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Home My WebLink About206-045STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS FED �l i 1. Operations Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Pull Tubing ❑ Operations shutdoA ❑ Performed: Suspend ❑ Perforate ❑ Other Stimulate ❑ Alter Casing ❑ Change Approved Program ❑ Plug for Redrill ❑ 'erforate New Pool ❑ Repair Well ❑ Re-enter Susp Well ❑ Convert to WAG INJ ❑� 2. Operator 4. Well Class Before Work: 5. Permit to Drill Number: Name: ConocoPhllllps Alaska, Inc. Development ❑ Exploratory ❑ Stratigraphic ❑ Service ❑ 206-045 3. Address: P. O. Box 100360, Anchorage, Alaska 6. API Number: 99510 50-029-23305-60-00 7. Property Designation (Lease Number): 8. Well Name and Number: KRU 1 J -184L1 ADL 25662 25661 380058 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): N/A 10. Field/Pool(s): Kuparuk River Field / West Sak Oil Pool 11. Present Well Condition Summary: Total Depth measured 16,548 feet Plugs measured none feet true vertical 3,336 feet Junk measured none feet Effective Depth measured 16,508 feet Packer measured 8,730 feet true vertical 3,331 feet true vertical 3,334 feet Casing Length Size MD TVD Burst Collapse Structural N/A N/A N/A N/A Conductor 80' 20" 108' 108' Surface 3,949' 13.375" 3977' 2,239' Intermediate 9,247' 9.625" 9,275' 3,424' Liner 7,494' 5.5" 16,548' 3,336' Perforations: Horizontal slotted liner Measured depth: 9,068'-16,508' feet True vertical depth: 3,375'-3,331' feet Packers and SSSV (type, measured and true vertical depth) Baker ZXP LinerTop packer 8,730' MD 3,334' TVD SSSV TYPE: N/A 12. Stimulation or cement squeeze summary: Intervals treated (measured): NA Treatment descriptions including volumes used and final pressure: NA 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas-Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation:0 0 1200 11300 1590 Subsequent to operation:10 1250 10 11000 11560 14. Attachments (required per 20 AAc 25.070, 25.071, 8 25.283) 15, Well Class after work: Daily Report of Well Operations [A Exploratory ❑ Development ❑ Service E] Strafigraphic ❑ Copies of Logs and Surveys Run ❑ 16. Well Status after work: Oil ❑ Gas ❑ WDSPL ❑ Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ ❑ WAG El GINJ ❑ SUSP ❑ SPLUG ❑ 17. 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: 318-551 Contact Name: Sydney Autry Authorized Name: Sydney Autry Contact Email: sydney.autry@cop.Com Authorized Title: Sr. Petroleum Engineer 2/2,1/20l Contact Phone: 907-265-6813 Authorized Signature: Date: IST[- 311111 ' ABDMSle FLd 2 5 2019 Form 10-404 Revised 4/2017 Submit Original Only 1J -184L1 CONVERT TO WAG Date Event 01/24/2019 PUMP 1,5 BBSL METH DWN WTR INJ LINE 1.5 BBLS METH DWN TBG & 50 BBLS DSL DWN TBG FOR FREEZE PROTECT. "JOB COMPLETE" 01/29/2019 Begin MI injection /t", KUP [NJ 1J-184 ConoeoPhillips Well Attributes I Max Angle &d TD Alaska Inc..VYaleore APvinVl Feta name Wenbom 5eaus 500292330500 WESTGAK INJ nal°I Molttrcel An Bim tercel 1],8]00 Comment N9S (ppm) Date Am"ohm en Ena Doh KBGrtl IX) NSNN Del¢ SSSV: NIPPLE Last V.U: 1013112015 31.51 5/252006 MilipM ltle,.B-u�le4.nn4rz0n leas so Pte w ccMlreYc ec A .Ntlnn Ceplh IRNBI Ena OM Tag: MnoWbn lest Moa By "m Deb Rev Reason: PULL DH CHOKE WI308'N000 pproven 11113201] -"Last amyl Strings Geeing oD(n ml19 role lnrce) sin Deem 11e10) Bel GepM(108 wvLen lL. Gratle Wop elded In The CONDUCTOR Insulatetl 20 19.124 30.0 1080 108.0 9400 CONDUCTOR I an di Top .I.O comiumn ODI IO llnl TOP1flKe1 set Depth (MB) SH C¢ptlr ITVOL.. WVLen I1... Gr Ed Eff, a! SURFACE 133'0 12615 30.2 3.877.0 2.239.0 8800 L-00 BTC Cain9 DncriPtlon ODlinl ID lint Top(flKB1 se[DepM InKB) aet D¢PM ITYLL.. WtlLen 11... G,We TOP iM1rm] INTERMEDIATE 95/8 8835 27).4 9.2]50 3,424.2 40.00 Le BTC Cesin9 DeecriPlion AD (in) IPam Top NKB) Set DepM IXKBI sol Cepm ITarV_WVLen 11...Grak To, Itrom CONDUCTOR inlet, do DLINER HH 51/2 4950 6,02].0 9.0939 3396.3 15.50 lamp Liner Details inal to NtvFLB aea Top 18 TCPIrv3I0e5 Top inclnem Des cam lin) 8,82]0 3.353505 80.23 HANGER Hook Manger (outside casing) 7740 8 8,848.0 3,334.1 80.25 HANGER Hook Hanger dueld¢ casing) 5020 GAsuri:2paZot alli 3,355.2 00.24 XO BUSHING Crossover Burning 5000 023 PACKER 4.910 89 3,364.3 ]9.99 EDP BAKER PAYZONE EXTERNALCASING 8.0195 3,383.0 00.15 XORedacing CROSSOVER 5.5x4.5' 3.960 90644 3,3914 00.30 BEJTJT 3.940 SDREACE', 303/,911.0 WcinpDescriptionGo(in) to lin) Top IXRB) $el oeplM1 IRKB) SN Depin ITVDI.. WVLen 11... Geaae Tep imeztl BSAND SLOTTED 51/2 4.950 89329 1].105.0 3.4056 15.50 L-80 HyUIT 521 sLEE9E;ala2o LINER Liner Details Nom maIID iop luxe) iopDorn 8Top 179nem Des eom li7 8932.9 3.363688 >9.0,8 7 PACKER END 2XP LT Packer 7,500 SEALA5rattle t 8951.4 3.3720 7906 NIPPLE RS Rackoff Seal Nipple 6.220 8954.3 3,3725 7985 HANGER FlexLock Liner Hanger 6.230 8,963.3 3,374.1 79.90 SBE 190-47 Casing Seal Bore 4750 17030.1 3,389.7 79.13 Swell Paek¢r Swell Pack¢rw VAM connections 3900 Own, Deecnplbn OD(in, I011nl Toplfll(el aN DapN 1aXB) Set reaPM IN01... WULen P -Gree ToThrutl D LINER LEM 4112 3958 8.]30.2 0,9736 ?3]5.9 1260 L-60 IOr Liner Details Nominal lD Top IRKB) Top 1rv((didel ToPlrcll°) Ihm D6 Com hir) 0,7302 3.333.9 79.71 PACKER SI -I LINER TOP PACKER 4.690 8,751.3 3,33].] 80.06 XOBUSHING CROSSOVER BUSHING 4.890 8,7521 3,337.8 80.08 SBR 190-47 CASING SEAL BORE RECEPTACLE 4.750 PACKER. Land 8,]]24 3,3419 80.20 XOBUSHING CROSSOVER BUSHING 3.930 8614.3 3,340.6 80.23 HANGER LEM ABOVE HOOK HANGER 39M 0.022.1 3,349.7 80.23 HANGER LEM INSIDE HOOK HANGER 3600 0,8821 13599 80.11 NIPPLE CAMCO Be NIPPLE 3.562 6,9704 3,3]53 7993 SEAL ASSY BAKER SEAL ASSEMBLY 3.900 am ASBY: race0 Tubblg Strings .a973a D LINER LEM, 9.730 1 � rubtnpye1PL1lon 5"my M'...ID(tn) Top laKa) Se[CepM 11t.. Set DepM 1TVD I�� WI(MM1 Gratle TopGonnMion 4-V2COMPLETION 41/2 3.958 o0 8]66.5 3.340.6 1250 L-00 IBW 2G15 RWO Com 18tion Del Nominal ID DLINER HX: B.B'Y r. %dB3B Tophi Top(TVDIXIKB) Topincl(°) iYm Com lin) 22.7 227 0.06 HANGER Viddo Gray 1358 x 10314 False TBG hanger bawl awl 16 4.500 316 x6-12 TBG hangerw/4.909" MCAtop threads and 4 INTERMEDNTE:27.41i -1/21BTM bottom thr8aas. r 4784 478.3 3.30 NIPPLE =..411ZDB-e Nipplewith3876'No-G.Pro51e 1415141064 3.705 (PULLED 1118201] SO' CHOKE W/ Sal NOGG (27" 8.7020 33288 7925 SLEEVE Baker 4-112' CMU Sliding Sleeve, W 3.813"X Piddle- 3813 Ran In Closed Position 8]50.1 333]5 6904 SEAL ASSY Baker 190 -4]20 -it Seal assembly with 4-11 speceout 3.840 Other In Hole (Wireline retrievable plugs, valves, Planes, fish, etc:) TnP(rvol Top Intra B) TOP 1') mm Dow Co. Run Dah 10 (in) 8,9070 3.3642 ]999 PACKER GSAND BAKER PAYZONE CASING PACKER W=2006 4910 (PUSHED DOWNHOLE FROM ORIGINAL LEM) 13,9]30 3.375.8 ]9.94 SEAL A53Y D SAND BAKER SEAL ASSEMBLY (FROM 5/23/2006 ORIGINAL LEM) 3.900 Perforations & Slots Bonn r L top(TVDI azquad, Den I:eI) SLOTS 9189.6170X1.0- fr To, II289 019(X1(51 (XKB) (fl,3 Zona Dale t) TYPo Com 9,209.0 17,020.0 3.426.2 3,38].8 WS B, WS C. 51112006 32.0 SLOTS Alternatingsolitl/5letl ot'. WB B, 1J-10 Else -6baILS sloftea pIbils 0.125°x25"x32ap d Circumferential adjacent tons3 Centers staggered to ft. non -slotted edeg.nds ands 3 Mandrel Inserts at r � o N TOPIXKBI Trotary.)vNYe I,Ke) M.MoaN OD (in) Baa TYW Let port Type size �Euairun Ilnl (P8O Run Cale Com 1 2.1470 lice Calrwo KBMG 1 GAS LIET DMY BK 0.000 00 11192015 BaskostaTO .U.Sen: 8932.9-1],IPl KUP INJ 1J-184 k-onocornnops A!aska, IOD. MJIpN IWefa6-IJ.164, 11111.711853 PM u RAMOER 227 NOWS: Generaafety End Dae Anm .ro 51242006 NOTE: CANNOT ENTER Ll LATERAL 5/24/2006 NOTE: MULTI -LATER WELL'. 1J-184 (B SAND). 1J -184L1 (D -SAND) 1112009 NOTE: VIEWSOHEMATIC w/Alaska Schemalic9.OREV CONDI] CTOR Iru W bd', 3J.0. 108.0 NIPPLE4704 GASLIFT:3.1470 011RFg E', 30.2-38]].0 SLEEVE,87020 SEKABBY:B>`A_i PACkEA;B.W]0 SEAL ASSYSR"0 D LINES LEM. 8.)90.1.09]].8 D LINER MN; 0aD.0A.RV.B INTERMEDWE: 37 483700 3L� BLOTS, 9.OB90.1"M,O- Y B BAND SLOTTED LINER; 8332.11.1 O5.OL� KUP INJ U-1840 ConomPflllip5 Well Attributes Max AngNa MD TD A dS'kd, 711 C. Wellbore MllUWI FiNtl Nanrc WNIOorestevs nd l'j MD IXNBI A[iDM IXNRI 500282330560 WESTSAK INJ 94.15 1561468 RBGMaq Rip RHexe DAe 31.51 W252O06 jCcwrkot H25 (ppm) ONe SS -NIPPLE Mndtlion EnJ Date 1_a= ID/31!2015 MMIge LBI¢lah-1.1- IS4u. 110S2015tx na'M Iwll Annotation Depih IXNBI EnE Dab Mnda1M LestMMBy EnEDaM Last Tag: Rev Reason: lNORKOVBR, GLV CIO lehalll 11/18/2015 :]- HPI4GER, 227- asmg 51drings Casing Caeia90IgL oO tial IO gd Top IXKBI Sel Depth IXNBI SN Depth ITV01... WULen 11.. Gratle Top TM1reatl Tlion OSa0tl SLOTTED 5112 4.950 9.053.8 16,548.0 3,3365 1550 1_60 BTCM .91 IS LINER Liner DoUNs s ID rota lXRel roplrv0)gll(BI Top Ind l°I Xem Des Lon IMI cONOucroR lrworea, Ha.0 Pao 8,053.8 3,3".0 0]02 SLEEVE HR LWER SETTING SLEEVE 6.280 9,062.1 33]44 0]25 XO RU6HING CROSSOVER RUSHING 6890 NIPPLE:4784 Perforations &Slots sone .UI ia 91m done Ish0bll Top IXKBI W.IXKBI (rm.) (XK.) IDne DSM p Type Cpm 9,060 .0 9,3180 3,3]4] 3,3 3,3,3]2.8 VAS D,11 5!202006 320SLOTS 61otiaverage 1841_1 stalleded lengths 5115. 0.125'X2.5'x32 ape® SURFACE: 303397 0 d CIICYmfefenlld ad) .sane rows, 3" SLEEVE'. e.ic3D Centers staggered 18 deg., 3 X. non -slotted ends 9,3560 9,713.0 3,3710 3.360.4 MD, 1J- 5!202006 32.0 SLOTS Altemaling sollWeefted 104L1 pipe - average slotted Sept. ASSY'. S)w.1 Isnglhe 2 lie. 0.126"x 2.5"x 32 spf ® 4 CircumrerelNial adjacent .a. 3" Centers D LINER LEM: area 14 soes Staggered 16 deg., 3 R IxTERMEDMTE; 27.4 g 2750 n-sloXed ends; alternating with 1 dank joint 9,940.0 10,4230 3.357.9 3,3645 WO D, 1J- 51201 320 SLOTS Alternating S01WISIofted 1841_1 pipe - avenge slatted 9hsslsrela5"x SLOTS. 9.0Ee69,319D-1 EI 26 2 v® Clrcumkrenllal adjacent rows, 3" Centers 1 staggered 18 deg., 3 X. nan-da8ed ends; altemaling with f blank B 0. ESSSa9p1x0- join) 10,651.0 11.133.0 3,363.8 3,356.8 VOS D, 1J- 5/202008 320 SLOTS Allemaling solitllsloded 184L1 pipe- average Speed lengths 2lie. 0.125" x 2.5"x 32 spf@4 Cimumfnertial adjacent ows, 3. Cereals SLOT59.94OO10.423.0 staggered lB deg., sit. non-slofted ends; altematingwfth 1 blank joint 11,359.0 11,8430 3,345.1 3,334.6 MD, 11 W2012006 32.0 SLOTS Alternating soliWSlDXed 1841.1 pipe -average slotted lengths 2jte.0.125"x 2.5"x 32 stat a 4 Cirtumferenlial adjacent 13" Centers SLOTS', teed P11.1 as O__ staggered 18 deg. 3 ft. On -slotted ends. a1tearp ingwXh 1 blank joint 12,070.0 12,5560 3,336.8 3.3380 NSD. 11 5/20/2006 320 SLOTS Alternating sotlWsiofted 1841_1 pipe -average Speed lengths 2 jb. 0.125"x 2.5'x32spf® 4 Cimumferenlial adjacent SLOTS',11.3`9.0.118430 NW s, 3" Centers staggered 18 deg., 3 a nonHiefted ends; alternating with 1 blank POST 12,86]0 13.5150 3.3460 3,3448 MD. 1J- 520!2006 32O SLOTS Alternating solid/sloded 1841_1 pipe -average slotted lengths 2 jb. 0.125"x 2.5"x 32 spf@ 4 Cimumkrential adjacent SLOTS, 1207o.042WSC rows, 3" Centers Staggered 18 deg..3 ft. L non-Moned ends; 1 alternating with 1 blank joint 13,895.0 14.4930 3,323.4 3.3244 NSD. 1J- 5202006 320 SLOTS Alternating solidlelodad st-pTa IIAV O lensa� F 184L1 pipe - average slotted lengths 2 its, 0.125" x 2 5"x 32 spf ® 4 Clmumferentieladjacent sLorS Is.e.011 we a- rotes, 3' Centers Staggered 18 deg., 3 ft. e-n-slofted ends', SLOTS; 14.a57.0.14,m4.0- alternating with 1 blank joint 14667.0 14,8300 3,334.4 3,339.5 Vu5 D,11 502012006 320 SLOTS Alternating amidlslonea st-ors: ISMSn5N30- 1841_1 pipe - average slotted lengths 2jls. 0125'x 2.5"x 32 spf ® 4 SLOrs: IESOGE IEI Clmumrerenlial adjacent rows. 3" Centers staggered 10 deg,.3 ft. noend 5; SLOTS I.A.a.ISEW.a- alteernatinmatind g with f blank join) G�SGM$LOTTED R.R.LI 9053.61 E$[enL KUP INJ 1J -184L1 ConocoMillips Alaska. Inc. zz9.3b Rm .cml VarrLeM,en.ophoo—lshes() HPNGER; YL.]- a O(a nB Snot Oen, am Top (RRB) arm (th s) Top (ND) IrtRan BIm ITW) IRRB) mne DABS Isnarsef B type cpm 150030 15.343.0 3,335.0 3,320.9 MD. 1! 51202008 32.0 SLOTS Altercating solidlslotted 1841_1 pipe- average slotted arvouc*are lmnm.e; MOIlengths 10a0 2lts. 0.125"x 2.5"x 32 spf@ 4 Circaparentlal Adjacent ares, 3"Centers NIR9LE14]a+ Staggered 18 deg, 3 R. non -slotted ends; altematingwhh 1 blank GASLIFT:3,1+]0 joint 15,560.0 15.732.D 3,309.0 3,297.1 MD. 1J 5202006 320 SLOTS Altercating So 184L1 pipe - average slotted lengths 21ts. 0.1 W SURFACE: So 23.977 2.5"x 32 spf Q 4 Circumferential adjacent .LEEME.rI rows, 3"Centers staggered 18 deg., 3 fl, non -Slotted ends; sltemating with 1 blank joint SEAL Asbv: am"16.1850 16,50180 3,299.0 3,331.3 MD. 1J 184L1 5202008 320 SLOTS Ahemoting so One pipe -average slotted lengma 2pa. 0.125"x 2.5"x 32 spfC4 Circumferential adjacent D LINER Lt. 11a. 116 Rho 3" Centers INTERMEDIATE: 214-9,Y13d , staggered 18 deg., 3 ft. non -slop ones! alternating wi1M1 1 blank join! Notes: General & Safety SLONL9.009.09.31e0� Entl D.I. I Anonotion 5/242006 I NOTE. CANNOT ENTER LI IATERAL 5/242DD6 NOTE'. MULTI -LATERAL WELL: 1J-184 (e-BAND),161841_1 (D SAND) 1112009 iNOTE: VIEW SCHEMATIC a/Alaska Schamati 9.0REV SLOT .1DS6.I SLOTS: 9.9+P0.1D+2SA SLOTS 10651P11133.0 &LOTb:I1.35a61f.9,30- 11r r SLOTS, 120700.12551 SLOTS', 138950.14.d9S.0� SLOTS l N.S67014.e390- IL ` BLOTb:15W3015,31a0- SLOTS:15.NESD"15]a30- SLOTS:18165.P165M➢- D-S,N SLOTTED LINER: aposs'S.S., STATE OF ALASKA AleKA OIL AND GAS CONSERVATION COM ION REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon E Plug Perforations E Fracture Stimulate E Pull Tubing F Operations Shutdown Performed: Suspend Perforate r Other Stimulate IT Alter Casing IT Change Approved Program Plug for Redrill IT Perforate New Pool IT Repair Well F Re-enter Susp Well I- 2.Operator Name: 4.Well Class Before Work: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Development Exploratory IT 206-045 - 3.Address: 6.API Number: P.O. Box 100360,Anchorage,Alaska 99510 Stratigraphic n Service 50-029-23305-60 7.Property Designation(Lease Number): 8.Well Name and Number: P Y 9 ) AD,25562,25661,380058 KRU 1J-184L1 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): none Kuparuk River Field/West Sak Oil Pool 11.Present Well Condition Summary: Total Depth measured 16692 feet Plugs(measured) None true vertical 3358 feet Junk(measured) None Effective Depth measured 16546 feet Packer(measured) 8907 true vertical 3336 feet (true vertical) 3364 Casing Length Size MD TVD Burst Collapse CONDUCTOR IN; 78 20 108 108 0 0 SURFACE 3947 13.375 3977 2239 0 0 INTERMEDIATE 9248 9.625 9275 3424 0 0 D SAND SLOTTEI 7494 5.5 16548 3336 0 0 0 0 0 0 0 0 Perforation depth: Measured depth: 9068-14838 pp ' p P SCANNEC M 0 2 .i9 I F 8r:ctzl ED True Vertical Depth: 3375-3339 EE,-. 0 1 2015 EEC Tubing(size,grade,MD,and TVD) Tubing in main wellbore �,, .)GCC Packers&SSSV(type,MD,and ND) HRD ZXP Liner Top Packer 8932=MD 3369=TVD, SLZXP Liner Top Packer 8730=MD 3334=TVD,D-Sand Baker Payzone Casing Packer 8907=MD 3364=TVD NIPPLE-Camco"DB-6"Nipple w/No-Go Profile @ 478 MD and 478 TVD 12.Stimulation or cement squeeze summary: Intervals treated(measured): none Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation Subsequent to operation 14.Attachments(required per 20 MC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations F Exploratory Development r Service F Stratigraphic Copies of Logs and Surveys Run IT 16.Well Status after work: Oil IT Gas IT WDSPL [— Printed Printed and Electronic Fracture Stimulation Data IT GSTOR WINJ IT WAG F GINJ SUSP IT SPLUG r- 17. 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: 315-644 Contact Danny Kane@265-6048 Email Danny.Kane@conocophillips.com Printed Name Danny Kane Title Sr. Wells Engineer Signature Phone:265-6048 Date 45t -'Dec-201S Form 10-404 Revised 5/2015 vv.. 1/G 114, RBDMS�Utt; 0 21015 Submit Original Only , KUP � � 1 J-1 84L1 ConocoPhillips 3', Well Attribut Max Angle D TD Alaska,Inc, Wellbore API/UWI Field Name Wellbore Status ncl(°) MD(ftKB) Act Btm(ftKB) C.oreocaFh181ps 500292330560 WEST SAK INJ „ 94.15 15,614.68 16,692.0 ... Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date Multiple Laterals-IJ-184L1,12/1/20152.52.33 PM SSSV:NIPPLE Last WO: 10/31/2015 31.51 5/25/2006 Vertical schemata(actual.. Annotation Depth(ftKB) End Date Annotation Last Mod By End Date Last Tag: Rev Reason:WORKOVER,GLV C/O lehallf 11/18/2015 HANGER;22.7 'as.1.1r. Casing Strings Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... Wt/Len(I...Grade Top Thread D-Sand SLOTTED 5 1/2 4.950 9,053.8 16,548.0 3,336.5 15.50 L80 BTCM . n ir,au.LINER Liner Details IIj Nominal ID A CONDUCTORInsulated;300-- I Top(ftKB) Top(TVD)(ftKB) Top Incl(°) Item Des Com lin) 108.0 9,053.8 3,374.0 87.02 SLEEVE HR LINER SETTING SLEEVE 6.280 9,062.1 3,374.4 87.25 XO BUSHING CROSSOVER BUSHING 4.890 NIPPLE;478.4 8 Perforations&Slots li Shot GAS LIFT,2,147 0 I MEt Dens Top(TVD) Btm(TVD) (shots/ I I Top(ftKB) Btm(ftKB) (ftKB) (ftKB) Zone Date ft) Type Com Q 9,068.0 9,319.0 3,374.7 3,372.8 WS D,1J- 5/20/2006 32.0 SLOTS Slotted pipe-average 184L1 slotted lengths 5 jts. SURFACE;30.2-3,977.0 { 0.125"x 2.5"x 32 spf @ II 4 Circumferential SLEEVE;8,702.0 �e=1 adjacent rows,3" I it'. Centers staggered 18 _ deg.,3 ft.non-slotted ends '= 9,356.0 9,713.0 3,371.4 3,360.4 WS D,1J- 5/20/2006 32.0 SLOTS Alternating solid/slotted SEAL ASSY;B,7W.1 = _ 184L1 pipe-average slotted lengths 2 jts.0.125"x 2.5"x32spf @ 4 Circumferential adjacent D LINER LEM;8,730.15,973.6 ,p f( rows,3"Centers INTERMEDIATE;27.4-9,275.0 4 °J staggered 18 deg.,3 ft. non-slotted ends; alternating with 1 blank I I joint 9,9400 10423.0 3,357-9 3,364.5 W5D.1J- 5/20/2006 32.0 SLOTS Alternating solid/slotted 184E 1 pipe-average slotted SLOTS,9,068.0-9,319.0 lengths 2 jts.0.125"x 2.5"x32spf@ 4 Circumferential adjacent rows,3"Centers staggered 18 deg.,3 ft. non-slotted ends; SLOTS;9,356.0-9,713.0 alternating with 1 blank joint 10,651.0 11 133.0 3.363.8 3,356.8 WS D,1J- 5/70/7006 32.0 SLOTS Alternating solid/slotted 184L1 pipe-average slotted lengths 2 jts.0.125"x 2.5"x32spf @ 4 Circumferential adjacent rows,3"Centers SLOTS;9,940.0.10,423.0 staggered 18 deg.,3 ft. non-slotted ends; alternating with 1 blank joint 11.359.0 11,843.0 3,345.1 3,334.6 WS D,1J- 5/20/2006 32.0 SLOTS Alternating solid/slotted 184L1 pipe-average slotted lengths 2 jts.0.125"x 2.5"x32spf @ 4 Circumferential adjacent SLOTS,10,651.0-11,133.0-. rows,3"Centers staggered 18 deg.,3 ft. non-slotted ends; alternating with 1 blank joint 12.070.0 12,558.0 3,336.9 3,339.6 WS D,1J- 5/20/2006 32.0 SLOTS Alternating solid/slotted 184L1 pipe-average slotted 1 lengths 2 jts.0.125"x 2.5"x32spf @ 4 -4 Circumferential adjacent SLOTS;11,359.0-11,843.0 rows,3"Centers staggered 18 deg.,3 ft. y non-slotted ends; r alternating with 1 blank I joint 12,867.0 13,515.0 3,346.0 3,344.6 WS D,1J- 5/20/2006 32.0 SLOTS Alternating solid/slotted 184L1 pipe-average slotted I lengths 2 jts.0.125"x 2.5"x32spf @ 4 sLors;lz,D7o.o-1z,ssa.0 Circumferential adjacent rows,3"Centers staggered 18 deg.,3 ft. -4 4- non-slotted ends; alternating with 1 blank joint 13,895.0 14,493.0 3,323.4 3,324.4 WS D,11- 5/20/2006 32.0 SLOTS Alternating solid/slotted SLOTS,12,867.0-13,515.0 -' r 184L1 pipe-average slotted lengths 2 jts.0.125"x .__. r 2.5"x 32 spf @ 4 SLOTS,13,895.0.14,493.0 Circumferential adjacent a- rows,3"Centers staggered 18 deg.,3 ft. non-slotted ends; SLOTS;14,887.0-14,638.0 r alternating with 1 blank joint 14,667.0 14838.0 3,334.4 3,339.5 WS D,1J- 5/20/2006 32.0 SLOTS Alternating solid/slotted SLOTS;15,003.045,343.0 r. 184L1 pipe-average slotted lengths 2 jts.0.125"x 2.5"x32spf @ 4 SLOTS;15,560.0-15,732.0------.-* Circumferential adjacent rows,3"Centers staggered 18 deg.,3 ft. SLOTS;18,165.0.16,508.0 - non-slotted ends; _ alternating with 1 blank joint DSand SLOTTED LINER; 9,053.8.16,548.0 • • >k �� Operations Summary (with Timelog Depths) 1J-184 OoncicoaPhillips Rig: NABORS 9ES Job: RECOMPLETION Time Log Start Depth Start Time End Time Our(hr) Phase Op Code Activity Code Time P-T-X Opera€Eon (ftKB) End Depth(ftKE) 10/26/2015 10/26/2015 3.00 MIRU MOVE MOB P Prep cellar area for rig move. Warm 12:00 15:00 up moving system,and pull front mats from under rig. Pull off 1J-180 and remove rigging material from around well. Clean area for Environmental handover to production. 10/26/2015 10/26/2015 6.00 MIRU MOVE MOB P Move in mats and lay herculite,Pull 15:00 21:00 Nabors 9ES over well and sit down. Move in pit module and tie in interconnect. Complete CPAI acceptance list-Accept Nabors 9ES at 21:00 hrs on 10-26-15. 10/26/2015 10/26/2015 1.00 MIRU WHDBOP MPSP P PU lubricator and pull BPV/Lay down 21:00 22:00 Lubricator-Obtain pressures-TBG= 133 psi,IA=215 psi and OA=145 psi. 10/26/2015 10/27/2015 2.00 MIRU MOVE RURD P Tie in circulation lines from the well to 22:00 00:00 the choke house. Bring 8.5 ppg KWF on board into rig pits and Condition KWF w/.06%by volume Safe lube. 10/27/2015 10/27/2015 4.75 MIRU WELCTL RURD P Continue to bring 8.5 ppg KWF on 00:00 04:45 board into rig pits and Condition KWF w/.06%by volume Safe lube. 10/27/2015 10/27/2015 3.50 MIRU WELCTL KLWL P PJSM,Circulate 890 bbls of 8.5 ppg 04:45 08:15 KWF w/.06%by volume Safe Lube to kill tanks thru Open Sliding sleeve© 8,699-ft @ 4 bpm @ 396 psi while holding 100 psi over sip of 150 psi. Pummped 666 bbls and recovered 595 bbls=89%returns.71 bbl losses. 10/27/2015 10/27/2015 0.50 MIRU WELCTL OWFF P Shut well in and monitor pressures-0 08:15 08:45 psi,blow down lines and monitor well for flow. No flow. 10/27/2015 10/27/2015 0.50 MIRU WELCTL RURD P RD circulation lines and put away. 08:45 09:15 Prep area for ND of the Tree. 10/27/2015 10/27/2015 0.75 MIRU WHDBOP MPSP P Dry rod in BPV and lay down dry rod. 09:15 10:00 10/27/2015 10/27/2015 1.00 MIRU WHDBOP NUND P ND Tree and hang back. 10:00 11:00 10/27/2015 10/27/2015 2.00 MIRU WHDBOP OTHR T clean and clear wotk area anround 11:00 13:00 well head. Work on functioning lock down screws- 10/27/2015 10/27/2015 0.50 MIRU WHDBOP MPSP P Intstall blanking plug 13:00 13:30 10/27/2015 10/27/2015 4.00 MIRU WHDBOP NUND P NU BOPE,obtain RKB's,Install 13:30 17:30 mouse hole and turn buckles. 10/27/2015 10/27/2015 1.00 MIRU WHDBOP RURD P RU BOP test equipment 17:30 18:30 Page 1/5 Report Printed: 12/1/2015 • • Operations Summary (with Timelog Depths) 0 ., 1J-184 ConocoPhillips Rig: NABORS 9ES Job: RECOMPLETION Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Death(ftKS) 10/27/2015 10/28/2015 5.50 MIRU WHDBOP BOPE P Conduct Initial BOP test at 250/3,500 18:30 00:00 psi with 4"and 4-1/2 test joints. Chuck Scheve waived witness of the test @ 5:50 hrs on 10-26-15. 24 hr notice was given @ 4:55 hrs on 10-26- 15. Test#1 Blind Rams,CM valves 1,2,3 and 16, Upper IBOP and Demco Kill valve on mud manifold Test#2 Blind Rams,CM valves 4,5 and 6, Lower IBOP and HCR Kill valve Test#3 Blind Rams,CM valves 7,8 and 9, Manual Kill valve and 4-1/2 EUE 8rd FOSV Test#4 Blind Rams,Manual and Hydraulic Choke and HCR Kill. Test#5 Blind Rams,CM valves 10 and 11 Test#6 Blind Rams,CM valves 12, 13 and 14. Test#7 Annular,CM valves 15,4"HT FOSV Test#8 Upper VBR's,4"HT Dart Valve,HCR Choke Test#9 Upper VBR's and Manual Choke Page 2/5 Report Printed: 12/1/2015 • S Operations Summary (with Timelog Depths) 1J-184 ConocoPhillips Rig: NABORS 9ES Job: RECOMPLETION Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code AetMity Code Time P-T-X Operation (mks) End Depth(ttKS) 10/28/2015 10/28/2015 1.50 MIRU WHDBOP BOPE P Continue to Conduct Initial BOP test at 00:00 01:30 250/3,500 psi with 4"and 4-1/2 test joints. Chuck Scheve waived witness of the test @ 5:50 hrs on 10-26-15. 24 hr notice was given @ 4:55 hrs on 10-26-15. Test#10 Lower VBR's,4-1/2 test joint,and 4- 1/2 FOSV--Koomey Test System Pressure-3,000 psi After closure-1,650 psi 1st 200 psi gain-26 seconds Full system pressure-146 seconds N2 Bottles-6 Ave 2,042 psi Test#11 Lower VBR's,4-1/2 test joint,4-1/2 FOSV,HCR Kill/Choke Test#12 Annular,4-1/2 test joint,4-1/2 FOSV, Outer Test Spool,HCR Kill Test#13 Upper VBR's,4-1/2 test joint,4-1/2 FOSV,Inner Test Spool,HCR Kill 10/28/2015 10/28/2015 2.00 MIRU WHDBOP MPSP P Pull Blanking plug and BPV 01:30 03:30 10/28/2015 10/28/2015 0.50 COMPZN RPCOMP PULL P Back out lockdown screws. Pull 03:30 04:00 hanger off seat 210k and pull seals at 95K. 10/28/2015 10/28/2015 2.00 COMPZN RPCOMP CIRC P Circulate 1.5 hole volumes @ 9 bpm 04:00 06:00 @ 360 psi-took 25 bbls to fill hole and 37 bbls to get 8.5 ppg back surface. Total losses=48 bbls - equivalent to 17 bph losses. 10/28/2015 10/28/2015 0.25 COMPZN RPCOMP PULL P Lay down tubing hanger and landing 06:00 06:15 joint. 10/28/2015 10/28/2015 0.75 COMPZN RPCOMP PULL P Lay down 4.5"TBG form 8,744-ft to 8,744.0 8,414.0 06:15 07:00 8,414-ft. Up wt=94K,Dn wt=61K 10/28/2015 10/28/2015 2.50 COMPZN RPCOMP MPSP X PU,MU and RIH w/9-5/8 40#Baker 8,414.0 107.0 07:00 09:30 Storm packer with 8,414-ft of 4.5 completion TBG hanging from the bottom of the packer to 107-ft and set. Test Storm packer to 500 psi-bleed off pressure and blow down lines. Drain stack. 10/28/2015 10/28/2015 1.25 COMPZN RPCOMP NUND X PJSM,Pull mouse hole,turn buckles, 107.0 0.0 09:30 10:45 riser. ND BOPE stack and rack back. 10/28/2015 10/28/2015 9.75 COMPZN RPCOMP EQRP X PJSM, RU tools and drill out galled 0.0 0.0 10:45 20:30 lock down,dress threads and service other lock down screws. MU landing joint to TBG hanger and land on No go. Attach to parent bowl. Back landing joint. Page 3/5 Report Printed: 12/1/2015 • • Operations Summary (with Timelog Depths) 1J-184 CgnoceiP'hilgps Rig: NABORS 9ES Job: RECOMPLETION Time Log Start Depth, Start Time End Time Our(hr) Phase Op Code Activity Code Time P-T-X Operation (MKS) End Depth(ftKE); 10/28/2015 10/28/2015 1.00 COMPZN RPCOMP NUND X NU BOPE,install riser,turn buckles 0.0 0.0 20:30 21:30 and mouse hole. 10/28/2015 10/28/2015 0.25 COMPZN RPCOMP BOPE X Install blanking plug for shell testing 0.0 0.0 21:30 21:45 purposes. 10/28/2015 10/28/2015 0.75 COMPZN RPCOMP BOPE X RU and shell test BOPE @ 250/ 0.0 0.0 21:45 22:30 3,500 psi. RD test equipment blow down lines and drain Bop. 10/28/2015 10/28/2015 0.25 COMPZN RPCOMP BOPE X Pull blanking plug 0.0 0.0 22:30 22:45 10/28/2015 10/29/2015 1.25 COMPZN RPCOMP PULL X MU landing joint and screw in top 0.0 0.0 22:45 00:00 drive. BOLDS,Un land TBG hanger and false bowl @ 100K. Lay down hanger and landing jt. 10/29/2015 10/29/2015 1.50 COMPZN RPCOMP MPSP X PJSM, PU,MU and RIH w/retrieving 0.0 107.0 00:00 01:30 overshot to 107-ft and engage Storm packer. Open unloader and check for pressure below packer. Release packer and POOH. Lay down storm packer. 10/29/2015 10/29/2015 1.00 COMPZN RPCOMP RURD X Change over elevators and handling 107.0 8,414.0 01:30 02:30 equipment from drill pipe to Tubing. Clean and clear rig floor in preparation for pulling and laying down 4-1/2 Tubing. 10/29/2015 10/29/2015 11.00 COMPZN RPCOMP PULL P POOH,laying down and tallying de 8,414.0 0.0 02:30 13:30 completion from 8,414-ft to seal assembly 10/29/2015 10/29/2015 0.50 COMPZN RPCOMP RURD P Clear and clean rig floor-off load pipe 0.0 0.0 13:30 14:00 shed. 10/29/2015 10/29/2015 0.50 COMPZN RPCOMP SFTY P Hold PJSM with all involved with 0.0 0.0 14:00 14:30 running 4-1/2 completion. 10/29/2015 10/30/2015 9.50 COMPZN RPCOMP PUTB P PU,MU and RIH w/4-1/2, 12.6#,L-80 0.0 6,660.0 14:30 00:00 IBTM-M Tubing Completion to 6,660-ft filling hole w/4 bbls every 15 jts. Average MU Torque 3,800 ft/lbs. Up wt-71KDn wt-57K 10/30/2015 10/30/2015 3.25 COMPZN RPCOMP PUTB P Continue to PU, MU and RIH w/4-1/2, 6,660.0 8,772.5 00:00 03:15 12.6#,L-80 IBTM-M Tubing Completion from 6,660-ft filling hole w/ 4 bbls every 15 jts. Average MU Torque 3,800 fUlbs. Up wt-71K Dn wt-57K to 8,772.51-ft. No go. PU 4- ft and space out. Lost 8 bbls during tripping operations 10/30/2015 10/30/2015 0.25 COMPZN RPCOMP PRTS P Close annular and pressure test the IA 8,772.5 8,732.0 03:15 03:30 to 1,000 psi for 10 minutes. Good Test. Bleed off pressure and open annular. 10/30/2015 10/30/2015 1.00 COMPZN RPCOMP HOSO P Pull jts 304 thru 302. PU 13.51-ft of 8,732.0 8,732.0 03:30 04:30 TBG pups. RIH below jt#302. PU, MU, RU landing joint on TBG hanger. RU to reverse circulate CI Brine taking returns to kill tank if needed. 10/30/2015 10/30/2015 5.75 COMPZN RPCOMP CRIH P PT treating lines at 3,500 psi. -good 8,732.0 8,732.0 04:30 10:15 test. Reverse circulate 570 bbls of CI brine down the IA taking returns up the Tubing to the kill tanks @ 3.5 bpm @ 344 psi. Recovered 478 bbls at the kill tanks-lost 92 bbls to formation. Page 4/5 Report Printed: 12/1/2015 • Operations Summary (with Timelog Depths) 1J-184 QxxicdPhillips Rig: NABORS 9ES Job: RECOMPLETION Time Log Start Depth Start Time End Time Our(hr) Phase Op Code Activity Code Time P-T-X Operation (ftEE)" End Depth(ftKB). 10/30/2015 10/30/2015 2.75 COMPZN WHDBOP THGR P Engage Seals into the SBE and Open 8,732.0 8,769.0 10:15 13:00 annular,Drain stack through the IA. Land hanger with Mule shoe at 8,769- ft.and RILDS. Blow down lines. Test upper and lower hanger seals @ 250/ 5,000 psi for 10 minutes. 10/30/2015 10/30/2015 0.50 COMPZN RPCOMP RURD P Remove landing joint, 8,769.0 8,769.0 13:00 13:30 10/30/2015 10/30/2015 1.50 COMPZN RPCOMP PRTS P PT IA @ 2,500 psi for 30 minutes on 8,769.0 8,769.0 13:30 15:00 chart. Monitor the TBG for flow.- Good Test. Bleed of IA and ramp up the pressure to 3.500 psi in an attempt to shear out the SOV Valve. Took 3 attempts prior to shearing @ 3,900 psi. 10/30/2015 10/30/2015 0.50 COMPZN RPCOMP RURD P Blow down all choke and kill lines in 8,769.0 8,769.0 15:00 15:30 preparation for ND of BOPE 10/30/2015 10/30/2015 0.25 COMPZN WHDBOP MPSP P Install 4"BPV with dry rod 8,769.0 8,769.0 15:30 15:45 10/30/2015 10/30/2015 1.25 COMPZN WHDBOP NUND P Pull mouse hole,riser and ND BOPE 0.0 0.0 15:45 17:00 10/30/2015 10/30/2015 0.50 COMPZN WHDBOP NUND P NU Tree 0.0 0.0 17:00 17:30 10/30/2015 10/30/2015 0.50 COMPZN WHDBOP MPSP P Pull BPV with dry rod and install TWC 0.0 0.0 17:30 18:00 10/30/2015 10/30/2015 1.25 COMPZN WHDBOP PRTS P Pressure test the adapter/Seal neck 0.0 0.0 18:00 19:15 void @ 250/5,000 for 10 minutes. RU test pump and PT tree with diesel- 250/5,000 psi. Found flange between upper and lower master leaking-tighten bolts and re test.- good test. 10/30/2015 10/30/2015 0.50 COMPZN WHDBOP MPSP P Pull TWC with dry rod 0.0 0.0 19:15 19:45 10/30/2015 10/30/2015 3.00 COMPZN WHDBOP FRZP P RU lines from the well to the kill tank 0.0 0.0 19:45 22:45 to take returns. Pt and verify no leaks. 10/30/2015 10/31/2015 1.25 COMPZN WHDBOP FRZP P PJSM,MIRU Little Red Services. PT 0.0 0.0 22:45 00:00 treating lines @ 2,200 psi,reverse circulate 110 bbls @ 2 bpm. 10/31/2015 10/31/2015 1.25 COMPZN WHDBOP FRZP P Continue to Freeze protect by closing 0.0 0.0 00:00 01:15 in Production valve and bull head 55 @ 1,000 psi ICP and 1,550 psi FCP. RD Little Red Services. Allowing the well to swap through jumper hoses. 10/31/2015 10/31/2015 3.25 DEMOB WHDBOP MPSP P PU,RU and operate lubricator and 0.0 0.0 01:15 04:30 lubricate in the BPV. Lay down and offload lubricator. Secure well and Service Tree. Release Nabors 9ES @ 04:30 hrs on 10-31-15 Page 5/5 Report Printed: 12/1/2015 ti OF ? • s, THE STATE Alaska Oil and Gas 7A of LASKA Conservation Commission z 333 West Seventh Avenue 1T.h'.a GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main: 907.279.1433 ALAS' Fax: 907.276.7542 www.aogcc.alaska.gov Danny Kane SCANNED Sr. Wells Engineer s, ConocoPhillips Alaska, Inc. Q (—d t+ P.O. Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, West Sak Oil Pool, KRU 1J-184L1 Sundry Number: 315-644 Dear Mr. Kane: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Cathy P Foerster Chair DATED this � day of October, 2015 Encl. RBDMS OCT Z 3 2015 STATE OF ALASKA • • laSKA OIL AND GAS CONSERVATION COMMISSION • • APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 1.Type of Request: Abandon r Rug Perforations r Fracture Stimulate r Pull Tubing 17. Operations Shutdown r Suspend r Perforate r Other Stimulate r Alter Casing r Change Approved R-ogram r Rug for Redrill r Perforate New Pool r Repair Well 17 r Re-enter Susp Well r Other: r 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Exploratory r Development r 206-045 3.Address: Stratigraphic r Service 6.API Number: P.O. Box 100360,Anchorage,Alaska 99510 50-029-23305-60 , 7.If perforating, 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require spacing exception? Yes r No , KRU 1J-184L1 . 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL 25662,380058 , Kuparuk River Field/West Sak Oil Pool • 11. PRESENT WELL CONDITION SUMMARY Total depth MD(ft): Total Depth TVD(ft): Effective Depth MD(ft): Effective Depth TVD(ft): Plugs(measured): Junk(measured): 16692 • 3358 • 16546' • 3336' none none Casing Length Size MD TVD Burst Collapse CONDUCTOR 78 20 108' 108' SURFACE 3947 13.375" 3977' 2239' EC E IVIED INTERMEDIATE 9248 9.625 9275' 3424' ./.4/ Z/ c/`j D-SAND SLOI FED OCT 2 2015 LINER 7494 5.5 16548' 3336' AOGCC Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): slotted liner from 9068-16508, 3373-3331 4.5 L-80 8767 Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft) NO PACKER NIPPLE-4-1/2"Cameo"DB-6"Nipple w/3.875"No-Go Profile MD=502 TVD=502 12.Attachments: Description Surrrnary of Proposal 13. Well Class after proposed work: Detailed Operations Program r BOP Sketch r Exploratory r Stratigraphic r Development r Service , 14.Estimated Date for Commencing Operations: 15. Well Status after proposed work: 10/21/2015 OIL r WINJ r WDSPL r Suspended r 16.Verbal Approval: Date: GAS r WAG _ GSTOR r SPLUG r Commission Representative: GINJ r Op Shutdown r Abandoned r 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Danny Kane @ 265-6048 Email: Danny.Kane(cDconocophillips.com Printed Name Danny Kane Title: Sr. Wells Engineer Signature 3c.,' Phone:265-6048 Date i 2—CCT—ZOI S Commission Use Only Sundry Number: Conditions of approval: Notify Commission so that a representative may witness 315.—U'4L( Plug Integrity r BOP Test ,Mechanical Integrity Test PKocation Clearance r Other: 00P /--,r5 t- 7,—d 35-0O`J5.- / (' /SSP /`S 14e5 /2515 ) rzv-1.Oa` p v—r✓tk--te-rr tr5-f f," 2-5—e)f-2 p5 i5 • /--- t 1,, , f 7755 -1 liAlT off- rro�vi - -c/ 4 f1-rr 1-12 b-I ldCdA inJrc l Spacing Exception Required? Yes 0 No [r Subsequent Form Required: o la —404- /��((1)/n APPROVED BY Approved by: I 7{ it1 fs- 1?-(4,/(4**--- COMMISSIONER THE COMMISSION Date: J • 21—tc- vTt- !b//-01 . Approved ap lication is valid for 12 months tr m the date of approval. Submit�gForm and Form 10-403 Revised 5/2015 oR �G I N A L l�i��,— RBDM�7 U� d iiAlad�licate feAe0 LU Q • INV RECEIVED ConocoPhillips OCT 12 2015 Alaska AOGCC P.O. BOX 100360 ANCHORAGE,ALASKA 99510-0360 October 8,2015 Cathy Foerster State of Alaska Alaska Oil&Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage,Alaska 99501 Dear Commissioner: ConocoPhillips Alaska,Inc.hereby submits an Application for Sundry Approval to workover West Sak Injector KRU 1J-184/ 1J-184 L1 (PTD#206-044/206-045). KRU 1J-184/1J-184 L1 was spudded in April 2006 and completed as a dual-lateral West Sak B-&D-sand injector. After receiving permission from the AOGCC to gas-lift the well by opening the sliding sleeve,the well was initially brought on pre-production. During pre-production, a production profile log showed that only the B-sand lateral was producing and when coiled tubing was brought on the well to perform a fill clean-out,they discovered that access to the D-sand lateral was lost. After reviewing the drilling&coiled tubing data,the town engineering team determined that the D-sand lateral entry module(LEM)was installed 180°out of phase preventing access to the D-sand lateral. A rig work-over was performed in November 2006 to pull the upper completion,mill the injection packer,pull the D-sand LEM, and replace with a new D-sand LEM&upper completion. After finishing the rig work-over,the well was placed back on pre-production until January 2007 when the well was converted to water injection service. In 2014,the well failed an AOGCC-witnessed MIT-IA and was shut-in. Subsequent diagnostic work has confirmed a hole in the tubing above 8,700'MD. The proposed rig work-over of 1J-184/ 1J-184 L1 will consist of pulling the entire existing 4-V2"upper completion to the seal assembly and replacing with a new 4-1/4"upper completion to bring the well back on water-alternating-gas injection service. This Sundry is intended to document the proposed rig workover on KRU 1J-184 / 1J-184 L1 where the intent is to pull tubing and to request approval to workover this well. If you have any questions or require any further information, please call me at 265-6048 or email me at danny.kane@conocophillips.com. Sincerely, Danny Kane Senior Wells Engineer CPAI Drilling and Wells • • KUP INJ 1J-184L1 liriiii .Kt. F • Conoc Phiilips ., ..,,•,. Well Attributes Max Angle&MD TD Alaska,Inc. / Wellbore API/IIWI Field Name Wellbore Status ncl CI MD(ftKB) Act Btm(nKB) r risiee,etmhpr 500292330560 WEST SAK INJ 94.15 15,614.68 16,692.0 ... Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date Multiple Laterals-lJ-f84L1,516/20153:34.58 PM 555V:NIPPLE Last WO' 12/11/2006 31.51 5/25/2006 Vemcal schematic(aMualt Annotation Depth(nKB) End Date Annotation Last Mod By End Date - Last Tag: {gip Rev Reason:GLV C/O hipshkf 5/6/2015 HANGER;22.8- l' F „ Cas/ng:Wrings ,:' { Casing Description 0D(in) ID(In) Top(1IKB) Set Depth(MB) Set Depth(TV0)...Wt/Len(I...Grade Top Thread D-Sand SLOTTED 5 1/2 4.950 9,053,8 16,548.0 3,336.5 15.50 L80 BTCM Lq 'I% ' LINER Liner Details Nominal ID .h CONDUCTOR Insutaled,30.0- Top(RIM) Top(TVD)(nKB) Top Incl(") Item Des Com (In) 108.0 9,053.8 3,374.0 87.02 SLEEVE HR LINER SETTING SLEEVE 6.280 NIPPLE.502.2 1.7 9,062.1- 3,374.4 87.25 XO BUSHING CROSSOVER BUSHING 4.890 GAS LIFT;2,040.0 4 Perforations&Slots Shot Dens 1 Top(TVD) Btm(TVD) (shots/f Top(nKB) Btm(11KB) MKS) (ftKB) Zone Date t) Type Com SURFACE:30.2-3,977.0 e- 9,068.0 9,319.0 3,374.7 3,372.8 WS D,1J- 5/20/2006 32.0 SLOTS Slotted pipe-average 184L1 slotted lengths 5 jts. SLEEVE-C',6699.8 ii 0.125'x 2.5"x 32 spf @ 4 Circumferential ' adjacent rows,3" 'r'a Centers staggered 18 k-11.tEr LOCATOR,8,748.9 end.,3 ft.non-slotted ?r ends SEAL ASSY;8,750.0 •® 9,356.0 9,713.0 3,371.4 3,360.4 WS D,1J- 5/20/2006 32.0 SLOTS Alternating solid/slotted '=ar- 184L1 pipe-average slotted lengths 2 jts.0.125"x SLEEVE-c;8 022.t 2.5"x 32 spf @ 4 D LINER LEM;8,730.t.8 973.6 -aaaa rq Circumferential adjacent INTERMEDIATE;27.4-9,275.0 - rows,3"Centers staggered 18 deg.,3 ft. non-slotted ends; alternating with 1 blank joint 9,940.0 10,423.0 3,357.9 3,364.5 WS D,1J- 5/20/2006 32.0 SLOTS Alternating solid/slotted I 9,068.0-9.319.0i_j 184L1 pine-sverag0 slotted SLOTS lengths 2sp)0.125"x 2.5"x32spf@ 4 Circumferential adjacent i- rows,3"Centers 1 staggered 18 deg.,3 ft. r non-slotted ends; SLOTS,9,356.0-9,713.0 alternating with 1 blank taint 10,651.0 11,133.0 3,363.8 3,356.8 WS D,1J- 5/20/2006 32.0 SLOTS .,Altemating solid/slotted 184L1 pipe-average stoned lengths 2 jts.0.125"x 2.5"x32spf@ 4 Circumferential adjacent rows,3"Centers SLOTS;9,940.0-10,423.0 staggered 18 deg.,3 ft. non-slotted ends; alternating with 1 blank joint 11,359.0 11,843.0 3,345.1 3,334.6 WS D,1J- 5/20/2006 32.0 SLOTS Alternating solid/slotted 184L1 pipe-average slotted lengths 2 jts.0.125"x 2.5"x32spf @ 4 Circumferential adjacent SLOTS;10,651.0-11,133.0- rows,3"Centers staggered 18 deg.,3 ft. non-slotted ends; I- alternating with 1 blank L joint 12,070.0 12,558.0 3,336.9 3,339.6 WS D,1J- 5/20/2006 32.0 SLOTS Alternating solid/slotted 184L1 pipe-average slotted lengths 2 jts.0.125"x 2.5"x32spf @ 4 Circumferential adjacent SLOTS;11359.0-11,843.0 rows,3"Centers staggered 18 deg.,3 ft. non-slotted ends; alternating with 1 blank joint 12,867.0 13,515.0 3,346.0 3,344.6 WS D,1J- 5/20/2006 32.0 SLOTS Altemating solid/slotted 184L1 pipe-average slotted lengths 2 jts.0.125"x 2.5"x32spf @ 4 Circumferential adjacent SLOTS;12670.0-12558.0 rows,3"Centers staggered 18 deg.,3 ft. non-slotted ends; alternating with 1 blank joint 13,895.0 14,493.0 3,323.4 3,324.4 WS D,1J- 5/20/2006 32.0 SLOTS Alternating solid/slotted SLOTS:12667.0-13,515.0 184L1 pipe-average slotted lengths 2 jts.0.125"x 2.5"x32spf @ 4 SLOTS,13895.0-14,493.0- Circumferential adjacent r rows,3"Centers staggered 18 deg.,3 ft. non-slotted ends; SLOTS;14,667.0-14,838.0 ~ alternating with 1 blank joint SLOTS;15,003.0-15,343.0 14,667.0 14,838.0' 3,334.4 3,339.5 WS D,1J- 5/20/2006 32.0 SLOTS Alternating solid/sk tted 184L1 pipe-average slotted lengths 2 jts.0.125"x 2.5"x32spf @ 4 SLOTS;15,560.0-15,732.0 Circumferential adjacent I- rows,3"Centers staggered 18 deg.,3 ft. SLOTS;16,165.0-16,508.0 Y non-slotted ends; alternating with 1 blank joint 0.Sand SLOTTED LINER. 9,053.8-16,548.01 • r,, . ,4414 KUP INJ 1J-184L1 • ConocoPhillips t Alaska,Inc. ••• Multiple Laterals-1J-184L1,5/8/20153.34.59 PM Vertical schematic(actual) IIIIIIIIMMIll HANGER.22.8-i j.i . Perforations&Slots Shot ut p Dens Top(TVD) Btm(TVD) (shotstl Top(ftKB) Bim(11KB) (BOB) (ftKB) Zone Date t) Type Com 15803.0 15,343.0 3,336.0 3,320.9 WS D,1J- 5/20/2006 32.0 SLOTS Alternating solid/slotted CONDUCTOR Insulated;30.0- 3AI' 184L1 pipe-average slotted 1 aao lengths 2 jts.0.125"x 2.5"x32spf @ 4 NIPPLE,502.2 4t Circumferential adjacent rows,3"Centers GAS LIFT,2,040.0 d staggered 18 deg.,3 ft. t non-slotted ends; alternating with 1 blank F joint SURFACE:30.2-3,977.0-4 L 15,560.0 15,732.0 3,309.0 3,297.1 WS D,1J- 5/20/2006 32.0 SLOTS Alternating solid/slotted 1840 pipe-average slotted lengths 2 jts.0.125"x SLEEVE-C,8,699.8 II 2.5"x 32 spf @ 4 Circumferential adjacent Q 111.8 rows,3"Centers r'2,. iL staggered 18 deg.,3 ft. LOCATOR;8,748.9 non-slotted ends; alternating with 1 blank —_- joint SEAL ASSY;8,750.0 16,165.0 16,503.0 3,299.0 3,331.3 WS D,1J- 5/20/2006 32.0 SLOTS Alternating solid/slotted 184L1 pipe-average slotted SLEEVE-C;8,822.1 ri r( lengths 2 jts.0.125"x D LINER LEM,8.730.1-8,973.6 ;L 4 2.5"0 32 spf @ 4 INTERMEDIATE,27.4-9,275.0` - Circumferential adjacent rows,3"Centers staggered 18 deg.,3 ft. non-slotted ends; alternating with 1 blank joint SLOTS,9,068.0-9 319.0 Notes:General&Safety ] [ End Date Annotation 5/24/2006 NOTE:CANNOT ENTER L1 LATERAL 5/24/2006 NOTE:MULTI-LATERAL WELL: 1J-184(B-SAND),1J-184L1(D-SAND) 1/1/2009 NOTE:VIEW SCHEMATIC w/Alaska Schematic9.OREV SLOTS',9.356.0-9,713.0 SLOTS.9,940.0-10,423.0 SLOTS;10,651.0-11,133.0 L SLOTS:11,359.0-11,843.0 Si OI S'.12 070.0-12.552.0 SLOTS.12,867.0-13,515.0 SLOTS;13,895.0-14,493.0 SLOTS,14,667.0-14.838.0 ~ r SLOTS,15,003.0-15,343.0 SLOTS,15,560.0-15,732.0 SLOTS,16,165.0-16,508.0 DSand SLOTTED LINER; 9,053.8-16,548.01 • • • KRU 1J-184 (& 1J-184 L1)—Proposed Rig Workover Pull & Replace Upper Completion PTD #:206-044 (& 206-045) Current Status: KRU 1J-184(& 1J-184 L1),a West Sak B-&D-sand dual-lateral injector,is currently shut-in after failing multiple MIT-IAs as a result of a tubing leak identified to be shallower than 8,700'MD. Please see below for the well integrity history of 1J-184,including the aforementioned failure which required the well to be shut-in: o 2006(April)—The KRU 1J-184& 1J-184 L1 dual lateral injector was drilled and completed. • The well was brought on pre-production. PPROF splits showed all production was coming from the D-lateral. Coiled-tubing unable to enter D-lateral for fill clean-out. Suspect misalignment of the D-lateral LEM(lateral entry module)during installation. o 2006(November)—KRU 1J-184 is worked over to replace the D-lateral LEM. Regained D-lateral access. o 2014—Failed a MIT-IA(15-May-2014). • The MIT-IA failed during a four-year AOGCC-witnessed test leaking 2.8 gpm at 1,205 psig. • The tubing&IC pack-offs were pressure-tested successfully. Either failed completion or casing integrity has caused the leak(not at surface). • Coiled tubing cycled the Baker CMD sliding sleeve open&close,but follow-up MIT-IAs still failed,leaking 0.16 bpm at 2,070 psig&0.25 bpm at 2,175 psig. • Coiled tubing set a 3.562"DB-P plug in the DB nipple profile at 8,882'MD to isolate the B-sand lateral. Set an isolation sleeve across the D-sand LEM at 8,814'MD to isolate the D-sand lateral. Attempted a MIT-T but failed the pressure-test. Applied coiled tubing weight and attempted a MIT-T,MIT-IA,&CMIT-TxTA—all tests failed. Diagnostic work inconclusive on leak location. • Coiled tubing set a CAT standing valve at 8,700'MD(immediately above the Baker CMD sliding sleeve). Attempted a MIT-T—failed. Attempted a CMIT-TxIA,passed. • Confirms there is a tubing leak above 8,700'MD. • Confirms integrity of the IA(tubing x production casing,surface to the SLZXP packer). • Suspect that the isolation sleeve and/or the DB-P plug are leaking(why prior coiled- tubing work failed an MIT-T,MIT-IA,&CMIT-TxIA where test pressure was leaking to the West Sak sands). • Slickline attempted a lead-detect log but the leak rate was too low to be conclusive(<0.25 bpm). Scope of Work: Pull the 4-1/2"upper completion&run a new 4-1/2"upper completion. General Well Info: Well Type: Injector MPSP: 1,485 psi using MASP=(PP-(0.1*TVD)),assuming dry gas gradient to surface. Reservoir Pressure/TVD: West Sak B/D—1,825 psi/3,409'TVD(10.3 ppg EMW) Wellhead Type/Pressure Rating: ABB Vetco Gray Horizontal(13-3/8"5M x 4-1/16"5M) BOP configuration: Annular/Pipe Rams/Blind Rams/Mud Cross/Pipe Rams MIT Results: MIT-IA Failed 14-May-2014 Last Passed 14-May-2010 CMIT-TxIA Passed 02-May-2015 Production Casing Integrity Confirmed MIT-OA—Open Shoe Earliest Estimated Start Date: .. 6e 5 2 t-c, ""1"-ZeDIS- Production Engineer: Michael Sullivan Workover Engineer: Danny Kane (907)265-6048 danny.kane a conocophillips.com • • KRU 1J-184 (& 1J-184 L1)—Proposed Rig Workover Pull & Replace Upper Completion PTD #:206-044 (& 206-045) Summary of Proposed RWO Procedure: Proposed Pre-Rig Work: 1. RU Coiled Tubing. a. Perform a leak-detect log to find&locate the leak(s). b. Perform a CMIT-TxIA to confirm that the Isolation Sleeve&DB plug were set&holding pressure. c. Open the Baker CMD sliding sleeve at 8,699'MD. d. RD Coiled Tubing. 2. Set the BPV. Proposed Rig Workover Procedure: 1. MIRU RWO Rig. 2. Pull the BPV. Circulate seawater around through the open Baker CMD sliding sleeve at 8,699' MD. Obtain SITP&SICP;if pressure is observed at surface,calculate the required KWF and circulate around as necessary. Verify the well is static. 3. Set the BPV,ND the tree,set the blanking plug,NU BOPE,&test BOPE to 250/3,500 psi low/high. 4. Pull the blanking plug&BPV,screw in the landing joint,BOLDS,&unseat the tubing hanger. 5. P/U on the tubing&pull the tubing hanger to the rig floor. Verify that the well is static& TOH laying down the existing 4-1/2"upper completion(entire upper completion to the base of the locating seal assembly). 6. M/U&TIH with the new 4-1/2"upper completion as per design to just above the casing sealbore receptacle. 7. Engage the seal assembly until fully-located into the casing sealbore receptacle. P/U from fully-located,space- out 7',&mark the pipe at surface. 8. Space-out the completion with tubing pups and M/U the tubing hanger, 9. Swap the well over to corrosion-inhibited seawater across the upper completion. 10. Land the tubing hanger&RILDS. 11. Pressure-test the tubing&IA. Bleed the IA&then the tubing. Ramp up the IA pressure quickly to shear the SOV(IA to tubing shear). 12. Back-out the landing joint&install the BPV. 13. ND BOPE,NU the tree,install the tree test plug,&pressure test the tree to 250/5,000 psi. Pull tree test plug. 14. Freeze protect the well through the SOV in GLM#1. 15. Set the BPV. 16. RDMO RWO Rig. Proposed Post-Rig Work 1. Pull the BPV. 2. RU Coiled Tubing: a. Remove the SOV from GLM#1 &replace with a DV. b. Pull the Isolation Sleeve from across the D-Sand LEM c. Pull the 3.562"DB Plug set within the DB Nipple at 8,882'MD. d. RD Coiled Tubing. 3. Reset well house(s)&re-attach flow line(s). 4. Turn the well over to operations. e . • 4. _, . , ..,_._ ........ ....._ , .... . ._ 1 !. i _. 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They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. O~®~ - ~ ~~ Well History File Identifier Organizing (done) ~wo-sided ~~~ IIIIIIII III II III ^ Rescan Needed III 111111 (III III III RESCAN DIGITAL DATA OVERSIZED (Scannable) ~olor Items: ~skettes, No. , ^ Maps: ^ Greyscale Items: ^ Other, No/Type: ^ Other Items Scannable by a Large Scanner ^ Poor Quality Originals: OVERSIZED (Non-Scannable) ^ Other: ^ Logs of various kinds: NOTES: ^ Other:: BY: Maria Date: ~ /s/ Protect Proofing III (IIIIIIIIII IIIII BY: Maria Date: /s/ Scanning Preparation _~ x 30 = ~ + ~ =TOTAL PAGES ~J Q~ (Count does not include cover sh et) BY: Maria Date: ~ 1 - ! _L~9 lsl Production Scanning ~' ~ ~ Illllllllllllllllll Stage 1 Page Count from Scanned File: _~ (Count does include cove heet) Page Count Matches Number in Scanning Preparation: _~/ YES NO BY: Maria Date: ~ ~g /s/ 'n~, . ~ ~/- P Stage 1 If NO in stage 1, page(s) discrepancies were found: YES NO BY: Maria Date: /s/ Scanning is complete at this point unless rescanning is required. IIIIIIIIII (I II I I III ReScanned III (IIIIIIIIII IIIII BY: Maria Date: Comments about this file: /s/ o~.~v~~e~k.a immiioiimiii 10/6/2005 Well History File Cover Page.doc ! • ~~ ~~~ ~, ~~. s ~'~~ #~:,~ s ~: MICROFILMED 6/30/2010 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE C:\temp\Temporary Internet Files\OLK9\Microfilm_Marker.doc ~s''J~. DATA SUBMITTAL COMPLIANCE REPORT 6/19/2008 Permit to Drill 2060450 Well Name/No. KUPARUK RIV U WSAK 1J-184L1 Operator CONOCOPHILLIPS ALASKA INC API No. 50-029-23305-60-00 MD 16692 TVD 3358 Completion Date 5/25/2006 Complet ion Status 1-OIL Current Status 1WINJ IC REQUIRED INFORMATION Mud Log No Samples No Directional Survey DATA INFORMATION Types Electric or Other Logs Run: GR/Rre, Dens/NEU (data taken from Logs Portion of Master Well Data Maint Well Log Information: Log/ Electr Data Digital Dataset Log Log Run Interval OH / T pe Med/Frmt Number Name Scale Media No Start Stop CH Received Comments ED D Asc Directional Survey 8759 16692 Open 6/27/2006 C Lis 13988/Induction/Resistivity 0 0 Open 7/19/2006 US ~~ ~ C Asc 13988 induction/Resistivity 0 0 Open 7/19/2006 Test i Rpt 13988 Induction/Resistivity 0 0 Open 7/19/2006 ~D C Lis 14576~nduction/Resistivity 3953 16692 Open 4/4/2007 LIS Veri, GR, FET, ROP Well Cores/Samples Information: Sample Interval Set Name Start Stop Sent Received Number Comments ADDITIONAL INFORMATION Well Cored? Y~ Daily History Received? V N Chips Received? -~-/-PY' Formation Tops ~ N Analysis '1`tid-~ Received? Comments: _ ---- -------_-_ _ -_------_-_-_ _-_-_--__ _ _ _ _ _ ~1___ Compliance Reviewed By: -~ Date: ~~ wvv~-~ ~~ O 1Vlt; iV1UKA11' ll U M To: Jim Regg P.I. Supervisor ( ~itlj 6) ~ ~~ ~ U 7 FRO't't: Jeff Jones Petroleum Inspector State of Alaska Alaska Oil and Gas Conservation Commi~ DATE: Thursday, May 03, 2007 SUBJECT: Mechanical Inteo ty Tests CONOCOPHILLIPS ALASK4 I?`'C IJ-184L1 KLP.aRUT< RIV U wSAiC 1J-184Li Sre: Inspector NON-CONFIDENTIAL Reviewed Bv: P.I. Suprv_~~ Comm Well Name: KUPARL'K RN U WSAK 1J-t84L Insp Num: mitJJ070502105810 Rel Insp Num: API Well Number: 50-029-23305-60-00 Permit Number: 206-045-0 Inspector Name: Jeff Jones Inspection Date: 4/30/2007 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well ~ IJ-184L p In~ ~r TVD - ~- ' 3337 ~i IA ]280 ~ 3010 2990 I 2990 j ~~~ 206040 SPT I P.T.D ~TypeTest j j Testpsi - Isoo ' pA --- . - 167 ~ ns ! - - t7s t7s ~ I InteCVal INITAL P~F P %~TUb(ng ~~ 378 331 ' ' 382 382 ~~ Notes• ~ BBLS diesel pumped. - - Thursday, May 03, 2007 Pale 1 of 1 ~~ RECEIVE STATE OF ALASKA APR 2 4 ZOO7 ALASKA 01L AND GAS CONSERVATION COMMISSION AIBSI(i3 QII 8t G8S COn3. Co(11n1I$SlOi7 REPORT OF SUNDRY WELL OPERATIONS Anchorage 1. Operations Performed: Abandon ^ Repair Well ^ Plug Pertorations ^ Stimulate ^ Other. O Prod to WINJ Alter Casing ^ PuI1 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 ^ 206-045 / 3. Address: Strati ra hic g p ^ Service ~ ^ 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-029-23305-60 7. KB Elevation (ft): 9. Well Name and Number' RKB 0' 1J-184L1 8. Property Designation:. 10. Field/Pool(s): ADL 25662; 380058 ~ Kuparuk River Field /West Sak Oil Pool y 11. Present WeII Condition Summary:. Total Depth measured 16692' f feet true vertical 3358'r feet Plugs (measured) Effective Depth measured feet Junk (measured) true vertical feet Casing Length Size MD ND Burst Collapse Structural CONDUCTOR 108' 20" 108' SURFACE 3977 13-3/8" 3977 INTERMEDIATE - 9275' 9-5/8" 9275' WINDOW L1 1' 9-5/8" 8849' D-SAND SLOTTE 7495' 5-1/2" 16548' Perforation depth: Measured depth: true vertical depth: Tubing (size, grade, and measured depth) 4-1/2" , L-8Q 8768' MD. Packers &SSSV (type & measured depth). no packer SSSV=NIP SSSV= 501' 12. Stimulation or cement squeeze summary: Intervals treated (measured) None Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casin Pressure Tubin Pressure Prior to well operation 1263 481 51 1050. 213 Subsequent to operation 66 941 1654 71 14. Attachments 15. Well Class after proposed work: Copies of Logs and Surveys run _ Exploratory ^ Development ^ Service ^J 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. N/A'f C.O. Exempt: ..contact Bob Christensen /Bob Buchholz Printed Name R ober t W Buchholz Title Production Engineering Technician ~ / ~ / ~ ~~ Signature ~~~G~Y~ `~ r~~,e~~~2r--'G~~ Phone 659-7535 Date .,.//Z z/~ i r": e. I 9 24i ~ MO ~,. APR .LI ~ 2(~ Form 10-404 Revised 04/2004 ~ I ~ ~ N ~ L Submit Original Only 1J-184L1 DESCRIPTION OF WORK COMPLETED SUMMARY: Date Event Summary 04/15/07 Commenced Water Injection ~ ~ WELL LOG TRANSMITTAL To: 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-184 + L1, The technical data listed below is being submitted herewith concerns to the attention of: March 15, 2007 AK-MW-4348857 Please address any problems or Rob Kalish, Sperry Drilling Services, 6900 Arctic Blvd. , Anchorage, AK 99518 1J-184 + Ll: Digital Log Images: 50-029-23305-00, -60 1 CD Rom PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry Drilling Services Attn: Rob Kalish 6900 Arctic Blvd. Anchorage, Alaska 99518 Date: U ~ ~ tJL ~ ~`~'~ l ~l5 ~~~ l~ f Signed: ~L ._..__. _ ~~ li ~ G ~~~~~~ t ~ .e~ -;e u _ . . E~EIVE® STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION JAN ~ 1 2007 REPORT OF SUNDRY WELL OPERATIONS~ilaska Oj- ~ ray r~,..,_ ,.__ 1. Operations Pertormed: Abandon ^ Repair Well ^ Plug Perforations ^ Stimulate ^ Other J~' ~Of8~8 Alter Casing ^ Pull Tubing Q Perforate New Pool ^ Waiver ^ Time Extension ^ Change Approved Program ^ Operat. Shutdown^ Perforate ^ Re-enter Suspended Well ^ 2. Operator Name: 4. Current Well Status: 5. Permit to Drill Number: ConocoPhillips Alaska, InC. Development ~ Exploratory ^ 206-045! 306-370 3. Address: Stratigraphic ^ Service ^ 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-029-23305-60 ' 7. KB Elevation (ft): 9. Well Name and Number: RKB 28' 1J-184L1 8. Property Designation: 10. Field/Pool(s): ADL 25662, 380058 Kuparuk River Field /West Sak Oil Pool 11. Present Well Condition Summary: Total Depth measured 16692' ~ feet true vertical 3358' ' feet Plugs (measured) Effective Depth measured 16546' feet Junk (measured) true vertical 3336' feet Casing Length Size MD TVD Burst Collapse Structural Conductor 80' 20" 108' 108' Surface 3949' 13.375" 3977' 2238' Intermediate 9247' 9-5/8" 9275' 3423' Liner 7495' 5.5" 16548' 3373' Perforation depth: Measured depth: slotter liner from 9068'-16508' true vertical depth: 3374'-3331' Tubing (size, grade, and measured depth) tubing in main wellbore, , MD. PBCkers & SSSV (type & measured depth) LEM D-sand SL ZXP liner top pkr, Baker payzone casing pkr @ 8730', 8907' CamCO'DB-06' nipple @ 501' 12. Stimulation or cement squeeze summary: Intervals treated (measured) not applicable Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casin Pressure Tubin Pressure Prior to well operation SI Subsequent to operation 1297 3639 48 -- 339 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: Contact Ty Kemner @ 265-6480 Printed Name Randy Thomas Title CPAI Drilling Team Leader Signature ~ ~ `~`_ Phone `Lays 6 ~ 3 ~? Date i ~ 1 t /0 7 Pre ared b Shar n Allsu -Drake 263-4612 n ~: _ ~~~. ,~:„~ ~ t,+~ ~ .C~~1/off Form 10-404 Revised 04/2004 ~ ~ ~ ~ ~ ~ (~ ~ Submit Original Only JJJ~~~ .~~ ~- zw3 ~"f a ~. ~' Gc~lnc-cc~Philps A1ask~, 1nC. 1J-184L1 j API: 500292330: SSSV T e: NIPPLE Annular Fluid: ~ Reference L 28' RKB ,:< Last Ta _ Last Tag Date: Casing String -ALL S ~ ( '~ ~ Descri lion rn~rnr rrTno PACKER (8730-8751, OD:9.625) BUSHING (8751-8753, OD:7.670) SBR (8753-8772, OD:6.280) BUSHING (8772-8774, OD:6.020) PUP-LEM (87748814, OD:5.200) PUP (885x9019, OD:5.500) SLEEVE-C (9o5a-9os2, OD:8.280) ;_ ~'~ Perf (9068-16508) ~~I I ~ __~ ~ - ~ - 1 __ 1 • KRU 1 J-184L1 Well T e: PROD An le TS: d Sri Com letion: 5/25/2006 An le TD: 81 d 16692 Last W/O: 12/11/2006 Rev Reason: WORKOVER, GLV C/O, OPEN SLV Ref L Date: Last U ate: 12/25/2006 TD: 16692 ftK6 Max Hole Angle: ' I Toq 94 deg (il 15615 I Bottom I TVD 1 VJt I Grade I Thread I D-SAND SLOTTED LINER 5.500 9053 16548 3336 15.50 L-80 HYD 521/BTCM Tubing String...-TUBING Size To Bottom TVD VYt Grade Thread 4.500 0 8768 3341 12.60 L-80 IBTM Perforations Summary Interval TVD Zone Status Ft SPF Date T e Comment 9068-16508 3374 - 3331 WS D,WS 7440 32 5/20!2006 SLOTS Alternating slots/solid pipe D.WS C Gas Lift Mandrels/Val ves t MD TVD Man Man Type i M V Type V OD Latch Port TRO Date Run Vlv ~ Mfr ~ ~ ~ Cmn~ 1 2040 1742 CAMCO _ _-- - ~ GLV 1 0 BK 5 0.143 1410 12/1/200 KBG_ -2 _ _ 6 - Other iu ,equip., etc.) - COMPLETi~N ~ De th TVD T e Descri lion ID 23 23 HANGER VETCO GRAY TUBING HANGER 4.500 501 501 NIP CAMCO'DB-06' NIPPLE w/3.875" NO GO PROFILE 3.875 8700 3328 SLEEVE-O BAKER 4.5" CMD SLIDING SLEEVE w/CAMCO 3.81"'DB' PROFILE - 3.812 OPEN 12/18/2006 8749 3337 LOCATOR BAKER LOCATOR 3.980 **NOTE: GBH-22 LOCATOR SPACED OUT 4.7' ABOVE FULLY INSERTED** 8750 3337 SEAL BAKER SBE SEAL ASSEMBLY 3.880 8767 3340 SHOE MULE SHOE --- - _- - 3.958 Other (plug s, equip., etc.} - D-SAND LINER DETAIL ---- De th TVD T e Descri lion ID 8730 3334 PACKER LEM D-SAND SL ZXP LINER TOP PACKER 7.500 8751 3338 BUSHING LEM 0.SAND CROSSOVER BUSHING 4.890 8753 3338 SBR LEM 0.SAND 190-47 CASING SEAL BORE RECEPTACLE 4.750 8772 3341 BUSHING LEM D-SAND CROSSOVER BUSHING 3.930 8774 3342 PUP-LEM 3.958 8814 3348 HANGER LEM D-SAND ABOVE HOOK HANGER 3.930 8822 3350 HANGER LEM D-SAND INSIDE HOOK HANGER 3.688 8827 3350 HANGER D-SAND L1 BAKER MOD PZ HOOK HANGER (INSIDE CASING) 7.740 8848 3353 HANGER BAKER MOD PZ HOOK HANGER OUTSIDE CASING 5.020 8854 3354 BUSHING CROSSOVER BUSHING 4.890 8855 3354 PUP 4.880 8907 3361 PACKER BAKER PAYZONE CASING PACKER 4.910 8973 3368 SEAL LEM D-SAND BAKER SEAL ASSEMBLY 3.900 9019 3372 XO 3.960 9020 3372 PUP 3.940 9054 3374 SLEEVE-C BAKER'HR' LINER SETTING SLEEVE 6.280 9062 3374 BUSHING CROSSOVER BUSHING 4.890 9093 3375 SHOE MULE SHOE 3.960 GeneraF Notes _ _ Date Note _ 5/24/2006 MULTI-LATERAL WELL: 1J-184 (B-SAND). 1J-184L1 (D-SAND) • Cori©t Phillips Time Log Summary LNelNrew YYeb RePOrYtng I Well Name: 1J-184 Job Type: RECOMPLETION - - - --- Time Logs ~Date___ From _To___ Dur S Depth E, De~th_ Phase Cody Subcode _T _ COM 11/28/2006 10:00 12:00 .2.00 0 0 COMPZ MOVE MOB P PJSM-Topic=moving rig. (Move rig from 1J-115 to 1J-184 Workover. 12:00 15:00 3.00 0 0 COMPZ MOVE MOB P PJSM=Continue move mud pump & mud tank complexes-move rig off 1 J-115 S of over 1 J-18.4 WO. 15:00 17:30 2.50 0 0 COMPZ MOVE MOB P Lay mats & set mud tanks, pumps, power & boiler complexes. Connect lines. 17:30 19:00 1.50 0 0 COMPZ MOVE MOB P Lay herculite, spot rock washer & pipe sheds, set stairs, landings & hand rails, Build berms. 19:00 21:00 2.00 0 0 COMPZ MOVE MOB P Connect power & supply lines (steam. around @ 19:30) Rig up mud flow & pump lines. Pits ready for fluid & take on OBM. Check gas alarms. (Rig accepted @ 21:00 11-28-2006 on 1 J-184. 21:00 23:00 2.00 0 0 COMPZ MOVE OTHR P Install rig cellar grating & rig up hard line from 4 1/2" tbg. X 9 5/8" annulus to choke-erect work scaffold lay out return hard line. 23:00 00:00 1.00 0 0 COMPZ RPCOh OTHR P Rig up lubricator & pull back pressure valve. 11/29/2006 00:00 00:30 0.50. 0 0 COMPZ RPCOh OTHR P Remove Bac Pressure Valve. Rig Down Lubricator. 00:30 02:00 1.50 0 0 COMPZ RPCOh RURD P Rig up to pump down tbg. & up annulus to tiger tanks thru choke manifold. 02:00 09:30 7.50 0 0 COMPZ RPCOA OTHR NP Off load from pits 440 bbls. contaminated mud MOBM (Stong Offensive odor) Loaded 583 bbls. new MOBM into its. 09:30 12:00 2.50 0 0 COMPZ RPCOh OTHR P Move tiger tanks, run 2" hard line from ri to tanks. 12:00 14:00 2.00 0 0 COMPZ RPCOh OTHR P PJSM-Topic=Well Kill. Continue rigging up hard line to tanks & pressure line with 120 psi air. Check for leaks & remove flow actuator valve. Ri u & test um line 1000 si. 14:00 15:00 1.00 0 0 COMPZ RPCOh OTHR P (SITP 1100 psi SICP 1050 psi.) Open tbg. w/ choke 1/8" open. Pump 5 bbls. @ 1.5 bpm 700 psi gas line pressure down stream of choke. Stop pump & shut in. Open choke 1/8" & vent w/ 500 psi gas line pressure down stream of choke.. (Made decision to tie into ad roduction header. l f I Time Logs Date Fam Te Dur S. De th E Depth Phase Codz_ Subco~,e _T__ COh1 11/29/2006 15:00 20:15 5.25 0 0 COMPZ RPCOh RURD P Tie into off well annulus. Hard line into pad production header with pad reps. Ri u ortable choke manifold. 20:15 20:30 0.25 0 0 COMPZ RPCOh SFTY P PJSM-Topic=Well kill procedure & hazards. 20:30 00:00 3.50 0 0 COMPZ RPCOh OTHR P Start pumping @ .5 bpm (ICP 1140 psi) Stage pump to 4 bpm @ 135 bbls. pumped (350 psi) @ 250 bbls. pumped. Reduced pump rate to 3 bpm @ 290 bbls. Pumped 600 bbls. mud. 170 si. 11/30/2006 00:00 00:1.5 0.25 0 0 COMPZ RPCOh SFTY P PJSM-Topic=Killing well 00:15 01:00 0.75 0 0 COMPZ RPCOh CIRC P Pumped total of 740 bbls. to production header. Final pump ressure 180 si. Annulus 10 si. 01:00 01:30 0.50 0 0 COMPZ RPCOh RURD P Blow down hard line & rig down same. 01:30 12:00 10.50 0 0 COMPZ RPCOh CIRC P Continue circ. thru choke manifold on rig. SICP 50 psi SITP 0. Pump @ 1 bpm. 259 bbls. crude returns. Max gas 2332 units. total loss this tower 368 bbls. 12:00 15:30 3.50 0 0 COMPZ RPCOh CIRC P Continue circ. OBM @ 1 BPM @ 130 psi. {8-10 bph loss on last hr. pumping): Total losses this tour. Total loss to hole 401 bbls. 15`30 16:00 0.50 0 0 COMPZ RPCOh OTHR P Monitor well (No Flow) 16:00 17:00 1.00 0 0 COMPZ RPCOh OTHR P Blow down choke & lines-Set BPV Rig down lines & Scaffold. 17:00 19:00 2.00 0 0 COMPZ RPCOh NUND P PJSM=Nipple down tree-check tbg. threads-install blank plug-nipple up bo e. 19:00 19:45 0.75 0 0 COMPZ RPCOh DHEQ P Make up valves & 5" testjoint & XO,S. Ri u test a ui ment. 19:45 20:00 0.25 0 0 COMPZ RPCOh SFTY P PJSM-Topic=Testing BOPE. 20:00 00:00 4.00 0 0 COMPZ RPCOh DHEQ NP Testing BOPE=Attempt first test (Leak) appears to be blank dart. rig down test manifold-pull test jt. & inspect blank dart. Replace same twice-still leakin . 12/01/2006 00:00 00:15 0.25 0 0 COMPZ RPCOh SFTY NP PJSM-Topic=testing BOPE. (Witness test waived b Jeff Jones AOGCC> 00:15 04:30 4.25 0 0 COMPZ RPCOh DHEQ NP Making multiple attempts to get VETCO test pop/et to seal. Nipple down bope-dress hanger threads-niplle up bope-remove bpv-install 2 way check valve & be in testin . ---- -- -- ~---- - _ s~s<g^ 2 of 9 • n Time Lomas Date From To D_ ur S_ .Depth _E. Depth Phase Code Subcode T C0~~1 12/01/2006 04:30 12:00 7.50 0 0 COMPZ RPCOh DHEC~ P Test bope (all tests @ 250 low & 3000 psi high) Test blind rams. pick up 5" testjt. & test annular-upper rams-all choke valves-manual-HCR choke & kill-test floor safety valve-ibop & accumulator test-upper hydraulic ibop-lay down 5" testjt. pick up 4 1/2" test 't. 12:00 13:00 1.00 0 0 COMPZ RPCOR DHEQ P PJSM-Continue testing bope w/4 1/2" testjt. Test annular-upper pipe rams-upper hyd. ibop-250-low & 3000 hi h. 13:00 14:00 1.00 0 0 COMPZ RPCOh DHEQ P Rig down test equipment-Jay down testjt. & XO,S-blow down top drive, choke & lines. Pump 2 bbls. @ 1/2 b m to fill annulus. 14:00 15:30 1.50 0 0 COMPZ RPCOh DHEQ P Rig up shooting flange-lubricator & rod extentions-pull 2 way check (Well Static) Rig down lubricator & shooting flan e. 15:30 17:30 2.00 8,775 8,745 COMPZ RPCO6 OTHR P Make up head pin-valve &circ. line on landing jt.-pick up landing jt. & make up in hanger-Back out lock down screws-pull tbg. & hanger to rig floor. (initial pick. up wt. 110k when hanger floor 88k. 17:30 00:00 -6.50 8,745 8,745 COMPZ RPCOA CIRC P Break circ. (pump 8 bbl. before returns) &circ @ 1.5 bpm 150 psi... Lost Total of 34.2 bbls. mud. 12/02/2006 00:00 06:30 6.50 8,745 0 COMPZ RPCOA PULD P Lay down tbg. hanger-poh w/ 4.5" tbg. Rack back in derrick (SLM) 94 stands-lay down 1 glm-1 sliding sleeve-1 jt. tbg.-1 pup jt, w/seal assembly. Calculate hole fill 40 bbls. Actual-56 bbls. 06:30 07:00 0.50 0 0 COMPZ RPCOh RURD P -Rig down csg. equipment. 07:00 07:45 0.75 0 0 COMPZ RPCOh OTHR P Set wear bushing-ctear& clean rig floor. 07:45 08:30 0.75 0 0 COMPZ RPCOh PULD P Pick up baker fishing tools.1nstall bell uides on to drive. 08:30 12:00 3.50 0 412 COMPZ RPCOh PULD P Make up BHA-bowen itco spear 7.689 grapple-extention-8" OD stop sub-xo-bumper jar-oil jar-12 6 3/4" dc,s & intensifier'ar: 12:00 12:15 0.25 412 412 COMPZ RPCOh SFTY P PJSM-Topic=Picking up 5"drill pipe. 12:15 18:15 6.00 412 8,740 COMPZ RPCOh PULD P R6H-Picking up & drifting 5"drill pipe to 8740'-break circ. @ 3 bpm 220 psi-P/U 140k S/O 80k ROT 102k TQ 8k. 18:15 19:00 0.75 8,740 8,756 COMPZ RPCOh OTHR P Wash in & engage. fish @ 8756'-stack 15k to confirm catch-with 20k overpull-S/O to 10k over-apply 11 rounds left hand torge to 13k-back off indicated & free 8k for ue. - _ _ _- _ - _ 3cf9 • • Time LocJs -_ --- _ ._ __ _ -- __ _ __ ------- -- - -- __ -- -- _ _ __~ Date_ FfORI To Dur_ S. Depth E De th Phase Code Subcode T COM -- - - --- - 12/02/2006 19:00 00:00 5.00 8,756 8,756 COMPZ RPCOh CIRC P Circ. complete circ. @ 2.25 bpm Max as 58 units 15 bbl. loss to hole. 12/03/2006 00:00 00:30 0.50 8,756 8,756 COMPZ RPCOh CIRC P Continue circ. @ 2.25 bpm-130 psi. 00:30 00:45 0.25 8,756 8,756 COMPZ RPCOh OTHR P Monitor well-pump pill. 00:45 05:00 4.25 8,756 0 COMPZ RPCOh TRIP P POH w/fish. P/U 140k. Hole fill est. 72.5 bbls. Actual 82.75 bbls. 05:00 06:00 1.00 0 0 COMPZ RPCOh PULD P Lay down fish-service breaks & lay downs ear. 06:00 07:45 1.75 0 60 COMPZ RPCOh PULD P Make up milling assembly.=8.5" Metal muncher shoe-8.375" washpipe extention-xo-bum er sub-oil 'ar. 07:45 12:00 4.25 60 7,468 COMPZ RPCOh TRIP P RIH w/ 4 stands dc,s-P/U accelerator 'ar-continue RIH w/ DP to 7468'. 12:00 12:30 0.50 7,468 8,763 COMPZ RPCOh TRIP P PJSM & continue RIH to 8706'-P/U 140k S/O 75k ROT 105k-TQ 8-9k-Wash & to ZXP 8763'. 12:30 00:00 11:50 8,763 8,766 COMPZ RPCOh OTHR P Milling over ZXP from 8763 to 8766'. 4 bpm 250 psi 100 rprn TQ 10-13k WOB 5-16k) Pump 25 bbl hi vis sweep @ 22:00 hrs. (Max gas 77 units Total fluid loss 75 bbls. 12/04/2006 00:00 00:45 0.75 8,766. COMPZ RPCOh OTHR P Continue to mill packer @ 8767, 100 rpm, torque = 10-12 k, 175 gpm, 290 si, 00:45 02:00 1.25 COMPZ RPCOh OWFF P Monitor well, pump slug and blow down to drive 02:00 09:30 7.50 COMPZ RPCOM1 TRIP P POOH, 09:30 10:30 1.00 COMPZ RPCOh OTHR P Clean outjunk baskets 10:30 11:00 0.50 COMPZ RPCOh OTHR P M/U new metal muncher mill shoe 11:00 11:15 0.25 COMPZ RPCOh OTHR P Clean rig floor 11:15 14:00 2.75_ COMPZ RPCOh TRIP P RIH to 3766' 14:00 14:15 0.25 COMPZ RPCOh SFTY P PJSM, crew change out 14:15 15:45 1.50 COMPZ RPCOA TRIP P Continue RIH w/milling assembly. Fill drill pipe @ 6130'. Break circulation @ 6705' and tag ZXP packer @ 8766'. P/U = 140k, S/O=75k, Rot=104k. Lost 10 bbl mud on tri in hole 15:45 00:00 8.25 COMPZ RPCOR OTHR P Mitl over ZXP packer from 8766' to 8768'. Lost total of 41 bbl mud 12/05/2006 00:00 12:00 12.00 8,768 8,769 COMPZ RPCOh OTHR P Milled on ZXP packer from 8,768' to 8,768.5', milled at 5-18K WOM, 60-90 rpm's, 3 bpm at 230 psi, 10-14K ft-Ibs torque, rot wt 104K, up wt 140K, do wt 80K, pumped 25 bbl hi vis sweep and had a small increase in the cuttings, have recovered approx. 25 Ibs of metal cuttings back and lost approx 30 bbls ' of mud to the hole. .'ag;: 4 of ~ Time Loys _ _ -_ _ Date From To __ Dur S _Depth E Depth. Phase Code Subcod° T COM __ 12/05/2006 12:00 16:45 4.75 8,769 8,769 COMPZ RPCOh OTHR P Cont to mill on ZXP packer at 8,768.5' with no progress, pumped 30 bbl hi vis sweep and had a small increase in the cuttings, lost approx 20 bbls of 8.2 ppg MOBM to the hole, decision was made to POOH and C/O mills 16:45 17:00 0.25 8,769 8,769 COMPZ RPCOh OWFF P Monitored well-static, pumped dry job 17:00. 20:45 3.75 8,769 440 COMPZ RPCOh TRIP P POOH from 8,768.5' to BHA #3 at 440' 20:45 21:15 0.50 440 40 COMPZ RPCOh TRIP P POOH from 440' to 40', LD Intensifier ~ars and stood back 6 1/4" Dc's 21:15 22:15 1.00 40 40 COMPZ RPCOh PULD P Cleaned out boot baskets and changed out Metal Muncher mills, #2 mill was 30% worn, recovered 7-9 thin pieces of metal from ZXP packer ranging from 1/4" to 1"wide by 8-10" long from boot baskets, hole took calc fill on tri out. 22:15 00:00 1.75 40 1,765 COMPZ RPCOh TRIP P RIH with shoe #3 on BHA #4'from 40' to 1,765', PU Intensifierjars and RIH with 6 1/4" DC's and remaining milling BHA #4 on 5" DP to 1,765' 12/06/2006 .00:00 02:45 2.75 1,765 8,700 COMPZ RPCOh TRIP P RIH with BHA #4 from 1,765' to 8,700', st wt up 140K, do wt 75K, lost approx 10 bbls mud while RIH 02:45 04:00 1.25 8,700 8,700 COMPZ RIGMN SVRG P Slip and cut 81' of drilling line and serviced to drive 04:00 04:15. 0.25 8,700 8,769 COMPZ RPCOh TRIP P RIH from 8,700' and washed over top of fish at 8,764' and tagged up at 8, 768.5' 04:15 18:30 14.25 8,769 8,773 COMPZ RPCOh OTHR P Fin milling over ZXP packer, milled from 8,768.5' to 8,772.5', (saw 12-18" of free travel after milling over slips on packer), milled at 5-12K WOM, 60 rpm's, 36 spm, 126 gpm at 220 psi, off btm torque 8K ft-Ibs, on btm 10-12K ft-Ibs, rot wt 104K, up wt 140K, do wt 75K, max gas was 204 units at btms up after RIH, lost approx 27 bbls of 8.2 ppg MOBM mud while milling, monitored well-static. 18:30 20:30 2.00 8,773 8,755 COMPZ RPCOA CIRC P Pumped 30 bbl hi vis sweep at 8,772' and PU to 8,755' to above TOF and fin circ sweep out of the hole, had 2% increase in cuttings from sweep, circ at 70 spm, 250 gpm at 500 psi, lost approx 7 bbls of MOBM while circ out the swee 20:30 20:45 0.25 . 8,755 8,755 COMPZ RPCOh OWFF P Monitored well-static and pumped dry .ob 20:45 00:00 3.25 8,755 2,340 COMPZ RPCOh TRIP P POOH with milling BHA #4 from 8,755' to 2,340' 12/07/2006 00:00 01:00 1.00 2,340 31' COMPZ RPCOh TRIP P POOH with BHA #4 from 2,340' to 31', LD Intensifier jars and stood back 4 stds of 6 1/4" DC's -- - -- - L___- _- __ P~r?~; a cif 9 C. Time Logs __ --- Date From To Dur S Depth E De th Phase Code Subcode T COM 12/07/2006 01:00 02:00 1.00 31 0 COMPZ RPCOh PULD P POOH LD jars, boot baskets and shoe,. cleaned out baskets and recovered 12 of 20 slip sections from ZXP pkr, mill was 10% worn, cleared ri floor 02:00 03:30 1.50 0 0 COMPZ RPCOh OTHR P Pulled wear bushing and flushed out stack, re-installed wear bushin 03:30 04:15 0.75 0 31 COMPZ RPCOh PULD P MU fishing BHA #5 RIH to 31', RIH with spear assembly with 6.22" ra le, bum er sub and oil 'ars 04:15 08:00 3.75 31 8,684 COMPZ RPCOh TRIP P RIH with BHA #5 from 31' to 8,684', RIH with 4 stds DC's, Intensifierjars and string magnet on 5" DP to 8,684', st wt u 137K, do wt 77K 08:00 08:15 0:25 8,684 8,713 COMPZ RPCOh OTHR P RIH from 8,684' and speared fish at 8,770' setting 10K wt down (TOF 8,764'), PU to 160K with no movement, PU to 175K and saw LEM snap out of hook, jars did not go off, PU LEM assembly to 8,71.3' to clear seals. of CSR, st wt u 140K. 08:15 10:15 2.00 8,713 8,713 COMPZ RPCOh CIRC P Circ btms up at 8,713', circ at 48 spm, 170 mat-210 si, max as 74 units 10:15 10:45 0.50 8,713 8,713 COMPZ RPC06 OWFF P Monitored well- static,. pumped dry job and blew down to drive 10:45 14:00 .3.25 8,713 437 COMPZ RPCOh TRIP P POOH from 8,713' to 43T 14:00 16:45 2.75 437 0 COMPZ RPCOh PULD.__ P LD BHA #5 POOH from 43T, LD Intensifierjars, 12-6 1/4" DC's, jars and string magnet, LD spear with ZXP pkr, then POOH LD LEM assembly. with seals, had full recovery of LEM, cleared ri floor 16:45 17:45 1.00 0 0 COMPZ RPCOh OTHR P Pulled wear bushing and flushed out the BOP stack 17:45 22:30 4.75 0 0 COMPZ WELC7 BOPE P RU and tested BOPE, tested rams, valves and choke manifold to 250 psi low and 3,000 psi high including annular, tested with both 4 1/2" tbg and 5" DP, tested the alarms, and koomey, had 3,000 psi on Koomey, 1,800 psi after functioning rams, took 35 seconds to build 200 psi, 3 min 5 sec. for full recovery. Note: Chuck Scheve W/AOGCC waived witnessing of test. 22:30 23:00 0.50 0 0 COMPZ RPCOh OTHR P Pulled test plug and installed wear bushin 23:00 00:00 1.00 0 0 COMPZ RPCOh OTHR P Cleared rig floor and RU 2 7/8" PAC DP handlin tools 12/08/2006 00:00 02:15 .2.25 0 268 COMPZ RPCOh PULD P MU CSR cleanout BHA #6 RIH to 268', MU 4 11/16" rev. circ jet basket & RIH with 7 jts of 2 7/8" PAC DP, 2-boot baskets bumper sub, oil jars, strin ma net and um out sub ~, Time Logs 'Date From To Dur S. De th E. Depth Phase _ Code Subcode T COM _ 12/08/2006 02:15 06:30 4.25 268 8,629 COMPZ RPGOh TRIP P RIH with BHA #6 from 268' to 8,629', PU 12 add. jts of 5" DP while RIH. (92 stds 5" DP in derrick) 06:30 09:00 2.50 8,629 9,005 COMPZ RPCOh TRIP P Dropped 9/16" ball and circ down to seat while RIH from 8,629' with ball on seat at 8,819', coht to RIH and rev. circ from 8,819' to 9,005', while RIH set down at 8,929', rotated 3 rds and cont RIH, sat down again at 8,939', rot. 3 rds and was able to RIH thru CSR to 9,005'„ st wt up 125K, do wt 76K, rot wt above CSR 100K. Note: Top of B lat ZXP pkr @ 8,933' and btm of CSR is 8,983' -09:00 13:00 4.00 9,005 8,819 COMPZ RPCOh CIRC P Pumped 30 bbl hi vis sweep and circ till sweep was 1,000' above rev. basket, circ at 4 bpm at 1,000 psi, dropped 2 1/4" ball and rod to open circ sub at top of BHA, ball did not seat,' PU to 8,819' to clear CSR and rotated DP at 20 rpm's and ball landed on seat, opened circ sub at 1,500 psi and stopped rotation, then increased pump rate to 600 gpm at 425 psi, pumped 2nd hi vis sweep and with both sweeps out of hole did not see much increase in cuttings and was clean at the shakers. 13:00 13:30 0.50 8,819 8,720 COMPZ RPCOh OWFF P POOH 1 std from 8,819' to 8,720' and monitored well-static, pumped dry job and blew down to drive. 13:30 16:30 3.00 8,720 268 COMPZ RPCOh TRIP P POOH from 8,720' to BHA #6 at 268', calc fill on trip out 67.5 bbls, actual fill 69 bbls. 16:30 20:30 4.00 268 0 COMPZ RPCOh PULD P POOH from 268' LD BHA #6, recovered 1 more slip segment on magnet with very little recovery in boot baskets, cleared rig floor. (13 of 20 sli se ments recovered) 20:30 20:45 0.25 0 0 COMPZ RPCOh SFTY P Held PJSM with rig crew, Baker and Sperry Sun reps on picking up and running of LEM assembly with MWD tool. 20:45 21:15 0.50 0 0 COMPZ RPCOti RURD P RU to run LEM assembly 21:15 00:00 2.75 0 220 COMPZ RPCOh PULD P MU "D" lat LEM and seal assembly RIH to 220', began to MU Sperry Sun's MWD tool 12/09/2006 00:00 00:30 0.50 220 255 COMPZ RPCOR PULD P Fin MU Sperry Sun's MWD tool to the "D" lat LEM and seal assembly then MU the ZXP hanger and packer assembly RIH to 255'. St wt up and down 40K 00:30 06:00 5.50 255 8,912 COMPZ RPCOh TRIP P RIH with LEM from 255' to 8,912', shallow tested MWD at 475' while RIH, st wt u 126K, do wt 77K Page 7 of 9 • i Time Log - s --- ,Date From To Dur -____ S De th E. Depth _ - Phase - Code - ---- Subcode --- T _ ___ -- - ---- - l COM 12/09/2006 06:00 07:15. 1.25 8,912 8,973 COMPZ RPCO _ h OTHR P RIH with seal assembly thru the hook with no problems, oriented hook and latched into same, orientation showed to be set at 29 deg rt of high side, (previous MWD showed 38 deg rt) PU and st wt up inside CSR was 128K, do wt 78K, snapped out of LEM at 145K, 19K over st wt, rotated string 180 deg, RIH and tagged top of LEM 1' high, rotated add. 180 deg then snapped back into LEM, orientation showed 26 deg rt of high side, snapped in and out of LEM twice with same results settin 25K wt down. 07:15 08:30 1.25 8,973 8,730 COMPZ RPCOh OTHR P Dropped 1 3/4" ball and pumped down to seat, pumped down at 3 bpm at 790 psi, slowed pump and with ball on seat pressured up to 3,000 psi to set hanger and packer, increased to 4,000 psi and released running tool, set top of ZXP packer at 8,730' with btm of seals at 8,973.55', no problems settin ZXP. St wt u 126K 08:30 08:45 0.25 8,730 8;730 COMPZ RPCOh DHEQ P Tested ZXP packer and annulus at 8,730` to 2,500 psi for 5 min, good test. 08:45 12:30 3.75 8,730 945 COMPZ RPCOti TRIP P POOH wet with running tool from 8,730 to 945' 12:30 13:30 1.00 945 945 COMPZ RPCOh OTHR T Repair skate 13:30 15:30 2.00 945 0 COMPZ RPCOh PULD P POOH from 945' LD 10 stds of 5" DP and Baker's running tool, cleared rig floor. 15:30 16:15 0.75 0 0 COMPZ RPCOh RURD P Pulled wear bushing and RU to run 4 1/2" com letion 16:15 16:30 0.25 0 0 COMPZ RPCOti SFTY P Held PJSM with rig crew, Baker rep and tong operator on running of 4 1/2" com letion 16:30 00:00 7.50 0 6,925 COMPZ RPCOh RCST P RIH with 4 1/2" completion assembly to 6,925' per well plan, RIH with seal assembly, open CMD sliding sleeve on 4 1/2", 12.6#, L-8Q IBTM tbg, MU KGB-2 GLM with dumm while RIH. 12/10/2006 00:00 00:45 0.75 6,925 8,700 COMPZ RPCOh RCST P Cont to RIH with 4 1/2" completion from 6,925' to 8,700', st wt up 87K, do wt 60K, blk wt 35K 00:45 02:00 1.25 8,700 8,767 COMPZ RPCOh HOSO P RIH from 8700' and tagged up on no go, PU and spaced out tbg, made up Vetco Gray hanger and landed 4 1/2", 12.6#, L-80 IBTM tb at 8,767. 02:00 03:00 .1.00 8,767 8,767 COMPZ RPCOh DHEQ P RILDS, tested upper and lower seals on hanger to 5,000 psi for10 min and ck'd ok 03:00 04:00 1.00 8,767 8,767 COMPZ RPCOh NUND P ND BOP stack 04:00 06:15 2.25. 8,767 8,767 COMPZ RPCOh NUND P NU tree and tested tree and void to 5,000 si and ck'd ok. ulled TWC ';a'~ B of 9 • • I Tirne Logs - - - -- __ ---_ __ _ ___ - -- --__ __ l Date From To Dur S. De tlp ~ E. Depth Phase Code___ Subcode T _ _ COM J 12/10/2006 06:15 08:00 1.75 8,767 8,767 COMPZ RPCOh RURD P RU mousehole to LD 5" DP and RU little red to displace hole over to diesel, held PJSM on displacing hole over. 08:00 13:30 5.50 8,767 8,767 COMPZ RPCOh FRZP P Little Red displaced hole over from 8.3 ppg MOBM to diesel thru open sliding sleeve at 8,700', ave 4 bpm at 600 psi, pumped 648 bbls diesel and recovered 590 bbls of MOBM, calc disp. was 621 bbls. SIM-OP, LD 87 jts of 5" DP out of the derrick thru the mousehole and cleaning mud pits while displacing hole. 13:30 14:15 0.75 8,767 8,767 COMPZ RPCOh NUND P RU lubricator and installed BPV, secured well and RDscaffoldin 14:15 18:00 3.75 0 0 COMPZ RPCOh PULD P Fin LD 5" DP out of the derrick thru the mousehole, LD an add. 159 jts, LD a total of 246 'ts. 18:00 20:00 2.00. 0 0 COMPZ RPCOh OTHR P Slip and cut 72' of drlg line, cleaned and ins acted saver sub and ck'd ok 20:00 21:30 1.50 0 0 COMPZ RPCOti OTHR P Changed out lower set of pipe rams on BOP stack from 5" to 7 5/8" 21:30 00:00 2.50 0 0 COMPZ RPCOh OTHR P .Fin cleaning pollution pan, rig floor and mud pits. RELEASED RIG @ 24:00 hrs 12/10/06 P~c~ 9 ~^ t g Re: Permission to pre produce 1J-184 PTD # 206-045 & 206-044 Subject: Re: Pernlission to pre produce IJ-184 PTD # 20fi-045 & 206-044 From: Thomas Maunder <tom_inaunder@admin.state.ak.us% Date: Fri, 22 Dec 2006 08:36:12 -0900 ~Co: A~ S K Problem ~`~~ ell 5 ups ~ -~~ l h l i s"u cuno~ ~>phillips.com> Perry, There are no issues that I know of. Good luck with the operations. Tom Maunder, PE AOGCC NSK Problem Well Supv wrote, On 12/22/2006 8:33 AM: Tam, It is a sliding sleeve that has been shifted to the open position. There is no device set in a profile like a commingling sleeve in an AVA. You are correct with regard to the lack of GL mandrels. The well bore was completed to be an injector after iYs short pre production period. There are no inherent annulus communication issues with the well due to leaks or mechanical failures. e performed an MITIA to 2500 psi prior to opening the sleeve. I agree with the splitting of hairs regarding gas lifting, There is a subtle difference between the sleeve and a gas lift valve, assuming the GLV checks are holding and I wanted to make sure the state didn't have any issues with temporarily using the sliding sleeve to assist in clean up. Perry From: Thomas Maunder [mailto:tom maunder@admin.state.ak.us] Sent: Friday, December 22, 2006 8:00 AM To: NSK Problem Well Supv Subject: Re: Permission to pre produce iJ-184 PTD # 206-045 & 206-044 Hi Perry, This gets down to splitting hairs. In order to gas lift you need some sort of communication from the IA to the tubing. GLMs are not ordinarily run in injection wells so your only option is to use the sliding sleeve. Normal flow should be from the IA via the sleeve into the tubing. If the well were to SI, I wouldn't think that flow would reverse. Is the sleeve just opened, or is there some device set in the profile? Look forward to your reply. Tom Maunder, PE AOGCC NSK Problem Well Supv wrote, On 12/22/2006 7:41 AM: Tom, 1 of ~. 12/26/2006 7:37 AM Re: Permission to pre produce 1J-184 PTD # 206-045 & 206-044 I was concerned with gas lifting the well via the open CMD and thought that we would need verbal permission for that aspect of the operation since we haue T X IA communication with the sleeve open during the clean up, Am I mistaken with regard to gas lift via the sleeve? Thanks Perry From: Thomas Maunder [mailto;tom maunder@admin.state.ak.us] Sent: Monday, December 18, 2006 4:35 PM To: NSK Problem Well Supv Cc:jim_regc~czadmin.state.ak.us Subject: Re: Permission to pre produce 1J-184 PTD # 206-045 & 206-044 Perry, 1J-184 and -184L1 are completed with 1-oil status. As such, they are production well(s) so you do not need permission to continue to produce them. You are correct that sundries will need to be submitted to convert the well(s) from producers to injectors. Thanks for the notice regarding the operations. Call or message with any questions. Tom Maunder, PE AOGCC NSK Problem Well Supv wrote, On 12/18/2006 4:18 PM: Tom, ConocoPhillips would like to request approval to pre produce well 1 J-184 PTD # 206-045 & 206-044 using gas lift through an open sliding sleeve at 8726 MD - 3333 TVD for approximately 90 days with option to extend after which a 10-403 will be submitted to convert 1J-184 to an injection well. CPAI originally submitted a similar request on 6/2/06 that was granted on 6/7/06. An attempt was made to flow both laterals on 8/27/06. It was determined that the hook hanger and Lateral Entry Module, LEM, was mistakenly set 180 degrees out of phase with the open hole preventing clean up and production from the isolated lateral. The well has since been worked over and the LEM reinstalled for entry into the lateral leg. We would like to reattempt to pre produce at this time. The West Sak PE will submit the 10-403 to convert to injection once the pre production diagnostics are finished. Approximate total production time will be 60 to 90 days. Please let me know if you have any questions or concerns. Sincerely, Perry Klein Problem Well Supervisor office (907) 659-7224 Cell (907) 943-1244 Pager (907) 659-7000 x909 2 of ~.. 12/26/2006 7:37 AM Re: Permission to pre produce 1J-184 PTD # 206-045 & 206-044 Subject: Re: Permission to pre produce 1J-184 PTD # ?U6-045 K ?06-044 From: Thomas Maunder <tom_maunder@,admin.state.ak.us> Date: Mon, 18 Dcc ?0OE~ 16:34:49 -0900 1'0: ti~SK ProblelT~ «'"cll Sups ~-n1617~conocophillips.com== C~': ~1T11 CE:~:~`(CLjL1lIllllil.Sl:lll.111;.L1 Perry, 1J-184 and -184L1 are completed with 1-oil status. As such, they are production well(s) so you do not need permission to continue to produce them. You are correct that sundries will need to be submitted to convert the well(s) from producers to injectors. Thanks for the notice regarding the operations. Call or message with any questions. Tom Maunder, PE AOGCC NSK Problem Well Supv wrote, On 12/18/2006 4:18 PM: Tom, ConocoPhillips would like to request approval to pre produce well 1J-184 PTD # 206-045 & 206-044 using gas lift through an open sliding sleeve at 8726 MD - 3333 TVD for approximately 90 days with option to extend after which a 10-403 will be submitted to convert 1J-184 to an injection well. CPAI originally submitted a similar request on 6/2/06 that was granted on 6/7/06. An attempt was made to flow both laterals on 8/27/06. It was determined that the hook hanger and Lateral Entry Module, LEM, was mistakenly set 180 degrees out of phase with the open hole preventing clean up and production from the isolated lateral. The well has since been worked over and the LEM reinstalled for entry into the lateral leg. We would like to reattempt to pre produce at this time. The West Sak PE will submit the 10-403 to convert to injection once the pre production diagnostics are finished. Approximate total production time will be 60 to 90 days. Please let me know if you have any questions or concerns. Sincerely, Perry Klein Problem Well Supervisor office (907) 659-7224 Cell (907) 943-1244 Pager (907) 659-7000 x909 n1617(r.~conocopillips.com «1 J-184.pdf» (~S ~~~~ ~~ Q~ ~~o 1 of 1 4/25/2007 10:47 AM FRANK H. MURKOWSKI, GOVERNOR 333 W. T" AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Randy Thomas CPAI Drilling Team Leader ConocoPhillips Alaska Inc. P.O. Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, West Sak Oil Pool, Well name: 1J-184L1 Sundry Number: 306-370 Dear Mr. Thomas: 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. n --~- DATED this `~ day of November, 2006 Encl. ~ ~~ _ STATE OF ALASKA Ll~t ~ ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVAL 20 AAC 25.28n 1. Type of Request: Abandon ^ Suspend ^ Operational Shutdown ^ Pertorate ^ Waiver ^ Other ^ Altercasing ^ Repair well ^~ - Plug Pertorations ^ Stimulate ^ Time Extension ^ Change approved program ^ Pull Tubing ^~ Pertorate New Pool ^ Re-enter Suspended Well ^ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development Q Exploratory ^ 206-045 ` 3. Address: Stratigraphic ^ Service ^ 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-029-23305-60 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-184L1 9. Property Designation: 10. KB Elevation (ft): 11. Field/Pool(s): ADL 25662, 380058 RKB 28' 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): 16692' 3358' 16546' - 3336' Casing Length Size MD ND Burst Collapse Conductor 80~ 20" 108' 108' Surface 3949' 13.375" 3977' 2238' Intermediate 9247' 9-5/8" g275' 3423' Liner 7495' 5.5" 16548' 3373' Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): slotter liner from 9068'-16508' 3374'-3331' tubing in main wellbore Packers and SSSV Type: Packers and SSSV MD (ft) HRD' ZXP liner top pkr @ 8933' Camco 'DB-06' nipple @ Ogg' 13. Attachments: Description Summary of Proposal ~ 14. Well Class after proposed work: Detailed Operations Program ^ BOP Sketch ^ Exploratory ^ Development Q Service ^ 15. Estimated Date for 16. Well Status after proposed work: Commencing Operations: November 22, Zoos 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: Ty Kemner @ 265-6480 Printed Name Randy Thomas Title: CPAI Drilling Team Leader Signature l --~ Phone 265-6830 Date 1 l /~(y~Ob Commission Use Onl Sundry Number: Conditions of approval: Notify Commission so that a representative may witness ~ - 3 alb Plug Integrity ^ BOP Test 9~ Mechanical Integrity Test ^ Location Clearance ^ Other: ~d~~ ~7` V"~`~v~~ V~-tvV"~._~~ ~~1 ~,~~ "T- 5~ Subsequent Form Required: L>~.-.~ q ~~ I ~ t A roved b : ~ APPROVED BY ~~~~~ ~„ ~~ pp y S I THE COMMISSION Date: rorm 1u-4u3 Kevisetl 0612006 V ' Submit in Du licate ~ ~/~~6 LJ FRANK H. MURKOWSK/, GOVERNOR Robert Buchholz Production Engineering Technician ConocoPhillips Alaska Inc. PO Box 100360 Anchorage, AK 99510 • 333 W. 7"' AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Re: Kuparuk River Field, West Sak Oil Pool, 1J-184L 1 Sundry Number: 306-316 Dear Mr. Buchholz: 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 (pagerl. 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 . Foerster Commissioner DATED this day of September, 2006 Encl. • ConocoPhillips September 11, 2006 To: Tom Maunder, P.E. Senior Petroleum Engineer State of Alaska, Oil & Gas Conservation Commission 33 W. 7th Ave. Ste. 100 Anchorage, AK 99501 Subject: Sundry Applications for Proposed Change of Well Class Robert Buchholz /Robert Christensen Production Engineering Tech. Greater Kuparuk Unit , NSK-69 PO Box 196105 Anchorage, AK 99519-6105 Phone: (907) 659-7535 Fax: 659-7314 ~~~ ~~~, _ ~~ _~. m'' _ ~ ~n ConocoPhillips Alaska, Inc. submits the attached sundry applications for proposed change of well class on Kuparuk well 1 Q-02B and 1 Q-02L1. ConocoPhillips Alaska, Inc. submits the attached sundry applications for proposed change of well class on West Sak wells 1J-127, 1J-127L1, 1J-127L2, 1J-184, 1J-184L1. If you have any questions regarding this matter, please contact myself or Robert Christensen at 659-7535. Robert W. Buchholz Attachments: 10-403 Forms '~ ~1~3/~ RECEIVE TATE F ALASKA ~ •~''~ S O ~,-~ ~p ALASKA OIL AND GAS CONSERVATION COMMISSION S E P 1 2 20Q~~~~ APPLICATION FOR SUNDRY APPROVAL Alaska Oil & Gas Cons. C"olmmission 20 AAC 25.280 Onrhnrana 1. Type of Request: Abandon ^ Suspend ^ Operational Shutdown ^ Perforate ^ Waiver ^ Other Q Alter casing ^ Repair well ^ Plug Perforations ^ Stimulate ^ Time Extension ^ C~t4 6 l ~ Change approved program ^ Pull Tubing ^ Perforate New Pool ^ C. 4fs !J&I Re-enter Suspended Well ^ rj•~8 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development 0 Exploratory ^ 206-045 " 3. Address:. Stratigraphic ~ Service ^ 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-029-23305-60 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 ^~ 1J-184L1 9. Property Designation: 10. KB Elevation (ft): 11. Field/Pool(s): ADL 25662, 380058 RKB 0' Kuparuk River Field /West Sak Oil Pool 12. PRESENT WELL CONDITION SUMMARY Total depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 16692' - 3358' 16546' 3336' ' Casing Length Size MD TVD Burst Collapse CONDUCTOR 108' 20" 108' 108' SURFACE 3977' 13-3/8" 3977' 2239' INTERMEDIATE 8275' 9-5/8" g275' 3424' WINDOW L1 1' 9-5/8" 8849' 3354' 7495' 5-1 /2" 16548' 3336' Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): Alternating Slotted/Solid Pipe 9068' - 16508' 3375' - 3331 4-1/2" L-80 8793' Packers and SSSV Type: Packers and SSSV MD (ft) no packer SSSV= NIP SSSV= 498' 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: October 4, 2006 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: Bob Christensen /Bob Buchholz Printed Name Robert D. Christensen Title: Production Engineering Technician Signature Phone 659-7535 Date ~ ~/~ Commission Us nl Sundry Number: Conditions of approval: Notify Commission so that a representative may witness ~ ' 3~ Plug Integrity ^ BOP Test ^ Mechanical Integrity Test ~ Location Clearance ^ Other. R~ S ~F~ s EP ~ ~ 2006 Subsequent Form Required: y~y APPROVED BY Approved by O MISSIONER THE COMMISSION Date: -~l3 ^' Form 10-403 Rey~(sed 06/2006 U ~ ~ (~ ~ !Y !'1 L ubmit in Dup'cate • 1J-184L1 DESCRIPTION SUMMARY OF PROPOSAL ConocoPhillips Alaska Inc. requests approval to begin Water Injection service in West Sak Dual-lateral Well 1 J-184L1. This well was pre-produced fora 93 day period in order to recover oil based drilling fluids prior to putting the well on injection. Lateral 1 J-184L1 will provide pressure support for the West Sak D sands. "~ The 13-3/8" Surface. casing (3977' and / 2239' tvd) was cemented with 740 sx AS .Cite followed by 228 sx DeepCrete. The 9-5/8" Intermediate casing (9275' and / 3424' tvd) was cemented with 589 sx DeepCrete. The injection tubing/casing annulus is isolated via SLZXP 7" x 9-5/8" Liner Top Packer with 190-47 Casing Sealbore Receptacle located @ 8761' and / 3339' tvd. This well also contains a Lower B sand 7" x 9-5/8" ZXP Liner Top Packer w / H RD located @ 8933' and / 3369' tvd. The top of West Sak D sand was found at 8825' and / 3350' tvd. The top of West Sak B sand was found at 9255' and / 3421' tvd. 1J-184L1 APL TUBING SSSV Type: (0-8793, OD:4.500, ID:3.958) ____;_.__ Annular Fluid: LOCATOR (x775-877s, OD:5.190) BUSHING (a7az-a7sa, OD:7.670) BUSHING (8803-8804, OD:6.020) PUP (88048973, OD:5.200) TERMEDIATE (0.9275, OD:9.625, wt:ao.oo) PUP (8855-9019, OD:5.500) xo (sots-solo, OD:5.500) SLEEVE-C (90549062, OD:8.280) Pert (9068-16508) ''' ~ '~:- r I{ -l # KRU 1J-184L1 Well T e: PROD An le TS: de Orig 5/25/2006 Angle @ TD: 81 deg @ 16692 Com letion: Last W/O: Rev Reason: PULL SLEEVE Reference L : 28' RKB Ref Lo Date: Last U date: 8/31/2006 Last Ta TD: 16692 ftKB ~ Last Tag Date: ~ Max Hole Angle: 94 deg @ 15615 ~ Casing Strfhg -ALL STRINGS Descri lion Size To Bottom ND Wt Grade Thread CONDUCTOR 20.000 0 108 108 94.00 H-40 WELDED SURFACE 13.375 0 3977 2239 68.00 L-80 BTC INTERMEDIATE 9.625 0 9275 3374 40.00 L-80 BTCM WINDOW L1 9.625 8848 8849 3353 0.00 B-SAND SLOTTED LINER 5.500 9053 16548 3336 15.50 L-80 HYD 521 BTCM Tubin Strin ''- TUBING _ ___ _-_-_ .--_ _ - Size To Bottom ND Wt Grade Thread 4.500 _ _ 0 _ _ _ 3345 12.60 i L- 80~ IBTM 8793 1 Perforations Summar _- _ __ Interval ND --- Zone Status Ft SPF Date T e Comment 9068 - 16508 3374 - 3331 WS D,WS 7440 32 5/20/2006 SLOTS Alternating slots/solid pipe _ D,WS C __ Ges Lift MandrelsNalves St MD j ND M - an Type V Mfr V eypT V OD Latch _ _ Port TRO ~ l _ Mfr ~ m R ~_C nt~ 1 2036 1740 CAMCO KBG 2 GLV 1 0 BK_-5 0.188 1460 6/6/2006 I 'Uther~ lugs, a ui ., eta) -COMPLETION - - _ De th ND T Descri lion ID 23 23 HANGER VETCO GRAY TUBING HANGER 4.500 8726 3333 SLEEVE-O BAKER 4.5" CMD SLIDING SLEEVE w/CAMCO 3.81" 'DB' PROFILE - OPEN 3.812 8775 3342 LOCATOR BAKER LOCATOR **NOTE: GBH-22 LOCATOR SPACED OUT 4.T ABOVE FULLY INSERTED** 3.980 8776 3342 SEAL BAKER SBE SEAL ASSEMBLY 3.880 8791 3344 SHOE MULE SHOE _ 3.958 !Other lu s, a ui ., etc.) - D-SAND LINER &LEM JEWE_L_ RY _ De th ND T ~ Descri lion ID 8761 3339 PACKER LEM D-SAND SL ZXP LINER TOP PACKER 7.500 8782 3343 BUSHING LEM D-SAND CROSSOVER BUSHING 4.890 8784 3343 SBR LEM D-SAND 190-47 CASING SEAL BORE RECEPTACLE 4.750 8803 3346 BUSHING LEM D-SAND CROSSOVER BUSHING 3.930 3.930 3.688 7.740 5.020 8973 3368 SEAL LEM D-SAND BAKER SEAL ASSEMBLY 3.900 9019 3372 XO 3.960 9020 3372 PUP 3.940 9054 3374 SLEEVE-C BAKER 'HR' LINER SETTING SLEEVE 6.280 9062 3374 BUSHING CROSSOVER BUSHING 4.890 9093 Genetal Date _3375 SHOE MULE SHOE - - Notes _ - - - - -- - _ _ _ --- - Note 3.960 - 5/24/2006 MULTI-LATERAL WELL: 1J-184 (B-SAND), 1J-184L1 (D-SAND) TREE: VETCO GRAY /HORIZONTAL / 4-1/16" 5M TREE CAP CONNECTION: 9" OTIS • • I~'C:iA3~ICAL INTEGRITY RPORT w =..G ..S_,~~..I. N rr LL JAT ~ TD : ?~.. 1'VD ; ?BTD : ?ID -~VD using °~~~~-, Shoe. ~~~~t-m ~TVD; DV. -?~ ~~ -V~i __:~e= . Shoe. `~ T~dT ; =CP . ~.~ '~iB =~oi~v _Paciser ~'~~'~ TVD; Set at =o1e S_re __~J_ and ; Perfs to ~~~:.c..r~?~=C~ `., _iYTEGR.TTy _ a a~~r # t ~nnuius Press Test: :? ~ S nin :;0 min Cor~ents r J 7 ~~ ,. r. '~' CHA NIC? ~ , INTEGR?TY -PART # Z Cement Voltmmes :- Amt. Liner Cr,t -rol to cover oers ~ `3~ t ~~v°~~~ ~~~~ OPER ~ FZELD ~~ ~~-.. ~~-.~~ ~ ~)~~ h ALL N IJMB E R ~. ~ _ ~, ZS ~ ~-'.!~ ~~ ~~~~~~ C s Q~ ~~ S-F D V -=:eoretical TOC ~ ~~Z~-,1L.S \ ~C ~= ~bl~c~-~~ . 1~ C ~s ~~ ~:~" ~^~'~~ ~ ~~} Cement Band Log (Yes ar No) ~ ~ In AOGCC File `~/~~'~~ .~- C3L Evaluation, gone aoove perfs "' ~, ~- Production Log: Type COI~CLJS?ONS : ?art #1: ?art 12: ~~ ~S Z+`~C-4.~~ Evaluation ~~ ~~ j - ~~,ttv c STATE OF ALASKA ~ JUL 1 2 2006 ALASKA OIL AND GAS CONSERVATION COMMISSION ons ~~rtmission WELL COMPLETION OR RECOMPLETION REPfi`fi ~~~,G 1a. Well Status: Oil ^ Gas Plugged Abandoned ^ Suspended WAG ^ 20AAC 25.105 20AAC 25.110 GINJ ^ WINJ ^ WDSPL ^ No. ofCompletions_ Other_ 1 b. Well Class: Development ^/ Exploratory ^ Service ^ StratigraphicTest^ 2. Operator Name: ConocoPhillips Alaska, Inc. 5. Date Comp., Susp., or Aband.: May 25, 2006 12. Permit to Drill Number: 206-045 / 3. Address: P. O. Box 100360, Anchorage, AK 99510-0360 6. Date Spudded: I~.~~ ~~~ Z~L 13. API Number: 50-029-23305-60 4a. Location of Well (Governmental Section): Surface: 1530' FSL, 2424' FEL, Sec. 35, T11N, R10E, UM 7. Date TD Reached: ? • Z/ •OL May 18, 2006 14. Well Name and Number: 1J-184L1 ' At Top Productive Horizon: 537' FNL, 2323' FWL, Sec. 11, T10N, R10E, UM 8. KB Elevation (ft): 28' RKB 15. Field/Pool(s): Kuparuk River Field Total Depth: 2170' FSL, 2430' FWL, Sec. 14, T10N, R10E, UM 9. Plug Back Depth (MD + ND): 16546' MD ! 3336' TVD West Sak Oil Pool 4b. Location of Well (State Base Plane Coordinates): Surface: x- 558789 y- 5945342 Zone- 4 10. Total Depth (MD + ND): 16692' MD / 3358' ND 16. Property Designation: ADL 25662, 380058 TPI: x- 558321 y- 5937992 Zone- 4 Total Depth: x- 558498 - 5930141 Zone- 4 11. Depth where SSSV set: nipple @ 498' 17. Land Use Permit: ALK 2177 & 4604 18. Directional Survey: Yes Q No~ 19. Water Depth, if Offshore: N/A feet MSL 20. Thickness of Permafrost: 3977' MD 21. Logs Run: ~- W W $$2t~!'ryf~ f 3~5-~'7"/,~y GR/Res, Dens/Neu /1D T• 2/•oIG 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" 62.6# H-40 28' 108' 28' 108' 42" 370 sx AS 1 13.375" 68# L-80 28' 3977' 28' 2238' 16" 74o sx AS Lite, 228 sx DeepCrete 9-5/8" 40# L-80 28' 9275' 28' 3423' 12.25" 589 sx DeepCRETE 5.5" 15.5# L-80 9053' 16548' 3373' 3336' 8.5" slotted liner 23. Perforations open to Production (MD + ND of Top and Bottom 24. TUBING RECORD Interval, Size and Number; if none, state "none"): SIZE DEPTH SET (MD) PACKER SET tubing in main wellbore 8794' 8933' slotted liner from 9068'-16508' MD 3374' - 3331' TVD 25. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED n/a 26. PRODUCTION TEST Date First Production June 8, 2006 Method of Operation (Flowing, gas lift, etc.) oil producer Date of Test 6/13/2006 Hours Tested 12 hours Production for Test Period --> OIL-BBL 385 GAS-MCF 695 WATER-BBL 35 CHOKE SIZE 15 Bean GAS-OIL RATIO 1924 Flow Tubing press. 393 psi Casing Pressure 986 Calculated 24-Hour Rate -> OIL-BBL 731 GAS-MCF 1406 WATER-BBL 69 OIL GRAVITY -API (corr) not available 27. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water (attach separate sheet, if necessary). Submit core chips; if none, state "none". `"- . ~)-e 1,,:: , x NONE RBDMS ~F~, JUL 2 4 1006 ~ ~~` j` ~~ Form 10-407 Revised 12/2003 ORIGINAL CONTINUED ON REVERSE ?. 2/•OG i~ i~ 2s. 2s. GEOLOGIC MARKERS FORMATION TESTS NAME MD TVD Include and briefly summarize test results. List intervals tested, and attach detailed supporting data as necessary. If no tests were conducted, state "None". 1J-184L1 West Sak D 8825' 3350' ' Base West Sak D 16500' 3330' N/A 30. LIST OF ATTACHMENTS Summary of Daily Operations, Directional Survey 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Pat Reilly @ 265-6048 Printed Na Rand Thomas Title: Greater Kuaaruk Area Drilling Team Leader 7 ~f ®l0 ~ - ..~--- Phone 2 ~ ~- 6~ ~~ Date Signature ~ INSTRUCTIONS Prepared by Sharon Allsup-Drake General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1a: Classification of Service wells: Gas injection, water injection, Water-Alternating-Gas Injection, salt water disposal, water supply for injection, observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 4b: TPI (Top of Producing Interval). Item 8: the Kelly Bushing elevation in feet abour mean low low water. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). Item 20: True vertical thickness. Item 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, Other (explain). Item 27: If no cores taken. indicate "none". Item 29: List all test information. If none, state "None". Form 10-407 Revised 12/2003 ~onoc ~h~ips Time Log Summary Welhiew t~'/eb ReDa+'XJng -------- -- _- ---- Time Logs - -_ --- -- Date FrorT~ To Dur S. Depth E_ Depth Phase Code Subcode T_ COM -- - - - -- 04/23/2006 00:00 03:00 3.00 MIRU RIGMN RURD P Prep'd rig for move. Blew down water and glycol lines. Disconnected service lines. Sucked out cellar on 1J-152. 03:00 05:00 2.00 MIRU RIGMN ' RURD P Hled PJSM. Staged pipe shed (2 pieces), rock washer, boiler, motor, um ,and it com lexes down ad. 05:00 07:00 2.00 MIRU RIGMN ' RURD P Pulled sub off of well 1J-152 and s otted over 1J-184. 07:00 09:00 2.00 MIRU RIGMN RURD P Spotted pits, pump, and motor com lexes. 09:00 09:30 0.50 MIRU RIGMN ' RURD P Spotted rock washer and waste water tank. 09:30 11:00 1.50 MIRU RIGMN ' RURD P Spotted pipe shed (2 pieces). 1100 12:00 1.00 MIRU RIGMN' RURD P Worked on completing rig acceptance checklist. Hooked up all service fines and electrical lines. Turned on steam, and set up berm @ rock washer. Connected skate rail. Rig acceptance checklist complete. Ri acce ted 1200hrs 4/23/2006. 12:00 15:00 3.00 MIRU RIGMN RURD P Held PJSM. Nippled up 20" riser to diverter system and secured. Installed 4" valves in conductor. 15:00 17:00 2.00 SURFA DRILL OTHR P Loaded 5" DP in shed and strapped. P/U 5" tools and safet valves. 17:00 00:00 7.00 SURFA DRILL PULD P Held PJSM. P/U and drifted 5" DP (applying steam as needed) and S/B 195 'ts total. Total len th=6,021.21'. 04/24/2006 00:00 01:30 1.50 SURFA DRILL PULD P PlU 17 jts HWDP, jars, 1 std NMFDCs. R/B in derrick. 01:30 02:00 0.50 SURFA WELC7 BOPE P Performed diverter test: Initiail Pressure=3000psi, Pressure after Closure=1800psi. 43 sec to 200 psi increase, 3min 22sec to 3000psi. Back-up Nitrogen Bottles (5) @ 2200 si. 02:00 04:00 2.00 SURFA RIGMN SVRG P C/O saver sub. 04:00 05:00 1.00 SURFA RIGMN SVRG P Held PJSM. Slipped and cut drilling line. 05:00 05:30 0.50 SURFA DRILL DHEQ P Flood conductor and check for leaks. 05:30 07:30 2.00 SURFA DRILL PULD P M/U BHA and test mud lines to 3000 si. 07:30 12:00 4.50 108 200 SURFA DRILL DRLG P Spudded well @ 0730hrs. Drilled ice from 80' to 108' MD. Drilled ahead to 200. ART=3.70hrs Jar hrs=39.97. Page 1 of 23 --- ~ Time Logs Date Frond To Dur 5. ~e~th E Depth_ Phase Code Subcode T OM 04/24/2006 12:00 12:30 0.50 200 215 SURFA DRILL DRLG P Drilled from 200' to 215' MD. ART=0.5 12:30 14:30 2.00 0 156 SURFA DRILL PULD P POOH. P/U MWD and PD sub. C/O stab on motor and set motor @ 1.83?. P/U UBHO sub and orient. RIH w/ NMFDCs fo 156' MD. 14:30 15:00 0.50 156 215 SURFA DRILL OTHR P Run wireline gyro surrey @ 75' MD (0.21? w/ 262.59? azimuth) and wash to 215' MD. 15:00 00:00 9.00 215 525 SURFA DRILL DDRL P Drilled 16" surface hole from 215' to 525' MD taking gyro surveys @ 90' intervals ART=1.23 AST=5.87 TDT=7.10 Jar hrs=47.07 PUW=67K SOW=67K ROT=67K TQon/off=2K/1 K Max Gas=28 Units 04/25/2006 00:00. 12:00 12.00 525 1,425 SURFA DRILL DRLG P Drilled 16" surface hole from 525' to 1,425' MD/ 1,340' TVD. ART=1.36, AST=7.69, ADT=9.05. PU=84K, S0=80K, ROT=84K, TQon 2-7K, TQoff=1-4K, Max C~as=42 BTU, Jar Hrs=56.12 12:00 22:30 10.50 1,425 2,466 SURFA DRILL DRLG P PJSM: Drilled from 1,425' to 2,466' MD, 1879" TVD. ART=1.6, AST=5.45, ADT=7.3~:~U=94K, S0=70K, ROT=82K, TQon=6-7K, TQoff=3-4K, Max Gas=562. BTU at 2410'. Decreased to +/-100 BTU within the next 40'. Jar hrs=63.46. 22:30 23:00 0.50 2,466 2,466 SURFA DRILL REAM P Back reamed up one stand at TD. Tight and slightly packing off from 2466' to 2370'. 23:00 00:00 1.00 2,466 1,915 SURFA DRILL REAM P BROOH from 2,466 to 1,915' MD at 650 gpm, 40 rpm, 15-20 fpm. Watchin careful) for ackin off. 04/26/2006 00:00 02:45 2.75 1,915 200 SURFA DRILL REAM P Continue to BROOH from 1915' to 200' MD. 1800 psi, 153 spm, 45 rpm, TQ= 2-10K. 02:45 04:00 1.25 200 0 SURFA DRILL TRIP P POOH on elevators to surface with no problems. Change out pressure drop sub and turn motor to 1.15 de rees. 04:00 06:00 2.00 0 2,466 SURFA DRILL TRIP P TIH to 2450. Wash down to 2466'. Surve . 06:00 12:00 6.00 2,466 2,975 SURFA DRILL DRLG P Drill 16" hole from 2466' to 2975' MD, 2005' TVD. ART=2.49, AST=1.18, ADT=3.67, PU=93K, S0=69K, ROT=80K, TQon=8-10K, TQoff=2-8K Max Gas~144 BTU, Jar hours = 67.13 12:00 00:00 12.00 2,975 3,895 SURFA DRILL DRLG P PJSM. Drilled from 2975' to 3895' MD, 2228' TVD. ART=3.52, AST=4.7, ADT=8.22. PU=115K, S0=58K, ROT=82K, TQon=7-8K, TQoff=5-7K Jar hours = 75.35 Max Gas=144 BTU Page 2 Qf 23 --- Time Logs I Date From To nur S uenth E Depth Phase Code Subcode T OM 04/27/2006 00:00 00:30 0.50 3,895 3,988 SURFA DRILL DRLG P Drilled from 3895 to TD of 3988' MD, 2240.9' TVD. ART=0.74, AST=0.13, ADT=0.87 00:30 02:15 1.75 3,988 3,988 SURFA DRILL CIRC P CBU at 177 spm, 750 gpm, 2200 psi, TQ=7K 02:15 07:30 5.25 3,988 424 SURFA DRILL REAM P Survey. Monitor well: static. BROOH from 3988' to 424' MD. 07:30 08:15 0.75 424 70 SURFA DRILL TRIP P POOH on elevators from 424' to 70' M D. 08:15 09:30 1.25 70 0 SURFA DRILL PULD P Download MWD and LD BHA. 09:30 10:30 1.00 0 0 SURFA DRILL OTHR P Clean and clear rig floor. 10:30 11:30 1.00 0 0 SURFA CASIN( SFTY P PJSM. R/U casing equipment. 11:30 12:00 0.50 0 0 SURFA CASIN( PUTB P Make dummy run with 13 3/8" hanger. Satisfacto 12:00 14:30 2.50 0 84 SURFA CASIN( RNCS P PJSM. Run 13 3/8" casing. Jt 2 had damaged threads. LD and CO shoe 'pint and ~t 2. 14:30 00:00 9.50 84 3,433 SURFA CASIN( RNCS P PU 13 3/8" casing. Place centralizers per program. Filling 6 bbls per joint. Check up and down weights every 10 joints. Break circulation and wash in from 1255 to 1428 at 60 bpom, 300# (Without pump PU=140K, S0=96K). Continue to run casing at 1608, S0=50-45 K, wash in from 1598-1682. (Without pumps PU=153K, S0=90K). Run to 1767', wash to 1894. Run to 1927. Wash to 1968. Run to 2130', wash to 2299'. Run to 2470'. Without pumps PU=270K, S0=80K. Wash to 3390 (Without pump PU=265K, S0=75K). Run in to 3433. Total 83 joints ran in, 11 washed in. 94 joints total. 04/28/2006 00:00 00:15 0.25 3,433 3,941 SURFA CASIN( RNCS P Continue to run 13 3/8" casing from 3,433' to 3941 00:15 00:30 0.25 3,941 3,977 SURFA CASINC PUTB P M/U hanger and landing joint. RIH to 3977 casin shoe de th. 00:30 02:00 1.50 3,977 3,977 SURFA CASIN( CIRC P Circulate and condition mud at 7 bpm, 400 psi, PU=260K, S0=60K. Working pipe every 5 mins over 10 feet. Slightly sticky towards bottom & after circulatin im roved. 02:00 02:45 0.75 3,977 3,977 SURFA CASIN( PUTB P UD franks tool M/U cement head. 02:45 05:45 3.00 3,977 3,977 SURFA CASIN( CIRC P Continue to circulate and condition mud per mud engineer. Mud before cond. 9.6 ppg, Vis 175, PV 23, YP 47. Mud after cond. 9.0+ ppg, Vis 40, PV 12, YP 6. Held PJSM with Dowell cmt'ers, ASRC vac trucks, Alf rig ersonnel. 05:45 06:00 0.25 3,977 3,977 SURFA CEMEf~ SFEQ P Pump 5 bbls water to pressure test cement lines to 3000 si. - - _ ~ag~ 3 Qf ~3~ - - - - Time Logs - - - - - - - -- . Date From To Dur S. e th E. D~th Phase Code Subcode T OM - - - -- ___ 04/28/2006 06:00 10:00 - 4.00 3,977 3,977 SURFA CEME~ DISP P Pump cement per plan. Pumped 50 bbls of CW100, Followed. by 50 bbls 10.5 ppg Mud Push with red bye. Dropped bottom plug, began mixing and pumping Articset Lite lead slurry. Purnp~1601 bbls, 729 sks, Yeild 4.63 ft/sk, at 6.6 bpm, at 120 psi. Followed by Tail cement:1001 bbls of DeepCrete, 228 sks, 12.0 ppg, Yield 2.47 ft/sk, at 6.4 bpm @ 150 psi. Shut down and dropped btm plug. Kick plug out with 20 bbls of fresh water. Turned over to rig pumps and displaced cement with 556.0 bbls, 5522 stks, at 7.6 bpm, 76 spm @ Initial pressure 300 to final 800 psi at 7.6 bpm. Rt~ciprocated pipe 10' every 5 minutes until 131.0 bbls cmt ~round'shoe (1750' up annulas). Did not visually see red dyed mud push. Slowed rate down to 30 spm (3.0 bpm) @ 550 psi at 5480 stks. Saw thick returns at 94.8 bbls prior to bump. Bumped plug with 1100 psi, held 10 mins. Check floats, Floats held-OK. CIP at 09:50 hrs 2/28/06. Had full returns through ouY job. vdith 44.8 bbls re4ttrns to surface. Shoe at 3977' MD, Float collar at 3889. 10:00 12:00 2.00 3,977 3,977 SURFA CEMEf~ RURD P Check float equipment. Rig down cement equipment, landing jiont. Flush the stack. 12:00 15:00 3.00 0 0 SURFA WELCT NUND P Nipple down diverter system. Move everything from cellar. Bring in Vetco Gra wellhead. Clean u wellhead. 15:00 16:45 1.75 0 0 SURFA WELCT NUND P Nipple up 13 3/8" 5000#, Wellhead. Test lower flan a to 5000 si. 16:45 19:45 3.00 0 0 SURFA WELCT NUND P Nipple up BOPEs, attache turnbucles. Rig up secondary annulus values. Rig u flow ni le. 19:45 21:00 1.25 0 0 SURFA WELCT NUND P Change lower pipe rams to 9 5/8". 21:00 21:45 0.75 0 0 SURFA WELC7 NUND P Bring test equpiment up to floor and rig u. 21:45 00:00 2.25 0 0 SURFA WELCT BOPE P Test BOPEs. 250 psi low, 3000 psi high. Testing witnessed by AOGCC John Crisp. Note; Cement samples caught from cement to surface has otten had. r age ~ of ~3 _-- Time Logs -- ~ Date From To Dur S_epth E_ D e th Phase Code ubcode S T OM 04/29/2006 00:00 02:30 2.50 0 _ _ 0 SURFA WELCT _ _ BUPE __ P Continue to test BOPEs. 250 psi low, 3000 psi high. Test Top pipe rams CV 1, 12, 13, 14, Man Kill valve, upper IBOP, HCR Kill, CV 9, 11, Lower IBOP, CV 54, 8, 10, Dart valve, CV 4, 6, 7, Floor valve, CV 2, HCR Choke, Manual choke valve, annular preventer, lower pipe rams 9 5/8", blind rams, accumulator test, system pressure=3000 psi, after closed = 1800 psi, 200 psi attained 38 sec, full pressure attained 3 min 18 sec, Nitro en bottle ave=2300 si. 02:30 03:00 0.50 0 0 SURFA WELCT OTHR P Rig down Test equipment. Set wear bushin 12.415" ID. 03:00 04:00 1.00 0 0 SURFA RIGMN SVRG P PJSM for servicing top drive. Service To Drive and install short bails. 04:00 06:00 2.00 0 78 SURFA DRILL PULD P PJSM. MU BHA #3, Bit, Geop Pilot, NMFC, MWD, 8" pulser, and NMF sub. 06:00 07:00 1.00 78 78 SURFA DRILL OTHR P Plug in and upload MWD. 07:00 07:45 0.75 78 448 SURFA DRILL TRIP P RIH with BHA and 6 stands of HWDP. LD excess HWDP. 07:45 11:15 3.50 448 3,882 SURFA DRILL PULD P PJSM. P/U 5" DP from pipe shed. RIH with 36 joints and then P/U ghost reamer. RIH picking up 63 more joints to 3882' MD. 11:15 12:00 0.75 3,882 3,882 SURFA DRILL CIRC P CBU at 3882' MD. 154 spm, 650 gpm, 1300 si, TQ=5-10K. 12:00 13:00 1.00 3,882 3,882 SURFA CASIN( DHEQ P Blow down top drive. Rig up for casing test. Test 13 3/8" casing to 3000 psi for 30 mins. 13:00 13:30 0.50 3,882 3,882 SURFA CEME~ CIRC P Pump tube pill. Torque before = 5-10K, after 7K. 13:30 16:45 3.25 3,882 4,008 SURFA CEMEI~ DRLG P Tag float equipment at 3884' MD. Drill float collar and shoe track plus 20 ft of new hole to 4008' MD. Shoe at 3975' M D. 16:45 17:30 0.75 4,008 4,008 SURFA DRILL CIRC P Displace over to LSND mud at 730 m, 1500 si. 17:30 18:30 1.00 4,008 4,008 SURFA DRILL LOT P Rig up and perform LOT at 4008' MD, 2238' TVD, 9,1 ppg OMW, 642 psi, ECD = 14.6 18:30 19:30 1.00 4,008 4,010 1NTRM1 DRILL DRLG NP Attempted to start drilling. Made 2' and torsional efficiency light showing red. Added tubes to the mud. r~~c~e ~ of 23_ -- - - -- - - - -- Time Logs _ -- - - --- Date From To Dur ~e th E De th Phase Code Subcode OM 04/29!2006 19:30 00:00 4.50 4,010 4,623 INTRM1 DRILL DRLG P Drilled from 4010' MD to 4623' MD, 2374' TVD. ADT=2.7 hrs. PU=105K, S0=70K, ROT=87K, TQon=6/8K, TQoff=5/7K ECDs=9.68, Max Gas=43 BTU, Jar hours=94.21 SPR at 4248 MD, 2292' TVD #1 20 spm / 90 psi, 20 spm / 130 psi #2 20 s m / 100 si, 30 s m /140 si 04/30/2006 00:00 12:00 12,00 4,623 6,010 INTRM1 DRILL DRLG P Drilled from 4,623' to 6,010' MD, 2,699' TVD. WOB=2-25, 130 RPM, 700 gpm PU=124K, S0=70K, ROT=89K, TQon=2-10K, TQoff=7-10 Max Gas=37 BTU, Jar hrs=101.78 ECDs=9.68 SPR at 5,968' MD, 2,689' TVD #1 30 spm / 170 psi 40 spm / 220 psi #230s m/170 si 40s m/210 si 12:00 13:45 1.75 6,010 6,288 INTRMI DRILL DRLG P Drilled from 6,010' to 6,288' MD. ECD s ike while makin connection 13 13:45 15:00 1.25 6,288 6,288 INTRM1 DRILL CIRC P Circulate while rotating or reciprocating pipe. 150 rpm, TQ=11 K, increase pumps to 750 gpm at 1600 psi. HOIe unloaded at bottoms u . 15:00 00:00 9.00 6,288 7,123 INTRM1 DRILL DRLG P Drilled from 6,288 to 7123' MD, 2,958' TVD. Pumped Hi Vis sweep at 6383' MD, 15% increase in cuttings. WOB=5-25K, 110/150 rpm, 650 gpm. PU=125K, S0=75K, ROT=96K, TQon=12/13K, TQoff=10K Max Gas=51 BTU, Jar hrs=108.69 ECDs=9.9 SPR at 6,935' MD, 2,958' TVD #1 30 spm / 240 psi 40 spm / 280 psi #2 30 s m / 240 si 40 s m / 290 si 05/01/2006 00:00 05:45 5.75 7,123 7,862 INTRM1 DRILL DRLG P Drill from 7123' to 7862' MD, 3127' TVD. ART=2.5, W0B=5-15K, 120 RPM, 600 m. 05:45 06:30 0.75 7,862 7,862 INTRM1 DRILL CIRC P Screens blinding off with UGNU sands. Circulate until shakers cleaned u . -- ~_ A ~~~ _ Page ~; of 23 - Time Loc~s_ Date From To Dur z th E De fh Phase Code Subcode T OM 05/01/2006 06:30 12:00 5.50 7,862 8,370 INTRM1 DRILL DRLG P Drill from 7862' to 8370' MD, 3256' TVD. ART=1.99, Total ART=4.49 hrs, WOB=5-15, 120 rpm, 600 gpm PU=135K, S0=80K, ROT=103K, TQon=12-14K, TQoff=9-10K ECD=9.78, Max Gas=220 BTU, Jar hours=113.18 SPR at 8324' MD, 3244' TVD MW=9.1 PP9 #1 30 spm / 240 psi 40 spm / 280 psi #2 30 s m / 240 si 40 s m / 280 si 12:00 00:00 12.00 8,370 9,162 INTRM1 DRILL DRLG P Drill from 8370' to 9162' MD, 3407' TVD. ART=4.57, WOB=5-20, 90/150 rpm, 600 gpm PU=151 K, S0=67K, ROT=101 K, TQon=15-16K, TQoff=14K ECD=9.87, Max Gas=124 BTU, Jar hours=117.75 SPR at 9067' MD, 3393' TVD MW=9.2 PP9 #1 30 spm / 250 psi 40 spm / 310 psi #230s m/260 si 40s m/310 si 05/02/2006 00:00 00:45 0.75 9,162 9,280 INTRM1 DRILL DRLG P Drilled from 9162' to TD of 9280', 3425' TVD. ART=0.43 PU-105K, So-68K, ROT=105K, TQon=5-15K, TQoff=12-20K Max gas=197 BTU, Jar hours=118.18 ECD 9.97 00:45 02:00 1.25 9,280 9,187 INTRM1 DRILL CIRC P Survey at TD. Get SPR. Monitor well, static. Circulate. Rack back one stand and pump 50 bbls hi vis sweep. Work pipe slowly & circulate sweep out at 800 gpm, 190 spm, 150 rpm. TQ=11-14K. Saw very little increase in cuttings. 9280' MD, 3425' TVD MW=9.2 ppg #1 30 spm / 230 psi 40 spm ! 280 psi #2 30 spm / 210 psi 40 spm / 300 si 02:00 10:00 8.00 9,187 9,280 INTRM1 DRILL REAM P RIH and tag bottom. BROOH at 190 s m=800 m, 2400 si, 150 r m. 10:00 12:00 2.00 9,280 9,280 INTRM1 DRILL CIRC P Pump 50 bbl weighted hi vis sweep at 3974' MD, 800 gpm, 190 spm, 100 rpm, TQ=4-5K, 1800 psi,. +BU. PU=100K, SO-60K, Monitor well: static. Pum d 'ob. 12:00 14:00 2.00 9,280 445 I NTRM1 DRILL TRIP P POOH to BHA. 14:00. 16:30 2.50 445 0 I NTRM1 DRILL PULD P LD BHA #3. XOs, Flex DCs, Plug in and download MWD. Continue to LD BHA. ~~~e 7 of 23 _ Time Loys __ _ Date From To Dur e th E Depth Phase Code Subcode T QOM 05/0212006 16:30 17:45 1.25 0 0 INTRM1 DRILL OTHR P Grade bit and pull wear ring. Clear and clean ri floor. 17:45 19:30 1.75 0 0 INTRM1 CASIN( RURD P PJSM. Gring casing tools to rig floor. RU to run casin . 19:30 00:00 4.50 0 1,606 INTRM1 CASIN( RNCS P PJSM with other crew. PU shoe track and float. Test floats. RIH with 9 5/8" casin to 1606' MD with centralizers. 05/03/2006 00:00 03:45 3.75 1,606 3,970 INTRM1 CASIN( RNCS P . PJSM. Continue to run 9 5/8" casing er detail from 1609 to 3970' MD. 03:45 04:30 0.75 3,970 3,970 INTRM1 CASIN( CIRC P CBU at surface shoe, 3970' MD. 6 b m, 350 si. 04:30 09:30 5.00 3,970 6,900 INTRM1 CASIN( RNCS P Cont to run casing to 6900. PU=200K, S0=70K. 09:30 11:00 1.50 6,900 6,979 INTRM1 CASIN( CIRC P CBU and condition mud. Wash down to 6979 at 550 si, 7 b m. 11:00 12:00 1.00 6,979 7,244 INTRM1 CASIN( RNCS P Run casing to 7244' MD (190 jts), PU=205K, S0=67K. 12:00 16:00 4.00 7,244 9,275 INTRM1 CASIN( RNCS P Cont. to run casing to 9276' MD. Last LoDrag centralizer on jt 232. Total 'oints run 243. PU=225K, S0=85K. 16:00 17:30 1.50 9,275 9,275 INTRM1 CASIN( CIRC P Circulate and condition mud. Stage to 7 b mat 500 si. PU=205K, S0=90K. 17:30 18:00 0.50 9,275 9,275 INTRM1 CASIN( RURD P Rig down franks fillup tool. Blow down to drive. Ri u cement head. 18:00 20:00 2.00 9,275 9,275 INTRM1 CASIN( CIRC P Circulate and condition mud at 7 bpm, 500 si. Hold PJSM for cement 'ob. 20:00 21:30 1.50 9,275 9,275 INTRM1 CEMEt~ CIRC P Pump 10 bbls of CW100 and pressure test lines to 3500 psi. Pump 40bbls more of CW100. Pump 75bbls MudPush and drop bottom plug. Follow with 240 bbls of 12.5ppg, DeepCrete cement. Wash lines and dro bottom lu . 21:30 00:00 2.50 9,275 9,275 INTRM1 CEMEI~ DISP P Switch over to rig pumps. Rig chase plug with OBM. Reciprocated pipe until 6400 stks. Bumped: ping at 688Tstks, 688 bbls mud. 05/04/2006 00:00 00:30 0.50 0 0 INTRM1 WELC7 NUND P Drain stack. Nipple down BOPE. 00:30 01:30 1.00 0 0 INTRM1 WELCT NUND P Set Emergency slips with 75K down weight. Had to clean pipe very well to et the sli s to set. 01:30 03:00 1.50 0 0 INTRM1 WELCT NUND P RU WACHS pneumatic cutter & cut casing per Vetco rep. Pull cut joint out of the hole. Len th but =16.8'. 03:00 04:30 1.50 0 0 INTRM1 WELCT BOPE P Nipple up BOPE. Set packoff, test to 2500 psi for 10 mins. Set wear bushin . 04:30 07:00 2.50 0 0 INTRM1 WELCT BOPE P RU to 13 378" and 9 5/8" annulus and pressure test line. Perfrom infectivity LOT. Observed break over at 7.0 bbls and 210 psi (EMW=10.6 ppg). Pumped additional 23bbls mud. Flushed with 262 bbls of fresh water at 3 bpm, 550 psi. Shuffle pipe in derrick while um in water down annulus. e _ m Eexr~~ ~ of 23 Time_Lo~s_ --- - Date From To Dur _ S. L ~pth E De th Phase C,ode__ Subcode T - _ ~UM_ __ _ - - --- 05/04/2006 07:00 12:00 5.00 0 0 INTRM1 DRILL PULD P RIH with mule shoe on DP and PU 22 stands of G drillpipe from derrick. Continue to RIH with S-135 drill pipe from shed. 12:00 13:00 1.00 0 0 INTRM1 DRILL PULD P Continue to PU S-135 drill pipe from shed, 54 stands. to shuffle order of i e in derrick. 13:00 16:00 3.00 0 0 INTRM1 DRILL PULD P POOH and stand back drill pipe with S-135 in the back to use on the top onion of B lateral. 16:00 16:45 0.75 0 0 INTRM1 DRILL SFTY P Clear and clean rig floor. Bring jewerly to rig floor for next run. PJSM for PU BHA#4. 16:45 19:45 3.00 0 446 INTRM1 DRILL TRIP P Picking up BHA #4. Plug in and upload MWD (1 hr). Continue to PU BHA and RIH. 19:45 20:45 1.00 446 446 INTRM1 RIGMN SVRG P PJSM. Cut and slip drilling line. 20:45 21:15 0.50 446 495 INTRM1 DRILL DHEQ P Shallow test MWD. Break in GeoPilot. 21:15 00:00 2.75 495 2,780 INTRM1 DRILL TRIP P RIH with BHA #4, singling in from shed with 80 "oints, to 2780' MD. 05/05/2006 00:00 02:30 2.50 2,780 9,157 INTRM1 DRILL TRIP P Continue to single in with more 22 joints from shed and pipe from the derrick to 9157' MD. 02:30 03:30 1.00 9,157 9,157 INTRM1 CASIN( DHEQ P R/U and test 9 5/8" intermediate casin to 3000 si from 30 mins. 03:30 05:45. 2.25 9,157 9,300 INTRM1 CEME~ DRLG P RIH to 9199' MD and drill out float equipment, shoe teack and 20' of new hole to 9300' MD. 05:45 06:15 0.50 9,300 9,300 INTRM1 DRILL CIRC P CBU at 169 spm, 600 gpm, ROT 90 r m with 2800 si. 06:15 07:00 0.75 9,300 9,300 INTRM1 DRILL LOT P Perform LOT at 9300' MD, 3428' TVD. Brake ova at 14.4 ppg. Clean hole ECD is 9.8 at 600 m. 07:00 12:00 5.00 9,300 9,650 PROD1 DRILL DRLG P Drill from 9300' MD to 9650' MD, 3448' TVD. ADT=3.61 hrs PU=156K, S0=60 K, ROT=100K, TQon=14/15K, TQoff=13K Max ECDs=9.89, Max Gas=118 BTU, Jar hours 119.09 SPR at 9431 MD, 3445' TVD, 8.7+ MD #1 30 spm / 280 psi 40 spm / 380 psi #2 30 spm / 280 psi 40 spm / 370 si ~a~a ~ ~f ?3 - -- _ -- ~Time Logs - - - _ - --- .Date From To Dur S~eQth E,_De~th Phase Code S_ubcode T - QOM - - - _ 05/05/2006 12:00 00:00 12.00 9,650 10,825 PROD1 DRILL DRLG P Drill from 9,650' MD to 10,825' MD, 3431' ND. The torsional efficiency was in the red zone after HWDP got outside of casing. Did not improve with WOB and RPM changes. Improved after HWDP reached +/-10,300' MD. ADT=6.26 hrs PU=160K, S0=50 K, ROT=100K, TQon=16K, TQoff=16K Max ECDs=10.46, Max Gas=102 BTU, Jar hours 125.35 SPR at 10,279 MD, 3429' TVD, 8.8 MD #1 30 spm / 330 psi 40 spm / 440 psi #2 30 spm / 350 psi 40 spm / 440 si 05/06/2006 00:00 00:30 0.50 10,825 10,914 PROD1 DRILL DRLG P Drill from 10,825' MD to 10,914' MD, ADT=0.51 00:30 01:30 1.00 10,914 10,914 PROD1 DRILL CIRC P Pump hi vis sweep at 140 spm, 575 gpm, 3000 psi per DD and MWD hands. Ve .little cuttin s increase. 01:30 12:00 10.50 10,914 11,862 PROD1 DRILL DRLG P Drilled from 10,914'to 11,862' MD, 3419' ND. ADT=4.61 PU=165K, S0=42K, ROT=100K, TQon=14K, TQoff=15-20K ECDs=10.92, Max Gas=206 btu, Jar hours=130.47 Concretion depths: 11,148'/11,153', 11,759'/11,764', 11,770'/11,773' MDs SPR at 11,751' MD, 3422' TVD MW=8.8 PP9 #1 30 spm / 390 psi 40 spm / 480 psi #2 30 spm / 420 psi 40 spm ! 510 si 12:00 00:00 12.00 11,862 12,870 PROD1 DRILL DRLG P Drilled from 11,862' MD to 12,870' MD 3412' ND. ADT=5.77 PU=175K, S0=0, ROT=105K, TQon=19K, TQoff=17K ECDs=11, Max Gas=174 btu, Jar hours=136.24 Concretion depths: SPR at 12,868' MD, 3411' TVD MW=8.75 ppg #1 30 spm / 360 psi 40 spm / 440 Psi #2 30 spm / 410 psi 40 spm / 490 si ____--.~ r ~cJe `Its of~3 Time Logs Date From To _ D_ur S. epth_ _E, Depth Fhase Cody Subcod_e T ~,OM - - - -- _ - - 05/07/2006 00:00 12:00 12.00 12,870 14,010 PROD1 DRILL DRLG P Drilled from 12,870' MD to 14,010' MD 3403' TVD. ADT=6.47 hrs PU=180K, S0=0, ROT=100K, TQon=18-19K, TQoff=15-18K ECDs=11.20, Max Gas=267 btu, Jar hours=142.71 Concretion depths: 12,888'/12,892, 13,002'/12,238', 13,238'/13,243', 13,328'/13,331', 13,380'/13,392', 13,438'/13441', 13,404'/13,408', 13,457'/13,465', 13,495'/13,500', 13,620'/13,635' SPR at 13,820' MD, 3405' TVD MW=8.8 pP9 #1 30 spm / 400 psi 40 spm / 460 psi #2 30 spm / 480 psi 40 spm / 530 si 12:00 00:00 12.00 14,010 15,343 PROD1 DRILL DRLG P Drilled from 14,010' MD to 15,343' MD 3391' TVD. ADT=4.49 hrs PU=185K, S0=0, ROT=102K, TQon=18K, TQoff=20K ECDs=11.08, Max Gas=175 btu, Jar hours=147.2 Concretion depths: 14,473'/14,477', 14,458'/14,560' SPR at 15,056' MD, 3396' TVD MW=8.7 pp9 #1 30 spm / 430 psi 40 spm / 520 psi #2 30 spm / 420 psi 40 spm / 500 si 05/08/2006 00:00 12:00 12.00 15,343 16,379 PROD1 DRILL DRLG P Drilled from 15,343' MD to 16,379' MD 3377' TVD. ADT=5.2 hrs PU=190K, S0=0, ROT=100K, TQon=20K, TQoff=21 K ECDs=11.53, Max Gas= 950 btu, Jar hours=152.4 Concretion depths: 15,691'/15,700', 15,805'!15,813', 16,085'/16,093' SPR at 16,197' MD, 3375' TVD MW=8.7 Ppg #1 30 spm / 550 psi 40 spm / 600 psi #2 30 spm / 540 psi 40 spm / 590 si ~~e 11 cif 23 Time Logs _ - _ _ - - --- Date From To Dur e~th S E Depth Phase Code Subcode T OM_ __ 05/08/2006 12:00 00:00 _ 12.00 _- 16,379 17,150 PROD1 DRILL _ DRLG P Drilled from 16,379' MD to 17,150' MD 3418' TVD. ADT=4.62 hrs PU=226K, S0=0, ROT=106K, TQon=18/20K, TOoff=22K ECDs=11.84, Max Gas=1118 btu, Jar hours=157.02 SPR at 17,052' MD, 3392' TVD MW=8.7 PP9 #1 30 spm / 540 psi 40 spm / 630 psi #2 30 spm / 540 psi 40 spm / 640 si 05/09/2006 00:00 05:15 5.25 17,150 17,795 PROD1 DRILL DDRL P Drilled from 17,150' to 17,795' MD. ADT=3.73 Concretion de ths: 17,679' to 17,682' 05:15 06:15 1.00 17,795 17,795 PROD1 DRILL CIRC NP Circulated and evaluated for geology. 06:15 07:30 .1.25 17,795 17,870 PROD1 DRILL DDRL P Cont'd drilling from 17,795' to 17,870' MD / 3751' TVD w/ WO6=10-15K, 150 rpm, 611 gpm, 3900 psi. ADT=0.75 Jar hrs=161.5 PUW=250K SOW=O ROT=114K TQon/off=19K-21 K/19K-21 K ECD=12.2 Max Gas=129 Units 07:30 09:45 2.25 17,870 17,150 PROD1 DRILL WPRT P BROOH from 17,870' to 17,150' MD w/ 150 r m, 611 m, 3900 si. 09:45 12:00 2.25 17,150 17,150 PROD1 DRILL CIRC P Circ'd a hi-vis weighted sweep and 2X BU w/ 150 r m, 611 m, 3900 si. 12:00 13:30 1.50 17,150 17,150 PROD1 DRILL CIRC P Cont'd to circ w/ 150 rpm, 611 gpm, 3800 si. Observed well, static. 13:30 15:00 1.50 17,150 16,295 PROD1 DRILL TRIP P POOH on elevators from 17,150' to 16,485' w/ improper fill. Screwed in and pumped out from 16,485' to 16,295' MD. 15:00 00:00 9.00 16,295 9,620 PROD1 DRILL WPRT P BROOH from 16,295' to 9,620' MD. 05/10/2006 00:00 00:15 0.25 9,620 9,250 PROD1 DRILL WPRT P Cont'd BROOH from 9,620' to 9,250' MD. 00:15 01:30 1.25 9,250 9,250 PROD1 DRILL CIRC P Pumped weighted hi-vis sweep @ 600 m, 150 r m, 2850 si. 01:30 03:00 1.50 9,250 9,250 PROD1 RIGMN SVRG P Held PJSM, cut and slipped 84' drill. line. Serviced TD. 03:00 03:15 0.25 9,250 10,177 PROD1 DRILL WPRT P TIH from 9,620' to 10,17T MD. SOW=O. 03:15 12:00 8.75 10,177 16,295 PROD1 DRILL WPRT P Washed and reamed in hole from 10,177' to 16,295' w/ 65 rpm, 313 gpm, 1500 si. 12:00 13:00 1.00 16,295 17,150 PROD1 DRILL WPRT P Cont'd to wash and ream from 16,295' to 17,150' MD w/ 65 rpm, 315 gpm, 1600 si and TQ=21 K. 13:00 15:30 2.50 17,150 17,150 PROD1 DRILL CIRC P Pumped a weighted hi-vis sweep and circa until shakers cleaned up w/ 600 m, 150 r m. ~ ~ Faye 12 of 23 ~~ ' Time Logs -- ~, Date _ From To _Dur S_ . epth E. Depth Phase Code _ Subcode T _ _ -- :OM ' 05/10/2006 15:30 16:30 1.00 17,150 17,150 PROD1 DRILL OTHR P Displaced well to SFOBM from 17,150' to 8,600' MD w/ 600 gpm, 150 rpm, TQ=20K, and 3750 psi. PUW=210K SOW=OK 16:30 23:30 7.00 17,150 9,157 PROD1 DRILL TRIP P Observed well, static. POOH on elevators from 17,150' to 9,157'. UD 8 stands of G DP, installed super sliders be ininin std # 124. 23:30 00:00 0.50 9,157 9,157 PROD1 DRILL OTHR P Observed well, static. Blew down TD. Crew chan out. 05/11/2006 00:00 00:45 0.75 9,157 8,599 PROD1 DRILL TRIP P ConYd TOOH from 9,157' to 8,599' MD while installing super-sliders. Dropped rabbit 2 3/8" 9,065' std #93 . 00:45 03:45 3.00 8,599 446 PROD1 DRILL TRIP P Cont'd to TOOH from 8,599' to 446' MD. 03:45 04:45 1.00 15,797 PROD1 DRILL PULD P S/B 3 stds HWDP, 1 std NMFDCs. UD float sub, and retrieved rabbit from to of'ars. 04:45 06:15 1.50 446 446 PROD1 DRILL PULD P Downloaded MWD. 06:15 07:00 0.75 446 0 PROD1 DRILL PULD P UD BHA #4 including: TM, HCIM, smart stab, EWR+DGR+PWD, smart stab, NMFDC w/ DM, eo- ilot and bit. 07:00 07:30 0.50 0 0 PROD1 DRILL OTHR P Cleared and cleaned rig floor. 07:30 08:30 1.00 0 0 COMPZ CASIN( RURD P Held PJSM, P/U and R/U 5 1/2" casin tools. 08:30 12:00 3.50 0 4,326 COMPZ CASIN( RNCS P RIH w/ 5 1/2" liner to 4,326' MD (91 'ts . 12:00 15:30 3.50 4,326 8,932 COMPZ CASIN( RNCS P Cont'd to RIH from 4,326' to 8,932' MD. P/U and ran seal assy, and ZXP acker. PUW=92K SOW=58K. 15:30 00:00 8.50 8,932 15,797 COMPZ CASIN( RUNL P Ran liner on DP from derrick. With 11 stds DP: PUW=105K SOW=65K ROT=88K TQ=4-5K w/ 25 rpm. RIH to 13,950' where SOW=O. Rotated liner in with 25 rpm and TQ=12K. RIH to 15,797. 05/12/2006 00:00 02:00 2.00 15,797 17,105 COMPZ CASIN( RUNL P Cont'd to rotate liner from 15,797' to 17,105' MD w/ 25 rpm and TQapprox=20K. PUW=195K ROT=74K. 02:00 03:30 1.50 17,105 8,933 COMPZ CASIN( OTHR P Dropped bal! and pumped down with 4.5 bpm to 1200 stks, 1.5 bpm to 1551 stks when ball seated. Pressured up and set ZXP w/ 4000 si. 03:30 08:00 4.50 8,933 0 COMPZ DRILL TRIP P Checked flow, static: POOH from liner to 8,933' MD. Stra ed OOH. 08:00 08:30 0.50 0 0 COMPZ DRILL PULD P Broke out and UD liner running tool. 08:30 09:00 0.50 0 0 COMPZ DRILL OTHR P Cleaned and cleared rig floor. 09:00 10:00 1.00 0 0 COMPZ WELCT NUND P Pulled wear bushing, installed test plug, filled stack and choke manifold w/ water. ~~P~~~e 13 ts~ ~3 Time Logs __ _ Subcode Ph~se Code From To Dur S__ depth E [~epth Date T ~M ~ - 05/12/2006 10:00 12:00 2.00 0 0 _ COMPZ __ WELCT BOPE _ P __ Started BOPS testes/ low pressure test @ 250 psi and high @ 3000 psi. Tested 3.5"X6" varible top rams, blind rams, choke valves 1-14, manual choke and kill valves, HCR choke and kill valves, 5" TIW valve, 5" dart valves. 12:00 14:00 2.00 0 0 COMPZ WELCT BOPE P Cont'd testing BOPE including gas alarms. Witnessing of test waived by Chuck Scheve 4:45 am 5/12/2006. 14:00 14:30 0.50 0 0 COMPZ WELCT NUND P Pulled test plug, set wear ring. Blew down stand i e, choke, and all lines. 14:30 16:00 1.50 0 0 COMPZ EVALV~ RURD P Held PJSM. R/U and P/U a-line cement bond to USIT tools. 16:00 19:30 3.50 0 0 COMPZ EVALV~ WOEQ T CHECK USIT TOOL. NO AUXILLARY POWER (CAN'T TURN SUB). BEGIN TROUBLESHOOTING CALL FSM. REQUEST BU POWER DRAWER AND COMPUTER RACK BE SENT FROM PRUDHOE. REPLACE FAILED POWER DRAWER (WFAD -FOUND KNICKED WIRE ON BACKPLANE). FINISH WITH USIT CHECKS. 19:30 00:00 4.50 0 0 COMPZ EVALV~ ELOG P RIH w/ a-line to 3,000'. Begin to tractor down @ 1000' per hour. RIH to +/- 6,000' MD midni ht. 05/13/2006 00:00 08:00 8.00 0 0 COMPZ EVALV~ ELOG P Cont'd to RIH w/USIT tool on tractor. Logged interval of interest w/good cement to 6,750' RAD and fair cerr-ent to 6,250' MD (top of UGNU @ 6,469' MD). POOH w/ logging tools and R/D Schlumber er. 08:00 09:00 1.00 0 0 COMPZ RIGMN RGRP NP Replaced bushings in link tilt on TD. 09:00 09:45 0.75 0 0 PROD2 DRILL PULD P Held PJSM. Began to P/U whipstock assembl from beaver slide. 09:45 12:00 2.25 0 131 PROD2 DRILL PULD P P/U assembly as follows: seal, stop sub, unloader, pup jt, 2 jts 5" DP, blank sub, 9 5/8" trip anchor, safety disconnect, drain sub, debris sub, 8" OD master whipstock, window mill, lower watermelon mill, flex jt, upper watermelon mill. 12:00 13:30 1.50 131 215 PROD2 DRILL PULD P P/U 1 jt HWDP, float sub. Orient whipstock. Attempted to program MWD. Not res ondin correct) . 13:30 14:30 1.00 215 215 PROD2 DRILL PULD T UD and C/O MWD w/ new battery. 14:30 15:00 0.50 215 215 PROD2 DRILL PULD P Uploaded MWD. 15:00 15:30 0.50 215 409 PROD2 DRILL PULD P P/U and RIH w/ bumper sub and 6 hybrid DCs. BHA weight on hook=25K. 15:30 17:00 1.50 409 1,510 PROD2 STK TRIP P RIH 12 stds and C/O 2 jts DP w/ bad threads. SHT MWD 1510' MD. 6'~g~~e ~1~ ~~t 23 --- - - Time Lomas - -- __ _ - - .Date Frgm- To Dur _ Depth E._ Depth Phase _ Code Subcode_ T OM__ _ __ __ __ 05/13/2006 17:00 21:00 4.00 1,510 8,170 PROD2 STK TRIP P RIH w/ whipstock assembly, filling pipe @ 4,855' and 7,880' MD. Broke circ 8,170' MD. 21:00 22:00 1.00 8,170 8,300 PROD2 STK OTHR P Made MAD pass from 8,207' to 8,300' MD: Orient whipstock as making pass to 12? left of HS. 22:00 23:00 1.00 8,300 8,824 PROD2 STK WPST P Cont'd to RIH and Up single to 8,901' MD. Broke circ and confirm orientation @ 12? left. PUW=140K and SOW=65K w/ pumps on. Stabbed in and stacked out to 18K WOB @ top of "B" lat liner 8,933' MD. Set and confirmed positive anchor. Stacked out 35-45K to shear off whipstock. Established rotation w/ 20 rpm and TQ=15K, increased to 60 rpm and TQ=8-10K w/ ROT=80K. ~r~~y 23:00 00:00 1.00 8,824 8,826 PROD2 STK MILL P Began to mill window @ 8,824' MD w! 60 rpm, 140 spm, 494 gpm, WOM=2-4K 05/14/2006 00:00 09:30 9.50 8,826 8,881 PROD2 STK MILL P Cont'd to mill window. With TOW=8,824' MD and BOW=8,841' ' „~,~/~ ' " MD MD. Milled gauge hole to 8,861 ~ A ' ~~C'CP w/ TD @ 8,881' MD. ~ ~ ~ PUW=145K SOW=65K ROT=85K TO=10K 09:30 10:00 0.50 8,881 8,793 PROD2 STK CIRC P Pumped weighted hi-vis sweep @ 500 m, 1800 si, 50 r m. 10:00 10:15 0.25 8,793 8,793 PROD2 STK OWFF P Checked flow, static. Pumped dry job and blew down TD. 10:15 12:00 1.75 8,793 6,828 PROD2 STK TRIP P POOH from 8,793' to 6,828' MD. 12:00 14:00 2.00 6,828 300 PROD2 STK TRIP P Held PJSM for new crew. Cont'd to POOH to BHA 300'. 14:00 16:00 2.00 300 0 PROD2 STK PULD P UD 6 hybrid DCs and bumper sub. Plugged in and downloaded MWD. UD milling assy w/ upper mill full au e. Cleaned and cleared ri floor. 16:00 17:00 1.00 0 0 PROD2 STK OTHR P Pulled wear bushing, flushed BOP stack, reset wear bushin . 17:00 19:30 2.50 0 441 PROD2 DRILL PULD P P/U geo-pilot BHA and MWD. Programmed and uploaded MWD. RIH w/ BHA and HWDP. SHT MWD @ 441' MD. BHA PUW=22K 19:30 22:30 3.00 441 8,780 PROD2 DRILL TRIP P RIH to 8,780' MD. Filled DP @ 3222', 6003', 8780' MD. 22:30 23:30 1.00 8,780 8,780 PROD2 RIGMN SVRG P He(d PJSM. Slipped and cut 81' DL. Serviced TD and ins ected brakes. 23:30 00:00 0.50 8,780 8,780 PROD2 RIGMN RGRP NP Held PJSM. C/O saver sub. 05/15/2006 00:00 00:30 0.50 8,780 8,780 PROD2 RIGMN RGRP NP Cont'd to C/O saver sub. _ - - Time Logs __ _ - __ - ~ Date From- To Dur S ve~h- E Depth Phase Code- Suhc_ode T f,11 - 05/15/2006 00:30 12:00 11.50 .8,861 10,154 PROD2 DRILL DDRL P Ran through window and drilled undergauge hole from 8,861' to 8,881' MD. Directionally drilled 8.5" hole from 8,881' to 10,154' MD / 3,357 TVD. ADT=6.81 Bit hrs=6.81 Jar hrs=195.27 PUW=165K SOW=50K ROT=98K TQon/off=14K/15K ECD=10.99 Max Gas=516 Units Concretion depths:8944-8958', 9010-9013', 9392-9396', 9408-9410', 9465-9474', 9479-9485', -9508'. SPR#1=30stk/330psi, 40stk/400psi SPR#2=30stk/350psi, 40stk/400psi @ 9,710' MD / 3,361' TVD 8.8 MW 12:00 16:30 4.50 10,154 10,643 PROD2 DRILL DDRL P Hefd PJSM for new crew. Drilled from 10,154' to 10,643' MD where geo-span failed. ADT=3.9 hrs Bit hrs=10.71 Jar hrs=199.17 ECD=11.18 16:30 18:15 1.75 10,643 10,643 PROD2 DRILL CIRC T Circ'd and recip'd while C/O geo-span unit w/ 500 m, and 100 r m. 18:15 00:00 5.75 10,643 . 11,287 PROD2 DRILL DDRL P Directionally drilled 8.5" hole from 10,643' to 11,287' MD / 3,348' TVD. ADT=3.5 Bit hrs=14.21 Jar hrs=202.67 PUW=180K SOW=50K ROT=95K TQon/off=14-15K/13-14K ECD=11.01 Max Gas=386 Units Concretion depths:10154-10163', 10241-10246', 10248-10252', 11190-11195', 11210-11212'. SPR#1=30stk/400psi, 40stk/490psi SPR#2=30stk/370psi, 40stk/450psi @ 11,194' MD / 3,352' TVD 8.8+ MW 05/16/2006 00:00 12:00 12.00 11,287 12,631 PROD2 DRILL DDRL P Directionally drilled 8.5" hole from 11,287' to 12,631' MD / 3,339' TVD. ADT=6.52 Bit hrs=20.73 Jar hrs=209.19 PUW=185K SOW=45K ROT=102K TQon/off=14/15K ECD=11.44 Max Gas=551 Units Concretion depths: 11305-11310', 11357-11360' SPR#1=30stk/420psi, 40stk/480psi SPR#2=30stk/380psi, 40stk/460psi @ . 12,504' MD / 3,339' TVD 8.8+ MW __ _ ~. ~_~ _-~~. Pie i~ o'f "?3 Time Logs - _- - -- ~ . Date. From To Dur S epth _E. De~t_h_ Phase _ Code Subcode_ _T QOM _ __ _ ~ 05/16/2006 12:00 00:00 12.00 12,631 13,782 PROD2 DRILL DDRL P Directionally drilled 8.5" hole from ' 12,631' to 13,782 MD / 3,328' ND. ADT=8.57 Bit hrs=29.3 Jar hrs=217.76 PUW=190K SOW=OK ROT=90K TQon /off=15-17 K/ 13-14 K ECD=11.49 Max Gas=546 Units Concretion depths: 12630-12634', 12655-12662', 12677-12680', 12699-12709', 12723-12730', 12733-12740', 12742-12744', 12748-12751', 12760-12768', 12771-12781', 12793-12795', 12811-12814', 13219-13222', 13405-13408', 13595-13604', 13694-13703'. SPR#1=30stk/380psi, 40stk/490psi SPR#2=30stk/370psi, 40stk/460psi @ 13,649' MD / 3,336' ND 8.9 MW 05/17/2006 00:00 12:00 12.00 13,782 15,007 PROD2 DRILL DDRL P Directionally drilled 8.5" hole from 13,782' to 15,007' MD / 3,335' ND. ADT=7.45 Bit hrs=36.75 Jar hrs=225.21 PUW=200K SOW=OK ROT=105K TQon/off=15-18K/15K ECD=11.81 Max Gas=520 Units Concretion depths: 14443-14445', 14488-14502', 14523-14526', 14533-14537', 14542-14550', 14556-14559', 14599-14612'. SPR#1=30stk/460psi, 40stk/520psi SPR#2=30stk/420psi, 40stk/510psi @ 14,790' MD / 3,342' ND 8.7+ MW 12:00 23:30 11.50 15,007 16,121 PROD2 DRILL DDRL P Directionally drilled 8.5" hole from 15,007 to 16,121' MD / 3,293' ND: Pumped 30 bbl weighted hi-vis sweep @ 15,315' and 16.,026' w/ a 20% increase in cuttings noted on both. ADT=8.35 Bit hrs=45.10 Jar hrs=233.56 PUW=200K SOW=OK ROT=105K TQon/off=16-17K/15K ECD=1.2.42 Max Gas=277 Units Concretion depths: 115033-15036', 15040-15043', 15055-15060', 15082-15085', 15089-15093', 15313-15321', 15344-15369', 15560-15578', 15581-15585'. SPR#1=30stk/540psi, 40stk/620psi SPR#2=30stk/480psi, 40stk/580psi @ 16,026' MD / 3,296' ND 8.8 MW 23:30 00:00 0.50 16,121 16,121 PROD2 DRILL CIRC P Circ'd sweep around while rotating and reci rocatin . ~CJ'L "~ t ~ I"~..1_ _ --_ - -- - - __ Time Logs -- - - -- 1 Date_ From To Dur S. ~e th E. Depth Phase _ _ Cody Subcodc_ T __ _ _C)M _ __ _ __ _ _ j 05/18/2006 00:00 00:30 0.50 16,121 16,121 PFZOD2 DRILL CIRC P Cont'd to circ sweep OOH w/ 618 gpm, 3700 psi, 145 rpm. Noted a 20% increase in cuttings w/ECDs decreasin from 12.67 to 12.23. 00:30 07:15 6.75 16,121 16,692 PROD2 DRILL DDRL P Directionally drilled 8..5" hole from 16,121' to 16,692' MD / 3,355' TVD. Pumped 30 bll weighted hi-vis sweep on last stand. ADT=4.81 Bit hrs=49.91 Jar hrs=238.42 PUW=205K SOW=OK ROT=98K TQon/off=17K/16K ECD=12.23 Max Gas=257 Units SPR#1=30stk/540psi, 40stk/620psi SPR#2=30stk/480psi, 40stk/580psi @ 16,026' MD / 3,296' TVD 8.8 MW 07:15 08:00 0.75 16,692 16,692 PROD2 DRILL CIRC P Circ'd sweep OOH w/ 608 gpm, 3800 psi, 150 rpm. Observed 10% increase in cuttin s. 08:00 08:15 0.25 16,692 16,692 PROD2 DRILL OWFF P Checked flow, static. Garnered SPRs. 08:15 12:00 3.75 16,692 14,794 PROD2 DRILL WPRT P BROOH from 16,692' to 14,794' MD w/ 130 r m, 620 m, 3700 si. 12:00 20:30 8.50 14,794 8,785 PROD2 DRILL WPRT P Held PJSM and cont'd BROOH from 14,794' to 8,972' MD w/ 130 rpm, 620 gpm. While BROOH @ 14,762' hole packed off and rotary stalled. Bled off and broke down, pipe free. BROOH @ 10 fpm, from 14,790' to 14,740' MD w! no further problems.Pumped and pulled through window from 8,972' to 8,785' MD. Pulled 65K going through window, went back down and came through again with 25K. PUW=165K SOW=50K ROT=95K above window. Monitored well, static. 20:30 21:30 1.00 8,785 8,785 PROD2 DRILL CIRC P Circ'd 30 bbl weighted hi-vis sweep w/ 130 rpm, 620 gpm while reciprocating. Noted 10% increase in cuttin s. 21:30 21:45 0.25 8,785 8,785 PROD2 RIGMN SVRG P Lubricated rig, blocks, TD, and crown. Monitored well, static. 21:45 23:00 1.25 8,785 10,733 PROD2 DRILL WPRT P RIH from 8,785' to 10,733' MD and filled DP. 23:00 00:00 1.00 10,733 11,476. PROD2 DRILL WPRT P Washed and reamed in hole from 10,733' to 11,476' MD w! 70 rpm, 426 m, 1600 si. 05/19/2006 00:00 06:30 -6.50 11,476 16,692 PROD2 DRILL WPRT P Cont'd wash and ream to bottom from 11,476' to 16,692' MD. 06:30 08:00 1.50 16,692 16,692 PROD2 DRILL CIRC P Pumped 30 bbl weighted hi-vis sweep around w/ 620 gpm, 130 rpm, while reci rocatin throu hout. 08:00 09:00 1.00 16,692 16,692 PROD2 DRILL OTHR P Displaced MOBM to SFOBM with a total of 588 bbl @ 8.7 ppg. Chased dis lacement with 155 bbl OBM. 09:00 12:00 3.00 16,692 13,272 PROD2 DRILL TRIP P POOH on elevators from 16,692' to 13,272' MD w/ no robiems. :~~~r: ~?~ ~f ~~~ ~, Time Logs - -- - - ^ate From...... To Dur S._~epth E Depth_Ph~se Code Subcod_e_ T -OM 05/19/2006 12:00 13:30 1.50 13,272 8,766 PROD2 DRILL TRIP P Held PJSM and cont'd to POOH from 13,272' to 8,766' MD. Open hole and window pulled slick. Monitored well, static. 13:30 16:30 3.00 8,766 446 PROD2 DRILL TRIP P Cont'd to POOH from 8,766' to HWDP. Monitored well, static. Diplacement Ion a total of 13 bbls. 16:30 18:00 1.50 446 81 PROD2 DRILL PULD P UD HWDP, and jars. Pumped and flushed MWD tools w/ 15 bbls clean mineral oil. UD 3 NMFDCs and float sub. 18:00 19:00 1.00 81 81 PROD2 DRILL PULD P Downloaded MWD. 19:00 20:00 1.00 81 0 PROD2 DRILL PULD P UD MWD, broke bit, cleaned and UD geo-pilot. Cleaned and cleared rig floor. P/U mousehole. 20:00 22:30 2.50 0 0 COMPZ DRILL PULD P Held PJSM and UD 20 stds 5" g-105 DP in mousehole. UD mousehole. 22:30 23:30 1.00 0 0 COMPZ RIGMN SVRG P Held PJSM. Cut and. slipped 73' DL. Ins ected brakes and ad'usted. 23:30 00:00 0.50 0 0 COMPZ CASIN( RURD P R/U to run 5.5" liner. 05/20/2006 00:00 00:45 0.75 0 0 COMPZ CASIN( RURD P Cont'd to R/U casing equip. Held PJSM for runiin 5.5" liner. 00:45 08:30 7.75 0 7,480 COMPZ CASIN( RNCS P Run 5.5" liner as per detail w/ 181 jts in hole (1st 85 jts BTCM and last 96 jts Hydril 521). Ran 125 roller centralizers, 35 hydroform centralizers, and 21 constrictor packers (no centralizers on constrictor 'ts 08:30 09:00 0.50 7,480 7,494 COMPZ CASIN( RNCS P M/U HR liner setting sleeve w/ associated u s and crossover. 09:00 12:45 3.75 7,494 11,937 COMPZ CASIN( RUNL P Held PJSM. Ran liner on DP from 7494' to 11,937' MD. Worked pipe through tight spot @ 11,300' MD. Garnered data for T&D analysis at intervals. 12:45 13:15 0.50 11,937 12,924 COMPZ CASIN( RUNL P Held PJSM. Cont'd to run liner of DP to 12,924' MD. Pumped and rotated through tight spot @ 11,937. Slack off weight went to zero @ 12,924'. Begin to rotate liner down. 13:15 20:45 7.50 12,924 16,548 COMPZ CASIN( RUNL P Rotated liner in hole from 12,924' to 16,538' MD w/ 20 rpm, 106 gpm, 200 psi. Worked past tight spots 14,521' and 15,891'. P/U single and rotated to 16,562 w/ PUW=190K ROT=70K. Pulled up in tension to 16,548' MD. ~'~~e 13 of 23 Time Logs Date _ From To Dur S_epth E Depth Phase Code Subcode T_ :OM 05/20/2006 20:45 21:45 1.00 16,548 9,053 COMPZ CASIN( OTHR P Dropped ball and pumped down (Note:ball seated @ 2031 stks 200 stks over calculated). Pressured up to 3000 psi and slacked off to 45K. Pressured up to 4150 psi and sheared out. PUW decreased to 165K from 190K. Liner in place @ 21:00 hrs w/ top @ 9,053' MD and bottom @ 16,548' MD. Monitored well, static. 21;45 22:15 0.50 9,053 8,757 COMPZ DRILL TRIP P UD single and POOH w/ DP to 8,757 MD (approx 100' above window). Cleaned floor and P/U mousehole. 22:15 00:15 2.00 8,757 8,757 COMPZ DRILL PULD P Held PJSM. UD 60 jts of G-1 Q5 DP from derrick using mousehole to provide more workspace on the rig floor. 00:15 00:45 0.50 8,757 8,757 COMPZ DRILL OWFF P Monitored well, static. Pumped dry 'ob for TOOH. 05/21/2006 00:00 03:15 3.25 8,757 0 COMPZ DRILL TRIP P POOH from 8,745' to surface. UD liner runnin tool 03:15 03:45 0.50 0 0 COMPZ DRILL OTHR P Cleaned and cleared rig floor. P/U Baker whipstock retrieval tools from beaver slide. 03:45 04:30 0.75 0 67 COMPZ DRILL PULD P Held PJSM. M/U whipstock retrieval tools. 04:30 07:30 3.00 67 7,096 COMPZ DRILL TRIP P RIH from 6T to 7,096' MD. 07:30 08:00 0.50 7,096 7,096 COMPZ RIGMN SVRG P Service top drive. 08:00 08:30 0.50 7,096 7,096 COMPZ RIGMN SVRG P Held PJSM. C/O swivel packing on to drive. 08:30 09:30 1.00 7,096 8,829 COMPZ DRILL TRIP P Cont'd to RIH from 7,096' to 8,829' MD. PUW=147K SOW=65K. 09:30 10:00 0.50 8,829 8,829 COMPZ DRILL OTHR P Hooked whipstock @ 8,829' MD. Cocked jars and pulled to 175K, 210K, 230K and jars fired w/o shearing. Pulled to 250K sheared and whipstock free. PUW=150K. 10:00 12:00 2.00 8,829 8,800 COMPZ DRILL CIRC P CBU @ 8,800' w/ 88 spm, 295 gpm, 500 psi. Staged pump down to 6.5 bpm due to fluid losses w/ 300 psi, 66 s m. Lost total of 35 bbls fluid. 12:00 15:30 3,50 8,800 200 COMPZ DRILL TRIP P POOH from 8,800' to whipstock assembl .Monitored well, static. 15:30 17:30 2.00 200 0 COMPZ DRILL PULD P UD BHA and whipstock assembly. Noted roll off to the right on whipstock more noticable than usual. 17:30 18:30 1.00 0 0 COMPZ CASIN( RURD P P/U and R/U casing tools 18:30 21:30 3.00 0 277 COMPZ CASIN( RURD P P/U 5.5" hook hanger assembly w/ ECP and inner string MWD. Oriented high side'180? out from hook. Cleared ri floor of tools and ton s. P~~~ ~~ c~~f ~3 .Time Logs __- --- - -_ Date From To Dur 5. epth E. Depth Phase Code Subcode i - - - --- OM __ -- - 05/21/2006 21:30 00:00 2.50 277 4,267 COMPZ CASIN( RUNL P RIH w/ 5.5" hook hanger assembly on DP. SHT MWD @ 738' MD. Confd to RIH to 4,267' MD. Filled DP @ 3,710' M D. 05/22/2006 00:00 02:45 2.75 4,267 9,089 COMPZ DRILL TRIP P Cont'd to RIH w/hook hanger. assembly to 8,736' MD. Oriented to hi h side and RIH to 9,089' MD. 02:45 06:00 3.25 9,089 9,089 COMPZ DRILL OTHR P Hooked hanger w/ hook @ 8,846' (5' deep to talc) w/shoe @ 9,087' MD. Set down 15K, toolface went from 7? left to 35? right, unhooked and toolface went back to the left, rehooked and toolface back to 35? right. Hook confirmed. P/U and rotate 180? to slide 10' past hook. All went well, pull back up and rotated 180? to hook final time. Hooked again toolface went back to 35?, attempted to set down. Weight went up to 12K and came off. Could not re-establish hook. PUW=160K SOW=65K 06:00 10:30 4.50 9,089 277 COMPZ DRILL TRIP T Monitored well, static. POOH from 9,089' to BHA @ 277'. inspected hook hanger; welds had failed between hook and han er bod . 10:30 12:00 1.50 277 231 COMPZ DRILL PULD T Cleared and cleaned rig floor. R/U casing tongs and slim hole handling equipment. Broke out hook hanger, and slimhole MWD. UD hook han er. 12:00 13:00 1.00 231 231 COMPZ RIGMN SVRG P Held PJSM. Serviced rig including: draw works couplings, over ride, clutch, top drive, adjusted and inspected brakes. Washed pipe and blocks. 13:00 18:00 5.00 231 231 COMPZ DRILL WOEQ T Waiting on new liner hanger. Monitored well on trip tank w/ 2.8 bbl losses. 18:00 19:00 1.00 231 231 COMPZ DRILL PULD T P/U and M/U new 5.5" hook hanger (different model) assembly and oriented. Cleared ri floor. 19:00 23:00 4.00 231 8,733 COMPZ DRILL TRIP T RIH w/hook hanger assembly. SHT MWD @ 644' MD. Cont'd to RIH to 8,733' MD (filled. pipe @ 3,981' and 6,831' . Broke circ 8,733' MD 23:00 00:00 1.00 8,733 8,733 COMPZ DRILL OTHR T Oriented hook hanger to high side. PUW=150K SOW=70K 8,733 COMPZ DRILL 05/23/2006 00:00 02:15 2.25 8,733 9,093 COMPZ DRILL OTHR P Orient to hi side at 8733'. RIH to 9041' and tagged NoGo in mother bore. PU to 8828' turn 3/4 and run back into mother bore. Turn another 3/4 POOH to 8828, RIH and enter into D lat. Hook hanger at 9039' MD (Shoe depth). Pull up and rehook. Pull up, rotate 1/2 turn. Rehook and set down 30K on hook han er. PU=165K, S0=70K. ---- _ ~ ~ ~ P~~~ 21 ~f 23 Time Logs Date From To Dur epth E. Depth Phase Code Subcode T ~OM 05/23/2006 02:15 03:15 1.00 9,093 9,093 COMPZ DRILL OTHR P Drop ball and pump down at 36 spm, 130 m, 900 si. 03:15 04:00 0.75 9,093 9,093 COMPZ DRILL OTHR P Pressure up to 2700 psi to inflate ECP. Release Hook Hanger, attempt to shear pump out sub with no success. Pull out of Hook and establish circulation. 04:00 08:30 4.50 9,093 100 COMPZ DRILL TRIP P Monitor well, PU=160K. POOH to 100'. Calculated fill=70.7 bbls, actual 79.1 bbls. 08:30 09:30 1.00 100 0 COMPZ DRILL PULD P Service break and LD hook hanger running tools, slimhole MWD, & wash i e. 09:30 10:30 1.00 0 0 COMPZ DRILL PULD P Clear and clean rig floor, PU LEM tools from beaver slide. 10:30 11:00 0.50 0 0 COMPZ CASIN( RURD P PJSM and RU casing equipment. 11:00 12:00 1.00 0 130 COMPZ CASIN( PUTB P PJSM- MU LEM assembly: bent joint, 1 jt of 4.5" tbg, 2 9.8' pup joints, 1 jt 4.5" tb , &LEM. 12:00 14:00 2.00 130 215 COMPZ CASIN( PUTB P PJSM with other crew. PU LEM, seal bore, Inner string and SLZXP packer. Clear floor. 14:00 14:45 0.75 215 215 COMPZ RIGMN RGRP T Repair broken hydraulic nipple (power ton su I 14:45 19:00 -4.25 215 8,781 COMPZ CASIN( RUNL P RIH with LEM assembly. fill drill pipe at 3010', 5834', 8211', break circulation at 8781'. PU=145K, S0=75K. 19:00 21:30 2.50 8,781 8,554 COMPZ CASINO RUNL P Wash in 8781' to 8970'. PU single and land at 8976' MD & stack 40K over. PU 20K over to confirm latch. Drop ball and pump down at 4 bpm, 300 psi. Seat at 1477 stks. Pressure up to 3000 psi to set packer. Increase pressure to 4000 psi to release LEM. Pressure up backside to .1000 psi and test packer for 5 mins. PU 20' release dogs on running tool. SO and confirm top of SLZXP at 8976' MD. POOH 4 stds & LD single to 8554' MD. Blow down to drive and clean ri floor. 21:30 00:00 2.50 8,554 8,554 COMPZ DRILL PULD P PJSM. Lay down G-105 DP out of derrick in mouse hole. 72 'ts down . 05/24/2006 00:00 01:15 -1.25 8,554 7,000 COMPZ DRILL PULD P Cont o LD 5" DP 51 jts. 01:15 05:45 4.50 7,000 675 COMPZ DRILL PULD P Monitor well: static. Pump dry job. POOH, clean OBM off super sliders and stand back. 05:45 07:15 1.50 675 0 COMPZ DRILL PULD P Serivice break and LD LEM running tools, 5 jts of 2 3/8" inner string and mule shoe. 07:15 07:45 0.50 0 0 COMPZ DRILL OTHR P Clear and clean rig floor. 07:45 08:15 0.50 0 0 COMPZ DRILL PULD P Pull wear bushing ~ ~ ~ ~ __ Page ~2 of 23 Time Logs Date Fro~~i To Dur epth E Depth Phase Code Subcode OM ~ ___ 05/24/2006 08:15 _ 09:15 1.00 0 0 COMPZ RIGMN SVRG P Slip and cut 89' drilling line 09:15 09:45 0.50 0 0 COMPZ RPCOti RURD P PJSM- RU & run casing equipment. 09:45 12:00 2.25 0 1,044 COMPZ RPCOh RCST P PJSM- RIH with 4.5" 12.6# IBT com letion tubin .Ran 34 'oint. 12:00 19:30 7.50 1,044 8,794 COMPZ RPCOh RCST P PJSM- Continue to RIH with 4.5" completion tubing per detail to 8793.55'. 283 joints total, PU=85K, S0=58K. 19:30 20:30 1.00 8,798 8,794 COMPZ RPCOh HOSO P PU 2 joints from shed, tag up locator at 8771.5'. LD 3 joints, PU & space out with 9.81' pup, and RIH with jt 283. PU and landing joint. MU hanger and land tb 23K on han er . 20:30 22:00 1.50 0 0 COMPZ RPCOh NUND P Run lock down screws. Test upper and lower hanger seals to 5000 psi for 10 mins. LD landin 'oint and clear floor. 22:00 23:00 1.00 0 0 COMPZ WELCT BOPE P PJSM-Change out lower rams to 7 5/8" 23:00 00:00 1.00 0 0 COMPZ WELC7 NUND P PJSM- Nipple down BOPE. 05/25/2006 00:00 00:30 0.50 0 0 COMPZ WELCT NUND P Cont N/D BOPE. 00:30 03:15 2.75 0 0 COMPZ WELCT NUND P PJSM: NU Tree and test void to 5000 psi for 10 mins. Install SSV valve, test tree and all valves to 5000 psi for 10 min. Pull two wa check. 03:15 04:00 0.75 0 0 COMPZ RPCOh FRZP P PJSM: RU Little Red. SIMOPS PJSM. Displace well with 643 bbls of diesel. LD 5" Drill i e from derrick. 04:00 07:00 3.00 0 0 COMPZ RPCOh FRZP P Displace well with 643 bbls of diesel at 5 bpm, 550 psi, while LD 5" drill pipe from derrick. 07:00 08:30 1.50 0 0 COMPZ RPCOI~ RURD P Rig down little red, RU scaffolding in cellar. RU lubricator set BPV. Install blind flan es. Secured well. 08:30 12:00 3.50 0 0 COMPZ DRILL PULD P Continue to LD 5" drill pipe. Total of 159 'oints. 12:00 18:30 6.50 0 0 COMPZ DRILL PULD P Cont to LD 5" drill pipe and super sliders (total of 129 joints). Clear rig floor. 18:30 20:00 1.50 0 0 COMPZ MOVE RURD P Rig down. Pull skate rail. Secure rig .. floor. R/D pipe shed. Blow down water lines. } ~ l~~~Q ~~ ~t dil _ _ Halliburton Company Survey Report Company: ConocoPhillips Alaska Inc. Uate: 6/5/2006 'l'ime: 16:34:20 Page: 1 Field: Kuparuk River Unif Co-ordinatclNE) Reference: Well: 1 J-184, True North Site: Kuparuk 1J Pad Vertical (TVD) Reference: 1J-184L1: 109.0 Well: 1J-184 Section (VS) Reference: Well (O:OON,O.OOE,1 80.OOAzi) Wellpath: 1J-184L1 Survey Calculation M ethod: Minimum Curvature Db: Oracle -- Field: Kuparuk River Unit - North Slope Alaska United States Map System:US State Plane Coordinate System 1927 Map Zone: Alaska, Zone 4 Geo Datum: NAD27 (Clarke 1866) Coordinate Syste m: Well Centre Sys Datum: Mean Sea Level Geomagnetic Model: bggm2005 Well: 1 J-184 Slot Name: ~ Well Position: +N/-S -577.27 ft Northing: 5945342. 40 ft Latitude: 70 15 40.580 N +E/-W -4.92 ft Easting : 558789. 54 ft Longitude: 149 31 29.150 W Position Uncertainty: 0.00 ft Wellpath: 1J-184L1 Drilled From: 1J-184 500292330560 Tie-on Depth: 8759.26 ft Current Datum: 1 J-184L1: Height 109. 00 ft Above System Datum: Mean Sea Level Magnetic Data: 4/21/2006 Declination: 24.11 deg ', Field Strength: 57565 nT Mag Dip Angle: 80.77 deg Vertical Section- Depth From (TVD) +N/-S +E/-W Direction ft 28.00 ft - 0.00 -- - ft 0.00 deg 180.00 - _~ r Survey Program for Det;nitive Wellpath Date: 6/5/2006 Validated: No Version: 5 Actual From To Survey Toolcode Tool Name ft ft 75.00 442.00 1J-184 gyro ( 75.00-442.00) (0) CB-GYRO-SS Camera based gyro single shot 473.59 8759.26 1J-184 (473.59-17838.72) (0) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 8825.00 16661.93 1J-184L1 (88 25.00-1666 1.93) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC Survey _ __ Mll Incl Azim TVD Sys TVD NIS E/W hlapN MapE Tool ft deg deg ft ft ft ft ft ft __ 28.00 0.00 0.00 28.00 -81.00 0.00 0.00 _ 5945342.40 • 558789.54 • ____ TIE LINE 75.00 0.21 260.98 75.00 -34.00 -0.01 -0.09 5945342.39 558789.46 CB-GYRO-SS 168.00 0.19 101.32 168.00 59.00 -0.07 -0.10 5945342.33 558789.44 CB-GYRO-SS 259.00 0.29 98.70 259.00 150.00 -0.13 0.27 5945342.27 558789.81 CB-GYRO-SS 350.00 0.43 224.27 350.00 241.00 -0.41 0.26 5945341.99 558789.81 CB-GYRO-SS 442.00 2.44 205.60 441.96 332.96 -2.43 -0.82 5945339.97 558788.73 CB-GYRO-SS 473.59 3.15 200.78 473.52 364.52 -3.85 -1.42 5945338.54 558788.15 MWD+IFR-AK-CAZ-SC 563.10 6.02 204.15 562.73 453.73 -10.43 -4.22 5945331.94 558785.41 MWD+IFR-AK-CAZ-SC 654.69 10.84 205.72 653.31 544.31 -22.58 -9.92 5945319.75 558779.80 MWD+IFR-AK-CAZ-SC 746.31 17.32 204.97 742.13 633.13 -42.72 -19.43 5945299.53 558770.45 MWD+IFR-AK-CAZ-SC 839.71 20.40 200.61 830.50 721.50 -70.57 -31.03 5945271.59 558759.06 MWD+IFR-AK-CAZ-SC li 932.47 22.39 200.63 916.87 807.87 -102.24 -42.95 5945239.84 558747.40 MWD+IFR-AK-CAZ-SC 1025.56 25.34 202.42 1001.99 892.99 -137.26 -56.80 5945204.72 558733.82 MWD+IFR-AK-CAZ-SC 1117.73 28.60 203.66 1084.13 975.13 -175.71 -73.18 5945166.14 558717.75 MWD+IFR-AK-CAZ-SC 1212.00 30.79 204.10 1166.01 1057.01 -218.40 -92.08 5945123.30 558699.17 MWD+IFR-AK-CAZ-SC 1303.50 32.41 201.59 1243.95 1134.95 -262.59 -110.67 5945078.98 558680.93 MWD+IFR-AK-CAZ-SC !i 1397.78 36.51 201.58 1321.66 1212.66 -312.18 -130.29 5945029.24 558661.70 MWD+IFR-AK-CAZ-SC i 1490.70 39.62 200.57 1394.81 1285.81 -365.64 -150.87 5944975.63 558641.54 MWD+IFR-AK-CAZ-SC i 1582.91 44.47 198.51 1463.27 1354.27 -423.83 -171.47 5944917.29 558621.40 MWD+IFR-AK-CAZ-SC 1676.13 48.49 197.49 1527.45 1418.45 -488.11 -192.34 5944852.85 558601.04 MWD+IFR-AK-CAZ-SC 1768.41 50.04 197.87 1587.67 1478.67 -554.73 -213.57 5944786.08 558580.32 MWD+IFR-AK-CAZ-SC 1860.73 52.75 197.06 1645.27 1536.27 -623.54 -235.21 5944717.10 558559.22 MWD+IFR-AK-CAZ-SC 1953.20 56.91 195.32 1698.52 1589.52 -696.12 -256.26 5944644.37 558538.75 MWD+IFR-AK-CAZ-SC 2045.99 62.34 193.70 1745.43 1636.43 -773.60 -276.27 5944566.74 558519.34 MWD+IFR-AK-CAZ-SC 2138.27 67.92 190.96 1784.23 1675.23 -855.35 -294.10 5944484.86 558502.15 MWD+IFR-AK-CAZ-SC '; 2230.74 72.47 188.70 1815.55 1706.55 -941.05 -308.92 5944399.06 558488.00 MWD+IFR-AK-CAZ-SC I, 2323.93 75.02 184.96 1841.64 1732.64 -1029.86 -319.54 5944310.18 558478.08 MWD+IFR-AK-CAZ-SC ~~ 2414.36 74.93 184.40 1865.09 1756.09 -1116.91 -326.67 5944223.09 558471.63 MWD+IFR-AK-CAZ-SC Halliburton Company Survey Report Compan~~: CortocoPhillips Alaska Inc. Uate: 6/5/2006 `l'ime: 16:3420 Page: 2 Field: Ku paruk River Unit Co-ord iuate(NE) Re ference: Well: 1J-184, True North Site: Ku paruk 1J Pad Vertica l (TVD) Refe rence: 1J-184L1: 109 .0 Yell: 9J-184 Section (VS) Referen ce: Well (O.OON,O.OOE, 180:OOAzi) 14`ellpath: 1J- 184L1 Su rve}' Calcula tion Method: Minimum Curv ature llb: Oracle Survc~' 6ID __ _ Incl _ Azim 7tiD _ SysTVD N/S E/R' MapN __ ti1apE Tool ', ft deg deg ft ft ft ft ft ft 2505. 48 75.28 181. 86 1888. 51 1779. 51 -1204 .82 -331 .47 5944135 .14 558467. 51 MWD+IFR-AK-CAZ-SC 2599. 69 75.14 181. 93 1912. 56 1803. 56 -1295 .86 -334 .49 5944044 .09 558465. 21 MWD+IFR-AK-CAZ-SC 'i ~ li 2692. 15 76.08 180. 00 1935. 54 1826. 54 -1385 .40 -335 .99 5943954 .55 558464. 41 MWD+IFR-AK-CAZ-SC ', ~~ 2785. 13 77.47 179. 49 1956. 81 1847. 81 -1475 .91 -335 .59 5943864 .05 558465. 52 MWD+IFR-AK-CAZ-SC ', 2879. 16 76.69 180. 48 1977. 84 1868. 84 -1567 .56 -335 .56 5943772 .42 558466. 26 MWD+IFR-AK-CAZ-SC ' 2971. 91 76.83 180. 39 1999. 08 1890. 08 -1657 .84 -336 .25 5943682 .14 558466. 28 MWD+IFR-AK-CAZ-SC 3064. 99 78.16 180. 02 2019. 23 1910. 23 -1748 .71 -336 .57 5943591 .28 558466. 66 MWD+IFR-AK-CAZ-SC 3156. 67 79.03 179. 75 2037. 36 1928. 36 -1838 .58 -336 .39 5943501 .42 558467. 54 MWD+IFR-AK-CAZ-SC 3250. 05 77.99 182. 15 2055. 97 1946. 97 -1930 .07 -337 .90 5943409 .94 558466. 75 MWD+IFR-AK-CAZ-SC 3342. 74 76.65 182. 83 2076. 31 1967. 31 -2020 .41 -341. 83 5943319 .58 558463. 52 MWD+IFR-AK-CAZ-SC 3436. 27 71.61 182. 69 2101. 88 1992. 88 -2110 .24 -346. 16 5943229 .72 558459. 89 MWD+IFR-AK-CAZ-SC 3528. 37 71.44 182. 27 2131. 07 2022. 07 -2197 .51 -349. 94 5943142 .43 558456. 80 MWD+IFR-AK-CAZ-SC 3621. 07 71.99 181. 80 2160. 15 2051. 15 -2285 .48 -353. 07 5943054 .46 558454. 36 MWD+IFR-AK-CAZ-SC ~ 3713. 58 78.21 179. 99 2183. 93 2074. 93 -2374 .82 -354. 44 5942965 .12 558453. 68 MWD+IFR-AK-CAZ-SC ~I 3805. 22 75.95 180. 56 2204. 42 2095. 42 -2464 .13 -354 .87 5942875 .81 558453. 95 MWD+IFR-AK-CAZ-SC ~ 3895. 79 79.49 180. 15 2223. 68 2114. 68 -2552 .61 -355. 42 5942787 .34 558454. 10 MWD+IFR-AK-CAZ-SC i 3936. 46 79.17 179. 89 2231. 21 2122. 21 -2592 .58 -355 .43 5942747 .37 558454. 39 MWD+IFR-AK-CAZ-SC 'i 4032. 62 78.30 180. 66 2249. 99 2140. 99 -2686 .88 -355 .88 5942653 .08 558454. 68 MWD+IFR-AK-CAZ-SC 4126. 37 78.73 180. 70 2268. 66 2159. 66 -2778 .75 -356 .97 5942561 .22 558454. 31 MWD+IFR-AK-CAZ-SC ~, 4219. 08 78.91 180. 43 2286. 63 2177. 63 -2869 .70 -357 .87 5942470 .27 558454. 12 MWD+IFR-AK-CAZ-SC 4312. 04 78.40 181. 40 2304. 92 2195. 92 -2960 .83 -359 .32 5942379 .14 558453. 38 MWD+IFR-AK-CAZ-SC 4405. 60 78.10 181. 92 2323. 97 2214. 97 -3052 .39 -361 .98 5942287 .57 558451. 44 MWD+IFR-AK-CAZ-SC 4498. 03 76.60 182. 50 2344. 22 2235. 22 -3142 .50 -365 .45 5942197 .44 558448. 66 MWD+IFR-AK-CAZ-SC 4590. 13 76.59 181. 02 2365. 57 2256. 57 -3232 .05 -368 .20 5942107 .89 558446. 61 MWD+IFR-AK-CAZ-SC 4682. 10 76.29 181. 56 2387. 13 2278. 13 -3321 .43 -370 .22 5942018 .50 558445. 30 MWD+IFR-AK-CAZ-SC 4775. 26 76.43 181. 55 2409. 10 2300. 10 -3411 .93 -372 .67 5941927 .99 558443. 55 MWD+IFR-AK-CAZ-SC 4867. 88 77.36 180. 19 2430. 10 2321. 10 -3502 .13 -374 .04 5941837 .80 558442. 88 MWD+IFR-AK-CAZ-SC ~i 4960. 59 76.40 181. 78 2451. 15 2342. 15 -3592 .40 -375 .59 5941747 .52 558442. 04 MWD+IFR-AK-CAZ-SC ~~ 5052. 83 76.48 181. 48 2472. 77 2363. 77 -3682 .03 -378 .14 5941657 .88 558440. 19 MWD+IFR-AK-CAZ-SC 5145. 75 76.27 182. 97 2494. 66 2385. 66 -3772 .26 -381 .65 5941567 .63 558437. 39 MWD+IFR-AK-CAZ-SC '' 5236. 35 76.59 182. 93 2515. 92 2406. 92 -3860 .22 -386 .18 5941479 .66 558433. 54 MWD+IFR-AK-CAZ-SC 'i 5328. 91 77.44 183. 50 2536. 72 2427. 72 -3950 .27 -391 .24 5941389 .58 558429. 19 MWD+IFR-AK-CAZ-SC 5422. 68 77.21 184. 60 2557. 30 2448. 30 -4041 .52 -397 .70 5941298 .28 558423. 44 MWD+IFR-AK-CAZ-SC '' 5516. 89 76.72 184. 39 2578. 54 2469. 54 -4133 .02 -404. 89 5941206 .74 558416. 96 MWD+IFR-AK-CAZ-SC i 5608. 62 75.66 184. 14 2600. 44 2491. 44 -4221 .85 -411 .52 5941117 .87 558411. 03 MWD+IFR-AK-CAZ-SC i 5700. 69 75.52 183. 78 2623. 35 2514. 35 -4310 .81 -417 .68 5941028 .87 558405. 57 MWD+IFR-AK-CAZ-SC 5794. 10 75.46 183. 79 2646. 76 2537. 76 -4401 .05 -423 .65 5940938 .60 558400. 30 MWD+IFR-AK-CAZ-SC I' 5887. 06 75.74 184. 24 2669. 87 2560. 87 -4490 .87 -429 .95 5940848 .75 558394. 70 MWD+IFR-AK-CAZ-SC 5980. 52 76.84 183. 23 2692. 03 2583. 03 -4581 .47 -435 .86 5940758 .11 558389. 50 MWD+IFR-AK-CAZ-SC 'I 6073. 09 76.05 182. 48 2713. 72 2604. 72 -4671 .35 -440 .35 5940668 .21 558385. 72 MWD+IFR-AK-CAZ-SC ', 6165. 98 76.05 181. 84 2736. 12 2627. 12 -4761 .43 -443 .74 5940578 .11 558383. 02 MWD+IFR-AK-CAZ-SC i ~ 6257. 51 75.98 181. 23 2758. 24 2649. 24 -4850 .22 -446 .12 5940489 .32 558381. 34 MWD+IFR-AK-CAZ-SC ~ 6350. 69 76.77 180. 40 2780. 19 2671. 19 -4940 .76 -447 .41 5940398 .77 558380. 76 MWD+IFR-AK-CAZ-SC ~ ~ 6444. 18 77.01 179. 38 2801. 39 2692. 39 -5031 .81 -447 .23 5940307 .73 558381. 64 MWD+IFR-AK-CAZ-SC ~ ~ 6536. 15 76.64 181. 09 2822. 36 2713. 36 -5121 .36 -447 .60. 5940218 .20 558381. 97 MWD+IFR-AK-CAZ-SC 6628. 42 76.47 180. 14 2843. 81 2734. 81 -5211 .09 -448 .56 5940128 .46 558381. 71 MWD+IFR-AK-CAZ-SC ~I 6720. 25 75.60 180. 68 2865. 97 2756. 97 -5300 .21 -449 .20 5940039 .36 558381. 77 MWD+IFR-AK-CAZ-SC ~, 6813. 01 76.16 182. 94 2888. 60 2779. 60 -5390 .11 -452 .04 5939949 .44 558379. 63 MWD+IFR-AK-CAZ-SC 6905. 31 76.75 181. 27 2910. 22 2801. 22 -5479 .78 -455 .34 5939859 .76 558377. 04 MWD+IFR-AK-CAZ-SC ~i 6998. 49 77.13 181. 17 2931. 28 2822. 28 -5570 .53 -457 .27 5939769 .01 558375. 81 MWD+IFR-AK-CAZ-SC 7091. 36 76.33 181. 25 2952 .60 2843. 60 -5660 .90 -459 .18 5939678 .63 558374. 61 MWD+IFR-AK-CAZ-SC j 7183. 00 76.43 182. 04 2974 .18 2865. 18. -5749 .92 -461 .74 5939589 .60 558372. 75 MWD+IFR-AK-CAZ-SC Halliburton Company, Survey Report Company: ConocoPhillips Alaska Inc. Date: 6/5/2006 Time: 16 :34:2D Page: 3 Field: Ku paruk River Unit Co-ordinate(NF) Re ference: WeIC 1J-184, True North Site: Ku paruk 1J Pad, Vertical (TVD)Refe rence: 1J-184E_1: 109.0 ' Well: 1J- 184 Section (VS) Reference: Well ( O.OON,O.OOE, 180.OOAzi) ' ~Vellpath: 1 J-184L1 Survey Calculation Method: Minim um Curvature Db: Oracle Survcv MD Incl Azim "TVD Sys ~I'VD N/S _ E/W _ MapN ti1apE Tool ft deg deg ft ft ft ft ft ft 7276 .13 77. 38 182. 13 2995. 28 2886. 28 -5840.57 -465.04 5939498. 94 558370.16 MWD+IFR-AK-CAZ-SC ' 7368 .84 77. 05 182. 57 3015 .79 2906. 79 -5930.91 -468.74 5939408. 59 558367.15 MWD+IFR-AK-CAZ-SC ' 7461 .78 77 .54 182. 86 3036 .23 2927. 23 -6021.47 -473.04 5939318. 00 558363.57 MWD+IFR-AK-CAZ-SC 7554 .44 77 .87 182. 25 3055 .96 2946. 96 -6111.91 -477.07 5939227. 54 558360.24 MWD+IFR-AK-CAZ-SC 7646 .15 77 .25 182. 56 3075 .72 2966. 72 -6201.39 -480.83 5939138. 04 558357.18 MWD+IFR-AK-CAZ-SC ' I 7739 .18 76 .30 182. 63 3097 .00 2988. 00 -6291.86 -484.93 5939047. 55 558353.79 MWD+IFR-AK-CAZ-SC I, 7830 .57 75 .71 182. 34 3119 .10 3010. 10 -6380.45 -488.78 5938958. 94 558350.63 MWD+IFR-AK-CAZ-SC 7924 .67 75 .40 181. 52 3142 .58 3033. 58 -6471.52 -491.85 5938867. 85 558348.27 MWD+IFR-AK-CAZ-SC ' 8016 .02 75 .65 181. 52 3165 .41 3056 .41 -6559.94 -494.19 5938779. 43 558346.62 MWD+IFR-AK-CAZ-SC ', 8108 .35 74 .97 182. 65 3188 .83 3079 .83 -6649.19 -497.44 5938690. 16 558344.07 MWD+IFR-AK-CAZ-SC II 8200 .91 75 .16 182. 58 3212 .68 3103 .68 -6738.53 -501.52 5938600. 80 558340.69 MWD+IFR-AK-CAZ-SC 8292 .53 75 .09 182. 54 3236 .20 3127 .20 -6827.00 -505.48 5938512. 32 558337.42 MWD+IFR-AK-CAZ-SC 8387 .93 75 .80 181. 91 3260 .17 3151 .17 -6919.26 -509.06 5938420. 04 558334.56 MWD+IFR-AK-CAZ-SC 8480 .98 76 .94 181. 78 3282 .10 3173 .10 -7009.64 -511.97 5938329. 65 558332.35 MWD+IFR-AK-CAZ-SC 8574 .70 77. 36 182. 53 3302 .95 3193 .95 -7100.95 -515.41 5938238. 32 558329.63 MWD+IFR-AK-CAZ-SC !i 8665 .93 78. 66 182. 78 3321 .90 3212. 90 -7190.09 -519.54 5938149. 16 558326.19 MWD+IFR-AK-CAZ-SC ~ 8759 .26 80 .19 181. 84 3339 .03 3230. 03 -7281.76 -523.24 5938057. 48 558323.21 MWD+IFR-AK-CAZ-SC ''~ .., 8825 8937 .00 .38 80 84 .23 .45 182. 183. 84 53 3350 3365 .20 ~ .18 3241 3256 .20 .18 -7346.49 -7457.67 -525.88 -532.07 5937992. 5937881. 74 52 558321.07 558315.75 MWD+IFR-AK-CAZ-SC MWD+IFR-AK-CAZ-SC 9030 .48 86 .37 182. 47 3372 .63 3263 .63 -7550.34 -536.93 5937788. 83 558311.62 MWD+IFR-AK-CAZ-SC ': 9121 .58 88 .90 180. 50 3376 .39 3267 .39 -7641.32 -539.29 5937697. 84 558309.97 MWD+IFR-AK-CAZ-SC i 9215 .21 91 .31 179. 83 3376 .22 3267 .22 -7734.94 -539.56 5937604. 23 558310.44 MWD+IFR-AK-CAZ-SC t 9309 .54 92 .34 176. 14 3373 .21 3264 .21 -7829.14 -536.24 5937510. 06 558314.48 MWD+IFR-AK-CAZ-SC '~ 9402 .24 92 .04 174. 95 3369 .67 3260 .67 -7921.49 -529.05 5937417. 78 558322.40 MWD+IFR-AK-CAZ-SC 9492 .82 92 .10 174. 93 3366 .40 3257 .40 -8011.66 -521.06 5937327. 68 558331.09 MWD+IFR-AK-CAZ-SC '~, 9586 .68 91 .85 173. 80 3363 .16 3254 .16 -8105.01 -511.85 5937234. 42 558341.02 MWD+IFR-AK-CAZ-SC ', 9678 .46 90 .92 175. 31 3360 .95 3251 .95 -8196.35 -503.15 5937143. 16 558350.44 MWD+IFR-AK-CAZ-SC ' 9771 .28 90 .93 175. 96 3359 .45 3250 .45 -8288.89 -496.08 5937050. 69 558358.23 MWD+IFR-AK-CAZ-SC ' 9863 .95 90. 31 176. 35 3358. 44 3249. 44 -8381.34 -489.87 5936958. 30 558365.16 MWD+IFR-AK-CAZ-SC ' 9957 .29 90. 62 178. 46 3357 .69 3248. 69 -8474.58 -485.64 5936865. 10 558370.11 MWD+IFR-AK-CAZ-SC ~I ' 10049 .75 90. 12 179. 59 3357 .09 3248 .09 -8567.02 -484.07 5936772. 69 558372.41 MWD+IFR-AK-CAZ-SC ~' ' 10143 .39 89 .44 179. 89 3357 .45 3248 .45 -8660.66 -483.64 5936679. 06 558373.56 MWD+IFR-AK-CAZ-SC ' 10236 .07 87 .33 179. 46 3360 .06 3251 .06 -8753.29 -483.12 5936586. 44 558374.81 MWD+IFR-AK-CAZ-SC ', 10329 .38 88 .90 178. 96 3363 .13 3254 .13 -8846.54 -481.83 5936493. 22 558376.83 MWD+IFR-AK-CAZ-SC ', 10421 .55 89 .45 177. 91 3364 .46 3255 .46 -8938.67 -479.32 5936401. 12 558380.06 MWD+IFR-AK-CAZ-SC ', 10514 .72 89 .82 178. 98 3365 .05 3256 .05 -9031.80 -476.79 5936308. 02 558383.32 MWD+IFR-AK-CAZ-SC ~ ', 10607 .37 90 .99 181. 39 3364 .40 3255 .40 -9124.44 -477.09 5936215. 39 558383.74 MWD+IFR-AK-CAZ-SC ', 10700 .10 90 .12 181. 84 3363 .50 3254 .50 -9217.12 -479.70 5936122. 70 558381.85 MWD+IFR-AK-CAZ-SC ~~ 10792 .54 89 .50 180. 79 3363 .80 3254 .80 -9309.54 -481.82 5936030. 28 558380.45 MWD+IFR-AK-CAZ-SC 10884 .24 90 .13 179. 98 3364 .10 3255 .10 -9401.23 -482.44 5935938. 59 558380.55 MWD+IFR-AK-CAZ-SC i 10977 .78 91 .24 180. 98 3362 .98 3253 .98 -9494.76 -483.22 5935845. 07 558380.50 MWD+IFR-AK-CAZ-SC ', 11069 .60 92. 66 178. 98 3359. 86 3250. 86 -9586.52 -483.19 5935753. 32 558381.25 MWD+IFR-AK-CAZ-SC 11160 .62 92. 97 179. 84 3355 .39 3246 .39 -9677.43 -482.25 5935662. 43 558382.89 MWD+IFR-AK-CAZ-SC i 11253 .98 92. 84 178. 83 3350 .66 3241 .66 -9770.66 -481.17 5935569. 22 558384.70 MWD+IFR-AK-CAZ-SC 11348 .48 93. 15 177. 29 3345 .72 3236. 72 -9864.97 -477.98 5935474. 94 558388.63 MWD+IFR-AK-CAZ-SC '. 11442 .32 92 .90 177. 91 3340 .77 3231 .77 -9958.60 -474.05 5935381. 36 558393.29 MWD+IFR-AK-CAZ-SC 11535 .43 91 .78 178. 87 3336 .96 3227 .96 -10051.59 -471.44 5935288. 40 558396.63 MWD+IFR-AK-CAZ-SC 11628 .03 91 .11 178. 17 3334 .63 3225 .63 -10144.13 -469.05 5935195. 89 558399.74 MWD+IFR-AK-CAZ-SC 11721 .63 89 .87 176. 70 3333 .83 3224 .83 -10237.63 -464.86 5935102. 44 558404.66 MWD+IFR-AK-CAZ-SC ~ 11813 .73 89 .51 177. 37 3334 .33 3225 .33 -10329.60 -460.10 5935010. 51 558410.14 MWD+IFR-AK-CAZ-SC I' 11906 .35 89 .63 178. 36 3335 .02 3226 .02 -10422.16 -456.65 5934918. 00 558414.31 MWD+IFR-AK-CAZ-SC 12000 .32 89 .20 179. 94 3335 .98 3226 .98 -10516.11 -455.25 5934824. 07 558416.44 MWD+IFR-AK-CAZ-SC 12094 .22 89 .26 179. 45 3337 .24 3228 .24 -10610.00 -454.75 5934730. 20 558417.67 MWD+IFR-AK-CAZ-SC ' Halliburton Company Survey Report Company: ConocoPhillips Alaska InC. Date: 6/5/2006 Time: 16 :342D Yagc: 4 Field: Ku paruk River Unit Co-ordinatc(NE) Reference: ' Well: 1J-184, True North_ Site: Ku paruk 1J Pad Vertical (TVD) Refe rence: 1J-184L1: 109 .0 Well: 1J-184 Section (VS) Reference: Well ( O.OON,O: OOE, 180.OOAzi) Wellpath: 1J-184L1 Survey Cala~lation Method: Minim um Curvature Db: Oracle Survey __ )iD Incl Azim TVD Sys 7ti'D N/S E/~V b1apN MapE "fool ' ft deg deg ft ft ft ft ft ft __ _ 12190 .00 90.94 182. 64 3337 .08 3228. 08 -10705.74 -456.50 5934634. 45 558416. 67 _ __ MWD+IFR-AK-CAZ-SC 12285 .74 90.18 183. 63 3336 .14 3227 .14 -10801.34 -461.73 5934538. 83 558412. 18 MWD+IFR-AK-CAZ-SC 12381 .26 89.26 183. 90 3336 .61 3227 .61 -10896.65 -468.01 5934443. 48 558406. 66 MWD+IFR-AK-CAZ-SC 12477 .06 $8.52 183. 19 3338 .46 3229 .46 -10992.24 -473.93 5934347. 85 558401. 48 MWD+IFR-AK-CAZ-SC I 12570 .61 90.13 182. 01 3339 .57 3230 .57 -11085.69 -478.17 5934254. 38 558397. 97 MWD+IFR-AK-CAZ-SC 12665 .95 89.88 180. 34 3339 .56 3230 .56 -11181.00 -480.13 5934159. 06 558396. 76 MWD+IFR-AK-CAZ-SC 12762 .70 88.20 179. 94 3341 .18 3232 .18 -11277.74 -480.36 5934062. 34 558397. 28 MWD+IFR-AK-CAZ-SC ', 12858 .25 86.66 176. 63 3345 .46 3236 .46 -11373.13 -477.51 5933966. 98 558400. 87 MWD+IFR-AK-CAZ-SC ~ 12953 .41 89.58 175. 63 3348 .58 3239 .58 -11468.01 -471.09 5933872. 16 558408. 03 MWD+IFR-AK-CAZ-SC 'i 13049 .28 89.14 175. 67 3349 .66 3240 .66 -11563.60 -463.82 5933776. 64 558416. 05 MWD+IFR-AK-CAZ-SC 13143 .39 89.32 175. 33 3350 .92 3241 .92 -11657.41 -456.44 5933682. 90 558424. 16 MWD+IFR-AK-CAZ-SC 13239 .13 88.58 178. 24 3352 .68 3243 .68 -11752.97 -451.07 5933587. 39 558430. 28 MWD+IFR-AK-CAZ-SC I 13333 .80 91.44 179. 93 3352 .66 3243 .66 -11847.62 -449.56 5933492. 77 558432. 53 MWD+IFR-AK-CAZ-SC 13429 .30 92.84 180. 42 3349 .09 3240 .09 -11943.05 -449.85 5933397. 35 558432. 98 MWD+IFR-AK-CAZ-SC 13524 .51 93.28 180. 84 3344 .01 3235 .01 -12038.12 -450.89 5933302. 29 558432. 68 MWD+IFR-AK-CAZ-SC 13618 .66 93.65 180. 05 3338 .32 3229 .32 -12132.09 -451.62 5933208. 32 558432. 68 MWD+IFR-AK-CAZ-SC ~~ 13713 ' .80 93.52 179. 76 3332 .37 3223 .37 -12227.04 -451.46 5933113. 38 558433. 58 MWD+IFR-AK-CAZ-SC ~ 13808 .40 92.83 177. 80 3327 .13 3218 .13 -12321.47 -449.45 5933018. 98 558436. 33 MWD+IFR-AK-CAZ-SC II 13903 .97 91.97 177. 64 3323 .13 3214 .13 -12416.88 -445.65 5932923. 61 558440. 87 MWD+IFR-AK-CAZ-SC ~i 13999 .19 90.18 177. 20 3321 .34 3212 .34 -12511.98 -441.37 5932828. 55 558445. 90 MWD+IFR-AK-CAZ-SC 14094 .13 90.06 178. 42 3321 .14 3212 .14 -12606.85 -437.74 5932733. 73 558450. 27 MWD+IFR-AK-CAZ-SC 14188 .55 89.88 178. 94 3321 .19 3212 .19 -12701.25 -435.57 5932639. 36 558453. 18 MWD+IFR-AK-CAZ-SC 14282 .92 89.88 181. 02 3321 .39 3212 .39 -12795.61 -435.53 5932545. 01 558453. 95 MWD+IFR-AK-CAZ-SC 14378 .52 88.70 180. 99 3322 .58 3213 .58 -12891.19 -437.21 5932449. 43 558453. 02 MWD+IFR-AK-CAZ-SC ~ 14473 .80 89.45 180. 72 3324 .11 3215 .11 -12986.44 -438.63 5932354. 18 558452. 34 MWD+IFR-AK-CAZ-SC 14567 .96 86.03 179. 21 3327 .83 3218 .83 -13080.51 -438.58 5932260. 12 558453. 13 MWD+IFR-AK-CAZ-SC !, 14663 .49 86.30 178. 15 3334 .22 3225 .22 -13175.80 -436.38 5932164. 86 558456. 07 MWD+IFR-AK-CAZ-SC 14755 .82 88.90 177. 12 3338 .08 3229 .08 -13267.96 -432.57 5932072. 74 558460. 60 MWD+IFR-AK-CAZ-SC 'I 14854 .45 89.14 176. 76 3339 .77 3230 .77 -13366.44 -427.31 5931974. 32 558466. 63 MWD+IFR-AK-CAZ-SC 14949 .83 92.55 178. 20 3338 .36 3229 .36 -13461.70 -423.12 5931879. 10 558471. 57 MWD+IFR-AK-CAZ-SC 15045 .71 92.47 176. 98 3334 .16 3225 .16 -13557.40 -419.09 5931783. 44 558476. 34 MWD+IFR-AK-CAZ-SC 15140 .91 91.72 175. 92 3330 .68 3221 .68 -13652.35 -413.20 5931688. 55 558482. 97 MWD+IFR-AK-CAZ-SC 15235 .53 93.40 177. 22 3326 .46 3217 .46 -13746.70 -407.54 5931594. 25 558489. 36 MWD+IFR-AK-CAZ-SC 15331 .10 92.65 179. 63 3321 .41 3212 .41 -13842.10 -404.92 5931498. 89 558492. 73 MWD+IFR-AK-CAZ-SC 15425 .96 93.40 182. 15 3316 .41 3207 .41 -13936.81 -406.39 5931404. 19 558492. 00 MWD+IFR-AK-CAZ-SC 15520 .41 92.96 180. 85 3311 .17 3202 .17 -14031.08 -408.86 5931309. 91 558490. 27 MWD+IFR-AK-CAZ-SC 15614 .68 94.15 179. 94 3305 .32 3196 .32 -14125.16 -409.51 5931215. 83 558490. 35 MWD+IFR-AK-CAZ-SC 15710 .90 93.95 182. 22 3298 .52 3189 .52 -14221.11 -411.32 5931119. 87 558489. 29 MWD+IFR-AK-CAZ-SC 15806 .40 92.71 180. 54 3292 .98 3183 .98 -14316.42 -413.61 5931024. 56 558487. 74 MWD+IFR-AK-CAZ-SC 15900 .83 89.55 181. 32 3291 .11 3182 .11 -14410.81 -415.14 5930930. 18 558486. 95 MWD+IFR-AK-CAZ-SC ~ 15993 .88 89.51 181. 14 3291 .88 3182 .88 -14503.83 -417.14 5930837. 15 558485. 68 MWD+IFR-AK-CAZ-SC 16089 .36 87.09 180. 60 3294 .71 3185 .71 -14599.25 -418.59 5930741. 73 558484. 97 MWD+IFR-AK-CAZ-SC 16184 .98 86.29 179. 21 3300 .23 3191 .23 -14694.71 -418.43 5930646. 28 558485. 87 MWD+IFR-AK-CAZ-SC 16278 .83 85.80 179. 33 3306 .70 3197 .70 -14788.33 -417.24 5930552. 69 558487. 80 MWD+IFR-AK-CAZ-SC 16374 .87 84.19 180. 60 3315 .08 3206 .08 -14884.00 -417.18 5930457. 03 558488. 60 MWD+IFR-AK-CAZ-SC 16470 .06 82.36 178. 32 3326 .23 3217 .23 -14978.52 -416.29 5930362. 53 558490. 23 MWD+IFR-AK-CAZ-SC 16564 .70 82.50 178. 69 3338 .70 3229 .70 -15072.30 -413.84 5930268. 78 558493. 41 MWD+IFR-AK-CAZ-SC 16661 .93 80.81 178. 19 3352 .81 3243 .81 -15168.46 -411.23 5930172. 65 558496. 78 MWD+IFR-AK-CAZ-SC 16692 .00 80.81 178. 19 3357 .61 3248 .61 -15198.13 -410.29 5930142. 99 558497. 95 • PROJECTED to TD • • WELL LOG TRANSMITTAL To: State of Alaska June 29, 2006 Alaska Oil and Gas Conservation Co. Attn.: Librarian 333 West 7th Avenue, Suite 1.00 Anchorage, Alaska 99501 RE: MWD Formation Evaluation Logs 1J-184 & 1J-184 L1, AK-MW-4348857 1 LDWG formatted CD Rom with verification listing. API#: 50-029-23305-00, -60 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry Drilling Services Attn: Rob Kalish 6900 Arctic Blvd. Anchorage, Alaska 99518 Date: ~ o ~o~ -O~/~/ X139 `~~ Signed: ~~~ a y5 ~ r 39 fs~f • • 14-Jun-06 AOGCC Ceresa Tolley 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 DEFINITIVE Re: Distribution of Survey Data for Well 1 J-184 L1 Dear Dear Sir/Madam: Enclosed is one disk with the *.PTT and '~.PDF files. Tie-on Survey: 8,759.26' MD Window /Kickoff Survey: 16,661.93' MD (if applicable) Projected Survey: 16,692.00' MD PLEASE ACKNOWLEDGE RECEIPT BY SENDING AN EMAIL TO CARL.ULRICH@HALLIBURTON.COM OR SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Carl Ulrich 6900 Arctic Blvd. Anchorage, AK 99518 Date Signed l/ Please call me at 273-3545 if you have any questions or concerns. Regards, Carl Ulrich Survey Manager Attachment(s) DECEIVED JUN 2 7 2006 qj~$ pll & Gas C0115.Opm~rtiSSi0n Anchorage RE: IJ-184 PTD (206-044 & 206-045) • Subject: RE: 11-184 PTD (20(~-044 & 206-045) From: NSK Problem Well Stip~~ ~_n1617@conocophillips.coiz~-=~ Date: Wed, 07 3u~ 2006 10: I > : ~ 0 -0800 To: 'A'SK Prolilcir~ Well Supv <r11G171c1~.conocophillips.com:°, ~~-inton_aubertru'ad~nin.sta~e.akus, to~~~~7~aunder~:~dmin.state.al:.us CC: NSK ~-Vest Sak Prod Cn~~r ~~nl C~3~~u'conocophillips.com== Winton, Tom I double checked with the West Sak PE and he confirmed that standard practice is to submit all 10-407's as producers then submit the 10-403 to convert to injection once the pre production diagnostics are finished. With your verbal permission we plan to preproduce each leg 14 days and the combined wait for 30 days. Approximate total production time will be 60 to 90 days. Sincerely Perry Klein Problem Wells Supervisor ConocoPhillips Alaska Inc. Office 907-059-7224 Cal I 907-943-1244 -----Original Message----- From: NSK Problem Well Supv Sent: Wednesday, June 07, 2006 9:34 AM To: winton_aubert@admin.state.ak.us Subject: FW: iJ-184 PTD (206-044 & 206-045) Winton, I found out today that Tom is out of the office. Would you give the following a read through and let me know your thoughts. Thanks in advance. Perry Klein -----Original Message----- From: NSK Problem Well Supv Sent: Friday, June 02, 2006 5:17 AM To: Thomas Maunder' Subject: 1J-184 PTD (206-044 & 206-045) Tom, ConocoPhillips would like to request approval to pre produce injection well 1J-184 using gas lift through an open sliding sleeve at 8726 MD - 3333 TVD for approximately 90 days with option to extend after which a 10-403 will be submitted to convert 1J-184 to an injection welt. 1 of~~ ~~~~ ~~ J ~~~ 4/25/2007 10:47 AM LJ ,®.~, a . ~ ~ ~ a ~ , L1~A~7~ OIL t>•1`L l7~-7 C011T5ERQATI011T COl-'II~'IISSIOI~T Randy Thomas Greater Kuparuk Area Drilling Team Leader ConocoPhillips Alaska, Inc. PO Box 100360 Anchorage, AK 99510-0360. ;; ~~ FRANK H. MURKOWSKI, GOVERNOR ~~ 333 W. 7T" AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 PAX (907) 276-7542 Re: Kuparuk River Field, West Sak Oil Pool, 1J-184L1 ConocoPhillips Alaska, Inc. Permit No: 206-045 Surface Location: 1530' FSL, 2424' FEL, SEC. 35, T 11 N, R l OE, UM Bottomhole Location: 1992' FSL, 2838' FEL, SEC. 14, T10N, RlOE, UM Dear Mr. Thomas: Enclosed is the approved application for permit to drill the above referenced service well. This permit to drill does not exempt you from obtaining additional permits or an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. The permit is for the new wellbore segment of existing well KRU 1J-154 Permit No. 206-044, API No. 50-029-23305-00. Production should continue to be reported as a function of the original API number stated above. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector aft (909-3607 (pager). DATED this day of April, 2006 cc: Department of Fish 8v 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 1 a. Type of Work: 1 b. Current Well Class: Exploratory Development Oil ^ 1 c. Specify if well is proposed for: Drill ^/ Re-drill ^ Stratigraphic Test ^ Service 0 ~ Development Gas ^ Coalbed Methane ^ Gas Hydrates ^ Re-entry ^ Multiple Zone^ Single Zone ^ Shale Gas ^ 2. Operator Name: 5. Bond: / Blanket Single Well 11. Well Name and Number: ConocoPhillips Alaska, Inc. Bond No. 59-52-180 ' 1J-184L1 ' 3. Address: 6. Proposed Depth: 12. Field/Pool(s): P.O. Box 100360 Anchorage, AK 99510-0360 MD: 16851' ~ ND: 3378' ~ Kuparuk River Field 4a. Location of Well (Governmental Section): 7. Property Designation: Surface: 1530' FSL, 2424' FEL, Sec. 35, T11 N, R10E, UM ~ ADL 25662 & 380058 ' West Sak Oil Poo! ~ Top of Productive Horizon: 8. Land Use Permit: 13. Approximate Spud Date: 4712' FSL, 2938' FEL, Sec. 11, T10N, R10E, UM ALK 2177 & 4604 4/18/2006 Total Depth: 9. Acres in Property: 14. Distance to ) y titi /~,f, 1992' FSL, 2838' FEL, Sec. 14, T10N, R10E, UM ~ 2560 NearestProperty: X442' .,/,e(, 4b. Location of Well (State Base Plane Coordinates): ~ ' 10. KB Elevation 15j Dista~55~L2 s ~ ~ ' l~ hi P l ~ Surface: x- 558789 y- 5945342 Zone- 4 (Height above GL): 28' RKB feet n oo wi t Wel : e , ~ ~ 16. Deviated wells: Kickoff depth: 8842 ' ft. 17. Maximum Anticipated Pressures in psig (see 20 AAC 25.035) ~ d Maximum Hole Angle: 92.5° deg Downhole: 1522 psig ~ Surface: 1149 psig 18. Casing Program if ti S Setting Depth Quantity of Cement Si peC lCa ons B tt m T f ze op o o c. . or sacks Hole Casing Weight Grade Coupling Length MD ND MD ND (inGuding stage data) 40" 20" 62.5# H-40 Welded 80' 28' 28' 108' 108' 260 cf ArcticCrete 16" 13.375" 68# L-80 BTC 3611' 28' 28' 3639' 2150' 700 sx AS Lite, 220 sx DeepCRETE 12.25" 9.625" 40# L-80 BTCM 9226' 28' 28' 9254' 3428' 630 sx DeepCrete 8.5" 5.5" 15.5# L-80 BTCM 8009' 8842' 3359' 16851' 3378' 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 '"" '"T ~ '`~ , ,-~: Conductor/Structura I Surface Intermediate .f -, P<3 Production . ~'° ' ~` ~• ~vf) r~y~ ' Liner ~ Perforation Depth MD (ft): Perforation Depth TVD (ft): y ~o/O BOP Sketch / Drilling Program / Time v. Depth Plot Shallow Hazard Analysis / 20. Attachments: Filing Fee _ Property Plat ^ Diverter Sketch ^ Seabed Report ^ Drilling Fluid Program ^/ 20 AAC 25.050 requirements ^/ 21. Verbal Approval: Commission Representative: Date: 22. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Pat Reilly @ 265-6048 Printed Name Randy Thomas Title Greater Kuparuk Area Drilling Team Leader Signature ~. ~-~-~~ ~~-~ ' °~~, Phone "L~ ~6 ~ ~~ Date 3 t'~~ i~i:> E. Commission Use Only Permit to Drill ' / API Number: Permit Approval See cover letter Number: ~.(„ ~~j -a Y 5 50- QZ,g - Z 33oS - ~ Date: for other requirements Conditions of approval : If box is checked, well may not be used to explore for, test, or produce coalbed methane, gas hydrates, or gas contained in shales: Samples req'd: Yes ^ No ~ Mud log req'd: Yes ^ No ~'~ ,~~~ ~ G (J ~~` S \i~~~ H2S measures: Yes ^ No []' tional svy req'd: Yes [t~ No ^ Other: APPROVED BY THE COMMISSION DATE: ~ ~ ,COMMISSIONER Form 10-401 Revised 12/2005 ;-~ Submit in Duplicate ~-rI31L~' "'J 7-~-~(o Ap~ion for Permit to Drill, Well 1J-184 L1 Revision No.O Saved: 29-Mar-06 Permit It -West Sak Well#1J-184L1 •~~~~ r.w +'l Application fol^ Permit to ~r^ill Document , ~t+~~c'~I~~II r~ax~mize Vl~ell ~ta~ue Table of Contents 1. Well Name .................................................................................................................. 2 Requirements of 20 AAC 25.005 (~ ............................................................................................................. 2 2. Location Summary ..................................................................................................... 2 Requirements of 20 AAC 25.005(c)(2) ......................................................................................................... 2 Requirements of 20 AAC 25.OS0(b) ............................................................................................................. 2 3. Blowout Prevention Equipment Information ........... .................................................... 3 Requirements of 20 AAC 25.OOS(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)(S) ........................................................................................................ 3 6. Casing and Cementing Program ................................................................................. 3 Requirements of 20 AAC 25.OOS(c)(6) ......................................................................................................... 3 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 YersaPro Mineral Oil Base) ............................................................................... 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 1J-184 L1 PERMIT lT Page 1 of 6 Printed: 29-Mar-06 ~!-~~~. .~:_}v ~~ Ap~on for Permit to Drill, Well 1J-184 L1 Revision No.O Saved: 29-Mar-06 Requirements of 20 AAC 25.005 (c)(12) ...............................................•-•--•--•-•-•------.......................-•---........ 5 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 Doyon 141. West Sak 2004 3 ksi BOP Configuration (1 page) ...........................................,...... 6 Attachment 2 Directional Plan (6 pages) .................................................................................................... 6 Attachment 3 Drilling Hazards Summary (1 page) ...................................................................................... 6 Attachment 4 Well Schematic (1 page) ...........................................................................................•---........ 6 1. Well Name Requirements of 20 AAC 25.005 (~ Loch well rnzest be identified by a unique name designated by tlae operator and a unique API number assigned by the commission tender 20 AAC 25.04{la). F'or a well tivith multiple well branches, each firaneh must similarly be ident~ed by a unique iaame and API ratember fw adding a suffix to tlae Warne designialed f rr the well Uv the operator acrd fo thc: number assigned) to the tivell by the corrzrraission. The well for which this Application is submitted will be designated as 1J-184 L1. 2. Location Summary Requirements of 20 AAC 25.005(c)(2) ,*in application_fhr a.Perrrtit to Drill must he accompanied by each of the following items, except.for an item calreacly on ftle with the cornrnirsion and identified in the application: ("2) a plat identifying the property and the property's owners and showing (A)the coordinates of•fhe proposed Iocation of the well at the surface,, at the top ofeacla objective formation, and at Total depth, referenced to goverrunental section lines. (B) the coordinates of floe proposed location of the well at tlae surface, rE ferenced to the state plane coordinate system for this state as mar."ntained by the National Geodetic, Survev ira the National Oceanic and Atmospheric Administration; (C) the proposed depth of the avell cat the top of each objective formation ezrad at total depth; Location at Surface 1,530' FSL, 2424' FEL, Section 35, T11N, R10E ASP Zone 4 NAD 27 Coordinates RKB Elevation 109' AMSL Northings: 5,945,342 Eastings: 558,789 Pad Elevation 81' AMSL Location at Top of Productive Interval (West Sak "B" Sand 4,712' FSL, 2,938' FEL, Section 11, T10N, R10E ` ASP zone 4 NAD 27 coordinates Measured Depth, RKB: 8,842 Northings: 5,937,961 Eastings: 558,341 Total Vertical Depth, RKB: 3,359 Total Vertical Depth, SS: 3,250 Location at Total De th 1,992' FSL, 2,838' FEL, Section 14, T10N, R10E " ASP zone 4 NAD z7 coordinates Measured Depth, RKB: 16,851 ' Northings: 5,929,963 Eastings: 558,511 Total Vertical Depth, RKB: 3,378 Total Vertical Depth, SS.• 3,269 and (Dj other information required fiY 20 AAC 25.050(bj,~ Requirements of ZO AAC 25.050(b) If•a well it to he irttentiortaltydeoiated the application fir u Permit to Drill (Form 1 {1-~01) rttttst OR161NAL 1J-184 L1 PERMIT IT Page 2 of 6 Printed: 29-Mar-O6 Ap~on for Permit to Drill, Well 1J-184 L1 Revision No.O Saved: 29-Mar-06 (1) include a plat, drawn to a suitable scale, showing the path c?f the proposed wellbore, iraclzrdin~ all adjacent tvellbares within 20Q feet pf any portion of the proposed well; Please see Attachment 1: Directional Plan and (2) for all wells tvithira 200 feet of the pr•aposed tvellborc: (4) list the names of•the aperatars of those wells, to the extent that Haase names are h:nawn ar discoverable in public records, aiad s-how that each named irperator has been furnished a copy of ilae application by certifzed mail; or (13) state that the applicant is the rimy affected owner. The Applicant is the only affected owner. 3. Blowout Prevention Equipment Information Requirements of 20 AAC 25.005(c)(3) An application, far a Permit to Drill rnzrst he accompczraied Uy each of tlae fcrllawirtg aterras, except for an item already on fle with the commission and i~denti/ied in the applicatian: (3) a diagram and dcscr•iptian of the blowaul preventian equipment (BD.PE) as required by 20 AAC 2.5.035, 20 AA C 25.036, or- 20 AAC 2 5:037, as applicable; An API 13-5/8" x 5,000 psi BOP stack (RSRRA) will be utilized to drill and complete well 1J-184. Please see information on the Doyon Rig 141 blowout prevention equipment placed on file with the Commission. 4. Drilling Hazards Information Requirements of 20 AAC 25.005 (c)(4) ~ ~~ ~' ~ ~ An application fi7r• a Permit to Drill must he accompanied by each of the following items, except for ezra Item already on file with the commissiart attd identified in the czppliccztian: (4) information art drilling hazards, including (A) the maximum dawnhole pressure that may be encauxtered, criteria used to determine it, and maximum patential sur face pressure based on a methane gradient; The expected reservoir pressure in the West Sak sands in the 1J-184 L1 is 0.45 psi/ft, or 8.6 ppg EMW (equivalent mud weight). The maximum potential surface pressure (MPSP) is 1,149 psi: Based on the above maximum pressure gradient, a methane gradient (0.11) and the deepest planned vertical depth of the West Sak A2 sand formation is 3,382'. The MPSP is: MPSP = (3,382 ft)(0.45 - 0.11 psi/ft) =1,149 psi ~ {B) data on potential gas wn~r; The well bore is not expected to penetrate any gas zones. .~incl (C) data concerning potential causes ofhole problems such as abnor~rnally geo pressured strata, lost circulation zanes, andzanes that have ca lrropensity for differential sticking; Please see Attachment 2: Drilling Hazards Summary. 5. Procedure for Conducting Formation Integrity Tests Requirements of 20 AAC 25.005 (c)(5) An application for a Permit Pa I?rill nztast be accompanied by each of the follotivirag items, except for an item already on file with the commission and identified in the application: (5) ca dercr Xttion of the larucedure far conducting formation irategrity° tests, as required zznder 20 AAC 25:030(/); No formation integrity test will be performed in the drilling of 1J-184 L1 6. Casing and .Cementing Program Requirements of 20 AAC 25.005(c)(6) .An czplrlication for ca Perrrtil to Drill must be accaanpanied by each of the following items, except far an item alrear(v on file with the carrtrni,ssicm and identified in the alrplicatian: 1J-184 L1 PERMIT IT Page 3 of 6 Printed: 29-Mar-06 ORIGINAL App~on for Permit to Drill, Well 1J-184 L1 Revision No.O Saved: 29-Mar-06 (S) a complete proposed casing and cementing program as required by ?U AAC 2 s.ll3EJ, and a description of any slotted liner; pre-perforated liner, or screen to he instadlerl,~ Casing and Cementing Program See also Attachment 3: Cement Summar Hole Top Btm Csg/Tbg Size Weight Length MD/TVD MD/TVD OD in in (lb/ft) Grade Connection t) (ft) t) Cement Pro ram 20" 40" 62.5 H-40 Welded 80 28' / 28' 80' / 80' Cemented to surface with 260 cf ArcticCRETE Cemented to Surface with 13-3/8" 16" 68 L-80 BTC 3,611 28' / 28' 3,639' / 2,150' 700 sx ArcticSet Lite Lead, 220 sx Dee CRETE Tail Cement Top planned @ 5,745' " 12-1/4" 40 L-80 BTCM 226 9 28' / 28' 9 254' / 3 428' MD / 2,656' TVD. Cemented , , , w/ 630 sx Dee CRETE 5-1/2 '' 8-1/2" mate 15 5 L-80 BT - tted-no cement d (1J-184} . 5-1/2 slotted 8-1/2" D Sand Lateral (1J-184L1) 15.5 L-80 BTCM 8,009 8,842' / 3,359' 16,851' / 3,378 Slotted-no cement 7. Requirements of 20 AAC 25.005(c)(7) Art application, for a Permit to Drill mttst be aecampanied by each of the following items, except for an item already on file with the commission and ider~ttified in the application: (7) a diagram and description of the diverter system as rerfiuired 1?y 20 AAC 25.35, unless this requirement is waived hJ' the eorurnission under zoAACZS.o3s(h){z); No diverter system will be used during operations on 1J-184 L1 8. Drilling Fluid Program. Requirements of 20 AAC 25.005(c)(8) An application jitr a Permit to Drill must be uccompaniecd by each oj'the followirzg items, except for an item already on file with the cornrnission rznd iderzt~r:d in the applicutiorz: (Y) cz drilling fluid program, including a diagram arul description of tFze drilling fluid system, rzs required by ?0_4.4C: '5.1133: Drilling will be done with muds having the following properties over the listed intervals: Lateral Mud Program (MI VersaPro Mineral Oil Base) Value Densi (pp) 9.0 Plastic Viscostiy (lb/100 s 15-25 Yield Point 18-28 (cP) HTHP Fluid loss (ml/30 min @ <4.0 200 si & 150° Oil /Water Ratio 80:20 Electrical Stability >600 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. 1J-184 L1 PERMIT /T Page 4 of 6 Printed: 29-Mar-06 App~on for Permit to Drill, Well 1J-184 L1 Revision No.O Saved: 29-Mar-06 9. Abnormally Pressured Formation Information Requirements of 20 AAC 25.005 (c)(9) Arc alrpl icatiorz, 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 ita the application: (9) foram explorutoty av stratigraphic test weld a tabuladion setting out tlae depths of predicted abnormally geo-pressured strata as required by 2U AAC 2.5. U_i3(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 upplication for a Permit to Drill tnarst be caccompartied 1?v each of the following iterrir, except for an item already nn file urith the commission cuad identified in the application: (1 U),for an expiorcztbry or stratigraphic test u~e11, a seismic refraction or reflection analysis us r-egzaired by 2U AAC 25. U61(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) Ara applicatiots,for aPermit to Drill must be accompanied by each of tlae following items, except for an item already on_frle with the commission and identifzed it^a the application: (11) for a well dr-r.'lled frrrns azs offshore platform, mobile bottom founded str~.reture, jack-up rig, or,flocating drilling vessel. an araalvszs ofseabed conditions as required by 2U AAC 25.0G1(b); Not applicable: Application is not for an offshore well. 12. Evidence of Bonding Requirements of 20 AAC 25.005 (c)(12) An application fhr• a Permit to Drill rmast be accompanied liv each of the following tterns, except for an item alreaady on file with the commission artd identified in the application: (12} evidence showing that the requirements ~f 2U AAC 25.02 5 t'13onding}hane beers 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) Arz applieatiorz, far a Permit tCr Drill must be aceomparzied by each of the following items, except for an item already on Jile with the commission and identified ira the application: The proposed drilling program is listed below. Please refer also to Attachment 4, Well Schematic. Note: Previous operations are covered under the 1J-184 Application for Permit to Drill. 1. Run and set Baker WindowMaster whipstock system, at window point of 8,842' MD / 3,359' TVD, the top of the "D" sand. 2. Mill 8-1/2" window. POOH. 3. Pick up 8-1/2" drilling assembly with LWD and MWD and PWD. RIH. 4. brill to TD of "D" sand lateral at 16,851' MD f 3,378' TVD, as per directional plan. 5. POOH, back reaming out of lateral. POOH. 6. RIH with whipstock retrieval tool. Retrieve whipstock and POOH. 7. PU and run 5-1/2" slotted liner. 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. POOH. 11. POOH, laying down drill pipe as required. 1J-184 L1 PERMIT IT Page 5 of 6 Printed: 29-Mar-O6 '~2',INAL Appon for Permit to Drill, Well 1J-184 L1 Revision No.O Saved: 29-Mar-06 12. PU injection completion as required and RIH to depth. Land tubing. Set BPV. 13. Nipple down BOPE, nipple up tree and test. Pull BPV. 14. Freeze protect well with diesel by pumping into 4-1/2" x 9-5/8" annulus, taking returns from tubing and allowing to equalize. 15. Set BPV and move rig off. 16. Rig up wire line unit. Pull BPV. '` 17. Set gas lift valves in mandrels. Operate well on gas lift for +/- 180 days. Shut well in. 18. Rig up wireline. Replace gas lift valves with blank dummy valves. Return well to injection. 14. Discussion of Mud and Cuttings Disposal and Annular Disposal Requirements of 20 AAC 25.005 (c)(14) An application for a Perrrait to Drill musty, he accompanied by each of the,fcrllawing fterru, except for ara item already on file with Ylze commission and iderzt Pied in the application: (14) a general description of how the operator plans to dispose ofdrilling mud and cxattings and a statement Uf whether the operator intends to request authori~atiorz under 20 AAC 25.ORD for an annular disposal aperution 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 lE Pad, hauled to the Prudhoe Bay Grind and Inject Facility for temporary storage and eventual processing for injection down an approved disposal well, or stored, tested for hazardous substances, and (if free of hazardous substances) used on pads and roads in the Kuparuk area in accordance with a permit from the State of Alaska. ConocoPhillips Alaska may in the future request authorization for the use of this well for annular disposal operations. 15. Attachments Attachment 1 Doyon 141 West Sak 2004 3 ksi BOP Configuration (1 page) Attachment 2 Directional Plan (6 pages) Attachment 3 Drilling Hazards Summary (1 page) Attachment 4 Well Schematic (1 page) 1J-184 L1 PERMIT IT Page 6 of 6 ~~gg Printed: 29-Mar-O6 ~~i~~ Drill String Valves To be tested to 250 psi and 3,000 psi at initial installation and every 14 days thereafter. 13-5 Annular ~ To be tested to 250 psi and 1,500 psi at initial installation and every 14 days thereafter. 13-5 Double Ram Upper Rams: 3-'/z' to 6" variables To be tested to 250 psi and 3,000 psi at initial installation and. every 14 days thereafter. Lower Rams: Blind To be tested to 250 psi and 3.,000 psi at initial installation and every 14 days thereafter. Choke and Kill Line Valves ~ To be tested to 250 psi and 3,000 psi at initial installation and every 14 days thereafter. 13-5 Single Ram Rams to fit Intermediate Casing: 7-5/8" or 9-5/8" ~ To be tested to 250 psi and 3,000 psi only before running casing. ~ Wellhead Valves tested to 3,000 psi upon assembly h Doyon 141 West Sak 3 ksi 13-560P3K Sheet1~of~ ~~~~~~~' •~~~~~ prepared by Steve McKeever Alaska BOP Configuration sit,/2o04 ~~~~~~: ~ 6 a % • ConocoPhillips Alaska ConocoPhillips Alaska (Kuparuk) Kuparuk River Unit Kuparuk 1J Pad Plan 1J-184 -Slot 1J-184 1J-184 L1 Plan: 1J-184 L1 (wp09) Proposal Report 12 March, 2006 ~~ Sperry Drilling Servc~a ~~ '_~ Z ~_ J it C ~ ~ j0~,.~J Q ~~~~3 Y Y ~ ~ ~ ``=~J R{ R ~ 33C.`r YY_O~ r ~ d V r ~ d C O~ ~ ~ a` a _O ~ r ~~ 7 _ m ~ C O N J ~ M Cn ~ ~ ~Z ~ ~ `- O~~ am .~- ~ (6 d ' C O~J~ f6 ~ ~ O J J m~ Q ~ 'O y ~ p O W ~ 0 ~ J C~ ~ W ~ ~' O M Z ~ ~ > l O W ~ ~ O Z~ + O ' ~ °' a ~ 3 ~ m a ~ r ~ m ~ M ~ ~ n ~ J ^ \\ a°o d C m ~ ~ c o ~ ~ ~ O ~~~, J O 0 r a ~' Q ~ eo O C -' G ~ m ' ~ /' o a tl ~ J ~~ ~ ~ 3 J m N ~ r N 0 A v ~ e68 J 92 ~ M - ' - , - 068 - ` - - 0 f ```--v I ~ ~ ,~ M ~ ,(16 ~ N e98.. G m ~ -~ - ' % ~i ~ u~ , - ' ~ ~ / C g J ~ ~ ~ ~ ~ i irl / ' ~~ m / / d ~ ~ o ~ ~ z M ' M w d f ~~ ~ ~ >9~ ~ ~ i J 3 $ ao 0 m ~ W ~ ~ J 3 J ~P °~~ °~9 OS. ~~d °O N o aN t^ ~ „o ' (w/y 000Z~4ida4 ~e~ij.ia~ arul Oj ° A O 3 a 3 w v Y / ^ d m ~~ 3 J h s ~ ~ ~ ~ O r ~0 r ~ 0 a J ; ~ Y ~~ ~ m a ~ J N d 3 N ~ ' ~ ~ a ~ J _ O ~ o 3 N ----- -- ---- Y R a m f _ ` '~ ' - ~ N 93" J ~ =l a, Y m a J r O O O O O O ~ N 0 0 °m 0 0 0 c°o O °o O r O °o 0 °o 0 o °~ °o N 0 o ° o ~ O~ ~ ~ O O u O ~ O ~ O 0 0 °v O M 0 N O O 0 0 0 0 0 0 0 0 N zooo Project: Kuparuk River Unit Site: Kuparuk 1J Pad Well: Plan 1J-184 Wellbore: 1J-184 L1 loon Plan: 1J-184 L1 (wp09) ConocoPhillips _ Ai1sk~ HAt_t_IBURTON 1000 sP~~Y DritlMy S~rvicss 13 318" 182° -7000 c_ O O O -8000 O Z -9000 s 0 11 1 L1 :TOW - 9 5l8" ~ 8842ft MD, 3359ft N L1 : BOW ~ 8859ft MD, 33828 N _ _ _ _ _ _ _ _ _ _ _ L1 : End 30' Rathole - Build ~ 3°/100ft, 88898 MD, 3388ft N i ~ I I !_ _ _ I ~79° I ' _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ L1 : Sail 92.8°, 9233ft MD, 3381ft N _ 1J-184 L1 T1 (Peak 1)(wp09 - - - - - - _ I I _ _ - _ _ - _ _ I X79° - I I I L7 : Continue Dir ~ 3°/100ft to 90.5° linc -Continue Undulations In D-Sand, 9778ft MI 1J-184 L1 T2 (Trough 1) (wp09 - - - - - - - - - - I I I I ~79° I ~ i ' > DD Poly defines a corridor 100' 1J-184 L1 T3 (Peak 2) (wp09 - - - - - ~ I wide with allowable deviation I I ~79° a from plan of +/-50' E or W I ~ 1J-184 L1 DD Poly@ 95% (wp09) 1J-184 L1 T4 (Trough 2) (wp09 ~ I _ I I i I 1J-184 L1 Geo-Poly (wp09) 1J-184 L1 TS (Peak 3) (wp09 - - - - - - - - - I I .--~ I I I.. I I , -' 1J-184 L7 T8 (Trough 3) (wp09 _ _ _ _ _ _ _ _ _ I I L1 : End Undulations In D-Sand, 15846ft MD, 3314ft N I I I 179° 1 ~~ ,,,_, -'" 1J-184 L1 T7 (Peak 4) (wp09 _ I , _ _ - _ _ I , - - - - L1 : Begin Drop ~ 1.8°/1008 to B-Sand Top, 18076ft MD, 3312ft I I I 1J-184 L1 T8 (Top B) (wp09 _ _ _ _ _ _ I I I _ _ _ I L7 : TD rID 18851ft MD, 33781ft ND- 5 1/2' ~ 1J-184 Toe (wp09) -7000 -6000 -5000 -4000 -3000 -2000 -1000 0 3357ft T MIy~ R.zimuths to True No^h Magnetic North: 24.72° Magnetic Field Strength: 57549.2nT Dip Angle: 80.75° Date: 9/14/2004 Model: BGGM2005 1000 2000 3000 4000 5000 6000 7000 • ~_.... _ -~--- e ---- ~ ~-- Halliburton Energy Services HAi.1.,tBURTON Ct~1'x?~C~P~'r1~11p5 Planning Report -Geographic ~~~---~~~---~~---- Alaska Database: EDM 2003.11 Single User Db Company: ConocoPhillips Alaska (Kuparuk) Project: Kuparuk River Unit Site: Kuparuk 1J Pad Well: Plan 1J-184 Wellbore; 1J-184 L1 Design: 1J-184 L1 (wp09) Sperry Drilling ServHcas Local Co-ordinate Reference: Well Plan 1J-184 -Slot 1J-184 TVD Reference: 1J-184 (28+81) @ 109.OOft (Doyon 141 (28)) MD Reference: 1J-184 (28+81) @ 109.OOft (Doyon 141 (28)) North Reference: True ~ Survey Calculation Method: Minimum Curvature ' Project Kuparuk River Unit, North Slope Alaska, United States Map System: US State Plane 1927 (Exact solution) System Datum: Mean Sea Level Geo Datum: NAD 1927 (NADCON CONUS) Using Well Reference Point Map Zone: Alaska Zone 04 Using geodetic scale factor I Well Plan 1J-184 -Slot 1J-184 I Well Position +N/-S 0.00 ft Northing: 5,945,342.40 ft ' Latitude: 70° 15' 40.580" N +E/-W 0.00 ft Easting: 558,789.54 ft ~ Longitude: 149° 31' 29.150" W Position Uncertainty 0.00 ft Wellhead Elevation: ft Ground Level: 81.OOft Wellbore -- 1J-184 L1 Magnetics Model Name Sample Date Declination Dip Angle Field Strength BGGM2005 9/14/2004 24.7189 80.7489 57,549 Design 1J-184 L1 (wp09) i Audit Notes: Version: 3 Phase: PLAN Tie On Depth: 8,842.24 Vertical Section: Depth From (TVD) +N/-S +EI-W Direction (ft) (ft) (ft) (°) ~i 28.00 0.00 0.00 180.00 3/12/2006 3:38:18PM Page 2 of 10 COMPASS 2003.11 Build 50 f i' ~ j ~-- ~ Halliburton Energy Services ~~~«~~~~~~ Planning Report -Geographic Database: Alaska. EDM 2003.11 Single User Db Company: ConocoPhillips Alaska (Kuparuk) Project: Kuparuk River Unit Site: Kuparuk 1J Pad Well: Plan 1J-184 Wellbore: 1J-184 L1 Design: iJ-184 L1 (wp09) HALi,tBURTC~M Sperry DrilMir~ Services Local Co-ordinate Reference: Well Plan 1J-184 - Siot 1J-184 ND Reference: 1J-184 (28+81) @ 109AOft (Doyon 141 (28)) MD Reference: 1J-184 (28+81) @ 109.OOft (Doyon 141 (28)) North Reference: True Survey Calculation Method: Minimum Curvature Plan Summary Measured Vertical Dogleg Build Turn Depth Inclination Azimuth Depth +N!-S +E/-W Rate Rate Rate TFO (ft) (°) (°) (ft) (ft) (ft) (°/100ft) (°1100ft) (°/100ft) (°) 8,842.24 80.00 179.24 3,359.00 -7,378.39 -506.20 0.00 0.00 0.00 0.0000 8,858.74 82.24 179.24 3,361.55 -7,394.69 -505.99 13.60 13.60 0.00 0.0000 8,888.74 82.24 179.24 3,365.60 -7,424.41 -505.59 0.00 0.00 0.00 0.0000 9,232.74 92.56 179.24 3,381.15 -7,767.56 -501.03 3.00 3.00 0.00 -0.0269 9,776.39 92.56 179.24 3,356.83 -8,310.62 -493.78 0.00 0.00 0.00 0.0000 9,844.52 90.52 179.24 3,355.00 -8,378.72 -492.87 3.00 -3.00 0.01 179.8646 10,229.82 88.59 179.25 3,357.98 -8,763.96 -487.78 0.50 -0.50 0.00 179.7947 10,471.67 88.59 179.25 3,363.92 -9,005.71 -484.61 0.00 0.00 0.00 0.0000 10,844.97 90.46 179.24 3,367.00 -9,378.95 -479.68 0.50 0.50 0.00 -0.2120 11,226.98 92.37 179.17 3,357.57 -9,760.79 -474.37 0.50 0.50 -0.02 -2.1625 11,475.02 92.37 179.17 3,347.32 -10,008.59 -470.77 0.00 0.00 0.00 0.0000 11,844.79 90.52 179.19 3,338.00 -10,378.18 -465.48 0.50 -0.50 0.01 179.3143 12,230.59 88.59 179.26 3,340.99 -10,763.92 -460.27 0.50 -0.50 0.02 177.8478 12,471.68 88.59 179.26 3,346.91 -11,004.91 -457.16 0.00 0.00 0.00 0.0000 12,845.24 90.46 179.24 3,350.00 -11,378.41 -452.28 0.50 0.50 -0.01 -0.6888 13,259.02 92.53 179.25 3,339.21 -11,792.00 -446.82 0.50 0.50 0.00 0.1986 13,454.28 92.53 179.25 3,330.59 -11,987.05 -444.26 0.00 0.00 0.00 0.0000 13,846.07 90.57 179.24 3,320.00 -12,378.64 -439.09 0.50 -0.50 0.00 -179.7901 14,259.64 88.50 179.25 3,323.35 -12,792.14 -433.63 0.50 -0.50 0.00 179.8013 14,454.95 88.50 179.25 3,328.45 -12,987.37 -431.06 0.00 0.00 0.00 0.0000 14,846.52 90.46 179.24 3,332.00 -13,378.87 -425.89 0.50 0.50 0.00 -0.2100 15,015.04 91.30 179.24 3,329.41 -13,547.35 -423.67 0.50 0.50 0.00 0.2706 15,563.51 91.30 179.24 3,316.94 -14,095.63 -416.43 0.00 0.00 0.00 0.0000 15,846.03 89.89 179.24 3,314.00 -14,378.10 -412.69 0.50 -0.50 0.00 -179.8385 16,076.03 91.04 179.24 3,312.13 -14,608.07 -409.64 0.50 0.50 0.00 0.0000 16,850.52. 79.12 179.12 3,378.44 ~ -15,378.24 -398.64 1.54 -1.54 -0.02 -179.4384 3/12/2006 3:38:18PM Page 3 of 10 COMPASS 2003.11 Build 50 ~~, ... .. ., - ~6 n4.wc -` i E S ~ H llib t " ' erv on ner ces a ur JY l-fALL~B W RTAN ~Cii ~CC1 P hf1~~1~35 Planning Report -Geographic ~~ ~~--° q~ Sp~fl'Y Ef~illing Serrrictgrs Database: EDM 2003.11 Single User Db Local Co-ordinate Reference: Well Plan 1J-184 -Slot 1J-184 Company: ConocoPhiilips Alaska (Kuparuk) ND Reference: 1J-184 (28+81) @ 109.OOft (Doyon 141 (28)) Project: Kuparuk River Unit MD Reference: 1J-184 (28+81) @ 109.OOft (Doyon 141 (28)) Site: Kuparuk 1J Pad North Reference: True Well: Plan 1J-184 Survey Calculation Method: Minimum Curvature Wellbore: 1J-184 L1 Design: 1J-184 L1 (wp09) Planned Survey 1J-184 L1 (wp09) _. _ Map Map MD Inclinatio n Azimuth ND SSND +N!-S +E/-W Northing Easting DLSEV Vert Section (ft) (°) {°) (ft) (ft) (ft) (ft) (ft) {ft) (°/100ft) (ftl 8,842.24 80.00 179.24 3,359.00 3,250.00 -7,378.39 -506.20 5,937,961.00 558,341.00 0.00 7,378.39 L1 :TOW @ 8842ft MD, 3359ft ND - 4712 ft FSL & 2938 ft FEL -Sec 11 - T10N - R10E - 9 5!8" 8,850.00 81.05 179.24 3,360.28 3,251.28 -7,386.04 -506.10 5,937,953.35 558,341.16 13.54 7,386.04 8,858.74 82.24 179.24 3,361.55 3,252.55 -7,394.69 -505.99 5,937,944.70 558,341.34 13.66 7,394.69 L1 : BOW @ 8859ft MD, 3362ft ND 8,888.74 82.24 179.24 3,365.60 3,256.60 -7,424.41 -505.59 5,937,914.99 558,341.97 0.00 7,424.41 L1 : End 30' Rathole -Build @ 3°/100ft, 8889ft MD, 3366ft ND 8,900.00 82.58 179.24 3,367.08 3,258.08 -7,435.57 -505.44 5,937,903.83 558,342.20 2.99 7,435.57 8,950.00 84.08 179.24 3,372.89 3,263:89 -7,485.23 -504.79 5,937,854.18 558,343.25 3.00 7,485.23 8,961.10 84.42 179.24 3,374.00 3,265.00 -7,496.27 -504.64 5,937,843.14 558,343.48 3.00 7,496.27 1J-184 L7 DD Poly@ 95% (wp09 ) - 1J-184 L1 Geo-Poly (wp09) 9,000.00 85.58 179.24 3,377.39 3,268.39 -7,535.02 -504.12 5,937,804.40 558,344.30 3.00 7,535.02 9,050.00 87.08 179.24 3,380.59 3,271.59 -7,584.91 -503.46 5,937,754.52 558,345.35 3.00 7,584.91 9,100.00 88.58 179.24 3,382.48 3,273.48 -7,634.87 -502.79 5,937,704.58 558,346.41 3.00 7,634.87 9,150.00 90.08 179.24 3,383.06 3,274.06 -7,684.86 -502.13 5,937,654.60 558,347.47 3.00 7,684.86 9,200.00 91.58 179.24 3,382.34 3,273.34 -7,734.85 -501.46 5,937,604.62 558,348.52 3.00 7,734.85 9,232.74 92.56 179.24 3,381.15 3,272.15 -7,767.56 -501.03 5,937,571.92 558,349.21 3.00 7,767.56 L1 : Sail @ 92.6°, 9233ft MD, 3381ft ND 9,250.00 92.56 179.24 3,380.38 3,271.38 -7,784.80 -500.80 5,937,554.68 558,349.58 0.00 7,784.80 9,300.00 92.56 179.24 3,378.15 3,269.15 -7,834.75 -500.13 5,937,504.74 558,350.64 0.00 7,834.75 9,350.00 92.56 179.24 3,375.91 3,266.91 -7,884.69 -499.46 5,937,454.81 558,351.69 0.00 7,884.69 9,400.00 92.56 179.24 3,373.67 3,264.67 -7,934.64 -498.80 5,937,404.87 558,352.75 0.00 7,934.64 9,450.00 92.56 179.24 3,371.43 3,262.43 -7,984.58 -498.13 5,937,354.94 558,353.81 0.00 7,984.58 9,500.00 92.56 179.24 3,369.20 3,260.20 -8,034.53 -497.46 5,937,305.01 558,354.86 0.00 8,034.53 9,550.00 92.56 179.24 3,366.96 3,257.96 -8,084.48 -496.80 5,937,255.07 558,355.92 0.00 8,084.48 9,600.00 92.56 179.24 3,364.72 3,255.72 -8,134.42 -496.13 5,937,205.14 558,356.98 0.00 8,134.42 9,650.00 92.56 179.24 3,362.49 3,253.49 -8,184.37 -495.46 5,937,155.20 558,358.03 0.00 8,184.37 9,700.00 92.56 179.24 3,360.25 3,251.25 -8,234.31 -494.79 5,937,105.27 558,359.09 0.00 8,234.31 9,750.00 92.56 179.24 3,358.01 3,249.01 -8,284.26 -494.13 5,937,055.34 558,360.14 0.00 8,284.26 9,776.39 92.56 179.24 3,356.83 3,247.83 -8,310.62 -493.78 5,937,028.98 558,360.70 0.00 8,310.62 L1 : Continue Dir @ 3°/100ft to 90.5° Zinc - Continue Undulations in D-Sand, 9776ft MD, 3357ft ND 9,800.00 91.86 179.24 3,355.92 3,246.92 -8,334.21 -493.46 5,937,005.40 558,361.20 3.00 8,334.21 9,844.52 90.52 179.24 3,355.00 3,246.00 -8,378.72 -492.87 5,936,960.90 558,362.14 3.00 8,378.72 1J-184 L1 T1 (Peak 1) (wp09) 9,850.00 90.49 179.24 3,354.95 3,245.95 -8,384.19 -492.80 5,936,955.42 558,362.26 0.50 8,384.19 9,900.00 90.24 179.24 3,354.63 3,245.63 -8,434.19 -492.13 5,936,905.44 558,363.31 0.50 8,434.19 9,950.00 89.99 179.24 3,354.53 3,245.53 -8,484.18 -491.47 5,936,855.46 558,364.36 0.50 8,484.18 10,000.00 89.74 179.24 3,354.64 3,245.64 -8,534.18 -490.81 5,936,805.47 558,365.41 0.50 8,534.18 10,050.00 89.49 179.24 3,354.98 3,245.98 -8,584.17 -490.15 5,936,755.49 558,366.46 0.50 8,584.17 10,100.00 89.24 179.24 3,355.53 3,246.53 -8,634.17 -489.49 5,936,705.51 558,367.51 0.50 8,634.17 10,150.00 88.99 179.25 3,356.30 3,247.30 -8,684.16 -488.83 5,936,655.53 558,368.56 0.50 8,684.16 10,200.00 88.74 179.25 3,357.29 3,248.29 -8,734.14 -488.17 5,936,605.56 558,369.61 0.50 8,734.14 10,229.82 88.59 179.25 3,357.98 3,248.98 -8,763.96 -487.78 5,936,575.75 558,370.23 0.50 8,763.96 10,250.00 88.59 179.25 3,358.48 3,249.48 -8,784.12 -487.52 5,936,555.59 558,370.66 0.00 8,784.12 10,300.00 88.59 179.25 3,359.70 3,250.70 -8,834.10 -486.86 5,936,505.62 558,371.70 0.00 8,834.10 10,350.00 88.59 179.25 3,360.93 3,251.93 -8,884.08 -486.20 5,936,455.65 558,372.75 0.00 8,884.08 10,400.00 88.59 179.25 3,362.16 3,253.16 -8,934.07 -485.55 5,936,405.68 558,373.80 0.00 8,934.07 3/12/2006 3:38:18PM Page 4 of 10 COMPASS 2003.11 Build 50 n, ~..~ Halliburton Energy Services CanaccaPhillips Planning Report -Geographic AJaska Database: EDM 2003.11 Single User Db Company: ConocoPhillips Alaska (Kuparuk) Project: Kuparuk River Unit Site: Kuparuk 1J Pad Well; Plan 1J-184 Wellbore: 1J-184 L1 Design: 1J-184 L1 (wp09) Planned Survey 1J-184 L1 (wp09) I MD Inclination Azimuth ND (ft) (°) (°) (ftl HQLILlBUl~Tt7N Sperry ®riliing Services Local Co-ordinate Reference: Well Plan 1J-184 -Slot 1J-184 ND Reference: 1J-184 (28+81) @ 109.OOft (Doyon 141 (28)) MD Reference: 1J-184 (28+81) @ 109.OOft (Doyon 141 (28)) North Reference: True Survey Calculation Method: Minimum Curvature Map Map SSND +NI-S +E/-W Northing Easting DLSEV Vert Section (ft) (ft) Ift) (ft) (ft) (°/100ft) (ft) 10,450.00 88.59 179.25 3,363.38 3,254.38 -8,984.05 -484.89 5,936,355.71 558,374.84 0.00 8,984.05 10,471.67 88.59 179.25 3,363.92 3,254.92 -9,005.71 -484.61 5,936,334.05 558,375.30 0.00 9,005.71 10,500.00 88.73 179.25 3,364.58 3,255.58 -9,034.03 -484.23 5,936,305.74 558,375.89 0.50 9,034.03 10,550.00 88.99 179.25 3,365.57 3,256.57 -9,084.01 -483.57 5,936,255.77 558,376.94 0.50 9,084.01 10,600.00 89.23 179.24 3,366.35 3,257.35 -9,134.00 -482.92 5,936,205.79 558,377.99 0.50 9,134.00 10,650.00 89.49 179.24 3,366.91 3,257.91 -9,184.00 -482.26 5,936,155.81 558,379.04 0.50 9,184.00 10,700.00 89.73 179.24 3,367.25 3,258.25 -9,233.99 -481.60 5,936,105.82 558,380.09 0.50 9,233.99 10,750.00 89.99 179.24 3,367.37 3,258.37 -9,283.99 -480.93 5,936,055.84 558,381.14 0.50 9,283.99 10,800.00 90.23 179.24 3,367.27 3,258.27 -9,333.98 -480.27 5,936,005.85 558,382.19 0.50 9,333.98 10,844.97 90.46 179.24 3,367.00 3,258.00 -9,378.95 -479.68 5,935,960.90 558,383.14 0.50 9,378.95 1J-184 L1 T2 (Trough 1) (wp09) 10,850.00 90.49 179.24 3,366.96 3,257.96 -9,383.98 -479.61 5,935,955.87 558,383.25 0.50 9,383.98 10,900.00 90.73 179.23 3,366.43 3,257.43 -9,433.97 -478.94 5,935,905.89 558,384.30 0.50 9,433.97 10,950.00 90.98 179.22 3,365.68 3,256.68 -9,483.96 -478.27 5,935,855.91 558,385.37 0.50 9,483.96 11,000.00 91.23 179.21 3,364.71 3,255.71 -9,533.94 -477.58 5,935,805.94 558,386.45 0.50 9,533.94 11,050.00 91.48 179.20 3,363.52 3,254.52 -9,583.92 -476.89 5,935,755.97 558,387.53 0.50 9,583.92 11,100.00 91.73 179.19 3,362.12 3,253.12 -9,633.90 -476.19 5,935,706.01 558,388.62 0.50 9,633.90 11,150.00 91.98 179.18 3,360.49 3,251.49 -9,683.87 -475.48 5,935,656.05 558,389.72 0.50 9,683.87 11,200.00 92.23 179.17 3,358,65 3,249.65 -9,733.83 -474.76 5,935,606.10 558,390.83 0.50 9,733.83 11,226.98 92.37 179.17 3,357.57 3,248.57 -9,760.79 -474.37 5,935,579.15 558,391.43 0.50 9,760.79 11,250.00 92.37 179.17 3,356.62 3,247.62 -9,783.78 -474.04 5,935,556.16 558,391.94 0.00 9,783.78 11,300.00 92.37 179.17 3,354.55 3,245.55 -9,833.73 -473.31 5,935,506.22 558,393.05 0.00 9,833.73 11,350.00 92.37 179.17 3,352.49 3,243.49 -9,883.69 -472.59 5,935,456.28 558,394.17 0.00 9,883.69 11,400.00 92.37 179.17 3,350.42 3,241.42 -9,933.64 -471.86 5,935,406.34 558,395.29 0.00 9,933.64 11,450.00 92.37 179.17 3,348.35 3,239.35 -9,983.59 -471.13 5,935,356.40 558,396.40 0.00 9,983.59 11,475.02 92.37 179.17 3,347.32 3,238.32 -10,008.59 -470.77 5,935,331.41 558,396.96 0.00 10,008.59 11,500.00 92.24 179.17 3,346.31 3,237.31 -10,033.54 -470.41 5,935,306.46 558,397.52 0.50 10,033.54 11,550.00 91.99 179.17 3,344.47 3,235.47 -10,083.50 -469.69 5,935,256.51 558,398.63 0.50 10,083.50 11,600.00 91.74 179.18 3,342.84 3,233.84 -10,133.47 -468.97 5,935,206.55 558,399.74 0.50 10,133.47 11,650.00 91.49 179.18 3,341.42 3,232.42 -10,183.45 -468.25 5,935,156.59 558,400.85 0.50 10,183.45 11,700.00 91.24 179.18 3,340.23 3,231.23 -10,233.43 -467.53 5,935,106.62 558,401.95 0.50 10,233.43 11,750.00 90.99 179.18 3,339.25 3,230.25 -10,283.41 -466.82 5,935,056.65 558,403.06 0.50 10,283.41 11,800.00 90.74 179.19 3,338.49 3,229.49 -10,333.40 -466.11 5,935,006.67 558,404.16 0.50 10,333.40 11,844.79 90.52 179.19 3,338.00 3,229.00 -10,378.18 -465.48 5,934,961.90 558,405.14 0.50 10,378.18 1J-184 L1 T3 (Peak 2) (wp09) 11,850.00 90.49 179.19 3,337.95 3,228.95 -10,383.39 -465.40 5,934,956.69 558,405.25 0.50 10,383.39 11,900.00 90.24 179.20 3,337.63 3,228.63 -10,433.39 -464.70 5,934,906.71 558,406.35 0.50 10,433.39 11,950.00 89.99 179.21 3,337.53 3,228.53 -10,483.38 -464.01 5,934,856.72 558,407.43 0.50 10,483.38 12,000.00 89.74 179.22 3,337.64 3,228.64 -10,533.38 -463.32 5,934,806.74 558,408.51 0.50 10,533.38 12,050.00 89.49 179.23 3,337.97 3,228.97 -10,583.37 -462.64 5,934,756.76 558,409.57 0.50 10,583.37 12,100.00 89.25 179.24 3,338.52 3,229.52 -10,633.37 -461.97 5,934,706.78 558,410.63 0.50 10,633.37 12,150.00 89.00 179.25 3,339.29 3,230.29 -10,683.36 -461.31 5,934,656.80 558,411.68 0.50 10,683.36 12,200.00 88.75 179.26 3,340.28 3,231.28 -10,733.34 -460.66 5,934,606.82 558,412.73 0.50 10,733.34 12,230.59 88.59 179.26 3,340.99 3,231.99 -10,763.92 -460.27 5,934,576.25 558,413.36 0.50 10,763.92 12,250.00 88.59 179.26 3,341.47 3,232.47 -10,783.32 -460.02 5,934,556.85 558,413.76 0.00 10,783.32 12,300.00 88.59 179.26 3,342.69 3,233.69 -10,833.30 -459.37 5,934,506.88 558,414.80 0.00 10,833.30 12,350.00 88.59 179.26 3,343.92 3,234.92 -10,883.28 -458.73 5,934,456.92 558,415.83 0.00 10,883.28 12,400.00 88.59 179.26 3,345.15 3,236.15 -10,933.27 -458.09 5,934,406.95 558,416.86 0.00 10,933.27 12,450.00 88.59 179.26 3,346.38 3,237.38 -10,983.25 -457.44 5,934,356.98 558,417.90 0.00 10,983.25 3/12/2006 3:38:18PM Page 5 of 10 COMPASS 2003.11 Build 50 ~-' ~ Halliburton Energy Services COnOCOPh~tltps Planning Report -Geographic Alaska Database: EDM 2003.11 Single User Db Company: ConocoPhillips Alaska (Kuparuk) Project: Kuparuk River Unit Site: Kuparuk 1J Pad Well: Plan 1J-184 Wellbore: 1J-184 L1 Design: 1J-184 L1 (wp09) Pla enn d Survey 1J-184 L1 (wp09) MD Inclination Azimuth TVD (ft) (°) (°) (ft) Sperry Drilling Services Local Coordinate Reference: Well Plan 1J-184 -Slot 1J-184 TVD Reference: 1J-184 (28+81) @ 109.OOft (Doyon 141 (28)) MD Reference: 1J-184 (28+81) @ 109.OOft (Doyon 141 (28)) North Reference: True Survey Calculation Method: Minimum Curvature Map Map SSTVD +N/-S +E/_yy Northing Easting DLSEV Vert Section (ft) (ft) (ft) Ift) (ft) (°/100ft) (ft) 12,471.68 88.59 179.26 3,346.91 3,237.91 -11,004.91 -457.16 5,934,335.31 558,418.34 0.00 11,004.91 12,500.00 88.73 179.26 3,347.57 3,238.57 -11,033.23 -456.80 5,934,307.01 558,418.93 0.50 11,033.23 12,550.00 88.98 179.26 3,348.57 3,239.57 -11,083.21 -456.15 5,934,257.03 558,419.97 0.50 11,083.21 12,600.00 89.23 179.25 3,349.34 3,240.34 -11,133.20 -455.50 5,934,207.05 558,421.01 0.50 11,133.20 12,650.00 89.48 179.25 3,349.90 3,240.90 -11,183.20 -454.85 5,934,157.07 558,422.05 0.50 11,183.20 12,700.00 89.73 179.25 3,350.25 3,241.25 -11,233.19 -454.20 5,934,107.09 558,423.09 0.50 11,233.19 12,750.00 89.98 179.25 3,350.37 3,241.37 -11,283.19 -453.54 5,934,057.11 558,424.14 0.50 11,283.19 12,800.00 90.23 179.24 3,350.27 3,241.27 -11,333.18 -452.88 5,934,007.12 558,425.19 0.50 11,333.18 12,845.24 90.46 179.24 3,350.00 3,241.00 -11,378.41 -452.28 5,933,961.90 558,426.14 0.50 11,378.41 1J-184 L1 T4 (Trough 2) (wp09) 12,850.00 90.48 179.24 3,349.96 3,240.96 -11,383.18 -452.22 5,933,957.14 558,426.24 0.50 11,383.18 12,900.00 90.73 179.24 3,349.43 3,240.43 -11,433.17 -451.56 5,933,907.16 558,427.29 0.50 11,433.17 12,950.00 90.98 179.24 3,348.68 3,239.68 -11,483.16 -450.89 5,933,857.18 558,428.35 0.50 11,483.16 13,000.00 91.23 179.24 3,347.71 3,238.71 -11,533.14 -450.23 5,933,807.20 558,429.40 0.50 11,533.14 13,050.00 91.48 179.24 3,346.53 3,237.53 -11,583.13 -449.57 5,933,757.23 558,430.45 0.50 11,583.13 13,100.00 91.73 179.24 3,345.12 3,236.12 -11,633.10 -448.91 5,933,707.27 558,431.50 0.50 11,633.10 13,150.00 91.98 179.25 3,343.50 3,234.50 -11,683.07 -448.25 5,933,657.31 558,432.55 0.50 11,683.07 13,200.00 92.23 179.25 3,341.66 3,232.66 -11,733.03 -447.60 5,933,607.36 558,433.59 0.50 11,733.03 13,250.00 92.48 179.25 3,339.60 3,230.60 -11,782.99 -446.94 5,933,557.42 558,434.64 0.50 11,782.99 13,259.02 92.53 179.25 3,339.21 3,230.21 -11,792.00 -446.82 5,933,548.41 558,434.83 0.50 11,792.00 13,300.00 92.53 179.25 3,337.40 3,228.40 -11,832.93 -446.28 5,933,507.48 558,435.69 0.00 11,832.93 13,350.00 92.53 179.25 3,335.19 3,226.19 -11,882.88 -445.63 5,933,457.55 558,436.73 0.00 11,882.88 13,400.00 92.53 179.25 3,332.99 3,223.99 -11,932.83 -444.97 5,933,407.61 558,437.78 0.00 11,932.83 13,450.00 92.53 179.25 3,330.78 3,221.78 -11,982.77 -444.31 5,933,357.68 558,438.82 0.00 11,982.77 13,454.28 92.53 179.25 3,330.59 3,221.59 -11,987.05 -444.26 5,933,353.40 558,438.91 0.00 11,987.05 13,500.00 92.30 179.25 3,328.67 3,219.67 -12,032.73 -443.66 5,933,307.74 558,439.87 0.50 12,032.73 13,550.00 92.05 179.25 3,326.77 3,217.77 -12,082.68 -443.00 5,933,257.79 558,440.92 0.50 12,082.68 13,600.00 91.80 179.24 3,325.09 3,216.09 -12,132.65 -442.34 5,933,207.83 558,441.97 0.50 12,132.65 13,650.00 91.55 179.24 3,323.63 3,214.63 -12,182.63 -441.68 5,933,157.87 558,443.02 0.50 12,182.63 13,700.00 91.30 179.24 3,322.38 3,213.38 -12,232.61 -441.02 5,933,107.90 558,444.07 0.50 12,232.61 13,750.00 91.05 179.24 3,321.36 3,212.36 -12,282.59 -440.36 5,933,057.93 558,445.12 0.50 12,282.59 13,800.00 90.80 179.24 3,320.55 3,211.55 -12,332.58 -439.70 5,933,007.95 558,446.17 0.50 12,332.58 13,846.07 90.57 179.24 3,320.00 3,211.00 -12,378.64 -439.09 5,932,961.90 558,447.14 0.50 12,378.64 1J-184 L7 TS (Peak 3) (wp09) 13,850.00 90.55 179.24 3,319.96 3,210.96 -12,382.57 -439.04 5,932,957.97 558,447.22 0.50 12,382.57 13,900.00 90.30 179.24 3,319.59 3,210.59 -12,432.57 -438.37 5,932,907.99 558,448.28 0.50 12,432.57 13,950.00 90.05 179.24 3,319.44 3,210.44 -12,482.56 -437.71 5,932,858.00 558,449.33 0.50 12,482.56 14,000.00 89.80 179.24 3,319.50 3,210.50 -12,532.56 -437.05 5,932,808.02 558,450.38 0.50 12,532.56 14,050.00 89.55 179.24 3,319.79 3,210.79 -12,582.55 -436.39 5,932,758.04 558,451.43 0.50 12,582.55 14,100.00 89.30 179.24 3,320.29 3,211.29 -12,632.55 -435.73 5,932,708.05 558,452.48 0.50 12,632.55 14,150.00 89.05 179.25 3,321.01 3,212.01 -12,682.54 -435.07 5,932,658.08 558,453.53 0.50 12,682.54 14,200.00 88.80 179.25 3,321.94 3,212.94 -12,732.52 -434.41 5,932,608.10 558,454.58 0.50 12,732.52 14,250.00 88.55 179.25 3,323.10 3,214.10 -12,782.51 -433.76 5,932,558.13 558,455.62 0.50 12,782.51 14,259.64 88.50 179.25 3,323.35 3,214.35 -12,792.14 -433.63 5,932,548.49 558,455.83 0.50 12,792.14 14,300.00 88.50 179.25 3,324.40 3,215.40 -12,832.48 -433.10 5,932,508.16 558,456.67 0.00 12,832.48 14,350.00 88.50 179.25 3,325.71 3,216.71 -12,882.46 -432.44 5,932,458.20 558,457.72 0.00 12,882.46 14,400.00 88.50 179.25 3,327.02 3,218.02 -12,932.44 -431.79 5,932,408.23 558,458.77 0.00 12,932.44 14,450.00 88.50 179.25 3,328.32 3,219.32 -12,982.42 -431.13 5,932,358.26 558,459.81 0.00 12,982.42 14,454.95 88.50 179.25 3,328.45 3,219.45 -12,987.37 -431.06 5,932,353.31 558,459.92 0.00 12,987.37 3/12/2006 3:38:18PM Page 6 of 10 COMPASS 2003.11 Build 50 ) «~'~~ ~: ,, ... ti-' Halliburton Energy Services ~~~~~~~~,~»~ ~k)t1ACAP~11~~ Planning Report -Geographic - -~~------~------~----°~°~---~--~ Sperry DriNing Sanrices Database: EDM 2003.11 Single User Db Local Co-ordinate Reference: Well Plan 1J-184 -Slot 1J-184 Company: ConocoPhillips Alaska (Kuparuk) TVD Reference: 1J-184 (28+81) @ 109.OOft (Doyon 141 (28)) Project: Kuparuk River Unit MD Reference: 1J-184 (28+81) @ 109.OOft (Doyon 141 (28)) Site: Kuparuk 1 J Pad North Reference: True Well; Plan 1J-184 Survey Calculation Method: Minimum Curvature Welibore: 1J-184 L1 Design: 1J-184 L1 (wp09) Pla denn Survey 1J-184 L1 (wp09) Map Map MD Inclination Azimuth TVD SSTVD +N/-S +E/-W Northing Easting DLSEV Vert Section (ft) (°) (°) (ft) (ft) (ft) (ft) (ft) (ft) (°/100ft) (ft) ~ 14,500.00 88.73 179.25 3,329.54 3,220.54 -13,032.40 -430.47 5,932,308.29 558,460.86 0.50 13,032.40 14,550.00 88.98 179.25 3,330.54 3,221.54 -13,082.39 -429.81 5,932,258.32 558,461.91 0.50 13,082.39 14,600.00 89.23 179.24 3,331.33 3,222.33 -13,132.38 -429.15 5,932,208.34 558,462.96 0.50 13,132.38 14,650.00 89.48 179.24 3,331.89 3,222.89 -13,182.37 -428.50 5,932,158.36 558,464.01 0.50 13,182.37 14,700.00 89.73 179.24 3,332.24 3,223.24 -13,232.36 -427.83 5,932,108.38 558,465.06 0.50 13,232.36 14,750.00 89.98 179.24 3,332.37 3,223.37 -13,282.36 -427.17 5,932,058.39 558,466.11 0.50 13,282.36 14,800.00 90.23 179.24 3,332.28 3,223.28 -13,332.35 -426.51 5,932,008.41 558,467.16 0.50 13,332.35 14,846.52 90.46 179.24 3,332.00 3,223.00 -13,378.87 -425.89 5,931,961.90 558,468.14 0.50 13,378.87 1J-184 L1 T6 (Trough 3) (wp09) 14,850.00 90.48 179.24 3,331.97 3,222.97 -13,382.35 -425.85 5,931,958.42 558,468.21 0.50 13,382.35 14,900.00 90.73 179.24 3,331.45 3,222.45 -13,432.34 -425.19 5,931,908.44 558,469.27 0.50 13,432.34 14,950.00 90.98 179.24 3,330.70 3,221.70 -13,482.33 -424.52 5,931,858.46 558,470.32 0.50 13,482.33 15,000.00 91.23 179.24 3,329.74 3,220.74 -13,532.32 -423.86 5,931,808.49 558,471.37 0.50 13,532.32 15,015.04 91.30 179.24 3,329.41 3,220.41 -13,547.35 -423.67 5,931,793.46 558,471.68 0.50 13,547.35 15,050.00 91.30 179.24 3,328.61 3,219.61 -13,582.30 -423.20 5,931,758.52 558,472.42 0.00 13,582.30 15,100.00 91.30 179.24 3,327.48 3,218.48 -13,632.28 -422.54 5,931,708.55 558,473.47 0.00 13,632.28 15,150.00 91.30 179.24 3,326.34 3,217.34 -13,682.27 -421.89 5,931,658.58 558,474.52 0.00 13,682.27 15,200.00 91.30 179.24 3,325.20 3,216.20 -13,732.25 -421.23 5,931,608.60 558,475.57 0.00 13,732.25 15,250.00 91.30 179.24 3,324.07 3,215.07 -13,782.23 -420.57 5,931,558.63 558,476.62 0.00 13,782.23 15,300.00 91.30 179.24 3,322.93 3,213.93 -13,832.21 -419.91 5,931,508.66 558,477.67 0.00 13,832.21 15,350.00 91.30 179.24 3,321.79 3,212.79 -13,882.20 -419.25 5,931,458.69 558,478.72 0.00 13,882.20 15,400.00 91.30 179.24 3,320.66 3,211.66 -13,932.18 -418.59 5,931,408.72 558,479.77 0.00 13,932.18 15,450.00 91.30 179.24 3,319.52 3,210.52 -13,982.16 -417.93. 5,931,358.75 558,480.82 0.00 13,982.16 15,500.00 91.30 179.24 3,318.38 3,209.38 -14,032.14 -417.27 5,931,308.78 558,481.87 0.00 14,032.14 15,550.00 91.30 179.24 3,317.25 3,208.25 -14,082.13 -416.61 5,931,258.81 558,482.91 0.00 14,082.13 15,563.51 91.30 179.24 3,316.94 3,207.94 -14,095.63 -416.43 5,931,245.31 558,483.20 0.00 14,095.63 15,600.00 91.12 179.24 3,316.17 3,207.17 -14,132.11 -415.95 5,931,208.83 558,483.96 0.50 14,132.11 15,650.00 90.87 179.24 3,315.30 3,206.30 -14,182.10 -415.29 5,931,158.86 558,485.02 0.50 14,182.10 15,700.00 90.62 179.24 3,314.65 3,205.65 -14,232.09 -414.63 5,931,108.88 558,486.07 0.50 14,232.09 15,750.00 90.37 179.24 3,314.22 3,205.22 -14,282.08 -413.97 5,931,058.89 558,487.12 0.50 14,282.08 15,800.00 90.12 179.24 3,314.00 3,205.00 -14,332.08 -413.30 5,931,008.91 558,488.17 0.50 14,332.08 15,846.03 89.89 179.24 3,314.00 3,205.00 -14,378.10 -412.69 5,930,962.90 558,489.14 0.50 14,378.10 L1 : End Undulations in D-Sand, 15846ft MD, 3314ft TVD - 1J-184 L1 T7 (Peak 4) (wp09) 15,850.00 89.91 179.24 3,314.01 3,205.01 -14,382.08 -412.64 5,930,958.93 558,489.22 0.50 14,382.08 15,900.00 90.16 179.24 3,313.98 3,204.98 -14,432.07 -411.98 5,930,908.94 558,490.28 0.50 14,432.07 15,950.00 90.41 179.24 3,313.73 3,204.73 -14,482.07 -411.31 5,930,858.96 558,491.33 0.50 14,482.07 16,000.00 90.66 179.24 3,313.26 3,204.26 -14,532.06 -410.65 5,930,808.98 558,492.38 0.50 14,532.06 16,050.00 90.91 179.24 3,312.58 3,203.58 -14,582.05 -409.99 5,930,759.00 558,493.44 0.50 14,582.05 16,076.03 91.04 179.24 3,312.13 3,203.13 -14,608.07 -409.64 5,930,732.98 558,493.99 0.50 14,608.07 L1 : Begin Drop @ 1.6°/100ft to B -Sand Top, 1 6076ft MD, 3312ft TVD 16,100.00 90.67 179.24 3,311.78 3,202.78 -14,632.04 -409.32 5,930,709.02 558,494.49 1.54 14,632.04 16,150.00 89.90 179.23 3,311.53 3,202.53 -14,682.03 -408.65 5,930,659.04 558,495.55 1.54 14,682.03 16,200.00 89.13 179.22 3,311.95 3,202.95 -14,732.03 -407.98 5,930,609.06 558,496.62 1.54 14,732.03 16,250.00 88.36 179.21 3,313.04 3,204.04 -14,782.01 -407.30 5,930,559.08 558,497.69 1.54 14,782.01 16,300.00 87.59 179.21 3,314.81 3,205.81 -14,831.97 -406.61 5,930,509.13 558,498.77 1.54 14,831.97 16,350.00 86.82 179.20 3,317.24 3,208.24 -14,881.91 -405.91 5,930,459.21 558,499.85 1.54 14,881.91 16,400.00 86.05 179.19 3,320.35 3,211.35 -14,931.81 -405.21 5,930,409.32 558,500.94 1.54 14,931.81 16,450.00 85.28 179.18 3,324.12 3,215.12 -14,981.66 -404.50 5,930,359.48 558,502.04 1.54 14,981.66 16,500.00 84.52 179.18 3,328.57 3,219.57 -15,031.46 -403.79 5,930,309.70 558,503.14 1.54 15,031.46 3/12/2006 3:38:18PM Page 7 of 10 COMPASS 2003.11 Build 50 ~'~ .~ ..: ~w' Halliburton Energy Services CC?l1000PIIl~IlpS Planning Report -Geographic Alaska Database: EDM 2003.11 Single User Db Company: ConocoPhillips Alaska (Kuparuk) Project: Kuparuk River Unit Site: Kuparuk 1 J Pad Well: Plan 1J-184 Wellbore: 1J-184 L1 Design: 1J-184 L1 (wp09) Planned Survey 1J-184 L1 (wp09) Map Map MD Inclination Azimuth ND SSTVD +N/-S +E/-W Northing Easting DLSEV Vert Section (ft) (°) (°) (ft) (ft) (ft) (ft) (ft) (ft) (°/100ft) (ft) 16,550.00 83.75 179.17 3,333.68 3,224.68 -15,081.19 -403.07 5,930,259.98 558,504.25 1.54 15,081.19 16,600.00 82.98 179.16 3,339.46 3,230.46 -15,130.85 -402.35 5,930,210.33 558,505.36 1.54 15,130.85 16,650.00 82.21 179.15 3,345.91 3,236.91 -15,180.42 -401.62 5,930,160.77 558,506.48 1.54 15,180.42 16,700.00 81.44 179.15 3,353.02 3,244.02 -15,229.91 -400.88 5,930,111.29 558,507.60 1.54 15,229.91 16,750.00 80.67 179.14 3,360.80 3,251.80 -15,279.29 -400.14 5,930,061.92 558,508.72 1.54 15,279.29 16,800.00 79.90 179.13 3,369.24 3,260.24 -15,328.57 -399.40 5,930,012.65 558,509.85 1.54 15,328.57 16,850.00 79.13 179.12 3,378.34 3,269.34 -15,377.73 -398.65 5,929,963.51 558,510.99 1.54 15,377.73 16,850.52 79.12 179.12 3,378.44 3,269.44 -15,378.24 -398.64 5,929,963.00 558,511.00 1.54 15,378.24 L1 : TD @ 16851ft MD , 33781ft ND : 1992ft FSL & 2838ft FEL -Sec 14 - T10N - R10 E - 5112" -1J-184 L1 T8 (Top B) (wp09) ~" Local Co-ordinate Reference: Well Plan 1J-184 -Slot 1J-184 TVD Reference: 1J-184 (28+81) @ 109.OOft (Doyon 141 (28)) MD Reference: 1J-184 (28+81) @ 109.OOft (Doyon 141 (28)) North Reference: True Survey Calculation Method: Minimum Curvature HAt.L.tRURTC3IV ~nY Drilling 8~srvltces 3/12/2006 3:38:18PM Page 8 of 10 COMPASS 2003.11 Build 50 ~ s t t ~'-` • '" Halliburton Energy Services N~ns_~t~uRT©N Canoca Phill~ps Planning Report -Geographic -- - ° ---- Sperry Drilling SnrviCes Database: EDM 2003.11 Single User Db Local Co-ordinate Reference: Well Plan 1J-184 -Slot 1J-184 Company: ConocoPhillips Alaska (Kuparu k) ND Reference: 1J-184 (28+81) @ 109.OOft (Doyon 141 (28)) Project: Kuparuk River Unit MD Reference: 1J-184 (28+81) @ 109.OOft (Doyon 141 (28)) Site: Kuparuk 1J Pad North Reference: True Well: Plan 1J-184 Survey Calculation Method: Minimum Curvature Wellbore: 1J-184 L1 Design: 1J-184 L1 (wp09) Geologic Targets 1 J 184 L1 ND Target Name +N/-S +EI-W Northing Easting (ft) -Shape ft ft (ft) (ft) 3,314.00 1J-184 L1 T7 (Peak 4) (wp09) -14,378.10 -412.69 5,930,962.90 558,489.14 - Point 3,378.44 1J-184 L1 T8 (Top B) (wp09) -15,378.24 -398.64 5,929,963.00 558,511.00 - Point 3,374.00 1J-184 L1 Geo-Poly (wp09) -7,378.39 -506.20 5,937,961.00 558,341.00 - Polygon Point 1 -121.01 0.94 5,937,961.00 558,220.00 Point 2 -82.47 -4,157.88 5,933,803.00 558,291.00 Point 3 -46.42 -7,995.65 5,929,966.00 558,357.00 Point 4 262.60 -7,998.06 5,929,966.00 558,666.00 Point 5 196.57 -4,157.06 5,933,806.00 558,570.00 Point 6 122.01 -0.95 5,937,961.00 558,463.00 3,332.00 1J-184 L1 T6 (Trough 3) (wp09) -13,378.87 -425.89 5,931,961.90 558,468.14 - Point 3,374.00 1J-184 L1 DD Poly@ 95% (wp09 ) -7,378.39 -506.20 5,937,961.00 558,341.00 - Polygon Point 1 -50.00 0.39 5,937,961.00 558,291.00 Point 2 -36.67 -999.94 5,936,960.90 558,312.14 Point 3 -23.48 -2,000.17 5,935,960.90 558,333.14 Point 4 -9.28 -2,999.41 5,934,961.90 558,355.14 Point 5 3.92 -3,999.64 5,933,961.90 558,376.14 Point 6 17.11 -4,999.87 5,932,961.90 558,397.14 Point 7 30.30 -6,000.10 5,931,961.90 558,418.14 Point 8 43.51 -6,999.33 5,930,962.90 558,439.14 Point 9 56.73 -7,996.45 5,929,966.00 558,460.15 Point 10 156.74 -7,997.24 5,929,966.00 558,560.15 Point 11 143.51 -7,000.11 5,930,962.90 558,539.14 Point 12 130.31 -6,000.88 5,931,961.90 558,518.14 Point 13 117.12 -5,000.65 5,932,961.90 558,497.14 Point 14 103.92 -4,000.42 5,933,961.90 558,476.14 Point 15 90.73 -3,000.19 5,934,961.90 558,455.14 Point 16 76.54 -1,999.95 5,935,961.90 558,433.14 Point 17 63.34 -1,000.72 5,936,960.90 558,412.14 Point 18 50.00 -0.39 5,937,961.00 558,391.00 3,367.00 1J-184 L1 T2 (Trough 1) (wp09) -9,378.95 -479.68 5,935,960.90 558,383.14 - Point 3,350.00 1J-184 L1 T4 (Trough 2) (wp09) -11,378.41 -452.28 5,933,961.90 558,426.14 -Point 3,355.00 1J-184 L1 T1 (Peak 1) (wp09) -8,378.72 -492.87 5,936,960.90 558,362.14 - Point 3,338.00 1J-184 L1 T3 (Peak 2) (wp09) -10,378.18 -465.48 5,934,961.90 558,405.14 - Point 3,320.00 1J-184 L1 T5 (Peak 3) (wp09) -12,378.64 -439.09 5,932,961.90 558,447.14 - Point 3/12/2006 3:38:18PM Page 3 of 10 COMPASS 2003.11 Build 50 ~ ~ .~ `t ._ Halliburton Energy Services HA-€..L.tBUI'~Ti~'tV CanacoP hi~ps Planning Report -Geographic - v Sperry Drillfng Servlices Database: EDM 2003.11 Single User Db Local Co-ordinate Reference: Well Plan 1J-184 -Sl ot 1J-184 Company: ConocoPhillips Alaska (Ku paruk) ND Reference: 1 J-184 (28+81) @ 109.OOft (Doyon 141 (28)) Project: Kuparuk River Unit MD Reference: 1J-184 (28+81) @ 109.OOft (Doyon 141 (28)) Site: Kuparuk 1 J Pad North Reference: True Well: Plan 1J-184 Survey Calculation Method: Minimum Curvature Wellbore: 1J-184 L1 Design: 1J-184 L1 (wp09) Prognosed Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (ft) (ft) ('~) (") 120.00 120.00 20 40 3,638.76 2,150.00 13-3/8 16 8,842.25 3,359.00 9-5/8 12-1 i4 16,850.51 3,378.44 5-1i2 8-112 Prognosed Formation Intersection Points Measured Vertical Depth Inclination Azimuth Depth +N/-E +E/-W lft) (°) (°) lftl (ft) (ft) Name 1,684.81 49.01 200.00 1,526.00 -507.01 -184.54 Base of Permafrost 1,854.56 53.56 196.11 1,634.00 -630.96 -226.47 T3 2,768.37 76.45 182.00 1,946.00 -1,474.93 -308.15 K15 3,638.76 76.45 182.00 2,150.00 -2,320.56 -337.71 T3 + 550 6,245.67 76.45 182.00 2,761.00 -4,853.31 -426.23 UGNU C 7,188.59 76.45 182.00 2,982.00 -5,769.41 -458.25 UGNU B 7,470.19 76.45 182.00 3,048.00 -6,042.99 -467.81 UGNU A 8,114.45 76.45 182.00 3,199.00 -6,668.93 -489.69 K13 8,773.13 80.00 179.24 3,347.00 -7,310.34 -507.11 West Sak D 3/12/2006 3.~38:18PM Page 10 of 10 COMPASS 2003.11 Build 50 a ~ r. • ~ ConocoPhillips Alaska ConocoPhillips Alaska (Kuparuk) Kuparuk River Unit Kuparuk 1J Pad Plan 1J-184 1J-184 L1 1J-184 L1 (wp09) Anticollision Report 12 March, 2006 a v~Y(~~~ {~r~~- l.~ lS~ L z. ~1-~~..~ Sperm Drilling Services r ~ ~ ~ i ~..~ ~ Y F asa o ? $ E;~~m Y ^ d CyV_~ ~ 3m EUTa' '°N ~EAWv a ~3 8~~°'t 6 .~ L ~ ~ ~ C t ~ L ~O.t.N O p W ~ ~ C O _ A W O U W V Op N' ~N ar o :- J~ w c a .ii °o $'z J_ ero a W 9~ O J ~ n 3 ~ a a ~ aN c ocm N ~Wm a n y n Q C C in~nn Z> 3v ul~ ~$ H~ O rn! o ,~ « i ~ n 3 Z ~uJ N F N N 7~ Orm~ o~ ~a 7 U Ky ~ ° E c 2 LL a o°iEd m~ ~~ o ~ at a c v -O O 0 0 r~ 0 ch 0 m .N- V N N m 0 N n 3 ~ 3 ; 3 rn a L ° m a ~ a ~ a ~ a ~ J J J J J J J J m m 4 w o m ~ ~ ~ i «nnv,.~on< "Oie`a vimneiO.~mnw.-mma °o,o ~o .-«{m n~e~ea vlo<V 1`Gmri vimoaa oriaoNnq~in onvi o ao ae ~ n n O nnnnowyy yC OWN ~ndOdvy~i LLLL Ob O~O~NO r V OOO~i0A00~AO ~1on r 0 0 0 g 0 O q N ~meo ooou~io nv~io vii v~io vii v~io nv~ioHHOHnn F O no~ooooeeoooooooeeoooo~ W 4411 Z 3 N ' n n V N ~ b 0 b b b O W avi vi Sri cin $ein^vie roi vi ~n ~ui ri viN eim F `'7 `?'?'7YYYYYYV44Y~~~YgYYYYYY? V W N ~rm'IPO N 'T~N~mmdoob~ rni enD rhib~ON 3n~N n +i V ^~inmrnoi V mnen AaQ b iQT ~ n V OdN QOe vi ~°u v' n mm°o na°oa°m °o ~~ Za r~i~n~.°a '~°nn°nw~n~~~n ~'~' o°rvrv.°.~.°V .°~~HnnN~n~«rHNr«rrrr °rv n.°~~~ °r°+f°.u1°innnwaMMnnnanu'in°n °w a.°°nm°o~ p r a m N N e~ m n~ of ~d°n npcminyHn~n p1 ydy e~udn ep ep e0 mmaf OoO~~~NNNhdMdd V NNNbb N ~ ti n a n b n ao m~ ~ ~ ~ ~ ~ ~ ~ ~ ~ n n r r n H H C^ C 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 O N O N O N v01 r O N O N O N 0~ 0 N O~ O N v1 n ~ ~ ~ ~ N N ch NJ N W~ m r r ~ ~ IIII I I~Ilil II'll 0 0 0 0 0 0 0 0 0 0 0 pppp 0 0 0 0 0 0 0 0 N~ n O N~ r O h 0~ 0~ 0~ 0~ 0~ O ~ ~ ~ ~ N N M M N tp OD m~~ .V- N 0 m ~~ UU c yaa C ,aCi x z_~ Y _~~c ~ ~ Fu~E o i ~ ~ _= ~ 8 ~ H F~~eS Y. c ~~~ =_38~ ~~x~ D N Cr o ,- `°-~ c r- o 0 $ 0 0 O O i cw~ smog NsZ_. $~o~~ Z ea`m(? A«_ «E ~ a~'~$E O = ' o ~ E __ 3~va~~ W d9 U ~ o W K df LL KCKKo K W O N S m zZ?°3 '"°°v V t N h `q j ~e U f • • ConocoPhillips Alaska Company: ConocoPhillips Alaska (Kuparuk) Project: Kuparuk River Unit Reference Site: Kuparuk 1 J Pad Site Error: O.OOft Reference Well: Plan 1J-184 Well Erroc O.OOft Reference Wellbore 1J-184 L1 Reference Design: 1J-184 L1 (wp09) Haitiburton Energy Services Anticollision Report Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Output errors are at Database: Offset TVD Reference: HALLtBURTQN Sperry Drilling Services Well Plan 1 J-184 -Slot 1 J-184 1 J-184 (28+81) @ 109.OOft (Doyon 141 (28)) 1J-184 (28+81) @ 109AOft (Doyon 141 (28)) True Minimum Curvature 2.00 sigma EDM 2003.11 Single User Db Offset Datum Reference 1J-184 L1 (wp09) Filter type: GLOBAL FILTER APPLIED: All wellpaths within 200'+ 100/1000 of reference Interpolation Method: MD Interval 50.OOft Error Model: Depth Range: 8,842.24 to 16,850.52ft Scan Method: Results Limited by: Maximum center-center distance of 1,882.25ft Enor Surface: Warning Levels evaluated at: 0.00 Sigma ISCWSA Trav. Cylinder North Elliptical Conic Survey Tool Program Date 3/12/2006 From To (ft) (ft) Survey (Wellbore) Tool Name 28.00 800.00 1J-184 (wp09) (1J-184) CB-GYRO-SS 800.00 8,842.24 1J-184 (wp09) (1J-184) MWD+IFR-AK-CAZ-SC 8,842.24 16,850.52 1J-184 L1 (wp09) (1J-184 L1) MWD+IFR-AK-CAZ-SC Description Camera based gyro single shot MWD+IFR AK CAZ SCC MWD+IFR AK CAZ SCC Summary Site Name Offset Well -Wellbore -Design Kuparuk 1J Pad 1 J-14 - 1 J-14 - 1 J-14 Plan 1J-129 (013 Phase 2) -Plan 1J-129 - 1J-129 Plan 1J-130 -Plan 1J-130 - 1J-130 (wp02) Plan 1 J-132 (012 Phase 2) - Pian 1 J-132 -1 J-132 Plan 1J-133 - 1J-133 - 1J-133 (wp06) Plan 1J-133 - 1J-133 L1 - 1J-133 L1 (wp06) Plan 1J-135 -Plan 1J-135 -Plan 1J-135 (wp01) Plan 1J-136 - 1J-136 - 1J-136 (wp03) Plan 1J-136 - 1J-136 L7 - 1J-136 L1 (wp03) Plan 1 J-137 - 1 J-137 - 1 J-137 (wp03) Plan 1J-137 - 1J-137 L1 - 1J-137 L1 (wp03) Plan 1J-174 (01 Phase 2) -Plan 1J-174 - 1J-174( Plan 1J-176 (02 Phase 2) -Plan 1J-176 - 1J-176 Plan 1J-178 (Q3 Phase 2) -Plan 1J-178 - 1J-178 Plan 1J-180 (04 Phase 2) -Plan 1J-180 - 1J-180 Plan 1 J-182 -1 J-182 - 1 J-182 (wp05) Plan 1J-182 - 1J-182 L1 - 1J-182 L1 (wp05) Plan 1 J-184 - 1 J-184 - 1 J-184 (wp09) Kuparuk River Unit Non Pad West Sak 5 -West Sak 5 -West Sak 5 Reference Offset Centre to No•Go Allowable Measured Measured Centre Distance Deviation Warning Depth Depth Distance (ft) from Plan (ft) (ft) (ft) (ft) 16,844.30 16,750.00 1,078.13 476.20 602.87 16,798.46 16,709.54 1,078.53 488.73 590.16 16,102.96 16,299.93 1,433.85 453.53 16,111.58 16,299.93 1,432.89 418.29 16,804.31 16,799.93 23.83 359.68 10,198.55 3,350.00 349.94 / 318.62 981.07 1,015.41 -140.13 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 Pass -Major Risk Pass -Major Risk Out of range Out of range Out of range Out of range Pass -Major Risk Pass -Major Risk FAIL -Minor Risk 31.33 Pass -Major Risk CC -Min centre to center distance or covergent point, SF -min separation factor, ES -min ellipse separation 3/12/2006 3:41:23PM Page 2 of 3 COMPASS 2003.11 Build 50 k iJ-184Li~brillina Hazards~um (SEE WELL PLAN AND ATTACHMENTS FOR DETAILED DISCUSSION OF THESE RISKS) Production Hole Hazard Risk Level Miti ation Strate Abnormal Reservoir Low Stripping drills, shut-in drills, increased Pressure mud wei ht. Stuck Pipe Low Good hole cleaning, PWD tools, hole o ener runs decreased mud wei ht Lost Circulation Low .Reduced um rates, mud rheolo , LCM Hole Swabbing on Trips Moderate Trip speeds, proper hole filling (use of trip sheets , um in out, backreamin ~~ ~ ~. ~ ~ ~ ~ ~ 1J-184L1 Drilling Hazards Summary 1 ~ ~ ~~ ~ ~ ~" 3/29/2006 3:04 PM Tubing, Special Drift to +/- 500' MD DB Nipple, set at +l- 500' MD `. GLM, Camco, 4112" x 1" KBMG 73-318" Casing Shoe, /GLM, Camco, 41/2" x 1" KBMG 68#, L-80, BTC set ~ // 3639' MD, 2150' ND CMD Sliding Sleeve, wl DB Nipple ConocoPhillips West Sak 9-5/8" Injector 1 J-184 Dual Lateral Completion Tubing String / 4112" 12.6#, L-80, IBTM 3.958" ID, 3.833" Drift Locating seal Assemay .4.75" Seal OD 7" % 9-518" ZXP Winer Top Packer hh Hold Downs Casing Sealbore F an° ID Assembly 7" X 9-518" ZXP Liner Top Packer with Hold Downs 7.500" Tieback Ext. ID 6.278" Tool Body ID Casing Sealbore Receptacle 4.75" ID, 5.75" OD 20' Length ifs OAenting Profile Automatic Alignment of LEM Positive Latching Collet \ Indicates Correct Location Seal Bore for Lateral Isolation - 3.688" ID Access Window ` Positive Lateral Access Via \ Thru-Tubing Diverter Seal Bore for Lateral Isolation - 3.688" ID ~\ Isolation Seal Asembly 4.75" Seal OD 3.875" Seal ID 2' Length Lateral Entry Module(~fyl).` C ~ _- ' - --__- - - _ pfede B-sand Window 'D' Sand Lateral at 8/842' MD, 3359' ND 51/Y' 15.Sa, L-BO Slotted Liner ((( Every Other Jdnl /5.112" Bent Jdnt 57/2" X 9-518" .,e ~ Liner Swivel As Planned ~~-^ Baker Oil Tools With Div Lateral GS Running Tod Strirg erters and Isolation Access Diverter Lateral Isdation Dlvrrrter InsWkd Insblkad p.oo" Laterel Drml IzsO° ID Mainbore Drml 'GS' ProOb for Cdl Connector l RunninglRetrievirp ` ~, (7.00' Length( a i Snap INSnap Out r Back Pressure Valve .~POSitive LOwtatg~ (1.60' Length) Collet I I Lateral Isolation ~~ r Flow-Thru Swivel Seals (t.zs Length/ Lateral Deserter ~ / Hydraulic Ramp ~ Disconnect IsolatioN Mainbae~e I (1.50' Length) ~ ' DiverMr Sleeve GS Spear ~ ' L t l I Wd ~" .50 Length) a era so on Seals j 8.es n Approx OAL• r I, I tars may be required in highly deviated 19' Diverter Length 19' Sleeve Length 51/2" Guide Shoe s-vz•• ca9mg snae,lss#, L-eo B ~guipment SDecifications p 3.582" DB Nlppb Set (8 16851' MD, 3378' ND ~"~ $-1/2° X 9-5/8" HOOK Hanger* I _ Mainbore Drift: 7.00" _ 4112" 12.6#TUbing Mainbore DATt, with diverter: 6.25" 3.837" DrM _ Lateral Drift, no diverter or LEM: 4.88" 3.958" ID ~-~ ~ -'-- ~ - ~ Lateral Drift, w/diverter, no LEM: 4.50" LateragMainbore Diverter OD: 8.50" T' %9-5~8" ZSP Liner To Packer Seal Assembty 4-112" Lateral Entry Module p 4.7s••se~oD 7.875"ID p '13' Sand Lateral Mainbore Drgt: 3.68" Mainbore Drift, w/ isolation sleeve: 2.50" ' " 5112" 15.5%, L-80 Sbtted Liner Lateral Drib, wl coil diverter: 3.00" x 9-518 Flex Look T Liner Hanger I Packer Assembty at Liner Hanger Every Other Joint 5112" Eccentric OD of Diverter and Sleeve: +/- 3,60" ' «I- 9750' MD Guide snce Diverter and Sleeve Length: +1-19 'iliese tl ms are spec tc to the PZ reworketl ens pmenl. Casing Sealbore Receptacle 4.75" ID 9-518" Casing Shoe, 40.0#, L-80 BTC ~ 9254' MD, 3428' ND (84 deg inc) J esker Hughes 3005. This document may not be reproduced or disnibulM, in whole or In part, in any farm or by any means erocnomc or mechanical, mclmmv phomcopyme, r«oming, or by any information alorace and retrkval system now (mown or hereaner invented, without wrinen permission from Baker Nuahes Inc. 5-1/2" Casing Shoe, 15.5#, BTCM Set @ 17626' MD, 3619' ND a • I • • TRANSMITTAL LETTER CHE/CKLIST WELL NAME /~i~GL ~-T /g 7' L- l PTD# ~~~-~7~ 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 segment of existing well K~C.e /..,7= /S~/ , (If last two digits in permit No. L~ -Dy , API No. 50-C3Z - 305~~ API number are between 60-69) Production should continue to be reported as a function of the original API number stated above. PILOT HOLE In accordance with 20 AAC 25.005(f), all records, data and logs acquired for the pilot hole must be clearly differentiated in both well name ( PH) and API number (50- - -~) from records, data and logs acquired for well SPACING The permit is approved subject to full compliance with 20 AAC EXCEPTION 25.055. Approval to perforate and produce /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 Well for (name of well) until after (Company Name) has designed and implemented a water well testing program to provide baseline data on water quality and quantity. ~Company Name) must contact the Commission to obtain advance approval of such water well testing ro ram. Rev: 1 /25/06 C : \j ody\transmittal_checkl ist WELL PERMIT CHECKLIST Field & Pool KUPARUK RIVER, WEST SAK OIL -490150 Well Name: KUPARUK RIV U WSAK 1J-184L1 Program SER _________-___ Well bore seg ^~ PTD#:2060450 Company CONOCOPHILLIPS ALASKA INC Initial ClasslType SER! PEND GeoArea 890 Unit 11160 OnlOff Shore On Annular Disposal ^ Administration 1 Permitfee attached_ _ - - - - - NA_ _ - _ _ - - - West Sak p Sand multilateral well branch; fee waived per 20 AAC 25.Q05(e).. - - . - - . - 2 Lease number appropriate___________________..-.._-.-.. --..--..-Yes_-__--_ Top-prod_inteNalirtADL_25662_andTD-inADL 380058.-.-__________ __ __ ___ ___ _______ 3 Uniquewell_nameandnumbe[_____________________________ _________Yes_____-_ 4 Well located in a_defined-pool_ _ _ _ _ - . - _ - - -Yes _ - _ _ - - _ KUPARUK RIVER,-WEST SAK OIL-490150 ov_erned b CO 4066 9- y 5 Well located proper diskance-from drilling unit_boundary- - - - - - - - - - - - - - - - - - - - - - - -Yes _ . - - .. - CO 4Q6B speCifes no restrictions ag to well spacing except that no pay shall_be opened in-a well_ _ _ _ _ _ _ _ .. _ 6 Well located proper distance_ f[o_m other wells- - - - - - - - - - - - - - - - - - - - - - - - - - - Yes - closer than 500 feet to an external_propefij line where ownership_or landownership changes. - 7 Sufficient acreageayailableindrillingunit ___________________ Yes____-- ------__--__-.------.-___-_-__-_______--__--__-----_---__-_-_-- _- 8 Ifdeviated,is-wellboreplat-included__________________________ _______ _Yes____-. .-..-._..._-...:.._...__ -- - - - 9 Operator only effected party- - - - - - Yes - - - - - - - - - - - - - 10 Operator has-apprgpriate_bondinforee________________________ ______._Yes.-.,_.. ...---.-_-_---._. 11 Permit can be issued without conservation order Yes Appr Date 12 Permit-can be issued without administrativ_e_appr_oval - _ _ - . _ _ - - _ _ -Yes - - -- - - - - - - - - - - - - SFD 4/4/2006 13 Can permit be approved before 15-day wait Yes 14 Well located within area and strata authorized by_ Injection Order # (putlQ# in_comments)_(F4r- Yes _ _ _ _ _ - - Area Injection Order No, 2B - - - , - - - 15 All wells within 1l4.mile area of review identified (For service well only)- - - - - - - - - - - - - - -Yes _ _ ... - - KRIJ 1 J-154.and laterals (Open), KRU 1J-159 and laterals (Opena, W Sak 5 (P&A'd). KRU_ 1J-154L2_closest at 530 16 Pre-produced injector; duration_ofore-production Less than_ 3 months-(For_service well only) _ -Yes _ - _ - - _ - 180-day flowback-on-gas-lift planned _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ AC_M_P_FindingofCOnsistency-hasbeenissued_forthisproject---_-_--___ ______-_ NA_______ ______________________ ---------------------------------------------- Engineering 18 Conductorstring_provided________________________________ _________ NA__-__ Con_ductorinstalled_in1J-184_(206.044.___________-____--______--__-_- - 19 Surface casing_protectsallknown_USDWS_-___-__-__..._ ..... ......... NA_--_--__ Allaquifersexempted,40CFR_147.102_(b)(3).___________________ ____-______ ____ 20 CMT-vol.adequate_tocirculate on conducior_&surf_csg__ ____________ _________ NA__-_---_ Surfacecasinginstalledin1J-184.,_--_--___---.---._____-------------__- 21 CMT-vol.adequate_totie-in long stringtasurfcsg______ ___-__----- ---------NA_--_--__ Intermediate-casing installed in-1J~184.___-_:-_-----_-_________-_________-____--- 22 CMT_will cover all knownproductiye horizons- - _ _ - _ _ - . - - - Na_ Slotted liner completion planned, ----------------------------------- 23 Casing desyns adequate for C, T, B &permafrost . . . . . . . . .. . ...... . . .. . . .. . . NA_ _ - _ _ _ - _ Motherbore tubulars met design specs._ NA for slotted liner._ - 24 Adequate tankage_or reserve pit - - - - - - - - - - - - - - - - - - - - - - - - - Yes Rig is_equipped with steel-pits.-No reserve_pitplanned, All waste to_approved disposal-wells._ - _ - - - - - - 25 Ifa_re-dill,has-a10-403 for abandonment been approved_____________ _________ NA_-_____- ____-_---__-__--_-------_______--_---__-______-------.__---_-.---- 26 Adequate wellbore_ separationproposed _ _ _ _ _ _ _ _ _ _ _ _ _____ _ __ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ _ _ _ _ _ _ Proximity analysis performed. Traveling cylinder path calculated, Nearest well is B_lateral, -75' deeper, - - - _ _ - 27 Ifdiverterrequired,doesitmeetregulations______________________ ___ _____NA_--___- BOPstack_willal[eady_beinplace,--___--_--_-.-_-.___-___-__.-_.----__-_--.--.- Appr Date 28 Drillingfluid-program schematic-& equip listadequate_ _ - - - Yes .. - . - Maximium expected formation pressure-8.6 EMW, Planned-MW 9,0 ppg-- - - - - - - - - - - - - - - - - - - - - - - - TEM 4!6/2006 29 BOPES, do they meet regulation - - - - - - - - - - - - - - - - - - - Yes - - - - - - ~j(;,~au A `" ~ 30 _B_OPE_press rating approp[iate; test to-(put psig incgmments)_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ _ _ _ _ _ _ MASP calculated at 11.49psi, 3K stack arrangement and test pressure-planned. - _ _ - _ _ _ .. _ _ _ _ , _ _ _ ('~~i - ~ 31 Choke_manifold complies wIAPI_ RP-53 (May 84)_ . - _ _ - -Yes - - - - - - - - - - - - - - - - - - _ _ - - - _ - 32 Work will occur without operation shutdown______________________ _________Yes_-__--_ _.-_-.-__-__--__--_-.-__-_- 33 Is presence-of H2S gas_ probable _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ - _ - _ _ _ _ _ - - _ - _ . - - No_ _ - _ _ - - _ H2S has notbeen reported in W$, Ry_is equipped-with sensors and alarms, - _ - - _ - . - _ - - _ .. - - - - .. . 34 Mechanical condition of wells within AQR verged (For_s_ervice well only) - - - - - - - - - - - - - -Yes _ _ _ _ - - _ W$ 5-is only penetration in AOR-and P&A is-satisfactory. -other wells_are in zone. Geology 35 Permit_canbeissuedw/ohydrogen-sulfidemeasures---------------- ---------Yes-__--_ -._-_-__-_---_-__-_-_--_______________________-___-____________,--- 36 Data_presented on potential overpressure zones - - - - - - - - - - - - - - - - Yes Expected r_eservoirpressure is 8,6-ppg EMW; will be drilled with 9.0 ppg mud. - Appr Date 37 Seismic analysis of shallowgas_zones_________________________ _________NA_____--_ _._ SFD 4/4!2006 38 Seabed condition survey_(if off_-shore) . - - NA----- - - - - - - 39 Contact namelpho_neforweekly-progress reports [exploratory only) _ _ - - _ _ - _ - - tJA- Geologic Commissioner: Engineering Public Date: Commissioner: Date Com ~ n r West Sak "D" sand in ector. Date 1 • 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 effort has been made to chronologically organize this category of information. ~~ -o ys ~ X39 ~ • Sperry-Sun Drilling Services LIS Scan Utility $Revision: 3 $ LisLib $Revision: 4 $ Thu Jun 29 10:03:11 2006 Reel Header Service name ......... ....LISTPE Date ................. ....06/06/29 Origin ............... ....STS Reel Name ............ ....UNKNOWN Continuation Number.. ....01 Previous Reel Name... ....UNKNOWN Comments ............. ....STS LIS Writing Library Tape Header Service name ......... ....LISTPE Date ................. ....06/06/29 Origin ............... ....STS Tape Name ............ ....UNKNOWN Continuation Number.. ....01 Previous Tape Name... ....UNKNOWN Comments ............. ....STS LIS Writing Library • Scientific Technical Services Scientific Technical Services Physical EOF Comment Record TAPE HEADER West Sak MWD/MAD LOGS WELL NAME: 1J-184 L1 API NUMBER: 500292330560 OPERATOR: ConocoPhillips Alaska, Inc. LOGGING COMPANY: Sperry Drilling Services TAPE CREATION DATE: 29-JUN-06 JOB DATA MWD RUN 3 MWD RUN 5 MWD RUN 6 JOB NUMBER: W-0004348857 W-0004348857 W-0004348857 LOGGING ENGINEER: P. ORTH T. GALVIN T. GALVIN OPERATOR WITNESS: M. THORNTON D. GLADDEN D. GLADDEN SURFACE LOCATION SECTION: 35 TOWNSHIP: 11N RANGE: l0E FNL: FSL: 1530 FEL: 2424 FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: 109.00 GROUND LEVEL: 81.00 WELL CASING RECORD OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 1ST STRING 12.250 13.375 3977.0 2ND STRING 8.500 9.625 8825.0 3RD STRING PRODUCTION STRING REMARKS: 1. ALL DEPTHS ARE MEASURED DEPTHS UNLESS OTHERWISE NOTED. THESE DEPTHS ARE BIT DEPTHS. 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTHS (TVD). 3. THIS WELLBORE WAS EFFECTED BY MEANS OF A WHIPSTOCK, • THE TOP OF WHICH WAS POSITIONED AT 8825'MD/3350'TVD WITHIN THE RUN 3 INTERVAL OF THE 1J-184 WELLBORE. THE WHIPSTOCK WAS POSITIONED, THE WINDOW MILLED, AND 39' OF NEW HOLE WERE DRILLED DURING MWD RUN 5. ONLY SROP DATA ARE PRESENTED FOR RUN 5. MWD DATA OVER THE RUN 7 INTERVAL WERE ACQUIRED WHILE RIH FOR RUN 6. 4. MWD RUNS 1 & 2 WERE DIRECTIONAL ONLY - NO DATA ARE PRESENTED. 5. MWD RUNS 3,6 COMPRISED DIRECTIONAL, DUAL GAMMA RAY (DGR) UTILIZING GEIGER- MUELLER TUBE DETECTORS, ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4), GEOPILOT ROTARY STEERABLE BHA (GP) WITH AT-BIT GAMMA (ABG), AND PRESSURE WHILE DRILLING (PWD). 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 1-3,5,6 REPRESENT WELL 1J-184 L1 WITH API#: 50-029-23305-60. THIS WELL REACHED A TOTAL DEPTH (TD) OF 16692'MD/3358'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). File Header Service name .............STSLIB.001 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/06/29 Maximum Physical Record..65535 File Type ................LO Previous File Name.......STSLIB.000 Comment Record FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged, DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE START DEPTH STOP DEPTH GR 3953.0 16654.5 FET 3960.0 16647.0 RPD 3960.0 16647.0 RPS 3960.0 16647.0 RPM 3960.0 16647.0 RPX 3960.0 16647.0 ROP 3988.5 16692.0 BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH • MERGED DATA SOURCE PBU TOOL CODE BIT RUN NO MWD 3 MWD 5 MWD 6 REMARKS: MERGED MAIN PASS. MERGE TOP MERGE BASE 3953.0 8825.0 8825.5 8881.5 8881.5 16692.0 Data Format Specification Record Data Record Type ..................0 Data Specification Block Type.....0 Logging Direction .................DOwn Optical log depth units...........Feet Data Reference Point ..............Undefined Frame Spacing .....................60 .lIN Max frames per record .............Undefined Absent value ......................-999 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel • DEPT FT 4 1 68 0 1 RPD MWD OHMM 4 1 68 4 2 RPM MWD OHMM 4 1 68 8 3 RPS MWD OHMM 4 1 68 12 4 RPX MWD OHMM 4 1 68 16 5 FET MWD HOUR 4 1 68 20 6 GR MWD API 4 1 68 24 7 ROP MWD FT/H 4 1 68 28 8 First Last Name Servi ce Unit Min Max Mean Nsam Reading Reading DEPT FT 3953 16692 10322.5 25479 3953 16692 RPD MWD OHMM 4.07 2000 35.6897 25375 3960 16647 RPM MWD OHMM 0.33 1089.68 31.7845 25375 3960 16647 RPS MWD OHMM 2.15 1848.07 33.4144 25375 3960 16647 RPX MWD OHMM 3.28 2000 35.5445 25375 3960 16647 FET MWD HOUR 0.1 67.01 0.672534 25375 3960 16647 GR MWD API 23.77 131.47 76.2736 25404 3953 16654.5 ROP MWD FT/H 0.07 708.88 238.684 25408 3988.5 16692 First Reading For Entire File..........3953 Last Reading For Entire File...........16692 File Trailer Service name .............STSLIB.001 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/06/29 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.002 Physical EOF File Header Service name .............STSLIB.002 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/06/29 Maximum Physical Record..65535 File Type ................LO Previous File Name.......STSLIB.001 Comment Record FILE HEADER FILE NUMBER: 2 z • • 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 3953.0 8825.0 FET 3960.0 8825.0 RPX 3960.0 8825.0 RPS 3960.0 8825.0 RPM 3960.0 8825.0 RPD 3960.0 8825.0 ROP 3988.5 8825.0 LOG HEADER DATA DATE LOGGED: 02-MAY-06 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 66.37 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT) 8825.0 TOP LOG INTERVAL (FT) 3988.0 BOTTOM LOG INTERVAL (FT) 8825.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 75.0 MAXIMUM ANGLE: 81.8 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 76571 EWR4 ELECTROMAG. RESIS. 4 78633 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) 12.250 DRILLER'S CASING DEPTH (FT) 3977.0 BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: 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 Other 9.10 58.0 9.2 250 4.2 2.600 68.0 1.790 102.0 3.600 68.0 2.000 68.0 • • Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 RPD MWD030 OHMM 4 1 68 4 2 RPM MWD030 OHMM 4 1 68 8 3 RPS MWD030 OHMM 4 1 68 12 4 RPX MWD030 OHMM 4 1 68 16 5 FET MWD030 HOUR 4 1 68 20 6 GR MWD030 API 4 1 68 24 7 ROP MWD030 FT/H 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 3953 8825 6389 9745 3953 8825 RPD MWD030 OHMM 4.07 2000 18.3364 9731 3960 8825 RPM MWD030 OHMM 0.33 1089.68 15.0447 9731 3960 8825 RPS MWD030 OHMM 2.15 948.71 14.3977 9731 3960 8825 RPX MWD030 OHMM 3.28 1670.76 13.3651 9731 3960 8825 FET MWD030 HOUR 0.1 67.01 0.820947 9731 3960 8825 GR MWD030 API 23.77 127.24 68.5224 9745 3953 8825 ROP MWD030 FT/H 3.4 708.88 264.975 9674 3988.5 8825 First Reading For Entire File..........3953 Last Reading For Entire File...........8825 File Trailer Service name ........... ..STSLIB.002 Service Sub Level Name. .. Version Number......... ..1.0.0 Date of Generation..... ..06/06/29 Maximum Physical Record ..65535 File Type .............. ..LO Next File Name......... ..STSLIB.003 Physical EOF File Header Service name .............STSLIB.003 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/06/29 Maximum Physical Record..65535 File Type ................LO Previous File Name.......STSLIB.002 Comment Record FILE HEADER FILE NUMBER: 3 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 5 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH ROP 8825.5 8881.5 LOG HEADER DATA DATE LOGGED: 14-MAY-06 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 66.37 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT) 8881.0 TOP LOG INTERVAL (FT) 8825.0 BOTTOM LOG INTERVAL (FT) 8881.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: .0 MAXIMUM ANGLE: .0 • TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: TOOL NUMBER 8.500 8825.0 Mineral Oil Base 8.80 88.0 .0 28000 2.6 .000 .0 .000 99.0 .000 .0 .000 .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 ROP MWDO50 FT/H 4 1 68 4 2 First Name Service Unit Min Max Mean Nsam Reading DEPT FT 8825.5 8881.5 8853.5 113 8825.5 ROP MWDO50 FT/H 0.07 65.32 20.8003 113 8825.5 First Reading For Entire File..........8825.5 Last Reading For Entire File...........8881.5 File Trailer Service name .............STSLIB.003 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/06/29 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.004 Last Reading 8881.5 8881.5 Physical EOF File Header Service name .............STSLIB.004 • • Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/06/29 Maximum Physical Record..65535 File Type ................LO Previous File Name.......STSLIB.003 Comment Record FILE HEADER FILE NUMBER: 4 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 6 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH RPX 8825.5 16647.0 RPD 8825.5 16647.0 GR 8825.5 16654.5 RPM 8825.5 16647.0 FET 8825.5 16647.0 RPS 8825.5 16647.0 ROP 8882.0 16692.0 LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: 18-MAY-06 Insite 66.37 Memory 16692.0 8881.0 16692.0 80.8 94.2 TOOL NUMBER 216265 10505932 8.500 8825.0 Mineral Oil Base 8.80 69.0 .0 16000 3.2 .000 .0 .000 129.0 .000 .0 .000 .0 Data Format Specification Record Data Record Type ..................0 • Data Specification Block Type.....0 Logging Direction ........ .........Down Optical log depth units.. .........Feet Data Reference Point ..... .........Undefined Frame Spacing ............ .........60 .lIN Max frames per record .... .........Undefined Absent value ............. .........-999 Depth Units .............. .......... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel • DEPT FT 4 1 68 0 1 RPD 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 8825.5 16692 12758.8 15734 8825.5 16692 RPD MWD060 OHMM 7.6 147.81 46.4839 15644 8825.5 16647 RPM MWD060 OHMM 7.31 494.43 42.1972 15644 8825.5 16647 RPS MWD060 OHMM 7.1 1848.07 45.2434 15644 8825.5 16647 RPX MWD060 OHMM 6.87 2000 49.3407 15644 8825.5 16647 FET MWD060 HOUR 0.13 18.76 0.580216 15644 8825.5 16647 GR MWD060 API 51.65 131.47 81.0974 15659 8825.5 16654.5 ROP MWD060 FT/H 0.69 518.96 223.978 15621 8882 16692 First Reading For Entire File..........8825.5 Last Reading For Entire File...........16692 File Trailer Service name .............STSLIB.004 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/06/29 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.005 Physical EOF Tape Trailer Service name .............LISTPE Date .....................06/06/29 Origin ...................STS Tape Name ................UNKNOWN Continuation Number......01 Next Tape Name...........UNKNOWN Comments .................STS LIS Writing Library. Scientific Technical Services Reel Trailer Service name .............LISTPE Date .....................06/06/29 Origin ...................STS Reel Name ................UNKNOWN Continuation Number......01 Next Reel Name...........UNKNOWN Comments .................STS LIS Writing Library. Scientific Technical Services Physical EOF Physical EOF • • End Of LIS File