Department of Commerce, Community, and Economic Development
Alaska Oil and Gas Conservation
Commission
HOME
EVENTS
DATA
Data List
Drilling
Production
Orders
Data Miner
Document Search
REPORTS
Reports and Charts
Pool Statistics
FORMS
LINKS
Links
Test Notification
Data Requests
Regulations
Industry Guidance Bulletins
How to Apply
ABOUT US
History
Staff
HELP
Loading...
The URL can be used to link to this page
Your browser does not support the video tag.
Home
My WebLink
About
200-001
• • pro aro— doJ Loepp, Victoria T (DOA) From: NSK Well Integrity Supv CPF3 and WNS <n2549@conocophillips.com> Sent: Monday, May 07, 2018 2:44 PM To: Loepp,Victoria T(DOA) Cc: Senden, R.Tyler Subject: KRU 3H-32 (PTD#200-001)IA Sustained Casing Pressure Follow Up Flag: Follow up Flag Status: Flagged Hi Victoria, Kuparuk producer 3H-32(PTD#200-001) has developed sustained casing pressure exceeding 2000 psi in the IA.At present,the pressure is approximately 2,140 psi.The well has 7",26 lb/ft, L-80 casing grade production casing,which has a burst pressure rating of 7,240 psi.We are working a plan that will have a tubing tail plug set and diagnostics performed in the near future. We will continue to monitor the well in the meantime. Please let us know if you have any questions or disagree with this plan. Sincerely, Sara Heskin on behalf of Travis Smith/Rachel Kautz Well Integrity Supervisor,ConocoPhillips Alaska Inc. Office:907-659-7126 Cell:907-331-7514 SCANNEV .itiNzoid 1 STATE OF ALASKA ALADA OIL AND GAS CONSERVATION COMMON REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon ❑ Plug Perforations LI Fracture Stimulate U Pull TubingLI Li Operations shutdown Performed: Suspend ❑ Perforate Q Other Stimulate El Alter Casing ❑ Change Approved Program ❑ Plug for Redrill ❑ erforate New Pool ❑ Repair Well ❑ Re-enter Susp Well ❑ Other: ❑ 2.Operator 4.Well Class Before Work: 5.Permit to Drill Number: Name: ConocoPhillips Alaska, Inc. Development ❑✓ Exploratory ❑ 200-001 3.Address: P. O. Box 100360,Anchorage,Alaska Stratigraphic ❑ Service ❑ 6.API Number: 99510 50-103-20322-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL 25524/25531 KRU 3H-32 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): Kuparuk River Field/Kuparuk River Oil Pool 11.Present Well Condition Summary: Total Depth measured 16,000 feet Plugs measured None feet true vertical 6,000 feet Junk measured None feet Effective Depth measured 0 feet Packer measured 13653 feet true vertical 0 feet true vertical 5909 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 82 16 117 Surface 4,672 12 4,707 �����w E Intermediate Production 13,777 10 13,809 Liner 2,362 7 16,000 DEC 0 5 Lin? Perforation depth Measured depth 14,475 feet fi�/�^GCC True Vertical depth 5,954 feet AO J Tubing(size,grade,measured and true vertical depth) 3.5 L-80 13652 5909 Packers and SSSV(type,measured and true vertical depth) No SSSV Baker ZXP Pacer 13,639 5909 12.Stimulation or cement squeeze summary: Intervals treated(measured): SCANNED AN 2 4 2'01,8 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: 0 0 0 1380 100 Subsequent to operation: 350 1800 200 725 250 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations El Exploratory Q Development❑ Service ❑ Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16.Well Status after work: Oil ❑✓ Gas ❑ WDSPL ❑ Printed and Electronic Fracture Stimulation Data El GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP❑ SPLUG ❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: N/A Authorized Name: Lynn Aleshire Contact Name: Lynn Aleshire Contact Email: Lynn.Aleshire@conocophillips.com Petroleum Engineer Authorized Title: /'/n _ 4 'L/ . /`} Contact Phone: (907)265-6525 Authorized Signature: �C„ Date: V7-1- //2/6 8 Form 10-404 Revised 4/20170 �� Submit Original Only RBC !S j,v L. i b 2017 • 3H-32 • DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary 11/20/17 E-COIL: RIH WITH 25' PERF GUN, 6 SPF 60 DEG PHASING. MAKE 3 CORRELATION PASSES FROM 14,620 RKB TO 13,600 RKB. TIE INTO GAMMA. PERF INTERVAL FROM 14,475'TO 14,500' RKB. 11/23/17 RIH WITH 25' PERF GUN, 6 SPF 60 DEG PHASING. MAKE 3 CORRELATION PASSES FROM 14,150' TO 13,600' RKB. TIE INTO GAMMA. PERFROM INTERVAL FROM 13,835'TO 13,860' RKB. 11/25/17 WELL BOL @ 11:47 AM. INITIAL WHP = 2000 PSI. GRADUALLY OPENED CHOKE TO 60/176. 3H-32 • DESCRIPTION OF WORK COMPLETED SUMMARY ConocoPhillips ConocoPhillips Alaska, Inc. 700 G St. Anchorage, AK 99501-3448 December 5, 2017 AOGCC Commissioner State of Alaska, Oil & Gas Conservation Commission 333 W. 7th Ave., Ste. 100 Anchorage, AK 99501 Dear Commissioner, Enclosed you will find the 10-404 Report of Sundry Well Operations for ConocoPhillips Alaska, Inc. regarding 3H-32 (PTD# 200-001) which reports additional Kuparuk pay that was recently perforated. If you have any questions regarding this work, please contact me at 907-265-6525. Sincerely, ((1_, 1664: Lynn Aleshire Petroleum Engineer ConocoPhillips Alaska, Inc. Attachments: Sundry Report Description of Work Completed Schematic 1 KUP POD 3H-32 ConocoPhillips Well Attributes Max Angle& D TD 7s Alaska.Inc. Wellbore API/UWI Field Name Wellbore Status a ncl(') MD(ftKB) Act Btm(ftKB) ConoCtlYhl6rps 501032032200 KUPARUK RIVER UNIT PROD 95.52 15,328.51 16,000.0 V ... Comment H2S(ppm) Date Annotation End Date KB-Grd(R) "Rig Release Date 3H-32.12/52017241;55 PM SSSV:NIPPLE 120 11/17/2007 Last WO: 6/4/2014 39.30 3/5/2000 Vertical schematic:(aoNa9... Annotation Depth(ftKB) End Date Annotation Last Mod By End Date COt Tag:RKB 14,712.0 11/19/2017 Rev Reason:TAG 8 PERFS pproven 12/5/2017 HANGER:29.6 'L`' Casing Strings 1 Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)... Wt/Len(I...Grade Top Thread E- CONDUCTOR 16 15.062 35.0 117.0 117.0 62.58 H-40 WELDED a Casing Description 'OD(in) 'ID(in) Top(ftKB) 'Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread • g p ('n) 8.835 34.4 4,706.6 2,989 4 40 00 L 80 BTCM PRODUCTION n OD 9 6B ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)...WtlLen(I..Grade Top Thread „rET7 6.276 32.0 13,809.2 5,913.4 26.00 L-80 BTC-MOD Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)...Wt/Len(I...Grade Top Thread ,.a^ 4 l✓."LINER 31/2 2.992 13,638.5 16,000.0 5,999.6 9.30 L-80 SLHT II Liner Details CONDUCTOR,35.0-1170- 41 Nominal ID Top(ftKB) Top(TVD)(ftKB) Top Incl C) Item Des Com (in) 13,638.5 5,908.7 90.24 PACKER BAKER ZXP PACKER 4.375 NIPPLE;494.9 ?= 13,652.6 5,908.7 89.98 HANGER BAKER FLEXLOCK LINER HANGER 8 5"RS 4.375 4 NIPPLE 13,656.1 5,908.7 89.92 PBR BAKER 80-40 PBR 4.000 Tubing Strings Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft..Set Depth(TVD)I...Wt(Iblft) Grade Top Connection TUBING WO 31/2 2.992 29.6 13,690.5 5,908.9 9.30 L-80 EUE 8rd GAS LIFT;3,620.8 Completion Details ill Nominal ID Top(ftKB) Top(ND)(RKB) Top Ind C) Item Des Com (in) 29.6 29.6! 0.19 HANGER HANGER 2.992 494.9 494.5 4.51 NIPPLE DS NIPPLE 2.875 SURFACE;34.4-4,706.6- 12,064.3 5,543.1 72.10 NIPPLE DS NIPPLE 2.812 13,651.9 5,908.7 89.99 LOCATOR LOCATOR SUB 2.990 SUB GAS LIFT;6,726.7 = 13,653.1 5,908.7 89.97 SEAL ASSY BAKER SEAL ASSY W/HALF MULE SHOE W/3' 2.990 "STICK UP" IIPerforations&Slots GAS LIFT;8,891.7 1 Shot Dens <- Top(TVD) Btm(TVD) (shots/ I Top(RKB) Btm(ftKB) (f6(B) (RKB) Zone Date ft) Type Com 13,835.0 13,860.0 5,915.0 5,916.8 UNIT D,3H- 11/23/2017 6.0 APERF 2.5'Power jet-Omega 32 PERF GUN,6 SPG 60 GAS LIFT,10,470.5 ".' DEG PHASING 4 14,316.0 14,660.0 5,940.3 5,968.0 C-4,3H-32 4/15/2000 4.0 (PERF 2"HSD Power jet 2006 14,475.0! 14,500.0 5,953.6 5,953.9 C-4,3H-32 11/20/2017 6.0 APERF 2.5'Power jet-Omega 4PERF GUN,6 SPG 60 GAS LFT;11.585.0 - DEG PHASING 14,730.0 14,795.0 5,973.5 5,975.4 A-1,3H-32 4/15/2000 4.0 (PERF 2"HSD Power jet 2006 4 14,910.0 15,120.0 5,972.6 5,971.0 C-4,3H-32 4/15/2000 4.0 IPERF 2"HSD Power jet 2006 It 15,140.0 15,155.0 5,970.6 5,970.3 C-4,3H-32 4/15/2000 4.0 IPERF 2"HSD Power jet 2006 NIPPLE,12064 3 • 15,180.0 15,435.0 5,969.7 5,955.0 C-4,3H-32 4/15/2000 4.0 IPERF 2"HSD Power jet 2006 15,600.0 15,760.0 5,955.7 5,971.2 C-4,3H-32 4/15/2000 4.0 IPERF 2"HSD Power jet 2006 8J [r 15,760.0 15,830.0 5,971.2 5,980.0 A-1,3H-32 4/15/2000 4.0 IPERF 2"HSD Power jet 2006 El Mandrel Inserts r St LOCATOR SUB;13,651.9 ati h .I on Top(ND) Valve Latch Port Size TRO Run VI 'IN Top)ftKB) (ftKB) Make Model OD(in) Sery Type Type (in) (psi) Run Date Corn SEAL ASSY;13,653.1 . ; 1 3,620.8 2,606.3 CAMCO KBMG 1 GAS LIFT GLV BK-5 0.156 1,352.0 6/4/2014 e e 2 6,726.7 3,697.4 CAMCO KBMG 1 GAS LIFT GLV 'BK-5 0.156 1,326.0 6/4/2014 MI 3 8,891.7 4,452.0 CAMCO KBMG 1 GAS LIFT GLV BK-5 0.188 1,344.0 6/4/2014 4 10,470.5 5,000.9 CAMCO KBMG 1 GAS LIFT GLV 'BK-5 0.188 1,323.0 6/4/2014 5 11,585.0 5,396.0 CAMCO KBMG 1 GAS LIFT OV .BEK 0.250 0.0 6/3/2014 Notes:General&Safety • PRODUCTION;32.0-13,809.2 End Date Annotation • 9/2/2010 NOTE:View Schematic w/Alaska Schematic9.0 --...1 APERF;13,835.0-13,660.0--. , APERF;14,475.0.14,500.01 IPERF;14,316.0-14,660.0 IPERF;14,730.014,785.0 IPERF;14,910.015,120.0 IPERF;15,140.015,155.0 IPERF;15,180.0-15,435.0 IPERF;15,600.015,760.0 IPERF;15,780.0-15,830.0 ti P- URER; LINER;13,638.5-16,000.0 o • • I-- 0 1 > N X a• r0 N O .Q N o�0 a '15p h {;}N� 40 T co Opr: a 00 o . N rn u p Q Y V coa c o + v o o� v C > 4. c .o +J �. • o v >. < p - -D m o¢ > > > > > > > > • E a) L + LNi zzzzzzzz 47 c t ,-.(13N S N N- N N N N C U L CD IA 2 Z g a) E v g v > ▪ v • O c L F- p 0 0 0 0 0 0 0 0 C '�WWWWWWWW CL)O- -0 > C• v1 _1 _i _1 _J _J _J _j _j Z Z Z Z Z Z Z Z u co a) p 'C LL LL LL LL LL LL LL LL L > E al u U C _a)o an U" v r-, P: r0 Y -c C C Z 0' .� fr. O ~ C ro a O O < Cl.) O_ (n C O. %) N c co y LL V d C) Cc t a J3... R Ca o0 • v c o o a - J Z6a (-)� o ' - ( . Ua W o U = F at ) 6f. I e, `) > co w ami %I �.. Z . - 0. J J J J J J J J , 82 'tCO Cr,R NN3333 � 33 � . 0 1 I I 1 1 1 1 1 1 1 I I I I I I I I I rtceIrecceeccew E W W W W W W W W Z W > > > > > > > > z Y Y Y Y Y Y Y Y en 0 W ¢ ¢ ¢ ¢ ¢ ¢ ¢ ¢ a L 0> LLI LL a a a 0. d a. d d O Y Y Y Y Y Y DD c a. u N tin - rr;, X n Imo CO r- v v v a N CO r CO LLI O p co co O N o 0 o 0 0 W 0 0 0 0 0 0 0 0 a) O U CO COrCO COra^o n CO o C WZ W' o g O g C1 0 C1CI x `�` rraa IX w u N o O 0 0 0 0 O V OLD 0 O O9 O O O O bp COM 0 4 Tr N er rb N I •N E:. 03 COa0 N 0 O r 0•1 N C-1 J p1 05 N In 0 N N 0 N N 0 vl N N N O N N N N N N L F.: Q an Of N ei Di co al , ER NNNNNONNto O O O O O O O •L O O O O O O O 0 O dr 0 v co C N N N N N N N N a U - CD 1- 0) ra I a CLI L) N < OO "LLCCI d' C ".... 22. �� ~ aJ '"i G v. 7 'tf CV N 1a N @ a) a) E Z +.,,- OA m z O r M N N a+ a) �' E v C a, a p N w = _ _ - M D o E i. Z N '� .1 u R r C C as N '-i C 0C/3 r2 ,÷-1 H aL a STATE OF ALASKA RECEIVED ALA_ .OIL AND GAS CONSERVATION COMM, JION JUN 13 2014 REPORT OF SUNDRY WELL OPERATIONS 1.Operations Performed: Abandon r Repair w ell rw Rug Perforations r Perforate r Other AQcGC Alter Casing r Pull TubingI✓ Stimulate-Frac r Waiver r Time Extension r Change Approved Program rOperat. Shutdown r Stimulate-Other r Re-enter Suspended Well r 2.Operator Name: 4.Well Class Before Work: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Development pr Exploratory r 200-001 3.Address: 6.API Number: Stratigraphic r Service r P. O. Box 100360,Anchorage,Alaska 99510 50-103-20322-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL 25531,25524 3H-32 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 16000 feet Plugs(measured) none true vertical 6000 feet Junk(measured) none Effective Depth measured 15937 feet Packer(measured) 13639 true vertical 5993 feet (true vertical) 5909 Casing Length Size MD TVD Burst Collapse CONDUCTOR 82 16 117 117 SURFACE 4672 9.625 4707 2989 PRODUCTION 13777 7 13809 5913 LINER 2362 3.5 16000 6000' SCANNED JUL 1 0 ZQ14, Perforation depth: Measured depth: 14316-14660, 14730-14795, 14910-15120, 15140-15155, 15180-15435, 15600-15830 Vertical D Tr uee t h: 5940-5968, 5974-5975, 5973-5971,5971-5970, 5970-5955, 5956-5980 Tubing(size,grade,MD,and TVD) 3.5, L-80, 13691 MD,5909 TVD Packers&SSSV(type,MD,and ND) PACKER-BAKER ZXP PACKER @ 13639' MD and 5909 TVD NIPPLE-CAMCO DS NIPPLE @ 495 MD and 495 ND 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 15.Well Class after work: Copies of Logs and Surveys run Exploratory r Development r✓ Service r Stratigraphic r 16.Well Status after work: Oil ri Gas r WDSPL r Daily Report of Well Operations XXX GSTOR r WIND r WAG r GINJ r SUSP r SPLUG r 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: none Contact Erik Nelson (a,263-4693 Email Erik.Nelson(c�conocophillips.com Printed Name Erik Nelson Title Sr. Wells Engineer Signature Phone:263-4693 Date /. tieZ4d/g ti,-- //« l RBGMS JUN 16 201t. 1 /01- , 4i� y Form 10-404 Revised 10/2012 Submit Original Only �r� KUP PROD 3H-32 Conoc hillips & Well Attributes Max Angle&MD TD Alaska Inc. Wellbore API/UWI Field Name Wellbore Status ncl(°) MD(ftKB) Act Btm(ftKB) 501032032200 KUPARUK RIVER UNIT PROD 95.52 15,328.51 16,000.0 °.. Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date 311-32,6/13201410:03:33 AM SSSV:NIPPLE 120 11/17/2007 Last WO: 6/4/2014 39.30 3/5/2000 Venwal schemata(Actual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date ..............._.._......._.,...................._......,._._.... .. ... ........._....._.Last Tag:SLM 12,036.0 6/1/2014 Rev Reason:WORKOVER;GLV C/O postojl 6/9/2014 HANGER.29.6 k',l Casing Strings 1I i i' Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread ,i_ Via. CONDUCTOR 16 15.062 35.0 117.0 117.0 62.58 H-40 WELDED I Ir Casing Description OD(in) ID(in) Top(ftKB) 'Set Depth(ftKB) Set Depth(TVD)...,WILen(I...Grade Top Thread SURFACE 95/8 8.835 34.4 4,706.6 2,989.4 40.00 L-80 BTCM ' 1 Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) 'Set Depth(ND)..,Wt/Len 0...Grade Top Thread PRODUCTION 7 6.276 32.0 13,809.2 5,913.4 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 LINER 312 2.992 13,638.5 16,000.0 5,999.6 9.30 L-80 SLHT ^Liner Details CONDUCTOR;35.0117.0 Top(ftKB) Top(TVD)(ftKB) Top Incl(°) Item Des Com No(in) I ID 13,638.5 5,908.7 90.24 PACKER BAKER ZXP PACKER 4.375 13,652.6 5,908.7 89.98 HANGER BAKER FLEXLOCK LINER HANGER 8 5"RS 4.375 NIPPLE;494.9 NIPPLE 13,656.1 5,908.7 89.92'PBR BAKER 80-40 PBR 4.000 Tubing Strings Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft..Set Depth(ND)(...Wt(lb/ft) Grade Top Connection TUBING WO 3 1/2 2.992 29.6 13,690.5 5,908.9 9.30 L-80 EUE 8rd Completion Details GAS LIFT;3,620.8 Nominal ID Top(ftKB) Top(TVD)(ftKB) Top Incl(°) Item Des Corn (in) 29.6 29.6 0.19 HANGER HANGER 2.992 494.9 494.5 4.51 NIPPLE DS NIPPLE 2.875 12,064.3 5,543.1 72.10'NIPPLE DS NIPPLE 2.812 13,653.1 5,908.7 89.97 SEAL ASSY BAKER SEAL ASSY W/HALF MULE SHOE W/3' 2.990 SURFACE.34.4-4,7066-r 4. "STICK UP" Perforations&Slots GAS LIFT;6,726.7 g' Shot Dens Top(TVD) Btm(TVD) (shotsl Top(ftKB) Btm(ftKB) (ftKB) (ftKB) Zone Date t) Type Corn 14,316.0 14,660.0 5,940.3 5,968.0 Miluveach,3H 4/15/2000 4.0 (PERF 2"HSD Power jet 2006 -32 GAS LIFT;8,891.7 - 14,730.0 14,795.0 5,973.5 5,975.4 Miluveach,3H 4/15/2000 4.0 (PERF 2"HSD Power jet 2006 -32 14,910.0 15,120.0 5,972.6 5,971.0 Miluveach,3H 4/15/2000 4.0 (PERF 2"HSD Power jet 2006 -32 GAS LIFT;10,470.5 g 15,140.0 15,155.0 5,970.6 5,970.3 Miluveach,3H 4/15/2000 4.0 (PERF 2"HSD Power jet 2006 -32 15,180.0 15,435.0 5,969.7 5,955.0 Miluveach,3H 4/15/2000 4.0 IPERF 2"HSD Power jet 2006 -32 15,600.0 15,830.0 5,955.7 5,980.0 Miluveach,3H 4/15/2000 4.0 IPERF 2"HSD Power jet 2006 GAS LIFT,11,585.0 .. -32 Mandrel Inserts St ati on Top(TVD) Valve Latch Port Size TRO Run NIPPLE,12,0643 _ N Top(ftKB) (ftKB) Make Model OD(in) Sery Type Type (in) (psi) Run Date Com 3,620.8 2,606.3 CAMCO KBMG 1 GAS LIFT GLV BK-5 0.156 1,352.0 6/4/2014 2 6,726.7 3,697.4 CAMCO KBMG 1 GAS LIFT GLV BK-5 0.156 1,326.0 6/4/2014 T , MI. 3 8,891.7 4,452.0 CAMCO KBMG 1 GAS LIFT GLV BK-5 0.188 1,344.0 6/4/2014 `-iii 4 10,470.5 5,000.9 CAMCO KBMG 1 GAS LIFT GLV BK-5 0.188 1,323.0 6/4/2014 1=t 5 11,585.0 5,396.0 CAMCO KBMG 1 GAS LIFT OV BEK 0.000 00 6/3/2014 LOCATOR SUB;13651.9 117 - Notes:General Safety 1'1I End Date Annotation 9/2/2010 NOTE:View Schematic w/Alaska Schematic9.0 SEAL ASSY;13,653.1 • i PRODUCTION.32 0-13.809.2-- IPERF,14.316.014,660.0 (PERF;14,730.0-14,795.0 IPERF:14.910 0-15.120.0 IPERF:15.140 0-15.155.0 IPERF,15,180.0.15,4350 IPERF;15,600.0-15,830.0 LINER,13,638.5-16,000.0 3H-32 WELL WORK SUMMARY DATE SUMMARY PRE-RIG WELL WORK 12/22/2013 (PRE-RWO) : FT LDS (ALL GOOD BUT ONE) UNABLE TO GET TO IC LDS @ 12 O CLOCK DUE TO AN OLD FLOOR KIT BRACKET, T-POT(PASSED), T-PPPOT(PASSED), IC-POT(PASSED), IC-PPPOT(PASSED). IN PROGRESS. 1/4/2014 (PRE-RWO): FT IC LDS @ 12:00 POSITION-FUNCTIONED PROPERLY. OA FL @ SF. 3/30/2014 (PRE RWO) : SCLD (PASSED). 4/30/2014 DRIFT W/2.84"G-RING TO X-NIP @ 12078' RKB; MEASURED BHP (3420 psi) @ 13202' RKB'; ATTEMPT TO PULL 1.5" OV @ 12033' RKB. IN PROGRESS. 5/1/2014 PULLED 1.5" DV @ 12033' RKB. JOB COMPLETE (READY FOR BPV) Conor Phillips Time Log & Summary WdlHew Web Reporting Report Well Name: 3H-32 Rig Name: NABORS 7ES Job Type: RECOMPLETION Rig Accept: 5/9/2014 10:00:00 AM Rig Release: 5/14/2014 12:00:00 AM Time Logs Date From To Dur S. Depth E. Death Phase Code Subcode T Comment 05/08/2014 24 hr Summary RDMO 3J-17. MIRU on 3H-32. 00:00 04:00 4.00 MIRU MOVE DMOB P Finish welding hubs on Rig Sub. Finish cleaning out cuttings tank& disconnecting lines. R/D rig& associated equip: R/D floor. Interconnect lines etc. Change out Saver Sub to HT-38. 04:00 07:00 3.00 MIRU MOVE DMOB P Bridle up. Remove Berming around rig, pits&camp. 07:00 08:00 1.00 MIRU MOVE DMOB P Lower Derrick. 08:00 10:00 2.00 MIRU MOVE DMOB P Change oil in#1 pump. Clean up well _ pad. Prep to move off location. 10:00 12:00 2.00 MIRU MOVE DMOB P Blow down steam lines in pits. Swap over to generator power.Jack up pit module.. Remove cuttings tank. 12:00 21:00 9.00 MIRU MOVE MOB P Mobilize rig&associated equip from 3J-17 to 3H-32. 21:00 00:00 3.00 MIRU MOVE MOB P Hang tree in cellar. Lay out Herculite &plywood in cellar area. 05/09/2014 Continue to Rig Up. Accept Rig at 10:00 hrs,05/09/2014. 00:00 02:00 2.00 MIRU MOVE MOB P Continue to MIRU. Transport rig mats and set same. Lay Herculite and plywood. Spot and set down the Sub Base. 02:00 06:00 4.00 MIRU MOVE MOB P Set rig mats and lay Herculite for the Pits. Spot Plts, Cuttings, Parts House,and the Mud Engineer's Shack. 06:00 10:00 4.00 MIRU MOVE MOB P Berm up arounds rig&modules. Hook up inter connects. Finish changing oil in Pump#1. Install stairs&landings around rig. 10:00 13:00 3.00 MIRU MOVE MOB P Raise derrick. Install cattle shute. Bridle down. Begin R/U for well kill in cellar.Take on fluid. ACCEPTED RIG @ 1000 hrs. 13:00 18:00 5.00 MIRU MOVE MOB P Con't to R/U cellar. Install 2nd Annular valve. R/U floor. Con't to take on fluid. 18:00 20:00 2.00 MIRU WHDBO THGR P P/U&test lubricator to 2000 psi, Ok. Pull BPV. Had some trouble pulling BPV due to seals being rolled.. UD Lubricator&BPV. 20:00 21:00 1.00 MIRU WHDBO RURD P R/U kill lines to tree. Con't to blend kill fluid for 11.6 ppg weight kill fluid. Page lof6 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 21:00 00:00 3.00 MIRU WHDBO COND P Con't to condition mud to 11.6 ppg wt.Test inter connect lines, mud lines, kelly hose&hard lines to Tiger Tank&choke house. Lines tested to 3500 psi. 35/10/2014 Continue with well kill operations. Kill well, Monitor well, static. N/D tree. N/U&begin testing BOPE. 00:00 01:00 1.00 MIRU WHDBO COND P Con't to blend brines to even out weights @ 11.6 ppg. Have 970 bbls on location. 01:00 06:00 5.00 MIRU WHDBO KLWL P Hold PJSM w/all hands. Review Well Kill procedure. Kill well as follows; Open well.TP- 1500 psi, IAP-1350 psi, OAP-300 psi. Blow down IA&Tbg.Well appears to be fluid packed. Pump 3 BPM. Initial PP 1350 psi,dropped to 185 psi after 1 hole volume. Choke press 1575 psi, dropped to 220 psi after 1 hole volume. Getting 11.4+ppg returns after 1 hole volume. (422 bbls)Con't to circulate @ 3 BPM, 230 psi.After 585 bbls getting 11.5 ppg back. 06:00 07:45 1.75 MIRU WHDBO KLWL P Continue circulating Well. Total volume pumped 635 bbls(-1 1/2 x hole volume from the present circulation point at 12,033-ft). 11.5 lb/gal(heavy)fluid returns. Shut down to have a Vac Truck get a returns load out of the Tiger Tank and to monitor the Well. Tubing on a slight vacuumn/SIP on the IA=65 psi. Bleed gas and trapped air to Bleed Trailer. IA pressure now"0" psi and spitting fluid. 07:45 09:00 1.25 MIRU WHDBO KLWL P Shut in the IA. Bullhead past the circulation point at 12,033-ft with 40 bbls at 2.0 bpm/530 psi down the tubing to contaminate the tubing and in the sump below the LinerTie-Back Packer at 13,671-ft. End bullhead. Monitor a gradual pressure fall-off from 530 psi down to100 psi. Pressure trying to stabilize at 100 psi. Slowly bleed remaining pressure from the tubing side. Monitor Well. Tubing went on slight vacuum. IAP= 140 psi. Bleed to "0"psi. Shut back in and observe a pressure at 30 psi. Page 2 of 6 Time Logs Date From To Dur S. Death E. Depth Phase Code Subcode T Comment 09:00 12:00 3.00 MIRU WHDBO KLWL P Pump down the Tubing taking returns to the tiger Tank. Grab a returns sample after 50 bbls pumped. Returns clean enough to take to the Plts. Continue to circulate IA volume at 4.0 bpm/720 psi back to surface (317 bbls). Monitor Well. Shut in pressure on both sides 140 psi. Flow the tubing side back to the Pits. Tubing side dead and the IA dropped to"0"psi. Open both sides at the Tree and flow into 5 gal buckets. Small stream. The tubing quit flowing and shortly so did the IA. Monitor the Well static for 30 minutes. No flow. Call out FMC. Rig down circulating equipment. Leave well open and continue to monitor. 12:00 13:30 1.50 MIRU WHDBO NUND P Secure well. Blow down lines. R/D Kill manifolding. 13:30 14:00 0.50 MIRU WHDBO THGR P Set BPV w/T-bar. 14:00 15:30 1.50 MIRU WHDBO NUND P N/D Tree. Inspect Hanger Threads, look good. Made up blanking plug w/ 11 3/4 turns.Top of plug.95'above flange. 15:30 18:00 2.50 MIRU WHDBO NUND P N/U BOPE. 18:00 20:00 2.00 MIRU WHDBO RURD P Change out bottom rams to 2 7/8"x 5" VBRs. L/D 3 1/2"x 6"VRBs. 20:00 21:00 1.00 MIRU WHDBO RURD P R/U test equip&test jt. Prep to Test BOPE. Hold PJSM. 21:00 00:00 3.00 MIRU WHDBO BOPE P Begin BOP test. Jeff Jones w/ AOGCC waived witnessing BOP test @ 09:30 hrs, 5-8-2014.Tested as follows: LP 250 psi, HP 4000 psi. Blind Rams, Ck Valve#1,2, 3,16. Kill to Demco on SP. Outer Test Spool Valve, Dart, Ck Valve#4,5, 6. Inner Test Spool Valve, Kill HCR. Ck Valve#7, 8, 9. Manual Kill. Super Ck, Manual Ck. Ck Valve#10, 11. Ck Valve#12, 13.Test Annular LP 250 psi, HP 3500 psi, 3 1/2"TIW. Tested Gas Alarms-Good. 35/11/2014 Finish BOP test. Monitor well. M/U landing jt&pull the Tubing Hanger to the floor. Circulate 1.5 hole volumes.Tally&prep new completion. POOH&LID existing completion 00:00 02:30 2.50 MIRU WHDBO BOPE P Con't to test BOPE. LP 250 psi, HP 4000 psi.Test Top Rams, Ck Valve# 15, Upper IBOP, HT-38 TIW. Lower Kelly, Ck Valve 14. HCR Ck Valve. Manual Ck Valve, Lower Rams. Perform Koomey test-200#recovery 19 sec. Total recovery 102 sec.5 N2 bottles-2025 psi. Page 3 of 6 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 02:30 03:30 1.00 MIRU WHDBO NUND P R/D test equip. L/D test jt. Drain stack.Verify tbg dead Pull BPV& L/D same. Monitor tbg&IA,well static. 03:30 04:00 0.50 13,656 13,626 COMPZ RPCOM PULL P Hold PJSM. M/U landing jt into hanger. BOLDS. P/U&pull hanger to floor. P/U&pull to 125K string appeared to be moving.At—13' pulled to 180 K&string came free from recepticle. Pull hanger to floor& insure string free.. 04:00 08:00 4.00 13,626 13,626 COMPZ RPCOM CIRC P Circulate 1 1/2 times hole volume. Pump 3 BPM @ 350 psi. Total volume pumped=715 bbls/370 psi. 11.6 lb/gal in/11.6 lb/gal out. No gas in retuns. Fluid lost at 16 bbls/hr. 08:00 12:00 4.00 13,626 13,626 COMPZ RPCOM CIRC P Continue to circulate at 1.0 bpm/55 psi to maintain hole fill. SIMOPS: Load,drift,and tally the 3 1/2" completion string. Move to the "off-drillers"side of the Pipe Shed. Total Joints numbered and tallied= 440(Total Jts on Location 460). Prep the"drillers-side"of the Pipe Shed to lay down the completion tubing presently in the well. 12:00 13:00 1.00 13,626 13,626 COMPZ RPCOM OWFF P Shut down Pump and blow down lines. Monitor Well,x 30 minutes. Fill Hole. Fluid loss=9 bbls/hr. 13:00 00:00 11.00 13,626 2,514 COMPZ RPCOM PULL P Lay down the Landing Joint and the Tubing Hanger. Up weight= 115K. Single down the 3 1/2"the Completion. Number and tally. Also look for corrosion areas or any other anomalies. Pulled from 13626 to 2514'. P/U 110K, Fluid loss—9 BPH. 35/12/2014 Finish POOH&L/D existing completion. Hold PJSM&review running order. Run New 3 1/2"completion as per program.Tag up&space out completion. M/U hanger&landing jt. Break circulation. 00:00 02:00 2.00 2,514 0 COMPZ RPCOM PULL P Con't to POOH&L/D 3 1/2" completion. 1 -"XN"nipple assy, 1 -"DS"nipple assy, 5-GLM assys, 1 -Seal assy&440 jts of 3 1/2"9.3# L-80 EUE tbg. From 10996 to 11642' tbg showing corrosion&pitting on boxes. Fluid losses 7.5 BPH. 02:00 03:00 1.00 0 0 COMPZ RPCOM OTHR P Clear&clean Rig floor. Monitor well. Verify jt count&jewelry running order. Service rig. 03:00 06:00 3.00 0 960 COMPZ RPCOM RCST P Hold PJSM. Review running order w/ all hands. P/U&RIH w/new 3 1/2" 9.3#, L-80, EUE 8rd completion. Have 30 jts in hole at 06:00 hrs. Page 4 of 6 • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T ' Comment 06:00 11:00 5.00 960 5,725 COMPZ RPCOM RCST P Continue to single in with the 3 1/2" Completion as designed. (SIMOPS: Meet with the Corrosion group on the Slope inspected miscellaneous corrosion areas observed mostly on collars at different depths. Found GLM#5(12,033-ft)had washed out ports. Take pictures as needed. Saw no holes in the Tubing. Corrosion Group will pass on their report to the next level). 11:00 11:30 0.50 5,725 5,725 COMPZ RPCOM RCST T RIH to 5725'. P/U 60K, SIO 50K. Blew hose on Power Tongs. Change out Power Tongs. 11:30 21:30 10.00 5,725 13,648 COMPZ RPCOM RCST P Con't to RIH w/ 3 1/2"completion as per program. RIH w/443 jts. 21:30 23:30 2.00 13,648 13,648 COMPZ RPCOM RCST P Kick in pump @ 1 BPM S/O&Tag up, Inside of recepticle dirty,took 20K wt then went thru. S/0 w/20k on NO-Go. UD 3 jts&space out completion. Ran 441 jts+2-10'pups + 1-2'pup. M/U hanger&pup assy. P/U wt-105K, S/Owt-50K. 23:30 00:00 0.50 13,648 13,648 COMPZ RPCOM CIRC P M/U circulating head pin&R/U to Circulate. Break circulation 2 BPM. 35/13/2014 Pump Corrosion Inhibited Brine. Land Tubing Hanger.Test Casing/Seal Assembly. Nipple down BOPE. Nipple up Tree.Test Tree. Shear SOV. Freeze protect Well with Diesel. Set BPV. Offload fluids from Rig and Tiger Tank. Secure Tree and Cellar. OA=440 psi; IA/tbg= 1200 psi. _ RIG RELEASE @ 23:59 00:00 02:30 2.50 13,648 13,648 COMPZ RPCOM CIRC P Circulate and rig up to pump corrosion inhibited fluid. Pump 60 bbls of 11.6 Corrosion Inhibited fluid down the tubing. Displace with 123 bbls of 11.6 lb/gal Brine. Pump at 3 BPM/500 psi. Drain stack. Blow _ down lines. 02:30 03:30 1.00 13,648 0 COMPZ RPCOM RCST P Attempt to land hanger, stacked out 5'from No-Go.Work string several times with out success. Bullhead 2 BPM/400 psi. Pumped 6 bbls and bled off pressure. Slack off and land the tubing Hanger. RILDS. Up weight= 105K. Down weight=50K. 03:30 04:30 1.00 0 0 COMPZ RPCOM PRTS P Rig up test equipment. Pressure test IA as follows: LP 250 psi, 10 min. HP 2500 psi, 30 min. Monitor the Tubing static. Charted same.Test Good. 04:30 05:00 0.50 0 0 COMPZ WHDBO THGR P Break out and lay down the landing joint. Monitor well x 30 minutes. Install TWCV. Flush the Stack. Blow down lines. 05:00 08:30 3.50 0 0 COMPZ WHDBO NUND P Nipple down BOPE stack and set back on the stump. Nipple up Tree. Drill Site Operator verified Tree alignment. Page 5 of 6 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 08:30 10:00 1.50 0 0 COMPZ WHDBO PRTS P Pressure test the hanger void/pack-offs at 250/5,000 psi. Good. Test the Tree at 250/5,000 psi. Good. Pull the TWCV. 10:00 12:30 2.50 0 0 COMPZ RPCOM CIRC P PJSM. Review pump procedure. Rig up lines to the circulating manifold and a line to the Tree. Rig up line from Little Red to the circulating manifold. Test Nabors line to 4,300 psi. 12:30 13:30 1.00 0 0 COMPZ RPCOM CIRC P Bring Nabors Pump on line and shear the SOV("bench set"to shear at 3,400 psi)at 4,000 psi (maximum allowable pressure limit) on the second attempt. Pump at 2.0 bpm/1,400 psi to confirm flow path. Record on chart. 13:30 14:30 1.00 0 0 COMPZ RPCOM CIRC P Pump 36 bbls of Corrosion Inhibited Sea Water at 2.0 bbls/min/1,900 psi. Chase with 8.0 bbl fresh water to flush pump and line to the Tiger Tank (with fresh water). 14:30 18:00 3.50 0 0 COMPZ RPCOM FRZP P Little Red Services pressure test their line at 3,500 psi. Start diesel down the 7"x 3 1/2"IA at 1.9 bpm/1,400 psi. Pump 379 bbls of diesel down IA. 18:00 20:00 2.00 0 0 COMPZ RPCOM RURD P Rig Down Little Red Services. SIMOPS: Blow Down rig and offload fluid from pits and tiger tank. 20:00 22:00 2.00 0 0 DEMOB MOVE RURD P Pick Up lubricator and set BPV. Pressure built from 700 psi to 1200 psi during this time period. SIMOPS: Blow Down rig and offload fluid from pits and tiger tank. 22:00 00:00 2.00 0 0 DEMOB MOVE RURD P Lay Down Lubricator and Secure Tree and Cellar. Finish offloading _fluids and prep rig for move off of well. Page 6 of 6 3H-32 WELL WORK SUMMARY DATE SUMMARY POST-RIG WELL WORK 6/1/2014 (WEATHER DELAYED START DUE TO WIND) DRIFT TBG TO 13453'SLM (STOPPED DUE TO DEVIATION); MEASURED BHP @ 13478' RKB: 3440 PSI. IN PROGRESS. 6/2/2014 SET 2.81" CAT STANDING VALVE @ 12064' RKB, PULLED SOV @ 13585' RKB&SET 1' DV, PASSING MIT-T OF 2500 PSI, IN PROGRESS. 6/3/2014 PULLED & SET DV @ 11585' RKB (MIT-IA PASS); PULLED DV & SET OV @ 11585' RKB; PULLED DV @ 10471' RKB. IN PROGRESS. WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. October 20, 2010 Attn.: Christine Shartzer 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Packer Setting: 31-1-32 Run Date: 10/5/2010 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Klinton Wood, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 3H -32 Digital Data in LAS format, Digital Log Image file 1 CD Rom 50 -103- 20322 -00 NG'V ��� PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Klinton Wood 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907 - 273 -3527 Fax: 907 - 273 -3535 klinton.wood bu.coi r Date: Signed: • WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. Attn.: Christine Mahnken 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Leak Detection Log: 3H-32 Run Date: 4/16/2010 Apri129, 2010 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Rafael Barreto, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 3H-32 Digital Data in LAS format, Digital Log Image file 1 CD Rom 50-103-20322-00 ~~ .-601 l `~ (ol 5 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Rafael Barreto 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-273-3527 Fax: 907-273-3535 rafael.barretoF ~ 'mil ;corn ' ~~- ~ ~ _ ~,,, ,~ Date: ;;yy~~~p ~~ (( :t ~ry Signed: • • WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. Attn.: Christine Mahnken 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Plug Setting Record: 3H-32 Run Date: 4/13/2010 April 23, 2010 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Rafael Barreto, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 3H-32 Digital Data in LAS format, Digital Log Image file 1 CD Rom 50-103-20322-00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Rafael Barreto 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-273-3527 Fax: 907-273-3535 rafael.barreto@halliburton. com c~CSU -oU ~ ~~~v ~ Date: ~,~, ~a fa ^~~~ ~ , ,ors ,~ Signed: ~, ~ ~ COI'10 ~~~ coPhillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 August 11, 2009 Mr. Tom Maunder Alaska Oil & Gas Commission o a.~ ~Q-~ 333 West 7~' Avenue, Suite 100 ~ }~..~ w-~~,~ ~ . _' ~~~.:a 3~ -3 ~-- Anchorage, AK 99501 h. Dear Mr. Maunder: Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRi~. Each of these wells was found to have a void in the conductor. These voids were filled with cement if needed and corrosion inhibitor, engineered to prevent water from entering the annular space. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treatments took place and meets the requirements of form 10-404, Report of Sundry Operations. The cement was pumped July 30~' 2009 and the corrosion inhibitor/sealant was pumped August 8~', 9~' and 10~' 2009. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please ca11 Perry Klein or MJ Loveland at 907-659-7043, if you have any questions. Sincerely, ~~G~' ( MJ Lov land ConocoPhillips Well Integrity Projects Supervisor ~ ~ ConocoPhillips Alaska Inc. Surtace Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (70-404) Kuparuk Field Date 08/11/09 ~~ ~~ ~~ a ~., ~,.a ell Name PI # TD # Initial top o cement Vol. of cement um ed Final top of cement Cement top off date .~...~ Corrosion inhibitor ~ Corrosion inhibitoN sealant date bbls al 3G-12 50103201310000 1900730 24' 4.00 20" 7/30/2009 4.25 8/10/2009 3G-13 50103201370000 1901160 17" Na 17" n/a 2.97 8/10/2009 3G-15 50103201390000 1901210 18" Na 18" n/a 2.97 8/10/2009 3G-23 50103201440000 1901320 17" n/a 17" n/a 1.27 8/10/2009 3H-02 50103200830000 1871070 21" n/a 21" n/a 3.82 8/8/2009 3H-06 50103200780000 1870780 8'5" 2.00 18" 7/30/2009 5.52 8/8/2009 3H-07 50103200790000 1870790 17" n/a 17" n/a 2.97 8/8/2009 3H-09 50103200860000 1871120 17" n/a 17" n/a 5.52 8/8/2009 3H-106 50103200870200 2031600 16" Na 16" n/a 2.55 8/8/2009 3H-12 50103200880000 1871290 2'7" n/a 2'7" n/a 8.92 8/9/2009 3H-15 50103200820000 1871030 19" n/a 19" n/a 3.4 8/9/2009 3H-16A 50103200960100 2000220 15' 2.75 17" 7/30/2009 1.7 8/9/2009 3H-18 50103200950000 1880090 SF n/a 17" n/a 5.52 8/9/2009 3H-20 50103200930000 1871340 16' 3.75 16" 7/30/2009 2.25 8/9/2009 3H-22 50103200970000 1880110 27'6" 4.25 21" 7/30/2009 8.5 8/9/2009 3H-25 50103202030000 1990400 30" n/a 30" n/a 7.65 8/9/2009 3H-26 50103202080000 1940290 SF n/a 9" n/a 2.12 8/9/2009 3H-28A 50103202360100 1960370 SF Na 18" n/a 5.1 8/9/2009 3H-32 50103203220000 2000010 10" n/a 10" Na 1.27 8/9/2009 3K-102 50029233786000 2071650 n/a n/a 5" n/a 1.27 8/8/2009 3Q-01 50029222200000 1911250 15'7" 2.00 17" 7/30l2009 4.25 8/8@009 3Q-02 50029216880000 1870040 41' 4.75 21" 7/30/2009 5.52 8/8/2009 3Q-04 50029222190000 1911240 4'10" 1.50 16" 7/30/2009 4.25 8/8/2009 3Q-07 50029216820000 1861940 6" n/a 6" n/a 1.7 8/9l2009 3Q-12 50029216770000 1861890 7" n/a 7" n/a 2.97 8!8/2009 3Q-13 50029216640000 1861760 44'6" 5.00 21" 7/30/2009 8.92 8/8/2009 3Q-15 50029216660000 1861780 49'S" 4.50 20" 7/30/2009 9.35 8/8/2009 3Q-16 50029216670000 1861790 46' 5.25 30" 7l30/2009 8.5 8/8l2009 ~ ~.~...~ ~ __---. _ _ __.._# ~~L~ ~~~ 1°l~A~~l~l/l~AL ProActive Diagnostic Services, Inc. ~ T0: AOGCC Christine Mahnken 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 (907) 659-5102 RE : Cased Hnle/Open Hoie/Mechanical Logs and/orTubing Inspection[Caliper/ MTf) The technical da~a listed below is being submitted herewith. Please acknowfedge receipt by retuming a signed copy of this transmittal letter to the following : ProActive Diagnostic Services, lnc. Attn: RobertA. Richey ~~~;~~~ ~~~ ~ ~ ~~~$ 130 West International Airport Road Suite C Anchorage, AK 99518 Fa~c (907j 245,8952 1) Caliper Repoet 26-Ju1~08 1 R-26 1 Repor9t/ EDE 50-029-22193-00 ~_ 2~ Caliper Report 25Ju1-08 `~ H•- ~~~ 1 Report / E~ 50-103-2032r ~-- ~ T ~ ~4 /-b~i ~ ~ /(-~S ~f ~ ~pt)-i~d t (oto SJ ~! ~.~- , ~ ,,, / , ~~ ~ ~/ ~~/~~ S+gned : l /. X~~-=~' Date : - Prirrt Name: _(~ (,,.~~t~,~ ~1.~,:ti~~~ PROAcTIVE DIaGNOSrIC SERVICES, Iwc., 130 W. ~Ni'ERNATIONAL AIRPORT RD SURE C, ANCHORAGE, AK 89518 PHONE: (907)245-8957 FAX: (907~245-88952 E-N411L: °^-~ -~~~ .,, :~ ~`'a WEBSITE -;, C:\Documents and Settings\Owne[\Desktop\Tisnsmit_C~eoco.doc ii ~ ~~ ~~v~ • • Memory Multi-Finger Caliper Log Results ~urnmary Company: ConocoPltillips Alaska, Inc. Well; 3M-32 Log Date: July 25, 2008 Field: Kuparuk Log No.: 7251 State: Alaska ', Run No.: 1 API No.: 50-103-20322-00 ~' Pipe1 Desc.: 3.5" 9.31b. L-80 EUE 8 RD Top Log Intvlt: Surface Pipet Use: Tubing Bot. Log Intvl1.: 12,026 Ft. (MD) Inspection Type : Comosnre & Mechanical Damage Inspection COMMENTS: This caliper data is fled into the GLM 3 @ 9,237' (Drillers Depth), This log was run to assess the condition of the tubing with respect to internal corrosive and mechanical damage. The caliper recordings indicate that the interval of 3.5" tubing logged is in good to poor condition, with a maximum recorded penetration of 64°~ ~ 7,427. Wall penetrations in excess of 20% waU thickness are recorded in 53 of the 397 joints togged. The most significant wall penetrations are recorded in a very thick line of corrosion (6,890' - 7,660'). There are no areas of significant Cross Sectional Wall loss or LD. restriction recorded throughout the tubing. Cross-sectiona! drawings of the most significant events recorded are included in this report. The distribution of maximum recorded penetrations is illustrated in the Body Region Analysis Page of this repork A graph illustrating the correlation of recorded damage to borehole profile is included in this report. MAXIMUM RECORDED WALL PENETRATIONS Corrosion (64°~) Jt. 240 ~ 7,427 Ft. (MD) Corrosion (63°r6) Jt. 234 ~ 7,238 Ft. (MDj Corrosion (62%) Jt. 236 ~ 7,319 Ft. (MD) Corrosion (61°~) Jt. 244 ~ 7,554 Ft. (MD) Corrosion (59°~) Jt. 229 ~ 7,082 Ft. (MD) MAXIMUM RECORDED CROSS-SECTIONAL METAL LOSS No areas of significant cross-sectional waft loss {>11%) are recorded. MAXIMUM RECORDED ID RESTRICTIONS : No significant I.D. restrictions are recorded. ~'~'~~~~ ~~ ~ ~` ~~~~ Field Engineer. Wm. McCrossan Analyst: J. Thompson Witness: C. Fitzpatnck ProActive Diagnostic Services, Inc. / P.O. Box 1369, Stafford; TX 77497 Phone: (281) 431-7100 or (888) 565-9085 Fax: (281) 431-7125 E-mail: PDS@memorylog.com Prudhoe Bay Field Office Phone: (907) 659-2307 Fax: {907) 659-2314 ~~~~ ~/~~ss, • • Correlation of Recorded Damage to Borehole Profile Pipe 1 3.5 in (33.6' - 12023.5') Well: 3H-32 Field: Kuparuk Company: ConocoPhillips Alaska, Inc. Country: USA Survey Date: July 25, 2008 ^ Approx. Tool Deviation ^ Approx. Borehole Profile 1 37 1535 3057 GLM 1 4612 6147 ~; GLM 2 c '- r Y Q.. ~ 7719 GLM 3 9280 GLM 4 10847 388 12024 0 50 100 Damage Profile (% wall) /Tool Deviation (degrees) Bottom of Survey = 388 50 100 150 ~ 200 E L. 0 -' 250 •= ~. • • PDS Report Overview ~. Body Region Analysis Well: 3H-32 Survey Date: July 25, 2008 Field: Kuparuk Tool Type: UW MFC 24 No 214320 Company: ConocoPhillips Alaska, Inc. Tool Size: 1.69 Country: USA No. of Rngers: 24 Ana st: .Thorn son Tubing: Nom.OD Weight Grade & Thread Nom.ID Nom. Upset Upper len. Lower len. 3.5 ins 9.3 f l_-80 EUE 8 RD 2.992 ins 3.5 ins 6.0 ins 0.0 ins Penetration and Metal Loss (°~ wall) ~ penetration body ~ metal loss body 400 300 200 100 0 0 to 1 to 10 to 20 ro 40 ro over 1% 10% 20% 40% 85% 85% Number of'oints anal sed total = 397 pene. 0 82 262 35 18 0 loss 27 369 1 0 0 0 Damage Configuration (body ) 150 100 50 0 isulatcKi beneral line ring hole/pons pitting corrosion corrosion corrosion ible hole Number of ~oints dama ed total = 241 113 127 1 0 0 Damage Profile (% wall) ~ penetration body metal loss body 0 50 100 0 100 GLM 1 _ 198 -_' GLM 2 GLM 3 296 GLM 4 Bottom of Survey = 388 Analysis Overview page 2 • PDS REPORT JOINT TABI. Pipe: 3.5 in 9.3 ppf L~0 EUE 8 RD Well: Body Wall: 0.254 in Field: Upset Wall: 0.254 in Company: Nominal I.D.: 2.992 in Country: Survey Date: • ELATION SHEET 3H-32 Kuparuk Conoco Phillips Alaska, Inc. USA July 25, 2008 Joint No. Jt. Depth (Et.) I'c•n. I ll,~~~t Ilrn.l Pen. Body (Ins.) Peen. %> Mc~lal I oss ,~~ Min. LD• (Ins.) Comments Damage Profile (%wall) 0 50 100 .1 34 tl 0.03 11 I 2.9 PUP 1 37 l) 0.04 1 7 ti 2. 0 hallo corrosion. LL De osits. - 2 74 t ~ 0.02 7 2. 2 3 109 It 0.03 13 2.91 Shall w corrosion. 4 41 tl 0.04 14 7 2.88 Shallow ittin LL De sits. 5 170 (~ 0.04 I' i 2.90 Shallow corrosion. Lt. De osit . 200 U 0.06 .' 3 6 2.92 Corrosion. Lt. De osits. 7 229 l) 0.04 15 (> 2.92 Shallow corrosion. 8 259 t) 0. 5 ? 1 5 .90 Corrosio Lt. De o ~ts. 9 288 tl 0.02 ~~ 2 2.91 10 317 tt 0.03 13 ? .91 Shallow ittin L . e sits. 11 347 t~ 0.04 1.7 I 2.89 Sha low ittin . 12 376 U 0.05 I') 2.92 Shallow corrosion. 13 404 a 0.04 1(, 2.93 Shallow corr sion. 14 434 U 0.0 I (~ 91 Shallow corrosion. 15 464 U .04 1 E, -1 2.90 Shallow corrosion. LL De osits. 16 4 U 0.03 13 .' 2.91 Sh Ilow ~ttin . 16.1 522 (t 0 U tl 2.88 DS Ni (e 17 524 !~ 0.04 17 ~ 2.90 Shallow corrosion. Lt. De o its. 18 553 t~ 0.06 22 5 2.92 Corrosion. 19 583 U 0. 4 14 ? 2.91 Shallo ittin Lt. De sits. 20 613 U 0.04 17 _' 2.90 Shallow corm ion. Lt. De osits. 21 643 U 0.0 'U 3 2.91 Shallow corrosion. 22 673 t~ 0.05 21 3 2.89 Corrosion. Lt. De sits. 70 a 0.04 1' .93 Shall i i D i 24 733 t) 0.04 17 4 2.92 Shallow corrosion. 25 764 t) 0.03 l a ~' 2.90 Shallow corrosion. 26 795 t) 0.03 I i _' 2.91 Shallow ittin . 27 826 l) 0.04 15 2.91 Shallow itti Lt. D sits. 28 856 (I 0.04 14 _' 2.91 Shallow ittin . 29 887 U 0.06 ~:~ ti 2.9 Corrosion. Lt. De osits. 30 917 U 0.03 12 2.91 31 947 U 0.04 15 2.91 Shallow ittin . 32 977 tl 0.03 I3 2.91 Shallow itti 33 1009 t I 0.03 I ? 2.91 34 1040 tt 0.06 ~'_' '~ 2.91 Corrosion. Lt. De osits. 35 1069 tt .03 I :> 2.90 Shall w corrosion. 36 1100 l~ 0.04 17 2.91 Shallow ittin . 7 1132 l~ 0.05 2U (, 2.92 Corr sion. Lt De osits. 38 1160 t 1 0.02 ~) _' 2.92 39 1189 O 0.03 1U I 2.91 40 1221 t) 0.03 1 3 I 2.91 Shallow ittin . 41 1252 t~ 0.0 11 _' 2.91 42 1284 t ~ 0.05 2l) 5 2.91 Shallow corrosion. 43 131 t I 0.03 I I ~' 2.90 44 1344 t ~ 0.03 1 ? 1 2.91 45 1376 tt 0.04 14 ~ 2.91 Shallow ittin . 46 1409 t) 0.04 14 2 2.91 ShaNow ittin . 47 1440 0.03 ~ ! ? 2.92 48 1471 0.03 i ! 2.92 _ Penetration Body Metal Loss Body Page 1 ' • • PDS REPORT JOINT TABULATION SHEET ' Pipe: 3.5 in 9.3 ppf L-80 EUE 8 RD Well: 3H-32 Body Wall: 0.254 in Field: Kuparuk Upset Wall: 0.254 in Company: ConocoPhillips Alaska, Inc. Nominal LD.: 2.992 in Country: USA Survey Date: July 25, 2008 Joint No. Jt. Depth (Ft.) I'c~n. Ulx~~( (Ins.) Pen. Body {Ins.) Pen. `%, alel.~l I os `;~, Min. LD• (Ins.) Comments Damage Profile (°~ wall) 0 50 100 49 1503 l) 0.04 17 ~i 2. 1 Sallow corrosion. 5 1535 O 0.03 12 Z 2.9 51 1 61 O 0.06 2:3 6 2. 1 orrosion. 2 1590 ~) 0.03 12 _' 2.92 53 1623 U 0.03 1 Z I 290 54 1653 (1 0.03 11 2.91 55 1684 ~~ 0.05 19 -1 2.92 Shallow ittin . 56 1716 t ~ 0.03 10 2.90 57 1747 U 0.04 17 2.92 Shallow corrosion. 58 1778 U 0.04 1 b 4 .93 Shallow corr sio . 5 1 9 U 0.05 18 s 2.91 Shallow i 'n . 60 1840 U 0.04 14 ~' 2.90 Shallow itti 6 1870 O 0.03 1 I ~' 2.90 6 1902 c) 0.05 ~(1 .89 Shallow itti 63 193 n .04 17 2.9 ha ow c r osion. Lt. De osi . 64 1965 U 0.04 14 2.92 Sh low ittin . 6S 1997 a 0.03 I1 ~ 2.89 66 0 8 O 0 03 I U s 2.92 67 2060 (J 0.03 12 3 2.91 68 2091 /1 0 03 13 _' 2.91 Salto itti 69 2121 O 0. 2 _' 2.91 70 2153 a 0.03 11 _' 2.89 71 84 ~) 0.02 9 2.91 72 2 16 O 0.02 ~) _' 2.91 7 2 O 0. 3 74 2279 a 0.02 ~) 2.91 75 231 1 U 0.03 1;_' ,' 2.92 76 2342 O 0.03 1:S ~ 2.89 Shallow ittin . 7 374 O 0.03 is 2 91 Sh Ilow ittin . 78 2405 l) 0.02 ~) 2.92 79 437 a 0.03 11 ~ 2.91 80 2468 O 0.03 10 2 2.92 8 2500 t) 0.03 1 ~ Z 2.91 Sha low i tin . 82 2531 l) 0.04 15 .' 2.91 Shal ow corrosion. Lt. De osits. 8 2560 O 0.03 1 ~ ~ 2.9 84 2592 t) 0.06 12 ' 2.90 Corrosion. Lt De osits. 85 2621 O 0.04 17 7 2.90 Shallow ittin . Lt. De sits. 86 2649 (~ 0.03 I , 2.90 Shallow ittin Lt. De sits. 87 2680 ii 0.05 ?1 2.92 rrosion. Lt. De osits. 88 2710 t) .05 ~u - 2.91 Corrosion. Lt. De osits. 89 2739 ~) 0.04 17 ~' .91 Shallow corr Sion. osi 90 2767 O 0.06 2 ; 4 2.91 Corrosion. Lt. De osits. 91 2797 U .06 24 5 2.90 Corrosion. 92 2826 (~ 0.04 17 ~ 2.92 Shallow corrosion. Lt De osils. 93 2856 U 0.05 ~?il i, 2.91 Shallo corrosion. 94 2884 t) 0.05 Zi) ~ 2.92 Corrosion. 95 2913 (~ .0 11 ti .91 Cor osion. L . De osits. 96 2942 U 0.04 17 ~' 2.89 Shallow ittin . Lt. De sits. 97 2972 t) 0.05 .'l) (, 2.91 C rrosion 98 3000 (~ 0.05 :'U 2.91 Corrosion. Penetration Body Metal Loss Body Page 2 PDS REPORT JOINT TABI. Pipe: 3.5 in 9.3 ppf L-80 EUE 8 RD Well: Body Wall: 0.254 in Field: Upset Wall: 0.254 in Company: Norninal I.D.: 2.992 in Country: Survey Date: ELATION SHEET 3Fi-32 Kuparuk ConocoPhillips Alaska, Inc USA July 25, 2008 Joint No. Jt. Depth (Ft.) I'~~n. lJl~u~t (In~.j Pen. Body (Ins.) Nc~n. % alct.il los. `i~~ Min. LD• (Ins.) Comments Damage Profile (%wall) 0 50 100 99 30 8 It 0. 4 14 ? 2.89 Shallow ittin . 100 3057 U 0.04 1 5 -1 2.90 Shallow corrosion. t. a sits. 10 3086 U 0.04 17 ~ 2.91 Shallow corrosi n. 102 3115 U 0.04 1 ? 2. 0 Sh Ilow ittin Lt. De sits. 103 145 ~ t 0 03 1 1 I 2.88 104 3175 tt 0.06 13 -1 2.90 Corrosion. 10 2 3 U 0. 4 14 ~ 2.93 Shallow ittin . 106 3233 a 0.05 <ll (, .90 Corr si n. 1 7 3261 tt 0.06 ~3 2.91 C rr s'on. Lt. D osi 10 3292 U 0.06 22 5 2.9 Corrosi n. 1 9 332 It 0.04 1 5 -1 2.91 hal w tort si n. 110 3354 a 0. 4 16 2.88 Shallo orro i Lt. De o 'ts. 111 33 3 t t 0.03 1 ~) _' 2.90 112 3414 a 0.03 1 > 2.89 Shallow ittin . 113 444 a 0.02 ~) .90 114 3474 (1 0.03 Il _' .90 115 3506 U 0.03 1:3 ~' .92 Shallow corrosion. 116 3 38 U 0.04 16 2.90 Shallow ittin . 117 3569 tt 0.03 13 2.91 Shallow ittin . 117.1 3600 U 0.04 17 I 2.88 P P Shallow corrosion. Lt. De sits. 117. 3606 t) 0 0 t? N A LM 1 Latch ~ 4:00 117 3613 lt.116 0. 3 11 s 8 PUP 11 3619 It 0.03 12 i .92 Sh Ilow ittin . 119 3650 t) 0.04 17 ~ 2.91 Shallow ittin . 1 0 3 2 O 0.03 13 h l o ~ tin . 121 3713 1 t 0.03 1 Z 1 2.92 122 3745 ct 0.03 13 2.90 Shallow ittin . 123 3776 tt 0.04 14 2.90 hallow ittin . 1 3807 tt 0.0 1:~ 2. 1 Shallow ittin . 125 3839 (t 0.03 13 2.92 Shallow itUn Lt. De osits. 12 871 (1 0.04 15 .89 h~ II w it ~n . 127 3901 tt 0.03 10 I 2.91 1 3932 ct 0.04 16 2.91 Ilow corrosion. 129 3964 tt 0.03 1l) _' 2.91 1 0 3994 O 0.03 11 t, 2.93 131 40 4 t t 0.02 ~3 2.89 132 4056 t t 0.03 I 1 _' 2.90 133 4084 t t 0.03 1 t t I 2.90 134 4114 t t 0.03 1 l1 1 2.90 135 4146 t t 0.04 15 t 2.90 Shallow 'tti 1 6 4178 (t 0.03 13 -1 2.91 h Ilow corrosion. 137 4209 tt 0.04 14 ~ 2.90 Shallow corrosion. 138 4239 O 0.04 15 .9 Shall w itti 139 4270 c? 0.04 14 -l 2.93 Shallow itti 140 4 02 t 1 0.03 11 i 2 89 141 4333 l1 0.03 13 ? 2.91 Shallow 'ttin . 142 4364 (t 0.02 9 ? 2.89 143 4395 t1 0.03 12 4 2.89 144 4426 ! ~ .04 1-1 .91 hallow corrosion. 145 44.18 ~' 0.05 1 2.91 Shallow corrosion. Penetration Body Metal Loss Body Page 3 ~ ~ PDS REPORT JOINT TABULATION SHEET Pipe: 3.5 in 9.3 ppf L-80 EUE 8 RD Well: 3H-32 Body Wall: 0.254 in Field: Kuparuk Upset Wall: 0.254 in Company: ConocoPhillips Alaska, Inc. Nominal I.D.: 2.992 in Country: USA Survey Date: July 25, 2008 Joint No. Jt. Depth (Ft.) I'~~n. i ll>set lln~.l Pen. Body (Ins.) Pen. °o Metal f c>ss °~~ Min. LD• (Ins.) Comments Damage Profile (%wall) 0 50 100 146 448 (~ 0.03 1 ~' ~ ~ 2.91 147 4519 tl 0.04 15 ~ 2.90 Shallo ittin . 148 4550 U 0 03 1 I ? 2. 149 4581 a 0.0 1 tl 1 2.91 1 0 461 U 0.0 ~> _' 2.91 151 4644 U 0.0 I U ~ 2.88 152 4675 t) 0.02 ~~ I 2.91 15 4705 t) 0.04 I (~ 4 .90 Shallow corrosion. 154 4737 1 0.03 11 _' 1 155 4768 U 0.02 ti 1 2.91 15 4798 0 0.02 8 2 2.9 57 4829 t) 0.03 I U 1 2 8 158 4861 tt 0.03 11 ~ 2.90 159 4891 U 0.04 -1 7 2.91 Shallow corrosion. 160 4920 t t .0 7 1 2.90 161 4951 a 0.02 9 ~' 2.90 162 49 t t 0.03 1 1 _' 2.90 163 S 15 U 0. 3 1 Z 2.93 64 5045 t ! 0.03 1 1 _' 2.90 165 5077 a 0.03 1U ~ 2.91 166 5109 O 0.04 15 2.91 Shallow corrosion. 167 5140 u 0. 2 ~) I 2. 0 168 5171 t) 0.03 11 ; .89 169 5202 U 0.04 15 ~ 2.91 Shallow corrosion. 170 5235 U 0.0 £3 ' 2. 1 171 5266 tt 0.06 Z3 a 2.90 Corrosion. 172 5294 a 0.03 11 2.88 173 5326 U 0.03 1 ~ ? 2.90 Shallow ittin . 74 5357 i) 0.0 1 U i .90 175 5388 it 0.07 ?t3 s 2.90 Corrosion. Lt. De osits. 176 5418 U 0.03 1 "3 3 2.91 Shallow ittin . 177 5446 U 0.03 11 7 2.89 178 5478 U 0.02 £3 I 2.90 179 5510 t t 0.03 1 Z _' 2.91 180 5541 t~ 0.04 17 4 2.93 Shallow ittin . 181 5570 a 0.05 1 ~) 2.91 Shallow corrosion. Lt. De osits. 182 5601 (t 0.04 14 ~ 2.91 Shallow ittin . 183 5632 t t 0.03 1 I 2.89 184 566 a 0.03 1 t) _' 2.90 185 5694 l1 0.04 17 ~' 2.91 Shallow corrosion. 186 5723 0 0.04 17 3 2 9 Shallow cor son. 187 5753 U 0.03 1O 1 t 2.89 188 5784 U 0.03 1 U 90 189 5816 (~ 0.04 15 2.93 Shallow ittin . 19 5847 t) 0.03 t 1 2.90 191 5880 t1.Ut~ 0.03 1~ 2.90 192 591 1 t~ .04 15 ~, 2.9 Shallow corrosion. 193 5939 tl 0.03 13 ~' 2.91 Shallow ~ttin . 194 5970 0.04 17 ~ 2. 2 Shallow corrosion. 195 5998 0.05 Zt) t~ 2.93 Corrosion. Penetration Body Metal Loss Body Page 4 • . PDS REPORT JOINT TABULATION SHEET Pipe: 3.5 in 9.3 ppf L-80 EUE 8 RD Well: 3H-32 Body Wall: 0.254 in Field: Kuparuk Upset Wall: 0.254 in Company: ConocoPhillips Alaska, Inc. Nominal I.D.: 2.992 in Country: USA Survey Date: July 25, 2008 Joint No. Jt. Depth (Ft.) 1'c•n. 111,x1 (inc.) Pen. Body (Ins.) Pc~n. % ~~•t,rl Icxc `9., Min. LD• (Ins.) Comments Damage Profile (%wall) 0 50 100 196 6026 ~~ 0.03 12 -1 2.91 197 6058 11 0.04 15 ~' 2.89 Shallow it ~n . 198 6086 U.t)b 0.04 16 <' 2.91 hallow ittin . 199 61 7 t1 0.05 1 £3 a 2.91 Shal ow corrosion. Lt. De sits. 00 6 47 0 0.04 15 ' .92 Shallow ittin . 201 6178 (~ 0.0 1 1 1 1 2 621 t~ 0.04 16 4 0 Shall ittin . 03 6 39 ! ~ 0.04 16 5 2.91 Shallow c rr sion. 2 4 6 76 (a 0.04 15 2 2.90 Sh II w ~tti Lt. De sits. 205 6307 U 0.04 17 Z .90 Sh Ilow ittin . 06 6338 a 0.04 15 <' .92 Shallow c rosion. 07 6369 U 0.04 I b (, .89 Shallow corrosion. 08 640 !) .04 1~ 4 2.90 Shallow orrosio . 09 6432 (t 0.05 1 t1 ~ 2. 9 Shallow ittin . 10 6463 (~ 0.04 14 i 2.89 Shallow itti 211 6495 ~_t 0.04 1' 1 .91 Shallow 'tti 212 525 U 0.04 1 ~ 1 2.90 Shallow corrosion. 13 6557 U 0.04 I ,' 2 89 Sall ittin . 14 6588 a 0.04 17 _' 2.91 Shal ow rr sion. 15 66 9 0 0.04 1 i 2.90 Shallow ~ttin . 216 6651 (~ 0.04 I?3 2.9 Shallow orrosion. 17 6682 U 0.05 ' I t .91 Isolat d ittin . 18 6714 ~~ 0.07 l(~ t 2.90 C rro io . 219 6745 tl 0.05 1U i .91 Shallow corrosion. Lt. De sits. 220 6775 t1 .0 ' i ~1 2.91 Corr sion. t. De s 221 6807 O 0.04 1 i i 2.90 Shallow ittin . 222 6839 tt 0.05 20 4 .91 C rrosion. 22.1 6870 U 0.04 15 I 2.88 PUP Shallow it6n . 22 .2 6876 11 0 (1 U N A GLM 2 atch ~ 4.00 222.3 6881 u.1 _' 0.04 14 1 2.89 PUP Shallow ittin . 3 6888 U 0.09 ~~ .91 orrosion. t. a osits. 224 6920 l1 0.10 3£1 !, 2.90 Corrosion. Lt. De osits. 2 5 6950 t1 0.12 46 (~ 2.91 Corro i . De osits. 226 6982 U.0' 0.10 40 2.91 Corrosion. Lt. e osits. 27 7013 U.0 ~ 0.13 50 ') .91 Corrosion. Lt. De osits. 228 7045 tl.l)6 0.11 4a 7 2.91 Corrosion. Lt. De osits. 29 7076 0 0.15 59 I U 2.91 Corrosio Lt D o its 230 7107 (1.Uti 0.10 3~> - 2.89 Corrosion. Lt. De osits. 231 7137 0 0.14 54 2.89 Corrosio t. e o its 232 7168 t) 0.14 5E~ ti 2.90 Corrosion. Lt. De sits. 3 72 0 t1 0.14 54 v 2.90 C rrosi Lt. De sits. - 234 7231 I) 0.16 b3 11 2.90 Corrosion. Lt. De osits. 35 7261 U 0.10 4U - 2.91 or o ion. Lt. De osits. 236 7292 U 0.16 (,Z t; 2.89 Corrosion. Lt. De osits. 37 73 3 U.U~? 0.1 ~8 t~ .90 Cor osio Lt. e 'ts. 238 7355 t~.UO 0.14 5~1 '~ 2.91 Corrosion. Lt. De osits. 239 7383 U 0.11 44 5 2.91 Corrosion. 240 7412 ~~ r11, 0.16 (~-1 2.90 Corrosion. Lt. De osits. 41 7444 0.13 '"~~? ? 2.90 Corrosion. 242 7 76 0.12 a 2.92 Isolated ittin . Penetration Body Metal Loss Body Page 5 • PDS REPORT JOINT TABI. Pipe: 3.5 in 9.3 ppf L-80 EUE 8 RD Well: Body Wall: 0.254 in Field: Upset Wall: 0.254 in Company: Nominal I.D.: 2.992 in Country: Survey Date: ELATION SHEEP 3H-32 Kuparuk ConocoPhillips Alaska, Inc. USA July 25, 2008 Joint No. Jt. Depth (Ft) I'c~n. Ui~,E~t (Ins.) Pen. Body (Ins.) NE~n. % :Metal lus~ ~ Min. LD• (Ins.) Comments Damage Profile (%wall) 0 50 100 243 7506 0.07 .1 46 7 2.90 Corrosion. Lt. De osits. 244 7538 a 0.1 bl ') 2.89 Corrosion. 245 7569 U 0.04 1 b 2.90 Shallow corrosion. 246 7601 U.US 0.14 54 t; 2.90 Lin corro ion. 247 7631 U 0. 9 sa 2. 1 Co rosion. 2 7662 U 0.05 U 2.90 Corrosion. 249 7691 i ~ 0.05 2U E, 2.91 Shall w corrosion. 250 7719 t) 0.0 'b t, 2.88 Corrosion. 251 7750 U 0.05 19 ~ 2.91 Shallow corrosion. 252 7778 t?.l) ~ 0.05 ~0 ~ 2.90 Corrosion. Lt. De osits. 253 7807 ~ ~ 0.05 ~0 -3 2.91 Corrosion. 254 7838 a 0.05 ~U - 2.91 hallow corrosion. Lt. De osi 255 7868 (~ 0.06 ,t4 u 2.91 Corrosion. 256 7897 t) 0.04 1 Ei b 2. 1 Shallow corrosion. 257 7927 tt 0.05 ?0 2.90 Corrosion. Lt. De osits. 258 7956 t) 0.05 21 _' 2.90 Isolated ittin . 259 7 88 0 .03 13 ; 2.90 Shallow ittin . 60 8019 U 0.05 I ~) -t 2.91 Shallow corrosion. Lt. osits. 261 8049 0 0.06 '_' -1 2.90 Corrosion. 262 8078 0 0.06 ~ i 2.89 Isolated ittin . 263 109 U 0.04 14 2.88 Shallow ittin Lt. De sits. 264 8141 U 0.04 1 ~ 2.91 Shallow corrosion. Lt. De osits. 265 8172 t~ 0.04 14 3 2.89 hallow ittin . 266 8203 n 0.03 1 3 ; 2.91 Shallow ittin . 267 8234 0 0.04 1 5 i 90 hallo i ti 268 8266 (~ 0.03 13 2 2.90 Shallow it6n . 269 8298 O 0.05 1 ~) 2.89 Shallow corrosion. Lt. De osi 270 8329 t) 0.04 14 _' 2.90 Shallow ittin . 271 8360 O 0.04 1.5 2.89 Shallow ittin . 272 8388 i) 0.03 1Z 2.92 273 8420 U 0.03 1.; _' 2.89 Shallow ittin . 274 8451 l) 0.04 14 ? 2.90 Shallow ittin . 275 8482 t) 0.04 14 ; 2.90 Shallow ittin Lt. De sits. 276 8514 n 0.04 14 ; 2.88 Shallow ittin . 277 8546 U 0.02 ~) ' 2.89 278 8575 t) 0.04 14 _" 2.89 Shallow ittin . 279 8608 t) 0.03 10 ? 2.90 280 8638 t) 0.04 1. 2.91 Shallow corrosion. 281 8670 U 0.02 t3 ~ 2.89 282 8702 U 0.03 11 ; 2.89 283 8732 ) 0. 9 ~' 2.93 284 8764 0 0.05 I Ei ~ 2.90 Shallow ittin . 285 8796 0 0.04 17 ; .89 Sh Ilow ittin . 286 8826 t~ 0.04 to ~' 2.89 Shallow ittin . 287 8858 t> 0.04 I (, ~ 2.89 Shallow ittin . 288 8888 ~~ 0.03 I ; ~' 2.89 Shallow ittin . 289 8919 i ~ 0.04 16 _' 2.90 Shallow ittin . 290 8951 ~) 0.04 15 2.88 Shallow ittin . 291 8982 t) 0.04 1-t ~' 2.88 Shallow ittin . 292 9012 U 0.05 18 _' 2.88 Shallow ittin t.t. De posits. _ Penetration Body Metal Loss Body Page 6 • PDS REPORT JOINT TABI. Pipe: 3.5 in 9.3 ppf L-80 EUE 8 RD Well: Body Wall: 0.254 in Field: Upset Wall: 0.254 in Company: Nominal I.D.: 2.992 in Country: Survey Date: ~ LATI ON SHEET 3H-32 Kuparuk ConocoPhillips Alaska, Inc. USA July 25, 2008 Joint No. Jt. Depth (Ft.) Pen. Upset Ilns.l Pen. Body (Ins.) Pc~n. %, ~1c~t,~l I offs "-~~ Min. LD• (Ins.) Comments Damage Profile (%wall) 0 50 100 293 9045 ~) 0.04 1(, ? 2.9 hallow corrosion. 294 9074 U 0.04 14 ! 2.91 Shallow ittin . 2 5 9105 U 0.04 16 <' 2.8 Shallow ittin . 296 9137 t) 0.05 1 ~) 4 2.89 Sh Ilo ittin . 297 9168 U 0.05 Wit) 2.89 Shallow corrosio . 298 9198 U 0.06 ,;} 2.89 I o ated ittin . 298.1 9230 U 0.03 lt) ~, 2.88 P P 298.2 9237 t) 0 l) u N A GL 3 Latc @ 12:00 298.3 9242 u.t)5 0.04 15 Z .88 P P S allow ittin . 299 9249 (~ 0.03 12 1 2.90 300 9280 U 0.03 1 3 2.91 Shall w corro ion. a osits. 301 9311 ~ 1 .03 111 _' 2.90 302 9343 U 0. 3 1l) 2.89 303 9374 a 0.03 11 2.90 304 9405 l~ 0.04 14 .' 2.88 Shallow ittin . 30 9436 i ~ 0.04 16 4 2.91 Shallow ittin . 306 9469 U 0.03 11 3 .91 307 9500 t) 0.03 1 Z 4 2.92 308 9531 t) 0.03 1~ _' 2.89 309 9563 l) 0.02 ~~ _' 2.90 ~ 310 9591 ti 0.02 ~~ a 2. 1 311 9622 t) 0.04 I4 2.89 Shallow ittin . 312 9653 t? 0.03 12 2.89 313 9685 ~) 0.02 8 _' 2.89 14 9717 U 0 3 11 .8 315 9746 ~) 0.03 I l ~~ 2.91 316 9779 O 0.04 14 2 2.88 Shallow itGn . 317 9811 ~) 0.03 I<' ~3 2.90 LL De osits. 318 9844 a 0.02 ti 2.93 319 9873 U 0.02 ~~ 2.89 Lt. De osits. 320 9902 ~) 0.03 1 ~) 2.91 L . De osi ts. 321 9931 l1 0.03 13 2.90 Shallow ittin . 322 9963 ~) .04 14 2.91 hallow ittin , 323 9994 t) 0.02 9 _' 2.93 324 10024 ~~ 0.02 9 _' 2.93 325 10055 U 0.02 ~) _' 2.93 326 10087 ~~ 0.02 9 I 2.90 327 10118 ~l 0.03 I I 2.92 328 10151 U 0.03 11 2.90 329 10182 U 0.03 1 U _' 2.88 330 102 0 ~ ~ 0.02 9 _' 2.89 331 10242 t) 0.02 8 _' 2.92 332 10271 U 0.03 1l) a .91 333 10304 t) 0.03 1:3 _' 2.90 Shallow ittin . 334 10335 n 0.02 9 .89 335 10364 t~ 0.03 1~' 2.88 336 10397 U 0.03 l;i _' 2.89 Shallow ittin . 337 10429 U 0.02 8 2.91 Lt. De osits. 38 10459 (~ 0.02 `) 3 2.8 339 10489 U 0.03 1l) ! 2.89 _ Penetration Body Metal Loss Body Page 7 • PDS REPORT JOINT TABI. Pipe: 3.5 in 9.3 ppf L-80 EUE 8 RD Well: Body Wall: 0.254 in Field: Upset Wall: 0.254 in Company: Nominal I.D.: 2.992 in Country: Survey Date: • ELATION SHEET 3H-32 Kuparuk ConocoPhillips Alaska, Inc. USA July 25, 2008 Joint No. Jt. Depth (FtJ I'c•n. tllnE•t (Ins.) Pen. Body (Ins.) I'e•n. `%, ~1~•I.~I I osti `i~~ Min. LD• (Ins.) Comments Damage Profile (%wall) 0 50 100 340 10522 O 0.0 11 ~' 2.90 341 10552 a 0.03 I1 1 .90 3 10582 t) 0.02 ti _' 2.92 343 10613 I) 0 3 l ? .89 344 106 U 0.04 14 ,' .90 Shallow ittin . 345 1 678 U.US 0.02 ~) ' 346 10704 (1.tLi 0.02 ~) 2.91 347 10736 O 0.03 II I 2.91 348 10767 U 0.03 11 ~ 2.91 349 10799 O .02 ~) .93 349.1 10828 U 0.04 1 5 ~ 2.8 PUP al w rros~on. Lt. De i 349.2 108 5 O 0 ~) ~) N A G M 4 Latch @ :00 349.3 10842 U.U~1 0.04 I' .! 2.88 PUP Shal ow corms on. Lt. De sits. 350 10847 u 0 02 ti ? 2.88 351 10878 t) 0.0 I ' Z .89 352 109 0 O 0. 3 I1 ~' 2.88 53 10941 U 0. 3 1 ? 2.89 3 4 10975 O 0.03 13 2.90 Shallow ittin . 355 11004 U 0.06 ~' "3 -1 2.90 Corrosion. 35 11035 l) 0.06 <':.' ~ 2. 9 Corrosion. 357 110 3 u 0.02 t3 _' 2.91 358 1109 O 0.05 1 ~) a 2.89 Sh Ilow corrosion. 3 9 11122 a 0.03 13 ~ 2.90 Shallow 'tti 360 11151 i) 0.05 21 -1 2.91 Corrosion. 61 11 I~ 9 1 362 11209 t ~ 0.05 I ~) ~ 2.90 Shallow corrosion. 36 112 O 0.02 ti 2.88 364 11271 O 0.04 14 1 2.89 Shallow ittin . 365 11 03 ~) 0.02 t3 ? .90 366 11331 ~) 0.03 11 ~ 2.89 367 11363 l) 0. 1 ? 2.91 368 11394 O 0.02 ') ~ 2.89 369 11424 O 0.03 12 _' .88 370 11456 (1 0.03 1 U ~' 2.91 371 11488 O 0.02 9 Z 2.91 372 11520 I> 0.02 ~) 1 2.90 373 115 1 U 0. ~) t 2.92 374 11582 U 0.02 `~ 2.89 375 1161 U 0.03 1 t .89 halo it 376 11645 U 0.03 11 ; 2.90 77 11676 U 0.0 11 i 2.91 378 11709 t) 0.02 9 _' 2.90 379 11740 a 0.03 I i _' 2.88 Sha low ittin . 380 11771 ~) 0.03 I_' I 2.89 38 11 0 11 0 03 I ~) ~ 2.88 382 11834 O 0.02 ~) _' 2.89 83 11866 U 0.03 Il 2.90 384 11896 U 0.03 11 1 2.89 385 119 0.04 I -i 2.89 Sallow ittin . 386 11960 0.03 I. ! 2.88 _ Penetration Body Metal Loss Body Page 8 • PDS REPORT JOINT TABULATION SHEET Pipe: 3.5 in 9.3 ppf L-80 EUE 8 RD Well: 3H-32 Body Wall: 0.254 in Field: Kuparuk Upset Wall: 0.254 in Company: ConocoPhillips Alaska, Inc. Nominal I.D.: 2.992 in Country: USA Survey Date: July 25, 2008 Joint Jt. Depth Pen. Pen. Pen. Met~il Min. Damage Profile No. (Ft.) Upset Body °l~ I ~~ss LD• Comments (%wall) (Ins.) (Ins.) ~~ (Ins.) 0 50 100 387 11992 ~ ~ 0.03 1 Z 2.89 Shallow ittin Lt De sits. 388 1 0 4 ~ ~ 0.02 t) _' .91 _ Penetration Body Metal Loss Body Page 9 _- PDS Report Cross Sections ~~u ~~ .. Well: 3H-32 Survey Date: July 25, 2008 Field: Kuparuk Tool Type: UW MFC 24 No 214320 Company: ConocoPhillips Alaska, Inc. Tool Size: 1.69 Country: USA No. of Fingers: 24 Tubing: 3.5 ins 9.3 ppf L-80 EUE 8 RD Analyst: t. Thompson Cross Section for Joint 240 at depth 7426.87 ft Tool speed = 43 Nominal ID = 2.992 Nominal OD = 3.500 Remaining wall area = 94 Tool deviation = 85 ° Finger 8 Penetration = 0,162 ins Corrosion 0.16 ins = 64% Wall Penetration HIGH 51DE = UP 1r~ u Cross Sections page 1 PDS Report Cross Sections ~ ~~ ,. Well: 3H-32 Survey Date: July 25, 2008 Field: Kuparuk Tool Type: UW MFC 24 No 214320 Company: ConocoPhillips Alaska, Inc. Tool Size: 1.69 Country: USA No. of Fingers: 24 Tubing:_ _ _ 3.5 ins 9.3 ppf L-80 EUE 8 RD Analyst: I. Thomason Cross Section for Joint 234 at depth 7237.83 ft Tool speed = 43 Nominal ID = 2.992 Nominal OD = 3.500 Remaining wall area = 95 Tool deviation = 83 ° Finger 8 Penetration = 0.16 ins Corrosion 0.16 ins = 63% Wall Penetration HIGH SIDE = UP Cross Sections page 2 ConocoPhillips Alaska, tnc. KRU 3H-32 -3 API: 501032032200 Weil T e: PROD A le TS: d NIP (513.514, - SSSV Type: NONE Orig 3/5/2000 Angle @ TD: 84 deg @ 16000 W:3.500) ' Com let ion: 1LBING (0.13666, Annular Fluid: DSUSW Last W/O: 4/15/2000 Rev Reason: Drifted to 12,091' - 00:3.500, hi h deviation 10:2.992) Reference L Ref L Dete: Last U ate: 3222006 Last T : 15956 TD: 16000 ftKB Last T Date: 4/122000 Max Hole An le: 96 d 15329 Casi Strin - A suRF - escr' lion Size To Bottom TVD W Gr Thread cnslNG ~ CONDUCTOR 16.000 0 117 117 62.58 H~0 WELDED (0.47os, OD:9 625 © SURF CASING 9.625 0 4706 299 0 40.00 L-80 BTCM . , we4o.a0) PROD CASING 7.000 0 13809 5913 26.00 L-80 BTCM -- _ LINER 3.500 13639 16000 16000 920 L-80 SLHT Tu in 3tr' -TUBING Size To Bottom TVD Wt Grede Thread 3.500 0 13666 5909 9.30 L-80 EUE 8 RD PROD --- - Pe rations S mm cnslNG Interval TVD Zone Statu s Ft SPF Date T Comment (a136os, 00:7 000 © ~ 14316 - 14660 5940 - 5968 344 4 4/152000 IPERF 2" HSD Power' t 2006 . , wczs.oo> 14730 - 14795 5973 - 5975 65 4 4/152000 IPERF 2' HSD Power 'et 2006 14910 - 15120 5973 - 5971 210 4 4/152000 IPERF 2" HSD Power ' t 2006 15140 - 15155 5971 - 5970 15 4 4/15/2000 IPERF 2" HSD Power ~ t 2006 15180 - 15435 5970 - 5955 255 4 4/15/2000 IPERF 2" HSD Power ' t 2006 15600 - 15830 5956 - 5980 230 4 4!152000 IPERF 2" HSD Power ' t 2006 Gas Lift --- ift Ma rels N N MarareWalva ~-~ St MD TVD Men Men Type V Mfr V Type V OD Latch Port TRO Date Vlv 3 (9237 ~ ® Mfr Run Cmnt ' 1 3604 2601 CAMCO KBMM CAMCO GLV 1.0 BK5 0.156 1298 8/14/2000 2 6872 3748 CAMCO KBMM CAMCO GLV 1.0 BK5 0.188 1328 8/14/2000 3 9237 4576 CAMCO KBMM CAMCO GLV 1.0 BK5 0.188 1321 8/14/2000 4 10873 5144 CAMCO KBMM CAMCO GLV 1.0 BK5 0250 1416 8!14/2000 5 12033 5534 CAMCO MMG2 CAMCO OV 1.5 RK 0250 0 8/13/2000 1 Gas Lirt --- 1. w/check ManCrewahe Other lu ui . ebe. -JEWELRY 4 1os731o67a © , D th TVD T Desc ' 'on ID , OD:5.500) 513 513 NIP CAMCO DS NIPPLE 2.875 12078 5547 NIP HES X NIPPLE 2.813 13632 5909 NIP HES XN NIPPLE 2.635 13666 5909 SEAL BAKER SEAL ASSY 2.992 General No13es GaeLiR ---- -- Date Note MandrewaNe 8/4/2000 Pressure Vested tubin & casin 3000# 5 1203312034, ~~ OD:5.750) - NIP 1207&12079, OD:3.500) NIP 13632-13633, OD:3.500) SEAL 13666.13667, OD:7.000) LINER 13639-16000, 00:3.500, VJt9.20) Pert 14316-14660) Pert - 1473414795) Pert 1491415120) Pert 1514415155) Scblullbel'ger d, 08/22/07 NO. 4384 Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth 2, '7 ZOO7 (;on\\l1i~,s\on Company: Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 1 1fJUt S~<¿O ~\Jb '¡, Field: Kuparuk Well Date Color CD Job# Log Description BL 1R-27 11850425 FPIT ¡q / -/0;;).. 08/18/07 1 31-08 11839638 LDL J"fr(", - rI-h\ 07/28/07 1 2M-19 11813070 INJECTION PROFILE I ,'-,, I~ 1- ~Q 07/29/07 1 3G-26 11813071 LDL Jo,O¡-^~:~ 07/30/07 1 1R-18 11837482 SBHP/DDL 10) J ..: t"I'lS'9- 07/31/07 1 1Y-01 11813072 INJECTION PROFILE U~ - ¡~3 -05""6 07/31/07 1 2C-08 11813073 INJECTION PROFILE' I J..," J1r~ -roA.< 08/01/07 1 3H-32 11837483 LDL .:J¡y-¡ - Ñ·" 08/01/07 1 1Y-10 11837485 INJECTION PROFILE U~ /'7f~ -as- i 08/03/07 1 3G-08 11813075 PRODUCTION PROFILE' /4;() - 0 Ç;,fr 08/04/07 1 1A-06 11837486 INJECTION PROFILE i >"-l" 1"if1-1Il... 08/04/07 1 2N-337B 11837489 PRODUCTION PROFILE . f:}N ~ - If A ~ 08/06/07 1 2U-08 11813076 LDL ~,1c< -^~( 08/06/07 1 1G-12 11837490 PRODUCTION PROFILE 1f¡3 - ~d 08/07/07 1 2N-343 11745232 MEM INJECTION PROFILE . UT(' Jq~ -I"'A:J 08/08/07 1 2N-327 11837491 SONIC SCANNER ~ ~ ...oln '" 08/08/07 1 2N-327 11837491 SONIC SCANNER-FMI ..........'1 ~F L>- 08/08/07 1 3K-01 11632749 PRODUCTION PROFILE . JfffJ:J - lot 08/12/07 1 2X-04 11846430 INJECTION PROFILE (1"U' )"X::o; -IIi'( 08/13/07 1 2Z-29 11850419 SBHP SURVEY /1r7r ':"J:JCJ 08/13/07 1 2X-19 11850420 SBHP SURVEY I O¡ ó - /,,::kÇ 08/13/07 1 1 A-20 11850421 SBHP SURVEY J ~() ~ J(~:J. 08/14/07 1 1F-13 11850422 SBHP SURVEY I) 1C' J~:'2.. -/¿,¡/J 08/14/07 1 1H-10 11846432 SBHP SURVEY Jq~ -~ 08/14/07 1 1Q-10 11846431 SBHP SURVEY 1'1f¿¡ - J0"?r 08/14/07 1 2U-05 11846433 INJECTION PROFILE I ~":I:1". ~-fìl.i<' 08/15/07 1 2D-12 11846434 PRODUCTION PROFILE I fJ£/ -1"A4 08/16/07 1 2H-06 11846435 LDL J~.c; - ¡(ßJ, 08/17/07 1 Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. ';}7J' . . ~-~~....... ~ ., ..... , -.'. ""'\''''\. ..\ MICROFilMED 04/01/05 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE F:\LaserFiche\CvrPgs _ Inserts\Microfilm _ Marker.doc IVIEMORANDUM State of Alaska Alaska Oil and Gas Consenalion Commission TO: Jim Reoo ~ (I P.I. Sup~~'isor K.i trl 7 7. ') (4 [)A TE: Thursday. July 22. 2()Ü-t SlIBJECT: t\1echamcallmegmy Tests BP EXPLOR.A nON (ALASK.AI rNC FROI\I : Lou Grimaldi Pelroleum Inspeclor R-07A PRUDHOE BAY UNIT R-07A Src: Inspector Re\'iewed B~': P.I. Suprv .~f2- Comm NON-CONFIDENTIAL \Vell Name: PRUDHOE BAY UNIT R-07A Insp Num: mnLG040716121-t34 Rellnsp Num: API Well Number: 50-029-20523-01-00 Permit Number: 200-010-0 Inspector Name: Lou Grimaldi Inspection Date: 7/16/2004 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. \Vell I R-07A Type Inj. G TVD I 9097 ! IA 110 ~OÜO 3995 3990 P.T. I 2000 I 00 ,TypeTest SPT Test psi I 2025.25 lOA 110 18U 210 2~O Inter\'al ~YRTST P/F P _Tubing J 1-10 31~ü 31~O 3140 Notes: t\1I injection. Packer 1760 feet abo\'e topofperfs. Thursday. July 22. 200-t Page 1 of I ~ ConocÓPhilli pS Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 May 2, 2004 Mr. Tom Maunder jex j) rrv1 Alaska Oil & Gas Commission ?4 r 5 '/ 0 l-\ 333 West ih Avenue, Suite 10 /1.-\.'-" Anchorage, AK 99501 Dear Mr. Maunder: Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRU). Each of these wells was found to have a void in the conductor by surface casing annulus. The voids were filled with cement to the top of the circulation ports in the conductor. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treatments took place. The top-fill operation was completed on April 29, 2004. Dowell-Schlumberger batch-mixed Arctic Set II cement to 15.7 ppg in a blender tub. The cement was placed in the conductor from the bottom-up via a hose ran to the bottom of the void. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volume used on each conductor. Please call Marie McConnell or me at 907-659-7224, if you have any questions. Sincerely, ~.*\c....«.~y,,-:~.,\<'-.~ (.L,<>\~\o ~~k~¥c-\.~ . \ ~ .~ \- u '<'- ,:I?'-.J....... \ ~~ \ \- \~ C<é Ú'-"-v..~",,-- T -\ö \? +u 'l ~ \ \ \JQ.~ ~l, f~ \ \ ~ «: \\,--,,(( ",,- \- \0 \?~ \: \,~ ~\'-G:~ .~\\~ '-D((\,~ ",~\\.~,,\l,'--'~\.'-.(' Cû~~ \..) c.\ 'ò c- . kt1f1ç(~-G~ ?c~ Jerry Dethlefs ConocoPhillips Problem Well Supervisor Attachment RECEIVED MAY 042004 Alaska Oil & Gas Cans. Commission Anchorage J ., WELL NAME 2C-09 2M-33 3H-21 3H-24 3H-28 3H-32 3K-12 ConocoPhillips Alaska, Inc. Surface Casing by Conductor Annulus Cement Top-off Kuparuk Field April 29, 2004 PTD# SERVICE CEMENT TOP TYPE ft 1842210 Producer 54.0 1960720 Producer 40.0 1880080 Producer 34.0 1960150 Injector 25.0 1960370 Producer 20.0 2000010 Producer 10.0 1861650 Injector 48.0 Arctic Set 1115.7 PPG Cement VOLUME BBLS 9 5 5 3 4 2 10 ,_J"'~"(~ J"'-::; v ~a\;JI.'\. e. ~ Ì::;\ C ì I .J t '^-. ¡ \.-\ I L.. \ J ~ ;) ( '. \ 'J' ~ \ l¡'S \ <Cod. ~ \ ~\ ---'7 ,r;¿.. '-S t\ \ \) -4. ~ ~I 'G" U ,^, "\. - ,,\a.~ 'b'~ y{-\- DATA SUBMITTAL COMPLIANCE REPORT Perm;t to Drill No. 2000010 Well Name/No. KUPARUK RIV UNH' 311-32 5/21/2002 Operator I)IIII,I,IPS AI,ASKA INC. APl No. 50-103-20322-00-00 MD 16000 TVD REQUIRED INFORMATION 60O0 DATA INFORMATION Types Electric or Other Logs Run: Well Log Information: Log/ Data Digital Digital Type Media Format Completion Date 4/15/2000 Completion Status I-OI1. Mud Log No Smnplcs No -- Name R SRVY RPT L DGPJEWR4-MD ? L DGPJEWR4-MD / L DGR/EWR4-TVD / Log Log Run Scale Media No 25 FINAL L DGR/C N PIS LD-TVD~"'"' R SRVY RPT ~ L DGR/CNP/SLD-MD / 25 25 FINAL 25 FINAL 25 FINAL 25 FINAL FINAL ,,T D W~l'~ores/S~n-pi~s' [n~'ormation: ' Interval OII / Start Stop CIi 2973 5999 OH 0 14278 OH 4660 14278 OH 4660 16000 OH 2973 6015 OH O · 5432 6015 OH 74 16000 OH O 11693 14278 OH Current Status I-OII, UIC N Directional Survey (data taken from Logs Portion of Master Well Data Maint) Dataset Received Nmnber Comments 7)6/2000 3/28/2000 SPERRY PB1 6/2912000 PB1 7/6/2000 6/29/2000 PB1 6/29/2000 09567 4660-14236 612912000 PB1 3/28/2000 SPERRY 13804. 7/6/2000 09566 4660-15950 6/29/2000 PB1 Name Interval Start Stop Sent Received Dataset Number Comments ADDITIONAL INFORMATION Well Cored? Y/(~) Chips Receiv~ Daily 1 listory Received? r-~ N Formation Tops Receuived? '~)N Analysis ReceiVed'! £ iN - Comments: Permit to Drill No. 2000010 MD 16000 TVD 6000 Compliance Reviewed By: DATA SUBMITTAL COMPLIANCE REPORT 5/21/2002 Well Name/No. KUI~ARUK RIV UNIT 311-32 Operator PlllLl,lPS ALASKA IN('. Completion Date 4/15/2000 Completion Y, tatus 1-011. ('urrcnt Status Date: APl No. I-O11, 50-103~20322-00-00 [Jl(' N STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown_ Stimulate _X Plugging _ Per/orate 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_X RKB 73 feet 3. Address Exploratory__ 7. Unit or Property name P. O. Box 100360 Stratigraphic_ Anchorage, AK 99510-0360 Service__ Kuparuk Unit 4. Location of well at surface 8. Well number 1044' FNL, 282' FWL, Sec.12, T12N, R8E, UM (asp's498656, 6000613) 3H-32 At top of productive interval 9. Permit number / approval number 1803' FNL, 668' FWL, Sec. 3, T12N, R8E, UM (asp's 488478, 6005142) 200-001 At effective depth 10. APl number 50-103-20322 At total depth 11. Field / Pool 351' FSL, 1708' FWL, Sec.33, T13N, R8E, UM (asp's 488466, 6007297) Kuparuk Oil Pool 12. Present well condition summary Total depth: measured 16000 feet Plugs (measured) Fill Cleanout to (8/8/00) @ 15943' MD. true vertical 6000 feet Effective depth: measured 15943 feet Junk (measured) true vertical 5993 feet Casing Length Size Cemented Measured Depth True vertical Depth CONDUCTOR 117' 16' 90 Sx AS I 117' 117' SURFACE 4633' 9-5/8' 580 Sx AS III Lite & 864 4706' 2989' Sx Class G PRODUCTION 13736' 7' 200 Sx Class G 13809' 5913' LINER 2361' 3-1/2' 440 Sx Class G 16000' 6000' Perforation depth: measured 14316 - 14660'; 14730 - 14795'; 14910- 15120'; 15140 - 15155'; 15180- 15435'; 15600 - 15830' true vertical 5940 - 5968'; 5973 - 5975'; 5973 - 5971'; 5971 - 5970'; 5970 - 5955'; 5956 - 5980' Tubing (size, grade, and measured depth) 3.5', 9.3#, L-80 Tubing @ 13666' MD. , ;;. - £ ..- -- , i ~ :~ ~. :" Packers & SSSV (type & measured depth) No Packer. Camco DS @ 513' MD. ,": i-';- i .. 13. Stimulation or cement squeeze summary Intervals tr~ted (measured) (see attached) ~.,~..~ Treatment description including volumes used and final pressure 14, Representative Daily Avera,qe Production or Injection Data OiFBbl Gas-Mc/ Water-I~l Casing Pressure Tubing Pressure Prior to well operation 250 308 108 135 Subsequent to operation 701 691 380 140 15. Attachments 16. Status of well classification as: Copies of Logs and Surveys run __ Daily Report of Well Operations ._X Oil __X Gas __ Suspended __ Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed j~~-- ~~Title: Datepr e pa~b~lJ~o~n~p e,rce 265. 6471 ,..~,~'~7.~,' l~,y Form 10-404 Rev 06/15/88 · SUBMIT IN DUPLICATE 3H-32 DESCRIPTION OF WORK COMPLETED HYDRAULIC FRACTURE TREATMENT 7/22/00: Tagged PBTD at 15957' MD. 8/6/00: MIRU & PT equipment. Pumped a Hydraulic Fracture Treatment using 20/40 mesh proppant through the perforation intervals located at: 14316-14660' MD 14730-14795' MD 14910-15120' MD 15140-15155' MD 15180-15435' MD 15600-15830' MD Pumped Breakdown stage @ 37 bpm, followed by Shutdown. Saw a good breakback. ISIP @ 1581. Started the Frac Treatment w/2480 bbls Slickwater Pad @ 30 bpm, and took a 2000 psi pressure break. Continued pumping 960 bbls of Crosslinked Pad @ 30 bpm, followed by Gelled Slurry stages w/proppant ramped from I to 8 ppa stages, followed by Screenout with 8 ppa stage at perfs, followed by Shutdown. Placed a total of 228,372 lbs of proppant into the formation. Rigged down. 8/8/00: RIH w/CT & jetted proppant fill from the wellbore to 15943' MD. Returned the well to production w/gas lift & obtained a valid well test. WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Atm.: Loft Taylor 3001 Porcupine Dr. Anchorage, Alaska 99501 MWD Formation Evaluation Logs July 06, 2000 3H-32 , AK-MM-90228 , 1 LDWG formatted Disc with verification listing. API#: 50-103-20322-00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND-RETURNING A COPY OF THE TRANSMITYAL LETTER TO THE A'ITENTION OF: Sperry-Sun Drilling Service Atto: Jim Oalvirl 5631 Silverado Way, Suite G. Anchorage~ Alaska 99518 RECEIVED Datg'Uk 06 20~ Alaska Oil & Gas Cons. Commission knchorage 5631 Silverado Way, Suite G · Anchorage, AK 99518 · 907-273-3500 · Fax: 907-273-3535 a Halliburton company spemry-sun C] R I I_l_l I~ I~ 5ERVICE~ WELL LOG TRANSMITTAL To.' State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Loft Taylor 3001 Porcupine Dr. Anchorage, Alaska 99501 MWD Formation Evaluation Logs 3H-32, AK-MM-90228 July 06, 2000 The technical data listed below is being submitted herewith. Please address any problems or concems to the attention of.' Jim Galvin, Sperry-Sun Drilling Services, 5631 Silverado Way, #G, Anchorage, AK 99518 3H-32: 2" x 5" MD Resistivity & Gamma Ray Logs: 50-103-20322-00 2"x 5" TVD Resistivity & Gamma Ray Logs: 50-103-20322-00 1 Blueline 1 Folded Sepia 1 Blueline 1 Folded Sepia RECEIVED JUL 06 200O Alaska Oil & Gas Cons. Comrnlaalor~ Anchorage 5631 Silverado Way, Suite G · Anchorage, AK 99518 · 907-273-3500 · Fax: 907-273-3535 a Halliburton comDanv DRI/I_I IM ~ SERVIr'E~ WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Loft Taylor 3001 Porcupine Dr. Anchorage, Alaska 99501 June 29, 2000 RE: MWD Formation Evaluation Logs 3H-32PB1, AK-MM-90228 The technical data listed below is being submitted herewith. Please address any problems or concems to the attention of.' Fan Galvin, Sperry-Sun Drilling Services, 5631 Silverado Way, ~G, Anchorage, AK 99518 3H-32PBl: 2" x 5" MD Resistivity & Gamma Ray Logs: 50-103-20322-70 2"x 5" TVD Resistivity & Gamma Ray Logs: 50-103-20322-70 2" x 5" MD Neutron & Density Logs: 50-103-20322-70 2"x 5" TVD Neutron & Density Logs: 50-103-20322-70 1 Blueline 1 Folded Sepia 1 Blueline 1 Folded Sepia 1 Blueline 1 Folded Sepia 1 Blueline 1 Folded Sepia RECEIVED JUN 2 9 000 Alaska Oil & Gas Cons. Commission Anchorage 5631 Silverado Way, Suite G · Anchorage, AK 99518 · 907-273-3500 · Fax: 907-273-3535 a Halliburton company WELL LOG TRANSS~Iq'AL To: State of Alaska June 29, 2000 Alaska Oil and Gas Conservation Comm. Atto: Loft Taylor 3001 Porcupine Dr. Anchorage, Alaska 99501 MWD Formation Evaluation Logs 3H-32PB1 ~ AK-MM-90228 1 LDWG formatted Disc with verification listing. APl#: 50-103-20322-70 PLEASE ACKNOWLEDGE RECEIFF BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETrER TO THE ATYENTION OF: Sperry-Sun Drilling Service Attn: J'un Gal~ 5631 Silverado Way, Suite G. Anchorage, Alaska 99518 RECEIVED Date: dUN 2 9 [000 Signed: Alaska 0ii & Gas Cons. ~ommission Anchorage 5631 Silverado Way, Suite G · Anchorage, AK 99518 · 907-273-3500 · Fax: 907-273-3535 a Halliburton company 6/15/00 Schlumberger GeoQuest 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Sherrle NO. 250 Company: Field: Alaska Oil & Gas Cons Corem Attn: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Prudhoe Bay (Cased Hole) Well Job # Log Description Date Blueline Sepia Color CD Prints B-10 ~ ~COq'~ 20194 RST 000505 1 1 1 F- 10A .'"~. ~' ~ .'~(-F 20247 MCNL 000605 1 1 1 F-1 lA '~,.L d~ ~ ~'-~ 20235 MCNL 000520 1 1 1 H-14A ~ O~J4 ~/.i~ 20183 RST 000416 1 1 1 R-07A -J~ Oj,~.~-' 20161 MCNL 000406 1 1 1 X-16 ~ ~/..~/4~ 20245 RST 000604 1 1 1 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Petrotectnical Data Center MB3-3 900 E. Benson Blvd. Anchorage, Alaska 99519-6612 Date Delivered: RECEIVED JUN 27 2000 Alaska Oil & Gas L;uns. uommissioI1 Anchorage Schlumberger GeoQuest 3940 Arctic Blvd, Suite 300 Received b~ 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 D Suspended D Abandoned D Ser~ce 2. of Operator 7. Permit Number Phillips Alaska, Inc.j~-~,~r~~l ¥~ ! 200-001 $. Address ! ~~, 8. APl Number P. O. Box 100360, Anchorage, AK 99510-0360 ~ 50-103-2032200 /50-103-2032270 4. Location of well at surface ~~ 9. Unit or Lease Name . 1044' FNL, 282' FWL, Sec. 12, T12N, R8E, UM (ASP: 498655.6, 6000612.9) Kuparuk River Unit At Top Producing Interval ~',/..~.. ,~ 10. Well Number 1803' FNL, 668' FWL, Sec. 3, T12N, R8E, UM (ASP: 488478, 6005142) 3H-32 / 3H-32PB1 At Total Depth /,~ 11. Field and Pool - 351' FSL, 1708' FWL, Sec. 33, T13N, R8E, UM (ASP: 488466, 6007296.8) Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) 16. Lease Designation and Serial No. Kuparuk River Pool RKB 29.6' feetI ADL 25524 / 25531 ALK 2655 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. Or A .b.13.b.b.b.b.b.b.b~nd., ,-., ~ 115. Water Depth, if offshore 16. No. of Completions January 19, 2000 February 28, 2000 Ma~ '~'/">/~'~'~ I N/A ,eetUSL 1 17. Total Depth (MD + TVD) 18. Plug Back Depth (MD + TVD) 19. Directional Survey 120. Depth where SSSV set 21. Thickness of Permafrost 16000' MD/5999.6'TVD 15937' MD/5993' TVD YES [~] No [--~I N/A feetMD 1748' (approx) 22. Type Elecb'ic or Other Logs Run MWD/G R/Res/PWD 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BO'FI'OM HOLE SIZE CEMENTING RECORDI AMOUNT PULLED 16' 62.5~ H-40 Surface 117' 24' 90 sx AS I 9.625' 40~ L-80 Surface 4707' 12-1/4' ~580 sx AS III Lite, 864 sx Class G 7' 26~ L-80 Surface 13809' 8-1/2' 220 sx Class G 3.5' 9.3# L-80 13639' 16000' 6.125' 440 sx Class G 24. Perforations open to Production (MD + TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 3.5' 13665' SBE @ 13665' 15830'-15600' MD 5980'-5956' TVD 4 spf 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. 15435'-15180' MD 5954'-5969' TVD 4 spf DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 15155'-15140' MD 5970'-5970' TVD 4 spf N/A N/A 15120'-14910' MD 5971' -5973' TVD 4 spf 14795'-14730' MD 5975'-5974' TVD 4 spf 14660'-14315' MD 5968'-5940' TVD 4 spf 27. PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) May 5, 2000 Flowing Date of Test Hours Tested Production for OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE I GAS-OIL RATIO 5/5/2000 18.0 Test Period > 171 979 35 176I 6389 Flow Tubing Casing Pressure Calculated OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY - APl (con') 118 psi 947 24-Hour Rate > 22.7. - 1305 47 not avaJlable 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and pressence of oil, gas or water. Submit core chips. .-. _~, --L ~ - ' -- ;- ~ .~: ~ ~._',.. "~:} 22 :~ ~5::~. :~-~. ~ r.:.: :_ .. · . Form 10-407 Rev. 7-1-80 CONTINUED ON REVERSE SIDE Submit in duplicate 29. NAME 3H-32 PB1 Top Kuparuk Top C (C4) Top A (Al) Top Miluveach 3H-32 Top Kuparuk Top C (C4) Top A (Al) GEOLOGIC MARKERS MEAS. DEPTH 13830' 13950' 14044' TRUE VERT. DEPTH 5916' 5930' 5947' 5974' 14150' 13837' 14300' 14550' 5915' 5939' 5953' 30. FORMATION TESTS Include interval tested, pressure data, all fluids recovered and gravity. GOR, and time of each pha~se. Annulus left open - freeze protected with diesel. 31. LIST OF A'I-I-ACHMENTS Summary of Daily Operations, Directional Survey 32. I hereby certify that the following is true and correct to the best of my knowledge. Questions? Call Brian Noel 265-6979 Signed ~raham ¢~ Alvor~ Title Ddlling Engineering Supervisor Date % /2"~ I ''~ INSTRUCTIONS Prepared by Sharon AIIsup-Drake General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 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. Shut-in,Item 27:Other_explain.Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water I~jection,i~_~~ ~!~ Gas_ lnjecti?n,~: -~-~ ~-";~' Item 28: If no cores taken, indicate "none". Form 10-407 Date: 03/23/00 ARCO ALASKA INC. WELL SUNfMARY REPORT Page: I WELL:3H-32 STATE:ALASKA COUNTY: NORTH SLOPE WEST FIELD: KUPARUK RIVER UNIT SPUD:0i/!9/00 START COMP: RIG: NABORS 16E BLOCK: FINAL: ___ WI: 0% SECURITY:0 API NUMBER: 50-103-20322-00 01/14/00 (D1) TD/TVD: 117/117 SUPV:FRED HERBERT 01/15/00 (D2) TD/TVD: 117/117 SUPV:FRED HERBERT 01/16/00 (D3) TD/TVD: 117/117 SUPV:BILL PENROSE 01/17/00 (D4) TD/TVD: 117/117 SUPV:BILL PENROSE 01/18/00 (D5) TD/TVD: 117/117 SUPV:BILL PENROSE 117) MW: 0.0 VISC: 0 PV/YP: 0/ 0 APIWL: 0.0 Rig down and move off location. Prep cellar for moving. MW: 0.0 VISC: 0) MOVE RIG TO 3H-32 0 PV/YP: 0/ 0 API%~L: 0 . 0 install spreader beam. Prepare floor to skid. Wait on weather. Phase 2 across field. Prepare ball mill for move. PJSM. Remove cattle chute. Skid rig floor to moving position. MW: 0.0 VISC: 0) MOVE RIG TO 3H-32 0 PV/YP: 0/ 0 APIWL: 0.0 Move rig from iR pad to 3H-32. Stand up BOPs and cradle. Prepare to move camp from iR pad to 3H pad. ~q: 0.0 VISC: 0) R/U TO SPUD 0 PV/YP: 0/ 0 AP!WL: 0.0 Put BOPs on stump. Hang diverter. Install walk arounds and windwalls. Repair hydraulic leak on moving system. Shovel snow out of cellar. Well house in the way of diverter line. Move sub-base away from well. Re-spot sub-base on well. Continue to rig up. Rig accepted 2200 hrs. 1/17/2000. N/U diverter. Mix spud mud. ~{: 8.6 VISC: 112 PV/YP: 24/28 0) GYRO SURVEY AT 252' APIWL: 9.2 N/U diverter system. P/U and make up 5" DP. Rabbit out packed snow. Repair brake water pump. P/U and make up 5" DP. Held pre-spud meeting. Function test diverter. Conduct accumulator drill. P/U HWDP. Steam and rabbit out packed snow. P/U and M/U BHA. Tag ice at 60'. Wash thru ice to 71'. Date: 03/23/00 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 2 01/19/00 (D6) TD/TVD: 978/974 SUPV:BILL PENROSE 01/20/00 (DT) TD/TVD: 1620/1593 SUPV:BILL PENROSE 01/21/00 (D8) TD/TVD: 2770/2736 SUPV:BILL PENROSE 01/22/00 (D9) TD/TVD: 4350/2936 SUPV:FRED HERBERT 01/23/00 (D10) TD/TVD: 4350/2936 SUPV:FRED HERBERT ~: 9.1 VISC: 75 PV/YP: 24/32 APIWL: 7.8 861) DEPTH 1042' MD. RIH W/ NEW BIT (PREVIOUS BIT/MOTOR SE Conduct pre-spud diverter drill. Directionally drill 12.25" surface hole from 117' to 573'. Work on SCR problem. Directionally drill 573' to 978', taking frequent gyro and MWD surveys, had to stop several times to clean gumbo from flowline. MW: 10.0 VISC: 84 PV/YP: 29/31 APIWL: 6.4 642) DRILLING 12-1/4" SURFACE HOLE AT 1950' MD. Directionally drill 12.25" hole from 978' to 1044'. Unable to build hole angle sufficiently to keep up with plan. POOH. Change mud motor bent sub angle. Change to milled tooth bit. RIH. Fill pipe and CBU. Drill from 1044' to 1366'. Held waste manifest training session. Repair electrical problem in ball mill. Drill from 1366' to 1391'. Ball mill overloaded w/sand and gravel. Call out super sucker and pump put. Drill from 1391' to 1461'. Ball mill overloaded w/sand. Pump out w/super sucker. Drill from 1461' to 1620' MW: 10.0 VISC: 69 PV/YP: 26/28 1150) DRILLING AHEAD AT 3169' APIWL: 6.8 Drill and survey 12.25" hole from 1620' to 2770'. CBU with hi-vis sweep. Circulate abundant cutting from hole. Pump dry job. Make wiper trip out to jars. Hole in good condition. RIH. MW: 10.1 VISC: 68 PV/YP: 24/31 1580) POOH FOR HOLE OPENER APIWL: 6.4 Circ bottoms up. Drilling 12.25" hole from 2770' to 3052'. Packing off on connection. Regain circ. Drilling 12.25" hole from 3052' to 4530' MW: 10.0 VISC: 72 PV/YP: 24/33 0) RUNNING CASING APIWL: 6.6 Drilling 12.25" hole from 4530' to 4716'. Circ hi density sweep around. Monitor well. P'mmp dry job & POOH for hole opener. Swabbing @ 2775'. Pump out stds from 2680' to 2490', 2208' to 21!0', 1545' to 1350'. RIH w/hole opener. Bridge 1760' Wash & ream from 1760' to 2208'. Packing off at start. Hole opener plugged. RIH w/hole opener assy to 4625'. Hole opener partially plugged. Wash and ream to bottom ~ 4716'. POOH. Tight spot ~ 2230'. - _.. Date: 03/23/00 01/24/00 (Dll) TD/TVD: 4716/2992 SUPV:FRED HERBERT ARCO ALASKA INC. ~ - .... Page: 3 WELL SUMMARY REPOR~~'~ ~ ~';' ~ ~ -'f '- ~'~ ........ MW: 10.1 VISC: 52 PV/YP: 24/22 366) NIPPLE UP APIWL: 6 . 4 POOH w/hole opener. PJSM. Run 9.625" casing. Circ 1 casing volume ~ 2100'. Run 9.625" casing. Bridge ~ 2760'. Circ thru bridge. PJSM. Pump cement. Bump plug. Check floats. OK. 01/25/00 (D12) TD/TVD: 4716/2992 SUPV:G.R. WHITLOCK MW: 8.5 VISC: 38 PV/YP: 6/10 0) RIH N/U BOPE and test to 250/3500 psi. P/U 5" D.P. APIWL: 12.4 01/26/00 (D13) TD/TVID: 5736/3364 SUPV:G.R. WHITLOCK MW: 8.7 VISC: 38 PV/YP: 13/12 1020) DRILLING e 6300' APIWL: 8.2 RIH to 3500'. Tag strings ~ 4600'. Clean out cement stringers 4600' to 4625'. CBU. Test casing to 1500 psi, OK. Drill float collar e 4626', soft cement to 4657', firm cement to 4706' Drill 20' new hole. Run FIT to 15.9 ppg EMW. Drill from 4736' to 5736'. 01/27/00 (D14) TD/TVID: 7054/3809 SUPV:G.R. WHITLOCK MW: 9.1 VISC: 40 PV/YP: 11/13 1318) DRILLING ~ 7426' APIWL: 7.6 Drill from 5736' to 6475' ECD increased from !0.1 to 11.1, circ sweep around and ECD dropped back to 10.1. Drill from 6475' to 7054'. Circ sweep. Short trip back to shoe w/proper fill. RIH w/no problems. 01/28/00 (D15) TD/TVD: 8706/4378 SUPV:G.R. WHITLOCK MW: 9.2 VISC: 42 PV/YP: 12/15 1652) DRILLING ~ 9200' APIWL: 6.4 RIH. CBU. Drill from 7054' to 8279'. Circ and condition mud to reduce ECD. Drill from 8279' to 8706'. 01/29/00 (D16) TD/TVD:10200/4907 SUPV:G.R. WHITLOCK MW: 9.2 VISC: 40 PV/YP: 10/ 0 1494) DRILLING ~ 10700' APIWL: 6.2 Drill from 8706' to 9500'. CBU 3 times. POOH to 6680'. Good hole fill and no tight spots. RIH to 9411'. CBU to decrease ECD from 10.76 to 10.28. Drill from 9500' to 10200'. 01/30/00 {D17) TD/TVD:l!661/5423 SUPV:G.R. WHITLOCK MW: 9.3 VISC: 39 PV/YP: 9/15 1461) POOH FOR LOT/BHA CHANGE Drill from 10200' to 11661' APIWL: 5 . 8 01/31/00 (D18) TD/TVD:l1754/5450 SUPV:G.R. WHITLOCK MW: 9.3 VISC: 41 PV/YP: 10/15 93) RIH APIWL: 6.0 Drill from 11661' to 11754'. Pump wud sweep. Pump dry job. POOH to 4706'. CBU. Perform LOT to 13.0 ppg. POOH. Test BOPE to 250/3500 psi. Pull test plug. RIH. Date: 03/23/00 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 4 02/01/00 (D!9) TD/TVD:12063/5542 SUPV:G.R. WHITLOCK MW: 10.8 VISC: 46 PV/YP: 14/32 309) DRILLING @ 12420' APIWL: 2 . 6 RIH. Change out saver sub in TDS. Work on topdrive (wouldn't unscrew from pipe). RIH to 6578'. Check out hydraulic problem on TD. RIH. Displace hole w/10.8 ppg GEM mud. Circ and condition new mud. Drill from 11754' to 12063'. 02/02/00 (D20) TD/TVD:!3424/5888 SUPV:G.R. WHITLOCK MW: 10.8 VISC: 44 PV?YP: 18/28 1361) DRILLING e 13850' APIWL: 2 . 8 Drill from 12063' to 12579'. Pump sweep and circ hole clean. Drill from 12579' to 13424'. 02/03/00 (D21) TD/TVD:14278/6022 SUPV:G.R. WHITLOCK MW: 11.6 VISC: 45 PV/YP: 18/26 854) WIPER TRIP APIWL: 2 . 6 Drill from 13424' to 14182' Circ and raise M?{ to i1.0 ppg. Drill from 14182' to 14278'. Circ and raise ~'~ to 114.5 ppg due to high connection gas. Monitor well, hole weeping a small amount. No pit gain while circulating. CBU. Monitor well. Still gassy on BU and flowing slightly while monitoring well. Circ and wt up to 11.6 ppg. 02/04/00 (D22) TD/TVD:14278/6022 SUPV:BILL PENROSE MW: 12.0 VISC: 45 PV/YP: 23/23 APiP~: 2.5 0) PUMPING 18.0 PPG PILL PRIOR TO POH FOR 7" CASING Bring mud weight up from 11.4 ppg to 11.6 ppg and circ all the way around. Shut down and monitor well. Appears dead. Pump dry job. Wiper trip out to 11739'. RIH back to bottom. Circulate around barifiber sweep. Received gas breaking out of mud at bottoms up. Bring mud weight up to 12.0 ppg. Circulate around and monitor well, OK. Pump out a 27-stand wiper trip to 11739' Hole sticky 13580'-13425'. RIH back to bottom. Start CBU to check for gas, keeping ECD at 13.1 ppg. Started experiencing reduced returns. Begin mixing and pumping LCM. 02/05/00 (D23) TD/TVD:14278/6022 ( SUPV:BILL PENROSE MW: 12.0 VISC: 48 PV/YP: 21/32 0) RUNNING 7" CASING (JT. #67 OF 331 RUN) AP!WL: 2.4 Circulate slowly, monitor losses. Hole stands full, losses are all dynamic. Circulate LCM around. Regain full returns. Monitor hole. Standing full. Spot mud pill on bottom. POOH to run casing. Hole tight at 9604' Monitor well at shoe, OK. PJSM. R/U to run 7" casing. Date: 03/23/00 02/06/00 (D24) TD/TVD:14278/6022 SUPV:BILL PENROSE ARCO ALASKA INC. Page: 5 WELL SUMMARY REPORT MW: 12.0 VISC: 50 PV/YP: 22/35 APIWL: 2.8 0)Preparing to cement 7" casing PJSM. Run 7" casing to 9-5/8" casing shoe. Break circulation at surf csg shoe. Repair hydraulic leak on top drive. Run 7" casing to 8200'. Lost circ. Circulate LCM in attempt to regain circulation. Could only get 15% returns. Run 7" casing to 13809' Land out OK. Still only 15% returns. Circ & cond hole for cementing. Still unable to regain more than 15% returns. 02/07/00 (D25) TD/TVD:13089/5840 SUPV:BILL PENROSE MPJ: 12.0 VISC: 49 PV/YP: 23/27 0) TESTING BOPS APIWL: 3 . 6 Circulate slowly, minimal returns. PJSM. Pump cement. Did not bump plug. Regained full circulation during cement displacement. Check floats, OK. Set casing packoff and test to 5000 psi, OK. PJSM. 02/08/00 (D26) TD/TVD:13809/5840 SUPV:FRED HERBERT MW: 12.0 VISC: 48 PV/YP: 22/27 720) RIH, P/U DP Test BOPE, hydril to 250/3500 psi. RIH w/BHA #6. APIWL: 3.5 02/09/00 (D27) TD/TVD:13809/5840 SUPV:FRED HERBERT M?~: 12.0 VISC: 49 PV/YP: 23/26 0) POOH TO SET BACK BHA. APIWL: 5.6 RIH. Tag ~ !3737'. Break circ, circ & cond mud. Drill out plugs, cement to 13780'. Circ for casing test. Test casing to 3500 psi. Drill out cement, shoe (138!3') . 10' cement below shoe, void & stringers after. Wash & ream to 13885'. Lost partial returns after 13323' Circ at reduced rate. Monitor losses. Clean out old hole from 13885' to 14207'. Losses decreasing w/reaming. 02/10/00 (D28) TD/TVD:13809/5840 SUPV:FRED HERBERT MW: 12.0 VISC: 57 PV/YP: 24/29 0) CIRC, WOC APIWL: 7.4 Clean out hole from 14207' to 14278'. Circ bttms up. Monitor returns. Spot LCM. POOH 10 stds to 13375'. CBU. POOH. RIH to 13736'. Circ and cond for plug. Had slight losses w/circ. Spot cement plug. Pump cement. POOH slow to 13800' Circ. 02/11/00 (D29) TD/TVD:13809/5840 SUPV:FRED HERBERT MW: 10.9 VISC: 46 PV/YP: 17/29 0) WELL SHUT IN MONITOR PRESSURE INCREASE. APIWL: 5 . 6 Circ & cond mud ~ 13800'. Rotate and recip pipe. RIH tag cement ~ 14008'. Circ & cond mud for 2nd cement plug. PJSM. Spot cement plug. POOH slow to 13444'. Circ& cond mud. Lower weight to 10.8 ppg. Monitor well, pump slug. POOH. Date: 03/23/00 ARCO ALASKA INC. WELL SUMlVLARY REPORT Page: 6 02/12/00 (D30) TD/TVD:13809/5840 SUPV:FRED HERBERT ~: 10.8 VISC: 43 PV/YP: 18/29 0) CIRC THRU CHOKE ~ 13448' APIWL: 5.8 POOH to 4416' DP came wet on std 47. Continued to flow f/DP. Install safety valve and shut, started to flow f/annulus. Shut in well & monitor pressure. Bleed off pressure & monitor well, flowing ~ 1.5 bph. Flowing out DP & annulus dropping. Shut in DP & well began flowing f/annulus. Shut in well & monitor pressure. Circ thru choke & degasser. PJSM. Strip in hole to 5765'. PJSM. Continue stripping in hole to 8995'. Circ thru choke & gas buster. Strip in hole from 8995' to 11055' 02/13/00 (D31) TD/TVD:13809/5840 SUPV:FRED HERBERT MW: 11.7 VISC: 56 PV/YP: 29/36 0) POOH FOR DRILLING ASSY APIWL: 4.8 Strip in hole to 13448' Circ thru choke & gas buster. Bleed off circ pressure, shut in & monitor. OPen annular & circ out gas cut mud. Circ & cond mud. Raise weight to 11.3 ppg. Rig & tag cement top ~ 13503'. Circ & cond mud. Raise mud wieght to 11.7 ppg. Monitor well, no flow. POOH. 02/14/00 (D32) TD/TVD:13809/5840 SUPV:FRED HERBERT MW: 11.7 VISC: 55 PV/YP: 28/37 0) CIRC ~ 13500' APIWL: 4.6 Pump out of hole to 8740' Monitor well, pump dry job. POOH, slow. Test BOPE to 250/5000 psi. Hydril would not test. PJSM. Change out element in Hydril. Test safety valves. 02/15/00 (D33) TD/TVD:I3915/5924 SUPV:FRED HERBERT MW: 11.7 VISC: 50 PV/YP: 23/24 106) KICKING OFF ~ 13955' APIWL: 4.0 RIH, slow. CIrc & cond mud. Clean out cement from 13516' to 13840'. Begin kick off ~ 13840'. Drill from 13840' to 13910'. Run FIT to 13.0 ppg. Drilling from 13910' to 13915'. 02/16/00 (D34) TD/TVD:14090/5923 SUPV:FRED HERBERT MW: 11.7 VISC: 45 PV/YP: 19/33 175) DRILLING AHEAD APIWL: 3.8 Drilling from 13915' to 14011'. Problems getting survey. Work pipe cycle pumps. Survey. Drilling from 14011' to 14090'. 02/17/00 (D35) MW: 11.7 VISC: 47 PV/YP: 19/29 APIWL: 3.4 TD/TVD:14401/5952 ( 311) POOH FOR BIT, PUMP OUT SUPV:FRED HERBERT Drilling from 14090' to 14108'. Circ hi density sweep around. Drilling from 14108' to 14401'. Date: 03/23/00 02/18/00 (D36) TD/TVD:14401/5952 SUPV:FRED HERBERT 02/19/00 (D37) TD/TVD:14542/5952 SUPV:FRED HERBERT 02/20/00 (D38) TD/TVD:14777/5975 SUPV:FRED HERBERT 02/21/00 (D39) TD/TVD:15258/5967 SUPV:FRED HERBERT 02/22/00 (D40) TD/TVD:15310/5967 SUPV:G.R. WHITLOCK ARCO ALASKA INC. WELL SUMMARY REPORT Page: 7 MW: 11.7 VISC: 46 PV/YP: 19/31 0) RIH, SLOW APIWL: 3.6 Drilling from 14401' to 14488'. Pump hi density sweep around for trip. POOH. Pump out of hole to 9800'. PJSM. Monitor well. POOH. RIH slow. MW: 11.7 VISC: 47 PV/YP: 20/30 141) MONITOR WELL. APIWL: 3.4 RIH slow. CBU. RIH slow. High winds swung boom line into fast line. Secure. RIH slow. PJSM. Circ slow. CBU. Gas cut mud to surface. Drilling from 14488' to 14542'. Lost 90% returns $ 14542'. Slow pump rate & attempt to regain full circ. Begin mixing LCM pill. Pump out to shoe w/reduced pump rate. Monitor well losses. RIH slow to 14493' fill pipe drop ball & circ ball to PBL sub. Open PBL sub & pump LCM pill. MW: 11.7 VISC: 44 PV/YP: 20/28 235) DRILLING APIWL: 4.4 Circ out LCM pill. Too much gas ~ surface to stop pumping to spot pill. Spot LCM pill. POOH to shoe. Circ ~ shoe. Squeeze away LCM w/ECD's. No gas on bttms up. Monitor well, fluid static. RIH to 14494'. CBU. Spot LCM pill. POOH to shoe. Circ & squeeze LCM pill. Drilling from 14452' to 14777'. MW: 11.7 VISC: 46 PV/YP: 20/32 APIWL: 3.6 481) CIRC STICKLESS BEADS AROUND BHA TO HELP SLIDING. Drilling from 14777' to 14969'. Circ hi density sweep around. Drilling from 14969' to 15258'. Circ hi density sweep around for wiper trip. Monitor well. Wiper trip to shoe. Pump out. MW: 11.7 VISC: 48 PV/YP: 22/34 52) POOH APIWL: 3.6 Pump out of hole to shoe. Table top drill on confined space entry. RIH, hit small bridge e 14290'. CBU. Drill from 15258' to 15310'. Motor stalling. CBU. Pump out of hole from 14973' to 13724'. Tight spots @ 14230' to 13900'. Moni5or well. Pull 2 stands hole swabbing. CBU, small amount of gas on bottoms up. RIH. Ream thru bridge ~ 14301'. Pipe displacement correct on trip in hole. CBU. Date: 03/23/00 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 8 02/23/00 (D41) TD/TVD:15310/5967 SUPV:G.R. WHITLOCK 02/24/00 (D42) TD/TVD:15310/5967 SUPV:G.R. WHITLOCK 02/25/00 (D43) TD/TVD:15310/5967 SUPV:G.R. WHITLOCK 02/26/00 (D44) TD/TVD:!5310/5967 SUPV:G.R. ~ITLOCK 02/27/00 (D45) TD/TVD:15630/5956 SUPV:G.R. WHITLOCK 02/28/00 (D46) TD/TVD:16000/5999 SUPV:G.R. WHITLOCK MW: 11.7 VISC: 48 PV/YP: 24/34 0) RIH APIWL: 3 . 6 CBU to check for gas. Pump out of hole~ to 13700'. Monitor well, well flowing but rate decreasing. Pump out of hole to 10200'. Monitor well, well flowing but rate decreasing. Pull 1 stand and well flowed back 1.5 bbl. Pumped out of hole to 8635'. Monitor well, well flowing but rate decreasing. Pump out of hole to 7002'. Hole taking 4.9 bbl for every 5 stands. Monitor well, well flowing 1.5 bbl. Pump out of hole to 5178' Hole taking 4.9 bbl for every 5 stands. Monitor well, no flow. Fluid level dropping in bell nipple very slowly. POOH w/ 20 stands. Monitor well, well flowing ~ .7 bph rate decreasing. MW: 12.3 VISC: 49 PV/YP: 32/34 0) POOH API~L: 2 . 8 Monitor well. POOH 5 stands. Pump out 2 stands and got gas and oil in returns. RIH. Circ at shoe. Barite sag indicated w/mud weights in returns. Circ out gas cut mud. RIH. Circ and increase MW to 12.1. Circ to even out mud. Monitor well still flowing. Circ and increase MW to 12.3. Monitor well, dead. Pump out of hole to shoe. MW: 12.3 VISC: 50 PV/YP: 31/33 0) RIH APIWL: 2 . 8 Monitor well. Circ and shoe. No gas. PUmp out of hole. Safety meeting. Pump out of hole to 3257'. Monitor well. No flow. POOH w/o pumping. MW: 12.2 VISC: 50 PV/YP: 22/34 0) DRILLING e 15360' APIWL: 3.0 RIH. CBU, no gas. RIH. Circ and condition mud. No lost returns. Wash last 50 to bottom w/no fill. CBU. Gradually increase rate. Check for losses. MW: 12.1 VISC: 49 PV/YP: 24/32 320) DRILLING ~ 15725 APIWL: 2.9 Drill from 15310' to 15630'. MW: 12.1 VISC: 51 PV/YP: 23/36 370) RIH ON WIPER TRIP APIWL: 3.0 Drill from 15630' to 16000'. CBU. Pump out of hole to shoe for ~ pass. _ , Date: 03/23/00 02/29/00 (D47) TD/TVD:!6000/5999 SUPV:G.R. WHITLOCK 03/01/00 (D48) TD/TVD:16000/5999 SUPV:G.R. WHITLOCK 03/02/00 (D49) TD/TVD:16000/5999 SUPV:G.R. WHITLOCK 03/03/00 (D50) TD/TVD:16000/5999 SUPV:G.R. WHITLOCK 03/04/00 (D51) TD/TVD:16000/5999 SUPV:G.R. WHITLOCK 03/05/00 (D52) TD/TVD:16000/5999 SUPV:G.R. WHITLOCK ARCO ALASKA INC. WELL SUMMARY REPORT Page: 9 MW: 12.3 VISC: 53 PV/YP: 26/34 0) POOH APIWL: 3 . 0 Make MAD pass while short tripping to shoe. RIH w/no problems. Pump out of hole to shoe. Monitor well. CBU to even out mud weight. Pump out of the hole. MW: 12.3 VISC: 57 PV/YP: 27/35 0) RIH W/ 3-1/2" LINER APIWL: 2.9 Pump out of the hole to 5500'. POOH wet. Hold safety meeting. RIH w/3.5" liner. MW: 12.1 VISC: 52 PV/YP: 22/32 0) CIRC APIWL: 3.2 RIH w/liner. CBU. RIH w/liner to 16000'. Circ and cond. mud. Cut mud weight to 12.1 ppg and shake out LCM. MW: 12.1 VISC: 49 PV/YP: 20/32 0) LAYING DOWN D.P. APIWL: 3.2 Circ and condition mud. Shake out LCM. Safety meeting. Pump cement. Drop plug. Bump plug. Set liner hanger and liner top packer. CBU. Safety meeting. MW: 12.1 VISC: 50 PV/YP: 20/34 0) FREEZE PROTECTING WELL APIWL: 3.4 RIH w/D.P, in derrick. R/U to run tubing. Hold Safety meeting. Run 3.5" tubing and completion jewelry. Verify seal assembly and PBR. R/U and test casing/liner to 3500 psi. Displace mud w/seawater. MW: 0.0 VISC: 50 PV/YP: 0/ 0 0) RIG RELEASED APIWL: 0.0 Displace w/seawater. Test tubing to 3000 psi, OK. Freeze protect 3.5" tubing and annulus w/diesel. N/D BOPE. N/U adapter and lower master valve, test to 5000 psi, OK. Release rig ~ 1600 hrs. 3/5/2000 Date: 05/11/00 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 1 REMEDIAL AND COMPLETION OPERATIONS WELL:3H-32COMP RIG:NORDIC 3 STATE:ALASKA COUNTY: NORTH SLOPE WEST FIELD: KUPARUK RIVER UNIT BLOCK: SPUD:04/12/00 START COMP:04/ll/00 FINAL: WI: 0% SECURITY:0 API NUMBER: 50-103-20322-00 04/11/00 (C!) TD:16000' PB:15937' 04/12/00 (C2) TD:16000' PB:15937' 04/13/00 (C3) TD:16000' PB:15937' 04/14/00 (C4) TD:16000' PB:15937' 04/15/00 (C5) TD:16000' PB:15937' POH W/ 3.5" TBG. MW:12.0 BRINE SUPV:M.C. HEIM Rig move from iD pad to 3H pad. Move over well and level rig. Accept rig $ 16:00 hrs 4/11/00. N/U bope and function test bope to 250/3500#. CIRC. CAPACITY OF WELL VO MW:12.0 BRINE SUPV:M.C. HEIM Displace well to brine. Bottoms up had 6 ppm H2S $ shakers-close annular & circ thru gas buster till hole clean. Reverse circ 2 tbg volumes. PJSM.RIH with 2-1/16" cs hydril. RIH w/3.5" tubing. RUNNING IN HOLE W/ PERF G MW:12.0 BRINE SUPV:M.C. HEIM Continue running in hole w/2-1/16" and 3.5" clean out string. Tag landing collar $ 15952' tubing measurements. Reverse circ out drilling mud in 3.5" liner. Circ and filter brine. Spot hi-vis perforation pill in 3.5" liner. POH 3.5" tubing. PJSM. RIH with 2-1/16" tubing. RUNNING COMPLETION. MW:12.0 BRINE SUPV:M.C. HEIM RIH w/perforating assembly on 3.5" tubing. Tag top of liner $ 13666'. PJSM. Fire guns. POH w/perforating guns. PJSM. Lay down perforating guns. MOVING RIG F/ 3H PAD TO 1 MW: 8.5 SW SUPV:M.C. HEIM Continue laying down perf guns, all shots fired. RIH w/3.5" completion. Set BPV. Environmental awareness meeting. N/D BOPE. N/U tree and test packoff to 5000#. Test tree to 250/5000#. Freeze protect well. Rig released @ 00:00 hrs. 4/16/00. North Slope Alaska Alaska State Plane 4 Kuparuk 3H 3H-32 Surveyed: 28 February, 2000 SURVEY REPORT 23 March, 2000 Your Ref: AP1-501032032200 Surface Coordinates: 6000612.94 N, 498655.63 E (70° 24' 46.4710" N, Kelly Bushing: 73. lOft above Mean Sea Level 150°00'39.4132"W) survey Ref: s vy9 ! 45 Sperry-Sun Drilling Services Survey Report for 3H-32 Your Ref: API-501032032200 Surveyed: 28 February, 2000 North Slope Alaska Measured Depth (ft) Incl. Azim. Sub-Sea Depth (ft) Vertical Local Coordinates Depth Northings Eastings (ft) (ft) (ft) 13804.74 86.380 347.910 5840.06 5913.16 13840.00 86.740 348.650 5842.18 5915.28 13855.17 85.040 347.770 5843.26 5916.36 13887.20 83.970 348.960 5846.33 5919.43 13920.59 85.070 349.550 5849.52 5922.62 13952.10 87.850 351.930 5851.46 5924.56 13985.82 90.120 355.080 5852.06 5925.16 14019.42 90.740 358.610 5851.81 5924.91 14048.93 89.320 359.900 5851.79 5924.89 14081.41 86.860 359.810 5852.88 5925.98 14113.84 86.000 0.490 5854.90 5928.00 14144.88 86.520 358.970 5856.92 5930.02 14176.95 86.640 359.530 5858.83 5931.93 14209.12 87.200 0.380 5860.56 5933.66 14240.48 87.450 0.100 5862.03 5935.13 14272.35 86.550 0.790 5863.69 5936.79 14304.05 84.890 1.350 5866.06 5939.16 14336.52 83.020 1.990 5869.48 5942.58 14368.91 83.030 2.770 5873.41 5946.51 14401.11 84.490 2.600 5876.91 5950.01 14428.97 86.420 0.290 5879.12 5952.22 14433.29 86.800 0.030 5879.38 5952,48 14465.28 89.450 359.860 5880.42 5953.52 14499.75 89.520 0.600 5880.73 5953.83 14528.99 86.960 0.420 5881.63 5954.73 Alaska State Plane 4 Kuparuk 3H 23 March, 2000 - 11:16 Global Coordinates Dogleg Vertical Northings Eastings Rate Section (ft) (ft) (°/100ft) (ft) Comment 4495.82 N 10171.37W 4530.28 N 10178.51W 4545.09 N 10181.61W 4576.32 N 10188.04W 4608.97 N 10194.23W 4640.01N 10199.29W 4673.50 N 10203.10W 4707.04 N 10204.95W 4736.55 N 10205.34W 4769.01 N 10205.42W 4801.37 N 10205.33W 4832.35 N 10205.48W 4864.36 N 10205.90W 4896.48 N 10205.92W 4927.81 N 10205.79W 4959.63 N 10205.55W 4991.24 N 10204.96W 5023.51 N 10204.02W 5055.63 N 10202.68W 5087.61 N 10201.18W 5115.37 N 10200.48W 5119.68 N 10200.47W 5151.65 N 10200.50W 5186.12 N 10200.36W 5215.34 N 10200.10W 6005110.59 N 488485.07 E 4497.59 6005145.05 N 488477.93 E 2,330 4532.06 6005159.87 N 488474.84 E 12.612 4546.87 6005191.09 N 488468.42 E 4.984 4578.10 6005223.75 N 488462.23 E 3.735 4610.75 6005254.78 N 488457.17 E 11.604 4641.79 6005288.28 N 488453.37 E 11.513 4675.28 6005321.82 N 488451.52 E 10.666 4708.82 6005351.33 N 488451.15 E 6.501 4738.33 6005383.79 N 488451.07 E 7.579 4770.79 6005416.15 N 488451.16 E 3.378 4803.16 6005447.12 N 488451.02 E 5.166 4834.13 6005479.13 N 488450.61 E 1.783 4866.14 6005511.26 N 488450.59 E 3.161 4898.26 6005542.58 N 488450.72 E 1.196 4929.59 6005574.41 N 488450.98 E 3.557 4961.41 6005606.01 N 488451.57 E 5.525 4993.02 6005638.29 N 488452.52 E 6.084 5025.29 6005670.41 N 488453.86 E 2.391 5057.41 6005702.38 N 488455.37 E 4.564 5089.39 6005730.14 N 488456.07 E 10.784 5117.15 6005734.45 N 488456.08 E 10.652 5121.46 6005766.42 N 488456.06 E 8.301 5153.43 6005800.89 N 488456.20 E 2.156 5187.90 6005830.11 N 488456.47 E 8.777 5217.12 Tie-on Survey Window Point -2- Continued... DrillQuest 1.05.04e Sperry-Sun Drilling Services Survey Report for 3H-32 Your Ref: A PI-501032032200 Surveyed: 28 February, 2000 North Slope Alaska Measured Depth (ft) Incl. Azim. Sub-Sea Depth (ft) Vertical Local Coordinates Global Coordinates Depth Northings Eastings Northings Eastings (ft) (ft) (ft) (ft) (ft) 14562.32 85.460 2.010 5883.83 5956.93 14594.33 82.730 359.540 5887.13 5960.23 14626,50 83.040 0.690 5891.11 5964.21 14658.63 84.090 1.510 5894.71 5967.81 14690.52 85.480 0.850 5897.61 5970.71 14720.82 86.340 1.230 5899.77 5972.87 14752.45 87.670 0.700 5901.42 5974.52 14784.34 89.450 0.480 5902,23 5975.33 14817.00 91.110 359.750 5902.07 5975.17 14848.93 91.570 0.370 5901.32 5974.42 14880.82 91.730 359.020 5900.40 5973,50 14912.47 91.730 359.690 5899.45 5972.55 14944.16 90.650 359.300 5898,79 5971.89 14976.43 90.060 0.410 5898.59 5971.69 15008.41 90.060 359.260 5898.55 5971.65 15040.87 90.060 359.170 5898.52 5971.62 15073.01 90.280 0.440 5898.42 5971.52 15104.49 90.770 0.850 5898.14 5971.24 15138.27 91.290 0.430 5897.53 5970.63 15169,84 91.440 0.070 5896.78 5969.88 15198.80 90.830 359.580 5896.20 5969.30 15231.71 91.110 359.550 5895.65 5968.75 15263.77 92,830 0.280 5894.54 5967.64 15297.80 94.100 358.980 5892.49 5965.59 15328.54 95.520 359.970 5889.91 5963.01 Dogleg Rate (°/100ft) 5248.59 N 10199.40W 6005863.36 N 488457.18 E 5280,42 N 10198.96W 6005895.19 N 488457.62 E 5312.34 N 10198.90W 6005927.12 N 488457.69 E 5344,26 N 10198.29W 6005959.04 N 488458.31 E 5376.01 N 10197.63W 6005990.79 N 488458.96 E 5406.23 N 10197.08W 6006021.00 N 488459.52 E 5437.81 N 10196.55W 6006052.59 N 488460.06 E 5469.69 N 10196.22W 6006084.46 N 488460.39 E 5502.35 N 10196.16W 6006117.12 N 488460.46 E 5534.27 N 10196.13W 6006149.04 N 488460.50 E 5566.14 N 10196.30W 6006180.92 N 488460.34 E 5597.78 N 10196.65W 6006212.55 N 488459.99 E 5629.46 N 10196.93W 6006244.23 N 488459.71 E 5661.73 N 10197.01W 6006276.50 N 488459.64 E 5693.70 N 10197.10W 6006308.48 N 488459.55 E 5726.16 N 10197.55W 6006340.94 N 488459.11 E 5758.30 N 10197.66W 6006373.08 N 488459.01E 5789.78 N 10197.30W 6006404.55 N 488459.37 E 5823.55 N 10196.93W 6006438.32 N 488459.75 E 5855.11 N 10196.79W 6006469.89 N 488459.90 E 5884.06 N 10196.88W 6006498.84 N 488459.81E 5916.97 N 10197.13W 6006531.74 N 488459.57 E 5949.01 N 10197.17W 6006563.78 N 488459.53 E 5982.97 N 10197.39W 6006597.75 N 488459.31 E 6013.60 N 10197.67W 6006628.38 N 488459.04 E 6.551 11.473 3.676 4.137 4.821 3.102 4.526 5.624 5.552 2.417 4.261 2.116 3.623 3.895 3.596 0.277 4.010 2.030 1.979 1.235 2.702 0.856 5.828 5.335 5.625 Alaska State Plane 4 Kuparuk 3H Vertical Section (ft) Comment 5250.37 5282.20 5314.12 5346.O4 5377.79 5408.01 5439.59 5471.47 5504.12 5536.05 5567.92 5599.55 5631.24 5663.50 5695.48 5727.94 5760.08 5791.56 5825.33 5856.89 5885.84 5918.75 5950.79 5984.75 6015.38 Continued... DrillQuest 1.05.04e 23 March, 2000 - 11:17 - 3 - ' Sperry-Sun Drilling Services Survey Report for 3H-32 Your Ref: API-501032032200 Surveyed: 28 February, 2000 North Slope Alaska Measured Sub-Sea Vertical Local Coordinates Depth Incl. Azim. Depth Depth Northlngs Eastings (ft) (ft) (ft) (ft) (ft) Global Coordinates Dogleg Northings Eastings Rate (ft) (ft) (°/100ft) 15360.43 95.240 359.800 5886.92 5960.02 6045.35 N 10197.74W 15393.11 93.940 0.750 5884.30 5957.40 6077.93 N 10197.58W 15425.45 93.080 0.090 5882.32 5955.42 6110.20 N 10197.35W 15457.98 92.310 0.480 5880.79 5953.89 6142.70 N 10197.18W 15489.32 90.030 0.620 5880.15 5953.25 6174.03 N 10196.88W 15521.67 88.280 359.880 5880.63 5953.73 6206.37 N 10196.74W 15553.08 88.550 0.690 5881.50 5954.60 6237.77 N 10196.59W 15585.67 88.800 1.520 5882.25 5955.35 6270.34 N 10195.96 W 15616.79 87.810 2.400 5883.17 5956.27 6301.43 N 10194.89 W 15648.00 85.900 359.830 5884.89 5957.99 6332.58 N 10194.29 W 15681.72 83.780 359.870 5887.92 5961,02 6366.17 N 10194.37W 15713.36 82.260 0.030 5891.76 5964.86 6397.57 N 10194.40W 15744.82 82.230 359.950 5896.01 5969.11 6428.74 N 10194.41W 15777.07 82.650 0.540 5900.25 5973.35 6460.71 N 10194.27W 15809.16 82.940 0.270 5904.28 5977.38 6492.55 N 10194.05W 15840.75 83.030 0.850 5908.14 5981.24 6523.90 N 10193.74W 15873.11 83.220 0.850 5912.01 5985.11 6556.02 N 10193.26W 15904.42 83.320 0.880 5915.68 5988.78 6587.11 N 10192.79W 15936.37 83.590 1.270 5919.32 5992.42 6618.85 N 10192.20W 16000.00 83.590 1.270 5926.42 5999.52 6682.07 N 10190.80W Alaska State Plane 4 Kuparuk 3H Vertical Section (tt) 6006660.13 N 488458.98 E 1~026 6047.13 6006692.70 N 488459.14 E 4,921 6079.71 6006724.98 N 488459.38 E 3,350 6111.98 6006757.47 N 488459.55 E 2,653 6144.48 6006788.80 N 488459.86 E 7.289 6175.81 6006821.15 N 488460.01 E 5.873 6208.15 6006852.54 N 488460.17 E 2.717 6239.55 6006885.12 N 488460.80 E 2.659 6272.12 6006916.21 N 488461.87 E 4.256 6303.21 6006947.36 N 488462.48 E 10.249 6334.36 6006980.94 N 488462.40 E 6.288 6367.94 6007012.35 N 488462.38 E 4.830 6399.35 6007043.52 N 488462.38 E 0.269 6430.52 6007075.49 N 488462.52 E 2.233 6462.49 6007107.32 N 488462.75 E 1.230 6494.33 6007138.67 N 488463.07 E 1.844 6525.68 6007170.80 N 488463.55 E 0.587 6557.80 6007201.89 N 488464.02 E 0.333 6588.89 6007233.62 N 488464.62 E 1.478 6620.63 6007296.84 N 488466.04 E 0.000 6683.85 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 26.501° (18-Jan-00) The Dogleg Severity is in Degrees per 100ft. Vertical Section is from Well and calculated along an Azimuth of 359.990° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 16000.00ft., Comment Projected Survey 23 March, 2000- 11:17 -4- DrillQuest 1.05.04e Sperry-Sun Drilling Services Survey Report for 3H-32 Your Ref: API-501032032200 Surveyed: 28 February, 2000 North Slope Alaska The Bottom Hole Displacement is 12186.15ft., in the Direction of 303.253° (True). Comments Measured Station Coordinates Depth TVD Northings Eastings Comment (ft) (fi) (ft) (ft) 13804.74 5913.16 4495.82 N 10171.37 W Tie-on Survey 13840.00 5915.28 4530.28 N 10178.51 W Window Point 16000.00 5999.52 6682.07 N 10190.80 W Projected Survey Survey tool program From To Measured Vertical Measured Depth Depth Depth (ft) (ft) (ft) 0.00 0.00 16000.00 Vertical Depth Ct) 5999.52 Survey Tool Description MWD Magnetic Alaska State Plane 4 Kuparuk 3H 23 March, 2000- 11:17 -5- DrillQuest 1.05.04e North Slope Alaska Alaska State Plane 4 Kuparuk 3H 3H-32PB1 Surveyed: 3 February, 2000 SURVEY REPORT 23 March, 2000 Your Ref: A PI-501032032270 Surface Coordinates: 6000612.94 N, 498655.63 E (70024, 46.4710" N, 150° 00' 39.4132" W) Kelly Bushing: 73. lOft above Mean Sea Level survey Ref: s vy9143 Sperry-Sun Drilling Services Survey Report for 3H-32PB1 Your Ref: API-501032032270 Surveyed: 3 February, 2000 North Slope Alaska Measured Depth (ft) Incl. Azim. Sub-Sea Depth (ft) Vertical Local Coordinates Depth Northings Eastings (ft) (ft) (ft) 0.00 0.000 0.000 -73.10 0.00 78.00 0.500 275.000 4.90 78.00 169.00 0.500 320.000 95.90 169.00 205.00 0.250 318.000 131.90 205.00 295.00 1.330 314.640 221.89 294.99 320.00 2.000 312.000 246.87 319.97 381.00 3.000 302.000 307.82 380.92 443.00 3.750 297.000 369.71 442.81 474.00 4.250 298.000 400.63 473.73 534.00 5.000 301,000 460.44 533.54 625.00 6,750 307.000 550.96 624.06 715.00 6.750 309.000 640.33 713.43 805,00 6.750 300.000 729.71 802.81 895.00 6.500 295,000 819.11 892.21 927.07 6.060 292.960 850.99 924.09 959.69 6.180 289.360 883.42 956.52 990.33 6.320 285.920 913.88 986.98 1020.64 6.870 282.950 943.99 1017.09 1051.15 7.770 277.750 974.25 1047.35 1082.30 9.180 273.460 1005.06 1078.16 1109.68 10.090 268.890 1032.05 1105.15 1203.46 14.170 264.030 1123.72 1196.82 1299.78 16.680 265.350 1216.57 1289.67 1392.89 16.170 265.130 1305.88 1378.98 1489.01 19.250 266.940 1397.43 1470.53 Global Coordinates Dogleg Northings Eastings Rate (ft) (ft) (°/100ft) 0.00 N 0.00 E 6000612.94 N 498655.63 E 0.03 N 0.34W 6000612.97 N 498655.29 E 0.641 0.37 N 0.99W 6000613.31 N 498654.64 E 0.421 0.55 N 1.14W 6000613.49 N 498654.49 E 0.695 1.43 N 2.02W 6000614.37 N 498653.61 E 1.201 1.92 N 2.55W 6000614.86 N 498653.08 E 2,697 3.48 N 4.69W 6000616.42 N 498650.94 E 1.782 5.26 N 7.88W 6000618.20 N 498647.76 E 1.298 6,26 N 9.79W 6000619.20 N 498645,84 E 1.628 8.65 N 14,00W 6000621.59 N 498641.63 E 1.313 13.91N 21.67W 6000626.86 N 498633.96 E 2.035 20.42 N 30.00W 6000633.37 N 498625.63 E 0.261 26.40 N 38.69W 6000639.34 N 498616.94 E 1.174 31.20 N 47,89W 6000644.14 N 498607.74 E 0.698 32.62 N 51.10W 6000645.57 N 498604.54 E 1.538 33.88 N 54.34W 6000646.83 N 498601.30 E 1.233 34.89 N 57.52W 6000647.84 N 498598.12 E 1.305 35.75 N 60.89W 6000648.70 N 498594.75 E 2.135 36.44 N 64.71W 6000649.39 N 498590.93 E 3.660 36.87 N 69.28W 6000649.82 N 498586.36 E 4.958 36.96 N 73.85W 6000649,91 N 498581.78 E 4.339 35.60 N 93,49W 6000648.56 N 498562.14 E 4.481 33.26 N 119.00W 6000646.22 N 498536.64 E 2.631 31.07 N 145.24W 6000644.04 N 498510.40 E 0.552 29.09 N 174.40W 6000642.06 N 498481.23 E 3.255 Alaska State Plane 4 Kuparuk 3H Vertical Section (ft) Comment 0.00 0.32 1.05 1.27 2.43 3.12 5.72 9.36 11.52 16.34 25.51 35.82 46.22 56.58 60.09 63.56 66.86 70.28 74.04 78.36 82.55 99.79 121.92 144.79 170.40 Continued... DrillQuest 1.05.04e 23 March, 2000 - 10:36 .2 - Sperry-Sun Drilling Services Survey Report for 3H-32PB1 Your Ref: API-501032032270 Surveyed: 3 February, 2000 North Slope Alaska Measured Depth (ft) Incl. Azim. Sub-Sea Depth (ft) Vertical Depth (ft) 1581.46 23.280 267.580 1483.57 1556.67 1675.84 26.730 267.570 1569.09 1642.19 1770.61 32.900 268.830 1651.28 1724.38 1865.36 37.420 274.390 1728.74 1801.84 1960.98 41.680 279.900 1802.48 1875.58 2055.15 46.370 284.710 1870.19 1943.29 2147.89 49.320 288.520 1932.43 2005.53 2244.71 53.430 291,610 1992.87 2065.97 2339.10 57.330 291.580 2046.48 2119.58 2432.62 59.850 290.140 2095.22 2168.32 2527.97 62.890 290.770 2140.90 2214.00 2619.81 66.460 291.470 2180.18 2253,28 2715.06 68.920 291.390 2216.34 2289.44 2817.11 67.140 290.180 2254.52 2327.62 2911.48 71.050 291.110 2288.18 2361.28 3005.20 70.740 291.310 2318.86 2391.96 3103.03 69.800 291.600 2351.88 2424.98 3190.14 69.700 290,980 2382.03 2455.13 3282.86 69.780 289,950 2414.14 2487.24 3376.58 68.820 289,970 2447.27 2520.37 3468.39 69.340 288,720 2480,05 2553.15 3563.94 69.860 287.410 2513.36 2586.46 3657.82 68.750 286.950 2546.53 2619.63 3751.58 68.300 286.870 2580.86 2653.96 3847.83 69.530 287,310 2615.49 2688.59 23 March, 2000 - 10:36 , Local Coordinates Northings Eastings (ft) (ft) Global Coordinates Northings Eastings (ft) (ft) 27.50 N 207.89W 6000640.48 N 498447.75 E 25.81 N 247.74W 6000638.80 N 498407.90 E 24.38 N 294.81W 6000637.38 N 498360.82 E 26.06 N 349.29W 6000639.07 N 498306.35 E 33.76 N 409.62W 6000646.77 N 498246.02 E 47.81 N 473.48W 6000660.83 N 498182.16 E 67.51 N 539.31W 6000680.55 N 498116.33 E 93.50 N 610.31W 6000706.55 N 498045.33 E 122.09 N 682.52W 6000735.15 N 497973.13 E 150.49 N 757.10W 6000763.57 N 497898.55 E 179.74 N 835.51W 6000792.83 N 497820.16 E 209.66 N 912.93W 6000822.76 N 497742.74 E 241.85 N 994.95W 6000854.97 N 497660.72 E 275.44N 1083.42W 6000888.57 N 497572.26 E 306.52 N 1165.90W 6000919.67 N 497489.79 E 338.56 N 1248.46W 6000951.72 N 497407.23 E 372.24 N 1334.16W 6000985.42 N 497321.54 E 401.92 N 1410.31W 6001015.11 N 497245.39 E 432.33 N 1491.80W 6001045.54 N 497163.91 E 462.25 N 1574.20W 6001075.48 N 497081.51 E 490.66 N 1655,12W 6001103.90 N 497000.60 E 518.43 N 1740,26W 6001131.68 N 496915.46 E 544.37 N 1824.16W 6001157.64 N 496831.57 E 569.75 N 1907.64W 6001183.03 N 496748.09 E 596.14 N 1993.48W 6001209.44 N 496662.26 E -3- Dogleg Rate (°ll00ft) 4.366 3.655 6.544 5.842 5.768 6,113 4.403 4.922 4.132 2.998 3.241 3.948 2.584 2.062 4.244 0.387 1.001 0.678 1.046 1,025 1.392 1.396 1.268 0.486 1.347 Alaska State Plane 4 Kuparuk 3H Vertical Section (ft) Comment 200.09 235.51 277.59 327.68 385.63 449.46 517.46 592.80 670.33 749.93 833.35 916.17 1004.12 1098.50 1186.39 1274.76 1366.67 1448.23 1534.95 1622.28 1707.63 1796.54 1883,55 1969,95 2058,91 Continued.,. DrillQuest 1.05.04e Sperry-Sun Drilling Services Survey Report for 3H-32PB1 Your Ref: A PI-501032032270 Surveyed: 3 February, 2000 North Slope Alaska Measured Depth (ft) Incl. Azim. Sub-Sea Depth (ft) Vertical Depth (ft) 3945.00 69.540 287.220 2649.46 2722.56 4037.65 69.690 286.280 2681,73 2754.83 4129.04 68.640 286.660 2714.24 2787.34 4225.05 69.100 287.130 2748.85 2821.95 4318.00 70.030 285.060 2781.30 2854.40 4412.45 68.930 285.630 2814.41 2887.51 4504.55 70.000 285,320 2846.72 2919.82 4600.78 70.210 286.240 2879.47 2952.57 4663,02 69.550 286.270 2900.87 2973.97 4814.06 67.850 290.360 2955.76 3028.86 4906.15 68,860 290.620 2989.73 3062.83 5003.79 68.110 290.390 3025.53 3098.63 5098.98 69.590 290.610 3059.88 3132.98 5193.96 70.220 289.670 3092.51 3165.61 5291.47 69.840 289.280 3125.82 3198.92 5385.60 69.360 288.930 3158.63 3231.73 5475.51 70.170 288.540 3189.72 3262.82 5564.54 69.680 288.040 3220.28 3293.38 5667.20 69.200 288.490 3256.34 3329.44 5758.68 69.940 288.810 3288.27 3361.37 5852,60 69.400 289.430 3320.90 3394.00 5945.90 68.850 289.240 3354.14 3427.24 6040.81 68.360 289.320 3388.77 3461.87 6135.90 69.270 287.790 3423.13 3496.23 6231.18 70,980 287.750 3455.52 3528.62 Local Coordinates Northings Eastings (ft) (ft) Global Coordinates Dogleg Northings Eastings Rate (ft) (ft) (°/100ft) 623.16 N 2080.41W 6001236.47 N 496575.33 E 648.19 N 2163.57W 6001261.52 N 496492.17 E 672.40 N 2245.48W 6001285.75 N 496410.27 E 698.43 N 2331.17W 6001311.79 N 496324.58 E 722.57 N 2414.85W 6001335.94 N 496240.91E 745.98 N 2500.15W 6001359.37 N 496155.61 E 768.99 N 2583.27W 6001382.39 N 496072.49 E 793.59 N 2670.35W 6001407.02 N 495985.42 E 809.95 N 2726.46W 6001423.38 N 495929.32 E 854.13 N 2860.02W 6001467.59 N 495795.77 E 884.10 N 2940.20W 6001497.57 N 495715.59 E 915.92 N 3025.28W 6001529.40 N 495630.52 E 947.01 N 3108.43W 6001560.51 N 495547.37 E 977.72 N 3192.17W 6001591.23 N 495463.63 E 1008.27 N 3278.58W 6001621.80 N 495377.23 E 1037.15 N 3361.94W 6001650.69 N 495293.87 E 1064.24 N 3441,83W 6001677.80 N 495213.99 E 1090.49 N 3521.23W 6001704.06 N 495134.60 E 1120.61 N 3612.51W 6001734.20 N 495043,32 E 1148.02 N 3693.73W 6001761.63 N 494962.11 E 1176.87 N 3776.94W 6001790.49 N 494878.90 E 1205.73 N 3859.20W 6001819.37 N 494796.65 E 1234.91 N 3942.61W 6001848.56 N 494713.24 E 1263,12 N 4026.66W 6001876.79 N 494629.19 E 1290,47 N 4111.99W 6001904.15 N 494543.87 E 0.087 0.965 1.213 0.662 2.314 1.295 1.204 0.925 1.061 2.762 1.128 0.799 1.570 1.142 0.541 0.618 O.989 0.762 0.622 0.873 0.845 0.619 0,522 1.779 1.795 Alaska State Plane 4 Kuparuk 3H Vertical Section (ft) Comment 2149.13 2235.08 2319.56 2408.23 2494.29 2581.50 2666.57 2755.90 2813.67 2953.41 3038.74 3129.31 3217.81 3306.70 3397.92 3485.69 3569.56 3652.61 3748.08 3833.29 3920.90 4007.66 4095.59 4183.70 4272.60 23 March, 2000 - 10:36 -4- Continued... _ . DrillQuest 1.05.04e Sperry-Sun Drilling Services Survey Report for 3H-32PB1 Your Ref: API-501032032270 Surveyed: 3 February, 2000 North Slope Alaska Measured Depth (ft) Incl. Azim. Sub-Sea Depth (ft) Vertical Depth (ft) 6326.35 70.710 287.990 3486.75 3559.85 6426.87 70.160 287.410 3520.41 3593.51 6514.12 69.920 287.540 3550.20 3623.30 6609.88 69.210 288.650 3583.63 3656.73 6702.92 69.900 288.610 3616.13 3689.23 6794.85 69.820 288.410 3647.78 3720.88 6891.49 69.560 289.000 3681.33 3754.43 6983.82 70.600 289.420 3712.79 3785.89 7080.04 70.580 290.010 3744.76 3817.86 7174.93 69.990 290.940 3776.77 3849.87 7268.78 69.560 289.140 3809.22 3882.32 7364.78 69.100 288.890 3843.11 3916.21 7455.17 68.520 288.430 3875.78 3948.88 7548.76 69.090 288.420 3909.62 3982.72 7640.09 69.880 288.080 3941.62 4014.72 7737.13 69.460 288.790 3975.34 4048.44 7832.09 69.800 288.070 4008.39 4081.49 7924.91 70.360 287.850 4040.01 4113.11 8019.24 69.800 287.230 4072.15 4145.25 8111.73 69.050 287.810 4104.66 4177.76 8200.20 70.240 287.980 4135.43 4208.53 8303.94 69.740 288.280 4170.93 4244.03 8397.70 69.090 288.220 4203.89 4276.99 8493.99 69.940 288.580 4237.59 4310.69 8589.00 69.240 288.940 4270.73 4343.83 Local Coordinates Northings Eastings (ft) (ft) 1318.05 N 4197.55W 1346.85 N 4287.79W 1371.48 N 4366.01W 1399.35 N 4451.30W 1427.20 N 4533.92W 1454.60 N 4615.76W 1483.66 N 4701.60W 1512.22 N 4783,57W 1542.84 N 4869.01W 1574.08 N 4952.69W 1604.26 N 5035.42W 1633.52 N 5120.33W 1660.49 N 5200.18W 1688.07 N 5282.97W 1714.86 N 5364.20W 1743.63 N 5450.53W 1771.77 N 5534.98W 1798,68 N 5618.00W 1825.41 N 5702.56W 1851.47 N 5785.13W 1876.96 N 5864.06W 1907.29 N 5956.70W 1934.78 N 6040.06W 1963.25 N 6125.65W 1991.89 N 6209.96W Global Coordinates Dogleg Northings Eastings Rate (fl) (ft) (°/100ft) 6001931.75 N 494458.31 E 0.370 6001960.56 N 494368.09 E 0.771 6001985.20 N 494289.87 E 0.309 6002013.09 N 494204.58 £ 1.315 6002040.95 N 494121.97 E 0.743 6002068.37 N 494040.13 E 0.222 6002097.45 N 493954.29 E 0.633 6002126.02 N 493872.33 E 1.205 6002156.65 N 493786.90 E 0.579 6002187.91 N 493703.22 E 1.113 6002218.11 N 493620.50 E 1.857 6002247.39 N 493535.59 E 0.538 6002274.37 N 493455.75 E 0.798 6002301.96 N 493372.97 E 0.609 6002328.76 N 493291.74 E 0.933 6002357.55 N 493205.42 E 0.811 6002385.71 N 493120.97 E 0.796 6002412.63 N 493037.96 E 0.643 6002439.38 N 492953.40 E 0.857 6002465.46 N 492870.83 E 1.001 6002490.96 N 492791.91 E 1.357 6002521.31 N 492699.27 E 0.553 6002548.81 N 492615.92 E 0.696 6002577.30 N 492530.34 E 0.950 6002605.95 N 492446.03 E 0.818 Alaska State Plane 4 Kuparuk 3H Vertical Section (ft) Comment 4361.81 4455.77 4537.08 4626.17 4712.82 4798.59 4888.68 4975.05 5065.42 5154.48 5242.21 5331.55 5415.32 5502.01 5586.97 5677.37 5765.82 5852.44 5940.38 6026.24 6108.56 6205.35 6292.52 6382.13 6470.66 23 March, 2000 - 10:36 -5- Continued,.. DrillQuestl.05.04e Sperry-Sun Drilling Services Survey Report for 3H-32PB1 Your Ref: API-501032032270 Surveyed: 3 February, 2000 North Slope Alaska Measured Depth (ft) Incl. Azim. Sub-Sea Depth (ft) Vertical Local Coordinates Global Coordinates Depth Northings Eastlngs Northings Eastings (fi) (ft) (ft) (ft) (ft) 8683.07 67.900 289.080 4305.09 4378.19 8776.67 69.560 288.880 4339.05 4412.15 8867.19 69.860 289.410 4370.44 4443.54 8960.47 68.990 288.550 4403.22 4476.32 9054.99 67.960 289.500 4437.90 4511.00 9149.72 69.160 289.620 4472.53 4545.63 9244.72 69.930 289.500 4505.73 4578.83 9340.80 69.650 290.670 4538.92 4612.02 9429.70 69.190 289.180 4570.17 4643.27 9527.63 70.380 290.960 4604.01 4677.11 9621.78 69.790 290.740 4636.08 4709.18 9714.06 71.070 290.480 4666.99 4740.09 9808.43 70.360 290.310 4698.16 4771.26 9905.60 69.880 290.530 4731.20 4804.30 9997.72 69.330 290.240 4763.30 4836.40 10091.03 70.000 290.440 4795.73 4868.83 10184.90 69.480 290.250 4828.23 4901.33 10277.61 69.590 291.020 4860.65 4933.75 10372.04 69.320 291.050 4893.79 4966.89 10465.67 70.180 290.270 4926.19 4999.29 10559.21 69.600 290.840 4958.36 5031.46 10654.76 69,040 290.740 4992.10 5065.20 10746.44 68.300 290.700 5025.45 5098.55 10840.47 68.960 289.930 5059.71 5132.81 10933.91 69.740 288.350 5092.66 5165.76 23 March, 2000 - 10:36 2020.41 N 6292.75W 6002634.48 N 492363.25 E 2048.78 N 6375.23W 6002662,87 N 492280.77 E 2076.62 N 6455.43W 6002690.73 N 492200.57 E 2105.03 N 6538.01W 6002719.14 N 492117.99 E 2133.69 N 6621.14W 6002747.82 N 492034.88 E 2163.21 N 6704.22W 6002777.35 N 491951.80 E 2193.01N 6788.10W 6002807.17 N 491867.93 E 2223.97 N 6872.77W 6002838.15 N 491783.26 E 2252.33 N 6951.02W 6002866.52 N 491705.02 E 2283.87 N 7037.33W 6002898.08 N 491618.72 E 2315.38 N 7120.05W 6002929.60 N 491536.00 E 2345.98 N 7201.43W 6002960.22 N 491454.62 E 2377.03 N 7284.92W 6002991.28 N 491371.14 E 2408.91 N 7370.56W 6003023.17 N 491285.51 E 2438.98 N 7451.49W 6003053.27 N 491204.57 E 2469.40 N 7533.53W 6003083.69 N 491122.54 E 2500.01 N 7616.10W 6003114.32 N 491039.98 E 2530.62 N 7697.39W 6003144.95 N 490958.70 E 2562.36 N 7779.92W 6003176.70 N 490876.17 E 2593.35 N 7862.11W 6003207.71 N 490793.99 E 2624.19 N 7944.36W 6003238.56 N 490711.75 E 2655.92 N 8027.93W 6003270.31 N 490628.18 E 2686.14 N 8107.80W 6003300.54 N 490548.31 E 2716.54 N 8189.92W 6003330.95 N 490466.20 E 2745.20 N 8272.52W 6003359.63 N 490383.60 E Dogleg Rate (°llOOft) 1.431 1.785 0.641 1.271 1.436 1.272 0.819 1.179 1.652 2.094 0.664 1.412 0.771 0.538 0.666 0.746 0.586 0.787 0.287 1.206 0.844 0.594 0.808 1.036 1.789 Alaska State Plane 4 Kuparuk 3H Vertical Section Comment 6557.75 6644.50 6728.97 6815.82 6903.28 6991.06 7079.67 7169.51 7252.42 7343.98 7432.27 7518.97 7607.76 7698.85 7784.92 7872.13 7959.91 8046.52 8134.74 8222.34 8309.91 8399.07 8484.24 8571.52 8658.50 -6- Continued... .. DrillQuest 7.05.04e Sperry-Sun Drilling Services Survey Report for 3H-32PB1 Your Ref: API-501032032270 Surveyed: 3 February, 2000 North Slope Alaska Measured Depth (ft) Incl. Azim. Sub-Sea Depth (ft) Vertical Local Coordinates Depth Northings Eastings (ft) (ft) (ft) 11028.48 69.100 289.110 5125.91 5199.01 11122.78 69,970 288.310 5158.88 5231.98 11215.73 69.600 288.050 5191.00 5264.10 11309.10 68.920 288.190 5224.06 5297.16 11402.34 68.700 288.200 5257.76 5330.86 11495.51 69.320 288.360 5291.14 5364.24 11588.17 69.020 288,510 5324.09 5397.19 11681.68 71.470 289.200 5355.69 5428.79 11735.64 71.540 291.440 5372.81 5445.91 11830.89 73.490 298.940 5401.47 5474.57 11924.68 73,220 300.840 5428.33 5501.43 12019,96 72.420 302.580 5456.48 5529.58 12114.51 71.730 303.350 5485.58 5558.68 12207.76 71.590 304.810 5514.92 5588.02 12301.90 71.590 307.550 5544.66 5617.76 12396.00 71.770 309,950 5574.24 5647.34 12490.36 71.970 313.060 5603.61 5676.71 12581.23 72.570 316.080 5631.29 5704.39 12676.88 72.730 318.850 5659.81 5732.91 12769.75 73.300 320.680 5686.95 5760,05 12862.06 74.350 322.200 5712.66 5785,76 12952.50 75.780 325.960 5735.98 5809.08 13046.94 77.380 328.700 5757.90 5831.00 13140.88 78.120 331.120 5777.83 5850.93 13234.63 78.610 333,860 5796.74 5869.84 Global Coordinates Dogleg Northings Eastings Rate (fi) (ft) (°/100fi) 2773.63 N 8356.37W 6003388.07 N 490299.76 E 2801.97 N 8440.05W 6003416.42 N 490216.09 E 2829.18 N 8522.92W 6003443.65 N 490133.22 E 2856.34 N 8605.90W 6003470.83 N 490050.24 E 2883.48 N 8688.49W 6003497.99 N 489967.66 E 2910.77 N 8771.09W 6003525.29 N 489885.06 E 2938.15 N 8853.25W 6003552.69 N 489802.91E 2966.60 N 8936.53W 6003581.14 N 489719.64 E 2984.37 N 8984.51W 6003598.92 N 489671.66 E 3023.03 N 9066.63W 6003637.60 N 489589.54 E 3067.80 N 9144.54W 6003682.39 N 489511.65 E 3115.65 N 9221.97W 6003730.25 N 489434.22 E 3164.59 N 9297.45W 6003779.21 N 489358.75 E 3214.19 N 9370.76W 6003828.82 N 489285.45 E 3266.91 N 9442.85W 6003881.55 N 489213.37 E 3322.82 N 9512.51W 6003937.48 N 489143.72 E 3382.24 N 9579.66W 6003996.91N 489076.58 E 3442.98 N 9641.31W 6004057.65 N 489014.94 E 3510.25 N 9703.02W 6004124.93 N 488953.24 E 3578.05 N 9760.39W 6004192.74 N 488895.89 E 3647.37 N 9815.64W 6004262,08 N 488840.64 E 3718,13 N 9866.89W 6004332.84 N 488789.41 E 3795.45 N 9916.46W 6004410.17 N 488739.85 E 3874.87 N 9962,48W 6004489,61 N 488693.85 E 3956.31 N 10004.89W 6004571.05 N 488651.45 E 1.012 1.218 0.477 0.742 0.236 0.684 0.357 2.710 3.939 7,783 1.962 1,936 1.064 1.494 2.762 2.429 3.139 3.234 2.769 1.982 1.948 4.317 3.291 2.638 2.910 Alaska State Plane 4 Kuparuk 3H Vertical Section (ft) Comment 8746.51 8834.33 8920.95 9007.65 9093.98 9180.38 9266.42 9353.93 9404.93 9495.70 9585.22 9675.61 9764.69 9852.O8 9939.68 10026.42 10112.37 10193.88 10278.21 10358.83 10438.17 10514.48 1O592.O4 10667.27 10740.O7 23 March, 2000- 10:36 -7- Continued.,. .. DrillQues t 1.05. 04e Sperry-Sun Drilling Services Survey Report for 3H-32PB1 Your Ref: A PI-SO 1032032270 Surveyed: 3 February, 2000 North Slope Alaska Measured Sub-Sea Vertical Local Coordinates Depth Incl. Azim. Depth Depth Northings Eastings (ft) (ft) (ft) (ft) (ft) Global Coordinates Northings Eastings (ft) (ft) 13328.08 79.140 335.840 5814.78 5887.88 4039.30 N 10043.85 W 13421.53 81.730 340.860 5830.31 5903.41 4124.92 N 10077.82 W 13516.35 90.410 344.250 5836.81 5909.91 4215.07 N 10106.14 W 13612.01 90.740 346.400 5835.85 5908.95 4307.60 N 10130.37 W 13707.28 88.960 348.260 5836.10 5909.20 4400.55 N 10151.26 W 13804,74 86.380 347.910 5840.06 5913.16 4495.82 N 10171.37 W 13901.61 82.950 349.600 5849.07 5922.17 4590.40 N 10190.17 W 13997,86 79.450 351.940 5863.79 5936.89 4684.26 N 10205.44 W 14092.20 75.450 352.490 5884.29 5957.39 4775.48 N 10217.91 W 14187.55 70.310 353.390 5912.35 5985.45 4865.88 N 10229.12 W 14278.00 70.310 353.390 5942.82 6015,92 4950.48 N 10238.92 W 6004654.05 N 488612.50 E 6004739.68 N 488578.55 E 6004829.83 N 488550.25 E 6004922.37 N 488526.04 E 6005015.31 N 488505.16 E 6005110.59 N 488485.07 E 6005205.17 N 488466.28 E 6005299.04 N 488451.04 E 6005390.26 N 488438.58 E 6005480.66 N 488427.39 E 6005565.26 N 488417.60 E 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 26.501° (18-Jan-00) The Dogleg Severity is in Degrees per 100ft. Vertical Section is from Well and calculated along an Azimuth of 294.950° (True), Based upon Minimum Curvature type calculations, at a Measured Depth of 14278.00ft., The Bottom Hole Displacement is 11372.89ft., in the Direction of 295.804° (True). Dogleg Rate (°/100ft) 2.155 5.978 9.823 2.274 2.702 2.671 3.944 4.358 4.278 5.466 0.000 Alaska State Plane 4 Kuparuk 3H Vertical Section (ft) Comment 10810.41 1O877.33 10941.03 11002.03 11060.18 11118.59 11175.54 11228.98 11278.76 11327.06 11371.63 Projected Survey Continued... 23 March, 2000 - 10:36 - 8 - DrillQuest 1.05.04e Sperry-Sun Drilling Services Survey Report for 3H-32PB1 Your Ref: API-501032032270 Surveyed: 3 February, 2000 North Slope Alaska Alaska State Plane 4 Kuparuk 3H Comments Measured Depth (ft) 14278.00 Station Coordinates TVD Northings Eastings (ft) (ft) (ft) 6015.92 4950.48 N 10238.92 W Comment Projected Survey Survey tool program From Measured Vertical Depth Depth (ft) (ft) 0.00 0.00 To Measured Vertical Depth Depth (ft) (ft) 14278.00 6015.92 Survey Tool Description MWD Magnetic 23 March, 2000 - 10:36 - 9 - DrillQuest 1.05.04e SENT BY' " .5 i ~-~_K 4_ 56; ,x I.) L ,.55:50 ?5:1 -4 5-25- 0 ' 2'37P~ PHILLIPS AK INC--, 907 276 7542'~ 2/ 2 ~ L/ \1 ~ L' I ] /~ ~ t_ ,~ "-%1 ! __ I I ' - ~ -- - -~ i ~,' · ~,/ :2~," i'.~ ~,~ ~ .... ~ ..... .~ .. -----_ I . ~'-~ '~'~-" '-.~ ~-.. ._ _ ~ 2~ ~" ~ / /7 7~ ~ "' ' ~ A~} ..... c, ~ I. PRCsCSE~ ~ o~--- 365rbQ 1 ._ *"~-~ '~.. ~ 2 "-" 55 " + t ". / - t~'~~ ., ' ._ ,,,' ..'". . ._ ~ ......~.--~ ..... ',.:,-4iL .... / - .... / r,; I ' ___ .~ % ,; ,. .. ,, ~'.,. ~-v', ~ ~r~,~,' ~ " -" I 7,_ ~ ~ I ' ~ '-- ~ -- ) ~-''' '':'~ '~/'~ '4 .... '",'": /'.:::-~[~.~o... ~;~, '"" h '5 ~ ~ ~.*' - ~ ,', r~ ,,' ~ ~.,x, ' "*,' ,,'.' ,. ,." ~ ~--~ I_~ I / ,~ ,~ ,~ ! J~'- ~ ,, .... ~' "~ ':' ~.,~. I :,:'(~ ~ ~ · '~ ~ ,, - j~ ~ -' ~ ~ , · ' ~' / 7 ', ~ z~ _ ,~ ~_ j /, .V4 -,~7~ - _ .' : ! " ' ', i ,/ ' ~ ~ ,. '~ 4 ¢ [' /. ~, ,' , : -~ ,. ',:X,,,,~ , ,h ~ ...., .~- , .~' ..' ~-~k, ~ .. / . .' I X- . t . , ,.' A '4" ,' I PhilLIPS Alaska, Inc. A Subsidiary of PHILLIPS PETROLEUM COMPANY Post Office Box 100360 Anchorage, Alaska 99510-0360 Phone (907) 265-6120 Fax: (907) 265-6224 May 24, 2000 Mr. Robert Cluistenson Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Subject: 3H-32 (Permit No. 200-001) Well Completion Report Dear Mr. Commissioner: Enclosed is the well completion report for the completion on KRU 3H-32. If there are any questions, please call 265-6120. Sincerely, G. C. Al vord Drilling Engineering Supervisor Phillips Drilling ORIGINAL GCA/skad STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS ,,, I 1. Type of request: Abandon _ Suspend _ Operational shutdown _ Re-enter suspended well Alter casing _ Repair well _ Plugging _ Time extension Stimulate Other _ Change approved program _ Pull tubing _X Variance _ Perforate _X 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB feet) ARCO Alaska, Inc. Development__X RKB 73' 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 1044' FNL, 282' FWL, Sec. 12, T12N, R8E, UM 3H-32 At top of productive interval 9. Permit number / approval number 1245' FNL, 647' FWL, Sec. 3, T12N, R8E, UM (proposed) 200-001 At effective depth 10. APl number 50-103-20322 At total depth 11. Field / Pool 244' FSL, 1700' FWL, Sec. 33, T13N, R8E, UM (proposed) Kuparuk River Field/Kuparuk Oil Pool 12. Present well condition summary Total depth: measured 16000 feet Plugs (measured) true vertical 5999.5 feet Effective depth: measured 15937 feet Junk (measured) true vertical 5993 feet Casing Length Size Cemented Measured Depth True vertical Depth Conductor 117' 16" 90 sx AS I 117' 11 7' Surface 4707' 9.625" 580 sx AS III Lite. 864 sx Class G 4707' 2990' Production 13809' 7" 220 sx Class G 1 3809' 591 3' Liner 2361' 3.5" 430 sx Class G 16000' 5999.5' Perforation depth: measured N/A0RIEINALRECEIVED true vertical N/A Tubing (size, grade, and measured depth 3.5", 9.2#, L-80 @13629' 1 0 2000 Packers & sssv (type & measured depth) Baker 'ZXP LT' retr. pkr @ 13639', No SSSV Alaska 0il & Gas Cons. Commission Anchorage 13. Attachments Description summary of proposal __X Detailed operations program __ BOP sketch __ 14. Estimated date for commencing operation 15. Status of well classification as: April 12, 2000 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 Brian Noel 265-6979 Signed ~¢.,~ ~ Title: Drilling Supervisor Date '~'/'fCC) Graham C A/vord Prepared b;,¢' Sharon Allsu?Drake FOR COMMISSION USE ONLY Conditions of approvah Notify Commission so representative may witness J Appr°valn°3~O Plug integrity _ BOP Test ~'/ Location clearance _ Mechanical Integrity Test_ Subsequent form required 10- L~ Approved by order of the Commission Robt~rt N. Chri~t,:,r~-,..~ Commissioner Date /'~ Form 10-403 Rev 06/15/88 · SUBMIT IN TRIPLICATE 3H-32 GENERAL WORKOVER PROCEDURE STATUS: Nabors 16E drilled and completed well during January - March 2000. A 3-1/2" liner was run and cemented across the horizontal section through the Kuparuk A&C sands and 3-1/2" tubing run back to surface. The liner contains 12.1 ppg drilling mud. The 3-1/2" tubing and tubing x 7" casing annulus contain seawater with a diesel cap. A sheared DCR valve is in the bottom GLM at 13,584' MD. There are no perforations. Workover will use Nordic 3 to pull 3-1/2" tubing, drill pipe convey =1200' perf guns to shoot selective intervals of the A&C sands, and rerun 3-1/2" gaslift completion. PRE-RIG WORK: 1. RU coiled tubing unit. RIH and clean out drilling mud from 3-1/2" liner. Lay in a viscosified perf pill (12.0 ppg brine) as POOH. Set BPV in tubing and install VR plug in annulus valve. Remove flow riser and gas lift riser, well house and scaffolding as required. . GENERAL WORKOVER PROCEDURE: 1. MIRU Nordic Rig 3. Lay hard-line to tree. Pull BPV and VR plug. 2. Load pits with 12.0 ppg NaBr brine and displace seawater & diesel from well. Ensure well is dead. 3. ND tree. NU and test BOPE. 4. POOH standing back 13,700' of 3-1/2" tubing, lay down jewelry. 5. PU 2" hollow carrier perf guns and blank spacer. RIH on 3-1/2" drill pipe off racks. 6. Place guns on depth and perforate 3-1/2" liner. Circulate brine to kill well. 7. POOH laying down drill pipe and per[ guns. 8. Run 3-1/2" tubing and gas lift mandrels. 9. Stab seals into tieback sleeve, space out, land tubing hanger. 10. Pressure test tubing and annulus. 11. ND BOPE. NU and test tree. Displace well with seawater. Freeze protect well with diesel. RECEIVED APR 1 0 20O0 ~as~a 0il & Gas Cons. Commissiol, An. ch0rage Lower Limit: Expected Case: Upper Limit: 5 days No problems running perf guns or killing well. 5.5 days 6.5 days Difficulties running perf guns or killing well. BDN 4/07/00 3H-32 FMC Gen V 9-5/8 x 7 x 31/2 12-1/4" Hole 9-5/8" 40# L-80 BTC-Mod Surf. Csg. @ 4,707' MD 81/2" Hole 3Y2" 9.3# L-80 8rd EUE tubing w/15' seal bore extension tied into top of liner 7" 26# L-80 BTC Intermediate Csg. @ 13,809' MD Baker 3.5" x 7" ZXP LTP and tieback sleeve and HMC Liner Hanger. TOL @ 13,639' MD 6-1/8" Hole L~ ~ o.. ... -:.:.:. I :;:::::~ -...-. :::;:;: ~i ::::::: :::::: · , , o. , :::::: ;:;::: y · .. · . . :.~.:. .'.'.' · . . ~1~ .'.'.' · . . ,.. ~.:.:. 2.2.2.: · . . ... ... .%.., .°%.., · , . ..-..., · . . .... .~.:.~.: · ....,. ,.%..-,. .... ,....°%. 9.2# L-80 SLHT Liner 13,639' - 16,000' MD 2.875" CAMCO DS nipple for SCSSV @ 551' MD Camco 31/2" x 1" side pocket GLM w/DV's Camco 31/~'' x 1 side pocket GLM CAMCO 2.812" DS nipple @ 13,628' MD RECEIVED APR 10 2000 ~aska O[ & Gas Coes. Commissior .Anchor~e 3-1/2" Slimhole Completion 04/07/00 Alar-03-i30 1t:02 From-CP; TNRE£ WI:LL. MI~3 i U~'lr H,t41~lJt~¥ C~ Well 3H-32 Workcver APl ~ 10~20322-00 ,New ',¢.!~ x ~TDW 200-01 Com.;31et:sn Date 3/5,'C0 I~'ELL INFORMATION $iTP iAP DAP Bt'~P /Depth / Date: o I o · To To Dh' lng x AFE Numr. er A~,.~,.~,7 DIRECTIONAl. I~ FOI~JVIATIO N RKB 2t~.,.~' KOP A,,~ ~ole ~e 02,12 Maxa~le of 95.52 ~ !~' ~W, ADDED OR Top Bot J:Nct pe~orated,_ .. I!; RE-PERI;~D INTERVALS SPF Gun T.y~e Date COMPLETION INFORMATION Depth Item yfclr 550.71 NjpPte ! c~.~ .~45 j G,,b. ~C~mco ~0912; .G~M, ,J Cam~, KBM~2 !204! ~ DOWNHOLE IN FORMATION Dri!!ers TE t806,0 ,;BTD~TOp otf:l cr J ~5937' Date '"agree,___ t___! 2 Wa~ Check L2 DA VR ._._J Dcwnhole KNOWN Comrn,nicatioTu:)in..g ~ IA ~-} CA! J SUt~FACE EQUIPMENT Tree FMC ~r, V ~M Tree Cap C~,n ~' Otis (Type/~r~sure ~t~0~ ~gr C~n 3-~'' EUE~d Model Vlv Size OD ID ValveLa1:cl'. KBMM-2 tJ ~1'~"' $.015 2.92 ,~-v iaK-~ '6v IBK-5' DY JBK-5 'or m I,o~J'" - 6,o18 1.5 ~ 6.018~ 2.~2 .zx~"~5 ~.;,;~ i. zx,~ ~T ! I ._ 136561 PBR I Baker ~g98 M~rjl j ; j 2.9375 ...... I .... ,15579~ k~r,, j l~8~L~d coq Baker . 15~8 i FI[ ~:G&meco Ala~ka Oil & Gas Con, s. Comm~,~.,o~ Anchorage Group Review R~g releaser ~,ubsequent Lo f~;h wo:t comlc]etJon a5 'e: $[a~e Drill'ng permi:;..~_x Yes No no. s.~ecif~ °err~ining ope'ation5; EN.¥1RONM..ENTAL SITE INSPECTION . I::)eotls cleaned dp on aha arour, d si~: , Equil~,en£ and supF, ly staqin¢l areas are No c~ri$ is left on tundra No drums o~qarba.~e receg~cte6 remair Weft house area and ¢oe$ n~ shc~v evidence Well cellar Is in gc~l condition and srn~[t spd!s 9.825 X T ann,.;JaS wa3 freeze ¢romcted w/300 Obls H23 & 60 diesel. Hot O;I pum .j~ed diesel. 12.1 ppg mud w~.$ le~ in tn'e liner. 23-Mar-00 AOGCC Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 .oo Re: Distribution of Survey Data for Well 3H-32 Dear Lori Taylor: Enclosed are two survey hard copies. Tie-on Survey: Window / Kickoff Survey Projected Survey: 13,804.74' MD 13,840.00' MD 16,000.00' MD (if applicable) Please call me at 273-3545 if you have any questions or concerns. Regards, RECEIVED ' Kenneth W. Allen Survey Manager Attachment(s) AJas~ Oil & Gas Cons. Cornmlss~on Anchorage 23-Mar-00 AOGCC Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Re: Distribution of Survey Data for Well 3H-32PB1 Dear Lori Taylor: Enclosed are two survey hard copies. Tie-on Survey: Window / Kickoff Survey Projected Survey: 0.00' MD 'MD 14,278.00' MD (if applicable) Please call me at 273-3545 if you have any questions or concerns. Regards, Kenneth W. Allen Survey Manager IVIAR 2 8 2000 Attachment(s) Alaska Oil & Gas Cons. Commission Anchorage Re: 3H-32 Connec~on Gas Subject: Re: 3H-32 Connection Gas Date: Tue, 15 Feb 2000 16:56:34 -1000 From: "William B Lloyd" <WLLOYD@mail.aai.arco.com> To: Tom Maunder <tom_maunder@admin.state.ak. us> Tom, Apparently I must have left something out regarding if the 15.6 ppg fluid was exerienced by the formation or not. Chronologically, we, set plug # 2 from -14006' to 13700' ('200' inside the shoe @ 13809'). After setting the plug we pulled to 13ddd' and drculated for 8.5 hours while lowering the mud weight from 12 ppg to 10.8 ppg. Once the mud weight was cut, we tripped out of the hole to 4416', a period of 6 hours, at which point we saw the flow out the drill pipe of -1.5 bbls per hour. We stripped back in to 13448' (24.5 hours), CCM to 10.8 ppg and shut the well in in order to obtain an aocurate gauge of reservoir pressure. We recorded 35 psi SICP (darts in the DP prevented a SIDPP at the Iow differential). We raised the mud weight to 11.6 ppg to provide hy:lrostatic for BHSP + trip margin. Based upon the data, we effectively have a 10.8 - 10.9 ppge reservoir pressure. Once the mud weight was increased, we pulled out of the hole with no problem, then ran baok in with our drilling assembly. The question as to whether the formation saw the 15.6 is supported by the evidence from 2 data points: 1) the initial influx after the plugs were in place and 2) the fact that we recorded pressure after tdpping (stripping) in some 39 hours after setting our second plug, dearly after any cement had hardened. Beyond that point, standard ddlling fluid was the only material the formation was exposed to. The recommendation to run to LO (antidpated to be >15.6 ppg) is not very plausible. With a known reservoir pressure of 10.8+ ppg, our kick tolerance with the shoe where it is would never approach that value. Running up the LO pressure just to see where it would leak in order to provide a drilling 'hardline' is much less acceptable than running dean fluid baseline tests with the PWD and recognizing that we put 15.6 on it without a problem - our hardline is then 0.5 ppg above dean fluid conditions (-14.8 ppge). Intentionally breaking down a formation may result in hole problems down the road. In any event, I felt I did not adequately convey the facts of the issue to you and Blair. We are running the FIT to the required 11.7 + 0.5 ppg limit assoon as we expose 20' of new formation. Please let me know if you have additional thoughts or comments. Tom Maunder <tom_maunder@admin.state.ak. us> on 02/15/2000 10:29:01 AM To: William B Lloyd/AAI/ARCO cc: Blair Wondzell <blair_wondzell@admin.state.ak. us>, AOGCC North Sope Office <aog cc_p ru d hoe_bay@ad min. state, a k. us> Subject: Re: 3H-32 Connection Gas Re: 3H-32 Conneclion Gas Bill, We have discussed the situation on 3H-22. It is not dear that the 15.6 ECD was experienced by the formation. We recommend you run an FIT after drilling 20' of NEW formation according to the regulations. We strongly recommend you run the test to leak-off. Please call with any questions. Tom Maunder AOGCC William B Lloyd wrote: > Tom, > Question: > I'm sure you've been following the issues on this well that I've been updating > you on. As you recall, after setting our KO plugs below the 7", we cut the MW > to 10.8 ppg and tookan influx. Stripped in to TD, weighted up to 11.7 and came > out of the hole. Last night we tagged cement (stringers) at 13500'. VVhile > circulating to clean up we hadECD'son the PWD of up to 15.6ppg. Now, > recognizing that we have open formation from which the influx came, we obviously > put 15. 6 against the formation. Is there any reason to run a LOT? Please let me know ASAP. Thanks Bill Tom Maunder <torn_maunder~admin. state, ak. us> on 02/07/2000 08:00:52 AM To: William B Lloyd/AAI/ARCO CC: Subject: Re: 3H-32 Connection Gas Bill, Did you get the 7" in the ground OK?? Tom William B Lloyd wrote: > Blair/Tom, > FYi, yesterday evening while drilling into the Kuparuk C sand on Well 3H-32 > (Nabors 16e) with a 10.8 ppg mud, we noted gas on bottoms-up after connections. > The mud weight was increased to 11.1 ppg however we continued to see gas at > bottoms up after connections and have subsequently raised the MW to 11.7 ppg for > running our 7" intermediate casing. Guy Whitlock indicated that the well would > 'weep' for a short period of time after shu~'ng down the pumps - so little and > for such a short duration that he thought it may only be the kelly hose > draining. In addition, there ne~er appeared to be any cause to shut the Re.: 3H-32 Conneclion Gas _ well >>in. >> > > We have pulled a short trip to 11700' (TD is 14278') with no problem since > going > > to the 11.7. We are currently circulating bottoms up and things are looking > > good. We should be coming out of the hole for 7" later today >> > >Bill. Tom Maunder <tom maunderC, admin.state.ak, us> Petroleum Engineer Alaska Oil and Gas Conservation Commission MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Robert Christenson~ DATE: January 31, 2000 Chairman THRU: Blair Wondzell, P. I. Supervisor FROM: John Crisp,-~'~w, (4__ SUBJECT: Petroleum h'fspector BOP TEST Nabors 16E KRU 3H-32 PTD 20001 January 31, 2000: I traveled to Nabors 16E in the Kuparuk River Field to witness the weekly BOP test on well 3H-32. The Rig & Location were neat & clean. This Rig has a good test procedure in place & all personnel involved with this test showed competence & familiarity with BOPE testing procedures. The choke manifold for this Rig has two hyd. Chokes. One hyd. Choke is inoperable with adjacent valves closed to isolate the inoperable choke from the rest of the choke manifold. The inoperable choke needs to be repaired ASAP or to be taken out of the choke manifold. SUMMARY: I witnessed weekly BOP test on Nabors 16E in KRU well 3h-32. Tested BOPs on Nabors 16E. No failures witnessed. Test time 2 % hours. Attachments' BOP Nabors 16E 1-31-00jc cc; NON-CONFIDENTIAL BOP Nabors 16E 1-31-00jc STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report OPERATION: Dflg: X Workover: Drlg Contractor: Nabors Alaska Rig No. Operator: Arco Alaska Inc. Well Name: KRU 3H-32 Casing Size: 9 5/8' Set @ 4706' Test: Initial Weekly X Other 16E PTD # Rep.: Rig Rep.: Location: Sec. TEST DATA 20001 DATE: 1/31/00 Rig Ph.# 659-7562 Guy Whitlock Darryl Green 12 T. 12N R. 8E Meridian UM MISC. INSPECTIONS: Location Gen.: OK Housekeeping: OK (Gen) PTD On Location YES Standing Order Posted YES Well Sign YES Dd. Rig OK Hazard Sec. YES BOP STACK: Annular Preventer Pipe Rams Lower Pipe Rams Blind Rams Choke Ln. Valves HCR Valves Kill Line Valves Check Valve Quan. Test Press. P/F 250/3,500 P 250/3,5OO P 250/3,5OO P 250/3,50O P 250/3,500 P 250/3,5O0 P 250/3,500 P MUD SYSTEM: Visual Alarm Tdp Tank YES YES Pit Level Indicators YES YES Flow Indicator YES YES Meth Gas Detector tested tested H2S Gas Detector tested tested FLOOR SAFETY VALVES: Upper Kelly/IBOP Lower Kelly/IBOP Ball Type Inside BOP Test Quart. Pressure P/F 1 250/3,500 P 250/3,500 P 250/3, 500 P 250/3,5OO P CHOKE MANIFOLD: No. Valves No. Flanges Manual Chokes Hydraulic Chokes Test Pressure P/F 14 250/3,500 P 28 250/3,500 P 1 OK Functioned Functioned OK ACCUMULATOR SYSTEM: System Pressure Pressure After Closure 200 psi Attained After Closure System Pressure Attained Blind Switch Covers: Master: Nitgn. Btl's: 2,850 t P 1,600 P minutes 28 2 minutes 32 X Remote: 6 btJs. ~ 1950psi. ave. Psig. sec. sec. X TEST RESULTS Number of Failures: 0 ,Test Time: 2.5 Hours. Number of valves tested 20 Repair or Replacement of Failed Equipment will be made within days. Notify the Inspector and follow with Wdtten or Faxed verification to the AOGCC Commission Office at: Fax No. 276-7542 Inspector North Slope P,,gm' No. 659-3607 or 3687 If your call is not returned by the inspector within 12 hours please contact the P. I. Supervisor at 279-1433 REMARKS: FOg is in good shape. This Rig has a good test procedure in ;)lace & all personnel involved with this test showed competence & familiarity with BOPE testing procedures. ~' The choke manifold for this Rig has 2 hyd. Chokes. One hyd. Choke is inoperable with adjacent valves closed to isolate this choke from manifold. This choke needs to be repaired ASAP or taken totally out of service. ~' Distribution: orig-Well File c - Oper./Rig c - Database c- Tdp Rpt File c - Inspe~;~,lL (Rev. 12/94) STATE WITNESS REQUIRED? YES X NO 24 HOUR NOTICE GIVEN YES X NO WaNed By. Witnessed By:. ~rs 16E 1-31-00jc John Crisp / I. ou Grimaldi 3H-32 Permit and close approach Subject: 3H-32 Permit and close approach Date: Wed, 12 Jan 2000 09:50:46 -1000 From: "William B Lloyd" <WLLOYD@mail.aai.arco.com> To: tom_maunder@admin.state.ak, us CC: "Sharon AIIsup-Drake" <SALLSUP@mail.aai.arco.com> Per our conversation regarding the referenced items: 1 ) Permit - In our original submittal, Arco had indicated we would be ready to spud 3H-32 by the 18th of January. As it appears now, our operations on 1R-22a have been ahead of schedule and it appears we will be prepared to be over the 3H-32 well by no later than Sunday. therefore I respectfully request permit approval by end of business day on Friday in order to get the permit in-hand and posted at the rig prior to spudding. 2) Close approach issues have been resolved through the use of IFR and modifications to the well path plan. Using IFR yields greater confidence in surveys therby allowing us to eliminate certain nudges in the well path and the "fight" of proximity issues between 2 offsetting wells. Our well path is now straighter with more survey confidence. We do come within 88' of P&A'd wellbore 3H-25 at 2380' and 86' at 2600' hov, ever, magnetic interference should not jeopardize survey quality at that depth. In addition, ~ will be running gyro surveys from 300' - -1200' for interference from shut-in injector 3H-18. If you have any additional questions or comments, please contact me at 265-6531. I appreciate your help in obtaining reulatory approval of this well. Sincerely, William Lloyd I n~F I 1/1 ?/nFl 1 FI.FIR TONY KNOWLES, GOVERNOR ALASKA OIL AND GAS CONSERVATION COMMISSION Chip Alvord Drilling Enginccnng Supervisor ARCO Alaska. Inc. P O Box 100360 Anhoragc. AK 995104)360 3001 PORCUPINE DRIVE ANCHC'~AGE. ALASKA 99501-3~ P~4ONE ~07) 279-1433 "AX: [;O7) 276-7542 Re' Kuparuk River Unit 3H-32 ARCO Alaska. inc. Permit No: 200-()()I Sur Loc: l()44'FSL. 282'FVv%. SEC. 12. T12N. R08E. L,~,I Btmhole Loc. 244'FSL. 17()0'FWL. SEC. 33. TI3N. R08E. UM Dear Mr. Alvord: Enclosed is rite approved applicalion for permit to drill file above referenced Please nolo that any disposal of fluids generated from lhis drilling operation which arc pumped doxl n lhc surface/production casing annulus ora '`tell approx'cd for mmular disposal on Drill Silc 3H musl comply x'`ilh Iht requirements and lilnilations of 20 AAC 25.¢/81}. Approval of tins permit Io drill docs no! aulhonzc disposal of drilling '`x'aste m a x'olmne greater than 35.{)1~1) barrels through the mmular space ora single xxcll or to usc tirol x~'cll for disposal purposes for a pcnod longer than one x ear. Annular disposal of drilling xxastcs '`'`-ill not be apprm'ed for tins well tlnlil sufficient ~141 is submmcd Io cnsurc that thc requirements of 20 AAC 25.()8¢) arc met. Annular disposal of drilling xYaslc will bc conlingcnt on obtaining a x~ ell cemented surface caSnlg confirmed by a valid Formation Inlcgnty Test (FIT). Ccmcm~ng records. FIT dam. and any CQLs must bc submitted to thc Comlmssion on form 10-403 prior to thc start of disposal operations. Thc permit to drill docs no~ exempt you from obtaimng additional penn,ts rcquircd b'` law from othcr govcrnmcmal agencies, and docs not authorize conducting drilling operations umil all other required pcrnnmng dclcnmnations arc made. Bio'`/out prevention equipmcul I BOPE) must bc lcslcd in accordance v;iltl 20 AAC 25 I}35. Sufficient nolicc {approxinmtely 24 hours} nlusl be gl,, cn 1o allml a rcprcscnlativc of thc Comnussion to/i i IllCSS il IcSl of BOPE installed prior to drilling nc'`l' hole. No, icc mav be given by contacting lhe Commission petroleum field inspector on lhc North Slope pager at o59-361)7. Rob/en N. Chnstcnson. P.E. Chair BY ORDER OF ~t.~.~MMISSION DATED this day of JanuaD', 2000 dlf Enclo~ure~ cc: I)cpanment of }:ish & (;amc. }tabitat Sccmm x~ o cncl. Dcpa~mcnI of Fnx ironnlenlal CollSCB'allOll x~ o cllcJ. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 la. Type of work: Drill [] Redrill [] J lb. Type of well. Exploratory [] Stratigraphic Test [] Development Oil [] Re-entry [] Deepen []J Service [] Development Gas [] Single Zone [] Multiple Zone [] 2. Name of Operator 5. Datum elevation (DF or KB) 10. Field and Pool ARCO Alaska. Inc. RKB 73 feet 3. Address 6. Property Designation ~ ,2. 2_"~'"~1) Kuparuk River Field P.O. Box 100360 Anchorage. AK 99510-0360 ADL 25524 ALK 2655 (_,'.Z.'¢~-~%,/~ Kuparuk River Pool 4. Location of well at surface 7. Unit or property Name.,"~ 11 . Type Bond .see 2c 1044' FNL. 282' FWL. Sec. 12. T12N,R8E. UM Kuparuk River Unit Statewide At top cf productive interval 8. Well number Number 1245' FNL, 647' FWL. Sec. 3. T12N, R8E. UM 3H-32 #U-630610 At total depth 9. Approximate spud date Amount 244' FSL, 1700' FWL, Sec. 33, T13N, R8E, UM January 18, 2000 S200.000 12. Distance to nearest property line J 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth '~,~D aha T~.D, 244' fee~ 3H-28 496' @ 14032' feet 2560 15856 ' MD / 5993 'TVD 16. To be completed for deviated wells 17. Anticipated pressure ,see 2O A~,3, 25 o35 ,e ,'2 Kickoff depth: 250' MD Maximum hole angle 92° Maximum surface 1883 psig At total depth (TVD) 2235 psig 18. Casing program Setting Depth size Specifications Top Bottom Quantit~ of Cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include sta~ie data) 24" 16" 62.5# R-3 Weld 47' 73' 73' 120' 120' Pre-set 12 25" 9.625" 40# L-80 BTC 5185' 73' 73' 5258' 3193' 790 sx AS III. 650 sx Class G 8.5" 7" 26# L-80 BTC-Mod 13949' 73' 73' 14022' 5962' 210 sx Class G 6.75" 3.5" 9.3# L-80 EUE 2006' 13850' 5951' 15856' 5993' 430 sx Class G 19. To be completed for Redrill. Re-entry, and Deepen Operations. Present well condition summary Total Depth: measured feet Plugs (measured) true vertical feet Effective Depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented Measured depth True Vertical depth RECEIVED ORIGINAL Perforation depth: measured Alaska Oil & Gas Cons. Commission true vertical Anchorage 20. Attachments Filing fee [] Property Plat [] BOP Sketch[] Diverter Sketch [] Drilling program[] Drilling fluid program [] Time vs depth plot [] Refraction analysis [] Seabed report [] 20,&AC 25.050 requirements [] 21. I hereby certify that the foregoing is true and correct to the best of my knowledge Questions? Call Bill Lloyd 265-653~,~)r Signed ~_/__., Title: ~r71hr~g. Super'¢sor Date , A Prepared bv Sharon AIIsuD-DrakE Commission Use Chi) Permit Number,~_C,,~) _ O/ APl number ~ Approval datel ISoo cover letter 50- JO% ~ .~-~'~ ,.~Z~ -/(,~J - (~i,~ Jforother requirements Conditions of approval Samples required [] Yes J~' No Mud Icg required [] Yes J~' No Hydrogen sulfide measures [] Yes J~ No Directional survey required ~j~ Yes [] No Required working pressure for BOPE [] 2M: [] 3M: [] 5M: [] 10M:[] 'J~ '~(~)(~ ~)~, ~,(~)'~ Other: ORIGINAL SIGNED BY Robert N Chdstensorl by order of /- Approved by Commissioner the commission Date~ ,~ ,,--, Form 10-401 Rev. 12/1/85 · Submit in triplicate ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 December 27, 1999 Robert Christenson, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501-3192 Re: Application for Permit to Drill: KRU 3H-32 Surface Location: ~.044' I=NL 282' FWL Se~ Target Location: :1.245' FNL, 647' I=WL Sec. 3, T:~2N-RO8E, UI~I Bottom Hole Location: 244' FSL, ~700' I=WL Se~. 33, T:I.3N, ROSE, UNI Dear Commissioner Christenson, ARCO Alaska, :[nc. hereby applies for a Permit to Drill an onshore development well to the Kuparuk interval from 3H 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 3H pad. The well is designated as a conventional production well using a 9 5/8" surface casing string, a 7" intermediate casing, 3-1/2" production liner and 3-1/2" 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) 2) 3) 4) 5) 6) 7) 8) 9) Form 10-40:t Application for Permit to Drill per 20 AAC 25.005 (a). Fee of $ :tOO payable to the State of Alaska per 20 AAC 25.005 (c) (:t). A directional plat showing the surface and bottomhole locations proposed for the well per 20 AAC 25.005 (c) (2). Directional plots and proximity calculations in accordance with the requirements of 20 AAC 25.050. Diagrams and descriptions of the BOP and diverter equipment to be used as required by 20 AAC 25.035 (a) (1) and (b) 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. The drilling fluid program, in addition to the requirements set forth in 20 AAC 25.033 are attached in this APD package. A copy of the proposed drilling program, including a request for approval of annular pumping operations is attached. ARCO does not anticipate the presence of H2S in the formations to be encountered in this well. However, H2S monitoring equipment will be functioning on the rigs as is the standard operating procedure in the Kuparuk River Unit drilling operation. Robert Christenson Application for Permit to Drill - 3H-32 Page 2 10) Due to the large volume of regional information available, 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.The following are ARCO's designated contacts for reporting responsibilities to the Commission: 1) Completion Report Technologist (20 AAC 25.070) Sharon AIIsup-Drake, Drilling 263-4612 2) Geologic Data and Logs Tony Hillegeist, Geologist (20 AAC 25.071) 265-1534 The anticipated spud date for this well is January 18, 2000. If you have any questions or require further information, please contact Bill Lloyd at (907) 263- 6531 or Chip Alvord at (907) 265;0120. Williatl~B. L/!_b~d ~X J- Senior Drilling Engin~ CC: Kuparuk 3H-32 Well File Chip Alvord ATO-1030 Havriky Kalugin ATO-1260 ARCO Alaska, Inc. Pad 3H 32 slot #32 Kuparuk River Unit North Slope, Alaska PROPOSAL LISTING by Baker Hughes INTEQ Your ref : 32 Version~q) Our ref : propg04 License : Date printed : 22-Dec-1999 Date created : 5-0ct-1993 Last revised : 21-Dec-1999 Field is centred on n70 16 18.576.w150 5 56.536 Structure is centred on n70 24 56.740.w150 0 47.688 Slot location is n70 24 46.472.w150 0 39.421 Slot Grid coordinates are N 6000613.087. E 498655.349 Slot local coordinates are 1044.00 S 282.00 E Projection type: alaska - Zone 4. Spheroid: Clarke - 1866 Reference North is True North ARCO Alaska. Inc. Pad 3H.32 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 13300.00 80.50 339.53 5889.77 4041.84 N 10071.19 W 13400.00 81.48 342.40 5905.43 4135.20 N 10103.40 W 13500.00 82.49 345.25 5919.37 4230.29 N 10130.97 W 13600.00 83.51 348.09 5931.56 4326.86 N 10153.84 W 13700,00 84.55 350.92 5941.95 4424.65 N 10171.95 W 13711.17 84.67 351.24 5943.00 4435.63 N 10173.67 W 13800.00 85.61 353.74 5950.53 4523.38 N 10185.24 W 13900.00 86.67 356,56 5957.26 4622.78 N 10193.67 W 14000.00 87.74 359.36 5962.14 4722.59 N 10197.23 W 14008.67 87.84 359.60 5962.47 4731.25 N 10197.31 W 14022.58 87.84 359.60 5963.00 4745.15 N 10197.40 W 14022.60 87.84 359.60 5963.00 4745.17 N 10197.40 W 14051.25 87.99 0.00 5964.04 4773.80 N 10197.50 W 14363.82 87.99 0.00 5975.00 5086.18 N 10197.48 W 14363.84 87.99 0.00 5975.00 5086.20 N 10197.48 W 14400.00 88.53 359.99 5976.10 5122.34 N 10197.48 W 14425.57 88.92 359.99 5976.67 5147.91N 10197.48 W 14500.00 88.92 359.99 5978.07 5222.32 N 10197.50 W 14654.92 88.92 359.99 5981.00 5377.21 N 10197.54 W 14654.94 88.92 359.99 5981.00 5377.23 N 10197.54 W 14700.00 89.59 359.99 5981.59 5422.29 N 10197.55 W 14800.00 91.09 359.99 5980.99 5522.29 N 10197.57 W 14845.89 91.78 359.99 5979.84 5568.16 N 10197.58 W 15000.00 91.78 359.99 5975.05 5722.20 N 10197.62 W 15130.12 91.78 359.99 5971.00 5852.25 N 10197.64 W 15130.14 91.78 359.99 5971.00 5852,28 N 10197.64 W 15148.90 91.50 359.99 5970.46 5871.03 N 10197.65 W 15178.73 91.05 359.99 5969.80 5900.85 N 10197.65 W 15500.00 91.05 359.99 5963.90 6222.06 N 10197.72 W 15603.26 91.05 359.99 5962.00 6325.31 N 10197.75 W 15603.28 91.05 359.99 5962.00 6325.32 N 10197.75 W 15664.96 87.09 359.99 5963.00 6386.99 N 10197.76 W 15700.00 84.84 359.99 5965.47 6421.94 N 10197.77 W 15800.00 78.41 359.99 5980.02 6520.82 N 10197.79 W 15823.30 76.92 359.99 5985.00 6543.58 N 10197.79 W PROPOSAL LISTING Page 1 Your ref : 32 Version#O Last revised : 21-Dec-1999 Dogleg Vert Deg/lOOft Sect 0.00 4041.84 SideTrack Pt/Cont Build & Turn 3.00 4135.20 3.00 4230.29 3.00 4326.86 3.00 4424.65 3.00 4435.63 Top of Kuparuk D 3.00 4523.38 3.00 4622,78 3.00 4722.59 3.00 4731.25 EOC 0.00 4745.15 Target #1/Top C4/Begin Turn 0.00 4745.17 3H-32 T1 Heel Rvsd 17-Nov-99 1.50 4773.80 EOC 0.00 5086.18 Target #2/Begin Build 0.00 5086.20 3H-32 T2 Rvsd 08-Dec-99 1.50 5122.34 1.50 5147.91EOC 0.00 5222.32 0.00 5377.21 Target #3/Begin Build 0.01 5377.23 3H-32 T3 Rvsd 17-Nov-99 1.50 5422.29 1.50 5522.29 1.50 5568.16 EOC 0.00 5722.20 0.00 5852.25 Target #4/Begin Drop 0.00 5852.28 3H-32 T4 Rvsd 17-Nov-99 1.50 5871.03 1.50 5900.85 EOC 0.00 6222.06 0,00 6325.31 Target #5/Begin Drop 0.00 6325.32 3H-32 T5 Rvsd 17-Nov-99 6.42 6386.99 6.42 6421.94 6.42 6520.82 6.42 6543.58 Top Kuparuk B 15827.68 76.64 359.99 5986.00 6547.84 N 10197.80 W 6.42 15856.04 74.81 359.99 5992.99 6575.33 N 10197.80 W 6.42 15856.06 74.81 359.99 5993.00 6575.35 N 10197.80 W 6.42 6547.84 Top Kuparuk A1 6575.33 TD-Casing Pt 6575.35 3H-32 T6 Rvsd 17-Nov-99 All data is in feet unless otherwise stated. Coordinates from slot #32 and ll/D from Nabors 16E (73.00 Ft above mean sea level). Bottom hole distance is 12133.85 on azimuth 302.81 degrees from wellhead. Total Dogleg for wellpath is 188.12 degrees. Vertical section is from S 0.00 W 0.00 on azimuth 0.00 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ ARCO Alaska. Inc. Pad 3H.32 Kuparuk River Unit. North Slope. Alaska PROPOSAL LISTING Page 2 Your ref : 32 Version#8 Last revised : 21-Dec-1999 Conments in wellpath MD TVD Rectangular Coords. Con~nent 13300.00 13711.17 14008.67 14022.58 14022.60 14051.25 14363.82 14363.84 14425.57 14654.92 14654,94 14845.89 15130.12 15130.14 15178.73 15603.26 15603.28 15823.30 15827.68 15856.04 15856.06 5889.77 5943.00 5962.47 5963.00 5963.00 5964.04 5975.00 5975.00 5976.67 5981.00 5981.00 5979.84 5971.00 5971.00 5969.80 5962 O0 5962 O0 5985 O0 5986 O0 5992 99 5993 O0 4041.84 N 10071.19 W SideTrack Pt/Cont Build & Turn 4435.63 N 10173.67 W Top of Kuparuk D 4731.25 N 10197.31W EOC 4745.15 N 10197.40 W Target #1/Top C4/Begin Turn 4745.17 N 10197.40 W 3H-32 T1 Heel Rvsd 17-Nov-99 4773.80 N 10197,50 W EOC 5086.18 N 10197.48 W Target #2/Begin Build 5086.20 N 10197.48 W 3H-32 T2 Rvsd 08-Dec-99 5147.91N 10197.48 W EOC 5377.21N 10197.54 W Target #3/Begin Build 5377.23 N 10197.54 W 3H-32 T3 Rvsd 17-Nov-99 5568.16 N 10197.58 W EOC 5852.25 N 10197.64 W Target ~/Begin Drop 5852.28 N 10197.64 W 3H-32 T4 Rvsd 17-Nov-99 5900.85 N 10197.65 W EOC 6325.31N 10197.75 W Target #5/Begin Drop 6325.32 N 10197.75 W 3H-32 T5 Rvsd 17-Nov-99 6543.58 N 10197.79 W Top Kuparuk B 6547.84 N 10197.80 W Top Kuparuk A1 6575.33 N 10197.80 W TD-Casing Pt 6575.35 N 10197.80 W 3H-32 T6 Rvsd 17-Nov-99 Casing positions in string 'A' Top MD Top TVD Rectangular Coords. Bot MD Bot TVD Rectangular Coords. Casing n/a 5889.77 4041.84N 10071.19W n/a 5889.77 4041.84N 10071.19W 9-5/8' Casing Targets associated with this wellpath Target name Geographic Location T.V.D. Rectangular Coordinates Revised 3H-32 T1 Heel Rvsd i 488460 000 6005360.000 0.0000 5963.00 4745 17N 10197 40W 8-0ct-1999 3H-32 T2 Rvsd 08-Dec 488460 000 6005701.000 0,0000 5975.00 5086 20N 10197 48W 8-0ct-1999 3H-32 T3 Rvsd 17-Nov 488460 000 6005992.000 0.0000 5981.00 5377 23N 10197 54W 30-Sep-1999 3H-32 T4 Rvsd 17-Nov 488460 000 6006467.000 -2.000 5971.00 5852 28N 10197 64W 2-Nov-1999 3H-32 T5 Rvsd 17-Nov 488460 000 6006940.000 0.0000 5962.00 6325 32N 10197 75W 2-Nov-1999 3H-32 T6 Rvsd 17-Nov 488460 000 6007190.000 0.0000 5993.00 6575 35N 10197 80W 2-Nov-1999 ARCO Alaska, Inc. Pad 3H,32PB1 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 3 Your ref : 32 PB1 Version#2 Last revised : 21-Dec-1999 Dogleg Vert Deg/lOOft Sect 9500.00 69.46 289.22 4681.33 2292.28 N 7088.40 W 0.00 7393.83 9600.00 69.46 289.22 4716.42 2323.11 N 7176.82 W 0.00 7487.00 9700.00 69.46 289.22 4751.50 2353.94 N 7265.24 W 0.00 7580.18 9800.00 69.46 289.22 4786.59 2384.77 N 7353.67 W 0.00 7673.35 9900.00 69.46 289.22 4821.67 2415.59 N 7442.09 W 0.00 7766.53 10000.00 69.46 289.22 4856.76 2446.42 N 7530.51 W 0.00 7859.70 10100.00 69.46 289.22 4891.84 2477.25 N 7618.94 W 0.00 7952.88 10200,00 69.46 289.22 4926.93 2508.08 N 7707.36 W 0.00 8046.06 10300.00 69.46 289.22 4962.01 2538.91 N 7795.78 W 0.00 8139.23 10400.00 69.46 289.22 4997.10 2569.73 N 7884.21 W 0.00 8232.41 10500.00 69.46 289.22 5032.18 2600.56 N 7972.63 W 0.00 8325.58 10600.00 69.46 289.22 5067.27 2631.39 N 8061.05 W 0.00 8418.76 10700.00 69.46 289.22 5102.35 2662.22 N 8149.48 W 0.00 8511.93 10800,00 69.46 289.22 5137.44 2693.05 N 8237.90 W 0.00 8605.11 10900.00 69.46 289.22 5172.52 2723.87 N 8326.32 W 0.00 8698.28 11000.00 69.46 289.22 5207.61 2754.70 N 8414.75 W 0.00 8791.46 11100.00 69.46 289.22 5242.69 2785.53 N 8503.17 W 0.00 8884.63 11200.00 69.46 289.22 5277.78 2816.36 N 8591.59 W 0,00 8977.81 11300.00 69.46 289.22 5312.87 2847.18 N 8680.02 W 0.00 9070.98 11400.00 69.46 289.22 5347.95 2878.01 N 8768.44 W 0.00 9164.16 11500.00 69.46 289.22 5383.04 2908.84 N 8856.86 W 0.00 9257 11600.00 69.46 289,22 5418.12 2939.67 N 8945.29 W 0.00 9350 11645.91 69.46 289.22 5434.23 2953.82 N 8985.88 W 0.00 9393 11700.00 69,61 290.94 5453.14 2971.22 N 9033.47 W 3.00 9443 11800.00 69.93 294.12 5487,73 3007.18 N 9120.13 W 3.00 9537 .33 .51 .29 Begin Build & Turn .78 .51 11900.00 70.31 297.29 5521.74 3047.96 N 9204.84 W 3.00 9631.53 12000.00 70.74 300.44 5555.08 3093.47 N 9287.40 W 3.00 9725.57 12100.00 71.23 303.57 5587.67 3143.57 N 9367.56 W 3.00 9819.39 12200.00 71.77 306.68 5619.40 3198.13 N 9445.11W 3.00 9912.71 12300.00 72.36 309.77 5650.20 3257.00 N 9519.83 W 3.00 10005.30 12400.00 73.00 312.84 5679.99 3320.01N 9591.53 W 3.00 10096.88 12500.00 73.68 315.89 5708.67 3386.99 N 9660.00 W 3.00 10187.22 12547.93 74.02 317.35 5722.00 3420.45 N 9691.62 W 3.00 10230.00 Base HRZ/Top Kalubik 12600.00 74.40 318.92 5736.17 3457,77 N 9725.06 W 3.00 10276.06 12700,00 75.17 321.93 5762.41 3532.14 N 9786.52 W 3.00 10363.16 12800.00 75.98 324.91 5787.33 3609.90 N 9844.22 W 3.00 10448.28 12900.00 76.82 327.87 5810.86 3690.84 N 9898.01W 3.00 10531.19 13000.00 77.69 330.82 5832.92 3774.74 N 9947.73 W 3.00 10611.66 13100.00 78.60 333.74 5853.46 3861.36 N 9993.25 W 3.00 10689.47 13175.86 79.31 335.94 5868.00 3928.75 N 10024.90 W 3.00 10746.59 K-l/Top Lower Kalubik 13200.00 79,54 336.64 5872.43 3950.48 N 10034.44 W 3.00 10764.41 13300.00 80.50 339.53 5889.77 4041.84 N 10071.19 W 3.00 10836.27 13300.02 80.50 339.53 5889.77 4041.86 N 10071.20 W 3.00 10836.28 Begin Angle Drop & Cont. Turn 13400.00 79.55 342.42 5907.09 4134,93 N 10103.30 W 3.00 10904.65 13500.00 78.54 345.33 5926.01 4229.25 N 10130.57 W 3.00 10969.16 13583.50 77.89 347.77 5943.00 4308.76 N 10149.59 W 3.00 11019.94 Top Kuparuk D 13600.00 77.75 348.25 5946.48 4324.53 N 10152.94 W 3.00 11029.63 13675.84 77.09 350.49 5963.00 4397.27 N 10166.59 W 3.00 11072.70 Top Kuparuk C4 13700.00 76.89 351.20 5968.44 4420.51N 10170.34 W 3.00 11085.90 13771.42 76.30 353.32 5985.00 4489.35 N 10179.70 W 3.00 11123.42 Top Kuparuk B All data is in feet unless otherwise stated. Coordinates from slot #32 and TVD from Nabors 16E (73.00 Ft above mean sea level). Bottom hole distance is 11247.38 on azimuth 294.95 degrees from wellhead. Total Dogleg for wellpath is 188.12 degrees. Vertical section is from N 0.00 E 0.00 on azimuth 294.95 degrees. Calculation uses the minim~ curvature method. Presented by Baker Hughes INTEQ ARCO Alaska. Inc. Pad 3H. 32PB1 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 4 Your ref : 32 PB1 Version #2 Last revised : 21-Dec-1999 Dogleg Vert Deg/lOOft Sect 13775.64 76.26 353.44 5986.00 4493.42 N 10180.17 W 3.00 11125.56 Top Kuparuk A1 13800.00 76.07 354.17 5991.83 4516.94 N 10182.72 W 3.00 11137.80 13888.74 75.36 356.82 6013.73 4602.66 N 10189.48 W 3,00 11180.09 EOC 13901.70 75.36 356.82 6017.00 4615.17 N 10190.18 W 0.00 11186.00 Base A1 14000.00 75.36 356.82 6041.84 4710.14 N 10195.46 W 0.00 11230.84 14036.23 75.36 356.82 6050.99 4745.14 N 10197.40 W 0.00 11247.37 TD-Pilot Hole 14036.25 75.36 356.82 6051.00 4745.17 N 10197.40 W 0.00 11247.38 3H-32PB1TD 14-Dec-99 All data is in feet unless otherwise stated. Coordinates from slot #32 and TVD from Nabors 16E (73.00 Ft above mean sea level). Bottom hole distance is 11247.38 on azimuth 294.95 degrees from wellhead. Total Dogleg for wellpath is 188.12 degrees. Vertical section is from N 0.00 E 0.00 on azimuth 294.95 degrees. Calculation uses the minim~n curvature method. Presented by Baker Hughes INTEQ ,, ° ARCO Alaska, Inc. Pad 3H.32PB1 Kuparuk River Unit. North Slope. Alaska PROPOSAL LISTING Page 5 Your ref : 32 PB1 Version #2 Last revised : 21-Dec-1999 Con~ents in wellpath MD TVD Rectangular Coords. Comment 250.00 800.00 1200.00 1747.96 2800.00 2912.00 3362.82 3633.03 4687.64 5257.78 11645.91 12547.93 13175.86 13300.02 13583.50 13675.84 13771.42 13775.64 13888.74 13901.70 14036.23 14036.25 250.00 798.10 1186.58 1673.00 2328.06 2369.89 2528.20 2623.00 2993.00 3193.00 5434.23 5722.00 5868.00 5889.77 5943.00 5963.00 5985 O0 5986 O0 6013 73 6017 O0 6050 99 6051 O0 0.00 N 0.00 E KOP-Begin 1.5 Deg/lO0' Build 19.76 N 34.23 W Begin 3 Deg/lO0' Build & Turn 39.86 N 124.21W Begin Right Turn/Cont. Build 79.76 N 369.18 W Base of Permafrost 263.30 N 1154.22 W Begin Left Turn/Cont. Build 286.65 N 1255.44 W End of Build/Begin 1.5 Deg Turn 400.17 N 1661.71W EOC 483.47 N 1900.64 W Top of West Sak 808.61 N 2833.16 W Base of West Sak 984.41N 3337.29 W 9-5/8" Casing Pt 2953.82 N 8985.88 W Begin Build & Turn 3420.45 N 9691.62 W Base HRZ/Top Kalubik 3928.75 N 10024.90 W K-l/Top Lower Kalubik 4041.86 N 10071.20 W Begin Angle Drop & Cont. Turn 4308.76 N 10149.59 W Top Kuparuk D 4397.27 N 10166.59 W Top Kuparuk C4 4489.35 N 10179.70 W Top Kuparuk B 4493.42 N 10180.17 W Top Kuparuk A1 4602.66 N 10189.48 W EOC 4615.17 N 10190.18 W Base A1 4745.14 N 10197.40 W TD-Pilot Hole 4745.17 N 10197.40 W 3H-32PB1TD 14-Dec-99 Casing positions in string 'A' Top MD Top TVD Rectangular Coords. Bot MD Bot ll/D Rectangular Coords. Casing 0.00 O. O0 O.OON O.OOE 5257.78 3193.00 984.41N 3337.29W 9-5/8" Casing Targets associated with this wellpath Target name Geographic Location T.V.D. Rectangular Coordinates Revised 3H-32PB1TD 14-Dec-9 488460.000,6005360.000.0.0000 6051.00 4745.17N 10197.40W 14-Dec-1999 ARCO Alaska. Inc. Pad 3H 32 slot #32 Kuparuk River Unit North Slope. Alaska SUMMARY CLEARANCE by Baker Hughes INTEQ REPORT Your ref : 32 VersionS8 Our ref : prop904 License : Date printed : 22-Dec-1999 Date created : 5-0ct-1993 Last revised : 21-Dec-1999 Field is centred on n70 16 18.576,w150 5 56.536 Structure is centred on n70 24 56.740,w150 0 47.688 Slot location is n70 24 46,472,w150 0 39.421 Slot Grid coordinates are N 6000613.087, E 498655.349 Slot local coordinates are 1044.00 S 282.00 E Projection type: alaska - Zone 4, Spheroid: Clarke - 1866 Reference North is True North Object wellpath PMSS <6133 - 7755'>.,13A,Pad 3H PGMS <O-7370'>.,13.Pad 3H PG~S <0-9360'>,.23.Pad 3H PMSS <7640 - 9875'>,,23A.Pad 3H PMSS <1743-6660'>,.26.Pad 3H PGMS <0-8095'>,,4,Pad 3H PGMS <0-7987'>..6,Pad 3H PGMS <O-7750'>,,11,Pad 3H PGMS <0-7155'>, 5,Pad 3H PMSS <461-12044'> .24,Pad 3H PGMS <0-8167'> PGMS <0-9555'> PGMS <0-8620'> PGMS <0-7310'> PGMS <0-8350'> PGMS <0-6785'>. PGMS <0-8614'>, PC¢4S <0-8250'>, PGMS <0-7298'>. PGMS <0-10234'> PG~S <0-11346'> I Pad 3H 3 Pad 3H 7 Pad 3H 9 Pad 3H 2 Pad 3H 10 Pad 3H 17 Pad 3H 14 Pad 3H 12 Pad 3H ,22,Pad 3H ,21,Pad 3H PMSS <1506-2076'>,,20,Pad 3H PMSS <1622-4449'>,,20,Pad 3H PGMS <0-9050'>.,20,Pad 3H PMSS <1506-3878'>,.20.Pad 3H PGMS <O-8650'>.,19,Pad 3H PGMS <0-12410'>,.25,Pad 3H Closest approach with 3-D Minimum Distance method Last revised Distance M.D. Diverging from M.D. 7-Jan-1999 9081.0 13300.0 15825.5 13-Nov-1991 8514.8 13300.0 13300.0 7-Nov-1996 5715.4 13300.0 13300.0 7-Jan-1999 5978.7 14874.0 14874.0 7-Jan-1999 11064.4 13300.0 13300.0 13-Nov-1991 12089.6 13300.0 13300.0 13-Nov-1991 7156.6 13300.0 13300.0 13-Nov-1991 12068.0 13300.0 13300.0 13-Nov-1991 10872.8 13300.0 13300.0 14-Feb-1996 7291.3 15856.1 15856.1 13-Nov-1991 11504.2 13300.0 13300.0 13-Nov-1991 12090.7 13300.0 13300.0 13-Nov-1991 9176.4 13300.0 13300.0 13-Nov-1991 11885.0 13300.0 13300.0 13-Nov-1991 12088.2 13300.0 13300,0 13-Nov-1991 11267.2 13300.0 13977.8 13-Nov-1991 11017.1 13300.0 14481.0 13-Nov-1991 11737.6 13300.0 14253.0 13-Nov-1991 11096.1 13300.0 13300.0 13-Nov-1991 10888.3 13300.0 15585.0 13-Nov-1991 11559.2 13300.0 13300.0 13-Nov-1991 11660.6 13300.0 13300.0 13-Nov-1991 11686.7 13300.0 13300.0 13-Nov-1991 11688.8 13300,0 13300.0 13-Nov-1991 11578.4 13300.0 13300.0 14-Feb-1996 8449.7 13300.0 14499.0 17-Feb-1999 1637.1 13300.0 13300.0 PGMS <0-6881'>, ,8.Pa . PGMS <0-8460' >,, 15, Pad 3H PMSS <12259 - 13247'>. ,25APB2. Pad 3H PMSS <11231' - 14458'>, ,25APB1,Pad 3H PMSS <12256 - 15240'>, ,25A,Pad 3H PGMS <0- 9770 '>,, 16. Pad 3H PGMS <0-10293 '>,, 18. Pad 3H 28 <0-14940' > I f Gyroed, ,28, Pad 3H PMSS <7395 - 12575'>, ,28A,Pad 3H PMSS <549 - 14940'>, ,28,Pad 3H PMSS <5706 - 8867'>, ,28A,Pad 3H PG~S <0-10730' >,. 31, Pad 3H 13-Nov-1991 13-Nov-1991 16-~un-1999 16-2un-1999 16-Ju1-1999 13-Nov-1991 13-Nov-1991 7-Dec-1999 7-Dec-1999 7-Dec-1999 28-Feb-1996 14-Feb-1996 8757.4 5847.9 431.6 268.0 211.6 5320.8 3174.8 655.1 1903.2 655.1 4443.6 8657.8 13300.0 13300.0 13300.0 13300.0 13300.0 13300.0 13300.0 13300.0 14757.1 13300.0 13300.0 15856.1 13300.0 13300.0 13300.0 13300.0 13300.0 13300.0 13300.0 13300.0 14757.1 13300.0 13300.0 15856.1 ARCO Alaska, Inc. Diverter Schematic Pool #6 21 ~,4" 2,000 psi WP DRILLING SPOOL w/16" Outlet Flowline 21 ~,4" HYDRIL MSP 2,000 psi WP ANNULAR PREVENTER 16" 200 psi WP HYDRAULIC KNIFE VALVE 16" 62 ppf PEB CONDUCTOR PIPE set at 80' (GL) ARCO Alaska, Inc. POOL #6 13-5/8" 5,000 PSI BOP COMPONENTS ¼ J I I 3" 5,000 psi WP OCT MANUAL GATE V KILL LINE 3" 5,000 psi WP Shaffer GATE VALVE ] w/hydraulic actuator / J / BSA 13-5/8" 5,000 psi WP -~"~"L x 11" 3,000 psi WP \ 13-5/8" 5,000 psi WP, HYDRIL Type GK ANNULAR PREVENTER w/companion flange to bell nipple DOUBLE 13-5/8" 5,000 psi WP, HYDRIL Magnum BOP w/pipe rams on top and blind rams on bottom b I 3" 5,000 psi WP Shaffer GATE VALVE ~ ~draulicactuator 13-5/8" 5,000 psi WP DRILLING SPOOL [--]'~~ w/two 3" 5M psi WP outlets I ] SINGLE 13-5/8" 5,000 psi WP, HYDRIL MPL BOP w/pipe rams I ARCO Alaska, Inc. Drill and Case Plan for 3H-32 Kuparuk Producer General Procedure: 1. Excavate cellar, install cellar box, set and cement 16" conductor to +/- 120' RKB. Weld landing ring on conductor. 2. Hove in / rig up drilling rig. ~[nstall diverter & function test same. 3. Spud and directionally drill 12 1/4" hole to the surface casing point at 5258' HD/3193' TVD. Run MWD / LWD logging tools in drill string as required for directional monitoring and formation data gathering. 4. Condition hole for casing, trip out. 5. 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. 6. Nipple down diverter, nipple up BOP's. Test BOP's. Notify AOGCC 24 hours before test 7. Hake up 8 1/2" bit and BHA and R[H to top of float equipment · Pressure test casing to 3000 psi for 30 minutes · Record results and fax to town 8. Drill float equipment and approximately 20' of new hole · Perform LOT · Record results and fax to town 9. Drill 8 1/2" pilot hole to _+14036' HD/6051' TVD to and run LWD logs for Kuparuk C and Kuparuk A sand evaluation. 10. Plug well back to ~13,300' and kick off to directionally drill into Kuparuk sands. Drill to 14022' MD/5963' TVD and ~88°. 11. Run and cement 7" 26# L80 BTC-Mod 12. Hake up 6 1/8" bit and BHA and R[H to top of float equipment · Pressure test casing to 3000 psi for 30 minutes · Record results and fax to town 13. Drill float equipment and approximately 20' of new hole · Perform LOT · Record results and fax to town :[4. Drill 6 1/8" hole to TD at 15856' MD/5993' TVD · Condition hole and mud for casing 15. Run and cement 3 1/2" 9.3# L80 EUE Liner 16. Hake 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 17. Run and land 3 1/2" tubing with gas lift completion 18. Nipple down BOP's. Tnstall production tree and pressure test same. 19. Secure well, release rig. ARCO Alaska, Inc. DRILLING FLUID PROGRAM, PRESSURE CALCULATIONS, AND DRILLING AREA RISKS Well KRU 3H-32 Drilling Fluid Properties: Spud to surface casing point Density PV YP Funnel Vis Initial Gel 10 Minute Gel API Filtrate pH % Solids 9.5-10.2 ppg 16-26 25-35 100- 120' Drill out to TD 9.5 - 10.8 ppg 6-20 5-20 35-50 10-20 15-40 7-15 9.5-10 +10% 2-6 4-8 <6 through Kup 9.0-10 <11% Drilling Fluid System: Triple Derrick Shale Shakers Desander, Desilter, Mud Cleaner Centrifuge Degasser Pit Level Indicator (Visual and Audio Alarm) Trip Tank Fluid Flow Sensor I Fluid Agitators *Spud mud should be adjusted to a FV between 100-200 sec/qt to drill gravel beds Drilling fluid practices will be in accordance with the regulations stated in 20 AAC 25.033. Maximum Anticipated Surface Pressure: Maximum anticipated surface pressure (HASP) while drilling the production hole is calculated using a surface casing leak-off of 13.5 ppg EMW (0.70 psi/ft) and a gas gradient of 0.:11 psi/ft. This shows that formation breakdown would occur at a surface pressure of 1~883 psi. Therefore ARCO will test the BOP equipment to 3,500 psi affcer setting surface casing. HASP = (3,193 ft)(0.70 - 0.11) = 1,883 psi Based on offset well data, reservoir pressures in the Kuparuk sands in the vicinity of 3H pad are expected to be ~,3185 psi (0.53 psi/R). Assuming a 150 psi overbalance is required to safely drill and trip in this formation, then a required mud weight of :10.8 ppcj can be predicted as the maximum mud weight needed to safely drill in this formation, assuming a TVD of S,963'. Target (Kuparuk C4) (3185+ 150)/(0.052'5963)= 10.8 Well Proximity Risks: The nearest well to 3H-32 is 3H-28. The wells are 496' from each other at a depth of 14032' MD. Drilling Area Risks: Drilling risks in the 31-1-32 area are surface interval hydrates, lost circulation and potential borehole instability in and below the permafrost formation as well as through the intermediate shales. Hydrate risks will be minimized by the use of sufficient mud weights to allow for tripping of pipe, controlled drilling rates, and optimum rheological properties to safely appropriate gas breakout. Lost circulation will be ARCO Alaska, Inc. addressed with lost circulation material (L£rvl). Shale instability will be controlled primarily with the planned fluid densities. Annular Pumping Operations: Incidental fluids developed from drilling operations will be either injected into an approved annulus on the same pad or hauled to the nearest permitted Class II disposal well. (Note that cement rinseate will not be injected down the dedicated disposal well but will be recycled or held for an open annulus.) The open annulus will be left with a non-freezing fluid during any extended shut down (> 4 hr) in pumping operations. The 3H-32 surface/production casing annulus will be filled with diesel after setting production casing and prior to the drilling rig moving off of the well. If isolation is required per regulations over significant hydrocarbons, then sufficient cement volume will be pumped during the production cement job to cover those formations. At the end of drilling operations, a request for 3H-32 to be permitted for annular pumping of fluids occurring as a result of future drilling operations on 3H pad, per regulation 20 AAC 25.080, will be submitted. 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 200' vertically below the base of the West Sak into the heart of the shales. The surface and production casing strings exposed to the annular pumping operations have sufficient strength by using the 85% collapse and burst ratings listed in the following table: Wt Connection 85% of 85% of OD (ppf) Grade Range Type Collapse Collapse Burst Burst 9-5/8" 40 L-80 3 BTC 3,090 psi NA 5,750 psi 4,888 psi 7" 26 L-80 3 LTC-IVlod 5,410 psi 4,599 psi 7,240 psi 6,154 psi 31/2''* 9.3 L-80 2 8rd EUE Mod 10,530 psi 8,951 psi 10,160 psi 8,636 psi * if needed 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). All Depths are RKB Nabors Rig 16e I FMC Gen IV 9-5/8 x 7 I 9-5/8 .... ... ~ Mandrel H;n;;; ........... "i Base of permafrost at 1,748' MD / 1,673' TVD 12-1/4" Top of West Sak at 3,633' MD / 2,623' TVD Base of West Sak 4,687' MD / 2,993' TVD 9-5/8" 40 ppf L-80 BTC Surface Casing 5,258' MD / 3,193' TVD 8-1/2" Hole Baker 3.5" x 7" ZXP LTP and tieback sleeve and HMC Liner Hanger w/PBR @ 13850' MD Weatherford Gemoco 7" Float Collar and Float Shoe Baker 3-1/2" Landing Collar, Float Collar and Float Shoe (1 jt. spacing between each) Completion Type 2 3H-32 Drdl and set Casing J · . . 16" Conductor Mud Weight in Surface hole: 10. 0 ppg by 1100' TVD 10.2 ppg by 1700' TVD Weatherford Gemoco 9-5/8" Float Collar and Float Shoe Mud Weight in Production hole 10.8 ppg i:i:i:i 7" 26 L-80 BTC Mod Csg ::::::: 14,022' MD / 5,962' 'I-VD .': 3-1/2" 9.3#/ft L-80 EUE 12/27/1999 Completed 3H-32 FMC Gen V 9-5/8 x 7 x 31/2 Base of permafrost at 1,748' MD / 1,673' TVD 12-1/4" Hole 9-5/8" 40 ppf L-80 BTC-Mod Surf. Csg. 5,258' MD / 3,193' TVD 31/2'' 9.3 ppf L-80 8rd EUE tubing w/15' seal bore extension tied 7" 26 ppf L-80 BTC Intermediate. Csg. 14,022' MD / 5,962' TVD Baker 3.5" x 7" ZXP LTP and tieback sleeve and HMC Liner Hanger. TOL @ 13850' MD/5951 ' TVD L.~I Ir-- I I ' .'.'.'. · ;.;.;. ..2.:. .:.:.:. ....:. .;-:.;~ :::::: ' . . . · . . :;:;::; ...... :.:.:.: :i:i:i: I I .'.'.'.' :::;:;: ~ ~< :::::::: · . · . , · . · . o · , , ;-:.:.; ..;.: .;.:.;. -.... ., , ·, . · , · . · , . · . · . . · . · · . 81/2" Hole 6-1/8" Hole 2.875" CAMCO DS nipple for SCSSV at 500' + MD 31/~" x 1" side pocket GLM CAMCO 2.812" 3-1/2"Slimhole Completion 12/27/1999 6OO 60O 200 800 Q. 2400 5000 5600 4200 I V 4800 5400 6000 6600 Crsoted by rixee FOR: [,iX)YD Dole plotted : 21-Dec-lB99 Plot Reference is 32 PB1 Version 1~2. I Coordlnotss ore in feet reference -lot 1~52 . I ]'rue Vsrlllcol Dep{hs ore reference Nobors 16£.I ARCO Alaska, Inc. Sfruafure : Pad 3H Well : $2PB1 Field : Kuparuk River Unlt Loooflon : Nor"Ih Slope, Alaska RKB ELEVATION: 7,3' 1.50 KOP-Begin 1.5 Dog/lO0' Build 4.50 DLS: 1.50 dog per 100 ft ~'05.~9 aegin 3 Deg/IO0' Build & Turn 16.1.3 Begin Right Turn/Cont. Build ~, 21.91 k 27.80 DLS: .3.00 deg per 100 ft ~, 53.73 Bose of Permofrost %. 39.70 '% 45.69 DLS: `3.00 dog per 100 ft ~, ,51.68 "~ 60.68 Begin Left Turn/Cent Build [0C~~9'17§9 45End of Build/Begin' 1.5 Dog Turn Top of West Sok ~ Bose of West 5ok TANGENT ANGLE ;g94.95 AZIMUTH 11247' (TO PB1 TD) ***Plone of Proposol*** Begin Build & Turn ~ Base HRZ/Top Kolubik ~ K- 1/Top Lower Kolubik Begin Angle Drop & Cont. Turn ~ Top of Kuparuk D ~~ Top Kuparuk C4 Top Kuporuk B Top Kuporuk A1 Bose A1 'rD-Pilot Hole 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 i i i i ! i ! i i i i ! 600 0 600 1200 1800 2400 3000 3600 4200 4000 5400 6000 6600 7200 7800 8400 9000 9600 10200 10800 ] ] 400 ] 2000 ] 2600 Verticol Section (feet) -> Azimuth 294.95 with reference 0.00 N, 0.00 E from slot //32 Creoted by rixse FOR: LLOYI~ Dote plotted : 21-Dec-199g I Plot Reference is 5.7 PB{ Version 1~12. l Coordinates ore {n feet reference slot ~52 'l True Vertical Depthe ore refermnce Nobore I§E.I ARCO Alaska, Inc. TARGET #5: 6' FNL, 648' FWL SEC. 5, T12N, R8E TARGET 954' FNL, 648' FWL SEC. 5, T12N, RBE Structure : Pad SH Well : 52P81 Field : Kuparuk River Unlt Location : North Slope, Alaska 11400 10800 10200 9600 9000 8400 7800 7200 6600 I I J I I I I I J i I I I J i { { EOC TD- Pilot Hole TARGET ~1 & TD 5H-52 PBI: 15§6' FNL, 647' FWL SEC. 5, T12N, RSE <- West (feet) 6000 5400 4800 4200 5600 ,~000 I I I i { { J J I { I Target ~6-TD/Caslng Pt Top Kuparuk A1 Top Kuparuk B Target ~5/Begin Drop EOC Target ~4/Begin Drop EOC Target ~5/Begin Build Target 1~2/Begln Build Target ~l/Top C4/Beg}n Turn 7" Casing Pt Top Kuporuk A1 Top Kuparuk C4 Top Kuporuk B Top Kuporuk D Begin Angle Drop & Cont. Turn SideTrack Pt/Cant Build &' Turn K-l/Top Lower Kalublk Bose HRZ/Top Kolubik TARGET t~6: TD LOCATION 3H-52: 244' FSL, 1700' FWL SEC. 33, T13N, RBE TARGET f~4: L 479' FNL, 648' FWL SEC. 3, T12N RSE ITARGET t~2: 1245' FNL, 647' FWL SEC. 3, T12N, RBE Begin Build & Turn SURFACE LOCATION: 1044' FNL, 282' FWL SEC. 12, T12N, RBE 2400 1800 1200 600 0 600 I I I I I I I I I I 7200 6600 6000 5400 4800 3600 0 2400 ~-~ 1800 , ~ ~ ~ 12oo Beg~~ 0 Begin 3 Deg/lO0' Build & Turn 600 525O 5400 555O · 4,- 5700 5~50 -4.- O §000 6150 6500 6450 66OO 6750 69O0 7050 Creoted by rixee FOR.' U. OYD ] Dote plotted : 21-Dec-1999 Plot Reference is 52 PB1 Version 1~12. I Coordlnetes are in feet reference elot t~52 . I ]'rue Verticol Oepthe ore reference Nobors 16E.I ARCO Alaska, Inc. Sfruofure : Pod 3H Well : 52PB1 Field : Kuporuk Rlver Unlf Locofion : North Slope, AIosko O. 0 DEG ***Plane of Proposal*** i [ i [ [ I I i i [ [ i i i [ i ! [ [ ! [ [ i ! i [ [ [ i [ [ [ i i [ i i [ i i [ i i 1 3600 3750 3900 4050 4200 4350 4500 4650 4800 4950 5100 5250 5400 5550 5700 5850 6000 6150 6300 6450 6600 6750 6900 Vertical Section (feet) -> Azimuth 0.00 with reference 0.00 N, 0.00 E from slot #52 Creoted by rixee FOR: LLOYI~ Dote plotted : 21-Dec-1999/ Plot Reference }. 52 PB~ Vereion t~12. l Coord;note. ore ;n feet reference I~lot ~52 'l ITru. Verflcol Depth. ore reference Noborl 16E.I I ! ARCO Alaska, Inc. Structure : Pad SH Well : $2PB1 Field : Kuparuk River Unit Location : North Slope, Alaska Point KOP-Begin 1.5 Dog/1 Begin 3 Dog/lO0' But Begin Right Turn/Con Bose of Permofrost Begin Left Turn/Cont End of Build/Begin 1 EOC Top of West Sok Bose of West Sok 9-5/8 Cosing Pt Begin Build & Turn Bose HRZ/Top Kolubik K-l/Top Lower Kolubi Begin Angle Drop & C Top Kuporuk D Top Kuporuk C4 Top Kuporuk B Top Kuporuk A1 EOC Bose A1 TD-Pilot Hole PROFILE COM M ENT DATA MD Inc Dir TVD North East V. Sect Deg/1 O0 250.00 0.00 300.00 250.00 0.00 0.00 0.00 0.00 800.00 8.25 500.00 798.1 0 19.76 -54.25 59.58 1.50 1200.00 18.98 275.00 1186.58 59.86 - 124.21 129.45 5.00 1747.96 55.16 281.65 1675.00 79.76 -569.18 568.57 5.00 2800.00 66.67 284.00 2528.06 263.50 - 1154.22 11 57.57 3.00 2912.00 69.47 282.00 2569.89 286.65 - 1255.44 1259.20 5.00 5562.82 69.46 289.22 2528.20 400.17 - 1661.71 1675.44 1.50 3633.04 69.46 289.22 2623.00 483.48 - 1900.65 1927.22 0.00 4687.70 69.46 289.22 2993.00 808.65 -2833.21 2909.92 0.00 5257.78 69.46 289.22 3193.00 984.41 -3337.29 3441.10 O.OC' 11 645.91 69.46 289.22 5434.23 2953.82 -8985.88 9393.29 0.00 12547.93 74.02 317.35 5722.00 3420.45 -9691.62 10230.00 3.00 13175.86 79.31 335.94 5868.00 3928.75 -10024.90 10746.59 3.00 13300.02 80.50 339.53 5889.77 4041.86 -10071.20 10836.28 3.00 13583.50 77.89 347.77 5943.00 4308.76 -10149.59 11019.94 3.00 13675.84 77.09 350.49 5963.00 4397.27 -10166.59 11072.70 3.00 13771.42 76.30 353.32 5985.00 4489.35 -10179.70 11123.42 3.00 13775.64 76.26 353.44 5986.00 4493.42 -10180.17 11125.56 3.00 13888.74 75.36 356.82 6013.73 4602.66 -10189.48 11180.09 3.00 13901.70 75.36 356.82 6017.00 4615.17 -10190.18 11186.00 0.00 ICreoted by rixse FOR: LLOYD Dote plotted : 25-Dec-1999 Plot Reference Ts 52 Version ~18 . Coordinotes ore in feet reference slot t~32 . True Vertlcol Depths ore reference Nobors 16£. ARCO Alaska, Inc. Structure: Pad 5H Well : ,52 Irleld : Kuparuk River Unit Looatlon : North Slope, Alasko Point SideTrack Pt/Cant Bu -- Top of Kuporuk D EOC 7 Casing Pt Target #1/Top C4/Beg -- Top Kuparuk C4 EOC arget #2/Begin Buil-- EOC Target #3/Begin Buil-- EOC Target #4/Begin Drop -- EOC Target #b/Begin Drop -- Top Kuporuk B Top Kuporuk A1 _T__D__-_...~.~ _s._!.__n_.g ,, p.! PROFILE COMMENT MD Inc Dir TVD 13300.00 80.50 339.53 5889.77 13711.17 84.67 551.24 5943.00 14008.67 87.84 559.60 5962.47 14022.07 87.84 559.60 5962.98 14022.58 87.84 559.60 5965.00 14022.60 87.84 359.60 5965.00 14051.25 87.99 0.00 5964.04 14565.82 87.99 0.00 5975.00 14425.57 88.92 559.99 5976.67 14654.92 88.92 359.99 5981.00 14845.89 91.78 559.99 5979.84 15150.12 91.78 559.99 5971.00 15178.73 91.05 359.99 5969.80 15605.26 91.05 359.99 5962.00 15825.50 76.92 559.99 5985.00 15827.68 76.64 359.99 5986.00 15856.04 74.81 559.99 5992.99 DATA North 4041.84 4455.63 4751.25 4744.64 4745.15 4745.17 East V. Sect Deg/1 O0 -10071.19 4041.84 0.00 -10173.67 4435.63 5.00 -10197.51 4751.25 5.00 -10197.40 4744.64 0.00 -10197.40 4745.15 0.00 -10197.40 4745.17 0.00 -10197.50 4775.80 1.50 -10197.48 5086.18 0.00 -10197.48 5147.91 1.50 -10197.54 5577.21 0.00 -10197.58 5568.16 1.50 -10197.64 5852.25 0.00 -10197.65 5900.85 1.50 -10197.75 6525.51 0.00 -10197.79 6545.58 6.42 - 10197.80 6547.84 6.42 -10197.80 6575.55 6.42 4773.80 5086.18 5147.91 5377.21 5568.1 6 5852.25 5900.85 6325.31 6543.58 6547.84 6575.33 ARCO Alaska, Inc. Pod ;SH W~II : 32PB1 510 21 O0 32~ 1900 ,54O 55O TRUE NORTH ,350 0 10 20 ,30 1 O0 300 60 29O 70 280 80 270 90 26O lO0 25O 110 240 2700 0 220 210 5900 1250O 2_ )C) ~ 190 0 170 1 O0 160 1500 300 ~40 300 ~00 120 Normol Plane Travelling Cylinder - Feet All depths shown are Measured depths on Reference ARCO Alaska, Inc. Pad 3H 32PB1 slot #32 Kuparuk River Unit North Slope, A1 aska PROPOSAL LISTING by Baker Hughes INTEQ Your ref : 32 PBi Version#2 Our ref : prop3773 License : Date printed : 22-Dec-1999 Date created : 9-Dec-1999 Last revised : 21-Dec-1999 Field is centred on n70 16 18.576.w150 5 56.536 Structure is centred on n70 24 56.740,w150 0 47.688 Slot location is n70 24 46.472,w150 0 39.421 Slot Grid coordinates are N 6000613.087, E 498655.349 Slot local coordinates are 1044.00 S 282.00 E Projection type: alaska - Zone 4, Spheroid: Clarke - 1866 Reference North is True North ARCO Alaska, Inc. Pad 3H,32PB1 Kuparuk River Unit,North Slope, Alaska PROPOSAL LISTING Page 1 Your ref : 32 PB1 Version#2 Last revised : 21-Dec-1999 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 Dogleg Vert Deg/lOOft Sect 0.00 0.00 300.00 0.00 0.00 N 0.00 E 250.00 0.00 300.00 250.00 0.00 N 0.00 E 350.00 1.50 300.00 349.99 0.65 N 1.13 W 450.00 3.00 300.00 449.91 2.62 N 4.53 W 550.00 4.50 300.00 549.69 5.89 N 10.20 W 0.00 0.00 0.00 0.00 KOP-Begin 1.5 Deg/lO0' Build 1.50 1.30 1.50 5.21 1.50 11.73 650.00 6.00 300.00 649.27 10.46 N 18.12 W 750.00 7.50 300.00 748.57 16.34 N 28.30 W 800.00 8.25 300.00 798.10 19.76 N 34.23 W 900.00 10.69 289.25 896.74 26.41 N 49.20 W 1000.00 13.35 282.59 994.54 31.98 N 69.23 W 1.50 20.84 1.50 32.55 1.50 39.38 Begin 3 Deg/lO0' Build & Turn 3.00 55.75 3.00 76.26 1100.00 16.13 278.15 1091.25 36.47 N 94.25 W 1200.00 18.98 275.00 1186.58 39.86 N 124.21 W 1300.00 21.91 276.90 1280.27 43.51 N 158.94 W 1400.00 24.85 278.36 1372.06 48.81 N 198.25 W 1500.00 27.80 279.53 1461.68 55.73 N 242.05 W 3.00 100.84 3.00 129.43 Begin Right Turn/Cont. Build 3.00 162.46 3.00 200.34 3.00 242.97 1600.00 30.77 280.50 1548.89 64.25 N 290.21 W 1700.00 33.73 281.31 1633.45 74.36 N 342.60 W 1747.96 35.16 281.65 1673.00 79.76 N 369.18 W 1800.00 36.71 282.00 1715.13 86.02 N 399.07 W 1900.00 39.70 282.30 1793.71 99.04 N 459.53 W 3.00 290.23 3.00 341.99 3.00 368.37 Base of Permafrost 3.00 398.12 3.00 458.42 2000.00 42.70 282.57 1868.94 113.23 N 523.84 W 2100.00 45.69 282.80 1940.63 128.54 N 591.84 W 2200.00 48.69 283.02 2008.58 144.93 N 663.34 W 2300.00 51.68 283.21 2072.60 162.36 N 738.14 W 2400.00 54.68 283.39 2132.52 180.78 N 816.04 W 3.00 522.72 3.00 590.83 3.00 662.57 3.00 737.74 3.00 816.14 2500.00 57.68 283.56 2188.17 200.13 N 896.82 W 2600.00 60.68 283.71 2239.40 220.38 N 980.27 W 2700.00 63.67 283.86 2286.08 241.45 N 1066.14 W 2800.00 66.67 284.00 2328.06 263.30 N 1154.22 W 2900.00 69.17 282.21 2365.65 284.30 N 1244.47 W 3.00 897.55 3.00 981.75 3.00 1068.50 3.00 1157.57 Begin Left Turn/Cont. Build 3.00 1248.25 2912.00 69.47 282.00 2369.89 286.65 N 1255.44 W 3000.00 69.45 283.41 2400.77 304.77 N 1335.83 W 3100.00 69.43 285.01 2435.89 327.76 N 1426.59 W 3200.00 69.43 286.61 2471.03 353.27 N 1516.67 W 3300.00 69.45 288.22 2506.15 381.29 N 1606.00 W 3.00 1259.20 End of Build/Begin 1.5 Deg Turn 1.50 1339.72 1.50 1431.71 1.50 1524.14 1.50 1616.96 3362.82 69.46 289.22 2528.20 400.17 N 1661.71 W 3400.00 69.46 289.22 2541.24 411.63 N 1694.59 W 3500.00 69.46 289.22 2576.33 442.46 N 1783.01 W 3600.00 69.46 289.22 2611.41 473.29 N 1871.43 W 3633.03 69.46 289.22 2623.00 483.47 N 1900.64 W 1.50 1675.44 EOC 0.00 1710.08 0.00 1803.26 0.00 1896.43 0.00 1927.21 Top cf West Sak 3700.00 69.46 289.22 2646.50 504.12 N 1959.86 W 0.00 1989.61 3800.00 69.46 289.22 2681.58 534.95 N 2048.28 W 0.00 2082.78 3900.00 69.46 289.22 2716.66 565.78 N 2136.70 W 0.00 2175.96 4000.00 69.46 289.22 2751.75 596.61 N 2225.13 W 0.00 2269.14 4100.00 69.46 289.22 2786.83 627.44 N 2313.55 W 0.00 2362.31 4200.00 69.46 289.22 2821.92 658.27 N 2401.97 W 0.00 2455.49 4300.00 69.46 289.22 2857.00 689.10 N 2490.40 W 0.00 2548.66 4400.00 69.46 289.22 2892.08 719.93 N 2578.82 W O.O0 2641.84 4500.00 69.46 289.22 2927.17 750.76 N 2667.24 W 0.00 2735.02 4600.00 69.46 289.22 2962.25 781.59 N 2755.66 W 0.00 2828.19 All data is in feet unless otherwise stated. Coordinates from slot #32 and TVD from Nabors 16E (73.00 Ft above mean sea level). Bottom hole distance is 11247.38 on azimuth 294.95 degrees from wellhead. Total Dogleg for wellpath is 188.12 degrees. Vertical section is from N 0.00 E 0.00 on azimuth 294.95 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ ARCO Alaska, Inc. Pad 3H,32PB1 Kuparuk River Unit,North Slope. Alaska PROPOSAL LISTING Page 2 Your ref : 32 PB1Version~P2 Last revised : 21-Dec-1999 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 t N A T E S Deg/lOOft Sect 4687.64 69.46 289.22 2993.00 808.61 N 2833.16 W 0.00 4700.00 69.46 289.22 2997.34 812.42 N 2844.09 W 0.00 4800.00 69.46 289.22 3032.42 843.25 N 2932.51 W 0.00 4900.00 69.46 289.22 3067.51 874.07 N 3020.93 W 0.00 5000.00 69.46 289.22 3102.59 904.90 N 3109.36 W 0.00 2909.85 Base of West Sak 2921.37 3014.54 3107.72 3200.89 5100.00 69.46 289.22 3137.67 935.73 N 3197.78 W 0.00 5200.00 69.46 289.22 3172.76 966.56 N 3286.20 W 0.00 5257.78 69.46 289.22 3193.00 984.41 N 3337.29 W 0.00 5300.00 69.46 289.22 3207.81 997.43 N 3374.63 W 0.00 5400.00 69.46 289.22 3242.90 1028.26 N 3463.05 W 0.00 3294.07 3387.25 3441.10 9-5/8" Casing Pt 3480.44 3573.61 5500.00 69.46 289.22 3277.98 1059.09 N 3551.47 W 0.00 3666.79 5600.00 69.46 289.22 3313.06 1089.92 N 3639.89 W 0.00 3759.97 5700.00 69.46 289.22 3348.14 1120.75 N 3728.32 W 0.00 3853.14 5800.00 69.46 289.22 3383.23 1151.59 N 3816.74 W 0.00 3946.32 5900.00 69.46 289.22 3418.31 1182.42 N 3905.16 W 0.00 4039.49 6000.00 69.46 289.22 3453.39 1213.25 N 3993.59 W 0.00 4132.67 6100.00 69.46 289.22 3488.48 1244.08 N 4082.01 W 0.00 4225.85 6200.00 69.46 289.22 3523.56 1274.91 N 4170.43 W 0.00 4319.02 6300.00 69.46 289.22 3558.64 1305.74 N 4258.86 W 0.00 4412.20 6400.00 69.46 289.22 3593.73 1336.57 N 4347.28 W 0.00 4505.38 6500.00 69.46 289.22 3628.81 1367.40 N 4435.70 W 0.00 4598.55 6600.00 69.46 289.22 3663.89 1398.23 N 4524.13 W 0.00 4691.73 6700.00 69.46 289.22 3698.98 1429.06 N 4612.55 W 0.00 4784.90 6800.00 69.46 289.22 3734.06 1459.89 N 4700.97 W 0.00 4878.08 6900.00 69.46 289.22 3769.15 1490.72 N 4789.39 W 0.00 4971.26 7000.00 69.46 289.22 3804.23 1521.55 N 4877.82 W 0.00 5064.43 7100.00 69.46 289.22 3839.31 1552.38 N 4966.24 W 0.00 5157.61 7200.00 69.46 289.22 3874.40 1583.21 N 5054.66 W 0.00 5250.78 7300.00 69.46 289.22 3909.48 1614.04 N 5143.09 W 0.00 5343.96 7400.00 69.46 289.22 3944.56 1644.87 N 5231.51 W 0.00 5437.14 7500.00 69.46 289.22 3979.65 1675.70 N 5319.93 W 0.00 5530.31 7600.00 69.46 289.22 4014.73 1706.53 N 5408.36 W 0.00 5623.49 7700.00 69.46 289.22 4049.82 1737.36 N 5496.78 W 0.00 5716.66 7800.00 69.46 289.22 4084.90 1768.19 N 5585.20 W 0.00 5809.84 7900.00 69.46 289.22 4119.98 1799.02 N 5673.63 W 0.00 5903.02 8000.00 69.46 289.22 4155.07 1829.85 N 5762.05 W 0.00 5996.19 8100.00 69.46 289.22 4190.15 1860.68 N 5850.47 W 0.00 6089.37 8200.00 69.46 289.22 4225.24 1891.50 N 5938.90 W 0.00 6182.54 8300.00 69.46 289.22 4260.32 1922.33 N 6027.32 W 0.00 6275.72 8400.00 69.46 289.22 4295.40 1953.16 N 6115.74 W 0.00 6368.89 8500.00 69.46 289.22 4330.49 1983.99 N 6204.17 W 0.00 6462.07 8600.00 69.46 289.22 4365.57 2014.82 N 6292.59 W 0.00 6555.25 8700.00 69.46 289.22 4400.66 2045.65 N 6381.01 W 0.00 6648.42 8800.00 69.46 289.22 4435.74 2076.48 N 6469.43 W 0.00 6741.60 8900.00 69.46 289.22 4470.83 2107.31 N 6557.86 W 0.00 6834.77 9000.00 69.46 289.22 4505.91 2138.14 N 6646.28 W 0.00 6927.95 9100.00 69.46 289.22 4541.00 2168.97 N 6734.70 W 0.00 7021.12 9200.00 69.46 289.22 4576.08 2199.79 N 6823.13 W 0.00 7114.30 9300.00 69.46 289.22 4611.16 2230.62 N 6911.55 W 0.00 7207.48 9400.00 69.46 289.22 4646.25 2261.45 N 6999.97 W 0.00 7300.65 All data is in feet unless otherwise stated. Coordinates from slot #32 and T1/D from Nabors 16E (73.00 Ft above mean sea level). Bottom hole distance is 11247.38 on azimuth 294.95 degrees from wellhead. Total Dogleg for wellpath is 188.12 degrees. Vertical section is from N 0.00 E 0.00 on azimuth 294.95 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INrFEQ ARCO Alaska, Inc. Pad 3H,32PB1 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 9500.00 69.46 289.22 4681.33 2292.28 N 7088.40 W 9600.00 69.46 289.22 4716.42 2323.11 N 7176.82 W 9700.00 69.46 289.22 4751.50 2353.94 N 7265.24 W 9800.00 69.46 289.22 4786.59 2384.77 N 7353.67 W 9900.00 69.46 289.22 4821.67 2415.59 N 7442.09 W PROPOSAL LISTING Page 3 Your ref : 32 PB1 Version#2 Last revised : 21-Dec-1999 Dogleg Vert Deg/lOOft Sect 0.00 7393.83 0.00 7487.00 0.00 7580.18 0.00 7673.35 0.00 7766.53 10000.00 69.46 289.22 4856.76 2446.42 N 7530.51 W 10100.00 69.46 289.22 4891.84 2477.25 N 7618.94 W 10200.00 69.46 289.22 4926.93 2508.08 N 7707.36 W 10300.00 69.46 289.22 4962.01 2538.91 N 7795.78 W 10400.00 69.46 289.22 4997.10 2569.73 N 7884.21 W 10500.00 69.46 289.22 5032.18 2600.56 N 7972.63 W 10600.00 69.46 289.22 5067.27 2631.39 N 8061.05 W 10700.00 69.46 289.22 5102.35 2662.22 N 8149.48W 10800.00 69.46 289.22 5137.44 2693.05 N 8237.90 W 10900.00 69.46 289.22 5172.52 2723.87 N 8326.32 W 0.00 7859.70 0.00 7952.88 0.00 8046.06 0.00 8139.23 0.00 8232.41 0.00 8325.58 0.00 8418.76 0.00 8511.93 0.00 8605.11 0.00 8698.28 11000.00 69.46 289.22 5207.61 2754.70 N 8414.75 W 11100.00 69.46 289.22 5242.69 2785.53 N 8503.17 W 11200.00 69.46 289.22 5277.78 2816.36 N 8591.59 W 11300.00 69.46 289.22 5312.87 2847.18 N 8680.02 W 11400.00 69.46 289.22 5347.95 2878.01 N 8768.44 W 0.00 8791.46 0.00 8884.63 0.00 8977.81 0.00 9070.98 0.00 9164.16 11500.00 69.46 289.22 5383.04 2908.84 N 8856.86 W 11600.00 69.46 289.22 5418.12 2939.67 N 8945.29 W 11645.91 69.46 289.22 5434.23 2953.82 N 8985.88 W 11700.00 69.61 290.94 5453.14 2971.22 N 9033.47 W 11800.00 69.93 294.12 5487.73 3007.18 N 9120.13 W 0.00 9257.33 0.00 9350.51 0.00 9393.29 Begin Build & Turn 3.00 9443.78 3.00 9537.51 11900.00 70.31 297.29 5521.74 3047.96 N 9204.84 W 3.00 9631.53 12000.00 70.74 300.44 5555.08 3093.47 N 9287.40 W 3.00 9725.57 12100.00 71.23 303.57 5587.67 3143.57 N 9367.56 W 3.00 9819.39 12200.00 71.77 306.68 5619.40 3198.13 N 9445.11 W 3.00 9912.71 12300.00 72.36 309.77 5650.20 3257.00 N 9519.83 W 3.00 10005.30 12400.00 73.00 312.84 5679.99 3320.01N 9591.53 W 3.00 10096.88 12500.00 73.68 315.89 5708.67 3386.99 N 9660.00 W 3.00 10187.22 12547.93 74.02 317.35 5722.00 3420.45 N 9691.62 W 3.00 10230.00 Base HRZ/Top Kalubik 12600.00 74.40 318.92 5736.17 3457.77 N 9725.06 W 3.00 10276.06 12700.00 75.17 321.93 5762.41 3532.14 N 9786.52 W 3.00 10363.16 12800.00 75.98 324.91 5787.33 3609.90 N 9844.22 W 3.00 10448.28 12900.00 76.82 327.87 5810.86 3690.84 N 9898.01W 3.00 10531.19 13000.00 77.69 330.82 5832.92 3774.74 N 9947.73 W 3.00 10611.66 13100.00 78.60 333.74 5853.46 3861.36 N 9993.25 W 3.00 10689.47 13175.86 79.31 335.94 5868.00 3928.75 N 10024.90 W 3.00 10746.59 K-l/Top Lower Kalubik 13200.00 79.54 336.64 5872.43 3950.48 N 10034.44 W 3.00 10764.41 13300.00 80.50 339.53 5889.77 4041.84 N 10071.19 W 3.00 10836.27 13300.02 80.50 339.53 5889.77 4041.86 N 10071.20 W 3.00 10836.28 Begin Angle Drop & Cont. Turn 13400.00 79.55 342.42 5907.09 4134.93 N 10103.30 W 3.00 10904.65 13500.00 78.64 345.33 5926.01 4229.25 N 10130.57 W 3.00 10969.16 13583.50 77.89 347.77 5943.00 4308.76 N 10149.59 W 3.00 11019.94 Top Kuparuk D 13600.00 77.75 348.25 5946.48 4324.53 N 10152.94 W 3.00 11029.63 13675.84 77.09 350.49 5963.00 4397.27 N 10166.59 W 3.00 11072.70 Top Kuparuk C4 13700.00 76.89 351.20 5968.44 4420.51N 10170.34 W 3.00 11085.90 13771.42 76.30 353.32 5985.00 4489.35 N 10179.70 W 3.00 11123.42 Top Kuparuk B All data is in feet unless otherwise stated. Coordinates from slot #32 and TVD from Nabors 16E (73.00 Ft above mean sea level). Bottom hole distance is 11247.38 on azimuth 294.95 degrees from wellhead. Total Dogleg for wellpath is 188.12 degrees. Vertical section is from N 0.00 E 0.00 on azimuth 294.95 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ ARCO Alaska. Inc. Pad 3H. 32PB1 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 4 Your ref : 32 PB1 Version #2 Last revised : 21-Dec-1999 Dogleg Vert Deg/lOOft Sect 13775.64 76.26 353.44 5986.00 4493.42 N 10180.17 W 3.00 11125.56 Top Kuparuk A1 13800.00 76.07 354.17 5991.83 4516.94 N 10182.72 W 3.00 11137.80 13888.74 75.36 356.82 6013.73 4602.66 N 10189.48 W 3.00 11180.09 EOC 13901.70 75.36 356.82 6017.00 4615.17 N 10190.18 W 0.00 11186.00 Base A1 14000.00 75.36 356.82 6041.84 4710.14 N 10195.46 W 0.00 11230.84 14036.23 75.36 356.82 6050.99 4745.14 N 10197.40 W 0.00 11247.37 TD-Pilot Hole 14036.25 75.36 356.82 6051.00 4745.17 N 10197.40 W 0.00 11247.38 3H-32PB1TD 14-Dec-99 All data is in feet unless otherwise stated. Coordinates from slot #32 and TVD from Nabors 16E (73.00 Ft above mean sea level). Bottom hole distance is 11247.38 on azimuth 294.95 degrees from wellhead. Total Dogleg for wellpath is 188.12 degrees. Vertical section is from N 0.00 E 0.00 on azimuth 294.95 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ ARCO Alaska, Inc. Pad 3H,32PB1 Kuparuk River Unit,North Slope. Alaska PROPOSAL LISTING Page 5 Your ref : 32 PB1 Version#2 Last revised : 21-Dec-1999 Con~ents i n wel 1 path MD TVD Rectangul ar Coords. Con~nent " 6166'" 6166 ....... 6166' ....... 800.00 798.10 19.76 N 34. 1200,00 1186.58 39,86 N 124. 1747.96 1673.00 79.76 N 369. 2800.00 2328.06 263.30 N 1154. 2912.00 2369.89 286.65 N 1255. 3362.82 2528.20 400.17 N 1661. 3633.03 2623.00 483,47 N 1900. 4687.64 2993.00 808.61N 2833. 5257.78 3193.00 984.41 N 3337. 11645.91 5434.23 2953.82 N 8985. 12547.93 5722.00 3420.45 N 9691. 13175.86 5868.00 3928.75 N 10024 13300.02 5889.77 4041.86 N 10071 13583.50 5943.00 4308.76 N 10149 13675.84 5963.00 4397.27 N 10166 13771.42 5985.00 4489.35 N 10179 13775.64 5986.00 4493.42 N 10180 13888.74 6013.73 4602.66 N 10189 13901.70 6017.00 4615.17 N 10190 14036.23 6050.99 4745.14 N 10197 14036.25 6051.00 4745.17 N 10197 23 W Begin 3 Deg/lO0' Build & Turn 21W Begin Right Turn/Cont. Build 18 W Base of Permafrost 22 W Begin Left Turn/Cont. Build 44 W End of Build/Begin 1.5 Deg Turn 71W EOC 64 W Top of West Sak 16 W Base of West Sak 29 W 9-5/8" Casing Pt 88 W Begin Build & Turn 62 W Base HRZ/Top Kalubik 90 W K-l/Top Lower Kal ubik 20 W Begin Angle Drop & Cont. Turn 59 W Top Kuparuk D 59 W Top Kuparuk C4 70 W Top Kuparuk B 17 W Top Kuparuk A1 48 W EOC 18 W Base A1 40 W TD-Pilot Hole 40 W 3H-32PB1TD 14-Dec-99 Casing positions in string 'A' Top MD Top T1/D Rectangular Coords. Bot MD Bot TVD Rectangular Coords. Casing 0.00 0.00 O.OON O.OOE 5257.78 3193.00 984.41N 3337.29W 9-5/8" Casing Targets associated with this wellpath Target name Geographic Location T.V.D. Rectangular Coordinates Revised 3H-32PB1TD 14-Dec-9 488460.000,6005360.000.0.0000 6051.00 4745.17N 10197.40W 14-Dec-1999 ARCO Alaska, Inc. Pad 3H 32 slot #32 Kuparuk River Unit North Slope, Alaska PROPOSAL LISTING by Baker Hughes INTEQ Your ref : 32 Version#8 Our ref : propg04 License : Date printed : 22-Dec-1999 Date created : 5-0ct-1993 Last revised : 21-Dec-1999 Field is centred on n70 16 18.576,w150 5 56.536 Structure is centred on n70 24 56.740.w150 0 47.688 Slot location is n70 24 46.472,w150 0 39.421 Slot Grid coordinates are N 6000613.087, E 498655.349 Slot local coordinates are 1044.00 S 282.00 E Projection type: alaska - Zone 4, Spheroid: Clarke - 1866 Reference North is True North ARCO Alaska, Inc. Pad 3H, 32 Kuparuk River Unit,North Slope. Alaska Measured Inclin. Azimuth True Vert R E C T A N G Depth Degrees Degrees Depth C 0 0 R D I N 13300.00 80.50 339.53 5889.77 4041.84 N 13400.00 81.48 342.40 5905.43 4135.20 N 13500.00 82.49 345.25 5919.37 4230.29 N 13600.00 83.51 348.09 5931.56 4326.86 N 13700.00 84.55 350.92 5941.95 4424.65 N 13711.17 84.67 351.24 5943.00 4435.63 N 13800.00 85.61 353.74 5950.53 4523.38 N 13900.00 86.67 356.56 5957.26 4622.78 N 14000,00 87.74 359.36 5962.14 4722.59 N 14008.67 87.84 359.60 5962.47 4731.25 N 14022,58 87.84 359.60 5963.00 4745,15 N 14022.60 87.84 359.60 5963.00 4745,17 N 14051.25 87.99 0.00 5964.04 4773.80 N 14363.82 87.99 0.00 5975.00 5086.18 N 14363.84 87.99 0.00 5975.00 5086.20 N ULAR ATES 10071.19 10103.40 10130.97 10153.84 10171.95 10173.67 10185.24 10193.67 10197.23 10197.31 10197.40 10197.40 10197.50 10197.48 10197.48 PROPOSAL LISTING Page 1 Your ref : 32 Version#8 Last revised : 21-Dec-1999 Dogleg Vert Deg/lOOft Sect 0.00 3.00 3.00 3.00 3.00 3.00 3.00 3.00 3.00 3.00 0.00 0.00 1.50 0.00 0.00 14400.00 88.53 359.99 5976.10 5122.34 N 10197.48 W 1.50 14425.57 88.92 359.99 5976.67 5147.91 N 10197.48 W 1.50 14500.00 88,92 359.99 5978.07 5222.32 N 10197.50 W 0.00 14654.92 88.92 359.99 5981.00 5377.21 N 10197.54 W 0.00 14654.94 88.92 359.99 5981.00 5377.23 N 10197.54 W 0.01 14700.00 89.59 359,99 5981.59 5422.29 N 10197.55 W 1.50 14800.00 91.09 359.99 5980.99 5522.29 N 10197.57 W 1.50 14845.89 91.78 359.99 5979.84 5568.16 N 10197.58 W 1,50 15000.00 91.78 359.99 5975.05 5722.20 N 10197.62 W 0,00 15130.12 91.78 359,99 5971.00 5852.25 N 10197.64 W 0.00 15130.14 91.78 359.99 5971.00 5852.28 N 10197.64 W 0.00 15148.90 91.50 359.99 5970.46 5871.03 N 10197.65 W 1.50 15178.73 91.05 359.99 5969.80 5900.85 N 10197.65 W 1.50 15500.00 91.05 359.99 5963,90 6222.06 N 10197.72 W 0.00 15603.26 91.05 359.99 5962.00 6325.31 N 10197.75 W 0.00 4041.84 SideTrack Pt/Cont Build & Turn 4135.20 4230.29 4326.86 4424.65 15603.28 91.05 359.99 5962.00 6325.32 N 10197.75 W 0.00 15664.96 87,09 359.99 5963.00 6386.99 N 10197.76 W 6.42 15700.00 84.~ 359.99 5965.47 6421.94 N 10197.77 W 6.42 15800.00 78.41 359.99 5980.02 6520.82 N 10197.79 W 6.42 15823.30 76.92 359.99 5985.00 6543.58 N 10197.79 W 6.42 4435.63 Top of Kuparuk D 4523.38 4622.78 4722.59 4731.25 EOC 15827.68 76.64 359.99 5986.00 6547.84 N 10197.80 W 6.42 15856.04 74.81 359.99 5992.99 6575.33 N 10197.80 W 6.42 15856.06 74.81 359.99 5993.00 6575.35 N 10197.80 W 6,42 4745.15 Target #1/Top C4/Begin Turn 4745.17 3H-32 T1 Heel Rvsd 17-Nov-99 4773.80 EOC 5086.18 Target #2/Begin Build 5086.20 3H-32 T2 Rvsd 08-Dec-99 5122.34 5147.91EOC 5222.32 5377.21 Target #3/Begin Build 5377.23 3H-32 T3 Rvsd 17-Nov-99 5422.29 5522.29 5568.16 EOC 5722.20 5852.25 Target #4/Begin Drop 5852.28 3H-32 T4 Rvsd 17-Nov-99 5871.03 5900.85 EOC 6222.06 6325.31 Target #5/Begin Drop 6325.32 3H-32 T5 Rvsd 17-Nov-99 6386.99 6421.94 6520.82 6543.58 Top Kuparuk B 6547,84 Top Kuparuk A1 6575.33 TD-Casing Pt 6575.35 3H-32 T6 Rvsd 17-Nov-99 All data is in feet unless otherwise stated. Coordinates from slot #32 and TVD from Nabors 16E (73.00 Ft above mean sea level). Bottom hole distance is 12133.85 on azimuth 302.81 degrees from wellhead. Total Dogleg for wellpath is 188.12 degrees. Vertical section is from S 0.00 W 0.00 on azimuth 0.00 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ ARCO Alaska. Inc. Pad 3H.32 Kuparuk River Unit. North Slope. Alaska PROPOSAL LISTING Page 2 Your ref : 32 Version#8 Last revised : 21-Dec-1999 Comments in wellpath MD TVD Rectangular Coords. Comment 13300.00 5889 77 4041 84 N 10071 19 W SideTrack Pt/Cont Build & Turn 13711.17 14008.67 14022.58 14022.60 14051.25 14363.82 14363 84 14425 57 14654 92 14654 94 14845 89 15130 12 15130 14 15178 73 15603 26 15603 28 15823 30 15827 68 15856 04 15856 06 5943 5962 5963 5963 5964 5975 5975 5976 5981 5981 O0 5979 84 5971 O0 5971 O0 5969 80 5962 O0 5962 O0 5985 O0 5986 O0 5992.99 5993.00 O0 47 O0 O0 04 O0 O0 67 O0 4435 63 4731 25 4745 15 4745 17 4773 80 5086 18 5086 20 5147.91 5377.21 5377.23 5568.16 5852.25 5852.28 5900.85 6325.31 6325.32 6543.58 6547.84 6575.33 6575.35 10173 67 W 10197 31W 10197 40 W 10197 40 W 10197 50 W 10197 48 W 10197 48 W 10197 48 W 10197 54 W 10197.54 W 10197.58 W 10197.64 W 10197.64 W 10197.65 W 10197.75 W 10197.75 W 10197.79 W 10197.80 W 10197.80 W 10197.80 W Top of Kuparuk D EOC Target #1/Top C4/Begin Turn 3H-32 T1 Heel Rvsd 17-Nov-99 EOC Target #2/Begin Bui 1 d 3H-32 T2 Rvsd 08-Dec-99 EOC Target #3/Begin Build 3H-32 T3 Rvsd 17-Nov-99 EOC Target ~/Begin Drop 3H-32 T4 Rvsd 17-Nov-99 EOC Target ~5/Begin Drop 3H-32 T5 Rvsd 17-Nov-99 Top Kuparuk B Top Kuparuk A1 TD-Casing Pt 3H-32 T6 Rvsd 17-Nov-99 Casing positions in string 'A' Top MD Top TVD Rectangular Coords. Bot MD Bot TVD Rectangular Coords. Casing n/a 5889.77 4041.84N 10071.19W n/a 5889.77 4041.84N 10071.19W 9-5/8" Casing Targets associated with this wellpath Target name Geographic Location T.V.D. Rectangular Coordinates Revised 3H-32 T1 Heel Rvsd I 488460.000.6005360.000.0.0000 5963.00 4745.17N 10197.40W 8-0ct-1999 3H-32 T2 Rvsd 08-Dec 488460.000,6005701.000.0.0000 5975.00 5086.20N 10197.48W 8-0ct-1999 3H-32 T3 Rvsd 17-Nov 488460.000.6005992.000,0.0000 5981.00 5377.23N 10197.54W 30-Sep-1999 3H-32 T4 Rvsd 17-Nov 488460.000.6006467.000.-2.000 5971.00 5852.28N 10197.64W 2-Nov-1999 3H-32 T5 Rvsd 17-Nov 488460.000.6006940.000,0.0000 5962.00 6325.32N 10197.75W 2-Nov-1999 3H-32 T6 Rvsd 17-Nov 488460.000.6007190.000.0.0000 5993.00 6575.35N 10197.80W 2-Nov-1999 ARCO Alaska, Inc. Pad 3H 32 slot #32 Kuparuk River Unit North Slope, Alaska SUMMARY CLEARANCE by Baker Hughes INTEQ REPORT Your ref : 32 Version#8 Our ref : prop904 License : Date printed : 22-Dec-1999 Date created : 5-0ct-1993 Last revised : 21-Dec-1999 Field is centred on n70 16 18.576,w150 5 56.536 Structure is centred on n70 24 56.740,w150 0 47.688 Slot location is n70 24 46.472,w150 0 39.421 Slot Grid coordinates are N 6000613.087. E 498655.349 Slot local coordinates are 1044.00 S 282.00 E Projection type: alaska - Zone 4, Spheroid: Clarke - 1866 Reference North is True North Object wel 1 path PMSS <6133 - 7755'>,,13A,Pad 3H PGMS <0-7370'>,,13,Pad 3H PGMS <O-9360'>,,23,Pad 3H PMSS <7640 - 9875'>,,23A.Pad 3H PMSS <1743-6660'>,,26,Pad 3H PGMS <0-8095'>,,4,Pad 3H PGMS <0-7987'>,,6,Pad 3H PGMS <0-7750'>,,11,Pad 3H PGMS <0-7155'>,,5,Pad 3H PMSS <461-12044'>,,24,Pad 3H PGMS <0-8167'> ,1,Pad 3H PGMS <0-9555'> PGMS <0-8620'> PGMS <0- 7310'> PGMS <0-8350' > PGMS <0-6785' >, PGMS <0-8614'>, PGMS <0-8250'>, PGMS <0-7298'>, PGMS <0-10234'> PGMS <0-11346'> ,3,Pad 3H ,7,Pad 3H ,9,Pad 3H ,2,Pad 3H lO,Pad 3H 17,Pad 3H 14,Pad 3H 12,Pad 3H ,22,Pad 3H ,21,Pad 3H PMSS <1506-2076'>,,20.Pad 3H PMSS <1622-4449'>,,20,Pad 3H PGMS <0-9050'>,,20,Pad 3H PMSS <1506-3878'>,,20,Pad 3H PGMS <0-8650'>,,19,Pad 3H PGMS <O-12410'>,,25,Pad 3H Closest approach with 3-D Minimum Distance method Last revised 7-Jan 1999 13-Nov 1991 7-Nov 1996 7-Jan 1999 7-Jan 1999 13-Nov 1991 13-Nov 1991 13-Nov 1991 13-Nov 1991 14-Feb 1996 13-Nov 1991 13-Nov 1991 13-Nov 1991 13-Nov 1991 13-Nov 1991 13-Nov-1991 13-Nov-1991 13-Nov-1991 13-Nov-1991 13-Nov-1991 13-Nov-1991 13-Nov-1991 13-Nov-1991 13-Nov-1991 13-Nov-1991 14-Feb-1996 17-Feb-1999 Distance M.D. 9081.0 13300.0 8514.8 13300.0 13300 5715.4 13300.0 13300 5978.7 14874.0 14874 11064.4 13300.0 13300 12089.6 13300.0 13300 7156.6 13300.0 13300 12068.0 13300.0 13300 10872.8 13300.0 13300 7291.3 15856.1 15856 11504.2 13300.0 13300 12090.7 13300.0 13300 9176.4 13300.0 13300 11885.0 13300.0 13300 12088.2 13300.0 13300 11267.2 13300.0 13977 11017.1 13300.0 14481 11737.6 13300.0 14253 11096.1 13300.0 13300 10888.3 13300.0 15585 11559.2 13300.0 13300 11660.6 13300.0 13300 11686.7 13300.0 13300 11688.8 13300.0 13300 11578.4 13300.0 13300 8449.7 13300.0 14499 1637.1 13300.0 13300 Diverging from M.D. 15825 5 PGMS <0-6881'>,,8,, 3H PGMS <0-8460'>,,15,Pad 3H PMSS <12259 - 13247'>.,25APB2,Pad 3H PMSS <11231' - 14458'>,,25APB1,Pad 3H PMSS <12256 - 15240'>,,25A,Pad 3H PGMS <0-9770'>,,16,Pad 3H PGMS <0-10293'>,,18,Pad 3H 28 <0-14940'> If Gyroed,,28,Pad 3H PMSS <7395 - 12575'>,,28A,Pad 3H PMSS <549 - 14940'>,,28,Pad 3H PMSS <5706 - 8867'>,,28A,Pad 3H PGMS <O-10730'>,,31,Pad 3H 13-Nov-1991 13-Nov-1991 16-Jun-1999 16-Jun-1999 16-Ju1-1999 13-Nov-1991 13-Nov-1991 7-Dec-1999 7-Dec-1999 7-Dec-1999 28-Feb-1996 14-Feb-1996 8757.4 5847.9 431.6 268.0 211.6 5320.8 3174.8 655.1 1903.2 655.1 4443.6 8657.8 13300. 13300.0 13300.0 13300.0 13300.0 13300.0 13300.0 13300.0 14757.1 13300.0 13300.0 15856.1 13300.0 13300.0 13300.0 13300.0 13300.0 13300.0 13300 0 13300 0 14757 1 13300 0 13300 0 15856 i ARCO Alaska, Inc. Kuparuk Unit Disbursement Account P.O. Box 102776 Anchorage, AK 99510-2776 PAY TO THE ORDER OF: STATE OF ALASKA ALASKA OIL & GAS CONSERVATION COMMI 3001 PORCUPINE DRIVE CHECK NUMBER 23010149O DECEMBER 10, 1999 *** VOID AFTER 90 DAYS *** 839 0997587 EXACTLY **********'100 DOLLARS AND O0 CENTS $***********100.00 The First National Bank of Chicago-0710 Payable Through Republic Bank Shelbyville, Kentucky TRACE NUMBER: 23010 1490 WELL PERMIT CHECKLIST 'r FIELD & POOL ........ --""'~Z/~_._Z/~ .................. INIT CLASS "~---~' ADMINI~-~R-~ii~ A~R DATE DATE GEOLOGY ,~ DATE /-~. c'd.b ANNULAR 6i§i~b§~,L APPR DATE COMPANY /Z~/"~.._ C. (~ __ WELL NAME/~-.~" -'~' .'~' PROGRAM: exp __ '~i. P~.?i~i{ fee attached ........................ 2. Lease number appropriate.'~r''' .................. 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 well~.:-'. ...... 7. Sufficient acreage available in drilling unit ............ 8. If deviated, is wellbore plat included ............... 9. Operator only affected pady ................... (" _Y. '~N 10. Operator has appropriate bond in force ............. ~ N 11. Permit can be issued without conservation order ........ r,~ N 12. Permit can be issued without administrative approval ...... '')~Y~, N 13. Can permit be approved before 15-day wait ........... N i4. C°ndiJ~ibr .~li-16~ ~i-6~[d~,a ................... 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 ....... C.Y.2 N -- 20. Adequate tankage or reserve pit ................. CY_.) N 21. If a re-drill, has a 10-403 for abandonment been approved... 22. Adequate wellbore separation proposed ............. 23. If diveder required, does it meet regulations .......... 24. Drilling fluid program schematic 8, equip list adequate ..... 25. BOPEs, do they meet regulation ................ 26. BOPE press rating appropriate; test to '~ ~ C.)I,_..) psig. 27. Choke manifold complies w/APl RP-53 (May 84) ........ 28. Work will occur without operation shutdown ........... 29. Is presence of H2S gas probable ................. 30. Permit can be isSUed w/0 hydrogen SUlfide measures ..... 31. Data presented on potential overpressure zones ....... ,,,,t/~ y N 32. Seismic analysis of shallow gas zones ............. AY/,-] Y N 33. Seabed condition survey (if off-shore) ............. /,.,'A/ ,-- ¥ N 34. Contact name/phone for weekly progress repods [exploratory onl)~Y.~ N 3g. Wiii~ prop~i' ~-~-~-n-[[6~l records, this plan (A) will contain waste in a suitable receiving zone; ....... Y N ([3) will not contaminate freshwater; or cause drilling waste... Y N 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. Y N dev ,,' redrll __ serv__ wellbore seg ann. disposal para req - -Y--N- Y N ~N Y N GEO[.~ ENGINEERING: UIC/Annular COMMISSION: SF~' _'~.~"~-- JDH ,~'~'-"- RNC TEM~ t/~L~ -ct_) CO ~,~ 'Z/l'2.-/u~ c:\msoffice\wordian\di;u~;]X~:lmcklist (rev. 09/27/99) 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 SRevision: 3 $ LisLib SRevision: 4 $ Fri Jun 23 08:12:31 2000 Reel Header Service name ............. LISTPE Date ..................... 00/06/23 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Previous Reel Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Tape Header Service name ............. LISTPE Date ..................... 00/06/23 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Previous Tape Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Technical Services Scientific Technical Services Physical EOF Comment Record TAPE HEADER Kuparuk River Unit MWD/MAD LOGS WELL NAME: API NUMBER: OPEP~ATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB A-UMBER: LOGGING ENGINEER: OPER3tTOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: MWD RUN 3 AK-MM-90228 P. SMITH F. HERBERT 3H-32PB1 501032032270 ARCO Alaska, Inc. Sperry Sun 21-JI/N-00 MWD RUN 4 AK-MM-90228 P. SMITH GUY WHITLOCK 12 12N 8E 1044 282 .00 RECFIVED JUN 29 2000 Alaska Oil & L~, L;ons. k,:, ........ Anchorage DERRICK FLOOR: 73.10 GROUND LEVEL: 38.40 WELL CASING RECORD OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 12.250 9.625 4706.0 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING REMARKS: 1. ALL DEPTHS ARE MEASURED DEPTHS (MD) UNLESS OTHERWISE STATED. 2. MWD RUNS 1 AND 2 ARE DIRECTIONAL ONLY AND ARE NOT PRESENTED. 3. MWD RUN 3 IS DIRECTIONAL WITH DUAL GAMMA PJtY (DGR) UTILIZING GEIGER MUELLER TUBE DETECTORS AND ELECTROMAGNETIC WAVE RESISTIVITY PHASE 4 (EWR4) . 4. MWD RUN 4 IS DIRECTIONAL WITH DUAL GAMMA RAY (DGR) UTILIZING GEIGER MUELLER TUBE DETECTORS, ELECTROMAGNETIC WAVE RESISTIVITY PI-IASE 4 (EWR4), COMPENSATED THERMAL NEUTRON POROSITY (CTN), STABILIZED LITH-DENSITY (SLD) . 5. THE GAP IN THE GAMMA P~AY FROM 11696' MD, 5433'TVD TO 11713' MD, 5439' TV/D IS DUE TO A CHANGE IN SENSOR DISTANCE BETWEEN MWD RUN 3 AArD MWD RUN 4. 6. DEPTH SHIFTING / CORRECTION OF MWD DATA IS WAIVED PER THE EMAIL MESSAGE FROM D. SCHWARTZ OF ARCO, ALASKA INC. OF 5/24/00. MWD DATA CONSIDERED PDC. 7. MWD RUN 1-4 REPRESENT WELL 3H-32PB1 WITH API 50-103-20322-70. THIS WELL REACHED A TOTAL DEPTH OF 14278'MD, 6016'TVD. SROP = SMOOTHED RATE OF PENETRATION SGRC = SMOOTHED GAMMA R3tY COMBINED SEXP = SMOOTHED PHASE SHIFT DERIVED RESISTIVITY ( EXTRA SH3LLLOW 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 SBD2 = SMOOTHED BULK DENSITY (LOW-COUNT BIN) SCO2 = SMOOTHED STANDOFF CORRECTION (LOW-COUNT BIN) SNP2 = SMOOTHED NEAR DETECTOR ONLY PHOTOELECTRIC ABSORPTION FACTOR (LOW-COUNT BIN) SPSF = SMOOTHED COMPENSATED NEUTRON POROSITY (SANDSTONE MATRIX, FIXED HOLE SIZE) CNNA = SMOOTHED AVERAGE OF NEAR DETECTOR'S COUNT RATE CNFA = SMOOTHED AVERAGE OF FAR DETECTOR'S COUNT RATE ENVIRONMENTAL PA_P_AMETERS USED IN PROCESSING THE NEUTRON LOG DATA: HOLE SIZE: 8.437" MUD WEIGHT: 10.8 - 12.0 PPG MUD FILTRATE SALINITY: 300 - 650 PPM CHLORIDES FORMATION WATER SALINITY: 13,000 PPM CHLORIDES FLUID DENSITY: 1.00 G/CC MATRIX DENSITY: 2.65 G/CC LITHOLOGY: SANDSTONE $ File Header Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 00/06/23 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.000 Comment Record FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: FILE SUMMARY PBU TOOL CODE GR FET RPX RPS RPM RPD ROP FCNT NCNT NPHI RHOB DRHO PEF $ .SO00 START DEPTH 4660 0 4694 0 4696 0 4696 0 4696 0 4696 0 4716 0 11693 0 11693 0 11693 0 11702 5 11702 5 11702 5 STOP DEPTH 14236 5 14209 0 14209 0 14209 0 14209 0 14209 0 14278 0 14216.5 14216.5 14216.5 14226.0 14226.0 14226.0 BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) EQUIVALENT UNSHIFTED DEPTH BASELINE DEPTH $ MERGED DATA SOURCE PBU TOOL CODE MWD MWD $ REMARKS: BIT RUN NO MERGE TOP MERGE BASE 3 4660.0 11749.5 4 11750.0 14278.0 MERGED MAIN PASS. $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD FT/H 4 1 68 4 2 GR MWD API 4 1 68 8 3 RPX MWD OHMM 4 1 68 12 4 RPS MWD OHMM 4 1 68 16 5 RPM MWD OHMM 4 1 68 20 6 RPD MWD OHMM 4 1 68 24 7 FET MWD HRS 4 1 68 28 8 NPHI MWD PU 4 1 68 32 9 NCNT MWD CP30 4 1 68 36 10 FCNT MWD CP30 4 1 68 40 11 RHOB MWD G/CC 4 1 68 44 12 DRHO MWD G/CC 4 1 68 48 13 PEF MWD B/E 4 1 68 52 14 Name Service Unit Min Max Mean Nsam DEPT FT 4660 14278 9469 19237 ROP MWD FT/H 3.58 3743.44 122.709 19125 GR MWD API 24.49 458.05 125.551 19120 RPX MWD OHMM 1.69 1575.75 5.03873 19027 RPS MWD OHMM 1.82 1768.41 5.38027 19027 RPM MWD OHMM 2.01 2000 8.14245 19027 RPD MWD OHMM 2.26 2000 10.2601 19027 FET MWD HRS 0.1675 83.4957 1.2598 19031 NPHI MWD PU 19.67 73.32 51.9209 5048 First Reading 4660 4716 4660 4696 4696 4696 4696 4694 11693 Last Reading 14278 14278 14236.5 14209 14209 14209 14209 14209 14216.5 NCNT MWD CP30 2138 3738 FCNT MWD CP30 475 1194 RHOB MWD G/CC 1.59 3.46 DRHO MWD G/CC -0.3 0.49 PEF MWD B/E 4.52 19.58 2519.15 5048 609.144 5048 2.44759 5048 0.0571018 5048 8.05806 5048 11693 11693 11702.5 11702.5 11702.5 14216.5 14216.5 14226 14226 14226 First Reading For Entire File .......... 4660 Last Reading For Entire File ........... 14278 File Trailer Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 00/06/23 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 ....... 00/06/23 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.001 Comment Record FILE HE~ER FILE NIIMBER: 2 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 3 DEPTH INCREMENT: .5000 FILE SUMMARY VENDCR TOOL CODE START DEPTH GR FET RPX RPS RPD RPM ROP $ LOG HEADER DATA DATE LOGGED: SOFTWARE 4660.0 4694 0 4696 0 4696 0 4696 0 4696 0 4716 0 SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: STOP DEPTH 11695.5 11705 0 11705 0 11705 0 11705 0 11705 0 11749 5 31-JAN-00 Insite 65.31 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: M~IMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3) : RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTP~ATE 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 A~osent value ...................... -999 Depth Units ....................... Datum Specification Block sub-type...0 Memory 11750.0 67.9 71.5 TOOL NUMBER 1417HGVR6 1417HGVR6 8.500 Water Based 9.30 39.0 8.5 275 5.8 3 .700 6.940 4 .200 3 .500 65.0 128.0 65.0 65.0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD030 GR MWD030 RPX MWD030 RPS MWD030 RPM MWD030 RPD MWD030 FET MWD030 FT/H 4 1 68 API 4 1 68 OHMM 4 1 68 OHMM 4 1 68 OHMM 4 1 68 OHMM 4 1 68 HRS 4 1 68 4 8 12 16 20 24 28 Name Service Unit DEPT FT ROP MWD030 FT/H GR MWD030 API RPX MWD030 OHMM RPS MWD030 OHMM RPM MWD030 OHMM RPD MWD030 OHMM FET MWD030 HRS Min Max 4660 11749.5 3.58 3743.44 24.49 229.01 1.78 1575.75 1.88 1768.41 2.01 1841.54 2.26 2000 0.1675 83.4957 Mean Nsam 8204.75 14180 133.773 14068 119.732 14072 4.54842 14019 4.80484 14019 5.0939 14019 7.08197 14019 0.973605 14023 First Reading 4660 4716 4660 4696 4696 4696 4696 4694 Last Reading 11749.5 11749.5 11695.5 11705 11705 11705 11705 11705 First Reading For Entire File .......... 4660 Last Reading For Entire File ........... 11749.5 File Trailer Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 00/06/23 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 ....... 00/06/23 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.002 Comment Record FILE HEADER FILE NUMBER: 3 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 4 DEPTH INCREMENT: .5000 FILE SUMM3~RY VENDOR TOOL CODE START DEPTH NPHI NCNT FCNT PEF RHOB DRHO RPD RPX RPM FET RPS GR ROP $ LOG HEADER DATA DATE LOGGED: SOFTWARE 11693 0 11693 0 11693 0 11702 5 11702 5 11702 5 11705 5 11705 5 11705 5 11705 5 11705 5 11713 0 11750 0 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 ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR EWR4 CNP SLD $ DUAL GAMMA P~AY ELECTROMAG. RESIS. 4 COMPENSATED NEUTRON 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 TEMPEP~ATURE (DEGF) MUD AT MEASURED TEMPEP~ATURE (MT) : MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: STOP DEPTH 14216 5 14216 5 14216 5 14226 0 14226 0 14226 0 14209 0 14209 0 14209 0 14209 0 14209 0 14236 5 14278 0 NEUTRON TOOL MATRIX: 03-FEB-00 Insite 65.31 Memory 14278.0 71.5 90.7 TOOL NUMBER PBO1419HRNLG6 PBO1419HPdqLG6 PBO1419HP~NLG6 PBO1419HRNLG6 8.437 Water Based 10.80 45.0 8.5 65O 9.6 1.850 3.930 1.600 2.000 65.0 145.7 65.0 65.0 MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ) : REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD040 FT/H 4 1 68 4 2 GR MWD040 API 4 1 68 8 3 RPX MWD040 OHMM 4 1 68 12 4 RPS MWD040 OHMM 4 1 68 16 5 RPM MWD040 OHMM 4 1 68 20 6 RPD MWD040 OHMM 4 1 68 24 7 FET MWD040 HRS 4 1 68 28 8 NPHI MWD040 PU 4 1 68 32 9 NCNT MWD040 CP30 4 1 68 36 10 FCNT MWD040 CP30 4 1 68 40 11 RHOB MWD040 G/CC 4 1 68 44 12 DRHO MWD040 G/CC 4 1 68 48 13 PEF MWD040 B/E 4 1 68 52 14 Name Service Unit Min Max Mean Nsam DEPT FT 11693 14278 12985.5 5171 ROP MWD040 FT/H 3.61 3495.18 91.9296 5057 GR MWD040 API 51.42 458.05 141.772 5048 RPX MWD040 OHMM 1.69 147.59 6.41127 5008 RPS MWD040 OHMM 1.82 181.76 6.9911 5008 RPM MWD040 OHMM 2.05 2000 16.6763 5008 RPD MWD040 OHMM 2.63 2000 19.1567 5008 FET MWD040 HRS 0.6525 41.7281 2.06119 5008 NPHI MWD040 PU 19.67 73.32 51.9209 5048 NCNT MWD040 CP30 2138 3738 2519.15 5048 FCNT MWD040 CP30 475 1194 609.144 5048 RHOB MWD040 G/CC 1.59 3.46 2.44759 5048 DRHO MWD040 G/CC -0.3 0.49 0.0571018 5048 PEF MWD040 B/E 4.52 19.58 8.05806 5048 First Reading 11693 11750 11713 11705.5 11705.5 11705.5 11705.5 11705.5 11693 11693 11693 11702.5 11702.5 11702.5 Last Reading 14278 14278 14236.5 14209 14209 14209 14209 14209 14216.5 14216.5 14216.5 14226 14226 14226 First Reading For Entire File .......... 11693 Last Reading For Entire File ........... 14278 File Trailer Service name ............. STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 00/06/23 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.004 Physical EOF Tape Trailer Service name ............. LISTPE Date ..................... 00/06/23 Origin ................... STS Tape Name ................ UNKI~OWN Continuation Number ...... 01 Next Tape Name ........... UNKI~OWN Comments ................. STS LIS Writing Library. Reel Trailer Service name ............. LISTPE Date ..................... 00/06/23 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Next Reel Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Technical Services Scientific Technical Services Physical EOF Physical EOF End Of LIS File Sperry-Sun Drilling Services LIS Scan Utility SRevision: 3 $ LisLib SRevision: 4 $ Thu Jun 29 15:10:00 2000 Reel Header Service name ............. LISTPE Date ..................... 00/06/29 ~,~ - (~f 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 ..................... 00/06/29 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 3 AK-MM-90228 P. SMITH F. HERBERT 3H-32 501032032200 Arco Alaska, Inc. Sperry Sun 29-JTJN-00 MWD RUN 4 AK-MM-90228 T. MCGUIRE GUY WHITLOCK MWD RUN 5 AK-MM-90228 P. SMITH F. HERBERT RECEIVED JUL 06 AJaska Oil & Gas Cons. Commission Anchorage JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: # WELL CASING RECORD MWD RUN 6 AK-MM-90228 P. SMITH F. HERBERT MWD RUN 7 AK-MM-90228 T. MCGUIRE G. WHITLOCK 12 12N 8E 1044 281 .00 73 . 10 38 .40 OPEN HOLE CASING DRILLERS MAD RUN 7 AK-MM- 90228 T. MCGUIRE G. WHITLOCK BIT SIZE (IN) SIZE (IN) DEPTH (FT) 12.250 9.625 4706.0 8.500 7.000 13813.0 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING REMARKS: 1. ALL DEPTHS ARE MEASURED DEPTHS (MD) I/NLESS OTHERWISE STATED. 2. MWD RUNS 1 A_N-D 2 ARE DIRECTIONkL ONLY A/W]D ARE NOT PRESENTED. 3. MWD RUN 3, 5, 6, AND 7 ARE DIRECTIONAL WITH DUAL GAMMA RAY (DGR) UTILIZING GEIGER MUELLER TUBE DETECTORS AND ELECTROMAGNETIC WAVE RESISTIVITY PRASE 4 (EWR4) . 4. MWD RUN 4 IS DIRECTIONAL WITH DUAL GAMMA RAY (DGR) UTILIZING GEIGER MUELLER TUBE DETECTORS, ELECTROMAGNETIC WAVE RESISTIVITY PHASE 4 (EWR4), COMPENSATED THERMAL NEUTRON POROSITY (CTN), STABILIZED LITHO-DENSITY (SLD) . 5 . DENSITY AND POROSITY LOGS WERE RUN ON 3H-32PB1 AArD ARE PRESENTED ON THE LOGS FOR 3H-32PB1. 6. THE EXTRA SHALLOW PHASE RESISTIVITY (SEXP) FAILED ON MWD RUN 6 AND IS NOT PRESENTED FOR THE INTERVAL14452' MD, 5953' TVD TO 15276' MD, 5967' TV/D. 7. THE GAP IN THE GAMMA RAY FROM 11696' MD, 5433'TVD TO 11713' MD, 5439' TVD IS DUE TO A CHANGE IN SENSOR DISTANCE BETWEEN MWD RUN 3 AND MWD RUN 4. 8. A MADPASS (MAD) WAS PERFORMED OVER SERVER_AL INTERVALS WHILE TRIPPING OUT OF THE HOLE AFTER MWD RUN 7. THIS DATA IS PRESENTED AS A TAIL TO THIS LOG. 9. DIGITAL DATA ONLY HAS BEEN TIED INTO 3H-32PB1. DEPTH SHIFTING / CORRECTIO MWD DATA IS WAIVED PER THE EMAIL MESSAGE FROM D. SCHWARTZ OF ARCO, ALASK3t INC. OF 5/24/00. MWD DATA CONSIDERED PDC. THIS WELL KICKS OFF FROM 3H-32PB1 AT 13840' MD, 5915' TVD. ALL MWD LOG HEADER DATA RETAINS THE ORIGINAL DRILLER'S DEPTH REFERENCES. 10. MWD RUNS 1-7 REPRESENT WELL 3H-32 WITH API # 50-103-20322-00. THIS WELL REACHED A TOTAL DEPTH OF 16000' MD, 5999' TVD. SROP = SMOOTHED R_ATE OF PENETRATION 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 CURVES WITH THE EXTENSION "M" ARE MEASURED AFTER DRILLING (MAD) $ File Header Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 00/06/29 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.000 Comment Record FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE START DEPTH STOP DEPTH SGRC 4660 0 15950 5 SEXP 4696 0 15957 5 SEDP 4696 0 15957 5 SFXE 4696 0 15957 5 SEMP 4696 0 15957 5 SESP 4696 0 15957 5 SROP 4716 0 15995 0 $ BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) BASELINE DEPTH GR EQUIVALENT UNSHIFTED DEPTH 13833.5 13838.5 15995.0 16000.0 $ MERGED DATA SOURCE PBU TOOL CODE BIT RUN NO MERGE TOP MWD 3 4660.0 MWD 4 11750.0 MWD 5 13840.5 MWD 6 14488.5 MWD 7 15310.5 $ REMARKS: MERGED MAIN PASS. $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999 Depth Units ....................... Datum Specification Block sub-type...0 MERGE BASE 11749.5 13840.0 14488.0 15310.0 16000.0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD FT/H 4 1 68 4 2 GR MWD API 4 1 68 8 3 RPX MWD OHMM 4 1 68 12 4 RPS MWD OHMM 4 1 68 16 5 RPM MWD OHMM 4 1 68 20 6 RPD MWD OHMM 4 1 68 24 7 FET MWD HRS 4 1 68 28 8 Name Service Unit Min Max Mean Nsam DEPT FT 4660 15995 10327.5 22671 ROP MWD FT/H 1.57 3743.44 108.634 22559 GR MWD API 24.49 458.05 119.235 22548 RPX MWD OHMM 1.69 1575.75 5.94569 20874 RPS MWD OHMM 1.82 1768.41 7.29668 22524 RPM MWD OHMM 2.01 2000 9.89907 22524 RPD MWD OHMM 2.26 2000 12.0517 22524 FET MWD HRS 0.1675 114.463 2.00172 22524 First Reading 4660 4716 4660 4696 4696 4696 4696 4696 Last Reading 15995 15995 15950 5 15957 5 15957 5 15957 5 15957 5 15957 5 First Reading For Entire File .......... 4660 Last Reading For Entire File ........... 15995 File Trailer Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 00/06/29 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.002 Physical EOF File Header Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 00/06/29 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.001 Comment Record FILE HEADER FILE NUMBER: 2 EDITED MERGED MAD Depth shifted and clipped curves; all MAD runs merged using earliest passes. DEPTH INCREMENT: FILE SUMMARY PBU TOOL CODE GR RPM RPD RPS RPX FET RAT $ .5000 START DEPTH 13807 5 13815 0 13815 0 13815 0 13815 0 13815 0 13854 5 STOP DEPTH 15796 5 15804 5 15804 5 15804 5 15804 5 15804 5 15843 5 MERGED DATA SOURCE PBU TOOL CODE MWD $ REMARKS: MAD RUN NO. MAD PASS NO. 7 0 MERGED MAD PASS. $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999 Depth Units ....................... Datum Specification Block sub-type...0 MERGE TOP 13812.5 Name Service Order Units Size Nsam Rep DEPT FT 4 1 68 P~AT MAD FT/H 4 1 68 GR MAD API 4 1 68 RPX MAD OHMM 4 1 68 RPS MAD OHMM 4 1 68 RPM MAD OHMM 4 1 68 RPD MAD OHMM 4 1 68 FET MAD HRS 4 1 68 Code Offset Channel 0 1 4 2 8 3 12 4 16 5 20 6 24 7 28 8 MERGE BASE 15848.5 Name Service Unit Min Max DEPT FT 13807.5 15843.5 RAT MAD FT/H 1.77 1742.3 GR MAD API 35.82 137.75 RPX MAD OHMM 2.14 2000 RPS MAD OHMM 2.59 2000 RPM MAD OHMM 3.28 2000 RPD MAD OHMM 1.25 2000 FET MAD HRS 12.6431 622.975 Mean 14825.5 263.021 75.2984 22.9257 24.4156 34.193 33.5753 165.047 Nsam 4073 2078 2071 2067 2067 2067 2067 2067 First Reading 13807.5 13854.5 13807.5 13815 13815 13815 13815 13815 Last Reading 15843 5 15843 5 15796 5 15804 5 15804 5 15804 5 15804 5 15804 5 First Reading For Entire File .......... 13807.5 Last Reading For Entire File ........... 15843.5 File Trailer Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 00/06/29 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.003 Physical EOF File Header Service name ............. STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 00/06/29 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.002 Comment Record FILE HEAl)ER FILE NUMBER: 3 P~AW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 3 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 4660 0 FET 4696 0 RPX 4696 0 RPS 4696 0 RPM 4696 0 RPD 4696 0 ROP 4716 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: MAXI~ ~GLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA P~AY EWR4 ELECTROMAG. RESIS. 4 $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3) : RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN) : EWR FREQUENCY (HZ) : REMARKS: STOP DEPTH 11695 5 11705 0 11705 0 11705 0 11705 0 11705 0 11749 5 31-JAN-00 Insite 65.31 Memory 11750.0 67.9 71.5 TOOL NUMBER 1417HGVR6 1417HGVR6 8.500 LSND 9.30 39.0 8.5 275 5.8 3.700 6.940 4.200 3.500 65.0 128.0 65.0 65.0 $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep DEPT FT 4 1 68 ROP MWD030 FT/H 4 1 68 GR MWD030 API 4 1 68 RPX MWD030 OHMM 4 1 68 RPS MWD030 OHMM 4 1 68 RPM MWD030 OHMM 4 1 68 RPD MWD030 OHMM 4 1 68 FET MWD030 HRS 4 1 68 Code Offset Channel 0 1 4 2 8 3 12 4 16 5 20 6 24 7 28 8 Name Service Unit Min Max DEPT FT 4660 11749.5 ROP MWD030 FT/H 3.58 3743.44 GR MWD030 API 24.49 229.01 RPX MWD030 OHMM 1.78 1575.75 RPS MWD030 OHMM 1.88 1768.41 RPM MWD030 OHMM 2.01 1841.54 RPD MWD030 OHMM 2.26 2000 FET MWD030 HRS 0.1675 83.4957 Mean Nsam 8204.75 14180 133.773 14068 119.732 14072 4.54842 14019 4.80484 14019 5.0939 14019 7.08197 14019 0.95006 14019 First Reading 4660 4716 4660 4696 4696 4696 4696 4696 Last Reading 11749.5 11749.5 11695.5 11705 11705 11705 11705 11705 First Reading For Entire File .......... 4660 Last Reading For Entire File ........... 11749.5 File Trailer Service name ............. STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 00/06/29 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 ....... 00/06/29 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.003 Comment Record FILE HEADER FILE NLrMBER: P~AW MWD Curves and log header data for each bit run in separate files. BIT RUN NIIMBER: 4 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH FET 11705 5 RPM 11705 5 RPS 11705 5 RPX 11705 5 RPD 11705 5 GR 11713 0 ROP 11750 0 $ 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 ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3) : RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPEP~ATURE (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 STOP DEPTH 13840 0 13840 0 13840 0 13840 0 13840 0 13840 0 13840 0 03-FEB-00 Insite 65.31 Memory 13840.0 71.5 90.7 TOOL NUMBER PBO1419HRNLG6 PBO1419HRNLG6 8.440 13813 .0 GEM / LSND 10.80 45.0 8.5 650 9.6 1.850 3.930 1.600 2.000 65.0 145.7 65.0 65.0 Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999 Depth Units ....................... Datum Specification Block sub-type...0 Name DEPT ROP GR RPX RPS RPM RPD FET Service Order Units Size Nsam Rep FT 4 1 68 MWD040 FT/H 4 1 68 MWD040 API 4 1 68 MWD040 OHMM 4 1 68 MWD040 OHMM 4 1 68 MWD040 OHMM 4 1 68 MWD040 OHMM 4 1 68 MWD040 HRS 4 1 68 Code Offset Channel 0 1 4 2 8 3 12 4 16 5 20 6 24 7 28 8 Name Service Unit Min Max DEPT FT 11705.5 13840 ROP MWD040 FT/H 3.61 3495.18 GR MWD040 API 56.37 458.05 RPX MWD040 OHMM 1.69 17.57 RPS MWD040 OHMM 1.82 26.36 RPM MWD040 OHMM 2.05 2000 RPD MWD040 OHMM 2.63 2000 FET MWD040 HRS 0.6525 41.7281 Mean 12772.8 92.9122 149.894 4.6863 5.44445 16.5752 18.6537 2.11199 Nsam 4270 4181 4255 4270 4270 4270 4270 4270 First Reading 11705.5 11750 11713 11705.5 11705.5 11705.5 11705.5 11705.5 Last Reading 13840 13840 13840 13840 13840 13840 13840 13840 First Reading For Entire File .......... 11705.5 Last Reading For Entire File ........... 13840 File Trailer Service name ............. STSLIB.004 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 00/06/29 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 ....... 00/06/29 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.004 Comment Record FILE HEADER FiLE NUMBER: 5 P~AW MWD Curves and log header data for each bit run in separate files. BiT RUN NUMBER: 5 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH ROP 13840.5 14488.0 RPD 13840 5 RPM 13840 5 RPS 13840 5 RPX 13840 5 GR 13840 5 FET 13840 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 ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : 14451 5 14451 5 14451 5 14451 5 14445 0 14451 5 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 TERMPEP~ATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ) : REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999 Depth Units ....................... Datum Specification Block sub-type...0 18-FEB-00 Insite 0.41 Memory 14488.0 83.0 90.7 TOOL NUMBER P1376GR4 P1376GR4 6.130 GEM / LSND 11.70 47.0 9.0 750 3.4 3 .500 1.910 1.920 1.950 70.0 132 .3 70.O 70.0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD050 FT/H 4 1 68 4 2 GR MWD050 API 4 1 68 8 3 RPX MWD050 OHMM 4 1 68 12 4 RPS MWD050 OHMM 4 1 68 16 5 RPM MWD050 OHMM 4 1 68 20 6 RPD MWD050 OHMM 4 1 68 24 7 FET MWD050 HRS 4 1 68 28 8 Name Service Unit DEPT FT ROP MWD050 FT/H GR MWD050 API RPX MWD050 OHMM RPS MWD050 OHMM RPM MWD050 OHMM RPD MWD050 OHMM FET MWD050 HRS Min Max Mean Nsam 13840.5 14488 14164.3 1296 1.57 1616.78 36.5199 1296 40.14 133.9 99.555 1210 4.46 61.3 11.0508 1223 4.49 58.7 11.4788 1223 4.42 61.85 12.1764 1223 4.84 74.45 14.013 1223 1.1725 9.6356 3.58945 1223 First Reading 13840 5 13840 5 13840 5 13840 5 13840 5 13840 5 13840 5 13840 5 Last Reading 14488 14488 14445 14451.5 14451.5 14451.5 14451.5 14451.5 First Reading For Entire File .......... 13840.5 Last Reading For Entire File ........... 14488 File Trailer Service name ............. STSLIB.005 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 00/06/29 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.006 Physical EOF File Header Service name ............. STSLIB.006 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 00/06/29 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.005 Comment Record FILE HEADER FILE NUMBER: 6 RAW MWD Curves and log header data for each bit run in separate files. BiT RUN NUMBER: 6 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR RPD FET RPM RPS ROP $ 14445 5 14452 0 14452 0 14452 0 14452 0 14488 5 STOP DEPTH 15269.5 15276.5 15276.5 15276.5 15276.5 15310.0 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 ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3) : RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ) : REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999 Depth Units ....................... Datum Specification Block sub-type...0 22-FEB-00 Insite 0.41 Memory 15310.0 82.7 91.7 TOOL NUMBER P1376GR4 P1376GR4 6.130 GEM / LSND 11.70 46.0 9.0 650 3.6 4.800 2.250 1.150 3.400 70.0 145.0 70.0 70.0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD060 FT/H 4 1 68 4 2 GR MWD060 API 4 1 68 8 3 RPS MWD060 OHMM 4 1 68 12 4 RPM MWD060 OHMM 4 1 68 16 5 RPD MWD060 OHMM 4 1 68 20 6 FET MWD060 HRS 4 1 68 24 7 Name Service Unit DEFT FT ROP MWD060 FT/H GR MWD060 API RPS MWD060 OHMM RPM MWD060 OHMM RPD MWD060 OHMM FET MWD060 HRS Min Max 14445.5 15310 5 . 87 955 . 74 44.09 97.52 11.05 29.93 11.64 34.36 13.84 37.26 0 . 6794 33 . 4335 Mean Nsam 14877.8 1730 50.1386 1644 78.3615 1649 18.9375 1650 21.4817 1650 23.6289 1650 4.57652 1650 First Reading 14445.5 14488.5 14445.5 14452 14452 14452 14452 Last Reading 15310 15310 15269.5 15276.5 15276.5 15276.5 15276.5 First Reading For Entire File .......... 14445.5 Last Reading For Entire File ........... 15310 File Trailer Service name ............. STSLIB.006 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 00/06/29 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.007 Physical EOF File Header Service name ............. STSLIB.007 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 00/06/29 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.006 Comment Record FILE HEADER FILE NUMBER: 7 P~AW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 7 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR FET RPD RPM RPS RPX ROP $ LOG HEADER DATA DATE LOGGED: SOFTWARE 15270.0 15277 0 15277 0 15277 0 15277 0 15277 0 15310 5 SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : STOP DEPTH 15955.5 15962 5 15962 5 15962 5 15962 5 15962 5 16000 0 29-FEB-00 Insite 0.41 Memory 16000.0 BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3) : RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ) : REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999 Depth Units ....................... Datum Specification Block sub-type...0 82.2 95.5 TOOL NUMBER PBO1376GRV4 PBO1376GRV4 6.130 GEM / LSND 12.10 49.0 9.5 750 2.9 1.300 .556 1.180 1.380 60.0 148.4 60.0 60.0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD070 FT/H 4 1 68 4 2 GR MWD070 API 4 1 68 8 3 RPX MWD070 OHMM 4 1 68 12 4 RPS MWD070 OHMM 4 1 68 16 5 RPM MWD070 OHMM 4 1 68 20 6 RPD MWD070 OHMM 4 1 68 24 7 FET MWD070 HRS 4 1 68 28 8 Name Service Unit Min Max Mean Nsam DEPT FT 15270 16000 15635 1461 ROP MWD070 FT/H 3.69 673.42 37.013 1380 GR MWD070 API 50.17 124.76 85.0655 1372 First Reading 15270 15310.5 15270 Last Reading 16000 16000 15955.5 RPX MWD070 OHMM RPS MWD070 OHMM RPM MWD070 OHMM RPD MWD070 OHMM FET MWD070 HRS 4.23 73.72 4.42 68.62 4.61 57.61 5.13 82.52 1.1393 114.463 19.6164 1372 20.8285 1372 22.3156 1372 26.6738 1372 7.91495 1372 15277 15277 15277 15277 15277 15962,5 15962,5 15962,5 15962,5 15962,5 First Reading For Entire File .......... 15270 Last Reading For Entire File ........... 16000 File Trailer Service name ............. STSLIB.007 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 00/06/29 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.008 Physical EOF File Header Service name ............. STSLIB.008 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 00/06/29 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.007 Comment Record FILE HE~_DER FILE NUMBER: 8 RAW MAD Curves and log header data for each pass of each run in separate files. DEPTH INCREMENT: .5000 MAD RUN NUMBER: 7 MAD PASS NIIMBER: 0 FILE S UMM3LRY VENDOR TOOL CODE ST~LRT DEPTH GR FET RPD RPM RPS RPX P~AT $ LOG HEADER DATA DATE LOGGED: SOFTWARE 13812 5 13820 0 13820 0 13820 0 13820 0 13820 0 13859 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: MAXIMU-MANGLE: TOOL STRING (TOP TO BOTTOM) STOP DEPTH 15801 5 15809 5 15809 5 15809 5 15809 5 15809 5 15848 5 29-FEB-00 Insite 0.41 Memory 16000.0 82.2 95.5 VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA P3%Y EWR4 ELECTROMAG. RESIS. 4 $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3) : RESISTIVITY (OHM_M) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ) : REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999 Depth Units ....................... Datum Specification Block sub-type...0 TOOL NUMBER PBO1376GRV4 PBO1376GRV4 6.130 GEM / LSND 12.10 49.0 9.5 750 2.9 1.300 .556 1.180 1.380 60.0 148.4 60.0 60.0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 P~AT MAD070 FT/H 4 1 68 4 2 GR MAD070 API 4 1 68 8 3 RPX MAD070 OHMM 4 1 68 12 4 RPS MAD070 OHMM 4 1 68 16 5 RPM MAD070 OHMM 4 1 68 20 6 RPD MAD070 OHMM 4 1 68 24 7 FET MAD070 HRS 4 1 68 28 8 Name Service Unit DEPT FT RAT MAD070 FT/H GR MAD070 API RPX MAD070 OHMM RPS MAD070 OHMM RPM MAD070 OHMM RPD MAD070 OHMM FET MAD070 HRS Min Max Mean Nsam 13812.5 15848.5 14830.5 4073 1.77 1742.3 263.021 2078 35.82 137.75 75.2984 2071 2.14 2000 22.9257 2067 2.59 2000 24.4156 2067 3.28 2000 34.193 2067 1.25 2000 33.5753 2067 12.6431 622.975 165.047 2067 First Reading 13812.5 13859.5 13812.5 13820 13820 13820 13820 13820 Last ReadinG 15848 15848 15801 15809 15809 15809 15809 15809 First Reading For Entire File .......... 13812.5 Last Reading For Entire File ........... 15848.5 File Trailer Service name ............. STSLIB.008 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 00/06/29 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.009 Physical EOF Tape Trailer Service name ............. LISTPE Date ..................... 00/06/29 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Next Tape Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Reel Trailer Service name ............. LISTPE Date ..................... 00/06/29 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Next Reel Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Scientific Technical Technical Services Services Physical EOF Physical EOF End Of LIS File
