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Home My WebLink About199-005MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Tuesday, June 14, 2022 SUBJECT:Mechanical Integrity Tests TO: FROM:Matt Herrera P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL ConocoPhillips Alaska, Inc. 1C-18 KUPARUK RIV UNIT 1C-18 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 06/14/2022 1C-18 50-029-22939-00-00 199-005-0 W SPT 6158 1990050 1540 2331 2332 2330 2326 385 485 485 480 4YRTST P Matt Herrera 5/17/2022 MIT-IA Performed to 1800 PSI Per Operations 30 MinPretestInitial15 Min Well Name Type Test Notes: Interval P/F Well Permit Number: Type Inj TVD PTD Test psi API Well Number Inspector Name:KUPARUK RIV UNIT 1C-18 Inspection Date: Tubing OA Packer Depth 930 1810 1765 1755IA 45 Min 60 Min Rel Insp Num: Insp Num:mitMFH220518152530 BBL Pumped:0.7 BBL Returned:0.9 Tuesday, June 14, 2022 Page 1 of 1 9 9 9 9 9 9 9 9 9 9 James B. Regg Digitally signed by James B. Regg Date: 2022.06.14 14:08:19 -08'00' • MEMORANDA State of Alaska Alaska Oil and Gas Conservation Commission DATE: Wednesday,May 16,2018 TO: Jim Regg 5 2AJlea P.I.Supervisor le � { SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA,INC. 1C-18 FROM: Austin McLeod KUPARUK RIV UNIT 1C-18 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry NON-CONFIDENTIAL Comm Well Name KUPARUK RIV UNIT 1C-18 API Well Number 50-029-22939-00-00 Inspector Name: Austin McLeod Permit Number: 199-005-0 Inspection Date: 5/13/2018 Insp Num: mitSAM180514080658 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 1C-18 'Type Inj W 'TVD 6158 • Tubing 2450 - 2450 - 2448 - 2448 PTD � 1990050 " Type Test PPT Test psi 1540 _ IA 885 1810 - 1765 1755- BBL Pumped: 0.9 - BBL Returned: 0.9 - OA 410 - 505 - 505 505 - Interval 4YRTST P/F P ✓ Notes: MIT-IA SCANNED JUN 0 i 2318 Wednesday,May 16,2018 Page 1 of 1 • • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Wednesday,November 18,2015 TO: P.1.Supervisor �c Jim Regg till 7'C SUBJECT: Mechanical Integrity Tests P CONOCOPHILLIPS ALASKA INC 1C-18 FROM: Lou Grimaldi KUPARUK RIV UNIT 1C-1s Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry NON-CONFIDENTIAL Comm Well Name KUPARUK RIV UNIT 1C-18 API Well Number 50-029-22939-00-00 Inspector Name: Lou Grimaldi Permit Number: 199-005-0 Inspection Date: 10/23/2015 Insp Num: mitLG151025113843 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well Ic-18 1Type Inl W jTVD 6158 Tubing 1470 - 1475 - 1475 - 1475 . PTD 1990050 - JType Test SPT Test psi 1540 - IA 750 2520 j 2450 2440 Interval INITAL P/F P OA 370 610 - 600 - 580 - Notes: 1.6 bbl's diesel pumped, 1.6 bbl's returned.Good test procedure followed.Good initial test of this recently worked over well.All required paperwork supplied prior to test. 444aCteCA ' v 021 t c /J7 \i— 1S0 pre-ssck- s Pie+- 13SEPi5ns Wednesday,November 18,2015 Page 1 of I M. - . S iv) ..... In , ,...) , C-) ,- in . _ dwaiiamogo 1 -J I --.-4--) Co 0 0 0 0 0 --) LO ..4 CJ ki) li I I, i i gi II II il . I 1 I a .I• li dill 1. 1:3 I. . .. -•-..."-' .4- ts(1 C•t-- . • • • • • e,•") _ ...— • _ "-.5. CL-. -- • ' • _ • . • ... ..._._____ _______. L _ N— I • ,__ -Z.5 c.) _ . . • . V • . •• *".................. 0 _ 6 . . • • . • . • • • . 0 . . • • . • • . . _ . . • • tc) . . . • . .. T- - • • ' cil . . . . • - . . . . — . • -- (..0 . • • . . • . _ 6 _ . • . . • . • • C\I I • • . . - - • ' . . ' . . • -------- Ln • . - . . • _ \-- .%— . • . . . . — • • - — a) 0 • • - . . . . U) . _ A VI" ' • • . • • . • . . . • . . . : ..- 4.4 ' • . . (0 0 . . . . . . CL . - . • • • • • • . . . • . . . • .... = . . . • ‹F :7,- - . • . • . • - • - • • i _ , . . . . . • • _ • • • • • • . • . • • • • • • • . . . . : • • - • , • • • • ! = • - • . 1 - • • ' I - . . • • - . . • . • 1 ' . • • • , 6) • : 1 ' . 1- a. a. • • • - . < I-- < • • • • • • • 1- in • • • • i c.) • • • - , _ • . • . : • . . . . ' Lo • • • • ) • • • • i LU .1 i P I' II I ' i ' I 'I 'I II i r r I' I I I • : r 0 0 0 A 0 I 1-- < 0 0 0 0 0 (NI U LI_ 0 C3 LO CI LI) CNI .--- AISd III • omens KUP INJ 1C-18 Catioc i hillips : e • : - 4 ,� Alaska,Inc, bonbon T- Welton.scan d(•) MV I T Act ten QIIB) yhl, 500292293900 KUPAR(M RIVER UNIT INJ 47.:1 6700.52 8,095.0 ... Comment 1428(ppm) Dae Mdeatbn End Mb NIS-0N((t) Rig Rebase Mb 1C-1e,1Ma20153:50'.30 PM SSSV'NIPLE Last WO: 9/14/2015 46.51 2121/1999 Vailmi echemal.(a.-• notelbn Depth(MOB) End Dab Amotwlon .. Entl Dib Last Tag CTMD 7.855.0 6/4/2014 Rev Reason:WORKOVER,PULL PLUG& 10//2015 _...._..........-...._.................... ......_....._....._.. { _.... SAND PLUG 17 i 7 ; .9, -Ohm •.So ID op ,.1 S4 Depth(0012) 84 0eptn(TVD.. T Top Thread CONDUCTOR 1. 15062 42.0 112.0 112.0 62,58 H-40 WELDED Casing Deee.ipti0n 00)4.) IDP..) Top(91(8) -t Depth(MCS) Depth(180)-..walan(I...Grade Tap Thread SURFACE 95/8 8.83 40.7 4,8186 4,342.' 40.00 L.80 BTC 17'7eg• OtIPUOn • 0D(b) ID(1a) Top(1180) See Depth 191(6) Set Mplh(TVD)...1)WL.n(1..Grade Top Thread PRODUCTION 7 6.276 45.5 7,578.0 6,307 5 26 00 L-80 BTC-MOD I t� camp Deet l�lpn OD 1(n) ID(+n) Tw IMO) Se(Depth(688) s4 Depth(WW). Maw.(I-.Dodo Top Thread 11 LINER 41 3.968 7 359 6,096.0 6,878 8 12 60 L 60 NSCT 11.1' � �i� Y'�_ .�'77:3538:::1:6:4 ';-::5441:::: .JM.: 4 }fir,. •' EJ„c�ll�A *$.- .WZt'4''� ..0='`�"6...;'.r 5..>,'; ,,. Nominal D Top(stip Top(1VD)(1266) Top 1.10 n.nl Des Com On) iiid 73596 6154.1 4503 •ACKER BAKERDIPLINERPACKERBTIEBACKSLEEVE 5000 li 7381 7 6,189.6 45.11 R BAKER NMC LPIER HANGER 5000 as TBhhg Desnption �hi-"g311-,11:2.992,7 g Ma.,. ap Bet D.pe(fl.,8tl Depth(TBUI)... Tap Co.neatbn TUBING-W02015 31-• n2.992 38- 7,365. 8.157.8 9.30 L-80 EUEM f aannew"w• .a "0' M.�.•t*.Ru Yy' 4 .a ..".:•, '' +>x!u...-L,Ate :..„:7,3,135( ; .^NQs: .:. , , c:Msti; S. v I1n fin) to TW 0688) Top(080)MIS Top Incl p Ron Da. CO.. (in) 38.3 38.3 0.1 I HANGER FMC GEN 5 TUBING HANGER 4 500 7,:,.6 6,1562 45.04 LOCATOR :Tr"R LOCATOR 193-47 N0-GO 3.850 CONDUCTOR:420.112.0 7,363.7 6,156.9 45.05 SEAL ASSY BAKER 182-47 SEAL ASSEMBLY W/PAJLE SHOE 3.850 sent Dene Top(080) Btm(TVD) (.hoIN Top(91(6) Ben(NCB) 111x8) (088) l na Dab 0 T • cam 7,713.0 7,753.0 6,401.8 6,430.0 C-.4 1C-18 '002 6.0 '-e 2 7/8'USD PJ Chgs,60 de9 Ph 7,7530 7,763.0 6,4300 8454.1 C 4,C 3,1C- 4/2/1999 4.0 PERF 2 7(8')SC/DP 180 deg 18 ph M-80 deg from law side Mandrel Inserts SURFACE,40.TABS( 06 8� mi 1st CO Top(TVD) Salve latch Port OW TRO Ren N p(M) per ) MVO Model OD(b) 3.n, Type 59p. (In) (pat) Rue Dab Com 1' Ta7.3071 6,11, • . MMG 11/2 GAS LIFT Dh1Y RKP 0.000 0.0 10/9/2015 DCR1 ::•;::.77.1..,=11,..;:::',77.4.''' r' l•'.:;"''''.' i'-'.":"'"-..' ... . a.',"•••-"-":•""`;--.1..-."i fFt -_ 4EnDale :*, zAo.nU bll GAS LIFT.7,407.1 NOTE.WELL CONVERTED FROM PRODUCER TO INJECTOR r 1/1112011 NOTE:View Schematic w/JVaska Schemwtic9.0 I F' Ili10I I 7100,11110N:485-7,874.0-' ii APERF:7.7130-7.7530 y PERE:7.757.0.0.783 0 LINER,7.159.88.095.0 e STATE OF ALASKA ALA OIL AND GAS CONSERVATION COIVIIISION REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon r Rug Perforations r Fracture Stimulate r Pull Tubing p Operations Shutdown r Performed: Suspend r Perforate r Other Stimulate r Alter Casing r Change Approved Program r Rug for Redrill r Perforate New Pool r Repair Well 17 Re-enter Susp Well r Other: r- 2. 2.Operator Name: 4.Well Class Before Work: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Development r Exploratory r 199-005 3.Address: 6.API Number: P. O. Box 100360,Anchorage,Alaska 99510 Stratigraphic Service 50-029-22939-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL 25649 KRU 1C-18 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): none Kuparuk River Field/Kuparuk River Oil Pool 11.Present Well Condition Summary: Total Depth measured 8095 feet Plugs(measured) 7410 true vertical 6677 feet Junk(measured) none Effective Depth measured 8030' feet Packer(measured) 7364 true vertical 6629 feet (true vertical) 6157 Casing Length Size MD TVD Burst Collapse CONDUCTOR 70 16 112 112 SURFACE 4776 9.625 4817 4343 PRODUCTION 7533 7 7578 6308 LINER 735 4.5 8095 6677 RECEIVED Perforation depth: Measured depth: 7713-7783 0 C T 13 2015 True Vertical Depth: 6402-6451 a�pqAOGCC J 2 4 2.0`1 Tubing(size,grade,MD,and TVD) 3.5, L-80, 7363 MD, 6157 TVD Packers&SSSV(type,MD,and TVD) PACKER-BAKER HMC PACKER @ 7364 MD and 6157 TVD NO SSSV 12.Stimulation or cement squeeze summary: Intervals treated(measured): no stimulation or cement squeeze during this operation 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 shut-in Subsequent to operation shut-in 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations I✓ Exploratory r Development r Service 1 Stratigraphic r Copies of Logs and Surveys Run r 16.Well Status after work: Oil r Gas r WDSPL r Printed and Bectronic Fracture Stimulation Data r GSTOR r WINJ r WAG GINJ r SUSP r SPLUG r 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: 315-422 Contact Diana Guzman 265-6318 Email Diana.Guzmanconocophillips.com Printed Name Dia Guzman i Title Sr. Wells Engineer /�-7 Signature ';, n�' Phone:265-6318 Date 10 ! C� �1M tk�,` //LL i/7-i,,. io 12411 r Form 10 404 Revised 5/2015 " i 04,41 3() RBDMS UL I 1 4 20 5 Submit Original Only • • Canaco hillips Time Log & Summary Wel/view Web Reporting Report Well Name: 1C-18 Rig Name: NABORS 7ES Job Type: RECOMPLETION Rig Accept: 9/15/2015 12:00:00 PM Rig Release: 9/18/2015 8:00:00 AM Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment p9/14/2015 24 hr Summary Moveing Rig to 1C-18.Wait on Roads&Pads to remove wet grave from pad and back fill with dry gravel. 12:00 19:30 7.50 MIRU MOVE MOB P Move rig from 1C-01 to 1C-18. Stage pit module and Spot rig over 1C-18. 19:30 00:00 4.50 MIRU MOVE WAIT T Waiting on Roads&Pads to move wet gravel and back fill with dry gravel. Rig is unable to move over the well becasue of the unstable gravel condition of 1C pad. 09/15/2015 Repair pad and move over 1C-18. R/U and kill well. N/D Tree and R/U BOPE. 00:00 06:00 6.00 MIRU MOVE WAIT T Continue to repair pad and set mats in front of the well. 06:00 08:00 2.00 MIRU MOVE MOB P Move the Rig over 1C-18. 08:00 12:00 4.00 MIRU MOVE RURD P R/U, Berm pits, fuel tanks, and cellar. Ready Rig to kill well. Rig Accepted 9/15/2015 12:00 HRS. 12:00 14:00 2.00 MIRU WELCTL RURD P Prep cellar and Tree for well kill,take on seawater in the pits. Rig Accepted 9/15/2015 12:00 pm. 14:00 15:00 1.00 MIRU WELCTL MPSP P P/U lubricator and pull BPV. 15:00 16:00 1.00 MIRU WELCTL RURD P R/U lines to kill tank and blow down. Prep cellar for well kill. 16:00 18:00 2.00 MIRU WELCTL OWFF P Bleed pressure from IA to flow tank, 180 psi to 0 psi. Shut in IA and open Tubing, 0 psi. 18:00 20:00 2.00 MIRU WELCTL KLWL P Reverse circulate 290 bbls of seawater, 8.6 ppg, 1 bpm =80 psi, 2 bpm= 150 psi. FCP 2 bpm=220 psi. 20:00 20:30 0.50 MIRU WHDBO MPSP P Set BPV. 20:30 23:00 2.50 MIRU WHDBO NUND P N/D Tree, pulled free at 11K. 23:00 00:00 1.00 MIRU WHDBO NUND P N/U BOPE. 09/16/2015 Test BOPE. Pull Hanger free to the rig floor. Pull 4 1/2"Tubing Completion, (Seal assembly free of corrosion). R/U to run 3 1/2"Tubing Completin. 00:00 03:30 3.50 MIRU WHDBO NUND P N/U BOPE Page 1 of 3 Time Logs • • Date From To Dur S.Depth E. Depth Phase Code Subcode T Comment 03:30 09:00 5.50 MIRU WHDBO BOPE P Test BOPE: Test choke manifold to 250/3000 psi, Super choke and Manual choke to 250/1500 psi. Test Annular preventer to 250/2500 psi. Blind rams and Top and Bottom VBR's to 250/3000psi. Perform AOGCC and CPAI Koomey test, all good. 09:00 09:30 0.50 MIRU WHDBO RURD P R/D testing equipment. 09:30 10:00 0.50 MIRU RPCOM MPSP P Pull Blanking plug and BPV. 10:00 11:00 1.00 COMPZ RPCOM PULL P Pull Hanger free at 120K PUW. pull Hanger to floor. 11:00 12:00 1.00 COMPZ RPCOM PULD P L/D the Landing joint and Tubing hanger. 12:00 13:00 1.00 COMPZ RPCOM CIRC P Circulate 8.6 Seawater, 180 bbls at 5 bpm, 375 psi. 13:00 21:30 8.50 COMPZ RPCOM PULL P Pull 4 1/2"Tubing Completion f/ 7,578' t/Rig floor. Some corrosion on theTubing pins. No corrosion on Seal Assembly, looked in very good condition, Minor ware on the rubber"0"ring gaskets. 21:30 22:00 0.50 COMPZ RPCOM SVRG P Service TD. 22:00 00:00 2.00 COMPZ RPCOM RURD P R/U to run 3 1/2"Tubing Completion. 09/17/2015 RIH with 3 1/2"EUE 9.3#L-80 Mod Tubing to 7,365'. Space out: No Go at 7,362', Seal Assembly Mule Shoe at 7,363'. Pump 270 bbls Corrosion Inhibitor. Land Hanger and RIID's and test Tubing to 3500 psi and Casing to 3000 psi. Shear SOV at 2800 psi and pump down Tubing. BWM on BOP Stack. N/D BOP Stack and N/U Tree. 00:00 04:45 4.75 0 6,931 COMPZ RPCOM PUTB P RIH with 3 1/2"Tubing Completion : 3 1/2" EUE 9.3#L-80 MOD to 6931', PUW=80K, SOW=72K. 04:45 05:00 0.25 6,931 6,931 COMPZ RPCOM SFTY P Well Control Drill:Well Secured 47 secs, CRT 78 secs. 05:00 06:00 1.00 6,931 7,365 COMPZ RPCOM PUTB P RIH with 3 1/2"Tubing Completion. 06:00 08:00 2.00 7,365 7,365 COMPZ RPCOM HOSO P Slack off to No Go and L/D 3 joints of Tubing and P/U 3 puu joints. Space out: No Go at 7362'and Seal Assembly Mule Shoe at 7363'. M/U Landing joint and Hanger. 08:00 10:00 2.00 7,365 7,365 COMPZ RPCOM CRIH P Circulate 270 bbls of CIH/Seawater, 3 bpm, 200 psi. 10:00 10:30 0.50 7,365 7,365 COMPZ RPCOM THGR P Land Hanger, 74K SOW and RILD's. 10:30 12:30 2.00 7,365 COMPZ RPCOM PRTS P Pressure test TBG, 3500 psi for 10 minutes. Pressure test IA, 3000 psi for 30 minutes. Bleed off pressures and ramp up pressure to 2800 psi to Shear SOV. (All good) 12:30 13:00 0.50 7,365 7,365 COMPZ RPCOM OWFF P Monitor well for flow 30 minutes. (No flow) 13:00 21:00 8.00 7,365 7,365 COMPZ WHDBO SVRG P BWM on BOP Stack 21:00 00:00 3.00 7,365 7,365 COMPZ WHDBO NUND P N/U Tree. Page 2 of 3 Time Logs • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 09/18/2015 24 hr Summary N/D BOP Stack. N/U Tree, set BPV and test Tree 250/5000 psi,test was good. Freeze protect well,diesel equalized at 2000'. Rig released at 08:00 hrs. 00:00 02:30 2.50 7,365 7,365 COMPZ WHDBO NUND P N/D BOP Stack 02:30 04:30 2.00 7,365 COMPZ WHDBO NUND P N/U Tree. 04:30 05:00 0.50 7,365 7,365 COMPZ WHDBO MPSP P Set BPV and test Tree 250/5000 psi for 5 minutes. (Test Good.) 05:00 08:00 3.00 7,365 7,365 COMPZ WHDBO FRZP P Freeze protect well: Pump diesel to 2000'MD/TVD. Pumped 70 bbls of diesel down the IA taking returns up the Tubing. Placed Tubing and IA in communication allow diesel toe equalize. Job completed-Pulled existing 4 1/2"tubing and replaced with new 3 1/2"9.3#L-80 8rd EUE AB Mod tubing. Rig release 8:00 am 9/18/2015. Page 3 of 3 s ' KUP INJ 1C-18 t ConocoPhi lips l O,o Well Attributes Max Angle&MD .o' Wellbore API/UWI Wellbore Status 1 MD ftKB Alaska.Inc. .me rid(`) l 1 m(RKB) .- • GrnomPhllfips• 500292293900 KUPARUK RIVER UNIT INJ 47.80 6,700.52 8,095.0 •-° Comment H2S(ppm) Date Annotation End Date KB.Grd(ft) Rig Release Date 10-18,10/12/201510:27:49 AM SSSV:NIPPLE Last WO: 9/14/2015 46.51 2/21/1999 Vedical schematic(actual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date Last Tag:CTMD 7,855.0 6/4/2014 Rev Reason:WORKOVER,PULL PLUG& smsmith 10/9/2015 ... _._... SAND PLUG x111.11II=ik l �-0QI asmg tangs Casin OD 9 Description p (in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)...Wt/Len(I...Grade Top Thread CONDUCTOR 16 15.062 42.0 112.0 112.0 62.58 H-40 WELDED T Casing Description OD)in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(L..Grade Top Thread SURFACE 9 518 8.835 4B) (ftKB) 4,342.9 eO 00 L-80 BTC 1 • Cas ng Descnphon OD(In) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)...WtlLen(I...Grade Top Thread PRODUCTION 7 6.276 45.5 7,578.0 6,307.5 2600 L-80 BTC-MOD Casing Description OD(In) ID(in) Top(FMB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread .11 LINER 41/2 3.958 7,359.6 8,095.0 6,676.8 12.60 L-80 NSCT I 1 Liner Details Nominal ID 11 1 Top((KB) Top(TVD)(566) Top Incl(°) Item Des Com (in) 7,359.6 6,1541 45.03 PACKER BAKER ZXP LINER PACKER&TIEBACK SLEEVE 5.000 7,381 7 6,169.6 45.11 HANGER BAKER HMC LINER HANGER 5.000 ' ' ' „ ` m Tubing Strings Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft..Set Depth(TVD)(...Wt(Ibis) Grade Top Connection Il 1 TUBING-WO 2015 31/2 2.992 .3 7,365.0 .8 9.30 L-80 EUEM Completion Details Nominal ID (In) Top(ftKB) Top(TVD)(ftKB) Top Incl(°) Item Des36Cam 36.3 36.3 0.00 HANGER FMC GEN 5 TUBING HA6,157NGER 4.500 CONDUCTOR,42.0-112.0 7,362.6 6,156.2 45.04 LOCATOR BAKER LOCATOR 193-47 NO-GO 3.850 7,363.7 6,156.9 45.05 SEAL ASSY BAKER 192-47 SEAL ASSEMBLY W/MULE SHOE 3.850 I I Perforations&Slots Shot Dens Top(TVD) Btm(TVD) (shots/f Top(ftKB) Btm(ftKB) (ftKB) (ftKB) Zone Date t) Type Com 7,713.0 7,753.0 6,401.8 6,430.0 C-4,(C-18 3/3/2002 6.0 APERF 2 7/8"HSD PJ Chgs,60 deg ph 7,753.0 7,783.0 6,430.0 6,451.1 C 4,C 3,1C- 4/2/1999 4.0 IPERF 2 7/8"HC/DP 180 deg 18 ph e/-80 deg from low side Mandrel Inserts ,r a st SURFACE;40.7-4,816.6 ati on Top(TVD) Valve Latch Port Size TRO Run N Top(ftKB) (ftKB) Make Model OD(in) Sery Type Type (in) (psi) Run Date Com I 1 7,307.1 6,116.8 CAMCO MMG 11/2 GAS LIFT DMY RKP 0.000 0.0 10/9/2015 DCR) Notes:General&Safety End Date Annotation GAS SFT;7,307.1 5/3/2000 NOTE:WELL CONVERTED FROM PRODUCER TO INJECTOR 1/11/2011 NOTE:View Schematic w/Alaska Schematic9.0 ' II 1111 ,I I PRODUCTION;45.5.7,578.0- -.K A APERF;7,713.0-7,753.0 (PEEP;7,753.0-7,783.0 II LINER,7,359.6-6,095.0 I t • `' of T� Alaska Oil and Gas ,,w��177,cs, THE STATE E., �M of AT lAsKigi. Conservation Commission u tf itt 333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main. 907.279 1433 ALASf� Fax: 907.276 7542 SL��NE�} iy! �� cl L`1� www.aogcc.alaska.gov Diana Guzman �- Sr. Wells Engineer3._ a ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, Kuparuk River Oil Pool, KRU 1C-18 Sundry Number: 315-422 Dear Ms. Guzman: 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, /()4r.,,,c/-1 — Cathy . Foerster Chair DATED this W`day of July, 2015 Encl. STATE OF ALASKA ' A KA OIL AND GAS CONSERVATION COMM BION • APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 1.Type of Request: Abandon r Rug Perforations r- Fracture Stimulate r Pull Tubing ly• Operations Shutdown r Suspend r Perforate r Other Stimulate r ,Yw Alter Casing r Change Approved Program r Rug for Redrill r Perforate New Pool r Repair Well Re-enter Susp Well E Other: r 2.Operator Name. 4.Current Well Class: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Exploratory r Developrrent r 199-005 • 3.Address: 6 API Number: Stratigraphic r Service Pi , P.O. Box 100360,Anchorage,Alaska 99510 1 50-029-22939-00 - 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 r+, / KRU 1C-18 9.Property Designation(Lease Number): 10.Field/Pool(s). ADL 25649 ' Kuparuk River Field/Kuparuk River 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): 8095 - 6677 • 7410' none Casing Length Size MD TVD Burst Collapse CONDUCTOR 70 16 112' 112' SURFACE 4776 9.625 4817' 4343' RECEIVED PRODUCTION 7533 7 7578' 6308' �/ LINER 735 4.5 8095' 6677' JUL 10 2015 AouCC Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 7713-7783 • 6402-6451 4.5 L-80 7378 Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft) PACKER-BAKER ZXP LINER PACKER MD=7360 TVD=6154 • NIPPLE-CAMCO DB NIPPLE MD=503 TVD=503 • 12.Attachments: Description Surrrrrary of Proposal r 13 Well Class after proposed work: Detailed Operations Program r BOP Sketch r Exploratory r Stratigraphic r Development r Service I 14.Estimated Date for Commencing Operations: 15. Well Status after proposed work. 7/25/2015 OIL r WINJ r WDSPL r Suspended r 16.Verbal Approval: Date: GAS r WAG p. 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: Diana Guzman @ 265-6318 Email: Diana.Guzmanna conocophillips.com Printed Name Diana Guzman Title. Sr. Wells Engineer Signature 7.(71A.1�1-� Phone 265-6318 Date sU 1. y Zl.►s Commission Use Only Sundry Number Conditions of approval: Notify Commission so that a representative may witness 3 t sj— y2-2- Plug Integrity r BOP Test r7 Mechanical Integrity Test V Location Clearance r Other. C30P ii-f3 t fo ,3 00 ) p5; (MPSP i' 2427,p5; ) fav7n14arprc ✓emstr 74-z-5 1- 71--, Zsaops , . S/-4tC vvi t�-,r5Sccl �v► iT- /4 i--cvvirecl' c� f t:!�' ��a b, li\�cl i,iJ"�cti° r� Spacing Exception Required? Yes ❑ No 2( Subsequent Form Required: /b ^4Q O APPROVED BY Approved by: �Q)-C.�� COMMISSIONER THE COMMISSION Date:7—l(k/ VTL 'i' Il- Approved application is valid tor 12 months 3te date of approval. ont1 � submit Form and Form 10-403 Revised 5/2015 Attachments in qate0RIGINAL . 7,/ RBDMS)IJ RECEIVED ConocoPhillipsJUL 10 2015 Alaska }� P.O. BOX 100360 O G C C ANCHORAGE,ALASKA 99510-0360 July 7,2015 Commissioner 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 the Kuparuk Well 1C- 18(PTD# 199-005). Well 1C-18 was originally drilled and completed as a pre-produced injector in 1999. Before being shut-in on March 27, 2015 well 1C-18 water injection rates have been between 1000 and 8000 BWPD while the MI injection rates have been between 5000 and 17000 mscfd over the life of the well. A Leak Detection Log ran on April 10, 2015 identified a tubing leak at 7114 ft. Due to widespread under-deposit tubing corrosion indicated by a caliper log ran on April 11, 2015 the tubing patch option was ruled out. The objectives of the rig workover will be to pull and replace the current 4 '4" tubing with 3 '/2" in order to fix the existing tubing leak and prevent future tubing under-deposit corrosion. / If you have any questions or require any further information,please contact me at 907-265-6318. Sincerely, Diana Guzman Wells Engineer CPAI Drilling and Wells 1C-18 Rig Workover Pull and Replace 4 1/2" & Install 3 1/2" Completion (PTD #: 199-005) Current Status: This well is currently shut in and awaiting a rig workover. Scope of Work: • Pull 4 1/4"tubing and install new 3 '/2"completion. General Well info: Well Type: Injector MASP: 2427 psi using 0.1 psi/ft gradient(Most recent SBHP=3054 psi on 04/05/15) Reservoir Pressure/TVD: 3054 psi/6272' TVD(9.4 ppg)on 03/19/14 Wellhead type/pressure rating: FMC Gen 5/5M psi TH BOP configuration: Annular/Pipe Rams/Blind Rams/Flow Cross/Pipe Rams TIFL/MIT results: CMIT—T x IA passed April 10,2015 Earliest Estimated Start Date: July 25,2015 Production Engineer: David Haakinson/David Lagerlef Workover Engineer: Diana Guzman Work: 265-6318 E-mail: Diana.Guzman@conocophillips.com Pre-Rig Work 1. RU DSL: a. Pull 3.69"WRP at 7410' b. Set new 2.70"HEX Plug at 7410' (tbg will be downsize to 3 '/2") c. Perform PT and NFT on plug. Dump sand on top of plug. d. Open GLM#6 at 7280' for circ point. 2. Test packoffs and LDS. 3. Set BPV and bleed down OA prior rig arrival. Proposed Procedure: 1. MIRU 2. Pull BPV. Reverse circulate KWF. Obtain SITP& SICP, if still seeing pressure at surface, calculate new KWF and repeat circulation as necessary. Verify well is dead. 3. Set BPV&blanking plug or two-way check,PT to 1,000 psi from below if possible,ND tree,NU BOPE& test to 2S8ffpsi. 3t PC p 5 4. Pull blanking plug&BPV. 5. RU to pull tubing,MU landing joint,BOLDS's laying down tubing. 6. If seals are corroded upon inspection,MU and RIH with polish mill to clean sealbore. 7. RIH with new 3 '/2"tubing to just above the liner packer. 8. Spot a balance pill of corrosion inhibited brine in the tbg and IA. 9. Slowly cycle the charge pump and look for pressure increase as the seals engage. Shut down charge pump. Space out 1 ft from fully located. 10. Install space out pumps below the hanger,MU hanger.Land the hanger,RILDS. 11. PT the tubing for 10 min. Reduce the tubing pressure and PT the IA and chart for 30 min. Bleed the IA to zero,then the tubing. Ramp up the IA pressure quickly to shear the SOV. 12. Pull the landing joint, install BPV. PT BPV. 13. ND BOPE. 14. NU tree. Pull BPV&install tree test plug. Test tree. Pull tree test plug. 1C-18 Rig Workover Pull and Replace 4 '/2" & Install 3 '/2" Completion (PTD #: 199-005) 15. Freeze protect well w/diesel. 16. Install BPV. 17. RDMO. Post-Rig Work 1. Reset well house(s)and flowlines of adjacent wells. 2. Pull BPV. 3. RU Slickline: Clean sand from top of plug,pull HEX plug,pull SOV from GLM#1. Set up for injection. 4. Handover to Ops to put back on injection. �,, KUP INJ 1C-18 Conoco Phillips `$ a r Well Attributes Max Angle&MD TD Alaska,Inc '' Wellbore API/UWI Field Name Wellbore Status net(°) MD(ftKB) Act Btm(ftKB) r,.. dfi,ll,p. 500292293900 KUPARUK RIVER UNIT INJ 47.80 6,700.52 8,095.0 ... Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) -Rig Release Date 1C-18,4/13/201512:26:53 PM SSSV:NIPPLE Last WO: 46.51 2/21/1999 Vertical schematic(actual Annotation Depth(ftKB) End Date Annotation Last Mod By End Date Last Tag:CTMD 7,855.0 6/4/2014 Rev Reason:SET PLUG hipshkf 4/13/2015 HANGER,36.3 l, . Casing Strings Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)... Wt/Len(1...Grade Top Thread CONDUCTOR 16 15.062 42.0 112.0 112.0 62.58 H-40 WELDED • Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)... WtlLen(I...Grade Top Thread I; SURFACE 9 5/8 8.835 40.7 4,816.6 4,342.9 40.00 L-80 BTC L Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)...Wt/Len(I...Grade Top Thread PRODUCTION 7 6276 45.5 7,578.0 6,307.5 26.00 L-80 BTC-MOD Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)...Wt/Len(1...Grade Top Thread a au,LINER 41/2 3.958 7,359.6 8,095.0 6,676.8 1260L-80 NSCT Liner Details Nominal ID d Top(ftKB) Top(ND)(ftKB) Top Incl(°) Item Des Com (in) 7,359.6 6,154.1 45.03 PACKER BAKER ZXP LINER PACKER 8 TIEBACK SLEEVE 5.000 CONDUCTOR;420-1120-b 'M� 7,381.7 6,169.6 45.11 HANGER BAKER HMC LINER HANGER 5.000 Tubing Strings NIPPLE',503.0 ItTubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft..Set Depth(ND)(...Wt(Ib/rt) Grade Top Connection TUBING 1 41/21 3.9581 36.31 7377.61 6,166 12.601 L-80 I NSCT Completion Details Nominal ID Top(ftKB) Top(ND)(ftKB) Top Mel(') Item Des Com (in) 36.3 363 0.00 HANGER FMC GEN V TUBING HANGER 4.500 503.0 503.0 0.29 NIPPLE CAMCO DB NIPPLE 3.813 GAS LIFT,2,5002 7,325.9 6,130.2 44.92 NIPPLE CAMCO DB NIPPLE 3.750 7 7,364.3 6,157.3 45.05 LOCATOR BAKER LOCATOR 3.880 I 7,365.3 6,158.1 45.05 SEAL ASSY BAKER SEAL ASSEMBLY 3.880 Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) GAS LIFT:4,016.6 Top(TVD) Top Incl Top(ftKB) I (ftKB) I (°) I Des 1 Corn I Run Date 1 ID(in) 7,410 0 6,189.6 45.20 PLUG 3.69"WRP(OAL=3.85') 4/0/2015 0.000 ) Perforations&Slots Shot Dens Top(TVD) Btm(ND) (shoran ° Top(ftKB) Btm(ftKB) (ftKB) (ftKB) Zone Date t) Type Corn SURFACE.40.7.4,8166-A A 7,713.0 7,753.0 6,401.8 6,430.0 C-4,1C-18 3/3/2002 6.0 APERF 2 7/8"HSD PJ Chgs,60 deg ph 7,753.0 7,783.0 6,430.0 6,451.1 C 4,C 3,1C- 4/2/1999 4.0 IPERF 2 7/8"HC/DP 180 deg 18 ph v/-80 deg from low GAS LIFT,5,237.4 . , side Mandrel Inserts St ati on Top(ND) Valve Latch Port Size TRO Run N Top(ftKB) (ftKB) Make Model OD(in) Ser/ Type Type (in) (psi) Run Date Corn GAS LIFT;6061.3 1' 2,586.2 2,582.6 CAMCO KBG2L 1 GAS LIFT DMY INT 0.000 0.0 2/21/1999 S 2 4,016.6 3,783.1 CAMCO KBG2L 1 GAS LIFT DMY INT 0.000 0.0 2/21/1999 S 3 5,237.4 4,641.7 CAMCO KBG2L 1 GAS LIFT DMY INT 0.000 0.0 2/21/1999 S GAS LIFT;6,763.t 4 6,061.3 5,2453 CAMCO KBG2L 1 GAS LIFT DMY INT 0.000 0.0 2/21/1999 S 5 6,763.1 5,739.7 CAMCO KBG2L 1 GAS LIFT DMY INT 0.000 0.0 2/21/1999 S 6 7,279.6 6,097.3 CAMCO KBG2L 1 GAS LIFT DMY INT 0.000 0.0 2/21/1999 GAS LIFT,7,276 '11 S 9 Notes:General&Safety End Date Annotation 5/3/2000 NOTE:WELL CONVERTED FROM PRODUCER TO INJECTOR NIPPLE.7,325.9m. 1/11/2011 NOTE:View Schematic w/Alaska Schematic9.0 I LOCATOR,7,364.3 SEAL ASSY,7.365.3 id i 1 1 PLUG;7,410.0 - - � PRODUCTION,45.57,578.0 f APERF;7.713.0-7.753.0 - (PERF;7353 0-7.783 0 LINER,7,359.6-8,095.0 KUP INJ PROPOSED COMPLE' 1 1C-18 ConohiIIips O° a r rWell Attributes Max Angle&MD TD ♦ Wellbore API/UWI Field Name Wellbore Status Incl(`) MD(ftKB) Act Btm(ftKB) Alaska,Inc. 0,,,,,,,,,,. . 500292293900 KUPARUK RIVER UNIT INJ 47.80 6.700.52 8,095.0 .w- Rig Release Date Drillsite Well Type Well Sub Type KB-Grd(ft) Loc Sensitive? Proposed by:Diana Guzman 2/21/1999 1C Development Injection 46.51 No July 5,2015 ................................................_. HANGER;38.3 Casing Strings Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... Wt/Len(I...Grade Top Thread CONDUCTOR 16 15.062 42.0 112.0 112.0 62.58 H-40 WELDED eprk. Casing SURFACE Description OD(in) ID(n) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(t...Grade Top Thread 95/8 8.835 40.7 4,816.6 4,342.9 40.00 L-80 BTC Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread PRODUCTION 7 6.276 45.5 7,578.0 6,307.5 26.00 L-80 BTC-MOD Casing Description OD(in) ID(in) Top(ftKB) 'Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread emataaeatanamweautaaaaaamaaa `A.5 app,LINER 41/2 3.958 7,359.6 8,095.0 6,676.8 12.60 L-80 NSCT Liner Details Nominal ID Top(ftKB) Top(TVD)(ftKB) Top Incl 4) Item Des Com (in) 7,359.6 6,154.1 45.03 PACKER BAKER ZXP LINER PACKER&TIEBACK SLEEVE 5.000 CONDUCTOR;42.0-112.0 r r'M'� 7,381.7 6,169.6 45.11 HANGER BAKER HMC LINER HANGER 5.000 Tubing Strings Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft...Set Depth(TVD)(...Wt(Ib/ft) Grade Top Connection 'PROPOSED' 31/2 2.992 36.3 7,377.6 6,166.7 9.20 L-80 AB-EUE MOD TUBING Proposed Completion Details Top(ftKB) Item Des Com 36.3 HANGER FMC GEN V TUBING HANGER 7,325.9 NIPPLE CAMCO DB NIPPLE 7,364.3 LOCATOR BAKER LOCATOR 7,365.3 SEAL ASSY BAKER SEAL ASSEMBLY Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) Top(TVD) Top Ieel Top(ftKB) (ftKB) 41 Des Corn Run Date ID ttn) • 7,410.0 6,189.6 45.20 PLUG 2.70"HEX PLUG 0.000 Perforations&Slots Shot Dens SURFACE;40.7-4616_6-- • Top(11V13) Bhn(TVD)(MB) Top(ftKB) Blot(ftKB) (MB) (ftKB) Zone Date Gt) Type Corn 7,713.0 7,753.0 6,401.8 6,430.0 4,1G78 3/3/2002 6.0 APERF 2 7/8"HSD PJ Chgs,60 deg ph 7,753.0 7,783.0 6,430.0' 6,451.1 C 4,C 3,1C- 4/2/1999 4.0 (PERF 2 7/8"HC/DP 180 deg 18 ph+/-80 deg from low side Proposed Gas Lift Design Statio No/SP M Top(ftKB) Top(TVD)(ftKB) OD(in) Sery Valve Type 1 6,763.1 5,739.7 1 GAS LIFT O`✓ 2 7,279.6 6,097.3 1 GAS LIFT DPM GAS LIFT;6,763.1 171 GAS LIFT;7,279.6 1 E NIPPLE;7,325.9 El LOCATOR;7,364.3- SEAL ASSY;7,365.3 PLUG;7,410.0 PRODUCTION;45.5-7,578.0- APERF;7,713.0.7,753.0 IPERF;7,753.0-7,783.0 LINER;7,359.8-8,095.0 • 00-03co va - o 05 X5`1 ' 3 25ik2, tr4S WELL LOG RECEIVED TRANSMITTAL DATA LOGGED APR 2 2 2015 5/ 12015 .„K NDER PROACTIVE DIAC{NOSTIC SERVICES, INC. AOG CC To: AOGCC Makana Bender 333 West 7th Avenue SCANNED JUN 0 8 2015 Suite 100 Anchorage,Alaska 99501 (907) 793-1225 RE : Cased Hole/Open Hole/Mechanical Logs and/or Tubing Inspection(Caliper/ MU) The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention of: ProActive Diagnostic Services, Inc. Attn: Robert A. Richey 130 West International Airport Road Suite C Anchorage, AK 99518 Fax: (907) 245-8952 1] Caliper Report 11-Apr-15 1 C 18 1 Report / CD 50-029-22939-00 2) Caliper Report 13-Apr-15 1L-20A 1 Report / CD 50-029-22027-01 Signed : P'),,442.47.0v"/) 1,...efixeet Date : Print Name: PROACTIVE DIAGNOSTIC SERVICES, INC., 130 W.INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245-8951 FAX: (907)245-8952 E-MAIL: PDSANCHORAGE(&MEMORYLOG.COM WEBSITE: ,'WW.MEMORYLOG.COM D\Archives\MasterTemplateFiles\Templates\Distribution\TransmittalSheets\ConocoPhil lips_Transmit.docx \qa-ooh I riECEIVED 251 VI,. APR 2 2 2015 Memory Multi-Finger Caliper . 0 AOGGC Log Results Summary Company: ConocoPhillips Alaska, Inc. Well: 1C-18 Log Date: April 11, 2015 Field: Kuparuk I Log No.: 10339 State: Alaska Run No.: 1 API No. 50-029-22939-00 Pipe Description: 4.5 inch 12.6 lb. L-80 NSCT Top Log Interval: Surface IPipe Use: Tubing Bottom Log Interval: 7,398 Ft. (MD) Inspection Type : Corrosive and Mechanical Damage Inspection 1 COMMENTS : This caliper data is tied into the DB Nipple at 7,325 feet(Driller's Depth). IThis log was run to assess the condition of the tubing with respect corrosive and mechanical damage and to identify any potential leaks in the tubing after the well failed an MITIA. The caliper recordings indicate a possible hole recorded in joint 227 (7,114 feet). A 3-D log plot of the caliper recordings across the possible Ihole recorded is included in this report. The caliper recordings indicate the 4.5 inch tubing appears to be in good to poor condition with respect to I corrosive and mechanical damage. Wall penetrations ranging from 40%to 72%wall thickness are recorded in 183 of the 251 joints analyzed. Recorded damage appears in the forms of apparent erosion from surface to approximately 3,500 feet and isolated pitting, lines of pits, line corrosion, and corrosion from approximately 1,550 feet to the end of the log interval. Cross-sectional wall loss ranging from 15% to 18% is recorded in 63 Iof the 251 joints analyzed. No significant I.D. restrictions are recorded. MAXIMUM RECORDED WALL PENETRATIONS : IDescription Percent Wall Penetration Possible Hole 89 227 7,114 Ft. (MD) Corrosion /Apparent Erosion 72 99 3,102 Ft. (MD) I Corrosion/Apparent Erosion 72 81 2,506 Ft. (MD) Line Corrosion 71 192 5,984 Ft. (MD) Line of Pits 71 215 6,717 Ft. (MD) IMAXIMUM RECORDED CROSS-SECTIONAL METAL LOSS : Description Percent Wall Loss I Apparent Erosion 18 82 2,533 Ft. (MD) Apparent Erosion 18 79 2,452 Ft. (MD) Apparent Erosion 18 80 2,481 Ft. (MD) I Apparent Erosion 18 20 665 Ft. (MD) Apparent Erosion 18 68 2,110 Ft. (MD) MAXIMUM RECORDED ID RESTRICTIONS : INo significant I.D. restrictions are recorded. IE. Gustin J. Bruning S. Drake -,nalyst(s) ProActive Diagnostic Services, Inc. / P.O. Box 1369, Stafford, TX 77497 I Phone: (281)431-7100 or(888) 565-9085 Fax: (281)431-7125 E-mail: PDSAnalvsis(aa memorylog.cont Prudhoe Bay Field Office Phone: (907)659-2307 Fax: (907) 659-2314 I I 1 C4:3. PDS Multifinger Caliper 3D Log Plot Company : ConocoPhillips Alaska, Inc. Field : Kuparuk Well : 1C-18 Date : April 11, 2015 IDescription : Detail of Caliper Recordings Across Possible Hole at 7,114 Feet. Comments Depth Maximum Penetration Maximum I.D. 3-D Log Image Map I I lft:65ft 10 % 100 3.5 inches 4.5 347° 0° 90° 180° 270° 0° Minimum I.D. I 4 .3.5 inches 4.5 I Nominal I.D. • 3.5 inches 4.5 IU .) ". I I i r -------'t—L:,.- 1 7100 , , = --_-:-..-- -....,_...--- I , o--- L _ ,.... Joint 227 7105 L,......... Ir I Possible Hole , @ 1 7,114' -..z.-_ ..::. ----- 6 89%Wall '"". 1 ? Er- al .z. I Penetration 7110 t"--- 111 . ) .--::_•-=-.. -a.- -IL- ..._•., ;.--_- _.--,-. I 7115 . --- - = 7-. ,-.- I 7120 . : .........: I E---: IJoint 228 7125 Line of Pits :-.- I 46%Wall - Penetration ... . . r.-- --_-_-_.= . 7130 . _- --- ,---._ 1 Ir---- - !-;--;------- I : ./.1.11 )• .-.,. I I Correlation of Recorded Damage to Borehole Profile i I. Pipe 1 4.5 in. (56.6'-7,398.0') Well: 1C-18 Field: Kuparuk I Company: ConocoPhillips Alaska, Inc. Country: USA Survey Date: April 11, 2015 I I _ Approx.Tool Deviation _ Approx. Borehole Profile 1 1 60 _ 25 797 I 50 1,553 I 75 —a 2,321 GLM 1 — -- —+� 100 3,104 Q a� 125 3,864 c GLM 2 -- �: c °- o p I150 4,652 GLM 3 - I 175 5,442 GLM 4 1 _+ 200 6,235 GLM 5 -_� 1 225 7,027 GLM 6 I 234.5 7,393 0 50 100 Damage Profile(%wall)/Tool Deviation (degrees) I Bottom of Survey=234.5 I I IPDS Report Overview Body Region Analysis M I (1114-SWell: 1C-18 Survey Date: April 11,2015 Field: Kuparuk Tool Type: UW MFC 40 No.218451 Company: ConocoPhillips Alaska, Inc. Tool Size: 2.75 inches I Country: USA No. of Fingers: 40 Pipe 4.5 in. 12.6 ppf L-80 NSCT Analyst: J. Bruning Pipe Nom.O.D. Weight Grade&Thread Nom.I.D. Top Depth Bottom Depth I4.5 in. 12.6 ppf L-80 NSCT 3.958 in. 57 ft. 7,398 ft. IPenetration(%wall) Damage Profile(%wall) 200 Imo Penetration body Jail Metal loss body 0 50 100 I 150 0.1 a 100 1 50 49 - 1 0 0 to 20 to 40 to over 20% 40% 85% 85% Number of joints analyzed(total=251) GLM 1 (8:30) I1 66 183 1 97 Damage Configuration(body) GLM 2 (1:00) - 150 145 - _ 100 7 GLM 3 (10:00) I 50 GLM 4(8:00) I 0 Isolated General Line Other Hole/ Pining Corrosion Corrosion Damage Pos.Hole GLM 5(8:30) I GLM 6(4:30) Number of joints damaged(total=251) 234.5 38 52 109 51 1 Bottom of Survey=234.5 I I I I1111 - PDS Report Joint Tabulation Sheet I Well: 1C-18 Kuparuk Survey Date: April 11, 2015 Field: Analyst: J. Bruning Company: ConocoPhillips Alaska,Inc. I Pipe Description 4.5 in. 12.6 ppf L-80 NSCT Tubing Nom. I.D. Body Wall Top Depth Bottom Depth 3.958 in. 0.271 in. 57 ft. 7,398 ft. Joint Jt. Depth Pen. Pen. Pen. Metal Min. Damage Profile No. (Ft.) Upset Body % Loss I.D. Comments (%wall) I (in.) (in.) % (in.) 0 50 100 0.1 57 0.06 0.06 21 17 4.02 Pup Apparent Erosion. 1 1 60 0.06 0.06 24 17 4.01 Apparent Erosion. I 1.1 91 0.06 0.06 24 16 4.02 Pup Apparent Erosion. ■ 2 99 0.05 0.06 24 15 4.00 Apparent Erosion. •■ 3 129 0.06 0.06 21 14 3.96 Apparent Erosion. ■ 4 160 0.06 0.06 24 17 3.98 Apparent Erosion. 190 0.06 0.06 23 17 4.00 , Apparent Erosion.IS 6 221 0.05 0.06 23 16 4.01 Apparent Erosion. ■ 7 253 0.06 0.07 24 15 3.99 Apparent Erosion. ■ 8 282 0.06 0.06 23 15 4.00 Apparent Erosion. ■ 9 311 0.06 0.06 23 16 4.01 Apparent Erosion. ■ I 10 342 0.06 0.06 21 17 4.00 Apparent Erosion. ii 11 373 0.05 0.06 24 17 4.01 Apparent Erosion. ii 12 404 0.06 0.07 25 15 _ 4.00 Apparent Erosion. ■ 13 432 0.05 0.07 25 15 4.00 Apparent Erosion. ■ I 14 462 0.05 0.06 24 16 3.99 Apparent Erosion. ■ 15 491 0.05 0.06 23 15 4.00 Apparent Erosion. ,i 15.1 522 0 0 0 0 3.90 Camco DB Nipple 16 524 0.06 0.06 21 15 4.00 Apparent Erosion. ■ 17 555 0.06 0.07 24 15 4.00 Apparent Erosion. ■ 18 586 0.05 0.06 23 15 4.01 Apparent Erosion. ■ 19 616 0.06 0.06 21 16 4.01 Apparent Erosion. 20 646 0.06 0.07 25 18 4.01 Apparent Erosion. 1 I 21 678 0.06 0.06 23 15 4.00 Apparent Erosion. ■ 22 707 0.05 0.06 23 15 4.01 Apparent Erosion. •■ 23 738 0.06 0.07 25 16 4.01 Apparent Erosion. ■ 24 768 0.05 0.07 25 16 3.99 Apparent Erosion. i 25 797 0.05 0.06 23 17 4.00 Apparent Erosion. 1 I 26 826 0.06 0.06 24 16 4.00 Apparent Erosion. a 27 857 0.06 0.07 25 17 4.01 . Apparent Erosion. a 28 887 0.06 0.06 23 17 4.00 Apparent Erosion. a 29 918 0.06 0.07 24 15 4.00 Apparent Erosion. ■ I 30 948 0.06 0.06 23 16 4.01 Apparent Erosion. ■ 31 979 0.06 0.06 23 15 4.00 Apparent Erosion. ■ 32 1009 0.06 0.07 25 16 4.00 Apparent Erosion. ■ 33 1040 0.05 0.06 23 16 3.96 Apparent Erosion. ■ I 34 1070 0.04 0.06 21 13 3.96 Apparent Erosion. ■ 35 1098 0.05 0.06 24 16 3.96 Apparent Erosion. 36 1128 0.05 0.06 24 15 4.00 Apparent Erosion. ■ 37 1159 0.05 0.06 20 14 4.00 Apparent Erosion. ■ 1 38 1190 0.05 0.06 21 15 3,98 Apparent Erosion. ■ 39 1220 0.05 0.06 23 15 3.99 Apparent Erosion. ■ 40 1251 0.05 0.06 20 13 3.98 Apparent Erosion. ■ 41 1281 0.05 0.06 23 16 4.00 Apparent Erosion. ■ I 42 1312 0.05 0.06 _ 21 14 3.96 Apparent Erosion. ■ 43 1342 0.05 0.08 29 15 4.00 Apparent Erosion. ■ 44 1372 0.05 0.06 20 14 3.96 Apparent Erosion. ■ 45 1402 0.05 0.06 23 14 _ 339 Apparent Erosion. ■ 46 1432 0.05 0.06 23 16 3.99 Apparent Erosion. ■ 47 1463 0.06 0.06 23 15 3.99 Apparent Erosion. IPenetration Body Metal Loss Body I Page 1 I I IJc PDS Report Joint Tabulation Sheet I Well: 1C-18 Survey Date: April 11, 2015 Field: Kuparuk Analyst: J. Bruning Company: ConocoPhillips Alaska,Inc. Pipe Description Nom. I.D. Body Wall Top Depth Bottom Depth I 4.5 in. 12.6 ppf L 80 NSCT Tubing 3.958 in. 0.271 in. 57 ft. 7,398 ft. Joint Jt. Depth Pen. Pen. Pen. Metal Min. Damage Profile No. (Ft.) Upset Body % Loss I.D. Comments (%wall) I (in.) (in.) % (in.) 0 50 100 48 1493 0.05 0.06 21 15 3.99 Apparent Erosion. ■ 49 1524 0.05 0.07 27 14 3.99 Apparent Erosion. ■ ISO1553 0.05 0.07 25 16 3.99 Corrosion.Apparent Erosion. a 51 1581 0.05 0.09 32 14 3.98 Corrosion.Apparent Erosion. ■ 52 1612 0.05 0.06 21 15 3.97 Corrosion.Apparent Erosion. 53 1642 0.04 0.05 20 13 3.96 Line Corrosion.Apparent Erosion. U 54 1672 0.04 0.08 31 14 3.97 Corrosion.Apparent Erosion. ■ I 55 1703 0.05 0.06 21 15 4.00 Corrosion.Apparent Erosion. ■ 56 1734 0.07 0.06 21 14 3.99 Corrosion.Apparent Erosion. ■ 57 1765 0.04 0.08 29 13 3.95 Corrosion.Apparent Erosion. ■ 58 1796 0.05 0.12 46 13 3.96 Corrosion.Apparent Erosion. Em I 59 1827 0.05 0.11 40 16 3.97 Corrosion.Apparent Erosion. a■� 60 1858 0.09 0.17 62 14 3.97 Corrosion.Apparent Erosion. ■mm 61 1889 0.04 0.11 42 13 3.94 Corrosion.Apparent Erosion. ■m■ 62 1920 0.06 0.13 49 12 3.97 Corrosion.Apparent Erosion. ■mm I 63 1950 0.05 0.12 42 11 3.93 Line Corrosion.Apparent Erosion. ■■■ 64 1981 0.05 0.12 44 14 3.96 Corrosion.Apparent Erosion. goon65 2012 0.05 0.14 52 14 3.97 Corrosion.Apparent Erosion. ■■■ 66 2043 0.06 0.15 56 17 3.99 Corrosion.Apparent Erosion. I 67 2075 0.05 0.07 27 12 3.97 Corrosion.Apparent Erosion. ■�, 68 2105 0.04 0.17 63 18 3.98 Corrosion.Apparent Erosion. gm69 2137 0.06 0.16 60 15 3.97 _Corrosion.Apparent Erosion. imm 70 2168 0.07 0.14 53 14 3.99 Corrosion.Apparent Erosion. Nom 71 2198 0.04 0.12 44 13 3.95 Corrosion.Apparent Erosion. MUM I 72 2229 0.05 0.12 42 13 3.97 Corrosion.Apparent Erosion. ■■■ 73 2259 0.12 0.16 59 14 3.97 Corrosion.Apparent Erosion. E■■ 74 2289 0.11 0.13 49 14 3.95 Corrosion.Apparent Erosion. goo 75 2321 0.07 0.14 50 11 3.94 Isolated Pitting.Apparent Erosion. ■m I 76 2351 0.04 0.09 32 11 3.98 Isolated Pitting.Apparent Erosion. magi77 2381 0.06 0.13 49 13 3.93 Corrosion.Apparent Erosion. Emig 78 2411 0.04 0.17 62 15 3.97 Corrosion.Apparent Erosion. moo 79 2439 0.06 0.15 56 18 3.97 Corrosion.Apparent Erosion. rmm I 80 2468 0.06 0.16 58 18 3.98 Corrosion.Apparent Erosion. i■m 81 2500 0.05 0.19 72 16 3.97 Corrosion.Apparent Erosion. rim■ 82 2529 0.08 0.16 58 18 3.94 Corrosion.Apparent Erosion. rim 83 2561 0.07 0.17 64 16 3.96 Corrosion.Apparent Erosion. iim I 83.1 2590 0.06 0.11 39 14 3.96 Pup Corrosion.Apparent Erosion. 83.2 2600 0 0 0 0 3.94 GLM 1 (Latch @ 8:30) U 83.3 2607 0.06 0.11 41 17 3.99 Pup Corrosion.Apparent Erosion. 111 amm 84 2615 0.05 0.17 64 17 3.97 Corrosion.Apparent Erosion. BIM I 85 2645 0.07 0.15 56 13 3.98 . Corrosion.Apparent Erosion. MINN 2674 0.05 0.17 61 13 3.95 Isolated Pitting.Apparent Erosion. Emm 87 2706 0.04 0.14 50 12 3.94 _Isolated Pitting.Apparent Erosion. MU 88 2736 0.04 0.14 52 13 3.93 Isolated Pitting.Apparent Erosion. (im■ 89 2765 0.05 0.15 57 14 3.95 Corrosion.Apparent Erosion. lam' 90 2796 0.04 0.15 56 14 3.96 Isolated Pitting.Apparent Erosion. Ems 91 2828 0.08 0.17 62 14 3.96 Corrosion.Apparent Erosion. Emm 92 2859 0.06 0.17 61 16 3.93 Corrosion.Apparent Erosion. MIN 93 2888 0.08 0.17 62 14 3.94 Corrosion.Apparent Erosion. ■■■ I94 2919 0.04 0.13 46 12 3.95 Corrosion.Apparent Erosion. IPenetration Body Metal Loss Body I Page 2 I I I - PDS Report Joint Tabulation Sheet I Well: 1C-18 Survey Date: April 11,2015 Field: Kuparuk Analyst: J. Bruning Company: ConocoPhillips Alaska,Inc. Pipe Description Nom.I.D. Body Wall Top Depth Bottom Depth I 4.5 in. 12.6 ppf L 80 NSCT Tubing 3.958 in. 0.271 in. 57 ft. 7,398 ft. Joint Jt. Depth Pen. Pen. Pen. Metal Min. Damage Profile No. (Ft.) Upset Body % Loss I.D. Comments (%wall) I (in.) (in.) % (in.) 0 50 100 95 2950 0.09 0.13 46 12 3.94 Isolated Pitting.Apparent Erosion. mon 96 2981 0.05 0.17 63 12 3.95 Isolated Pitting.Apparent Erosion. Emma 97 3011 0.05 0.15 56 14 3.94 Corrosion.Apparent Erosion. num I 98 3042 0.12 0.16 58 15 3.97 Corrosion.Apparent Erosion. Emma 99 3073 0.06 0.19 72 17 3.93 Corrosion.Apparent Erosion. MUM 100 3104 0.05 0.16 59 14 3.99 Corrosion.Apparent Erosion. moo 101 3133 0.07 0.17 64 16 3.95 Corrosion.Apparent Erosion. mom I102 3164 0.11 0.16 58 13 3.95 Line Corrosion.Apparent Erosion. Eames 103 3195 0.11 0.17 64 11 3.96 Line Corrosion.Apparent Erosion. ■■mm 104 3226 0.09 0.17 61 13 3.94 Corrosion.Apparent Erosion. ■amm 105 3255 0.04 0.16 60 11 3.92 Isolated Pitting.Apparent Erosion. ■mam I106 3285 0.04 0.16 60 11 3.97 Line Corrosion.Apparent Erosion. mum 3315 0.05 0.15 55 12 3.94 Isolated Pitting.Apparent Erosion. nu. 108 3345 0.05 0.13 49 13 3.97 Corrosion.Apparent Erosion. ■mmm 109 3375 0.05 0.16 58 12 3.95 Line Corrosion.Apparent Erosion. Ii 10 3405 0.07 0.10 36 11 3.95 Isolated Pitting.Apparent Erosion.111 3436 0.04 0.16 60 11 3.96 Isolated Pitting.Apparent Erosion. ■■■■�' ■■a■ 112 3466 0.04 0.15 57 11 3.96 Isolated Pitting.Apparent Erosion. ■mm■ 113 3496 0.07 0.15 54 10 3.94 Isolated Pitting.Apparent Erosion. ■■■■ I 114 3528 0.09 0.15 57 9 3.95 Isolated Pitting. mom'3558 0.04 0.14 53 11 3.94 Isolated Pitting. min 116 3589 0.04 0.14 52 9 3.97 Line of Pits. mom= 117 3619 0.06 0.14 53 9 3.93 Line Corrosion. mom 118 3649 0.05 0.17 63 9 3,91 Isolated Pitting. minim I 119 3680 0.05 0.17 62 10 3,92 Corrosion. mom ■� 120 3709 0.04 0.13 48 10 3.95 Isolated Pitting. ■■ 121 3740 0 0.14 53 9 3.92 Isolated Pitting. MINIM 122 3771 0.05 0.17 61 10 3.94 Isolated Pitting. ■■■a I 123 3801 0.07 0.17 63 11 3.94 Isolated Pitting. ■mmm 124 3833 0 0.15 55 11 3.93 Line Corrosion. ■main 125 3864 0,04 0.18 67 10 3.95 Line Corrosion. mmma 126 3893 0.09 0.16 58 10 3.93 Line Corrosion. tom I 127 3925 0.09 0.16 60 11 3.95 Line Corrosion. comma 128 3955 0.05 0.16 60 10 3.94 Isolated Pitting. comma 129 3986 0.09 0.16 58 11 3.96 Line Corrosion. ■m■ 129.1 4018 0.05 0.11 40 12 3.94 Pup Isolated Pitting. 129.2 4027 0 0 0 0 3.89 GLM 2 (Latch @ 1:00) ��'� I 129.3 4034 0.04 0.14 52 13 3.96 Pup Corrosion. Emma 130 4041 0.04 0.16 59 8 3.91 Isolated Pitting. immm■ 131 4071 0.11 0.14 52 10 3.89 Line Corrosion.Lt. Deposits. ■■■■ I 132 4103 0.05 0.15 . 54 9 3.94 Isolated Pitting. immaa 133 4133 0 0.16 61 11 3.95 Line Corrosion. comm■ 134 4164 0.07 0.16 61 10 3.94 Isolated Pitting. comm■ 135 4195 0.14 0.18 66 11 3.94 Line Corrosion. ■mm■ 136 4225 0 0.17 64 9 3.90 Line Corrosion.I 137 4256 0.09 0.18 66 12 3.92 Corrosion. mum138 4287 0.05 0.17 61 10 3.92 Isolated Pitting. ■■■■ 139 4318 0.06 0.18 67 8 3.91 Line Corrosion. immmm 140 4346 0.04 0.16 59 9 3.94 Line Corrosion. immm■ I141 4377 0 0.15 54 7 3.91 Line Corrosion. IPenetration Body Metal Loss Body I Page 3 I I I tii 101., w PDS Report Joint Tabulation Sheet I Well: 1C-18 Survey Date: April 11, 2015 Field: Kuparuk Analyst: J. Bruning Company: ConocoPhillips Alaska,Inc. I Pipe Description 4.5 in. 12.6 ppf L-80 NSCT Tubing Nom. I.D. Body Wall Top Depth Bottom Depth 3.958 in. 0.271 in. 57 ft. 7,398 ft. Joint Jt. Depth Pen. Pen. Pen. Metal Min. Damage Profile No. (Ft.) Upset Body % Loss I.D. Comments (%wall) I (in.) (in.) % (in.) 0 50 100 142 4409 0.13 0.18 67 _ 11 _ 3.94 Line Corrosion. Emmis 143 4438 0.08 0.17 61 15 3.94 Corrosion. .m■ 144 4469 0.10 0.13 48 10 3.92 Isolated Pitting. mom I 145 4499 0.04 0.13 48 8 3.95 Isolated Pitting. Immm 146 4528 0.11 0.15 57 10 3.92 Line Corrosion. mime 147 4558 0.09 0.17 62 8 3.94 Line of Pits. mom. 148 4588 0.10 0.15 56 9 3.89 Line Corrosion.Lt. Deposits.I 149 4620 0.12 0.16 57 8 3.91 Line Corrosion. Immmm 150 4652 0.12 0.17 62 10 3.90 Line Corrosion. i■m■m 151 4682 0.05 0.15 57 10 3.94 Line Corrosion. =mom 152 4713 0.09 0.16 59 10 3.94 Isolated Pitting. mum I 153 4744 0 0.15 56 9 3.94 Line Corrosion. ■m■ 154 4775 0.06 0.13 47 _ 8 3.93 Isolated Pitting. I■■ o! 155 4803 0.05 0.18 68 10 3.92 Line Corrosion. sumiN2 156 4835 0.04 0.13 48 7 3.94 Isolated Pitting. Immo I 157 4866 0 0.13 49 8 3.94 Line of Pits. mom 4896 0.07 0.19 68 8 3.94 Line Corrosion. Imm■m 159 4927 0.09 0.16 60 8 3.91 Line Corrosion. Imo 160 4958 0.09 0.15 55 6 3.91 Line Corrosion. 1■emo I 161 4988 0.04 0.16 59 7 3.93 Line Corrosion. immmm 162 5019 0 0.16 59 8 3.94 Isolated Pitting. Ie■mm 163 5049 0 0.17 63 8 3.92 Line Corrosion. I■■■■ 164 5080 0.04 0.15 55 7 3.93 Line of Pits. i■■■■ 165 5111 0.05 0.16 58 8 3.92 _Line Corrosion. I■■■■ I 166 5142 0.06 0.15 56 11 3.94 Isolated Pitting. mm.. 167 5173 0 0.17 63 10 3.94 Line Corrosion. ■■■■ 168 5203 0.10 0.19 68 10 3.94 Line Corrosion. minim I168.1 5234 0.10 0.15 57 10 3.92 Pup Line Corrosion. 168.2 5243 0 0 0 0 3.87 GLM 3 (Latch @ 10:00) .1111 168.3 5251 0.05 0.15 56 11 3.93 Pup Corrosion. Immo 169 5259 0.11 0.16 59 9 3.92 _Line Corrosion. I■■■■ 170 5288 0.04 0.17 62 8 3.95 Line Corrosion. Immo■ I 171 5320 0.12 0.14 53 7 3.95 Line Corrosion. ■m.. 172 5349 0.07 0.14 52 7 3.92 Line Corrosion. l■■■■ 173 5381 0.08 0.16 59 9 3.92 Line Corrosion. Immo 174 5412 0.13 0.15 56 9 3.94 Line Corrosion. Ieeee I 175 5442 0.05 0.16 59 8 3.94 Line Corrosion. Ieeeo 176 5474 0 0.16 61 7 3.93 Line Corrosion. mom= 177 5505 0 0.14 53 7 3.93 Line Corrosion. mmm■ 178 5535 0.05 0.15 55 7 3.91 Line of Pits. I■■■■ I 179 5567 0.08 0.16 58 4 3.87 Line Corrosion.Lt. Deposits. �Em■■ 180 5596 0 0.17 62 7 3.93 Line of Pits. 1EmmE 181 5626 0 0.15 55 6 3.93 Line Corrosion. m■■m■ 182 5656 0 0.18 66 8 3.94 Line Corrosion. m.o. 183 5687 0.05 0.16 59 8 3.87 Line of Pits. Lt. Deposits. miaow I184 5717 0.05 0.14 51 6 3.92 Line of Pits. immmm 185 5748 0.08 0.15 56 6 3.88 Line of Pits, Lt. Deposits. li meo 186 5779 0 0.16 59 9 3.91 Line Corrosion. e■ee 187 5809 0.15 . 0.19 70 7 3.94 Line Corrosion. ,mem■ I188 5840 0.10 0.16 59 9 3.93 Line Corrosion. I IPenetration Body Metal Loss Body I Page 4 I I C6-3S. PDS Report Joint Tabulation Sheet I Well: 1C-18 Survey Date: April 11,2015 Field: Kuparuk Analyst: J. Bruning Company: ConocoPhillips Alaska,Inc. Pipe Description Nom. I.D. Body Wall Top Depth Bottom Depth I 4.5 in. 12.6 ppf L-80 NSCT Tubing 3.958 in. 0.271 in. 57 ft. 7,398 ft. Joint Jt. Depth Pen. Pen. Pen. Metal Min. Damage Profile No. (Ft.) Upset Body % Loss I.D. Comments (%wall) I (in.) (in.) % (in.) 0 50 100 189 5871 0.06 0.16 61 7 3.92 Line Corrosion. �■■■■ 190 5902 0.09 0.16 60 7 3.92 Line Corrosion. m■■■ 191 5933 0 0.18 65 6 3.92 Line of Pits. I■■■■ I 192 5964 0.14 0.19 71 6 _ 3.89 Line Corrosion.Lt. Deposits. �■■■■ 193 5995 0 0.16 58 8 3.92 _Line Corrosion. s■■■■ 194 6026 0 , 0.16 60 7 3.92 Line Corrosion. m■■■ . 194.1 6056 0.06 0.16 58 13 3.96 Pup Line Corrosion. I 194.2 6064 0 0 0 0 3.88 GLM 4 (Latch @ 8:00) 11111 194.3 6073 0 0.14 51 10 3.92 Pup Line Corrosion. ■■■■ 195 6079 0.05 0.14 52 6 3.92 Line Corrosion. m■■■ 196 6110 0.05 0.15 56 6 3.90 Line Corrosion. ■■■■■ I 197 6142 0.06 0.16 61 6 3.91 Line of Pits. o■■■■ 198 6172 0 0.14 52 6 3.92 Line of Pits. s■■■ 199 6203 0 0.12 44 3 3.90 Line of Pits. Lt. Deposits. Emma 200 6235 0.04 0.16 59 6 3.93 Line Corrosion. 11■■■■ I 201 6265 0 0.18 67 5 3.90 Line Corrosion.Lt. Deposits. .■■■■ 202 6297 0.08 0.16 58 6 3.90 Line Corrosion. Naomi 203 6327 0 0.14 51 5 3.92 Line Corrosion. mum 204 6358 0.07 0.17 62 _ 7 _ 3.90 Line Corrosion. 1■■■■ I 205 6388 0 0.16 59 5 3.88 _ Line Corrosion.Lt. Deposits. ■■■■ 206 6420 0.10 0.17 64 8 3.90 Line Corrosion. Immo 207 6450 0.05 0.18 67 7 3.87 Line Corrosion.Lt. Deposits. mum 208 6480 0.07 0.18 65 7 3.90 Line Corrosion. 1■■■■ I 209 6512 0 0.14 52 6 3.92 Line Corrosion. ammo 6541 0 0.17 62 8 3.89 Line Corrosion.Lt. Deposits. mom 211 6571 0 0.11 42 3 3.86 Isolated Pitting.Lt. Deposits. mom 212 6601 0 0.12 46 4 3.90 Line of Pits. m■■ I213 6633 0.11 0.16 59 , 5 3.90 Isolated Pitting. s■■■ 214 6663 0 0.12 42 4 3.90 Line of Pits. �■■■� 215 6694 0.05 0.19 71 5 3.90 Line of Pits. M■■■ 216 6725 0 0.17 63 7 3.90 . Line Corrosion.Lt. Deposits. m■■■ 216.1 6755 0.10 0.12 45 6 3.92 Pup Line of Pits. 11" 1 ' I 216.2 6762 0 0 0 0 3.87 GLM 5 (Latch @ 8:30) 216.3 6772 0.08 0.15 55 8 3.92 Pup Line Corrosion. I■■■■ 217 6779 0.11 0.16 59 , 6 3.86 Line Corrosion.Lt. Deposits. �■■■■ 218 6810 . 0.04 0.16 60 4 3.88 Line of Pits.Lt.Deposits. .1■■■■ I 219 6841 0.05 0.14 52 6 3.83 Isolated Pitting.Lt. Deposits. 220 6871 0.10 0.09 35 2 3.92 Line of Pits. mil 221 6902 0.12 0.16 58 6 3.88 Line of Pits.Lt. Deposits. s■■■■ 222 6933 0 0.17 62 3 3.87 Line of Pits.Lt. Deposits. m■■■ 1 223 6965 0.08 0.17 63 6 3.90 _Line Corrosion. t■■■■ 224 6996 0 0.15 56 4 3.92 Line of Pits. u■■■ 225 7027 0.11 0.15 57 6 3.91 Line Corrosion. o■■■■ 226 7058 . 0 0.16 59 5 3.92 Line of Pits. m■■■ 227 7087 0 0.24 89 6 3.89 Possible Hole! Lt. Deposits. I 228 7118 0 0.12 46 2 3.88 Line of Pits. Lt. Deposits. �■■■ ■■■■ ■■ 229 7149 0.07 0.12 44 2 3.90 Line of Pits. ■■i, 230 7180 0.09 0.19 69 4 3.91 Line of Pits. m■■■ 231 7208 0 0.15 55 4 3.89 Line of Pits. Lt. Deposits. II■■■■ 232 7239 0 0.17 62 3 3.91 Line of Pits. 'Penetration Body Metal Loss Body I Page 5 I I 11111 PDS Report Joint Tabulation Sheet I Well: 1C-18 Survey Date: April 11, 2015 Field: Kuparuk Analyst: J. Bruning Company: ConocoPhillips Alaska,Inc. I Pipe Description Nom.I.D. Body Wall Top Depth Bottom Depth 4.5 in. 12.6 ppf L 80 NSCT Tubing 3.958 in. 0.271 in. 57 ft. 7,398 ft. Joint jt. Depth Pen. Pen. Pen. Metal Min. 1 Damage Profile No. (Ft.) Upset Body % Loss I.D. Comments (%wall) I (in.) (in.) % (in.) 0 50 100 232.1 7270 0 0.14 53 3 3.92 Pup Line of Pits. INEMMIll 232.2 7279 0 0 0 0 3.87 GLM 6 (Latch @ 4:30) I 232.3 7285 0 0.07 26 8 3.92 Pup Corrosion. 233 7293 0 0.15 55 3 3.91 Line of Pits. 233.1 7325 0 0 0 0 3.74 Camco DB Nipple Pm. 234 7326 0.09 0.12 44 4 3.90 Line of Pits. Pill. 234.1 7358 0 0.09 31 1 3.92 Pup Line of Pits. I 234.2 7363 0 234.3 7376 0 0 0 0 3.85 Baker Locator 0 0 0 3.81 Baker Seal Assembly 234.4 7385 0 0.05 18 1 3.90 _PUP Shallow Pitting. imi 234.5 7393 0.09 0.14 52 4 3.87 Pup Line of Pits. Lt.Deposits. 1111111111111111111 IPenetration Body 'Metal Loss Body I I I I I I 1 I I 1 Page 6 1 PDS Report Cross Sections 1Well: 1C-18 Survey Date: April 11,2015 Field: Kuparuk Tool Type: UW MFC 40 No.218451 Company: ConocoPhillips Alaska,Inc. Tool Size: 2.75 inches ' Country: USA No. of Fingers: 40 Tubing: 4.5 in. 12.6 ppf L-80 NSCT Analyst: J.Bruning 1 1 Cross Section for Joint 227 at depth 7,113.910 ft. Tool speed= 55 Nominal ID=3.958 Nominal OD=4.5 Remaining wall area=94% ' Tool deviation=51° 1 ,` 1 1 1 1 1 1 ,,' Finger=35 Penetration=0.242 in. Possible Hole 0.24 in.=89%Wall Penetration HIGH SIDE=UP 1 1 1 1 I I PDS Report Cross Sections IWell: r 1C-18 Survey Date: April 11,2015 Field: Kuparuk Tool Type: UW MFC 40 No.218451 Company: ConocoPhillips Alaska,Inc. Tool Size: 2.75 inches I Country: USA No. of Fingers: 40 Tubing: 4.5 in. 12.6 ppf L-80 NSCT Analyst: J.Bruning 1 ICross Section for Joint 99 at depth 3,102.240 ft. I Tool speed=56 Nominal ID=3.958 Nominal OD=4.5 /��'—" � ` Remaining wall area=87% Tool deviation=34° ` I I / / \ 111 ( I \I I 1 / I \ / I 1/ r� I Finger=26 Penetration=0.195 in. ICorrosion/Apparent Erosion 0.20 in.=72%Wall Penetration HIGH SIDE=UP 1 I I I I k.S., PDS Report Cross Sections IWell: 1C-18 Survey Date: April 11,2015 Field: Kuparuk Tool Type: UW MFC 40 No.218451 Company: ConocoPhillips Alaska,Inc. Tool Size: 2.75 inches I Country: USA No. of Fingers: 40 Tubing: 4.5 in. 12.6 ppf L-80 NSCT Analyst: J.Bruning I ICross Section for Joint 82 at depth 2,532.600 ft. I Tool speed=54 Nominal ID=3.958 Nominal OD=4.5 000,00....'�""'�" Remaining wall area=82% ITool deviation= 13° /� I 7 \\ 11 I I I I I I I / \,lid I N,, _6/ I *81111.81.1110/ Finger=31 Penetration=0.078 in. 1 Corrosion/Apparent Erosion 18%Cross-Sectional Wall Loss HIGH SIDE=UP I I I I I I1111 PDS Report Cross Sections IWell: 1C-18 Survey Date: April 11,2015 Field: Kuparuk Tool Type: UW MFC 40 No.218451 Company: ConocoPhillips Alaska,Inc. Tool Size: 2.75 inches I Country: USA No. of Fingers: 40 Tubing: 4.5 in. 12.6 ppf L-80 NSCT Analyst: J. Bruning I ICross Section for Joint 79 at depth 2,451 .510 ft. I Tool speed=54 Nominal ID=3.958 Nominal OD=4.5 '� Remaining wall area=82% / Tool deviation= 11° / / 1 I / /I I \ _______ -------- i / I \ 10"" I Finger=23 Penetration=0.104 in. ICorrosion/Apparent Erosion 18%Cross-Sectional Wall Loss HIGH SIDE=UP I I I 1 I KUP INJ 1C-18 ConocoPhillips '-a Well Attributes Max Angle&MD TD r, _ Alaska,Inc. Wellbore APIIUWI Field Name Wellbore Status Ind(°) MD(ftKB) Act Btm(ftKB) crop -Ph4bps 500292293900 KUPARUK RIVER UNIT INJ 47.80 6,700.52 8,095.0 ... Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date 1c-10,6/62o1ae37.58AM SSSV:NIPPLE Last WO: 46.51 2/21/1999 Venice]schematic{actual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date _ _ ___.._.................. Last Tag:CTMD 7.855.0 6/4/2014 Rev Reason:TAG hipshki 6/6/2014 HANGER;36.3 Mil-Oea -Casing Strings Casing Description OD OMB)ID tin) Top(RKB) Set Depth KB) Set Depth(ND)... Wt/Len(I...Grade Top Thread CONDUCTOR 16 15.062 42.0 112.0 112.0 62.58 H-40 WELDED Casing Description 013(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)...Wt/Len(I...Grade Top Thread ,. SURFACE 9 5/8 8.835 40.7 4,816.6 4,342.9 40.00 L-80 BTC 's Casing Description 00(in) 10 In) Top(ftKB) Set Depth(ftKB) 'Set Depth(11/1))...'Wt/Len(I...Grade Top Thread i M1PRODUCTION 7 6276 45.5 7,578.0 6,307.5 26.00 L-80 BTC-MOD Casing Description OD(in) ID(in) Top(RKB) Set Depth(MB) Set Depth(ND)...WtlLen(I..'Grade Top Thread �, nu11 LINER 41/2 3.958 7,359.6 8,095.0 6,676.8 12.60 L-80 NSCT Liner Details Nominal ID Top(RKB) Top(TVD)(BKB) Top Ind(') Item Des Com (in) 7,359.6 6,154.1 45.03 PACKER BAKER ZXP LINER PACKER&TIEBACK SLEEVE 5.000 7,381.7 6,169.6 45.11 HANGER BAKER HMC LINER HANGER • 5.000 CONDUCTOR;42.0-112.0-4 Tubing Strings NIPPLE;503.0 '� Tubing Description String Ma...ID(in) Top(ftKB) Set Depth itt..Set Depth(TVD)(...Wt(lb/ft) Grade Top Connection at TUBING I 4 1/21 3.9581 36.31 7,377.61 6,166.71 12.601 L-80 I NSCT Completion Details I Nominal ID Top IRKS) Top(TVD)(1tl(3)•Top lent('I Item Des Com (in) 36.3 36.3 0.00 HANGER FMC GEN V TUBING HANGER 4.500 503.0 503.0 0.29 NIPPLE CAMCO DB NIPPLE 3.813 I GAS LIFT,2566.2 7,325.9 6,130.2 44.92 NIPPLE CAMCO DB NIPPLE 3.750 7,364.3 6,157.3 45.05 LOCATOR BAKER LOCATOR 3.880 7,365.3 6,158.1 45.05 SEAL ASSY BAKER SEAL ASSEMBLY 3.880 Perforations&Slots I GAS LIFT;4.016.6 -' Dens Top(TVD) B6n(TVDI (shots/f Top(MB) Btm(ftKB) (111(B)) MB)) Zona Date 8 Type Corn 7,713.0 7,753.0 6,401.8 6,430.0 Com,1C-18 3/3/2002Dent 6.0 APERF 2 7/8"HSD PJ Chgs,60 deg ph I 7,753.0 7,783.0 6,430.0 6,451.1 C 4,C 3,1C- -4/2/1999 4.0 IPERF 2 7/8"HC/DP 180 deg i SURFACE;40.74,8166-A Mandrel Inserts 18 ph+/-80 deg from low side • St aR on Top(TVD) Valve Latch Port Size TRO Run II N Top(RKB) (ftKB) Make Model OD lin) Sen Type n) (psi) GAS LIFT;5.237.4 {' 2,586.2 2,582.6 CAMCO KBG2L 1 GAS LIFT DMY INTType (I 0.000 0.0 28Run7/1999Date Com S 2 4,016.6 3,783.1 CAMCO KBG2L 1 GAS LIFT DMY INT 0.000 0.0 2/21/1999 S 3 5,237.4 4,641.7 CAMCO KBG2L 1 GAS LIFT DMY INT 0.000 0.0 2/21/1999 I S GAS LIFT;6,061.31 4 6,061.3 5,245.3 CAMCO KBG2L 1'GAS LIFT DMY INT 0.000 0.0 2/21/1999 5 6,763.1 5,739.7 CAMCO KBG2L 1 GAS LIFT DMY INT 0.000 0.0 2/21/1999 S 6 7,279.6 6,097.3 CAMCO KBG2L 1 GAS LIFT DMY INT 0.000 0.0 2/21/1999 OAS UFT;6,763.1 Notes:General&Safety End Dote Annotation 5!3/2000 S NOTE:WELL CONVERTED FROM PRODUCER TO INJECTOR -- 1/11/2011 NOTE:View Schematic w/Alaska Schematic9.0 GAS LIFT;7.279.6 i . NIPPLE;7,325.9 I li I LOCATOR.73603 - -- SEAL ASSY 7 365 3 5 i .'t PRODUCTION;45.57,576.0-A A t APERF;7,713.0-7,753.0--. IPERF;7,753.07,783.0 -f - I LINER;7,359.66,085.0 1 Wallace, Chris D (DOA) From: NSK Problem Well Supv <n1617@conocophillips.com> Sent: Wednesday, March 25, 2015 9:13 AM To: Wallace, Chris D (DOA) Cc: Senden, R. Tyler; NSK Problem Well Supv Subject: 1C-18 (PTD 199-005) IA pressure increase Attachments: image001.png; 1C-18 Schematic.pdf; 1C-18 90 day TIO.JPG Chris- Kuparuk Injector 1C-18 (PTD 199-005)was reported by operations with an unexplained increase in IA pressure. The increase in pressure was originally thought to be caused by the increase in injection rate but operations conducted an unsuccessful bleed attempt. The well was shut in and freeze protected at that time. Initial diagnostic testing will be scheduled as soon as reasonably possible. Depending on the outcome of the initial diagnostics the proper notifications for continued injection or repair will be submitted. Please let me know if you have any questions or disagree with this plan. Attached is a copy of the well schematic and 90 day TIO plot. Dusty Freeborn/Jan Byrne Problem Wells Supervisor ConocoPhillips Alaska, Inc. Office phone: (907)659-7126 Cell phone: (907)943-0450 4INWELLS TEAM Conocamip, SCANNED .� ;ti), 1 KUP INJ 1C-18 ConocoPhillips Well Attributes Max Angle&MD TD Alaska,InC. Wellbore API/UWI Field Name Wellbore Status Inc!(1 MD(EBB) Act Bye(ftKB) /otrrrrfte1ast 500292293900 KUPARUK RIVER UNIT INJ 47.80 6.700.52 8.095.0 ... Comment 1125(ppm) Date Annotation End Date KB-Grd(ft) -Rig Release Date 1C-18.8/6/20148:37:59 AM SSSV:NIPPLE Last WO. 46.51 2/21/1999 Vertical schematic(actual) Annotation Depth(MB) End Date Annotation Last Mod By End Date ............................................................ Last Tag:CTMD 7855.0 6/4/2014 Rev Reason:TAG hipshkf 6/6/2014 HANGER;38.3 11.5r.11.1 Casing Strings Casing Description OD(in) ID(in) Top(EBB) Set Depth(ftKB) Set Depth)TVD)... Wt/Len(l...Grade Top Thread CONDUCTOR 16 15.062 42.0 112.0 112.0 62.58 H-40 WELDED Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) 'Set Depth(ND)...Wt/Len(I...Grade -Top Thread 111 IE t SURFACE 95/8 8.835 40.7 4,816.6 4,3429 40.00 L-80 _BTC Casing Deseription OD(in) ID(in) Top(EBB) -Set Depth(ftKB) :Set Depth)TVD)... Wt/Len(I...Grade Top Thread PRODUCTION _ 7 6.276 45.5 7,578.0 6,307.5 26.00 L-80 -Top Casing Description OD(in) ID(in) Top(EBB) Set Depth(EBB) "Set Depth)TVD)... Wt/Len(I...Grade Top Thread 1e „ aea.LINER 41/2 3.958 7,359.6 8,095.0 6,676.8 12.60 L-80 NSCT � Liner Details Nominal ID Top(ftKB) Top)TVD)(ftKB) Top Incl(°) Item Des I Com (in) 7,359.6 6,154.1 45.03 PACKER BAKER ZXP LINER PACKER 8 TIEBACK SLEEVE 5.000 a'''' 7,381.7 6,169.6 45.11 HANGER BAKER HMC LINER HANGER 5.000 CONDUCTOR;42.0-112.0-e Tubing Strings NIPPLE;503.0 Tubing Description 'String Ma...11D(in) !Top(kKB) !Set Depth(ft..l Set Depth(ND)(...I Wt(Ib/ft) "Grade 'Top Connection to TUBING 41/2 3.958 36.3 7,377.61 6,1667 12.60 L-80 NSCT I Completion Details Nominal ID Top OMB) Top(ND)VOW) Top Incl(°) Item Des Com )in) 36.3 36.3 0.00 HANGER FMC GEN V TUBING HANGER 4.500 503.0 503.0 0.29 NIPPLE CAMCO DB NIPPLE 3.813 GAS car/ see 7,325.9 6,130.2 44.92 NIPPLE CAMCO DB NIPPLE 3.750 7,364.3 6,157.3 45.05 LOCATOR BAKER LOCATOR 3.880 7,365.3 6,158.1 45.05 SEAL ASSY BAKER SEAL ASSEMBLY 3.880 I Perforations&Slots Shot GAS LIFT;4,016.8 Dena Top(TVD) BM(ND) (shotsM Top(ftKB) BM(ftKB) (NK8) 011(B) Zone Data t) Type Com 7,713.0 7,753.0 6,401.8 6,430.0'C-4,1C-18 '3/3/2002 6.0 APERF 2 7/8"HSD PJ Chgs,60 deg ph 7,753.0 7,783.0 6,430.0 6,451.1 C 4,C 3,1C- 4/2/1999 4.0 IPERF 2 7/8"HC/DP 180 deg 18 ph+/-80 deg from low Side SURFACE;40.7-4,816.6�. Mandrel Inserts st ao Top)ND) Valor Latch Pon Size TRO Run a N Top(kKB) (ftKB) Make Model _OD(in) Sery Type Typo (in) (psi) Run Date Corn GAS LIFT;5,237.4 fi 2,586.2 2,582.6 CAMCO KBG2L 1 GAS LIFT DMY INT 0.000 0.0 2/21/1999 S • • 2 4,016.6 3,783.1 CAMCO KBG2L 1 GAS LIFT DMY INT 0.000 0.0 2/21/1999 S 3 5,237.4 4,641.7 CAMCO KBG2L ' 1'GAS LIFT DMY INT 0.000 0.0'2/21/1999 S GAS LIFT'B4O81a 4 6,061.3 5,245.3 CAMCO KBG2L 1'GAS LIFT DMY INT ' 0.000 0.0 2/21/1999 S 5 6,763.1 5,739.7 CAMCO KBG2L 1-GAS LIFT DMY INT 0.000 0.0 2/21/1999 S 6 7,279.6 6,097.3 CAMCO KBG2L 1 GAS LIFT DMY INT 0.000 0.0 2/21/1999 S GAS LIFT;6,763 1 Notes:General&Safety • End Date Annotation 5/3/2000 NOTE:WELL CONVERTED FROM PRODUCER TO INJECTOR r. - 1/11/2011 NOTE:View Schematic w/Alaska Schematic9.0 GAS LIFT;7,270.8 1 • NIPPLE;7,325.0 _ s LOCATOR,7,3643 SEAL ASSY,7,365.3 11 ff a• 11=1 e PRODUCTION;45.6-7,578.0- APERF;7,713.0-7,753.0 IPERF;7,753.0-7,783.0 LINER;7,359.8-0,095.0 tu Y cc ti w N C7 x w N Q U N W cc a.. u . N w w K s a v d ry ry N Z y W m N W tY o a o r I- rV I- an u, W o 2 ry p L7'34 r> G —1 0 J J ,6 ap u, el r-,-. N O o o O o 0, m r- u> u,u, I I I I I 1 I I 1 L - - w u. 0m no u, 1Y. t_m w LI u, N a W b C2 c........-"...-.."'- -'3 4 7 GO U J InC C 4 R "......3v5 C G , 0 u, N V A a- w a 01 '3 Z C u• .'> a to to v. u 1 a m Cop O , N O N o N r N f"Y a •y► i t d e 4. G7 1 1 1 1 S E :: 0! I ,�, 1: t: >: I: K >: t: t: t: ,. a> 04 (d R o 0 0 o 0 0 0 0 0 o p K L P 6 K V K K t7 O CI U', 0 UJ O ui 0 ui 0 U) aiU V[a9 t N o d c, M N N CI) CO l4 C i$d N 0 W XHVZE Pages NOT Scanned in this Well History File This page identifies those items that were not scanned during the initial scanning project. They are available in the original file and viewable by direct inspection. /~C~ ,., ~')5 File Number of Well History File PAGES TO DELETE RESCAN ~~Col'or items - Pages: Complete Grayscale, halftones, pictures, graphs, charts- Pages: Poor Quality Original- Pages: [] Other- Pages: DIGITAL DATA [] Diskettes, No. [] Other, No/Type OVERSIZED [] Logs of various kinds [] Other COMMENTS: Scanned by: Bevedy Mildred Daretha~owell Date: ,~/...~ TO RE-SCAN Notes: Re-Scanned by~ildred Daretha Nathan Lowell Date:q~.2~l~ ~,~ ~.~lsl ~ • • ConocoPhillips Alaska 1 �'�! �, �;-', , ,. „- P.O. BOX 100360 r `: `Y ANCHORAGE, ALASKA 99510 -0360 WAR 9 March 9, 2012 44y h t3 A `? � Alaska 011 & Gas Cons. Commission Anchorage Commissioner Dan Seamount Alaska Oil & Gas Commission 333 West 7 Avenue, Suite 100 (q 61_ C 0'5 Anchorage, AK 99501 Commissioner Dan Seamount: Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRU). Each of these wells were found to have a void in the conductor. These voids were filled with cement and corrosion inhibitor, engineered to prevent water from entering the annular space. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treatments took place and meets the requirements of form 10 -404, Report of Sundry Operations. The cement was pumped in the fall of 2011. The corrosion inhibitor /sealant was pumped on various days in January and February 2012. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please call MJ Loveland or Martin Walters at 907 - 659 -7043, if you have any questions. Sincerel MJ oveland ConocoPhillips Well Integrity Projects Supervisor • • • ConocoPhamps P laska 1' c" Surface Casing by Conductor Annulus Cement, Corrosion Inhibitor, Sealant Top -off Report of Sundry Operations (10 -404) Kuparuk Field Date 3-09 -2012 1B, 1C, 113, 1 E PAD Corrosion Initial top of Vol. of cement Final top of Cement top off Corrosion inhibitor/ Well Name API # PTD # cement pumped cement date inhibitor sealant date ft bbls ft gal 18-02 50029205310000 1801330 SF NA 16" NA 2.98 1/21/2012 1B-06 50029206030000 1810750 8' 1.50 5'6" 9/11/11 18 1/21/2012 WSW-04 50029208330000 1821590 6'4" 1.30 24" 9/11/11 6.8 1/21/2012 WSW-06 50029208510000 1821770 20" NA ' 20" NA 2.13 1/21/2012 1C -11 50029227140000 1961720 SF 1.50 22" 9/11/11 4.68 2/10/2012 /� 1C -18 50029229390000 1990050 SF ' NA 18" NA 2.55 2/10/2012 I" 1C-26 50029229440000 1990510 SF NA 18" NA 3.75 2/10/2012 10-128 50029229000000 1981330 2" NA 26" NA 3.83 2/10/2012 • MEMORANDUM TO: Jim Regg ~~,~ ~ ~Z~ ,ID P.I. Supervisor ~ t FROM: John Crisp Petroleum Inspector State of Alaska Alaska Oil and Gas Conservation Commission DATE: Tuesday, May 25, 2010 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 1C-18 KUPARLIK RIV UNIT 1C-18 Src: Inspector NON-CONFIDENTIAL Reviewed By: P.I. Suprv ~R2- Comm Well Name: KUPARUK RIV UNIT IC-18 API Well Number: 50-029-22939-00-00 Inspector Name: John Crisp Insp Num: mitJCr100524060554 Permit Number: 199-005-0 Inspection Date: 5/21/2010 Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well~C-1 T pe Inj. ~' "~ TVD~ 6lss ~ ~ IA ~--- 1539 i OA P.T.D 90050 'ITYpCTCSt SPT Test psi ~ 9so zzao 500 360 ~ z2oo 500 zl9o '' 500 ~ _ ~ i - 1702 ~ 1694 1701 1692 TUb ng InteCVal 4YRTST P~F P ~ ~ _ - Notes: 1.2 bbls pumped for test. No problems witnessed. ,, ,,+:_. Tuesday, May 25, 2010 Page ] of 1 12/30/08 (--~~ k' '"` }.. `.,~ `~ Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth f y' - (~ N0.5024 f~ fC(?r ~1 I~ C1 ~~ Well Job # Log Description Company: Alaska'-Oil' & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Kuparuk Date BL Color CD 2U-03 12080460 INJECTION PROFILE '(' ~j 11/17/08 1 1 1Y-03 12096583 INJECTION PROFILE 'j - 12/07/08 1 1 iC-11 12114998 PRODUCTION PROFILE ~ a 12/14/08 1 1 1 D-07 12114999 USIT ._ a 12/15/08 1 1 1 B-09 12115001 INJECTION PROFILE L ~ 12/18/08 1 1 3G-26 12115002 WEATHERFORD WRP/SBHP 12/19/08 1 1 iC-18 12100472 INJECTION PROFILE 12/21/08 1 1 1 E-21 12115005 INJECTION PROFILE Q 12/22/08 1 1 2C-02 12100475 INJECTION PROFILE V ~ 7j 12/24/08 1 1 r I. J Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. . . ConocóPhillips Alaska RECEIVED AUG 2 9 2007 Alaska Oil & Gas Cons. Commission Anchorage P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 August 23, 2007 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 Anchorage, AK. 99501 lC\q- OD5 scANNED SE? 0 6 2007 Dear Mr. Maunder: . Enclosed please find a spreadsheet with a list of wells trom the Kuparuk field (KRU). Eacþ: of these wells was fôund to have a void in the conductor. These voids were filled with a corrosion inhibitor, engineered to prevent water trom entering the annular space. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treatments took place and meets the requirements of form 10-404, Report of Sundry Operations. The corrosion inhibitor/sealant was pumped between August 19 & 21, 2007. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please call me at 907-659-7043, if you have any questions. Æ4~~ M.J.¿el~d ConocoPhiIlips Well Integrity Projects Supervisor . . ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) Kuparuk Field Date 8/21/2007 Corrosion Initial top of Vol. of cement Final top of Cement top off Corrosion inhibitor/ Well Name PTO# cement pumped cement date inhibitor sealant date - ft bbls ft Qal 1 0-28 204-237 18" N/A N/A N/A 10 8/19/2007 10-30 200-104 24" N/A N/A N/A 6.5 8/19/2007 10-34 200-143 14" N/A N/A N/A 4 8/19/2007 10-12 199-084 1" N/A N/A N/A 1.7 8/20/2007 10·14 199-089 2" N/A N/A N/A 3.4 8/20/2007 10-140 200-136 29'9" 3.4 12" 12/16/2006 14.5 8/20/2007 10-141 200-112 SF N/A N/A N/A 0.5 8/20/2007 ·1C-11 199-172 ~SF NA NA NA 0.5 8/21/2007 1C-12 196-177 SF NA NA NA 0.5 8/21/2007 1C-15 198-229 SF NA NA NA 0.5 8/21/2007 1C-16 198-246 22" NA NA NA 8 8/21/2007 1C-17 198-224 17" NA NA NA 1.7 8/21/2007 1C-18 199-005 SF NA NA NA 0.5 8/21/2007 1C-24 201-248 20" NA NA NA 11 8/21/2007 1C-26 199-051 3" NA NA NA 0.85 8/21/2007 1 C-27 199-043 4" NA NA NA 1.7 8/21/2007 1C-28 205-104 SF NA NA NA 0.5 8/21/2007 1C-117 201-121 26" NA NA NA 12.3 8/21/2007 MEMORANDUM e State of Alaska e Alaska Oil and Gas Conservation Commission TO: Jim Regg 'K.saCc ~/J(c{()t P.I. Supervisor l l ' DATE: Tuesday, May 09, 2006 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC lC-18 KUPARUKRIV UNIT IC-18 O(l5:-~' \ ql!f' FROM: Jeff Jones Petroleum Inspector Src: Inspector Reviewed By: P.I. Suprv J5iZ- Comm NON-CONFIDENTIAL Well Name: KUPARUK RIV UNIT IC-18 API Well Number 50-029-22939-00-00 Inspector Name: Jeff Jones Insp Num: miUJ060508175629 Permit Number: 199-005-0 Inspection Date: 5/8/2006 ReI Insp Num Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. _._~~ I --~ Well IC-18 IT I· I w !TVD 6158 I IA 200 2800 2800 2800 I I ype nJ., i I P.T. I 1990050 ITypeTest I SPT I Test psi 1539.5 i OA 300 600 600 600 I " Interval 4YRTST P/F P Tubing I 2062 2061 i 2061 2062 - Notes 1.4 bbls diesel pumped, I well house inspected; no exceptions noted. ;:jÇ¿\NNEJ), "': ) r)í1rQ ;: /~~ [...';'·.)U ..,,~ ..,.. Tuesday, May 09, 2006 Page I of I e (lPHILLIPS Alaska, Inc. ~ A Subsidiary of PHilLIPS PETROLEUM COMPANY e KRU 1C-18 TUBING 1C-18 (0-7365, API: 500292293900 Well Tvpe: INJ Angle @ TS: 45 deg @ 7712 00:4.500, SSSV Type: NONE Orig 2/21/1999 Angle @ TD: 43 deg @ 8095 10:3.958) Completion: Annular Fluid: SW/DSL Last WID: Rev Reason: Drift&Tag, PERF bvlmO Reference Loa: Ref Loa Date: Last Update: 4/10/2002 , Last Taa: 7763 TD: 8095 ftKB Last Taa Date: 3/2/2002 Max Hole Anale: 48 dea (á) 6701 Casing String - ALL DescriDtion Size TOD Bottom TVD Wt Grade Thread CONDUCTOR 16.000 0 112 112 62.58 H-40 WELDED SURFACE 9.625 0 4817 4343 40.00 L-80 BTC-MOD PRODUCTION 7.000 0 7578 6307 26.00 L-80 BTC-MOD I LINER 4.500 7360 8095 8095 12.60 L-80 NSCT Tubina Strina - ALL Size TOD I Bottom I TVD I Wt I Grade I Thread 4.500 I 0 I 7365 I 6158 I 12.60 I L-80 I NSCT Peñorations Summarv Interval TVD Zone Status Ft SPF Date Type Comment 7713 - 7753 6402 - 6430 C-4 40 6 3/3/2002 APERF 27/8" HSD PJ Chgs, 60 deg ph 7753 - 7783 6430 - 6451 C-4,C-3 30 4 4/2/ 1999 IPERF 27/8" HC/DP 180 deg ph +/- 80 deg from low side Gas Lift MandrelsNalves St MD TVD Man Man VMfr V Type VOD Latch Port TRO Date Vlv Mfr Type Run Cmnt 1 2577 2574 CAMCO KBG2LS CAMCO DMY 1.0 INT 0.000 0 2/21/1999 2 4017 3783 CAMCO KBG2LS CAMCO DMY 1.0 INT 0.000 0 2/21/1999 3 5237 4642 CAMCO KBG2lS CAMCO DMY 1.0 INT 0.000 0 2/21/1999 4 6061 5244 CAMCO KBG2LS CAMCO DMY 1.0 INT 0.000 0 2/21/1999 5 6763 5740 CAMCO KBG2LS CAMCO DMY 1.0 INT 0.000 0 2/21/1999 6 7280 6098 CAMCO KBG2LS CAMCO DMY 1_0 INT 0.000 0 2/21/1999 Other I 31uas, eauiD., etc. - JEWELRY Depth TVD TVDe Description ID i 503 503 NIP CAMCO DB NIPPLE 3.813 7326 6130 NIP CAMCO DB NIPPLE. 3.750 7365 6158 SEAL BAKER SEAL ASSY 3.750 , I - Perf - (7713-7753) - - - Perf - (7753-7783) i - - \ ... ~ ') ) Mike Mooney Wells Group Team Leader Drilling & Wells ConocóP'hillips P. O. Box 100360 Anchorage, AK 99510-0360 Phone: 907-263-4574 November 22, 2004 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Subject: Report of Sundry Well Operations for 1 C-18 (APD # 199-005) Dear Commissioner: ConocoPhillips Alaska, Inc. submits the attached Report of Sundry Well Operations for the recent stimulation operation on the Kuparuk well 1 C-18. If you have any questions regarding this matter, please contact me at 263-4574. Sincerely, M,AIl~ M. Mooney Wells Group Team Leader CPAI Drilling and Wells MM/skad SCANNED NO\} 2 ti 2D04 (' ~ NAL LJI ) ) STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS RepairWell 0 Pull Tubing 0 Operat. ShutdownO ~2004 .[3 Time Extension 0 Re-enter Suspended Well 0 5. Permit to Drill Number: 199-005 1 6. API Number: 50-029-22939-00 Stimulate 0 Waiver D 1 dti¡e~: Abandon D Alter Casing D Change Approved Program D 2. Operator Name: ConocoPhillips Alaska, Inc. 3. Address: P. O. Box 100360, Anchorage, Alaska 7. KB Elevation (ft): RKB 102' 8. Property Designation: ADL 25649, ALK 467 11. Present Well Condition Summary: 1. Operations Performed: Total Depth Effective Depth Casing Structural CONDUCTOR SURFACE PRODUCTION LINER Perforation depth: Plug Perforations 0 Perforate New Pool D Perforate D 4. Current Well Status: Development D Stratigraphic D Exploratory D Service 0 9. Well Name and Number: 1 C-18 10. Field/Pool(s): Kuparuk River Field 1 Kuparuk Oil Pool measured 8095' feet true vertical 6677' feet measured 7763' feet true vertical 6440' feet Length Size MD 112' 16" 112' 4715' 9-5/8" 4817' 7476' 7" 7578' 735' 4-1/2" 8095' Plugs (measured) Junk (measured) TVD Burst Collapse 112' 4343' 6307' 6677' Measured depth: 7713'-7783' true vertical depth: 6402'.6451' Tubing (size, grade, and measured depth) 4-1/2" , L-80, 7365' MD. Packers & SSSV (type & measured depth) no packer Cameo DB @ 503' 12. Stimulation or cement squeeze summary: Intervals treated (measured) 7713'-77831 13. Treatment descriptions including volumes used and final pressure: Representative Daily Average Production or Injection Data Gas-Met Water-Bbl n/a 2361 3077 15. Well Class after proposed work: Exploratory D Development D Service 0 16. Well Status after proposed work: OilO GasD WAG 0 GINJD WINJ D 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: 713 bbls of slick seawater Oil-Bbl n/a Casinq Pressure TubinQ Pressure 1851 1572 Prior to well operation Subsequent to operation 14. Attachments Copies of Logs and Surveys run - Daily Report of Well Operations _X Contact Printed Name Signature WDSPLD Mike Mooney @ 263-4574 Mike Mooney RBDMS 8FL NOV 2 2 2004 Kuparuk Wells Team Leader Date 1( }-¿¿/ Ó 1 Prepared b~ Sharon Allsup-Drake 263-4612 ~AI¡' ;J{ ~ Title Phone ¡GI~JAL Form 10-404 Revised 04/2004 Submit Original Only ') ) 1C-18 Well Events Summary Date Summary 10/30/04 POOR BOY HPBD COMPLETED. PUMPED 713 BBLS OF 55 DEGREE SLICK SEAWATER. MAXWHTP 3050 PSI AND MAX RATE 11.6 BPM. RETURNED WELL TO PW INJECTION POST BREAKDOWN. [HPBD] ') PHilliPS Alaska, Inc. A Subsidiary of PHilLIPS PETROLEUM COMPANY TUBING 11 ' 1C-18 (0-7365. API: 500292293900 OD:4.500. SSSV Type: NONE ID:3.958) Annular Fluid: SW/DSL !. \' ' j ;: ., . ~ t :. [I ; .. , .. .11' :~j Perf (7713-7753) Perf (7753-7783) ~ ; I ¡ : ~ ) KRU 1 C-18 Well Type: INJ Orig 2/21/1999 Completion: Last W/O: Angle @ TS: 45 deg @ 7712 Angle @ TD: 43 deg @ 8095 Ref Log Date: TD: 8095 ftKB Max Hole Angle: 48 deg @ 6701 Rev Reason: Drift &Tag, PERF bylmO Last Update: 4/10/2002 Reference Log: Last Tag: 7763 Last Tag Date: 3/2/2002 Casing String - ALL Description CONDUCTOR SURFACE PRODUCTION LINER Tubing String - ALL Size Top 4.500 Wt 62.58 40.00 26.00 12.60 Grade H-40 L-80 L-80 L-80 Thread WELDED BTC-MOD BTC-MOD NSCT Size 16.000 9.625 7.000 4.500 Top 0 0 0 7360 Bottom 112 4817 7578 8095 TVD 112 4343 6307 8095 Interval TVD 7713 -7753 6402 - 6430 Status Ft SPF Date Type Comment 40 6 3/3/2002 APERF 27/8" HSD PJ Chgs, 60 deg ph 30 4 4/2/1999 IPERF 2 7/8" HC/DP 180 deg ph +1- 80 from low side Zone C-4 7753 - 7783 6430 - 6451 C-4,C-3 St MD TVD Man Man V Mfr V Type VOD Latch Port TRO Date Vlv Mfr Type Run Cmnt 1 2577 2574 CAMCO KBG2LS CAMCO DMY 1.0 INT 0.000 0 2/21/1999 2 4017 3783 CAMCO KBG2LS CAMCO DMY 1.0 INT 0.000 0 2/21/1999 , 3 5237 4642 CAMCO KBG2LS CAMCO DMY 1.0 INT 0.000 0 2/21/1999 4 6061 5244 CAMCO KBG2LS CAMCO DMY 1.0 INT 0.000 0 2/21/1999 5 6763 5740 CAMCO KBG2LS CAMCO DMY 1.0 INT 0.000 0 2/21/1999 6 7280 6098 CAMCO KBG2LS CAMCO DMY 1.0 INT 0.000 0 2/21/1999 Other (,lugs, equip., etc.: - JEWELRY Depth TVD Type Description ID 503 503 NIP CAMCO DB NIPPLE 3.813 7326 6130 NIP CAMCO DB NIPPLE. 3.750 7365 6158 SEAL BAKER SEAL ASSY 3.750 ... MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: DATE: Wednesday, June 02, 2004 SlJBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC IC-18 KUPARUKRIVUNIT IC-18 Jim Regg ?t~" b/7 {O;" P.I. Supervisor ( ( FROM: Chuck Scheve Petroleum Inspector Iqq- ()~ Src: Inspector NON-CONFIDENTIAL Well Name: KUPARUK RIV UNIT IC-I8 API Well Numbe 50-029-22939-00-00 Inspector Name: Permit Number 1990050 Inspection Date: Reviewed By: P.I. Suprv :'J8C---- Comm Chuck Scheve 5/30/2004 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well: IC-18 Type Inj. P TVD 6677 IA 500 2500 2430 2420 P.T. 1990050 !ype~~st SPT Test psi 1539.5 OA 520 760 710 700 --- Interval 4YRTST P/F P Tu bing 1850 1850 1850 1850 Notes: The pretest pressures were observed for 30+ minutes and found stable. Well demonstrated good mechanical integrity. Wednesday, June 02, 2004 Page 1 of 1 Annular Disposal during the second quarter of 2003: h(1) h(2) h(3) Total for Freeze Previous New Start End Source Wells Well Name Volume Volume Volume Quarter Protect Total Total Date Date Volumes 3S-10 9972 100 0 10072 388 21204 31664 March April 3S-21, 3S-08, 3S-23 2003 2003 1C-22 21553 100 0 21653 0 27044 48697 March May 1C-190, 1C-174, 1C-178, 1C-19 2003 2003 Puviaq #1 5063 100 0 5163 0 4731 9894 March April Puviaq 1 2003 2003 CD2-46 31393 100 0 31493 371 0 31864 April May 2003 CD2-51, CD2-12 2003 3S-16 31006 100 0 31106 357 0 31463 April May 2003 3S-23, 3S-17, 3S-06, 3S-16 2003 Hansen 1 47382 100 0 47482 0 67796 115278 January June 2003 Hansen, Hansen lA 2002 1C-19 31325 100 0 31425 0 0 31425 May 2003 June 2003 1C-184, 1C-170, 1C-172 3S-08B 31610 100 0 31710 290 0 32000 May 2003 June 2003 3S-24, 3S-03, 3S-19 CD2-19 30860 100 0 30960 377 0 31337 May 2003 June 2003 CD2-58, CD2-52 CD2-41 3900 100 0 4000 377 0 4377 June 2003 June 2003 CD2-20 3S-17A 4559 100 0 4659 361 5020 5020 June 2003 June 2003 3S-19 Total Volumes into Annuli for which Disposal Authorization Expired during the second quarter 2003: ~ ~ Freeze Pl~otect To~al Volume ~ Start End Source Wells Total h(1) Total h(2) Total h(3) Fluids Injected Date Date Well Name Volume Volume Volume Volume Status of Annulus CD2-17 17709 100 0 372 18181 Open, Freeze Protected May 2002 Feb 2003 CD2-08, CD2-48, CD2- 46 CD2-32 31337 100 0 379 31816 Open, Freeze Protected June 2002 July 2002 CD2-19, CD2-41, CD2- 23 CD2-50 31530 100 0 370 32000 Open, Freeze Protected July 2002 Sept 2002 CD2-41, CD2-35 1D-11 32102 100 0 235 32437 Open, Freeze Protected May 2002 June 2002 1D-103 1C-18 32251 100 0 373 32724 Open, Freeze Protected June 2002 July 2002 1C-104 SCANNEU"JUL 6 200 . Kuparuk and Alpine Annular Disposal during the third quarter of 2002: h(1) h(2) h(3) Total f~r Freeze Previous New Start End Source Wells Well Name Volume Volume Volume Quarter Protect Total Total Date Date Volumes CD2-32 12701 100 0 12801 379 18636 31816 June 2002 July 2002 CD2-19, CD2-23, CD2-41 CD2-50 31530 100 0 31630 370 0 32000 July2002 Sept2002 CD2-41, CD2-19, CD2-16, CD2-38 112-18 27969 100 0 28069 379 4276 32724 June 2002 July 2002 1C-104 CD2-39 1966 100 0 2066 379 27500 29945 Oct. 2OOl Sept 2002 CD2-15, CD2-47, CD2-44 CD2-15 10459 100 0 10559 371 20722 31652 March Sept 2002 CD2-50, CD2-25, CD2-44 2002 CD2-26 13802 100 0 13902 380 0 14282 Sept 2002 Sept2002 CD2-38, CD2-44, CD2-29 Cook Inlet Annular Dis ~osal during the third ~,,uarter of 2002: h(1) h(2) h(3) Total for Freeze Previous New Start End Source Wells Well Name Volume Volume Volume Quarter Protect Total Total Date Date Volumes Hansen #1 52255 100 0 52355 0 14869 67224 January Sept 2002 Hansen #1 2002 Total Volumes into Annuli for which Disposal Authorization Expired during the third quarter 2002: J ~ ~ h-' Freeze Protect Total Volum Start End Source Wells Total h(1) Total h(2) Total h(3) Fluids Injected Date Date Well Name Volume Volume Volume Volume Status of Annulus CD2-24 33524 100 0 375 33999 Open, Freeze Protected July 2001 Oct 2001 CD2-33, CD2-39, CD2- 14, CD2-15 1C-26 34160 100 0 0 34260 Open, Freeze Protected August September 1C-123, 1C-119, 1C-102 2001 2001 2N-332 31453 100 0 325 31878 Open, Freeze Protected August 2001 Sept 2001 2N-348, 2N-350 1C-16 32017 100 0 0 32117 Open, Freeze Protected Sept 2001 Oct 2001 1C-102, 1C-131, 1C-125 [tECEIVED OCT 2 4 2002 .~1aska Oil& Bas Oons. Commission anehora~ %,~ STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSIO~' REPORT OF SUNDRY WELL OPERATIONS .::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::: .............. ' .............................. :::::::::::::::::::::::::::::::::::::::::::::::::: "' :::::::::::::::::::::::::: :::::::::::::: :: ::: ::::"::: ::::::::::::::::::::::::::::::::::::::::::::::::::: ................... ::' ::': ::::71: :t::.::::: :: :::::::::~: ~i'~¢~t~.....~..~;< ~,t:::F::~:r-:<~-.:<:~::::;::::..:::<:::: :~!::::7::;: ::::::::::::::::::::::::::::::::::::: :::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::: ::': :::::~:~" .................... 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB feel} . Phillips Alaska, Inc. Development__ FIKB 102 feet $. Address Explorato~/_ 7. Unit or Property name P. O. Box 100360 Stratigraphic__ .A_ nchora~le, AK 99510-0360 Service_x Kuparuk Unit 4. Location of well at surface 8. Well number 1476' FNL, 4268' FEL, Sec. 12, T11 N, R 10E, UM (asp's 562016, 5968759) 1 O-18 ,,,, At top of productive interval '"9. Permit number / approval number 849' FSL, 1455' FEL, Sec. 2, T11N, R10E, UM 199-005/ At effective depth 10. APl number 50-029-22939 At total depth 11. Field / Pool 4233' FNL, 1638' FEL, Sec. 2, T11 N, R10E, UM (asp's 559346, 5971260) Kuparuk Oil Pool 1' 2. Present well condition summary Total depth: measured 8095 feet Plugs (measured) true vertical 6677 feet Effective depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented Measured Depth True vertical Depth CONDUCTOR 112' 16" 9 cu yds High Early 112' 112' SURFACE 4715' 9-5/8" 820 sx AS III LW, 550 sx Class G 4817' 4343' PRODUCTION 7476' 7" 170 sx Class G 7578' 6307' LIN ER 735' 4-1/2" 130 sx Class G 8095' 6677' LINER Perforation depth: measured i~i;~!iiiiii ii ii :il i!iiiiiii i !i il i! i ii}i~:ii~!iiii iil i i} i i!i i c:,~. Packers & SSSV (type & measured depth) 13. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes;U;;d';~i~;i:"~;;;~;;;;": ........................................... ";'":'~;":" 14. Representative Daily Average Production o.r. Iniection Data OiI-Bbl Gas~Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation ;:. ................... !?! :~.i; .:: :. ::.~ .. ;!)~i ::~!..~...,;::.~ !.!~!,,~ ~...! ?.i??. !i;.,~ ::;,,~,i!.!, iii;:~,, ,.:?.!i!!i!!i:. !::ii!iii! ?iiiiiiii?~}!iiii?}i~~. ?} il. iii::! ~-ii .:.:'; i ~:.: :15. Attachments Oopies of Logs and Surveys run __ Daily Report of Well Operations X ' ;::~ ~i'l i J; ~ :'i~:§ ! : i i ~6a:~' i : :i ~7. I hereby ce~~h~ fore~oi/ngis true. and correct to the best of my knowledge. Questions? Call Jeff Spencer659-7226 Signed /'//'~,r~ ~ (~ Title Production Engineering Technician Date Robert D. 6hristensen Prepare~t by Robert Ohristensen 659-7535 , SCANNED OCT 0 & 2002 Form 10-404 Rev 06/15/88 · ~P !~ 2O02 ORIGINAl. SUBMIT IN DUPLICATE 1C-18 DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary Annular Disposal during the second quarter of 2002' h(1) h(2) h(3) Total for Freeze Previous New Start End Source Wells Well Name Volume Volume Volume Quarter Protect Total Total Date Date Volumes CD2-15 10176 100 0 10276 371 10446 21093 March April CD2-25, CD2-50 2002 2002 2P-420 9479 100 0 9579 150 0 9729 April May 2002 2P-427, Heavenly 2002 2P-415A 26238 100 0 26338 52 4943 31333 March April 2P-431, 2P-422A, 2P-427, 2002 2002 Heavenly, Grizzly, 2P-441 CD2-49 27474 100 0 27574 386 0 27960 April May2002 CD2-46, CD2-22, CD2-50 2002 CD2-17 14962 100 0 15062 372 0 15434 May 2002 June 2002 CD2-48, CD2-46 ID-II 32102 100 0 32202 235 0 32437 May 2002 June 2002 1D-103 CD2-32 18536 100 0 18636 379 0 19015 June 2002 June 2002 CD2-19, CD2-41 1C-18 4176 100 0 4276 379 0 4655 June 2002 June 2002 1C-104 Total Volumes into Annuli for which Dis 9osal Authorization Expired during the second ,uarter 2002: ~ Freeze Protect Total Volume Start End Source Wells Total h(1) Total h(2) Total h(3) Fluids Injected Date Date Well Name Volume Volume Volume Volume Status of Annulus 1J-09 24202 100 0 330 24632 Open, Freeze Protected May 2001 May 2001 1J-10 1C-17 33139 100 0 160 33399 Open, Freeze Protected May 2001 June 2001 1C-133, 1C-121, 1C- 123, 1C-127 CD2-42 33507 100 0 385 33992 Open, Freeze Protected June 2001 October CD2-24, CD2-33, CD2- 2001 15 2P-417 30965 100 0 887 31952 Open, Freeze Protected October March 2P-422, Grizzly, 2P-451, 2001 2002 2P-441, 2P-448, 2P- 422A, 2P-420 1C-27 31766 100 0 153 32019 Open, Freeze Protected June 2001 July 2001 1C-127, lC-117, 1C- 111, 1C-123 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS :; ;::: ; ; ;;;]~ :; : :;: ; ::: Variance_ Perforate_ 2. Name of Operator Phillips Alaska, Inc. 3. Address P. O. Box100360 Anchoraqe, AK 99510-0360 5. Type of Well: Development __ Exploratory __ Stratigraphic __ Service__X 4. Location of well at surface 1476' FNL, 4268' FEL, Sec. 12, T11N, R10E, UM (asp's 562016, 5968759) At top of productive interval At effective depth At total depth 4233' FNL, 1638' FEL, Sec. 2, T11 N, R10E, UM (asp's 559346, 5971260) 6. Datum elevation (DF or KB feet) RKB 102 feet 7. Unit or Property name Kuparuk Unit 8. Well number 1C-18 9. Permitnumber/approvalnumber 199-005 10. APInumber 50-029-22939 11. Field / Pool Kuparuk Oil Pool Other _X ¢' Annular DispOsal 12. Present well condition summary Total depth: measured true vertical 8095 feet Plugs (measured) 6677 feet Effective depth: Casing Length Size CONDUCTOR 112' 16" SURFACE 4776' 9-5/8" PRODUCTION 7537' 7" LINER 735' 4-1/2" LINER Junk (measured) Cemented ;62o: sx ;AS;;III;LW, :550;s× Class G 130sxCta~SG::: : ::; ;;:; Measured Depth 112' 4817' 7578' 8095' True vertical Depth 112' 4343' 6307' 6677' Tubing (size, grade, and measured depth 4-1/2", 12.6#, L-80 Tbg @ 7365' MD. Packers & SSSV (type & measured depth) Np packer ~ CAMCO DB @ 503' MD. Anchorage BOP sketch __ 14. Estimated date for commencing operation ~;26i 2002 15. Status of well classification as: Oil __ Gas __ Service :WAG ,/ Suspended __ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed '~O.~ ,~~ Title: Kuparuk Drilling Team Leader Paul Mazzolim FOR COMMISSION USE ONLY Questions? Call Tom Brockway 263-4135 Date O~,/~..i / O Z_ Prepared by Sharon AIIsup-Drake 263-4612 Conditions of approval: Notify Commission so representative may witness [ Appr°va' n°~(~2 Plug integrity_ BOP Test __ Location clearance __ "" Mechanical Integrity Test __ Subsequent form required 10- Ong,na, S,,ned By ~.~ ~//~ Approved by order of the Commission Cafftm? Ocx-J~.~li T~ylnr Commissioner Date Form 10-403 Rev 06/15/88 · SUBMIT IN TRIPLICATE Annulus Disposal Transmittal Form Designation of the well or wells to receive drilling wastes: 1C-18 The depth to the base of freshwater aquifers and if present: No Aquifers / Base Permafrost = 1785' TVD RKB / stratigraphic description of the interval exposed to the From the 9-5/8" shoe to the Cement top all that is open open annulus and other information sufficient to su is Upper Cretaceous basal Schrader Bluff mudstones a commission finding that the waste will be confined and Shale Wall (Campanian). and will not come to the surface or contaminate freshwater. A list of all publicly recorded wells within one-quarter mile and all publicly recorded water wells within one mile of the well to receive drillino waste: See attached map indicating 1C-05 and 1C-09 are within 1/4 mile of 1C-18. There are no potable water wells within one mile of 1C-18. Identify the types and maximum volume of waste to be disposed of and the estimated density of the waste slurry: Types of waste can be drilling mud, drilling cuttings, cement-contaminated drilling mud, completion fluids, diesel, formation fluids associated with the act of drilling a well and any added water needed to facilitate pumping of drilling mud or drilling cuttings. Maximum volume to be pumped is 35,000 bbls. t An estimate of maximum anticipated pressure at the outer casing shoe during annular disposal operations and calculations showing how this value was determined: Maximum anticipated pressure at casing shoe during disposal operations is 1,839 psi. See attached calculation page. Details that show the shoe of the outer casing is set below the base of any freshwater aquifer and if present, and cemented with sufficient to provide zone isolation: See attached: cementing reports, LOT/FTT reports and casing reports for :tC-18. / Details that show the inner and outer casing strings ~have sufficient strength in collapse and burst to withstand anticipated pressure of disposal operations: See attached: casing summary sheet and calculation pages, r~ Any additional data required by the Commission to confirm containment of drillinq wastes: sCANNED' JUN 5 ?.007_ 1C-18 Annular Disposal Summary Well Name Original Completion Date Permafrost MD Permafrost TVD Surface Pipe Size Burst Rating Collapse Rating Surface Pipe MD Surface Pipe TVD Surface Pipe set in Formation Surface Top of Cement Surface Top of Tail Surface Pipe Test Pressure LOT 1 Depth (9-5/8" Shoe) LOT I EMW (9-5/8" Shoe) LOT 2 Depth (7" Shoe) LOT 2 EMW (7" Shoe) LOT 3 Depth (9-5/8"x7") LOT 3 EMW (9-5/8"x7") Long String Pipe Size Burst Rating Collapse Rating Long String Depth MD Long String TVD Long String Set in Formation Long String Top of Cement Long String Top of Tail Cement lC-18 Feb-99 1,785 1,785 9-5/8", 40#, L-80 5,750 3,090 4,817 4,343 162' TVD below the base of West Sak Surface 2,935 3,000 4837 MD, 4353 TVD 13.8`/ 7578 MD, 6308 TVD 15.1 / 4817 MD, 4343 TVD 13.4 ~ 7", 26#, L-80 7,240 5,410 7,578 6,307 Lower Kalubik 6,175' 6,175' 1C- 18 Annular Disposal Summary. xls prepared by Howard Gober 6/21/2002 Maximum Pressure @ The Shoe 1c-18 Surface Casinq: Size Weight Grade Shoe Depth Burst (100%) Burst (85%) 9-5/8 4O# L-80 4,817' MD / 4,343' TVD 5,750 psi 4,887 psi Assumptions: Water on Backside of 9-5/8" (Worst Case) 1,500 psi Maximum Injection Surface Pressure Maximum Mud Weight Required to Drill 1C-Pad West Sak Wells = 9.8 ppg Maximum Fluid Density to Burst 9-5/8" Casin.q: 4,887 psi + 8.3 ppg (.052) (4,343') = 1,500 psi + MW (.052) (4,343') MW = 23.3O ppg / Maximum Pressure on 9-5/8" Shoe: Max Pressure = 1,500 psi + 9.8 ppg (.052) (4,343') - 8.3 ppg (.052) (4,343') Max Pressure - 1,500 psi + 2,213 - 1,874 / Max Pressure = 1,839 psi ~ Maximum Fluid Density to Collapse 7" Casin.q 1c-18 Casing: Size Weight Grade Shoe Depth Collapse (100%) Collapse (85%) Assumptions: 11 26# L-80 7,578' MD / 6,308' TVD 5,410 psi 4,598 psi 9-5/8" Casing Shoe @ 4,343' TVD Inside 7" Casing - Diesel from 2,200' TVD to Surface (6.7 ppg) Inside 7" Casing - Seawater from 4,343' TVD to 2,200' TVD (8.4 ppg) Maximum Fluid Density to Collapse 7" Casinq: 4,598 psi + 6.7 ppg (.052) (2,200') + 8.4 ppg (.052) (4,343' - 2,200') = 1500 + MW (.052) (4,343) / MW - 21.26 ppg 00:4.500, AnnularFluid: Reference Lc SW/DSL 7763 3/2/2002 ID:3958) Well Type Orig Completion Last W/O: Ref LO9 Date TO Max Hole An,gle 8095 ftKB Rev Reason Drift &Tag, PERF r ImO Last Update 4/10/2002 Thread WELDED BTC-MOD BTC-MOD NSCT Thread NSCT Comment 2 2/8" HSD PJ Chgs, 60 2 7/8" HC/DP 180 deg ph from Iow side CAMCO DB NIPPLE CAMCO DB NIPPLE BAKER SEAL ASSY Description 3750 3 750 Perf ¢71~7753) SCANNED JUN g 5 200~ PRESSURE INTEGRITY TEST PHILLIPS Alaska, Inc..~ WellName: 1C-18 I Rig:~~Date: ~/5/6/19997 I Volumelnput Volume/Stroke I PumpRate: Drilling Supervisor' RL Morrison Pumpused' Other-see~co-lYi,~'n~ ~'1 : .... Strokes y 0.0750 Bbls/Strk Type of Test: Annulus Leak Off Test for Disposal Adequacy ~ Pumping down annulus '"' ~' ~, ' I ~ Casing Test I I Pressure Integrity Test Hole Size: USE P:[CK I_[ST I Casing Shoe Depth I Hole Depth I~ ~ ~1 Shut-in Casin,cI Size and Description: 9-5/8 40#/Ft L-80 BTC ~' I o[~.~.J I 0 30501 oJ.~.].~~ I 0 1250 Chanaes for Annular Adeauacv Test Pressure IntearitvTest 1 4L___.fl._._~ 1130241 7[~l~Z~l 0.25 Enter oute'~casing shoe test resdlts ii~ comments Mud Weight: . . 7.4 ppg I~ I~ 302311 44 Casing Description references outer casing string. Inner casing OD: ~ In. I ~ 13 302211 211 135011 1 1000 Hole Size is that drilled below outer casing. ! ~ 1~~~5 ~~I 12i~) Use estimated TOC for Hole Depth. Enter inner casing OD at right. Desired PIT EMW: 13.5ppgt~~987~~11 ~-Wl '~Ull ~' '""'°" '-' 'wv' Estimates for Test: ~ psi 0 bbls EMW = Leak-off Pressure + M-o~-Weight = 1350 PIT 15 Second ' --~ ~+ 7.4 Shut-in Pressure, psi I~1 lO 3o151~1 4.5~ EMWat4817Ft-MD(4343Ft-TVD)= 13.4~ Fill in FIT Columns ==> 1~~205~~1 5 750 3500 ~ - Lost 44 psi during test, held ~ 5.5 ' 6 700 -- 98.6% of test pressure., ' [~/~~3~~~1 6.5~ ,,, , F---I l 2000: / i ~, 6§0 ~ ~' ~ ~ ~ ~ ~ .:.:. 1000~ ,~ / :i!_.'.~:[:ii:~:.' $oo- / ~ ;?- o ~ 0 1 2 3 4 5~ ~ o ~ ,o ~ ~o ~ co /I Volume I Volume II Volume IIVoiume Barrels Shut-In time, Minutes ~=~I=~CASING TEST '-~I-'LEAK-OFF TEST O Pit Point / ~ ~ PumI~-~~! .... Bled Back / I 3.s BblS ~S~lS II 6.3 Bbls I~ems Comments: Test performed with Hot Oil Unit. -- -- LU:51. W~ I J:51 UUIIII~ L~L, II~IU -- - 98.6% of test pressure. -- ,;, -'.:i:ii:~:.' :::::::::::::::::::::::::::::: EASING TEST and FORMATION,INTEGRITY'TEST 'Supervisor: Don Breedon Reason(s) for test: ,, [] Initial Casing Shoe Test [] Formation Adequacy for Annular Injection 'Il Deep Test: Open Hole Adequacy for Higher Mud Weight Casing Size and Description: 9-5/8" 40# L-80 BTC Casing Setting Depth: 4,817' TMD 4,343' TVD Hole Depth: 4,837'TMD. 4,353'.TVD Mud Weight: 8.4 ppg Length of Open Hole Section: . 20' EMW .= Leak-off Press. + Mud Weight 0.052 x TVD = 1,219 psi + 8.4 ppg 0.052 x 4,353' EMW for open hole section = 13.8 ppg 3ump output = 0.0850 bps Fluid.Pumped = 2.6 bbl 3,400 psl 3,300 psi 3.200 pd 3,100 psi 3,000 psi ZS00 p~ 2,700 p~ ' 2,500 p.~ 2.400 p~ Z000 p~ 1,700 p~ 1,500 1,4Q0 ~ 1,100 p~t 70O ~ I ,,~ · ' Jq ..e- LEAK-OFF TEST J' J' ""-a"-CASING TEST --~-LOT SHUT IN TIME ' --~, -- CASING TEST SHUT IN TIME I ,TIME LINE 024681012141618~2~2628~32~42~48~52~62~7072747675~82~88~94969810101010 kkkkkkkkkkkkkkkkkkk'kkkkkkkkkkkkkkkkkkkkkkkkkkkkkkk~ kkk'k ~ROKES ' NOTE:' STROKES TURN TO MINUTES DURING "SHUT IN TIME":see time line above LEAK-OFF DATA CASING TEST DATA MINUTES FOR LOT STROKES PRESSURE .................. .2...s.t..k_.s. ...... .2_5._p._si .... ................... .4...s_Lk..s. ....... ~.R.s.i_... ................ 6stks .~ 136 psi , I 8stks 201 psi ................. ].o. _s.t..k.?. .... ??.~.L_ .. . j. ~._s. Lk..s.. ~ _ ~Es__,..s. L .. 14 stks ...474psi..,._..____ ................. .1_ .6. - .s.t..k..s_. 567'. psi .,. .... ~ ........ .1..8...s.t_k..s... 677 psi. 22 stks ' 869 psi .................. .2.?_?.t_.k.?. .... ~.~..p..~j..., 26 stks 1,068 psi ................. .2..E.s.t..~..s._.!,~.Z!R.s.t. ................. ~& .s!.~..s. _ .!,..~.~.! P. ~ L 30 stks 901 psi I- .............. 4- ................................ m ................ , ............ ':--'I' ............. ,"~ , L .............. .,~.,.-...,. ........ ~ ................ ....................... '~ .................... ' I ' SHUT IN TIMEI SHUT IN PRESSURE i 0.0min !' T 901 psi .............. -I- .............. -t- ............ ~--- [.2 :.o_m_Ln_i .............. 2.0 mJn { { 734 psi ...............· 3.0miR T, ............... ' "'i .............. 729 psi.' ....4:.0...m_i.n....i. ........... _.[ 725 psi. 5.0 min. ! ~ 723 psi 6.0min {! 720 psi 7.0 min ~ 'i ' 718 psi .............. T_Co.'i '.(E&iiiiiZZii].iiDZ./,:Eii 10.0min{ , { 715psi MINUTES FOR CSG TEST STROKEs PRESSURE [ 0 stks 0 pm '.'ziziiiiiiiiiiiiiii. ii. . i,:.;.iii { 8stks 310p_si ! i 16 stks 760 psi. ................ f'-~[~--~i~; ...... ............... [ ............... ...... ~ ........... ~"~i~"[ ................ L_.~_.s_~_tk.~ .... ]:~.qg_~L ................ L...~..~..s..Lk..s_. | 36 stks. 1,950 psi ............... ~ ............... r ................ [ '40 stks [ 2,200 psi ': ........ ? .... ~"a-~--~;--'~;~8--~'~i'I ........ " ....... [i-;f~"~i~; .... ~;~'a-'~,'~i-! ~ I ................ i-: .............................. ............... L_.- ............................ ............ T-'~ .......................... ~ ..... SHUT IN TIME i ' SHUT IN PRESSURE iiEE6LEi,.iiiiiiiZiiiii 1.0 min '[ 3,024 psi ! , ":~:b"~i~,---{ ....... , ....... !'-:i;i:i~.~-'f,~i' ......... : ..... · ........ 6.0..m_i.n_[ ............... _3_,_o. Ls..p..s_!j "7 0 min '{ ~ 3,018 psi { ~---' .... .-----I' ............. ,f ............. 8.0 m,n '[ ......., ...... [..3_,.O.1_7_p_s..{.] g.O'min j j 3,016 psi! ,_,..EZZZZii ;E iEEs]]. ..!.5....O_m.i_n_[ ............... [.],.o3_o_?.~Lj 20.0 min { · J 3,008 psi { ............ l l NOTE: 'TO CLEAR DATA, HIGHLIGHT AND PRESS THE DELETE KEY CASING TEST and FORMATION INTEGRITY TEST Well Name: 1C-18 KRU SUpervisor: Don E. Breeden Date: 2/15/99 Casing Size and Description: Casing Setting Depth: Mud Weight: 10.8 ppg Hole Depth: 6,308' 'rvD 1,420 psi + 10.8 ppg EMW /' LOT = (0.052 x 6,308') = 15.1 ppg Fluid Pumped = 1.9 bbl Pump output = 0.1010 bps 7", 26#, L-80, ABM-BTC (10' of new hole to 7595' MD) 7,578' TMD 6,308' TVD EMW = Leak-off Press. + MW 0.052 x TVD 2,000 psi 3,300 psi 3,200 psi ..... , .................... ~, ,,~,~,- ,~ ,, 3,100psi ...... - - - ' ~ ....... ~-*'1 :~: i .......... 2,900 psi ~ i / -- 2,800 psi. -- 2,700 psi -- -- -- 2,600 psi 2,500 psi 2,400 psi -- -~ -- -- -- 2,300 psi 2,200 psi, 2,100 psi r -- 1,900 psi · -- 1,800 psi 1,700 psi ! 1,600 psi 1,500 psi -- 1,400 psi ~a~*~'::'~'';g~;: ~,!~ i:;~ ~!~,~ -- 1,300 psi -- 1,200 psi / · -- -- 1,100 psi ~.~ 1,000 psi ~ LEAK-OFF TEST 900 psi J 800 psi . f, r - --a--CASING TEST 700 psi 600 psi ~ · ~,! ~-~>- LOT SHUT IN TIME 50O psi ~oo psi -~ -~ CASING TEST SHUT IN TIME 300 psi -- -- 200psi----~ ' ' TIMELINE 100 psi 0psi, J J 2 4 6 8 1~12141618 2~ 22 24 26 28 3~ 32 34 36 38 4~ 42 44 46 48 5~ 52 54 56 58 6~ 62 64 66 68 7~ 72 74 76 78 8~ 82 ~ ~ ~ ~ 92 94 st st st st st st st ~t st st st st st st st st st st st st st st st st st st st st st st st st st st st st st st st st st st st st st st st st k k k k k k k k k k k k k k k k k k k k k k k k k k k k k k k k k k k k k k k k k k k k k k k k STROKES NOTE: STROKES TURN TO MINUTES DURING "SHUT IN TIME":see time line above LEAK-OFF DATA MINUTES FOR LOT STROKES PRESSURE ................... [ ..... _0. _s_ !_k_ _s_ .... j ...... _o_£_sj ...... i 2stks I 91p_si , ~ 4 stks I 172 Psi , - ................. f .................. ~ .......... · ........ .,, ................ :_.,, ..... .6_.s..t.k._s_ .... j .... .2._8.o_.p..s_[ .... ................... [ ..... _8_s__t_k_s_ .... j .... _4_ _4_9_ _ p_ _s_ [ .... .- ................. [ .... ! _0_ _s_ t_ _k_ _s_ ........ _6_ _3_3_ _ p_ _s_ [ .... ................... i .... ! _2_ _s_ Lk. .s_ ........ _7_?A p_.s_[ .... ................... .,, .... j. .4. .s_ Lk. _s_ ........ _9Zs__p..s_[ .... ................... [ .... j_6..s_ Lk_s_ ....... _tJ__S__~_p__s.L ................... [ .... j__8__s_t_~_s_ ....... _t,~.o.p_s_L_. , ................ i .... !-~--s-Lk--s- ....... _L_4_.2_0_p..sj_.. I. .................. i .................. ,.r .................. i. .................. i .................. '"' .................. i- .................. ~ .................. .~ .................. ,,,i ~. .................. ~ .................. ,.L .................. ,.i i , ~ J :::::::::::::::::::::::::::::::::::::::::::::::::::::::::: SHUT IN TIME I SHUT IN PRESSURE 0.0min ~ ~ 1420~si ............. ,- ..... f .................. i ..... L ...... ~- ...... ..... j_..o.__m_j.n_ .... [ .................. .,'____t,.3_8_5_ ~_sj _ _. ..... 2.:.o...m.j.n. .... [ .................. i..j.,.3.!2..~.sj_.. ..... ~.:.o_..m_j_n_ .... i .................. i...M!s..p_sj._. ..... ~....o._.mj.n. .... [ .................. i...~._,~..~!._. ~ .... 5_:.o.._m_j.n_ .... t .................. J___L.3.7._°__P___s_L.~ ..... _~:_o.__m_j.n_ .... [ .................. i__j_,~_s_~_s_L_~ ..... _7:_.0__m__i.n_ .... [ .................. ~ _. _ .1.,.3_ .6_ _6_ p_s_ L' 80 min = ~ 1,364~si ...... L ........... f .................. .~ ........... j:- ..... 9.0 min ~ : 1,362Dsi 10.0 min ...................................... L_t,_3_6__o_~__sj_. CASING TEST DATA MINUTES FOR CSG TEST STROKES PRESSURE 0 stks 0 ~si r .................. .-,. .................. .~ ................. ........................ .~._s__t.k__s_ .......... J__o_~__s.[ ..... ........................ f__s..t.k..s_ ......... _t_O_O.p._s_[ .... ......................... f_.s_tk..s. ......... _2j_.o_p_.s_[ .... ......................... .8_.s__t.k_.s_ ......... _3_ p. .5_ p_ _s_ [ .... ........................ J. .o_ _s_ .t ~ .s_ ........ .5_ .o_ .7. p__s_ [ .... 12 stks 676 Psi ........................ J_f_.s._t.k._s_ ........ .s_ _2_ .7_ p_ _s_ [ _ _ . ,, ,___,_ ................... J_.S_.s..t_k..s_ ....... _t,_o__o_.o_~_s.L.~ ........................ JA.s!k._s_ ....... _M _s. f_ ~.s. _L j ........................ _2_p..s!k..s. ....... _t,~J_Je_S__L_~ ........................ _2_ .2__s__t.k_ _s_ .... L__j_,_s_~_o_~_s_L_j ................... : .... _2_f..s__t_k..s__.L.j_,.8__l_2_~_sJ_.. ........................ _2.f..s__t_k..s_ ....... .2:.o__o_.9_je._s_L_j , 28 stks 2,250~si .................................. ~- ................. ~---i : 30 stks 2,468os~ .................... + .............................. -"- ..... ................... :, .... _3__2..s. Lk..s_ ....... _2.,~_7__p.s_L..,, t 34 stks 2,898.E. si ! .......... ' ......... j"---~'~-~ii~' ....... ~-,-~-i~i'-] SHUT IN TIME SHUT IN PRESSURE ............. 7 ..... T .................. 1 ............... O.Om~n : : 3025[}s~ : t. .................. .t .................. .4 ..... ~ ...... ,. ..... j 1.0 min i : 3,024.~.si ..... ~:0'-r~r~ .... ? ...................... ~i'~' F~i'- r .... §';E'r~Tri .... T .................. !"'~",-6]~'~'_s_'i'" I- ...... '- ........... ~r .................. 4 .................. : 4.0 min : : 3,0210si f ............ r ..... f .................. '1 ........... -'---:---I :, .... .5. .. .°_ . _m_ t n. .... 1 .................. :,.___3.,_°_~_°_As_!_j ..... _~_ ._ .o_ . _m_ t n_ .... i ...................... _3:_o_ j_ _~_ ~.s_!__j 7.0 min ~ 3,018~si .... §;E'rYri .... l ...................... ~',-6i'f'E~i"i ...... '- ..... r ..... {' .................. -I ........... -' ...... ..... 9.._O_m._,_n. .... i .................. j..._~_,_o_!.6.p...sJ__j .... J__O:_O___m_j.n_.__t .................. ]____3.,_o_.!.s_~.s_!__j ___Z _5_._0__.m__i.n__._i .................. !.___3_,_o_ J_.o_ 9.s_L j 2o o min , ~ 3,008psi ...... :': .......... '~ .................. 4 ........... J: ..... -I 25.0 min : ~ 3,007osi .... &o:_o_mj_n_ ...................... :,_.__~_,_o__o_p_~_s_L_j NOTE: TO CLEAR DATA, HIGHLIGHT AND PRESS THE DELETE KEY SCANNED JUN 2 5 2002, CASING / TUBING / LINER DETAIL 9-5/8" Surface Casing WELL: 1C-'18 KRU ARCO Alaska, Inc. DATE: 2~8~99 Subsidiary of Atlantic Richfield Company 1 OF 1 PAGES # ITEMS COMPLETE DESCRIPTION OF EQUIPMENT RUN LENGTH DEPTH TOPS RKB to Landing Ring - Parker Rig #245 40.73 FMC Gen 5 Fluted Mandrel Casing Hanger & 40#, NSCC x BTC pup 1.58 40.73 25 Jts 9-5/8", 40#, L-80, BTC Casing (Joints #99 - #123) 970.05 42.31 TAM Port Collar 3.00 1012.36 96 Jts 9-5/8", 40#, L-80, BTC Casing (Joints #3 -#98) 3721.18 1015.36 Gemoco Float Collar 1.53 4736.54 2 Jts 9-5/8", 40#, L-80, BTC Casing (Joints #1 & #2) 76.93 4738.07 Gemoco Float Shoe 1.62 4815.00 Bottom of Shoe ==>> 4816.62 I TD of 12-1/4" Hole = 4826' MD (--10' of Rathole)i Baker Lok thru Float Collar Install TAM Port Collar on top of Jt #98 Run FMC Han~Ter on Top of Joint #123 15 Bow ~ prin,c/ Centralizers: 1 / Jt on first 15 joints, first 2 on stop ring in middle of joint i ii · ! i 2 R~qid Stra~c/ht Blade Centralizers' Slide 1 on Jts #98 & #99 Leave OUT 7 joints: Jts #124 thru #130 Remarks: String Weights with Blocks: 245K# Up, 205K# Dn, 75K# Blocks. Ran 123 joints of casing. Drifted casing with 8.679" plastic rabbit. Calipered hanger ID to verify 8-1/2" bit would pass. Used Arctic Grade APl Modified No Lead thread compound on all connections. Torqued connections to the base of the.triangle stamp. Parker Rig #245 Drillin~t Supervisor: Don E. Breeden ARCO ALASKA INC CASING TALLY PAGE: I of 1 WELL NUMBER: tC-18 Kuparuk River Unit RIG: Parker Rig #245 CASING DESCRIPTION: 9-5/8", 40#, L-80, BTC Casing - Range 3 - Class A DATE: 217199 Column I Column 2 Column 3 Column 4 Column 5 Column 6 Column 7 Column 8 No Feet No Feet No Feet No Feet No Feet No Feet No Feet No Feet iiiiiiii/~iiiiii 38.96 26 38.89 51 38.70 76 39.33 t01 38.70 ~/z~~ 151 176 iiiii~iii!i 37.97 27 38.13 52 39.66 77 39.60 102 37.97 ~/~152 177 iiiiiiiii~il 39.08 28 39.15 53 38.18 78 38.38 103 38.70 ~ ~ 153 t78 38.48 79 38.19 104 38.03 ¢/~.////~154 179 39.3O 29 39.O7 54 !iiiiiiii~iil 36.95 30 39.30 55 37.75 80 38.11 105 39.33 ~x~,~155 180 iiiiiiili~iiil 38.77 31 38.97 56 39.19 81 38.13 106 39.21 131 156 181 iiiiiiiii~iiiiiii 38.71 32 37.78 57 38.13 82 38.96 107 39.02 132 157 182 ~ 39.32 33 3~.9~ s8 3s.7~ 83 39.20 ~os 39.0~ ~33 ~s8 ~83 ~ 38.20 34 38.97 59 38.69 84 39.08 109 38.28 134 159 184 ~ ~.00 ~ ~.~ ~0 ~.02 ~ 3~.03 ~0 ~.5~ ~ ~0 ~ss '~a~¥~'"~'=='"':' 39.02 3s 3~.0~ s~ 39.~4 8s 37.90 ~ 39.~3 ~3s 161 186 39.0~ 37 3~.07 s2 3~.~0 87 3~.97 ~2 3~.9~ ~37 ~s2 ~s7 39.24 38 38.73 63 39.60 88 38.96 113 38.99 138 163 188 3s.7~ 3~ 3~.~9 ~ 3~.9~ ss 3~.7~ ~ 39.29 ~3~ ~ ~8s 16 39.12 41 38.93 66 39.21 91 39.19 116 39.12 141 166 191 17 39.30 42 38.69 67 38.98 92 39.31 117 37.28 142 167 192 18 39.48 43 39.95 68 38.99 93 39.12 118 38.68 t43 168 193 19 38.69 ~ 38.64 69 38.72 94 39.33 119 40.17 144 169 194 20 39.21 45 37.94 70 38.68 95 39.72 120 39.13 145 170 195 39.~0 ~s 3~.~ 7~ 3~.~7 ~s 3~.3~ ~ 39.0~ ~s ~7~ ~s 22 3~.97 ~7 3~.94 7~ 3~.97 ~7 39.29 ~22 3s.~ ~7 ~72 ~7 ~3 39.~0 48 39.30 73 39.00 s8 3~.97 ~23 3~.7~ ~s ~73 ~s8 2~ 39.~~s 39.00 7~ 3~.7~ ~ 39.~9 ~~~ ~7~ ~ so 3~.9~ 7s 37.2~ ~0039.~~~~~so ~Ts 200 25 38.27 Tot 972.04 Tot 968.21 Tot 966.89 Tot 969.34 Tot 966.23 Tot 192.56 Tot Tot TOTAL LENGTH THIS PAGE = TOTAL JOINTS THIS PAGE = Landing Joint = 46.13' 5035.27 130 Leave OUT Joints #124 thru #130. DIRECTIONS: RKB to Landing Ring = 40.73' FMC Fluted Mandrel Casing Hanger = 1.58' TAM Port Collar = 3.00' Gemoco Float Collar = 1.53' Gemoco Float Shoe = 1.62' ARCO Alaska, Inc. Cementing Details Well Name: IC-18 Report Date: 07./I0/99 Report Number: 11 Rig Name: RIG # 245 AFC No.: AK0020 Field: Kuparuk River Unit Casing Size Hole Diameter: I Angle thru KRU: Shoe Depth: I LC Depth: % washout: 9-5/8" 12-1/4"I KOP (~ 2250' 4817' MD, 4342' TVDI FC (~ 4737' MD 45* Slant Centralizers State type used, intervals covered and spacing Comments: 15 Gemoco Bow Spring Centralizers: 1 / Joint on first 15 joints, first 2 on stop dngs in middle of shoe joints. 2 ROTCO Rigid Straight Blade Centralizers: One on joints on each side of TAM port collar (~ 1012'. Mud Weight: PV(prior cond): PV(after cond): YP(prior cond): YP(afler cond): Comments: 10.3 to 10.2 ppg 49 34 52 23 Gels before: Gels after: Total Volume Circulated: 20/38 10115 2839 Bbls Wash 1 Type: Volume: Weight: Comments: ARCO 20 Bbls 8.34 ppg Spacer 2 Type: Volume: Weight: Comments: ARCO Spacer 50 Bbls 10.5 ppg Lead Cement 3 Type: Mix wtr temp: No. of Sacks: Weight: Yield: Comments: AS III LW 70* F 620 sx 10.7 ppg 4.44 cfs Additives: Class G + 50% D124 + 9.0% D44 + 0.4% D46 + 30% D53 + 1.5% Sl + 1.5% D79 Tail Cement 4 Type: Mixwtr temp: No. of Sacks: Weight: I Yield: Comments: G 70' F 550 sx 15.8 PPgI 1.17 cfs Additives: . Class G + 1% S1 + 0.2% D46 + 0.5% D155 (Fluid Loss Additive) + 0.3% D65 Displacement 5 Rate(before tail at shoe): Rate(tail around shoe): Str. Wt. Up: Comments: 8 BPM 8 BPM 245K# (75K# Blocks) Reciprocation length: Reciprocalion speed: Str. Wt. Down: -15' -20 fpm . 205K# (75K# Blocks) Theoretical Displacement: Actual Displacement: Str. Wt. in mud: 359 Bbls 363 Bbls 146,600# Calculated top of cement/ CP: Bumped plu~: I Floats held: Cemented to Surface '" Date:2/10/99 Yes" Yes Time:0700 hrs Remarks: Circulated to condition mud & hole for cementing, 6 to 8 BPM, 450 psi, 2839 Bbls total. Reciprocated casing, 245K# Up, 205K# Down. Circulated 2-1/2 hours extra while working on frozen valve at 1C-'15 injection annulus & lining up trucks to haul returns to tR-18 injection well - got 1C-15 thawed out at 0900 hrs, 2/9. Cement Surface Casing, 2/9/99: Dowell flush lines with 5 Bbls water & test to 3500 psi. Pump 20 Bbls ARCO Pre-Flush & 50 Bbls, 10.5 ppg ARCO Spacer. Drop bottom plug. Mix & pump 490 Bbls, 620 sx, 10.7 ppg AS III LW Lead Cement, 8 BPM. Mix & pump 105 Bbls Class G Tail Cement with additives including D156 fluid loss additive. Drop top plug & chase with 10 Bbls Tail Cement [550 sx total) & 20 bbls wash-up water. Displace with mud using rig pump, 8 BPM. Bumped plug. Pressured up to 2000 psi & held briefly, OK. Floats held, OK. ClP {~ 0700 hrs, 2/9/99. Reciprocated casing until '167 Bbls of Lead Cement had rounded the shoe, then left set on hanger (42 Bbls into Tail). Started seeing cello-flakes (put in 1st 3 Bbls of pre-flush) in returns at 92 Bbls into Tail, a/b.o~'-ut~Bbl~ after calculated volume for gauge hole. Started dumping contaminated mud & cement shortly thereafter - theoretically had 70 Bbls of spacers ~ ~02 Bbls~/ead Cement returns to surface. Had 10.7 ppg cement returns, including some up to 11.6 ppg, until last 50 to 100 Bbls of displacement, when retum~ were~,l~4 ppg to 10.6 ppg & very watery looking (not good cement), estimate 25% to 50% free water, Had full returns throughout. First 25 Bbls of Tail mixed nbrmally at '15.8 ppg, then started having problems maintaining weight. PACR showed 12 to 13 ppg, DIS balance showed 14 ppg. Trying to mix heavier went to powder. Samples looked normal & weighed one at 15.6 ppg with dg scales. DIS mix water & slurry volumes came out right. DIS cementer had seen this mixing problem before, when D156 additive was used. RIH with TAM Combo Tool & shifted Port Collar at 1012' open. Circulated out contaminated mud & cement thru port collar. After circulating out 110 Bbls, about two 12-1/4" annular volumes, flutes in FMC Gen 5 hanger packed off & returns broke around conductor in cellar. Closed Port Collar & POH with TAM tool. Spent rest of day & night rigging up & cleaning out 16" x 9-5/8" annulus to finish circulating same clean & cementing thru Port Collar. Had to cut window in 16" below landing ring to run 1" CS Hydril tubing to 120' & circulate same clean. Flutes in hanger had not been opened up to get 1" CS Hydril thru them. Also, bypass area in flutes is much too small, making the Gen 5 hangers very prone to plugging off, as this one did. Once 16" x 9-5/8" annulus was cleaned up, RBIH with TAM Combo Tool. Shifted Port Collar open & finished circulating annulus clean above ports. RU Dowell. Dowell pumped 15 Bbl water spacer. Mix & pump 10.7 ppg AS III LW Cement until getting good, clean 10.7 ppg cement returns to surface thru port collar. Pumped 110 Bbls of Cement, started getting cement returs at about 65 Bbls pumped. Pump 1-1/2 Bbls of water behind to clear line to head pin. Rig displace DP with 18 Bbls mud. Closed port collar at 1012'. Circulated DP & casing clean. CIP (~ 0700 hrs, 2/10/99. Cement Company: Dowell Rig Contractor: Parker Approved By: Don E. Breeden ~ CASING / TUBING / LINER DETAIL ~7" Intermediate Casinq WELL: '1 C-18 KRU ARCO Alaska, Inc. DATE: 2/14/99 Subsidiary of Atlantic Richfield Company '1 OF '1 PAGES # ITEMS COMPLETE DESCRIPTION OF EQUIPMENT RUN LENGTH DEPTH TOPS RKB to Casing Head Lockdowns 38.53 FMC Gen 5 Fluted Mandrel Hanger & 29#, L-80, NSCC x BTC pup 2.59 38.53 180 Jts 7", 26#, L-80, ABM-BTC Casing (Jts #3 - #182) 7451.02 41.12 Gemoco Float Collar 1.30 7492.14 2 Jts 7", 26#, L-80, ABM-BTC Casing (Jts #1 & #2) 83.46 7493.44 Gemoco Float Shoe 1.50 7576.90 Bottom of Shoe ==>> 7578.40 I TD of 8-1/2" Hole = 7585' MD (~7' of Rathole) Parker Rig #245 - RKB to LDS on Tubing Head = 36.29' Baker Lock through the Float Collar Put FMC Casing Hanger on Top of Joint #182 20 Bow Sp rin,q Centralizers & 2 Stop Rin,~s: Put a stop ring in the middle of Joints #1 & #2; ' " Put one cent;alize;'on each of t~e fir;t 20 joints. 10 Spira,~iiders: Slip one on every 5th joint, as follows: Joints # 135, 140, #145, 150, 155, 160, 165, 170, 175, & 180. Leave OUT 18 Joints (Joints #183 through #200) Remarks: String Weights with Blocks: 240K# Up, 180K# Dn, 75K# Blocks. Ran 182 joints of casing. Drifted casin9 with 6.151" plastic rabbit. Calipered hanger & 29# pup to be sure 6-1/8" bit would pass. Used Arctic Grade APl Modified No Lead thread compound on all connections. Torqued connections to the base of the triangle stamp. Parker Ri~l #245 Drilling Supervisor: Don E. Breeden ARCO ALASKA INC CASING TALLY PAGE: I of 1 WELL NUMBER: 1C-18 Kuparuk River Unit RIG: Parker Rig #245 CASING DESCRIPTION' 7", 26#, L-80, ABM-BTC Casing - Range 3 - Class A DATE: 2/13~99 ._ Column 1 Column 2 Column 3 Column 4 · Column 5 Column 6 Column 7 Column 8 tiNe]ii~l Feet No Feet No Feet No Feet No Feet No Feet No Feet No Feet iiii}i~i{ii 41.80 26 43.11 51 40.70 76 40.70 101 41.97 126 41.50 151 41.14 176 40.77 41.66 27 42.00 52 42.00 77 39.26 102 42.18 127 39.53 152 42.89 177 38.66 .[i. Ii~i] 41.7628 43.28 53 41.68 78 40.51 103 40.90 128 41.46 153 42.66 178 42.38 ii i!ili!il41.75 29 41.00 54 40.34 79 41.72 104 41.10 129 41,64 154 42.58 179 42.16 !iiiiIii~tiiiiil 41.35 30 41.86 55 41.64 80 42.16 105 42.22 130 41.13 ,i,~i~i43.28 i.i~.~i43.61 i!!ii iiiil ! 41.28 31 43.50 56 41.18 81 41.72 106 40.94 131 42.19 156 40.66 181 40.10 41.33 32 41.23 57 42.20 82 41.77 107 42.82 132 42.77 157 41.57 182 41.79 ii!i~i,:,,iltl 43.22 33 41.00 58 42.66 83 40.55 108 37.99 133 42.04 158 42.88 ~,~~ tiiiiii~iiiiiiii 42.73 34 42.81 59 42.61 84 38.36 109 41.78 134 41.04 159 43.51 tiil~i~ii! 40.34 35 41.23 60 39.14 85 41.71 110 41.72 ii~i~ ............ 41.17 ............... i~i~ 39.22 ~/'#'// Iiii~ ! 43.10 36 41.76 61 38.05 86 40.67 111 40.11 136 40.49 161 41.27 l~!.~i~iiiil 41.86 37 41.77 62 43.60 87 41.69 112 40.93 137 40.82 162 41.65 ii! !;~i~.i].! 41.68 38 38.98 63 41.88 88 41.06 113 41.16 138 38.02 163 39.79 .........iiI~ i! 43.17 39 43.30 64 42.36 89 40.70 114 41.76 139 41.76 164 40.13 I.i.i.~i~..].! 38.84 40 38.58 65 41.27 90 42.85 115 42.64 .i.~i~i.41.61 i.i~.~.i43.14 iiiiil~i~.....! 41.13 41 41.18 66 42.58 91 42.21 116 40.78 141 39.58 166 43.22 i!i!li~i~iiiiii 41.14 42 41.77 67 40.80 92 39.61 117 39.95 142 37.18 167 41.19 ii!iii~i~iilil 43.25 43 43.16 68 39.78 93 41.31 118 42.75 143 39.57 168 41.76 iiiii~i~iiill 39.8344 41.12 69 38.34 94 37.64 119 41.76 144 42.28 169 43.31 iI~iil 37.84 45 41.20 70 41.67 95 43.27 120 39.31 ii~ii 38.82 ii~i 42.36 2tl43.21 46 41.40 71 42.61 96 40.71 121 41.16 146 43.29 171 43.45 22J 43.14 47 42.77 72 41.46 97 41.66 122 43.16 147 42.77 172 40.87 23 40.59 48 39.96 73 43.22 98 4t .76 123 38.11 148 43.59 173 39.73 24 40.99 49 42.85 74 41.19 99 42.21 124 43.17 149 43.22 174 42.92 ,29 41.43 50 39.99 75 38.95 100 39.07 12~ 41.25 [i~ii 42.48 .i.~i~!.42.24 Tot 1038.42 Tot 1040.81 Tot 1031.91 Tot 1024.88 Tot 1031.62 Tot 1029.95 Tot 1047.42 Tot 1043.17 TOTAL LENGTH THIS PAGE = 8288.18 TOTAL JOINTS THIS PAGE = 200 Leave OUT Jts #183 thru #200 & Marker Joint. DIRECTIONS: _anding Joint = 45.47' FMC Fluted Mandrel Hanger & pup = 2.59' (includes Packoff to LDS) Marker Joint = 21.18' Top Half + 21.15' Bottom Half Gemoco Float Collar = 1.30' Gemoco Float Shoe = 1.50' ARCO Alaska, Inc. Cementing Details Well Name: 1C-18 Repod Date: 02/14/99 Report Number: 15 Rig Name: RIG # 245 AFC No.: AK0020 Field: Kuparuk River Unit Casing Size Hole Diameter: Angle thru KRU: } Shoe Depth: LC Depth: % washout: 7" 8-1/2" 45* SlantI 7578' MD, 6308' 'I'VD FC (~ 7492' Centralizers State type used, intervals covered and spacing Comments: 120 Gemoco Bow Spring Centralizers: 1/joint on first 20 joints, first two on stop rings in middle of shoe joints. 10 Gemoco Spiragliders: 1 15 joints from -2000' 'I-VD to sun'ace. Mud Weight: PV(prior cond): PV(after cond): I YP(prior cond): YP(after cond): Comments: 10.0 to 9.8 ppg 22 17I 25 17 Gels before: Gels after: Total Volume Circulated: 7/8 5/6 879 Bbls Wash I Type: Volume: Weight: Comments: ARCO 20 Bbls 8.34 ppg !Spacer 2 Type: Volume: Weight: Comments: ARCO Spacer 40 Bbls 12.0 ppg Lead Cement 0 Type: Mix wtr temp: No. of Sacks: I Weight: Yield: Comments: I None Additives: Comments: G 80* F 170 sx 15.8 ppg 1.16 cfs 3:04 TT Additives: Class G + 0.20% D46 + 0.15% D65 + 0.27% D800 Displacement 4 Rate(before tail at shoe): Rate(tail around shoe): Str. Wt. Up: Comments: 5.0 BPM 5.0 BPM 240K# (75K# Blocks) Reciprocation length: Reciprocation speed: Str. Wt. Down: -20' -20 fpm 180K# (75K# Blocks) Theoretical Displacement: Actual Displacement: Str. Wt. in mud: 287 Bbls 290 Bbls 139,000# Calculated top of cement: I CP: Bumped plug.~. Floats held: Between 6775' & 6175' MD '/ Date:2/14/99 Yes v" Yes I Time:0715 hfs Remarks: Circulated 879 Bbls to condition mud & hole. Lost 182 Bbls of mud while running & circulating casing. Final rate at 5 BPM with no loss. Started losing mud at higher rates, so stayed at 5 BPM. Reciprocated casing, 240K# Up, 180K~ Down. Dowell flushed lines with 5 Bbls water. Tested to 4250 psi. Pumped 20 Bbls ARCO Pre-Flush & 40 Bbls, 12.0 ppg ARCO Spacer. Drop bottom plug. Mix & pump 170 sx, 35 Bbls, 15.8 ppg Class G Cement (+additives). Drop top plug. Chase plug with 20 Bbls wash-up water. Switch to rig pump & displace with mud, 5 BPM. Bumped plug. Pressured up to 2000 psi & held 5 minutes, OK. Bled o~F& checked floats, OK. Reciprocated casing, landed hanger 10 Bbls before plug bumped. Lost -10 Bbls of mud before spacers & cement reached the shoe. VFull returns thereafter. CIP (~ 0715 hrs, 2/14/99. , !Cement Company: Rig Contractor: Approved By: Dowell Parker Don E. Breeden CASING / TUBING / LINER DETAIL 4-1/2" Liner WELL: 1C-18 KRU DATE: 2/17/98 I OF I PAGES ARCO Alaska, Inc. Subsidiary of Atlantic Richfield Company # ITEMS COMPLETE DESCRIPTION OF EQUIPMENT RUN I LENGTH 3-1/2", 15.50# Drill Pipe - Parker 245 (minimum to rig floor)[ 7348.41 Baker C2 Setting Tool and 3-1/2" DP Pup 11.24 Top of Liner ==>> Baker 5x7 'ZXP' Liner Packer & Tieback Sleeve (Locator @ 11160.51') 22.02 Baker 5x7 'HMC' Liner Hanger 6.65 21 Jts 4-1/2", 12.60#, L-80, NSCT Liner /Jts. # 3-#23) 641.66 Baker Landing Collar 1.12 1 Jt 4-1/2", 12.60#, L-80, NSCT Liner (Jt. # 2) 29.73 Baker Float Collar 1.13 1 Jt 4-1/2", 12.60#, L-80, NSCT Liner (Jt. # 1) 31.13 Baker Float Shoe 1.91 Bottom of Shoe ==>> Tubin,~ Seal Assembly locates on Shoulder in bottom of tie-back sleeve @ 7373. 70' 7" Shoe @ 7578' MD TD of 6-1/8" Hole = 8095' MD Baker Lock thru Landing Collar rRlider Centralizers: 2 / Joint, on either side of a stop collar in middle of joint. Put Baker Liner Hanger Assembly on top of Joint #23. Leave OUT 2 Joints (Joints ~24 & ~25) 46 Spir, DEPTH TOPS 7359.65 7381.67 7388.32 8029.98 8031.10 8060.83 8061.96 8093.09 8095.00 Remarks: DP & Liner Wei~lhts with Blocks: xxxK# Up, xxxK# Dn, 75K# Blocks. Ran 23 ioints of liner. Drifted liner with 3.833" plastic rabbit. Used Arctic Grade APl Modified No Lead thread compound on all connections. Torqued connections to 4100 fi-lb optimum. Parker Ri~t #245 Drilling! Supervisor: G.R. Whitlock ARCO ALASKA INC CASING TALLY PAGE: 1 of 1 WELL NUMBER: 1C-18 Kuparuk River Unit RIG: Parker Rig #245 TUBING DESCRIPTION: 4-1/2", 12.60#, L-80, NSCT Tubing, Non-Coated - Range 2 - Class A DATE: 2/17/99 Column 1 Column 2 Column 3 Column 4 Column 5 Column 6 Column 7 Column 8 No Feet No Feet No Feet No Feet No Feet No Feet No Feet No Feet ~ 31.13 26 51 76 101 126 151 176 ~ 29.73 27 52 77 102 127 152 177 ~ 31.13 28 53 78 103 128 153 178 ~ 31.33 29 54 79 104 129 154 179 ~ 31.42 30 55 80 105 130 155 180 ~ 29.29 31 56 81 106 131 156 181 ~ 31.60 32 57 82 107 132 157 182 ~ 30.13 33 58 83 108 133 158 183 ~ 31.42 34 59 84 109 134 159 184 ~ 30.48 35 60 85 110 135 160 185 ~ 29.93 36 61 86 111 136 161 186 ~ 31.52 37 62 87 112 137 162 187 ~i~ 30.21 38 63 88 113 138 163 188 ~ 30.60 39 64 89 114 139 164 189 30.42 40 65 90 115 140 165 190 28.95 41 66 91 116 141 166 191 31.48 42 67 92 117 142 167 192 ~ 30.74 43 68 93 118 143 168 193 ~ 30.99 44 69 94 119 144 169 194 ~ 28.79 45 70 95 120 145 170 195 ~ 28.61 46 71 96 121 146 171 196 ~ 3t,00 47 72 97 122 147 172 197 ~ 31,62 48 73 98 123 148 173 198 i~i~ii~!~i~iiiiiii~.~::,ii~ 49 74 99 124 149 174 199 !ii?ili~!!!~!i?~!~ii!i 50 75 100 125 150 175 200 Tot 764.76 Tot Tot Tot Tot Tot Tot Tot TOTAL LENGTH THIS PAGE = TOTAL JOINTS THIS PAGE = 764.76 25 DIRECTIONS: Leave OUT 3 Joints (Jts #23 thru #25) iED JUN 5 ARCO Alaska, Inc. Cementing Details Well Name: 1C-18 Report Date: 02/18/99 Report Number: 19 Rig Name: RIG # 245 AFC No.: AK0020 Field: KRU Casing Size Hole Diameter: Angle thru KRU: Shoe Depth: LC Depth: % washout: 4.5 6.125 45 8095 8029.98' Centralizers State type used, intervals covered and spacing Comments: 2 spiraglide centralizers per jt with a stop ring between centralizers Mud Weight: PV(prior cond): PV(after cond): YP(prior cond): YP(after cond): Comments: 11.1 32 31 34 34 Gels before: Gels after: Total Volume Circulated: 7/11 7111 510 : Wash 0 Type: Volume: Weight: Comments: ARCO Wash 10 8.33 ~pacer 0 · Type: Volume: Weight: Comments: ARCO Spacer 30 13 Lead Cement 0Comments: G Type: I Mix wtr temP:75 N°' of Sacks:I'130 Weight:l 5.8 Yield:1.2 Additives: .1 gps D47, 3% D53, .75% D65, .1 gps D135, 2 gps D600, .1% D800 Comments: I I I Additives: Displacement 0 Rate(before tail at shoe): Rate(tail around shoe): Str. Wt. Up: Comments: 4 4 170 Reciprocation length: Reciprocation speed: Sir. Wt. Down: 30 30 fpm 145 Theoretical Displacement: Actual Displacement: Sir. Wt. in mud: 68.2 60.9 Calculated top of cement: CP: Bumped plug: Floats held: TOL (~ 7359.65' Date:2/18/99 yes yes Time:16:25 Remarks:Good returns throughout job. Reversed out 7 bbl cement and cement contaminated mud, spacer and water cut mud. Cement Company: IRig Contractor: Approved By: DS I PARKER G.R. Wh t ock CASING / TUBING / LINER DETAIL .4.-1/2" Tapered Single Completion WELL: 1C-18 KRU ARCO Alaska, Inc. DATE: 2-17-99 Subsidiary of Atlantic Richfield Company Page I of I # ITEMS COMPLETE DESCRIPTION OF EQUIPMENT RUN LENGTH DEPTHTOPS RKB to Tubing Hanger Lockdown Screws - Parker Rig #245 36.29 Hanger FMC Gen V 4-1/2" Tubing Hanger & pup, 4-1/2" NSCT landing thread .91 36.29 4-1/2", 12.6#, L-80, NSCT pup 2.29 37.20 Ijt 4-1/2", 12.6#, L-80, NSCT (Jt #234) 30.89 39.49 4-1/2", 12.6#, L-80, NSCT pup---Estimated 7.81 70.38 14 its 4-1/2", 12.6#, L-80, NSCT (Jt #220-233) 424.83 78.19 Nipple Camco "DB" Nipple (3.81") 1.50 503.02 68 its 4-1/2", 12.6#, L-80, NSCT (Jt #152-219) 2072.18 504.52 4-1/2", 12.6#, L-80, NSCT pup 9.45 2576.70 GLM #6 Camco KBG-2-LS w/integral latch and Dummy Valve 7.55 2586.15 4-1/2", 12.6#, L-80, NSCT pup 7.45 2593.70 46jts 4-1/2", 12.6#, L-80, NSCT (Jts #106-151) 1405.97 2601.15 4-1/2", 12.6#, L-80, NSCT pup 9.49 4007.12 GLM #5 Camco KBG-2-LS w/integral latch and Dummy Valve 7.54 4016.61 4-1/2", 12.6#, L-80, NSCT pup 7.48 4024.15 39 its 4-1/2", 12.6#, L-80, NSCT (Jts #67-105) 1196.35 4031.63 4-1/2", 12.6#, L-80, NSCT pup 9.45 5227.98 GLM #4 Camco KBG-2-LS w/integral latch and Dummy Valve 7.54 5237.43 4-1/2", 12.6#, L-80, NSCT pup 7.53 5244.97 24 jts 4-1/2", 12.6#, L-80, NSCT (Jts #41-66) 799.37 5252.50 4-1/2", 12.6#, L-80, NSCT pup 9.38 6051.87 GLM #3 Camco KBG-2-LS w/integral latch and Dummy Valve 7.54 6061.25 4-1/2", 12.6#, L-80, NSCT pup 7.44 6068.79 22 its 4-1/2", 12.6#, L-80, NSCT (Jts #19-40) 677.50 6076.23 4-1/2", 12.6#, L-80, NSCT pup 9.34 6753.73 GLM ~2 Camco KBG-2-LS w/integral latch and Dummy Valve 7.55 6763.07 4-1/2", 12.6#, L-80, NSCT pup 7.48 6770.62 16 its 4-1/2", 12.6#, L-80, NSCT (Jts #3-#18) 492.04 6778.10 4-1/2", 12.6#, L-80, NSCT pup 9.43 7270.14 GLM #1 Camco KBG-2-LS w/integral latch and Dummy Valve 7.54 7279.57 4-1/2", 12.6#, L-80, NSCT pup 7.51 7287.11 1 jt 4-1/2", 12.6#, L-80, NSCT (Jt #2) 31.24 7294.62 Nipple Camco "DB" Nipple (3.75") 1.51 7325.86 1 jt 4-1/2", 12.6#, L-80, NSCT (Jt #1) 31.12 7327.37 pup 4-1/2", 12.6#, L-80, NSCT pup 5.76 7358.49 Baker Locator 1.05 7364.25 Baker Seal Assembly 12.30 7365.30 Tubing tail @ 7377.60 Remarks: String Weights with Blocks: 152K# Up, 140K# Down, 75K# Blocks. Drifted 4-1/2" tubing, seal asse GLMs, & hanger w/3.75" plastic rabbit. Used Arctic Grade APl modified no-lead dope on all connections(BOL; Bottom of Iocator 1' above tieback. Top of liner @ 7259.65' by liner tally. Ran 334 its 4-1/2" tubing. Leave its #235 to #264-30 its in shed. Parker Ri~! #245 Drilling7 Supervisor: G.R. Whitlock ~. ~- -.. Page 1 Well Name:l C-18 Begin End Rpt Date Time Time ~ 01/31/99 00:00 15:00 OTHER Held safety meeting: Review recent safety bulletins and reports 01/31/99 15:00 18:00 RIGS Repaired wear plate and replaced kickplaate on drawworks drum. 01/31/99 . 18:00 19:00 RIGS Cut drilling line 01/31/99 19:00 24:00 RIGS Prepare rig floor to pickup cellar box. Continue to prep for rig move 02/01/99 00:00 15:00 MIRU Wait on weather to moderate 02/01/99 15:00 24:00 MIRU APC moved brine tanks away from rig. Skid rig and jack up modules. Move modules away from well line. Move rig off pad. 02/02/99 00:00 24:00 MIRU Move rig. Moving Utility Module in front, stopped at 'Y' for fuel & water trucks to service Doyon 19 & Parker camp. Drilling Module at 3C access road. (Repaired hydraulics problem on Lampson #2 which was preventing left track brake from fully releasing). 02/03/99 00:00 24:00 MIRU Move rig. Utility Module moving ahead, from Oliktok 'Y' to 1C Pad. Drilling Module moved from 3C access road & moving down access road to 1C Pad at midnight. Welder repaired bolster on #1 Lampson on Drilling Module at lQ wide spot. 02/04/99 00:00 06:00 MIRU Move Drilling Module onto 1C-18. Skid derrick over hole. Set down & level DM. Spot Utility Module & mate up to DM. 15.1 mile rig move. 02/04/99 06:00 08:00 MIRU Hook up all service lines. Chink cracks, heat up equipment, start warming up rig. Accepted Rig @ 0800 hrs, 2/4/99. (Moved camp, change house, SDS & shop from 3K to 1C @ 0800 hrs to 1600 hrs - had to change a flat tire on shop.) 02/04/99 08:00 16:00 NU_ND Heat up cellar area to get Diverter stack off stump. NU Diverter system. Heat up Shaffer rubber. Fill aits& mix spud mud. RU to PU DP. 02/04/99 16:00 22:00 PREP PU 150 joints of 5" DP, 29 joints HWDP, Jars & 6 DC. 02/04/99 22:00 22:30 BOPE Function test Diverter system. Witnessing of test waived by Larry Wade, AOGCC Field Inspector. 02/04/99 22:30 23:30 PREP Realign flow nipple & flow line. Fill hole & check for leaks. 02/04/99 23:30 24:00 BHA PU BHA #1. 02/05/99 00:00 02:30 BHA MU BHA. Reset AKO on motor to 1.35'. MU, orient, & program LWD tools. 02/05/99 02:30 12:00 DRIL Spud-in & drill from 121' to 850'. (6.91 ADT) 02/05/99 12:00 12:30 RIGS Service rig & top drive. 02/05/99 12:30 15:00 DRIL Drill to 1155'. (2.22 ADT) 02/05/99 15:00 16:30 CIRC Circulate out gas cut mud. 10.0 ppg mud cut to 8.2 ppg. 02/05/99 16:30 24:00 DRIL Drill to 2087' & drilling ahead. CBU at 1257' & 1526' to circulate out gas cut mud. (4.38 ADT). 02/06/99 00:00 00:30 DRIL Drill from 2087' to 2250'. (0.27 ADT) 02/06/99 00:30 01:30 CIRC Circulate Io-visc sweep around. 02/06/99 01:30 03:30 TRIP_OUT POH for wiper trip. 02/06/99 03:30 05:00 BHA Change to larger nozzle in MWD. LD UBHO sub. Check bit. 02/06/99 05:00 06:00 RIGS Service rig. Change out grabs on top drive. 02/06/99 06:00 08:00 TRIP_IN RIH. 6' of fill on bottom. 02/06/99 08:00 08:30 CIRC CBU. 02/06/99 08:30 24:00 DRIL Kick-off & drill from 2250' to 3668' MD, 3531' TVD, & drilling ahead. (8.77 ADT) 02/07/99 00:00 12:30 DRIL Drill from 3668' to 4826' MD, 4349' TVD. (10.07 ADT) 02/07/99 12:30 15:00 CIRC Circulate Io/hi-visc sweeps around. Circulate & condition mud & hole, 2.5 bottoms up. 02/07/99 15:00 18:00 TRIP_OUT POH. Work thru tight spots between 3100' to 2000'. Circulate out 2 stands to 1811'. 02/07/99 18:00 19:00 CIRC Circulate hole clean & monitor bubbling from hydrates. Adjust weight indicator. 02/07/99 19:00 21:30 TRIP_OUT Circulate out to HWDP at 1160'. POH. Down load LWD. LD LWD tools & mud motor. 02/07/99 21:30 24:00 TRIP_IN MU 12-1/4" hole opener & BHA #2. RIH. 02/08/99 00:00 03:00 TRIP_IN RIH with hole opener. Ream from 1853' to 2036'. RIH to 4826'. 02/08/99 03:00 06:00 CIRC Circulate Io-visc sweep around. Circulate & condition mud & hole for casing, 1963 Bbls total. 02/08/99 06:00 08:00 TRIP_OUT POH. Work thru tight spots from 3800' to 3744' & 2220' to 2130', work back thru OK. 02/08/99 08:00 09:00 BHA LD BHA. 02/08/99 09:00 10:00 CASG RU to run 9-5/8" surface casing. Hold pre-job safety meeting. 02/08/99 10:00 21:00 CASG Run 9-5/8" surface casing, 123 joints total. Circulate casing volume at 2100' & 3104'. Circulate & work casing thru tight spots from 3400' to 4000'. Wash joints down to 4816'. 02/08/99 21:00 24:00 CIRC Circulate to condition mud & hole for cementing, 6 BPM to 8 BPM, 450 psi. Reciprocate casing, 245K# Up, 205K# Down. : Well Name:l C-18 Page 2 R__pt Date Be~in End Time Time ~ 02/09/99 00:00 04:O0 CIRC Cimulate to condition mud & hole for cementing, 6 to 8 BPM, 450 psi, 2839 Bbls total. Reciprocate casing, 245K# Up, 205K# Down. Cimulated 2-1/2 hours extra while working on frozen valve at injection annulus on lC-15 & lining up trucks to haul returns to 1R-18 injection well. 02/09/99 04:00 07:00 CMT_CSG Cement 9-5/8" surface casing: Dowell flush lines with 5 Bbls water & test to 3500 psi. Pump 20 Bbls ARCO pre-flush & 50 Bbls, 10.5 ppg ARCO Spacer. Drop bottom plug. Mix & pump 490 Bbls, 620 sx, 10.7 ppg AS III LW Lead Cement. Mix & pump 105 Bbls Class G Tail Cement with additives including D156 fluid loss additive. Drop top plug & chase with 10 Bbls Tail Cement (550 sx total) & 20 Bbls wash-up water. Displace with mud using rig pump. Bumped plug. Pressured up to 2000 psi & held briefly, OK. Floats held. ClP @ 0700. Reciprocated casing until 167 Bbls of Lead Cement had rounded the shoe, then left set on hanger (42 Bbls into Tail). Started seeing celloflakes (put in 1st 3 Bbls of pre-flush) in returns at 92 Bbls into Tail, about 10 Bbls after calculated volume for gauge hole. Started dumping contaminated mud & cement shortly thereafter - theoretically had 70 Bbls of spacers & 302 Bbls Lead Cement returns to surface. Had 10.7 ppg cement returns, including some up to 11.6 ppg, until last 50 to 100 Bbls of displacement, when returns were 10.4 ppg to 10.6 ppg & very watery looking (not good cement). Had full returns throughout. First 43 Bbls of Tail mixed normally at 15.8 ppg, then started having problems maintaining weight. PACR showed 12 to 13 ppg, D/S balance showed 14 ppg. Trying to mix heavier went to powder. Samples looked normal & weighed one at 15.6 ppg with rig scales. D/S mix water & slurry volumes came out right. (Note: TBC --- starting cement job thru TAM port collar now, 0600 hrs, Wed, 2/10.) 02/09/99 07:00 08:30 CMT_CSG LD cement head. Rotate out & LDLJ. RD casing elevators & tools. RU floor to run DP. Wash down diverter stack. 02/09/99 08:30 10:30 PRB_CJO PU TAM Combo Tool. RIH on 5" DP. Circulate out contaminated mud. 02/09/99 10:30 13:30 PRB_CJO Drop 1.25" ball & circulate to seat. Test to 1000 psi, OK. Open TAM port collar at 1012'. Circulate B out contaminated mud & cement thru port collar. After circulating o.~ 110 Bbls, about two 12-1/4" annular volumes, flutes in FMC Gen 5 hanger packed off & returns ]3roke around conductor in cellar. 02/09/99 13:30 15:00 PRB_CJO PU & Close port collar. Test to 1000 psi, OK. Hold upstrain & shear ball at 2100 psi. Release=tool & B drop below port collar. Circulate casing clean. POH. LD & redress Combo Tool. 02/09/99 15:00 17:30 PRB_CJO ND diverter system. Washed mud & cement out of riser, annular, & knife valve. Greased top& B bottom flanges & set back on stump. 02/09/99 17:30 19:30 PRB_CJO Clean up cellar. Stab bar thru flutes in hanger & wash out contaminated mud in flutes. Cut window in B conductor to get 1" CS Hydril tubing into annulus. (Note: Flutes in FMC Gen 5 hangers will only pass 1.25" max OD - 1" CS Hydril connections are 1.60" OD, 1.315" OD pipe body. Hangers need to be modified to allow 1" CS Hydril to pass, & to greatly increase flute bypass area - very prone to packing off.) 02/09/99 19:30 22:00 PRB_CJO Stab 1" tubing thru window cut in conductor & run to 120'. Washed down each joint & circulate B annulus clean with water. 02/09/99 22:00 24:00 PRB_CJO PU TAM Combo Tool. RIH - push stands in. Circulate out contaminated mud with water; taking B returns into cellar & pumping to CPM. 02/10/99 00:00 04:00 PRB_CJO RIH with TAM Combo Tool, pushing thru contaminated mud. POH 3 stands & LD tool. RIH open B ended below port collar. Circulate out contaminated mud with water. POH. Cleaned mud out of Combo Tool. RIH with Combo Tool. Displace casing to 10 ppg mud. 02/10/99 04:00 06:00 PRB_CJO Drop ball & circulate down. Test to 1000 psi. Shift open port collar at 1012'. Circulate out B contaminated mud & cement from annulus thru port collar. Take returns into cellar & pump to CPM. Circulate water thru 1" CS Hydril tubing to lift & thin out returns. Circulated annulus clean. 02/10/99 06:00 08:00 PRB_CJO Dowell pump 15 Bbls water spacer. Mix & pump 10.7 ppg AS III LW Cement until getting good, clean B 10.7 ppg cement returns to surface thru port collar. Pumped 110 Bbls of Cement, started getting cement returns at about 65 Bbls pumped. Pump 1-1/2 bbls water behind to clear line to head pin. Rig displace DP with 18 Bbls mud. PU & closed port collar. Shear out ball holding light up strain. Release tool. Drop below prt collar & circulate DP & casing volume. CIP at 0700 hrs. 02/10/99 08:00 10:00 PRB_CJO LD 1" CS Hydril tubing. Start POH with DP, had cement coating inside DP. Screw in with top drive & B circulate DP & casing clean with water. POH. LD TAM Combo Tool. 02/10/99 10:00 12:00 PRB_CJO Clean out cellar. Weld up windows cut in 16" conductor. Fill top of conductor to windows with 02/10/99 12:00 14:30 NU_ND NU FMC Gen 5 "split speed heads". Test seal to 1000 Psi for 10'minutes. NU BOPE. 02/10/99 14:30 15:00 PREP RU test tools. 2 Page 3 Well Narne:l C-18 Rpt Date Beqin End Time Time TvpeO~ 02/10/99 15:00 18:30 BOPE Test BOPE: All rams, valves, lines, upper & lower IBOPs, safety valves, & choke manifold to 300 psi & 5000 psi; Annular to 300 psi & 3000 psi. Test accumulator. Witnessing of test waived by Lou Grimaldi, AOGCC Field Inspector. 02/10/99 18:30 19:30 RIGS Service rig. Change out saver sub. Blowdown lines. 02/10/99 19:30 21:30 BHA PU BHA #3. Orient tools & program LWD tools. RIH with HWDP. CBU. 02/10/99 21:30 22:00 PREP Pre-job safety meeting. RU to PU more 5" DP. 02/10/99 22:00 24:00 TRIP_IN RIH- PU 5" DP. Circulated out thick mud at 2293'. 02/11/99 00:00 03:00 TRIP_IN RIH PU DP to 3271'. CBU. RIH. Break circulation at 4208'. Tag cement at 4690'. 02/11/99 03:00 04:00 CLN_OUT Clean out cement to 4708'. CBU. 02/11/99 04:00 06:00 TEST RU test equipment. Blowdown top drive. Test casing to 3000 psi for 30 minutes, lost 30 psi. 02/11/99 06:00 07:30 CLN_OUT Drill out cement & float equipment. Clean out rathole. Drill 20' of new hole to 4846'. 02/11/99 07:30 09:00 ClRC Circulate hole clean & change over to new 8.4 ppg mud. 02/11/99 09:00 10:30 EVAL RU test equipment. Blowdown top drive. Test formation - broke down at 1219 psi, 13.8 ppg EMW. Blowdown choke & kill lines. 02/11/99 10:30 16:00 DRIL Drill to 5641'. (5.43 ADT). 02/11/99 16:00 16:30 RIGS Service rig. Reset SCR breaker. 02/11/99 16:30 17:00 ClRC Restart Sperry Sun tools. 02/11/99 17:00 24:00 DRIL Drill to 6385' MD; 5474' TVD - & drilling ahead. (4.85 ADT). 02/12/99 00:00 09:00 DRIL Drill from 6385' to 7274'. (6.95 ADT). 02/12/99 09:00 10:30 ClRC Circulate out gas cut mud from connection at 7225'. Monitor hole, very slow flow. CBU, 9.0 ppg mud gas cut to 8.1 ppg. 02/12/99 10:30 11:00 DRIL Start raising MW to 9.4 ppg & drill stand down to 7320' MD, 6086' TVD. (0.38 ADT). 02/12/99 11:00 13:00 ClRC Circulate 9.4 ppg mud around. Monitor 15 minutes, no flow. CBU, no heaving, light foaming. 02/12/99 13:00 16:00 DRIL Drill to 7575' MD, 6305' TVD. (2.52 ADT). Base HRZ at 7416' MD, 6194' TVD; K1 at 7527' MD, 6273' TVD. 02/12/99 16:00 17:30 ClRC Circulate hole clean. Monitor hole 15 minutes, static. CBU, some light foaming. 02/12/99 17:30 19:30 WlPERTR Pump out 5 stands. Pull 25 stands wet, into 9-5/8" shoe. 02/12/99 19:30 20:30 RIGS Service rig & top drive. 02/12/99 20:30 22:00 EVAL Circulate once around at shoe. Test formation integrity: Leaked-off to formation at 662 psi with 9.5 ppg mud; 12.4+ ppg EMW. RD test equipment. 02/12/99 22:00 23:00 RIGS Cut off 96' of drilling line. 02/12/99 23:00 24:00 WlPERTR RIH. 02/13/99 00:00 01:30 WIP~RTR RIH. 02/13/99 01:30 02:00 CI~C Circulate Io-visc sweep around. Mud gas cut to 7.6 ppg on bottoms up, circulate out same. 02/13/99 02:00 02:30 DRIL Drill from 7575' to 7585' MD, 6312' TVD. Start increasing MW to 9.8 ppg. 02/13/99 02:30 03:30 ClRC Circulate & weight up to 9.8 ppg. 02/13/99 03:30 04:00 OTHER Monitor hole, slow flow. 02/13/99 04:00 07:00 CIRC CBU, slight gas/air cut. Weight up to 9.9+ ppg. 02/13/99 07:00 07:30 OTHER Monitor hole, slow flow. 02/13/99 07:30 08:30 ClRC Circulate 720 Bbls. No gas cut. 02/13/99 08:30 12:00 TRIP_OUT Circulate out 5 stands. Monitor hole. Pump slug. POH 25 more stands into 9-5/8" shoe. Monitor hole. POH. 02/13/99 12:00 12:30 RIGS Service rig. 02/13/99 12:30 15:30 TRIP_OUT POH. LD 5" HWDP & 6-1/4" DC. 02/13/99 15:30 16:30 BHA Down load LWD tools. LD LWD tools & mud motor. 02/13/99 16:30 17:00 PREP RU to run casing. 02/13/99 17:00 17:30 SAFETY Pre-job safety meeting on running casing. 02/13/99 17:30 24:00 CASG Run 7" casing. Circulated casing volume at 4600'; lost 25 Bbls mud. (140 joints in hole at midnight - 42 jts more to run.) 02/14/99 00:00 02:30 CASG Run 7" casing. CBU at 6200'. Ran 182 joints. MU FMC hanger & landing joint. Land hanger, shoe at 7578'. MU cement head & line. Well Na .me:l C-18 Page, Be~in End RptDate .Time Time TvDeO~ 02/14/99 02:30 05:30 CIRC Break circulation & slowly increase rate. Reciprocate casing, 240K# Up, 180K# Down. Losing mud initially, slowly increased rate to 5 BPM with no losses. Started losing mud at higher rates, so staye¢ at 5 BPM. Circulate & condition mud & hole for cementing. Circulated 879 Bbls. Lost 182 Bbls total while running & circulating casing, before cementing. 02/14/99 05:30 07:30 CMT_CSG Dowell flush lines with 5 Bbls water & test to 4250 psi. Pump 20 Bbls ARCO pre-flush &40 Bbls, 12. ppg ARCO Spacer. Drop bottom plug. Mix & pump 170 sx, 35 Bbls, 15.8 ppg Class G Cement (+additives). Drop top plug. Chase plug with 20 Bbls wash-up water. Switch to rig pump & displace with mud, 5 BPM. Bumped plug. Pressured up to 2000 psi & held 5 minutes, OK. Bled off & checked floats, OK. Reciprocated casing. Landed on hanger 10 Bbl~before bumping plug. Lost about 10 Bbls mud before spacers & cement reached the shoe, full returns thereafter. CIP @ 0715 02/14/99 07:30 08:30 CASG LDLJ. RD cement head & lines. RD casing elevators & bails. RU DP elevators & bails. Set FMC 7' packoff. 02/14/99 08:30 13:00 BOPE Change upper pipe rams to 3-1/2" x 6" variables & lower pipe rams to 3-1/2". Change out saver sub. RU test equipment. 02/14/99 13:00 16:00 BOPE Test BOPE: Annular to 300 psi & 3000 psi; Rams, safety valves, lines, & choke manifold to 300 psi 5000 psi. Test accumulator; Witnessing of test waived by Lou Grimaldi, AOGCC Field Inspector. 02/14/99 16:00 16:30 PREP RD test equipment. Blowdown lines & choke manifold. 02/14/99 16:30 17:00 RIGS Service rig. 02/14/99 17:00 17:30 PREP RU to PU DP & BHA. 02/14/99 17:30 19:30 BHA Pre-job safety meeting on PU BHA & loading RA sources. PU BHA. Program LWD tools. Load RA sources & RIH. 02/14/99 19:30 24:00 TRIP_IN RIH PU 4-3/4" DC; 3-1/2" HWDP; & 3-1/2" DP. Fill & test LWD tools. Continue RIH PU DP. 02/15/99 00:00 04:00 TRIP_IN RIH PU 3-1/2" DP. 02/15/99 04:00 05:00 CIRC CBU. 02/15/99 05:00 06:30 TEST RU test equipment. Test 7" casing to 3000 psi for 30 minutes, lost 20 psi, OK. RD test tools. 02/15/99 06:30 09:30 CLN~OUT Tag cement at 7484'. Drill out cement, plugs, & floats. Clean out rathole to 7585', 02/15/99 09:30 11:00 CIRC Circulate hole clean & change over mud to 10.8 ppg mud. 02/15/99 11:00 11:30 DRIL Drill 10' of new hole to 7595'. 02/15/99 11:30 12:30 CASG Circulate hole clean & balance out mud to 10.8 ppg. 02/15/99 12:30 13:00 PREP Pull back into shoe. RU test equipment. 02/15/99 13:00 14:00 EVAL Test formation to 1420 psi with 10.8 ppg mud. No leak-Off; 15.1+ ppg EMW - FIT. 02/15/99 14:00 14:30 RIGS Service rig. 02/15/99 14:30 21:30 DRIL Drill from 7595' to 7652'. (4.5 ADT). 02/15/99 21:30 22:30 OTHER Short trip 3 stands into casing. Wash & ream back into hole; to clean off bit if balled up (slow ROP). 02/15/99 22:30 24:00 DRIL Drill to 7656' MD; 6362' TVD & drilling ahead - still slow ROP. (0.57 ADT). 02/16/99 00:00 00:30 CIRC Pump pill 02/16/99 00:30 01:00 ClRC Monitor well 02/16/99 01:00 02:00 PRB_EFC Repair rotary brake on topdrive 02/16/99 02:00 05:00 TRIP_OUT POOH 02/16/99 05:00 07:00 BHA Down MWD M/U new bit 02/16/99 07:00 09:30 TRIP_IN RIH 02/16/99 09:30 10:00 RIGS Service rig and topdrive 02/16/99 10:00 24:00 DRIL Drill from 7656' to 8005' 02/17/99 00:00 03:00 DRIL Drill from 8005' to 8095' 02/17/99 03:00 04:00 ClRC CBU monitor well 02/17/99 04:00 05:00 WIPERTR Pump out of hole 6 stands to shoe. Monitor well. RIH 02/17/99 05:00 06:30 . ClRC Circ and condition mud 02/17/99 06:30 07:00 SURV Drop survey 02/17/99 07:00 08:00 TRIP_OUT Pump of hole to shoe (5 stands), monitor well, pump pill. Pull 5 stands-3bbl fill. Pull 5 stands- 1 bbl gain. Monitor well-very slight flow. 02/17/99 08:00 08:30 TRIP_IN RIH. Fill pipe flow show increased from 42% to 54% 02/17/99 08:30 11:30 OTHER Shut well in. SIDP=100 psi. $1CP=160 psi. Gained 3 bbl in pits. Circ well on choke for 2700 strokes Open well-no flow 02/17/99 11:30 14:00 ClRC Circ and raise mw to 11.1 .ppg decrease viscosity ~ ---- Page 5 Well Name:l C-18 Rpt Date ~ End Time Time TvpeO~ 02/17/99 14:00 14:30 OTHER Monitor well 02/17/99 14:30 15:30 CIRC CBU 02/17/99 15:30 16:30 TRIP_OUT Pump out of hole 10 stands 02/17/99 16:30 17:30 OTHER Monitor well and flush/blowdown choke manifold. Pump pill 02/17/99 17:30 20:30 TRIP_OUT POOH 02/17/99 20:30 22:30 BHA L/D hwdp and dc. 02/17/99 22:30 24:00 BHA Retrieve sources. Download mwd 02/18/99 00:00 01:00 BHA L/D bha, D/L mwd 02/18/99 01:00 01:30 CEMENT M/U cement head 02/18/99 01:30 02:00 CEMENT R/U floor for liner job = 02/18/99 02:00 02:30 OTHER Hold pre-job safety meeting ,, 02/18/99 02:30 04:30 CASG P/U 23 jts 4-1/2" liner and liner hanger 02/18/99 04:30 11:30 CASG RIH w/4-1/2" liner to shoe 02/18/99 11:30 13:00 CIRC CBU 02/18/99 13:00 14:00 CASG RIH to 8095' 02/18/99 14:00 15:00 CIRC Circ and condition mud 02/18/99 15:00 15:30 CEMENT R/U cementers 02/18/99 15:30 16:30 CEMENT Flush lines w/5 bbl water. Test lines to 5000 psi. Pump 10 bbl prewash. 300 bbl spacer @ 13.0 ppg, 26 bbl cement @ 15.8 ppg. Displaced w/5 bbl water & 43.4 bbl mud w/rig pump CIP @ 16:25 02/18/99 16:30 17:00 CEMENT Set liner hanger w/3200 psi. Check floats-OK. Set liner top packer w/4200 psi. Released running tool from liner. Pressure up to 1000 psi and sting out of liner. Pump 20 bbl and pickup above TOL. Reverse out. Recovered 7 bbl cement and contaminated mud, spacer and water cut mud. 02/18/99 17:00 18:00 CIRC Circ hole clean. 02/18/99 18:00 24:00 TRIP_OUT POOH, L/D 3.5" D.P. 02/19/99 00:00 01:00 CEMENT L/D liner running tool and cement head 02/19/99 01:00 01:30 BOPE Pull wear bushing 02/19/99 01:30 02:00 OTHER Safety meeting 02/19/99 02:00 09:30 RUN_COM Run 4-1/2" tubing and jewelry 02/19/99 09:30 10:30 RUN_COM Stab into packer and verify spaceout 02/19/99 10:30 12:00 CI'RC Reverse out to displace mud w/freshwater 02/19/99 12:00 13:00 TEST Test casing to 3500 psi for 30 min. 02/19/99 13:00 14:00 OTHER Freezeprotect tubing and tubing x casing annulus w/82 bbl diesel 02/19/99 14:00 17:00 RUN_COM Spaceout land tubing. Test tubing and tubing x annulus to 3500 psi - 10 min. L/D landing jr. Set back P ~ressure valve. 02/19/99 17:00 19:00 OTHER Freeze protect 9-5/8" x 7" annulus w/300 bbl water and 70 bbl diesel @ 1/4 bpm to 6 bpm w/400-800 psi. SIP= 750 psi 02/19/99 19:00 24:00 NU_ND N/D BOPE. Remove all rams from preventers. Prep BOPE for removal from cellar 02/20/99 00:00 13:30 NU_ND N/D annular from BOP stack, L/D risers, L/D diverter, breakdown BOPE components and set outside. Clean pits 02/20/99 13:30 14:30 NU_ND N/U xmas tree and test to 5000 psi. Continue cleaning pits 02/20/99 14:30 16:00 TEST Perform LOT on 9-5/8" x 7" annulus @ .5 bpm w/breakdown @ 860 psi. SI pressure - 800 psi. LOT = 11.0 ppg emw. Continue cleaning pits 02/20/99 16:00 20:00 MIRU Finish securing cellar. Service choke manifold. Prepare floor to I/d drillpipe 02/20/99 20:00 21:00 RIGS Service rig and topdrive 02/20/99 21:00 24:00 TRIP_OUT L/D 5" d.p. out of derrick 02/21/99 00:00 03:00 TRIP_OUT Finish L/D 5" d.p. out of derrick 02/21/99 03:00 12:00 OTHER Clean pits and floor. Move camp to West Sak Pilot Pad. Release rig @ 12:00 hrs 2/21/99. 02/21/99 12:00 14:00 MIRU Finish tranferring water from boiler and water lines to CPM 02/21/99 14:00 15:30 MIRU Prepare rig for move. Skid rig to center of module and secure storm clamps. Raise cellar box and secure 02/21/99 15:30 18:00 MIRU Finish injecting into lC-15 w/150 bbl water and 75 bbl diesel @ 2-4 bpm w/1500 psi. Jack up.drill module and set on crib blocks. Raise stomper and secure. Move drill module out and spin lampSons 180 deg. Well Name:lC-18 Page6 R~t Date Be~in End Time Time Tv~eO~ 02/21/99 18:00 20:00 MIRU Move CPM to West Sak Pilot Pad @ 17:30. Jack up utility Module, move out and spin lampsons 180 deg. Move to end of pad. 02/21/99 20:00 24:00 MIRU Leave pad w/utility moduel. Move 1.8 mi. Move drill module down pad. Right brake on #1 lampson locked-working on same. 02/22/99 00:00 02:00 MIRU Repair brake pump on #1 Lampson right track 02/22/99 02:00 08:00 MIRU Move drill module from 1C pad to KOC 02/22/99 08:00 12:00 MIRU Move drill module from KOC to 1D pad 02/22/99 12:00 13:30 MIRU Move drill module from front of 1D pad to back of 1D pad 02/22/99 13:30 15:30 MIRU Service Lampsons and fuel same 02/22/99 15:30 21:00 MIRU Move drill module from 1D pad to West Sak Pilot Pad 02/22/99 21:00 24:00 MIRU Move drill module and set on matting boards 02/23/99 00:00 02:30 MIRU Let stomper down. Set drill module. Jack floor out. Set cellar down. Mate up utility module 02/23/99 02:30 07:00 MIRU Put curtains down on lampsons. Change flat on CPM module. Turn steam on drill module 02/23/99 07:00 12:00 MIRU Slip drilling line on drum to laydown top drive. Start stripping top drive 02/23/99 12:00 24:00 MIRU Clear floor of subs, sub racks and tongs. Prep top drive for removal. L/D service loop for topdrive. Removed balls from ball mill. 02/24/99 00:00 06:00 MIRU Finish locking topdrive into L/D skid. L/D cement standpipe and hose, L/D stabbing board. Pull "C" section in and latch in place. Hook up I/D lines to topdrive 02/24/99 06:00 12:00 MIRU Finish prepppping top drive for removal. Secure vibrator hose to derrick. Unpin skid guide and throat from rig and pull forward. Welder cut blue room and MWD shack loose and crane set on ground. 02/24/99 12:00 18:00 MIRU Pull windwalls off floor, set off topdrive, set compensator off floor, set fuel tank off top of motor room, 02/24/99 18:00 19:00 MIRU Safety meeting w/all personnel. Discussed final stackout and schedule of events. 02/24/99 19:00 24:00 MIRU Rig managers inspected derrick prior to laying same down. 02/25/99 00:00 03:00 MIRU Pre derrick to laydown. Grease sheaves. Secure lines to derrick 02/25/99 03:00 06:00 MIRU Prep drill module to laydown derrick. Check drawworks tie-down bolts 02/25/99 06:00 10:00 MIRU Finish prepping derrickto laydown. Hold safety meeting. Laydown derrick 02/25/99 10:00 18:00 MIRU Continue storing tools and equipment. 02/25/99 18:00 21:00 MIRU Continue stacking rig 02/26/99 00:00 24:00 MIRU Continue stacking rig 02/27/99 00:00 24:00 MIRU Continue stacking rig 02/28/99 00:00 24:00 MIRU Continue stacking. Had walk through with Dan Graika, AAI Environmental Rep. 03/01/99 00:00 24:00 MIRU Continue stacking rig APC moved brine tanks away from rig. Skid rig and jack up modules. Move modules awav 1C-18 Proximity in Horixontal Plane 1/4 Mile Radius @ Surface Casing Shoe (4817~ MD /4241~ SSTVD) --1321 1240 3~ 0 827 413 --0 413 20 :827 1240 ~1321 21 ~0 Reference Azimuth Angle [deg] vs Centre to Centre Separation [fi] ARCO Alaska, Inc. A PBR (6799-6800, OD:3580) PKR OD6156) (6820-6821, OD:3500) OD:6156) MaadrelNalve 2 (6945-6946, 00:5793) Peal (6970~972) PKR OD:6156) GKA 1C-05 1C-05 SSSV Type: 500292055000 TRDP-1A~SSA Orig Completion:12/27/81 -Angle @ TO 1~4 deg @ 7753 Last W/O:13/11/90 Rev Reason: ~ylmoTag fill, set new CVs AnnularFluld: Date: I Last Update: J 3127100 Last Tagi Z~ ~ (WLM) 7783 ffKB j 3/26/00 7300 Size Bottom TVD 16000 0 75 75 Size Bottom TVD 10750 0 2782 2695 Size J Bottom TVD 7 000 0 7723 7024 Size Top Bottom TVD 3 500 0 6854 6302 3 500 6854 7203 6596 Interval I TVD 6970-6972 , 6402~6404 7046-7118 i. 6466-6526 7442-7454 I 6792-6802 7466-7488 ! 6812-6830 Closed 22 TVD Man Mfr TVD Man Description 18241 SSSV Camco TRDP-1A~SSA Thread Thread Grade Thread K-55 Thread J-55 EUE 8RD MOD EUE 8RD MOD Comment d Jet 5" Vann Guns TRO Date Run 0 8/31/91 TRO Date J Run 01 3/26/00 0 3/26/00 PKR JBaker'HB'RETR Otis 'X' PACKOFF i Tri State 'PIP' Pack Off Assembly; Run on 3/9/90 TOP CUT i Top of 3 1/2" Cut-Off Tbg Stub OFF STUB i Baker 'FHL' SOS iBaker PLUG 1Camco CA-2 Plug 2.992 NIP iCamco'D'N TTL i Description Comment 2 5/8" WA Chem Cut;er Left in tail ~e above CA-2 from workover Date Note rUBING STRING @ 6854' on Down Le6 in Hole 6 Previous Completion (4/15/85) Tri.State HP Pack Off Assembly Run on 3/9/90 ~'~, 6853' SOS OD:3500) (7442-7454) Perf (7466-7~8) .tlanticRichfieldCompany -', · Drilling-Completion-Workover Log · ~'Time distribution - hours J IRig up and tear down Drilling n. ormal. Directional drilling Reamin~ Trips to change,bit .Drilling with partial' returns. ,Combatin. g lost circulation Conditionin and circulating Fishing Deviation Lubricate. rig , Cut off drilling line Repair rig · Test casing or B.O.P-. Eve IDrill stem test . open hole . Wire line . logging open IPluggi'ng back · Running casing and cementing Waiting on cement Logging cased hole -. Perforating Wi re line formation test cased hole Drill stem test cased hole Testing Swabbing Acidizing Fracturing Tubing trips Other Totals ,ts Feet IWeight I~rade I Th~ad IClas.~; . Size O.D. casing Time sumi~ary . Shoe I / I¢0 IDaywOck '~' Setjoint.~ [ .e,e~¢,¢~ k8 I.oursw/Op Collar I / ~0/H°urs 'wO/d" Oointsp,pe~7 ~¢~ ~.ours'sta.d~y ' . Total' ;;:tth~~~ ~ ~ ~l,otalda;work' SCANNED JUN2 5- ?r 0-2 ................... AtlanticRichfieldCompany ~ Drilling Report ---'Daily Days .... J SiZe & Depth Last CSG " , Dale~.~.~ Formation actor _ J Depth Today v {Depth Yesterday J Progress ~ud [W~ight '[Vis. IP.V~ [~P[ IGe'l~. [ph. ' IW.L. 'lCak~ I Chi, Isa~d so~. Io,', I Temp Data Pump ]No. & Type Liner Size JSPM JGPM IP.S.I. - INoz. Vel. 3A.V. - D.P. A.V. - D.C. ISIow Pu~p Rate Data Bit NO, Size JMak ~ ~Type . ISN l Jets ]Depth In I ~pth Out IFeet . IHrs, ~RPM ]WT.-M ]Condition ' ' ! ANGLE DIRECTION T.V.D. TOTAL COORDINATES VERT. SEC. NORTH/SOUTH EAST/WEST Angle .... Direction . .. ANGLE/DI RECTI ON FROM LAST SURVEY POINT · _ TO TARGET TIME Iq3o _Z~0o OPERATIONS FROM 0600 TO 0600 . ' ~"~',,~,V,," '~-', 99L', I b~. ~ z~q, ~~ c~x ~, T~ ,~oo ps', _ . CHECK THIS BLOCK IF SUMMARY CONTINUED ON BACK Ser.' Pers. %~) Loc: . I- Diesel on Loc. "~..._% _ ""z...t. 0 ,J Temp. I C.F. ~.~-', ~ 0,~>~o I ~ '/..~. ~ '~ ~c~o,~ ~' ~~!~'''d'nt' ~DateLast ~DateLa,t .OP IKick Drill I Test IDiesel Used IDiesel Rec'd. IGas ~sed (MCF) ~r Rec'd. - From ' ' I~,q~ I I~,~ ~ I~ ~ ~ i~q ~,~ ~ TIME OPERATIONS LAST 24,. HRS. CONT'D: WELL NUMBER DESCRIPTION OF KICK DRILL: [] WHILE PULLING PIPE .o .A SIGNED DATE MORN lNG TOU R -- WELL CLOSED IN EVENING TOUR --WELLCLOSEB IN WHILE RUNNING PIPE SECONDS, ON STATION SECONDS, ON STATION SECONDS SECONDS WHILE DRILLING DESCRIPTION OF ACCIDENT: NAME Of INJURED EMPLOYER DATE REPORT FILED ~tlantiCRichfieldCompany -,~ Drilling-Completion-Workover Log Init or lease 'ield :oun~ or parish ;ontractor ~ Time distribution - hours ' Eve Rig up and tear down --. Drilling normal Directional drilling Reaming I Province or state ,,q 5 >'Oz.z..ot, O$ · qq. 06 14,Z Trips to chang, e~bit .. > Drilling with partial returns Combating lost circulation Conditioning mud and circulating Fishing $~/Z. 75 76z$.~o :Deviation surveyi qo. IZ 7os3.1£ Z'~JK~ ?' 0 6I 77~f'~' O"~ ]Lubricate rigI 'Cut off 4~0. Sq '70'.~. q7 drilling line ~. ~ ~OO ~.q~ i Repair rig Test casing or B.O.P. Sid.e'.xwali ;.:, .-.~,., ..£ .i · . Conventional Diamond Wire line Drill stem test open hole Wire line ' logging open Plugging back Running casing and cementing Waiting on cement Logging cased hole Perfor, a~.ing~ .. - ; . 3.5 /5 O3 31',,-ZO< ',"' 3/.Zo %',_ Wire lineformation test cased hole Drill stem test cased hole Testing Swabbing Acidizing Fracturing Tubing trips Other ;' : ~ . ~ ... - _. , '. ~ -.. . '-." .. ~i3B.22a:B' Thread J/pT 8u~. Class r . Totals Size O.D. casing Time summary Day work Hours w/dp i Hours wo/dp 'Hours standby Shoe Set joint Coilm, Joints pipe Total Rkb to I ?$¢ I Dep.th set ,O, ,_ Total day work ... 7 ~,~,~:~ ~,,~= e.- 3 55 ' :.~%,~ .~':. :.. '-:~-v z,.z6 -.--- L. A tlanticR ichfieldCompany .~' Well Contractor ' '- I Si~e & D~pth Last CSG m I -..! .7"~- 77z $ ' I I Depth'Toda'~ IDepth Yesterday d'peration at 0600 . - · .IDaily Cost I A s I Accum. MUd Cost L¢~¢/,/o CBL ~ 1~ Z-3.~/8/~h' 7~~'~ I /3 ¢ 7/3 ~IPump INc. & Type:p~.9 i S{~¢lLi"er'ze I1' II .. I"" ' Ihi ' '"' ~'v" ~" "i ~'v'- =' I ~ ' . BOTTOM HOLE ASSEMBLY: (INCLUDING DRILL PIPE SIZE.& GRADE) / - TOTAL COORDINATES M.D. ANGLE DI RECTI ON T.V.D. V E RT. SEC. .. TIME OPERATIONS FROM 0600 TO 0600 NORTH/SOUTH EAST/WEST ANGLE/DI RECTION FROM LAST SURVEY POINT TO TARGET Angle Direction :'~ ~ - ~ CHECNTHIS BLOCK IF SUMMARY CONTINUED ON BACK ' I Date Date Last BOP ger. Pets. on Loc: Accidents . Kick Drill/ Die~el on I.oc5 w [Diesel Used ~ '~4Diesel 'Rec'd.~ ' ]Gas ~J ~ [W~'d. - From ' 3~53~ I 3~$ I /oooo I 7ZOo-- /i _q~o C~mp ~o~ Tamp C.F. I Visibility [W, ndW,. TIME OPERATIONS LAST 24 HRS. CONT'D: 0~o- 04~ 0 WELL C...¢ NUMBER DESCRIPTION OF KICK DRILl_: [] WHILE PULLING PIPE [] MORNING TOU R- WELL CLOSED IN [] EVENING TOUR --WELL CLOSED IN DATE [] WHILE RUNNING PIPE [] WHILE DRILLING SECOND'S, ON STATION SECONDS SECONDS, ON STATION SECONDS DESCRIPTION OF ACCIDENT: NAME OF INJURED DATE REPORT FILED EMPLOYER AtlanticRichfieldCompany ~ We l I ISize & Depth Last CSG 7"~. . Drilling Report-- Dai~y Contractor I Depth Today Operation at 0600 , . [ Daily Cost = i.,. I~a~2oz VelChI' Pump [NO. & Type '[Liner size . ISpM I~ I .s.. I ' ' Depth Yesterday A.V. - D.P. DRLG Time I i ~C._.~st~ Accum. Mud Cost Acc m Z3~· I )3 ~ 7 13 Sol. Oil Temp Pit IF.L. A.V. - D.C. Slow Pump Rate Accum. Rot. BOTTOM HOLE ASSEMBLY: (INCLUDING DRILL PIPE SIZE & GRADE) /~fO~)~ · - TOTAL COORDINATES DIRECTION VE RT. SEC. M,D. ANGLE T.V.D. NORTH/SOUTH EAST/WEST ANGLE/DI RECTION FROM LAST SURVEY POINT iTO TARGET Angle .. Direction TIME 1'530- ,0130 OPERATIONS FROM 0600 TO 0600 ~ CHECK THIS BLOCK IF SUMMARY CONTINUED ON BACK ~ " Set. Pars. on Loc: .~I Accldents~ DateLast ;DateLast BOP TIME OPERATIONS LAST 24 HRS, CONT'D~ WELL NUMBER ? ?/4 DESCRIPTION OF KICK DRILL: [] WHILE PULLING PIPE [] MORNING TOUR--WELL CLOSED IN [] EVENING TOUR IWELL CLOSED IN [] WHILE RUNNING PIPE [] WHILE DRILLING SECONDS, ON STATION SECONDS SECONDS, ON STATION SECONDS DESCRIPTION OF ACCIDENT: NAME OF INJURED DATE REPORT FILED EMPLOYER >m-:~ING~ I TUBING I LINE'R - __ , DR,,.L ,E ~, ' ~' DATE ARCO Alaska, Inc. ,~w Page '/ / Subsidiary of AtlantlcRichfleldCompany . of pages .- w/ #ITEMS COMPLETE DlSCRIPTION OF EQuIpMENT RUN LENGTH DEPTH o~,'~,'/o~/A','~ ~/¢/~ - /g~a~ ~,'~ ~.?~ ,~7. ~o ~,, ~ .- , ~,~s' ~,~, , " " _. : Z~,-54~t~ E;-~. ~ ~, ~~- /s ~oa~d. ARCO PM 1 18 I~.rvso-supe i--r - ~ PHILLIPS Alaska, Inc. A Subsidiary of PHILLIPS PETROLEUM COMPANY (1909-1910, 0D:3.500) (0-6288, 0D:3.500, ID:2.992) Gas Uti landrel/Dummy Valve 1 (6147-6148, OD:5.313) NIP (6180-6181, 0D:3.500) PRODUCTION (0-7034, OD:7.000, Wt:26.00) SBR (6182-6183, OD:3.500) PKR 0D:6.i56) NIP (6253.6254, 0D:3.500) KRU 1C-09 1C-09 APl: 500292085900 Well Type: INJ I Angle @ TS:I 1 deg @ 6371 SSSV Type: TRDP Odg Completion: 11/14/82 i Angle @ TD: I deB @ 7050 Annular Fluid:I Last W/O: 4/30/83 Rev Reason: Tag, pull inj valve, I see damaged SSS¥ I bylmO Reference Log:! Ref Log Date: Last Update: 14/25/01 Last Tag: 16790 TD: ~ 7034 ftKB Last Tag Date: 14/24101 Max Hole Angle: 3 deg @ 3400 I Casing String - ALL STRINGS I Description Size Top Bottom TVD Wt Grade I Thread CONDUCTOR 20.000 0 101 101 92.00 H-40 I SURFACE 10.750 0 2273 2273 45.50 K-55 PRODUCTION 7.000 I 0 7034 7034 26.00 K-55 Tubing String - TUBING Size Top I Bottom 1-VD Wt Grade ~ Thread 3.500 0 I 6288 6286 9.30 J-55 -|' DSS-HTC Perforations Summary Interval I TVD Zone Status I Ft SPFI Date Type Comment 6372-6418 I 6370-6416 C-4,C-3 Open 46 4 11/11/82 IPERF Vann Guns; Perfreference is I ' from old RKB (30.36') 6424-6430 6422-6428 C-2 Open 6 4 I 11/11/82 IPERF Vann Guns; Perf reference is ·J from old RKB (30.36') Gas Lift Mandrels/Valves St MD I -I'VD Man I Man V Mfr VType VOD Latch Port TRO Date VIv MfrI Type I I Run Cmnt !1 I 6147i 6145 Camco KBUG DMY I 0.0 BK 0.000 0 11/15/82 u[ner {plugs, equ,p., etc.) - JEWELh[¥ Depth TVD Type Description I ID 1909 1909 SSSV CamcoTRDP-1A - FLAPPER IS GONE OR DAMAGED (see WSR dated I 2.813 1/24/92) Injection Valve pulled 4/24/01 6180 6178 NIP Camco ¥V-1' Selective Landing 2.813 6182 6180 SBR Otis I 2.813 6207 6205 PKR Otis 'HCL' PERM. I 4.000 6253 6251 NIP Camco 'D' Nipple NO GO J~ 2.750 6286 6284 SOS Vann !2.992 6288 6286 TTL 12.992 I Fish - JUNK in Hole I DepthI Description ~00 J GeoVann Guns 6820 JUNK IN HOLE Comment Left in Hole after Perf E-Line Tools in Hole; Dresser Cable Head, Swivel, CCL, Sinker, Bar, , HP, Temp Tool, Switch, GR & Spinner. Total Length 34' @ 6820' I General Notes Date J Note 10/4/94 l Camco 'TRDP-1A' NOT LOCKED OUT_; See WSR's 10/4/94 & 1/26/93 SOS (6286-6287, OD:3.500) TTL OD:3.500) Perf (6372-6418) Perf (6424-6430) JUNK IN HOLE (682o-6854, OD:1.688) t ~SING/TUBINGILINER DE'; !L DRILL SITE ~ DATE !.1 ARCO Alaska,Inc. ~ Page I of J pages Subsidia~ of AtlanticRichfieldCompany #ITEMS COMPLETE DISCRIPTION OF EQUIPMENT RUN LENGTH DEPTH ~ _~ lo ~A ~5.~~ ~ ~.,-~ ~- ss q~.~z . BOTTOM OF TUBING TAIL ~ Carbonless paper - no carbon required ARCO Oil and'Gas Company '~' IPage I°f ,, Casing, Tub' ,, Line Pipe Tally Store !Date Field reqn. no. ;,,~o. AFE no. From ... Col I Col 2 Col 3 Col 4 Col 5 Col 6 Col 7 Col 8 No Feet Hds No Feet Hds No Feet Hds No Feet Hds No Feet Hds No Feet Hds No Feet Hds No Feet Hds ~ ~' ~z, o~~ ~[ ~ ~ qo ,0~ ~o~ ~ ~ ~ ~ Vy 2~ ~ q III ~" qO q& 79 104 120 154 179 18 ~ ~0 43 3~~ 68 93 ~118 143 168 193 19 ~ ¢ /~ 44 ~/ ~ 7 69 94 119 144 169 194 21 q/ C/ 46 qO ~ 71 96 121 ,46 171 196 22 ~ :~ 47 ~ 7 ~ 72 ~7 122 147 172 197 23 3 9 ~0 48 ~ ~ ~Z 73 98 123 148 173 198 · . _ 24 3~ Zq 49 ~ /¢ 74 99 124 ,149 174 199 ~ ~ ~ 50 ~[ ¢7 75 100 125 150 175 200 I Col1 /o[Ft this~page~ Pgl Joints this order~ CarrierTallied ~. ~ ~ ~ ~ Received~ ~ 1 ~bY TruCk no. ' Directions __ 5 Feet this order I~T I~ ARCO Alaska, Inc. ,~, Subsidiary of AtlanticRichfieldCompany Well lc_-':) Co~tractor JSize & Depth Last CSG Depth Today IDays Actual Drilling Report -- Daily TOTAL COORDINATES Pump Data ~it Nc N O RTH/SOUTH M.D, ANGLE DIRECTION T.V.D. Date JFormatiofi EAST/I JAccum. Mud Cost ' A.V. - D.C. I I Temp Pit IF.L. Slow Pump Rate Condition l, ! ~z~ Accum. Rot. Hrs, ANGLE/DI RECTION FROM LAST SURVEY POINT iTO TARGET Angle Direction I TIME J OPERATIONS FROM 0600 TO 0600 I I ' E~ r - Set. Pers. on~/_oc: Accidents Diesel on Diesel Used (~CF) / Date Last Kick Drill Water Rec'd From G Date Last BOP Test '/~/~. TIME OPERATIONS LAST 24 HRS. CONT'D: WELL DESCRIPTION OF KICK DRILL= [] WHILE PULLING PIPE SIGNED MORNINGTOUR--WELL CLOSED IN EVENING TOUR--WELL CLOSED IN WHILE RUNNING PIPE SECONDS, ON STATION SECONDS, ON STATION SECON DS SECONDS DATE WHILE DRILLING DESCRIPTION OF ACCIDENT~ NAME OF INJURED EMPLOYER DATE REPORT FILED ARCO Oil and Gas Company Unit or lease Drilling - Completion - Workover Lo! Date Field · District County or parish · Auth. or W.O. No.-- --/' TitJew I Province or sta ] I u~"'Z. ='"rs. 3.22_ I.~1 ~.l.p/ - 2t.)& -??.9 / 13:rT'~ I.~'(,, 2.17. Joints J Feet Weight Grade Thread Class Size O.D. casing Time summary I Shoe Day work Set joint Hours w/dp / Collar Hours wo/dp Joints pipe Hours standby Total Rkb to Depth set Total day work Signed AR3B-228-E SCANi~l~r~ flf~, ~ ~ .... ARCO Alaska, Inc. v Subsidiary of AtlanticRichfieldCompany Drilling Report -- Dmly Well Contractor Operatio~at ~600 Mud [Wei~9~ t [Vis._ [P.V. ' IY.I~. PumpINo. &Type I i · I Data Torque P.U. Wt. '! JGels. JPh. Size & Depth Last CSG7//~ '7 i~ ~" ¢/J ' . J' Days Actual I DaYs Predicted I Date/~ /~ ,,~~, ~~ ~ ¢~/I ~ ~ - '- Accum. Cost iw. . V Ch,. Is~.0 so,. Io,I Temp I I~'~ I~'"' Rot. Wt. DRLG Time Js.o. Wt. JBHA Wt, - Air JBHA Wt. Mud Slow Pump Rate I Condition Accum. Rot. Hrs, BOTTOM HOLE ASSEMBLY: (INCLUDING DRILL PIPE SIZE & GRADE) ? TOTAL COORDINATES ANGLE DIRECTION T.V.D. VERT. SEC. M.D. NORTH/SOUTH EAST/WEST ANGLE/DI RECTION FROM LAST SURVEY POINT TO TARGET Angle Direction OPERATIONS FROM 0600 TO 0600 TIME J Rec'd. I Gas Used Tem p_/ I--:~ I I C'F' I W,.:? CHECK THIS BLOCK IF SUMMARY CONTINUED ON BACK Accidents ~ Date Last IDate Last BOP [ Kick Dr'ill J Test Water Rec'd ~r~m - - TIME OPERATIONS LAST 24 HRS, CONT'D: WELL DESCRIPTION OF KICK DRILL,' [] WHILE PULLING PIPE [] MORNING TOUR -- WELL CLOSED IN [] EVENING TOUR --WELL CLOSED IN [] WHILE RUNNING PIPE [] WHILE DRILLING SECONDS, ON STATION __SECONDS SECONDS, ON STATION SECONDS DESCRIPTION OF ACCIDENT: NAME OF INJURED EMPLOYER DATE REPORT FILED _ : C ;lNG / TUBING / LINER DET, ;..//T~ ~'~J-- :~,~ LJ ~_ DRILL SITE'~ ~'q~ DATE 42~~3 ARCOAlaska,Inc.~r _ _ Paae I of / pages Subsidia~ of AtlanticRichfieldCompany {~E~~0 ~E~[~ ~J~ ~, ~, #ITEMS COMPLETE DISCRIPTION OF EQUIPMENT RUN LENGTH DEPTH ~ ~ ol~O~. ~+ ~~)_ 1'7,~o,oo' x- ov[g F/TSO ~~ [4~%0[e~x ~" 1.85 ' ~8.~ 3~*_- D~a- ~c- J-~s q,~.T8e YoP 7,~' 46,3~ -c~m~ S~sv m~e- ~A ~o~ ~O~h, I O,~t'IqOq,~8 Cgm~ 1~)-I ~)tP~t E - ~,~. ~.~ &18o,00¢ BOTTOM OF TUBING TAIL d . I d , PHILLIPS Alaska, Inc. A Subsidiary of PHILLIPS PETROLEUM COMPANY Post Office Box 100360 Anchorage, Alaska 99510-0360 P. Mazzolini Phone (907) 263-4603 Fax: (907) 265-6224 June 21,2002 Ms. Cammy Oechsli-Taylor Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 W. 7th Avenue, Suite 100 Anchorage, Alaska 99501 RECEIVED JUH 2 i 20.2 Anchorage Subject: lC-18 Application for Sundry Approval Dear Commissioner: Phillips Alaska, Inc. hereby files this Application for Sundry Approval for annular disposal down the Kuparuk lC-18 well. This well has been permitted for annular disposal in June of 1999 and expired in June of 2000. Currently, there is 379 bbls disposed in the well. If you have any questions regarding this matter, please contact Tom Brockway at 263-4135. Sincerely, P. Mazzolir~i Drilling Team Leader PAl Drilling Note to File Well 1C-18 PTD 199-005 Sundry 302-194 Phillips Alaska, Inc. (PAl) requests approval for annular disposal in the subject well. This note analyzes information submitted by PAl and recommends approving PAl's request for annular disposal. Well 1C-18 was permitted for annular disposal June 1999. Annular disposal permission expired June 2000 after 379 bbls disposal. 9-5/8" surface casing in 1C-18 was cemented with 490 bbls lead cement followed by 105 bbls tail cement, totaling about 220% excess cement relative to gauge wellbore. Lead cement circulated to surface during initial placement. Successful placement of such volumes of cement indicates that 1C-18's surface casing is adequately cemented. After drill-out to 30 feet below the 9-5/8" shoe, the formation supported a 13.8 ppg EMW leak off test. 1C-18 was then drilled to 7578', where 7" production casing was run and cemented. After drill-out a 15.1 ppg leak off test resulted. An annular (9-5/8" x 7") injectivity test showed a pressure gradient of 13.4 ppg EMW referenced to the 9-5/8" casing shoe. During this test, pressure response departed from linear at about 1350 psi and reached a maximum of 1400 psi. The pressure then dropped and stabilized at about 1250 psi. Shut in pressure stabilized at about 700 psi over 10 minutes. Based upon information submitted, AOGCC recommends approval of Phillips' request for annular disposal in Well 1C-18 (PTD 199-005). Winton Aubert Petroleum Engineer PHILLIPS Alaska, Inc. A Subsidiary of PHILLIPS PETROLEUM COMPANY Post Office Box 100360 Anchorage, Alaska 99510-0360 M. Mooney Phone (907) 263-4574 Fax: (907) 265-6224 April 23, 2002 Commissioner Cammy Oechsli Taylor State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Subject: Report of Sundry Well Operations 1C-18 (199-005) Dear Commissioner: Phillips Alaska, Inc. submits the attached Report of Sundry Well Operations for the recent perforation operations on the KRU well lC-18. If there are any questions, please contact me at 263-4574. Sincerely, M. Mooney Wells Team Leader Phillips Drilling MM/skad .'i;'J' i ~-" ~,~.~ Alaska 0il & Eas Con.q, Anchora STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS :l, operations performed: : : : :operationshutdown stimulate Plugging_ Perforate xx :: :: : i : Pull tubing ~ Alter casing_ Repair well _ Other_ 2. Name of Operator Phillips Alaska, Inc. 3. Address P. O. Box 100360 Anchorage, AK 99510-0360 4. Location of well at surface 1476' FNL, 4268' FEL, Sec. 12, TllN, R10E, UM 5. Type of Well: Development __ Exploratory __ Stratigraphic __ Service__X (asp's 562016, 5968759) 6. Datum elevation (DF or KB feet) RKB 102 feet 7. Unit or Property name Kuparuk Unit 8. Well number 1C-18 At top of productive interval 849' FSL, 1455' FEL, Sec. 2, T11N, R10E, UM At effective depth At total depth 4233' FNL, 1638' FEL, Sec. 2, T11N, R10E, UM (asp's 559346, 5971260) 9. Permit number / approval number 199-OO5 / 10. APl number 50-029-22939 11. Field / Pool Kuparuk Oil Pool 12. Present well condition summary Total depth: measured true vertical 8095 feet 6677 feet Plugs (measured) Effective depth: measured 7763 feet true vertical 6437 feet Junk (measured) Casing Length Size CONDUCTOR 112' 16" SURFACE 4715' 9-5/8" PRODUCTION 7476' 7" LINER 735' 4-1/2" LINER Cemented 9 cu yds High Early 620 sx AS III LW, 550 sx Class G 170 sx Class G 130 sx Class G Perforation depth: measured 7713'-7753', 7753' 7783' true vertical 6402!- 6430,, 6430'- 6451' Tubing (size, grade, and measured depth) 4-1/2". 12.6#, L-80 Tbg @ 7365' MD. Measured Depth 112' 4817' 7578' 8095' True vertical Depth 112' 4343' 6307' 6677' Packers & SSSV (type & measured depth) NO Packer CAMCO DB @ 503! MD, 13. Stimulation or cement squeeze summary Intervals treated (measured) : N/A Treatment description including volumes used and final pressure 14. Prior to well operation Subsequent to operation 15. Attachments Copies of Logs and Surveys run __ Daily Report of Well Operations __X OiI-Bbl Injector i Injector Representative Daily Average Production or Injection Data Gas-Mcr Water-Bbl Casing Pressure Tubing Pressure Form 10-404 Rev 06/15/88 · 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~ //~(,r'¢~ Michael Mooney Title: Wells Team Leader Questions? Call Mike Mooney 263-4574 Date Prepared b? Sharon AIIsup-Drake 263-4612 SUBMIT IN DUPLICATE ~) Oil__ Gas__ Suspended __ Service _Water Injector XX Date Comment 1C-18 Event History 03/02/02 03/03/02 GAUGED TBG W/3.19" CENT. TO 7763' WLM. DRIFTED W/2.65" X 22' DUMMY GUN TO 7760' WLM. PERFORATED C SAND INTERVAL 7713' - 7753' IN TWO RUNS W/2 7/8" HSD, 6 SPF, P J, 60 DEG PHASING. PRIOR TO PERF LOADED WELL W/DIESEL. TAGGED TD @ 7753' . [PERF] Page 1 of 1 4/23/2002 · Ms. Wendy Mahan AOGCC Second Quarter 2000 Annular Injection Report Page Two · Total Volumes into AnnuIi for which Injection Authorization Expired during the second quarter 2000: Total Total h(1) Total h(2) Total h(3) Volume Well Name Volume Volume Volume Injected Status of Annulus _ CDI-19 33933 100 0 34033 Open, Freeze Protected 1C-25 34836 100 0 34936 Open, Freeze Protected ~ CD1-40 32777 100 0 32877 Open, Freeze Protected 1C-23 34470 100 0 34570 Open, Freeze Protected 5- 1C-18 0 0 0 0 Open, Freeze Protected CD1-35 217 100 0 317 Open, Freeze Protected Please call me at 263-4603 should you have any questions. Sincerely, Paul Mazzolini Drilling Team Leader CC: Mike Zanghi Paul Mazzolini Randy Thomas Doug Chester Kupamk Environmental: Engel / Snodgrass B. Mordson and M. Winfree Sharon Allsup-Drake Well Files 199-005-0 KUPARUK RIV UNIT Roll #1: Start: Stop Roll #2: MD 08095 TVD 06677 Completion Date: 1C-18 50- 029-22939-00 PHILLIPS ALASKAINC Start Stop 4/2/99 Completed Status: 1WINJ Current: T Name~//'" D 9221 ~ I SPERRY MPT/GR/EWR4/CNP/SLD L CBL-" FINAL 7200-8003 L DGPUCNP/SLD-MD ~NAL 122-8095 L DGR/CNP/SLD-TVD/~F~',IAL 121-6676 L DGR/EWR4-TVD /FINAL 121-6676 L SCMT-PSP~-'~'~' ~AL BL(C) 7200-8003 4/2/99 L STATIC BHPL,,,'~/, FINAL 7500-7850 R SRVY RPT/ SPERRY 0-8095. Interval OH CH 5 OH OH OH OH CH 5 CH 5 OH Sent Received T/C/D 7/8/99 7/8/99 4/22/99 5/13/99 7/15/99 7/15/99 7/15/99 7/15/99 7/15/99 7/15/99 7/15/99 7/15/99 6/8/99 6/16/99 4/22/99 5/13/99 2/25/99 3/3/99 Wednesday, March 28, 2001 Page 1 of 1 STATE OF ALASKA ~ ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown_ Stimulate _X Plugging _ Perforate_ Pull tubing _ Alter casing _ Repair well _ Other__ 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB feet) Phillips Alaska, Inc. Development__ RKB 102 feet 3. Address Exploratory__ 7. Unit or Property name P. O. Box 100360 Stratigraphic__ Anchora~le, AK 99510-0360 Service__X Kuparuk Unit 4. Location of well at surface 8. Well number 1478' FNL, 1010' FWL, Sec. 12, T11N, R10E, UM (asp's562016, 5968762) 1C-18i At top of productive interval 9. Permit number / approval number 849' FSL, 1455' FEL, Sec. 2, T11 N, R10E, UM (asp's 559530, 5971069) 199-005 At effective depth 10. APl number 50-029-22939 At total depth 11. Field / Pool 1042' FSL, 1638' FEL, Sec. 2, T11 N, R10E, UM (asp's 559346, 5971260) Kuparuk Oil Pool 12. Present well condition summary Total depth: measured 8095 feet Plugs (measured) Tagged Fill (5/31/00) @ 8007' MD. true vertical 6677 feet Effective depth: measured 8007 feet Junk (measured) true vertical 6612 feet Casing Length Size Cemented Measured Depth True vertical Depth CONDUCTOR 121' 16" 9 cu yds High Early 121' 121' SURFACE 4716' 9-5/8" 620 Sx AS III LW & 550 4817' 4343' Sx Class G PRODUCTION 7477' 7" 170 Sx Class G 7578' 6308' LINER 735' 4-1/2" 130 Sx Class G 8095' 6677' ORiGiNAL Perforation depth: true vertical 6430 - 6451' Tubing (size, grade, and measured depth) 4-1/2", 12.6#, L-80, Tubing @ 7365' MD.RECEIVED Packers & SSSV (type & measured depth) No Packer. Camco DS Nipple @ 503'MD. MAR 2 ? 200! 13. Stimulation or cement squeeze summary Intervals treated (measured) (see attached) Alaska 0ii & Gas Cons, P~.,~ ' -i , Treatment description including volumes used and final pressure Anchorage 14. Representative Daily Average Production or Iniection Data OiI-Bbl Gas-Md Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 450 - 2150 Subsequent to operation 850 - 2100 15. Attachments 16. Status of well classification as: Copies of Logs and Surveys run ~ Daily Report of Well Operations ___X Oil __ Gas ~ Suspended __ Service ~,(Water Inj).~ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed Prepar__ _. v_..n Peirce 265-6471 Form 10-404 Rev 06/15/88 · SUBMIT IN DUPLICATE"~ 1C-18i DESCRIPTION OF WORK COMPLETED HIGH PRESSURE BREAKDOWN TREATMENT 5/31/00: RIH & tagged fill at 8007' MD. 7/2/00: MIRU & PT equipment to 9500 psi. Pumped a 3 Stage Fullbore High Pressure Breakdown treatment through the open perforation interval located at: 7753 - 7783' MD Pumped Breakdown Stage #1: a) 200 bbls Pad, followed by b) 50 bbls Scour Slurry containing 2036 lbs of proppant, followed by c) 200 bbls Flush to 40 bpm, followed by d) Shutdown. ISIP @ 2217. Pumped Breakdown Stage #2: e) 20 bbls Gelled Diesel w/2 ppa Rock Salt Diverter, followed by f) 10 bbls Gelled Diesel Spacer, followed by g) 15 bbls Gelled Diesel w/2 ppa Rock Salt Diverter, followed by h) 5 bbls Gelled Diesel Spacer @ 7 bpm, followed by i) Seawater Displacement @ 25 bpm, followed by j) 150 bbls Pad @ 40 bpm, followed by k) 50 bbls Scour Slurry w/1 ppa proppant concentration, followed by I) 250 bbls Flush, followed by m) Shutdown. ISIP @ 2172. Pumped Breakdown Stage #3: n) 15 bbls Gelled Diesel w/2 ppa Rock Salt Diverter, followed by o) 15 bbls Gelled Diesel Spacer, followed by p) 15 bbls Gelled Diesel w/2 ppa Rock Salt Diverter, followed by q) 10 bbls Gelled Diesel Spacer @ 7 bpm, followed by r) Seawater Displacement @ 25 bpm, followed by s) 150 bbls Pad @ 40 bpm, followed by t) 50 bbls Scour Slurry w/1 ppa proppant concentration, followed by u) 213 bbls Flush, followed by v) Shutdown. ISIP @ 2211. RECEIVED MAR ~ ? ~001 Alaska Oil & Gas Cons, Commission Anchorage Rigged down. Returned the well to water injection & obtained a valid injection rate. '~ul-03-00 0g:Z6 Fr0m-KUP WELLS CNST PROJ +g0?-SSg-?314 T-SSI P.0Z/0Z F-$33 STATE OF ALASKA ALASKA gib AND GAS OON~ERVAT1QN COMMI~81ON .._~ APPLICATION FOR SUNDRY APPROVALS 1. Type of reque Change Name of Opel 3. Address; Abandon ~ Alter ~a~ing __ pproved program X ator-' Phi!Lips?sake, Inc. Suspend __ Operation Sh~dewr Reenter suspended well ~ Repair well __ Plugging ~ Time extension __ Stimulate Pull tubing _ Variance PedorAte __ Other__ t5. Type of Well; Developr~ent X. Exploratory_~ 8tratagrapic ._:. service ~ 6. Oa~m of elevation (.DF er KB) 41' RKB 7. Unit or Property: 4. Locmion of ~ At top of prod AI~ effective d~ At total depth 12. Prese.t wel Total Dep' Effective Dep~ Casing Cortductor Surface ProduGtlon Liner Perforation Tubing (size Packers P.O. Box100360 Anchorage, AK 99510.0360 ~i'i ~,t eurface: 478' FNL, ~0~0' FVVL, $~¢ ~2, T~N, R~OE~ UM ~tlYe Int~tv~h 849' FSL, 1455' eEL. Sec 2, T11N, R10¢, UM 1042' FSL, 1838' EEL, Sec 2, TllN. RIOEf~M condition summary measured 8095 feet Pluge (measured) true vertical 6677 feet Illeaeured 8030 f~t June (measured) true vertical 6529 feet Length Size Cemented Measured depth 71' 16" 9 cu yds high early 112' 4776' 9.5/8" 620 a× AS I11 LW 4817' 7537' 7" 170eX CLASS c~ 7578' 4.5" 7366'-809S' :~epth meaeured 7753'-7783' true vertical G430'.64~$' 9rede, and measured depth) 4~1/2", 12,6~f, L-80, IPC Tubing @ 7365' MD, SSSV (type and measured depfll) KHp_amk River Unil: 8. Well number. 10-18 e. Permit number: 99-05 10. APl number: 50-029-22~39-00 11. Reid/Pooh Kuparuk River Field/Pool True vertical depth !12' 4343' 6307' ORI61NAL Baker Seal &say@ 7365' MD, Camco nipple @ 503' MD. 13, Attachmem ;I;4. Estimated c Convert OII Prod 16. If proposal Name o! ap; 17. I hereby ce ~3~)s~rlption ~ummary of proposal _X Detailed operations program ate for eol11~encin9 up=ration IIS. Status of well claaajfication as: ~cer ~o WAG Injector. June ;~000 I Oil _X Gas__ ~as verbally approved rover Date_~..a provedt Service tify that the forgoing is t~ue and =orrect to the best of my knowledge. BOP sketch _ Suspended__ [ *~/ ~, .... FOR COMMISSION USE ONLY Conditions of approval: Notii~t ComJs~io, so repros~litive n~ay wi~n~s~ .... I Pbg int~m~ BOP teal ~ Lom~on cleamn~ M~hanical intogrotyt~t~ Subsequent fo~ required 1 I .)RIGINAL SIGNED BY ommlsmor D Tayor Seamount ~ommlseloner .eS 0o¢ Dale 07/01/00 IApprovat No,,,~ ,~ RECE!VED "Jul-03-00 09:2T Fr0m-KUP WELLS CNST PEOJ +g07-659-7314 T-$62 PHILL ps Alan"a, Inc. A Subsidi~ 3HILLIPS PETR~ .JM COMPA~ .... . ......... .. ., , TU~ING 1C-1'; · ' -' ':..': __ ': .... (0-7365, APl: J 5002e2293~0 [ .... ~e'll'~pe: I INJ OO~,~00, - ....$$SV T~ONE ...... ~Ori~ Comp~tion: ] ~21~9 ID:3.9Sa) ~~u~'D~ ' ' / ~S~W/O',I ~&'L~g:I" / RefLcg ~teL~ ~~~5~3~/00 ......... I.Max Hole Angle',~48 de9 ~ 6791 P.OZ/02 F-$34 '~",~n,~l~-~ T0:143 deg_~ 809,5 Rev Reason: LT. ag fill kY. [mO Last U p d'~'~'.' J 676/b~ ..... .Caslrtg 8tring.'-ALL ' .'; .. : ...... Size I Top -' -Bottom TVD Wt [ Grade I Thread.. _ ~'6~'~OO I 0 t12 112 62.58 J H-40 ........ WELDED ~]~'~ - ' 7578 63(37 I 26.00 L-80 [ BTC-MOD 4.500 ,_L~ 7360 8095 _ 8-0-9-~ .... ]" '1'2,6~' '1 .... i~-'~ "' I ...... ~ - - ~~tr,-~-~:ALL~ ....... . ..... ~:~';"~. i' ' : ' · ' ' . "" · - -~' '- '- ...... Size Top I~o~--~~ "] TVO I Wt IGrade L .T.h..read __ J~o-T~t~ns,$ummary . ' .... .-'--~ .........'".'"" ' '" ' '~" ' . ........................ I"" interval TVD Zone Status Feet SPF D_a.t,e,] Type I Comment ??S3-7783 6430-6451 I C-4C-3 30t '";t"4~/~'~{i'Tl'F'ER~ I | ' J | ;deg from Iow side ~;'~i~%-,~ral,--~wl--;e-~-' - ' ' ................... ~"-MD -~:~l--~n---~ Man VMfr VType VOD LatchlPort TROI Date Vlv I I J IVlfr I TJ~.e I I I RUn Cosset 1 I 2577 25741 CAMCO I---~'~--CS'"'I~CAM¢O-I .... DMY I 1,0 I~NT 10,000 2~'0'~"f'l" a7a31 GAMCO~ K~G2L_$~C_AMCO [ DMY I 1.0 3~S237l 4642/ CAMC.O_~ K~S~-~,~I~-[ ...... DMY ' ~.0--/--~-~T----I-~7~b'01 ..... -o-l--~7_~1/~-q~-~ ~-~--]~6-0-6'1'[ 52441 ¢^Mc'~FI-i~T~$--I-'~Mco/ DMY I ~,e '"~' I STe3| $740/¢^MCOI KBG2LS I CAMCOI DMY I 1.0 [INT 10.0001 01 2121/991 Other (plugs, equip,, etc.) - dlSWELRY Depth TVD; Type Description ID 5,03 s03] NIP ICAMCO DB NIPPLE 3.813 73261 613~T"~h'l'lS~'~l cAMCO DI~ NIPPLE. 3.750 736SI 61581 SEAL ...IBAKERSEALAS'~'~' 3.?~0 Pad (77~3-7783) =.Jun-Ol-O0 I?:~ From-KUP WELLS CNST PROJ +g0T-65g-T314 T-431 STATE OF ALASKA, ALASKA OIL AND GAS CONSERVATION COMMI$$IO, ~-- APPLICATION FOR SUNDRY APPROVALS P.01/03 F-184 1, Type of request; Abandon ~ Aher casing Ch~mge approvec~ progr',~m '2. Name of Operator: 3, Addresa; Phillips Alaska, Inc. P.O. Box '[00360 Anchorage, AK 99510-0360 Suspend __ Repcdr well __ Pul, ~ubln§ _ 4, Location et well at auHaee; 147a' PNL. 1010' FWL, Sec , 'I'1 IN. R10E, UM At top of productive inlerval; 849' FSL. 1455' FEL, Sec 2, T11N, R10E, UM At effective depth: 1042' FSL .1§:~6' FEL, Se." 2~ T11N~_RI0_E, UM At total depth: Operation Shuldcw~ __ Reenter suspended Wmll __ Plugging_ Time ex3ansIon __ Variance L Perto~e _ St;mul&te _ OIMe~ ~ !~. Permit number: 99-05 ~ 10. APl number: 50-029-2293~.cQ 11, Field/Pooh Kqpa~uK River Fielo/Pool 12. Present Well condition eummary Total O~pth: '% moasnred e veal,al EfFective Depth: il~eu red true v% Caeing Length ~ Size Conductor 1~1~ ~ ~ 1~" Production 7578' ~ / 8095 feet /ll~(meaeu~ 6s77 fo~/ ~030 feel Junk 65E9 feet Comely g cu hiQh ee;ly AS III LW sX CLAS9 G Meeaured deplh 11o' ~:7 t, True vertical depth 110' 6406 Liner Perforation Depth m~sured 77~$'. true Vertigo! G490'- Tubing (sl~e, grade, and meae,l'~d d,p~h) T~ .-~e~ ~.~ 4-1/2", 12,6#, L-80, IPC Tu~ @ 9044' MD. Packers and $SSV (type and measured L "'"": 2000 ui',~ UP Gas C, ons Commissmn An.,chor~e Baker Sea~ sasy~ MD, Camco ricple ~ 503' MD. '~ 13, Attachmenls Description of proposal_X Delalled operations program_"~ 9OP s~atch_ 14, E.ti~ted dale for com~noing 15. ~atus of well =l~sflieafion as: Co~e~ Oil Proaucur 1o WAG Injector. ~ne 2000 I Oil _X Gas ~. d __ 16. ~ prepoa~ was Name of ~ppmver Date ~pra~d] SeMce 17. I he~e~ codify th~t the f¢ ~oing la ~m. an~ eo~ect fo tl~e best of mv knowledge_ "- S,~ed ~,le: Wells ~ngin~ering Tach Da~ ~25/00 FOR COMMISSION USE ONLY o_ Confli¢cns of app~val; Comiesion so reprosentifive ~y witness I Rug inlegre~ _. BOP te~t__ Locaz~on ole~n¢~ __ ~~ord~ of lho Commiesion Com~ssio~r Oa~ orm - ev08/15/8~ SU~MIT IN TRI PLIC~I ~ ,~Jun-Ol-O0 1T:22 Fr0m-KUP V/ELLS CF/ST PEOJ +90T-GSg-?314 Attachment 1 . Conversion to Water Injection Kuparuk Well 10-18 T-431 P.0Z/0$ F-IB4 Phillips Alaska, Inc. requests approval to convert Well 1C-18 from an oil producer to a water injector. This well will be operated as a Class II UIC well in compliance with Area Injection Order No. 2, Water will be injected for the purpose of enhanced recovery into the Kuparuk interval between the depth~ of 6430' and 6451'. This interval correlates with the strata found in ARCO's West Sak River State Well No, 1 between the depths of 6474' and 6880' as authorized in Rule 1 of this injection order. A Mechanical Integrity Test will be performed before injection is initiated and every four years thereafter, in compliance with Rule 6 of this order. This well's injection volumes, average injeotion pressure, and average annulus pressure will be reported to the AOGCC monthly. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATtON COMMISSION Mec hanlcal Integrity Test PhilNps Alosko, Inc. FIELD / UNIT/PAD: Kuparuk River/KRO ,I COMMENTS: Pre C,o~version MIT 2250 3OO 2250 3OOO ~FTJME~.i 225O 2950 DATE: 2250 295O COMMENTS: COMMENTS: COMMENTS: COMMENTS; I I '1 5/3 I 'i , m r 2 C) TBG.'INJ, FLUID CODES F = FRESH WATER iNJ. G = GAS lEU. S: SALTWATER N = NOT ~NJECTING TESTTYPE: M = ANNULUS MONITORING P = STD ANNULUS PRESSURE TEST R = iNTERNAL RAD. TRACER SURVEY A = TEMPERATURE ANOMALY TEST D = DIFFE,RENltAL TEIVlPEP, ATURE TES'I DJsttibul[on: ohg - Well File ~ - Op~alor c - i)ataba.~ c-Trip Rpl OPERATOR REP SIGNATURE: Eric Zuspan MIT 5.31-00.xls ANNULAR Ft. UtD: DIESEL GLYCOL SALT WATER DRILLING MUD OTH ER P.P.G. Grad, O. OO WELLTEST: Initial X 4 - Year Workover Other , AOGCC REP SIGNATURE: (Rev' 9/1 T 0 FI I /1_11M CS SE FI~JI i-- E ~ WEI J~ LOG TRANSMITYAL To: State of Alaska July 15, 1999 Alaska Oil and Gas Conservation Comm. Atm.: Loft Taylor 3001 PoreupineDr. Anchorage, Alaska 99501 MWD Formation Evaluation Logs lC- 18, AK-MM-90076 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of. Jan Galvin, Sperry-Sun Drilling Services, 5631 Silverado Way, #G, Anchorage, AK 99518 1C-18: 2" x 5" MD Resistivity & Cramma Ray Logs: 50-029-22939-00 2"x 5" TVD Resistivity & Gamma Ray Logs: 50-029-22939-00 2"x 5" MD Neutron & Density Logs: 50-029-22939-00 2"x 5" TVD Neutron & Density Logs: 50-029-22939-00 jut. q 5 1999 0ii & (~as Cons. t Btudine t Folded Sepia t Btueline 1 Folded Sepia t Bludine 1 Folded Sepia 1 Bktdine 1 Folded Sepia 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 · (907) 273-3500 · Fax (907) 273-3535 A Halliburton Company To: State of Alaska -July 8, 1999 Alaska Oil and Gas Conservation Comm. Atm.: Ix)ri Taylor 3001 Porcupine Dr. Anchorage, Alaska 99501 MWD Formation Evah~on Logs lC- 18, 1 LDWG formatted Disc with verification listing. APl#: 50-029-22939-00 PI.EASE ACKNOWI,EBGE RECEIPF BY SIGNING AND RETURNING TI:IF. ATTACHEI~ COPY OF THE TRANSMrIT~ LE'VrER TO THE A'ITENTION OF: Sperry-Sun Drilling Service Attrr Jim Galvin 5631 Silverado Way, Suite G. Anchorage, Alaska 99518 Date: ..'.3[- O 8 1999 Si Alaska 0il & Gas Cons. Commmi0n An~or~Je 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 · (907) 273-3500 · Fax (907) 273-3535 A Halliburton Company 6/8/99 GeoQuest 3940 Arctic Blvd Anchorage, AK 99503 AI'I'N: Sherrie NO. 12633 Company Alaska Oil & Gas Cons Comm Attn: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Field: Kuparuk/Tarn Pool/West Sak Well Job # Log Description Date Color Print 2T-210 99240 CBL W/PSP/SCMT 990523 1 2N-320 99241 SCMT 990303 1 2L-323 L~ ~_- 99239 CBT W/PSP/SCMT 990221 1 1C-18 99243 CBT W/PSP/SCMT 990402 1 1D-132 ~ ~._ 99248 SCMT 990216 1 1D- 125 99249 CBT W/PSP/SCMT 990220 1 1D- 114 L,~ ~ ~ 99246 CBT W/PSP/SCMT 990421 1 i 1 D- 128 99247 SCMT 990215 1 1 D- 122 ~, ~ ¢._. 99244 CBT W/PSP/SCMT 990226 1 1D-111 1,~ ~ . 99245 CBT W/PSP/SCMT 990415 1 1 C- 14 ~,~ f/.__. 99242 SCMT 990122 1 SIGNE ._.. ~-,._L~_._ k_~~~~-~. DATE: Please sign and return one copy of this transmittal to Sherrie at the above address. Thank you. ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 May 19, 1999 Mr. Robert Christenson Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Subject: lC-18 (Permit No. 99-05) Addendum to Application for Sundry Dear Mr. Commissioner: Enclosed is an addendum to the Application for Sundry on KRU 1C-18. This chart will correct the one sent previously. If there are any questions, please call 265-6890. Sincerely, G. C. Alvord Drilling Engineering Supervisor AAI Drilling GCA/skad Cc: Blair Wondzell ARCO Alaska, Inc. ~ Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 May 5, 1999 1Vk. Robert Christenson Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Subject: 1 C-18 (Permit No. 99-05) Well Completion Report Dear Mr. Commissioner: Enclosed is the well completion report for the completion on KRU 1C-18. If there are any questions, please call 265-6890. Sincerely, G. C. Alvord Drilling Engineer AAI Drilling GCA/skad STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of well Classification of Service Well Oil [] Gas [] Suspended [] Abandoned [] Service [] Pre-produced injector 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 99-05 3. Address 8. APl Number P. O. Box 100360, Anchorage, AK 99510-0360 50-029-22939 4. Location of well at surface 19. Unit or Lease Name 1478' FNL, 1010' FWL, Sec. 12, T11N, R10E, UM . '..;: '-': ~;'¢(L~'~ ~. ~ ~'. Kuparuk River Unit At Total Depth At Top Producing Interval ;! ~~Z~". ~. i'//~ . .,.-..¢. _. ~ ~ 10. Wail Number 849' FSL, 1455' FEL, SEC 2, T11N, R10E, UM ' 1C-18 ~ ~~:~ i 11. Field and Pool 1042' FSL, 1638' FEL, SEC 2, T11N, R10E, UM L.~'7 ......... - -" _. Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) ~6. Lease Designation and Serial No. Kuparuk River Pool RKB 41 feet~ ADL 25649 ALK 467 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. Or Aband.. ~5. Water Depth, if o~hore 16. No. of Completions FebruaW 5, 1999 FebruaW 17, 1999 ~ ~A feetMSL 1 17. Total Depth (MD + TVD) 18. Plug Back Depth (MD + TVD) 19. Directional Su~ey ~20. Depth where SSSV set 21. Thickn~s of Permafrost 8095' MD/6677'TVD 8030' MD/6629'TVD YES ~ No ~ ~ WA feetMD 1802' 22. Type Electric or Other Logs Run GWPWD, GWRe~Neu Dens, SCMT 23. CASING, LINER AND CEMENTING RECORD S~ING DEPTH MD CASING SIZE ~. PER ~. GRADE TOP BOSOM HOLE SIZE CEME~ING RECORD~ AMOUNT PULLED 16" 62.5~ R-3 Suflace 121' 24" 9 cu yds High Early 9.625" 40¢ L-80 Sudace 4817' 12.25" 620 sx AS III LW, 55O sx Cla~ G 7" 26¢ L-80 Sudaoe 7578' 8.5" 17o sx Cla~ G 4.5" 12.6¢ L-80 7360' 8095' 6.125" 130 sx Cla~ G 24. Perforations open to Production (MD + TVD of Top and Bottom and 25. TUBING RECORD inte~al, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 4.5" 7378' WA 26. ACID, F~CTURE, CEMENT SQUEEZE, ETC. 7753'-7783' MD 6430'-6451' TVD ~ 4spf DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 27. PRODUCTION TEST Date First Production Method o, O,er , on ,i*. April 24, 1999 Flowing b 0il & Gas Cons. ~mmissio¥~ Date of Test %uts Tested Production for OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE ~[~10 I 4/24/1999 6.0 Test Period > 25 1118 1 176 ~ 32000 Flow Tubing Casing Pressure Calculated OIL-BBL GAS-MCF WATER-BBL OIL G~VI~ - APl (corr) press. 200 psi 0 24-Hour Rate > 93 4477 0 23.8° 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. See Attachment Form 10-407 Rev. 7-1-80 CONTINUED ON REVERSE SIDE Submit in duplicate 29. NAME Top Kuparuk C Base Kuparuk C Top Kuparuk A Base Kuparuk A GEOLOGIC MARKERS MEAS. DEPTH 7712' 7902' 8062' 8095' TRUE VERT. DEPTH 6401' 6536' 6653' 6677' 30. FORMATION TESTS Include interval tested, pressure data, all fluids recovered and gravity. GOR, and time of each phase. Annulus left open - freeze protected with diesel. 31. LIST OF ATTACHMENTS Summary of Daily Operations, Directional Survey 32. I hereby certify that the following is true and correct to lhe best of my knowledge. Signed ~ d~ ~ Title Drilling Engineering Supervisor Date Chip Alvord INSTRUCTIONS Prepared by Sharon AIIsup~Drake General: This form is designed for submitting a complete and correct well completion report and Icg on all types of lands and leases in Alaska. Item 1' Classification of Service wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10-407 Date: 4/16/99 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 1 WELL:lC-18 WELL_ID: AK0020 TYPE: AFC: AK0020 STATE:ALASKA AREA/CNTY: NORTH SLOPE EAST FIELD: KUPARUK RIVER UNIT SPUD:02/05/99 START COMP: RIG:PARKER 245 WI: 0% SECURITY:0 API NUMBER: 50-029-22939-00 BLOCK: FINAL:02/19/99 01/31/99 (D1) TD: 121'(121) SUPV:G.R. WHITLOCK 02/01/99 (D2) TD: 121'( 0) SUPV:G.R. WHITLOCK 02/02/99 (D3) TD: 121'( 0) SUPV:DON E. BREEDEN 02/03/99 (D4) TD: 121'( 0) SUPV:DON E. BREEDEN 02/04/99 (D5) TD: 121'( 0) SUPV:DON E. BREEDEN 02/05/99 (D6) TD: 2087'(1966) SUPV:DON E. BREEDEN 02/06/99 (D7) TD: 3668'(1581) SUPV:DON E. BREEDEN MW: 0.0 VISC: 0 PV/YP: 0/ 0 APIWL: 0.0 WAITING ON WEATHE Held safety meeting. Prepare rig floor to move. MW: 0.0 VISC: 0 PV/YP: 0/ 0 APIWL: 0.0 MOVING RIG Wait on weather. Move rig off pad. MW: 0.0 VISC: 0 PV/YP: 0/ 0 APIWL: 0.0 MOVING RIG - DRILLING MODULE AT iQ WIDE SPOT, UTILITY MODULE Continue to move rig. MW: 0.0 VISC: 0 PV/YP: 0/ 0 APIWL: 0.0 DRILLING MODULE OVER 1C-18. MATING UP UTILITY MODULE. Move rig. MW: 8.6 VISC: 175 PV/YP: 28/44 APIWL: 12.2 DRILLING AT 375' Move drilling module to 1C-18. Accept rig @ 0800 hrs. 2/4/99. NU diverter system and function test. MW: 10.0 VISC: 120 PV/YP: 34/35 APIWL: 6.2 OOH - WIPER TRIP AT 2250' Spud in and drill from 121' to 2087' Circulate out gas cut mud. MW: 10.0 VISC: 180 PV/YP: 46/55 APIWL: 5.6 DRILLING AT 4285' Drill from 2087' to 3668' Date: 4/16/99 ARCO ALASKA INC. WELL SI/MMARY REPORT Page: 2 02/07/99 (D8) TD: 4826' (1158) SUPV:DON E. BREEDEN 02/08/99 (D9) TD: 4826' ( 0) SUPV:DON E. BREEDEN 02/09/99 (D10) TD: 4826' ( 0) SUPV:DON E. BREEDEN 02/10/99 (Dll) TD: 4826'( 0) SUPV:DON E. BREEDEN 02/11/99 (D12) TD: 6385'(1559) SUPV:DON E. BREEDEN 02/12/99 (D13) TD: 7575'(1190) SUPV:DON E. BREEDEN 02/13/99 (D14) TD: 7585' ( 10) SUPV:DON E. BREEDEN MW: 10.2 VISC: 135 PV/YP: 48/53 START POH WITH HOLE OPENER APIWL: 5.4 Drill from 3668' to 4826' POH. Work thru tight spots between 3100' to 2000' Circulate hole clean & monitor bubbling from hydrates. MW: 10.2 VISC: 70 PV/YP: 34/23 CEMENTING 9-5/8" SURFACE CASING APIWL: 6.0 RIH with hole opener. Ream from 1853' to 2036' Run 9-5/8" surface casing. MW: 9.8 VISC: 44 PV/YP: 13/10 APIWL: 9.8 PREPARE TO CEMENT THRU TAM PORT COLLAR AT 1013' Cement 9-5/8" casing. Circulate out contaminated mud. MW: 8.7 VISC: 33 PV/YP: 4/ 3 TEST CASING TO 3000 PSI FOR 30 MINUTES. APIWL: 40.0 RIH w/TAM Combo tool, pushing thru contaminated mud. Pump cement. MW: 8.9 VISC: 53 PV/YP: 14/24 DRILLING AT 6960' APIWL: 6.2 Clean out cement to 4708' Drill out cement and float equipment. Drill 20' of new hole to 4846'. Test formation to 13.8 ppg EMW. Drill to 6385' MW: 9.5 VISC: 67 PV/YP: 24/35 MONITOR HOLE AT 7585' WITH 10.0 PPG MUD APIWL: 2.8 Drill from 6385' to 7274'. Circulate out gas cut mud from connection at 7225'. Start raising MW to 9.4 ppg and drill stand down to 7320' Circulate 9.4 ppg mud around. CBU, no heaving, light foaming. Drill to 7575'. Test formation integrity, leaked-off to formation at 9.5 ppg mud, 12.4+ ppg EMW. MW: 9.9 VISC: 54 PV/YP: 19/22 CEMENTING 7" CASING. APIWL: 2.0 Circulate lo-visc sweep around. Mud gas cut to 7.6 ppg on bottoms up. Drill from 7575' to 7585'. Start increasing MW to 9.8 ppg. CBU, slight gas/air cut. Weight up to 9.9+ ppg. Run 7" casing. Date: 4/16/99 02/14/99 (D15) TD: 7585' ( 0) SUPV:DON E. BREEDEN 02/15/99 {D16) TD: 7656' ( 71) SUPV:DON E. BREEDEN 02/16/99 (D17) TD: 8005'(349) SUPV:G.R. WHITLOCK 02/17/99 (D18) TD: 8095' ( 90) SUPV:G.R. WHITLOCK 02/18/99 (D19) TD: 8095' ( 0) SUPV:G.R. WHITLOCK 02/19/99 (D20) TD: 8095' ( 0) SUPV:G.R. WHITLOCK 02/20/99 (D21) TD: 8095' ( 0) SUPV:G.R. WHITLOCK 02/21/99 (D22) TD: 8095'( 0) SUPV:G.R. WHITLOCK 02/22/99 (D23) TD: 8095' ( 0) SUPV:G.R. WHITLOCK Page: 3 ARCO ALASKA INC. WELL S[/MMARY REPORT MW: 9.7 VISC: 47 PV/YP: 16/14 APIWL: 5.0 TESTING 7" CASING TO 3000 PSI. Run 7" casing. Pump cement. Test BOPE. MW: 10.8 VISC: 58 PV/YP: 23/28 APIWL: 4.0 POH TO CHECK BIT, BIT BALLED-UP & 1 NOZZLE PLUGGED. Tag cement at 7484' Drill out cement, plugs and floats. Drill 10' of new hole to 7595'. Test formation to 10.8 ppg. No leak-off, 15.1+ppg EMW. Drill from 7595' to 7656' MW: 10.8 VISC: 80 PV/YP: 34/43 APIWL: 3.0 WIPER TRIP Drill from 7656' to 8005' MW: 11.2 VISC: 66 PV/YP: 35/35 APIWL: 3.2 RUNNING 4-1/2" LINER Drill from 8005' to 8095'. Pump out of hole to shoe, monitor well, pump pill. Monitor well, very slight flow. Shut well in. Open well, no flow. Raise MW to 11.1 ppg decrease viscosity. Monitor well. MW: 11.1 VISC: 65 PV/YP: 31/34 APIWL: 3.2 RUNNING TUBING RIH w/4.5" liner. Pump cement. MW: 0.0 VISC: 0 PV/YP: 0/ 0 APIWL: 0.0 CLEANING PITS, N/D BOPE Run 4.5" tubing. Freeze protect tubing. N/D BOPE. MW: 0.0 VISC: 0 PV/YP: 0/ 0 APIWL: 0.0 FINAL RINSE OF RIG N/U tree and test to 5000 psi. Perform LOT on 9-5/8" x 7" annulus, 11.0 ppg EMW. MW: 0.0 VISC: 0 PV/YP: 0/ 0 APIWL: 0.0 RIG RELEASED. MOVING TO WEST SAK PILOT PAD Release rig @ 1200 hrs 2/21/99. Move camp to West Sak pilot pad. MW: 0.0 VISC: 0 PV/YP: 0/ 0 APIWL: 0.0 STACKING RIG Move drill module to West Sak Pilot pad. Date: 4/16/99 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 4 02/23/99 (D24) TD: 8095' ( 0) SUPV:G.R. WHITLOCK 02/24/99 (D25) TD: 8095'( 0) SUPV:G.R. WHITLOCK 02/25/99 D26) TD: 8095' 0) SUPV:G.R. WHITLOCK 02/26/99 D27) TD: 8095' 0) SUPV:G.R. WHITLOCK 02/27/99 (D28) TD: 8095'( 0) SUPV:G.R. WHITLOCK 02/28/99 (D29) TD: 8095' ( 0) SUPV:G.R. WHITLOCK 03/01/99 (D30) TD: 8095'( 0) SUPV:G.R. WHITLOCK MW: 0 0 VISC: PREPPING TO LAYDOWN DERRICK Rig down. MW: 0 0 VISC: MOTHBALLING RIG Continue to rig down. MW: 0 0 VISC: 0 PV/YP: 0/ 0 STACKING RIG Stacking rig. MW: 0 0 VISC: 0 PV/YP: 0/ 0 STACKING RIG Continue stacking rig. MW: 0 0 VISC: 0 PV/YP: 0/ 0 STACKING RIG Continue stacking rig. MW: 0 0 VISC: 0 PV/YP: 0/ 0 STACKING RIG Continue stacking. MW: 0.0 VISC: 0 PV/YP: 0/ 0 STACKING RIG Continue stacking rig. 0 PV/YP: O/ 0 0 PV/YP: 0/ 0 APIWL: 0 0 APIWL: 0 0 APIWL: 0 0 APIWL: 0 0 APIWL: 0 0 APIWL: 0 0 APIWL: 0 0 ARCO Alaska. Inc. KUPARUK RIVER UNIT ,, WELL SERVICE REPORT '' K1(1C-18(W4-6)) WELL JOB SCOPE JOB NUM'BER " 1 C-18 DRILLING SUPPORT-CAPITAL 0223990726.19 DATE DAILY WORK UNIT NUMBER 04/02/99 SCMT/PERF/SBHP 8345 DAY OPERATION COMPLETE SUCCESSFUL KEY PERSON SUPERVISOR 3 YES YES SWS-STEPH ENSON GOBER FIELD AFC# CC# Signed ESTIMATE AK0020 230DS10CG Initial Tbg Press Final Tbg Press Initial Inner Ann Final Inner Ann I Initial Outer Ann I Final Outer Ann 500 PSI 675 PSI 500 PSI 500 PSII 500 PSII 500 PSI DAILY SUMMARY SCMT (BOND LOG) FROM 8002'-7218' - LOG RUN W/500 PSI ON WELL - NO LOG RUNS MADE W/0 PSI - PERF 7783'-7753' (2 I RUNS) WITH 2-7/8" DP, 4 SPF, 180 DEG +/- 90 DEG FROM LOW SIDE - SBHP = 3342 PSI @ 7570' AND 3400 PSI @ 7768'[Perf, I Pressure Data] TIME LOG ENTRY 07:30 MIRU SWS 08:45 PRESSURE TEST LUBRICATOR TO 3000 PSI - ALL OK 09:00 RIH W/PSP/SCMT TOOLS 09:45 RUN SCMT (BOND LOG) FROM 8002'-7218' - GOOD BOND ABOVE AND BELOW PROPOSED PERF ZONES - LOG RAN WITH 500 PSI ON WELL - NO LOG RUN MADE WITH 0 PSI ON WELL - NOTIFY DSE OF LOG RESULTS - DSE REVIEWED LOG AND APPROVED PROCEEDING WITH PERFORATING 11:00 POOH 12:00 RD LOGGING TOOLS - CALL FOR RADIO SILENCE ON PAD - RU 20' 2.875" HC/DP/4SPF/180 DEG PHASING +/- 90 DEG FROM LOW SIDE - PRESSURE TEST LUBRICATOR TO 3000 PSi - ALL OK - RIH 13:45 TIE IN WITH SCMT LOG - PERF 7763'-7783' - POOH 15:00 RIG UP 10' 2.875" HC/DP/4SPF/180 DEG PHASING +/- 90 DEG FROM LOW SIDE - PRESSURE TEST LUBRICATOR TO 3000 PSI - ALL OK - RIH 16:15 TIE IN TO SCMT - PERF 7753'-7763' - POOH 17:15 RD PERF GUN - RELEASE RADIO SILENCE 17:20 RU PSP TOOL FOR SBHP READINGS - PRESSURE TEST LUBRICATOR TO 3000 PSI - ALL OK - OPEN UP WELL - TAKE READINGS IN LUBRICATOR 17:50 RIH W/PSP TOOL 18:30 SBHP @ 7768' - LOOSING 1 PSI/MIN - WILL RECORD AGAIN LATER 18:55 SBHP @ 7570' = 3342 PSI - STABLE READING 19:25 SBHP @ 7768' = 3400 PSI - STABLE READING 20:00 POOH TIME LOG ENTRY 20:50 TAKE READINGS IN LUBRICATOR - TEMP DEC DUE TO WIND AFFECTING READINGS 21:15 RD PSP TOOLS 22:00 RDMO SWS - NOTIFY DSO OF WELL STATUS - AWAITING INJECTION LINE HOOKUP AND MITIA PRIOR TO INITIATING INJECTION Prudhoe Bay Unit Alaska State Plane Zone 4 Kuparuk 1C, Slot 1C- 18 1C-18 Job No. AKMM90076, Surveyed: 17 February, 1999 ORIGINAL SURVEY REPORT 24 February, 1999 Your Ref: API-500292293900 KBE-101.50 Surface Coordinates: 5968758.00 N, 562016.22 E (70° 19' 30.6311" N, 149° 29' 49.6231" W) ~lmmr',r',v-mum DRILLING SERVICES Survey Ref: svy8354 Sperry-Sun Drilling Services Survey Report for lC- 18 Your Ref: API-500292293900 Job No. AKMM90076, Surveyed: 17 February, 1999 Prudhoe Bay Unit Measured Depth (ft) Incl. Azim. Sub-Sea Depth (ft) Vertical Depth (ft) 0.00 0.000 0,000 -101.50 0.00 121.00 0.000 0.000 19.50 121.00 196.30 0.550 237,650 94.80 196.30 378,74 0.440 354.640 277.24 378.74 559.15 0.220 348.760 457.64 559.14 741.38 0.280 186.980 639.87 741.37 920.94 0.070 316.990 819.43 920.93 1104.35 0.340 333.310 1002.84 1104.34 1290.54 0.260 326.080 1189.03 1290.53 1475.51 0.550 148.160 1373,99 1475,49 1661.47 0.350 295,290 1559.95 1661.45 1943.78 0.370 135.760 1842.26 1943.76 2201,10 1.280 315.460 2099.56 2201,06 2311.14 5.990 322.610 2209,35 2310.85 2404.72 7.590 322.110 2302.27 2403.77 2498.57 9.730 315.080 2395.05 2496.55 2591.27 11.600 315.250 2486.14 2587.64 2687.10 14.900 '315.680 2579.41 2680.91 2780.66 18.220 313.450 2669,08 2770.58 2875.03 21.440 312.660 2757,84 2859.34 2968,55 24.390 313.260 2843.97 2945,47 3059.80 26.630 313.740 2926.32 3027.82 3155.81 28.880 314.120 3011.28 3112,78 · 3245.81 30.780 314.100 3089.35 3190.85 3340.90 32.620 313,170 3170.25 3271.75 Local Coordinates Global Coordinates Northings Eastings Northings Eastings (ft) (ft) (ft) (ft) 0.00 N 0.00 E 0.00 N 0.00 E 0.19 S 0.31 W 0.04 N 1.11 W 1.06 N 1.24 W 0.97 N 1.37 W 0.61 N 1.49 W 1.18 N 1.81 W 2.02 N 2.30 W 1.62 N 2.06 W 1.10 N 2.11 W 0.82 N 2.25 W 2.27 N 3.69 W 7.71 N 8.04 W 16.47 N 14.80 W 26.98 N 24.21 W 39.14 N 36.30 W 54.81 N 51.70 W 73.48 N 70.72 W 95.32 N 94.12 W 120.14 N 120.76 W 147.19 N 149.26 W 178.21 N 181.45 W 209.37 N 213.60 W 243.84 N 249.77 W 5968758.00 N 562016.22 5968758.00 N 562016.22 5968757.80 N 562015.92 5968758.03 N 562015.11 5968759.05 N 562014.97 5968758.95 N 562014.85 5968758.60 N 562014.72 5968759.16 N 562014.40 5968760.00 N 562013.91 5968759.60 N 562014.14 5968759.08 N 562014.10 5968758.80 N 562013,96 5968760,24 N 562012.51 5968765.64 N 562008.12 5968774.35 N 562001.29 5968784.78 N 561991.79 5968796.84 N 561979,60 5968812.38 N 561964,07 5968830.89 N 561944.89 5968852.53 N 561921,31 5968877.13 N 561894,47 5968903.95 N 561865,75 5968934.71N 561833.30 5968965.60 N 561800,90 5968999.77 N 561764,45 Alaska State Plane Zone 4 Kuparuk 1C Dogleg Vertical Rate Section (°/100fi) (fi) Comment E 0.00 E 0.000 0.00 E 0.730 0.09 E 0.464 O.83 E 0.123 1.63 E 0.271 1.65 E 0.183 1.50 E 0.149 2.13 E 0.047 3.06 E 0,438 2,61 E 0.465 2.28 E 0.251 2.19 E 0.641 4.23 E 4.292 11,14 E 1.711 22.08 E 2,540 36.14 E 2.018 53.29 E 3.445 75.24 E 3.612 101.89 E 3.424 133.90 E 3.164 170.31 E 2.465 209.60 E 2.351 254.31 E 2,111 299,07 E 2.002 349.04 Continued... 24February, 1999-16:29 -2- DrlllQuest Sperry-Sun Drilling Services Survey Report for lC- 18 Your Ref: AP1-$00292293900 Job No. AKMM90076, Surveyed: 17 February, 1999 Prudhoe Bay Unit Measured Depth (ft) Incl. Azim. Sub-Sea Depth (ft) Vertical Depth (ft) 3432.19 35.860 313.520 3245.71 3347.21 3525.18 38.310 314.180 3319.89 3421.39 3618.43 40.500 315.520 3391.93 3493.43 3712.23 42.750 315.390 3462.05 3563.55 3897.82 44.180 314.800 3596.74 3698.24 4269.73 45.690 315.450 3860.02 3961.52 4550.04 46.060 313.050 4055.19 4156.69 4773.15 45.430 312.680 4210.89 4312.39 5023.42 44.820 311.480 4387.47 4488.97 5303.66 43.890 312.940 4587.85 4689.35 5581.90 42.490 313.650 4790.71 4892.21 5860.26 41.910 313.780 4996.92 5098.42 6140.30 45.100 312.400 5200.01 5301.51 6419.72 43.580 313.460 5399.85 5501.35 6700.52 47.800 308.080 5596.03 5697.53 6979.81 46.530 311.530 5785.95 5887.45 7260.74 44.710 315.460 5982.46 6083.96 7511.62 45.530 313.330 6159.50 6261.00 7665.23 45.760 317.010 6266.91 6368.41 7854.24 44.540 315.530 6400.21 6501.71 8046.41 42.530 317.400 6539.52 6641.02 8095.00 42.530 317.400 6575.33 6676.83 Local Coordinates Global Coordinates Northings Eastings Northings Eastings (ft) (ft) (ft) (ft) 279.10 N 287.11 W 5969034.72 N 561726.81 E 317.95 N 327.54 W 5969073.23 N 561686.07 E 359.70 N 369.49 W 5969114.63 N 561643.77 E 404.10 N 413.19 W 5969158.67 N 561599.70 E 494.52 N 503.32 W 5969248.34 N 561508.83 E 680.67 N 688.64 W 5969432.96 N 561321.98 E 821.05 N 832.76 W 5969572.14 N 561176.71 E 929.76 N 949.88 W 5969679.88 N 561058.69 E 1048.62 N 1081.50 W 5969797.64 N 560926.09 E 1180.22 N 1226.62 W 5969928.04 N 560779.89 E 1310.79 N 1365.23 W 5970057.47 N 560640.21 E 1440.01 N 1500.37 W 5970185.56 N 560504.00 E 1571.64 N 1641.18 W 5970316.02 N 560362.10 E 1704.62 N 1784.18 W 5970447.82 N 560218.01 E 1835.45 N 1936.43 W 5970577.39 N 560064.69 E 1966.48 N 2093.76 W 5970707.11 N 559906.28 E 2104.54 N 2239.43 W 5970843.96 N 559759.47 E 2228.88 N 2366.45 W 5970967.24 N 559631.43 E 2306.75 N 2443.85 W 5971044.47 N 559553.38 E 2403.58 N 2536.46 W 5971140.54 N 559459.98 E 2499.50 N 2627.65 W 5971235.70 N 559368.00 E 2523.68 N 2649.89 W 5971259.69 N 559345.57 E Alaska State Plane Zone 4 Kuparuk 1C Dogleg Rate (°/100ft) Vertical Section (ft) Comment 3.556 2.669 2.519 2.400 0.801 0.424 0.629 0.306 0.418 0.493 0.533 0.211 1.189 0.605 2.033 1.013 1.191 0.685 1.719 0.851 1.242 0.000 400.40 456.46 515.64 577.91 705.54 968.13 1169.31 1329.09 1506.36 1702.20 1892.62 2079.60 2272.34 2467.60 2668.06 2872.32 3073.02 3250.75 3360.52 3494.37 3626.57 3659.34 PROJECTED SURVEY Continued... 24 February, 1999 - 16:29 - 3 - DrlllQuest Sperry-Sun Drilling Services Survey Report for lC- 18 Your Ref: API-500292293900 Job No. AKMM90076, Surveyed: 17 February, 1999 Prudhoe Bay Unit All data is in feet unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well. Northings and Eastings are relative to Well. Magnetic Declination at Surface is 27.291° (17-Feb-99) The Dogleg Severity is in Degrees per 100ft. Vertical Section is from Well and calculated along an Azimuth of 313.710° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 8095.00ft., The Bottom Hole Displacement is 3659.35ft., in the Direction of 313.603° (True). Comments Measured Station Coordinates Depth TVD Northings Eastings Comment (ft) (ft) (ft) (ft) 8095.00 6676.83 2523.68 N 2649.89 W PROJECTED SURVEY Alaska State Plane Zone 4 Kuparuk lC 24 February, 1999 - 16:29 - 4 - DrlllQuest [~ F:! I L..[_ I ~ C3 S E I~JI I-- i~ S 25-Feb-99 AOGCC Lori Taylor 300'1 Porcupine Drive Anchorage, AK 9950 '1 Re: Distribution of Survey Data for Well 1C-18 Dear Lori Taylor: Enclosed are two survey hard copies. Tie-on Survey: Window / Kickoff Survey: Projected Survey: 0.00' MD 'MD 8,095.00' MD (if applicable) Please call me at 563-3256 if you have any questions or concerns. Regards, William T. Allen Survey Manager Attachment(s) 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 · (907) 273-3500 · Fax (907) 273-3535 A Halliburton Company Re: KRU C-18 Well Control ~ P-245, 2/17/99 ~'~ Subject: Re: KRU C-18 Well Control ~ P-245, 2/17/99 Date: Thu, 18 Feb 1999 11:28:19-0900 From: Blair Wondzell <Blair_Wondzell~admin.state.ak.us> Organization: SOA-AOGCC To: Chip Alvord <CALVORD~mail.aai.arco.com> CC: aogcc_prudhoe_bay~admin.state.ak.us, "Randy L. Thomas" <RLTHOMAS ~mail.aai. arco.corn>, Parker 245 Kuparuk <N 1268~mail.aai.arco.com>, Mike Zanghi <MZANGHI~mail.aai.arco.com> Chip, Thanks for the information. This is a minor incident and nothin9 further is warrented. Thank's again. Blair 2/18/99. Chip Alvord wrote: > Blair, > Parker #245 experienced a well control problem on 2/17/99 while drilling 1C-18 @ > KRU. ?" intermediate casing had been set directly above the Kuparuk sands @ > 7578'PIP. The well was TD'd in 6-1/8" hole @ 8095'FID with lO.Sppg drilling fluid. > After short tripping the interval in preparation of running the 4-1/2" > production liner the rig pumped out of the open hole interval to the 7" casing > shoe. The well was flow checked satisfactorily and the rig continued to POH with > the BHA. After pulling 10 stands the hole fill-up was inaccurate and a slight > flow was noted. The BHA was tripped back to bottom and the well was shut-in. > After stabilizing the recorded pressures were $IDP = lOOpsi and SICP = 160psi. > The influx was circulated out and the fluid system was weighted up to ll.lppg. > After getting kill fluid circulated around the well was opened up, monitored for > 30 minutes and was stable. The BHA was pulled without incident and the rig is > progressing with the completion of the well. Please call if you have questions. > > Regards, > Chip Alvord (265-6120) of 1 2/18/99 11:28 AM STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS ' 11 :'l-ype of request Abandon _ Suspend _ Operational shutdown _ Re-enter Sus-~-~nd~d-w~ii---_- ............ Alter casing _ Repair well _ Plugging _ Time extension _ Stimulate _ Other _X Change approved program _ Pull tubing _ Variance Perforate Annular Injection 2. Name of Operator 5. Type of Well' 6. Datum elevation (DF or KB feet) ARCO Alaska, Inc. Development__X RKB 41 feet 3. Address Exploratory__ 7. Unit or Property name P. O. Box 100360 Stratigraphic__ Anchorage, AK 99510-0360 Service__ Kuparuk River Unit 4. Location of well at surface 8. Well number 1478' FNL, 1010' FWL, Sec. 12, T11 N, R10E, UM 1C-18 At top of productive interval 9. Permit number / approval number 849' FSL, 1455' FEL, SEC 2, T11N, R10E, UM 99-05 At effective depth 10. APl number 50-029-22939 At total depth 11. Field / Pool 1042' FSL, 1638' FEL, SEC 2, T11 N, R10E, UM Kuparuk River Field / Kuparuk River Pool 12. Present well condition summer Total depth: measured 8095 feet Plugs (measured) true vertical 6677 feet Effective depth: measured 8030 feet Junk (measured) true vertical 6629 feet Casing Length Size Cemented Measured Depth True vertical Depth Conductor 80' 16" 9 cu yds. High Early 121' 121' Surface 4776' 9.625" 620 sx AS III LW, 550 sx Class e 4817' 4351' Production 7537' 7" 170 sx Class G 7578' 6307' Liner 735' 4.5" 130 sx Class G 8095' 6677' Perforation depth: measured 7753'-7783' MD true vertical 6430'-6451' TVD ORIGINAL RECEIVED APR 0 '[999 Tubing (size, grade, and measured depth 4.5", 12.6#, L~80 @ 7378' Packers & SSSV (type & measured depth) Baker 'ZXP' Liner packer @ 7360' j~¢0il & Anch0rag~ 13. Attachments Description summary of proposal __X Detailed operations program__ BOP sketch__ 14. Estimated date for commencing operation 15. Status of well classification as: May 1, 1999 16. If proposal was verbally approved Oil __X Gas__ Suspended __ Name of approver Date approved Service __ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Questions? Call Scott Goldberg263-4622 Signed ///~,,~,, ~ t~.,.,~ Title: Drilling Engineering Supervisor Date Chip Alvord~ ~_~.-- .~,. Prepared by Sharon AIIsup-Drake FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness I Appr°valn'~Jl"'L/~7 Plug integrity __ BO P Test __ Location clearance Mechanical Integrity Test__ Subsequent form required 10- ORIGINAL S!GNED BY / // Approved by order of the Commission ~nh~_rt NI _.~hri~,t~nson _C~o,k-~[nissioner Date _ _ Form 10-403 Rev 06/15/88 · SUBMIT IN TRIPLICATE CASING / TUBING I LINER DETAIL 9-5/8" Surface Casinq WELL: 1C-18 KRU ARCO Alaska, Inc. DATE: 2~8~99 Subsidiary of Atlantic Richfield Company 1 OF 1 PAGES # ITEMS COMPLETE DESCRIPTION OF EQUIPMENT RUN LENGTH DEPTH TOPS RKB to Landing Ring - Parker Rig #245 40.73 FMC Gen 5 Fluted Mandrel Casing Hanger & 40#, NSCC x BTC pup 1.58 40.73 25 Jts 9-5~8", 40#, L-80, BTC Casing (Joints #99 - #123) 970.05 42.31 TAM Port Collar 3.00 1012.36 96 Jts 9-5/8", 40#, L-80, BTC Casing (Joints #3 -#98) 3721.18 1015.36 Gemoco Float Collar 1.53 4736.54 2 Jts 9-5/8", 40#, L-80, BTC Casing (Joints #1 & #2) 76.93 4738.07 Gemoco Float Shoe 1.62 4815.00 Bottom of Shoe ==>> 4816.62 I TD of 12-1/4" Hole = 4826' MD (--10' of Rathole) Baker i_ok thru Float Collar Install TAM Port Collar on top of Jt #98 Run FMC Hanger on Top of Joint #123 15 Bow Spring Centralizers: 1/Jt on first 15 [oints, first 2 on stop rin$t in middle °f joint 2 Ri.~id Strai.~ht Blade Centralizers · Slide 1 on Jts #98 & #99 Leave OUT 7joints: Jts #124 thru #130 Remarks: String Weights with Blocks: 245K# Up, 205K# Dn, 75K# Blocks. Ran 1'23 joints of casing. Drifted casing with 8.679" plastic rabbit. Calipered hanger ID to verify 8-1/2" bit would pass. Used Arctic Grade APl Modified No Lead thread compound on all connections. Torqued connections to the base of the triangle stamp. Parker Ri~I #245 Drillin¢] Supervisor: Don E. Breeden ~,/~~~ ,ak ARCO Alaska, Inc. Cementing Details Well Name: 1C-18 Report Date: 02./10199 Report Number: 11 Rig Name: RIG # 245 AFC No.: AK0020 Field: Kuparuk RiverUnit Casing Size Hole Diameter: Angle thru KRU: I Shoe Depth: LC Depth: % washout: 9-5/8" 12-114" KOP (~ 2250'I 4817' MD, 4342' 'rVD FC (~ 4737' MD 45' Slant Centralizers State type used, intervals covered and spacing Comments: 15 Gemoco Bow Spring Centralizers: 1 I Joint on first 15 joints, first 2 on stop rings in middle of shoe joints. 2 ROTCO Rigid Straight Blade Centralizers: One on joints on each side of TAM port collar @ 1012'. Mud Weight: PV(prior cond): PV(after cond): YP(prior cond): YP(afler cond): Comments: 10.3 to 10.2 ppg 49 34 52 23 Gels before: Gels after: Total Volume Circulated: 20/38 10/15 2839 Bbls Wash 1 Type: Volume: Weight: Comments: ARCO 20 Bbls 8.34 ppg Spacer 2 Type: Volume: Weight: Comments: ARCO Spacer 50 Bbls 10.5 ppg Lead Cement 3 Type: Mix wtr temp: No. of Sacks: Weight: Yield: Comments: AS III LW 70* F 620 sx 10.7 ppg 4.44 cfs Additives: Class G + 50% D124 + 9.0% D44 + 0.4% D46 + 30% D53 + 1.5% SI + 1.5% D79 Tail Cement 4 Type: Mix wtr temp: No. of Sacks: Weight: Yield: Comments: G 70* F 550 sx 15.8 ppg 1.17 cfs Additives: Class G + 1% S1 + 0.2% D46 + 0.5% D156 (Fluid Loss Additive) + 0.3% D65 Displacement 5 Rate(before tail at shoe): Rate(tail around shoe): Sir. Wt. Up: Comments: 8 BPM 8 BPM 245K# (75K~ Blocks) Reciprocation length: Reciprocation speed: Str. Wt. Down: -15' -20 fpm 205K# (75K# Blocks) Theoretical Displacement: Actual Displacement: Sir. Wt. in mud: 359 Bbls 363 Bbls 146,600# Calculated top of cement · CP: Bumped plug: Floats held: Cemented to Surface - Date:2/10/99 Yes Yes Time:0700 hrs Remarks: Circulated to condition mud & hole for cementing, 6 to 8 BPNI, 450 psi, 2839 Bbls total. Reciprocated casing, 245K# Up, 205K~ Down. Circulated 2-1/2 hours extra while working on frozen valve at 1C-15 injection annulus & lining up trucks to haul returns to 1R-18 injection well - got lC-15 thawed out at 0900 hrs, 2/9. Cement Surface Casing, 2/9/99: Dowell flush lines with 5 Bbls water & test to 3500 psi. Pump 20 Bbls ARCO Pre-Flush & 50 Bbls, 10.5 ppg ARCO Spacer. Drop bottom plug. Mix & pump 490 Bbls, 620 sx, 10.7 ppg AS III LW Lead Cement, 8 BPM. Mix & pump 105 Bbls Class G Tail Cement with additives including D156 fluid loss additive. Drop top plug & chase with 10 Bbls Tail Cement (550 sx total) & 20 bbls wash-up water. Displace with mud using rig pump, 8 BPM. Bumped plug. Pressured up to 2000 psi & held briefly, OK. Floats held, OK. ClP (~ 0700 hrs, 2/9199. Reciprocated casing until 167 Bbls of Lead Cement had rounded the shoe, then left set on hanger (42 Bbls into Tail). Started seeing cello-flakes (put in 1st 3 Bbls of pre-flush) in returns at 92 Bbls into Tail, about 10 Bbls after calculated volume for gauge hole. Started dumping contaminated mud & cement shortly thereafter - theoretically had 70 Bbls of spacers & 302 Bbls Lead Cement returns to surface. Had 10.7 ppg cement returns, including some up to 11.6 ppg, until last 50 to 100 Bbls of displacement, when returns were 10.4 ppg to 10.6 ppg & very watery looking (not good cement), estimate 25% to 50% free water. Had full returns throughout. First 25 Bbls of Tail mixed normally at 15.8 ppg, then started having problems maintaining weight. PACR showed 12 to 13 ppg, DIS balance showed 14 ppg. Trying to mix heavier went to powder. Samples looked normal & weighed one at 15.6 ppg with rig scales. DIS mix water & slurry volumes came out right. DIS cementer had seen this mixing problem before, when D156 additive was used. RIH with TAM Combo Tool & shifted Port Collar at 1012' open. Circulated out contaminated mud & cement thru port collar. After circulating out 110 Bbls, about twvo 12-1/4" annular volumes, flutes in FMC Gen 5 hanger packed off & returns broke around conductor in cellar. Closed Port Collar & POH with TAM to°l. Spent rest of day & night rigging up & cleaning out 16" x 9-5/8" annulus to finish circulating same clean & cementing thru Port Collar. Had to cut Window in 16" below landing ring to run 1" CS Hydril tubing to 120' & circulate same clean. Flutes in hanger had not been opened up to get 1" CS HydHI thru them. Also, bypass area in flutes is much too small, making the Gen 5 hangers very prone to plugging off, as this one did. Once 16" x 9-518" annulus was cleaned up, RBIH with TAM Combo Tool. Shifted Port Collar open & finished circulating annulus clean above ports. RU Dowell. Dowell pumped 15 Bbl water spacer. Mix & pump 10.7 ppg AS III LW Cement until getting good, clean 10.7 ppg cement returns to surface thru port collar. Pumped 110 Bbls of Cement, started getting cement returs at about 65 Bbls pumped. Pump 1-1/2 Bbls of water behind to clear line to head pin. Rig displace DP with 18 Bbls mud. Closed port collar at 1012'. Circulated DP & casing clean. ClP (~ 0700 hrs, 2J10/99. Cement Company: Rig Contractor: Parker Approved By: Don E. Breeden ~ Dowell CASING TEST and FORMATION INTEGRITY TEST Well Name: 1C-18 Date: 2/20/99 Reason(s) for test: Supervisor: Guy Whitlock [] Initial Casing Shoe Test [] Formation Adequacy for Annular Injection [] Deep Test: Open Hole Adequacy for Higher Mud Weight Casing Size and Description: 9-5/8" 40# L-80 BTC Casing Setting Depth: 4,817' TMD Hole Depth: 4,343' TVD Mud Weight: 7.2 ppg Length of Open Hole Section: 7,585' TMD 6,312' TVD 2,768' EMW = Leak-off Press. + Mud Weight = 860 psi 0.052 x TVD 0.052 x 6,312' EMW for open hole section = 9.8 ppg + 7.2 ppg Pump output = 0.0580 bps Fluid Pumped = 2.6 bbl 3,400 psi 3,300 psi 3,200 psi 3,100 psi 3,000 psi 2/~30 psi 2,800 psi 2,700 psi 2,600 psi 2,500 psi 2,400 psi 2,300 psi 2,200 psi 2,100 psi 2,000 psi 1,900 psi 1,800 psi 1,700 psi 1,600 psi 1,500 psi 1,400 psi 1,300 1,200 psi 1,100 psi 1,000 psi 900 800 psi 700 psi 600 psi 500 psi 400 psi 300 psi 200 psi 100 psi 0 psi _~~!~T.~_~- -M- --~__~~p_~.~_: --e-- LEA K-OFF TEST l :i~q-~~-j-~_~~~!R~_H_H_FF~__-~ ........ i:,:, ........ LOT SHUT IN TIME ~~--~-¢1-~'~-CASING TEST SHUT IN TIME L~-~-~-~--~--~~-~..~_L_l_~_~ ~ TIMELINE ............... 11111111111111111111-7111 0 2 ~ 6 g 10121416182022242628SO$23436S8~04244~648~2~S~62~657072747678808284868S~9294969g 101010101011 1111111112 k k k k k k k k k k k k k k k k k k k k k k k k k k k k k k k k k k k k k k k k k k k k k k k k k k¢¢¢~¢¢¢~¢¢ k k k k k k k k k k k STROKES LEAK-OFF DATA CASING TEST DATA MINUTES MINUTES FOR FOR LOT STROKES PRESSURE CSG TEST STROKES PRESSURE 0 stks 750 psi ~ 0 stks 0 psi 2 stks 810 psi i ...................._4___s_t_k__s. ...... __8_0___p._s_! .... 4 stks 840 psi i 8 stks 310 psi ~. ...............~. ............... ~. ................ ..~ 6 stks 850 psi i 12 stks 550 psi ............................... ~ ................ .~ ................ ~. ............... ~. ................. 8 stks 850 psi i i ............... ..t. .............. .t. ................ 10 stks 850 psi : 12 stks 850 psi i .................. 'i:i-~;ii~--' 7-~§E~;~T-'i ~ .............. ..e. ................ ., .1. ~_ _s_t__k__s_ .8_.5.?_p._sL__j : ................. i 16 stks 760 psi t. ............... k ............... t. ................ -t 20 stks 960 psi .................... _%4..s..tk..s. .... ?__9__0___P_s! ................... _2..Es__tk_.s_ .... _! , .4_ _4_ _0_ _Es_ ! ................... _~..2__s__tk_.s_ .... 18 stks 860 psi i 36 stks 1,950 psi i, .................. .... ::::::::::::::::::::::::::::::::::::::::::::::: i i i · j ............... ~__2__2___s.t..k..s..~._.8._6__0.__p..sL..i 44 stks 2,470 psi j .................. .2_4.._s.t__k..s__~._.8..6..0...p..s.i___] 48 stks 2,750 psi 28 stks 860 psi ................................................ ................. .3_.o___s_t__k__s_ .... ~_o__p__s.L_~ 32 stks 860 psi .................. A4...s.t_.k..s_ .... ~E°_P..S!__j .................. ~..s.t..k..s__ ': __ ~E°___P..SL ..j 38stks ! 860 psi .............................. t ................ 40stks = 860 psi ................. -~-;~;--T---~-b';'~'--i ::::::::::::::::::::::::::::::::::::::::::: ~ i SHUT IN TIME i SHUT IN PRESSURE 1.0 min i 820 psi ............... ..~ .............. ~ ................ ....2:.O....m.i.n_ .................. ,,' _ _.8_ .1..0. _p..sj. _. 3.0 min j 810 psi 4.0 min J 810 psi 5.0 min i 810 psi ilEEEEiiiiiiiii !E Fi] 7.0 min i 810 psi 8.0min i ~ 810psi r' ............... r ................................ ! ' I SHUT IN TIME SHUT IN PRESSURE _..O....O...m.!.n._ 3,050 psi j ...1..9...m!n. ................... ~,.o?..4..p..s!j. 2.0 min 3,023 psi '"§:~"~ih' .................... ~;iJ~'~"F~f{,, ...E..g_..m!n. .................... ~,.o..2.L2.s!4 ___5_-._o...m!n. ................... ~,.o..%o..p..s! j _6_.__o_..m!n_ .................... ~:.O.l.%p..s!j ,_Z..g.._m!n_ .................... 8.0 min 3,017.psi J 9.0 min 3,016 psi l 10.0 rain 3,015 psi i ~. ............... ~. ............... ~. ................ ..~ ~_!_5.._9__.m_Ln..L .................. ~,.o.!.o..p..s! ',' '_.2._o...o.__m_Ln__[ ............... ~.~,_o__o__~__p__s!~ 9.0 min : ~ '~ 25.0 min: , 3,007 psi: ............... ~ .............. -F ................................. ~ ............... ~ ................ -~ 10.0 min: i 800 psi 30.0 min i ~ 3,006 psi i NOTE: STROKES TURN TO MINUTES DURING "SHUT IN TIME":see time line above NOTE: TO CLEAR DATA, HIGHLIGHT AND PRESS THE DELETE KEY CASING TEST and FORMATION INTEGRITY TEST Well Name: 1C-18 Date: 2/11/99 Reason(s) for test: Supervisor: Don Breedon [] Initial Casing Shoe Test [] Formation Adequacy for Annular Injection [] Deep Test: Open Hole Adequacy for Higher Mud Weight Casing Size and Description: 9-5/8" 40# L-80 BTC Casing Setting Depth: 4,817' TMD Hole Depth: 4,343' TVD Mud Weight: 8.4 ppg Length of Open Hole Section: 4,837' TMD 4,353' TVD 20' EMW = Leak-off Press. + Mud Weight = 1,219 psi 0.052 x TVD 0.052 x 4,353' EMW for open hole section = 13.8 ppg + 8.4 ppg Pump output = 0.0850 bps Fluid Pumped = 2.6 bbl TIME LINE: 3,400 psi 3,300 psi 3,200 psi 3,100 psi 3,000 psi 2,900 psi 2,800 psi 2,700 psi 2,600 psi 2,500 psi 2,400 psi 2,300 psi 2,200 psi 2,100 psi 2,000 psi 1,900 ps[ 1,500 psi 1,700 psi 1,600 psi 1,500 psi 1,400 psi 1,300 psi 1,200 psi 1,1 O0 psi 1,000 psi 900 psi 800 psi 700 psi 600 psi 500 psi 400 psi 300 psi 200 psi 1 O0 pSI _. _ _ ~(-- ~-;~_~- --e--LEAK-OFF TEST - ~-- )-~ .... "'em'CASING TEST _ ~i::i,:~! '.!~i?:,, ~xi~,,: ~:'~"~ - ,.,:,,.:~i~!i,~,,.,,.. LOT SH UT IN TIM E ---_. :,,_ --- ,,ST S.T T.. - -- t , TIME LINE 0 psi I 0 2 4 6 8 1~12141618 2~ 22 24 26 28 3~ 32 34 36 38 4~ 42 44 46 48 ~ 52 ~ ~ 58 ~ 62 ~ ~ 68 7~ 72 74 76 78 8~ 82 84 86 88 ~ 92 94 96 981~1~1~1~ kkkkkkkkkkkkkkkkkkkkkkkkkkkkkkkkkkkkkkkkkkkkkkkkkk~ kkkk STROKES LEAK-OFF DATA CASING TEST DATA MINUTES MINUTES FOR FOR LOT STROKES PRESSURE CSG TEST STROKES PRESSURE ................ i----~-;ii~;---1- .... i:i-~;'f .... l ................ F--b--~¥~;---[ .... -~"r;;i .... ............... 1- .............. 1' ................ 1 ................ I' ............... t ................ ............... ,__,_,,,,___,___,,_,_,,____, ................ ,___,_,,,,___,___,,_,,,___, ............... / __.4._s!k_.s__i ___.8__6___p__s! ___] ................... _8__s__t.k._s_ ..... ._3.1..o.__p_.s_L 10 stks 276 psi 12 stks 385 psi ............... · .I- .............. --i- ................ 14 stks 474 psi ................. !S__.s_t__k._s. .... .5_.6_.7_._p. _s_i___, ................... _l__8___s_Lk__s_ .... .6_Z.7___P._s.i___. 20 stks 774 psi 22 stks 869 psi 24 stks 966 psi 26 stks 1,068 psi ................. _2_~__s_t__k__~___ __~_,__2a ~. R .s.[..~ 30 stks 901 psi ~ ! 12 stks 550 psi 20 stks 960 psi , 24stks 1,190psi2 44 stks 2,470 psi 48 stks 2,750 psi SHUT IN TIME J SHUT IN PRESSURE ................................................. ~ 1.0 minj 3,024 psi ............................... T ................ ::::::::::::::::::::::::::::::::::::::::::::::: SHUT IN TIME SHUT IN PRESSURE ._.l.:.O._.m..i_n_ ...................... .7_.4_.4.._p..s_i... ,__2:_o.__m__i.n_ .................... Z.3_.4_p__sL __ ,._._3:.O...m..i.?.. ", .............. ',,..Z~R.p..s.i...., ....4:.o...m..i.n...! .............. i, ..Z&S...p.?/.. 5.0 min J J 723 psi ..!:~.~J?....~ ................ 8.0min i i 716psi , ............... .{.. .............. ,-}- ................. __ .9:.0....m.i.n... j. .............. i...7_1..5...p..s.i..., 3.0 min ~ j 3,022 psi j ................ ,~ ............... t ................ 4.0 min i i 3,021 psi4 .__~...o_..m_!.n__.. ................ ... _~,.o.]__9__p..s.]_j 7.0 mini i 3,018 psi: ............... J. ............... - ................ ,.~ ....8_...O...m!n...L ............... i_~,.o.]z.p..s.].,i 9.0 min : : 3,016 psi : 15.0 min L : 3,010 psi: ............ ?'", ............... t .............. 20.0 mm: : 3,008 ps~: 10.0 min: : 715 psi 30.0 min: : 3,006 psi : NOTE: STROKES TURN TO MINUTES DURING "SHUT IN TIME":see time line above NOTE: TO CLEAR DATA, HIGHLIGHT AND PRESS THE DELETE KEY CASING TEST and FORMATION INTEGRITY TEST Well Name: 1C-18 Date: 5/6/99 Supervisor: R.L. Morrison Reason(s) for test: [] Initial Casing Shoe Test [] Formation Adequacy for Annular Injection [] Deep Test: Open Hole Adequacy for Higher Mud Weight Casing Size and Description: 9-5/8" 40# L-80 BTC Casing Setting Depth: 4,817' TMD 4,343' TVD Hole Depth: 7,585' TMD 6,312' TVD Mud Weight: 7.2 ppg Length of Open Hole Section: 2,768' EMW- Leak-off Press. + Mud Weight 0.052 x TVD = 1,400 psi + 7.2 ppg 0.052 x 6,312' EMW for open hole section = 11.5 ppg Pump output = 0.0750 bps Fluid Pumped = 6.3 bbl 3,300 3,200 3,] O0 psi 3,000 psi 2,900 psi 2,800 psi 2,700 psi 2,600 psi 2,500 psi 2,400 psi 2,300 psi 2,200 psi 2,1 O0 psi 2,000 psi 1,900 psi 1,800 1,700 1 ,b00 1,500 1,400 1,300 1,200 1,100 1,000 800 70O 60O 5OO 300 200 0 psi -1 1 3 5 7 9 11 13 15 17 19 21 23 25 27 29 31 33 35 37 39 41 43 45 47 49 51 53 55 57 59 61 63 65 67 69 71 73 75 77 79 81 83 85 87 89 91 93 95 97 99 stk stk stk stk stk stk stk stk stk stk stk stk stk stk stk sfk stk stk sfk stk bik stk stk stk bik ~fk b"tk stk sfk stk stk stk stk atk stk stk stk stk stk stk stk stk stk stk ark stk stk stk stk stk sfk STROKES LEAK-OFF DATA CASING TEST DATA MINUTES MINUTES FOR FOR LOT STROKES PRESSURE CSG TEST STROKES PRESSURE .................... -~-i;iR~- ........ i~-~;~-~ .... ! .................... ~-'4i-~"-f .... -6-~;i;i ...... ............... ~ .............. ~- ................ 4 ................................ t ................. i 7stks ~ 700 psi i 4stks ~ 80 psi 35stks 1,300psi i 42stks 1,300psi i 8stks j 310psi ................... _l__2__s__t.k_.s.__[___ _s.S_.0_..p..s.[._. ................... _l__6__s__t_k__s_ _[.. Z?.°._.P_.S_L .j 20stks i 960 psi ~ ................... 28 stks j 1,440 psi~ J 63 stks 1,250 psi J ................ ~ .............. ..,i. ................ .[. ' 70stks 1,250psi ~ 77 stks 1,250 psi ! 84 stks , 1,250 psi i ............... '{' .............. T ................ , ' ! ! ! ' 1 ............................... T ................ I SHUT IN TIME, SHUT IN PRESSURE ...............0.0 min T ................. ............... ~,- ............................... 1.0 min ! 1,000 psi ! ............... ..~ ................................ 36 stks ! 1,950 psi J 44 stks i 2,470 psi 1 ................... 52 stks j 3,050 psi j ................................ ~- ................ ! ................................ [ ................ ! SHUT IN TIME SHUT IN PRESSURE _ _ _O_ ._ _O_ _m_ ! _n_ .................. 3,050 psi l 1.0 min 3,024 psi L 3.0 min ~ . 3,022 psi 4.0 min : 3,021 psi 5.0 min ! 3,020 psi ._..2:.O...m_i.n.._ .j .................. _9..O_O...p..s.i...] ._.6_...O...m.!.n...L ................. .3. ,.O..'l..9..p..s.].j ,_.9:_o__m__Ln__:, ................. _a.~_q.p__sl_j .... l..9_..m_Ln___L ................. ~,.q!9_.P..S_]_J 4.0 min : 775 psi i 8.0 min ' 3,017 psi i 5.0 min i 750 psi i 9.0 min i 3,016 psi ~ ._..6:_o._.m..i.n...i ................. .7_.0__0__p__s.i._.j 10.0 min: 3,015 psi ~ 7.0rain : i 700 psi i 15.0mini 3,010psi: ........... r---l- .............. ~ ............ -.---I ,~ ........... :---~ ............... t .............. :--t 8.0mln ~ ~ 690psm : : 20.0m{n: : 3,008psm: ........... .'-----P .............. ,J- ............ -.---4 ,'- ............... I- ............... I- .............. :--{ 90mln : : 690psm : : 25.0mln [ : 3,007psm ~ ,-----': ......... d- .............. q- ................ 4 l ................ I. ............... I. ................ L_!g:.o_.m_!n_ i .............. ±__.6_.9_.q_p__s_i___] k_3__o_._g___m_Ln__k ............... L],_qp_6__p__s_)_j NOTE: STROKES TURN TO MINUTES DURING "SHUT IN TIME":see time line above NOTE: TO CLEAR DATA, HIGHLIGHT AND PRESS THE DELETE KEY TONY KNOWLE$, GOVERNOR ALASKA OIL AND GAS CONSERVATION COMMISSION 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 January 21, 1999 Chip Alvord Kupamk Drilling Team Leader ARCO Alaska,. Inc. PO Box 100360 Anchorage, AK 99510-0360 Re: Kuparuk River Unit 1 C- 18 ARCO Alaska,. Inc. Permit No: 99--05 Sur Loc: 1478'FNL, 1010'FWL, SEC 12, T11N, R10E. UM Btmhole Loc. 1024'FSL, 1607'FEL, SEC 02, T11N, R10E,UM Dear Mr. Alvord: Enclosed is the approved application for permit to drill the above referenced well. Please note ttmt any disposal of fluids generated from this drilling operation which are pumped down the surface/production casing annulus of a well approved for annular disposal on Drill Site C1 must comply with the requirements and limitations of 20 AAC 25.080. Approval of this permit to drill does not authorize disposal of drilling waste in a volume greater than 35,000 barrels dtrough the annular space of a single well or to use that well for disposal purposes for a period longer than one year. The permit to drill does not exempt you from obtaining additional permits required by law from other govermnental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are nmde. Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25 035. Sufficient notice (approximately 24 hours) must be given to allow a representative of the Commission to witness a test of BOPE installed prior to drilling new hole. Notice may be given by contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. · ~,' S~ncerely, " /. Clmirman BY ORDER OF THE COMMISSION dlf/Enclosures cc: Department of Fish & Game, Habitat Section w?o encl. Department of Environmental Conservation w/o encl. STATE OF ALASKA AL,k~KA OIL AND GAS CONSERVATION COMi'~SSION PERMIT TO DRILL 2O AAC 25.OO5 la. Type of Work Drill X Redrill I lb Type of Well Exploratory Stratigraphic Test Development Oil X Re-Entry Deepen/ Service Development Gas Single Zone X Multiple Zone 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool ARCO Alaska, Inc. RKB 41', Pad 61' feet Kuparuk River Field 3. Address 6. Property Designation Kuparuk Oil Pool P. O. Box 100360, Anchorage, AK 99510-0360 ADL 25649, ALK 467 4. Location of well at surface 7. Unit or property Name 11. Type Bond (see 20 AAC 25.025) 1478' FNL, 1010' FWL, Sec. 12, T11N, R10E, UM Kuparuk River Unit Statewide At top of productive interval (@ TARGET ) 8. Well number Number 857' FSL, 1432' FEL, Sec. 2, T11N, R10E, UM 1C-18 #U-630610 At total depth 9. Approximate spud date Amount 1024' FSL, 1607' FEL, Sec. 2, T11N, R10E, UM 1/24/99 $200,000 12. Distance to nearest 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) properly line 1 C-04 8058' MD 857' @ Target feet 45.4' @ 1360' feet 2560 6632' TVD feet 16. To be completed for deviated wells 17. Anticipated pressure (see 2O AAC 25.035(e)(2)) Kickoff depth 2250' feet Maximum hole angle 45.28° Ma~dmum surface 2994 psig At total depth (TVD) 3710 psig 18. Casing program Setting Depth size Specifications Top Bottom Quantity of cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) 24" 16" 62.5# R-3 Weld 79' 41' 41' 120' 120' 9 cu yds. High Early 9.625" 12.25" 40# L-80 BTC 4776' 41' 41' 4817' 4351' 683 Sx Arcticset III L & 541 Sx Class G 7" 8.5" 26# L-80 BTC-Mod 7502' 41' 41' 7543' 6270' 208 sx Class G 4.5" 6.125" 12.6# L-80 NSCT 715' 7343' 6129' 8058' 6632' 111 sx Class G 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: truemeasuredvertical feetfeet Plugs (measured) J/~ N, ~, 3 '! 9 9 9 Effective depth: measured feet Junk (measured) ~l~Jas~/~, 0il & Gas Cons, Oorr-irnission true vedical feet Anchoraoe Casing Length Size Cemented Measured depth TrLTe Vertical depth Structural Conductor Surface Intermediate Production Pedoratio~i;;rpth: measuredORIGINAL true vertical 20. Attachments Filing fee X Propedyplat ~ BOP Sketch X Diverter Sketch X Drilling program X Drilling fluid program X Time vs depth plot E~ Refraction analysis [~ Seabed report [~ 20 AAC 25.050 requirements X 21. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed //~_~..~ ~ ~..~.. Title Kuparuk Drilling Team Leader Date CZ.f~ Commission Use Only Perm(~_b~..~ APl number 50- O 2'C~- 22 ~;;~ ~ ¢ IAppr°val date I-~ ~ -- C~ ISee c°ver letterf°r~r requirements Con~litions of approval Sampler required [~ Yes ~ No Mud Icg required E~l Yes No Hydrogen sulfide measures Ei~ Yes r~i No Directional survey required .~ Yes F~ No Required w°rking pressure f°r BO F.i 2M r~l aM [~~ 10M [] 1EM Other: ORIGINAL SIGNED. BY Robert N. Chdstenson by order of/ F~l ~ .... Form 10-401 Rev. 7-24-89 Submit in triplicate ARCO Alaska, Inc. - Kuparuk Drillsite Development Post Office Box 100360 Anchorage, Alaska 99510 Telephone 907 265-6206 Michael Zanghi Supervisor Jan 12, 1999 Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 (907) 279-1433 Re: Application for Permit to Drill 1C-18 Kuparuk Development Production Well, Kuparuk River Unit Dear Sirs: ARCO Alaska, Inc. hereby applies for a Permit to Drill an onshore development well to the Kuparuk interval from 1C pad in the Kuparuk River Unit ("KRU"). The well is designed to penetrate and further develop the production potential of the Kuparuk sands in the vicinity of 1C pad. The well is designated as a conventional production well using a 9 5/8" surface casing string, a 7" intermediate casing string, a 4 Y2" liner and 4-1/2" tubing. Please find attached information as required by 20 AAC 25.005 (a) and (c) for your review. Pertinent information attached to this application includes the following: 1) Form 10-401 Application for Permit to Drill per 20 AAC 25.005 (a). 2) Fee of $100 payable to the State of Alaska per 20 AAC 25.005 (c) (1). 3) A directional plat showing the surface and bottomhole locations proposed for the well per 20 AAC 25.005 (c) (2). 4) Directional plots and proximity calculations in accordance with the requirements of 20 AAC 25.050. 5) Diagrams and descriptions of the BOP and diverter equipment to be used as required by 20 AAC 25.035 (a) (1) and (b) 6) A complete proposed casing and cementing program is attached as per 20 AAC 25.030. A wellbore schematic is also attached visually depicting the proposed well and completion design. 7) The drilling fluid program, in addition to the requirements set forth in 20 AAC 25.033 are attached in this APD package. 8) A copy of the proposed drilling program, including a request for approval of annular pumping operations is attached. 9) Also note that ARCO does not anticipate the presence of H2S in the formations to be encountered in this well. However, there will be H2S monitoring equipment functioning on the rigs as is the standard operating procedure in the Kuparuk River Unit drilling operation. ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany 10) Please note that because of the large volume of regional information available in this area, ARCO considers this well to be a development well, and as such, no mudlogging operations such as type log generation and sample catching are planned. Please note that the anticipated spud date for this well is January 24, 1999. If you have any questions or require further information, please contact Scott Goldberg at (907) 263-4622 or Chip Alvord at (907) 265-6120. Sincerely, Scott Goldbterg (___ Operations Drilling Engineer CC: Kuparuk lC-18 Well File Chip Alvord ATO-1200 MJ Loveland NSK6 Drill and Case Plan for 1C-18 Kuparuk Producer General Procedure: 1. Excavate cellar, install cellar box, set and cement 16" conductor to +/- 120' RKB. Weld landing ring on conductor. 2. Move in / rig up drilling rig. Install diverter & function test same. Spud and directionally drill 12 1/4" hole to the surface casing point at 4817' MD. Run MWD / LWD logging tools in drill string as required for directional monitoring and formation data gathering. 4. Condition hole for casing, trip out. . · Run and cement 9 5/8" 40# L80 BTC casing string to surface. Employ lightweight permafrost cement lead slurry to assure cement returns to the surface in a one stage job. Adequate excess cement will be pumped to ensure cement reaches the surface during the cement job. · TAM Port Collar will be placed in the casing string at 1000' MD to be used in the event that cement does not reach the surface in the primary one stage job. 6. Nipple down diverter, nipple up BOP's. Test BOP's. Notify AOGCC 24 hours before test . Make up 8 Y2" bit and BHA and RIH to top of float equipment · Pressure test casing to 3000 psi for 30 minutes · Record results and fax to town , Drill float equipment and approximately 20' of new hole · Perform LOT · Record results and fax to town . Drill 8 Y2" hole to intermediate casing point at +7543' MD · Perform a second LOT and determine an acceptable kick tolerance · If kick tolerance is acceptable, 8 Y2" hole will be drilled to TD · If kick tolerance is unacceptable, 7" casing will be run to top Kuparuk 10. Run and cement 7" 26# L80 BTC-Mod Steps 11-14 are only applicable if we are required to top set the Kuparuk with 7" casing 11. Make up 6 1/8" bit and BHA and RIH to top of float equipment · Pressure test casing to 3000 psi for 30 minutes · Record results and fax to towr~ 12. Drill · float equipment and approximately 20' of new hole Perform LOT · Record results and fax to town 13. Drill 6 1/8" hole to TD at 8058' · Condition hole and mud for casing 14. Run and cement 4 Y~" 12.6# L80 NSCT Liner 15. Make a cleanout run with bit and scrapers · Displace to filtered seawater · Pressure test well to 3000 psi for 30 minutes · Record results and fax to town 1 C-18 Page 1 SG,01/12/99,v1 16. Run and land 4 Y2" tubing with gas lift completion 17. Nipple down BOP's. Install production tree and pressure test same. 18. Secure well, release rig 1 C-18 Page 2 SG,01/12/99,v1 DRILLING FLUID PROGRAM, PRESSURE CALCULATIONS & DRILLING AREA RISKS Kuparuk 1C-18 Producer Drillinq Fluid Tvpe Surface Hole: Intermediate Hole: Production Hole: Extended Bentonite Slurry Low Solids Non-Dispersed System Low Solids Non-Dispersed System Drilling Fluid Properties: Formation Density FV YP PV ppg sec/qt lb/100 ft2 cP Permafrost 8.9 120-140 25-40 16-20 West Sak 9.5-9.8 50-80 15-25 20-26 Colville 8.8-9.0 35-40 5-8 4-8 H RZ 9.5 40-50 8-20 15-25 Kalubik 9.5 40-50 8-20 15-25 Kuparuk C Sands 10.8-11.0 50-60 (Tau 0) 7-9 20-30 Filtrate mi/30 min 12-15 7-8 8-15 5-6 5-6 12.0 Drilling Fluid System: Tandem Brandt Scalping Shale Shakers Triple Derrick Flow Line Cleaners Solids Processing System to Minimize Drilling Waste Desander, Mud Cleaner, Centrifuges, Degasser Pit Level Indicator (Visual and Audio Alarm) Trip Tank Fluid Flow Sensor Fluid Agitators Mud Hoppers with Mixing Pumps MASP (Maximum Anticipated Surface Pressure): Based on estimated Static Bottom Hole Pressure data from nearby wells, expected reservoir pressures in the Kuparuk sands in the 1C pad area are approximately 10.4 ppg EMW (equivalent mud weight), depending on the TVD of the sand layer being evaluated. Assuming a 150 psi overbalance is required to safely drill and trip in this formation, then a required mud weight of 10.9 ppg can be predicted as a maximum mud weight required to safely drill this formation, assuming a TVD of 6367'. Calculating MASP based on the most recent reservoir pressure data from nearby wells, and assuming a gas gradient of 0.11 psi/ft from the Kuparuk base to surface, the following MASP can be computed: MASP = (6509 ft)(0.57 - 0.11 psi/ft) = 2994 psi 1 C~18 Page 1 SG,01/12/99,v. 1 Drilling Area Risks: Drilling risks in the 1C-18 area are lost circulation and potential borehole instability in and below the permafrost formation. Lost circulation will be addressed with lost circulation material (LCM) and reduced circulating rates as needed. Borehole instabilty will be addressed through mud treatments and control drilling if necessary. In addition, there is a strong likelihood of shallow gas while drilling off Drillsite 1C. This will be handled by control drilling and mud treatments. Well Proximity Risks: The nearest existing well to lC-18 is 1C-04. As designed, the minimum distance between the two wells would be 45.4' at 1360' MD. Annular Pumping Activities: Incidental fluids generated from drilling operations will be hauled to the nearest permitted disposal well or will be pumped down the surface / production casing annulus of a annular disposal permitted existing well on DS-lC. That annulus will be left with a non-freezing fluid during any extended shut down (> 4 hr) in pumping operations. The lC-18 well will be freeze protected after running the 3 Y2" tubing and prior to the drilling rig moving off of the well. We request that lC-18 be permitted for annular pumping of fluids occurring as a result of drilling operations, per regulation 20 AAC 25.080. Any zones containing significant hydrocarbons will be isolated prior to initiating annular pumping. There will be no USDW's open below the shoe or potable/industrial water wells within one mile of the receiving zone. Reference the enclosed directional drilling plan for other formation markers in this well. Surface casing will be set in the Cretaceous shales below the base of the West Sak Sands. These 300-500' thick shales are part of the Colville Group and are known to provide vertical barriers to fluid flow. The surface casing shoe will be set a minimum of 100' vertically below the base of the West Sak into the heart of the shales. The maximum volume of fluids to be pumped down the annulus of this well will not exceed 35,000 bbl without the specific permission of the AOGCC. Fluid densities will range from diesel to a maximum of 12.0 ppg for drilling fluid wastes. Using 12.0 ppg fluid and the rig's specified maximum pumping pressure of 1,500 psi for annular injection, the maximum pressure at the surface casing shoe is estimated by: Max Shoe Pressure = (12.0 ppg) * (0.052) * (Surf. Shoe TVD) + 1,500 psi = (12.0 ppg) * (0.052) * (4351') + 1,500 psi Max Pressure = 4,215 psi This pressure is conservative, since frictional losses while pumping have not been taken into consideration. The surface and production casing strings exposed to the annular pumping operations have sufficient strength by using the 85% collapse and burst ratings. Fluids to be disposed of in the annulus will be limited to drilling wastes associated with drilling a well as defined in 20 AAC 25.080 (h). 1 C-18 Page 2 SG,01/12/99,v.1 TAM International Port Collar set at +/-1000' MD Surface csg. 9 5/8" 40# L-80 BTC (+/-4817' MD / 4351' TVD) ,RU lC-18 Producer Complet, ..... i 6-1/8" Hole / 4-1/2" Liner I, 4-1/2" 5M FMC Gen V tubing hanger with 4-1/2" L-80 NSCT pin down H. 4-1/2" 12.6# L-80 NSCT tubing to surface G. 4-1/2" Camco WRDP-2 SSSV F, 4-1/2" 12.6# L-80 NSCT tubing to nipple All depths reference Parker 245 RKB F. 4-1/2" 12.6# L-80 NSCT tubing to SSSV w/4 1/2" x 1" Camco KBG- 2 mandrels w/DV's and BK Latches. 4 1/2" x 10' NSCT pups installed. Spaced out as follows: GLM # TVD-RKB MD-RKB Size-Valve 1 1 "-Dummy 2 1" Dummy 3 1" Dummy 4 1" Dummy 5 1" Dummy 6 1 1/2" (As described in "E") 4-1/2" Liner Top: 200' above 7" shoe (+/- 7343' MD / 6129' TVD) Intermediate csg. 7" 26# L-80 BTC-Mod set above KUP, run to surface (+/-7543' MD / 6270' TVD) E. 4-1/2" x 1" Camco 'KBG-2' mandrel w/RD Dummy Valve & BK latch, 4-1/2" x 10' pups installed, L-80 NSCT D. I jt 4-1/2" L-80 NSCT tubing C. 4-1/2" Camco "DB" landing nipple w/3.75" ID, NoGo profile (No pups) B. 1 jt 4-1/2" L-80 NSCT tubing A. Baker 4-1/2" 'GBH-22' Seal Assembly w/10' of seals and special Iocator to locate in liner tieback sleeve. Locator 5.125" OD, seals 4.75" ID. 6' handling pup installed on top 4-1/2" Liner Assembly (run on drillpipe): -- Baker 'C-2' tieback sleeve with Iocator, 6' -- Baker 5" x 7" 'ZXP' Liner Top Isolation Packer -- Baker 5" x 7" 'HMC' Hydraulic Liner Hanger -- Baker '80-40' 10' Seal Bore Extension (4.0" ID seal bore), 4-1/2" NSCT pin down Liner 4-1/2" 12.6# L-80 NSCT (+/- 8058' MD / 6632' TVD) Future Perforations 4-1/2" NSCT landing collar/FS/FC SG, 1/12/98, v. 1 ARC~O Alaska, Inc. 5h'uafur~: Pad 1C Well: 18 F~d: Kul~rUk I~r Unit I.=maflon: North ~op~, Alaska 4O0 4OO 8OO 1200 1600 2000 24O0 2800 5200 5600 4000 44O0 480O 5200 5600 6000 64-00 <- West (feet) 5000 2700 2400 2100 1800 t 500 1200 go0 600 500 0 500 31:3.71 AZIMUTH ' ' , , , , , , , , ~ , , , , , , , , , , , ~ooo 3378' (TO TARGET) RK8 ELEVATION 102' TD LOCATION: t024' FSL, 1607' FEL SEC 2, TIIN, RIOE TARGET LOCATION: 857' [~L, 1'1~2' FEL SEC 2, TI1N, Rt0E TARGET TVD=6592 TMD=771 7 DEP=5378 NORTH=2555 WEST=2442 2700 2400 2100 18oo Z 15oo 0 BASE PERMAFROST TVD= 1802 TMO= 1802 DEP=O \'"~'"~'-'~ KOP ~=~50 TMD=2250 DEP=O 0 ~.~ ~00 O~: 3.00 deg per 100 ft ~ WSlO 12,00 21.00 ' ~ 27.00 , ~C Sa 24.00 ~ 30.00 ] SUR~ ~c~os: J ~ ~oo 45.00EOC WD=3607 ~D=3759 DEP=566 Bose Pe~ofros~KOP 0 TOP WEST ~K ~=5758 TMD=5974 DEP=718 300 ~10 ~=4151 ~D=4552 DEP=1115 9 5/8" CSG PT WD=4551 ~D=~17 DEP=1517 ' ~ C90 ~=4589 TMD=4871 DEP=1356 -10) ~=4553 TMD=5104 DEP=1521 C50 WD=5520 ~D=6194 DEP=~96 ~ C~ (K-5) ~D=5658 TMD=6646 DEP:2617 ~. c30 (K-~ ~=59~ T~D=70~2 0[P=29~7 TARGET / T~GENT ~~E: ~ C20 (HR~ MID-PT> m:6065 mD:7255 DEP=3048 45.28 DEC ~ ~-~ ~.~E. ~=~23s ~=7.~. OEP=~=O ........ % 7" CSt ~r W0=~270 ~0=75~3 0EP=3255 D~=337~ --% TOP C5 ~=6403 TMD=7755 DEP=3589 TAR~2 ~7~ % TOP C2 WD=6~51 ~D=7775 DEP=5418 ~ TOP C1 WD=6509 TMD=7884 DEP=5496 - ~%~ TOP B SHOE WD=6523 ~D=7905 DEP=5511 TD - 4 1/2" LINER TVD=6652 TMD=8058 DEP=5621 6800 7200 [ [ i [ [ [ , , = [ [ , ~ [ , i ] [ [ [ i [ 400 0 400 800 1200 1600 2000 2400 2800 5200 5600 4000 Vertical Section (feet) -> Azimuth 515.71 with reference 0.00 N, 0.00 E from slot #18 I Created ~ Andre~ Oata I~c~,,d: B-don-99 ARCO Alaska, .nc. Sfruafur~: Pad lC Well: F/Md: Kuparuk R/~r Unft Lam:alton: North ~ape, Na=kal I <- West (feet) 260 240 220 200 180 160 1 40 120 1 O0 80 60 40 20 320 I J I I I J I I 500 280 260 240 220 200 \ \ \ \%,3300 \ \ \ __300 120 0 Z 100 6o 2o 20 60 26( e \ \ \~,3200 \ \ \ 1900 2400 120d 2300 1800 2200 \ ~lOCk gOO 2100 2000 \ 0 1 '" ~.1200 1800 /~00 X 1700 1 0 20 40 60 2700 250o" 24o~oo I~UU .... .... ~ ........... ~ , ~ I 4,~0 ,~ I 6 I ~0 I I I 240 220 2 0 180 160 140 120 100 0 0 0 40 60 <- West (feet) 520 300 280 260 240 22O 200 180 160 A I Z 120 ~ 100 ~ 80 §0 6O 2O 2O ARCO Alaska, Inc. ~af~ p/oVid: R--Jan-gg Fqot Refe~nc~ ;~ ~8 ~ I~. ~d: Kulak ~r Unlf ~on: North ~o~ Namka T~ ~1 ~p~ a~ r~ ~B (~ 2~). ~ ..... --- ' ~ - ,~ <- Wost (foot) 520 ~0 ~0 460 ~ 420 ~0 3~0 360 ~ ~20 ~00 280 260 2~ 220 2~ 5~0 ] I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I 5~0 560 560 5~ 5~ 520 520 ~0 N N N ~0 ~80 N ~80 160 X 420 A N 1100~ ~ Z ~ ~ ~ 1500 ~0 0 380 %%~%% 1~0 360 v 5~ 900 % % 1200 ~500= % 1 O0 ~20 520 % 1500 800 % 000 ~00 ~00 O0 700 2000 280 % 280 600 1 ~ 5400 260 260 1 11 1700 % % 2~ 1 220 ~ 1 ~ x~3gO0 220 200 200 520 500 480 480 4~ 420 ~0 380 ~80 ~ ~20 300 280 260 2~ 220 2~ <- Wosf (foot) 420 380 (.- ,-.I-- 0 Z 360 h I Cmeted by:. Andre~ Fo~. C, OLDB~ Tree v~l~l I~1~ ore r~ R~8 (Perker 245). 20(]0 1900 1800 1700 2500 220O 2100 2O0O 1900 1800 1700 1600, 1500 1400 1500 1200 1100 1000 gOO 800 700 600 500 400 2000 ARCO Alaska, Inc. ~trualur~: Pad lC Well: 18 F/eld: Kuper~k Rrver Unit I.~=cfflon: Norfh Slope, Alaska <- West (feet) 1600 1500 1400 1500 1200 11 OD 1000 900 800 700 600 , , , , I , , , , , , , I , , , , , I , , , , , , , I ~.t I , I \ 2600 k ~ ~oo '2600 \~oo ~ \ Xoo° ~oo~,, \ \ x q X. 2600 2~oo ), "°°".X'°° .... 500 \ -,~oo \.oo \,~ 4400 $¢00 ~ \ 2000 500 4000 19O0 5200 1700 \ ,.. 5900 700 ,,, 3800 1600 i i i i i , i i i i i i i i i i i i i i i i i i J i i i 1900 1800 1700 1600 1500 1400 1500 1200 1100 1000 900 800 <- West (feet) 700 600 500 400 5O0 4O0 2500 22OO 2100 2000 1900 1800 1700 1600 1500 1400 1300 1200 1100 1000 900 800 700 6OO 500 4O0 Created b)c Andre~ ~'o~. COr. ni~R~ Tru~ V~tlcol {~pt~ or~ r~.~-.o~ RXB ([Parker 24~). ARCO Alaska, ~nc.[ ........... Sh'~ot'ure: Pod lC Well: FTo4d : KupGruk RTver Unft LGocrHon: Norfh Siop~ AJoska] <- West (feet) 4000 5800 5600 5400 3200 5000 2800 2600 2400 2200 2000 1800 1600 1400 1200 1000 800 4600 4600 15800 4100 44O0 5700 44O0 4000 5600 4O00 4200 5500 5900 590C 4.200 5400 4000 5800 5500 4000 5200 $700 5800 5100 3800 5600 5000 5600 5600 3500 4900 2800 2600 2400 3400 3400 ~800 3400 \ 5300 ~4700 5200 3200 k3200 ~4600 k ,~45oo A 5ooo, 't~~°° ~44oo ~ooo ^1 ' 5000 · 4500 ~ k~°°° ~oo k~oo ~oo ~oo ~ ~~oo ~ 6~0 % 2700 .4;~oo 52700 53700 2200 ~oo ~ % 6000 X ooo '<5;oo ooo ~ ~soo~ ~3oo -,~7oo k .... ~oo 1800 nn ~-3100 ' ,~60~ 52400 1800 5000 %~;~0 2500 O0 1600 4900 ~00 5500~. k2900 1600 4700 520~X 2200 ~2800 1~0 4600 5100% ~2700 1~0 4500 500~ ~004500 49~ 2100 1200 4200 %4700 1200 4100 ~00 % 4600 1000 5900 %4500 ~000 5800 %~00 1 2800 2600 2400 800 800 4000 5800 5600 3400 5200 5000 2800 2600 2400 2200 2000 1 BOO 1600 1400 1200 1000 800 <- Wesf (feel) ARCO Alaska, Inc. Cre~ted t~. ~ndrewl For:. OOLDHBEG ~ anl ~ feet r~'~-.~ .i~ ~1~. 'rn~ vm,t~al ~ ar~ .,..'---~ g~cB ~ 24~). Struotur~: Fad 1C Well: 18 FTe~d : Kuparuk RNer Unit Lom=flon: North Slope, AJaska V, Sect Deg/lO0 o. oo o.ool 0.00 0.00I 566.01 $.00I $578.33 0.00 3620.69 0.00 Point MD ~e on 0.00 KOP 2250.00 End of Build 5759.35 ITorget lC-99F pi SO-No 7717.25 iT.D. & End of Hold {~058.34 320 loo ooo 3O0 330 340 WELL PROFILE DATA Inc Oir TVD Nor'[h 0.00 513.71 0.00 0.00 0.00 515.71 2250.00 0.00 45.28 515.71 5607.07 591.15 45.28 51,3.71 6392.00 2534.62 4-5.28 515.71 §652.00 2502.11 TRUE NORTH 350 0 10 2O East 0.00 0,00 -409.11 -24-41.86 -2617,04 3( 6O 29O 7O 280 8O 270 9O 25O 100 25O 110 240 230 1400 220 200 Normal Plane Travelling Cylinder - Feet 190 o )000 ~00 900 2100 150 160 180 170 All depths shown are Measured dep[hs on Reference Well ARCO Alaska, Inc. Pad 1C 18 slot #18 Kuparuk River Unit North Slope, Alaska PROPOSAL LISTING INCLUDING POSITION UNCERTAINTIES Baker Hughes INTEQ Your ref = 18 Version Our ref = prop3262 License = Date printed : 8-Ja~-99 Date created = 30-Dec-98 Last revised = 8-Jan-99 Field is centred on nT0 16 18.576,w150 5 56.536 Structure is centred on nT0 19 45.173,w149 30 19.124 Slot location is nT0 19 30.636,w149 29 49.643 Slot Grid coordinates are N 5968758.528, E 562015.523 Slot local coordinates are 1478.00 S 1010.00 E Projection type~ alaska - Zone 4, Spheroid= Clarke - 1866 Reference North is True North ARCO Alaska, Inc. Pad 1C,18 Kuparuk River Unit,North Slope, Alaska PROPOSAL LISTING Page 1 Your ref ~ 18 Version Last revised = 8-Jan-99 Measured Inclin. Azimuth True Vert R E C T A N G U L A R Dogleg Vert Depth Degrees Degrees Depth C 0 0 R D I N A T E S Deg/100ft Sect 0.00 0.00 313.71 0.00 0.00 N 0.00 E 0.00 0.00 500.00 0.00 313.71 500.00 0.00 N 0.00 E 0.00 0.00 1000.00 0.00 313.71 1000.00 0.00 N 0.00 E 0.00 0.00 1500.00 0.00 313.71 1500.00 0.00 N 0.00 E 0.00 0.00 1802.00 0.00 313.71 1802.00 0.00 N 0.00 E 0.00 0.00 Base Permafrost 2000.00 0.00 313.71 2000.00 0.00 N 0.00 E 0.00 0.00 2250.00 0.00 313.71 2250.00 0.00 N 0.00 E 0.00 0.00 2350.00 3.00 313.71 2349.95 1.81 N 1.89 W 3.00 2.62 2450.00 6.00 313.71 2449.63 7.23 N 7.56 W 3.00 10.46 2550.00 9.00 313.71 2548.77 16.25 N 17.00 W 3.00 23.51 KOP 2650.00 12.00 313.71 2647.08 28.84 N 30.17 W 3.00 41.74 2750.00 15.00 313.71 2744.31 44.97 N 47.04 W 3.00 65.08 2850.00 18.00 313.71 2840.18 64.60 N 67.56 W 3.00 93.48 2950.00 21.00 313.71 2934.43 87.66 N 91.69 W 3.00 126.85 3050.00 24.00 313.71 3026.81 114.10 N 119.35 W 3.00 165.12 3150.00 27.00 313.71 3117.06 143.85 N 150.46 W 3.00 208.16 3250.00 30.00 313.71 3204.93 176.82 N 184.94 W 3.00 255.87 3350.00 33.00 313.71 3290.18 212.93 N 222.71 W 3.00 308.12 3450.00 36.00 313.71 3372.59 252.06 N 263.64 W 3.00 364.75 3550.00 39.00 313.71 3451.91 294.13 N 307.64 W 3.00 425.62 3650.00 42.00 313.71 3527.95 339.00 N 354.57 W 3.00 490.56 3750.00 45.00 313.71 3600.47 386.57 N 404.32 W 3.00 559.38 3759.35 45.28 313.71 3607.07 391.15 N 409.11 W 3.00 566.01 EOC 3973.85 45.28 313.71 3758.00 496.47 N 519.28 W 0.00 718.43 Top West Sak 4000.00 45.28 313.71 3776.40 509.32 N 532.71 W 0.00 737.01 4500.00 45.28 313.71 4128.22 754.83 N 789.51 W 0.00 1092.29 4532.38 45.28 313.71 4151.00 770.73 N 806.13 W 0.00 1115.29 WS10 4816.61 45.28 313.71 4351.00 910.30 N 952.12 W 0.00 1317.26 9 5/8" CSG PT 4870.62 45.28 313.71 4389.00 936.82 N 979.85 W 0.00 1355.63 C90 5000.00 45.28 313.71 4480.04 1000.35 N 1046.30 W 0.00 1447.57 5103.69 45.28 313.71 4553.00 1051.27 N 1099.56 W 0.00 1521.25 C80 (~K-10) 5500.00 45.28 313.71 4831.86 1245.87 N 1303.10 W 0.00 1802.85 6000.00 45.28 313.71 5183.68 1491.39 N 1559.89 W 0.00 2158.13 6193.74 45.28 313.71 5320.00 1586.52 N 1659.40 W 0.00 2295.79 C50 6500.00 45.28 313.71 5535.50 1736.91 N 1816.69 W 0.00 2513.41 6645.68 45.28 313.71 5638.00 1808.44 N 1891.51 W 0.00 2616.92 C40 (-K-5) 7000.00 45.28 313.71 5887.31 1982.43 N 2073.48 W 0.00 2868.68 7081.98 45.28 313.71 5945.00 2022.68 N 2115.59 W 0.00 2926.94 C30 (-K-2) 7252.52 45.28 313.71 6065.00 2106.42 N 2203.18 W 0.00 3048.12 C20 (~RZ m~d-pt) 7352.01 45.28 313.71 6135.00 2155.27 N 2254.27 W 0.00 3118.81 Base 7494.13 45.28 313.71 6235.00 2225.06 N 2327.26 W 0.00 3219.79 K-1 Marker 7500.00 45.28 313.71 6239.13 2227.94 N 2330.28 W 0.00 3223.96 7543.35 45.28 313.71 6269.64 2249.23 N 2352.54 W 0.00 3254.77 7" CSG PT 7643.35 45.28 313.71 6340.00 2298.33 N 2403.90 W 0.00 3325.82 Top D 7681.72 45.28 313.71 6367.00 2317.18 N 2423.61 W 0.00 3353.09 Top C4 ss 7717.25 45.28 313.71 6392.00 2334.62 N 2441.86 W 0.00 3378.33 1C-99F pi 30-Nov-98 7732.89 45.28 313.71 6403.00 2342.30 N 2449.89 W 0.00 3389.44 Top C3 ss 7772.68 45.28 313.71 6431.00 2361.84 N 2470.33 W 0.00 3417.72 Top C2 ss 7883.53 45.28 313.71 6509.00 2416.27 N 2527.26 W 0.00 3496.49 Top C1 ss 7903.43 45.28 313.71 6523.00 2426.04 N 2537.48 W 0.00 3510.62 Top B Shale All data is in feet unless otherwise stated. Coordinates from slot #18 and TVD from RKB (Parker 245) (102.00 Ft above mean sea level). Bottom hole distance is 3620.69 on azimuth 313.71 degrees from wellhead. Total Dogleg for wellpath is 45.28 degrees. Vertical section is from wellhead on azimuth 313.71 degrees. Calculation uses the minimu~ curvature method. Presented by Baker Hughes INTEQ ARCO Alaska, Inc. Pad lC,18 Kuparuk River U~it,North Slope, Alaska Measured Inclin. Azimuth True Vert R E C T A N G U L A R Depth Degrees Degrees Depth C 00 R D I N A T E S PROPOSAL LISTING Page 2 Your ref ~ 18 Version #4a Last revised ~ 8-Jan-99 Dogleg Vert Deg/100ft Sect 8000.00 45.28 313.71 6590.95 2473.46 N 2§87.08 W 0.00 3579.24 8058.34 45.28 313.71 6632.00 2502.11 N 2617.04 W 0.00 3620.69 TD - 4 1/2" Liner All data is in feet unless otherwise stated. Coordinates from slot #18 and TVD from RKB (Parker 245) (102.00 Ft above mean sea level). Bottom hole distance is 3620.69 on azimuth 313.71 degrees from wellhead. Total Dogleg for wellpath is 45.28 degrees. Vertical section is from wellhead on azimuth 313.71 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ ARCO Alaska, Inc. Pad lC,18 Kuparuk River Unit,North Slope, Alaska PROPOSAL LISTING Page 3 Your ref ~ 18 Version Last revised = 8-Jan-99 Comments in wellpath MD TVD Rectangular Coords. Comment 1802.00 1802.00 0.00 N 0.00 E Base Permafrost 2250.00 2250.00 0.00 N 0.00 E KOP 3?59.35 3607.07 391.15 N 409.11 W E0C 3973.85 3758.00 496.47 N 519.28 W Top West Sak 4532.38 4151.00 770.73 N 806.13 W WS10 4816.61 4351.00 910.30 N 952.12 W 9 5/8" CSG PT 4870.62 4389.00 936.82 N 979.85 W C90 5103.69 4553.00 1051.27 N 1099.56 W C80 (~K-10) 6193.74 5320.00 1586.52 N 1659.40 W C50 6645.68 5638.00 1808.44 N 1891.51 W C40 (~K-5) 7081.98 5945.00 2022.68 N 2115.59 W C30 (~K-2) 7252.52 6065.00 2106.42 N 2203.18 W C20 (HRZ mid-pt) 7352.01 6135.00 2155.27 N 2254.27 W Base HRZ 7494.13 6235.00 2225.06 N 2327.26 W K-1 Marker 7543.35 6269.64 2249.23 N 2352.54 W 7" CSG PT 7643.35 6340.00 2298.33 N 2403.90 W Top D 7681.72 6367.00 2317.18 N 2423.61 W Top C4 ss 7717.25 6392.00 2334.62 N 2441.86 W 1C-99F pi 30-Nov-98 7732.89 6403.00 2342.30 N 2449.89 W Top C3 ss 7772.68 6431.00 2361.84 N 2470.33 W Top C2 ss 7883.53 6509.00 2416.27 N 2527.26 W Top C1 ss 7903.43 6523.00 2426.04 N 2537.48 W Top B Shale 8058.34 6632.00 2502.11 N 2617.04 W TD - 4 1/2" Liner Casing positions in string 'A' Top MD Top TVD Rectangular Coords. Bot MD Bot TVD Rectangular Coords. Casing 0.00 0.00 0.00N 0.00E 4816.61 4351.00 910.30N 952.12W 9 5/8" 0.00 0.00 0.00N 0.00E 7543.35 6269.64 2249.23N 2352.54W 7" 0.00 0.00 0.00N 0.00E 8058.34 6632.00 2502.11N 2617.04W 4 1/2" Liner Targets associated with this we11path ===================================== Target name Geographic Location T.V.D. Rectangular Coordinates Revised 1C-99F pi 30-Nov-98 559555.000,5971073.000,2.0000 6392.00 2334.62N 2441.86W 30-Nov-98 ARCO Alaska, Inc. Pad 1C,18 Kupa=uk River Unit,North Slope, Alaska PROPOSAL LISTING Page 1 Your ref = 18 Version #4a Last revised = 8-Ja=1-99 Measured Inclin. Azimuth True Vert R E C T A N G ~ L A R Dogleg Vert Depth Degrees Degrees Depth C 0 0 R D I N A T E S Deg/100ft Sect 0.00 0.00 313.71 0.00 1478.00 S 1010.00 E 0.00 0.00 500.00 0.00 313.71 500.00 1478.00 S 1010.00 E 0.00 0.00 1000.00 0.00 313.71 1000.00 1478.00 S 1010.00 E 0.00 0.00 1500.00 0.00 313.71 1500.00 1478.00 S 1010.00 E 0.00 0.00 1802.00 0.00 313.71 1802.00 1478.00 S 1010.00 E 0.00 0.00 Base Permafrost 2000,00 0.00 313.71 2000.00 1478.00 S 1010.00 E 0.00 0.00 2250.00 0.00 313.71 2250.00 1478.00 S 1010.00 E 0.00 0.00 2350.00 3.00 313.71 2349.95 1476.19 S 1008.11 E 3.00 2.62 2450.00 6.00 313.71 2449.63 1470.77 S 1002.44 E 3.00 10.46 2550.00 9.00 313.71 2548.77 1461.75 S 993.00 E 3.00 23.51 KOP 2650.00 12.00 313.71 2647.08 1449.16 S 979.83 E 3.00 41.74 2750.00 15.00 313.71 2744.31 1433.03 S 962.96 E 3.00 65.08 2850.00 18.00 313.71 2840.18 1413.40 S 942.44 E 3.00 93.48 2950.00 21.00 313.71 2934.43 1390.34 S 918.31 E 3.00 126.85 3050.00 24.00 313.71 3026.81 1363.90 S 890.65 E 3.00 165.12 3150.00 27.00 313.71 3117.06 1334.15 S 859.54 E 3.00 208.16 3250.00 30.00 313.71 3204.93 1301.18 S 825.06 E 3.00 255.87 3350.00 33.00 313.71 3290.18 1265.07 S 787.29 E 3.00 308.12 3450.00 36.00 313.71 3372.59 1225.94 S 746.36 E 3.00 364.75 3550.00 39.00 313.71 3451.91 1183.87 S 702.36 E 3.00 425.62 3650.00 42.00 313.71 3527.95 1139.00 S 655.43 E 3.00 490.56 3750.00 45.00 313.71 3600.47 1091.43 S 605.68 E 3.00 559.38 3759.35 45.28 313.71 3607.07 1086.85 S 600.89 E 3.00 566.01 EOC 3973.85 45.28 313.71 3758.00 981.53 S 490.72 E 0.00 718.43 Top West Sak 4000.00 45.28 313.71 3776.40 968.68 S 477.29 E 0.00 737.01 4500.00 45.28 313.71 4128.22 723.17 S 220.49 E 0.00 1092.29 4532.38 45.28 313.71 4151.00 707.27 S 203.87 E 0.00 1115.29 WS10 4816.61 45.28 313.71 4351.00 567.70 S 57.88 E 0.00 1317.26 9 5/8" CSG PT 4870.62 45.28 313.71 4389.00 541.18 S 30.15 E 0.00 1355.63 C90 5000.00 45.28 313.71 4480.04 477.65 S 36.30 W 0.00 1447.57 5103.69 45.28 313.71 4553.00 426.73 S 89.56 W 0.00 1521.25 C80 (~K-10) 5500.00 45.28 313.71 4831.86 232.13 S 293.10 W 0.00 1802.85 6000.00 45.28 313.71 5183.68 13.39 N 549.89 W 0.00 2158.13 6193.74 45.28 313.71 5320.00 108.52 N 649.40 W 0.00 2295.79 C50 6500.00 45.28 313.71 5535.50 258.91 N 806.69 W 0.00 2513.41 6645.68 45.28 313.71 5638.00 330.44 N 881.51 W 0.00 2616.92 C40 (~K-5) 7000.00 45.28 313.71 5887.31 504.43 N 1063.48 W 0.00 2868.68 7081.98 45.28 313.71 5945.00 544.68 N 1105.59 W 0.00 2926.94 C30 ('K-2) 7252.52 45.28 313.71 6065.00 628.42 N 1193.18 W 0.00 3048.12 C20 (}IRZ =Lid-pt) 7352.01 45.28 313.71 6135.00 677.27 N 1244.27 W 0.00 3118.81 Base HRZ 7494.13 45.28 313.71 6235.00 747.06 N 1317.26 W 0.00 3219.79 K-1 Marker 7500.00 45.28 313.71 6239.13 749.94 N 1320.28 W 0.00 3223.96 7543.35 45.28 313.71 6269.64 771.23 N 1342.54 W 0.00 3254.77 7" CSG PT 7643.35 45.28 313.71 6340.00 820.33 N 1393.90 W 0.00 3325.82 Top D 7681.72 45.28 313.71 6367.00 839.18 N 1413.61 W 0.00 3353.09 Top C4 ss 7717.25 45.28 313.71 6392.00 856.62 N 1431.86 W 0.00 3378.33 1C-99F pi 30-Nov-98 7732.89 45.28 313.71 6403.00 864.30 N 1439.89 W 0.00 3389.44 Top C3 ss 7772.68 45.28 313.71 6431.00 883.84 N 1460.33 W 0.00 3417.72 Top C2 ss 7883.53 45.28 313.71 6509.00 938.27 N 1517.26 W 0.00 3496.49 Top C1 ss 7903.43 45.28 313.71 6523.00 948.04 N 1527.48 W 0.00 3510.62 Top B Shale All data is in feet unless otherwise stated. Coordinates from NW Corner of Sec. 12, T11N, R10E and TVD from RKB (Parker 245) (102.00 Ft above mean sea level). Bottom hole distance is 3620.69 on azimuth 313.71 degrees from wellhead. Total Dogleg for wellpath is 45.28 degrees. Vertical section is from wellhead on azimuth 313.71 degrees. Calculation uses the m/nimum curvature method. Presented by Baker Hughes INTEQ ARCO Alaska, Inc. Pad 1C,18 Kuparuk River ~nit,North Slope, Alaska Measured Inclin. Azimuth True Vert R E C T A N G U L A R Depth Degrees Degrees Depth C 00 R D I N A T E S PROPOSAL LISTING Page 2 Your ref ~ 18 Version #4a Last revised = 8-Jan-99 Dogleg Vert Deg/100ft Sect 8000.00 45.28 313.71 6590.95 995.46 N 1577.08 W 0.00 3579.24 8058.34 45.28 313.71 6632.00 1024.11 N 1607.04 W 0.00 3620.69 TD - 4 1/2" Liner All data is in feet unless otherwise stated. Coordinates from NW Corner of Sec. 12, T11N, RiOE and TVD from RK~ (Parker 245) (102.00 Ft above mean sea level). Bottom hole distance is 3620.69 on azimuth 313.71 degrees from wellhead. Total Dogleg for wellpath is 45.28 degrees. Vertical section is from wellhead on azimuth 313.71 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ ARCO Alaska, Inc. Pad lC,18 Kuparuk River ~nit,North Slope, Alaska PROPOSAL LISTING Page 3 Your ref ~ 18 Version Last revised = 8-Ja~-99 Comments in we11path MD TVD Rectangular Coords. Comment 1802.00 1802.00 1478.00 S 1010.00 E Base Permafrost 2250.00 2250.00 1478.00 S 1010.00 E K0P 3759.35 3607.07 1086.85 S 600.89 E E0C 3973.85 3758.00 981.53 S 490.72 E Top West Sak 4532.38 4151.00 707.27 S 203.87 E WS10 4816.61 4351.00 567.70 S 57.88 E 9 5/8" CSG PT 4870.62 4389.00 541.18 S 30.15 E C90 5103.69 4553.00 426.73 S 89.56 W C80 (~K-10) 6193.74 5320.00 108.52 N 649.%0 W C50 6645.68 5638.00 330.4% N 881.51 W C40 (~K-5) 7081.98 5945.00 5%%.68 N 1105.59 W C30 (~K-2) 7252.52 6065.00 628.%2 N 1193.18 W C20 (~Z mid-pt) 7352.01 6135.00 677.27 N 1244.27 W Base HRZ 7494.13 6235.00 747.06 N 1317.26 W K-1 Marker 7543.35 6269.64 771.23 N 1342.54 W 7" CSG PT 7643.35 6340.00 820.33 N 1393.90 W Top D 7681.72 6367.00 839.18 N 1413.61 W Top C% ss 7717.25 6392.00 856.62 N 1431.86 W 1C-99F pi 30-Nov-98 7732.89 6403.00 864.30 N 1439.89 W Top C3 ss 7772.68 6431.00 883.84 N 1460.33 W Top C2 ss 7883.53 6509.00 938.27 N 1517.26 W Top C1 ss 7903.43 6523.00 948.04 N 1527.48 W Top B Shale 8058.3% 6632.00 1024.11 N 1607.04 W TD - 4 1/2" Liner Casing positions in string Top MD Top TVD Rectangular Coords. Bot MD Bot TVD Rectangular Coords. Casing 0.00 0.00 1478.00S 1010.00E 4816.61 4351.00 567.70S 57.88E 9 5/8" 0.00 0.00 1478.00S 1010.00E 7543.35 6269.6% 771.23N 1342.54W ?" 0.00 0.00 1478.00S 1010.00E 8058.3% 6632.00 1024.11N 1607.04W % 1/2" Liner Targets associated with this wellpath Target name Geographic Location T.V.D. Rectangular Coordinates Revised 1C-99F pi 30-Nov-98 559555.000,5971073.000,2.0000 6392.00 856.62N 1431.86W 30-Nov-98 ARCO Alaska, Inc. Pad 1C,18 Kuparuk River Unit,North Slope, Alaska PROPOSAL LISTING Page 1 YOur ref : 18 Version #4a Last revised : 8-Ja~-99 Measured In¢lin. Azimuth True Vert R E C T A N G U L A R Depth Degrees Degrees Depth C O 0 R D I N A T E S Vert Ellipse Semi Axes Minor Sect Major Minor Vert. Azi. 0.00 0.00 313.71 0.00 0.00 N 0.00 E 0.00 0.00 0.00 0.00 N/A 500.00 0.00 313.71 500.00 0.00 N 0.00 E 0.00 1.31 1.31 0.75 N/A 1000.00 0.00 313.71 1000.00 0.00 N 0.00 E 0.00 2.61 2.61 1.50 N/A 1500.00 0.00 313.71 1500.00 0.00 N 0.00 E 0.00 3.92 3.92 2.25 N/A 1802.00 0.00 313.71 1802.00 0.00 N 0.00 E 0.00 4.70 4.70 2.70 N/A 2000.00 0.00 313.71 2000.00 0.00 N 0.00 E 0.00 5.22 5.22 3.00 N/A 2250.00 0.00 313.71 2250.00 0.00 N 0.00 E 0.00 5.87 5.87 3.38 N/A 2350.00 3.00 313.71 2349.95 1.81 N 1.89 W 2.62 6.14 6.14 3.53 N/A 2450.00 6.00 313.71 2449.63 7.23 N 7.56 W 10.46 6.42 6.40 3.68 313.71 2550.00 9.00 313.71 2548.77 16.25 N 17.00 W 23.51 6.75 6.67 3.83 313.71 2650.00 12.00 313.71 2647.08 28.84 N 30.17 W 41.74 7.17 6.94 3.98 313.71 2750.00 15.00 313.71 2744.31 44.97 N 47.04 W 65.08 7.74 7.22 4.14 313.71 2850.00 18.00 313.71 2840.18 64.60 N 67.56 W 93.48 8.50 7.52 4.31 313.71 2950.00 21.00 313.71 2934.43 87.66 N 91.69 W 126.85 9.51 7.84 4.48 313.71 3050.00 24.00 313.71 3026.81 114.10 N 119.35 W 165.12 10.81 8.17 4.67 313.71 3150.00 27.00 313.71 3117.06 143.85 N 150.46 W 208.16 12.43 8.52 4.88 313.71 3250.00 30.00 313.71 3204.93 176.82 N 184.94 W 255.87 14.40 8.90 5.11 313.71 3350.00 33.00 313.71 3290.18 212.93 N 222.71 W 308.12 16.72 9.29 5.36 313.71 3450.00 36.00 313.71 3372.59 252.06 N 263.64 W 364.75 19.41 9.71 5.66 313.71 3550.00 39.00 313.71 3451.91 294.13 N 307.64 W 425.62 22.46 10.14 5.99 313.71 3650.00 42.00 313.71 3527.95 339.00 N 354.57 W 490.56 25.88 10.59 6.37 313.71 3750.00 45.00 313.71 3600.47 386.57 N 404.32 W 559.38 29.66 11.05 6.79 313.71 3759.35 45.28 313.71 3607.07 391.15 N 409.11 W 566.01 30.02 11.10 6.84 313.71 3973.85 45.28 313.71 3758.00 496.47 N 519.28 W 718.43 38.37 12.12 7.84 313.71 4000.00 45.28 313.71 3776.40 509.32 N 532.71 W 737.01 39.39 12.24 7.96 313.71 4500.00 45.28 313.71 4128.22 754.83 N 789.51 W 1092.29 59.23 14.73 10.49 313.71 4532.38 45.28 313.71 4151.00 770.73 N 806.13 W 1115.29 60.53 14.90 10.67 313.71 4816.61 45.28 313.71 4351.00 910.30 N 952.12 W 1317.26 71.91 16.38 12.18 313.71 4870.62 45.28 313.71 4389.00 936.82 N 979.85 W 1355.63 74.08 16.66 12.47 313.71 5000.00 45.28 313.71 4480.04 1000.35 N 1046.30 W 1447.57 79.26 17.33 13.16 313.71 5103.69 45.28 313.71 4553.00 1051.27 N 1099.56 W 1521.25 83.43 17.88 13.72 313.71 5500.00 45.28 313.71 4831.86 1245.87 N 1303.10 W 1802.85 99.37 19.99 15.88 313.71 6000.00 45.28 313.71 5183.68 1491.39 N 1559.89 W 2158.13 119.52 22.69 18.65 313.71 6193.74 45.28 313.71 5320.00 1586.52 N 1659.40 W 2295.79 127.34 23.74 19.73 313.71 6500.00 45.28 313.71 5535.50 1736.91 N 1816.69 W 2513.41 139.69 25.41 21.43 313.71 6645.68 45.28 313.71 5638.00 1808.44 N 1891.51 W 2616.92 145.57 26.21 22.25 313.71 7000.00 45.28 313.71 5887.31 1982.43 N 2073.48 W 2868.68 159.88 28.16 24.24 313.71 7081.98 45.28 313.71 5945.00 2022.68 N 2115.59 W 2926.94 163.19 28.61 24.70 313.71 7252.52 45.28 313.71 6065.00 2106.42 N 2203.18 W 3048.12 170.08 29.55 25.66 313.71 7352.01 45.28 313.71 6135.00 2155.27 N 2254.27 W 3118.81 174.09 30.10 26.22 313.71 7494.13 45.28 313.71 6235.00 2225.06 N 2327.26 W 3219.79 179.83 30.88 27.02 313.71 7500.00 45.28 313.71 6239.13 2227.94 N 2330.28 W 3223.96 180.07 30.92 27.05 313.71 7543.35 45.28 313.71 6269.64 2249.23 N 2352.54 W 3254.77 181.82 31.16 27.29 313.71 7643.35 45.28 313.71 6340.00 2298.33 N 2403.90 W 3325.82 185.86 31.71 27.86 313.71 7681.72 45.28 313.71 6367.00 2317.18 N 2423.61 W 3353.09 187.41 31.92 28.07 313.71 7717.25 45.28 313.71 6392.00 2334.62 N 2441.86 W 3378.33 188.85 32.12 28.27 313.71 7732.89 45.28 313.71 6403.00 2342.30 N 2449.89 W 3389.44 189.48 32.20 28.36 313.71 7772.68 45.28 313.71 6431.00 2361.84 N 2470.33 W 3417.72 191.09 32.43 28.59 313.71 7883.53 45.28 313.71 6509.00 2416.27 N 2527.26 W 3496.49 195.56 33.04 29.21 313.71 7903.43 45.28 313.71 6523.00 2426.04 N 2537.48 W 3510.62 196.37 33.15 29.32 313.71 All data is in feet unless otherwise stated. Coordinates from slot #18 and TVD from RKB (Parker 245) (102.00 Ft above mean sea level). Bottom hole distance is 3620.69 on azimuth 313.71 degrees from wellhead. Vertical section is from wellhead on azimuth 313.71 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ ARCO Alaska, Inc. Pad lC,18 Kuparuk River Unit,North Slope, Alaska PROPOSAL LISTING Page 2 Your ref = 18 Version Last revised = 8-Jan-99 Measured Inclin. Azimuth True Vert R E C T A N G ~ L A R Depth Degrees Degrees Depth C O 0 R D I N A T E S Vert Ellipse Semi Axes Minor Sect Major Minor Vert. Azi. 8000.00 45.28 313.71 6590.95 2473.46 N 8058.34 45.28 313.71 6632.00 2502.11 N 2587.08 W 3579.24 200.27 33.69 29.87 313.71 2617.04 W 3620.69 202.63 34.01 30.20 313.71 POSITION UNCERTAINTY SUMMARY Depth Position Uncertainty From To Suz-vey Tool Error Model Major Minor Vert. 0 8058 ARCO (H.A. Mag) User specified 202.63 34.01 30.20 1. Ellipse dimensions are half axis. 2. Casing dimensions are not included. 3. Ellipses are calculated on 2.58 standard deviations. 4. Uncertainty calculations start at drill depth zero. 5. Surface position uncertainty is not included. 6. Where two surveys are tied together the errors of one are considered to have a systematic relationship to the corresponding errors of the other. 7. Detailed description of the INTEQ error models can be found in the Ec*Trak manual. All data is in feet unless otherwise stated. Coordinates from slot #18 and TVD from RKB (Parker 245) (102.00 Ft above mean sea level). Bottom hole distance is 3620.69 on azimuth 313.71 degrees from wellhead. Vertical section is from wellhead on azimuth 313.71 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ ARCO Alaska, Inc. Pad 1C,18 Kuparuk River Unit,North Slope, Alaska PROPOSAL LISTING Page 3 Your ref = 18 Version Last revised : 8-Jan-99 Comments in wellpath MD TVD Rectangular Coords. Comment 1802 00 2250 00 3759 35 3973 85 4532 38 4816 61 4870.62 5103.69 6193.74 6645.68 7081.98 7252.52 7352.01 7494.13 7543.35 7643.35 7681.72 7717.25 7732.89 7772.68 7883.53 7903.43 8058.34 1802.00 2250.00 3607.07 3758.00 4151.00 4351.00 4389.00 4553.00 5320.00 5638.00 S945.00 6065.00 6135.00 6235.00 6269.64 6340.00 6367.00 6392.00 6403.00 6431.00 6§09.00 6523.00 6632.00 0.00 0.00 391.15 496.47 770.73 910.30 936.82 1051.27 1586.52 1808 44 2022 68 2106 42 2155 27 2225 06 2249 23 2298 33 2317.18 2334.62 2342.30 2361.84 2416.27 2426.04 2502.11 N 0.00 E Base Permafrost N 0.00 E KOP N 409.11 W EOC N 519.28 W Top West Sak N 806.13 W WS10 N 952.12 W 9 5/8" CS~ PT N 979.85 W C90 N 1099.56 W C80 (~K-10) N 1659.40 W C50 N 1891.51 W C40 (~K-5) N 2115.59 W C30 (-K-2) N 2203.18 W C20 (~IRZ mid-pt) N 2254.2? W Base HRZ N 2327.26 W K-1 Marker N 2352.54 W 7" CSG PT N 2403.90 W Top D N 2423.61 W Top C4 ss N 2441.86 W 1C-99F pi 30-Nov-98 N 2449.89 W Top C3 ss N 2470.33 W Top C2 ss N 2527.26 W Top C1 ss N 2537.48 W Top B Shale N 2617.04 W TD - 4 1/2" Liner Casing positions in string 'A' Top MD Top TVD Rectangular Coords. Bot MD Bot TVD Rectangular Coords. Casing 0.00 0.00 0.00N 0.00E 4816.61 4351.00 910.30N 952.12W 9 5/8" 0.00 0.00 0.00N 0.00E 7543.35 6269.64 2249.23N 2352.54W 7" 0.00 0.00 0.00N 0.00E 8058.34 6632.00 2502.11N 2617.04W 4 1/2" Liner Targets associated with this wellpath Target na~ne Geographic Location T.V.D. Rectangular Coordinates Revised 1C-99F pi 30-Nov-98 559555.000,5971073.000,2.0000 6392.00 2334.62N 2441.86W 30-Nov-98 ARCO Alaska, Inc. Pad lC,18 KuparuJc River Unit,North Slope, Alaska PROPOSAL LISTING Page 1 Your ref : 18 Version Last revised ~ 8-Jan-99 Measured Inclin Azimuth True Vert R E C T A N G U L A R Dogleg Vert G R I D C O O R D S Depth Degrees Degrees Depth C O O R D I N A T E S Deg/100ft Sect Easting Northing 0.00 0.00 313.71 0.00 0.00N 500.00 0.00 313.71 500.00 0.00N 1000.00 0.00 313.71 1000.00 0.00N 1500.00 0.00 313.71 1500.00 0.00N 1802.00 0.00 313.71 1802.00 0.00N 0.00E 0.00 0.00 562015.52 5968758.53 0.00E 0.00 0.00 562015.52 5968758.53 0.00E 0.00 0.00 562015.52 5968758.53 0.00E 0.00 0.00 562015.52 5968758.53 0.00E 0.00 0.00 562015.52 5968758.53 2000.00 0.00 313.71 2000.00 2250.00 0.00 313.71 2250.00 2350.00 3.00 313.71 2349.95 2450.00 6.00 313.71 2%49.63 2550.00 9.00 313.71 25%8.77 0.00N 0.00N 1.81N 7.23N 16.25N 0.00E 0.00 0.00 562015.52 5968758.53 0.00E 0.00 0.00 562015.52 5968758.53 1.89W 3.00 2.62 562013.62 5968760.32 7.56W 3.00 10.46 562007.90 5968765.70 17.00W 3.00 23.51 561998.%0 596877%.64 2650.00 12.00 313.71 26%7.08 2750.00 15.00 313.71 2744.31 2850.00 18.00 313.71 2840.18 2950.00 21.00 313.71 2934.%3 3050.00 24.00 313.71 3026.81 28.84N 64.60N 87.66N 114.10N 30.17W 3.00 41.74 561985.13 5968787.12 47.04W 3.00 65.08 561968.13 5968803.11 67.56W 3.00 93.48 561947.44 5968822.57 91.69W 3.00 126.85 561923.13 5968845.%3 119.35W 3.00 165.12 561895.27 5968871.65 3150.00 27.00 313.71 3117.06 3250.00 30.00 313.71 3204.93 3350.00 33.00 313.71 3290.18 3450.00 36.00 313.71 3372.59 3550.00 39.00 313.71 3451.91 143.85N 176.82N 212.93N 252.06N 294.13N 150.46W 3.00 208.16 561863.91 5968901.14 184.94W 3.00 255.87 561829.16 5968933.82 222.71W 3.00 308.12 561791.11 5968969.62 263.64W 3.00 364.75 561749.87 5969008.42 307.64W 3.00 %25.62 561705.53 5969050.12 3650.00 42.00 313.71 3527.95 3750.00 %5.00 313.71 3600.47 3759.35 %5.28 313.71 3607.07 3973.85 %5.28 313.71 3758.00 4000.00 45.28 313.71 3776.40 339.00N 386.57N 391.15N 496.47N 509.32N 354.57W 3.00 490.56 561658.24 596909%.60 %04.32W 3.00 559.38 561608.11 5969141.76 %09.11W 3.00 566.01 561603.28 59691%6.30 519.28W 0.00 718.43 561492.28 5969250.72 532.71W 0.00 737.01 561478.74 5969263.%5 %500.00 45.28 313.71 4128.22 754.83N 789.51W 0.00 1092.29 561219.98 5969506.85 %532.38 45.28 313.71 4151.00 770.73N 806.13W 0.00 1115.29 561203.23 5969522.61 4816.61 45.28 313.71 4351.00 910.30N 952.12W 0.00 1317.26 561056.13 5969660.97 %870.62 45.28 313.71 %389.00 936.82N 979.85W 0.00 1355.63 561028.18 5969687.26 5000.00 45.28 313.71 %480.04 1000.35N 1046.30W 0.00 1447.57 560961.22 5969750.25 5103.69 45.28 313.71 4553.00 1051.27N 1099.56W 0.00 1521.25 560907.56 5969800.72 5500.00 45.28 313.71 4831.86 1245.87N 1303.10W 0.00 1802.85 560702.47 5969993.6% 6000.00 45.28 313.71 5183.68 1491.39N 1559.89W 0.00 2158.13 560443.71 5970237.0% 6193.74 45.28 313.71 5320.00 1586.52N 1659.40W 0.00 2295.79 560343.4% 5970331.36 6500.00 45.28 313.71 5535.50 1736.91N 1816.69W 0.00 2513.41 560184.95 5970480.%% 6645.68 45.28 313.71 5638.00 1808.44N 1891.51W 0.00 2616.92 560109.56 5970551.36 7000.00 45.28 313.71 5887.31 1982.43N 2073.48W 0.00 2868.68 559926.19 5970723.8% 7081.98 45.28 313.71 5945.00 2022.68N 2115.59W 0.00 2926.94 559883.76 5970763.75 7252.52 45.28 313.71 6065.00 2106.42N 2203.18W 0.00 3048.12 559795.50 5970846.77 7352.01 45.28 313.71 6135.00 2155.27N 2254.27W 0.00 3118.81 55974%.02 5970895.2.0 7494.13 45.28 313.71 6235.00 2225.06N 2327.26W 0.00 3219.79 559670.%7 5970964%38 / 7500.00 45.28 313.71 6239.13 2227.94N 2330.28W 0.00 3223.96 559667.%3 5970967.24 7543.35 45.28 313.71 6269.64 2249.23N 2352.54W 0.00 3254.77 559645.00 5970988.3% 7643.35 45.28 313.71 6340.00 2298.33N 2403.90W 0.00 3325.82 559593.25 5971037.02 7681.72 45.28 313.71 6367.00 2317.18N 2423.61W 0.00 3353.09 559573.39 5971055.70 7717.25 45.28 313.71 6392.00 2334.62N 2441.86W 0.00 3378.33 559555.00 5971073.00 7732.89 45.28 313.71 6403.00 2342.30N 2449.89W 0.00 3389.44 559546.91 5971080.61 7772.68 45.28 313.71 6431.00 2361.84N 2470.33W 0.00 3417.72 559526.32 5971099.98 7883.53 45.28 313.71 6509.00 2416.27N 2527.26W 0.00 3496.49 559468.95 5971153.9% 7903.43 45.28 313.71 6523.00 2426.04N 2537.48W 0.00 3510.62 559458.65 5971163.63 All data in feet unless otherwise stated. Calculation uses minimum curvature method. Coordinates from slot #18 and TVD from RKB (Parker 245) (102.00 Ft above mean sea level). Bottom hole distance is 3620.69 on azimuth 313.71 degrees from wellhead. Total Dogleg for wellpath is %5.28 degrees. Vertical section is from wellhead on azimuth 313.71 degrees. Grid is alaska - Zone 4. Grid coordinates in FEET and computed using the Clarke - 1866 spheroid Presented by Baker Hughes INTEQ ARCO Alaska, Inc. Pad 1C,18 Kuparuk River Unit,North Slope, Alaska Measured Inclin Azimuth True Vert R E C T A N G U L A R Depth Degrees Degrees Depth C 0 0 R D I N A T E S PROPOSAL LISTING Page 2 Your ref ~ 18 Version Last revised = 8-Jan-99 Dogleg Vert G R I D C 0 0 R D S Deg/100ft Sect Easting Northing 8000.00 45.28 313.71 6590.95 2473.%6N 2587.08W 0.00 3579.24 559408.67 5971210.64 8058.34 45.28 313.71 6632.00 2502.11N 2617.04W 0.00 3620.69 559378.48 5971239.04 All data in feet unless otherwise stated. Calculation uses minimum curvature method. Coordinates from slot #18 and TVD from RF~B (Parker 245) (102.00 Ft above mean sea level). Bottom hole distance is 3620.69 on azimuth 313.71 degrees from wellhead. Total Dogleg for wellpath is 45.28 degrees. Vertical section is from wellhead on azimuth 313.71 degrees. Grid is alaska - Zone 4. Grid coordinates in FEET and computed using the Clarke - 1866 spheroid Presented by Baker Hughes INTEQ ARCO Alaska, Inc. Pad lC,18 Kuparuk River Unit,North Slope, Alaska PROPOSAL LISTING Page 3 Your ref ~ 18 Version Last revised = 8-Jan-99 Comments in wellpath MD TVD Rectangular Coords. Comment 1802.00 2250.00 3759.35 3973.85 4532.38 4816.61 4870.62 5103.69 6193.74 6645.68 7081.98 7252.52 7352.01 7494.13 7543 35 7643 35 7681 72 7717 25 7732 89 7772 68 7883 53 7903.43 8058.34 1802.00 0.00N 0.00E Base Permafrost 2250.00 0.00N 0.00E KOP 3607.07 391.15N 409.11W EOC 3758.00 496.47N 519.28W Top West Sak 4151.00 770.73N 806.13W WS10 4351.00 910.30N 952.12W 9 5/8" CS~ PT 4389.00 936.82N 979.85W C90 4553.00 1051.27N 1099.56W C80 (~K-10) 5320.00 1586.52N 1659.40W C50 5638.00 1808.44N 1891.51W C40 (~K-5) 5945.00 2022.68N 2115.59W C30 (~K-2) 6065.00 2106.42N 2203.18W C20 (HRZ mid-pt) 6135.00 2155.27N 2254.27W Base HRZ 6235.00 2225.06N 2327.26W K-1 Marker 6269.64 2249.23N 2352.54W 7" CSG PT 6340.00 2298.33N 2403.90W Top D 6367.00 2317.18N 2423.61W Top C4 ss 6392.00 2334.62N 2441.86W 1C-99F pi 30-Nov-98 6403.00 2342.30N 2449.89W Top C3 ss 6431.00 2361.84N 2470.33W Top C2 ss 6509.00 2416.27N 2527.26W Top C1 ss 6523.00 2426.04N 2537.48W Top B Shale 6632.00 2502.11N 2617.04W TD - 4 1/2" Liner Casing positions in string Top MD Top TVD Rectangular Coords. Bot MD Bot TVD Rectangular Coords. Casing 0.00 0.00 0.00N 0.00E 4816.61 4351.00 910.30N 952.12W 9 5/8" 0.00 0.00 0.00N 0.00E 7543.35 6269.64 22~9.23N 2352.54W 7" 0.00 0.00 0.00N 0.00E 8058.34 6632.00 2502.11N 2617.04W 4 1/2" Liner Targets associated with this wellpath Target name Geographic Location T.V.D. Rectangular Coordinates Revised 1C-99F pi 30-Nov-98 559555.000,5971073.000,2.0000 6392.00 2334.62N 2441.86W 30-Nov-98 ARCO Alaska, Inc. Pad 1C 18 slot #18 Kuparuk River Unit North Slope, Alaska SUMMARY CLEARANCE by Baker Hughes INTEQ REPORT Your ref : 18 Version #4a Our ref : prop3262 License : Date printed : 12-Jan-99 Date created : 30-Dec-98 Last revised : 8-Jan-99 Field is centred on n?0 16 18.576,w150 5 56.536 Structure is centred on nT0 19 &5.173,wi49 30 19.124 Slot location is n?0 19 30.636,w149 29 49.643 Slot Grid coordinates are N 5968758.528, E 562015.523 Slot local coordinates are 1478.00 S 1010.00 E Projection type: alaska - Zone 4, Spheroid: Clarke - 1866 Reference North is True North Object wellpath MMS <6948-7570'>,,WS#24,Pad lC PMSS <0-11300'>,,11,Pad 1C Unknown Data,,WS1,Pad lC PMSS <O-10980'>,,14,Pad 1C PMSS <0-8677'>,,13,Pad 1C GMS <0-7780'>,,1,Pad 1C GMS <0-7615'>,,2,Pad 1C GMS <O-9700'>,,3,Pad 1C GMS <O-7753'>,,5,Pad 1C GMS <0-10243'>,,6,Pad lC GMS <0-9784'>,,?,Pad 1C GMS <O-9600'>,,8,Pad 1C PGMS <0-9002'>,,10GI,Pad 1C MSS <0-7000'>,,9GI,Pad 1C PMSS <0 - 10969'),,17,Pad 1C PMSS <0-9390'>,,15,Pad 1C PMSS <O-17089'>,,12,Pad 1C PMSS <0 - 11918'>,,16,Pad lC GMS <0-7575'>,,4,Pad 1C Closest approach with 3-D Minimum Distance method Last revised Distance M.D. Diverging from M.D. 17-Dec-97 10390.5 3161.1 3350.0 19-Mar-97 449.5 320.0 320.0 2-Nov-98 3775.5 8058.3 8058.3 18-Mar-98 156.2 120.0 120.0 1-Dec-98 148.2 360.0 360.0 18-Dec-98 427.7 1300.0 1300.0 18-Dec-98 306.8 1400.0 1400.0 18-Dec-98 186.1 800.0 920.0 18-Dec-98 51.1 700.0 1140.0 18-Dec-98 172.8 500.0 500.0 18-Dec-98 292.3 400.0 400.0 18-Dec-98 413.3 20.0 1420.0 18-Dec-98 336.1 20.0 620.0 2-Jan-98 224.3 3483.3 3483.3 2-Dec-98 454.6 120.0 120.0 17-Dec-98 277.1 120.0 120.0 7-Jan-98 313.9 1820.0 1820.0 8-Jan-99 116.4 660.0 660.0 18-Dec-98 45.4 1360.0 1360.0 AAI PAYABLES CHECK NUMBER P.O. BOx 102776 Anchorage, AK 99510-2776 PAY TO THE ORDER OF: ALASKA DEPT OF REVENUE ALASKA OIL & GAS CONSERVATION COMMI 3001 PORCUPINE DRIVE 2O5O87381 DECEMBER 22, 1998 VOID AFTER 90 DAYS 73-426 839 0997579 EXACTLY *********** 100 DOLLARS AND O0 CENTS $**********.100.00 The First National Bank of Chicago-0710 Chicago, Illinois Payable Through Republic Bank Shelbyville, Kentucky TRACE NUMBER: 205087381 ,' 20 50,o, ? ~,P' ;i,,' ,:DP, ~,ciOh ;~r-, 2': WELL PERMIT CHECKLIST COMPANY/~/,/'-~- FIELD & POOL ? ¢¢:~.//25c:::~ INIT CLASS ADMINISTRATION 1. Permit fee attached ....................... 2. Lease number appropriate ................... 3. Unique well name and number .................. 4. Well located in a defined pool .................. 5. Well located proper distance from drilling unit boundary .... 6. Well located proper distance from other wells .......... 7. Sufficient acreage available in drilling unit ............ 8. If deviated, is we,bore plat included ............... 9. Operator only affected party ................... 10. Operator has appropriate bond in force ............. 11. Permit can be issued without conservation order ........ 12. Permit can be issued without administrative approval ...... 13. Can permit be approved before 15-day wait ........... ;~,~ DATE 14. Conductor string provided ................... 15. Surface casing protects all known USDWs ........... 16. CMT vol adequate to circulate on conductor & surf csg ..... 17. CMT vol adequate to tie-in long string to surf csg ........ 18. CMT will cover all known productive horizons .......... 19. Casing designs adequate for C, T, B & permafrost ....... 20. Adequate tankage or reserve pit ................. 21. If a re-drill, has a 10-403 for abandonment been approved... 22. Adequate wellbore separation proposed ............. 23. If diverter required, does it meet regulations .......... 24. Drilling fluid program schematic & equip list adequate ..... 25. BOPEs, do they meet regulation ................ 26. BOPE press rating appropriate; test to ,~'~ .psig. 27. Choke manifold complies w/APl RP-53 (May 84) ........ 28. Work will occur without operation shutdown ........... PROGRAM: exp ~ --OL AREA. ~-~--./.--~ N ~ serv wellbore seg ann. disposal para req ~ UNIT# ,,/,///~,~,~ ON/OFF SHORE <2~/,_..~ dev ~ redrll (~N (~)N ~)N 29. Is presence of H2s gas probable ................. Y ~ Permit can be issued w/o hydro[Ion sulfide measures ..... ¥ N Data presented on potential overpressure zones ....... ~ ~ 2~ Seismic analysis of shallow gas zones ............. Y N . , Seabed condition survey (if off-shore) ............. Contact name/phone for weekly progress reports [explora~,~only] Y N GEOLOGY ,DAT~ 30. 31. 32. 33. 34. ANNULAR DISPOSAL 35. APPR DATE With proper cementing records, this plan (A) will contain waste in a suitable receiving zone; ....... (B) will not contaminate freshwater; or cause drilling waste... to surface; (C) will not impair mechanical integrity of the well used for disposal; (D) will not damage producing formation or impair recovery from a pool; and (E) will not circumvent 20 AAC 25.252 or 20 AAC 25.412. GEOLOGY: )N ENGINEERING: UIC/Annular COMMISSION: ~"! DW~L_-'~ BEW ~ '//~5"~ WM ~ Ill ~ RNC JDH ~ co 'h~t~ Comments/Instructions: c:\msoffice\wordian\diana\checklist 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. Sperry-Sun Drilling Services LIS Scan Utility Wed Jul 07 14:53:09 1999 Reel Header Service name ............. LISTPE Date ..................... 99/07/07 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Previous Reel Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Technical Services Tape Header Service name ............. LISTPE Date ..................... 99/07/07 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Previous Tape Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Technical Services Physical EOF Comment Record TAPE HEADER KUPARUK RIVER UNIT MWD/MAD LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 1 AK-MM-90076 P. SMITH D. BREEDEN RECEIVED JUL 0 8 1999 1c- 18 Alaska Oil & Gas Cons. 500~.9~.~.93900 An~or~ge ARCO ~AS~, INC. SPERRY-S~ DRILLING SERVICES 07-~L-99 MWD RUN 2 AK-MM-90076 K. FERGUSON D. BREEDEN MWD RUN 3 AK-MM-90076 S. BURKF~ARDT D. BREEDEN JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: MWD RUN 4 AK-MM-90076 T. MCGUIRE G. WHITLOCK 12 liN 10E 1478 FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD 1010 101.50 101.50 60.50 OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 1ST STRING 16.000 121.0 2ND STRING 12.250 9.625 4815.0 3RD STRING 8.500 7.000 7576.0 PRODUCTION STRING 6.125 8095.0 REMARKS: 1. ALL DEPTHS ARE MEASURED DEPTHS (MD) UNLESS OTHERWISE NOTED. 2. MWD RUNS 1 AND 2 ARE DIRECTIONAL WITH DUAL GAMMA P~AY (DGR) . 3. MWD RUNS 3 AND 4 ARE DIRECTIONAL WITH DUAL GAMMA P~AY (DGR), ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4), COMPENSATED THERMAL NEUTRON POROSITY (CTN) AND STABILIZED LITHO DENSITY (SLD) . 4. DEPTH SHIFTING/CORRECTION OF MWD DATA IS WAIVED AS PER THE E-MAIL MESSAGE FROM DEDE SCHWARTZ OF ARCO ALASKA, INC. ON 20 MAY, 1999. SPERRY-SUN MWD DATA IS PRIMARY DEPTH CONTROL (PDC) FOR WELL 1C-18. 5. THIS WELL REACHED A TOTAL DEPTH (TD) OF 8095'MD, 6676'TVI). 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. TNPS = SMOOTHED COMPENSATED THERMAL NEUTRON POROSITY (SANDSTONE MATRIX-FIXED HOLE SIZE). CTNA = SMOOTHED AVERAGE OF NEAR DETECTORS' COUNT RATES. CTFA = SMOOTHED AVERAGE OF FAR DETECTORS' COUNT RATES. SBD2 = SMOOTHED BULK DENSITY - COMPENSATED. SCO2 = SMOOTHED STANDOFF CORRECTION. SNP2 = SMOOTHED NEAR DETECTOR ONLY PHOTOELECTRIC ABSORPTION FACTOR. ENVIRONMENTAL PARAMETERS USED IN PROCESSING NUCLEAR/NEUTRON LOG DATA: HOLE SIZE = 6.125" MUD FILTRATE SALINITY = 300 PPM. MUD WEIGHT = 10.8 PPG. FORMATION WATER SALINITY = FLUID DENSITY = MATRIX DENSITY = LITHOLOGY = $ File Header Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/07/07 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.000 14545 PPM. 1. oo G/CC 2.65 G/CC SANDSTONE Comment Record FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. .5000 DEPTH INCREMENT: FILE SUMMARY PBU TOOL CODE PEF GR ROP FCNT NCNT NPHI FET RPD RPM RPS RPX DRHO RHOB $ START DEPTH 78.5 122.0 7575 0 7575 0 7575 0 7575 0 7575 0 7575 0 7575 0 7575 0 7579 0 7579 0 BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) BASELINE DEPTH $ MERGED DATA SOURCE PBU TOOL CODE MWD MWD MWD MWD $ REMARKS: BIT RUN NO MERGE TOP MERGE BASE 1 122.0 4826.0 2 4826.0 7585.0 3 7585.0 7660.0 4 7660.0 8095.0 STOP DEPTH 8060 5 8O95 0 8010 5 8010 5 8010 5 8057 0 8067 5 8067 5 8067 5 8067 5 8026 0 8026 0 EQUIVALENT UNSHIFTED DEPTH MERGED MAIN PASS. $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam DEPT FT 4 1 ROP MWD FT/H 4 1 GR MWD API 4 1 NPHI MWD P.U. 4 1 FCNT MWD CNTS 4 1 NCNT MWD CNTS 4 1 RHOB MWD G/CC 4 1 DRHO MWD G/CC 4 1 PEF MWD BAR/~ 4 1 RPS MWD OHMM 4 1 RPD MWD OHMM 4 1 FET MWD HOUR 4 1 RPX MWD OHMM 4 1 RPM MWD OHMM 4 1 Rep Code Offset Channel 68 0 1 68 4 2 68 8 3 68 12 4 68 16 5 68 20 6 68 24 7 68 28 8 68 32 9 68 36 10 68 40 11 68 44 12 68 48 13 68 52 14 Name DEPT ROP GR NPHI FCNT NCNT RHOB DRHO PEF RPS RPD FET RPX RPM Min 78.5 0 10.24 18.03 112.71 13663 O.88 -1 38 2 58 1 38 1 48 0 47 1 41 1 45 First Max Mean Nsam Reading 8095 4086.75 16034 78.5 3935.74 201.73 15947 122 520.97 96.8982 15965 78.5 72.22 32.4633 872 7575 818.1 406.216 872 7575 34408 24091.4 872 7575 3.15 2.40693 895 7579 0.48 0.0761117 895 7579 11.02 4.34435 895 7579 1613.22 9.51862 986 7575 1706.65 13.5218 986 7575 70.39 3.46645 965 7575 1442.47 7.98099 986 7575 2000 14.5984 986 7575 Last Reading 8095 8095 8060.5 8010.5 8010.5 8010.5 8026 8026 8026 8067.5 8067.5 8057 8067.5 8067.5 First Reading For Entire File .......... 78.5 Last Reading For Entire File ........... 8095 File Trailer Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/07/07 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 ....... 99/07/07 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.001 Comment Record FILE HEADER FILE NUMBER: 2 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 1 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 78.5 ROP 122.0 $ 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 $ 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: STOP DEPTH 4787.5 4826.0 07-FEB-99 ISC 5.06/INSITE 3.2 HCIM 630.91/SP4 5.16/TM 4.15 MEMORY 4826.0 122.0 4826.0 .1 46.1 TOOL NUMBER P1234CG8 12.250 12.3 SPUD, LSND 10.00 120.0 8.5 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 ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 60O 6.6 .000 .000 .000 .000 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD 1 FT/H 4 1 68 4 2 GR MWD 1 API 4 1 68 8 3 32.5 First Name Min Max Mean Nsam Reading DEPT 78.5 4826 2452.25 9496 78.5 ROP 0.61 1946.89 211.916 9409 122 GR 10.24 130.42 71.668 9419 78.5 Last Reading 4826 4826 4787.5 First Reading For Entire File .......... 78.5 Last Reading For Entire File ........... 4826 File Trailer Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/07/07 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 ....... 99/07/07 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: 2 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 4788.0 7543.0 ROP 4826.5 7585.0 $ LOG HEADER DATA DATE LOGGED: 13-FEB-99 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: 41.9 MAXIMUM ANGLE: 47.8 ISC 5.06/INSITE 3.2 HCIM 630.91/SP4 5.16/TM 4.15 MEMORY 7585.0 4826.0 7585.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY $ TOOL NUMBER P1247HWGV6 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : 8.500 8.5 BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM) : LSND 9.20 67.0 9.2 300 FLUID LOSS (C3) : RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPEP~ATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL ST~NDOFF (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 ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 2.8 .000 .000 .000 .000 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD 2 FT/H 4 1 68 4 2 GR MWD 2 API 4 1 68 8 3 44.5 First Name Min Max Mean Nsam Reading DEPT 4788 7585 6186.5 5595 4788 ROP 0 3935.74 211.723 5518 4826.5 GR 52.12 520.97 140.794 5511 4788 Last Reading 7585 7585 7543 First Reading For Entire File .......... 4788 Last Reading For Entire File ........... 7585 File Trailer Service name ............. STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/07/07 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.004 Physical EOF File Header Service name ............. STSLIB.004 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/07/07 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.003 Comment Record FILE HEAiDER FILE N-UMBER: 4 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NTJMBER: 3 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 7543.5 FCNT 7575 0 NCNT 7575 0 NPHI 7575 0 FET 7575 0 RPD 7575 0 RPM 7575 0 RPS 7575 0 RPX 7575 0 PEF 7579 0 DRHO 7579 0 RHOB 7579 0 ROP 7585 5 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWN-HOLE 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 A/~GLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 CTN COMP THERMAL NEUTRON STOP DEPTH 7626 0 7576 0 7576 0 7576 0 7633 0 7633 0 7633 0 7633 0 7633 0 7589 5 7589 5 7589 5 7660 0 15-FEB-99 ISC 5.06/INSITE 3.2 HCIM 630.91/SP4 5.16/TM 4.15 MEMORY 7660.0 7585.0 7660.0 45.5 45.5 TOOL NUMBER P1241GR4 P1241GR4 P1241GR4 SLD STABILIZED LITHO DEN BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3) : RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ) : REMARKS: $ 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 ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 P1241GR4 6.130 6.1 LSND 10.80 58.0 9.6 300 4.0 1.100 .580 2.5O0 .900 .0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD 3 FT/H 4 1 68 4 2 GR MWD 3 API 4 1 68 8 3 RPX MWD 3 API 4 1 68 12 4 RPS MWD 3 API 4 1 68 16 5 RPM MWD 3 API 4 1 68 20 6 RPD MWD 3 API 4 1 68 24 7 FET MWD 3 HOUR 4 1 68 28 8 NPHI MWD 3 P.U. 4 1 68 32 9 NCNT MWD 3 CNTS 4 1 68 36 10 FCNT MWD 3 CNTS 4 1 68 40 11 PEF MWD 3 BB_P_N 4 1 68 44 12 RHOB MWD 3 G/CC 4 1 68 48 13 57.4 DRHO MWD 3 s/cc 4 i 68 52 14 Name DEPT ROP GR RPX RPS RPM RPD FET NPHI NCNT FCNT PEF RHOB DRHO Min 7543.5 0 O2 52 45 1 41 1 38 1 45 1 48 1 86 56 31 16258.4 120.976 6.81 2.16 0.08 Max Mean Nsam 7660 7601.75 234 2081.99 74.4238 150 148.89 102.551 166 1442.47 19.9831 117 1613.22 31.212 117 2000 76.1952 117 1706.65 65.9338 117 70.39 14.9779 117 58.67 57.49 3 16578.8 16418.6 3 121.708 121.342 3 11.02 8.43273 22 3.12 2.28227 22 0.48 0.165455 22 First Reading 7543.5 7585.5 7543.5 7575 7575 7575 7575 7575 7575 7575 7575 7579 7579 7579 Last Reading 7660 7660 7626 7633 7633 7633 7633 7633 7576 7576 7576 7589.5 7589.5 7589.5 First Reading For Entire File .......... 7543.5 Last Reading For Entire File ........... 7660 File Trailer Service name ............. STSLIB.004 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/07/07 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.005 Physical EOF File Header Service name ............. STSLIB.005 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/07/07 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.004 Comment Record FILE HEADER FILE NUMBER: 5 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 4 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH FCNT NCNT NPHI PEF DRHO RHOB GR FET RPD RPM RPS RPX ROP $ LOG HEADER DATA DATE LOGGED: SOFTWARE 7576 5 7576 5 7576 5 7590 0 7590 0 7590 0 7626 5 7633 5 7633 5 7633 5 7633 5 7633 5 7660 5 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: 8010.5 8010.5 8010 5 8026 0 8026 0 8026 0 8060 5 8057 0 8067 5 8067 5 8067 5 8067 5 8095 0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 CTN COMP THERMAL NEUTRON SLD STABILIZED LITHO DEN $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3) : RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL 17-FEB-99 ISC 5.06/INSITE 3.2 HCIM 630.91/SP4 5.16/TM 4.15 MEMORY 8095.0 7660.0 8095.0 42.5 45.8 TOOL NUMBER P1241GR4 P1241GR4 P1241GR4 P1241GR4 6.130 6.1 LSND 10.80 80.0 9.5 300 3.0 .9OO .503 1.200 1.100 52.5 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 ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 .0 Name Service Order Units Size Nsam DEPT FT 4 1 ROP MWD 4 FT/H 4 1 GR MWD 4 API 4 1 RPX MWD 4 OHMM 4 1 RPS MWD 4 OHMM 4 1 RPM MWD 4 OHMM 4 1 RPD MWD 4 OHMM 4 1 FET MWD 4 HOUR 4 1 NPHI MWD 4 P.U. 4 1 NCNT MWD 4 CNTS 4 1 FCNT MWD 4 CNTS 4 1 DRHO MWD 4 G/CC 4 1 RHOB MWD 4 G/CC 4 1 PEF MWD 4 BARN 4 1 Rep Code Offset Channel 68 0 1 68 4 2 68 8 3 68 12 4 68 16 5 68 20 6 68 24 7 68 28 8 68 32 9 68 36 10 68 40 11 68 44 12 68 48 13 68 52 14 Name DEPT ROP GR RPX RPS RPM RPD FET NPHI NCNT FCNT DRHO RHOB PEF Min 7576.5 0 01 31 34 1 64 1 64 1 63 1 62 0 47 18 03 13663 112.71 -1.38 0.88 2.58 Max Mean 8095 7835.75 1968.83 50.1348 159.18 90.9053 55.12 6.36506 53.4 6.59787 47.21 6.30513 45.62 6.46517 16.64 1.8782 72.22 32.3769 34408 24117.9 818.1 407.199 0.38 0.0738603 3.15 2.41007 11.02 4.24132 Nsam 1038 870 869 869 869 869 869 848 869 869 869 873 873 873 First Reading 7576 5 7660 5 7626 5 7633 5 7633 5 7633 5 7633 5 7633 5 7576 5 7576 5 7576 5 7590 7590 7590 Last Reading 8095 8095 8060.5 8067.5 8067.5 8067.5 8067.5 8057 8010.5 8010.5 8010.5 8026 8026 8026 First Reading For Entire File .......... 7576.5 Last Reading For Entire File ........... 8095 File Trailer Service name ............. STSLIB.005 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/07/07 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.006 Physical EOF Tape Trailer Service name ............. LISTPE Date ..................... 99/07/07 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Next Tape Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Reel Trailer Service name ............. LISTPE Date ..................... 99/07/07 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Next Reel Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Scientific Technical Services Technical Services Physical EOF Physical EOF End Of LIS File