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207-016
Image Pect V1/ell Hist®ry File r 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. ~~ ~ - ~ ~ ~ Well History File Identifier Organizing (done) ~wo-sided III IIIIII II III II III ^ Rescan Needed III II~II) 0II III III RESC DIGITAL DATA OVERSIZED (Scannable) olor Items: iskettes, No. ~ ^ Maps: ^ Greyscale Items: ^ Other, No/Type: ^ Other Items Scannable by a Large Scanner ^ Poor Quality Originals: ^ Other: NOTES: 8Y: Maria ~ Date: Project Proofing BY: Maria Date: Scanning Preparation ~~ x 30 = BY: Maria ~ Date:. Production Scanning Stage 7 BY: Stage 1 BY: OVERSIZED (Non-Scannable) ^ Logs of various kinds: ^ Other:: /s/ /s/ + =TOTAL PAGES--~ I- (Count does not include cover sheet) "1 /s/ Page Count from Scanned File: _C~j,~ (Count does include cover sheet) Page Count Matches Number in Sc11ann,'ing Preparation: .J~ rES NO Maria Date: ~zj 1~~ ~ ~ /s/ If NO in stage 1, page(s) discrepancies were found: YES NO Maria Date: /Shin^iu~uu ~1~11 Scanning is complete at this point unless rescanning is required. Rescanned III IIIIIIIIIII IIIII BY: Maria Date: ~s~ Comments about this file: Quality Checked III II~III III IIII III 1016/2005 Well History File Cover Page.doc STATE OF ALASKA ALASOIL AND GAS CONSERVATION COMMION ` REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Abandon F Repair well Plug Perforations Stimulate F Other f7 Matrix Bypass Alter Casing ull Tubing Perforate New Pool Waiver Isolation 9 9 � Time Extension Change Approved Program Operat. Shutdown Re -enter Suspended Well 2. Operator Name: 4. Well Class Before Work: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development r Exploratory % 207 -016 3. Address: 6. API Number: Stratigraphic Service P. O. Box 100360, Anchorage, Alaska 99510 ti 50- 029 - 23344 -60 7. Property Designation (Lease Number): 8. Well Name and Number: 6 ADL 25660, 25661, 25663 1J -1601-1 9. Field /Pool(s): Kuparuk River Field /West Sak Oil Pool 10. Present Well Condition Summary: Total Depth measured 13064 feet Plugs (measured) 11133', 11973', 12200' true vertical 3264 feet Junk (measured) None Effective Depth measured 13054 feet Packer (measured) 8519 true vertical 3264 feet (true vertucal) 3247 Casing Length Size MD TVD Burst Collapse CONDUCTOR 81 20 120 120 SURFACE 3511 13.375 3551 2190 INTERMEDIATE 9110 9.625 9150 3340 B -SAND LINER 4536 4.5 13055 3264 RPOFI DEC 0 9 201 Perforation depth: Measured depth: 8746'- 9213', 9600'- 10152', 10409'- 11010', 11268'- 11911', 12036' - 12041', 12169' -1 015' , True Vertical Depth: 3286'- 3287', 3316'- 3304', 3291'- 3277', 3269'- 3280', 3284'- 4Ak*C nS. o"0110an Tubing (size, grade, MD, and TVD) 4.5, L -80, 8342 MD, 3215 TVD Packers & SSSV t e, MD, and TVD I Zulu ( YP ) HRD ZXP Liner Packer @ MD= 8519 TVD= 3247 NIPPLE @ MD =505 TVD =498 11. Stimulation or cement squeeze summary: Intervals treated (measured): not applicable Treatment descriptions including volumes used and final pressure: 12. Representative Daily Average Production or Injection Data Oil - Bbl Gas - Mcf Water - Bbl Casing Pressure Tubing Pressure Prior to well operation 328 Subsequent to operation 500 13. Attachments 14. Well Class after work: Copies of Logs and Surveys run Exploratory f Development Service Stratigraphic 15. Well Status after work: Oil 17 Gas F WDSPL Daily Report of Well Operations XXXX SPLUG GSTOR WINJ WAG GINJ SUSP 16. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 310 -326 Contact John Peirce (5 265 -6471 Printed Name John Peirce Title Wells Engineer Signature i Phone: 265 -6471 Date 3DAAS DEC 0 9 lZ / Form 10 -404 Revised 10/2010 1 Submit Original Only 1J -160L1 Well Work Summary DATE SUMMARY 11/6/10 PULLED PRONG AND PLUG A DB- NIPPLE @ 8443' RKB. WELL LEFT ✓ SHUT IN. DE -MOB UNIT TO 1 B FOR PRE -RIG PREP.(IN PROGRESS) / 11/8/10 PERFORMED FLUFF & STUFF FCO IN B -LAT TO 11820' CTMD UTILIZING SEAWATER /SAFE LUBE AND BIO ZAN, PERFORATED B -LAT LINER AT 11540'- 11545' RKB WITH HES 2" BIG HOLE 6spf GUN. WELL LEDT SHUT IN, RETURN IN THE AM FOR MBE CEMENT REPAIR. IN PROGRESS 11/9/10 SET 2.5" INFLATABLE CEMENT RETAINER AT 11135' RKB (TOP), P 35 B BLS 8.5ppg ULTRA LITE -CRETE WITH 2.5 ppb CEMNET BELOW RETAINER LEAVING .5 bbls ON TOP. EST. TOP OF CEMENT AT 11 100' RKB. WELL LEFT SHUT IN AND FREEZE PROTECTED TO 2200' TVD WITH DIESEL. TURN OVER TO DSO WITH INSTRUCTIONS NOT TO POI FOR 5 DAYS. (COMPLETE) KUP 0 1J -160L1 ����� Max v. �il �� ' I y �J � - Angle & MD TD Alaska. kv Wellho ' re API /UWI Feld Name Well Status Inc! ( °) MD (ftK8) ACt at. (k KB) W ell ; WEST SAK �INJ � 1 - _._ 13, 064.0 C ent HYS (ppm) Dab IAn elation End D to KB - Grtl (ft) Rig Release Dab weu con @gnn 0pl Lai, RW:', .1f14,?.3?12914JA,4Si..�3.tU?., SSSV NIPPLE Last WO: 43.01 4!10/2007 ^ohemm6c am.a1 Annotation nn Depth (HKB) End Date Aotation Last Mod... End Dab Last Tag Rev Reason: Set L1 CMT Retainer /CMT Plug Imosbor 1 112 8/2 01 0 HANGER, 36 4 CaSIn Strin S i'uTd r ,y ffi8z? Casing D.- iletc. I Stnng O... Strmg ID Top (ftKB) Set Depth If Set Depth (TVD) ... String W1... Str ng ... String Top Thrd IB -SAND LINER 41/2 4 -000 1 8,518.9 13,0550 3.2633 11.60 1.80 BTC CONDUCTOR._ top 40 -121 Top Depth NIPPLE, 508 - - (TVD) Top Intl N-1..NCB) (ftK8) (°) Ibtn Dasaipdon Comment ID (in) GAS LIFT, __.. 8,518.9 3,246.51 79.98 PACKER "HRD" ZXP Liner Top Packer 95/8" (7.50" X 8.42") 7.500 2,280 8,537.3 3,247.2 78.06 NIPPLE "RS" Packoff Seal Nipple 7.00"(6.18" ID x 8.00" OD) - 6.180 SURFACE, 8,540.8 3,248.0 78.12 HANGER FlexLock Liner Hanger 7"x 9 -518" (6.21" X 8.30 ") 6.210 8 - 3,551 5 8,550.6 3,250.2 78.27 XO BUSHING XO Bushing 4.93" ID, 7.66" OD 4.930 SLEEVE 8,552.0 3,250.5 7829 SSE 19047 Casing Seal Bore Ext. 4.75 "ID x 6.27" OD 4.750 8.291 _ -_ 8,571.3 , 3,254.7 78 58 XO BUSHING XO Bushing 3.91" ID, 6.01" OD 3.910 LOCATOR, 13,015.5 3,261.5 86 88 XO 4.5x3.5 X 04 - 1/2" BTC Box x 3 - 1/2" IBT Pin (5.04" Odx 2.992" ID) 2.992 8,342 -- SEALASSV, - _. - Other In Hole . (Wireline retrievable plugs, valves, pumps, fish, etc -) 8,343 - "_ Top Depth _ (TVD) Top Inc] T (_HK, (RKBI (') Descd on _ Comment __ Run Date ID (in) 11,133.0 3,273.6 88.98 CMT INFLA (ABLE CEMENT RETAINER 11/9/2010 0.000 RETAINER 11,973.0 3,280.3 90.05 CMT CEMENT RETAINER PERMANENT 10/31/2009 0.000 RETAINER 12,200.0 3,270.2 93.50 PLUG PERMANENT BRIDGE PLUG IN B- LATERAL 10/292009 0.000 orations & Slots _ Shot Top(rVD) atm(TVD) Dan. T ftK8 Btrn {itl(B) (RK8) , (ftKl _.. _ Zone Date (.h Tn. Command D -SAND LINER - 8,746.0 9,213.0 3,285.7 3,287.0 WS C, WS B, 328/2007 32.0 SLOTS Alternating slotted /solid pipe LEM, 1 J -1601.1 2.5"x.125" slots D - SAND LINER 9,600.0 1Q152.0 3,315.7 3,304.3 WS B, 1J -1601.7 32812007 32.0 SLOTS Alternating slotledlsolid pipe HH, 2.5 "X.125" slots 8,391 -8,657 SLOTS, - -- 8,746 - 9,213 10,409.0 11,010.0 3,291.3 3,276.6 WS B, 1J -1601-1 328/2007 32.0 SLOTS Alternating slotted /solid pipe WHIPSTOCK, - _- 2.5 "x.125" slots 8,750-9,064 S _ TERMEDIATE, - �'^ 41 _ "', ` ;N: 11,268.0 11,911.0 3,269.2 3,279.7 WS B, 1J 1601.7 3128/2007 32.0 SLOTS Alternating lotted/so pe pi 2.5 "x.125" slots 11,540.0 11,545.0 3,271.4 3,271.3 WS B, 1J -16017 11 /82010 6.0 APERF HES 2" Big Hole Gun --..., - 12,036.0 12,041.0 3,284.4 3,283.8 WS B, 1J -1601_1 10/302009 6.0 APERF HES PERF GUN, 60 deg phase 12,169.0 13,015.0 3,272.2 3,261.5 WS B, WS C, WS 328/2007 32.0 SLOTS Alternating slotted /solid pipe B, 11-16011 2.5 "x.125" slots No --��= tes: General &Safety Ens 0 te a Annofat n 4!11/2007 NOTE MULTILAT WELL- 1J -160 (NO PERFS) 1J 160L1(B SAND), 1,1 (l 9 - 6!10/2009 NOTE: VIEW SCHEMATIC W /Alaska Schemat c9 0 SLOTS, I 9,so41o,1sz �- i r 1 ° r i SLOTS, 1o,aos -11,om - CMT RETAINER, - 11,133 11,54(,11,545" __... - •" SLOTS, 11,26&11,911 CEMENT PLUG, 11,143 CMT RETAINER, 11,973 APERF, 12,036 - 12,041 - Mandrel Details _ __ - - - Top Depth Top SLOTS, Port PLUG, 12,200 (TVD) Inc! OD Valve Latch Size TR Run Stn To B (ftK61 ( °) Hake Mpdel (inl Sary T". -- (in) (psi) Run Dab Can... -7 'sf _ 1 2,280.0 1,859.4 70.66 CAMCO KBMG 1 GAS LIFT DMY 8K -5 0.0xi 0.0 6252007 3 �_ -�� 12,169 - 13,015' ' BANND LINER, 8,519 - 13,055 TD (1J- 1 13.064 13.064 _ -___ oai2vt o ~ !tom Schlumberger -DCS 2525 Gambell Street. Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Well Job NO. 5511 Company: Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Kuparuk Log Description Date BL Color CD J-160L7 1J-184L7 3H-0a BAUJ-00016 BAUJ-00014 BDaB-00009 MEMORY INJECTION PROFILE ~'Q MEMORY INJECTION PROFILE N~MOpY LDL 04na10 04/OanO 04n4n0 1 1 1 1 1 1 Please sign antl return one copy of this transmittal to Beth at the above atltlress or fax to (907) 561-8317. Thank you. APR ~ ~ 2(l1~ Ott ~ ~rVee11 Pi6 /°V :tom ~D~ • ~'~. y • • . . ~. ~,, s MICROFILMED 6/30/2010 D O NOT. P LAC E ANY NEW MATERIAL UNDER THlS PAGE C:\temp\Temporary Internet Files\OLK9\Microfilm_Marker.doc ~~~~ STATE OF ALASKA 1 g ~a1$LASKA OIL AND GAS CONSERVATION COMMISSIIIIV MAY REP T OF SUNDRY WELL OPERATIONS ~. Operations Perfo ~ Repair w ell r Plug Perforations ~ Stimulate ~ Other y; Isolated B sand After"~ _ PUII Tubing ~ F~rforate New Pbol ~ Waiver ~ Time Extension Change Approved Program r Operat Shutdow n ~ Perforate ~ Re-enter Suspended Well 2.Operator' Name: 4. Current Well Status: . Permit to Drill Number. ConocoPhillips Alaska, Inc. Development ~ Expbratory ~ 207-016 3. Address: Stratigraphic ~ Service Ni API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-029-23344-60 7. Property Designatio ~ 5 ~/ 8. Well Name and N~mber: ADL 25690, 25663, ~ 1 J-160L1 9. Field/Pool(s): ~ Kuparuk River Field /West Sak Oil Pool 10. Present Well Condition Summary: Total Depth measured 13064 feet Plugs (measured) 8443 true vertical 3264 feet Junk (measured) None Effective Depth measured 13054 feet Packer (measured) 8519 true vertical 3264 feet (true vertucal) 3247 Casing Length Size MD ND Burst Collapse CONDUCTOR 80 20 120 120' 0 0 SURFACE 3511 13.375 3551 2190 0 0 INTERMEDIATE 9110 9.625 9150 3340 0 0 B-SAND LINER 4536 4.5 13055 3264 0 0 Perforation depth: Measured depth: Slots: 8746'-9213;9600'-'10152';10409'-11010';11268'-11911 ;12036'-12041 ;12169'-13015' True Vertical Depth: Slots: 3286'-3287 ;3316'-3304';3291'-3277';3269'-3280 ;3284'-3284';3272'-3262' .~,~+:., ~i j~~ ~~ ~ 2 Tubing (size, grade, MD, and TVD) 4.5, L-80, 8357 MD, 3215 TVD ~ ~ i~ Packers & SSSV (type, MD, and TVD) "HRD" ZXP Liner Top Packer 8519 nd 3247 TVD SSDSV=NIPPLE 505 MD and 498 TVD 11. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 12. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 772 1363 521 Subsequent to operation 862 1437 127 13. Attachments .Well Class after proposed work: Copies of Logs and Surveys run E~loratory ['"~ Development ~ Service . Well Status afterwork: Oil ~ ! Gas [! VVDSPL Daily Report of Well Operations GSTOR ~ WAG r? GASINJ r WINJ ++l SPLUG ['? 16. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or NJA if C.O. Exempt: N/A Contact Bob Christensen/Darrell Humphrey Printed Name of ert D. Ch 'stensen Title Production Engineering Specialist Signature Phone: 659-7535 Date D~ /~~ / Form 10-404 Revised 7/2009 pgpMS -~v i a ~~ /~o ~ ~~/j,/USubmit Original Only • i 1J-160L1 DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary 04/11/10 Injector 1J-160L1 had a B sand MBE to offset producer 1J-158 on March 11, 2010. RAN 3.562" OD PLUG TO ISOLATE THE B-LEM. SET PLUG AT 8443' RKB IN CAMCO DB- 6 PROFILE. RAN 1.875" X 3.5' EQUALIZING PRONG WITH 1-3/8" FISHNECK. SET PRONG IN PLUG AT 8443' RKB. KUP 1J-160L1 ° ~,, ' ConocoPhillips ell Attributes ax An le s MD TD AI,i5k:1. '~": Wellbore APIIUWI Fiele Name Well Status Incl (°) MD (RKB) Mt Btm (RKB) ... 500292334460 WESTSAK INJ 13,064.0 CONDUCTOR, 40-121 NIPPlE, 506 GAS LIFT, z.zeo SURFACE, 5&3,551 SLEEVE-O, 8.291 LOCATOR, 8,342 SEAL ASSV. 8,30.3 Last Tag Rev Reason: SET PLUG Imosbor 4/18/2010 Casin Strin s Casing Description String 0... String ID ... Top (RKB) Sal Depth (t... Sat Depth (TVD) ... String Wt... String ... String Top Thre BSAND LINER 4 1/2 4.000 8,518.9 13,055.0 3,263.7 11.60 L-80 BTC Liner Details Top Depth Nomi... Top (1tKB) (TND) IRKBI Top Incl (°) Item Dascrlptbn Comment ID (In) 8,518.9 3,246.5 79.98 PACKER "HRD" ZXP Lirler Top Packer 9-5/8" (7.50" X 8.42") 7.500 8,537.3 3,247.2 78.06 NIPPLE "RS" PackoH Seal Nippte 7.00" (6.18" ID x 8.00" OD) 6.180 8,540.8 3,248.0 78.12 HANGER FlexLock Liner Hanger T' x 9-5/8" (6.21"X 8.30") 6.210 8,550.6 3,250.2 78.27 XO BUSHING XO Bushing 4.93" ID, 7.66" OD 4.9~ o aco n v ern a 7R 90 FRF 19647 CaSIr10 Seal Bore Ext. 4.75"ID x 6.27" OD 4.750 ID PLUG, 8,493 D-SANO IEM, 8,3N-8.562 D-SAND Hn, 8.3978,657 SLOTS. 8,748-9,213 WHIPSTOCK, 8.750-9,064 rERMEDIATE, __.,2° 41-s,1so - a i SLOTS, 9,60070,152 SLOTS, 1n.4os-11 om s I I sLOrs. 11,268-11 911 CMT RETNNER, 11 973 PERFS. 12.038-12,091 PLUG, 12,200 SLOTS, 12,169-13.015 B-SAND LINER, B 51 B-13.055 TO (1J-1 WLt), 13,061 SIOtS slots GUI SIOR SIOtS Make Velw I Latch Date I Com... RECEIVED ED STATE OF ALASKA NOV 2 0 2009 ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONSka Oil Gas Cons. Commission 1. Operations Performed: Abandon Repair Well Plug Perforations Stimulate Other AnChl mBE Isolation Alter Casing Pull Tubing Perforate New Pool Waiver 111 Time Extension Change Approved Program Operat. Shutdown❑ Perforate Re -enter S spended Well 2. Operator Name: 4. Well Class Before Work: Permit to Drill Number: ConocoPhillips Alaska, Inc. Development Exploratory 207 -016 3. Address: Stratigraphic Service El \6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50- 029 23344 -60 ...7. Property Designation (Lease Number): Sy>�., 8. Well Name and Number: Kuparuk River Field Ku River Oil Pool W 5s'kl aI (A 1 r 1J -160L1 9. Fiekj /Pool(s) 1 ADL 25660, 25663 10. Present Well Condition Summary: Total Depth measured 13064' feet Plugs (measured) 11973', 12200' feet true vertical 3264' feet Junk (measured) feet Effective Depth measured 13054' feet Packer (measured) 8519 feet true vertical 3264' feet (true vertical) 3247 feet Casing Length Size MD TVD Burst Collapse Structural CONDUCTOR 80' 20" 120' 120' SURFACE 3511' 13 -3/8" 3551' 2190' INTERMEDIATE 9110' 9.625" 9150' 3340' SLOTTED LINER 4536' 4.5" 13055' 3264' Perforation depth: Measured depth: slots at 8746'- 9213', 9600'- 10152', 10409'- 11010', 11268'- 11911', 12169'- 13015', perfs 12036- 12041' true vertical depth: slots from 3286'- 3287', 3316- 3303', 3291'- 3276', 3269'- 3280', 3272'- 3261', perfs 3284' -3284' Tubing (size, grade, measured and true vertical depth) 4.5" L -80 8357' Packers SSSV (type, measured and true vertical depth) HRD ZXP Liner top pkr @8519', 3247' TVD nipple 505' MD 498' TVD 11. Stimulation or cement squeeze summary: hh�Y Intervals treated (measured) 'i, ✓HIV ESyF N O J 2 7 2009 not applicable Treatment descriptions including volumes used and final pressure: 12. Representative Daily Average Production or Injection Data Oil Bbl Gas Mcf Water Bbl Casing Pressure Tubing Pressure Prior to well operation 480 Subsequent to operation 1350 13. Attachments \k4. Well Class after work: Copies of Logs and Surveys run Exploratory Development Service 0 Daily Report of Well Operations _X 15. Well Status after work: Oil Gas WDSPL GSTOR WAG GINJ WINJ 111 SPLUG 16. 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: 309 -279 Contact John Peirce 265 -6471 Printed Name John Peirce Title Wells Engineer Signature Phone: 265 -6471 Date 11/2.0409 Prepared by Shama Allsup -Drake 263 -4612 Form 10 -404 Revised 7/2009 ,4Q //,23-01 Submi i inal Only /z "o 1J -160 Well Events Summary DATE SUMMARY 10/13/09 ATTEMPT TO PULL PRONG FROM PLUG 8443 CTMD, UNABLE TO PA THROUGH LEM 8398 CTMD, RTN IN A.M. WITH DIFFERENT BHA. 10/14/09 PULLED PRONG FROM DB6 PLUG 8449 CTMD AFTER 2 RUNS, FIRST RUN DROPPED FISH WITH HYD OVERSHOT, SECOND RUN USED S/L SS PULLING TOOL. RTN IN A.M. TO PULL PLUG BODY. 10/15/09 ATTEMPT TO PULL 3.562 DB6 LOCK PLUG BODY FROM NIPPLE 8451 CTMD WITH S/L PRS PULLING TOOL, FIRST RUN UNABLE TO LATCH PLUG BODY, RBIH WITH SAME BHA, APPLIED MORE DOWN WT, LATCHED FISH, PULLED FISH FREE WITH 20K OVERPULL, HUNG UP IN LEM 8398 CTMD, RBIH 10 FT, PICKED UP FREE. SURFACE, PORTED CROSSOVER TO SUCKER ROD HAS PARTED, RTN IN A.M. TO FISH WITH OVERSHOT. 10/16/09 ATTEMPT TO FISH 3.562 DB PLUG BODY PULLING TOOL 8413 CTMD, FIRST RUN WITH 2.31 JDC HYD OVERSHOT, SEEN 5K OVERPULL ONCE, SECOND RUN WITH 2.0 SHORT CATCH OVERSHOT, UNABLE TO LATCH FISH, THIRD RUN WITH 3.50 LIB SHOWED FISH NECK OFF CENTER, RTN IN A.M. WITH MODIFIED SHORT CATCH. 10/17/09 FISH S/L PULLING TOOL WITH 3.562 DB PLUG BODY FROM 8415 CTMD ON SECOND RUN, ALL TOOLS ELEMENTS RECOVERED, WELL IS FREEZE PROTECTED AND SHUTIN. 10/28/09 RUN 2.5" JDN PERFORM FLUFF STUFF WITH SAFE LUBE IN THE B LATERAL TO 12,200' CTMD. IN PROGRESS. 10/29/09 SET BAKER PERMANENT BRIDGE PLUG IN B LATERAL 12,100' CTMD. IN PROGRESS. 1v 10/30/09 SHOT 5' PERF INTERVAL IN B LATERAL FROM 12,036' TO 12,041' RKB USING HES 0 PERF GUN 6 SPF 60 DEG PHASING. PERFORM FLUFF STUFF WITH SAFE LUBE IN B LATERAL FROM 8750' CTMD TO 12050' CTMD. IN PROGRESS. 1 10/31/09 SET BAKER INFLATABLE CEMENT RETAINER IN B LATERAL 11,978' CTMD. 3,/i L- PERFORM GOOD INJECTIVITY THROUGH RETAINER PERFS. PUMP 13 BBLS 6F 8.5 PPG ULTRA LITECREATE CEMENT WITH FIBERS, LEAVING .5 BBL ON TOP OF THE RETAINER.TBG FREEZE PROTECTED WITH DIESEL. JOB COMPLETE. ,,nom t.J NOTE: WELL TO BE LEFT SHUT FOR AT LEAST 7 DAYS TO ALLOW CEMENT TO SET UP. 11'2 •BC am•. KUP 1J -160L1 ConocoPt fillips 'r Well Attributes Max Angle MD 1p Ala.. q WellboreAPUUWI 'Field Name Well Status Inc! IMO (ftKB) Act Btm (ftKB) e" 500292334460 WEST SAK INJECTING 13,064.0 C ent H2S (ppm) Date Annotation End Date KB Grd (ft) Rig Release Data __.i.911_gnig_MU11i(Iq_�Ner�lt_ iJ 1 1.. 19X11/ 70,17;11 AM_ SSSV NIPPLE I Last WO 43.01 4/10/2007 Schenledc Aduel Annotation (Depth (ftKB) End Date Annotation Last Mod ...IE d Date Last Ta o 1 Rev Reason PERF set Permanent Plug in B -Lat Imosbor 10/31/2009 HANGER .36- Casing Strings Casing Description Strip 0... Strip ID... To (ftKB) Set Depth f... Set Depth (ND) Strip Wt... Strip Strip To 9 9 9 'Top I P I P 9 9 I 9 P 8SAND LINER 41/2 i 4000 8,518.9 130550 3,2637 11.60 180 BTC Thrd CONDUCTOR,_ Liner Details 40 -121 Top Depth (TVD) Top Intl NIPPLE, 508 1,, Top (ftKB) (ftKB) Item Description Comment ID (in) GAS LIFT, xt 8,518.9 3246.5 79.98 PACKER "HRD" ZXP Liner Top Packer 9 (7.50" X 8.42 7.500 2.280 8,537.3 3,247.2 78.06 NIPPLE "RS" PackoH Seal Nipple 7 -00" (6.18' ID x 8.00" OD) 6.180 8,540.8 3,248.0 78.12 HANGER FlexLock Liner Hanger 7" x 9 -5/8" (6.21 "X 8.30 6.210 SURFACE, L. 5a -3,551 8,550.6 3,250.2 78.27 X0 BUSHING X0 Bushing 4.93" ID, 7.66" OD 4.930 SLEEVE 0, 8,552.0 3,250.5 78.29 SBE 190-47 Casing Seal Bore Ext. 4.7510 x 6.27" OD 4.750 8,291 9 6.01" 8,571.3 3254.7 78.58 X0 BUSHING X0 Bushin 3.91 ID OD 3.910 13015.5 3,261.5 8688 X0 4.5x35 X 04 1/2 BTC Box x3- 1 /2 "IBTPln Oils 2.992 "ID) 2.992 LOCATOR, 6.342 r t Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) AL SE ASSY, %L Top Depth 8,343 "Ll (TVD) Top lnol Top{flK8) (ftKB) (1 Description Comment Run Date ID(in) 11,973 3,280.3 90.05 CMT CEMENT RETAINER PERMANENT 10/31/2009 0.000 I RETAINER 12,200 3,270.2 93.50 PLUG PERMANENT BRIDGE PLUG IN B- LATERAL 10/29/2009 j 0.000 Perforations Slots Shot Top ((VD) Bttn (TVD) Dens c- T.. (ftKB)' Btm (ftKB (ftKB) (ftKB) Zone Date (h Type Comment 8,746 9,213 3,285.7 3,287.0 WS C, WS B, 3/28/2007 32.0 SLOTS Alternating slotted /solid pipe 13-16011 2.5"x .125" slots 9,600 10,152 3,315.7 3,304.3 WS B, 1J 16011 3/28/2007 32.0 SLOTS Alternating slotted /solid pipe I iii 2.5"x 125" slots D SAND LEM, 8,324.8,562 10,409 11,010 3,291.3 3,276.6 WS B, 1J -160L1 3/28/2007 32.0 SLOTS Alternating slotted /solid pipe 2.5 "0.125" slots D -SAND HH, 1,i69.2 8,391.8,657 11,268 11,911 69 3,279.7 WS B, 1J 160L1 3/28/2007 32.0 SLOTS Alternating slotted /solid pipe SLOTS, 2.5"x.125" slots 8,746 9,213 WHIPSTOCK. 8750 9064 12,036 12,041 3,284.4 3,283.8 WS B, 1J 16011 10/30/2009 6 0 PERFS HES PERF GUN 60 deg phase NTERMEDIATE, SLOTS lt 41 12,169 13,015 3,272.2 3,261.5 WS B, WS C, WS 3/28/2007 32 0 SLOTS Alternating slotted/solid pipe 1 B, 1J -160L1 2.5"x.125" slots 1 I Notes: General Safety I 1 End Date Annotation 4/112007 NOTE: MULTILAT WELL 1J -160 (NO PERFS) 13- 160L1(B- SAND), 1J -160L2 (D -SAND) 1 6/10/2009 NOTE: VIEW SCHEMATIC w /Alaska Schemat1c9.0 1 1 I I SLOTS, I I 9.60010.' 52 I I I 1= I I- I I I I SLOTS, I 10,409.11,010 I I LL I �i 1° 1= i- SLOTS, c I 11,268-11,911 r 1 I r CMT �Y RETAINER, 11,973 PERFS. 12,036 -12,041 Mandrel Details r t ."e Top Depth Top Port PLUG, 12,200 (TVD) Incl OD Valve Latch Sae TRO Run w Ste Top (Po(B) (ftKB) (1 Make Model (in) Sery TM. Type 00 (pa9 Run Date Com... T 1 2,280.0 1.859.4j70.66 CAMCO KBMG 1 GAS LIFT OMY BK -5 0.000 0.0 6252007 SLOTS. I I 12,169.13,015 1 I 1 IE I i= i 1: I B -SAND 3.0 8. /1.16 L1 TD (1., 16011), 13 s ,064 • • ~~ ~ ~ °~ ~ ~~~ ~ ~ ~ ~-~~ ~~ ~ ~ ~- . ~ ~. ~~'~~ '`~` ~(~ ~ ~~t ¢~ ~~ ~ ~ ~ u ~ ~ ~~ ~ ~ ~~, ~ ` ~ ~ ~ ~~`~ ~ ~ ~" ~~ w ~ ~'°" ~ ~ ~ ~ „3~ ~ ~ S`~ ~-~ ~~~q~ ~~ ~ SEAN PARNELL, GOVERNOR ~: ~~ ~~~~ ~~~~ e.~,~ ~,~,~ ~ ~ :~~_ ~.~ ~.~~du. ~~~ ~~ ~~ ~~~ ~ ~+ ~ 1~Lt~-7~~ ~I~ t~l~il Vrv-7 a 333 W. 7th AVENUE, SUITE 100 COI~SERQATI01~ COMDIISSIOl~ ~ ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 e FAX. __ (907)276-7542 Mr. John Peirce Wells Engineer ConocoPhillips Alaska Inc. P. O. Box 100360 Anchorage, AK 99510 ~°r~ ~~: ~,'e ~:~:i.~ . . r J. .w ,~ ~ n ~ tl~i,.. Re: Kuparuk River Field, West Sak Oil Pool, 1J-160L1 J Sundry Number: 309-279 ~~ ~ ... ~ ~ ~~ 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. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Sincerely, Cathy P. Foerster Commissioner DATED this~~ day of August, 2009 Encl. ~ ~` ~ ~r !\ • STATE OF ALASKA ~ "° ~~.~~`~~.~ • ~~~~~ ~ ALASKA OIL AND GAS CONSERVATION COMMISSION ~ ~~7 .~ ~ L~`'v~ APPLICATION FOR SUNDRY APPROVAL.~~~~~~ ~~~~, ~: ~~3: y~3,~. ~~~~,;;~~;~~, 20 AAC 25.280 ~ ~ r,- 1. Type of Request: Abandon ~ Suspend ^ Operational Shutdown ^ Pertorate ^ Waiver ~ Other ~ Alter casing ^ Repair well ^ Plug Perforations ^ Stimulate ^ Time Extension ~ MBE isolation . Change approved program ^ Pull Tubing ^ Perforate New Pool ^ Re-enter Suspended Well ~ C~ I K3 ~~ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: E~ ConocoPhillips Alaska, InC. Development ^ Exploratory ^ 207-016 • ~ 3. Address: Stratigraphic ~ Service Q• 6. API Number: P. O. Box 100360, Anchora e, Alaska 99510 50-029-23344-60 ' 7. If perforating, closest approach in pool(s) opened by this operation to nearest property line 8. Well Name and Number: where ownership or landownership changes: Spacing Exception Requires? YeS ^ NO ^~ 1J-160L1 9. Property Designation: 10. KB Elevation (ft): 11. Field/Pool(s): ADL 25660,~25663 • RKB 122' ~ Kuparuk River Field / West Sak Oil Pool . 12. PRESENT WELL CONDITI ON SUMMARY Total depth MD (ft): Total Depth ND (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 13064' ' 3264' • 13054' • 3264' . Casing Length Size MD ND Burst Coliapse CONDUCTOR g0' 20" 120' 120' SURFACE 3511' 13-3/8" 3551' 2190' INTERMEDIATE 9110' 9.625" 9150' 3340' SLOTTED LINER 4536' 4.5" 13055' 3264' Perforation Depth MD ( slots at s7as'-9213~, Perforation Depth ND (ft): slots at 3286'-3287' Tubing Size: Tubing Grade: Tubing MD (ft): 9600'-10152', 10409'-11010', 11268'-t1911', 12169'-13015' 3315'-3303', 3291'-3276', 3269'-3280', 3272'-326T 4.5~~ L-8~ 835T Packers and SSSV Type: Packers and SSSV MD (ft) HRD ZXP liner top pkr @ 8519' nipple @ 505' 13. Attachments: Description Summary of Proposal Q 14. Well Class after proposed work: Detailed Operations Program ^ BOP Sketch ^ Exploratory ~ Development ^ Service Q• 15. Estimated Date for 16. Well Status after proposed work: Commencing Operat August 17, 2009 Oil ^ Gas ^ Plugged ^ Abandoned ^ 17. Verbal Approval: Date: WAG ~ GINJ ^ WINJ ^~ ' WDSPL ~ Commission Representative: 18. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: John Peirce @ 265-6471 Printed Name JOhl1 P@IfC@ Title: Wells Engineer Signature ,~''°' ~/ ~` Phone 265-6471 Date p~ -~- Commission Use Onl Sundry Number. Conditions of approval: Notify Commission so that a representative may witness ~~_ ~~~ Plug Integrity ~ BOP Test ~ Mechanical Integrity Test ~ Location Clearance ^ Other: Subsequent Form Required: Za - y~y APPROVED BY Q / Approved by: MISSIONER THE COMMISSION ~ ~ ~ Date: ~ SI Form 10-40~3 Revi d 06/2006 ~~ $ r-~ Submit in Du lic te . ~c:?` ,,~` :,_ ..~ ~P~ r~,~~s ~. '~ ~~D~C P ~ ~ ~:/~ ~ ~-d~ L ~ .<%''~i-~/~ ConocoPhil{ips :S„rv;h~.. irt;: KUP IboraAPVUWI FieldName 500292334460 WEST SAK nment IH2! ~V: NIPPLE ~ 1J-160L1 _ I Max Angle 8 MD TD ! Well Status ~.Incl (") MD (HKB) Acf Bbn (ftKB) ~INJECIING ~I I 13,064.0 Mnotation IEnd Data IKB-Grd ((t) Rig Ralease Da Last W0: 43.01 4l70/2007 a ...._ ..,. ~~~y ... ,.,,.~,~y ~,.~ ~ 11.60 . L-80 ~~ BTC NIPPLE. 506 GAS LIFl. 2280 SURFACE, 58-3.55~ SLEEVE-O, 8.291 LOCATOR, 6.342 SEA1 ASSY,_ 6,343 PLUG. 8.443 D-SAND LEM, 8,324-8,562 D-SAND HH, 8,391-8.65] SIOTS, ~ 8,]a6-9,213 W HIPSTOCK, 6.750-9.G60 ~ fERMEDIATE, a1-9.~50 i' ~ _ ~~ ~~ SLOTS, ~' ~ ~ 9,600-10.i52 = ~ i m ' '~ -' ~~ ~~i !~ SLOTS. _ _ _ _-. _ y ! ! ° to.aosii,o:o ~~ ~- ~~ ~a ~I iw I I~ i i= i i ;~~ i i~ SLOTS. ~ i i ,',_ 11,268~ 1 I 4'~ i ~ ~ - ~I i= I I u ~~ !~ ~~ ~~ ~! ~Y SLOTS, ~ ' ~ ~2,1fi9-13,015 ~ ~ ~ I - ~! ~~ ~1 Iv. ! ! ` ~ ~ ! m ~ ~ ~ _ esauo uNER 8.519-t3,055 TO(iJ-160L1). ~ . ~ ~ 13.O6a Top Depth I (ND) I 7op Inel Top (kK6) (ftKe) ~ (°I Item Dasaiption Commenl ID (in) 8,518_9 3,2465; 79.98 PACKER "NRD" ZXP Liner Top Packer9-S/8" (Z50" X SA2") 7.500 8,537.3 3,2472 ~ 78.06 NIPPLE "RS" Packoff Seal Nipple 7 00" (6,18" ID x 8.00" OD) 6.180 8,540.8 3,248.0 78.12 HANGER RexLock liner Hanger 7" x 9-S/8" (621"X 8.30") 6210 8,550.6 3,2502 7827 XO BUSHING XO Bushing 4.93" ID, 7.66" OD 4.930 8,552.0 3,25Q5 7829 SBE 190-07 Casing Seal Bore Ext. 4J5'ID z 627" OD 4J50 8,571.3~ 3,254_7 78.SS.XO BUSHING XO Bushing 3 91" ID, 6.01"OD i 3.910 13,015.5~ 3,26t5 _. - 56.88' XO 4.Sx3.5 X-O 4-1l2" BTC Box x 3-U7' IBT Pin (5.04" Odx 2.992" ID) 2.992 Perfora [ions 8 Slots Shot I i Top (fVD) Bim (TVD) Dens ~~ Top (HKB) ', Btrn (kK6) ' (HKB) (ftK6) Zone Da~e ~(sh-~ Type CommaM ~ 8,746 1 9,213 I 3,285J 3,287.0 WS C, WS 8, 328/2007 i 32.0 SLOTS Altemating slonedlsolid pipe I l 1J-160L1 2S'x.125" slots ~ 9,600 ~ 10,152 3,375.7 3,3043 WS B, iJ-160L7 3;28/2007 i 32A SLOTS Altemating slotled/solitl pipe ~ ~ ~~ 25'x.12S' slots 14409 11,010 3,2913 3,276.6 WS B, iJ-160L7 ~3l28/2007 32.0 SLOTS ~Altemating slonedlsolid pfpe j 2.5'k.125' slots ~ 11,268 11.911 3,2692 3,279 7 WS B, iJ-160L7 ~3/28/2007 32.0 SIOTS ~Altemating 5lotted/soli0 pipe 25 x 125" slots ~ 72,169 'I 13015 ~ 32722 3,267.S~WSB,WSC WS 328/2007 32.OSLOTS Alrernatingslotted/solidpipe I '~I ~.B.7J-160L7 . `. 2.5'x.125"slots i No;es__ General _-- & Safety ____ _ _ Entl Date Annotation 4/11/2007 NO IE MULTILAT WELL - 1J-160 (NO PERFS), iJ-160L7(&SAND), iJ-i60L2 (D-SAND) 6l10/2009 NOTE:VIEWSCHEMATICw/AlaskaSchematic9.0 .___.._.-__ . .. _.. ..__. Mandrel Details . .... roPOePm rou i .. __._ . _--- . .. . .... ..p.rt. . _.___. ~ (TYD) Incl pD ~ ~ Valve Latch Sae TRO Run I I Stn Top (ft I Type (~) (psi) Run Date i KB) (NKg) (°) ~ Maka ~ MoAel ( ~) Serv ~ TYPe Com... ~ .1 22800 1,859.470.66iCAMCOiKBMG 1,GASUFT'~DMY iBK-5 I0.000~ 00625/2007 ~I ~ ~ 1J-160 L1 Procedure Proposed for Matrix Bypass Event (MBE) Isofation 1J-160L1 is a horizontal injector lateral in the West Sak B sand. An MBE in 1J-160 became evident on 5/13/09 and resulted in a main bore IPROF on 5/31/09 that showed 80% of PWI entering the B lateral (1J-160L1). A 6/7/09 IPROF in the B lateral showed a temperature inflection indicating an MBE exists at ~12190' RKB. An IBP was set 6/8/09 at 8443' RKB in 1 J-160 main bore to temporarily isolate 1 J-160L1. ' The MBE is located just below a 258' section of uncemented blank 4.5" liner in 6.75" OH. This procedure will set a Bridge Plug in the 258' blank liner and cement fill 4.5" x 6.75" annulus behind the 258' blank liner section to halt all PWI to the MBE. ~ Procedure: Coil Tubinq: 1. Pull the plug from the 1 J-160 main bore at 8443' RKB. Note: A diverter has already been previously set in the `B' LEM. 2. Fluff, Stuff, & Lubricate 1J-160L1 to at least 12200' RKB to reduce hole friction. 3. Set a Bridge Plug at ~12100' RKB inside a 258' section of blank 4.5" liner. 4. Shoot 5' of squeeze perforations at 12036 - 12041' RKB at the mid-point of a 258' section of blank 4.5" liner. 5. Fluff, Stuff, & Lubricate 1 J-160L1 to at least 12050' RKB to remove perF debris and to reduce hole friction as much as possible. 6. Set an inflatable cement retainer in blank 4.5" liner at ~11978' RKB. Circulate one CT volume of freshwater through cement retainer to the annulus to verify good communication to the annulus, followed by 13 bbls of 8.5 ppg ultra- light weight cement at 1 bpm, followed by a freshwater spacer. PU to disconnect CT from retainer as the last 0.5 bbl of cement passes through the cement retainer. POOH slow with CT displacing liner with water and tubing with diesel to surface. Wait on cement 7 days then return 1 J-160 to PWI. JWP 8/4/2009 1 J-160 L1 Cement Placement for MBE Isolation Coil Tubing Procedure: 1) Fluff, Stuff, & Lubricate to 12200' 2) Set Bridge Plug at 12100' 3) Perforate at 12036-12041' 4) Fluff, Stuff, & Lubricate to 12050' 5) Set Cement Retainer at 11978', Pump 13 bbls 8.5 ppg Cement, Disconnect & POOH with coil. 4.5" Liner Volume from Cement Retainer to Bridge Plug = 1.9 bbls 4.5" Liner: Slotted 11867 - 11910' Blank 11910 - 12168' Slotted 12168 - 12255' Slotted sections have 0.125" x 2.5" slots at 32 slots/ft 13 bbls Cement fills 122' Straddle in 4.5" Liner and 451' of Blank Linerx OH Annulus to isolate MBE ~ 6.75" OH 4.5" Liner ~ Cement Perforate Retainer 12036 - 12041' at 11978' perfs at mid-point of 258' Blank Bridge Plug at 12100' West Sak 8 Sand MBE is at ~12190' JWP 7-30-09 • • Page 1 of 2 Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Thursday, July 02, 2009 12:42 PM To: 'NSK Prod Engr SpeciaiisY Subject: RE: OL2 17) ~~._ 1 ~ ~ ~., ~., ~b`~- ~ ~ ~o Darrell, I have reviewed the file and see what Eric wrote about. There was no penetration drilled out of the 9-5/8" casing that was set at 9150'. The "B" or L1 lateral exited the casing at -8750' and the "D" or L2 lateral exited the casing at ~8391. Based on the depths provided in the sundries I have, the L1 lateral was isolated as indicated by Eric. After further review, it may not be necessary to send in new 404s. I think it will be possible to make the corrections by hand. Please give me a call. Tom Maunder, PE AOGCC From: Maunder, Thomas E (DOA) Sent: Thursda Jul 02 2009 8:04 AM Y, Y , 4_.. ~~~~~ .J~i :~ ~~ ~~~ To: NSK Prod Engr Specialist :~'c~ Subject: RE: 1J-160L2 (207-017) Darrell, Thanks for looking into this. When you send in the new 404s, please put a note somewhere that these docurnents are revised. 7om From: NSK Prod Engr Specialist [mailto:ni139@conocophillips.com] Sent: Thursday, July 02, 2009 6:21 AM To: Maunder, Thomas E (DOA) Subject: FW: 1]-160L2 (207-017) Tom- as you can see from below it looks like we filed the 404 for the wrong sand. You are not going nuts. I will correct the 404 for isolating the B sand and resubmit it. You should have it in the next couple of days. barrell From: Hollar, Eric Andrew Sent: Wednesday, July O1, 2009 3:05 PM To: NSK Prod Engr Specialist Subject: RE: 1J-160L2 (207-017) Darrell, This well is a little unusual in that--according to the multilat drawing--it was drilled in the traditional tri-lateral way with a motherbore extending to the A sand. However, no lateral was compieted in the A sand. I am going to assume that Tom's reference to the L2 matches a full tri-lateral (motherbore = A sand, L1 = B sand, L2 = D sand), even though this well isn't really a full tri-lateral well. The D sand (L2) isn't isolated in this well. A plug is set in a nipple at 8443' MD, which is below the D sand lateral junction. If we filed that the L2 was isolated, we should amend it. The B sand (L1) was isolated due to rapid water injection breakthrough. 7/2/2009 ~ • Page 2 of 2 Eric Hollar West Sak Production Engineer ConocoPhillips Alaska, Inc. Phone 907-265-6525 Cell 907-748-0181 . __ _ _ _ _ From: NSK Prod Engr Specialist Sent: Wednesday, July 01, 2009 2:38 PM To: Hollar, Eric Andrew Subject: FW: 1J-160L2 (207-017) Eric, would you be able to provide some insight to Tom's question? thanks Darrell From: Maunder, Thomas E (DOA) [ma+lto:tom.maunder@alaska.gov] Sent: Wednesday, July O1, 2009 9:28 AM To: NSK Prod Engr Specialist Subject: i]-160L2 (207-017) Bob and Darrell, I am revieyving the series of 404s submitted for this 1J-160L2 and the other segments reporting the isolation of 1J- 160L2. Do you have additional information as to why this lateral was isolated? I don't have any emails and did not find any new information in the well file. Thanks in advance. Tom Maunder, PE AOGCC '7/2/2009 - ~~~~ _ ~ • , ~~.1~/ ~ ~ ~~QS STATE OF ALASKA ,~~~5~~ ~~~ ~i ~ ALASKA OIL AND GAS CONSERVATION COMMISSION ,~r~ ~j ~~~' ~~~1t1]71~sjQ~ REPORT OF SUNDRY WELL OPERATIONS t~ ~boL~. 1. Operations Performed: Abandon ^ Repair Well ^ Plug Perforations ~ Stimulate ~ Other ~^ Isolated Alter Casin Pull Tubin g ^ g ^ Pertorate New Pool ~ Waiver ~ "~" sand • ^ Time Extension Change Approved Program ^ Operat. Shutdown^ Perforate ~ Re-enter Suspended Well ^ 2. Operator Name: 4. Current Well Status: 5. Permit to Drill Number: ConOCOPhillips AlaSka, InC. Development ^ Expioratory ^ 207-016 /- 3. Address: Stratigraphic ^ Service Q• 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-029-23344-60 . 7. KB Elevation (ft): 9. Well Name and Number: RKB 122' 1J-160L1 • 8. Property Designation: 10. Field/Pool(s): ADL 25660, 25663 ' Kuparuk River Field / West Sak Oil Pool 11. Present Well Condition Summary: Total Depth measured 13064' feet true vertical 3264' ' feet Plugs (measured} Effective Depth measured 13054' feet Junk (measured) true vertical 3264' feet 4-1/2" Casing Length Size MD ND Burst Collapse Structural CONDUCTOR 120' 20" 120' 120' SURFACE 3428' 13-3/8" 3550' 2191' INTERMEDIATE 9028' 9-5/8" 9150' 3343' WINDOW D-SAN 1' 9-518" 8392' 3224' WINDOW B-SAN 1' 9-5/8" 8751' Perforation depth: Measured depth: 8746' - 13015' true vertical depth: 3286' - 3304' Tubing (size, grade, and measured depth) 4-1/2" , L-80, 8357' MD. Packers & SSSV (type & measured depth) PKR ='HRD' ZXP Liner Top Pkr PKR = 8519' ~ ~ SSSV= NIP SSSV= 506' ~ ~~S ~~ ~~ ~~--- 12. Stimulation or cement squeeze summary: o ~ \_~~~~~~~0 ~ ~,~~ ~ Intervals treated (measured) Treatment descriptions including volumes used and final pres . ~~ ~(JC ~~~?~~~ ~~ 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casin Pressure Tubin Pressure Prior to well operation 1227 1221 957 Subsequent to operation 1177 • 1121 997 14. Attachments 15. Well Class after proposed work: Copies of Logs and Surveys run _ Exploratory ^ Development ^ Service ~^ Daily Report of Well Operations _X 16. Well Status after proposed work: Oil^ Gas^ WAG[] GINJ^ WINJ Q 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: N/A contact Bob Christensen /Darrell Humphrey Printed Name :~ Obe D. Ch 's sen Title Production Engineering Technician Signature ~ ~~ ~" ~ ~~ ~' Phone 659-7535 Date ~~ ~ 3 ~ l; ~~ ~ Form 10-404 Revised 04/2004 ,~ ~ ~ r~ ° ~ ~ ~~~.~ ~; ~ ,~ ~ ~~~~~~C~~31~ '" ~1 ~ ,~ l~. -'~G'~Z~.c`~' Submit Origina~~~~ . ~ 1J-160L1 DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary 06/08/09 PERFORM FINAL RUN FOR IPROF IN B-LAT TO 12151 CTMD, SET 3.562 CS LOCK & PRONG IN DB-NIPPLE @ 8443 RKB. WELL IS FREEZE PROTECTED & SHUTIN. ~,. KUP 1J-160L1 ~ ConoCOPhillips Well Attributes Max An le & MD r~ WellboreAPllUWI FielONama WeII31nNS Incl~°~ MD~ftKB) Ac[Btm~Po(B) ~ ~ 500292334460 WESTSAK INJECTING 13,064.0 Reason: Set CS Imosbor I 6/10/2009 .„ CONDUCTOft, 40-121 NIPP~E.506 GAS UFT, 2.280 SURFACE 5&3551 SLEEVE O 8 291 LOCA70R, 8,312 SEALASSY, 8.303 PLUG. 9.903 SLOTS. 9.600-10.152 SLOTS, 10.W9-11.010 S I SLOTS, 11 Z6B-11 911 SLOTS, 72.18&13.075 9-SM1D LINER 8,579-13,055 T0~1J~76~L1) ~ 13.069 Inc IStnlTop~M(B~I ~ KB) I I~~I I Make I Model I l/ I Serv I 7yps I T pe I sin) ITR~,unl RunDate ICOm_.I ~~ DATA SUBMITTAL COMPLIANCE REPORT 5/7/2009 Permit to Drill 2070160 Well Name/No. KUPARUK RIV U WSAK 1J-150L1 Operator CONOCOPHILLIPS ALASKA INC API No. 50-029-23344-60-00 MD 13064. TVD 3264 Completion Date 4/9/2007 Completion Status 1WINJ Current Status 1WINJ UIC Y REQUIRED INFORMATION fig Mud Log IVo DATA INFORMATION Types Electric or Other Logs Run: GR/Res, USIT Well Log Information: Log/ Electr Data Digital Dataset Type Med/Frmt Number Name __ D D Asc Directional Survey ~D D Asc Directional Survey ~D C Lis 15186 ~nduction/Resistivity pt 15186 LIS Verification C Lis 15187~nduction/Resistivity ~~ Samples No Directional Survey ~e (data taken from Logs Portion of Master Well Data Maint 15187 LIS Verification C 17992' ~~qs,~~~~~,~t~` Induction'//Resistivityesistivity ~duction/Resistivity C 17993 Se~s ,p ~ •~r -Eti : ~... c c n Induction/Resistivity Induction/Resistivity Log Log Run Interval OH / Scale Media No Start Stop CH Received Comments 9170 13064 Open 5/8/2007 _ _ _ 8721 9439 Open 5/8/2007 PB 1 3525 13064 Open 6/12/2007 LIS Veri, GR, NPHI, NCNT, RHOS, RHOB w/Graphics 3525 13064 Open 6/12/2007 LIS Veri, GR, NPHI, NCNT, RHOB, RHOB 3525 9439 Open 6/12/2007 PB1 LIS Veri, GR, NPHI, NCNT, RHOS, RHOB w/Graphics 3525 9439 Open 6/12/2007 PB1 LIS Veri, GR, NPHI, NCNT, RHOB, RHOS 0 0 5/5/2009 EWR Logs in CGM, PDS and EMF graphics 2 Col 121 13064 ~e 5/5/2009 MD ROP, EWR, DGR 2 Col 121 3560 ~ 5/5/2009 TVD EWR, DGR 6~~ti 0 0 5/5!2009 PB1 EWR Logs in CGM, PDS and EMF graphics 2 Col 121 943 ,4-- 9 5/5/2009 P61 MD ROP, EWR, DGR 2 Col 121 3281 S%~ 5/5/2009 PB1 TVD EWR, DGR DATA SUBMITTAL COMPLIANCE REPORT 5/7/2009 Permit to Drill 2070160 Well NamelNo. KUPARUK RIV U WSAK 1J-160L1 Operator CONOCOPHILLIPS ALASKA INC API No. 50-029-23344-60-00 MD 13064 TVD 3264 Well Cores/Samples Information: Name ADDITIONAL INFORMATION Well Cored? Y I`N Chips Received? Y~'1Q- Analysis Y / N Received? Comments: Interval Start Stop Completion Status 1WINJ Current Status 1WINJ UIC Y Sample Set Sent Received Number Comments Daily History Received? ~/ N Formation Tops ~/ N ___ Compliance Reviewed By: __ ~ Date: ~ I ~ ~ Z )`U Completion Date 4/9/2007 `~`~ELiL LDG l~'RAi~~M~'~'~A~, T®e State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: MWD Formation Evaluation Logs: 1J-160+L1+L1PB1+L2 Apri129, 2009 AK-MW-4877337 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention o£ Bryan Burinda, Sperry Drilling, Arctic Blvd., Anchorage, AK 99518 1J-160+L1+L1PB1+L2 2" x 5" MD RESISTIVITY & GAMMA RAY Logs: 1 Color Log 50-029-23 344-00,60,61,70 2" x 5" TVD RESISTIVITY & GAMMA RAY Logs: 1 Color Log 50-029-23344-00,60,61,70 Digital Log Images 4 CD Rom 50-029-23 344-00,60,61,70 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry Drilling Attn: Bryan Burinda 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-273-3536 Fax: 907-273-3535 ~ BP Exploration (Alaska) Inc. Petrotechnical Data Center, MB33 900 E. Benson Blvd. Anchorage, Alaska 99508 Bryan.Burnda@halliburton.com ~,, ~3~'~2c~~ _ ~ `~ j ,; ;~ ~ .~e a-~ i ~ Tlate• ~tgnecl' ~ ~ i" ~~~ -c~~~ y~~ 1 i ~ ~~3~ ] ~ ~~r ~ 1 °,~~ ,~ WELL LOS TI'ZSi~JTTAL T®a State of Alaska Alaska Oil and Gas Conservation Comm, Attn.: Librarian 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: MWD Formation Evaluation Logs: 1J-160+L1+L1PB1+L2 April 29, 2009 AK-MW-4877337 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of Bryan Burinda, Sperry Drilling, Arctic Blvd., Anchorage, AK 99518 1J-160+L1+L1PB1+L2 2" x 5" MD RESISTIVITY & GAMMA RAY Logs: 1 Color Log 50-029-23344-00,60,61,70 2" x 5" TVD RESISTIVITY & GAMMA RAY Logs: 1 Color Log 50-029-23 344-00, 60,61, 70 Digital Log Images 4 CD Rom 50-029-23344-00,60,61,70 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry Drilling Attn: Bryan Burinda 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-273-3536 Fax: 907-273-3535 Bryan.Burinda@halliburton. com Tlate• Ci unecl: a-- ~ BP Exploration (Alaska) Inc. Petrotechnical Data Center, MB33 900 E. Benson Blvd. Anchorage, Alaska 99508 l~ ~' °L a~~ - ~ iS c~ ~~ ~ -e~ r ~- ~~j'} -~i',~' d`~-~ r ~-~- 99~ r~4~~ i 'may' ~t~l~ Ll j/VV • 4V1~.+4ivN vii iu i ivy .vy' •.r i.... • w.. ... .• ~.. ~... .. Maunder, Thomas E (DOAj __ From: Maunder, Thomas E (DOA) Sent: Monday, August 27, 2007 9:52 AM To: 'NSK West Sak Prod Engr'; Regg, James B (DOA} Cc: CPF1 DS Lead Techs; CPF1 Prod Supt; Hollar, Eric Andrew; Rodgers, James T Subject: RE: LPPISSN defeated on 1E-112, 1J-102, 1J-127, 1J-164, 1J-180 _.O _ _ _. Thanks Hai, While we will file this information in the main wellbore file, it is probably appropriate to list the lateral permit numbers for completeness. Call or message with any questions. Tom Maunder, PE AOGCC From: NSK West Sak Prod Engr [mailto:n1638@conocophillips.com] Sent: Sunday, August 26, 2007 8:59 AM To: Maunder, Thomas E (DOA); Regg, James B (DOA) Cc: CPF1 DS Lead Techs; CPFl Prod Supt; NSK West Sak Prod Engr; Hollar, Eric Andrew; Rodgers, James T Subject: RE: LPPISSN defeated on 1E-112, iJ-102, iJ-127, 1J-164, iJ-180 Tom' Jim, The LPPISSN's on all of the West Sak DS1 E and DS1J wells are now back in service as their wellhead injection pressures have increased to above 500 psi. The following wells had been defeated; permit to drill numbers are also listed. I ~niasn't sure if yo! i v+ranted the permit to drill number for the mainbore only or the laterals as we!I so I included both. WELL !D Permit to Drill No. 1 E-112 204-091 (MAlNBORE), 204-092 (L1 ), 204-093 (L2) 1J-102 206-110 (MAINBORE), 206-111 (L1 ), 206-`I12 (L2) 1J-105 207-027 (MAINBORE), 207-028 (L1 ), 207-029 (L2) 1J-'127 206-047 (MAINBORE), 206-048 (L1 ), 206-049 (L2) ~-',> 1 J-160 207-015 (MAiNBORE), 207-016 (L1), 207-017 (L2) 1J-164 205-144 (MAINBORE}, 205-145 (L1 ), 205-146 (L2) 1J-180 206-150 (MAINBORE), 206-151 (L1) Note: 1J-105 and 'IJ-160 were defeated in early July 2007, before the CPF1 ESD, because they were new injectors (notification for these wells was sent 7/9/2007). Let me know if you have any questions. Regards, Hai Hunt Hai Hunt /Pete Nezaticky /Eric Hollar NSK West Sak Production Engineer ConocoPhillips Alaska, Inc. Phone: (907) 659-7061 Fa;<: (907) 659-7749 Email: n1638@ConocoPhillips.com ~ ~ ~.ECEIVED STATE OF ALASKA ~U~ Q ~ ZOO7 ALASKA OIL AND GAS CONSERVATION COMMISSION Alaska Oil & Gas Cons. Ct}fTlftliSSlUn REPORT OF SUNDRY WELL OPERATIONS Anchorage 1. Operations Performed: Abandon ^ Repair Well ^ Plug Perforations ^ Stimulate ^ Other ^ Prod to WINJ Alter Casing ^ Pull Tubing ^ Perforate New Pool ^ Waiver ^ Time Extension ^ Change Approved Program ^ Operat. Shutdown^ Perforate ^ Re-enter Suspended Well ^ 2. Operator Name: 4. Current Well Status: 5. Permit to Drill Number: ConocoPhillips Alaska, InC. Development ~ Exploratory ^ 207-016 / 3. Address: Strati ra hic g p ^ Service ^ 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-029-23344-60 7. KB Elevation (ft): 9. Well Name and Number: RKB 122' 1J-160L1 8. Property Designation: ~, d7 K r k Ri U it !`~D L ~ ~(0~~~ 10. Field/Pool(s): ' upa u ver n . 7. Kuparuk River Field /West Sak Oil Pool • 11. Present Well Condition Summary: Total Depth measured 13064' feet true vertical 3264' ~ feet Plugs (measured) Effective Depth. measured 13054' feet Junk (measured) true vertical 3264' feet 4-1/2" Casing. Length Size.. MD TVD Burst Collapse Structural CONDUCTOR. 120' 20" 120' 120' SURFACE 3428' 13-3/8" 3550' 2191' INTERMEDIATE 9028' 9-5/8" 9150' 3343' .. . WINDOW D-SAN 1' 9-5/8" 8392' 3224' WINDOW B-SAN 1' 9-5/8" 8751' Perforation depth: .Measured depth: 8746' - 13015' true vertical depth: 3286' - 3304' Tubing (size, grade, and measured depth) 4-1l2" , L-8Q 835T MD . Packers &SSSV (type & measured depth) PKR = 'HRD' ZXP Liner To p Pkr PKR = 8519' SSSV=NIP SSSV= 506' 12. Stimulation. or cement squeeze summary: In ~ ~ ~~D, ~~ ~U~ tervals treated (measured) - Treatmenfdescriptions 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 702 100 23 1011 207 ` Subsequentto operation 327 1339 932 14. Attachments 15. Well Class after proposed work: Copies of Logs and Surveys run _ Exploratory ^ Development ^ Service ^~ Daily Report of Well Operations X 16. Well Status after proposed 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: 307-184 contact Bob Christensen /Bob Buchholz Printed Name ob D. ri tensen Title Production Engineering Technician. Signature Phone 659-7535 Date Form 10-404 Revised 04/2004 ~ ~ ~ -1 Y A L ~~~`T` ~~~Submit Original Only • 1J-160L1 DESCRIPTION OF WORK COMPLETED. SUMMARY Date Event Summary 07/01/07 Commenced Water Injection Service WELL ~.®G T'RA'e1S~'IITTAL • ~'a; State of Alaska June 1, 2007 Alaska OiI and Gas Conservation Comm. Attn.: Librarian 333 West 7`" Avenue, Suite 100 Anchorage, Alaska RE: iYIWD Formation Evaluation Logs 1J-160 Ll AK-MW-4877337 1 LDWG formatted CD Rom with verification listing. API#: 5 0-029-23 344-60 PLEASE ACKNOWLEDGE RECEIPT BY SIG.NLNG AND RETLrRiNING A COPY OF THE TRA_NS_MITTAL LETTER TO THE ATTENTION OF: Sperry Drilling Services Attn: Rob Kalish 6900 Arctic Blvd. Anchora?e_ ~laa 9~ ~, - „ Date.: _ .:: ...:.,Signed: U-`~ app 'O1(° ~l'ifl ~~ LJ WELL L®G T~R.-~NS1~II'I'Tr~. ~~ 'J.®: State of Alaska June 1.2007 Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West 7`h Avenue, Suite 100 Anchorage, Alaska RE: MWD Formation Evaluation Logs 1J-160 Ll PBl AK-MW-4877337 1 LDWG formatted CD Rom with verification listing. API#: 5 0-02 9-23 3 44-70 PLEASE ACK,'~OWLEDGE RECEIPT BY SIGNING AND RETU-R1VP:V"G A COPY OF TFIE TRA~rrS1VIITTAL LETTER TO THE ATTENTION OF: Sperry Drilling Services Attn: Rob Kalish 6900 Arctic Blvd. Anchorage, Alaska 99518 Date: ~ ~ ~ - Signed: ~ ._ ,~,~,~~ ;':~('' ~r . ~ f ~iy,4-~ • ~Sl~Q~[~ 0~ aL~Q~~G~ / ~.....wa, °~a~~ O~ ~ ~ 33 C011T5ERQ1-7`I011T COrII`'IISSIOIQ 3 W. 7th AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Robert Christensen Production Engineering Technician ConocoPhillips Alaska, Inc. PO Box 100360 Anchorage, AK 99510-0360 Re: Kuparuk River Field, West Sak Oil Pool, 1J-160L1 Sundry Number: 307-184 Dear Mr. Christensen: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. DATED this ~ day of June, 2007 Encl. add - v~ ~ Sincerely, ~ ~~ ~/ 7 IVED ~ 1~E~E STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION ~~ JUN O' S 2007 APPLICATION FOR SUNDRY APPROVALAIaska Oil & Gas Cons. Commission 20 AAC 25.280 Anrhnrana 1. Type Of Request: Abandon ^ Suspend ^ Operational Shutdown ^ Perforate ^ Waiver ^ Other Q Alter casing ^ Repair well ^ Plug Perforations ^ Stimulate ^ Time Extension ^ Chan e a roved r ram g pp p og ^ Pull Tubing ^ Perforate New Pool ^ Producer to Reinter Suspended Well ^ Injector 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska, InC. Development^ Exploratory ^ 207-016 3. Address: Stratigraphic ^ Service ^ 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-029-23344-60 7. If perforating, closest approach in pool(s) opened by this operation to nearest property line 8. Well Name and Number: where ownership or landownership changes: Spacing Exception Required? YeS ^ NO ^Q 1J-160L1 9. Property Designation: ~DL LSD ~ © ~ 10. KB Elevation (ft): 11. Field/Pool(s): Kuparuk River Unit ~.D t. 2~(oL°a ~ ~.~,,~'7 RKB 122' Kuparuk River Field /West Sak Oil Pool 12. PRESENT WELL CONDITI ON SUMMARY Total depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 13064' 3264' 13054' 3264' ' Casing Length Size MD TVD Burst Collapse CONDUCTOR 120' 20" 120' 120' SURFACE 3428' 13-3/8" 3550' 2191' INTERMEDIATE 8028' 9-5/8" 9150' 3343' WINDOW D-SAND 1' 9-5/8" g3g2' 3224' WINDOW B-SAND 1' 9-5/8" 8751' 3287' Alternating Slotted Liner 4537' 4-1/2" 13055' 3264' Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 8746' -13015' 3286' - 3304' 4-1 /2" L-80 8357' Packers and SSSV Type: Packers and SSSV MD (ft) PKR ='HRD' ZXP Liner Top Pkr PKR = 8519' SSSV= NIP SSSV= 506' 13. Attachments: Description Summary of Proposal Q 14. Well Class after proposed work: Detailed Operations Program ^ BOP Sketch ^ Exploratory ^ Development ^ Service^ 15. Estimated Date for 16. Well Status after proposed work: Commencing Operations: June 20, 2007 Oil ^ Gas ^ Plugged ^ Abandoned ^ 17. Verbal Approval: Date: WAG ^ GINJ ^ WINJ 0 WDSPL ^ Commission Representative: 18. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Bob Christensen !Bob Buchholz Printed Name R Bert D. Christensen Title: Production Engineering Technician Signature Phone 659-7535 Date ~ Commission Use Onl Sundry Number: Conditions of approval: Notify Commission so that a representative may witness 3v Plug Integrity ^ BOP Test ^ Mechanical Integrity Test I~ Location Clearance ^ Other. ~ ~"C~ ~`^~ O ~~f GTibl~~ ~ ~ ~- C~ (~ ~ / +"t ~ ~ ~ \) . ~ D1r~ i(1N ~ $ 2~~7 Subsequent Form Required: `~V~ « APPROVED BY Approved by: OMMISSI THE COMMISSION Date: ~ Form 10-403 Revised 06/2006 _ J Submit in Duplicate ~- ~• ~-d~ ~. Robert Buchholz /Robert Christensen Production Engineering Tech. Greater Kupanak Unit , NSK-b9 PO Box 196105 ~~~~~~~~' ~'' ~ Anchorage, AK 99519-6105 Phone: (907)659-7535 Fax: 659-7314 i June 1, 2007 Tom Maunder, P.E. Senior Petroleum Engineer State of Alaska, Oil & Gas Conservation Commission 33 W. 7th Ave. Ste. 100 Anchorage, AK 99501 Dear Mr. Maunder, ConocoPhillips Alaska, Inc. requests approval to convert Kuparuk West Sak wells 1J-160 (PTD 207-015), 1J-160L1 (PTD 207-016), and 1J-160L2 (PTD 207-017) from Oil Production to Water Injection service. Enclosed you will find the 10-403 Application for Sundry Approvals for ConocoPhillips .Alaska, Inc. wells 1J-160, 1J-160L1, and 1J-160L2. If you have any questions regarding this matter, please contact myself or Robert Buchhloz at 659-7535. Sincerely, Robert D. Christensen Attachments 1J-160L1 DESCRIPTION SUMMARY OF PROPOSAL ConocoPhillips Alaska Inc. requests approval to begin Water Injection service in West Sak Tri- lateral Well 1J-160L1. This well has been pre-produced for 30 days in order to recover Oil based drilling fluids prior to putting the well on injection. 1J-160L1 will provide pressure support for the West Sak B sands. The 13-3/8" Surface casing (3551' and / 2190' tvd) was cemented with 667 sx Class 'G'. The 9~ 5/8" Intermediate casing (9150' and / 3340' tvd) was cemented with 735 sx DeepCRETE. The injection tubing/casing annulus is isolated via the following: Upper D sand SLZXP 7" x 9- 5/8" Liner Top Packer with 190-47 Casing Sealbore Receptacle located @ 8324' and / 3212' tvd, Upper B sand HRD ZXP 5-1/2" x 7-5/8" Liner Top Packer with 190-47 Casing Sealbore Receptacle located @ 8519' and / 3247' tvd. The top of West Sak D sand was found at 8387' and / 3223' tvd. D sand Lateral window top is located @ 8391' and / 3224' tvd. The top of West Sak B sand was found at 8767' and / 3289' tvd. B sand Lateral window top is located @ 8750' and / 3286' tvd. The top of West Sak A sand was found at 10241' and / 3454' tvd. • • ConocoPhillips Alaska, Inc. KRU 1J-160L1 xo (63458347, OD:7.670) CSG SBR (6347-6366, OD:6.310) XO Bushing (~, OD:6.000) PUP OD:5.210) PACKER (8519-6537, OD:8.420) NIP (8537-8541, OD:8.000) HANGER (8541-8551, OD:8.300) SBE (8552-8571, OD:6.270) Perf (87469213) 1J-160L1 A PI: 500292334 4 6 0 W ell Ty~e: SVC An le TS: de~_ _ . SSSV T e: NIPPLE _ . . _ _ Ori Completion: 4/10/2007 An le TD: 87 d 13064 Annular Fluid: Last W/O: Rev Reason: GLV C/O Reference L 40' RKB Ref Loc,ZDate: Last U date: 4/26/2008 Last Tag: TD: 13064 ftK6 __ _ Last Ta Date: __ _ _ Max Hde An le: _ 95 d 10555 Casing Strin -ALL S T RINGS Description Size To Bottom TVD Wt - Grade Thread - CONDUCTOR -- - 20.000 0 - 120 -- 120 94.00 H-40 WELDED SURFACE 13.375 0 3550 2191 68.00 L-80 BTC INTERMEDIATE _ 9.625 0 9150 3288 40.00 L-80 BTCM WINDOW D-SAND 9.625 8391 8392 3224 0.00 LINER B-SAND 4.500 8518 13055 3264 11.60 L-80 BTC WINDOW B-SAND 9.625 8750 8751 3286 0.00 Tubin Strin -TUBI NG Size Top Bottom TVD Wt Grade Thread 4.500 0 _ 8357 3218 12.60 L-80 IBTM Perforations Summa r ~ __ Interval _ TVD Zone Status Ft SPF Date T e Comment 8746 - 9213 3286 - 3288 WS C,WS B 467 32 3/28/2007 SLOTS Alternating slotted/solid pipe 2.5"x.125" slots 9600 - 10152 3315 - 3304 W S B 552 32 3/28/2007 SLOTS Alternating slotted/slid pipe 2.5"x.125" slots 10409 - 11010 3291 - 3276 WS B 601 32 3/28/2007 SLOTS Alternating slotted/slid pipe 2.5"x.125" slots 11268 - 11911 3273 - 3280 W S B 643 32 3/28/2007 SLOTS Alternating slotted/slid pipe 2.5"x.125" slots 12169 - 13015 3272 - 3262 W S B,W S C WS B 846 32 3/28/2007 SLOTS Alternating slotted/slid pipe 2.5"x.125" slots Gas Lift Mandrels/Val ves St MD TVD Man I, Mfr Man Type V Mfr V Type V OD Latch Port TRO Date Run Vlv Cmnt 1 2280 1859 CAMCO ~ KBMG GLV 1.0 BK-5 0.188 1415 4/25/2007 Other (plus, equip., De th TVD_ Type 36 36 HANGER 506 504 NIP etc.) -COMPLETION - - - Description VETCO GRAY TUBING HANGER CAMCO DB-6 w/NO GO PROFILE ID 4.500 3.875 8290 3206 SLEEVE-O BAKER CMD SLIDING SLEEVE w/OPEN PROFILE 3.812 8342 3215 L CA TO R O BAKER LOCATOR 3.940 8343 3216 _ _ _ _ _ -SEAL BAKER SEAL ASSEMBLY PBR/SBR 3.880 8357 3218 SHOE 3.958 Other lu s, equip., etc.1 LINER DETAIL De th TVD Type Descri tion ID 8324 _ 3212 PACKER - -- D-SAND SLZXP LINER TOP PACKER 7.500 8345 3216 XO D-SAND LEM CROSSOVER 7" x 5.5" 4.920 8347 3216 CSG SBR D-SAND LEM 190-47 CASING SEAL BORE RECEPTACLE 4.750 8366 3220 XO Bushin D-SAND CROSSOVER BUSHING 3.940 8368 3220 PUP 3.958 8377 3222 HANGER D-SAND LEM ABOVE HOOK HANGER 3.960 8391 3224 HANGER D-SAND BAKER MODEL 'B' LEM HOOK HANGER INSIDE CSG 7.470 8519 3247 PACKER B-SAND'HRD' ZXP LINER TOP PACKER 7.500 8537 3250 NIP B-SAND'RS' PACKOFF SEAL NIPPLE 6.180 8541 3250 HANGER B-SAND FLEXLOCK LINER HANGER 6.210 8551 3252 XO Bushin B-SAND CROSSOVER BUSHING 4.930 8552 3252 SBE B-SAND 190-47 CASING SEAL BORE EXTENSION 4.750 8571 256 XO Bu shims 3 B-SAND CROSSOVER BUSHING 3.910 _ 8750 _ _ _ _ 3286 Whi stock B-SAND BAKER GEN II PERMANENT WHIPSTOCK 8.400 General Notes Date __ Note _ 4/11/2007 NOTE: MULTILAT WELL - 1J-160 NO PERFS , 1J-160L1 B-SAND , 1J-160L2 D-SAND • r ,~~ ~ -~~ ;~3~ ~--~- -w ~ 1 ~, ~ ^_ _ '_ T~ , ~ `VD ; =STD . ?~.J - - '~ Iasi=_5 ~~'~~s Shoe- ~~' `~ ~~'~~ TTv`~J; :7~I. ~~, ?~ ~ =~-?i .,,e.. Shoe: '~~ _'~ , _~._ }'~ ~'~iD -~~;- PacKer '.-~ T'v'D; ~e~ ec s'~ ? S _~ e and ? e~~s ~o ~-~ Vv`a~L'L3 ~3c1. __nu~us P_ess est. _? Cc~ents . j r:in S 0 min ~'CH~NIC~ ~, TNTEGRIT`~ - PART #Z ~~3~;3~5 = a~S hh15 Cement Vo1~es : Amt. Liner ~~ Csg ~~~° S'~ DV Q~1.Q C.ut -JOl to cover oers ~ , ~j ~ _, . COQ ~ ~ ~~~~~ ~ 3v~~; ~ 5 _.-:eoretical TOC ~ ~S~~o`l.~ ^`~~~C~ ~r,~r~t~i ~•_~'~ ~~'J~~~ Cement Bond Log (Yes or No) ~~a-~ In AOGCC File ~~~ C3L Fva7.uation, gone above perks ~, ~rt ~s SC--b~~c c~~~~' ~l.~ci~~~, Production Log: T~ve CONCLJSIONS: art f1: ~c\ ~~5~ evaluation ~' ~~`.~~ • STATE OF ALASKA • ALASKA OIL AND GAS CONSERVATION COMMISSION ~~~~~ V MAY 1 4 2007 WELL COMPLETION OR RECOMPLETION REPORjaTas~AI~I~ 9~L~~• Commission 1a. Well Status: Oil ^ Gas Plugged Abandoned ^ Suspended 20AAC 25.105 20AAC 25.110 GINJ ^ WINJ ~ WDSPL ^ WAG ^ Other ^ No. of Completions: 1b. Well Class: ~ Development ^ Exploratory ^ Service ~ Stratigraphic Test ^ 2. Operator Name: ConocoPhillips Alaska, Inc. 5. Date Comp., Susp., q ,,~ Z9.D7 orAband.: April , 2~7 12. Permit to Drill Number: 207-016 / ' 3. Address: P. O. Box 100360, Anchorage, AK 99510-0360 6. Date Spudded: ~ ~S•~Q.o9 March , 2007 13. API Number: 50-029-23344-60 4a. Location of Well (Governmental Section): Surtace: 2016' FSL, 2541' FEL, Sec. 35, T11N, R10E, UM ~ 7. Date TD Reached: March 26, 2007 14. Well Name and Number: 1J-160L1 ° Top of Productive Horizon: 392' FSL, 1721' FWL, Sec. 34, T11 N, R10E, UM 8. KB (ft above MSL): 122.5' AMSL Ground (ft MSL): 81' AMSL 15. Field/Pool(s): Kuparuk River Field Total Depth: 1403' FSL, 1773' FWL, Sec. 3, T10N, R10E, UM 9. Plug Back Depth (MD + ND): 13054' MD / 3264' TVD West Sak Oil Pool • 4b. Location of Well (State Base Plane Coordinates): Surface: x- 558668.6 y- 5945827.5 Zone- 4 10. Total Depth (MD + ND): ° 13064' MD / 3264' TVD - 16. Property Designation: ALK 25660,' 25661, 25663 TPI: x- 552385 y- 5944157 Zone- 4 Total Depth: x- 552475 ~ - 5939889 • Zone- 4 11. SSSV Depth (MD + ND): nipple @ 505' MD / 498' ND 17. Land Use Permit: 470, 472 18. Directional Survey: Yes ^/ No ^ (Submit electronic and printed information per 20 AAC 25.050) 19. Water Depth, if Offshore: N/A (ft MSL) 20. Thickness of Permafrost (ND): 2183' ND 21. Logs Obtained (List all logs here and submit electronic and printed information per 20 AAC 25.071): ~j~i. (J~~W 7~p r1j8~ jZ?5!o • ~/D GR/RES, USIT ~D f =29 •o~ 22. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTH ND HOLE AMOUNT CASING SIZE WT. PER FT. GRADE TOP BOTTOM TOP BOTTOM SIZE CEMENTING RECORD PULLED 20" x 34" 78.6# H-40 40' 120' 40' 120' 42" 365 sx AS 1 13.375" 68# L-80 40' 3551' 40' 2190' 16" 513 sx Class G, 106 sx Class G, 48 sx Class G 9.625" 40# L-80 40' 9150' 40' 3340' 12.25" 735 sx DeepCRETE 4.5" 11.6# L-80 8519' 13055' 3247' 3264' 6.75" slotted/blank liner 23. Open to production or injection? Yes / No ^ If Yes, list each 24. TUBING RECORD Interval open (MD+ND of Top & Bottom; Pertoration Size and Number): SIZE DEPTH SET (MD) PACKER SET 4.5" 8357' 8519' alternating slotted liner from: • 8746'-9213' MD 3286'-3287' ND 25. ACID, FRACTURE, CEMENT SQUEEZE, ETC. 9600'-10152' MD 3315'-3303' TVD DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED 10409'-11010' MD 3291'-3276' ND na 11268'-11911' MD 3272'-3280' ND 12169'-13015' MD 3272'-3261' TVD 26. PRODUCTION TEST Date First Production waiting facility hook-up Method of Operation (Flowing, gas lift, etc.) pre-producing injection well -shares injection with 1J-160L2 Date of Test Hours Tested Production for Test Period --> OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO Flow Tubing press. psi Casing Pressure Calculated 24-Hour Rate -> OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY -API (corr) 27. CORE DATA Conventional Core(s) Acquired? Yes No ^/ Sidewall Cores Acquired? Yes ^ No / If Yes to either question, list forrnations and intervals cored (MD+ND of top and bottom of each), and summarize lithology and presence of oil, gas or water (Submit separate sheets with this form, if needed). Submit detailed descriptions, core chips, photographs and laboratory analytical results per 20 AAC 25.071. __ DAj•o'J NONE V6RIi^iE!? 3 Form 10-407 Revised 2/2007 ^ ~ ~ ~ ~ ~ ~ CONTINUED ON REVERSE SIDE ~ s.~•O'J 5 ~ h~A~ ~ ? ~D 7 ( ~ ~/~~ ~~ ~ 28. GEOLOGIC MARKERS (List all formations and ma s encountered): 29. FORMATION TESTS NAME MD TVD Well tested? ^ Yes ~ No If yes, list intervals and formations tested, Permafrost -Top ground surface ground surface briefly summarizing test results. Attach separate sheets to this form, if Permafrost -Bottom 3519' 2183' needed, and submit detailed test information per 20 AAC 25.071. T3 3519' 2183' K15 3519' 2183' Ugnu C 5973' 2709' Ugnu B 6742' 2873' Ugnu A 6924' 2913' K13 7622' 3067 West Sak D 8387' 3223' West Sak C 8620' 3264' West Sak B 8767' 3289' N/A 1 J-1601 P61 TD 9439' 3282' Formation at total depth: West Sak ' 30. LIST OF ATTACHMENTS Summary of Daily Operations, Directional Survey, slotted liner detail sheet 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Mike Greener @ 263-4820 Printed Na Ran Thomas Title: Drillino Team Leader ~~f0/O Signature t-~-oPhone 26~-6~3a Date INSTRUCTIONS Sharon Allsup-Drake General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. 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 and Ground level elevations in feet above mean sea level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). Item 20: Report true vertical thickness of permafrost in Box 20. Provide MD and TVD for the top and base of permafrost in Box 28. 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, or Other (explain). Item 27: Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Submit detailed description and analytical laboratory information required by 20 AAC 25.071. Item 29: Provide a list of intervals tested and the corresponding formation, and a brief summary of this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Form 10-407 Revised 2/2007 • Halliburton Company Survey Report Company: ConocoPhillips Alaskatnc. Date: 4l'Z612007 Time: '] 5:23:01 Page: 1 Field: Kuparuk River Unit Co-ordiuatetNE)Reference: WeII: 1J-160, Ti e North Site: Kuparuk 1J Pad VcrticaT~tl D) Re ference: 1J-160L1: 122.3 Well: 1 J-160 " Section (VS) Refer ence: WeII (O.OON,O.OOE,180.OOAzi) Wellpath: 1 ~I-160L1 Survey Calculation Alethod: Minimum Curvat ure ilh: Gracie Field: Kuparuk River Unit North Slope Alaska United States Map System:US State Plane Coordinate System 1927 Map Zone: Alaska, Zone 4 Geo Datum: NAD27 (Clarke 1866) Coordinate Sy stem: Well Centre Sys Datum: Mean Sea Level Geomagnetic Model: bggm2006 Well 1 J-160 Slot Name: ~ Well' Position: +N/-S -91.18 ft Northing: 5945827.52 ft Latitude: 70 15 45.361 N ,' +E/-W -122.08 ft Easti ng : 558668.60 ft Longitude: 149 31 32.559 W j Position Uncertainty: 0.00 ft Wellpath: 1J-160L1 Drilled From: 1J-160L1P61 500292334460 Tie-on Depth: 9170.51 ft j Current Datum: 1 J-160L1: Height 122.29 ft Above System Datum: Mean Sea Level Magnetic Data: 2/27/2007 Declination: 23.61 deg Field Strength: 57619 nT Mag Dip Angl e: 80.82 deg Vertical Section: Depth From (TVD) +N/-S +E/-W Direction ft ft ft deg 41.29 0.00 0.00 180.00 Survey Program for Definitive Wellpath Date: 4/26/2007 Validated: No Version: 5 Actual From To Survey Toolcode Tool Name ft ft 100.00 600.00 1 J-160 gyro (100.00 -600.00) (0 C B-GYRO-SS Camera based gyro sin gle shot ~I 666.10 8721.13 1J-160 (666.10-102 41.22) (0) M WD+IFR-AK-C AZ-SC MWD+IFR AK CAZ SC C i - 8750.00 9170.51 1J-160L1 P61 (8750 .00-9367.50) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 9200.00 13011.40 1J-160L1 (9200.00-13011.40) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC Survey _- :1zim TVD MD Incl Sys TVD N1S E/N' ~tapN ~tuph~. Tool ft deg deg ft ft ft ft ft ft 41.29 0.00 0.00 41.29 -81.00 0.00 0.00 5945827.52 558668.60 TIE LINE 100.00 0.15 293.36 100.00 -22.29 0.03 -0.07 5945827.55 558668.53 CB-GYRO-SS 200.00 0.59 243.72 200.00 77.71 -0.15 -0.65 5945827.37 558667.95 CB-GYRO-SS 300.00 3.54 277.00 299.92 177.63 0.00 -4.18 5945827.49 558664.42 CB-GYRO-SS 400.00 6.99 280.33 399.49 277.20 1.47 -13.23 5945828.89 558655.36 CB-GYRO-SS 500.00 10.60 279.01 498.29 376.00 4.00 -28.31 5945831.30 558640.26 CB-GYRO-SS 600.00 12.77 273.73 596.22 473.93 6.16 -48.42 5945833.30 558620.14 CB-GYRO-SS 666.10 15.31 273.65 660.34 538.05 7.19 -64.42 5945834.21 558604.13 MWD+IFR-AK-CAZ-SC 761.80 19.50 270.99 751.64 629.35 8.27 -93.02 5945835.07 558575.53 MWD+IFR-AK-CAZ-SC 856.80 21.31 271.11 840.67 718.38 8.88 -126.13 5945835.42 558542.41 MWD+IFR-AK-CAZ-SC 951.55 22.79 271.51 928.49 806.20 9.70 -161.69 5945835.96 558506.85 MWD+IFR-AK-CAZ-SC 1046.43 26.48 271.02 1014.72 892.43 10.56 -201.22 5945836.51 558467.32 MWD+IFR-AK-CAZ-SC 1140.73 28.46 269.82 1098.39 976.10 10.86 -244.72 5945836.48 558423.83 MWD+IFR-AK-CAZ-SC ~ 1236.43 30.07 270.84 1181.87 1059.58 11.14 -291.50 5945836.39 558377.05 MWD+IFR-AK-CAZ-SC 1331.29 34.01 271.18 1262.26 1139.97 12.04 -341.80 5945836.90 558326.75 MWD+IFR-AK-CAZ-SC 1427.82 38.94 273.79 1339.87 1217.58 14.60 -399.10 5945839.01 558269.43 MWD+IFR-AK-CAZ-SC 1522.70 40.38 275.76 1412.91 1290.62 19.66 -459.44 5945843.60 558209.07 MWD+IFR-AK-CAZ-SC 1616.58 42.50 273.46 1483.29 1361.00 24.63 -521.36 5945848.08 558147.11 MWD+IFR-AK-CAZ-SC ~, 1712.58 43.81 274.04 1553.32 1431.03 28.92 -586.88 5945851.87 558081.57 MWD+IFR-AK-CAZ-SC ~ 1807.77 49.26 274.61 1618.78 1496.49 34.15 -655.74 5945856.55 558012.67 MWD+IFR-AK-CAZ-SC 1903.13 51.56 271.96 1679.55 1557.26 38.33 -729.09 5945860.16 557939.30 MWD+IFR-AK-CAZ-SC 1996.53 56.44 269.59 1734.44 1612.15 39.30 -804.62 5945860.55 557863.78 MWD+IFR-AK-CAZ-SC i 2093.62 61.82 270.96 1784.24 1661.95 39.73 -887.92 5945860.33 557780.49 MWD+IFR-AK-CAZ-SC 2187.20 66.18 272.62 1825.25 1702.96 42.38 -971.96 5945862.32 557696.43 MWD+IFR-AK-CAZ-SC 2282.89 70.74 274.59 1860.38 1738.09 48.00 -1060.76 5945867.25 557607.60 MWD+IFR-AK-CAZ-SC 2378.18 73.48 273.77 1889.65 1767.36 54.60 -1151.19 5945873.15 557517.13 MWD+IFR-AK-CAZ-SC 2473.19 76.25 274.34 1914.45 1792.16 61.09 -1242.67 5945878.92 557425.61 MWD+IFR-AK-CAZ-SC Halliburton Company Survey Report Company:. ConocoPhillipSAlaska Inc. Date: 4f2612007 Time: 15:23:01 Page: 2 Field: Ku paruk River Unit Co-ordinaCe(NE) Reference: Weli: 1J-16 0, Tru e North Site: Ku paruk 1J Pad Vcrti cal(T'V D) Reference: 1J-160L1: 122.3 Well: 1J -160 Section (VS) Reterence: Well {O.OON;O.OO E,18000Azi) Wcilpath; 1J -160L1 Sun~ey Calc ulation ~Icthod: Minimum C urvature Db: Oracle ' Survey _-- - - _ __ MD lucl Azim TVD SysTVD ti/S E/W T•1apV n[apE luul ~! fr deg deg ft ft ft ft ft ft ~ 2569. 11 75.19 274. 37 1938. 11 1815.82 68. 15 -1335. 36 5945885. 26 557332. 88 MWD+IFR-AK-CAZ-SC ( 2664. 24 76.14 275. 44 1961. 67 1839.38 76. 03 -1427. 18 5945892. 42 557241. 00 MWD+IFR-AK-CAZ-SC I i 2758. 57 75.86 274. 88 1984. 49 1862.20 84. 26 -1518. 34 5945899. 94 557149. 80 MWD+IFR-AK-CAZ-SC 2851 .96 74.81 273. 90 2008. 13 1885.84 91. 18 -1608. 42 5945906. 16 557059. 67 MWD+IFR-AK-CAZ-SC 2948 .15 75.36 275. 64 2032. 89 1910.60 98. 91 -1701. 04 5945913. 17 556967 .00 MWD+IFR-AK-CAZ-SC 3044 .30 75.45 275. 64 2057. 12 1934.83 108. 06 -1793. 64 5945921. 59 556874 .35 MWD+IFR-AK-CAZ-SC j 3139 .49 70.69 275. 49 2084. 83 1962.54 116. 89 -1884. 25 5945929. 71 556783 .68 MWD+IFR-AK-CAZ-SC I 3208 .76 73.20 274. 22 2106. 30 1984.01 122. 45 -1949. 86 5945934. 77 556718 .03 MWD+IFR-AK-CAZ-SC I 3232 .39 74.16 273. 99 2112. 94 1990.65 124. 08 -1972. 48 5945936. 21 556695 .40 MWD+IFR-AK-CAZ-SC 3327 .00 76.38 273. 00 2136. 99 2014.70 129. 65 -2063. 81 5945941. 07 556604 .04 MWD+IFR-AK-CAZ-SC 3422 .91 77.13 270. 67 2158. 97 2036.68 132. 64 -2157. 11 5945943. 33 556510 .73 MWD+IFR-AK-CAZ-SC 3505 .57 74.33 271. 00 2179. 34 2057.05 133. 80 -2237. 20 5945943. 88 556430 .64 MWD+IFR-AK-CAZ-SC 3585 .63 76.30 269. 24 2199. 64 2077.35 133. 96 -2314. 64 5945943 .43 556353 .21 MWD+IFR-AK-CAZ-SC 3682 .35 78.55 269. 66 2220. 70 2098.41 133. 05 -2409. 03 5945941. 79 556258. 84 MWD+IFR-AK-CAZ-SC 3775 .98 79.30 270. 21 2238. 68 2116.39 132. 95 -2500. 92 5945940. 97 556166 .96 MWD+IFR-AK-CAZ-SC 3871 .49 77.27 268. 63 2258. 07 2135.78 132. 01 -2594. 42 5945939. 30 556073 .48 MWD+IFR-AK-CAZ-SC 3966 .38 76.90 270. 39 2279. 28 2156.99 131. 22 -2686. 91 5945937. 79 555981 .01 MWD+IFR-AK-CAZ-SC 4061 .25 77.27 270. 60 2300. 49 2178.20 132. 02 -2779. 37 5945937. 87 555888 .55 MWD+IFR-AK-CAZ-SC 4156 .45 78.17 272. 30 2320. 74 2198.45 134. 37 -2872. 36 5945939 .50 555795 .56 MWD+IFR-AK-CAZ-SC 4252 .44 78.17 271. 32 2340. 42 2218.13 137. 34 -2966. 26 5945941. 73 555701 .64 MWD+IFR-AK-CAZ-SC 4346 .85 78.17 271. 73 2359. 77 2237.48 139. 80 -3058. 63 5945943 .47 555609 .26 MWD+IFR-AK-CAZ-SC 4440 .64 77.21 270. 93 2379. 77 2257.48 141. 93 -3150. 24 5945944. 89 555517 .65 MWD+IFR-AK-CAZ-SC 4536 .81 76.27 271. 04 2401. 83 2279.54 143. 54 -3243. 83 5945945 .77 555424 .06 MWD+IFR-AK-CAZ-SC 4632 .22 77.79 271. 66 2423. 24 2300.95 145. 73 -3336. 78 5945947 .23 555331 .11 MWD+IFR-AK-CAZ-SC 4726 .71 77.53 272. 00 2443. 43 2321.14 148. 68 -3429. 04 5945949 .46 555238 .84 MWD+IFR-AK-CAZ-SC 4821 .96 76.83 273. 07 2464. 57 2342.28 152. 78 -3521. 82 5945952 .84 555146 .03 MWD+IFR-AK-CAZ-SC I 4916 .93 78.61 274. 80 2484. 77 2362.48 159. 15 -3614. 39 5945958 .49 555053 .43 MWD+IFR-AK-CAZ-SC 5011 .45 78.41 274. 77 2503. 60 2381.31 166. 88 -3706. 69 5945965 .50 554961 .07 MWD+IFR-AK-CAZ-SC 5106 .28 77.10 275. 39 2523. 71 2401.42 175. 09 -3799. 00 5945972. 99 554868 .72 MWD+IFR-AK-CAZ-SC 5202 .19 78.22 275. 38 2544. 21 2421.92 183. 88 -3892. 28 5945981. 05 554775 .38 MWD+IFR-AK-CAZ-SC 5296 .10 78.29 274. 82 2563. 32 2441.03 192. 05 -3983. 86 5945988 .51 554683 .75 MWD+IFR-AK-CAZ-SC 5388 .25 77.28 274. 64 2582. 82 2460.53 199. 48 -4073. 62 5945995. 24 554593 .95 MWD+IFR-AK-CAZ-SC li 5485 .00 77.47 274. 47 2603. 97 2481.68 206. 98 -4167. 73 5946002 .00 554499 .79 MWD+IFR-AK-CAZ-SC ~ 5583 .88 77.34 273. 88 2625. 53 2503.24 214. 00 -4263. 97 5946008 .27 554403 .50 MWD+IFR-AK-CAZ-SC 5678 .36 77.98 273. 66 2645. 72 2523.43 220. 07 -4356. 07 5946013 .62 554311 .37 MWD+IFR-AK-CAZ-SC 5777 .05 78.04 269. 67 2666. 23 2543.94 222. 87 -4452. 54 5946015 .68 554214 .88 MWD+IFR-AK-CAZ-SC 5868 .89 77.16 266. 73 2685. 95 2563.66 220. 06 -4542. 19 5946012 .16 554125 .27 MWD+IFR-AK-CAZ-SC 5963 .84 77.66 265. 63 2706. 65 2584.36 213. 89 -4634. 64 5946005 .27 554032 .88 MWD+IFR-AK-CAZ-SC 6059 .13 77.55 263. 42 2727. 11 2604.82 205. 01 -4727. 28 5945995 .67 553940 .32 MWD+IFR-AK-CAZ-SC 6154 .34 77.86 262. 17 2747. 38 2625.09 193. 34 -4819. 57 5945983 .29 553848 .13 MWD+IFR-AK-CAZ-SC 6249 .56 77.92 260. 43 2767. 36 2645.07 179. 26 -4911. 60 5945968 .49 553756 .23 MWD+IFR-AK-CAZ-SC 6344 .64 77.66 256. 98 2787. 47 2665.18 161. 06 -5002. 71 5945949 .58 553665 .27 MWD+IFR-AK-CAZ-SC 6439 .37 77.83 253. 45 2807. 59 2685.30 137. 44 -5092. 20 5945925 .27 553575 .97 MWD+IFR-AK-CAZ-SC 6534 .39 77.79 248. 57 2827. 66 2705.37 107. 23 -5180. 00 5945894 .38 553488 .42 MWD+IFR-AK-CAZ-SC ~ ' 6630 .46 77.47 244. 65 2848. 25 2725.96 69. 98 -5266. 11 5945856 .47 553402 .61 MWD+IFR-AK-CAZ-SC 6725 .46 77.34 241. 24 2868. 97 2746.68 27. 82 -5348. 66 5945813 .67 553320 .40 MWD+IFR-AK-CAZ-SC 6819 .15 77.27 238. 32 2889. 57 2767.28 -18. 18 -5427. 63 5945767 .06 553241 .80 MWD+IFR-AK-CAZ-SC 6914 .80 76.77 235. 22 2911. 06 2788.77 -69. 24 -5505. 59 5945715 .39 553164 .25 MWD+IFR-AK-CAZ-SC ' 7010 .91 77.79 233. 52 2932. 22 2809.93 -123. 86 -5581. 78 5945660 .19 553088 .49 MWD+IFR-AK-CAZ-SC 7105 .85 76.88 231. 23 2953. 04 2830.75 -180 .40 -5655. 14 5945603 .08 553015 .58 MWD+IFR-AK-CAZ-SC 7201 .03 76.96 228. 08 2974. 58 2852.29 -240 .41 -5725. 79 5945542 .53 552945 .40 MWD+IFR-AK-CAZ-SC 7295 .69 77.80 223. 74 2995. 27 2872.98 -304. 67 -5792. 12 5945477 .76 552879 .59 MWD+IFR-AK-CAZ-SC 7391 .01 77.53 220. 85 3015. 64 2893.35 -373. 54 -5854. 78 5945408 .41 552817 .47 MWD+IFR-AK-CAZ-SC j Halliburton Company Survey Report Company: ConocoPhiliips Alaska lnc. Date. 4!26/2007 Time: 75:23:01 Page 3 Field: Kuparuk River Unit Co-ordi»ate(NE}Reference: Well: 1J-160, True North Site: Kuparuk 1J Pad Vertical (TVD) Reference: 1J-160L1: 122.3 Well: 1J-160 Section (VS) Reference: Weli (O.OON,O.OOE,180.OOAzi) Wellpath: 1J-160L1 .Survey E'aMulation Alethod: Minimum Curvature Db: Oracle Sint c~ >1i) Inc! Aim TVD Syc TVD N/S F,/~L' A1apiY NTapE Tnol '~ ft deg rieg ft ft ft ft ft ft 7485.86 77.16 218.95 3036.42 2914.13 -444.54 -5914.14 5945336.96 552758.67 MWD+IFR-AK-CAZ-SC I 7579.69 77.15 216.43 3057.29 2935.00 -516.92 -5970.06 5945264.15 552703.32 MWD+IFR-AK-CAZ-SC 7674.68 77.28 211.84 3078.32 2956.03 -593.58 -6022.03 5945187.10 552651.96 MWD+IFR-AK-CAZ-SC 7770.42 77.15 207.30 3099.51 2977.22 -674.76 -6068.09 5945105.57 552606.53 MWD+IFR-AK-CAZ-SC 7866.83 77.27 203.67 3120.86 2998.57 -759.61 -6108.54 5945020.41 552566.75 MWD+IFR-AK-CAZ-SC 7962.10 77.22 200.77 3141.90 3019.61 -845.62 -6143.67 5944934.14 552532.29 MWD+IFR-AK-CAZ-SC 8056.00 77.79 196.74 3162.23 3039.94 -932.41 -6173.14 5944847.13 552503.51 MWD+IFR-AK-CAZ-SC 8151.22 78.98 192.83 3181.40 3059.11 -1022.57 -6196.93 5944756.80 552480.42 MWD+IFR-AK-CAZ-SC ~ 8246.11 79.80 190.56 3198.88 3076.59 -1113.90 -6215.83 5944665.34 552462.23 MWD+IFR-AK-CAZ-SC j 8340.39 80.30 189.08 3215.17 3092.88 -1205.40 -6231.67 5944573.73 552447.11 MWD+IFR-AK-CAZ-SC 8436.16 79.61 189.65 3231.87 3109.58 -1298.44 -6247.01 5944480.57 552432.50 MWD+IFR-AK-CAZ-SC 8531.29 80.04 188.99 3248.68 3126.39 -1390.84 -6262.17 5944388.07 552418.05 MWD+IFR-AK-CAZ-SC 8627.07 79.43 189.05 3265.75 3143.46 -1483.92 -6276.95 5944294.89 552404.01 MWD+IFR-AK-CAZ-SC 8721.13 80.86 187.17 3281.85 3159.56 -1575.66 -6290.02 5944203.06 552391.65 MWD+IFR-AK-CAZ-SC • 8750.00 81.27 186.74 3286.33 ~ 3164.04 -1603.97 -6293.47 5944174.72 552388.42 MWD+IFR-AK-CAZ-SC 8774.81 82.14 187.71 3289.91 3167.62 -1628.32 -6296.56 5944150.35 552385.52 MWD+IFR-AK-CAZ-SC i 8873.67 91.11 188.31 3295.72 3173.43 -1725.95 -6310.30 5944052.63 552372.54 MWD+IFR-AK-CAZ-SC 8972.96 92.59 190.39 3292.52 3170.23 -1823.86 -6326.42 5943954.60 552357.19 MWD+IFR-AK-CAZ-SC I 9070.68 91.42 187.38 3289.10 3166.81 -1920.33 -6341.50 5943858.02 552342.86 MWD+IFR-AK-CAZ-SC 9170.51 90.56 188.43 3287.37 3165.08 -2019.20 -6355.23 5943759.06 552329.91 MWD+IFR-AK-CAZ-SC 9200.00 91.00 187.87 3286.97 3164.68 -2048.39 -6359.41 5943729.85 552325.95 MWD+IFR-AK-CAZ-SC 9269.53 83.75 185.99 3290.15 3167.86 -2117.29 -6367.79 5943660.89 552318.11 MWD+IFR-AK-CAZ-SC 9368.16 86.04 180.90 3298.94 3176.65 -2215.31 -6373.68 5943562.83 552312.98 MWD+IFR-AK-CAZ-SC ~ 9466.72 84.68 180.06 3306.91 3184.62 -2313.54 -6374.50 5943464.61 552312.93 MWD+IFR-AK-CAZ-SC 9565.43 86.54 179.32 3314.46 3192.17 -2411.95 -6373.97 5943366.21 552314.23 MWD+IFR-AK-CAZ-SC j 9664.78 90.80 176.38 3316.77 3194.48 -2511.17 -6370.24 5943267.03 552318.73 MWD+IFR-AK-CAZ-SC 9764.24 90.00 173.88 3316.08 3193.79 -2610.26 -6361.80 5943168.02 552327.94 MWD+IFR-AK-CAZ-SC 9864.15 91.48 171.78 3314.78 3192.49 -2709.38 -6349.33 5943069.02 552341.18 MWD+IFR-AK-CAZ-SC 9962.30 90.37 168.32 3313.20 3190.91 -2806.02 -6332.38 5942972.52 552358.88 MWD+IFR-AK-CAZ-SC 10061.02 93.95 168.58 3309.48 3187.19 -2902.66 -6312.63 5942876.05 552379.38 MWD+IFR-AK-CAZ-SC i 10159.98 92.41 166.40 3303.99 3181.70 -2999.11 -6291.23 5942779.77 552401.53 MWD+IFR-AK-CAZ-SC I 10258.44 95.13 168.21 3297.52 3175.23 -3094.94 -6269.64 5942684.12 552423.87 MWD+IFR-AK-CAZ-SC 10357.44 91.17 176.80 3292.07 3169.78 -3192.84 -6256.77 5942586.34 552437.49 MWD+IFR-AK-CAZ-SC '~ 10457.44 90.49 177.69 3290.62 3168.33 -3292.71 -6251.97 5942486.52 552443.08 MWD+IFR-AK-CAZ-SC ~ 10555.30 95.26 179.94 3285.71 3163.42 -3390.39 -6249.94 5942388.86 552445.86 MWD+IFR-AK-CAZ-SC i 10653.52 90.06 184.11 3281.15 3158.86 -3488.39 -6253.41 5942290.85 552443.15 MWD+IFR-AK-CAZ-SC 10752.38 93.21 183.75 3278.33 3156.04 -3586.96 -6260.19 5942192.24 552437.15 MWD+IFR-AK-CAZ-SC 10851.20 89.20 184.88 3276.25 3153.96 -3685.46 -6267.62 5942093.70 552430.49 MWD+IFR-AK-CAZ-SC 10947.39 89.29 185.22 3277.52 3155.23 -3781.27 -6276.08 5941997.83 552422.77 MWD+IFR-AK-CAZ-SC i 11045.92 92.86 185.99 3275.67 3153.38 -3879.29 -6285.70 5941899.75 552413.91 MWD+IFR-AK-CAZ-SC 11144.59 89.28 185.22 3273.83 3151.54 -3977.46 -6295.34 5941801.52 552405.05 MWD+IFR-AK-CAZ-SC ~~ 11243.44 91.82 183.77 3272.88 3150.59 -4075.99 -6303.08 5941702.94 552398.07 MWD+IFR-AK-CAZ-SC 11342.41 88.85 182.92 3272.30 3150.01 -4174.78 -6308.86 5941604.12 552393.07 MWD+IFR-AK-CAZ-SC 11440.91 90.52 177.97 3272.85 3150.56 -4273.24 -6309.62 5941505.67 552393.07 MWD+IFR-AK-CAZ-SC 11539.97 91.14 169.08 3271.41 3149.12 -4371.56 -6298.46 5941407.45 552404.99 MWD+IFR-AK-CAZ-SC 11638.35 86.75 168.01 3273.22 3150.93 -4467.94 -6278.94 5941311.23 552425.27 MWD+IFR-AK-CAZ-SC 11737.30 88.85 175.05 3277.02 3154.73 -4565.67 -6264.39 5941213.62 552440.58 MWD+IFR-AK-CAZ-SC 11835.45 89.10 179.29 3278.78 3156.49 -4663.66 -6259.54 5941115.68 552446.18 MWD+IFR-AK-CAZ-SC 11935.45 89.16 178.65 3280.30 3158.01 -4763.63 -6257.74 5941015.74 552448.76 MWD+IFR-AK-CAZ-SC j 12034.75 91.51 185.91 3279.71 3157.42 -4862.78 -6261.69 5940916.57 552445.59 MWD+IFR-AK-CAZ-SC 12134.05 94.41 186.36 3274.59 3152.30 -4961.37 -6272.29 5940817.91 552435.76 MWD+IFR-AK-CAZ-SC 12232.58 93.05 180.98 3268.17 3145.88 -5059.45 -6278.58 5940719.80 552430.24 MWD+IFR-AK-CAZ-SC Halliburton Company Survey Report Company: ConocoPhillips Alaska Inc. Date: 4/26/2007 'time: 15:23:01 I'a~c: 4 Field: Kuparuk Rivet Unit Co-o rdinate(NE)Reference: WeII: 1J-160, Tr ue North Site: ki~paruklJ Pad Verti cal (TVD)Reference: 1J-160L1:122.3 WeII: 1J-160 Section (VS)Reference: Well (O.OON,O.OOE;180-OOAzi) Wellpath: 1J-160L1 Survey Calculation Method: Minimum Curvat ure Db: oracle Su rve~~ ___ _ -_ MD Incl ~.zim TVD -_ Svs T~'D V!S __ E/W 11iapN _ >ViapE ' Tool ft deg deg ft ft ft ft ft ft 12331.01 92.74 174.82 3263.20 3140.91 -5157.64 -6274.97 5940621.65 552434.60 MWD+IFR-AK-CAZ-SC 12429.78 91.88 173.16 3259.22 3136.93 -5255.78 -6264.64 5940523.60 552445.70 MWD+IFR-AK-CAZ-SC 12527.77 90.77 174.28 3256.95 3134.66 -5353.15 -6253.93 5940426.32 552457.17 MWD+IFR-AK-CAZ-SC 12627.35 92.19 179.70 3254.38 3132.09 -5452.52 -6248.70 5940327.00 552463.17 MWD+IFR-AK-CAZ-SC 12719.84 88.23 176.22 3254.04 3131.75 -5544.92 -6245.41 5940234.64 552467.18 MWD+IFR-AK-CAZ-SC 12821.93 89.22 180.12 3256.31 3134.02 -5646.91 -6242.15 5940132.69 552471.23 MWD+IFR-AK-CAZ-SC 12917.05 88.91 179.90 3257.86 3135.57 -5742.02 -6242.17 5940037.59 552471.96 MWD+IFR-AK-CAZ-SC 13011.40 86.88 178.55 3261.33 3139.04 -5836.29 -6240.89 5939943.34 552473.97 MWD+IFR-AK-CAZ-SC ~ ~ 13064.00 86.88 178.55 3264.19 3141.90 -5888.80 -6239.56 5939890.86 552475.71 PROJECTED to TD ~ ~ Halliburton Company Survey Report Company: ConocoPhillips Alaska Inc . Date: 4/26/2007 Timc: 15:11:50 Paae: 1 Field: Kuparuk River Unit Co -ordinate(NE) Reference: Well: 1 J-160, T rue North Site: Kuparuk 1J Pad Vertlcal(TVD) Rc fcrcnce: 1J-160L1PB1 : 122.3 We1L• 1J-160 Section(VS)Reterence: Well,(O:OON,O.OOE,180.OOAzI) Wellpath: 1 J-160L1 PB1 Survey Calculatio n Method: Minimum Cutvature llb: Oracle Field: Kuparuk River Unit _ _- North Slope Alaska United States Map System:US State Plane Coordinate System 1927 Map Zone: Alaska, Zone 4 i; Geo Datum: NAD27 (Clarke 1866) Coordinate Sy stem: Well Centre i ~ Sys Datum: Mean Sea Level Geomagnetic Model: bggm2006 ~~ 1 Welt: 1J-160 Slot Name: Well Position: +N/-S -91.18 ft North ing: 594582 7.52 ft Latitude: 70 15 45.361 N +E/-W -122.08 ft Easting : 558668.60 ft Longitude: 149 31 32.559 W Positron Uncertainty: 0.00 ft Wellpath: 1 J-160L1 PB1 Drilled From: 1 J-160 500292334470 Tie-on Depth: 8721.13 ft ~ Current Datum: 1 J-160L1 P61 : Height 122.29 ft Above System Datum: Mean Sea Level Magnetic Data: 2/27!2007 Declination: 23.61 deg Field Strength: 57619 nT Mag Dip Angle: 80.82 deg ~ ~ Vertical Section: Depth From (TVD) +N/-S +E/-W Direction j ft ft ft deg 41.29 0.00 0.00 180.00 !~, Survey Program for Definitive Wellpa th Date: 4/26/2007 Validated: No V ersion: 2 Actual From To Survey Toolcode Tool Name ft ft 100.00 600.00 1 J-160 gyro (100.00-600.00) (0 CB-GYRO-SS Camera based gyro single shot 666.10 8721.13 1J-160 (666.10-10241.22) (0) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 8750.00 9367.50 1J-160L1P61 (8750. 00-9367.50) - MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC Survey _ __ __ M11D incl Azim TVD Sys "1'VD N/S E/M1V MapN MapE Tool ft deg deg ft ft ft ft ft ft 41.29 0.00 0.00 41.29 -81.00 0.00 0.00 5945827.52 558668.60 TIE LINE 100.00 0.15 293.36 100.00 -22.29 0.03 -0.07 5945827.55 558668.53 CB-GYRO-SS ~ i 200.00 0.59 243.72 200.00 77.71 -0.15 -0.65 5945827.37 558667.95 CB-GYRO-SS I 300.00 3.54 277.00 299.92 177.63 0.00 -4.18 5945827.49 558664.42 CB-GYRO-SS ~ 400.00 6.99 280.33 399.49 277.20 1.47 -13.23 5945828.89 558655.36 CB-GYRO-SS 500.00 10.60 279.01 498.29 376.00 4.00 -28.31 5945831.30 558640.26 CB-GYRO-SS 600.00 12.77 273.73 596.22 473.93 6.16 -48.42 5945833.30 558620.14 CB-GYRO-SS 666.10 15.31 273.65 660.34 538.05 7.19 -64.42 5945834.21 558604.13 MWD+IFR-AK-CAZ-SC 761.80 19.50 270.99 751.64 629.35 8.27 -93.02 5945835.07 558575.53 MWD+IFR-AK-CAZ-SC 856.80 21.31 271.11 840.67 718.38 8.88 -126.13 5945835.42 558542.41 MWD+IFR-AK-CAZ-SC 951.55 22.79 271.51 928.49 806.20 9.70 -161.69 5945835.96 558506.85 MWD+IFR-AK-CAZ-SC 1046.43 26.48 271.02 1014.72 892.43 10.56 -201.22 5945836.51 558467.32 MWD+IFR-AK-CAZ-SC I 1140.73 28.46 269.82 1098.39 976.10 10.86 -244.72 5945836.48 558423.83 MWD+IFR-AK-CAZ-SC I 1236.43 30.07 270.84 1181.87 1059.58 11.14 -291.50 5945836.39 558377.05 MWD+IFR-AK-CAZ-SC 1331.29 34.01 271.18 1262.26 1139.97 12.04 -341.80 5945836.90 558326.75 MWD+IFR-AK-CAZ-SC 1427.82 38.94 273.79 1339.87 1217.58 14.60 -399.10 5945839.01 558269.43 MWD+IFR-AK-CAZ-SC 1522.70 40.38 275.76 1412.91 1290.62 19.66 -459.44 5945843.60 558209.07 MWD+IFR-AK-CAZ-SC ~ 1616.58 42.50 273.46 1483.29 1361.00 24.63 -521.36 5945848.08 558147.11 MWD+IFR-AK-CAZ-SC 1712.58 43.81 274.04 1553.32 1431.03 28.92 -586.88 5945851.87 558081.57 MWD+IFR-AK-CAZ-SC 1807.77 49.26 274.61 1618.78 1496.49 34.15 -655.74 5945856.55 558012.67 MWD+IFR-AK-CAZ-SC I 1903.13 51.56 271.96 1679.55 1557.26 38.33 -729.09 5945860.16 557939.30 MWD+IFR-AK-CAZ-SC ' 1996.53 56.44 263.59 1734.44 1612.15 39.30 -804.62 5945860.55 557863.78 MWD+IFR-AK-CAZ-SC 2093.62 61.82 270.96 1784.24 1661.95 39.73 -887.92 5945860.33 557780.49 MWD+IFR-AK-CAZ-SC 2187.20 66.18 272.62 1825.25 1702.96 42.38 -971.96 5945862.32 557696.43 MWD+IFR-AK-CAZ-SC 2282.89 70.74 274.59 1860.38 1738.09 48.00 -1060.76 5945867.25 557607.60 MWD+IFR-AK-CAZ-SC 2378.18 73.48 273.77 1889.65 1767.36 54.60 -1151.19 5945873.15 557517.13 MWD+IFR-AK-CAZ-SC 2473.19 76.25 274.34 1914.45 1792.16 61.09 -1242.67 5945878.92 557425.61 MWD+IFR-AK-CAZ-SC 2569.11 75.19 274.37 1938.11 1815.82 68.15 -1335.36 5945885.26 557332.88 MWD+IFR-AK-CAZ-SC Halliburton Company Survey Report __ Company: ConocoPhillips Alaska lnc. llatc: 4/26.12007 .. __ Time: 15:11:50 _ _ __ Page: 2 Field: Ku paruk River Uni t Co-or dinate(NEp Reference: WeII: 1J-16 0, T rue North Site: Kuparuk 1J Pad y'crtical(TVD)Referencr. 1J-160C1PB1 : 122.3 '~ Well: 1J -160 Section (VS)12eference: WeII (O.OON,O.OOE,180.OOAzi) Wellpath: 1 J -160L1 P61 Survey Calculation Method: Minimum C urvature 111,: Oracle Sui~~rc \lU - Ins{ _ _ azim TVD -- SysTV D N/S EIW b1apN A1apE foul ft deg de g ft ft ft ft ft ft 2664. 24 76.14 275 .44 1961. 67 1839. 38 76. 03 -1427.18 5945892. 42 557241. 00 MWD+IFR-AK-CAZ-SC 2758. 57 75.86 274 .88 1984. 49 1862. 20 84. 26 -1518.34 5945899. 94 557149. 80 MWD+IFR-AK-CAZ-SC 2851. 96 74.81 273 .90 2008. 13 1885. 84 91. 18 -1608.42 5945906. 16 557059. 67 MWD+IFR-AK-CAZ-SC 2948. 15 75.36 275 .64 2032. 89 1910. 60 98. 91 -1701.04 5945913. 17 556967. 00 MWD+IFR-AK-CAZ-SC 3044. 30 75.45 275 .64 2057. 12 1934. 83 108. 06 -1793.64 5945921. 59 556874. 35 MWD+IFR-AK-CAZ-SC ~ 3139. 49 70.69 275 .49 2084. 83 1962. 54 116. 89 -1884.25 5945929. 71 556783. 68 I MWD+IFR-AK-CAZ-SC ~ 3208. 76 73.20 274 .22 2106. 30 1984. 01 122. 45 -1949.86 5945934. 77 556718. 03 MWD+IFR-AK-CAZ-SC 3232. 39 74.16 273 .99 2112. 94 1990. 65 124. 08 -1972.48 5945936. 21 556695. 40 MWD+IFR-AK-CAZ-SC 3327. 00 76.38 273 .00 2136. 99 2014. 70 129. 65 -2063.81 5945941. 07 556604. 04 MWD+IFR-AK-CAZ-SC 3422. 91 77.13 270 .67 2158. 97 2036. 68 132. 64 -2157.11 5945943. 33 556510. 73 MWD+IFR-AK-CAZ-SC 3505. 57 74.33 271 .00 2179. 34 2057. 05 133. 80 -2237.20 5945943. 88 556430. 64 MWD+IFR-AK-CAZ-SC ~ 3585. 63 76.30 269 .24 2199. 64 2077. 35 133. 96 -2314.64 5945943. 43 556353. 21 MWD+IFR-AK-CAZ-SC 3682. 35 78.55 269 .66 2220. 70 2098. 41 133. 05 -2409.03 5945941. 79 556258. 84 MWD+IFR-AK-CAZ-SC 3775. 98 79.30 270 .21 2238. 68 2116. 39 132. 95 -2500.92 5945940. 97 556166. 96 MWD+IFR-AK-CAZ-SC 3871. 49 77.27 268 .63 2258. 07 2135. 78 132. 01 -2594.42 5945939. 30 556073. 48 MWD+IFR-AK-CAZ-SC j 3966. 38 76.90 270 .39 2279. 28 2156. 99 131. 22 -2686.91 5945937. 79 555981. 01 MWD+IFR-AK-CAZ-SC 4061. 25 77.27 270 .60 2300. 49 2178. 20 132. 02 -2779.37 5945937. 87 555888. 55 MWD+IFR-AK-CAZ-SC 4156. 45 78.17 272 .30 2320. 74 2198. 45 134. 37 -2872.36 5945939. 50 555795. 56 MWD+IFR-AK-CAZ-SC 4252. 44 78.17 271 .32 2340. 42 2218. 13 137. 34 -2966.26 5945941. 73 555701. 64 MWD+IFR-AK-CAZ-SC 4346. 85 78.17 271 .73 2359. 77 2237. 48 139. 80 -3058.63 5945943. 47 555609. 26 MWD+IFR-AK-CAZ-SC 4440. 64 77.21 270 .93 2379. 77 2257. 48 141. 93 -3150.24 5945944. 89 555517. 65 MWD+IFR-AK-CAZ-SC 4536. 81 76.27 271 .04 2401. 83 2279. 54 143. 54 -3243.83 5945945. 77 555424. 06 MWD+IFR-AK-CAZ-SC i 4632. 22 77.79 271 .66 2423. 24 2300. 95 145. 73 -3336.78 5945947. 23 555331. 11 MWD+IFR-AK-CAZ-SC 4726. 71 77.53 272 .00 2443. 43 2321. 14 148. 68 -3429.04 5945949. 46 555238. 84 MWD+IFR-AK-CAZ-SC 4821. 96 76.83 273 .07 2464. 57 2342. 28 152. 78 -3521.82 5945952. 84 555146. 03 MWD+IFR-AK-CAZ-SC ~ 4916. 93 78.61 274 .80 2484. 77 2362. 48 159. 15 -3614.39 5945958. 49 555053. 43 MWD+IFR-AK-CAZ-SC 5011. 45 78.41 274 .77 2503. 60 2381. 31 166. 88 -3706.69 5945965. 50 554961. 07 MWD+IFR-AK-CAZ-SC 5106, 28 77.10 275 .39 2523. 71 2401. 42 175. 09 -3799.00 5945972. 99 554868. 72 MWD+IFR-AK-CAZ-SC 5202. 19 78.22 275 .38 2544. 21 2421. 92 183. 88 -3892.28 5945981. 05 554775. 38 MWD+IFR-AK-CAZ-SC 5296. 10 78.29 274 .82 2563. 32 2441. 03 192. 05 -3983.86 5945988. 51 554683. 75 MWD+IFR-AK-CAZ-SC 5388. 25 77.28 274 .64 2582. 82 2460. 53 199. 48 -4073.62 5945995. 24 554593. 95 MWD+IFR-AK-CAZ-SC i 5485. 00 77.47 274 .47 2603. 97 2481. 68 206. 98 -4167.73 5946002. 00 554499. 79 MWD+IFR-AK-CAZ-SC 5583. 88 77.34 273 .88 2625. 53 2503. 24 214. 00 -4263.97 5946008. 27 554403. 50 MWD+IFR-AK-CAZ-SC 5678. 36 77.98 273 .66 2645. 72 2523. 43 220. 07 -4356.07 5946013. 62 554311. 37 MWD+IFR-AK-CAZ-SC 5777. 05 78.04 269 .67 2666. 23 2543. 94 222. 87 -4452.54 5946015. 68 554214. 88 MWD+IFR-AK-CAZ-SC 5868. 89 77.16 266 .73 2685. 95 2563. 66 220. 06 -4542.19 5946012. 16 554125. 27 MWD+IFR-AK-CAZ-SC 5963. 84 77.66 265 .63 2706. 65 2584. 36 213. 89 -4634.64 5946005. 27 554032. 88 MWD+IFR-AK-CAZ-SC 6059. 13 77.55 263 .42 2727. 11 2604. 82 205. 01 -4727.28 5945995. 67 553940. 32 MWD+IFR-AK-CAZ-SC 6154 .34 77.86 262 .17 2747. 38 2625. 09 193. 34 -4819.57 5945983. 29 553848. 13 MWD+IFR-AK-CAZ-SC 6249 .56 77.92 260 .43 2767. 36 2645. 07 179. 26 -4911.60 5945968. 49 553756. 23 MWD+IFR-AK-CAZ-SC 6344 .64 77.66 256 .98 2787. 47 2665. 18 161. 06 -5002.71 5945949. 58 553665. 27 MWD+IFR-AK-CAZ-SC 6439. 37 77.83 253 .45 2807. 59 2685. 30 137. 44 -5092.20 5945925. 27 553575 .97 MWD+IFR-AK-CAZ-SC 6534. 39 77.79 248 .57 2827. 66 2705. 37 107. 23 -5180.00 5945894. 38 553488. 42 MWD+IFR-AK-CAZ-SC 6630. 46 77.47 244 .65 2848. 25 2725. 96 69. 98 -5266.11 5945856. 47 553402. 61 MWD+IFR-AK-CAZ-SC 6725. 46 77.34 241 .24 2868. 97 2746. 68 27. 82 -5348.66 5945813. 67 553320. 40 MWD+IFR-AK-CAZ-SC 6819. 15 77.27 238 .32 2889. 57 2767. 28 -18. 18 -5427.63 5945767. 06 553241. 80 MWD+IFR-AK-CAZ-SC ~I 6914. 80 76.77 235 .22 2911. 06 2788. 77 -69. 24 -5505.59 5945715. 39 553164. 25 MWD+IFR-AK-CAZ-SC 7010 .91 77.79 233 .52 2932. 22 2809. 93 -123. 86 -5581.78 5945660. 19 553088 .49 MWD+IFR-AK-CAZ-SC 7105. 85 76.88 231 .23 2953. 04 2830. 75 -180. 40 -5655.14 5945603. 08 553015. 58 MWD+IFR-AK-CAZ-SC 7201 .03 76.96 228 .08 2974. 58 2852. 29 -240. 41 -5725.79 5945542. 53 552945 .40 MWD+IFR-AK-CAZ-SC 7295 .69 77.80 223 .74 2995. 27 2872. 98 -304. 67 -5792.12 5945477 .76 552879 .59 MWD+IFR-AK-CAZ-SC 7391 .01 77.53 220 .85 3015. 64 2893. 35 -373. 54 -5854.78 5945408 .41 552817 .47 MWD+IFR-AK-CAZ-SC Halliburton Company Survey Report v Company: C,onocoPhillips Alaska Ine. Date: 4/26/2007 Time: 15:11:50 Page: 3 Field: Kuparuk RiverUnit Co-ordinate(NF)Reference: Well: 1J-160, True North Site:'> KuparuklJPad Vertical ('i'Vll)Rcference: 1J-160L1PB1.122.3 WeIL• 1J-160 ''Secfion (VS)Reference: Well (O.OON,O.OOE,180.OOAzl1 Weltpath: 1J-160L1PB1 SurveyCakulationl`IeYhod: Minimum Curvature ' Db: Oracle Survev MD Iucl Azi~n TVD Sys TVD N/S E/N' D1apN MapE Tool ft deg deg ft ft ft ft ft it ~ 7485.86 77.16 218.95 3036.42 2914.13 -444.54 -5914.14 5945336.96 552758.67 MWD+IFR-AK-CAZ-SC i, 7579.69 77.15 216.43 3057.29 2935.00 -516.92 -5970.06 5945264.15 552703.32 MWD+IFR-AK-CAZ-SC 7674.68 77.28 211.84 3078.32 2956.03 -593.58 -6022.03 5945187.10 552651.96 MWD+IFR-AK-CAZ-SC 7770.42 77.15 207.30 3099.51 2977.22 -674.76 -6068.09 5945105.57 552606.53 MWD+IFR-AK-CAZ-SC 7866.83 77.27 203.67 3120.86 2998.57 -759.61 -6108.54 5945020.41 552566.75 MWD+IFR-AK-CAZ-SC j 7962.10 77.22 200.77 3141.90 3019.61 -845.62 -6143.67 5944934.14 552532.29 MWD+IFR-AK-CAZ-SC 8056.00 77.79 196.74 3162.23 3039.94 -932.41 -6173.14 5944847.13 552503.51 MWD+IFR-AK-CAZ-SC 8151.22 78.98 192.83 3181.40 3059.11 -1022.57 -6196.93 5944756.80 552480.42 MWD+IFR-AK-CAZ-SC 8246.11 79.80 190.56 3198.88 3076.59 -1113.90 -6215.83 5944665.34 552462.23 MWD+IFR-AK-CAZ-SC 8340.39 80.30 189.08 3215.17 3092.88 -1205.40 -6231.67 5944573.73 552447.11 MWD+IFR-AK-CAZ-SC 8436.16 79.61 189.65 3231.87 3109.58 -1298.44 - -6247.01 5944480.57 552432.50 MWD+IFR-AK-CAZ-SC 8531.29 80.04 188.99 3248.68 3126.39 -1390.84 -6262.17 5944388.07 552418.05 MWD+IFR-AK-CAZ-SC 8627.07 79.43 189.05 3265.75 3143.46 -1483.92 -6276.95 5944294.89 552404.01 MWD+IFR-AK-CAZ-SC 8721.13 80.86 187.17 3281.85 3159.56 -1575.66 -6290.02 5944203.06 552391.65 MWD+IFR-AK-CAZ-SC 8750.00 81.27 186.74 3286.33 3164.04 -1603.97 -6293.47 5944174.72 552388.42 MWD+IFR-AK-CAZ-SC 8774.81 82.14 187.71 3289.91 3167.62 -1628.32 -6296.56 5944150.35 552385.52 MWD+IFR-AK-CAZ-SC 8873.67 91.11 188.31 3295.72 3173.43 -1725.95 -6310.30 5944052.63 552372.54 MWD+IFR-AK-CAZ-SC ~ 8972.96 92.59 190.39 3292.52 3170.23 -1823.86 -6326.42 5943954.60 552357.19 MWD+IFR-AK-CAZ-SC 9070.68 91.42 187.38 3289.10 3166.81 -1920.33 -6341.50 5943858.02 552342.86 MWD+IFR-AK-CAZ-SC 9170.51 90.56 188.43 3287.37 3165.08 -2019.20 -6355.23 5943759.06 552329.91 MWD+IFR-AK-CAZ-SC ~ 9269.09 92.04 186.56 3285.14 3162.85 -2116.90 -6368.08 5943661.27 552317.81 MWD+IFR-AK-CAZ-SC 9439.00 90.74 183.00 3281.82 3159.53 2286.32 6380.02 5943491.78 552307.20 ODJECTEDKto D SC ~ ~ Time Logs_ Date From. To Dur S Depth E Depth Phase Codz `jubcode T COM_ -- - - -_ 03/17/2007 20:00 20:45 0.75 9,009 9,009 INTRM1 DRILL DHEQ P Pickup 4"subs and lifters from beaver slide while ri u to test 9-5/8" casin . 20:45 21.:15 0.50 9,009 9,009 INTRM1 DRILL TRIP P Pull a stand of 5"drill pipe: Change. out elevators to 4", rig up skate. extension @ the rig floor. PU a single 't of 4". 21:15 22:15 1.00 9,009 9,009 INTRM1 CASINC OTHR P Fill stack with water: Rig up hos, gunge and fittings to test 9-5/8" casin . 22:15 23:30 1.25 9,009 9,009 INTRM1 CASINC DHEQ P " Test 9-5/8" 40 ppf L-80 BTGcasing. Chart test. Pumping down annulus and drillpipe @ 6 spm. Also testing the upper rams (variable 3-1 /2" x 6" with 4" drill pipe). Test rams low to 250 psi f/ 5 min. Continue to test casing to 3000 psi. Hold test f/ 30 min. Chart test. 23:30 00:00 0.50 9,009 9,009 INTRM1 WELCT BOPS P Test annular to 250 psi and 3000 psi with a joint of 4".drill pipe. Chart test. Test to 250 psi low f/ 5 min. then 3000 si hi h f/ 5 min. OK. 03/18/2007 00:00 00:30 0.50 9,009 9,009 INTRM1 WELCT ROPE P Finish testing annular to 250 psi.and 3000 psi with a joint of 4"drill pipe. - Chart test: Test to 250 psi low f/ 5 min. then X3000 si hi h f/ 5 min. OK. 00:30 01:30 1.00 9,009 8,911 INTRM1 WELCT OTHR P Rig down lines after testing. Blow down kill line. Lay down 4" drill pipe to the pipe shed: Change elevators to 5°. MU to drive connection. 01:30 02:00 0.50 8,911 8,911 INTRM1 DRILL CIRC P Pumped a 25 bbl dry job. Pumped @ 6bpm w/ 530 psi. PU wt 195k, SO wt 110k, Rot wt 155k. Blow down top drive. 02:00 06:00 4.00 8,911 5,550 INTRM1 DRILL TRIP P Pull out of hole w/ BHA #5. Inspecting and moving super sliders to fit in fingers in derrick board. Inspecting LoTads, SLM, record PU and slack off weights. Pick up Centurian circulating valve to rig floor PU a short cut off joint of 4-1/2" 12.6ppf L-80 IBT tubing to be run with the whipstock to the rig floor. 06:00 07:30 1.50 5,550 4,561 INTRM1 DRILL TRIP P Pull out of hole w/ BHA #5. Inspecting and moving super sliders to fit in fingers in derrick board. Inspecting LoTads, SLM, record PU and slack off wei hts. 07:30 09:15 1.75 4,561 185 INTRM1 DRILL TRIP P Pull out of hole w/ BHA #5. SLM, record PU and slack off wei hts. 09:15 09:30 0.25 185 0 INTRM1 DRILL PULD P Stand back 2 stands of 5" HWDP. Lay down bit sub, break bit. 09:30 10:00 0.50 0 0 INTRM1 DRILL OTHR P Clear and clean rig floor. 10:00 10:15 0.25 0 0 I NTRM1 CASINC SFTY P Pre job safety meeting on running the permenant whipstock assembly to drill "B" lateral. --- - - Pc'~L~E:S~3'JF~a.. Time Logs i Date From To Dur S Depth E De~~th Phase CodE S~ibco~le T COM 03/18/2007 10:15 10:45 0.50 0 0 PROD2 CASINC RURD P Rig up GBR tongs to run the cut off jt and 9 jts of 4-1/2" 12.6 ppf L-80 IBT-m tubin below the whi stock. 10:45 11:00 0.25 0 292 PROD2 CASINC RNCS P Run 9 joints+ cut offjoint of 4-1/2" 12.6 f L-80 IBT-m tubin . 11:00 11:15 0.25 292 292 PROD2 CASINC RURD P Rig down GBR tongs and tools. 11:15 12:00 0.75 292 314 PROD2 .CASINC RUNL P Make up the crossover, bottom trip anchor, and the 9-5/8".Gen 2 Whipstock slide. Note: This assembly will be left in the hole setting on top of wiper rubbers which were to ed 9064'. 12:00 13:15 1.25 314 385 PROD2 FISH PULD P PU/MU 8-1/2" window miU, bit sub, upper string mill (8-1/2"), 1jt 5" HWDP, float sub, then Sperry Sun .MWD. 13:15 13:45 0.50 385 385. PROD2 FISH OTHR P Upload Sperry Sun MWD. 13:45 14:15 0.50 385 455 PROD2 FISH PULD P Continue to PU/MU BHA #6: Bumper sub, 2 "oints 5" HWDP. 14:15 14:30 0.25 455 455 PROD2 FISH OTHR P Shallow test MWD, OK. Pumping 600 m w/ 900 si. Blow down to drive. 14:30 18:00 3.50 455 5,143 PROD2 FISH TRIP P Trip in hole w/ permenant whipstock assembly f/ "B" lateral. RIH w/ 5" dp to 5143'. Record PU and So wt's. 18:00 18:45 0.75 5,143 5,143 PROD2 RIGMN SVRG P Service top drive. Closed manual valves on BOP stack. 18:45 20:30 1.75 5.,143 7,910 PROD2 FISH TRIP P Continue RIH w! BHA.#6. Running s eed 95'/min. 20:30 21:15 0.75 7,910 7,950 PROD2 FISH OTHR P .Fill pipe. Increase pump rate to 650 gpm w/ 2950 psi. Mad pass f/ bottom. of assembly @ 7910' to 7950'. Gamma f/ 7550' to 7590'. Log @ 3'/min T80'/hr 21:15 22:00 0.75 7,950 8,968 PROD2 FISH TRIP P Continue RIH w/ BHA #6: Running speed 95'/min. 22:00 23:00 1.00 8,968 9,064 PROD2 FISH OTHR P Orient whipstock while working pipe f/ 8968' to 9055'. PU wt 190k, SO wt 115k. Pumping 550 gpm w/ 2170 psi. Oriented until 17L. Make a connection and slack off to tag top of wiper rubbers @ 9064' w/ bottom of assembly. Set down 15k to set anchor, set down 25k, PU to 10k overpull. Slack off 50k to shear mills free of whi stock. 23:00 23:15 0.25 8,750 8,750 PROD2 FISH OTHR P Pickup above whipstock top @ 8750', obtain parameters.. Rotate @ 90 rpm w! 8k ft Ibs torque. Rot wt 145k. PU wt 185k, SO wt 115k. 23:15 00:00 0.75 8,750 8,754 PROD2 FISH MILL P Milling on 9-5/8" 40 ppf L-80 BTC-m casing f/ the window f/the "B" lateral. Rotating 90 rpm w/ 8-11 k ft Ib torque, running 2k weight on mills. Pumping_ 545 m w/ 2150 si. a.~ _ - ' __ .._~ ~ ~ ~a;~e ~~ o :~ Tirnc Logs __ ! Dafe__ Frc~m_ __To _ Dur___ S- D~o;n E DaE~th Phase _Code Subco~e T CO~~~__ __ _ ___ 03/19/2007 00:00 03:00 3.00 8,754 8,767 PROD2 FISH MILL P Milling on 9-5/8" 40 ppf L-80 BTC-m casing f/the window f/the "B" lateral. Rotating 100-110 rpm w/ 8-11 k ft Ib torque, running 3-6k weight on mills. Pumping 545 gpm w/ 2150 psi. Pumped a 40 bbls 10.4 ppg 185 vis sweep while millin 8758'. 03:00 03:45 0.75 8,767 8,782 PROD2 FISH MILL P Milling on 9-5/8" 40 ppf L-80 BTC-m casing f/the window f/the "B" lateral. Rotating 110 rpm w/ 8k ft lb torque, running 5-6k weight on mills. Pumping 545 m w/ 2150 si. 03:45 04:15 0.50 8,782 8,782 PROD2 FISH MILL P Work mills through window, cleaning up window. TOW @ 8750' (3286' TVD , BOW 8767 (3289' ND) 04:15 04:30 0.25 8,782 8,787 PROD2 FISH MILL P Milling 8-1/2" open hole. Rotating 90 rpm w/ 8-11 k ft Ib torque, running 2-5k weight on mills. Pumping 545 gpm w/ 2150 psi. Pumped a 40 bbls 10.4 ppg 185 vis swee while millin 8782'. 04:30 05:15 0.75 8,787 8,787 PROD2 FISH CIRC P Continue to circulate and work window w/milling assembly while circulate sweep to surfaces Pumping 545 gpm w/ 2150 psi.. 05:15 06:00 0.75 8,787 8,741 PROD2 FISH OTHR T POOH above window. Prepare to stand back stand # 90. While attempting to break off stand. # 90, pumps were still running. Had a unplanned release of mineral oil base mud to rig floor (secondary containment) and windwalls around the rig floor, partially broke off stand # 90 f/ stand #89.. Estimated spill @ 3 bbls (126 gals). Rig time to clean up alf OBM from the ri floor. 06:00 10:15 4.25. 8,741 8,741 PROD2 FISH OTHR T Cleaning rig floor and windwalls from spill. Circ hole while cleaning. Pum in 560 m w/ 2150 psi. 10:15 10:45. 0.50 8,741. 8,741 PROD2 DRILL CIRC P Continue to circulate prior to LOT. 10:45 12:00 1.25 8,741 8,741 PROD2 DRILL LOT P Blow down top drvie. Rig up to perform LOT after drilling 20' of new hole below bottom of window f/ "B" lateral. LOT = 14 ppg. TOW @ 8750' (3286.33'), BOW @ 8767 (3288.87) Open hole to 8787 (3291.77 TVD}. 12:00. 12:30 0.50 8,741. 8,741 PROD2 DRILL LOT P Blow down kill line. Close manual valve on kill line. Rig down testing. e uipment. 12:30 12:45 0.25 8,741 8,741 PROD2 FISH TRIP P Monitor well, static.. 12:45 13:15 0.50 8,741 8,741 PROD2 FISH CIRC P Pump 25 bbl dry job. Blow.down top drive. Install stripper rubbers. Pumped d 'ob 6 b m w/ 550 si. 13:15 15:00 1.75 8,741 6,904 PROD2 FISH TRIP P POOH w/ BHA #6 (8-1/2" mills). Inspect and clean IoTads and super sliders ~ ,_ ®_~ ~s~ ~ .~ _. P~~t~o ~~ er =a ~ • Tirne Logs ~ Dare From To Dur S, D~pfh E De to Phase Code 5_ih~ode T_ COM 03/19/2007 15:00 18:00 3.00 6,904 1,523. PROD2 FISH TRIP P Continue to POOH w/ BHA #6., 18:00 19:00 1.00 1,523 141 PROD2 FISH TRIP P Continue to POOH wl BHA #6. 19:00 19:45 0.75 141 71 PROD2 FISH PULD P Lay down 2 joints of 5" H1NDP and bumper ~ars. 19:45 20:15 0.50 71 71 PROD2 FISH OTHR P Download Sperry Sun MWD. 20:15 21:15 1.00 71 0 PROD2 FISH PULD P Finish Paying down milling BHA. 21;15 22:00 0.75 0 0 PROD2 FISH PULD P Remove Baker mills from floor. Clear and clean ri floor. 22°00 22:30. 0.50. 0 0 PROD2 WELCT OTHR P Rig up, then pull Vetco/Gray wear bushing (13-3l8" ODx 9" ID x 38'° Ion ). 22:30 23:30 1.00 0 0 PROD2 WELCT OTHR P Rig up then flush stack out with stack washing tool, after milling operations. Blow through choke and HCR lines. Perform weekly function test of Annular, upper pipe rams, kill HCR and choke HCR and blind rams, OK. 23:30 00:00 0.50 0 0 PROD2 WELCT OTHR P Iristall Vetco/Gray wear bushing (13-3/8" OD x 9" ID x 38" long). Rig down runnin tools. 03/20/2007 00:00 01:00 1..00 0 0 PROD2 DRILL PUtD P Pickup tools and equipment for BHA #7. 01:00 01:15 0.25 0 0 PROD2 DRILL SFTY P Pre job safety meeting on picking up BHA #7. 01:15 03:00 1.75 0 97 PROD2 DRILL PULD P PU/MU BHA #7. 03:00 03:30 0.50 97 97 PROD2 DRILL OTHR P Upload Sperry Sun MWD. 03:30 04:30 1.00 97 220 PROD2 DRILL PULD P PU/MU BHA #7. 04:30 05:00 0.50 220 220 PROD2 DRILL OTHR P Shallow test MWD. Pump 280 gpm w/ 1550 si. Blow down lines. 05:00 05:45 0.75 220 283. PROD2 DRILL PULD P Continue PU/MU BHA #7. 05:45 06:15 0.50 283 283 PROD2 RIGMN SVRG P Service traveling equipment 06:15 09:00 2.75 283 283. PROD2 RIGMN' RGRP T Repair leak on hydraulic cylinder on to drive. Service travelin a uipment. 09:00 11:45 2.75 283 1,837 PROD2 DRILL PULD P PU/MU 48 jts of 4"drill pipe from pipe shed, rabbit to 2-3/8", PU/MU crossover, agitator, shock sub and crossover, then fill pipe, test agitator @.1837. Pumping 330 gpm w/2780 psi. 11:45 13:00 1.25 1,837 1,837 PROD2 DRILL PULD NP . Lay down agitator, PU another agitator, test same pumping 330 gpm w/ 2700 psi. Sperry Sun MWD tested ok 1837. • • Time Lo~s_ I ~ Date From To Dur S D~r~fh E De th Phase Code Subcode T C~OM ~~ 03/20/2007 13:00 15:30 2.50 1,837 3;588 PROD2 DRILL PULD P PU/MU 57 jts of 4"drill pipe from pipe shed, rabbit to 2-3/8". Fill pipe. Pumping 315 gpm w/ 2990 psi. Rig down pumping ,equipment and blow down. Sperry Sun MWD tested ok @ 3584'. 15:30 16:30 1.00 3,588 4,544 PROD2 DRILL .PULD P PU/MU 30 jts of 4"drill pipe from pipe shed, rabbit to 2-3/8". MU crossover to 5" drill pipe, MU Centurian circulation valve, 1630 18:00 1.50 .4,544 5,495 PROD2 DRILL. TRIP P Clean floor, install airslips. Continue to RIH f/derrick w/ 5"drift pipe filling every 20 stands. Sperry Sun MWD tested ok 5486'. 18:00 20:00 2.00 5,495 8,550 PROD2 DRILL TRIP P Continue trip in the hole recording PU and SO wt's every 10 stands. Fill pipe . @ 7382'. Sperry Sun MWD tested ok. RIH to 8550'. 20:00 20:15 0.25 8,550 8,550 PROD2 DRILL OTHR P Blow down top drive.: .20:15 20:30 0.25 8,550 8,550 PROD2 RIGMN SFTY P Fre job safety meeting on cutting drillin line.: 20:30 22:15 1.75 8,550 8,550 PROD2 RIGMN SVRG P Slip and cut 104' of 1-3/8"drilling line. Install new brass in deadman tie down. Inspect brakes, reset crown o matic. 22:15 23:15 1.00 8,550. 8,749 PROD2 DRILL TRIP P Make top drive connection. and orient. to 14 left. PU wt 160k, SO wt 115k. RIH to 8653'. Then top drive connection, RIH to top of the window pumping 316 gpm w/ 3150 psi. Sperry sun updates takin 6-7 min. 23:15 23:45 0:50 8,749 8,777 PROD2 DRILL TRIP T Make top drive connection, RIH w/o pumping to 8777; then try to pump up survey's, too much noise. Swapped ' pumps, isolated pumps, checked pulsation dampner pressures. Nothing ' im roved detection. 23:45 00:00 0.25 8,777 8,600 PROD2 DRILL TRIP T POOH to continue to trouble shoot S er Sun MWD detection roblems. 03/21/2007 00:00 00:15 0.25 8,600 8,600 PROD2 DRILL CIRC T Establish circulation, trouble shoot Sperry Sun MWD detection problems.. Detection was ood. 00:15 01:00 0.75 8,600 8,747 PROD2 DRILL TRIP T Run back in the hole pumping. 01:00 01:15 0.25 8,747 8,787 PROD2 DRILL TRIP P RIH w/o pumps. Establish circulation, 01:15 06:00 4.75 8,787 9,044 PROD2 DRILL DDRL P Directional drill "B" lateral Concretion drilled @ 8794' to 8797 (3'), 8800' to 8803' (3'), 8878' to 8890' 12' , 8982' to 8984' (2'). 06:00 09:00 3.00 9,044 9,200 PROD2 DRILL DDRL. P Directional di-ill. "B" lateral. Concretion drilled @ 9053' to 9058` 5',9169'to9172'(3'. ---°-- : - ~ _a__ .._.. .__ ~~ - ~ ~_ Time Logs .Date. From To Dur S Depth E. De th Phase Code Subcode T COM ~ 03/21/2007 09:00 12:15 3.25 9,200 9,439 PROD2 DRILL DDRL P Directional drill "B" lateral. Note: Out of pay f! 9255' to 9439' (184'), Fault w/ a 35' throw. 8" thick sand. 12:15 13:00 0.75 9,439 9,150 PROD2 STK TRIP NP POOH f/sidetrack. 13:00 13:30 0.50 9,150 9,200 PROD2 STK KOST NP Trough f/ sidetrack. 13:30 14:15 0.75 9,200 9,215 PROD2 STK KOST NP Time drill. 14:15 17:15 3.00 9,215 9,439 PROD2 DRILL DDRL NP Directional drill "B" lateral. Note: Out of pay f/ 9255' to 9542' (287'), Fault w/ a 35' throw. 8" thick sand after sidetrack. 17:15 00:00 6.75 9,439 9,632 PROD2 DRILL DDRL P Continue to directional drill "B" lateral. Concretion drilled @ 9592' to 9604' 12' , 9622' to 9630' 8' . 03/22/2007 00:00 06:00 6.00 9,632 9,935 PROD2 DRILL DDRL P Continue to directional drill "B" lateral. Concretion drilled @ 9808' to 9810' 2'). 06:00 12:00 6.00 9,935 10,291 PROD2 DRILL DDRL P Continue to directional drill "B" lateral. Concretions drilled @ 10202' to 10211' (9'), 10226' to 10238' (12'), 10245' to 10247' 2' . 12:00 18:00 6.00 10,291 10,528 PROD2 DRILL DDRL P Continue to directional drill "B" lateral. Concretions drilled @ 10400' to 10403' (3'), 10 406' to 10410' (4'), 10517' to 10519' 2' . 18:00 00:00 6.00 10,528 10,627 PROD2 DRILL DDRL P Continue to directional drill "B" lateral. 03/23/2007 00:00 06:00 6.00 10,627 10,923 PROD2 DRILL DDRL P Continue to directional drill "B" lateral. 06:00 09:30 3.50 10,923 11,000 PROD2 DRILL DDRL P Continue to directional drill "B" lateral. 09:30 10:00 0.50 11,000 11,000 PROD2 DRILL CIRC P Pump 35 bbls high vis sweep (8.9 ppg w/ 185 vis . 10:00 12:00 2.00 11,000 10,827 PROD2 DRILL REAM P Back ream while circ sweep out of the hole. 12:00 15:30 3.50 10,827 8,653 PROD2 DRILL TRIP P Trip out on elevators. No extra drag ullin throu h window. 15:30 15:45 0.25 8,653 8,653 PROD2 DRILL OWFF P Observe well for flow. OK. 15:45 16:15 0.50 8,653 8,653 PROD2 DRILL CIRC P Pump 25 bbl dry job (10.5 ppg w/ 60 vis), blow down to drive. 16:15 16:45 0.50 8,653 8,356 PROD2 DRILL TRIP P POOH 16:45 17:00 0.25 8,356 8,356 PROD2 DRILL OTHR P Decision to test ROPE after setting a 9-5/8" storm packer, and using a test lu in the wellhead. Clean floor. 17:00 17:30 0.50 8,356 8,356 PROD2 WELCT OTHR P PUlMU Baker "EA" Retrievamatic Storm packer. Install on top of stand # 85, RIH and set top of stub @ 163' below rotary table. Center of element @ 175.63', bottom of assembly @ 181.92'.40k wt hanging on packer. PU wt 160k, SO wt 118k. ~ ~~_ ~... ®~ _ ~ m.n m i Time Logs Date __ From To Dur S. De th E. DEpth Phase Code Subcode T COM _ _ 03/23/2007 17:30 _ 18:00 0.50 8,356 _ 8,564 _ PROD2 __ WELCT _ TRIP P RIH 2 stands and set top of stub @ 163' below rotary table. Center of element @ 175.63', bottom of assembly @ 181.92'.40k wt hanging on acker. PU wt 160k, SO wt 118k. 18:00 18:30 0.50 8,564 0 PROD2 WELCT TRIP P Pull out of hole 2 stands. Stand # 85 in the hole. 18:30 19:00 0.50 0 0 PROD2 WELCT BOPE P Test Baker "EA" Retrievamatic Storm packer to 1000 psi f/ 5 minutes, OK. Center of element @ 175.63', bottom of assembly @ 181.92'.40k wt hanging on acker. 19:00 21:00 2.00 0 0 PROD2 WELCT OTHR P Drain stack. Puli wear bushing, rig up to test BOPE. Fill stack with water. Perform body test (300 psi and 3000 psi) with Annular and outside valves on choke manifold and outside kill valve w/ 5" drill pipe. Replace a needle valve on testin manifold. 21:00 23:15 2.25 0 0 PROD2 WELCT BOPE P 14 day BOPE test. Witness of test waived by AOGCC rep Chuck Scheve. Test w/ 5" test joint: Test annular, upper pipe rams (3-1/2" x 6" variables), choke manifold, 4" and 5" floor safety valves, upper and lower IBOP valves on the top drive, inside and outside kill line valves. Pull test joint and test blind rams. All tests @ 300 psi low and 3000 psi high. Chart tests. Test accumulator. Valve #5 on choke manifold failed to open (stem threads ulled/worn out). 23:15 00:00 0.75 0 0 PROD2 WELCT BOPE P Pull 5" test joint, install 4" test joint. Working to repair valve #5 on choke manifold. 03/24/2007 00:00 01:15 1.25 0 0 PROD2 WELCT BOPE P Working to repair valve #5 on choke manifold. Test upper pipe rams (3-1/2" x 6") and annular with 4" test joint. Test choke inside and outside valves. Test valve # 5 in the choke manifold. Test all to 300 psi low and 3000 psi hi h. Hold each test 5 min. Chart test. 01:15 01:45 0.50 0 0 PROD2 WELC OTHR P Pull test plug, drain stack, MU wear bushing and install same. Run in lockdown screws. 01:45 02:15 0.50 0 0 PROD2 WELCT OTHR P Rig down testing equipment. Blow down choke manifold and kill line. 02:15 02:45 0.50 0 0 PROD2 DRILL OTHR P Clear and clean rig floor. Prepare to make u Baker overshot. 02:45 03:00 0.25 0 0 PROD2 DRILL SFTY P PJSM on making up overshot to pull storm acker. 03:00 03:15 0.25 0 0 PROD2 FISH PULD P MU Baker overshot to pull storm acker. 03:15 04:15 1.00 0 0 PROD2 RIGMN SVRG P Lay down overshot. Service and inspect top drive, blocks and crown. Service drawworks, inspect drawworks chains. _~-~ ~~.~ ~ v _ ~__ _ ~~~e 2~ of ~~l ~~ _ Time Logs _ Date _ From To Dur S De~th_ E Depth__Phase___Code Subcode T COM --- 03/24/2007 04:15 05:45 1.50 0 0 PROD2 RIGMN' RGRP NP Remove a hydraulic cylinder on top drive for the link tilt. Rebuild seals and install on to drive. 05:45 06:00 0.25 0 0 PROD2 FISH PULD P MU Baker overshot to pull storm acker. 06:00 06:30 0.50 0 0 PROD2 FISH TRIP P Trip in the hole w/ stand # 86 and #87. Install floor safety valve between second and third single. Tag up w/ overshot. 06:30 07:00 0.50 0 8,564 PROD2 FISH FISH P Rotate and engage packer, shear screws and open rotational equalizing valve, break off single, open TIW valve, slight suction on drill pipe (no pressure below packer), make up single, pickup 5' monitor well, static. 07:00 07:30 0.50 8,564 8,356 PROD2 FISH TRIP P Break off Floor safety valve. MU single. POOH w/ fishing assembly and storm packer. Lay down Baker "EA" retievamatic storm acker. 07:30 10:30 3.00 8,356 4,544 PROD2 DRILL TRIP P Monitor well. Pull out of hole w/ BHA #7. Lay down Centurian circulating sub. Never did drop any balls to open. Chan a elevators to 4". 10:30 13:00 2.50 4,544 1,807 PROD2 DRILL TRIP P Continue to POOH w/ BHA #7 to the antler ua e a itator. 13:00 14:00 1.00 1,807 1,784 PROD2 DRILL OTHR P Install a crossover and MU the top drive to pump and check out pressure drop w/the agitator in and out of the string. Lay down agitator and shock sub. With out the agitator: 300 gpm = 1700 psi, 330 gpm = 1970 psi. With the agitator :300 gpm = 2310 psi, 330 gpm = 2760 psi. 610 psi dill @ 300 gpm, 790 psi dill @ 330 m. 14:00 14:30 0.50 1,784 1,784 PROD2 DRILL CIRC P Pump a 20 bbl dry job (10.5 ppg, 68 vis .Blow down to drive. 14:30 15:30 1.00 1,784 255 PROD2 DRILL TRIP P Continue to POOH w/ BHA #7. 15:30 16:30 1.00 255 193 PROD2 DRILL PULD P Lay down jars. PU hydraulic jars w/ bumper sub and stand back in the derrick. 16:30 17:00 0.50 193 97 PROD2 DRILL TRIP P Pull a stand of flex collars. 17:00 18:00 1.00 97 97 PROD2 DRILL OTHR P Download Sperry Sun MWD. 18:00 19:45 1.75 97 0 PROD2 DRILL PULD P Lay down BHA #7. On trip out: hole fill 29.5 bbls over calculated. Note: Lower bearing housing sleeve, above bit sub on the motor was dama ed. Bit in ua e. 19:45 20:15 0.50 0 0 PROD2 DRILL OTHR P Clear and clean rig floor. 20:15 21:45 1.50 0 93 PROD2 DRILL PULD P PU/MU BHA#8. -Time Logs _ Date From To Dur S. Depth E. D_Epth Phase Code Subcode T COM ___ __ 03/24/2007 21:45 22:30 0.75 93 93 PROD2 DRILL OTHR P Upload Sperry Sun MWD. 22:30 23:00 0.50 93 278 PROD2 DRILL TRIP P Continue to MU BHA #8. 23:00 23:45 0.75 278 278 PROD2 DRILL OTHR P Shallow pulse test MWD. Break in seals on geopilot w/ 25 rpm. Blow down to drive. 23:45 00:00 0.25 278 1,120 PROD2 DRILL TRIP P Trip in the hole w/ BHA #8. 03/25/2007 00:00 02:15 2.25 1,120 4,590 PROD2 DRILL TRIP P Trip in the hole w/ BHA #8. Fill pipe every 25 stands. Record PU and SO wt's every 10 stands. While filling pipe break in seals on Geo ilot. 02:15 03:00 0.75 4,590 4,606 PROD2 DRILL PULD P Change elevators to 5". PU and install Centurian circulating valve. Install 5" air sli s. 03:00 06:00 3.00 4,606 9,279 PROD2 DRILL TRIP P Trip in the hole w/ BHA #8. Fill pipe every 25 stands. Record PU and SO wt's every 10 stands. While filling pipe break in seals on Geopilot. Start taking Cassandra survey's @ 9181' and 9279' bit de th. Did not use. 06:00 07:00 1.00 9,279 9,444 PROD2 DRILL TRIP P Continue trip in the hole w/ BHA #8. Fill pipe every 25 stands. Record PU and SO wt's every 10 stands. While filling pipe break in seals on Geopilot. Cassandra survey @ 9378' bit depth. Did not use. Went into sidetracked hole (9200' to 9439' . 07:00 07:30 0.50 9,444 9,110 PROD2 DRILL TRIP NP POOH above sidetracked hole. 07:30 11:45 4.25 9,110 11,000 PROD2 DRILL REAM P Ream back in the hole to bottom. The Cassandra survey's kept and will be used is 10947' surve de th.. 11:45 12:00 0.25 11,000 11,031 PROD2 DRILL DDRL P Directional drill "B" lateral w/ BHA #8. Max as 485 units. 12:00 18:00 6.00 11,031 11,367 PROD2 DRILL DDRL P Directional drill "B" lateral w/ BHA #8. Max as 358 units. 18:00 22:15 4.25 11,367 11,578 PROD2 DRILL DDRL P Directional drill "B" lateral w/ BHA #8. Max as 365 units 22:15 22:45 0.50 11,578 11,578 PROD2 DRILL SRVY P Stand back a stand, then check survey's @ 11440', 11496', and 11539'. Then ream back to bottom. Survey's were good. Showed to be turning left 5 degrees, then another 8 degrees, resulting in a 3 deg dogleg, 5.3 deg dogleg and 9 deg dogleg. Drilled a 13' concretion @ 11468' to 11481', and a 5' concretion 11341' to 11346'. 22:45 00:00 1.25 11,578 11,676 PROD2 DRILL DDRL P Directional drill "B" lateral w/ BHA #8. Max as 304 units. 03/26/2007 00:00 06:00 6.00 11,676 12,130 PROD2 DRILL DDRL P Directional drill "B" lateral w! BHA #8. Max as 304 units. 06:00 12:00 6.00 12,130 12,665 PROD2 DRILL DDRL P Directional drill "B" lateral w/ BHA #8. Max as 450 units. ~. ew~ ~~......~ ~a~~, .2~~ at ~~ • ~~ '- Time Lomas ___ _ ` Date___ ___From To Dur S _Depth E,De~th__Phase___Code___ Subcode T COM_____ 03/26/2007 12:00 15:00 3.00 12,665 13,064 PROD2 DRILL DDRL P Directional drill "B" lateral w/ BHA #8. Max as 450 units. 15:00 17:30 2.50 13,064 13,064 PROD2 DRILL CIRC P Pump hi vis sweep. 17:30 00:00 6.50 13,064 9,815 PROD2 DRILL REAM P Backream out of the hole. Record PU and SO wt's eve 5 stands. 03/27/2007 00:00 02:45 2.75 9,815 8,750 PROD2 DRILL REAM P Backream out of the hole. Record PU and SO wt's eve 5 stands. 02:45 03:30 0.75 8,750 8,710 PROD2 DRILL PULD T Found a washout on stand # 89. Pin of LoTad (ser # 258282) and box of single DP. UD Lotad, replace joint of 5"drill i e. 03:30 06:00 2.50 8,710 8,710 PROD2 DRILL CIRC P Circulate while recip. Rotate 130 rpm w/ 6-7k ft/Ib torque, Pumping 315 gpm w/ 2250 psi. PU wt 165k, SO wt 112k, Rot wt 135k.Crew Chan e 06:00 07:00 1.00 8,710 8,710 PROD2 RIGMN SVRG P Prepare to RIH. Inspect & service Top Drive & traveling assembly. Monitor well -static. 07:00 09:30 2.50 8,710 13,064 PROD2 DRILL TRIP P Install Super Slider on replaced drill pipe joint. Trip in hole from 8710' - 13064'. Observed clean hole & no issues. Filf drill string @ 10688'. Hole fill = 4 BBL loss on TIH. 09:30 11:45 2.25 13,064 13,064 PROD2 DRILL CIRC P Fill drill string. Rotate & reciprocate drill string while pumping 30 BBL Hi-Visc sweep @ 300 GPMs- 2430 PSI. ECD = 9.92 PPG. 11:45 12:00 0.25 13,064 13,064 PROD2 DRILL CIRC P Drop 2 1/8" ball in drill string, make up stand. 12:00 12:15 0.25 13,064 13,064 PROD2 DRILL CIRC P Pump ball down until observed seating in CCV Valve @ 725 strokes. Pressure to 2150 PSI observing valve o enin . 12:15 13:30 1.25 13,064 13,064 PROD2 DRILL CIRC P Continue circulate @ 900 GPM's 3050 PSI cleaning hole while reciprocate & rotate drill strip . 13:30 14:45 1.25 13,064 13,064 PROD2 DRILL CIRC NP Phase III weather declared at 1300 HRS. Continue reciprocate & rotate drill string while circulating @ 900 GPM's - 3050 PSI. 14:45 15:15 0.50 13,064 13,064 PROD2 DRILL CIRC NP Break out single of DP. Drop #2 - 2 1/8" ball in drill string.Pump ball down until observed seating in CCV valve. Pressure to 2300 PSI to shift valve closed. 15:15 18:00 2.75 13,064 13,064 PROD2 DRILL CIRC NP Continue reciprocate & rotate drill string while circulating well waiting on Phase III weather conditions. Circulate @ 300 GPM's - 2430 PSI. Crew Chan a in Convo . 18:00 19:45 1.75 13,064 13,064 PROD2 DRILL CIRC NP Continue reciprocate & rotate drill string while circulating well waiting on Phase III weather conditions. Circulate 300 GPM's - 2430 PSI. ~~~~ zx ~~~:~a • Time Lis ___ - - - Date - From T o - Dur S_ Depth, E D~h_ Phase-_ Code Subcode -- T _ - - _ C_OM - 03/28/2007 13:30 17:00 3.50 0 4,546 COMPZ CASIN( RNCS P Make up 3 1/2" float shoe & joint with crossover. Continue RIH from pipe shed with 4 1/2" 11.6 PPF L80 slotted / blank liner assembly to 4546' MD. Record T & D parameters every 10 'oints of liner as er ri en ineer. 17:00 17:30 0.50 4,546 4,546 COMPZ CASINC RNCS P Make up BOT Flexlock liner hanger & ZXP liner top packer assembly as per BOT re . 17:30 18:00 0.50 4,546 4,546 COMPZ CASINC RURD P Rig down GBR casing running equipment, rig up to run DP. Crew Chan e 18:00 00:00 6.00 4,546 11,943 COMPZ CASIN RUNL P Run 4 1/2" slotted liner assembly on drill pipe from 4546' - 11943' at 1 1/2 - 2 minutes a stand as per BOT rep. Continue record T & D parameters as per rig engineer every 5 stands Observe ro er hole fill. 03/29/2007 00:00 01:30 1.50 11,943 13,055 COMPZ CASINC RUNL P Continue run 4 1/2" slotted liner on DP from 11943' - 13055' .Rotate liner down starting at a depth of 12324' to bottom with 30 RPM's - 6K ft/Ibs of torque. Contiue obtain T & D parameters. UP WT' =210K, SO WT = 120K. 01:30 02:30 1.00 13,055 8,518 COMPZ CASINC RUNL P Set liner on depth with shoe @ 13055' as per detail. Break connection on drill string and drop 1 3/4" ball. Pump ball down @ 5 BPM - 430 PSI, slowing pumps to 2 BPM - 200 PSI observing ball seat @ 1124 strokes. Pressure to 1500 PSI, set down 50K, continue pressure to 2800, and then to 4000 PSI to release. Bleed pressures. Line up and pressure test packer down annulus to 1000 PSI - 5 minutes. Bleed pressures. Pull up to verify free of liner observing loss of weight of 15K. Aliow dogs to release and set back down verifying top of liner set at 8518.89' as per detail.. Pull up 40 feet to clear inner strip from to of liner. 02:30 02:45 0.25 8,518 8,518 COMPZ CASINC SFTY P Held PJSM with entire crew, vac truck drivers and BOT rep. Discuss safety issues and procedure for displacing well with OBM. Designate a Spill Cham ion. 02:45 04:15 1.50 8,518 8,518 COMPZ CASIN CIRC P Begin circulating, swap to OBM and displace well with OBM at 9 BPM - 890 PSI. 04:15 04:30 0.25 8,518 8,518 COMPZ CASINC OTHR P Monitor well -static. Pump dry job. 04:30 06:00 1.50 8,518 5,590 COMPZ CASINC RUNL P POOH with Liner runing & setting tools from 8518' - 5590'. Observed ro er hole fill. Crew than e. W __ ® _~ ~~qe 2~ raf~ ~~ ~~~ • Time Lo~s_ I Date From To Our S. De ~ih E Degth Phase Code Suhcode T COw1 03/29/2007 06:00 10:15 4.25 5,590 0 COMPZ 'CASIN( RUNL P Continue POOH with Liner tuning & setting tools from 5590' -surface. Observed ro er hole fill 10:15 10:45. 0.50 0 0 COMPZ CASIN ( RUNL P Breakou, Inspect and lay down running & setting tools as per BOT rep. 10:45 11:15 0.50 0 0 COMPZ EVALI/ ~ RURD P PJSM with crew &SWS reps. Rig up SWS wireline crew & equi ment. 11:15 12:45 1.50 0 103 COMPZ EVAL1/~ RURD P Make up wireline tools with tractors and USIT rotatin sub. 12:45 17:15 4.50 103 8,474 COMPZ EVALV~ ELOG P WLIH with tractors arid USIT logging tools from 103' -:8474' MD. Observed no issues on WLIH. 17:15 18:00 0.75 8,474 7,300 COMPZ EVAL1/~ FLOG P WLOH with tools logging from 8474' - 7300'. Crew Chan e 18:00 20:00 2.00 7,300 0 COMPZ EVALW ELOG P Continue WLOH with tools logging from 7300'. - 4300'. WLOH to surfacer Monitor well -static. 20:00 21:00 1.00 0 0 COMPZ EVALV1i RURD P Rig down SWS wireline tools and e ui ment: 21:00 21:45. 0.75 0 0 COMPZ STK PULD P Clear & clean rig floor area, Monitor well -static. 21:45 22:15 0.50 0 0 PROD3 STK OTHR P Hld PJSM with rig crew, Sperry sun -_ rep, and BOT rep. Discuss safety & hazard recognition issues. Discuss makin u Whi stock assembl . 22:15 23:00 0.75 0 0 PROD3 STK PULD P Pull all tools & lift subs to rig floor, re tools in i e shed for pickin u . 23:00 00:00 1.00 0 0 PROD3 STK PULD P Make up. mills & flex joint. Lay down same in pipe shed. Make up Seal assembly & locator sub with space out i e and unloader sub. 03/30/2007 00:00 02:45 2.75 0 310 PROD3 STK PULD P Continue make up remaining whipstock BHA. Total length = 310.29'. 02:45 03:00 0.25 310 400. PROD3 STK OTHR P Make up first stand of DP, top drive connection. Perform Shallow pulse test @ 450 GPMs- 850 PSI. Good test. Blow down To Drive & lines. 03:00 06:00 3.00 400 3,766 PROD3 STK TRIP P Trip in hole with Whipstock assembly from 400' - 3766' @ 90 seconds / stand as per BOT rep.. Fill drill string eve 25 stands. Crew Chan e 06:00 10:00 4.00. 3,766 7,748 PROD3 STK TRIP P Continue trip in hole with Whipstock assembly from 3766' - 7748' MD @ 90 seconds /stand as per BOT rep. Fill drill string every 25 stands. Observed proper hole fill. Rig back on Hi-Line power 0930 HRS. 10:00 10:45 0.75 7,748 7,799 PROD3 STK TRIP P Perform MAD PASS from 7748' - 7799'. Trouble shoot MWD detection. Network problems. 10:45 11:45 1.00 7,748 7,799 PROD3 STK TRIP P Perform MAD PASS again from 7748' - 7799'. 11:45 12:00 0.25 7,799. 7,992 PROD3 STK TRIP P Continue trip in hole with Whipstock assembl from 7799' - 7992'. -_m _ i ~ Time Logs__ ~i Date From To Dur_ S_ D~h_ E Depth Phase Code _ Subco_d__e___ _T __ COM __ _ 03/3012007 12:00 12:15 0.25 7,992 8,393 PROD3 STK TRIP P Continue trip in hole with whipstock assembl from 7992'.- 8393'. 12:15 13:15 1.00 8,393 8,520 PROD3 STK CIRC P Establish circulation & orient whipstock face to 12 degrees left of high side as per DD & SOT reps. TIH tagging top od B lateral liner @ 8520 (2' low), setting seals into liner top. UP WT = 180K, SO WT = 110K. Set down 18k to set BTA, pull 10 K over to verify set. Set down 35K to shear bolt. Pickup to neutral position. Rotate free of whipstock. Top of whipstock = 8391' MD. 13:15 18:00 4.75 8,520 8,416 PROD3 STK MILL P Mill window from 8391' - 8408' in 4.41 HRS.Continue mill in open hole to 8416'. Crew Chan e 18:00 20:00 2.00 8,416 8,431 PROD3 STK MILL P Continue mill in open hole from 8416' 8431' MD. 60 - 100 RPM's. 2 - 10K WOB, Pumps @ 500 GPM's - 2000. PSI. Total millin time = 6.33 HRS. 20:00 21:15 1.25 8,431 8,431 PROD3 STK MILL P Work mills through window area while .pumping Hi-Viso-sweep. Continue work mills until observed good clean - window. '21:15 21:45 0.50 8,431 8,431 PROD3 STK OWFF P Monitor well -static. Pump dry job, and blow down Top Drive & lines. 21:45 22:45 1.00 8,431 7,197 PROD3 STK TRIP P Trip out of hole from 8431' - 7197. lay down 24 joints of 5" DP for allowance of 4" bP to be icked u . 22:45 00:00 .1.25 7,197 4,625 PROD3 STK TRIP P Continue POOH from 719T - 4625'. Observed ro er hole fill. 03/31/2007 00:00 06:00 6.00 4,625 180 PROD3 STK TRIP P Continue POOH with milling assembly from 4625' - 180'. Reposition super sliders 1 foot down and inspect same. Wrap super sliders and LoTads for target zero issues. Observed well takin about 36 BBLS. Crew Chan e 06:00 07:15. 1.25 180 0 PROD3 STK PULD P Breakout, inspect & lay down milling assembl .Mills in au e. 07:15 07:45 0.50 0 0 PROD3 STK PULb P Clean & clear rig floor area. Send out tools. 07:45. 08:30 0.75 0 0 PROD3 STK OTHR P Pull wear bushing, Make up Stack washing tools, and flush BOP stack of iron cuttings. Install wear bushing & RILDS. 08:30 09:00 0.50 0 0 PROD3 STK OTHR P Perform weekly BOP function test. Record on IADC. Blow down Kill & choke lines. 09:00 09:30 0.50 0 0 PROD3 DRILL PULD P Clean & clear rig floor area, pull tools to ri floor. 09:30 09:45 0.25 0 0 PROD3 DRILL PULD P - Make up CCV valve & ball catcher. La down same in i e shed. 09:45. 10:15 0.50 0 0 PROD3 DRILL SFTY P Held PJSM with crew, DD & MWD reps. Discuss safety & hazard recognition issues. Discuss procedure formakin u and runnin BHA#10. ~~ - - ;u f-~~ ~ 3 $ e ., • • Tirne Logs Dot=- Fro~1~ To Dur S Depth E Depth Ph~~e Code Subc:o ,~_ T c~Oh~1 _~, -- ---- 03/31/2007 10:15 12:00 1.75 0 93 PROD3 DRILL PULD P Make up BHA #10 with 6 34" Security bit RR & 6 3/4" Geo ilot assembl . 12:00 12:45 0.75 93 280 PROD3 DRILL. PULD P Continue MU BHA#10. Plug in and U load MWD assembl . 12:45 13:00 0.25 280 280 PROD3 DRILL PULD. P Perform shallow pulse test on MWD assembly with 6.5 BPM - 1100 PSI. Good test. Rotate drill string at 30 RPM's for break in seals on GeoPilot. 13:00 13:45 0.75 280 280 PROD3 DRILL PULD P Blow down Top drive & lines. Inspect to drive & travelin a ui ment. 13:45 15:45. 2.00 280 4,492 PRO D3 DRILL TRIP P Trip in hole with BHA #10 from 280' - 4492' MD. Fill drill strin at 2708'. 15:45 16:00 0..25 4,492 4,762 PROD3 DRILL PULD P Pick up 9 more joints of 4" DP from pi a shed. 16:00 16:30. 0.50 4,762 4,762 PROD3 DRILL PULD P Change out drill pipe elevators and equipment from 4" DP to 5" DP. Install CCV valve & crossovers. 16:30 18:00 1.50. 4,762 7,028 PROD3 DRILL TRIP P Trip in hole with BHA.#10from-4762' - 7028' MD. UP WT = 120K, SO WT = 102K. Fill drill string every 25 stands. Observed proper hole fill. Filt drill string, and rotate 30 RPM's for break in of Geopilot bearings & seals. Crew Chan e 18:00 19:45 1.75 7,028 8,308 PROD3 DRILL TRIP P Continue trip in hole with BHA #10 from 7028' - 8308'. UP WT = 160K, SO WT = 115K. Fill drill string: Observed proper hole fill. Blow down Top drive & lines. Install TIW valve in drill strin . 19:45 21:15 1.50 8,308 8,308 PROD3 RIGMN' SVRG P Held PJSM. Discuss safety & hazard recognition issues. Slip & cut 142' of drilling line.lnspect & adjust draw works brakes & linka e. 21:15 22:00 0.75 8,308 8,308 PROD3 RIGMN' SVRG P PJSM, Change out saver sub. 22:00 23:00. 1.00 8,308 8,308 PROD3 RIGMN SVRG P Service Top Drive, Crown & blocks. 23:00 00:00 1.00 8,308 8,308 PROD3 RIGMN' RGRP. T Work on leaking Hydraulic hose in Top Drive. Check all Hydraulic hoses & connections. 04/01/2007 00:00 03:15 .3.25 8,308 8,308. PROD3 RIGMN' RGRP T . Work on leaking Hydraulic hose & failed O ringin Shot pin maifold assembly. in Top Drive. Check all H draulic hoses & connections. 03:15 03:30 0.25 8,308 8,308 PROD3 DRILL CIRC P Remove TIW Valve & Establish circulation rates. 03:30 06:00 .2.50 .8,430 8,538 PROD3 DRILL DDRL P Slack off and run Geo Pilot assembly through window with no issues to 8430' MD. Directional drill 6 3/4" hole in the D lateral from 8430' - 8538' MD. TVD = 3249'. Crew Chan e 06:00 12:00 6.00 8,538 8,781: PROD3 DRILL DDRL P Directional drill 6 3/4" hole in the D lateral from 8538' -.8781' MD. TVD = 3291'. ~ ~ _ _ ~ _ ~~ i °~~a3~ of fir) • ~•' Slotted and Blank B Liner Detail Well: 1J-160 r ~~~Q~Q~h~l~~~~ 4 7/2" Slotted and Blank Liner Date: 3/2812007 klask~, n,c, Rig: Doyon Rig 15 DEPTH Jt Number Num of Jts COMPLETE DESCRIPTION OF EQUIPMENT RUN Page 1 LENGTH TOPS 5" DP to Surface =_> 8508.20 Liner Runnin Tool 5" Does not sta in hole 10.69 8508.20 "HRD" ZXP Liner Top Packer 9-5/8" (7.50" X 8.42") 18.37 8518.89 "RS" Packoff Seal Nipple 7.00" (6.18" ID x 8.00" OD) 3.51 8537.26 flexLock Liner Hanger 7" x 9-5/8" (6.21" X 8.30") 9.85 8540.77 XO Bushing 4.93" ID, 7.66" OD 1.37 8550.62 190-47 Casing Seal Bore Ext. 4.75"ID x 6.27" OD 19.33 8551.99 XO Bushing 3.91" ID, 6.01" OD 1.47 8571.32 Pup Jt. - 4-1/2", 12.6 ppf, L-80, BTC 3.82 8572.79 Jts 101 to 10 4 Jts 4-1/2", 11.6 ppf, L-80, BTC Blank Casing 170.33 8576.61 Jts 100 to 10 1 Jts 4-1/2",11.6 ppf, L-80, BTC Slotted Casing 41.89 8746.94 Jts 99 to 99 1 Jts 4-1/2",.11.6 ppf, L-80, BTC Blank Casing 39.68 8788.83. Jts 98 to 98 1 Jts 4-1/2",11.6 ppf, L-80, BTC Slotted Casing 43.59 .8828.51 Jts 97 to 97 1 Jts 4-1/2", 11.6 ppf, L-80, BTC Blank Casing 43.31 8872.10 Jts 96 to 96 1 Jts_ 4-1/2",11.6 ppf, L-80, BTC Slotted Casing. 43.37 `_ 8915.41 Jts 95 to 95 1 Jts 4-1/2' ;.11.6 ppf, L-80, BTC Blank Casing 40.27 8958.78 Jts 94 to 94 1 Jts 4-1/2",11.6 ppf, L-80, BTC Slotted Casing 43.25 8999.05 Jts 93 to 93 1 Jts 4-1/2", 11.6 ppf, L-80, BTC Blank Casing 43.29 ..: 9042.30 Jts 92 to 92 1 Jts 4-1/2",11.6 ppf, L-80, BTC Slotted Casing 43.02 9085.59 Jts 91 to s1 1 Jts 4-1/2", 11.6 ppf, L-80, BTC Blank Casing 43.10 9128.61 Jts 9p to so 1 Jts 4-1/2",11.6 ppf, L-80, BTC Slotted Casing 40.81 9171.71 Jts 81 to 89 9 Jts 4-1/2", 41.6 ppf, L-80, BTC Blank Casing 387.36 Jts 80 to so 1 Jts 4-1/2",11.6 ppf, L-80, BTC Slotted Casing 42.00 >'~~~8 .........................:.. Jts 79 to 79 1 Jts 4-1/2", 11.6 ppf, L-80, BTC Blank Casing- 41.40 .9641.88 Jts 7s to 78 1 Jts 4-1/2",11.6 ppf, L-80, BTC Slotted Casing 43.30 9683.28 Jts 77 to 77 1 Jts 4-1/2", 11..6 ppf, L-80, BTC Blank Casing 39.68 9726.58 Jts 76 to 76 1 Jts 4-1/2",11.6 ppf, L-80, BTC Slotted Casing 43.29 : 9766.26 Jts 75 to 75 1 Jts 4-1/2", 11.6 ppf, L-80, BTC Blank Casing .42.42 9809.55 Jts 74 to 74 1 Jts 4-1/2",11.6 ppf, L-80, BTC Slotted Casing 42.20 9851.97 Jts 73 to 73 1 Jts 4-1/2", 11.6 ppf, L-80, BTC Blank Casing 43.20 9894.17 Jts 72 to 72 1 Jts 4-1/2",11.6 ppf, L-80, BTC Slotted Casing 43.31 9937.37 Jts 71 to 71 1 Jts 4-1/2", 11.6 ppf, L-80, BTC Blank Casing 42.98 9980.68 Jts 7o to 70 1 Jts 4-1/2",11.6 ppf, L-80, BTC Slotted Casing 42.79 10023.66 Jts 69 to 69 1 Jts 4-1/2", 11.6 ppf, L-80, BTC Blank Casing 42.15 10066.45 Jts 68 to 6s 1 Jts 4-1/2",11.6 ppf, L-80, BTC Slotted. Casing 43.43 10108.60 Jts 62 to 67 6 Jts 4-1/2",11.6 ppf, L-80, BTC Blank Casing 256.71 "['1~~O Jts 6o to 61 2 Jts 4-1/2",11.6 ppf, L-80, BTC Slotted Casing 84.38 ';~a)408<~~4 ............................ Jts 59 to 59 1 Jts 4-1/2"y 11.6 ppf, L-80, BTC Blank Casing 43.16 10493.12 Ran total of 64 jts Blank BTC Csg = 2734.44' and 40 jts Slotted Up UVt (RT) 210K BTC Csg =1704.44' Ran Total 99 Hydro-Forms Dn Wt (RT) 120K Used Run-N-Seal thread compound on all connections. Block V11t 70K Drifted casing to 3.885" w! teflon rabbit. Rot Wt 120K Torque Rings Installed in joints #66 Thru #104 = 39 torque rings+ pup on top of # 104= 40 Supervisors: Fred Herbert/Granville Rizek • • Jt Number Num of Jts COMPLETE DESCRIPTION OF EQUIPMENT RUN. Page 2 LENGTH TOPS Jts 58 to 58 1 Jts 4-1/2",11.6 ppf, L-80, BTC Slotted Casing 41.69 10536.28 Jts 57 to 57 1 Jts 4-1/2", 11.6 ppf,. L-80; BTC Blank Casing 42.42 10577.97 Jts 56 to 56 1 Jts 4.1/2",11.6 ppf, L-80, BTC Slotted Casing 43.38 10620.39 Jts 55 to 55 1 Jts 4-1/2", 11.6 ppf, L-80, BTC Blank Casing 43.27 10663.75 Jts 54 to 54 1 Jts 4-1/2",11.6 ppf, L-80, BTC Slotted Casing 43.61 10707.02 Jts 53 to 53 1 Jts 4-1/2", 11.6 ppf, L-80, BTC Blank Casing 43.08 10750.63 Jts 52 to 52 1 Jts 4-1/2",11.6 ppf, L-80, BTC Slotted Casing 43.26 10793.71 Jts 51 to 51 1 Jts 4-1/2", 11.6 ppf, L-80, BTC Blank Casing 42.89 .10836.97 Jts 5o to 50 1 Jts 4-1/2",11.6 ppf, L-80, BTC Slotted Casing 43.59 10879.86 Jts 4s to 49 1 Jts 4-1/2", 11.6 ppf, L-80, BTC Blank Casing 43.27 .10923.45 Jts 48 to 48 1 Jts 4-1/2",11.6 ppf, L-80, BTC Slotted Casing 43.30 10966.72 Jts 42 to 47 6 Jts 4-1/2", 11.6 ppf, L-80, BTC Blank Casing 257.63 '':;?11:©;1.13.02' Jts 41 to 41 1 Jts 4-1 /2" 11.6 , ppf, L-80 BTC Slotted Casing 43.37 <:~~~~'~,65; Jts 40 to 40 1 Jts 4-1/2", 11.6 ppf, L-80, BTC Blank Casing 42.9s 11311.02 Jts 39 to 39 1 Jts 4-1 /2",11.6 ppf, L-80, BTC Slotted Casing 43.00 11354.00 Jts 38 to 38 1 Jts 4-1/2", 11.6 ppf, L-80, BTC Blank Casing 43.25 11397.00 Jts 37 to 37 1 Jts 4-1/2",11.6 ppf, L-80, BTC. Slotted Casing 43.01 11440.25 Jts 36 to 36 1 Jts 4-1/2", 11.6 ppf, L-80, BTC Blank Casing 42.80 11483.26 Jts 35 to 35 1 Jts 4-1/2",11.6 ppf, L-80, BTC Slotted Casing 42.97 11526.06 Jts34 to 34 1 Jts ~ --- 4-1 /2' ; 11.6 ppf, L-80,BTC Blank Casing 42.78 11569.03 Jts 33 to 33 1 Jts 4-1/2",11.6 ppf, t-80, BTC Slotted Casing 42.99 11611.81 Jts 32 to 32 1 Jts 4-1/2", 11.6 ppf, L-80, BTC Blank Casing 42.86 11654.80 Jts 31 to 31 1 Jts 4-1 /2",11.6 ppf, L-80, BTC Slotted Casing 40.53 11697.66 Jts 3o to 30 1 Jts 4-1/2", 11.6 ppf, L-80, BTC Blank Casing 42.75 11738.19 Jts 29 to 29 1 Jts 4-1/2",11.6 ppf, L-80, BTC Slotted Casing 43.76 11780.94 Jts 2s to 2s 1 Jts 4-1/2", 11.6 ppf, L-80, BTC Blank Casing 42:78 11824.70 Jts 27 to 27 1 Jts 4-1/2",11.6 ppf, L-80, BTC Slotted Casing 43.26 11867.48 Jts 21 to 26 6 Jts 4-1/2", 11.6 ppf, L-80, BTC Blank Casing 257.96 13 910 74 Jts 19 to 20 2 Jts 4-1/2",11,6 ppf, L-80, BTC Slotted Casing 86.61 121:06 7€3 Jts 18 to 18 1 Jts 4-1/2", 11.6 ppf, L-80, BTCBIank Casing 40.67 12255.31 Jts 17 to 17 1 Jts 4-1/2",11.6 ppf, L-80, BTC Slotted Casing 43.22 12295.98 Jts 16 to 16 1 Jts 4-1/2", 11.6 ppf, L-80, BTC Blank Casing 43.59 12339.20 Jts 15 to 15 t Jts 4-1 /2",11.6 ppf, L-80, BTC Slotted Casing 43.44 12382.79 Jts 14 to 14 1 Jts 4-1/2", 11.6 ppf, L-80, BTC Blank Casing 43.19 12426.23 Jts 13 to 13 1 Jts 4-1/2",11.6 ppf, L-80, BTC Slotted Casing 43.01 12469.42 Jts 12 to 12 1 Jts 4-1/2", 11.6 ppf, L-80, BTC Blank Casing 42.75 12512.43 Jts 11 to 11 1 Jts 4-1/2",11.6 ppf, L-80, BTC Slotted Casing 42.74 12555.18 Jts 10 to 10 1 Jts 4-1/2", 11.6 ppf, L-80, BTC Blank Casing 43.06. 12597.92 Remarks: Jt Number Num of Jts COMPLETE DESCRIPTION OF EQUIPMENT Page 3 Jts 9 to 9 1 Jts 4-1/2",11.6 ppf, L-80, BTC Slotted Casing 41.44 . 12640.98. Jts 8 to s 1 Jts 4-1/2", 11.6 ppf, L-80, BTC Blank Casing 43.08 12682.42 Jts 7 to 7 1 Jts 4-1 /2",11.6 ppf, L-80, BTC Slotted Casing 34.24 12725.50 Jts 6 to 6 1 Jts 4-1/2", 11.6 ppf, L-80, BTC Blank Casing 43.64 12759.74 Jts 5 to 5 1 Jts 4-1/2",11.6 ppf, L-80, BTC Slotted Casing 43.25 1.2803.38 Jts 4 to 4 1 Jts 4-1/2", 11.6 ppf, L-80, BTC Blank Casing 43:28 12846.63 Jts 3 to 3 1 Jts 4-1/2",11.6 ppf, L-80, BTC Slotted Casing 40.81 12889.91 Jts 2 to 2 1 Jts 4-1/2", 11.6 p.pf, L-80, BTC Blank Casing 41:42 12930.72 Jts 1 to 1 1 Jts 4-1/2",11.6 ppf, L-80, BTC Slotted Casing 43.35 12972.14 X-0 4-1/2" BTC Box x 3-1/2" IBT Pin (5.04" Odx 2.992" ID 1:45 13015.49 3-1/2", 9.2 ppf, L-80, IBT Box x EUE 8rd Pin x/o pup jt 6.28 13015.94 3-1/2", 9.3 ppf, L-80, EUE 8rd Blank Casing 31.18 13023.22 3-1 /2" EUE Weatherford float Shoe (4.52" OD) .so 13054.40 Bttm of Shoe==> 13055.00 13055.00 .13055.00 13055.00 13055.00 13055.00 13055;00 13055.00 13055.00 13055.00 TD 6 3/4" hole 13064' MD / 3264.19' TVD 13055.00 3-1/Z" Shoe 13055' MD /3263.70' TVD 9' Rathole 13055.00 13055.00 Interm. 9- 5/8 Window Top @ 8750' MD/ 3,286' TVD 13055.00 Bottom of 9- 5/8 Window @ 8767' MD/ 3,288' TVD 13055.00 Run 1 Hydro-Form per joint floating on the BTC 13055.00 On jts 1-100 13055.00 13055.00 Total 99 Hydro-Form Centralizers used 13055.00 13055.00 13055.00 13055.00 13055.00 13055.00 13055.00 Remarks: • RUN LENGTH TOPS i 07-May-07 AOGCC Librarian 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 Re: Distribution of Survey Data for Well 1J-160 L1 Dear Dear Sir/Madam: Enclosed is one disk with the *.PTT and *.PDF files. Tie-on Survey: 9,170.51 ' MD Window /Kickoff Survey 9,200.00' MD (if applicable) Projected Survey: 13,064.00' MD PLEASE ACKNOWLEDGE RECEIPT BY SENDING AN EMAIL TO Timothy.Allen@HALLIBURTON.COM OR SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Timothy Allen 6900 Arctic Blvd. Anchorage, AK 99518 Date ~ Si ned Please call me at 273-3534 if you have any questions or concerns. Regards, Timothy Allen Survey Manager Attachment(s) ~.o~- o~~ `..J 07-May-07 AOGCC Librarian 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 Re: Distribution of Survey Data for Well 1 J-160 L1 PB1 Dear Dear Sir/Madam: Enclosed is one disk with the *.PTT and *.PDF files. Tie-on Survey: 8,721.13' MD Window /Kickoff Survey 8,750.00' MD (if applicable) Projected Survey: 9,439.00' MD PLEASE ACKNOWLEDGE RECEIPT BY SENDING AN EMAIL TO Timothy.Allen@HALLIBURTON.COM OR SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Timothy Allen 6900 Arctic Blvd. Anchorage, AK 99518 Date ~1 Signed Please call me at 273-3534 if you have any questions or concerns. Regards, Timothy Allen Survey Manager Attachment(s) a c~?- otc~ Re: 1J-160 Update Subject: Re: 1J-160 Update From: Thomas Maunder <tom_-rlaunder@admin.state.ak.us> Date: Fri, 16 Mar 2007 13:31:05 -0800 To: "Hartwig, Dennis D" ~Denriis.D.I~art~~~i~, ~r_conocophillips.conl> Dennis, ~ ~ ~~ ' ~ ~~° This information is sufficient for 1J-160L1 and -L2. I will place a copy of this message in the files. In our call you indicated that 1J-176 has yet to be permitted. Nothing is needed for that well at this time. Call or message with any questions. Tom Maunder, PE AOGCC Hartwig, Dennis D wrote, On 3/16/2007 1:21 PM: Tom, I am covering the 1J-160 while Mike Greener is taking some much earned vacation. I thought I would update you on some current activities and forward plans on the 1J-160 being drilled by Doyon 15. As you already. know, the West Sak A-Lateral was wet and thus the A-sand lateral will not be drilled. Further, Both the B & D laterals will be shortened by approximately 1500' (moved 1500' to the North). Shortening the laterals by 1500' allows for a much simpler Intermediate casing /cementing on the offset well to the South (1J-176). The new 1J-176 Intermediate will be landed approximately 1500' further North making it a much more feasible well. If shortening the 1J-160 B & D lateral requires any change to permitting etc... please contact me. Thanks and have a good weekend... Dennis Dennis Harrivig Drilling Engineer ConocoPhillips Alaska, Inc. Office :907-265-6862 Cel I :907-980-1433 Fax :907-265-1535 1 of 1 3/16/2007 131 PM Re: 1J-160 status as of 3/13/07 Subject: Re: 1J-160 status as of 3/13/07 From: Thomas Maunder <tom_maunder~~admin.state.ak.us> Dxte: Tue, 13 Mar ?007 09:36:01 -0800 To: "Greener, Mike R." ~1ike.R.Green~rcrconocopllillips.com> ~~~ `-~ ~~ CC: "~I~lic,mas, Randy 1." ~ Kandy.L. l~h~~ni~u~r~cono~:~~E~hillii,~.r~~«1>, "I (~iri~~i~, Dennis [)~~ Ucn~~is.I~.Hartwig~uc~>nocophillips.eom>, Steve Davies ~ stc~~~~_davie~ ua~lmin.~st~i~~.<il..us-~ Thanks Mike. Your plan should effect isolation from the water. This. situation poses an interesting situation since this well was intended to be a tri-lateral and what would have been the motherbore penetration will essentially be plugged. In order to avoid what likely would be significant paperwork, it is probably best that the originally planned naming convention continue with 1J-160L1 in the B sand and 1J-160L2 in the D sand. 1J-160 still needs to be "on the books" since all Iateral production is reported against the motherbore that has the -00- suffix in the API number. Lets all be aware of the situation on this well. It is probably appropriate to be sure that your other colleagues (especially Sharon) are aware of this well. Call or message with any questions. Tom Maunder, PE AOGCC Greener, Mike R. wrote, On 3/13/2007 9:19 AM: I_,ast n~~ht we finished our cirillin~ of the intermediate section f®~- this well. 'VVe .: drilfed to ~ measured depth. o l t~,271 " .AVID, ~,4~ 5' T~JD. {fur TD is in tl~e ~? ~" sand. The ~'~2 sand is ~fet. The D and sands are oil bea~in~. Cur plan Ior~varcf is to set t>ur intermediate casing; {~-~/~") at , l {)' IiL?, 3,3~C)' T~jL). "I'he top cif the sand. is at 8,75()' ~~, 3,25' T~' We ~~-ill cut a ~-indovv to access tl~e I3 sand. y setting our slue at 0,150" MD eve expect to isolate any ~%ater fio~n the A2 Sand. 'G~1ike Cireerter «Greener, Mike R..vcf» 1 of 1 3/13/2007 9:37 AM w S,4RAh° P.4L1A1, GOVERflI®R 333 W. 7th AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Randy Thomas Greater Kuparuk Area Drilling Team Leader ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510-0360 Re: Kuparuk River Field, West Sak Oil Pool, 1J-160L 1 ConocoPhillips Alaska, Inc. Permit No: 207-016 Surface Location: 2016' FSL, 2541' FEL, Sec. 35, T11N, R10E, UM Bottomhole Location: 96' FNL, 1842' FWL, Sec. 10, T10N, RlOE, UM Dear Mr. Thomas: Enclosed is the approved application for permit to drill the above referenced service well. The permit is for a new wellbore segment of existing well KRU 1J-160, Permit No 207- 015, API 50-029-23344-00. Production should continue to be reported as a function of the original API number stated above. This permit to drill does riot exempt you from obtaining additional permits or an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inctor at (907) 659-3607 (pager). DATED this ~ day of February, 2007 cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL ~~~ 20 AAC 25.005 d~E~~ V ~D 1f1Ai '~ ~ ~~(1? 1 a. Type of Work: 1 b. Curcent Well Class: Exploratory ^ Development Oil ^ 1 c. Specify if well is proposed for: Drill ^/ Re-drill ^ Stratigraphic Test ^ Service ^ • Development Gas ^ t.1 I~~~©~ Oft~afgglsSS~ Re-entry ^ Multiple Zone ^ Single Zone ^ n as ^ 2. Operator Name: 5. Bond: / Blanket Single Well 11. Well Name and Number: ConocoPhillipsAlaska, Inc. Bond No. 59-52-180 1J-160L1 3. Address: 6. Proposed Depth: 12. Field/Pool(s): P.O. Box 100360 Anchorage, AK 99510-0360 MD: 14466' TVD: 3249' Kuparuk River Field 4a. Location of Well (Governmental Section): 7. Property Designation: Surface: 2016' FSL, 2541' FEL, Sec. 35, T11 N, R10E, UM ~ ADL 25660 & 25663 ~ 1S+Grcl West Sak Oil Pool Top of Productive Horizon: 8. Land Use Permit: v7 13. Approximate Spud Date: ®. ~ 3 419' FSL, 1651' FWL, Sec. 34, T11 N, R10E, UM ~ ALK 470 & 472 2/21/2007 Total Depth: 9. Acres in Property: 14. Distance to 96' FNL, 1842' FWL, Sec. 10, T10N, R10E, UM 2560 Nearest Property: < 1 mile 4b. Location of Well (State Base Plane Coordinates): 10. KB Elevation 15. Distance to Nearest ~S /'~~' Surface: x- 558668 • y- 5945827 • Zone- 4 (Height above GL): 28' RKB feet Well within Pool: ycrie , /Skip' 16. Deviated wells: Kickoff depth: 8664 ft. 17. Maximum Anticipated Pressures in psig (see 20 ,aAC 25.035) /• Maximum Hole Angle: 92° deg Downhole: 1498 psig Surface: 1132 psig 18. Casing Program cif cations S Setting Depth Quantity of Cement Size pe i Top Bottom c. f. or sacks Hole Casing Weight Grade Coupling Length MD ND MD ND (including stage data) 42" 20" x 34" 94# K-55 Welded 80' 28' 28' 108' - 108' 260 cf ArcticCRETE 16" 13.375" 68# L-80 BTC 3226' 28' 28' 3226' - 2135' 650 sx AS Lite, 220 sx DeepCRETE 12.25" 9-5/8" 40# L-80 BTCM 9704' 28' 28' 9704' 3472' 790 sx DeepCRETE 6.75" 4.5" 11.6# L-80 BTC 5803' 8663' 3309' 14466' 3249' 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 Conductor/Structural Surface Intermediate Production Liner Perforation Depth MD (ft): Perforation Depth ND (ft): ,` 1, i',' 20. Attachments: Filing Fee BOP Sketch Drilling Program Q Time v. Depth Plot Shallow Hazard Analysis / _ Property Plat ^ Diverter Sketch ^ Seabed Report ^ Drilling Fluid Program Q 20 AAC 25.050 requirements ^/ 21. Verbal Approval: Commission Representative: Date: 22. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Mike Greener @ 263-4820 Printed Name Randy Thomas Title Greater Kuparuk Area Drilling Team Leader ~.. Phone '~ ~ ~ ~ ~~ `; Date ~ ~ 2` /(}~+ Signature •~ L ~ : °,-- - ~ ~•~~ _.. . - --~ - Pr n All Drak Commission Use Only Permit to Drill API Number: Permit Approval See cover letter / Number: 207~~~(p 50-b7q.~~T~~ s Date:Oa ~£%j ~`T for other requirements m ethane, gas hydrates, or gas contained in shales: Conditions of approval : If box is checked, well may not be used to explore for, test, or produce coalbed r a Samples req'd: Yes ^ No LJ ud log req'd: Yes ^ No Other: 30~~ Q56 ~~ -~~- H2S measures: Yes ^ f nal svy req'd: Yes © No ^ ` APP VED BY THE COMMISSION ~D ,COMMISSIONER DATE: `~ Form 10-401 Revised 12/2005 ~ ~ t ~ ~ ~ ('~ i F~ t v ~ /,~ /•3d,O~ubmit in Duplicate r07 • Appln for Permit to Drill, Well 1 J-160 L1 Revision No.0 Saved: 29-Jan-07 Permit It -West Sak Well #1J-160 L1 •°~° r.~ i~ Application for Permit to Drill Document II~IaW+~ll MGxirriiz~ VWell 'fvlue Table of Contents 1. Well Name ................................................................................................................. 2 Requirements of 20 AAC 25.005 (17 ....................................................................................................... 2 2. Location Summary ................................................................................................... 2 Requirements of 20 AAC 25.005(c)(2) ................................................................................................... 2 Requirements of 20 AAC 25.050(b) ....................................................................................................... 3 3. Blowout Prevention Equipment Information ......................................................... 3 Requirements of 20 AAC 25.005(c)(3) ................................................................................................... 3 4. Drilling Hazards Information ................................................................................... 3 Requirements of 20 AAC 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 ............................................................................ 3 Requirements of 20 AAC 25.005(c)(6) ................................................................................................... 4 7. Diverter System Information ................................................................................... 4 Requirements of 20 AAC 25.005(c)(7) ................................................................................................... 4 8. Drilling Fluid Program ............................................................................................. 4 Requirements of 20 AAC 25.005(c)(8) ................................................................................................... 4 Lateral Mud Program (MI VersaPro Mineral Oil ease) ........................................................................... 4 9. Abnormally Pressured Formation Information ..................................................... 5 Requirements of 20 AAC 25.005 (c)(9) .................................................................................................. 5 10 . Seismic Analysis ..................................................................................................... 5 Requirements of 20 AAC 25.005 (c)(10) ................................................................................................ 5 11 . Seabed Condition Analysis ..................................................................................... 5 Requirements of 20 AAC 25.005 (c)(11) ................................................................................................ 5 12 . Evidence of Bonding ............................................................................................... 5 Requirements of 20 AAC 25.005 (c)(12) ................................................................................................ 5 1J-160L1 PERMIT IT Page 1 of 6 ~ Printed: 29-Jan-07 u Applic ~ n for Permit to Drill, Well 1 J-160 L1 Revision No.0 Saved: 29-Jan-07 13. Proposed Drilling Program ..................................................................................... 5 Requirements of 20 AAC 25.005 (c)(13) ................................................................................................ 5 14. Discussion of Mud and Cuttings Disposal and Annular Disposal ....................... 6 Requirements of 20 AAC 25.005 (c)(14) ................................................................................................ 6 15. Attachments ............................................................................................................. 6 Attachment 1 Directional Plan ................................................................................................................ 6 Attachment 2 Drilling Hazards Summary ............................................................................................... 6 Attachment 3 Well Schematic ................................................................................................................ 6 1. Well Name Requirements of 20 AAC 25.005 (fl Each well must be identified by a unique name designated by the operator and a unique API number assigned by the commission under 20 AAC 25.040(b). For a well with multiple well branches, each branch must similarly be identified by a unique name and API number by adding a suffrx to the name designated for the well by the operator and to the number assigned to the well by the commission. The well for which this Application is submitted will be designated as 1J-160 L1. 2. Location Summary Requirements of 20 AAC 25.O05(c)(2) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (2) a plat identifying the property and the property's owners and showing (A)the coordinates of the proposed location of the well at the surface, at the top of each objective formation, and at total depth, referenced to governmental section lines. (8) the coordinates of the proposed location of the well at the surface, referenced to the state plane coordinate system for this state as maintained by the National Geodetic Survey in the National Oceanic and Atmospheric Administration; (C) the proposed depth of the well at the top of each objective formation and at total depth; Location at Surface 2,016' FSL 2,541' FEL, Section 35, T11N, R10E ASP Zone 4 NAD 27 Coordinates RKB Elevation 109.0' AMSL Northings: 5,945,827 Eastings: 558,668 Pad Elevation 81.0' AMSL Location at Top of Productive Interval West Sak "B" Sand 419' FSL, 1,651' FWL, Section 34, T11N, R10E ASP Zone 4 NAD 27 Coordinates Measured De th, RKB: 8,664 Northings: 5,944,183 Eastings: 552,315 Total Vertical De th, RKB: 3,309 Total Vertical De th, SS: 3,188 Location at Total De th 96' FNL 1,842' FWL, Section 10, T10N, R10E ASP Zone 4 NAD 27 Coordinates Measured De th, RKB: 14,466 Northings: 5,938,391 Eastings: 552,557 Total Vertical De th, RKB: 3,249 Total Vertical De th, SS: 3,128 and (D) other information required by 20 AAC 25.050(b); 1J-160L1 PERMIT IT Page 2 of 6 Printed: 29-Jan-07 ~~. ~~{~, __ E t ~ ~ c t i..,,, Appli for Permit to Drill, Well 1 J-160 L1 Revision No.O Saved: 29-Jan-07 Requirements of 20 AAC 25.050(b) If a well is to be intentionally deviated, the application for a Permit to Drill (Form 10-401) must (1) include a plat, drawn to a suitable scale, showing the path of the proposed wellbore, including all adjacent wellbores within 200 feet of any portion of the proposed well; Please see Attachment 1: Directional Plan 1J-160L1 and (2) for all wells within 200 feet of the proposed wellbore (A) list the names of the operators of those wells, to the extent that those names are known or discoverable in public records, and show that each named operator has been furnished a copy of the application by certified mail; or (8) state that the applicant is the only affected owner. The Applicant is the only affected owner. 3. Blowout Prevention Equipment Information Requirements of 20 AAC 25.005(c)(3) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (3) a diagram and description of the blowout prevention equipment (BOPS) 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 iJ-160 Li. Please see information on Doyon 15 blowout prevention equipment placed on file with the Commission. 4. Drilling Hazards Information Requirements of 20 AAC 25.005 (c)(4) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (4) information on drilling hazards, including (A) the maximum downhole pressure that maybe encountered, criteria used to determine it, and maximum potential surface pressure based on a methane gradient; The expected reservoir pressures in the West Sak sands in the iJ area are 0.45 psi/ft, or 8.7 ppg EMW (equivalent mud weight). Pressures are predicted based on the undisturbed West Sak pressure gradient. The maximum potential surface pressure (MPSP) based on the above maximum pressure gradient, a methane gradient (0.11), and the deepest planned vertical depth of the West Sak ~~B" sand formation is 1,132 psi, calculated thusly: MPSP = (3,329 ft TVD)(0.45 - 0.11 psi/ft) = 1,132 psi (8) data on potential gas zones; The well bore is not expected to penetrate any gas zones. and (C) data concerning potential causes of hole problems such as abnormally geo-pressured strata, lost circulation zones, and zones that have a propensity for differential sticking; Please see Attachment 2: 1J-160 L1 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 following items, except for an item already on file with the commission and identified in the application: (5) a description of the procedure for conducting formation integrity tests, as required under 20 AAC 25.0300; The parent wellbore, iJ-160, will be completed with 9-5/8" 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. 1J-160L 1 PERMIT IT t ~ Page 3 of 6 Printed: 29-Jan-07 Applic n for Permit to Drill, Well 1 J-160 L1 Revision No.O Saved: 29-Jan-07 6. Casing and Cementing Program Requirements of 20 AAC 25.005(c)(6) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (6) a complete proposed casing and cementing program as required by 20 AAC 25.030, and a description of any slotted liner, pre- perforated liner, or screen to be installed; Casing and Cementing Program See also Attachment 3: Cement Summa Hole Top Btm Csg/Tbg Size Weigh Length MD/TVD MD/TVD OD (in) (in) t (Ib/ft) Grade Connection (ft) ft) (ft) Cement Program 20 x 34 42 94 K55 Welded 80 28 / 28 108 / 108 Cemented to surface with 260 cf ArcticCRETE Cemented to Surface with 13-3/8 16 68 L-80 BTC 3,226 28 / 28 3,226 /2,135 650 sx ASLite Lead, 220 sx DeepCRETE Tail Cement Top planned @ 5,300' 9-5/8 12-1/4 40 L-80 BTCM 9,704 28 / 28 9,704 / 3,472 MD / 2,561'TVD. Cemented w/ 790sx DeepCRETE 4-1/2 6-3/4" A Sand 11.6 L-80 BTC 5,715 8,773 / 3,323 14,478 / 3,407 Slotted- no cement 4-1/2 6-3/4" B Sand 11.6 L-80 BTC 5,803 8,663 / 3,309 14,466 / 3,249 slotted- no cement Slotted Lateral (1]-160 Ll) ~_ i ~ - - /4" D Sand 11.6 L-80 BTC 6,184 8,273 / 3,2 - slotted Lateral(i]-160 L2) 7. Diverter System Information Requirements of 20 AAC 25.005(c)(7) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (7) a diagram and description of the diverter system as required by 20 AAC 25.035, unless this requirement is waived by the commission under 20 AAC 25.035(h)(2); No diverter system will be utilized during operations on iJ-160 L1. 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 following items, except for an item already on file with the commission and identified in the application: (8) a drilling fluid program, including a diagram and description of the drilling fluid system, as required by 20 AAC 25.033; Drilling will be done with mud having the following properties over the listed intervals: Lateral Mud Program (MI VersaPro, Mineral Oil Base) Value Density (pp) 8.8 Plastic Viscostiy (Ib/100 sf) 15 - 25 Yield Point (cP 18 - 28 HTHP Fluid loss (ml/30 min 200 si & 150° <4.0 Oil /Water Ratio 70 / 30 Electrical Stabilit 650-900 1J-160L1 PERMIT IT Page 4 of 6 Printed: 29-Jan-07 ~~~~v. • Applic n for Permit to Drill, Well 1 J-160 L1 Revision No.0 Saved: 29-Jan-07 Drilling fluid practices will be in accordance with appropriate regulations stated in 20 AAC 25.033. Please see information on file with the Commission for diagrams and descriptions of the fluid system of Doyon Rig 141. 9. Abnormally Pressured Formation Information Requirements of 20 AAC 25.005 (c)(9) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (9) for an exploratory or stratigraphic test well, a tabulation setting out the depths of predicted abnormally geo-pressured strata as required by 20 AAC 25.033(f); Not applicable: Application is not for an exploratory or stratigraphic test well. 10. Seismic Analysis Requirements of 20 AAC 25.005 (c)(10) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (10) for an exploratory or stratigraphic test well, a seismic refraction or reflection analysis as required by 20 AAC 25.061(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 application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (11) for a well drilled from an offshore platform, mobile bottom-founded structure, jack-up rig, or floating drilling vessel, an analysis of seabed conditions as required by 20 AAC 25.061(b); Not applicable: Application is not for an offshore well. 12. Evidence of Bonding Requirements of 20 AAC 25.005 (c)(12) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (12) evidence showing that the requirements of 20 AAC 25.025 {Bonding}have been met; Evidence of bonding for ConocoPhillips Alaska, Inc. is on file with the Commission. 13. Proposed Drilling Program Requirements of 20 AAC 25.005 (c)(13) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: The proposed drilling program is listed below. Please refer also to Attachment 3, Well Schematic. Note: Previous operations are covered under the iJ-160 Application for Permit to Drill. 1. Run and set Baker WindowMaster whipstock system, at window point of +/- 8,663' MD / 3,309' TVD, the top of the B sand. 2. Mill 6-3/4"window. POOH. 3. Pick up 6-3/4"drilling assembly with LWD and MWD and PWD. RIH. 4. Drill to TD of B sand lateral at +/- 14,466' MD / 3,249' TVD, as per directional plan. 5. POOH, back reaming out of lateral to window. TIH to bottom & displace to solids-free oil based mud. POOH on elevators. 6. RIH with whipstock retrieval tool. Retrieve whipstock and POOH. 7. PU and run 4-1/2" slotted liner. 1J-160L1 PERMIT IT Page 5 of 6 Printed: 29-Jan-07 ~~~~!i~. LJ Appli~ for Permit to Drill, Well 1 J-160 L1 Revision No.O Saved: 29-Jan-07 8. RIH, until liner hanger is just above window. Orient hanger to window and land hanger. 9. Release hanger running tool. POOH. 10. Make up junction isolation / re-entry assembly (Lateral Entry Module or LEM) and RIH to depth. Orient and set packer atop assembly and release from assembly. il. POOH and prepare to drill the ~~D" sand lateral iJ-160 L2. 14. Discussion of Mud and Cuttings Disposal and Annular Disposal Requirements of 20 AAC 25.005 (c)(14) An application for a Permit to Drill mustc be accompanied by each of the following items, except for an item already on rile with the commission and identified in the application: (14) a general description of how the operator plans to dispose of drilling mud and cuttings and a statement of whether the operator intends to request authorization under 20 AAC 25.080 for an annular disposal operation in the well.; Waste fluids generated during the drilling process will be disposed of either by pumping authorized fluids into a permitted annulus on 1J Pad, or by hauling the fluids to a KRU Class II disposal well. All cuttings generated will be disposed of either down a permitted annulus on 1J Pad, hauled to the Prudhoe Bay Grind and Inject Facility for temporary storage and eventual processing for injection down an approved disposal well, or stored, tested for hazardous substances, and (if free of hazardous substances) used on pads and roads in the Kuparuk area in accordance with a permit from the State of Alaska. ConocoPhillips Alaska may in the future request authorization for the use of this well for annular disposal operations. 15. Attachments Attachment 1 Directional Plan Attachment 2 Drilling Hazards Summary Attachment 3 Well Schematic 7J-160L1 PERMIT IT Page 6 of 6 Printed: 29-Jan-07 ~~~~~,~ • ConocoPhillips Alaska • Plan: 1J-160 L1 (wp06) Sperry Drilling Services Proposal Report -Geographic 26 January, 2007 ConocoPhillips Alaska, Inc. Kuparuk River Unit Kuparuk 1J Pad Plan 1J-160 Plan 1J-160 L1 Local Coordinate Origin: Centered on Well Plan 1J-160 Viewing Datum: Doyon 15 (40+81) @ 121.OOft (Doyon 15 (40+81)) TVDs to System: N North Reference: True Unit System: API - US Survey Feet FYI ~. ~.~. ~ I~'T Sperry Drilling Services HALLIBCJRTON WELL DETAILS: Plan U-160 L1 Ground Level: 81.00 Sperry Dritling Services +?I/-S +FJ-W ~lonhing Fasting Latinude Longitude Slot 0.00 0.00 59458'_752 558668.60 70`15'45.361V 149°31'32.559W FORMATION TOP DETAILS No.NDPath NDSS MDPath Formation 1 1525.76 1404.76 1667.19 Pfrost 2 1651.58 1530.58 1856.80 T3 3 1939.25 1818.25 2423.51 K15 4 2153.28 2032.28 3317.26 Casing Pt 5 2678.05 2557.05 5863.51 Ugnu C -500- 6 2861.21 2740.21 6672.60 Ugnu B - 7 2923.21 2802.21 6925.75 Ugnu A - 8 3086.20 2965.20 7595.32 K 13 SHL - 2016' FSL, 2541' FEL -Sec35-T11 N-R10E - _ 9 3228.00 3107.00 8244.03 W Sak D 10 3279.00 3158.00 8504.39 W Sak C 0 _ _ _ - - - - - - - 11 3303.00 3182.00 8631.13 W Sak B _ 12 3343.00 3222.00 8851.28 W Sak A4 _ 13 3425.00 3304.00 9340.61 W Sak A3 _ 0° I 14 3479.00 3358.00 9828.07 W Sak A2 'i 500 500- CASING DETAILS - 10° No MD TVD TVDss Name I 14478.35 3407.01 3286.01 41/2" 2 9704.44 3472.53 3351.53 9 Sib" _ 1000-~ 1000 3 3317.26 2153.28 2032.28 13 3/R" 13-3;8 ,"~ ~ 30° '~~ 1500 ~0-Pfrost------ - - T3 ------- ~^'1 ^ 2000 ~0-' - K15- - - - - - - ~bOII 13 3/8" Csg @ 3317 MD, 2153' ND - 1988' FSL, 747 FWL -Sec35-711 N-R10E ----- ------------------- l -=- C i Pt ------- L2: BHL @ 14457 MD, 3173' ND - 96' FNL, 1842' FWL - Sec10-T10N-R10E , ------------------ ---------------- -------------------- n as ng ~_~ -- ---- 3500 T ~ L2: 9 518" TOW @ 8274' MD, 3234' ND - 791' FSL, 1738' FWL -Sec34-711 N-R10E " t Q~~ _ 13 3/8 4500 ' ' " ' ' ND - 419 FSL, 1651 F 4i..~60- L1: 9 5/8 TOW @ 8664 MD 3309 WL -Sec34-T11N-R10E ~ 5500 ~ " - ' 0 0 __ .' -~ --- UgnuB ---- -- -~-- -----~---------------------------- ------ ----------- 1J- 60L2 w 06 ~ 1 -- ----- `--- p ~---- - UgnuA --- --->~--~---~;'---------__,,-=--------------------- > ----------------'4112"--~----°-------- 3000 ------- --~--->° a---=--------------------------- ~ -~--K13-~ - ar---- -- -----------~~--a-~~ -o----- -- 1 6 2 _' _ _ _ _ W Sak D -.a , m o, - ; o ~ ~_--==-===-WSakC------ - - - -- ~ ------------------- -- (wp0 ) o _ 11J-160 L -- ------ --------=~_'----------- --- ~=-v= =--------------f~--- - ---- - ----------------------- _ _ -- T-=_---- --------- -------- ~ - - - _-_----_--- -' -=WSakB------=~~- -~-1- - ~ ~ -cD-~~-- -' -~-- ----,- -~---1--~\--------~ 3500-i~~ ° ---t --~ ---~----~----~,r-==-'~1J-160(wp06) ` WSakA4 95/8"TOW ~ ~ ~ ~~ ~ °~ ° ~~o ° o ~ ~. r °o ~ °o ~ °o ~ ~ \ o _ W Sak A3 ,~ ~ ,' ~ ~ ~ ~ i i , , ~ ' t~ 4 1 /2" i t ~ r 1 J-160 D Top 1/19/07. 9 5/8" TOW ~ ~ ~ ~~ i r , , ~ ' _ 4000- W Sak A2 ~ ' , i t 1J-160 Top B'', i ~~ ~ ' t i t - 1J-160A CPO1 10!27/06 1J-160A CP0310/27/06~ i ~1J-160A_CP0510/27106 ~ ~ 1J-t60A CP0710/27/06 ~ t 4500 - - i _ , , , `~ _ 1J-t60A CP0210i27'00 1J-160A_CP0410/27/06 11J-160A CP06 10/27/06 _ _ 1J-160A CP0810t27/06i ~ 1J-160A Tee 10:27r0~~ 5000 ' ' ' ' _ BHL @ 14478 MD, 3407 ND - 96 FNL, 1842 FWL - Sec10-T10N-R10E - -- - -- -- -- - -- - - --- -- - - 5500 ~ _ _~- -1 - _~ - -- ~ - I- - r --r~--~- ~- -~ - ~ ~~ T ~ ~ r ~ i ~ -1000 -500 0 500 1000 1500 2000 2500 3000 3500 4000 4500 5000 5500 6000 6500 7000 7500 8000 0500 Vertical Section at 180.00° (1000 ft/in) '~ ConocoPt~illips A~-sska HAL LIBURTON Project: Kuparuk River Unit WIiLLUF:TAIL.S Plan IJ-160LI Sperry ~riiiing Services ~ Site: Kuparuk 1J Pad clruunJLeve1: 81.00 Well: Plan 1J-160 +ws -I(:-w northing r-a,ti~~ [.9tim,a- t.on~it~d~ sl,.~ Wellbore: Plan 1J-160 L1 °0° I?01i `y4'x'7sz ~Sxv6x.6o 7o°ISas.361N1a9°3r1z.5sew Plan: 1J-160 (wp06) REFERENCE INFORMATION 11°° Coordinate (N/E) Reference: Well Plan iJ-160, True North Vertical (TVD) Reference: Doyon 15 (40+g1) @ 121.OOft (Doyon 15 (40+81)) Measured Depth Reference: Doyon 15 (40+g1) @ 121.OOft (Doyon 15 (40+81)) Calculation Method: Minimum Curvature 500 c c ° 13 /8" o ° r ~ ~ ~ o / , ~ _ 2S0 p \ ~ up' ~ p \ \ O O G \ \ -50(1 ~ G \ \ \ \ \ \ SHL-2016'FSL,2S41'FBL-Sec3S-TIIN-RIOE v 9 5/R" TOW v -10(10 \\ 13 3/R" Csg (u; 311 T MD, 21 S1' T'VD - 19RR' FSL, 74T FWL - Sec3S-T11 N-Rl OE - " '1250 ~ ~ ~ ~ ~~ ~ S/8" TOW (m x274' MD, 3214' TVU - 791' FSL, 1738' 1+WL - Sec34-TI IN-R I OF: -1500 9 S/x TOW Ll 9 $/8" TOW C<u x664' MD 3109' TVD - 419' FSL, 16S I' h WL - Scc14-TI IN-R I OP. -2000 -250(1 ~ 9 5/x" -3000 -3500- 0 w o -~~ CV + -4500 0 ` ^ -5ax1 0 -5500 -600° L2 B I IL (n; 144?T MD, 1171' TV D - 9(,' FNL, I X42' F W L -Sec 10-T1 ON-R I OE -6500 -7000 BHL (~1447R'MD, 1407TVD-9G'PNL, Ix42'F'WL-Sec10- '' _ TION-RIIIF: 4 I/2" - __ T ~\ ,' 07 ~ M Azimuths to True North _7S(1(1 ,~ Magnetic North: 24.65° \ , Magnetic Field 17-160(wp06) ~ Strength: 57552.4nT -8000 I1-160 U (wp06) ~ Dip Angle: 80.75° Date: 11/18/2004 , Model: BGGM2005 - I1 -160 L2 (\v106) -8500 -9000 - CASING DETAILS -9500- No MD TVD TVDss Name Sizc - 114478.35 3407.0] 3286.01 41/2" 4-1/2 2 9704.44 3472.53 3351.53 9 5/8" 9-5/8 3 3317.26 2153.28 2032.2R 13 3/8" 13-3/8 - 10000 -7500 -70(1(1 -6500 -60(10 -5500 _5000 -4500 -4000 -3500 ~~p -3 000 -2500 -200(1 -1500 -1000 -500 0 500 1000 , 1 n ~ ~LY~~t(ast~~) 1250 fUin) ' , , ~ ~ . _ ~" ConotoPhillips ~as~ Colr~coPhil~ips Alaska Halliburton Company Planning Report -Geographic ~.A~.~i~~~~r~lt~a Sperry DriFling 8e~vices Database: Compass 2003.11 Local Co-ordinate Reference: Well Plan 1J-160 Company: ConocoPhillips Alaska, Inc. TVD Reference: Doyon 15 (40+81) @ 121.OOft (Doyon 15 (40+81)) Project: Kuparuk River Unit MD Reference: Doyon 15 (40+81) @ 121.OOft (Doyon 15 (40+81)) ~ Site: Kuparuk 1J Pad North Reference: True Well: .Plan 1J-160 Survey Calculation Method: Minimum Curvature Wellbore: Plan 1J-160 L1 Design: 1J-150 L1 (wp06) Project Kuparuk River Unit. North Slope Alaska, United States Map System: US State Plane 1927 (Exact solution) System Datum Geo Datum: NAD 1927 (NADCON CONUS) Map Zone: Alaska Zone 04 Mean Sea Level Using Well Reference Point Using geodetic scale factor Well Plan iJ-ih0 Well Position +N/-S 0.00 ft Northing: 5,945,827.52 ft Latitude: 70° 15' 45.361" N +E/-W 0.00 ft Easting: 558,668.60ft Longitude: 149° 31' 32.559" W Position Uncertainty 0.00 ft Wellhead Elevation: ft Ground Level: 81.OOft y ~ a m- a- ,,, ~x~,k Wellhore Plan 1J-160 L1 Magnetics Model Name Sample Date Declination Dip Angle Field Strength ~ bggm2005 8/8/2006 24.00 80.78 57,564 Design iJ-ibOL1(wp06) Audit Notes: Version: 15 Phase: PLAN Tie On Depth: 8,663.88 Vertical Section: Depth Frorn (TVD} +N/-S +E/-W Direction (ft) Ift) (ft) (°) 40.00 0.00 0.00 180.00 1/26/2007 4:09:40PM Page 2 of 7 ~:~~~ ~ COMPASS 2003.11 Build 48 • '-~`' ~~ ~ Halliburton Company H~.~O..~~3URTC~1"~! n4CO l lp5 Alaska Planning Report -Geographic Spret~y Drilling Sera€ces Datahase: Compass 2003.11 Local Co-ordinate Reference: Well Plan 1J-160 Company: ConocoPhillips Alaska; Inc. TVD Reference: Doyon 15 (40+81) @ 121.OOft (Doyon 15 (40+81)) Project: Kuparuk River Unit MD Reference: Doyon 15 (40+81) @ 121.OOft (Doyon 15 (40+81)) Site: Kuparuk 1J Pad North Reference: True Well: Plan 1J-160 Survey Calculation Method: Minimum Curvature Wellborn Plan 1J-160 L1 Design: 1J-160 L1 (wp06) I Plan Summary Measured Vertical Dogleg Build Turn Depth Inclination Azimuth Depth +N/-S +E/-W Rate Rate Rate TFO (ft) (°) (°) (ft) (ft) (ft} (°/100ft) (°f100ft) (°MOOft) ~~) 8,663.88 79.32 187.19 3,309.09 -1,594.94 -6,366.40 0.00 0.00 0.00 0.00 8,680.38 81.26 186.06 3,311.88 -1,611.09 -6,368.27 13.60 11.79 -6.88 -30.00 8,710.38 81.26 186.06 3,316.43 -1,640.58 -6,371.40 0.00 0.00 0.00 0.00 8,969.53 94.47 177.83 3,326.07 -1,898.61 -6,380.08 6.00 5.10 -3.17 -32.14 9,062.39 94.47 177.83 3,318.83 -1,991.12 -6,376.57 0.00 0.00 0.00 0.00 9,213.16 88.50 177.00 3,314.92 -2,141.62 -6,369.78 4.00 -3.96 -0.55 -172.07 9,713.16 88.50 177.00 3,328.01 -2,640.76 -6,343.62 0.00 0.00 0.00 0.00 10,038.31 91.75 177.01 3,327.29 -2,965.42 -6,326.65 1.00 1.00 0.00 0.26 10,538.48 91.75 177.01 3,312.01 -3,464.68 -6,300.61 0.00 0.00 0.00 0.00 10,706.49 90.56 178.20 3,308.62 -3,632.51 -6,293.60 1.00 -0.71 0.70 135.26 11,488.85 90.56 178.20 3,301.01 -4,414.44 -6,268.99 0.00 0.00 0.00 0.00 11,576.01 91.42 178.09 3,299.50 -4,501.54 -6,266.17 1.00 0.99 -0.12 -6.94 12,079.13 91.42 178.09 3,287.01 -5,004.22 -6,249.42 0.00 0.00 0.00 0.00 12,251.47 89.70 178.09 3,285,32 -5,176.45 -6,243.68 1.00 -1.00 0.00 -179.96 12,573.38 89.70 178.09 3,287,01 -5,498.19 -6,232.96 0.00 0.00 0.00 0.00 12,627.78 90.24 178.08 3,287.03 -5,552.55 -6,231.14 1.00 1.00 -0.01 -0.82 13,104.84 90.24 178.08 3,285.01 -6,029.34 -6,215.18 0.00 0.00 0.00 0.00 13,327.14 92.47 178.08 3,279.75 -6,251.44 -6,207.75 1.00 1.00 0.00 0.02 13,739.46 92.47 178.08 3,262.01 -6,663.15 -6,193.98 0.00 0.00 0.00 0.00 13,881.53 91.05 178.11 3,257.65 -6,805.07 -6,189.26 1.00 -1.00 0.02 178.86 14,026.48 91.05 178.11 3,255.01 -6,949.92 -6,184.49 0.00 0.00 0.00 0.00 14,053.82 90.77 178.09 3,254.57 -6,977.24 -6,183.59 1.00 -1.00 -0.07 -175.99 14,466.26 90.77 178.09 3,249.01 -7,389.41 -6,169.86 0.00 0.00 0.00 0.00 1/26/2007 4:09:40PM Page 3 of 7 COMPASS 2003.11 Build 48 Ct7t'K7-COI~IE~I[pS Alaska Halliburton Company ~~L_1.1C~.3~'T'IJN Planning Report -Geographic ~p,B1.,.y Dritiiing Services Datahase: Compass 2003.11 Local Co-ordinate Reference: ``:ell Plan 1J-160 Company: ConocoPhillips Alaska, Inc. TVD Reference: Doyon 15 (40+81) @ 121.OOft (Doyon 15 (40+81)) Project: Kuparuk River Unit MD Reference: noyon 15 (40+81) @ 121.OOft (Doyon 15 (40+81)) `Site: Kuparuk 1J Pad North Reference: True We11: Plan 1J-160 Survey Calculation Method: .Minimum Curvature j Wellbore: Plan 1J-160 L1 Design: 1J-160 Li (wp06) Planned Survey -- 1J-~1G0 L1 (wp06) Map Map MD Inclination Azimuth TVD SSTVD +N/-S +E/_vy Northing Easting DLSEV Vcrt Section (fti (°) (°) (ft) (ft) (ft1 (ft) (ft) (ft) (°I100ft) (ftl 8,663.88 79.32 187.19 3,309.09 3,188.09 -1,594.94 -6,366.40 5,944,183.19 552,315.45 0.00 1,594.94 L1: 9 5i8" TOW @ 86 64' MD 3309' TVD - 419' FSL, 1651' FW L - Sec34-T11 N-R10E - 9 5/8" TOW 8,680.38 81.26 186.06 3,311.88 3,190.88 -1,611.09 -6,368.27 5,944,167.02 552,313.70 13.60 1,611.09 8,700.00 81.26 186.06 3,314.86 3,193.86 -1,630.38 -6,370.32 5,944,147.72 552,311.80 0.00 1,630.38 8,710.38 81.26 186.06 3,316.43 3,195.43 -1,640.58 -6,371.40 5,944,137.51 552,310.80 0.00 1,640.58 8,800.00 85.82 183.19 3,326.51 3,205.51 -1,729.31 -6,378.57 5,944,048.74 552,304.33 6.00 1,729.31 8,824.07 87.05 182.43 3,328.01 3,207.01 -1,753.30 -6,379.74 5,944,024.74 552,303.34 6.00 1,753.30 1J-160 B CP02 10/27/06 8,900.00 90.93 180.03 3,329.35 3,208.35 -1,829.18 -6,381.37 5,943,948.85 552,302.30 6.00 1,829.18 8,969.53 94.47 177.83 3,326.07 3,205.07 -1,898.61 -6,380.08 5,943,879.44 552,304.13 6.00 1,898.61 9,000.00 94.47 177.83 3,323.69 3,202.69 -1,928.97 -6,378.93 5,943,849.10 552,305.52 0.00 1,928.97 9,062.39 94.47 177.83 3,318.83 3,197.83 -1,991.12 -6,376.57 5,943,786.97 552,308.36 0.00 1,991.12 9,100.00 92.98 177.62 3,316.38 3,195.38 -2,028.62 -6,375.09 5,943,749.49 552,310.14 4.00 2,028.62 9,200.00 89.02 177.07 3,314.63 3,193.63 -2,128.48 -6,370.46 5,943,649.68 552,315.54 4.00 2,128.48 9,213.16 88.50 177.00 3,314.92 3,193.92 -2,141.62 -6,369.78 5,943,636.55 552,316.32 4.00 2,141.62 9,300.00 88.50 177.00 3,317.19 3,196.19 -2,228.31 -6,365.24 5,943,549.91 552,321.54 0.00 2,228.31 9,400.00 88.50 177.00 3,319.81 3,198.81 -2,328.14 -6,360.00 5,943,450.13 552,327.55 0.00 2,328.14 9,500.00 88.50 177.00 3,322.43 3,201.43 -2,427.97 -6,354.77 5,943,350.36 552,333.56 0.00 2,427.97 9,600.00 88.50 177.00 3,325.04 3,204.04 -2,527.79 -6,349.54 5,943,250.58 552,339.57 0.00 2,527.79 9,700.00 88.50 177.00 3,327.66 3,206.66 -2,627.62 -6,344.31 5,943,150.81 552,345.58 0.00 2,627.62 9,713.16 88.50 177.00 3,328.01 3,207.01 -2,640.76 -6,343.62 5,943,137.67 552,346.37 0.00 2,640.76 9,800.00 89.37 177.00 3,329.62 3,208.62 -2,727.47 -6,339.08 5,943,051.02 552,351.58 1.00 2,727.47 9,900.00 90.37 177.01 3,329.85 3,208.85 -2,827.33 -6,333.86 5,942,951.21 552,357.58 1.00 2,827.33 10,000.00 91.37 177.01 3,328.34 3,207.34 -2,927.18 -6,328.64 5,942,851.41 552,363.58 1.00 2,927.18 10,038.31 91.75 177.01 3,327.29 3,206.29 -2,965.42 -6,326.65 5,942,813.19 552,365.87 1.00 2,965.42 10,100.00 91.75 177.01 3,325.41 3,204.41 -3,027.00 -6,323.44 5,942,751.64 552,369.56 0.00 3,027.00 10,200.00 91.75 177.01 3,322.35 3,201.35 -3,126.82 -6,318.23 5,942,651.88 552,375.54 0.00 3,126.82 10,300.00 91.75 177.01 3,319.30 3,198.29 -3,226.64 -6,313.03 5,942,552.11 552,381.52 0.00 3,226.64 10,400.00 91.75 177.01 3,316.24 3,195.24 -3,326.45 -6,307.82 5,942,452.35 552,387.51 0.00 3,326.45 10,500.00 91.75 177.01 3,313.18 3,192.18 -3,426.27 -6,302.62 5,942,352.59 552,393.49 0.00 3,426.27 10,538.48 91.75 177.01 3,312.01 3,191.01 -3,464.68 -6,300.61 5,942,314.20 552,395.79 0.00 3,464.68 1J-160 B CP03 10/27/06 10,600.00 91.31 177.45 3,310.36 3,189.36 -3,526.11 -6,297.64 5,942,252.80 552,399.24 1.00 3,526.11 10,700.00 90.60 178.15 3,308.69 3,187.69 -3,626.02 -6,293.80 5,942,152.93 552,403.86 1.00 3,626.02 10,706.49 90.56 178.20 3,308.62 3,187.62 -3,632.51 -6,293.60 5,942,146.45 552,404.11 1.00 3,632.50 10,800.00 90.56 178.20 3,307.71 3,186.71 -3,725.96 -6,290.66 5,942,053.03 552,407.78 0.00 3,725.96 10,900.00 90.56 178.20 3,306.74 3,185.74 -3,825.91 -6,287.51 5,941,953.12 552,411.71 0.00 3,825.91 11,000.00 90.56 178.20 3,305.76 3,184.76 -3,925.86 -6,284.36 5,941,853.21 552,415.63 0.00 3,925.86 11,100.00 90.56 178.20 3,304.79 3,183.79 -4,025.80 -6,281.22 5,941,753.30 552,419.55 0.00 4,025.80 11,200.00 90.56 178.20 3,303.82 3,182.82 -4,125.75 -6,278.07 5,941,653.39 552,423.48 0.00 4,125.75 11,300.00 90.56 178.20 3,302.84 3,181.84 -4,225.69 -6,274.93 5,941,553.48 552,427.40 0.00 4,225.69 11,400.00 90.56 178.20 3,301.87 3,180.87 -4,325.64 -6,271.78 5,941,453.57 552,431.32 0.00 4,325.64 11,488.85 90.56 178.20 3,301.01 3,180.01 -4,414.44 -6,268.99 5,941,364.81 552,434.81 0.00 4,414.44 1J-160 B CP04 10/27/06 11,500.00 90.67 178.18 3,300.89 3,179.89 -4,425.58 -6,268.64 5,941,353.67 552,435.25 1.00 4,425.58 11,576.01 91.42 178.09 3,299.50 3,178.50 -4,501.54 -6,266.17 .5,941,277.74 552,438.31 1.00 4,501.54 1/26/2007 4:09:40PM Page 4 of 7 COMPASS 2003.11 Build 48 ~~ • Cc~r~caPhillps Alasfca C Halliburton Company Planning Report -Geographic ~.~..~..~ ~ IF~Tt'~I Sperry Grilling Serelces Database: Compass 2003.11 Company: ConocoPhillips Alaska, Inc. .Project: Kuparuk River Unit Site: Kuparuk 1J Pad Well: Plan 1J-160 Wellbore: Plan 1J-160 L1 Design: 1J-160 L1 (wp0~~i Local Co-ordinate Reference: Well Plan 1J-160 ND Reference: .Doyen 15 (40+81) @ 121.OOft (Doyen 15 (40+81)) MD Reference: Doyen 15 (40+81) @ 121.OOft (Doyen 15 (40+81)) North Reference: True Survey Calculation Method: Minimum Curvature -_ _ -- Planned Survey - 1J-160 L1 ~ .dp06) Map Map MD Inclination Azimuth ND SSND +NI-S +EI-W Northing Fasting DLSEV Vert Section Iftl ('1 ~~) (ft) Ift) (ft) ~ft~ (ft) (ft) (°I100ft) (ft) 11,600.00 91.42 178.09 3,298.90 3,177.90 -4,525.51 -6,265.37 5,941,253.78 552,439.29 0.00 4,525.51 11,700.00 91.42 178.09 3,296.42 3,175.42 -4,625.42 -6,262.04 5,941,153.90 552,443.40 0.00 4,625.42 11,800.00 91.42 178.09 3,293.94 3,172.94 -4,725.34 -6,258.71 5,941,054.03 552,447.51 0.00 4,725.34 11,900.00 91.42 178.09 3,291.45 3,170.45 -4,825.25 -6,255.38 5,940,954.15 552,451.61 0.00 4,825.25 12,000.00 91.42 178.09 3,288.97 3,167.97 -4,925.16 -6,252.05 5,940,854.28 552,455.72 0.00 4,925.16 12,079.13 91.42 178.09 3,287.01 3,166.01 -5,004.22 -6,249.42 5,940,775.25 552,458.97 0.00 5,004.22 1J-160 B CP05 10/27/06 12,100.00 91.21 178.09 3,286.53 3,165.53 -5,025.08 -6,248.73 5,940,754.40 552,459.83 1.00 5,025.08 12,200.00 90.21 178.09 3,285.28 3,164.28 -5,125.02 -6,245.40 5,940,654.51 552,463.94 1.00 5,125.01 12,251.47 89.70 178.09 3,285.32 3,164.32 -5,176.45 -6,243.68 5,940,603.09 552,466.05 1.00 5,176.45 12,300.00 89.70 178.09 3,285.57 3,164.57 -5,224.96 -6,242.06 5,940,554.60 552,468.04 0.00 5,224.96 12,400.00 89.70 178.09 3,286.10 3,165.10 -5,324.90 -6,238.73 5,940,454.70 552,472.15 0.00 5,324.90 12,500.00 89.70 178.09 3,286.62 3,165.62 -5,424.84 -6,235.40 5,940,354.79 552,476.26 0.00 5,424.84 12,573.38 89.70 178.09 3,287.01 3,166.01 -5,498.19 -6,232.96 5,940,281.48. 552,479.28 0.00 5,498.19 1J-160 B CPO6 10/27/06 12,600.00 89.97 178.09 3,287.08 3,166.08 -5,524.79 -6,232.07 5,940,254.89 552,480.37 1.00 5,524.79 12,627.78 90.24 178.08 3,287.03 3,166.03 -5,552.55 -6,231.14 5,940,227.14 552,481.52 1.00 5,552.55 12,700.00 90.24 178.08 3,286.73 3,165.73 -5,624.73 -6,228.72 5,940,154.98 552,484.50 0.00 5,624.73 12,800.00 90.24 178.08 3,286.30 3,165.30 -5,724.67 -6,225.38 5,940,055.08 552,488.62 0.00 5,724.67 12,900.00 90.24 178.08 3,285.88 3,164.88 -5,824.62 -6,222.03 5,939,955.18 552,492.74 0.00 5,824.62 13,000.00 90.24 178.08 3,285.45 3,164.45 -5,924.56 -6,218.69 5,939,855.27 552,496.87 0.00 5,924.56 13,100.00 90.24 178.08 3,285.03 3,164.03 -6,024.50 -6,215.34 5,939,755.37 552,500.99 0.00 6,024.50 13,104.84 90.24 178.08 3,285.01 3,164.01 -6,029.34 -6,215.18 5,939,750.53 552,501.19 0.00 6,029.34 1J-160 B CP07 10/27/06 13,200.00 91.20 178.08 3,283.81 3,162.81 -6,124.44 -6,212.00 5,939,655.47 552,505.11 1.00 6,124.44 13,300.00 92.20 178.08 3,280.85 3,159.85 -6,224.34 -6,208.66 5,939,555.61 552,509.23 1.00 6,224.34 13,327.14 92.47 178.08 3,279.75 3,158.75 -6,251.44 -6,207.75 5,939,528.52 552,510.35 1.00 6,251.44 13,400.00 92.47 178.08 3,276.61 3,155.61 -6,324.19 -6,205.32 5,939,455.79 552,513.35 0.00 6,324.19 13,500.00 92.47 178.08 3,272.31 3,151.31 -6,424.04 -6,201.98 5,939,355.98 552,517.47 0.00 6,424.04 13,600.00 92.47 178.08 3,268.01 3,147.01 -6,523.90 -6,198.64 5,939,256.17 552,521.59 0.00 6,523.90 13,700.00 92.47 178.08 3,263.70 3,142.70 -6,623.75 -6,195.30 5,939,156.36 552,525.71 0.00 6,623.75 13,739.46 92.47 178.08 3,262.01 3,141.01 -6,663.15 -6,193.98 5,939,116.97 552,527.33 0.00 6,663.15 1J-160 B CP08 10/27106 13,800.00 91.86 178.10 3,259.72 3,138.72 -6,723.61 -6,191.96 5,939,056.53 552,529.82 1.00 6,723.61 13,881.53 91.05 178.11 3,257.65 3,136.65 -6,805.07 -6,189.26 5,938,975.10 552,533.15 1.00 6,805.07 13,900.00 91.05 178.11 3,257.32 3,136.32 -6,823.53 -6,188.66 5,938,956.65 552,533.90 0.00 6,823.53 14,000.00 91.05 178.11 3,255.49 3,134.49 -6,923.46 -6,185.36 5,938,856.76 552,537.97 0.00 6,923.46 14,026.48 91.05 178.11 3,255.01 3,134.01 -6,949.92 -6,184.49 5,938,830.31 552,539.05 0.00 6,949.92 1J-160 B CP09 10/27/06 14,053.82 90.77 178.09 3,254.57 3,133.57 -6,977.24 -6,183.59 5,938,803.00 552,540.17 1.00 6,977.24 14,100.00 90.77 178.09 3,253.95 3,132.95 -7,023.39 -6,182.05 5,938,756.87 552,542.06 0.00 7,023.39 14,200.00 90.77 178.09 3,252.60 3,131.60 -7,123.32 -6,178.72 5,938,656.97 552,546.17 0.00 7,123.32 14,300.00 90.77 178.09 3,251.25 3,130.25 -7,223.26 -6,175.39 5,938,557.08 552,550.27 0.00 7,223.26 14,400.00 90.77 178.09 3,249.90 3,128.90 -7,323.20 -6,172.07 5,938,457.18 552,554.38 0.00 7,323.20 1/26/2007 4:09:40PM .Page 5 of 7 COMPASS 2003.11 Build 48 ?~~~''~ • • C4~4~1i~~1p5 Alaska Database: Compass 2003.11 ~ Company: ConocoPhillips Alaska, Inc. Project: Kuparuk River Unit Site: Kuparuk 1J Pad Well: Plan 1J-160 Wellbore: Plan 1J-160 L1 LDesign:__ 1J-160 L1 (wp06) Halliburton Company .~i.L.i1~U TC~~ Planning Report -Geographic SPer`~'Y Drilling Services Local Co-ordinate Reference: Well Plan 1J-160 TVD Reference: Doyon 15 (40+81) @ 121.OOft (Doyon 15 (40+81)) MD Reference: Doyon 15 (40+81) @ 121.OOft (Doyon 15 (40+81)) North Reference: True Survey Calculation Method: Minimum Curvature Planned Survey 1J-1L0 LI twp06) Map Map MD Inclination Azimuth TVD SSTVD +N/-S +E/_~y Northing Easting DLSEV Vert Section (ft) (~) (~) (ft) (ftl (ft) (ft) (ft) (ft) (°1100ft1 (ft) 14,466.06 90.77 178.09 3,249.01 3,128.01 -7,389.21 -6,169.87 5,938,391.19 552,557.09 0.00 7,389.21 L1: BHL @ 14466' MD, 3249' TVD - 96' FNL, 1 842' FWL - S ec10-T10N-R10E - 4 1/2" 14,466.26 90.77 178.09 3,249.01 3,128.01 -7,389.41 -6,169.86 5,938,390.99 552,557.10 0.00 7,389.41 1J-160 B Toe 10/27106 ~- Geologic Targets Plan 1J-160 L1 ND Target Name +N/-S +E/-W Northing Easting (ft) -Shape ft ft (ft) (ft) 3,287.01 1J-160 B_CP05 10/27/06 -5,004.22 -6,249.42 5,940,775.25 552,458.97 - Point 3,312.01 1J-160 B_CP03 10/27/06 -3,464.68 -6,300.61 5,942,314.20 552,395.79 - Point 3,249.01 1J-160 B_Toe 10/27/06 -7,389.41 -6,169.86 5,938,390.99 552,557.10 - Point 3,262.01 1J-160 B_CPO8 10/27/06 -6,663.15 -6,193.98 5,939,116.97 552,527.33 -Point 3,255.01 1J-160 B_CP09 10/27/06 -6,949.92 -6,184.49 5,938,830.31 552,539.05 - Point 3,303.01 1J-160 B_Heel 1/19/07 -1,595.13 -6,366.42 5,944,183.00 552,315.43 - Polygon Point 1 0.00 0.00 5,944,183.00 552,315.43 Point 2 -354.81 15.28 5,943,828.38 552,333.47 3,328.01 1J-160 B_CP02 10/27/06 -2,640.78 -6,328.82 5,943,137.77 552,361.17 - Point 3,301.01 1J-160 B_CP04 10/27/06 -4,414.44 -6,268.99 5,941,364.81 552,434.81 - Point 3,285.01 1J-160 B_CP07 10/27/06 -6,029.34 -6,215.18 5,939,750.53 552,501.19 - Point 3,287.01 1J-160 B_CP06 10/27/06 -5,498.19 -6,232.96 5,940,281.48 552,479.28 - Point 3,307.01 1J-160 B_CP01 10/27/06 -1,949.91 -6,351.14 5,943,828.38 552,333.47 - Polygon Point 1 0.00 0.00 5,943,828.38 552,333.47 Point 2 -690.87 22.32 5,943,137.77 552,361.17 1/26/2007 4:09:40PM Page 6 of 7 COMPASS 2003.11 Build 48 F" fi Cc~r~ocoPhi[~ips Alaska Compass 2003.11 ConocoPhillips Alaska, Inc. Kuparuk River Unit Kuparuk 1J Pad Plan 1J-160 Plan 1J-160 L1 1J-160 L1 (wp05; H t~f,~.1~.1R"T`71 Sperry Qrilling Services Database: Company: Project: Site: Well: Wcllbore: I Design: I Prognosed Casing Points Measured Verticai Casing Hole Depth Depth Diameter Diameter (ft) lft) (") (°} 3,317.26 2,153.28 13-3/8 16 8,663.90 3,309.10 9-5/8 12-1 /4 14,466.06 3,249.01 4-1 /2 6-3/4 Prognosed Formation Intersection Points Measured Vertical Depth Inciination Azimuth Dcpth +N/-E +E/-W (ft) ('1 f') (ftl (ft) (ft) Name 1,667.19 47.14 267.00 1,525.76 -26.12 -498.36 Pfrost 1,856.80 50.93 267.67 1,651.58 -32.96 -639.99 T3 2,423.51 67.82 269.98 1,939.25 -42.06 -1,125.76 K15 3,317.26 78.11 271.11 2,153.28 -28.39 -1,992.03 Casing Pt 5,863.51 78.11 271.11 2,678.05 19.98 -4,483.15 Ugnu C 6,672.60 75.95 247.57 2,861.21 -115.83 -5,253.24 Ugnu B 6,925.75 75.73 239.74 2,923.21 -224.64 -5,473.03 Ugnu A 7,595.32 76.38 219.05 3,086.20 -645.11 -5,963.32 K 13 8,244.03 78.50 200.00 3,228.00 -1,195.36 -6,269.83 W Sak D 8,504.39 78.94 192.05 3,279.00 -1,440.56 -6,340.24 W Sak C 8,631.13 79.23 188.19 3,303.00 -1,563.06 -6,362.09 W Sak B - - --~ Plan Annotations Measured Vertical Local Coor dinates Depth Depth +N!-S +EI-W Comment (ft) lft) (ftl eft) 8,663.90 3,309.10 -1,594.96 -6,366.40 L1: 9 5/8" TOW @ 8664' MD 3309' TVD - 419' FSL, 1651' FWL - Sec34-T11~ 14,466.06 3,249.01 -7,389.21 -6,169.87 L1: BHL @ 14466' MD, 3249' TVD - 96' FNL, 1842' FWL - Sec10-T10N-R10E Halliburton Company Planning Report -Geographic Local Co-ordinate Reference: Well Plan 1J-160 TVD Reference: Doyon 15 (40+81) @ 121.OOft (Doyon 15 (40+g1)) MD Reference: Doyon 15 (40+81) @ 121.OOft (Doyon 15 (40+g1)) North Reference: True Survey Calculation Method: Minimum Curvature 1/26/2007 4:09:40PM Page 7 of 7 ~ COMPASS 2003.11 Build 48 ~~~ ~ ~ ~ .~.~ :~ • ConocoPhillips Alaska • Plan : 1 J-160 L1 (wp06) Sperry Drilling Services Anticollision Summary 26 January, 2007 ConocoPhillips Alaska, Inc. Kuparuk River Unit Kuparuk 1J Pad Plan 1J-160 Plan 1J-160 L1 Local Coordinate Origin: Centered on Well Plan 1J-160 Viewing Datum: Doyon 15 (40+81) @ 121.OOft (Doyon 15 (40+81)) TVDs to System: N North Reference: True Unit System: API - US Survey Feet ~~~ 8p®rry Oriliing 8erviaes ,~, a SURVEY PROCR4M llate: 2007-01-19700:00:00 Validated: Yes Version: 15.000 Depth FroFnDepth To Survey/Plan Tool 40.00 1000.00 C~GYRO-SS 1000.00 3929.01 MND+IFR-AK-CA~SC 3929.01 8663.88 MW"D+IFR-AK-CA~SC 8663.8814465.86 1J-160 Ll (wp06) D7WD+iFR-AK-C.>~SC p 1J-160 (wp06) ANTI-COLLISION SETTINGS Interpolation Method: MD Interval: SOStations Depth Range From: 8663.88 To 14466.072082' Maximum Range:1642.60720027888 Reference: Plan: 1J-160 L1 (wp06) 1J-160 (wp06) 270 180 Travelling Cylinder Azimuth (TFO+.ALI) (°~ vs Centre to Cenh•c Separation X150 ft/ink NAD 27 ASP Zone 4 : WELL DETAILS: Plan 1J-160 Ground Level: 0.00 +NI-S+EI-W Northing Easting Latittude Longitude Slot 0.00 0.00 5945827.52 558668.60 70°15'45.361N 149°31'32.565W REFERENCE INFORMATION Co-ordinate (N/E) Reference: Well Plan 1J-160, True North Vertical (TVD) Reference: Doyon 15 (40+81) @ 121.OOft (Doyon 15 (40+81)) Section (VS) Reference: Slot - (O.OON, O.DOE) Measured Depth Reference: Doyon 15 (40+g1) ~ 121.OOft (Doyon 15 (40+g1)) Calculation Method: Minimum Curvature From Colour To MD 0 8500 8500 9000 9000 9500 9500 10000 10000 11000 11000 12000 12000 -- 13000 13000 14000 14000 15000 180 90 Travelling Cylinder elzinmth (TFO+ALI) ~°~ vs Centre to Centre Separation i50 it/in( 64< MD fa TVD +WS +E/-W pLe9 TFace VSec Target 1 6663.66 )932 16).16 3309.13 -15%.11 -63%.22 0.00 2 8680.38 8126 18605 331191 -16112] b3%.10 1360 0.00 t5%.tt -3(1.00 16112] 3 8]1038 8126 18605 3316 d) -1640)5 b3]122 000 8%9.16 M.48 1P8] 332608 -18%.41 -63]9.% 6W 000 1640]5 -3199 1898.91 5 9%189 94 dB 1)78] 3318.84 -1990.89 b3)653 000 000 19%.89 6 921298 88.50 1]]00 3319.92 -2191.62 ~fi369.18 4.00 ] 9]1298 88.50 1]]00 332601 -2fid0 )6 -6343fiZ 000 -1]1.68 2141.62 000 2640.]6 8 10038.13 91]5 1]]00 332729 -2%5 d2 -6326 fi0 1.00 9 10538.29 91.]5 11700 331201 -3464.66 6300.41 000 -004 2%5.42 000 3464.66 1}1606_CPo3 10'2)106 10 1010).80 %.56 1]8.20 33%S9 ;3633.% -639331 100 134.80 % 11 11488.66 %.% 1]8.30 3301.01 -041442 -6268.19 °00 12 115]599 9142 1]609 3299.50 450168 b266% 100 0.00 44 4.42 1J~160 B_CPo4 102]/% -].13 450168 120)894 9 1]609 328}Ot -500421 -624922 000 000 5004.21 1J-160 B_CP05102]I% 14 1225131 89]0 1)609 328532 -51)64] -629348 100 15125]3]0 89.]0 1]809 328)01 -5498.1) -6232.)6 0.00 -1]991 51 J6 d] 000 54981) 1J-1606_CP%tN2]I% 16 1263/.61 %.Z4 1]808 328).p3 -5552.$ b330.94 1.00 -083 555255 111310466 90.19 11608 328501 4A2932 -621498 0.00 18 13326 % 93 d] t )608 32]9 )5 b251 02 -620] 55 1.00 0.00 6029.32 1}1606_CPO] 1N2]I% 0.02 6251.42 19 13>39.28 9Z 47 1]6.08 326201 -6663.13 -6193.)8 000 ZO 13881.35 91 OS 1]8.11 325]65 -68(IS.W -6189.% 100 000 6663.13 111608 CP08 1N2]/Ofi 1)086 6805% Zt 14026.30 9105 1)6.11 325501 694990 -6184.29 000 000 6949% 1J-1600_CPo9 10271% 22 1405364 90.]) 1]609 3254.5] b9)]22 618339 100 23 144%0) 90.]] 1]809 324901 -]38939 b169.% 600 -1]599 69]1.23 000 ]389.39 1J-1606_TOe 1012]!06 COMPANY DETAILS: ConocoPhillips Alaska, Inc. Engineering Calculation Method: Minimum Curvature Error System: ISCWSA Scan Method: Trav. Cylinder North Error Surface: Elliptical Conic Warning Method: Rules Based • r CUt1C1GQ~1~~1~35 Alaska Company: ConocoPhillips Alaska, Inc Project: Kuparuk River Unit Reference Site: Kuparuk 1J Pad '~ Sifc Error, O GOft ~ Referenco Well: Plan IJ-160 Well Error: D.i1Gfl Reference Wellbore Plan 1J-160 L1 ~ Reference Design: 1J-160 L1 (wp06) Halliburton Company Anticollision Report LoCa1 Co-ordinate Referenco: ND Reference: MD Reference: North Reference: Survey Calculation Method: Output errors are at Database: ' Offset TVD Reference: • Sperry Dritiing Services Well Plan 1J-160 Doyon 15 (40+81) @ 121.OOft (Doyon 15 (40+81)) Doyon 15 (40+81) @ 121.OOft (Doyon 15 (40+81)) True Minimum Curvature 2.00 sigma Compass 2003.11 Offset Datum Reference 1J-160 L1 (vvh~u~:: Filter type: GLOBAL FILTER APPLIED: All wellpaths within 200'+ 100/1000 of refer Interpolation Method: MD Interval 25.OOft Error Model: ISCWSA Depth Range: 8,663.88 to 14,466.07ft Scan Method: Trav. Cylinder North Results Limited by: Maximum center-center distance of 1,642.61ft Error Surtace: Elliptical Conic Warning Levels evaluated at: 0.00 Sigma r- _ _ __ Survey Tool Program Date 1 , 2007 From To (ft} (ft) Survey (Wellbore) 40.00 1,000.00 1J-160 (wp06) (Plan 1J-160) 1,000.00 3,929.01 1J-160 (wp06) (Plan 1J-160) 3,929.01 8,663.88 1J-160 (wp06) (Plan 1J-160) 8,663.88 14,465.86 1J-160 L1 (wp06) (Plan 1J-160 L1) Tool Name Description CB-GYRO-SS Camera based gyro single shot MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 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 1/26/2007 10:48:07AM Page 2 of 3 COMPASS 2003.11 Build 48 ~3~x~~ n L Corx3c©P~~tlips Alaska Company: Project: Reference Site:. Site Error: Reference Well: Well Error: Reference Wellbore Reference Design: ConocoPhillips Alaska, Inc. Kuparuk River Unit Kuparuk 1J Pad O.OOft Plan 1J-160 O.OOft Plan 1J-160 L1 1J-160 L1 (wp06) Halliburton Company Anticollision Report Local Co-ordinate Reference: ND Reference: MD Reference: North Reference: Survey Calculation Method: Output errors are at Database: Offset lVD Reference: Summary Reference Offset Centre to No-Go Allowable Measured Measured Centre Distance Deviation Warning Site Name Depth Depth Distance (ft) from Plan Offset WeII -Wellbore -Design (ft) (ft) (ft) (ft) Kuparuk 1J Pad 1 J-105 - 1 J-1-09 - 1 J-109 1J-152 - 1J-152 - 1J-152 1J-152 - 1J-152 L1 - 1J-152 L1 1J-152 - 1J-152 L2 - 1J-152 L2 1J-152 - 1J-152 PB2 - 1J-152 PB2 1J-154 - 1J-154 - 1J-154 1J-154 - 1J-154 L1 - 1J-154 L1 1J-154 - 1J-154 L2 - 1J-154 L2 1J-156 - 1J-156 - 1J-156 1J-156- 1J-156L1 - 1J-156L1 1J-156 - 1J-156L1PB1 - 1J-156L1PB1 1J-156 - 1J-156L2 - 1J-156L2 1 J-159 - 1 J-159 - 1 J-159 1J-159 - 1J-159 L1 - 1J-159 L1 1J-159 - 1J-159 L1 PB2 - 1J-159 L1 PB2 1J-159 - 1J-159 L2 - 1J-159 L2 1J-159 - 1J-159 PB1 - 1J-159 PB1 Plan 1J-105 - 1J-105 - 1J-105 (wp03) Plan 1J-105 - 1J-105 L1 - 1J-105 L1 (wp03) Plan 1J-105 - 1J-105 L2 - 1J-105 L2 (wp03) Plan 1J-107 -Plan 1J-107 - 1J-107 (wp03) Plan 1J-107 -Plan 1J-107 L1 - 1J-107 L1 (wp03) Plan 1J-107 -Plan 1J-107 L2 (wp03) - 1J-107 L2 i Plan 1J-111 -Plan 1J-111 - 1J-111 (wp03) Plan 1J-158 - 1J-158 - 1J-158 (wp06) Plan 1J-158 - 1J-158 L1 - 1J-158 L1 (wp06) Plan 1J-158 - 1J-158 L2 - 1J-158 L2 (wp06) Plan 1J-160 -Plan 1J-160 - 1J-160 (wp06) Plan 1J-160 -Plan 1J-160 L2 - 1J-160 L2 (wp06) Plan 1J-162 - 1J-162 - 1J-162 (wp05) Plan 1J-162 - 1J-162 L1 - 1J-162 L1 (wp3.1) Plan 1J-162 - 1J-162 L2 - 1J-162 L2 (wp3.1) Plan 1J-174 (01 Phase 2) - 1J-174 - 1J-174 (wp0: Plan 1J-174 (Q1 Phase 2) - 1J-174 L1 - 1J-174 L1 Plan 1J-176 (02 Phase 2) - 1J-176 - 1J-176 (wp0; Plan 1J-176 (Q2 Phase 2) - 1J-176 L1 - 1J-176 L1 Rig: 1 J-103 - 1 J-103 - 1J-103 Rig: 1J-103 - 1J-103 L1 - 1J-103 L1 Rig: 1J-103 - 1J-103 L1 PB1 - 1J-103 L1 (wp10) Rig: 1J-103 - 1J-103 L2 - 1J-103 L2 Rig: 1J-103 - 1J-103 L2 - 1J-103 L2 Pilot Toe (wp Rig: 1J-103 - 1J-103 L2 Pilot Toe - 1J-103 L2 Pilo Rig: 1J-103 - 1J-103PB1 - 1J-103PB1 Rig: 1J-103 - 1J-103PB2 - 1J-103PB2 Rig: 1J-103 - 1J-103PB3 - 1J-103PB3 Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range 8,690 .16 8,000. 00 1,455. 40 122. 74 1,332. 66 Pass -Major Risk 8,688 .39 8,000. 00 1,438. 03 121. 89 1,316. 15 Pass -Major Risk 13,535 .36 12,650. 00 1,642. 06 365. 18 1,276. 88 Pass -Major Risk 8,675 .00 8,675. 00 0. 13 0. 47 -0. 34 FAIL - No Errors 9,433 .67 9,425. 00 53. 54 1. 27 52. 27 Pass - No Errors 8,900 .00 10,299. 98 1,568. 25 116. 95 1,451. 30 Pass -Major Risk 8,900 .00 10,150. 00 1,583. 58 117. 27 1,466. 31 Pass -Major Risk 8,900 .00 10,150. 00 1,584. 98 117 .81 1,467. 17 Pass -Major Risk 13,457 .14 10,150. 00 467. 36 189 .45 277. 91 Pass --Major Risk 13,457 .14 10,150 .00 467. 36 189 .49 277. 87 Pass -Major Risk 14,466 .07 10,425. 00 375. 48 229. 06 146. 42 Pass -Major Risk 14,466 .07 10,425. 00 375. 48 229. 36 146. 11 Pass -Major Risk Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range CC -Min centre to center distance or covergent point, SF -min separation factor, ES -min ellipse separation 1/26/2007 10:48:07AM Page 3 of 3 COMPASS 2003.14 Build 48 • ~a~-L~,M ~ u~t~r r~ Sperry C~rilting 8erertca~ Well Plan 1J-160 Doyon 15 (40+81) @ 121.OOft (Doyon 15 (40+81)) Doyon 15 (40+81) @ 121.OOft (Doyon 15 (40+81)) True Minimum Curvature 2.00 sigma Compass 2003.11 Offset Datum ~~?~~"~ • TRANSMITTAL LETTER CHECKLIST WELL NAME /~~~ ~ ~""~G~ PTD# ~o ~ - d l.~ Development Service Exploratory Stratigraphic Test Non-Conventional Well Circle Appropriate Letter /Paragraphs to be Included in Transmittal Letter CHECK ADD-ONS TEXT FOR APPROVAL LETTER WHAT (OPTIONS) APPLIES MULTI LATERAL The permit is for a new wellbore se m ~t of existing ~ / well ~~~ l a.~ '~ ~~fJ(.,/ , (If last two digits in A permit No. 20.6/.S, API No. 50-~- L3'~ D~ . PI number are between 60-69) j Production should continue to be reported as a function of the I original API number stated above. ~ PILOT HOLE In accordance with 20 AAC 25.005(f), all records, data and logs acquired for the pilot hole must be clearly differentiated in both well name ( PH) and API number (50- - -_) from records, data and logs acquired for well SPACING The permit is approved subject to full compliance with 20 AAC EXCEPTION 25.055. Approval to perforate and produce /inject is contingent upon issuance of a conservation order approving a spacing ~ exception. assumes the ~ liability of any protest to the spacing exception that may occur. DRY DITCH All dry ditch sample sets submitted to the Commission must be in ~ SAMPLE no greater than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. Please note the following special condition of this permit: Non-Conventional production or production testing of coal bed methane is not allowed Weli for (name of welly until after (Company Name) has designed and implemented a water well testing program to provide baseline data on water quality and quantity. (Company NameZmust contact the Commission to obtain advance approval of such water well testing rogram. Rev: I /25/06 C : \j odyltransmittal_checkl ist • • ~~ O) O ~ . ~ W ~ ~ ~ .O ~ ~ ~ O. ~ ~ - ~ r. Q' C ~, ~~ , , ~ ~ d N p' ~: . ~ m ~~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ N c. N, O , 4 ~ ~ ~ ~ a. O , ~ W ~ N ~ t a, v. o: v a. ~ N ~ a, ~ m v ~~ ' ~ L. ~ ~ ~ ~ O. ' ~ N. ~ ~ ~~ ~~ f6. 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E. i ~ a i, N, i ~ ~ 'v. ~, ~ M. ~ N ~ ~ ~ ~, • o N ~' ° aci' 3. ia' a'i o' w O .~ o a n ° ~ ° a' c' ' v, a, ' a' a~, , ~ , .. a i ~ •_ ' ' °' ~, ~: :.. o ~ p, 6 ' ~ ~ o' ' ,~ Q a ~ m' o, °~ o a L: Z, ~'' .,- ' U a J J a; t, flL m ~ d m N. a 4 4 N ~ ~ o ~ O, fl N~ N o Q m E o, U C ~, N ~ ~ Y ° °' Q ~ N d - i a ~ o N o ar a r~ ~' a ~' N' ` a m' ~' ~' O O' U ~ o ~ +-' a i' °: O' G' N; O' c O ~ Z U, f0. ~~ O O. O. OS N ~ < • .~ q y, N, O N : . .L..•, r, 'C, N, O) Q'. (O (6 N; N' U O N' O N' p1 T C ~'~ 2~ a~ y~ ~ ~ O, O. N ~ ~~ "" t6 C N, c: d O. N~ 7+ y. y. N ~~ ~, a' 0) C' C O' tyr O, ~ c. ~' ~' ~ 7. a ~' ~' O, 7 p' O' y' j~ ""'' ~' m' (6 N c m' a m. C U ;~ •N a> a~ >: U 'O O .o? to o, L ° 3 .~ y O y C U cr ~ ~ c. m. c, C ~, O O, ~~ ~~ ~~ d, ~~ . -a, O, L, G C. m m ~~ , . w' 3; p a~ O, o p m ° p, o , p _~ ~ ° . ~ ~, ° O. o ~ f6. C. N. N . O. ° o N, c ~ Z ~ p, p, V- c m. m. u~, ~' v c~ v ~, °, °~ ° , , ~ ° ° o p ~, '?, o c, ~ o, o, _ ~'' ' a' ~ m: _ v, m, °~ a ~ o- ~ _ c p •~ 3 o ° ~ ~ a, O o ~, _° -_ 'o, _- ~, ~, a -°, a~, o 3 ~ ° > > 3 m > > a i, O1 c w w, ~ `~ f6 °- ° N m, ui Y >, a~ a`0i, ~c p' °' o' ~, v ~ ~ ~' 4 4 a~' ~ ~ ~ . a ' ' ' . o ~ ~, ~ ~ ~ a f6~ a, ~° ' o O' O r', ° o' ~' ' ' ' a`~' ~, i a~6i ~a o ~ U c a, -~, ~, , cn, ~; ; ; o, o, a; a, v , a; z ~ ¢ v, cn, v v. v, v, Q, ~; Q. ~; ; m, m, ~, ~ , ~ , `~ a, o, cn, cn, v. w a N R~ f0 f~ 00 r r O r r r si' ~O CO f~ r r r r r N W O O r r N N N M N ~ N ~O CO I~ N N N 00 N r m O N M M N M V M M M M M M ~ n o ~ o^ ~ o 0 C G p C ~ N R N I f~ 6 N V p M ~ 0 O (\ ~ ~ N ~ ~ ~ D O M Of W O N W p R ` r i G N r O' Ja N y ~ ~ ~ ~ ~~ W a ~ c a ~ ~ ~ O a 0 U ~ ~ ~ a cn ~ W a ~ ~ Q`n a s • Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special efifort has been made to chronologically organize this category of information. 1J160L10032520075SN.txt Sperry-Sun Drilling Services LIS Scan Utility $Revision: 3 $ LisLib $Revision: 4 $ Fri May 25 16:43:15 2007 Reel Header Service name .............LISTPE Date . ...................07/05/25 Ori9in ...................STS Reel Name. .... ........UNKNOWN Continuation Number......01 Previous Reel Name.......UNKNOWN Comments .................STS LIS writing Library. Tape Header Service name .............LISTPE Date . ...................07/05/25 Origin ...................STs Tape Name. .... ........UNKNOWN Continuation Number......01 Previous Tape Name.......UNKNOWN Comments .................STS LIS Writing Library. Physical EOF comment Record TAPE HEADER Kuparuk River unit west sak MWD/MAD LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: • scientific Technical services Scientific Technical services 1J-160 L1 500292334460 ConocoPhillips Alaska Inc. Sperry Drilling Services 25-MAY-07 MWD RUN 3 MWD RUN 4 MWD RUN 5 W-0004877337 W-0004877337 W-0004877337 T. MCGUIRE R. WILSON R. WILSON M. THORNTON M. THORNTON F. HERBERT MWD RUN 6 MWD RUN 7 w-0004877337 w-0004877337 R. WILSON R. WILSON F. HERBERT F. HERBERT 35 11N l0E 2016 2541 Page 1 ~-~-~ ao~-"~« * ~`Zs1~~ ELEVATION (FT FROM MSL O) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD 1J 160L1003252007SSN.txt 122.29 81.00 OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 1sT STRING 12.250 13.375 3551.0 2ND STRING 6.750 9.625 8750.0 3RD STRING PRODUCTION STRING REMARKS: 1. ALL DEPTHS ARE BIT DEPTHS UNLESS OTHERWISE NOTED. THESE DEPTHS ARE MEASURED DEPTH (MD). 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTH (TVD). 3. THIS WELLBORE IS AN OPENHOLE SIDETRACK EXITING THE 1J-160 L1PB1 WELLBORE AT 9200'MD/3287'TVD. 4. MWD RUNS 1 & 2 WERE DIRECTIONAL ONLY - NO DATA ARE PRESENTED. 5. MWD RUNS 3,5-7 COMPRISED DIRECTIONAL, DUAL GAMMA RAY (DGR) UTILIZING GEIGER- MUELLER TUBE DETECTORS, ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4), AND PRESSURE-WHILE-DRILLING (PWD). MWD RUNS 5,6 ALSO INCLUDED AT-BIT INCLINATION (ABI), AND MWD RUN 7 ALSO INCLUDED GEO-PILOT ROTARY STEERABLE BHA (G P). POROSITY LOG DATA ACQUIRED OVER THE MWD RUN 3 INTERVAL ARE PRESENTED WITH THE 1J-160 LOGS. 6. DEPTH SHIFTING OF MWD DATA WAS WAIVED PER E-MAIL, DATED 12/16/04, FROM M. WERNER (CPAI) TO R. KALISH (SDS). MWD DATA ARE CONSIDERED PDC. 7. MWD RUNS 1-7 REPRESENT WELL 1J-160 L1 WITH API#: 50-029-23344-60. THIS WELL REACHED A TOTAL DEPTH (TD) OF 13064'MD/3264'TVD. SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRC = SMOOTHED GAMMA RAY COMBINED. SEXP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (EXTRA SHALLOW SPACING). SESP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (SHALLOW SPACING). SEMP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (MEDIUM SPACING). SEDP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (DEEP SPACING). SFXE = SMOOTHED FORMATION EXPOSURE TIME (DEEP SPACING). SLIDE = NON-ROTATED INTERVALS REFLECTING BIT DEPTHS. File Header service name .............sTSLI6.001 Page 2 17160L10032520075SN.txt service sub Level Name... version Number.. ........1.0.0 Date of Generatio n.......07/05/25 Maximum Physical Record..65535 File Type. .... ........LO Previous File Nam e.......STSLIB.000 Comment Record FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE START DEPTH STOP DEPTH GR 3525.0 13006.0 NPHI 3540.0 8750.0 RPM 3540.0 13013.5 FCNT 3540.0 8750.0 RPD 3540.0 13013.5 RPS 3540.0 13013.5 FET 3540.0 13013.5 NCNT 3540.0 8750.0 DRHO 3540.0 8750.0 CALA 3540.0 8750.0 RHOB 3540.0 8750.0 RPx 3540.0 13013.5 PEF 3540.0 8750.0 ROP 3561.5 13064.0 BASELINE CURVE FOR 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 3525.0 8750.0 MwD 4 8750.5 8783.0 MwD 5 8783.0 9200.0 MwD 6 9200.0 11000.0 MwD 7 11000.0 13064.0 REMARKS: MERGED MAIN PASS. Data Format specification Record Data Record Type... ..........0 Data Specification Block Type.....0 Loging 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 Page 3 • 1~160L1o03252007sSN.txt DEPT FT 4 1 68 0 1 CALA MWD INCH 4 1 68 4 2 FCNT MWD CNTS 4 1 68 8 3 NCNT MWD CNTS 4 1 68 12 4 RHOB MWD G/CM 4 1 68 16 5 DRHO MWD G/CM 4 1 68 20 6 RPD MWD OHMM 4 1 68 24 7 RPM MWD OHMM 4 1 68 28 8 RPS MWD OHMM 4 1 68 32 9 RPX MWD OHMM 4 1 68 36 10 FET MWD HOUR 4 1 68 40 11 GR MWD API 4 1 68 44 12 PEF MWD BARN 4 1 68 48 13 ROP MWD FT/H 4 1 68 52 14 NPHI MWD PU-S 4 1 68 56 15 First Last Name Service unit Min Max Mean Nsam Reading Reading DEPT FT 3525 13064 8294.5 19079 3525 13064 GALA MWD INCH 10.18 14.32 12.2903 10421 3540 8750 FCNT MWD CNTS 548.07 3672.06 1053.54 10421 3540 8750 NCNT MWD CNTS 127381 225203 172510 10421 3540 8750 RHOB MWD G/CM 0.071 2.889 2.12846 10421 3540 8750 DRHO MWD G/CM -4.72 0.289 0.0518945 10421 3540 8750 RPD MWD OHMM 1.7 2000 56.9824 18948 3540 13013.5 RPM MWD OHMM 4.75 2000 57.2992 18948 3540 13013.5 RPS MWD OHMM 4.6 2000 47.9676 18948 3540 13013.5 RPX MWD OHMM 3.3 2000 49.5367 18948 3540 13013.5 FET MWD HOUR 0.1 100.94 1.21254 18948 3540 13013.5 GR MwD API 19.59 121.33 67.1695 18963 3525 13006 PEF MWD BARN -0.32 12.99 2.1104 10421 3540 8750 ROP MWD FT/H 3.07 1944.23 206.52 19006 3561.5 13064 NPHI MwD Pu-S 9.25 107.7 40.8326 10421 3540 8750 First Reading For Entire File..........3525 Last Reading For Entire File...........13064 File Trailer service name... .......sTSLI6.001 service sub Level Name... version Number. ........1.0.0 Date of Generation.......07/05/25 Maximum Physical Record..65535 File TyC~e ................L0 Next File Name...........STSLIB.002 Physical EOF File Header Service name... .......STSLIB.002 service sub Level Name... version Number. ........1.0.0 Date of Generation.......07/05/25 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......STSLI6.001 Page 4 • 17160L100325200755N.txt comment Record FILE HEADER FILE NUMBER: 2 RAW MWD curves and log header data for each bit run in separate files. BIT RUN NUMBER: 3 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 3525.0 8750.0 FET 3540.0 8750.0 NCNT 3540.0 8750.0 RHOB 3540.0 8750.0 PEF 3540.0 8750.0 GALA 3540.0 8750.0 FCNT 3540.0 8750.0 RPS 3540.0 8750.0 RPX 3540.0 8750.0 NPHI 3540.0 8750.0 DRHO 3540.0 8750.0 RPM 3540.0 8750.0 RPD 3540.0 8750.0 ROP 3561.5 8750.0 LOG HEADER DATA DATE LOGGED: 13-MAR-07 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 72.13 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 8750.0 TOP LOG INTERVAL (FT): 3560.0 BOTTOM LOG INTERVAL (FT): 8750.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 76.3 MAXIMUM ANGLE: 87.3 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 76571 EWR4 ELECTROMAG. RES IS. 4 78633 CTN COMP THERMAL NE UTRON 158416 ALD Azimuthal Litho -Dens 220637 ACAL Acoustic Calipe r 727406 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 12.250 DRILLER'S CASING DEPTH (FT): 3551.0 BOREHOLE CONDITIONS MUD TYPE: LSND MUD DENSITY (LB/G): 9.10 MUD VISCOSITY (5): 60.0 MUD PH: 9.4 MUD CHLORIDES (PPM): 700 FLUID LOSS (C3): 5.6 RESISTIVITY (OHMM) AT TEMPERATURE (DEG F) MUD AT MEASURED TEMPERATURE (MT): 2.300 70.0 MUD AT MAX CIRCULATING TERMPERATURE: 1.430 116.6 Page 5 MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: • 17160L1o032520075SN.txt 2.600 70.0 3.000 70.0 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 CALA MWD030 INCH 4 1 68 4 2 FCNT MWD030 CNTS 4 1 68 8 3 NCNT MWD030 CNTS 4 1 68 12 4 RHOB MwD030 G/CM 4 1 68 16 5 DRHO MwD030 G/CM 4 1 68 20 6 RPD MWD030 OHMM 4 1 68 24 7 RPM MWD030 OHMM 4 1 68 28 8 RPS MwD030 OHMM 4 1 68 32 9 RPX MWD030 OHMM 4 1 68 36 10 FET MwD030 HOUR 4 1 68 40 11 GR MWD030 API 4 1 68 44 12 PEF MWD030 BARN 4 1 68 48 13 ROP MWD030 FT/H 4 1 68 52 14 NPHI MwD030 PU-S 4 1 68 56 15 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 3525 8750 6137.5 10451 3525 8750 GALA MWD030 INCH 10.18 14.32 12.2903 10421 3540 8750 FCNT MWD030 CNTS 548.07 3672.06 1053.54 10421 3540 8750 NCNT MWD030 CNTS 127381 225203 172510 10421 3540 8750 RHOB MWD030 G/CM 0.071 2.889 2.12846 10421 3540 8750 DRHO MWD030 G/CM -4.72 0.289 0.0518945 10421 3540 8750 RPD MWD030 OHMM 5.49 2000 17.4692 10421 3540 8750 RPM MWD030 OHMM 4.75 1258.18 16.2856 10421 3540 8750 RPS MWD030 OHMM 4.6 178.44 14.8097 10421 3540 8750 RPx MWD030 OHMM 3.3 77.6 11.7204 10421 3540 8750 FET MwD030 HOUR 0.1 100.94 0.844562 10421 3540 8750 GR MWD030 API 19.59 121.33 68.875 10451 3525 8750 PEF MWD030 BARN -0.32 12.99 2.1104 10421 3540 8750 ROP MWD030 FT/H 4.97 1068.15 227.232 10378 3561.5 8750 NPHI MwD030 PU-S 9.25 107.7 40.8326 10421 3540 8750 Page 6 ~ • 17160L1003252007SSN.txt First Reading For Entire File..........3525 Last Reading For Entire File...........8750 File Trailer Service name... .......STSL26.002 Service Sub Level Name... version Number. ........1.0.0 Date of Generation.......07/05/25 Maximum Physical Record..65535 File Type ................L0 Next File Name...........STSLiB.003 Physical EOF File Header service name... .......sTSLI6.003 Service sub Level Name... version Number. ........1.0.0 Date of Generation.......07/05/25 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......STSLI6.002 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 ROP 8750.5 8783.0 LOG HEADER DATA DATE LOGGED: 19-MAR-07 SOFTWARE SURFACE SOFTWARE VERSION: Incite DOWNHOLE SOFTWARE VERSION: 72.13 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 8783.0 TOP LOG INTERVAL (FT): 8750.0 BOTTOM LOG INTERVAL (FT): 8783.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: .O MAXIMUM ANGLE: .O TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 8.500 DRILLER'S CASING DEPTH (FT): 8750.0 BOREHOLE CONDITIONS Page 7 • 1~160L1003252007SSN.txt MUD TYPE: Mineral Oil Base MUD DENSITY (LB/G): 9.00 MUD VISCOSITY (S): 68.0 MUD PH: .O MUD CHLORIDES (PPM): 26000 FLUID LOSS (C3): .0 RESISTIVITY (OHMM) AT TEMPERATURE (DEG F) MUD AT MEASURED TEMPERATURE (MT): .000 .O MUD AT MAX CIRCULATING TERMPERATURE: .000 95.0 MUD FILTRATE AT MT: .000 .O MUD CAKE AT MT: .000 .O 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 ROP MWD040 FT/H 4 1 68 4 2 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 8750.5 8783 8766.75 66 8750.5 8783 ROP MWD040 FT/H 27.57 440.84 173.231 66 8750.5 8783 First Reading For Entire File..........8750.5 Last Reading For Entire File...........8783 File Trailer service name... .......STSLIB.003 service sub Level Name... version Number. ........1.0.0 Date of Generation.......07/05/25 Maximum Physical Record..65535 File Ty e ................Lo Next File Name...........STSLIB.004 Physical EOF Page 8 i • 1~160L1o0325200755N.txt File Header Service name... .......STSLIB.004 service sub Level Name... version Number. ........1.0.0 Date of Generation.......07/05/25 Maximum Physical Record..65535 File Type. ............Lo Previous File Name.......STSLI6.003 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 8750.5 9200.0 RPD 8750.5 9200.0 RPM 8750.5 9200.0 RPX 8750.5 9200.0 FET 8750.5 9200.0 GR 8750.5 9200.0 ROP 8783.5 9200.0 LOG HEADER DATA DATE LOGGED: 21-MAR-07 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 72.13 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 9200.0 TOP LOG INTERVAL (FT): 8783.0 BOTTOM LOG INTERVAL (FT): 9200.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 81.2 MAXIMUM ANGLE: 92.6 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 135134 EWR4 Electromag Resis. 4 167218 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 6.750 DRILLER'S CASING DEPTH (FT): 8750.0 BOREHOLE CONDITIONS MUD TYPE: Mineral Oil Base MUD DENSITY (LB/G): 8.40 MUD VISCOSITY (S): 64.0 MUD PH: .O MUD CHLORIDES (PPM): 32000 FLUID LOSS (C3): .O RESISTIVITY (OHMM) AT TEMPERATURE (DEG F) MUD AT MEASURED TEMPERATURE (MT): .000 .O MUD AT MAX CIRCULATING TERMPERATURE: .000 105.8 Page 9 i 17160L10032520075SN.txt MUD FILTRATE AT MT: .000 .O MUD CAKE AT MT: .000 .O 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 MWD050 OHMM 4 1 68 4 2 RPM MWD050 OHMM 4 1 68 8 3 RPS MWD050 OHMM 4 1 68 12 4 RPX MwD050 OHMM 4 1 68 16 5 FET MwD050 HOUR 4 1 68 20 6 GR MwD050 API 4 1 68 24 7 ROP MWD050 FT/H 4 1 68 28 8 First Last Name Service unit Min Max Mean Nsam Reading Reading DEPT FT 8750.5 9200 8975.25 900 8750.5 9200 RPD MwD050 OHMM 1.7 180.35 63.9154 900 8750.5 9200 RPM MwD050 OHMM 8.44 167.18 64.1538 900 8750.5 9200 RPS MWD050 OHMM 10.34 2000 68.8256 900 8750.5 9200 RPX MWD050 OHMM 8.15 2000 76.8475 900 8750.5 9200 FET MWD050 HOUR 0.22 2.07 1.04304 900 8750.5 9200 GR MWD050 API 35.31 93.02 60.9628 900 8750.5 9200 ROP MWD050 FT/H 3.41 473.38 227.062 834 8783.5 9200 First Reading For Entire File..........8750.5 Last Reading For Entire File...........9200 File Trailer Service name... .......STSLIB.004 Service Sub Level Name... version Number. ........1.0.0 Date of Generation.......07/05/25 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.005 Page 10 • 17160L1o03252007SSN.txt Physical EOF File Header Service name... .......sTSLI6.005 Service Sub Level Name... version Number. ........1.0.0 Date of Generation.......07/05/25 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 GR 9141.5 10942.0 ROP 9200.5 11000.0 FET 9200.5 10948.5 RPX 9200.5 10948.5 RPS 9200.5 10948.5 RPM 9200.5 10948.5 RPD 9200.5 10948.5 LOG HEADER DATA DATE LOGGED: 23-MAR-07 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 72.13 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 11000.0 TOP LOG INTERVAL (FT): 9200.0 BOTTOM LOG INTERVAL (FT): 11000.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 84.7 MAXIMUM ANGLE: 95.3 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 135134 EWR4 Electromag Resis. 4 167218 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 6.750 DRILLER'S CASING DEPTH (FT): 8750.0 BOREHOLE CONDITIONS MUD TYPE: Mineral Oil Base MUD DENSITY (LB/G): 8.40 MUD VISCOSITY (S): 78.0 MUD PH: .O MUD CHLORIDES (PPM): 25000 FLUID LOSS (C3): .O Page 11 a • 17160L1o03252007ssN.txt RESISTIVITY (OHMM) AT TEMPERATURE (DEG F) MUD AT MEASURED TEMPERATURE (MT): .000 .O MUD AT MAX CIRCULATING TERMPERATURE: .000 105.8 MUD FILTRATE AT MT: .000 .O MUD CAKE AT MT: .000 .O 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 Loging Direction .................Down optical log depth units...........Feet Data Reference Point ..............undefined Frame Spacing....... ............60 .lIN Max frames per record .............undefined Absent value ......................-999 Depth Units. .. .. ..... Datum Specification Block sub-type...0 Name service order units size Nsam Rep code offset channel DEPT FT 4 1 68 0 1 RPD MWD060 OHMM 4 1 68 4 2 RPM MWD060 OHMM 4 1 68 8 3 RPS MWD060 OHMM 4 1 68 12 4 RPx MWD060 oHMM 4 1 68 16 5 FET MWD060 HOUR 4 1 68 20 6 GR MWD060 API 4 1 68 24 7 ROP MwD060 FT/H 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 9141.5 11000 10070.8 3718 9141.5 11000 RPD MwD060 OHMM 6.8 2000 56.6718 3497 9200.5 10948.5 RPM MwD060 OHMM 6.48 2000 56.814 3497 9200.5 10948.5 RPS MWD060 OHMM 6.14 531.02 51.4231 3497 9200.5 10948.5 RPx MWD060 OHMM 5.94 2000 65.5264 3497 9200.5 10948.5 FET MWD060 HOUR 0.22 5.97 1.44449 3497 9200.5 .10948.5 GR MWD060 API 27.41 120.82 65.1342 3602 9141.5 10942 ROP MWD060 FT/H 5.6 1944.23 177.692 3600 9200.5 11000 First Reading For Entire File..........9141.5 Last Reading For Entire File...........11000 File Trailer Service name... .......STSLIB.005 service Sub Level Name... version Number. ........1.0,0 Date of Generation.......07/05/25 Maximum Physical Record..65535 Page 12 • 1.7160L1003252007SSN.txt File Type ................LO Next File Name...........STSLIB.006 Physical EOF File Header Service name... .......STSLIB.006 service sub Level Name... version Number. ........1.0.0 Date of Generation.......07/05/25 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......sT5LI6.005 Comment Record FILE HEADER FILE NUMBER: 6 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 7 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 10942.5 13006.0 RPS 10949.0 13013.5 FET 10949.0 13013.5 RPX 10949.0 13013.5 RPM 10949.0 13013.5 RPD 10949.0 13013.5 ROP 11000.5 13064.0 LOG HEADER DATA DATE LOGGED: 25-MAR-07 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 72.13 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 13064.0 TOP LOG INTERVAL (FT): 11000.0 BOTTOM LOG INTERVAL (FT): 13064.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 86.8 MAXIMUM ANGLE: 94.4 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 135134 EWR4 Electromag Resis. 4 167218 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 6.750 DRILLER'S CASING DEPTH (FT): 8750.0 BOREHOLE CONDITIONS MUD TYPE: Mineral Oil Base MUD DENSITY (LB/G): 8.40 MUD VISCOSITY (S): 68.0 Page 13 17160L1o03252007SSN.txt MUD PH: .O MUD CHLORIDES (PPM): 25000 FLUID LOSS (C3): 11.2 RESISTIVITY (OHMM) AT TEMP ERATURE (DEG F ) MUD AT MEASURED TEMPERATURE (MT): .000 .O MUD AT MAX CIRCULATING TERMPERATURE: .000 .O MUD FILTRATE AT MT: .000 .O MUD CAKE AT MT: .000 .O 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 ......... .....undefine d Frame Spacing....... ....... .....60 .lIN Max frames per record ........ .....undefine d Absent value ................. .....-999 Depth Units. .. .. ..... Datum Specification Block sub -type...0 Name service order units size N sam Rep Code offset Channel DEPT FT 4 1 68 0 1 RPD MWD070 OHMM 4 1 68 4 2 RPM MWD070 OHMM 4 1 68 8 3 RPS MWD070 OHMM 4 1 68 12 4 RPX MwD070 oHMM 4 1 68 16 5 FET MWD070 HOUR 4 1 68 20 6 GR MWD070 API 4 1 68 24 7 ROP MwD070 FT/H 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 10942.5 13064 12003.3 4244 10942.5 13064 RPD MWD070 OHMM 15.09 2000 155.436 4130 10949 13013.5 RPM MWD070 OHMM 12.7 2000 159.704 4130 10949 13013.5 RPS MWD070 OHMM 11.62 2000 124.162 4130 10949 13013.5 RPX MWD070 OHMM 10.89 2000 125.466 4130 10949 13013.5 FET MwD070 HOUR 0.2 52.45 1.98156 4130 10949 13013.5 GR MwD070 API 26.74 102.75 65.7785 4128 10942.5 13006 ROP MWD070 FT/H 3.07 503.35 175.973 4128 11000.5 13064 First Reading For Entire File..........10942.5 Last Reading For Entire File...........13064 File Trailer Service name... .......STSLIB.006 Service Sub Level Name... Page 14 • • 1~160L1o03252007SSN.txt version Number. ........1.0.0 date of Generation.......07/05/25 Maximum Physical Record..65535 File Type ................L0 Next File Name...........STSLIB.007 Physical EOF Tape Trailer Service name .............LISTPE gate . ...................07/05/25 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 . ...................07/05/25 Ori9in ...................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 Page 15 1j-16011pbl.tapx Sperry-Sun Drilling Services LIS Scan Utility $Revision: 3 $ LisLib $Revision: 4 $ Fri May 25 16:40:12 2007 Reel Header Service name .............LISTPE Date . ...................07/05/25 Ori 9in ...................STs Reel Name. .... ........UNKNOWN continuation Number......01 Previous Reel Name.......UNKNOWN Comments .................STS LIS Writing Library. Tape Header Service name .............LISTPE Date . ...................07/05/25 Origin ...................STS Tape Name. .... ........UNKNOWN Continuation Number......01 Previous Tape Name.......UNKNOWN Comments .................STS LIS Writing Library. Physical EOF Comment Record TAPE HEADER Kuparuk River unit west Sak MWD/MAD LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA MWD RUN 3 JoB NUMBER: w-0004877337 LOGGING ENGINEER: T. MCGUIRE OPERATOR WITNESS: M. THORNTON SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL O) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD • scientific Technical services scientific Technical services 17-160 L1 PB1 500292334470 ConocoPhillips Alaska Inc. Sperry Drilling Services 25-MAY-07 MWD RUN 4 MWD RUN 5 w-0004877337 w-0004877337 R. WILSON R. WILSON M. THORNTON F. HERBERT 35 11N l0E 2016 2541 122.29 81.00 Page 1 UZCi 8t~~'C~tCo +~ t~I~~- r~ 1j-16011pb1.tapx OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 1sT STRING 12.250 13.375 3551.0 2ND STRING 6.750 9.625 8750.0 3RD STRING PRODUCTION STRING REMARKS: 1. ALL DEPTHS ARE BIT DEPTHS UNLESS OTHERWISE NOTED. THESE DEPTHS ARE MEASURED DEPTH (MD). 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTH (TVD). 3. THIS WELLBORE WAS DRILLED FROM A WHIPSTOCK, THE TOP OF WHICH WAS AT 8750' MD/3286'TVD, WITHIN THE RUN 3 INTERVAL OF THE 1J-160 WELLBORE. THE WHIP- STOCK WAS POSITIONED, THE WINDOW WAS MILLED, AND A BIT OF RAT HOLE WAS DRILLED DURING MWD RUN 4. ONLY SROP DATA ARE PRESENTED FOR THIS RUN. 4. MWD RUNS 1 & 2 WERE DIRECTIONAL ONLY - NO DATA ARE PRESENTED. 5. MWD RUNS 3,5 COMPRISED DIRECTIONAL, DUAL GAMMA RAY (DGR) UTILIZING GEIGER- MUELLER TUBE DETECTORS, ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4), AND PRESSURE-WHILE-DRILLING (PWD). MWD RUN 5 ALSO INCLUDED AT-BIT INCLINATION (ABI). POROSITY LOG DATA ACQUIRED OVER THE MWD RUN 3 INTERVAL ARE PRESENTED WITH THE 1J-160 LOGS. 6. DEPTH SHIFTING OF MWD DATA WAS WAIVED PER E-MAIL, DATED 12/16/04, FROM M. WERNER (CPAI) TO R. KALISH (SDS). MWD DATA ARE CONSIDERED PDC. 7. MWD RUNS 1-5 REPRESENT WELL 1J-160 L1PB1 WITH API#: 50-029-23344-70. THIS WELL REACHED A TOTAL DEPTH (TD) OF 9439'MD/3282'TVD. SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRC = SMOOTHED GAMMA RAY COMBINED. SEXP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (EXTRA SHALLOW SPACING). SESP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (SHALLOW SPACING). SEMP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (MEDIUM SPACING). SEDP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (DEEP SPACING). SFXE = SMOOTHED FORMATION EXPOSURE TIME (DEEP SPACING). SLIDE = NON-ROTATED INTERVALS REFLECTING BIT DEPTHS. File Header Service name... .......STSLIB.001 service sub Level Name... version Number. ........1.0.0 Date of Generation.......07/05/25 Page 2 v 1j- 16011pb1.tapx Maximum Physical Record..65535 File Type. .... ........LO Previous File Nam e.......STSLIB.000 Comment Record FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE START DEPTH STOP DEPTH GR 3525.0 9381.0 NPHI 3540.0 8750.0 FONT 3540.0 8750.0 NCNT 3540.0 8750.0 PEF 3540.0 8750.0 RPS 3540.0 9388.0 DRHO 3540.0 8750.0 FET 3540.0 9388.0 RPD 3540.0 9388.0 RPx 3540.0 9388.0 RPM 3540.0 9388.0 GALA 3540.0 8750.0 RHOS 3540.0 8750.0 RoP 3561.5 9439.0 BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH MERGED DATA SOURCE PBU TOOL CODE MWD MWD MWD BIT RUN NO MERGE TOP 3 3525.0 4 8750.5 5 8783.0 REMARKS: MERGED MAIN PASS. MERGE BASE 8750.0 8783.0 9439.0 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 CALA MWD INCH 4 1 68 4 2 FCNT MWD CNTS 4 1 68 8 3 NCNT MWD CNTS 4 1 68 12 4 RHOB MWD G/CM 4 1 68 16 5 Page 3 1j-16011pb1.tapx DRHO MWD G/CM 4 1 68 20 6 RPD MWD OHMM 4 1 68 24 7 RPM MWD OHMM 4 1 68 28 8 RPS MWD OHMM 4 1 68 32 9 RPX MWD OHMM 4 1 68 36 10 FET MWD HOUR 4 1 68 40 11 GR MWD API 4 1 68 44 12 PEF MWD BARN 4 1 68 48 13 ROP MWD FT/H 4 1 68 52 14 NPHI MWD PU-S 4 1 68 56 15 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 3525 9439 6482 11829 3525 9439 CALA MWD INCH 10.18 14.32 12.2903 10421 3540 8750 FONT MWD CNTS 548.07 3672.06 1053.54 10421 3540 8750 NCNT MWD CNTS 127381 225203 172510 10421 3540 8750 RHOB MWD G/CM 0.071 2.889 2.12846 10421 3540 8750 DRHO MWD G/CM -4.72 0.289 0.0518945 10421 3540 8750 RPD MWD OHMM 1.7 2000 21.3938 11697 3540 9388 RPM MWD OHMM 4.75 1258.18 20.2925 11697 3540 9388 RPS MWD OHMM 4.6 2000 19.3009 11697 3540 9388 RPX MWD OHMM 3.3 2000 17.189 11697 3540 9388 FET MWD HOUR 0.1 100.94 0.855813 11697 3540 9388 GR MWD API 19.59 121.33 68.3661 11713 3525 9381 PEF MWD BARN -0.32 12.99 2.1104 10421 3540 8750 ROP MWD FT/H 3.41 1068.15 224.95 11756 3561.5 9439 NPHI MwD PU-S 9.25 107.7 40.8326 10421 3540 8750 First Reading For Entire File..........3525 Last Reading For Entire File...........9439 File Trailer Service name... .......STSLIB.001 service sub Level Name... version Number. ........1.0.0 Date of Generation.......07/05/25 Maximum Physical Record..65535 File Type ................L0 Next File Name...........STSLIB.002 Physical EOF File Header Service name... .......STSLIB.002 Service Sub Level Name... version Number. ........1.0.0 Date of Generation.......07/05/25 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......STSLI6.001 Comment Record FILE HEADER FILE NUMBER: 2 RAW MWD Curves and log header data for each bit run in separate files. Page 4 1j- 16011pbl.tapx BIT RUN NUMBER: 3 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 3525.0 8750.0 PEF 3540.0 8750.0 FET 3540.0 8750.0 RPx 3540.0 8750.0 NPHI 3540.0 8750.0 RPS 3540.0 8750.0 RHOB 3540.0 8750.0 CALA 3540.0 8750.0 RPD 3540.0 8750.0 FCNT 3540.0 8750.0 DRHO 3540.0 8750.0 RPM 3540.0 8750.0 NCNT 3540.0 8750.0 ROP 3561.5 8750.0 LOG HEADER DATA DATE LOGGED: 13-MAR-07 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 72.13 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 8750.0 TOP LOG INTERVAL (FT): 3560.0 BOTTOM LOG INTERVAL (FT): 8750.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 76.3 MAXIMUM ANGLE: 87.3 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RA Y 76571 EWR4 ELECTROMAG. R ESIS. 4 78633 CTN COMP THERMAL NEUTRON 158416 ALD Azimuthal Lit ho-Dens 220637 ACAL Acoustic cali per 727406 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 12.250 DRILLER'S CASING DEPTH (FT): 3551.0 BOREHOLE CONDITIONS MUD TYPE: Other MUD DENSITY (LB/G): 9.10 MUD VISCOSITY (S): 60.0 MUD PH: 9.4 MUD CHLORIDES (PPM): 700 FLUID LOSS (C3): 5.6 RESISTIVITY (OHMM) AT TEMPERATU RE (DEGF) MUD AT MEASURED TEMPERATURE (MT): 2.300 70.0 MUD AT MAX CIRCULATING TERMP ERATURE: 1.430 116.6 MUD FILTRATE AT MT: 2.600 70.0 MUD CAKE AT MT: 3.000 70.0 NEUTRON TOOL MATRIX: Page 5 MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: 1j-16011pbl.tapx 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 CALA MWD030 INCH 4 1 68 4 2 FCNT MWD030 CNTS 4 1 68 8 3 NCNT MwD030 CNTS 4 1 68 12 4 RHOS MwD030 G/CM 4 1 68 16 5 DRHO MwD030 G/CM 4 1 68 20 6 RPD MwD030 OHMM 4 1 68 24 7 RPM MwD030 OHMM 4 1 68 28 8 RPS MwD030 OHMM 4 1 68 32 9 RPX MWD030 OHMM 4 1 68 36 10 FET MWD030 HOUR 4 1 68 40 11 GR MwD030 API 4 1 68 44 12 PEF MwD030 BARN 4 1 68 48 13 RoP MwD030 FT/H 4 1 68 52 14 NPHI MwD030 PU-5 4 1 68 56 15 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 3525 8750 6137.5 10451 3525 8750 GALA MWD030 INCH 10.18 14.32 12.2903 10421 3540 8750 FCNT MWD030 CNTS 548.07 3672.06 1053.54 10421 3540 8750 NCNT MwD030 CNTS 127381 225203 172510 10421 3540 8750 RHOB MWD030 G/CM 0.071 2.889 2.12846 10421 3540 8750 DRHO MWD030 G/CM -4.72 0.289 0.0518945 10421 3540 8750 RPD MWD030 OHMM 5.49 2000 17.4692 10421 3540 8750 RPM MWD030 OHMM 4.75 1258.18 16.2856 10421 3540 8750 RPS MWD030 OHMM 4.6 178.44 14.8097 10421 3540 8750 RPX MWD030 OHMM 3.3 77.6 11.7204 10421 3540 8750 FET MwD030 HOUR 0.1 100.94 0.844562 10421 3540 8750 GR MWD030 API 19.59 121.33 68.875 10451 3525 8750 PEF MwD030 BARN -0.32 12.99 2.1104 10421 3540 8750 ROP MWD030 FT/H 4.97 1068.15 227.232 10378 3561.5 8750 NPHI MwD030 PU-S 9.25 107.7 40.8326 10421 3540 8750 First Reading For Entire File..........3525 Last Reading For Entire File...........8750 Page 6 1j-16011pbl.tapx File Trailer Service name... .......STSLIB.002 service sub Level Name... version Number. ........1.0.0 Date of Generation.......07/05/25 Maximum Physical Record..65535 File TyPe ................LO Next File Name...........STSLIB.003 Physical EOF File Header Service name... .......STSLIB.003 service sub Level Name... version Number. ........1.0.0 Date of Generation.......07/05/25 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......ST5LI6.002 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 RoP 8750.5 8783.0 LOG HEADER DATA DATE LOGGED: 19-MAR-07 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 72.13 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 8783.0 TOP LOG INTERVAL (FT): 8750.0 BOTTOM LOG INTERVAL (FT): 8783.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: .O MAXIMUM ANGLE: .O TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 8.500 DRILLER'S CASING DEPTH (FT): 8750.0 BOREHOLE CONDITIONS MUD TYPE: Mineral Oil Base MUD DENSITY (LB/G): 9.00 MUD VISCOSITY (S): 68.0 MUD PH: .O MUD CHLORIDES (PPM): 26000 Page 7 1j-16011pbl.tapx FLUID LOSS (C3): .O RESIST IVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): .000 .O MUD AT MAX CIRCULATING TERMPERATURE: .000 95.0 MUD FILTRATE AT MT: .000 .O MUD CAKE AT MT: .000 .O 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 ROP MWD040 FT/H 4 1 68 4 2 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 8750.5 8783 8766.75 66 8750.5 8783 ROP MWD040 FT/H 27.57 440.84 173.231 66 8750.5 8783 First Reading For Entire File..........8750.5 Last Reading For Entire File...........8783 File Trailer Service name... .......STSL26.003 Service Sub Level Name... version Number. ........1.0.0 Date of Generation.......07/05/25 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.004 Physical EoF File Header Service name... .......STSLIB.004 Service Sub Level Name... version Number...........1.0.0 Page 8 1j-16011pbl.tapx Date of Generation.......07/05/25 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......5T5LI6.003 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 RP5 8750.5 9388.0 GR 8750.5 9381.0 FET 8750.5 9388.0 RPx 8750.5 9388.0 RPD 8750.5 9388.0 RPM 8750.5 9388.0 RoP 8783.5 9439.0 LOG HEADER DATA DATE LOGGED: 21-MAR-07 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 72.13 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 9439.0 TOP LOG INTERVAL (FT): 8783.0 BOTTOM LOG INTERVAL (FT): 9439.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 81.2 MAXIMUM ANGLE: 92.6 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 135134 EWR4 Electromag Resis. 4 167218 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 6.750 DRILLER'S CASING DEPTH (FT): 8750.0 BOREHOLE CONDITIONS MUD TYPE: Mineral Oil Base MUD DENSITY (LB/G): 8.40 MUD VISCOSITY (S): 64.0 MUD PH: .O MUD CHLORIDES (PPM): 32000 FLUID LOSS (C3): .O RESISTIVITY (OHMM) AT TEMPERATURE (DEG F) MUD AT MEASURED TEMPERATURE (MT): .000 .O MUD AT MAX CIRCULATING TERMPERATURE: .000 105.8 MUD FILTRATE AT MT: .000 .0 MUD CAKE AT MT: .000 .0 NEUTRON TOOL MATRIX: Page 9 MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: 1j-16011pbl.tapx Data Format Specification Record Data Record Type... ..........0 Data Specification Block Type.....0 Logging Direction .................DOwn optical log depth units...........Feet Data Reference Point ..............undefined Frame Spacing ........ ............60 .lIN Max frames per record .............undefined Absent value ......................-999 Depth units. .. .. ..... Datum specification Block sub-type...0 Name service order units size Nsam Rep code offset channel DEPT FT 4 1 68 0 1 RPD MWD050 OHMM 4 1 68 4 2 RPM MWD050 OHMM 4 1 68 8 3 RPS MwD050 OHMM 4 1 68 12 4 RPX MWD050 OHMM 4 1 68 16 5 FET MwD050 HOUR 4 1 68 20 6 GR MWD050 API 4 1 68 24 7 ROP MwD050 FT/H 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 8750.5 9439 9094.75 1378 8750.5 9439 RPD MwD050 OHMM 1.7 180.35 53.4464 1276 8750.5 9388 RPM MWD050 OHMM 8.44 167.18 53.0168 1276 8750.5 9388 RPS MWD050 OHMM 10.34 2000 55.9797 1276 8750.5 9388 RPX MWD050 OHMM 8.15 2000 61.8513 1276 8750.5 9388 FET MwD050 HOUR 0.22 2.07 0.947704 1276 8750.5 9388 GR MWD050 API 35.31 94.46 64.1516 1262 8750.5 9381 ROP MWD050 FT/H 3.41 473.38 209.505 1312 8783.5 9439 First Reading For Entire File..........8750.5 Last Reading For Entire File...........9439 File Trailer Service name... .......STSLIB.004 service sub Level Name... version Number. ........1.0.0 Date of Generation.......07/05/25 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.005 Physical EOF Tape Trailer Page 10 1j-16011pbl.tapx Service name .............LISTPE gate . ...................07/05/25 Origin ...................STS Tape Name. .... ........UNKNOWN Continuation Number......01 Next Tape Name...........UNKNOWN Comments .................STS LIS writing Library Reel Trailer Service name .............LISTPE gate . ...................07/05/25 Ori9in ...................STS Reel Name. .... ........UNKNOWN Continuation Number......01 Next Reel Name...........UNKNOWN Comments .................STS LIS Writing Library. Physical EoF Physical EOF End Of LIS File Scientific Technical Services scientific Technical Services Page 11
