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Home My WebLink About205-060Originated: Delivered to:1-Jul-21Halliburton Alaska Oil and Gas Conservation Comm.Wireline & Perforating Attn.: Natural Resource TechnicianAttn: Fanny Haroun 333 West 7th Avenue, Suite 1006900 Arctic Blvd. Anchorage, Alaska 99501Anchorage, Alaska 99518Office: 907-275-2605FRS_ANC@halliburton.comThe technical data listed below is being submitted herewith. Please address any problems orconcerns to the attention of the sender aboveWELL NAME API # SERVICE ORDER # FIELD NAME JOB TYPE DATA TYPE LOGGING DATE PRINTS # DIGITAL #1 1A-24 50-029-22984-00 907203651 Kuparuk River Packer Setting Record Field- Final 11-Jun-21 0 12 1E-34 50-029-22805-00 n/a Kuparuk River Leak Detect Log Field- Final 27-Jun-21 0 13 1E-34 50-029-22805-00 n/a Kuparuk River Plug Setting Record Field- Final 27-Jun-21 0 14 1J-168 50-029-23260-00 907188201 Kuparuk River Packer Setting Record Field- Final 3-Jun-21 0 15 2M-33 50-103-20240-00 907209681 Kuparuk River Packer Setting Record Field- Final 17-Jun-21 0 16 2N-347 50-103-20337-00 906961909 Kuparuk River Plug Setting Record Field- Final 14-Jun-21 0 17 2T-207 50-103-20287-00 907201320 Kuparuk River Leak Detect Log Field- Final 9-Jun-21 0 18 2T-207 50-103-20287-00 907199652 Kuparuk River Multi Finger Caliper Field & Processed 9-Jun-21 0 19 2V-03 50-029-21040-00 907177252 Kuparuk River Plug Setting Record Field- Final 27-May-21 0 110 3F-08 50-029-21464-00 907196137 Kuparuk River Plug Setting Record Field- Final 10-Jun-21 0 1PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF:Fanny Haroun, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518FRS_ANC@halliburton.comDate:Signed:Transmittal Date:07/01/2021Wd͗ϮϬϱϬϲϬϬͲ^Ğƚ͗ϯϱϯϮϬBy Abby Bell at 3:53 pm, Jul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y Samantha Carlisle at 8:32 am, Jun 29, 2021 Stefan Weingarth Digitally signed by Stefan Weingarth Date: 2021.06.28 17:03:02 -08'00' DSR-6/29/21 West Sak "!"#$#*""*#=>" SFD 6/29/2021 SFD 6/29/2021 5!7#0/ "# RBDMS HEW 6/30/2021 VTL 8/9/21 !"# $ %&!! #! ' ( !%!#) #!#!# ! !!!# #)* !# !!! # ##!"' ( ###!!! # ' + ( (! !"!##)))!!"#&! ,-#*!#!!' 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Last Tag Annotation Depth (ftKB) End Date Wellbore Last Mod By Last Tag: CTMD-BLUE FLAG 8,050.0 5/7/2016 1J-168 pproven Last Rev Reason Annotation End Date Wellbore Last Mod By Rev Reason: Set OV & INSTALLED PATCH 6/4/2021 1J-168 zembaej Casing Strings Casing Description CONDUCTOR Insulated OD (in) 16 ID (in) 15.06 Top (ftKB) 26.0 Set Depth (ftKB) 80.0 Set Depth (TVD) … 80.0 Wt/Len (l… 62.50 Grade H-40 Top Thread WELDED Casing Description SURFACE OD (in) 10 3/4 ID (in) 9.95 Top (ftKB) 30.0 Set Depth (ftKB) 3,693.9 Set Depth (TVD) … 2,116.4 Wt/Len (l… 45.50 Grade L-80 Top Thread BTC Casing Description INTERMEDIATE OD (in) 7 5/8 ID (in) 6.87 Top (ftKB) 26.3 Set Depth (ftKB) 8,224.0 Set Depth (TVD) … 3,466.1 Wt/Len (l… 29.70 Grade L-80 Top Thread BTCM Casing Description D LINER LEM OD (in) 4 1/2 ID (in) 3.96 Top (ftKB) 6,706.8 Set Depth (ftKB) 7,128.0 Set Depth (TVD) … 3,291.2 Wt/Len (l… 12.60 Grade L-80 Top Thread IBTM Liner Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Com Nominal ID (in) 6,706.8 3,194.6 75.49 SLEEVE 5.75" ID Tie back sleeve 5.750 6,717.8 3,197.4 75.48 PACKER 5.5"x7.625" "HRD" ZXP Liner Top Packer w/ hold down slips 4.960 6,725.5 3,199.3 75.48 SBE 190-47 Casing Seal Bore Recepetacle 6.30" OD 4.750 6,760.4 3,208.1 75.23 NIPPLE DB Nipple 3.75" ID, 4.5" IBTM Box x Pin3.750 6,773.7 3,211.5 75.11 HANGER LEM Above Hook Hanger 3.970 6,780.5 3,213.3 75.05 HANGER LEM Below Hook Hanger 3.930 7,124.8 3,290.7 80.14 SEAL ASSY 190-47 Non-Locating Seal Assembly 3.880 Casing Description B LINER LEM OD (in) 4 1/2 ID (in) 3.96 Top (ftKB) 7,096.7 Set Depth (ftKB) 7,299.9 Set Depth (TVD) … 3,320.6 Wt/Len (l… 12.60 Grade L-80 Top Thread IBT Liner Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Com Nominal ID (in) 7,096.7 3,285.8 79.91 PACKER ZXP LINER TOP PACKER 5.510 7,115.7 3,289.1 80.14 SBR CASING 109-47 SEAL BORE RECEPTACLE 4.750 7,134.9 3,292.4 80.15 XO BUSHING 4.750 7,143.9 3,293.9 80.15 HANGER LEM ABOVE HOOK HANGER 3.970 7,154.6 3,295.8 80.15 HANGER LEM BELOW HOOK HANGER, ISO SLEEVE 3.69"X19' SET AT 7158 3.930 7,221.5 3,307.2 80.17 NIPPLE CAMCO DB-6 NIPPLE 3.563 7,296.6 3,320.0 80.22 SEAL ASSY BAKER SEAL ASSEMBLY 3.880 Casing Description B LINER HH OD (in) 4 1/2 ID (in) 3.96 Top (ftKB) 7,147.9 Set Depth (ftKB) 7,402.8 Set Depth (TVD) … 3,337.5 Wt/Len (l… 12.60 Grade L-80 Top Thread IBT Liner Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Com Nominal ID (in) 7,147.9 3,294.6 80.15 HANGER BAKER MOVEL B-1 HOOK HANGER 5.300 7,170.8 3,298.5 80.15 XO BUSHING CROSSOVER BUSHING 3.960 7,241.5 3,310.6 80.18 ECP BAKER PAYZONE EXTERNAL CASING PACKER 3.950 7,359.7 3,330.5 80.60 BENT JT 3.960 Casing Description A-SAND LINER OD (in) 4 1/2 ID (in) 3.96 Top (ftKB) 7,245.8 Set Depth (ftKB) 12,975.0 Set Depth (TVD) … 3,651.4 Wt/Len (l… 12.60 Grade L-80 Top Thread IBT Liner Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Com Nominal ID (in) 7,245.8 3,311.4 80.18 PACKER "HRD" ZXP Liner Top Packer 5.5" X 7.6"5.500 7,264.9 3,314.6 80.19 NIPPLE "RS" Packoff Seal Nipple 5.5" 4.875 7,267.7 3,315.1 80.20 HANGER FlexLock Liner Hanger 5.5" X 7.6" 4.853 7,277.6 3,316.8 80.20 SBE 190-47 Casing Seal Bore Ext. 4.75"ID x 6.25" OD 4.750 7,297.0 3,320.1 80.22 XO BUSHING XO Bushing 3.92" ID, 6.02 OD 3.920 Tubing Strings Tubing Description TUBING WO String Ma… 4 1/2 ID (in) 3.96 Top (ftKB) 22.5 Set Depth (ft… 6,731.2 Set Depth (TVD) (… 3,200.7 Wt (lb/ft) 12.60 Grade L-80 Top Connection IBTM Completion Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Com Nominal ID (in) 22.5 22.5 0.07 HANGER Vetco Gray Hanger 11" x 4.5" w/ 4.909" MCA Top Conn. Made up on full 3.900 499.7 499.2 5.95 NIPPLE 3.875" 'DB' Nipple 3.875 6,649.1 3,180.2 75.50 NIPPLE 3.812" 'DB' Nipple 3.812 6,650.6 3,180.5 75.50 GAUGE Baker Guardian Gauge 3.958 6,702.8 3,193.6 75.49 LOCATOR Locator Sub 3.990 6,703.9 3,193.9 75.49 SEAL ASSY Bonded Seal Assembly w/ Full Mule Shoe w/ 2' space out 3.870 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Des Com Run Date ID (in) SN 6,194.0 3,047.6 67.91 PATCH-UPPER PACKER 3.76" P2P @ 6187,0' RKB (ME) (OAL = 4.89' ) 6/3/2021 2.000 CPP45003 6,198.3 3,049.2 68.10 SPACER PIPE & ANCHOR LATCH SPACER PIPE & ANCHOR LATCH MADE UP TO UPPER PACKER 6/3/2021 1.995 CPAL45010 6,207.0 3,052.4 68.47 LEAK LEAK FOUND AT 6207' AT WHAT APPEARS TO BE THE POCKET OF THE GAS LIFT MANDREL. LOG CORRELATED TO TUBING DETAIL RECORD DATED 6 SEP 2008 1/13/2015 0.000 6,217.0 3,056.0 68.89 PATCH-LOWER PACKER 3.76" P2P @ 6220' RKB (ME) (OAL = 4.89' ) 6/3/2021 2.000 CPP45023 1J-168, 6/22/2021 10:17:34 AM Vertical schematic (actual) A-SAND LINER; 7,245.8- 12,975.0 SLOTS; 12,912.0-12,942.0 SLOTS; 11,464.0-12,631.0 SLOTS; 10,512.0-11,248.0 SLOTS; 10,170.0-10,263.0 SLOTS; 9,582.0-9,861.0 SLOTS; 8,876.0-9,274.0 SLOTS; 8,474.0-8,659.0 INTERMEDIATE; 26.3-8,224.0 B LINER HH; 7,147.9-7,402.8 B LINER LEM; 7,096.7-7,299.9 D LINER LEM; 6,706.8-7,128.0 D-SAND LINER; 6,780.5- 12,942.7 GAUGE; 6,650.6 PATCH-LOWER PACKER; 6,217.0 SPACER PIPE & ANCHOR LATCH; 6,198.3 GAS LIFT; 6,203.2 PATCH-UPPER PACKER; 6,194.0 GAS LIFT; 4,210.6 SURFACE; 30.0-3,693.9 NIPPLE; 499.7 CONDUCTOR Insulated; 26.0- 80.0 KUP PROD KB-Grd (ft) 31.01 Rig Release Date 9/26/2005 1J-168 ... TD Act Btm (ftKB) 12,995.0 Well Attributes Field Name WEST SAK Wellbore API/UWI 500292326000 Wellbore Status PROD Max Angle & MD Incl (°) 93.12 MD (ftKB) 11,172.18 WELLNAME WELLBORE1J-168 Annotation Last WO: End Date 9/10/2008 H2S (ppm) 60 Date 12/16/2013 Comment SSSV: NIPPLE Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft )Type Com 8,474.0 8,659.0 3,477.2 3,481.3 WS A2, 1J-168 8/31/2005 32.0 SLOTS ALL SLOTS: Alternating slotted/solid pipe 0.125" x 2.5" x 32 spf @ 4 Circumferential adjacent rows, 3" Centers staggered 18°, 3 ft. non-slotted ends 8,876.0 9,274.0 3,489.7 3,502.9 WS A2, 1J-168 8/31/2005 32.0 SLOTS 9,582.0 9,861.0 3,512.1 3,533.6 WS A2, 1J-168 8/31/2005 32.0 SLOTS 10,170.0 10,263.0 3,558.1 3,564.8 WS A2, 1J-168 8/31/2005 32.0 SLOTS 10,512.0 11,248.0 3,581.5 3,574.0 WS A2, 1J-168 8/31/2005 32.0 SLOTS 11,464.0 12,631.0 3,564.9 3,609.0 WS A2, 1J-168 8/31/2005 32.0 SLOTS 12,912.0 12,942.0 3,642.9 3,646.6 WS A2, 1J-168 8/31/2005 32.0 SLOTS Mandrel Inserts St ati on N o/Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Make Model OD (in) Serv Valve Type Latch Type Port Size (in) TRO Run (psi) Run Date Com 1 4,210.6 2,303.9 69.39 Camco KBG-2- 1R 1 GAS LIFT OV BK 0.250 0.0 6/4/2021 2 6,203.2 3,051.0 68.31 Camco KBG-2- 1R 1 GAS LIFT OPEN OPEN 0.0 6/3/2021 Notes: General & Safety End Date Annotation 9/26/2005 NOTE: MULTI-LATERAL WELL: A-SAND (1J-168), B-SAND (1J-168L1), D-SAND (1J-168L2) 1J-168, 6/22/2021 10:17:35 AM Vertical schematic (actual) A-SAND LINER; 7,245.8- 12,975.0 SLOTS; 12,912.0-12,942.0 SLOTS; 11,464.0-12,631.0 SLOTS; 10,512.0-11,248.0 SLOTS; 10,170.0-10,263.0 SLOTS; 9,582.0-9,861.0 SLOTS; 8,876.0-9,274.0 SLOTS; 8,474.0-8,659.0 INTERMEDIATE; 26.3-8,224.0 B LINER HH; 7,147.9-7,402.8 B LINER LEM; 7,096.7-7,299.9 D LINER LEM; 6,706.8-7,128.0 D-SAND LINER; 6,780.5- 12,942.7 GAUGE; 6,650.6 PATCH-LOWER PACKER; 6,217.0 SPACER PIPE & ANCHOR LATCH; 6,198.3 GAS LIFT; 6,203.2 PATCH-UPPER PACKER; 6,194.0 GAS LIFT; 4,210.6 SURFACE; 30.0-3,693.9 NIPPLE; 499.7 CONDUCTOR Insulated; 26.0- 80.0 KUP PROD 1J-168 ... WELLNAME WELLBORE1J-168 i FOperations Performed: Depth Depth CONDUCTOR SURFACE INTERMEDIATE A -SAND LINER STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Pull Tubing❑ Suspend ❑ Perforate ❑ Other Stimulate ❑ Alter casing❑ Plug for Redrill ❑ erforate New Pool ❑ Repair Well ❑ Re-enter Susp Well ❑ ConocoPhillips Alaska, Inc. 4. well Class Before work: 5. Pern Development ❑' Exploratory ❑ P. 0. Box 100360, Anchorage, Stratigmphic❑ Service ❑ 6. API t Alaska 99510 Perforation depth: per N/A measured 12,995 feet Plugs true vertical 3,654 feet Junk measured PACKER - P2P PACKER feet Packer true vertical PACKER - P2P PACKER feet 3,049' TVD Length Size 6,221' MD MD 54 feet 16 6,718' MD 80' MD 3,664 feet 10 3/4 " _ 7,097' MD 3,694' MD 8,198 feet 75/811 8,224' MD 5,729 feet 4 1/2 " 12,975' MD Name and Number: Operations shutdown ❑ Change Approved Program ❑ Other: RPPG MBE TREATMENT❑+ 205-060 KRU 1J-168 River Field / West Sak Oil Pool measured None feet measured None feet measured 6199, 6221, 6718, 7097, 7246 true vertical 3049, 3057, 3197, 3286, 3311 TVD Burst 80' TVD 2116'TVD 3466' TVD 3651' TVD Collapse RECEIVE Measured depth: 8474-12942 feet UL ? , 2ul� True Vertical depth: 3477-3647 feet (size, grade, measured and true vertical depth) ' •®u c 4.5" L-80 6,731' MD „j 3,201' TVD and SSSV (type, measured and true vertical depth) PACKER - P2P PACKER PACKER - P2P PACKER 6,199' MD 3,049' TVD PACKER - HRD ZXP LINER TOP PKR 6,221' MD 3,057' TVD PACKER 7xP I Ini1=R 6,718' MD 3,197' TVD - TOP PKR PACKER xp _ 7,097' MD 3.286' TVD -HRD I IN R TOP PI. SSSV NONE 7 245' MD — _ — 3.311' TVD ulation or cement squeeze summary: treated (measured): NIA descriptions including volumes used and final pressure: Prior to well operation: 42 v 98911 Subsequent to operation: 102 861 ttaChments(requiretl p:�uC 25.07Q 25.071, 825.283) 15. Well Class after% Report of Well OperO Exploratory ❑ is of Logs and Surve❑ 16. Well Status after d and Electronic Fratimulation Data ❑ GSTOR ❑ hereby certify that the foregoing is true and correct to the best of my know) ized Name: John Peirce ized Title: Sr. Wells EEniliinerneer !zed Signature: � [ Dal Form 30-404 Revised 4/2017 2 or Injection Development t7 Service ❑ Strefigraphic ❑ work: Oil p Gas ❑ WDSPL ❑ WINJ ❑ WAG ❑ GINJ❑ SUSP❑ SPI UG❑ edge. Sundry Number or N/A if C.O. Exemor Contact Name: John Peirce Contact Email: John.W.Peirce@cop.com ?1161f-1 Contact Phone: (907) 265-6471 RBDMS.L%CT 2 17014 Submit Original Only 1 J-168 OFFSET PRODUCER FOR 1 E-1 17L2 RPPG MBE TREATMENT DTTM JOBTYP SUMMARYOPS START 4/20/19 MISC. RIH W/ DRIFT FREEZE PROTECT WELL W / 38 BBLS OF DIESEL RAN CAPACITY DRIFT TO 9529' JETTED TUBING AT SETTING DEPTH POOH. RBIH AND SUSTAINMENT SET ME BRIDGE PLUG AT 9496' POOH RDMO 4/20/19 PUMPING FREEZE PRTOECT TRACKING 65 BBLS DSL DOWN TUBING ONLY 2 BBLS METH DOWN FLOW LINE JOB COMPLETE 4/26/19 MISC. DRIFT TUBING COULD NOT FALL PAST 2220RKB DUE TO DEVIATION. CAPACITY SBHP JOB ABORTED, READY FOR SRIT. SUSTAINMENT 5/1/19 MISC. CONDUCT STEP RATE INJETION TEST CAPACITY SUSTAINMENT PUMP 10 BBLS SEAWATER AT 1 BPM PUMP 10 BBS SEAWATER AT 2 BPM PUMP 30 BBLS SEAWATER AT 3 BPM PUMP 200 BBLS SEAWATER AT 4 BPM PUMP 63 BBLS DIESEL FOR TUBING FREEZE PROTECT JOB COMPLETE 9/27/19 MISC. PUMPED FULLBORE RPPG TO TARGET D -SAND MBE, ESTIMATED CAPACITY TOE OF 1 E-1 17L2. PUMPED 599 -BBL TREATMENT INCLUDING 50 -BBL SUSTAINMENT 2% KCI PRE -FLUSH, FOLLOWED BY 333 -BBL SLURRY CONTAINING KCI PLUS 7040 -LB RPPG PRODUCT. DISPLACED SLURRY TO MBE WITH 154 -BBL KCI AND 62 -BBL DIESEL FP. GAINED APPROXIMATELY 700 - PSI NET PRESSURE DURING TREATMENT PUMPING 2.7-3.6 BPM. FINAL PUMP PRESSURE 1111 -PSI. NOTE: SUPPORTED PRODUCER 1J-168 WAS DIVERTED FROM FACILITY TO FLOWBACK TANK AT 12:35PM AT THE SAME TIME PUMPING TREATMENT INTO 1E-117 STARTED. 1J-168 SI @ 15;40 WITH 129 -BBL FLOWBACK. KUP PROD WELLNAME 1J-168 WELLBORE 1J-168 Well Attributes Ma: An le 8 MD TD ConocoPhillips g C rvame Wllbore ApYGWI Welllprearslu¢ Icll) MB(XKBI ACI BGn (flHa) AldSka,Inc, IWFfiT SAK I mapcnR_ ITO In.n _.. _.., ,,�� 1J-1�,1a1am1Wz5zmPM Last Tag vmblmlwmac l• man AnnahtlanOePX11XKel ism, Dab We11Wre "a, Maa By ................................................_..... coal Oa InmNSVIA �0 NIPPLE', W9] 11 T -INTERMEDIATE SURFACE;0a0D8a:1.9- GAS U i4.21De pame Fame, 6,I'so GAS upr: eza52 Ricew.kair paw panwac San 0 xIPPLe awed cAecE: e.esoe LOCAroa;s.Trar sent Assr; eTm.e DEANDUNER:6Apa- 12,91 D LINER LEM; 6706 L7,igBa ic _ B LINER LEM: TOGS a LINER HH; 7.147 O7.aoz.e INTERMEDIATE; ASS, z4.D swrs,aaa.oa,em.D� f stors:S,am.oe,na0- 1 sLors; esexae,eel o-�� SLOTS; 10 ITE R-10261 sai 10,512011.2140� 6tOT5, 11.M40-12e31.a- $112 scars; lz,alzoe2eaz.a-� r AurvD uM'.a; Tzaxb 1r 1z,11l Last Tag: CTMD-BLLEFLAG 8,050.0 502016 ii-nat Rom en Last Rev Reason .mammon End Dab Wplay,IeEl Metl a Rev RNoun : Installed New GILD B Ended EVO plug 80atcher ]242019 iJ-168 zembaej Casing Strings Ce¢ing uesctlptlon pulp, ID pal) Tnp(M(e) Be, )i mKin Set Depth Ten- WULen p... Greae rop TM1raaa CONDUCTOR InsulaieB 16 15.06 26.0 80.0 80.0 62.50 H40 WELDED Lazlne DesarlpliDn Go (in) to (in) Top(XKBI 5th Depth le(Bt Set Depth BVEd. WYLen II..,Graee TOp Thread SURFACE 10314 9.95 30.0 3,693.9 2,116.4 4550 L-80 BTC Cezlnp ue"Pson OO pall 10 (in) Top(KKB) Set Depth OrKB) Sea Depth OVD) mail 11-jamee Top TI.. ]6l8 fib] 26.3 8,224.0 3,466.1 29'0 L-80 ST cazmp Desanplion ODllni IDgnt Top MKs) Set Depth does; set Depth(rvD1... wVLen IL.. Graee Topmreae DLNER LEM 412 3.96 6,7068 ],126.1] 3,2912 12.fi0 L-80 BTM Liner Details Nominal ID Top (iTop (iMl(XNeI Top Incl l'1 Mm Des Cam tod 6,706.8 3.194.6 75.49 SLEEVE S75' ID Tie back sleeve 5,750 6717.8 3,19].4 7548 PACKER bbW.525""HRD PLiner Top Pacer w/hold 4.960 down slips 6,725.5 3,199.3 75.48 SBE 19047 Casing Seal Bore Respelacle . 'Onx 4'50 475" ID 6,7604 3,208.1 75.23 NIPPLE DB Nipple 3.75" ID, 4.5"IBTM Box x Pin 3.750 6]73.] 3,211.5 ]5.11 HANGER LEM Above Hook Hanger 3.970 6,780.5 3,213.3 75.05 HANGER LEM Below Hook Hanger 3.930 7,1248 3,290.7 80.14 SEAL ABBY 19047 Non -Locating Seal Assembly 3.880 ..Eing Dezanptln. OD 'In, ID 1") Top(M<id semepth DKal set Depth BVDl._WVLen(I.-Grade Top Thread BLINER LEM 4112 3.96 7,09fi.7 ],299.9 3,320.fi 12.60 L-80 IBT Liner Details Nominal ID TCP Mild iop (NDI (Xl(B) Top Incl l•I has Des Cam (In) PA 7,0967 3,285.8 79.91 CKER ZXP LINER TOP PACKER 5.510 ],115.] 3,289.1 80.14 SBR CASING 10947 SEAL BORE RECEPTACLE 4,750 7,1349 3,2924 80.15 To BUSHING 4.750 7,143.9 3,293.9 80.15 HANGER LEM ABOVE HOOK HANGER 3.970 7,154.6 3,295.8 80.15 HANGER LEM BELOW HOOK HANGER, ISOSEVE 3.69%19 SET AT 7158 3.930 7,221.5 3,3072 80.17 NIPPLE CAMCO DB -6 NIPPLE 3.563 7,296.6 3,320.0 80.22 BEAL-ASSY BAKER SEAL ASSEMBLY 3,880 Game DewrlPtun aD linl lD Iln) rop IXKEM see Depm MKB) Sat D-on(ND) WULen p... Gale. TOP Threee B LINER HE 4112 3.96 ],147.9 7,402.8 3,3325 1260 L-80 IBT Liner Details Hear lXMEMTopLVD) IXKBI Top Incl (°I Imp Des Lom rvmems"(in) 7,147.9 3,294.6 80.15 HANGER IBAKER MOVEL B-1 HOOK HANGER 5.300 3,298.5 80.15 XO BUSHING CROSSOVER BUSHING 3.960 ],241.5 3,310.6 80.18 ECP BAKER PAYZONE EXTERNAL CASING PACKER 3.950 7,359) 3,330.5 80.80 BENT JT 3.960 CasInD D3ECeiplion OD 11.1 1.Dd Top(XKBI SN Depth iffil Set Depth IIau, WULen 0 -Mr. Top Threae A -SAN. LINER 41rz 396 7,2458 12,9758 3,6514 12.60 L-80 HIT Liner Details xommm ID Top (724 Top lNOHMR) Top lncq°I Imp Dea Com (in) 1.4 ],245.8 3,311.4 80.18 PACKER "HRD"ZXP Liner Top Pmker55'X7.B" 5.500 7,2649 3,314fi 80.19 NIPPLE "RS" Packoff Seal Nipple 55" 4.875 -3,315,1 7,2677 80.20 HANGER Heal Liner Hanger 5.5"X).6' 4.853 7,2"B 3,316.8 BON SBE 19017 Casing Seal Bore Ext 4,75 76.27 OD 4750 7,297.0 3,320.1 8022 XO BUSHING XO Bushing 3.92" ID, 6020D 3.920 Tubing Strings Tulin, Description Sixng Ma...10(inl Tap1XKB) Set Depth ft. Sel uesh IND) I- jwt(IWM Graas Topeonnre n TUBING WO 4112 3.96 22.5 6,731 2 3,200.7 12.60 L-80 IBTM Completion Details TOP IND) Top Incl Top ltlHsl Mrp (') Iqm Des Com Nominal In (In) 22.5 22.5 0.07 HANGER Vatc0 ray Hang.,lV. .5"w/4.909'MCA op onn.Maaeup 3,900 on fell 499.7 499.2 595 NIPPLE .875 DW Nipple 3.875 6,649.1 3,180.2 75.50 NIPPLE 3812"'DB'Hipple 3.812 6,BE.6 =75.50 GAUGE Baker Guardian Gauge 3.958 6)02.8 3,193.6 75.49 LOCATOR Locator Sub 3.990 6,]03.9 3,1B3.a ]549 BEALASSY Bonded Seal Assembly cal Full Mule Shoe wl2'space out 3870 Other In Hole (VAreline retrievable plugs, valves, pumps, fish; etc.) Tap RVn Tap mal rop(XKBI lnKal C) no coin aan Date ID (in) 6,1990 3,049.4 68.13 Patch Packer PYP Packer PP45013 w/ PO LM spacer pipe and 51412019 anchor lath CPAL45001. DAL 24'Max OD 3.76, 2800 6,203.0 3,050.9 6830 POGLM POGLM assembly with l" By Iakh OV $et A24119. 5I4rz018 0.000 6,221.0 3,0525 69.06 Pakh Packer Jai Paoker CPP45003 DAL 5' M170D3.76. 5I4rz01B 2. KUP PROD WELLNAME 1J-168 WELLBORE 1J-168 ConwcoPhillips Alaska, Inc. u1ee, Imlea01a zs2'.w PM Perforations & Slots ..F- (eme9 iopmxBl BM659.0SKS) roRNS) elm lTVol 1X41) Linke0J-11 Shot Snel Gen Ienacem i Type Co. ........._...................._.......................... 8,474.0 8,659.0 3.47 3,4]]2 3,4813 WSA2, 1J-168 211Dat 813112005 320 SLOTS ALL SLOTS /solid pipe 0.125" z pipe ZY It 25 umfere 11@ 4 ers rows, 3'Stacent rows, 3- Centers Staggered gger 1811e0. 3 fl. non-slOneJ eox0ucroR Me,YW: So 0, ends wvvLE: .TZ'0 8,878.0 9,274.0 3,4897 3,502.9 WS A2, tJ-168 &312005 32.0 SLOTS 9,582.0 9,861.0 3,512.1 3,533.6 WS Al?, 1J-168 813112005 32.0 SLOTS suRrncE;xibaeas.P_ 7 l 63.9 3,558.1 3,5648 WS A2, 1J-168 8/31/2005 320 SLOTS 80 3,581.5 3,5]40 WS A2, 1J-168 fl1312005 32.0 SLOTS GAS LIFT; 4,2ma REi 31.0 3,564.9 3,609.0 WS A2, 1J-166 81312005 32.0 SLOTS 42.0WSA2,J-1688131/200532.0SLOTS ts Pe�Pecker, 8,1W0 SI GASLrT; BIDa2 BE POGIM; E.iO an TOPIry01 NTopms) IRUD Make Model Whe 011in) 5¢ry Type La2x Pod Sill type 0n1 TRO Run IPell Run Oale Com wxn v.Bmo 4,210.6 2,303.9 Camw KBO -2- 1 GAS LIFT GLV BK 0188 1,448.0 ]12312019 Nippl.... Nipple: . GRUGEBSAp 1R 2 6,2032 3,051.0 Camco KUBG-2- 1 1 GAS LIFT OPEN 0.0 7/132018 P091 In LOCATOR8ID2.e Notes: General & Safety arae" anrom°on SEALASSY;6TN.a 9126/2005 NOTE:MULTI-LATERAL WELL: ASAND(1J-168),BSAND(1J-1681-1), D-SAND(1J-1681-2) 911612008 j.V1 E ViewbM.Oe Gcwl Alaska SchemBlicaOREV OSPNO LINER: EM& 12,°42] OURERLEM;EMS-7.,1280 B LINER LEM, ],M.]-T.Aa.a BUNEAX11:7.147&74428 NTERMEOIATE; Seas.4. SLOTB, BgT4B9.a'A.p� SLOTS;8,8]66a,2r4O� SLOTS', 8`61.OS.EEI.O� EmTS;101MtaI0=.O SLOTS: 10.512011,24S.0� I SLOTS; 11,480.612W10�� SLOTS, 12,°12612,8420=— A,SnrvouNER:r,a4sa I? Ws.O 20 5060 • f 29252 LL Lf V E TRANSMITTALMAY 1 1 2018 PROACTIVE DIAGNOSTIC SERVICES, INC. ht g ,; To: AOGCC Natural Resources Technician 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 (907) 793-1225 RE : Cased Hole/Open Hole/Mechanical Logs and/or Tubing Inspection(Caliper/MTT) The technical data listed below is beingsubmitted sub tted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention of: ProActive Diagnostic Services, Inc. Attn: Ryan C. Rupe 130 West International Airport Road Suite C Anchorage, AK 99518 Fax: (907)245-8952 Z) 16 scow JUN 1) Production Profile 02-Apr-18 (run 1) 1J-168 CD 50-029-23260-00 2) Production Profile 03-Apr-18 (run 2) 1J-168 CD 50-029-23260-00 Signed : Date : Print Name: 1 V r _ PROACTIVE DIAGNOSTIC SERVICES, INC., 130 W.INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245-8951 FAX: (907)245-8952 E-MAIL: PDSANCHORAGE@MEMORYLOG.COM WEBSITE:WWW.MEMORYLOG.COM D:\Achives\MasterTemplateFiles\Templates\Distribution\TransmittalSheets\ConocoPhillips_Transmit.docx • • 20 5060 WELL LOG, RECE1 LLP TRANSMITTAL 92 APR 26 2018 PROACTIVE Di/4No51ik SERVICES, INC. AOGCC To: AOGCC Natural Resources Technician 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 (907) 793-1225 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 attention of: ProActive Diagnostic Services, Inc. Attn: Ryan C. Rupe 130 West International Airport Road Suite C Anchorage, AK 99518 Fax: (907) 245-8952 SCANNED 1) Production Profile 04-Apr-18 1J-168 run2 CD 50-029-23260-00 2) C � ' (30/ (� Signed : , Date : t Print Name: PROACTIVE DIAGNOSTIC SERVICES, INC., 130 W.INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245-8951 Fax: (907)245-8952 E-MAIL: PDSANCHORAGE@.MEMORYLOG.COM WEBSITE:WWW.MEMORYLOG.COM D:\Achives\MasterTemplateFiles\Templates\Distribution\TransmittalSheets\ConocoPhillips_Transmit.docx . PTD Loepp, Victoria T (DOA) From: Loepp,Victoria T(DOA) Sent: Wednesday,January 17,2018 9:46 AM To: 'NSK Well Integrity Supv CPF1 and 2' Subject: RE: KRU Producer 1J-168 (PTD205-060) Request for production test with known tubing leak Follow Up Flag: Follow up Flag Status: Completed Jan, Approval is granted to put KRU 1J-168 on gas-lifted production for a period not to exceed 30 days for the purpose of running a PPROF to evaluate an MBE. Thanx, Victoria Victoria Loepp Senior Petroleum Engineer State of Alaska SCANNED 1. Oil&Gas Conservation Commission 333 W.7th Ave Anchorage,AK 99501 Work: (907)793-1247 Victoria.Loepp a(�alaska.gov CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission(AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information.The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail,please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Victoria Loepp at(907)793-1247 or Victoria.Loepp@alaska.gov From: NSK Well Integrity Supv CPF1 and 2 [mailto:n1617@conocophillips.com] Sent: Monday,January 15,2018 11:35 AM To: Loepp,Victoria T(DOA)<victoria.loepp@alaska.gov> Cc:Senden, R.Tyler<R.Tyler.Senden@conocophillips.com>; NSK Well Integrity Supv CPF1 and 2 <n1617@conocophillips.com> Subject: KRU Producer 1J-168(PTD205-060) Request for production test with known tubing leak Victoria, CPAI requests permission to put KRU producer 1J-168(PTD 205-060)online with lift gas for a production test(not to exceed 30 days)with known TxIA communication. 1J-168 has been shut in since May 19,2016 due to an Matrix Bypass Event from offset injector 1E-117. To facilitate repair plan development a PPROF has been requested to evaluate the MBE as it cannot be evaluated from the injector side due to a misaligned LEM. The 30 day production test is requested to allow pre flush to be produced and sufficient time to perform the PPROF. The well will be shut in upon completion of the PPROF. 1 • • *To enable running a PPROF the existing tubing patch (10-404 submitted 2-3-15)wasulled allowingthe known TxIA p communication from GLM#2 at 6203'to resume. A passing CMIT TxIA was performed to prove the production casing integrity. A wellbore schematic and 10-426 for the CMIT are attached. Please give us a call if you have any questions or concerns. Regards, Jan Byrne/Kelly Lyons Well Integrity Supervisor ConocoPhillips Alaska, Inc. Office phone: (907)659-7224 41WELLS TEAM conoaphisips2 • • Carlisle, Samantha J (DOA) WI) AS MOO O From: Loepp,Victoria T(DOA) -" I Sent: Friday,July 22, 2016 1:12 PM To: Carlisle, Samantha J (DOA) Subject: FW: Cancelation of 10-403 Approvals for 1E-117 Crystal Seal MBE Treatment Please handle. From: Peirce, John W [mailto:John.W.Peirce@conocophillips.com] Sent: Thursday, June 09, 2016 1:37 PM To: Loepp, Victoria T(DOA) Subject: Re: Cancelation of 10-403 Approvals for 1E-117 Crystal Seal MBE Treatment Hi Victoria, The proposed 1E-117 Crystal Seal MBE treatment recently approved by AOGCC (per 10-403 approvals for: 1E-117, 1E- 117L2, 1J-168, and 1J-168L2)was attempted, but we had unexpected problems getting coil tubing through the D Diverter to enter the D lateral (1E-117L2)to pump the Crystal Seal job. After unsuccessful attempts to enter the D lateral we terminated plans to perform a Crystal Seal treatment and left 1E-117 configured with all 3 laterals open. The recent 1E-117 well events are summarized below. Future work options for 1E-117 will be evaluated. Since no Crystal Seal treatment will be pumped,there will be no Crystal Seal treatment to report on 10-404's. Thus, I request that the following 10-403 approvals be canceled: 1E-117(316-272) 1E-117L2(316-273) 1J-168 (316-274) 1J-168L2 (316-275) Regards, SCANNED FEE 0 6"2[117 John Peirce Sr Wells Engr CPAI Drilling&Wells (907)-265-6471 office Well Events History 1E-117 : 5002 92325100 : 6/9/2016 Date Event 05/27/2016 B&C CTU#1: RETRIEVE TYPE 1 ISO SLEEVE ACROSS B LEM AT 9706'. ALL SANDS LEFT IN OPEN POSITION. B&C CTU#1: PERFORM DOWNHOLE VIDEO OF D SAND LATERAL LEM 05/26/2016 AT 9706' WITH MEMORY EV VIDEO AND HES N2, TWO RUNS. VIDEO INDICATES DIVERTER KEY NOT ORIENTING CORRECTLY INTO SLOT ON LEM. IN PROGRESS. 05/24/2016 B&C CTU#1: REMOVE PLUG BODY FROM DB NIPPLE AT 9760' WITH BAKER G-FORCE JARS AND INSTALL TYPE 1 ISO SLEEVE ACROSS B 1 RBDMS krV .;U.. 2 6 2016 • • • LEM AT 9706' WITH BAKER HIPP TRIPPER. WILL RETURN IN THE MORNING TO LOG VIDEO OF D LATERAL LEM. IN PROGRESS. B&C CTU#1: PERFORM WEEKLY BOP TEST ON BACK DECK. RETRIEVE 05/23/2016 TYPE 1 ISO SLEEVE ACROSS B LEM AT 9706'AND P PRONG FROM DB PLUG AT 9760' WITH BAKER G-FORCE JARS. WILL RETURN IN THE MORNING TO REMOVE PLUG BODY FROM DB NIPPLE. IN PROGRESS. B&C CTU #1: ATTEMPT TO GET THROUGH DIVERTER WITH SLIM FCO ASSEMBLY WITH 1.7" DJN AND NOTE METAL MARKS ON BOTTOM OF 05/22/2016 NOZZLE. ONE LAST ATTEMPT WITH LARGER 2.7" NOZZLE UNSUCCESSFUL. REMOVE TYPE 2 DIVERTER IN D LEM AT 9385' WITH BAKER G-FORCE JARS. IN PROGRESS. B&C CTU#1: INSTALL TYPE 2 DIVERTER IN D LEM AT 9385' WITH 05/21/2016 BAKER HIPP TRIPPER. MAKE TWO UNSUCCESSFUL ATTEMPTS TO GET THROUGH DIVERTER WITH DIFFERENT FCO ASSEMBLIES. IN PROGRESS. B&C CTU #1: ATTEMPT FCO OF D LATERAL WITH DJN. UNABLE TO MAKE IT PAST DIVERTER WITH 2 DIFFERENT BHA CONFIGURATIONS. 05/20/2016 REMOVE TYPE 2 DIVERTER IN D LEM AT 9385' WITH BAKER G-FORCE JARS. JET WASH LEM PROFILE WITH HES PULSONICS NOZZLE. WILL RETURN IN THE MORNING TO RESET DIVERTER AND REATTEMPT FCO. IN PROGRESS. B&C CTU#1: INSTALL TYPE 1 ISO SLEEVE ACROSS B LAT AT 9706'AND 05/19/2016 TYPE 2 DIVERTER IN D LEM AT 9385' WITH BAKER HIPP TRIPPER. IN PROGRESS. B&C CTU#1: REMOVE TYPE 2 ISO SLEEVE ACROSS D LEM AT 9365' 05/18/2016 AND TYPE 1 DIVERTER IN B LEM AT 9706" WITH BAKER G-FORCE JARS. IN PROGRESS 2 0 0 000Z 110v -J N W Y u > trl O 0 a) y O t u Z. on _' I- > I O OC:. Y O c° U d u > o cu 1- Q;. c9 . c° > O_ Q 0 W O O V7 O /0 fO (0 fD O1:3, N L J co .J 0 r r T T T > ''' a) 0 Y -, I- C 0 R IO m CO to c 16 L C C tp f' C W - E cD O_ a) S� h 1A o0 a0 N L c > Z o N C Q a Q u v v Ou .� F D 00000000 Ycr a v Y s iiii a J J J J J J J y W W W W W W W 0Op O ca O F LL LL LL LL LL LL LL c Q J J J J J J n a) E 'p ^ :C Q 2 0 C O Ozzzzzzz .1.-+ co a) U. LL U. U. U. U. U. a) -Cv 0trol L1 CC • G . ca u a) _, O - C v E .3,- O O O _ N 0 c O _0 C a) n, a) v o= •L U C c as 0 C N a F Q a) s u > it 5 c.. O ijj -0 HHfl ,0 Wm Q - oc a V w a) m rn U t0 >> a) in (Q 0) dS d g G a O c- ` Z .Y. f0 co r w 0 V d J O J O J O J "'7 .--.'71,2„...,Ir 2 E4 111. p 9v o z z z z z z zILI DDMM a`, LuCtCCWC4C4 CC X 00 5 W W W W W W W a Q > > > > > > > 4 0 Y Y Y Y Y Y Y t W fY R C4CL a' a'= DDMDD 111 v to Q Q Q Q Q Q Q v O. a a a a a a CI IX C. tU X n u W N N IA CO O 1A 1•••••0 CO O CO O N O CO U 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 co V N O N N N D ca fy > a 2 v 2 Y E v E '� e••1 / N 0010000 0 liel e7 0 xCO 13CO o 0 0 0 0 0 0 CO tD 0 0 0 c� 0 0 0 U' N .. Y N 1D 0) h 10 N N va E !Y) O N M r O N •N O N M Cr N N r 0 N IN N N N N N N N n a) 0 0) C) O) M T O -c N N N N N 0 N Q1 O co O O O r O _ O O O O O O O a) In IA N I[) N N N 3 a) HCID 1:4 .rm. CO CIn a G 0 C Ff. Z Q) E cu @ a) Y 8 W s c ,� �c`' *' Q n C O CO CA J N n jC a) 7 C1 �_ a, ~ Z r .1- N v N N EU E Z(13 C .,--,co C F- a. a Q OF TJX • • THE STATE Alaska Oil and Gas 4., --s.=��7A of LAsKA Conservation Commission 333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 www.aogcc.alaska.gov John W. Peirce scIONED SEP 2 8 2D16 Sr. Wells Engineer ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, West Sak Oil Pool, KRU 1J-168 Permit to Drill Number: 205-060 Sundry Number: 316-274 Dear Mr. Peirce: 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. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration 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. Sincerely, Cathy :. Foerster Chair DATED this day of May, 2016. RBDMS (,l/ MAY 3 1 2016 il FrE c.. STATE OF ALASKA f�Y1 • ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS s-/ u1i6C 20 MC 25.280 1.Type of Request: Abandon ' Plug Perforations EFracture Stimulate I- Repair Well E Operations Shutdown L. Suspend I, Perforate Other Stimulate Pull Tubing E Change Approved Program Plug for Redrill FI Perforate New Pool Re-enter Susp Well Alter Casing E Other: Crystal SPai MRF Irmt F 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: ConocoPhillips Alaska,Inc. • Exploratory ;"" Development F• 205-060 f 3.Address: 6.API Number: P.O.Box 100360,Anchorage,Alaska 99510 Stratigraphic E Service 50-029-23260-00 • 7.If perforating: 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? N/A • Will planned perforations require a spacing exception? Yes r No F KRU 1J-168 9.Property Designation(Lease Number): ',/6 10.Field/Pool(s): ADL 25660I L3-6421 Kuparuk River Field/West Sak Oil Pool 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth TVD: MPSP(psi): Plugs(MD): Junk(MD): 12,995' ' ,3,654' 12973 • 3651 970 - Casing Length Size MD TVD Burst Collapse Structural Conductor 54' 16" 80' 80' Surface 3,664' 103/4 3,694' 2,116' Intermediate 8,198' 75/8 8,224' 3,466' Liner 5,729' 4 1/2 12,975' 3,651' Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 8474-8861 . 3477-3534 4.500" L-80 6,731' Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): PACKER-4.5 ER WFD UPPER PACKER ' MD=6200 TVD=3050 PACKER-4.5 ER WFD LOWER PACKER . MD=6222 TVD=3058 PACKER-HRD ZXP Liner Top Packer ' MD=7097 TVD=3286 SSSV: NONE • MD=7246 TVD=3311 PACKER-ZXP Liner Top Packer N/A 12.Attachments: Proposal Summary j Wellbore schematic 3 13.Well Class after proposed work: Detailed Operations Program 0 BOP Sketch ❑ Exploratory fl Stratigraphic I— Development F- Service 1-••••. 14.Estimated Date for 5/26/2016 15.Well Status after proposed work: Commencing Operations: OIL p- - WINJ WDSPL Suspended 16.Verbal Approval: Date: GAS E WAG E GSTOR 1 SPLUG Commission Representative: GINJ E Op Shutdown Abandoned 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Contact John Peirce @ 265-6471 Email John,W.Peirce@cop.com Printed Name John W.Peirce Title Sr.Wells Engineer • 51.121201GSignature +� Phone 265-6471 Date COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 3\14.— 21 ii Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test 0 Location Clearance ❑ Other: Post Initial Injection MIT Req'd? Yes ❑ No Spacing Exception Required? Yes ❑ No Subsequent Form Required: /e - ICCIF RBDMS �� MAY 3 1 2016 APPROVED BY Approved by: -* C MMISSIONER THE COMMISSION Date:5 , 2_5- o� il • � C„Attachments in e Form 10-403 Revi d 11/2016 a s valid for 12 mon frpm the date of a proval. in Duplicate • • 1E-117L2 to 1J-168L2 'D' MBE Crystal Seal Treatment Proposal 1E-117 injector was shut-in after an MBE occurred to adjacent producer 1J-168. With 1E-117 SI, a decision was made to SI 1E-170 for reservoir and pattern protection. In order to return 1E-170 (750 bopd) to service, 1E-117 must be returned to injection. Diagnostics have been done on the MBE between 1E-117 and 1J-168 as follows: 1. Mainbore IPROF completed in 1E-117 on 1/30/16. (PROF Identified injection splits as 30% D- sand, 60% B-sand, 10% A-sand. (PROF results show majority of injection into the B-sand led team to decide that a B lateral (PROF would determine location of MBE. 2. Set an A Sand Isolation Plug on 1/31/16 in DB Nipple at 9759' RKB. 3. B-sand lateral (PROF completed in 1E-117 on 3/15/16. IPROF got 2000' in lateral (3000' remaining). Logged interval showed no signs of an MBE. Team decided to perform a PPROF in 1J-168 to determine in which lateral the MBE existed. 4. Mainbore PPROF obtained in 1J-168 on 5/8/16. PPROF showed 98% of flow was entering the wellbore from D-sand. Team decided that MBE exists in D-sand lateral. Proposed Procedure - Coil Tubing will perform in 1E-117 & 1E-117L2: 1. RIH & pull the D Iso-Sleeve at 9385' RKB. 2. RIH & pull the B Lat Diverter at 9706' RKB. 3. RIH & set a B Lat Iso-Sleeve at 9706' RKB. 4. RIH & set a D Lat Diverter at 9385' RKB. 5. RIH with Nozzle and perform a D Lat Fluff& Stuff to deep as possible. 6. RIH with memory (PROF BHA and log D Lat IPROF to deep as possible to locate MBE. 7. If D MBE location can be determined from (PROF, RIH with 2" OD Perf Gun to perforate a 5' interval at 6 spf across the MBE location, using `big hole' charges to provide large inflow area for Crystal Seal to exit slotted liner to the D MBE. If the MBE is not detected on the (PROF, it may be that the MBE exists at depth greater than can be attained with CT, in which case perforating will not be performed. 8. RIH with Down Port Nozzle and park nozzle above all slots at `safety' (9575' RKB), then pump 0.4 bpm Diesel down CT x Tbg (until Flush is called), and simultaneously start pumping 1,2,4 mm mesh Crystal Seal Slurry at 0.25 lbs Crystal Seal per gallon in 3% KCL Water, or Winter Seawater. Pump slurry down CT at steady rate between 2 - 3 bpm to MBE until target Wellhead Pressure on Tbg x CT annulus reaches 1000 - 1200 psi (near Frac pressure), then call Flush of 5 bbls 3% KCL Water (or Seawater) down CT, followed by 1 CT volume (-47 bbls) Diesel to FP CT, followed by POOH with CT replacing voidage with Diesel. Leave tubing FP to 2200' TVD (4889' RKB) = 75 bbls Diesel. 9. RIH with Down Jet Nozzle to Fluff & Stuff with Seawater through Crystal Seal to deep as possible while injecting all fluid to well. POOH. Return 1E-117L2 to PWI to and D Lateral to evaluate Crystal Seal treatment results at 1E-117 and 1J-168. JWP 5/12/2016 -`',� KUP D IJ-168 ConocoPhillips 9 Well Attribu Max Angle MD TD A 1_I-,;f li Wellbore APVUWI Field Name Wellbore Status ncl C) MD(ftKB) Act Btm(ftKB) CnrroocN1118pt};; 500292326000 WEST SAK PROD 93.12 11,172.18 12,995.0 ... Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date 1J-166.5/12/2016 2 44.10 PM SSSV:NIPPLE 60 12/16/2013 Last WO: 9/10/2008 31.01 9/26/2005 vertical schemabc(actual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date ...-.:_gi® Last Tag'SLM 7,067.0 12/12/2013 Rev Reason:SET PATCH lehallf 2/2/2015 ( Casing Strings I Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...WtlLen(I...Grade Top Thread I' '- CONDUCTOR Insulated 16 15.062 26.0 80.0 80.0 62.50 H-40 WELDED ��I_ I�� Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len ..Grade TopThread SURFACE 103/4 9.950 30.0 3,693.9 2,116.4 45.50 L-80 BTC CONDUCTOR Insulated;26.0 Casing Description OD(in) SID(in) Top(ftKB) Set Depth(ftKB) Set Depth(NO)...WtlLen I Grade Top Thread 80A INTERMEDIATE 75/8 6.875 26.3 8,224.0 3,466.1 29.70 L-80 BTCM NIPPLE 499.7 Casing Description OD(in) SID(in) Top)ftKB) Set Depth(ftKB) Set Depth(ND)...Wt/Len g...Grade Top Thread D LINER LEM 41/2 3.958 6,706.8 7,128.0 3,291.2 12.60 L-80 IBTM 1 1 Liner Details II Nominal ID SURFACE;30.03,693.9-. Top(•BB) Top(TVD)(ftKB) Top Incl C) Item Des Corn (In) 6,706.8 3,194.6 75.49 SLEEVE 5.75"ID Tie back sleeve 5.750 GAS LIFT;4,210.6 6,717.8 3,197.4 75.48 PACKER 5.5"x7.625""HRD"ZXP Liner Top Packer w/hold 4.960 down slips • 6,725.5 3,199.3 75.48 SBE 190-47 Casing Seal Bore Recepetacle 6.30"OD x 4.750 PACKER;6,200.0 -_ 4.75"ID GAS LIFT;6,203.2 •1--..a 6,760.4 3,208.1 75.23 NIPPLE DB Nipple 3.75"ID,4.5"IBTM Box x Pin 3.750 II 6,773.7 3,211.5 75.11 HANGER LEM Above Hook Hanger 3.970 PACKER;6,222.0 6,780.5 3,213.3 75.05 HANGER LEM Below Hook Hanger 3.930 NIPPLE,8,649.1 ■w 7,124.8 3,290.7 80.14 SEAL ASSY 190-47 Non-Locating Seal Assembly 3.880 GAUGE;8,650.6 IL� Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... Wt/Len)I...Grade Top Thread B LINER LEM 41/2 3.958 7,096.7 7,299.91 3,320.61 12.601L-80 IIBT OM Liner Details LOCATOR;6,702.8I Nominal ID 's Top(CAB) Top(ND)(ftKB) Top Incl C) Item Des Corn (In) SEAL ASSY;6,703.9 - : 7,096.7 PACKER TOP IPACKER 5.510 `ar 7,115.7 3,289 1 :t t• BORE RECEPTACLE 4.750 7,134.9 3,292 4 80.15 •BUSHING 4.750 7,143.9 3,293.9 :t.15 HANGER LEM ABOVE HOOKt 7,154.6 3,295.8 80.15 HANGER LEM BELOW HOOK HANGER,ISO SLEEVE 3.930 3.69"X19'SET AT 7158 II 11 D-SAND LINER;8,780.5- 7`( 4 7,221.5 3,307.2 80.17 NIPPLE CAMCO DB-6 NIPPLE 3.563 12,942.7 lk 5 7,296.6 3,320.0 80.22 SEAL ASSY BAKER SEAL ASSEMBLY 3.880 Casing DescriptionOD(in) ID(in) Top)ftKB) Set Depth(ftKB) Set Depth(ND)... Wt/Len(I Len ...Grade Top Thread B LINER HH 1 41/21 3.9581 7,147.91 7,402.81 3,337 .51 12.601L-80 IBT Liner Details Nominal ID Top(ftKB) Top(ND)(ftKB) Top Incl(°) Item Des Corn (in) 'r 7,147.9 3,294.6 80.15 HANGER BAKER MOVEL B-1 HOOK HANGER 5.300 D LINER LEM,6,706.8-7,128.0 - 7,170.8 3,298.5 80.15 XO BUSHING CROSSOVER BUSHING 3.960 r I 7,241.5 3,310.6 80.18 ECP BAKER PAYZONE EXTERNAL CASING PACKER 3.950 7,359.7 3,330.5 80.60 BENT JT 3.960 Casing Description (in) ID(in) Top(ftKB) Set Depth)ftKB) Set Depth(TVD)... WtlLen(I...Grade Top Thread tli i( A-SAND LINER 1 OD 41/21 3.9581 7,245.81 12,975.01 3,651. 4( 12.601 L-80 IBT •11 d+ Liner Details 11=� I Nominal ID -4IITo )11K13) Top(ND)(ftKB) Top Incl(°) Item Des Com (in) 7,245.8 3,311.4 80.18 PACKER "HRD"ZXP Liner Top Packer 5.5"X 7.6" 5.500 7,264.9 3,314.6 80.19 NIPPLE "RS"Packoff Seal Nipple 5.5" 4.875 7,267.7 3,315.1 80.20 HANGER FlexLock Liner Hanger 5.5"X 7.6" 4.853 7,277.6 3,316.8 80.20 SBE 190-07 Casing Seal Bore Ext.4.75"ID x 6.25"OD 4.750 7,297.0 3,320.1 80.22 XO BUSHING 'XO Bushing 3.92"ID,6.02 OD 3.920 ■ Tubing Strings �__� r Tubing Description I String Ma...In) Top(ftKB) Set Depth(ft..Set Depth(NO)(...Wt(Iblft) Grade Top Connection TUBING WO 41/211"n) D(i 3.9581 22.51 6,731.21 3,200 12.601L-80 1 IBTM • 1, Completion Details i,:�"'1 Nominal ID I�' `:. Top(ftKB) Top(ND)(ftKB) Top Ind(*) Item Des Com (in) EMI 22.5 22.5 0.07 HANGER Vetco Gray Hanger 11"x 4.5"w/4.909"MCA Top Conn. 3.900 14/' 6 Made up on full j'onlai- 499.7 4992 5.95 NIPPLE 3.875"'DB'Nipple 3.875 MEW B LINER LEM;7,098.7-7,299.9 6,649.1 3,1802 75.50 NIPPLE 3.812"'DB'Nipple 3.812 6,650.6 3,180.5 75.50 GAUGE Baker Guardian Gauge 3.958 B LINER HH;7,147.97,402.8 6,702.8 3,193.6 75.49 LOCATOR Locator Sub 3.990 6,703.9 3,193.9 75.49 SEAL ASSY Bonded Seal Assembly w/Full Mule Shoe w/2'space out 3.870 INTERMEDIATE,26.3-8,224.0 Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) H- Top(ND) Top Incl SLOTS;8,474.03,659.0 - Top(ftKB) (ftKB) )°) Des Corn Run Date ID)in) SLOTS;8,876.0-9,274.0 6,200.0 3,049.8 68.17 PACKER 4.5 ER WFD UPPER PACKER 1/25/2015 1.900 I-- 6,222.0 3,057.8 69.11 PACKER 4.5 ER WFD LOWER PACKER 1/24/2015 1.900 SLOTS;9,582.0-9,661.0 e-- Perforations&Slots i... Shot ns SLOTS;10,170.0-10,263.0 Top(ND) Btm(TVD) (sots/ r Top(ftKB) Btm(ftKB) (ftKB) (ftKB) Zone Date ft) Type Com i- sLo7s;10,512.0-11,248 0 8,474 0 8,659.0 3,477.2 3,481.3 WS A2,1J- 8/31/2005 32.0 SLOTS ALL SLOTS:Alternating 168 slotted/solid pipe 0.125" x2.5"x32spf@ 4 P-- Circumferential adjacent SLOTS;11,461.0-12,631.0 rows,3"Centers staggered 18 deg.,3 ft. SLOTS;12,912.0-12,942.0 r non-slotted ends L A-SAND LINER;7,245.8- 12,975.0.'--• ,245.8- 12,975.0 ' 3 KUP OD 0 1J-168 ConocoPhillips . Alaska,lnc, ° Catoaliffips 1J-166 5112/2016 2.44 10 PM _ VaMa1 achmnato(actual) perforations&Slots ,,t t Dens Top(ftKB) Btm(MTop (ftKB)B B(ftKB)D) Zone Date (shots/ft) Type Com �II 8,876.0 9,274.0 3,489.7 3,502.9 WS A2,1J- 8/31/2005 32.0 SLOTS CONDUCTOR Insulated;26.0- 168 la I eo.o NIPPLE,499.7 — 9,582.0 9,861.0 3,512.1 3,533.6 WS A2,1J- 8/31/2005 32.0 SLOTS 168 10,170.0 10,263.0 3,558.1 3,564.8 WS A2,1J- 8/31/2005 32.0 SLOTS 168 SURFACE;30.03,693.9 10,512.0 11,248.0 3,581.5 3,574.0 WS A2,1J- 8/31/2005 32.0 SLOTS kit 168 GAS LIFT,4,210sI! 11,464.0 12,631.0 3,564.9 3,609.0 WS A2,1J- 8/31/2005 32.0 SLOTS 168 12,912.0 12,942.0 3,642.9 3,646.6 WS A2,1J- 8/31/2005 32.0 SLOTS PACKER;6,200.0 _ 168 GAS LIFT;6,203.2 t 1c" Mandrel Inserts M St ai PACKER;6,2710 - - = on Top(TVD) Valve Latch Port Size TRO Run N Top(ftKB) (ftKB) Make Model OD(in) Sery Type Type (in) (psi) Run Date Corn NIPPLE;6,649.1 1 4,210.6 2,303.9 Camco KBG-2- 1 GAS LIFT GLV BK 0.156 1,477.0 1/9/2015 GAUGE;6,650.6 Z�.7 1R 2 6203.2 3,051.0 Camco KBG-2- 1 GAS LIFT OPEN 0.000 0.0 1/16/2015 LOCATOR;6,702.8 1R Notes:General&Safety SEAL ASSY;6,703.9 End Date Annotation p 9/26/2005 NOTE:MULTI-LATERAL WELL:A-SAND(1J-168),B-SAND(1J-168L1),D-SAND(1J-168L2) 9/16/2008 NOTE:View Schematic w/Alaska Schematic9.OREV D-SAND LINER;6,780.5- 8 12,942.7 11 q 4 4 "717- , D LINER l EM:6.706.8-7,128.0 I 4 f 3 8 LINER LEM;7098.7-7299.9 . a B LINER HH;7,147.9-7,402.8 INTERMEDIATE;26.3-8,224.0 SLOTS;8,474.0-8,659.0 SLOTS;8,876.0-9,274.0 SLOTS;9,582.0-9,861.0 SLOTS;10,170.0-10,283.0 SLOTS;10,512.0-11,248.0 SLOTS;11,464.0-12,631.0 SLOTS;12,912.0-12,942.0 A-SAND LINER;7,245.8- 12,975.0' STATE OF ALASKA ALS A OIL AND GAS CONSERVATION COM, 3ION REPORT OF SUNDRY WELL OPERATIONS 1.Operations Performed. Abandon r Repair w ell r Rug Perforations r Perforate r Other ?'v ii--Ly Alter Casing r Pull Tubing r Stimulate-Frac r Waiver r Time Extension r /9471-e, 4 fc (� Change Approved Program rOperat Shutdow n r Stimulate-Other r Re-enter Suspended Well r 2.Operator Name 4.Well Class Before Work: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Development 1' Exploratory r 205-060 3 Address: 6.API Number: P. O. Box 100360,Anchorage,Alaska 99510 Stratigraphic r Service r 50-029-23260-00 7.Property Designation(Lease Number): 8 Well Name and Number: ADL25661/ADL25660 WSAK 1J-168 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): Kuparuk River Field/West Sak Oil Pool 11.Present Well Condition Summary. Total Depth measured 12995 feet Plugs(measured) None true vertical 3654 feet Junk(measured) None Effective Depth measured feet Packer(measured) 6200, 6222,6704 true vertical feet (true vertical) 3050, 3058, 3194 Casing Length Size MD TVD Burst Collapse CONDUCTOR INF. 54 16 80 80 SURFACE 3664 10 3/4 3694 2116 INTERMEDIATE 8198 7 5/8 8224 3466 T'. �.., ti„lkw ED F.tia^n FFB052015 Perforation depth: Measured depth: 8474'-12942' True Vertical Depth: 3477'-3647' (+ Tubing(size,grade,MD,and TVD) 4 5, L-80,6703 MD, 3194 TVD Packers&SSSV(type,MD,and TVD) PACKER-4.5 ER WFD UPPER PACKER @ 6200 MD and 3050 TVD PACKER-4.5 ER WFD LOWER PACKER @ 6222 MD and 3058 TVD SEAL ASSY-BONDED SEAL ASSEMBLY W/FULL MULE SHOE @ 6704 MD and 3194 TVD NIPPLE-3.875"'DB'Nipple @ 500 MD and 499 TVD 12.Stimulation or cement squeeze summary N/A Intervals treated(measured) Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation N/A N/A N/A N/A N/A Subsequent to operation N/A N/A N/A N/A N/A 14.Attachments 15.Well Class after work. Copies of Logs and Surveys run_ Exploratory r Development r Service r Stratigraphic r 16.Well Status after work: Oil r Gas r WDSPL r Daily Report of Well Operations x GSTOR r WIND r WAG r GINJ r SUSP r SPLUG r 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C 0 Exempt N/A Contact Kelly Lyons/ Brent Ro;ers Email n1617@conocophillips.com Printed Name K- I L on / Title Problem Wells Supervisor Signature 0 Phone:659-7224 Date 02/03/15 vrZ- 2/i z/ 5 RBDMS '� FEB - 6 2015 A 042.14' Form 10-404 Revised 10/2012 Submit Original Only r „ ✓ . . ECEIVED ConocoPhillips FEB 0 5 2015 Alaska /,� P.O. BOX 100360 AU iCC ANCHORAGE,ALASKA 99510-0360 February 3, 2015 Ms. Cathy Foerster Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Dear Commissioner Foerster: Enclosed please find the 10-404 Report of Sundry Operations for ConocoPhillips Alaska, Inc. well 1J-168 (PTD 205-060) for a retrievable patch set in the tubing above the packer. Please call Brent Rogers or myself at 659-7224 or Jan Byrne /Dusty Freeborn at 659- 7126 if you have any questions. Sincerely, Kelly Lyons ConocoPhillips Problem Wells Supervisor Enclosures • 1J-168 DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary 10/29/14 (AC EVAL)TIFL- FAILED DUE TO IA INFLOW AND PRESSURE INCREASE. Initial T/I/O= SI 1700/1700/13 T FL @ 5748'. IA FL @ 5808' (6203' OV) Bled IA gas 60 min (unable to obtain 500 psi differential) T/I/O= 1650/1440/13; T FL @ 5092' (Inflowed 656") IA FL @ 5628' (Inflowed 687') IA increased 20 psi after SI bleed and shooting T & IA FL's. 15 min reading T/I/O= 1600/1500/13/13; T FL @ 5871' (Outflowed 821') IA FL @ 5466' (Inflowed 162') Final T/I/O= 1600/1540/13 11/10/14 BRUSHED n' FLUSHED TBG TO 6649' RKB; SET CATCHER @ SAME. PULLED OV @ 6203' RKB REPLACED IN KIND (CHECK& NOSE CONE ERODED AWAY). PULLED GLV @ 4210' RKB REPLACED IN KIND. PULLED EMPTY CATCHER. COMPLETE. 01/05/15 (AC EVAL): RE-TIFL (Failed - unable to achieve a differential). T/I/O =252/491/140, IA FL @ 6203' (station#2 OV). Blocked AL line, shut in WV. Pressurized Tbg W/lift gas from AL line up stream of the choke for 1 hour.(1200 psi available) T/I/O = 725/700/140, IA FL @ 5987' (216'of inflow). Continued pressurizing Tbg with lift gas for an additional 30 min (1.5 hrs total). T/I/O = 750/750/140, IA FL @ 5987' (same location). Bled IA down to 700 psi in 30 min. T/I/O = 755/700/140, T FL @ 6970' (767' below OV), IA FL @ 5987' (same location), Bled IA an additional 45 min. (1 hr 15 min total) T/I/O = 770/725/140, T FL @ 6791' (179' of inflow), IA FL @ 5987' (same location). 'Final T/I/O = 770/725/140. 01/13/15 LOG LEAK DETECT BY PUMPING DIESEL DOWN TUBING, FLOWING WELL TO ADJACENT WELL FLOWLINE. PUMPING AT .4 BPM AT 1000 PSI, LEAK FOUND AT 6207' AT WHAT APPEARS TO BE THE POCKET OF THE GAS LIFT MANDREL. LOG CORRELATED TO TUBING DETAIL RECORD DATED 6 SEP 2008. READY FOR CALIPER LOG. 01/24/15 SET 4 1/2"WFD ER LOWER PACKER @ 6222' RKB, SET 4 1/2" ER TEST TOOL INTO LOWER PACKER. *JOB IN PROGRESS 01/25/15 LRS PUMPED 264 BBL OF DIESEL TO CIRC-OUT TBG/IA. PERFORMED CMIT-TxIA TO 2000#. PASSED. PULLED 4 1/2" ER TEST TOOL FROM LOWER PACKER @ 6222' RKB. SET 4 1/2"WFD UPPER ER PACKER W/SPACER PIPE &2 3/8" SPM W/ 1" OV(.313" PORT) @ 6200' RKB. *JOB IN PROGRESS 01/28/15 SET 4 1/2" ER TEST TOOL INTO UPPER PACKER @ 6200' RKB. PERFORMED MIT-T TO 2000#. PASSED, NO LOSS OF PRESSURE. PULLED TEST TOOL. *JOB COMPLETE, READY TO BOL. . 1J-168 DESCRIPTION OF WORK COMPLETED 02/03/15 (AC EVAL): RE-TIFL (PASSED). SUMMARY Initial T/I/O = 219/446/140. IA FL @ 6203' (station#2, OV). SI wellhead @ WV&double block AL. Pressured tubing w/lift gas from the AL line up stream of the choke for 1 hour(1200 psi available). T/I/O = 625/435/140. IA FL @ same location. Continued to stack tubing pressure w/lift gas for an additional 1 hour. (2 hours total). Stacked WHP's to 650/435/140. IA FL @ same location. Bled IA from 435 psi to 180 psi in 2 hours. T/I/O =675/180/140. IA FL @ same location. Monitor for 1 hour. 15 min T/I/O = 675/180/140. 30 min T/I/O = 680/180/140. IA FL @ same location. 45 min T/I/O = 680/180/140. 60 min T/I/O =685/180/140. IA FL @ same location. (Passed). Final T/I/O = 685/180/140. Summary Set 22' retrievable tubing patch across leaking GLM. Follow-up TIFL confirmed integrity. - - KUP PROD 1J-168 " ConocoPhillips ; Well Attributes Max Angle&MD TD Alaska,Inc. Wellbore API/UWI Field Name Wellbore Status ncl 1') MD(ftKB) Act Ste(ftKB) Ccmocclaly, 500292326000 WEST SAK PROD 93.12 11,172.18 12,995.0 ,-, Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) -Rig Release Date 12-166,1/17/2015 8 01.27 AM SSSV:NIPPLE 60 12/16/2013 Last WO: 9/10/2008 31.01 9/262005 Vertical schemata(actual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date tI�� --- J'''- Last Tag:SLM 7,067.0 12/12/2013 Rev Reason:GLV C/O hipshkf 1/17/2015 Casing Strings Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)... Wt/Len(I...Grade Top Thread ' ""' " ' ' '- If 1'°j' F CONDUCTOR Insulated 16 15.062 26.0 80.0 80.0 62.50 H-40 WELDED Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)...Wt/Len(I...Grade Top Thread ''- __ SURFACE 103/4 9.950 30.0 3,693.9 2,116.4 45.50 L-80 BTC __ Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)...Wt/Len(I...Grade Top Thread .r.CONDUCTOR Insulated;26.0- e,...,,,,,,‘,...,INTERMEDIATE 75/8 6.875 26.3 8,224.0 3,466.1 29.70 L-80 BTCM 80.0 Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth)T/D)...Wt/Len(I...Grade Top Thread NIPPLE;499.7 - D LINER LEM 4 12 3.958 6,706.8 7,128.0 3,291.2 12.60 L-80 IBTM I Liner Details Nominal ID Top(ftKB) Top(TVD)(ftKB) Top Incl('I Item Des Com (In) SURFACE;30.O-3,6939- IL6,706.8 3,194.6 75.49 SLEEVE 5.75"ID Tie back sleeve 5.750 6,717.8 1197.4 75.48 PACKER 5.5"x7.625""HRD"ZXP Liner Top Packer w/hold 4.960 GAS LIFT;4,210.61(.7! down slips 6,725.5 3,199.3 75.48 SBE 190-47 Casing Seal Bore Recepetacle 6.30"OD x 4.750 4.75"ID GAS LIFT;6,203.2---- 3,208.1 75.23 NIPPLE DB Nipple 3.75"ID,4.5"IBTM Box x Pin 3.750 _-- 6,773.7 3,211.5 75.11 HANGER LEM Above Hook Hanger 1970 NIPPLE;6,649.1 6,780.5 3,213.3 75.05 HANGER LEM Below Hook Hanger 3.930 GAUGE;6,650.6 7,124.8 3,290.7 80.14 SEAL ASSY 190-47 Non-Locating Seal Assembly 3.880 Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... Wt/Len(I...Grade Top Thread LOCATOR;6,702.8 B LINER LEM 41/2 3.958 7,096.7 7,299.9 3,320.6 12.60 L-80 IBT 1 '$' 1 Liner Details SEAL ASSY;6.703.9 - Nominal ID Top(ftKB) Top(ND)(ftKB) Top Incl(") Item Des Com (in) 7,096.7 3,285.8 79.91 PACKER ZXP LINER TOP PACKER 5.510 7,115.7 3,289.1 80.14 SBR CASING 109-47 SEAL BORE RECEPTACLE 4.750 -_ 7,134.9 3,292.4 80.15 XO BUSHING 4.750 7,143.9 3,293.9 80.15 HANGER LEM ABOVE HOOK HANGER 3.970 7,154.6 3,295.8 80.15 HANGER LEM BELOW HOOK HANGER,ISO SLEEVE 3.930 3.563 3.880 0-SAND LINER;6,780.5- 3.69"X19'SET AT 7158 12,942.7 7,221.5 3,3072 80.17 NIPPLE CAMCO DB-6 NIPPLE 7,296.6 3,320.0 80.22 SEAL ASSY BAKER SEAL ASSEMBLY Casing Description KB) ND)...WtlLen(I... Top Thread Grade B LINER HH I OD(in)4 121 ID(in) Top(ftKB)3.958 7,147.91 Set Depth(ft7,402.81 Set Depth(3,337.5 12.60 L-80 IBT finer Details -.-- Nominal ID Top(ftKB) Top(ND)(ftKB) Top Incl('I Item Dec Com (in) D LINER LEM,6,706.8-7,1280 7,147.9" 3,294.6 80.15 HANGER BAKER MOVEL B-1 HOOK HANGER 5.300 e 7,170.8 3,298.5- 80.15 XO BUSHING CROSSOVER BUSHING 3.960 I 7,241.5 3,310.6 80.18 ECP BAKER PAYZONE EXTERNAL CASING PACKER 3.950 7,359.7' 3,330.5 80.60 BENT JT 3.960 Casing Description IOD(in) IID(in) -Top(ftKB) ISet Depth(ftKB) ISet Depth(ND)...I WULen(I...l Grade I Top Thread A-SAND LINER 4 1/2 3.958 7,2458 12,975.0 3,651.4 12 60 L-80 IBT -_ Liner Details Nominal ID Top(ftKB) Top(ND)(ftKB) Top Incl I') Item Des Com (in) 7,245.8 3,311.4 80.18 PACKER "HRD"ZXP Liner Top Packer 5.5"X 7.6" 5.500 7,264.9 3,314.6 80.19 NIPPLE "RS"Packoff Seal Nipple 5.5" 4.875 7,267.7 3,315.1 80.20 HANGER FlexLock Liner Hanger 5.5"X 7.6" • 4.853 7,277.6 3,316.8 80.20 SBE 190-47 Casing Seal Bore Ext.4.75-ID x 6.25"OD 4.750 7,297.0 3,320.1 80.22 XO BUSHING XO Bushing 3.92"ID,6.02 OD 3.920 1 f p,Ill Tubing Strings Tubing Description String Me...ID(in) Top(ftKB) Set Depth(ft..Set Depth(TVD)(...WI(lblft) Grade Top Connection A r _Lt'r TUBING WO 41/2 3958 22.5 6,131.2 3,200.7 12.60 L-80 IBTM Completion Details " Nominal ID .F Top(ftKB) Top(ND)( ftKB Top Incl Item Des Com (in) i W. 22.5 22.5 0.07 HANGER 2 :=. E.1rij 5.95 NIPPLE Vetco Gray Hanger 11 x 4.5"w/4.909"MCA Top Conn. 3.900 Made up on full B LINER LEM;7,096.7-7,299.9 499.7 499.2 3.875"'DB'Nipple 3.875 6,649.1 3,180.2 75.50 NIPPLE 3.812"'DB'Nipple 3.812 B LINER MH;7,147.9-7,402.6 6,650.6 3,180.5 75.50 GAUGE Baker Guardian Gauge 3.958 6,702.8 3,193.6 75.49 LOCATOR Locator Sub 3.990 6,703.9 3,193.9 75.49 SEAL ASSY Bonded Seal Assembly w/Full Mule Shoe w/2'space out 3.870 INTERMEDIATE;26.38,224.0 t- Perforations&Slots SLOTS;8,474.0-8,659.0--• .- Shot Den SLOTS;8,876.08,274.0 Top(ND) Btm(ND) (shots/f Top(ftKB) Btm(ftKB) (ftKB) (ORB) Zone Date t) Type Corn 8,474.0 8,659.0 3,477.2 3,481.3 WS A2,1J- 8/31/2005 32.0 SLOTS ALL SLOTS:Alternating SLOTS;9,582.0-9.861.0 T 168 slotted/solid pipe 0.125" - x2.5"x32spf@ 4 - Circumferential adjacent SLOTS;10,170.040,263.0- rows,3"Centers staggered 18 deg.,3 h. non-slotted ends SLOTS;10,5120.11,248.0 4- 8,876.0 9,274.0 3,489.7 3,502.9 WS A2,1J- 8/31/2005 32.0 SLOTS 168 SLOTS;11,464.0.12,631.0 r 9,582.0 9,861.0 3,512.1 3,533.6 WS A2,1J- 8/31/2005 32.0 SLOTS 168 SLOTS;12,912.0-12,942.0 10,170.0 10,263.0 3,558.1 3,564.8 WS A2,1J- 8/312005 32.0 SLOTS 168 A-SAND LINER;7,245.8- 12,975.0-s- ConocoPhillips 01 KUP PROD 1J-168 Aaska,Inc. (,.x u,dlvELp, 1J-168,1/17/2015 8:01:28 AM Vertical schematic(actual) Perforations&Slots Shot ,.. Dens TopBtm(ND) (shotsff B Top(ftKBtm(ftKB) (pKB)KB) (ftKB) Zone Date t)t) Type Com 10,512.0 11,248.0 3,581.5 3,574.0 WS A2,1J- 8/31/2005 32.0 SLOTS ,A CONDUCTOR Insulated;260- 168 80'0 11,464.0 12,631.0 3,564.9 3,609.0 WS A2,1J- 8/31/2005 32.0 SLOTS NIPPLE;499.7 , 168 12,912.0 12,942.0 3,642.9 3,646.6 WS A2,1J- 8/31/2005 32.0 SLOTS 168 SURFACE;30.03.693.9— -. Mandrel Inserts St GAS LIFT;4,210.6 atii N Top(ftKB) Top (ftKB)D) Make Model OD in Sees Tylvepo Latch Port Size TRO Run -- ( ) Type Type (in) (psi) Run Date Com - 1 4,210.6 2,303.9 Camco KBG-2- 1 GAS LIFT GLV BK 0.156 1,477.0 1/9/2015 1R KB GAS LIFT,6,203.2 a.._ 2 6,203.2 3,051.0 Camco KBG-2- 1 GAS LIFT OPEN 0.000 0.0 1/16/2015 &Safety NIPPLE;6649.1 = Notes::General: Safety GAUGE;6,6506 End Date Annotation it 9/26/2005 NOTE:MULTI-LATERAL WELL: A-SAND(1J-168),B-SAND(1J-168L1),D-SAND(1J-168L2) LOCATOR;6.702.8 9/16/2008 NOTE:View Schematic w/Alaska Schematic9.OREV n SEAL ASSY;6703.9 2 a D-SAND LINER;0,700.5- , 12.942.7 r7*. D LINER LEM;6,706.8-7,128.0 IP I M MI ,'a nom-.. MI B LINER LEM;7.096.7-7,299.9 B LINER HO;7,147.91,402.8 INTERMEDIATE;26.3-8,224.0 SLOTS 8,474.08,659.0 SLOTS;8,876.0.9,274.0 SLOTS;9,582.0.9,861.0 SLOTS;10,170.010,263.0 SLOTS;10.512.0-11,248.0 _ SLOTS;11 464.042,6316 — ,4 SLOTS;12,912.0-12,942.0 l- ASAND LINER;7245.8- 12,975.0' - 295- o,0 2- 3-1 I WELL LOG TRANSMITTAL DATA LOGGED . 5 i2oi K BENDER To: Alaska Oil and Gas Conservation Comm. January 20, 2015 Attn.: Makana Bender 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 FEB 05 ?015 RE: Multi Finger Caliper(MFC) &Leak Detect Log (LDL): 1J-168 ,r� (' . ;° Run Date: 1/13/2015 - 1/14/15 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Chris Gullett, Halliburton Wireline& Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 FRS_ANC@halliburton.com 1J-168 Digital Data (LAS), Digital Log file, Casing Inspection Report, 3D Viewer 1 CD Rom 50-029-23260-00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LET1'bR TO THE ATTENTION OF: Halliburton Wireline&Perforating Attn: Chris Gullett 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-273-3527 y Fax: 907-273-3535 FRS_ANC@halliburton.com Date: Signed: 6.edizat • • Image Project Well History File Cover Page XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. 0 .~- ~ ~p(~ Well History File Identifier Organizing ~done> ^ Two-sided ~~~ ~~~~ ~~ ~~ ~~ ~ ~~ ~~~ --- ^ Rescan Needed III IIII II II I I III III RESCAN DIGITAL DATA OVERSIZED (Scannable) '~olor Items: Diskettes, No. ~ ^ Maps: ^ Greyscale Items: ^ Other, No/Type: ^ Other Items Scannable by a Large Scanner ^ Poor Quality Originals: OVERSIZED (Non-Scannable) ^ Other: ^ Logs of various kinds: NOTES: ^ Other:: BY: Maria Date: I l © / / s ProjectProofing I III III III II II I III I BY: Maria Date: f ~ V /s! Scanning Preparation ~ x 30 = ~ + =TOTAL PAGES -G (fount does not include cover sheet} BY: Maria Date: ~ ~ ~ ~ ~ / ~ /~' /s/ ~ '~ Production Scanning Stage 1 Page Count from Scanned File: ~ (Count does include cover sheet) Page Count Matches Number in Scanning Preparation: ~ YES _ BY: Maria Date: `I /~ ~/Q Stage 7 If NO in stage 1, page(s) discrepancies were found: YES BY: Maria Date: Scanning is complete at this. point unless rescanning is required. -,~P rsllIIIIIIIIIIIIIIII ReScanned BY: Maria Date: /s/ Comments about this file: a~e,.~~e~Kea iiiumuuuiuu 10/6/2005 Well History File Cover Page.doc • • SELL L~ J ~y~.f. y Ti4~4N~M-Il"~®4L 4:; ~~~ ~~.~ ProActive Diagnostic Services, Ina. To: AOt~C Christine Mahnken 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 (907J 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 ProActive Diagnostic Services, Inc. Attn: Robert A. Richey 130 West International Airport Road Suite C Anchorage, AK 99518 Fa~c (907) 245-8952 1 J Production Profie 13-Dec-08 1 J-168 1 Color Log / EDE 50-029-2326000 2) ~., .,% ,. Signed : %_ __ Date ~~".~°~ ~'. ~~ ~'i~9~ Print Name: `~ PROACTIVE DIAGNOSTIC SERVICES, INC., 130 W. INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245-8951 FAX: (907)245-88952 E-MAIL : 62dsanchora~(a7memorvlog,com WEBSITE : www.rr~~ratorylerg.com C:\Documen6 and Settings\(hvneilDesktop\Tiar~smit_Canow.do~ac • on P ' ' C oco hillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 • November 27, 2008 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7~' Avenue, Suite 100 Anchorage, AK 99501 ~s ~~~ J ~' ~(~8 l 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 Novemberl7, 2008. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please call MJ Loveland or Perry Klein at 907-659-7043, if you have any questions. ConocoPhillips Well Integrity Projects Supervisor • • ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) Kuparuk Field n~+~ 1 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 1F-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-123 207-070 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 1J-166 205-198 12" NA 12" NA 8.5 11/7/2008 1 J-168 205-060 10" NA 10" NA 3.82 11 /7/2008 1 J-170 206-062 8" NA 8" NA 1 11 /7/2008 1J-174 207-143 24" NA 24" NA 17 11/7/2008 1J-178 207-121 12" NA 12" NA 5.95 11/7/2008 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION ~,_. REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Abandon ^ Repair Well ~ ~ Plug Pertorations ^ Stimulate ^ Other ^ Alter Casing ^ Pull Tubing Q' Perforate New Pool ^ Waiver ^ Time Extension ^ 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 ^ 205-060 / • 3. Address: Stratigraphic ^ Service ^ 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-029-23260-00 7. KB Elevation (ft): 9. Well Name and Number: RKB 22.46' 1 J-168 • 8. Property Designation: 10. Field/Pool(s): ADL 25661, 25660 ~ Kuparuk River Field /West Sak Oil Pool 11. Present Well Condition Summary: Total Depth measured 12995' ' feet true vertical 3654' ~ feet Plugs (measured) Effective Depth measured 12973' feet Junk (measured) true vertical 3651' feet Casing Length Size MD TVD Burst Collapse Structural CONDUCTOR 80' 20" 102' 10~~~~~ii"~~ ~~`,~ ~' ~ j~~~~" SURFACE 3664' 10-3/4" 3694' ,~~:. 2115' INTERMEDIATE 8198' 7-5/8" 8224' 3472' LINER 5730' 4.5" 12975' 3653' Perforation depth: Measured depth: 8474'-8659', 8876'-9274' , 9582'-9861', 10170'-10263 ', 10512'-11248', 11464'-12631', 12912'-12942' true vertical depth: 3473'-3482', 3488'-3505', 3512'-3532', 3558'-3564',3581'-3574', 3565'-3609', 3643'-3647' Tubing (size, grade, and measured depth) 4.5", L-80, 6731.16' MD. Packers 8 SSSV (type & measured depth) 3 HRD ZXP liner top packers @ 7246' (A-sand), 7097' (B sand), 6718' (D sand) DB' nipple @ 500' 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 910 1640 3 -- 184 Subsequent to operation 764 1621 259 - 204 14. Attachments 15. Well Class after work: Copies of Logs and Surveys run _ Exploratory ^ Development ^~ Service ^ Daily Report of Well Operations _X 16. Well Status after work: Oil^~ Gas ^ WAG ^ GINJ ^ WINJ ^ WDSPL ^ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: none Contact Brett Packer @ 265-6845 Printed Name Brett Packer Title Wells Engineer J ~ _ Signature "" ~~ _ -~ ~ ~.t ' Phone: 265-6845 Date ( ~ ~ /~ `~ / ~ ~~l Pre aced h r n A!!su Drake 263-4612 ~ f3v.~ Form 10-404 Revised 04/2006 ~ ~ ;,`'. ` y, Submit Original Only ~~ It~~r'-t~ "--~ KUP ~. - ' ~ y ~U1"1fJCCI~~"lll~lp$ ! Well Attributes weuhore Ar'uuvu e~ea Naas, ' I 500292326000 WEST SAK ... uric uiga: s, nc9oa liai: -:-,• Comment .. S_SSV: NIPPLE H2S (PPn 60 sche±~a~K Act~l ~Annota»on Depth (RKB) End Date L, ~ ~.t Taq: Casing Strings c ~ ~~/~ NIPPLE, SDD SURFACE, a3,s94 8,700 D-SAND SBR Lt, 7,116 D-SAND LEM, fi,70]-],126 XO BUSHING, 7,135 HANGER L1, ],100 B-SAND WINDOW, 7.14&7,15] 1a,nalD,ze3 SLOTS, 1D,512-11,248 SLOTS, 77,48412, 637 SLOTS, 12,972-12,942 D-SAND L2 LINER, 6,781-12,943 • 1 J-168 Yieil SCalus '~~G,netio it ~ n1C1~Ui IWal Laplh )tiKB) ~ 93.12 PROD ~ 11,172.18 12,995.0 ate (Annotation !End Date IKBGrd (R) Rig Release Date 711/2008 '~LastWO: ~ 9(10/2008 31.01 9Y26Y1005 4ation (End Date Reason: WORKOVER, GLV C/O 9/1 612 0 0 8 1 asmg cscriptwn I CONDUCTOR I SUin-. 16 string l..., 15.062 ~ lop )nna) 0.0 Set Ucpln )tt.. 80.0 Sa uopm (IVU)(R... 80.0 sung ... 62.50 ~uin..•I H-40 ~ sznng lop rnra WELDED I (Casing Deseripton Strip... String I... ( Top (RKB) Set Depth (K.. Set DepM (ND) (R... ( String ... Strip... String Top Thrd !SURFACE 103/4 9.794 0.0 3,694.0 2,117.9 j 45.50 L-80 ; BTC ICesing Description ~ Strin... String I... Top (RKB) Set Depth (R.. Set DepM (ND) (R... 1 5trirg ... Strip... Skiing Top Thrtl (INTERMEDIATE 75/8 6.875 I 0.0 ~ 8,224.0 3,466.0 29.70 L-80 BTCM Casing Description Strip... String 1... Top (RKB( I Set Depth (R... Set Depth (ND) (R... Stdng ... Strip... Shang Top Thrd 0.SAND LEM 4 1Y1 3.958 6,706.8 ~ 7,128.0 3,291.2 72.60 L-80 IBTM Casing Deseripton Strip... Skiing 1... Top (RKB) ( Set Depth (tt.. Set Depth (ND) IR... String ... Strip... String Top Thrd 0.SAND WINDOW 75/8 6.875 6,797.0 j 6,826.0 3,223.0 29.70 ; L-80 BTCM _ Casing Descriptlon Strip... Skiing I... Top (RKB) Set Depth (tt.. Set Depth (TVD) In... Shang .- SMn... String Top Thrd BSAND WINDOW 75/8 6.875 7,145.0 7,157.0 3,296.2 29.70 L-80 BTCM Casing Descripton Strip... String I... Top (RKB) Set Depth (R.. Set Depth (TVDI IR.. String ... Shin... String Top Thrd A-SAND LINER 41/2 3ASR 7.245 A 12,975.0 s fist 4 12.60 ! -?0 IRT Liner Details rop iron) (rem rxsenpmn 7,245.8 PACKER comment "HRD" ZXP Liner Top Packer 5.5" X 7.6" m pn) 5.500 7,264.91 NIPPLE 1 "RS" PackoN Seal Nipple 5.5" 4.875; I 7,267.7 HANGER ~ FlexLOCk Liner Hanger 5.5" X 7.6" 4.853 7,277.6 SBE 7 ~q~ n xn 1190-07 Casing Seal Bore EM. 4.75"ID x 6.25" OD vn R„ahlnn ~ o~" In a m nn 4.750 ~ q~n Tubing Strings I b nr~ Dcs, F ion Stn I JD _iring ID I... Top In.. ct ^rpth (fiN Scl De ytM1 (TVL InkBl nn~ l`Jt St in Siring Iop rhr~f ~TU51Nli I 41f1 Is 3.ySts I D.V I 1i,731.Y I S,ZD0.7 I tY.bU I L-$U I IBTM 1J- y f I i -.. I I i FEI 1 1 i - 1 1 A-SAND LINER, ],24612,9]5 TD (1J-16B), 12,995 12,912.0~12,942.0~ 3,643.11 3,646.7SLOTS WS A2, 1J-168 ~ 32.0(8131/2005 Notes: Gelttaral & safety Perforations fop dtm I Sho[ lop Btm (TVD) (ND) Dena (RKB) (RKB) (RKB) ~ (RKB) Type Zone Isho... Date , Comment 8,474.0 8,659.0 3,473.41 3,482.4 SLOTS WS A2, 1J-168 32.0 8/31Y2005 ALL SLOTS: Alternating slottedlsolid pipe 0.125" x 2.5" x 32 spf @ 4 Circumferential adjacent rows, 3" ~ Centers staggered 18 deg., 3 ft. I ! non-slo»ed ends I Mandr®I Details Set Depth Port Top ITVD) Valve Latch I Size 7R0 Run j Sin (RKB) (RKB) Make Model OD lint TYPe TYPe '. Iln) (Psi) ~~ Run Date '.. Comment • r~ Time Log & Summary ConocoPhillips w~,~~~, ~~~ Ra~A,~R9 Report - _ _ -- - Well Name: 1J-168 Rig Name: NORDIC 3 Job Type: RECOMPLETION Rig Accept: 9/2/2008 5:30:00 PM Rig Release: 9/9/2008 8:30:00 PM _Time Logs - __ _ _ - - - _ Date From To Dur S Depth E. Depth Phase Code Subcode T Comment___ _____ 8/29/2008 2a hr Summary Standby with rig crews while placing mats for moving rig on. Move Nordic rig 3 off 1C-184 to SWTP "Y" 00:00 08:30 8.50 MIRU MOVE MOB P Standing by w/ Nordic Rig 3 crews while settin mats to ull off 1 C-Pad. 08:30 09:00 0.50 MIRU MOVE MOB P Moving rig on 1C Pad on mats. 09:00 11:00 2.00 MIRU MOVE MOB P Standing by w/ crews while setting mats to ull off 1C-Pad. 11:00 11:30 0.50 MIRU MOVE MOB P Moving rig on 1C Pad on mats. 11:30 12:30 1.00 MIRU MOVE MOB P Standing by w/ crews while setting mats to ull off 1C-Pad. 12:30 13:00 0.50 MIRU MOVE MOB P Move rig around corner of pad and off mats. 13:00 18:30 5.50 MIRU MOVE MOB P Stage mats on road off of 1C-Pad. Remove 13 5/8 BOPE from Cellar and place on skid, while staging mats. 18:30 19:30 1.00 MIRU MOVE MOB P Move rig to end of pad and onto mats then moving down 1C Pad access road. 19:30 21:30 2.00 MIRU MOVE MOB P Standby with rig crews while staging mats ahead of ri . 21:30 22:00 0.50 MIRU MOVE MOB P Move rig ahead to SWTP "Y" 22:00 00:00 2.00 MIRU MOVE MOB P Standby with rig crews while staging mats ahead of ri . 8/30/2008 Continue to standby with rig crews while placing mats for moving rig on and move rig to KCC Parking lot. 00:00 02:30 2.50 MIRU MOVE MOB P Standby with rig crews while staging mats ahead of ri . 02:30 03:00 0.50 MIRU MOVE MOB P Move rig ahead of SWfP "Y" 03:00 06:30 3.50 MIRU MOVE MOB P Standby with rig crews while staging mats ahead of ri . 06:30 07:00 0.50 MIRU MOVE MOB P Move rig ahead of SWTP "Y" towards KIC "Y" 07:00 09:00 2.00 MIRU MOVE MOB P Standby with rig crews while staging mats ahead of ri . 09:00 09:30 0.50 MIRU MOVE MOB P Move rig ahead of SWTP "Y" towards KIC "Y" 09:30 11:30 2.00 MIRU MOVE MOB P Standby with rig crews while staging mats ahead of ri . 11:30 12:00 0.50 MIRU MOVE MOB P Move rig ahead of SWTP "Y" towards KIC "Y" 12:00 16:00 4.00 MIRU MOVE MOB P Standby with rig crews while staging mats ahead of ri . 16:00 16:30 0.50 MIRU MOVE MOB P Move rig ahead of SWTP "Y" towards KIC "Y" ~..~.. _..__. ~ - _® _ F~~g~ 1 tit ~ • r~ Time Logs Date From To ____ Dur 5 De th E. De th Phase Code____ Subcode T Comment __ 16:30 18:30 2.00 MIRU MOVE MOB P Standby with rig crews while staging mats ahead of ri . 18:30 20:30 2.00 MIRU MOVE MOB P Move rig ahead KCC parking lot. 20:30 00:00 3.50 MIRU MOVE MOB P Standby with rig crews while staging mats ahead of ri . 8/31 /2008 Continue to standby with rig crews while placing mats for moving rig on and move rig from KCC Parking lot towards 1J-Pad. 00:00 01:00 1.00 MIRU MOVE MOB P Standby with rig crews while staging mats ahead of ri . 01:00 04:00 3.00 MIRU MOVE MOB P Move rig from KCC parking lot to 1J Pad access road 04:00 06:30 2.50 MIRU MOVE MOB P Standby with rig crews while staging mats ahead of ri . 06:30 07:00 0.50 MIRU MOVE MOB P Move rig forward on 1J Pad access road 07:00 10:30 3.50 MIRU MOVE MOB P Standby with rig crews while staging mats ahead of ri . 10:30 11:00 0.50 MIRU MOVE MOB P Move rig forward on 1J Pad access road 11:00 12:00 1.00 MIRU MOVE MOB P Standby with rig crews while Double stack mats behind ri , 12:00 12:30 0.50 MIRU MOVE MOB P Move rig back on double mats. 12:30 13:30 1.00 MIRU MOVE MOB P Standby with rig crews while staging mats ahead of ri . 13:30 14:00 0.50 MIRU MOVE MOB P Move rig forward on 1J Pad access road 14:00 15:00 1.00 MIRU MOVE MOB P Standby with rig crews while Double stack mats behind ri , 15:00 15:30 0.50 MIRU MOVE MOB P Move rig back on double mats. 15:30 16:00 0.50 MIRU MOVE MOB P Standby with rig crews while staging mats ahead of ri . 16:00 16:30 0.50 MIRU MOVE MOB P Move rig forward on 1J Pad access road 16:30 17:00 0.50 MIRU MOVE MOB P Standby with rig crews while Double stack mats behind ri , 17:00 17:30 0.50 MIRU MOVE MOB P Move rig back on double mats. 17:30 19:00 1.50 MIRU MOVE MOB P Standby with rig crews while staging mats ahead of ri . 19:00 19:30 0.50 MIRU MOVE MOB P Move rig forward on 1J Pad access road 19:30 20:30 1.00 MIRU MOVE MOB P Standby with rig crews while Double stack mats behind ri , 20:30 21:00 0.50 MIRU MOVE MOB P Move rig back on double mats. 21:00 22:30 1.50 MIRU MOVE MOB P Standby with rig crews while staging mats ahead of ri . 22:30 23:00 0.50 MIRU MOVE MOB P Move rig forward on 1J Pad access road 23:00 00:00 1.00 MIRU MOVE MOB P Standby with rig crews while Double stack mats behind ri , 9/01/2008 Continue to standby with rig crews while placing mats for moving rig on and move rig towards 1J-Pad. 00:00 01:00 1.00 MIRU MOVE MOB P Continue to standby with rig crews while Double stack mats behind ri , F~ar~~ 2 ~f 9 Time Logs __ _- _ - IDate From To Dur S De th E. De th Phase Code Subcode T Comment 01:00 01:30 0.50 MIRU MOVE MOB P Move rig back on double mats. 01:30 03:00 1.50 MIRU MOVE MOB P Standby with rig crews while staging mats ahead of ri . 03:00 03:30 0.50 MIRU MOVE MOB P Move rig forward on 1J Pad access road 03:30 05:00 1.50 MIRU MOVE MOB P Standby with rig crews while Double stack mats behind ri , 05:00 05:30 0.50 MIRU MOVE MOB P Move rig back on double mats. 05:30 07:00 1.50 MIRU MOVE MOB P Standby with rig crews while staging mats ahead of ri . 07:00 07:30 0.50 MIRU MOVE MOB P Move rig forward on 1J Pad access road 07:30 08:30 1.00 MIRU MOVE MOB P Standby with rig crews while Double stack mats behind ri , 08:30 09:00 0.50 MIRU MOVE MOB P Move rig back on double mats. 09:00 10:00 1.00 MIRU MOVE MOB P Standby with rig crews while staging mats ahead of ri . 10:00 10:30 0.50 MIRU MOVE MOB P Move rig forward on 1J Pad access road 10:30 11:30 1.00 MIRU MOVE MOB P Standby with rig crews while Double stack mats behind ri , 11:30 12:00 0.50 MIRU MOVE MOB P Move rig back on double mats. 12:00 13:00 1.00 MIRU MOVE MOB P Standby with rig crews while staging mats ahead of ri . 13:00 13:30 0.50 MIRU MOVE MOB P Move rig forward on 1J Pad access road 13:30 14:30 1.00 MIRU MOVE MOB P Standby with rig crews while Double stack mats behind ri , 14:30 15:00 0.50 MIRU MOVE MOB P Move rig back on double mats. 15:00 16:00 1.00 MIRU MOVE MOB P Standby with rig crews while staging mats ahead of ri . 16:00 16:30 0.50 MIRU MOVE MOB P Move rig forward on 1J Pad access road 16:30 18:00 1.50 MIRU MOVE MOB P Standby with rig crews while Double stack mats behind ri , 18:00 18:30 0.50 MIRU MOVE MOB P Move rig back on double mats. 18:30 19:30 1.00 MIRU MOVE MOB P Standby with rig crews while staging mats ahead of ri . 19:30 20:00 0.50 MIRU MOVE MOB P Move rig forward on 1J Pad access road 20:00 21:00 1.00 MIRU MOVE MOB P Standby with rig crews while Double stack mats behind ri , 21:00 21:30 0.50 MIRU MOVE MOB P Move rig back on double mats. 21:30 22:30 1.00 MIRU MOVE MOB P Standby with rig crews while staging mats ahead of ri . 22:30 23:00 0.50 MIRU MOVE MOB P Move rig forward on 1J Pad access road 23:00 00:00 1.00 MIRU MOVE MOB P Standby with rig crews while Double stack mats behind ri , 9/02!2008 Continue to standby with rig crews while placing mats for moving rig on and move rig to 1J-Pad. Spot and set up equipment on 1J-168. Accept Nordic Rig 3 @ 1730 hrs. Lubricate out BPV and RU to Circulate and kill well. Page ~ cf 9 r 1 Time Lo~_ --- -- _ Date _ From To Dur S. De th_ E Depth Phase Code _ Subcode T Comment 00:00 00:30 0.50 MIRU MOVE MOB P Move rig back on double mats. 00:30 02:00 1.50 MIRU MOVE MOB P Standby with rig crews while staging mats ahead of ri . 02:00 02:30 0.50 MIRU MOVE MOB P Move rig forward on 1J Pad access road 02:30 04:00 1.50 MIRU MOVE MOB P Standby with rig crews while Double stack mats behind ri , 04:00 04:30 0.50 MIRU MOVE MOB P Move rig back on double mats. 04:30 05:30 1.00 MIRU MOVE MOB P Standby with rig crews while staging mats ahead of ri . 05:30 06:00 0.50 MIRU MOVE MOB P Move rig forward on 1J Pad access road 06:00 07:30 1.50 MIRU MOVE MOB P Standby with rig crews while Double stack mats behind ri , 07:30 08:00 0.50 MIRU MOVE MOB P Move rig back on double mats. 08:00 08:30 0.50 MIRU MOVE MOB P Standby with rig crews while staging mats ahead of ri . 08:30 09:00 0.50 MIRU MOVE MOB P Move rig forward on 1J Pad access road 09:00 10:00 1.00 MIRU MOVE MOB P Standby with rig crews while Double stack mats behind ri , 10:00 10:30 0.50 MIRU MOVE MOB P Move rig back on double mats. 10:30 11:30 1.00 MIRU MOVE MOB P Standby with rig crews while staging mats ahead of ri . 11:30 12:00 0.50 MIRU MOVE MOB P Move rig forward on 1J Pad access road 12:00 13:00 1.00 MIRU MOVE MOB P Standby with rig crews while Double stack mats behind ri , 13:00 13:30 0.50 MIRU MOVE MOB P Move rig back on double mats. 13:30 14:00 0.50 MIRU MOVE MOB P Standby with rig crews while staging mats ahead of ri 14:00 14:30 0.50 MIRU MOVE MOB P Move rig forward on 1J Pad access road 14:30 15:30 1.00 MIRU MOVE MOB P Standby with rig crews while Double stack mats behind ri , 15:30 16:00 0.50 MIRU MOVE MOB P Move rig back on double mats. 16:00 16:30 0.50 MIRU MOVE MOB P Standby with rig crews while staging mats ahead of ri . 16:30 17:00 0.50 MIRU MOVE MOB P Move rig forward on 1J Pad access road 17:00 17:30 0.50 MIRU MOVE MOB P Move rig to back side of pad by well 1 J-168 COMPZ RPCOM OTHR P Accept Nordic Rig 3 @ 17:30 hrs on 9-2-08. 17:30 19:00 1.50 MIRU MOVE OTHR P Install foot beam and Set back 13 5/8 BOP on stum . 19:00 20:30 1.50 MIRU MOVE OTHR P Set Pit liner and 'T" mats along with 9 - 40" Rig mats. Spot and level rig on 1 J-168. 20:30 22:00 1.50 COMPZ RPCOM OTHR P RU hose in cellar to kill well. Obtain SIP's - OA = 150 psi., IA=650 psi. RU lubricator and lub out BPV. SITP= 750 psi. Load Pits 290 bbls of Sea water w/ 6% KCL. ~m~_ ~ ~~c~c ~ of ~ Time Logs Date From To Dur 5. De th E. De th Pha~e_ Code Subcode T Comment _ 22:00 00:00 2.00 COMPZ RPCOM OTHR P Set Berm and spot Kill tank. RU hard line. 9/03/2008 PT kill lines and Kill well. Set BPV and ND Tree NU BOPE. Test BOPE. Unland hanger and make sure i e is free. Circulate well w/ Hot Kill Fluid. 00:00 06:00 6.00 COMPZ WELCTL CIRC P PT Lines lines to 1,000 psi. Bleed down IA from 675 psi to 180 psi. Circulate 251 bbls 6% KCL Seawater @ 2 bpm @ 500 psi ICP & 40 psi FCP. 0 psi IA pressure. IA on Vacuum. Bullhead 200 bbls down IA 3 b m 50 si. 06:00 06:30 0.50 COMPZ WELCTL OWFF P Monitor well -well dead. 06:30 07:00 0.50 COMPZ WELCTL OTHR P Set BPV. 07:00 14:00 7.00 COMPZ WELCTL NUND P PJSM, ND tree, install blanking plug. NU BOPE. 14:00 15:30 1.50 COMPZ RPCOM RURD P Loading ESP Cable spooler. 15:30 20:30 5.00 COMPZ WELCTL BOPE P Pressure testing BOPE 250/2500 psi. AOGCC (Lou Grimaldi) waived test on 9/3/08 13:20. 20:30 21:30 1.00 COMPZ WELCTL CIRC P Had pressure build up under BPV, Pump 1 tbg vol, 90 bbls down TBG 2 b m 50 si. 21:30 22:00 0.50 COMPZ WELCTL OTHR P Pull BPV 22:00 23:00 1.00 COMPZ RPCOM OTHR P MU Landing jt, BOLDS, Unland hanger @ 150k and Pull up 5' to veri TBG strin free 100k u wt. 23:00 00:00 1.00 COMPZ RPCOM CIRC P Held PJSM w/ crew and LRS on Pumping 160? Sea water. RU LRS and PT @ 2,000 psi. Pump 100 bbls 160? Seawater down TBG @ 2 bpm 365 si. 9/04/2008 Continue to Circulate 160? Seawater down IA, Pooh w/ 4.5" Production assy. MU and Rih w/ CO assy. 00:00 03:00 3.00 COMPZ RPCOM CIRC P Continue to Pump 200 bbls 160? Seawater down IA @ 2 bpm @ 400 si w/ LRS. RD LRS. 03:00 03:30 0.50 COMPZ RPCOM OWFF P Monitor well. 03:30 04:30 1.00 6,131 6,100 COMPZ RPCOM PULD P Pull hanger to rig floor, disconnect ESP cable from penetrator and lay down han er't and landin ~t. 04:30 15:00 10.50 6,100 130 COMPZ RPCOM RCST P Run ESP cable through sheeve and Continue to POOH w/ 4.5" IBTM L-80 12.6# TBG and ESP a ui ment. 15:00 16:30 1.50 130 0 COMPZ RPCOM PULD P LD ESP completion equipment 16:30 19:00 2.50 0 COMPZ RPCOM OTHR P Clean and clear rig floor of ESP e ui ment. Unload i e shed. 19:00 20:30 1.50 COMPZ RPCOM OTHR P Load Clean out BHA in Pipe shed. 20:30 22:30 2.00 0 595 COMPZ RPCOM PULD P PJSM, PU and MU 4.5" Clean out and lateral wash ass . 22:30 00:00 1.50 595 956 COMPZ RPCOM TRIP P Continue to RIH w/ Clean out assy, PU and MU 3 1/2 DP Pumping 1 drill string vol every 1,000' and pumping 16 bbls down IA eve 1,000'. ~ e P~r~g 5 ;f ~ Time L©c,~s Date From To Dur S Depth E. Depth Phase Code Subcode T Comment _______ _ 9/05/2008 2a hr Summary Continue to PU and RIH w/ CO assy. Wash thru D sand hook and window. Pooh and LD CO assy. PU and RIH w/ D Sand LEM Ass . 00:00 09:00 9.00 956 6,700 COMPZ RPCOM TRIP P Continue to PU DP and RIH w! Clean out ass f/ 956' to 09:00 09:30 0.50 6,700 6,700 COMPZ RPCOM TRIP P Bottom nozzle at 6700'. Up wt = 110K, down wt = 70K. Pumping 5 bpm @ 1250 psi down the tbg, no returns. Close annular, pumping 6 bpm @ 50 psi down the IA, no returns. 09:30 11:00 1.50 6,700 7,134 COMPZ RPCOM FCO P RIH while washing @ 5 bpm. Nozzle @ 7100'. Up wt = 110K, down wt = 70K. No go at 7134' (corrected for RKB. 11:00 11:30 0.50 7,134 7,134 COMPZ RPCOM FCO P Reciprocate several time to wash across hook hanger, pumping 5 bpm @ 1250 psi. Shut annular and bullhead 50 bbl down the IA pumping 6 BPM 50 si. 11:30 16:00 4.50 7,134 592 COMPZ RPCOM TRIP P POOH with 3 x displacement and stand back 3-1/2" DP and wash BHA. 16:00 18:30 2.50 592 0 COMPZ RPCOM PULD P Stand Back DC's, Lay down Clean out Ass . 18:30 20:00 1.50 COMPZ RPCOM OTHR P Held PJSM on Offloading ESP Spool. Re loading Tec wire and Heat trace. 20:00 23:00 3.00 0 524 COMPZ CASING PUTS P PU and MU "D" Sand LEM #2 Assy w/Slim MWD tools and run inside LEM assy below ZXP packer. Shallow test MWD. 23:00 00:00 1.00 524 1,195 COMPZ CASING RUNL P Continue to Rih w/ LEM #2 assy to 1,195' 9/06/2008 Continue to RIH w/ LEM #2 Assy. Set ZXP and release ZXP running tool. PT IA to 2,500 psi. Pooh laying down DP. Load remainin 4.5' Com letion in i e shed. 00:00 07:00 7.00 1,195 7,100 COMPZ CASING RUNL P Continue to Rih w/ LEM #2 assy from 1,195' to 7100'. Up wt = 115K, down wt = 73K. Start pumping 3 bpm @ 250 psi. Intial orientation 23L. Rotate to 97R, RIH. Pa~~, 6 of 9 Time Logs Date From To Dur S De th E. De th Phase Code Subcode T Comment 07:00 10:00 3.00 7,100 7,127 COMPZ CASING OTHR P RIH to 7125' sit down 20K#, no indication of latch or orientation movement. PUH 25' with 120K#, no over pull coming off bottom. Rotate to 126L, RIH with 75K# and sit down 20K# at 7108'. PU and rotate several times to work past. RIH at 102L, sit down 15K# at 7125', weight dropped off 5K#, orientation turned to 35L. Sat down 20K# more, weight dropped off 10K#, orientation turned to 15R. Sit down 20K#, no change in orientation. PU to 135K#, remained latched in and orientation remained at 15R. Sit down 30K#, no change. Sit down 20K#, drop ball. Pump 31 bbl before seeing pressure increase. Pressure up to 2800 psi, pressure broke back to 2650 psi, giving an indication of HRD release. Pressure up to 3800 psi, pressure broke back to 3600 psi, neutralize pusher tool. PU 20K# (neutral weight), close annular, pressure test IA to 2500 psi. Bleed off pressure, open annular, pull out of ZXP packer with 120K# up wt. Packer set de th = 6718'. 10:00 12:00 2.00 7,127 5,352 COMPZ RPCOM TRIP P POOH laying down 3-1/2" DP (up wt = 110K#), pumping 3 x dis lacement. 12:00 14:30 2.50 5,352 5,352 COMPZ RPCOM OTHR P PJSM, slip and cut drilling line. Service block and drawworks. 14:30 22:00 7.50 5,352 0 COMPZ RPCOM TRIP P Continue POOH laying down 3-1/2" DP. @ 17:30 hrs had spill in Charge pump room -Charge pump #2 packing failed spilling 16 gallons. 8 gallons in containment and 8 gallons on gravel pad. Cleaned up and resumed la in down i e. 22:00 22:30 0.50 0 COMPZ RPCOM OTHR P Pull wear ring 22:30 00:00 1.50 COMPZ RPCOM OTHR P RD DP equipment and RU TBG equipment. Load remaining 4.5" TBG and Jewel 9/07/2008 MU and Rih w/ 4.5' Completion, installing gauge and running wire to 3,697' -Gauge failed. Pooh to gauge and re lace. Rih to 1,231'. 00:00 02:00 2.00 COMPZ RPCOM OTHR P RU TEC Wire sheeve and Spooler. 02:00 03:00 1.00 0 82 COMPZ RPCOM RCST P MU and RIH w/ Seal assy, 1 jt, and MU au a carrier. 03:00 04:00 1.00 82 82 COMPZ RPCOM OTHR P Splice in Baker Gaurdian gauge 04:00 05:00 1.00 82 214 COMPZ RPCOM RCST P Continue to RIH w/ 4.5" Completion - unable to et ast 214'. ®~ ~ i ~~~ 7 of 9 ._ r~ a ~, Time Logs _ _ _ i Date From To Dur S. De th E. De th Phase Code Subcode T Comment 05:00 06:00 1.00 29 214 COMPZ RPCOM TRIP T Pooh and found hex plug to be hanging up. Clean up threads and screw in lu in flush 06:00 14:00 8.00 214 3,697 COMPZ RPCOM RCST P Continue to RIH with 4.5" comlpletion 14:00 15:00 1.00 3,697 3,697 COMPZ RPCOM WOEL T Testing tech wire and gauge. Troubleshooting downhole gauge reading. Teck wire has good conductivity, bad reading from gauge. Confirmed that the gauge reading was bad by testing Centrilift program with s are au e. 15:00 20:00 5.00 3,697 82 COMPZ RPCOM TRIP T POOH with 4.5" completion to re lace Baker Gaurdian au e. 20:00 23:00 3.00 82 82 COMPZ RPCOM OTHR T Remove Guardian Gauge, Install new au a and test - ood 23:00 00:00 1.00 82 1,231 COMPZ RPCOM RCST T Rih w/ 4.5 completion from 82' to 1,231'. 9/08/2008 Continue to Rih w/ 4.5 completion and heat trace. Space out and MU hanger and landing jt. 00:00 02:30 2.50 1,231 3,729 COMPZ RPCOM RCST T Rih w/ 4.5 Completion to 3,729' 02:30 03:00 0.50 3,729 3,729 COMPZ RPCOM OTHR P RU heat trace spool and sheeve. 03:00 22:00 19.00 3,729 6,732 COMPZ RPCOM RCST P Continue to Rih w/ 4.5 Completion f/ 3,729' Starting heat trace @ 3,733' for 3,000' Heat trace cable received a kink @ 4887' while RIH. Raychem Rep tested and inspected cable and determined that cable was good. Continue to RIH to 6,734' OKB Measurement. 95k u wt, 65k do wt. 22:00 00:00 2.00 6,732 6,710 COMPZ RPCOM HOSO P Pooh w/ 3 joints and space out MU Han er and landin 't. 9/09/2008 Make Final Splice on heat trace and Tec wire. 00:00 03:00 3.00 6,710 0 COMPZ RPCOM OTHR P Make final splice on heat trace and Tec wire. Had to resplice Guardian Gua e. Test Good. 03:00 04:00 1.00 0 0 COMPZ RPCOM OTHR P Load IA w/ 180 bbls of 8.8 seawater w/ 1% by volume CRW 132 using char a um . 04:00 06:30 2.50 0 0 COMPZ RPCOM DHEQ P Land hanger and RILDS. Test upper and lower seals to 5000 si. 06:30 10:00 3.50 0 0 COMPZ RPCOM SFEO P R/U to fill IA with charge pump. Gas conitues to swap out. Call in valve crew to lubricate in VR plug. C/O IA and test body to 5000 psi. Pull VR plug with lubricator, R/U to test casin and shear SOV. 10:00 10:30 0.50 0 0 COMPZ RPCOM DHEQ P Pressure test IA. Fluid level in tubing is unknown, well is over balanced with SW. Pump up IA pressure to 500 psi and hold for 10 min. Start increasing pressure to 1000 psi, but pressure broke back at 950 si, shearin out the SOV. Fac$t~f3 i Time Logs _ _ Date From To Dur S De th _ E De th Phase Code Subcode T Comment 10:30 _ 13:30 3.00 0 0 COMPZ RPCOM _ NUND P _ Set TWC. ND BOPE. 13:30 16:30 3.00 0 0 COMPZ RPCOM NUND P NU Tree and adaptor. Test void to 5K for 15 min, test tree to 5K. 16:30 18:00 1.50 0 0 COMPZ RPCOM OTHR P RD test equipment, pull TWC with lubricator. 18:00 20:00 2.00 0 0 COMPZ RPCOM FRZP P RU LRS and pump 90 bbls diesel down IA, 50 bbls down tubing to freeze rotect well. 20:00 20:30 0.50 0 0 COMPZ RPCOM OTHR P RD LRS, set BPV, install gauges, clean and secure well site, released Nordic Rig 3 at 20:30 hrs, IA = Opsi, Tb = 0 si ~_ ~ P~ye 9 of 9 ~~ e~ ~~~~ DATA SUBMITTAL COMPLIANCE REPORT 10/29/2007 Permit to Drill 2050600 Well Name/No. KUPARUK RIV U WSAK 1J-168 Operator CONOCOPHILLIPS ALASKA INC MD 12995 TVD 3654 Completion Date 9/26/2005 Completion Status 1-OIL Current Status 1-OIL API No. 50-029-23260-00-00 UIC N REQUIRED INFORMATION ~ Mud Log No Samples No Directional Survey Yes V DATA INFORMATION Types Electric or Other Logs Run: GR/Res, Dens/Neu Well Log Information; Log/ Electr Data Digital Dataset Tye Med/Frmt Number Name (data taken from Logs Portion of Master Well Data Maint Interval Log Log Run OH / Scale Media No Start Stop CH Received Comments D D Asc Directional Survey D D Lis 13443 ~lnduction/Resistivity pt 13443 ,, LE~IS Verification J~D C Lis 15028'"~Induction/Resistivity Well Cores/Samples Information: Name ADDITIONAL INFORMATION Well Cored? Y Chips Received? -~'~-rd"- Analysis $`~t"iV"~ Received? Comments: Sample Interval Set Start Stop Sent Received Number Comments 0 12995 Open 11/17/2005 Definitive 3670 12937 Open 1/31/2006 GR/EWR4/ROP/PWD/GEO PILOT 3670 12937 Open 1/31/2006 GR/EWR4/ROPlPWD/GEO PILOT 3662 12994 Open 4/17/2007 LIS Veri, GR, FET, ROP, w/Graphics PDF, EMF, CGM Daily History Received? '~ Y N Formation Tops ~ N i Compliance Reviewed By: _ o _ Date: r WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West 7th Avenue, Suite 100 Anchorage, Alaska 9901 RE: MWD Formation Evaluation Logs: 1J-168, L1, L2 & LZ PB1, C April 16, 2007 AK-'VIW-3877631 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-168, 1J-168 Ll, 1J-168 L2 & 1J-168 L2 PB1: LIS & Digital Log Images: 50-029-23260-00, 60, 61, 70. . "'~~1 ~ ~ ~~~~,~ app ~lo~ ~ ~S6a~t c?OS=C~ f ~ ~ S~2~j aa5=a~~ ~ -so3~ ~1So3~ 1 CD Rom i r WELL LOG TRANSMITTAL To: State of Alaska January 26, 2006 Alaska Oil and Gas Conservation Co. Attn.: Ceresa Tolley 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 a~-a~ ~ RE: MWD Formation Evaluation Logs 1J-168, , ~~h~ AK-MW-3877631 1 LDWG formatted Disc with verification listing. A P I# : 50-029-23260-00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETiJRNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry Drilling Services Attn: Rob Kalish 6900 Arctic Blvd. Anchorage, Alaska 99518 Date: t Signed: • • 26-Oct-05 AOGCC Helen Warman 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 DEFINITIVE Re: Distribution of Survey Data for Well 1J-168 Dear Dear Sir/Madam: Enclosed is one disk wit the *.PTT and *.PDF files. Tie-on Survey: ' 0.00' MD Window / Kickof~ Survey: 0.00' MD (if applicable) Projected Survey: 12,995.00' 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 /J ~ , , Date ~ ~ N ~Y ~ d ~ Signed Please call me at 273-3545 if you have any questions or concerns. Regards, Carl Ulrich Survey Manager Attachment(s) al,s~ oGa ~`li • ConocoPhillips October 26, 2005 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Subject: Well Completion Reports for 1J-168, 1J-168L1 and 1J-168L2 Dear Commissioner: ''~ a ~ 205 ConocoPhillips Alaska, Inc. submits the attached Well Completion Reports for the recent drilling operations on the West Sak wells 1J-168, 1J-168L1, 1J-168L2. If you have any questions regarding this matter, please contact me at 265-6830 or Pat Reilly at 265-6048. Sincerely, -''~ _ ~ - R. Thomas Kuparuk Drilling Team Leader CPAI Drilling • Randy Thomas Kuparuk Drilling Team Leader Drilling & Wells P. O. Box 100360 Anchorage, AK 99510-0360 Phone: 907-265-6830 RT/skad STATE OF ALASKA ~ ~~~ ,~ %`t,t~J ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETiON REPOR~'~-~f~~~~Q~` ~_ ~''~~""~'~~`~~' 1a. Well Status: Oil ^ Gas Plugged ^ Abandoned Suspended ^ WAG ^ 20AAC 25.105 20AAC 25.110 GINJ ^ WINJ ^ WDSPL ^ No. ofCompletions_ Other_ 1b. Well Class: " ` Development Q Exploratory ^ Service ^ StratigraphicTest^ 2. Operator Name: ConocoPhillips Alaska, Inc. 5. Date Comp., Susp., or Aband.: September 26, 2005 / 12. Permit to Drill Number: 205-060 / 3. Address: P. O. Box 100360, Anchorage, AK 99510-0360 6. Date Spudded: August 15, 2005 ~ 13. API Number: 50-029-23260-00 4a. Location of Well (Governmental Section): Surface: 1841' FSL, 2499' FEL, Sec. 35, T11N, R10E, UM 7. Date TD Reached: August 30,2005 ' 14. Well Name and Number: 1J-168 At Top Productive Horizon: 1619' FNL, 1991' FEL, Sec. 34, T11 N, R10E, UM 8. KB Elevation (tt): 2g' RKg 15. Field/Pool(s): Kuparuk River Field Total Depth: 2372' FNL, 1852' FEL, Sec. 27, T11 N, R10E, UM 9. Plug Back Depth (MD + TVD): 12973' MD / 3651' TVD West Sak Oil P001 4b. Location of Well (State Base Plane Coordinates): Surface: x- 558712 ' y- 5945653 ' Zone- 4 10. Total Depth (MD + TVD): = 12995' MD / 3654' TvD 16. Property Designation: ADL 25661 & 25660 TPI: x- 553925 y- 5947437 Zone- 4 Total Depth: x- 554023 r - 5951964 Zone- 4 11. Depth where SSSV set: none 17. Land Use Permit: ALK 471 & 470 18. Directional Survey: Yes ^~ No ^ 19. Water Depth, if Offshore: NIA feet MSL 20. Thickness of Permafrost: 1855' MD 21. Logs Run: GR/Res, Dens/Neu 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" 163 sx AS 1 10.75" 45.5# L-80 28' 3694' 28' 2115' 13.5" 66o sx ASLite, 180 sx DeepCrete 7-5/8" 29.7# L-80 28' 8224' 28' 3472' 9-7/8" 490 sx DeepCrete 4.5" 12.6# L-80 7245' 12975' 3315' 3653' 6.75" slotted liner 23. Perforations open to Production (MD + TVD of Top and Bottom 24. TUBING RECORD Interval, Size and Number; if none, state "none"): SIZE DEPTH SET (MD) PACKER SET 4.5" 6131' 7246' slotted liner from 8474'-8659', 8876'-9274', 9582'-9861', 10170'-10263', 13 constrictor packers 10512'-11248', 11464'-12631', 12912'-12942' 25. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNTAND KIND OF MATERIAL USED n/a 26. PRODUCTION TEST Date First Production October 18, 2005 Method of Operation (Flowing, gas lift, etc.) Gas Lift Oil -shares production with 1J-168L1 and 1J-168L2 Date of Test 10/21/2005 Hours Tested 4.5 hours Production for Test Period --> OIL-BBL 286 GAS-MCF 52 WATER-BBL 0 CHOKE SIZE not available GAS-OIL RATIO 210 Flow Tubing press. 241 psi Casing Pressure not available Calculated 24-Hour Rate -> OIL-BBL 1477 GAS-MCF 310 WATER-BBL 1 OIL GRAVITY -API (core) 20.8 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". '~ '" 1 L G C'S ~. ~~ ` NONE ~. .. ~ ~N .. ~; ;. ~~~5 ^ ~,~-D......_ _; Form 10-407 Revised 12/2003 ~ ~ ~ ~ ~ ~ A L CONTINUED ON REVERSE r~ ~. 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-168 West Sak A Sand 8447' 3476.5 Base West Sak A sand 12995' 3654' N/A 30. LIST OF ATTACHMENTS Summary of Daily Operations, Directional Survey 31. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Pat Reilly @ 265-6048 Printed Name Ra d Thomas Title: Greater Kuoaruk Area Drilling Team Leader ` 5(' ~~ 3 r Lc a, Signature ~~..-~r~ ~-~----_~Phone •Z~S-- ~~ ~ ~ Date INSTRUCTIONS Prepared by Sharon AUsup-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 fomT and in any attachments. Item 13: The AP! 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: !f no cores taken, indicate "none". Item 29: List all test information. If none, state "None". Form 10-407 Revised 12/2003 ConocoPhillips Alaska Page ~ of 29 Operations Summary Report Legal Well Name: 1 J-168 Common W ell Name: 1 J-168 Spud Date: 8/13/2005 Event Nam e: ROT -D RILLING Start: 8/13/2005 End: Contractor Name: n 1334@ ppco.co m Rig Release: Group: Rig Name: Doyon 1 41 Rig Number: I Date Prom - To Hours ; Code Code Phase Description of Operations ~.._ 8!13/2005 16:30 - 18:30 2.00 MOVE DMOB MOVE Prep rig for move and disconnected service loops and blow down water and steam lines 18:30 - 20:00 1.50 MOVE DMOB MOVE Staged rig complex's on 1 E pad, pipe sheds, rock washer, boilers, motors and mud pumps 20:00 - 23:00 3.00 MOVE OTHR MOVE Began to move mud pump complex off pad to access road and broke thru road, laid plywood and moved pumps to middle of road, laid add. plywood and matting boards down on road to 1E's main road 23:00 - 00:00 1.00 MOVE MOVE MOVE Began moving complex's from 1E to 1J pad, moving mud pumps, pits, motors and boiler complex's + 8/14/2005 00:00 - 02:30 2.50 MOVE MOVE MOVE Cont to move rig's complex's from 1E pad and spotted on 1J pad, moved pumps, pits, motors and boilers, trucks returned to 1E pad 02:30 - 03:00 0.50 MOVE MOVE MOVE Moved sub base off 1 E-117 03:00 - 08:00 5.00 MOVE MOVE MOVE Moved rock washer, pipe sheds and sub base 9 miles from 1 E pad and spotted on 1J pad 08:00 - 08:30 0.50 MOVE POSN MOVE Spotted sub base over well 1J-168 08:30 - 12:30 4.00 MOVE POSN MOVE Spotted rig complex's, pits, mud pumps, motors, boilers, pipe shed and bermed rock washer and set in same 12:30 - 14:00 i 1.50 MOVE RURD MOVE Connected rigs service loops, got steam and water around rig and began to mix spud mud, completed rig acceptance check list and ACCEPTED RIG at 14:00 hrs 14:00 - 16:00 2.00 WELCT NUND SURFAC NU riser and knife valve onto 21 1/4"diverter 16:00 - 17:30 1.50 DRILL OTHR SURFAC Loaded pipe shed with 5" DP, HWDP and jars 17:30 - 23:00 5.50 DRILL PULD SURFAC PU and stood back 28 stds of 5" DP, 10 stds 5" HWDP and jars, 1 std of 8" NMFDC's 23:00 - 23:15 0.25 WELCT BOPE SURFAC Function tested diverter, knife valve and accumulator, NOTE:, Chuck Scheve waived witnessing of test 23:15 - 00:00 0.75 DRILL PULD SURFAC PU BHA from beaver slide to rig floor, MU 13 1/2" bit #1 onto 8" motor with 1.83 deg bend 8/15/2005 00:00 - 00:15 0.25 DRILL PULD SURFAC Fin MU float sub and XO onto motor RIH to 35' 00:15 - 00:45 0.50 DRILL OTHR SURFAC Flooded conductor checking lines for leaks, pressure tested mud line i and standpipe to 2,500 psi and ck ok 00:45 - 01:00 0.25 DRILL CIRC SURFAC RIH from 35' and tagget~ cement inside conductor at 85', cleaned out to 108' 01:00 - 03:15 2.25 DRILL DRLG SURFAC Spudded well and drilled 13 1/2" hole from 108' to 180' (72') ART 1.61 hrs 03:15 - 03:45 0.50 DRILL TRIP SURFAC I POOH from 180' to motor at 30' 03:45 - 05:30 1.75 DRILL PULD SURFAC MU BHA #1 RIH to 163', MU MWD, oriented and uploaded same, MU UBHO sub and oriented same, RIH with 1 std of 8" NMFDC's to 163' 05:30 - 06:15 0.75 DRILL SURV SURFAC Ran Sperry Suns surface read out Gyro at 163', RIH to 180' 06:15 - 12:00 5.75 DRILL DRLG SURFAC Drilled 13 1/2" hole from 180' to 478', (298') ART 1.77 hrs, AST 2.31 hrs, 10-12K wob, 40 rpnls, 120 spm, 509 gpm, 850 psi, ran 3 Gyro's at 256', 348' and 435' and took 1- 1/4 hrs 12:00 - 00:00 12.00 DRILL DRLG SURFAC Directionally drilled 13 1/2" hole per directional plan from 478' to 1,270' MD/1,205' TVD (792') ART 7.98 hrs, AST 1.43 hrs, 10-25K wob, 40 rpm's, 120 spm, 509 gpm at 1,150 psi, off btm torque 1-5K ft-Ibs, on btm 1-4K ft-Ibs, rot wt 88K, up wt 85K, do wt 81 K, ran 2 Gyro's at 530' and 622' and took 1/2 hr, After Gyro at 622' RD unit at 16:30 hrs 8/16/2005 00:00 - 07:45 7.75 DRILL DRLG SURFAC Continue Directional drill 13 1/2" hole from 1270' - 1936' (666'). TVD = 1552' Upweight = 95K, SO WT = 70K, Rot Wt = 81 K. TO on btm = 5-8K TO off btm = 2-6K. ART = 1.13 HRS. AST = 4.25 HRS ADT = 5.38 HRS. Jars = 86.78 HRS. WOB = 20-35K. 40 RPM's. Pumps ~ 535 GPM's with 1600 PSI. 07:45 - 10:15 2.50 DRILL REAM SURFAC ~ BROOH from 1936' - 530' (1406'), to set mud motor @ 1.5 Degrees. J Printed: 10/21/2005 2:52:30 PM ~~ LJ Con©c©Phillips Alaska Page 2 of 29 Operations. Summary Report Legal Well Name: 1 J-168 Common W ell Name: 1 J-168 Spud Date: 8/13/2005 Event Nam e: ROT -D RILLING Start: 8/13/2005 End: Contractor Name: n 1334@ ppco.co m Rig Release: Group: Rig Name: Doyon 1 41 Rig Number: Date From - To Hours Code Code Phase ' Description of Operations 8/16/2005 ~ 07:45 - 10:15 2.50 DRILL REAM .SURFAC Pumps @ 650 GPM's with 1650 PSI. 10:15 - 11:00 0.75 DRILL TRIP SURFAC POOH on elevators from 530' - 51' (479'). 11:00 - 12:00 1.00 DRILL PULD SURFAC POOH & lay down UBHO sub. POOH to surface. Clean & inspect bit and orient Mud motor to 1.5 Degrees. 12:00 - 13:30 1.50 DRILL PULD SURFAC Make up Pressure Drop Sub.Observed that the Retaining orifice had fallen on top of Mud Motor Stator and damaged Motor. Change out 8" Mud Motors. New motor is Sperry Drill Lobe w/ 4/5 - 5.3 stage, at 1.5 degrees. MU 13 1/2" Hughes MX-1 Roller Cone Bit, with 1 x 13, and 3 x 20 for a TFA of 1.050". Continue MU MWD assembly, 1 -stand 8" NMFC's, crossover, 5" HWDP, JARS, and Ghost Reamer. 13:30 - 14:15 0.75 DRILL TRIP SURFAC TIH from 1084' - 1890' (806'). Wash from 1890' - 1936'. (46'), at 623 GPM's with 1700 PSI. 14:15 - 00:00 9.75 DRILL DRLG SURFAC Continue Directional drill 13 1/2" hole from 1936' - 3060' (1124'). TVD = 1892'. Upweight = 97K, SO WT = 66K, Rotate Wt = 79K. TO on bottom = 7.5K off bottom = 6K. ART = 4.43 HRS, AST = 2.02 HRS, ADT = 6.45 HRS. Jars = 93.23 HRS Max Hydrates = 3788 Units @ 2890' MD TVD - 1838'. WOB = 5-20K, 80 RPM's .Pumps @ 708 GPM's with ! 2025 PSI. 8/17/2005 00:00 - 07:30 7.50 DRILL DRLG SURFAC Continue Directional drill 13 1/2" hole from 3060' - 3704' (644'). TVD = 2118.44'. Upweight = 125K, SO WT = 57K, Rotate Wt = 86K. TQ on bottom = 10K off bottom = 10-12K. ART = 3.33 HRS, AST = 1.88 HRS, ADT = 5.21 HRS. Jars = 98.44 HRS Max Hydrates = 3088 Units @ 3170' MD TVD - 1928'. WOB = 10-20K, 80 RPM's .Pumps @ 650 GPM's with 2000 PSI. Total Bit Hrs = 32.14. Total Footage = 3596' 07:30 - 08:30. 1.00 DRILL CIRC SURFAC POOH, rack back 1 stand. CBU @ 3652' while reciprocating string @ 177 SPM, 2150 PSI, 80 RPM's and 8-11 K Torque. 08:30 - 09:30 1.00 DRILL REAM SURFAC Pick up 1 stand Dp, attempt to tag bottom, NO-GO. Wash & ream back to tag bottom at 3704' @ 181 SPM, 2350 PSI. 10-12K torque. 09:30 - 12:00 2.50 DRILL REAM SURFAC BROOH, from 3704' - 2321' (1383'). Pumps @ 750 GPM's, 2350 PSI. 80 RPM's, TO @ 10-12K. i 12:00 - 13:30 1.50 DRILL REAM SURFAC Continue BROOH, from 2321' - 1084' (1237'). Pumps @ 750 GPM's, 2350 PSI. 80 RPM's, TQ @ 10-12K. 13:30 - 14:15 0.75 DRILL PULD SURFAC Rack Back 10 Stands of 5" HWDP and Jars. (917.06') 14:15 - 15:45 1.50 DRILL PULD SURFAC Breakout & lay down drilling BHA. Lay do crossover (2.52'), 3 - NMFC's ( 93.05'), Float sub (2.49'), MWD assembly (25.05'), Pressure drop sub ( 2.0'), NM Crossover (2.51'), Sleeve type stabilizer (5.08'), 8" Sperry Mud Motor (28.89'), and Hughes MX1 13 1/2" bit (1.00'). Gauge bit to 212/WT/A/0/I/NO/TD 15:45 - 17:45 2.00 CASE RURD SURFAC Rig Up to run 10 3/4" 45.5# casing. Held Pre- Job safety meeting. Discuss running order, centralizer placement, and make up torques. 17:45 - 20:15 2.50 CASE RUNC SURFAC Make up 10 3/4" shoe joint, w/ Weatherford Model 303 Sure Seal Float Shoe, 1 JNT 10 3/4" 45.5# casing, and Float collar joint w/ Weatherford Model 402 Sure Seal Float Collar. Continue RIH with 10 3/4" casing as per running order palcing centralizers on 5' above Shoe, 10' Below Float collar, 10' above Float collar, and 1 each on every collar from jnt # 4 - 20. RIH to 1900' Make up Torque = 10K 20:15 - 21:00 0.75 CASE CIRC SURFAC CBU @ 2 BPM - 200 PSI, 3 BPM - 225 PSI, 4 BPM - 250 PSI, 5 BPM - 300 PSI while reciprcate string. JNTS # 50 & 51 21:00 - 23:00 2.00 CASE RUNC SURFAC Continue RIH w/ 10 3/4" 45.5# casing from 1900' - 3693' (1793'). Make up Landing Joint 8~ RIH to land hanger @ 29.99' RKB to spoof. Upweight = 180K . SO weight = 68K 23:00 - 00:00 1.00 CASE j CIRC SURFAC Circulate & condition mud while reciprocate string 10'. 3.5 BPM = 275 Printed: 10/21/2005 2:52:30 PM • ConocoPt~illips Alaska Operations Summary Report Legal Well Name: 1J-168 Common Well Name: 1J-168 Event Name: ROT -DRILLING Contractor Name: n1334@ppco.com Rig Name: Doyon 141 Date From - To Hours Code Code Phase 8117!2005 23:00 - 00:00 1.00 CASE CIRC SURFAC 8/18/2005 00:00 - 00:15 0.25 CEMEN CIRC SURFAC 00:15 - 00:45 0.50 CEMEN PULD SURFAC 00:45 - 02:00 1.25 I CEMEN CIRC SURFAC 02:00 - 05:15 3.25 i CEMEN PUMP SURFAC 05:15 - 06:30 1.25 CEMENl~ PULD SURFAC 06:30 - 09:30 3.00 WELCT ' NUND SURFAC 09:30 - 11:00 1.50 WELCT NUND SURFAC 11:00 - 12:00 1.00 WELCT NUND SURFAC 12:00 - 13:00 1.00 WELCT NUND SURFAC 13:00 - 14:00 1.00 WELCT NUND SURFAC 14:00 - 15:45 1.75 DRILL RIRD SURFAC 15:45 - 21:45 6.00 WELCT BOPE SURFAC 21:45 - 22:15 22:15 - 00:00 0.50 DRILL OTHR SURFAC 1.75 DRILL PULD i SURFAC 8/19/2005 100:00 - 01:00 01:00 - 06:15 1.001 DRILL I PULD I SURFAC 5.251 DRILL I PULD I SURFAC Page 3 of 29 Spud Date: 8/13/2005 Start: 8/13/2005 End: Rig Release: Group: Rig Number: Description of Operations PSI, 4 SPM = 275 PSI, 5 BPM = 300 PSI, and 6 BPM = 350 PSI. Upweight = 160K, SO Weight = 65K with pumps on. Continue circulate & condition mud while reciprocate string 10'. 6.5 BPM = 375 PSI, Upweight = 165K, SO Weight = 60K with pumps on. Breakout & lay down Franks Fill UP Tool. Load cement head 8~ MU head and lines to Landing Joint. Continue circulate & condition mud while reciprocate string 10'. 6.5 BPM = 325 PSI, Conditioned mud from a 9.5 PPG, Visc = 260, PV = 41, YP = 54, Gels @ 20/51/70 with a PH of 8.6, to a 9.2 PPG, Visc = 40, PV = 18, YP = 9, Gel @ 1/2/2, with a PH of 8.4. Upweight = 165K, SO Weight = 60K with pumps on. Hold Pre-Job Safety Meeting with entire crew, truck drivers and Cementers. Turned over to Dowell and pumped 10 bbls of CW 100 at 8.35 ppg @ 4 BPM - 50 PSI, pressure tested lines to 3,500 psi, pumped additional 40 bbls of CW 100 (50 bbls Total) @ 5.4 BPM - 85 PSI, then pumped 50 bbls of 10.5 ppg XL Mudpush with Red Dye, avg 5 bpm at 110 psi, shut down and dropped btm plug, Mix and pump Lead cement, Fa~+pad a total of 531 BBLS of 10:7 ppg Arctic set lite cement with a yield of 4.49, with additives,660 sacks, Avg pumping @ 6.6 BPM 140 PSI. Upweight = 175K, SO WT = 73K. Landed casing in hanger @ 485 BBLS into Lead as we observed reciprocatiion becoming "sticky". Up weight = 190K, SO WT = 65K. Mix & pump 83.6 BBLS of 12.0 PPG Deepcrete Tail Slurry, Yield = 2.47, with additives, 180 sacks, avg 6.1 bpm at 200 psi, shut down and dropped top plug. Dowell pumped 20 bbls, 8.35 PPG FW for flush, and turned over to rig. Rig displaced cmt with 325 bbls of 9.2 ppg mud, ave 7 bpm, initial pressure 680 psi, max pressure 690 psi, slowed to 3 bpm and bumped plug on talc displacement of 325 BBLS = 3227 STKS to 1,000 psi, check floats and floats held, CIP at 05:15, Had 103.4 bbls of 10.7 ppg lead cmt back to surface. RKB to landing = 29.99' Rig down Cement Equipment. Backout & lay down landing jnt. Flush stack. Nipple down diverter system. Nipple up wellhead as per Vetco rep. Test lower flange to 5000 PSI. 15 minutes. Nipple up BOP stack, choke & kill lines. Continue Nipple up BOP stack ,choke & kill lines. Change out Lower pipe rams from 5" to 7 5/8" rams. Change out Top Drive saver sub, grabbers, & bell guide to 4". RU and tested BOPE, choke manifold, 4" and 5" floor valves, rams including 7 5/8" csg rams to 250 psi low and 3,500 psi high, annular to 250 psi low and 2,800 psi high, John Crisp with AOGCC witnessed test, recorded on chart. Install wear bushing. RILDS. WB ID = 12 1/4" Pick up & rack back 6 stands of "PUSH PIPE". Stands are made up of 2 jnts of 4 3/4" DC's with 1 JNT of 4" XT-39 HWDP on top. Continue to pick up & rack back 9 stands of "PUSH PIPE". (15 stnds Total) Stands are made up of 2 jnts of 4 3/4" DC's with 1 JNT of 4" XT-39 HWDP on top. Pick up 180 Jnts, (60 studs) of 4" XT-39 drill pipe and rack back in Derrick. Printed: 10/21/2005 2:52:30 PM • C©nocoPhillips Alaska Page 4 of 29 Operations Summary Report Legal Well Name: 1J-168 Common Well Name: 1J-168 Event Name: ROT -DRILLING Contractor Name: n1334@ppco.com Rig Name: Doyon 141 Date From - To Hours Code Code Phase 8/19/2005 ~ 06:15 - 07:30 ~ 1.25 ~ DRILL ~ PULD SURFAC 07:30 - 08:00 0.50 DRILL PULD SURFAC 08:00 - 09:45 1.75 DRILL PULD SURFAC 09:45 - 10:15 0.50 DRILL PULD SURFAC 10:15 - 11:00 0.75 DRILL PULD SURFAC 11:00 - 11:30 I 0.501 DRILL I PULD I SURFAC 11:30 - 12:00 I 0.501 DRILL I PULD I SURFAC 12:00 - 13:30 1.501 DRILL ~ PULD SURFAC 13:30 - 14:00 I 0.501 DRILL (PULD I SURFAC 14:00 - 15:00 1.00 CASE DEOT SURFAC 15:00 - 15:15 0.25 DRILL REAM SURFAC 15:15 - 17:45 2.50 DRILL DRLG SURFAC 17:45 - 18:15 0.50 ~ DRILL CIRC SURFAC 18:15 - 19:00 I 0.751 DRILL I LOT I SURFAC 19:00 - 00:00 5.001 DRILL DRLG INTRM1 8/20/2005 100:00 - 12:00 I 12.001 DRILL I DRLG I INTRMI 12:00 - 15:30 I 3.501 DRILL i DRLG I INTRM1 Spud Date: 8/13/2005 Start: 8/13/2005 End: Rig Release: Group: Rig Number: Description of Operations Rig up and lay down 21 jnts of 5" HWDP from derrick. lay down mousehole. Clean floor area, pull BHA equipment to rig floor from beaver slide. Hold PJSM. "Making up BHA #3 ". Make up 9 7/8" BHA as per Dir Driller. MU 9 7/8" Security FS2653 PDC bit (1.60') with a TFA of 1.845 sq in. 7600 Series Geo-Pilot (20.15'), 6 3/4" Non Mag GP Flex Pony collar (9.20'), 6.770" Smart Stabilizer (2.18'), 6 3/4" MWD GR / RES / PWD (20.93'), 6.770" Smart Stabilizer (2.16'), 6 3/4" MWD HCIM 6.83'), 6 3/4" MWD TM HOC (9.96'), and Non Mag Float Sub (1.96'). Plug in and upload MWD Equipment. Continue making up BHA picking up 3 -Non Mag Flex Drill collars 91.66'), 4 -HWDP (123.4'), 6 1/4" Drilling jars w/ 98.43 Hrs (30.38'), 1 stnd 4" DP. Perform Shallow pulse test MWD /Geo Span @ 538', at 550 GPM's - 1050 PSI. Continue MU 18 JNTS 5" DP (571.29), 6 1/2" Ghost reamer (5.08'), 41 JNTS 5" DP (1237.44'), and a 6 1/2" Ghost Reamer (6.34'). Continue MU 41 JNTS 5" DP (1237.44'), and a 6 1/2" Ghost Reamer 6.34'). RIH to tag Float Collar @ 3609' DPM. Pull up to position bit @ 3586'. CBU @ 650 GPM's - 2050 PSI. Up weight = 115K, SO WT = 53K Rot WT = 79K TO = 6-8K Rig up and test 10 3/4" casing to 3000 PSI. Held test 30 minutes and recorded on chart. Good test. Bleed Pressure and Rig down test lines. Wash down from 3586' - 3609' (25'). Drill through float equipment. Float collar @ 3613', Shoe track, and Float Shoe @ 3693', Continue drill 20' of 9 7/8" new hole to 3724' MD at TVD of 2128'. ADT = .19 HRS. Up weight = 120K, SO WT = 52K, ROT WT = 80K, RPM's @ 100 Tq on btm = 6-8K, Pumps @ 600 GPM's - 1800 PSI. Obtain SPR's @ 3678' MD, TVD = 2112'. #1 pump 30 SPM - 220 PSI. 40 SPM - 290 PSI. Pump #2 - 30 SPM - 170 PSI, 40 SPM - 220 PSI Circulate i~ condition mud displacing well with re-conditioned 9.0 PPG mud, @ 600 GPM's - 1800 PSI. On btms up, Density = 9.0 PPG, Gels 10 min = 14 RU lines and Perform LOT to Equivalent Mud Weight of 15.3 ppg, with 691 PSI, 9.0 ppg mud, Shoe TVD 2115' (EMW pick by computer). Record on chart. Bleed all pressures and rig down lines. Directional drill 9 7/8" hole with Geo-Pilot from 3724' - 4184' MD (460'). TVD = 2294' ADT = 2.81 HRS. UP WT = 124K, SO WT = 50K, ROT WT = 75K. Torque on btm = 6-8K, off btm = 7-9K. 100 RPM's, WOB = 10-15K, Pumps @ 550 GPM's - 1500 PSI. Jars = 101.43 HRS. Clean hole ECD = 9.7 PPG. Drilling ECD = 9.8 PPG Total Bit HRS = 3.0 Directional drill 9 7/8" hole with Geo-Pilot from 4184' - 5362' MD 1178'). TVD = 2752' ART = 7.91 HRS. UP WT = 134K, SO WT = 59K, ROT WT = 81 K. Torque on btm = 9-12K, off btm = 11 K. 60 RPM's, WOB = 5-25K, Pumps @ 450 GPM's - 1250 PSI. Jars = 109.34 HRS. Clean hole ECD = 9.7 PPG. Drilling ECD up to = 10.1 PPG Total Bit HRS = 10.91 The drilling parameters were adjusted to directionally control assembly in the soft formation. Directional drill 9 7/8" hole with Geo-Pilot from 5362' - 5642' MD 280'). TVD = 2842' ADT = 2.29 HRS. UP WT = 132K, SO WT = 55K, Printed: 10/21/2005 2:52:30 PM • ConocoPhillips Alaska Operations Summary Report Legal Well Name: 1 J-168 Common Well Name: 1J-168 Event Name: ROT -DRILLING Contractor Name: n1334@ppco.com Rig Name: Doyon 141 Date From - To Hours Code Code Phase 8/20/2005 12:00 - 15:30 15:30 - 19:00 19:00 - 19:30 19:30 - 22:00 3.50 ~ DRILL DRLG INTRM1 3.501 DRILL ITRIP IINTRM1 0.501 DRILL CIRC INTRM1 2.501 DRILL ITRIP I INTRM1 22:00 - 22:45 0.75 DRILL PULD INTRMI 22:45 - 23:15 0.50 DRILL OTHR INTRM1 23:15 - 00:00 0.75 FISH PULD INTRM1 8/21/2005 00:00 - 01:30 1.50 RIGMNT RSRV INTRM1 01:30 - 03:30 2.00 FISH ~ PULD INTRM1 03:30 - 06:15 I 2.751 FISH ITRIP (INTRMI 06:15 - 11:00 I 4.751 FISH I WASH I INTRM1 11:00 - 12:00 1.00 FISH FISH INTRM1 12:00 - 13:00 1 1.001 FISH I PULL I INTRM1 13:00 - 14:00 1.00 FISH CIRC INTRM1 14:00 - 15:15 1.25 FISH PULL INTRM1 15:15 - 15:45 0.50 ~ FISH CIRC INTRM1 15:45 - 18:30 2.75 ~ FISH PULL INTRM1 18:30 - 19:30 I 1.001 FISH ITRIP I INTRM1 Page 5 of 29 Spud Date: 8/13/2005 Start: 8/13/2005 End: Rig Release: Group: Rig Number: Description of Operations ROT WT = 80K. Torque on btm = 14K, off btm = 10-12K. 90 RPM's, WOB = 10-25K, Pumps @ 585 GPM's - 1900 PSI. Jars = 111.63 HRS. Clean hole ECD = 9.7 PPG. Drilling ECD up to = 10.1 PPG Total Bit HRS = 13.2. Lost MWD communication, could not regain it. Monitor well, BROOH from 5642' - 3693' Shoe depth (1949'), at 90-100 RPM's 650 GPM's - 1750 PSI. Observed 30 - 40% increase in cuttings over shakers while backreaming Pump Hi Visc sweep and CBU 2 -times @ 700 GPM's - 1750 PSI. 30 - 40%increase in cutting while circulating Monitor well -static. Pump Dry Job, POOH from 3682' -surface. Stand back HWDP, Jars, and NM Flex Collars. Breakout Float sub. Pull up & Observed MWD tool broke and parted at the crossover below MWD HCIM and above Smart Stabilizer. Total fish left in hole = 57.90'. The OD Of break = 6.223". Left in hole -Crossover top (1.68'), 6.70" Smart Stabilizer (2.16'), 6 3/4" MWD GR / RES / PWD (20.93'), 6.770" Smart Stabilizer (2.18"), Non-Mag GP Flex Pony Collar (9.20'), 7600 Series Geo-Pilot (20.15'), and 9 7/8" Security bit (1.60'). Fishing neck looking up = 1.68' Breakout & lay down MWD TM HOC and HCIM assembly. Clean Rig floor area, and send tools down beaver slide. Load pipe shed with 6 - 6 3/4" Drill collars, strap same. PJSM, Slip & Cut 45 FT of Drilling line. Service Top Drive Make up BHA #1 Fishing Assembly. MU 9 5/8" Series 150 Overshot dressed with a 6 1/4" Grapple and Mill Control packoff, and Guide with tungsten carbide welded on (3.75"), 6 1/4" Pump out sub (2.02'), 6 1/4" Lubricated Bumper Sub (9.00'), 6 1/4" Oil Jar (11.23'), 3 - 6 3/4" Drill Collars (91.83'), and Accelerator Jar (12.91'). Total BHA lenght = 130.74. Trip in hole from 130' - 3732' (3602'). Shoe depth = 3693'. Tag up, taking 5K weight. Upweight = 85K SO WT = 35K Wash & ream through open hole from 3732' - 5575' (1843'). Observe minimal pressure increases and could not verify that we were pushing fish. Pumps @ 50 SPM - 250 PSI, Up Wt = 110K, SO WT = 40K, Rot WT = 70K, staging pumps up 75 SPM - 600 PSI, and 115 SPM - 800 PSI. Note: Held Pad evacuation drill along with Nordic 2, and Construction. Wash over top of fish at 5588' DPM. 60 SPM - 400 PSI. 40 RPM's. Observed little or no pressure increase, and no increase in up weight when set down 10k, and pull up. Repeat several times to attempt to catch fish. No indication of fish on. Up Wt = 125K, SO WT = 75K TO = 17K. Attempt to POOH- Hole swabbing, Pump out of hole from 5588' - 5040' ( 548'). Circulate Bottoms up @ 360 GPM's - 500 PSI. Continue Pump Out of hole into shoe from 5040' - 3600' (1440') @ 360 GPM's - 500 PSI. Note; Hole swabbed all the way to the shoe without pump. Circulate Bottoms up @ 420 GPM's - 400 PSI. Momitor well -static. Pump Dry job. POOH from 3600' - 130' (3470'), on elevators. Observe overpull of 55K at shoe. (overshot at shoe) Stand back drill collars and pull 9 5/8" overshot to rig floor. NO-FISH. Breakout & lay down Overshot assembly. Inspect 6 1/4" grapple and mill control packoff. Observed packoff rubber gone, indication marks on Printed: 10/21/2005 2:52:30 PM • ConocoPhillips Alaska Page 6 of 29 Operations Summary Report Legal Well Name: 1J-168 Common Well Name: 1J-168 Event Name: ROT -DRILLING Contractor Name: n1334@ppco.com Rig Name: Doyon 141 Date From - To Hours Code Code Phase Spud Date: 8/13/2005 Start: 8/13/2005 End: Rig Release: Group: Rig Number: Description of Operations 8/21/2005 18:30 - 19:30 1.00 FISH TRIP INTRM1 the mill control that we had been over top of fish, and the grapple had definite indications that we had been over the fish and had "spun" the grapple wickers to "DULL". The grapple was also spread open 1/2". The carbide on the guide indicated we were just to the top of the stabilizer, and had a full bite. Pictures were taken and sent to town. 19:30 - 20:15 0.75 FISH OTHR INTRM1 Clean rig floor area, lay do tools. Discuss options with town. Decision to run 8 1/8" Overshot with 6 1/4" Grapple, without 6 3/4" drill collars. 20:15 - 20:30 0.25 FISH PULD INTRM1 Strap & make up fishing BHA #2. 8 1/8" Overshot assembly with 6 1/4" Grapple and Mill Control Packoff with carbide. on the guide. This will swallow 1.84'. length = 3.60'. Continue make up 6 1/4" Pump out sub 2.02'), 6 114" Lubricated Bumper Sub (9.0'), 6 1/4" Oii jar (11.23), 6 - Jnts of 5" HWDP (184.40), and Accelerator Jar (12.91'). Total BHA length = 223.13'. Top fish @ 5584' 20:30 - 00:00 3.50 FISH TRIP INTRMI Trip in hole with BHA #2, from 223' - 5320' (5097'). Stop at the Shoe (3693') and obtain parameters. Up Wt - 84K, SO WT = 40K Pumps at 50 SPM - 300 PSI. Continue TIH to 5320' with no issues, and take weight @ 4950'. Screw into TD and wash & rotate @ 30 Rpm's with 450 GPM - 650 PSI, 3 studs to continue in hole. We were able to TIH with little rotation or pumping after that to Tag hard @ 5475'. UP WT = 130K, SO WT = 50K. 8/22/2005 00:00 - 00:30 0.50 FISH TRIP INTRM1 Continue TIH from 5320' made up to TD and wash i~ rotate @ 30 Rpm's with 450 GPM - 650 PSI, 3 studs to continue in hole. We were able to TIH with little rotation or pumping after that to Tag hard @ 5475'. UP WT = 125K, SO WT = 52K. 00:30 - 00:45 0.25 FISH FISH INTRMI Tag hard @ 5475' while washing through open hole with overshot. 30 RPM's. Stop rotating, and straight slackoff to engage fish. Pull up to 200K first pull and fire jars. (75K over) Straight pull to 250K, and fish pulling free with 60-120K drag. We engaged fish 113' higher than expected. Pumps @ 530 GPM's - 1400 PSI. Observe no pressure increase when engage fish. 00:45 - 04:45 4.00 FISH TRIP INTRM1 Pump out of hole from 5475', observing overpull of 60-100K. 530 Gpm's - 1400 PSI. Continue POOH pumps off checking well for swabbing, hole taking fluid. Continue pull on elevators to tight spot @ 5140', observe weight falling off to drag at 145K UP WT. Staright pull @ 200K, Slack off to break over free, and pull up to 145K, observed weight fall off, with Upweight now of 125K. Continue POOH to surface. 04:45 - 05:00 0.25 FISH PULD INTRMI Breakout & lay down Overshot assembly. NO FISH. Inspect 8 1/8" overshot. Observed wickers on 61/4" grapple still sharp, slivers of Monel steel in wickers, and good indications inside Top Sub showed overshot bottomed out over fish. Guide looked good but had minimal "flare" on the cut lip. Discuss options with town. 05:00 - 06:00 1.00 FISH PULD INTRM1 Clean floor area, Make up Fishing BHA #3, Strap & make up 8 1!S" Overshot assembly with 6 1/8" Grapple and Mill Control Packoff with carbide on the guide. This will swallow 1.84'. length = 3.60'. Continue make up 6 1/4" Pump out sub (2.02'), 6 1!4" Lubricated Bumper Sub 9.0'), 6 1/4" Oil jar (11.23), 6 - Jnts of 5" HWDP (184.40), and Accelerator Jar (12.91'). Total BHA length = 223.13'. Suspected Top fish @ 5140' 06:00 - 09:45 3.75 FISH TRIP INTRMI TIH to 3638', Break circulation. Up WT = 103K, SO WT = 50K. Pumps @ 530 GPM's - 1425 PSI. RIH to tag fish @ 5140' DPM, and push fish to 5563', then observed 200 PSI increase in pressure. Pull up to 250K 147K over), to observe drag @ 60-100K. 09:45 - 12:00 2.25 FISH TRIP INTRM1 ; Pump out of hole with fish on from 5563' - 4292' (1271') observing drag Printed: 10/21/2005 2:52:30 PM • ConocoPhillips Alaska Operations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 J-168 1 J-168 ROT -DRILLING n1334@ppco.com Doyon141 Page 7 of 29 Spud Date: 8/13/2005 Start: 8/13/2005 End: Rig Release: Group: Rig Number: Date From - To Hours Code Code Phase 8/22/2005 09:45 - 12:00 12:00 - 12:45 12:45 - 15:30 15:30 - 17:00 17:00 - 17:30 17:30 - 18:30 18:30 - 21:00 21:00 - 21:15 21:15 - 21:45 21:45 - 00:00 8/23/2005 00:00 - 02:30 02:30 - 10:30 10:30 - 11:00 11:00 - 12:00 12:00 - 12:30 12:30 - 15:15 15:15 - 16:30 Description of Operations 2.251 FISH TRIP INTRM1 up to 100K. Pumps @ 80 SPM - 700 PSI 0.75 FISH TRIP INTRM1 Continue Pump out of hole wfth fish on from 4292' - 3550' (742') observing drag up to 100K, with drag falling off. Pumps @ 340 GPM - 600 PSI 2.75 FISH TRIP INTRM1 Monitor well -static. Pump Dry job, POOH on elevators to surface 1.50 FISH ~ PULD INTRM7 Breakout & lay down 8 1/8" Overshot assembly, releasing from fish. Lay down fish. Fish = 57.90'. Layed down Crossover top (1.68'), 6.70" Smart Stabilizer (2.16'), 6 3/4" MWD GR /RES /PWD (20.93'), 6.770" Smart Stabilizer (2.18"), Non-Mag GP Flex Pony Collar (9.20'), 7600 Series Geo-Pilot (20.15'), and 9 7/8" Security bit (1.60'). Fishing neck looking up = 1.68' x 6 1/8" 0.50 DRILL PULD INTRM1 Clean floor area, pull tools to rig floor. Insert Vortex jets in bit and orient them to point more ahead of the bit. 1.00 RIGMNT RSRV INTRM1 Service Top Drive and Drawworks. 2.50 DRILL PULD INTRM1 Make up BHA #7. MU 9 7/8" Security FMFX653 Bit w/ TFA of .969 Sq in. (1.40'), Jet Nozzles = 3 x 14's, and 3 x 15's. Continue with 9 7/8" 7600 Geo-Pilot (23.22'), 6 3/4" Non-Mag Pony Collar (9.20'), 6.760" Smart Stabilizer (2.18'), 6 3/4" MWD - GR /RES /PWD (21.02'), 6.70" Smart Stabilizer (2.17'), 6 3/4" MWD HCIM (6.97'), 6 3/4" MWD TM HOC (9.96'), and Non Mag Float Sub (1.96'). Plug in, Up Load MWD assembly. 0.25 DRILL PULD INTRM1 RIH from 68' - 540'. (472'), making up remaing BHA. 3 -Non Mag Flex collars (91.56'), 4 -jnts 5" HWDP (123.24'), 6 1/4" drilling jars with 98.43 HRS (30.38'), and 4 -jnts 5" HWDP (122.76'). Pick up 9 7/8" Ghost reamer( 5.08') on #6 stand of 5"HWDP. Total BHA length = 446.12' 0.50 DRILL PULD INTRM1 Break in Geo-Pilot and pulse test MWD tools. Good test. Pumps @ 500 GPM"S - 875 PSI. 2.25 DRILL TRIP INTRM1 Trip in hole from 540' - 3704' (3164'), picking up 9 7/8" Ghost Reamer (6.34') on stand # 19 of 5" DP. UP WT = 115K, SO WT = 50K. 2.50 DRILL REAM INTRM1 Wash & Ream Open Hole from 3704' - 5642' (1938') @ 350 GPM's - 650 -800 PSI. 80 RPM's Torque = 8-10K. 8.00 DRILL DRLG INTRM1 Directionally Drill 9 7/8" Intermediate hole from 5642' - 6205' (563'). ND = 3056' Observe trouble controlling Geo-Pilot assembly, and could not maintain required direction. Pumps @ 450 - 530 GPM's - 1350 - 2150 PSI, UP WT = 163K, SO WT = 55K, ROT WT = 82K. WOB = 15-34K. 60-90 RPM's, TQ = 11-17K. Jars = 117.61 HRS Mud wt = 9.1 PPG. ECD = 9.82 PPG. 0.50 WAITON ORDR INTRM1 Directional Drillers discuss with Co. Rep,and town. 1.00 DRILL REAM INTRMI BROOH from 6205' - 5834' (371'). Pumps @ 650 GPM's - 2500 PSI. TO = 10 -12K. 0.50 DRILL REAM INTRM1 Continue BROOH from 5834' - 5554' (371'). Pumps @ 650 GPM's - 2500 PSI. TQ = 10 -12K. 2.75 DRILL TRIP INTRM1 POOH on elevators From 5554' - 4900' (654'). Pump dryjob, Continue POOH to MWD. 1.25 DRILL PULD INTRM1 Plug in and download MWD. Breakout & lay down BHA #7. Layed down Non-Mag float sub (1.96'), 6 3/4" MWD TM HOC (9.96'), 6 3/4" MWD HCIM (6.97'), 6.70" Smart Stabilizer (2.17'), 6 3/4" MWD GR /RES/ PWD (21.02), 6.760" Smart Stabilizer (2.18'), 6 3!4" Non Mag GP Flex Pony (9.20'), 7600 GEO-Pilot (23.22), and the 9 7/8" Security FMFX653 bit (1.40'). Observed 9 7/8" bit had 15 cutters, worn or Printed: 10/21/2005 2:52:30 PM ConocoPhillips Alaska Operations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 J-168 1 J-168 ROT -DRILLING n1334@ppco.com Doyon141 Page 8 of 29 Spud Date: 8/13/2005 Start: 8/13/2005 End: Rig Release: Group: Rig Number: Date From - To Hours Code I Code Phase 8/23/2005 15:15 - 16:30 16:30 - 19:00 19:00 - 23:00 23:00 - 00:00 8/24/2005 100:00 - 12:00 12:00 - 23:15 23:15 - 00:00 8/25/2005 00:00 - 04:30 04:30 - 05:30 05:30 - 06:00 06:00 - 06:30 06:30 - 09:00 09:00 - 10:15 10:15 - 10:45 10:45 - 12:00 Description of Operations 1.25 DRILL PULD ~ INTRM1 broken. 2.50 DRILL PULD INTRM1 Make up BHA #8, Bit #4. Make up 9 7/8" Hughes MXC1 bit with jets of 3 x20's, 1 x 12 for a TFA Of 1.031 sq. in.(.80'), 7" SperryDrill Lobe 7/8 - 6.0 stage (25.40) with a bend configuration of 1.5 degrres. 6 1/2" Non Mag Float sub (1.96'), 6 314" Welded Blade Stabilizer (5.62'), 6 3!4" MWD DM HOC (9.02'), 6.760" Smart Stabilizer (2.18'), 6 3/4" MWD - GR/RES/PWD (21.02'), 6.70" Smart Stabilizer (2.17'), 6 3/4 MWD HCIM (6.97'), 6 3/4" MWD TM HOC (9.96'). Up load MWD. 4.00 DRILL PULD INTRM1 TIH from 116' - 6205' (6089'). Make up remaining BHA, 3 -NON MAG Flex Collars (91.66'), 4 -JNTS 5" HWDP (123.24'), 6 1/4" Drilling Jars ( 30.38') with 98.43 HRS, 4 -JNTS 5" HWDP (122.76'). Perform shallow pulse test on MWD Assembly -good test @ 550', 525 GPM's - 1050 PSI. Continue TIH, install 9 7/8" Ghost reamer on stand # 6 5.08'), and9 7/8" Ghost Reamer on stand #19 (6.34'). Continue TIH, observe no issues through Shoe @ 3693', continue to bottom @ 6205', Wash down last stand. 1.00 DRILL DRLG INTRM1 Directional Drill 9 7/8" Hole from 6205' - 6253' (48') TVD = 3075'. Pumps @ 550 GPM's - 2050 PSI, WOB = 6-30K 60-80 RPM's. PU WT = 140K, SO WT = 59K, ROT WT = 87K. AST = .40 HRS. ECD = 9.86 PPG. 12.00 DRILL DRLG INTRM1 Continue Directional Drill 9 7/8" Hole from 6253' - 7147' (894') TVD = 3298'. Pumps @ 650 GPM's - 2975 PSI, WOB = 25-33K, 60-80 RPM's. PU WT = 166K, SO WT = 58K, ROT WT = 85K. Torque on btm = 11 K, off bottom = 12K, ART =5.98 HRS, AST = 2.24 HRS. ADT = 8.4 HRS. ECD = 10.23 PPG.MAx GAS = 321 units. Jar Hrs = 127.45. SPR's #1 pump = 30 SPM - 370 PSI, 40 SPM - 450 PSI, Pump #2 - 30 SPM -370 PSI, 40 SPM - 450 PSI. Total BIT HRS = 8.8 Mud WT = 9.1 PPG 11.25 DRILL DRLG INTRM1 Continue Directional Drill 9 7/8" Hole from 7147' - 8229 ' (3073.80') TVD = 3298'. Pumps @ 650 GPM's - 2975 PSI, WOB = 10-30K, 80 RPM's. PU WT = 130K, SO WT = 65K, ROT WT = 88K. Torque on btm = 11 K, off bottom = 12K, ART =4.63 HRS, AST = 1.90 HRS. ADT = 6.53 HRS. ECD = 10.46 PPG.MAX GAS = 527 units. Jar Hrs = 133.20. Total Bit Hrs = 15.55 MUD WT = 9.1 PPG, Pump HI-VISC weighted sweep on last connection. 0.75 DRILL CIRC INTRM1 Continue Circulate sweep out of hole @ 650 GPM's - 2950 PSI. 4.50 DRILL TRIP INTRM1 Obtain last surveys at TD, as per DD. Monitor well -Static. BROOH from 8229' - 4627' (3602'). Pumps @ 650 GPM's, - 3000 PSI. UP WT = 135K, SO WT = 65K, ROT WT = 87K with 8K torque. Observed increase in cuttings across shakers 30-40%. We backreamed to get lower Ghost Reamer into shoe area, and saw hole cleaned up. 1.00 DRILL TRIP INTRM1 POOH on elevators from 4627' - 3692' (935'). Observed clean hole conditions. UP WT = 110K, SO WT = 55K. Hole taking proper fill. 0.50 DRILL CIRC INTRM1 Pump Hi-Visc weighted sweep 9.1 PPG, @ 650 GPM's-1700 PSI., while reciprocating drill string @ 50 RPM's. Observe 10 % increase in cuttings and hole cleaned up. 0.50 DRILL TRIP INTRM1 Monitor well -static. Pump dry job, POOH from 3692' - 3130' (562') to stand back remaing 4" DP. 2.50 DRILL TRIP INTRM1 POOH, lay down 84 Joints of 5" drill pipe. 1.25 DRILL PULD INTRM1 Breakout & lay down 8 joints 5" HWDP, and drilling jars, (276.38'). Lay down 3 Non-Mag flex drill collars (91.66'), Flush mud motor with water. 0.50 DRILL PULD INTRM1 Plug in ,download MWD assembly. 1.25 DRILL PULD INTRMI Continue breakout & lay down 9 7/8" Hughes MXC1 bit with jets of 3 Printed: 10/21/2005 2:52:30 PM • ConocoPhillips Alaska Page 9 of 29 Operations Summary Report Legal Well Name: 1J-168 Common Well Name: 1J-168 Event Name: ROT -DRILLING Contractor Name: n1334@ppco.com Rig Name: Doyon 141 Date From - To !Hours Code Code Phase Spud Date: 8/13/2005 Start: 8/13/2005 End: Rig Release: Group: Rig Number: Description of Operations 8/25!2005 ~ 10:45 - 12:00 ~ 1.25 DRILL PULD INTRM1 12:00 - 12:30 0.50 DRILL PULD INTRM1 12:30 - 13:00 0.50 CASE OTHR INTRM1 13:00 - 14:30 1.50 CASE RURD INTRM1 14:30 - 18:30 4.00 CASE RUNC INTRM1 18:30 - 18:45 I 0.251 CASE CIRC INTRM1 18:45 - 20:15 1.50 CASE RUNC INTRM1 20:15 - 20:45 0.50 CASE CIRC INTRM1 20:45 - 00:00 3.25 CASE RUNC INTRMI 8/26/2005 00:00 - 03:00 3.00 ~ CASE RUNC INTRMI 03:00 - 04:45 I 1.75 i CASE I CIRC I INTRM1 04:45 - 05:15 0.50 CEMEN PULD INTRM1 05:15 - 07:30 2.25 CEMEN CIRC INTRM1 07:30 - 08:30 1.00 CEMEN PUMP ~ INTRM1 08:30 - 09:30 1.001 CEMENT PUMP INTRM1 x20's, 1 x 12 for a TFA Of 1.031 sq. in.(.80'), 7" SperryDrill Lobe 7/8 - 6.0 stage (25.40) with a bend configuration of 1.5 degrres. 6 1/2" Non Mag Float sub (1.96'), 6 3/4" Welded Blade Stabilizer (5.62'), 6 3/4" MWD DM HOC (9.02'), 6.760" Smart Stabilizer (2.18'), 6 3/4" MWD - GR/RES/PWD (21.02'), 6.70" Smart Stabilizer (2.17'), 6 3/4 MWD HCIM (6.97'), 6 3/4" MWD TM HOC (9.96'). Inspect & grade bit to I / I / WT/A/E/I/NO/TD Clean floor area, and lay down all 5" handling tools. Rig up. BOLDS and pull wear ring. Rig up to run 7 5/8" 29.7# casing. Hold PJSM. Discuss "running detail as planned" and safety issues. Make up Float shoe joint, # 2 jint and Float collar joint- all baker locked, and check floats. Continue RIH with 7 518" casing installing tandem rise centralizers 10' from each end of joints #1-#9, then install 1 centalizer on center of joints #10 X80, and 1 each 10' from end on joints #81-#82. All centralizers are over "Stop Collars". RIH to 2100'. AVG make-up torque = 8500 FT/LBS Circulate bottoms up through Franks fill up tool @ 215 GPM's - 250 PSI. Continue RIH with 7 518" casing from 2100' - 3700' (1600'). Circulate bottoms up through Franks fill up tool @ 215 GPM's - 300 PSI. Continue RIH with 7 5/8" casing from 3700' - 6116', (2416'). Avg Make up Torque = 8500 FT/LBS. Continue RIH with 7 5/8" casing from 6116' - 8224, (2108'). AVG Make up torque = 8500 FT/LBS. We ran 7 5/8" Weatherford Model 303 Sure Seal Float Shoe (1.50'}, 2 jts 7 518" BTC-M casing (85.25), 7 5!8" Weatherford Model 402 Sure Seal Float Collar (1.31'), 22 jts of 7 5/8" BTC-M casing (936.18'), 7 5/8" Casing Pup Jt (20.21'), 8 jts 7 5/8" Casing (339.79'), 7 5/8" Casing Pup Jt (21.46'), 158 Jts 7 5/8" BTC-M casing (6768.45'), and Jt # 191 to set in slips and cut off. RKB = 26.31'. The window Jts were spaced to allow tops of collars at 7136.45, and 6774.78. We ran a total of 82 Tandem Rise centralizers & stop rings. 2 per joint - 10' from each end on jts #1 -#9, 1 per joint on center of each joint #10 -#80, and 2 per joint on each end of jnts # 81 - #82. Centralizer spacing from 4761' - 8224'. Circulate bottoms up through Franks Tool staging up to 5 BPM - 450 PSI, while reciprocating string. UP WT = 185K, SO WT = 68K. Mud wt = 9.2+ PPG, PV= 12, YP = 20. Breakout & lay down Franks Fill up tool. Make up crossover and Cement Head. Continue Circulate & condition while reciprocating string, and RU Dowell Cement crew. Condition mud to pre cement properties of 9.0 PPG, PV = 11, and YP of 11. Held PJSM with entire crew and truck drivers. Discuss Cement Job, Fluid transfers, and safety. Circulating 6 BPM - 500 PSI UP WT = 205K, SO WT = 68K. Turn over to Dowell. Pump 5 BBLS of 8.36 PPG water @ 5.1 BBUMIN, Pressure test lines to 3500 PSI. Good Test. Pump 40 BBLS of 8.35 PPG CW100 @ 5 BBUMIN, 40 BBIs of 10.2 PPG MudPush @ 5 BBLS/MIN, Drop Bottom Plug, Pump 193 BBLS of 12.5 PPG Tail Slurry 6 BBLS/MIN, Drop Top Plug, and flush lines. While reciprocating string, Displace well with 9.0 PPG MOBM @ 7.5 Printed: 10/21/2005 2:52:30 PM ConocoPhillips Alaska Operations Summary Report Legal We!! Name: 1J-168 Common Well Name: 1J-168 Event Name: ROT -DRILLING Contractor Name: n1334@ppco.com Rig Name: Doyon 141 Date From - To Hours Code Code Phase 8/26/2005 08:30 - 09:30 09:30 - 11:15 11:15 - 12:00 12:00 - 14:00 1.001 CEMEN7~PUMP INTRM1 1.751 CEMEN7f RURD I INTRM1 0.75 CASE OTHR INTRMI 2.00 CASE OTHR INTRM1 14:00 - 14:30 14:30 - 14:45 14:45 - 15:00 15:00 - 16:00 16:00 - 17:45 0.50 CASE OTHR INTRM1 0.25 CASE NUND INTRMI 0.25 CASE OTHR INTRM1 1.00 CASE OTHR INTRM1 1.75 CMPLTN OTHR INTRM1 17:45 - 19:00 I 1.25.1 WELCTLI BOPE I INTRM1 19:00 - 00:00 I 5.00 I DRILL I PULD I PROD 8/27/2005 100:00 - 03:00 I 3.001 DRILL I PULD I INTRMI 03:00 - 06:30 I 3.501 DRILL I PULD I INTRM1 06:30 - 10:45 4.251 DRILL TRIP INTRM1 10:45 - 12:00 1.25 DRILL TRIP INTRM1 12:00 - 12:15 0.25 DRILL TRIP INTRM1 12:15 - 13:15 1.00 RIGMNT RSRV INTRMI 13:15 - 13:30 0.25 DRILL TRIP INTRM1 13:30 - 17:45 4.25 DRILL DEQT INTRMI Page 10 of 29 Spud Date: 8!13/2005 Start: 8/13/2005 End: Rig Release: Group: Rig Number: Description of Operations BBLS/MIN to 3500 stks. Parked casing at 307 BBL into displacement. LAst UP WT = 215K, SO WT = 40K. We then slow pumps to 3.5 BBLS/MIN @ 360 BBLS into displacement, to bump plug at calculated 3725 STKS (375.10 BBLS). Recorded Cement in place at 09:25 HRS. Circulating pressure before bump 600 PSI. Pressure to 1100 PSI, hold for 5 minutes. Open valves and c~teck floats - OK. Float shoe @ 8224' MD 3472' TVD Rig down cement head and lines. Nipple down & lift BOP stack for setting slips. Set 7 5/8" csg slips with 100K block wt, 65K set on slips. Rig up & make cold cut using WACHS casing cutter and POOH LD cut piece of 7 5/8" casing (17.59'), Dress stump, and install pack-off. Remaing casing jt #191 in slips = 23.54') Rig up and lower packoff on to stump. Nipple up BOP stack 8 choke line. Rig up and pressure test 7 5/8" packoff to 4200 PSI. Hold for 10 Minutes. Good test. Rig up and perform Casing annulus infectivity test w 9.1 PPG Mud. Pump down 7 5/8" x 10 3/4" annulus to flush with 175 BBLS of water @ 2 BPM - 900 PSI. Rig up and test BOP's, and flange breaks. Test to 250 PSI for Low test, and 3000 PSI, recoreded on chart. Bleed pressures. Rig down all test equipment. Rig up and make up Lo-Tads on 4" Dp in derrick. Stand back same. Obtain SLM on each stand, picked up 41 of 65 stands needed. NOTE: Little Red Services rigged up and pumped 90 BBLS freeze protect diesel down 7 5/8" x 10 3/4" casing @ 1.9 BBLS/MIN. Final shut in pressure = 600 PSI. Diesel to 2267' Continue make up Lo-Tads on 4" Dp in derrick. Stand back same. Obtain SLM on each stand, picked up 24 of 65 stands needed. Note: Blind Ram Function test. Held PJSM. Discuss BHA & Safety. Make up BHA #9. Make up 6 3/4" SDBS FSF 2641 PDC bit (1.20') w! 3 x 15 Jets for a TFA of .518 sq in. 6 3/4" 5200 Geo-Piiot (16.22), 4 3/4" Non-Mag Flex (battery) (11.55'), 4 314" DM Collar (8.03'), 4 3/4" Smart Stabilizer (3.59'), 4 3/4" Slimphase 4 w/DGR (24.39'), 4 3/4" PWD Collar (10.77'), 4 3!4" 7M HOC (11.28'), 4.710" Non-Mag Float Sub w/ valve(2.35'), 4 3/4" Non-mag IBS Stabilizer (5.33'), 3 - 4.630" Non-Mag Flex Drill Collars 93.17'), 4.90" - 4" XT 39 x 3 1/2" IF Crossover sub (1.72'), 1 -Jt 4" HWDP (30.33'), 4 3/4" Drilling jars (28.90, 4 - JTs 4" HWDP. Total BHA = 369.68'. Pulse test MWD @ 250 GPM"S - 1050 PSI. Break in Geo-Pilot bearings. PU WT = 45K, SO WT = 42K, ROT WT = 42K, 70 RPM"S Trip in hole picking up 165 joints of 4" DP from pipe shed. Fill every 20 stands. Checked MWD @ 2892' and 5507' with 180 GPM's - 800 PSI. Cont trip in hole from 5507' - 7537' (2030'). Continue trip in hole from 7537' - 8114' (577'). Slip & Cut Drilling tine. Service Top Drive, while CBU. Wash down from 8114' - 8136' (22'), to tag Float Collar @ 8136'. Rig up & perform 7 5/8" casing test to 3000 PSI. Record on chart. Pressure bled off 150 PSI in 30 Minutes. Reposition drill string and repeat test. Pressure bled 150 psi in 30 Minutes. Change out "easy turn" valve & perform Re-test. Pressure bled 150 PSi in 30 Minutes. Rig Printed: 10/21/2005 2:52:30 PM • ConocoPhillips Alaska Page 11 of 29 Operations Summary Report Legal Well Name: 1 J-168 Common Well Name: 1J-168 Event Name: ROT -DRILLING Contractor Name: n1334@ppco.com Rig Name: Doyon 141 I Date From - To Sub Mours Code Code Phase Spud Date: 8/13/2005 Start: 8/13/2005 End: Rig Release: Group: Rig Number: Description of Operations 8/27/2005 13:30 - 17:45 4.251 DRILL ~ DEOT ~ INTRMI 17:45 - 20:45 3.00 DRILL DRLG INTRM1 20:45 - 22:00 1.251 FRMTSTI CIRC INTRM1 22:00 - 22:45 I 0.75 I FRMTSTI OTHR I INTRM1 22:45 - 00:00 1.25 DRILL DRLG PROD 8/28/2005 00:00 - 12:00 12.00 ~ DRILL DRLG PROD 12:00 - 00:00 I 12.001 DRILL I DRLG I PROD 8/29/2005 ; 00:00 - 12:00 ~ 12.00 DRILL DRLG PROD 12:00 - 16:45 4.75 ~ DRILL DRLG PROD 16:45 - 17:30 I 0.751 DRILL I CIRC I PROD down test equipment. Circulate 15 minutes. Rig up test equipment. Pertorm Re-test to 3000 PSI. 2$50 psi after 30 min Test -Recorded on chart. Drill Float equipment. FC @ 8136', and Flaot shoe at 8224'. Drill 20' of new hole to 8249'. Pull up into shoe track, and circulate & condition mud @ 250 GPM's - 1950 PSI for LOT. Mud wt = 9.0 PPG, Visc = 75, YP = 14 Gels @ 18/28, in & out of hole. Rig up and fill all lines with mud. Pump at 7 strokes !minute to 66 stks. 5 1/2" Liners in pumps. Pump output = .085. Calculated Leak off @ 986 PSI for a calculated EMW = 14.46 PPG. Rig down all test equipment & lines. Recorded on chart. Directional Drill 6 3/4" hole from 8249' - 8308' (59'). TVD = 3472". ADT _ .60 HRS. PU WT = 125K, SO WT = 60K, ROT WT = 81 K. Torque on bottom = 6K, off bottom = 7K. 100 Rpm's. WOB = 6-10K. Pumps at 250 GPM's - 2000 PSI. Clean hole ECD = 10.37 PPG. Slow pump rates @ #1 pump 20 SPM - 380 PSI. 30 SPM - 680 PSI. #2 Pump , 20 SPM - 330 PSI, 30 SPM - 520 PSI. Directional Drill 6 3/4" hole from 8308 - 9408' (1100'). TVD = 3503". ADT = 7.67 HRS. PU WT = 125K, SO WT = 60K, ROT WT = 81 K. Torque on bottom = 6K, off bottom = 7K. 120 Rpm's. WOB = 5-10K. Pumps at 280 GPM's - 2600 PSI. ECD = 10.75 PPG. Max Gas = 90 Units. MOBM @ 9.0 PPG Vis = 75, YP = 19, Gels = 18/32, Total BIT HRS = 8.27 Continue Directional Drill 6 3/4" hole from 9408' - 10602' (1194'). TVD = 3583". ADT = 7.46 HRS. PU WT = 136K, SO WT = 54K, ROT WT = 86K. Torque on bottom = 7K, off bottom = 7-9K. 120 Rpm's. WOB = 5-10K. Pumps at 280 GPM's - 2825 PSI. ECD = 11.50 PPG. Max Gas = 189 Units.Jar = 15.73 HRS, Total Bit HRS = 15.73, MOBM @ 9.0 PPG Vis = 86, YP = 21, Gels = 19/31 "*"Note: We drilled +/- 230 feet of shale out of shoe, then 150' of sand, and back into shale for +/_ 200 ft. Geologist stopped and re-evaluated 3 times, discussing plan with town. Decision to keep drilling as per Geo. Also observed ABI tool readings 2.88 degrees avg, OFF from MWD surveys. DD's compensated for this. SPR's= Pump#1 - 20 SPM - 720 PSI, 30 SPM = 860 PSI. Pump #2 - 20 SPM = 530 PSI, 30 SPM = 700 PSI. Continue Directional Drill 6 3/4" hole from 10602' - 11705' (1103'). TVD = 3561". ADT = 7.15 HRS. PU WT = 150K, SO WT = 50K, ROT WT = 82K. Torque on bottom = 7K, off bottom = 7-9K. 120 Rpm's. WOB = 5-10K. Pumps at 291 GPM's - 3050 PSI. ECD = 11.70 PPG. Max Gas = 264 Units.Jars = 22.88 HRS, Total Bit HRS = 22.88, MOBM @ 9.0 PPG Vis = 84, YP = 21, Gels = 25/33 104 BBLS fluid loss Pumping Hi-Visc weighted sweeps to clean hole 8~ control ECD MAx ECD = 12.3 PPG. Continue Directional Drill 6 3/4" hole from 11705 - 12150' (1075'). TVD = 3580' ADT = 3.63 HRS. PU WT = 158K, SO WT = 55K, ROT WT = 90K. Torque on bottom = 7K, off bottom = 7-9K. 120 Rpm's. WOB = 5-10K. Pumps at 295 GPM's - 3400 PSI. ECD = 12.3 PPG. Max Gas = 264 Units, MOBM @ 9.0 PPG Con't to Pump Hi- Visc weighted sweep @ 295 GPM's - 3400 PSI to clean hole and control ECD's. Observed 250% increase in cuttings on shakers and hole parameters cleaned up. ECD @ 11.56 PPG Printed: 10/21/2005 2:52:30 PM • ConocoPhillips Alaska Page 12 of 29 Operations Summary Report Legal Well Name: 1J-168 Common Well Name: 1J-168 Event Name: ROT -DRILLING Contractor Name: n1334@ppco.com Rig Name: Doyon 141 Date From - To Hours Code Code Phase 8/29/2005 117:30 - 23:15 I 5.75 I DRILL I DRLG 1 PROD 23:15 - 00:00 I 0.751 DRILL I CIRC I PROD 8/30!2005 100:00 - 04:15 I 4.25 I DRILL I DRLG 1 PROD 04:15 - 05:45 I 1.501 DRILL I CIRC I PROD 05:45 - 06:00 0.25 DRILL OBSV PROD 06:00 - 13:45 7.75 DRILL REAM PROD 13:45 - 15:30 I 1.751 DR1LL I CIRC I PROD 15:30 - 18:30 3.00 DRILL TRIP PROD 18:30 - 19:45 1.25 DRILL CIRC PROD 19:45 - 21:30 1.75 DRILL CIRC PROD 21:30 - 21:45 0.25 DRILL OBSV PROD 21:45 - 00:00 2.25 DRILL TRIP PROD 8/31/2005 00:00 - 04:00 4.00 DRILL TR1P PROD 04:00 - 06:30 I 2.50 I DRILL I PULD !PROD 06:30 - 07:00 0.50 CASE RURD CMPLTN 07:00 - 07:15 0.25 CASE SFTY CMPLTN 07:15 - 12:30 5.25 CASE PULR CMPLTN 12:30 - 13:00 0.50 CASE PULR (CMPLTN Spud Date: 8/13/2005 Start: 8/13/2005 End: Rig Release: Group: Rig Number: Description of Operations Continue Directional Drill 6 3/4" hole from 12150' - 12602' (452'). TVD = 3605' ADT = 4.14 HRS. PU WT = 173K, SO WT = 62K, ROT WT = 103K. Torque on bottom = 9K, off bottom = 10K. 120 Rpm's. WOB = 4-8K. Pumps at 295 GPM's - 3650 PSI. ECD = 11.74 PPG. Max Gas = 212 Units. Jars = 30.64 HRS, Total Bit HRS = 30.64, MOBM @ 9.0 PPG Vis = 78, YP = 21, Gels = 25/33 Pumping Hi-Visc weighted sweeps to clean hole & control ECD MAX ECD = 12.3 PPG. Slow pump Rates @ 12240'. TVD = 3585'. #1 = 20 SPM - 680 PSI, 30 SPM - 880 PSI. #2 = 20 SPM - 610 PSI, 30 SPM - 800 PSI. Con't to Pump Hi- Visc weighted sweep @ 295 GPM's - 3600 PSI to clean hole and control ECD's. Observed 300% increase in cuttings at shakers, and hole parameters cleaned up. ECD @ 11.74 PPG Drilled 6 3/4" hole in A2 sand lateral with Geo-pilot assembly from 12,602' to 12,995' MD/ 3,654' TVD (393') (T.D.) ADT 2.89 hrs, 4-8K wob, 120 rpm's, 83 spm, 295 gpm at 3,800 psi, off btm torque 10K ft-Ibs, on btm 9K ft-Ibs, rot wt 105K, up wt 195K, do wt 55K, 9.0 ppg MOBM, ave ECD 11.9 ppg, ave BGG 90 units, max gas 195 units Pumped 35 bbl weighted hi vis sweep and circ out of hole, circ hole at 295 gpm, 3,800 psi and 120 rpm's with 10K ft-tbs torque, ECD 11.8 ppg after circ out sweep Monitored well-static, took SPR's Backreamed out of hole from 12,995' to 8,214' with no problems (csg shoe @ 8,224'), BROOH at 120 rpm's, 9-10K ft-Ibs torque, 295 gpm, initial circ press 3,700 psi, final circ press 2,700 psi Pumped 35 bbl weighted hi vis sweep at csg shoe and circ hole clean, had 50% increase in cuttings back from sweep, circ a total of 3X btms up and was clean at shakers, circ at 295 gpm at 2,600 psi, monitored well-static RIH from 8,214' to btm at 12,995' with no problems Pumped 35 bbl weighted hi vis sweep and circ out of hole, had 10% increase in cuttings back from sweep, circ hole at 295 gpm, 4,000 psi and 120 rpm's Displaced hole over from 9.0 ppg MOBM to 9.0 ppg SFMOBM, rotated DP at 120 rpm's and circ at 295 gpm at 4,000 psi Monitored well-static, dropped 1 3/4" rabbit on a wire POOH on elevators with BHA #9 from 12,995' to 10,341' Cont POOH with BHA #9 from 10,431' to BHA at 370', monitored well at shoe, well-static Stood back HWDP and jars, downloaded MWD and LD same with Geo-pilot, cleared rig floor, calc fill on trip out of hole 91 bbls, actual fill 98 bbls RU Doyon's 4 1/2" liner running equipment Held PJSM on running of liner PU and ran 4 112" liner per well program to 5,673', ran 4 112" ROT silver bullet guide shoe with no float, 184 jts, (5,673') of 4 1/2" 12.6#, L-80, BTCM liner, placed blank liners across shale sections per geology, ran 90 jts (2,782') of blank liner and 94 jts (2,889') of slotted liner, ran 152- 4 1/2" x 6 1/4" spiralglide centralizers 1/jtjt #1 to Jt #165, ran 13 constrictor packers placed on blank liner to isolate shale sections per geology, did not run any centralizers on jts with constrictor packers. MU Baker 190-47 seal bore ext, 5 1/2" x 7 5/8" Flexlock liner hanger with, "RS" pack-off seal nipple and "HRD" ZXP liner top packer and RIH to 5,741', st wt up 75K, do wt 55K (blk wt 35K) Printed: 10(21(2005 2:52:30 PM r 1 LJ ConocoPhillips Alaska Page 13 of 29 Operations Summary Report Legal Well Name: 1J-168 Common Well Name: 1J-168 Event Name: ROT -DRILLING Contractor Name: n1334@ppco.com Rig Name: Doyon 141 Date From - To Hours Code Coded Phase 8/31/2005 113:00 - 14:15 14:15 - 14:30 14:30 - 17:30 17:30 - 18:30 18:30 - 18:45 1.251 CASE I RUNL I CMPLTN 0.251 CASE I CIRC I CMPLTN 3.00 I CASE I RUNL I CMPLTN 1.001 CASE I OTHR I CMPLTN 0.251 CASE I DEOT I CMPLTN 18:45 - 19:00 ~ 0.25 CASE OTHR CMPLTN 19:00 - 20:15 1.25 DRILL TRIP CMPLTN 20:15 - 21:15 1.00 RIGMNT RSRV CMPLTN 21:15 - 23:15 2.00 DRILL TRIP CMPLTN 23:15 - 00:00 0.75 DRILL ~ PULD CMPLTN 9/1/2005 00:00 - 00:30 0.50 DRILL ~ PULD CMPLTN 00:30 - 01:00 0.50 WELCT OTHR CMPLTN ~ 01:00 - 05:00 4.00 WELCT BOPE CMPLTN 05:00 - 05:30 0.50 WELCT OTHR CMPLTN 05:30 - 05:45 0.25 WINDO FTY CMPLTN 05:45 - 09:00 3.25 ~ WINDO ULD PROD2 09:00 - 13:45 4.75 WINDO RIP PROD2 13:45 - 14:30 0.75 WINDO THR PROD2 14:30 - 15:15 I 0.751 WINDOVVTRIP I PROD2 15:15 - 16:00 I 0.751 WINDOWSETW I PROD2 16:00 - 17:00 I 1:001 WINDOVVCIRC I PROD2 17:00 - 00:00 I 7.001 WINDOVVSTWP . PROD2 9/2/2005 100:00 - 01:00 I 1.001 WINDOVV/CIRC I PROD2 Spud Date: 8/13/2005 Start: 8/13/2005 End: Rig Release: Group: Rig Number: Description of Operations RIH with liner on 4" XT-39 DP from 5,741' to 8,160' (7 5/8" Csg shoe 8,224') Circ a DP cap at csg shoe, pumped 40 bbls of 9.0 ppg SFMOBM at 180 gpm at 350 psi, st wt up 98K, do wt 55K Cont to run 4 1/2" liner in open hole, RIH from 8,160' and tagged btm at 12,995' with no problems, PU to 12,975', st wt up 160K, do wt 60K, Note: RIH with 65 stds of 4" DP with Lo-Tads, 13 stds of Hybrid push pipe and 1 std of slick DP to set 4 1/2" liner Dropped 1 3/4" ball and pumped down to seat, pumped at 2 bpm at 300 psi, with ball on seat pressured up to 1,600 psi to set Flexlock hanger, slacked off 25K, cont to set packer, pressured up to 4,000 psi and set ZXP packer, no problems setting hangedpacker, set "A2" sand liner with TOL @ 7,246' MD/ 3,311' TVD and shoe at 12,975' MD 3,653' TVD, st wt up after setting liner 125K, lost 35K st wt RU & tested annulus above ZXP packer to 1,000 psi for 5 min and ck ok Monitored well-static POOH from 7,246' to 4,800' Slipped and cut 78' of drlg line Cont to POOH with liner running tool from 4,800' to 40' Made service breaks and LD Baker Liner running tool, calc fill on trip out of hole 51 bbls, actual 54 bbls Fin LD Baker liner running tool and cleared rig floor Pulled wear bushing RU & Tested BOP's, tested annular, rams, valves and manifold to 250 psi low and 3,000 psi high, no problems, NOTE: Chuck Scheve with AOGCC waived witnessing of test Pulled test plug and installed wear bushing Held PJSM on PU & MU of whipstock milling assembly MU Baker 7 5/8" whipstock assembly BHA #10 and RIH to 389', MU milling assembly and LD same, PU seal assembly, locator sub, flex pup jt, 2-jts 3 1/2" DP and unloader sub for space out and RIH with seal assembly, MU whipstock, milling assembly with MWD, oriented and uploaded MWD and RIH with 2-bumper subs and 2 stds 4" Hybrid push pipe to 389' RIH with whipstock assembly from 389' to 6,405' Made MADD pass from 6,405' to 6,483' (6,230' to 6,310' sensor depth) and correlated MWD to K-13 sand RIH with whipstock assembly from 6,483' to 7,200', st wt up 130K, do wt 82K Oriented whipstock to 6 deg left of high side, RIH, tagged TOL at 7,246', set whipstock and sheared off from same, set top of whipstock at 7,145' Displaced hole over from 9.0 ppg SFMOBM to 9.0 ppg MOBM, circ at 250 gpm at 2,000 psi Milled window in 7 5/8" csg for "B" Lateral, top of window at 7,145', btm of window at 7,157', drilled 6 3/4".hole to 7,187' MD/ 3,300' TVD (42'), 2-8K wob, 78-95 rpm's, 275 gpm, 2,500 psi, rot wt 92K, up wt 130K, do wt 82K, 5-8K ft-Ibs torque, pumped 2-15 bbl weighted hi vis sweeps while milling window with no increase in cuttings back. Pumped 35 bbl weighted hi vis sweep and circ hole clean after milling window, worked mills thru window while circ hole clean, circ at 266 gpm at 2,200 psi, rot wt 95K, up wt 125K, do wt 83K, no increase in cuttings Printed: 10!21!2005 2:52:30 PM • ConocoPhillips Alaska Page 14 of 29 Operations Summary Report Legal Well Name: 1 J-168 Common Well Name: 1J-168 Event Name: ROT -DRILLING Contractor Name: n1334@ppco.com Rig Name: Doyon 141 Date From - To Hours Code Coe Phase Spud Date: 8/13/2005 Start: 8/13/2005 End: Rig Release: Group: Rig Number: Description of Operations 9/2/2005 00:00 - 01:00 1.00 WINDOVCIRC PROD2 01:00 - 01:15 0.25 WINDO THR PROD2 01:15 -04:00 2.75 WINDO RIP PROD2 04:00 - 05:30. I 1.501 WINDOWPULD I PROD2 05:30 - 07:00 ! 1.501 WINDOWOTHR I PROD2 07:00 - 08:30 I 1.50 RIGMNT RSRV PROD2 08:30 - 11:45 ~ 3.25 DRILL PULD PROD2 11:45 - 15:00 3.251 DRILL TRIP PROD2 15:00 - 15:15 0.251 DRILL REAM PROD2 15:15 - 00:00 I 8.75 I DRILL I DRLG I PROD2 9/3/2005 ~ 00:00 - 12:00 ~ 12.00 DRILL DRLG PROD2 12:00 - 00:00 12.00 DRILL DRLG PROD2 9/4/2005 100:00 - 12:00 I 12.00 i DRILL I DRLG f PROD2 12:00 - 00:00 i 12.00 I DRILL I DRLG I PROD2 9/5/2005 100:00 - 12:00 12.00 DRILL DRLG PROD2 12:00 - 00:00 ~ 12.001 DRILL DRLG. PROD2 back from sweep Monitored well-static, took spr's and pumped dry job POOH with BHA #10 from 7,187', stood back hybrid push pipe POOH to MWD at 38' Downloaded MWD and LD same along with milling assembly, upper mill was in gauge Pulled wear bushing and flushed out BOP stack after milling window, re-installed wear bushing Changed out 4" XT-39 saver sub on top drive and serviced same MU 6 3/4" Geo-pilot BHA #11 and RIH to 370', MU new bit #6, Geo-pilot with MWD only, uploaded MWD and RIH with NMFDC's, HWDP and jars to 370' RIH with BHA #11 from 370' to 7,088' (TOW @ 7,145') Washed down from 7,088' thru top of window at 7,145' and cunt to btm at 7,187', no problems going thru window, rot wt 79K, up wt 99K, do wt 65K Drilled 6 3/4" hole in "B" sand lateral with Geo-pilot assembly from 7,187' to 7,540' MD/ 3,317' TVD (353'), ADT 7.05 hrs, 5-14K wob, 120 rpm's, 83 spm, 295 gpm, 2,650 psi, off btm torque 7K ft-Ibs, on btm 6K ft-Ibs, rot wt 79K, up wt 122K, do wt 55K, 9.05 ppg MOBM, ave ECD 10.8 ppg, ave BGG 25 units, max gas 66 units, drilling thru numerous concretions Drilled 6 3/4" hole in "B" sand lateral with Geo-pilot assembly from 7,540' to 8,463' MD/ 3,338' TVD (923'), ADT 9.04 hrs, 5-8K wob, 120 rpm's, 84 spm, 298 gpm, 2,800 psi, off btm torque 8K ft-Ibs, on btm 6K ft-Ibs, rot wt 80K, up wt 125K, do wt 55K, 9.0 ppg MOBM, ave ECD 11.2 ppg, ave BGG 25 units, max gas 83 units Drilled 6 3/4" hole in "B" sand lateral with Geo-pilot assembly from 8,463' to 9,081' MD/ 3,355' TVD (618'), ADT 10.08 hrs, 5-17K wob, 120 rpm's, 84 spm, 298 gpm, 2,900 psi, off btm torque 8K ft-Ibs, on btm 7.5K ft-Ibs, rot wt 78K, up wt 133K, do wt 53K, 9.0 ppg MOBM, ave ECD 11.4 ppg, ave BGG 40 units, max gas 105 units, cont to drill thru numerous concretions Drilled 6 3/4" hole in "B" sand lateral with Geo-pilot assembly from 9,081' to 9,901' MD/ 3,383' TVD (820'), ADT 9.22 hrs, 5-15K wob, 120 rpm's, 84 spm, 298 gpm, 3,000 psi, off btm torque 8K ft-Ibs, on btm 8K ft-Ibs, rot wt 80K, up wt 135K, do wt 55K, 9.0 ppg MOBM, ave ECD 11.45 ppg, ave BGG 30 units, max gas 403 units from apprx 9,470'. NOTE: Rig off highline at 02:00 hrs and back on highlsne at 10:00 hrs Drilled 6 3/4" hole in "B" sand lateral with Geo-pilot assembly from 9,901' to 10,895' MD/ 3,406' TVD (994'), ADT 8.99 hrs, 5-17K wob, 120 rpm's, 84 spm, 298 gpm, 3,150 psi, off btm torque 9K ft-lbs, on btm 8K ft-Ibs, rot wt 77K, up wt 140K, do wt 53K, 9.05 ppg MOBM, ave ECD 11.8 ppg, ave BGG 40 units, max gas 166 units, pumped 30 bbl wt'd hi vis sweep at 10,532' with no increase in cuttings back from the sweep, cont to drill thru concretions, approx 15% of "B" lateral has been concretions Drilled 6 3/4" hole in "B" sand lateral with Geo-pilot assembly from 10,895' to 11,531' MD/ 3,418' TVD (636'), ADT 9.62 hrs, 5-15K wob, 120 rpm's, 84 spm, 298 gpm, 3,125 psi, off btm torque 9K ft-Ibs, on btm 8K ft-Ibs, rot wt 80K, up wt 145K, do wt 48K, 9.0 ppg MOBM, ave ECD 11.8 ppg, ave BGG 40 units, max gas 204 units Drilled 6 3/4" hole in "B" sand lateral with Geo-pilot assembly from Printed: 10/21/2005 2:52:30 PM • ConocoPhillips Alaska Page 15 of 29 Operations Summary Report Legal Well Name: 1J-168 Common Well Name: 1J-168 Event Name: ROT -DRILLING Contractor Name: n1334@ppco.com Rig Name: Doyon 141 Date From`- To Hours ~'° Code Code Phase Spud Date: 8/13/2005 Start: 8/13/2005 End: Rig Release: Group: Rig Number: Description of Operations 9/5/2005 112:00 - 00:00 I 12.00 I DRILL I DRLG I PROD2 9/6/2005 100:00 - 12:00 I 12.001 DRILL I DRLG I PROD2 12:00 - 12:15 I 0.25 DRILL OBSV PROD2 12:15 - 20:45 ~ 8.50 DRILL REAM PROD2 20:45 - 22:15 1.501 DRILL CIRC PROD2 22:15 - 23:15 1.00 RIGMNT RSRV PROD2 23:15 - 00:00. 0.75 DRILL TRIP PROD2 9/7/2005 100:00 - 04:30 I 4.50 i DRILL I TRIP I PROD2 04:30 - 04:45 I 0.251 DRILL I REAM I PROD2 04:45 - 07:00 I 2.251 DRILL I CIRC I PROD2 07:00 - 09:00 I 2.001 DRILL I CIRC I PROD2 09:00 - 09:15 0.25 DRILL OBSV PROD2 09:15 - 13:45 4.50 DRILL TRIP PROD2 13:45 - 14:00 0.25 DRILL OBSV PROD2 14:00 - 16:00 2.00 DRILL TRIP PROD2 16:00 - 18:45 2.75 DRILL PULD PROD2 11,531' to 12,431' MD/ 3,456' TVD (900'), ADT 8.17 hrs, 4-17K wob, 120 rpm's, 84 spm, 298 gpm, 3,450 psi, off btm torque 11 K ft-Ibs, on btm 9.5K ft-Ibs, rot wt 90K, up wt 163K, do wt 50K, 9.05 ppg MOBM, ave ECD 12.0 ppg, ave BGG 40 units, max gas 86 units, began using hybrid push pipe at 11,878', cont to drill thru concretions, approx 12% of "B" lateral has been concretions Drilled 6 3/4" hole in "B" sand lateral with Geo-pilot assembly from 12,431' to 12,967' MD/ 3,480' TVD (536'), (T.D.) ADT 8.2 hrs, 4-17K wob, 120 -130 rpm's, 79 spm, 281 gpm, 3,200 psi, off btm torque 11 K ft-Ibs, on btm 10K ft-Ibs, rot wt 95K, up wt 165K, do wt 50K, 9.0 ppg MOBM, ave ECD 11.75 ppg, ave BGG 30 units, max gas 75 units, TD well with hybrid push pipe, cont to drill thru concretions, approx 11 % of "B" lateral was concretions (621'), pumped weight hi vis sweep on last std and had 20-30% increase in cuttings back from sweep, crossed fault at 12,050' and while drilling below 12,550' began to have slight mud losses slowed pump rate and losses decreased, Geo-pilot began having trouble holding tool face from 12,512' to TD, was able to TD well in the target Monitored well for 15 min, well breathed back 19 bbls of mud, initial rate was 5 bpm, final rate after 15 min .3 bpm Backreamed out of hole from 12,967' to 7,245', then pumped out of hole to 7,100' to above TOW at 7,145', no problems pulling thru window, BROOH at 120 rpm's and 225 gpm at 2,350 psi, no problems BROOH, monitored well every 1,000' and well was breathing Blighty up to 8,092' where well was static, calc fill 45.5 bbls actual fill 70 bbls Pumped 30 bbl weighted hi vis sweep and circ hole clean above TOW, circ at 265 gpm, 2,200 psi and 120 rpm's with 7K ft-Ibs torque, had no increase in cuttings back from sweep and circ an add. btms up after sweep was out of the hole and was clean at shakers, rot wt 79K, up wt 117K, do wt 64K Slip and cut 56' of drlg line and service top drive, monitored well while servicing rig and well was static RIH slow from 7,100' thru window at 7,145' with no problems and cont RIH to 7,440', lost 258 bbls of 9.0 ppg MOBM to hole last 24 hrs Cont RIH from 7,440' and set down at 12,602', washed down 1 std to 12,694' and cont RIH to 12,879' with no problems Washed and reamed down from 12,879' to btm at 12,967' (88'), washed down at 62 spm, 220 gpm at 2,450 psi, 120 rpm' with 10K ft-Ibs torque Pumped 35 bbl weighted (1 Ib over) hi vis sweep and circ out of hole, had no increase in cuttings back from the sweep, circ an add. btms up and was clean at shakers, circ at 220 gpm at 2,500 psi, 120 rpm's with 10K ft-Ibs torque, rot wt 95K, up wt 170K, do wt 45K with pumps on, Held PJSM with rig crew and ASRC vac truck drivers on changing over to SFMOBM Displaced hole over from 9.0 ppg MOBM to 9.0 ppg SFMOBM, circ at 220 gpm at 2,200 psi and 120 rpm's Monitored well-static, took SPR's POOH wet on elevators from 12,967' to 6,883', no problems pulling thru window at 7,145' Monitored well at 6,883' and well was static Cont POOH with BHA #11 from 6,883' to BHA at 369' POOH standing back HWDP, jars and NMFDC's, downloaded MWD and LD same along with Geo-pilot and bit, cleared rig floor, talc fill on Printed: 10!212005 2:52:30 PM • ConocoPhillips Alaska Page 16 of 29 Operations Summary Report Legal Well Name: 1J-168 Common Well Name: 1J-168 Event Name: ROT -DRILLING Contractor Name: n1334@ppco.com Rig Name: Doyon 141 Date From - To Hours Code Code Phase Spud Date: 8/13/2005 Start: 8/13/2005 End: Rig Release: Group: Rig Number: Description of Operations 9/7/2005 16:00 -18:45 2.75 DRILL PULD PROD2 trip out of hole 87.75 bbls, actual 110.5 bbls 18:45 - 19:30 0.75 FISH PULD CMPLT2 MU whipstock retrieving BHA #12 and RIH to 60' 19:30 - 22:30 3.00 FISH TRIP CMPLT2 RIH with BHA #12 from 60' to 7,100', st wt up 127K, do wt 71 K, RIH with BHA on 4 stds of hybrid push pipe, 65 stds of 4" DP with to-tads and 5 stds of hybrid push pipe 22:30 - 00:00 1.50 FISH FISH CMPLT2 Worked and rotated retrieving hook attempting to engage hook and after 16 attempts est. circ and washed around top of whipstock after 2nd attempt engaged whipstock slot at 7,144' and worked jars up to 200K, (73K over) then pulled up to 215K after jars went off and after 2nd hit on jars whipstock came free 9/8/2005 00:00 - 00:45 0.75 FISH CIRC CMPLT2 Circ btms up after pulling whipstock loose, circ at 242 gpm at 1,100 psi, st wt up 135K 00:45 - 01:00 0.25 FISH OTHR CMPLT2 Monitored well-static, dropped 1 13/16" rabbit on a wire 01:00 - 05:00 4.00 FISH TRIP CMPLT2 POOH with whipstock assembly from 7,145' to 60' 05:00 - 07:00 2.00 FISH PULD CMPLT2 LD whipstock retrieving BHA #12 then LD whipstock assembly with 2 jts of 3 1/2" DP and seal assembly, cleared rig floor, talc fill on trip out of hole 39 bbls, actual 46 bbls 07:00- 07:45 0.75 CASE RURD CMPLT2 RU Doyon's 4 1/2" liner running equipment 07:45 - 08:00 0.25 CASE SFTY CMPLT2 Held PJSM with rig crew, tong operator and Baker Rep on liner running detail and associated hazards 08:00 - 12:30 4.50 CASE PULR CMPLT2 PU &RIH with 4 1/2" liner per well plan to 5,768', ran 3 1/2" ROT guide shoe, 1 bent jt of 3 1/2" 9.3# L-80 Liner with XO to 4 1/2", ran 24 jts (738') of 4 1/2" 12.6#, L-80 slotted liner, 5 jts (155') of 4 1/2" 12.6#, L-80 blank liner with 2-constrictor packers, then RIH with 156 jts slotted (4,792') and 2 pups and 1 jt of 4 1/2" blank liner (50'), ran 1-4 1/2" x 6 1/4" x 8" straight blade aluminum centralizer perjt (184 total) total liner RIH 5,768'. 12:30 - 13:15 0.75 CASE PULR CMPLT2 MU Bakers 7 5/8" x 4 1!2" hook hanger assembly &RIH to 5,809', st wt up 78K, do wt 54K, RD liner running equip. 13:15 - 17:45 4.50 CASE RUNL CMPLT2 RIH with 4 1/2" liner on 4" DP from 5,809', RIH thru window at 7,145' on 1st attempt, cont RIH and liner stopped at 11,044', st wt up 128K, do wt 35K (blk wt) 17:45 - 19:30 1.75 CASE OTHR CMPLT2 Attempted to work liner thru hard spot at 11,044' with no success, POOH 5 stds with liner to 10,644' to PU add. wt pipe and Lo-tads 19:30 - 20:00 0.50 CASE OTHR CMPLT2 PU add. Lo-tads to rig floor and strapped HWDP in pipe shed 20:00 - 22:45 2.75 CASE RUNL CMPLT2 Cont RIH with 4 1 /2" liner from 10,644' to 11,617', st wt up 165K, do wt 35-40K, PU a total of 8 stds of HWDP with 2 Lo-Tads per std while RIH to 11,617', having to work liner down, liner went thru spot at 11,044' ok then sat down solid at 11,170, worked thru and sat down again at 11,468' and worked thru after approx 15 min's, cont to work liner to 11,617', decision was made to POOH and inspect liner. 22:45 - 00:00 1.25 CASE OTHR CMPLT2 POOH with 4 1/2" liner from 11,617' to 11,033', having to remove 1-Lo-tad per std of HWDP in order to set back NOTE: Rig off highline at 0800 hrs and back on highline at 18:15 hrs to install VSM's on J pad 9/9/2005 00:00 - 02:30 2.50 CASE RUNL CMPLT2 Cont POOH with 4 1/2" liner on 4" DP from 11,033' to 5,809' (hook hanger) 02:30 - 03:00 0.50 CASE OTHR CMPLT2 LD excess Lo-tads from rig floor 03:00 - 03:30 0.50 CASE RURD CMPLT2 RU Doyon's 4 1/2" liner handling equip. and held PJSM on LD liner 03:30 - 11:30 8.00 CASE OTHR CMPLT2 POOH LD Bakers 7 5/8" x 4 1/2" hook hanger and 186 jts of 4 1/2" liner, recovered 178 of 184 aliminum centralizers RIH, left in hole 3 full and 3 half pieces of centralizers (Total of 9 halts), recovered both constrictor packers, they were in good condition and hadn't moved on the pipe 11:30 - 12:30 1.00, CASE RURD CMPLT2 RD Doyon's 4 1/2" liner handling equip. and cleared rig floor Printed: 10/21/2005 2:52:30 PM • ConocoPhillips Alaska Page 17 of 29 Operations Summary Report Legal Well Name: 1 J-168 Common W ell Name: 1 J-168 Event Nam e: ROT -D RILLING Contractor Name: n 1334@ ppco.co m Rig Name: Doyon 1 41 Date From - To Hours Code Phase Code 9/9!2005 12:30 - 14:15 1.75 FISH PULD CMPLT2 14:15 - 16:45 2.50 FISH TRIP CMPLT2 16:45 - 17:15 0.50 FISH WASH CMPLT2 17:15 - 18:15 1.00 FISH CIRC CMPLT2 18:15 - 18:45 0.50 FISH CIRC CMPLT2 18:45 - 19:00 0.25 FISH CIRC CMPLT2 19:00 - 21:15 2.25 FISH TRIP CMPLT2 21:15 - 22:30 1.25 FISH PULD CMPLT2 22:30 - 00:00 1.50 FISH OTHR CMPLT2 9/10/2005 00:00 - 00:30 0.50 CASE RURD CMPLT2 00:30 - 00:45 0.25 CASE SFTY CMPLT2 00:45 -04:00 3.25 CASE PULR CMPLT2 04:00 - 04:30 0.50 CASE PULR CMPLT2 04:30 - 05:00 0.50 CASE RURD CMPL72 05:00 - 09:45 4.75 CASE RUNL CMPLT2 09:45 - 11:30 1.75 CASE RUNL CMPLT2 11:30 - 12:30 1.00 CASE CIRC CMPLT2 12:30 - 12:45 0.25 CASE RUNL CMPLT2 12:45 - 13:30 0.75 CASE CIRC CMPLT2 13:30 - 13:45 0.25 CASE OTHR CMPLT2 13:45 - 16:00 2.25 CASE RUNL CMPLT2 16:00 - 16:30 0.50 CASE OTHR CMPLT2 16:30 - 17:30 1.00 RIGMNT RSRV CMPLT2 17:30 - 18:45 1.25 FISH PULD CMPLT2 Spud Date: 8/13/2005 Start: 8/13/2005 End: Rig Release: Group: Rig Number: Description of Operations MU Baker fishing BHA #13 and RIH to 137', MU 6 3/4" rev junk basket with 3 boot baskets and bumperjars, 2-4 3/4" Dc's and 1-jt of HWDP RIH with BHA #13 from 137' and set down at btm of window at 7,157' Reamed thru tight spot at 7,157' to 7,159', 3-4K wob, 25 rpm's, 47 spm, 167 gpm at 600 psi, 4-5K torque, rot wt 75K, up wt 103K, do wt 63K Dropped 7/8" steel ball and cont to circ ball on seat while washing down from 7,159' and tagged top of A2 liner at 7,246', set 5K wt down on TOL with 25 rpm's and 4-7K torque and would not drill off, circ at 71 spm, 252 gpm at 1,600 psi Cont to circ hole working junk baskets, cycled pumps 8 times Pumped out of hole from 7,246' to 7,062' to work junk basket to above TOW at 7,145', circ at 252 gpm at 1,600 psi Monitored well-static, POOH with BHA #13 from 7,062' to BHA at 137' Stood back HDP and Dc's and LD BHA #13, recovered several large ;pieces of aluminum centralizers from rev junk basket, no recovery in boot baskets, junk weighted approx 8 Ibs or equivelant to 1 1/4 centralizer, cleared rig floor Pulled wear bushing and installed test plug, drained stack and functioned rams checking forjunk in stack and found none, pulled test plug and installed wear bushing RU Doyon's 4 1/2" liner running equipment Held PJSM with rig crew, tong operator and Baker rep on liner detail and potential hazards PU &RIH with 4 1/2" liner per well plan to 5,557', ran 3 1/2" ROT guide shoe, 1 bent jt of 3 1/2" 9.3# L-80 Liner with XO to 4 1/2", ran 25 jts (769') of 4 1/2" 12.6#, L-80 slotted liner, 4 jts (124') of 4 1/2" 12.6#, L-80 blank liner with 2-constrictor packers, then RIH with 150 jts slotted (4,602') and 3 blank pups for spacing out, total liner RIH 5,557'. ' MU Baker 5 1 /2" x 4 1 /2" setting sleeve and RIH to 5,316', st wt up 74K, do wt 54K, rotated liner at 20 rpm's with 2K ft-Ibs torque RU Doyon's 4 1/2" liner running equipment and cleared rig floor RIH with 4 1/2" liner on 4" DP from 5,613' to 11,617', no problems RIH thru window, went thru on 1st attempt, cont RIH to 11,617', st wt up at TOW (7,136') 75K, do wt 54K, rotated liner at 20 rpm's with 3K ft-Ibs torque, Note: 11,617' was the deepest finer was ran on 1st trip. Cont RIH with liner from 11,617' to btm at 12,967', RIH with no problems or rotation, st wt up 165K, do 63K, NOTE: Held Pad Evacuation drill with rig and construction crews Dropped 29/32" ball and pumped down to seat, pumped down at 3 bpm at 525 psi, with ball on seat pressured up to 2,600 psi to release HR running tool, slacked off then pressured up to 3,900 psi to blow ball seat, PU and was released from liner, st wt up 135K, slacked off and tagged TOL at 7,362' POOH from 7,362' to 7,094', POOH thru window with no problems ~ (TOW @ 7,145') Circ btms up at 7,094' above TOW, circ at 213 gpm at 1,000 psi Monitored well-static POOH with running tool from 7,094' to running tool at 28' LD liner running tool and cleared rig floor, talc fill on trip out of hole 48 ' bbls, actual 52 bbls Slip and cut 72' of drilling line and serviced top drive MU Baker fishing BHA #14 and RIH to 137', MU 6 3/4" rev junk basket with 3 boot baskets and bumperjars, 2-4 3/4" Dc's and 1 jt of HWDP Printed: 10/21/2005 2:52:30 PM • ConocoPhillips Alaska Page 18 of 29 Operations Summary Report Legal Well Name: 1J-168 Common Well Name: 1J-168 Event Name: ROT -DRILLING Contractor Name: n1334@ppco.com Rig Name: Doyon 141 -Date From - To 'Hours ' Code Code Phase Spud Date: 8/13/2005 Start: 8/13/2005 End: Rig Release: Group: Rig Number: Description of Operations 9/10/2005 118:45 - 20:45 I 2.00 I FISH I TRIP I CMPLT2 - 21:30 I 0.751 FISH I WASH I CMPLT2 21:30 - 21:45 0.25 FISH CIRC CMPLT2 21:45 - 22:00 0.25 FISH OTHR CMPLT2 22:00 - 00:00 2.00 FISH TRIP CMPLT2 9/11/2005 00:00 - 00:30 0.50 FISH TRIP CMPLT2 00:30 - 01:30 1.00 I FISH PULD CMPLT2 01:30 - 03:00 1.501 FISH PULD CMPLT2 03:00 - 05:30 2.50 FISH ~ TRIP CMPLT2 05:30 - 06:30 I 1.00 I FISH I WASH I CMPLT2 06:30 - 06:45 0.25 FISH OTHR CMPLT2 06:45 - 09:30 2.75 FISH TRIP CMPLT2 09:30 - 12:00 2.50 FISH PULD CMPLT2 12:00 - 12:30 0.50 CASE RURD CMPLT2 12:30 - 12:45 0.25 CASE SFTY CMPLT2 12:45 - 15:00 2.251 CASE PULR CMPLT2 15:00 - 18:30 I 3.501 CASE I RUNL I CMPLT2 18:30 - 20:45 2.25 CASE OTHR CMPLT2 20:45 - 00:00 I 3.251 CASE I OTHR I CMPLT2 9/12/2005 100:00 - 00:45 I 0.75 i CASE I CIRC I CMPLT2 RIH with BHA #14 from 137' to 7,070', (TOW @ 7,145') st wt up 108K, do wt 62K, rot wt 76K, 25 rpm's with 5K torque Washed down from 7,070' and tagged top of liner at 7,246', didn't see anything at BOW at 7,157', worked reverse junk basket on TOL with 5K wob, 25 rpm's, 5-7K torque and wouldn't drill off, circ at 337 gpm at 2,800 psi Pumped out of hole from 7,246' to above TOW to 7,130' Monitored well-static POOH with BHA #14 from 7,130' to 2,425' Cont POOH with 6 3/4" rev junk basket on BHA #14 from 2,425' to 137' Stood back 1 std of hybrid push pipe and LD 6 3/4" reverse junk basket, had no recovery in basket, broke out 6 3/4" basket and LD same MU 4 5/8" reverse junk basket on BHA #15 and RIH to 197', MU reverse junk basket onto 2 jts of 2 7/8" PAC DP and RIH with 3-boot baskets, jars and 1 std of hybrid push pipe. RIH with BHA #15 from 197' to 7,220', est circ and rotation, circ at 163 gpm at 700 psi, 25 rpm's with 5K ft-Ibs torque, st wt up 110K, do wt 60K rot 76K Washed and rotated down from 7,220' thru TOL at 7,246' to 7,250', washed down only from 7,250' and started to take 2-3K wt down, PU to 7,250' and washed and rotated down from 7,250' and tagged XO below CSR at 7,297', set 3K wt down on XO and wouldn't drill off, washed down at 71 spm, 252 gpm at 1,450 psi, 25 rpm's with 4-6K torque, PU and washed down to XO again with no fill, pumped out of ho{e to 7,223' to above TOL at 7,246' Monitored well-static POOH with BHA #15 from 7,223' to BHA at 197' Stood back 1 std of hybrid push pipe and LD 4 5/8" reverse junk basket, had no recovery in basket, broke out and LD remaining BHA, recovered 2 cups of fine sand, small pieces of metal and aluminum in boot baskets, cleared rig floor RU Doyon's liner running equipment Held PJSM with rig crew and Baker rep on running of hook hanger assembly MU 7 5/8" x 4 1/2" hook hanger assembly with ECP packer and 90' of 2 3/8" inner string RIH to 265' RIH with hook hanger assembly from 265' and tagged XO below A2 lateral CSR at 7,302.5', (5.49' low), wt up 130K, do wt 78K, PU to top of window at 7,145' Worked hook hanger and bent jt from top of window at 7,145' tagging up on XO of A2 lateral at 7,302.5', after 9 attempts worked hook hanger assembly thru window RIH with hook hanger assembly and tagged up on XO of 5 1/2" setting sleeve at 7,405' (0.13' low) PU and attempted to hook hanger on calc depth with no hook, RIH and hooked hanger 7.53' low after several attempts, after hooking hanger, unhooked and re-hooked 5 times while tagging up on XO each time after unhooking, set 40K down on hook leaving hook assembly bent joint spaced out 2.5' above fully located from 5 1/2" x 4 1/2" XO. Top of hook hanger at 7,148' with end of bent jt at 7,403' Began circ btms up with top of hook hanger at 7,148', circ at 23 spm, 82 gpm at 400 psi, circ while talking to town about setting hook and ECP packer, decision was made to set same. Printed: 10/21/2005 2:52:30 PM • ConocoPhillips Alaska Operations Summary Report Legal Well Name: 1J-168 Common Well Name: 1J-168 Event Name: ROT -DRILLING Contractor Name: n1334@ppco.com Rig Name: Doyon 141 Date From - To Hours Code Code Phase 9!12/2005 100:45 - 01:30 01:30 - 02:15 02:15 - 03:00 03:00 - 07:00 07:00 - 08:30 08:30 - 09:45 09:45 - 10:15 10:15 - 14:00 14:00 - 15:45 15:45 - 17:30 17:30 - 17:45 17:45 - 21:30 21:30 - 22:00 22:00 - 23:00 23:00 - 23:30 23:30 - 00:00 9/13/2005 00:00 - 04:30 04:30 - 06:15 06:15 - 07:00 07:00 - 09:45 09:45 - 10:15 Page 19 of 29 Spud Date: 8!13/2005 Start: 8/13/2005 End: Rig Release: Group: Rig Number: Description of Operations 0.75 CASE CIRC CMPLT2 Dropped 29/32" ball and pumped down to seat, began circ at 105 gpm at 475 psi and slowed to 63 gpm at 175 psi, with ball on seat pressured up to 530 psi. 0.75 CASE OTHR CMPLT2 Turned over to Dowell and pressure tested lines to 4,500 psi, then pressured up in 300 psi increments and opened up by-pass on ECP at 2,700 psi, pressure decreased to 1,600 psi and by pass closed, monitored for 5 min with no decrease in pressure, bled off to 530 psi and checked tank volume and took .75 bbls to inflate ECP, pressured up to 4,700 psi and blew the ball seat. 0.75 CASE CIRC CMPLT2 PU to 7,140' and circ a btms up, circ at 400 gpm at 3,000 psi, monitored well-static 4.00 CASE RUNL CMPLT2 POOH with hook hanger running tool from 7,140' to 121' 1.50 CASE RUNL CMPLT2 POOH LD running tool and 2 3!8" tubing inner string and cleared rig floor 1.25 CASE PULR CMPLT2 MU "B" sand LEM assembly with ZXP packer, hanger, CSR, LEM and 2 jts of 4 112" 12.6 ppf, L-80 IBT tubing and seals, RIH to 217' 0.50 CASE RURD CMPLT2 RD Doyon's 4 1!2" liner running tools 3.75 CASE RUNL CMPLT2 RIH with LEM assembly on 4" DP from 217' and tagged up at 7,167', st wt up 135K, do wt 80K 1.75 CASE RUNL CMPLT2 Attempted to RIH thru hook hanger and was unable to go deeper than 7,172', made 4 attempts by turning LEM 4 full turns and 2-3/4 turns and was able to work LEM down to 7,167', cont to work LEM by turning at 1/4 turn increments and after 10-1/4 turns work down to 7,172' setting 30-40K st wt down, made 20 additional 1!8 turns and was unable to go deeper, Tagged up a couple times @ 7,153'. Decision was made to POOH with LEM 1.75 CASE CIRC CMPLT2 PU to 7,170' and circ btms up at 30 spm, 106 gpm at 350 psi 0.25 CASE OTHR CMPLT2 Monitored well-static 3.75 CASE RUNL CMPLT2 POOH with LEM assembly from 7,170' to 217', SLM out with no correction, talc fill on trip out of hole 50 bbls, actual fill 52 bbls 0.50 DRILL RIRD CMPLT2 RU Doyon's 4 1/2" liner running tools 1.00 CASE PULR CMPLT2 POOH LD ZXP packer, hanger, CSR and LEM, LD 2 jts of 4 1/2" liner with seals, ZXP and LEM looked new, found mute shoe on seals to be damaged with gouges on OD & ID, 4.71" OD mule shoe was egg shaped to approx 4.5", had scarring above mule shoe up into seal area to coincide with gouges on OD of shoe, jt above seals looked ok. 0.50 CASE RURD CMPLT2 RD Doyon's 4 1/2" liner running tools 0.50 WELCT EQRP CMPLT2 Pulled wear bushing 4.50 WELCT BOPE CMPLT2 Install test plug. Test BOP's, IBOP's, Floor & Dart Valves, & Choke Manifold Valves. Pull Test plug and install wear bushing. RILDS. Witness of test waived by AOGCC rep John Spaulding. 1.75 CASE OTHR CMPLT2 Make up "DUMMY LATCH "assembly on MWD tools. Orient to latch. Make up LEM (14.94'), Crossover (1.42), 4 3/4"Integral Blade stabilizer (5.55'), NM Float sub (2.14'), NM F-oat Sub (2.35'), DM HOC ( 8.55'), MWD Gamma / RES (24.18'), TM HOC (11.28'), and Cross over (1.66). 0.75 CASE OTHR CMPLT2 Plug in and upload MWD assembly. 2.75 ~ CASE OTHR CMPLT2 Trip in hole with Dummy Latch assembly from 205' - 7156' (6951'). UP WT = 127K. SO WT = 84K. 178 GPM - 1000 PSI. 0.50 CASE OTHR CMPLT2 Orient to 86 degrees right, and slack off to observe latch up @ 7156' with 20K set down wt, with orientation reading 11 Degrees left of H.S. Pull up and unlatch @ 23K over, and orient to 107 degrees right of H.S. I Slack off, observe latch up @ 7156' with orientation of 8 Degrees left of Printed: 10/21/2005 2:52:30 PM ConocoPhillips Alaska Page 20 of 29 Operations Summary Report Legal Well Name: 1J-168 Common Well Name: 1 J-168 Event Name: ROT -DRILLING Contractor Name: n1334@ppco.com Rig Name: Doyon 141 Date From - To Hours Code I C de Phase Spud Date: 8/13/2005 Start: 8/13/2005 End: Rig Release: Group: Rig Number: Description of Operations 9/13/2005 09:45 - 10:15 0.50 CASE OTHR CMPLT2 H.S. Pull up to unlatch with 23K overpull, and orient to 130 Degrees right of H.S., Slack off to observe latch up @ 7156'with a 5 degrees left of H.S. reading, and 20K set down wt. Pull up to 23K over and unlatch again. Total of 3 times with indication of proper orientation of Hook Hanger. 10:15 - 11:00 0.75 CASE CIRC CMPLT2 Circulate Bottoms up @ 81 SPM, 288 GPM's - 2200 PSI. Obtain Slow pump rates. #1 pump - 20 SPM - 210 PSI, 30 SPM - 400 PSI. #2 Pump - 20 SPM - 190 PSI, 30 -SPM - 390 PSI. Moitor well -Static. 11:00 - 12:00 1.00 CASE OTHR CMPLT2 POOH from 7156' - 6230' (926'). Observed proper hole fill. 12:00 - 13:45 1.75 CASE OTHR CMPLT2 Continue POOH with Dummy Latch assembly from 6230' - 72' (6158'). Calculated hole fill = 50 BBLS, actual fill = 55 BBLS. 13:45 - 14:30 0.75 CASE OTHR CMPLT2 Breakout & Lay down crossover, MWD assembly, and Dummy Latch assembly. BHA total = 72.07' 14:30 - 14:45 0.25 CASE OTHR CMPLT2 Clean & clear floor area, from wet trip. Pull tools to rig floor. 14:45 - 17:00 2.25 CASE OTHR CMPLT2 Make up 4 1/4" tapered mill assembly. Make up 4 1/4" Tapered mill 2.06'), Crossover (1.43'), 2 -jnts 2 7/8" PAC drill pipe (62.44'), crossover (3.58'), 4 3/4" String Mill (4.34'), 3 - jnts 2 7/8" PAC drill pipe 9 94.07'), crossover to 3 1/2 IF (1.78'), Crossover to 3 1/2 REG 1.50'), 3 - 4 3/4" Junk Baskets (10.89'), Crossover( 2.85'), 4 3/4" Bumper jar (7.87'), 4 3/4" Oil jar (11.14'), and crossover to XT39 1.66') Total BHA = 205.61 17:00 - 17:30 0.50 CASE OTHR CMPLT2 Trip in hole from 205' - 1349' (1144'). 17:30 - 18:00 0.50 CASE OTHR CMPLT2 Check pump pressures. ID of tools = 1". 30 SPM - 1000 PSI, then pressure climbed to 2600 PSI. Unplug jet in mill to observe pressure @ 3400 PSI w/ 48 SPM. 18:00 - 20:45 2.75 CASE OTHR CMPLT2 TIH to pressure check @ 2992'. 55 SPM - 3300 PSI. TIH to 5023'. 55 SPM - 2800 PSI. TIH to 5893'. 55 SPM - 2900 PSI. TIH to 6815'. 55 SPM -3400 PSI. Un plugged jet & 58 SPM - 2250 PSI. Tlh to 7162'. Tagged @ 7162 DPM. UP WT = 125K, SO WT = 80K, ROT WT = 95K. 25 RPM's w/ 4-5K torque. 20:45 - 00:00 3.25 CASE OTHR CMPLT2 Rotate @ 25 rpm's to work through spot @ 7162' with no issues. Observe little or no torque increase and continue down to tag crossover in seal bore @ 7302' DPM. Work mills from 7302' - 7271', while circulate btms up. POOH to above Hook Hanger @ 7130', and RIH to tag again at 7162', working mill through with no issues, continuing in hole to tag again at 7302'. 9/14/2005 00:00 - 00:15 0.25 CASE OTHR CMPLT2 POOH to above Hook Hanger @ 7130', and RIH to tag again at 7162', working mill through with no issues, continuing in hole to tag again at 7302'. UP WT = 130K, SO WT = 84K 252 GPM's - 3000 PSI. 00:15 - 01:00 0.75 CASE CIRC CMPLT2 Circulate bottoms up @ 250 GPM's - 3000 PSI. Monitor well -Static 01:00 - 04:30 3.50 CASE OTHR CMPLT2 POOH from 7302' - 205' (7097'). Hole taking proper fill. 04:30 - 06:30 2.00 CASE OTHR CMPLT2 Break out and lay down BHA. Layed down 4 1/4" tapered mill assembly. 4 1/4" Tapered mill (2.06'), Crossover (1.43'), 2 -jnts 2 7/8" PAC drill pipe (62.44'), crossover (3.58'), 4 3/4" String Mill (4.34'), 3 - jnts 2 7/8" PAC drill pipe 9 94.07'), crossover to 3 1/2 IF (1.78'), Crossover to 3 1/2 REG (1.50'), 3 - 4 3/4" Junk Baskets (10.89'), Crossover( 2.85'), 4 3/4" Bumper jar (7.87'), 4 3/4" Oil jar (11.14'), and crossover to XT39 ( 1.66') Total BHA = 205.61 Observed Little or no wear on mills. 06:30 - 07:00 0.50 CASE OTHR CMPLT2 Clean and Clear floor area. Pull tools to rig floor. 07:00 - 07:30 0.50 CASE RURD CMPLT2 Rig up casing running equipment, tongs, elevators and slips. 07:30 - 09:30 2.00 CASE RUNC CMPLT2 Make up B Lateral LEM assembly. Run #2. Make up Seal assembly with bent joint. Change out 5.2" collar to a 4.94" collar (3.27', 43.03'), 1 ~ -jnt 4 1/2 12.6# tbg (30.09'), Camco "D" Nipple (1.52'), 1 -jnt 4 1/2 Printed: 10/21/2005 2:52:30 PM • ConocoPhillips Alaska Page 21 of 29 Operations Summary Report Legal Well Name: 1J-168 Common Well Name: 1J-168 Event Name: ROT -DRILLING Contractor Name: n1334@ppco.com Rig Name: Doyon 141 Date From - To !'~! Hours Code Code Phase Spud Date: 8/13/2005 Start: 8/13/2005 End: Rig Release: Group: Rig Number: Description of Operations 9/14/2005 07:30 - 09:30 2.00 CASE RUNC CMPLT2 09:30 - 10:00 0.50 CASE RURD CMPLT2 10:00 - 12:00 2.00 CASE RUNC CMPLT2 12:00 - 13:45 1.75 CASE RUNC CMPLT2 13:45 - 15:45 2.00 CASE RUNC CMPLT2 15:45 - 19:30 3.75 CASE RUNC CMPLT2 19:30 - 21:30 2.00 CASE RUNC CMPLT2 21:30 - 22:00 0.50 CASE RURD CMPLT2 22:00 - 23:30 1.50 RIGMNT RSRV CMPLT2 23:30 - 00:00 0.50 CASE OTHR CMPLT2 9/15/2005 00:00 - 02:45 2.75 CASE RURD CMPLT2 02:45 - 05:00 2.25 CASE OTHR CMPLT2 05:00 - 08:00 3.00 CASE OTHR CMPLT2 08:00 - 09:45 1.75 CASE OTHR CMPLT2 09:45 - 12:00 2.25 CASE OTHR CMPLT2 12:00 - 13:00 1.00 CASE OTHR CMPLT2 13:00 - 15:45 2.75 CASE OTHR CMPLT2 15:45 - 18:00 ~ 2.25 CASE OTHR CMPLT2 12.6# tbg (30.82'), 2 - 4 1 /2" Pups (3.81', 7.80'), LEM assembly inside Hook Hnager (24.48'), LEM above Hook hanger (10.65"), 2 - 4 1!2" Pup jnts (3.80', 3.82'), Baker casing Swivel (2.45'), XO bushiing 5 1/2 Hydril x 4 1/2 IBT (1.33'), 109-47 Casing Seal Bore 6.26" OD x 4.75" ID (19.11'), ZXP 5 112" x 7 518" Liner top Packer (19.05'), Baker Hydraulic setting tool (5.20'), Baker running tool (5.70'), and XO to DP XT39 1.66'). Rig down casing running Equipment, and clear floor. RIH with LEM assembly on DP, from 218' - 3199' (2994'). Continue RIH with LEM assembly on DP from 3199' - 7166' (3967'). Tagged up @ 7166'. UP WT = 127K, SO WT = 82K. Work through spot @ 7166' and continue down to tag again at 7174' DPM. Attempt to work Mule shoe through, could not get down setting down to 25K. Repeat attempts several times to verify Mule Shoe would not pass through spot, white pumping 106 GPM's - 325 PSI. POOH with LEM assembly from 7172' - 217' (6955'). Hole took proper fill. Rig up casing Equipment. Tongs, elevators and slips. Lay down entire LEM assembly and breakout Casing Swivel form Packer assembly. Observe Mule shoe "pinched" down to 4 1!4" OD, egg shaped and little junk cut damage to OD of mule shoe, and seals. Pictures were taken and sent to town. Rig down casing running Equipment, and clear floor. Slip & cut drilling line, Service Top Drive and inspect saver sub. OK. Pull tools to rig floor and rig up to run 2 7/8 PAC DP for next BHA, Mill 'run. Clean & Clear rig floor area, Wait on mills from Baker, and pull tools to rig floor. Strap & make up BHA -Milling Assembly. Make up 4 1/4" Tapered mill ( 2.06'), Crossover (1.43'), 2 - jnts 2 7/8" PAC DP (62.44'), Crossover 3.58'), 5 1/4" String Mill (4.36'), Crossover (3.55'), 5 1/4" String Mill 4.75'), Crossover (1.78'), 4 3/4" Float Sub (2.14'), XT39 Crossover 1.65'), 3 - jnts DP (93.36'), Crossover (1.64'), Crossover (1.50'), 3 - 4 3/4" Junk Baskets (10.89'), Crossover (2.85'), 4 314" Bumper jar 7.87'), 4 3/4" Oil Jar (11.14'), and Crossover (1.66'). Trip in hole from 218' - 7194' (6976'). Pump down @ 70 SPM - 1900 PSI, while rotating 20-100 RPM's multiple times tagging at 7164' .Observe torque @ 5-6K while rotating. Mill through spot @ 7164' until free. Work mills through spot until free 'travel with no pumps or rotation. Continue work mills through spot between 7228' - 7236' continuously until observed free travel with no pumps or rotation. Continue RIH to tag crossover in SBE @ 7302'. UP WT = 119 K, SO WT = 78K, ROT WT = 92K, TO = 4-6K. Continue work string up to 7116' and down to 7206', and tag Crossover at 7302'. UP WT = 125K, SO WT = 80K, ROT WT = 100K. TO = 5-6K, using pumps at 70 SPM - 1900 PSI. Work up and down with and without pump or rotation to verify clean hole conditions. Pull back to ' 7190', and RIH to tag crossover again @ 7302', observe clean hole, no tag. Monitor well -static. POOH from 7302' - 218' (7084'). Observe proper hole fill. Breakout & lay down milling BHA. Lay down entire assembly as above, Printed: 10/21/2005 2:52:30 PM • Operations Summary Report Legal Well Name: 1J-168 Common Well Name: 1J-168 Spud Date: 8/13/2005 Event Name: ROT -DRILLING Start: 8/13/2005 End: Contractor Name: n1334@ppco.com Rig Release: Group: Rig Name: Doyon 141 Rig Number: Date From - To Hours Code Code Phase 9/15/2005 15:45 - 18:00 ~ 2.25 ~ CASE ~ OTHR ~ CMPLT2 18:00 - 19:30 I 1.501 CASE I RURD 1 CMPLT2 19:30 - 22:45 3.251 CASE RUNC CMPLT2 22:45 - 00:00 I 1.251 CASE I RUNC I CMPLT2 9/16/2005 100:00 - 00:15 I 0.25 I CASE I RUNC I CMPLT2 00:15 - 00:45 0.50 ~ CASE j RUNC CMPLT2 00:45 - 01:00 0.25 CASE DEOT CMPLT2 01:00 - 03:45 2.75 CASE RUNC CMPLT2 ConocoPhillips Alaska Page 22 of 29 Description of Operations and clean junk baskets. Recovered approximately 1/2 cup of metal shavings, and piece of twisted iron 2" long. Mills in gauge to 5 114" and in good shape. Clean floor area, RU casing running equipment. Make up B Lateral LEM assembly. Run #3. Make up Seal assembly with bent joint. Change out 5.2" collar to a 4.94" collar (3.27', 43.47'), 1 - jnt 4 1/2 12.6# tbg ( 30.12'), Camco "D" Nipple (1.52'), 1 - jnt 4 1/2 12.6# tbg (30.84'), 2 - 4 112" Pups (3.80', 7.80'), LEM assembly inside Hook Hanger (24.48'), LEM above Hook hanger (10.65"), 2 - 4 1/2" Pup jnts (3.80', 3.82'), XO bushiing 5 1/2 Hydril x 4 1/2 IBT (1.43'), 109-47 Casing Seal Bore 6.26" OD x 4.75" ID (19.11'), ZXP 5 1/2" x 7 5/8" Liner top Packer 19.05'), Baker Hydraulic setting tool (5.21'), Baker running tool (5.70'), and XO to DP XT39 (1.66'). Total BHA = 215.73' Rig down casing running equipment. Trip in hole with B lateral LEM assembly from 216' - 7174' (6958'). Tag up at 7164', and work mule shoe through spot setting down max weight of 20K to get through. Work approximately 1/2 hour. UP WT = 120K, SO WT = 79K. Continue work LEM assembly down to 7290' with no tagging issues. UP WT = 128K, SO WT = 80K. Pick up 1 single of DP to get to bottom. Continue RIH w/ LEM assembly to tag and latch up on Hook Hanger at 7154.56'. Observed this depth = 6' low. Pull up to 15K over upweight to verify good latch up. Slack off to neutral position. UP WT =128K, SO WT = 82K. Seals positioned @ 7299.86'. (3' above crossover). Rig up and drop 1 1/2" Ball down DP pumping @ 3 1/2 BPM - 250 PSI, until ball seated at 55 BBLS pumped. Continue pressure up to 4300 PSI as per BOT rep to set ZXP packer. Hold 5 minutes and bleed pressure. Rig up. Close Annular and test casing pumping down annulus to 1000 PSI for 10 minutes. Record on chart. Good test. Bleed pressure. Momitor well -static. Pick up above ZXP to allow dogs to kick out on running tool and then slack off to tag and verify top of ZXP @ 7096.70' DPM. Repeat tag. (ZXP = 6.63' Low) POOH. Observed proper hole fill. 03:45 - 04:15 0.50 CASE OTHR CMPLT2 04:15 - 04:45 0.50 CASE OTHR CMPLT2 04:45 - 10:00 5.251 WINDO ULD PROD3 10:00 - 12:00 12:00 - 14:30 14:30 - 15:15 15:15 - 15:30 2.00 WIN 2.50 WIN 0.75 WIN 0.25 WIN PROD3 PROD3 PROD3 PROD3 Breakout & Lay down Baker Hydraulic Setting tool and Running tool. Inspect tools and all looked good. Clean & Clear floor area, lay down tools. Pull tools to rig floor and make up 7 5/8" Whipstock assembly with space out pipe. Made up Seal assembly (2.83'), Stop Sub (1.92'), 4 3/4 Unloader (4.88'), 9 -jnts 3 1/2" DP (281.50'), Blanking sub (1.03'), BTA (3.23'), Safety Disconnect (3.23'), Ported drain sub (1.50'), Debris barrier sub w/ cup (2.02'), 7 5/8" Whipstock (14.36'), 6.125" Starting Mill (1.50'), 6 1/8" Lower Mill (5.52'), 6.750" Upper Mill (5.84'), 1 - Jnt 3 1/2 HWDP (29.83'), Float sub (2.35'), Float sub (2.14'), MWD assembly (44.01'), Bumper jar (7.87'), Bumper Jar (7.83'), Crossover 1.66'), and 2 stands Hybrid Collars (179.70'). Up load MWD and perform shallow pulse test. 70 SPM -700 PSI. Trip in hole at 2 minutes /stand as per BOT rep, from 601' - 2999' 2300'). Obatain SLM on TIH. Continue trip in hole from 2999' - 6626' (3627'), at 2 minutes /stand. UP WT = 122K SO WT = 75K. Perform MAD PASS Log from 6626' - 6712' (86'), AT 250 gpm's - 1650 PSI, at 250 FT/HR. Continue trip in hole at 2 minutes /stand to 7098'. UP WT = 135K, SO Printed: 10/21/2005 2:52:30 PM • ConocoPhillips Alaska Paye 23 of 29 Operations Summary Report Legal Well Name: 1J-168 Common Well Name: 1J-168 Event Name: ROT -DRILLING Contractor Name: n1334@ppco.com Rig Name: Doyon 141 Date From - To Hours Code Code Phase Spud Date: 8/13/2005 Start: 8/13/2005 End: Rig Release: Group: Rig Number: Description of Operations 9/16/2005 15:15 - 15:30 0.25 WINDORIP PROD3 15:30 - 16:15 0.75 WINDO ETW PROD3 16:15 - 17:00 I 0.75 { WINDOWCIRC 1 PROD3 17:00 - 20:00 i 3.00 f WINDOWOTHR I PROD3 20:00 - 21:30 I 1.501 WINDOV~/CIRC PROD3 21:30 - 00:00 2.50 WINDO RIP PROD3 9/17/2005 00:00 - 01:15 1.25 WINDO RIP PROD3 01:15 - 03:00 1 1.75 { WINDOWPULD I PROD3 03:00 - 04:15 I 1.25 I WELCTLI EORP I PROD3 04:15 - 04:45 0.50 RIGMNT RSRV PROD3 04:45 - 08:30 3.75 DRILL PULD PROD3 08:30 - 12:00 I 3.50 I DRILL I TRIP I PROD3 12:00 - 12:15 ~ 0.25 DRILL TRIP PROD3 12:15 - 00:00 I 11.751 DRILL I DRLG I PROD3 9/18/2005 00:00 - 12:00 12.001 DRILL DRLH PROD3 WT = 84K. Orient whipstock face to 7 Degrees left of high side as per DD and BOT rep. Slack off and tag top of ZXP at 7098' and set down to set BTA at 10k. Pull up 10K over to verify set and slack off to shear bolt at 30K. Pick up to neutral position and rotate free of whipstock. Top of whipstock at 6784". The "D" sand top is at 6783". Displace well from SFMOBM to 9.0 PPG MOBM @ 250 GPM's - 1950 PSI. Mill window from 6785' - 6797` (12') in 1.66 HRS. Continue mill OPEN HOLE from 6797' - 6826' (29') in 1.34 HRS for a total milling time of 3.0 HRS, with 20' of gauged hole as per plan. 100 RPM's with torque at 6-8K avg. Pump Hi -Visc sweep at 250 GPM's - 1950 PSI, while dressing window area with mills until window looked clean. PU WT = 125K, SO WT = 80K, ROT WT = 92K. Obtain SPR's at 6787 MD TVD = 3215'. MW 9.0 PPG. #2 pump - 20 SPM - 330 PSI, 30 SPM - 460 PSI. Monitor well -static, pump dry job. POOH with milling assembly. Continue POOH from 2255'-287' (1968'). Breakout & lay down last 10 Lo-Tads in hole for drilling run. Rack back 2 stands Push pipe. Breakout and lay down Milling BHA.. Lay down Crossover (1.66'), 2 - 4 3/4" Bumper Jar (7.83', 7.87'), MWD assembly (44.01'), 2 -Float subs (2.14', 2.35'), 1-jnt 3 1/2" HWDP 29.83'), 6 3/4" Upper mill (5.84'), 6 1/8" Lower mill (5.52'), and starting milt (1.5'). Observed upper mill in full gauge of 6.750". BOLDS and pull wear bushing. Make up stack washer and RIH to flush BOP stack. Function test all rams. Install wear bushng and RILDS. Service Top Drive. Inspect saver sub. OK. Make up BHA #22. Make up 6 3/4" Security FSF2641 bit with TFA of .920 sq in. (1.26'), 5200 Geo-Pilot Assembly (16.18'), 4.68" NM Flex Pony (11.55'), DM Collar (8.29'), 4 3/4" Smart Stabilizer (3.59'), 4 3/4" Slimphase 4 w! DGR (24.51'), PWD collar (10.77'), TM HOC (10.96'), Non Mag float sub (2.35'), NM IBS Stabilizer (5.33'), 3 - NM Flex Drill collars (93.17'), XO sub (1.66'), 1 - 4" HWDP (30.33'), $ 3/4 rilling jars ( 28.90'), 4 - 4" HWDP (120.85'). Orient and perform shallow pulse test. OK. Trip in hole from 370' - 6565' (6195'). Change out bad Lo-tad on stand # 67. Continue TIH from 6565'-6814' (261'). Pass through window area with no issues. Wash & Ream down undergauge hole to 6826'. Clean hole ECD = 10.2 PPG Drill 6 3/4 D Lateral from 6826' - 7755' (929'). TVD = 3246'. ADT = 7.97 HRS. PU WT = 118K, SO WT = 55K, ROT WT = 80K. Torque on = 6K, off = 7K. RPM's = 120. Pump at 300 GPM's-2600 PSI. 85 SPM. Mud weight = 9.0 ppg, YP = 16, Visc = 77, Gels 21128129. Max gas units observed = 198 units. Jars = 111.87 HRS total. Total bit Hrs = 7.97. Slow pump rates #1 - 20 SPM - 340 PSI, 30 SPM - 560 PSI. #2 pump - 20 SPM - 350 PSI, 30 SPM - 530 PSI. Drill 6 3/4 "D" Lateral from 7755 - 9395' (1640'). TVD = 3289'. ADT = 7.78 HRS. PU WT = 145K, SO WT = 43K, ROT WT = 76K. Torque on = 7-8K, off = 6-8K. RPM's = 120. Pump at 300 GPM's-2720 PSI. 85 SPM. Mud weight = 9.0 ppg, YP = 18, Visc = 72, Gels 21!28!33. Max gas units observed = 236 units. WOB = 5-14K. Jars = 119.95 HRS total. Total bit Hrs = 15.75. Slow pump rates #1 - 20 SPM - 400 PSI, 30 Printed: 10/21/2005 2:52:30 PM • ConocoPhillips Alaska Operations Summary Report Legal Well Name: 1J-168 Common Well Name: 1J-168 Event Name: ROT -DRILLING Contractor Name:. n1334@ppco.com Rig Name: Doyon 141 Date From - To Hours Code Code Phase 9/18/2005 00:00 - 12:00 12.00 DRILL DRLH PROD3 12:00 - 12:15 0.25 DRILL DRLH PROD3 12:15 - 12:30 0.25 DRILL CIRC PROD3 12:30 - 13:30 1.00 DRILL TRIP PROD3 13:30 - 15:45 2.25 DRILL DRLH PROD3 15:45 - 21:45 6.00 DRILL DRLH PROD3 21:45 - 00:00 2.25 DRILL DRLH PROD3 9!1912005 00:00 - 04:00 4.00 DRILL DRLH PROD3 04:00 - 04:30 0.50 DRILL CIRC PROD3 04:30 - 12:00 7.50 DRILL DRLH PROD3 12:00 - 17:45 5.75 DRILL DRLH PROD3 17:45 - 20:00 2.25 DRILL CIRC PROD3 20:00 - 00:00 4.00 DRILL DRLH ~ PROD3 Page 24 of 29 Spud Date: 8/13/2005 Start: 8/13/2005 End: Rig Release: Group: Rig Number: Description of Operations SPM - 620 PSI. #2 pump - 20 SPM - 420 PSI, 30 SPM - 630 PSI. ECD @ 11.46 PPG. Pump Hi Visc sweep at 8275'. Observe minimal incresae in cuttings at shakers when sweep returned. Continue drill 6 3/4 "D" Lateral From 9395' - 9435' (40'). TVD -3293'. Stopped Drilling as we are out of zone as per Geologist. Observed Fauli @ 8846' MD with throw 10 -12' down. ADT .45 HRS. Allow Hi Visc sweep to come back, circulating @ 300 GPM's 2720 PSI. while reciprocating drill string. BROOH 2 stands. Pull 5 stands out on elevators from 9435' - 8664' 771') Trough with 6 3/4" Geo-pilot assembly from 8664' - 8680 (16'). Perform sidetrack and drill 6 3/4" hole from 8680' - 9435' (755'). ADT = 5.16 HRS. UP WT = 127K, SO WT = 50K. ROT WT = 80K Torque On/OFF BTM = 8K. Drill 6 3/4 "D" Lateral from 9395' - 9629'. (234'). TVD = 3306'. ADT = 1.83 HRS. PU WT = 130K, SO WT = 50K, ROT WT = 77K. Torque on = 8K, off = 9K. RPM's = 120. Pump at 300 GPM's-2700 PSI. 85 SPM. Mud weight = 9.0 ppg, YP = 18, Visc = 72, Gels 22130133. Max gas units observed = 223 units. WOB = 5-10K. Jars = 126.09 HRS total. Total bit Hrs = 22.19. Slow pump rates @ 9049'. TVD - 3281'. #1 - 20 SPM - 420 PSI, 30 SPM - 620 PSI. #2 pump - 20 SPM - 450 PSI, 30 SPM - 640 PSI. MAX ECD @ 11.8 PPG. Pump Hi Visc sweep. Observed 15 - 20 %incresae in cuttings at shakers. Dri116 3/4 "D" Lateral from 9629' - 10112' (483'). TVD = 3322'. ADT = 3.49 HRS. PU WT = 135K, SO WT = 49K, ROT WT = 75K. Torque on = 8K, off = 9K. RPM's = 120. Pump at 300 GPM's-2700 PSI. 85 SPM. Mud weight = 9.0 ppg, YP = 20, Visc = 77, Gels 21/33. Max gas units observed = 177 units. WOB = 5-10K. Jars = 129.58 HRS total. Total bit 'Hrs = 25.68. MAX ECD @ 11.8 PPG. Pump 35 BBL Hi Visc sweep. Observed 15 - 20 °lo incresae in cuttings at shakers. Complete circulating #2 Hi Visc sweep while reciprocating drill string at 300 GPM's - 2700 PSI. ECD's @ 11.8 PPG ,down to 11.3 PPG. Observed 20-30% increase in cuttings at shakers. Dril16 3/4 "D" Lateral from 10112' -10886'. (774'). TVD = 3324'. ADT = 4.21 HRS. PU WT = 144K, SO WT = 42K, ROT WT = 75K. Torque on = 8K, off = 9K. RPM's = 120. Pump at 300 GPM's-2975 PSI. 85 SPM. Mud weight = 9.0 ppg, YP = 18, Visc = 72, Gels 22/30/33. Max gas units observed = 177 units. WOB = 5-10K. Jars = 133.89 HRS total. Total bit Hrs = 29.89. Slow pump rates @ 10209'. TVD - 3323'. #1 - 20 SPM - 520 PSI, 30 SPM - 710 PSI. #2 pump - 20 SPM - 530 PSI, 30 SPM - 720 PSI. MAX ECD @ 12.01 PPG. Pump Hi Visc sweep. 'Concretions @ 10013' - 10016' (3'). Continue Drill 6 3/4 "D" Lateral from 10886' - 11369'. (483'). TVD = 3348'. ADT = 2.95 HRS. PU WT = 146K, SO WT = 38K, ROT WT = 84K. Torque on = 11 K, off = 11 K. RPM's = 120. Pump at 300 GPM's-3150 PSI. 85 SPM. Mud weight = 9.0 ppg, YP = 21, Visc = 82, Gels 25/37. Max gas units observed = 135 units. WOB = 5-15K. Jars = 136.84 HRS total. Total bit Hrs = 32.84. MAX ECD @ 12.2 PPG. Pump Hi Visc sweep. Change out GEO -SPAN on rig floor, valve failed. Complete circulating Hi Visc sweep while BROOH and stand back 1 stand, at 300 GPM's - 3200 PSI. ECD's @ 12.2 PPG ,down to 11.8 PPG. Observed 20% increase in cuttings at shakers. ,Continue Drill 6 3/4 "D" Lateral from 11369' - 11709'. (340'). TVD = Printed: 10/21/2005 2:52:30 PM • ConocoPhillips Alaska Page 25 of 29 Operations Summary Report Legal Well Name: 1J-168 Common Well Name: 1 J-168 Event Name: ROT -DRILLING Contractor Name: n1334@ppco.com Rig Name: Doyon 141 Date From - To Hours Code Code Phase Spud Date: 8/13/2005 Start: 8/13/2005 End: Rig Release: Group: Rig Number: Description of Operations 9/19/2005 ~ 20:00 - 00:00 ( 4A0 DRILL (DRLH i PROD3 9/20/2005 ~ 00:00 - 12:00 12.00 ~ DRILL DRLH PROD3 3365'. ADT = 2.12 HRS. PU WT = 148K, SO WT = 36K, ROT WT = 84K. Torque on = 11 K, off = 11 K. RPM's = 120. Pump at 300 GPM's-3200 PSI. 85 SPM. Mud weight = 9.0 ppg, YP = 21, Visc = 82, Gels 25137. Max gas units observed = 135 units. WOB = 5-15K. Jars = 138.96 HRS total. Total bit Hrs =34.96. Slow pump rates @ 11274'. ND - 3351'. #1 - 20 SPM - 710 PSI, 30 SPM - 890 PSI. #2 pump - 20 SPM - 720 PS1, 30 SPM - 930 PSI. MAX ECD @ 12.2 PPG. Pump Hi Visc sweep as neede to control ECD. Concretions @ 11647'-11652' (5'), 11656'-11660' (4'). Continue Drill 6 3/4 "D" Lateral from 11709' - 12796. (1087'). ND = 3416'. ADT = 7.95 HRS. PU WT = 174K, SO WT = 35K, ROT WT = 93K. Torque on = 11.5K, off = 10K. RPM's = 125. Pump at 300 GPM's-3900 PSI. 85 SPM. Mud weight = 9.0+ ppg, YP = 20, Visc = 74, Gels 22!29. Max gas units observed = 161 units. WOB = 5-15K. Jars = 146.91 HRS total. Total bit Hrs = 42.91. Slow pump rates @ 12297'. ND - 3391'. #1 - 20 SPM - 620 PSI, 30 SPM - 820 PSI. #2 pump - 20 SPM - 650 PSI, 30 SPM - 830 PSI. MAX ECD @ 12.2 PPG. Concretions @ 11735'-11737' (2'), 11780'-11781' (1'), 11881' - 11882' 1'), 12220' - 12240' (20'), 12583' - 12593' (10'), 12658' - 12686' (28'). 12:00 - 15:00 3.00 DRILL DRLH PROD3 Continue Drill 6 3/4 "D" Lateral from 12796 - 12959' MD (163'). ND = 3424'. ADT = 2.0 HRS. PU WT = 165K, SO WT = 55K, ROT WT = 100K. Torque on = 10.5K, off = 11 K. RPM's = 125. Pump at 300 GPM's-2900 PSI. 70 SPM. Mud weight = 9.2 ppg, YP = 22, Visc = 83, Gels 22/32. Max gas units observed = 102 units. WOB = 2-5K. Jars = 148.91 HRS total. Total bit Hrs = 44.91. Slow pump rates @ 12297'. ND - 3391'. #1 - 20 SPM - 620 PSI, 30 SPM - 820 PSI. #2 pump - 20 SPM - 650 PSI, 30 SPM - 830 PSI. MAX ECD @ 12.2 PPG. Pump Hi Visc weighted sweep @ 12842' ECD @ 11.8 PPG Observe 20% increase in cuttings at shakers when sweep out of hole. 12959' = TD we TD'd the well with lower flow rates of 67 SPM (240 gpm)- due to losses. 132 BBLS total fluid loss. 15:00 - 00:00 9.00 DRILL WIPR PROD3 Obtain Surveys, Monitor well -Static. BROOH from 12959' - 7697' 5262'). Average back reamming speed @ 25 - 40 ft/minute. Staged pump rates up from 230 GPM's - 2700 PSI, 285 GPM's, and back to 300 GPM's - 2800 PSI, as we BROOH. Losses seemed to slow down upon reaching window. 9/21/2005 00:00 - 01:30 1.50 DRILL WIPR PROD3 Obtain Surveys, Monitor well -Static. BROOH from 7697'-6924' (773'). Average back reamming speed @ 25 - 40 fUminute. Staged pump rates up from 230 GPM's - 2700 PSI, 285 GPM's, and back to 300 GPM's - 2800 PSI, as we BROOH. Losses seemed to slow down upon reaching i window. Observed no issues when BHA going through window area. While BROOH, calculated displacement = 47.3 BBLS. Hole fill was 80.3 BBLS. 01:30 - 03:00 1.50 DRILL CIRC PROD3 Pump Hi Visc weighted sweep @ 300 GPM's - 2300 PSI. Observed 25°!° increase in cuttings on shakers. Reciprocate drill string while circulating at 120 RPM's with torque @ 5K. UP WT = 112 K, SO WT = 60K. 03:00 - 04:15 1.25 RIGMNT RSRV PROD3 Slip & cut 72' od drilling line. Inspect and service Top Drive & Drawworks. 04:15 - 08:30 4.25 DRILL WIPR PROD3 POOH with last 3 stands of Lo-Tads on DP. Inspect and change out 8 Total Lo-Tads on stands # 66,68,69,70,71,73,86, and 87. Lo-Tads had , flat rollers and plastic insert washed out. Trip in hole to 10974' (4340'). Printed: 10/21/2005 2:52:30 PM • ConocoPhillips Alaska Page 26 of 29 Operations Summary Report Legal Well Name: 1J-168 Common Well Name: 1J-168 Event Name: ROT -DRILLING Contractor Name: n1334@ppco.com Rig Name: Doyon 141 Date From - To Hours Code Code i Phase Spud Date: 8/13/2005 Start: 8/13/2005 End: Rig Release: Group: Rig Number: Description of Operations 9/21/2005 04:15 - 08:30 4.25 DRILL WIPR PROD3 08:30 - 12:00 3.50 DRILL WIPR PROD3 12:00 - 12:15 I 0.251 DRILL I WIPR I PROD3 12:15 - 15:00 I 2.751 DRILL I C1RC I PROD3 15:00 - 16:45 1.751 DRILL ~ CIRC PROD3 16:45 - 00:00 I 7.251 DRILL I TRIP I PROD3 9/22/2005 00:00 - 00:45 0.75 DRILL 'TRIP PROD3 00:45 - 04:00 3.25 DRILL PULD PROD3 04:00 - 04:45 ~ 0.75 ~ WINDOV'iIPULD CMPLT3 04:45 - 07:15 I 2.501 WINDOWTRIP .CMPLT3 07:15 - 07:45 I 0.501 WINDOWOTHR I CMPLT3 07:45 - 08:30 I 0.751 WINDOWCIRC I CMPLT3 08:30 - 09:15 0.75 WINDO~RIP CMPLT3 09:15 - 09:45 0.50 WINDO RIP CMPLT3 09:45 - 12:00 I 2.25 WINDOV~ITRIP CMPLT3 12:00 - 14:30 2.50 ~ WINDOVVITRIP CMPLT3 14:30 - 16:30 { 2.00 WINDOVIIPULD CMPLT3 16:30 - 17:00 I 0.501 WINDOWPULD I CMPLT3 Observed no downweight left. Wash & rotate down from 10974' - 12846' (1872'), with pumps at 64 SPM, 227 GPM - 2500 PSI. 110 RPM's with torque at 8.5K. UP WT = 160K, SO WT = 52K, ROT WT = 105K. Wash & rotate down from 12846' - 12959' (113'), with pumps at 64 SPM, 230 GPM - 2825 PSI. 110 RPM's with torque at 8.5K. UP WT = 160K, SO WT = 52K, ROT WT = 105K. Pump Hi Visc weighted sweep and circulate out plus 1 bottoms up @ 230 GPM's - 2825 PSI, while reciprocate drill string @ 120 RPM's - 8K TO. Held PJSM, discuss Safety and Spill Prevention. RU and displace MOBM with SFMOBM @ 230 GPM's - 2825 PSI. Monitor well -static. POOH on elevators from 12959' - 2237' (10722'), with no swabbing observed. End of tour PU WT = 62K, SO WT = 52K. Total fluid loss this tour = 105 BBLS. Drop 1 3/4" Steel Hollow drift in DP on POOH. Continue POOH, from 2237' - 369' (1868'). Breakout & lay down BHA. Download MWD tools. Lay down BHA #22, 6 3/4" Security FSF2641 bit with TFA of .920 sq in. (1.26'), 5200 Geo-Pilot Assembly (16.18'), 4.68" NM Flex Pony (11.55'), DM Collar 8.29'), 4 3/4" Smart Stabilizer (3.59'), 4 3/4" Slimphase 4 w/ DGR 24.51'), PWD collar (10.77'), TM HOC (10.96'), Non Mag float sub 2.35'), NM IBS Stabilizer (5.33'), 3 - NM Flex Drill collars (93.17'), XO sub (1.66'), 1 - 4" HWDP (30.33'), 6 3/4 drilling jars (28.90'), 4 - 4" HWDP(120.85').Gaugebitto I/I/CT/N/X/I/NO/TD MAke up BHA # 23, Whipstock retrieving assembly. Make up Retrieving Hook (7.5'), 1 - jnt 3 1/2 HWDP (29.85), 4 3/4" Float sub (2.35'), 4 3/4" Bumper jar (7.86'), 4 3/4" Oil Jar (11.13'), crossover (1.66), 3 - stands Hybrid Push Pipe (270.26). Retrieving slot @ 6789'. TIH from 330' - 6769' (6439'). UP WT = 107K, SO WT = 61 K. Pumps at 124 GPM's - 300 PSI. 35 SPM. Attempt to hook slot @ 6782' DPM. Work 1!4 turns in string 4 times to wash slot and hook whipstock slot. Slack off and confirm hook in slot with set down weight 10K. Pull up from 127K, up to 200K cocking and firing jars to release whipstock and observe 9K increase in upweight. Now UP WT = 116K. NOTE: Found slot @ 6782' = 7' higher. Circulate bottoms up @ 170 GPM's - 575 PSI @ 6764'. Monitor well - static. POOH from 6764' - 6302' (462'). Observed swabbed in 1 BBL. Close rams and pump 3 BBLS into DP. Pull 1 stand @ 5 FT/MIN with proper hole fill. Pull 4 stands @ 25 FT/MIN w/ proper hole fill. Continue POOH to 4004' observing proper hole fill. Continue POOH with whipstock asembly observing proper hole fill form 4004' - 330' (3674'). Calculated hole fill @ 89 BBLS, actual fill = 91 BBLS. POOH, breakoput & lay down Whipstock retrieving assembly as above. Continue POOH breakout and lay down 7 5/8" Whipstock assembly with space out pipe. Seal assembly (2.83'), Stop Sub (1.92'), 4 3/4 Unloader (4.88'), 9 -jnts 3 1/2" DP (281.50'), Blanking sub (1.03'), BTA (3.23'}, Safety Disconnect (3.23'), Ported drain sub (1.50'), Debris barrier sub w/ cup (2.02'), 7 5/8" Whipstock (14.36'), Clean floor area, and lay down tools on beaver slide. Printed: 10/21/2005 2:52:30 PM • ConocoPhillips Alaska Page 27 of 29 Operations Summary Report Legal Well Name: 1 J-168 Common W ell Name: 1 J-168 Spud Date: 8/13/2005 Event Nam e: ROT -D RILLING Start: 8/13/2005. End: Contractor Name: n 1334@ ppco.com Rig Release: Group: Rig Name: Doyon 1 41 Rig Number: Date From - To Hours Code Code Phase Description of Operations 9/22/2005 17:00 - 22:00 5.00 CASE RUNC CMPLT3 Held PJSM, discuss Safety & running detail. Rig up casing running tools. Make up 4 1/2" Bent joint with crossover (30.65'). Continue RIH with 4 1/2 L-80 IBT Slotted Liner assembly,Average MU torque = 5700 - 6000 FT/LBS. 22:00 - 00:00 2.00 CASE RUNC CMPLT3 Held PJSM with entire crew.( New crew /Change out day) Discuss safety and procedure to make up 3 1/8" Super Slim MWD tool on inner string of Hook Hanger.BOT Hook Hanger BOT Model B1 Hook hanger to MWD to Hook (180 degrees out). MWD offset = 161.45 degrees. UP WT = 79K, SO WT = 52K. 9/23/2005 00:00 - 00:30 0.50 CASE RURD CMPLT3 Pull Lo-Tads to floor to add to string. Rig down casing running equipment. 00:30 - 05:00 4.50 CASE RUNG CMPLT3 TIH, installing 2 - Lo-Tads on stands #1- #7 as per TAD engineer. Perform Shallow pulse test on MWD at 6265' w! 33 SPM -575 PSI, 120 GPM. Continue TIH to attempt getting bent joint through window, tagged up @ 339' down on crossover bushing @ 7135'. Pull up above window, putting 114 RH turns in string for a total of 6 attempts before finally rotating at 5 RPM's, 3K torque to observe bent joint through window. 05:00 - 09:30 4.50 CASE RUNC CMPLT3 Continue trip in hole from bottom of 7 5/8" window @ 6796' - 12929' 6133'). We did not have to rotate string to get to bottom. 09:30 - 11:15 1.75 CASE RUNC CMPLT3 Pumps on, attempt to orient with MWD tool, and we could not move pipe down. Rack back 1 stand, work pipe until verify free movement, and RIH w/ orientation of 8 Degrres left of high side. Hook Hanger. Pull free and orient to 180 degrees out, and run in hole past the window with Hook. Pull back and re-orient to 7 degrres left to hook, Hook Hanger. Good latch up, and several tool faces were pumped up to verify orientation. Drop 29/32" ball and allow to seat, pumping 2 BBIs a minute, 400 PSI .Pressure to 4190 PSI, to shear out ball seat & release from Hook Hanger. Pull up high enough to observe Setting tool released and 55K weight loss. Bottom of window = 6796'. Hook on depth. 11:15 - 12:00 0.75 CASE RUNC CMPLT3 Monitor well -static. POOH from 6771' - 6423' (348'). PU WT = 137K, SO WT = 86K. 12:00 - 15:00 3.00 CASE RUNG CMPLT3 Continue POOH from 6423'. Breakout & lay down Lo-Tads off of stands #1 -#7. 15:00 - 15:45 0.75 ~ CASE ,RURD CMPLT3 Breakout & Lay down running and setting toots, inspect same. All good. 15:45 - 16:15 0.50 CASE RURD CMPLT3 Breakout & lay dowm 3 1/8" MWD assembly i~ crossovers. 16:15 - 17:15 1.00 CASE OTHR CMPLT3 ' Clean & clear floor area. Remove Lo-Tads and Rig down all casing ~ running equipment, and Baker tools. 17:15 - 00:00 6.75 CASE OTHR CMPLT3 Rig up. Breakout & lay down 15 stands of Hybrid push pipe in derrick. Continue breakout and lay down 33 stands of 4" XT39 Drill Pipe. Making room in derrick for 4 1/2" completion tbg. Note: Held scheduled Safety Shutdown at rig camp with all drilling supervisors, rig hands, including service contractors. Topic: Pinch 9/24/2005 00:00 - 01:00 1.00 CASE SFTY CMPLT3 Points. Held safety Stand down with Kuparuk Team Leader and entire Rig Team, including service contractors, and HSE reps. Topic - "Pinch Points". 01:00 - 08:30 7.50 CASE OTHR CMPLT3 Continue Lay down 32 stands of 4" DP, 8 stands of 4" HWDP w/ Lo-Tads, and 34 stands 4" DP w/ Lo-tads. 74 stands total and 42 Lo-Tads. 08:30 - 09:00 0.50 CMPLTN RURD CMPLT3 i Clear and clean Rig Floor area. Lay down all uneccessary tools. Printed: 10/21/2005 2:52:30 PM • ConocoPhillips Alaska Page 28 of 29 Operations Summary Report Legal Well Name: 1J-168 Common Well Name: 1J-168 Event Name: ROT -DRILLING Contractor Name: n1334@ppco.com Rig Name: Doyon 141 Date From - To Hours Code Code Phase Spud Date: 8/13/2005 Start: 8/13/2005 End: Rig Release: Group: Rig Number: Description of Operations 9/24/2005 09:00 - 09:30 0.501 CMPLTN RUNT CMPLT3 Rig up tubing running equipment, tongs, elevators etc.. 09:30 - 12:00 2.50 CMPLTN RUNT CMPLT3 Pick up singles of 4 1/2, 12.6#, L-80, IBTM SCC tubing from shed and RIH with 31 joints. Make up Torque =3400 FT/LBS. 12:00 - 15:45 3.75 CMPLTN PULD CMPLT3 Continue Pick up singles of 4 1/2, 12.6#, L-80, IBTM SCC tubing from shed and RIH with 155 joints. Total ran in hole = 186 or 62 stands. Make up Torque = 3400 FT/LBS. 15:45 - 16:45 1.00 CMPLTN RURD CMPLT3 Rig Down tubing tongs and rig up Double stack tongs. 16:45 - 17:15 0.50 CMPLTN RURD CMPLT3 Attempt to repair Double stack tongs. Could not repair gauge or Hydraulic hose. Lay down and replace tongs. 17:15 - 21:15 4.00 CMPLTN PULD CMPLT3 POOH, stand back 62 stands of 4 1/2 tbg. 186 Joints total. 21:15 - 21:45 0.50 CMPLTN RURD CMPLT3 Clear and clean rig floor area. 21:45 - 00:00 2.25' CMPLTN RURD CMPLT3 Held PJSM, discuss rigging up Centrilift equipment,and running procedure. Load Centrilift Motor, Tandem Seal section, and TTC ~ crossover with Screen Intake, GLM's, in pipe shed. Rig up Spooling Unit, and pull all tools to rig floor. Pull 100 Cannon Clamps, 3 -Flat Guards, and SS Flat bands to rig floor, and double check count. Double check count on 4 1/2" tubing in shed. 240 Joints total. 9/25/2005 00:00 - 01:30 1.50 CMPLTN RURD CMPLT3 Continue Rig up Centrilift equipment. Pull 100 Cannon Clamps to rig floor. Visually inspect and strap all equipment to be run. 01:30 - 03:30 2.00 CMPLTN RUNT CMPLT3 Hold PJSM with crew& Centrilift Rep.. Discuss Safety & Running Procedures and Installation Procedure of all Clamps. Pick up a 5.62" OD Motor 418 HP-KMFER - 2610/98 Serial # 21 K68696 (33.90') with an A-Well I Pump gauge 4.50" OD Serial# 216 (2.09'). Make up a 6" OD Motor Centralizer Serial # 63569 (1.98') on bottom of A-Well Pump Gauge. Load motor with Centrilift CL-5 oil, and continue Make up 5.13" OD Tandem Seal Section GSB 3 DB AB/HSN (13.82'). Verify free rotation travel in Motor and load TSS with CL-5 oil. Make up TTC Crossover w/ Screen Intake 5.13" OD (10.60') with 4 1/2 12.6# L-80 IBTM SCC tubing pup (5.84'). Continue fill with oil and check all vent, construction & drain plugs, to be tight. Check resistivity in Motor @ .6 OHMS. After not being install pulled back up and Install 3 Flatguards on line and secure same, with 3 Proctetolizer guards. The centrilift hand said he got ahead of himself. 03:30 - 06:45 3.25 CMPLTN RUNT CMPLT3 Rig up, and hang ESP line Sheave, Make up ESP line and 1/4" control line to A-Well Gauge and Motor using Stainless Steel Flat bands and Cannon Clamps for attachment. Meaure OD of of Cannon Clamps on Motor @ 5 7/8", on TSS @ 5 13/16", and on TTC @ 5 3/4". Measure OD of Cannon Clamp on tubing collars at 5 13/16". Run 2 -juts 4 1/2" TBG, and Centrilift A-Well Discharge Pressure Sub. Attach 1/4" control line to same with Cannon Clamp and measure OD @ 5 13/16". 06:45 - 10:00 3.25 CMPLTN RUNT CMPLT3 RIH with 4 1/2" Tubing stands from derrick installing Cannon Clamps on every other joint. Run 8 stands (738.12'), and install Camco GLM KBG-2 4 1/2" x 1" w/ 1/4" Orifice Valve BK-5 Latch and pups (18.84'). Test ESP line evrey 1000'. Continue run 4 1/2" tbg from derrick. Test line on stand #20, and ESP line failed test. (2742'). 10:00 - 10:30 0.50 CMPLTN RUNT CMPLT3 Continue attempt to get good test on ESP line. No Good. 10:30 - 12:00 1.50' CMPLTN RUNT CMPLT3 POOH, looking for bad cable from 2742' - 2006'. Rack back 8 stands. 12:00 - 12:45 0.75 CMPLTN RUNT CMPLT3 Continue POOH looking for failed line, and observe "bad spot" in line at the first GLM. The ESP line was clamped improperly on the side of the GLM, and was dragging on low side of hole causing a wear spot causing ESP line to fail. . 12:45 - 17:00 4.25 CMPLTN RUNT CMPLT3 Centrilift hand cut and removed 120' of bad line, and spliced line back i j together. Test line to good test. Printed: 10/21!2005 2:52:30 PM • ConocoPhillips Alaska Operations Summary Report Legal Well Name: 1 J-168 Common Well Name: 1J-168 Event Name: ROT -DRILLING Contractor Name: n1334@ppco.com Rig Name: Doyon 141 Date From - To Hours Code Code Phase 9/25/2005 117:00 - 18:45 18:45 - 00:00 1.75 I CMPLTNI RUNT I CMPLT3 5.25 I CMPLTNI RUNT I CMPLT3 9!26/2005 00:00 - 02:00 2.001 CMPLTNI RUNT CMPLT3 02:00 - 02:30 I 0.50 {CMPLTNI RUNT I CMPLT3 02:30 - 06:00 3.501 CMPLTNI RUNT 1 CMPLT3 06:00 - 08:00 2.00 {CMPLTNI RUNT 1 CMPLT3 08:00 - 09:30 1.501 CMPLTN NUND CMPLT3 09:30 - 10:00 0.50 CMPLTN NUND CMPLT3 10:00 - 11:00 1.00 CMPLTN NUND CMPLT3 11:00 - 12:00 1.00 CMPLTN NUND CMPLT3 12:00 - 12:30 0.50 CMPLTN SEOT CMPLT3 12:30 - 13:00 0.501 CMPLTNI SEOT CMPLT3 13:00 - 16:00 3.00 CMPLTNI FRZP CMPLT3 16:00 - 17:15 1.25 CMPLTN RURD CMPLT3 17:15 - 19:15 2.00 CMPLTN RURD CMPLT3 19:15 - 19:45 0.50 CMPLTN OTHR CMPLT3 19:45 - 20:30 0.75 CMPLTN RURD CMPLT3 20:30 - 22:30 2.001 CMPLTNI NUND CMPLT3 22:30 - 00:00 I 1.501 CMPLTNI OTHR I CMPLT3 Page 29 of 29 Spud Date: 8/13/2005 Start: 8/13/2005 End: Rig Release: Group: Rig Number: Description of Operations Continue RIH with 4 1/2" tbg from derrick installing Cannon Clamps on every other joint. Test ESP line at 20 stands. Good test. Continue RIH with 4 1/2" tbg from derrick installing Cannon Clamps on every other joint. Test ESP line every 1000 feet. Good test. 55 stands total in hole at midnight. Continue RIH with 4 1/2" tbg from pipe shed installing Cannon Clamps on every otherjoint. Test ESP line. Good test. Run 2 -jnts 4 1/2" tbg, Camco GLM KBG-2 4 1/2" x 1" with Dummy and pups (18.91'), 1 -jnt 4 1/2" tbg (30.85'), Camco GLM KBG-2 4 1/2" x 1" with Dummy and pups (18.87'), 1 - jnt 4 112" tbg (31.05'), 2 - 4 112" tbg space out pups 5.76', 7.81'). Avg MU torque = 3400 FULBS Pick up landing joint, and Vetco Gray 11" x 4 1/2" hanger with a joint of 4 1/2" tbg made up on it (32.57'). Make up joint and hanger. UP WT = 92K, SO WT = 60K. Lower hanger to rotary table, installing Stainless Steel Flat clamps. Install Penetration sub in hanger. Centritift hand splicing ESP line, and make up pigtail to hanger.Test same. Good Test. RIH land Tbg hanger as per Vetco Gray rep. UP WT = 92K, SO WT = 60K. Run in lock down screws. Test hanger seals, upper and lower to 250 PSI -low test. 5000 PSI -high test for 15 minutes. Nipple down BOP stack Remove hold down cap on tubing hanger. Clear floor area, and test ECP cable with Centrilift. Good test. Hang Tree on tugger. Nipple up Tree as per Vetco rep. Rig up and test Tree void to 250 PSI low, 10 minutes. 5000 PSI high for 15 minutes. Tets Tree Flanges to 250 PSI low -10 minutes, 5000 PSI high - 15 minutes. Centrilift rep tested Penetrator Sub and ESP line. All good tests. Held PJSM. Discuss Safety and procedure to displace. Rig up Little Red Serices and pump 250 BBLS of Diesel @ 2.75 BBUMIN , 300 -500 PSI, down annulus for freeze protecting the well. Rig down Little Red and secure valves. Breakout & lay down last 21 stands of 4" XT39 DP in derrick with Lo-Tads. Lay down Bales form Top Drive. Change out Saver Sub, while rig up scaffolding in cellar area. Install BPV as per Vetco Rep. Begin cleaning pits and rockwasher pits. Continue Change out saver sub while break down and remove scaffolding from cellar area. Nipple up Actuator Valve on tree and secure well. Record shut in pressures. TBG Pressure = 225 PSI. Inner Annulus Pressure = 250 PSI. Outer Annulus Pressure = 0 PSI. Clean up cellar area, Suck out all fluids with super sucker truck, and wipe down tree. Rig Released @ 2400 HRS. Printed: 10/21/2005 2:52:30 PM Halliburton Sperry-Sun Western North Slope ConocoPhillips Kuparuk 1 J Pad 1 J-168 Job No. AK ZZ-0003877631, Surveyed: 30 August 2005 Survey Report 4 October, 2005 Your Ref.• 500292326000 • Surface Coordinates: 5945652.97 N, 558712.01 E (70° 15'43.6408" N, 149° 31' 31.3352" YIQ Grid Coordinate System: NAD27 Alaska State Planes, Zone 4 Surtace Coordinates relative to Project H Reference: 945652.97 N, 58712.01E (Grid) Surface Coordinates relative to Structure: 266.05 S, 80.03 W (True) ~~ Kelly Bushing Elevation: 109.OOft above Mean Sea Level Kelly Bushing Elevation: 109.OOft above Project V Reference Kelly Bushing Elevation: 109.OOft above Structure E~"~~/-U~"1 ~ ~ < <- ~ ~ ~ ~ s Survey Ref.• svy2217 A HatlRbgr6On Coarrpa~ny Halliburton Sperry-Sun Survey Report for Kuparuk 1J Pad -1J-188 Your Ref.• 500292326000 Job No. AK 2Z-0003877631, Surveyed: 30 August, 2005 ConocoPhillips Western North Slope Measured True Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (°/100ft) 0.00 0.000 0.000 -109.00 0.00 0.00 N 0.00E 5945652.97 N 558712.01E 0.00 CB-SS-Gyro 79.35 0.240 263.900 -29.65 79.35 0.02 S 0.17 W 5945652.95 N 558711.84E 0.302 -0.02 168.30 0.200 240.160 59.30 168.30 0.11 S 0.49 W 5945652.85 N 558711.53E 0.111 -0.11 264.30 0.890 246.800 155.29 264.29 0.49 S 1.32 W 5945652.47 N 558710.70E 0.721 -0.49 356.30 3.100 241.090 247.23 356.23 1.98 S 4.15 W 5945650.96 N 558707.88E 2.409 -1.98 447.30 5.190 242.190 337.99 446.99 5.09 S 9.95 W 5945647.81 N 558702.10E 2.298 -5.09 540.30 6.530 242.880 430.50 539.50 9.46 S 18.37 W 5945643.37 N 558693.71E 1.443 -9.46 MWD+IIFR+MS+SAG 654.89 8.840 243.980 544.05 653.05 16.29 S 32.09 W 5945636.43 N 558680.05E 2.020 -16.29 751.70 14.320 247.770 638.86 747.86 24.09 S 49.87 W 5945628.49 N 558662.33E 5.712 -24.09 846.91 20.870 252.080 729.57 838.57 33.78 S 76.93 W 5945618.60 N 558635.34E 7.010 -33.78 938.45 22.410 246.520 814.66 923.66 45.75 S 108.46 W 5945606.38 N 558603.91E 2.800 -45.75 1029.04 26.970 247.850 896.95 1005.95 60.38 S 143.34 W 5945591.47 N 558569.14E 5.071 -60.38 1126.10 32.720 249.150 981.10 1090.10 78.03 S 188.28 W 5945573.47 N 558524.35E 5.961 -78.03 1219.65 37.610 248.530 1057.56 1166.56 97.49 S 238.50 W 5945553.62 N 558474.27E 5.241 -97.49 1314.11 39.570 248.510 1131.39 1240.39 119.06 S 293.33 W 5945531.62 N 558419.62E 2.075 -119.06 1409.27 47.050 250.290 1200.58 1309.58 141.94 S 354.40 W 5945508.27 N 558358.72E 7.964 -141.94 1504.72 57.310 250.380 1259.03 1368.03 167.28 S 425.31 W 5945482.38 N 558288.01E 10.749 -167.28 1599.67 60.330 249.680 1308.19 1417.19 195.03 S 501.65 W 5945454.04 N 558211.90E 3.243 -195.03 1695.03 64.370 253.930 1352.45 1461.45 221.34 S 581.87 W 5945427.10 N 558131.88E 5.790 -221.34 1789.98 66.020 253.800 1392.28 1501.28 245.29 S 664.66 W 5945402.51 N 558049.28E 1.742 -245.29 1885.98 71.010 252.520 1427.43 1536.43 271.17 S 750.13 W 5945375.96 N 557964.02E 5.344 -271.17 1985.12 71.140 253.740 1459.59 1568.59 298.39 S 839.87 W 5945348.04 N 557874.49E 1.171 -298.39 2081.29 70.200 253.500 1491.42 1600.42 323.98 S 926.93 W 5945321.77 N 557787.63E 1.005 -323.98 2176.50 73.180 253.920 1521.33 1630.33 349.33 S 1013.69 W 5945295.75 N 557701.08E 3.158 -349.33 2271.63 70.490 254.460 1550.98 1659.98 373.95 S 1100.65 W 5945270.45 N 557614.31E 2.879 -373.95 2367.17 72.870 254.610 1581.01 1690.01 398.14 S 1188.05 W 5945245.58 N 557527.10E 2.496 -398.14 2461.13 71.650 256.090 1609.64 1718.64 420.77 S 1274.63 W 5945222.27 N 557440.70E 1.984 -420.77 2556.95 74.920 253.910 1637.20 1746.20 444.53 S 1363.25 W 5945197.82 N 557352.26E 4.049 -444.53 2652.44 76.430 252.620 1660.83 1769.83 471.18 S 1451.85 W 5945170.49 N 557263.88E 2.053 -471.18 2747.60 74.370 250.990 1684.81 1793.81 499.92 S 1539.33 W 5945141.06 N 557176.63E 2.726 -499.92 2843.66 70.970 250.890 1713.42 1822.42 529.86 S 1625.99 W 5945110.44 N 557090.20E 3.541 -529.86 2937.63 71.220 252.070 1743.87 1852.87 558.10 S 1710.28 W 5945081.55 N 557006.13E 1.217 -558.10 3031.55 71.820 253.010 1773.64 1882.64 584.83 S 1795.25 W 5945054.16 N 556921.37E 1.144 -584.83 3127.90 70.040 253.220 1805.12 1914.12 611.27 S 1882.39 W 5945027.04 N 556834.45E 1.859 -611.27 3222.38 68.690 253.660 1838.41 1947.41 636.48 S 1967.14 W 5945001.18 N 556749.90E 1.494 -636.48 4 October, 2005 - 15:47 Page 2 of 6 DnllQuest 3.03.06.008 Ha/liburton Sperry-Sun Survey Report for Kuparuk 1J Pad - 1J--168 Your Ref,•500292326000 Job No. AK ZZ-0003877631, Surveyed: 30 August, 2005 Western North Slope Measured True Sub-Sea Depth Incl. Azim. Depth (ft) (ft) 3316.82 69.990 255.660 1871.74 3413.18 70.290 255.500 1904.47 3507.41 67.060 256.270 1938.74 3603.48 68.090 255.170 1975.38 3743.53 71.650 255.820 2023.58 3837.03 3931.36 4024.81 4118.54 4211.09 69.530 68.080 66.280 67.970 69.400 255.210 254.680 255.730 256.330 255.810 2054.65 2088.75 2124.99 2161.43 2195.07 Vertical Depth (ft) 1980.74 2013.47 2047.74 2084.38 2132.58 2163.65 2197.75 2233.99 2270.43 2304.07 Local Coordinates Northings Eastings (ft) (ft) 659.84 S 2052.35 W 682.41 S 2140.12 W 703.82 S 2225.24 W 725.73 S 2311.29 W 758.65 S 2438.58 W Global Coordinates Dogleg Northings Eastings Rate (ft) (ft) (°/100ft) 5944977.14 N 556664.87E 2.413 5944953.89 N 556577.27E 0.348 5944931.82 N 556492.33E 3.511 5944909.24 N 556406.44E 1.507 5944875.33 N 556279.42E 2.579 ConocoPhillips Vertical Section Comment -659.84 X82.41 -703.82 -725.73 -758.65 780.71 S 2523.96 W 5944852.61 N 556194.22E 2.349 -780.71 803.55 S 2608.88 W 5944829.11 N 556109.47E 1.624 -803.55 825.55 S 2692.16 W 5944806.46 N 556026.37E 2.187 -825.55 846.39 S 2775.96 W 5944784.96 N 555942.73E 1.897 -846.39 867.15 S 2859.64 W 5944763.55 N 555859.22E 1.631 -867.15 4304.38 68.360 257.050 2228.68 2337.68 887.57 S 2944.23 W 5944742.47 N 555774.79E 1.667 -887.57 4397.74 67.900 259.340 2263.46 2372.46 905.30 S 3029.03 W 5944724.08 N 555690.13E 2.329 -905.30 4491.75 65.460 261.150 2300.68 2409.68 919.93 S 3114.10 W 5944708.78 N 555605.18E 3.140 -919.93 4585.61 66.290 264.280 2339.05 2448.05 930.79 S 3199.06 W 5944697.27 N 555520.31E 3.169 -930.79 4678.63 67.240 267.200 2375.75 2484.75 937.13 S 3284.28 W 5944690.26 N 555435.13E 3.060 -937.13 4769.95 66.950 270.930 2411.31 2520.31 938.50 S 3368.37 W 5944688.23 N 555351.06E 3.776 -938.50 4864.63 66.810 273.470 2448.49 2557.49 935.16 S 3455.37 W 5944690.90 N 555264.03E 2.472 -935.16 4958.27 65.530 277.280 2486.33 2595.33 927.15 S 3540.63 W 5944698.24 N 555178.71E 3.965 -927.15 5051.69 67.030 280.930 2523.92 2632.92 913.61 S 3625.06 W 5944711.13 N 555094.18E 3.921 -913.61 5145.15 68.600 284.290 2559.22 2668.22 894.70 S 3709.49 W 5944729.37 N 555009.61E 3.729 -894.70 5238.18 .67.420 287.520 2594.06 2703.06 871.08 S 3792.44 W 5944752.35 N 554926.48E 3.460 -871.08 5332.66 69.560 294.730 2628.74 2737.74 839.39 S 3874.34 W 5944783.40 N 554844.33E 7.451 -839.39 5426.83 71.700 303.570 2660.03 2769.03 796.13 S 3951.81 W 5944826.05 N 554766.53E 9.141 -796.13 5520.26 70.310 310.210 2690.47 2799.47 743.16 S 4022.43 W 5944878.47 N 554695.50E 6.882 -743.16 5611.80 70.750 313.830 2720.99 2829.99 685.39 S 4086.53 W 5944935.74 N 554630.95E 3.759 -685.39 5705.96 68.810 312.180 2753.53 2862.53 625.13 S 4151.14 W 5944995.49 N 554565.88E 2.636 -625.13 5798.94 66.390 313.910 2788.96 2897.96 566.47 S 4213.96 W 5945053.66 N 554502.60E 3.120 -566.47 5891.97 66.930 312.010 2825.82 2934.82 508.26 S 4276.47 W 5945111.38 N 554439.63E 1.963 -508.26 5986.37 68.920 317.550 2861.32 2970.32 446.65 S 4338.51 W 5945172.50 N 554377.12E 5.832 -446.65 6079.50 68.460 316.870 2895.17 3004.17 382.98 S 4397.45 W 5945235.71 N 554317.68E 0.841 -382.98 6174.39 67.080 315.230 2931.07 3040.07 319.75 S 4458.40 W 5945298.47 N 554256.24E 2.162 -319.75 6262.70 70.840 318.040 2962.77 3071.77 259.83 S 4514.96 W 5945357.95 N 554199.22E 5.191 -259.83 6356.18 71.330 324.690 2993.11 3102.11 190.79 S 4570.13 W 5945426.55 N 554143.51E 6.750 -190.79 6450.71 74.750 331.610 3020.71 3129.71 114.03 S 4617.76 W 5945502.94 N 554095.28E 7.880 -114.03 6542.49 75.400 336.680 3044.36 3153.36 34.25 S 4656.41 W 5945582.42 N 554056.01E 5.384 -34.25 • 4 October, 2005 -15:47 Page 3 of 6 DrillQuest 3.03.06.008 Halliburton Sperry-Sun Survey Report for Kuparuk 1 J Pad -1 J--168 Your Ref.• 500292326000 Job No. AK-ZZ-0003877631, Surveyed: 30 August, 2005 ConocoPhillips Wesfern North Slope Measured True Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment 6635.77 75.500 341.940 3067.81 3176.81 50.19 N 4688.30 W 5945666.60 N 554023.46E 5.459 50.19 6731.85 75.480 347.550 3091.90 3200.90 139.88 N 4712.76 W 5945756.10 N 553998.30E 5.653 139.88 6825.36 74.650 347.530 3116.00 3225.00 228.11 N 4732.26 W 5945844.17 N 553978.12E 0.888 228.11 6919.21 75.990 351.460 3139.79 3248.79 317.35 N 4748.79 W 5945933.28 N 553960.89E 4.295 317.35 7011.28 78.030 353.370 3160.49 3269.49 406.27 N 4760.63 W 5946022.11 N 553948.36E 2.999 406.27 7107.37 80.140 353.920 3178.68 3287.68 500.04 N 4771.07 W 5946115.79 N 553937.19E 2.267 500.04 • 7199.94 80.160 356.350 3194.52 3303.52 590.91 N 4778.80 W 5946206.60 N 553928.74E 2.586 590.91 7294.87 80.210 356.980 3210.70 3319.70 684.29 N 4784.25 W 5946299.93 N 553922.57E 0.656 684.29 7387.22 80.770 356.850 3225.96 3334.96 775.24 N 4789.15 W 5946390.84 N 553916.96E 0.622 775.24 7479.65 81.070 356.410 3240.55 3349.55 866.35 N 4794.51 W 5946481.91 N 553910.89E 0.571 866.35 7574.75 80.270 357.910 3255.97 3364.97 960.07 N 4799.16 W 5946575.59 N 553905.51E 1.769 960.07 7666.66 80.030 358.030 3271.69 3380.69 1050.57 N 4802.37 W 5946666.07 N 553901.59E 0.291 1050.57 7760.91 79.990 357.570 3288.04 3397.04 1143.32 N 4805.94 W 5946758.79 N 553897.31E 0.483 1143.32 7854.28 80.900 357.590 3303.54 3412.54 1235.32 N 4809.82 W 5946850.75 N 553892.70E 0.975 1235.32 7940.55 80.410 1.020 3317.55 3426.55 1320.42 N 4810.86 W 5946935.84 N 553891.00E 3.964 1320.42 8040.30 81.280 0.370 3333.42 3442.42 1418.89 N 4809.66 W 5947034.32 N 553891.43E 1.084 1418.89 8134.02 81.650 2.420 3347.33 3456.33 1511.54 N 4807.41 W 5947126.98 N 553892.96E 2.199 1511.54 8189.92 84.560 3.690 3354.04 3463.04 1566.95 N 4804.45 W 5947182.41 N 553895.49E 5.673 1566.95 8272.94 85.890 4.960 3360.95 3469.95 1649.44 N 4798.21 W 5947264.95 N 553901.09E 2.211 1649.44 8368.51 88.550 9.390 3365.59 3474.59 1744.12 N 4786.28 W 5947359.72 N 553912.27E 5.402 1744.12 8465.72 88.660 10.260 3367.96 3476.96 1839.87 N 4769.70 W 5947455.60 N 553928.11E 0.902 1839.87 8562.61 87.980 6.830 3370.80 3479.80 1935.63 N 4755.31 W 5947551.47 N 553941.75E 3.607 1935.63 8658.56 90.280 8.240 3372.26 3481.26 2030.73 N 4742.73 W 5947646.66 N 553953.59E 2.812 2030.73 • 8755.27 87.850 5.170 3373.83 3482.83 2126.75 N 4731.44 W 5947742.77 N 553964.13E 4.048 2126.75 8851.23 85.990 358.980 3379.00 3488.00 2222.46 N 4727.97 W 5947838.50 N 553966.85E 6.726 2222.46 8948.24 87.130 357.820 3384.82 3493.82 2319.25 N 4730.68 W 5947935.27 N 553963.39E 1.675 2319.25 9045.03 89.040 0.160 3388.05 3497.05 2415.96 N 4732.38 W 5948031.96 N 553960.94E 3.120 2415.96 9143.11 88.720 2.450 3389.97 3498.97 2513.99 N 4730.15 W 5948130.00 N 553962.40E 2.357 2513.99 9239.69 87.850 3.000 3392.86 3501.86 2610.42 N 4725.56 W 5948226.46 N 553966.24E 1.066 2610.42 9334.60 89.720 3.620 3394.87 3503.87 2705.14 N 4720.08 W 5948321.23 N 553970.98E 2.076 2705.14 9432.97 88.220 3.150 3396.64 3505.64 2803.32 N 4714.27 W 5948419.45 N 553976.02E 1.598 2803.32 9529.68 87.240 4.910 3400.47 3509.47 2899.71 N 4707.48 W 5948515.89 N 553982.06E 2.082 2899.71 9626.59 86.610 1.110 3405.67 3514.67 2996.33 N 4702.40 W 5948612.55 N 553986.39E 3.969 2996.33 9723.20 85.490 4.730 3412.33 3521.33 3092.57 N 4697.49 W 5948708.82 N 553990.55E 3.914 3092.57 9819.80 84.630 5.860 3420.65 3529.65 3188.40 N 4688.61 W 5948804.71 N 553998.68E 1.467 3188.40 4 October, 2005 - 15:47 Page 4 of 6 DrillQuest 3.03.06.008 Halliburton Sperry-Sun Survey Report for Kuparuk 1 J Pad -1J--168 Your Ref: 500292326000 Job No. AK ZZ-0003877631, Surveyed: 30 August, 2005 ConocoPhillips Western North Slope Measured True Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (°/100ft) 9928.50 83.710 5.980 3431.69 3540.69 3295.96 N 4677.46 W 5948912.36 N 554008.99E 0.853 3295.96 10013.18 85.270 8.290 3439.82 3548.82 3379.59 N 4666.99 W 5948996.06 N 554018.81E 3.281 3379.59 10111.56 87.500 7.030 3446.02 3555.02 3476.89 N 4653.90 W 5949093.46 N 554031.14E 2.602 3476.89 10206.57 85.930 4.410 3451.47 3560.47 3571.26 N 4644.45 W 5949187.90 N 554039.86E 3.211 3571.26 10304.97 84.950 6.340 3459.29 3568.29 3668.91 N 4635.26 W 5949285.62 N 554048.28E 2.194 3668.91 10400.35 86.070 3.910 3466.76 3575.76 3763.61 N 4626.77 W 5949380.39 N 554056.03E 2.798 3763.61 • 10497.15 87.810 359.330 3471.93 3580.93 386020 N 4624.04 W 5949477.00 N 554058.01E 5.055 3860.20 10593.15 89.910 7.640 3473.84 3582.84 3955.91 N 4618.21 W 5949572.76 N 554063.09E 8.926 3955.91 10689.49 89.960 6.360 3473.95 3582.95 4051.53 N 4606.47 W 5949668.46 N 554074.09E 1.330 4051.53 10786.10 89.960 2.290 3474.02 3583.02 4147.85 N 4599.19 W 5949764.83 N 554080.62E 4.213 4147.85 10882.98 91.080 0.720 3473.14 3582.14 4244.69 N 4596.64 W 5949861.69 N 554082.41E 1.991 4244.69 10979.95 89.450 351.160 3472.69 3581.69 4341.30 N 4603.50 W 5949958.24 N 554074.80E 10.001 4341.30 11075.79 91.020 350.480 3472.30 3581.30 4435.90 N 4618.79 W 5950052.73 N 554058,77E 1.785 4435.90 11172.17 93.120 353.990 3468.81 3577.81 4531.32 N 4631.80 W 5950148.04 N 554045.02E 4.242 4531.32 11268.05 92.610 355.410 3464.02 3573.02 4626.67 N 4640.65 W 5950243.31 N 554035.43E 1.572 4626.67 11365.63 92.550 357.220 3459.63 3568.63 4723.94 N 4646.91 W 5950340.54 N 554028.41E 1.854 4723.94 11462.05 91.800 0.540 3455.97 3564.97 4820.26 N 4648.79 W 5950436.84 N 554025.77E 3.528 4820.26 11559.08 90.630 0.530 3453.91 3562.91 4917.26 N 4647.89 W 5950533.84 N 554025.92E 1.206 4917.26 11654.79 90.510 3.890 3452.96 3561.96 5012.88 N 4644.20 W 5950629.49 N 554028.87E 3.513 5012.88 11752.96 88.460 3.600 3453.84 3562.84 5110.83 N 4637.79 W 5950727.49 N 554034.51E 2.109 5110.83 11843.70 88.600 3.160 3456.17 3565.17 5201.39 N 4632.44 W 5950818.08 N 554039.16E 0.509 5201.39 11933.08 85.750 359.580 3460.58 3569.58 5290.61 N 4630.30 W 5950907.31 N 554040.60E 5.115 5290.61 12025.20 87.810 358.570 3465.75 3574.75 5382.56 N 4631.79 W 5950999.26 N 554038.40E 2.490 5382.56 • 12114.52 87.300 356.680 3469.56 3578.56 5471.72 N 4635.48 W 5951088.38 N 554034.00E 2.190 5471.72 12205.16 87.360 0.090 3473.78 3582.78 5562.21 N 4638.04 W 5951178.85 N 554030.75E 3.759 5562.21 12296.47 87.360 358.560 3477.99 3586.99 5653.42 N 4639.11 W 5951270.04 N 554028.96E 1.674 5653.42 12385.85 87.430 357.620 3482.05 3591.05 5742.65 N 4642.09 W 5951359.26 N 554025.29E 1.054 5742.65 12474.83 86.500 357.610 3486.76 3595.76 5831.43 N 4645.78 W 5951448.00 N 554020.90E 1.045 5831.43 12567.60 84.870 358.840 3493.74 3602.74 5923.89 N 4648.65 W 5951540.43 N 554017.31E 2.199 5923.89 12656.39 83.280 0.630 3502.91 3611.91 6012.20 N 4649.06 W 5951628.74 N 554016.21E 2.688 6012.20 12747.25 81.700 2.200 3514.79 3623.79 6102.25 N 4646.84 W 5951718.80 N 554017.73E 2.441 6102.25 12838.56 84.300 1.660 3525.91 3634.91 6192.82 N 4643.79 W 5951809.39 N 554020.08E 2.907 6192.82 12928.87 82.970 1.340 3535.92 3644.92 6282.54 N 4641.44 W 5951899.12 N 554021.73E 1.514 6282.54 12958.31 81.490 1.940 3539.90 3648.90 6311.69 N 4640.60 W 5951928.29 N 554022.33E 5.418 6311.69 12995.00 81.490 1.940 3545.33 3654.33 6347.96 N 4639.38 W - 5951964.56 N 554023.28E 0.000 6347.96 Projected Survey All data is in Feet (US Survey) unless otherwise stated. Directions and coordinates are relative to True North. 4 October, 2005 -15:47 Page 5 of 6 DrillQuest 3.03.06.008 Halliburton Sperry-Sun Survey Report for Kuparuk 1J Pad -1.ti168 Your Ref 500292326000 Job No. AK ZZ-0003877631, Surveyed: 30 Augusts 2005 Western North Slope Vertical depths are relative to Well. Northings and Eastings are relative to Well. Global Northings and Eastings are relative to NAD27 Alaska State Planes, Zone 4. The Dogleg Severity is in Degrees per 100 feet (US Survey). Vertical Section is from Well and calculated along an Azimuth of 0.000° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 12995.OOft., The Bottom Hole Displacement is 7862.59ft., in the Direction of 323.839° (True). Comments Measured Station Coordinates Depth TVD Northings Eastings Comment (ft) (ft) (ft) (ft) 12995.00 3654.33 6347.96 N 4639.38 W Projected Survey Survey tool program for 1J--168 From Measured Vertical Depth Depth (ft) (ft) 0.00 0.00 540.30 539.50 To Measured Vertical Depth Depth (ft) (ft) 540.30 539.50 12995.00 3654.33 Survey Tool Description CB-SS-Gyro MWD+I IFR+MS+SAG ConocoPhillips • 4 October, 2005 -15:47 Page 6 of 6 DrillQuest 3.03.06,008 ~~ ~ ~~ , ~ .~ ~ ~'~ ~ ~ :, FRANK H. MURKOWSKI, GOVERNOR ~ 4 s ~~~~ ~~~~++ ~t~~ ~ ~~a di/~.-7~ OIL L>•is1J. ~ 1~ 333 W. T" AVENUE, SUITE 100 C011TSERQA'1`IO1Q CO1~II1'IISSI011T ~~ 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 1J-168 ConocoPhillips Alaska, Inc. Permit No: 205-060 Surface Location: 1841' FSL, 2499' FEL, SEC. 35, T11N, R10E, UM Bottomhole Location: 2371' FNL, 1877' FEL, SEC. 27, T11N, R10E, UM Dear Mr. Thomas: Enclosed is the approved application for permit to drill the above referenced development well. This permit to drill does not exempt you from obtaining additional permits or approvals required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Ple e p ovide at least twenty-four (24) hours notice for a representative of the Commission witnes any required test. Contact the Commission's petroleum field inspector at (907659 60~a r). N DATED this~day of April, 2005 cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. ConocoPhillips Alaska Post OfFce Box 100360 Anchorage, Alaska 99510-0360 Randy Thomas Phone (907) 265-6830 Email: Randy.L.Thomas@conocophillips.com April 7, 2005 Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 ~ ~i I ~.r„ ~ V Lwar ~~f~ "' t7 ~~Q~ Alaska Oil &'Ges Cons. Comrrus>~ior- Anchorage Re: Applications for Permit to Drill, West Sak Producer, 1J-168, 1J-168L1 and 1J-168L2 Dear Commissioners: ConocoPhillips Alaska, Inc. hereby applies for Permits to Drill for an onshore production well, a multilateral horizontal well in the West Sak "A", "B"and "D" sands. The main bore of the well. will be designated 1J-168 ("A" Sand), and the lateral bore of the well will be designated iJ-168L1 ("B" Sand) and iJ-168L2("D" Sand). Please find attached for the review of the Commission a Form 10-401 and the information required by 20 ACC 25.005 for each of these well bores. The expected spud date of 1J-168 is 6/5/2005. If you have any questions or require any further information, contact Shane Cloninger at 265-6829. Sincerely, .t-s Randy Thomas Greater Kuparuk Area Drilling Team Leader _, ~~~ i ~.. STATE OF ALASKA ~ ~;~ ~(~ ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL ~~'~ " ~~~~ 20 AAC 25.005 ni.,..L~ rlil 12. f:~e t^.nnx_ Comnitsui~n; 1 a. Type of Work: Drill / Redrill Re-entry ^ 1 b. Current Well Class: Exploratory Development Oil / iple Zone ^ AnCh~lr Stratigraphic Test ^ Service ^ Development Gas ^ Ingle Zone Q 2. Operator Name: ConocoPhillipsAlaska, Inc. 5. Bond: / Blanket Single Well Bond No. 59-52-180 11. Well Name and Number: 1J-168 3. Address: P.O. Box 100360 Anchorage, AK 99510-0360 6. Proposed Depth: MD: 12975' ' ND: 3658' ~ 12. Field/Pool(s): Kuparuk River Field 4a. Location of Well (Governmental Section): Surface: 1841' FSL, 2499' FEL, Sec. 35, T11 N, R10E, UM s 7. Property Designation: ADL 25661 & 25660 Y West Sak Oil Pool Top of Productive Horizon: 1843' FNL, 2068' FEL, Sec. 34, T11 N, R10E, UM 8. Land Use Permit: ALK 471 & 470 13. Approximate Spud Date: 6/5/2005 Total Depth: 2371' FNL, 1877 FEL, Sec. 27, T11 N, R1 OE, UM ~ 9. Acres in Property: 2560 14. Distance to ~ ~' ~/ r3• Nearest Property: at~face;~frS4T 4b. Location of Well (State Base Plane Coordinates): Surface: x- 558712 ~ y- 5945653 ~ Zone- 4 10. KB Elevation (Height above GL): 28' RKB ~ feet 15. Distance to Nearest ~ ~.~ Well within Pool: ~,~ Ze-~7" 5"~j 16. Deviated wells: Kickoff depth: 300 ~ ft. MaximumHOleAngle: 90° deg 17. Maximum Anticipated Pressures in psig (see 20 AAC 25.035) Downhole:1481 psig Surface: 1134 psig ~'!3 18. Casing Program S ecific tion Setting Depth Quantity of Cement Size p a s Top Bottom c. f. or sacks Hole Casing Weight Grade Coupling Length MD ND MD ND (including stage data) 40" 20" 94# K-55 Welded 80' 28' 28' 108' 108' 260 cf ArcticCRETE 13.5" 10.75" 45.5# L-80 BTC 3527' 28' 28' 3555' 2118' 640 sx ASLite, 180 sx DeepCRETE 9-718" 7-518" 29.7# L-80 BTCM 8181' 28' 28' 8209' ' 3481' _ 480 sx DeepCRETE 6.75" 4.5" 12.6# L-80 BTCM 4766' 8209' 3481' 12975' ' 3658' ~ slotted liner 19 PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re-Entry Operations) Total Depth MD (ft): 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 Perforation Depth MD (ft): Perforation Depth ND (ft): 20. Attachments: Filing Fee a BOP Sketch Drilling Program / Time v. Depth Plot Shallow Hazard Analysis Property Plat ^ Diverter Sketch ^ Seabed Report ^ Drilling Fluid Program ^/ 20 AAC 25.050 requirements Q 21. Verbal Approval: Commission Representative: Date: 22. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Shane Cloningef @ 265-6829 Printed Name Randy Thomas Title Greater Kuparuk Area Drilling Team Leader Signature ~ ~~ Phone Z(S'~6 S 3~ Date ~~ t~ ~oS~ P h I D Commission Use Only Permit to Drill Number: U~ ~ ~- (~~jZ,j API Number: 50- ~' L~-~,~ ~ ~ ^•~ Permit Approval Date: ~ ~ ~ .~~ See cover letter for other requirements Conditions of approval S ple required Yes ^ No ~ Mud log required Yes ^ No n sulfid~te meaTS~ures Yes ^ No ICI Directional survey required Yes ~ No ^ Other: 3fl ` vr-~. v~ C ~.Sk , y°~ APPROVED BY ~~ Approved by: THE COMMISSION Date: Form 10-401 Re ' ed 06!2004 ^ ~ ~ ~ ~ ~ ~ ~ ~ ~-~ ~ Submit in Duplicate ~S Application for Permit to Drill, Well 1 J-168 Revision No.O March 31, 2005 Permit- West Sak #1J-168 Producer ("A" Sand) •,,,d a~ Application for Permit to Drill Document I~I~xWell Mpxitnixp 1M~11 Vplue Table of Contents 1. Well Name ................................................................................................................. 2 Requirements of 20 AAC 25.005 (fl ....................................................................................................... 2 2. Location Summary ................................................................................................... 2 Requirements of 20 AAC 25.005(c)(2) ................................................................................................... 2 Requirements of 20 AAC 25.050(b) ....................................................................................................... 2 3. Blowout Prevention Equipment Information ................................... 3 ...................... Requirements of 20 AAC 25 005(c)(3) . .................................................................................................. . 3 4. Drilling Hazards Information ............................................. ... 3 .. ................................. Requirements of 20 AAC 25 005 (c)(4) . .................................................................................................. 3 5. Procedure for Conducting Formation Integrity Tests ........................................... 3 Requirements of 20 AAC 25.005 (c)(5) .................................................................................................. 3 6. Casing and Cementing Program ................................... 4 ......................................... Requirements of 20 AAC 25 005(c)(6) . ................................................................................................... 4 7. Diverter System Information ............................................. .. 4 .. .................................. Requirements of 20 AAC 25 005 7 . (c)( ) ................................................................................................... 4 8. Drilling Fluid Program ............................................................................................. 5 Requirements of 20 AAC 25.005(c)(8) ................................................................................................... 5 Lateral Mud Program (MI FloPro NT) ..................................................................................................... 5 9. Abnormally Pressured Formation Information ..................................................... 5 Requirements of 20 AAC 25.005 (c)(9) .................................................................................................. 5 10. Seismic Analysis ..................................................................................................... 5 Requirements of 20 AAC 25.005 (c)(10) ................................................................................................ 5 11. Seabed Condition Analysis ..................................................................................... 5 Requirements of 20 AAC 25.005 (c)(11) ................................................................................................ 5 12. Evidence of Bonding ............................................................................................... 6 Requirements of 20 AAC 25.005 (c)(12) ................................................................................................ 6 ORIGINAL 1J-168 Producer Permit Page 1 of 8 Printed: March 31, 2005 ~" Application for Permit to Drill, Well 1 J-168 Revision No.O March 31, 2005 13. Proposed Drilling Program ..................................................................................... 6 Requirements of 20 AAC 25.005 (c)(13) ................................................................................................ 6 14. Discussion of Mud and Cuttings Disposal and Annular Disposal ....................... 7 Requirements of 20 AAC 25.005 (c)(14) ................................................................................................ 7 15. Attachments Attachment 1 Directional Plan Attachment 2 Drilling Hazards Summary Attachment 3 Cementing Data Attachment 4 Well Schematic 1. Well Name Requirements of 20 AAC 25.005 (fJ Each wel/ must be identified by a unique name designated by the operator and a unique API number assigned by the commission under ZO AAC Z5.040(b). For a wel/ with mu/tip/e wel/ branches, each branch must Simi/arty be identified by a unique name and API number by adding a suffix to the name designated for the welf by the operator and to the number assigned to the well by the commission. The well for which this Application is submitted will be designated as 1J-168. 2. Location Summary Requirements of 20 AAC 25.005(c)(2) An application for a Permit to Dril/ must be accompanied by each of the following items, except for an item already on file with the commission and identified in the app/ication: (Z)ap/at identifying the property and the property's owners and showing (A)the coordinates of the proposed location of the well at the surface, at the top of each objective formation, and at total depth, referenced to govemmenta/section lines (B) the coordinates of the proposed location of the we/l at the surface, referenced to the state plane coordinate system for this state as maintained by the National Geodetic Survey in the National Oceanic and Atmospheric Administration; (C) the proposed depth of the we/l at the top of each objective formation and at total depth; Location at Surface FSL 1841' ,FEL 2499', Sec.35, T11N/R10E ASPZone 4 NAD 17 Coordinates RKB Elevation 109' AMSL Northings: 5945653 Eastings: 558712 Pad Elevation 81' AMSL Location at Top of Productive Interval West Sak "A" Sand FNL 1843', FEL 2068', Sec. 34, R11N/R10E ASP Zone 4 NAD 17 Coord/Hates Measured De th, RKB.' 8209' Northings: 5947213 Eastings: 553849 Total 1/ertica/ De th, RKB; 3481' Total l/ertical De th, SS.' 3372' Location at Total Depth FNL 2371', FEL 1877', Sec. 27, T11 N/R10E ASP Zone 4 NAD 17 Coordinates Measured De th RKB: 12975' Northings: 5951965 Eastings; 553998 Total I/ertica/ De th, RKB: 3658' Total l/ertica/ De th, SS.' 3549' and (D) other information required by ZO AAC25.050(b); Requirements of 20 AAC 25.050(b) If a we// is to be intentional/y deviated, the app/ication for a Permit to Dri/! (Form 10-401) must 1 J-168 Producer Permit Page 2 of 8 Printed: March 31, 2005 ORIGINAL Application for Permit to Drill, Well 1 J-168 Revision No.0 March 31, 2005 (1) include a p/at, drawn to a suitab/e scale, showing the path of the proposed welJbore, inc/uding all adjacent welJbores within 200 feet of any portion of the proposed wel% Please see Attachment 1: Directional Plan and (2) for al/ we/ls within 200 feet of the proposed wellbore (A) list the names of the operators of those we/ls, to the extent that those names are known or discoverab/e in public records, and show that each named operator has been furnished a copy of the application by certified mail; or (B) state that the applicant is the only affected owner. The Applicant is the only affected owner. 3. Blowout Prevention Equipment Information Requirements of 20 AAC 25.005(c)(3) An app/icarion for a Permit to Drill must be accompanied by each of the fo/%wing items, except far 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 (HOPE) as required by 20 AAC 25.035, 20 AAC 25.036, or 20 AAC 25.037, as applicable; An API 13-5/8" x 5,000 psi BOP stack (RSRRA) will be utilized to drill and complete well 1J-168. Due to the formation pressures being far less then the rating of the HOPE, CPAI would like to request that the stack be operated under the 3 0 i BOP uidelines thereby allowing the use of one ram cavity for casing rams an negating an additional BOP test once the intermediate casing has been run. Please see information on Doyon 141 blowout prevention equipment placed on file with the Commission. 4. Drilling Hazards Information Requirements of 20 AAC 25.005 (c)(4) An app/ication for a Permit to Drill must be accompanied by each of the fol%wing items, except for an item already on file with the commission and identified in the application: (4) information on drilling hazards, including (A) the maximum downho% pressure that maybe encountered, criteria used to determine it, and maximum potentia/surface pressure based on a methane gradient; The expected reservoir pressures in the West Sak sands in the iJ-168 area vary from 0.44 to 0.47 psi/ft, or 8.6 to 9.0 ppg EMW (equivalent mud weight). These pressures are predicted based on actual bottom ~ hole pressure data from the nearby West Sak wells. The maximum potential surface pressure (MPSP) based on the above maximum pressure gradient, a methane gradient (0.11) and the deepest planned vertical depth of the West Sak A sand formation is 1134 psi, calculated thusly: MPSP =(3150 ft)(0.47 - 0.11 psi/ft) =1134 psi (B) data on potentia/gas zones; The well bore is not expected to penetrate any gas zones. and (C) data concerning potential causes of ho% prob/ems such as abnormally geo-pressured strata, lost circu/ation zones, and zones that have a propensity for differential sticking; Please see Attachment 2: Drilling Hazards Summary. 5. Procedure for Conducting Formation Integrity Tests Requirements of 20 AAC 25.005 (c)(5) An application for a Permit to Drill must be accompanied by each of the fo/%wing items, except for an item a/ready on file with the commission and identified in the application: (S) a description of the procedure for conducting formation integrity tests, as required under 20 AAC 25.030(1); 1 J-168 Producer Permit Page 3 of 8 Printed: March 31, 2005 ~rUI~AL • Application for Permit to Drill, Well 1J-168 Revision No.O March 31, 2005 The parent wellbore, iJ-168, will be completed with 7 5/8" intermediate casing landed in the West Sak A- Sand. The casing shoe will be drilled out and a formation integrity test will be performed in accordance with the °Formation Integrity Test Procedure" that ConocoPhillips Alaska placed on file with the Commission. 6. Casing and Cementing Program Requirements of 20 AAC 25.005(c)(6) An app/ication for a Permit to Drill must be accompanied by each of the fol%wing items, except for an item a/ready on fi/e with the commission and identified in the application: (6) a comp/ete proposed casing and cementing program as required by 20 AAC 25.030, and a description of any slotted /iner, pre- perforated liner, or screen to be instal/ed; Casing and Cementing Program See also Attachment 3 APD for iJ-168: Cement Summa Hole Top Btm Csg/Tbg Size Weight Length MD/TVD MD?VD OD (in) (in /b!ft Grade Connection ft ft) ft} Cement Pro ram 20" 40" 94 K55 Welded 80' 28' / 28' 108' / 108' Cemented to surface with 260 cf ArcticCRETE 10 3/4" 13 1/2" 45.5# L-80 BTC 3527' 28'/28' 3555'/2118' Cemented to Surface with 640sx ASLite Lead, 180sx Dee CRETE Tail 7 5/8" 9 7/8" 29.7# L-80 BTCM 8181' 28'/28' 8209'/3481' Cement Top planned @ 4778' MD/' TVD. Cemented w/ 480 sx ee 4 1/2" 6 3/4" °A" 12.6# L-80 BTCM 4766' 8209'/3481' 12975'/3658' Slotted - no cement slotted Lateral L-80 -M 57 ` 3310` ...1295,2'/351-2' Slotted - noseme+~t slotted Lateral 1 J-168 L1 4 1/2" 6 3/4""D" 12.6# L-80 BTCM 6107' 6835'/3229' 12942'/3453' Slotted - no cement slotted Lateral 1 J-168 L2 4 1/2 NA 12.6# L-80 IBTM 6807' 28'/28' 6835'/3300' Production Tubing tubin 7. Diverter System Information Requirements of 20 AAC 25.005(c)(7) An app/ication for a Permit to Dri/l must be accompanied by each of the fol%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, un/ess 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-168. Please see diagrams of the Doyon 141 diverter system on file with the Commission. ORIGINAL 1J-168 Producer Permit Page 4 of 8 Printed: March 31, 2005 • Application for Permit to Drill, Well 1 J-168 Revision No.O March 31, 2005 8. Drilling Fluid Program Requirements of 20 AAC 25.005(c)(8) An application for a Permit to Drill must be accompanied by each of the fol%wing items, except for an item already on fi/e with the commission and identified /n the application: (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 mud having the following properties over the listed intervals: Pro erties Surface Intermediate Production Mud T e Extended Bentonite Extended Bentonite MI VersaPro Mineral Oil Base Densi 8.6-9.6 9.0 9.0 Funnel Viscosity (seconds 150-300 45-60 60 Yield Point (cP) 30-70 26-35 18-28 Electric Stability NA NA 650-900 Chlorides m /I) <500 <500 NA H 8.5-9.0 9.0-9.5 NA APl filtrate cc / 30 min 6-8 4-6 <4 't'rHTHP filtrate (cc / 30 min <10 <10 <10 Drilling fluid practices will be in accordance with regulations stated in 20 AAC 25.033. Please see information on file with the Commission for diagrams and descriptions of the fluid system of Doyon 141. 9. Abnormally Pressured Formation Information Requirements of 20 AAC 25.005 (c)(9) An app/ication for a Permit to Dri//must be accompanied by each of the fo/lowing items, except for an item already on file with the commission and identified in the application: (9) for an exp/oratory or stratigraphic test we/% a tabulation setting out the depths of predicted abnormally geo-pressured strata as required by 20 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 fol%wing items, except for an item a/ready on fi/e with the commission and identified in the application: (10) for an exploratory or stratigraphic test well, a seismic refraction or reflection analysis as required by 20 AAC25.061(a); Not applicable: Application is not for an exploratory or stratigraphic test well. 11. Seabed Condition Analysis Requirements of 20 AAC 25.005 (c)(11) An app/ication for a Permit to Drill must be accompanied by each of the fo/%wing items, except for an item already on file with the commission and identified in the app/ication: (11) far a we// dri/led from an offshore platform, mobile bottom-founded structure, jack-up rig, or floating drilling vessel, 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 (c)(12) An app/ication for a Permit to Drill must be accompanied by each of the fol%wing items, except for an item already on fi/e with the commission and identified in the application: (12) evidence showing that the requirements of20 AAC 25.025 {Bonding}have been met; Evidence of bonding for Phillips Alaska, Inc. is on file with the Commission. ORIGINAL 1J-168 Producer Permit Page 5 of 8 Printed: Maroh 31, 2005 • Application for Permit to Drill, Well 1J-168 Revision No.O March 31, 2005 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 fol%wing items, except for an item a/ready on file with the commission and identified in the application: The proposed drilling program for iJ-168 is listed below. 1. Excavate cellar, install cellar box, set and cement 20" x 34" insulated conductor to +/-120' RKB. Install landing ring on conductor. 2. Move in /rig up Doyon 141. Install 21-1/4"Annular with 16" diverter line and function test. 3. Spud and directionally drill 13 1/2" hole to casing point at +/- 3555' MD / 2118' ND as per directional plan. Run MWD tools as required for directional monitoring. 4. Run and cement 10 3/4", 45.5#, L-80, BTC casing to surface. Displace cement with water base mud and, pressure test casing to 3000 psi for 30 minutes and record results. Perform top job if required. 5. Remove diverter system, install and test 13-5/8" x 5,000 psi BOP's and test to 5000 psi (annular preventer to 3500 psi). Notify AOGCC 24 hrs before test. 6. PU 9 7/8" bit and drilling assembly, with MWD &LWD. RIH, clean out cement to top of Float equipment. Re-test casing if cement is tagged more than 100 feet above the float collar. 7. Drill out cement and between 20' and 50' of new hole. Perform formation integrity test to leak off, recording results. 8. Directionally drill to 7 5/8" casing point at 8209' MD / 3481' TVD. 9. Run 7 5/8", 29.7# L-80, BTCM Mod casing to surface. Pump cement and displace with oil base mud. 10. Install wellhead 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" Bit and drilling assembly, with MWD, PWD, and LWD logging tools. RIH, clean out cement to /~`~~, top of float equipment. Test casing to 3000 psi for 30 minutes and record results. ~ 13. Drill out cement and between 20' and 50' of new hole. Perform formation integrity test to leak off, C~ recording results. 14. Directionally drill 6 3/4" hole to TD at +J-12975' MD / 3658' TVD'as per directional plan. 15. Back ream out of lateral to casing shoe. RIH to TD and change over to solids-free OBM. POOH. 16. If injector, RU and run the USIT log from the shoe of the 7 5/8' casing to the shoe of the 10 3/4" casing. 17. PU and run 4 i/2" slotted liner. 18. Land finer, set liner hanger POOH. ~ ~--~-"'~~~-~, Note: Remaining operations are covered under the iJ-168L1 Application for Permit to Drill, and are provided here for information only. 19. Run and set Baker WindowMaster whipstock system, at window point of 7185' MD / 3310' TVD, the top of the B sand. 20. Mill 6 3/4" window. POOH. 21. Pick up drilling assembly with LWD and MWD and PWD. RIH. 22. Drill to TD of B sand lateral at 12952` MD j 3512' TVD, as per directional plan. 23. Back ream out of lateral to casing window. RIH to TD and change over to solids-free OBM. POOH. 24. RIH with whipstock retrieval tool. Retrieve whipstock and POOH. ORIGINAL 1J-168 Producer Permit Page 6 of 8 Printed: March 31, 2005 • 25. PU and run 41/2" slotted liner. Application for Permit to Drifl, Weli 1J-168 Revision No.0 March 31, 2005 26. RIH, until liner hanger is just above window. Orient hanger to window and land hanger. 27. Release hanger running tool, POOH. 28. PU LEM, RIH and install same. 29. POOH and prepare for drilling the "B" lateral. Note: Remaining operations are covered under the 1J-168L2 Application for Permit to Drill, and are provided here for information only. 30. Run and set Baker WindowMaster whipstock system, at window point of 6835' MD/ 3229' TVD, the top of the "D" sand. 31. Mill 6 3/4" window, POOH. 32. Pick up drilling assembly with LWD, MWD, and PWD. RIH. 33. Drill to TD of "D" sand lateral at 12942' MD / 3453' TVD, as per directional plan. 34. Back ream out of lateral to casing window. RIH to TD and change over to solids-free OBM. POOH. 35. RIH with whipstock retrieval tool. Retrieve whipstock and POOH. 36. PU and run 4 1/2" slotted liner. 37. RIH, until liner hanger is just above window. Orient hanger to window and land hanger. 38. Release hanger running tool. 39. POOH and lay down drill pipe. 40. RU and run a 4 1/2" ESP completion with backup gaslift. 41. Space out tubing and land tubing in tubinghead. 42. Nipple down BOPE, nipple up tree and test, change over the hole to diesel. 43. Set BPV and RDMO Doyon 141. 44. Rig up wire line unit. Pull BPV. 45. Circulate out well with diesel through the ESP. 46. Set gas lift valves in mandrels. Operate well on gas lift until ESP facilities are ready. 47. Replace gas lift valves with blank dummy valves. 48. Place well on production with ESP. 14. Discussion of Mud and Cuttings Disposal and Annular Disposal Requirements of 20 AAC 25.005 (c)(14) An application for a Permit to Dril/ mustc be accompanied by each of the fol%wing items, except for an item a/ready on file with the commission and identified in the app/ication: (14) a general description of how the operator plans to dispose of drilling mud and cuttings and a statement of whether the operator intends to request authorization under 20 AAC 25.080 for an annular disposal operation in the we/%; Waste fluids generated during the drilling process will be disposed of by hauling the fluids to a KRU Class II disposal well. All cuttings generated will be disposed of either down a permitted annulus on iJ 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. 1J-168 Producer Permit Page 7 of 8 Printed: March 31, 2005 ORIGINAL Application for Permit to Drill, Well 1 J-168 Revision No.O March 31, 2005 15. Attachments Attachment 1 Directional Plan Attachment 2 Drilling Hazards Summary Attachment 3 Cementing Data Attachment 4 Well Schematic 1J-168 Producer Permit Page 8 of 8 Printed: March 31, 2005 ~~4AL • ConocoPhillips Alaska ConocoPhillips Alaska (Kuparuk) Kuparuk River Unit Kuparuk 1J Pad Plan 1 J-168 (L3) 1 J-168 Plan: 1 J-168 (wp08) Proposal Report 30 March, 2005 HALL.~BURTON Sperry Drilling Services ORIGINAL s ~- UKIViIVHL `~ '~.i . ___.. SHL ~ 1841tt FSL 249911 FEL -Sec 35 - T71 N - 810E -Drill 11112" Nok Continue Build ~ 4.0°I100ft to 5.0° tnc - 4671[ MD, 466ft ND ` -looo ~~~~~~~~~ KOP ~ 3008 MD, 100tt ND - Build ~ 3.00°I100fl Continue Build ~ 5.0'11008 to 15.0° Inc - 717ft MD, 712K ND A: _°.kr1 Sail ~ 89°Inc a 253°Azi :18028 MD,14908 ND -500 10 314" Csg Pt -Drill Out 9 7l8" Hok - 35558 MD, 21188 ND Begin Dir ~ 4.0°I7008, 4202ft MD, 2350([ TVD Sail ~ 70°Inc a 270°Azi : 46018 MD, 2491 k ND 0 Begin Dir @ 4.0°I100h, 47018 MD, 25258 ND Sail ~ 70'Inc a 29SAzf : 52878 MD, 2728fl ND 500 Begin Dir ~ 4.0°/1008, 53378 MD, 27458 ND 1000 Base of Permafrost rn Pum Tan Beg' p gent - 70°Inc a 320°Azi - 59248 MD, 2%98 NO T3 1500 _ _ _- _- End Pump Tangent -Build @ 4°17008, 61248 MD, 3017(1 ND K15 2000 TS + 550 Sail ~ 75°Inc a 345°Azi : 6732fl MD, 320J8 ND c w Ugnu C Begin Dir ~ 4.0°11008, 6%98 MD, 3259([ ND 82500 t -_ ---- _ -- Sail Q 80°Inc a 353•Azi : 7[ 858 MD, 13108 ND p Ugnu B `~3DD0 - - Ugnu A 1J-188 Faun Intersect N K13 1 _ 2 1J-188 tvq T1 1J-168 tv6tT 111681WIT 1J-166 tvQT 1J-168 tv4tT ~3500 - - tJ-166 teat ro DSerW Intersect C A4 1J-168 (v4) Dto BSand Intersect 4000 Begin Dir ~ 4.0°/100ft, 80508 MD, 34608 ND TD @ 12975(1 MD, 36588 ND :23718 FNL a 1877([ FEL -Sec 27-Ti i N-R10E ' A2-Sand 4500 Sail ~ 83.7°Inc a 2.9°Azi : Bf 678 MD, 34778 ND 5000 5$00 Begin Dir ~ 5.0°11008, 82298 MD, 3484ft ND Begin Dir ~ 3.0°11008, 93898 MD, 35088 ND Begin UnduWtion k A2Sand : Dir (d11.0'/1008,110768 MD,15778 ND 7 518 Csg ~ 18428 FNL 20688 FEL -Sec 34 - T11 N - 810E :82098 MD, 14818 TVD Sao ~ 89.Sfflnc a 7.05°Azi : 63728 MD, 34!928 ND Sail ~ 87.59°Inc a 2.34°Azi : 9551ft MD, 1513 ft ND 6000 FiALLiBURTON Sperry Drilling Servkes -1500 -1000 -500 0 500 1000 1500 2000 2500 3000 3500 4000 4500 5000 5500 6000 6500 7000 7500 8000 Vertical Section at 0.00° (1000 fVin) a n • ConocoPhillips Alaska Database: EDM 2003.11 Single User Db Company: ConocoPhillips Alaska (Kuparuk) Project: Kuparuk River Unit Site: Kuparuk 1J Pad Well: Plan 1J-168 (L3) Wellbore: 1J-168 Design: 1J-168 (wp08) i Halliburton Company HALLIBURTON Planning Report -Geographic Sperry Drilling Services Local Co-ordinate Reference: Well Plan 1J-168 (L3) TYD' Reference: 1J-168 (28+81) @ 109.OOft (Doyon 141 @ 28') MD References 1J-168 (28+g1) @ 109.OOft (Doyon 141 @ 28') Norfh 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 Welt Plan 1J-168 (L3) Well Position +Nl.S 0.00 ft Northing: 5,945,553.00 ft ~ Latitude: 70° 15' 43.641" N +Ei-W 0.00 ft Easting: 558,712.00 ft ~ Longitude: 149° 31' 31.336" W Position Uncertainty 0.00 ft Wellhead Elevation: ft Ground Level: 81.00 ft Wellbore 1J-168 ~ i Magnetics Model Name Sample Date Declination Dip Angle Field Strength BGGM2004 9/17/2003 25.06 80.71 57,537 I Design 1J-168 (wp08) Audit Notes: Version: Vertical Section: Phase: PLAN Depth From IND) +NI-S (ft) 1~1 2s.oo o.oo Tie On Depth: 28.00 +E/-W Direction Ift) 1°) o.oo o.oo 3/3tX2005 1:53:3TPM Page 2 of 10 COMPASS 2003.118uiid 48 ORIGINAL • ~ Hailiburton Company C Phill HALLIBURTON onoco ips Planning Report -Geographic ,ql~~ Sperry Drilling Services Databas®: EDM 2003.11 Single User Db Local Co-ordih8#e Reference: Well Plan 1J-168 (L3) Company: ConocoPhillips Alaska (Kuparuk) ND References 1J-168 (28+81) ~ 109.OOft (Doyon 141 ~ 28') Project: Kuparuk River Unit MD'Referencea 1J-168 (28+81) ~ 109.OOft (Doyon 141 ~ 28') Site: Kuparuk 1J Pad North: Reference: True WeII: Plan 1J-168 (L3) Survey Calculation Method: Minimum Curvature Wellbore: 1J-168 Design: 1J-168 (wp08) Plan Summary Measured Vertical Dogleg Build Turn Depth Inclination Azimuth Depth +w.$ +E1.yy Rate Rate Rate TFO (ttj (°) (°) (ft) (ft) (fty (°HOOft) (°l100ft) (°I100ft) (°) 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 0.00 466.67 5.00 243.00 466.46 -3.30 -6.48 3.00 3.00 0.00 243.00 716.67 15.00 243.00 712.34 -22.98 -45.11 4.00 4.00 0.00 360.00 1,801.86 69.00 253.00 1,489.90 -252.24 -704.71 5.00 4.98 0.92 11.52 4,201.86 69.00 253.00 2,349.98 -907.32 -2,847.39 0.00 0.00 0.00 0.00 4,600.54 70,00 270.00 2,490.51 -962.09 -3,215.06 4.00 0.25 4.26 89.43 4,700.54 70.00 270.00 2,524.71 -962.09 -3,309.03 0.00 0.00 0.00 0.00 5,287.29 70.00 295.00 2,728.24 -843.92 -3,842.04 4.00 0.00 4.26 94.34 5,337.29 70.00 295.00 2,745.35 -824.06 -3,884.63 0.00 0.00 0.00 0.00 5,924.05 70.00 320.00 2,948.88 -491.71 -4,317.76 4.00 0.00 4.26 94.34 6,124.05 70.00 320.00 3,017.29 -347.74 -4,438.56 0.00 0.00 0.00 0.00 6,732.42 75.00 345.00 3,202.85 162.73 -4,702.32 4.00 0.82 4.11 82.16 6,949.42 75.00 345.00 3,259.01 365.20 -4,756.57 0.00 0.00 0.00 0.00 7,185.28 80.00 353.20 3,310.13 591.06 -4,799.90 4.00 2.12 3.48 58.95 7,285.28 80.00 353.20 3,327.49 688.85 -4,811.57 0.00 0.00 0.00 0.00 8,050.28 80.00 0.00 3,460.49 1,440,43 -4,856.22 0.88 0.00 0.89 90.59 8,166.63 83.69 2.86 3,476.99 1,555.54 -4,853.33 4.00 3.17 2.46 37.69 8,229.00 83.69 2.86 3,483.84 1,617.45 -4,850.24 0.00 0.00 0.00 0.00 8,372.12 89.50 7.05 3,492.34 1,759.69 -4,837.88 5.00 4.06 2.93 35.93 9,389.35 88.74 7.05 3,508.00 2,769.10 -4,713.01 0.08 -0.08 0.00 -180.00 9,551.20 87.60 2.33 3,513.18 2,930.27 -4,699.78 3.00 -0.70 -2.92 -103.57 11,076.24 87.60 2.33 3,577.00 4,452.72 -4,637.87 0.00 0.00 0.00 0.00 11,326.24 85.19 1.68 3,592.72 4,702.05 -4,629.14 1.00 -0.97 -0.26 195.00 11,546.24 85.08 358.60 3,611.39 4,921.23 -4,628.61 1.40 -0.05 -1.40 267.88 11,861.24 88.23 358.60 3,629.77 5,235.56 -4,636.29 1.00 1.00 0.00 0.00 12,211.24 88.23 358.60 3,640.58 5,585.29 -4,644.84 0.00 0.00 0.00 0.00 12,411.24 90.23 358.60 3,643.27 5,785.20 -4,649.72 1.00 1.00 0.00 0.00 12,611.24 88.25 358.60 3,645.92 5,985.12 -4,654.61 0.99 -0.99 0.00 180.00 12,811.24 88.25 358.60 3,652.03 6,184.96 -4,659.49 0.00 0.00 0.00 0.00 12,975.66 87.59 357.50 3,658.00 6,349.17 -4,665.09 0.78 A.40 -0.67 -121.10 3/30/2005 1:53:37PM Paqe 3 of 10 COMPASS 2003.11 Build 48 ~~irINAL C7 ConocoPhillips Alaska Database: EDM 2003.11 Single User Db Company: ConocoPhillips Alaska (Kuparuk) Project: Kuparuk River Unit Site: Kuparuk 1J Pad Well: Plan 1J-168 (L3) W el lbore: 1 J-168 Design: 1J-168 (wp08) Halliburton Company Planning Report -Geographic Local Co-ordinate Reference: TVD Reference: MD References North Reference: Survey Calculation {Method: • HALLIBURTGN Sperry Drilling Services Well Plan 1J-168 (L3) 1J-168 (28+81) @ 109.OOft (Doyon 141 @ 28') 1J-168 (28+g1) @ 109.OOft (Doyon 141 ~ 28') True Minimum Curvature Planned Survey 1J-168 (wp08) Map Map ~ MD Inclination Azimuth TVD SSTVD +N/.S +E(=W `Northing Easting DLSEV Vert Section Ift) (°) (°) (ft) (ft) (ft) (ft) (ft) (ft) (°/100ft) 1ft1 ~ 28.00 0.00 0.00 28.00 -81.00 0.00 0.00 5,945,653.00 ~ 558,712.00 0.00 0.00 SHL ~ 1841ft FSL 2499ft FEL -Sec 35 - T11 N - R10E - Dr11113 1l2" Hole 100.00 0.00 0.00 100.00 -9.00 0.00 0.00 5,945,653.00 558,712.00 0.00 0.00 200.00 0.00 0.00 200.00 91.00 0.00 0.00 5,945,653.00 558,712.00 0.00 0.00 300.00 0.00 0.00 300.00 191.00 0.00 0.00 5,945,653.00 558,712.00 0.00 0.00 KOP ~ 300ft MD, 300ft ND - Build ~ 3.00°/100ft 400.00 3.00 243.00 399.95 290.95 -1.19 -2.33 5,945,651.79 558,709.68 3.00 -1.19 466.67 5.00 243.00 466.46 357.46 -3.30 -6.48 5,945,649.65 558,705.55 3.00 -3.30 CoMlnue Build ~ 4.0°I100ft to 6.0° Inc - 4678 MD, 4668 TVD 500.00 6.33 243.00 499.62 390.62 -4.79 -9.41 5,945,648.13 558,702.63 4.00 -4.79 600.00 10.33 243.00 598.55 489.55 -11.37 -22.32 5,945,641.46 558,689.77 4.00 -11.37 700.00 14.33 243.00 696.22 587.22 -21.07 -41.35 5,945,631.61 558,670.82 4.00 -21.07 716.67 15.00 243.00 712.34 603.34 -22.98 -45.11 5,945,629.67 558,667.08 4.00 -22.98 CorKinue Build ~ 6.0°11008 to 16.0° Inc - 717ft MD, 712ft TVD 800.00 19.10 245.54 792.00 683.00 -33.53 -67.14 5,945,618.95 558,645.13 5.00 -33.53 900.00 24.05 247.48 884.97 775.97 -48.12 -100.87 5,945,604.10 558,611.51 5.00 -48.12 1,000.00 29.02 248.78 974.41 865.41 -64.71 -142.33 5,945,587.19 558,570.19 5.00 -64.71 1,100.00 33.99 249.74 1,059.64 950.64 -83.18 -191.19 5,945,568.34 558,521.45 5.00 -83.18 1,200.00 38.97 250.47 1,140.02 1,031.02 -103.39 -247.09 5,945,547.70 558,465.75 5.00 -103.39 1,300.00 43.96 251.06 1,214.93 1,105.93 -125.18 -309.60 5,945,525.42 558,403.42 5.00 -125.18 1,400.00 48.94 251.55 1,283.81 1,174.81 -148.39 -378.23 5,945,501.68 558,334.97 5.00 -148.39 1,500.00 53.93 251.98 1,346.12 1,237.12 -172.84 -452.48 5,945,476.66 558,260.92 5.00 -172.84 1,600.00 58.92 252.35 1,401.40 1,292.40 -198.34 -531.77 5,945,450.54 558,181.84 5.00 -198.34 1,700.00 63.91 252.69. 1,449.23 1,340.23 -224.70 -615.51 5,945,423.52 558,098.32 5.00 -224.70 1,800.00 68.91 252.99 1,489.23 1,380.23 -251.73 -703.05 5,945,395.82 558,011.00 5.00 -251.73 1,801.86 69.00 253.00 1,489.90 1,380.90 -252.24 -704.71 5,945,395.30 558,009.35 5.00 -252.24 Sail ~ 69°Inc 8 253°Azi :1802ft MD,1490it TVD 1,855.16 69.00 253.00 1,509.00 1,400.00 -266.79 -752.29 5,945,380.38 557,961.88 0.00 -266.79 Base of Permafrost 1,900.00 69.00 253.00 1,525.07 1,416.07 -279.02 -792.33 5,945,367.83 557,921.95 0.00 -279.02 2,000.00 69.00 253.00 1,560.91 1,451.91 -306.32 -881.60 5,945,339.85 557,832.90 0.00 -306.32 2,100.00 69.00 253.00 1,596.74 1,487.74 -333.62 -970.88 5,945,311.86 557,743.84 0.00 -333.62 2,164.90 69.00 253.00 1,620.00 1,511.00 -351.33 -1,028.82 5,945,293.69 557,686.05 0.00 -351.33 T3 2,200.00 69. 00 253. 00 1,632. 58 1,523.58 -360. 91 -1,060. 16 5,945,283. 87 557,654.79 0.00 -360. 91 2,300 .00 69. 00 253. 00 1,668. 42 1,559.42 -388. 21 -1,149. 44 5,945,255 .88 557,565.73 0.00 -388. 21 2,400 .00 69. 00 253. 00 1,704. 25 1,595.25 -415, 50 -1,238. 72 5,945,227. 89 557,476.68 0.00 -415. 50 2,500 .00 69. 00 253. 00 1,740. 09 1,631.09 -442. 80 -1,328. 00 5,945,199. 91 557,387.62 0.00 -442. 80 2,600 .00 69. 00 253. 00 1,775. 93 1,666.93 -470. 09 -1,417. 28 5,945,171. 92 557,298.57 0.00 -470. 09 2,700 .00 69. 00 253. 00 1,811. 76 1,702.76 -497. 39 -1,506. 56 5,945,143. 93 557,209.51 0.00 -497. 39 2,800 .00 69. 00 253. 00 1,847. 60 1,738.60 -524. 68 -1,595. 83 5,945,115. 94 557,120.46 0.00 -524. 68 2,900 .00 69. 00 253. 00 1,883. 44 1,774.44 -551. 98 -1,685. 11 5,945,087. 95 557,031.40 0.00 -551. 98 2,954 .59 69. 00 253. 00 1,903. 00 1,794.00 -566. 88 -1,733. 85 5,945,072. 68 556,982.79 0.00 -566. 88 K15 3,000 .00 69. 00 253. 00 1,919. 27 1,810.27 -579. 27 -1,774. 39 5,945,059. 97 556,942.35 0.00 -579. 27 3,100 .00 69. 00 253. 00 1,955. 11 1,846.11 -606. 57 -1,863. 67 5,945,031. 98 556,853.29 0.00 -606. 57 3/3GY2005 1:53:37PM Page 4 of 10 COMPASS 2003.11 Build 48 ORIGINAL • • / Halliburton Company HALLIBURTON ConocoPhiflips Planning Report -Geographic Alaska Sperry Drilling Services Database: EDM 2003.11 Single User Db Local Co-ordinate Reference:. Well Plan 1J-168 (L3) Company: ConocoPhillips Alaska (Kuparuk) ND ReferertceE 1J-168 (28+81) (~ 109.OOft {Doyon 141 @ 28') Project: Kuparuk River Unit MD Reference; 1J-168 (28+g1) Q 109.OOft (Doyon 141 @ 28') Site: Kuparuk 1J Pad North-Reference: True Well: Plan 1J-168 (L3) Survey Calculation Method: Minimum Curvature Wellbore: 1 J-168 Design: 1J-168 (wp08) i Planned Survey 1J-168 (wp08) MD Inclination Azimuth ND SSND - +N/-5 (ft) (°) (°I (ft) (ft) {fti 3,200.00 69.00 253.00 1,990.95 1,881.95 -633.86 3,300.00 69.00 253.00 2,026.79 1,917.79 -661.16 3,400.00 69.00 253.00 2,062.62 1,953.62 -688.45 3,500.00 69.00 253.00 2,098.46 1,989.46 -715.75 3,554.53 69.00 253.00 2,118.00 2,009.00 -730.63 10 3/4" Cag Pt -Drill Out 9 7/8" Hole - 3555ft MD, 211 8ft ND - T3 +550 3,600.00 69.00 253.00 2,134.30 2,025.30 -743.04 3,700.00 69.00 253.00 2,170.13 2,061.13 -770.34 3,800.00 69.00 253.00 2,205.97 2,096.97 -797.63 3,900.00 69.00 253.00 2,241.81 2,132.81 -824.93 4,000.00 69.00 253.00 2,277.64 2,16$.64 -852.23 4,100.00 69.00 253.00 2,313.48 2,204.48 -879.52 4,200.00 69.00 253.00 2,349.32 2,240.32 -906.82 4,201.86 69.00 253.00 2,349.98 2,240.98 -907.32 Begin Dir ~ 4.0°HOOft, 4202ft MD, 2350ft ND 4,300.00 69.09 257.20 2,385.09 2,276.09 -930.88 4,400.00 69.29 261.48 2,420.64 2,311.64 -948.16 ~ 4,500.00 69.59 265.74 2,455.77 2,346.77 -958.58 4,600.00 70.00 269.98 2,490.32 2,381.32 -962.09 4,600.54 70.00 270.00 2,490.51 2,381.51 -962.09 Sail ~ 70°Inc 8 270°Azi : 4801ft MD, 2491 ft ND 4,700.00 70.00 270.00 2,524.52 2,415.52 -962.09 4,700.54 70.00 270.00 2,524.71 2,415.71 -962.09 Begin Dir ~ 4.0°HOOft, 4701ft MD, 2525ft ND 4,800.00 69.75 274.23 2,558.94 2,449.94 -958.65 4,900.00 69.60 278.49 2,593.69 2,484.69 -948.26 5,000.00 69.55 282.76 2,628.60 2,519.60 -930.99 5,100.00 69.61 287.03 2,663.50 2,554.50 -906.91 5,200.00 69.77 291.29 2,698.22 2,589.22 -876.13 5,277.81 69.97 294.60 2,725.00 2,616.00 -847.66 Ugnu C 5,287.29 70.00 295.00 2,728.24 2,619.24 -843.92 Sail ~ 70°Inc & 295°Azl : 5287ft MD, 2728ft ND 5,300.00 70.00 295.00 2,732.59 2,623.59 -838.88 5,337.29 70.00 295.00 2,745.35 2,636.35 -824.06 Begin Dir ~ 4.0°/t00ft, 5337ft MD, 2745ft ND 5,400.00 69.83 297.66 2,766.88 2,657.88 -797.94 5,500.00 69.64 301.92 2,801.53 2,692.53 -751.35 5,600.00 69.56 306.19 2,836.40 2,727.40 -698.87 5,700.00 69.58 310.46 2,871.32 2,762.32 -640.78 5,800.00 69.70 314.72 2,906.13 2,797.13 -577.35 5,848.75 69.80 316.80 2,923.00 2,814.00 -544.58 Ugnu B 5,900.00 69.93 318.98 2,940.64 2,831.64 -508.89 5,924.05 70.00 320.00 2,948.88 2,839.88 -491.71 Agin Pump Tangwrt - TO°inc i 320°Azi - 892.ftt MD, 2949ft Ti/D Map Map +EJ-yy Northing Easting pLSEV Vert Section (ft) (ft1 (ftl (°I100ft) lft) -1,952.95 5,945,003.99 556,764.24 0.00 -633.86 -2,042.23 5,944,976.00 556,675.19 0.00 -661.16 -2,131.51 5,944,948.02 556,586.13 0.00 -688.45 -2,220.79 5,944,920.03 556,497.08 0.00 -715.75 -2,269.47 5,944,904.77 556,448.51 0.00 -730.63 -2,310.06 5,944,892.04 556,408.02 0.00 -743.04 -2,399.34 5,944,864.05 556,318.97 0.00 -770.34 -2,488.62 5,944,836.06 556,229.91 0.00 -797.63 -2,577.90 5,944,808.08 556,140.86 0.00 -824.93 -2,667.18 5,944,780.09 556,051.80 0.00 -852.23 -2,756.46 5,944,752.10 555,962.75 0.00 -879.52 -2,845.74 5,944,724.11 555,873.69 0.00 -906.82 -2,847.39 5,944,723.59 555,872.04 0.00 -907.32 -2,935.94 5,944,699.35 555,783.69 4.00 -930.88 -3,027.78 5,944,681.35 555,692.00 4.00 -948.16 -3,120.80 5,944,670.21 555,599.07 4.00 -958.58 -3,214.55 5,944,665.97 555,505.35 4.00 -962.09 -3,215.06 5,944,665.97 555,504.85 4.00 -962.09 -3,308.52 5,944,665.24 555,411.40 0.00 -962.09 -3,309.03 5,944,665.24 555,410.89 0.00 -962.09 -3,402.33 5,944,667.95 555,317.58 4.00 -958.65 -3,495.50 5,944,677.61 555,224.34 4.00 -948.26 -3,587.58 5,944,694.16 555,132.13 4.00 -930.99 -3,678.12 5,944,717.53 555,041.41 4.00 -906.91 -3,766.69 5,944,747.61 554,952.62 4.00 -876.13 -3,833.96 5,944,775.56 554,885.14 4.00 -847.66 -3,842.04 5,944,779.23 554,877.02 4.00 -843.92 -3,852.86 5,944,784.19 554,866.16 0.00 -838.88 -3,884.63 5,944,798.75 554,834.29 0.00 -824.06 -3,937.40 5,944,824.46 554,781.32 4,00 -797.94 -4,018.79 5,944,870.42 554,699.58 4.00 -751.35 -4,096.42 5,944,922.28 554,621.55 4.00 -698.87 -4,169.91 5,944,979.79 554,547.61 4.00 -640.78 -4,238.91 5,945,042.68 554,478.12 4.00 -577.35 -4,270.82 5,945,075.19 554,445.96 4.00 -544.58 -4,303.08 5,945,110.63 554,413.43 4.00 -508.89 -4,317.76 5,945,127.69 554,398.62 4.00 -491.71 3/30/2005 1:53:37PM Page 5 of 10 COMPASS 2003.11 Build 48 • ConocoPhitlips Alaska .Database:. EDM 2003.11 Single User Db .Company: ConocoPhillips Alaska (Kuparuk) Project: Kuparuk River Unit SRe: Kuparuk 1J Pad Well: Plan 1J-168 (L3) Welibore: 1 J-168 Design: 1J-168(wp08) Halliburton Company !-1ALLIBURTON Planning Report -Geographic SPeRy Drilling Services LocalCo-ordinate Reference: Well Plan 1J-168 (L3} TYD ReferenCec 1 J-168 (28+81) @ 109.OOft (Doyon 141 @ 28') MDReference; 1J-168 (28+81) @ 109.OOft (Doyon 141 @ 28') North R,#fen3nce: True Survey Cakulation Method: Minimum Curvature Planned Survey 1J-168 (wp08) MD I nclination Azimuth TVD SSTVD +N/S" +E/-W (~) (°) (°) (ft) ft) s~- ~~ 6,000.00 70.00 320.00 2,974.86 2,865.86 -437.03 -4,363.64 6,058.89 70.00 320.00 2,995.00 2,886.00 -394.64 -4,399.21 Ugnu A 6,085.20 70.00 320.00 3,004.00 2,895.00 -375.70 -4,415.10 K13 6,100.00 70.00 320.00 3,009.06 2,900.06 -365.05 -4,424.04 6,124.05 70.00 320.00 3,017.29 2,908.29 -347.74 -4,438.56 End Pump Tangent - Build ~ 4°MOOft, 81248 MD, 3017ft TVD 6,200.00 70.44 323.19 3,042.99 2,933.99 -291.74 -4,482.95 6,300.00 71.11 327.37 3,075.93 2,966.93 -214.14 -4,536.71 6,400.00 71.87 331.51 3,107.69 2,998.69 -132.50 -4,584.90 6,500.00 72.72 335.61 3,138.11 3,029.11 -47.22 -4,627.29 6,600.00 73.65 339.68 3,167.05 3,058.05 41.29 -4,663.68 6,700.00 74.66 343.70 3,194.37 3,085.37 132.60 -4,693.68 6,732.42 75.00 345.00 3,202.85 3,093.85 162.73 -4,702.32 Saii ~ 75°Inc &345°Azi : 8732ft MD, 3203ft lYD 6,800.00 75.00 345.00 3,220.34 3,111.34 225.79 -4,719.22 6,837.32 75.00 345.00 3,230.00 3,121.00 260.61 -4,728.55 D-Sand intersect -1J-188 (v4) Dtop 6,900.00 75.00 345.00 3,246.22 3,137.22 319.09 -4,744.22 6,949.42 75.00 345.00 3,259.01 3,150.01 365.20 -4,756.57 Begin Dir ~ 4.0°f100ft, 8949ft MD, 3269ft TVD 7,000.00 76.05 346.79 3,271.66 3,162.66 412.69 -4,768.51 7,035.54 76.80 348.03 3,280.00 3,171.00 446.41 -4,776.04 C 7,100.00 78.16 350.27 3,293.98 3,184.98 508.21 -4,787.88 7,184.53 79.98 353.17 3,310.00 3,201.00 590.33 -4,799.82 BSand Intersect 7,185.28 80.00 353.20 3,310.13 3,201.13 591.06 -4,799.90 Sail ~ 80°Inc 3 353°Azi : T185ft MD, 3310it TVD 7,200.00 80.00 353.20 3,312.69 3,203.69 605.45 -4,801.62 7,285.28 80.00 353.20 3,327.49 3,218.49 688.85 -4,811.57 7,300.00 80,00 353.33 3,330.05 3,221.05 703.24 -4,813.27 7,400.00 79.99 354.22 3,347.42 3,238.42 801.14 -4,823.94 7,437.83 79.99 354.56 3,354.00 3,245.00 838.21 -4,827.59 A4 7,500.00 79.99 355.11 3,364.81 3,255.81 899.19 -4,833.10 7,600.00 79.98 356.00 3,382.20 3,273.20 997.37 -4,840.74 7,700.00 79.98 356.89 3,399.60 3,290.60 1,095.66 -4,846.85 7,708.07 79.98 356.96 3,401.00 3,292.00 1,103.60 -4,847.27 A3 7,800.00 79.98 357.76 3,416.99 3,307.99 1,194.02 -4,851.43 7,900.00 79.99 358.66 3,434.38 3,325.38 1,292.45 -4,854.49 8,000.00 80.00 359.55 3,451.75 3,342.75 1,390.92 -4,856.02 Map Map J Northing Easting DLSEV Vert Section (ft) (ft) (°1100ft) (ft) 5,945,182.00 554,352.32 0.00 -437.03 5,945,224.11 554,316.43 0.00 -394.64 5,945,242.92 554,300.39 0.00 -375.70 5,945,253.50 554,291.37 0.00 -365.05 5,945,270.70 554,276.71 0.00 -347.74 5,945,326.35 554,231.89 4.00 -291.74 5,945,403.52 554,177.53 4.00 -214.14 5,945,484.77 554,128.71 4.00 -132.50 5,945,569.71 554,085.66 4.00 -47.22 5,945,657.93 554,048.59 4.00 41.29 5,945,748.99 554,017.68 4.D0 132.60 5,945,779.05 554,009.00 4.00 162.73 5,945,841.97 553,991.62 0.00 225.79 5,945,876.71 553,982.02 0.00 260.61 5,945,935.06 553,965.89 0.00 319.09 5,945,981.07 553,953.18 0.00 365.20 5,946,028.46 553,940.88 4.00 412.69 5,946,062.11 553,933.09 4.00 446.41 5,946,123.81 553,920.77 4.00 508.21 5,946,205.83 553,908.19 4.00 590.33 5,946,206.56 553,908.09 4.00 591.06 5,946,220.94 553,906.27 0.00 605.45 5,946,304.25 553,895.67 0.00 688.85 5,946,318.63 553,893.86 0.87 703.24 5,946,416.43 553,882.42 0.88 801.14 5,946,453.47 553,878.49 0.88 838.21 5,946,514.40 553,872.50 0.87 899.19 5,946,612.SD 553,864.10 0.88 997.37 5,946,710.73 553,85722 0.88 1,095.66 5,946,718.66 553,856.73 0.88 1,103.60 5,946,809.05 553,851.87 0.88 1,194.02 5,946,907.44 553,848.05 0.88 1,292.45 5,947,005.88 553,845.75 0.88 1,390.92 3/30/2005 1:53:37PM Page 6 of 10 COMPASS 2003.11 Build 48 ~~~~~~. • ConocoPhitiips Alaska Database: EDM 2003.11 Single User Db Company: ConocoPhillips Alaska (Kuparuk) Project: Kuparuk River Unit Site: KuparuklJ Pad We{I: Plan 1J-168 (L3) W elibore: 1 J-168 Design: 1J-168 (wp08) Planned Survey 1J-168 (wp08) Halliburton Company HALL{BURTON Planning Report -Geographic Sperry Drilling Services LocaFCo-oMinats Reference: 'Well Plan 1J-168 (L3) ND Reference: 1J-168 (28+g1) @ 109.OOft (Doyon 141 @ 28') MD Reference: 1 J-168 (28+81) @ 109.OOft (Doyon 141 @ 28') North Reference: True Survey Calculation Method: Minimum Curvature ~ Map Map MD Inclination Azimuth ND SSND +W-S +E!-W Northing Easting DLSEV Vert Section ~ (ft) (°) (°) (ft) (ft) (ft) (ft) (ft) (ft) (°/100ft) Ift- I 8,050.28 80.00 0.00 3,460.49 3,351.49 1,440.43 -4,856.22 5,947,055.39 553,845.17 0.88 1,440.43 Begin Dir ~ 4.0°HOOft, 8050ft MD, 3480ft ND 8,100.00 81.57 1.23 3,468.45 3,359.45 1,489.51 -4,855.69 5,947,104.46 553,845.31 4.00 1,489.51 8,166.63 83.69 2.86 3,476.99 3,367.99 1,555.54 -4,853.33 5,947,170.50 553,847.16 4.00 1,555.54 Sail ~ 83.7°Inc $ 2.9°Azi : 8167ft MD, 34778 ND 8,184.94 83.69 2.86 3,479.00 3,370.00 1,573.72 -4,852.42 5,947,188.69 553,847.92 0.00 1,573.72 8,200.00 83.69 2.86 3,480.65 3,371.65 1,588.66 -4,851.67 8,206.00 83.69 2.86 3,481.31 3,372.31 1,594.62 -4,851.38 A2-Sand Intersect 8,209.00 83.69 2.86 3,481.64 3,372.64 1,597.60 -4,851.23 7 5t8 Csg ~ 1 8428 FNL 2088ft FEL -Sec 34 - T11N - 810E : 82098 MD, 3481ft ND 8,229.00 83.69 2.86 3,483.84 3,374.84 1,617.45 -4,850.24 Begin Dir ~ 5.0°f100ft, 8229ft MD, 3484ft ND 8,300.00 86.57 4.95 3,489.86 3,380.86 1,688.02 -4,845.42 8,372.12 89.50 7.05 3,492.34 3,383.34 1,759.69 -4,837.88 Sail ~ 89.50°Inc 8 7.OS°Azi : 8372ft MD, 3492ft ND • 1J•188 (v4) T2 8,400.00 89.48 7.05 3,492.58 3,383.58 1,787.36 -4,834.46 8,500.00 89.40 7.05 3,493.56 3,384.56 1,886.60 -4,822.18 8,600.00 89.33 7.05 3,494.66 3,385.66 1,985.84 -4,809.91 8,700.00 89.25 7.05 3,495.90 3,386.90 2,085.07 -4,797.63 8,800.00 89.18 7.05 3,497.27 3,388.27 2,184.31 -4,785.35 8,900.00 89.10 7.05 3,498.77 3,389.77 2,283.54 -4,773.08 9,000.00 89.03 7.05 3,500.40 3,391.40 2,382.77 -4,760.80 9,100.00 88.95 7.05 3,502.16 3,393.16 2,482.00 -4,748.53 9,200.00 88.88 7.05 3,504.06 3,395.06 2,581.22 -4,736.25 9,300.00 88.80 7.05 3,506.08 3,397.08 2,680.45 -4,723.97 9,389.35 88.74 7.05 3,508.00 3,399.00 2,769.10 -4,713.01 Begin Dir ®3.0°f100ft, 9389ft MD, 35088 ND 9,400.00 88.66 6.74 3,508.24 3,399.24 2,779.67 -4,711.73 9,500.00 87.96 3.82 3,511.19 3,402.19 2,879.19 -4,702.53 9,551.20 87.60 2.33 3,513.18 3,404.18 2,930.27 -4,699.78 Sail ~ 87.59°I nc & 2.34°Azi : 9551ft MD, 3513 ft ND 9,600.00 87.60 2.33 3,515.22 3,406.22 2,978.99 -4,697.80 9,700.00 87.60 2.33 3,519.40 3,410.40 3,078.82 -4,693.74 9,800.00 87.60 2.33 3,523.59 3,414.59 3,178.65 -4,689.68 9,900.00 87.60 2.33 3,527.77 3,418.77 3,278.48 -4,685.62 10,000.00 87.60 2.33 3,531.96 3,422.96 3,378.31 -4,681.56 10,100.00 87.60 2.33 3,536.14 3,427.14 3,478.14 -4,677.50 10,200.00 87.60 2.33 3,540.33 3,431.33 3,577.97 -4,673.44 10,300.00 87.60 2.33 3,544.51 3,435.51 3,677.80 -4,669.38 10,400.00 87.60 2.33 3,548.70 3,439.70 3,777.63 -4,665.32 10,500.00 87.60 2.33 3,552.88 3,443.88 3,877.46 -4,661.26 10,600.00 87.60 2.33 3,557.07 3,448.07 3,977.29 -4,657.20 10,700.00 87.60 2.33 3,561.25 3,452.25 4,077.12 -4,653.14 10,800.00 87.60 2.33 3,565.44 3,456.44 4,176.95 -4,649.09 5,947,203.64 553,848.55 0.00 1,588.66 5,947,209.60 553,848.80 0.00 1,594.62 5,947,212.57 553,848.93 0.00 1,597.60 5,947,232.43 553,849.77 0.00 1,617.45 5,947,303.03 553,854.03 5.00 1,688.02 5,947,374.75 553,861.01 5.00 1,759.69 5,947,402.44 553,864.22 0.08 1,787.36 5,947,501.76 553,875.72 0.08 1,886.60 5,947,601.08 553,887.22 0.08 1,985.84 5,947,700.40 553,898.72 0.08 2,085.07 5,947,799.72 553,910.22 0.08 2,184.31 5,947,899.04 553,921.72 0.08 2,283.54 5,947,998.35 553,933.22 0.08 2,382.77 5,948,097.66 553,944.72 0.08 2,482.00 5,948,196.97 553,956.23 0.08 2,581.22 5,948,296.28 553,967.73 0.08 2,680.45 5,948,385.00 553,978.00 0.08 2,769.10 5,948,395.58 553,979.20 2.99 2,779.67 5,948,495.16 553,987.62 3.00 2,879.19 5,948,546.26 553,989.97 3.00 2,930.27 5,948,594.99 553,991.57 0.00 2,978.99 5,948,694.84 553,994.85 0.00 3,078.82 5,948,794.69 553,998.13 0.00 3,178.65 5,948,894.54 554,001.41 0.00 3,278.48 5,948,994.39 554,004.69 0.00 3,378.31 5,949,094.23 554,007.97 0.00 3,478.14 5,949,194.08 554,011.25 0.00 3,577.97 5,949,293.93 554,014.53 0.00 3,677.80 5,949,393.78 554,017.81 0.00 3,777.63 5,949,493.63 554,021.10 0.00 3,877.46 5,949,593.48 554,024.38 0.00 3,977.29 5,949,693.33 554,027.66 0.00 4,077.12 5,949,793.18 554,030.94 0.00 4,176.95 313Q/2005 1:53:37PM Page 7 of 10 COMPASS 2003.11 8uifd 48 ORIGINAL • ~-' Halliburton Company C Philli HA LLIBUR TON onoco ps Planning Report -Geographic Alaska Sperry Drilling Services Database: EDM 2003.11 Singfe User Db LocafCo-ordinate Reference:' Weli Plan 1J-168 (L3) Company: ConocoPhillips Alaska (Kuparuk) TVDReference: 1J-168 (28+81) @ 109.OOft (Doyon 141 @ 28') Project: Kuparuk River Unit MD'Reference: 1J-168 (28+g 1) @ 109.OOft(Doyon 141 @28') Site: Kuparuk 1J Pad North Reference: True Well: Plan 1J-168 (L3) Su rvey Calculation Method: Minimum Curvature Welibore: 1J-168 Design: 1J-168 (wp08) r-- Planned Survey 1J-168 (wpD8) Map Map j MD Inclination Azimuth ND SSTVD +NI-S +FFyli Northing Easting DLSEV Vert Section ft O °) (°- R) ft) fq ft> ft l 1 R (1 ° (/1008) ft) 10,900.00 87.60 2.33 3,569.62 3,460.62 4,276.78 -4,645.03 5,949,893.03 554,034.22 0.00 4,276.78 11,000.00 87.60 2.33 3,573.81 3,464.81 4,376.61 -4,640.97 5,949,992.87 554,037.50 0.00 4,376.61 11,076.24 87.60 2.33 3,577.00 3,468.00 4,452.72 -4,637.87 5,950,069.00 554,040.00 0.00 4,452.72 Begin Unduiation in A2Sand : Dir ~ 1.0°!1008,110768 MD, 35778 ND -1J-168 (v4) T3 11,100.00 87.37 2.27 3,578.04 3,469.04 4,476.44 -4,636.92 5,950,092.72 554,040.77 1.00 4,476.44 11,200.00 86.41 2.01 3,583.47 3,474.47 4,576.22 -4,633.20 5,950,192.52 554,043.71 1.00 4,576.22 11,300.00 85.44 1.75 3,590.58 3,481.58 4,675.91 -4,629.93 5,950,292.22 554,046.20 1.00 4,675.91 11,326.24 85.19 1.68 3,592.72 3,483.72 4,702.05 -4,629.14 5,950,318.37 554,046.78 1.00 4,702.05 ~ Begin Dir ~ 1 .40°H008,11326R MD, 3S93ft TVD 11,400.00 85.15 0.65 3,598.94 3,489.94 4,775.54 -4,627.65 5,950,391.85 554,047.70 1.39 4,775.54 11,500.00 85.10 359.25 3,607.43 3,498.43 4,875.17 -4,627.74 5,950,491.47 554,046.83 1.40 4,875.17 11,546.24 85.08 358.60 3,611.39 3,502.39 4,921.23 -4,628.61 5,950,537.52 554,045.61 1.40 4,921.23 Begin Dir ~ 1.00°I100it,11846R MD, 361 18 TVD 11,565.38 85.27 358.60 3,613.00 3,504.00 4,940.30 -4,629.08 5,950,556.58 554,044.99 1.00 4,940.30 11,600.00 85.62 358.60 3,615.75 3,506.75 4,974.80 -4,629.92 5,950,591.07 554,043.88 1.00 4,974.80 11,630.51 85.92 358.60 3,618.00 3,509.00 5,005.22 -4,630.66 5,950,621.48 554,042.90 1.00 5,005.22 11,700.00 86.62 358.60 3,622.52 3,513.52 5,074.54 -4,632.36 5,950,690.78 554,040.67 1.00 5,074.54 11,800.00 87.62 358.60 3,627.55 3,518.55 5,174.38 -4,634.80 5,950,790.59 554,037.45 1.00 5,174.38 11,861.24 88.23 358.60 3,629.77 3,520.77 5,235.56 -4,636,29 5,950,851.76 554,035.48 1.00 5,235.56 Sail ~ 88.T3° I nc : 118618 MD, 36308 ND 11,900.00 88.23 358.60 3,630.97 3,521.97 5,274.29 -4,637.24 5,950,890.47 554,034.23 0.00 5,274.29 12,000.00 88.23 358.60 3,634.05 3,525.05 5,374.22 -4,639.68 5,950,990.36 554,031.01 0.00 5,374.22 12,095.39 88.23 358.60 3,637.00 3,528.00 5,469.53 -4,642.01 5,951,085.64 554,027.93 0.00 5,469.53 12,100.00 88.23 358.60 3,637.14 3,528.14 5,474.14 -4,642.12 5,951,090.25 554,027.79 0.00 5,474.14 12,200.00 88.23 358.60 3,640.23 3,531.23 5,574.06 -4,644.56 5,951,190.14 554,024.56 O.DO 5,574.06 12,211.24 88.23 358.60 3,640.58 3,531.58 5,585.29 -4,644.84 5,951,201.37 554,024.20 0.00 5,585.29 Begin Dir ~ 1.00°I100ft,12211R MD, 36418 ND 12,300.00 89.12 358.60 3,642.63 3,533.63 5,674.00 -4,647.01 5,951,290.05 554,021.34 1.00 5,674.00 12,400.00 90.12 358.60 3,643.30 3,534.30 5,773.97 -4,649.45 5,951,389.99 554,018.12 1.00 5,773.97 12,411.24 90.23 358.60 3,643.27 3,534.27 5,785.20 -4,649.72 5,951,401.22 554,017.76 1.00 5,785.20 Begin Dir ~ 0.99°/100ft,12411R MD, 3643ft ND 12,500.00 89.35 358.60 3,643.59 3,534.59 5,873.94 -4,651.89 5,951,489.92 554,014.90 0.99 5,873.94 12,600.00 88.36 358.60 3,645.59 3,536.59 5,973.88 -4,654.34 5,951,589.84 554,011.68 0.99 5,973.88 12,611.24 88.25 358.60 3,645.92 3,536.92 5,985.12 -4,654.61 5,951,601.07 554,011.32 0.99 5,985.12 Sail ~ 88.25° I nc : 126118 MD, 36468 ND 12,646.65 88.25 358.60 3,647.00 3,538.00 6,020.50 -4,655.48 5,951,636.44 554,010.18 0.00 6,020.50 12,700.00 88.25 358.60 3,648.63 3,539.63 6,073.81 -4,656.78 5,951,689.73 554,008.46 0.00 6,073.81 12,800.00 88.25 358.60 3,651.68 3,542.68 6,173.73 -4,659.22 5,951,789.63 554,005.24 0.00 6,173.73 12,811.24 88.25 358.60 3,652.03 3,543.03 6,184.96 -4,659.49 5,951,800.85 554,004.87 0.00 6,184.96 Begin Dir ~ 0.78°h008,128118 MD, 36528 ND 3/3Q/2005 1:53.B7PM Page 8 of 10 COMPASS 2003.11 Build 48 ORIGINAL Y Halliburton Company HALLIBURTON Conoco Phillips Planning Report -Geographic Alaska Sperry Drillin Services 9 Database: EDM 2003.11 Single User Db Lacal'Co-ordinate Reference: Well Plan 1J-168 (L3) Company: ConocoPhillips Alaska (Kuparuk) TVD Reference: 1J-168 (28+g1) @ 109.OOft (Doyon 141 ~ 28') Project: Kuparuk River Unit MD Reference: 1J-168 (28+81) ~ 109.OOft (Doyon 141 ~ 28') Site: Kuparuk 1J Pad North Reference: True ~ Well: Plan 1J-168 (L3) Survey Gakulation Method::.. Minimum Curvature Welibore: 1J-168 Design: 1J-168(wp08) I Planned Surve 1J 168 08 y - (wp ) Map Map MD Inclination Azimuth TVD SSTVD +N/-S +EI_W Northing Easting DLSEV Vert Section Ift) (°) (°1 ift) (ft) Ift) (ft) (ft) (ft) (°/100ft) (ftl 12,900.00 87.89 358.01 3,655.01 3,546.01 6,273.63 -4,662.12 5,951,889.49 554,001.56 0.78 6,273.63 12,975.66 ~ 87.59 357.50 3,658.00 3,549.00 6,349.17 -4,665.09 5,951,965.00 553,998.00 0.78 6,349.17 TD ~ t2975ft MD, 3858ft ND : 2871ft FNL 818778 FEL -Sec 27-T11N-R10E - 4112" -1J•168 (v4) Toe i~ Geologic Targets ~ 1J-168 I TVD Target Name '+Nl~ +E/-W Northing Easting (fk) -snaps ft ft (ft) (ft) 3,613,00 1J-i68 Fault Intersect 5,732.92 -4,641.89 5,951,349.00 554,026.00 3,479.00 1J-168 (v4) T1 1,484.49 -4,784.03 5,947,100.00 553,917.00 3,637.00 iJ-168 (v4) T5 5,808.96 -4,646.30 5,951,425.00 554,021.00 3,573.00 1J-168 (v4) T3 4,452.72 -4,637.87 5,950,069.00 554,040.00 3,230.00 1J-168 (v4) Dtop 284.30 -4,779.39 5,945,900.00 553,931.00 -Circe (radius 50.00) 3,618:00 1J-168 (v4) T4 5,594.91 -4,642.97 5,951,211.00 554,026.00 3,654.00 1J-168 (v4) Toe 6,349.17 -4,665.09 5,951,965.00 553,998.00 3,504.00 1J-168 (v4) T2 2,769.10 -4,713.01 5,948,385.00 553,978.00 3,647.00 1J-168 (v4) T6 6,124,05 -4,652.84 5,951,740.00 554,012.00 3/30/2005 1:53:37PM Page 9 of 10 ~~~~~~ COMPASS 2003.11 Build 48 fonocoPhillips Alaska Database: EDM 2003.11 Single User Db Company: ConocoPhillips Alaska (Kuparuk) Project: Kuparuk River Unit Site: Kuparuk 1J Pad Well: Plan 1J-168 (L3) Wellbore: 1J-168 Design: 1 J-168 (wp08) Halliburton Company HALLIBURTON Planning Report -Geographic Sperry Drilling Services Local Co-ordinate Reference: Well Pian 1J-168 (L3) ND Reference: 1J-168 (28+81) ~ 109.OOft (Doyon 141 ~ 28') MD 2eference: 1J-168 (28+81) @ 109AOft (Doyon 141 @ 28') Nortlt Reference: True Survey Calculation Method: Minimum Curvature Prognosed Casing Points .Measured.. Vertical Depth Depth. i~) (~1 3,554.53 2,118.00 8,209.00 3,481.64 12,975.65 3,658.00 Easing Hole Diameter Diameter - ") 1.,) 10314 13-1i2 7-518 9-718 41/2 6-314 i ~ Prognosed Formation Intersection Points - Measured Veetical Dept Inclination Azimuth Depth +N/-E +FJ-W (ft) i (o) 1°) (ft} (R) eft) Name 1,855.16 69.00 253.00 1,509.00 -266.79 -752.29 Base ofPennafrost 2,164.90 69.00 253.00 1,620.00 -351.33 -1,028.82 T3 ~ 2,954.59 69.00 253.00 1,903.00 -566.88 -1,733.85 K15 ~ 3,554.53 69.00 253.00 2,118.00 -730.63 -2,269.47 T3 +550 ~ 5,277.81 69.97 294.60 2,725.00 -847.66 -3,833.96 Ugnu C 5,848.75 69.80 316.80 2,923.00 -544.58 -4,270.82 Ugnu B 6,058.89 70.00 320.00 2,995.00 -394.64 -4,399.21 Ugnu A 6,065.20 70.00 320.00 3,004.00 -375.70 -4,415.10 K13 6,837.32 75.00 345.00 3,230.00 260.61 -4,728.55 D-Sand Inteniect 7,035.54 76.80 348.03 3,280.00 446.41 -4,776.04 C 7,184.53 79.98 353.17 3,310.00 590.33 -4,799.82 B-Sand lrttersect 7,437.83 79.99 354.56 3,354.00 838.21 -4,827.59 A4 7,708.07 79.98 356.96 3,401.00 1,103.60 -4,847.27 A3 8,206.00 83.69 2.86 3,481.31 1,594.62 -4,851.38 A2-Sand Irnersect 3/3GY2005 1:53:37PM Page 10 of 10 COMPASS 2003.11 Burld 48 ORIGINAL • ConocoPhillips Alaska ConocoPhillips Alaska (Kuparuk) Kuparuk River Unit Kuparuk 1J Pad Plan 1 J-168 (L3) 1 J-168 1 J-168 (wp08) Anticollision Report 30 March, 2005 :7 HALLIBL~RTCiN Sperry Drilling Services OR161NAL SURVEY PROGRAM Dale: 2110503-30TDO:W:00 Validatevl: Ys Vernioo: Depth Fmm Depth Tu Survq/Plan Tool 28.00 800,011 1J-168 (wptat) CB-GYROSS 8011.OD 12973.66 1J-16A (wpOR) MWD+IFR-AK-CA2 SC 0 V ' ConocoPhillips Alaska (K~ Engineering West Sak Calculation Method: Minimum Curvature Ertor System: ISCWSA Scan McMod: Tnv. Cylinder North Error Surface: Elliptical COnlt Warning Method: Rules Based Travelling C}'linder Azimuth (TFO+AZI) ~°~ vs Centre to Centre Separation )I00 ft/in) ANTI-COLLISION SETTINGS Interpolation Method: MD Interval: 25Stations Depth Range From: 28.00 To 12975.66 Maximum Range:1630 Reference: Plan: 1.1-168 (wp08) REFERENCE INFORMATION Co-0rdinate (N/E) Reference: Well Plan iJ-168 (L3), True North Verkcal (TVD) Re/erence: iJ-168 (28+81) ~ 109.OOft (Doyon 141 ~ 28~ SecGOn (VS) Reference: Slot - (O.OON, O.OOE) Measured Depth Reference: iJ-168 (28+81) @ 109.OOft (Doyon 141 ~ 28') Calculation Method: Minimum Curvature WELL DETAILS: Plan 1J-168 (L3) Ground Level: 81.00 +WS +E/-W Northing Easting Latittude Longitude Slot 0.00 0.®45653.00 558712.0070°15'43.641N19°31'31.336W From Colour To MD 28 100 100 200 200 300 300 550 550 "" - " - 800 800 1050 1050 1550 1550 2050 2050 2550 2550 3050 3050 3550 3550 5050 5050 6550 6550 8050 8050 9550 9550 11050 11050 12550 12550 13000 LEGEND --~ tE~112, tE-112.1E-112 V1 --;-- tE-112,1E-112L1, tE-112L1 V0 -'E,} 1E-112.1E-112L2, 1E~112L2 V1 tE-128.1E-126.1E-126 V1 1E~126, 1E~126L1,1E-126L1 V1 1E-126,1E-126L2.1E-12613 V1 ~- 1EJ5. 1E-%.1E-%Vt 1E35. 1E~35A, tE-36A (wp021 VO 1110, 1110. 1J-10V] Pbn 1}tlt(M121. Fen 1J-M12 Let A.Pbn 1}M12lMAV0 ~- Pbn 1}115(L9).Pbn 1J-L9 La1 A.Pbn 1J-L9 tAtA VO --[} Plan 11110(110). Plan 17110 Lat A.Pbn1x10latA VO -*- Plan 1J-120(L11). Plan 17111 Let A. %an 17111 latAVD -~(~ Plan 1J-1221L12).Pbn 17112 tat A, Fan 17112 LatA VO A Fen ulna 1L13).Pbn1x131At A.Pbntxl3 LatAVO %en 1J-12] 0.B), Pbn 1x8 LaIA, Plan 1 J-L8 LaIA VD Fan 11129101]). Fan 1J-0IJB VI-Pbn 1J-01JBLal V0 Z Plan 1}156(IM1.Pbn IJ-IMALar. Fan 1J-M4ALet VO Plan 1J-15] (GKUp), 1J-L (KUP). 1J-L (KUP) VerlO.A V4 Fan 1}150 (M31.11M] A lahlal. iJ#IJ A LetMMVarsR.I Plan 11159 Mn.1 J-139,1}159 (wp0]) VO -~ Pbn 1J-159 (M7J.1J-159 L1, 1}159L1 (wp031 V0 {] Plan 1y159 M]1. 11159 L2. 11159 L2 (wp03)VO Plen 11160 M2), Plan 17142 Lel A. Nan 1J-M21a1 A VO Pbn 1J-182 Mt), 1J-162. 1J-t621w031-Neae/WAVO -~ Plan 111621M11.1}182 L1.1J-182 L1 (wp3.1)VO -Q~-~ Ren tJ-182 (Mt), 17-182 L2.1J-162 L2 (wp31) V0 Plan 1}161 (L6),1J-161.1}L6 A LN ('ap031 V0 ~~ Nan 1J-164 (L6). i}161 Lt, 11164 Li (wp03) VO Plan 1J-164 (L6), iJ-164 L2, 1J-164 L2 (wpW)VO Plan 1J-166 (LS).1}166,1}186 (wp03) VO --~- Fan 11166 (IS). 1}168 L1. 1}188 L1 (wp03)VO -~ Fan 1J-160 (LS), 1J-186 L2.1J-188 LZ (wp03) VO -~- Pbn 1J-1]0 (Ld). Plan I1L4 LaM, Pbnix4LaM VO ~•~ Plant}1]4101). Nan 17-018 WL Pbn 17-01 BLH Vo -~- Pbn 1J-1]5(A-KUp).1}A p(IRI, 11A (Kt1P)VarWAV3 ~~ Pbn 111]6 (02). Ran 1J-028lat. Pbn 17-026 LM V0 -EI- Fan 111]6 (03). Ran 1J-038laL Nen 17-038 Let VO -~- Wnt}t)9(&Nup). 1}6 (KUP1. 17.6 (KWIVenpAV6 ~- Pbn 11180 (011. Ran 1J-04 Blai, Nan 1J-046lat VO W6P-03, WSP-03, WSP-03V1 -$- WSP-04, WSP-D4, WfiP-04 V1 $ wsPOS. wsP-m, W6P-osw -~ WSP-Ofi. W5P-O6, W6P-O6 V1 --~ wsP-o]. wsp-o]. wsP-o]v1 N5P-0B. WSP~OO, WSP-00 Vt -£- WSP-NI, W6P-20, WSP-20 V1 90 Travelling Cylinder Azimuth (TFO+A7.1) ~°~ vs Centre to Centre Separation X40 ft<n~ SECTION DETAILS Sec MD Inc Azi ND +N/S +E/-W DLeg TFace VSec Target 1 ze.oo D.oo o.oa 2a.oo o.oo o.oo o.oo o.oo o.oo 2 300.00 0.00 0.00 3aa.oo o.oo o.oo o.oo o.oo o.oo 3 466.67 5.00 243.00 466.46 -3.30 -6.48 3.00 243.00 -3.30 4 716 67 15.00 243.00 712.34 -22.98 35.11 4.00 360.00 -22.98 5 1801.86 69.00 253.00 1469.90 -252.24 -704.71 5.00 11.52 -252.24 6 4201.86 69.00 253.00 2349.96 -907.32 -2847.39 0.00 0.00 -907.32 7 4600.54 70.00 270.00 2490.51 -962.09 -3215.06 4.00 89.43 -962.09 8 4700.54 70.00 270.00 2524.71 -962.09 -3309.03 0.00 0.00 -962.09 9 5287.29 70.00 295.00 2728.24 -843.92 -3842.04 4.00 94.34 -84392 10 5337.29 70.00 295.00 2745.35 -824.06 -3884.63 0.00 0.00 -824.06 11 5924.05 70.00 320.00 2948.88 391.71 3317.76 4.00 94.34 191.71 12 6124.05 70.00 320.00 301229 -347.74 -4438.56 0.00 0.00 747.74 13 6732.42 75.00 145.00 3202.85 162 73 3702.32 4.00 82.16 162.73 14 6949.42 75.00 345.00 3259.01 365.20 4756.57 0.00 0.00 365.20 15 7185.28 80.00 353.20 3310.13 591.06 4799.90 4.00 58.95 591.06 16 7285.28 80.00 353.20 3327.49 688.85 3811.57 0.00 0.00 688.85 17 8050.28 80.00 0.00 3460.49 1440.43 3856.22 0.88 90.59 1440.43 18 816663 83.69 2.86 3476.99 1555.54 3853.33 4.00 37.69 1555.54 19 8229.00 83.69 2.86 34(13.84 1617.45 3850.24 0.00 0.00 1617.45 20 8372.12 89.50 7.05 3492.34 1759.69 3837.88 5.00 35.93 1759.69 17-168 (vd) T2 21 9389.75 88.74 7.05 3508.00 2769.10 3713.01 0.08 -180.00 2769.10 17-168 (v4) T2 22 9551.20 87.60 2.33 3513.18 2930.27 3699.78 3.00 -103.57 2930.27 23 11076.24 67.60 2.33 3577.00 4452.72 3637.87 0.00 0.00 4452.72 17-188 (v4) T3 24 11326.24 65.19 1.68 3592.72 4702.05 3629.14 1.00 195.00 4702.05 2511546.24 65.08 358.60 3611.39 4921.23 3628.61 1.40 267.88 4921.23 26 11861.24 88.23 358 60 3629.77 5235.56 3636.29 1.00 0.00 5235.56 27 12211.24 88.23 358.60 3640.56 5585.29 3644.84 0.00 0.00 5585.29 2812411.24 90.23 358.60 3643.27 5785.20 3649.72 1.00 0.00 5785.20 2912611.24 88.25 358.60 3645.92 5985.12 3654.61 0.99 180.00 5985.12 3D 12811.24 88.25 358 60 3652.03 6184 96 3659.49 0.00 0.00 6184.96 31 1297566 8759 357.50 3658 00 6349.17 3665.09 0.78 -121.10 6349.17 1 J-168 (v4) Toe • • ~ Haliiburton Company C ~' ~~ HALLIBURTON 011000 11 1 S p Anticollision Report Alaska Spent' Drilling Services Comparry; " ConocoPhittips Alaska (Kuparuk) Local Co-ordittate Reference: Well Plan 1J-168 (L3) Project: Kuparuk River Unit TVD Reference: 1J-168 (28+81) @ 109.OOft (Doyon 141 @ 28') Reference Site: Kuparuk 1J Pad MD Reference: `' 1J-168 (28+g1) @ 109.OOft (Doyon 141 @ 28') Site Error: O.OOft North Reference: True Reference Well: Ptan 1J-168 (L3) Survey Calculation Method: Minimum Curvature Well Error: O.OOft Outputerrorsare et 1.96 sigma Reference Wellbore 1J-168 Database: EDM 2003.11 Single User Db Reference Design: 1J-168 (wp08) Offset TVD Reference: Offset Datum Reference 1J-168 (wp08) Filter type: NO GLOBAL FILTER: Using user defined selection & filtering criteria Interpolation Method: MD Interval 25.OOft Error Model: ISCWSA Depth Range: Unlimited Scan Method: Trav. Cylinder North Results Limited by: Maximum center-center distance of 1,630.OOft Error Surtace: Elliptical Conic Warning Levels evaluated at: 0.00 Sigma Survey Tool Program Date 3!3012005 From To (ft} (ft) Survey (Wellbore) Toot Name Description 28.00 800.00 1J-168 (wp08) (1J-168) CB-GYRO-SS Camera based gyro single shot 800.00 12,975.66 1J-168 (wp08) (1J-168) 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 3/3GV2005 2:37.~14PM Page 2 of 155 COMPASS 2003.11 Build 48 ~~ • Conoco~illips Alaska Company: ConocoPhillips Alaska (Kuparuk) Project: Kuparuk River Unit Reference Site: Kuparuk 1J Pad Site Error: O.OOft Reference Well: Plan 1J-168 (L3) WeII Error: O.OOft Reference Wellbore 1J-i68 Reference Design: 1J-168 (wp08) • Halliburton Company Anticollision Report HALLIBURTON Sperry Drilling Services Local Co-ordinate Refererce: Well Plan 1J-168 (L3) ND Reference: 1J-168 (28+81) @ 109.OOft (Doyon 141 @ 28') MD Reference: 1J-168 (28+g1) @ 109.OOft (Doyon 141 @ 28') Borth Reference: True Survey Calculation Method: 'Minimum Curvature Output errors are at ` 1.96 sigma Database: EDM 2003.11 Single User Db Offset ND Reference: Offset 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 - Desigrt tff) (fr) (ft) lfi) Kuparuk 1 E Pad 1 E-35 - 1 E-35 - 1 E-35 Out of range 1E-35-1E-35A-1E-35A(wp02) 12,964.39 10,450.00 1,364.57 176.23 1,188.34 Pass-Major Risk Kuparuk 1J Pad 1 J-10 - 1 J-10 - 1 J-10 417.36 425.00 161.10 7.70 153.40 Pass -Major Risk Plan 1J-111 (M12) -Plan 1J-M12 Lat A -Plan 1J-M 323.71 325.00 231.87 6.24 225.62 Pass -Major Risk Plan 1J-115 (L9) -Plan 1J-L9 Lat A -Plan 1 J-L9 Lat A 346.93 350.00 177.47 6.69 170.79 Pass -Major Risk Plan 1 J-118 (L10) -Plan 1 J-L10 Lat A -Plan 1J-L10 324.09 325.00 151.46 6.25 145.21 Pass -Major Risk Plan 1J-120 (L11) -Plan 1J-L11 Lat A -Plan 1J-L11 324.20 325.00 146.06 6,25 139.81 Pass -Major Risk Plan 1J-122 (L12) -Plan 1 J-L12 Lat A -Plan 1 J-L12 324.31 325.00 151.72 6.25 145.47 Pass -Major Risk Plan 1J-124 (L13}-Plan 1J-L13 LatA-Plan 1J-L13 276.00 275.00 166.74 5.34 161.40 Pass-Major Risk Plan 1J-127 (LS) -Plan 1 J-L8 LatA -Plan 1J-L8 LatA 371.85 375.00 203.13 7.15 195.98 Pass -Major Risk Plan 1J-129 (013) -Plan 1J-013 B Lat-Plan 1J-013 226.00 225.00 232.10 4.40 227.70 Pass -Major Risk Plan 1 J-156 (M4) -Plan 1J-M4 A Lat -Plan 1 J-M4 A Lat 421.98 425.00 260.83 8.10 252.73 Pass -Major Risk Plan 1J-157 (C-Kup) - 1J-C (KUP) - 1J-C (KUP) Ver# 446.43 450.00 241.28 8,56 232.72 Pass -Major Risk Plan 1J-158 (M3) - 1J-M3 A Lateral - 1J-M3 A Laterlal V 6,386.31 6,125.00 211.99 96.99 115.00 Pass -Major Risk Plan 1J-159 (M7) - 1J-159 - 1J-159 (wp03) 447.12 450.00 201.40 8.44 192.96 Pass -Major Risk Plan 1J-159 (M7) - 1J-159 L1 - 1J-159 L1 (wp03) 447.12 450.00 201.40 8.44 192.96 Pass -Major Risk Plan 1J-159 {M7) - 1J-159 L2 - 1 J-159 L2 {wp03) 447.12 450.00 201.40 8.44 192.96 Pass -Major Risk Plan 1J-160 (M2) -Plan 1J-M2 Lat A -Plan 1J-M2 Lat A 325.43 325.00 180.39 6.28 174.11 Pass -Major Risk Plan 1J-162 (M1)- 1J-162- 1J-162 (wp03.1-North Heel 350.26 350.00 120.78 7.43 113.35 Pass- Major Risk Plan 1J-162 (M1) - 1J-162 L1 - 1J-162 L1 (wp3.1) 350.26 350.00 120.78 7.32 113.46 Pass- Major Risk Plan 1J-162 (M1) - 1J-162 L2 - 1J-162 L2 {wp3.1) 350.26 350.00 120.78 7.32 113.46 Pass -Major Risk Plan 1J-164 (L6) - 1J-164 - 1J-L6 A Lat (wp03) 424.60 425.00 81.03 8.01 73.02 Pass -Major Risk Plan 1J-164 (L6)- 1J-164 L1 - 1J-164 L1 (wp03) 424.60 425.00 81.03 8.01 73.02 Pass- Major Risk Plan 1J-164 (L6) - 1J-164 L2 - 1J-164 L2 (wp03) 424.60 425.00 81.03 8.01 73.02 Pass -Major Risk Plan 1J-166 (L5) - 1J-166 - 1 J-166 (wp03) 400.41 400.00 40.68 7.46 33.22 Pass -Major Risk Plan 1J-166 (LS) - 1J-166 L1 - 1J-166 L1 (wp03} 400.41 400.00 40.68 7.46 33.22 Pass -Major Risk Plan 1J-166 (LS) - 1J-166 L2 - 1 J-166 L2 (wp03) 400.41 400.00 40.68 7.46 33.22 Pass -Major Risk Plan 1J-170 (L4) -Plan 1 J-L4 LatA -Plan 1 J-L4 LatA 650.69 650.00 40.02 12.42 27.60 Pass -Major Risk Plan 1J-174 (01) -Plan 1 J-01 B Lat -Plan 1 J-01 B Lat 250.99 250.00 120.56 4.87 115.69 Pass -Major Risk Plan 1J-175 (A-Kup) - 1J-A (KUP) - 1J-A (KUP) Ver# 655.64 650.00 140.55 12.50 128.05 Pass -Major Risk Plan 1J-176 (02) -Plan 1J-02 B Lat -Plan 1J-02 B Lat 301.01 300.00 160.68 5.80 154.88 Pass -Major Risk Plan 1J-178 (03) -Plan 1J-03 B Lat-Plan 1J-03 B Lat 301.02 300.00 200.84 5.80 195.04 Pass -Major Risk Plan 1J-179 (B-Kup) - 1J-B (KUP) - 1J-B (KUP) Ver# 752.54 750.00 214.54 14.52 200.02 Pass -Major Risk Plan 1J-180 {04)-Plan 1J-04 B Lat-Plan 1J-04 B Lat 276.00 275.00 240.39 5.34 235.05 Pass- Major Risk WSP-03 -WSP-03 -WSP-03 371.22 375.00 228.81 9.86 218.95 Pass -Major Risk WSP-04 -WSP-O4 - WSP-04 360.88 375.00 195.45 7.34 188.11 Pass -Major Risk WSP-05 -WSP-05 -WSP-05 356.68 375.00 181.00 9.07 171.92 Pass -Major Risk WSP-06 -WSP-06 -WSP-06 334.03 350.00 185.93 8.52 177.41 Pass -Major Risk WSP-07 -WSP-07 -WSP-07 380.56 400.00 207.16 11.01 196.15 Pass -Major Risk WSP-08 -WSP-08 -WSP-08 466.67 475.00 244.23 18.54 225.69 Pass -Major Risk WSP-20 -WSP-20 -WSP-20 628.62 625.00 87.10 15.78 71.32 Pass -Major Risk CC -Min centre to center distance or covergent point, SF -min separation factor, ES -min ellipse separation 3/3N2005 2:37:14PM Page 3 of 155 COMPASS 2003.11 Build 48 g; ,~ ; i A km,a~ n %an: Il-168 (wp08)(Poan I1-168 (L3)/IJ-168) • ~_ O .Y c~ s. c~ a. r~ N t•. a-+ N U O Y ~-1 ,~~.yy~ i~-1 U Measured Depth [ft] - Il-I6R (wpORl --~ IF:112, II 112. IG 112 VI --- IF'-I 12. ICI 121.1. IE-1121.1 VfF--~ IL-112, Iti-1121.2.11; 1121.2 V~ 11.-126. IF: 126. IF:-121, VI - 11 126. If:INL1. If 1261.1 Vi- IF: 126.IGI261.2. 1111261.2 Vt- IF ;i. IF li. IF:75 VI II J>. II~: 3iA. Ih:-35A (wpf12/V - IJ-I(r. IJ-I(1, I1-111 V7 WSI'-frt. WSP-03. WSP-<13 VI W'SP-(14. WSP-04. WSP-Ib VI WSP-Ili. WSP-115, W'SP-Oi VI W'SP-(Ni, WSP-(W. WSP-IK VI '- WSP-07. WSP-r17. WSP-(17 VI ~ WSP-IIR, W'SP-(18. WSP-OR VI WSP-2f1. WSP-2U. WSP-111 VI Ir1 -168 Drillin 13 1/2" Onen Hole / 10 3/4" Casino Interval mm Hazard Risk Level Miti ation Strate Broach of Conductor Low Monitor cellar continuously during interval. Gas Hydrates Low Control drill, Reduced pump rates, Reduced drilling fluid temperatures, Additions of Driltreat. Running Sands and Moderate Maintain planned mud parameters, Gravels Increase mud weight, use weighted swee s. Hole swabbing on trips Moderate Trip speeds, Proper hole filling (use of trip sheets , um in out 9 7/8" Onen Hole ! 7 5/8" Casing Interval Hazard Risk Level Miti ation Strate Running Sands and Moderate Maintain planned mud parameters, Gravels Increase mud weight, use weighted swee s. Stuck Pipe Low Good hole cleaning, Pretreatment 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" Ouen 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 0 ener, Decreased mud wei ht Lost Circulation Moderate Reduced um rates, Mud rheolo ,LCM Hole Swabbing on Trips Low Trip speeds, Proper hole filling (use of trip sheets , Pum in out 1J-168 Drilling Hazards Summary prepared by Shane C/oninger 4/412005 2:41 PM ~~ • .. CemCADE Preliminary Job Design 10 3/4" Surface Preliminary Job Design based on limited input data. For estimate purposes only. Rig: Doyon 141 Location: West Sak Client: Phillips Alaska, Inc. Revision Date: 3/28/2005 Prepared by: C. Akwukwaegbu Location: Anchorage, AK Phone: (907) 263-4247 Mobile: (907) 830-8168 email: cakwukwaegbu@slb.com < TOC at Surface Previous Csg. < 20", 91.5# casing at 118' MD >,,j < Base of Permafrost at 1,855' MD (1,509' TV D) ,l < Top of Tail at 2,755' MD < 10 314", 45.5# casing in 13 1/2" OH TD at 3,555' MD (2,118' ND) Mark of Schlumberger Schlumberger 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 2,755' MD. Lead Slurry Minimum pump time: 240 min. (pump time plus 90 min.) ARCTICSET Lite @ 10.7 ppg - 4,45 ft3/sk 1.3644 ft3/ft x (118) x 1.00 (no excess) = 161 ft3 0.3637 ft3/ft x (1855 - 118) x 3.50 (250°/d excess) = 2211.1 ft3 0.3637 ft3/ft x (2755 -1855 ~ x 1.35 (35% excess) = 441.9 ft3 161 ft3 + 2211.1 ft3+ 441.9 ft = 2814 ft3 2814 ft3/ 4.45 ft3/sk = 632.4 sks Round up to 640 sks Have 290 sks of additional Lead on location for Top Out stage, if necessary. Tail Slurry Minimum pump time: 160 min. (pump time plus 90 min.) DeepCRETE @ 12.0 ppg - 2.52 ft3lsk 0.3637 ft3/ft x (3555 - 2755) 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/ 2.52 ft3/sk = 173 sks Round up to 180 sks BHST = 46°F, Estimated BHCT = 63°F. (BHST calculated using a gradient of 2.6°F/100 ft. below the permafrost) PUMP SCHEDULE Stage Cumulative Stage Pump Rate Volume Stage Time Time (bpm) (bhll (min) r~,~n- CW100 5 50 10.0 10.0 MudPUSH II 5 50 10.0 20.0 Drop Bottom Plug 15.0 35.0 Lead Slurry 7 507 72.4 107.4 Tail Slurry 6 81 13.5 120.9 Drop Top Plug 8.0 128.9 Displacement 7 319 45.6 174.5 Slow Rate 2 15 7.5 182.0 MUD REMOVAL Recommended Mud Properties: 9.6 ppg, Pv < 15, TY < 15. As thin and light as possible to aid in mud removal during cementing. Spacer Properties: 10.5 ppg MudPUSH* II, Pv = 17-21, TY = 20-25 Centralizers: Recommend 1 perjoint across zones of interest for proper cement placement. ORIGINAL .: CemCADE Preliminary Job Design 7.625" Intermediate Casina Rig: Doyon 141 Location: West Sak Client: ConocoPhillips Alaska Revision Date: 3/28/2005 Prepared by: C. Akwukwaegbu Location: Anchorage, AK Phone: (907) 263-4247 Mobile: (907) 830-8168 email: cakwukwaegbu@slb.com Previous Csg. < 10 3/4", 45.5# Casing at 3,555' MD < Top of Tail at 4,778' MD < 7 5/8", 29.7# casing in 9 7/8" OH TD at 8,306' MD (3,483' ND) Mark of Schlumberger Preliminary Job Design based on limited input data. For estimate purposes onry Schlumberger Volume Calculations and Cement Systems Volumes are based on 40% excess. Tail slurry is designed for 3528 shoe tack. Tail Slurry Minimum thickening time: 200 min. (Pump time plus 90 min.) DeepCRETE @ 12.5 ppg - 2.26 ft3/ft 0.2148 ft3lft x 3528 x 1.40 (40°I° excess) = 1060.9 ft3 0.2578 ft3/ft x 80 (Shoe Joint) = 20.6 ft3 1060.9 ft3+20.6 ft3= 1081.5 ft3 1081.5 ft3/ 2.26 ft3/sk = 478.5 sks Round up to 480 sks BHST = 81 °F, Estimated BHCT = 70°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) Ibbq (minj (min) CW100 5 40 8.0 8.0 Drop Bottom Plug 10.0 18.0 MudPUSH II 5 55 11.0 29.0 Tail Slurry 5 193 38.6 67.6 Drop Top Plug 10.0 77.6 Displacement 7 358 51.1 128.7 Slow Rate 3 20 6.7 135.4 MUD REMOVAL Recommended Mud Properties: 9.1 ppg, Pv < 15, TY < 15. As thin and light as possible to aid in mud removal during cementing. Spacer Properties: 10.2 ppg MudPUSH* II, Pv = 19-22, TY = 22-29 Centralizers: Recommend 1 per joint across zones of interest for proper cement placement. ORIGINAL 10-3/4" Casing, L-80, ` BTC set @ +l- 3555' MD, 2118' TVD, 13-1/2" hole Tubing String: 4-1/2" 12.6#, L-80, IBTM, ConocoPhillips Spec. Clearance Couplings, (4.920" OD) West Sak 1J-168 Producer 7-5/8" Tri-Lateral Completion ~ (2) Gas Lift Mandrels, 4-1/2" X 1" Electric Submersible Pump, Centralift 418 HP Motor, FC6000 WL Deployed Pump D-sand Window at+/- 6835' MD, 322x' TvD 'D' Sand Lateral 5-112" X 7-5/8" Model 'B' HOOK Hanger 4-1/2" 12.6#, L-80, Slotted Liner 6-3/4" Lateral TD @ 12942' MD, 3453' TVD 5-112" X 7-5I8" ZXP Liner Top Packer with Hold Downs Lateral Entry Module (LEM- ,,., Assembly .--- 5-112" X 7SI8" ZXP Liner Top Packer with Hold Downs Casing Sealbore Receptacle 4.75" ID Tubing Swivel, 4-112" Orienting Profile Automatic Alignment of LEM - Positive Latching Collet Indicates Coned Location ~ Seal Bore for Lateral Isolation - 3.68" ID ~ Access window Positive Lateral Access Via Thru-Tubing Diverter Seal Bore for Lateral Isolation - 3.68" ID Isolation Seal Asembly 4.75" Seal OD 3.875" Seal ID Casing Sealbore Receptacle 4-1/2" X 7-5/8" Model'B' HOOK Hanaer * Ensure LEM ` Position #1 is used. Tubing, 4112" 12.6#, from LEM to A2 Liner, w/ seal stem and 3.562" DB Nipple B-sand Window at +/- 7185' MD, 3310' TVD 5-112" X 7SI8" ZXP Liner Top Packer with Hold Downs Liner Hanger /Packer s-1/2'• x Assembly Top at L;, +l- 7261' MD, 3323' TVD BAKER • Nuexes Baker Oil Tools With Diverters and Isolation Lateral Access Diverter Lateral Isolation Diverter GS Running Tool String Installed Installed (3.00" Lateral Drift) (2.50" ID Mainbo re Drih) 'GS' Profile for Coil Connector ~ f Running/Retdevng ~ (1.00' Length) I Snap In/Snap Out d PosRive Locating ~ r Back Pressure Valve C llet (1.60' LengM) I o ~' - Fbw-Thru Swivel Lateral IsoWtion Seals (1.2s' LengM) H draulic f Lateral Diverter Ram i ~ y p D ' Isolatbn/Maintrore~ (1 .50 Leng ) Diverter Sleeve 1 _,-GS Spear ~~ ~ I (1.50' Length) Lateral IsoWtion Seals 6.85 ft Approx. OAL' I,, I 'Jars may be required n hghy deviated 18.5' Diverter Length 18.5' Sleeve LengM ~ ' or deep applications (6' approx kng M). t 'B' Sand Lateral 4-112" 12.6#, L-80, Slotted Liner 3.562" DB Nipple Lock Casing, 7-5/8" 29.7#, L-80, BTCM, Set @ +/- 8306' MD, Baton Hughes 4g W. TM1n tlocumentmry not be reprotlucM Or Cistribw,J.in xAolen mpntJn any lmm~ 3483' TvD, Set @ 80 deg, by any means Nectromc or mechanical, inclutling photocopying. recording, or by a,ry informaEOn sbrage antl retrieval system now Mnoxn or hereafter inventetl, wiMOUt written pemnissian hom BaMerHUghes Inc. 9-7/8r, HoIQ, 6-3/4" Lateral TD @ 12952' MD, 3512' TVD ~os-o6`b ~ 'A' Sand \ Undulating Lateral 4-112" 12.6#, L-80, slots over sand, blank over shales, constrictors for isolation 12975' Equipment Specifications 4-112" X 7-518" HOOK Hanger Mainbore Drift: 5.32" Mainbore Drift, with diverter: 4.63" Laterel Drift, no diverter or LEM: 3.88" Lateral Drift, w/diverter, no LEM: 3.88" Lateral/Mainbore Diverter OD: 6.75" 4-1/2" Lateral Entry Module Mainbore Drift: 3.65" Mainbore Drift, cal isolation sleeve: 2.50" Lateral Drift, w/coil diverter: 3.00" OD of Diverter and Sleeve: +/- 3.89" Diverter and Sleeve Length: +l- 18.5' TD @ B' TVD. 1J-168 Tri-lateral Completion -Producer Drawn BY: Revision No.: 2005 Marc D. Kuck 0 f } 1 z8 \ E bltPF3 1E- ~ 1 -31 1E 115 '09 1L-28 tE-36 ` ~ 1 E-32 •.. --. 1L-2a4 1 1L-z1oPN 4I f0 1E-~z ~ fo-12~z; 10-131 to-t a4 t -22 1D-12~ 1D-0' \ t E-1 p5P81 ~~- 2 1, ., ~~,` tE-34 1~-1®~ 'fit' ~~=t~"a ~, .. 11 1J-168 /Slotted Liner 1 E-JS s ~ 10 38 1 t ~-OB n®--na". KRU 1 J-168 Proposed,1-Oil West Sak A Sand 2050600 Confidential wells are red SFD 411312005 ttooo t o000 34 35 ~._ t ~~. 9000-... ,, ` 1 ~,. 8000 ~~` ! - ~.~~/,- -~-~, ,,_ 1000 O ~- Y5P-3 fE-117L.P r0~ O ty~ ''-`i6,j~r~!"j -11 u7 lr5 ~ P-1 4A~ ~3P-13 Q ~ 4F~P-14 1 J-1 SOLI T11N, R10E, UM T10N, R11 E, UM FFFt q 1 ;~qC~ 2;ggq 3~g00 4,g0q _.. __ _~ 1100 SHARON K. ALLSUP-DRAKE CONOCOPHILLIPS ~~- Z~p~ s2-ta1311 ATO1530 oaTE 7 700 G ST. ` ANCHORAGE AK 99501 ~ ~~ PAY TOTHE f D~ ~' ` ~" ORDER OF ot" OT " l p, s..a ..~.. ; ~d C2 ~-J" ppLLARS W ba~;.o.AK. w _~' a Chase Manhattan Bank USA, N.A. Valid UQ TO 5000 ~Olla(S ; . 'W` '~, CHASE r.. Newark, DE 19111 /^') ' r 200 While Clay Center D - ,i~- / ___(/'/j/_/Y//~______- MEMO J III • ^ 0 0 x:03 L BOO L44~:2 La47 L9079 276 , _ --- ..._::_ .. • • • TRANSMITAL LETTER CHECK LIST CIRCLE APPROPRIATE LETTER/PARAGRAPHS TO BE INCLUDED IN TRANSMITTAL LETTER WELL NAME K/~C,C /~/ - jG PTD# ~~ --~ ~~ Development Exploration Service Stratigraphic CHECK WAAT ADD-ON5 "CLUE"~ APPLIES (OPTION MULTI The permit is !or a new wellbore ~segmeni of LATERAL existing well ~ . Permit No, ~ API No. (If API number Production. should continue to be reported as last two. (2) digits a function'of the original API number stated are between 60-69) above. PILOT 1:IOLE In accordance with 20 AAC 25.005(f), all (PIS records, data and logs acquired for the pilot bole must be clearly differentiated 'in both name (name on permit plus PIS and API Dumber (50 - ~0/80) lrom records, data and logs acquired for well (name oa permit). SPACING The permit is approved subject •to full EXCEPTION compliance ~viib 20 AAC 25.055. Approval 10 perforate and produce is contingent upon issuance o! a coaservation order approving a spacing ~ eaception. ~Companv Name) assumes the liability of any protest to the spacing ,eaception that may occur. DRY DITCH All dry ditch sample sets submitted to the SAMPLE Commission must be in no greater than 30' sample intervals from below ibe permafrost or from where samples are first caught and l0' sample intervals through target zones. WELL PERMIT CHECKLIST Field & Pool KUPARUK RIVER, WEST SAK OIL - 490150 Well Name: KUPARUK RIV U WSAK iJ-168 Program DEV Well bare seg ^ PTD#:2050600 Company CONOCOPHILLIPS ALASKA INC Initial ClasslType DEV 1 PEND GeoArea 890 Unit 11160 On/Off Share On Annular Disposal ^ Administration 1 Petinit.feeattached_-_---_____________________________ _________Yes____-- _____-_--__-_________-_-_ - - ' 2 Lease number appropriate- - - - . _ Yes Surface loco-lion in ADL 025661; topproductive interval and_TD_in ADL 025.660. - - - - _ . - 3 tJniquewell_nameandnumber_____________________________ _________Yes_--_-- _---..._--_.-._--._- 4 Well located in a_d_efnedpool- _ _ _ - Yes KRU West_Sak_O_il Pool,governed-by Conservation_Order_No, 406B- _ - - _ - 5 Well located proper distance-from drilling unit-boundary_ . - _ - - _ - _ - Yes Well is more_ than_ 500 feet from an extemaf property line, - - _ _ 1 6 Well locatedpcoperdistance-from other wells_____________________ _________Yes_____- -No restrictionsas_towellspacinginCO-406B.__-_--.-_ ___---__----._-__----_---.-_ 7 Sufficient acreage available in drilling unit- _ - - - Yes _ - - No restrictions as to well spacing except that no_pay shall be opened in a well closer 8 If deviated, is wellbore plat included Yes - _ . _ - _ _ - than 500 feet to an external ro ert line P p y - - 9 Operator only affectedparty_____-- __Yes------ -------------- 10 Operator has-appropriatebondinf4rce...-_---_-._----------- ---------Yes__.-__ _-----.-_- 11 Permit can be issued without conservation order Yes Appr Date 12 Permitcanbeissuedwithoutadministrative-appr_oyal________________ _________Yes__---. --_-_-__----.._--__- SFD 4!1212005 13 Can permit be approved before 15-day wait Yes 14 Well located within areaand_strataauthorizedby_InjectionOrder#(putl9#incomments)-(Fpr_NA___---- -_-----------------------------------------_--.._----.--___--_____ 15 All wells-within 114.mile area of review identified (For service well only) _ ___ _ _ _ _ _ _ _ _ _ _ _ NA ... _ _ _ - _ . . 16 Pre-produced injector; duration ofpre-production Less than. 3 months_ (For service well only} - - NA_ - _ _ - - _ -- - - - -- 17 AC_M_P-Finding of Consistency-has been issued-for_this project- - - - _ - - NA_ _ - ACMP determination_n_oJonger_a_ffects AOGCC approval_of permit to drill._ _ - - - _ - - - - - Engineering 18 Conducto[st[ing_provided-------------------_-__.__-.- ---_-_..Yes__-_ _-____._ 1 19 Surface casing_protects alLknown USDWS - - - - .. - . - NA_ - - - - - - All aquifers exempted, 40 CFR 147.1 Q2-(b)(3).- - _ _ - _ _ 20 CMT_vol_adequate_tocirculate_onconductor_&surf_csg__ ___________ ___-_____Yes--____ -__-_--__--_-___--_____ - - - 21 CMT_vol_ adequate-to tie-in long string to su _rf csg_ _ _ - _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ __ _ _ No_ - . - _ _ _ All hydrocarbon zones_planned.to be covered._ - - - _ _ _ _ - _ - - _ _ _ _ _ - _ - - _ _ - _ - - _ - _ _ _ - - _ _ _ _ _ - 22 CMT_Will cover all known-productive horizons- - - _ _ - _ - No_ _ _ - _ _ Slotied liner completion planned, _ _ _ 23 CasingdesynsadequateforC,_T,B&_permafcost------.---------- -- _----Yes------ ------------------------------- --.---------------.------- 24 Adequate tankage_or reserve pit _ - - - _ _ - Yes - - - - -Rig isequippe_d with steel-pits. No reserve-pitplanned, All waste to.approved annulus or disposal wells, - - - - 25 If_a_re-drill, has-a 1.0-403 for abandonment been approved _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ NA_ _ - _ _ _ - _ - - _ _ _ 26 Adequate wellbore separation-proposed___ _ _ _ _ _ _ _ ___ _ _ _ _ _ _ _ ___ _ _ _ _ _ _ _ _ _ _ Yes - .... - -Proximity analysis performed. Ng wells_proximate at this time. _ _ , _ _ _ _ _ _ . _ _ _ _ _ _ _ , . _ _ _ _ _ _ _ . _ _ _ _ i 27 If_diverterrequited,doesitmeetregu_lotions------_-------------- ---------Yes___-- _---___--_______--_--_ ---------------------------------------------- Appr Date ! 28 Drilling fluid-grogram schematic-~ equip listadequate_ _ _ - - _ - - _ -Yes Maximum expected formatipn pressure 9,0-EMW._ Planned mud weight, up to 9,0-in West Sak__ _ _ _ _ _ _ _ _ _ _ _ TEM 411412005 1 29 B_O_PEs, do they meet-regulation - - - - - Yes - - - - - - - - - - - - - - - ~C~A ,_` 30 BOPS-press rating appropriate; test to_(put prig in comments)_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _Yes _ . - _ - - _ MASP calculated at 1134 psi. 3000-psi_appr_opriate. CP_AI normally tests_to 5000_psi. _ _ _ _ _ - - _ _ _ - - _ - _ _ - ~ 31 Choke_manifoldcomplieswlAPl_RP-53(May84)------------------- ---------Yes-,--- ------------------------------------.----------------------------- 32 Work willoccur-withoutoperationshutdown_____________________ -__---___Yes..___- -.-_.-_ ------------------------------------------------------------- 33 Is presence of H2S gas_probable.. - - - - - _ _ - - - _ .. - - _ - - - - - - Na- - No produckion_on-pad, butH2$hasnot been reported in WS production, -Rig has sensors and alarms, 34 Mechanical_condition of wells within AOR verified (Forservice well only) _ _ _ - - - - NA_ _ - - _ Geology 35 Permit_can be issued wlohvdrogen-sulfide measures - - - - - - - - - - - - - - - - - -- - Yes _ - _ - - - 36 Data-presented on potential overpressure zones- - _ - _ _ _ - - _ - -Yes - - - - -Expected resen!oirp[essure i_s 8,6 - 9,0_ppg EMW; will_be drilled with 9.0 ppg mud. _ - _ _ - - _ _ - _ _ Appr Date 37 Seismicanalysisofshallowgas_zones------------------------- ---___-NA_--____ __---__-_-- SFD 4!12!2005 38 Seabed condition survey_(if off_-shore} - - - _ _ - . - - - _ _ . _ 39 - Contact namelphone for weekly progress_reports [exploratory only] - _ _ _ - _ - _ - - NA_ _ _ _ _ - _ - - _ _ _ - - Geologic Engineering is Date D t ' D t Commissioner: a e: Commissioner. mi ner a e ~ ~/~lS ~ ~ iy~s ~/~ a,~" • Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well Nistory file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. • Sperry-Sun Drilling Services LIS Scan Utility $Revision: 3 $ LisLib $Revision: 4 $ Wed Jan 25 08:57:24 2006 Reel Header Service name ........ .....LISTPE Date ................ .....06/01/25 Origin .............. .....STS Reel Name ........... .....UNKNOWN Continuation Number. .....01 Previous Reel Name.. .....UNKNOWN Comments ............ .....STS LIS Writing Library Tape Header Service name ........ .....LISTPE Date ................ .....06/01/25 Origin .............. .....STS Tape Name ........... .....UNKNOWN Continuation Number. .....01 Previous Tape Name.. .....UNKNOWN Comments ............ .....STS LIS Writing Library Physical EOF 13443 X705-DInD Scientific Technical Services Scientific Technical Services Comment Record TAPE HEADER West Sak MWD/MAD LOGS WELL NAME: 1J-168 API NUMBER: 500292326000 OPERATOR: ConocoPhillips Alaska, Inc. LOGGING COMPANY: Sperry Drilling Services TAPE CREATION DATE: 24-JAN-06 JOB DATA MWD RUN 3 MWD RUN 4 MWD RUN 5 JOB NUMBER: MW0003877631 MW0003877631 MW0003877631 LOGGING ENGINEER: T. GALVIN T. GALVIN P. ORTH OPERATOR WITNESS: M. THORTON M. THORTON D. GLADDEN MWD RUN 6 JOB NUMBER: MW0003877631 LOGGING ENGINEER: P. ORTH OPERATOR WITNESS: D. GLADDEN SURFACE LOCATION SECTION: 35 TOWNSHIP: 11N RANGE: l0E FNL: FSL: 1841 FEL: 2499 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 3693.0 2ND STRING 6.750 7.875 8224.0 3RD STRING PRODUCTION STRING REMARKS: LJ 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 3-6 COMPRISED DIRECTIONAL, DUAL GAMMA RAY (DGR) UTILIZING GEIGER- MUELLER TUBE DETECTORS, ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4), AND PRESSURE WHILE DRILLING (PWD) MWD RUNS 3,4,6 ALSO INCLUDED GEO-PILOT ROTARY STEERABLE BHA (GP). 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 - 6 REPRESENT WELL 1J-168 WITH API#:50-029-23260-00. THIS WELL REACHED A TOTAL DEPTH (TD) OF 12995'MD / 3654'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. 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...... .06/01/25 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 RPD 3662.0 12944.5 RPS 3662.0 12944.5 RPM 3662.0 12944.5 FET 3662.0 12944.5 RPX 3662.0 12944.5 GR 3670.0 12937.5 ROP 3704.5 12994.5 BASELINE CURVE FO R SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH MERGED DATA SOURCE PBU TOOL CODE BIT RUN NO MERGE TOP MERGE BASE MWD 3 3662.0 5642.0 • • MWD 4 5642.0 6205.0 MWD 5 6205.0 8229.0 MWD 6 8229.0 12995.0 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 3662 12994.5 8328.25 18666 3662 12994.5 RPD MWD OHMM 0.94 .2000 35.5904 18566 3662 12944.5 RPM MWD OHMM 3.28 2000 28.9024 18566 3662 12944.5 RPS MWD OHMM 2.89 2000 23.6767 18566 3662 12944.5 RPX MWD OHMM 0.48 2000 23.8545 18566 3662 12944.5 FET MWD HOUR 0.12 71.78 1.59992 18566 3662 12944.5 GR MWD API 24.54 118.68 72.2101 18536 3670 12937.5 ROP MWD FT/H 1.03 679.83 173.455 18581 3704.5 12994.5 First Reading For Entire File..........3662 Last Reading For Entire File...........12994.5 File Trailer Service name ............ .STSLIB.001 Service Sub Level Name.. . Version Number.......... .1.0.0 Date of Generation...... .06/01/25 Maximum Physical Record. .65535 File Type ............... .LO Next File Name.......... .STSLIB.002 Physical EOF File Header Service name........... Service Sub Level Name. Version Number......... Date of Generation..... Maximum Physical Record File Type .............. Previous File Name..... .STSLIB.002 .1.0.0 .06f01/25 .65535 .LO .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 RPD 3662.0 5600.0 RPM 3662.0 5600.0 RPX 3662.0 5600.0 RPS 3662.0 5600.0 FET 3662.0 5600.0 GR 3670.0 5607.5 ROP 3704.5 5642.0 LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: 20-AUG-OS Insite 66.37 Memory 5642.0 3704.0 5642.0 65.5 71.7 TOOL NUMBER 149206 66259 9.875 3693.0 LSND 9.10 52.0 9.3 250 5.0 3.800 68. 0 2.910 91. 0 4.800 68. 0 3.250 68. 0 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 3662 5642 4652 3961 3662 5642 RPD MWD030 OHMM 0.94 2000 41.1991 3877 3662 5600 RPM MWD030 OHMM 3.28 1809.23 18.3042 3877 3662 5600 RPS MWD030 OHMM 5.7 1112.47 14.3103 3877 3662 5600 RPX MWD030 OHMM 0.48 40.61 13.3675 3877 3662 5600 FET MWD030 HOUR 0.12 59.83 1.7642 3877 3662 5600 GR MWD030 API 24.54 118.68 65.9548 3876 3670 5607.5 ROP MWD030 FT/H 1.46 679.83 195.606 3876 3704.5 5642 First Reading For En tire File... .......3662 Last Reading For Ent ire File.... .......5642 File Trailer Service name ..... ........STSL IB.002 Service Sub Level Name... Version Number... ........1.0. 0 Date of Generation.......06/01/25 Maximum Physical Record..65535 File Type ........ ........LO Next File Name... ........STSL IB.003 Physical EOF File Header Service name .............STSLIB.003 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/01/25 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 5600.5 6159.5 FET 5600.5 6159.5 RPM 5600.5 6159.5 RPD 5600.5 6159.5 RPS 5600.5 6159.5 GR 5608.0 6167.5 ROP 5642.5 6205.0 LOG HEADER DATA DATE LOGGED: 23-AUG-OS SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 66.37 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT) 6205.0 TOP LOG INTERVAL (FT) 5642.0 BOTTOM LOG INTERVAL (FT) 6205.0 BIT ROTATING SPEED (RPM): • • HOLE INCLINATION (DEG MINIMUM ANGLE: 66.4 MAXIMUM ANGLE: 70.8 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 124725 EWR4 ELECTROMAG. RESIS. 4 121079 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) 9.875 DRILLER'S CASING DEPTH (FT) 3693.0 BOREHOLE CONDITIONS MUD TYPE: LSND MUD DENSITY (LB/G) 9.10 MUD VISCOSITY (S) 57.0 MUD PH: 8.9 MUD CHLORIDES (PPM): 300 FLUID LOSS (C3) 4.4 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT) 3.800 68.0 MUD AT MAX CIRCULATING TERMPERATURE: 3.310 79.0 MUD FILTRATE AT MT: 4.800 68.0 MUD CAKE AT MT: 3.250 68.0 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 Mi n Max M ean Nsam Reading Reading DEPT FT 5600 .5 6205 590 2.75 1210 5600.5 6205 RPD MWD040 OHMM 9. 51 19.25 14. 1124 1119 5600.5 6159.5 RPM MWD040 OHMM 8. 72 20.31 13. 8028 1119 5600.5 6159.5 RPS MWD040 OHMM 7. 97 20.93 13. 6461 1119 5600.5 6159.5 RPX MWD040 OHMM 7. 67 20.72 13. 4856 1119 5600.5 6159.5 FET MWD040 HOUR 0. 19 60.1 5. 1829 1119 5600.5 6159.5 GR MWD040 API 28. 83 103.96 65. 2015 1120 5608 6167.5 ROP MWD040 FT/H 11. 54 552.69 145 .563 1126 5642.5 6205 First Reading For Entire File..........5600.5 Last Reading For Entire File...........6205 • • File Trailer Service name............ Service Sub Level Name.. Version Number.......... Date of Generation...... Maximum Physical Record. File Type ............... Next File Name.......... Physical EOF .STSLIB.003 .1.0.0 .06/01/25 .65535 .LO .STSLIB.004 File Header Service name .............STSLIB.004 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/01/25 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 RPS 6160.0 8174.5 FET 6160.0 8174.5 RPM 6160.0 8174.5 RPX 6160.0 8174.5 RPD 6160.0 8174.5 GR 6168.0 8182.0 ROP 6205.5 8229.0 LOG HEADER DATA DATE LOGGED: 24-AUG-O5 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 66.37 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT) 8229.0 TOP LOG INTERVAL (FT) 6205.0 BOTTOM LOG INTERVAL (FT) 8229.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 70.8 MAXIMUM ANGLE: 84.6 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 124725 EWR4 ELECTROMAG. RESIS. 4 121079 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) 9.875 DRILLER'S CASING DEPTH (FT) 3693.0 BOREHOLE CONDITIONS MUD TYPE: LSND MUD DENSITY (LB/G) 9.10 MUD VISCOSITY (S) 49.0 MUD PH: 9.0 MUD CHLORIDES (PPM): 300 FLUID LOSS (C3) 4.5 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT) 3.700 70.0 • MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format Specification Record Data Record Type .................. 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 2.560 109.4 4.650 70.0 3.150 70.0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 RPD MWDO50 OHMM 4 1 68 4 2 RPM MWDO50 OHMM 4 1 68 8 3 RPS MWDO50 OHMM 4 1 68 12 4 RPX MWDO50 OHMM 4 1 68 16 5 FET MWDO50 HOUR 4 1 68 20 6 GR MWDO50 API 4 1 68 24 7 ROP MWDO50 FT/H 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 6160 8229 7194.5 4139 6160 8229 RPD MWDO50 OHMM 4.33 320.38 32.1865 4030 6160 8174.5 RPM MWDO50 OHMM 3.47 274.99 29.4328 4030 6160 8174.5 RPS MWDO50 OHMM 2.89 235.42 26.2321 4030 6160 8174.5 RPX MWDO50 OHMM 2.37 166.05 21.2623 4030 6160 8174.5 FET MWDO50 HOUR 0.21 13.37 0.952499 4030 6160 8174.5 GR MWDO50 API 25.85 107.52 73.9443 4029 6168 8182 ROP MWDO50 FT/H 4.62 679.78 186.825 4048 6205.5 8229 First Reading For Entire File..........6160 Last Reading For Entire File...........8229 File Trailer Service name .............STSLIB.004 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/01/25 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..... ..06/01/25 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 8175.0 12944.5 RPX 8175.0 12944.5 RPS 8175.0 12944.5 RPD 8175.0 12944.5 FET 8175.0 12944.5 GR 8182.5 12937.5 ROP 8229.5 12995.0 LOG HEADER DATA DATE LOGGED: 30-AUG-OS SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 66.37 DATA TYPE (MEMORY OR REAL-TIME) : Memory TD DRILLER (FT) 12995.0 TOP LOG INTERVAL (FT) 8229.0 BOTTOM LOG INTERVAL (FT) 12995.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 81.5 MAXIMUM ANGLE: 93.1 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 178513 EWR4 Electromag Resis. 4 159439 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) 6.750 DRILLER'S CASING DEPTH (FT) 8224.0 BOREHOLE CONDITIONS MUD TYPE: Oil Based MUD DENSITY (LB/G) 9.00 MUD VISCOSITY (S) 80.0 MUD PH: .0 MUD CHLORIDES (PPM): 33000 FLUID LOSS (C3) 3.6 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATU RE (MT) .000 .0 MUD AT MAX CIRCULATING TE RMPERATURE: .000 116.6 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 Specificat ion 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 8175 12995 10585 9641 8175 12995 RPD MWD060 OHMM 2.41 2000 37.2683 9540 8175 12944.5 RPM MWD060 OHMM 4.54 2000 34.7565 9540 8175 12944.5 RPS MWD060 OHMM 3.29 2000 27.5803 9540 8175 12944.5 RPX MWD060 OHMM 4.52 2000 30.4276 9540 8175 12944.5 FET MWD060 HOUR 0.21 71.78 1.38638 9540 8175 12944.5 GR MWD060 API 48.31 117.36 74.85 9511 5182.5 12937.5 ROP MWD060 FT/H 1.03 302.19 162.058 9532 8229.5 12995 First Reading For Entire File..........8175 Last Reading For Entire File...........12995 File Trailer Service name .............STSLIB.005 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/01/25 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.006 Physical EOF Tape Trailer Service name .............LISTPE Date .....................06j01/25 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 .....................06/01/25 Origin ...................STS Reel Name ................UNKNOWN Continuation Number......01 Next Reel Name...........UNKNOWN Comments .................STS LIS Writing Library. Scientific Technical Services Physical EOF Physical EOF End Of LIS File