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'% =* ": 7 Last Tag Annotation Depth (ftKB) End Date Wellbore Last Mod By Last Tag:1J-156 lmosbor Last Rev Reason Annotation End Date Wellbore Last Mod By Rev Reason: Pulled DP Plug, D LEM Diverter, B LEM Isosleeve 6/7/2020 1J-156 rogerba Casing Strings Casing Description CONDUCTOR OD (in) 20 ID (in) 19.12 Top (ftKB) 28.0 Set Depth (ftKB) 108.0 Set Depth (TVD) … 108.0 Wt/Len (l… 94.00 Grade H-40 Top Thread WELDED Casing Description SURFACE OD (in) 10 3/4 ID (in) 9.95 Top (ftKB) 30.2 Set Depth (ftKB) 2,768.7 Set Depth (TVD) … 2,167.0 Wt/Len (l… 45.50 Grade L80 Top Thread Buttress Thread Casing Description INTERMEDIATE OD (in) 7 5/8 ID (in) 6.87 Top (ftKB) 26.2 Set Depth (ftKB) 6,961.3 Set Depth (TVD) … 3,625.5 Wt/Len (l… 29.70 Grade L-80 Top Thread BTCM Casing Description D-SAND LINER LEM OD (in) 4 1/2 ID (in) 3.96 Top (ftKB) 5,640.2 Set Depth (ftKB) 5,830.4 Set Depth (TVD) … 3,449.0 Wt/Len (l… 12.60 Grade L-80 Top Thread IBT Liner Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Com Nominal ID (in) 5,640.2 3,410.4 78.39 PACKER BAKER ZXP LINER TOP PACKER 4.970 5,659.2 3,414.3 78.37 SBR BAKER 190-47 CASING SEAL BORE RECEPTACLE 4.750 5,678.9 3,418.2 78.36 XO BUSHING CROSSOVER BUSHING 3.950 5,684.2 3,419.3 78.36 HANGER LEM ABOVE HOOK HANGER 3.980 5,694.4 3,421.4 78.36 HANGER LEM INSIDE HOOK HANGER 3.980 5,785.4 3,439.8 78.19 BENT JT 3.950 5,827.1 3,448.4 78.43 SEAL ASSY BAKER SEAL ASSEMBLY 3.880 Casing Description D-SAND LINER HH OD (in) 4 1/2 ID (in) 3.48 Top (ftKB) 5,694.3 Set Depth (ftKB) 5,908.8 Set Depth (TVD) … 3,463.2 Wt/Len (l… 11.60 Grade L-80 Top Thread BTC Liner Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Com Nominal ID (in) 5,694.3 3,421.4 78.36 HANGER BAKER MODEL B-1 HOOK HANGER FOR LEM (INSIDE CSG) 5.580 5,711.0 3,424.7 78.35 HANGER BAKER MODEL B-1 HOOK HANGER FOR LEM (OUTSIDE CSG) 3.990 5,810.7 3,445.0 78.13 ECP BAKER PAYZONE EXTERNAL CSG PACKER 3.930 Casing Description B-SAND LINER LEM OD (in) 4 1/2 ID (in) 3.96 Top (ftKB) 5,801.3 Set Depth (ftKB) 6,197.6 Set Depth (TVD) … 3,511.9 Wt/Len (l… 12.60 Grade L-80 Top Thread IBT Liner Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Com Nominal ID (in) 5,801.3 3,443.1 78.15 PACKER ZXP LINER TOP PACKER 4.970 5,820.4 3,447.0 78.26 SBR BAKER 109-47 CASING SEAL BORE RECEPTACLE 4.750 5,840.1 3,450.9 78.77 XO BUSHING CROSSOVER BUSHING 3.950 6,059.6 3,487.9 80.57 HANGER LEM ABOVE HOOK HANGER 3.980 6,070.4 3,489.7 80.56 HANGER LEM INSIDE HOOK HANGER 3.980 6,118.2 3,497.6 80.21 NIPPLE CAMCO DB-6 NIPPLE 3.562 6,194.3 3,511.3 79.11 SEAL ASSY BAKER SEAL ASSEMBLY 3.880 Casing Description B-SAND LINER HH OD (in) 4 1/2 ID (in) 3.48 Top (ftKB) 6,070.3 Set Depth (ftKB) 6,283.0 Set Depth (TVD) … 3,527.3 Wt/Len (l… 11.60 Grade L-80 Top Thread BTC Liner Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Com Nominal ID (in) 6,070.3 3,489.6 80.56 HANGER BAKER MODEL B-1 HOOK HANHER FOR LEM (INSIDE CSG) 5.600 6,086.7 3,492.3 80.56 HANGER BAKER MODEL B-1 HOOK HANHER FOR LEM (OUTSIDE CSG) 5.600 6,182.7 3,509.1 79.16 ECP BAKER PAYZONE EXTERNAL CASING PACKER 3.930 Casing Description A2 LINER OD (in) 4 1/2 ID (in) 3.48 Top (ftKB) 6,160.5 Set Depth (ftKB) 8,275.0 Set Depth (TVD) … 3,630.8 Wt/Len (l… 11.60 Grade L-80 Top Thread BTC Liner Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Com Nominal ID (in) 6,160.5 3,505.0 79.52 PACKER 'C2' ZXP LINER TOP PACKER 5.750 6,177.9 3,508.2 79.24 HANGER FLEXLOCK LINER HANGER 4.850 6,187.4 3,510.0 79.08 SBR BAKER 190-47 CASING SEAL BORE EXT. 4.750 6,207.0 3,513.7 79.25 XO BUSHING CROSSOVER BUSHING 3.950 Tubing Strings Tubing Description TUBING PRODUCTION String Ma… 4 1/2 ID (in) 3.96 Top (ftKB) 22.4 Set Depth (ft… 5,675.0 Set Depth (TVD) (… 3,417.4 Wt (lb/ft) 12.60 Grade L-80 Top Connection IBTM Completion Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Com Nominal ID (in) 22.4 22.4 0.05 HANGER Tubing Hanger, Vetco MB-222A Gray 10-3/4" x 4-1/2", IBTM Box X MCA Pin 4" H BPV 3.900 5,600.3 3,402.3 78.07 NIPPLE Nipple, Halliburton, 3.813" X profile, SN: m101024023 3.810 5,646.7 3,411.7 78.38 LOCATOR Baker Locator 3.875 5,648.4 3,412.1 78.38 SEAL ASSY Baker 4.75" SBE Seal Assy Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Des Com Run Date ID (in) SN 5,307.0 3,334.2 74.06 CASING PATCH Casing patch set at 5414' to 5307' 10/21/2018 6.086 Multiple Laterals, 1J-156, 4/8/2021 5:21:22 PM Vertical schematic (actual) A2 LINER; 6,160.5-8,275.0 SLOTS; 8,197.0-8,241.0 SLOTS; 8,111.0-8,155.0 SLOTS; 8,025.0-8,068.0 SLOTS; 7,941.0-7,984.0 SLOTS; 7,857.0-7,898.0 SLOTS; 7,771.0-7,814.0 SLOTS; 7,685.0-7,728.0 SLOTS; 7,602.0-7,642.0 SLOTS; 7,517.0-7,561.0 SLOTS; 7,431.0-7,474.0 SLOTS; 7,344.0-7,387.0 SLOTS; 7,043.0-7,130.0 INTERMEDIATE; 26.2-6,961.3 B-SAND LINER HH; 6,070.3- 6,283.0 B-SAND LINER LEM; 5,801.3- 6,197.6 D-SAND LINER HH; 5,694.3- 5,908.8 D-SAND LINER LEM; 5,640.2- 5,830.4 SEAL ASSY; 5,648.4 LOCATOR; 5,646.7 NIPPLE; 5,600.3 GAS LIFT; 5,573.9 CASING PATCH; 5,307.0 SURFACE; 30.2-2,768.7 CONDUCTOR; 28.0-108.0 HANGER; 22.4 KUP INJ KB-Grd (ft) 31.20 Rig Release Date 8/12/2006 1J-156 ... TD Act Btm (ftKB) 8,281.0 Well Attributes Field Name WEST SAK Wellbore API/UWI 500292331100 Wellbore Status INJ Max Angle & MD Incl (°) 94.07 MD (ftKB) 8,027.36 WELLNAME WELLBORE1J-156 Annotation Last WO: End Date 10/14/2018 H2S (ppm) DateComment SSSV: NONE Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft )Type Com 7,043.0 7,130.0 3,630.7 3,637.2 WS A2, 1J-156 7/9/2006 32.0 SLOTS Alternating slotted/solid pipe 0.125" x 2.5" x 32 spf @ 4 Circumferential adjacent rows, 3" Centers staggered 18 deg., 3 ft. non-slotted ends 7,344.0 7,387.0 3,661.5 3,664.1 WS A2, 1J-156 7/9/2006 32.0 SLOTS 7,431.0 7,474.0 3,665.4 3,665.5 WS A2, 1J-156 7/9/2006 32.0 SLOTS 7,517.0 7,561.0 3,664.7 3,663.5 WS A2, 1J-156 7/9/2006 32.0 SLOTS 7,602.0 7,642.0 3,662.1 3,661.6 WS A2, 1J-156 7/9/2006 32.0 SLOTS 7,685.0 7,728.0 3,661.6 3,660.3 WS A2, 1J-156 7/9/2006 32.0 SLOTS 7,771.0 7,814.0 3,657.6 3,654.7 WS A2, 1J-156 7/9/2006 32.0 SLOTS 7,857.0 7,898.0 3,652.1 3,649.8 WS A2, 1J-156 7/9/2006 32.0 SLOTS 7,941.0 7,984.0 3,647.6 3,645.2 WS A2, 1J-156 7/9/2006 32.0 SLOTS 8,025.0 8,068.0 3,642.5 3,639.6 WS A2, 1J-156 7/9/2006 32.0 SLOTS 8,111.0 8,155.0 3,637.0 3,634.7 WS A2, 1J-156 7/9/2006 32.0 SLOTS 8,197.0 8,241.0 3,633.0 3,631.7 WS A2, 1J-156 7/9/2006 32.0 SLOTS Stimulation Intervals Interva l Numbe r Type Subtype Start Date Top (ftKB) Btm (ftKB) Proppant Designed (lb) Proppant Total (lb) Vol Clean Total (bbl) Vol Slurry Total (bbl) Mandrel Inserts St ati on N o/Top (ftKB) Top (TVD) (ftKB) Make Model OD (in) Serv Valve Type Latch Type Port Size (in) TRO Run (psi) Run Date Com 1 5,573.9 3,396.8 Camco KBG-2 1 GAS LIFT DV BK 0.000 0.0 10/27/2018 Notes: General & Safety End Date Annotation 2/8/2011 NOTE: VIEW SCHEMATIC w/Alaska Schematic9.0REV 7/28/2006 NOTE: MULTI-LATERAL WELL: 1J-156(A-SANDS),1J-156L1(B-SANDS),1J-156L2(D-SANDS) Multiple Laterals, 1J-156, 4/8/2021 5:21:22 PM Vertical schematic (actual) A2 LINER; 6,160.5-8,275.0 SLOTS; 8,197.0-8,241.0 SLOTS; 8,111.0-8,155.0 SLOTS; 8,025.0-8,068.0 SLOTS; 7,941.0-7,984.0 SLOTS; 7,857.0-7,898.0 SLOTS; 7,771.0-7,814.0 SLOTS; 7,685.0-7,728.0 SLOTS; 7,602.0-7,642.0 SLOTS; 7,517.0-7,561.0 SLOTS; 7,431.0-7,474.0 SLOTS; 7,344.0-7,387.0 SLOTS; 7,043.0-7,130.0 INTERMEDIATE; 26.2-6,961.3 B-SAND LINER HH; 6,070.3- 6,283.0 B-SAND LINER LEM; 5,801.3- 6,197.6 D-SAND LINER HH; 5,694.3- 5,908.8 D-SAND LINER LEM; 5,640.2- 5,830.4 SEAL ASSY; 5,648.4 LOCATOR; 5,646.7 NIPPLE; 5,600.3 GAS LIFT; 5,573.9 CASING PATCH; 5,307.0 SURFACE; 30.2-2,768.7 CONDUCTOR; 28.0-108.0 HANGER; 22.4 KUP INJ 1J-156 ... WELLNAME WELLBORE1J-156 Last Tag Annotation Depth (ftKB) End Date Wellbore Last Mod By Last Tag:1J-156L2 lmosbor Last Rev Reason Annotation End Date Wellbore Last Mod By REV REASON: ADD PERF 10/25/2019 1J-156L2 aappleh Casing Strings Casing Description D-SAND LINER OD (in) 4 1/2 ID (in) 3.48 Top (ftKB) 5,859.8 Set Depth (ftKB) 12,551.8 Set Depth (TVD) … 3,330.5 Wt/Len (l… 11.60 Grade L-80 Top Thread BTC Liner Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Com Nominal ID (in) 5,859.8 3,442.8 87.31 SLEEVE BAKER 'HR' SETTING SLEEVE 5.750 5,918.5 3,443.7 89.72 XO BUSHING CROSSOVER BUSHING 3.930 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Des Com Run Date ID (in) SN 10,797. 0 3,347.7 92.19 INFLATABLE CEMENT RETAINER 2.5" INFLATABLE CEMENT RETAINER 10.5' LONG 5/18/2019 11,437. 0 3,337.9 90.41 FISH 2.5" INFLATABLE CEMENT RETAINER 5/17/2019 11,536. 0 3,337.3 90.32 IBP 2.50" INFLATABLE BRIDGE PLUG 5/15/2019 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft )Type Com 5,922.0 6,649.0 3,443.8 3,437.7 WS D, 1J-156L2 7/24/2006 32.0 SLOTS Alternating solid/slotted pipe - 0.125"x2.5" @ 4 circumferential adjacent rows, 3" centers staggered 18 deg, 3' non-slotted ends 6,906.0 7,656.0 3,433.3 3,434.5 WS D, 1J-156L2 7/24/2006 32.0 SLOTS 7,912.0 8,423.0 3,425.1 3,405.6 WS D, 1J-156L2 7/24/2006 32.0 SLOTS 8,683.0 9,159.0 3,399.3 3,391.7 WS D, 1J-156L2 7/24/2006 32.0 SLOTS 9,417.0 9,892.0 3,380.4 3,368.7 WS D, 1J-156L2 7/24/2006 32.0 SLOTS 10,151.0 10,657.0 3,364.6 3,354.6 WS D, 1J-156L2 7/24/2006 32.0 SLOTS 10,395.0 10,400.0 3,362.4 3,362.2 WS D, 1J-156L2 10/25/2019 APERF ADD PERF 2.0" GUN, 6 SPF -60*-2006 PF HMX-6.4GM- 3.5" CASING-.45" END HOLE-4.5" PENETRATION 10,917.0 11,429.0 3,344.5 3,337.9 WS D, 1J-156L2 7/24/2006 32.0 SLOTS 11,170.0 11,175.0 3,338.3 3,338.3 WS B, 1J-156L1 7/17/2006 32.0 IPERF ADD PERF 2.50" HSD 2506 6 SPF 11,644.0 12,505.0 3,336.0 3,332.5 WS D, 1J-156L2 7/24/2006 32.0 SLOTS Stimulation Intervals Interva l Numbe r Type Subtype Start Date Top (ftKB) Btm (ftKB) Proppant Designed (lb) Proppant Total (lb) Vol Clean Total (bbl) Vol Slurry Total (bbl) Cement Squeezes Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Des Com Pump Start Date 10,764.0 11,536.0 3,349.1 3,337.3 Liner Cement 35.7 BBLS 8.6 PPG ULTRA-LITE CRETE, 35.2 BBLS THROUGH RETAINER, .5 BBLS LEFT ON TOP OF RETAINER 5/18/2019 Notes: General & Safety End Date Annotation 6/6/2019 NOTE: EXTENDED CEMENT PLUG IN LINER AND OPEN HOLE from 10,797' to 11,536' 7/28/2006 NOTE: MULTI-LATERAL WELL: 1J-156 (A-SAND), 1J-156L1 (B-SAND), 1J-156L2 (D-SAND) Multiple Laterals, 1J-156L2, 4/8/2021 5:21:23 PM Vertical schematic (actual) D-SAND LINER; 5,859.8- 12,551.8 SLOTS; 11,644.0-12,505.0 IBP; 11,536.0 FISH; 11,437.0 SLOTS; 10,917.0-11,429.0 IPERF; 11,170.0-11,175.0 Open Hole Cement; 10,764.0 ftKB INFLATABLE CEMENT RETAINER; 10,797.0 Liner Cement; 10,764.0 ftKB SLOTS; 10,151.0-10,657.0 APERF; 10,395.0-10,400.0 SLOTS; 9,417.0-9,892.0 SLOTS; 8,683.0-9,159.0 SLOTS; 7,912.0-8,423.0 SLOTS; 6,906.0-7,656.0 SLOTS; 5,922.0-6,649.0 INTERMEDIATE; 26.2-6,961.3 D-SAND LINER HH; 5,694.3- 5,908.8 D-SAND LINER LEM; 5,640.2- 5,830.4 SEAL ASSY; 5,648.4 LOCATOR; 5,646.7 NIPPLE; 5,600.3 GAS LIFT; 5,573.9 CASING PATCH; 5,307.0 SURFACE; 30.2-2,768.7 CONDUCTOR; 28.0-108.0 HANGER; 22.4 KUP INJ KB-Grd (ft) 31.20 Rig Release Date 8/12/2006 1J-156L2 ... TD Act Btm (ftKB) 12,566.0 Well Attributes Field Name WEST SAK Wellbore API/UWI 500292331161 Wellbore Status INJ Max Angle & MD Incl (°) 94.22 MD (ftKB) 6,772.48 WELLNAME WELLBORE1J-156 Annotation Last WO: End DateH2S (ppm) DateComment SSSV: NONE STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Pull Tubing ❑ Operations shutdown ❑ Performed: Suspend ❑ Perforate 0 Other Stimulate ❑ Alter Casing ❑ Change Approved Program ❑ Plug for Redrill ❑ erforate New Pool ❑ Repair Well ❑ Re-enter Susp Well ❑ Other: RPPG MBE TRTMT❑] 2. Operator Name: ConocoPhillips Alaska, Inc. 4. Well Class Before Work: 5. Permit to Drill Number: Development ❑ Exploratory ❑ Stratigraphic❑ Service Q 206-069 3. Address: P. O. Box 100360, Anchorage, Alaska 6, API Number: 99510 50-029-23311-61-00 7. Property Designation (Lease Number): 8. Well Name and Number: ADL 25660, ADL 25661, ADL 25663 KRU 1J -156L2 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 12,566 feet Plugs measured None feet true vertical 3,330 feet Junk measured None feet Effective Depth measured 12,550 feet Packer measured 5,640 feet true vertical 3,330 feet true vertical 3,411 feet Casing Length Size MD TVD Burst Collapse CONDUCTOR 80 feet 20 108' MD 108' TVD SURFACE 2,739 feet 10 3/4 " 2,769' MD 2167' TVD INTERMEDIATE 5,671 feet 75/8" 6,991'MD 3625'TVD RECEIVED D -SAND LINER 6,692 feet 4 1/2 " 12,552' MD 3330' TVD NOV 0 5 2019 Perforation depth: Measured depth: 5922-12505 feet SLOTS True Vertical depth: 3444-3333 feet A!`1/'��"C �i.„.//�73,44117''TVD Tubing (size, grade, measured and true vertical depth) 4.5 " L-80 5,675' MD Packers and SSSV (type, measured and true vertical depth) PACKER -BAKER ZXP LINER TOP PKR 5,640' MD 3,411' TVD SSSV -NONE 12. Stimulation or cement squeeze summary: 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 Casing Pressure Tubing Pressure Prior to well operation: - _ g50 _ e Subsequent to operation: - - 191 - 590 14. Attachments (required per 20 MC 25.070, 25.071, & 25.283) 15. Well Class afterwork: Daily Report of Well Operations El Exploratory ❑ Development ❑ Service 21 Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16. Well Status after work: Oil ❑ Gas ❑ WDSPL ❑ Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ O WAG ❑ GINJ ❑ SUSP❑ SPLUG❑ 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 319-435 Authorized Name: John Peirce Contact Name: John Peirce Authorized Title: Sr. Wells Engineer contact Email: John.W.Peirce@cop.com Contact Phone: (907) 265-6471 Authorized Si /� nature: C g Date: -T .LIS ! Form 10-404 devised 4/2017 V TL /'V! L9 AgDMS NOv o s tots Submit Original Only ��l?�% j� '\ KUP INJ WELLNAME 1J-156 WELLBORE 1J-156 Conoco` Phillips & Slots CASINO PATCH, OAS ulr NIPPLE .NO LINER TYPE 1150 SLEEVE oe &&ANO LINER LEM, SLOTS: SLOTS', SLOTS: SLOTS: MaXe o� T E- & Run Run non - Com 1J -156L2 PERFORATE/RPPG MBE TREATMENT DTTM JOBTYP SUMMARYOPS START 10/25/19 SUSTAIN- RIH WITH 2" PF HMX PERF GUN, TAG CEMENT RETAINER AT MENT 10751.2 CTMD, PU TO 10400' BOTTOM SHOT, DROP .5" BALL, FIRE GUNS 10400'-10395'. OOH ALL SHOTS FIRED, .5" BALL RECOVERED. WELL READY FOR RPPG JOB. 10/29/19 SUSTAIN- PUMPED FULLBORE RPPG TO D -LAT TOE; FRESH 5' PERF MENT INTERVAL AT 10395-10400' (SEE WSR 10/25/19). PUMPED 578 - BBL TREATMENT INCLUDING 159 -BBL 2% KCI PRE -FLUSH, FOLLOWED BY 262 -BBL SLURRY CONTAINING KCI PLUS 7040# RPPG PRODUCT. DISPLACED SLURRY TO MBE WITH 121 -BBL KCI AND 39 -BBL DIESEL FP (160 -BBL TOTAL DISPLACEMENT). GAINED APPROXIMATELY 1100 -PSI NET PRESSURE DURING TREATMENT PUMPING 2.5-3.5 BPM. SHUT IN SUPPORTED PRODUCER 1J-152 SIMULTANEOUSLY AT START OF PUMPING, AND REQUESTED IT BE FREEZE PROTECTED SLOWLY, AND B.O.L. ONLY AFTER 48 -HOURS. THE STATE °fALASKA GOVERNOR MIKE DUNLEAVY John Peirce Sr. Wells Engineer ConocoPhillips Alaska, Inc. PO Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, West Sak Oil Pool, KRU 1J -156L2 Permit to Drill Number: 206-069 Sundry Number: 3 19-43 5 Dear Mr. Peirce: Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 www.aogcc.olcsko.gov Enclosed is the approved application for the 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, Daniel T. Seamount, Jr. Commissioner DATED this day of September, 2019. BBDMS �� OCT 012019 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 1. Type of Request: Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Repair Well ❑ Operations shutdown[] Suspend ❑ Perforate 21 Other Stimulate ❑ Pull Tubing ❑ Change Approved Program❑ Plug for Redrill ❑ Perforate New Pool ❑ Reenter Susp Well ❑ Alter Casing ❑ Other: RPPG MBE Trtmt[D 2. Operator Name: 4. Current Well Class: 15. Permit to Drill Number. COnocoPhilli s Alaska Inc. Exploratory ❑ Development ❑ Stratigraphic ❑ Service 1 206-069- 06-069-3. 3.Address: 6, API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-029-23311-61-00 ' 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? N/A KRU 1J -156L2 Will planned perforations require a spacing exception? Yes ❑ No O 9. Property Designation (Lease Number): 10. FieldlPool(s): ADL 256607, ADL 25661, ADL 25663 1 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): 12,566' 3,330' 12550 3330 1500psi NONE NONE Casing Length Size MD TVD Burst Collapse Conductor 80' 20" 108' 108' Surface 2,739' 103/4 2,769' 2,167' Intermediate 5,671' 7518 6,991' 3,625' Liner 6,692' 41/2 1 12,552' 13,449' Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): slots 5922-12505 slots 3444-3333 4.500" L-80 5,675' Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): PACKER - BAKER ZXP Liner Top Packer 5640' MD and 3411' TVD SSSV -NONE N/A 12. Attachments: Proposal Summary Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stratigraphic ❑ Development ❑ Service 0 - 14. Estimated Date for 10/1512019 15. Well Status after proposed work: Commencing Operations: OIL ❑ WINJ O - WDSPL ❑ Suspended ❑ GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ 16. Verbal Approval: Date: Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. 1 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: Sr. Wells Engineer Contact Email: John.W.Peirce@cop.com Contact Phone: (907) 265-6471 2 3 Authorized Signature: o-� W — Date: �) 1• COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: v l / Ll J Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: / Post Initial Injection MIT Req'd? Yes ❑ No Spacing Exception Required? Yes ❑ No d Subsequent Form Required:g(J4- APPROVED BY /.T ^ I � G Approved by:�91K� COMMISSIONER THE COMMISSION Date: � 1 Lka vrc q/a57/1 ey ORIGINAL RBDMS.� ooao�p, I�-', OCT �Wsed4/201.7 Approved application is valid for 12 months from the date of approval. OJGForm and Attachments in Duplicate KUP INJ WLLLNHMt 1J-15b 'I J-9 bb ConocoPhillips Alaska. Inc. MIsp.ImMMnilsx Bzarzme Tm:+, Au Other In Hole (Wireline retrievable plugs, valves, pumps, fish, aft.) V., WImeE No u') ruPlrvO) Top HANGER n0and Top mK81 InKal fl Des cam Run pat apm ........ . : .. 6,072.0 34699 80.56 1 150 BAKER TYPE 1 ISOLATION LEEVE, 4" G PROFILE, 32912019 SLEEVE -& 3.69'ODX19'L LEM 6,118.0 349).5 8021 DB PLUG DB PLUG B PRONG jN28Q019 1 0.000 CONDUCTOR: ai➢101.0 Perforations & Slots shoe Dend TOP".) S.MD) lanom SVREFCE;9b3.ieeT TopWB) BMmnB) ms) MKBI LINMNJ ZOM DON I TYM Coal 7,0430 7,1300 3.63IL7 3,6372 WSA2,1J-156 792006 32.0 SLOTS Aternatinq"IGUM1s0I pipe 0.125' x 2.5' x 32 spf CA4NO PATCn:5.AP70 @ 4 Cumnde edal adjarent GANS, 3' Centers GM LIFT: Sm 9 sOdgm,ed 18 deg. 3 X. Rem sloMd ends NIPPLE: 5.6003 T,344.0 ],3870 3.6615 3,884.1 Ws A2, 11-158 792006 32. SLOTS 7,4310 7,474.0 36654 &865.5 WS A2,17156 792006 SLOTS LOCATOR: S.EM.7 7,5170 7,561.0 1664.7 3,663S WS A2, 1J-156 792006 U.0 SLOTS SEALASSY: SERO ],602.0 ],642.0 36621 1.6 WSA$1J-156 792006 LOTS ],6850 7,728.0 3.6616 3,660.3 WS A2, 1J-156 792006 U,O SLOTS 7.771.0 ],814.0 3657.6 3,654.] WS 02r 1J-'M 792006 32.0 LOTS TwE2DnERTERDIEM: ],8570 7,898.0 3.6521 3, 4.8 WS A2, 1J 156 792006 320 SLOTS RAND 7,9410 7,984.0 3,647.6 3645.2 WSA$1J-156 ]92006 320 SLOTS 8,0250 8,068.0 3,642.5 3,639.6 WS A2, 1J-156 792006 320 SLOT 8,111.0 8,155.0 3,637.0 3,634.] WS A2, 1J-155 7192006 32.0 SLOTS 8.197.0 8,241.0 3633.0 3,631.7 WS Q, IJ-155 792006 32.0 SLOTS kandrel.nnserts 68PNOLINERLEM:SBIOb On TOFI1Vb)Pm191xeTROnun ) Wn Mab MWeI OD 6n) dery TyPe Type Ila) IpAd RunNNA Com39 3,3968USSE0 KeG-2 1GASLIFT DV DK 0000 0010/27208 neral & Safety AnnnUnon DsnxDunER Hx,5.NOTE:MULTI-LATERAL WELL. IJ-156(A-SANDS),1J-156L1)B-SANDS).iJ-156L2(D-SANDS) N TE VIEW SCHEMATIC w/Alaska Sc5emaw9.OREV TYPE 11808LEEN% GLEN, B.ORO De PLUG: 61180- 8 SAAR) 11908.SAN0 LINER LEM: s.e01 s 8,1918 BSAND LINER NH; EMS B.R10 INTERMEDIATE; 26219813 Smnv.O4D0-7A3O0 u0T8: 7,W 0-738]0 SLOrs: 740181ara0 SLOTS'.7SI7O-7.9810 SLOTS:T.803.67.8430 SLOTS:7.685E4.7DOO SLOTS: 7.rl0078140 SLOTS: ],bT.bT,eD0.0 SLOTS: 7.94161,6e10 SLOTS; e.02808,R40 SLOTS', 9,1110 ,Imo SLOTS: S+8T.082110 A21JNER:8,1605 27s.0� j KUP [NJ WELLNAME IJ -156 WELLBORE 1J -156L2 �(���(� hP." Well Attributes Max Angle 8 MD TD ��"���' •'l''ims Alaska. INC. Fieltl Name WNIW,e APOUWI Well�ee Status Icl f) MD IHas) Act arm IXKBI 422 6)]2.48 12,566.0 Cmmment SSSV:NONE IMS/ppm) Dale AnnoWO End Data Xa GM M1 Rip ReMace Date Lax WO: 3120 8112/2006 MWM,M uwaN. a-lsez a0vm13>»11 AM Last Tag verWlvJmnatic l+ctr+pI AnneWron Dep.WBI I End DataMed By naxGER;oO Last Ta 1)-15xwIa 2 ,. Last Rev Reason A.... I End Data I wxlere. Last Mod By V EAS N'. SE IBP, ET CEMENT TFETAINER PUMP 35J BBLS 6Ifi12019 1J-IS6L2 pOroven hticoNDDcroR,ma109.0 CEMENT FOR MBE TREATMENT, Updated CAN JOB Casing Strings Casino 0asc,i peon D -SAND LINER 00(in) 11.(nl Top(NK5) S0DepmlNKOI 5e1DepIM1 1ND I...W11Len(1-.Gntle Top Thread 412 348 5,859.8 12.5518 3,330.5 11.60 L-80 BTC $URFALE;bi-2,189.] Liner Details CASING PATCH: 5.3010 Nominal ID GASIlFT;551a.9 Top (ft ioplNOl lhKa) icp Incl l-) on. Com lint NIPPLE S.B-A.a 5.859.8 3,442.8 8].31 SLEEVE JOAKEK' HW SETTINGSLEEVE 5]50 5.918.5 3,443.] 69)2 %O BUSHING J1R1Q,1.ddn BUSHING 3.930 muroR; ease., Other In Hole (Wireline retrievable plugs, Valves, Pumps, hen, e j SEUA5sv: Top(IVD Tap IXNB) IXKBI Top Incl -I Des Lom Run Dele ID (in) DRUEM. TYPE 20NER1ER-55.. 5,30x.0 DSAND LINER LEM.5 are1 5830.4 INTERMEDIATE: 8.2Hrpe13 OSAND LINER TH, s,e84y 10.]9] 0 3,347 ] 92.19 INFLATABLE 25" INFLATABLE CEMENT RETAINER 10.5' LONG 511812019 CEMENT RETAINER $.a 114370 3,33].9 9041 FISH 2.5"INFLATABLE CEMENT RETAINER 511712019 F 11,5360 3,33]1 --9N 32 IBP 250" INFLATABLE BRIDGE PLUG 5/15/2019 Perforations &.511 Star Den Topadds)Bim TeISKED IXKDI aMlrvDl Lndat Isnotsm 1 Type Can E490 6,649.0 3,443.8 3fl43 3,43]] 01r]- W D, 15612 20 72412006 32.0 SLOTS pipe -0 n95od '@4 pipe- smre:5.e2zoGaw.o temne.+2.5"ac4 HANS, 3 centers staggered rows, centerssoved ends 18 deg, 3' nan-sl0detl ends , 7,656. 3,433.3 4 .5 W D, 1J- '12412006 32.0 SLOTS 15612 8.42. 3,4251 3405. D, J- )242006 32.0 SLOTS 5612 9,159. 3,399.3 3,391.] W50. 1J- 7242006 32.0 SLOTS 15612 SLOT,BS�0L3050, 9,892.0 3,380.4 3.)68.] 5 D, 1J- 7242006 32,0 SLOTS 15612 10,1510 10,657.0 ,384.fi 3,3546 WS D,11 7 42006 32.0 SLOTS 15612 10,91].0 1-429.0 ,344.5 3.337.9 WSg1J- ] 2006 W1 SLOTS 156 2 ours', I.C.A.0 11,1000 11,775. ,338.3 3,338.3 WS B, 1J-15611 7/]2006.0 (PERF WIT15 PERF 50250 6 SPF 11,644.0 12,505. 7336.0 --3—.3M-5 WED, J- 7242006 32.0 SLOTS 15612 — Cement Squeezes Top mK01 BlmINK eI Top RVDI mK0) elm lrv0l RKBI Des Smn Dah Com 10764.0 11,5360 33491 3,3373 Liner Cement 5/18/2019 8.6 PPG ULTRA LITE CRE TE sLDTs S..oe.lu.a Notes: General & Safety Entl Dale Annohtion )282006 NOTE'. MULTFLATERAL WELL: 1J-156 (A-SANDI, IJ-156Li (-SAND), 1115612 (D -SAND) 6162019 N TE E%TENDED CEMENT PLUG IN LINER AND OPEN HOLE from 10,79T W 11,536- 1,5 'SLOTS. SLOTS.9417.0p.EMt0 SLOT, 10,15, I'C._o Unra Cancan[ 1DTMO SKS 1NFIATPBLECFMEM RETNNER: 10.1%0 open Rcb Cs,wR lolMo .S pX9 IPERF; 11 T.C-I" o S.. 10¢1Ta11,429.0 4 RSHTI4.910 4 NIP'.u.Rf80 SI.DTS:ITNLCa12.EO50 — D.GND UNER:5,8596 12,$1 S 1J -156L2 to 1J-1521-2 Reformed Polymer Particle Gel Treatment of D Sand Toe MBE 1J-156 Tri -Lateral injector was drilled & completed in 2006 with West Sak A, B, & D Sand laterals. On 3/8/19, an initial MBE at the toe of 1J-1561-2 'D' Sand lateral occurred to 1J-1521-2 offset producer. On 5/18/19, 35.7 bbls of 8.6# Ultralight Cement was pumped through a Cement Retainer in 1J-1561-2 to place a cement plug in the Liner and adjacent Liner x OH annulus to isolate the toe MBE. The Cement Plug was spotted at 10764 - 11536' RKB. Offset producer 1J-152 was put on production after 1J-1561-2 cement plug cured above the D MBE. 1J-152 well tests show that -300 BOPD was successfully restored as a result of the MBE isolation, but WC% was still quite high and the oil rate somewhat lower than expected. This suggested that the cement plug might be leaking to the toe MBE. An IPROF in 1J-1561-2 on 9/5/19 showed some injection split was still flowing to 1561-2 toe indicating that the MBE is not yet completely isolated. Per this procedure, it is proposed that 5' OAL of 'large hole' perforations be shot in 1J-1561-2 slotted liner just above the cement plug, to be followed by a fullbore RPPG treatment to seal off the remaining injection to the MBE past the cement plug. Procedure Coil Tubing: 1) RIH with a Perf Gun on CT and perforate slotted liner just above the recent tag at 10427' CTMD. Fire the gun at 10420 -10425 RKB (target) or as deep as possible to provide 6 spf, 60 deg phasing, of big hole perforations in 4.5" liner to enable RPPG slurry passage through the liner to the MBE. POOH with pert gun. Verify all shots fired. 2) Pumping: Put 1J-1561-2 on injection at 1000 BWPD at 6 - 12 hours before RPPG job, to start displacing gas head and Diesel FP from wellbore to D MBE, to ensure that the MBE is open and that the well becomes liquid packed and flushed of hydrocarbon contaminants that can inhibit RPPG swelling and crosslinking. RU Mixing Van & pumping equipment. When ready to pump RPPG job, SI injection to 1J-1561-2 and swap to fullbore pumping 1 wellbore volume (160 bbls to perfs at 10420' RKB) of ultraclean 2% KCL Brine into 1J-1521-2, followed by RPPG slurry at steady -2.4 bpm by adding 1 - 4 mm mesh RPPG to ultraclean 2% KCL Brine to make slurry concentration at 0.75 ppg added (target), and to place swelling RPPG into MBE within -70 minutes. Continue pumping slurry -2.4 bpm at 0.75 ppg concentration until WHIP reaches 800 - 1000 psi, then swap from RPPG slurry to 123 bbls 2% KCL Brine -2.4 bpm, followed by 37 bbls Diesel FP at -2.4 bpm to 2000' TVD, followed by Shutdown. Wait 48 hours for RPPG to fully swell and crosslink in D MBE to form rigid amalgamated mass of non - flowing crosslinked gel before returning 1J-1561-2 to injection and 1J-152 to production. Originated: Schlumberger PTS- PRINT CENTER 6411 A Street Anchorage, AK 99518 (907)273-1700 main (907)273-4760 fax Delivered to: � y/ AOGCC -. ATTN: Natural Resources Technician II �.� Alaska Oil & Gas Conservation Commision 333 W. 7th Ave, Suite 100 -. Anchorage, AK 99501 .i69 3 1193 TRANSMITTAL DATE- TRANSMITTAIp , 1C-20 1H-04 2A-25 1H-105 1R-34 50-029-23273-00 50-029-20770-00 50-103-20239-00 50-029-20727-01 50.029.22534-00 EDEA -00011 E118-00096 EOSH-00086 EOSH-00087 EOSH-00088 KUPARUK RIVER KUPARUK RIVER KUPARUK RIVER KUPARUK RIVER KUPARUK RIVER Memory WL WL WL WL IPROF (PROF Caliper p (PROF LDL-WFL FINAL FIELD FINAL FIELD FINAL FIELD FINAL FIELD FINAL FIELD 2-Aug -19 1 27 -Aug -19 1 28 -Aug -19 1 29 -Aug -19 1 30 -Aug -19 1 2A -27A 50-103-20604-01 EOSH-00090 KUPARUK RIVER WL (PROF FINAL FIELD 2 -Sep -19 1 1J-156LZ 1H-115 50.029.23311-61 50.029-23605-00 EDEA -00019 EOSH-00094 1 KUPARUK RIVER KUPARUK RIVER 1.IPROF Memory WL IPROF FINAL FIELD FINAL FIELD 5 -Sep -19 1 5 -Seo -19 8 l A Transmittal Receipt signature confirms that a package (box, nvelope, etc.) has been received and the contents of the X package have been verified to match the media noted above. ' Print Na € Signature Date The specific content of the CDs and/or hardcopy prints mayor Please return via courier or sign/scan and email a copy to hl Berger and CPAI, may not have been verified for correctness or quality level at this point. Alaska PTSPrintCenter@slb com Tom.Osterkam Conoco hit com SLB A u d itor- Schlumberger -Private STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Abandon ❑ Plug Perforationsq!j�.,Fracture Stimulate EJ Pull Tubing E] Operations shutdown E]Performed: Suspend E] Perforate & V fn- Other Stimulate ❑ Alter Casing ❑ Change Approved Program ❑ Plug for Redrill ❑ erforate New Pool ❑ Repair Well ❑ Re-enter Strap Well ❑ Other: MBE Cmnt Isolation 0 2. Operator Name: ConocoPhillips Alaska, Inc. 4. Well Class Before Work: 5. Permit to Drill Number: Development ❑ Exploratory ❑ Stratigraphic❑ Service 0 206-069 3 Address: P. 0. Box 100360, Anchorage, Alaska 6. API Number: 99510 50-029-23311-61 7. Property Designation (Lease Number):8. Well Name and Number. ADL 25660, ADL 25661, ADL 25663 KRU 1 J -156L2 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 70. Field/Pool(s): N/A Kuparuk River Field / West Salk Oil Pool 11. Present Well Condition Summary: Total Depth measured 12,566 feet Plugs measured None feet true vertical 3,330 feet Junk measured None feet Effective Depth measured 12,550 feet Packer measured 5,640 feet true vertical 3,330 feet true vertical 3,411 feet Casing Length Size MD TVD Burst Collapse CONDUCTORSURFACE R RECEIVED 2,739 feet 103/4" 2,7MD 2167 EIVED 69'2167'TVD INTERMEDIATE 5,671 feet 75/8" 5,697' MD 3625' VD D -SAND LINER 6,692 feet 4 1/2 " 12,552' MD 3449' VD MAY 3''aa1 22019 /" Perforation depth: Measured depth: slots 5922-12505 feet OG CC True Vertical depth: slots 3444-3333 feet Tubing (size, grade, measured and true vertical depth) 4.5" 0 5,675' MD 3,417' VD Packers and SSSV (type, measured and true vertical depth) PACKER - BAKER ZXP Liner Top Packer 5,640' MD 3,411' TVD SSSV -NONE 12. Stimulation or cement squeeze summary: Intervals treated (measured): N/A Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas-Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: - - Shut -In - - Subsequenttooperation: - - Shut -In - - 14. Attachments (required per 20 AAC 29.070, 25.071, E 25.283) 15. Well Class after work: Daily Report of Well Operations 0 Exploratory ❑ Development ❑ Service O Stratigraphic [D Copies of Logs and Surveys Run ❑ 16. Well Status after work:JAI Oil E] Gas ElWDSPL E]11Printed and Electronic Fracture Stimulation Data GSTOR F_WINJ WAG GINJ ❑ SUSP❑ SPLUG❑ L� 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 319-199 contact Name: John Peirce Authorized Name: John Peirce Contact Email: John.W.Peirce@cop.com Authorized Title: Sr. Wells Engineer Authorizetl Signature: /3 �'1 Contact Phone: (907) 265-6471 r�yxDale: .S Form 10-40XeAsed 4/2017 11 "7' "/'3/"' l!3/! `) 0 31019 { 6/�Il / Submit Original Only /( (/ ��BDMS4�✓JUN Loepp, Victoria T (CED) From: Peirce, John W <John.W.Peirce@conocophillips.com> Sent: Friday, June 7, 2019 6:39 AM To: Loepp, Victoria T (CED) Subject: 11-1561-2 Schematic Update - Shows Cement Plug for Toe MBE Isolation - attached Attachments: 11-1561-2 Schematic Post -MBE Isolation.pdf Follow Up Flag: Follow up Flag Status: Flagged Victoria, Here is an updated 1J-1561-2 schematic you requested for the 10-404 that reported the 1J-1561-2 MBE Isolation using a Cement Plug. We placed Cement in the Liner x Openhole annulus adjacent to the Cement Plug in the straddle inside the Liner so we tried to show all of this on the schematic. John Peirce Sr Wells Engr CPAI Drilling & Wells (907)-265-6471 office KUP INJ WELLNAME 1J-156 WELLBORE 1J-156L2 ConocoPhillips Well Attributes Max Angle & MD TD Alaska.lrX;. „x Wm,�pM �„� Mein MpmNel MlaxnlNNm WEST SAK 600292331161 INJ 90.21 6.n2.48 12.566.0 N]S IWmI Dab Mmlrlor Ifteewi $BSV MDNE led WO; 31.20 M122006 M„mcx l.ww-1r15I aeSR-?, :,2RM Last Tag VRRNRe lenm (R-nl Mn~Rn Dope, IgKBI Entl DM I W.I. Ilu[MM aY r4WGE.F 0.0 Las Teq 1 SONNSCr Last Rev Reason I Mrro elan EM Oere `R". Iae1 MTA 6Y REV EAS N: 1 ET CEM ETAINER PUMP 35.] BBlS 982019 J- 5 pDrmen CONDUCTOR. 2dOIm0 CEMENT FOR MBE TREAWM .Upi CMT JOB Casing Strings -=er oD lau m8aTa.85u9.8m sal,Dep.l,slNe19a,D..pnRw1ww.nn1-410 Top Tl,rue SURFACE: 542$NaT BTC Liner Details CAVNG IATCN; C..D NRRi 10 OASLIFT'. S,STJB TCp T- Top (Np)INNB) Tnp inti r) Ilem Des Cwn lin! r1PRLENK03 5. 44 B 8 . I SLEEVE BAKER'FIR'SETTI 5 VE .7 5,16.5 ..4d.789.721XOSUSHING CROSSOVER BUSHING 3.930 sFL.AL�"T'sse sva: Other In Hob (Wirelhla retrievable plugs, valves, pumps, fish, etc.) TYRE20ry RTER-CHEM; Top1TV01 Taplrcl S..n T'P(DKB) aMBI fl Dee Com RunDee ID (in) D NDUNERLEMESW.? 11 10,797p .34.) 92.191NFLATABL 5- INFLATABLE CEMENT RETAINER 105' L 916219 s'�a CEMENT INTERMFW.TE: 182e..' D RETAINER CRAND NNER IN: S.® . S.O.ba 11437.0 3. ). . 1 FISH 2S INFIATABL CEMENT RETAINER 1J 11,536. 144'.41 90. I6 50'INFLAT B -BRIDGE PLUG 9T521 Perforations S Slots rop(rvDl n`iW 01 IMnIN1 tln4mbm Wm 1 Type Can Tw INNBI 91mpMD1 I3,4 - - 3.B 5. .0 6,609.0 3. a )J WS ,11 ] .0 SLOTS AD.125 padIJI510tle0 pipe TS _ -D.TzsWs raa 4 9Lmaa.&200 1ie5 ND%R, 3'ecrean VaWe nid 18 Ce3nSndweG.ndN 6. ],65&0 3433.3 3W-5 WSD, 1}15812 7 ,0 SLOTS 8423.0 3, 257 -7MET WS D-. M 7/24!1 SLOTS 9. 1. O. 1}15612 72 .0 SLOTS SLOTSA=0-7,e5&0� 9,692-0 3. 3,560 WS D. 1J.1 ) M 0 SL T 1 .16 . 1 ,69.0 .6 3, .6 WS D, 11156L2 -7<=6 32.0 SLOTS _ _ 1 11,429.0 3,W5 3.207.9WSO, 111 ]242006 voTS 11717Z. -1-1-M-0 3 .3 Ws-5-1-M, 7-112006 32.01PERF ADDPERF2. 'Hso2506 SLOTS; i.M2O8I23.D - 6 SPF 11.614.0 12505. .0 3, W D. 1J•1 )WA-69 32.0 SLOTS _ Cement Squeezes Tcp ITVD) Bim (Nm Top lflNBl BIm IflXB) IRNB) pIRDI D4 b2 pah Com $ - 1.04.0 11,536.0 3, 9. 3, ). Unar Cement 9181 19 8.6 PPG ULTRA LITE CRETE xms:4eesoa,,9.D - Notes: General & Safety EM pal' M,roMbn - ]282006 N TE'. MULTPATERAL WELL; 1J-156(AAAN)I. J-15611(MA C),IJ-156L2( ND) - iw NTE: EXItIRORLD CEMENT PLUG IN IGNER AND PEN HOLE finen 10,79T to 11.5 SLOTa:9,e1LO4as SLOTS; 10.151610 we Lvu Caret; 10,]y0 NG IHFIATASLECFMFm RETNHER; 14NT0 Opn11r6 CR,w; IsAMA r 1' 6LOTSa09N.0.t1A2B.0 LOTS. 1000 i ] ra F15N;11.4Y1A RP: 11,98.0 SLOTS, 11.6N.O12SM,0 D DUNEIRLRSW6 RaMa KUP INJ WELLNAME 1J-156 WELLBORE 1J-156 Conocomillips AIa$Iu, I11C H.,y,SS. YR'PI52:13i]PM Other In Hole (Wireline retrievable plugs, valves, pumps, her, eto.) VevalcMr,n�lacOnll raP Z( Ol Top mcl .,... TePIXKB) (XKB) P) Ox Can flunDM ID lint HANGER 00 6,0]2.0 3,489.9 8056 TYPE160 BAKER TYPE I(SOLAN LEVE, 4' G PROFILE, &2&2019 2.590 SLEEVE -B- 3.69'ODX19'L LEM 6.118.0 3.49].5 8021 DB PLUG OB PLUG B PRONG 312812019 0000 .�.�. CONDUCTOR:M O-IDLo perforations& Slots Snot Den rop IT) Bl WAS) 'Aho SURFACE', i].2-],iOI.T Top M. st-wal Xtl(BI I(O(91 LinkM Zone paq I Type Cam ],043.0 ],130.0 TWT 3,6372 WS A2, 1J-156 7192006 320 SLOTS Ilemann9 slotletllsolitl LASING PATCH: 5.3J]0 glpeD125"%2.5"A3 sp1 4 CiMumferentiel adjacent rows. 3- Centers GAS UET:5,5I3a sNggeretl 18 deg., 3 X. non- NIPPLE: S.WJ.J Sinned ends ],344.0 7,3870 3,661.5 3,664.1 WSA2,1J-156 7791296 32.0 SLOTS 7.431.0 ],4]40 3,665.4 3,665.5 WS A2, 1J-56 7/912006 32.0 SLOTS LOCATOR', S..1 7,517. ),5610 3,6647 3,663.5 WS A2, 1J-156 7/912006 32.0 SLOTS sEUAssv; s.ea3.a 7,602.0 ],642,0 3,662.1 3,861.8 WS A2, 1J-156 719/2006 320 SLOTS 7,685.0 7.728.0 3,6618 3,660.3 WSA21J-156 7/9/20M 32.0 SLOTS ],7]1.0 7.8140 3,657,6 3,654.7 WS A2, 1J-156 7512W6 32.0 SLOTS TYPE zorvERrea-SEEM: 3 78570 7,8980 3,652.1 3,649.8 W6 A2, IJ-155 752006n.0 SLOTS -LE ],9410 7,9840 7,647.8 3,9T5.2 WS A$ 1J-15S ]/912006 32.0 SLOTS 8,0250 8,068.0 3,842.5 3,639.6 WS A2, iJ-156 7/92006 32.0 SLOTS 8.1110 8,155.0 3,837.0 3,M 7 WS A2. 1JA56 752006 320 SLOTS 8,1970 8,241.0 3, 3,631] WS A2, 1J-156 7512006 32.0 TL UTS Mandrel Inserts s aR 0.SWOLINER LEM:SSgT Top ITV3) Valve LeleX PoNSiY TRO Run S.Sro.a N Top (ORB) IXKBI Make Model OD gni Sery Type rype (in) Ipag Run Oeb Co. 5573.9 3,396.8 Camco KR12 I 1 GAS LIFT DV BK 0.000 0.0 102]12018 Notes: General & Safely D-SAND LINER HH: SARK 3 EM Da18 AnM,tlion sense- 7/282006 NOTE:MULTI-LATERALWELL: IJ-156(A-SANDS),1.15L1(B-SANDS),1J-156L2(D-SANDS) 0&2011 NOTE'. VIEW SCHEMATIC W/Alaska SLDem.k9.OREV TYPE I ISO SLFF7EB EM: sono Oa PLUG a,taO &SAND LINER LEM; sWI3— 6.,9] S IRS B DLINER HH; S.0)03 S ASO INIENUI.C.TE', 35.28,5313 SLOTS1,03.61.130.0 SL015; 7..07,33r.3 $Lon. 7e310-7 4ra.0 SLOTS. 7517 O7,SPS SLOTS:7.802.0-7.320 SLOTS;7.60 77m.o SLOT: 77710-7m40 SLOT: 1.83707,x.0 SLOTS: 7.WH 67,98,10 SLOTS.S...T8.0 SLOTS; 31111.08,150.0 SLOT:8,167C$y10 A2 LINER; B.tEQ.5d.T50� Tell ConocciPhillips Alaska. Inc. KUP INJ WELLNAME U-156 WELLBORE 1J -156L2 molepM Lm,a-u.+seLZ Snaaomzl5m vm1 Last Tag O+eml wavee(cpitl) MnabTron Oepta(wr 1 End DAM Wellbore Lmt Moo By .......................... NPNOER ed pas......... LOS! Tag: IJ -15612 Imosbor Last Rev Reason Mnomlon EnaDM WNlbort Iae+mM lsy Rev Reason' REVISE tL6a IDs 5/1)2013 1J-15612 os60rl corvoucroR:2e.D+mo Casing Strings caslne 0a:crlptrcn oG lm) to fin) ropnlKBl set D.pN eKZ? SAI, N,HM1 INDI... W 1-,n p._ Gude Top Tnl D -SAND LINER 412 348 5,859.8 125518 3,330.5 t160 L-80 BTC SUREUE: 3o.2z2 M 7 LmBr DeGlls CASING PATCH: 5.3]]0 TOPM 61Tap(NOIIM{BI TOp IMI C) IkT Des Com Nominal l0 0n) GAsunasn.p 5,6598 3,4428 8).31 SLEEVE BAKER'HR' SETTING SLEEVE 5.750 NIpFLE: 5.¢00.3 5,918.5 3,443) B9J2 ixu BUSHING CROSSOVER BUSHING 3.930 Perforations 3 Slate LOCATOR', 55167 SEALA6sY, ss16A WPE20rvERTER. RLEM: 5894.0 DSAMD uNER HN, 5694.3 s.eoe.e INIERMEOIATe, 262e.s61 S T"MB) BtMMKB) Top VVD) WB) BM(TV IbNB) LlnkeE ZOnp Dab fiber DeM paobHl ) Type Com 5,922.0 6649.0 3.443.8 3,43Z] W 0, 1J- 1560 ]I2d12006 32.0 SL T Iemaling solldsSIORed Fice-O.RS" F'@4 OSANOUNERLEM:SewaL arWnfismo4aladjac t S.H10.1 rows,r centers Ste ere] 18 Deg, 3' non-slo ends 89080 ).6560 3,4333 3,4345 .7r. 1J- ]242006 320 SLOT 15612 7,9120 8,4230 3,425.1 3,405.6 WSD, 1J- ]/24/2006 320 3E7TS / — — 15812 i — — 8683.0 9.59.0 3,399.3 3,391.7 WS D, 1J- 7/242006 32.D SLOTS 15612 ' SLors:SMOA.ueo_— — 94120 9,892.0 3,3804 \ 3,368] WS D. IT-- 15812 TrN=T 320 SLOTS / — 10,1510 10,6510 3,3@46 3,354.6 WS 5T )242006 320 SLOTS 15612 10,91]0 11,429.0 3,344.5 3,33).9 W D, - )I24I2006 .0 SLOTS' 56 2 1, 40 12,505.0 3,336.0 .5 J- )242006 J2.0 SLOTS 5612 Notes: General & Safety —End sLors: ¢song;ess.0— Da@ AMowixan p2&21X16 NOTE. MULTI -LATERAL WELL: IJ-156(A-SAND),tJ-156L1(8-SAND),1J-156I2(D-SAND) - SLOTS,),slzoe,ia.0 - /1 perfs not,i�t t�r'ccL sLors: aeenusJsao � � � J i SLOT6:9i176 092,0 h SLOT5:+0.+516t0 On,0 141 61016: 10.912011,<R,0 L ( {+ e 11 '9gp a say 6LOTS:II.SMO-IZS0SO D-SAMD USES, 5M5 �j i]5s1 e 1 J-1 56L2 PERFORATE, MBE CEMENT ISOLATION DTTM JOBTYP SUMMARYOPS START 5/15/19 SUSTAINMENT RIH WITH BAKER DUMMY DRIFT AND JET NOZZLE, PERFORM FLUFF -N -STUFF FCO FROM 5810' CTMD TO COIL LOCKUP AT 11696' CTMD, RIH AND SET BAKER 2.50" IBP AT 11536' CTMD, JOB IN PROGRESS. 5/16/19 SUSTAINMENT RIH WITH BAKER MHA AND SLB TCP GUNS (2.50" HSD 2506 POWER F 6 SPF), DROP 1/2" 8A IRE GUNS, TOP SHOT A 11170' RKB, BOTTOM SHOT @ 11175 B, GUNS CONFIRMIRE_ , RIG UP BAKER CEMENT RETAINER, JOB IN PROGRESS. 5/17/19 SUSTAINMENT RIH WITH BAKER INFLATABLE CEMENT RETAINER TO 10,787' CTMD, DROP BALL TO INFLATE RETAINER BUT UNABLE TO GET THE RETAINER TO HOLD DOWN WEIGHT, RIH TO 11437' CTMD AND STACK -10K ON RETAINER, DROP 5/8" BALL TO DISCONNECT BHA, RIH WITH SIDE JETTING NOZZLE AND WASH ACROSS SETTING AREA FROM 10,700' TO 10,850' CTMD, F/P TBG TO 5000' CTMD, RETURN IN AM FOR RESTART. 5/18/19 SUSTAINMENT RIH WITH BAKER INFLATABLE CEMENT RETAINER TO jQZR7' CTMD, DROP BALL TO INFLATE RETAINER, PUMP 35.7 BBLS OF 8.6 PPG ULTRA -LITE CRETE, PUMP 35.2 BBLS THROUGH CEMENT RETAINER, UNSTING AND LAY IN .5 BBLS ABOVE RETAINER, LAY IN FRESH WATER 1:1 TO 5000' CTMD, LAY IN SLICK DIESEL FROM 5000' TO SURFACE, CALL WEST SAK PE TO DISCUSS KEEPING WELL SHUT IN FOR 3 DAYS BEFORE RETURNING WELL TO INJECTION, JOB COMPLETE. p 7`D ,2 06 —oro 9 Loepp, Victoria T (DOA) From: Loepp, Victoria T (DOA) Sent: Thursday, May 16, 2019 9:13 AM To: Peirce, John W Subject: KRU 1J-1561_2 (PTD 206-069, Sundry 319-199) Cement Plug to Isolate Toe MBE Revision Approval John, Approval is granted for the change outlined below. Please update the approved sundry with this approved revision. Thanx, Victoria Victoria Loepp Senior Petroleum Engineer State of Alaska Oil & Gas Conservation Commission 333 W. 7th Ave Anchorage, AK 99501 Work: (907)793-1247 Victoria. Loeooaalaska.00v CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Victoria Loepp at (907)793-1247 or victoca.Loe .g alaska.gov From: Peirce, John W <John.W.Peirce@conocophillips.com> Sent: Wednesday, May 15, 2019 12:48 PM To: Loepp, Victoria T (DOA) <victoria.loepp@alaska.gov> Subject: re 1J-1561-2 Cement Plug to Isolate Toe MBE Sundry Approval 319-199 of 4/22/19 Hi Victoria, I just got a call from our Coil Tbg Well Supvsr on 1J-156 D Sand Toe MBE Isolation with Cement job (Sundry approval #319-199, of 4/22/19). We just got down the well with an Agitator on Coil Tbg while pumping lubricant and were able to get down 11700' RKB before stacking out. Our previous max depth attained during an IPROF we did 4/2/19 only made it to 11230', so we have gained some reach. Plan forward is that we now try to set our bottom Plug for the Cement job at 11536' RKB (target) at the middle of a 216' blank liner section at 11428 —11644', but we have concerns that without the Agitator on BHA that we may not be able to get to 11536' target to set the plug. The Agitator can't be used while setting a Plug. Our plan B option is that we would set our bottom Plug in the next up hole long section of blank liner where the Cement Retainer was intended to be set at 10787' RKB. This is 749' shallower so we would be giving up another 749' of wellbore. We would also then move up our Cement Retainer to the next long blank section with the mid -point of this blank section at 10021' RKB. Because the Cement plug may have to be placed up hole by ^749', this is different from what we proposed in the 10-403 that was approved. I don't suspect this is a significant issue regarding the Sundry approval we have but I wanted to let you know about it anyway. We are on the well today and will be attempting to set the bottom plug this afternoon at 11536, but if we can't reach we may target setting it at 10787' and proceed to move the cement placement —749' up the hole. If all goes well we may have this Cement Plug job done by this weekend. Please contact me if you have any concerns regarding our Sundry approval with regard to modifying the Cement placement plan, if needed. Regards, John Peirce Sr Wells Engr CPAI Drilling & Wells (907)-265-6471 office THE STATE 0ALASKA GOVERNOR MIKE DUNLEAVY John Peirce Sr. Wells Engineer ConocoPhillips Alaska, Inc. PO Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, West Sak Oil Pool, KRU 1J -156L2 Permit to Drill Number: 206-069 Sundry Number: 319-199 Dear Mr. Peirce: Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 www. oog cc. of a ska.g ov Enclosed is the approved application for the 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, Daniel T. Seamount, Jr. Commissioner / DATED this �ay of April, 2019. . RBDMSu:_ APR X019 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 RECEIVED APR 17 2019 AOGCC 1. Type of Request: Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Repair Well ❑ Operations shutdown❑ Suspend ❑ Perforate [D Other Stimulate ❑ Pull Tubing ❑ Change Approved Program❑ Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other: MBE Cmnt IsolabonEl 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number. ConocoPhilli s Alaska Inc. Exploratory ❑ Development ❑ Stratigraphic ❑ Service o 206-069 3. Address: 6. API Number. P. O. Box 100360, Anchorage, Alaska 99510 50-029-23311-61-00 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? N/A KRU 1J -156L2 a Will planned perforations require a spacing exception? Yes ❑ No 111 9. Property Designation (Lease Number): A.�� 10. Field/Pool(s): ADL 25660, ADL 25663 'Z 64i Kuparuk River Field /West Sak Oil Pool 11. 3 PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): 12,566' 3,330' 12550 3330 1450psi NONE NONE Casing Length Size MD TVD Burst Collapse Conductor 80' 20" 108' 108' Surface 2,739' 12" 2,769' 2,167' Intermediate 5,671' 8" 6,961' 3,626' Liner 6,692' 412 12,552' 3,331' Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): slots 5922-12505 Slots 3336-3437 4.500" L-80 5,675' Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): PACKER = BAKER ZXP LINER TOP PACKER MD = 5640 and TVD = 3411 SSSV =NONE N/A 12. Attachments: Proposal Summary Ej Wellbore schematic 0 13. Well Class after proposed work: Detailed Operations Program ❑ BOP k h ❑ Exploratory ❑ Stratigraphic ❑ Development ❑ Service p 14. Estimated Date for 16/2019 15. Well Status after proposed work: Commencing Operations: OIL ❑ WINJ ❑ WDSPL ❑ Suspended ❑ GAS ❑ WAG O GSTOR ❑ SPLUG ❑ 16. Verbal Approval: Date: /1 Commission Representative: \ r GINJ ❑ O p Shutdown ❑ Abandoned ❑ 17. 1 hereby certify that the foregoing is true and the procedure app ved herein will not be deviated from without prior written approval. Authorized Name: John Peirce Contact Name: John Peirce Authorized Title: Sr. Wells Engineer Contact Email: John.W.Peirce@cop.com /1) Contact Phone: (907) 2653471 Authorized Signature: W - t ' — Date: 1 17 — - COMSSION USE O LY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: I M1 (J) Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Loce6on Clearance ❑ Other. / Post Initial Injection MIT Req'd? Yes ❑ No PJ Spacing Exception Required? Yes ❑ No E?/ Subsequent Form Required: �9.9L RBDMS -14�APR 2 3 2019 APPROVED BY Cri Approved by/ll//� OI Dale: /G 2— E THE COMMISSION I Form 1ONO3 Reviud 4/2017 v 7-'-4//"//l Submit Form and Approved application is valid for 12 months from the date of approval. Attachments in Duplicate West Sak 1J -156L2 Cement Plug Placement to isolate `D' MBE 1J-1561-2 West Sak D Sand horizontal Lat has 4.5", L-80 tubing & liner set to 12551' RKB. The 4.5" liner has single -40' slotted joints alternating with single -40' blank joints, with periodic -250' blank sections spaced apart at every 500 to 1000' in the liner. On 3-8-19, an MBE occurred from 1J-156 to 1J-156 offset producer. This is the first MBE in 1J-156 since it was drilled and completed in 2008. On 3/29/19, a 1J-156 mainbore IPROF saw all SWI going to the D lateral. On 4/2/19, a D lat IPROF to 11230' CTMD (lockup) did not log any detectable MBE, but the log showed a good split of total injection still heading toward the toe beyond what could be reached with the CT logging BHA. This highly suggests that a D MBE must exist toward the toe of the well. It is proposed that the toe D MBE in 1J-1561-2 be isolated with a Cement Plug rather than attempt an RPPG treatment, because similar cement plug jobs using 8.6# Ultralight Cement in horizontal wellbores to isolate toe MBE's in 6 other wells all remain successful so far. Using 8.6 ppg cement that is neutrally buoyant to -8.6 ppg water prevents leaving a high side channel due to cement slumping that can occur using heavier cement blends. 1J-156 is currently configured with the A Lat isolated by a Plug, the B Lat isolated by an Iso-Slv, and a D Diverter is set. Coil Tubing - Proposed Procedure: 1J-156 & 1J-152 will both be Sl for several days to a week before cement job to abate crossflow and pressure equalize the wells via open MBE. This mitigates possibility of cement movement before set. 1) RIH with Agitator and Nozzle BHA to maximum attainable depth in 4.5" liner while performing a Fluff & Stuff and jetting away 1 full 290 bbl transport of lubricant solution mixed in Seawater to the well. This helps CT to reach target depth of Bridge Plug set. POOH with BHA to PU Bridge Plug. 2) RIH with 2.5" run OD Permanent Inflatable Bridge Plug. Inflate and set the Bridge Plug at 11536' RKB at the middle of a 215' OAL blank section of 4.5" liner. POOH. 3) RIH with 2.5" run OD x -5' CAL perforating gun to shoot 5' of 'large hole' perfs, at 6 spf, 60 deg phasing in 4.5" slotted liner at 11170 - 11175' RKB (target). POOH with gun. 4) RIH with 2.5" run OD Inflatable Cement Retainer and set the Retainer at -10787' RKB (target) in the middle of a 259' CAL blank section of 4.5" liner. Pump 35.7 bbls 8.6# Ultralight Cement to fill -749' of 4.5" slotted & blank liner between Cement Retainer & Bridge Plug, and to fill -987' of adjacent 4.5" liner x 6.75" OH annulus to isolate the D toe MBE below the Bridge Plug. PU to disconnect CT from Cement Retainer. Spot last 0.5 bbl of cement above Retainer. POOH slowly displacing liner & tubing with Seawater and Diesel FP to 2000' TVD. The perfs are -374' above Bridge Plug, and -374' below inflatable Cement Retainer, with intent that cement placement to Liner x OH annulus will occur from the center of the straddle in the liner to displace cement evenly along the liner (upward & downward) adjacent to the straddle inside the liner. Wait on cement 7 days then return 1J-1561-2 to SWI. Evaluate 'D only' SWI performance and monitor offset producer 1J-152 performance to verify that the D MBE has been isolated. Restore SWI to B &A Lats after D MBE has been verified to be isolated. JWP 4/17/2019 ConocoPhillips Alaska, Inc. SURFACE: LOCATOR', SEµ ASSY. 0.5PNULINER © 5awvA 0E DLINER HH, 6 MS mPE11sOSLEEVE- SSANO LINER A-: SLOB; SLOTS: .TS: SLOTS. SLOTS', KUP INJ WELLNAME 1J-156 Sam pM CSG) WELLBORE Com cmn 1J-156 Top(--) 's' MD) (WE) Top Incl fl Des Com aun Deh mSnl 5,3070 3,334.2 74.06 SIN Casing patch set at 5414to 5307' 1OQ41201 6.086 PATCH8 5,664.0 3,419.3 7838 TYPE 2..KERTY E DIVER PR "LE, 3.69" D% 3I2&2019 3000 DIVERTER-D- 18'L LEM KUP INJ WELLNAME 1J-156 WELLBORE 1J -156L2 r ' Conoc�a�a� tl �' oPhllhps Well WbUtes 17ONWeIIEORAPVUW Max Angle 8 MD TD Alaska, 0,c' We11Mn$ us MO (XK91 piBlm (ttNB) WEST SAN 500292331161 INJ 4.22 6,__248 12,566.0 Comment X35(Ppm) Date E.E Gale KfiUM(a) RIB Ro"-Dale SSSV: NONE JA—co.. Law WO. I 3120 8/12_20(6 A9tirb lwarals1,F15612. 472019131 i]PM Last Tag VMLl vlmleh lattuv0 Ammmmion pepta gets) I Endome I WMpJ(e 1 Lmm MOtley ....................... HANGER: 00' ... Last Tag: 1J, 15612 Premsbor Last Rev Reason Annotation End Oare WNll teal Mod By Rev Reason: REVBE 116b IDs 91J/2013 1J-15612 osb0rl M CONDUCTOR: ]eP1fA.0 Casing Strings Casing DescrlWon 1,00 Pal ID pn1 Top(RKie fie[0¢pM(me( - dome (ND)—WtlL.,p Glade Top Tinned D -SAND LINER 412 3.48 5,8598 12,551.8 3,330.5 11.60 L-80 BTC 6LRERCE: 30L 2Z l.] Liner Details MING PATCH: 5, 3070 Top MKS) Top (iWl((111(s) Topincl ('1 11em Des NominaflD Cam (In) Gas uPT:6sT3.e 5,859.8 3,4428 8_.31 SLEEVE BAKER'RR'SETTING SLEEVE 5._50 NIPPIE.60006 5,918.5 3,443) 89_2 XO BUSKING CROSSOVER BUSHINGVII 3.030 Perforations & Slots LOCATOR. 6,61fi.7 IiE A55V:5,616,4 SNW TYPE 2 DIVERTER-6LEM: Top(NDI Eftn"M Sena (sMWI edetO SAXD LINER HH 5= ToP(I EQ 60n tM1Ke) Penn (Mid LlntM gena Oab Type Com 8906e 5,922. 6,649.0 ,4438 3,43__ D, 1J- JI242006 32.0 LOTS Aftenta9ng solid/slut INTERMEDIATE:26286=] 16612 pipe- 0.125"%25" @ 4 6&WO GNER LEM' S.6M9 s.aea circumferentia) adjacent rows, 3"centers ma,oned 18 deg. 3' non -slotted ends 06.0 _,656.0 7433.3 4345 —WTD—Tr--- 7774M 320 SLOTS 156L2 ], 120 $423.0 3425.1 _4056 W D, - 72412006 32.0 SLOTS 15612 8.0310 9,1590 3,3993 3,3917 W - _124 006 32.0 SLOTS 15612 94170 9,892. 3.360.4 3368.7 W - _I24I2006 32.0 SLOTS SLOTe: 59a0ge190— _ 15612 _ _ 10,151.0 10,65]0 3,384.8 33546 WS D, 1J- 7242006 32.0 SLOTS 15612 1e9120 11,4290 3,314.5 3,33].9 0,, U,7j'- ]2412006 32.0 SLOTS – 15612 11,6440 12,5 5.0 3,336. 3332.5 J- 71242006 32.0 SLOTS 16612 Notes: General & Safety sl.ms.9ma.P�aSs o__ — Ene a.M Ammnomon 7/2812006 NOTE: MULTILATERAL WELL iJ-156 (A -SAND), 1J-15611 (B -SAND), 1J-156L2(D-SAND) SLOTS: 7,912,oa4a o SLOTS 9,693.0-9.159.0 SLOTS: 10,1510-10,8570 SLOTS: 10.91T0,t 1,,Q9S 6LOT5:1f U1612,Yh0 G8AV0 GNER, 6a�6 tIS518 PyoF � • • • y ,\ Iy/74?, THE STATE Alaska Oil and Gas tib'`"+y'�����1 ofA T Conservation Commission 333 West Seventh Avenue c GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main: 907.279.1433 ALAS ' Fax: 907.276.7542 www.aogcc.alaska.gov Robert Christensen NSK Production Engineering Specialist SCANNED F FE 21.17. ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, West Sak Oil Pool, KRU 1J-156L2 Permit to Drill Number: 206-069 Sundry Number: 316-355 Dear Mr. Christensen: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Cathy P Foerster ' Chair A�U DATED this day of July, 2016. RBDMS IN JUL 2 2 2016 0III RECEIVED • STATE OF ALASKA JUL �O,S ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 01•,',SGCIlb 20 AAC 25.280 C 1.Type of Request: Abandon r Rug Perforations r Fracture Stimulate r Repair Well r Operations shutdown r Suspend r Perforate r Other Stimulate r Pull Tubing r Change Approved Program r Rug for Redrill r Perforate New Pool r Re-enter Susp Well r Alter Casing r Other: WINJ to WAG E✓ 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. . _ Exploratory r Development r 206-0690 ' 3.Address: Stratigraphic r Service I✓ 6.API Number: P. 0. Box 100360,Anchorage, Alaska 99510 50-029-23311-61 ' 7. If perforating, I?r' . 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? NA Will planned perforations require spacing exception? Yes r No V KRU 1J-156L2 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL025660;ADL025663 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): 12566 - 3.330 ` 12550' ' 3330' ' 943 Casing Length Size MD TVD Burst Collapse CONDUCTOR 80' 20 108' 108' SURFACE 2739' 10 3/4 2769' 2167' INTERMEDIATE 6935' 7 5/8 6961' 3626' D LINER 6692' 4 1/2 12552' 3331' Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): Slots:5922-12505 Slots:3336-3437 4 1/2 L-80 5675 Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft) SSSV=CAMCO'DB'NIPPLE w/3.875 NO GO PROFILE ` MD=497 TVD=496 PKR=BAKER ZXP LINER TOP PACKER -MD=5640 TVD=3411 12.Attachments: Proposal summary r WellBore Schematic 17 13. Well Class after proposed work: Detailed Operations Program r BOP Sketch r Exploratory r Stratigraphic r Development r Service 1"4"; 1 14.Estimated Date for 15. Well Status after proposed work: 07/20/16 OIL WINJ Suspended Commencing Operations: r r WDSPL r p r 16.Verbal Approval: Date: GAS r WAG p' , GSTOR r SPLUG r Commission Representative: GINJ r Op Shutdown r Abandoned r 17.I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Contact: Darrell Humphrey/Bob Christensen Printed Name Robert D. Christensen Phone:659-7535 Email: n1139@conocophillips.com ///�o_ _______ Title: NSK Production Engineering Specialist / Signature p`Vr4�""'� x� Date: 7---/ ,/`4 Commission Use Only Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 3 `Le - 5 Rug Integrity r BOP Test r Mechanical Integrity Test Vation Clearance r Other: Post Initial Injection MIT Req'd? Yes I" No r Spacing Exception Required? Yes r No rr� Subsequent Form Required: /0 --4-0 RBDMS I,L- JUL 2 2 2016 APPROVED BY Approved by: /142COMMISSIONER THE COMMISSION Date: 7-24e3 ._/ vrL 7r`� im i j , ,A Submit Form and Form 10-403 Revised 11/2015 veb Gm a d for 12 months from the date of approval. Attachments in Duplicate VVV 1 • • 1J-156L2 DESCRIPTION SUMMARY OF PROPOSAL ConocoPhillips Alaska Inc. requests approval to convert West Sak Well 1J-156L2 (PTD# 206-0690)from Water Only Injection Service to EOR Water Alternating Gas Injection service. Area of Review: West Sak well 1J-156L2 was completed as a Water Only Injector on July 7, 2006 to provide injection support into the West Sak D sands. Converting this well to a WAG injection well will provide enhanced recovery injection into the reservoir and increase the ultimate recovery of oil. This well will support existing producers 1J- 152, 158, & 178. Area Map with Y4 mile radius around target injection zone (see attached): There are three wells which pentrate the Wsak interval within a 1/4 mile radius of 1J-156L2. Offset producer 1J-152, and the production/injection pair 1J-180 & 182. The additional wells (158, & 178) are provided to give a complete picture of the developement area. Mechanical Condition of Well to be Converted: The mechanical condition of Wsak well 1 J-156 is good and is classified as a"Dual Casing -Trilateral"well. The injection tubing/casing annulus is isolated via a Baker ZXP Liner Top packer located at 5640' and (3411' tvd). Passed State-witnessed MIT-IA to 2010 psi was last performed on 16-MAY-14. KUP 1J-156L2 ConocoPhillips Well Attributes Max Angle&MD TD AlaskaInc. �� Wellbore API/UWI Field Name Well Status Inc!('I IMO(RKB) Act Btm(RKB) - 500292331161 WEST SAK INJ 94.22 6,772.48 12,566.0 ConocdRullips Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date SSSV:NIPPLE Last WO: 31.20 8/12/2006 Well Cantle Mu!bale Laterals-1J-1561_2,5/1720136:56:32 AM Schematic-Actual Annotation Depth(ftK8) End Date Annotation Last Mod By End Date ---- ----- --- Last Tag: Rev Reason:REVISE 11.68 IDs osborl 5/17/2013 HANGER,22 Illi Casing Strings Casing Description String 0... String ID...Top(kKB) Set Depth(1...Set Depth(ND)...String Wt...String... String Top Thrd D-SAND LINER 41/2 3.476 5,859.8 12,551.8 3,330.5 11.60 L-80 BTC CONDUCTOR, 28-108 Liner Details NIPPLE.497 Top Depth (ND) Top lnol Nonni... * F Top(ftKB) MKS) (9 Item Description Comment ID(In) 5,859.8 3,443.3 89.41 SLEEVE BAKER'HR'SETTING SLEEVE 5.750 SURFACE. L 5,918.5 3,443.7 89.72 XO BUSHING CROSSOVER BUSHING 3.930 GAS LIFT, 3.211 Perforations&Slots GAS LIFT, 1E1Shot 4'985 SLEEVE-C, Top(NO) Btm(TVD) Dens 5,595 Top(RKB)Btm(ftK8) (ftKB) (RKB) Zone Date lah... Type Comment LOCATOR 5,922.0 6,649.0 3,443.7 3,436.7 WS D,1J-156L2 7/24/2006 32.0 SLOTS Alternating solid/slotted pipe- 5,646 ISMS SEAL ASSY. 0.125'x2.5"@ 4 circumferential 5,648 � adjacent rows,3"centers staggered 0-SAND LINER a 18 deg,3'non-slotted ends LEM, 5,640.5,830 D-SAND LINER 6,906.0 7,656.0 3,432.9 3,434.4 WS D,1J-156L2 7/24/2006 32.0 SLOTS H. 5,694.5,009 7,912.0 8,423.0 3,425.9 3,405.5 WS D,1J-156L2 7/24/2006 32.0 SLOTS SLOTS, 5,922-6,649 8,683.0 9,159.0 3,401.0 3,391.3 WS D,1J-156L2 7/24/2006 32.0 SLOTS NTERMEDIATE. 266.961 9,417.0 9,892.0 3,381.9 3,368.8 WS D,1J-156L2 7/24/2006 32.0 SLOTS 10,151.0 10,657.0 3,363.3 3,355.2 WS D,1J-156L2 7/24/2006 32.0 SLOTS 10,917.0 11,429.0 3,344.5 3,337.9 WS D,1J-156L2 7/24/2006 32.0 SLOTS 11,644.0 12,505.0 3,335.5 3,332.4 WS D,1J-156L2 7/24/2006 32.0 SLOTS Notes:General&Safety = End Date Annotation 7/28/2006 NOTE:MULTI-LATERAL WELL: 1J-156(A-SAND),1J-156L1(B-SAND),1J-156L2(D-SAND) r E. SLOTS, ® a 6,906-7,656 8 8 SLOTS, 7,9124423 ti 8,6830,159 SLOTS, c c e SLOTS,___-_ 9,417-9,892 e c 1 i SLOTS, 10,151-10,657 a A SLOTS. 10,917-11,429 SLOTS, it, `c _ 11,644-12,505 Mandrel Details g 0 Top Depth Top Port - 5... (ND) Incl OD Valve Latch Size TRO Run $ g = N...Top(kKB) (ftK8) P) Make Model (in) Sere Type Type (10) (psi) Run Date Com... 0-SAND 1 3,210.8 2,396.0 60.66 1 GAS LIFT DMY BK-5 0.000 0.0 9/26/2006 LINER, d 2 4,984.8 3,222.7 65.42 CAMCO KBG-2-1R 1 GAS LIFT DMY BK-5 0.000 0.0 9/26/2006 5,860-12 552 TD(1J-1561_2),6L2L 12,566 - ✓ 27Jun16 • • ConocoPhillips Alaska, Inc. 1J-156 N 10-403 Sundry 0 0.15 0.3 0.45 0.6 Miles ADL025660 / ADL025661 „r" J M A' 9 -_ 1 I ; 1 { 3 i 1J-156` I I \ / 1 1 41I �1 I 1J158 r gi 4 , ADL025662 j' 1 7 1J-152L2 ADL025663 1 i `' 1J-152L1 x 1J-156L2 1J-156L1 i 11 11 1 11 1J-156 Open Interval 5 .5.415. mos 1J-156L2 Open Interval 7 3 i 1J-156L1 Open Interval l I 5 — 1J-156 Trajectory 5 1 *Well Pad 1J-178 01/4mi Radius 1J-156 5 31/4mi Radius 1J-156L2 ■Atlinrs m---% a ADL380058 11 11 3 1/4mi Radius 1J-156L1 —Well within 1/4mi Radius ' 'I a 1J-182L1 ■• WestSak PA 1J-180L1 1J-180 5 1J-182 KRU Boundary 11 CPAI Lease . • • • § -} �k2 \ E \\\\ } \ \\\ \ \ p6 0 2 122 [ P . - g (grg-,,,, 5 - - 8: 99 §r. , ! ! /!7§ME ":' ! 3 #ƒ I , \\� \ �k 7, \ \} \ \ \ \\ \k \\)t, }/ {15 815 " \\ }\ }\\\ }\ rg 01 § - \{ Jf-f)] � - \f - \} ) - },,,-,8 1 } , \) w .. ,- _ » () 2 L` \ ° \ \ \ 17 u ° i f« - - - - IL , , .t:-. , , « # \7 \\ j j ] § § d\{ j § �\ ƒ } }%} \ } \g. k :1'2, 2 - co� 1 q \ } \ \ a '.1 - .?-R, - F. - / 0 0 0 0 0 0 Image Projeet 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. d ~p - ~-(Q ~' Well History File Identifier Organizing (done) Two-sided III (I'III II III II III ^ Rescan Needed III II~III II II III III RESCAN DIGITAL DATA OVERSIZED (Scannable) ~olor Items: Diskettes, No. ~ ^ Maps: ^ Greyscale Items: ^ Other, No/Type: ^ Other Items Scannable by a Large Scanner ^ Poor Quality Originals: OVERSIZED (Non-Scannable) ^ Other: ^ Logs of various kinds: NOTES: ^ Other:: BY: Maria Date: O /s/ ~, Protect Proofing III IIIIIIIIIII IIIII BY: Maria Date: /s/ Scanning Preparation _~ x 30 = ~Q_ + ~ =TOTAL PAGES. ~~ Y/ (Count does not include cover sheet) ~/~/~`n BY: Maria Date: ~ ~ / / ~/'1 Q /s/ Y r Ll" Production Scanning Stage 1 Page Count from Scanned File: (count does include cover sheet) Page Count Matches Number in Scanning Preparation: ~ES NO BY: Maria Date: q/ ~ ~ O ~ /s/ I/// p Stage 1 If NO in stage 1, page(s) discrepancies were found: YES NO BY: Maria Date: /s/ Scanning is complete at this point unless rescanning is required. II I II II II I II II ((III ReScanned BY: Maria Date: /s/ Comments about this file: 7~ ouaory cneaee (III I~ 10/6/2005 Well History File Cover Page.doc i ~~ ~ ~ ,~„„ ~.y ~`~ '~ 'f ..~.s ,,. ~~ ~n ~ ,~ ~~ r ..5 ~~ ~ ir. m k iillll ,~, .~ M a~ 4. ~~. '~ .K: MLCROFILMED 6/30/2010 DO NOT PLACE ANY NEW MATE RLAL UNDER THIS PAGE C:\temp\Temporary Internet Files\OLK9\Microfilm_Marker.doc • • WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: MWD Formation Evaluation Logs: 1J-156 1+L1PB L2 ~ ! l October 15, 2008 AK-MW-4467716 Jtlee~ 3 d ~ ARew~- !~- -s~ The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Bryan Burinda, Sperry Drilling Services, 6900 Arctic Blvd., Anchorage, AK 99518 1J-156+L1+L1PB1+L2 2" x 5" MD RESISTIVITY & GAMMA RAY Logs: 1 Color Log 5 0-029-23 311-00, 60, 61, 70 2" x 5" TVD RESISTIVITY & GAMMA RAY Logs: 1 Color Log 50-029-23311-00,60,61,70 Digital Log Images '~,y~~~ ~ ~t~ J .t n n~~ 1 CD Rom 50-029-23311-00,60,61,70 ~ ~' ~` ~,-~I~ ,~ ,~ ~,~~,~~ PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry Drilling Services Attn: Bryan Burinda 6900 Arctic Blvd. Anchorage, Alaska 99518 907=273-3536 Date: BP Exploration (Alaska) Inc. Petrotechnical Data Center, MB33 900 E. Benson Blvd. Anchorage, Alaska 99508 lJ 1 C. cN Signed: ~~ 1 ~,cao6-o~~ U -t C ~ o~-~ ~S i~~ts 2 r7ts"3 DATA SUBMITTAL COMPLIANCE REPORT Q,~~ ~i~i2oos Y~ ~ Permit to Drill 2060690 Well Name/No. KUPARUK RIV U WSAK 1J-156L2 Operator CONOCOPHILLIPS ALASKA INC """~~~ MD 12566 ND 3330 Completion Date 7/27/2006 Completion Status 1-OIL Current Status 1 WINJ REQUIRED INFORMATION Mud Log No DATA INFORMATION Types Electric or Other Log s Run: GR/Res, Dens/Neu Well Log Information: Log/ Electr Data Digital Dataset Type Med/Frmt Number Name i ~!C'pt 14046 LIS Verification ~D C Lis 14046 Induction/Resistivity D Directional Survey Well Cores/Samples Information: Name ADDITIONAL INFORMATION Well Cored? Y N~ Chips Received? I~PY' Analysis ls`t'1~ Received? Comments: Compliance Reviewed By: API No. 50-029-23311-61-00 UIC Y Samples No Directional Survey Yes (data taken from Logs Portion of Master Well Data Maint Log Log Run Interval OH / Scale Media No Start Stop CH Received Comments Open 8!22!2006 2735 12508 Open 8/22/2006 GR, FET, ROP, Res 5697 12566 Open 11/9/2006 Sample Interval Set Start Stop Sent Received Number Comments Daily History Received? ~ N Formation Tops ~/ N Date: ov • r 26-Oct-06 AOGCC Librarian 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 Re: Distribution of Survey Data for Well 1 J-156L2 Dear Dear Sir/Madam: Enclosed is one disk with the *.PTT and *.PDF files. Tie-on Survey: 5,631.47' MD Window /Kickoff Survey: 5,697.00' MD (if applicable) Projected Survey: 12,566.00' MD PLEASE ACKNOWLEDGE RECEIPT BY SENDING AN EMAIL TO CARL.ULRICH@HALLIBURTON.COM OR SIGNING AND RETURNING A COPY OF THE TRANSMITTAL. LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Carl Ulrich 6900 Arctic Blvd. Anchorage, AK 99518 Date % euD y ~ ~ Signed Please call me at 273-3545 if you have any questions or concerns. Regards, Carl Ulrich Survey Manager Attachment(s) aob-o~9 STATE OF ALASKA ~ F. i,1 ~ ~ ~~'~~. ALASKA OIL AND GAS CONSERVATION COMMISSION ~~8s~8 Ij G8 ~ur~~. ~>O,r~s~l¢c,~~gl REPORT OF SUNDRY WELL OPERATIONS ~ ~t Fr,_~ 1. Operations Performed: Abandon ^ Repair Well ^ Plug Pertorations ^ Stimulate ^ Other ~ Prod to WIND Alter Casing ^ Pult Tubing ^ Perforate New Pool ^ Waiver ^ Time Extension ^ Change Approved Program ^ Operat. Shutdown[] Perforate ^ Re-enter Suspended Well ^ 2. Operator Name: 4. Current Well Status: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development ^ Exploratory ^ 206-069! 3. Address: Strati ra hic g p ^ Service / ^ 6. API Number. P. O. Box 100360, Anchorage, Alaska 99510 50-029-23311-61 7. K6 Elevation (ft): 9. Well Name and Number: RKB 109' 1J-156L2 8. Property Designation: 10. Field/Pool(s): ADL 25660 & 25663 Kuparuk River Field /West Sak Oil Pool , 11. Present Well Condition Summary: Total Depth measured 12566' feet true vertical 3330' feet Plugs (measured) Effective Depth measured 12550 ~ feet Junk (measured) true vertical 3330 feet Casing Length Size MD TVD Burst Collapse Structural CONDUCTOR 108' 20" 108' 10$' SURFACE 2659' 10-3/4" 2768' 2167 D-SAND WINDOI 1' 7-5/8" 5698' 3422' INTERMEDIATE 6852' 7-5/8" 6961' 3626' D-SAND LINER 6692' 4-1/2" 12551' Perforation depth: Measured depth: 5922'- 12505' true vertical depth: 3444' - 3332' Tubing (size, grade, and measured depth) 4-1/2" , L-80, 5674' MD . Packers &SSSV (type & measured depth) no packer SSSV=NIP SSSV= 497' 12. Stimulation or cement squeeze summary: Intervals treated (measured) ~~~ ~ - () CT `~ ~ 2006 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 2865 3536 72 1190 248 Subsequent to operation 2117 978 1 14. Attachments 15. Well Class after proposed work: . Copies of Logs and Surveys run _ Exploratory ^ Development ^ Service ^/ ` Daily Report of Well Operations _X 16. Well Status after proposed work: Oil^ Gas ^ WAG ^ GINJ ^ WINJ ~ ~ WDSPL ^ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.o. Exempt: 306-323 contact Bob Christensen /Bob Buchholz Printed Nam rt D ristense Title Production Engineering Technician , Signature Phone 659-7535 Date ~ p / Form 10-404 Revised 04/2004 / ~ `~- , Sub Original ~~a~~' 1J-156L2 DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary 09/17/06 Well. shut in for Producer to Injector conversion 10/01/06 Commenced Water Inject Service ,;; ~. Anchorage, AK 99510 Re: Kuparuk River Field, West Sak Oil Pool, 1J-156L2 Sundry Number: 306-323 Dear Mr. Christensen: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. .DATED this~,day of October 2006 Encl. STATE OF ALASKA ~ ~C/ R~4.~+~' V ED 2 ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVAL SAP 1 8 2006 20AAC25.280 __ ~_.4r.:__:_,. 1 . Type of Request: Abandon ^ Suspend ^ Operational Shutdown ^ , Perforate W fiver Other ^ ~nchora~ Alter casing ^ Repair well ^ Plug Perforations ^ Stimulate ^ Time Extension Chan e a roved ro ram g pp p g ^ Pull Tubing ^ Perforate New Pool ^ Re-enter Producer to Suspended Well ^ Injector 2. Operator-Name: 4. Current Well Class: 5. Permit to Driil Number: ConocoPhillips Alaska, Inc. Development ^ Exploratory ^ 206-069 3. Address: Stratigraphic ^ service ^ 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-029-23311-61 7. If perforating, closest approach in pool(s) opened by this operation to nearest property line 8. Well Name and Number: where ownership or landownership chang es: Spacing Exception Required? YeS ^ NO Q 1J-156L2 9. Property Designation: 10. KB Elevation (ft): 11. Field/Pool(s): ADL 25660 & 25663 RKB 109' Kuparuk River Field /West Sak Oil Pool 12. PRESENT WELL CONDITION SUMMARY Total depth MD (ft): Total Depth TVD (ft): Effective Deptn nn~ (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 12566' 3330' 12550' 3330' Casing Length Size MD TVD Burst Collapse CONDUCTOR 108' 20" 108' 108' SURFACE 2659' 10-3/4" - 2768' 216T D-SAND WIND0IN ~ _ 7-5/8" 5698' 3422' INTERMEDIATE 6852' 7-5/8" 6961' 3626' D-SAND LINER 6692' 4-1/2" 12551' 3331' Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 5922' - 12505' 3444' - 3332' 4-~/2" L-80 5674' Packers and SSSV Type: Packers and SSSV MD (ft) no packer SSSV= NIP SSSV= 49T 13. Attachments: Description Summary of Proposal ~ 14. Well Class after proposed work: Detailed Operations Program ^ BOP Sketch ^ Exploratory ^ Development ^ Service 15 Estimated Date for 16. Well Status after proposed work: Commencing Operations: October 1, 2006 Oil ^ Gas ^ Plugged ^ Abandoned ^ 17. Verbal Approval: Date: WAG ^ GINJ ^ WINJ ^~ WDSPL ^ Commission Representative: 18. I hereby certify that the foregoing is true and correct to the best of my knowledge.. Contact: Bob Christensen /Bob Buchholz Printed Name Robert D. Chris .nsen Title: Production Engineering Technician Signature Phone 659-7535 Date ~ `.~ Commission Use Only Sundry Number: Conditions of approval: Notify Commission so that a representative may witness b _ Plug Integrity ^ BOP Test ^ Mechanical Integrity Test Location Clearance ^ Other: ~~~ ~~~ Q~7 ~ ~ 2~~6 Subsequent Form Required: ~Q IGINA~L APPROVED BY /1~ d ~ - ~~^ ~ (vJ Approve by: COMMISSIONER T HE COMMISSION Date Form 10-403 Revised 06/2006 "' `/ Submit in Dupl'cate ,,~ 4.8.06 1J-156L2 DESCRIPTION SUMMARY OF PROPOSAL ConocoPhillips Alaska Inc. requests approval to begin Water Injection service in West Sak Tri- lateral Well 1J-156L2. This well has been pre-producing for 27 days in order to recover Oil based drilling fluids prior to putting the well on injection. Lateral 1 J-156L2 will provide pressure support for the West Sak D sands. The 10-3/4" Surface casing (2769' and / 2167' tvd) was cemented with 498 sx Class G followed by 184 sx Class G. The 7-5/8" Intermediate casing (6961' and / 3626' tvd) was cemented with 405 sx Class G. The injection tubing/casing annulus is isolated via the following: Upper D sand ZXP 5-1/2" x 7- 5/8" Liner Top Packer with 190-47 Casing Sealbore Receptacle located @ 5640' and / 3410' tvd, Upper B sand ZXP 5-1/2" x 7-5/8" Liner Top Packer with 190-47 Casing Sealbore Receptacle located @ 5801' and / 3443' tvd, and an Upper A sand ZXP 5-1/2" x 7-5/8" Liner Top Packer with 190-47 Casing Sealbore Receptacle located @ 6161' and / 3505' tvd. The top of West Sak D sand was found at 5683' and / 3419' tvd. ~- - , _ The top of Weft Sak B sand was found of 6080'_ and / 3491' tvd. The top of West Sak A sand was found at 7024'. and / 3630' tvd. ~` KRU 1 J-156L2 .t~ ~~~~cc~illips Al~s~a, lr~l~. 1-156L2 API: 500292331161 Well T : PROD An Ie TS: d SSSV T e: NIPPLE Ori Com letion: 7/28/2006 An le TD: 92 d 12566 Annular Fluid: Last W/O: Rev Reason: GLV C/O ..~ Reference Loq: 28' RKB Ref Loq Date: Last Uadate: 8/9/2006 "°~., Last Ta TD: 12566 ftK6 ,. Last Ta Date: Max Hole Angle: 94 deg ~ 6772 - - - - - Casing Stringy -ALL STRINGS Descri tion Size To Bottom ND Wt Grade Thread CONDUCTOR 20.000 0 108 108 62:60 H-40 WELDED ~ SURFACE 10.750 0 2768 2167 45:50 L-80 BTC ~~ ~~ 1 INTERMEDIATE 7.625 0 6961 3432 29.70 L-80 BTCM :':'. .::.~ '''....>~ D-SAND WINDOW 8.000 5697 5698 3422 0.00 TUBING D-SAND LINER 4.500 5859 12551 3331 11.60 L-80 BTC (0.5674, # -- - - Tubing String - TUBING _ oo:asoo, ID:3.958) _ _ __ _ Size mop Bottom _ ND i Wt Grade -~ Thread 4500 I 0 ~ 5674 t 3417 ` 12.60 ~ L-80 IBTM - -- - - _ - -- - i _ - _ Pertorations Summa __ _ - T Ft SPF Date Type I Comment Status - - e D ,6 5922 12505 3444 3 32 7/24!2006 SLOTS ARernating slottedlsolid pipe 3332 WS D 58 PACKER . _ Gas Lift MandreFs/Valves ~ 5640.5659, ( < :::: _ _ St MD ND Man Man Type V Mfr V Type V OD Latch Port TRO Date Run . Vlv OD:6.550) Mfr Cmnt 1 3211 2396 CAMCO KBG-2-1R GLV 1.0 BK 0.188 1456 8/8/2006 2 4985 3226 CAMCO KBG-2-1 R OV 1.0 BK 0._3_13 0 8/8/2006 f Other lu s, equip., etc. -COMPLETION _ - - - De th ND T e Descri tion - ID 22 22 HANGER VETCO GRAY TUBING HANGER 4.909" TOP CONNECTION. 4.500 497 496 NIP CAMCO'DB-6' NIPPLE w/3.875" NO GO PROFILE 3.875 5595 3401 SLEEVE-O BAKER CMD SLIDING SLEEVE OPEN 3.812 SBR 5659 5679 5646 3412 LOCATOR BAKER LOCATOR 3.875 ( - , oD:s 28o) 5648 3412 SEAL BAKER 4.75" SBE SEAL ASSEMBLY 3.875 . 5675 3417 SHOE 3.958 PUP (5sao-5ssa, -- - Other _ _ _ _ - -- -- - lugs,_equip., etc.)__D-SAND LINER 8 LEM°DETAIL _ - - -- _ oD:5.210) De h ND T e Descri ion ID HANGER 5640 3410 PACKER ZXP LINER TOP PACKER 4.970 (56845694, 5659 3414 SBR 190-47 CASING SEAL BORE RECEPTACLE 4.750 OD:6.600) 5679 3418 BUSHING CROSSOVER BUSHING 3.950 HANGER 5680 3418 PUP 3.958 (56945711, 5684 3419 HANGER LEM ABOVE HOOK HANGER 3.980 OD:7.625) 5694 3421 HANGER LEM INSIDE HOOK HANGER 3.980 5694 3421 HANGER BAKER MODEL B-1 HOOK HANGER FOR LEM 1NS1DE CASING 4.500 5711 3424 HANGER BAKER MODEL B-1 HOOK HANGER FOR LEM OUTSIDE CASING 4.500 HANGER 5717 3425 PUP 3.958 (56945718, 5810 3438 PACKER BAKER PAYZONE EXTERNAL CASING PACKER 3.930 OD:6.600) 5827 3439 SEAL BAKER SEAL ASSEMBLY 3.958 HANGER 5860 3441 SLEEVE BAKER'HR' LINER SETTING SLEEVE 5.750 (5711-5717, 5879 3443 BENT JT 3.958 OD:7.625) 5908 3444 SHOE MULE SHOE 3.958 PUP 5919 3444 BUSHING CROSSOVER BUSHING 5.5"x4.5" 3.730 (5717-5879, ~ 12550 3331 SHOE SILVER BULLET ECCENTRIC GUIDE SHOE - - 4.500 Genera __ l Notes --- PACKER 5810 5833 ~ Date - _ _ -_ - _ Note ( - , OD:5.630) 7/28/2006 MULTI-LATERAL WELL: 1J-156 (A-SANDS), 1J-156L1 (B-SANDS), 1J-156L2 (D-SANDS) TREE: VETCO GRAY! HORZ / 4-1/8" :~:~z:~:~~~< <:"^i•~€~~ TREE CAP CONNECTION: 1/2" OTIS x 4-1/8" 5M MEC:~ANICAI, INTEGRITY REPORT _ ~UL Li:__- `bf~~-V ~' QPER ~ FZELJ C~%~r.1. h~LL NUMBER ~ ~' IS ~ ~- ~...~ E- PL.. ~- HALL ~ATe Corsi^g ~71~ Shoe. ~~_MD 36~ TVD; D'J. ~~ ?~ ~•~ T~~ -=:~e= . ly~ Shoe . ~ '?'`1r ; ~'CP . ?•~ _'i~ _.:o,_ v. ~1~1~.~ packer ~ T'J7i cet et 5~,~15 ole S_~e end pelf; to C'r'.~?~ =C~.~ _NTEGRTTY - P?.RT # ? ~ ~ 'v.~~~J ~~a:.~ ,.7 ~:c1~ rnnulus ?ress Test: _? 15 min ~0 min Conents i `~' CHP NI C~~.., ~ NTEGR2'ry _ p~T # 2 ~ ~ L 6.~ ~ h ~ S . ~, ~~ ,,~ d ~ Cement Voles :~ Amt. Liner ~~ ~ Csg ~{ ~ 1~V ~~c Cmt -rol to cover oerfs ~ ~~ XS ~55Sh~~~~.~~~ck Sv ~~~~ ~`v :-:eoretical TOC C 3~~® X5 ~~C ~ ~~~R ~~c~,~rc9 ~~. C~b'`.,~: s ~-t~C~ - Cement Bond Log (Yes or No) l~~j In AOGCC File ~`(,O'OCo C3L Evaluation, gone aoove perfs ~3~3 ~' ~l '( Production Log: Ty-De ~ ~ ;c; Evaluation 4~~~-c=~ rvs~~Zv~C~\~~C~~~ CONCLJSIONS: ?art #1. ? 6r ~ f L - ~'~~~ " ~ ~~ °-~ ~ _~~ ~~ ~ ~-- ~LZv L STATE OF ALASKA ~' ALASKA OIL AND GAS CONSERVATION COMMISSION SEP 0 ~~ ?006 WELL COMPLETION OR RECOMPLETION REPoI ~~re~„m;~~;nn 1a. Well Status: Oil Q Gas Plugged ^ Abandoned ^ Suspended WAG ^ 20AAC 25.105 20AAC 25.110 GINJ ^ WINJ ^ WDSPL ^ No. of Completions _ Other _ 1b. Well Clas~nChO(age Development 0 Exploratory ^ Service ^ Stratigraphic Test ^ 2. Operator Name: ConocoPhillips Alaska, Inc. 5. Date Comp., Susp., ~ ,ba•S.DI~ or Aband.: July~j$'2006 12. Permit to Drill Number; 206-069 / 3. Address: P. O. Box 100360, Anchorage, AK 99510-0360 6. Date Spudded~~ ~G~ , 2006 •S•dlO 13. API Number: 50-029-23311-61 ' 4a. Location of Well (Governmental Section): Surface: 2094' FSL, 2559' FEL, Sec. 35, T11N, R10E, UM 7. Date TD Reached: July 23, 2006 ' 14. Well Name and Number: 1J-156L2 At Top Productive Horizon: 565' FSL, 313' FEL, Sec. 34, T11 N, R10E, UM 8. KB Elevation (ft): 28' RKB 15. Field/Pool(s): Kuparuk River Field Total Depth: 1028' FNL, 259' FEL, Sec. 10, T10N, R10E, UM 9. Plug Back Depth (MD + ND): 12550' MD / 3330' TVD West Sak Oil P001 4b. Location of Well (State Base Plane Coordinates): Surface: x- 558649 y- 5945905. Zone- 4 10. Total Depth (MD + ND): .12566' MD / 3330' TVD 16. Property Designation: ADL 25660 & 25663 TPI: x- 555629 y- 5944353 Zone- 4 Total Depth: x- 555744 - 5937482 ' Zone- 4 11. Depth where SSSV set: nipple @ 497' 17. Land Use Permit: ALK 470 & 472 18. Directional Survey: Yes ^~ No ^ 19. Water Depth, if Offshore: N/A feet MSL 20. Thickness of Permafrost: 4077' MD 21. Logs Run: (,(} d14.) J~`97 ~~j ,~ ~. ~~ ~ 9•S• C~ GR/Res, Dens/Neu 22. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTH ND HOLE AMOUNT CASING SIZE WT. PER FT. GRADE TOP BOTTOM TOP BOTTOM SIZE CEMENTING RECORD PULLED 20" x 34" 94# K-55 28' 108' 28' 108' 42" 1s3 sx Class G 10.75" 45.5# L-80 28' 2769' 28' 2167' 13.5" 498 sx Class G, 184 sx Class G 7-5/8" 29.7# L-80 28' 6961' 28' 3626' 9-7/8" 405 sx Class G 4.5" 11.6# L-80 5859' 12551' 3440' 3330' 6.75" slotted liner 23. Pertorations open to Production (MD + ND of Top and Bottom 24. TUBING RECORD Interval, Size and Number; if none, state "none"): SIZE DEPTH SET (MD) PACKER SET tubing in main wellbore 5675' slotted liner from 6649'-11644' MD 25. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNTAND KIND OF MATERIAL USED n/a 26. PRODUCTION TEST Date First Production August 17, 2006 Method of Operation (Flowing, gas lift, etc.) Pre-produced injector- shares production with 1J-156 and 1J-156L1 Date of Test 8/20/2006 Hours Tested 15 hours Production for Test Period --> OIL-BBL 1681 GAS-MCF 3073 WATER-BBL 33 CHOKE SIZE 85 Bean GAS-OIL RATIO 1921 Flow Tubing press. 578 psi Casing Pressure 1320 Calculated 24-Hour Rate -> OIL-BBL 2565 ~ GAS-MCF 4928 WATER-BBL 53 OIL GRAVITY -API (corr) not available 27. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water (attach separate sheet, if necessary). Submit core chips; if none, state "none". CO{~; pLET10N DZ~ NONE DER ED Form 10-407 Revised 12/2003 CONTINUED ON REVERSE .[D g~,'~. Q~ f$~ S ~F~. SEP ~ ~ 06 , ,,~/' ~~~. G ~~~~~~~ 28. 29. GEOLOGIC MARKERS FORMATION TESTS NAME MD TVD Include and brieFly summarize test results. List intervals tested, and attach detailed supporting data as necessary. If no tests were conducted, state "None". 1J-156L2 Top West Sak D 5683' 3419' Base West Sak D 12556' 3330' N/A 30. LIST OF ATTACHMENTS Summary of Daily Operations, Directional Survey 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Mike Greener @ 263-4820 Printed Name Ran Thom s Title: Greater Kuoaruk Area Drilling Team Leader ~ (3t /6 = Signature one ~~, ~ ~.~ Sp Date INSTRUCTIONS Prepared by Sharon Allsup-Drake General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1a: Classification of Service wells: Gas injection, water injection, Water-Alternating-Gas Injection, salt water disposal, water supply for injection, observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 4b: TPI (Top of Producing Interval). Item 8: the Kelly Bushing elevation in feet abour mean low low water. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). Item 20: True vertical thickness. Item 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, Other (explain). Item 27: If no cores taken, indicate "none". Item 29: List all test information. If none, state "None". Form 10-407 Revised 12/2003 ~onoctPhiiiips Time Log Summary We th iev,+ tYeb Reporting Time LocJs ~ Date From To Dur 5. Depth E D~th Phase Lode 5~~hcode T COM 06/29/2006 00:00 08:00 8.00 0 _ 0 _ MIRU MOVE DMOB P Move rig off of 1J-170 and spot up rig and all modules over 1J-156. No problems and no incidents. Rig Acce ted 08:00 hrs. 08:00 10:00 2.00 0 0 MIRU MOVE RURD P N/U Diverter, Load pipe shed w/drill pipe and strap same, weld toe board in derrick. Rig on Hi-Line power @ 09:00 hrs. 10:00 12:00 2.00 0 0 MIRU MOVE RURD P C/O saver sub, grabbers and bell guide to 4-1/2"IF 12:00 13:15 1.25 0 0 MIRU MOVE RURD P Space out grabbers & safety wire top drive, clear rig floor, R/U floor and pipe shed to P/U 5" DP. 13:15 14:15 1.00 0 0 MIRU WELC7 BOPE P Perform Diverter test w/ State Man, Co. Rep, & Motorman. Diverter test witnessed by AOGCC rep Lou Grimaldi. Bag Close @ 47 sec. Knife valve close @ 7 sec. Accumulator psi before shut in = 3000psi, after = 1900 psi. 200 psi recovery = 44 sec. Overall recovery = 3min 8 sec. 5 btl avg = 2300 psi. Diverter Length 148' ' fom center ofwell. Gasalarms calibrated and tested. 14:15 17:30 3.25 0 0 MIRU DRILL PULD P P/U 30 stands 5" DP, 6 stands 5" HWDP w/Jars, 1 stand 8" non-mag, some-o s mix s ud mud 17:30 18:30 1.00 0 0 MIRU DRILL PULD P M/U and stand back 1 stand Non-mag DC 18:30 21:30 3.00 0 0 MIRU DRILL PULD P P/U motor, re-orient sleeve on motor, M/U stabilizer & float sub 21:30 22:00 0.50 0 0 MIRU DRILL PULD P M/U bit, flood conductor and check for leaks. 22:00 22:15 0.25 0 0 MIRU DRILL PULD P Continue M/U BHA 22:15 22:30 0.25 0 108 SURFA DRILL DRLG P Wash and drill ice from 90' to 108' 22:30 00:00 1.50 108 150 SURFA DRILL DRLG P Spud Well -Drilling from 108' to 150'. ART = 1.2 hrs 06/30/2006 00:00 00:30 0.50 150 224 SURFA DRILL DDRL P Cont. Drilling from 150' to 224'. AART =.5 00:30 01:00 0.50 224 224 SURFA DRILL TRIP P POOH to C/O BHA 01:00 01:15 0.25 224 224 SURFA DRILL PULD P M/U BHA, MWD, UBHO 01:15 01:30 0.25 224 224 SURFA DRILL PULD P Orient MWD to Motor 01:30 02:00 0.50 224 224 SURFA DRILL PULD P R/U Gyro 02:00 02:30 0.50 224 224 SURFA DRILL TRIP P RIH to 133' and Tag hard fill, UD 1 jt NMFDC & P/U stand of HWDP a ~ ~ Wage `I cif 22 - -- ---- ~'Time L~s__ -- Date From To Dur 5. e th E. De th Phase Code Subcode T QOM 06/30/2006 02:30 03:00 0.50 224 224 SURFA DRILL REAM. P Wash & Ream from 133' to 224' 03:00 03:15 0.25 224. 224. SURFA DRILL TRIP P P/U 1 jt NMFDC & RIH to 224' 03:15 12:00 8.75 224 718 SURFA DRILL DDRL P Drilling from 224' to 718' MD (700' TVD). AST = 3.12, ART = 2.69, ADT = 5.81. Gyro @ 253' 20 min. Gyro @ 346' 20 min. Gyro @ 440' 20 min. Gyro @ 622' 20 min. PU = 74k, SO = 70k, Rot Wt = 70k, TQ on btm = 1-2k, TQ off btm = 1-2k, Jar Hrs = 63.17 12:00 00:00 12.00 718 1,870 SURFA DRILL DDRL P Drilling from 718' MD (700' TVD) to 1870' MD (1693' TVD), 130 spm, 530 gpm, 1475 psi on btm, 1250 psi off btm, 20-30k WOB, 85 rpm, PU = 92k, SO = 80k, TO on btm = 5k, TQ off btm = 1 k, ADT = 8.45 hrs, ART = 6.22 hrs, AST = 5.01 hrs, Max Gas = 67 units, Jar hrs = 71.62, Bit hrs = 14.26 07/01/2006 00:00 00:15 0.25 1,870 1,870 SURFA DRILL SFTY P PJSM -Hazards of drilling and connections -Getting tools in and out from beaver slide 00:15 08:45 8.50 1,870 2,780 SURFA DRILL DDRL P Con't Drlg f/ 1870' to 2780' MD / 2173' TVD - TD surface csg point - Up wt 110k, Dn wt 75k, Rot wt 87k, Torq on and off bttm 7k. ADT 6.01 (2.81 Rot, 3.20 slide Jars = TT 77.63 08:45 09:00 0.25 2,780 2,780 SURFA DRILL CIRC P Circu 10 min to clear assy -Flow ck well -Static 09:00 12:00 3.00 2,780 1,095 SURFA DRILL TRIP P BROOH f/ 2780' MD to 1095' MD - PR 600 gpm, RPMs 85 ***Note*** Had hidrates gas 1984. units @ 2070' MD/ 1816' TVD and 2113 units @ 2358' MD/ 1961' TVD- 12:00 15:15 3.25 1,095 0 SURFA DRILL TRIP P Con't BROOH 1095' MD ghost reamer ( Top HWDP) - LD Ghost reamer - POOH to monels. - LD BHA #1 15:15 15:45 0.50 0 0 SURFA DRILL PULD P Clear all tools from rig floor -Clean rota area 15:45 17:00 1.25 0 0 SURFA DRILL RURD P RU to run 10 3/4" Csg. 17:00 17:30 0.50 0 0 SURFA DRILL SFTY P PJSM -Discuss know hazards - Review runnin detail 17:30 22:45 5.25 0 2,776 SURFA CASIN( RNCS P Run Surface Csg -Run 67 jts + 2 pup joints 10 3/4" 45.5# L80 BTC csg - Shoe @ 2776' MD/2171' TVD ***NOTE*** Had 1 small tight spot around the base of perma-frost (Jt #44 1848' MD) Took a little wt 25k - No roblem 22:45 00:00 1.25 2,776 2,776 SURFA CASINC CIRC P Circu and Condition w/ Franks Tool - PR 7 bpm, PP 550psi , Up wt 150k, Dn wt 78k 07/02/2006 00:00 00:15 0.25 2,776 2,776 SURFA CASIN( SFTY P PJSM on rigging down Franks tool & R/U cement head Psge2 ~f 2~ Time Logs _ __ ___ ___ _ __ --- -- - - _ i Date From Tn I~~ir enth F flenth Phase (note 4uhcnrle T ,CAM 07/02/2006 00:15 00:30 0.25 2,776 2,776 SURFA CASIN ( RURD P Rig down Franks tool & rig up cement head 00:30 02:00 1.50 2,776 2,776 SURFA CEME~ CIRC P Cont. circ & cond mud for cement 70 s m, 350 si 02:00 02:15 0.25 2,776 2,776 SURFA CEMEI~ SFTY P PJSM on cementing 02:15 05:30 3.25 2,776 2,776 SURFA CEMEf~ DISP P Cement surface casing, 5 bbls, H2O test lines 3000 psi, 50 bbls. CW100, 50 bbls, Mud push, drop bottom plug, pump lead 410 bbls, 10.7 ppg, pump tail 80 bbls, 12 ppg, drop top plug, 20 bbls wash tub & lines, dosplace with ri 2350 strokes CIP 05:15 05:30 07:30 2.00 2,776 2,776 SURFA CASINC RURD P Flush riser, take turn buckles off, take off diverter pipe, P/U on diverter stack to set emer enc sli s 07:30 08:30 1.00 2,776 2,776 SURFA CASIN( RURD P Set Slips (w/ 65k overpull) 08:30 09:00 0.50 2,776 2,776 SURFA CASIN( OTHR P Drain & cut off casing 09:00 12:00 3.00 2,776 2,776 SURFA CASIN( RURD P R/D diverter stack & clean cement out of same, ull out of cellar 12:00 13:00 1.00 2,776 2,776 SURFA CASIN( NUND P UD long bails, R/U 4" handling tools, sime-ops: weld on starting head flange, repair drag chain in pits, clean R/W, P/U mousehole 13:00 14:45 1.75 2,776 2,776 SURFA CASIN( RURD P Recharge accum bottles on top drive, UD 7 stds 5" DP in mousehole, some-ops -pull diverter sys out under roduction lines. Retrieve 3 test 'oints. 14:45 1.5:15 0.50 2,776 2,776 SURFA CASIN( OTHR P R/U 4" handling tools, PJSM & hazzard assessment on C/O saver sub. 15:15 16:45 1.50 2,776 2,776 SURFA CASIN( RURD P C/O 4-1/2" IF saver suv to 4" XT-39, sime-ops P/U starting head, collect tools, re are fro ni lin u in cellar 16:45 22:00 5.25 2,776 2,776. SURFA CASIN( OTHR P P/U 144 jts 4" XT-39 DP in mousehole, rack back in derrick 22:00 00:00 2.00 2,776 2,776 SURFA CASINC RURD P M/U 4" & 5"floor valves, M/U 1 std 6-3/4" non mag & rack back in derrick, UD mousehole, grease choke manifold, get test plug & wear ring uller from Vetco Gre 07/03/2006 00:00 00:15 0.25 0 0 SURFA CASIN( NUND P PJSM -discuss and review NU Well Head and BOPs 00:15 00:30 0.25 0 0 SURFA CASINC DHEQ P Test weld on adaptor well head. 1900 si 10 min "OK" 00:30 01:00 0.50 0 0 SURFA WELC7 NUND P NU Well Head on adapter 01:00 03:00 2.00 0 0 SURFA WELCT NUND P NU BOPS 03:00 09:00 6.00 0 0 SURFA WELCT BOPE P Test BOPS and Choke manifold - 250 psi low and 3000 psi high - No failures - All test charted and held 5 min. AOGCC rep John H. Crisp waived witness test. Page ~ of 22 ~ Time Logs ate From To Dur S. e th E_ De th Phase Code Subcode T SUM ~ 07/03/2006 09:00 09:15 0.25 0 0 SURFA DRILL SFTY P PJSM -Discuss and review PU BHA 09:15 10:15 1.00 0 80 SURFA DRILL PULD P PU BHA #2 - Motor, MU bit, Flt sub, Stab, HOC, MWD, TM 10:15 10:45 0.50 80 80 SURFA DRILL SRVY P Up Load MWD 10:45 11:30 0.75 80 452 SURFA DRILL PULD P Con't PU BHA #2 -TIH w/ NMDCs, 8 'ts HWDP + Jars, XO 11:30 12:00 0.50 452 452 SURFA DRILL SRVY P Pulse Test MWD "OK" 12:00 12:15 0.25 452 460. SURFA DRILL PULD P PU Ghost reamer 12:15 13:00 0.75 460 2,597 SURFA DRILL TRIP P TIH to 2597' -Circu air from system 13:00 14:00 1.00 2,597 2,597 SURFA CASIN( DHEQ P RU and Test csg to 3000 psi on chart for 30 min -Good test - No bleedoff 14:00 15:30 1.50 2,780 2,805 SURFA CEMEf~ DRLG P Drlg out Flt collar, shoe track, Flt shoe 2769' MD w/ 9 7/8" bit, FR 450 gpm, PP 1100 psi, RPMs 60-65, Torq 5-8k, lus 25' of new hale to 2805' MD 15:30 17:00 1.50 2,805 2,805 SURFA DRILL CIRC P Circu re-conditioned mud around - Circu until mud is uniform in and out. 17:00 17:30 0.50 2,769 2,769 SURFA DRILL . LOT P Pull to shoe - RU and Preform LOT - MW 9.0 ppg, 2169' TVD, 382 psi at surface = 12.4 EMW 17:30 18:00 0.50 2,805 2,867 INTRM1 DRILL DDRL P Drlg 9 7/8 " hole w/ Motor f/ 2805' MD to 2867' MD / 2214' TVD - PR 550 m, PP 1250 si, WOB 8-10k, 18:00 19:00 1.00 2,867 2,867 INTRM1 DRILL SRVY T Trouble Shoot MWD - No Signal 19:00 19:30 0.50 2,867 2,867 INTRM1 DRILL CIRC T Circu BU -Max gas units 616 units 19:30 19:45 0.25 2,867 2,867 INTRM1 DRILL OWFF T Obsevre Well -Static 19:45 21:45 2.00 2,867 150 INTRM1 DRILL TRIP T POOH on elevators f/ 2867' 21:45 22:15 0.50 150 110 INTRM1 DRILL SRVY T Down Load MWD 22:15 22:45 0.50 110 60 INTRM1 DRILL PULD T LD MWD, TM collar & HOC 22:45 23:15 0.50 60 150 INTRM1 DRILL PULD T PU New MWD tool, TM collar & HOC 23:15 00:00 0.75 150 150 INTRM1 DRILL SRVY T Up Load MWD 07/04/2006 00:00 00:15 0.25 150 150 INTRM1 DRILL SFTY T PJSM on TIH 00:15 00:30 0.25 150 452 INTRM1 DRILL DHEQ T TIH T/ 452' MD & Shallow test MWD OK 00:30 01:30 1.00 452 2,768 INTRM1 DRILL TRIP T TIH T/ 2768' MD 01:30 02:00 0.50 2,768 2,768 INTRM1 DRILL CIRC T Circ Bottoms up, Gas cut 504 units, circ 500 al/min & 1100 si 02:00 02:15 0.25 2,768 2,865 I NTRM1 DRILL TRIP T TIH F/ 2768'. MD T/ 2865' MD, Survey on bottom 02:15 03:45 1.50 2,867 3,055 I NTRM1 DRILL DDRL P Drilling F/ 2867' MD to/ 3055' MD ~~e~of22 Time Logs Date Fro~~~ To Dur S epth E. De th Phase Code Subcode T 01~~ -- 07/04l2006 03:45 - 04:15 - _ 0.50 -- 3,055 3,055 INTRM1 DRILL SRVY T - MWD Detection problems 04:15 12:00 7.75 3,055 3,940 INTRM1 DRILL DDRL P Drilling F/ 3055' MDT/ 3940' MD (2759' TVD), ADT = 5.52, AST = 2.68, ART = 2.84, PU = 112k, SO = 70k, ROT = 85k, TQ = 7k On abtm & 6k off btm, ECD = 9.65, Max Gas = 53 units dlg, 504 units on TIH, Jar hrs = 80.24, PR @ 3800' MD, 2691' TVD, MW = 9.0 ppg, MP #1 @ 30 spm = 250 psi, @ 40 spm = 320 psi, MP#2 @ 30 spm = 250 si, 40 s m = 320 si 12:00 00:00 12.00 3,940 5,088 INTRM1 DRILL DDRL P Held PJSM & Hazard assesment on drilling ahead & making connections, Drilling F / 3940' MD (2759' TVD) to 5088' MD (3266' TVD), 550 gpm, 1700 psi, 131 spm, 90 RPM, 10-20k WOB, ADT = 13.16, ART = 3.75, AST = 3.89, PU = 110k, SO = 78k, ROT = 92k, TQ = 5k on btm & 4.5k off btm, ECD = 9.91, Max GAs = 86 units, Jar hrs = 87.88, SPRs @ 5018' MD, 3238' TVD, MW=9.0, MP#1 @30 spm=320 psi, @ 40 spm = 410 psi, MP #2 @ 30 spm = 320 psi, @ 40 spm = 400 si 07/05/2006 00:00 00:15 0.25 5,088 5,088 INTRM1 DRILL SFTY P PJSM on drilling ahead & making connections 00:15 12:00 .11.75 5,088 5,850 INTRM1 DRILL DDRL P Drlg from 5088' MD to 5850' MD (3452' TVD). ADT = 8.61, AST = 2.09, ART = 6.52, PU = 110k, SO = 75k, ROT = 90k, TW = 6k on btm & 5-8k off btm, ECD = 9.65, Max Gas = 67 units, Jar hrs = 96.49. S P R@ 5802' M D (3443' TVD) w/ MW = 9.1 ppg: #1 MP @ 30 spm = 320 psi, @ 40 spm = 410 psi; #2 MP @ 30 spm = 320 psi, @ 40 s m=410 si 12:00 12:15 0.25 5,850 5,850 INTRM1 DRILL SFTY P PJSM on drilling ahead, scrubbing windwalls, & hazard assesment 12:15 00:00 11.75 5,850 6,699 INTRM1 DRILL DDRL P Dlg from 5850' MD (3452' TVD) to 6699' MD (3588' TVD). ADT = 7.24, ART = 4.94, AST = 2.3, PU = 115k, SO = 72k, ROT = 90k, TQ = 5-6k on btm & 6k off btm, ECD = 10.09, Max Gas = 198 units, Jar hrs = 103.73. SPRs @ 6699' MD (3588' TVD) w/ MW = g.2+: MP #1 @ 30 spm = 370 psi & @ 40 spm = 450 psi; MP #2 @ 30 s m = 370 si & 40 s m = 450 si 07!06/2006 00:00 00:15 0.25 6,699_ 6,699 INTRM1 DRILL CIRC P PJSM -Discuss drilling hazards & BROOH :>sg~ ~ of ~2 Time Lois ~ Date From To Dur ~zpth E. Depth Phase Code Subcode T ~OM 07/06/2006 00:15 02:45 2.50 6,699 6,968 INTRMI DRILL DDRL P Directional Drig w/ Motor 6699' to 6968' MD / 3625' TVD. Up wt 120k, Dn wt 70k, Rot wt 85k On bttm torq 6-7k, PR 550 gpm, PP 2000 psi, Total ADT 2.31 hrs, (ART 1.44, AST .87), Total hrs on jars = 105.5. ***Note'`* Jars came out of hole half cocked. These will be sent in to weartherford to be ins ected. 02:45 03:45 1.00 6,968 6,968 INTRM1 DRILL CIRC P Pump &Circu Wt/ HiVis ,Noted 10% increase in cutting when back to surface, PR 550 gpm, PP 2000 psi, RPMs 90. Hole appears to be in good sha a and clear of cuttin beds. 03:45 09:15 5.50 6,968 2,769 INTRM1 DRILL TRIP P Flow Ck well- Static - BROOH f/ 6968' to 2769'. PR 500 gpm, RPMs 90. All pulled well - No signs of pack off or cuftin roblems. 09:15 10:30 1.25 2,769 2,769 INTRM1 DRILL PULD P Std back last 2 stds 4" DP - UD all 5" DP 36 'ts .2769' to 1569' 10:30 12:00 1.50 2,769 2,769 INTRM1 DRILL CIRC P Circu & Pump Sweep at shoe until clean, PR 550 gpm, PP1300 psi, RPMs 50 12:00 13:15 1.25 2,769 311 INTRM1 DRILL SFTY P PJSM -Discuss hazards LD DP POOH & LD BHA 13:15 13:45 0.50 311 94 INTRM1 DRILL PULD P UD HWDP & Collars 13:45 14:30 0.75 94 94 INTRM1 DRILL SRVY P Dn Load MWD 14:30 15:00 0.50 94 0 INTRM1 DRILL PULD P UD MWD, Mud Motor & Bit 15:00 15:30 0.50 0 0 INTRM1 CASIN( RURD P Pull Wear Bushing 15:30 16:00 0.50 0 0 INTRM1 CASIN( RURD P Clean and clear rig floor -Lay all tools do beaver slide 16:00 17:30 1.50 0 0 INTRM1 CASIN( RURD P PJSM running csg - RU 7 5/8" csg tools -Slips, elevators, long bails, ower ton s, Franks tool 17:30 17:45 0.25 0 0 INTRM1 CASIN( SFTY P PJSM hazards rolling csg -Safety meetin with roustabouts in i e shed 17:45 18:15 0.50 0 0 INTRM1 CASIN( RUNL P PU pups and tools from beaver slid 18:15 18:30 0.25 0 0 INTRM1 CASIN( SFTY P PJSM with floor crew on hazards while runnin cs 18:30 19:00 0.50 0 168 INTRM1 CASIN( RNCS P Run Jts 1 thru 4 -Check floats - "OK" 19:00 21:45 2.75 168 2,758 INTRM1 CASIN( RNCS P Con't running csg f/ 168' to 2758' MD - No roblems noted. 21:45 22:15 0.50 2,758 2,758 INTRMI CASIN( CIRC P Circu csg volume @ surface shoe - 1253 stks 22:15 00:00 1.75 2,758 3,680 INTRM1 CASIN( RNCS P Con't running csg f/ 2758' MD to 3680' - Hole appears in good shape - No ti ht hole noted. 07/07/2006 00:00 00:15 0.25 3,680 3,680 I NTRM1 CASINC SFTY P PJSM -Crew change -review hazards runnin cs ~~ ~ P~~e 6 ~f 2~ Time Logs _ __ -- ------ Date From T~ f~iir S , .nth F rlenth Phase ~nrie SiihrnriP T ,:C1M 07/07/2006 00:15 02:15 2.00 3,680 6,962 INTRMI CAS1N ( RNCS P Con't running 7 5/8" 29.7# L80 BCTM csg f/ 3689' to 6962' TD Shoe (162 jts cut off #163) No problems running cs - No ti ht hole 02:15 03:15 1.00 6,962 6,962 INTRM1 CEME~ CIRC P Circu BU + w/ Franks Tool (2779 stks total) - PR 7 bpm, PP 670 psi. Recip cs 20' 03:15 03:45 0.50 6,962 6,962 INTRM1 CEME-~ RURD P R/D Franks Tool - Blow do TD - R/U CMT head 03:45 05:45 2.00 6,962 6,962 INTRM1 CEME~ CIRC P Con't to Circu and condition mud for CMT.- PR 7 bpm, PP 450 psi -Start properties MW 9.6 ppg, FV 56, PV 9, YP 27, 10 min gels 18 and the After cond = MW 9.1+, FV 42, PV 10, YP 10, 10 min els 6 05:45 07:45 2.00 6,962 6,962 INTRM1 CEMEt~ DISP P Cement 7 5/8" Csg, Pump 10 bbl CW100, Test lines to 3500 psi, pump 65 bbls, pump 75 bbls MudPush @ 12ppg, Drop bttm plug, pump 163 bbls tail cmt @ 12.5ppg, drop top plug, DS kick out w/ 2 bbls water. Rig displace with MOBM, 3127 stks, Bump Plug w/ 500 psi over to 1350 psi. Ck floats after 4 min "Held" - CIP 0730 hrs 07:45 08:00 0.25 6,962 6,962 INTRM1 CASIN( SFTY P PJSM -Review Slip setting procedures - Review known hazards. 08:00 09:00 1.00 6,962 6,962 INTRM1 CASIN( RURD P P/U BOPs -RD CMT head -Clear tools from ri floor 09:00 10:30 1.50 6,962 6,962 INTRM1 CASIN( NUND T Vetco/Gray set slips (planned). Had trouble with the firsf set of slips would not hold. Had to use and set second set of sli s. 10:30 12:00 1.50 6,962 6,962 INTRM1 CASIN( NUND P Cut Casing w/ Pneumatic Cutter 12:00 12:15 0.25 6,962 6,962 INTRMI CASIN< SFTY P PJSM - instgll packoff/Nipple up BOP inch oints 12:15 12:45 0.50 6,962 6,962 INTRM1 CASIN( RURD P Install pack off /Rig down casing tools and chan a bales 12:45 13:45 1.00 6,962 6,962 INTRM1 CASIN( NUND P Nipple up BOP, test pack off @ 3800 si 10 min . Install wear rin . 13:45 15:00 1.25 6,962 6,962 INTRM1 CASIN( OTHR P 7-5/8" x 10-3/4" annulus infectivity test w/ 9.0 ppg WBM (11.8 ppg EM W). Pump 120 BBL fresh water flush @ 3 BPM IP 600 psi & FP 730 psi. Stop pump & stabilize @ 400 psi & shut in. Freeze Protected Annulus w/ 83 BBLs Diesel @ 2.5 BPM IP 400 psi & FP 700 si. 15:00 15:15 0.25 6,962 6,962 INTRM1 CASIN( SFTY P PJSM -cut & slip drill line (Hazard Reco nition 15:15 16:15 1.00 6,962 6,962 I NTRM1 RIGMN SVRG P Cut & Slip drill line 72', inspect brakes, check C-O-M, Lube Top Drive & Blocks 16:15 21:15 5.00 6,962 6,962 I NTRM1 DRILL TRIP P PU, drift, and RIH w/45jts Hybrid DC, 21 jts HWDP, & 99 jts 4" DP w/ Su er-Sliders ~. ~ac~e 7 of 2~ -- - Time Logs _ - Date From To Dur 5. nth E. De th - Phase Code Subcode T QOM 07/07/2006 21:15 23:30 2.25 6,962 6,962 INTRM1 DRILL TRIP P POOH standing back drill string 23:30 00:00 0.50 6,962 6,962 INTRM1 DRILL RURD P Clean Rig Floor 07/08/2006 00:00 00:15 0.25 0 0 INTRM1 DRILL SFTY P PJSM on PU & MU BHA & 102 jts DP 00:15 01:15 1.00 0 96 INTRM1 DRILL PULD P PU & MU BHA #4, Motor, Float Sub, Stav, DM, SlimPhase 4, PWD, TM collar 96` MD 01:15 03:30 2.25 96 96 INTRM1 DRILL SRVY P Plug in & up-load MWD (Trouble w/ si nal 03:30 04:00 0.50 96 371 INTRM1 DRILL PULD P PU & MU 3jts non mag DCs, 1 jt HWDP, Jars, 4 'ts HWDP 04:00 08:00 4.00 371 6,716 INTRM1 DRILL TRIP P TIH from 371' to 6716' MD by PU 102 jsts of 4" DP from pipe shed and 68 stds from derrick 08:00 08:30 0.50 6,716 6,875 INTRM1 DRILL REAM P Wash down from 6716' MD to 6875' MD. Tagged up @ 6875' MD w/ 10k- On de th for float collar 08:30 09:30 1.00 6,875 6,875 INTRM1 CASIN( DHEQ P Circu air from system -Preform casing Test 3000 si & chart for 30 min 09:30 11:15 1.75 6,968 6,993 INTRMI DRILL DRLG P Drill float equipment & 25' of new hole to 6993' MD. PU = 103k, SO = 70k, Rot = 80k, TQ = 5k, ADT = .07, AST _ .07 11:15 12:00 0.75 6,993 6,993 INTRM1 DRILL CIRC P Circ. BU and until mud is uniform in and out for LOT 12:00 12:15 0.25 6,993 6,993 INTRM1 DRILL SFTY P PJSM -Leak off test (Pressure Hazards 12:15 13:00 0.75 6,993 6,993 INTRM1 DRILL FIT P Leak off test w/ 8.8 ppg, TVD 3628', OBM @ 15.9 ppg EMW. Blow down lines 13:00 00:00 11.00 6,993 7,660 PROD1 DRILL DDRL P Drill ahead from 6993' to 7660' MD (3658' TVD). AST = 1.02 hrs, ART = 6.82 hrs, ADT = 7.84 hrs, Jars (#14001358) = 7.91 hrs, PU = 135k, S0 = 74k, ROT = 93k, TQ = 5k (on & off btm), ECDs = 10.13, Max Gas = 70 units, Kill rates w/ 8.7 ppg MW @ 7620' MD (3657' TVD): #1 Pump @ 30 spm = 700. psi, @ 40 spm = 910 psi; #2 Pump @ 30 spm = 650 psi, @ 40 spm = 880 psi. SLIDE Ftg (7107-7140' @ 150R), (7337-7348' @ 20R), (7348-7382' @ 34R), 7439-7479' @ 10 R). Concretion MDs (7035-7042'), (7190-7192'), (7274-727T), 7482-7606' ... Total = 136' 07/09/2006 00:00 00:15 0.25 7,660 7,660 PROD1 DRILL SFTY P PJSM - On drlg ahead -Discuss pinch oints r - -- rage 3' cif 2~ ~_Time Logs Date From To Dur e th E Depth Phase Code Subcode T ~~M 07/09/2006 00:15 12:00 11.75 7,660 8,170 PROD1 DRILL DDRL P Drlg w/ Motor f17660' MD to 8170' MD ADT 9.09 hrs, Up wt 135k, Dn wt 80k, Rot wt 105k, Torq On Bttm 6k -Off bttm 6k, ECDs 10.15, Max gas = 107 units, Jar hrs = 17 hrs. PR 298 gpm, PP 3300 psi, RPMs 80, WOB 10-15k. Concretions @ 7673' - 7706', 7730' - 7740', 7801' - 7812' , 7895' - 7940' Total 99' 12:00 12:15 0.25 8,170 8,170 PROD1 DRILL SFTY P PJSM - Drlg Ahead - BROOH hazards 12:15 14:00 1.75 8,170 8,281 PROD1 DRILL DDRL P Drlg w/ Motor f/ 8170' to 8281' MD / 3631' TVD, ADT 1.89 hrs, PR 300 m, PP 3200, RPMs 80, WOB 8-12k, 14:00 15:00 1.00 8,281 8,281 PROD1 DRILL CIRC P Get SPR -Pump up last Survey - CBU, Recip drill string fuA 90', PR 300 m. RPMs 80 15:00 16:30 1.50 8,281 6,898 PROD1 DRILL TRIP P POOH on elevators to 6898' MD small tight spots at 7435' & 7350') both wiped clean. These were noted to be set and slide area's. 16:30 17:15 0.75 6,898 6,898 PROD1 DRILL CIRC P Pump 30 sweep @ csg shoe. Pump, rotate and recip 90' stroke. PR 300 gpm, 70 RPMs -Sweep showed minimal increase in cutting -Hole a ears clean and in ood sha e. 17:15 18:15 1.00 6,898 8,281 PROD1 DRILL TRIP P RIH to 8258' MD -Precautionary wash to bttm 8281' MD / 3631' TVD. No tight hole noted - No fill 18:15 19:30 1.25 8,281 8,281 PROD1 DRILL CIRC P Pump 30 bbl Wt/Hi Vis sweep - Circu and condition, PR 300 gpm, 80 RPMs - Flow Ck well 19:30 20:15 0.75 8,281 8,281 PROD1 DRILL CIRC P CO well bore fluid to 8.7ppg SFOBM - Pump 123 bbls SFOBM -Displace w/ 62 bbls OBM including dry job -Drop 1.75" drift. 20:15 23:00 2.75 8,281 160 PROD1 DRILL TRIP P POOH on elevators - No tight hole - recoverdrift -Std bk HWDP w/jars - LD MWD tools. 23:00 00:00 1..00 160 0 PROD1 DRILL SRVY P Down Load MWD 07/10/2006 00:00 00:15 0.25 90 90 PROD1 DRILL SRVY P Con't Down load MWD 00:15 00:30 0.25 90 90 PROD1 DRILL SFTY P PJSM- Discuss UD BHA and known hazards 00:30 01:00 0.50 0 0 PROD1 DRILL RURD P UD BHA - TM collar, PWD, Slimephase 4, DM HOC, Stab, NM Flt Sub, Motor, Bit 01:00 01:30 0.50 0 0 COMPZ DRILL RURD P Clear & Clean Rig Floor 01:30 01:45 0.25 0 0 COMPZ CASIN( SFTY P PJSM - on Rigging up & running 4.5" slotted liner 01:45 03:30 1.75 0 2,040 COMPZ CASIN( RUNL P PU & MU48 jts of 4.5" slotted liner 03:30 04:00 0.50 2,040 2,040 COMPZ CASINC PUTS P PU & MU seal bore ext., liner hanger, C2 ZXP liner to acker Ir'a~2 9 cif ~2 Time Logs Date From To Dur 5 e th E De th Phase Code Subcode T .;OM 07/10/2006 04:00 07:30 3.50 2,040 8,282 COMPZ CASIN ( RUNL P Cont. RIH with 4.5" liner on DP to 8282' MD. Tagged up w/ 20k down wei ht 07:30 08:15 0.75 8,282 8,275 COMPZ CASIN( DHEQ P PU to 8275' MD, PU = 148k, SO = 85k, Drop ball and pump down @ 3 BPM & 500 psi. Pressure up to 2500 psi to set hanger, 4000 psi to set packer, back out of setting tool with 15 turns to the right, PU = 134k, SO = 90k 08:15 09:30 1.25 8,275 3,561 COMPZ DRILL TRIP P Flow check well (static), POOH from 6150' to 3561' MD 09:30 10:30 1.00 3,561 3,561 COMPZ RIGMN RGRP T Hydraulic power unit line Leak ... Fix same 10:30 12:00 1.50 3,561 0 COMPZ DRILL TRIP P Continue POOH from 3561' to surface 12:00 12:15 0.25 0 0 COMPZ DRILL SFTY P PJSM on UD running tools (proper ri in of overhead loads 12:15 13:00 0.75 0 0 COMPZ DRILL RURD P Brreak & UD running tools, clean rig floor monitor well on tri tank 13:00 13:30 0.50 0 0 COMPZ RIGMN SVRG P Service rig, top drive, drawworks couplings, override clutch & drum s ear 13:30 14:15 0.75 0 0 COMPZ EVALV~ RURD P Spot SWS logging unit & off load tools 14:15 14:30 0.25 0 0 COMPZ EVALVI~ SFTY P PJSM on PU & RU wireline tools & USIT to in Pinch Points 14:30 16:00 1.50 0 0 COMPZ EVAL~/1~ RURD P RU wireline & PU USIT tools 16:00 17:30 1.50 0 0 COMPZ EVALVI~ DHEQ. P Calibrate & Check equipment 17:30 20:15 2.75 0 6,150 COMPZ EVAL1/~ ELOG P RIH w/ USIT tools (begin to tractor down @ 18" 30 hrs from 5130' MD to 6150' MD Schlumber er Tractor. 20:15 22:30 2.25 6,150 4,000 COMPZ EVALVI~ ELOG P Logging from 6150-4000' MD 22:30 23:00 0.50 4,000 0 COMPZ EVALV~ ELOG P POOH 23:00 00:00 1.00 0 0 COMPZ EVALVI~ RURD P Rig down wireline & lay down USIT tools. Well monitored -Static. 07/11/2006 00:00 00:15 0.25 0 0 COMPZ EVAL1/1~ RURD P Continue LD Cement/Corrosion to in tools. 00:15 00:30 0.25 0 0 PROD2 DRILL SFTY P PJSM for PU/MU whipstock assembly. 00:30. 02:15 1.75 0 107 PROD2 STK WPST P PU/MU anchor, whipstock /mill, seals, stop sub, unloader, 3-1/2" HWDP, pups, blank sub, trip anchor, safety disconnect, drain sub, debris catcher, lower water mellon mill, flex joint, string mill, 3-1/2" HWDP, float sub, MWD. 02:15 03:00 0.75 107 107 PROD2 DRILL SRVY P . Upload MWD. 03:00 03:30 0.50 107 479 PROD2 STK WPST P Continue PU Bumper sub, XO and 3 stds of 4" x 4-3/4" h brid ush i e. ~'~3e ~u ~~ ~2 - - -- -- -- -- - - Time Logs _ ___ __ - _ Date From To _ Dur e~th E_ De th 5 Subcode T__ Phase Code OP~I _ _,__ 07/11/2006 03:30 _ 03:45 ___ 0.25 _ 479 479 PROD2 _ DRILL DHEQ P Shallow test MWD at 285 GPM and 1,075 si - oka . 03:45 06:00 2.25 479 5,220 PROD2 STK WPST P RIH from 479' - 5,220'. 06:00 06:45 0.75 5,220 5,270 PROD2 STK WPST P Make correlation MAD pass of K-13 from 5,250-70' tmd, at 295 gal and 2,060 si. 06:45 07:30 0.75 5,270 6,148 PROD2 STK WPST P Continue TIH from 5,270 - 6,148'. 07:30 07:45 0.25 6,148 6,072 PROD2 STK WPST P Orient whipstock to 14 deg left, PU = 130K, SO = 90K. Set whipstock. Top of whi stock at 6,072' tmd. 07:45 12:00 4.25 6,072 6,085 PROD2 STK WPST P Mill B-lateral window. Pump 30 bbl Hi-Vis sweep at 6,080'. TOW= 6,072' BOW= 6,085' 12:00 12:15 0.25 6,085 6,085 PROD2 DRILL SFTY P PJSM for milling. 12:15 13:00 0.75 6,085 6,111 PROD2 STK WPST P Drill new hole from 6,085-6,111'tmd, with 6-3/4" full guage hole to 6,095'. Pum 30 bbl Hi-Vis swee . 13:00 14:00 1.00 6,111 6,111 PROD2 DRILL CIRC P Circulate sweep out of hole at 300 GPM, 120 RPM, reciprocating pipe from 6,111 - 6,065' and working string mills throu h window. 14:00 15:45 1.75 6,111 479 PROD2 DRILL TRIP P POOH with milling assembly. 15:45 16:30 0.75 479 4,060 PROD2 DRILL PULD P LD Bumper sub and download MWD 16:30 17:00 0.50 4,060 0 PROD2 DRILL PULD P LD MWD and milling assembly. Upper mill in au e. 17:00 18:15 1.25 0 0 PROD2 DRILL OTHR P Pull WB, flush stack, set WB and clean ri floor. 18:15 19:00 0.75 0 91 PROD2 DRILL PULD P PU/MU drilling assembly with 6-3/4" Concretion bit, 5" motor, float sub and MWD. Orient MWD. 19:00 19:30 0.50 91 91 PROD2 DRILL SRVY P Upload MWD.. 19:30 20:15 0.75 91 1,762 PROD2 DRILL DHEQ P RIH 15 stds to 1,762', shallow test MWD: 260 GPM = 1,630 psi, 300 GPM= 2,100 si. 20:15 21:00 0.75 1,762 1,873 PROD2 DRILL DHEQ P PU AGI-tater, shock sub and RIH to std #16 at 1,873'. Shallow test AGI-tater and MWD: 260 GPM= 2,100 psi, 300 GPM= 2,650 psi. AGI-tater pressure increase = +/- 550 si. 21:00 22:00 1.00 1,873 5,980 PROD2 DRILL TRIP P Continue RIH to 5,980' filling DP at 5,048' and 5,980'. 22:00 22:15 0.25 5,980 5,980 PROD2 DRILL SFTY P PJSM for cut and slip DL. 22:15 23:15 1.00 5,980 5,980 PROD2 RIGMN SVRG P Cut and slip 48' of DL. Inspect brakes, check Saver sub, Tube blocks and Top Drive. ~dC~E °I ~ ~~ ~Z~ ~~ _._ Time Lo~_ _ -- - Date From_ To Dur 5. e th E. Depth Phase Code Subcode T ~;UM _ ~ 07/11/2006 23:15 00:00 0.75 5,980 6,095 PROD2 DRILL TRIP P Break circ orient to 10L and wash to 6,065' tmd. Slide to 6,085'. Slide and ream to 6,095'. PU=98K, SO= 70K. 07/12/2006 00:00 12:00 12.00 6,095 6,919 PROD2 DRILL DDRL P Directionally drill 6-3/4" B-lateral from 6,095' - 6,919' tmd (3,488') ADT= 6.87, ART= 5.15, AST= 1.72 PU= 104K, S0= 65K, ROT= 83K TO on/off = 5,000 / 4,000 ft-Ib ECD= 9.92 ppg Max Gas= 71 umits Concretions: 6,118-124', 6,154-161', 6,263-278', 6,309-332', 6,349-370', 6,372-379', 6,390-397' = 83' 12:00 00:00 12.00 6,919 8,010 PROD2 DRILL DDRL P Directionally drill 6-3/4" B-lateral from 6,919' - 8,010' tmd (3,487') ADT= 8.54, ART= 5.80, AST= 2.74 PIJ= 118K, S0= 58K, ROT= 83K TQ on/off = 5,000 / 4,500 ft-Ib ECD= 10.38 ppg Max Gas= 150 umits Concretions: 6,988-996', 7,389-39T, 7,492-511', 7,528-540', 7,586-601', 7,661-668', = 69' 07!13/2006 00:00 09:00 9.00 8,010 8,988 PROD2 DRILL DRLG P PJSM. Drill 8,010 - 8,988' and (3,448' tvd). ADT= 5.8, AST= 1.52, ART= 4.28 09:00 10:00 1.00 8,988 8,998 PROD2 DRILL CIRC P Pump 35 bbl weighted Hi-Vis sweep @ 302 GPM, 3,600 psi and 100 rpm. Had 25% increase in cutting returns. Evaluate eolo 10:00 12:00 2.00 8,998 9,115. PROD2 DRILL DRLG P Drill ahead from 8,988-9,115' and (3,445' tvd). ADT= 0.77, AST= 0.13, ART= 0.54 PU= 125K S0= 45K ROT= 82K ECD= 10.77 ppg Max Gas= 127 units 12:00 13:30 1.50 9,115 9,248 PROD2 DRILL DRLG P Drill ahead from 9,115-9,248' and (3,432' tvd). ADT= 1.19, AST= 0.25, ART= 0.94 PU= 125K S0= 45K ROT= 82K ECD= 10.77 ppg Max Gas= 127 units 13:30 14:30 1.00 9,248 8,788 PROD2 DRILL REAM T POOH to 8,860' with 50K over uII.BROOH 8,845-8,788'. 14:30 15:45 1.25 8,825 8,832 PROD2 DRILL DDRL T Sidetrack B-lateral, troughing and time drilling from 8,825-8,832'. KOP @8,825' and AST= 1.25 hr. 15:45 16:00 0.25 8,832 8,850 PROD2 DRILL DDRL T Drill sidetrack hole from 8,832-8,850' md. AST= 0.18 hr ~~ ~ t's~r~~ 12 ~f ~~ Time Logs Date From To Dur 5. ~e th E De th Phase Code Subcode_ T ;Orv1 _ _ _ 07/13/2006 16:00 16:30 0.50 8,850 8,850 PROD2 DRILL SRVY T Take check shot surveys. Orient toolface for slide drillin . 16:30 21:00 4.50 8,850 9,248 PROD2 DRILL DRLG T Drill ahead from 8,850' - 9,248' and , ADT= 4.43 21:00 00:00 3.00 9,248 9,371 PROD2 DRILL DRLG P Drill from 9,248-9,371' and (3,452' tvd) ADT= 0.70, AST= 0.22, ART= 0.48 07/14/2006 00:00 12:00 12.00 9,371 10,200 PROD2 DRILL DRLG P PJSM. Drill ahead B-lateral from 9,371-10,200' tmd (3,431' tvd} ADT= 8.0, AST= 2.69, ART= 5.31 hrs PU= 135K S0= 60K ROT= 94K TQ on/off = 6,500 / 6,500 ft-Ib ECD= 10.8 ppg Max Gas= 153 units Concretions: 9,372-378', 9,412-16', 9,492-501', 9,710-12', 9,778-8T, 9,792-9,800', 10,013-020' 12:00 00:00 12.00 10,200 11,261 PROD2 DRILL DRLG P PJSM. Drill ahead B-lateral from 10,200-11,261' tmd (3,431' tvd) ADT= 6.67, AST= 1.67, ART= 5.0 hrs PU= 135K S0= 60K ROT= 94K TQ on/off = 6,500 / 6,500 ft-Ib ECD= 10.8 ppg Max Gas= 153 units Concretions: 10,249-258', 10,365-366', 10,472-475', 10,546-550', 10,646-649' 07/15/2006 00:00 12:00 12.00 11,261 12,252 PROD2 DRILL DRLG P Drill ahead B-lateral 11,261' - 12,252' tmd (3,409) Pump 30 bbl Hi-Vis sweep at 11,550', with a 15% increase in cutting returns. ADT= 6.85, ART= 5.47, AST= 1.38 hrs, PU= 155K, S0= 47K, ROT= 100K, TQ on/off = 9,000 / 9,000 ft-Ib, Max Gas= 130 units, ECD= 11.16 ppg Concretions: 12,020-033', 12,049-055', 12,120-124', 12,142-150' 12:00 21:15 9.25 12,252 12,963 PROD2 DRILL DRLG P Drill ahead B-lateral 12,252' - 12,963' tmd (3,407) Pump 30 bbl Hi-Vis sweep at 12,930'. ADT= 5.67, ART= 4.09, AST= 1.58 hrs, PU= 15K, S0= 35K, ROT= 100K, TQ on/off = 10,000 / 10,000 ft-Ib, Max Gas= 70 units, ECD= 11.27 ppg, Concretions: 12,020-033', 12,049-055', 12,120-124', 12,142-150' 21:15 22:30 1.25 12,963 12,963 PROD2 DRILL CIRC P Circ sweep out while reciprocating pipe with 90 rpm and 278 gpm. Had a 5% increase in cutting returns. Monitor well -static. Surve at TD. 22:30 22:45 0.25 12,963 12,963 PROD2 DRILL SFTY P PJSM for BROOH. 22:45 00:00 1.25 12,963 12,277 PROD2 DRILL REAM P BROOH from 12,963' - 12,277' at 90 rpm, 45-50 ft/min, 278 gpm and 4,000 si. ~r~~e 13 of22 ~me Lois -- --- -- -- - -- -- ~ate From To Dur e th E De th Phase Code Subcode T '~M 07/16/2006 00:00 07:45 7.75 12,277 5,985 PROD2 DRILL REAM P BROOH from 12,277 - 6,085' md, at 90 rpm, 278 gpm, 40-45 ft/hr. Max overpull 10-12K. Pull thru window with pumps off, no problem. Hole unloading a "moderate" amount of sand while BROOH from 7,000' - 6,085'. 07:45 09:00 1.25 5,985 5,985 PROD2 DRILL CIRC P Pump 30 bbl weighted Hi-Vis sweep. Circ 3x btms up at 5,985' with 300 gpm, 3,000 psi, 40 rpm, TQ=4,000 ft-Ib. Had a 10% increase in cuttings returns when um in swee . 09:00 10:00 1.00 5,985 5,985 PROD2 RIGMN SVRG P Service TD and inspect saver sub. 10:00 11:00 1.00 5,985 6,825 PROD2 DRILL TRIP P RIH through window w/o problems. PU 105K, S0= 65K. 11:00 13:30 2.50 6,825 12,425 PROD2 DRILL TRIP P PJSM. RIH to 12,140', filling pipe at 8,788' and 11,560'. Ream from 12,140-184'. Continue RIH to 12,425 with slackoff weight decreasing from 45K-34K block wei ht . 13:30 14:30 1.00 12,425 12,963 PROD2 DRILL REAM P Ream from 12,425' to TD at 90 rpm, 271 gpm and 3,900 psi and 45-50 ft/min. Tag btm, set back stand and PU single to be able to reciprocate i e. 14:30 16:00 1.50 12,963 12,963 PROD2 DRILL CIRC P Pump 30 bbl Hi-Vis sweep. Circulate and reciprocate pipe with 90 rpm, 278 gpm and 4,000 psi (pressure limit). Sweep returned 10% increase in cuttings. Monitor well -static. PU=170K, S0=34K, ROT=100K. 16:00 17:15 1.25 12,963 12,963 PROD2 DRILL CIRC P Pump and displace open hole 325 bbl of 8.7 SFMOBM. 17:15 22:30 5.25 12,963 250 PROD2 DRILL TRIP P LD single and POOH to AGI-tater and shock sub, LD same. Continue POOH, stand back HWDP, jars and flex collars. 22:30 00:00 1.50 250 50 PROD2 DRILL SRVY P Download MWD. Max Gas= 78 units 07/17/2006 00:00 01:00 1.00 50 50 PROD2 DRILL PULD P Continue downloading MWD. 01:00 01:30 0.50 50 0 PROD2 DRILL PULD P Continue LD BHA, break bit, and LD motor. 01:30 02:00 0.50 0 0 COMPZ DRILL OTHR P Pull WB 02:00 05:30 3.50 0 0 COMPZ DRILL OTHR P RU pressure test equipment, chrt recorder and test BOPE to 250 psi / 3,000 psi hi/low, holding for 5 minutes of stabilized pressure. Test upper pipe rams, choke valve manifold valves number 1, 12, 13 and 14, manual kill line, upper IBOP, HCR Kill, choke manifold valves #5,8 and 10, Dart valve, CV No. 4,6,7, floor valve, CV 2, HCR, Annual reventer, and Blind rams. 05:30 06:00 0.50 0 0 COMPZ DRILL OTHR P RD test equipment, install WB. r age °i cf ~2 f ___ _-- Time Lomas _ _ _ _ _ _ Date From To Dur 5. e th E. De th Phase Code Subcode T 'OM _ 07/17/2006 06:00 07:00 1.00 0 0 COMPZ CASIN( RURD P Clean rig floor and RU liner running tools. 07:00 11:30 4.50 0 6,053 COMPZ CASIN( RNCS P PJSM. Run 140 joints of Blank / Slotted, 11.6 Ib/ft, L-80, BTC liner with torque rings installed and 4-1/2" x 6-3/8" Hydroform centralizers on each joint with Stop collars on the center of each 'oint. 11:30 12:30 1.00 6,053 6,693 COMPZ CASIN( RNCS P PJSM. Finish running 155 joints of Blank !Slotted, 11.6 Ib/ft, L-80, BTC liner with torque rings installed. PU= 82K, S0= 60K, ROT= 65K, TQ=3,000 ft-Ib at 10 and 20 rpm. RD liner runnin tools, clean ri floor. 12:30 16:30 4.00 6,693 12,925 COMPZ CASIN( RUNL P PU/MU 5-1 /2" receptacle, Liner setting sleeve and running tool, continue running liner on 4" DP to 12,608' and where SO weight = 0. Commence rotating liner down, working through tight spot @ 12,802'. Continue rotating liner until tagging bottom at 12, 959' md. PU and locate liner shoe on depth at 12, 925'. PU=175K, S0= OK, ROT= 97K, T0= 10,000 ft-Ib at 20 r m. 16:30 17:15 0.75 12,925 6,032 COMPZ CASIN< RUNL P Drop ball and pump down to ball seat, pressure up to 2,000 psi and release liner. Pressure up to 4,400 psi and shear out Circ sub. PU= 135K. PU and tag top of liner, confirming TOL at 6,238'. POOH with running tool to 6, 032' 17:15 18:00 0.75 6,032 6,032 COMPZ CASIN( CIRC P GBU. Monitor well -static. Pump slug. 18:00 20:00 2.00 6,032 200 COMPZ CASINC RUNL P POOH with displacement 6 bbl over Had lost 6 bbl whilst testin BOPE 20:00 20:15 0.25 200 0 COMPZ CASIN( OTHR P Inspect-ok, and LD liner running tools. 20:15 20:45 0.50 0 50 COMPZ FISH PULD P PU/MU whipstock retrieving fishing tools 20:45 22:45 2.00 50 6,115 COMPZ FISH TRIP P RIH to 6,068 filling DP at 3,130' and 6,068'. PU single, PU= 125K, S0=82K. Break circ. 22:45 23:30 0.75 6,100 6,100 COMPZ FISH FISH P Wash across whipstock slot, and attem t to hook. 07/18/2006 00:00 02:15 2.25 6,077 6,077 COMPZ FISH JAR P Attempt and Hook Whipstock @ 6, 07T. 02:15 02:30 0.25 6,077 5,975 COMPZ FISH TRIP P UD 1 jt. 4" DP Rack back 1 stand DP Pick u wt. 130k-145K. 02:30 03:30 1.00 5,975 5,975 COMPZ FISH CIRC P CBU @ 5975' 48 spm 173 gpm 850 psi Max as B/U 51 units. 03:30 07:30 4.00 5,975 100 COMPZ FISH TRIP P Monitor well & pump dry job. POH P/U 130k-135k Calculate for trip out 51 bbls. Actual 55 bbls. ~~ t'~~~: 1~ of 22 ._- _- _Time Logs _ _ _ _ ~ Rata Frnm Tn flier ~ ,anth F f~anth Phase C'nrie Siihr.nrie T ;C7M 07/18/2006 07:30 08:30 1.00 100 0 COMPZ FISH .PULD P PJSM-Lay down BHA Whipstock & Trip anchor assembly,2 3.5" pups 1 jt. 3.5" HWDP & seal assembl . 08:30 09:15 0.75 0 0 COMPZ FISH OTHR P Clean & clear rig floor. 09:15 10:15 1.00 0 0 COMPZ RIGMN SVRG P PJSM-Slip & cut 66' Drlg. line. 10:15 10:45 0.50 0 0 COMPZ RPCOh PULD P P/U Baker & MWD slimhole tools. 10:45 11:15 0.50 0 0 COMPZ RPCOh PULD P R/U Csg. Equipment. 11:15 12:00 0.75 40 40 COMPZ RPCOh RCST P P/U Shoe jt. 1 jt. 4.5" tbg. 12:00 12:15 0.25 40 213 COMPZ RPCOh RCST P PJSM-on P/U Hook hanger (Pinch points, good comunications,Remjnder sto ro ram. 12:15 14:15 2.00 213 300 COMPZ RPCON RCST P P/U & M/U Hook hanger/MWD assembly, running tool &RIH (SPT @ 300' 14:15 16:30 2.25 300 6,207 COMPZ RPCOh TRIP P RIH tag main bore XO @ MD 620T-P/U wt. 135k S/O wt. 84k. 16:30 18:15 1.75 6,207 6,283 COMPZ RPCOti TRIP P Pull up to 6060'-rotate 6 revs. & work torque-enter window & TO 6261-orient tool face & hook @ 6087 @ 7L_ stack 40k-pull up w/ hook @ 6060' turn 180 deg. S/O & tag XO @ 6290'-P/U to hook @ 6060' & reorient TF 0-S/O & hook @ (MD 6087 & Stack 45k TF 7L) w/shoe MD 6283'. 18:15 19:00 0.75 6,283 6,283 COMPZ RPCOh DHEQ P Drop & Pump ball on seat-Press. up 2000 psi increase to 2700 psi shear & inflate packer w/ 4 stks (14.2 gal).-shear out circ. sub w/ 4500 si-monitor well-Static-POOH to 6038'. 19:00 19:45 0.75 6,283 6,283 COMPZ RPCOh CIRC P CBU (Max gas units 57) Monitor well-static- um slu . 19:45 21:45 2.00 6,283 120 COMPZ RPCOh TRIP P POOH -Displacement 1.25 bbls. long. 21:45 23:00 1.25 120 0 COMPZ RPCOh PULD P Lay down running tools & MWD assembl . 23:00 23:30 0.50 0 0 COMPZ RPCOti RURD P Clear & clean rig floor of tools. 23:30 00:00 0.50 0 0 COMPZ RIGMN SVRG P Rig service-tube crown,blocks & Top Drive. 07/19/2006 00:00 00:30 0.50 0 0 COMPZ RPCOti SFTY P PJSM-Rig up csg. Equipment 00:30 02:30 2.00 0 477 COMPZ RPCOh PULD P M/U Lem assembly, Bent jt. w/ seals, 1 jt. 4 1/2" tbg. DB-6 nipple 3 pup jts. 7 jts. IBT 4.5" tbg.CSBR, ZXP w/ runnin tool & XO. 02:30 05:30 3.00 477 6,070 COMPZ RPCOh TRIP P RIH w/ LEM assembly P/U 140k S/O 88k. Latch @ 6070' w/Seal Assembly @ 6197.62' (10.21' Inside A2 CSR). Pull 160k-unlatch to verify. Relatch LEM & u11 150k. w ~~~~ 't~ cfi ~2 r Pale 1`?c~fi 22- Time Logs Date From To Dur S e th E De th Phase Code Subcode T OM _ 07/19!2006 05:30 06:00 0.50 6,070 6,070 COMPZ RPCOI~ OTHR P Drop ball & pump down @ 3 bpm 400 psi.; Ball on seat @ 455 strokes.Set ZXP pressure to 2200psi. Pressure to 4000 si release LEM. 06:00 06:30 0.50 6,070 6,070 COMPZ RPCOh OTHR P Test ZXP down annulus to 1000 f/ 10 min on chart OK. 06:30 07:15 0.75 6,040 6,040 COMPZ RPCOh CIRC P Pull up to 6040-CBU @ 80 spm 1500 si 37 units as on B/U. 07:15 09:30 2.25 6,040 0 COMPZ RPCOh TRIP P Monitor well-pump dryjob & POH. 09:30 10:00 0.50 0 0 COMPZ RPCOti OTHR P Lay down liner running tools. 10:00 10:30 0.50 0 0 COMPZ RPCOh OTHR P Clear & clean floor & pick up tools. 10:30 12:00 1.50 0 0 PROD3 FISH PULD P PJSM-make up mill assembly. NO w/ seals-unloader sub & 1 't. 3.5" DP. 12:00 12:15 0.25 0 0 PROD3 FISH PULD P PJSM-on pick up milling & Whipstock assembl . 12:15 13:00 0.75 0 .200 PROD3 FISH PULD P P/U & M/U Whipstock, mill & MWD assembly (Orient) & pick up bumper sub. 13:00 13:30 0.50 200 200 PROD3 FISH PULD P Program MWD. 13:30 16:00 2.50 200 5,050 PROD3 FISH TRIP P RIH (SPT@ 477) Fill dp @ 3280 cont. RIH to 5050' & break circ. 16:00 16:30 0.50 5,050 5,140 PROD3 FISH TRIP P Mad pass from 5050 to 5140'. 16:30 17:00 0.50 5,140 5,801 PROD3 FISH TRIP P RIH to 5755-break circ. P/U 125k S/O 85k-tag 5801'-shear anchor w/ 25k & Set whipstock @ 16 deg Left of Highside -confirm w/ 5k overpull-slack off & shear off whipstock w/ 45k RT wt 100k 80 r mt 3-5k 256 m 1750 si. 17:00 22:30 5.50 5,697 5,711 PROD3 FISH MILL P MiII L-2 window from5697 to 5711. 22:30 00:00 1.50 5,711 5,720 PROD3 FISH MILL P Mill new hole from 5711 to 5720'. 07/20/2006 00:00 00:45 0.75 5,720 5,741 PROD3 FISH MILL P Continue to drill gauge hole from 5720' t0 5741'. 00:45 01:45 1.00 5,741 5,741 PROD3 FISH CIRC P Pump 30 bbls. weighted hi-vis sweep-work mills thru window w/ pumps & rotation & without pumps & rotation. No problems. P/U 125k S/O 95k. 01:45 03:00 1.25 5,741 3,461 PROD3 FISH TRIP P Monitor well-SPR-Pump dry job & poh to 3461'. 03:00 06:45 3.75 3,461 0 PROD3 FISH TRIP P PJSM-Rig up & relocate supersliders on drill i e while POH. 06:45 07:00 0.25 0 0 PROD3 FISH PULD P Lay down BHA-XO & Bumper sub. 07:00 07:15 0.25 0 0 PROD3 FISH PULD P Down load MWD. 07:15 08:00 0.75 0 0 PROD3 FISH PULD P Continue lay down BHA-upper mill was in au e. 08:00 08:15 0.25 0 0 PROD3 FISH OTHR P Clear & clean rig floor. --- Time Logs Date From To ____ Dur 5. Depth E De th Phase Code Subcode T ~M _ I 07/20/2006 08:15 09:15 1.00 0 0 PROD3 FISH OTHR P Pull wear bushing-flush bop stack-run wear bushin . 09:15 11:00 1.75 0 100 PROD3 DRILL PULD P PJSM-Make BHA #8. 11:00 12:00 1.00 100 100 PROD3 DRILL PULD P Upload MWD. 12:00 12:15 0.25 100 100 PROD3 DRILL SFTY P PJSM-On Tripping & Drlg. 12:15 12:30 0.25 100 365 PROD3 DRILL TRIP P RIH w/ BHA #8 to 365'. Break in eo- ilot S.P.T. & command test. 12:30 14:00 1.50 365 5,691 PROD3 DRILL TRIP P RIH to 5691'-break circ. 270 gpm 1700# P/U 98k S/O 70k.RW 84k TQ 4k. 14:00 14:30 0.50 5,691 5,741 PROD3 DRILL CIRC P Wash & Slide from 5691 to 5731'- & ream 5731 to 5741'. 14:30 00:00 9.50 5,741 6,400 PROD3 DRILL DDRL P Drilling from 5741' to 6400' (TVD 3434') Actual Rotatin Time 6.63 Hrs. 07/21/2006 00:00 12:00 12.00 6,400 7,430 PROD3 DRILL DDRL P Drlg. 6 3/4" Horizontal hole from 6400' to 7430'. (3435 TVD) P/U 110k S/O 60k ROT 80k TQ 5.5k Max gas 134 units ECD 10.26 SPR @ Concretion depths 649T-6501', 8505'-6506', 6514'-6517', 6554'-6556', 7064'-7067', 7139'-7141', 7172'-7175', 7178'-7190', 7199'-7203', 7357'-7363', 7380'-7387', 7389'-7397,. 12:00 00:00 12.00 7,430 8,430 PROD3 DRILL DDRL P Drlg. 6 3/4" Horizontal hole from 7430' to 8430'. (3408 TVD) P/U 115k S/O 50k ROT 78k TQ 6k Max gas 125 units ECD 10.5 SPR @ Concretion depths 7412-7418-7500-7507-7550-7569-7571- 7588-7844-7849-7863-7872-7874-7876- 7881-7888-7905-7907-7910-7911-7995- 8002-8005-8063-8064-8067-& 8068. 07/22/2006 00:00 12:00 12.00 8,430 9,985 PROD3 DRILL DDRL P Drlg. 6 3/4" Horizontal hole From 8430' to 9985'. (TVD 3365'.) ART-8.07 P/U 127k S/O 35k ROT 77k TQ on 7k TQ off 7.5k Max gas 363 units ECD 11.07 Concretions=8620-8621-8625-8626-87 21-8724-8733-8736-8753-8756-9185- & 9188. 12:00 00:00 12.00 9,985 11,508 PROD3 DRILL DDRL P Drlg. 6 3!4" Horizontal hole From 9985' to 11508'. (TVD 333T) ART 7.38 P/U 137k S/O 0 ROT 82k TQ on 8.5k TQ off 8.5k Max gas 118 units ECD 11.45 Concretions 10435-10440-10732-10733-10744-1074 5-10750-10751-10763-& 10765'. 07/23/2006 00:00 07:30 7.50 11,508 12,285 PROD3 DRILL DDRL P Drlg. Horizontal hole from 11508 to 12285'. (TVD) 3345'. (777') ART 4.61 WOB 5-15K, RPM 135, Pu 160K, Dn OK, ROT 98K, TQ 9.5K on / 8.5K off, Max gas 289 units, Ave ECD's 11.8 07:30 08:15 0.75 12,285 12,285 PROD3 DRILL DHEO T Trouble shoot MWD. Change Mode. ~ _~ ~ - ~~g~ °~8 c~€ ~~ Time Low Date From To Dur 5. e th E De th Phase Code Subcode T COM 07/23/2006 08:15 10:45 2.50 12,285 12,566 PROD3 DRILL DDRL P Drlg. Horizontal hole from 12285' to -- 12566'. (TVD) 3330' (281'). ART 1.45 P/U 160k S/O 0 Rot 98k TQ on 9.5k Off 8.5k Max as 289 units ECD 11.8 10:45 11:00 0.25 12,566 12,566 PROD3 DRILL OTHR P SPR,s Lay Down Jt. 4" DP. 11:00 12:00 1.00 12,566 12,566 PROD3 DRILL CIRC P Pump 30 bbls. weighted hi-vis sweep @ 12562' @ 83 spm 3370 psi 135 rpm T 8k. 12:00 12:30 0.50 12,566 12,566 PROD3 DRILL CIRC P Circ. sweep out @ 83 spm 3370psi 135 r m 8k TO "0" increase in returns. 12:30 12:45 0.25 12,566 12,566 PROD3 DRILL OTHR P Monitor well-Static-install stripping rubbers. 12:45 21:30 8.75 12,566 12,566 PROD3 DRILL TRIP P BROOH f/ 12,565' MD 3330 TVD to window @ 5711 MD @ 120 rpm 85 spm 310 gpm 3050 psi tq 7k pulled @ 40-45 FPM Calc displacement 45 bbls. Actual dis lacement 58.4 bbls. 21:30 21:45 0.25 12,566 12,566 PROD3 DRILL OTHR P Monitor well inside window-Static- Pull stri in rubbers. 21:45 00:00 2.25 12,566 12,566 PROD3 DRILL CIRC P Break circ. pump 35 bbls weighted hi-vis sweep @ 275 gpm till thru mwd , increase rate to 300 gpm 100 rpm, 2100 psi, 10% increase in returns, circulate shakers clean @ 3-bottoms u. 07/24/2006 00:00 01:00 1.00 12,566 5,600 PROD3 DRILL OTHR P PJSM=Cut 91' drlg. line, Service top drive & ins ect saver sub. 01:00 03:15 2.25 5,600 10,127 PROD3 DRILL TRIP P RIH, slide thru window-no problems, RIH to 10127' ran out of down wei ht. 03:15 06:00 2.75 10,127 12,560 PROD3 DRILL TRIP P Wash & ream in hole from 10127' to 12560' @ 77 spm 280 gpm 50 rpm 2500 si TQ 6k. 06:00 07:30 1.50 12,560 12,560 PROD3 DRILL CIRC P Pump 30 bbls. weighted hi-vis sweep 310 gpm 85 spm 120 rpm 3560 psi TQ 8.5k ECD 11.58 total gas 30 units 10% increase in cuttings on BU w/ swee . 07:30 08:45 1.25 12,560 12,560 PROD3 DRILL CIRC P Pump 320 bbls. 8.7# SFOBM, Displace w/ 50 bbls. OBM including d 'ob. 08:45 12:00 3.25 12,560 7,652 PROD3 DRILL TRIP P Monitor well, POH w/25-30k 175k P/U. 25-30k drag from 11970. (NOTE) Ramp on geo-pilot stuck @ 60deg. reflection. POH to 7652' P/U 125k S/O 52k. 12:00 14:45 2.75 7,652 0 PROD3 DRILL TRIP P POH on elevators from 7652' No roblems ullin thru window. 14:45 15:45 1.00 0 0 PROD3 DRILL PULD P Lay down hwdp, jars & 3 moneys. 15:45 16:30 0.75 0 0 PROD3 DRILL OTHR P Down load MWD. 16:30 17:45 1.25 0 0 PROD3 DRILL PULD P Pulf up, Break bit, lay down MWD & Geo- ilot. 17:45 18:15 0.50 0 0 COMPZ DRILL OTHR P Clear & clean rig floor. }~~~,~e 1y ~F 22 Time Logs - --- - ---------- 1 Date From To Dur 5 )e th E. De th Phase Code Subcod_e_ 7 COM 07/24/2006 18:15 18:45 0.50 0 0 COMPZ CASIN( RURD P Rig up to run 4 1/2" slotted liner in "D" Lateral. 18:45 23:00 4.25 0 6,629 COMPZ CASIN ( RUNL P PJSM=Run 4 1/2" liner to 6629', went thru window w/ no problems. Calc. displacement 27.7 Actual dis lacement 15.8 bbls. 23:00 23:30 0.50 6,629 6,629 COMPZ CASIN( PUTS P Change out handling tools=make up liner settin tool 23:30 00:00 0.50 6,629 6,629 COMPZ CASIN( PUTS P Rig down csg. tools, rig up to run liner on 4" dp. P/U Jt. #154 82k S/O Jt. 154 58k. 07/25/2006 00:00 03:45 3.75 6,629 12,566 COMPZ CASIN( RUNL P Rotate liner @ 6730' 20 rpm TQ 3.5k=Run 4.5" slotted liner on 4" dp from 6629' to 12,566'=tag bottom P/U 170k S/O 45k. 03:45 04:00 0.25 12,566 12,551 COMPZ CASIN< RUNL P Pull up, rotate liner 20 rpm w/ 9K ft/Ib Torque, S/O tag bottom pull up to 12551.0 04:00 04:45 0.75 12,551 12,551 COMPZ CASIN( RUNL P Drop ball-set liner on depth while rotating. Pump down @ 4bpm saw no indication of ball seating after 1250 strokes. Shut down pumps. Mechanicaly released from liner 10k dro P/U 125k. 04:45 05:30 0.75 12,551 5,711 COMPZ DRILL CIRC P Pull 2 stands dp=CBU-wash whipstock slot from 5697-5711 @ 72 spm 1400 si 275 m. 05:30 08:00 2.50 5,711 0 COMPZ DRILL TRIP P Monitor well & POH. 08:00 08:30 0.50 0 0 COMPZ DRILL PULD P Lay down liner running tool & clean floor. 08:30 09:30 1.00 0 0 COMPZ DRILL PULD P PJSM-Make up whipstock retrieving tools. 09:30 12:00 2.50 0 5,604 COMPZ DRILL TRIP P RIH to 5604' P/U 125k S/O 85k. 12:00 12:15 0.25 5,604 5,604 COMPZ DRILL OTHR P Latched whipstock on second try ulled 60k over strin wt. 12:15 12:30 0.25 5,604 5,573 COMPZ DRILL PULD P Lay down single. 12:30 13:00 0.50 5,573 5,573 COMPZ DRILL CIRC P CBU @ 86 spm 1800 psi No gas. 13:00 13:30 0.50 5,573 5,573 COMPZ DRILL CIRC P Monitorwell-static-pump dry job. 13:30 16:00 2.50 5,573 0 COMPZ DRILL TRIP P POH w/ whipstock. 16:00 17:45 1.75 0 0 COMPZ DRILL PULD P Lay down BHA & whipstock ramp assembl . 17:45 18:30 0.75 0 0 COMPZ DRILL OTHR P Clear & clean rig floor. 18:30 19:00 0.50 0 220 COMPZ CASIN( RURD P P/U hook hanger tools from bottom of slide. 19:00 20:00 1.00 220 220 COMPZ CASIN( RURD P Rig up csg. tools. 20:00 20:30 0.50 220 220 COMPZ CASIN( SFTY P PJSM=on making up & running hook han er assembl . ~~ ~_ ~ Pane. ~~ ~~ 2~ --- Time Logs Date _ __ From To Dur 5. e th E De th Phase Code Subcode T COM 07/25/2006 20:30 21:00 0.50 220 220 COMPZ RIGMN SVRG P Service top drive. 21:00 23:15 2.25 220 220 COMPZ .CABIN( RURD P Make up hook hanger assembly slimhole MWD, space out tbg. for inner strin . 23:15 00:00 0.75 220 220 COMPZ CABIN( RURD P Lay down csg. tools, clear & clean rig floor. 07/26/2006 00:00 03:45 3.75 220 5,670 COMPZ CABIN( RUNL P Shallow test MWD-RIH to 5840'-Tag up in mother bore-pull up to 5670'. Rotate 3.5 turns to right-go thru window-orient 6 de .left. 03:45 04:45 1.00 5,670 5,694 COMPZ CABIN( RUNL P Hook window-unhook turn 180 deg. go past-pull up-rehook set down 35k twice-hook set on depth @ 5711'-top of hook 5694'. 04:45 05:30 0.75 5,694 5,694 COMPZ CABIN( CIRC P Drop ball-pump @ 2 bpm on seat @ 560 strokes-pressure up 2650 psi inflate ECP-release from hook-pressure to 4300 psi could not shear um out sub. 05:30 08:30 3.00 5,694 0 COMPZ DRILL TRIP P POH to 5672' monitor well pump pill & POH. 08:30 10:30 2.00 0 0 COMPZ CABIN( RURD P Rig down double stack tongs lay down hook running tool 3 jts. 2 7/8" wash i e & slim hole MWD. 10:30 11:30 1.00 0 0 COMPZ CABIN( RURD P Rig down tongs-clear & clean rig floor. 11:30 12:00 0.50 0 0 COMPZ CABIN( RURD P Rig up csg. equipment. 12:00 12:30 0.50 0 0 COMPZ CABIN( SFTY P PJSM=Hazard assesment on make up & runnin LEM. 12:30 15:30 3.00 0 . 5,653 COMPZ CABIN( RNCS P RIH w/ LEM on 4" DP to 5653'. 15:30 16:45 1.25 5,653 5,653 COMPZ CASINC OTHR P Slid LEM into sealbore assembly, Latched up, unlatched then reatched, saw visual on wt. indicator, dropped ball & pumped down @ 36 spm 430 psi ball seat @ 460 strokes, pressured up to 2000 psi, saw shear, pump to 4000 si for 1 minute. 16:45 17:00 0.25 5,653 5,653 COMPZ CABIN( OTHR P Test ZXP packer @ 1000 psi for 10 minutes on chart. 17:00 17:45 0.75 5,653 5,653 COMPZ CASINC CIRC P CBU @ 51 spm 770 psi. 17:45 18:00 0.25 5,653 5,653 COMPZ CABIN( RURD P Rig down test equipment. 18:00 18:30 0.50 5,653 5,653 COMPZ CASINC CIRC P Pump dry job, blow down top drive & kill line. 18:30 20:45 2.25 5,653 0 COMPZ CABIN( OTHR P Monitor well-POH. 20:45 21:00 0.25 0 0 COMPZ CABIN( OTHR P Clean rig floor. & pull wear bushing. 21:00 21:45 0.75 0 0 COMPZ CABIN( RURD P Rig up csg. tools. 21:45 22:15 0.50 0 0 COMPZ CASINC SFTY P PJSM on running tbg. w/Baker re =Co. re & crew. F'~e ~1 cfZ~~ __ Time Logs _ _ -, _ Date From To Dur e th E De th Phase Code Subcode T __ 'OM 07/26/2006 22:15 00:00 1.75 0 660 COMPZ CASIN ( OTHR P Running completion tbg. & accesaries. 07/27/2006 00:00 03:45 3.75 660 5,646 COMPZ RPCOh PULD P Continue to RIH w/ 4.5" 12.6# IBTM tbg. ran total of 180 jts. P/U 75k S/O 60k. 03:45 05:00 1.25 5,646 5,646 COMPZ RPCOh CIRC P Rig up circ. head Circ. 3 B/U @ 210 spm 810 gpm 1800 psi circ. till shakers clean ri down circ. head. 05:00 06:00 1.00 5,646 5,674 COMPZ RPCOh HOSO P RIH to 5674' tagged seal locator, pull u & s ace out w/ 5.80 u . 06:00 06:30 0.50 5,674 5,674 COMPZ RPCOh HOSO P Make up tbg. hanger & land tbg. P/U 75k S/O 60k. 06:30 07:30 1.00 5,674 5,674 COMPZ RPCOh DHEQ P RILDS-test tbg. hanger seals 5000 psi test10 mins. OK. 07:30 08:45 1.25 COMPZ RPCOh NUND P PJSM=Nipple down BOPE. 08:45 11:30 2.75 COMPZ RPCOh NUND P PJSM- nipple. uptree-test void to 5000 si test tree & actuator 5000 si OK. 11:30 12:00 0.50 COMPZ RPCOh OTHR P Rig up cellar for displacement. Rig up to la down DP from derrick. 12:00 12:15 0.25 COMPZ RPCOti SFTY P PJSM= hazard assesment on laying down drill i e. 12:15 13:15 1.00 COMPZ RPCOh PULD P Lay down 16 stands 4" drill pipe. 13:15 13:30 0.25 COMPZ RPCOh SFTY P PJSM=on Freeze protect. 13:30 15:30 2.00 COMPZ RPCOh FRZP P Freeze protect tbg. & annulus w/ 255 bbls. diesel 5 b m. 15:30 16:15 0.75 COMPZ RPCOh PULD P Lay down 7 stands 4" drill pipe. 16:15 16:45 0.50 COMPZ RPCOh OTHR P Pick up BPV & set same w/ Vetco Gra . 16:45 21:00 4.25 COMPZ RPCOh PULD P Lay down the rest of slick pipe 82 stands. 21:00 00:00 3.00 COMPZ RPCOti PULD P Lay down 15 stands push pipe-7 stands hwdp-5 stands super slider i e. 07/28/2006 00:00 02:45 2.75 COMPZ RPCO4 PULD P Continue laying down 4" DP from derrick-inspecting hard bands, removing supersliders from the ones that need new hard bands. 02:45 04:00 1.25 COMPZ RPCOti OTHR P - Clear & clean rig floor & cellar. (Release rig from 1J-156 to Rig Maintenance 7-28-2006 0400. Halliburton Company Survey Report C~nnp:ui}: ConocoPhillips Alaska Inc. ll;itc: 819120C6 1 inic: 1032A8 I'a,c: Iicld: Kuparuk River Unit (;u-ur~linalclAI.) Rclcrencc: Well- 1J-155. T rue North , tiiu•: K~_iparuh 1J Pad Pcr~ic:~l (lbll~ Ilcfcrcncc: iJ-156L2 109 .0 ~~ell: 1J-15~ ~ectiun I~ti1 Hefcrenec: Well i000N.0. OOE 180-OOAzi) ~1cll~rith: 1J-156L2 Snn~c~ (alculs[iun ~[ethod: Minimum Curv ature Ub: Orade Field: Kuparuk River Unit North Slope Alaska United States Map System:US State Plane Coordinate System 1927 Map Zone: Alaska, Zone 4 Geo Datum : NAD27 (Clarke 1866) Coordinate System: Well Centre Sys Datum: Mean Sea Level Geomagnetic Model: bggm2005 Well: 1 J-156 Slot Name: Well Position: +N/-S -13.52 ft Northing: 59459 05.02 ft o Latitude: 70 15 46.125 N +E/-W -140.85 ft Easting : 558649.22 ft • Longitude: 149 31 33.105 W Position Un certainty: 0.00 ft Wellpath: 1J-156L2 Drilled From: 1J-156 500292331161 Tie-on Depth: 5631.47 ft Current Datum: 1 J-156L2: Height 1 09.00 ft Above System Datum: Mean Sea Level Magnetic Data: 6/28/2006 Declination: 24.04 deg Field Strength: 57565 nT Mag Dip Angle: 80.78 deg Vertical Sec tion: Depth From (TVD) +N/-S +E/-W Direction ft ft ft deg 28.00 0.00 0.00 180.00 Survey Program for Definitive Wellpath Date: 8/9/2006 Validated: No Version: 1 Actual From To Survey Toolcode Tool Name ft ft 50.00 539.00 1 J-156 gyro (50.00-539.00) (0) C&GYRO-SS Camera based gyro single shot 628.39 5631.47 1J-156 (628.39-8233.13) (0) MWD+-FR-AK-CAZ-SC MWD+IFR AK CAZ SCC 5697.00 12521.84 1J-156L2 (5697.00-12521.84) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC Survey \II1 Intl \iim I ~'I) ti~~~ ll'I) \~:ti t:'l1 ~Ia~~A 11ap1~: ~fuol ft deg deg ft ft ft ft ft ft 28.00 0.00 0.00 28.00 -81.00 0.00 0.00 5945905.02 558649.22 TIE LINE 50.00 0.12 309.10 50.00 -59.00 0.01 -0.02 5945905.03 558649.20 CB-GYRO-SS 100.00 0.33 302.21 100.00 -9.00 0.12 -0.18 5945905.14 558649.04 CB-GYRO-SS 170.00 0.16 227.52 170.00 61.00 0.17 -0.42 5945905.18 558648.80 CB-GYRO-SS 261.00 0.84 274.09 261.00 152.00 0.13 -1.18 5945905..14 558648.04 CB-GYRO-SS 357.00 3.64 283.48 356.91 247.91 0.89 -4.85 5945905.87 558644.37 CB-GYRO-SS 446.00 7.52 285.11 445.47 336.47 3.07 -13.22 5945907.98 558635.98 CB-GYRO-SS 539.00 9.29 284.65 537.47 428.47 6.55 -26.36 5945911.36 558622.81 CB-GYRO-SS 628.39 10.78. 282.16 625.49 516.49 10.14 -41.51 5945914.83 558607.63 MWD+IFR-AK-CAZ-SC 661.48 12.02 281.08 657.93 548.93 11.45 -47.92 5945916.10 558601.22 MWD+IFR-AK-CAZ-SC 697.90 13.22 279.83 693.47 584.47 12.89 -55.75 5945917.47 558593.38 MWD+IFR-AK-CAZ-SC 764.19 15.65 278.50 757.66 648.66 15.51 -72.06 5945919.96 558577.05 MWD+IFR-AK-CAZ-SC 856.58 15.78 279.44 846.60 737.60 19.41 -96.78 5945923.67 558552.30 MWD+IFR-AK-CAZ-SC 948.01 18.55 280.46 933.95 824.95 24.09 -123.35 5945928.15 558525.70 MWD+IFR-AK-CAZ-SC 1040.41 22.41 279.81 1020.49 911.49 29.76 -155.17 5945933.57 558493.84 MWD+IFR-AK-CAZ-SC 1133.37 25.84 279.39 1105.32 996.32 36.09 -192.63 5945939.60 558456.34 MWD+IFR-AK-CAZ-SC 1225.55 28.82 279.19 1187.20 1078.20 42.91 -234.39 5945946.10 558414.53 MWD+IFR-AK-CAZ-SC 1320.60 32.24 280.08 1269.06 1160.06 51.01 -281.98 5945953.83 558366.88 MWD+IFR-AK-CAZ-SC 1413.40 34.96 281.94 1346.35 1237.35 60.85 -332.37 5945963.27 558316.41 MWD+IFR-AK-CAZ-SC 1506.74 35.50 281.10 1422.59 1313.59 71.60 -385.13 5945973.61 558263.58 MWD+IFR-AK-CAZ-SC 1598.95 36.98 280.44 1496.96 1387.96 81.78 -438.68 5945983.37 558209.95 MWD+IFR-AK-CAZ-SC 1692.74 39.87 279.40 1570.43 1461.43 91.80 -496.10 5945992.95 558152.47 MWD+IFR-AK-CAZ-SC 1782.84 46.17 278.46 1636.28 1527.28 101.31 -556.80 5946001.98 558091.71 MWD+IFR-AK-CAZ-SC 1875.42 48.72 278.17 1698.88 1589.88 111.17 -624.27 5946011.31 558024.16 MWD+IFR-AK-CAZ-SC 1967.60 52.01 275.99 1757.68 1648.68 119.88 -694.71 5946019.48 557953.67 MWD+IFR-AK-CAZ-SC 2060.57 58.03 272.32 1810.97 1701.97 125.31 -770.63 5946024.31 557877.71 MWD+IFR-AK-CAZ-SC 2154.73 58.56 270.78 1860.45 1751.45 127.47 -850.71 5946025.85 557797.63 MWD+IFR-AK-CAZ-SC 2242.55 60.83 269.43 1904.77 1795.77 127.60 -926.52 5946025.39 557721.83 MWD+IFR-AK-CAZ-SC Halliburton Company Survey Report t'omp:m~: ConocoPhillipsAlask,a Inc- Ihuc: 315'2005 Iimc: 10J2~4~ Pa,c: '_ Fichl: Kuparuk. ~iverUnii (~~-urilin;it~'I~~l Rcii•rcncr. Well_ 1J-156. True North 1itc: Kup2ruk 1J Pad ~~crtical (~~I)) Kcfercncc: 1J-'1562 109.0 ~~cll: 1J-156 ti<~rtiuu 151 ILcfcrcucc: We!I (QGON O OGE,130 OQAzi) Nellpsth: 1J-15oL2 3un~c}~('alculslion~IcUuxl: Minimum Curvature Ub_ Oracle ~urcc~ 111) Intl ~iim l~~U tics"Ill) \:ti I~-~~ ~la~iA ~la~il: l~ixi~ ft deg deg ft ft ft ft ft ft 2335.91 60.92 269.25 1950.21 1841.21 126.66 -1008.07 5946023.82 557640.29 MWD+IFR-AK-CAZ-SC 2429.73 60.92 270.59 1995.81 1886.81 126.55 -1090.06 5946023.06 557558.31 MWD+IFR-AK-CAZ-SC 2523.25 61.26 268.34 2041.02 1932.02 125.78 -1171.91 5946021.66 557476.48 MWD+IFR-AK-CAZ-SC 2616.59 57.90 268.87 2088.28 1979.28 123.82 -1252.37 5946019.07 557396.05 MWD+IFR-AK-CAZ-SC 2709.57 58.96 268.53 2136.96 2027.96 122.02 -1331.56 5946016.65 557316.87 .MWD+IFR-AK-CAZ-SC 2729.48 59.49 268.15 2147.14 2038.14 121.52 -1348.66 5946016.02 557299.78 MWD+IFR-AK-CAZ-SC 2826.57 60.03 267.98 2196.04 2087.04 118.69 -1432.49 5946012.54 557215.98 MWD+IFR-AK-CAZ-SC 2920.36 58.92 266.59 2243.68 2134.68 114.87 -1513.19 5946008.09 557135.33 MWD+IFR-AK-CAZ-SC 3012.90 58.01 264.09 2292.08 2183.08 108.47 -1591.79 5946001.08 557056.78 MWD+IFR-AK-CAZ-SC 3108.25 57.70 263.40 2342.82 2233.82 99.67 -1672.04 5945991.66 556976.61 MWD+IFR-AK-CAZ-SC 3202.47 59.79 259.98 2391.71 2282.71 88.01 -1751.72 5945979.38 556897.04 MWD+IFR-AK-CAZ-SC 3295.75 61.28 254.21 2437.62 2328.62 69.85 -1830.82 5945960.61 556818.08 MWD+IFR-AK-CAZ-SC 3389.35 61.96 248.08 2482.14 2373.14 43.25 -1908.70 5945933.39 556740.43 MWD+IFR-AK-CAZ-SC 3482.06 60.16 242.90 2527.03 2418.03 9.63 -1982.49 5945899.21 556666.90 MWD+IFR-AK-CAZ-SC 3575.84 59.32 237.52 2574.31 2465.31 -30.57 -2052.76 5945858.46 556596.96 MWD+IFR-AK-CAZ-SC 3669.53 59.15 236.82 2622.23 2513.23 -74.22 -2120.40 5945814.30 556529.66 MWD+IFR-AK-CAZ-SC 3762.54 59.35 236.61 2669.79 2560.79 -118.08 -2187.22 5945769.91 556463.19 MWD+IFR-AK-CAZ-SC 3856.53 59.81 237.44 2717.38 2608.38 -162.20 -2255.22 5945725.28 556395.55 MWD+IFR-AK-CAZ-SC 3949.79 62.02 236.39 2762.71 2653.71 -206.69 -2323.49 5945680.26 556327.63 MWD+IFR-AK-CAZ-SC 4041.96 62.70 235.18 2805.47 2696.47 -252.60 -2391.01 5945633.83 556260.48 MWD+IFR-AK-CAZ-SC 4135.29 62.94 233.80 2848.11 2739.11 -300.83 -2458.59 5945585.08 556193.28 MWD+IFR-AK-CAZ-SC 4228.84 63.84 233.61 2890.01 2781.01 -350.34 -2526.00 5945535.05 556126.27 MWD+IFR-AK-CAZ-SC 4324.27 63.22 228.72 2932.57 2823.57 -403.87 -2592.52 5945481.00 556060.17 MWD+IFR-AK-CAZ-SC 4415.66 61.95 227.40 2974.64 2865.64 -458.09 -2652.87 5945426.33 556000.25 MWD+IFR-AK-CAZ-SC 4511.02 62.68 223.46 3018.96 2909.96 -517.34 -2713.00 5945366.62 555940.59 MWD+IFR-AK-CAZ-SC 4604.16 61.72 221.00 3062.41 2953.41 -578.33 -2768.38 5945305:20 555885.70 MWD+IFR-AK-CAZ-SC 4695.44 62.82 217.23 3104.89 2995.89 -641.01 -2819.32 5945242.13 555835.25 MWD+IFR AK-CAZ-SC 4789.29 65.39 211.95 3145.90 3036:90 -710.50 -2867.19 5945172.28 555787.93 MWD+IFR-AK-CAZ-SC 4882.76 66.00 206.67 3184.39 3075.39 -784.75 -2908.86 5945097.71 555746.84 MWD+IFR-AK-CAZ-SC 4977.56 66.41 201.68 3222.66 3113.66 -863.85 -2944.37 5945018.34 555711.95 MWD+IFR-AK-CAZ-SC 5071.42 68.37 197.34 3258.76 3149.76 -945.50 -2973.27 5944936.48 555683.69 MWD+IFR-AK-CAZ-SC 5163.66 71.51 194.39 3290.40 3181.40 -1028.83 -2996.93 5944852.98 555660.68 MWD+IFR-AK-CAZ-SC 5257.97 72.05 190.73 3319.90 3210.90 -1116.25 -3016.40 5944765.42 555641.89 MWD+IFR-AK-CAZ-SC 5351.05 75.87 186.20 3345.62 3236.62 -1204.69 -3029.53 5944676.88 555629.46 MWD+IFR-AK-CAZ-SC 5444.97 76.47 180.99 3368.09 3259.09 -1295.68 -3035.24 5944585.87 555624.45 MWD+IFR-AK-CAZ-SC 5538.34 77.43 178.91 3389.17 3280.17 -1386.63 -3035.16 5944494.93 555625.25 MWD+IFR-AK-CAZ-SC 5631.47 78.39 178.69 3408.68 3299.68 -1477.67 -3033.25 5944403.91 555627.86 MWD+IFR-AK-CAZ-SC 5697.00 78.35 178.85 3421.89 3312.89 -1541.84 -3031.87 5944339.76 555629.74 MWD+IFR-AK-CAZ-SC 5748.80 82.36 179.62 3430.57 3321.57 -1592.89 -3031.19 5944288.72 555630.82 MWD+IFR-AK-CAZ-SC 5791.91 81.99 180.25 3436.44 3327.44 -1635.60 -3031.14 5944246.02 555631.20 MWD+IFR-AK-CAZ-SC 5888.49 89.56 181.66 3443.55 3334.55 -1731.83 -3032.75 5944149.78 555630.34 MWD+IFR-AK-CAZ-SC 5934.32 89.80 182.32 3443.80 3334.80 -1777,64 -3034.35 5944103.98 555629.10 MWD+IFR-AK-CAZ-SC 5982.40 90.42 183.02 3443.71 3334.71 -1825.66 -3036.59 5944055.94 555627.24 MWD+IFR-AK-CAZ-SC 6027.20 91.29 183.67 3443.04 3334.04 -1870.38 -3039.20 5944011.20 555624.97 MWD+IFR-AK-CAZ-SC 6073.45 91.53 184.20 3441.90 3332.90 -1916.51 -3042.37 5943965.06 555622.16 MWD+IFR-AK-CAZ-SC 6120.86 92.40 182.19 3440.28 3331.28 -1963.81 -3045.01 5943917.74 555619.89 MWD+IFR-AK-CAZ-SC 6168.84 92.20 180.31 3438.35 3329.35 -2011.74 -3046.06 5943869.81 555619.21 MWD+IFR-AK-CAZ-SC 6214.06 91.58 178.67 3436.86 3327.86 -2056.93 -3045.66 5943824.63 555619.97 MWD+IFR-AK-CAZ-SC 6307.05 90.10 178.31 3435.50 3326.50 -2149.88 -3043.21 5943731.71 555623.14 MWD+IFR-AK-CAZ-SC 6398.46 90.23 178.91 3435.23 3326.23 -2241.26 -3040.99 5943640.36 555626.07 MWD+IFR-AK-CAZ-SC 6492.14 89.48 178.23 3435.47 3326.47 -2334.91 -3038.65 5943546.74 555629.14 MWD+IFR-AK-CAZ-SC 6586.12 89.11 177.61 3436.63 3327.63 -2428.82 -3035.24 5943452.87 555633.28 MWD+IFR-AK-CAZ-SC Halliburton Company Survey Report (~~nupam: Conoco PhillipsAlasBa Inc. I)a~e: Bi9i"006 Cimc: 10:2:48 I',i~,c: 3 ficl~l: Kuparuk River Unit Cu-unlinstcltt~l KcFcrcncc: Well: 1J-156.. True North ~irc: Kuparuk 1J Pad ~crlir.il f~l~~ ~)~ 12cfcrcncc: 1J-156L2 109.0 ~~ell: 1 J-15o Scc~iun 1~~1 Ilctercncc: Well i0.OON.O OOE180 OOAzi) 11'cll~ath: 1J-156L2 ~tiurce~v (~alcul:~tion \IcUnnl: Minimum Curvature I)h: Oracle \in ccc III) Intl ~iim ll I) ~~tillll \ti I~_/1V ~la~~A 1};i~~l: lnul ft dey deg ft ft ft ft ft ft 6679.35 88.93. 178.97 .3438.22 3329.22 -2521.99 -3032.46 5943359.73 555636.79 MWD+IFR-AK-CAZ-SC 6772.48 94.22 180.09 3435.66 3326.66 -2615.05 -3031.69 5943266.69 555638.28 MWD+IFR-AK-CAZ-SC 6867.40 88.96 176.18 3433.03 3324.03 -2709.83 -3028.60 5943171.94 555642.10 MWD+IFR-AK-CAZ-SC 6959.51 92.04 176.23 3432.23 3323.23 -2801.72 -3022.51 5943080.11 555648.91 MWD+IFR-AK-CAZ-SC 7051.53 92.02 176.02 3428.97 3319.97 -2893.48 -3016.29 5942988.42 555655.84 MWD+IFR-AK-CAZ-SC 7146.58 88.97 176.25 3428.15 3319.15 -2988.30 -3009.89 5942893.66 555662.99 -MWD+IFR-AK-CAZ-SC 7239.84 87.00 176.06 3431.42 3322.42 -3081.28 -3003.64 5942800.73 555669.96 MWD+IFR-AK-CAZ-SC 7332.46 88.82 181.87 3434.80 3325.80 -3173.78 -3001.97 5942708.26 555672.35 MWD+IFR-AK-CAZ-SC 7427.59 89.55 182.56 3436.16 3327.16 -3268.83 -3005.65 5942613.19 555669.41 MWD+IFR-AK-CAZ-SC 7521.18 90.17 182.84 3436.39 3327.39 -3362.32 -3010.06 5942519.68 555665.73 MWD+IFR-AK-CAZ-SC 7614.86 91.03 182.49 3435.41 3326.41 -3455.89 -3014.41 5942426.09 555662.11 MWD+IFR-AK-CAZ-SC 7708.51 91.84 180.84 3433.06 3324.06 -3549.47 -3017.13 5942332.50 555660.12 MWD+IFR-AK-CAZ-SC 7801.49 92.58 179.77 3429.47 3320.47 -3642.37 -3017.63 5942239.60 555660.34 MWD+IFR-AK-CAZ-SC 7894.20 92.02 178.44 3425.75 3316.75 -3735.00 -3016.18 5942147.01 555662.51 MWD+IFR-AK-CAZ-SC 7987.99 93.20 178.88 3421.48 3312.48 -3828.66 -3013.99 5942053.37 555665.43 MWD+IFR-AK-CAZ-SC 8082.05 93.07 178.16 3416.34 3307.34 -3922.55 -3011.56 5941959.51 555668.59 MWD+IFR-AK-CAZ-SC 8174.25 92.01 177.09 3412.25 3303.25 -4014.58 -3007.74 5941867.53 555673.12 MWD+IFR-AK-CAZ-SC 8262.32 91.46 176.43 3409.59 3300.59 -4102.46 -3002.77 5941779.69 555678.78 MWD+IFR-AK-CAZ-SC 8360.99 91.34 176.63 3407.18 3298.18 -4200.92 -2996.80 5941681.29 555685.52 MWD+IFR-AK-CAZ-SC 8454.76 91.77 178.43 3404.63 3295.63 -4294.57 -2992.76 5941587.69 555690.29 MWD+IFR-AK-CAZ-SC 8548.09 90.78 178.68 3402.55 3293.55 -4387.84 -2990.41 5941494.44 555693.37 MWD+IFR-AK-CAZ-SC 8640.85 91.53 179.01 3400.68 3291.68 -4480.56 -2988.54 5941401.75 555695.96 MWD+IFR-AK-CAZ-SC 8734.66 93.27 179.45 3396.76 3287.76 -4574.28 -2987.28 5941308.05 555697.95 MWD+IFR-AK-CAZ-SC 8827.42 90.65 177.28 3393.58 3284.58 -4666.93 -2984.63 5941215.43 555701.31 MWD+IFR-AK-CAZ-SC 8921.88 89.80 177.05 3393.21 3284.21 -4761.28 -2979.96 5941121.14 555706.72 MWD+IFR-AK-CAZ-SC 9013.66 90.04 178.34 3393.34 3284.34 -4852.98 -2976.27 5941029.47 555711.13 MWD+IFR-AK-CAZ-SC 9108.78 90.60 179.62 3392.81 3283.81 -4948.08 -2974.57 5940934.40 555713.56 MWD+IFR-AK-CAZ-SC 9202.57 92.96 182.31 3389.90 3280.90 -5041.80 -2976.15 5940840.68 555712.71 MWD+IFR-AK-CAZ-SC 9296.14 92.82 181.46 3385:18 3276.18 -5135.20 -2979.23 5940747.27 555710.37 MWD+IFR-AK-CAZ-SC 9389.06 91.83 180.42 3381.41 3272.41 -5228.03 -2980.75 5940654.44 555709.57 MWD+IFR-AK-CAZ-SC 9484.16 92.76 178.87 3377.60 3268.60 -5323.04 -2980.16 5940559.44 555710.89 MWD+IFR-AK-CAZ-SC 9575.77 91.46 177.93 3374.23 3265.23 -5414.55 -2977.60 5940467.96 555714.16 MWD+IFR-AK-CAZ-SC 9667.14 90.97. 177.02 3372.29 3263.29 -5505.81 -2973.58 5940376.74 555718.90 MWD+IFR-AK-CAZ-SC 9762.31 90.60 176.45 3370.99 3261.99 -5600.82 -2968.16 5940281.79 555725.06 MWD+IFR-AK-CAZ-SC 9855.95 91.28 178.02 3369.45 3260.45 -5694.33 -2963.64 5940188.32 555730.30 MWD+IFR-AK-CAZ-SC 9949.30 90.78 178.81 3367.77 3258.77 -5787.63 -2961.06 5940095.06 555733.61 MWD+IFR-AK-CAZ-SC 10043.78 91.28 181.07 3366.07 3257.07 -5882.09 -2960.96 5940000.61 555734.44 MWD+IFR-AK-CAZ-SC 10135.61 90.41 181.77 3364.72 3255.72 -5973.88 -2963.24 5939908.82 555732.88 MWD+IFR-AK-CAZ-SC 10229.57 89.92 180.05 3364.45 3255.45 -6067.82 -2964.73 5939814.87 555732.12 MWD+IFR-AK-CAZ-SC 10323.11 90.79 180.07 3363.87 3254.87 -6161.36 -2964.83 5939721.35 555732.75 MWD+IFR-AK-CAZ-SC 10416.20 91.84 182.49 3361.73 3252.73 -6254.40 -2966.91 5939628.31 555731.40 MWD+IFR-AK-CAZ-SC 10509.96 91.34 182.77 3359.13 3250.13 -6348.02 -2971.21 5939534.66 555727.83 MWD+IFR-AK-CAZ-SC 10603.25 91.71 181.37 3356.65 3247.65 -6441.21 -2974.58 5939441.45 555725.19 MWD+IFR-AK-CAZ-SC 10697.03 93.33 179.15 3352.52 3243.52 -6534.89 -2975.00 5939347.78 555725.49 MWD+IFR-AK-CAZ-SC 10791.11 92.26 175.82 3347.93 3238.93 -6628.76 -2970.88 5939253.96 555730.35 MWD+IFR-AK-CAZ-SC 10884.16 91.09 175.73 3345.21 3236.21 -6721.51 -2964.03 5939161.27 555737.92 MWD+IFR-AK-CAZ-SC 10977.56 91.59 176.55 3343.03 3234.03 -6814.67 -2957.74 5939068.17 555744.93 MWD+IFR-AK-CAZ-SC 11070.59 91.90 177.85 3340.20 3231.20 -6907.55 -2953.20 5938975.34 555750.20 MWD+IFR-AK-CAZ-SC 11160.84 90.40 177.19 3338.39 3229.39 -6997.69 -2949.29 5938885.24 555754.80 MWD+IFR-AK-CAZ-SC 11251.71 89.92 176.53 3338.13 3229.13 -7088.42 -2944.32 5938794.56 555760.48 MWD+IFR-AK-CAZ-SC 11342.91 89.99 178.08 3338.20 3229.20 -7179.52 -2940.03 5938703.51 555765.48 MWD+IFR-AK-CAZ-SC 11433.01 90.42 179.54 3337.88 3228.88 -7269.60 -2938.16 5938613.46 555768.05 MWD+IFR-AK-CAZ-SC 11524.82 90.23 180.81 3337.36 3228.36 -7361.40 -2938.44 5938521.66 555768.49 MWD+IFR-AK-CAZ-SC Halliburton Company Survey Report (~onip;w~: ConoroPhillipsAlaskalnc. Ih~tc: 219!2006 liroc : 103240 Parc: ~ Iiclil: Kuparuk P,iv er Unit (~~~- urJinatcl~l:) Rcli~rcuc~~: Well_ 'J-156. Tr ue North tiitc: Kuparuk 1J Pad ~~crf ical(l~l)~ Itc fcrcncc: 1J-156L2: 109.0 \1 ell: 1J-156 tiec~ iun ~~ti) Itcfc rcucc: WeII i0_CON.O OO E 120 OOAzi) Wcllp:Uh: 1J-156L2 5ur~c~ (~alcula[iu n ~Iciho~l: Minimum Curvat ure I)li: Oracle lien cc X111 lucl ~zini l~~ l) C~,, Il I) \ ti t';+\1 ~la~iA' ~1a~~F: find ft deg deg ft ft ft ft ft ft 11615.45 90.97 180.35 3336.41 3227.41 -7452.02 -2939.35 5938431.05 555768.28 MWD+IFR-AK-CAZ-SC 11706.01 90.35 179.96 3335.37 3226.37 -7542.58 -2939.60 5938340.50 555768.74 MWD+IFR-AK-CAZ-SC 11796.08 90.72 178.38 3334.53 3225.53 -7632.63 -2938.29 5938250.47 555770.74 MWD+IFR-AK-CAZ-SC 11886.91 90.47 177.83 3333.58 3224.58 -7723.41 -2935.29 5938159.73 555774.45 MWD+IFR-AK-CAZ-SC 11978.94 90.17 177.64. 3333.07 3224.07 -7815.36 -2931.65 5938067.81 555778.81 MWD+IFR-AK-CAZ-SC 12070.30 88.67 179.84 3334.00 3225.00 -7906.69 -2929.64 5937976.52 555781.53 MWD+IFR-AK-CAZ-SC 12158.56 89.41 183.02 3335.47 3226.47 -7994.90 -2931.85 5937888.30 555780.01 MWD+IFR-AK-CAZ-SC 12248.12 90.17 186.25 3335.80 3226.80 -8084.15 -2939.08 5937799.00 555773.47 MWD+IFR-AK-CAZ-SC 12340.53 89.79 185.95 3335.84 3226.84 -8176.04 -2948.90 5937707.05 555764.37 MWD+IFR-AK-CAZ-SC 12431.72 91.47 185.49 3334.83 3225.83 -8266.76 -2957.99 5937616.26 555755.99 MWD+IFR-AK-CAZ-SC 12521.84 92.40 185.29 3331.79 3222.79 -8356.43 -2966.45 5937526.54 555748.23 MWD+IFR-AK-CAZ-SC • 12566.00 92.40 185.29 3329.94 3220.94 -8400.37 -2970.52 5937482.58 ' 555744.50 • PROJECTED to TD • WELL LOG TRANSMITTAL • To: State of Alaska August 11, 2006 Alaska Oil and Gas Conservation Comm. Attn.: Librarian . 333 West 7t~' Avenue, Suite 100 Anchorage, Alaska RE: MWD Fornlation Evaluation Logs 1J-156, L1, Ll PBl & L2, AK-MW-4467716 1 LDWG formatted CD Rom with verification listing. API#: 50-029-23311-00, 60, 70, 61. PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry Drilling Services Attn: Rob Kalish 6900 Arctic Blvd. Anchorage, Alaska 99518 Date: Signed: _--~'"' " ~~,~ V AUG 2 ~ zoos & ~ Cons. Commission Anchorage 20~ -o~~-, ~oc~, - 06~~ ac,~ -o~,~ ~/yo3~S "~~, +~~ ~ ~ ice.` ~~! , ~ ~ , , ~ ~ ' ~ I - +~ ~ FRANK H. MURKOWSKI, GOVERNOR r DiI[1•.~7~ OII, A1~TD GAS 333 W. T" AVENUE, SUITE 100 CO~S~RQAiiO" CO~TISSIO~ ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 Randy Thomas FAx (so7) z7s-7sa2 Greater Kuparuk Area Drilling Team Leader ConocoPhillips Alaska, Inc. PO Box 100360 Anchorage, AK 99510-0360 Re: Kuparuk River Field, West Sak Oil Pool, 1J-156L2 ConocoPhillips Alaska, Inc. Permit No: 206-069 Surface Location: 2094' FSL, 2560' FEL, SEC. 35, Tl 1 N, R 10E, UM Bottomhole Location: 4252' FSL, 248' FEL, SEC. 10, T10N, R10E, UM Dear Mr. Thomas: Enclosed is the approved application for permit to drill the above referenced service well. This permit to drill does not exempt you from obtaining additional permits or an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. The permit is for a new wellbore segment of existing well KRU 1J-156, Permit No 206-067, API 50-029-23311-00. Injection should continue to be reported as a function of the original API number stated above. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907,~i59-3607 (pager). DATED this~day of June, 2006 cc: Department of Fish 8v Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. STATE OF ALASKA ~~~ ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 1 a. Type of Work: Drill Q Re-drill ^ Re-entry ^ 1 b. Current Well Class: Exploratory ^ Development Oil ^ Stratigraphic Test ^ Service ^~ Development Gas ^ Multiple Zone^ Single Zone ^ 1 a Specify if well is proposed for ` Coalbed Methane ^ Gas Hydrates ^ Shale Gas ^ 2. Operator Name: ConocoPhillips Alaska, Inc. 5. Bond: ~ Blanket Single Well Bond No. 59-52-180 11. Well Name and Number: 1J-156L2 3. Address: P.O. Box 100360 Anchorage, AK 99510-0360 6. Proposed Depth: MD: 12596' TVD: 3296' ~ 12. Field/Pool(s): Kuparuk River Field 4a. Location of Well (Governmental Section): Surface: 2094' FSL, 2560' FEL, Sec. 35, T11 N, R10E, UM 7. Property Designation: ADL 25660 & 25663 West Sak Oil Pool • Top of Productive Horizon: 656' FSL, 321' FEL, Sec. 34, T11 N, R10E, UM 8. Land Use Permit: ALK 470 & 472 13. Approximate Spud Date: 7/27/2006 Total Depth: 4252' FSL, 248' FEL, Sec. 10, T10N, R10E, UM 9. Acres in Property: 2560 14. Distance to Nearest Property: <1 mile to KRU 4b. Location of Well (State Base Plane Coordinates): Surface: x- 558649 y- 5945905 Zone- 4 10. KB Elevation (Height above GL): 28' RKB feet 15. Distance to Nearest Well within Pool: 1 J-152L2 , 1248' @ 73: 16. Deviated wells: Kickoff depth: 5625 ft. Maximum Hole Angle: 93.6° -deg 17. Maximum Anticipated Pressures in psig (see 20 AAC 25.035) Downhole: 1532 psig Surface: 1157 psig' 18. Casing Program ecif cations S Setting Depth Quantity of Cement Size i p Top Bottom c. f. or sacks Hole Casing Weight Grade Coupling Length MD ND MD ND (including stage data) 42" 20"x34" 94# K-55 Welded 80' 28' 28' 108' 108' 260 cf ArcticCrete 13.5" 10.75" 45.5# L-80 BTC 2768' 28' 28' 2791' 2168' 510 sx AS Lite, 180 sx DeepCRETE 9-7/8" 7.625" 29.7# L-80 BTCM 6835' 28' 28' 6863' 3628' 400 sx DeepCrete 6.75" 4.5" 11.6# L-80 BTC 6971' 5625' 3404' 12596' • 3296' ~ slotted liner 19 PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re-Entry Operations) Total Depth MD (ft): Total Depth TVD (ft): Plugs (measured) Effective Depth MD (ft): Effective Depth ND (ft): Junk (measured) Casing Length Size Cement Volume MD ND Conductor/Structural Surface Intermediate Production liner Perforation Depth MD (ft): ~ Perforation Depth TVD (ft): 20. Attachments: Filing Fee BOP ketch Drilling ProgramQ Time v. Depth Plot Shallow Hazard Analysis ~ Property Plat ^ Diverter Sketch ^ Seabed Report ^ Drilling Fluid Program Q 20 AAC 25.050 requirements ^~ 21. Verbal Approval: Commission Representative: Date: 22. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Mike Greener @ 263-4820 Printed Name Randy Thomas Title Greater Kuparuk Area Drilling Team Leader Signature ~ ~ Phone 'Z,b S- G$ 3 d Date ~l t Zrb 6 P r d har All D k Commission Use Only Permit to Drill Number: ~d ~, ~ r~69 API Number: 50-~Z~- l~J~ f ' ~ / Permit Approval Date: . ' See cover letter for other requirements Conditions of approval : If box is checked, well may not be used to explore for, test, or produce coalbed me hane, gas by , or gas contained in shales: ~~ ~-~ ~ ~`` i~ a t~v ~c ~C'~'P -~-~5-~ ~ Samples req'd: Yes ^ No ~ u log req'd: Yes ^ No [~ Other: y, ~a~ ~ ~ I•~S measures: Yes ecti svy req'd: Yes []~ No ^ ~1 w~Crt, R Z; ~~ rCA~ \ts~S ~ ~ C~CC~S~C@ '°'`j ~ ~ ~~ r APPROVED BY THE COMMISSION DATE: ~~ ~ 'O ,COMMISSIONER Form 10-401 Revised 12/2005 Sub"' m Duplicate ~~~~~~d~ /~ ~d~ Apple ion for Permit to Drill, Well 1 J-156 L2 Revision No.O Saved: 12-May-06 Permit It -West Sak Well #1J-156 L2 •~°~ r.~ i~ Application for Permit to Drill Document :~~. t~~c ~Il to d x i m i x g tMell +talue Table of Contents 1. Well Name ................................................................................................................. 2 Requirements of 20 AAC 25.005 (f) ....................................................................................................... 2 2. Location Summary ................................................................................................... 2 Requirements of 20 AAC 25.005(c)(2) ................................................................................................... 2 Requirements of 20 AAC 25.050(b) ....................................................................................................... 3 3. Blowout Prevention Equipment Information ......................................................... 3 Requirements of 20 AAC 25.005(c)(3) ................................................................................................... 3 4. Drilling Hazards Information ................................................................................... 3 Requirements of 20 AAC 25.005 (c)(4) .................................................................................................. 3 5. Procedure for Conducting Formation Integrity Tests ........................................... 3 Requirements of 20 AAC 25.005 (c)(5) .................................................................................................. 3 6. Casing and Cementing Program ............................................................................ 3 Requirements of 20 AAC 25.005(c)(6) ................................................................................................... 4 7. Diverter System Information ........................................Error! Bookmark not defined. Requirements of 20 AAC 25.005(c)(7) ................................................................................................... 4 8. Drilling Fluid Program ............................................................................................. 4 Requirements of 20 AAC 25.005(c) (8) ................................................................................................... 4 Lateral Mud Program (MI VersaPro Mineral Oil Base) ........................................................................... 4 9. Abnormally Pressured Formation Information ..................................................... 5 Requirements of 20 AAC 25.005 (c)(9) .................................................................................................. 5 10. Seismic Analysis ..................................................................................................... 5 Requirements of 20 AAC 25.005 (c)(10) ................................................................................................ 5 11. Seabed Condition Analysis ..................................................................................... 5 Requirements of 20 AAC 25.005 (c)(11) ................................................................................................ 5 12. Evidence of Bonding ............................................................................................... 5 Requirements of 20 AAC 25.005 (c)(12) ................................................................................................ 5 not done 1J-156L2 PERMIT IT Page 1 of 6 ~°~,,. l; Printed: 12-May-06 Application for Permit to Drill, Well 1J-156 L2 Revision No.O Saved: 12-May-06 13. Proposed Drilling Program ..................................................................................... 5 Requirements of 20 AAC 25.005 (c)(13) ..............................................................:................................. 5 14. Discussion of Mud and Cuttings Disposal and Annular Disposal ....................... 6 Requirements of 20 AAC 25.005 (c)(14) ................................................................................................ 6 15. Attachments ............................................................................................................. 6 Attachment 1 Directional Plan ................................................................................................................ 6 Attachment 2 Drilling Hazards Summary ............................................................................................... 6 Attachment 3 Well Schematic ................................................................................................................ 6 1. Well Name Requirements of 20 AAC 25.005 (i) Each well must be identified by a unique name designated by the operator and a unique API number assigned by the commission under 20 AAC 25.040(b). For a well with multiple well branches, each branch must similarly be identified by a unique name and API number by adding a suffix to the name designated for the well by the operator and to the number assigned to the well by the commission. The well for which this Application is submitted will be designated as 1J-156 L2. 2. Location Summary Requirements of 20 AAC 25.005(c)(2) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on frle with the commission and identified in the application: (2) a plat identifying the property and the property's owners and showing (A)the coordinates of the proposed location of the well at the surface, at the top of each objective formation, and at Iota! depth, referenced to governmental section lines. (8) the coordinates of the proposed location of the well at the surface, referenced to the state plane coordinate system for this state as maintained by the National Geodetic Survey in the National Oceanic and Atmospheric Administration; (C) the proposed depth of the well at the top of each objective formation and at total depth; Location at Surface 2,094' FSL, 2,560' FEL, Section 35, T11N, R10E ASP Zone 4 NAD 27 Coordinates RKB Elevation 109.0' AMSL Northings: 5,945,905 Eastings: 558,649 Pad Elevation 81.0' AMSL Location at Top of Productive Interval 656' FSL, 321' FEL, Section 34, T11N, R10E West Sak "D" Sand ASP Zone 4 NAD 27 Coordinates Measured De th, RKB: 5 625 Northings: 5,944,444 Eastings: 555,621 Total Vertical De th, RKB: 3 404 Total Vertical De th, SS: 3 295 Location at Total De th 4,252' FSL, 248' FEL, Section 10, T10N, R10E ASP Zone 4 NAD 27 Coordinates Measured De th, RKB: 12, 596 Northings: 5,937,482 Eastings: 555,755 Total Vertical De th, RKB: 3,296 Total Vertical De th, SS: 3,187 and (D) other information required by 20 AAC 25.050(b); not done 1J-156L2 PERMIT IT Page 2 of 6 Printed: 12-May-06 Applic"~fion for Permit to Drill, Well 1 J-156 L2 Revision No.0 Saved: 12-May-06 Requirements of 20 AAC 25.O5O(b) If a well is to be intentionally deviated, the application for a Permit to Drill (Form i0-401) must (1) include a plat, drawn to a suitable scale, showing the path of the proposed wellbore, including all adjacent wellbores within 200 feet of any portion of the proposed well; Please see Attachment 1: Directional Plan iJ-156L2 and (2) for all wells within 200 feet of the proposed wellbore (A) list the names of the operators of those wells, to the extent that those names are known or discoverable in public records, and show that each named operator has been furnished a copy of the application by certified mail; or (8) state that the applicant is the only affected owner. The Applicant is the only affected owner. 3. Blowout Prevention Equipment Information Requirements of 20 AAC 25.OO5(c)(3) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (3) a diagram and description of the blowout prevention equipment (ROPE) as required by 20 AAC 25.035, 20 AAC 25.036, or 20 AAC 25.037, as applicable; An API 13-5/8" x 5,000 psi BOP stack (RSRRA) will be utilized to drill and complete the well. Please see information on Doyon 141 blowout prevention equipment placed on file with the Commission. 4. Drilling Hazards Information Requirements of 20 AAC 25.005 (c)(4) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (4) information on drilling hazards, including (A) the maximum downhole pressure that maybe encountered, criteria used to determine it, and maximum potential surface pressure based on a methane gradient; The expected reservoir pressures in the West Sak sands in the iJ area are 0.45 psi/ft, or 8.7 ppg EMW (equivalent mud weight). Pressures are predicted based on the undisturbed West Sak pressure gradient. The maximum potential surface pressure (MPSP) based on the above maximum pressure gradient, a methane gradient (0.11), and the deepest planned vertical depth of the West Sak "D" sand formation is 1,157 psi, calculated thusly: MPSP = (3,404 ft TVD)(0.45 - 0.11 psi/ft) = 1,157 psi (8) data on potential gas zones; The well bore is not expected to penetrate any gas zones.. and (C) data concerning potential causes of hole problems such as abnormally geo-pressured strata, lost circulation zones, and zones that have a propensity for differential sticking; Please see Attachment 2: 1J-156L2 Drilling Hazards Summary. 5. Procedure for Conducting Formation Integrity Tests Requirements of 20 AAC 25.005 (c)(5) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (5) a description of the procedure for conducting formation integrity tests, as required under 20 AAC 25.030(f); The parent wellbore, 1J-156, will be completed with 7-5/8" intermediate casing landed in the West Sak A- Sand. The casing shoe will be drilled out and a formation integrity test will be performed in accordance with the "Formation Integrity Test Procedure" that ConocoPhillips Alaska placed on file with the Commission. not done 1J-156L2 PERMIT IT Page 3 of 6 ®~ ~ ~ ~ ~ ~~ Printed: 12-May-06 Apple ion for Permit to Drill, Well 1J-156 L2 Revision No.O Saved: 12-May-06 6. Casing and Cementing Program Requirements of 20 AAC 25.005(c)(6) An application for a Permit to Dri//must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (6) a complete proposed casing and cementing program as required by 20 AAC 25.030, and a description of any slotted liner, pre- perforated liner, or screen to be installed; Casing and Cementing Program See also Attachment 3: Cement Summary Hole Top Btm Csg/Tbg Size Weigh Length MDlrVD MD/TVD OD in (in t Ib/ft) Grade Connection ft) ft) ft Cement Pro ram 20 x 34 4z 94 K55 Welded 80 28 / 28 108 / 108 Cemented to surface with 260 cf ArcticCRETE BTC Cemented to Surface with 10-3/4 13-1/2 45.5 L-80 special 2,791 28 / 28 2,791 /2,168 510 sx ASLite Lead, drift 180 sx DeepCRETE Tail Cement Top planned 7-5/8 9-7/8 29.7 L-80 BTCM 6 863 28 / 28 6,863 / 3,628 3,650' MD / 2,592' TVD. , Cemented w/ 400 sx DeepCRETE 4-1/2 6-3/4" A Sand 11.6 L-80 BTC 2,265 6,052 / 3,500 8,317 / 3,637 Slotted- no cement slotted Lateral (1J-156) 4-1/2 6-3/4" l3 Sand 6 L- 7,042 5 9 476 12,994 / 3,368 Slotted- no cement - 6 Ll) 4-1/2 6-3/4" D Sand 11.6 L-80 BTC 6,971 5,625 / 3,404 12,596 / 3,296 Slotted- no cement slotted Lateral (iJ-156 L2) Diverter System Information Requirements of 20 AAC 25.005(c)(7) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (7) a diagram and description of the diverter system as required by 20 AAC 25.035, unless this requirement is waived by the commission under 20 AAC Z5.035(h)(2); No diverter system will be utilized during operations on 1J-156 L2. 8. Drilling Fluid Program Requirements of 20 AAC 25.005(c)(8) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (8) a drilling fluid program, including a diagram and description of the drilling fluid system, as required by 20 AAC 25.033; Drilling will be done with mud having the following properties over the listed intervals: Lateral Mud Program (MI VersaPro, Mineral Oil Base) Value Densit ( g) 8.8 Plastic Viscostiy 15 - 25 (Ib/100 sf) Yield Point 18 - 28 (cP) HTHP Fluid loss (ml/30 min @ <4.0 200 si & 150° ORIGIn!A! not done 1J-156L2 PERMIT IT Page 4 of 6 Printed: 12-May-O6 Appli~'dfion for Permit to Drill, Well 1 J-156 L2 Revision No.O Saved: 12-May-06 Oil /Water Ratio 70 / 30 Electrical Stabilit 650-900 Drilling fluid practices will be in accordance with appropriate regulations stated in 20 AAC 25.033. Please see information on file with the Commission for diagrams and descriptions of the fluid system of Doyon Rig 141. 9. Abnormally Pressured Formation Information Requirements of 20 AAC 25.005 (c)(9) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (9) for an exploratory or stratigraphic test well, a tabulation setting out the depths of predicted abnormally geo-pressured strata as required by 20 AAC 25.033(f); Not applicable: Application is not for an exploratory or stratigraphic test well. 10. Seismic Analysis Requirements of 20 AAC 25.005 (c)(10) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (10) for an exploratory or stratigraphic test well, a seismic refraction or reflection analysis as required by 20 AAC 25.061(a); Not applicable: Application is not for an exploratory or stratigraphic test well. 11. Seabed Condition Analysis Requirements of 20 AAC 25.005 (c)(11) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (11) for a well drilled from an offshore platform, mobile bottom-founded structure, jack-up rig, or floating drilling vessel, an analysis of seabed conditions as required by 20 AAC 25.061(b); Not applicable: Application is not for an offshore well. 12. Evidence of Bonding Requirements of 20 AAC 25.005 (c)(12) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (i2) evidence showing that the requirements of 20 AAC 25.025 {Bonding}have been met; Evidence of bonding for ConocoPhillips Alaska, Inc. is on file with the Commission. 13. Proposed Drilling Program Requirements of 20 AAC 25.005 (c)(13) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: The proposed drilling program is listed below. Please refer also to Attachment 3, Well Schematic. Note: Previous operations are covered under the 1J-156 Application for Permit to Drill. 1. Run and set Baker WindowMaster whipstock system, at window point of +/- 5,625' MD / 3,404' TVD, the top of the top of the D sand. 2. Mill 6-3/4" window. POOH. 3. Pick up 6-3/4"drilling assembly with LWD and MWD and PWD. RIH. 4. Drill to TD of D sand lateral at +/- 12,596' MD / 3,296' TVD, as per directional plan. 5. POOH, back reaming out of lateral to window. TIH to bottom & displace to solids-free oil based mud. POOH on elevators. 6. RIH with whipstock retrieval tool. Retrieve whipstock and POOH. not done 1J-156L2 PERMIT IT ,; fi~~ ~ ~ Page 5 of 6 ~<~ ~ ~ ~ 4 ~ #~ ~ Printed: 12-May-O6 AppIi~2Tion for Permit to Drill, Well 1 J-156 L2 Revision No.O Saved: 12-May-06 7. PU and run 4-1/2" slotted liner. 8. RIH, until liner hanger is just above window. Orient hanger to window and land hanger. 9. Release hanger running tool. POOH. 10. Make up junction isolation / re-entry assembly (Lateral Entry Module or LEM) and RIH to depth. Orient and set packer atop assembly and release from assembly. li. POOH, laying down drill pipe as required. 12. PU injection completion as required and RIH to depth. Land tubing. Set BPV. 13. Nipple down ROPE, nipple up tree and test. Pull BPV. 14. Freeze protect well with diesel. 15. Set BPV and move rig off. 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 file with the commission and identified in the application: (14) a general description of how the operator plans to dispose of drilling mud and cuttings and a statement of whether the operator intends to request authorization under 20 AAC 25.080 for an annular disposal operation in the well.; Waste fluids generated during the drilling process will be disposed of either by pumping authorized fluids into a permitted annulus on 1J Pad, or by hauling the fluids to a KRU Class II disposal well. All cuttings generated will be disposed of either down a permitted annulus on 1J Pad, hauled to the Prudhoe Bay Grind and Inject Facility for temporary storage and eventual processing for injection down an approved disposal well, or stored, tested for hazardous substances, and (if free of hazardous substances) used on pads and roads in the Kuparuk area in accordance with a permit from the State of Alaska. ConocoPhillips Alaska may in the future request authorization for the use of this well for annular disposal operations. 15. Attachments Attachment 1 Directional Plan Attachment 2 Drilling Hazards Summary Attachment 3 Well Schematic not done 1J-156L2 PERMIT IT Page 6 of 6 [~ 1 ~ ~ Printed: 12-May-O6 ConocoPhillips ~~~ ConocoPhillips Alaska (Kuparuk) Kuparuk River Unit Kuparuk 1J Pad Plan 1J-156 -Slot 1J-156 1 J-156 L2 Plan: 1J-156 L2 (wp05) Proposal Report 14 April, 2006 ~A: Sperry Drilling Services ~R~~ .~ N N N C " Q. O O O f/1 N r 1~ ~ ~ 3 ~ e O O ~ ~ - -------------- v ~ ~ ~ ~ ~ )a a- ~ E. MmN _ IA ~ Q ZN~t~O ~ ~ ~ ~ N ~ ~ ~_ M {Y ~C O v o O 'n ro w po~nu~o O ~omvo (, O r ~fl Ip ° c ~ ~ y~ j ~ Q O Z O~OINO/ ~ O ~~~ N N~f1` U ~ ' ; ~ Yl u o ~ -_-- _ ~ ao 0000 M O O O M ~o dv c p f ~y J a ~ ~ t 0~ N N M M ~ ~ ~ ~ ' O O O Z r N M ~ N ~ ~ - ~~ ` ~ a t0 I~ J ~ 3 N J J b N O ------- N O a 3 m - r- O 0 u~ co N J ~O ~g+ ry O O D ~ O o ~ °' 3 ,~ M °' --- - - - - - ~ `~ u~ C ~ 'a ;~ J G a tO ~ C ~ ~~" C ,~ c - ~ ° j u i - a o. 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L ~ `~~ ~ O Z ~~ `~~~, s n 79° ~~~, 1J-156 (wp05) 8317ft MD c 1J-156 LZ T4 (wp05 79° CASING DETAILS _ _ _ _ 1J-156 L2 TS (wp05 No TVD MD Name Size 1 80.00 80.00 20" 20 2 2168.00 2791.96 10 3/4" 10-3/4 79° 3 3404.00 5625.45 7 5/8" 7-5/8 4 3296.33 12596.00 4 1 /2" 4-1 /2 HALLIBURTON Sperry Drillir`ag Servieea --' ConocoPhillips Alaska Project: Kuparuk River lv;~. Site: Kuparuk 1J Pad Well: Plan 1J-156 We(Ibore: 1J-156 L2 Plan: 1J-156 L2 (wp05) - _ 1J-156 L2 T6 (wp05 1J-1ss L2 n (wpo5 181 ° 1J-156 L2 TS Toe (wp05 L2 : BHL ~ 12596ft MD, 3296ft TVD - 4 1/2' 1J-156 L1 (wp05) ~ 12995ft M -1000 -500 0 (1000 ft/in) -5000 -4500 -4000 -3500 -3000 T ~.~imuths to True North Magnetic North: 24.04° Magnetic Field Strength: 57564.2nT Dip Angle: 80.77° Date: 6/30!2006 Model: BGGM2005 500 1000 1500 2000 • Carx~ccP~i[t~ps Alaska Database: EDM 2003.11 Single User Db Company: ConocoPhiilips Alaska (Kuparuk) Project: Kuparuk River Unit Site: Kuparuk 1J Pad Well: Plan 1J-156 Wellbore: 1J-156 L2 Design: 1J-156 L2 (wp05) • Halliburton Energy Services HAi,~I<.tBUF"ET't]N Planning Report -Geographic ~ -~~~ ~~ ~~ ~ Local Co-ordinate Reference: Well Plan 1J-156 - Slot iJ-156 TVD Reference: Planning RKB @ 109.OOft (Doyon 141 (28+81)) MD Reference: Planning RKB @ 109.OOft (Doyon 141 (28+81)) North Reference: True Survey Calculation Method: Minimum Curvature Project Kuparuk River Unit, North Slope Alaska, United States Map System: US State Plane 1927 (Exact solution) System Datum: Mean Sea Level Geo Datum: NAD 1927 (NADCON CONUS) Using Well Reference Point Map Zone: Alaska Zone 04 Using geodetic scale factor Well Plan 1 J-156 -Slot 1 J-156 Well Position +N/-S 0.00 ft Northing: 5,945,905.10 ft Latitude: 70° 15' 46.125" N +E/-W 0.00 ft Easting: 558,649.10 ft Longitude: 149° 31' 33.109" W Position Uncertainty 0.00 ft Wellhead Elevation: ft Ground Level: 81.OOft Wellbore 1J-156 L2 Magnetics Model Name Sample Date Declination Dip Angle Field Strength BGGM2005 2/9/2006 24.1848 80.7685 57,563 Design 1J-156 L2 (wp05) Audit Notes: Version: Phase: PLAN Tie On Depth: 5,625.44 Vertical Section: Depth From (TVD) +N/-S +E/-W Direction (ft) (ft) (ft) (°) 28.00 0.00 0.00 180.00 4/14/2006 11;18:55AM Page 2 of 8 COMPASS 2003.11 Build 50 ~~~~~z~~~.~ • ~` ' " Halliburton Energy Services ~A~~lBUatT~ru CQ! 1000 ~ 1l~~1p5 Planning Report -Geographic -----~_ _. ___..___ Alas4Ca Sperry Drilling Services Database: EDM 2003.11 Single User Db Local Co-ordinate Reference: Well Plan 1J-156 -Slot 1J-156 Company: ConocoPhillips Alaska (Kuparuk) TVD Reference: Planning RKB @ 109.OOft (Doyon 141 (28+81 )) Project: Kuparuk River Unit MD Reference: Planning RKB @ 109.OOft (Doyon 141 (28+81)) Site: Kuparuk 1J Pad North Reference: True Well: Plan 1J-156 Survey Calculation Method: Minimum Curvature Wellbore: 1 J-156 L2 Design: 1J-156 L2 (wp05) Plan Summary Measured Vertical Dogleg Build Turn Depth Inclination Azimuth Depth +N/-S +E/-W Rate Rate Rate TFO (ft) (°) (°) (ft) (ft) (ft) (°/100ft) (°/100ft) (°/100ft) (°) 5,625.44 77.00 179.30 3,404.00 -1,437.60 -3,039.68 0.00 0.00 0.00 0.0000 5,637.44 78.91 179.30 3,406.50 -1,449.34 -3,039.54 15.90 15.90 0.00 0.0000 5,667.44 78.91 179.30 3,412.28 -1,478.78 -3,039.18 0.00 0.00 0.00 0.0000 5,867.57 90.92 179.30 3,429.99 -1,677.74 -3,036.75 6.00 6.00 0.00 0.0000 5,912.99 93.64 179.48 3,428.19 -1,723.12 -3,036.26 6.00 5.99 0.39 3.7064 6,182.52 93.64 179.48 3,411.10 -1,992.09 -3,033.80 0.00 0.00 0.00 0.0000 6,228.39 90.90 179.17 3,409.28 -2,037.92 -3,033.26 6.00 -5.96 -0.67 -173.6061 6,628.39 90.90 179.17 3,403.00 -2,437.83 -3,027.47 0.00 0.00 0.00 0.0000 6,728.39 90.90 179.17 3,401.43 -2,537.81 -3,026.02 0.00 0.00 0.00 0.0000 6,841.98 85.22 179.23 3,405.27 -2,651.27 -3,024.44 5.00 -5.00 0.05 179.3883 7,243.72 85.22 179.23 3,438.74 -3,051.58 -3,019.06 0.00 0.00 0.00 0.0000 7,380.51 92.06 179.30 3,441.99 -3,188.24 -3,017.31 5.00 5.00 0.05 0.5812 7,630.51 92.06 179.30 3,433.00 -3,438.06 -3,014.26 0.00 0.00 0.00 0.0000 7,636.09 91.95 179.30 3,432.80 -3,443.64 -3,014.19 2.00 -2.00 -0.01 -179.6818 8,630.39 91.95 179.30 3,399.00 -4,437.28 -3,002.04 0.00 0.00 0.00 0.0000 8,674.46 91.07 179.24 3,397.84 -4,481.33 -3,001.48 2.00 -2.00 -0.13 -176.2677 9,630.88 91.07 179.24 3,380.00 -5,437.51 -2,988.83 0.00 0.00 0.00 0.0000 9,687.93 92.21 179.30 3,378.37 -5,494.52 -2,988.10 2.00 2.00 0.11 3.0254 10,631.91 92.21 179.30 3,342.00 -6,437.73 -2,976.62 0.00 0.00 0.00 0.0000 10,656.90 91.71 179.24 3,341.15 -6,462.71 -2,976.30 2.00 -1.99 -0.24 -173.1410 11,632.67 91.71 179.24 3,312.00 -7,437.96 -2,963.40 0.00 0.00 0.00 0.0000 11,673.27 90.90 179.31 3,311.07 -7,478.54 -2,962.89 2.00 -1.99 0.16 175.2898 12,185.91 90.90 179.31 3,303.00 -7,991.08 -2,956.71 0.00 0.00 0.00 0.0000 12,247.38 90.93 180.54 3,302.01 -8,052.55 -2,956.63 2.00 0.05 2.00 88.5049 12,596.01 90.93 180.54 3,296.33 -8,401.11 -2,959.91 0.00 0.00 0.00 0.0000 4/14/2006 11:18:55AM Page 3 of 8 COMPASS 2003.11 Build 50 • ~-' Halliburton Energy Services ~~~L~~~~~-(per CC)tIOCQ PII[II[~?S Planning Report -Geographic -----_- Alaska SPerrY 1~lniiling Servie~s Database: EDM 2003.11 Single User Db Local Co-ordinate Reference: Well Plan 1J-156 -Slot 1J-156 Company: ConocoPhllips Alaska (Kuparuk) TVD Reference: Planning RKB @ 109.OOft (Doyon 141 (28+81 )) Project: Kuparuk River Unit MD Reference: Planning RKB @ 109.OOft (Doyon 141 (28+81 )) Site: Kuparuk 1J Pad North Reference: True Well: Plan 1J-156 Survey Calculation Method: Minimum Curvature Wellbore: 1J-156 L2 Design: 1 J-156 L2 (wp05) Planned Survey 1J-156 L2 (wp05) Map Map MD Inclination Azimuth TVD SSTVD +N/-S +E/-W Northing Easting DLSEV Vert Section (ft) (°) (°) (ft) (ftl (ft) lftl lft) (ftl (°l100ft) lft) 5,625.44 77.00 179.30 3,404.00 3,295.00 -1,437.60 -3,039.68 5,944,444.00 555,621.00 0.00 1,437.60 L2 : Top of 7 5/8" Window, 5625ft MD, 3404ft TVD - 656ft FS L & 321ft FEL -Sec 34 - T11N - R 10 E - 7 5/8" -1J-156 L2 DD Poly (wp05) 5,637.44 78.91 179.30 3,406.50 3,297.50 -1,449.34 -3,039.54 5,944,432.27 555,621.23 15.90 1,449.34 L2 : Bttm of Window - 5637ft MD, 3407ft TVD 5,667.44 78.91 179.30 3,412.28 3,303.28 -1,478.78 -3,039.18 5,944,402.84 555,621.82 0.00 1,478.78 L2 : End 30' Rathole -Begin Build @ 6°/100ft to 93.6°, 5667ft MD, 3412ft TVD 5,700.00 80.86 179.30 3,417.99 3,308.99 -1,510.83 -3,038.79 5,944,370.80 555,622.46 6.00 1,510.83 5,800.00 86.86 179.30 3,428.68 3,319.68 -1,610.20 -3,037.57 5,944,271.45 555,624.45 6.00 1,610.20 5,867.57 90.92 179.30 3,429.99 3,320.99 -1,677.74 -3,036.75 5,944,203.92 555,625.80 6.00 1,677.74 5,900.00 92.86 179.43 3,428.92 3,319.92 -1,710.15 -3,036.39 5,944,171.52 555,626.42 6.00 1,710.15 5,912.99 93.64 179.48 3,428.19 3,319.19 -1,723.12 -3,036.26 5,944,158.55 555,626.64 6.01 1,723.12 L2 : Continue Geosteer in D-Sand , 5913ft MD, 3428ft TVD 6,000.00 93.64 179.48 3,422.67 3,313.67 -1,809.95 -3,035.47 5,944,071.74 555,628.11 0.00 1,809.95 6,100.00 93.64 179.48 3,416.33 3,307.33 -1,909.74 -3,034.56 5,943,971.97 555,629.80 0.00 1,909.74 6,182.52 93.64 179.48 3,411.10 3,302.10 -1,992.09 -3,033.80 5,943,889.64 555,631.19 0.00 1,992.09 6,200.00 92.59 179.36 3,410.15 3,301.15 -2,009.54 -3,033.63 5,943,872.18 555,631.51 5.99 2,009.54 6,228.39 90.90 179.17 3,409.28 3,300.28 -2,037.92 -3,033.26 5,943,843.81 555,632.09 6.01 2,037.92 6,300.00 90.90 179.17 3,408.16 3,299.16 -2,109.51 -3,032.23 5,943,772.24 555,633.69 0.00 2,109.51 6,400.00 90.90 179.17 3,406.59 3,297.59 -2,209.49 -3,030.78 5,943,672.29 555,635.91 0.00 2,209.49 6,500.00 90.90 179.17 3,405.02 3,296.02 -2,309.47 -3,029.33 5,943,572.33 555,638.14 0.00 2,309.47 6,600.00 90.90 179.17 3,403.45 3,294.45 -2,409.44 -3,027.88 5,943,472.38 555,640.37 0.00 2,409.44 6,628.39 90.90 179.17 3,403.00 3,294.00 -2,437.83 -3,027.47 5,943,444.00 555,641.00 0.00 2,437.83 1J-156 L2 T1 (wp05) 6,700.00 90.90 179.17 3,401.88 3,292.88 -2,509.42 -3,026.43 5,943,372.43 555,642.59 0.00 2,509.42 6,728.39 90.90 179.17 3,401.43 3,292.43 -2,537.81 -3,026.02 5,943,344.05 555,643.23 0.00 2,537.81 6,800.00 87.32 179.21 3,402.54 3,293.54 -2,609.39 -3,025.01 5,943,272.48 555,644.80 5.00 2,609.39 6,841.98 85.22 179.23 3,405.27 3,296.27 -2,651.27 -3,024.44 5,943,230.61 555,645.69 5.00 2,651.27 6,900.00 85.22 179.23 3,410.11 3,301.11 -2,709.08 -3,023.66 5,943,172.81 555,646.92 0.00 2,709.08 7,000.00 85.22 179.23 3,418.44 3,309.44 -2,808.73 -3,022.32 5,943,073.19 555,649.03 0.00 2,808.73 7,100.00 85.22 179.23 3,426.77 3,317.77 -2,908.37 -3,020.99 5,942,973.57 555,651.15 0.00 2,908.37 7,200.00 85.22 179.23 3,435.10 3,326.10 -3,008.01 -3,019.65 5,942,873.95 555,653.26 0.00 3,008.01 7,243.72 85.22 179.23 3,438.74 3,329.74 -3,051.58 -3,019.06 5,942,830.39 555,654.19 0.00 3,051.58 7,300.00 88.03 179.26 3,442.05 3,333.05 -3,107.75 -3,018.32 5,942,774.23 555,655.36 5.00 3,107.75 7,380.51 92.06 179.30 3,441.99 3,332.99 -3,188.24 -3,017.31 5,942,693.76 555,657.00 5.00 3,188.24 7,400.00 92.06 179.30 3,441.29 3,332.29 -3,207.71 -3,017.07 5,942,674.29 555,657.39 0.00 3,207.71 7,500.00 92.06 179.30 3,437.69 3,328.69 -3,307.64 -3,015.85 5,942,574.39 555,659.39 0.00 3,307.64 7,600.00 92.06 179.30 3,434.10 3,325.10 -3,407.57 -3,014.63 5,942,474.48 555,661.39 0.00 3,407.57 7,630.51 92.06 179.30 3,433.00 3,324.00 -3,438.06 -3,014.26 5,942,444.00 555,662.00 0.00 3,438.06 1J-156 L2 T2 (wp05) 7,636.09 91.95 179.30 3,432.80 3,323.80 -3,443.64 -3,014.19 5,942,438.42 555,662.11 2.00 3,443.64 7,700.00 91.95 179.30 3,430.63 3,321.63 -3,507.50 -3,013.41 5,942,374.57 555,663.39 0.00 3,507.50 7,800.00 91.95 179.30 3,427.23 3,318.23 -3,607.44 -3,012.19 5,942,274.66 555,665.39 0.00 .3,607.44 7,900.00 91.95 179.30 3,423.83 3,314.83 -3,707.37 -3,010.96 5,942,174.75 555,667.39 0.00 3,707.37 8,000.00 91.95 179.30 3,420.43 3,311.43 -3,807.31 -3,009.74 5,942,074.83 555,669.39 0.00 3,807.31 8,100.00 91.95 179.30 3,417.03 3,308.03 -3,907.24 -3,008.52 5,941,974.92 555,671.39 0.00 3,907.24 8,200.00 91.95 179.30 3,413.63 3,304.63 -4,007.18 -3,007.30 5,941,875.01 555,673.39 0.00 4,007.18 8,300.00 91.95 179.30 3,410.23 3,301.23 -4,107.11 -3,006.08 5,941,775.10 555,675.39 0.00 4,107.11 4/14/2006 11:18:55AM ~ a e 4 f 8 COMPASS 2003.11 Build 50 ~# ~~ ~--' Halliburton Energy Services ~s,zL~guATt~IVt ~f?t1aC0 ~1i~~1~?S Planning Report -Geographic _-- -_~--~~~ Alaska Spent' 1.lciilin~g Serirvtces Database: EDM 2003.11 Single User Db Local Co-ordinate Reference: Well Plan 1J-156 -Slot 1J-156 Company: ConocoPhillips Alaska (Kuparuk) TVD Reference: Planning RKB @ 109.OOft (Doyon 141 (28+81)) Project: Kuparuk River Unit MD Reference: Planning RKB @ 109.OOft (Doyon 141 (28+81)) Site: Kuparuk 1J Pad North Reference: True Well: Plan 1J-156 Survey Calculation Method: Minimum Curvature Wellbore: 1J-156 L2 Design: 1J-156 L2 (wp05) Planned Survey 1J-156 L2 (wp05) Map Map MD Inclination Azimuth TVD SSTVD +N/-S +E/-W Northing Easting DLSEV Vert Section (ft) (°) 1°) (ft) (ft) lft) (ft) lft) (ft) (°1100ft) (ft) 8,400.00 91.95 179.30 3,406.83 3,297.83 -4,207.04 -3,004.85 5,941,675.18 555,677.39 0.00 4,207.04 8,500.00 91.95 179.30 3,403.43 3,294.43 -4,306.98 -3,003.63 5,941,575.27 555,679.39 0.00 4,306.98 8,600.00 91.95 179.30 3,400.03 3,291.03 -4,406.91 -3,002.41 5,941,475.36 555,681.39 0.00 4,406.91 8,630.39 91.95 179.30 3,399.00 3,290.00 -4,437.28 -3,002.04 5,941,445.00 555,682.00 0.00 4,437.28 1J-156 L2 T3 (wp05) 8,674.46 91.07 179.24 3,397.84 3,288.84 -4,481.33 -3,001.48 5,941,400.96 555,682.90 2.00 4,481.33 8,700.00 91.07 179.24 3,397.36 3,288.36 -4,506.87 -3,001.14 5,941,375.43 555;683.44 0.00 4,506.87 8,800.00 91.07 179.24 3,395.50 3,286.50 -4,606.84 -2,999.82 5,941,275.48 555,685.54 0.00 4,606.84 8,900.00 91.07 179.24 3,393.63 3,284.63 -4,706.82 -2,998.49 5,941,175.53 555,687.64 0.00 4,706.82 9,000.00 91.07 179.24 3,391.77 3,282.77 -4,806.79 -2,997.17 5,941,075.57 555,689.74 0.00 4,806.79 9,100.00 91.07 179.24 3,389.90 3,280.90 -4,906.76 -2,995.85 5,940,975.62 555,691.85 0.00 4,906.76 9,200.00 91.07 179.24 3,388.04 3,279.04 -5,006.74 -2,994.53 5,940,875.67 555,693.95 0.00 5,006.74 9,300.00 91.07 179.24 3,386..17 3,277.17 -5,106.71 -2,993.20 5,940,775.72 555,696.05 0.00 5,106.71 9,400.00 91.07 179.24 3,384.31 3,275.31 -5,206.69 -2,991.88 5,940,675.77 555,698.15 0.00 5,206.69 9,500.00 91.07 179.24 3,382.44 3,273.44 -5,306.66 -2,990.56 5,940,575.82 555,700.25 0.00 5,306.66 9,600.00 91.07 179.24 3,380.58 3,271.58 -5,406.63 -2,989.24 5,940,475.87 555,702.35 0.00 5,406.63 9,630.88 91.07 179.24 3,380.00 3,271.00 -5,437.51 -2,988.83 5,940,445.00 555,703.00 0.00 5,437.51 1J-156 L2 T4 (wp05) 9,687.93 92.21 179.30 3,378.37 3,269.37 -5,494.52 -2,988.10 5,940,388.00 555,704.17 2.00 5,494.52 9,700.00 92.21 179.30 3,377.90 3,268.90 -5,506.59 -2,987.96 5,940,375.94 555,704.41 0.00 5,506.59 9,800.00 92.21 179.30 3,374.05 3,265.05 -5,606.50 -2,986.74 5,940,276.04 555,706.40 0.00 5,606.50 9,900.00 92.21 179.30 3,370.20 3,261.20 -5,706.42 -2,985.52 5,940,176.15 555,708.40 0.00 5,706.42 10,000.00 92.21 179.30 3,366.35 3,257.35 -5,806.34 -2,984.31 5,940,076.25 555,710.39 0.00 5,806.34 10,100.00 92.21 179.30 3,362.49 3,253.49 -5,906.26 -2,983.09 5,939,976.35 555,712.39 0.00 5,906.26 10,200.00 92.21 179.30 3,358.64 3,249.64 -6,006.18 -2,981.87 5,939,876.46 555,714.38 0.00 6,006.18 10,300.00 92.21 179.30 3,354.79 3,245.79 -6,106.10 -2,980.65 5,939,776.56 555,716.38 0.00 6,106.10 10,400.00 92.21 179.30 3,350.93 3,241.93 -6,206.01 -2,979.44 5,939,676.66 555,718.37 0.00 6,206.01 10,500.00 92.21 179.30 3,347.08. 3,238.08 -6,305.93 -2,978.22 5,939,576.77 555,720.37 0.00 6,305.93 10,600.00 92.21 179.30 3,343.23 3,234.23 -6,405.85 -2,977.00 5,939,476.87 555,722.36 0.00 6,405.85 10,631.91 92.21 179.30 3,342.00 3,233.00 -6,437.73 -2,976.62 5,939,445.00 555,723.00 0.00 6,437.73 1J-156 L2 TS (wp05) 10,656.90 91.71 179.24 3,341.15 3,232.15 -6,462.71 -2,976.30 5,939,420.02 555,723.51 2.00 6,462.71 10,700.00 91.71 179.24 3,339.86 3,230.86 -6,505.79 -2,975.73 5,939,376.96 555,724.42 0.00 6,505.79 10,800.00 91.71 179.24 3,336.87 3,227.87 -6,605.73 -2,974.41 5,939,277.04 555,726.52 0.00 6,605.73 10,900.00 91.71 179.24 3,333.88 3,224.88 -6,705.68 -2,973.09 5,939,177.11 555,728.62 0.00 6,705.68 11,000.00 91.71 179.24 3,330.90 3,221.90 -6,805.63 -2,971.76 5,939,077.19 555,730.72 0.00 6,805.63 11,100.00 91.71 179.24 3,327.91 3,218.91 -6,905.57 -2,970.44 5,938,977.27 555,732.82 0.00 6,905.57 11,200.00 91.71 179.24 3,324.92 3,215.92 -7,005.52 -2,969.12 5,938,877.34 555,734.92 0.00 7,005.52 11,300.00 91.71 179.24 3,321.94 3,212.94 -7,105.47 -2,967.80 5,938,777.42 555,737.01 0.00 7,105.47 11,400.00 91.71 179.24 3,318.95 3,209.95 -7,205.41 -2,966.48 5,938,677.49 555,739.11 0.00 7,205.41 11,500.00 91.71 179.24 3,315.96 3,206.96 -7,305.36 -2,965.16 5,938,577.57 555,741.21 0.00 7,305.36 11,600.00 91.71 179.24 3,312.98 3,203.98 -7,405.31 -2,963.84 5,938,477.65 555,743.31 0.00 7,405.31 11,632.67 91.71 179.24 3,312.00 3,203.00 -7,437.96 -2,963.40 5,938,445.00 555,744.00 0.00 7,437.96 1J-156 L2 T6 (wp05) 11,673.27 90.90 179.31 3,311.07 3,202.07 -7,478.54 -2,962.89 5,938,404.43 555,744.83 2.00 7,478.54 11,700.00 90.90 179.31 3,310.65 3,201.65 -7,505.27 -2,962.57 5,938;377.71 555,745.36 0.00 7,505.27 11,800.00 90.90. 179.31 3,309.08 3,200.08 -7,605.25 -2,961.36 5,938,277.75 555,747.34 0.00 7,605.25 11,900.00 90.90 179.31 3,307.50 3,198.50 -7,705.23 -2,960.16 5,938,177.79 555,749.33 0.00 7,705.23 4/14/2006 11:18:55AM Page 5 of 8 COMPASS 2003.11 Build 50 CrfJf tOCt~~11~~t~3S Kaska Database: EDM 2003.11 Single User Db Company: ConocoPhillips Alaska (Kuparuk) Project: Kuparuk River Unit Site: Kuparuk 1J Pad Well: Plan'1J-T56 Wellbore: 1 J-156 L2 Design: 1 J-156 L2 (wp05) Halliburton Energy Services Planning Report -Geographic HAl.Lt1~3UR7CtN Spelrry Drilling Selrv~ces - Local Co-ordinate Reference: Well Plan 1 J-156 -Slot 1 J-156 TVD Reference: Planning RKB @ 109.OOft (Doyon 141 (28+81 )) MD Reference: Planning RKB @ 109.OOft (Doyon 141 (28+81 )) North Reference: True Survey Calculation Method: Minimum Curvature Planned Survey 1J-156 L2 (wp05) Map Map MD Inclination Azimuth TVD SSTVD +N/-S +E/-W Northing Easting fftl (°) 1°) (ft) (ft) Ift) (ft) lft) (ft) 12,000.00 90.90 179.31 3,305.93 3,196.93 -7,805.21 -2,958.95 5,938,077.83 555,751.31 12,100.00 90.90 179.31 3,304.35 3,195.35 -7,905.19 -2,957.75 5,937,977.87 555,753.30. 12,185.91 90.90 179.31 3,303.00 3,194.00 -7,991.08 -2,956.71 5,937,892.00 555,755.00 1J-156 L2 T7 (wp05) 12,200.00 90.91 179.59 3,302.78 3,193.78 -8,005.17 -2,956.58 5,937,877.91 555,755.24 12,247.38 90.93 180.54 3,302.01 3,193.01 -8,052.55 -2,956.63 5,937,830.54 555,755.56 12,300.00 90.93 180.54 3,301.16 3,192.16 -8,105.15 -2,957.12 5,937,777.94 555,755.48 12,400.00 90.93 180.54 3,299.53 3,190.53 -8,205.14 -2,958.06 5,937,677.96 555,755.32 12,500.00 90.93 180.54 3,297.90 3,188.90 -8,305.12 -2,959.00 5,937,577.98 555,755.15 12,596.01 90.93 180.54 3,296.33 3,187.33 -8,401.11 -2,959.91 5,937,482.00 555,755.00 L2 : BHL @ 12596ft MD, 3296ft TVD : 4252ft FSL 8: 248ft FEL -Sec 10 - T10N - R10E - 41/2" - 1J-156 L2 T8 Toe (wp05) DLSEV Vert Section (°/100ft) (ft) 0.00 7,805.21 0.00 7,905.19 0.00 7,991.08 1.99 8,005.17 2.00 8,052.55 0.00 8,105.15 0.00 8,205.14 0.00 8,305.12 0.00 8,401.11 4/14/200611:18:55AM ~ ~ ~ ~ t~8 ~ COMPASS 2003.11 Build 50 • Halliburton Energy Services Na-~LtBUA~rc~N -~~'~~ ~f~~~~ Planning Report -Geographic s ~ry~~ ~~ p~~'~~g ~$ Database: EDM 2003.11 Single User Db Local Co-ordinate Reference: Well Plan 1 J-156 -Slot 1 J-156 Company: ConocoPhillips Alaska (Kuparuk) TVD Reference: Planning RKB @ 109.OOft (Doyon 141 (28+81 )) Project: Kuparuk River Unit MD Reference: Planning RKB @ 109.OOft (Doyon 141 (28+81)) Site: Kuparuk 1J Pad North Reference: True Well: Plan 1J-156 Survey Calculation Method: Minimum Curvature Wellbore; 1J-156 L2 Design: 1J-156 L2 (wp05) Geologic Targets 1J-156 L2 TVD Target Name +N!-S +E/-W Northing Easting (ft) -Shape ft ft (ft) (ft) 3,303.00 1J-156 L2 T7 (wp05) -7,991.08 -2,956.71 5,937,892.00 555,755.00 - Point 3,312.00 1J-156 L2 T6 (wp05) -7,437.96 -2,963.40 5,938,445.00 555,744.00 - Point 3,296.33 1J-156 L2 T8 Toe (wp05) -8,401.11 -2,959.91 5,937,482.00 555,755.00 - Point 3,380.00 1J-156 L2 T4 (wp05) -5,437.51 -2,988.83 5,940,445.00 555,703.00 - Point 3,433.00 1J-156 L2 T2 (wp05) -3,438.06 -3,014.26 5,942,444.00 555,662.00 - Point 3,342.00 1J-156 L2 T5 (wp05) -6,437.73 -2,976.62 5,939,445.00 555,723.00 - Point 3,404.00 1J-156 L2 DD Poly (wp05) -1,437.61 -3,039.68 5,944,444.00 555,621.00 - Polygon Point 1 -50.00 0.39 5,944,444.00 555,571.00 Point 2 -49.85 -11.34 5,944,432.27 555,571.24 Point 3 -49.52 -40.78 5,944,402.84 555,571.80 Point 4 -47.07 -239.74 5,944,203.92 555,575.80 Point 5 -46.59 -285.12 5,944,158.55 555,576.64 Point 6 -44.13 -554.09 5,943,889.64 555,581.19 Point 7 -43.59 -599.93 5,943,843.81 555,582.09 Point 8 -37.79 -999.83 5,943,444.00 555,591.00 Point 9 -36.34 -1,099.81 5,943,344.05 555,593.23 Point 10 -34.76 -1,213.27 5,943,230.61 555,595.69 Point 11 -29.38 -1,613.59 5,942,830.39 555,604.19 Point 12 -27.64 -1,750.25 5,942,693.76 555,607.00 Point 13 -24.58 -2,000.06 5,942,444.00 555,612.00 Point 14 -24.51 -2,005.64 5,942,438.42 555,612.11 Point 15 -12.36 -2,999.28 5,941,445.00 555,632.00 Point 16 -11.80 -3,043.33 5,941,400.96 555,632.90 Point 17 0.85 -3,999.51 5,940,445.00 555,653.00 Point 18 1.58 -4,056.53 5,940,388.00 555,654.17 Point 19 13.06 -4,999.73 5,939,445.00 555,673.00 Point 20 13.38 -5,024.72 5,939,420.02 555,673.51 Point 21 26.27 -5,999.96 5,938,445.00 555,694.00 Point 22 26.79 -6,040.54 5,938,404.43 555,694.83 Point 23 32.97 -6,553.09 5,937,892.00 555,705.00 Point 24 29.77 -6,963.11 5,937,482.00 555,705.00 Point 25 129.78 -6,963.89 5,937,482.00 555,805.00 Point 26 132.97 -6,553.86 5,937,892.00 555,805.00 Point 27 126.79 -6,041.32 5,938,404.43 555,794.83 Point 28 126.28 -6,000.74 5,938,445.00 555,794.00 Point 29 113.38 -5,025.50 5,939,420.02 555,773.51 Point 30 113.07 -5,000.51 5,939,445.00 555,773.00 Point 31 101.58 -4,057.30 5,940,388.00 555,754.17 Point 32 100.86 -4,000.29 5,940,445.00 555,753.00 Point 33 88.20 -3,044.11 5,941,400.96 555,732.90 Point 34 87.65 -3,000.06 5,941,445.00 555,732.00 Point 35 75.49 -2,006.42 5,942,438.42 555,712.11 Point 36 75.43 -2,000.84 5,942,444.00 555,712.00 Point 37 72.37 -1,751.03 5,942,693.76 555,707.00 Point 38 70.63 -1,614.36 5,942,830.39 555,704.19 Point 39 65.24 -1,214.05 5,943,230.61 555,695.69 Point 40 63.67 -1 100.59 5 943 344.05 555 693.23 Q/14/200611:18:55AM ~ ~ ~ ~e 7 of 8 COMPASS 2003.11 Build 50 ~ ~ , !~ ! ~ R ~ __ • Ct~l"1!UGOP~'1 t ~ ~ t X35 Alaska Database: EDM 2003.11. Single User Db Company: ConocoPhillips Alaska (Kuparuk) Project: Kuparuk River Unit Site: Kuparuk 1J Pad Well: Plan 1J-156 Wellbore: 1J-156 L2 Design: 1J-T56 L2{wp05) • Halliburton Energy Services MAL~.1BUR'1'C~N Planning Report -Geographic ~~~~~$ D e S p rry ri11€ng Local Co-ordinate Reference: Well Plan 1J-156 -Slot 1J-156 TVD Reference: Planning RKB @ 109.OOft (Doyon 141 (28+81)) MD Reference: Planning RKB @ 109.OOft (Doyon 141 (28+81)) North Reference: True Survey Calculation Method: Minimum Curvature Point 41 62.21 -1,000.61 5,943,444.00 555,691.00 Point 42 56.42 -600.71 5,943,843.81 555,682.09 Point 43 55.88 -554.87 5,943,889.64 555,681.19 Point 44 53.42 -285.90 5,944,158.55 555,676.64 Point 45 52.93 -240.52 5,944,203.92 555,675.80 Point 46 50.50 -41.56 5,944,402.84 555,671.82 Point 47 50.15 -12.12 5,944,432.27 555,671.24 Point 48 50.00 -0.39 5,944,444.00 555,671.00 3,399.00 1J-15s L2 T3 (wp05) -4,437.28 -3,002.04 5,941,445.00 555,682.00 - Point 3,403.00 1J-156 L2 T1 (wp05) -2,437.83 -3,027.47 5,943,444.00 555,641.00 - Point Prognosed Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (ft) (ft) (") (") so.oo 80.00 20 2s 2,791.96 2,168.00 10-3l4 13-1/2 5,625.45 3,404.00 7-518 9-7/8 12,596.00 3,296.33 4-1/2 6-3l4 4/14/2006 11:18:55AM Page 8 of 8 COMPASS 2003.11 Build 50 ~~~~~ ConocoPhillips Alaska ConocoPhillips Alaska (Kuparuk) Kuparuk River Unit Kuparuk 1J Pad Plan 1J-156 1 J-156 L2 1 J-156 L2 (wp05) Anticollision Report 14 April, 2006 • ~A~~~~ Spell'r~y Qlrillin selrv~es s z o8~ z c B. ENVmm x _ X35 d E U - a - 3m E`-'~6d'' Y ~N a ~ d f W ~ c3 'oN ~~ a o $'~°o L~ L `i O aLri N ~ C O W~ O C G _- R `. ~ ~ A W ;" o ~ ~ U U om H' O ~~ c~ J a e9Z Q a~N.- W JN 0 „1 J r 9 C V O C O N (~ xv a wm in n Q ae Cm 2a 3S wo N 2 e + e O ~ N C N N m ; 2 z ~ b J CH~e~- N 0 ~°e,a~ N ~ ~ N ,~j ~ ~ ~ d v ~ E ~ d z cd'°' o rn E ,a`! oz~~ ~c cg - o rn O o O ~ N N N r N N 0') O m 0 O °m N 0 ,-. 3 3 3 3 3 3 3 3 g ~ ~ ~ ~' ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ o„mAN mrua rv ~pym N~ai m n ~yny ~n V ~-N1`e> '~~~~~ ~-rvrvrvnMe's rei~<~u~NbbrAAaeem o d o O O m 0 LLLL OdOag0000 Fo0o0e'! O H ONO4lG oooooeoo 0000000000000 J G YI O ~C W C N O O vi o vi O N o N o H o N C eV C eV O J O Q o ~~ ~cd a. i~.'a aoi~oo~eurin~cu a. o +ooooooooeoooe'e°o °o mmmmmmmmm F nrfnnnnM~.~. .~.±nn~7o.nnn.VNn~.n W ybel~~~omamNU°OiNOUNMVri u^in~mnoro~ N 2~ei e>~ei ~i~~~.-.-m si ri~~ri<~rv,:m~~i .= 'a3ra~ronPOenroe°r°^a aaaavamo°a QOO°m wm~°n °o aw~m °o °n°o°w°on°o~°oa °o on Zg Oa aaaa°a°a°v °e v~aan ~m rrn aaoyrtiy~NN c°om'mm3~o°,°w8,.~v«eemmerenni ~°mme^~^m rr~Rmmmmmmmmmmmmmmmammmae pgg~rmannnmw.-.-mmabm m m uNmno ~" r°.~H«°m °n n$°n °mm~ roam N~nnduf brapm~.~-~~~~~~~~rvNNHNH 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 O ~ o ion oo N ~ n o0 00 00 00 °o 00 00 00 00 o c°~ c°~ ~.-. N u~ r .- ~ .- ~ N c~ o ~n co ~ m m V I I I ~ '. ~ 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 u> o ~n o ~n o~ o 0 0 0 0 o g o 0 0 0 N N t~ O N ~[] r N (°~1 O~ O~ O~~ O 0 0 0 ~~ L V - Eaa > sti ~~~ j. C}'+ D D ~ FUSE O `~ i _ ro Y v 5 ~ C ~ FB~T ~_~. 0 E 4 $ ~ f..N~ v: a m 0 N tr _ 2 .- w~ ~ o 0 ~0 D c ~io~ moZ~g z imem~ O ~K~KU Q ~ ~E ~ ~~~. rc a~~~c LL - A O A _ Z ~1yh~ W d d Z <<~~t W ~~ W ~~~~; Ws; a- ?z - o m ~ v V 9 ~ M H b~ A U ~ ORIGINAL • lr' Halliburton Energy Services ConocoPh~ll~ps Anticollision Report Alaska Company: ConocaPhillips Alaska (Kuparuk) Local Co-ordinate Reference: Project: Kuparuk River Unit ND Reference: Reference Site: Kuparuk 1J Pad MD Reference: Site Error: O.OOft North Reference: Reference Well: Plan 1 J-156 Survey Calculation Method: Well Error: O.OOft Output errors are at Reference Wellbore 1J-156 L2 Database: Reference Design: 1 J-156 L2 (wp05) Offset ND Reference: • HALLtBtJRTON Sperry Drillieg Services Well Plan 1J-156 -Slot 1J-156 Planning RKB @ 109.OOft (Doyon 141 (28+81)) Planning RKB @ 109.OOft (Doyon 141 (28+81)) True Minimum Curvature 2.00 sigma EDM 2003.11 Single User Db Reference Datum Reference 1J-156 L2 (wp05) Filter type: GLOBAL FILTER APPLIED: All wellpaths within 200'+ 100/1000 of reference Interpolation Method: MD Interval SO.OOft Error Model: ISCWSA Depth Range: 5,625.44 to 12,596.01ft Scan Method: Trav. Cylinder North Results Limited by: Maximum center-center distance of 1,456.80ft Error Surface: Elliptical Conic Warning Levels evaluated at: 0.00 Sigma Survey Tool Program Date 4/13/2006 From To (ft) (ft) Survey (Wellbore) Tool Name Description 28.00 800.00 1J-156 (wp05) (1J-156) CB-GYRO-MS Camera based gyro multishot 800.00 5,625.44 1J-156 (wp05) (1J-156) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 5,625.44 12,595.96 1J-156 L2 (wp05) (1J-156 L2) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC CC -Min centre to center distance or covergent point, SF -min separation factor, ES -min ellipse separation 4/14/2006 12:45:54PM Page 2 of 4 COMPASS 2003.11 Build 50 ~~~~~,.a ! • / Halliburton Energy Services ConocoPhillips Anticollision Report Alaska HALLIBURTON Sperry Drliling Services Company: ConocoPhillips Alaska (Kuparuk) Local Co-ordinate Reference: Well Plan 1 J-156 -Slot 1 J-156 Project: Kuparuk River Unit ND Reference: Planning RKB @ 109.OOft (Doyon 141 (28+81)) Reference Site: Kuparuk 1J Pad MD Reference: Planning RK8 @ 109.OOft (Doyon 141 (28+81)) Site Error: O.OOft North Reference: True Reference Well: Plan 1J-156 Survey Calculation Method: Minimum Curvature Well Error: O OOft Output errors are at 2.00 sigma Reference Wellbore 1J-156 L2 Database: EDM 2003.11 Single User Db Reference Design: 1 J-156 L2 (wp05) Offset ND Reference: Reference Datum Summary Reference Offset Centre to No-Go Allowable Measured Measured Centre Distance Deviation Warning Site Name Depth Depth Distance (ft) from Plan Offset Well -Wellbore -Design (ft) (ft) (ft) (ft) Kuparuk 1J Pad 1 J-154 - 1 J-154 - 1 J-154 Out of range 1J-154 - 1J-154 L1 - 1J-154 L1 Out of range 1 J-154 - 1 J-154 L2 - 1 J-154 L2 Out of range 1 J-159 - 1 J-159 - 1 J-159 Out of range 1 J-159 - 1 J-159 L1 - 1 J-159 L1 Out of range 1J-159 - 1J-159 L1 P61 - 1J-159 L1 P61 Out of range 1J-159 - 1J-159 L1 PB2 - 1J-159 L1 PB2 Out of range 1 J-159 - 1 J-159 L2 - 1 J-159 L2 Out of range 1J-159 - 1J-159 PB1 - 1J-159 PB1 Out of range Plan 1 J-102 - 1 J-102 - 1 J-102 (wp06) Out of range Plan 1J-102 - 1J-102 L1 - 1J-102 L1 (wp06) Out of range Plan 1 J-102 - 1 J-102 L2 - 1 J-102 L2 (wp06) Out of range Plan 1J-103 -Plan 1J-103 - 1J-103 (wp02) Out of range Plan 1 J-105 -Plan 1 J-105 - 1 J-105 (wp02) Out of range Plan 1 J-107 -Plan 1 J-107 - 1 J-107 (wp02) Out of range Plan 1J-109 -Plan 1J-109 - 1J-109 (wp05) Out of range Plan 1J-111 -Plan 1J-111 - 1J-111 (wp03) Out of range Plan 1J-152 - 1J-152 - 1 J-152 8,559.49 10,053.00 1,266.21 176.01 1,090.73 Pass -Major Risk Plan 1J-152 - 1J-152 L1 - 1J-152 L1 11,270.46 12,750.00 1,195.24 260.61 935.47 Pass -Major Risk Plan 1J-152 - 1J-152 L2 - 1J-152 L2 5,921.30 7,400.00 1,249.39 120.56 1,132.59 Pass -Major Risk Plan 1J-152 - 1J-152 PB1 - 1J-152 P61 6,044.40 7,550.00 1,297.87 121.26 1,179.86 Pass -Major Risk Plan 1J-152- 1J-152 PB2- 1J-152 P62 7,801.49 9,296.00 1,260.04 157.63 1,102.93 Pass- Major Risk Plan 1J-156 - 1J-156 - 1J-156 (wp05) 5,649.99 5,650.00 0.62 3.19 -1.88 FAIL - No Errors Plan 1J-156 - 1J-156 L1 - 1J-156 L1 (wp05) 5,649.99 5,650.00 0.62 3.19 -1.88 FAIL - No Errors Plan 1 J-158 - 1 J-158 - 1 J-158 (wp03) Out of range Plan 1J-160- Plan 1J-160 - 1J-160 (wp01) BHI Out of range Plan 1J-162 - 1J-162 - 1J-162 (wp03.1-North Heel) Out of range Plan 1J-162 - 1J-162 L1 - 1J-162 L1 (wp3.1) Out of range Plan 1J-162 - 1J-162 L2 - 1J-162 L2 (wp3.1) Out of range Plan 1J-173 Kuparuk - 1J-73 E Lateral - 1J-73 E Lat 5,645.92 5,450.00 217.57 106.41 112.89 Pass -Major Risk Plan 1J-173 Kuparuk- 1J-73 Kuparuk- 1J-73 W Lat 5,645.92 5,450.00 217.57 106.41 112.89 Pass- Major Risk Plan 1 J-173 Kuparuk - 1 J-73 Pilot - 1 J-173 Pilot (wp 5,645.92 5,450.00 217.57 106.41 112.89 Pass -Major Risk Plan 1J-176 (02 Phase 2) -Plan 1J-176 - 1J-176 (wp 8,879.08 6,550.00 1,257.05 186.43 1,119.59 Pass -Major Risk Plan 1 J-178 (03 Phase 2) -Plan 1 J-178 - 1 J-178 (wp 10,573.78 7,950.00 807.08 242.45 619.14 Pass -Major Risk Plan 1J-180 (04 Phase 2) -Plan 1J-180 - 1J-180 (wp 12,568.71 9,550.00 173.81 21.07 173.34 Pass -Minor 1/200 Plan 1J-182 - 1J-182 - 1J-182 (wp05) 12,549.86 9,450.00 1,286.57 302.65 985.34 Pass -Major Risk Plan 1J-182 - 1J-182 L1 - 1J-182 L1 (wp05) 12,558.90 9,450.00 1,283.43 297.52 986.60 Pass -Major Risk CC -Min centre to center distance or covergent point, SF -min separation factor, ES -min ellipse separation 4/14/2006 12:45.~54PM g COMPASS 2003.11 Build 50 ~~~ ~ 1J-156L~Drillin~ Hazards ~ummary (SEE WELL PLAN AND ATTACHMENTS FOR DETAILED DISCUSSION OF THESE RISKS) 6-3/4" Open Hole / 4-1/2" Liner Interval Hazard Risk Level Miti anon Strate Abnormal Reservoir Pressure Low , Stripping drills, shut-in drills, increased mud weight. Stuck Pipe Low Good hole cleaning, PWD tools, hole opener runs, decreased mud weight Lost Circulation Low Reduced pump rates, mud rheology, LCM Hole Swabbing on Trips Moderate Trip speeds, proper hole filling (use of trip sheets),pumping out, backreaming ~~ ~~ 1J-156L2 Drilling Hazards Summary ~~~...111 111 prepared by Mike Greener 5/4/2006 12:13 PM O Insulated Conductor Casing, 20", 94ft, K55 x 34", 0.31 T' WT~7Z ~~ +I-SO'MD ~~ r b (/~ z m ~ ~ s c '~ ~ c -°n ~ ~ n ~ " 3 ~' ai A n ` t s~ K~ ;~ C w 3y . ~' a ~:~ 10-3/4", 68#, L-SQ BTC, R3 2,792' MD / 2,168' TVD ~~ 41.6 degrees TU 13-3/8" bole Top of lignu C (a ~ 4,100' DID / 2,811' TVD Lateral Entry Module #2 (LEM), Baker, with seal bore and ZXP packer (~ x,xxx' MD, x,xxx' TVD Wellhead /Tubing Head /Tree, 10-3/4" x 4-''/z", 5,000 ksi Tubing String: 4-I/2", 12.G#, L-80, lB'IM 'Cop of West Sak B (a1 --> 5,999' MD / 3,484' TVD Lateral Entry Module # I (LEM), Baker, with seal bore and ZXI' packer n. x,xxx' MU, x,xxx' TVD (1) 3.875" DB nipple set +/- 500' - (1) Gas Lift h4andrel, CAD1C04-1/2" x I" Model KBG-2, @ 25 deg, 1,200' MD, I,lti9' TVU. (l) Gas Lift Mandrel, CAMCO 4-I/2" x I" Model KBG-2, @ 70 deg., (+/- 1 joint above sliding sleeve) (1) Sliding Sleeve, with 3.812" nipple, en 72 deg, (+/- l joint above seals) 156 L2"D" Sand Window rr 5,629 MD / 3,404' TVD 73 degrees "D" Liner, 4-I/2", 11.6N, L80, BTCM, R2 ~~ ~ ~ ~ ~ I56 LI "B" S~indow _ _~ - 5,952' MD / 3,476' TVD 80 degrees "B" Liner, 4-I/2", 11.6#, L8Q, BTCM, R2 "Cop of West Sak A n ~ 6,2W' NID / 3,519"1'VD Tubing, 4-S'z" IBTM, Gom LEM to AZ Liner, with seal stem and CAMCO 3.562" "DB" nipple. Seal bore and ZXP packer fur A2 liner 6,042' MD, 3,630' TVD 7-5/8", 40#, L-SQ BTCM, R3 Cs'g ~. 6,8GT MU / 3,628' TVD rr. 86 degrees TD 9-5/8" hole A2 Sand Liner, 4-U2", 116#, L80, BTCM, R2 /- IJ-I56 L2: 6-3/4" D sand lateral 3 303' TVD Angle 9 6 3/4" "B" sand lateral TD 12,994' Iv4D / 3,381' TVD Angle 90 degrees IJ-l56_ 6-3/4 A2 sand lateral TD 8,31 T MD / 3,637 TVD Angle 90 degrees • • • TRANSMITTAL LETTER CHECKLIST WELL NAME l'~/2GC ~~^/ SCo L Z PTD# Z~ f~ ' d (oq Development ~ Service Exploratory Stratigraphic Test Non-Conventional Well Circle Appropriate Letter /Paragraphs to be Included in Transmittal Letter CHECK ADD-ONS TEXT FOR APPROVAL LETTER WHAT (OPTIONS) APPLIES MULTI LATERAL The permit is for a new wellbore segment of existing well 1~~~ /.T'"~~cv (If last two digits in API b permit o4 260' C.~(o7API No. 50- 01'q - Z 3 3 // - G~. num er are between 60-69) ould continue to be reported as a function of the original API number stated above. PILOT HOLE In accordance with 20 AAC 25.005(f), all records, data and logs acquired for the pilot hole must be clearly differentiated in both well name ( PH) and API number (50- - -) from records, data and logs acquired for well SPACING The permit is approved subject to full compliance with 20 AAC EXCEPTION 25.055. Approval to perforate and produce /inject is contingent upon issuance of a conservation order approving a spacing exception. assumes the liability of any protest to the spacing exception that may occur. DRY DITCH All dry ditch sample sets submitted to the Commission must be in SAMPLE no greater than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. Please note the following special condition of this permit: Non-Conventional production or production testing of coal bed methane is not allowed Weil for (name of welll until after (Company NameZhas designed and implemented a water well testing program to provide baseline data on water quality and quantity. (Companyy NameZmust contact the Commission to obtain advance approval of such water well testing ro ram. Rev: 1 /25/06 C:\j ody\transmittal_checklist WELL PERMIT CHECKLIST Field & Pool KUPARUK RIVER, WEST SAKOIL - 490150 Well Name: KUPARUK RIV U WSAK 1J-156L2 _Program SER Well bore seg ~ PTD#:2060690 Company CONOCOPHILLIPS ALASKA INC Initial ClasslType SER 1 PEND GeoArea 890 Unit 11160 On1Off Shore On Annular Disposal ^ Administration 1 Permit_fee attached- _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ NA_ _ _ _ _ _ _ West Sak D Sand multilateral well branch; fee waived per 2l) AAC 25.005(e), _ _ _ _ _ _ _ _ - . - - - _ _ 2 Lease number appropriate- - - - . - _ - - - _ - Yes _ _ - _ - _ Top productive interval in ADL 025660; and TD in ADL_025663_ _ _ _ _ _ _ _ _ _ _ _ _ 3 Uniquewell_nameandnumber_ __ __________ __ __ _____ __ -.. Ye$----- __ _ ______ _ 4 Well locatedin-a-defined-pool_______________________ ______ _________Yes---_ _KuparukRiver,WestSak Oil Pool-490150,_ oyerned_b CO 4066_--_--______________- -9 Y 5 Well located proper distance. from drilling urlit_boundary_ _ .Yes - - - - Well is more than-509 feet from an external property line .. . . . . . . . ..... 6 Well located proper distance_ from other wells- - - - - - - - - - - - - - - - - Yes - - - . - . . CO 406B, Rule 3:_ no restrictions as_to well spacing except that no_pay shall be opened in a well closer - 7 Su~cient acreage_ayail_able in_dril_ling unit _ _ _ _ ...... _ _ Yes than 500 feet to-an extemal_property line where ownership-or landownership changes_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 8 If deviated, is-wellboreplat_included__________________________ _________ Yes_____ _____-_---__.-_ ------------------------------------------------------ 9 Operator only affected party - - - Yes - - - - - - - 10 Operakorhas.appropriate.bondinforce________________________ _________Yes_.___. __-__-___-._- 11 Permit_canheissuedwithoutconseryationorder----------- ------- ---------Yes____-- _-______-_____-____-_-______- Appr Date 12 Permit. can be issued without administrative_approval Yes _ - _ - -- SFD 5116!2006 13 Can permit be approved before 15-day wait Yes 14 Well located within area and strata authprized ay Injection Order # (put_1O# in_comments)_(For_ Yes _ - - _ - - Area Injection Order No._ 26. _ - - - - -------------------------- 15 All wells within 1!4_mile area of review identified (For service well only) _ _ _ _ _ _ _ __ _ _ _ __ Yes _ _ - _ _ _ _ KRIJ 1J-152_and laterals, KRII 1J-170 and_laterals._ _ .. _ _ . _ . _ . _ .. _ _ _ . _ _ _ _ _ .. _ _ _ _ _ _ . - . _ - . _ 16 Pre-produced injector. duration of pre Production less_ than_ 3 months_(Forservice well only) . -Yes .. - KRU 1J-Pad_ injection wells a[e_typirallypre-produced for cleanup for 30-45 days.- - - - AC_M_P_Finding of Con_sistency_has been issued_forthis proiect. - - - _ _ - _ NA_ _ _ _ _ - - ACMP deter_mination_no longer_affeets AOGCC approval of permit to drill._ _ - - - - - _ _ - Engineering 18 Conductor string_p_rovided - - - - - - - - - - - - - - - NA_ _ - - Conductor set_in motherbore,_1J-156 (206-067)._ - - _ - - - 19 Surface casing_protectsa11kn4wnUSDWS______________________ _________ NA-__-__- -Alaquifers_exempted, 40CFR147.102_(b)(3).________-----_ ------------------ 20 CMT_vol-adeguate_tocirculate_onconductor&su_rf_csg____--_-____- -__-.__--NA-_____- -Surface casing set in1Jr156______________---___--__--_______-__--_-----_.-_-- 21 CMT_vol-adequate_totie-in long string to surfcsg___________________ _________NA--_--_ _Pr_oduction_casingset in-1J,156.-______________-___-_-_________-__--__--_ 22 CMT_will coverall know_n_productiye horizons- - - - - - - - - - - - - - - - - - No_ Slotted liner completion plaanned._ _ _ _ - _ _ - _ _ - - - 23 Casing designs adequate for_ G,.T, B &-permafrost- Yes . _ .. - . . Motherbgre met design repui[ements._ NA for slottedJiner, _ - - - _ - _ _ - _ _ 24 Adequate tankage_o_r reserve pit _ Yes Rig js-equipped with steel_pits. No reserve_pitplanned, All waste to approved annulus-or disposal wells. 25 If_a_re-drill,has_a_10-4D3forabandonmentbeenapproved______------ --------- NA_______ ___-__--_-_______ 26 Adequate wellbore separation_proposed _ _ _ _ ____ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes . _ ... _ ,Proximity analysis performed: Nearest well segment is 1J-156L1- X75' tvd below. - _ _ _ _ _ _ _ _ _ _ 27 Ifdive[terrequired,doesitmeetregulations______________________ __________N_A_______ _BOPStack_willalready_beinplace,__--_-__--_-.-__--_________________--____-_-- Appr Date 28 Drilling fluid_ program schematic & equip list adeguate_ _ - - - - - _ - - - - Yes Maximum expected formation pressure 8,7_EMW.- Planned MW $:8-ppg. - TEM 5/3012006 2g BOPEs,-do they meet regulation____________________________ _________Yes-____ ___________-__-.__-__-___ (,~ ~ ' 30 _B_OPE_press rating appropriate; test to_(put prig in comments)- - - - - _ _ - - _ _ _ Yes - M/1$P calculated at 11.57 psi. 3K stack arrangement and BOP test planned. - h J~ 31 Choke_manifoldcompliesw/API-RP-53 (May84)___________________ ____ ____Yes__---_ --____-________._ ------------------------- 32 Work will occur without operation shutdown-__________________ ____--_-.Yes-_--__ ______________-.--.--_________--__--___-__-----_-- ------------------ 33 Is presence. of H2Sgos-probable _ _ . - - _ - - No.. _ - - H2S has not_been reported o01J pad. Rig has sensors and alarms._ - .. - - - .. - ---------------- 34 Mechanical_condition of wells within AOR yenfied (For service well only _ Yes . _ .. - . -There are no known issues within the AOR. _ _ _ _ _ _ _ Geology 35 Permit_c-an be issuedwlohydrogen_sulfidemeasures________________ ________ Yes-.__ .Noneexpected._Rig has sensors and_a_larms.___-___-_____________-______-___-__--_-. 36 Data_presented on potential ove_rpressur_e zones - - _ - _ _ - - _ - - _ Yes Expected res._pressure is ~8.7ppg EMW; will be drilled with 8.8 ppgoil-based mud. Appr Date 37 Seismic analysis of shallow gas-zones ..... . . . . . . . . . NA- - - -- SFD 5/1612006 38 Seabed condition curve rf off_-shore y ( ) - NA- - -- - - ----------------------- 39 Contactnamelpho_nefotweekly_progress reporls_]exploratoryonly]_ - - _ _ - NA_ _ - - - - _ _ _ Geologic Commissioner: ' Engineering Public Date: Date m i ssio r: _ ~ ~ ner o/ m~ r~C West Sak D Sand multilateral in ector. Date 1 0., [c / ~. ( ~ ~ l ~} O~ r • • Well History File APPENDIX InforrT~aiion of detailed nature that is not parliculariy germane to the Well Permitting Process but is part of the history tile. To improve the readability of tl~e Well History file and to simplify finding infom~ation, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. Sperry-Sun Dr~ing Services LIS Scan Utility $Revision: 3 $ LisLib $Revision: 4 $ Wed Aug 09 16:44:55 2006 Reel Header Service name .............LISTPE Date .....................06/08/09 Origin ...................STS Reel Name ................UNKNOWN Continuation Number......01 Previous Reel Name.......UNKNOWN Comments .................STS LIS Writing Library. Tape Header Service name .............LISTPE Date .....................06/08/09 Origin ...................STS Tape Name ................UNKNOWN Continuation Number......01 Previous Tape Name.......UNKNOWN Comments .................STS LIS Writing Library Physical EOF r 1 ~J Scientific Technical Services Scientific Technical Services Comment Record TAPE HEADER West Sak MWD/MAD LOGS WELL NAME: 1J-156 L2 API NUMBER: 500292331161 OPERATOR: ConocoPhillips Alaska, Inc. LOGGING COMPANY: Sperry Drilling Services TAPE CREATION DATE: 09-AUG-06 JOB DATA MWD RUN 2 MWD RUN 3 MWD RUN 9 JOB NUMBER: W-0004467716 W-0004467716 W-0004467716 LOGGING ENGINEER: P. ORTH P. ORTH P. ORTH OPERATOR WITNESS: D. GLADDEN D. GLADDEN M. THORNTON MWD RUN 10 JOB NUMBER: W-0004467716 LOGGING ENGINEER: P. ORTH OPERATOR WITNESS: M. THORNTON SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD OPEN HOLE 35 11N l0E 2094 2560 109.00 81.00 CASING DRILLERS 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING REMARKS: BIT S~ (IN) 9.875 6.750 SIZE (IN) DEPTH (FT) • 10.750 2769.0 7.625 5697.0 1. ALL DEPTHS ARE MEASURED DEPTHS UNLESS OTHERWISE NOTED. THESE DEPTHS ARE BIT DEPTHS. 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTHS (TVD). 3. THIS WELLBORE WAS DRILLED FROM A WHIPSTOCK, THE TOP OF WHICH WAS AT 5697' MD/3422'TVD, WITHIN THE RUN 3 INTERVAL OF THE 1J-156 WELLBORE. THE WHIPSTOCK WAS POSITIONED, THE WINDOW MILLED, AND A BIT OF RAT HOLE WAS DRILLED DURING MWD RUN 9. ONLY SROP DATA ARE PRESENTED FOR THIS RUN. 4. MWD RUNS 1,8 WERE DIRECTIONAL ONLY - NO DATA ARE PRESENTED. 5. MWD RUNS 2,3,10 COMPRISED DIRECTIONAL, DUAL GAMMA RAY (DGR) UTILIZING GEIGER-MUELLER TUBE DETECTORS, ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4), AND PRESSURE WHILE DRILLING (PWD) MWD RUN 10 ALSO INCLUDED GEO- PILOT ROTARY-STEERABLE BHA (GP). 6. DEPTH SHIFTING OF MWD DATA WAS WAIVED PER E-MAIL, DATED 12/16/04, FROM M. WERNER (CPAI) TO R. KALISH (SDS) MWD DATA ARE CONSIDERED PDC. 7. MWD RUNS 1-3,9,10 REPRESENT WELL 1J-156 L2 WITH API#: 50-029-23311-61. THIS WELL REACHED A TOTAL DEPTH (TD) OF 12566'MD/3330'TVD. SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRC = SMOOTHED GAMMA RAY COMBINED. SEXP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (EXTRA SHALLOW SPACING).. SESP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (SHALLOW SPACING) . SEMP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (MEDIUM SPACING). SEDP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (DEEP SPACING). SFXE = SMOOTHED FORMATION EXPOSURE TIME (DEEP SPACING). SLIDE = NON-ROTATED INTERVALS REFLECTING BIT DEPTHS. File Header Service name .............STSLIB.001 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/08/09 Maximum Physical Record..65535 File Type ................LO Previous File Name.......STSLIB.000 Comment Record FILE HEADER ~ • FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE START DEPTH STOP DEPTH GR 2735.0 12508.5 RPX 2750.0 12515.5 RPS 2750.0 12515.5 RPM 2750.0 12515.5 FET 2750.0 12515.5 RPD 2750.0 12515.5 ROP 2780.5 12566.5 BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH MERGED DATA SOURCE PBU TOOL CODE MWD MWD MWD MWD BIT RUN NO MERGE TOP 2 2735.0 3 2869.0 9 5697.5 10 5741.0 REMARKS: MERGED MAIN PASS. MERGE BASE 2869.0 5697.0 5741.0 12566.5 Data Format Specification Record Data Record Type ..................0 Data Specification Block Type.....0 Logging Direction .................Down Optical log depth units...........Feet Data Reference Point ..............Undefined Frame Spacing .....................60 .lIN Max frames per record .............Undefined Absent value ......................-999 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 RPD MWD OHMM 4 1 68 4 2 RPM MWD OHMM 4 1 68 8 3 RPS MWD OHMM 4 1 68 12 4 RPX MWD OHMM 4 1 68 16 5 FET MWD HOUR 4 1 68 20 6 GR MWD API 4 1 68 24 7 ROP MWD FT/H 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 2735 12566.5 7650.75 19664 2735 12566.5 RPD MWD OHMM 0.48 2000 62.5302 19532 2750 12515.5 RPM MWD OHMM 1.87 1743.45 56.3624 19532 2750 12515.5 RPS MWD OHMM 1 2000 58.0979 19532 2750 12515.5 RPX MWD OHMM 0.17 2000 55.8078 19532 2750 12515.5 FET MWD HOUR 0.18 367.04 0.972361 19532 2750 12515.5 GR MWD API 20.93 114.94 63.5752 19548 2735 12508.5 ROP MWD FT/H 0.15 448.81 200.604 19573 2780.5 12566.5 • First Reading For Entire File..........2735 Last Reading For Entire File...........12566.5 File Trailer Service name .............STSLIB.001 Service Sub Level Name... Version Number...........1.0.0 Bate of Generation.......06/08/09 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.002 Physical EOF File Header Service name .............STSLIB.002 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/08/09 Maximum Physical Record..65535 File Type ................LO Previous File Name.......STSLIB.001 Comment Record FILE HEADER FILE NUMBER: 2 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 2 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 2735.0 2823.0 RPD 2750.0 2814.5 RPX 2750.0 2814.5 RPM 2750.0 2814.5 FET 2750.0 2814.5 RPS 2750.0 2814.5 ROP 2780.5 2869.0 LOG HEADER DATA DATE LOGGED: 03-JUL-06 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 66.37 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT) 2869.0 TOP LOG INTERVAL (FT) 2780.0 BOTTOM LOG INTERVAL (FT) 2869.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 59.5 MAXIMUM ANGLE: 59.5 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 10718517 EWR4 ELECTROMAG. RESIS. 4 66259 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) 9.875 DRILLER'S CASING DEPT~T): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format Specification Record Data Record Type ..................0 Data Specification Block Type.....0 Logging Direction .................Down Optical log depth units...........Feet Data Reference Point ..............Undefined Frame Spacing .....................60 .lIN Max frames per record .............Undefined Absent value ......................-999 Depth Units ....................... Datum Specification Block sub-type...0 2769.0 • Native/Spud Mud 9.10 40.0 8.5 100 7.0 3.300 110.0 4.890 72.0 4.500 110.0 3.200 110.0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 RPD MWD020 OHMM 4 1 68 4 2 RPM MWD020 OHMM 4 1 68 8 3 RPS MWD020 OHMM 4 1 68 12 4 RPX MWD020 OHMM 4 1 68 16 5 FET MWD020 HOUR 4 1 68 20 6 GR MWD020 API 4 1 68 24 7 ROP MWD020 FT/H 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 2735 2869 2802 269 2735 2869 RPD MWD020 OHMM 1.54 2000 419.052 130 2750 2814.5 RPM MWD020 OHMM 5.06 1743.45 59.1091 130 2750 2814.5 RPS MWD020 OHMM 7.67 24.86 15.797 130 2750 2814.5 RPX MWD020 OHMM 0.91 23.7 12.2931 130 2750 2814.5 FET MWD020 HOUR 0.51 57.61 29.5562 130 2750 2814.5 GR MWD020 API 26.44 105.29 59.0393 177 2735 2823 ROP MWD020 FT/H 41.91 448.81 235.299 178 2780.5 2869 First Reading For Entire File..........2735 Last Reading For Entire File...........2869 File Trailer Service name .............STSLIB.002 Service Sub Level Name.. • • Version Number...........1.0.0 Date of Generation.......06/08/09 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.003 Physical EOF File Header Service name .............STSLIB.003 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/08/09 Maximum Physical Record..65535 File Type ................LO Previous File Name.......STSLIB.002 Comment Record FILE HEADER FILE NUMBER: 3 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 3 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH FET 2815.0 5697.0 RPX 2815.0 5697.0 RPM 2815.0 5697.0 RPS 2815.0 5697.0 RPD 2815.0 5697.0 GR 2823.5 5697.0 ROP 2869.5 5697.0 LOG HEADER DATA DATE LOGGED: 06-JUL-06 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 66.37 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT) 5697.0 TOP LOG INTERVAL (FT) 2869.0 BOTTOM LOG INTERVAL (FT) 5697.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 57.7 MAXIMUM ANGLE: 85.9 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 10718517 EWR4 ELECTROMAG. RESIS. 4 157645 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) 9.875 DRILLER'S CASING DEPTH (FT) 2769.0 BOREHOLE CONDITIONS MUD TYPE: Native/Spud Mud MUD DENSITY (LB/G) 9.10 MUD VISCOSITY (S) 67.0 MUD PH: 9.8 • MUD CHLORIDES (PPM): 150 FLUID LOSS (C3) 4.6 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT) 3.300 110.0 MUD AT MAX CIRCULATING TERMPERATURE : 3.860 93.2 MUD FILTRATE AT MT: 4.500 110.0 MUD CAKE AT MT: 3.200 110.0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (TN): EWR FREQUENCY (HZ): REMARKS: Data Format Specification Record Data Record Type ............. .....0 Data Specification Block Type .....0 Logging Direction ............ .....Down Optical log depth units...... .....Feet Data Reference Point ......... .....Undefined Frame Spacing ................ .....60 .lIN Max frames per record ........ .....Undefined Absent value ................. .....-999 Depth Units .................. ..... Datum Specification Block sub -type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 RPD MWD030 OHMM 4 1 68 4 2 RPM MWD030 OHMM 4 1 68 8 3 RPS MWD030 OHMM 4 1 68 12 4 RPX MWD030 OHMM 4 1 68 16 5 FET MWD030 HOUR 4 1 68 20 6 GR MWD030 API 4 1 68 24 7 ROP MWD030 FT/H 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 2815 5697 4256 5765 2815 5697 RPD MWD030 OHMM 5.91 68.41 13.5193 5765 2815 5697 RPM MWD030 OHMM 5.21 63.56 12.5165 5765 2815 5697 RPS MWD030 OHMM 4.94 1330.66 12.7469 5765 2815 5697 RPX MWD030 OHMM 4.74 1345.1 11.9694 5765 2815 5697 FET MWD030 HOUR 0.23 8.42 0.713193 5765 2815 5697 GR MWD030 API 20.93 114.94 67.4145 5748 2823.5 5697 ROP MWD030 FT/H 5.73 432.8 178.712 5656 2869.5 5697 First Reading For Entire File..........2815 Last Reading For Entire File...........5697 File Trailer Service name .............STSLIB.003 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/08/09 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.004 Physical EOF File Header Service name .............STSLIB.004 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/08/09 Maximum Physical Record..65535 File Type ................LO Previous File Name.......STSLIB.003 Comment Record FILE HEADER • FILE NUMBER: 4 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 9 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH ROP 5697.5 5741.0 LOG HEADER DATA DATE LOGGED: 20-JLTL-06 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 66.37 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT) 5741.0 TOP LOG INTERVAL (FT) 5697.0 BOTTOM LOG INTERVAL (FT) 5741.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: .0 MAXIMUM ANGLE: .0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) 6.750 DRILLER'S CASING DEPTH (FT) 2769.0 BOREHOLE CONDITIONS MUD TYPE: Mineral Oil Base MUD DENSITY (LB/G): 8.80 MUD VISCOSITY (S) 69.0 MUD PH: .0 MUD CHLORIDES (PPM): 21500 FLUID LOSS (C3) 3.0 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT) .000 .0 MUD AT MAX CIRCULATING TERMPERATURE: .000 72.0 MUD FILTRATE AT MT: .000 .0 MUD CAKE AT MT: .000 .0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # • REMARKS: Data Format Specification Record Data Record Type ..................0 Data Specification Block Type.....0 Logging Direction .................Down Optical log depth units...........Feet Data Reference Point ..............Undefined Frame Spacing .....................60 .lIN Max frames per record .............Undefined Absent value ......................-999 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD090 FT/H 4 1 68 4 2 • First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 5697.5 5741 5719.25 88 5697.5 5741 ROP MWD090 FT/H 0.15 33.28 13.7367 88 5697.5 5741 First Reading For Entire File..........5697.5 Last Reading For Entire File...........5741 File Trailer Service name .............STSLIB.004 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/08/09 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.005 Physical EOF File Header Service name .............STSLIB.005 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/08/09 Maximum Physical Record..65535 File Type ................LO Previous File Name.......STSLIB.004 Comment Record FILE HEADER FILE NUMBER: 5 RAW MWD Curves and log header data BIT RUN NUMBER: 10 DEPTH INCREMENT: .5000. FILE SUMMARY for each bit run in separate files. VENDOR TOOL CODE START DEPTH STOP DEPTH RPX 5697.5 12515.5 RPD 5697.5 12515.5 RPM 5697.5 12515.5 GR 5697.5 12508.5 . FET 5697 12515.5 RPS 5697.5 12515.5 ROP 5741.5 12566.5 LO G HEADER DATA DATE LOGGED: 23-JUL-06 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 66.37 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT) 12566.0 TOP LOG INTERVAL (FT) 5741.0 BOTTOM LOG INTERVAL (FT) 12566.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 78.4 MAXIMUM ANGLE: 93.3 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 153879 EWR4 Electromag Resis. 4 48783 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) 6.750 DRILLER'S CASING DEPTH (FT) 2769.0 BOREHOLE CONDITIONS MUD TYPE: Mineral Oil Base MUD DENSITY (LB/G): 8.80 MUD VISCOSITY (S) 77.0 MUD PH: .0 MUD CHLORIDES (PPM): 25000 FLUID LOSS (C3) 3.5 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT) .000 .0 MUD AT MAX CIRCULATING TERMPERATURE: .000 111.2 MUD FILTRATE AT MT: .000 .0 MUD CAKE AT MT: .000 .0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format Specification Record Data Record Type ..................0 Data Specification Block Type.....0 Logging Direction .................Down Optical log depth units...........Feet Data Reference Point ..............Undefined Frame Spacing .....................60 .lIN Max frames per record .............Undefined Absent value ......................-999 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 RPD MWD100 OHMM 4 1 68 4 2 ~ RPM MWD100 OHMM 1 68 8 3 RPS MWD100 OHMM 4 1 68 12 4 RPX MWD100 OHMM 4 1 68 16 5 FET MWD100 HOUR 4 1 68 20 6 GR MWD100 API 4 1 68 24 7 ROP MWD100 FT/H 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 5697.5 12566.5 9132 13739 5697.5 12566.5 RPD MWD100 OHMM 0.48 1689.35 79.8507 13637 5697.5 12515.5 RPM MWD100 OHMM 1.87 745.1 74.8719 13637 5697.5 12515.5 RPS MWD100 OHMM 1 2000 77.6731 13637 5697.5 12515.5 RPX MWD100 OHMM 0.17 2000 74.7551 13637 5697.5 12515.5 FET MWD100 HOUR 0.18 367.04 0.809437 13637 5697.5 12515.5 GR MWD100 API 37.22 93.38 62.0142 13623 5697.5 12508.5 ROP MWD100 FT/H 0.55 349.64 210.427 13651 5741.5 12566.5 First Reading For Entire File..........5697.5 Last Reading For Entire File...........12566.5 File Trailer Service name .............STSLIB.005 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/08/09 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.006 Physical EOF Tape Trailer Service name .............LISTPE Date .....................06j08/09 Origin ...................STS Tape Name ................UNKNOWN Continuation Number......01 Next Tape Name...........UNKNOWN Comments .................STS LIS Writing Library Reel Trailer Service name .............LISTPE Date .....................06/08/09 Origin ...................STS Reel Name ................UNKNOWN Continuation Number......01 Next Reel Name...........UNKNOWN Comments .................STS LIS Writing Library Physical EOF Physical EOF Scientific Technical Services Scientific Technical Services End Of LIS File
