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206-016
C:\Users\mdguhl\AppData\Local\Microsoft\Windows\INetCache\Content.Outlook\LCF4WGUY\2022-11-24_21110_KRU_1J-152_ProductionProfile_Transmittal.docx DELIVERABLE DISCRIPTION Ticket #Field Well #API #Log Description Log Date 21110 KRU 1J-152 50-029-23298-00 Production Profile 24-Nov-22 DELIVERED TO Company & Address DIGITAL FILE # of Copies LOG PRINTS # of Prints CD’s # of Copies 1 AOGCC Attn: Natural Resources Technician 333 W. 7th Ave., Suite 100 Anchorage, Ak. 99501-3539 Delivered By: CPAI Sharefile ______________________________ ______________________________________ Date received Signature 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 By Meredith Guhl at 1:12 pm, Nov 29, 2022 206-016 T37337 Meredith Guhl Digitally signed by Meredith Guhl Date: 2022.11.29 13:13:04 -09'00' ~. 1~." w -,- ,~ i r ,. ~:. ~. ~' ,'-~ R S~ y`-< i`#: ~`_ ~..~ ~, _ ~.: ;X:; ~. ~.-. MICROFILMED 6/30/2010 DO NOT PLACE. ANY NEW MATERIAL UNDER THIS PAGE C:\temp\Temporary Internet Files\OLK9\Microfilm_Marker.doc C®no P ' ' eo hellips Alaska P.0. BOX 100360 ANCHORAGE, ALASKA 99510-0360 November 27, 2008 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7~' Avenue, Suite 100 Anchorage, AK 99501 C: 6 a s:~~r Dear Mr. Maunder: Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRU). Each of these wells was found to have a void in the conductor. These voids were filled with cement if needed and corrosion inhibitor, engineered to prevent water from entering the annular space. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treatments took place and meets the requirements of form 10-404, Report of Sundry Operations. Cement was pumped October 30, 2008 and the corrosion inhibitor/sealant was pumped November 7 and Novemberl 7, 2008. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please call MJ Loveland or Perry Klein at 907-659-7043, if you have any questions. ConocoPhillips Well Integrity Projects Supervisor ~i ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) Kuparuk Field n~~e 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 1 F-18A 204-167 15' 5" 2.50 44" 10/30/2008 27.2 11 /7/2008 1E-168 204-200 15" NA 15" NA 3.4 11/7/2008 1E-17 205-074 13" NA 13" NA 5.53 11/7/2008 1J-122 207-070 15" NA 15" NA 3.4 11/7/2008 1J-14 200-200 16" NA 16" NA 1.27 11/7/2008 1J-152' 206-016 3' NA 3' NA 19.55 11/17/2008 1J-158 207-054 6' NA 6' NA 27.2 11/7/2008 1J-162 2 7-080 15" NA 15" NA 2.55 11/7/2008 1 J-166 205-198 12" NA 12" NA 8.5 11 /7/2008 1J-168 205-060 10" NA 10" NA 3.82 11/7/2008 1J-170 206-062 8" NA 8" NA 1 11/7/2008 1 J-174 207-143 24" NA 24" NA 17 11 /7/2008 1J-178 207-121 12" NA 12" NA 5.95 11/7/2008 • SELL LiG _____ ar TRA/V~fVf/1 °TAL 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/ MTT) The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the following BP Exploration (Alaska), Inc. Petrotechnical Data Center Attn: Joe Lastuflca LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 and a05 -t°r'~f '~ /~$~( ProActive Diagnostic Services, Inc. UlCo ~ ~~ ~ .~ 2 Attn: Robert A. Richey ~~~ 130 West International Airport Road Suite C Anchorage, AK 99518 Fax: (907) 245-8952 1) Production Profile 02-Ju~08 1 J-152 2) Production Profile 03-JuE08 1 J-166 1 Signed : ~~ Print Name: ~ ~~ ~ ~-~t~ ~ ~n ~,, _0~~, G3L I EDE 50-029-23298-00 EDE 50-029-23291-00 Date PROACTIVE DIAGNOSTIC SERVICES, INC., 130 W. INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245-8951 Fax: (907)245-88952 y E-MAIL : psisarac~aor~s~e(t~saoertaorylog.calla WEBSITE : v~~a~r.~te~or~llog.~o~ C:\Documents and Settings\Owner\Desktop\Transmit_BP.doc ~. a. ~ DATA SUBMITTAL COMPLIANCE REPORT si2oi2oos Permit to Drill 2060160 Well NamelNo. KUPARUK RIV U WSAK 1J-152 Operator CONOCOPHILLIPS ALASKA INC MD 10053 TVD 3622 Completion Date 4/22/2006 Completion Status 1-OIL REQUIRED INFORMATION Mud Log No Samples No _. __ DATA INFORMATION Types Electric or Other Logs Run: GR/Res, CBL Welt Log Information: Log/ Electr Data Digital Dataset Log Log Run Type Med/Frmt Number Name Scale Media No Current Status 1-OIL API No. 50-029-23298-00-00 UIC N Directional Survey Yes (data taken from Logs Portion of Master Well Data Maint Interval OH / Start Stop CH Received Comments 'rED V D Asc Directional Survey 8346 10053 Open 6/27/2006 ', ~D D Asc Directional Survey 28 7646 Open 6/27/2006 D Asc Directional Survey 6761 9343 Open 6/27/2006 '~ D C Lis 13991 induction/Resistivity 0 0 Open 7/19/2006 IiED C Asc 13991 ~uction/Resistivity 0 0 Open 7/19/2006 !, Rpt 13991 LIS Verification 0 0 Open 7/19/2006 ',!E'D C Lis 1399'~Induction/Resistivity 0 0 Open 7/19/2006 C Asc 13991(~i'nduction/Resistivity 0 0 Open 7/19/2006 ', Rpt 13991 LIS Verification 0 0 Open 7/19/2006 QED C Lis 13991~Induction/Resistivity 0 0 Open 7!19/2006 ~D C Asc 13991 ~duction/Resistivity 0 0 Open 7/19/2006 Rpt 13991 LIS Verification 0 0 Open 7/19/2006 ~D C Lis 15036~tfiduction/Resistivity 2741 10053 Open 4/17/2007 FD i C Lis 15037rnduction/Resistivity 2741 7646 Open 4/17/2007 E'~ C Li ~ 15038 I ti i it d /R ti . s n v uc on es s y 2741 9343 Open 4/17/2007 ~ J,og Production 15 Blu 1 100 5500 Case 2/22/2006 PB 1 PB 2 LIS GR, ROP Text GR, ROP LIS GR, ROP PB 1 Text GR, ROP PB 1 PB1 LIS GR, ROP PB 2 Text GR, ROP PB 2 PB 2 LIS Veri, GR, FET, ROP w/Graphics CGM, EMF, PDF P61 LIS Veri, GR, FET, ROP w/Graphics CGM, EMF, PDF PB2 LIS Veri, GR, FET, ROP w/Graphics CGM, EMF, PDF PPL w/Maxtrac, pres, Temp, Gradio, Spin, Deft 18-Feb-2008 DATA SUBMITTAL COMPLIANCE REPORT 5/20/2008 Permit to Drill 2060160 Well Name/No. KUPARUK RIV U WSAK 1J-152 Operator CONOCOPHILLIPS ALASKA INC MD 10053 TVD 3622 Completion Date 4/22/2006 Completion Status 1-OIL Current Status 1-OIL Well Cores/Samples Information: Sample Interval Set Name Start Stop Sent Received Number Comments ADDITIONAL INFORMATION Well Cored? Y ~J Chips Received? -Y'TI~'" Analysis ~~ Received? Daily History Received? ~N Formation Tops ~ N API No. 50-029-23298-00-00 UIC N Comments: ~ ~ ~ ~ ~ ~- Compliance Reviewed By: Sn,; ~,.,~~.,~ Date: 17~i~~~~~~~~ Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Well Job # /V l~ NO. 4707 Company: Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Kuparuk Log Description Date BL Color CD 05/15/08 1F-12 11996623 PRODUCTION PROFILE / ~ 05/01/08 1 1 3J-11 11996624 PRODUCTION PROFILE CAL( ^ 05/02/08 1 1 3K-102 11963094 MEM PROD PROFILE aD'~ - ~ 05/09/08 1 1 iJ-152 11996632 GLS ( C 05/09/08 1 1 1E-166 11994665 GLS - / 05/11/08 1 1 1 E-168 11994665 GLS 05/10/08 1 1 iH-01 11996626 PRODUCTION PROFILE W/FSI J (o / - 05/10/08 1 1 2X-15 11996634 PRODUCTION PROFILE W/FSI - ~ 05/12/08 1 1 Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. C~ CJ ~ct~I~mC~erer Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Well Job # V ,: 02/20/08 NO. 4595 Company: Alaska Oil ~ Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Kuparuk Log Description Date BL Color CD 2L-319 11970619 SCMT - I 12131107 1 1A-02 11994615 INJECTION PROFILE / - 02/11/08 1 1F-10 11994616 . INJECTION PROFILE - /~ 02112108 1 2X-O8 11996603 INJECTION PROFILE U='C / ~, - (~ 02/13108 1 3N-11 11968841 INJECTION PROFILE - €~~ 02/16/08 1 1J-152 11994623 PRODUCTION PROFILE (o - / 02/18108 1 2W-17 NIA SBHP SURVEY ~ _ ~ ` 02/20108 1 Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION ~~~ ~l` REPORT OF SUNDRY WELL OPERATIONS 1. operations Pertormed: Abandon ^ Repair Well ^ Plug Perforations ^ >9$ Ot~ Stimulate ^ aS ~ ) Alter Casing ^ Pull Tubing Q Perforate New Pool ^ aa Waiver ^ ~'ime Exf~~5i8~~~ Change Approved Program ^ Operat. Shutdown^ Perforate ^ Re-enter Suspended Well ^ 2. Operator Name: 4. Well Class Before Work: 5. Permit to Drill Number: ConocoPhillips Alaska, InC. Development ^~ Exploratory ^ 206-016 / ' 3. Address: Stratigraphic ^ Service ^ 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-029-23298-00 ' 7. KB Elevation (ft): 9. Well Name and Number: , RKB 28', 108' AMSL 1J-152 8. Property Designation: 10. Field/Pool(s): ADL 25661 ~& 25662 Kuparuk River Field !West Sak Oil Pool • 11. Present Well Condition Summary: Total Depth measured 10053' feet true vertical 3622' feet Plugs (measured) Effective Depth measured 9840' feet Junk (measured) true vertical 3621' feet Casing Length Size MD TVD Burst Collapse Structural CONDUCTOR 108' 20" 108' 108' SURFACE 2664' 10-3/4" 2773' 2198' PRODUCTION 6414' 7-5/8" 6523' 3638' LINER 3979' 4.5" 9841' 3620' Perforation depth: Measured depth: slotted liner 6500'-6885', 7310'-8075', 8291'-8421', 8630'-8673', 8843'-9102', 9104'-9320', 9475'-9808' true vertical depth: 3636'-3633', 3662'-3639' , 3630'-3623',3630'-3632', 3632'-3633', 3632'-3632', 3629'-3621' Tubing (size, grade, and measured depth) 4-1/2" , L-80, 5352' MD. Packers & SSSV (type & measured depth) HRD ZXP liner pkr @ 5355' Camco 'DB' nipple @ 504' 12. Stimulation or cement squeeze summary: Intervals treated (measured) not applicable Treatment descriptions including volumes used and final pressure : 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casin Pressure Tubin Pressure Prior to well operation SI SI -- Subsequent to operation 1797 • 723 44 -- 200 14. Attachments 15. Well Class after work: Copies of Logs and Surveys run _ Exploratory ^ Development ^O Service ^ Daily Report of Well Operations _X 16. Well Status after work: Oi10 Gas ^ WAG ^ GINJ ^ WINJ ^ WDSPL ^ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or NIA if C.O. Exempt: none Contact Brett Packer Printed Name Brett Packer ~~ Title Ph 265 6845 Wells Group Engineer / / D t ~ ~ v Signature one: - a e / ( Pre a h ron Allsu Dr ke 263-4612 Form 10-404 Revised 04/2006 ~" ~~. Ir'kF ~ ~ 2Q0~ a ('~ Submit final O ly ~ ~,P~~ i - ----~ ., KRU 1 J-152 ~~' 1J-y 52 API: 500292329800 Well T e: - PROD An le TS: - de Heat Trace (20-2991 ~ ~ ~ SSSV Type:. NIPPLE - Orig 4/22/2006 Angle @ TD: 88 deg @ 10053 , OD:0.500) ~~ Com letion: Annular Fluid: Last W/O: 1/17/2008 Rev Reason: GLV C/O Reference Lo 22' RKB Ref Lo Date: Last U date: 1/30/2008 Last Ta TD: 10053 ftK6 Last Ta Date' Max Hole An le: 94 de 75i 1 ~~ . _ Casn Strin` -COMMON STRINGS A-San _stotted liner has 17 constrictor ackers) d ~ Descri lion Size _ _ To Bottom TVD Wt Grade Thread [ CONDUCTOR 20.000 0 108 108 62.50 H-40 WELDED jjj SURFACE 10.750 0 2773 2198 45.50 L-80 BTC y~ PRODUCTION 7.625 0 6523 3637 29.70 L-80 BTCM NiP ~ WINDOW D-SAND 8.000 5403 5404 - 3443. 0.00 (szs7-szs6, ~ ' WINDOW B-SAND 8.000 5747 5748 3507 0.00 oD:5.z1o) ~~ A-SAND SLOTTEDLINER 4.500 5862 9102 3633 11.60 L-80 BTC A-SAND SLOTTEDLINER 4 5n0 9102 9841 3621 12.60 L-Rn IBTM -- -- _ _ ~~ ' Tubing String -TUBING... Size Top Got tom _ TVD Wt 4 500 0 "352 ~ J-tP.1 12.60 _- Perforations Summary Interval ~ TVD Zone Status Ft SPF Date _ _Grade Thread L-80 _ IBTL~ -- T e Comment 6500 - 6885 3636 - 3633 WS A3,WS A2 385 32 3/29/2006 Slots Alternating solid/slotted pipe _ 7310 - 8075 3662 - 3639 WS A2 765 32 3/29/2006 Slots Alternatin solid/slotted i e 8291 -8421 3630 - 3623 WS A2 .130 32 3/29/2006 Slots Alternatin solid/slotted i e - 8630 - 8673 3630 - 3632 WS A2 43 32 3/29/2006 Slots Alternatin solid/slotted i e 8843 - 9102 3632 - 3633 WS A2 259 32 3/29/2006 Slots Alternatin solid/slotted i e 9104 - 9320 3632 - 3632 WS A2 216 32 3/29/2006 Slots Alternatin solid/slotted i e ANGER 9475 - 9808 3629 - 3621 WS A2 333 32 3/29/2006 Slots Alternating solid/slotted pipe Gas Lift MandrelslValves --- - St MD TVD Man Mfr .Man Type V Mfr V Type V ©D Latch Port TR© Date Run Vlv Cmnt (5399-5415, 1 3154 2403 CAMCO KBG-2-1R GLV 1.0 BK 0.125 1470 1/29/2008 oD:s.asa) 2 5064 3353 CAMCO KBG-2-1R OV 1.0 B K 0.312 0 1 /29/2008 Other lu s, e ui ., etc _ _ _ . -COMPLETION JEWELRY __ - De th TVD T e _ - -- Descri lion - ID 20 20 Heat Trace TYCO DDH HEAT TRACE 0.000 25 25 HANGER TUBING HANGER 3.900 HANGER (5742-5766 504 504 NIP CAMCO'DB' NIPPLE 3.875 , OD:6.750) 5297 3419 NIP CAMCO DB NIPPLE 3.812 ~ 5298 3419 GAUGE BAKER POLARIS GUARDIAN GAUGE CARRIER w/GUARDIAN PRESSURE TEMP PUMP GAUGE 0.000 5352 3431 SEAL BAKER GBH-22 192-47 LOCATING SEAL ASSEMBLY 3.880 1-" ~ 5355 3432 PACKER D-SAND BAKER ZXP LINER TOP PACKER 4.950 L 5363 3434 SBE D-SAND SEAL BORE EXTENSION 190-47 4.750 5383 3438 XO Bushing D-SAND LEM BAKER CROSSOVER BUSHING 3.950 5388 3439 HANGER D-SAND LEM BAKER ABOVE HOOK HANGER 3.690 5399 3442 HANGER D-SAND LEM BAKER BELOW HOOK HANGER 3.690 ~ 5485 3460 SEAL D-SAND LEM BAKER NON-LOCATING SEAL ASSEMBLY 3.880 Other lu s, equip., etc .) - A-SAND LINER DETAIL De th TVD T e Descri lion ID 5862 3527 PACKER A-SAND LINER HRD ZXP LINER TOP PACKER 4.970 R 5880 3530 NIP A-SAND LINER'RS' PACKOFF SEAL NIPPLE 4.875 ~°'~ ''' `: . ,- " ~ 5883 3530 HANGER A-SAND LINER FLEXLOCK LINER HANGER 4.853 , . 5893 3532 SBE A-SAND LINER 190-47 CASING SEAL BORE EXTENSION 4.750 I - 5913 3535 XO A-SAND LINER CROSSOVER BUSHING 3.830 ~ ~ 9840 3621 SHOE _ A-SAND LINER ROT WEATHERFORD GUIDE SHOE 3.500 . Other _ ___ lu s, a ui ., etc. - B-SAND L_EM - ~ I De th TVD T e Descri lion _ ID ~ ~ - 5502 3463 PACKER B-SAND LEM ZXP LINER TOP PACKER 4.970 I 5521 3467 CSR B-SAND LEM 109-47 CASING SEAL BORE RECEPTACLE 4.750 5541 3471 XO B-SAND LEM CROSSOVER BUSHING 3.830 ~ ~ 5732 3504 HANGER B-SAND LINER LEM ABOVE HOOK HANGER 5.320 I ~ ~ 5742 3506 HANGER B-SAND LINER LEM INSIDE HOOK HANGER 5.32_0 General Notes - -- -_- _ Date Note I 4/24/2006 NOTE: MULTI-LATERAL WELL: 1J-152 A-SAND , 1J-152L1 B-SAND , 1J-152L2 D-SAND ~ ~ - 10/6/2007 NOTE: WAIVERED WELL T x IACOMMUNICATION - PACKERLESS WELL, FAILED ESP 1/17/2008 NOTE: WORKOVER PULLED ESP ASSY; NEW COMPLETION w/GLM/NIPPLE/LEM - I ~ ~ . I . ' ' _ ConocoPhillips Time Log Summary ktief7v7ew 4Yeb Red°rtfng _ ~ _ Well Name: 1 J-152 - _~ -~- Job Type: RECOMPLETION Time Loys _-__ Date From To Dur S_Depth_ E_, Depth Phase Code Subcode T COM ___ 01/09/2008 16:00 00:00 8.00 MIRU MOVE MOB P RD move rig from 2A-18 to 1J-152 01/10/2008 00:00 10:30 10.50 MIRU MOVE MOB P Continue moving rig & camp from 2A-18 to 1J-152. Arrived on location with rig @ 10.00 am. Arrived with Cam 12:30 m. 10:30 17:30 7.00 MIRU MOVE OTHR P While Pad Maint. removing Thermosiphon. Removed 11" BOPE from stump in cellar and replacing with 13 5/8". S of cam and level. 17:30 19:30 2.00 MIRU MOVE MOB P Move rig around pad to 1J-152 well, s of ri over well, level same. 19:30 20:30 1.00 MIRU MOVE RURD P Berm up cellar and spot rock washer building. Run hardline and tie in kill tank to rig. Rig accepted this day, the 10th of Jan 2008 1930 hours. 20:30 00:00 3.50 COMPZ WELC KLWL T Attem ted to ull BPV, wellhead frozen. RU steam lines and bring in heater, apply heat to wellhead for thaw. 01/11/2008 00:00 03:00 3.00 COMPZ WELCT OTHR T Finish thawing wellhead, pull BPV, Attempt to circulate and kill well, kill lines froze. Work through system and thaw same. 03:00 07:00 4.00 COMPZ WELCT CIRC P P-test kill lines. Press at start 190 psi TBG, 200 psi IA, start pumping 6% KCL down tubing with IA open to kill tank. At 83 bbls away, IA pressure started dropping, Ramp pumps up to 5 bpm while venting gas. Achieved circulation @ last 188 bbls pumped. Pumped total 200 bbls 140 deg F 6% KCL down tbg. Swap lines, start pumping down IA w/ returns up tbg. Pump 90 bbls 140 deg 6% KCL, Chase with 110 bbls 120 deg 6% KCL. Had full returns up tubing throughout pumping procedure on IA. Pumped down IA @ 4 bpm. Swapped from kill tank back to pits and circulated another 60 bbls. to clean hole. Shut in, monitor well, IA='0' tb ='0'. 07:00 08:00 1.00 COMPZ WELCT NUND P B/D & R/D circ. lines 08:00 10:30. 2.50 COMPZ WELCT NUND P N/D tree & hang in cellar. Set test lu 10:30 16:00 5.50 COMPZ WELCT NUND P N/U 13 5/8" BOPE. C Time Logs _ Date Frorn To Dur S Depth E. Depth Phase Code Subcode T COM __ 01/11/2008 16:00 17:00 1.00 COMPZ RPCOti RURD P Load empty ESP spool on floor w! crane. 17:00 23:30 6.50 COMPZ WELCT NUND P Finish NU 13 5/8" 5M BOPE. 23:30 00:00 0.50 COMPZ WELCT BOPE P Testing BOPE 250 psi Low, 2500 psi Hi h. 01/12/2008 00:00 05:00 5.00 PROD1 WELC BOPE P Testing BOPE to 250 psi low, 2500 si hi h. 05:00 08:00 3.00 PROD1 WELC WOEO NP Waiting on test jt for lower rams. Trouble locatin . 08:00 09:00 1.00 PROD1 WELCT BOPE P Test lower pipe rams 250/2500 psi. 09:00 10:00 1.00 PROD1 RPCOh NUND P Pull blankin lu & BPV. Fill hole 25 bbls . 10:00 10:30 0.50 PROD1 RPCOh SFTY P PJSM on pulling ESP. 10:30 12:00 1.50 PROD1 RPCOti NUND P Screw into the tubing hanger with the landing jt. Mark pipe at the rotary table. BOLDSs on tubing hanger. Unland tubing hanger and pull to rig floor. Lay down hanger, attach ESP cable to spooler. Pulled 150 klbs to unseat, PU 95 klbs, SO 75 klbs, 12:00 14:30 2.50 PROD1 RPCOh OTHR P Load 170 jts 3 1/2" IF, Drill Pipe in shed so it can be warming up while ESP is being pulled. Strap & tally same. 14:30 20:30 6.00 PROD1 RPCOh PULD P POOH standing back the 4 1/2" tubin ,removing all jewelry, and s oolin u the ESP cable. 20:30 23:00 2.50 PROD1 RPCOh PULD P Disconnect, Break-out and LD ESP. 23:00 00:00 1.00 PROD1 RPCOti OTHR P Shuffle components in pipe shed, clear /clean floor for next o eration. 01/13/2008 00:00 02:30 2.50 PROD1 RPCO CIRC P Shuffle tubing in pipe-shed. MU Wash BHA and break circulation at surface. Ramp up rate to get baseline data on circulation parameters. Achieved 6 bpm (252 gpm) @ 2400 psi. Decision made to pull circulating subs, pick up and RIH open ended w/ BHA and 3 1/2" DP, circulate to flush out any debris in DP before attempting wash routine. 02:30 04:00 1.50 PROD1 RPCOh PULD P Break out lateral and bottom wash subs, MU remainin BHA. 04:00 08:00 4.00 PROD1 RPCO PULD P PU and RIH w/ 3 1/2" IF DP workstring o en-ended. 08:00 08:30 0.50 PROD1 RPCOh CIRC P Pumped 40 bbls (DP vol) to clean out drill i e. 4 BPM w/180 si. 08:30 09:00 0.50 PROD1 RPCO PULD P Pull and stand back 3 stnds. PU and run 9 ~ts. 09:00 09:30 0.50 PROD1 RPCO CIRC P Pumped 50 bbls to clean out drill pipe. 5 BPM w/380 si. 09:30 12:00 2.50 PROD1 RPCOti PULD P POOH standing back drill pipe and drill collars. Page 2 €~t 5 Time Logs Date From To Dur S. De th E. De th Phase Code Subco de T COM 01/13/2008 12:00 15:00 3.00 PROD1 RPCOM1 _ PULD P _ ___ Break out BHA and install wash nozzles and RIH to 650'. 15:00 15:30 0.50 PROD1 RPCOh CIRC P Pump to get baseline data on pumping parameters. Achieved 6 BPM @ 2460 si. 15:30 17:30 2.00 PROD1 RPCO PULD P Continue to RIH with Wash BHA to 5303'. 17:30 18:00 0.50 PROD1 RPCO OTHR P Put steam to Top Drive and lubricate. 18:00 20:00 2.00 PROD1 RPCOb CIRC P MU top drive, establish pumping parameters, wash from 5332.5 - 5539.5 (ORKB) @ 5 bpm & 1850 psi. Reci rocate throu h hook area and . Established circulation, able to um at 5 b m w/ 50% returns. 20:00 21:00 1.00 PROD1 RPCO CIRC P Rack 1 stand and CBU @ 6 bpm & 2800 psi. Blow down top drive, monitor well f 21:00 23:00 2.00 PROD1 RPCOA TRIP P TOH from 5497' - 459'. 23:00 00:00 1.00 PROD1 RPCOh PULD P Break out and LD BHA #2. Inspect wash subs, OK. 01/14/2008 00:00 01:30 1.50 PROD1 RPCOM1 PULD P LD wellbore wash BHA and remove from floor. 01:30 02:30 1.00 PROD1 RIGMN SVRG P S&C Drill line. 02:30 03:30 1.00 PROD1 RPCOh OTHR P Organize pipe shed and floor, ready all to ick u LEM ass . 03:30 06:30 3.00 PROD1 RPCOh PULD P Picking up LEM Assembl and runnin tools. 06:30 11:00 4.50 PROD1 RPCOh PULD P RIH with LEM Assembly on Drillpipe to 5351'. U wt. 110K Dwn wt 75K 11:00 11:30 0.50 PROD1 RPCO PULD P Oriented LEM w/MWD. 11:30 14:00 2.50 PROD1 RPCO HOSO P Lowered LEM down and engaged hook hanger @5398'. MWD showed LEM window @ 3 degress left. Snapped out of hook hanger w/20K overpull. Repeat process 3 times to verify orientation of 3 degrees left. Picked up single and rigged up circulating lines. Dropped 1 3/4" ball. Snapped in and out 2 more times to verify engagement., Pressured up to 4000 si set acker and relea ool. Tested acker to 2500 si and charted. Broke lines off, pulled up and released running tool. New top of liner 5344'. 14:00 17:00 3.00 PROD1 RPCOti OTHR P Change out ESP spool and install I-wire control lines ool. 17:00 23:30 6.50 PROD1 RPCO PULD P POOH laying down 4 1/2" drillpipe. 23:30 00:00 0.50 PROD1 RPCOh PULD P PJSM, LD LEM running BHA. 01/15/2008 00:00 01:30 1.50 PROD1 RPCOh PULD P PJSM, Finish break-out and LD BHA. Page 3 ~f ~ Time Logs _ _ __ Date From To Dur S. De th E. De th Phase Code Subcode T COM 01/15/2008 _ 01:30 02:30 1.00 PROD1 RPCOh PULD P Remove BHA tools from rig. Pull wear bushin ,clear floor. 02:30 18:00 15.50 PROD1 RPCO WOEQ NP Wait on equipment needed to assemble final completion string prior to RIH. While waiting on equipment crew continued to rig up sheeves for I wire and heat sensor. Along w/ 20 extra 'ts of 4.5 12.6# I BTM L-80 tb . 18:00 18:30 0.50 PROD1 RPCOh SFTY P Held PJSM w/ Rig crew and Third Part Contractors 18:30 21:00 2.50 0 357 PROD1 RPCO PULD P Pick up & Rih w/ GBH-22 Locating Seal Assembly 1 jt of tbg and Polaris Guardian pressure / tempature gauges w/ 3.813" DS Nipple (used 3 SS bands). Rih w/ 7 jts of tbg w/single cannon clamps @ ea coupling, GLM #1 w/ SOV, 1 't 21:00 23:30 2.50. 357 2,389 PROD1 RPCOh Continue to Rih w/ tbg from derrick w/ single cannon clamps @ ea coupling to 2389'. 23:30 00:00 0.50 2,389 2,420 PROD1 RPCOti PJSM, Start Heat Trace and Rih to 2420' 01/16/2008 00:00 05:00 5.00 2,420 3,020 PROD1 RPCO RCST P Continue to Rih f/ 2420' installing heat trace, Tec wire and cannon clam s. 05:00 06:30 1.50 3,020 3,020 PROD1 RPCOh RCST P Shut down running to test cable and than a out sheave for the I-wire. 06:30 12:00 5.50 3,020 4,077 PROD1 RPCOh RCST P Continue to RIHf/ 2420' t/ 4077'. Installing heat trace, Tec wire and cannon clamps. Crew Change. 75k u wt. 68k do wt. 12:00 20:00 8.00 4,077 5,382 PROD1 RPCOh RCST P PJSM, Continue to Rih f/ 4077' to 5349' and tag top of ZXP Tie back sleeve@ 5349'. Work into tie back sleeve w/ 1/2 turn, and Rih to 5384' bottom of seals and locator (cil 5355'. Pressure test to 500 i. 20:00 22:30 2.50 5,382 5,330 PROD1 RPCO HOSO P Space out to 5382' @ bottom of seal assy. PU and MU 2 space out pups (15'), 1 jt and hanger w/ MCA Landing 't. 22:30 00:00 1.50 5,330 PROD1 RPCOh OTHR P Install Penetrators and install splices in tech wire and heat trace. 01/17/2008 00:00 01:00 1.00 PROD1 RPCOh OTHR P Continue to Splice I Tech and Heat Trace and tie into Penetrator. 01:00 02:30 1.50 PROD1 RPCOh CIRC P pump 35 bbls corrosion inhibited sea water followed b 100 bbls sea water. 02:30 04:00 1.50 PROD1 RPCOA HOSO P Land Hanger and RILDS. RU to test IA 04:00 04:30 0.50 PROD1 RPCO SFEO P Pum on IA attempting to work air from s stem rior to chart test and rematural shear out SOV 1150 si. 04:30 08:00 3.50 PROD1 RPCOCV WOEQ T CaII for Slick line to change out 1500 psi SOV to 2000 psi SOV. RD heat trace sheave. Pa€~e 4 of 5 n Time Logs Date From To -- _ _ Dur S Depth E. De th Phase Code Subcode T ---- COM __ _- -__-- 01/17/2008 08:00 13:30 5.50 PROD1 RPCOM1 OTHR T PJSM on RU slick line. RU slickline and attempt to run plug in DB nipple @ 5298'. Unable to get past 4500'. Dropped Standing valve and attempted to push down with weight. Could not et ast 4500'. POOH with slickline. 13:30 15:30 2.00 PROD1 RPCOh DHEQ P RD slickline. RU hoses and pumped standing valve down on seat of DB nipple @ 5298'. _Pressured up on , IA/tubing combination to 2500 psi and charted for 30 min. 15:30 16:00 0.50 PROD1 RPCOti NUND P Bled off pressure. Back out landing jt. and la ed down. Set two-wa check. 16:00 18:00 2.00 PROD1 RPCO NUND P PJSM. ND BOPE 18:00 22:30 4.50 PROD1 RPCOh NUND P PJSM. NU Tree and test hanger void and Tree to 5,000 psi f/ 10 min. Good test. 22:30 00:00 1.50 PROD1 RPCO FRZP P RU LRS and pressure test circ. lines to 3,000 psi. Freeze protect w/ 87.5 bbls diesel. U tube tbg x IA. RD LRS set HBPV. 2052 bbls KCL Seawater lost to well during workover. Release ri 23:59 hrs. ~ ~~ye ~S of 5 ~ ~ o ~ d d ~ SARAH PAUN, GOVERNOR L7W[>•~70[>• Ou ~ ~ 333 W. 7th AVENUE, SUITE 100 C011TSER~A~'IO1Q COM11iISSIOIQ ANCHORAGE. ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 MJ Loveland Problem Well Supervisor ConocoPhillips Alaska, Inc. PO Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, West Sak Oil Pool, 1J-152 Sundry Number: 307-303 Dear Ms. Loveland: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless. rehearing has been requested. Sincerely, ~~d~ Dan T. Seamount Commissioner DATED this ~ day of October, 2007 Encl. ~CSlo -bl fo ConocoPhiliips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 September 27, 2007 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 ~~~ ~~ . ~~ ,. ~, j 1 ~a -~~- Dear Mr. Maunder: Enclosed please find a 10-403 Sundry Notice variance request for ConocoPhillips Alaska, Inc., West Sak well 1J-152, 1J-152L1, and 1J-152L2 (PTD #'s 2060160, 2060170, 2060180). The variance request is for approval to temporarily use gaslift to produce the ESP completed well. Also attached is a discussion and well schematic. Please call MJ Loveland or myself at 907-659-7043, and 907-659-7224 respectively if you have any questions. Sincerely, Brent Rogers Problem Well Supervisor Attachments ® f STATE OF ALASKA ` ALASKA OIL AND GAS CONSERVATION COMMISSION t~~.> d(;T ~„ 7 APPLICATION FOR SUNDRY APPROVAL Kaska ~~! ~t ~, 20 AAC 25.280 1. Type of Request: Abandon ^ Suspend. ^ Operational Shutdown ^ . Perforate ^ Waiver Other. ^ Alter casing ^ Repair well ^ Plug Pertorations ^ Stimulate ^ Time Extension ^ Change approved program ^~ ~ Pull Tubing ^ Perforate New Pool ^ Re-enter Suspehded Well ^ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska, 1nC_ Development ^~ - Exploratory ^ 206-016. 3: Address: Stratigraphic ^ Service ^ 6; API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-029-23298-00 ° 7. If perforating, closest approach in pool(s) opened by this operation to nearest property line 8. Well Name and Number: where ownership o r landownership changes: Spacing Exception Required? YeS ^ NO ^Q ~ 1J-152. 9. Property Designation:. 10. KB Elevation (ft): 11. Field/Pool(s): ADL 25661 & 25662'. ALK 471 & 2177. RKB 109' Kuparuk River Field /West Sak Oil Pool 12. PRESENT WELL CONDITION SUMMARY Total depth MD (ft): Total Depth TVD (ft): Effective Depth M~ (n): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 10053' '' 3622' Casing Length Size MD TVD Burst Collapse CONDUCTOR 108'. 20" 108' 108'. SURFACE 2664' 10-3/4" 2773' 2198` WINDOW D-SAND 1' 7-5/8" 5404' 3443` WINDOW B-SAND 1' 7-5/8" 5748' 350T PRODUCTION 6414' 7-5/8" 6523' 3637 Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): Zones FR 6500' - 9808' Zones FR 3621"- 3662' 4-1/2" L-80 4892' Packers and SSSV Type: Packers and SSSV MD (ft) no packer no SSSV no SSSV 13. Attachments:: Description Summary of Proposal Q 14. Well Class after proposed work:. Detailed Operations Program ^ BOP Sketch ^ Exploratory ^ Development Q ~ Service 15. Estimated Date for 16. Well Status after proposed work: Commencing Operations:. October 3, 2007 Oil ^~ - Gas ^ Plugged ^ Abandoned ^ 17. Verbal.Approval Date: WAG ^ GINJ ^ WINJ ^ WDSPL ^ Commission Representative: 18. I hereby certify that the foregoing is true a nd correct to the best of my knowledge. Contact: M J Loveland / Perry Klein Printed Name: M J Loveland Title: Problem Well Supervisor Signature Phone 659-7224 Date 09/27/07 Commission Use Only Sundry Number.. Conditions of approval: Notify Commission so that a representative may witness 3 ofj - 3 a3 Plug.Integrity ~ BOP Test ^ Mechanical Integrity Test ^ Location Clearance ^ Other: ~ 1AF~- ~~i ,~ 7~~~ Subse uent Form Re uired: q q h~'t1fC \ 1 ~ ~~~`~ `5 "T~~'~fC ~fJ.'~S`~3~E QtT,'~:r,3 , _ `~- rTi~.J~~"tE~~r ~feyr„R~~ G)`~ ''Cl.'~a. Y~~ - -C _ RR ~~ Gr NN ~ L ~ ~ APPROVED BY ! ~ ~~,I /~ Approved by: ~R' OMMTSSTO THE COMMISSION Date: Form 10-403 Revised 06/2006 ,~ iok2.~7 Sub ~~~.~ ConocoPhillips Alaska, Inc. West Sak Injection Well 1J-152 (PTD 2060160) & 1J-152L1 (PTD 2060170) & 1J-152L2 (PTD 2060180) SUNDRY NOTICE 10-403 VARIANCE REQUEST 09-27-07 The purpose of this Sundry Notice is for approval to produce dual lateral West Sak producer 1J- 152 via gas lift until the failed ESP is replaced. The well is completed as an ESP (electric submersible pump) producer and does not have a packer. 1J-152 was completed in April, 2006. The well produced via ESP until 09/11/07, at which time it was shut-in due to a downhole motor electrical failure. The A-well gauges (suction and temperature) flat lined starting August 22 as the ESP was ramped up after CPF 1 came back online post ESD test so we have no down hole telemetry during the failure. The failure mechanism will not be known until the ESP is pulled and torn down. A no-flow situation is suspected to have occurred, followed by the motor overheating or another form of electrical burnout. A no-flow condition or high motor temperature would have been caught by the down hole gauge readings had they been working. The tubing is configured with two gas lift mandrels at 3138' RKB (2395' TVD) and 4210' RKB (2986' TVD). A GLV was installed at 3138' and an orifice valve was installed at 4210'. Gas lift will be applied in the "standard" configuration; i.e., gas will be injected down the annulus and enter the tubing through the gaslift and orifice valves. Attached is a motherbore well diagram of the well. The following is a summary of the proposed plan: 1. The AOGCC approve this request for a time period not to exceed 24 months from the approval date; 2. Should a workover not be completed within the approved time period the AOGCC will be contacted for a review and discussion of the plan forward. HANGER (5399-5415, OD:8.470) HANGER (5742-5766, OD:6.750) "='.- v.~: ~ ^ ~ ~ ~ ~ ^ ~ s ~ KRU 1 J-152 1 J-152 oar ~nmo~z~aunn I w~Pu Tvna~ I PRnn Anale na TS: ~ dea Ca) i----- SSSV Type::' NONE Oriq Completion ; 4/22/2006 _ - Angle @ TD 188 deg @ 10053 T Annular Fluid: i Last W/O: Rev Reason. ,NEW WELL _ Reference Log 22' RKB Ref Log Date: Last U date. ; 5!13/2006 ' Last Ta TD: ~ 10053 ftK6 I Last Tag Date ; Max Hole Angle:' 94 deg @ 7511 j Casing String -COMMON STRINGS A-Sand slotted liner has 11 constrictor ackers _~ ! Descri tion I Size Top ' Bottom _TVD ~ Wt Grade Thread CONDUCTOR 20.000 0 ' 108 __ 108 62.50 ' H-40 WELDED SURFACE 10.750 I 0 ' 2773 2198 45.50 L-80 BTC ' PRODUCTION 7.625 0 ~ 6523 3637 29.70 I L-80 BTCM WINDOW D-SAND 8.000 ' 5403 5404 3443 ~ 0.00 WINDOW B-SAND 8.000 5747 5748 3507 0.00 ~ A-SAND SLOTTEDLINER 4.500 5862 i 9102 3633 A-SAND SLOTTEDLINER 4.500 9102 9841 3621 ~ 11.60 ~ L-80 BTC 12.60 ! L-80 i IBTM Tu6in` Strin ' -TUBING ' Size To Bottom TVD Wt Grade ! Thread 4.500 0 4892 3286 ~ 12.60 L-80 IBTM I Perforations Summa Interval TVD Zone Status Ft ! SPF Date T e Comment 6500 - 6885 3636 - 3633 WS A3,WS A2 1385 32 3(29/2006 Slots Alternating solid/slotted pipe 7310 - 8075 3662 - 3639 WS A2 ! 765 32 3/29/2006 Slots Alternatin solid/slotted i e 8291 - 8421 3630 - 3623 WS A2 130 32 3/29/2006 Slots Altematin solid/slotted i e 8630 - 8673 ! 3630 - 3632 WS A2 43 32 3/29/2006 Slots : Alternatin solid/slotted i e 8843 - 9102 3632 - 3633 WS A2 ' 259 32 3/29/2006 ' Slots Alternatin solid/slotted i e 9104 - 9320 ~ 3632 - 3632 WS A2 ' 216 32 3/29/2006 Slots Alternatin solid/slotted i e 9475 - 9808 3629 - 3621 WS A2 333 , 32 3/29/_2006 Slots Alternatin solid/slotted i e ' Gas Lift MandrelsNalves - _ St MD TVD Man Man Type i Mfr V Mfr V Type V OD ~ Latch ' I T Port TRO Date Run Vlv '~ ~, Cmnt 1 3138 2395, CAMCO ~ KBMG SOV 1.0 BEK-5 ' 0.000 0 ~ 4/22/2006 2 4210 2986' CAMCO I KBMG DMY ~ 1.0 BK-5 0.000 0 ' 4/22/2006 Other lu s a ui etc. = COMPLETION`JEWELRY ' De th TVD T e Descri tion ID 23 23 HANGER VETCO GRAY TUBING HANGER 4.500 4752 3227 DIS. SUB A-WELL DISCHARGE SUB ' 0.000 4830 3260 i XO TTC CROSSOVER w/SCREEN INTAKE 0.000 4840 3264 SEAL TANDEM SEAL SECTION GSB 3 DB AB/HSN PFSA ' 0.000 4854 3270 ~ MOTOR/ PUMP MOTOR 418 HP KMHFER 2610 / 98 "w/ PUMP INSTALLED IN MOTOR" 0.000 4888 3284 GAUGE A-WELL PUMP GAUGE 0.000 4890 3285 Centralizer MOTOR CENTRALIZER '. 0.000 5399 3442 HANGER D-SAND BAKER MODEL B-1 HOOK HANGER INSIDE CASING 4.020 Other ha s, a ui et c. = A-SAND LINER JEWELRY De th TVD T e Descri tion ID ~ 5862 3527 PACKER ! HRD ZXP LINER TOP PACKER 4.970 5880 3530 i NIP 'RS' PACKOFF SEAL NIPPLE 4.875 5883 3530 HANGER FLEXLOCK LINER HANGER ~ 4.853 5893 3532: SBE 190-47 CASING SEAL BORE EXTENSION 4.750 5913 3535 XO CROSSOVER BUSHING ~ 3.830 9840 3621 SHOE ROT WEATHERFORD GUIDE SHOE 3.500 Other lu s, a ui ', etc.) - B-SAND LEM ; De th TVD ! T e Descri tion ID 5502 ' 3463 PACKER ZXP LINER TOP PACKER 4.970 5521 3467 , CSR 109-47 CASING SEAL BORE RECEPTACLE ~ 4.750 5541 ~ 3471 XO CROSSOVER BUSHING 3.830 5732 3504 ~ HANGER LEM ABOVE HOOK HANGER ' 5.320 5742 HANGER 3506 HANGER LEM INSIDE HOOK 5.320 _ General Notes _ Date Note 4/24/2006 MULTI-LATERAL WELL: 1J-152 A-SAND , 1J-152L1 B-SAND , 1J-152L2 D-SAND 1J-152 PTD # 206-016, failed ESP ~ ~ Page 1 of 1 ,. ' . Regg, James B (DOA) From: NSK Problem Well Supv [n1617@conocophillips.com] Sent: Saturday, September 15, 2007 5:23 AM To: Maunder, Thomas E (DOA); Regg, James B (DOA) ~~~, ~ (2(a ~C7 Subject: 1J-152 PTD # 206-016, failed ESP Attachments: 1 J-152. pdf Tom, 1J-152 PTD # 206-016, ESP producer, experienced a pump failure. Operations plans on converting the well to gas lift production indefinitely until a work over can be completed. The appropriate paperwork will be submitted for the lift conversion. Let me know if you have any questions. Perry Klein Problem Well Supervisor office (907) 659-7224 Cell (907) 943-1244 Pager (907) 659-7000 x909 n1617@conocophillips.comProblem Wells Supervisor «1 J-152. pdf» 9/26/2007 KRU 1 J-152 1J-152 -- -- ? -- - API: 500292329800 WeII T e: PROD An le TS: d ~, SSSV T e: NONE Ori Com letion: 4/22/2006 An le TD: 88 d 10053 Annular Fluid: Last W/O: Rev Reason: NEW WELL :~" Reference L : 22' RKB Ref L Date: Last U date: 5/13!2006 _ Last Ta TD: 10053 ftK6 ,~, Last Tag ,Date: _ Max Hole Angle_ 94 d~ @ 7511 _ -- -- Casing String - COMMON S_T_ RINGS A-Sand slotted liner has 11 ~ constrictor packers) ~ Descri tion Size To Bottom TVD Wt Grade Thread CONDUCTOR 20.000 0 108 108 62.50 H-40 WELDED SURFACE 10.750 0 2773 2198 45.50 L-80 BTC PRODUCTION 7.625 0 6523 3637 29.70 L-80 BTCM WINDOW D-SAND 8.000 5403 5404 3443 0.00 WINDOW B-SAND 8.000 5747 5748 3507 0.00 A-SAND SLOTTEDLINER 4.500 5862 9102 3633 11.60 L-80 BTC A-SAND SLOTTEDLINER 4.500 9102 9841 3621 12.60 L-80 IB T M Tubing Strin~c -TUBING ... _ __ __ .. ,- ,~~ -_-. - ~ _ Size +_ Top.. Botto~ TVD Wt Grade ~ Thread - - 4 500 ~ 0 4892 3246 12.60 L-4G IETM _- Perforations Summary _ Interval TVD Zone Status Ft SPF Date T e Comment 6500 - 6885 3636 - 3633 WS 385 32 3/29/2006 Slots Alternating solid/slotted pipe >~''` A3,WSA2 HANGER =~~ ~ 7310 - 8075 3662 -3639 WS A2 765 32 3/29/2006 Slots Alteratin solid/slotted i e (5399-5415, ~ 8291 -8421 3630 - 3623 WS A2 130 32 3/29/2006 Slots Altematin solid/slotted i e OD:8.470) ' ` 8630 - 8673 3630 - 3632 WS AZ 43 32 3/29/2006 Slots Altematin solid/slotted i e --- 8843 - 9102 3632 - 3633 WS A2 259 32 3/29/2006 Slots Altematin solid/slotted i e 9104 - 9320 3632 - 3632 WS A2 216 32 3/29/2006 Slots Alteratin solid/slotted i e ;~ 9475 - 9808 3629 - 3621 WS A2 333 32 , 3/29/2006 - -- - Slots Alt_e_mating solid/slotted pipe - Gas Lift Mandrels/1/alves - St MD TVD Man Man Type V Mfr V Type V OD Latch Port TRO Date Run Vlv Mfr Cmnt 1 3138 2395 CAMCO KBMG SOV 1.0 BEK-5 0.000 0 4/22/2006 <,. ~. >= > 2 4210 2986 CAMCO KBMG DMY 1.0 BK-5 0.000 0 4/22/2006 . ., .. a _ - -- ~Other (plugs, equip., etc.) - COMPL_E JEWELRY TIO N _ _ _ _ De th TVD T e Descri tion ID ~: ~, ~ 23 23 HANGER VETCO GRAY TUBING HANGER 4752 3227 DIS. SUB A-WELL DISCHARGE SUB 4.500 0.000 , 4830 3260 XO TTC CROSSOVER w/SCREEN INTAKE 0.000 j ~ ~ ~ ~ 4840 3264 SEAL TANDEM SEAL SECTION GSB 3 DB AB/HSN PFSA 0.000 HANGER -^ ~ ~ 4854 3270 MOTOR/ MOTOR 418 HP KMHFER 2610 / 98 " w/ PUMP I NSTALLED IN MOTOR'"` 0.000 (5742-5766, ,~; .€; . 'i PUMP oD:6.750) ' ' ~ ~~: 4888 3284 GAUGE A-WELL PUMP GAUGE 0.000 4890 3285 Centralizer MOTOR CENTRALIZER 0.000 5399 3442 HANGER D-SAND BAKER MODEL B-1 HOOK HANGER (INSIDE CASING) 4.020 l . - -- -•- I Other lugs, eguip., etc.) - A SAND LINER_JEWELRY _ ~ De th TVD T e Descri tion ID 5862 3527 PACKER HRD ZXP LINER TOP PACKER 4.970 ` "~~ 5880 3530 NIP 'RS' PACKOFF SEAL NIPPLE 4.875 I 5883 3530 HANGER FLEXLOCK LINER HANGER 4.853 ~ ~ 5893 3532 SBE 190-47 CASING SEAL BORE EXTENSION 4.750 5913 3535 XO CROSSOVER BUSHING 3.830 - 9840 3621 SHOE ROT WEATHERFORD GUIDE SHOE 3.500 - - •- Other lu s, a uip., etc.) - B-SAND LEM ;~ ;1_~ , De th TVD T e Descri tion ID T ` 5502 3463 PACKER ZXP LINER TOP PACKER 4.970 5521 3467 CSR 109-47 CASING SEAL BORE RECEPTACLE 4.750 5541 3471 XO CROSSOVER BUSHING 3.830 ,- . , 5732 3504 HANGER LEM ABOVE HOOK HANGER 5.320 5742 3506_ _HANGER LEM INSIDE HOOK HANGER 5.320 ' _ __ General Notes ~ ~ Date Note - I - 4/24/2006 MULTI-LATERAL WELL: 1J-152 A-SAND , 1J-152L1 B-SAND , 1J-152L2 D-SAND - ~ ~ _ - -,~ ~ - -, I ~= -- ~ ~ ~ I --- ~ , I - - ~ - - - - ~-- ' l 1 `._J WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 April 16, 2007 RE: MWD Formation Evaluation Logs: 1J-152, PB1, PB2, Ll, L2 & L2 PB1, AK-MW-4263658 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 1J-152, PB1, PB2, Ll, L2, L2 PB1: LIS & Digital Log Images: 50-029-23298-00, 70, 71, 60, 61, 72. ;~~~~? ~ ao~ _ ai ~ ~ yS63~ ~- - S~~'~ ~ i S(~ ~f - loll , . ~ ..,~. ~~ s.~ ~~ ~aoc~ -o t ~ ~ t 503 1 CD Rom '~ ~b~ ' Ol ~ ~ 150 ~~O ~I~UV~ '~ • WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Co. Attn.: Librarian 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 • June 22, 2006 RE: MWD Formation Evaluation Logs: 1J-152, PBl, PB2, L1, L2, L2 PB1, AK-MW-4212091 1 LDWG formatted CD Rom with verification listing(s). API#: 50-029-23298-00, 70, 71, 60, 61, 72 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: Signed: • • 11-May-06 AOGCC Ceresa Tolley 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 DEFINITIVE Re: Distribution of Survey Data for Well 1 J-152 Dear Dear Sir/Madam: Enclosed is one disk with the *.PTT and *.PDF files. Tie-on Survey: 8,346.90' MD Window /Kickoff Survey: 10,009.64' MD (if applicable) Projected Survey: 10,053.00' MD PLEASE ACKNOWLEDGE RECEIPT BY SENDING AN EMAIL TO CARL.ULRICH@HALLIBURTON.COM OR SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Carl Ulrich 6900 Arctic Blvd. Anchorage, AK 99518 a Date ,~?~~~ Signed Please call me at 273-3545 if you have any questions or concerns. Regards, Carl Ulrich Survey Manager Attachment(s) ~(~6-Ol~ • • 11-May-06 AOGCC Ceresa Tolley 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 DEFINITIVE Re: Distribution of Survey Data for Well 1J-152 PB1 Dear Dear Sir/Madam: Enclosed is one disk with the *.PTT and *.PDF files. Tie-on Survey: 28.00' MD Window /Kickoff Survey: 7,605.55' MD (if applicable) Projected Survey: 7,646.00' MD PLEASE ACKNOWLEDGE RECEIPT BY SENDING AN EMAIL TO CARL.ULRICH@HALLIBURTON.COM OR SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Carl Ulrich 6900 Arctic Blvd. Anchorage, AK 99518 Date ~ Signed Please call me at 273-3545 if you have any questions or concerns. Regards, Carl Ulrich Survey Manager Attachment(s) Z~co-~~ ~ • • 11-May-06 AOGCC Ceresa Tolley 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 DEFINITIVE Re: Distribution of Survey Data for Well 1J-152 PB2 Dear Dear Sir/Madam: Enclosed is one disk with the *.PTT and *.PDF files. Tie-on Survey: 6,761.64' MD Window /Kickoff Survey: 9,254.00' MD (if applicable) Projected Survey: 9,343.00' MD PLEASE ACKNOWLEDGE RECEIPT BY SENDING AN EMAIL TO CARL.ULRICH@HALLIBURTON.COM OR SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Carl Ulrich 6900 Arctic Blvd. Anchorage, AK 99518 Date, ? elw~.t. tad ~P Signed 7 Please call me at 273-3545 if you have any questions or concerns. Regards, Carl Ulrich Survey Manager Attachment(s) • ConocoPhillips May 24, 2006 . Randy Thomas Kuparuk Drilling Team Leader Drilling & Wells P. O. Box 100360 Anchorage, AK 99510-0360 Phone: 907-265-6830 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Subject: Well Completion Reports for 1J-152, 1J-152L1 and 1J-152L2 Dear Commissioner: ConocoPhillips Alaska, Inc. submits the attached Well Completion Reports for the recent drilling operations on the West Sak wells 1J-152, 1J-152L1, 1J-152L2. If you have any questions regarding this matter, please contact me at 265-6830 or Mike Greener at 263-4820. Sincerely, l ~. R. Thomas Kuparuk Drilling Team Leader CPAI Drilling RT/skad STATE OF ALASKA • ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1a. Well Status: pil ^ Gas Plugged Abandoned Suspended WAG ^ 20AAC 25.105 20AAC 25.110 GINJ ^ WINJ ^ WDSPL ^ No. of Completions _ Other _ 1b. Well Class: Development Q Exploratory ^ Service ^ Stratigraphic Test ^ 2. Operator Name: ConocoPhillips Alaska, Inc. 5. Date Comp., Susp., or Aband.: April 22, 2006 ~ 12. Permit to Drilt Number: 206-016 / 3. Address: P. O. Box 100360, Anchorage, AK 99510-0360 6. Date Spudded: ~~ [~ ~~ March y!; 2006 4'V~ 13. API Number: 50-029-23298-00 ' 4a. Location of Well (Governmental Section): Surface: 2191' FSL, 2582' FEL, Sec. 35, T11N, R10E, UM ~ 7. Date TD Reached: March 28, 2006 14. Well Name and Number: 1J-152 At Top Productive Horizon: 1252' FSL, 952' FWL, Sec. 35, T11 N, R10E, UM 8. KB Elevation (ft): 28' RKB / 108' AMSL 15. Field/Pool(s): Kuparuk River Field Total Depth: 2265' FNL, 960' FWL, Sec. 2, T10N, R10E, UM 9. Plug Back Depth (MD + TVD): 9840' MD / 3621' ND West Sak Oil Pool - 4b. Location of Well (State Base Plane Coordinates): Surface: x- 558625 ' y- 5946002 Zone- 4 10. Total Depth (MD + TVD): 10053' MD / 3622' TVD 16. Property Designation: ADL 25661 & 25662 TPI: x- 556888 y- 5945049 Zone- 4 Total Depth: x- 556927 - - 5941533 ° Zone- 4 11. Depth where SSSV set: none 17. Land Use Permit: ALK 471 & 2177 18. Directional Survey: Yes Q No 19. Water Depth, if Offshore: N/A feet MSL 20. Thickness of Permafrost: 2365' MD 21. Logs Run: GR/Res, CBL 22. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTH TVD HOLE AMOUNT CASING SIZE WT. PER FT. GRADE TOP BOTTOM TOP BOTTOM SIZE CEMENTING RECORD PULLED 20" 62.58# H-40 28' 108' 28' 108' 42" 120 sx Class G 10.75" 45.5# L-80 28' 2774' - 28' 2198' 13.5" 52o sx AS Lite, 184 sx DeepCRETE 7-5/8" 29.7# L-80 28' 6523' ~ 28' 3638' 9-7/8" 375 sx DeepCrete 4.5" 11.6# / 12.6# L-80 5862' 9841' 3527' 3620' 6.75" slotted liner 23. Pertorations open to Production (MD + TVD of Top and Bottom 24. TUBING RECORD Interval, Size and Number; if none, state "none"): SIZE DEPTH SET (MD) PACKER SET 4.5" 4892' 5863' slotted liner: 9807' to 9474', 93.19'-8842', 8672'-8629', 8421'-8291', 8075'-7310', 6885'-6500' MD 25. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED n/a 26. PRODUCTION TEST Date First Production May 14, 2006 ~ Method of Operation (Flowing, gas lift, etc.) ESP Oil -shares production with 1J-152L1 and 1J-152L2 Date of Test 5/16/2006 Hours Tested .5 hours Production for Test Period --> OIL-BBL 80 GAS-MCF 28 WATER-BBL 21 CHOKE SIZE 19% GAS-OIL RATIO 390 Flow Tubing press. 186 psi Casing Pressure not available Calculated 24-Hour Rate -> OIL-BBL 2837 GAS-MCF 1107 WATER-BBL 744 OIL GRAVITY -API (corr) not available 27. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water (attach separate sheet, if necessary). Submit core chips; if none, state "none". f: ~~ - ~. NONE R '~Fl ~uN 0 S Zoos ' ~i o~ _ ~~.x Form 10-407 Revised 12/2003 CONTINUED ON REVERSE ORIGINAL G 28. 29. GEOLOGIC MARKERS FORMATION TESTS NAME MD TVD Include and briefly summarize test results. List intervals tested, and attach detailed supporting data as necessary. If no tests were conducted, state "None". 1 J-152 Top West Sak A2 6532' 3638' Base West Sak A2 10053' 3622' N/A 1 J-152PB 1 TD 7646' 3668' 1 J-152PB2 TD 9296' 3645' ' 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: Mike Greener @ 263-4820 Printed Na Ran ma Title: Greater Kuoaruk Area Drillino Team Leader / / ~ 2 ~" ~ t 1 - Signature ~.6s--6~ 3a Date - ( - INSTRUCTIONS Prepared by Sharon Allsup-Drake 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 1J-152 Daily Operations Summary DATE Summary operations 03/13/06 Move offwe111J-159.... 03/14/06 RDMO of well 1 J-159 -Move North 160' on well row to 1 J-152 03/15/06 Drill, PU Dir BHA, resume drilling 03/16/06 Drilled from 1,173' to 1,816' MD. Tripped for bit. RIH and washed and reamed from 1,636' to 1,816'. Lost 5? of angle, inadvertently S/T @ 1,636'. Cont'd drilling from 1,816' to 1,838'. 03/17/06 Drilled 13.5" hole to TD @ 2787' MD / 2,205' TVD. BROOH from 2,787' to 2,048'. POOH and L/D BHA. R/U to run 10.75" casing. Run casing to 1,496'. 03/18/06 Ran 10 3/4" casing to 2,774.8' "and cemented same. Set casing on slips. Welded on flange and wrapped to cool. dim-Ops C/O saver sub, P/U 27 jts 4" DP. 03/19/06 P/U 4" DP and R/B. Tested BOPs. Run gyro on wireline. P/U BHA #3. 03/20/06 RIH w/ BHA #3. Performed casing test to 3000 psi. Drilled out FC and FS and performed LOT to 14.2# EMW. Drilled from 3,193' to 4,096' MD / 2,925' TVD. 03/21/06 Drilled 9 7/8" intermediate from 4,096' to 5,614' MD / 3,483' TVD. 03/22/06 Drilled from 5,614' to TD @ 6,532' MD / 3,639' TVD. BROOH to 3,335'. 03/23/06 POOH and L/D BHA #3. R/U for 7 5/8" casing run and run to TD @ 6,522' MD / 3.638' TVD. Cemented as per detail. 03/24/06 Set 7 5/8" casing on slips. P/U DP and install 90 super sliders. M/U BHA #4 and singled in hole. RIH tagged cement, PU and CBU. Slipped and cut, serviced TD and DWS. Performed casing test. 03/25/06 Tested casing to 3000 psi for 30 min. Drilled out shoe +20' new hole, performed LOT to 13.5 EMW. Drilled intermediate from 6,552' to 7,646'. Pulled back fcx~S/T (fault) @ 6,811' MD. Drilled from 6,811' to 7,085' MD. 03/26/06 Drilled "A" Lat from 7,085' to 9,024' MD. 03/27/06 Drilled from 9,024' to 9,343' M[}. Decision made to StT, pulled back to 8,425' MD. Drilled from 8,425' to 9,803' MD. 03/28/06 Drilled to TD of 10053' MD/ 3621' TVD. Pump hi visc sweeps. POOH to 7 5/8" shoe, RIH to TD. Went into old sidetracked hole twice. Made it to TD. POOH to 362' MD. 03/29/06 LD BHA #4. Run & set 4.5" liner and liner hanger. MU whipstock and mill assembly. Set whipstock. Displace from SFOBM to MOBM. __ _w.... 03/30/06 Mill window from 5747' to 5759'. Drill 5' gauge hole to 5774' MD. POOH and LD milling assembly. RU and Test BOPEs. PU BHA #6. Slip & cut drill line, service TD, DWs, & saver sub. Drill from 5774' to 5828' MD / 3522' TVD. 03/31/06 Drilled B Lat from 5,828' to 7,962' MD / 3,492' TVD. 04/01/06 Drilled B lat from 7,962' to 10,079' / 3452' TVD 04/02/06 Drilled B lat from 10,079' to 11,631' MD / 3,438' TVD. 04/03/06 Drilled B lat from 11,631' to TD at 13,408' MD / 3426' TVD. 04/04/06 BROOH to window. Circ sweep. TIH to TD, change over to SFOBM. 04/05/06 POOH, LDBHA, PU Whipstock retrieving tools, PJSM, RIH and pull whipstock. 04/06/06 LD Whipstock & retrieving tools. RIH with 4.5" liner. 04/07/06 POOH and PU flop and drop assembly to leave 4.5" liner. RIH with with liner and HR setting sleeve on drill pipe. Rotated liner down from 11,519' MD to TD at 13,374' MD. Set liner & POOH. LD running tools. 04/08/06 MU Hook Hanger assembly for the drop run. RIH and find liner. Set hook hanger. POOH and LD running tools. PU milling assembly. 04/09/06 MU Milling assembly. RIH and tagged up 23' early & mill plugged off. POOH and MU milling assembly with float sub. RIH, filling pipe every 10 stds. Tag RS nipple, cycle boot baskets. POOH and LD milling assembly. MU LEM assembly. 04/10/06 Set LEM & ZXP. POOH & LD running tools. MU Whipstock assembly. RIH & MAD pass. 1J-152 Daily Operations Summary 04/11/06 Set whipstock, drilled window from 5,403' to 5,415'. POOH, and UD mills. Tested BOPE. M/U drilling BHA and SHT MWD. ~ ~~ a ~ ~ ~ L 04/12/06 Cut and slipped DL, serviced TD. Drilled "D" lat from 5,442' to 6,024' MD. Unable to get proper directional response, POOH. M/U BHA w/ motor and agitator. 04/13/06 Trough from 5,425-5,445' MD. StT~rn 5i~45' ttt 7,249' R~U ! 3;446' TVD. 04/14/06 Drilled from 7,249' to 7,572' w/ motor. POOH due to washout. UD motor and P/U Geo- pilot and assoc. BHA. RIH and drill from 7,572' to 7,967' MD. 04/15/06 Drilled from 7,967' to 9,775' MD w/ geo-pilot. 04/16/06 Drilled from 9,775' MD to 11,307' w/ geo-pilot. 04/17/06 Drilled from 11,307' MD to 13,112' TD w/geo-pilot. Began to BROOH. 04/18/06 BROOH to window, pumped sweep +2BU. Cut and slipped DL and serviced TD. RIH to TD circa sweep and disp. well to SFOBM. TOOH and began L/D BHA. 04/19/06 L/D BHA. Ran 4.5" slotted liner to 13,086' w/ top @ 5,603' and released. POOH w/ DP. RIH and retrieved whipstock. 04/20/06 RIH w/ hook hanger and ECP and set. Began L/D DP. 04/21/06 L/D DP. Singled in hole w/ completion tubing and S/B. Rigged up Centrilift and began R/U motor and ESP. 04/21/06 SET 46.01' X 3.80" OD ESP PUMP (W/CHECK) @ 86' SLM (TOP OF PUMP @ 40' SLM ). SET D&D PACKOFF ASSEMBLY, 5' SPACER, AND STINGER ASSEMBLY (94 3/4" OAL) AND SET ONTOP OF PUMP @ 40' SLM. TEST TBG. TO 1000 PSI FOR 10 M1N. (HELD SOLID ). SET 4 1/2 SLIP 04/22/06 Ran ESP and associated completion. • Halliburton Company i Survey Report Company: ConocoPhillips Alaska Inc. Uate: 5/3/2006 Time: 13:36:36 Page: 1 Field: Kuparuk River Unit Co-ordinatc(NE) Reference: Well: 1J-152, True North Site: Kuparuk 1J Pad Vertical (TVD) Refer ence: 1J-152: 109.0 Well: 1J-152 Section (VS) Reference: Welt (O.OON,O.OOE,180.OOAzi) Wellpath: 1J-152 Survey Calculation _~ tethod: Minimum Curvature Dh: Oracle Field: Kuparuk River Unit ', North Slope Alaska ', United States Map System:US State Plane Coordinate System 1927 Map Zone: Alaska, Zone 4 Geo Datum: NAD27 (Clarke 1866) Coordinate Syste m: Well Centre ii Sys Datum: Mean Sea Level Geomagnetic Model: bggm2005 _ Well: 1 J-152 Slot Name: Well Position: +N/-S 83.97 ft Northing : 5946002.32 ft Latitude: 70 15 47.084 N +E/-W -163.96 ft Easting : 558625.36 ft Longitude: 149 31 33.778 W ', ~ Position Uncertainty: 0.00 ft ~I _ Wellpath: 1J-152 Drilled From: 1J-152P62 ~ ~, 500292329800 Tie-on Depth: 8346.90 ft Current Datum: 1 J-152: Height 109.00 ft Above System Datum: Mean Sea Level Magnetic Data: 3/10/2006 Declination: 24.16 deg Field Strength: 57565 nT Mag Dip Angle: 80.77 deg Vertical Section: Depth From (IVD) +N/-S +E/-W Direction ft ~ ft ft deg - I 28.00 L----_-...------- --- 0.00 0.00 - 180.00 - ~ - Survey Program for Definitive Wellpath ---- --- --- _ I Date: 5/3/2006 Validated: No Version: 3 Actual From To Survey Toolcode Tool Name ft ft 90.00 537.00 1J-152P61 gyro (90.00- 537.00) CB-GYRO-SS Camera based gyro single shot 656.75 6761.64 1J-152P61 (656.75-760 5.55) (0) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 6811.00 8346.90 1J-152P62 (6811.00-92 54.00) (1 MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 8425.00 _ 10009_64 1J-152 (8425 .00-10009. 64) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC Survey __ __ ____ M19D Licl Azim I'VD Sys TVD N/S E/W' MapN 1apE Tool ft deg deg ft ft ft ft ft ft 28.00 0.00 0.00 28.00 -81.00 0.00 0.00 5946002.32 558625.36 TIE LINE ', 90.00 0.31 153.79 90.00 -19.00 -0.15 0.07 5946002.17 558625.44 CB-GYRO-SS 169.00 0.33 240.18 169.00 60.00 -0.46 -0.03 5946001.86 558625.33 CB-GYRO-SS ', 257.00 0.37 215.61 257.00 148.00 -0.81 -0.41 5946001.50 558624.95 CB-GYRO-SS 353.00 0.61 342.02 353.00 244.00 -0.58 -0.75 5946001.74 558624.61 CB-GYRO-SS ~I 445.00 2.63 346.08 444.95 335.95 1.94 -1.41 5946004.25 558623.93 CB-GYRO-SS '~ 537.00 4.04 349.64 536.80 427.80 7.17 -2.50 5946009.47 558622.80 CB-GYRO-SS ii 656.75 7.14 348.99 655.96 546.96 18.63 -4.68 5946020.91 558620.53 MWD+IFR-AK-CAZ-SC I 747.98 11.14 348.52 746.02 637.02 32.84 -7.52 5946035.10 558617.58 MWD+IFR-AK-CAZ-SC 839.68 13.86 349.80 835.53 726.53 52.33 -11.23 5946054.56 558613.72 MWD+IFR-AK-CAZ-SC 931.01 14.42 353.74 924.10 815.10 74.40 -14.41 5946076.60 558610.38 MWD+IFR-AK-CAZ-SC 1020.87 16.90 354.31 1010.62 901.62 98.53 -16.92 5946100.70 558607.67 MWD+IFR-AK-CAZ-SC 1120.48 20.55 357.30 1104.94 995.94 130.41 -19.18 5946132.56 558605.17 i MWD+IFR-AK-CAZ-SC 1213.13 22.43 356.92 1191.14 1082.14 164.31 -20.90 5946166.44 558603.19 MWD+IFR-AK-CAZ-SC ' 1273.52 24.12 356.30 II 1246.62 1137.62 188.13 -22.31 5946190.25 558601.59 I MWD+IFR-AK-CAZ-SC 1306.74 26.79 355.67 1276.61 1167.61 202.37 -23.32 5946204.48 558600.47 MWD+IFR-AK-CAZ-SC 1397.20 33.70 353.74 1354.71 1245.71 247.70 -27.60 5946249.77 558595.84 MWD+IFR-AK-CAZ-SC 1491.41 39.81 355.12 1430.16 1321.16 303.78 -33.02 5946305.80 558589.98 MWD+IFR-AK-CAZ-SC 1584.09 46.04 357.97 1498.00 1389.00 366.75 -36.73 5946368.73 558585.78 MWD+IFR-AK-CAZ-SC; 1677.37 44.16 357.94 1563.84 1454.84 432.77 -39.09 5946434.74 558582.91 MWD+IFR-AK-CAZ-SC 1769.27 43.33 359.13 1630.23 1521.23 496.29 -40.71 5946498.23 558580.79 MWD+IFR-AK-CAZ-SC 1859.90 45.61 356.18 1694.91 1585.91 559.71 -43.34 5946561.62 558577.66 MWD+IFR-AK-CAZ-SC ', 1952.12 49.11 352.59 1757.38 1648.38 627.19 -50.04 5946629.04 558570.44 MWD+IFR-AK-CAZ-SC ', 2043.67 52.60 342.96 1815.24 1706.24 696.39 -65.18 5946698.11 558554.76 MWD+IFR-AK-CAZ-SC 'I I~ 2136.92 55.91 333.37 1869.79 1760.79 766.45 -93.40 5946767.94 558526.01 MWD+IFR-AK-CAZ-SC 2229.42 57.89 326.70 1920.35 1811.35 833.49 -132.11 5946834.68 558486.78 MWD+IFR-AK-CAZ-SC li 2323.46 61.30 323.86 1967.94 1858.94 900.11 -178.32 5946900.93 558440.06 MWD+IFR-AK-CAZ-SC ~I Halliburton Company. Survey Report Company: ConocoPhillips Alaska Inc. llatc: 5/3/2006 'l'ime: 13 :36:36 Page: 2 Field: Ku paruk River Unit Co-ordinate~NE) Re ference: WeU: 1J-152, True North Site: Ku paruk 1J Pad Vertical (TVD) Refe rence: 1J-15 2: 109.0 Well: 1J-152 Section (VS) Reference: Well ( O.OON,O.OOE, 180.OOAzi) Wellpath: 1J-152 Survey Calcula tion,tilethod: Minimum Curv ature Db: Oracle Survcv - __ __ J7D incl Azim 'TVD Sys TV D N/S EIW tvlapN MapE Tool ft deg deg , ft ft ft ft ft ft 2415 .35 59. 74 326. 15 2013. 17 1904. 17 965.63 -224 .20 5946966.08 558393. 67 MWD+IFR-AK-CAZ-SC 2507 .53 61. 17 322. 16 2058. 63 1949. 63 1030.60 -271 .16 5947030.68 558346. 21 MWD+IFR-AK-CAZ-SC 2600 .04 57. 97 321. 79 2105. 48 1996. 48 1093.43 -320 .29 5947093.12 558296. 60 MWD+IFR-AK-CAZ-SC 2694 .14 58. 26 320. 11 2155. 19 2046. 19 1155.48 -370 .62 5947154.77 558245. 79 MWD+IFR-AK-CAZ-SC 2737 .89 57. 29 318. 61 2178. 52 2069. 52 1183.56 -394 .72 5947182.66 558221. 47 MWD+IFR-AK-CAZ-SC 2824 .65 56. 33 316. 70 2226. 02 2117. 02 1237.23 -443 .62 5947235.94 558172. 16 MWD+IFR-AK-CAZ-SC 2917 .67 56. 95 310. 44 2277. 20 2168. 20 1290.72 -499 .88 5947288.99 558115. 50 MWD+IFR-AK-CAZ-SC 3010 .82 58. 11 305. 21 2327. 23 2218. 23 1338.87 -561 .93 5947336.65 558053. 07 MWD+IFR-AK-CAZ-SC 3106 .49 58. 00 297. 13 2377, 91 2268. 91 1380.84 -631 .30 5947378.07 557983. 39 MWD+IFR-AK-CAZ-SC ' , 3199 .84 57. 91 291. 80 2427. 47 2318. 47 1413.59 -703 .28 5947410.25 557911. 16 MWD+IFR-AK-CAZ-SC 'I 3293 .54 57. 09 284. 95 2477. 86 2368. 86 1438.50 -778 .20 5947434.58 557836. 06 MWD+IFR-AK-CAZ-SC i 3386 .38 56. 42 278. 35 2528. 79 2419. 79 1454.18 -854 .18 5947449.66 557759. 97 MWD+IFR-AK-CAZ-SC t i 3480 .31 57. 70 271. 98 2579. 90 2470. 90 1461.24 -932 .62 5947456.11 557681. 48 MWD+IFR-AK-CAZ-SC 3573 .11 57. 79 264. 56 2629. 48 2520. 48 1458.87 -1010 .98 5947453.13 557603. 15 MWD+IFR-AK-CAZ-SC 3666 .73 56. 46 257. 70 2680. 34 2571. 34 1446.79 -1088 .60 5947440.45 557525. 64 MWD+IFR-AK-CAZ-SC 3760 .80 55. 63 251. 72 2732. 91 2623. 91 1426.25 -1163 .81 5947419.33 557450. 59 MWD+IFR-AK-CAZ-SC 3853 .77 55. 26 245. 94 2785. 68 2676. 68 1398.63 -1235 .17 5947391.15 557379. 46 MWD+IFR-AK-CAZ-SC 3945 .47 53. 52. 240. 08 2839. 10 2730. 10 1364.85 -1301 .57 5947356.87 557313. 33 MWD+IFR-AK-CAZ-SC 4039 .70 55. 93 231. 18 2893. 59 2784. 59 1321.43 -1364 .90 5947312.95 557250. 34 MWD+IFR-AK-CAZ-SC 4131 .77 57. 12 225. 10 2944. 40 2835. 40 1270.20 -1422 .04 5947261.29 557193. 61 MWD+IFR-AK-CAZ-SC 4225 .31 58. 72 218. 73 2994. 12 2885. 12 1211.24 -1474 .91 5947201.93 557141. 20 MWD+IFR-AK-CAZ-SC 4318 .68 62. 42 211. 13 3040. 04 2931. 04 1144.60 -1521 .34 5947134.93 557095. 31 MWD+IFR-AK-CAZ-SC ''~ 4412 .45 62. 54 205. 36 3083. 39 2974. 39 1071.39 -1560 .66 5947061.42 557056. 55 MWD+IFR-AK-CAZ-SC '~ 4505 .47 65. 67 199. 24 3124. 04 3015. 04 994.00 -1592 .34 5946983.80 557025. 48 MWD+IFR-AK-CAZ-SC 4599 .02 64. 31 198. 33 3163. 59 3054. 59 913.74 -1619 .64 5946903.34 556998. 81 MWD+IFR-AK-CAZ-SC 4693 .03 65. 96 193. 22 3203. 14 3094. 14 831.69 -1642 .79 5946821.12 556976. 30 MWD+IFR-AK-CAZ-SC 4784 .50 65. 62 191. 43 3240 .66 3131. 66 750.20 -1660 .60 5946739.49 556959. 13 MWD+IFR-AK-CAZ-SC 4879 .26 64. 36 190. 69 3280 .72 3171. 72 665.92 -1677 .08 5946655.10 556943. 31 MWD+IFR-AK-CAZ-SC 4974 .57 67. 36 187. 23 3319 .70 3210. 70 580.03 -1690 .59 5946569.11 556930. 47 MWD+IFR-AK-CAZ-SC 5068 .20 69. 45 185. 25 3354. 16 3245. 16 493.49 -1700 .04 5946482.52 556921. 69 MWD+IFR-AK-CAZ-SC 5161 .20 72. 44 182. 54 3384. 53 3275. 53 405.81 -1705 .99 5946394.80 556916. 43 MWD+IFR-AK-CAZ-SC 5254 .29 77. 35 182. 62 3408. 78 3299. 78 316.06 -1710 .04 5946305.02 556913. 08 MWD+IFR-AK-CAZ-SC 5347 .73 76. 10 181. 87 3430. 23 3321. 23 225.19 -1713 .60 5946214.14 556910. 22 MWD+IFR-AK-CAZ-SC ~ 5441 .59 77. 86 182. 13 3451. 38 3342. 38 133.80 -1716 .79 5946122.74 556907. 74 MWD+IFR-AK-CAZ-SC 5534 .45 79. 40 182. 58 3469. 69 3360. 69 42.84 -1720 .53 5946031.76 556904. 71 MWD+IFR-AK-CAZ-SC 5627 .15 80. 41 182. 99 3485. 93 3376. 93 -48.31 -1724 .97 5945940.58 556900. 99 MWD+IFR-AK-CAZ-SC 5720 .63 79. 48 181. 58 3502. 26 3393. 26 -140.28 -1728 .64 5945848.60 556898. 03 MWD+IFR-AK-CAZ-SC 5814 .68 79. 62 183. 10 3519. 32 3410. 32 -232.69 -1732 .42 5945756.17 556894. 97 MWD+IFR-AK-CAZ-SC ''~ ~~ 5907 .86 81. 93 182. 84 3534. 25 3425. 25 -324.54 -1737 .18 5945664.30 556890. 93 MWD+IFR-AK-CAZ-SC 'I 6001 .30 80. 25 183. 31 3548 .72 3439. 72 -416.71 -1742 .13 5945572.10 556886. 69 MWD+IFR-AK-CAZ-SC i 6092 .38 79. 76 183. 30 3564 .53 3455. 53 -506.26 -1747 .30 5945482.52 556882. 22 MWD+IFR-AK-CAZ-SC t 6188 .39 77. 17 179. 31 3583 .74 3474. 74 -600.28 -1749 .46 5945388.50 556880. 80 MWD+IFR-AK-CAZ-SC 6281 .80 78. 32 179. 93 3603 .56 3494. 56 -691.56 -1748 .86 5945297.24 556882. 11 MWD+IFR-AK-CAZ-SC 6375 .27 80. 13 179. 00 3621 .04 3512. 04 -783.37 -1748 .00 5945205.44 556883. 68 MWD+IFR-AK-CAZ-SC 6468 .43 84. 42 178. 54 3633 .56 3524. 56 -875.64 -1746 .01 5945113.20 556886. 39 MWD+IFR-AK-CAZ-SC ~ 6491 .30 84. 91 178. 56 3635 .68 3526. 68 -898.40 -1745 .44 5945090.44 556887. 14 MWD+IFR-AK-CAZ-SC '~ 6574 .48 90. 88 180. 44 3638 .74 3529. 74 -981.48 -1744 .71 5945007.38 556888. 51 MWD+IFR-AK-CAZ-SC 6668 .07 92. 59 179. 00 3635 .90 3526. 90 -1075.02 -1744 .26 5944913.85 556889. 69 MWD+IFR-AK-CAZ-SC '.. 6761 .64 91. 80 178. 39 3632. 32 3523. 32 -1168.50 -1742 .13 5944820.40 556892. 55 MWD+IFR-AK-CAZ-SC ' 6811 .00 91. 65 179. 21 3630. 84 3521. 84 -1217.83 -1741 .09 5944771.09 556893. 97 MWD+IFR-AK-CAZ-SC 6856 .80 87. 41 179. 48 3631. 21 3522. 21 -1263.61 -1740 .57 5944725.32 556894. 85 MWD+IFR-AK-CAZ-SC ' 6950 .18 83. 59 180. 04 3638. 54 3529. 54 -1356.69 -1740 .18 5944632.26 556895. 96 MWD+IFR-AK-CAZ-SC ~ 7043 .58 83. 76 179. 51 3648. 83 3539. 83 -1449.52 -1739 .82 5944539.44 556897. 05 MWD+IFR-AK-CAZ~ • Halliburton Company,i Survey Report Compan~~: ConocoPhillips Alaska Inc. Date: 5/3/2006 t'iroe: 13:36:36 Page: 3 Field: Kuparuk River Unit Co-ordinatc(NE) Reference: Well: 1J-152, True North Site: Kuparuk 1J Pad Vertical (TVD) Reference: 1J-152: 109.0 WeIL• 1J-152 Section (VS) Reference: Well (O.OON,O.OOE,180.OOAzi) Wcllpath: 1J-152 Survey Calculatia~Method: Minimum Curvature Db: Oracle Survey ___ I~ID Ind Azim TVD Sys TVD N/S E/V1' Map\ MapE Tool ft deg deg ft ft ft ft ft ft 7135.81 88.58 180.30 3654.98 3545.98 -1541.51 -1739.66 5944447.46 556897.92 MWD+IFR-AK-CAZ-SC ~! ', 7229.17 86.00 181.42 3659.40 3550.40 -1634.75 -1741.06 5944354.22 556897.24 MWD+IFR-AK-CAZ-SC ' 7325.49 89.83 181.87 3662.90 3553.90 -1730.95 -1743.83 5944258.02 556895.23 MWD+IFR-AK-CAZ-SC ', 7416.09 92.61 182.11 3660.97 3551.97 -1821.46 -1746.97 5944167.49 556892.79 MWD+IFR-AK-CAZ-SC i 7510.85 93.65 181.11 3655.80 3546.80 -1916.04 -1749.63 5944072.90 556890.87 MWD+IFR-AK-CAZ-SC ii 7603.73 89.70 181.09 3653.08 3544.08 -2008.85 -1751.41 5943980.09 556889.81 MWD+IFR-AK-CAZ-SC ~'i 7697.59 92.92 180.52 3650.94 3541.94 -2102.66 -1752.73 5943886.28 556889.22 MWD+IFR-AK-CAZ-SC '~, !, 7789.92 91.59 178.46 3647.31 3538.31 -2194.91 -1751.91 5943794.05 556890.76 MWD+IFR-AK-CAZ-SC ~! 7884.30 92.48 178.27 3643.95 3534.95 -2289.19 -1749.22 5943699.80 556894.19 MWD+IFR-AK-CAZ-SC 7977.28 91.88 179.33 3640.42 3531.42 -2382.08 -1747.27 5943606.94 556896.85 MWD+IFR-AK-CAZ-SC ~~ 8070.43 90.32 182.37 3638.63 3529.63 -2475.19 -1748.65 5943513.83 556896.20 MWD+IFR-AK-CAZ-SC 8165.87 92.38 181.49 3636.38 3527.38 -2570.54 -1751.87 5943418.47 556893.73 MWD+IFR-AK-CAZ-SC 8256.73 93.17 178.71 3631.98 3522.98 -2661.28 -1752.03 5943327.73 556894.27 MWD+IFR-AK-CAZ-SC 8346.90 93.10 177.64 3627.05 3518.05 -2751.27 -1749.16 5943237.78 556897.84 MWD+IFR-AK-CAZ-SC 8425.00 93.19 181.15 3622.76 3513.76 -2829.24 -1748.34 5943159.83 556899.27 MWD+IFR-AK-CAZ-SC 8527.86 86.31 178.37 3623.21 3514.21 -2932.02 -1747.91 5943057.06 556900.50 MWD+IFR-AK-CAZ-SC 8618.72 85.23 179.69 3629.91 3520.91 -3022.62 -1746.37 5942966.49 556902.74 MWD+IFR-AK-CAZ-SC 8709.94 90.32 179.77 3633.45 3524.45 -3113.74 -1745.94 5942875.38 556903.88 MWD+IFR-AK-CAZ-SC 8801.59 90.99 180.21 3632.41 3523.41 -3205.38 -1745.93 5942783.75 556904.61 MWD+IFR-AK-CAZ-SC 8892.45 89.33 178.79 3632.15 3523.15 -3296.23 -1745.13 5942692.92 556906.11 MWD+IFR-AK-CAZ-SC 8982.70 89.39 177.97 3633.16 3524.16 -3386.44 -1742.58 5942602.74 556909.36 MWD+IFR-AK-CAZ-SC 9073.70 91.18 179.76 3632.71 3523.71 -3477.42 -1740.78 5942511.79 556911.87 MWD+IFR-AK-CAZ-SC 9164.66 89.64 183.10 3632.06 3523.06 -3568.33 -1743.05 5942420.87 556910.31 MWD+IFR-AK-CAZ-SC 9256.26 89.83 177.81 3632.48 3523.48 -3659.89 -1743.78 5942329.31 556910.30 MWD+IFR-AK-CAZ-SC 9346.25 90.51 177.69 3632.21 3523.21 -3749.81 -1740.24 5942239.43 556914.53 MWD+IFR-AK-CAZ-SC 9436.33 91.62 176.70 3630.54 3521.54 -3839.77 -1735.84 5942149.52 556919.64 MWD+IFR-AK-CAZ-SC ~I ~ 9527.05 91.99 180.68 3627.68 3518.68 -3930.40 -1733.76 5942058.92 556922.42 MWD+IFR-AK-CAZ-SC 9616.05 91.25 177.74 3625.16 3516.16 -4019.34 -1732.54 5941969.99 556924.33 MWD+IFR-AK-CAZ-SC 9707.44 91.25 178.72 3623.17 3514.17 -4110.67 -1729.71 5941878.70 556927.87 MWD+IFR-AK-CAZ-SC 9797.42 91.00 179.18 3621.40 3512.40 -4200.62 -1728.07 5941788.78 556930.22 MWD+IFR-AK-CAZ-SC 9888.52 90.81 181.77 3619.97 3510.97 -4291.69 -1728.82 5941697.71 556930.17 MWD+IFR-AK-CAZ-SC 9981.96 89.58 181.06 3619.65 3510.65 -4385.10 -1731.13 5941604.30 556928.59 MWD+IFR-AK-CAZ-SC 10009.64 88.14 181.65 3620.20 3511.20 -4412.77 -1731.78 5941576.63 556928.15 MWD+IFR-AK-CAZ-SC 10053.00 88.14 _ 181.65 3621_61 _ 3512.61 -4456.09 -1733.03 5941533.30_ 556927.24 PROJECTED to TD ~ i Halliburton Company • Survey Report Company: ConocoPhillips Alaska Inc. Date: 5/3/2006 Time: 10:34:28 Page: 1 Field: Kuparuk River Unit Co-ordinate(NE) Reference: Well: 1J-152, True North Site: Kuparuk 1J Pad Vertical (TVD) Refe rence: 1J -152PB1: 109.0 Well: 1J-152 Section (VS) Reference: Well (O.OON,O.OOE,1 80.OOAzi) Wellpath: 1J-152PB1 Survey Calculation D lethod: Mi nimum Curvature llb: Oracle Field: Kuparuk River Unit ', North Slope Alaska I United States Map System:US State Plane Coordinate System 1927 Geo Datum: NAD27 (Clarke 1866) Map Zone: Coordinate Syste Alaska, Zone 4 m: Well Centre Sys Datum: Mean Sea Level _ Geomagnetic Model: bggm2005 - -- _ Well: 1J-152 _--_ - _ Slot Name: Well Position: +N/-S 83.97 ft Northing : 5946002.32 ft Latitude: 70 15 47.084 N +E/-W -163.96 ft Easting : 558625.36 ft Longitude: 149 31 33.778 W Position Uncertainty: 0.00 ft Wellpath: 1J-152PB1 Drilled From: Well Ref. Point i 500292329870 Tie-on Depth: 28.00 ft Current Datum: 1 J-152P61: Height 109.00 ft Above System Datum: Mean Sea Level ii Magnetic Data: 3/10/2006 Declination: 24.16 deg Field Strength: 57565 nT Mag Dip Angle: 80.77 deg Vertical Section: Depth From (TVD) ft +N/-S ft +E/-W ft Direction deg 28.00 0.00 0.00 180.00 ~ Survey Program for DeTiuitive Wellpath - ---..._ Date: 12/18/2004 Validated: No Version: 3 Actual From To Survey Toolcode Tool Nam e ft ft 90.00 537.00 1J-152P61 gyro (90.00- 537.00) CB-GYRO-SS Camera based gyro single shot 656.75 7605.55 1J-152PB1 (656.75-760 5.55) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC Survey MD Incl ~zim TVD S_vs'FVll N/S E/!V NIapN MapE Tool ', ft deg deg ft ft ft ft ft ft 28.00 0.00 0.00 28.00 -81.00 __ 0.00 0.00 5946002.32 558625.36 __ TIE LINE 90.00 0.31 153.79 90.00 -19.00 -0.15 0.07 5946002.17 558625.44 CB-GYRO-SS 169.00 0.33 240.18 169.00 60.00 -0.46 -0.03 5946001.86 558625.33 CB-GYRO-SS 257.00 0.37 215.61 257.00 148.00 -0.81 -0.41 5946001.50 558624.95 CB-GYRO-SS 353.00 0.61 342.02 353.00 244.00 -0.58 -0.75 5946001.74 558624.61 CB-GYRO-SS 445.00 2.63 346.08 444.95 335.95 1.94 -1.41 5946004.25 558623.93 CB-GYRO-SS 537.00 4.04 349.64 536.80 427.80 7.17 -2.50 5946009.47 558622.80 CB-GYRO-SS 656.75 7.14 348.99 655.96 546.96 18.63 -4.68 5946020.91 558620.53 MWD+IFR-AK-CAZ-SC ' 747.98 11.14 348.52 746.02 637.02 32.84 -7.52 5946035.10 558617.58 MWD+IFR-AK-CAZ-SC ', 839.68 13.86 349.80 i 835.53 726.53 52.33 -11.23 5946054.56 558613.72 MWD+IFR-AK-CAZ-SC I ', 931.01 14.42 353.74 924.10 815.10 74.40 -14.41 5946076.60 558610.38 MWD+IFR-AK-CAZ-SC '~~ '~ 1020.87 16.90 354.31 1010.62 901.62 98.53 -16.92 5946100.70 558607.67 MWD+IFR-AK-CAZ-SC ' 1120.48 20.55 357.30 1104.94 995.94 130.41 -19.18 5946132.56 558605.17 MWD+IFR-AK-CAZ-SC '~ 1213.13 22.43 356.92 1191.14 1082.14 164.31 -20.90 5946166.44 558603.19 MWD+IFR-AK-CAZ-SC ~~ ~I 1273.52 24.12 356.30 1246.62 1137.62 188.13 -22.31 5946190.25 558601.59 MWD+IFR-AK-CAZ-SC 1306.74 26.79 355.67 1276.61 1167.61 202.37 -23.32 5946204.48 558600.47 MWD+IFR-AK-CAZ-SC ~' 1397.20 33.70 353.74 1354.71 1245.71 247.70 -27.60 5946249.77 558595.84 MWD+IFR-AK-CAZ-SC ~, 1491.41 39.81 355.12 1430.16 1321.16 303.78 -33.02 5946305.80 558589.98 MWD+IFR-AK-CAZ-SC '~ ~ 1584.09 46.04 357.97 1498.00 1389.00 366.75 -36.73 5946368.73 558585.78 MWD+IFR-AK-CAZ-SC ' 1677.37 44.16 357.94 I 1563.84 1454.84 432.77 -39.09 5946434.74 558582.91 MWD+IFR-AK-CAZ-SC !, ' ~! 1769.27 43.33 359.13 ~ 1630.23 1521.23 496.29 -40.71 5946498.23 558580.79 MWD+IFR-AK-CAZ-SC '', 1859.90 45.61 356.18 1694.91 1585.91 559.71 -43.34 5946561.62 558577.66 MWD+IFR-AK-CAZ-SC ~, 1952.12 49.11 352.59 1757.38 1648.38 627.19 -50.04 5946629.04 558570.44 MWD+IFR-AK-CAZ-SC 2043.67 52.60 342.96 1815.24 1706.24 696.39 -65.18 5946698.11 558554.76 MWD+IFR-AK-CAZ-SC 2136.92 55.91 333.37 1869.79 1760.79 766.45 -93.40 5946767.94 558526.01 MWD+IFR-AK-CAZ-SC 2229.42 57.89 326.70 1920.35 1811.35 833.49 -132.11 5946834.68 558486.78 MWD+IFR-AK-CAZ-SC 2323.46 61.30 323.86 1967.94 1858.94 900.11 -178.32 5946900.93 558440.06 MWD+IFR-AK-CAZ-SC ~, 2415.35 59.74 326.15 2013.17 1904.17 965.63 -224.20 5946966.08 558393.67 MWD+IFR-AK-CAZ-SC 2507.53 61.17 322.16 2058.63 1949.63 1030.60 -271.16 5947030.68 558346.21 MWD+IFR-AK-CAZ-SC Halliburton Company i Survey Report Company: ConocoPhillips Alaska Inc. Date: 5/3/2006 Time: 10:3428 Page: 2 Field: Kuparuk River Unit Co-ordinate(NE) Refcrencr. Weil: 1J-152, True North Site: Kuparuk 1J Pad Vertical(TVD) Reference: 1J-152PB1: 109.0 Well: 1J-152 Section (VS) Reference: Well (O.OON,O.OOE,180.OOAzi) Wcllpath: 1J-152PB1 Survey Calculation IVlethod: Minimum Curvature Db: Oracle Survey ~1D Incl [~LJtn CVD Sys TVD N/S E/~V MapV h1apE 'Cool ', ft deg deg ft ft ft ft ft ft ' ___ _ _ _ __ 2600.04 57.97 321.79 2105.48 1996.48 1093.43 -320.29 5947093.12 558296.60 MWD+IFR-AK-CAZ-SC 2694.14 58.26 320.11 2155.19 2046.19 1155.48 -370.62 5947154.77 558245.79 MWD+IFR-AK-CAZ-SC ' 2737.89 57.29 318.61 2178.52 2069.52 1183.56 -394.72 5947182.66 558221.47 MWD+IFR-AK-CAZ-SC 2824.65 56.33 316.70 2226.02 2117.02 1237.23 -443.62 5947235.94 558172.16 MWD+IFR-AK-CAZ-SC 2917.67 56.95 310.44 2277.20 2168.20 1290.72 -499.88 5947288.99 558115.50 MWD+IFR-AK-CAZ-SC 3010.82 58.11 305.21 2327.23 2218.23 1338.87 -561.93 5947336.65 558053.07 MWD+IFR-AK-CAZ-SC 3106.49 58.00 297.13 2377.91 2268.91 1380.84 -631.30 5947378.07 557983.39 MWD+IFR-AK-CAZ-SC ' 3199.84 57.91 291.80 2427.47 2318.47 1413.59 -703.28 5947410.25 557911.16 MWD+IFR-AK-CAZ-SC ', 3293.54 57.09 284.95 2477.86 2368.86 1438.50 -778.20 5947434.58 557836.06 MWD+IFR-AK-CAZ-SC it j ' 3386.38 56.42 278.35 2528.79 2419.79 1454.18 -854.18 5947449.66 557759.97 MWD+IFR-AK-CAZ-SC i 3480.31 57.70 271.98 2579.90 2470.90 1461.24 -932.62 5947456.11 557681.48 MWD+IFR-AK-CAZ-SC i 3573.11 57.79 264.56 2629.48 2520.48 1458.87 -1010.98 5947453.13 557603.15 MWD+IFR-AK-CAZ-SC 3666.73 56.46 257.70 2680.34 2571.34 1446.79 -1088.60 5947440.45 557525.64 MWD+IFR-AK-CAZ-SC ', 3760.80 55.63 251.72 2732.91 2623.91 1426.25 -1163.81 5947419.33 557450.59 MWD+IFR-AK-CAZ-SC ', 3853.77 55.26 245.94 2785.68 2676.68 1398.63 -1235.17 5947391.15 557379.46 MWD+IFR-AK-CAZ-SC '~ 3945.47 53.52 240.08 2839.10 2730.10 1364.85 -1301.57 5947356.87 557313.33 MWD+IFR-AK-CAZ-SC '~ '~ 4039.70 55.93 231.18 2893.59 2784.59 1321.43 -1364.90 5947312.95 557250.34 MWD+IFR-AK-CAZ-SC 4131.77 57.12 225.10 2944.40 2835.40 1270.20 -1422.04 5947261.29 557193.61 MWD+IFR-AK-CAZ-SC 4225.31 58.72 218.73 2994.12 2885.12 1211.24 -1474.91 5947201.93 557141.20 MWD+IFR-AK-CAZ-SC 4318.68 62.42 211.13 3040.04 2931.04 1144.60 -1521.34 5947134.93 557095.31 MWD+IFR-AK-CAZ-SC 4412.45 62.54 205.36 3083.39 2974.39 1071.39 -1560.66 5947061.42 557056.55 MWD+IFR-AK-CAZ-SC 4505.47 65.67 199.24 3124.04 3015.04 994.00 -1592.34 5946983.80 557025.48 MWD+IFR-AK-CAZ-SC ~i 4599.02 64.31 198.33 3163.59 3054.59 913.74 -1619.64 5946903.34 556998.81 MWD+IFR-AK-CAZ-SC ' ~~ 4693.03 65.96 193.22 3203.14 3094.14 831.69 -1642.79 5946821.12 556976.30 MWD+IFR-AK-CAZ-SC ~!, 4784.50 65.62 191.43 3240.66 3131.66 750.20 -1660.60 5946739.49 556959.13 MWD+IFR-AK-CAZ-SC j 4879.26 64.36 190.69 3280.72 3171.72 665.92 -1677.08 5946655.10 556943.31 MWD+IFR-AK-CAZ-SC ~ I 4974.57 67.36 187.23 3319.70 3210.70 580.03 -1690.59 5946569.11 556930.47 MWD+IFR-AK-CAZ-SC II 5068.20 69.45 185.25 3354.16 3245.16 493.49 -1700.04 5946482.52 556921.69 MWD+IFR-AK-CAZ-SC ' ~ 5161.20 72.44 182.54 3384.53 3275.53 405.81 -1705.99 5946394.80 556916.43 MWD+IFR-AK-CAZ-SC 5254.29 77.35 182.62 3408.78 3299.78 316.06 -1710.04 5946305.02 556913.08 MWD+IFR-AK-CAZ-SC 5347.73 76.10 181.87 3430.23 3321.23 225.19 -1713.60 5946214.14 556910.22 MWD+IFR-AK-CAZ-SC 5441.59 77.86 182.13 3451.38 3342.38 133.80 -1716.79 5946122.74 556907.74 MWD+IFR-AK-CAZ-SC 5534.45 79.40 182.58 3469.69 3360.69 42.84 -1720.53 5946031.76 556904.71 MWD+IFR-AK-CAZ-SC i 5627.15 80.41 182.99 3485.93 3376.93 -48.31 -1724.97 5945940.58 556900.99 MWD+IFR-AK-CAZ-SC ~I 5720.63 79.48 181.58 3502.26 3393.26 -140.28 -1728.64 5945848.60 556898.03 MWD+IFR-AK-CAZ-SC ~' it 5814.68 79.62 183.10 3519.32 3410.32 -232.69 -1732.42 5945756.17 556894.97 MWD+IFR-AK-CAZ-SC '' 5907.86 81.93 182.84 3534.25 3425.25 -324.54 -1737.18 5945664.30 556890.93 MWD+IFR-AK-CAZ-SC ii 6001.30 80.25 183.31 3548.72 3439.72 -416.71 -1742.13 5945572.10 556886.69 MWD+IFR-AK-CAZ-SC ' ~, 6092.38 79.76 183.30 3564.53 3455.53 -506.26 -1747.30 5945482.52 556882.22 MWD+IFR-AK-CAZ-SC ~ 6188.39 77.17 179.31 3583.74 3474.74 -600.28 -1749.46 5945388.50 556880.80 MWD+IFR-AK-CAZ-SC 'I 6281.80 78.32 179.93 3603.56 3494.56 -691.56 -1748.86 5945297.24 556882.11 MWD+IFR-AK-CAZ-SC ~, I 6375.27 80.13 179.00 3621.04 3512.04 -783.37 -1748.00 5945205.44 556883.68 MWD+IFR-AK-CAZ-SC 6468.43 84.42 178.54 3633.56 3524.56 -875.64 -1746.01 5945113.20 556886.39 MWD+IFR-AK-CAZ-SC 6491.30 84.91 178.56 3635.68 3526.68 -898.40 -1745.44 5945090.44 556887.14 MWD+IFR-AK-CAZ-SC 6574.48 90.88 180.44 3638.74 3529.74 -981.48 -1744.71 5945007.38 556888.51 MWD+IFR-AK-CAZ-SC 6668.07 92.59 179.00 3635.90 3526.90 -1075.02 -1744.26 5944913.85 556889.69 MWD+IFR-AK-CAZ-SC 6761.64 91.80 178.39 3632.32 3523.32 -1168.50 -1742.13 5944820.40 556892.55 MWD+IFR-AK-CAZ-SC 6856.97 91.51 179.98 3629.57 3520.57 -1263.78 -1740.77 5944725.15 556894.65 MWD+IFR-AK-CAZ-SC 6948.18 91.37 180.23 3627.28 3518.28 -1354.96 -1740.94 5944633.98 556895.19 MWD+IFR-AK-CAZ-SC 7043.27 86.90 179.76 3628.71 3519.71 -1450.01 -1740.93 5944538.94 556895.94 MWD+IFR-AK-CAZ-SC !. 7136.50 91.39 179.30 3630.10 3521.10 -1543.21 -1740.17 5944445.76 556897.43 MWD+IFR-AK-CAZ-SC i i 7230.28 87.05 179.02 3631.38 3522.38 -1636.94 -1738.79 5944352.05 556899.53 MWD+IFR-AK-CAZ-SCE L--- --- -- - _ _. _ -- - . . Halliburton Company • Survey Report Company: ConocoPhillips Alaska Inc. Dafe: 5J3/2006 Time: 10:34:28 Page: 3 Field: Kuparuk River Unit Co-ordinate(NE) Reference: Well: 1J-152, True North Site: Kuparuk 1J Pad Vertical (TVD) Reference: 1J-152PB1: 109.0 Wetl: 1J-152 Section (VS) Reference: Well (OAON,O.OOE,9 80.OOAzi) ~~'ellpath: 1J-152PB1 Survey Calculation ~~4ethod: Minimum Curvature Db: Oracle Survc~° ,~~(D incl Azim T~'D __ Sys T'1'D _ __ N!S E/~V MapN ;V1apE Tool ft deg deg ft ft ft ft ft ft 7324.98 84.02 178.70 3638.75 3529.75 -1731.33 -1736.91 5944257.69 556902.14 MWD+IFR-AK-CAZ-SC j 7417.93 84.69 179.65 3647.89 3538.89 -1823.82 -1735.58 5944165.22 556904.19 MWD+IFR-AK-CAZ-SC ~ 7511.49 84.44 181.12 3656.75 3547.75 -1916.95 -1736.21 5944072.10 556904.29 MWD+IFR-AK-CAZ-SC 7605.55 85.68 179.11 3664.86 3555.86 -2010.65 -1736.40 5943978.40 556904.84 MWD+IFR-AK-CAZ-SC 7646.00 85.68 179.11 3667.90 3558.90 -2050.98 -1735.77 5943938.08 556905.78 PROJECTED to TD • Halliburton Company Survey Report Company: ConocoPhillips Alaska Inc. Date: 5/3/2006 Lime: 10:58:27 Page: 1 Field: Kuparuk River Unit Co-ordinate(NE) Reference-. We11: 1J-152, True North Site: Kuparuk 1J Pad Vertical (TVD) Reference: 1J-152PB2: 109.0 ' Well: 1J-152 Section (VS) Reference: Well (O.OON,O.OOE,180.OOAzi) 1y'ellpath: 1J-152P62 Survey Calculation M ethod: Minimum Curvature Db: Oracle Field: Kuparuk River Unit North Slope Alaska United States Map System:US State Plane Coordinate System 1927 Map Zone: Alaska, Zone 4 Geo Datum: NAD27 (Clarke 1866) Coordinate Syste m: Well Centre i~ Sys Datum: Mean Sea Level Geomagnetic Model: bggm2005 ~ Well: 1J-152 -- Slot Name: ---- ---------~I Well Position: +N/-S 83.97 ft Northing : 5946002.32 ft Latitude: 70 15 47.084 N +E/-W -163.96 ft Easting : 558625.36 ft Longitude: 149 31 33.778 W Position Uncertainty: 0.00 ft Wellpath: 1J-152P62 Drilled From: 1J-152P61 500292329871 Tie-on Depth: 6761.64 ft j Current Datum: 1J-152P62: Height 109.00 ft Above System Datum: Mean Sea Level Magnetic Data: 3/10/2006 Declination: 24.16 deg ', Field Strength: 57565 nT Mag Dip Angle: 80.77 deg ', Vertical Section: Depth From (TVD) +N/-S +E/-W Direction ft ft ft deg __- ~!~ 28.00 0.00 ----- ---- 0.00 -180.00 ~ -- ------ r -- --------- - I Survey Program for Definitive Wellpath ----- ------ _ - -_----_ I Date: 5/3/2006 Validated: No Version: 4 Actual From To Survey Toolwde Tool Name ~ ft ft 90.00 537.00 1J-152PB1 gyro (90.00- 537.00) CB-GYRO-SS Camera based gyro single shot 656.75 6761.64 1 J-152P61 (656.75-7605.55) (0) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 6811.00 9254.00 1 J-152P62 (6811.00-92 54.00) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC Survey MU Incl Azim TVD Sys TVll N/S E/W 111ap5 MapE Tool ft deg deg ft ft ft ft ft ft 0 90.00 0.3~ 153.9 I 90.00 -$9.00 5 0.0~ -0.1 5946002.17 558625.44 CB-GYRO-SS , 169.00 0.33 240.18 169.00 60.00 -0.46 -0.03 5946001.86 558625.33 CB-GYRO-SS 257.00 0.37 215.61 257.00 148.00 -0.81 -0.41 5946001.50 558624.95 CB-GYRO-SS 353.00 0.61 342.02 353.00 244.00 -0.58 -0.75 5946001.74 558624.61 CB-GYRO-SS 445.00 2.63 346.08 444.95 335.95 1.94 -1.41 5946004.25 558623.93 CB-GYRO-SS !, 'I 537.00 4.04 349.64 536.80 427.80 7.17 -2.50 5946009.47 558622.80 CB-GYRO-SS ', 656.75 7.14 348.99 655.96 546.96 18.63 -4.68 5946020.91 558620.53 MWD+IFR-AK-CAZ-SC ! 747.98 11.14 348.52 746.02 637.02 32.84 -7.52 5946035.10 558617.58 MWD+IFR-AK-CAZ-SC ' 839.68 13.86 349.80 835.53 726.53 52.33 -11.23 5946054.56 558613.72 MWD+IFR-AK-CAZ-SC '. ', 931.01 14.42 353.74 924.10 815.10 74.40 -14.41 5946076.60 558610.38 MWD+IFR-AK-CAZ-SC 1020.87 16.90 354.31 1010.62 901.62 98.53 -16.92 5946100.70 558607.67 MWD+IFR-AK-CAZ-SC ~ 1120.48 20.55 357.30 1104.94 995.94 130.41 -19.18 5946132.56 558605.17 MWD+IFR-AK-CAZ-SC 1213.13 22.43 356.92 1191.14 1082.14 164.31 -20.90 5946166.44 558603.19 MWD+IFR-AK-CAZ-SC ~ 1273.52 24.12 356.30 i 1246.62 1137.62 188.13 -22.31 5946190.25 558601.59 MWD+IFR-AK-CAZ-SC 1306.74 26.79 355.67 1276.61 1167.61 202.37 -23.32 5946204.48 558600.47 MWD+IFR-AK-CAZ-SC 1397.20 33.70 353.74 1354.71 1245.71 247.70 -27.60 5946249.77 558595.84 MWD+IFR-AK-CAZ-SC 1491.41 39.81 355.12 1430.16 1321.16 303.78 -33.02 5946305.80 558589.98 MWD+IFR-AK-CAZ-SC ~! 1584.09 46.04 357.97 1498.00 1389.00 366.75 -36.73 5946368.73 558585.78 MWD+IFR-AK-CAZ-SC '~! 1677.37 44.16 357.94 i 1563.84 1454.84 432.77 -39.09 5946434.74 558582.91 MWD+IFR-AK-CAZ-SC 1769.27 43.33 359.13 1630.23 1521.23 496.29 -40.71 5946498.23 558580.79 MWD+IFR-AK-CAZ-SC 1859.90 45.61 356.18 1694.91 1585.91 559.71 -43.34 5946561.62 558577.66 MWD+IFR-AK-CAZ-SC ~, 1952.12 49.11 352.59 1757.38 1648.38 627.19 -50.04 5946629.04 558570.44 MWD+IFR-AK-CAZ-SC 2043.67 52.60 342.96 1815.24 1706.24 696.39 -65.18 5946698.11 558554.76 MWD+IFR-AK-CAZ-SC 2136.92 55.91 333.37 1869.79 1760.79 766.45 -93.40 5946767.94 558526.01 MWD+IFR-AK-CAZ-SC 2229.42 57.89 326.70 1920.35 1811.35 833.49 -132.11 5946834.68 558486.78 MWD+IFR-AK-CAZ-SC 2323.46 61.30 323.86 1967.94 1858.94 900.11 -178.32 5946900.93 558440.06 MWD+IFR-AK-CAZ-SC ', 2415.35 59.74 326.15 2013.17 1904.17 965.63 -224.20 5946966.08 558393.67 MWD+IFR-AK-CAZ-SC i Halliburton Company • Survey Report Company: ConocoPhillips Alaska Inc. Uate: 5/3/2006 Time: 10:5827 Page: 2 Ficld: Kuparuk River Unit Co-ordinate(NE) Reference. Weli: 1J-152, True North Site: Kuparuk 1 J Pad Vertical (TVD) Reference: 1 J-152P62 109.0 Well: 1J-152 Section (VS) Reference: Well (OAON,OAOE,180.OOAzi) ' ~Vellpath: 1J-152PB2 Survey Calculation Method: Minimum Curvature llb: Oracle Sm-~ ev __ ___ A1D Incl Azim TVD SysTVD N/5 E/W IV1apN IV1apF, Tool ', ft deg deg ft ft ft ft ft ft ' 2507.53 61.17 322.16 2058.63 1949.63 1030.60 -271.16 5947030.68 558346.21 MWD+IFR-AK-CAZ-SC ' 2600.04 57.97 321.79 2105.48 1996.48 1093.43 -320.29 5947093.12 558296.60 MWD+IFR-AK-CAZ-SC !. 2694.14 58.26 320.11 2155.19 2046.19 1155.48 -370.62 5947154.77 558245.79 MWD+IFR-AK-CAZ-SC 2737.89 57.29 318.61 2178.52 2069.52 1183.56 -394.72 5947182.66 558221.47 MWD+IFR-AK-CAZ-SC ', 2824.65 56.33 316.70 2226.02 2117.02 1237.23 -443.62 5947235.94 558172.16 MWD+IFR-AK-CAZ-SC 2917.67 56.95 310.44 2277.20 2168.20 1290.72 -499.88 5947288.99 558115.50 MWD+IFR-AK-CAZ-SC 3010.82 58.11 305.21 2327.23 2218.23 1338.87 -561.93 5947336.65 558053.07 MWD+IFR-AK-CAZ-SC ~ 3106.49 58.00 297.13 2377.91 2268.91 1380.84 -631.30 5947378.07 557983.39 MWD+IFR-AK-CAZ-SC 3199.84 57.91 291.80 2427.47 2318.47 1413.59 -703.28 5947410.25 557911.16 MWD+IFR-AK-CAZ-SC 3293.54 57.09 284.95 2477.86 2368.86 1438.50 -778.20 5947434.58 557836.06 MWD+IFR-AK-CAZ-SC 3386.38 56.42 278.35 2528.79 2419.79 1454.18 -854.18 5947449.66 557759.97 MWD+IFR-AK-CAZ-SC ~; 3480.31 57.70 271,98 2579.90 2470.90 1461.24 -932.62 5947456.11 557681.48 MWD+IFR-AK-CAZ-SC ' 3573.11 57.79 264.56 2629.48 2520.48 1458.87 -1010.98 5947453.13 557603.15 MWD+IFR-AK-CAZ-SC 3666.73 56.46 257.70 2680.34 2571.34 1446.79 -1088.60 5947440.45 557525.64 MWD+IFR-AK-CAZ-SC 3760.80 55.63 251.72 2732.91 2623.91 1426.25 -1163.81 5947419.33 557450.59 MWD+IFR-AK-CAZ-SC 3853.77 55.26 245.94 2785.68 2676.68 1398.63 -1235.17 5947391.15 557379.46 MWD+IFR-AK-CAZ-SC 3945.47 53.52 240.08 2839.10 2730.10 1364.85 -1301.57 5947356.87 557313.33 MWD+fFR-AK-CAZ-SC I, 4039.70 55.93 231.18 2893.59 2784.59 1321.43 -1364.90 5947312.95 557250.34 MWD+IFR-AK-CAZ-SC ~~ 4131.77 57.12 225.10 2944.40 2835.40 1270.20 -1422.04 5947261.29 557193.61 MWD+IFR-AK-CAZ-SC 4225.31 58.72 218.73 2994.12 2885.12 1211.24 -1474.91 5947201.93 557141.20 MWD+IFR-AK-CAZ-SC 4318.68 62.42 211.13 3040.04 2931.04 1144.60 -1521.34 5947134.93 557095.31 MWD+IFR-AK-CAZ-SC ': 4412.45 62.54 205.36 3083.39 2974.39 1071.39 -1560.66 5947061.42 557056.55 MWD+IFR-AK-CAZ-SC '' 4505.47 65.67 199.24 3124.04 3015.04 994.00 -1592.34 5946983.80 557025.48 MWD+IFR-AK-CAZ-SC 4599.02 64.31 198.33 3163.59 3054.59 913.74 -1619.64 5946903.34 556998.81 MWD+IFR-AK-CAZ-SC 4693.03 65.96 193.22 3203.14 3094.14 831.69 -1642.79 5946821.12 556976.30 MWD+IFR-AK-CAZ-SC 4784.50 65.62 191.43 3240.66 3131.66 750.20 -1660.60 5946739.49 556959.13 MWD+IFR-AK-CAZ-SC ' 4879.26 64.36 190.69 3280.72 3171.72 665.92 -1677.08 5946655.10 556943.31 MWD+IFR-AK-CAZ-SC 4974.57 67.36 187.23 3319.70 3210.70 580.03 -1690.59 5946569.11 556930.47 MWD+IFR-AK-CAZ-SC 5068.20 69.45 185.25 3354.16 3245.16 493.49 -1700.04 5946482.52 556921.69 MWD+IFR-AK-CAZ-SC ~, ', 5161.20 72.44 182.54 3384.53 3275.53 405.81 -1705.99 5946394.80 556916.43 MWD+IFR-AK-CAZ-SC '; ' 5254.29 77.35 182.62 3408.78 3299.78 316.06 -1710.04 5946305.02 556913.08 MWD+IFR-AK-CAZ-SC i 5347.73 76.10 181.87 3430.23 3321.23 225.19 -1713.60 5946214.14 556910.22 MWD+IFR-AK-CAZ-SC I 5441.59 77.86 182.13 3451.38 3342.38 133.80 -1716.79 5946122.74 556907.74 MWD+IFR-AK-CAZ-SC ', 5534.45 79.40 182.58 3469.69 3360.69 42.84 -1720.53 5946031.76 556904.71 MWD+IFR-AK-CAZ-SC 'I 5627.15 80.41 182.99 3485.93 3376.93 -48.31 -1724.97 5945940.58 556900.99 MWD+IFR-AK-CAZ-SC 5720.63 79.48 181.58 3502.26 3393.26 -140.28 -1728.64 5945848.60 556898.03 MWD+IFR-AK-CAZ-SC 5814.68 79.62 183.10 3519.32 3410.32 -232.69 -1732.42 5945756.17 556894.97 MWD+IFR-AK-CAZ-SC 5907.86 81.93 182.84 3534.25 3425.25 -324.54 -1737.18 5945664.30 556890.93 MWD+IFR-AK-CAZ-SC 6001.30 80:25 183.31 3548.72 3439.72 -416.71 -1742.13 5945572.10 556886.69 MWD+IFR-AK-CAZ-SC ~~ 6092.38 79.76 183.30 3564.53 3455.53 -506.26 -1747.30 5945482.52 556882.22 MWD+IFR-AK-CAZ-SC i 6188.39 77.17 179.31 3583.74 3474.74 -600.28 -1749.46 5945388.50 556880.80 MWD+IFR-AK-CAZ-SC '. 6281.80 78.32 179.93 3603.56 3494.56 -691.56 -1748.86 5945297.24 556882.11 MWD+IFR-AK-CAZ-SC ' 6375.27 80.13 179.00 3621.04 3512.04 -783.37 -1748.00 5945205.44 556883.68 MWD+IFR-AK-CAZ-SC '~ 6468.43 84.42 178.54 3633.56 3524.56 -875.64 -1746.01 5945113.20 556886.39 MWD+IFR-AK-CAZ-SC ~, ' 6491.30 84.91 178.56 3635.68 3526.68 -898.40 -1745.44 5945090.44 556887.14 MWD+IFR-AK-CAZ-SC 6574.48 90.88 180.44 3638.74 3529.74 -981.48 -1744.71 5945007.38 556888.51 MWD+IFR-AK-CAZ-SC 6668.07 92.59 179.00 3635.90 3526.90 -1075.02 -1744.26 5944913.85 556889.69 MWD+IFR-AK-CAZ-SC ~ 'i 6761.64 91.80 178.39 3632.32 3523.32 -1168.50 -1742.13 5944820.40 556892.55 MWD+IFR-AK-CAZ-SC ' 6811.00 91.65 179.21 3630.84 3521.84 -1217.83 -1741.09 5944771.09 556893.97 MWD+IFR-AK-CAZ-SC ~ 6856.80 87.41 179.48 3631.21 3522.21 -1263.61 -1740.57 5944725.32 556894.85 MWD+IFR-AK-CAZ-SC ~I ' 6950.18 83.59 180.04 3638.54 3529.54 -1356.69 -1740.18 5944632.26 556895.96 MWD+IFR-AK-CAZ-SC I~ 7043.58 83.76 179.51 3648.83 3539.83 -1449.52 -1739.82 5944539.44 556897.05 MWD+IFR-AK-CAZ-SC ', ~, Halliburton Company! Survey Report Company: ConocoPhillips Alaska Inc. llate: 5/3/2006 Time: 10:58:27 Pahe: 3 Field: Ku paruk River Unit Co-ordinate(NE) Re ference: Well: 1J-152, True North Site: Ku paruk 3J Pad Vertical (TVD) Refe rence: 1J -152P62: 109.0 Well: 1J-152 Section (VS) Refere nce: Well (O.OON,O.OOE,1 80AOAzi) Wcllpath: 1J-152PB2 Survey Calculation Method: Mi nimum Curvature llb: Oracle Survc~ ', ~1D Incl Azim TVD Sys TVD N/S F.1W 111apN MapE Too] ', ft deg deg ft ft ft ft ft ft 7135.81 88.58 180.30 3654.98 -____ 3545.98 -1541.51 -1739.66 _ 5944447.46 __ 556897.92 MWD+IFR-AK-CAZ-SC 7229.17 86.00 181.42 3659.40 3550.40 -1634.75 -1741.06 5944354.22 556897.24 MWD+IFR-AK-CAZ-SC 'i 7325.49 89.83 181.87 3662.90 3553.90 -1730.95 -1743.83 5944258.02 556895.23 MWD+IFR-AK-CAZ-SC 7416.09 92.61 182.11 3660.97 3551.97 -1821.46 -1746.97 5944167.49 556892.79 MWD+IFR-AK-CAZ-SC 7510.85 93.65 181.11 3655.80 3546.80 -1916.04 -1749.63 5944072.90 556890.87 MWD+IFR-AK-CAZ-SC ' 7603.73 89.70 181.09 3653.08 3544.08 -2008.85 -1751.41 5943980.09 556889.81 MWD+IFR-AK-CAZ-SC 7697.59 92.92 180.52 3650.94 3541.94 -2102.66 -1752.73 5943886.28 556889.22 MWD+IFR-AK-CAZ-SC ' 7789.92 91.59 178.46 3647.31 3538.31 -2194.91 -1751.91 5943794.05 556890.76 MWD+IFR-AK-CAZ-SC 7884:30 92.48 178.27 3643.95 3534.95 -2289.19 -1749.22 5943699.80 556894.19 MWD+IFR-AK-CAZ-SC 'i 'I 7977.28 91.88 179.33 3640.42 3531.42 -2382.08 -1747.27 5943606.94 556896.85 MWD+IFR-AK-CAZ-SC 8070.43 90.32 182.37 3638.63 3529.63 -2475.19 -1748.65 5943513.83 556896.20 MWD+IFR-AK-CAZ-SC 8165.87 92.38 181.49 3636.38 3527.38 -2570.54 -1751.87 5943418.47 556893.73 MWD+IFR-AK-CAZ-SC 8256.73 93.17 178.71 3631.98 3522.98 -2661.28 -1752.03 5943327.73 556894.27 MWD+IFR-AK-CAZ-SC 8346.90 93.10 177.64 3627.05 3518.05 -2751.27 -1749.16 5943237.78 556897.84 MWD+IFR-AK-CAZ-SC 8438.20 93.20 181.74 3622.03 3513.03 -2842.41 -1748.67 5943146.65 556899.04 MWD+IFR-AK-CAZ-SC 8528.94 91.80 180.28 3618.07 3509.07 -2933.05 -1750.26 5943056.02 556898.15 MWD+IFR-AK-CAZ-SC 8619.50 93.00 180.47 3614.28 3505.28 -3023:52 -1750.86 5942965.55 556898.27 MWD+IFR-AK-CAZ-SC 8710.38 86.80 178.86 3614.44 3505.44 -3114.36 -1750.32 5942874.73 556899.50 MWD+IFR-AK-CAZ-SC i 8801.27 86.62 177.95 3619.65 3510.65 -3205.06 -1747.80 5942784.06 556902.73 MWD+IFR-AK-CAZ-SC ~ 8892.31 86.80 177.87 3624.88 3515.88 -3295.89 -1744.48 5942693.27 556906.76 MWD+IFR-AK-CAZ-SC I 8982.38 87.66 178.62 3629.23 3520.23 -3385.81 -1741.73 5942603.38 556910.21 MWD+IFR-AK-CAZ-SC '. 9073.05 91.25 181.45 3630.10 3521.10 -3476.45 -1741.79 5942512.75 556910.86 MWD+IFR-AK-CAZ-SC ', 9163.14 85.43 183.65 3632.70 3523.70 -3566.37 -1745.79 5942422.81 556907.56 MWD+IFR-AK-CAZ-SC ', 9254.00 84.14 179.68 3640.97 3531.97 -3656.80 -1748.42 5942332.37 556905.63 MWD+IFR-AK-CAZ-SC i ~ 9343.00 84.14 179.68 3650.05 3541.05 -3745.33 -1747.92 5942243.86 556906.82 PROJECTED to TD • ~ ~'°~ ` ~ ~ ~ ,~ ~~ FRANK H. MURKOWSKI, GOVERNOR ~~ ~~~++ ~~~+ ~ ~r oi/L~~7~ 0~ ~`l>~-7 333 W. 7"' AVENUE, SUITE 100 C~l~-7~RQA'1`I~1Q COMl~'IIS9IUI~T 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, AK 99510-0360 Re: Kuparuk River, 1J-152 ConocoPhillips Alaska, Inc. Permit No: 206-016 Surface Location: 2191' FSL, 2582' FEL, Sec. 35, T 11 N, R 10E, UM Bottomhole Location: 2265' FNL, 957' FSL, Sec. 2, T10N, RlOE, UM Dear Mr. Thomas: Enclosed is the approved application for permit to drill the above referenced development well. This permit to drill does not exempt you from obtaining additional permits or an approval 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. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). Sincerely, f~ Cath P. Foerster Commissioner DATED this ~~~ y of January, 2006 cc: Department of Fish 8ti Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. Conoco~hillips ~ Alaska Post Office Box 100360 Anchorage, Alaska 99510-0360 Randy Thomas Phone (907) 265-6830 Email: Randy.L.Thomas@conocophillips.com ~~'~~'~~® January 23, 2006 Alaska ~~ ~ ~~~ ~~ Alaska Oil and Gas Conservation Commission ' ~~sarp~ 333 West 7th Avenue Ancfiorag~ Suite 100 ~ y`2rT Anchorage, Alaska 99501 (~rur~ ~ ~ Y, ,~ ;~ ~z; r~v~~7 ~ Re: Applications for Permit to Drill, West Sak I ~ or, 1J-152, 1J-152 Ll, 1J-152 L2 Dear Commissioners: // ~~~ L`'~ .~ ~~ "' t ~' .L~11J~ /' ConocoPhillips Alaska, Inc. hereby applies for Permits to Drill for an onshore ~ on well, a trilateral horizontal well in the West Sak °A2", "B"and'~D" sands.' The main bore of the well will be designated 1]- 152, and the lateral bores of the well will be designated iJ-152L1 and iJ-152L2. Please find attached for the review of the Commission forms 10-401 and the information required by 20 ACC 25.005 for each of these well bores. The expected spud date of 1J-152 is March 26, 2006. ' If you have any questions or require any further information, please contact Mike Greener at 263-4820. Sincerely, .~~ ~ Randy Thomas Greater Kuparuk Area Drilling Team Leader ~ECEivED STATE OF ALASKA ~ ., (i~j ALASKA OIL AND GAS CONSERVATION COMMISSION ~ ~ i `SAN 2 6 LU PERMIT TO DRILL Alaska Oil,& Gas Cons. Commissron 20 AAC 25.005 ~b (~ ~`~` ~ Anchorage 1 a. Type of Work: Drill / Redrill 1 b. Current Well Class: Exploratory ~ ` ~ Development Oil lu~`'`~;2w~ Multiple Zone ^ Re-entry ^ Stratigraphic Test ^ Service ', i.~s Development Gas ^ Single Zone 0 2. Operator Name: 5. Bond: / Blanket Single Well 11. Wetl Name and Number: ConocoPhillips Alaska, Inc. Bond No. 59-52-180 ~ 1J-152 P.O. Box 100360 Anchorage, AK 99510-0360 . Location of Well (Governmental Section): Surface: 2191' FSL, 2582' FEL, Sec. 35, T11 N, R10E, UM p of Productive Horizon: 1268' FSL, 942' FWL, Sec. 35, T11 N, R10E, UM ~ tal Depth: 2265' FNL, 95T FWL, Sec. 2, T10N, R10E, UM ~ . Location of Well (State Base Plane Coordinates): Surface: x- 558625 y- 5946002 a Zone- 4 MD: 9888' ~ ND: 3632' Property Designation: ADL 25661 & 25662 ~ ALK 471 & 2177 9. Acres in Property: 2560 10. KB Elevation above Gu 28' RKB / 108' AMSL I Well within Pool: 1J-154L1 , 1170' @ 56: ~ Kuparuk River Field West Sak Oil Pool ' 3/26!2006 14. Distance to Nearest Property: <3 miles - 16. Deviated wells: Kickoff depth: 300 ft. Maximum Hole Angle: 91.8° deg 17. Maximum Anticipated Pressures in psig (see 20 AAC 25.035) Downhole: 1638 psig ' Surface: 1237 psig ~ 18. Casing Program S if ti Setting Depth Quantity of Cement Size pec ica ons Top Bottom c. f. or sacks Hole Casing Weight Grade Coupling Length MD ND MD ND (including stage data) 42" 20x34" 94# K-55 Welded 80' 28' 28' 108' ° 108' ' 260 cf ArcticCrete 13.5" 10.75" 45.5# L-80 BTC 2825' 28' 28' 2825' ~ 2204' 530 sx AS Lite, 180 sx DeepCrete 9-7/8" 7-5/8" 29.7# L-80 BTCM 6353' 28' 28' 6353' . 3639' 360 sx DeepCrete 6.75" 4.5" 12.6# L-80 IBTM 4270' 5618' 3520' 9888' ~ 3632' - slotted liner 19 PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re-Entry Operations) Total Depth MD (ff): Total Depth ND (ft): Plugs (measured) Effective Depth MD (ft): Effective Depth ND (ft): Junk (measured) Casing Length Size Cement Volume MD TVD Structural Conductor Surface Intermediate Production Liner - refer to 1 F-01A Perforation Depth MD (ft): Perforation Depth ND (ft): 20. Attachments: Filing Fee Q BOP Sketch ^ Drilling Program ^/ Time v. Depth Plot ^ Shallow Hazard Analysis Q Property Plat ^ Diverter Sketch ^ Seabed Report ^ Drilling Fluid Program ^/ 20 AAC 25.050 requirements ^/ 21. Verbal Approval: Commission Representative: Date: 22. I hereby certify that the foregoing is true and corcect to the best of my knowledge. Contact Mike Greener @ 263-4820 Printed Name Randy Thomas Title Greater Kuparuk Area Drilling Team Leader Signature f ~ - Phone Z.6 S 6 ~Sp Date j, ~Z-3/~,r, P a b r nAll u k Commission Use Only Permit to Drill API Number: Permit Approval See cover letter Number: ~.~..~ "c~/~ ~~ ~/ ~ 50- {.:~~9 - ~J~,~G~ ~...C..-~ ate: r 1 ~'~ for other requirements Conditions of approval : 7J~JQ5~ ~oe ~..,. 5~ ~S ~Ur,~~ Samples required ~ ~- Yes ~ No ~ Mud log required Yes ^ No [~ Hydrogen sulfide measures Yes ^ No ~ Directional survey required Yes [~ No ^ Other: APPROVED BY Approved b . THE COMMISSION Date: "' Form 10-401 Revised 06/2004 ~ K ~ ~ ~ t ~ ~ L Submit in Duplicate f~tion for Permit to Drill, Well 1 J-152 Revision No.O Saved: 23-Jan-46 Permit It -West Sak Well #1J-152 ~~`~~ r.• +~k Application for Permit to Dri/l Document „~: I1+~W~11 M Crx i ith i z ~ weft Vc~iue Table of Contents 1. Well Name .....................................................................................................................2 Requirements of 20 AAC 25.005 (~ .................................................................................................... 2 2. Location Summary .......................................................................................................2 Requirements of 20 AAC 25.005(c)(2) ..............................................................................~...............~. 2 Requirements of 20 AAC 25.050(b) .................................................................................................... 3 3. Blowout Prevention Equipment Information ............................................................ 3 Requirements of 20 AAC 25.005(c)(3) ................................................................................................ 3 4. Drilling Hazards Information ...................................................................................... 3 ............... Requirements of 20 AAC 25A05 (c)(4) ............................................................ .................... 3 5. Procedure for Conducting Formation Integrity Tests ............................................. 4 Requirements of 20 AAC 25.005 (c)(5) ............................................................................................... 4 6. Casing and Cementing Program ................................................................................ 4 Requirements of 20 AAC 25.005(c)(6) ............................................................:................................... 4 7. Diverter System Information ...................................................................................... 4 Requirements of 20 AAC 25A05(c)(7) ................................................................................................ 4 8. Drilling Fluid Program .................................................................................................4 Requirements of 20 AAC 25.005(c)(8) ....................~..................................,,...,................................... 4 Surface Hole Mud Program (extended bentonite) ................................................................................ 5 Intermediate Hole Mud Program (extended bentonite) ........................................................................ 5 Lateral Mud Program (MI VersaPro Mineral Oil Base) ......................................................................... 5 9. Abnormally Pressured Formation Information ........................................................5 Requirements of 20 AAC 25.005 (c)(9) .......................~....................................,.................................. 5 10. Seismic Analysis ..........................................................................................................5 Requirements of 20 AAC 25.005 (e)(10) ............................................................................................. 5 11. Seabed Condition Analysis ........................................................................................6 Requiremenfs of 20 AAC 25.005 (c)(11) ............................................................................................. 6 ~ ~ ~ ~ ~ ~ ~ ~ (not done) 1J-152 PERMIT lT Page 7 of 8 Printed:23-Jan-06 • /~ation for Permit to Drill, Well 1J-152 Revision No.O Saved: 23-Jan-06 12. Evidence of Bonding ...................................................................................................6 Requirements of 20 AAC 25.005 (c)(72) ............................................................................................. 6 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 Requirements of 20 AAC 25.005 (c)(74) ............................................................................................. 8 15.Attachments ..................................................................................................................8 Attachment 7 Directional Plan ............................................................................................................. 8 Attachment 2 Drilling Hazards Summary ............................................................. ................................ 8 Attachment 3 Cement Loads and CemCADE Summary ...................... ...................... 8 ......................... Attachment 4 Well Schematic ............................................................................................................ 8 1. Well Name Requirements of 20 AAC 25.005 (f} Each we/1 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(6 ). For a well with mu/tip/e we// branches, each branch must simi/ar/y be identified by a unique name and API number by adding a sui"fix to the name designated for the we// by the operator and to the number assigned to the we/I by the commission. The well for which this Application is submitted will be designated as 1J-152. - 2. Location Sumnnary Requirements of 20 AAC 25.005(c}(2} An application for a Permit to Dri0 must be accompanied by each of the fo!/owing items, except for an item a/re~x/y on fi/e with the commission and identified in the app/ication.• (2) a p/at identifying the property and the property's owners and showing (A)the coordinates of the proposed location of the we// at the surface, at the top ofeach objective formation, and at tota/depth,. referenced to govemmenta/section lines. (B) the coordinates of the proposed /ocation of the we// at the surface, referenced to the state plane coordinate system for this state as maintained by the Nationa/ Geodetic Survey in the National Oceanic and Atmospheric Administration,- (C) the proposed depth of the we/l at the top ofeach objective formation and at Iota/ depth; Location at Surface 2,191' FSL, 2,582' FEL, Section 35, T11N, R10E - ASPZone 4NAD27Coordinates RKB E/evation 108.0' AMSL - Northings: 5,946,002 Eastings: 558,625 Pad E/evation 80.0' AMSL Location at Top of Productive Interval 1,268' FSL, 942' FWL, Section 35, T11N, R10E West Sak "A2" Sand ASP Zone 4 NAD 27 Coordinates Measured De th RKB: 6 353 /Vorthings: 5,945,065 Eastings 556,877 Total I/ertica/ De th, RKB: 3,639 Tota/ t/ertica/ Depth, SS.- 3,530 Location at Total De th 2,265' FNL, 957' FWL, Section 2, T10N, R10E - ASP Zone 4 NAD 27 Coordinates Measured De th, RKB.• 9,888 Northings: 5,941,533 Eastings: 556,924 Total ~ettical De th, RKB: 3,632 Tota/ ~ertica/Depth, SS.• 3, 523 and ORIGINAL (not done) 1J-152 PERMI7IT Page 2 of 8 Printed: 23-Jan-06 F~tion for Permit to Drill, Well 1 J-152 Revision No.O Saved: 23-Jan-06 (D) other information required by 20 AAC 25.050(6),• Requirements of 20 AAC 25.050(6) If a we// is to be intentional/y deviated, the app/ication for a Permit to DriJ/ (Form 10-401) must (1) include a p/at, drawn to a suitable sca/e, showing the path of the proposed we//bore, including a//adjacent we/!bores within 200 feet of any portion of the proposed wel% Please see Attachment 1: Directional Plan and (Z) for all we//s within 200 feet of the proposed we!/bore (AJ list the names of the operators of those wells, to the extent that those names are known or discoverab/e in pub/ic records, and show that each named operator has been furnished a copy of the application by certified mai/,- or (B) state that the app/icant is the on/y affected owner The Applicant is the only affected owner. 3. Blowout Prevention Equipment Information Requirements of 20 AAC 25.005(c)(3) An app/ication for a Permit to Dri/! must be accompanied by each of the following items, except for an item a/ready on fi/e with the commission and identified in the application: (3) a diagram and description of the blowout prevention equipment (BOPS) as required by 20 AAC 25.035, 20 AAC 25.036, or 20 AAC 25.037, as app/icab/e,• An API 13-5/8" x 5,000 psi BOP stack (RSRRA) will be utilized to drill and complete well 1J-152. For all operations the stack will be equipped with 3-1/2" to 6" variable bore rams in the uppermost ram cavity, `~ blind rams in the middle cavity, and 7-5/8" rams in the lowermost cavity. See attached diagram entitled f °Doyon 141 West Sak 2004 3ksi BOP Configuration" for clarification. Upon initial nipple up, and at ~^ intervals of no more than 14 days thereafter, a test plug will be set below the lowermost rams, the annular preventer will be tested to 1,500 psi and the blind rams and upper rams will be tested to 3,000 ~~"~~ psi. (This test will test the shell and end connections of the lowermost ram). Immediately prior to running the intermediate string of 7-5/8" casing, a test plug will be set below the lowermost rams, and those rams will be closed and tested to 3,000 psi on a 7-5/8" OD. 4. Drilling Hazards Information Requirements of 20 AAC 25.005 (c)(4) An app/ication for a Permit to Dri/l must be accompanied by each of the fol/owing items, except for an item a/ready on fi/e with the commission and identified in the application: (4) information on drilling hazards, including (A) the maximum downho% pressure that may be encountered, criteria used to determine it, and maximum potential surface pressure based on a methane gradient,- The expected reservoir pressures in the West Sak sands in the 1J area are 0.45 psi/ft, or 8.7 ppg EMW , (equivalent mud weight). These pressures are predicted based on the undisturbed West Sak pressure gradient. The maximum potential surface pressure (MPSP) based on the above maximum pressure gradient, a methane gradient (0.11), and the deepest planned vertical depth of the West Sak A2 sand formation is 1,237 psi, calculated thusly: MPSP =(3,639 ft TVD)(0.45 - 0.11 psi/ft) =1,237 psi (B) data on potentia/gas zones; The well bore is not expected to penetrate any gas zones. ' and (C) data concerning potentia/ causes of ho% problems such as abnorma//y geo pressured strata, lost circulation zones, and zones that have a propensity for differential sticking, Please see Attachment 2: 1J-152 Drilling Hazards Summary. ~ ORIGINAL (not done) 1J-152 PERMIT tT Page 3 of 8 Printed: 23-Jan-06 ,~tion for Permit to Drill, Well 1 J-152 Revision No.O Saved: 23-Jan-46 5. Procedure for Conducting Formation Integrity Tests Requirements of 20 AAC 25.005 (c)(5) An application for a Permit to Dril/must be accompanied by each of the fo/Jowmg items, except for an item a/ready on file with the commission and identified m the app/ication.• (5) a description of the procedure for conducting formation integrity tests, as required under 20 AAC 25.0300• 1J-152 will be completed with 7-5/8" intermediate casing landed at the top of the West Sak A2 sand. ` The casing shoe will be drilled out and a formation integrity test will be performed in accordance with the "Formation Integrity Test Procedure" that ConocoPhillips Alaska placed on file with the Commission. 6. Casing and Cementing Program Requirements of 20 AAC 25.005(c)(6) An app/ication for a Permit to Dri// must be accompanied by each of the fo/%wing items, except for an item already on fi/e with the commission and identified in the app/ication.• (6) a comp/ete proposed casing and cementing program as required by 20 AAC 25.030, and a description of any slotted liner pre- perforated liner or screen to be instal/ed,• Casing and Cementing Program See also Attachment 3: Cement Summary Hole Top Btm Csg/Tbg Size Weigh Length MDlTVD MD/TVD OD (in (in) t (lb/ft Grade Connection ft (ft) ft Cement Program 20 x 34 42 94 K55 Welded 80 28 / 28 108 / 108 Cemented to surface with 260 cf ArcticCRETE BTC Cemented to Surface with 10-3/4 13-1/2 45.5 L-80 special 2,825 28 / 28 2,825 /2,204 530 sx ASLite Lead, 180 sx DeepCRETE Tail drift Cement Top planned @ 7-5/8 9-7/8 29.7 L-80 BTCM 6,353. 28 / 28 6,353 / 3,639 3.450' MD / 2,596` TVD_ Cemented w/ 360 sx Dee RETE 4-1/2 6-3/4" A Sand 12.6 L-80 IBTM 4,270 5,618 / 3,520 9,$88 / 3,632 Slotted- no cement Slotted Lateral (iJ-152) 4-1/2 6-3/4" B Sand 12.6 L-80 IBTM 7,727 5,518/ 3,502 13,245 / 3,423 Slotted- no cement slotted Lateral (1J-152 Ll) 4-1/2 6-3/4" D sand 12.6 L-80 IBTM 7,708 5,232/ 3,437 12,940 / 3,347 Slotted- no cement slotted Lateral (1J-152 L2) 7. Diverter System Information Requirements of 20 AAC 25.005(c)(7) An application for a Permit to Dri// must be accompanied by each of the fo/%wing items, except for an item a/ready on fi/e with the commission and identified in the application: (7) a diagram and description of the diverter system as required by 20 AAC 25.035, unless this requirement is waived by the commission under 20 AAC 25.035('h)(2); A 21-1/4", 2000 psi annular with a 16"diameter diverter line will be the diverter system used in the drilling of 1J-152. Please see diagrams of the Doyon 141 diverter system on file with the Commission. 8. Drilling Fluid Program Requirements of 20 AAC 25.005(c)(8) An app/ication for a Permit to Drill must be accompanied by each of the fo/%wing items, except for an item a/re~xly on file with the commission and identified in the app/ication: (8) a drilling fluid program, including a diagram and description of the drilling fluid system, as required by 20 AAC 25.033,- Drilling will be done with muds having the following properties over the listed intervals: ORIGINAL (not done) 1J-152 PERMIT IT Page 4 of 8 Printed: 23-Jan-06 • Surface Hole Mud Program (extended bentonite) P~tion for Permit to Drill, Well 1 J-152 Revision No.O Saved: 23-Jan-06 Spud to Base of Permafrost Base of Permafrost to 10-3/4" Casin Point lnitial Value Final Value Initial Value Final Value Density (ppg) 8.9 9.2 9.5 9.6 (runnel viscosity 150 250 200 300 seconds Yield Point (cP) 50-70 50-70 30-50 30-50 Plastic Viscostiy 20-45 20-45 15-20 15-20 Ib/100 s pH 8.5-9.0 8.5-9.0 8.5-9.0 8.5-9.0 API Filtrate NC-8 0 NC-8 0 5.0-7.0 5.0-7.0 (cc / 30 ruin ) . . *9.6 ppg if hydrates are encountered Intermediate Hole Mud Program (LSND) 10-3/4"Casing Shoe to 7-5/B" Casin Point lnitial Value Density (ppg) 9.0-9.1 Funnel Viscosity 45-60 (seconds Plastic Viscostiy 12-18 (lb/100 s Yield Point 26-35 cP) APl Filtrate 4-6 (cc / 30 min) Chlorides (mg/I) <500 pH 9.0-9.5 MBT <20.0 i Lateral Mud Program (MI VersaPro Mineral Oil Base) A/B/D sand laterals Value Density (ppg) 8.6 Plastic Viscostiy 15-25 (lb/100 s Yield Point 18.28 (cP) HTHP Fluid loss (ml/30 min <4.0 @ 200psi & 150° Oil /Water 70 / 30 Ratio Electrical >600 Stability Drilling fluid practices will be in accordance with appropriate regulations stated in 20 AAC 25.033. Please see information on file with the Commission for diagrams and descriptions of the fluid system of Doyon Rig 141. 9. Abnormally Pressured Formation Information Requirements of 20 AAC 25.005 (c)(9) An app/ication for a Permit to Dri1/ must be accompanied by each of the fo/%wing items, except for an item a/ready on fi/e with the commission and identified in the app/ication: (9) For an exp/oratory or stratigraphic test we/% a tabu/ation setting out the depths of predicted abnormal/y geo pressured strata as required by ZO AAC 25.033((] Not applicable: Application is not for an exploratory or stratigraphic test well. 10. Seismic Analysis Requirements of 20 AAC 25.005 (c)(10) An application for a Permit to Drill must be accompanied by each of the fo/%wing items, except for an item a/ready on fi/e with the commission and identified in the app/ication. (i0) for an exploratory or stratigraphic test we!/,. a seismic refraction or reflection analysis as required by 20 AAC 25.061(a); Not applicable: Application is not for an exploratory or stratigraphic test well. ORIGINAL (not done) 1J-152 PERMI7IT Page 5 of 8 Printed: 23-Jan-06 • A~ion for Permit to Drill, Well 1J-152 Revision No.O Saved: 23-Jan-06 11. Seabed Condition Analysis Requirements of 20 AAC 25.005 (c)(11) An app/ication for a Permit to Drill must be accompanied by each of the fo//awing items, except for an item a/ready on h/e with the commission and identified in the application: (11) for a we// dri/led from an offshore platform, mobile bottom-founded structure, jack-up rig, or floating dri/ling vess% an analysis ofseabed conditions as required by 20 AAC 25.061(b),~ Not applicable: Application is not for an offshore well. 12. Evidence of Bonding Requirements of 20 AAC 25.005 (e)(12) An app/ication for a Permit to Dri/l must be accompanied by each ofthe fo/%wing items, except for an item a/ready on fi/e with the commission and identified in the app/ication: (12J 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. 13. Proposed Drilling Program Requirements of 20 AAC 25.005 (c)(13) An app/ication for a Permit to Dri//must be accompanied by each of the fo/%wing items, except for an item a/reo~dy on fi/e with the commission and identified in the application: The proposed drilling program is listed below. Please refer also to Attachment 4, Well Schematic. 1. Excavate cellar, install cellar box, set and cement 20" x 34"insulated conductor to +/- 108' RKB. Install landing ring on conductor. 2. Move in /rig up Doyon Rig 141. Install 21-1/4" Annular with 16" diverter line and function test. 3. Spud and directionally drill 13-1/2" hole to casing point at +/- 2,825' MD / 2,204' TVD as per directional plan. Run MWD tools as required for directional monitoring. 4. Run and cement 10-3/4", 45.5#, L80, BTC casing to surface. `Displace cement with mud and, pressure test casing to 2500 psi for 30 minutes and record results. Perform top job if required. 5. Remove diverter system, install and test 13-5/8" x 5,000 psi BOP's as described above in Section 3 above and test to 3,000 psi (annular preventer to 1500 psi). Notify AOGCC 24 his before test. 6. PU 9-7/8" bit and 6-1/4"drilling assembly, with MWD, LWD & PWD. RIH, clean out cement to top of float equipment. Re-test casing if cement is tagged more than 100 feet above the float collar. 7. Drill out cement and between 20' and 50' of new hole. Perform formation integrity test to leak off, recording results. (ECD's modeled to be less than 11.0 ppg) 8. Directionally drill to 7-5/8" casing point at 6,353 ,MD / 3,639' TVD, the prognosed top of the A2 sand. 9. Run 7-5/8", 29.7# L80, BTC Mod casing to surface. Pump cement and displace with mud (top of cement to be 3,450' MD / 2,596' TVD if Ugnu C formation is oil bearing. Top of cement to be 500 feet (MD) above shallowest oil bearing sand.). Pressure test casing to 3,000 psi for 30 minutes and record results. 10. Install wellhead x 7-5/8" packoff and test to 5000 psi. 11. Flush 10-3/4" x 7-5/8"annulus with water, followed by diesel. 12. PU 6-3/4" PDC Bit and 4-3/4"drilling assembly, with MWD, and LWD~logging tools. RIH, clean out cement to top of float equipment. Re-test casing if cement is tagged more than 100 feet above the float collar 13. Drill out cement and between 20' and 50' of new hole. Displace hole to lateral drilling mud. Perform formation integrity test to leak off, recording results. (expected ECD's in 6-3/4" lateral modeled to be less than 12.0 ppg). 14. Directionally drill 6-3/4" hole to TD at +/- 9,888' MD / 3,632' TVD as per directional plan. (not done) 1J-152 PERMlT 1T Page E of 8 Printed: 23-Jan-06 fl • A~tion for Permit to Drill, Well 1 J-152 Revision No.O Saved: 23-Jan-46 15. POOH, back reaming out of lateral to 7-5/8"shoe. TIH to bottom & displace to solids-free oil based mud. POOH on elevators. -~^ 16. PU and run 4-1/2" slotted liner. 1 ~i~-6~ 17. Land liner, set liner hanger @ +/- 5,618' MD j 3,520`TVD. POOH. Note: Remaining operations are covered under the 1J-152L1 Application for Permit to Drill, and are provided here for information only. 18. Run and set Baker WindowMaster whipstock system, at window point of 5,518' MD / 3,502' TVD, the top of the B sand. 19. Mill 6-3/4"window. POOH. 20. Pick up 6-3/4"drilling assembly with LWD and MWD and PWD. RIH. 21. Drill to TD of B sand lateral at 13,245' MD / 3,423' TVD, as per directional plan. 22. POOH, back reaming out of lateral to window. TIH to bottom & displace to solids-free oil based mud. POOH on elevators. 23. RIH with whipstock retrieval tool. Retrieve whipstock and POOH. _ 24. PU and run 4-1/2" slotted liner. A ~"~~ 25. RIH, until liner hanger is just above window. Orient hanger to window and land hanger. 26. Release hanger running tool. POOH. 27. Make up junction isolation / re-entry assembly (Lateral Entry Module or LEM) and RIH to depth. Orient and set packer atop assembly and release from assembly. POOH. Note: Remaining operations are covered under the 1J-152L2 Application for Permit to Drill, and are provided here for information only. 28. Run and set Baker WindowMaster whipstock system, at window point of 5,232' MD / 3,437' TVD, the top of the D sand. 29. Mill 6-3/4"window. POOH. ~ ~ _ ~ ~~ ~~ 30. Pick up 6-3/4"drilling assembly with LWD and MWD and PWD. RIH. 31. Drill to TD of D sand lateral at 12,940' MD / 3,347' TVD, as per directional plan. 32. POOH, back reaming out of lateral to window. TIH to bottom & displace to solids-free oil based mud. POOH on elevators. 33. RIH with whipstock retrieval tool. Retrieve whipstock and POOH. 34. PU and run 4-1/2" slotted liner. 35. RIH, until liner hanger is just above window. Orient hanger to window and land hanger. 36. Release hanger running tool. POOH. 37. Make up junction isolation / re-entry assembly (Lateral Entry Module or LEM) and RIH to depth. Orient and set packer atop assembly and release from assembly. 38. POOH, laying down drill pipe as required. 39. PU completion as required and RIH to depth. Land tubing. Set BPV. 40. Nipple down BOPE, nipple up tree and test. Pull BPV. 41. Freeze protect well with diesel. ORIGINAL (not done) 7J-152 PERMIT 1T Page 7 of 8 Printed: 23-Jan-06 • /~ation for Permit to Drill, Well 1 J-152 Revision No.O Saved: 23-Jan-46 14. Discussion of Mud and Cuttings Disposal and Annular Disposal Requirements of 20 AAC 25.005 (c)(14) An application for a Permit to Dri/l must be accompanied by each of the fo/%wing items, except for an item a/ready on fi/e with the commission and identified in the app/ication: (14) a genera/ descriptron 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 we/%; Waste fluids generated during the drilling process will be disposed of either by pumping authorized fluids into a permitted annulus on iJ Pad, or by hauling the fluids to a KRU Class II disposal well. All cuttings generated will be disposed of either down a permitted annulus on 1J Pad, hauled to the Prudhoe Bay Grind and Inject Facility for temporary storage and eventual processing for injection down an approved disposal well, or stored, tested for hazardous substances, and (if free of hazardous substances) used on pads and roads in the Kuparuk area in accordance with a permit from the State of Alaska. ConocoPhillips Alaska may in the future request authorization for the use of this well for annular disposal operations. 15. Attachments Attachment 1 Directional Plan Attachment 2 Drilling Hazards Summary Attachment 3 Cement Loads and CemCADE Summary Attachment 4 Well Schematic ORIGINAL (not done) 7J-152 PERMIT !T Page 8 of 8 Printed: 23-Jan-06 ~ • ConocaPhi{lips Alaska ConocoPhillips Alaska (Kuparuk) Kuparuk River Unit Kuparuk 1J Pad Plan 1J-152 -Slot 1J-152 Plan: 1J-152 (wp05) Proposal Report 16 January, 2006 HAL.LIUI~Tt~71\i ORIGINAL v N j d N ~ Y ~ ~ ~ C Y Y r ~ 3 i ` ~ ~ N ~ ~ a QC d 3 ~ ~ 7 ta~'- .. ~ ~ U +~+ ry ~ l0 O N ~ d a d rn oa O m'edRm~mm J @FO NU(OQ f/1N NNNlA f C N N+ C C C M N N YI N N a Q ~OJ IONMNUf ODb Yf NMANO F ~NmtOMIAbMANNhA MO p, Oi O EO N O Y1 A ~0{pp 0 'pQp[l 01 O1 ~ N ~' ~~NNM~~d N1n~NtOfll fMO Q t O O O O O O O O O O O O O O 0 0 0 0 0 0 0 0 0 0 0 0 0 0 ~ a a~ o °o m ~, M o ypyp A O a'a A M O ~N"N000~MOO NNYi ID LL ~J. e~ tVV NMMMIIIIII~~+'~~~I+'+++ MMMMM IZ~NMONIDMaG OI~~ r ~~ c N M ~ r O ^ ~ J ~ ,y G0 f V Q moln~ r z.-aaAv ~ ~ M N N z N N O ~ 00 M 00 Q Nf0 T U j o ~ o ~ O P I M N lO') M Z r N M O 1~f~~ O U O f a N u °v a ~: O f 3: ~ N N J ; "0 N ~ ~ _ a_ ~ °o M N 1~0 ~ ~: ~ ~ : ~ ~Op, M A N ~:~ y N H ~ " ' ~'~ f i°a IC~ ~ m - m O ~ \ ~~ N N N ~ ~ I: F O C \\ ~ ~ a N ~ ~ t p < .. 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O ]' e H O a O ryC Q O d O 0 0 in ~ °m O O ~ ~ v> ~~ A ~ i\ C Ir J ~„ c. O O U O N P ~ N O wz O L Q c ~ ~4. ~ O a ~~ o N J ~ ~; ~ ~ J n Q p Gl (O W r c 1^ \ ~ ~ ~ V O J (7wm p W In \p 3 `o O1m L N Z [e O C ~ O L `~ 0 N ~ ~ zl ~ o. ~ d 3 ~ ~ ~ c N o ~ ~ 1 m ~i M i3 ~ m n r / ~ ~ c 0 f N 1 / ~ W m m / .. ~ ~ ~ ~ ~ ~ M ~ i / i ~~ N A M ~ g 1° 1 1 ~ ~ ~ r ~~ ~ .. N ~ I / C \O M ~ ~ i ~ in ~ ~ O ~ m i I r~ m / I I ~ q I // ~'' ~ ~ ~ a ~ a ~ m M o ~ a o \ \ \; \ : , ~ f c > \ o F \\ \\ \ 1 \ \ ~ II' 11 I',. A U O V 0 O c C O O O ~ M O O o ~ 0 0 ch ~ C O U ~ ~ N ~ U o ~ °o ~ N O O \ ~ ._ .. .. - o ~ \ \ \ \ :\ \ 1 ` • ~ \ \ \ \ 1 \ 1 - \ :\ 1 g d ob \ O N M o a - R' ~ ~... N \ \ \ 1 1 \ \ \ '\ 091(1 ~ Z O \ \ \ \ I \ \~~\` \ \ \ \ \ \ \ , \~ 1 V F' M 4 \ \ ~ l \ \; a \ '\ \ 1 1 ~ - ' : '~~ ~ p~ V ~ ~ \ \, \ \ \ ~ \ ~ I Y \ \ \ ~ ~ ~ O V ~~ O t+ i e \ : \ ~ fA I \ \ ~ , o o c ~ , ~ v~ O ~ ~ U o 0 ~ o v \ I y _A ~I I ~ m N a2{ \ I 1' I _.,"" ~ +„ ~ Ip Y '~ a Y LL O\ +A .~ ~ ~ \ i \ I !. ~ ~~ ~ yd ~. O 4~ ~w ~ ai ~~ ~ , \ ~' o O O O O O O O O O O O O O O O O O O O O O O O O O O G O O 0 N O 1 O O N ~ ~ O {C1 ~ O ~ O {fi ~ .- ~ N N O ~ O t") t`J V ~ O V lI~ ~ to (Continue Build/Turn @ 5°/100ft , 3232(1 MD, 2440(( ND ; I10 3i4" - 2825ft MD, 2204fl ND Con~i~ ue Turn @ 5°/100ft , 2492ft MD, 2012ft ND - - - _ _ Sail @ 56° Inc. 2442ft MD, 1984ft ND __ o 1500 - - '-- ~ ~, ° ~~~/ ~_ Begin Pump Tangent -Sail @64.75°Inc & 194°Azi : 4615ft MD, 3218ft ND I ~ `~ moo ~ ~ ~ - ' ~ ~ _ j v ,~~ _ - ' ~ ~ (Continue Turn @ 5°/100ft , 1996f[ MD, 1731 fl ND o° _ . _ ._______ 1000 (End Pump Tangent - Build @ 4°/100ft , 4804ft MD, 3299ft TVD -' 27p° 3 , - -' ~ Sail @ 56° Inc : 1946f[ fs~ID, 1703ft ND __ i - _ ....- -__.-.--- --_,-. 7 - - -.., - - - - (Continue Bwld/Turn @ 5°/100(1 , _1 i '9ft MD, 1568ft TVD I _ _ -_ _ _ 500 (Sail @ 76°Inc:5172ft MD,3422ft ND I~ ' _____ - --- - -- - Base Perm Tangent -Sail @ 47.14° Inc :16290 MD, 1500ft TVD 184° - 0 Continue Build @ 4°/100ft , 5407ft MD, 3479ft ND ~ - - - - - - -- - _ _ - - /"~ _ _ - - ~ - Continue Build @ 4°/1008 , 702fl MD, 700ft ND Continue Nudge for Turn @ 0.15/100(1 , 5518ft MD, 3502ft ND ~ ~ ~ , -500 ~ ' ~ _ (Continue Build @ 4°/100ft , 6193ft MD, 3620ft ND I ~ , ~ KOP @ 300ft MD, 300ft Tb'D -Build @ 2.5°/100ft -- Jl ~~. -loco - _____------- ~Sail @ 85° Inc : 6319ft MD, 3636ft ND ~ , _ - -~ .. - 8"St>aft nqD c. 7rt T_-G ~ -: _.- ,, _1500 ~' 180` -~~------ SHL@2191flFSL82582ftFEL-Sec 35-T11N-R10E Begin GeoSteer in Upper Lobe of A2-Sand, 6490fl MD, 3643ft ND 180° Drillers Target - defines a corridor 80° .with allowable deviation from plan !of +/- 50ft while in production zone, _ .- ,_ _ ._ I7J-152 T2 (wp0>~ 179' -4000 ~ w o 0 0 -4500 ..., L r ~ ' ~_~ Z 1J-152 (wp05) ~41/2~ -5000 r 0 rn -5500 -6000 ~' `'~~ ~.. ,::\ -6500 -`~ T 1J-152 L2 (wp05) @ 12940'MD -7000 fi1 gnetic North: 24.16° Magnetic Field -7500 Strength: 57563.4nT Dip Angle: 80.77° Dale: 3!1/2006 /// Model: BGGM2005 // -8000 1J-152 L1 (wp05) @ 13245'MD ///// ~CbnocaPhill~~s ,ai-lslca I--s.~LLiE3LtRT~T1 Sperry Drilling Services Project: Kuparuk River Unit Site: Kuparuk 1J Pad Well: Plan 1J-152 Wel lbore: 1 J-152 Plan: 1J-152 I;wp05) CASING DETAILS No TVD MD Name Size 1 2204.00 2825.33 10 3!4" 10-3/4 2 3639.13 6353.54 7 5/8" 7-5/8 3 3632.00 9888.24 4112" 4-1 /2 WELL DETAILS: Plan 1J-152 Ground Level: 81.00 +N/-S +E/-W Northing Easting Latittude Longitude Slot 0.00 0.00 5946002.32 558625.36 70°15'47.084N 149"31'33.778W 1J-152 -4500 -4000 -3500 -3000 -2500 -2000 -1500 -1000 -500 0 500 1000 1500 2000 2500 • • ~-f Halliburton Energy Services ~gLLtBUgTQN ~'~~~~~~~ Planning Report -Geographic _- Atasica Database: EDM 2003.11 Single User Db Company: ConocoPhillips Alaska (Kuparuk) Project: Kuparuk River Unit Site: Kuparuk 1J Pad Well: Plan 1J-152 Wellbore: 1 J-152 Design: 1J-152 (wp05) SI'neny br111ing 5erv#o.ss Local Co-ordinate Reference: Well Plan 1J-152 -Slot 1J-152 TVD Reference: Planned RKB @ 109.OOft (Doyon 141 (28+8'1)) MD Reference: Planned RKB @ 109.OOft (Doyon 141 (28+8'1)1 North Reference: True Survey Calculation Method: Minimum Curvature - Project Kuparuk River Unit, North Slope Alaska, United States Map System: US State Plane 1927 (Exact solution) System Datum: Mean Sea Level Geo Datum: NAD 1927 (NADCON CONUS) Using Well Reference Point Map Zone: Alaska Zone 04 Using geodetic scale factor Well Plan 1J-152 -Slot 1J-152.. _. _ _ Well Position +N/-S 0.00 ft Northing: 5,946,402.32 ft - Latitude: 70° 15' 47.084" N +E/-W 0.00 ft Easting: 558,625.36 ft Longitude: 149° 31' 33.778" W Position Uncertainty O.OOft Wellhead Elevation: ft Ground Level: 81.OOft Wellbore 1J-152 I Magnetics Model Name Sample Date Declination Dip Angle Field Strength BGGM2005 3/1/2006 24.16 80.77 57,563 Design 1J-152 (wp05) Audit Notes: Version: Phase: PLAN Tie On Depth: 28.00 ii Vertical Section: Depth From (TVD) +N/-S +E/-W Direction (ft) (ft) (ft) (°) 28.00 0.00 0.00 180.00 1/16/2006 1:19:26PM Page 2 of 9 COMPASS 2003.11 Build 48 y .~~ ~-~` Halliburton Energy Services t-iA~uBU~aTON ~~~~~~~~ Planning Report -Geographic -- ~- --~ ~.m ~tiaa~a Spt~rry C>triiling Seuvvi~~s Database: EDM 2003.11 Single User Db Local Co-ordinate Reference: Well Plan 1J-152 -Slot 1J-152 Company: ConocoPhillips Alaska (Kuparuk) TVD Reference: Planned RKB @ 109.OOft (Doyon 141 (28+81)~ Project: Kuparuk River Unit MD Reference: Planned RKB @ 109.OOft (Doyon 141 (28+81)) Site: Kuparuk 1J Pad North Reference: True Well: Plan 1J-152 Survey Calculation Method: Minimum Curvature Wellbore: 1 J-152 Design: 1J-152 (wp05) P{an Summary Measured Vertical Dogleg Build Turn Depth Inclination Azimuth Depth +NI-S +Et-W Rate Rate Rate TFO (ft) (°) (°) (ft) (ft) (ft) (°I100ft) (°/100ft) (°/100ft) (°) 28.00 0.00 0.00 28.00 0.00 0.00 0.00 0.00 0.00 0.00 300.00 0.00 0.00 300.00 0.00 0.00 0.00 0.00 0.00 0.00 702.06 10.05 355.00 700.00 35.04 -3.07 2.50 2.50 0.00 355.00 1,629.31 47.14 355.00 1,500.00 469.50 -41.08 4.00 4.00 0.00 0.00 1,729.31 47.14 355.00 1,568.02 542.52 -47.46 0.00 0.00 0.00 0.00 1,946.10 56.00 347.00 1,702.76 709.73 -74.69 5.00 4.09 -3.69 322.15 1,996.10 56.00 347.00 1,730.72 750.12 -84.01 0.00 0.00 0.00 0.00 2,442.47 56.00 320.00 1,983.53 1,07628 -246.63 5.00 0.00 -6.05 262.35 2,492.47 56.00 320.00 2,011.49 1,108.04 -273.27 0.00 0.00 0:00 0.00 3,232.36 56.00 275.00 2,440.23 1,379.20 -794.17 5.00 0.00 -6.08 256.96 4,614.56 64.75 194.06 3,218.12 743.79 -1,619.36 5.00 0.63 -5.86 -107.05 4,804.34 64.75 194.06 3,299.06 577.28 -1,661.06 0.00 0.00 0.00 0.00 5,171.61 76.00 184.00 3,422.48 236.54 -1,714.13 4.00 3.06 -2.74 -41.94 5,231.61 76.00 184.00 3,437.00 178.47 -1,718.19 0.00 0.00 0.00 0.00 5,406.61 76.00 184.00 3,479.34 9.08 -1,730.04 0.00 0.00 0.00 0.00 5,517.93 80.00 182.00 3,502.48 -99.62 -1,735.72 4.00 3.59 -1.80 333.72 6,192.93 80.00 181.00 3,619.69 -764.13 -1,753.12 0.15 0.00 -0.15 269.91 6,318.54 85.00 180.50 3,636.08 -888.62 -1,754.75 4.00 3.98 -0.40 354.30 6,353.54 85.00 180.50 3,639.13 -923.49 -1,755.05 0.00 0.00 0.00 0.00 6,489.74 91.81 180.50 3,642.92 -1,059.55 -1,756.24 5.00 5.00 0.00 0.00 6,589.74 91.81 180.50 3,639.76 -1,159.49 -1,757.11 0.00 0.00 0.00 0.00 6,738.87 86.60 180.23 3,641.84 -1,308.56 -1,758.06 3.50 -3.50 -0.18 -177.01 7,017.81 86.60 180.23 3,658.39 -1,587.00 -1,759.16 0.00 0.00 0.00 0.00 7,153.14 91.31 179.75 3,660.86 -1,722.27 -1,759.14 3.50 3.48 -0.35 -5.79 8,153.14 91.31 179.75 3,638.00 -2,722.00 -1,754.77 0.00 0.00 0.00 0.00 8,292.60 86.43 179.57 3,640.75 -2,861.39 -1,753.95 3.50 -3.50 -0.13 -177.92 8,458.42 86.43 179.57 3,651.07 -3,026.88 -1,752.72 0.00 0.00 0.00 0.00 8,588.25 90.97 179.33 3,654.01 -3,156.64 -1,751.47 3.50 3.50 -0.19 -3.07 9,888.25 ~ 90.97 179.33 3,632.00 ~-4,456.37 -1,736.27 0.00 0.00 0.00 0.00 1/1612006 1:99:26PM Page 3 of 9 COMPASS 2003.91 Build 48 ,~~~ ~~ • • r-' Halliburton Energy Services iHALL~BUI'~'1"t~N ~'~'~~~~~~-' Planning Report -Geographic ~~ ~°. °µ; ~ °~ -~° ~a Database: EDM 2003.11 Single User Db Company: ConocoPhillips Alaska (Kuparuk) Project: Kuparuk River Unit Site: Kuparuk 1J Pad Well: Plan 1J-152 Wellbore: 1 J-152 Design: 1J-152 (wp05) Sperry d 111t~g Services Local Co-ordinate Reference: Well Plan 1J-152 -Slot 1J-152 TVD Reference: Planned RKB @ 109.OOft (Doyon 141 (28+81 j) MD Reference: Planned RKB @ 109.OOft (Doyon 141 (28+81j~ North Reference: True Survey Calculation Method: Minimum Curvature Planned Survey 1J-152 (wp05) MD Inclination Azimuth TVD SSTVD +NiS (ft) (°) (°) (ft) (ft) (ft) 28.00 0.00 0.00 28.00 -81.00 0.00 SHL @ 2181ft FSL 8 2582ft FEL - Sec 35 - T11 N - R1 OE ' 100.00 0.00 0.00 100.00 -9.00 0.00 200.00 0.00 0.00 200.00 91.00 0.00 300.00 0.00 0.00 300.00 191.00 0.00 KOP @ 300ft MD, 300ft TVD -Bui ld @ 2.5°MOOft ' 400.00 2.50 355.00 399.97 290.97 2.17 500.00 5.00 355.00 499.75 390.75 8.69 600.00 7.50 355.00 599.14 490.14 19.53 700.00 10.00 355:00 697.97 588.97 34.69 702.06 10.05 355.00 700.00 591.00 35.04 Continue Build @ 4°t100ft , 702ft MD, 700ft TVD 800.00 13.97 355.00 795.78 686.78 55.34 900.00 17.97 355.00 891.90 782.90 82.74 1,000.00 21.97 355.00 985.87 876.87 116.76 1,100.00 25.97 355.00 1,077.23 968.23 157.22 1,200.00 29.97 355.00 1,165.53 1,056.53 203.93 1,300.00 33.97 355.00 1,250.34 1,141.34 256.66 1,400.00 37.97 355.00 1,331.26 1,222.26 315.16 1,500.00 41.97 355.00 1,407.89 1,298.89 379.14 1,600.00 45.97 355.00 1,479.84 1,370.84 448.29 1,629.31 47.14 355.00 1,500.00 1,391.00 469.50 Base Perm Tangent - Sail @ 47.14° Inc : 1629ft MD, 1500ft TVD 1,689.59 47.14 355.00 1,541.00 1,432.00 513.51 Base of Perm 1,700.00 47.14 355.00 1,548.08 1,439.08 521.11 1,729.31 47.14 355.00 1,568.02 1,459.02 542.52 Continue Build/Turn @ 5°/100ft , 1729ft MD, 1568ft TVD 1,800.00 49.97 352.17 1,614.81 1,505.81 595.16 1,870.86 52.87 349.56 1,659.00 1,550.00 649.83 T3 1,900.00 54.07 348.54 1,676.34 1,567.34 672.81 1,946.10 56.00 347.00 1,702.76 1,593.76 709.73 Sail @ 56° Inc : 1946ft MD, 1703ft TVD 1,996.10 56.00 347.00 1,730.72 1,621.72 750.12 Continue Turn @ 5°t1 00ft , 1996ft MD, 1731ft TVD 2,000.00 55.97 346.77 1,732.90 1,623.90 753.27 2,100.00 55.47 340.75 1,789.26 1,680.26 832.54 2,200.00 55.26 334.67 1,846.13 1,737.13 908.62 2,300.00 55.35 328.59 1,903.09 1,794.09 980.90 2,368.62 55.59 324.44 1,942.00 1,833.00 1,028.03 K15 2.400.00 55.74 322.55 1,959.70 1,850.70 1.048.86 Map Map +E/-W Northing Easting DLSEV Vert Section (ft) (ft) (ft) (°/100ft) {ft) 0.00 5,946,002.32 558,625.36 0.00 0.00 0.00 5,946,002.32 558,625.36 0.00 0.00 0.00 5,946,002.32 558,625.36 0.00 0.00 0.00 5,946,002.32 558,625.36 0.00 0.00 -0.19 5,946,004.49 558,625.15 2.50 -2.17 -0.76 5,946,011.00 558,624.53 2.50 -8.69 -1.71 5,946,021.84 558,623.50 2.50 -19.53 -3.03 5,946,036.98 558,622.06 2.50 -34.69 -3.07 5,946,037.33 558,622.02 2.50 -35.04 -4.84 5,946,057.62 558,620.09 4.00 -55.34 -7.24 5,946,085.00 558,617.48 4.00 -82.74 -10.21 5,946,118.98 558,614.24 4.00 -116.76 -13.75 5,946,159.41 558,610.38 4.00 -157.22 -17.84 5,946,206.09 558,605.93 4.00 -203.93 -22.46 5,946,258.78 558,600.91 4.00 -256.66 -27.57 5,946,317.23 558,595.34 4.00 -315.16 -33.17 5,946,381.16 558,589.24 4.00 -379.14 -39.22 5,946,450.25 558,582.65 4.00 -448.29 -41.08 5,946,471.44 558,580.63 4.00 -469.50 -44.93 5,946,515.42 558,576.44 0.00 -513.51 -45.59 5,946,523.01 558,575.72 0.00 -521.11 -47.46 5,946,544.40 558,573.68 0.00 -542.52 -53.41 5,946,596.98 558,567.32 5.00 -595.16 -62.23 5,946,651.58 558,558.08 5.00 -649.83 -66.68 5,946,674.53 558,553.45 5.00 -672.81 -74.69 5,946,711.38 558,545.16 5.00 -709.73 -84.01 5,946,751.70 558,535.52 0.00 -750.12 -84.74 5,946,754.83 558,534.76 4.99 -753.27 -107.83 5,946,833.92 558,511.07 5.00 -832.54 -139.00 5,946,909.74 558,479.30 5.00 -908.62 -178.04 5,946,981.71 558,439.71 5.00 -980.90 -209.22 5,947,028.59 558,408.16 5.00 -1,028.03 -224.63 5,947,049.30 558,392.59 5.00 -1,048.86 1/16/2006 1:19:26PM Page 4 of 9 ~~~~ COMPASS 2003.11 Build 48 ir-' HalliburEon Energy Services HA~uBUraTOn ~~'~'~~~~ Planning Report -Geographic - _ _. Ft4~ska ~#~tTY D~ifling ~~rvices Database: EDM 2003.11 Single User Db Local Co-ordinate Reference: Well Plan 1J-152 -Slot 1J-152 Company: ConocoPhiilips Alaska (Kuparu k) TVD Reference: Planned RKB @ 109.OOft {Doyon 141 (28+81)j Project: Kuparuk River Unit MD Reference: Planned RKB @ 109.OOft (Doyon 141 (28+81)j Site: Kuparuk 1J Pad North Reference: True Wetl: Plan 1J-152 Survey Calculation Method: Minimum Curvature Wellbore: 1 J-152 Design: 1J-152 (wp05) Planned Survey 1J-152 (wp05) Map Map MD Inclination Azimuth TVD SSTVD +N/-S +E/-W Northing Easting (ft) (°) (°) (ft) (ft) (ft) (ft) (ft) (ft) 2,442.47 56.00 320.00 1,983.53 1,874.53 1,076.28 -246.63 5,947,076.55 558,370.39 Sail @ 56° Inc : 2442ft MD,1984ft TVD 2,492.47 56.00 320.00 2,011.49 1,902.49 1,108.04 -273.27 5,947,108.09 558,343.50 Continue Turn @ 5°/100ft , 2492ft MD, 2012ft TVD 2,500.00 55.92 319.56 2,015.71 1,906.71 1,112.80 -277.30 5,947,112.82 558,339.43 2,600.00 54.95 313.60 2,072.48 1,963.48 1,172.58 -333.84 5,947,172.15 558,282.43 2,700.00 54.29 307.52 2,130.41 2,021.41 1,225.57 -395.73 5,947,224.65 558,220.14 2,800.00 53.93 301.36 2,189.08 2,080.08 1,271.36 -462.48 5,947,269.91 558,153.04 2,825.33 53.89 299.80 2,204.00 2,095.00 1,281.77 -480.10 5,947,280.19 558,135.34 10 3/4" @ 1807ft FNL & 2219ft FWL -Sec 35 - T11 N - R10E, 2825ft MD, 2204ft TVD - T3 + 550 -10 3!4" 2,900.00 53.89 295.17 2,248.02 2,139.02 1,309.60 -533.59 5,947,307.60 558,081.64 3,000.00 54.17 289.00 2,306.79 2,197.79 1,340.00 -608.52 5,947,337.41 558,006.48 3,100.00 54.76 282.90 2,364.95 2,255.95 1,362.33 -686.71 5,947,359.13 557,928.14 3,200.00 55.65 276.91 2,422.05 2,313.05 1,376.42 -767.54 5,947,372.59 557,847.20 3,232.36 56.00 275.00 2,440.23 2,331.23 1,379.20 -794.17 5,947,375.16 557,820.55 Continue Build/Turn @ 5°/100ft , 3232ft MD, 2440ft TVD 3,300.00 55.07 271.06 2,478.52 2,369.52 1,382.15 -849.84 5,947,377.68 557,764.87 3,400.00 53.94 265.07 2,536.62 2,427.62 1,379.43 -931.15 5,947,374.33 557,683.59 3,500.00 53.11 258.94 2,596.10 2,487.10 1,368.28 -1,010.71 5,947,362.56 557,604.12 3,600.00 52.60 252.70 2,656.52 2,547.52 1,348.79 -1,087.94 5,947,342.46 557,527.06 3,700.00 . 52.43 246.40 2,717.41 2,608.41 1,321.09 -1,16222 5,947,314.19 557,453.00 3,800.00 52.59 240.10 2,778.31 2,669.31 1,285.40 -1,233.01 5,947,277.96 557,382.50 3,900.00 53.08 233.86 2,838.76 2,729.76 1,242.00 -1,299.76 5,947,234.04 557,316.09 3,950.55 53.45 230.74 2,869.00 2,760.00 1,217.22 -1,331.81 5,947,209.02 557,284.24 Ugnu C 4,000.00 53.89 227.72 2,898.30 2,789.30 1,191.21 -1,361.97 4,100.00 55.01 221.73 2,956.46 2,847.46 1,133.42 -1,419.16 4,200.00 56.42 215.92 3,012.83 2,903.83 1,069.07 -1,470.89 4,275.65 57.66 211.66 3,054.00 2,945.00 1,016.32 -1,506.16 Ugnu B 4,300.00 58.09 210.31 3,066.95 2,957.95 998.65 -1,516.77 4,400.00 59.99 204.92 3,118.42 3,009.42 922.69 -1,556.46 4,427.38 60.55 203.48 3,132.00 3,023.00 901.01 -1,566.21 Ugnu A 4,500.00 62.10 199.74 3,166.85 3,057.85 841.78 -1,589.65 4,600.00 64.41 194.77 3,211.87 3,102.87 756.53 -1,616.09 4,614.56 64.75 194.06 3,218.12 3,109.12 743.79 -1,619.36 Begin Pump Tangent -Sail @ 64.75°Inc & 194°Azi : 4615ft MD, 3218ft TVD 4,700.00 64.75 194.06 3,254.56 3,145.56 668.83 -1,638.13 4,800.00 64.75 194.06 3,297.21 3,188.21 581.09 -1,660.11 4,804.34 64.75 194.06 3,299.06 3,190.06 577.28 -1,661.06 End Pump Tangent -Continue Build @ 4°/100ft , 4804ft MD, 3299ft TVD 4,820.76 65.24 193.58 3,306.00 3,197.00 562.84 -1,664.61 K13 DLSEV Vert Section 5.00 -1,076.28 0.00 -1,108.04 4.99 -1,112.80 5.00 -1,172.58 5.00 -1,225.57 5.00 -1,271.36 5.00 -1,281.77 5.00 -1,309.60 5.00 -1,340.00 5.00 -1,362.33 5.00 -1,376.42 5.00 -1,379.20 5.00 -1,382.15 5.00 -1,379.43 5.00 -1,368.28 5.00 -1,348.79 5.00 -1,321.09 5.00 -1,285.40 5.00 -1,242.00 5.00 -1,21722 5,947,182.77 557,254.29 5.00 -1,191.21 5,947,124.55 557,197.56 5.00 -1,133.42 5,947,059.80 557,146.33 5.00 -1,069.07 5,947,006.79 557,111.48 5.00 -1,016.32 5,946,989.03 557,101.00 5,946,912.78 557,061.91 5,946,891.02 557,052.34 5,946,831.62 557,029.36 5,946,746.17 557,003.59 5, 946, 733.41 557, 000.41 5.00 -998.65 5.00 -922.69 5.00 -901.01 5.00 -841.78 5.00 -756.53 5.01 -743.79 5,946,658.31 556,982.23 0.00 -668.83 5,946,570.41 556,960.94 0.00 -581.09 5,946,566.59 556,960.01 0.00 -577.28 5,946,552.12 .556,956.57 4.00 -562.84 4,900.00 67.63 191.30 3,337.68 3,228.68 491.91 -1,680.24 5,946,481.09 556,941.50 4.00 -491.91 1/16/2006 1:19:26PM Page 5 of 9 COMPASS 2003.11 Build 48 OR16!NAL • ~Cc~rr~cc~i~l}p I~Jaska • Halliburton Energy Services HALLIBiJRTON Planning Report -Geographic --° _ ~°--- _~-~- n'Y ~r~llir-g 5erv~ces Database: EDM 2003.11 Single User Db Local Co-ordinate Reference: Well Plan 1J-152 -Slot 1J-152 Company: ConocoPhillips Alaska (Kuparu k) N D Reference: Planned RK B @ 109.OOft (Doyon 141 {2 8+81)) Project: Kuparuk River U nit MD Reference: Planned RK B @ 109.OOft (Doyon 141 (2 8+81)1 Site: Kuparuk 1J Pad North Reference: True Well: Plan 1J-152 Su rvey Calculat ion Method: Minimum Cu rvature Wellbore: 1 J-152 Design: 1J-152 (wp05) ~ Planned Survey 1J-152 (wp 05) ICI Map Map ~I MD Inclination Azimuth ND SSND +N/S +E/-W Northing Easting DLSEV Vert Section '~ (ft) (°) (~) (ft) (ft) (ft) (ft) (ft) {ft) (°/100ft) (ft) 5,000.00 70.68 188.53 3,373.27 3,264.27 399.87 -1,696.30 5,946,388.94 556,926.16 4.00 -399.87 5,100.00 73.77 185.86 3,403.81 3,294.81 305.42 -1,708.20 5,946,294.40 556,915.00 4.00 -305.42 5,171.61 76.00 184.00 3,422.48 3,313.48 236.54 -1,714.13 5,946,225.49 556,909.60 4.00 -236.54 Sail Q 76° Inc : 5172ft MD, 3422ft ND 5,200.00 76.00 184.00 3,429.35 3,320.35 209.07 -1,716.05 5,946,198.00 556,907.89 0.00 -209.07 5,231.61 76.00 184.00 3,437.00 3,328.00 178.47 -1,718.19 5,946,167.39 556,905.99 0.00 -178.47 1J-152 T1 D top (wp05) -1J-152 DD Poly (wp05) 5,260.55 76.00 184.00 3,444.00 3,335.00 150.46 -1,720.15 5,946,139.37 556,904.25 0.00 -150.46 West Sak D 5,300.00 76.00 184.00 3,453.54 3,344.54 112.27 -1,722.82 5,946,101.17 556,901.88 0.00 -112.27 5,400.00 76.00 184.00 3,477.74 3,368.74 15.48 -1,729.59 5,946,004.33 556,895.87 0.00 -15.48 5,405.22 76.00 184.00 3,479.00 3,370.00 10.43 -1,729.94 5,945,999.28 556,895.55 0.00 -10.43 West Sak C 5,406.61 76.00 184.00 3,479.34 3,370.34 9.08 -1,730.04 5,945,997.93 556,895.47 0.00 -9.08 Continue Bui ld @ 4°/100ft , 5407ft MD, 3479ft ND 5,500.00 79.35 182.32 3,499.27 3,390.27 -82.00 -1,735.06 5,945,906.82 556,891.16 4.00 82.00 5,517.93 80.00 182.00 3,502.48 3,393.48 -99.62 -1,735.72 5,945,889.19 556,890.63 4.00 99.62 Continue Nudge for Turn @ 0.15/1 00ft , 5518ft MD, 3502ft ND 5,549.73 80.00 181.95 3,508.00 3,399.00 -130.93 -1,736.80 5,945,857.89 556,889.80 0.15 130.93 West Sak B 5,600.00 80.00 181.88 3,516.73 3,407.73 -180.40 -1,738.46 5,945,808.40 556,888.53 0.15 180.40 5,700.00 80.00 181.73 3,534.09 3,425.09 -278.84 -1,741.56 5,945,709.96 556,886.19 .0.15 278.84 5,739.77 80.00 181.67 3,541.00 3,432.00 -317.98 -1,742.72 5,945,670.81 556,885.34 0.15 317.98 West Sak A4 5,800.00 80.00 181.58 3,551.46 3,442.46 -377.28 -1,744.40 5,945,611.51 556,884.11 0.15 377.28 5,900.00 80.00 181.43 3,568.83 3,459.83 -475.72 -1,747.00 5,945,513.06 556,882.29 0.15 475.72 5,941.32 80.00 181.37 3,576.00 3,467.00 -516.40 -1,747.99 5,945,472.38 556,881.61 0.15 516.40 West Sak A3 6,000.00 80.00 181.29 3,586.19 3,477.19 -574.18 -1,749.33 5,945,414.60 556,880.72 0.15 574.18 6,100.00 80.00 181.14 3,603.56 3,494.56 -672.63 -1,751.42 5,945,316.14 556,879.40 0.15 672.63 6,192.93 80.00 181.00 3,619.69 3,510.69 -764.13 -1,753.12 5,945,224.63 556,878.41 0.15 764.13 Continue Bui ld @ 4°/100ft , 6193ft MD, 3620ft ND 6,200.00 80.28 180.97 3,620.90 3,511.90 -771.10 -1,753.24 5,945,217.67 556,878.34 3.99 771.10 6,300.00 84.26 180.57 3,634.35 3,525.35 -870.16 -1,754.58 5,945,118.61 556,877.78 4.00 870.16 6,318.54 85.00 180.50 3,636.08 3,527.08 -888.62 -1,754.75 5,945,100.15 556,877.75 4.01 $88.62 Sail @ 85° Inc : 6319ft MD, 3636ft ND 6,352.00 85.00 180.50 3,639.00 3,530.00 -921.96 -1,755.04 5,945,066.82 556,877.72 0.00 921.96 West Sak AZ 6,353.54 85.00 180.50 3,639.13 3,530.13 -923.49 -1,755.05 5,945,065.29 556,877.72 0.00 923.49 7 5/8" @ 1268ft FSL & 942ft FWL - Sec 35 - T11N - R 10E :Build @ 5°/100ft - 6354ft M D, 3639ft TVD - 7 5/8" - 6,400.00 87.32 180.50 3,642.24 3,533.24 -969.84 -1,755.46 5,945,018.94 556,877.67 5.00 969.84 6,489.74 91.81 180.50 3,642.92 3,533.92 -1,059.55 -1,756.24 5,944,929.23 556,877.59 5.00 1,059.55 Begin GeoSteer in Upper Lobe of A2-Sand, 6490ft MD, 3643ft TVD 1/16/2006 1:19:26PM Page 6 of 9 COMPASS 2003.11 Build 48 ORIGINAL Halliburton Energy Serrrices w ~~C1~CC)i~11~S Pl i R hi rt G HALLIBtJ{~70N - - - w. ann ng eograp epo - c Alaska' ~ D~Ittng 5t~rv3ce~ Database: EDM 2003.11 Single User Db Local Co-ordinate Reference: Well Plan 1J-152 -Slot 1J-152 Company: ConocoPhillips Alaska (Kuparu k} TVD Reference: Planned RKB @ 109.OOft (Doyon 141 (28+81)) Project: Kuparuk River Unit MD Reference: Planned RKB @ 109.OOft (Doyon 141 (28+81 jl Site: Kuparuk 1J Pad North Reference: True Well: Plan 1J-152 Survey Calculation Method: Minimum Curvature Wellbore: 1 J-152 Design: 1J-152 (wp05) Planned Survey 1J-152 {wp05) Map Map MD Inclination Azimuth TVD SSTVD +N/-S +EI-W Northing Easting DLSEV Vert Section fftl (°) (°) eft) (ft) (ft) (ft) (ft) (ft) (°1100ftj (ft? 6,500.00 91.81 180.50 3,642.60 3,533.60 -1,069.80 -1,756.33 5,944,918.98 556,877.58 0.00 1,069.80 6,589.74 91.81 180.50 3,639.76 3,530.76 -1,159.49 -1,757.11 5,944,829.29 556,877.50 0.00 1,159.49 6,600.00 91.45 180.48 3,639.47 3,530.47 -1,169.75 -1,757.20 5,944,819.04 556,877.49 3.49 1,169.75 6,700.00 87.96 180.30 3,639.99 3,530.99 -1,2fi9.73 -1,757.88 5,944,719.06 556,877.59 3.50 1,269.73 6,738.87 86.60 180.23 3,641.84. 3,532.84 -1,308.56 -1,758.06 5,944,680.24 556,877.71 3.50 1,308.56 6,800.00 86.60 180.23 3,645.46 3,536.46 -1,369.58 -1,758.30 5,944,619.23 556,877.94 0.00 1,369.58 6,900.00 86.60 180.23 3,651.40 3,542.40 -1,469.40 -1,758.70 5,944,519.41 556,878.33 0.00 1,469.40 7,000.00 86.60 180.23 3,657.33 3,548.33 -1,569.22 -1,759.09 5,944,419.60 556,878.71 0.00 1,569.22 7,017.81 86.60 180.23 3,658.39 3,549.39 -1,587.00 -1,759.16 5,944,401.82 556,878.77 0.00 1,587.00 7,100.00 89.46 179.94 3,661.22 3,552.22 -1,669.13 -1,759.28 5,944,319.70 556,879.30 3.50 1,669.13 7,153.14 91.31 179.75 3,660.86 3,551.86 -1,722.27 -1,759.14 5,944,266.57 556,879.86 3.50 1,722.27 7,200.00 91.31 179.75 3,659.79 3,550.79 -1,769.12 -1,758.93 5,944,219.73 556,880.42 0.00 1,769.12 7,300.00 91.31 179.75 3,657.50 3,548.50 -1,869.09 -1,758.50 5,944,119.77 556,881.64 0.00 1,869.09 7,400.00 91.31 179.75 3,655.22 3,546.22 -1,969.06 -1,758.06 5,944,019.82 556,882.85 0.00 1,969.06 7,500.00 91.31 179.75 3,652.93 3,543.93 -2,069.04 -1,757.62 5,943,919.86 556,884.07 0.00 2,069.04 7,600.00 91.31 179.75 3,650.65 3,541.65 -2,169.01 -1,757.19 5,943,819.90 556,885.28 0.00 2,169.01 7,700.00 91.31 179.75 3,648.36 3,539.36 -2,268.98 -1,756.75 5,943,719.95 556,886.50 0.00 2,268.98 7,800.00 91.31 179.75 3,646.07 3,537.07 -2,368.96 -1,756.31 5,943,619.99 556,887.71 0.00 2,368.96 7,900.00 91.31 179.75 3,643.79 3,534.79 -2,468.93 -1,755.88 5,943,520.03 556,888.93 0.00 2,468.93 8,000.00 91.31 179.75 3,641.50 3,532.50 -2,568.90 -1,755.44 5,943,420.08 556,890.14 0.00 2,568.90 8,100.00 91.31 179.75 3,639.21 3,530.21 -2,668.87 -1,755.01 5,943,320.12 556,891.35 0.00 2,668.87 8,153.14 91.31 179.75 3,638.00 3,529.00 -2,722.00 -1,754.77 5,943,267.00 55fi,892.00 0.00 2,722.00 1J-152 T2 (wp05) 8,200.00 89.67 179.69 3,637.60 3,528.60 -2,768.86 -1,754.54 5,943,220.15 556,892.59 3.50 2,768.86 8,292.60 86.43 179.57 3,640.75 3,531.75 -2,861.39 -1,753.95 5,943,127.64 556,893.91 3.50 2,861.39 8,300.00 86.43 179.57 3,641.21 3,532.21 -2,868.77 -1,753.89 5,943,120.25 556,894.02 0.00 2,868.77 8,400.00 86.43 179.57 3,647.43 3,538.43 -2,968.58 -1,753.15 5,943,020.47 556,895.54 0.00 2,968.58 8,458.42 86.43 179.57 3,651.07 3,542.07 -3,026.88 -1,752.72 5,942,962.18 556,896.43 0.00 3,026.88 8,500.00 87.88 179.49 3,653.13 3,544.13 -3,068.41 -1,752.38 5,942,920.66 556,897.09 3.50 3,068.41 8,588.25 90.97 179.33 3,654.01 3,545.01 -3,156.64 -1,751.47 5,942,832.44 556,898.68 3.50 3,156.64 8,600.00 90.97 179.33 3,653.81 3,544.81 -3,168.39 -1,751.34 5,942,820.70 556,898.91 0.00 3,168.39 8,700.00 90.97 179.33 3,652.12 3,543.12 -3,268.37 -1,750.17 5,942,720.74 556,900.86 0.00 3,268.37 8,800.00 90.97 179.33 3,650.42 3,541.42 -3,368.34 -1,749.00 5,942,620.79 556,902.81 0.00 3,368.34 8,900.00 90.97 179.33 3,648.73 3,539.73 -3,468.32 -1,747.83 5,942,520.83 556,904.75 0.00 3,468.32 9,000.00 90.97 179.33 3,647.04 3,538.04 -3,568.30 -1,746.66 5,942,420.87 556,906.70 0.00 3,568.30 9,100.00 90.97 179.33 3,645.34 3,536.34 -3,668.28 -1,745.49 5,942,320.91 556,908.65 0.00 3,668.28 9,200.00 90.97 179.33 3,643.65 3,534.65 -3,768.26 -1,744.32 5,942,220.96 556,910.60 0.00 3,768.26 9,300.00 90.97 179.33 3,641.96 3,532.96 -3,868.24 -1,743.15 5,942,121.00 556,912.54 0.00 3,868.24 9,400.00 90.97 179.33 3,640.27 3,531.27 -3,968.22 -1,741.98 5,942,021.04 556,914.49 0.00 3,968.22 9,500.00 90.97 179.33 3,638.57 3,529.57 -4,068.20 -1,740.81 5,941,921.09 556,916.44 0.00 4,068.20 9,600.00 90.97 179.33 3,636.88 3,527.88 -4,168.17 -1,739.64 5,941,821.13 556,918.39 0.00 4,168.17 9,700.00 90.97 179.33 3,635.19 3,526.19 -4,268.15 -1,738.47 5,941,721.17 556,920.33 0.00 4,268.15 9,800.00 90.97 179.33 3,633.49 3,524.49 -4,368.13 -1,737.31 5,941,621.21 556,922.28 0.00 4,368.13 9,888.25 90.97 179.33 3,632.00 3,523.00 -4,456.37 -1,736.27 5,941,533.00 556,924.00 0.00 4,456.37 BHL @ 9888ft MD, 3632ft TVD : 2265ft FNL & 957ft FWL -Sec 2 - T10N - R10E - 4112" - 7J-152 T3 (wp05) - 1/16/2006 1:19:26PM Page 7 of 9 COMPASS 2003.11 Build 48 ORIGINAL • • ti•-` Halliburton Energy Services HA~uBUgTON ~C~C1C3Ct)P~"~I~IpS Planning Report -Geographic -- ~- _ _.~ ._ .._._, ftl3ska terry D~i111ng 5eevices Database: EDM 2003.11 Single User Db Local Co-ordinate Reference: Well Plan 1J-152 -Slot 1J-152 Company: ConocoPhillips Alaska (Kuparuk) TVD Reference: Planned RKB @ 109.OOft (Doyon 141 (28+81)) Project: Kuparuk River Unit MD Reference: Planned RKB @ 109.OOft (Doyon 141 (28+81)) Site: Kuparuk 1J Pad North Reference: True Well: Plan 1J-152 Survey Calculation Method: Minimum Curvature Wellbore: 1 J-152 Design: 1J-152 (wp05) __ Geologic Targets 1J-152 TVD (ft) 3,632.00 - Point 3,437.00 - Polygon Point 1 Point 2 Point 3 Point 4 Point 5 Point 6 Point 7 Point 8 Point 9 Point 10 3,437.00 - Point 3,638.00 - Point Target Name +N!-S +E/-W -Shape ft ft 1J-152 T3 {wp05) -4,456.37 -1,736.27 1J-152 DD Poly {wp05) 178.47 -1,718.19 Northing Easting {ft) (ft) 5,941,533.00 556,924.00 5,946,167.39 556,905.99 -50.00 0.00 5,946,167.00 556,856.00 -67.53 -277.71 5,945,889.19 556,840.63 -84.93 -942.22 5,945,224.63 556,828.41 -86.58 -2,900.08 5,943,267.00 556,842.00 -68.08 -4,634.45 5,941,533.00 556,874.00 31.92 -4,635.22 5,941,533.00 556,974.00 13.42 -2,900.86 5,943,267.00 556,942.00 15.08 -943.00 5,945,224.63 556,928.41 32.47 -278.49 5,945,889.19 556,940.63 50.00 0.00 5,946,167.78 556,955.99 1J-152 T1 D top (wp05) 178.47 -1,718.19 5,946,167.39 1J-152 T2 (wp05) -2,722.00 -1,754.77 5,943,267.00 556,905.99 556,892.00 Prognosed Casing Points Measured Depth (ft) 2,825.33 6,353.54 9.888.24 Vertical Casing Hole Depth Diameter diameter 2, 204.00 10-3!4 13-1 /2 3,639.13 7-5/8 9-7/8 3,632.00 41/2 6.314 1/16/2006 1:19:26PM Page 8 of 9 COMPASS 2003.11 Build 48 • • ~-' Halliburton Energy Services Ct~CtACOPh~I~pS Planning Report -Geographic 131H~k~ Database: EDM 2003.11 S ingle User Db Local Co-ordinate Reference: Company: ConocoPhillips Alaska (Kuparuk) TVD Reference: Project: Kuparuk River U nit MD Reference: Site: Kuparuk 1J Pad North Reference: Well: Plan 1J-152 Survey Calculation Method: Wellbore: 1 J-152 Design: 1J-152 (wp05) Prognosed Formation Intersection Points Measured Vertical ', Depth Inclination Azimuth Depth +N/-E +E/-W tft) (°) (°) eft) (ft) lft1 1,689.59 47.14 355.00 1,541.00 513.51 -44.93 1,870.86 52.87 349.56 1,659.00 649.83 -6223 2,368.62 55.59 324.44 1,942.00 1,028.03 -209.22 2,825.33 53.89 299.80 2,204.00 1,281.77 -480.10 3,950.55 53.45 230.74 2,869.00 1,217.22 -1,331.81 4,275.65 57.66 211.66 3,054.00 1,016.32 -1,506.16 4,427.38 60.55 203.48 3,132.00 901.01 -1,566.21 4,820.76 65.24 193.58 3,306.00 562.84 -1,664.61 5,260.55 76.00 184.00 3,444.00 150.46 -1,720.15 5,405.22 76.00 184.00 3,479.00 10.43 -1,729.94 5,549.73 80.00 181.95 3,508.00 -130.93 -1,736.80 5,739.77 80.00 181.67 3,541.00 -317.98 -1,742.72 5,941.32 80.00 181.37 3,576.00 -516.40 -1,747.99 6,352.00 85.00 180.50 3,639.00 -921.96 -1,755.04 HALLIBtJRT'ON ~uperry Drilling 5ervice~ ~~ Well Plan 1J-152 -Slot 1J-152 Planned RKB @. 109.OOft (Doyon 141 (28+81 p) Planned RKB @ 109.OOft (Doyon 141 (28+81)) True Minimum Curvature Name Base of Perm T3 K15 T3 + 550 Ugnu C Ugnu B Ugnu A K13 West Sak D West Sak C West Sak B West Sak A4 West Sak A3 West Sak A2 1/16/2006 1:19:26PM Page 9 of 9 COMPASS 2003.118ui1d 48 ~ • ConocoPhllips Alaska ConocoPhillips Alaska (Kuparuk) Kuparuk River Unit Kuparuk 1J Pad Plan 1 J-152 1 J -152 Anticollision Summary 16 January, 2006 H A ~ L.f 1 ~ U i~'T'"`C11 ~~ ~.~~ , , SCkb'E}' PNOGFU}I NAD 27 ASP Zone 4 : WELL DETAILS: Plan 1J-152 ANTILOLLISION SETTINGS llate: 200601-18700:00:00 1'alldstrd: }'es VerNon: Ground Level: 81.00 interpolation Method: MD Interval: SOStations +N/•S +E/-W Northing Easting Latittude Longitude Urpth From Uepth Tu Sur.ey/Plan Trwl Depth Range From: 28.00 To 9888.25 0.00 0.00 5946002.32 558625.36 70°75'47.OB4N 149°31'33.778W 28.00 800.00 IJ-152 (ep05) ('8-G}'RO-$S Maximum Range:10000 800.00 9887.69 IJ-152 (ep05) >INT>+]Fl2-,gK•C.gZ-SC Reference: Plan: iJ-152 (wp05) x70 Plan 330 300 //l/~ Plan 1J-102 so Plan 1J-103 T ' Plan 1J-105 -Plan 1J-107 Plan 1J-109 From Colour To MD ~ 28 250 - 250 500 500 750 750 1000 1000 1250 1250 1500 ~ 1500 i Plan 1J-156 ~ 1aD ~ 1J-101,1 ~~ 1750 1J-154 1750 2000 !Plan 1J-159 2000 -' 2500 1J-10 1J-164 2500 -'°-_"-°' - Plan 1 _ J-162 3000 3000 Travelling Cylinder Azimuth (TFO+AZI) [°] vs Ceutre to Ceutre Separation X150 ftJin~ aooo 4000 5000 5000 6000 6000 7000 7000 8000 8000 9000 sooo loooo 10000 11000 11000 2000 REFERENCE INFORMATION 1 12000 13000 Coordinate (NIE) Reference: Well Plan 1J-152 -Slot 1J-152, True North Vertical (TVD) Reference: Planned RKB @ 109.OOft (Doyon 141 (28+81)) 13000 14000 Section (VS) Reference: Slot - iJ-152(O.OON, O.OOE) Measured Depth Reference: Planned RKB @ 109.OOft (Doyon 141 (28+81)) Calculation Method: Minimum Curvature 240\ ConocoPhillips Alaska (Kuparuk) Drilling 8 Wells Slot West Sak 1J-152 Calculation Method: Minimum Curvature Ertor System: ISCWSA Scan Method: Trov. Cylinder North Error Surface: Elliptical Conic Warning Methotl: Rules Based 3 30 2 2 60 1 90 1 1 120 1 J-154 210 150 180 Tra}•elling C~•linder Azimuth (TFO-rAZI) [°[ vs Centre to Centre Separafion [15 ft/in] SECTION DETAILS Sec MD Inc Azi TVD +NIS +EI-W DLeg TFace VSec Target f 28.00 0.00 0.00 28.00 0.00 0.00 0.00 0.00 0.00 2 300.00 0.00 0.00 300.00 0.00 0.00 0.00 0.00 0.00 3 702.06 10.05 355.00 700.00 35.04 -3.07 2.50 355.00 -35.04 4 1629.31 47.14 355.00 1500.00 489.50 -01.08 4.00 0.00 X89.50 5 1729.31 47.14 355.00 1568.02 542.52 <7.48 0.00 0.00 -542.52 fi 1946.10 56.00 347.00 1702.78 709.73 -74.89 5.00 322.15 -709.73 7 1998.10 58.00 347.00 1730.72 750.12 -84.01 0.00 0.00 -750.12 8 2442.47 56.00 320.00 1983.53 1076.28 -246.63 5.00 282.35 -1076.28 9 2492.47 56.00 320.00 2011.49 1108.04 -273.27 0.00 0.00 -1108.04 10 3232.36 58.00 275.00 2440.23 1379.20 -794.17 5.00 258.98 -1379.20 11 4614.56 64.75 194.06 3218.12 743.79 -1819.38 5.00 -107.05 -743.79 12 4804.34 84.75 194.06 3299.06 577.28 -1681.06 0.00 0.00 -577.28 13 5171.61 76.00 184.00 3422.48 236.54 -1714.13 4.00 X1.94 -238.54 14 5231.61 76.00 184.00 3437.00 178.47 -1718.19 0.00 0.00 -178.47 iJ-152 Tt D top (wp05) 15 5408.61 78.00 184.00 3479.34 9.08 -1730.04 0.00 0.00 -9.08 16 5517.93 80.00 182.00 3502.48 -99.82 -1735.72 4.00 333.72 99.62 17 6192.93 80.00 181.00 3819.89 -784.13 -1753.12 0.15 289.91 764.13 18 6316.54 85.00 180.50 3636.08 $88.82 -1754.75 4.00 354.30 588.62 19 fi353.54 85.00 180.50 3639.13 -923.49 -1755.05 0.00 0.00 923.49 20 6489.74 91.81 180.50 3842.92 -1059.55 -1756.24 5.00 0.00 1059.55 21 6583.74 91.61 180.50 3639.76 -1159.49 -1757.11 0.00 0.00 1159.49 22 673&.&7 56.60 150.23 3641.54 -1308.56 -1785.06 3.50 -177.01 1308.56 23 7017.81 88.80 18013 3658.39 -1557.00 -7759.ifi 0.00 0.00 1587.00 24 7153.74 99.31 179.75 3660.86 -1722.27 -1759.14 3.50 -5.79 1722.27 25 8153.14 91.31 179.75 3638.00 -2722.00 -1754.77 0.00 0.00 2722.00 1 J-152 T2 (wp05) 26 8292.60 88.43 179.57 3640.75 -2861.39 -1753.95 3.50 -177.92 2861.39 27 8458.42 88.43 179.57 3651.07 -3028.88 -1752.72 0.00 0.00 3026.88 28 8588.25 90.97 179.33 3654.01 -3158.64 -1751.47 3.50 3.07 3156.64 29 9888.25 90.97 179.33 3632.00 -0456.37 -1736.27 0.00 0.00 4456.37 1J-152 T3 (wp05) Pian 1J-123 Kuparuk Prelim • • ~.-~ ~ Halliburton Energy Services HA~>LiBUATOnrI ~~-t~~tlrp5 Anticollision Report - ~ - A'a;<a Company: ConocoPhillips Alaska (Kuparuk) Project: Kuparuk River Unit Reference Site: Kuparuk 1J Pad Site Error: O.OOft Reference Well: Plan 1J-152 Well Error: O.OOft Reference Wellbore 1J-152 Reference Design: 1J-152 (wp05) Local Co-ordinate Reference TVD Reference: MD Reference: North Reference: Survey Calculation Method: Output en-ors are at Database: Offset TVD Reference: Sperry Drill#ng 5aruioes Well Plan 1J-152 -Slot 1J-152 Planned RKB @ 109.OOft (Doyon 141 (28+81 )) Planned RKB @ 109.OOft (Doyon 141 (28+81)j True Minimum Curvature 2.00 sigma EDM 2003.11 Single User Db Reference Datum Reference 1J-152 (wp05) Filter type: GLOBAL FILTER APPLIED: All wellpaths within 200'+ 100/1000 of referE Interpolation Method: MD Interval 100.OOft Error Model: ISCWSA Depth Range: Unlimited Scan Method: Trav. Cylinder North Results Limited by: Maximum center-center distance of 1,186.03ft Error Surface: Elliptical Conic Warning Levels evaluated at: 0.00 Sigma ____ Survey Tool Program Date 1!16!2006 From To (ft) (ft) Survey {Wellbore) Tool Name Description 28.00 800.00 1J-152 (wp05) (1J-152) CB-GYRO-SS Camera based gyro single shot 800.00 9,887.69 1J-152 (wp05) (1J-152) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC CC -Min centre to center distance or covergent point, SF -min separation factor, ES -min ellipse separation 9/17/2006 90:28:97AM Page 2 of 4 COMPASS 2003.? 1 Build 48 ~~~„e ~~ s Halliburton Energy Services HALLIBURT~N ~C~f t~C~~i~li~5 Anticollision Report __.___s.u Alt~k~ 5~erry ~riliing 3ervi~~r~ Company: ConocoPhillips Alaska (Kuparuk) Local Co-ordinate Refierence: Well Plan 1J-152 -Slot 1J-152 Project: Kuparuk River Unit ND Reference: Planned RKB @ 109.OOft (Doyon 141 (28+81)) Reference Site: Kuparuk 1J Pad MD Reference: Planned RKB @ 109.OOft (Doyon 141 (28+g1)1 Site Error: O.OOft North Reference: True Reference Well: Plan 1J-152 Survey Calculation Method: Minimum Curvature Well Error: O.OOft Output errors are at 2.00 sigma Reference Wellbore 1J-152 Database: EDM 2003.11 Single User Db Reference Design: 1J-152 (wp05) Offset ND Reference: Reference Datum Summary Reference Offset Centre to No-Go Allowable Measured Measured Centre Distance Deviation Warning Site Name Depth Depth Distance (ft} from Plan Offset Well -Wellbore -Design (ft) (ft) (ft) (ft) Kuparuk 1J Pad 1 J-03 - 1 J-03 - 1 J-03 192.86 200.00 185.10 3.38 181.72 Pass -Major Risk 1J-09 - 1J-09 - 1J-09 687.51 700.00 36.74 12.78 23.96 Pass -Major Risk 1J-10 - 1J-10 - 1J-10 387.18 400.00 201.58 7.15 194.43 Pass -Major Risk 1J-101 - 1J-101 - 1J-101 908.55 900.00 136.48 20.48 116.00 Pass -Major Risk 1J-101 - 1J-101 L1 - 1J-101 L1 908.55 900.00 136.48 19.26 117.22 Pass -Major Risk 1J-101 - 1J-101 L1 PB1 -1J-101 L1 PB1 908.55 900.00 136.48 19.26 117.22 Pass -Major Risk 1J-101 - 1J-101 L2 - 1J-101 L2 908.55 900.00 136.48 19.26 117.22 Pass -Major Risk 1J-101 - 1J-101 P61 - 1J-101 PB1 908.55 900.00 136.48 19.26 117.22 Pass -Major Risk 1J-154 - 1J-154 - 1J-154 Rig 397.54 400.00 58.69 8.77 49.92 Pass -Major Risk 1J-154 - 1J-154 L1 - 1J-154 L1 397.54 400.00 58.69 8.77 49.92 Pass -Major Risk 1J-154 - 1J-154 L2 - 1J-154 L2 397.54 400.00 58.69 8.77 49.92 Pass -Major Risk 1J-164 - 1J-164 - 1J-164 389.16 400.00 282.21 8.64 273.57 Pass -Major Risk 1J-164 - 1J-164 L1 - 1J-164 L1 389.16 400.00 282.21 8.64 273.57 Pass -Major Risk 1J-164 - 1J-164 L2 - 1J-164 L2 389.16 400.00 282.21 8.64 273.57 Pass -Major Risk 1J-164 - 1J-164 L2 P61 - 1J-164 L2 P61 389.16 400.00 282.21 8.64 273.57 Pass -Major Risk Plan 1J-102 - 1J-102 - 1J-102 (wp04) 401.78 400.00 146.72 9.91 136.81 Pass -Major Risk Plan 1J-102 - 1J-102 L1 - 1J-102 L1 (wp03) 704.27 700.00 143.45 15.11 128.34 Pass -Major Risk Plan 1J-102 - 1J-102 L2 - 1J-102 L2 (wp03) 704.27 700.00 143.45 15.11 128.34 Pass -Major Risk Plan 1J-103 -Plan 1J-103 - 1J-103 (wp01) BHI 502.40 500.00 145.09 10.66 134.43 Pass -Major Risk Plan 1J-105 -Plan 1J-105 - 1J-105 (wp01) BHI 400.00 400.00 151.18 8.45 142.73 Pass -Major Risk Plan 1J-107 -Plan 1J-107 - 1J-107 (wp01) BHI 300.00 300.00 166.09 6.23 159.86 Pass -Major Risk Plan 1J-109 -Plan 1J-109 - 1J-109 (wp04) 299.99 300.00 202.66 6.60 196.06 Pass -Major Risk Plan 1J-111 -Plan 1J-111 - 1J-111 (wp02) 300.00 300.00 231.53 6.49 225.03 Pass -Major Risk Plan 1J-123 Kuparuk Prelim - 1J-23 E Lat - 1J-23 6,351.01 4,599.98 258.46 104.29 154.18 Pass -Major Risk Plan 1J-123 Kuparuk Prelim - 1J-23 Pilot - 1J-23 F 6,351.01 4,599.98 258.46 104.29 154.18 Pass -Major Risk Plan 1J-123 Kuparuk Prelim - 1J-23 W Lat- 1J-23 6,351.01 4,599.98 258.46 103.71 154.75 Pass -Major Risk Plan 1J-150 (Ugnu Disposal) -Plan 1J-UgnuDispc 504.39 500.00 41.03 9.62 31.41 Pass -Major Risk Plan 1J-152 - 1J-152 L1 - 1J-152 L1 (wp05) 5,599.90 5,599.98 3.23 3.66 -0.42 FAIL - No Errors Plan 1J-152 - 1J-152 L2 -1J-152 L2 (wp05) 5,299.92 5,299.98 2.56 3.29 -0.73 FAIL - No Errors Plan 1J-156 - 1J-156 L1 - 1J-156 L1 (wp02) 395.77 400.00 101.92 8.59 93.32 Pass -Major Risk Plan 1J-156 - 1J-156 L2 -1J-156 L2 (wp02) 395.77 400.00 101.92 8.59 93.32 Pass -Major Risk Plan 1J-156 -Plan 1J-156 - 1J-156 (wp02) 395.77 400.00 101.92 8.59 93.32 Pass -Major Risk Plan 1J-158 - 1J-158 - 1J-158 {wp2A) BHI 394.98 400.00 139.89 7.65 132.24 Pass -Major Risk Plan 1J-159 - 1J-159 - 1J-159 (wp06) 393.48 400.00 162.21 8.56 153.65 Pass -Major Risk Plan 1J-159 - 1J-159 L1 - 1J-159 L1 {wp06) 393.48 400.00 162.21 8.56 153.65 Pass -Major Risk Plan 1J-159 - 1J-159 L2 - 1J-159 L2 (wp06) 393.48 400.00 162.21 8.56 153.65 Pass -Major Risk Plan 1J-160 -Plan 1J-160 - 1J-160 (wp01) BHI 392.51 400.00 180.43 8.55 171.88 Pass -Major Risk Plan 1J-162 - 1J-162 - 1J-162 (wp03.1-North Heel 391.24 400.00 240.44 8.37 232.07 Pass -Major Risk Plan iJ-162 - 1J-162 L1 - 1J-162 L1 (uvp3.1) 391.24 400.00 240.44 8.27 232.17 Pass -Major Risk Plan 1J-162 - 1J-162 L2 - 1J-162 L2 (wp3.1) 391.24 400.00 240.44 8.27 232.17 Pass -Major Risk Plan 1J-166 - 1J-166 - 1J-166 4,882.72 4,300.00 158.71 93.78 64.93 Pass -Major Risk Plan 1J-166 - 1J-166 L1 - 1J-166 L1 (wp07) 4,868.38 4,299.98 166.83 93.22 73.61 Pass -Major Risk Plan 1J-166 - 1J-166 L1 - 1J-166 L1 Rig 4,882.72 4,300.00 158.71 93.78 64.93 Pass -Major Risk Plan 1J-166 - 1J-166 L2 - 1J-166 L2 (wp07) 4,868.38 4,299.98 166.83 93.22 73.61 Pass -Major Risk Plan 1J-173 Kuparuk - 1J-73 E Lateral - 1J-73 E L 6,632.25 4,399.98 539.77 103.46 436.31 Pass -Major Risk Plan 1J-173 Kuparuk- 1J-73 Kuparuk- 1J-73 W L 6,632.25 4,399.98 539.77 103.46 436.31 Pass -Major Risk Plan 1J-173 Kuparuk- 1J-73 Pilot- 1J-173 Pilot (u 6,632.25 4,399.98 539.77 103.46 436.31 Pass -Major Risk Plan 1J-182 - 1J-182 - 1J-182 (wp05) 300.00 300.00 639.64 6.50 633.14 Pass -Major Risk Plan 1J-182 - 1J-182 L1 -1J-182 L1 (wp05) 300.00 300.00 639.64 6.28 633.36 Pass -Major Risk WSP-02 -WSP-02 -WSP-02 386.88 400.00 242.84 7.90 234.93 Pass -Major Risk WSP-15 -WSP-15 -WSP-15 480.91 500.00 210.70 12.29 198.41 Pass -Major Risk WSP-1 S -WSP-1 S -WSP-1 S 686.37 700.00 188.83 25.71 163.12 Pass -Major Risk CC -Min centre to center distance or covergent point, SF -min separation factor, ES -min ellipse separation 1/17!2006 10:28:17AM Page 3 of 4 COMPASS 2003.11 Build 48 ~RI~!!~~,^' -152 ~illing Hazards momma (SEE WELL PLAN AND ATTACHMENTS FOR DETAILED DISCUSSION OF THESE RISKS) 13-1/2" Onen Hole / 10-3/4" Casing Interval Hazard Risk Level Miti ation Strate Broach of Conductor Low Monitor cellar continuously during interval. .Gas Hydrates Moderate i Control drill, Reduced pump rates, Reduced drilling fluid temperatures, Additions of Driltreat. Running Sands and Low Maintain planned mud parameters, Gravels Increase mud weight, use weighted swee s. Hole swabbing on trips Moderate Trip speeds, proper hole filling (use of trip sheets um in out 9-7/8" Open Hole / 7-5/8" Casing Interval Hazard Risk Level Miti ation Strate Running Sands and Low Maintain planned mud parameters, Gravels Increase mud weight, use weighted swee s. Gas Hydrates Low ~ Control drill, reduced pump rates, reduced drilling fluid temperatures, additions of Driltreat. Stuck Pipe Low Good hole cleaning, pre-treatment with lost circulation material,, stabilized BHA, decreased mud wei ht Abnormal Reservoir Low BOP training and drills, increased mud Pressure wei ht. Lost circulation Low Reduced um rates mud rheolo ,LCM Hole swabbing on trips Moderate Trip speeds, proper hole filling (use of trip sheets , um in out 6-3/4" Open Hole / 4-1/2" Liner Interval Hazard Risk Level Miti ation Strate Abnormal Reservoir Pressure Low - Stripping drills, shut-in drills, increased mud wei ht. Stuck Pipe Low Good hole cleaning, PWD tools, hole o ener runs, decreased mud wei ht Lost Circulation Low Reduced um rates, mud rheolo ,LCM Hole Swabbing on Trips Moderate Trip speeds, proper hole filling (use of trip sheets , um in out, backreamin q 1J-152 Drilling Hazards Summary f ~ q ~ ~, ~ prepared by Mike Greener ~~ 1/23/2006 7:14 AM Rig: Doyon 141 Location: West Sak Client: ConocoPhillips Alaska, Inc. Revision Date: 1/17/2006 Prepared by: Mike Martin Location: Anchorage, AK Phone: (907) 265.4207 Mobile: (907) 748-6955 email: martin13@slb.com Previous Csg. < 10 3/4", 68.0# casing at 2,825' MD < Top of Tail at 3,450' MD < 7 5/8", 29.7# casing in 9 7/8" OH TD at 6,354' MD (3,638' TVD) CemCADE Preliminary Job Design 7-5/8" Intermediate Casing reliminary Job Design based on limited input data. For estimate purposes only Sd~l~m~e~g~ Volume Calculations and Cement Systems Volumes are based on 25% excess. Tail slurry is designed for 500' MD above Ugnu C - (2904' MD annular length). Tail Slurry Minimum thickening time: 180 min. (Pump time plus 90 min.) DeepCRETE @ 12.5 ppg - 2.25 ft3/ft 0.2148 ft3/ft x 2904' x 1.25 (25% excess) = 779.7 ft3 0.2578 ft3/ft x 80' (Shoe Joint) = 20.6 ft3 779.7 ft3 + 20.6 ft3 = 800.3 ft3 800.3 ft3/ 2.25 ft3/sk = 355.7 sks Round up to 360 sks BHST = 85°F, Estimated BHCT = 73°F. (BHST calculated using a gradient of 2.6°F/100 ft. below the permafrost) PUMP SCHEDULE Pump Rate Stage Stage Time Cumulative Stage Volume Time (bpm) (bbll (min) (min) CW100 5.0 10.0 2.0 2.0 Pressure test lines 0.0 0.0 10.0 12.0 CW100 5.0 40.0 8.0 20.0 Drop bottom plug 0.0 0.0 5.0 25.0 MUDPUSH II 5.0 50.0 10.0 35.0 DeepCRETE 5.0 142.5 28.5 63.5 Drop top plug 0.0 0.0 5.0 68.5 Water 5.0 20.0 4.0 72.5 Switch to rig 0.0 0.0 5.0 77.5 Mud 6.0 259.1 43.2 120.7 Slow & bump plug 3.0 9.0 3.0 123.7 MUD REMOVAL Recommended Mud Properties: 8.9 ppg, Pv < 15, TY < 15. As thin and light as possible to aid in mud removal during cementing. Spacer Properties: 11.0 ppg MudPUSH" II, Pv ? 19-22, TY ? 22-29 Centralizers: 1-'/2 Tandem Rise centralizers perjoint across the West Sak and Ugnu formations and 1 per joint between. ~~?~~ ~_ • • CemCADE Preliminary Job Design 10 3/4" Surface Casing Preliminary Job Design based on limited input data. For esLmate purposes only. Rig: Doyon 141 Location: West Sak Client: ConocoPhillips Alaska, Inc. Revision Date: 1/17/2006 Prepared by: Mike Martin Location: Anchorage, AK Phone: (907) 265207 Mobile: (907) 748-6955 email: martin13@slb.com < TOC at Surface Previous Csg. < 20", 91.5# casing at 80' MD < Base of Permafrost at 1,690' MD (1,541' TVD) I' ~' Volume Calculations and Cement Systems Volumes are based on 250% excess in the permafrost and 35% excess below the permafrost. The top of the tail slurry is designed to be at 2,025' MD. Lead Slurry Minimum pump time: 210 min. (pump time plus 90 min.) ARCTICSET Lite @ 10.7 ppg - 4.45 ft3/sk 1.3644 ft3/ft x (80') x 1.00 (no excess) = 109.2 ft3 0.3637 ft3/ft x (1690' - 80') x 3.50 (250% excess) = 2049.4 ft3 0.3637 ft3/ft x (2025' - 1690') x 1.35 (35% excess) = 164.5 ft3 109.2 ft3 + 2049.4 ft3+ 164.5 ft3 = 2323.1 ft3 2323.1 ft3 / 4.45 ft3/sk = 522 sks Round up to 530 sks Have 290 sks of additional Lead on location for Top Out stage, if necessary. Tail Slurry Minimum pump time: 150 min. (pump time plus 90 min.) DeepCRETE @ 12.0 ppg - 2.47 ft3/sk 0.3637 ft3/ft x (2825' - 2025') x 1.35 (35% excess) = 392.8 ft3 0.5400 ft3/ft x 80' (Shoe Joint) = 43.2.ft3 392.8 ft3 + 43.2 ft3 = 436 ft3 436 ft3! 2.47 ft3/sk = 176.5 sks Round up to 180 sks BHST = 47°F, Estimated BHCT = 64°F. (BHST calculated using a gradient of 2.6°F/100 ft. below the permafrost) PUMP SCHEDULE Pump Rate Stage Stage Time Cumulative Stage (bpm) Volume (min) Time (bbl) (min) < Top of Tail at 2,025' MD < 10 314", 68.0# casing in 13 1/2" OH TD at 2,825' MD (2,204' TVD) Mark of Schlumberger CW100 5.0 10.0 2.0 2.0 Pressure test lines 0.0 0.0 10.0 12.0 CW100 5.0 40.0 8.0 20.0 Drop bottom plug 0.0 0.0 5.0 25.0 MUDPUSH II 6.0 50.0 8.3 33.3 AS L 7.0 413.8 59.1 92.4 DeepCRETE 6.0 77.7 12.9 105.3 Drop top plug 0.0 0.0 5.0 110.3 Water 5.0 20.0 4.0 114.3 Switch to rig 0.0 0.0 5.0 119.3 Mud 7.0 235.0 33.6 152.9 Slow & bump plug 3.0 9.0 3.0 155.9 MUD REMOVAL Recommended Mud Properties: 9.6 ppg, Pv < 15, TY < 15. As thin and light as passible to aid in mud removal during cementing. Spacer Properties: 10.5 ppg MudPUSH" II, Pv ? 17-21, Ty ? 20-25 Centralizers: Recommend 1 per joint across zones of interest and 2 per joint on the shoe track to assist in mud removal. ~~ 0 z 0 Insulated Conductor Casing, 20" 94#, KSS s 34", 0.312" WT (H `~~ +:- 8U' MD ~• 10.314", 68#, L-80, BTC, R3 C<2,825` MD / 2 X04' TVD _~ ~~. 53.9 elegrees TD 13-1.2" (tole Top of Llgnu C r' _~ 3,900' Mn ~ zss9' ~rvn ms w '~' v /~ T n S ~ ~ A rt 3 2 ^_ tr• .~. ^• o c ~ o -"owe m ~_ 9 ` C a N ' °~~e T~~ ;s a Lateral Entry Module #1 (LEM), Baker, with seal bore acrd ZXP packer above. Tubhtg, 4 ';:" IBTM, from LEM to -~ A2 Lmzr, with seal stem and CAMCO 3.56:' "DB" nipple. Seal bore and ZXP packer for A2 liner +/- 9U' below "B" window (2) Gas Lifl Mandrels, CAMC'D 4.1iY' s 1" Model KMBG wi dummy valves, one (u: 100' MD & one ~:: I50' MD, bolt are both downhole recombhtation (1) Gas Lift Mandrel, CAMCO 41 i2" s 1" Model KMBG w/ dummy vahe (v.., one (I 1 set (a. 2.40U' MD, 1.959' TVD. (1) Gas Lift Mandrel, CAMCD 4•U:' x 1" Model KMBG w/ dummy valve, (w <'P_ deg, 5,000' MD, 3,373' TVD. Electric Submersible Pump, Centrilift 418 HP motor, with F00000 wireline deployed pump. Bottom at 6,193' MD, 3,620' 7VD 152 L2 "D" Sand Window ~: 5,232' MD ~ 3,43T TVD 76 decrees "D" Liner, 4.1/2" 12.8#, LSQ, IBTM, R3 IJ-I52 L2: (0.125" s 25" slots, 32 per foot, 5.9P%o open azea) 6-3!4" D sand lateral TD 12,940' MD / 3,347 TVD Angle 91.24 deerees 7.5 ~8", 40#, L-8U, BTC'M, R3 C'sg 6,353' MD i 3,530`7VD 85 degrees TD 9.7/8" hole 152 LI "B" Sand Window p. 5,518' MD / 3,502' TVD 1J-152 Ll: 4(1 degrees "B"Liner, 4.1/2", 128x, L8Q IBTM, R3 6.3 i4" "B" sand lateral (0.125" x 2.5" slots, 32 per foot, 5.9°-6 open area) TD 13,245' MD ' 3,423' TVD Angle 91.01 degrees -.- A2 Sand Liner, 4-I i2", 12.8#, L80, .., \ ~ ~ ' e _ .~ 16TH, R3 ',•; slotted acrd': i blarilc, eonsn~ic•rms (or iso(ntion IJ-152: 6-3/4 A2 sand lateral / ,`` : /' -\ ~ TD 9,886' MD / 3,632' TVD Angle 90.97 degrees \ Wellhead /Tubing Head /Tree, 10-314" x 4-!5" 5,000 ksi Tubing String: 4-I/2", 12.6 #, L-80, IBTM • • ConocoPhillips Alaska ConocoPhillips Alaska (Kuparuk Kuparuk River Unit Kuparuk 1J Pad Plan 1J-152 -Slot 1J-152 1 J-152 Plan: 1J-152 (wp05) 1/4 Mile Scan 23 January, 2006 HALLIE3U[aT01V Sperry Drilling Services ~a~rrnat. V ~~ ~..i r- 3 Wells violate the 114' mile radius surrounding the 1J-152 production zone; WSP-6, 1J-166 ~ 1J-154 1 J-168 1 J-10 ~\ ,, =_._ 1J-152 1!4 mile @ Heel (wp05) 1J-152 (wp05) -i / 1J-152 L2 (wp05) ,--- 1J-152 L1 (wp05)_ 1J-152 1!4 mile ~ Tce (wp05) WSP-06 1J-101 WSP-07 -- -----------WSP-10 f ` - 1 J-154 Project: Kuparuk River Unit Site: Kuparuk 1J Pad Well: Plan 1J-152 Wellbore: 1J-152 L1 Plan: 1J-152 L1 (wp05) 12000 1 OOOO 8000 i 6000 400 2000 O -2000 •i •i 1 J-166 1 J-164 -6250 -5625 -5000 -4375 1 J-168 0 I -1875- -3125 ~ O U-) N 3750 L C O x{375 Z 0 1/4 Mile @ T M Aamulhs m Tna! Nodh Mapnetlc Nodh: 24.54° Stre~ptt~5 ~ FH T Dq Angye: 80.72° Date: 1 12 3120 0 4 Model: BGGM2004 West(-yEast(+) (1250 ltfin) 3125 -2500 -1875 -1250 -825 1 J-166 1 J-164 r~~ ~1 7 5/8" 1 J-152 (wp05) - - 10 3/4" 625 1250 1875 2500 1 J-101 ,250 ~ WSP-06 625 0 ~_ WSP-07 -625 -1250 i i i i ~ -1875 i i WSP-10 -3125 N O C Z -3750 0 -4375 N -50~ 1 J-154 -5625 -6250 -6875 1J-154 LZ ~ - ' asoo _____ 1J-154 L1 -8125 1 J-152 L2 (wp05) -s25o -6875 1 J-152 L1 (wp05) ~~ ,'~~ -7500 -' _ ` 41 /2' -8125 ~ 1/4 Mile @ Toe ^'c^ proms: Kuparuk River Unit Site: Kuparuk 1J Pad 3 Wells Violate the 1/4 mile radius Well: Plan 1J-152 surrounding the 1J-152 production ConocoPhilli s Welltwre. 1J-152 L1 p Plan: 1J-152 L1 (wp05) zones; WSP-6, 1J-166 8~ 1J-154 a~~~ska -6250 -5625 -5000 -4375 -3750 -3125 -2500 -1875 -1250 -625 D 625 1250 1875 2500 West(-East(+) (1250 tUn) ORIGINAL _ __ ,. Closest Wells in Pool -1J-152 Ref. Well MD TVD Offset WeU MD TVD Closest Well 1J 152 10875 3467 1J 154L1 8900 3488 1170' 1J 152 5199 3429 1J 166 5025 3452 943' IJ-152 5650 3517 WSP-6 3850 3662 1107' ORIGINAL t SHARON K. ALLSUP-DRAKE 1130 i CONOCOPHILLIPS /~ AT00 5530 ~~%;_)~ c r~~'.,,~~~ ~%~%~~s-1ssliaal DATE ANCHORAGE AKC 99s01 }, 7 { y/~, / / /~ <~ PAY TO THE J~ f~ I ~-_' G'1'~ ~ ~~~I (?~ f~ ~I CL-/C l- ~j / ~~. (J U ~~ ORDER OF ff - - - ~~ , ~,~ ~` ----_° (ice ~~ ~~ = ~ ~..~,~ r~~ ~..~---oo~~ARS ~ o~~ o~ ~~ J PMOrydnChdS@ ~ % Valid Up To 5000bollars JPMorgan Chase Bank, N.A. - j - Columbus, OH `' F ~ ~~~ ~ ~ V. MEMO ~ ,. /~-~ ___ _ -- -- " - - -- - ~:0441L551L~:5.2.8747L90?92711'L13~ • TRANSMITTAL LETTER CHECKLIST WELL NAME ~ ~'f~C ~~/ `~S ~-. PTD# ~C~~ "~~ ~~C~ Development _ _ aervice Exploratory Stratigraphic Test Circle Appropriate Letter /Paragraphs to be Included in Transmittal Letter CHECK ADD-ONS TEXT FOR APPROVAL LETTER WHAT (OPTIONS) APPLIES MULTI LATERAL The permit is for a new wellbore segment of existing well , (If last two digits in permit No. ,API No. 50- - - API number are between 60-69) Production should continue to be reported as a function of the original API number stated above. PILOT HOLE In accordance with 20 AAC 25.005(f), all records, data and logs acquired for the pilot hole must be clearly differentiated in both well name ( PH) and API number (50- - -_) from records, data and logs acquired for well SPACING The permit is approved subject to full compliance with 20 AAC EXCEPTION 25.055. Approval to perforate and produce / infect is contingent upon issuance of a conservation order approving a spacing exception. assumes the liability of any protest to the spacing exception that may occur. DRY DITCH All dry ditch sample sets submitted to the Commission must be SAMPLE in no greater than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. Rev: 1/05/06 C:\jody\transmittal_checklist • • o ~ ~ ~ a~ .... ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~~ ~ ,~ ~ c m m o c. o o_ a o c , ~, - c p ~ ~ ~, 3: .~ c= p ~, vi ~, ai, .a g ~: ~ _N O ~ y, N' O C7 ~ ~ ~ ' ~ ~ ~ ~ ~ ~ ~ ~ ~, L O' ~ ~~ Of O O L O F-' ~ ~ ~ ~ ~ ~ ~~ ~ G O. Or O ~~ C O Q~ ~ ~ ~ ~ Q ~ 4 ' O' ~~ ~ ~ N N O p_ ~ ~ ~ ~ . ~ ~ T O~ ~ 4 N . a p. ~ m M ~, ;~ ~ 3. ~ m. c. ~ a~ ° ~ ~ c o ~ ~ ~ _ ~ ~ a Q, o, ~ ~, ~, 3, o ~ N. O, y, N, ~ ~ ~ ~~ ~ ~ ~ N. ~ ~, N, ~ O: N. a, w e O: ~ ~ c, ~ ~ c. o: 0. c. y = ~, ~ N o ~~ Q. m' •~ o, a ~ Q. ~ ~ ?~ ~ N a, ~ c o. ~ Z o ~ ~ ~° ~ _ . , , Y co ~ c. a~, 3 ~ O 3: m. g a ~; o > ~ Z~ ~ v ~, ~: ~, -o. m, a ~ v ~ ~, U a ~ m. No $ N ~ ~, ~ a g axi, ~ c N' T ~ ~ ~ ~ N• ~ ~ ~ N• ~ ~ N. ~ ~: ~ 7. ~' •~~ W~ N O~ ~ ~ ~ c. c, oa . 3. ~~ -d. Z H n M, N 4 3, m a> °o Y ° n ° ~ m. rn '. ~ U ~ p, m 4 °~ a ca ~. ~ ~, r N .f6c ~ M ~ d' p E p. ~~ N, ~ ~ ~ ~ Q. ~ ~ ~~ ~ ~ N. ~ ~: ~ ~~ ~ ~ ~ , ~ ~, ~ Z~ ~ • U ~ O O ~ , ~ ' ~ p 0 0- p p ~ C' 0-~ C. N, ~ ~ ~ V~ ~ N, _: ~~ L. ~ p~ ~ ~~ ~ ~ y, ~' ~ U w fA Y m ~ ~ O,ri ~ a~, ~ N, ~ •3 ~ ~ ~, 3 ' v' n a o ~ i a a~ O , ~, ~ ' ~, a : a> ' ~ c, n E m : ~ in, N m ~ o ~ c o Z >~ ~~ p. ~p~ ~ ~ ~: __: ~ __~ ~, 01 ~ O. ~ gyp, ~ Q, ~ ~ N' a ~ N. O E Q : a~o~ ~ ~ d. m w , o ~ ~ ~ ~ ~ N N, N N, N, N~ N~ N N: N, N, N, N, N~ N~ y N, N, N, N: y N, N, N~ N N, N ~ Q, Q, ~ Q, Q, N~ y ~ N, Q, N, O, O, N N~ N, N, y: Q, N, N: N N, N, y N~ N N, N, N, N N, O, Q, N: N~ N, N, Q, Q, Q, d } ~-, }: }, ~, ).., } } } } } } } Z Z Z Z ~ Z ~- Z Z ~ } Z ~ ~ )- ~• ~ } } Z Z i )- } Z z Z T y ~ ~ ~ ~ ~ ~ ~ C ~ I ~ , . , - 5 o, : o. o, Z' c O v ~, a~, .° 3 E~ ~.' 3, o ~ N ~ ~ ~ ~ ~ N• • O o o ~ .o a. aci ~ ' ~, ` . or ~ ~ ~ ~ ~ c: ~ ~ ~ ~ ~ ~: a~ ~c: O, N: ~ N, c~' ~ d a ~ m, o. ~ U: ~ o. ~ ~ LL+ N N ~ "~ ~ Q ~ ~ ~ i ~, 4 ~~ a: O. ~ ~ y. N O. ~ C p ~ ~ ~~ N ~ N N ~ ~ ~~ 'C~ y ~ `O. f6 N. ~ 7. 7. ~ ~ ~: `C: N. f6 ~ 1 N N. Q T : ~' ~ E: O 4 .-. ~ c..) _ ~ ~ Z ;~ m ~ 3, m. o: ~ c. of ~: °~ ~, y~ ~: ~ ~ ,~ ~ Q' v',' uyi' d' m ai .. Y Z v' o : c. a' m. o, m N: .c a ~ N: m. > ~ n, N. ~ o. c. o, ' U: c. > m. p. o: a, 4 p~ Qy ~, 4.' ~ ' ' t, c, N' ' ~ N• c: ' °' ° o' ~ c C~ ~, O O _ a. C, c ~ ~ f6. ~, O. f6. c ~ O y, ~ .-,~ c ~ ~ ~ a~ i ~ ~ _: ~ c, N. a~ a O N t O. ~ Q ~ ~ U 1 U -C N `' N O ~ C ~ O` U ~ C ~ ~~ U. • O, ~, d: ~~ ~~ 3, ~ ~: j. ~~ .~' , ~ N N d g ~ ~ p, s o ~ ~ ~, c: . , . o , , , A o' a ~ , .N.~ a : m. f 6 m ¢, m y a o, an o o: a~ . Y m ~, 4 ~ ~ ~ m. ~ ~~: _ °. n ~ m. ~ w, . ~~ ~ c. a ~' ~, ° m. ~, ~ rn a N Q. a 3 0 ~-°~ o 3 ~' Q N. c, ~: f6. ~ Dl ~ _ ~ 3, s a 3 o a. N, ~ a N. ~ c ' ~ ° N, ~ M: ~: : N~ t, N~ ~ N~ ' O~ .~-~ C ~ 3, , ° E O W o a a a~ c ~ ~; m a~' a' , ~ i ~, a~ ' .. ~, ~ ~ - ~ . o' ~ ~, ~ o: ,~ Q a ~, m, o, ~, o t U ao ~ a. °' m; ai ' ~' p' ~ ~° ~, o aai, ' ~ o ' ~ ~, ' ' o o' ~' V' o' o' °' °' Y ' a~i `o' : o N' , a. ~ ~, m' ~: : L, o~ o, ~ ~: Q ~ N: , : _, : -~ a~ a 4 a N 4 4 a~ a> > 4 o_ ~ c v N a ° ai ai _ a m ~ o ~ ~ ~ o ~ U .r •3 N c ~ o o ot$ " t' ~ f6, : ~, C, O. O. ~ 3: ~, N• ~ .N~ y. Q Vl. (6 L' ~~ _, ~', : ~ • G O. _ Q ~ ~~ ~, N. ~ f6• O y (6• O' ~~ N' ~ ._~ O , ~ C, ~ '~ -O. ~ . ~: _~ p N, O, N' O~ .N~ O. a' ' ' ~, 4 ~ d ~ ~~ N' 2], C, ~ 4 O. : a' -O, -O. N, N ~: ~ U. ~ N' ~~ ~~ N' N Q, ~ 3: S a ~: a' O) N• ~, ~ i' c' O' LT N' y' N. N. >: c. Y, .~? C N O, t, ~ 7. ~ a p. ~.'~ N. _ ~~ O. U °~ U N _ N• ~~ >, "'~ .O. ~ _ N ^ ~ - ( ~ _ a;, u;, ~, C m o t, c _ c ~ •3: ~ c, m~~ o o o _ ~ a o 0 0, ~ m o, c a~ c~ m. „ / ~ ~ O , ~ ~' 3. m. m. m: v U U ' ' ' ' ~ m , ~~ o, m: " ~ m. E ° ~ m. u ~; a~ ~~ , o - ° ° ~ , ~ a a?: v r, ~~ 4 ~~, vi c. v o •~, o m N ca ~ U~ a '?'~ c ~ 0 fA a~~ o o o o ~ > , o' o >' > ~` ~' ' ~ a' m' ~, ~ . , ~ ~~ . O1 . r Y~ ~~ c' ~, ~~ Y N N' N' N' C a O 3 • ~ ~~ ~ ~, ~, _ N ( ) O ~~ ~~ ~~ a a m a c L ~ ~ . O O. N N ~ N~ O U >, c . N. a .~ , ~ ~ ~ ~ , r cn ~ O N O o. o. U ~ Q ~ .. a Q , O, , ~ , V ~ v v v m a, V Q a, w. - Q ~ - ~ . ~ , m m U ~ ~' ~ , N. , ~ a o cn cn . U , , , : , , , , , , , , , , : : , . . : , , , , , , , , , , , .~ w _ U Q ~ O ~ _ N M V S O N 0p O O _ N M ~ r V ~ ~ GO _ OD O O N N N N M V N N ~ CO N N h OO N N _ O O N M M N M R M M M ~ t17 CO I~ O M M M M Q) M . F- C U o O o O o O ,~~ ~~ O ~ y N Y N Y • O O •C+ Q M ~ Q M Q~ j M O ._ W O R ~ C ~ ~ O' o J N ~ ~ d CTi ~~ J ~k ~ p. 0 ~ p. ~ ~ pap Y ~ ~ a s a ~ w a ~ ~ a~ . , J • Well Hisfory 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 Nistory file and to simplify finding information, information of this nature is accumulated at the end of the fiile under APPENDIX. No special effort has been made to chronologically organize this category of information. ~-otro "~39g( Sperry-Sun Ding Services LIS Scan Utility $Revision: 3 $ LisLib $Revision: 4 $ Tue Jun 20 15:05:25 2006 Reel Header Service name .............LISTPE Date .....................06/06/20 Origin ...................STS Reel Name ................UNKNOWN Continuation Number......01 Previous Reel Name.......UNKNOWN Comments .................STS LIS Writing Library Tape Header Service name .............LISTPE Date .....................06/06/20 Origin ...................STS Tape Name ................UNKNOWN Continuation Number......01 Previous Tape Name.......UNKNOWN Comments .................STS LIS Writing Library. Physical EOF r1 Scientific Technical Services Scientific Technical Services Comment Record TAPE HEADER West Sak MWD/MAD LOGS WELL NAME: 1J-152 API NUMBER: 500292329800 OPERATOR: ConocoPhillips Alaska, Inc. LOGGING COMPANY: Sperry Drilling Services TAPE CREATION DATE: 20-JUN-06 JOB DATA MWD RUN 3 MWD RUN 4 MWD RUN 5 JOB NUMBER: W- 0004263658 W-0004263658 W-0004263658 LOGGING ENGINEER: T. GALVIN T. GALVIN T. GALVIN OPERATOR WITNESS: D. GLADDEN M. THORTON M. THORTON MWD RUN 6 JOB NUMBER: W- 0004263658 LOGGING ENGINEER: T. GALVIN OPERATOR WITNESS: M. THORTON SURFACE LOCATION SECTION: 35 TOWNSHIP: 11N RANGE: 10E FNL: FSL: 2191 FEL: 2582 FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: 109.00 GROUND LEVEL: 81.00 WELL CASING RECORD OPEN HOLE CASING DRILLERS BIT ~ (IN) 1ST STRING 9.875 2ND STRING 6.750 3RD STRING PRODUCTION STRING REMARKS: SIZE (IN) DEPTH (FT) • 10.750 2774.0 7.875 6522.0 1. ALL DEPTHS ARE MEASURED DEPTHS UNLESS OTHERWISE NOTED. THESE DEPTHS ARE BIT DEPTHS. 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTHS (TVD). 3. THIS WELL IS AN OPEN-HOLE SIDETRACK EXITING THE 1J-152 PB2 WELLBORE AT 8425'MD/3623'TVD. 4. MWD RUNS 1 & 2 WERE DIRECTIONAL ONLY - NO DATA ARE PRESENTED. 5. MWD RUNS 3-6 COMPRISED DIRECTIONAL, DUAL GAMMA RAY (DGR) UTILIZING GEIGER-MUELLER TUBE DETECTORS, ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4), AND PRESSURE WHILE DRILLING (PWD). MWD RUNS 4-6 ALSO INCLUDED 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 (SDS) MWD DATA ARE CONSIDERED PDC. 7. MWD RUNS 1-6 REPRESENT WELL 1J-152 WITH API#: 50-029-23298-00. THIS WELL REACHED A TOTAL DEPTH (TD) OF 10053'MD/3622'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). SLIDE = NON-ROTATED INTERVALS REFLECTING BIT DEPTHS. File Header Service name .............STSLIB.001 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/06/20 Maximum Physical Record..65535 File Type ................LO Previous File Name.......STSLIB.000 Comment Record FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: .5000 • FILE SUMMARY PBU TOOL CODE START DEPTH STOP DEPTH GR 2741.5 9992.0 RPD 2760.0 9999.0 RPS 2760.0 9999.0 RPM 2760.0 9999.0 FET 2760.0 9999.0 RPX 2760.0 9999.0 ROP 2787.5 10053.0 BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH MERGED DATA SOURCE PBU TOOL CODE MWD MWD MWD MWD BIT RUN NO MERGE TOP MERGE BASE 3 2741.5 6532.0 4 6532.0 6811.0 5 6811.5 8425.0 6 8425.5 10053.5 REMARKS: MERGED MAIN PASS. Data Format Specification Record Data Record Type ..................0 .Data Specification Block Type.....0 Logging Direction .................Down Optical log depth units...........Feet Data Reference Point ..............Undefined Frame Spacing .....................60 .lIN Max frames per record .............Undefined Absent value ......................-999 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 RPD MWD OHMM 4 1 68 4 2 RPM MWD OHMM 4 1 68 8 3 RPS MWD OHMM 4 1 68 12 4 RPX MWD OHMM 4 1 68 16 5 FET MWD HOUR 4 1 68 20 6 GR MWD API 4 1 68 24 7 ROP MWD FT/H 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 2741.5 10053 6397.25 14624 2741.5 10053 RPD MWD OHMM 0.31 2000 29.5653 14479 2760 9999 RPM MWD OHMM 0.06 2000 24.3458 14479 2760 9999 RPS MWD OHMM 2.5 2000 17.7467 14479 2760 9999 RPX MWD OHMM 3.05 2000 16.2076 14479 2760 9999 FET MWD HOUR 0.12 68.:15 1.49666 14479 2760 9999 GR MWD API 26.27 1 28.14 74.2596 14502 2741.5 9992 ROP MWD FT/H 0.14 13 49.87 154.402 14532 2787.5 10053 First Reading For Entire File..........2741.5 Last Reading For Entire File...........10053 File Trailer • Service name .............STSLIB.001 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/06/_20 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.......06/06/20 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: 3 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 2741.5 6485.5 RPD 2760.0 6478.0 RPM 2760.0 6478.0 RPX 2760.0 6478.0 RPS 2760.0 6478.0 FET 2760.0 6478.0 ROP 2787.5 6532.0 LOG HEADER DATA DATE LOGGED: 23-MAR-06 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 66.37 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT) 6532.0 TOP LOG INTERVAL (FT) 2787.0 BOTTOM LOG INTERVAL (FT) 6532.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 53.5 MAXIMUM ANGLE: 84.9 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 119546 EWR4 ELECTROMAG. RESIS. 4 105242 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) 9.875 DRILLER'S CASING DEPTH (FT) 2774.0 BOREHOLE CONDITIONS MUD TYPE: Other MUD DENSITY (LB/G) 9.00 MUD VISCOSITY (S) • 60.0 • MUD PH: 9.9 MUD CHLORIDES (PPM): 300 FLUID LOSS (C3): 4.8 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT) 2.800 65.0 MUD AT MAX CIRCULATING TERMPERATURE: 1.880 100.0 MUD FILTRATE AT MT: 2.350 65.0 MUD CAKE AT MT: 2.700 65.0 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.....0 Logging Direction .................Down Optical log depth units...........Feet Data Reference Point ..............Undefined Frame Spacing .....................60 .lIN Max frames per record .............Undefined Absent value ......................-999 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 RPD MWD030 OHMM 4 1 68 4 2 RPM MWD030 OHMM 4 1 68 8 3 RPS MWD030 OHMM 4 1 68 12 4 RPX MWD030 OHMM 4 1 68 16 5 FET MWD030 HOUR 4 1 68 20 6 GR MWD030 API 4 1 68 24 7 ROP MWD030 FT/H 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 2741.5 6532 4636.75 7582 2741.5 6532 RPD MWD030 OHMM 1.71 2000 21.5643 7437 2760 6478 RPM MWD030 OHMM 2.2 1597.77 15.7237 7437 2760 6478 RPS MWD030 OHMM 2.5 1922.05 14.8228 7437 2760 6478 RPX MWD030 OHMM 3.05 1353.33 13.1062 7437 2760 6478 FET MWD030 HOUR 0.12 68.15 1.39653 7437 2760 6478 GR MWD030 API 26.27 125.3 71.0299 7489 2741.5 6485.5 ROP MWD030 FT/H 0.14 653.26 135.562 7490 2787.5 6532 First Reading For Entire File..........2741.5 Last Reading For Entire File...........6532 File Trailer Service name .............STSLIB.002 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/06/20 Maximum Physical Record..65535 File Type ................LO Next File Name.........~SLIB.003 Physical EOF File Header Service name .............STSLIB.003 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/06/20 Maximum Physical Record..65535 File Type ................LO Previous File Name.......STSLIB.002 Comment Record FILE HEADER FILE NUMBER: 3 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 4 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH RPX 6478.5 6811.0 FET 6478.5 6811.0 RPM 6478.5 ..6811.0 RPD 6478.5 .6811.0 RPS 6478.5 6811.0 GR 6486.0 6811.0 ROP 6532.5 6811.0 LOG HEADER DATA DATE LOGGED: 25-MAR-06 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 66.37 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT) 6811.0 TOP LOG INTERVAL (FT) 6532.0 BOTTOM LOG INTERVAL (FT) 6811.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 84.0 MAXIMUM ANGLE: 92.6 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 135134 EWR4 Electromag Resis. 4 73634 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) 6.750 DRILLER'S CASING DEPTH (FT) 6522.0 BOREHOLE CONDITIONS MUD TYPE: Mineral Oil Base MUD DENSITY (LB/G): 8.80 MUD VISCOSITY (S) 70.0 MUD PH: .0 MUD CHLORIDES (PPM): 20500 FLUID LOSS (C3) 3.2 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT) .000 .0 MUD AT MAX CIRCULATING TERMPERATURE: .000 104.0 MUD FILTRATE AT M~ MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format Specification Record Data Record Type ..................0 Data Specification Block Type.....0 Logging Direction .................Down Optical log depth units...........Feet Data Reference Point ..............Undefined Frame Spacing .....................60 .lIN Max frames per record .............Undefined Absent value ......................-999 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order DEPT RPD MWD040 RPM MWD040 RPS MWD040 RPX MWD040 FET MWD040 GR MWD040 ROP MWD040 Name Service Unit DEPT FT RPD MWD040 OHMM RPM MWD040 OHMM RPS MWD040 OHMM RPX MWD040 OHMM FET MWD040 HOUR GR MWD040 API ROP MWD040 FT/H .000 •0 .000 .0 Units Size Nsam Rep Code Offset Channel FT 4 1 68 0 1 OHMM 4 1 68 4 2 OHMM 4 1 68 8 3 OHMM 4 1 68 12 4 OHMM 4 1 68 16 5 HOUR 4 1 68 20 6 API 4 1 68 24 7 FT/H 4 1 68 28 8 First Last Min Max Mean Nsam Reading Reading 6478.5 6811 6644.75 666 6478.5 6811 0.31 2000 215.191 666 6478.5 6811 0.06 2000 163.601 666 6478.5 6811 11.21 2000 39.0852 666 6478.5 6811 5.76 1859.83 31.8651 666 6478.5 6811 0.22 59.86 10.3876 666 6478.5 6811 39.64 89.21 65.2787 651 6486 6811 11.6 294.97 204.845 558 6532.5 6811 First Reading For Entire File..........6478.5 Last Reading For Entire File...........6811 File Trailer Service name .............STSLIB.003 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/06/20 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.004 Physical EOF File Header Service name...........~SLIB.004 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/06/20 Maximum Physical Record..65535 File Type ................LO Previous File Name.......STSLIB.003 Comment Record FILE HEADER FILE NUMBER: 4 RAW MWD Curves and log header data BIT RUN NUMBER: 5 DEPTH INCREMENT: .5000 FILE SUMMARY for each bit run in separate files. VENDOR TOOL CODE START DEPTH RPS 6811.5 FET 6811.5 RPM 6811.5 RPX 6811.5 GR 6811.5 RPD 6811.5 ROP 6811.5 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 EWR4 STOP DEPTH 8425.0 8425.0 8425.0 8425.0 8425.0 8425.0 8425.0 BOTTOM) TOOL TYPE DUAL GAMMA RAY Electromag Resis. 4 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): 27-MAR-06 Insite 66.37 Memory 8425.0 6811.0 8425.0 83.6 93.7 TOOL NUMBER 135134 73634 6.750 6522.0 Mineral Oil Base 8.80 63.0 .0 18500 3.0 000 .0 000 111.0 000 .0 000 .0 # ~ • TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format Specification Record Data Record Type ..................0 Data Specification Block Type.....0 Logging Direction .................Down Optical log depth units...........Feet Data Reference Point ..............Undefined Frame Spacing .....................60 .lIN Max frames per record .............Undefined Absent value ......................-999 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 RPD MWD050 OHMM 4 1 68 4 2 RPM MWD050 OHMM 4 1 68 8 3 RPS MWD050 OHMM 4 1 68 12 4 RPX MWDO50 OHMM 4 1 68 16 5 FET MWD050 HOUR 4 1 68 20 6 GR MWD050 API 4 1 68 24 7 ROP MWD050 FT/H 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 6811.5 8425 7618.25 3228 6811.5 8425 RPD MWD050 OHMM 4.55 63.06 21.3351 3228 6811.5 8425 RPM MWD050 OHMM 4.4 81.85 20.944 3228 6811.5 8425 RPS MWD050 OHMM 4.51 59.98 20.6726 3228 6811.5 8425 RPX MWD050 OHMM 4.5 72.37 20.0374 3228 6811.5 8425 FET MWD050 HOUR 0.25 13.1 0.741859 3228 6811.5 8425 GR MWD050 API 49.78 128.14 78.667 3228 6811.5 8425 ROP MWD050 FT/H 5.19 581.48 169.882 3228 6811.5 8425 First Reading For Entire File..........6811.5 Last Reading For Entire File...........8425 File Trailer Service name .............STSLIB.004 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/06/20 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.......06/06/20 Maximum Physical Record..65535 File Type ................LO Previous File Name.......STSLIB.004 Comment Record FILE HEADER FILE NUMBER: 5 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 6 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH RPM 8425.5 9999.0 ROP 8425.5 10053.5 RPX 8425.5 9999.0 RPS 8425.5 9999.0 RPD 8425.5 9999.0 GR 8425.5 9992.0 FET 8425.5 9999.0 LOG HEADER DATA DATE LOGGED: 28-MAR-06 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 66.37 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT) 10053.0 TOP LOG INTERVAL (FT) 8425.0 BOTTOM LOG INTERVAL (FT) 10053.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 85.2 MAXIMUM ANGLE: 93.2 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 135134 EWR4 Electromag Resis. 4 73634 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) 6.750 DRILLER'S CASING DEPTH (FT) 6522.0 BOREHOLE CONDITIONS MUD TYPE: Mineral Oil Base MUD DENSITY (LB/G): 8.80 MUD VISCOSITY (S) 63.0 MUD PH: .0 MUD CHLORIDES (PPM): 18500 FLUID LOSS (C3) 3.0 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT) .000 .0 MUD AT MAX CIRCULATING TERMPERATURE: .000 114.0 MUD FILTRATE AT MT: .000 .0 MUD CAKE AT MT: .000 .0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format Specification ~ord • Data Record Type ..................0 Data Specification Block Type.....0 Logging Direction .................Down Optical log depth units...........Feet Data Reference Point ..............Undefined Frame Spacing .....................60 .lIN Max frames per record .............Undefined Absent value ......................-999 Depth Units ....................... .Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 RPD MWD060 OHMM 4 1 68 4 2 RPM MWD060 OHMM 4 1 68 8 3 RPS MWD060 OHMM 4 1 68 12 4 RPX MWD060 OHMM 4 1 68 16 5 FET MWD060 HOUR 4 1 68 20 6 GR MWD060 API 4 1 68 24 7 ROP MWD060 FT/H 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 8425.5 10053.5 9239.5 3257 8425.5 10053.5 RPD MWD060 OHMM 5.3 87.32 17.635 3148 8425.5 9999 RPM MWD060 OHMM 5.08 2000 18.7419 3148 8425.5 9999 RPS MWD060 OHMM 4.98 2000 17.1398 3148 8425.5 9999 RPX MWD060 OHMM 4.62 2000 16.2949 3148 8425.5 9999 FET MWD060 HOUR 0.26 16.15 0.62621 3148 8425.5 9999 GR MWD060 API 51.74 118.61 79.303 3134 8425.5 9992 ROP MWD060 FT/H 0.52 1349.87 173.726 3257 8425.5 10053.5 First Reading For Entire File..........8425.5 Last Reading For Entire File...........10053.5 File Trailer Service name .............STSLIB.005 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/06/20 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.006 Physical EOF Tape Trailer Service name .............LISTPE Date .....................06/06/20 Origin ...................STS Tape Name ................UNKNOWN Continuation Number......01 Next Tape Name...........UNKNOWN Comments .................STS LIS Reel Trailer Writing Library. Scientific Technical Services Service name .............LISTPE Date .....................06/06/20 Origin ...................STS Reel Name ................UNKNOWN Continuation Number......01 Next Reel Name.........~KNOWN • Comments .................STS LIS Writing Library. Scientific Technical Services Physical EOF Physical EOF End Of LIS File • _ ~o(a-o1~~~3991 Sperry-Sun Dr~ing Services LIS Scan Utility $Revision: 3 $ LisLib $Revision: 4 $ Wed Jun 21 16:01:55 2006 Reel Header Service name .............LISTPE Date .....................06/06/21 Origin ...................STS Reel Name ................UNKNOWN Continuation Number......01 Previous Reel Name.......UNKNOWN Comments .................STS LIS Writing Library. Tape Header Service name .............LISTPE Date .....................06/06/21 Origin ...................STS Tape Name ................UNKNOWN Continuation Number......01 Previous Tape Name.......UNKNOWN Comments .................STS LIS Writing Library Physical EOF Comment Record TAPE HEADER west Sak MWD/MAD LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION • Scientific Technical Services Scientific Technical Services 1J-152 PB2 500292329871 ConocoPhillips Alaska, Inc. Sperry Drilling Services 21-JUN-06 MWD RUN 3 MWD RUN 4 MWD RUN 5 W-0004263658 W-0004263658 W-0004263658 T. GALVIN T. GALVIN T. GALVIN D. GLADDEN M. THORTON M. THORTON SECTION: 35 TOWNSHIP: 11N RANGE: l0E FNL: FSL: 2191 FEL: 2582 FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: 109.00 GROUND LEVEL: 81.00 WELL CASING RECORD OPEN HOLE CASING BIT SIZE (IN) SIZE (IN) 1ST STRING 9.875 10.750 2ND STRING 6.750 7.875 3RD STRING PRODUCTION STRING DRILLERS DEPTH (FT) 2774.0 6522.0 REMARKS: • • 1. ALL DEPTHS ARE MEASURED DEPTHS UNLESS OTHERWISE NOTED. THESE DEPTHS ARE BIT DEPTHS. 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTHS (TVD). 3. THIS WELL IS AN OPEN-HOLE SIDETRACK EXITING THE 1J-152 PB1 WELLBORE AT 6811'MD/3631'TVD. 4. MWD RUNS 1 & 2 WERE DIRECTIONAL ONLY - NO DATA ARE PRESENTED. 5. MWD RUNS 3-5 COMPRISED DIRECTIONAL, DUAL GAMMA RAY (DGR) UTILIZING GEIGER-MUELLER TUBE DETECTORS, ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4), AND PRESSURE WHILE DRILLING (PWD). MWD RUNS 4,5 ALSO INCLUDED 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 (SDS) MWD DATA ARE CONSIDERED PDC. 7. MWD RUNS 1-5 REPRESENT WELL 1J-152 PB2 WITH API#: 50-029-23298-71. THI5 WELL REACHED A TOTAL DEPTH (TD) OF 9343'MD/3650'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). SLIDE = NON-ROTATED INTERVALS REFLECTING BIT DEPTHS. File Header Service name .............STSLIB.001 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/06/21 Maximum Physical Record..65535 File Type ................LO Previous File Name.......STSLIB.000 Comment Record FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE START DEPTH GR 2741.5 FET 2760.0 RPD 2760.0 RPS 2760.0 all bit runs merged. STOP DEPTH 9282.5 9289.5 9289.5 9289.5 0 RPM 276 9289.5 RPX 2760.0 9289.5 ROP 2787.5 9343.0 BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH MERGED DATA SOURCE PBU TOOL CODE MWD MWD MWD BIT RUN NO MERGE TOP MERGE BASE 3 2741.5 6532.0 4 6532.0 6811.0 5 6811.5 9343.5 REMARKS: MERGED MAIN PASS. Data Format Specification Record Data Record Type ..................0 Data Specification Block Type.....0 Logging Direction .................Down Optical log depth units...........Feet Data Reference Point ..............Undefined Frame Spacing .....................60 .lIN Max frames per record .............Undefined Absent value ......................-999 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 RPD MWD OHMM 4 1 68 4 2 RPM MWD OHMM 4 1 68 8 3 RPS MWD OHMM 4 1 68 12 4 RPX MWD OHMM 4 1 68 16 5 FET MWD HOUR 4 1 68 20 6 GR MWD API 4 1 68 24 7 ROP MWD FT/H 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 2741.5 9343 6042.25 13204 2741.5 9343 RPD MWD OHMM 0.31 2000 29.8379 13060 2760 9289.5 RPM MWD OHMM 0.06 2000 23.7362 13060 2760 9289.5 RPS MWD OHMM 2.5 2000 16.7747 13060 2760 9289.5 RPX MWD OHMM 3.05 1859.83 15.2297 13060 2760 9289.5 FET MWD HOUR 0.12 68.15 1.59228 13060 2760 9289.5 GR MWD API 26.27 128.14 74.9876 13083 2741.5 9282.5 ROP MWD FT/H 0.14 653.26 150.529 13112 2787.5 9343 First Reading For Entire File..........2741.5 Last Reading For Entire File...........9343 File Trailer Service name .............STSLIB.001 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/06/21 Maximum Physical Record..65535 File Type ................LO Next File Name.........~SLIB.002 Physical EOF File Header Service name .............STSLIB.002 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/06/21 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: 3 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 2741.5 6485.5 FET 2760.0 6478.0 RPX 2760.0 6478.0 RPS 2760.0 6478.0 RPM 2760.0 6478.0 RPD 2760.0 6478.0 ROP 2787.5 6532.0 LOG HEADER DATA DATE LOGGED: 23-MAR-06 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 66.37 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT) 6532.0 TOP LOG INTERVAL (FT) 2787.0 BOTTOM LOG INTERVAL (FT) 6532.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 53.5 MAXIMUM ANGLE: 84.9 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 119546 EWR4 ELECTROMAG. RESIS. 4 105242 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) 9.875 DRILLER'S CASING DEPTH (FT) 2774.0 BOREHOLE CONDITIONS MUD TYPE: Other MUD DENSITY (LB/G) 9.00 MUD VISCOSITY (S) 60.0 MUD PH: 9.9 MUD CHLORIDES (PPM): 300 FLUID LOSS (C3) 4.8 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT) 2.800 65.0 MUD AT MAX CIRCULATING TERMPERATURE: 1.880 100.0 MUD FILTRATE AT M~ MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format Specification Record Data Record Type ..................0 Data Specification Block Type.....0 Logging Direction .................Down Optical log depth units...........Feet Data Reference Point ..............Undefined Frame Spacing .....................60 .lIN Max frames per record .............Undefined Absent value ......................-999 Depth Units ....................... Datum Specification Block sub-type...0 2.350 ~0 2.700 65.0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 RPD MWD030 OHMM 4 1 68 4 2 RPM MWD030 OHMM 4 1 68 8 3 RPS MWD030 OHMM 4 1 68 12 4 RPX MWD030 OHMM 4 1 68 16 5 FET MWD030 HOUR 4 1 68 20 6 GR MWD030 API 4 1 68 24 7 ROP MWD030 FT/H 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 2741.5 6532 4636.75 7582 2741.5 6532 RPD MWD030 OHMM 1.71 2000 21.5643 7437 2760 6478 RPM MWD030 OHMM 2.2 1597.77 15.7237 7437 2760 6478 RPS MWD030 OHMM 2.5 1922.05 14.8228 7437 2760 6478 RPX MWD030 OHMM 3.05 1353.33 13.1062 7437 2760 6478 FET MWD030 HOUR 0.12 68.15 1.39653 7437 2760 6478 GR MWD030 API 26.27 125.3 71.0299 7489 2741.5 6485.5 ROP MWD030 FT/H 0.14 653.26 135.562 7490 2787.5 6532 First Reading For Entire File..........2741.5 Last Reading For Entire File...........6532 File Trailer Service name .............STSLIB.002 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/06/21 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.003 Physical EOF File Header Service name...........~TSLIB.003 • Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/06/21 Maximum Physical Record..65535 File Type ................LO Previous File Name.......STSLIB.002 Comment Record FILE HEADER FILE NUMBER: 3 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 4 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH FET 6478.5 6811.0 RPS 6478.5 6811.0 RPX 6478.5 6811.0 RPM 6478.5 6811.0 RPD 6478.5 6811.0 GR 6486.0 6811.0 ROP 6532.5 6811.0 LOG HEADER DATA DATE LOGGED: 25-MAR-06 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 66.37 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT) 6811.0 TOP LOG INTERVAL (FT) 6532.0 BOTTOM LOG INTERVAL (FT) 6811.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 84.0 MAXIMUM ANGLE: 92.6 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 135134 EWR4 Electromag Resis. 4 73634 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) 6.750 DRILLER'S CASING DEPTH (FT) 6522.0 BOREHOLE CONDITIONS MUD TYPE: Mineral Oil Base MUD DENSITY (LB/G) 8.80 MUD VISCOSITY (S) 70.0 MUD PH: .0 MUD CHLORIDES (PPM): 20500 FLUID LOSS (C3) 3.2 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT) .000 .0 MUD AT MAX CIRCULATING TERMPERATURE: .000 104.0 MUD FILTRATE AT MT: .000 .0 MUD CAKE AT MT: .000 .0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): ~ s TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format Specification Record Data Record Type ..................0 Data Specification Block Type.....0 Logging Direction .................Down Optical log depth units...........Feet Data Reference Point ..............Undefined Frame Spacing .....................60 .lIN Max frames per record .............Undefined Absent value ......................-999 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 RPD MWD040 OHMM 4 1 68 4 2 RPM MWD040 OHMM 4 1 68 8 3 RPS MWD040 OHMM 4 1 68 12 4 RPX MWD040 OHMM 4 1 68 16 5 FET MWD040 HOUR 4 1 68 20 6 GR MWD040 API 4 1 68 24 7 ROP MWD040 FT/H 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 6478.5 6811 6644.75 666 6478.5 6811 RPD MWD040 OHMM 0.31 2000 215.191 666 6478.5 6811 RPM MWD040 OHMM 0.06 2000 163.601 666 6478.5 6811 RPS MWD040 OHMM 11.21 2000 39.0852 666 6478.5 6811 RPX MWD040 OHMM 5.76 18 59.83 31.8651 666 6478.5 6811 FET MWD040 HOUR 0.22 59.86 10.3876 666 6478.5 6811 GR MWD040 API 39.64 89.21 65.2787 651 6486 6811 ROP MWD040 FT/H 11.6 2 94.97 204.845 558 6532.5 6811 First Reading For Entire File..........6478.5 Last Reading For Entire File...........6811 File Trailer Service name .............STSLIB.003 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/06/21 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.......06/06/21 Maximum Physical Record..65535 File Type ................LO Previous File Name.......STSLIB.003 • ~ Comment Record FILE HEADER FILE NUMBER: 4 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 5 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH RPM 6811.5 9289.5 RPX 6811.5 9289.5 ROP 6811.5 9343.5 RPD 6811.5 9289.5 GR 6811.5 9282.5 FET 6811.5 9289.5 RPS 6811.5 9289.5 LOG HEADER DATA DATE LOGGED: 27-MAR-06 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 66.37 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT) 9343.0 TOP LOG INTERVAL (FT) 6811.0 BOTTOM LOG INTERVAL (FT) 9343.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 83.6 MAXIMUM ANGLE: 93.7 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 135134 EWR4 Electromag Resis. 4 73634 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) 6.750 DRILLER'S CASING DEPTH (FT) 6522.0 BOREHOLE CONDITIONS MUD TYPE: Mineral Oil Base MUD DENSITY (LB/G) ..8.80 MUD VISCOSITY (S) 63.0 MUD PH: .0 MUD CHLORIDES (PPM): 18500 FLUID LOSS (C3): 3.0 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT) .000 .0 MUD AT MAX CIRCULATING TERMPERATURE: .000 111.0 MUD FILTRATE AT MT: .000 .0 MUD CAKE AT MT: .000 .0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ) ' REMARKS: Data Format Specification ~ord Data Record Type ..................0 Data Specification Block Type.....0 Logging Direction .................Down Optical log depth units...........Feet Data Reference Point ..............Undefined Frame Spacing .....................60 .lIN Max frames per record .............Undefined Absent value ......................-999 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 RPD MWD050 OHMM 4 1 68 4 2 RPM MWD050 OHMM 4 1 68 8 3 RPS MWD050 OHMM 4 1 68 12 4 RPX MWD050 OHMM 4 1 68 16 5 FET MWD050 HOUR 4 1 68 20 6 GR MWD050 API 4 1 68 24 7 ROP MWD050 FT/H 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 6811.5 9343.5 8077.5 5065 6811.5 9343.5 RPD MWD050 OHMM 4.55 63.06 17.3476 4957 6811.5 9289.5 RPM MWD050 OHMM 4.07 81.85 16.9658 4957 6811.5 9289.5 RPS MWD050 OHMM 3.81 59.98 16.7055 4957 6811.5 9289.5 RPX MWDO50 OHMM 3.73 72.37 16.1805 4957 6811.5 9289.5 FET MWD050 HOUR 0.25 13.1 0.704257 4957 6811.5 9289.5 GR MWD050 API 49.78 128.14 82.2623 4943 6811.5 9282.5 ROP MWD050 FT/H 5.19 581.48 166.659 5065 6811.5 9343.5 First Reading For Entire File..........6811.5 Last Reading For Entire File...........9343.5 File Trailer Service name .............STSLIB.004 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/06/21 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.005 Physical EOF Tape Trailer Service name .............LISTPE Date .....................06/06/21 Origin ...................STS Tape Name ................UNKNOWN Continuation Number......01 Next Tape Name...........UNKNOWN Comments .................STS LIS Reel Trailer Writing Library. Scientific Technical Services Service name .............LISTPE Date .....................06/06/21 Origin ...................STS Reel Name ................UNKNOWN Continuation Number......01 Next Reel Name.........~KNOWN • Comments .................STS LIS Writing Library. Scientific Technical Services Physical EOF Physical EOF End Of LIS File aoC~ -ol ~ ~ r 3g9 f Sperry-Sun Dr~ing Services LIS Scan Utility $Revision: 3 $ LisLib $Revision: 4 $ Wed Jun 21 15:49:25 2006 Reel Header Service name .............LISTPE Date .....................06/06/21 Origin ...................STS Reel Name ................UNKNOWN Continuation Number......01 Previous Reel Name.......UNKNOWN Comments .................STS LIS Writing Library. Tape Header Service name .............LISTPE Date .....................06/06/21 Origin ...................STS Tape Name ................UNKNOWN Continuation Number......01 Previous Tape Name.......UNKNOWN Comments .................STS LIS Writing Library Physical EOF • Scientific Technical Services Scientific Technical Services Comment Record TAPE HEADER West Sak MWD/MAD LOGS WELL NAME: 1J-152 PB1 API NUMBER: 500292329870 OPERATOR: ConocoPhillips Alaska, Inc. LOGGING COMPANY: Sperry Drilling Services TAPE CREATION DATE: 21-JUN-06 JOB DATA MWD RUN 3 MWD RUN 4 JOB NUMBER: W-0004263658 W-0004263658 LOGGING ENGINEER: T. GALVIN T. GALVIN OPERATOR WITNESS: D. GLADDEN M. THORTON SURFACE LOCATION SECTION: 35 TOWNSHIP: 11N RANGE: l0E FNL: FSL: 2191 FEL: 2582 FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: 109.00 GROUND LEVEL: 81.00 WELL CASING RECORD OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 1ST STRING 9.875 10.750 2774.0 2ND STRING 6.750 7.875 6522.0 3RD STRING PRODUCTION STRING REMARKS: ~ • 1. ALL DEPTHS ARE MEASURED DEPTHS UNLESS OTHERWISE NOTED. THESE DEPTHS ARE BIT DEPTHS. 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTHS (TVD). 3. MWD RUNS 1 & 2 WERE DIRECTIONAL ONLY - NO DATA ARE PRESENTED. 4. MWD RUNS 3 AND 4 COMPRISED DIRECTIONAL, DUAL GAMMA RAY (DGR) UTILIZING GEIGER-MUELLER TUBE DETECTORS, ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4), AND PRESSURE WHILE DRILLING (PWD) MWD RUN 4 ALSO INCLUDED AT-BIT INCLINATION (ABI). 5. DEPTH SHIFTING OF MWD DATA WAS WAIVED PER E-MAIL, DATED 12/16/04, FROM M. WERNER (CPAI) TO R. KALISH (SDS) MWD DATA ARE CONSIDERED PDC. 6. MWD RUNS 1-4 REPRESENT WELL 1J-152 PB1 WITH API#: 50-029-23298-70. THIS WELL REACHED A TOTAL DEPTH (TD) OF 7646'MD/3668'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). SLIDE = NON-ROTATED INTERVALS REFLECTING BIT DEPTHS. File Header Service name .............STSLIB.001 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/06/21 Maximum Physical Record..65535 File Type ................LO Previous File Name.......STSLIB.000 Comment Record FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE START DEPTH STOP DEPTH GR 2741.5 7585.0 RPD 2760.0 7592.0 FET 2760.0 7592.0 RPS 2760.0 7592.0 RPM 2760.0 7592.0 RPX 2760.0 7592.0 ROP 2787.5 7646.0 BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH BASELINE DEPTH MERGED DATA SOURCE PBU TOOL CODE MWD MWD BIT RUN NO MERGE TOP MERGE BASE 3 2741.5 6532.0 4 6532.0 7646.5 REMARKS: MERGED MAIN PASS. Data Format Specification Record Data Record Type ..................0 Data Specification Block Type.....0 Logging Direction .................Down Optical log depth units...........Feet Data Reference Point ..............Undefined Frame Spacing .....................60 .lIN Max frames per record .............Undefined Absent value ......................-999 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel • DEPT FT 4 1 68 0 1 RPD MWD OHMM 4 1 68 4 2 RPM MWD OHMM 4 1 68 8 3 RPS MWD OHMM 4 1 68 12 4 RPX MWD OHMM 4 1 68 16 5 FET MWD HOUR 4 1 68 20 6 GR MWD API 4 1 68 24 7 ROP MWD FT/H 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 2741.5 764 6 5193.75 9810 2741.5 7646 RPD MWD OHMM 0.31 2000 33.912 9665 2760 7592 RPM MWD OHMM 0.06 2000 25.6476 9665 2760 7592 RPS MWD OHMM 2.5 2000 15.9563 9665 2760 7592 RPX MWD OHMM 3.05 1859.83 14.0896 9665 2760 7592 FET MWD HOUR 0.12 68.15 1.88816 9665 2760 7592 GR MWD API 26.27 125.3 72.9802 9688 2741.5 7585 ROP MWD FT/H 0.14 653.26 147 9718 2787.5 7646 First Reading For Entire File..........2741.5 Last Reading For Entire File...........7646 File Trailer Service name .............STSLIB.001 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/06/21 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.......06/06/21 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: 3 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 2741.5 6485.5 FET 2760.0 6478.0 RPX 2760.0 6478.0 RPS 2760.0 6478.0 RPM 2760.0 6478.0 RPD 2760.0 6478.0 ROP 2787.5 6532.0 LOG HEADER DATA DATE LOGGED: 23-MAR-06 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 66.37 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT) 6532.0 TOP LOG INTERVAL (FT) 2787.0 BOTTOM LOG INTERVAL (FT) 6532.0 $IT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 53.5 MAXIMUM ANGLE: 84.9 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 119546 EWR4 ELECTROMAG. RESIS. 4 105242 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): 9.875 2774.0 BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3) RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: Other 9.00 60.0 9.9 300 4.8 2.800 65.0 1.880 100.0 2.350 65.0 2.700 65.0 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.....0 Logging Direction .................Down Optical log depth units...........Feet Data Reference Point ..............Undefined Frame Spacing .....................60 .lIN Max frames per record .............Undefined Absent value ......................-999 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel r\ LJ DEPT FT 4 1 68 0 1 RPD MWD030 OHMM 4 1 68 4 2 RPM MWD030 OHMM 4 1 68 8 3 RPS MWD030 OHMM 4 1 68 12 4 RPX MWD030 OHMM 4 1 68 16 5 FET MWD030 HOUR 4 1 68 20 6 GR MWD030 API 4 1 68 24 7 ROP MWD030 FT/H 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 2741.5 6532 4636.75 7582 2741.5 6532 RPD MWD030 OHMM 1.71 2000 21.5643 7437 2760 6478 RPM MWD030 OHMM 2.2 1597.77 15.7237 7437 2760 6478 RPS MWD030 OHMM 2.5 1922.05 14.8228 7437 2760 6478 RPX MWD030 OHMM 3.05 1353.33 13.1062 7437 2760 6478 FET MWD030 HOUR 0.12 68.15 1.39653 7437 2760 6478 GR MWD030 API 26.27 125.3 71.0299 7489 2741.5 6485.5 ROP MWD030 FT/H 0.14 653.26 135.562 7490 2787.5 6532 First Reading For Entire File..........2741.5 Last Reading For Entire File...... ......6532 File Trailer Service name .............STSLIB.002 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/06/21 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.......06/06/21 Maximum Physical Record..65535 File Type .............. Previous File Name.......STSLIB.002 Comment Record FILE HEADER FILE NUMBER: 3 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 4 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH RPX 6478.5 7592.0 RPD 6478.5 7592.0 RPM 6478.5 7592.0 FET 6478.5 7592.0 RPS 6478.5 7592.0 GR 6486.0 7585.0 ROP 6532.5 7646.5 LOG HEADER DATA DATE LOGGED: 25-MAR-06 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 66.37 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT) 7646.0 TOP LOG INTERVAL (FT) 6532.0 BOTTOM LOG INTERVAL (FT) 7646.0 BIT ROTATING SPEED (RPM) HOLE INCLINATION (DEG MINIMUM ANGLE: 84.0 MAXIMUM ANGLE: 92.6 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 135134 EWR4 Electromag Resis. 4 73634 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) 6.750 DRILLER'S CASING DEPTH (FT) 6522.0 BOREHOLE CONDITIONS MUD TYPE: Mineral Oil Base MUD DENSITY (LB/G): 8.80 MUD VISCOSITY (S): 70.0 MUD PH: .0 MUD CHLORIDES (PPM): 20500 FLUID LOSS (C3) 3.2 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT) .000 .0 MUD AT MAX CIRCULATING TERMPERATURE: .000 104.0 MUD FILTRATE AT MT: .000 .0 MUD CAKE AT MT: .000 .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.....0 Logging Direction .................Down Optical log depth units...........Feet Data Reference Point ..............Undefined Frame Spacing .....................60 .lIN Max frames per record .............Undefined Absent value ......................-999 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel • DEPT FT 4 1 68 0 1 RPD MWD040 OHMM 4 1 68 4 2 RPM MWD040 OHMM 4 1 68 8 3 RPS MWD040 OHMM 4 1 68 12 4 RPX MWD040 OHMM 4 1 68 16 5 FET MWD040 HOUR 4 1 68 20 6 GR MWD040 API 4 1 68 24 7 ROP MWD040 FT/H 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 6478.5 7646.5 7062.5 2337 6478.5 7646.5 RPD MWD040 OHMM 0.31 2000 75.128 2228 6478.5 7592 RPM MWD040 OHMM 0.06 2000 58.7731 2228 6478.5 7592 RPS MWD040 OHMM 3.41 2000 19.7397 2228 6478.5 7592 RPX MWD040 OHMM 3.34 1859.83 17.3718 2228 6478.5 7592 FET MWD040 HOUR 0.22 59.86 3.5292 2228 6478.5 7592 GR MWD040 API 39.64 122.98 79.6221 2199 6486 7585 ROP MWD040 FT/H 11.6 404.19 185.396 2229 6532.5 7646.5 First Reading For Entire File..........6478.5 Last Reading For Entire File...........7646.5 File Trailer Service name .............STSLIB.003 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/06/21 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.004 Physical EOF Tape Trailer Service name .............LISTPE Date .....................06/06/21 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 .....................06/06/21 Origin ...................ST5 Reel Name ..............~KNOWN • Continuation Number......01 Next Reel Name...........UNKNOWN Comments .................ST5 LIS Writing Library. Scientific Technical Services Physical EOF Physical EOF End Of LIS File
