSND 9.40 55.0 12.5 1300 5.6 1.900 66.0 . MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: 1. 450 2.000 1. 900 . 66.0 66.0 # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type....... ......... ..0 Data Specification Block Type.....O Logging Direction. . . . . . . . . . . . . . . . . Down Optical log depth units.......... .Feet Data Reference Point...... .... ....Undefined Frame Spacing... ....... ..... .... ..60 .1IN Max frames per record............ .Undefined Absent value..................... .-999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD050 FT/H 4 1 68 4 2 GR MWD050 API 4 1 68 8 3 RPX MWD050 OHMM 4 1 68 12 4 RPS MWD050 OHMM 4 1 68 16 5 RPM MWD050 OHMM 4 1 68 20 6 RPD MWD050 OHMM 4 1 68 24 7 FET MWD050 HOUR 4 1 68 28 8 NPHI MWD050 PU-S 4 1 68 32 9 FCNT MWD050 CNTS 4 1 68 36 10 RHOB MWD050 G/CM 4 1 68 40 11 DRHO MWD050 G/CM 4 1 68 44 12 PEF MWD050 BARN 4 1 68 48 13 NCNT MWD050 CNTS 4 1 68 52 14 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 4871.5 5149 5010.25 556 4871.5 5149 ROP MWD050 FT/H 0.31 192.28 84.4584 373 4963 5149 GR MWD050 API 92.9 135.78 112.891 379 4907.5 5096.5 RPX MWD050 OHMM 2.08 6.98 2.51913 378 4915.5 5104 RPS MWD050 OHMM 2.11 7.04 2.55254 378 4915.5 5104 RPM MWD050 OHMM 2.13 7.82 2.65553 378 4915.5 5104 RPD MWD050 OHMM 2.22 7.6 2.77188 378 4915.5 5104 FET MWD050 HOUR 0.44 12.17 3.65503 378 4915.5 5104 NPHI MWD050 PU-S 24.75 42.44 36.5705 379 4871.5 5060.5 FCNT MWD050 CNTS 198.95 577.8 269.671 379 4871.5 5060.5 RHOB MWD050 G/CM 2.198 2.606 2.32938 380 4885.5 5075 DRHO MWD050 G/CM -0.027 0.342 0.132197 380 4885.5 5075 PEF MWD050 BARN 2.38 5.69 3.89447 380 4885.5 5075 NCNT MWD050 CNTS 18040.4 29827.9 20990.6 379 4871.5 5060.5 First Reading For Entire File......... .4871.5 Last Reading For Entire File.......... .5149 File Trailer . Service name........... ..STSLIB.003 Service Sub Level Name... Version Number.. ........ .1.0.0 Date of Generation...... .05/03/02 Maximum Physical Record. .65535 File Type.............. ..LO Next File Name...... .....STSLIB.004 Physical EOF File Header Service name. .......... ..STSLIB.004 Service Sub Level Name... Version Number....... ....1.0.0 Date of Generation. .... ..05/03/02 Maximum Physical Record. .65535 File Type. . . . . . . . . . . . . . . . LO Previous File Name...... .STSLIB.003 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE NPHI FCNT NCNT PEF RHOB DRHO GR RPX RPS RPM FET RPD ROP $ 4 . header data for each bit run in separate files. 6 .5000 START DEPTH 5061.0 5061.0 5061. 0 5075.5 5075.5 5075.5 5097.0 5104.5 5104.5 5104.5 5104.5 5104.5 5149.5 # 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 DGR CTN EWR4 SLD $ # STOP DEPTH 8258.5 8258.5 8258.5 8273.0 8273.0 8273.0 8295.0 8302.0 8302.0 8302.0 8302.0 8302.0 8350.0 BOTTOM) TOOL TYPE DUAL GAMMA RAY COMP THERMAL NEUTRON Electromag Resis. 4 STABILIZED LITHO DEN 06-FEB-05 Insite 66.37 Memory 8350.0 5149.0 8350.0 31. 6 70.9 TOOL NUMBER 151107 110041 148579 64082 . 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 TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type..................O Data Specification Block Type.....O Logging Direction.. ......... .... ..Down Optical log depth units......... ..Feet Data Reference Point............ ..Undefined Frame Spacing.................... .60 .1IN Max frames per record............ . Undefined Absent value...................... -999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O . 6.125 4234.0 LSND 9.40 52.0 10.5 1400 7.4 2.000 1. 090 2.500 2.600 69.0 132.8 69.0 69.0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD060 FT/H 4 1 68 4 2 GR MWD060 API 4 1 68 8 3 RPX MWD060 OHMM 4 1 68 12 4 RPS MWD060 OHMM 4 1 68 16 5 RPM MWD060 OHMM 4 1 68 20 6 RPD MWD060 OHMM 4 1 68 24 7 FET MWD060 HOUR 4 1 68 28 8 NPHI MWD060 PU-S 4 1 68 32 9 FCNT MWD060 CNTS 4 1 68 36 10 NCNT MWD060 CNTS 4 1 68 40 11 RHOB MWD060 G/CM 4 1 68 44 12 DRHO MWD060 G/CM 4 1 68 48 13 PEF MWD060 BARN 4 1 68 52 14 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 5061 8350 6705.5 6579 5061 8350 ROP MWD060 FT/H 0.06 1141.7 85.8946 6402 5149.5 8350 GR MWD060 API 44.54 505.58 154.252 6397 5097 8295 RPX MWD060 OHMM 0.7 20.33 3.07417 6396 5104.5 8302 RPS MWD060 OHMM 0.77 20.27 3.27179 6396 5104.5 8302 RPM MWD060 OHMM 0.75 38.13 3.77315 6396 5104.5 8302 RPD MWD060 OHMM 0.8 31.7 3.99301 6396 5104.5 8302 FET MWD060 HOUR 0.31 15.56 1.14732 6396 5104.5 8302 . . NPHI MWD060 PU-S 18.93 60.57 38.5371 6396 5061 8258.5 FCNT MWD060 CNTS 143.81 753.85 250.312 6396 5061 8258.5 NCNT MWD060 CNTS 16557.4 37001.1 20155.6 6396 5061 8258.5 RHOB MWD060 G/CM 2.147 3.208 2.36944 6396 5075.5 8273 DRHO MWD060 G/CM -0.27 0.475 0.0507537 6396 5075.5 8273 PEF MWD060 BARN 1. 76 8.96 3.30272 6396 5075.5 8273 First Reading For Entire File.. ....... .5061 Last Reading For Entire File.......... .8350 File Trailer Service name............ .STSLIB.004 Service Sub Level Name... Version Number.. ........ .1.0.0 Date of Generation...... .05/03/02 Maximum Physical Record. .65535 File Type............... .LO Next File Name.......... .STSLIB.005 Physical EOF File Header Service name. .......... ..STSLIB.005 Service Sub Level Name... Version Number.... .......1.0.0 Date of Generation..... ..05/03/02 Maximum Physical Record. .65535 File Type............... .LO Previous File Name.... ...STSLIB.004 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE GR FET RPD RPM RPS RPX ROP $ 5 header data for each bit run in separate files. 7 .5000 START DEPTH 8295.5 8302.5 8302.5 8302.5 8302.5 8302.5 8350.5 STOP DEPTH 8565.0 8577.5 8577.5 8577.5 8577.5 8577.5 8621.0 # 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: ll-FEB-05 Insite 4.3 Memory 8621. 0 8350.0 8621. 0 23.1 30.7 # TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE GM EWR4 $ . TOOL TYPE Dual GR ELECTROMAG. RESIS. 4 # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type..................O Data Specification Block Type.....O Logging Direction....... ......... .Down Optical log depth units......... ..Feet Data Reference Point............ ..Undefined Frame Spacing.................... .60 .1IN Max frames per record...... ...... . Undefined Absent value... ........ ......... ..-999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O TOOL NUMBER. 72829 708 4.750 8348.0 LSND 11. 80 51.0 9.5 '500 5.2 4.000 2.340 3.700 4.500 78.0 138.1 78.0 78.0 Name Service Order units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD070 FT/H 4 1 68 4 2 GR MWD070 API 4 1 68 8 3 RPX MWD070 OHMM 4 1 68 12 4 RPS MWD070 OHMM 4 1 68 16 5 RPM MWD070 OHMM 4 1 68 20 6 RPD MWD070 OHMM 4 1 68 24 7 FET MWD070 HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 8295.5 8621 8458.25 652 8295.5 8621 ROP MWD070 FT/H 1. 66 89 21.7968 542 8350.5 8621 GR MWD070 API 35.05 126.79 85.3792 540 8295.5 8565 RPX MWD070 OHMM 1. 73 1836.18 32.1557 551 8302.5 8577.5 RPS MWD070 OHMM 0.1 2000 160.343 551 8302.5 8577.5 RPM MWD070 OHMM 0.37 2000 159.828 551 8302.5 8577.5 RPD MWD070 OHMM 0.05 2000 283.782 551 8302.5 8577.5 FET MWD070 HOUR 2.1 92.42 18.7543 551 8302.5 8577.5 . . First Reading For Entire File....... ...8295.5 Last Reading For Entire File.......... .8621 File Trailer Service name...... ...... .STSLIB.005 Service Sub Level Name... Version Number.... ..... ..1.0.0 Date of Generation..... ..05/03/02 Maximum Physical Record. .65535 File Type............... .LO Next File Name.......... .STSLIB.006 Physical EOF Tape Trailer Service name. ........... .LISTPE Date. . . . . . . . . . . . . . . . . . . . .05/03/02 Origin. . . . . . . . . . . . . . . . . . . STS Tape Name............... .UNKNOWN Continuation Number..... .01 Next Tape Name.. ........ .UNKNOWN Comments. .... .......... ..STS LIS Writing Library. Scientific Technical Services Reel Trailer Service name............ .LISTPE Date. . . . . . . . . . . . . . . . . . . . .05/03/02 Origin. . . . . . . . . . . . . . . . . . . STS Reel Name... ........... ..UNKNOWN Continuation Number..... .01 Next Reel Name.......... .UNKNOWN Comments................ .STS LIS Writing Library. Scientific Technical Services Physical EOF Physical EOF End Of LIS File