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
204-153
WELL LOG TRANSMITTAL #906156335 To: Alaska Oil and Gas Conservation Comm. Attn.: Natural Resource Technician 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Packer Setting Record: 1E-166 Run Date: 12/4/2019 20 4153 3 194 8 January 17, 2020 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Fanny Sari, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 FRS_ANC@halliburton.com 1E-166 Digital Data in LAS format, Digital Log Image file 1 CD Rom 50-029-23223-00 Rr CE' /E® L.JAN 2 2 2020 AOGCC PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Fanny Sari 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-275-2605 FRS_ANC@halliburton.com Date: WVZOZO Signed: nct.crvmu STATE OF ALASKA DEC 1 1 2017 ALL OIL AND GAS CONSERVATION COMMI ION REPORT OF SUNDRY WELL OPERATIONS AOGCC 1.Operations Abandon ❑ Plug Perforations❑ Fracture Stimulate ❑ Pull Tubing❑ Operations shutdown ❑ Performed: Suspend ❑ Perforate ❑ Other Stimulate ❑ Alter Casing❑ Change Approved Program ❑ Plug for Redrill ❑ erforate New Pool ❑ Repair Well ❑ Re-enter Susp Well❑ Other: RPPG D MBE Trtmt E 2.Operator 4.Well Class Before Work: 5.Permit to Drill Number: Name: ConocoPhillips Alaska, Inc. Development 0 Exploratory ❑ 204-153 3.Address: P. O. Box 100360,Anchorage, Alaska Stratigraphic Service ❑ 6.API Number: 99510 50-029-23220-00 7.Property Designation(Lease Number): 8.Well Name and Number: KRU 1E-166 ADK 25661,ADL 25660 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): N/A Kuparuk River Field/West Sak Oil Pool 11.Present Well Condition Summary: Total Depth measured 9,602 feet Plugs measured None feet true vertical 3,519 feet Junk measured None feet Effective Depth measured 9,594 feet Packer measured 4677,5010.5302 feet true vertical 3,517 feet true vertical 3244,3331,3391 feet Casing Length Size MD TVD Burst Collapse CONDUCTOR 78 feet 20 " 108'MD 108 TVD SURFACE 2,982 feet 10 3/4" 3,012' MD 2392 TVD INTERMEDIATE 5,987 feet 7 5/8 " 6,014' MD 3502 TVD A-SAND LINER 4,294 feet 4 1/2" 9,596' MD 3518 TVD Perforation depth Measured depth 6043-9561 feet True Vertical depth 3508-3517 feet Tubing(size,grade,measured and true vertical depth) 4.5" L80 4,712' MD 3,256'TVD Packers and SSSV(type,measured and true vertical depth) PACKER=ZXP Packer 4,677' MD 3,244'TVD PACKER=ZXP Liner Top Packer 5,010' MD 3,331'TVD PACKER= HRD ZXP Liner Packer 5,302' MD 3,391'TVD SSSV: = NONE N/A N/A 12.Stimulation or cement squeeze summary: Intervals treated(measured): N/A Treatment descriptions including volumes used and final pressure: SCANNED JAN 2 A ZU1 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 251 290 158 - 278 Subsequent to operation: Shut-In - - - - 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations 0 Exploratory ❑ Development 0 Service ❑ Stratigraphic El Copies of Logs and Surveys Run ❑ 16.Well Status after work: Oil 0 Gas ❑ WDSPL ❑ Printed and Electronic Fracture Stimulation Data ❑ 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: 317-404 Contact Name: John Peirce Authorized Name: John Peirce Contact Email: John.W.Peirce©cop.com Authorized Title: Sr.Wells Engineer Authorized Signature: '/ €i Date: 1211 .117 Contact Phone: (907)265-6471 Fnrm 10-404 Ravi d d/7017 • •� Submit Original Only , '/V4 VT& //Z'' RF3DMS t/ Er 1 2 2017 • • IE- 112L2 - IE- 166 RPPG D MBE TREATMENT DTTMSTE JOBTYP SUMMARYOPS 11/3/17 MISC. CAPA(RIH WITH 2" E-COIL GR/CCL, E-FIRE AND 5' POWERFLOW HSD GUN (6SPF) BHA. LOG 8849' -8400', CORRECT DEPTH TO 8840.7' RKB. PICK UP TO 8796.7' RKB, PERFORATE FROM 8800' -8805' RKB. POOH, CONFIRM SHOTS FIRED. RDMO. JOB . 11/9/17 MISC. Performed full-bore RPPG treatment pumping 144.3 bbls of—0.75 CAPACITY ppg RPPG placing 5016#of RPPG followed by 330 lb of 0.25 ppg SUSTAINM crystal seal. Displaced into liner/MBE with 125 seawater and 36 bbl ENT freeze protect. Note: Well to remain shut in until CTU cleanout. Will attach treatment report once available. 11/11/17 PUMPING INJECTIVITY TEST TRACKING 0.5 BPM FOR 30 MIN ONLY 0.75 BPM FOR 30 MIN (JOB COMPLETE) • . KUP PD 1E-166 • Con©coPhillips Well Attribut Max AngleIP TD A,1i=18k ,)31c:.. Wellbore APIIUWI Field Name Wellbore Status ncl(°) MD(ftKB) Act Btm(ftKB) Catod44,11ips 500292322000 WEST SAK PROD 100.34 6,460.04 9,602.0 ..- Comment H2S(ppm) Date Annotation' End Date KB-Grd(ft) Rig Release Date 1E-166,12/11!20178:42:12 AM SS V:NIPPLE 200 7/31/2015 Last WO' 2/9/2009 35.29 9/24/2004 _ versa sawn..f...1,4.) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date W Last Tag: C/O pproven 7/12/2016 11 I ii 't:asing Strings """""^""""""HANGER;22.0' "r __Via '` alLL Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread CONDUCTOR 20 19.124 30.0 108.0 108.0 62.50 H-40 WELDED �,�-................ 11,11511 �• -,,�_Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth)TVD)...Wt/Len(I...Grade Top Thread CONDUCTOR;30.0-106.0ligl SURFACE 103/4 9.950 29.8 3,012.0 2,392.4 45.50 L-80 BTC NIPPLE;509.1AN Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... WtlLen(I...Grade Top Thread - INTERMEDIATE 75/8 6.875 26.9 6,014.0 3,501.9 29.70 L-80 _BTCM HEAT TRACE;22.0 • Description OD(in) ID(in) Top IRKS) Set Depth(ftKB) Set Depth(TVD)...'Wt/Len(I...Grade Top Thread D-SAND LINER LEM 41/2 3.958 4,676.5 5,034.0 3,336.0 12.60 SCC IBTM Liner Details Nominal ID SURFACE;29.83,012.0 t Top(ftKB) Top(ND)(ftKB) Top Incl CI Item Des Corn (in) lICaning 4,676.5' 3,244.3 70.58 PACKER ZXP Packer 4.970 lllal GAS LIFT;3,0292 4,695.5' 3,250.5 71.26 SBE '190-47 Casing Seal Bore Extension 4.750 fli 4,751.6' 3,267.6 73.27 NIPPLE 3.75"'DB'Nipple 3.750 ME ME 4,788.3 3,277.8 74.31 UPPER HH Upper LEM Assembly 3.910 GAS LIFT,4542.7 4,795.1 3,279.6 74.47 LOWER HH Lower LEM Assembly 3.990 IN 5,030.7' 3,335.3 78.07 SEAL ASSY Seal Assembly 3.930 NIPPLE;4,624.6 Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)...WtlLen(I...Grade Top Thread GAUGE;4,632.0gilti- D-SAND WINDOW 41/2 3.958 4,799.0 4,811.0_ 3,283.8 12.60 Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread B-SAND LINER HH 41/2 3.958 5,010.1 5,345.8 3,399.1 12.60 L-80 IBT LOCATOR;4,684.8 Liner Details -I Nominal ID SEAL ASSY;4,693.9 ',- Top(ftKB) Top(ND)(MB) Top Incl C) Item Des Com (in) 5,010.1 3,331.0 77.66 PACKER ZXP LINER TOP PACKER 6.230 5,029.1 3,335.0 78.03 XO BUSHING 4.760 5,029.9 3,335.1 78.05 SBR 109-47 CASING SEAL BORE RECEPTACLE 4.750 5,049.2 3,339.1 78.27 XO BUSHING 3.910 5,057.1 3,340.7 78.23 HANGER LEM ABOVE HOOK HANGER 4.020 III 4 I f 5,063.1 3,341.9 78.20 HANGER LEM INSIDE HOOK HANGER 4.020 11 D-SAND WINDOW;4,799.0- 1j ril 5,129.0 3,355.6 77.87 NIPPLE DB-6CAMCONIPPLE 3.562 4,811.0 ) !JI 5,342.5 3,398.6 80.02 SEAL ASSY BAKER SEAL ASSEMBLY 3.890 Casing Description OD(in) ID(in) Top(BOB) Set Depth(ftKB) Set Depth(ND)... Wt/Len(I...Grade Top Thread IB-SAND WINDOW 41/2 3.958 5,068.0 5,080.0 3,345.4 12.60 SLOTS;4,022.0-9,363D Casing Description OD(in) ID(in) 'Top(ftKB) Set Depth(BOB) Set Depth(ND)... Wt/Len g...Grade Top Thread D-SAND LINER;4,795.7-9,402.0I I A-SAND LINER 4 1/2 3.958 5,302.2 9,596.0 3,518.4 12.60 L-80 DWC Liner Details Nominal ID Top(MB) Top(ND)(ftKB) Top Incl(°) Item Des Com (in) mom: 5,302.2 3,391.3 79.17 PACKER 'HRD ZXP LINER TOP PACKER 4.970 ff D-SAND LINER LEM;4,676E- I. i 5,321.2 3,394.8 79.52 NIPPLE 'RS PACKOFF SEAL NIPPLE 4.875 5,034.0 alvC 5,324.0 3,395.3 79.58 HANGER FLEXLOCK LINER HANGER 4.853 l 5,334.6 3,3972 79.83 SBE 190-47 CASING SEAL BORE EXTENSION 4.750 5,353.9 3400.5 80.29 XO BUSHING 4.500 • B-SAND LINER;5,063.1-9,379.7 TubingStrings B-SAND WINDOW;5,068.0- g 5,080.0 ! i-1 TubingDescription String Ma...ID(in) To (ftKB)22.11 Set De th ft..Set Depth(ND)(...Wt Ib/rt Grade To Connection - TUBING p 1 41/21 3.9581 p 4,712.01 (3,255.71 12.601 L80 'Top Completion Details Nominal ID Top(ftKB) Top(ND)(ftKB) Top Incl(') Item Des Com (in) 22.1 22.1 0.00 HANGER Vetco Gray 13 1/2"x 4 1/2"Hgr w/4.909"MCA Top 3.900 Conn. 509.1 507.8 11.10 NIPPLE Camco 4 1/2"X 3.875""DB"Nipple 3.875 -� - 4,624.6 3,226.3 68.82 NIPPLE Camco 4 1/2"X 3.812""DB"Nipple 3.812 I.sr.I 4,632.0 3,228.9 69.07 GAUGE Baker Guardian Gauge w/pups 3.958 r■t . 4,684.8 3,247.0 70.87 LOCATOR Locator Ring and Coupling 3.890 B-SAND LINER HH;5.010.1- 4,693.9 3,250.0 71.20 SEAL ASSY GBH-22 Seal Assembly(2 ft space out) 4.000 5,315.8 ij Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) Top(TVD( Top Incl Top(ft013) (ftKB) (°I Des Corn Run Date ID(in) 22.0 22.0 0.00 HEAT 2/10/2009 0.000 INTERMEDIATE;26.9-6,014.0 • TRACE SLOTS;6,043.08,073.0 Perforations&Slots Shot Dens BLOTS;0.188.0-6,229.o--. Top(TVD) Btm(ND) (shots/ Top(ftKB) Btm(ftKB) (ftKB) (MO) Zone Date ft) Type Corn 6,043.0 6,073.0 3,507.7 3,513.6 WS A2,1E- 9/24/2004 32.0 SLOTS ALL PERFS 6023'- SLOTS;6,384.0-6,415.0 166 9561':Slotted liner w/constrictor packers SLOTS;6,S3v.o-6.Bze.o between,32 spf,2.5"L x.1251A/in 4 circumferential rows 1-- 6.198,0 6,229.0 3,536.9 3,541.4 WS A2,1E- 9/24/2004 320 SLOTS SLOTS;7,06567,583.0 r 166 I- 6,384.0 6,415.0 3,543.1 3,539.0 WS A2,1E- 9/24/2004 32.0 SLOTS SLOTS;7355.0-8/372.0-. l_ 166 Ti 6,539.0 6,629.0 3,518.6 3,507.7 WS A2,1E- 9/24/2004 32.0 SLOTS r 166 SLOTS;8,559.0-9,104.07,065.0 7,583.0 3,508.6 3,520.4 WS A2,1E- 9/24/2004 32.0 SLOTS 166 7,955.0 8,372.0 3,529.6 3,524.3 WS A2,1E- 9/24/2004 32.0 SLOTS SLOTS;9,352.0-9,561.01 .1... 166 8,559.0 9,104.0 3,508.7 3,498.7 WS A2,1E- ,9/24/2004 32.0 SLOTS 166 A-SAND LINER;5,302.2&,588.0 - KUP POD 0 1E-166 ConocoPhillips Aidi)s ,Inc.. CorwcdlMllips ••.•• 1 E-166,12/11/2017 8:42:13 AM Vertical.acod anc(eolod) i 1I r a Perforations&Slots Shot YYYI4 ftwft"""'HANGER;22.5 ' ,, ,"a^�•, Dens Top(TVD) Btm(TVD) (shots/ -'s-A"CONDUCTOR;30.0-108.0~' �''"Sc Top(ftKB) Btm(ftKB) (NAB) (ftKB) Zone Date ft) Type Com 9,352.0 9,561.0 3,512.7 3,517.1 WS A2,1E- 9/24/2004 32.0 SLOTS NIPPLE;508.1 'I 166 HEAT TRACE;22.0 Mandrel Inserts St 0ati Top(TVD) Valve Latch Port Size TRO Run SURFACE;28.8-3,0123 t N Top(ftKB) (ftKB) Make Model OD(In) Sew Type Type (in) (psi) Run Date Corn I 1 3,029.2 2,403.9 Camco KBG-2- 1 GAS LIFT GLV BK 0.188 1,459.0 7/9/2016 ill 1R GAS LIFT;3,029.2 2 4,542.7 3,194.9 Camco KBG-2- 1 GAS LIFT +OV BK 0.250 7/8/2016 111 Mk Notes:General&Safety GAS LIFT;4,542.7 li End Date Annotation 11/17/2005 NOTE:WORKOVER TO RECONNECT ESP CABLE-NO OTHER CHANGES NIPPLE;4,624.6 2/17/2009 NOTE:VIEW SCHEMATIC w/Alaska Schematic9.0 2/17/2009 NOTE:WORKOVER TO CONVERT FROM ESP TO GAS LIFT GAUGE;4,832.0 LOCATOR;4,684.8 IE.' MA' SEAL ASSY;4,693.9- I It I D-SAND WINDOW;4,799.0-4,811.0 ' SLOTS;4,822.5-9,363.0 D-SAND LINER;4,795.7-9,402.0 D-SAND LINER LEM;4,676.5- 5,034.0 Sr B-SAND LINER;5,063.1-9,379.7 8SAND WINDOW;5,088.0- I II 5080.0 t d I 111 B-SAND LINER HH;5,010.1- r 5,345.5 INTERMEDIATE;26.9-6,014.0 SLOTS;6,043.08,073.0 'f 1 SLOTS;6,198.0-6,228.0 - r - r SLOTS;6,384.0-6,415.0 4-4 SLOTS;6,539.0-6,629.0 SLOTS;7,065.0-7,583.0 ' r, SLOTS;7,955.58,372.0 r SLOTS;8,559.0-9,104.0 SLOTS;9,352.0-9,561.0 A-SAND LINER',5,302.2-9,596.0 1 I RECEIVED STATE OF ALASKA AIL OIL AND GAS CONSERVATION COMM ON DEC 1 1 2017 REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon LIPlug Perforations ElFracture Stimulate 1=I1I Pull Tubing❑ � 1 r ,Gown ❑ Performed: Suspend ❑ Perforate ❑ Other Stimulate ❑ Alter Casing❑ Change Approved Program ❑ Plug for Redrill ❑ erforate New Pool ❑ Repair Well ❑ Re-enter Susp Well❑ Other: RPPG D MBE Trtmt D 2.Operator 4.Well Class Before Work: 5.Permit to Drill Number: Name: ConocoPhillips Alaska, Inc. Development 0 Exploratory ❑ 204-153 3.Address: P. O. Box 100360, Anchorage,Alaska Stratigraphic❑ Service ❑ 6.API Number: 99510 50-029-23220-00 7.Property Designation(Lease Number): 8.Well Name and Number: KRU 1E-166 ADK 25661,ADL 25660 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): N/A Kuparuk River Field/West Sak Oil Pool 11.Present Well Condition Summary: Total Depth measured 9,602 feet Plugs measured None feet true vertical 3,519 feet Junk measured None feet Effective Depth measured 9,594 feet Packer measured 4677,5010.5302 feet true vertical 3,517 feet true vertical 3244,3331,3391 feet Casing Length Size MD TVD Burst Collapse CONDUCTOR 78 feet 20 " 108' MD 108 TVD SURFACE 2,982 feet 10 3/4" 3,012' MD 2392 TVD INTERMEDIATE 5,987 feet 7 5/8" 6,014' MD 3502 TVD A-SAND LINER 4,294 feet 4 1/2 " 9,596' MD 3518 TVD Perforation depth Measured depth 6043-9561 feet True Vertical depth 3508-3517 feet Tubing(size,grade,measured and true vertical depth) 4.5 " L80 4,712' MD 3,256'TVD Packers and SSSV(type,measured and true vertical depth) PACKER=ZXP Packer 4,677' MD 3,244'TVD PACKER=ZXP Liner Top Packer 5,010' MD 3,331'TVD PACKER= HRD ZXP Liner Packer 5,302' MD 3,391'TVD SSSV: = NONE N/A N/A 12.Stimulation or cement squeeze summary: Intervals treated(measured): N/A lF Treatment descriptions including volumes used and final pressure: SCANWE i ►�! �' 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 251 290 158 - 278 Subsequent to operation: Shut-In - - - - 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations 2 Exploratory ❑ Development 0 Service ❑ Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16.Well Status after work: Oil El Gas ❑ WDSPL ❑ Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ LI 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: --simo4 31T-30 Contact Name: John Peirce r 4 45 Authorized Name: John Peirce Contact Email: John.W.Peirce@cop.com Authorized Title: Sr.Wells Engineer A> trier /� Contact Phone: (907)265-6471 Authorized Signature: c�l+�. .•t, "" Date: ��/ �'�7 Fnrm 1n-4n4 Reui prl 417017 - - _ Submit Original()illy ,�( v'r� z l RBD VIS L`-CEC 1 2 2017 • • IE- 1 19- IE- 166 RPPG D MBE TREATMENT DTTMSTAF JOBTYP SUMMARYOPS 11/10/17 NRWO Performed full-bore RPPG treatment pumping 151 bbls of— 0.85 ppg RPPG placing 5016# of RPPG into formation followed by 550 lb of—0.46 ppg crystal seal. Displaced with 27 bbls seawater and 28 bbl diesel freeze protect. KUP P D 1E-166 Cone Phillips P Well Attribut� Max Angle TD Alatika.Inc,. Wellbore API/UWI Field Name Wellbore Status Inc'(°) MD(ftKB) Act Btm(ftKB) Can "hl8ips ,? 500292322000 WEST SAK PROD 100.34 6,460.04 9,602.0 --- Comment H2S(ppm) Date Annotation End Date KB-Gm(tt) Rig Release Date 1E-166,12/11/20179:44:05 AM SSSV:NIPPLE 200 7/31/2015 Last WO: 2/9/2009 35.29 9/24/2004 Vertical scherratc(actual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date y Last Tag: Rev Reason:H2S,GLV C/O pproven 7/12/2016 i IlrI i Casing Strings Luuuu""�""�"�u HANGER;22.0 • L I '� J_ .qua Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... Wt/Len(I...Grade Top Thread CONDUCTOR 20. 19.124 30.0 108.0 108.0 62.50 H-40 WELDED MI�tiw w w w w w w w j��Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread CONDUCTOR;30.6106.0 SURFACE 10 3/4 9.950 29.8 3,012.0 2,392.4 45.50 L-80 BTC NIPPLE;509.1 Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)...Wt/Len(I...Grade Top Thread INTERMEDIATE 7 5/8 6.875 26.9 6,014.0 3,501.9 29.70 L-80 BTCM HEAT TRACE;22.0 Casing Description 'OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread ID-SAND LINER LEM 4 1/2 3.958 4,676.5 5,034.0 3,336.0 12.60 SCC IBTM Liner Details Nominal ID SURFACE;29.8-3,012.0-. I. Top(16(B) Top(ND)(ftKB) Top Incl r) Item Des Com (in) 4,676.5 3,244.3 70.58 PACKER ZXP Packer 4.970 itE 4,695.5 3,250.5 71.26'SBE 190-47 Casing Seal Bore Extension 4.750 GAS LIFT;1028.2 Li L 4,751.6' 3,267.6 73.27_NIPPLE 3.75"'DB'Nipple .' 3.750 MN 4,788.3' 3,277.8 74.31 UPPER HH Upper LEM Assembly 3.910 GAS LIFT'4,542.7 4,795.1 3,279.6 74.47 LOWER HH Lower LEM Assembly 3.990 MIN MIM 5,030.7' 3,335.3 78.07 SEAL ASSY Seal Assembly 3.930 NIPPLE;4,824.6 Casing Description OD(in) ID(in) `Top(ftKB) Set Depth(ftKB) Set Depth(ND)...Wt/Len(I...Grade Top Thread lit GAUGE;4,6320 D-SAND WINDOW 41/2 3.958 4,799.0 4,811.0 3,283.8 12.60. Casing Description 'OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)...-Wt/Len(I...'Grade Top Thread 111 B-SAND LINER HH 4 1/2 3.958 5,010.1 5,345.8 3,399.1 12.60 L-80 IBT LOCATOR;4,684.8 Liner Details .iiii-I Nominal ID Top(ftKB) Top(ND)(ftKB) Top Inel r) Item Des Com (in) SEAL ASSY;4093.9 5,010.1 3,331.0 77.66 PACKER ZXP LINER TOP PACKER 6.230 ii5,029.1 3,335.0 78.03 XO BUSHING 4.760 5,029.9 3,335.1 78.05 SBR 109-47 CASING SEAL BORE RECEPTACLE 4.750 5,049.2 3,339.1 7827 XO BUSHING .. 3.910 5,057.1 3,340.7' 78.23 HANGER LEM ABOVE HOOK HANGER 4.020 •i' 'l lint€ ( 5,063.1 3,341.9' 78.20 HANGER 'LEM INSIDE HOOK HANGER 4.020 o-SAND WINDOW;4,799.0- Ili Iff 5,129.0 3,355.6 77.87 NIPPLE CAMCO'DB-6' NIPPLE 3.562 4,811.0 II; III 5,342.5 3,398.6 80.02 SEAL ASSY BAKER SEAL ASSEMBLY 3.890 1 Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)...WtlLen(I...Grade Top Thread B-SAND WINDOW 41/2 3.958 5,068.0 5,080.0 3,345.4 12.60 SLOTS;4,822.0-6363.0--. Casing Description OD(in) ID(in) 'Top(ftKB) Set Depth(ftKB) 'Set Depth(ND)...-Wt/Len(I...Grade Top Thread 0-SAND LINER;4,795.7-9,402.0 A-SAND LINER 41/2 3.958 5,302.2 9,596.0 3,5184 12.60 L-80 DWC Liner Details Nominal ID Top(ftKB) Top(TVD)(ftKB) Top Incl C) Item Des Com (in) 5,302.2 3,391.3 79.17 PACKER HRD ZXP LINER TOP PACKER 4.970 4.11 D-SAND LINER LEM;4,678.5- 5,321.2 3,394.8 79.52 NIPPLE RS PACKOFF SEAL NIPPLE 4.875 5,034.0 5,324.0 3,395.3 79.58 HANGER FLEXLOCK LINER HANGER 4.853 5,334.6 3,397.2 79.83 SBE '190-47 CASING SEAL BORE EXTENSION 4.750 5,353.9 3,400.5 80.29 XO BUSHING ' 4.500 B-SAND LINER;5,063.1-9,379.7 e. 1 TubingStrings B-SAND WINDOW;5,068.0- '' g 5,080.0 a -': Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft..Set Depth(ND)(...Wt(Iblft) Grade Top Connection 17 5 TUBING 41/21 3.9581 22.11 4,712.01 3,255.71 12.60 L80 I IBTM Completion Details Nominal ID Top(ftKB) Top(ND)(ftKB) Top Incl(°) Item Des Com (in) 22.1 22.1 0.00 HANGER Vetco Gray 13 1/2"x 4 1/2"Hgr w/4.909"MCA Top 3.900 Conn. 509.1 507.8 11.10 NIPPLE Camco 4 1/2"X 3.875""DB"Nipple 3.875 4,624.6 3,226.3 68.82 NIPPLE Camco 4 1/2"X 3.812""DB"Nipple 3.812 Y 4,632.0' 3,228.9 69.07 GAUGE Baker Guardian Gauge w/pups 3.958 Iti 4,684.8 3,247.0 70.87 LOCATOR Locator Ring and Coupling 3.890 B-SAND LINER HH;5.010.1- r 4,693.9 3,250.0 71.20 SEAL ASSY GBH-22 Seal Assembly(2 5 space out) 4.000 5,345.8 Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) Top(TVD) Top Incl Top(ftKB) (ftKB) (') Des Com Run Date ID lin) 22.0 22.0 0.00 HEAT 2/10/2009 0.000 INTERMEDIATE;26.96,014.0 TRACE SLOTS;6143.06673.0 Perforations&Slots Shot Dens SLOTS;6,198.06,228.0 Top(TVD) Btu)(ND) (shots/ Top(ftKB) Btm(ftKB) (ftKB) (ftKB) Zone Dat: ft) Type Com 6,043.0 6,073.0 3,507.7 3,513.6 WS A2,1E- 9/24/2004 32.0 SLOTS ALL PERFS6023'- SLOTS;6,384.06,415.0 166 9561':Slotted liner wlconstrictor packers between,32 spf,2.5"L SLOTS;6,538.06,629.0 x.125'W in 4 circumferential rows SLOTS;7,065.0-7,583.0 6,198.0 6,229.0 3,536.9 3,541.4 WS A2,1E- 9/24/2004 32.0 SLOTS 166 6,384.0 6,415.0 3,543.1 3,539.0 WS A2,1E- 9/24/2004 32.0 SLOTS SLOTS;7,955.06,372.0 166 6,539.0 6,629.0 3,518.6 3,507.7 WS A2,1E- 9/24/2004 32.0 SLOTS .- 166 SLOTS;esss.a9,104.0 7,065.0 7,583.0 3,508.6 3,520.4 WS A2,1E- 9/24/2004 32.0 SLOTS 166 7,955.0 8,3720 3,529.6 3,524.3 WS A2,1E- 9/24/2004 32.0 SLOTS 1- 166 SLOTS;9,352.0-9,561.0 8,559.0 9,104.0 3,508.7 3,498.7 WS A2,1E- 9/24/2004 32.0 SLOTS 166 A-SAND LINER;5,302.2-9,596.0 KUP D • 1E-166 • ConocoPhillips 41; Alaska Inc. Cgn°cophiBips':. ••• 1E-166,12/11/2017 9'.44 06A Venlcal s homaOc.:(Admel) ii [ I final Lind i'. Perforations&Slots III A...l................... v I VI , Jut MANGER;21.0 Shot Dens ON ^^UCTOR; Top(ND) Btm(ND) (shots/ �ti^ COND30.0-108.0 I ' Top(ftKB) Btm(ftKB) (ftKB) (kKB) Zone Date k) Type Com 9,352.0 9,561.0 3,512.7 3,517.1 WS A2,1E- 9/24/2004 32.0 SLOTS MIL NIPPLE;509.1 _ 166 HEAT TRACE;22.0 Mandrel Inserts St ak °^ Top(TVD) Valve Latch Port Size TRO Run N Top(ftKB) (ftKB) Make Model OD(in) Sery Type Type (in) (psi) Run Date Com SURFACE;29.B-3,012.0 - 1 1 3,029.2 2,403.9 Camco KBG-2- 1 GAS LIFT GLV BK 0.188 1,459.0 7/9/2016 1R GAS LIFT;3,029.2 �'. 2 4,542.7 3,194.9 Camco KBG-2- 1 GAS LIFT OV BK 0.250 7/8/2016 N1R Notes:General&Safety GAS LIFT;4,5427 End Date Annotation r - 11/17/2005 NOTE WORKOVER TO RECONNECT ESP CABLE-NO OTHER CHANGES XIIN NIPPLE;4,624.6 2/17/2009 NOTE:VIEW SCHEMATIC w/Alaska Schematic9.0 2/17/2009 NOTE:WORKOVER TO CONVERT FROM ESP TO GAS LIFT GAUGE;4,6320 (...-- LOCATOR;4,884.8 llkiail I -1 SEAL ASSY;4,8939 I Hca L J1 D-SAND WINDOW;4,789.0- III 111I SLOTS;4,6220-9,3/23.0—.--. IRq*' D-SAND LINER;4,795.7-9,402.0 aii D-SAND LINER LEM;4,678.5- 5,034.0 LI If i 8-SAND LINER;5,063.1-9,379.7 P B-SAND WINDOW;5,068.0- ill 5,080.0 1 d- JI B-SAND LINER HH;5,010.1- r - 5,345.8 I' o INTERMEDIATE;26.98,014.0 SLOTS;8,043.0-6,073.0 1 4 SLOTS;6,198.0-6,229.0 y SLOTS;6,38•0-6,4150—.1 SLOTS;6,539.08,629.0 SLOTS;7,055.0-7,583.0 SLOTS;7,955.08,372.0 ` SLOTS;0,559.0-9,104.0 -... [ SLOTS;9,352.0-9,561.0 L 1 A-SAND LINER;5,302.2-9,596.0 I I OF 7114, • • I%%i4A THE STAT E Alaska Oil and Gas �•'i�7 of /� Conservation Commission LsKA 333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main: 907.279.1433 oh- ALAS Fax: 907.276.7542 www.aogcc.alaska.gov John Peirce Staff Wells Engineer S`p�NED F P 0017, ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage,AK 99510 Re: Kuparuk River Field, West Sak Oil Pool,KRU 1E-166 Permit to Drill Number: 204-153 Sundry Number: 317-404 Dear Mr. Peirce: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown,a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Cathy '. Foerster Commissioner DATED this 2i day of August, 2017. RBDMS LV t 3 0 2017 • • RECEIVED STATE OF ALASKA AUG 2 3 2017 ALASKA OIL AND GAS CONSERVATION COMMISSION 046t13 ci8 2,""/1 APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 1.Type of Request: Abandon El Plug Perforations❑ Fracture Stimulate ❑ Repair Well ❑ Operations shutdown❑ Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing ❑ Change Approved Program❑ Plug for Redrill ❑ Perforate New Pool 0 Re-enter Susp Well ❑ Alter Casing ❑ Other: RPPG D MBE TrtmtU 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Exploratory ❑ Development (] , 204-153 , 3.Address: Stratigraphic ❑ Service ❑ 6.API Number: P. O. Box 100360,Anchorage,Alaska 99510 50-029-23220-00 - 7.If perforating: 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? N/A " KRU 1E-166 Will planned perforations require a spacing exception? Yes ❑ No 0 / 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL 25661,ADL 25660 • Kuparuk River Field/West Sak Oil Pool 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth TVD: MPSP(psi): Plugs(MD): Junk(MD): 9,602' ' 3,519' - 9594 • 3517 • 1500 NONE NONE Casing Length Size MD TVD Burst Collapse Conductor 78' 20" 108' 108' Surface 2,982' 10 3/4 3,012' 2,392' Intermediate 5,987' 7 5/8 6,014' 3,502' Liner 4,294' 4 1/2 9,596' 3,518' Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 6043-9561 . 3508-3517 4.500" L80 4,712' Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): PACKER=ZXP PACKER • 4677 MD and 3244 ND PACKER=ZXP LINER TOP PACKER , 5010 MD and 3331 ND PACKER=HRD ZXP LINER PACKER . 5302 MD and 3391TVD SSSV: =NONE N/A 12.Attachments: Proposal Summary 0 Wellbore schematic U 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stratigraphic❑ Development U' Service ❑ 14.Estimated Date for 9/12/2017 15.Well Status after proposed work: Commencing Operations: OIL V WINJ 1 WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ Commission Representative: GINJ 0 Op Shutdown ❑ Abandoned o ?ILI) 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name: John Peirce Contact Name: John Peirce Authorized Title: Staff Wells Engineer Contact Email: John.W.Peirce@cop.com Contact Phone: (907)265-6471 Authorized Signature: %,/ - Date: 8/2 2I0 7 " COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: _/ Post Initial Injection MIT Req'd? Yes ❑ No L� �1 !14 Spacing Exception Required? Yes ❑ No �' Subsequent Form Required: JO-- '9 O RBDMS 1,1, P s,n 3 0 2017 APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: V _ 2.5_/7 -?1,4 8101,0ff't4' V`TL 612s/17- 0 RAPe1 ASubs in Form ane Form 10-x03 Revised 4/2017 C/{.y-�j IS valid for 12 months from the date of approval. Attachments in Duplicate • • West Sak 1E-112L2 RPPG Treatment of D MBE 1E-112L2 is a West Sak horizontal D sand injector lateral with 5.5", L-80 liner at 5839' - 11240' RKB containing alternating single —40' slotted joints and single —31' blank joints over the entire liner length. An MBE occurred in 1E-112L2 in 2009 to offset 1E-166L2 producer. An 8/20/09 IPROF evaluation resulted in perforating 1E-112L2 on 7/28/12 at 6834 - 6839' RKB and pumping of a CT Crystal Seal job the same day to treat a D MBE believed to exist at —7000' RKB. A total of 2135 lbs Crystal Seal was pumped, but the resulting treatment benefit was brief. A 12/23/15 IPROF in 1E-112L2 showed clear temperature inflections on multiple passes at —9350' RKB indicating a D MBE likely existed there. No indication existed on the 12/23/15 IPROF that an MBE was at —7000' RKB. On 2/12/17, a Cement Plug placement was attempted into a straddle constructed in the liner between 8800 - 9200' RKB to isolate the D MBE in 1E-112L2. However, the inflatable Cement Retainer set to complete the straddle failed and was POOH still attached to CT with a ruptured bag after pumping 30 bbls of 8.6# cement through the ICR. CT underreamed cement from liner 4/20/17 to a final hard tag at 8835' RKB. An (PROF on 4/22/17 in the D Lat showed —40% of PWI was still exiting through slots below 8800' RKB toward the toe MBE in the lateral. It is proposed that a fullbore RPPG treatment now be performed to seal off the toe D MBE. Proposed Procedure: A Plug was set 7/19/12 in a DB Nipple at 6126'RKB to isolate A lateral. The B lateral was isolated by an Iso-Sly on 2/7/17. A `D'Diverter was set 2/8/17. 1E-112 is configured for D lateral MBE treatment. 1) Coil Tubing: RIH with 2" run OD x 5' OAL perforating gun to shoot 5' of large hole perfs at 6 spf, 60 deg phasing, in 5.5" slotted liner at —8800' RKB (target), or as deep as possible in 1E-112L2. POOH with gun. 2) Pumping: About 24 hrs before the RPPG job, shut-in 1E-166 producer, and put 1E-112L2 on PWI at 500 - 1000 BWPD to establish injection through the D MBE to 1E-166L2. RU mixing van & pumping equipment on 1E-112. Have DSO SI PWI to 1E-112 and then fullbore pump RPPG slurry at a steady rate in 1.0 - 2 bpm range. Mix slurry in 3% KCL Water (or Seawater) adding 1 - 4 mm mesh RPPG to make 0.75 ppg slurry concentration on-the-fly, while fullbore pumping slurry down 1E-112 tubing to the D MBE. Continue pumping at a steady rate and slurry concentration until WHIP reaches —800 psi, and then swap from RPPG slurry to 139 bbls 3% KCL (or Seawater) spacer, followed by 36 bbls Diesel FP to 2000' TVD, followed by Shutdown. Wait 2 days for swelling RPPG particles to fully crosslink in the D MBE to form a stout amalgamated crosslinked non-flowing gel before returning 1E-166 to production. JWP 8/22/2017 • • Coil Tubing: 3) RIH with jet swirl nozzle and tag top of RPPG in well. Jet through RPPG and fill to deep as possible to shear and mechanically break RPPG remaining in the well, and to open slotted liner to injection as deep as possible. POOH. RD CTU. Place 1E-112L2 on PWI to evaluate results of the MBE treatment. / Evaluate 'D only' PWI performance and monitor offset producer 1 E-166 performance to verify that the D MBE has been isolated. JWP 8/22/2017 • KUPD • 1E-166 Con+f oPhiliips &' Well Attribut Max Angle D TD Aleisk<,illi:. Wellbore API/UWI Field Name Wellbore Status ncl(°) MD(ftKB) Act Btm(ftKB) Concillips, 500292322000 WEST SAK PROD 100.34 6,460.04 9,602.0 .°. Comment 1425(ppm) Date Annotation End Date KB-Grd(ft) -Rig Release Date 1E-166,8/9/20174.00.08 PM SSSV:NIPPLE 200 7/31/2015 Last WO. 2/9/2009 35.29 9/24/2004 Vertical schematic(actual) Annotation Depth(ftKB) End Date Annotation Inst Mod By End Date Last Tag- Rev Reason:H2S,GLV C/O pproven 7/12/2016 a I��t 1, A Casing Strings d uI,n,,,.,,�.,,nn eel HANGER;22.0 l i a Y, uuu Casing Description OD(in) ID(in) Top(ORB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread c USA CONDUCTOR 20 19.124 30.0 108.0 108.0 62.50 H-40 WELDED ��........IPPLE .. I �Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...WtlLen(I...Grade Top Thread CONDUCTOR;3o.o-loe0 SURFACE 103/4 9.950 29.8 3,012.0 23924 4550 L 80 ETC NIPPLE;508.1 I Casing Description OD(in) ID(in) Top(ftKB) Set Depth OMB) Set Depth(TVD)...Wt/Len(I Grade Top Thread I INTERMEDIATE 75/8 6.875 26.9 6,014.0 3,501.9 29.70 L-80 BTCM HEAT TRACE,22.0 Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... Wt/Len(I...Grade Top Thread D-SAND LINER LEM 4 1/2 3.958 4,676.5 5,034.0 3,336.0 12.60 SCC IBTM Liner Details Nominal ID SURFACE,29.8-3,012.0-- A Top(ftKB) Top(TVD)(ftKB) Top Incl(°) Item Des Com (in) • 4,676.5 3,244.3 70.58 PACKER ZXP Packer 4.970 GAS LIFT;3,029.2 4,695.5 3,250.5 71.26 SBE 190-47 Casing Seal Bore Extension 4.750 ill 4,751.6 3,267.6 73.27 NIPPLE 3.75"'DB'Nipple 3.750 MR ifIE 4,788.3 3,277.8 74.31 UPPER HH Upper LEM Assembly 3.910 GAS LIFT;4,542.7 �; -' 4,795.1 3,279.6 74.47 LOWER HH Lower LEM Assembly 3.990 nlin 5,030.7 3,335.3 78.07*SEAL ASSY Seal Assembly 3.930 NIPPLE;4,624.6 ` Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread GAUGE;4,832.0 ■-.iffi D-SAND WINDOW 4 1/2 3.958 4,799.0 4,811.0 3,283.8 12.60 II Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)... Wt/Len(I...Grade Top Thread B-SAND LINER HH 4 1/2 3.958 5,010.1 5,345.8 3,399.1 12.60 L-80 IBT LOCATOR;4,684.8 1 Liner Details r e I Nominal ID Top(ftKB) Top(ND)(ftKB) Top Incl C) Item Des Com SEAL ASSY;4,693.9 t (In) ;, 5,010.1 3,331.0 77.66 PACKER ZXP LINER TOP PACKER 6.230 I 5,029.1 3,335.0 78.03 XO BUSHING 4.760 5,029.9 3,335.1 78.05 SBR 109-47 CASING SEAL BORE RECEPTACLE 4.750 5,049.2 3,339.1 78.27 XO BUSHING 3.910 tzr '. 5,057.1 3,340.7 7823 HANGER LEM ABOVE HOOK HANGER 4.020 a I p1v, (+f l 5,063.1 3,341.9 7820 HANGER LEM INSIDE HOOK HANGER 4.020 D-SAND WINDOW;4,799.0 ,11 iII 5,129.0 3,355.6 77.87 NIPPLE CAMCO'DB-6'NIPPLE 3.562 4,811.0 11 'IE 5,342.5 3,398.6 80.02 SEAL ASSY BAKER SEAL ASSEMBLY 3.890 7 Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)... Wt/Len(I...Grade Top Thread SLOTS,4,822.o-9,363.0 B-SAND WINDOW 41/2 3.958 5,068.0 5,080.0 3,345.4 12.60 Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len 1...Grade Top Thread D-SAND LINER;4,795.7-9,402.0A-SAND LINER 41/2 3.958 5,302.2 9,596.0 3,518.4 12.60 L-80 DWC I Liner Details Nominal ID Top(ftKB) Top(ND)(ftKB) Top Incl(1) Item Des Com (in) t 5,302.2 3,391.3 79.17 PACKER HRD ZXP LINER TOP PACKER 4.970 D-SAND LINER LEM;4,876.5- 5,321.2 3,394.8 79.52 NIPPLE RS PACKOFF SEAL NIPPLE 4.875 5,034.0 5,324.0 3,395.3 79.58 HANGER FLEXLOCK LINER HANGER 4.853 5,334.6 3,397.2 79.83 SBE 190-47 CASING SEAL BORE EXTENSION 4.750 5,353.9 3,400.5 80.29 XO BUSHING 4.500 B-SAND LINER;5,063.1-9,379.7 B-SAND WINDOW;5,068.0. �� Tubing Strings 5,080.0 I Tubing Description String Ma...ID(ie) Top(ftKB) Set Depth(ft..Set Depth(ND)(...Wt(Ib/ft) Grade Top Connection i% TUBING 41/21 3.9581 22.11 4,712.01 3,255 12.601 L80 'Top Completion Details Nominal ID -- Top(ftKB) Top(TVD)(ftKB) Top!noir) Item Des Com (in) I 22.1 22.1 0.00 HANGER Vetco Gray 131/2"x41/2"Hgrw/4.909"MCA Top 3.900 Conn. Iar, 509.1 507.8 11.10 NIPPLE Camco 41/2"X 3.875""DB"Nipple 3.875 4,624.6 3,226.3 68.82 NIPPLE Camco 4 1/2"X 3.812""DB"Nipple 3.812 ARI 4,632.0 3,228.9 69.07 GAUGE Baker Guardian Gauge w/pups 3.958 ,.'1111: E 4,684.8 3,247.0 70.87 LOCATOR Locator Ring and Coupling 3.890 8-SAND LINER HH.0,010.1- 4,693.9' 3,250.0 71.20 SEAL ASSY GBH-22 Seal Assembly(2 ft space out) 4.000 5,3458 Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) Top(ND) Top Incl Top(ftKB) (ftKB) (°) Des Com Run Date ID(in) 22.0 22.0 0.00 HEAT - 2/10/2009 0.000 INTERMEDIATE;26.96,014.0 ' TRACE SLOTS;6,043.86,073.0 Perforations&Slots Shot SLOTS;6,198.06,229.0 Dens Top(ND) Bier(ND) (shots/ Top(ftKB) Btm(ftKB) (ftKB) (ftKB) Zone Date ft) Type Com 6,043.0 6,073.0 3,507.7 3,513.6 WS A2,1E- 9/24/2004 32.0 SLOTS ALL PERFS 6023'- SLOTS;6,384.06,415.0 166 9561':Slotted liner w/constrictor packers SLOTS;0039.0608.0 between,32 spf,2.5"L • x.125"W in 4 .1-- circumferential rows 010/0;7,065.0-7,583.0-e6,198.0 6,229,0 3,536.9 3,541.4 WS A2,1E- 9/24/2004 32.0 SLOTS 166 6,384.0 6,415.0 3,543.1 3,539.0 WS A2,1E- 9/24/2004 320 SLOTS SLOTS;7,955.06,372.0 166 6,539.0 6,629.0 3,518.6 3,507.7 WS A2,1E- 9/24/2004 32.0 SLOTS 166 SLOTS,8,559.0-9,104.07,065.0 7,583.0 3,508.6 3,520.4 WS A2,1E- 9/24/2004 32.0 SLOTS 166 7,955.0 8,372.0 3,529.6 3,524.3 WSS A2,1E- 9/24/2004 32.0 SLOTS SLOTS;9,352.09,561 0 L 8,559.0 9,104.0 3,508.7 3,498.7 WS A2,1E- 9/24/2004 320 SLOTS 166 ASAND LINER,5,302.2-9,596.0 KUP Ili?D 1E-166 ConocoPhillips • AI1slt,ir1t:, Corwcofhilkps ...•- 1 E-166,819/2017 4:00:08 PM Verooalsohemano(actual) I i Perforations&Slots ��•"^��^^"^"'���HANGER;22.0 _ Shot Dens Top(TVD) Btm(TVD) (shots/ ~CONDUCTOR;30.0.108.0~ t � 3�1' Top(ftKB) Btm(kKB) (ftK8) (ftK8) Zone Date ft) Type Com St i 9,352.0 9,561.0 3,512.7 3,517.1 WS A2,1E- 9/24/2004 32.0 SLOTS NIPPLE;509.1 I 166 HEAT TRACE,22.0 I.. j Mandrel Inserts St 1 p ati yVy Top(ND) Valve Latch Port Size TRO Run SURFACE;29.8-3,012.0 l N Top(RAG) (ftKB) Make Model OD(in) Sew Type Type (in) (psi) Run Date Com 1 3,029.2 2,403 9 Camco KBG-2- 1 GAS LIFT GLV BK 0.188 1,459.0 7/9/2016 1R GAS LIFT 3,029.2 2 4,542.7 3,194.9 Camco KBG-2- 1 GAS LIFT OV BK 0.250 7/8/2016 1R gr Notes:General&Safety GAS LIFT;4,542.7 End Date Annotation lig 11/17/2005 NOTE WORKOVER TO RECONNECT ESP CABLE-NO OTHER CHANGES ME NIPPLE;4,624.6 2/17/2009 NOTE:VIEW SCHEMATIC w/Alaska Schematic9.0 IN GAUGE;4632.0 2/17/2009 NOTE:WORKOVER TO CONVERT FROM ESP TO GAS LIFT illi LOCATOR;4,684.6 Iit �� l- �a-1 SEAL ASSY;4,693.9 l)1 . DSAND WINDOW;4,799.0. f 4,811.0 SLOTS;4,822.0-9,363.0 D-SAND LINER;4,795.7-9,402.0 4.1 D-SAND LINER LEM;4,676.5- 5,034.0 1111_ B-SAND LINER,5,063.1-9,379 7 / B-SAND WINDOW,5,068.0. 1 NI. 5,080.0 3 �i i ir I Ar- I 13-SAND LINER HH, �■.5,010.1- 5,345.8 INTERMEDIATE;26.9-,014.0 SLOTS;6,043.0-,073.0 1 I 4 1- SLOTS;6,198.0-,229.0 4 LL_ SLOTS;6,384.0-,415.0 _ 1- SLOTS;6,539.0-6,629.0 i 4 1- SLOTS;7,065.0-7,583.01 � T SLOTS;7,955.0-8,372.0 SLOTS,8,559.0-9,104.0 4 1- - r SLOTS,9,352.0-9561.0 A-SAND LINER;5,302.2-9,596.0 I • • V OF/Tye s THE STATE AlaskaOil --->„,„„_,., A„,__-----A and Gas ��' ��'�_�9 o Conservation Commission N- ,iii �1 fi iLi i }(J\ sri �� 333 West Seventh Avenue' GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 .a Main: 907.279.1433 01"ALAS�� Fax: 907.276.7542 www.aogcc.alaska.gov John Peirce Satiti6DAtJ G i 1201 7, Senior Wells Engineer ConocoPhillips Alaska, Inc. PO Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, West Sak Oil Pool, KRU 1E-166 Permit to Drill Number: 204-153 Sundry Number: 317-361 Dear Mr. Peirce: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown,a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, p93.,,,(4...._ Cathy . Foerster Commissioner DATED thisay of August, 2017. RBDMS w tint - 9 2017 1 • RECEIVED STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION AUG 0 3 2 17 APPLICATION FOR SUNDRY APPROVALS ors p11 20 AAC 25.280 { 1.Type of Request: Abandon ❑ Plug Perforations❑ Fracture Stimulate ❑ Repair Well ❑ Operations shutdown❑ Suspend ❑ Perforate E Other Stimulate ❑ Pull Tubing ❑ Change Approved Program❑ Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other: RPPG D MBE Trtment❑ 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Exploratory ❑ Development 0, 204-153 3.Address: Stratigraphic ❑ Service EI 6.API Number: P. O. Box 100360,Anchorage,Alaska 99510 50-029-23220-00, 7.If perforating: 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? N/A Will planned perforations require a spacing exception? Yes ❑ No 0 / KRU 1E-166• 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL 25651,ADL 25660 Kuparuk River Field/West Sak Oil Pool 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth TVD: MPSP(psi): Plugs(MD): Junk(MD): 9,602' . 3,519' . Casing Length Size MD ND Bdrst Collapse Conductor 78' 20" 108' 108' Surface 2,982' 10 3/4 3,012' 2,392' Intermediate 5,987' 7 5/8 6,014' 3,502' Liner 4,294' 4 1/2 9,596' 3,518' Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 6043-9561 ' 3508-3517 4.500" L80 4,712' Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): ' 4676=MD and 3244 TVD PACKER=ZXP PACKER 5010=MD and 3331 TVD PACKER=ZXP LINER TOP PACKER 5302=MD and 391 TVD PACKER=HRD ZXP LINER TOP PACKER SSSV: =NONE N/A 12.Attachments: Proposal Summary 0 Wellbore schematic 0 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stratigraphic❑ Development E• Service ❑ 14.Estimated Date for 9/1/2017 15.Well Status after proposed work: Commencing Operations: OIL 0 , WINJ 0 WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ Commission Representative: GINJ ❑ Op Shutdown 0 Abandoned ❑ 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name: John Peirce John Peirce Contact Name: Authorized Title: Sr.Wells Engineer Contact Email: John.W.Peirce@cop.com Contact Phone: (907)265-6471 Authorized Signature: Kr.7 Date: Sz,�'J COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance 0 Other: Post Initial Injection MIT Req'd? Yes 0 No [L]" Spacing Exception Required? Yes ❑ No I( Subsequent Form Required: ` 0 — 4-0 RBDMS L t AU i - 9 2017 APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: g-¢-/ 7 -Kaifile. iT 4i1aA Laud IForm 10-403 Revised 4/2017 for 12 months from the date of Submit Form and Oapproval. Attachments in Duplicate • • Proposal for Retreatment of 1E-119 to 1E-166 D Sand MBE with RPPG 1E-119 is a single vertical injector that was drilled & completed in 2004 with 3.5", L-80 Tubing and 5.5", L-80 Production Casing. On 5/27/15, an MBE occurred from 1E-119 to offset producer 1E-166. A Flowing Temp Log in 1E-119 on 6/6/15 verified a D MBE existed at 6454' RKB, and top of fill was at 6583' RKB covering all A sand perfs and lower B sand perfs. On 9/19/15, a fullbore Crystal Seal job was pumped in 1E-119 to the D MBE. 1E-119 was then returned to 'D sand only' PWI for-1 year before the MBE treatment eventually failed. On 4/28/17, a fullbore RPPG (Reformed Polymer Particle Gel) job was pumped to try to reseal the D MBE. A total of 4,590 lbs of RPPG was placed into the MBE, but no treating pressure ever developed and the treatment failed. On 5/2/17, A CT FCO removed fill and RPPG from the well to 6995' RKB. On 5/27/17, an IPROF then verified that 100% of injection was still entering the D sand MBE. 1E-119 RPPG job was the first RPPG job that was ever pumped on the Slope. A key learning from the job was that the RPPG concentration we pumped was far too light to be effective in sealing off an MBE. The RPPG concentration needed to seal off the MBE should have been at least double of what was pumped to develop non-flowing crosslinked gel placement in the MBE. The following procedure is proposed to seal the D MBE at 6454' RKB with RPPG to return 1E-119 to PWI service. The RPPG slurry concentration to be pumped will be increased to 0.6 - 0.7 ppg range. Procedure Pumping: 1) About 24 hrs before the RPPG job, shut-in 1E-166 producer, and place 1E-119 on PWI at -1000 BWPD to establish injection through the D MBE to 1 E-166. RU mixing van and pumping equipment on 1E-119. When ready to fullbore pump into 1E-119, contact DSO to SI PWI to 1 E-119, and then swap over to fullbore pumping RPPG slurry at a steady rate in 1.0 to 1.5 bpm range. Mix slurry in 3% KCL Water (or Seawater) by adding 1 - 4 mm mesh RPPG to make up water for steady 0.6 - 0.7 ppg slurry concentration mixed on-the-fly in the mixing van, and then fullbore pump the slurry down 1E-119 tubing. Continue pumping at a steady rate and slurry concentration until WHIP eventually reaches -800 psi, and then swap from RPPG slurry to pumping 27 bbls of Seawater spacer, followed by -28 bbls Diesel freeze protection, followed by Shutdown. Wait 2 days for the swelling RPPG particles to fully crosslink in the MBE to form stout amalgamated non-flowing crosslinked gel before returning 1E-166 to production. Coil Tubing: 2) RIH with jet swirl nozzle and tag top of RPPG in well, then jet down through RPPG and fill to as deep as possible to shear and mechanically break any RPPG remaining in the well, and to uncover all the perforation intervals to injection. Maintain 1:1 returns to tanks during FCO. POOH. RD CTU. Place 1E-119 on PWI to evaluate results of the MBE treatment. i KUP P D 1E-166 ConocoPhillips 3 Well Attribu Max Angle TD FbJelti}43.lit{; -` Wellbore API/UWI Field Name Wellbore Status ncl C) MD(MB) Act Btm(ftKB) Corrot8ips'_fy 500292322000 WEST SAK PROD - 100.34 6,460.04 9,602.0 A ... Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date 1E-166 7/2612017629:21 AM SSSV:NIPPLE 200 7/31/2015 Last WO: 2/9/2009 35.29 9/24/2004 Verpral nobernane(eotuo0 Annotation Depth(ftKB) End Date Annotation Last Mod By End Date • Last Tag. Rev Reason:H2S,GLV C/O pproven 7/12/2016 11.1 i ill I t1 a Casing Strings •"•'••••••••^'^'^^•HANGER;22.0 � J - , ,Caning Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)...Wt/Len(I...Grade Top Thread ��"� CONDUCTOR 20 19.124 30.0 108.0 108.0_ 62.50 H-40 WELDED I..."-n.•••„„,�,�... ,�Casing Description OD(in) ID(in) Top(ftKB) Set Depth(kKB) Set Depth(TVD)...Wt/Len(I Grade Top Thread CONDUCTOR;30.0-108.0-• ( ` SURFACE 10 3/4 9.950 29.8 3,012.0 2,392.4 45.50 L-80 BTC Casing Description OD(in) ID(in) 'Top(kKB) Set Depth(ftKB) Set Depth)TVD)...Wt/Len(I...Grade Top Thread NIPPLE;509.1 INTERMEDIATE 7 5/8 6.875 26.9 6,014.0 3,501.9 29.70 L-80 BTCM HEAT TRACE,220l.'"''',. Casing Description OD(in) ID(in) 'Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...'Wt/Len(I...Grade Top Thread D-SAND LINER LEM 41/2 3.958, 4,676.5 5,034.0 3,336.0 12.60 SCC IBTM • Liner Details • Nominal ID SURFACE;29.83,012.0-a t Top(ftKB) Top(TVD)(ftKB) Top Incl(°) Item Des Corn (in) i 4,676.5 3,244.3 70.58 PACKER ZXP Packer 4.970 4,695.5 3,250.5 71.26 SBE 190-47 Casing Seal Bore Extension 4.750 GAS LIFT;3,029.2 4,751.6 3,267.6 73.27 NIPPLE 3.75"'DB'Nipple 3.750 4,788.3 3,277.8 74.31 UPPER HH Upper LEM Assembly 3.910 GAS LIFT;4,542.7 4,795.1 3,279.6 74.47 LOWER HH Lower LEM Assembly 3.990 5,030.7 3,335.3 78.07 SEAL ASSY Seal Assembly 3.930 NIPPLE;4,624.6 Casing Description OD(in) ID(In) Top(ftKB) Set Depth(ftKB) Set Depth(ND)...WtlLen(I...Grade Top Thread an GAUGE,4,6320 - D-SAND WINDOW 41/2 3.958 4,799.0 4,811.0 3,283.8 12.60 Casing Description OD(in) ID(in) Top(ftKB) Set Depth)ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread B-SAND LINER HH 41/2 3.958 5,010.1 5,345.8 3,399.1 12.60 L-80 IBT LOCATOR;4,684.8I Liner Details Nominal ID I Top(ftKB) Top(ND)(ftKB) Top Incl C) Item Des Corn (in) SEAL ASSY;4,693.9 = 5,010.1 3,331.0 77.66 PACKER ZXP LINER TOP PACKER 6.230 I 5,029.1 3,335.0 78.03 XO BUSHING 4.760 5,029.9 3,335.1 78.05 SBR 109-47 CASING SEAL BORE RECEPTACLE 4.750 5,049.2 3,339.1 78.27 XO BUSHING 3.910 5,057.1 3,340.7 78.23 HANGER LEM ABOVE HOOK HANGER 4.020 9j '+ 5,063.1 3,341.9 78.20 HANGER LEM INSIDE HOOK HANGER 4.020 1 D-SAND WINDOW;4,789.0- Ili III 5,129.0 3,355.6 77.87 NIPPLE CAMCO'D8-6'NIPPLE 3.562 4.0110 �j; 'II 5,342.5 3,398.61 80.02TSEAL ASSY BAKER SEAL ASSEMBLY 3.890 ff ' Casing Description OD(in) ID(in) Top(ftKB) Set Depth MKS) Set Depth(ND)... Wt/Len(I...Grade Top Thread B-SAND WINDOW 41/2 1958 5,068.0 5,080.0 3,345.4 12.60 SLOTS,4,822.0-5363.0-- Casing Description- OD(in) ID(in) 'Top(ftKB) Set Depth(ftKB) Set Depth CND)...'Wt/Len(I...Grade Top Thread D-SAND LINER;4,785.7-9,402.0 A-SAND LINER 41/2 1958 5,302.2 9,596.0 3,518.4 12.60 L-80 DWC Liner Details Nominal ID '^••• Top(ftKB) Top(TVD)(ftKB) Top Inc!C) Item Des Corn (in) - 5,302.2 3,391.3 79.17 PACKER HRD ZXP LINER TOP PACKER 4.970 D-SAND LINER LEM;4,676.5- 5,321.2 3,394.8 79.52 NIPPLE RS PACKOFF SEAL NIPPLE 4.875 5,034.0 :'.. 5,324.0- 3,395.3 79.58 HANGER FLEXLOCK LINER HANGER 4.853 5,334.6- 3,397.2 79.83 SBE 190-47 CASING SEAL BORE EXTENSION 4.750 5,353.9 3,400.5 8029 XO BUSHING 4.500 • B-SAND LINER;5,063.1-9,379.7 ` Tubing Strings B-SAND WINDOW;5,068.0- y�I g g ' 5,080.0 jTubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft..Set Depth(ND)(...Wt(Ibfft) Grade Top Connection �I°+ TUBING 41/2 3.958 22.1 4,712.0 3,255.7 12.60 L80 IBTM Completion Details Nominal ID Top OMB) Top(TVD)(ftKB) Top Incl CI Item Des Com (in) 22.1 22.1 0.00 HANGER Vetco Gray 13 1/2"x 4 1/2"Hgr w/4.909"MCA Top 3.900 Conn. 509.1 507.8 11.10 NIPPLE Camco 4 1/2"X 3.875""DB"Nipple 3.875 4,624.6 3,226.3 68.82 NIPPLE Camco 4 1/2"X 3.812""DB"Nipple 3.812 I- 9r I 4,632.0 3,228.9 69.07 GAUGE Baker Guardian Gauge w/pups 3.958 • 4,684.8 3,247.0 70.87 LOCATOR Locator Ring and Coupling 3.890 8-SAND LINER HH;5,010.1- 4,693.9 3,250.0 71.20 SEAL ASSY GBH-22 Seal Assembly(2 ft space out) 4.000 5,345.8 ffi. Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) Top(ND) Top Incl ( I Top(ftKB) (ftKB) _ (7 Des Com Run Date ID(in) 22.0 22.0 0.00 HEAT 2/10/2009 I 0.000 INTERMEDIATE;26.9-6,014.0 0 TRACE SLOTS;6,043.0-6,073.0 Perforations&Slots 1 Shot • SLOTS;6,198.0-6,229.0 i Dens Top(ND) Btm(TVD) (shoal Top(MB) Btm(kKB) (ftKB) (ftKB) Zone Date ft) TypeCom 6,043.0 6,073.0 3,507.7 3,513.6 WS A2,1E- 9/24/2004 32.0 SLOTS 'ALL PERFS 6023'- SLOTS.6,384.0-6,415.0 - / 166 9561'.Slotted liner w/constrictor packers SLOTS;6,539.06,629.0 between,32 spf,2.5"L x.125"W in 4 4circumferential rows SLOTS,7,065.0-7,503.0 T 6,198.0 6,229.0 3,536.9 3,541.4 WS A2,1E- 9/24/2004 32.0 SLOTS 166 6,384.0 6,415.0- 3,543.1 3,539.0 WS A2,1E- 9/24/2004 32.0 SLOTS SLOTS;7,955.0-6,372.0 166 6,539.0 6,629.0 3,518.6 3,507.7 WS A2,1E- 9/24/2004 32.0 SLOTS i 166 SLOTS,8,559.0-9,104.0 _ 7,065.0 7,583.0 3,508.6 3,520.4 WS A2,1E- 9/24/2004 32.0 SLOTS 166 ?I 7,955.0 8,372.0 3,529.6 3,524.3 WS A2,1E- 9/24/2004 32.0 SLOTS I r 166 SLOTS;9,352.0-9,561.0 1 1 i 8,559.0 9,104.0 3,508.7 3,498.7 WS A2,1E- 9/24/2004 32.0 SLOTS 166 A-SAND LINER;5,302.26,596.0 KUP P.D 1E-166 Con©coPhiilips z A/ s)c.r, %:,. Car6DccPhiNips ••• 1E-166,712612017629.22 AM Vertical schematic:(aotuak ■■i flitLL iPerforations&Slots 4'.�....,�... ..n.. ,.�.�.HANGER;22.0 Y. Shot N11—III rhos Top(TVD) Btm(TVD) (shots/ '°'CONDUCTOR;30.0-108.0 Top(ftKB) Btm(MB) (ftKB) (ftKB) Zone Date ft) Type Com IIVW9,352.0 9,561.0 3,512.7 3,517.1 WS A2,1E- 9/24/2004 32.0 SLOTS NIPPLE;509.1 _ ... 166 HEAT TRACE;22.0 Mandrel Inserts St I ati on Top(TVD) Valve Latch Port Size TRO Run SURFACE;29.8-3,012.0 N� Top(ftKB) (1IKB) Make Model OD(in) Sew Type Type (in) (psi) Run Date Com 1 1 3,029.2 2,403.9 Camco KBG-2- 1 GAS LIFT GLV BK 0.188 1,459.0 7/9/2016 1R GAS LIFT;3,029.2 2 4,542.7 3,194.9 Camco KBG-2- 1 GAS LIFT OV BK 0.250 7/8/2016 1R it Notes:General&Safety GAS LIFT;4,542.7 End Date Annotation 1111 11/17/2005 NOTE:WORKOVER TO RECONNECT ESP CABLE-NO OTHER CHANGES NIPPLE;4,624.6 - 2/17/2009 NOTE VIEW SCHEMATIC w/Alaska Schematic9.0 LW 2/17/2009 NOTE:WORKOVER TO CONVERT FROM ESP TO GAS LIFT GAUGE,4,632.0 -- IR LOCATOR;4,684.8 SEAL ASSY;4,693.9 — 11 I.I' III r fr D-SAND WINDOW;4799.0- 4,811.0 L !I ■ I SLOTS;4,822.0-9,363.0 D-SAND LINER;4,795.7-9,402.0 D-SAND LINER LEM;4,676.5- 5,034.0 nII s B-SAND LINER;5,083.1-9,379.7 i. B-SAND WINDOW,5,068.0- I 5,080.0 iill til�i 1 ME ImW _ B-SAND LINER HH;5,010.1- r 5,345.8 i I o INTERMEDIATE;26.96,014.0 SLOTS,6,043.06,073.0 I r I SLOTS;6,196.0-6,229.0 j Z T- SLOTS;8,384.06,415.0 44 4- SLOTS;8,539.06,629.0 j j 4 1- 4 '- SLOTS;7,065.0-7,583.0 I i SLOTS;7,955.06,372.0 SLOTS;8,559.0-9,104.0 1 1 SLOTS;9,352.0-9,561.0 4 1 ASAND LINER;5,302.25,596.0 1 AMITE OF ALASKA WSAK 1E-166 AkEigKA OIL AND GAS CONSERVATION COMitION REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon E Plug Perforations Fracture Stimulate E Pull Tubing r Operations Shutdown Performed: Suspend E Perforate 1- Other Stimulate l Alter Casing fl Change Approved Program Plug for Redrill E Perforate New Pool 1, Repair Well r Re-enter Susp Well E Other:Crystal Seal MBE Treetmnlw 2.Operator Name: 4.Well Class Before Work: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Development F Exploratory E 204-153 3.Address: 6.API Number: P.O. Box 100360,Anchorage,Alaska 99510 Stratigraphic Service 50-029-23220-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL 25651,25660 KRU 1E-166 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): none Kuparuk River Field/West Sak Oil Pool 11.Present Well Condition Summary: Total Depth measured 9602 feet Plugs(measured) None true vertical 3519 feet Junk(measured) None Effective Depth measured 9594 feet Packer(measured) 0 true vertical 3517 feet (true vertical) 0 Casing Length Size MD TVD Burst Collapse CONDUCTOR 78 20 108 108 0 0 SURFACE 2982 10.75 3012 2393 0 0 INTERMEDIATE 5987 7.625 6014 3502 0 0 A-SAND LINER 4294 4.5 9596 3518 0 0 0 0 0 0 0 0 Perforation depth: Measured depth: 6043-9561 RECEIVED True Vertical Depth: 3508-3517 - ,, ���$����3 `' � � '�'` FEB 17 201 6 Tubing(size,grade,MD,and ND) 4.5, L80,4712 MD, 3256 TVD AOGCC Packers&SSSV(type,MD,and ND) PACKERS-ZXP PACKER @4677 MD an d3244 TVD,ZXP Liner Top Pkr @ 5010 MD and 3331 ND HRD ZXP Liner Top Pkr @ 5302 MD and 3391 ND NIPPLE-Camco 4 1/2"X 3.875""DB"Nipple @ 509 MD and 508 ND 12.Stimulation or cement squeeze summary: Intervals treated(measured): none Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 77 - 1515 - 320 Subsequent to operation shut-in - - - - 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations F Exploratory I Development F Service r Stratigraphic Copies of Logs and Surveys Run F 16.Well Status after work: Oil F Gas 8.. WDSPL r Printed and Electronic Fracture Stimulation Data n GSTOR r WINJ F WAG EGINJ fl SUSP SPLUG 1 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: 315-425 Contact John Peirce ca 265-6471 Email John.W.Peirce@conocophillips.com Printed Name John Peirce Title Sr. Wells Engineer Signature ,j Phone:265-6471 Date 2/16/./6 / _______ Form 10-404 Revised 5/2 15 VTZ Z/6 4`/� RBDMS FEB 1 8 2016 Submit Original Only Z qlb KUP OD 1 E-166 Con©coPhiflips •fr"11' Well Attrib Max AngiliD TD Alaska,lno Wellbore APIIUWI Field Name Wellbore Status nol(°) MD(ftKB) Act Btm(ORB) Corwc4lilips 500292322000 WEST SAK PROD 100.34 6,460.04 9,602.0 ,:.., L ... Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date 1E-166 211 6/201 6 8:10:38 AM SSSV:NIPPLE 120 8/24/2012 Last WO: 2/9/2009 35.29 9/24/2004 verocal schematic(acOU) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date I Last Tag: iRev Reason:WELL REVIEW osborl 10/23/2013 1 l f; .....MMISA... "'HANGER;71.0 a 5i -`.1-�Casing Strings gI lialtair.. Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread CONDUCTOR 20 19.124 30.0 108.0 108.0 62.50 H-40 WELDED -A-"CONDUCTOR;30.0-106.0" al " Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread ISIE SURFACE 10 3/4 9.950 29.8 3,012.0 2,392.4 45.50 L-80 BTC NIPPLE;509.1 I - Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)...Wt/Len(I...Grade Top Thread HEAT TRACE;22.0 INTERMEDIATE 7 5/8 6.875 26.9 6,014.0 3,501.9 29.70 L-80 BTCM Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)... WtlLen(I...Grade Top Thread D-SAND LINER LEM 41/2 3.958 4,676.5 5,034.0 3,336.0 12.60 SCC IBTM Liner Details SURFACE;29.8-3,012.0-. Nominal ID l Top(ftKB) Top(TVD)(ftKB) Top Inel(°) Item Des Com (in) OM 4,676.5 3,244.3 70.58 PACKER ZXP Packer 4.970 GAS LIFT;3,029.2 - IME 4,695.5 3,250.5 71.26 SBE 190-47 Casing Seal Bore Extension 4.750 ME 111, 4,751.6' 3,267.6 73.27 NIPPLE 3.75"'DB'Nipple 3.750 GAS LIFT;4.542.7lit 4,788.3 3,277.8 74.31 UPPER HH Upper LEM Assembly 3.910 lEil 4,795.1 3,279.6 74.47 LOWER HH Lower LEM Assembly 3.990 AK NIPPLE;4,624.6 5,030.7 3,335.3 I 78.07 SEAL ASSY Seal Assembly 3.930 MIN GAUGE;4,6320 Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)...Wt/Len(I...Grade Top Thread D-SANDWINDOW 41/2 3.958 4,799.0 4,811.0 3,283.8 12.60 Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)... WtlLen(I...Grade Top Thread LOCATOR;4864.0 B-SAND LINER HH 4 1/2 3.958 5,010.1 5,345.8 3,399.1 12.60 L-80 IBT 1- r-1 Liner Details SEAL ASSY;4893.8 r Nominal ID at Top(ftKB) Top(ND)(ftKB) Top Teel rt Item Des Corn (in) I 5,010.1 3,331.0 77.66 PACKER ZXP LINER TOP PACKER 6.230 5,029.1 3,335.0 78.03 XO BUSHING 4.760 5,029.9 3,335.1 78.05 SBR 109-47 CASING SEAL BORE RECEPTACLE 4.750 5,049.2 3,339.1 78.27 XO BUSHING 3.910 lil aI 5,057.1 3,340.7 78.23 HANGER LEM ABOVE HOOK HANGER 4.020 D-SAND WINDOW;4,799.0- 11 if 5,063.1 3,341.9 78.20 HANGER LEM INSIDE HOOK HANGER 4.020 4,611.0 i 0 5,129.0 3,355.6 77.87 NIPPLE CAMCO'DB-6'NIPPLE 3.562 5,342.5 3,398.6 80.02 SEAL ASSY BAKER SEAL ASSEMBLY 3.890 - ' Casing Description OD lin) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)... Wt/Len(I...Grade Top Thread SLOTS;4,622.0-9.363.8 B-SAND WINDOW 41/2 3.958 5,068.0 5,080.0 3,345.4 12.60 0.5AND LINER;4,785.7-6402.0 I. I L Casing Description OD lin) ID(in) Top(ftKB) Set Depth(ftKB) 'Set Depth(ND)...Wt/Len(I...Grade Top Thread A-SAND LINER 4 1/2 3.958 5,3022 9,596.0 3,518.4 12.60 L-80 DWC Liner Details Nominal ID iii Top(ftKB) Top(ND)(ftKB) Top Incl(°l Item Des Com (in) s,I r 5,302.2 3,391.3 79.17 PACKER HRD ZXP LINER TOP PACKER 4.970 D-SAND LINER LEM;4878.5- I- _ 5,034.0 TINIF 5,321.2 3,394.8 79.52 NIPPLE RS PACKOFF SEAL NIPPLE 4.875 j 5,324.0 3,395.3 79.58 HANGER FLEXLOCK LINER HANGER 4.853 5,334.6 3,397.2 79.83 SBE 190-47 CASING SEAL BORE EXTENSION 4.750 11 B-SAND LINER;5,063.1-6379.7 11 °": 5,353.9 3,400.5' 80.29 00 BUSHING 4.500 B-SAND WINDOW;5,0660. ! 1 TubingStrings 6060.0 1 i- 1.1 Tubing Description Ma...ID(in) Top(ftKB( Set Depth(ft..Set Depth(ND)(...Wt(Ib/ft) Grade Top Connection TUBING 'String 4 1/21 3.9581 22.11 4,712.01 3,255.71 12.601 L80 IBTM Completion Details Nominal ID Top(ftKB) Top(ND)(ftKB) Top Incl(°) Item Des Com (in) 22.1 22.1 0.00 HANGER Vetco Gray 13 1/2"x 4 1/2"Hgr w/4.909"MCA Top 3.900 Conn. elk 509.1 507.8 11.10 NIPPLE Camco 4 1/2"X 3.875""DB"Nipple 3.875 4,624.6 3,226.3 68.82 NIPPLE Camco 4 1/2"X 3.812""D8"Nipple 3.812 14,632.0 3,228.9 69.07 GAUGE Baker Guardian Gauge w/pups 3.958 r 4,684.8 3,247.0 70.87 LOCATOR Locator Ring and Coupling 3.890 B-SAND LINER HH;5,010.1- 5,345.0 ----V- 4,693.9 3,250.0 71.20 SEAL ASSY GBH-22 Seal Assembly(2 ft space out) 4.000 Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) Top(TVD) Top Incl Top(ftKB) (9513) I°) Des Corn Run Date ID lin) INTERMEDIATE;26.9-6,ota.o 22.0 22.0 0.00 HEAT 2/10/2009 0.000 TRACE SLOTS;6,043.0.6073.0 1.- Perforations 8 Slots Shot SLOTS;6,198.0-6,229.0 Dens Top(ND) Bte,(TVD) (shots/ Top(ftKB) Btm(ftKB) (ftKB) (ftKB) Zone Date ft) Type Com 6,043.0 6,073.0 3,507.7 3,513.6 WS A2,1E- 9/24/2004 32.0 SLOTS ALL PERFS 6023'- SLOTS;8.38A0-8.415.0-. 166 9561':Slotted liner w/constrictor packers SLOTS;8.5390-8,629.0-. between,32 spf,2.5"L x.125'W in 4 circumferential rows SLOTS;7.065.0-7,5030 6,198.0 6,229.0 3,536.9 3,541.4 WS A2,1E- 9/24/2004 32.0 SLOTS 166 6,384.0 6,415.0 3,543.1 3,539.0 WS A2,1E- 9/24/2004 32.0 SLOTS SLOTS;7,955.0-6.372.0 P- 166 6,539.0 6,629.0 3,518.6 3,507.7 WS A2,1E- 9/24/2004 32.0 SLOTS 166 SLOTS;6559.0-9,104.0 7,065.0' 7,583.0 3,508.6 3,520.4 WS A2,1E- 9/24/2004 32.0 SLOTS 166 7,955.0 8,372.0 3,529.6 3,524.3 WS A2,1E- 9/24/2004 32.0 SLOTS 1 f 166 SLOTS;9.352.0-9,581.04 L 1 L 8,559.0 9,104.0 3,508.7 3,498.7 WS A2,1E- 9/24/2004 32.0 SLOTS 166 A-SAND LINER;5,302.2-9596.0 KUP 11OD 1E-166 ConocoPhillips :_. Alaska_Inc. CorwcC,NiUips 1E-166,2116/20168.10.39 AM I Vergoal schematic(actual) 1 ',Trig f• r 117-1 S' Perforations&Slots MAim0mmIMAMMim HANGER;22.0 ' ' ° ; Shot A I lillii�I Dens .A (TVD) (hots/ CONDUCTOR;30.0.708.0---. - Top(TVD) Btm( Top(ftKB) Btm(ftKB) (ftKB) (ftKB) Zone Date ft) Type Com NIPPLE;5091 9,352.0 9,561,0 3,512.7 3,517.1 WS A2,1E- 9/24/2004 32.0 SLOTS ' HEAT TRACE,22.0 166 Mandrel Inserts I St aft SURFACE;28.53,012.0 on Top(TVD) Valve Latch Port Size TRO Run l N Top(ftKB) (ftKB) Make Model OD(in) Sery Type Type (in) (psi) Run Date Corn AM 1 3,029.2 2,403.9 Camco KBG-2- 1 GAS LIFT GLV BK 0.188 1,498.0 9/19/2009 GAS LIFT;3,029.2 1R 2 4,542.7 3,194.9 Camco KBG-2- 1 GAS LIFT OV BK 0.313 0.0 9/19/2009 1R IIE GAS LIFT;4,542.7 Notes:General&Safety End Date Annotation NIPPLE;4,824.8gilt 11/17/2005 NOTE:WORKOVER TO RECONNECT ESP CABLE-NO OTHER CHANGES ME 2/17/2009 NOTE VIEW SCHEMATIC w/Alaska Schematic9.0 GAUGE;4,832.0 2/17/2009 NOTE:WORKOVER TO CONVERT FROM ESP TO GAS UFT LOCATOR;4,684.8 -I SEAL ASSY;4,693.9- -,- 111'..... I ii a) D-SAND WINDOW,4,799.0- 11II, II 4,811.0 'k 111 . SLOTS;4,822.0-9,363.0 ' D-SAND LINER;4,795.7-9,402.0 I I D-SAND LINER LEM;4,878.5- I 5,034.0 B-SAND LINER;5,063.1-9,379.7 ' IrI' B-SAND WINDOW;5,068.0- W 5,080.0 LC i-;s i � 3I !' 1r4 B-SAND LINER HH;5,010.1- )' 5,345.8 INTERMEDIATE;26.96,014.0 is SLOTS;6,043.08,073.0 I} I SLOTS;8,188.06,229.0 1 SLOTS;8,384.06,415.0 SLOTS;6,539.08,629.0 EI L 1 SLOTS;7,065.0-7,583.0 f SLOTS;7,855.0-8,372.0 SLOTS;8,559.0-9,104.0 T r SLOTS;9,352.0-9,561.0 A-SAND LINER;5,302.2-9,596.0 1 Well History 1E-119 500292319800 Page 1 of 3 • ' • lips Well History 1E-119 : 500292319800 : 2/16/2016 Date Event 02/11/2016 INJECTIVITY TEST 1E-119, PUMP 30 BBL DIESEL DOWN TBG DNE 1000PSI AND .75 BPM START PUMPING, RATE @ .75 BPM TBG PSI= 1000, PUMPED 30 BBLS SHUT DOWN PUMP, RATE @ .75 BPM, TBG PSI=600 JOB COMPLETE 10/15/2015 LOGGED 24 ARM CALIPER FROM TUBING TAIL @ 6135' TO SURFACE. LOG CORRELATED TO TUBING TALLY DATED 13-APR-2004. JOB COMPLETE. 09/29/2015 PUMPED 30 BBLS OF DSL DOWN TBG FOR INJECTIVETY TEST JOB COMPLETE 09/19/2015 PUMPED FULLBORE MBE TREATMENT PLACING 275 BBLS 3%KCL, 36 SW w/ 1-2-4 & 4 MIL CRYSTAL SEAL (495# 124 & 2695#4 mil, 3190#s total) SURRY INTO FORMATION. WELLFREEZE PROTECTED W/35 DIESEL.Note: Do not bring well back on injection or offset producer 1E-166 on prod until after 20:00, 9/20. 09/17/2015 INJECTIVITY TEST W/ S/W PUMPED 56 BBL @ 1BPM PUMPED 10 BBL @ 1.5BPM PUMPED 10 BBL@ 2BPM FREEZE PROTECT TBG WITH 33 BBL OF DIESEL JOB COMPLETE 09/09/2015 TAGGED FILL @ 6564' SLM—299' FILL. MEASURED BHP @ 6559' RKB. JOB COMPLETE 06/07/2015 FREEZE PROTECT F/L W/5 BBLS METHANOL FREEZE PROTECT TUBING W/ 3 BBLS METHANOL, FOLLOWED BY 30 BBLS DIESEL JOB COMPLETE 06/06/2015 MEASURE INJECTION TEMPERATURE SURVEY @ 6400', 6540', & 6583' RKB. JOB COMPLETE 06/02/2015 TAG FILL @ 6564' SLM (EST. 289' FILL); MEASURED BHP @ 6579' RKB (994 PSI). JOB COMPLETE. 05/27/2015 FREEZE PROTECT F/L WITH 3 BBLS METH FREEZE PROTECT TBG WITH 30 BBLS DIESEL JOB COMPLETE 07/12/2014 BAILED FILL/ SCHMOO FROM 6383'- 6475' SLM. PERFS: 6454' - 6872' RKB. MEASURED BHP @ 6470' RKB: 1741 PSI. COMPLETE. 08/25/2011 08/25/2010 LOG STATIC PRESSURE/TEMPERATURE SURVEY TO 6585'. 30 MIN STOP AT 6585', PRESSURE WAS 1765 PSI AT 76 DEG. 15 MIN STOP AT 4100', PRESSURE WAS 1287 PSI AT 62 DEG . 15 MIN STOP AT 2000', PRESSURE WAS 971 PSI AT 59 DEG. TOOLS WERE UNABLE TO FALL PAST 6700' 02/23/2010 TAGGED @ 6858' SLM, EST. 6881' RKB. READY FOR E/L. 01/23/2009 INJECTION PROFILE. RATE: 430 BWPD, 830 PSI, 139 DEGF. 30% OF FLUID ENTERING D SAND AT 6454'-6524'. 70% OF FLUID ENTERING B SAND AT 6562'-6614'. 0% OF FLUID ENTERING A SANDS. DID NOT SHUT IN WELL. DID NOT TAG TD. FLOWING BOTTOMHOLE PRESSURE WAS 2400 PSI. 08/22/2008 07/03/2008 http://akapps.conocophillips.net/WebBert/Well/Report/rptWellTable.aspx?REPORT=..%2... 2/16/2016 OF T�� �9P,,\ /j��s� THE STATE Alaska Oil and Gas h" � l, OfA T i AsKA Conservation Commission Witt- _ 333 West Seventh Avenue .•• "- - Anchorage, Alaska 99501-3572 - :aTR,, � GOVERNOR BILL WALKER g Main• 907.279 1433 OFALASIk? - ` li V-',' Fax 907.276 7542 Ouk�CGS) !^•\1i- x www.aogcc.alaska gov John Peirce D4— t53 Sr. Wells Engineer (3 ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, West Sak Oil Pool, KRU 1E-166 Sundry Number: 315-425 Dear Mr. Peirce: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, dil Cathy W Foerster Chair DATED this ',LA— DATED day of July, 2015 Encl. STATE OF ALASKA ' SKA OIL AND GAS CONSERVATION COMI. 3ION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 1.Type of Request Abandon r Rug Perforations r Fracture Stimulate r Pull Tubing r Operations Shutdown r Suspend r Perforate r Other Stimulate r Alter Casing r Change Approved Program'— Rug for Redrill r Perforate New Pool r Repair Well Re-enter Sus Well , p r P OtherCrystal Seal MBE Treatment 2 Operator Name 4 Current Well Class 5 Permit to Drill Number ConocoPhillips Alaska, Inc. ' Exploratory r Development 17. 204-153 3.AddressStratigraphic r Service r' 6 API Number P.O. Box 100360,Anchorage,Alaska 99510 50-029-23220-00 7 If perforating, What 8 Well Name and Number. Regulation or Conservation Order governs well spacing in this pool9 Will planned perforations require spacing exception, Yes r No r / KRU 1E-166 9 Property Designation(Lease Number): 10 Field/Pool(s) ADL 25651,25660 • Kuparuk River Field/West Sak Oil Pool • 11 PRESENT WELL CONDITION SUMMARY Total depth MD(ft) Total Depth TVD(ft) Effective Depth MD(ft) Effective Depth TVD(ft) Plugs(measured) Junk(measured) 9602 • 3519_ 9594'• 3517' - none none Casing Length Size MD TVD Burst Collapse CONDUCTOR 78 20 108' 108' gg q�' y SURFACE 2982 10 75 3012' 2393' E C i:. VU C INTERMEDIATE 5987 7.625 6014' 3502' �57/20-its JUL 14 2015 A-SAND LINER 4294 4.5 9596' 3518' ,AOGCC Perforation Depth MD(ft) Perforation Depth TVD(ft) Tubing Size Tubing Grade Tubing MD(ft): slots from 6043-9561 ' 3508-3517 4.5 L80 4712 Packers and SSSV Type Packers and SSSV MD(ft)and TVD(ft) PACKER-ZXP PACKER MD=4677 TVD=3244 PACKER-ZXP LINER TOP PACKER MD=5010 TVD=3331 „ PACKER-HRD ZXP LINER TOP PACKER MD=5302 TVD=3391. NIPPLE-Camco 4 1/2"X 3 875""DB"Nipple MD=509 TVD=508. 12 Attachments: Description Summary of Proposal 13 Well Class after proposed work: 1 Detailed Operations Program r BOP Sketch r Exploratory r Stratigraphic r Development 'Service �- 14 Estimated Date for Commencing Operations: 15 Well Status after proposed work 7/29/2015 OIL r ' WINJ r WDSPL F" Suspended r 1 16 Verbal Approval Date GAS r WAG r GSTOR r SPLUG r Commission Representative GINJ r Op Shutdown r Abandoned r 17. I hereby certify that the foregoing is true and correct to the best of my knowledge Contact John Peirce @ 265-6471 Email John W Peirce@conocophillips corn Printed Name John Peirce Title Sr.Wells Engineer Signature /d, L.1": t . Phone 265-6471 Date 7/13 I is Commission Use Only Sundry Number Conditions of approval Notify Commission so that a representative may witness 36.- y26 Plug Integrity r BOP Test r Mechanical Integrity Test r Location Clearance r Other Spacing Exception Required? Yes ❑ No d Subsequent Form Required /a — 4 U 4-- APPROVED BY [/ Approved by *ii° COMMISSIONER THE COMMISSION Date 7 - 2 T �S l� /�� Approved application is valid for 12 i-nonths from the date of approval. submit Form and Form 10-403 Revised 5/2015 ORIGINAL rKa ?,,,�/ ttachments in Duplicate /lkZ�6�j�' RBDMSJA" AUG 2 2015 KUP PROD 1E-166 ConocoPhillips :,:‘,•:•0,. Well Attributes Max Angle&MD TD Alaska,Inc Wellbore APIIUWI Field Name Wellbore Status Incl n MD MKS) Act Btm MKS)(�„u, ,.1 lµ; 500292322000 WEST SAK PROD 100.34 6,460.04 9,602.0 ... Comment H2S(ppm) Date Annotation End Date KB-Grd(R) -Rig Release Date 1E-166.10/23/20131.32,22 FM SSSV:NIPPLE 120 8/24/2012 Last WO: 2/9/2009 35.29 9/24/2004 Vertical schematic laaua0 Annotation Depth(RKB) End Date Annotation Last Mod By •End Date Last Tag: Rev Reason:WELL REVIEW osborl 10/23/2013 I d s Casing Strings _____leuuam___HANGER;21.d tr' - :Or Casing Descrindon OD(In) ID(in) Top(ftKB) Set Depth(565) Set Depth(ND)...WULen(I...Grade Top Thread - CONDUCTOR 20 19.124 30.0 108.0 108.0 62.50 H-40 WELDED Casing Description OD(In) ID(In) Top(RKB) Set Depth(RKB) Set Depth(ND)...Wt/Len(I...Grade Top Thread -A^2'CONDUCTOR;30.0.106.0�AM� '�SURFACE 10 3/4 9.950 29.8 3,012.0 2,392.4 45.50 L-80 BTC Casing Description OD(in) ID(In) Top(RKB) Set Depth(111(B) Set Depth(ND)...WULen(I...Grade Top Thread NIPPLE;509.1 igli INTERMEDIATE 75/8 6.875 26.9 6,014.0 3,501.9 29.70 L-80 BTCM HEAT TRACE;22.0 Casing Description OD(In) ID(in) Top(RKB) Set Depth(RKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread D-SAND LINER LEM 4 1/2 3.958 4,676.5 5,034.0 3,336.0 12-60 SCC IBTM Liner Details Nominal ID SURFACE 29.8-30120-.. Top(RKB) Top(ND)(RKB) Top Incl C) Item Des Com (In) _ 4,676.5 3,244.3 70.58 PACKER ZXP Packer 4.970 4,695.5 3,250.5 71.26 SBE 190-47 Casing Seal Bore Extension 4.750 GAS LIFT;3.029.2 4,751.6 3,267.6 73.27 NIPPLE 3.75"'DB'Nipple 3.750 4,788.3 3,277.8 74.31 UPPER HH Upper LEM Assembly 3.910 GAS LIFT;45427ill 4,795.1 3,279.6 74.47 LOWER NH Lower LEM Assembly 3.990 ini! 5,030.7 3,335.3 78.07 SEAL ASSY Seal Assembly 3.930 NIPPLE;66246 Casing Description OD(In) IID(In) Top(ftKB) Set Depth(hKB) Sat Depth(TVD)...Wt/Len(I...Grade Top Thread 1.11 GAUGE;4.632.0 0-SAND WINDOW 412 3.958 4,799.0 4,811.0 3,283.8 12.60 Casing DescriptionOD(in) ID(in) Top(RKB) Set Depth IRKS) Set Depth(TVD)...WULen p...Grade Top Thread B-SAND LINER HH 4 12 1958 5,010.1 5,345.8 3,399.1 12.60 L-80 IBT LOCATOR;4.884.8 Liner Details Nominal ID "I z Top(RKB) Top(ND)(RKB) Top Incl(") Item Des Com (In) SEAL ASSY;4.693.9 = 5,010.1 3,331.0 77.66 PACKER ZXP LINER TOP PACKER 6.230 5,029.1 3,335.0 78.03 XO BUSHING 4.760 5,029.9 3,335.1 78.05 SBR 109-47 CASING SEAL BORE RECEPTACLE 4.750 5,0492 3,339.1 7827 XO BUSHING 3.910 5,057.1 3,340.7 78.23 HANGER LEM ABOVE HOOK HANGER 4.020 5,063.1 3,341.9 78.20 HANGER LEM INSIDE HOOK HANGER 4.020 D-SAND WINDOW;4,7990- 5,129.0 3,355.6 77.87 NIPPLE CAMCO'DB-6'NIPPLE 3.562 4.811.0 /n 5,342.5 3,398.6 80.02 SEAL ASSY BAKER SEAL ASSEMBLY 3.890 Casing Description OD(In) ID(in) -Top IRKS) Set Depth(RKB) Set Depth(ND)...Wt/Len(I...Grade Top Thread B-SAND WINDOW 4 1/2 3.958 5,068.0 5,080.0 3,345.4 12.60 SLOTS;4822.0.9,363.0-- D-SAND LINER:6795.7. Casing Description OD(in) ID(in) Top(RKB) Set Depth(MB) Set Depth(TVD)...WULen(I...Grade Top Thread 9.402. 0,402.0 � A-SAND LINER 4 1/2 3.958 5,302.2 9.596.0 3,518.4 12.60 L-80 DWC Liner Details Nominal ID Top(RKB) Top(ND)(11K13) Top Incl(") Item Des Com (In) lilj .. 5,3022 3,391.3 79.17 PACKER HRD ZXP LINER TOP PACKER 4.970 IlMf D-SAND LINER LEM;4,676.5- 5,3212 3,394.8 79.52 NIPPLE RS PACKOFF SEAL NIPPLE 4.875 5,0340 g' 5,324.0 3,395,3 79.58 HANGER FLEXLOCK LINER HANGER 4.853 5,334.6 3,397.2 79.83 SBE 190-47 CASING SEAL BORE EXTENSION 4.750 5,353.9 3,400.5 80.29 XO BUSHING 4.500 B'SAND LINER;5,063.1-9.379.7 7'ubin Strin s BSAND WINDOW;5,0686 g g 5,080.0 robing Description String Ma...ID(in) Top(hKB) Set Depth(ft_Set Depth(N0)(...Wt(Ib/h) Grade Top Connection TUBING 41/2 3.958 22.1 4,712.0 3,255.7 12.60 180 IBiM Completion Details Nominal ID Top(11K6) Top(ND)(RKB) Top Incl(") Ifem Des tom (In) I 22.1 22.1 0.00 HANGER Vetco Gray 13 1/2"x 4 1/2"Hgr w/4.909"MCA Top Conn. 3.900 509.1 507.8 11.10 NIPPLE Camco 4 12'X 3.875""OB'Nipple 3.875 ` 4,624.6 3,226.3 68.82 NIPPLE Camco 4 1/2"X 3.812""DB"Nipple 3.812 1 4,632.0 3,228.9 69.07 GAUGE Baker Guardian Gauge w/pups - 3.951 in 4,684.8 3,2476 70.87 LOCATOR Locator Ring and Coupling 3.890 B-SAND LINER HH;5,0101 4,693.9 3,250.0 71.20 SEAL ASS'S GBH-22 Seal Assembly(2 ft space out 4.000 5,345.8 Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) Top(TVD) Top Incl Top(ftKB) (RKB) Cl Des Com Run Dale ID(in) 22.0 22.0 0.00 HEAT TRACE 2/10/2009 1. 0.000 INTERMEDIATE;26.96,014.0 SLOTS;6,043.56,073.0 Perforations&Slots Shot Dens SLOTS;6,1988.6,229.0 Top((VD) Btm IND) (shotsit Top MKS) Btm(ftKB) (hKB) (11108) Zone Dale t) Type Com 6.0430 6.073.0 3,507"7' 3,513.6 WS A2,1E- 9/24/2004 32.0 SLOTS ALL PERFS 6023'- SLOTS;6,384.0$4150 166 9561':Slotted liner I- w/constrictor packers between,32 sof,2.5"L SLOTS;6,539.0.6,829.0 x.125"W in 4 1 circumferential rows 6,198.0 6,229.0 3,536.9 3,541.4 WS A2,1E- -9/24/2004 32.0 SLOTS SLOTS;7,065.07,583.0 ti , 166 6,384.0 6,415.03,543.1 3,539.0 WS A2,1E- 9/24/2004 32.0 SLOTS 166 SLOTS;7,955.0.83720 6,539.0 6,629.0 3,518.6 3,507.7 WS A2,1E- 9/24/2004 32.0 SLOTS 166 SLOTS.8.559.49.184.0 _1 _ 7,065.0 7,583.0 3,508.6 3,520.4 WS A2,1E- 9242004 32.0 SLOTS _ I 166 7,955.0 8,372.0 3,529.6 3,524.3-WS A2,1E- 9/242004 32.0 SLOTS T 166 SLOTS;9,352.49,561.0 Jj L 8,559.0 9,104.0 3,508.7 3,498.7 WS A2,1E- 9/24/2004 32.0 SLOTS 166 A-SAND LINER;5,302,2-9,596.0 KUP PROD 1E-166 ConocoPhillips1 . Alaska.Inc. cmuxmaegx"` 1E-166.1023/2013 1 32 23 PM Vertical schematic(actual) gi'�= I iii Perforations&Slots br fl .- 4 J � NANGER;720..., Dens = Dens `'`M CONDUCTOR.30.0.1080 V' I Top(ORB) Btm(ORB) T(RKop(TVD) Bt(ORB)rn D) Zone Date (sht)tsH Type Com 44 9,352.0 9,561.0 3,512.7 3,517.1 WS AZ 1E- 9/24/2004 32.0 SLOTS NIPPLE,509.1 166 NEAT TRACE:220 1 Mandrel Inserts St at c I on Top(TVD) Valve Latch Port Size TRO Run I NoSURFACE;29.8-3,0120—A Top(ftKB) (560) Make Model OD(In) Sery Type Type (in) (psi) Run Date m 1 3,029.2 2403.9 Camco KBG-2- 1 GAS LIFT GLV BK 0.188 1,498.0 9/19/2009 1R GAS LIFT,3.029.2 2 4,542.7 3,194.9 Camco KBG-2- 1 GAS LIFT OV BK 0.313 0.0 9/19/2009 1R Notes:General&Safety GAS LIFT;4,642.7 - End Date Annotation 11/17/2005 NOTE:WORKOVER TO RECONNECT ESP CABLE-NO OTHER CHANGES NIPPLE;4,624,6 2/17/2009 NOTE'VIEW SCHEMATIC w/Alaska Schematic9.0 2/17/2009 NOTE:WORKOVER TO CONVERT FROM ESP TO GAS LIFT GAUGE;4.632 0 LOCATOR;4.684.8 —.I SEAL ASSY;4,693.9 s 9$ D-SAND WINDOW;4,7990— 4,811.0 SLOTS;4,822.0.9,363.0—-tee D-SAND UNER;4,795.7- . 9.4020 I Milif INF D-SAND UNER LEM,4,676.5 5.034.0 ik iff e-SAND LINER;5,063.13,379.7 B-SAND WINDOW;5,068.0-\ 5,080.0 I ::i B.SAND LINER HH;5, S.345.8.345.8 INTERMEDIATE;26.9.6,014.0 SLOTS;6,043.0.6,073.0 J ._ SLOTS;6,195.0.5229.0 SLOTS.6,384.06.415 0 1 SLOTS;5539.66.629.0 SLOTS;7,065.0-7,583.0— i ,065.07,583.0 r r SLOTS,7,955.0.8,372.0 SLOTS,8,559 0-9,1040 SLOTS;9,352.69,561.0 4 L A-SAND LINER;5,302.2-9,596.0 1E-119 D MBE to 1E-166 Crystal Seal Treatment Proposal An MBE occurred between 1E-119 vertical injector and the offset 1E-166 tri-lateral producer on 5-27-15. A SL tag was attained in 1E-119 on 6-2-15 at 6583' RKB (289' fill), and a SBHP was taken at 6579' RKB (3305' TVD) = 994 psi (EMW - 5.8 ppg). A 6-6-15 Flowing Temp Survey in 1E-119 confirms the D sand perfs at 6454 - 6524' RKB act as a thief zone due to a D MBE communicating with 1E-166. A 1E-166 well test on 5-27-15 shows a sudden high spike in watercut from 35% to 95% (1515 BWPD). 1E-119 has been SI since 5-27-15 due to the D MBE. Per this procedure, the D MBE will be sealed off by fullbore pumping Crystal Seal down 1E-119. This will enable the return of 1E-119 to PWI service to the West Sak A, B, and D sand ASAP. Procedure: Pumping 1. FB Step Rate Injection Test with Seawater at 0.5 to 1.5 bpm to verify good injectivity. 2. FB Crystal Seal treatment to seal the D sand MBE. Initiate pumping with 56 bbis Seawater down tubing to determine optimal steady rate to pump Crystal Seal slurry. Immediately after Seawater pumping and constant pump rate determination, continue pumping 3% KCL water with 0.05 ppg of 4 mm Crystal Seal down tubing at the established rate. Volume of this stage (and all subsequent stages) is TBD during pumping based on treating pressure responses seen during pumping. Ramp stages as they are called at: 0.10, 0.15, 0.20 and 0.25 ppg (4 mm Crystal Seal) at the established rate, else swap to pumping Flush when signs of a screen out development are seen. If screenout development is noted, attempt to pump 55 bbls of Diesel Flush down tubing to displace all the Crystal Seal from the tubing to the MBE. Underdisplace Crystal Seal from the tubing by -1 barrel to leave the D MBE entirely sealed with Crystal Seal to the wellbore. If screenout has not been seen, but it is time to call Flush, pump 55 bbls of Diesel to displace Crystal Seal from the tubing at stable established rate, then SD. RD. Coil Tubing: 3) RIH with Jet Swirl Nozzle to perform a Crystal Seal & fill cleanout. Perform cleanout jetting Seawater with FR to as deep as possible. FP well with 28 bbls Diesel. RD CTU. E-line (optional): 4) Perform an IPROF to verify that the D MBE has been sealed off. Return 1E-119 to PWI. Obtain well tests at 1E-166 producer to verify watercut trends as key indicator for presence of an open MBE, or not. JWP 7/13/2015 · . Image Project Well History File Cover Page XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. dOy. - J 53 Well History File Identifier Organizing (done) D Two-sided II 111111I11" 111111 D Rescan Needed 11111111111 II 111111 RES CAN ~olor Items: o Greyscale Items: DIGITAL DATA OVERSIZED (Scannable) D Maps: D Other Items Scannable by a Large Scanner D Diskettes, No. D Other, NolType: D Poor Quality Originals: OVERSIZED (Non-Scannable) o Other: D Logs of various kinds: NOTES: D Other:: BY: c:: Maria ) Date: 1/ 1<3 ! O~ 151 V11P Date ~ I ' I,?' I Db ~ x 30 = (p 0 Date: t I ~ L~/ ób III II 1/1111 III II III mp Project Proofing BY: ~ Maria => 151 Scanning Preparation BY: C Maria) + J ~ = TOTAL PAGES rt d-- (Count does not include cover shJt) fA A íJ 151 r y Y r 11111111111111 II 1/1 Production Scanning Stage 1 Page Count from Scanned File: 7 3 (Count does include cover sheet) Page Count Matches Number in Scanning Preparation: V YES Date: H 113/0b NO BY: C Maria) ... 151 VV\ P NO Stage 1 If NO in stage 1, page(s) discrepancies were found: YES BY: Maria Date: 151 11I1/111111I11111/1 Scanning is complete at this point unless rescanning is required. ReScanned III II 111111I11 111/1 BY: Maria Date: 151 Comments about this file: Quality Checked 11111111111I111111I 10/6/2005 Well History File Cover Page.doc • WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. Attn.: Christine Shartzer 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Gas Lift Survey: 1 E-166 Run Date: 8/13/2010 ~, ,,}~.,~ i'° f ~'~`~1 August 16, 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 1E-166 Digital Data in LAS format, Digital Log Image file 50-029-23220-00 1 CD Rom 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~halhbu cAomr~.- _~ ~ ~ ~~ q , ,. Date: ~R~~ ~ ~ ~' ~~ =~` nu~ d~ (S~ n~~~C `~J Signed: ~t9C' ~' • • ~~~~ ~~C 1~ ,~ , -, OCT 2 3 2(l0~ STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION ~~as~a Oil & Gas Cons. COfI'1f111SSI0n REPORT OF SUNDRY WELL OPERATIONS Anchoraae 1. Operations Pertormed: Abandon ^ Repair Well ^ Plug Perforations ~ Stimulate ~ Other ~ Set D Sand ISO Alter Casing ^ Pull Tubing ^ Perforate New Pool ~ Waiver ^ Time Extension ^ S~eeve Change Approved Program ^ Operat. Shutdown^ Perforate ~ Re-enter' uspended Well ^ 2. Operator Name: 4. Current Well Status: . Permit to Drill Number: ConocoPhillips Alaska, It1C. Development ~^ Exploratory ^ 204-153 3. Address: Stratigraphic ^ Service ^ API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-029-23220-00 KB Elevation (ft): Well Name and Number: RKB 28' 1 E-166 . Property Designation: . Field/Pool(s): ADL 25651 & 25660 Kuparuk River Field / West Sak Oil Pool 11. Present Well Condition Summary: ~ ' ~ Total Depth measured 9602 feet true verticai ~ 3519' . feet Plugs (measured) NONE Effective Depth measured 9594 feet Junk (measured) NONE true vertical 3517 feet Casing Length Size MD ND Burst Collapse CONDUCTOR 80' 20" 108' 108' SURFACE 2982.15' 10-3/4" : 3012' 2392' INTERMEDIATE 5987' 7-5/8" 6014 3500' A-SAND LINER 4294' 4-1/2" 9596 3518' Perforation depth: Measured depth: 6043-6073,6198-6229,6384-6415,6539-6629,7065-7583,7955-8372,8559-9104,9352-9561 true vertical depth: 3528-3538,3547-3540,3518-3507,3508-3520,3529-3524,3509-3498,3515-3517 Tubing (size, grade, and measured depth) 4-1/2", L80, 4712' MD. ~ ~, ~` Packers & SSSV (type & measured depth) NONE N/A SSSV= NIPPLE 5321' 12. Stimulation or cement squeeze summary: Intervals treated (measured) ~ Treatment descriptions inctuding volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casin Pressure Tubin Pressure Prior to weil operation 1209 533 942 783 221 Subsequent to operation 1118 627 1155 757 233 14. Attachments . Well Class after proposed work: Copies of Logs and Surveys run _ Exploratory ^ Development ~ Service ^ Daily Report of Well Operations _X 6. Well Status after proposed work: il^~ Gas^ WAG^ GtNJ^ WINJ ^ WDSPL^ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or wA if C.O. Exempt N/A Contact B. Christensen/ D. Humphrey Printed Name Darrell R. Humphrey Titie Production Engineering Specialist Signature ~ f Phone: 659-7535 Date /D ~O• ~ q ~ ~~~r~ 1~~~~ `~ Sub~i O 9~a On~Y • • 1 E-166 DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary 10/11/09 SET BAKER TYPE 2 ISOLATION SLEEVE @ 4799' RKB ISOLATING THE D SAND. RIH W/ 3.65" X 19' TYPE 2 ISO SLEEVE (COLLETS ARE 3.86" AND WILL COLLAPSE TO GO THROUGH 3.81" NIPPLE @ 4624' RKB) WT CK @ 4550' CTMD= 7000#. RIH WT -1500 @ 30 FPM. TAG UP @ 4822' CTMD-PULL !2000# OVER SLACK OFF. ON LINE DOWN COIL W/ SLICK DIESEL @ 1.3 BPM CTP 2000# WHP 550 WORK HIPP TRIPPER WHILE EASING DOWN-WORK FOR SEVERAL MINUTES UNTIL STALL. DO A 2500# OVER PULL-PUMP OFF-FOOH. ~~ ~ Cor~ocoPhiliips nlaska. trx: CONDUCTOR, 30-108 NIPPLE,509 HEATTRACE, n SURFACE, 30-3017 GAS LIFT, a,oz9 GAS LIFT, a,saa NIPPlE,0,675 GAUGE, 0,632 LOCATOR, 4,685 SEl1l ASSY. 4,69C SLEEVE,4,799 D-SAND WINDOW, a.~ss-a,ai i D-SAND LEM. <,677-S,D31 8-SAN~ LINER, 5,0639.380 o-snno LINER, 4,79F9.002 KUP ~ 1 E-166 We1lDOreAPIIUWI FIe~tlName WeII3taNs Incl~°) MD~ttNB) AclBtm(ttNB) 500292322000 WESTSAK PRODUCING 100.34 6,460.04 9,602.0 Comment NYS (ppm) DaOe Mnotatlon End Dafa NB[ird (tt) Rig Releasa Data SSSV: NIPPLE 0 8/18I2008 Last WO: 2/9/2009 3529 9/24I2004 n~~oeeuo~ Depth (ftl(B) e~a o.re a~~otano~ lest Motl ... End ~ate Last Tag: Rev Reason: SET ISO SLEEVE IN D-LEM Imosbor 10/11/2009 Casln Strin s Casing Descriptlon String 0... String 10 ... Top (kNB) 3e1 Dept~ (f... Set DepM (TVO) ... String Wt... String ... String Top Thrd CONDUCTOR 20 19.124 30.0 108.0 108.0 62.50 H-40 WELDED Ceaing Descriptlon Strinp 0... Strinp ID ... Top (RNB) Set Oepth (f... Set DepM ~TVD) ... Strinp Wt... String ... String Top ThrO SURFACE 103/4 9.794 29.8 3,012.0 2,392.3 45.50 L-80 BTC Ceaing Daecriptlon Strinp 0... Strinp ID ... Top (!tl(B) Set Dept~ ~f... Sel Depth ~TVD) ... Slrlnp Wt... Strlnp ... String Top Thrtl INTERMEDIATE 75/8 6.875 26.9 6,014.0 3,500.2 29.70 L-SO BTCM Casing Dascriptlon Strlnp 0... Strinp ID ... Top (ftNB) Sat Dapth ~f... Set Dept~ (TVD) ... 3[rlnp Wt... Strlnp ._ String Top ThrO 0.SAND LEM 4 1/2 3.960 4,676.5 5,034.0 3,336.0 12.60 SCC IBTM Casing Dascrlptlon Strinp 0... Strinp ID ... Top (ftNB) Sat Oept~ ~1... Set Depth (TVD) ... Strinp Wt... Strinp ... S4inp Top Thrd 0.SAND WINDOW 4 1l2 3.958 4.799.0 4,811.0 3,283.4 12.60 Casing Dascriptlon String 0... String ID ... Top (ttNB) Set DepN ~f... Set Uept~ ~TVD) ... String Wt.. String ... String Top T~rtl BSAND HH 4 tl2 3.958 5,010.1 5,345.8 3,399.0 12.60 L-80 IBT Casing DaecripHOn Strlnp 0... Strlnp ID ... Top (ftl(B) Set DepM (f... Sat DapM (TVD) ... Strlnp Wt... Strlnp ... Sbinp Top T~rtl BSAND WINDOW 4 1l2 3.958 5,068.0 5,080.0 3,345.3 12.60 Casing Descriptlon 341np 0... Strinp ID ... Top (lIXB) Set Dapt~ ~f... Set Ueplh ~TVD) ... 3tring Wt... String ... String Top T~rd ASAND LINER 4 tl2 3.958 5.3022 9.596.0 3.518.4 12.60 L-80 DWC InG TUBING 41/2 3.958 22.1 4,712.0 3,255.4 72.60 L80 IBTM Compietion Details I ~roP oepm ~ ~TVD) Top Incl Run Oeta Btm Zone I Dete Comment RFS 6023' - 9561': Slotted constricta P~kers between. 2.5"L x.125"Win 4 I I I(RNB) I Incl I I I OD I I Valve I LaOC~ I Slze ITRO Run I I . I 9tn Too IttKBI ( ~ (~) Maks Model Ilnl Serv TYDa TYVB (^~ Ipsi~ Run Date Com.. !~i ~~~ ~~d~~ !`d~s ( d~ ~~ rb~53 Schfu~berger Schlumberger -DCS 2525 Gambell Streel, Suite 400 Anchorage, AK 99503-2838 ATTN: Belh Well ~ ~~ ~ ~~~/ ~ / ~'~~ v~ ~ ~ Job N Log Description Date NO. 5359 Company: Alaska OII & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage,AK 98501 FielA: Kuparuk BL Color CD 1J-105 1J-136 B2WY-00017 B2WV 000 MEMINJECTIONPflOFILE ~- ME 07/23/09 1 7 1E-166 ~~'~~xA - 2q 82WV-00025 A7(B~ MINJECTIONPROFILE ~ MEMPRODUCTIONPROFILE OBf24109 0625IU9 1 1 1 ~ ~Y'~A -~042 AP3a-00066 MEMpRODUCT10NPpOFILE ~ SFRT - pgng~pg 09I05/09 ~ 1 ~ 1 Please sign and retur~ one copy of this transmittal to Beth at tAe above address or fax to (907) 561-8317. Thank you. osn vos ~?r ,~°~ ~ ~~ ,.~ .,- M; . . `t3 ~~~~~~' ~., ! ~l%°1 it.il~ ;`,;s(1~"-. r ~ a, L~ i ~ ~~~ , i' . q 7`1t'4~ J ..~ s~.Y.='w o iat~ ., .. , , ' " ~ • STATE OF ALASKA • ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERA u ~ Gas ~~ 1. Operations Pertormed: Abandon ^ Repair Well ^ Plug Perforations ^ Stimulate ^ Ot er ~~~ Q Set B Sand ISO Alter Casin Pull Tubin Perforate New Pool ^ Waiver ^ Sleeve g ^ g ^ ^ Time Extension Change Approved Program ^ Operat. Shutdown^ Perforate ^ Re-enter Suspended Well ^ 2. Operator Name: 4. Current Well Status: 5. Permit to Drill Number: ConocoPhillips Alaska, InC. Development ~ Exploratory ^ 204-153 3. Address: Stratigraphic ^ Service ^ 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-029-23220-00 7. KB Elevation (ft): 9. Well Name and Number: RKB 28' 1 E-166 8. Property Designation: 10. Field/Pool(s): ADL 25651 & 25660 Kuparuk River Field /West Sak Oil Pool 11. Present Well Condition Summary: 1 S~~ 4~\p ~ S~C~.L~i F.. S~fo~ Total Depth measured 9602' feet true vertical 3519' feet Plugs (measured) NONE Effective Depth measured 9594 feet Junk (measured) NONE true vertical 3517 feet Casing Length Size MD TVD Burst Collapse CONDUCTOR 80` 20" 108' 108' SURFACE 2982.15' 10-3/4" 3012' 2392' r; ~:. . ' ' ~4~'~."~}~~..' s4~~~ ~ ~~~ ' " INTERMEDIATE 5987 6014 3500 7-5/8 A-SAND LINER 4294' 4-1/2" 9596 3518' Perforation depth: Measured depth: 6043-6073,6198-6229,6384-6415,6539-6629,7065-7583,7955-8372,8559-9104,9352-9561 true vertical depth: 3528-3538,3547-3540,3518-3507,3508-3520,3529-3524,3509-3498,3515-3517 Tubing (size, grade, and measured depth) 4-1/2", L80, 4712' MD. `E.~ `~~ ~~ ~ ` ~ sA T ~ ~ ,(` ~.~Lt~OV~ Packers &SSSV (type & measured depth) NONE N/A ~~ ~pr~c~~tjv~n~~ pca SSSV= NIPPLE 5321' 12. Stimulation or cement squeeze summary: ~,, ~~ ~. ~~~~, ~ ~ ~~fl~ ~c~c Intervals treated (measured) Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casin Pressure Tubin Pressure Prior to well operation 713 497 819 996 175 Subsequent to operation 130 62 140 50 204 14. Attachments 15. Well Class after proposed work: Copies of Logs and Surveys run _ Exploratory ^ Development ~ Service ^ Daily Report of Well Operations X 16. Well Status after proposed work: OilO Gas^ WAG^ GINJ^ WINJ ^ WDSPL^ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or NiA if C.O. Exempt: N/A contact B. Christensen/ D. Humphrey Printed Name Darrell R. Humphrey Title Production Engineering Specialist Signature Phone: 659-7535 Date ~I' 12-0 ~~~ Y S ?SAY 0 4 ZrlflS '~ ~ ~~ r~~a~~ ~ a ~ ~r~ s~Cof Form 10-404 Revised 04/2004 ~ ~ ~ ,~~ ~~ ! ~SSubmit Original Only Page 1 of 1 ~ • Maunder, Thomas E (DOA) From: NSK Prod Engr Specialist [n1139@conocophillips.com] Sent: Friday, May 08, 2009 9:14 AM To: Maunder, Thomas E (DOA) Subject: RE: 1 E-166 (204-153), et at Tom -Only the B sand was isolated on this well. I will be faxing you some tech /sales info on the ISO sleeve. As far as I know there is notF-ing new with these. They are the same type we have been using for some time. The tech /sales info should tell you the length. All I know at this point is that it was set at 5067' MD. Darrell From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov] Sent: Wednesday, May 06, 2009 5:17 PM To: NSK Prod Engr Specialist Subject: 1E-166 (204-153), et al Darrel and Bob, I am reviewing the 404 for the installation of the B sand isolation sleeve. Was only the B sand isolated or did this also isolate the A sand? Do you more specifics on the "Type 1 sleeve"? Top and bottom measured depths would be appreciated. Call or message with any questions. Tom Maunder, PE AOGCC 5/19/2009 • • Well Date Event Descri tion 1E-166 1/2/09 (PRE -RWO) T PPPOT -PASSED. T POT -PASSED. IC PPPOT -PASSED. IC POT ~ - PASSED. UPPER BODY SEAL PPPOT -PASSED. UPPER BODY SEAL POT - ~ PASSED. LOWER BODY SEAL PPPOT -PASSED. LOWER BODY SEAL POT - w FAILED. LDS FUNCTION TEST -PASSED. a 1E-166 215/09 Nordic Rig 3 accepted onto 1E-166 on 2-5-2009 @ 09:00 am. RU hardline, bermed up cellar, pulled BPV, RU circ lines, loaded pit's with 8.8ppg seawater/KCL, tested hardline, loaded ESP spooler, kiiled well, installed BPV, ND tree, installed test dart, NU BOP, RU and started BOP test. 1E-166 2!6/09 Cont BOP test, RD test equipment, pull test dart and BPV, install iso-sleeve, MU landing jnt and circ hose, BOLD's and pull hanger to rig floor, flush IA ~ ' with 150"bbls hot seawater, POOH stand back 4 iJ2" tbg and strap in > derrick, MU and RIH with lateral wash tools, cleanout to 5,046`, POOH to Y 264`. ~ O 1E-166 2/7/09 POOH LD cleanout assembly, MU seat assembly dummy run, RIH to 5,046', ~ POOH, MU and RIH with LEM assembly to 4,774' ~ 1E-166 2/8/09 Orient and latch LEM in place, set ZXP, test 7 5/8" csg x ZXPfor 5 minutes, M monitor well, pull setting tools out of ZXP, POOH LD 3 1/2" DP, RU and run 4 0 1/2" gas lift completion to 3,992'. 0 1E-166 219!09 Locate SBE, confirm seals in place, space out, drop ball/rod down tbg, MU Z hanger and landing jnt, make final splices, pump 150 bbls inhibited seawater/KCL down IA, land hanger, test tbg x IA, shear SOV, install BPV, ND/NU, freeze protect well, allow to u-tube. 1E-166 2!10/09 Install BPV, secure well, install guages on tree, blow down all lines, break down hard line, clean out pits, RDMO well 1E-166, clean out cellar box, mov rig off lE Pad. 1E-166 2/14/09 PULLED B&R, RHC @ 4625' RKB. PULLED SOV AND SET 1" OV(PORT=5/16") @ 4542' RKB. PULLED DMY AND SET 1" GLV(PORT=3/16" TRO=1494) @ 3029' RKB. ~ ~ COMPLETE. ~ O a • 1 E-166 • DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary 03/21/09 INSTALL A TYPE 1 ISOLATION SLEEVE INTO THE B-SAND LEM @ 5067' CTMD. *Vetco Gray Hanger, 11" X 4-1/2"*Conductor, 20" X 34" Insulated, set at 108' MD. Tubing String: 4-1/2" 12.6#, L-80, IBTM ~ 509' MD - 3.875" DB Nipple 3029' MD -GLM, Camco 4-1/2" X 1" KBG-2-1R 4543' MD -GLM, Camco 4-1/2" X 1" KBG-2-1R 4625' MD - 3.812" DB Nipple ,.4632' MD -Guardian Gauge Carrier Heat Trace Cable to 3024' MD MD - 5-1/2" X 7-S18" ZXP Liner Top Packer w/ Hold Downs 16' MD -Casing Sealbore Receptacle 4.75" ID 4712' MD -Bottom of Seal Assembly 4.75" Seal OD 10-3/4" Casing Shoe, 45.5/40.5#, L-80, BTC set ~ 3012' MD, 2393' TVD 4796' MD - 4-1 /2" X 7-518" Model 'B' HOOK Hanaer 4752' MD - 3.75" DB Nipple RWO 09 NKYGIIFS Raker Oil 7 irol5 w ^ HS 1~0~T1pI~L~U 'D' Sand Lateral 4788' MD -Lateral Entry Module (LEM) Orienting Profile /166L2: D-sand Window at +/- 4799' MD, 72 deg 3-1/2" bent joint and guide ~__ 4-1/2" 12.6# slotted and blank liner shoe 5010' MD - 5-1/2" X 7-5/8" ZXP Liner Top Packer w/Hold Downs Lateral Entrv Module ILEM) Assembly 5-1/2 X 7-518 ZXP Liner Top Packer w/ Hold Downs 5030' MD-Casing Sealbore Receptacle SO` ci~ ~-~ Casing Sealbore Receptacle - 4.75" ID j f Tubing Swivel, 4-1/2" L/ Orienting Profile f Positive Latching Collet '- Seal Bore for Lateral Isolation - 3.68" ID ~ Access Window Positive Lateral Access Seal Bore for Lateral Isolation - 3.68" ID Isolation Seal Asembly 4.75" Seal OD 5063' MD - 4-1/2" X 7-5/8" Model 'B' HOOK Hanaer 5-1/2" X 7-5/8" ZXP Liner Top Packer with Hold Downs 5-1/2" X 7-5/8" Flex Liner Hanger /Packer - Lock Assembly Top at \ Liner Hanger +/_ 5302' MD ~_~ 5335' MD-Casing Sealbore Receptacle Baker Hugaez 2ppa. Tbia tlocumenl may not be reprotlocetl or tlislributetl, in wbok or in part, in any loaner s elecbanic er mecnanical, inclutliny pbotocopying, recortling, or By any inlormalion storage antl retrieval system now known or M1ereaner inventetl. wiMOUt wrinen permission bom Baker Hugbea Inc. 'A' Sand Undulatina Lateral Casing, 7-5/8" 29.7#, L-80, BTCM, Set @ +/- 6014' MD, 3502' TVD. Lateral E ntry Module (LEM) With Div erters and Isolation Lateral Access Diverter Lateral Isolation Diverter GS Running Tool String Installed Installed (1.00" Lateral Dr'rft) (2.50" ID Mainbor e Drift) 'GS' Profile for i Coil Connector ! Running/Retrieving a'i )1.00'Length) Snap In/Snap Out r Back Pressure Valve '- Positive Locating-- (1.60' LengM) Collet Lateral Isolation - ~- Flow-Thru Swivel Seals (t-25' Length) ~ Lateral Diverter __- Hydraulic ' Ramp Disconnect Isolation/Mainbore (1.50' Length) Diverter Sleeve _ _ - GS Spear r '~ ~~, ' (1.50' Length) Lateral Isolation 6 .85 ft Approx. ~ Seals _ _ j ~ OAL' 'Jars may be required in highly deviated or deep apphcaticns (6' approx length). 18.5' Diverter Length 18.5' Sleeve Length Eauipment Specifications 4-1/2" X 7-5/8" HOOK Hanger Mainbore Drift: 5.32" Mainbore Drift, with diverter: 4.63" Lateral Drift, no diverter or LEM: 3.68" Lateral Drift, wl diverter, no LEM: 3.88" LaterallMainbore Diverter OD: 6.75" 4-112" Lateral Entry Module Mainbore Drift: 3.65" Mainbore Drift, wl isolation sleeve: 2.50" Lateral Drift, wl coil diverter: 3.00" OD of Diverter and Sleeve: +I- 3.89" Diverter and Sleeve Length: +/- 18.5' 4-112" 12.6# slotted and blank liner 1E-166: 4-1/2" Liner shoe @ 9596' MD, 3518' TVD 2004-1E-166 Trlaateral COmpletlon -Producer ' January 70. 2009 ~ ~~~~ •~ Ian Toomey ~ RWO GOmpletetl 1E-166L2: 3-1/2" Liner Shoe @ 9402' MD, 3258' TVD MD -Bottom of Seal Assembly 4.75" Seal OD 5057' MD -Lateral Entry Module (LEM) ~ ~ Orienting Profile 'B' Sand Lateral 166L7 • B-sand Window at +/- 5068' MD 82 deg ConocoPhillips West Sak 1 E-166 Producer Tri-Lateral Completion 3-1/2" bent joint and guide 4-1 /2" 12.6# slotted and blank liner shoe 5128' MD - 3.562" DB Nipple 1 E-166L1: 3-1/2" Liner shoe @ 9380' MD, 3329' TVD 5346' MD -Bottom of Seal Assembly 4.75" Seal OD KUP _ ~ COnoCOPhillips well Attributes r Wellbora API/U WI Field Nama 500292322000 WEST SAK comment ... .-. .._ _ ._._______ __.______ SSSV: NIPPLE 1 E-166 ____ _ Last Tag: Rev Reason: Workover, Pull RHC Ball/Rod, GLV C/O 2/17/2009 ~- Casin 3trin s ' ~ Casing Descrlptlon String 0... Slring ID ... Top (FIKB) Set Depth (f... Set Depth (TVDI ... String Wt.. String ._ String Top Thrc CONDUCTOR 20 19.124 0 108 108.0 62.50 H-00 WELDED ': ~' Casing Descrlptlon Slring 0... S[ring ID ... Top (RKB) Set Depth If... Set Depth (TVD) ... String WL.. Slring ... String Top Thrd - SURFACE 10314 9.794 30 3,012 2,392.3 45.50 L-80 BTC CONDUCTOR. ' Casing Descrlptlon String 0... String 10 ... Tap (Po(3) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top ThrO at% INTERMEDIATE 7 SS 6.875 27 6,014 3,500.2 29.70 L~0 BTCM Casing Descrlptlon String 0... String ID _. Top (Po(B) Sat Oapth (f... Set Oeplh (TVD) .. String Wt... String ... String Top ThM 0.SAND LEM 4 1/2 3.960 4,677 5,034 3,336.0 12.60 SCC IBTM HEA7 TRACE, Caeing Descrlptlon String 0... String ID ... T op (RKB) Set Depth (f... Set Oeplh (TVDI ... String Wt... String ... String Top ThM zz 0.SAND WINDOW 4 1/2 3.958 4,799 4,811 3,283.4 12.60 SURFACE, Casing Descrlptlon String 0... String 10 ... T op (ftK8) Set OapM (f... Set Depth (TVD) ... String Wt... String ... Slring Top ThM 3D-3.Dtz BSAND HH 4 1/2 3.958 5,010 5,346 3,399.0 12.60 L-80 IBT Casing Deacriptlon Slring 0... String ID ... Top (ftl(8) Sat DepM (1... Set Oepth (TVD) ... String Wt... String ... String Top Thrd GAS LIFT BSAND WINDOW 4 1/2 3.958 5,068 5,080 3,345.3 12.60 . 3,029 Casin Oeacri tl a Pon Strin 0... g Strin ID T g ~ o ftKB P l ) Sat De lh f P 1 ~~~ Set De th TVD P ( 1 ~~~ Strin Wt... g Strin 9 ~~~ Strin To Thrd 9 P ASAND LINER 4 1/2 3.958 5,302 9,596 3,518.4 12.60 L-80 DWC Liner Details GAS LIFT, Top Depth 4.543 NIPPLE. 4.625 (TVD) Top Intl ° GAUGE, 4,632 Top (RKB ) (RKB) ( ) Ihm Descrlptlon Comment ID ( LocnrDR. % 5 5,302 3,391.2 79.05 PA CKER HRD ZXP LINER TOP PACKER 4.£ SEAL ASS V , 1,694 ~ 5,321 3,394.8 79.51 NIP PLE RS PACKOFF SEAL NIPPLE 4.£ D-sAND 5,324 3,395.3 79.58 HA NGER FLEXLOCK LINER HAN GER 4.£ WINDOW, 4,T%-!677 5 335 3 397.2 79.83 SBE 190.47 CASING SEAL BORE EXTENSION 4 ; D~6AN0 LEM, , , . !,6775.034 5,354 3,400.3 80.29 XO BUSHING 4.; BSAND W r e5 e s D > c o Tubin Strln s B-SAND HH. Tubing Descrlptlon String 0... String ID .. T op (ftK8) Set Oepth (t... Set Oepth (TVDI ... String WL.. String ... String Top Thrd 5,0705306 ITERMEDIATE. TUBING 41/2 3.958 22 4,712 3,255 12.60 L80 IBTM z7-rm4 sbb. Com letion Det ails 8,013b,073 Top Depth Sbb. ' ITVD) Top Intl 6.1%1 ''229 Ebb, lop (ftK8) IRKS) ('1 14m Dasoriplbn Comment ID ( 6,Se4a.47s 22 21.8 -0.14 HANGER Vetco Grav 13 1/2" x 4 1/2" FiDr w/ 4.909" MCA Too Conn. 3.f 7 liner wlconsMctor packers between, 32 spf, 2.5"L x.125"W in 4 circumferential rows ISh ITOD IRKBII ( el I I') I Meke Model O/ I Serv Type Type I Sln) ITR p~ pn Run Doh ICOTm__ Sbb. 9,352-9,561 A-SAND LINER. 5.302-9.5% TD (1 E-766), 9,602 • ~ Page 1 of 1 Maunder, Thomas E (DOA) From: Packer, Brett B [J.Brett.Packer@conocophillips.com] Sent: Wednesday, March 25, 2009 8:59 AM To: Maunder, Thomas E (DOA) Subject: RE: 1 E-166 (204-153) Attachments: 1 E-166 Addendum to 10-404.pdf Tom, Attached is the pre and post rig work summaries and a better schematic. I only included the pre-rig work relevant to the workover. Let me know if you'd like more detail. Thanks, ,~ Brett hacker ~DrilCing aZ'WeQs 'Worf~ver~ngineer ~;„~~~ ~it~~ '%' ~` `~a 'Work# (907) 265-6845 Cell# (907) 230-8377 From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov] Sent: Saturday, March 21, 2009 3:06 PM To: Packer, Brett B Subject: 1E-166 (204-153) Bret, I am reviewing the 404 for the recent workover on this well and have some requests. 1. Please send a copy of the pre and post rig work. 2. Since this well is a multilateral, the "straight" drawing is a little confusing. Can you provide a simple drawing such as provided with the PTD application that illustrates the total 1E-166? Thanks in advance. Email is fine. Tom Maunder, PE AOGCC 3/25/2009 • STATE OF ALASKA R~ ii' D ALASKA OIL AND GAS CONSERVATION COMMISSION MAR Q ?(~~~ REPORT OF SUNDRY WELL OPERATIOa Oi! ~ ~~~ ~aa~a. "nlrnnissinn 1. Operations Performed: Abandon ^ Repair Well Q Plug Pertorations ^ Stimulate ^ Other~p0~l~~~y Alter Casing ^ Pull Tubing ~ •Perforate New Pool ^ Waiver ^ Time Extension ^ Change Approved Program ^ Operat. Shutdown^ Perforate ^ Re-enter S uspended Well ^ 2. Operator Name: 4. Well Class Before Work: 5. Permit to Drill Number: ConocoPhillips Alaska, InC. Development ^~ Exploratory ^ 204-153 / 3. Address: Stratigraphic ^ Service ^ 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-029-23220-00 7. KB Elevation (ft): 9. Well Name and Number. RKB 28' 1 E-166 8. Property Designation: • 10. Field/Pool(s): ADL 25651 & 25660 ` Kuparuk River Field /West Sak Oil Pool 11. Present Well Condition Summary: Total Depth measured 9602' feet true vertical 3519' feet Plugs (measured) Effective Depth measured 9594' feet Junk (measured) true vertical 3517' feet Casing Length Size MD ND Burst Collapse Structural CONDUCTOR 80' 20" 108' 108' SURFACE 2984' 10-3/4" 3012' 2393' INTERMEDIATE 5986' 7-5/8" 6014' 3502' A SAND LINER 4294' 4-1/2" 9596' 3518' Perforation depth: Measured depth: slotted liner from 6043'-9 561' true vertical depth: 3508'-3517' Tubing (size, grade, and measured depth) 4.5", L-80, 4712' MD. Packers & SSSV (type & measured depth) 3 ZXP pkrs, @ 4676', so~ o', 5302' CamCO 'DB' nipple @ 509' 12. Stimulation or cement squeeze summary: Intervals treated (measured) not applicable Treatment descriptions including volumes used and final pressure : 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casin Pressure Tubin Pressure Prior to well operation SI -- Subsequent to operation SI -- 14. Attachments 15. Well Class after work: Copies of Logs and Surveys run _ Exploratory ^ Development ^~ Service ^ Daily Report of Well Operations _X 16. Well Status after work: OilO Gas^ WAG^ GINJ^ WINJ ^ WDSPL^ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: none contact Brett Packer @ 265-6845 + Printed Name B acker Title Wells Engineer ~/ / Signature Phone: 265-6845 ~ D Date Pie ared b Shar n All u -Drake 263-4612 Form 10-404 Revised 04/2006 -, ~ fi~ ~.,. •, !~ 31 Submit Original Only *Vetco Gray Hanger, 11" X 4-1/2"*Conductor, 20" X 34" Insulated, set at 108' MD. Tubing String: 4-1/2" 12.6#, L-80, IBTM 509' MD - 3.875" DB Nipple 3029' MD -GLM, Camco 4-1/2" X 1" KBG-2-1R j 4543' MD -GLM, Camco 4-1/2" X 1" KBG-2-1R / 4625' MD - 3.812" DB Nipple ~ 4632' MD -Guardian Gauge Carrier Heat Trace Cable to 3024' MD MD - 5-1/2" X 7-5/8" ZXP Liner Top Packer w/ Hold Downs ~6' MD -Casing Sealbore Receptacle 4.75" ID 4712' MD -Bottom of Seal Assembly 4.75" Seal OD 10-3/4" Casing Shoe, 45.5/40.5#, L-80, BTC set @ 3012' MD, 2393' TVD 4796' MD - 4-1/2" X 7-5/8" Model 'B' HOOK Hanger 4752' MD - 3.75" DB Nipple ConocoPhillips West Sak 1 E-166 Producer Tri-Lateral Completion RWO 09 MD -Lateral Entry Module (LEM) Orienting Profile _2: D-sand Window at +/- 4799' MD, 72 deg 3-1 /2" bentjointand guide 4-1/2" 12.6# slotted and blank liner / shoe 5010' MD - 5-1/2" X 7-5/8" ZXP Liner Top Packer w/ Hold Downs Lateral Entrv Module (LEM) Assembly 5-1/2 X 7-5/8 ZXP Liner Top `- Packer w/ Hold Downs Casing Sealbore Receptacle - 4.75" ID ~ Tubing Swivel, 4-1/2" a/ Orienting Profile f Positive Latching Collet '- Seal Bore for Lateral Isolation - 3.68" ID ~ Access Window Positive Lateral Access Seal Bore for Lateral Isolation - 3.68" ID ~ Isolation Seal Asembly 4.75" Seal OD 5030' MD-Casing Sealbore Receptacle 5063' MD - 4-1 /2" X 7-5/8" Model 'B' HOOK Hanger 5-1/2" X 7-5/8" ZXP ~-• Liner Top Packer with Hold Downs i' 5-1/2" X 7-5/8" Flex Liner Hanger /Packer ~-- Lock Assembly Top at \ Liner Hanger +/_ 5302' MD _- - 5335' MD-Casing Sealbore Receptacle Baaer Hugbes 2aea. Tbis tlocumen> may not be repraducetl ar dlsbibukd, In wbak or In purl, in any loan or by any means Neclronic er mecMnkal, including photocopying, recording, or by any Inlormation storage and rebleval ayslem now known or bereaner mvenrM, vnmaut written perm)>aion Irom Baker Hugbea Inc. 5128' MD - 3.562" DB Nipple 'A' Sand Undulating Lateral Casing, 7-5/8" 29.7#, L-80, BTCM, Set @ +/- 6014' MD, 3502' TVD. saxlcE~s &~kcr Oil Tools As Completed Lateral E ntry Module (LEM) With Dive rters and Isolation Lateral A ccess Diverter Lateral Isolation Diverter GS Running Tool String In sUlkd Installed (3.00" Lateral Drift) (2.50" ID Mainbor e Drift) ~ 'GS'Profile for I ~ Coil Connector ~ Running/Retrieving til ~ i (1.00'Length) ~ Snap In/Snap Out ' "Positive Locating r Bxk Pressure Valve Collet (tso• Lengm) ~ I ' ~ i ~'~ r Fbw-Thro Swivel Lateral Isolat on ~ Seals (7.25'Lengih) (Lateral Diverter I -Hydraulic ~ Ramp '_ ' Disconnect I I Isolation/ Mainbore /• ~ (1.50' LengM) Diverter Skeve GS Spear r (1.50' Length) Lateral Isolation' 6.8 5ftApproz. Seals u OAL' ~ ~ 'Jars may be required in hghly deviated ', I, or deep applications (5' approz length). 18.5' Diverter Length 18.5' Skeve Length -' Equipment Specifications 4-1 /2" X 7-5/8" HOOK Hanger Mainbore Drift: 5.32" Mainbore Drik, with diverter: 4.63" Lateral Drift, no diverter or LEM: 3.86" Lateral Drift, wl diverter, no LEM: 3.88" Lateral/Mainbore DiveRer OD: 6.75" 41/2" Lateral Entry Module Mainbore Drift: 3.65" Mainbore Drift, wl isolation sleeve: 2.50" Lateral Drift, wl coil diverter: 3.00" OD of Diverter and Sleeve: +l- 3.89" Diverter and Sleeve Length: +/-18.5' 4-112" 12.6# slotted and blank liner 1E-166: 4-1 /2" Liner shoe @ 9596' MD, 3518' TVD 200A • tE-166 Td~aterol Gompletlon -Producer January Jg, 2809 RWO Completed 1 E-166L2: 3-1/2" Liner Shoe @ 9402' MD, 3258' TVD MD -Bottom of Seal Assembly 4.75" Seal OD 5057' MD -Lateral Entry Module (LEM) ~ ~' Orienting Profile 'B' Sand Lateral 166L1: B-sand Window at +/- 5068' MD, 82 deg 3-1/2" bent joint and guide 4-1/2" 12.6# slotted and blank liner shoe 1 E-166L1: 3-1/2" Liner shoe @ 9380' MD, 3329' TVD 5346' MD -Bottom of Seal Assembly 4.75" Seal OD ConocoPhillips :Vu3~2:, hx ... -_.._.. ____... __.SaaV. NIPPLE CONDUCTOR, 0106 NEATTRACE, 22 SURFACE, 30-3,012 GAS LIFT. ____ 3.029 GAS LIFT, _ -_- _ 4.5,3 NIPPLE, 6,625 GAUGE, 6.632 LOCATOR, 4.685 SEAL ASSY, - 4.69a D SANG 6, • KU P 1 Well Attributes I Welllwre APVU WI ''Field Namr 500292322000 (WEST SA c~,m ent 1 E-166 Status Protl/lnj Ty Ne ID IAnnotahon Enrl Dale .,a~~~~y veo~upuon .~~~ny ..... .,~n~y ~~... CONDUCTOR 20 19.124 ,,.P,,,...,, 0 ..e, ..er.,, ,.... 108 .,a...o . 108.0 ~I __...a ....... 62.50 .,_...e ... H-00 ....a ._~...._ WELDED Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (ND) ... String Wt... String ... String Top Thrd SURFACE 10 3/4 9.794 30 3,012 2,392.3 45.50 L-80 BTC Casing Description String 0... String ID ... Top (ftKB) Set Depth (t... Set Depth (ND) ... String Wt... String ... String Top Thrd INTERMEDIATE 7518 6.875 27 6,014 3,500.2 29.70 L-80 BTCM Casing Description String 0... String ID ... Top (ftKB) Set Depth (i... Set Depth (ND) _. String Wt... String ... String Top Thrd D-SAND LEM 41/2 3.960 4,677 5,034 3,336.0 1260 SCC IBTM Casing Descnption String 0... String ID ... Top (kKB) Sat Depth (f... Sat Depth (ND) ... ( String Wt... String ... String Top Thrd D-SAND WINDOW 41/2 I 3.958 4,799 4,811 3,2834 I 12.60 Casin Descri Strin O._ Strin ID ... Top (ftKB) Sat De th (f... Set De th (ND) ...' g trln String ... String Top Thrd B-SA DHH 4 /2 3.9 58 5,010 6 S 99.0 . 12.60 L-80 I IBT 9 9 8 peon Casin Descd Strin 0... Strin ID ... Top (ftK8 ( e~ Set D th f... 3 Set De th (ND) Str12 O... i String ... String TOp Thrd B-SAND WINDOW 41/2 3.958 5,068 5,080 3,345.3 .Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Deptn (ND) ... - iString Wt... ( String ... i String Top Thrd A-SAND LINER 41/2 3.958 5,302 9,596 3,518.4 ', 12.60 L-80 DWC j Liner Details Top Depth ~~ (ND) Too Irlcl 3.83'SBE 1190-4/CASING SEAL BORE EXTENSION 4./SL ).29 XO BUSHING 14.SOC Ing 0... j5tring ID .-. Top (ftKB) Set Depth (f... Set Depth (ND) ... String Wt...iString _. String Top Thrd 41/2 I 3.958 22 I 4,712..1 .3255 12.60 ~ L80 IBTM Inch ') Item Description Comment ID (in) 1.14 HANGER Vetco Gray 13 1/2" x 4 V2" Hgrw! 4.909" MCA Top Conn. 3.90( 5.85 NIPPLE Camco 4 V2" X 3.875" "DB" Nipple 3.87° 3.82 NIPPLE Camco 4 112" X 3.812" "DB" Nipple 3.814 3.07 GAUGE Baker Guardian Gauge w/pups 3.95E 1.79 LOCATOR iLOCator Ring and Coupling 3.89( ?.Ol SEAL ASSY (GBH-22 Seal Assembly (2 ft space out) pumps fish etc valves din retrievable lu s _ _ 4.00( ) , , , p g , e Intl . _ . L._ ) Description Comment Run Date ID (in) 114HEAT TRACE I, I 2/10/2009 0.00( - tS Shot ~ (ND) Btm (ND) De^ tK6) (ftKB) Zone Date (sh-- Type Commerd ,507.0 3,513.6 WS A2, 1E-166 924/2004 32.0 Slots ALL PERFS 6023' - 9561' Slotted liner w/COnstbGYOr packers between, 32 spi, 2.5"L x.125"W in 4 I circumferential rows ,528.0 3,538.3 WS A2, 1E-166 9/24/2004 32.0 Slots ,547.4 3,540.4 WS A2, 1E-166 9/242004 32.0 Slots ,518.7 3,507.9 WS A2, 1E-166 9/24/2004 320 Slots 7,065( 1.583 7,955(} 8,372 8,559, 9,104 TO RECONNECT ESP CABLE - NO TO CONVERT FROM ESP TO GAS IATIC w/Alaska Schematic9.0 landrel Details IITop Depth Top ', ~~. PoA (TVD) Incl OD V I ~' Latch Size TRO Run -. n T_p_(kK8) (k KB) (°) Make Modal I tin) I Serv TYP ~ TYPe ~ P^) lP 1 ~ Run Date Com 1 30291 2403.748.13 Camco KBG-2-1R 1IGAS LIFT ~,GLV ~i.BK 0,188 1,494.0(2(74/2009 ~4,543~ 3,194.6I66.08Camco (KBG-2-1R I 1GAS LIFT OV BK 10.313 0.0(2/142009 slor~. 9,362-9,561 ---~~ A-SAND LINER, 5,302-9.596 TD (tE-166), 9.602 n • Well Date Event Descri tion 1 E-166 1/2/09 (PRE -RWO) T PPPOT -PASSED. T POT -PASSED. IC PPPOT -PASSED. IC POT ~ - PASSED. UPPER BODY SEAL PPPOT -PASSED. UPPER BODY SEAL POT - ~ PASSED. LOWER BODY SEAL PPPOT -PASSED. LOWER BODY SEAL POT - w FAILED. LDS FUNCTION TEST -PASSED. ate. 1E-166 2/5f09 Nordic Rig 3 accepted onto 1E-166 on 2-5-2009 @ 09:00 am. RU hardline, bermed up cellar, pulled BPV, RU circ lines, loaded pit's with 8.8ppg seawater/KCL, tested hardline, loaded ESP spooler, killed well, installed BPV; ND tree, installed test dart, NU BOP, RU and started BOP test. 1E-166 216/09 Cont BOP test, RD test equipment, pull test dart and BPV, install iso-sleeve, MU landing jnt and circ hose, BOLD's and pull hanger to rig floor, flush IA ~ with 150 bbls hot seawater, POOH stand back 4 1/2" tbg and strap in > derrick, MU and RIH with lateral wash tools, cleanout to 5,046', POOH to Y 264'. ~ O 1E-166 2!7109 POOH LD cleanout assembly, MU seal assembly dummy run, RIH to 5,046', ~ POOH, MU and RIH with LEM assembly to 4,774' ~? 1E-166 2/8109 Orient and latch LEM in place, set ZXP, test 7 5/8" csg x ZXP for 5 minutes, M monitor welt, pull setting tools out of ZXP, POOH LD 3 1/2" DP, RU and run 4 0 1/2" gas lift completion to 3,992'. ~ 1E-166 2/9/09 Locate SBE, confirm seals in place, space out, drop ball/rod down tbg, MU Z hanger and landing jnt, make final splices, pump 150 bbls inhibited seawater/KCL down IA, land hanger, test tbg x IA, shear SOV, install BPV, ND/NU, freeze protect well, allow to u-tube. 1E-166 2/10/09 Install BPV, secure well, install guages on tree, blow down all lines, break down hard line, clean out pits, RDMO well 1E-166, clean out cellar box, mov rig off 1E Pad. 1E-166 2/14/09 PULLED B&R, RHC @ 4625' RKB. PULLED SOV AND SET 1" OV(PORT=5/16") @ 4542' RKB. PULLED DMY AND SET 1" GLV(PORT=3/16" TRO=1494) @ 3029' RKB. ~ ~ COMPLETE. ~ O a r1 Con©coPhi~~ip-s Time Log & Summary ~ve,~~WWe~~e~~nn~ Report Well Name: 1 E-166 Rig Name: NORDIC 3 Job Type: RECOMPLETION Rig Accept: 2/5/2009 9:00:00 AM Rig Release: 2/10/2009 3:00:00 AM Time Logs Date____ From To Dur S. Depth E Depth Phase Code____ Subcode T Comment ___ 2!05/2009 24 hr summary Nordic Rig 3 accepted onto 1 E-166 on 2-5-2009 @ 09:00 am. RU hardline, bermed up cellar, pulled BPV, RU circ lines, loaded pit's with 8.8ppg seawaterlKCL, tested hardline, loaded ESP spooler, killed well, installed BPV, ND tree, installed test dart, NU BOP, RU and started BOP test. 07:30 09:00 1.50 0 0 COMPZ RPCOM MOB P Set up double stack of rig mats. Move rig over 1 E-166 A e t Nordic Ri 3 at 9:00 am on 09:00 10:00 1.00 0 0 COMPZ RPCOM RURD P RU hardline, tiger tank and berm. 10:00 11:30 1.50 0 0 COMPZ RPCOM MPSP P nd ull BPV. 11:30 14:00 2.50 0 0 COMPZ RPCOM RURD P Rig up to kill well. Off load fluids to pits. Test lines to 2000 psi. Crane on location, load ESP spool onto rig floor. 14:00 17:00 3.00 0 0 COMPZ RPCOM KLWL P Initial well pressures T/I/O = 80/840/150 psi. Bleed down tubing and IA. Pump 90 bbl down the tubing at 5 bpm - 80 psi, and 200 bbl down the IAat 5 bpm - 90 psi. Well is on a vacuum, shut in and monitor well. 17:00 18:00 1.00 0 0 COMPZ RPCOM OTHR P Blow down and RD circ lines, install BPV. 18:00 19:00 1.00 0 0 COMPZ RPCOM NUND P ND tree, install test dart. 19:00 22:00 3.00 0 0 COMPZ RPCOM NUND P NU 13 5/8" BOP. 22:00 00:00 2.00 0 0 COMPZ RPCOM BOPE P RU and test BOPE at 250/2.500 psi on chart. Witness of BOP test waived by AOGCC Rep Bob Noble on 2-5-09 at 18:00 hrs. 2/06/2009 Cont BOP test, RD test equipment, pull test dart and BPV, install iso-sleeve, MU landing jnt and circ hose, BOLD's and pull hanger to rig floor, flush IA with 150 bbls hot seawater, POOH stand back 4 1/2" tbg and stra in derrick, MU and RIH with lateral wash tools, cleanout to 5,046', POOH to 264'. 00:00 03:30 3.50 0 0 COMPZ RPCOM BOPE P Cont testing BOPE at 250/2,500 psi on chart. 03:30 05:30 2.00 0 0 COMPZ RPCOM OTHR P RD test equipment, pull test dart, un-chain stands of 3 1/2 in derrick and shuffle to off-side. 05:30 06:30 1.00 0 0 COMPZ RPCOM RURD P Putl BPV, install isolation sleeve, MU landin ~nt and circ hose, BOLD's. r~ ;• Time Logs Date From To Dur S De th E De th Phase Code Subcode T Comment 06:30 08:30 2.00 0 0 COMPZ RPCOM CIRC P Pull hanger to rig floor, pump 150 bbls hot sea-water/KCL down IA to clean tb and a ui ment. 08:30 13:30 5.00 4,468 0 COMPZ RPCOM PULL P Pull completion standing back 4 1/2" tbg. Spool ESP cable, pumping 50 bbls Hr for well control. Recovered All (76) Cannon clamps, (2) Flat guards, (3) Protectolizers, and (10) Bands. Missing (1) door off a protectolizer, but screw was in place. All equipment shafts rotated freely. Oil in the Tandem Seals and Motor were all clean and clear. Cable and Motor Test good. Procedure showed we should recover 15 Bands but 5 where removed during previous operation to connect the enetrators. 13:30 15:30 2.00 0 0 COMPZ RPCOM PULL P Rig down and lay down ESP motor. 15:30 16:00 0.50 0 0 COMPZ RPCOM EQRP P Install wear Ring. 16:00 17:00 1.00 0 564 COMPZ RPCOM PULD P RU Snozzelators BHA on 3 1/2" DP. 17:00 19:00 2.00 564 4,726 COMPZ RPCOM TRIP P RIH with Snozzelator on 3 1/2" DP to 4,726', up weight 95K, down weight 69K. 19:00 21:00 2.00 4,726 5,046 COMPZ RPCOM CIRC P Warm up top drive quill and grease washpipe, MU top drive and wash down from 4,726' to 5046', pumping at 8 bpm - 3,000 psi down tbg, 6 bpm down IA. Had no trouble going in and out of hook han er. 21:00 21:30 0.50 5,046 5,046 COMPZ RPCOM OWFF P Blow down top drive while monitoring well well on vac. 21:30 00:00 2.50 5,046 264 COMPZ RPCOM TRIP P POOH with cleanout assembly standing back 3 1/2" DP from 5,046' to 264'. 2/07/2009 POOH LD cleanout assembly, MU seal assembly dummy run, RIH to 5,046', POOH, MU and RIH with LEM assembl to 4,774' 00:00 01:30 1.50 264 0 COMPZ RPCOM PULD P Cont POOH LD cleanout assembly. 01:30 03:30 2.00 0 607 COMPZ RPCOM PULD P MU 4 1/2" seal assembl 4.76" seals) BHA for dumm run. 03:30 06:00 2.50 607 4,790 COMPZ RPCOM TRIP P RIH with seal assembly BHA on 3 1/2" DP to 4,790' and MU top drive, u wei ht 95K, down wei ht 70K. 06:00 07:00 1.00 4,790 5,046 COMPZ RPCOM DHEO P Made numerous attempts to pass through hook hanger but to in9 up at 4 813'. Rotated and reciprocated string and finally assed throw h. hook han er to a de th of 5,046'. 07:00 12:00 5.00 5,046 0 COMPZ RPCOM TRIP P POOH from 5,046' and LD dummy run BHA. 12:00 14:00 2.00 0 0 COMPZ RPCOM OTHR P RU crane remove ESP cable and s ool from floor 14:00 17:00 3.00 0 461 COMPZ RPCOM TRIP P Pick u LEM BHA, perform shallow MWD test GOOD. --____- __~__ ~ ~ P~~~~ 2 0¢' r~ ~~ Time_L~s __ Date_ From To Dur __ S. Depth E. De th _ Phase Code Subcode T Comment 17:00 22:00 5.00 461 4,774 COMPZ RPCOM TRIP P RIH with LEM on 3 1/2" DP, 30 FPM, filling hole @ 50 bph for well control, to 4,774', up weight 95K, down wei ht 75K. 22:00 00:00 2.00 4,774 4,774 COMPZ RPCOM DHEO P Break circ at 3 bpm - 600 psi to orient LEM assembly to 16 degrees left of hi hside. 2/08/2009 Orient and latch LEM in place, set ZXP, test 7 5/8" csg x ZXP for 5 minutes, monitor well, pull setting tools out of ZXP, POOH LD 3 1!2" DP, RU and run 4 1/2" as lift com letion to 3,992'. 00:00 01:00 1.00 4,774 5,034 COMPZ RPCOM OTHR P Wash down to 5,034' mule shoe ~ieoth. passing through hook hanger with no roblem, re-oriented LEM and latched ZXP at 4 de rees left of hi hside, un-latched with 20K over ull 115K) slacked off and latched into hook han era ain at 4 degrees left of hi hside. 01:00 02:00 1.00 5,034 5,034 COMPZ RPCOM PACK P Dropped 1 3/4" ball and pumped down string at 1 bpm, seated ball, pressured up to 2,000 psi to activate pus er too and set ZXP, cunt pressure up to 3,200 si with test um and neutralized usher tool. 02:00 03:00 1.00 5,034 5,034 COMPZ RPCOM PRTS P Fill la with 8.8ppg sea-water/KCL, close u er i e rams, ressure u on IA to 2,500 psi and test 7 5/8" cs x ZXP acker for 5 minutes on chart, good test. Blled off IA and pull settin tools from ZXP. 03:00 03:30 0.50 5,034 5,034 COMPZ RPCOM OWFF P Blow down top drive, monitor well for 15 minutes, fluid level in IA dropped out of sight, no indication of gas bubble. 03:30 09:30 6.00 5,034 0 COMPZ RPCOM PULD P POOH LD 3 1/2" DP filling hole with 50 b h. 09:30 10:30 1.00 0 0 COMPZ RPCOM RGRP P Slip and cut drill line. 10:30 12:00 1.50 0 0 COMPZ RPCOM RURD P RU sheaves, spools and rig floor to run 4 1/2" com letion. 12:00 00:00 12.00 0 3,992 COMPZ RPCOM RCST P MU seal assembly and gauge carrier, splice Tec wire to gauge, RIH with 4 1/2" SCC completion to 3,992', checking electrical integrity of heat trace and Tec wire every 1,000', filling hole 50 bph. Up weight 80K, down wei ht 63K. 2/09/2009 Locate SBE, confirm seals in place, space out, drop ball/rod down tbg, MU hanger and landing jnt, make final splices, pump 150 bbls inhibited seawater/KCL down IA, land hanger, test tbg x IA, shear SOV, install BPV, ND/NU, freeze rotect well, allow to u-tube. 00:00 02:30 2.50 3,992 4,717. COMPZ RPCOM RCST P Cont RIH withf4 1/2" SCC gaslift com letion from 3,992', locate SBE, no- o'd at 4,717', set down 10K. 02:30 03:30 1.00 4,712 4,699 COMPZ RPCOM HOSO P Loaded IA with 8.8 seawater/KCL to surface, fluid level holding. Pulled up hole 18' drag dropped 5K, fluid level dro ed out of si ht. ~'~g~ 3 0€ r~ Time Logs _ _ _ _-- . _ Date From To Dur S De th E. De th Phase Code Subcode T Comment _ 03:30 04:30 1.00 4,699 4,688 COMPZ RPCOM HOSO P ___ Space out completion with a 2' space out, MU hanger and landing 'nt. 04:30 06:00 1.50 4,688 4,688 COMPZ RPCOM OTHR P MU heat trace and Tec wire splices and tested both. (Waiting on correct enetrator! 06:00 07:30 1.50 4,688 4,688 COMPZ RPCOM CIRC P Pump 150 bbls inhibited seawater/KCL (1 % CRW-132) followed by 40 bbls clean seawater/KCL down IA. 07:30 09:00 1.50 4,688 4,712 COMPZ RPCOM HOSO P Lowered hanger down thru stack and landed. RILDS. 90K up wt 65 dwn wt. Tested tubing hanger Orings to 5000 si. 09:00 10:30 1.50 4,712 4,712 COMPZ RPCOM DHEQ P Dro ed ball and rod: With annulus open, pressure test tubing to 3000 psi monitoring IA for returns. Bleed down tubing to 1750 psi. Pressure up on IA to 3000 psi for 30 min on chart. Bled pressure off IA, bled pressure off tubing. Ramp up pressure on IA and sheared SOV @ 4543' w/1300 si. 10:30 15:00 4.50 4,712 4,712 COMPZ RPCOM NUND P Back out landing jt. and wash out BOP stack. Drain stack and lay down landing jt. Remove side port isolation sleeve from hanger. Install two-wa check. ND BOPE. Replace HCR valve. Lift off BOP stack. 15:00 17:00 2.00 4,712 4,712 COMPZ RPCOM DHEQ P Meggar heat trace thru penetrator. Make final connection and final electrical test on TECH wire. RD s oolers. 17:00 21:00 4.00 4,712 4,712 COMPZ RPCOM NUND P NU tree, heat trace penetrator leaked, removed tree, replaced o-ring on penetrator, installed tree, tested at 250/5,000 psi, good test, pull two -- • wa check. 21:00 23:00 2.00 4,712 4,712 COMPZ RPCOM FRZP P PJSM with LRS personell, test manifold and circ lines at 250/2,500 psi, good test, freeze protect well with 130 bbls diesel down IA at 2 b m, 800 si ICP - 1,000 si FCP. 23:00 00:00 1.00 4,712 4,712 COMPZ RPCOM RURD P Allow well to u-tube, warm up move system, move mudshack and tanks for ri move. 2/10/2009 Install BPV, secure well, install guages on tree, blow down all lines, break down hard line, clean out pits, RDMO well 1 E-166, clean out cellar box, move ri off 1 E Pad. 00:00 01:30 1.50 0 0 COMPZ RPCOM RURD P Blow down and RD circ lines, set BPV, install guages and secure tree, SITP = 0, IA = 0, OA = 180 si. 01:30 03:00 1.50 0 0 DEMOB MOVE DMOB P PJSM, back rig off well site, move mats, clean cellar box and well site. Nordic Rig 3 Released at 03:00 hrs on 2/10/2009. -~_ ~~wy~~~~ JUI~ ~% ~ 200 ~ih~lll~~~~~~' Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Well Job # ~~w~ ~ ~'„ Log Description NO. 4707 /~ I / ;` I_,, ~..,~~_ Company: Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Kuparuk Date BL Color CD 05/15/08 iF-12 11996623 PRODUCTION PROFILE - / ~ 05/01/08 1 1 3J-11 11996624 PRODUCTION PROFILE C/G( ~ 05/02/08 1 1 3K-102 11963094 MEM PROD PROFILE 20'~ - ~ 05/09/08 1 1 iJ-152 11996632 GLS ( C 05/09/08 1 1 E-166 11994665 GLS 05/11/08 1 1 1 E-168 11994665 GLS - 05/10/08 1 1 1 H-01 11996626 PRODUCTION PROFILE W/FSI ~ („ / 05/10/08 1 1 2X-15 11996634 PRODUCTION PROFILE W/FSI - ~ 05/12/08 1 1 Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. • • • ConocoPhillips a P.O. BOX 100360 ANCHORAGE, ALASKA, 99510-0360 Apri116, 2008, . • Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7~' Avenue, Suite ~` APR ~ ~ 2008 Anchorage, AK 99501 Dear Mr. Maunder:. RECEIVED APR 2 2 2008 Alaska Oil & Gas Cons. Commission Anchorage -l~3 1~ Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRU). Each of these wells was found to have a void in the conductor. These voids were filled with cement if needed and corrosion inhibitor, engineered to prevent water from entering-the annular space. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treatments took place and meets the requirements of form 10-404, Report of Sundry Operations. The corrosion inhibitor/sealant was pumped on 3/29/200$. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please call MJ Loveland or Perry Klein at 907-659-7043, if you have any questions. Sinc ~~~~ Perr ConocoPhillips Well Integrity Projects Supervisor • • ~~ ,, ConocoPhillips Alaska Inc. Surf~ice' Casing'by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off , Report of Sundry Operations (10-404) Kuparuk Field n~+e 3/Z 9/Z008 Well Name PTD # Initial top of cement ft Vol. of cement um ed Final top of cement Cement top off date Corrosion inhibitor Corrosion inhibitor) sealant date 1 E-34 197-166 9" bbls ft " al 1 E-102 204-231 14" NA 9 NA 7 3/29/2008 1 E-114 204-171 24" NA 14" " NA 8 3/29/2008 1 E-126 204-122 25" NA 24 NA 16 3/29!2008 1 E-166 204-153 20" NA 25" " NA 14 3/29/2008 NA 20 NA 12 3/29/2008 • • .= ~.,,- ~° ~. ~.-~~,. .~ - ... ate, ~;~, r MICROFILMED 03/01 /2008 DO NOT PLACE ANY NE1IV MATERIAL UNDER THIS PAGE F:\LaserFiche\CvrPgs_Inserts\Microfilm Marker.doc ;< f.J( b ~ ;t~~~ DATA SUBMITTAL COMPLIANCE REPORT 9/28/2006 Permit to Drill 2041530 Well Name/No. KUPARUK RIV U WSAK 1E-166 Operator CONOCOPHILLlPS ALASKA INC S/~¿/M-~'1 API No. 50-029-23220-00-00 MD 9602 / TVD 3519 /' Completion Date 9/24/2004 ,-- Completion Status 1-01L Current Status 1-01L UIC N -_..~-~_.._~ ---~,--~-~-~-_. ---..-----.'. REQUIRED INFORMATION Mud Log No Samples No Directional surve~ DATA INFORMATION Types Electric or Other Logs Run: GR ¡ RES Well Log Information: (data taken from Logs Portion of Master Well Data Maint Induction/Resistivity 25 Blu 11 Þ Interval Start Stop o 9602 108 9602 . Log/ Data Digital Typ~ed/Frmt FRPt ~ ~ C Lis J 3/ / 7 Induction/Resistivity Electr Dataset Number Name Directional Survey Log Log Run Scale Media No OH/ CH Open Open Received 1 0/13/2004 5/9/2005 Comments 108 multiple propagation resistivity/gr/mwd/rwd 9602 Open 5/9/2005 multiple propagation £;reslstlvlty¡g d 9602 Open 5/9/2 5 multiple propagati n 1ú f 1.- t~ _ _ _ re~r/ /rwd ,--RI5( LIS Yerifi~ion ~T---- r~~/~· Well Cores/Samples Information: À¡-" /)~ 't(/) 108 !ð P Name Interval Start Stop Sent Received Sample Set Number Comments Formation Tops G)N ~/N . ADDITIONAL INFORMATION Well Cored? ~ Chips Received?~ Daily History Received? Analysis Received? ~ Comments: Compliance Reviewed By: ;J» Date: I! 0 ~CZ- . ConocJPhillips December 16, 2005 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West ih Avenue Suite 100 Anchorage, Alaska 99501 . Jim Ennis Wells Group Engineer Drilling & Wells P. o. Box 100360 Anchorage, AK 99510-0360 Phone: 907-265-1544 ~otj-- ¡53 RECEIVED DEe 2 1 2005 Alaska Oil & G as Cons. CDItImi ' AnChorage . . "ton Subject: Reports of Sundry Well Operations for 1 E-166 Dear Commissioner: ConocoPhillips Alaska, Inc. submits the attached Reports of Sundry Well Operations for the recent workover on the West Sak weIl1E-166. If you have any questions regarding this matter, please contact me at 265-1544. Sin~ J. Enn s , Wells Group Engineer CPAI Drilling and Wells JE/skad 1. Operations Performed: Abandon D Alter Casing D Change Approved Program D 2. Operator Name: ConocoPhillips Alaska, Inc. 3. Address: . STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION . RECEIVED DEC 2 1 2005 Repair Well 0 Pull Tubing 0 Operat. ShutdownD P. O. Box 100360, Anchorage, Alaska 99510 7. KB Elevation (ft): RKB 28' 8. Property Designation: ADL 25651 & 25660, ALK 469 & 470 11. Present Well Condition Summary: Total Depth Effective Depth Casing Structural CONDUCTOR SURFACE INTERMEDIATE LlNER-A SAND Perforation depth: Alaska Oil & Gas Cons. Commission REPORT OF SUNDRY WELL OPERATIONS Anchorage D Time Extension D Re-enter Suspended Well D measured 9602' feet true vertical 3519' feet measured 9594' feet true vertical 3517' feet Length Size MD 80' 20" 108' 2984' 10-3/4" 3012' 5986' 7-5/8" 6014' 4294' 4-1/2" 9596' Plug Perforations D Perforate New Pool D Perforate D 4. Current Well Status: Development 0 Stratigraphic D Stimulate D Waiver D Other true vertical depth: 3508'-3517' Exploratory D D 5. Permit to Drill Number: 204-153/ 6. API Number: 50-029-23220-00 Service 9. Well Name and Number: 1 E-166 10. Field/Pool(s): Kuparuk River Field / West Sak Oil Pool Plugs (measured) Junk (measured) TVD Burst Collapse 108' 2393' 3502' 3518' Measured depth: slots in 'A' liner from 6043'-9561' Prior to well operation Subsequent to operation 14. Attachments Copies of Logs and Surveys run _ Daily Report of Well Operations _X Form 10-404 Revised 04/2004 Packers & SSSV (type & measured depth) HRD ZXP pkr @ 5302' no SSSV 12. Stimulation or cement squeeze summary: Intervals treated (measured) Oil-Bbl 1004 1058 Printed Name Signature Jim Ennis @ 265-1544 Ji~;. Tubing (size, grade, and measured depth) 4-1/2" , L-80, 4470' MD. not applicable RBDMS 8FL OEC 2 1 2D05 13. Treatment descriptions including volumes used and final pressure: 2161 15. Well Class after proposed work: Exploratory D Development 0 Service D 16. Well Status after proposed work: Oil0 GasD WAGD GINJD WINJ D 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. I Sundry Number or N/A ifC.O. Exempt: Contact Representative Daily Average Production or Injection Data Gas-Mcf Water-Bbl Casinr:¡ Pressure Tubinr:¡ Pressure 222 248 50 64 WDSPL D Title Phone Wells Group Engineer I. / ~:~:red b! ~ron ~1I~-~a~263-4612 ORIGINAL Submit Original Only TUBING (0-4470. ODA.500. ID:3.958) SCREEN (4408-4418. OD:5.130) SEAL (4418-4432. OD:5.130) GAUGE (4466-4468, OD:4500) Hanger L2 (4795-4799, OD:7.625) Packer L 1 (5010-5030. OD:7.625) SBR L1 (5030-5057. OD:6.260) Hanger L 1 (5057-5068, OD:6.260) ConocoPhilllps Ala!. Inc. 1E-166 ~ . £-166 KRU API: 500292322000 SSSV Type: NONE Well Type: PROD Orig 9/24/2004 Completion: Annular Fluid: Last W/O: Reference Log: 28' RKB Ref Log Date: Last Tag: TO: 9602 ftKB LastTag Date: Max Hole A 100 deg @ 6460 Casing String - COMMON STRINGS Description Size Top Bottom TVD Wt Grade INTERMEDIATE 7.625 0 6014 3502 29.70 L-80 CONDUCTOR 20.000 0 108 108 62.50 H-40 SURFACE 10.750 0 3012 2392 45.50 L-80 g::~~~ti~~ring - LINER - AI SAs~~ (pel rfor~~~d Lilne~Ît~~f allte~~~ed Wllb~tk r~~~de LlNER-A SAND 4.500 5302 9596 3518 12.60 L-80 Tubing String - TUBING Size I Top 4.500 0 Perforations Summary Interval TVD 6043 - 6073 3508 - 3514 Angle @ TS: deg @ Angle @ TO: 88 deg @ 9602 Rev Reason: GL V C/O Last Update: 11/812005 Thread BTCM WELDED BTC Thread DWC Bottom 4470 Wt I 12.60 Thread IBT TVO 3165 Grade L-80 Zone WSA2 Status Ft SPF Date Type 30 32 9/24/2004 IPERF Comment ALL PERFS 6023' - 9561': Slotted liner w/constrictor packers between, 32 spf, 2.5"L x.125'W in 4 circumferential rows 6198 - 6229 3536 - 3540 6384 - 6415 3543 - 3538 6539 - 6629 3519 - 3508 7065 - 7583 3509 - 3520 7955 - 8372 3530 - 3524 8559 - 9104 3509 - 3499 9352 - 9561 3513 - 3517 Gas Lift MandrelsNalves St MD TVO Man Man Type V Mfr V Type Mfr 3006 2388 CAMCO KBG-2 DMY 2 3800 2866 CAMCO KBG-2 DMY Other~plugs, equip.. etc.) - COMMON JEWELRY Depth TVD Type 22 22 HANGER 4408 3138 SCREEN 4418 3142 SEAL 4432 3148 MOTOR 4466 3163 GAUGE 4468 3164 Centralizer 4795 3279 Hanger L2 4799 3280 WINDOW L2 3331 Packer L 1 3335 SBR L 1 3341 Hanger L 1 3343 WINDOW L1 Other :plugs, equip., etc.) - LINER - A SAND Depth TVD Type 5302 3391 PACKER WSA2 WSA2 WSA2 WSA2 WSA2 WSA2 WSA2 31 31 90 518 417 545 209 32 9/24/2004 IPERF 32 9/24/2004 IPERF 32 9/24/2004 IPERF 32 9/24/2004 IPERF 32 9/24/2004 IPERF 32 9/24/2004 IPERF 32 9/24/2004 IPERF VOD Latch Port TRO 1.0 BK-5 0.000 0 1.0 BK-5 0.000 0 Vlv Cmnt Date Run 11/1/2005 11/212005 Description VETCO GRAY MCA TUBING HANGER TIC CROSSOVER w/SCREEN INTAKE TANDEM SEAL SECTION GSB 3 DB AB/HSN PFSA CENTRILlFT MOTOR, 418 HP KMHFER 2610 /98 A-WELL 1 PUMP GAUGE MOTOR CENTRALIZER BAKER MODEL B1 FLANGED HOOK HANGER FOR D-SAND L2 D-SAND L2 LINER WINDOW ID 4.500 0.000 0.000 0.000 0.000 0.000 4.500 0.000 5.500 4.750 4.750 0.000 5010 5030 5057 5068 ZXP LINER TOP PACKER FOR B-SAND L 1 190-47 CASING SEAL BORE RECEPTACLE FOR B-SAND L 1 LEM HOOK HANGER FOR B-SANO L 1 B-SAND L 1 WINDOW Description HRD ZXP LINER TOP PACKER, RS PACKOFF SEAL NIPPLE, FLEXLOCK LINER HANGER 190-47 CASING SEAL BORE EXTENSION ID 5.500 4.750 3.958 5334 3397 SBE 9596 3518 SHOE Gemeral Notes Date Note 9/24/2004 TREE: ABB VETCO GRAY / HORZ /4-1/16" 5M (w/penetratorwire) TREE CAP CONNECTION: 9" OTIS 9/24/2004 TRI-LATEAL WELL: A, B & D SANDS . Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 E~ 166 1 E~166 WORKOVER/RECOMP Nabors 3S Sta rt: Rig Release: Rig Number: 11/13/2005 11/17/2005 Spud Date: 9/1/2004 End: 11/17/2005 Group: 11/13/2005 15:00 - 19:00 4.00 MOVE MOVE CMPL TN Prepare rig for move to 1 E-166. Scoped derrick down @ 1700 hrs. 19:00 - 20:00 1.00 MOVE !MOVE CMPL TN Move rig off of 1 E-170 and begin preparations for spotting up on 1 E-166. 20:00 - 00:00 4.00 MOVE MOVE . CMPL TN Continue spotting rig on 166. 11/14/2005 00:00 - 04:00 4.00 MOVE POSN DECaMP PMove rig over well and begin setting up secondary containment. Fire up boilers. Hook up all lines. - 05:30 1.50 MOVE SFTY DECOMP Warm up time w/pre-derrick raising safety meeting. 05:30 - 08:00 2.50 MOVE RURD DECOMP Hydraulic problems when raising derrick. Lowered back down for repairs. 08:00 - 11 :00 3.00 MOVE RURD DECOMP After repairs, raised derrick and scoped up. Hook up guide lines, raise windwalls. Accept rig @ 1100 hrs. 11/14/2005 11:00-12:00 1.00 WELLSR RURD DECOMP Rigged up lubrcator and check for pressure. 750 psi on tubing. Pulled 'I BPV. RD lubricator. Rigged up LRS pump truck for well kill. 12:00 - 17:00 5.00 WELLS1 KILL DECOMP Rigged up LRS pump truck for well kill. Pumped hot seawater 8.6 ppg w/3% KCL Pumped 290 bbls @ 3.25 BPM ending up @ 4.5 BPM. 1.00 WELlslUND Never established returns only gas. Shut down, tubing on vac. IA press '0' psi. Flushed lines out to tank, blew down with air to clear lines. RD LRS. 17:00 - 18:00 DECOMP Install BPV. Witness of BOP test by AOGCC waived - John Crisp. 18:00 - 20:00 2.00 WELLSJ NUND DECOMP Rig down hard line. Hard line frozen. Pull production tree. Install BOP. 20:00 - 00:00 4.00 WELLS ,NUND DECaMP Continue to install BOP. 11/15/2005 00:00 - 01 :00 1.00 WELCTL NUND DECOMP Continue to rig up BOP and function test rams. 01 :00 - 06:00 5.00 WELCTL BOPE DECOMP Perform BOP test. IA pressure = 750 PSI. Begin bleed dwn proceedures. Noticed that IA valve was shut and asked why? Opened 4.50 WElCJ Kill valve and pressure reading was 750 PSI. Begin bleed down proceedures. Pressure bled down to 250 PSI and will not bleed further. Call out more KWF and prepare to re-kill well. 06:00 - 10:30 DECOMP RU to IA pumped 4.5 BPM, pressure started at 470 psi. 10:30 - 11 :30 1.00 WELCT~ KILL DECOMP RU to IA pumped 4.5 BPM, pressure started at 470 psi. Pumped 200 additional BBLs down IA shut down and monitor pressure. 11 :30 - 16:00 4.50 WELCTL' KILL DECOMP IA pressured up to 400 psi bleed pressure on IA to tank farm to 0 psi. check two way check valve pressure and it was low and bleeding slowly. Bleed tubing down threw check valve and pulled to floor. Rigged up landing joint and control valve to hanger shut well in and monitor for 1.00 WELCT~ KILL pressure. 16:00 - 17:00 DECOMP IA pressure at 300 psi and tubing at 100 psi. Called for 290 more bbls of 8.6 brine and hot oil pump. We will attempt to kill the well down the tubing and up the IA if we can not get returns we will use hot oil to 7.00 WELCT~ KILL pump down the IA as we pump down the tubing with the rig. 17:00 - 00:00 DECaMP Wait on another load of 8.6 brine. LRS on loaction 11/16/2005 00:00 - 01 :00 1.00 WELCT[J KILL DECOMP Held pre-job safety meeting. Brine on loaction. PT equipment. 01 :00 - 04:00 3.00 WELCTi KILL DECOMP Pumped 100 bbls of 8.6 ppg w/3% KCL from pits down tubing. Starting tubing pressure 350psi. Started getting crude returns to tanks at 90 bbls. Pumped another 30 bbls, same results. Tubing on a vaccum. LRS started pumping brine down IA @ 5 bpm. Starting IA pressure 650psi. Check well at 130 bbls away. IA on vaccum, but after 15 mins, IA begins to blow gas, maybe 50 psi. Pump total of 180 bbls down tubing and 200 bbls down lA, with same results. 04:00 - 05:00 1.00 WELCTL KILL DECOMP Called town engineer for next game plan. Decide to call out another load of 290 bbls 8.6ppg brine with KCL. 05:00 - 09:00 4.00 WELCTL KILL DECOMP Waiting on another load of brine. 09:00 - 13:00 , 4.00 I WELCTï KILL DECOMP Bleed IA down to tanks 90 psi to 0 psi and monitor for returns. Shut in I 1 Printed: 12/6/2005 10:29:30 AM . . Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1E-166 1E-166 WORKOVER/RECOMP Nabors 3S Sta rt: Rig Release: Rig Number: 11/13/2005 11/17/2005 Spud Date: 9/1/2004 End: 11/17/2005 Group: 08:00 - 13:00 i IA to check for pressure build up. Pressure built to 51 psi in 1 hr and 45 min. Still waiting on brine to reach location Pull hanger free up wt. 75k pull to floor and clean penetrator. Annular closed with 500 psi. Filling hole with 5 bbls every 15 min. Begin testing cable and making splices. Cable tested, down hole gauge did not test confer with town (OK to run with out gauge) and continue to make splice. Cable tested after splice, and after connecting to penetrator. Land tubing after redressing hanger with new Orings and wiper seals. Down wt. 44K, up wt. 56K torque lockdowns and test. Had to pump additional 160 bbls of 8.6 ppg brine to rekill tubing, tubing on vaccum, monitor pressure for 1 hour, tubing still on vaccum. Still bleeding IA to open top tank, less than 10 psi on IA. Set BPV and secure well ND BOP Continue ND of BOP and test ESP cable. Cable tested OK. NU tree Pull BPV. Set test plug. Test tree to 5000 psi (Good). Tested ESP cable with tree installed all test good BHG still will not test. FP well with 45 bbls diesel down the tubing and 60 bbls down the IA both pressures where at 0 psi after pumping the dies!. 5.00 MOVE RURD MOVE Rig released @ 0800 am on 11/17/05 in the process ofrigging down and preparing to move. 13:00 - 13:30 0.50 WELCTL EQRP DECOMP 13:30 - 17:00 3.50 WELLS~ EQRP DECOMP 17:00 - 18:30 1.50 WELLS~ EQRP DECOMP 18:30 - 21:30 3.00 WELCTL KILL CMPL TN 21 :30 - 22:00 0.50 WELLSR PLGM CMPL TN 22:00 - 00:00 2.00. WELCTL NUND CMPL TN 11/17/2005 00:00 - 05:00 5.00· WELCTL NUND CMPL TN 05:00 - 08:00 3.00 WELLSR PLGM CMPL TN Printed: 12/6/2005 10:29:30 AM . Conoc~illips . Randy Thomas Kuparuk Drilling Team Leader Drilling & Wells P. O. Box 100360 Anchorage, AK 99510-0360 Phone: 907-265-6830 October 19, 2004 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West ih Avenue Suite 100 Anchorage, Alaska 99501 OCT I ~~ 2004 Subject: Well Completion Report for 1 E-166, 1 E-166L 1, 1 E-166L2 Dear Commissioner: ConocoPhillips Alaska, Inc. submits the attached Well Completion Report for the recent drilling operations of the Kuparuk well 1 E-166, 1 E-166L 1 and 1 E-166L2. If you have any questions regarding this matter, please contact me at 265-6830 or Steve McKeever at 265-6826. Sincerely, ~~~ R. Thomas Kuparuk Drilling Team Leader CPAI Drilling RT/skad OR\G\NAL I STATE OF ALASKA .. ALA A Oil AND GAS CONSERVATION COM"ION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1a. Well Status: Oil 0 Gas U GINJ 0 2. Operator Name: WINJ 0 WDSPL 0 Plugged 0 Abandoned 0 20AAC 25.105 No. of Completions _ ConocoPhillips Alaska, Inc. 3. Address: P. O. Box 100360, Anchorage, AK 99510-0360 4a. Location of Well (Governmental Section): Surface: 147' FNL, 640' FEL, Sec. 21, T11N, R10E, UM At Top Productive Horizon: 1534' FSL, 1276' FWL, Sec. 22, T11N, R10E, UM Total Depth: 1961' FNL, 1052' FWL, Sec. 27, T11N, R10E, UM 4b. Location of Well (State Base Plane Coordinates): Surface: x- 549890 ' y- TPI: x- 551837 y- Total Depth: x- 551644 - y- 18. Directional Survey: Yes 0 NoU 21. Logs Run: GRlRes 22. CASING SIZE WT. PER FT. 62.5# 45.5# 29.7# 12.6# GRADE H-40 L-80 L-80 L-80 20" x 34" 10.75" 7-5/8" 4.5" 26. ............. Date First Producti~ October 12, 2004 Date of Test Hours Tested 10/15/2004 Flow Tubing not available 27. 6 hours Casing Pressure not available , 5959440 5955854 5952359 ' Zone-4 Zone-4 5. Date Comp., Susp., ~ or Aband.: September 24, 2004 6. Date Spudded: September 1, 2004 7. Date TD Reached: September 11, 2004 ' 8. KB Elevation (It): 28' RKB 9. Plug Back Depth (MD + TVD): 9594' MD 13517' TVD 10. Total Depth (MD + TVD): . 9602' MD 13519' TVD ' Suspended 0 20AAC 25.110 Other_ 11 . Depth where SSSV set: none 19. Water Depth, if Offshore: NIA CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTH TVD TOP BOTTOM TOP BOTTOM 28' 108' 28' 108' 28' 3012' 28' 2393' 28' 6014' 28' 3502' 5302' 9596' 3391' 3518' WAG 0 feet MSL 41 Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water (attach separate sheet, if necessary). Submit core chips; if none, state "none". 23. Perforations open to Production (MD + TVD of Top and Bottom 24. Interval, Size and Number; if none, state "none"): slots in lower 'A' liner from: 6043'-6073' MD 3504'-3512' TVD 9352'-9561' MD 3512'-3517' TVD 6198'-6229' MD 3536'-3540' TVD 25. 6384'-6415' MD 3543'-3538' TVD 6539'-6629' MD 3519'-3508' TVD 7065'-7583' MD 3509'-3520' TVD 7955'-8372' MD 3529'-3523' TVD 8559'-9104' MD 3512'-3499' TVD Form 10-407 Revised 12/2003 Zone- 4 Test Period --> Calculated 24-Hour Rate -> NONE SIZE 4.5" 1b. Well Class: Development 0 Service 0 12. Pennit to Drill Number: Exploratory 0 Stratigraphic Test 0 204-1531 13. API Number: 50-029-23220-00 14. Well Name and Number: 1 E-166 15. Field/Pool(s): Kuparuk River Field West Sak Oil Pool 16. Property Designation: ADL 25651 & 25660 17. Land Use Penn it: ALK 469 & 470 20. Thickness of Permafrost: 1630' MD HOLE AMOUNT CEMENTING RECORD SIZE PULLED 42" 317sx ASI 13.5" 520 sx AS Lite, 181 sx DeepCrete 9-718" 320 sx DeepCrete 6.75" slotted liner TUBING RECORD DEPTH SET (MD) PACKER SET 4470' 5302' ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED n/a ~C-"-"'''O'' i vUh'. ~·'U: 11 i1 ~ ~ DllTE " ~ ~z.~ t ~ v~~ ' L-v'~~~ CHOKE SIZE 33 Bean OIL GRAVITY - API (corr) not available IGAS-Oll RATIO 617 PRODUCTION TEST Method of Operation (Flowing, gas lilt, etc.) Production shared with 1 E -166L 1 and 1 E -166L2 Production for OIL-BBL GAS-MCF WATER-BBL 1077 736 10 OIL-BBL GAS-MCF WATER-BBl 4185 2582 CORE DATA R ,'- r. f-!, ,b~~ \,co} OCT 1 H 2004 CornmiSS!CHl G~ CONTINUÈD ON REVERSE O R, I r:: \ t-.... f.^, L .. .,,, ; ',' '..0 it\.../ ¡ i" ¡ "\ ~ AæJ)frl~ 28. GEOLOGIC MARKERS . 29. . FORMATION TESTS NAME MD TVD Include and briefly summarize test results. List intervals tested, and attach detailed supporting data as necessary. If no tests were conducted, state "None". 1 E-166 West Sak A2 West Sak A2 6040' 7060' 3507' 3508' N/A 30. LIST OF ATTACHMENTS Summary of Daily Operations, Directional Survey 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Steve McKeever @ 265-6826 Printed Na~ Randv Tho~as Signature \ <..~ ~ Title: ..--'Phone KUDaruk DrillinQ Team Leader Date WI"? (00/ Prepared by Sharon Allsup-Drake INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1a: Classification of Service wells: Gas injection, water injection, Water-Alternating-Gas Injection, salt water disposal, water supply for injection, observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 4b: TPI (Top of Producing Interval). Item 8: the Kelly Bushing elevation in feet abour mean low low water. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). Item 20: True vertical thickness. Item 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, Other (explain). Item 27: If no cores taken, indicate "none". Item 29: List all test information. If none, state "None". ORIGINAL Form 10-407 Revised 2/2003 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1E-166 1 E-166 ROT - DRILLING n1334@ppco.com Doyon 141 Start: 8/31/2004 Rig Release: 9/24/2004 Rig Number: Spud Date: 9/1/2004 End: 9/24/2004 Group: Slip and cut 104' of drlg line and serviced top drive MU 13 1/2" BHA #1, Bit, bit sub and 1-NM flex DC, tagged ice in conductor at 55' Flooded conductor checking for leaks Repaired Willis choke and Demco valve on standpipe Re-Ieveled sub over hole Cleaned out inside conductor from 55' to 108' Drilled 13 1/2" hole from 108' to 310' (202') ART 2 Hrs POOH MU 13 1/2" BHA #2 with MWD, oriented and uploaded same, RIH to 310' RU HES slickline unit for Gyro Drilled 13 1/2" hole per directional plan from 310' to 1,390' MD/1 ,327' TVD (1,080'), ART 2.4 hrs, AST 4.9 hrs, 20-35K wob, 50 rpm's, 450-530 gpm, 1,200 psi -1,700 psi, rot wt 90K, up wt 95K, dn wt 85K, torque Off btm -0-, on btm 4K ft-Ibs, took Gyro survey's for check shots at 375' and 560' and ck ok, RD slickline at 940' 5.25 DRILL DRLG SURFAC Drilled 13 1/2" hole per directional plan from 1,390' to 1,947' MD/1 ,704' TVD, (557'), ART 1.6 hrs, AST 2.0 hrs, 10-30K wob, 50 rpm's, 550 gpm, off btm pressure 1,400 psi, on btm 1,750 psi, off btm torque 2.5K ft-lbs, on btm 4.5K ft-Ibs, rot wt 92K, up wt 100K, dn wt 85K, pumped 1 weighted hi vis sweep and had 20% increase in cuttings back Pumped out of hole from 1,947' to HWDP at 1,113', pumped out at 500 gpm at 1,400 psi POOH standing back HWDP and BHA #2, drained 1.8 deg bend mud motor and LD same MU BHA #3 with 1.3 deg bend motor jetted for 700 gpm, oriented MWD and RIH with HWDPthen MU 131/2" ghost reamer, RIH to 1,119' RIH to 1,861', washed 86' to btm at 1,947' with no problems Circ btms up after trip, circ out a large amount of clay and sand Drilled 13 1/2" hole per directional plan from 1,947' to 3,020' MD/2,398' TVD, (1,073'), (Csg Pt), ART 4.2 hrs, AST.6 hrs, 10-30K wob, 100 rpm's, 700 gpm, off btm pressure 2,300 psi, on btm 2,400 psi, off btm torque 7K ft-Ibs, on btm 9K ft-Ibs, rot wt 104K, up wt 132K, dn wt 85K, pumped weighted hi vis sweep on last std, no gas hydrates in surface hole ... Note"' After conferring with town the new surface TD was picked @ 2400' TVD +1- 8/31/2004 12:00 - 14:30 2.50 MOVE DMOB MOVE 14:30 - 17:00 2.50 MOVE MOVE MOVE 17:00 - 18:00 1.00 MOVE RURD MOVE 18:00 - 20:00 2.00 WELCTL NUND SURFAC 20:00 - 22:00 2.00 DRILL OTHR SURFAC 22:00 - 00:00 2.00 DRILL PULD SURFAC 9/1/2004 00:00 - 01 :45 1.75 DRILL PULD RIGUP 01:45 - 02:15 0.50 WELCTL BOPE RIGUP 02:15 - 03:45 1.50 RIGMNT RSRV RIGUP 03:45 - 04:30 0.75 DRILL PULD SURFAC 04:30 - 05:00 0.50 DRILL CIRC SURFAC 05:00 - 06:15 1.25 RIGMNT RGRP SURFAC 06:15 - 07:00 0.75 RIGMNT OTHR SURFAC 07:00 - 07:30 0.50 DRILL CIRC SURFAC 07:30 - 10:15 2.75 DRILL DRLG SURFAC 10:15 - 10:45 0.50 DRILL TRIP SURFAC 10:45 - 13:00 2.25 DRILL PULD SURFAC 13:00 - 13:30 0.50 LOG RURD SURFAC 13:30 - 00:00 10.50 DRILL DRLG SURFAC 9/212004 00:00 - 05:15 05:15 - 06:15 1.00 DRILL TRIP SURFAC 06:15 - 08:45 2.50 DRILL PULD SURFAC 08:45 - 10:15 1.50 DRILL PULD SURFAC 10:15 - 11 :00 0.75 DRILL TRIP SURFAC 11 :00 - 12:00 1.00 DRILL CIRC SURFAC 12:00 - 19:00 7.00 DRILL DRLG SURFAC Rig down and moved rig off 1 E-126 Spot sub, rig complex's, rock washer and pipe sheds on 1 E-166, moved rig 1,080' from 1E-126to 1E-166 Finished rigging up service lines and completed rig acceptance check list ACCEPTED RIG @ 18:00 hrs 8/31/04 NU 21 1/4" 2M diverter and 16" line and began mixing spud mud Loaded pipe shed with 5" DP & HWDP, continued mixing spud mud and changed out saver sub on top drive PU and stood back 16 stds of 5" DP Fin PU & standing back 21 stds of 5" DP, PU & Stood back 10 stds of 5" HWDP and jars Function tested diverter, John Spaulding WAOGCC waived witnessing test Printed: 10/11/2004 3:38:27 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1E-166 1 E-166 ROT - DRILLING n1334@ppco.com Doyon 141 Start: 8/31/2004 Rig Release: 9/24/2004 Rig Number: Spud Date: 9/1/2004 End: 9/24/2004 Group: 91212004 9/3/2004 Fin circ out weighted hi vis sweep, circ at 700 gpm at 2,200 psi and 100 rpm's, had 35% increase in cuttings back from sweep Monitored well-static Backreamed out of hole at drlg rate from 3,020' to 1,119', at Ghost reamer and BHA #3, LD ghost reamer, no problems backreaming out POOH wet with HWDP to 200', stood back HWDP and Cleared rig floor, RU to LD BHA #3 LD BHA #3,3-63/4" NMCSDP, short NMDC, stab, MWD, drained and LD motor, cleared rig floor Began RU to run 10 3/4" csg when hydraulics went out on top drive Trouble shoot loss of hyd. power to top drive, changed out relief valve and hyd. pump to top drive, changed out lower set of 5" pipe rams on BOP's to 7 5/8" csg rams Fin RU Doyons 10 3/4" csg equipment with Franks fill up tool Held PJSM with rig crew and tong operator on running of csg MU 103/4" float shoe, 2 jts 103/4' 45.5# L-80, BTC csg, fit collar, thread locked conn below FC and circ thru shoe track, RIH with 103/4" csg to 1,003' Circ btms up at 1,003', circ at 2 bpm at 325 psi, st wt up 73K, dn wt 60K, circ out thick mud with sand and clay RIH with 103/4' csg to 2,007' Circ btms up at 2,007', circ at 2 bpm at 325 psi, st up wt 118K, dn wt 86K RIH with 103/4" csg, MU hanger and landed csg with float shoe at 3,012' MD/2,393' TVD, float collar at 2,925', no problems RIH, Ran a total of 20 jts (798') of 40.5# L-80, BTC csg above shoe track and a total 53 jts (2,177') of 45.5#, L-80, BTC csg including shoe track, total float equip, csg and hanger, 2,982', ran 52 bow spring centralizers and 21 stop rings per well plan Circ btms up thru fill up tool and began cond mud for cementing, staged pump rate up to 6 bpm at 300 psi, st wt up 155K, dn wt 100K RD Franks fill up tool and MU Dowell's cement head Cont to circ and cond mud for cementing, circ at 6 bpm at 325 psi, reciprocating pipe with 160K up wt and 105K dn wt, circ and cond mud to 9.4 ppg and lower PVIYP to <15 Fin circ and conditioning mud for cementing, final MW in & out, 9.4 ppg, 44 vis, 12 PV and 15 YP, circ at 6 bpm at 325 psi, st wt up 160K dn wt 105K, held PJSM with Dowell, APC vac truck drivers and rig crew on cementing operations while circ. 2.00 CEMENì PUMP SURFAC Turned over to Dowell and cemented 103/4" csg, pumped 10 bbls of CW 100 at 8.3 ppg, pressure tested lines to 3,500 psi, then pumped an additional 40 bbls of CW 100 (50 bbls total), then pumped 50 bbls of 10.5 ppg mudpush,dropped btm plug, began mixing and pumping Arcticset lead slurry, pumped 412 bbls (520 sxs) of lead cement at 10.7 ppg and 4.45 yield with additives, ave 6 bpm at 110 psi, followed with 80.5 bbls (181 sxs) of DeepCrete tail cmt at 12.0 ppg and 2.48 yield with add., ave 5.5 bpm at 180 psi, reciprocated csg and had full returns, shut down and dropped top plug 1.00 CEMENT DISP SURFAC Dowell pumped 20 bbls fresh water then turned over to rig and rig displaced cement with 262 bbls of 9.4 ppg mud, displaced cmt at 6 bpm, initial circ pressure 350 psi, max pressure 700 psi, slowed rate to 3.5 bpm and bumped plug on calc displacement, pressured up to 1,400 psi, checked floats and held, CIP @ 03:20 hrs, had full returns during 19:00 - 19:30 0.50 DRILL CIRC SURFAC 19:30 - 19:45 0.25 DRILL OBSV SURFAC 19:45 - 22:30 2.75 DRILL REAM SURFAC 22:30 - 00:00 1.50 DRILL TRIP SURFAC 00:00 - 01 :45 1.75 DRILL PULD SURFAC 01 :45 - 02:30 0.75 CASE RURD SURFAC 02:30 - 12:00 9.50 RIGMNT RGRP SURFAC 12:00 - 12:45 0.75 CASE RURD SURFAC 12:45 - 13:00 0.25 CASE SFTY SURFAC 13:00 - 15:45 2.75 CASE RUNC SURFAC 15:45 - 16:15 0.50 CASE CIRC SURFAC 16:15 - 17:30 1.25 CASE RUNC SURFAC 17:30 - 18:45 1.25 CASE CIRC SURFAC 18:45 - 20:15 1.50 CASE RUNC SURFAC 20:15 - 21:30 1.25 CEMENTCIRC SURFAC 21:30-22:15 0.75 CEMENTRURD SURFAC 22:15 - 00:00 1.75 CEMENì CIRC SURFAC 9/4/2004 00:00 - 00:30 0.50 CEMENì CIRC SURFAC 00:30 - 02:30 02:30 - 03:30 Printed: 10/11/2004 3:38:27 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1E-166 1 E-166 ROT - DRILLING n 1334@ ppco.com Doyon 141 Start: 8/31/2004 Rig Release: 9/24/2004 Rig Number: Spud Date: 9/1/2004 End: 9/24/2004 Group: job and had 110 bbls of 10.7 ppg cmt back to surface, reciprocated csg till 02:45 hrs, 70 bbls into displacement, approx 275 bbls lead cement out of shoe RU and tested 10 3/4" csg to 2,500 psi for 30 min, good test RD cement head, LD landing jt and cleared rig floor ND 21 1/4" diverter, starting head and 16" diverter line NU & Orient Vetco Gray MB 222 Wellhead, Tested seals to 5,000 psi for 15 min. NU 133/8" BOP stack NOTE: Had 4 bbl spill at injection skid, mud was spilled into secondary containment and immediately cleaned up RU to test BOPE Began to test BOP's and door seal on blind rams leaked, re-tightened and continued to leak, removed choke line hose and changed out door seal on off drillers side, rigged back up and refilled choke manifold and stack 4.75 WELCTL BOPE SURFAC Tested BOPE, choke manifold, 4" and 5" floor valves, rams including 7 5/8" csg rams to 250 psi low and 3,000 psi high, annular to 250 psi low and 1,500 psi high John Spaulding W/AOGCC waived witnessing of test Installed wear bushing Began changing over top drive to 4" XT-39 DP, changed out saver sub Finished changing over top drive to 4" XT-39 DP, changed pipe grabbers and pipe guide PU 54 jts (18 std) of 4" XT-39 DP from pipe shed and RIH to 1,670' Circ thru 4" DP and displaced out 9.4 ppg mud in hole to re-condtioned 9.0 ppg LSND mud POOH standing back 4" DP PU an additional 54 jts (18 std) of 4" XT-39 DP from pipe shed and RIH to 1,670' POOH standing back 4" DP RU and LD 2 stds of 5" DP from derrick MU 9 7/8" BHA #4 with 1.1 deg bend mud motor, and MWD, oriented and uploaded MWD, RIH with HWDP and jars, MU ghost reamer RIH to 1,110' RIH with BHA #4 from 1,110' to 2,871' with 5" DP, changed over to 4" DP Circ and tested MWD, staged pump rate to 510 gpm at 1,325 psi and tool ck ok Fin displacing out 9.4 ppg mud with re-conditioned 9.0 ppg LSND mud, circ at 530 gpm at 1,500 psi, rot wt 98K, up wt 130K, dn wt 78K Drilled out plugs, float collar at 2,925', shoe jts and float shoe at 3,012', drilled 20' of new formation to 3,040' MD/2,411' TVD, drilled with 5K wob, 50 rpm's, 530 gpm at 1,500 psi Circ hole clean evening MW in and out at 9.0 ppg for LOT, circ at 530 gpm at 1 ,500 psi RU and performed LOT to 13.4 ppg EMW, 550 psi, 9.0 ppg mud at 2,393' TVD Drilled 9 7/8" hole per directional plan from 3,040' to 3,809' MD/2,870' TVD, (769'), ART 2.1 hrs, AST 2.6 hrs, 5-15K wob, 100 rpm's, 155 spm, 657 gpm, off btm pressure 2,250 psi, on btm 2,450 psi, off btm torque 5-12K ft-Ibs, on btm 7-10K ft Ibs, rot wt 103K, up wt 145K, dn wt 79K, clean hole ECD with 9.0 ppg MW = 9.4 ppg, ECD with 9.0 ppg MW 9/4/2004 02:30 - 03:30 1.00 CEMENT DISP SURFAC 03:30 - 04:15 0.75 CASE DEQT SURFAC 04:15 - 05:15 1.00 CASE RURD SURFAC 05:15 - 09:00 3.75 WELCTL NUND SURFAC 09:00 - 10:30 1.50 WELCTL NUND SURFAC 10:30 . 13:30 3.00 WELCTL NUND SURFAC 13:30 - 14:45 1.25 WELCTL BOPE SURFAC 14:45 - 17:30 2.75 WELCTL EQRP SURFAC 17:30 - 22:15 22:15 - 22:45 0.50 DRILL RIRD SURFAC 22:45 - 00:00 1.25 DRILL RIRD SURFAC 9/5/2004 00:00 - 01 :30 1.50 DRILL RIRD SURFAC 01 :30 - 03:45 2.25 DRILL PULD SURFAC 03:45 . 04:30 0.75 DRILL CIRC SURFAC 04:30 - 05:15 0.75 DRILL TRIP SURFAC 05:15 - 07:00 1.75 DRILL PULD SURFAC 07:00 - 07:30 0.50 DRILL TRIP SURFAC 07:30 - 08:00 0.50 DRILL PULD SURFAC 08:00 - 12:00 4.00 DRILL PULD SURFAC 12:00·13:00 1.00 DRILL TRIP SURFAC 13:00 - 13:15 0.25 DRILL DEQT SURFAC 13:15 - 13:45 0.50 DRILL CIRC SURFAC 13:45·15:00 1.25 CEMENT DSHO SURFAC 15:00 - 15:30 0.50 DRILL CIRC SURFAC 15:30 - 16:15 0.75 DRILL LOT SURFAC 16:15 - 00:00 7.75 DRILL DRLG INTRM1 Printed: 10/11/2004 3:38:27 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 E-166 1 E-166 ROT - DRILLING n1334@ppco.com Doyon 141 Start: 8/31/2004 Rig Release: 9/24/2004 Rig Number: Spud Date: 9/1/2004 End: 9/24/2004 Group: 9/5/2004 16:15 - 00:00 7.75 DRILL DRL.G INTRM1 while drlg ave 9.65 ppg 9/6/2004 00:00 - 12:00 12.00 DRILL DRL.G INTRM1 Drilled 9 7/8" hole per directional plan from 3,809' to 5,023' MD/3,331' TVD, (1,214') ART 5.2 hrs, AST 2.5 hrs, 5-30K wob, 100 rpm's, 155 spm, 655 gpm, off btm pressure 2,700 psi, on btm 3,000 psi, off btm torque 5-11K ft-Ibs, on btm 7-10K ft-Ibs, rot wt 98K, up wt 145K, dn wt 76K, 9.2 ppg MW, ave ECD 10.4 ppg, max ECD 10.9 ppg, pumped weighted hi vis sweep at 4,276' and had 30% increase in cuttings Est Top of West Sak "D" at 4,798' MD/3,280' TVD, No BGG was seen until drilling "D" sand, Max gas from "D" sand 1 ,500 units 12:00 - 23:00 11.00 DRILL DRl.G INTRM1 Drilled 97/8" hole per directional plan from 5,023' to 6,020' MD/3,503' TVD, (997') ART 5.7 hrs, AST 1.8 hrs, 5-30K wob, 100 rpm's, 155 spm, 655 gpm, off btm pressure 3,150 psi, on btm 3,300 psi, off btm torque 9K ft-Ibs, on btm 11K ft-Ibs, rot wt 94K, up wt 135K, dn wt 72K, 9.2 ppg MW, ave ECD 10.4 ppg, max ECD 10.7 ppg, pumped 1-weighted hi vis sweep at 5,180' with 5% increase in cuttings and 1 at 5,985' with 10% increase in cuttings Est Top of West Sak "B" at 5,067' MD/3,343' TVD, Ave BGG while drilling 300-400 units, Max gas from "B" sand 2,700 units 23:00 - 00:00 1.00 DRILL REAM INTRM1 Backreamed out of hole at drilling rate from 6,020' to 5,494' with no problems 9/7/2004 00:00 - 03:30 3.50 DRILL REAM INTRM1 Backreamed out of hole from 5,494 to 4,185' at drlg rate till ghost reamer was at csg shoe, backreamed at 100 rpm's, 655 gpm at 3,000 psi, with no problems, pumped out of hole to csg shoe at 3,012' 03:30 - 04:15 0.75 DRILL CIRC INTRM1 Pumped weighted hi vis sweep and circ hole clean at 3,012' (csg shoe), circ at 575 gpm at 1,700 psi and 40 rpm's, had 5% increase in cuttings from sweep, circ 3X btms and clean at shakers, rot wt 95K, up wt 11 OK, dn wt 95K 04:15 - 04:30 0.25 DRILL OBSV INTRM1 Monitored well-static 04:30 - 05:00 0.50 DRILL TRIP INTRM1 POOH wet from 3,012' to 2,875', hole taking proper fill, pumped dry job and changed over handling tools to 5" DP 05:00 - 06:30 1.50 DRILL PULD INTRM1 POOH LD 56 jts of 5" DP to 1,110' (BHA) 06:30 - 09:30 3.00 DRILL PULD INTRM1 POOH LD, 5" HWDP, jars and ghost reamer, downloaded MWD and LD BHA #4 09:30 - 10:00 0.50 DRILL PULD INTRM1 Pulled wear bushing, cleared rig floor 10:00 - 11:45 1.75 CASE RURD INTRM1 RU Doyon's 7 5/8" csg handling equipment with Franks fill up tool 11 :45 - 12:00 0.25 CASE SFTY INTRM1 Held PJSM on running of 7 5/8" csg 12:00 - 17:00 5.00 CASE RUNC INTRM1 RIH with 7 5/8",29.7#, L-80, BTC-M csg to 2,100', MU 75/8" Float shoe, 2 jts csg, float collar, thread locked btm 3 conn's and circ thru float equip and ck ok, RIH with 47 add. jts along with pup jts for spacing out to 2,100' 17:00 - 18:00 1.00 CASE CIRG INTRM1 Circ a csg cap at 2,100', staged pump rate up to 3 1/2 bpm at 275 psi, circ out thick mud, st wt up 124K, dn wt 47K 18:00 - 19:30 1.50 CASE RUNC INTRM1 RIH with 7 518" csg from 2,100' to 2,984 19:30 - 20:00 0.50 CASE CIRG INTRM1 Circ a csg cap at 10 3/4" csg shoe, staged pump rate up to 4 bpm at 350 psi, st up wt 156K, dn wt 45K 20:00 - 23:30 3.50 CASE RUNC INTRM1 Fin RIH with 7 5/8" csg, RIH to btm with no problems in open hole, MU hanger and landed 7 5/8" csg at 6,014' MD/3,502' TVD with float collar at 5,927', ran a total of 140 jts 7 5/8", 29.7#, L-BO BTC-M csg with 3-pup jts and hanger (Total 5,987') 23:30 - 00:00 0.50 CASE CIRG INTRM1 Began circ and conditioning mud for cementing, circ thru Franks fill up tool, staged pump rate up to 5 bpm at 525 psi, st wt up 175K, dn wt 77K 9/8/2004 00:00 - 00:30 0.50 CEMENTCIRG INTRM1 Fin circ btms up thru Franks fill-up tool while conditioning mud, staged pump rate to 6 bpm at 550 psi, st wt up 175K, dn wt 77K Printed: 10/11/2004 3:38:27 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 E-166 1 E-166 ROT - DRILLING n1334@ppco.com Doyon 141 Start: 8/31/2004 Rig Release: 9/24/2004 Rig Number: Spud Date: 9/1/2004 End: 9/24/2004 Group: 9/812004 00:30 - 01 :00 0.50 CEMENT RURD INTRM1 LD Franks fill up tool and MU Dowell's cement head 01:00-03:15 2.25 CEMENTCIRC INTRM1 Cont to circ and cond mud for cementing, circ at 6 bpm at 500 psi, st wt up 190K, dn 80K, conditioned mud from 9.3 ppg, 58 vis, 21YP, 18 PV to 9.2 ppg, 50 vis, 17 YP, 15 PV, Held PJSM with Dowell, APC vac truck drivers and rig crew on cementing csg while circ 03:15 - 04:15 1.00 CEMENT PUMP INTRM1 Dowell pumped 10 bbls CW 100 at 8.3 ppg, pressure tested lines to 3,500 psi, then pumped 20 add. bbls of CW 100, pumped 50 bbls of MudPush at 10.5 ppg, dropped btm plug then pumped 128 bbls, (320 sxs) of DeepCrete cmt at 12.5 ppg, 2.26 yield with additives, ave 6 bpm at 250 psi, reciprocated pipe with full returns, shut down, washed up and dropped btm plug 04:15 - 05:15 1.00 CEMENT DISP INTRM1 Rig displaced cement with 8.8 ppg OBM, bumped plug after pumping 271.3 bbls OBM (95% pump eff.) (Calc Disp 272.5 bbls) ave 7 bpm while displacing cmt, max pressure 1,000 psi, slowed pump rate to 4 bpm with 15 bbls left to pump and bumped plug to 1,500 psi, ck floats and held CIP at 05:00 hrs, reciprocated pipe until 50 bbls of cement was around shoe when hole began getting tight and stopped reciprocating, est TOC @ 3,600' 05:15 - 06:00 0.75 CEMENTRURD INTRM1 RD cement head and LD landing jt 06:00 - 07:30 1.50 WELCTL EQRP INTRM1 Installed 7 5/8" pack-off and tested to 5,000 psi for 15 min 07:30 - 08:00 0.50 DRILL PULD INTRM1 Installed wear bushing 08:00 - 08:45 0.75 DRILL RIRD INTRM1 RD 7 5/8 csg equipment, elevator bales and cleared rig floor 08:45 - 10:45 2.00 RIGMNT RSRV INTRM1 Slip & cut 65' of drlg line and serviced top drive. R/U hardline on 10-3/4" x 7-5/8" annulus. PTto 1,500 psi, OK. Pump 15 bbls water @ 1,100 psi 2 BPM. SID 800 psi. 10:45 - 12:30 1.75 DRILL PULD INTRM1 PU and stood back in derrick 9 stds 4" push pipe 12:30 - 14:15 1.75 DRILL PULD INTRM1 MU BHA #5, 4 3/4" mud motor with 1.2 deg bend, MWD, LWD and PWD, oriented and uploaded MWD, RIH with BHA #5 to 256' 14:15 - 16:30 2.25 DRILL PULD INTRM1 RIH with BHA #5 PU 4" XT-39 DP from pipe shed, RIH to 3,030' 16:30 - 17:00 0.50 DRILL DEQT INTRM1 Shallow tested MWD at 3,030', 300 gpm at 1,480 psi and ck ok, st wt up 75K, dn wt 65K 17:00 - 19:30 2.50 DRILL PULD INTRM1 Cont to RIH with BHA #5 PU 4" DP from pipe shed, RIH to 5,486', PU a total of 186', RIH from 5,486' to 5,926' from derrick and tagged up on plugs above float collar at 5,925' 19:30 - 20:00 0.50 DRILL CIRC INTRM1 Circ btms up for csg test evening MW in & out at 8.8 ppg, 300 gpm at 1,900 psi, st wt up 99K, dn wt 69K 20:00 - 21 :00 1.00 CASE DEQT INTRM1 RU and tested 7 5/8" csg to 2,500 psi for 30 min 21 :00 - 22:15 1.25 CEMENT DSHO INTRM1 Drilled out cmt plugs, float collar at 5,925', soft cement inside shoe track, float collar at 6,014' then drilled 20' of new formation from 6,020' to 6,040' MDI 3,503' TVD, ADT .1 hrs,4-6K wob, 40-60 rpm's, 300 gpm at 2,100 psi, rot wt 80K, up wt 105K, dn wt 67K 22:15 - 23:00 0.75 DRILL CIRC INTRM1 Circ hole clean for LOT, circ at 300 gpm at 1,850 psi 23:00 - 00:00 1.00 DRILL FIT INTRM1 RU to perform LOT, pressured up on well to 1,300 psi and shut down for FIT, at 1,300 psi, 8.8 ppg mud at 3,502' = 15.9 ppg EMW FIT 9/9/2004 00:00 - 02:30 2.50 DRILL DRLG PROD Drilled 63/4" hole from 6,040' to 6,236' MD/3,547' TVD, (196'), ART.6 hrs, AST .7 hrs, 10K wob, 80 rpm's, 296 gpm, off btm pressure 1,850 psi, on btm 2,000 psi, off btm torque 3K ft-Ibs, on btm 4K, rot wt 82K, up wt 108K, dn wt 68K NOTE: Flushed 7 5/8" x 10 3/4" annulus with 150 bbls fresh water then freeze protected with 100 bbls diesel 02:30 - 02:45 0.25 DRILL CIRC PROD Circ hole to est cleanhole ECD, with 8.8 ppg OBM cleanhole ECD was 10.2 ppg NOTE: While circ, determined internal scribe line correction was not Printed: 10/11/2004 3:38:27 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 E-166 1 E-166 ROT - DRILLING n1334@ppco.com Doyon 141 Start: Rig Release: Rig Number: 8/31/2004 9/24/2004 Spud Date: 9/1/2004 End: 9/24/2004 Group: 9/912004 02:30 - 02:45 0.25 DRILL CIRC PROD made in the MWD tool, scribe line correction was to be 94 deg. causing well to get off directional plan. To drill ahead we would cross 1 E-35 hard line and decision was made to shut in well and set tbg plug in well 1 E-35 before drlg ahead 02:45 - 03:00 0.25 DRILL TRIP PROD POOH from 6,236' to 6,014' to 7 5/8" csg shoe 03:00 - 12:00 9.00 WAlTON EQIP PROD Called out HES slickline, worked pipe and circ often inside csg while W.O. slickline, production shut down injection on 1 E-35 well and HES Slickline RI H and set pi ug in tbg at 11,114' 12:00 - 12:15 0.25 DRILL TRIP PROD RIH from 6,014', washed 96' to btm at 6,236' with no problems 12:15 - 18:00 5.75 DRILL DRLG PROD Directionally drilled 6 3/4" hole from 6,236' to 6,701' MDI 3,504' (465') ART -0-, AST 3.8 hrs, 4-15K wob, -0- rpm's, 75 spm, 318 gpm, off btm pressure 2,225 psi, on btm 2,400 psi, off btm torque 4K, on btm 6K ft-Ibs, rot wt 80K, up wt 115K, dn wt 55K, 8.8 ppg OBM, ECD while sliding 9.9 ppg 18:00 - 19:00 1.00 DRILL CIRC PROD Circ hole evaluating geological and directional options, circ at 318 gpm at 2,225 psi, found to have drilled out the top of zone, decision was made with town to drill back into zone and continue drilling, clean hole ECD while circ was 10.2 ppg with 8.8 ppg OBM 19:00 - 00:00 5.00 DRILL DRLG PROD Directionally drilled 6 3/4" hole from 6,701' to 7,134' MD/3,511' (433') ART 1 hr, AST 1.9 hrs, 2-5K wob, 100-120 rpm's, 75 spm, 318 gpm, off btm pressure 2,250 psi, on btm 2,400 psi, off btm torque 4K, on btm 5K ft-Ibs, rot wt 75K, up wt 115K, dn wt 60K, 8.9 ppg OBM, Ave ECD 10.6 ppg 9/10/2004 00:00 - 12:00 12.00 DRILL DRLG PROD Directionally drilled 6 3/4" hole from 7,134' to 8,103' MD/3,536' TVD, (969') ART 3.6 hrs, AST 4.1 hrs, 2-15K wob, 120 rpm's, 318 gpm, off btm pressure 2,400 psi, on btm 2,500 psi, off btm torque 5K ft-Ibs, on btm 5.5K ft-Ibs, rot wt 80K, up wt 115K, dn wt 56K, 8.8 ppg OBM, ave ECD 10.4 ppg, max ECD 10.8 ppg, ave BGG 75 units, max gas 450 units 12:00 - 18:00 6.00 DRILL DRLG PROD Drilled from 8,103' to 8,680' MD/3,501' TVD, (577') ART 3.1 hrs, AST .8 hr, 2-15K wob, 120 rpm's, 318 gpm, off btm pressure 2,475 psi, on btm 2,575 psi, off btm torque 6K ft-Ibs, on btm 6K ft-Ibs, rot wt 80K, up wt 123K, dn wt 46K, 8.9 ppg OBM, ave ECD 10.7 ppg, max ECD 11.1 ppg, ave BGG 50 units, max gas 200, pumped wt'd hi vis sweep at 8,640' and had 25% increase in cuttings back from sweep 18:00 - 19:30 1.50 DRILL CIRC PROD Troubleshoot MWD not decoding, checked mud pumps screens and pulsation dampners and slowed data rate on MWD and tool ck'd ok, problem occured before and after pumping wt'd sweep 19:30 - 00:00 4.50 DRILL DRLG PROD Drilled from 8,680' to 9,032' MD/3,497' TVD, (352') ART 1.8 hrs, AST 1 hr, 2-6K wob, 120 rpm's, 318 gpm, off btm pressure 2,550 psi, on btm 2,675 psi, off btm torque 6K ft-Ibs, on btm 6K ft-Ibs, rot wt 80K, up wt 117K, dn wt 57K, 8.8 ppg OBM, ave ECD 10.9 ppg, max ECD 11.1 ppg, aye BGG 30 units, max gas 100 units, began PU 4" pushpipe at 8,941' 9/11/2004 00:00 - 08:45 8.75 DRILL DRLG PROD Drilled 6 3/4" hole from 9,032' to 9,602' MD/3,518' TVD, (570') (T.D.) ART 4.5 hrs, AST 1 hr, 2-5K wob, 120 rpm's, 318 gpm, off btm pressure 2,825 psi, on btm 3,000 psi, off btm torque 6K ft-Ibs, on btm 6K ft-Ibs, rot wt 95K, up wt 131 K, dn wt 74K, 8.8 ppg OBM, ave ECD 10.9 ppg, max ECD 11.1 ppg, ave BGG 50 units, max gas 100 units, pumped weighted hi vis sweep on last std 08:45 - 09:30 0.75 DRILL CIRC PROD Circ weighted hi vis sweep out of hole, had 15% increase in cuttings back from sweep, circ at 318 gpm, 2,825 psi at 120 rpm's 09:30 - 09:45 0.25 DRILL OBSV PROD Monitored well-static 09:45 - 16:00 6.25 DRILL REAM PROD Backreamed out of hole at drlg rate from 9,602' to 5,950', (Csg Shoe) Printed: 10/11/2004 3:38:27 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 E-166 1 E-166 ROT - DRILLING n1334@ppco.com Doyon 141 Start: 8/31/2004 Rig Release: 9/24/2004 Rig Number: Spud Date: 9/1/2004 End: 9/24/2004 Group: 9/11/2004 09:45 - 16:00 6.25 DRILL REAM PROD circ at 318 gm, 100-120 rpm's, initial circ pressure 2,825 psi, final circ pressure 2,375 psi, no problems backreaming out 16:00 - 17:30 1.50 DRILL CIRC PROD Pumped weighted hi vis sweep and circ hole clean at 5,950', circ at 318 gpm at 2,000 psi, had 10% increase in cuttings back from sweep, circ 1.5x btms up and clean at shakers, rot wt 79K, up wt 113K, dn wt 56K, 5.5K ft-Ibs torque 17:30 - 18:00 0.50 DRILL OBSV PROD Monitored well-static, dropped 1 7/8" rabbit and pumped dry job 18:00 - 21 :30 3.50 DRILL TRIP PROD POOH from 5,950' to BHA #5 at 256', SLM, no corr, retrieved rabbit 21 :30 - 23:30 2.00 DRILL PULD PROD POOH and stood back HWDP and jars, downloaded MWD, LD MWD and motor, cleaned rig floor 23:30 - 00:00 0.50 CASE RURD CMPL TN RU to run 4 1/2" liner 9/12/2004 00:00 - 00:15 0.25 CASE SFTY CMPL TN Held PJSM with rig crew on running liner 00:15 - 04:45 4.50 CASE PULR CMPL TN PU and ran 41/2" liner per well program, ran 4 1/2" ROT silver bullet guide shoe with no float, 125 jts, (4,237') of 41/2" 12.6#, L-80, DWC liner, placed blank liners across shale sections per geology, ran 76 jts (2,360') of blank liner and 49 jts (1,873') of slotted liner, ran 1- 4 1/2' x 6 1/4" spiralglide centralizer 1/jt to csg shoe (105 total) ran 15 restrictor packers with 30 spacer rings placed on blank liner to isolate shale sections per geology. 04:45 - 06:00 1.25 CASE PULR CMPL TN MU Baker 190-47 csg seal bore ext, 5 1/2" x 75/8" Flexlock liner hanger, "RS" pack-off seal nipple and "HRD" ZXP liner top packer and RIH to 4,298' 06:00 - 09:00 3.00 CASE RUNL CMPL TN RIH with 41/2" Liner on 5' DP to 5,900', had to screw into each std to keep from running over 09:00 - 09:15 0.25 CASE CIRC CMPL TN Circ a DP cap at 7 5/8" csg shoe, circ at 170 gpm at 250 psi, rotated liner, with pumps on rot wt 75K, up wt 77K, dn wt 73, rotated at 20 rpm's at 2-3K ft-Ibs torque, pumps off st wt up 85K, dn wt 65K 09:15 - 13:30 4.25 CASE RUNL CMPL TN RIH with liner from 5,900' to 9,596' liner setting depth with no problems in open hole, st wt up 120K, dn wt 75K 13:30 - 14:00 0.50 CASE OTHR CMPL TN Dropped 1/34" ball and pumped down to seat, pump at 2 bpm at 510 psi, with ball on seat pressured up to 3,500 psi to set Flexlock hanger, bled off the pressure, cont to set packer, worked 45K wt down and packer didn't set, rotated 20 rpm's with 3K ft-Ibs torque and set ZXP packer, set st wt down several times to ensure packer set, no other problems setting hangerlpacker, set "A" sand liner with TOL @ 5,302' and shoe at 9,596', st wt up after setting liner 11 OK, dn wt 86K 14:00 - 14:15 0.25 CASE DEQT CMPL TN RU & tested 7 5/8" csg and ZXP packer to 1,500 psi for 10 min, good test 14:15 - 14:45 0.50 DRILL OBSV CMPL TN Monitored well-static, pumped dry job 14:45 - 18:00 3.25 DRILL TRIP CMPL TN POOH and LD Baker liner setting tool, cleared rig floor 18:00 - 21 :45 3.75 WINDOWPULD CMPL TN PU Whipstock and mills to rig floor, MU Baker seal assembly, 6 jts of 3 1/2" DP for space out and 7 5/8" Baker btm trip whipstock, milling assembly with LWD/MWD, uploaded MWD and oriented BHA #6, TIH with 4" HWDP to 1,250' 21:45-22:15 0.50 WINDOWOTHR CMPL TN Shallow tested MWD at 1,250' at 300 gpm, 1,000 psi and tool ck ok 22:15 - 00:00 1.75 WINDOwrRIP CMPLTN RIH with whipstock assembly, BHA #6 from 1,250' to 3,306' 9/13/2004 00:00 - 00:45 0.75 WINDOwrRIP CMPL TN RIH with whipstock from 3,306' to 4,626' 00:45 - 01:15 0.50 WINDOWOTHR CMPL TN Made MADD pass from 4,626' to 4,654' and correlated MWD to K-13 sand 01:15 - 02:00 0.75 WINDOwrRIP CMPL TN RIH with whipstock from 4,654' to 5,269' 02:00 - 02:15 0.25 WINDOWSETW CMPL TN Oriented whipstock to 15 deg left of high side, tagged TOL at 5,302', set whipstock and sheared off from same, st wt up 1 02K dn wt 71 K 02:15 - 05:15 3.00 WINDOWSTWP CMPL TN Milled window in 7 5/8" csg, top of window at 5,068', btm of window at Printed: 10/11/2004 3:38:27 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1E-166 1E-166 ROT - DRILLING n1334@ppco.com Doyon 141 Start: 8/31/2004 Rig Release: 9/24/2004 Rig Number: Spud Date: 9/1/2004 End: 9/24/2004 Group: 9/13/2004 02:15 - 05:15 3.00 WINDOWSTWP CMPL TN 5,080', drilled 6 3/4" hole to 5,100' MD (32'), 2-6K wob, 60-80 rpm's, 250-270 gpm, 1,450 psi, rot wt 75K, up wt 102K, dn wt 71 K, 6-8K ft-Ibs torque 05:15 - 06:15 1.00 WINDOWCIRC CMPL TN Circ hi vis sweep and circ hole clean, had no increase in cuttings back from sweep, circ at 270 gpm at 1,450 psi, worked mills thru window with no problem 06:15 - 06:30 0.25 WINDOWOTHR CMPL TN Monitored well-static, pumped dry job 06:30 - 10:30 4.00 WINDOWTRIP CMPL TN POOH and LD milling assembly, upper mill in gauge, cleared rig floor 10:30 - 12:30 2.00 WELCTL OTHR CMPL TN Pulled wear bushing and flushed out BOP stack, re-installed wear bushing 12:30 - 14:00 1.50 DRILL PULD PROD2 MU 6 3/4" BHA #7, 1.2 deg 4 3/4" motor, MWD/LWD/PWD, oriented and uploaded MWD, RIH to 257' 14:00 - 14:30 0.50 DRILL TRIP PROD2 RIH with BHA #7 from 257' to 2,500' 14:30 - 14:45 0.25 DRILL DEOT PROD2 Shallow tested MWD at 2,500', 297 gpm at 1,525 psi, tool checked ok, st wt up 67K, dn 62K 14:45 - 16:00 1.25 DRILL TRIP PROD2 RIH with BHA #7 from 2,500' to 5,017' 16:00 - 17:30 1.50 RIGMNT RSRV PROD2 Slip and cut 47' of drlg line, serviced top drive and drawworks 17:30 - 17:45 0.25 DRILL CIRC PROD2 Oriented BHA and RIH thru window from 5,068' to 5,080' with no pumps or problems, washed and reamed undergauge hole from 5,082' to btm at 5,100', string up wt 90k, dn wt 70K 17:45 - 20:30 2.75 DRILL DRLG PROD2 Drilled 6 3/4" hole from 5,100' to 5,207' MD/3,355' TVD, LWD tool failed, ART 1.2 hrs, AST .4 hrs, 5-12K wob, 90 rpm's, 70 spm, 297 gpm, off btm pressure 1,850 psi, on btm pressure 2,150 psi, off btm torque 3.5K ft-Ibs, on btm 4K, rot wt 78K, up wt 89K, dn wt 69K 20:30 - 21 :45 1.25 DRILL TRIP PROD2 Backreamed out from 5,207' to window, took several attempts then pulled BHA thru window. 21 :45 - 22:15 0.50 DRILL CIRC PROD2 Circ btms up at 5,022',297 gpm, 1,850 psi and 80 rpms 22:15 - 22:30 0.25 DRILL OBSV PROD2 Monitored well-static, pumped dry job 22:30 - 00:00 1.50 DRILL TRIP PROD2 POOH from 5,022' to 1,846' to change out LWD tools 9/14/2004 00:00 - 01 :00 1.00 DRILL TRIP PROD2 POOH f/1 ,846' to bit. 01 :00 - 02:30 1.50 DRILL TRIP PROD2 Inspect bit, Down load MWD tools, Change out LWDI MWD tools and program same. 02:30 - 06:00 3.50 DRILL TRIP PROD2 Surface test tools, RIH & orient thru window @ 5,080'. 06:00 - 07:45 1.75 DRILL TRIP PROD2 Madd pass fl 5,105' to 5,206'. 07:45 - 00:00 16.25 DRILL DRLH PROD2 Drill 6-3/4" hole f/5,206' to 6,888' MOl 3,357' TVD (1,682'), ART = 9.5 hrs, AST= 1.7 hrs, WOB 2I12K, RPM 80/120, 320 gpm @ 2250 psi, UP 101 K, DN 63K, ROT 78K, TO 5500 ftllbs ON 15500 ftIIbs OFF, Ave. ECD's 10.4 ppg wi 8.9 ppg mud, Max gas 854 units, Ave gas 110 units. 9/15/2004 00:00 - 12:00 12.00 DRILL DRLH PROD2 Drill 6-3/4" hole f/6,888' to 8,009' MD/3,345' TVD (1,121 '), ART = 4.8 hrs, AST = 3.0 hrs, WOB 2I10K, RPM 120, 320 gpm @ 2375 psi, UP 105K, DN 55K, ROT 77K, TO 6000 ftllbs ON 16000 ftIIbs OFF, Ave. ECD's 10.6 ppg wI 8.9 ppg mud, Max gas 178 units. 12:00 - 19:15 7.25 DRILL DRLH PROD2 Drill 6-3/4" hole fl 8,009' to 8,941' MD/3,329' TVD (1,932'), ART = 4.0 hrs, AST = 1.5 hrs, WOB 2I6K, RPM 90/120, 320 gpm @ 2750 psi, UP 111 K, DN 51 K, ROT 75K, TO 6500 ftllbs ON 16500 ftIIbs OFF, Ave. ECD's 10.9 ppg wi 8.9 ppg mud, Max gas 207 units. 19:15 - 20:00 0.75 DRILL TRIP PROD2 Circ evaluate logs for side track, POOH to 8,658' 20:00 - 00:00 4.00 DRILL DRLH PROD2 Orient and side track to low side of hole fl 8,663' to 8,860' MDI 3,339' TVD, ART= 1.0 hrs, AST= 1.0 hrs, WOB 2I7K, RPM 90/120, 330 gpm @ 2700 psi, UP 120K, DN 45K, ROT 76K, TO 6000 ftIIb ON 16500 ftllb OFF, Ave ECD's 10.9 ppg wI 8.9 ppg mud. 9/16/2004 00:00 - 01:15 1.25 DRILL DRLH PROD2 Orient and side track to low side of hole fl 8,860' to 8,941' MDI 3,340' TVD, ART = 0.5 hrs, AST = 0.25 hrs, WOB 2I12K, RPM 90/120,330 Printed: 10/11/2004 3:38:27 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 E-166 1 E-166 ROT - DRILLING n1334@ppco.com Doyon 141 Start: 8/31/2004 Rig Release: 9/24/2004 Rig Number: Spud Date: 9/1/2004 End: 9/24/2004 Group: 9/16/2004 00:00 - 01:15 1.25 DRILL DRLH PROD2 gpm @ 2750 psi, UP 11 OK, DN 57K, ROT 78K, TQ 7000 ftllb ON I 6500 ftllb OFF, Ave ECD's 10.9 ppg wI 8.9 ppg mud. 01 :15 - 05:30 4.25 DRILL DRLH PROD2 Drill 6-3/4" hole fl 8,941' to 9,423' MD/3,329' TVD (482'), ART = 2.9 hrs, AST = .25 hrs, WOB 2I12K, RPM 90/120, 320 gpm @ 2900 psi, UP 119K, DN 66K, ROT 92K, TQ 6500 ftllbs ON 16500 ftllbs OFF, Ave. ECD's 11.0 ppg wI 8.9 ppg mud, Max gas 108 units, Pump Hi-vis weighted sweep on last connection. 05:30 - 06:45 1.25 DRILL CIRC PROD2 Finish pumping Hi-vis sweep out of hole - 10 to 15% increase in cuttings. 06:45 - 13:15 6.50 DRILL TRIP PROD2 Monitor well, Back ream out of hole at drilling rate- 320 gpm @ 2900 to 1850 psi, 100 RPM, Pulling rate 40/45 ftlmin, No problems- hole in good shape, No problems going thru window @ 5,080' to 5,068'. 13:15 - 14:30 1.25 DRILL CIRC PROD2 Pump Hi-vis sweep and circ hole clean w/3 times btm's up at rate of 320 gpm @ 1850 psi, Monitor well, Pump dry job. 14:30 - 18:00 3.50 DRILL TRIP PROD2 POOH, Stand back HWDP, Jars, NMDC's, Lay down Bit & Motor, Down load & lay down MWD tools, Clear rig floor. 18:00 - 21:45 3.75 WINDOWTRIP CMPL T2 Make up Baker whipstock retrieving tools, Pick up 11 jts. 4-3/4" DC's, 1 jt HWDP, RIH to 5,073'. 21 :45 - 23:30 1.75 WINDOWCIRC CMPL T2 Wash & Work whipstock retrieving tool several times and latch onto whipstock on depth @ 5,073' (whipstock slot), Jar loose wi 80K over pull. 23:30 - 00:00 0.50 WINDOWTRIP CMPL T2 Pull and stand back 1 stand drill pipe & single. 9/17/2004 00:00 - 00:30 0.50 WINDOWCIRC CMPL T2 Circ btm's up at rate of 5 bpm @ 900 psi. 00:30 - 02:30 2.00 WINDOWTRIP CMPL T2 Monitor well, POOH slow to 4,400' due to swabbing & Work pipe to make well take proper fill- well finally began taking proper fill, Pump dry job, Drop rabbit. 02:30 - 07:30 5.00 WINDOWTRIP CMPL T2 POOH, Lay down whipstock and tools, Clear rig floor. 07:30 - 12:00 4.50 CASE PULR CMPL T2 Rig & run 4-1/2" liner, Pick up Baker B1 Flanged Hook Hanger. 12:00 - 13:00 1.00 CASE RUNL CMPL T2 RIH wI liner on drill pipe to window & work thru same, Made it thru window on second try. 13:00 - 16:00 3.00 CASE RUNL CMPL T2 RIH wi liner on drill pipe with no problems, Shoe @ 9,379' 16:00 - 17:30 1.50 CASE CIRC CMPL T2 Hook hanger at bottom of window @ 5,080' wI Top of liner @ 5,063.13' and Shoe @ 9,379.68', Drop ball, Circ, ball did not seat, drop 2nd 29/32" ball, cir. Ball did not seat. Drop1-3/4" ball, Pressure up and release running tool. Reverse circ and recover ball at surface. 17:30 - 18:00 0.50 CASE CIRC CMPL T2 Rig & reverse circ out ball. 18:00 - 22:00 4.00 CMPLTN TRIP CMPL T2 Monitor well, Pump dry job, POOH & lay down liner running tools. 22:00 - 00:00 2.00 CMPL TN PCKR CMPL T2 Rig & run LEM assembly. 9/18/2004 00:00 - 05:00 5.00 CMPL TN PCKR CMPL T2 RIH wI LEM assembly to 5,345' wi top @ 5,010', Latch and pull test LEM to 10K over. 05:00 - 05:45 0.75 CMPL TN PCKR CMPL T2 Drop ball, Pressure up to 3000 psi & Set ZXP Packer, Increase pressure to 4400 psi to lease fl LEM & neutralize push tool, Close Hydril & test annulus to 1500 psi f/5 min.- OK. 05:45 - 08:15 2.50 CMPL TN CIRC CMPL T2 Stand back 1 stand, Rig & attempt to shear out ball wi 6000 psi - No good, Rig & reverse circ ball out of pipe at rate of 3.5 bpm @ 700 psi. 08:15 - 12:30 4.25 CMPL TN TRI P CMPL T2 Monitor well, Pump dry job, POOH & lay down LEM running tool. 12:30 - 17:00 4.50 WELCTL BOPE CMPL T2 Pull wear bushing, Rig & test BOPE to 250 psi low & 3000 psi High, Test witnessed by AOGCC Jhon Crisp, Install wear bushing. 17:00 - 19:00 2.00 WINDOWPULD CMPL T2 Make up 'D' Lateral whipstock & mill assembly, Orient & Make up MWD. 19:00 - 23:00 4.00 WINDOWTRIP CMPL T2 RIH slow wI whipstock assembly to 4,330'. 23:00 - 23:30 0.50 WINDOWCIRC CMPL T2 Madd pass & log f/4,330' to 4,360'. 23:30 - 00:00 0.50 WINDOWTRIP CMPL T2 Continue RIH to 4,962'. Printed: 10/11/2004 3:38:27 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1E-166 1 E-166 ROT - DRILLING n1334@ppco.com Doyon 141 Start: 8/31/2004 Rig Release: 9/24/2004 Rig Number: Spud Date: 9/1/2004 End: 9/24/2004 Group: 9/19/2004 00:00 - 00: 15 0.25 WINDOWSETW CMPL T2 Orient whipstock 16 deg. Left, Tag top of liner wI No-Go @ 5,010' & Seals @ 5,014', Set trip anchor, Shear off fl bolt wI top of whipstock @ 4,799'. 00:15 - 04:45 4.50 WINDOWSTWP CMPL T2 Mill window f/4,799' to 4,811', Mill guage mill out window with btm. mill @ 4,830', WOM 2/4K, 80 RPM, 270 gpm @ 1750 psi, TQ 5/9,000 Wlb. 04:45 - 05:30 0.75 WINDOWCIRC CMPL T2 Pump Hi-vis weighted sweep & ream out window. 05:30 - 09:30 4.00 WINDOWTRIP CMPL T2 Monitor well, Dry pipe, POOH & Lay down mill assembly (All mills in guage). 09:30 - 10:30 1.00 WELCTL CIRC CMPL T2 Pull wear bushing, Wash out stack, Reinstall wear bushing. 10:30 - 12:00 1.50 DRILL PULD PROD3 Make up BHA #11, Orient tools, Program MWD/LWD. 12:00 - 14:00 2.00 DRILL TRIP PROD3 RIH to 2,100', Shallow test MWD tools, RIH to 4,740'. 14:00 - 15:00 1.00 RIGMNT RSRV PROD3 Cut & slip drilling line 61'. 15:00 - 15:30 0.50 DRILL REAM PROD3 Orient motor, Slide thru window fl 4,799' to 4,811' with no problem, Wash to 4,830'. 15:30 - 00:00 8.50 DRILL DRLH PROD3 Drill 6-3/4" hole fl 4,830' to 5,673' MD/3,300' TVD (843'), ART = 3.8 hrs, AST = 1.9 hrs, WOB 2/5K, RPM 90, 300 gpm @ 1800 psi, UP 98K, DN 66K, ROT 78K, Torque 4000 Wlbs ON 16500 Wlbs OFF, Ave. ECD's 10.0 ppg wi 8.9 ppg mud, Max gas 744 units. 9/20/2004 00:00 - 12:00 12.00 DRILL DRLH PROD3 Drill 6-3/4" hole f/5,673' to 6,608' MOl 3,290' TVD (935'), ART = 7.5 hrs, AST= 1.1 hrs, WOB 2/12K, RPM 90/120, 300 gpm @ 2000 psi, UP 102K, DN 63K, ROT 77K, Torque 6000 Wlbs ON 16000 Wlbs OFF, Ave. ECD's 10.4 ppg wi 8.9 ppg mud, Max gas 586 units. 12:00 - 00:00 12.00 DRILL DRLH PROD3 Drill 6-3/4" hole f/6,608' to 8,075' MD/3,284' TVD (1,467'), ART'" 8.6 hrs, AST= 0.5 hrs, WOB 2/6K, RPM 90/100, 310 gpm @ 2100 psi, UP 115K, DN 53K, ROT 76K, Torque 7000 Wlbs ON /7000 Wlbs OFF, Ave. ECD's 10.5 ppg wi 8.9 ppg mud, Max gas 541 units. 9/21/2004 00:00 - 03:15 3.25 DRILL DRLH PROD3 Drill 6-3/4" hole fl 8,075' to 8,380' MOl 3,280' TVD (305'), ART = 2.0 hrs, AST = 0.0 hrs, WOB 2/12K, RPM 100/120, 310 gpm @ 2450 psi, UP 112K, DN 52K, ROT 76K, Torque 7000 Wlbs ON 17000 Wlbs OFF, Ave. ECD's 10.5 ppg wI 8.9 ppg mud, Max gas 664 units. 03:15 - 04:15 1.00 RIGMNT RGRP PROD3 Change out top drive saver sub, Work pipe several times between operations. 04:15 - 16:30 12.25 DRILL DRLH PROD3 Drill 6-3/4" hole fl 8,380' to 9,417' MD/3,258' TVD (1,037'), ART", 9.0 hrs, AST= 0.5 hrs, WOB 2/12K, RPM 100/120,310 gpm @ 2600 psi, UP 128K, DN 55K, ROT 85K, Torque 8000 Wlbs ON 18000 Wlbs OFF, Ave. ECD's 10.9 ppg wI 8.9 ppg mud, Max gas 978 units, Pump Hi-vis weighted sweep on last connection. 16:30 - 17:30 1.00 DRILL CIRC PROD3 Finish pumping Hi-vis sweep out of hole - 10 to 15% increase in cuttings. 17:30 - 00:00 6.50 DRILL TRIP PROD3 Monitor well, Back ream out of hole at drilling rate- 310 gpm @ 2600 to 1850 psi, 100 RPM, Pulling rate 40/45 Wmin, No problems- hole in good shape, No problems going thru window @ 4,811' to 4,799'. 9/22/2004 00:00 - 01 :15 1.25 DRILL CIRC PROD3 Pump Hi-vis weighted sweep, Circ hole clean wI 3 times btm's up (Hole appeared clean, No noticeable increase in cuttings). 01:15 - 06:45 5.50 DRILL TRIP PROD3 Monitor well, Pull 5 stands and observe for swabbing, Pump dry job, POOH & lay down BHA (Hole took good fill). 06:45 - 09:45 3.00 WINDOWTRIP CMPL T3 Make up Baker whipstock retrieving tools, RIH to 4,805'. 09:45 - 10:15 0.50 WINDOWTRIP CMPL T3 Work pipe & Hook whipstock, Pull Anchor loose w/40K over. 10:15 - 15:00 4.75 WINDOWTRIP CMPL T3 Monitor well, Pump dry job, Drop rabbit, POOH & lay down whipstock & tools. 15:00 - 16:00 1.00 CASE RURD CMPL T3 Clear rig floor, Rig to run 4-1/2" liner, PJSM. 16:00 - 19:30 3.50 CASE PULR CMPL T3 Pick up 4-1/2",12.6#, L-80, DWC slotted liner and pick up Baker Hook Hanger as per detail. Printed: 10/11/2004 3:38:27 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 E-166 1 E-166 ROT - DRILLING n1334@ppco.com Doyon 141 Start: 8/31/2004 Rig Release: 9/24/2004 Rig Number: Spud Date: 9/1/2004 End: 9/24/2004 Group: 9/22/2004 9/23/2004 9/24/2004 3.00 CASE RUNL CMPL T3 RIH wI liner on drill pipe (Oriented thru window first time), Ran liner to btm @ 9,402' with no problems 1.00 CASE OTHR CMPL T3 Drop 29/32" ball, Check UP wt. of 122K, DN 71 K, Hook Hanger @ 4,811' (first time down), Unhook turn 1/4 tum and bypass window 10', Turn Hook 1/4 turn and bypass window again, Turn Hook 1/4 turn and Hook Hanger 1.57' low @ 4,812.57' wI Top of liner @ 4,795.72' & Guide Shoe @ 9,401.98', Set 36K down on Hook, Pump down ball at rate of 2 bpm @ 370 psi, Release from Hanger wI 3500 psi, Pull up to 9,353' (Lost 14K liner weight), Rig & shear out ball wi 4200 psi. Observe well, Circ btm's up at rate of 5 bpm @ 1100 psi. Monitor well, Pump dry job, POOH & lay down liner running tools. Lay down 4" drill pipe from off drillers side of derrick. Rig & pick up 138 joints 4-1/2",12.6#, L-80, IBT Tubing for completion string. POOH and stand back 4-112" tubing on off drillers side. Rig & lay down remaining drill pipe and collars from drillers side of derrick. Pull wear bushing. Clear rig floor, Rig to run ESP completion string. Service top drive. PJSM, Pick up Centrilift ESP Completion, Guage, Motor, Seal section, Screen Intake, Service same wi oil, Connect Esp cable & check same. RIH slow running cable & Installing Cannon clamps every other joint & checking cable conductivity every 1000' to 4,420', Make up hanger, Make final cable splice to wellhead penetrator. Found Penetrator connector to be incorrect tread, and correct one not in state, Wait on Orders Wrap and secure ESP Cable below tubing hanger (With out connecting to hanger), Land string as per detail wi Tail @ 4,470', Pump guage @ 4,466', Motor @ 4,432', Seal Section @ 4,418' (64.2 deg), GLM #1 @ 3,800' MD ( 2866' TVD), GLM #2 @ 3,006' MD ( 2388' TVD) Parts used on ESP cable; 3 - Protectolizer guards= OD 5.875" 2 - Flat guards= OD 5.625" 15 - Flat stainless steel bands 76 - Cannon clamps= 6.75" 1.00 WELCTL NUND CMPL TN Lay down landing joint, Install 2 way check, Rig & flush out BOP stack wI wash tool. 1.50 WELCTL NUND CMPL TN Nipple down BOPE. 1.50 WELCTL NUND CMPL TN Nipple up & test Vetco Gray Tree to 250 psi low and 5000 psi High. 1.50 CMPL TN FRZP CMPL TN Pull 2 way check, Rig & Freeze protect well wI 185 bbls diesel, Pumping down 7-5/8" x 4-1/2" annulus thru Screen intake @ 4,408' with returns up 4-1/2" tubing, Had good diesel to surface. 1.00 CMPL TN OTHR CMPL TN Rig lubricator, Install BPV, Install blind flanges to wellhead, Secure well, Remove scaffolding, Record pressures of 10-3/4" x 7-5/8" = 150 psi, 7-5/8" x 4-1/2" = 225 psi, 4-1/2" tubing = 100 psi. Note; Release rig to move to 1 E-114 at 24:00 hrs 9/24/2004. 19:30 - 22:30 22:30 - 23:30 23:30 - 00:00 0.50 CASE CIRC CMPL T3 00:00 - 03:00 3.00 CASE CIRC CMPL T3 03:00 - 08:00 5.00 DRILL PULD CMPL T3 08:00 - 12:00 4.00 CMPL TN RUNT CMPL T3 12:00 - 14:30 2.50 CMPL TN TRIP CMPL T3 14:30 - 19:30 5.00 DRILL PULD CMPL T3 19:30 - 20:00 0.50 CMPL TN PULD CMPL T3 20:00 - 23:30 3.50 CMPL TN RURD CMPL T3 23:30 - 00:00 0.50 RIGMNT RSRV CMPL T3 00:00 - 03:15 3.25 CMPL TN PULD CMPL TN 03:15 - 15:00 11.75 CMPLTN RUNT CMPL TN 15:00 - 17:00 2.00 WAlTON ORDR CMPL TN 17:00 - 17:30 0.50 CMPL TN SOHO CMPL TN 17:30 - 18:30 18:30 - 20:00 20:00 - 21 :30 21 :30 - 23:00 23:00 - 00:00 Printed: 10/1112004 3:38:27 PM y ConocoPhillips Wèllbore Name 166 Well Name 166 Slot Name Slot #166 losta".o Name Pad 1E Field Name Kuoaruk River Unit ~, ¡,¿;"fi:/íi,'" Created B;W;Í;~' lomnfènts . ConocoPhillips Alaska, Inc.,Slot #166 Pad 1 E, Kuparuk River Unit, North Slope, Alaska welh: GSS<0-446'>MWD-Sagll FR<490-6020>M WD-Sag/MagIlIFR<6089-9602'> Date Printed: 11-0ct-2004 J&ií. BAKER HUGHES INTEQ I Created 25-Auç -2004 I Government 10 I Last Revised 4-Feb-2004 I Grid Northinç¡ I Grid Eastinç 5959439.6800 r 549889.7100 I North 147.15S lEast 639.55W I Latitude - N70 17 59.8686 I Lonç itude W149 35 45.4138 I Eastina I Northina I Coord Svstern Name I North Alianment 550528.194 5959591.109 AK-4 on NORTH AMERICAN DATUM 1927 datum True I Eastina 487754.6208 I Northino 5948985.8206 I Coord Svstem Name I North Alianment AK-4 on NORTH AMERICAN DATUM 1927 datum True All data is in Feet unless otherwise stated Coordinates are from Slot MD's are from Rig and TVD's are from Rig (Doyon #141 RKB 99.0ft above mean sea level) Vertical Section is from O.OON O.OOE on azimuth 131.95 degrees Bottom hole distance is 7295.03 Feet on azimuth 166.46 degrees from Wellhead Calculation method uses Minimum Curvature method Prepared by Baker Hughes Incorporated Conoc;p.,illips . weith: GSS<0-446'>MWD-Sag/IFR<490-6020>M WD-Sag/Mag/ll FR<6089-9602'> Date Printed: 11-0ct-2004 r&ií. BAKER HUGHES INTEQ ConocoPhillips Alaska, Inc.,Slot #166 Pad 1E, Kuparuk River Unit,North Slope, Alaska Well path (Grid) Report MD[ft] Inc[deg] Azi[deg] TVD[ft] Station Station Dogleg 8everity Vertical Eastlng Northing Position(Y) Positîon(X) Sectionfftl 0.00 0.00 0.00 0.00 O.OON O.OOE 0.00 0.00 549889.71 5959439.68 108.00 0.00 0.00 108.00 O.OON O.OOE 0.00 0.00 549889.71 5959439.68 263.00 0.25 222.00 263.00 0.258 0.23W 0.16 0.00 549889.49 5959439.43 446.00 7.00 115.00 445.55 5.278 9.63E 3.87 10.68 549899.37 5959434.48 490.53 9.81 113.44 489.60 7.928 15.57E 6.33 16.87 549905.33 5959431.86 580.72 16.09 112.03 577.45 15.688 34.22E 6.97 35.93 549924.03 5959424.23 671.95 16.40 116.24 665.04 26.118 57.49E 1.33 60.21 549947.37 5959413.95 763.98 16.25 115.61 753.36 37.428 80.76E 0.25 85.08 549970.70 5959402.80 855.10 17.65 121.05 840.52 50.068 104.09E 2.32 110.88 549994.12 5959390.32 947.51 18.13 118.33 928.47 64.118 128.75E 1.04 138.61 550018.87 5959376.43 1038.85 19.60 119.68 1014.90 78.448 154.57E 1.68 167.39 550044.78 5959362.28 1130.64 23.66 124.09 1100.21 96.39S 183.21E 4.76 200.70 550073.54 5959344.51 1224.68 26.03 126.85 1185.55 119.35S 215.36E 2.81 239.95 550105.83 5959321.78 1317.21 31.72 130.17 1266.54 147.248 250.22E 6.39 284.52 550140.88 5959294.12 1410.24 38.81 133.08 1342.46 182.988 290.26E 7.83 338.19 550181.15 5959258.65 1503.12 43.06 133.84 1412.61 224.84S 334.40E 4.61 399.01 550225.57 5959217.09 1596.45 43.48 133.95 1480.57 269.198 380.50E 0.46 462.94 550271.95 5959173.05 1689.43 47.84 135.49 1545.54 315.998 427.72E 4.84 529.34 550319.47 5959126.56 1781.67 53.26 136.21 1604.13 367.09S 477.30E 5.91 600.37 550369.39 5959075.80 1875.86 52.62 136.05 1660.89 421.288 529.39E 0.69 675.34 550421.83 5959021.97 1971.33 51.63 136.25 1719.50 475.62S 581.60E 1.05 750.49 550474.39 5958967.98 2064.14 51.23 134.77 1777.37 527.39S 632.44E 1.32 822.91 550525.58 5958916.56 2156.61 51.07 135.38 1835.37 578.38S 683.30E 0.54 894.82 550576.76 5958865.91 2249.96 51.18 135.74 1893.96 630.26S 734.18E 0.32 967.35 550627.99 5958814.37 2342.86 51.71 133.55 1951.87 681.308 785.87E 1.93 1039.91 550680.00 5958763.67 2434.76 51.47 133.55 2008.96 730.92S 838.06E 0.26 1111.89 550732.52 5958714.41 2528.04 48.58 134.72 2068.89 780.688 889.37E 3.24 1183.32 550784.15 5958665.00 2621.35 49.24 134.57 2130.21 830.108 939.40E 0.72 1253.56 550834.51 5958615.92 2714.75 47.94 134.70 2191.99 879.318 989.25E 1.40 1323.53 550884.67 5958567.04 2806.68 47.39 133.49 2253.90 926.60S 1038.05E 1.14 1391.44 550933.78 5958520.08 2900.03 47.22 133.30 2317.20 973.74S 1087.90E 0.24 1460.03 550983.94 5958473.28 2944.88 47.87 131.87 2347.48 996.138 1112.27E 2.76 1493.12 551008.45 5958451.06 3175.14 48.59 133.84 2500.87 1112.93S 1238.14E 0.71 1664.81 551135.08 5958335.10 3266.50 51.74 135.39 2559.39 1162.21S 1288.05E 3.69 1734.88 551185.32 5958286.16 3361.82 52.19 136.94 2618.12 1216.368 1340.04E 1.36 1809.75 551237.67 5958232.36 3453.78 53.85 140.18 2673.45 1271.438 1388.63E 3.34 1882.70 551286.61 5958177.62 3546.74 55.49 143.63 2727.21 1331.12S 1435.39E 3.50 1957.37 551333.76 5958118.25 3641.05 56.34 147.89 2780.08 1395.678 1479.31E 3.85 2033.19 551378.11 5958054.00 3736.33 57.57 150.92 2832.05 1464.428 1519.94E 2.96 2109.36 551419.19 5957985.53 3829.25 58.89 154.18 2880.98 1534.518 1556.33E 3.30 2183.28 551456.04 5957915.69 3922.68 61.52 157.63 2927.41 1608.518 1589.40E 4.26 2257.34 551489.59 5957841.91 4016.85 63.91 163.94 2970.61 1687.50S 1616.87E 6.47 2330.58 551517.59 5957763.12 4109.60 65.40 168.05 3010.33 1768.81S 1637.13E 4.31 2400.00 551538.39 5957681.96 4203.00 64.61 169.40 3049.79 1851.82S 1653.68E 1.56 2467.81 551555.49 5957599.06 4296.81 64.93 169.64 3089.78 1935.27S 1669.12E 0.41 2535.07 551571.48 5957515.73 4389.17 64.04 169.57 3129.56 2017.25S 1684.16E 0.97 2601.06 551587.06 5957433.85 4483.20 64.68 169.69 3170.25 2100.64S 1699.42E 0.69 2668.15 551602.87 5957350.58 4577.09 67.23 169.18 3208.50 2184.92S 1715.14E 2.76 2736.19 551619.15 5957266.41 4670.78 70.37 169.11 3242.38 2270.69S 1731.59E 3.35 2805.76 551636.16 5957180.76 4763.77 73.71 169.43 3271.05 2357.598 1748.06E 3.61 2876.10 551653.20 5957093.98 4857.09 75.98 169.76 3295.45 2446.188 1764.32E 2.46 2947.42 551670.06 5957005.51 All data is in Feet unless otherwise stated Coordinates are from 810t MD's are from Rig and TVD's are from Rig (Doyon #141 RKB 99.00 above mean sea level) Vertical 8ection is from O.OON O.OOE on azimuth 131.95 degrees Bottom hole distance is 7295.03 Feet on azimuth 166.46 degrees from Wellhead Calculation method uses Minimum Curvature method Prepared by Baker Hughes Incorporated Conoc;p.,illips . ConocoPhillips Alaska, Inc.,Slot #166 Pad 1 E, Kuparuk River Unit,North Slope, Alaska welh: GSS<0-446'>MWD-Sag/lFR<490-6020>M WD-Sag/Mag/lIFR<6089-9602'> Date Printed: 11-0ct-2004 f'ií. BAKER HUGHES INTEQ Well path (Grid) Report MD[ft] Inc[deg] Azi[deg] TVD[ft] 8tation 8tation Dogleg 8everity Vertical Easting Northing Position(Y) Position(X) Section[ftl 4950.91 76.51 171.04 3317.75 2536.038 1779.52E 1.44 3018.79 551685.85 5956915.77 5042.79 78.30 171.41 3337.79 2624.65S 1793.19E 1.99 3088.20 551700.11 5956827.25 5137.55 77.83 171.05 3357.39 2716.28S 1807.33E 0.62 3159.97 551714.85 5956735.73 5229.47 77.83 171.55 3376.76 2805.098 1820.92E 0.53 3229.45 551729.03 5956647.01 5322.96 79.55 172.14 3395.10 2895.848 1833.92E 1.94 3299.78 551742.63 5956556.37 5418.08 81.82 172.18 3410.49 2988.828 1846.73E 2.39 3371.46 551756.05 5956463.48 5511.43 83.55 173.18 3422.38 3080.658 1858.52E 2.14 3441.62 551768.46 5956371.74 5604.53 83.49 172.30 3432.89 3172.428 1870.21E 0.94 3511.66 551780.75 5956280.07 5696.07 81.63 172.37 3444.74 3262.37S 1882.32E 2.03 3580.80 551793.46 5956190.20 5790.29 79.92 172.94 3459.84 3354.608 1894.21 E 1.91 3651.30 551805.96 5956098.06 5882.63 79.17 172.86 3476.60 3444.715 1905.43E 0.82 3719.89 551817.78 5956008.03 5943.81 78.86 173.13 3488.26 3504.328 1912.76E 0.67 3765.18 551825.50 5955948.48 6089.17 78.43 174.47 3516.88 3646.005 1928.15E 0.95 3871.34 551841.83 5955806.92 6181.84 79.97 180.59 3534.26 3736.905 1932.06E 6.70 3935.01 551846.34 5955716.06 6273.66 85.11 184.08 3546.18 3827.825 1928.33E 6.75 3993.03 551843.22 5955625.13 6368.80 96.40 182.95 3544.93 3922.628 1922.51E 11.93 4052.07 551838.03 5955530.30 6460.05 100.34 175.25 3531.63 4012.808 1923.90E 9.40 4113.38 551840.01 5955440.14 6554.45 98.36 167.59 3516.27 4104.825 1937.80E 8.28 4185.24 551854.52 5955348.22 6650.53 93.81 162.45 3506.08 4197.058 1962.49E 7.12 4265.27 551879.83 5955256.17 6742.05 88.89 161.74 3503.93 4284.098 1990.62E 5.43 4344.36 551908.52 5955169.33 6834.53 89.05 161.61 3505.59 4371.865 2019.69E 0.22 4424.66 551938.18 5955081.76 6928.13 89.51 165.47 3506.76 4461.608 2046.20E 4.15 4504.37 551965.28 5954992.20 7021.73 89.32 170.98 3507.72 4553.195 2065.29E 5.89 4579.80 551984.98 5954900.75 7115.49 87.33 173.94 3510.46 4646.095 2077.59E 3.80 4651.04 551997.89 5954807.95 7208.10 90.18 175.65 3512.47 4738.285 2085.99E 3.59 4718.92 552006.90 5954715.82 7303.04 91.04 179.69 3511.46 4833.115 2089.85E 4.35 4785.19 552011.39 5954621.02 7397.27 88.68 181.72 3511.69 4927.335 2088.69E 3.30 4847.31 552010.86 5954526.82 7490.43 86.62 180.14 3515.51 5020.395 2087.18E 2.79 4908.40 552009.96 5954433.76 7584.12 87.30 182.07 3520.48 5113.925 2085.37E 2.18 4969.58 552008.78 5954340.22 7677.64 88.74 184.72 3523.71 5207.215 2079.84E 3.22 5027.83 552003.86 5954246.91 7770.75 88.92 189.55 3525.61 5299.565 2068.28E 5.19 5080.96 551992.92 5954154.50 7862.23 88.99 192.47 3527.28 5389.335 2050.81E 3.19 5127.99 551976.05 5954064.62 7955.66 88.13 189.70 3529.63 5480.985 2032.86E 3.10 5175.90 551958.70 5953972.86 8048.78 87.79 189.49 3532.95 5572.735 2017.34E 0.43 5225.70 551943.80 5953881.01 8143.40 90.80 189.68 3534.11 5666.025 2001.59E 3.19 5276.35 551928.67 5953787.64 8236.05 93.04 191.84 3531.01 5756.975 1984.31E 3.36 5324.30 551911.99 5953696.58 8329.13 92.46 190.93 3526.54 5848.125 1965.95E 1.16 5371.58 551894.25 5953605.32 8422.63 94.94 190.05 3520.51 5939.85S 1948.97E 2.81 5420.27 551877.87 5953513.49 8515.52 95.11 188.82 3512.37 6031.135 1933.80E 1.33 5470.01 551863.31 5953422.12 8612.15 93.72 189.57 3504.93 6126.235 1918.40E 1.63 5522.14 551848.55 5953326.92 8703.48 92.42 190.63 3500.04 6216.025 1902.41E 1.84 5570.26 551833.15 5953237.05 8798.28 92.02 192.07 3496.37 6308.895 1883.77E 1.58 5618.49 551815.13 5953144.06 8887.50 89.88 192.84 3494.89 6395.995 1864.53E 2.55 5662.41 551796.47 5953056.84 8980.19 89.88 192.46 3495.08 6486.435 1844.23E 0.41 5707.77 551776.78 5952966.28 9070.88 87.58 193.22 3497.09 6574.835 1824.08E 2.67 5751.88 551757.22 5952877.76 9160.60 85.63 191.39 3502.41 6662.325 1805.00E 2.98 5796.17 551738.72 5952790.15 9250.60 87.08 191.32 3508.13 6750.388 1787.31E 1.61 5841.89 551721.62 5952701.98 9343.31 87.73 191.21 3512.33 6841.215 1769.22E 0.71 5889.15 551704.13 5952611.04 9432.85 89.63 194.17 3514.39 6928.538 1749.56E 3.93 5932.90 551685.05 5952523.61 9522.88 88.50 194.22 3515.86 7015.808 1727.48E 1.26 5974.82 551663.56 5952436.20 9550.98 87.91 194.58 3516.74 7043.00S 1720.50E 2.46 5987.82 551656.76 5952408.96 All data is in Feet unless otherwise stated Coordinates are from 510t MOos are from Rig and TVD's are from Rig ( Doyon #141 RKB 99.0ft above mean sea level) Vertical 5ection is from O.OON O.OOE on azimuth 131.95 degrees Bottom hole distance is 7295.03 Feet on azimuth 166.46 degrees from Wellhead Calculation method uses Minimum Curvature method Prepared by Baker Hughes Incorporated Conoc;p.,illips . ConocoPhillips Alaska, Inc.,Slot #166 Pad 1 E, Kuparuk River Unit,North Slope, Alaska we'h: GSS<O-446'>MWD-SagllFR<490-6020>M WD-Sag/MagllIFR<6089-9602'> Date Printed: 11-0ct-2004 f'~. BAKER HUGHES INTEQ Well path (Grid) Report MD[ftj Inc[degj I Azi[deg] 9602.00 87.91 194.58 ITVD[ft] ¡Station I Station I Dogleg severi,Vertical I Easting Northing Position(Y) Position(X) Section[ft] 3518.60' 7092.34S 1707.67E 0.00 6011.26 551644.25 5952359.53 All data is in Feet unless otherwise stated Coordinates are from Slot MD's are from Rig and TVD's are from Rig ( Doyon #141 RKB 99.00 above mean sea level) Vertical Section is from O.OON O.OOE on azimuth 131.95 degrees Bottom hole distance is 7295.03 Feet on azimuth 166.46 degrees from Wellhead Calculation method uses Minimum Curvature method Prepared by Baker Hughes Incorporated , . y ConocoPhillips . ConocoPhillips Alaska, Inc.,Slot #166 Pad 1 E, Kuparuk River Unit,North Slope, Alaska welh: GSS<0-446'>MWD-Sag/IFR<490-6020>M WD.Sag/Mag/IIFR<6089.9602'> Date Printed: 11-0ct-2004 J&I. BAKER HUGHES INTEQ Comments MDfftl TVDlftl I Northrftl I Eastrftl Comment ., 9602.00 3518.60' 7092.34S 1707.67E Projected Data - No Survey Hole Sections Diameter 5tart Start 5tart Start End End End Start Wellbore rinl MDlftl TVDlftl Northrftl Eastrftl MDrftl TVDlftl Northrftl Eastrftl 24.000 0.00 0.00 O.OON O.OOE 108.00 108.00 O.OON O.OOE 166 131/2 108.00 108.00 O.OON O.OOE 3020.00 2397.76 1033.615 1153.62E 166 97/8 3020,00 2397.76 1033.615 1153.62E 6020.00 3503.13 3578.575 1921.24E 166 63/4 6020.00 3503.13 3578.575 1921.24E 9602.00 3518.60 7092.345 1707.67E 166 Casings Name Top Top Top Top Shoe 5hoe Shoe 5hoe Wellbore MDlftl TVDlftl Northrftl Eastrftl MDlftl TVDlftl Northfftl Eastrftl 20.000in Conduct, 0.00 0.00 O.OON O.OOE 108.00 108.00 O.OON O.OOE 166 103/4" Casino 0.00 0.00 O.OON O.OOE 3012.00 2392.41 1029.595 1149.22E 166 7 5/8" Casino 0.00 0.00 O.OON O.OOE 6013.93 3501.93 3572.65S 1920.60E 166 4 1/2" Liner 5063.13 3341.93 2644.34S 1796.18E 9379.68 3330.74 6899.595 1775.79E 166 L 1 4 1/2" Liner 5302.18 3391.26 2875.61S 1831.11E 9596.00 3518.38 7086.545 1709.17E 166 All data is in Feet unless otherwise stated Coordinates are from 510t MD's are from Rig and TVD's are from Rig ( Doyon #141 RKB 99.0ft above mean sea level) Vertical Section is from O.OON O.OOE on azimuth 131.95 degrees Bottom hole distance is 7295.03 Feet on azimuth 166.46 degrees from Wellhead Calculation method uses Minimum Curvature method Prepared by Baker Hughes Incorporated . ~ì [ffi} !Æ~!Æ~_ . FRANK H. MURKOWSKI, GOVERNOR AI,ASIiA OIL AND GAS CONSERVATION COMMISSION 333 W. "JTH AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Randy Thomas Kuparuk Drilling Team Leader ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, Alaska 99510-0360 Re: Kuparuk lE-166 ConocoPhillips Alaska, Inc. Permit No: 204-153 Surface Location: 147' FNL, 640' FEL, SEC. 21, TIIN, RI0E, UM Bottomhole Location: 1960' FNL, 1046' FWL, SEC. 27, TIIN, R1OE, UM Dear Mr. Thomas: Enclosed is the approved application for permit to drill the above referenced development well. This permit to drill does not exempt you from obtaining additional permits or approvals required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Please provide at least twenty-four (24) hours notice for a representative of the Commission to witness any required test. Contact the Commission's petroleum field inspector at (907) 659-3 (pager). erel BY ORDER OE THE COMMISSION DATED this jjday of August, 2004 cc: Department ofFish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o end *- ConocoPhillips Alaska . Post Office Box 100360 Anchorage, Alaska 99510-0360 Randy Thomas Phone (907) 265-6830 Email: Randy.L.Thomas@conocophillips.com August 12, 2004 Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 8 Re: Applications for Permit to Drill, West Sak Producer: 1E-166, 1E 166 Ll, 1E-166 L2 Dear Commissioners: ConocoPhillips Alaska, Inc. hereby applies for Permits to Drill for an onshore production well, a trilateral horizontal well in the West Sak "A2", "B" and "D" sands. The main bore of the well will be designated 1E- 166, and the lateral bore of the well will be designated 1E-166Ll and 1E-166L2 Please find attached for the review of the Commission forms 10-401 and the information required by 20 ACC 25.005 for each of these well bores. Please note that ConocoPhillips is proposing a new BOP configuration for this well to reduce costs and the risk of injury. Details are provided in Section 3, Blowout Prevention Equipment Information, of the Application for Permit to Drill Document. The expected spud date of 1E-166 is September 4,2004. If you have any questions or require any further information, please contact Steve McKeever at 265- 6826. , sÔcer:~ J) fl ~ "- Iú}w--f Pø r ~"-V\.c{j 7/to ~~J Randy Thomas Greater Kuparuk Area Drilling Team Leader ORIG\NAL 1 a. Type of Work: Drill 0 Re-entry 0 2. Operator Name: ConocoPhillips Alaska, Inc. 3. Address: . . ~~ STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 RedrillU 1b. Current Well Class: Stratigraphic Test 0 ExploratoryU Development Oil ~ Multiple Zone 0 Service 0 Development Gas 0 Single Zone 0 5. Bond: ~ Blanket U Single Well 11. Well Name and Number: Bond No. 59-52-180 1E-166 6. Proposed Depth: 12. Field/Pool(s): MD: 9635' TVD: 3509' Kuparuk River Field 7. Property Designation: P.O. Box 100360 Anchorage, AK 99510-0360 4a. Location of Well (Governmental Section): Surface: 147' FNL, 640' FEL, Sec. 21, T11N, R10E, UM Top of Productive Horizon: 1505' FSL, 1286' FWL, Sec. 22, T11N, R10E, UM Total Depth: 1960' FNL, 1046' FWL, Sec. 27, T11 N, R10E, UM 4b. Location of Well (State Base Plane Coordinates): Surface: x- 549890 16. Deviated wells: Kickoff depth: 400 18. Casing Program Size Hole 42" Casing 20"x34" 13.5" 9-7/8" 6.75" 10.75" 7-5/8" 4.5" 19 Total Depth MD (It): Casing Structural Conductor Surface Intermediate Production Liner Perforation Depth MD (ft): West Sak Pool 13. Approximate Spud Date: 9/4/2004 ADL 25651 & 25660 8. Land Use Permit: ALK 469 & 470 9. Acres in Property: 2560 14. Distance to Nearest Property: 6326' 10. KB Elevation 15. Distance to Nearest y- 5959440 Zone- 4 (Height above GL): 28 feet Well within Pool: 1E-112,1027' 17. Maximum Anticipated Pressures in psig (see 20 AAC 25.035) ft. Maximum Hole Angle: 94° Downhole: 1582 psig Surface: 1160 psig Setting Depth Quantity of Cement Specifications Top Bottom c. f. or sacks Weight Grade Coupling Length MD TVD MD TVD (including stage data) 94# K-55 Welded 80' 28' 28' 108' 108' 260 cf ArcticCrete 45.5/40.5 L-80 BTC 2172'/691 28' 28' 2891' 2300' 510 sx AS Lite, 180 sx DeepCrete 29.7 L-80 BTCM 6088' 28' 28' 6116' 3516' 290 sx DeepCrete 12.6# L-80 DWC 3719' 5916' 3481' 9635' 3509' slotted liner PRESENT WELL CONDITION SUMMARY Total Depth TVD (It): Plugs (measured) (To be completed for Redrill and Re-Entry Operations) I Effective Depth MD (It): Effective Depth TVD (It): Junk (measured) Cement Volume MD rvD Length Size 20. Attachments: Filing Fee 0 Property Plat 0 BOP Sketch ~ Diverter Sketch 0 I Perforation Depth TVD (ft): Drilling Program~ Time v. Depth Plot 0 Seabed Report 0 Drilling Fluid Program 0 Date: Shallow Hazard Analysis 0 20 AAC 25.050 requirements [2] 21. Verbal Approval: Commission Representative: 22. I hereby certify that the foregoing is true and correct to the best of my knowledge. Printed Name Signature M~ Pzw- Contact Steve McKeever @ 265-6826 Title Kuparuk Drilling Team Leader t2...~::J 7~4 Phone ~{,c;-~e '" q Date r/13/oy ~ PreDared bv Sharon AI/suD-Drake Commission Use Only Permit to Drill I API Number: I Permit Approval Number: ;Zð 7" - IS 3 50- 02.. 9 - 2...3 2- 2-0 Date: Conditions of approval: Samples required 0 Yes ~ No Mud log required H ragen sulfide measures 0 Yes .J8 No Directional survey required ~~~'i(\o..~~. ~~-\t~-\ ~ \\.\~~~ i; ~~cs.\oc. 'k-0.~~~e.,,-\ ~~- :~;:~:'ON 0." 1~/{)'I Submit in Duplicate Isee cover letter for other requirements o Yes ~ g¡ Yes 0 No No Form 10-401 Revised 12/2003 OF~IGINAL · aation for Permit to Drill, Well 1 E-166 Revision No.O Saved: 11-Aug-Q4 Permit It - West Sak Well #1 E-166 Application for Permit to Drill Document MoxirnizE Well Vglu~ Table of Contents 1. Well Name ........ ......................... ....... ..................... ...... ..... ................ ..... ............. ....... 2 Requirements of 20 AAC 25.005 (f)................... ..... .... ................ ........... ......... .................... ... .................2 2. Location Sum mary ............................ ........ ................ ............... ....... ......... ............. ... 2 Requirements of 20 AAC 25.005(c){2) ........... ............. ......... .... ..... ...... .............. ....... ............. ...... ...........2 Requirements of 20 AAC 25. 050(b ).............................................. ..... .......................................... ........... 3 3. Blowout Prevention Equipment Information ......................................................... 3 Requirements of 20 AAC 25.005(c){3) ...................... ............................. ................................... ....... ...... 3 4. Drilling Hazards Information ................................................................................... 3 Requirements of 20 AAC 25.005 (c){4) ..................................................................................................3 5. Procedure for Conducting Formation Integrity Tests........................................... 4 Requirements of 20 AAC 25.005 (c){5) .................................................................................................. 4 6. Casing and Cementing Program............................................................................. 4 Requirements of 20 AAC 25. 005( c){6) .... ..... ................. ................ ......... ....... ........... .................... .......... 4 7. Diverter System Information ................................................................................... 4 Requirements of 20 AAC 25.005(c){7) .. ............. ..... .......... ............... .................. ......... ............ ............... 4 8. Dri II i ng FI uid Program ................. ............................... ........ ...................... ..... .......... 5 Requirements of 20 AAC 25.005(c){B) ............................ .................... ...... .............. ........... .................... 5 Surface Hole Mud Program (extended bentonite) .................................................................................. 5 Intermediate Hole Mud Program (extended bentonite) .......................................................................... 5 Lateral Mud Program (MI FloPro NT) ..................................................................................................... 5 9. Abnormally Pressured Formation Information ...................................................... 5 Requirements of 20 AAC 25.005 (c){9) .................................................................................................. 5 10. Seismic Analysis ............ ............... .............................. ......... ............. ........ ............... 6 Requirements of 20 AAC 25.005 (c){10) ................................................................................................ 6 11. Seabed Condition Analysis ..................................................................................... 6 Requirements of 20 AAC 25.005 (c)(11) ................................................................................................6 1E-166 PERMIT IT. doc Page 1 of 8 Printed: 11-Aug-04 · aation for Permit to Drill, We1l1E-166 Revision No.O Saved: 11-Aug-Q4 12. Evidence of Bonding ...............................................................................................6 Requirements of 20 AAC 25.005 (c)(12) ................................................................................................ 6 13. Proposed Drilling Program .....................................................................................6 Requirements of 20 AAC 25.005 (c)(13) ................................................................................................6 14. Discussion of Mud and Cuttings [)isposal and Annular Disposal....................... 8 Requirements of 20 AAC 25.005 (c)(14) ................................................................................................8 15. Attachments ...................... .................. ..... ... ......... .......... ............................. ......... ..... ........ 8 Attachment 1 Directional Plan (14 pages) ..............................................................................................8 Attachment 2 Drilling Hazards Summary (1 page) .................................................................................8 Attachment 3 Cement Loads and CemCADE Summary (2 pagse)....................................................... 8 Attachment 4 Well Schematic (1 pages) ...............................................................................................8 1. Well Name Requirements of 20 AAC 25.005 (f) Each well must be identified by a unique name designated by the operator and a unique API number assigned by tile commission under 20 MC 25.040{b). For a well with multiple well branches, each branch must similarly be identified by a unique name and API number by adding a suffìx to the name designated for the well by the operator and to the number assigned to the well by the commission. The well for which this Application is submitted will be designated as lE-166. ,- 2. Location Summary Requirements of 20 AAC 25.005(c)(2) An application far a Permit to Drill must be accompanied by each of the following items, except fòr an item already on file wIth the commission and Identified in the application: (2) a plat identifylilg the plvperty and the property's Oý1/.ners and showing (A)the coordinates of the proposed location of the well ¿it the sufface, at the top of each objective formation, and at total depth, referenced to governmental section lines. (8) the coordinates of the proposed location of the well at the surface, referenced to the state plane coordinate system for this state as maintained by the National Geodetic Survey in the National Oceanic and Atmospheric Administrationr' (C) the proposed depth of the well at the top of each oþ/ective formation and at total depth/ Location at Surface ASP Zone 4 NAD 27 Coordinates Northings: 5,959,440 Eastings: 549,890 147' FNL, 640' FEL, Section 21, T11N, Rl0E, UM I RKB Elevation I 9804' AMSL Pad Elevation 7004' AMSL Location at Top of Productive Interval (West Sak "A2" Sand) ASP Zone 4 NAD 27 Coordinates Northings: 5,955,825 Eastings: 551,848 1505' FSL, 1286' FWL, Section 22, T11N, Rl0E, UM Measured Depth~ RKB: Total Vertical Depth~ RKB: Total Vertical Depth~ 55: 6,116 3,516 3,417 Location at Total Depth ASP Zone 4 NAD 27 Coordinates Northings: 5,952,359 Eastings: 551,638 1960' FNL, 1046' FWL, Section 27, T11N, Rl0E, UM Measured Depth~ RKB: 9,635 Total Vertical Depth~ RKB: 3,509 Total Vertical Depth~ 55: 3,410 1E-166 PERMIT IT. doc Page20fB Printed: 11-Aug-04 ~ t\. 'f\ ~Q ~~ (~S~,,~ . aation for Permit to Drill, Well 1 E-166 Revision No.O Saved: 11-Aug-04 and (D) other information required by 20 MC 25.050(b); Requirements of 20 AAC 25.050(b) If a well is to be intentionally deviatec£ the application for a Permit to Dnll (Form 10-401) must (1) include a plat, drawn to a sUitable scale, showing the path ofthe proposed well bore, including all adjacent wellbores within 200 feet of any portion ofthe propo::.c:d well; Please see Attachment 1: Directional Plan and (2) for all wells within 200 feet of the proposed wellbore (A) list the names of the operators of those wells, to the extent that those names are known or discoverable in public records, and show that each named operator has been furnished a copy of the application by certified mai¿· or (B) state that the applicant is the only affected owner. The Applicant is the only affected owner. 3. Blowout Prevention Equipment Information Requirements of 20 AAC 25.005(c){3) An application for a Permit to Dtill must be accompanied by each of the following items, except for an item a/ready on file with the commission and Identified in the application: (3) a diagram and desctiption of the blowout prevention equipment (BOPE) as required by 20 MC 25. 035, 20 MC 25.036, or 20 MC 25.037, as applicable; An API 13-5/8" x 5,000 psi BOP stack (RSRRA) will be utilized to drill and complete well lE-166. For all operations the stack will be equipped with 3-1/2" to 6" variable bore rams in the uppermost ram cavity, blind rams in the middle cavity, and 7-5/8" rams in the lowermost cavity. See attached diagram entitled "Doyon 141 West Sak 2004 3ksi BOP Configuration" for clarification. Upon initial nipple up, and at intervals of no more than 14 days thereafter, a test plug will be set below the lowermost rams, the annular preventer will be tested to 1,500 psi and the blind rams and upper rams will be tested to 3,000 psi. (This test will test the shell and end connections of the lowermost ram). Immediately prior to running the intermediate string of 7-5/8" casing, a test plug will be set below the lowermost rams, and those rams will be closed and tested to 3,000 psi on a 7-5/8" 00. - 4. Drilling Hazards Information Requirements of 20 AAC 25.005 (c){4) An application for a Permit to Drill must be accompanied by each of the following item!:>" except for an item already on file with the commission and identified in the application: (4) information on drilling hazards, including (A) the maximum downhole pressure that may be encountered, mteria used to detelmine it, and maximum potential surrar" pressure based on a methane gradient; The expected reservoir pressures in the West Sak sands in the lE-166 area vary from 0.42 to O.Lr::> psi/ft, or 8.0 to 8.6 ppg EMW (equivalent mud weight). These pressures are predicted based on actual bottom hole pressure data from the nearby West Sak welllE-119. The maximum potential surface pressure (MPSP) based on the above maximum pressure gradient, a methane gradient (0.11) and the deepest planned vertical depth of the West Sak A2 sand formation is 1,160 psi, calculated thusly: MPSP =(3,516 ft)(0.45 - 0.11 pSi/ft) =1,160 psi (B) data on potential gas zones; The well bore is not expected to penetrate any gas zones. and tE-166 PERMIT IT. doc Page 3 of 8 Printed: 11-Aug-04 · aation for Permitto Drill, We1l1E-166 Revision No.O Saved: 11-Aug-04 (C) data concerning potential causes of hole problems such as abnormally geo-pressllred strata, lost drculation zones, and zones that have a propensity for differential sticking; Please see Attachment 2: Drilling Hazards Summary. 5. Procedure for Conducting Formation Integrity Tests Requirements of 20 AAC 25.005 (c)(5) An application for a Permit to Drill must be accompanied by ea(.j¡ of the following ¡terns, except for an ¡tern already on file with the commis..c;ion and identified in the application: (5) a description of the procedure for conducting formation integrity tes~ as required under 20 AAC 2.5. 030(f); lE-166 will be completed with 7-5/8" surface casing landed at the top of the West Sak A2 sand. The casing shoe will be drilled out and a formation integrity test will be performed in accordance with the "Formation Integrity Test Procedure" that ConcocoPhillips Alaska placed on file with the Commission. 6. Casing and Cementing Program Requirements of 20 AAC 25.005(c)(6) An application for a Pemlit to Drill must be accompanied by each of the following items, except for an item already on file witil the commission and identified in the application: (6) a complete proposC!d casing and cementing program as required by 20 MC 25.03rt and a description of any s10tted liner, pre- perforated liner, or screen to be installed; 4-1/2 6-3/4" A2 slotted Sand Lateral (lE- 166) 4-1/2 6-3/4"8 slotted Sand Lateral (lE- 166 Ll) 4-1/2 6-3/4" D slotted Sand Lateral (1 E- 166 L2) 7. Diverter System Information Requirements of 20 AAC 25.005(c)(7) An application for a Permit to Drill must be al.;wmpanied by each of the following items, except for an item already on file with the commission and ide/lt/fied in the application: (7) a diagram and description of the diverter system as required by 20 MC 25. 035, unless this requirement is waived by the commi..<;sion under 20 MC 25.035(h)(2/· Casing and Cementing Program See also Attachment 3: Cement Summary Hole Top CsglTbg Size Weight Length MD/TVD OD (in) (in) (Ib/ft) Grade Connection (ft) (ft) 20 X 34 42 94 K55 Welded 80 28 / 28 10-3/4 13-1/2 45.5 L-80 BTC 2172 28 / 28 40.5 691 2200 / 1855 7-5/8 9-7/8 29.7 L-80 BTCM 6088 28 / 28 12.6 5916 / 3481 L-80 Grant Prideco DWC/C Grant Prideco DWC/C Grant Prideco DWC/C 3719 12.6 L-80 4361 5102/3340 4634 4823/ 3275 12.6 L-80 Cement Program Cemented to surface with 260 d ArcticCRETE Cemented to Surface with 510 sx ASLite Lead, 180 $X DeepCRETE Tail 6116 / 351(Jcement Top planned @ 4300' MD / 3088' TVD. Cemented w/ 290 " DeepCRETE Slotted- no cement Btm MD/TVD (ft) 108 / 108 2200/1855 2891 / 2300 9635 / 3509 9463 / 3320 9457 / 3250 ~~~ Slotted- no cement Slotted- no cement 1E-166 PERMIT IT. doc Page 4 of 8 Printed: 11-Aug-04 · .cation for Permit to Drill, Well 1 E-166 Revision No.O Saved: 11-Aug-04 A 21-1/4",2000 psi annular with a 16" diameter diverter line will be the diverter system used in the drilling of 1E-166. Please see diagrams of the Doyon 141 diverter system on file with the Commission. 8. Drilling Fluid Program Requirements of 20 AAC 25.005(c)(B) An application for a Permit to Drill must be accompanied by each of the following ¡tem~ except for an Item a/ready on file with the commission and identified in the application: (8) a drilling fluid program, ¡f¡eluding a diagram and description of the drilling fluid system, as required by 20 MC 25. 03~' Drilling will be done with muds having the following properties over the listed intervals: Surface Hole Mud Program (extended bentonite) Spud to Base of Permafrost Density (ppg) Funnel Viscosity {seconds} Yield Point {cP} Plastic Viscostiy {1b/1 00 sf} pH API Filtrate (cc / 30 min)} *9.6 ppg if hydrates are encountered Initial Value 8.5 150 50-70 20-45 8.5-9.0 NC-8.0 Final Value 9.2 250 50-70 20-45 8.5-9.0 NC-8.0 Intermediate Hole Mud Program (LSND) 10-3/4// Casing Shoe to 7-5/8// Casing Point ~ ¡tial Valt¡e Density (ppg) 9.0-9.1 Funnel 45-60 Viscosity (seconds) Plastic Viscostiy (lb1100 sf) Yield Point (cP) API Filtrate (cc 130 min)) Chlorides (mgll) pH MBT 12-18 26- 35 4-6 <500 9.0-9.5 <20.0 Base of Permafrost to 10-3/4// Casing Point Initial Value Final Value 9.5 9.6 200 200 30-50 30-50 15-20 15-20 8.5-9.0 8.5-9.0 5.0-7.0 5.0-7.0 Lateral Mud Program (MI Versa Pro Mineral Oil Base) ~ Vii!ùr Density (ppg) 9.0 Plastic Viscostiy (lb1100 sf) Yield Point (cP) A2/BID sand laterals HTHP Fluid loss (m1/30 min @200psi& 1500 Oil I Water Ratio Electrical Stability 18-28 <4.0 80 I 20 >600 Drilling fluid practices will be in accordance with appropriate regulations stated in 20 MC 25.033. Please see information on file with the Commission for diagrams and descriptions of the fluid system of Doyon Rig 141. 9. Abnormally Pressured Formation Information Requirements of 20 AAC 25.005 (c)(9) An application for a Permit to Drill mllst be accompanied by each of the following item~ except for an item already on file with the commission and identified in the application: (9) for an exploratory or stratigraphic test wel¿ a tabulation settti¡g out the depths of predicted abnormally gee-pressured strata as required by 20 MC 25.033(f); 1E-166 PERMIT IT. doc Page 5 of 8 Printed: 11-Aug-04 · aation for Permit to Drill, We1l1E-166 Revision No.O Saved: 11-Aug-Q4 Not applicable: Application is not for an exploratory or stratigraphic test well. 10. Seismic Analysis Requirements of 20 AAC 25.005 (c)(10) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the applIcatIon: (10) for an exploratory or stratigraphic test wellr a seismic refraction or reflection analysis as required by 20 MC 25.061(a); Not applicable: Application is not for an exploratory or stratigraphic test well. 11. Seabed Condition Analysis Requirements of 20 AAC 25.005 (c)(11) An application for a Permit to Drill must be accompanied by each of the fo/lowing items, except for an item already on file with the commission and identified in the application: (11) for a well drilled from an offshore platform, mobile bottom-founded structur~ jack-up rig, or floating drilling vessel, an analysis of seabed conditions as required by 20 MC 25.061 (b); Not applicable: Application is not for an offshore well. 12. Evidence of Bonding Requirements of 20 AAC 25.005 (c)(12) An application for a Pelmit to Drill must be accompanied by each of the following Items, except for an item already on file with the commission and identified in the application: (12) evidence show/ìlg that the requirements of 20 MC 25.025 {Bonding}have been met; Evidence of bonding for ConocoPhil/ips Alaska, Inc. is on file with the Commission. 13. Proposed Drilling Program Requirements of 20 AAC 25.005 (c)(13) An application for a Pemlit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: The proposed drilling program is listed below. Please refer also to Attachment 5, Well Schematics. 1. Excavate cellar, install cellar box, set and cement 20" x 34" insulated conductor to +/- 108' RKB. Install landing ring on conductor. 2. Move in / rig up Doyon Rig 141. Install 21-1/4" Annular with 16" diverter line and function test. 3. Spud and directionally drill 13-1/2" hole to casing point at +/- 2891' MD /2300' 1VD as per directional plan. Run MWD tools as required for directional monitoring. 4. Run and cement to surface. Displace cement with mud and, pressure test casing to 2500 psi for 30 minutes and record results. Perform top job if required. 5. Remove diverter system, install and test 13-5/8" x 5,000 psi BOP's as described above in Section 3 above and test to 3,000 psi (annular preventer to 1500 psi) Notify AOGCC 24 hrs before test. ""--""""\ 6. PU 9-7/8" bit and 6-1/4" drilling assembly, with MWD, LWD & PWD. RIH, clean out cement to top of float equipment. Re-test casing if cement is tagged more than 100 feet above the float collar. 7. Drill out cement and between 20' and 50' of new hole. Perform formation integrity test to leak off, recording results. (ECD's modeled to be less than 11.0 ppg) 8. Directionally drill to 7-5/8" casing point at 6,116 MD /3,516' 1VD, the prognosed top of the A2 sand. 9. Run 7-5/8", 29.7# L80, BTC Mod casing to surface. Pump cement and displace with mud (top of cement to be 4,300 MD / 30881VD if Ugnu formation is not oil bearing. Top of cement to be 500 feet (MD) above shallowest oil bearinq sand if Ugnu is oil bearin~.» and pressure test casing to 3,000 psi for 30 minutes and record results. 10. Install wellhead x 7-5/8" packoff and test to 5000 psi. 11. Flush 10-3/4" x 7-5/8" annulus with water, followed by diesel. 1E-166 PERMIT IT. doc Page 6 of 8 Printed: 11-Aug-04 ~ ~ . .cation for Permit to Drill, W ell 1 E-166 Revision No.O Saved: 11-Aug-04 12. PU 6-3/4" PDC Bit and 4-3/4" drilling assembly, with MWD, and LWD logging tools. RIH, clean out cement to top of float equipment. Re-test casing if cement is tagged more than 100 feet above the float collar 13. Drill out cement and between 20' and 50' of new hole. Displace hole to lateral drilling mud. Perform formation integrity test to leak off, recording results. (expected ECD's in 6-3/4" lateral modeled to be less than 12.0 ppg). 14. Directionally drill 6-3/4" hole to TD at +/- 9,635' MD /3,509' ìVD as per directional plan. 15. POOH, back reaming out of lateral. POOH. 16. PU and run 4-1/2" slotted liner. 17. Land liner, set liner hanger @ +/- 5,916' MD / 3,481'. POOH. dO€-\ - \5S ~ Note: Remaining operations are covered under the lE-166L1 Application for Permit to Drill, and are provided here for information only. 18. Run and set Baker WindowMaster whipstock system, at window point of 5,102' MD / 3,340' ìVD, the top of the B sand. 19. Mill 6-3/4" window. POOH. 20. Pick up 6-3/4" drilling assembly with LWD and MWD and PWD. RIH. 21. Drill to TD of B sand lateral at 9,463' MD / 3,320' ìVD, as per directional plan. 22. POOH, back reaming out of lateral. POOH. 23. RIH with whipstock retrieval tool. Retrieve whipstock and POOH. 24. PU and run 4-1/2" slotted liner. -------- ~04- \S~ 25. RIH, until liner hanger is just above window. Orient hanger to window and land hanger. 26. Release hanger running tool. POOH. 27. Make up junction isolation / re-entry assembly (Lateral Entry Module or LEM) and RIH to depth. Orient and set packer atop assembly and release from assembly. POOH. Note: Remaining operations are covered under the lE-166L2 Application for Permit to Drill, and are provided here for information only. 28. Run and set Baker WindowMaster whipstock system, at window point of 4,823' MD / 3,2,75' ìVD, the top of the D sand. 29. Mill 6-3/4" window. POOH. 30. Pick up 6-3/4" drilling assembly with LWD and MWD and PWD. RIH. 31. Drill to TD of D sand lateral at 9,457' MD /3,250' ìVD, as per directional plan. dO L\ - \ S S- 32. POOH, back reaming out of lateral. POOH. 33. RIH with whipstock retrieval tool. Retrieve whipstock and POOH. 34. PU and run 4-1/2" slotted liner. 35. RIH, until liner hanger is just above window. Orient hanger to window and land hanger. Release hanger running tool. 36. POOH, laying down drill pipe as required. 37. Make up ESP drive section (motor only, no pump), other completion equipment and tubing as required and RIH to depth. Land tubing. Set BPV. 1E-166 PERMIT IT. doc Page 7018 Printed: "-Aug-04 · aation for Permit to Drill, Well 1 E-166 Revision No.O Saved: 11-Aug-04 38. Nipple down BOPE, nipple up tree and test. Pull BPV. 39. Set BPV and move rig off. 40. Freeze protect well with diesel by pumping into 4-1/2" x 7-5/8" annulus, taking returns from tubing and allowing to equalize. 41. Rig up wire line unit. Pull BPV 42. Set gas lift valves in mandrels. Operate well on gas lift for +/- 180 days. Shut well in. 43. Rig up wireline. Replace gas lift valves with blank dummy valves. Run ESP through tubing. 44. Operate well with ESP. 14. Discussion of Mud and Cuttings Disposal and Annular Disposal Requirements of 20 AAC 25.005 (c)(14) An application for a Permit to Drill mustc be accompanied by each of the following items, except for an Item already on fìle with the commission and identifìed in the application: (14) a general description of how the 01-1(3rator plans to dispose of drilling mud and cuttings and a statement of whether the operator intends to request authorization under 20 AAC 25.080 for an amular disposal operation in the wel/.; Waste fluids generated during the drilling process will be disposed of either by pumping authorized fluids into a permitted annulus on lE Pad, or by hauling the fluids to a KRU Class II disposal well. All cuttings generated will be disposed of either down a permitted annulus on lE Pad, hauled to the Prudhoe Bay Grind and Inject Facility for temporary storage and eventual processing for injection down an approved disposal well, or stored, tested for hazardous substances, and (if free of hazardous substances) used on pads and roads in the Kuparuk area in accordance with a permit from the State of Alaska. ConocoPhillips Alaska may in the future request authorization for the use of this well for annular disposal operations. 15. Attachments Attachment 1 Doyon 141 West Sak 2004 3ksi BOP Configuration (1 page) Attachment 2 Directional Plan (18 pages) Attachment 3 Drilling Hazards Summary (1 page) Attachment 4 Cement Loads and CemCADE Summary (2 pages) Attachment 5 Well Schematic (1 page) 1E-166 PERMIT IT. doc Page 8 of 8 Printed: 11-Aug-04 · - -v- ~ ~ -v- --b L Drill String Valves To be tested to 250 psi and 3,000 psi at initial installation and every 14 days thereafter. 13-5 Annular ____________ To be tested to 250 psi and 1,500 psi at initial ~ installation and every 14 days thereafter. ~ 5 13-5 Double Ram Upper Rams: 3-%" to 6" variables To be tested to 250 psi and 3,000 psi at initial ~ Þ installation and every 14 days thereafter. C ~ Þ Lower Rams: Blind To be tested to 250 psi and 3,000 psi at initial installation and every 14 days thereafter. Choke and Kill Line Valves +-- To be tested to 250 psi and 3,000 psi at initial installation and every 14 days thereafter. ~ Þ ~ 13-5 Single Ram .J L Rams to fit Intermediate Casing: 7~5/8" or 9-5/8" To be tested to 250 psi and 3,000 psi only before running casing. ~ Wellhead Valves tested to 3,000 psi upon assembly ----Ar ~ ConocoPhillips Alaska Doyon 141 West Sak 3 ksi BOP Configuration 13-5 BOP 3K diagram. vsd Sheet 1 of 1 prepared by Steve McKeever 8/1112004 . . C~illips ConocoPhillips Alaska, Inc.,Slot #166 Pad 1 E, Kuparuk River Unit,North Slope, Alaska PROPOSAL LISTING Page 1 Well bore: 166 Well path: 166 Ver#3 Date Printed: 29-Jul-2004 Well bore Name 166 I Created 4-Feb-2004 I Last Revised 26-Jul-2004 Name 166 Government 10 I Last Revised 4-Feb-2004 Latitude N70 17 59.8686 35 45.4138 Installation Name Pad 1 E I EastinQ 550528.1946 NorthinQ I 5959591.1090 I Coord System Name I North AliQnment AK-4 on NORTH AMERICAN DATUM 1927 datu~ True Field Name Kuparuk River Unit EastinQ 487754.6208 I NorthinCl , 5948985.8206 I I Coord System Name I North AliQnment I AK-4 on NORTH AMERICAN DATUM 1927 datu~ True All data is in Feet unless otherwise stated Coordinates are from Slot MD's are from Rig and TVD's are from Rig ( Datum #1 99.0ft above mean sea level) Vertical Section is from O.OON O.OOE on azimuth 180.00 degrees Bottom hole distance is 7294.05 Feet on azimuth 166.51 degrees from Wellhead Calculation method uses Minimum Curvature method Prepared by Baker Hughes Incorporated e . conocóPhillips ConocoPhillips Alaska, Inc.,Slot #166 Pad 1 E, Kuparuk River Unit,North Slope, Alaska PROPOSAL LISTING Page 2 Wellbore: 166 Wellpath: 166 Ver#3 Date Printed: 29-Jul-2004 Wellpath Report MD[ft) Inc[deg] Azi[deg] I TVD[ft] Vertical North[ft) East[ft) 5tation 5tation Dogleg Vertical Station Comment Depth 55 Position(Grid Position(Grid [deg/10 Section[f North} East) Oft! t1 0.00 0.00 0.00 0.00 -99.00 O.OON O.OOE 5959439.68 549889.71 0.00 0.00 Tie on 100.00 0.00 0.00 100.00 1.00 O.OON O.OOE 5959439.68 549889.71 0.00 0.00 200.00 0.00 0.00 200.00 101.00 O.OON O.OOE 5959439.68 549889.71 0.00 0.00 300.00 0.00 0.00 300.00 201.00 O.OON O.OOE 5959439.68 549889.71 0.00 0.00 400.00 0.00 0.00 400.00 301.00 O.OON O.OOE 5959439.68 549889.71 0.00 0.00 KOP. End of Hold 500.00 3.00 130.00 499.95 400.95 1.68S 2.00E 5959438.01 549891.73 3.00 1.68 600.00 6.00 130.00 599.63 500.63 6.725 8.02E 5959433.01 549897.77 3.00 6.73 700.00 9.00 130.00 698.77 599.77 15.115 18.01E 5959424.69 549907.82 3.00 15.11 733.33 10.00 130.00 731.64 632.64 18.655 22.23E 5959421.18 549912.06 3.00 18.65 End of BuildlTurn 833.33 14.00 130.00 829.44 730.44 32.01S 38.15E 5959407.92 549928.07 4.00 32.01 933.33 18.00 130.00 925.54 826.55 49.73S 59.26E 5959390.35 549949.29 4.00 49.73 983.33 20.00 130.00 972.82 873.82 60.19S 71.73E 5959379.97 549961.83 4.00 60.19 End of Build 1083.33 25.00 130.00 1065.18 966.18 84.78S 101.04E 5959355.58 549991.30 5.00 84.78 1183.33 30.00 130.00 1153.85 1054.85 114.455 136.40E 5959326.15 550026.85 5.00 114.45 1283.33 35.00 130.00 1238.16 1139.16 148.98S 177.54E 5959291.90 550068.22 5.00 148.98 1383.33 40.00 130.00 1317.47 1218.47 188.10S 224.16E 5959253.10 550115.09 5.00 188.10 1483.33 45.00 130.00 1391.18 1292.18 231.51S 275.90E 5959210.03 550167.11 5.00 231.51 1583.33 50.00 130.00 1458.71 1359.71 278.885 332.36E 5959163.04 550223.88 5.00 278.88 EOC, End of Build 1600.00 50.00 130.00 ¡ 1469.43 1370.43 287.09S 342.14E 5959154.90 550233.72 0.00 287.09 1630.45 50.00 130.00 1489.00 1390.00 302.085 360.01 E 5959140.02 550251.68 0.00 302.08 Base Permafrost 1700.00 50.00 130.00 1533.71 1434.71 336.33S 400.82E 5959106.05 550292.72 0.00 336.33 1800.00 50.00 130.00 1597.98 1498.99 385.57S 459.51 E 5959057.21 550351.72 0.00 385.57 1900.00 50.00 130.00 1662.26 1563.26 434.815 518.19E 5959008.36 550410.72 0.00 434.81 1971.15 50.00 130.00 1708.00 1609.00 469.855 559.94E 5958973.61 550452.70 0.00 469.85 Top T-3 2000.00 50.00 130.00 1726.54 1627.54 484.055 576.87E 5958959.52 550469.72 0.00 484.05 2100.00 50.00 130.00 1790.82 1691.82 533.29S 635.55E 5958910.67 550528.73 0.00 533.29 2200.00 50.00 130.00 1855.10 1756.10 582.53S 694.24E 5958861.83 550587.73 0.00 I 582.53 2300.00 50.00 130.00 1919.38 1820.38 631.77S 752.92E 5958812.98 550646.73 0.00 631.77 2400.00 50.00 130.00 1983.66 1884.66 681.01S 811.60E 5958764.14 550705.73 0.00 681.01 2430.09 50.00 130.00 2003.00 1904.00 695.835 829.26E 5958749.44 550723.49 0.00 695.83 Top K-15 2500.00 50.00 130.00 2047.94 1948.94 730.25S 870.28E 5958715.29 550764.73 0.00 730.25 2600.00 50.00 130.00 2112.22 2013.22 779.49S 928.97E 5958666.45 550823.74 0.00 779.49 2700.00 50.00 130.00 2176.49 2077.49 828.74S 987.65E 5958617.60 550882.74 0.00 828.73 2800.00 50.00 130.00 2240.77 2141.77 877.98S 1046.33E 5958568.76 550941.74 0.00 877.97 2900.00 50.00 130.00 2305.05 2206.05 927.225 1105.01 E 5958519.91 551000.74 0.00 927.22 3000.00 50.00 130.00 2369.33 2270.33 976.465 1163.69E 5958471.07 551059.75 0.00 976.46 3100.00 50.00 130.00 2433.61 2334.61 1025.70S 1222.38E 5958422.22 551118.75 0.00 1025.70 3200.00 50.00 130.00 2497.89 2398.89 1074.945 1281.06E 5958373.38 551177.75 0.00 1074.94 3DXS Kick off Point 3300.00 50.91 135.05 2561.58 2462.58 1127.055 1337.84E 5958321.65 551234.87 4.00 1127.04 3400.00 52.04 139.96 2623.88 2524.88 1184.72S 1390.64E 5958264.34 551288.05 4.00 1184.72 3500.00 53.36 144.70 2684.50 2585.50 1247.675 1439.21E 5958201.72 551337.03 4.00 1247.67 3514.28 53.57 145.37 2693.00 2594.00 1257.075 1445.78E 5958192.36 551343.66 4.00 1257.07 Top U!1nu C 3600.00 54.87 149.28 2743.14 2644.14 1315.595 1483.30E 5958134.09 551381.56 4.00 1315.59 3700.00 56.54 153.68 2799.50 2700.50 1388.16S 1522.70E 5958061.79 551421.44 4.00 1388.16 3800.00 58.36 157.91 2853.32 2754.32 1465.025 1557.22E 5957985.17 551456.47 4.00 1465.02 3900.00 60.31 161.96 2904.34 2805.34 1545.80S 1586.69E 5957904.60 551486.47 4.00 1545.80 4000.00 62.38 165.86 2952.30 2853.30 1630.105 1610.97E 5957820.47 551511.30 4.00 1630.10 4035.55 63.15 167.21 2968.57 2869.57 1660.84S 1618.32E 5957789.79 551518.86 4.00 1660.84 End of BuildlTurn 4063.06 63.15 167.21 2981.00 2882.00 1684.775 1623.76E 5957765.89 551524.45 0.00 1684.77 Top UQnu B 4100.00 63.15 167.21 2997.69 2898.69 1716.915. 1631.05E 5957733.80 551531.96 0.00 1716.91 All data is in Feet unless otherwise stated Coordinates are from 510t MD's are from Rig and TVD's are from Rig ( Datum #1 99.0ft above mean sea level) Vertical Section is from O.OON O.OOE on azimuth 180.00 degrees Bottom hole distance is 7294.05 Feet on azimuth 166.51 degrees from Wellhead Calculation method uses Minimum Curvature method Prepared by Baker Hughes Incorporated . . conocJPhillips ConocoPhillips Alaska, Inc.,Slot #166 Pad 1 E, Kuparuk River Unit,North Slope, Alaska PROPOSAL LISTING Page 3 Wellbore: 166 Wellpath: 166 Ver#3 Date Printed: 29-Jul-2004 ".. BAlCER NUGHIS INTEQ Wellpath Report MD[ft] Inc[deg] Azi[deg] TVD[ft] Vertical North[ft] East[ft) 8tation 8tation Dogleg Vertical 8tation Comment Depth 88 Position(Grid Position(Grid [deg/10 8ection[f North) East) Oft] tI 4102.91 63.15 167.21 2999.00 2900.00 1719.448 1631.62E 5957731.28 551532.55 0.00 1719.44 Top UQnu A 4200.00 63.15 167.21 3042.86 2943.86 1803.92S 1650.79E 5957646.94 551552.28 0.00 1803.92 4206.56 63.15 167.21 3045.82 2946.82 1809.62S 1652.09E 5957641.24 551553.61 0.00 1809.62 Start 200' Pump TanQent 4300.00 63.15 167.21 3088.03 2989.03 1890.928 1670.54E 5957560.08 551572.60 0.00 1890.92 4399.55 63.15 167.21 3133.00 3034.00 1977.53S 1690.19E 5957473.61 551592.82 0.00 1977.53 K-13 4400.00 63.15 167.21 3133.20 3034.21 1977.93S 1690.28E 5957473.21 551592.91 0.00 1977.93 4406.56 63.15 167.21 3136.17 3037.17 1983.638 1691.57E 5957467.52 551594.25 0.00 1983.63 End 200' Pump TanQent. End of Hold 4500.00 66.63 168.71 3175.82 3076.82 2066.37S 1709.20E 5957384.91 551612.42 4.00 2066.37 4600.00 70.37 170.23 3212.47 3113.46 2157.83S 1726.19E 5957293.58 551630.01 4.00 2157.83 4700.00 74.13 171.67 3242.95 3143.95 2251.868 1741.16E 5957199.65 551645.60 4.00 2251.86 4723.19 75.00 172.00 3249.12 3150.12 2273.998 1744.33E 5957177.54 551648.92 4.00 2273.99 End of BuildlTum 4800.00 75.00 172.00 3269.00 3170.00 2347.468 1754.66E 5957104.15 551659.74 0.00 2347.46 4823.18 75.00 172.00 3275.00 3176.00 2369.648 1757.77E 5957082.00 551663.00 0.00 2369.64 Top West 8ak 0, W8 1 E E2 D TOP RV8D062104, End of Hold 4900.00 75.00 172.00 3294.88 3195.88 2443.11S 1768.10E 5957008.60 551673.81 0.00 2443.11 4935.18 75.00 172.00 3303.99 3204.99 2476.768 1772.83E 5956974.99 551678.76 0.00 2476.76 End of Hold 4988.22 76.59 172.00 3317.00 3218.00 2527.688 1779.98E 5956924.12 551686.26 3.00 2527.68 C 5035.18 78.00 172.00 3327.32 3228.32 2573.048 1786.36E 5956878.81 551692.93 3.00 2573.04 5101.62 80.00 172.00 3340.00 3241.00 2637.63S 1795.44E 5956814.29 551702.44 3.00 2637.63 Top West 8ak B, End of Build 5200.00 80.00 172.00 3357.08 3258.08 2733.57S 1808.92E 5956718.45 551716.56 0.00 2733.57 5300.00 80.00 172.00 3374.45 3275.45 2831.09S 1822.63E 5956621.03 551730.91 0.00 2831.09 5349.25 80.00 172.00 3383.00 3284.00 2879.12S 1829.38E 5956573.05 551737.98 0.00 2879.12 A4 5400.00 80.00 172.00 3391.81 3292.81 2928.618 1836.33E 5956523.61 551745.26 0.00 2928.61 5500.00 80.00 172.00 3409.18 3310.18 3026.138 1850.04E 5956426.19 551759.61 0.00 3026.13 5600.00 80.00 172.00 3426.54 3327.54 3123.66S 1863.74E 5956328.77 551773.96 0.00 ' 3123.66 5648.71 80.00 172.00 3435.00 3336.00 3171.16S 1870.42E 5956281.32 551780.95 0.00 3171.16 A3 .-200.00 80.00 172.00 3443.91 3344.91 3221.18S 1877 .45E 5956231.36 551788.32 0.00 3221.18 ~OO.OO 80.00 172.00 3461.27 3362.27 3318.708 1891.15E 5956133.94 551802.67 0.00 3318.70 5900.00 80.00 172.00 3478.64 3379.64 3416.228 1904.86E 5956036.52 551817.02 0.00 3416.22 6000.00 80.00 172.00 3496.00 3397.00 3513.758 1918.57E 5955939.10 551831.37 0.00 3513.75 6091.58 80.00 172.00 3511.90 3412.90 3603.068 1931.12E 5955849.88 551844.51 0.00 3603.06 End of Hold 6116.22 80.86 172.00 3516.00 3417.00 3627.12S 1934.50E 5955825.84 551848.05 3.50 3627.12 A2 6191.58 83.50 172.00 3526.25 3427.25 3701.04S 1944.89E 5955752.00 551858.93 3.50 3701.04 6291.58 87.00 172.00 3534.53 3435.53 3799.72S 1958.76E 5955653.43 551873.45 3.50 3799.72 6375.38 89.93 172.00 3536.77 3437.77 3882.66S 1970.41 E 5955570.57 551885.66 3.50 3882.66 End of Build 6475.38 91.03 172.00 3535.93 3436.93 3981.688 1984.33E 5955471.65 551900.23 1.10 3981.68 6575.38 92.13 172.00 3533.17 3434.17 4080.678 1998.24E 5955372.77 551914.80 1.10 4080.67 6675.38 93.23 172.00 3528.49 3429.49 4179.59S 2012.14E 5955273.96 551929.36 1.10 4179.59 6728.47 93.82 172.00 3525.22 3426.22 4232.068 2019.52E 5955221.54 551937.08 1.10 4232.06 End of Build 6800.00 93.82 172.00 3520.46 3421.46 4302.74S 2029.45E 5955150.94 551947.48 0.00 4302.74 6819.08 93.82 172.00 3519.19 3420.19 4321.598 2032.10E 5955132.10 551950.25 0.00 4321.59 End of Hold 6919.08 92.72 172.00 3513.49 3414.49 4420.458 2046.00E 5955033.34 551964.80 1.10 4420.45 7019.08 91.62 172.00 3509.71 3410.71 4519.418, 2059.90E 5954934.49 551979.37 1.10 4519.41 7119.08 90.52 172.00 3507.85 3408.85 4618.42S 2073.82E 5954835.59 551993.94 1.10 4618.42 7172.17 89.93 172.00 3507.64 3408.64 4670.99S 2081.21 E 5954783.07 552001.67 1.10 4670.99 End of Drop 7200.00 89.69 172.86 3507.73 3408.73 4698.58S 2084.87E 5954755.51 552005.52 3.20 4698.58 7300.00 88.84 175.94 3509.01 3410.01 4798.08S 2094.63E 5954656.09 552015.94 3.20 4798.08 7400.00 87.98 179.03 3511.79 3412.79 4897.938 2099.02E 5954556.28 552020.99 3.20 4897.93 7500.00 87.14 182.12 3516.04 3417.04 4997.828 2098.02E 5954456.39 552020.66 3.20 4997.82 7504.36 87.10 182.25 3516.26 3417.26 5002.178 2097.86E 5954452.04 552020.52 3.20 5002.17 End of DropfTum All data is in Feet unless otherwise stated Coordinates are from Slot MD's are from Rig and TVD's are from Rig ( Datum #1 99.0ft above mean sea level) Vertical 8ection is from O.OON O.OOE on azimuth 180.00 degrees Bottom hole distance is 7294.05 Feet on azimuth 166.51 degrees from Wellhead Calculation method uses Minimum Curvature method Prepared by Baker Hughes Incorporated . . ConocriP'hillips ConocoPhillips Alaska, Inc.,Slot #166 Pad 1 E, Kuparuk River Unit,North Slope, Alaska PROPOSAL LISTING Page 4 WeJlbore: 166 WeJlpath: 166 Ver#3 Date Printed: 29-Jul-2004 We II path Report , I MD[ft] Inc[deg] 'Azi[deg] TVD[ft] Vertical North[ft] East[ft] 8tation 8tation Dogleg Vertical 8tation Comment Depth 88 Position(Grid Position(Grid [deg/10 8ection[f North) East) Oft] tl 7600.00 87.10 185.12 3521.10 3422.10 5097.488 2091.72E 5954356.70 552015.01 3.00 5097.48 7642.59 87.10 186.40 3523.26 3424.26 5139.808 2087.45E 5954314.36 552011.02 3.00 5139.80 End of BuildlTum 7700.00 87.59 188.17 3525.91 3426.91 5196.698 2080.17E 5954257.43 552004.13 3.20 5196.68 7800.00 88.45 191.26 3529.37 3430.37 5295.18S 2063.30E 5954158.84 551987.92 3.20 5295.18 7802.10 88.47 191.32 3529.42 3430.42 5297.24S 2062.89E 5954156.78 551987.52 3.20 5297.24 End of BuildlTurn 7900.00 89.54 191.32 3531.12 3432.12 5393.228 2043.67E 5954060.69 551968.94 1.10 5393.22 8000.00 90.64 191.32 3530.96 3431.96 5491.27S 2024.04E 5953962.52 551949.96 1.10 5491.27 8009.84 90.75 191.32 3530.84 3431.84 5500.918 2022.11E 5953952.86 551948.09 1.10 5500.91 End of BuildlTurn 8109.84 91.85 191.32 3528.56 3429.56 5598.94S 2002.48E 5953854.71 551929.11 1.10 5598.94 8209.84 92.95 191.32 3524.37 3425.37 5696.908 1982.86E 5953756.63 551910.15 1.10 5696.90 8305.02 94.00 191.32 3518.60 3419.60 5790.068 1964.21E 5953663.36 551892.12 1.10 5790.06 End of Build 8400.00 94.00 191.32 3511.97 3412.97 5882.978 1945.61E 5953570.34 551874.13 0.00 5882.97 8500.00 94.00 191.32 3505.00 3406.00 5980.788 1926.02E 5953472.41 551855.20 0.00 5980.78 8539.54 94.00 191.32 3502.24 3403.24 6019.468 1918.27E 5953433.69 551847.71 0.00 6019.46 End of Hold 8639.54 92.90 191.32 3496.22 3397.22 6117.338 1898.68E 5953335.69 551828.77 1.10 16117.33 8739.54 91.80 191.32 3492.12 3393.12 6215.308 1879.06E 5953237.61 551809.80 1.10 6215.30 8834.72 90.75 191.32 3490.00 3391.00 6308.608 1860.38E 5953144.19 551791.74 1.10 6308.61 3D8 Kick off Point 8900.00 90.04 191.36 3489.55 3390.55 6372.618 1847.54E 5953080.11 551779.33 1.10 6372.61 9000.00 88.94 191.41 3490.45 3391 .45 6470.64S 1827.80E 5952981.96 551760.25 ' 1.10 6470.63 9100.00 87.84 191.46 3493.26 3394.26 6568.61 S 1807.98E 5952883.87 551741.08 1.10 6568.61 9155.45 87.23 191.49 3495.65 3396.65 6622.90S 1796.96E 5952829.51 551730.42 1.10 6622.90 End of DroplTum 9200.00 87.23 191.49 3497.80 3398.80 6666.495 1788.10E 5952785.87 551721.85 0.00 6666.49 9300.00 87.23 191.49 3502.64 3403.63 6764.325 1768.20E 5952687.91 551702.60 0.00 6764.33 9315.00 87.23 191.49 3503.36 3404.36 6779.005 1765.22E 5952673.22 551699.72 0.00 6779.00 End of Hold I 9415.00 88.33 191.49 3507.24 3408.24 6876.925 1745.31E 5952575.18 551680.46 1.10 6876.92 I 9515.00 89.43 191.49 3509.19 3410.19 6974.89S 1725.39E 5952477.09 551661.19 1.10 6974.89 9615.00 90.53 191.49 3509.23 3410.23 7072.898 1705.4 7E 5952378.97 551641.92 1.10 7072.89 1 9635.36 90.75 191.49 3509.00 3410.00 7092.848 1701.41E 5952359.00 551638.00 1.10 7092.83 TD, W8 1 E E2 A2 TOE RV5D0621 04, 1/2in Liner, End of Build All data is in Feet unless otherwise stated Coordinates are from 810t MD's are from Rig and TVD's are from Rig ( Datum #1 99.0ft above mean sea level) Vertical Section is from O.OON O.OOE on azimuth 180.00 degrees Bottom hole distance is 7294.05 Feet on azimuth 166.51 degrees from Wellhead Calculation method uses Minimum Curvature method Prepared by Baker Hughes Incorporated -- . '¡w/ ConocòPhillips ConocoPhillips Alaska, Inc.,Slot #166 Pad 1 E, Kuparuk River Unit,North Slope, Alaska PROPOSAL LISTING Page 5 Well bore: 166 Wellpath: 166 Ver#3 Date Printed: 29-Jul-2004 B.. BAkER HUGHES INTEQ Comments MOlftl TVOlftl Eastlftl Northlftl Comment 400.00 400.00 O.OOE O.OON KOP 1583.33 1458.71 332.36E 278.88S EOC 1630.45 1489.00 360.01 E 302.08S Base Permafrost 1971.15 1708.00 559.94E 469.85S Top T-3 2430.09 2003.00 829.26E 695.838 Top K-15 3514.28 2693.00 1445.78E 1257.078 Top UQnu C ~3.06 2981.00 1623.76E 1684.77S Top Uanu B 4102.91 2999.00 1631.62E 1719.44S Top UQnu A 4206.56 3045.82 1652.09E 1809.62S 8tart 200' Pump Tanaent 4399.55 3133.00 1690.19E 1977.538 K-13 4406.56 3136.17 1691.57E 1983.638 End 200' Pump TanQent 4823.18 3275.00 1757.77E 2369.648 Top West 8ak 0 4988.22 3317.00 1779.98E 2527.68S C ~1.62 3340.00 1795.44E 2637.63S Top West Sak B 5349.25 3383.00 1829.38E 2879.128 A4 5648.71 3435.00 1870.42E 3171.168 A3 6116.22 3516.00 1934.50E 3627.12S A2 9635.36 3509.00 1701.41E 7092.848 TD Hole Sections Diameter 8tart 8tart Start Start End End lEnd End\nEast[ft] Wellbore finl MOlftl TVDlftl Northlftl Eastlftl MOlftl TVDlftl Northlftl 131/2 0.00 0.00 O.OON O.OOE 2890.59 2299.00 922.588 1099.49E 166 97/8 2890.59 2299.00 922.58S 1099.49E 6116.22 3516.00 3627.128 1934.50E 166 63/4 6116.22 3516.00 3627.12S 1934.50E 9635.36 3509.00 7092.848 1701.41E 166 Casinas Name Top Top Top Top 8hoe 8hoe 8hoe Shoe Wellbore MOlftl TVDlftl Northlftl Eastlftl MDlftl TVDlftl Northlftl Eastlftl 10 3/4in Casina 0.00 0.00 O.OON O.OOE 2890.59 2299.00 922.588 1099.49E 166 7 5/8in Casina 0.00 0.00 O.OON O.OOE 6116.22 3516.00 3627.12S 1934.50E 166 4 1/2in Liner 4823.18 3275.00 2369.64S 1757.77E 9457.46 3250.00 6942.02S 1732.42E 166L2 4 1/2in Liner 5101.62 3340.00 2637.638 1795.44E 9463.19 3320.00 6942.02S 1732.42E 166L 1 4 1/2in Liner 6116.22 3516.00 3627.128 1934.50E 9635.36 3509.00 7092.84S 1701.41E 166 Taraets Name Northlftl Eastlftl TVOlftl Latitude LonQitude EastinQ NorthinQ WS 1E E2 A2 TOE 7092.84S 1701.41E 3509.00 N70 16 50.1091 W149 34 55.8595 551638.00 5952359.00 RVS0062104 W8 1 E E2 0 TOP 2369.64S 1757.77E 3275.00 N70 17 36.5613 W149 34 54.1858 551663.00 5957082.00 RV800621 04 WS 1E E2 4923.208 2097.86E 3538.00 N70 17 11 .4463 W149 34 44.2951 552020.00 5954531.00 A2-MOPT#1 RV80062104 All data is in Feet unless otherwise stated Coordinates are from Slot MO's are from Rig and TVD's are from Rig ( Oatum #1 99.0ft above mean sea level) Vertical Section is from O.OON O.OOE on azimuth 180.00 degrees Bottom hole distance is 7294.05 Feet on azimuth 166.51 degrees from Wellhead Calculation method uses Minimum Curvature method Prepared by Baker Hughes Incorporated e . conocJPhillips ConocoPhillips Alaska, Inc.,Slot #166 Pad 1 E, Kuparuk River Unit,North Slope, Alaska PROPOSAL LISTING Page 6 Well bore: 166 Wellpath: 166 Ver#3 Date Printed: 29-Jul-2004 ... 8AICIR HUGHIS INTEQ Survey Tool Program Reference I Survey Name 647695 Planned IMDlftl 9635.36 I TVOlftl 3509.00 I Survey Tool ISCWSA MWD I Error Model SA -:-26 J.~ MWO+SAG - ISCWSA - 28 Ja 03 OJH All data is in Feet unless otherwise stated Coordinates are from Slot MO's are from Rig and TVD's are from Rig ( Oatum #1 99.0ft above mean sea level) Vertical Section is from O.OON O.OOE on azimuth 180.00 degrees Bottom hole distance is 7294.05 Feet on azimuth 166.51 degrees from Wellhead Calculation method uses Minimum Curvature method Prepared by Saker Hughes Incorporated · ~ _ ConocoPhillips Alaska, Inc. I Location: North Slope, Alaska Slot: Slot #166 I Field: Kuparuk River Unit Well: 166 I Installation: Pad 1E Wel/bore: 166 ~ Jliì. ... ~<~~.~,.~_..~~,~.. INTEQ Scale 1 em = 200 ft -800 -400 0 400 East (feet) -> 800 1200 1600 2000 2400 2800 I SURFACE LOCATION: I 147' FNL, 640' FEL SEC. 21. T11N, R10E I KOP Start 200' Pump Tangent End 200' Pump Tangent 1 E-166 TOP WEST SAK D LOCATION: 2517' FNL, 1113' FWL SEC. 22, T11 N. R10E 1 E-166 TOP WEST SAK B LOCATION: 2495' FSL. 1150' FWL SEC. 22. T11N. R10E 1E-166 TOP WEST SAKA2 LOCATION: 1505' FSL. 1287' FWL SEC. 22. T11N, R10E 1E-166L1 & 1E-11L2 TDJ LOCATIONS: 1810' FNL, 1077' FWL SEC. 27. T11N. R10E Top K-15 "t;"'v 10 3/4in Casing Top Ugnu C Top Ugnu B Top Ugnu A K-13 C A4 A3 7 5/8in Casing J.L A2 3516 TVD 4 1/2in Liner 400 I 0 -400 -800 ~ -1200 - -1600 - -2000 - -2400 ~ -2800 -3200 ^ J Z 0 -3600 ::.1- :T - ëi3' - -4000 ~ - I - -4400 - -4800 - -5200 ~ -5600 - -6000 - -6400 -6800 en £ m -7200 ;:: 3 II -7600 ~ o ;::I> Conoc~illips Created by : Planner Date plotted: 26-Jul-2004 Plot reference is 166. Ref wellpath is 166 Verlf3. Coordinates are in feet reference Slot #166. True Vertical Depths are reference Rig Datum. Measured Depths are reference Rig Datum. Rig Datum: Datum #1 Rig Datum to mean sea level: 99.00 ft. Plot North is aligned to TRUE North. 4: 0 -300 LO ..... II E u 0 ..... Q) ~ en 300 600 900 :t:i" m 1200 .... - .c - Q. 1500 Q) C ëã 1800 (.) :e Q) > 2100 Q) ::s .. I- 2400 I V 2700 3000 3300 3600 3900 ConocoPhillips Alaska, Inc. ConocóPhillips Location: North Slope, Alaska Field: Kuparuk River Unit Installation: Pad 1 E Slot: Slot#166 Well: 166 Wellbore: 166 INTÈQ _m___ --~,--- -~--~~-- r--------created by : Planner Date plotted: 26-Jul-2004 Plot reference is 166. Ref weHpath is 166 Ver#3. Coordinates are in feet reference Slot #166. True Vertical Depths are reference Rig Datum. Measured Depths are reference Rig Datum. Rig Datum: Datum #1 Rig Datum to mean sea level: 99.00 ft. Plot North is aligned to TRUE North. I RKB Elevation: 99' KOP 6.00 . 18.00 25.00 DLS: 5.00 deg/100ft 10 3I4in Casing 50.91 52.04 Top Ugnu C 56.54 58.36 Top Ugnu 606~~38 Top Ognu A Start 200' Pump Tangent K-13 End 200' Pump Tangent 70.37 Iop W9sJ Sak D -- 4 1/2in Liner 166L2 TO TO 166L 1 4 1/2in Liner -....-LJ 7 5/8in casi~ "~ 51 ;; s ~ 4~/2i~~ij1661 -300 0 300 Scale 1 cm = 150 ft 600 900 1200 1500 1800 2100 2400 2700 3000 3300 3600 3900 4200 4500 4900 5100 5400 5700 6000 6300 Vertical Section (feet) -> Azimuth 130.00 with reference 0.00 N, 0.00 E from Slot #166 -- ..... iÑ'iEQ~ "" 3000 - o CD " Q r:l'lJ 0 foO? 5 3120 - S~'f. *"~~~â-'e, ell ~etö\. . fõ\~~e~ f( ~ ~- ~~~~~\ ~~~~ _ 3240 ~{\Ò :1-~ ~ . fõ\.O ~œ!.~e~ ...... 'ò 1'ò~ ~\'~~~U j - ~. Y~OÇ"fõeÒ~~ ' - ~. ~~~ - 3360 - '(>. . " , , .c S¥ Õ. ~etö\. Q) ~ oÇ C 3480 - A4 'ò'ò~\ 'iš u :e 3600 ~ Q) 3720 :3 I- .... I V I .-'---'- I 2160 2280 2400 2520 2640 Scale 1 cm = 60 ft 2760 2880 "" 3000 - o CD " 5 3120 - ell r¡ (fJ 3240 _ - ...... Q) .! - 3360 .c ...... Q. ~ 3480 CIS U :e ~ Q) :3 I- .... l~v~ _166L2 -166L1 .89.88 .89.60 =~ ,88.84 ,87.59 3600 3720 4560 4680 4800 4920 5040 Scale 1 cm = 60 ft 5160 5260 Co no co Phillips Alaska, Inc. Location: NQrth Slope, Alaska Field: Kuparuk River Unit Installation: Pad 1E Slot: Slot #166 Well: 166 Well bore: 166 ---_.__._----------~,- 83.50 I~~II I ---r--l---r-¡----,--, I 3000 3120 3240 3360 3480 3600 3720 3840 3960 Vertical Section (feet) -> Azimuth 180.00 with reference 0.00 N, 0.00 E from Slot #166 92.90 5400 5520 5640 5760 5880 6000 6120 6240 6360 Vertical Section (feet) -> Azimuth 180.00 with reference 0.00 N, 0.00 E from Slot #166 ConocJP'hillips Created by : Planne,- Date plotted: 26·Jul·2004 Plot reference is 166. Ref wenpath is 166 Ver#3. Coordjnates are in feet reference Slot #166. True Vertical Depths are reference Rig Datum. Measured Depths are reference Rig Datum~ Rig Datum: Datum #1 Rig Datum to mean sea level: 99.00 ft. Plot North is aligned to TRUE North. ,,--, I I ---r 4080 4200 4320 4440 4560 4680 1166L2) . /166L2) ~ -¡---'--Ti 4800 4920 4 1/2in Liner e ~166L2 =:L 166L 1 ~ 4 1/2in Liner ~- 4112in Liner --Æ1661 ~ 6480 6600 6720 6840 6960 7080 7200 11""" ... IN'f¡;¡¡-" e . -- ConocoPhillips Alaska, Inc. Location: North Slope, Alaska Field: Kuparuk River Unit Installation: Pad 1E Slot: Slot #166 Well: 166 Well bore: 166 Conocó"Phillips @ ~. ~ NORTH Created by: Planner Date plotted: 29-Jul-2004 Plot reference is 166. Ref wellpath is 166 Ver#3. Coordinates are in feet reference Slot #166. True Vertical Depths are reference Rig Datum. Measured Depths are reference Rig Datum. Rig Datum: Datum #1 Rig Datum to mean sea level: 99.00 ft. Plot North is aligned to TRUE North. 30b o 10 ~ ~.. 340 20 ". 330 2300 30 --'-..-- 40 '<26A/ 320.... 310 50 C2lI7Øìo· ". ~....... 60 70 ~. ~, 80 270 90 ~/ 100 250 240 230 1900 1Zó~ 220 !!oo/ V9B / 210 / / / 150 €J 200 / 190 /160 180 1100170 @ðf; €J Normal Plane Travelling Cylinder - Feet All depths shown are Measured depths on Reference Well e . Riitl IlAKER - IN'ŒQ Location: North Slope. Alaska Field: Kuparuk River Unit Installation: Pad 1E ConocoPhillips Alaska, Inc. Slot: Well: Wellbore: Slot #166 166 166 Conocó'Phillips Created by: Planner Date plotted: 29-JuJ..2004 Plot reference is 166. Refwellpath is 166 Ver#3. Coordinates are in feet reference Slot #166. True Vertical Depths are reference Rig Datum. Measured Depths are reference Rig Datum. Rig Datum: Dalum #1 Rig Datum to mean sea level: 99.00 It. Plot North is aligned to TRUE North. 310 TRUE NORTH 350 0 340 330 30 40 50 60 70 80 100 '0 90 100 100 110 300 290 280 270 260 250 240 220 140 210 150 160 180 170 Normal Plane Travelling Cylinder - Feet All depths shown are Measured depths on Reference Well ConocoPhillips Alaska, Inc. "~ ^--~~..._--~~.-..._-- Cono ,^=~,,~^wm_"w.~'·'~^%c" INn;Q location: North Slope, Alaska Field: Kuparuk River Unit Installation: Pad 1 E Slot: Slot #166 Well: 166 Wellbore: 166 Created by : Date plotted: 26.Jul·2004 Plot reference is 166. Ref well path is 166 Ver#3. Coordinates are in feet reference Slot #166. True Vertical Depths.<i\rereference Rig Datum. Measured Depths are reference Rig Datum. Rig Datum: Datum #1 Rig Datum to me¡¡n S!la level: 99.00 ft. Plot North is aligned to TRUE North. Scale 1 cm = 10 ft -40 -20 0 20 40 60 East tfeet) -> 80 100 120 140 160 180 200 220 240 "-$9CIIDO . 1200 1300 120 100 ~) 700 1200 80 60 40 20 0 -20 -40 ^ , Z 0 -60 :::1- :T - ø' -80 C'I) ... - -100 -120 - -140 -160 1100 -180 en 1400 -200 £ m ~ -'" (~ 0 - -220 : 3 It -'" 0 -240 ;: ¡ 900 I!) 1400 2000 1000 1200 130cP 300500 600 2100 1100 300 500 600 1300\ 1000 (277 ~J ~5ôð~ .2~0 ", 3400 3700 4000 , &.&.00 4800 47Ò046\JO 700 2400 800 ~ ConocoPhillips Alaska., Inc. Alaska Field: Kuparuk River Unit Installation: Pad 1E Slot: Slot #166 Well: 166 Wellbore: 166 conocJí)tdllips _ wm"~N.~~""""'~N INTEQ Created by : Planner Date plotted: 26·Jul~2004 Plot reference is 166. Ref well path is 1<>6 Ver#3. Coordinates are in faet reference Slot #166. True Vertical Depths are reference Rig Datum. Measured Depths are reference Rig Datum. Rig Datum: Datum #1 Rig Datum to mean saa level: 99.00 ft. Plo! North is aligned !o TRUE North. Scale 1 cm = 20 ft 200 240 280 320 360 400 East (feet) -> 440 480 526 560 600 640 680 720 760 800 I ~ -80 1100 1800 1200 2500 1900 2600 1200 1300 2000 2700 " 3900 ~ -160 - -120 -200 -240 - -280 - -320 - -360 1700 2100 - -400 Z o ::+ '::t' - -440 ;' ø - .......... -480 1400 -520 1800 -560 -600 1400 -640 1500 -680 - -720 (J) £ ro 1900 \9 \§ II - -760 \.) o ;::p INTEQ Scale 1 cm ::: 20 ft 680 720 760 800 2300 1500 ConocoPhillips Alaska., Inc. North Slope, Alaska Field: Kuparuk River Unit Installation: Pad 1 E 840 East (feet) -> 920 1360 1000 880 1600 3000 3100 2400 ./ì 2500 ¡/.>': \ ~\ \\~ Slot: Slot #166 Well: 166 Well bore: 166 1040 1080 1120 ~ 4600 4700 1700 / 3200 3300 ~/ ConocoPhillips Created by. Planner Date plotted: 26-Jul-2004 Plot reference is 166. Ref well path is 166 Ver#3. Coordinates are in feet reference Slot #166. True Vertical Depths are reference Rig Datum. Measured Depths are reference Rig Datum. Rig Datum: Datum #1 Rig Datum to mean sea level: 99.00 ft. Plot North is aligned to TRUE North. 1160 1200 1240 -440 2300 -480 -520 -560 4800 -600 -640 4900 -680 -720 -760 ^ I Z 0 -800 ;::¡. :T - ;' -840 (j) - - -880 (~! -920 "...../J -960 2400 -1000 -1040 en -1080 () ro CD () -1120 :3 II N 0 -1160 ~ ConoeoPhillips Alaska, Ine.. ¡Uips Conoe _~_______~_~______~..m__'~~_____"'____ __ _ ____~.___~~ Location: North Slope, Alaska Field: Kuparuk River Unit Installation: Pad 1 E Slot: Slot #166 Well: 166 Wellbore: 166 iÑ'f"EQ···mmm.... Created by: Planner Date plotted: 26..Jul-2QQ4 Plot reference is 166. Ref well path is 166 Ver#3. Coordinates ara in feet reference Slot #166. True Vertical Depths are reference Rig Datum. Measured Depths are reference Rig Datum. I Rig Datum: Datum #1 Rig Datum to mean sea level: 99.00 ft. Plot North is aligned to TRUE North. Scale 1 cm = 50 ft 1000 1100 1200 1300 1400 1500 East (feet) -> 1600 1700 1800 1900 2000 2100 2200 2300 2400 2500 [?2!)~ "' '. ..... 5700 "" 35ÓÖ "' "' -900 - -1000 58?0133!)¡= 5500 5600 5700 5800 -1100 , "\ 3600 Ln_ - -1200 2000 3700 2700 ~500 2400 3800 300" 6000 - -1300 6100 6200 6300 6400 6500 6600 6700 3500 2100 3900 2800 -1400 '~ 2300 3600 2200 -1500 2900 3700 - -1600 ^ . /í 3800 \2/ 3899.99 2900 4000 3000 \~ 3100 4000 3200 4100 \~~0 -1700 Z o ~ :::::r -1800 -:::;¡ (þ (þ - - ~ 3000 - -1900 3100 -2000 -2100 -2200 -2300 -2400 (J) (") ID m -2500 -" II -2600 (j o ;:t> Conoco:Pbillips Alaska, Inc. î¡;r'ÎiQ~^m'm Field: Kuparuk River Unit Installation: Pad 1 E Well: 166 Wellbore: 166 Scale 1 em = 100 ft 800 1000 1200 1800 East (feet) -> 2000 ~200 2400 2600 2800 1400 1600 ~4900 5100 , f..~---;;1, \\ \ ~ (--3 \, ~!) 5300 "l31l 3300 §§t!t! \wwtJ: \ ~ L[111~ ~-ITv \~ r..::;.\. \~ ~j - 5300 5500 5700 5900 6100 6300 '" 6500 [~-~] 5500 5700 4300 Canoe ¡Uips /" ------Cre~-·-Planner Date plotted: 26-Jul-2004 Plot refarance is 166. Raf wellpath is 166Var#3, Coordinates are in faat reference 510t#166. True Vertical Depths are referenca Rig Datum, Measuraq Depths are ",ference Rig Datum. Rig Datum: DatJJm #1 Rig Datum to mean sea level: 99.00 ft. Plot North is aligned to TRUE North, 3000 3200 3400 3600 5900 -2400 -2600 -2800 -3000 -3200 -3400 -3600 -4400 -4600 -4800 -5000 -5400 en (") 00 ¡j) -5600 II ConoeoPhilUps Alaska, Inc. Cono~ i^¡;¡:rE¡:r·~···m^'^ Well: 166 Wellbore: 166 Field: Kuparuk River Unit Installation: Pad if Date Plot Rei wellpath is 166 Ver#3. Coordinates are in I¡¡et r¡¡l¡¡r¡¡pGe$IPt#166. Tru¡¡ Vertical Depths are r¡¡lerenG¡¡Rigpatum. Measured Depths are relerenGe Rig Datum. Rig Datum: Datum #1 Rig Datum to mean s"a level: 99.00 ft. Plot North is aligned to TRUE North. East (feet) -> 18DO ~OOO 2200 2400 2600 2800 3000 3200 3400 Scale 1 cm :::: 100 ft 600 800 1000 1600 1200 1400 -5000 -5200 -5400 -5600 -5800 3600 -6000 -6200 -6400 -6600 ^ I 5000 5050 5100 5150 5200 5250 5300 4350 4400 4450 4500 4550 4600 2700 2750 2800 5350 5400 5450 5500 5550 5600 5650 5700 5750 5800 5850 5900 r--..::;.:¡ \~ 19 2850 2900 2950 5100 5150 5200 5250 5300 5350 5400 5450 5500 5550 5600 3100 6000 3000 3150 3050 -7200 3200 3100 -7400 3250 3150 -7600 -7800 3250 -8000 (j) @ -8200 (Õ 3300 ...... (") 3 -8400 II ...... g -8600 3450 '~--~--:I :~ \ ....).; I~ '''-.../ ,--- ~ 113 -- L .aker Hughes Incorporatl Anticollision Report GLOBAL SCAN APPLIED: All well paths within 200'+ 100/1000 of reference Interpolation Method: MD Interval: 25.00 ft Depth Range: 0.00 to 9632.29 ft Maximum Radius: 5280.00 ft Reference: Error Model: Scan Method: Error Surface: Principal Plan & PLANNED PROGRAM ISCWSA Ellipse Trav Cylinder North Ellipse Survey Program for Definitive Wellpath Date: 12/10/2003 Validated: No Planned From To Survey ft ft 0.00 9632.29 Planned: 1E-166 Vers#3 V18 Version: Toolcode Tool Name MWD+SAG+IFR MWD+SAG+IFR (AK) Summary Pad 1 E 112 1E-112L1 V3 399.99 400.00 535.58 5.79 529.78 Pass: Major Risk Pad 1 E 112 1E-112L2V2 399.99 400.00 535.58 5.79 529.78 Pass: Major Risk Pad 1 E 117 117 A2-Lateral VO Plan 1675.78 1525.00 276.21 42.82 233.39 Pass: Major Risk Pad 1 E 117 117 B-Lateral VO Plan: 1675.78 1525.00 276.21 42.82 233.39 Pass: Major Risk Pad 1 E 117 117 D-Lateral VO Plan: 1675.78 1525.00 276.21 42.82 233.39 Pass: Major Risk Pad 1 E 119 119VOPlan: 1E-119Ve 1659.61 1525.00 218.84 36.28 182.57 Pass: Major Risk Pad 1 E 166 1E-166L1 V1 Plan: 1E-1 3850.00 3850.00 0.87 171.82 -170.95 FAIL: Major Risk Pad 1 E 166 1E-166L2 V1 Plan: 1E-1 3850.00 3850.00 0.87 171.82 -170.95 FAIL: Major Risk Pad 1 E 168 168 A2-Lateral V3 Plan 374.98 375.00 60.45 5.44 55.01 Pass: Major Risk Pad 1 E 168 168 B-Lateral VO Plan: 374.98 375.00 60.45 5.44 55.01 Pass: Major Risk Pad 1E 168 168 D-Lateral VO Plan: 374.98 375.00 60.45 5.44 55.01 Pass: Major Risk Pad 1 E 170 170 A2-Lateral VO Plan 275.00 275.00 99.82 3.30 96.51 Pass: Major Risk Pad 1 E 170 170 B-Lateral VO Plan: 275.00 275.00 99.82 3.30 96.51 Pass: Major Risk Pad 1E 170 170 D-Lateral VO Plan: 275.00 275.00 99.82 3.30 96.51 Pass: Major Risk Pad 1 E 2 1E-02 VO 443.58 450.00 441.23 6.16 435.07 Pass: Major Risk Pad 1 E 26 1 E-26 VO 1562.68 1600.00 198.08 34.03 164.04 Pass: Major Risk Pad 1 E 26 1 E-26A VO 1562.68 1600.00 198.08 34.03 164.04 Pass: Major Risk Pad 1 E 27 1 E-27 VO 1010.79 1000.00 126.30 17.48 108.81 Pass: Major Risk Pad 1 E 28 1 E-28 VO 726.22 725.00 28.49 10.90 17.59 Pass: Major Risk Pad 1 E 29 1 E-29 VO 448.58 450.00 80.56 6.24 74.32 Pass: Major Risk Pad 1E 30 1 E-30 VO 446.85 450.00 200.38 6.21 194.17 Pass: Major Risk Pad 1E 34 1 E-34 VO 459.45 475.00 781.76 6.75 775.01 Pass: Major Risk Pad 1 E 35 1 E-35 V1 6462.38 6200.00 272.96 260.02 12.94 Pass: Major Risk Pad 1E 35 35A VO Plan: 35A ST Ve 6462.85 6200.00 288.85 260.65 28.20 Pass: Major Risk lE-166 erillina Hazards.ummary (SEE WELL PLAN AND ATTACHMENTS FOR DETAILED DISCUSSION OF THESE RISKS) 13-1/2" Open Hole /10-3/4" Casina Interval Hazard Broach of Conductor Gas Hydrates Running Sands and Gravels Hole swabbing on trips Risk Level Mitigation Strategy Low Monitor cellar continuously during interval. Moderate Control drill, Reduced pump rates, Reduced drilling fluid temperatures, Additions of Driltreat. Low Maintain planned mud parameters, Increase mud"weight, use weighted sweeps. Moderate Trip speeds, proper hole filling (use of trip sheets), pumping out 9-7/811 Open Hole / 7-5/8" Casing Interval Hazard Running Sands and Gravels Gas Hydrates Stuck Pipe Abnormal Reservoir Pressure Lost circulation Hole swabbing on trips Risk Level Low Low Low Low Low Moderate Mitigation Strategy Maintain planned mud parameters, Increase mud weight, use weighted sweeps. Control drill, reduced pump rates, reduced drilling fluid temperatures, additions of Driltreat. Good hole cleaning, pre-treatment with lost circulation material, stabilized BHA, decreased mud weight BOP training and drills, increased mud weight. Reduced pump rates, mud rheology, LCM Trip speeds, proper hole filling (use of trip sheets), pumping out 6-3/4" Open Hole / 4-1/2" Liner Interval Hazard Abnormal Reservoir Pressure Stuck Pipe Lost Circulation Hole Swabbing on Trips Risk Level Low Low Low Moderate Mitigation Strategy Stripping drills, shut-in drills, increased mud weight. Good hole cleaning, PWD tools, hole opener runs, decreased mud weight Reduced pump rates, mud rheology, LCM Trip speeds, proper hole filling (use of trip sheets),pumping out, backreaming 1E-166 Drilling Hazards Summary. doc prepared by Steve McKeever 8/10/2004 12:00 PM Preliminary Job Design based on limited input data. For estimate purposes only. Rig: Doyon 141 Location: West Sak Client: CPAI Revision Date: 8/4/2004 Prepared by: Mike Martin Location: Anchorage, AI< Phone: (907) 265~205 Mobile: (907) 229-6266 email: martin13@slb.com Icb blrger Volume Calculations and Cement Systems Volumes are based on 250% excess in the permafrost and 35% excess below the permafrost. The top of the tail slurry is designed to be at 2,100' MD. Lead Slurry Minimum pump time: 210 min. (pump time plus 90 min.) ARCTICSET Lite @ 10.7 ppg - 4.45 ft3/sk 3 0.6381 ft 1ft x (108') x 1.00 (no excess) = 0.3637 ft3/ft x (1630' - 108') x 3.50 (250% excess) = 0.3637 ft3/ft x (2100' -1630') x 1.35 (35% excess) = 68.9 ft3 + 1937.4 ft3+ 230.8 ft3 = 2237.1 ft3 /4.45 ft3/sk = Round up to 510 sks < TOC at Surface 68.9 ft3 1937.4 ft3 230.8 ft3 2237.1 ft3 502.7 sks Have 270 sks of additional Lead on location for Top Out stage, if necessary. Previous Csg. < 16",62.6# casing at 108' MD Tail Slurry Minimum pump time: 150 min. (pump time plus 90 min.) DeepCRETE @ 12.0 ppg - 2.49 ft3/sk 0.3637 ft3/ft x (2900' - 2100') x 1.35 (35% excess) = 0.5400 ft3/ft x 80' JShoe Joint) = 392.8 ft3 + 43.2 ft = 436 ft31 2.49 ft3/sk = Round up to 180 sks 392.8 fe 43.2 ft3 436 ft3 175.1 sks < Base of Permafrost at 1,630' MD (1,489' TVD) BHST = 51°F, Estimated BHCT = 66°F. (BHST calculated using a gradient of 2.6°F/100 ft. below the permafrost) PUMP SCHEDULE Pump Rate Stage Stage Time Cumulative Stage (bpm) Volume (min) Time (bbl) (min) CW100 5 50 10.0 10.0 < Top of Tail at Drop Bottom Plug 5.0 15.0 2,100' MD MudPUSH II 5 50 10.0 25.0 Lead Slurry 7 404 57.7 82.7 Tail Slurry 6 80 13.3 96.0 Drop Top Plug 5.0 101.0 Displacement 7 256 36.6 137.6 Slow Rate 3 15 5.0 142.6 < 103/4",45.5# casing in 13 1/2" OH MUD REMOVAL TO at 2,900' MD (2,305' TVD) Recommended Mud Properties: 9.5 ppg. Pv < 20, Ty < 30. As thin and light as possible to aid in mud removal during cementing. Spacer Properties: 10.5 ppg MudPUSH* II, Pv > 20, Ty > 30 Centralizers: Recommend 1 per joint across zones of interest for proper cement placement. Mark of Schlumberger Scb blllDlr Preliminary Job Design based on limited input data. For estimate purposes only. Rig: Doyon 141 Location: West Sak Client: CPAI Revision Date: 8/4/2004 Prepared by: Mike Martin Location: Anchorage, AK Phone: (907) 265-6205 Mobile: (907) 229-6266 email: martin13@slb.com Volume Calculations and Cement Systems Volumes are based on 60% excess. Tail slurry is designed for 523' MD above upper lateral window- (1816' MD annular length). Tail Slurry Minimum thickening time: 170 min. (Pump time plus 90 min.) DeepCRETE @ 12.5 ppg - 2.25 ft3/ft 3 0.2148ft 1ft x 1816' x 1.60 (60% excess) = 0.2578 ft31ft x 80' JShoe Joint) = 624.1 ft3 + 20.6 ft = 644.7 ft3/ 2.25 ft3/sk = Round up to 290 sks 624.1 ft3 20.6 ft3 644.7 ft3 286.5 sks Previous Csg. < 103/4",45.5# casing at 2,900' MD BHST = 83°F, Estimated BHCT = 72°F. (BHST calculated using a gradient of 2.6°F/100 ft. below the permafrost) PUMP SCHEDULE Pump Rate Stage Stage Time Cumulative Stage (bpm) Volume (min) Time (bbl) (min) CW100 5 30 6.0 6.0 Drop Bottom Plug 10.0 16.0 MudPUSH II 5 40 8.0 24.0 Tail Slurry 5 116 23.2 47.2 Drop Top Plug 10.0 57.2 Displacement 7 257 36.7 93.9 < Top of Tail at Slow Rate 3 20 6.7 100.6 4,300' MD MUD REMOVAL < 75/8", 29.7# casing in 9 7/8" OH Recommended Mud Properties: 9.2 ppg, Pv < 15, Ty < 15. As thin and light as possible to aid in mud removal during cementing. Spacer Properties: 10.5 ppg MudPUSH* II, Pv = 20-24, Ty = 22-29 ~ TD at 6,116' MD (3,516' TVD) Centralizers: Recommend 1 % per joint across zones of interest for proper cement placement. 6' ::1 o 8 -0'( æ;' &r= ~i ~ !IL en 1\1 "rI,," en~::V i''''&. «Dens:: -nn ~¡~ :i~ Q:~ n= ... rp ... Ø> Ø> ïi "'Q. ~~ "'!II "'~ ~~!g ~æf! ~¡¡'æ~ ~!~: Lateral Entry Module #1 (LEM), Baker, with seal bore and ZXP packer above. Insulated Conductor Casing, 20", 94#, K55 x 34", 0.312" WT@ \ - +1-108'MD r - 10-3/4",45.5#, L-SO, Special Drift, BTC \ (10542532) set @ +1- 2,S91' MD I 2,300' TVD ~ @ 50 degrees TD 13-1/2" hole Top of Ugnu C@3,~1f ----. MD 12,693' TVD Top of West SåkD@ 4,823' MD I 3,275' TVD ----. Top of West Sak 8 @ 5,102' MD 13,340' TVD----' Wellhead I Tubing Head / Tree, 13-51 r 8"x4-14", 5.000ksi Tubing String: 4-1/2",12.6 #, L- SD, IBT,AB Modiifed with Special _ ~ Clearance Couplings (4.920" ---.y' OD) ~ (1) Gas Lift Mandrels, (1062-2035) CAMCO 4-1/2" 10... / x 1" Model KBG-2, one 3 joints above ESP, one at ~ 2400' TVD. 1 E-166 As Built: ASP NAD 27 Easlings: 549.889.71 ASP NAD 27 Northings: 5.959,439.68 Pad Elevation: 70,4' AMSL Doyon Rig 141 Rig Floor (RF) @O' Elevation: 9S' AMSL 6 f£.\.3 iE.ø,\6 ton~\ O\feC . Electric Submersible Pump, Centrilift 41S HP motor, with FC6000 wireline ~ deployed pump. Bottom at 4,406' MD, ./' 3,136'TVD ¥' 166L2 D Sand Window@ +/- ~ 4,S23' MD 13,275' TVD, 75 ~ ¥ degrees 1E-166L2: 6-%" D sand lateral TD @ 7 9,457' MD 13,250' TVD ~:~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~I ~ D and B Sand Liners, 4-'1.", 12.6#, LSO, R3, DWC/C, every 1E-166L1: joint slotted, (0.125" x 2.5" 6-%" B sand lateral TD @ 7 slots, 32 per foot, 5.9% open 9,463' MD / 3,320' TVD area) ~~~~~~~~~~~~~~~~~~~~~~~[~~~~~~~~~~~~~~~~~~~~~~@~~~E~~~~~~~~~~I 166L 1 B Sand Window @ +1- ~ 5,102' MD 13,340' TVD, SO ¥ degrees . Tubing, 4-'1." IBTM, from LEM to A2 Liner, with seal stem and CAMCO 3.562" "DB" nipple. Top of West Sak A2 @ 6,116' MD 13,516' TVD----' 7-5/S", 29.7#, L-BO, BTCM J (10527S3S) Casing set @ +1- 6,116' MD I 3,516' TVD. Set @ S1 degrees TD 9-7/S" hole '- A2 Sand Liner, 4-'1.",12.6#, LSO, R3, DWC/C, with slots over sand, blank over shales, and constrictors for isolation. (0.125" x 2.5" slots, 32 per foot, 5.9% open area) R3 Slotted = 10783557, R2 Slotted = 10790121 R3 Blank =10794247. R2 Blank = 10790738 1 E-166: 6-%" A-Sand lateral TD @ 9,635' MD I 3,509' TVD · e SHARON K. ALLSUP-DRAKE 1060 CONOCOPHILLIPS ATO 1530 2.£C>4-. 700 G STREET 62-14/311 ANCHORAGE AK 99501 :~:;~¿;<~ ¿¡Are Of" 11~ 10.0. 0.0 <, ~ îAiiS 6J ~-... CHASE Chas. Manhatran Bank USA, N.A. , 200 Whit. CI" C'nt" D,.. New",. DE "71, .,: 16_/~~~~~ .: 03 · · 0 0 · ~ ~.: 2 òB ~ ? . 'i 0 ? 'i 2 nil' .0 ¡; 0 INlVf=RS'l!. . . TRANSMIT AL LETTER CHECK LIST CIRCLE APPROPRIATE LETTERIP ARAGRAPHS TO BE INCLUDED IN TRANSMITTAL LETTER WELLNAME¡fÆt1 /£-/bÇ PTD# dOL\. - \ S -:s x Development Service CHECK WHAT APPLIES ADD-ONS (OPTIONS) MULTI LATERAL (If API Dumber last two (2) digits are between 6.0-69) Exploration Stratigraphic ~'CLUEn Tbe permit is for a new well bore segment of existing wen . Permit No, API No. Production. should continue to be reponed as a function 'of tbe original API number. stated above. HOLE In accordance witb 2.0 AAC 25..0.05(1), an records, data and logs acquired for tbe pilot bole must be dearly differentiated In both name (name on permit plus PH) and API Dumber (SO 70/80) from records, data and logs acquired for well (name on permit). PILOT (PH) SPACING EXCEPTION DRY DITCH SAMPLE The permit is approved subject ·to fuD compliance with 20 AAC 25.05S~ Approval to perforate and produce is contingent upon issuance of ~ conservation order approving a spacing eneption. (Companv Name) assumes tbe Jiahility of any protest to tbe spacing .exception tbat may occur. AU dry ditcb sampJe sets submitted to tbe Commission must be in no greater ·tban 30' sample intervals from below tbe permafrost or from wbere samples are first caught and ] 0' sample iIiter:val.s tbrough target zones. Field & Pool KUPARUK RIVER. WEST SAK OIL - 490150 Well Name: KUPARUK RIV U WSAK 1E-166 Program DEV Well bore seg PTD#: 2041530 Company CONOCOPHILLlPS ALASKA INC Initial ClasslType DEV 11-01L GeoArea Unit On/Off Shore On Annular Disposal 1 Pß(miUee <!ttache.d. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Yes. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 2 .Le<!sßnumberappro¡:¡riate . . . . ... ...................... YßS . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 3 .UJlique weILn.amß.and ol!mb.er . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . YßS. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 4 We.IUQcatßd inadefioe~ppol . . . . . . . . . . . . . . . . . . YßS. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 5 We.IUQcatßd proper distance from driJling uoitbouod.a(y. . . .Yßs. . . . . . . CO <106A, RULE 3 sets Wsest Sak sp.acing <!t10ac per.well. . . . . . . . . . . . . . . . . . . . . . 6 We.IIJQc¡;Itßd proper .distance. from othe.r welJs. . . . . . . . . . . . . . . . . . . . . . . . . . Yßs . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 7S.utfjcieoLacre<!g.e.aY<!ilable in.drilliog l!njL . . . . . . . . . . . . . . . . . . Yes. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 8 Ifdßvi<!ted, js. weJlbQre platiocJu.ded . . . . . . . . . . . . . . . . . . YßS . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 90-pe(ator ooly <!ffected party. . . . . . . . . . . .. ........ YßS . . . . . . . . . . . . .. ............................ . . . . . . . . 10 .O-pe(ator has.apprppriate.bond inJorce. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . YßS. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 11 Pß(mit can be iSSl!ed withQut co.nserva.tioo order. . . . . . . . .. ................. Yes. . . . . . . . . . . . . . . . . . . . . . . . . . .. ............ ................ ........ Appr Date 12 Pß(mit c.an be iSSl!ed withQut <!d.mioist(atÎ\leapproval . .. ...... . . . . . . . . . . . . Yßs. ........................................................................ RPC 8/16/200413 Can permit be approved before 15-daywait Yes 14 We.IUQcatßd within <!rea <!ndstrata .authorized by Injection Order # {putlO# in.cPmments) (For NA . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .. ....................... 15 .AJI welJs. wit/lin .1l4.mile.are.a.of (eyiew idßotified (FO( servjCß .well ooly). . . . . . . . . . . . . . . .NA . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 16 Pre.-produ.ced injector; ~uratiQn.of pre--pro~uctipn less th<!n:3 mooths (For.service well onJy) . .NA . . . . . . . . . . . .. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 17 .ACMPFïndingofCon.slstenGy.h.as beenJssued.forJhis project . . . . . . . . . . . NA .. ............................................. ............... . . . . . . . . 18 .C.ondu.ctor st(ingprQvided . . . . . . . . . . . . . . . . . . . . . .. ............. YßS. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 19SuIT<!cßcasingprotects alLknown USDWs . . . . . . . . . . . . NA . . . 81l aquife.rs eXßmpled,40CFR1<I7.1Q21b)(3). . . . . . . . . 20CMT vol adeq uateJo circ.ulate. oJl.cood.uctor. & surf csg . . . . . . . . . . . . . . . Y ßS . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .. .......... 21 .CMT v.ol adequateJo tie-lnJQngstring to.SUIT csg. . . . . . . . . . . . No. . . . . . 81l hydrocarbQn.zone.s.will becPve.red.. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 22CMTwiIJ Goyera!l kno.wn.Pfo.ductiYe hQri;!:on.s. . . . . . . . . . . . . . . . . . . . . . No. . . . . . . . Slotte.dJiner.completion pLanned.. . . . . . . . . . . . . . . . . . . . . . . . . . . 23 .C.asing designs <!d.equa.te. fO( C,T~ B&permafrosl . . . . . . . . . . . . . . . . . . . . . . . . Yes. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 24 .A~equate.t<!n.kage.or re.serve pit. . . . . . . . . . . . . . . . YßS. . . . . . . Rig jse.quippe.dwith stßelpits.. No. rese.rve.pjt-planne.d. All waste to.apprpve.dannuJl!s.Of dispsaLweJI. . . . . . . . 25 Jfare-d(ilt h<!s.a. tOA03 fQr abandonmeJlt beßn apPJoved . . . . .NA . . . . . . . . . . . . . . . . . . . . . . . . . . . 26 .A~equate.wellbofe. sepªratjo.n-Pfo-posed. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . YßS. . . . . . .I?ro~imity. analysis pe.rto(me.d, J(ayeling cylioder path ~IGu!ate.d, GYrOS pos.sible, . . . . . . . . . . . . . . . . . . . 27 Jtdiverte.r re.quire.d, dQes iLmeel regulatioos . . . . . . . . . . . . . YßS . . . . . .. ............................................. ........... 28 .Drilling fluid prog.ram sc.hematic.& e.q.uipJisladequatß. . . . . . . . . . . .. Yßs.. ... Maximl!m expected formation pres.sure8.6. EMW.. MW planned 9.1 ppg in 9-7/8" /lole and. 9.0 pp.gin 6-3/<1" hoJe.. 29 .BOPEs, dO they meet regulatioo . . . . . . . . . . . . . . . . . . YßS. ...................... . . . . . . . . . . . . . . . . . . . . 30 ..B.OPE-Pfe.ssratiogapp(op(iate;te.stlo.(pu.tpsigln.comments)........ ......... yes..... .MASP~Ic.ulate.d.at1160psJ. CPAlpropos.estotesLBOPE.to30.00psi.. .......... 31 Choke manifold complies w/APL RP-5:3 (May 84) . . Yßs . . . . . . . . . . . . . . . . . . . .. ................................. 32 WQrk will OGC.U( withoutoperatjoJl.shl!tdo.wn. . . . . . . . . . . . . . . . . .YßS . . . . . . . . . . . . . .. ........................................................ 33 ls.pres.enceQfH2Sg<!sprobable...... .......... No...... .tl2Sisnolexpe.cted.. RigJse.q.uipped.with.senso(s.andalarms,............... 34 MeçhanicaLcondJtionofwe.lIswithinAORYe.rified(For.s.ervi~welJonIy)............. .NA........ ............ ......... ...... .............. Administration Engineering Appr Date TEM 8/16/2004 1ft ~I \y Geology Appr RPC Date 8/16/2004 Geologic Commissioner: - ~u - - - - - - - - - - - - - 35 Pe(milc.anbeisSl!edwlo.hydroge.ns.ulfideme<!s.u(es... ............ ..... Yßs..... . The.Wes.t SªkhasJow.lellels oftl2S <!t.thistjme..asthewaterfloodma turesthismay.chªnge....... . 36 .D.atapresented on. pote.ntial oveJpressure .zones. . .. ......... ............. NA . . . . . . . . . . . . . . . . . . . . . . . . .. ............... 37 .Sßismic.analysJs Qf shallow gas.zooe.s. . . . . . . . . NA . . . . . . . . . . .. ............ . . . . . . . . . .. ............ . . . . . . . . . . . 38Sßabedcondition Sl!rvey(if off-shore) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . NA . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 39 . CQnta.ct namelp/loneJor.weekly progress reports [explorato(yonly] . . . . . . . . . . . . . . . . NA . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Date: Engineering Commissioner: Date Public Commissioner Date 8/ 1£1 ~ D ~ . . e e 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 infomlation, 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. **** REEL HEADER **** LDWG 05/05/02 AWS 01 **** TAPE HEADER **** LDWG 05/05/02 01 *** LIS COMMENT RECORD *** . . doc/.-fS'"!J o I r 3 / (1 !!!!!!!!!!!!!!!!!!! LDWG File Version 1.000 !!!!!!!!!!!!!!!!!!! Extract File: LISTAPE.HED 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 3 C. WONG D. GLADDEN # SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION(FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: # WELL CASING RECORD 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING # REMARKS: OPEN HOLE BIT SIZE (IN) 42.000 13.500 9.625 6.750 lE-166 500292322000 ConocoPhillips Alaska, Inc. BAKER HUGHES INTEQ 02-May-05 MWD RUN 4 4 S. TUFT ON M. THORTON 21 llN 10E 98.40 70.40 CASING SIZE (IN) 20.000 10.750 7.625 MWD RUN DRILLERS DEPTH (FT) 108.0 3012.0 6014 . 0 9602.0 PER CONOCOPHILLIPS ALASKA STANDING ORDER, THE GAMMA RAY CURvE FROM THIS LOG IS THE DEPTH REFERENCE FOR THIS WELL. AS SUCH, NO DEPTH SHIFTS HAVE BEEN APPLIED. INDIVIDUAL MWD RUN DATA WAS MERGED IN THE FIELD PRIOR . . TO DELIVERY FROM THE WELL SITE. SURfACE LOCATION: LAT: N 70 DEG 17' 59.869" LONG: W149 DEG 35 I 45.414" LOG MEASURED FROM D.F. AT 98.4 FT. ABOVE PERM. DATUM (:M.S.L.) . COMMENTS: 1) Baker Hughes INTEQ runs 1 & 2 utilized an 8" directional only tool to drill from 108 to 3020 feet MD (108 to 2398 feet TVD). 2) Baker Hughes INTEQ run 3 utilized a 6.75" directional tool with a Multiple propagation Resistivity (MPR), Gamma Ray, along with Annular Pressure to drill from 3020 to 6020 feet MD (2398 to 3503 feet TVD). 3) Baker Hughes INTEQ run 4 utilized a 4.75" directional tool with a Multiple Propagation Resistivity (MPR), Gamma Ray, along with Annular Pressure to drill from 6020 to 9602 feet MD (3503 to 3518 feet TVD). REMARKS : 1) Depth of 10 3/4" casing Shoe - Driller: 3012 feet MD (2392 feet TVD). Depth of 10 3/4" Casing Shoe - Logger: 3012 feet MD (2392 feet TVD). 2) Depth of 7 5/8" Casing Shoe - Driller: 6014 feet MD (3501 feet TVD). Depth of 7 5/8" Casing Shoe - Logger: 6016 feet MD (3502 feet TVD). 3) The interval from 5977 to feet TVD) was not logged due 4) The interval from 9571 to feet TVD) was not logged due $ 6020 feet to 7 5/8" 9602 feet to sensor MD (3494 to 3503 casing. (3517 to 3518 offsets at TD. Tape Subfile: 1 78 records... Minimum record length: Maximum record length: 8 bytes 132 bytes **** FILE HEADER **** LDWG .001 1024 *** LIS COMMENT RECORD *** ! ! ! ! ! ! ! ! !! !! ! ! ! ! ! ! ! !!!!!!!!!!!!!!!!!! ! FILE HEADER FILE NUMBER: EDITED MERGED MWD Depth shifted and DEPTH INCREMENT: # FILE SUMMARY PBU TOOL CODE MWD $ LDWG File Version 1.000 Extract File: FILE001.HED 1 clipped curves; all bit runs merged. .5000 START DEPTH 3012.0 STOP DEPTH 9602.0 # BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH $ # MERGED DATA SOURCE . . PBU TOOL CODE MWD MWD $ BIT RUN NO 3 4 MERGE TOP 3012.0 5977.0 MERGE BASE 5977.0 9602.0 # REMARKS: MERGED PASS. NO DEPTH SHIFTS WERE APPLIED AS THIS LOG IS THE DEPTH REFERENCE FOR THIS WELL. $ # *** INFORMATION TABLE: CONS MNEM VALU ------------------------------------ WDFN LCC CN WN FN COUN STAT 1e-166 5.xtf 150 ConocoPhillips Alaska, Inc. 1E-166 Kuparuk River North Slope Alaska *** INFORMATION TABLE: CIFO MNEM CHAN DIMT CNAM ODEP ---------------------------------------------------- GR GR GRAM 0.0 RPD RPD RPD 0.0 RPM RPM RPM 0.0 RPS RPS RPS 0.0 RPX RPX RPX 0.0 ROP ROP ROP 0.0 FET FET RPTH 0.0 * FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame Size is: 32 bytes Logging direction is down (value= 255) Optical Log Depth Scale Units: Feet Frame spacing: 0.500000 Frame spacing units: [F ] Number of frames per record is: 31 One depth per frame (value= 0) Datum Specification Block Sub-type is: 1 FRAME SPACE = 0.500 * F ONE DEPTH PER FRAME Tape depth ID: F 7 Curves: Name Tool Code Samples Units Size Length 1 GR MWD 68 1 GAP I 4 4 2 RPD MWD 68 1 OHMM 4 4 3 RPM MWD 68 1 OHMM 4 4 4 RPS MWD 68 1 OHMM 4 4 5 RPX MWD 68 1 OHMM 4 4 6 ROP MWD 68 1 FPHR 4 4 7 FET MWD 68 1 HR 4 4 ------- 28 Total Data Records: 426 . . Tape File Start Depth Tape File End Depth Tape File Level spacing Tape File Depth Units 3012.000000 9602.000000 0.500000 feet **** FILE TRAILER **** Tape Subfile: 2 468 records... Minimum record length: Maximum record length: 8 bytes 4124 bytes **** FILE HEADER **** LDWG .002 1024 *** LIS COMMENT RECORD *** !!!!!! !!!!!!!! !!!!! LDWG File Version 1.000 !!!!!!!!!!!!!!!!!!! Extract File: FILEOl1.HED FILE HEADER FILE NUMBER: RAW MWD Curves and BIT RUN NO: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE MWD $ 2 log header data for each bit run in separate files. 2 .2500 START DEPTH 2976.0 STOP DEPTH 5977.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG) MINIMUM ANGLE: MAXIMUM ANGLE: 06-SEP-04 MSB 18704 6.75 MPR MEMORY 6020.0 2976.0 5977.0 o 48.6 78.9 # TOOL STRING (TOP TO VENDOR TOOL CODE DIR PRES MPR GRAM $ BOTTOM) TOOL TYPE DIRECTIONAL PRESSURE MULT. PROP. GAMMA RAY RES. TOOL NUMBER DHA 6289 1006728 6010 10083974 # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): 9.625 3012.0 # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: LSND 9.05 .0 .0 . . MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TEMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: 200 .0 .000 .000 .000 .000 114.0 .0 .0 .0 # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): .00 .000 # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): .0 o # REMARKS: BIT RUN 2 (MWD Run 3). MPR/GR. CURVE GLOSSARY: GRAM - GAMMA RAY APPARENT (MWD-API) ROPA - RATE OF PENETRATION (FPHR) RPCL - DEEP PHASE RESISTIVITY (OHMM) RPSL - MEDIUM PHASE RESISTIVITY (OHMM) RPCH - SHALLOW PHASE RESISTIVITY (OHMM) RPSH - EXTRA SHALLOW PHASE RESISTIVITY (OHMM) RPTH - FORMATION EXPOSURE TIME (MIN) $ # *** INFORMATION TABLE: CONS MNEM VALU -------------------------------- WDFN LCC CN WN FN COUN STAT le-166.xtf 150 ConocoPhillips Alaska, I 1E-166 Kuparuk River North Slope Alaska *** INFORMATION TABLE: CIFO MNEM CHAN DIMT CNAM ODEP ---------------------------------------------------- GRAM GRAM GRAM 0.0 RPCL RPCL RPD 0.0 RPSL RPSL RPM 0.0 RPCH RPCH RPS 0.0 RPSH RPSH RPX 0.0 ROPA ROPA ROP 0.0 RPTH RPTH RPTHM 0.0 * FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame Size is: 32 bytes Logging direction is down (value= 255) Optical Log Depth Scale Units: Feet Frame spacing: 0.250000 Frame spacing units: [F ] Number of frames per record is: 31 One depth per frame (value= 0) Datum Specification Block Sub-type is: 1 FRAME SPACE = 0.250 * F ONE DEPTH PER FRAME . Tape depth ID: F 7 Curves: Name Tool Code Samples Units Size Length 1 GRAM MWD 68 1 GAP I 4 4 2 RPCL MWD 68 1 OHMM 4 4 3 RPSL MWD 68 1 OHMM 4 4 4 RPCH MWD 68 1 OHMM 4 4 5 RPSH MWD 68 1 OHMM 4 4 6 ROPA MWD 68 1 FPHR 4 4 7 RPTH MWD 68 1 MINS 4 4 ------- 28 Total Data Records: 388 Tape File Start Depth Tape File End Depth Tape File Level Spacing Tape File Depth Units 2976.000000 5977.000000 0.250000 feet **** FILE TRAILER **** Tape Subfile: 3 473 records... Minimum reçord length: Maximum record length: 8 bytes 4124 bytes **** FILE HEADER **** LDWG .003 1024 *** LIS COMMENT RECORD *** !!!!!!!!!!!!!!!!!! ! !!!!!!!!!!!!!!!!!! ! LDWG File Version 1.000 Extract File: FILE012.HED FILE HEADER FILE NUMBER: RAW MWD Curves and BIT RUN NO: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE MWD $ 3 . log header data for each bit run in separate files. 3 .2500 START DEPTH 5977.0 STOP DEPTH 9602.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG) MINIMUM ANGLE: MAXIMUM ANGLE: 1l-SEP-04 MSB 18704 4.75 MPR MEMORY 9602.0 5977.0 9602.0 o 78.4 100.3 . # TOOL STRING (TOP TO VENDOR TOOL CODE DIR MPR GRAM PRES $ BOTTOM) TOOL TYPE DIRECTIONAL MULT. PROP. GAMMA RAY PRESSURE RES. # 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 TEMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # . TOOL NUMBER C0165 6032 5170 10056318 6.750 6014.0 OBM 8.85 .0 .0 42000 .0 .000 .000 .000 .000 107.0 .0 .0 .0 .00 .000 .0 o BIT RUN 3 (MWÐ Run 4). MPR/GR. CURVE GLOSSARY: GRAM - GAMMA RAY APPARENT (MWÐ-API) ROPA - RATE OF PENETRATION (FPHR) RPCL - DEEP PHASE RESISTIVITY (OHMM) RPSL - MEDIUM PHASE RESISTIVITY (OHMM) RPCH - SHALLOW PHASE RESISTIVITY (OHMM) RPSH - EXTRA SHALLOW PHASE RESISTIVITY (OHMM) RPTH - FORMATION EXPOSURE TIME (MIN) $ REMARKS: # *** INFORMATION TABLE: CONS MNEM VALU -------------------------------- WDFN LCC CN WN FN COUN STAT le-166.xtf 150 ConocoPhillips Alaska, I lE-166 Kuparuk River North Slope Alaska *** INFORMATION TABLE: CIFO MNEM CHAN DIMT CNAM ODEP ---------------------------------------------------- GRAM GRAM GRAM 0.0 RPCL RPCL RPD 0.0 RPSL RPSL RPM 0.0 RPCH RPCH RPS 0.0 RPSH RPSH RPX 0.0 ROPA ROPA ROP 0.0 . . RPTH RPTH RPTHM 0.0 * FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame Size is: 32 bytes Logging direction is down (value= 255) Optical Log Depth Scale Units: Feet Frame spacing: 0.250000 Frame spacing units: [F ] Number of frames per record is: 31 One depth per frame (value= O) Datum Specification Block Sub-type is: 1 FRAME SPACE = 0.250 * F ONE DEPTH PER FRAME Tape depth ID: F 7 Curves: Name Tool Code Samples Units Size Length 1 GRAM MWD 68 1 GAP I 4 4 2 RPCL MWD 68 1 OHMM 4 4 3 RPSL MWD 68 1 OHMM 4 4 4 RPCH MWD 68 1 OHMM 4 4 5 RPSH MWD 68 1 OHMM 4 4 6 ROPA MWD 68 1 FPHR 4 4 7 RPTH MWD 68 1 MINS 4 4 ------- 28 Total Data Records: 468 Tape File Start Depth Tape File End Depth Tape File Level Spacing Tape File Depth Units 5977.000000 9602.000000 0.250000 feet **** FILE TRAILER **** Tape Subfile: 4 553 records... Minimum record length: Maximum record length: 8 bytes 4124 bytes **** TAPE TRAILER **** LDWG 05/05/02 01 **** REEL TRAILER **** LDWG 05/05/02 AWS 01 Tape Subfile: 5 Minimum record length: Maximum record length: . . 2 records... 132 bytes 132 bytes
