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'% =* ": 7 Last Tag Annotation Depth (ftKB) End Date Wellbore Last Mod By Last Tag:1J-152 lmosbor Last Rev Reason Annotation End Date Wellbore Last Mod By Rev Reason: GLV C/O 11/11/2015 1J-152 lehallf Casing Strings Casing Description CONDUCTOR Insulated 20"x34" OD (in) 16 ID (in) 15.06 Top (ftKB) 28.0 Set Depth (ftKB) 108.0 Set Depth (TVD) … 108.0 Wt/Len (l… 62.50 Grade H-40 Top Thread WELDED Casing Description SURFACE OD (in) 10 3/4 ID (in) 9.95 Top (ftKB) 30.1 Set Depth (ftKB) 2,773.8 Set Depth (TVD) … 2,198.0 Wt/Len (l… 45.50 Grade L-80 Top Thread BTC Casing Description INTERMEDIATE OD (in) 7 5/8 ID (in) 6.87 Top (ftKB) 27.3 Set Depth (ftKB) 6,523.2 Set Depth (TVD) … 3,637.9 Wt/Len (l… 29.70 Grade L-80 Top Thread BTC-M Casing Description D-SAND LINER HH OD (in) 4 1/2 ID (in) 3.48 Top (ftKB) 5,398.6 Set Depth (ftKB) 5,636.5 Set Depth (TVD) … 3,487.5 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) 5,398.6 3,442.0 77.05 HANGER 1 BAKER B-1LEM HOOK HANGER (Inside CSG) 4.950 5,415.0 3,445.7 77.36 HANGER 2 BAKER B-1LEM HOOK HANGER (Outside CSG) 4.950 5,508.5 3,464.8 78.97 PACKER BAKER PAYZONE EXTERNAL CASING PACKER 7.625 5,607.8 3,482.7 80.20 BENT JT 3.476 Casing Description B-SAND LINER LEM OD (in) 4 1/2 ID (in) 3.96 Top (ftKB) 5,501.9 Set Depth (ftKB) 5,904.3 Set Depth (TVD) … 3,533.7 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) 5,501.9 3,463.6 78.86 PACKER ZXP LINER TOP PACER 4.970 5,521.0 3,467.2 79.18 SBR 109-47 CASING SEAL BORE RECEPTACLE 4.750 5,540.6 3,470.8 79.47 XO BUSHING BAKER CROSSOVER BUSHING 4.750 5,742.1 3,506.2 79.51 HANGER LEM ABOVE HOOK HANGER 4.950 5,767.0 3,510.7 79.55 HANGER LEM INSIDE HOOK HANGER 4.950 5,825.3 3,521.2 79.88 NIPPLE CAMCO 'DB-6' NIPPLE 3.562 5,901.0 3,533.3 81.76 SEAL ASSY BAKER SEAL ASSEMBLY 3.890 Casing Description B-SAND LINER HH OD (in) 4 1/2 ID (in) 3.48 Top (ftKB) 5,742.6 Set Depth (ftKB) 5,920.3 Set Depth (TVD) … 3,536.0 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) 5,742.6 3,506.3 79.51 HANGER BAKER MODEL B-1 HOOK HANGER (INSIDE CSG) 3.950 5,759.0 3,509.2 79.54 HANGER BAKER MODEL B-1 HOOK HANGER (OUTSIDE CSG) 3.688 5,765.6 3,510.4 79.55 XO BUSHING CROSSOVER BUSHING 5.5" x 4.5" 3.910 5,818.4 3,520.0 79.71 PACKER BAKER PAYZONE EXTERNAL CASING PACKER 3.940 Casing Description A-SAND LINER OD (in) 4 1/2 ID (in) 3.48 Top (ftKB) 5,862.5 Set Depth (ftKB) 9,841.0 Set Depth (TVD) … 3,620.7 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) 5,862.5 3,527.4 80.81 PACKER "HRD" ZXP Liner Top Packer 5.5" x 7.6" 4.970 5,880.1 3,530.2 81.24 NIPPLE RS Packoff Seal Nipple 5.5" 4.875 5,883.5 3,530.7 81.33 HANGER Flexlock Liner Hanger 5.5" x 7.6" 4.853 5,892.9 3,532.1 81.56 SBE 190-47 Casing Seal Bore Ext. 4.75" ID x 6.26" OD 4.750 5,912.6 3,534.9 81.85 XO BUSHING XO Bushing 3.83" ID 6.01" OD 3.830 9,807.6 3,621.2 90.98 XO 4.5x3.5 3.958 Tubing Strings Tubing Description TUBING w/D- SAND LEM String Ma… 4 1/2 ID (in) 3.96 Top (ftKB) 25.0 Set Depth (ft… 5,530.2 Set Depth (TVD) (… 3,468.9 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) 25.0 25.0 0.00 HANGER TUBING HANGER 3.958 504.3 504.2 3.54 NIPPLE CAMCO CAMCO 'DB' NIPPLE 3.875 5,296.7 3,418.3 76.78 NIPPLE CAMCO "DB" NIPPLE 3.812 5,298.2 3,418.6 76.76 Gauge Carrier Polaris Guardian Gauge Carrier w/Guardian Press/Temp 3.958 5,352.4 3,431.3 76.19 SEAL ASSY "GBH-22" LOCATING SEAL ASSEMBLY w/2' space out 3.880 5,355.1 3,432.0 76.24 LINER PACKER "ZXP" LINER TOP PACKER (11.05' Ext) 6.410 5,363.1 3,433.9 76.39 SBE 190-47 SEAL BORE EXTENSION 4.750 5,382.7 3,438.4 76.76 XO BUSHING XO BUSHING 5 1/2" Hyd 563 x IBT 3.950 5,387.9 3,439.6 76.85 HANGER 1 D LEM HANGER 3.688 5,398.5 3,442.0 77.05 HANGER 2 D LEM HANGER 3.688 5,484.9 3,460.2 78.58 SEAL ASSY 4 3/4" 190-47 NON-LOCATING SEAL ASSEMBLY 3.870 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Des Com Run Date ID (in) SN 20.0 20.0 0.00 Heat Trace TYCO DDH HEAT TRACE 1/20/2008 0.000 10,000. 0 3,619.9 88.64 FISH 1/2" Centralizer & 1" Spinner in bottom of wellbore 7/24/2008 0.000 Multiple Laterals, 1J-152, 4/8/2021 5:45:35 PM Vertical schematic (actual) FISH; 10,000.0 A-SAND LINER; 5,862.5-9,841.0 SLOTS; 9,475.0-9,808.0 SLOTS; 9,104.0-9,320.0 SLOTS; 8,843.0-9,102.0 SLOTS; 8,630.0-8,673.0 SLOTS; 8,291.0-8,421.0 SLOTS; 7,310.0-8,075.0 SLOTS; 6,500.0-6,885.0 INTERMEDIATE; 27.3-6,523.2 B-SAND LINER HH; 5,742.6- 5,920.3 B-SAND LINER LEM; 5,501.9- 5,904.3 D-SAND LINER HH; 5,398.6- 5,636.5 LLEM Assembly D-Lat; 4.750 4 3/4" 190-47 Non-Locating Seals; 4.750 SEAL ASSY; 5,484.9 1 jt 4 1/2" IBT w/ SCC Tbg; 4.861 1 jt 4 1/2" IBT w/ SCC Tbg; 4.861 LEM {2} below Hook Hanger; 5.920 HANGER 2; 5,398.5 LEM {2} above Hook Hanger; 6.620 HANGER 1; 5,387.9 Liner Pup; 4.910 XO Bushing, 5 1/2" Hyd x IBT; 5.990 XO BUSHING; 5,382.7 190-47 Seal Bore Extension; 6.270 SBE; 5,363.0 SEAL ASSY; 5,352.4 ZXP Liner Top Packer (11.05' Ext); 6.410 Gauge Carrier; 5,298.2 NIPPLE; 5,296.7 GAS LIFT; 5,063.6 GAS LIFT; 3,154.0 SURFACE; 30.1-2,773.8 Heat Trace; 20.0 NIPPLE; 504.3 CONDUCTOR Insulated 20"x34"; 28.0-108.0 HANGER; 25.0 KUP PROD KB-Grd (ft) 31.01 Rig Release Date 4/22/2006 1J-152 ... TD Act Btm (ftKB) 10,053.0 Well Attributes Field Name WEST SAK Wellbore API/UWI 500292329800 Wellbore Status PROD Max Angle & MD Incl (°) MD (ftKB) 7,605.55 WELLNAME WELLBORE1J-152 Annotation Last WO: End Date 1/17/2008 H2S (ppm) 10 Date 11/8/2014 Comment SSSV: NIPPLE Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft )Type Com 6,500.0 6,885.0 3,636.4 3,632.8 WS A3, WS A2, 1J-152 3/29/2006 32.0 SLOTS ALL SLOT DESIGNS ARE THE SAME: Alternating slotted/solid pipe 2.5" long x .125" 7,310.0 8,075.0 3,662.8 3,638.6 WS A2, 1J-152 3/29/2006 32.0 SLOTS Alternating slotted/solid pipe 8,291.0 8,421.0 3,630.1 3,623.0 WS A2, 1J-152 3/29/2006 32.0 SLOTS Alternating slotted/solid pipe 8,630.0 8,673.0 3,630.8 3,633.0 WS A2, 1J-152 3/29/2006 32.0 SLOTS Alternating slotted/solid pipe 8,843.0 9,102.0 3,632.0 3,632.2 WS A2, 1J-152 3/29/2006 32.0 SLOTS Alternating slotted/solid pipe 9,104.0 9,320.0 3,632.2 3,632.4 WS A2, 1J-152 3/29/2006 32.0 SLOTS Alternating slotted/solid pipe 9,475.0 9,808.0 3,629.4 3,621.2 WS A2, 1J-152 3/29/2006 32.0 SLOTS Alternating slotted/solid pipe 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 3,154.0 2,403.1 CAMCO KBG-2- 1R 1 Gas Lift GLV BK 0.156 1,417.0 11/3/2015 2 5,063.6 3,352.5 CAMCO KBG-2- 1R 1 Gas Lift OV BK 0.313 0.0 11/2/2015 Notes: General & Safety End Date Annotation 7/24/2008 NOTE: VIEW SCHEMATIC w/9.0REV 1/17/2008 NOTE: WORKOVER PULL ESP ASSY; NEW COMPLETION w/GLM/NIP/LEM 10/6/2007 NOTE: WAIVERED WELL T x IA COMMUNICATION - PACKERLESS WELL , ESP FAILED 4/24/2006 NOTE: MULTI-LATERAL WELL: 1J-152 (A-SAND), 1J-152L1 (B-SAND), 1J-152L2 (D-SAND) Multiple Laterals, 1J-152, 4/8/2021 5:45:36 PM Vertical schematic (actual) FISH; 10,000.0 A-SAND LINER; 5,862.5-9,841.0 SLOTS; 9,475.0-9,808.0 SLOTS; 9,104.0-9,320.0 SLOTS; 8,843.0-9,102.0 SLOTS; 8,630.0-8,673.0 SLOTS; 8,291.0-8,421.0 SLOTS; 7,310.0-8,075.0 SLOTS; 6,500.0-6,885.0 INTERMEDIATE; 27.3-6,523.2 B-SAND LINER HH; 5,742.6- 5,920.3 B-SAND LINER LEM; 5,501.9- 5,904.3 D-SAND LINER HH; 5,398.6- 5,636.5 LLEM Assembly D-Lat; 4.750 4 3/4" 190-47 Non-Locating Seals; 4.750 SEAL ASSY; 5,484.9 1 jt 4 1/2" IBT w/ SCC Tbg; 4.861 1 jt 4 1/2" IBT w/ SCC Tbg; 4.861 LEM {2} below Hook Hanger; 5.920 HANGER 2; 5,398.5 LEM {2} above Hook Hanger; 6.620 HANGER 1; 5,387.9 Liner Pup; 4.910 XO Bushing, 5 1/2" Hyd x IBT; 5.990 XO BUSHING; 5,382.7 190-47 Seal Bore Extension; 6.270 SBE; 5,363.0 SEAL ASSY; 5,352.4 ZXP Liner Top Packer (11.05' Ext); 6.410 Gauge Carrier; 5,298.2 NIPPLE; 5,296.7 GAS LIFT; 5,063.6 GAS LIFT; 3,154.0 SURFACE; 30.1-2,773.8 Heat Trace; 20.0 NIPPLE; 504.3 CONDUCTOR Insulated 20"x34"; 28.0-108.0 HANGER; 25.0 KUP PROD 1J-152 ... WELLNAME WELLBORE1J-152 Last Tag Annotation Depth (ftKB) End Date Wellbore Last Mod By Last Tag:1J-152L2 lmosbor Last Rev Reason Annotation End Date Wellbore Last Mod By Rev Reason: GLV C/O 11/11/2015 1J-152L2 lehallf Casing Strings Casing Description D-SAND LINER OD (in) 4 1/2 ID (in) 3.48 Top (ftKB) 5,603.4 Set Depth (ftKB) 13,086.0 Set Depth (TVD) … 3,357.9 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) 5,603.4 3,475.6 89.11 SLEEVE BAKER 'HR' LINER SETTING SLEEVE 5.000 5,645.2 3,475.2 92.01 XO BUSHING CROSSOVER BUSHING 5.5" x 4.5" 4.500 13,050.6 3,357.5 88.69 XO Reducing CROSSOVER 4.5" x 4.5" 3.500 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft )Type Com 5,651.0 6,712.0 3,475.0 3,429.9 WS D, 1J-152L2 4/1/2006 32.0 SLOTS ALL SLOT DESIGNS ARE THE SAME: Alternating slotted/solid pipe 2.5" long x .125" @ 4 Circumferential adjacent rows, 3" Centers staggered 18 deg., 3 ft. non- slotted ends 7,013.0 8,250.0 3,446.8 3,419.9 WS D, 1J-152L2 4/1/2006 32.0 SLOTS Alternating slotted/solid pipe 8,336.0 10,370.0 3,418.6 3,396.6 WS D, 1J-152L2 4/1/2006 32.0 SLOTS Alternating slotted/solid pipe 10,413.0 13,051.0 3,394.7 3,357.5 WS D, 1J-152L2 4/1/2006 32.0 SLOTS Alternating slotted/solid pipe 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) Notes: General & Safety End Date Annotation 1/17/2008 NOTE: WORKOVER PULLED ESP ASSY; NEW COMPLETION w/GLM/NIPPLE/LEM 10/6/2007 NOTE: WAIVERED WELL T x IA COMMUNICATION - PACKERLESS WELL , ESP FAILED 4/24/2006 NOTE: MULTI-LATERAL WELL: 1J-152 (A-SAND), 1J-152L1 (B-SAND), 1J-152L2 (D-SAND) Multiple Laterals, 1J-152L2, 4/8/2021 5:45:37 PM Vertical schematic (actual) D-SAND LINER; 5,603.4- 13,086.0 SLOTS; 10,413.0-13,051.0 SLOTS; 8,336.0-10,370.0 SLOTS; 7,013.0-8,250.0 SLOTS; 5,651.0-6,712.0 INTERMEDIATE; 27.3-6,523.2 D-SAND LINER HH; 5,398.6- 5,636.5 LLEM Assembly D-Lat; 4.750 LEM {2} below Hook Hanger; 5.920 HANGER 2; 5,398.5 LEM {2} above Hook Hanger; 6.620 HANGER 1; 5,387.9 Liner Pup; 4.910 XO Bushing, 5 1/2" Hyd x IBT; 5.990 XO BUSHING; 5,382.7 190-47 Seal Bore Extension; 6.270 SBE; 5,363.0 SEAL ASSY; 5,352.4 ZXP Liner Top Packer (11.05' Ext); 6.410 Gauge Carrier; 5,298.2 NIPPLE; 5,296.7 GAS LIFT; 5,063.6 GAS LIFT; 3,154.0 SURFACE; 30.1-2,773.8 Heat Trace; 20.0 NIPPLE; 504.3 CONDUCTOR Insulated 20"x34"; 28.0-108.0 HANGER; 25.0 KUP PROD KB-Grd (ft) 31.01 Rig Release Date 4/22/2006 1J-152L2 ... TD Act Btm (ftKB) 13,112.0 Well Attributes Field Name WEST SAK Wellbore API/UWI 500292329861 Wellbore Status PROD Max Angle & MD Incl (°) 94.74 MD (ftKB) 7,613.94 WELLNAME WELLBORE1J-152 Annotation Last WO: End Date 1/17/2008 H2S (ppm) 10 Date 11/8/2014 Comment SSSV: NIPPLE 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 ❑ Other Stimulate ❑ Alter Casing ❑ Change Approved Program ❑ Plug for Rednll ❑ •erforate New Pool ❑ Repair Well ❑ Re-enter Susp Well ❑ Other: RPPG MBE TRTMTE] 2. Operator Name: ConocoPhillips Alaska, Inc. 4. Well Class Before Work: 5. Permit tc Drill Number: Development ❑ Exploratory ❑ Stratigraphic❑ Service ❑ 206-018 3. Address: P. O. Box 100360, Anchorage, 6. API Number: Alaska 99510 50-029-23298-61 7. Property Designation (Lease Number): 8. Well Name and Number: ADL 25661, ADL 25662 KRU 1 J -152L2 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 13,112 feet Plugs measured None feet true vertical 3,358 feet Junk measured None feet Effective Depth measured 13,085 feet Packer measured 5,502 feet true vertical 3,358 feet true vertical 3,464 feet Casing Length Size MD TVD Burst Collapse ULATED 20^x34° 80 feet 16 108' MD 108'TVD SURFACE 2,744 feet 10 3/4 2,774'MD 2198'TVD R�CveeEIVE INTERMEDIATE 5,376 feet 7 5/8 " 6,523' MD 3638' TVD D -SAND LINER 7,483 feet 4 1/2 " 13,086' MD 3358' TVD NOV 0 5 2019 Perforation depth: Measured depth: 5651-6712. 7013-8250 8336-10370 10413-13051 feet A 0 G Cr'`' True Vertical depth: 3475-3430. 3447-3420 3419-3397 3395-3357 feet Tubing (size, grade, measured and true vertical depth) 4.5 " L-80 5,530' MD 3,469' TVD Packers and SSSV (type, measured and true vertical depth) LINER PACKER- "ZXP" LINER TOP PKR 5,502' MD 3,464' 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:1 480 365 1550 - 259 Subsequent to operation: 1617 365 1640 - 269 14. Attachments (required per 20 AAC 25.070, 25.071, 8 25.293) 15. Well Class after work: Daily Report of Well Operations O Exploratory ❑ Development Service ❑ Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16. Well Status after work: Oil O Gas ❑ WDSPL ❑ Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ ❑ 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: 319-436 Contact Name: John Peirce Authorized Name: John Peirce Contact Email: John.W.Peirce@cop.com Authorized Title: Sr. Wells Engineer � �� .4 Contact Phone: (907) 265-6471 Authorized Signature: �/ — Date: /�9 I/TL �fj:y l l C-/ �p din ['Fly/ NOV j Form 10-404 Revised 4/2017 AW (•/ RBD1 SII!�lNO 0 6 2019 Submit Original Only Conoco`PhillKUP PROD WELLNAME U-152 WELLBORE U-152 a, ro; �— AMsktinc Dam CONDIXTOR ws JIT, 1ESAME: Alternating oned/solid pipe 2.5" long .125•• san I Tr I Tm I dat I ioa) I Run mm HANGER I: HANGER 2', D -SAND LINER HH: .No aEMD LINER HH INTERMEDIATE, P.%,E2S2- .LOTS; ],31n68,N5n� SLOTS;. Zn.D 4210�-. = SLOTS, SIX.= SLOTS 9475�.KSO� ASML LINER, 58NLE5994101 Fl3H', 1p0."0o �,��t�t. KUP PROD WELLNAME 1J-152 WELLBORE 1J -152L2 ConoeoPhdlip$ Well Attributes Max Angle & MD TD ame 1e APWWI—1-osStates I clll MDIfINB1 pcl Bim (XKBI AI85Kd, 11C. IWFCT CnK I 01ioRF1 Fenn I �, ...... NIPPLE MulEple LNnY,IJ-15RL211513019 7I^o:39gM Last Tag Vinien.med ,enesp Annionlon Dsp,(nl(B) End paraWe11M1e LaslMwl Ry ................................................................ ........................ Last Tag: iJ-15212 Imosbor Last Rev Reason HANOER35J ...................... Sensation End Date WeIIWte Lasl Motl By Rev Reason: GLCIO11/112015 iballfCasing Strings MOM casing CescNpT"oppe) SAND LINER 41/2 mpn) TOplKKe) setDepthpKB) set On In(rvJILen 9._Dredo IDpTN,eatl 348 5603.4 13,0860 3,3519 11.60 L-80BTCLiner Details NaWWmen"OealasO5,645.2 Ke)TOP(TVp)(RKB) Me. 1. Tap lnui r) Item DesCam56031 34]56 89.11 SLEEVE BAKER'HR'LINER SETTING SLEEVE 5.0011CONDUCTOR 31]52 92.01 XO BUSHING CROSSOVER BOSHING 5.5"x4.5' 4.SWNIPPLE; eAs3p.6 3,35].5 869 XO Reducing CROSSOVER 4.5"x 4.5" 3.500WNT Eo Perforations & Slots Shot Topffl BISIXKSI Top (TVD) min Ban (TVD) mleB) Linleamne Dale Den Isnsism ) Type CO. 5,6510 6,712.0 3,475.0 3,429.9 W U. J- 41112006 32.0 SLOTS ALL7L TDESIGN ARE 1521-2 THE SAME: Altemaiing SURFACE. 30.1-R, TY.a 5lalledlsclid pipe 2.5" long X.12$" @ 4 Circumferential adjacent Centers staggered rows,,on 18 deg. . 3 fl. n-slotletl ends 7,013.0 8,2500 3,44 6.8 3,4199 WE D,1 - 152L2 4112006 32.0 SLOTS AlernatingslDMNsolld pipe ras"ET RIse'a 8,336,0 10,370.013,418fi 3,3866 WS D, 11- 521-2 4/12006 320 SLOTS Allemanng Sanetllsplitl pipe 1p,41JO I 13,051.0 1 3,394.7 3,35]51WSJ- 4/12006 32.0 SLOTS Altani Mini pipe Notes: General & Safety GAS LIFT: Sees.6 End Dale Annotation 4/24/2006 NOTE: MULTI -LATERAL WELL: 1J-152 (ASAND), 1J -152L1 (BSAND),1J-1521-2 (D -SAND) 1016/200> NOTE: WAIVERED WELL T s A COMMUNICATION- PACKERLESS WELL, ESFFAILED NIPPLE', 5R6.7 111712008 NOTE: WORKOVER PULLED ESP ASSY; NEW COMPLETION W/GLMMIPPLEALEM Ge�Me Lufiir; 5,19.$ SEALASSY B3io 4 SBE; S.a xO BUSXIHG', KPNOER I; 5,SR19 NgNGER 2; 5,3995 INTERMEDNTE;P38,SZi2 DSAND LINER XH; OSES Ease SLOTS; S.6S1➢6.7120 SLOTS, 7,013032a.0 SLOTS;8.336,010,3700 t SLOTS: 10413013,X10 DSAND LINER: 4BL0.n- 13,Wed 1 J-1 52L2 OFFSET PRODUCER FOR 1J -156L2 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 -152L2 Permit to Drill Number: 206-018 Sundry Number: 319-436 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.00gcc.alaskc.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, O'Z'IW Daniel T. Seamount, Jr. Commissioner DATED this,?- day of September, 2019. RBDMS L ( OCT 0 12019 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 9n AAr. 9F 2R0 1. Type of Request: Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Repair Well ❑ Operations shutdown❑ Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing ❑ Change Approved Program Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other: RPPG MBE TrtmtO 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhilli s Alaska Inc. Exploratory ❑ Development El . Stratigraphic ❑ Service ❑ 206-018 3. Address: 6. API Number: P. 0. Box 100360, Anchorage, Alaska 99510 50-029-23298-61-00- 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? N/A KRU 1J -152L2 Will planned perforations require a spacing exception? Yes ❑ No ID 9. Property Designation (Lease Number): 10. Field/Pool(s): ADL 25661; ADL 25662 Kuparuk River Field /West Salk 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): 13,112' 3,358' - 13065 3358 1500psi NONE NONE Casing Length Size MD TVD Burst Collapse Conductor 80' 16" 108' 108' Surface 2,744' 103/4 2,774' 2,198' Intermediate 5,376' 75/8 6,523' 3,638' Liner 7,483' 41/2 1 13,086' 3,358' Perforation Depth MD (ft): Perforation Depth TVD (ft) ITubing Size: Tubing Grade: Tubing MD (ft). 5651-6712,7013.8250,8336.10370, 34753430,3447-3420, 4.500" L-80 5,530' 10413-13051 3419-3397 3395.3357 Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): PACKER - ZXP Liner Top Pkr 5355' MD and 3432' TVD SSSV - NONE N/A 12. Attachments: Proposal Summary 0 Wellbore schematic C] 13. Well Class after proposed work: - Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stratigraphic ❑ Developmenl0 Service ❑ 14. Estimated Date for 10/15/2019 15. Well Status after proposed work: Commencing Operations: OIL O ' WINJ ❑ 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 c7 / �7 rI Authorized Signature: / �I/ E ' Date: / y9 Contact Phone: (907) 265.6471 (G COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 311-L43V Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: // No - Post Initial Injection MIT Req'd? Yes ElL9 Spacing Exception Required? Yes No Subsequent Form Required: / ❑ [i3, APPROVED BY Approved by: COMMISSIONER THECOMMISSION Date: i 9/25/ 9 0 M h �b� 118481 RBDMS�� OCT 9zd I � it Form and (/ Fo b-4 ev ed a/zDi] Approved application is veli for 2 o h f t e of approval. Attachm n m Duplicate KUP PROD WELLNAME 1J-152 WELLBORE 1J-152 ConocoPhillips Naska, Ilw Inwmla Lelxp.+}+529mE0,e>:m�e AM Perforations BSlots vxtimsMmalM lamvml sna, oen .._............. .. .'..'......... Top et IsnoKm HANGER; Y.o�� Top mMBl III IttNm IflNB) (Me) Yr Llnke02one Type Com ......... ............... 6.5000 6.885.0 3.636.4 3832.8 A3. WS 200 32912006 32.0 SLOTS ALL LOT ti 1J-152 THE SAME' pe 2.6 ling Skt25'sSo id pipe 2.5" long 2.125" COupumoR inWaW .DoI xiOiwo 7,310.0 8,0]50 3,862.8 3, 38.6 WS A?1J-152 &2912006 320 SLOTS ernaung used/solid Pipe rviPpLe, 5019 NWTIe[+:mo 8,29TD 8,4210 3,6 .i 3,623.0 WS A2, 1J-152 &2912006 320 SLOTS Ikmanng slpded/sDlid vice 8,6300 8,673.0 3,630.8 3,6330 W3 A2, IJ -152 3/29/2006 32.0 SLOTS liftming SlDnedl6Dlid Pipe SURFACE 30 14.M 8,843.0 9,102.0 3,632.0 3,6322 WS A2, 1J-152 W912006 So SLOTS AXernating slonedlsolid Dipe 9,104.0 9320D 3,6322 3.632.0 WS A2, 1J-152 3I29/KC6 32.0 1 SLOTS lAfteounng dolled/solid pipe DA6 UFT: 3.1510 9,479.0 9808.0 3,6n.d $fi21.2 WS A2, 1J-152 3I29I20W 32.0 SLOTS Alkmeling SlotleNSDlid Pipe Mandrel Inserts GAa UFT:4C61.6 St on NIPPLE: Ste.] 'Sioni','NS' on Top DVD)Valve N Top IXNB) pa l Make MOEeI OD(in) SeN Type —Ift Type I PITFO (in) Run Ipig Run DI COT 1 3,1540 2,403.1 CAMCO KB -- 1 Gas Lift GLV BK 0.156 1,417.0 111312015 139 1 2 5,063.6 3.352.5 CAMCO KBGI 1 I,AS Ll. IJV BK 0.313 0.0 1102015 SEAL ASSY I E% 4 113 I 1 1 1 Sae,esee0 Notes: General& Safety %O III5.392] Enc Dale Annolalion X4NGER 1; S.YI.B 4I24I2W6 NOTE:MULTI-LATERAL WELL'. 1 J-152(A-SAND).1J-152LI(13SAND), 1 J -1501D -SAND) r 10I62007 NOTE: WAIVERED WELL ixIA COMMUNICATION-PACKERLESS WELL, ESP FAILED HANGER D. 5,3965 1117QON NOTE: WORKOVER PULL ESP ASSY; NEW COMPLETION w)GLMINIP&EM ]2412008 JNUIIE. VIEW SCHEMATIC W190REV SE9LABBY; S.�Ba.B DBAND LINER HN; 5,396.& 56365 84P NO DNEN LEM:550H & Sm93 6 DLINER HH: S]42& S,ea13 NTERME.ATE; T]... SLOTS;SSD3.OEI SLOTS, ],31D0UPSO0 _ SLOTS: e,aH 0-LQI 0- SLOTS: SHNSS ,03.0 SLOTS', S,IM.OHA.o SLW$;94750e.E050- ASAND YNER; S662S96N 0� � FISH, 10O1 ConocoPhillips Alaska, Inc. KUP PROD WELLNAME 1J-152 WELLBORE 1J -152L2 Bat WO: MUBPk I.lxm.+4-+szu. SRryA,ai:s38 AA1 Last Tag veMJ edleeaec lxLVll .—tan- D-ORYBLa) I rna Dem wen0ae ..Rd By Last Iag: iJ-15212 ImSO., Last Rev Reason HARRIES. 210 Ann..1— End D. Wellbore LesIMM By -------"""...."""""...... ------ Rev Reason: GLVCIO 11111wm 1J -152L2 IJSh.Iit Casing Strings casl,lq Oeecavron 0011.4 D -SAND LINER 412 l0 (In Top lnnel 348 5,6034 se[pepinlRNal see OePIn IT/DL.. wvLen p._praae roarnreaa 13,086.0 3.35].9 11.60 L-eo BTC Liner Details Tap (ME) roplrv0l (nNB) T.11 -1 f) Nem Des omm com 6n)xl ID 5,6034 3.475.6 89.11 SLEEVE BAKER' HRLINER SETTING SLEEVE SOOo CONDUCTOR IIUWVW z.rw-¢aD+oe.D 5.645.2 3,4]5.2 I 92.01 JAU BUSHING ICROSSOVEI 55"x4.5" 4.500 NIPPLE: 904.3 13A50.6 3,35)5 8869 I SO Reducing 1ROSSOVER4e x45" 3.500 HMTro', NO Perforations& Slots snm Den TOP RKS 1 BM p(e 1 1 TaMB) DIKa) B dab LDNed lane Des (snoWn I type cam 5,651.0 6,]12.0 .475.0 3,429.9 ,4 WS D. 1J- d1112008 32.0 SLOTS AL q 152L2 THE SAME: ANernating SURFACE 3111,113-0 StaBedlsolid pipe 2.5" long %.125" @ 4 Circumlerental adjacent rows. 3" Centers staggered 18 deg, 3 ft. non-sloded ends 7,0130 8,250.0 ].446.8 7,4199 WSD, - 1520 4812006 32.0 SLOTS AI@meting sone solid pipe GAS LOT: 3, 164.0 8.336.0 j 10,3]0.0 3,4186 3,3966 WSD, - 152L2 4/12006 320 SLOTS Allerna0ng s.dellsolid pipe 10413.0 13,051.0 3,3941 3,39.5 J. J- 41112006 32.0 SLOTS Anemaeng SIONedlsolid 1 5212 I pipe Notes: General & Safety GAS UR: sl93.6 End Dale Aanp.nd n 41242006 NOTE'. MULTI -LATERAL WELL. 1J -1521A -SAND), 1J -152L1 (B -SAND), 1J -152L2 (D -SAND) 1 01612 00 7 NOTE: WAVERED WELL T x IA COMMUNICATION- PACKERLESS WELL, ESP FAILED NIPPLE:5,0ee.7 1117120D8 INOTE WORKOVER PULLED ESP ASSY: NEW COMPLETION w/GUANIPPLEnEM GWNe c.,,I.,. s,aez SEALASSY:4353A See: 43.0 xO SLENNG', 5 312 7 ..GER 1:5.99].8 RAWER 2. E.5 IM T,ESIM.9 NDLIAER DS4xDtIHER HH, 5,i.. 5,6Y5 SL01S: 9,661 OR7130 SLOTS. 7.0130a.z90G slots: es9e.alp.9m.D SLOTS. 1.413013.10 OSANO LINER: 5 UJ3.0. 130SED 1J -156L2 to 1J-1521-2 Reformed Polymer Particle Gel Treatment of D Sand Toe MBE U-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 bbis 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. 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 ❑ Other Stimulate ❑ Alter Casing ❑ Change Approved Program ❑ Plug for Redrill ❑ erforete New Pool ❑ Repair Well ❑ Re-enter Susp Well ❑ Other: MBE Cmnt Isolation ❑' 2. Operator 4. Well Class Before Work: 5. Permit to Drill Number Name: ConocoPhillips Alaska, Inc. Development El Exploratory ❑ Stratigraphic❑ Service ❑ 206-018 3. Address: P. O. BOX 100360, Anchorage, 6. API Number: Alaska 99510 50-029-23298-61-00 7. Property Designation (Lease Number): 8. Well Name and Number. KRU U-1521-2 ADL 25661, ADL 25662 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pool(s): NIA Kuparuk River Field / West Sak Oil Pool 11. Present Well Condition Summary: Total Depth measured 13,112 feet Plugs measured None feet true vertical 3,358 feet Junk measured None feet Effective Depth measured 13,085 feet Packer measured 5,355 feet true vertical 335 feet true vertical 3,432 feet Casing Length Size MD TVD Burst Collapse CONDUCTORSURFACE RECEIVE 2,744 feet 10 3/4 " 2,774' MD 2198' TVD :_ INTERMEDIATE 5,376 feet 7 5/8 " 5,403' MD 3638' TVD LINER 7,483 feet 41/2 " 13,086' MD 3358' TVD MAY 3 1 2019 AOGCC Perforation depth: Measured depth: 5651-6712 7013-8250 8336-10370 10413-13051 feet True Vertical depth: 3475-3430 3447-3420 3419-3397 3395-3357 feet Tubing (size, grade, measured and true vertical depth) 4.5 " L-80 5,530' MD 3,469' TVD Packers and SSSV (type, measured and true vertical depth) PACKER - BAKER ZXP Liner Packer 5,355' MD 3,432' TVD SSSV -NONE N/A 12. Stimulation or cement squeeze summary: Intervals treated (measured): WA Treatment descriptions including volumes used and final pressure: 18 Representative Daily Average Production or Injection Data Oil -Bbl Gas-Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: Shut -In - - - Subsequent to operation: 21 1326 2076 - 370 14. Attachments (required W W AAC 25. W0, 25.071, &25,283) 15. Well Class after work: Daily Report of Well Operations 171 Exploratory ❑ Development O Service ❑ Stratigraphic ❑ 16. Well Status after work: Oil p Gas ❑ WDSPL ❑ Copies of Logs and Surveys Run ❑ Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ ❑ 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: 319-198 Contact Name: John Peirce Authorized Name: John Peirce Contact Email John.W.Peirce@cop.com Authorized Title: Sr. Wells Engineer Contact Phone: Phone: (907) 266.6471 -z-.�� Date:s�3ot/1� Authorized Signature -�/ W z. Form 104WRevised 4/2017 'T Vy-L (vIJ3//9 3BDMSZL' JUN p 35yb1n�tOriginal Only 1J -152L2 OFFSET PRODUCER FOR 1 J-1561_2 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 FLOW 6 SPF), DROP 1/2" BALL TO FIRE GUNS, TOP SHOT AT 11 170'RKB, BOTTOM SHOT @ 11 175'RKB, GUNS CONFIRMED FIRED, 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 -1 OK 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 10,797' 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. KUP PROD WELLNAME 1J-152 WELLBORE 1J-152 ConocoPhiOips Well Attributes Max Angle 8, MD TD ftr WLT Name We11Mre APYUWI Welllore Stilus ncl C) NUMI) ASIBIm(DNBI Alaska, Ino WEST BAK 500292329800 PROD ],605.55 10,0530 NIPPLE MunFN 16en6-iJ-14.5/9YAIeeSB. 1-7--ti-get Tag Vernal uS:iew)I Annotation Depth(WI1 End Data We11Me Not MW By .__......,__.......................................... ................_.._... .ANGER xo CONDUCTOR I""No mxar, za.oT.0 NIPFLF.5W.3 IrtTmca mo euaEAce, 33.11?nae GAS LET. Mata GAS LIFT: 50313 SIME; 5267 caRa Cemm:5t933 SEAnaSYESEC4 Sees.sv.o x0 auvohG, s.sez.7 HANGE41:53N.S NANGERTS.YMs SEALASSY.Essi OSANO LINER HM; S,�6 9.5ffis - eSAND LINER LEM, ESONA sper.3 S - SAND LINER HH; E7SaS- 59213 NTERMEIXOE: naesng smTs;e.mo..'sa o-_ _ SLora:7.3e-Par .o- SLOTS ETENAT .4ao- _ SLOT8:8.S30."En aLOTe: e,eaT.oe.lm.o- - SLOTSI9.104,05.320.o� SLOTS. 9,4756,8.-90-:: - ASND LINER. SAID as tut 0� FISH, 100000 Lest Tag: 1J-152 Ildrospor Last Rev Reason Annotation EM Data WellEare tes[MW ay Rey Reason: GLV CIO 111112015 I1J-152 lintesit Casing Strings Casing Description On (in) IDe.) Top (103) .. Deth Ila.) .10.pIN ITVDL.. WYLan g.. Grade CONDUCTOR 16 15.06 280 1080 108.0 62`0 H40 Insulated 20"x34" Tap ]Nage WELDED Casm9 Description OO lin) Ipllnl Top pg(6) Set DelNnlKKe) See OepinUion WYLen ll._Grade SURFACE 10 Y0. 9.95 30.1 2,])38 2,1980 45.50 LA0 rap Throaa BTC Casing Oescriplion O011nl I011n) Top las, SSL DeWh(Ita61 sMO Tien .n 11... GrWe INTERMEDIATE ]518 6.87 27.3 6,5232 3.63].9 29.70 LA0 Tap Theta BTC -M Casing Desviption ori in) 111 pen Top lttKel sin De�I e., Set OapM j g,.. WYLen (F.. GrMe D -SAND LINER HH 412 348 5,3986 5635.5 3487.5 11.60 L-80 Top IN. BTC Liner Details N- reuD Topgnig Top IVD)WE) Top Incl C) 1. Dee Com on) 5,398.6 3,4428 77.05 HANGERI BAKER B-1LEM HOOK HANGER(lnade CSG) 4950 5,415.0 3,4453 77 Be HANGER2 BAKER BALEM HOOK HANGER (Outside CSG) 4950 5,5085 3,46LITS1 78.97 PACKER BAKER PAYZONE EXTERNAL CASING PACKER 7,625 5,60].8 3482] 8020 BENT JT 3,476 Cashq Description 00 (in) IDgn) Tap(NLa) 9NDepth dl Sal Death (ND)... Wihin 9...ones Top IDrwa B -SAND LINER LEM 412 3.96 5,501.9 5,904.3 3,533.7 1260 LA0 IST Liner Details NwmesMD Too NEXT) Top(WUNRKIN Top mtl (9 Item Des Co. (m) 5,501.9 34636 78.86 PACKER ZXP LINER TOP PACER 4.970 Elan0 34672 79.18 SBR 10947 CASING SEAL BORE RECEPTACLE 4.750 5540.6 34708 79.47 XO BUSHING BAKER CROSSOVER BUSHING 4.750 5,742.1 3,506.2 7951 HANGER LEM ABOVE HOOK HANGER 4950 5,767.0 3,5107 7.55 HANGER LEM INSIDE HOOK HANGER 4.50 5,825.3 3,5212 7.88 NIPPLE CAMCO'DBA'NIPPLE 356 5,901.0 3,5333 81.]6 SEAL ASSY BAKER SEAL ASSEMBLY 3890 Casing 0e5trtplbn 00 (In) ID (In) Top IHLe) SeL Mpm ((1K.) sal Death(ND).. WNsn p... GrWe Tap Throad B -SAND LINER HH 4V2 348 5,742.6 5,9203 3,536.0 11.60 L-80 BTC Liner Details Nanaal in IDplttKel Top PVC)ME) Top not ri nem mat Com (n) 5,742.6 3,5(6.3 7951 HANGER BAKER MODEL 8-1 HOOK HANGER (INSIDE CSG) 3.950 5,759.0 3509.2 7954 HANGER BAKER M DEL87 H N OU IDE 3888 CSG) 5, 65.6 3,5104 7955 XO BUSHING CROSSOVER BUSHING 5.5"x4.5- 3.910 5,818.4 3,520.0 7971 IPACKER BAKER PAYZONE EXTERNAL CASING PACKER 3.940 maFp DncripYonOO lin) NO (in) TOS) BM OePIh IaILe) sal OeNh RVD)... V/IlLen ll._GMe FREThreaa A -SAND LINER 412 348 5,862.5 9,8418 3,620] 11.60 L40 BTC Liner Details Nominal 10 Top(Xnel Top (NOMUN Top Incl Cl .in Des Com nn) 5862.5 3,5274 8081 PACKER "PIRG" ZXPLIner Top Packer5.S'x76" 4.970 5, 80.1 3,530.2 81.24 NIPPLE RS Packets Seal Nipple 5.5' 4875 5, 83.5 3,5303 8183 HANGER Flexlotle Liner Hanger 65"x76" 4853 5 29 3,532.1 8156 SBE 19047 Casing Seal Bore Ext 475- ID 728" -OD 4350 5,912.6 3,5349 81.85 XO BUSH ING XO Bushing383' ID 6,01" DID 3.830 7807.6 3,6212 90.98 X045.35 3.958 Tubing Strings Teeing DesW inion .1N q Ma.. TUBING wID- 412 SAND LEM m p.1 396 Top WS, 250 set Depth (n.. 5,530.2 set Depth (rv0) (-1.1 3,468.9 11om) 1260 IG,, L-80 top eonneamn DIM Completion Details Top(TVD) Set) I E mend Top WE" We) C) fieri Co. 10 (in) 250 250 000 HANGER TUBING HANGER 3958 504.3 504.2 3.54 NIPPLE CAMCO CAMCO'DB' NIPPLE 3.875 5,296) 3,418.3 7678 NIPPLE CAMCO 'DB" NIPPLE 3.812 5=,B 3,4186 7676 Gauge Carrier Polaris Guardlan Gauge Carver adGeandian Preasriemp 3.958 5352.4 3431.3 66.19TEAL -ASSY "GBH -22" LOCATING SEAL ASSEMBLYw' space out 3880 5355.1 34320 7624 LINERPACKER "ZXP" LINERTOPPACKER (1185'Ex0 641 5,363.1 3,433.9 76.39 SBE 19047 SEAL BORE EXTENSION 4350 5,382] 3,4384 7676 TO BUSHING XO BUSHING 5 VT Hyd 563 x IBT 3.950 5,387.9 3,4396 7685 HANGERI DLEM HANGER 3.688 5,398.5 3,4420 7705 HANGER 2 D LEM HANGER 88 5484.9 3,4602 7858 SEAL ASSY 4314" 19047 NON4OCATING SEAL ASSEMBLY 3.870 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Tovlrv9) top mol Top(MB) (RKa) (°) has Lam Run Data 10 (in) 20,0 200 OOO Heal Trace TYCO DDH HEAT TRACE 120208 0.000 10,Lul 36199 8864 FISH Ila "Cenkalizer8l"Sp inner in INNER of wellDpre ]24208 0800 KUP PROD WELLNAME 1J-152 WELLBORE 1J-152 ConocoPPhillips AJBske, Inc. F— I L�] MJBPMLMxN-ulsz. soam19 e:.1AM Perforations 6 Slob v.awemm..x la<kM TOPERS) BMnIKB) TOP (TVD) MISS) Ron l D) ME) Unkee]nne Dam Skm Dane Iskame 1 TYM Com ............_ . ... ...... H4NGEX: R5.0� """"......-"""""""""""""""""' 6,500.0 6.8850 3,636.4 3,632.8 WS A3 'WS AZ. V-152 3292006 32.0 SLOTS ALL SLOT DEI N5 AHL THE SAME'. Anemating slonedlSolid pipe 2.5- long x.125" 7,310.0 8,0150 3,6628 3,638,6 WSA2,1J-152 32W2006 32.0 9LOTS ARernakng slonetl/solid h^ CONDUCTOR McWme 2OYNIPPUE D43 rvIPPLe,Ea.9 plpe 8,291.0 8421.0 3,630.1 3,823.0 WS ,1J-152 329I200fi 320 SLOT Altamagng slopeNsolid II.IT�:20.o pipe 8,630.0 8,6710 3,630.8 3,633.0 WS A2, 1J-152 3/2912006 32.0 BLOTS Altamanng slode sDlitl PIN WRrACE: SO 1.2,m5 $8430 91020 3,6320 3,632.2 WS A2, 1 J-152 3292006 32.0 BLOTS Anemating slode solitl pipe 9,104.0 9,320.0 3,632.2 3,632.4 WSA2, 1J-152 3292006 32.0 SLOTB emaeng slowlisolid pipe GAsuFT SIS4.0 9,475.0 9,8080 3,829.4 3,621.2 WSA2. 1J-152 329200fi 41,0 SLOTS erna6ln slonetl/solid 1 pipe Mandrel Inserts WSLIFT: S.l08 Me Top DV01 IBKBI Valve Make Model Op11n1 See'/ TYPe Twe PwISlee TYPe Iln)IPall TROT)NIPPLE:53EeT Run Oa@ Lom r p.Cu Bms2 F25,0 2,403.1 OAMCO KB -- 1 Gas Lih GLV BK 0.156 141)0 11 2015 1R 3,3525 AM K - 1 Gas Lift OV BK 0.313 015 SEALASSv: s.u2.4 1R Notes: General E Safety SEE; 5'mO Ene Odle Mnomrwn xo a115NING: 5.3R.T 41240006 NOTE MULTI -LATERAL WELL; IJ-152(ASANO).1J-152L1(BSAND), 1 J-1 52U (D -SAND) RANGER t 53EI9 101N200J jn.,E..,V,NEID WELL TxIACOMMUNICATION -PACKERLESS WELL, ESP FAILED HANGER P. E..5 1/1712006 INOTE: WORK VER PULL ESP ASSY; NEW COMPLETION w GLMNIIFIEM 71242008 NOTE: VIEW BCHEMAHU MU,UKEV SEALASSY;5,ASI 0. DLINERHH:5.3il S®55 &&WD LINER IEM:5.501 & 5}W] BSPNO LINER HH, S.TQB S9A3 INTERMEDIATE; 27 8$ .i BLOTS:SSW.OaW0- SLOTS:TSIOD-SOTSO� _ $IDTS',Ei810$Q10� SLOTS: a,B70.Pa,8130� _ SLOTB: 8,�19.09,102.0� SLOTB; 9.104.0-0,35.0�� SLOTS', 9.47509.80e.0� AdAND LNER.596259.841.0� l FISH, 10.080.0�� KUP PROD WELLNAME 1J-152 WELLBORE 1J -152L2 Well Attributes max Angle amu lu a�/�r/w ConocoPhillips F,cla Alaska, Inc Nama w.11b p uW went ms us WEST SAK 500292329861 PROD elrl MD (nnBl A 1811 IMB) 4.]4 ),fi13.94 13.1120 Xi51PPm1 BSSV.NIPPLE 10 GM Annoialian End Uale NBGMIX) Bq Re1e06e Dale 111812014 Last WO'. 1/1]12006 31D1 "222006 Comment MulµJs lOxab-1J-15313.5%YA19 e:A'. Z11PMI Last Tag yeMyssrcyreysla;plyl AnndaSm� Degnmid End Dale Wellbore tasl Mod By Last TaB:I 1J-152 Imnewl ............................................................. ................. Last Rev Reason WJ4GER: e3.0� ------ Anne.- End In. WOW lest Motl By Rev Reason: GLV CIO 11111112010 1J-15212 IeM1all( Casing strings cazl�cescrippon oDlin) IDpN Top XlrcBl set Depm Mnel set Dego lrvDl... WtlLen p... Ghee Top Torsed D -$AND LINER d112 348 5,6030 13.0860 3,35A9 1160 IL40 BTC Liner Details Nominal lD TopmKB) I Top(wn)o eg Topmnl Pl 1 Hem Dee Com pin 5603.4 3,4]56 89.11 LEEVE BAKER'HR' LINER SET TING BLEEVE 5.000 CONDUCTOR InwMNe 'N'tld", ID 61m0 5.64521 3,4752 92.01 I Xu BUSHINGCROSS VER BUSHING 5.5"x4.5" 4500 13050.6 3,357.5 88.69 MiT oucinq CROSSOVER 4.5"x4.5' 3500 NIPPLE, 9s.9 Perforations & Slots 11 7 a mo snm Den TOR Top 651,1 5, 8510 Blm 7120 712.0 Top a) (X18) ]5.0 BM"D) 3,429.9 9,4 United!D1J- ,1J- 152L2 Bine 4/18006 h. I 32. type SLOTS C- ALL L OE A E THESAME pe 2 V ling Sl pipe 2.5' long SUflFACE; 3D1-3.TTd.S 125-sdliE x 12S (<D1 Q ant Cueninfinendat odce mors, 3" Centers Staggered news, 18 tleg.. 3 X. non-slgnetl ends 7=0 8,250.0 578 3,419S Wn7ri- 52L2 41112006 J2.0 TLOTS emoting slDneNSDlI pipe GASUFr;31AD 8.336. 10,3700 3418. 3.396.8 W 152U 4112006 32.0 SLOTS Ilemeong sonetllsDli Pil1e 10,413.0 13.0510 3.394] J,35).5 W - 52L2 411/2006 320 SLOTS Alternating sDlteNSDlitl pipe Notes: General & Safety End De@ Annotation GAS UFT S.e838 4242006 NOTE:MULTI-LA TERAL WELL. iJ-152(A-SAND),1J-152L1(B-SAND),1J-152L2(D-SAND) 1N61200] INME. WAIVERED WELL T COMMUNICATION-PACKERLESSWELL, ESP FAILED 111]2008 NOTE:WORKOVER PULLED ESP ASSY; NEW COMPLETIONw LMINIPPLEILEM NIPPLE: 5337 Gnpeei—.SM2 SE XSW;5,310 SBE: 5,33.0 M BUSHING:5,32.i HANGER1:63i9 IUNGER 2: S,3995 IWERMEDNTE', 21.38.5233 DS NDUNERHH;5.39 S,S35 SI075, 5 W10sT120� SLOTS', 7,01309,23.0�� 1 1 sears:33e.o-mproo � amn:1 o i13D13.M1 o ---L D.SANDUNER:S.600 - 13.M80 THE STATE °fALASKA GOVERNOR MIRE DUNLEAVT John Peirce Sr. Wells Engineer ConocoPhillips Alaska, Inc. PO Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, West Sak Oil Pool, KRU IJ -152L2 Permit to Drill Number: 206-018 Sundry Number: 319-198 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. o ogc c.a las ko.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, zrz�� Daniel T. Seamount, Jr. Commissioner j r DATED this _day of April, 2019. ABDMSI&APR 2 3 2019 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 RECEIVED APR 17 2019 ,i O 1. Type of Request: Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Repair Well ❑ Operations shutdown❑ Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing ❑ Change Approved Program❑ Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other: MBE Cmnt Isolation 0 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhilli S Alaska Inc. Exploratory ❑ Development 0 Stratigraphic ❑ Service ❑ 206-018 3. Address: 6. API Number: r P. O. Box 100360, Anchorage, Alaska 99510 50-029-23298-61-00 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? N/A r KRU 1J -152L2 Will planned perforations require a spacing exception? Yes ❑ No 0 9. Property Designation (Lease Number): • 10. FieldlPool(s): ADL 25661, ADL 25662 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 ND: MPSP (psi): Plugs (MD): Junk (MD): 13,112' 3,358' 13,085 3,358 1450psi NONE NONE Casing Length Size MD TVD Burst Collapse Conductor 80' 16" 108' 108' Surface 2,744' 103/4 2,774' 2,198' Intermediate 5,376' 75/8 5,403' 3,638' Liner 7,483' 41/2 13,086' 3,358' Perforation Depth MD (ft): lPerfbration Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 5651-6712, 7013-8250, 8336- 3475-3430, 3447-3420, 3419- 4.500" L-80 5,530' 10370 10413 3397. 3395-3357 Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): PACKER = BAKER ZXP LINER PACKER MD = 5355 and TVD = 3432 SSSV = NONE N/A 12. Attachments: Proposal Summary 0 Wellbore schematic 0 13. Well Class after proposed work: Detailed Operations Program ❑ BOP ket Exploratory ❑ Stratigraphic ❑ Development0 Service ❑ 14. Estimated Date for 4/16/2019 15. Well Status after proposed work: Commencing Operations: OIL 0 WINJ ❑ WDSPL ❑ Suspended ❑ GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ 16. Verbal Approval: Date: I/1 Commission Representative: r GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. 1 hereby certify that the foregoing is true and the procedure ap oved 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.Peime@cop.com A ,✓ 1 Contact Phone: (907) 265.6471 Authorized -G✓ — Signature: Date: 1 COMMISSION USE NLY Conditions of approval: Notify Commissiorf so that a representative may witness Sundry Number: ^ I I Ll ^ /✓, (� 'XC) Plug Integrity ❑ BOP Test El Mechanical Integrity Test El Location Location Clearance Other: Post Initial Injection MIT Req'd? Yes ❑ No t�,/ 13BDMS,4` APR 2 3 2019 Spacing Exception Required? Yes ❑ No Subsequent Form Required: / C —4C 1 C� 1 APPROVED BY /�Z/ 10 ( / COMMISSIONER THE COMMISSION Date t Approved by:� I �l«(�� 411q!`q ORIGINAL Submit Form and Form toaos Revised 4/2017 Approved application is valid for 12 months from the date of approval. ��i� Attachments in puplicate �ll`� -p-j% 6 � �r�F8�F9 West Sak 1J-1561-2 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 SI for several days to a week before cement job to abate cross/low 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 KUP PROD WELLNAME 1J-152 WELLBORE 1J-152 ConocoPhillips AtE::] a6kB. l„L M,eyb{aMgs-1J-I$$,.m.a30:5]PY PeiFOI811ons& Sluts VeRUIx.M,rph (acpWl SM DMa ......._. ....._......... ............. _.. Toole) Ben Islwtsae NM'GER: EO Top(n1(B) BM8850ifti 3.691 E) LXT. Zone Doh 1 iype ....,,.... ._.......... 6.500.0 ,885.0 3,636.4 3.622 3,832.8 12912906 32.0 SLOTS ECoar ALL SLOTDE NSA 9I 1J-152 THE SAME: - log SloneNsoliE pipepe 2,5 2.5” long x.125" CONDUCTOR Fri 29ax•, ai.nmeu 2.31. 8,0]50 3,662.0 3,638.6 WS A2, 1J-152 32912 32.0 SLOTS SUNNI MNSDIiR so pip• .pT1 Co. Nut Traq AO 8,291.0 84210 3,630.1 3,623.0 WSA2. 1J-152 1291200 32.0 SLOTS Alternaa slDneWSDIiU R9 ape 8,630.0 8,673.0 3,630.8 3,6330 WS A21 1J-152 3/29200(3 32.0 SLOTS Alternating slotteNaoliB pipe SURFACE:Vi-Z77 8 8,843.0 9.102.0 3,832.0 ,632.2 WS A2, 1J-152 3292006 320 SLOTS Alternating Slottelllaoli6 pipe 9,104.0 9,3200 3,6322 3,6324 WS A2, IJ -152 O6 32.0 SLOTS Alternating SloneNaolitl pipe CASUFT,3.1.0 9.4]50 9.808.0 3,fi29.4 3,6212 WS A2, 1J-152 92006 32.0 SLOTS Alternating slonerYsolid pipe Mandrel Inserts Gxs UFT:s.Osxe st an NIFPIE: 5.2MT G°'pe 0enlf'B'ID8'0 N Top Man Top MKe) WPB) Mate MMN Dole) NNe 9ery Type LakN FORS Type Na. TRO Run (III RUn Dere Com 3,154.0 ,431 CAMCO KFIG-- 1 Gas LiX GLV BK 0.156 101].0 11132015 R 2 5,063.6 3,352.5 CAMCO KERG4. I Gas OR OV BK 0.313 U,111=15 sEU Asbv: s.asa 1R I seal 5.MO Notes: General & Safety xOBU6NING:5,391.) EnJDar, Annotation N9NGER 1a.MT9 � 4242 00fi NOTE: MULTI -LATERAL WELL: 1J-152 (A -SAND), 1J-15211 (BSAND), lJ-15211(DSAND) r 1916200] Ni WAIVERED WEI-I ACOMMUNICATION- PACKERIESS WELL, ESP FAILED NANGER 2 s,'.tsas 1/122090. NOTE: WORKOVER PULL ESP ASSY; NEW COMPLETION w1GIMINII II2412tH18 NOTE: VIEWS HEMATIC.19 UREV SEAL Afi5V, i.F RMND UNER HN: a.3%.6 %,OS% S-SPIM UNERLEM;5,501.9- S.pM3 ke BbPNDUNERHH:5,7QG SPV3 INTERME.4TF, P36,5ZSi SLOT6: S50].OS.M5.0�� stATa:>SO."Or SLOTa: 9.. 09x210 SLOT5:9,exp"Ip30� SLOTS, 8W 0-9.102.0 SLOT$9Ipt"Sap.- .SAND LINER: %.M2.59,Be10� I FISH, 1CODDO� ��..�1w, KUP PROD WELLNAME 1J-152 a-.WIVlai%illips Well Attributes FVMName WaIIEore APWWI W¢IIM AIaSNA,IRC (WEST SAK 500999i94Rfi1 PRM NIPPLE ast WELLBORE 1J -152L2 MulEga laWVY-iN5T3,N21fe33SY PM Last Tag VvazlWwmOc(veeell AnnoWhon Ceen(M(e) End Date WellEwe Lu1Mo]By ......_._...........__ Lass Tag: 1)-152"2 Imoabor .................................................. __._.. _. Last Rev Reason KSNOER: DOS long An..eonEM DeepWelSom Don Mod By . . -.. ..... Rev Reason'. GLVC/O 11/112 15 1J -152L2 le6allf Casing Strings CaelnB Oeaalpllon00(nl D-SPND LINER 4112 IO pnl TPo nIKBI 3.48 5,6084 SN CepM nd(B) SN OepM ITVOL.. WOLm (L.. GIMe Top TOrem 13,086.0 3,35].9 11.60 LSO BTC Liner Details Nominal to 1, MAB) rop Intl l°1 Xem Des coin (In) 5,603.4 3,475fi 69.11 SLEEVE BAKER'HR' LINER SETTING SLEEVE 5.000 CONDUCTOR mxu-. NSWW MSIOLO 5,6452 I 3,415.2 2.01 1 XO BUSHING JURU55DVER BUSHING 5.5-x4.S 4.Wp NIpPLE;SW.i 13,0506 3,35].5 88.69 XO Reducing ROSSOVER 4S' x 4.5" 3.500 Perforations & Slots .T—.No— BNa pens Tap MKBI Btm nlKa) roplrvo) MKM Mm (TV "a) Unke4IDm Mh (enaM I Type Can 51651.0 67120 3,4750 3429.9 WS D, 1J- 4/12006 32.0 SLOTS ALL SLOT DESI N 15211 THE SAME: Alternating 6URFRCE; bt-;TI30 slonedepAid pipe 2.5long 125'@4 Circumferential adjacent rows, 3° Centers staggered 10 deg- 30. non -slotted ends 7,013.0 8,250.0 3446.8 3,419.9 WS—15, F 41112006 320 SLOTS AlMrnatinp slOtredlsolid 15212 pipe cnsuFT. 316.0 $335.0 103704 3418.6 3,396.6J- IN12006 320 SLOTS Alerne ng S OBedlsolid 5212 pipe 10.4130 13,051.0 3,394) 3,3525 ,tJ- 4H2O06 320 SLOTS Alternating slonedlmlitl 152 pipe Notes: General a Safety GASUFT:E0036 end Odle An—woon 424/2006 NOTE: MULTI-IATERAL WELL: 1)-152 (A-SAND),1J-152L1 (B-SAND),1J-152U2(DSAND) 1016'200] NOTE: WAIVERED WELL T x IA COMMUNICATION- PACKERLESS WELL, ESP FAILED NIFME,52E67 1/1]2 NOTE: WORKOVER PULLED ESP ASSY; NEW COMPLETION w/GUA?NIPP[E/LEM Wupa CSM1: 5.48.1 MAL ASSY; S352 %09USHINO; i3B27 K411OER 1; S,39].6 RANGER $ 6,360,5 INTERMEDIATE: V 3 w DUNOLINERHH;6.3056- 6$N5 8LOT6: 6.861.08,]120 SLOTS; 7,0110-LMO SLOTa,83d6610,3]0p SLOTfi: 10.4130.1810 .O LINER: SR0.6 138m0 DATA SUBMITTAL COMPLIANCE REPORT 5/20/2008 Permit to Drill 2060180. Well Name/No. KUPARUK RIV U WSAK 1J-152L2 Operator CONOCOPHILLIPS ALASKA INC API No. 50-029-23298-61-00 MD 13112 TVD 3358 REQUIRED INFORMATION Mud Log No Samples No Directional Survey Yes DATA INFORMATION Types Electric or Other Logs Run: GR/Res, CBL Well L og Information: Log/ Electr Data Digital Dataset Type Med/Frmt Number Name D Asc Directional Survey v .~D D Asc Directional Survey vFD C Lis 13991 ~ruiuction/Resistivity r~B' C Asc 13991 /Induction/Resistivity Rpt 13991 LIS Verification i I ~ C Lis 13991 `t'nyiuction/Resistivity C Asc 13991 Induction/Resistivity ~'~ Rpt 13991 LIS Verification ~D C Lis 15040r'Induction/Resistivity ~D C Lis 15041~duction/Resistivity --- - Well Cores/Samples Information: Name ADDITIONAL INFORMATION Well Cored? Y ~N Chips Received? ~{-PL Analysis ~'7'~ Received? Completion Date 4/22/2006 Completion Status 1-OIL Current Status 1-OIL UIC N Interval Start Stop (data taken from Logs Portion of Master Well Data Maint Log Log Run Interval OH / Scale Media No Start Stop CH Received Comments 5347 13112 Open 6/27/2006 5347 6024 Open 6/27/2006 PB 1 0 0 Open 7!19/2006 LIS GR, ROP 0 0 Open 7/19/2006 Text GR, ROP 0 0 Open 7/19/2006 0 0 Open 7/19/2006 LIS GR, ROP PB 1 0 0 Open 7/19/2006 Text GR, ROP PB 1 0 0 Open 7/19/2006 PB 1 2741 13112 Open 4/17/2007 LIS Veri, GR, FET, ROP w/Graphics CGM, EMF, PDF 2741 13112 Open 4/17/2007 P61 LIS Veri, GR, FET, ROP w/Graphics CGM, EMF, PDF Sent Received Daily History Received? Formation Tops Sample Set Number Comments ~' N ~1 !N • DATA SUBMITTAL COMPLIANCE REPORT 5/20/2008 Permit to Drill 2060180 Well Name/No. KUPARUK RIV U WSAK 1J-152L2 Operator CONOCOPHILLIPS ALASKA INC API No. 50-029-23298-61-00 MD 13112 ND 3358 Completion Date 4/22/2006 Completion Status 1-OIL Current Status 1-OIL UIC N Comments: Compliance Reviewed By: Date: • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION ~~~ ~, REPORT OF SUNDRY WELL OPERATIO ~ ~, Y ~ - ri ~ ~~ T. Operations Performed: Abandon ^ Repair Well ^ Plug Pertorations ^ Stimulate ^ Other 1~9C~1~i-0 Alter Casing ^ Pull Tubing Q Perforate New Pool ^ Waiver ^ Time Extension ^ Change Approved Program ^ Operat. Shutdown^ Perforate ^ Re-enter Suspended Well ^ 2. Operator Name: 4. Well Class Before Work: 5. Permit to Drill Number: COnOCOPhillips Alaska, InC. Development ~ Exploratory ^ 206-018 / - 3. Address: Stratigraphic ^ Service ^ 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-029-23298$1 ' 7. KB Elevation (ft): 9. Well Name and Number: RKB 28', 108' AMSL 1 J-152L2 ' 8. Property Designation: 10. FieldlPool(s): ADL 25661 ~& 25662 Kuparuk River Field /West Sak Oil Pool ' 11. Present Well Condition Summary: Total Depth measured 13112' feet true vertical 3358' feet Plugs (measured) Effective Depth measured 13085' feet Junk (measured) true vertical 3358' feet Casing Length Size MD TVD Burst Collapse Structural CONDUCTOR 108' 20" 108' 108' SURFACE 2664' 10-3/4" 2773' 2198' PRODUCTION 6414' 7-5l8" 6523' 3638' LINER 7688' 4.5" 13085' 3358' Perforation depth: Measured depth: slotted liner 5651'-6712', 7013'-8250', 8336'-10370', 10413'-13051' true vertical depth: 3474'-3430', 3446'-3420', 3419'-3397', 3395'-3357' Tubing (size, grade, and measured depth) tubing in main wellbore, , Packers & SSSV (type & measured depth) Baker ZXP liner pkr ~ 5355' Camco'DB' nipple @ 504' 12. Stimulation or cement squeeze summary: Intervals treated (measured) not applicable Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casin Pressure Tubin Pressure Prior to well operation SI SI -- Subsequent to operation 1797 723 44 -- 200 14. Attachments 15. Well Class after work: Copies of Logs and Surveys run _ Exploratory ^ Development ^~ Service ^ Daily Report of Well Operations _X 16. Well Status after work: 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: none Contact Brett Packer Printed Name Brett Packer%~ Title Wells Group Engineer ? /9/O~ Phone: 265-6845 Date Signature .~~ '_ „ ` Pre h ron Allsu -Dr ke 263-4612 r ~~ ~ ~- 2?.Oa Form 10-404 Revised 04/2006 "'"' ~~' ~t•~ ~ '~ ~~~~ ~~~ Submit Original Only ~ ~~~~~ __ • ~ ~_ _,- KRU .. ~ - --- 1 J'-152L2 API: 500292329861 Well T e: PROD Heat Trace - SSSV Type: NIPPLE Orig . 4/22/2006 (z°-zssz, Com letion: Annular Fluid: Last W/O: 1/17/2008 Reference Lo 28' RKB Ref Lo Date: ruewc (0-5352 Last Ta TD: 13112 fitK6 , oD:a.SO°, Last Ta Date: Max Hole An le: 95 de 7614 ID:3ss6> ~ Casin Strin -COMMON STRINGS D-Sand slotted liner has 6 Descri lion Size To Bottom TVI f CONDUCTOR 20.000 0 108 107 NIP (5297-5298, OD:5.210) Tubing Strin~_ .TUBING Size To Bot1 4.500 0 53 Pertorations Summa Interval TVD Zone 5651 - 6712 3474 - 3430 WS D € 7013 - 8250 3446 - 3420 WS D [ 8336 - 10370 3419 - 3397 WS D 10413 - 13051 3395 - 3357 WS D ~' Gas Lift MandrelsNalves I Other (Dluos, eouiD.. HANGER (5399-5415, OD:5.460) :OI KBG-2-1R etc.) - GOM 1J-152L2 An le TS: de Angle @ TD: 90 deg @ 13112 Rev Reason: GLV C/O Last U date: 1/30/2008 nstrictor ackers Wt Grade Thread 62.50 H-40 WELD ~TVD j Wt I Grade Thread j 3431 2.00 L-80 IBTM Ft SPF Date T e Comment 1061 32 4/1/2006 Slots Alternatin slotted/solid i e 1237 32 4/1/2006 Slots Alternatin slotted/solid i e 2034 32 4/1/2006 Slots Alternatin slotted/solid i e 2638 32 V Type 4/1/2nn6 Sims V OD Latch Port Alternating clotted/snliri ripe TRO Date Run Vlv Cmnt GLV 1.0 BK 0:125 1470 1/29/2008 OV 1.0 BK 0.312 0 1/29/2008 5298 3419 GAUGE BAKER POLARIS GUARDIAN GAUGE CARRIER w/GUARDIAN PRESSURE TEMP PUMP GAUGE 0.000 5352 3431 SEAL BAKER GBH-22 192-47 LOCATING SEAL ASSEMBLY 3.880 5355 3432 PACKER D-SAND BAKER ZXP LINER TOP PACKER 4.950 5363 3434 SBE D-SAND SEAL BORE EXTENSION 190-47 4.750 5383 3438 XO Bushing D-SAND LEM BAKER CROSSOVER BUSHING 3.950 5388 3440 HANGER D-SAND LEM BAKER ABOVE HOOK HANGER 3.690 5399 3442 HANGER D-SAND LEM BELOW HOOK HANGER 3.690 5485 3462 SEAL D-SAND LEM BAKER NON-LOCATING SEAL ASSEMBLY 3.880 C~thar / nluns arnlin att. 1 - n-SANfI I INFR De th TVD T e Descri lion ID 5415 3446 HANGER D-SAND LINER BAKER MODEL B-1 HOOK HANGER OUTSIDE CSG 4.500 5509 3465 PACKER D-SAND LINER BAKER PAYZONE EXTERNAL CASING PACKER 7.625 5603 3474 SLEEVE D-SAND LINER 5.5" BAKER'HR' LINER SETTING SLEEVE 0.000 bh3b I ;i4 /4 I SKUt I Ll-SHNU LINtK 4..h" FULL MULt SHUt I 0.000 I General Notes ~~ ', I ~ ~ I ~ ~ _ I i ~ I - ~ ~ I ~~ C~ Time Logs Date From To _ Dur S, Depth E._Depth Phase Code Subcode T CC~M 01/11/2008 16:00 17:00 1.00 COMPZ RPCOti RURD P Load empty ESP spool on floor w/ crane. 17:00 23:30 6.50 COMPZ WELCT NUND P Finish NU 13 5/8" 5M BOPE. 23:30 00:00 0.50 COMPZ WELCT BOPE P Testing BOPE 250 psi Low, 2500 psi Hi h. 01/12/2008 00:00 05:00 5.00 PROD1 WELCT BOPE P Testing BODE to 250 psi low, 2500 si hi h. 05:00 08:00 3.00 PROD1 WELCT WOEQ NP Waiting on testjt for lower rams. Trouble locatin . 08:00 09:00 1.00 PROD1 WELCT BOPE P Test lower pipe rams 250/2500 psi. 09:00 10:00 1.00 PROD1 RPCO NUND P Pull blanking plug & BPV. -Fill hole 25 bbls . 10:00 10:30 0.50 PROD1 RPCOh SFTY P PJSM on pulling ESP. 10:30 12:00 1.50 PROD1 RPCOh NUND P Screw into the tubing hanger with the landing jt. Mark pipe at the rotary table. BOLDSs on tubing hanger. Unland tubing hanger and pull to rig floor. Lay down hanger, attach ESP cable to spooler. Pulled 150 klbs to unseat, PU 95 klbs, SO 75 klbs, 12:00 14:30 2.50 PROD1 RPCO OTHR P Load 170 jts 3 1/2" IF, Drill Pipe in shed so it can be warming up while ESP is being pulled. Strap & tally same. 14:30 20:30 6.00 PROD1 RPCOh PULD P POOH standing back the 4 1/2" tubing, removing all jewelry, and s oolin u the ESP cable. 20:30 23:00 2.50 PROD1 RPCOh PULD P Disconnect, Break-out and LD ESP. 23:00 00:00 1.00 PROD1 RPCOh OTHR P Shuffle components in pipe shed, clear /clean floor for next o eration. 01/13/2008 00:00 02:30 2.50 PROD1 RPCOh CIRC P Shuffle tubing in pipe-shed. MU Wash BHA and break circulation at surface. Ramp up rate to get baseline data on circulation parameters. Achieved 6 bpm (252 gpm) @ 2400 psi. Decision made to pull circulating subs, pick up and RIH open ended w/ BHA and 3 1/2" DP, circulate to flush out any debris in DP before attempting wash routine. 02:30 04:00 1.50 PROD1 RPCOh PULD P Break out lateral and bottom wash subs, MU remainin BHA. 04:00 08:00 4.00 PROD1 RPCOCV PULD P PU and RIH w/ 3 1/2" IF DP workstring o en-ended. 08:00 08:30 0.50 PROD1 RPCOh CIRC P Pumped 40 bbls (DP vol) to clean out drill i e. 4 BPM w/180 si. 08:30 09:00 0.50 PROD1 RPCOti PULD P Pull and stand back 3 stnds. PU and run 9 'ts. 09:00 09:30 0.50 PROD1 RPCOh CIRC P Pumped 50 bbls to clean out drill pipe. 5 BPM w/380 si. 09:30 12:00 2.50 PROD1 RPCOh PULD P POOH standing back drill pipe and drill collars. - - -- - Pa,^r 7_ of 7 • Time Logs -___ Dat? From To Dur S_D_epth E D_epth_Phase__ Code Subcode T CGfyl - - - - -- - - 01/13/2008 12:00 15:00 3.00 PROD1 RPCO PULD P Break out BHA and install wash ,nozzles and RIH to 650'. 15:00 15:30 0.50 PROD1 RPCOI~ CIRC P Pump to get baseline data on pumping parameters. Achieved 6 BPM @ 2460 si. 15:30 17:30 2.00 PROD1 RPCOh PULD P Continue to RIH with Wash BHA to 5303'. 17:30 18:00 0.50 PROD1 RPCO OTHR P Put steam to Top Drive and lubricate. 18:00 20:00 2.00 PROD1 RPCOA CIRC P MU top drive, establish pumping parameters, wash from 5332.5 - 5539.5 (ORKB) @ 5 bpm & 1850 psi. Reciprocate through hook area and SBE. Established circulation, able to um at 5 b m w/ 50% returns. 20:00 21:00 1.00 PROD1 RPCOti CIRC P Rack 1 stand and CBU @ 6 bpm & 2800 psi.. Blow down top drive, monitor well, fluid ra idl dro in . 21:00 23:00 2.00 PROD1 RPCOh TRIP P TOH from 5497 - 459'. 23:00 00:00 1.00 PROD1 RPCOh PULD P Break out and LD BHA #2. Inspect wash subs, OK. 01/14/2008 00:00 01:30 1.50 PROD1 RPCOti PULD P LD wellbore wash BHA and remove from floor. 01:30 02:30 1.00 PROD1 RIGMN SVRG P S&C Drill line. 02:30 03:30 1.00 PROD1 RPCOh OTHR P Organize pipe shed and floor, ready all to ick u LEM ass . 03:30 06:30 3.00 PROD1 RPCOh PULD P Picking up LEM Assembly and runnin tools. 06:30 11:00 4.50 PROD1 RPCOh PULD P RIH with LEM Assembly on Drillpipe to 5351'. U wt. 110K Dwn wt 75K 11:00 11:30 0.50 PROD1 RPCOh PULD P Oriented LEM w/MWD. 11:30 14:00 2.50 PROD1 RPCOrV HOSO P Lowered LEM down and engaged hook hanger @5398'. MWD showed LEM window @ 3 depress left. Snapped out of hook hanger w/20K overpull. Repeat process 3 times to verify orientation of 3 degrees left. Picked up single and rigged up circulating lines. Dropped 1 3/4" ball. Snapped in and out 2 more times to verify engagement. Pressured up to 4000 psi set packer and released running tool. Tested packer to 2500 psi and charted. Broke lines off, pulled up and released running tool. New top of liner ... 5344'. 14:00 17:00 3.00 PROD1 RPCOti OTHR P Change out ESP spool and install I-wire control lines ool. 17:00 23:30 6.50 PROD1 RPCOh PULD P POOH laying down 4 1/2" drillpipe. 23:30 00:00 0.50 PROD1 RPCOti PULD P PJSM, LD LEM running BHA. 01/15/2008 00:00 01:30 1.50 PROD1 RPCOh PULD P PJSM, Finish break-out and LD BHA. l__ ,.: 3 n~ 7 • I Time Logs _ Date __ From To Dur __ S, Depth E. Depth Phase Code Subcode T COP~~1 01/15/2008 01:30 02:30 1.00 PROD1 RPCOh -PULD P Remove BHA tools from rig. Pull wear bushin , clearfiloor. 02:30 18:00 15.50 PROD1 RPCOti WOEQ NP Wait on equipment needed to assemble final completion string prior to RIH. While waiting on equipment crew continued to rig up sheeves for I wire and heat sensor. Along w/ 20 - extra 'ts of 4.5 12.6# IBTM L-80 tb . 18:00 18:30 0.50 PROD1 RPCOti SFTY P Held PJSM w/ Rig crew and Third Part Contractors 18:30 21:00 2.50 0 357 PROD1 RPCOh PULD P Pick up & Rih w/ GBH-22 Locating Seal Assembly 1 jt of tbg and Polaris Guardian pressure / tempature gauges w/ 3.813" DS Nipple (used 3 SS bands). Rih w/ 7 jts of tbg w! single cannon clamps @ ea coupling, GLM #1 w/ SOV, 1 't 21:00 23:30 2.50 • 357 2,389 PROD1 RPCOh Continue to Rih w/ tbg from derrick w/ single cannon clamps @ ea coupling to 2389'. 23:30 00:00 0.50 2,389 2,420 PROD1 RPCOh PJSM, Start Heat Trace and Rih to 2420' 01/16/2008 00:00 05:00 5.00 2,420 3,020 PROD1 RPCO RCST P Continue to Rih f! 2420' installing heat trace, Tec wire and cannon clam s. 05:00 06:30 1.50 3,020 3,020 PROD1 RPCOti RCST P Shut down running to test cable and chan a out sheave for the I-wire. 06:30 12:00 5.50 3,020 4,077 PROD1 RPCO RCST P Continue to RIHf/ 2420' t/ 4077'. Installing heat trace, Tec wire and cannon clamps. Crew Change. 75k u wt. 68k do wt. 12:00 20:00 8.00 4,077 5,382 PROD1 RPCOh RCST P PJSM, Continue to Rih f/ 4077' to 5349' and tag top of ZXP Tie back sleeve@ 5349'. Work into tie back sleeve w/ 1/2 turn, and Rih to 5384' bottom of seals and locator @ 5355'. Pressure test to 500 si. 20:00 22:30 2.50 5,382 5,330 PROD1 RPCOh HOSO P Space out to 5382' @ bottom of seal assy. PU and MU 2 space out pups (15'), 1 jt and hanger w/ MCA Landing 't. 22:30 00:00 1.50 5,330 PROD1 RPCO OTHR P Install Penetrators and install splices in tech wire and heat trace. 01/17/2008 00:00 01:00 1.00 PROD1 RPCOh OTHR P Continue to Splice I Tech and Heat Trace and tie into Penetrator. 01:00 02:30 1.50 PROD1 RPCOh CIRC P pump 35 bbls corrosion inhibited sea water followed b 100 bbls sea water. 02:30 04:00 1.50 PROD1 RPCOh HOSO P Land Hanger and RILDS. RU to test IA 04:00 04:30 0.50 PROD1 RPCOh SFEQ P Pump on IA attempting to work air from system prior to chart test and prematuraly shear out SOV @ 1150 si. 04:30 08:00 3.50 PROD1 RPCOh WOEO T Call for Slick line to change out 1500 psi SOV to 2000 psi SOV. RD heat trace sheave. _ -~ r a. ~ .~f 'i Time Logs ~ Date From To__ _ _Dur 5. De th E. D_cpth_ Phase Code Subcode T COM 01/17/2008 08:00 13:30 5.50 PROD1 RPCOti OTHR T PJSM on RU slick line. RU slickline and attempt to run plug in DB nipple @ 5298'. Unable to get past 4500'. Dropped Standing valve and attempted to push down with weight. Could not et ast 4500'. POOH with slickline. 13:30 15:30 2.00 PROD1 RPCOti DHEQ P RD slickline. RU hoses and pumped standing valve down on seat of DB nipple @ 5298'. Pressured up on IA/tubing combination to 2500 psi and charted for 30 min. 15:30 16:00 0.50 PROD1 RPCOh NUND P Bled off pressure. Back out landing jt. and la ed down. Set two-wa check. 16:00 18:00 2.00 PROD1 RPCO NUND P PJSM. ND BOPS 18:00 22:30 4.50 PROD1 RPCOh NUND P PJSM. NU Tree and test hanger void and Tree to 5,000 psi f/ 10 min. Good test. 22:30 00:00 1.50 PROD1 RPCOti FRZP P RU LRS and pressure test circ. lines to 3,000 psi. Freeze protect w/ 87.5 bbls diesel. U tube tbg x IA. RD LRS set HBPV. 2052 bbls KCL Seawater lost to well during workover. Release ri 23:59 hrs. ..~ 5 7f 7 D d ~ d SARAH PAUN, GOVERNOR L7•iI[!-7~L1 Oaa! ~ ~ 333 W. 7th AVENUE, SUITE 100 C011j5ERQA~'IO1~T COMI-IIS5IOIQ ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 MJ Loveland Problem Well Supervisor ConocoPhillips Alaska, Inc. PO Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, West Sak Oil Pool, 1J-152L2 Sundry Number: 307-305 Dear Ms. Loveland: 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. Sincerely, Dan T. Seamount Commissioner DATED this Zday of October, 2007 Encl. 2o~_e(~ n ConocoPhillips ~s~ P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 September 27, 2007 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7`h Avenue, Suite 100 Anchorage, AK 99501 Dear Mr. Maunder: • ~~; ~.-~. `J~`T ~ 4 7ri~f ; ~~,r~.:, Enclosed please find a 10-403 Sundry Notice variance request for ConocoPhillips Alaska, Inc. West Sak well 1J-152, 1J-152L1, and 1J-152L2 (PTD #'s 2060160, 2060170, 060180) The variance request is for approval to temporarily use gaslift to produce the ,~ ~SP completed well. Also attached is a discussion and well schematic. Please call MJ Loveland or myself at 907-659-7043, and 907-659-7224 respectively if you have any questions. Sincerely, Brent Rogers Problem Well Supervisor Attachments STATE F ALASKA ~ ALASKA OIL AND GAS CONSERVATION COMMISSION .~ ~ . ~! ,~ APPLICATION FOR SUNDRY APPROVAL `~~aska Dit ~ ,: W 20 AAC 25.280 r: , 1: Type of Request: Abandon ^ Suspend ^ Operational Shutdown ^ Perforate. ^ Waiver ^ Other ^ Alter casing ^ Repair well ^ Plug Perforations ^ Stimulate ^ Time Extension ^ Change approved program ^~ ~ Pull Tubing ^ Perforate New Pool ^ Re-enter Suspended Well 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development ~ Exploratory ^ 206-018 ` 3. Address:. Stratigraphic ^ Service ^ 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-029-23298-61 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 changes: Spacing Exception Required? Y2S ^ NO ^~ ' 1J-152L2 "" 9. Property Designation: 10. KB Elevation (ft): 11. Field/Pool(s): ADL 25661. & 25662 ALK 471 & 2177 RKB 109' = Kuparuk River Field /West Sak Oil Pool - 12. PRESENT WELL CONDITION SUMMARY Totatdepth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured):. Junk (measured): 13112' -' 3358' Casing Length Size MD TVD Burst Collapse CONDUCTOR 108' 20" 108' 108' SURFACE 2664' 10-3/4" 2773' 2198'' PRODUCTION 6414' 7-5/8" 6523' 3637. WINDOW D-SAND 1' 7.. 5404' 3443' D-SAND SLOTTED LINER 7482' 4-172" 13085' 3358' Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size:. Tubing Grade:. Tubing MD (ft): 5651-6712, 7013-8250, 8336-10370, 10413-13051 3474-3430, 3446-3420, 3419-3397, 3395-3357 4-~~2" L-$0 4892' Packers and SSSV Type: Packers and SSSV MD (ft) no packer no SSSV no SSSV 13. Attachments: Description Summary of Proposal Q 14. Well Class after. proposed work: Detailed. Operations Program ^ BOP Sketch ^ Exploratory ^ Development ^~ Service 15. Estimated Date for 16. Well Status after proposed work: Commencing Operations: October 3, 2007 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 knowledge. Cont t~-~'"' ~ M J Loveland / Perry Klein Printed Name: M J Loveland /n / itle: Problem WeII Supervisor Signature Phone 659-7224 Date 09/27/07 Commission Use Only Sundry Number: Conditions of approval: Notify Commission so that a representative may witness 3 -30 Plug Integrity ^ BOP Test ^ Mechanical Integrity Test ~ Location Clearance. ^ Other:. ®~~ (j~~ ~ ~~ 20~~ Subsequent Form Required: h~t~Cc ~~.~ ~4~~`~°~~htfk APPROVED BY /~/ ~ / Approved by: COMMISSIONER THE COMMISSION Date>G ( (((,,, Form 10-40~F.'evfsed 0672006 ( f ~ ~ ~ ~ n ~ Sub it in Dupiica#e ~~~ • ConocoPhillips Alaska, Inc. West Sak Injection Well 1J-152 (PTD 2060160) & 1J-152L1 (PTD 2060170) & 1J-152L2 PTD 2060180) ¢.~- SUNDRY NOTICE 10-403 VARIANCE REQUEST 09-27-07 The purpose of this Sundry Notice is for approval to produce dual lateral West Sak producer 1J- 152 via gas lift until the failed ESP is replaced. The well is completed as an ESP (electric submersible pump) producer and does not have a packer. 1J-152 was completed in April, 2006. The well produced via ESP until 09/11/07, at which time it was shut-in due to a downhole motor electrical failure. The A-well gauges (suction and temperature) flat lined starting August 22 as the ESP was ramped up after CPF 1 came back online post ESD test so we have no down hole telemetry during the failure. The failure mechanism will not be known until the ESP is pulled and torn down. A no-flow situation is suspected to have occurred, followed by the motor overheating or another form of electrical burnout. A no-flow condition or high motor temperature would have been caught by the down hole gauge readings had they been working. The tubing is configured with two gas lift mandrels at 3138' RKB (2395' TVD) and 4210' RKB (2986' TVD). A GLV was installed at 3138' and an orifice valve was installed at 4210'. Gas lift will be applied in the "standard" configuration; i.e., gas will be injected down the annulus and enter the tubing through the gaslift and orifice valves. Attached is a motherbore well diagram of the well. The following is a summary of the proposed plan: 1. The AOGCC approve this request for a time period not to exceed 24 months from the approval date; 2. Should a workover not be completed within the approved time period the AOGCC will be contacted for a review and discussion of the plan forward. HANGER (5399-5415, OD:8.470) HANGER (5742-5766, OD:6.750) • KRU g~ API: 500292; ~t ~ SSSV T e: i NONE Annular Fluid: Reference Lo 22' RKB 0 ~ ^ ~ ~ e l ~ I s ~ ~ Well 1 (1l~F'2 ffllR 4n le TD:''88 Rev Reason:. NE Last Uodate: ~ 5/1 1J-152 Last Tag Date ~ Max Hole Angle: ! 94 deg @ 7511 ! ~ Casin Strin -COMMON STRINGS A-Sand sl otted liner has 11 constrictor ackers Descri tion Size To Bottom TVD Wt Grade Thread CONDUCTOR 20.000 0 108 108 62.50 H-40 ! WELDED SURFACE 0 ~ 10.750 2773 2198 45.50 L-80 BTC PRODUCTION _ 7.625 0 6523 3637 29.70 L-80 ' BTCM WINDOW D-SAND 8.000 5403 5404 3443 0.00 -~ WINDOW B-SAND 8.000 5747 5748 3507 0.00 A-SAND SLOTTEDLINER ~ 4.500 5862 9102 i 3633 11.60 L-80 BTC A-SAND SLOTTEDLINER 4.500 9102 9841 i 3621 12.60 ~ L-80 ' IBTM (TubingString=TUBING I Size To Bottom TVD 1Nt Grade Thread 4.500 0 4892 3286 12.60 L-80 IBTM Perforations Summa Interval TVD Zone Status Ft SPF Date T e Comment 6500 - 6885 i 3636 - 3633 WS A3,WSA2 385 32 3/29/2006 Slots Alternating solid/slotted pipe 7310 - 8075 3662 - 3639 WS A2 765 32 3!29/2006 Slots Alternatin solid/slotted i e 8291 - 8421 3630 - 3623 WS A2 130 32 3/29/2006 Slots Alternatin solid/slotted i e 8630 - 8673 3630 - 3632 WS A2 ' 43 32 3/29/2006 Slots Alternatin solid/slotted i e 8843 - 9102 3632 - 3633 WS A2 259 32 3/29/2006 Slots Alternatin solid/slotted i e 9104 - 9320 3632 - 3632 W S A2 . 216 32 3/29/2006 Slots Alternatin solid/slotted i e 9475 - 9808 3629 - 3621 W S A2 333 32 3/29/2006 Slots Alternatin solid/slotted i e Gas Lift Mandrels/Valves -- St MD TVD Man Man Type V Mfr , V Type V OD latch ! Port TRO ,Date Run Vlv I Mfr ~, Cmnt 1 3138 2395, CAMCO KBMG SOV 1.0 BEK-5 ~ 0.000 ' 0 4/22/2006 2 4210 2986'CAMCO KBMG I DMY 1.0 BK-5 0.000 0 '4/22/2006 Other lu s„e ui .,.etc. -COMPLETION JEWELRY '' _ De th TVD T e Descri tion ID 23 23 HANGER VETCO GRAY TUBING HANGER 4.500 4752 3227 DIS. SUB A-WELL DISCHARGE SUB ' 0.000 4830 3260. XO TTC CROSSOVER w/SCREEN INTAKE 0.000 4840 3264 SEAL TANDEM SEAL SECTION GSB 3 DB ABlHSN PFSA 0.000 4854 3270 MOTOR! PUMP MOTOR 418 HP KMHFER 2610 / 98 " w/ PUMP INSTALLED IN MOTOR" 0.000 ~ 4888 3284 I GAUGE A-WELL PUMP GAUGE 0.000 4890 3285 Centralizer MOTOR CENTRALIZER ~ 0.000 5399 3442 HANGER D-SAND BAKER MODEL B-1 HOOK HANGER INSIDE CASING i 4.020 Other` lu s a ui :;.:etc.- A-SAND LINER JEWELRY De th .TVD T e Descri tion ~ ID 5862 3527 PACKER HRD ZXP LINER TOP PACKER 4.970 5880 3530 NIP 'RS' PACKOFF SEAL NIPPLE ! 4.875 5883 3530 HANGER FLEXLOCK LINER HANGER 4.853 5893 3532 SBE 190-47 CASING SEAL BORE EXTENSION 4.750 5913 3535 XO CROSSOVER BUSHING 3.830 9840 3621 SHOE ROT WEATHERFORD GUIDE SHOE i 3.500 Other lu s, a ui '.,.etc. = B-SAND LEM ' ' De th TVD I T e Descri tion ID 5502 3463 PACKER ZXP LINER TOP PACKER 4.970 5521 3467 I CSR 109-47 CASING SEAL BORE RECEPTACLE i 4.750 5541 3471 XO CROSSOVER BUSHING 3.830 5732 3504 ! HANGER LEM ABOVE HOOK HANGER ! 5.320 5742 3506 HANGER _ LEM INSIDE HOOK HANGER __ _ 5.320 General Notes _ _ Date Note _ 4!24/2006 MULTI-LATERAL WELL: 1J-152 A-SAND , 1J-152L1 B-SAND , 1J-152L2 D-SAND WELL LOG TRAtiSMITTAL 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-152, PB1, PB2, L1, L2 & L2 PBl, AK-MW-4263658 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of Rob. Kalish, Sperry Drilling Services, 6900 Arctic Blvd., Anchorage, AK 99518 1J-452, PB1, PB2, Ll, L2, L2 PBl: LIS & Digital Log .Images: 50-029-23298-00, 70, 71, 60, 61, 72. I~ a~ b ~ - ~ ~~~ ,"4~3 °° i5 ~ ao~ - v ~ ~ ~ yso3~ ~ i Sd~~ ~ i S~ ~ ~,> ~aoc~ -o r ~ ~ ~ 503 April 16; 2007 1 CD Rom ~~~ ~~~ ~ l ~0~~~ '~I~U~l~ • • WELL LOG TRANSMITTAL To: State of Alaska June 22, 2006 Alaska Oil and Gas Conservation Co. Attn.: Librarian 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 R1/: MWD Formation Evaluation Logs: 1J-152, PB1, PB2, L1, L2, L2 PB1, AK-MW-4212091 1 LDWG formatted CD Rom with verification listing(s). API#: 50-029-23298-00, 70, 71, 60, 61, 72 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: ~'?oCa ~6(C~ , ~o~,-vr~, X06 -vr~ ~~ 399 < • 11-May-06 AOGCC Ceresa Tolley 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 DEFINITIVE Re: Distribution of Survey Data for Well 1J-152 L2 Dear Dear Sir/Madam: Enclosed is one disk with the *.PTT and *.PDF files. Tie-on Survey: 5,347.73' MD Window /Kickoff Survey: 13,076.42' MD (if applicable) Projected Survey: 13,112.00' 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: Cart Ulrich 6900 Arctic Blvd. Anchorage, AK 99518 Date ~ Si ned Please call me at 273-3545 if you have any questions or concerns. Regards, Carl Ulrich Survey Manager Attachment(s) 11-May-06 AOGCC Ceresa Tolley 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 DEFINITIVE Re: Distribution of Survey Data for Well 1J-152 L2 PB1 Dear Dear Sir/Madam: Enclosed is one disk with the *.PTT and *.PDF files. Tie-on Survey 5,347.73' MD Window /Kickoff Survey: 5,932.69' MD (if applicable) Projected Survey: 6,024.00' 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 o~,~ ~wM 0 f/ Signed Please call me at 273-3545 if you have any questions or concerns. Regards, Carl Ulrich Survey Manager Attachment(s) ConocoPhillips May 24, 2006 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 . Randy Thomas Kuparuk Drilling Team Leader Drilling & Wells P. O. Box 100360 Anchorage, AK 99510-0360 Phone: 907-265-6830 Subject: Well Completion Reports for 1J-152, 1J-152L1 and 1J-152L2 Dear Commissioner: ConocoPhillips Alaska, Inc. submits the attached Well Completion Reports for the recent drilling operations on the West Sak wells 1 J-152, 1 J-152L1, 1 J-152L2. If you have any questions regarding this matter, please contact me at 265-6830 or Mike Greener at 263-4820. Sincerely, ~-- Tom---' R. Thomas Kuparuk Drilling Team Leader CPAI Drilling RT/skad STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOC 1a. Well Status: Oil ^ ~ Gas Plugged Abandoned Suspended WAG ^ 20AAC 25.105 20AAC 25.110 GINJ ^ WINJ ^ WDSPL ^ No. of Completions _ Other _ 1b. Well Class:. Development Q • "Exploratory ^ Service ^ Stratigraphic Test ^ 2. Operator Name: ConocoPhillipsAlaska, Inc. 5. Date Comp., Susp., oraband.: April 22, 2006 ~ 12. Permit to Drill Number: 206-018! " 3. Address: P. O. Box 100360, Anchorage, AK 99510-0360 6. Date Spudded: ,f ~ ~ ~z ~ 1~~ ~ Mp1kr"ZOUS ~ 6' 13. API Number: 50-029-23298-61 4a. Location of Well (Governmental Section): Surface: 2191' FSL, 2582' FEL, Sec. 35, T11N, R10E, UM - 7. Date TD Reached: April 17, 2006 14. Well Name and Number: 1J-152L2 At Top Productive Horizon: 811' FSL, 949' FWL, Sec. 35, T11 N, R10E 8. KB Elevation (ft): 28' RKB / 108' AMSL 15. Field/Pool(s): Kuparuk River Field Total Depth: 52' FNL, 971' FWL, Sec. 11, T10N, R10E 9. Plug Back Depth (MD + TVD): 13085' MD / 3358' TVD West Sak Oil P001 4b. Location of Well (State Base Plane Coordinates): Surface: x- 558625 y- 5946002. Zone- 4 10. Total Depth (MD + TVD): ~ 13112' MD / 3358' TVD 16. Property Designation: ADL 25661 ~ 25662 TPI: x- 556889 y- 5944609 Zone- 4 Total Depth: x- 556965 < - 5938467 Zone- 4 11. Depth where SSSV set: none 17. Land Use Permit: ALK 471 8~ 2177 18. Directional Survey: Yes ^/ No 19. Water Depth, if Offshore: N/A feet MSL 20. Thickness of Permafrost: 2365' MD 21. Logs Run: ,~T//v +s~7 S C$ h9,~ , 3~1~{3 ~ '~~'A GR/Res, CBL ,,~~'~•~ 22. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTH TVD HOLE AMOUNT CASING SIZE WT. PER FT. GRADE TOP BOTTOM TOP BOTTOM SIZE CEMENTING RECORD PULLED 20" 62.58# H-40 28' 108' 28' 108' 42" 12o sx Class G 10.75" 45.5# L-80 28' 2774' 28' 2198' 13.5" 520 sx AS Lite, 184 sx DeepCRETE 7-5/8" 29.7# L-80 28' 6523' 28' 3638' 9-7/8" 375 sx DeepCrete 4.5" -# L-80 5398' 13086' 3440' 3358' 6.75" slotted liner %; ~ 23. Perforations open to Production (MD + TVD 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 4892' 5508' slotted liner: 13050'-10413', 10370'-8335', 8249'-7013', 6712'-5650' MD ' 25. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED n/a 26. PRODUCTION TEST Date First Production May 14, 2006 Method of Operation (Flowing, gas lift, etc.) ESP Oil -shares production with 1J-152 and 1J-152L1 Date of Test 5/16/2006 Hours Tested .5 hours Production for Test Period --> OIL-BBL 80 GAS-MCF 28 WATER-BBL 21 CHOKE SIZE 19% GAS-OIL RATIO 390 Flow Tubing press. 186 psi Casing Pressure not available Calculated 24-Hour Rate -> OIL-BBL 2837 ~ GAS-MCF 1107 WATER-BBL 744 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". ' ~- : ~fil ~}~ ~I•~ ,I~JN ~ ~° 2~Q~ NONE s _.____. Form 10-407 Revised 12/2003 ORIGINAL CONTINUED ON REVERSE L'G~oG. C~ ~ 6lrl~ ~ r ~ r ~ 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". 1 J-152L2 Top West Sak D 6960' 3443' ^ Base West Sak D 13112' 3358' N/A 1 J-152L2PB1 TD 6024' 3462' 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 Na a Ran Title: Greater Kuoaruk Area Drillino Team Leader Signature ~ one Date c~~2~6 6 2.6 f' -6-8 ~o 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: Caas 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 1J-152 Daily Operations Summary • DATE Summary operations 03/13/06 Move off well 1 J-159.... 03/14/06 RDMO of well 1J-159 -Move North 160' on well row to 1J-152 03/15/06 Drill, PU Dir BHA, resume drilling 03/16/06 Drilled from 1,173' to 1,816' MD. Tripped for bit. RIH and washed and reamed from 1,636' to 1,816'. Lost 5? of angle, inadvertently S/T @ 1,636'. Cont'd drilling from 1,816' to 1,838'. 03/17/06 Drilled 13.5" hole to TD @ 2787' MD / 2,205' TVD. BROOH from 2,787' to 2,048'. POOH and UD BHA. R/U to run 10.75" casing. Run casing to 1,496'. 03/18/06 Ran 10 3/4" casing to 2,774.8' and cemented same. Set casing on slips. Welded on flange and wrapped to cool. Sim-Ops C/O saver sub, P/U 27 jts 4" DP. 03/19/06 P/U 4" DP and R/B. Tested BOPs. Run gyro on wireline. P/U BHA #3. 03/20/06 RIH w/ BHA #3. Performed casing test to 3000 psi. Drilled out FC and FS and performed LOT to 14.2# EMW. Drilled from 3,193' to 4,096' MD / 2,925' TVD. 03/21/06 Drilled 9 7/8" intermediate from 4,096' to 5,614' MD / 3,483' TVD. 03/22/06 Drilled from 5,614' to TD @ 6,532' MD / 3,639' TVD. BROOH to 3,335'. 03/23/06 POOH and UD BHA #3. R/U for 7 5/8" casing run and run to TD @ 6,522' MD / 3.638' TVD. Cemented as per detail. . 03/24/06 Set 7 5/8" casing. on slips. P/U DP and install 90 super sliders. M/U BHA #4 and singled in hole. RIH tagged cement, PU and CBU. Slipped and cut, serviced TD and DWS. Performed casing test. 03/25/06 .Tested casing to 3000. psi. for 30 min. Drilled out shoe +20' new hole,-performed LOT to 13.5. EMW. Drilled intermediate from 6,552' to 7,646'. Pulled back for S/T (fault) @ 6,811' MD. Drilled from 6,811' to 7,085' MD. 03/26/06 Drilled "A" Lat from 7,085' to 9,024' MD. 03/27/06 Drilled from 9,024' to 9,343' MD. Decision made to S/T, pulled back to 8,425' MD. Drilled from 8,425' to 9,803' MD. 03/28/06 Drilled to TD of 10053' MD/ 3621' TVD. Pump hi visc sweeps. POOH to 7 5/8" shoe, RIH to TD. Went into old sidetracked hole twice. Made it to TD. POOH to 362' MD. 03/29/06 LD BHA #4. Run & set 4.5" liner and liner hanger. MU whipstock and mill assembly. Set whipstock. Displace from SFOBM to MOBM. 03/30/06 Mill window from 5747' to 5759'. Drill 5' gauge hole to 5774' MD. POOH and LD milling assembly. RU and Test BOPEs. PU BHA #6. Slip & cut drill line, service TD, DWs, & saver sub. Drill from 5774' to 5828' MD / 3522' TVD. 03/31/06 Drilled B Lat from 5,828' to 7,962' MD / 3,492' TVD. 04/01/06 Drilled B lat from 7,962' to 10,079' ! 3452' TVD 04/02/06 Drilled B lat from 10,079' to 11,631' MD / 3,438' TVD. 04/03/06 Drilled B lat from 11,631' to TD at 13,408' MD / 3426' TVD. 04/04/06 BROOH to window. Circ sweep. TIH to TD, change over to SFOBM. 04/05/06 POOH, LDBHA, PU Whipstock retrieving tools, PJSM, RIH and pull whipstock. 04/06/06 LD Whipstock & retrieving tools. RIH with 4.5" liner. 04/07/06 POOH and PU flop and drop assembly to leave 4.5" liner. RIH with with liner and HR setting sleeve on drill pipe. Rotated liner down from 11,519' MD to TD at 13,374' MD. Set liner & POOH. LD running tools. 04/08/06 MU Hook Hanger assembly for the drop run. RIH and find liner. Set hook hanger. POOH and LD running tools. PU milling assembly. 04/09/06 MU Milling assembly. RIH and tagged up 23' early & mill plugged off. POOH and MU milling assembly with float sub. RIH, filling pipe every 10 stds. Tag RS nipple, cycle boot baskets. POOH and LD milling assembly. MU LEM assembly. 04/10/06 Set LEM & ZXP. POOH & LD running tools. MU Whipstock assembly. RIH & MAD pass. • 1J-152 Daily Operations Summary • 04/11/06 Set whipstock, drilled window from 5,403' to 5,415'. POOH, and L/D mills. Tested BOPE. M/U drilling BHA and SHT MWD. 04/12/06 Cut and slipped DL, serviced TD. Drilled "D" lat from 5,442' to 6,024' MD. Unable to get proper directional response, POOH. M/U BHA w/ motor and agitator. 04/13/06 Trough from 5,425-5,445' MD. S/T from 5,445' to 7,249' MD / 3,446' TVD. 04/14/06 Drilled from 7,249' to 7,572' w/ motor. POOH due to washout. L/D motor and P/U Geo- pilot and assoc. BHA. RIH and drill from 7,572' to 7,967' MD. 04/15/06 Drilled from 7,967 to 9,775' MD w/geo-pilot. 04/16/06 Drilled from 9,775' MD to 11,307' w/geo-pilot. 04/17/06 Drilled from 11,307' MD to 13,112' TD w/geo-pilot. Began to BROOH. 04/18/06 BROOH to window, pumped sweep +2BU. Cut and slipped DL and serviced TD. RIH to TD circa sweep and disp. well to SFOBM. TOOH and began L/D BHA. 04/19/06 L/D BHA. Ran 4.5" slotted liner to 13,086' w/ top @ 5,603' and released. POOH w/ DP. RIH and retrieved whipstock.. 04/20/06 RIH w/ hook hanger and ECP and set. Began L/D DP. 04/21/06 L/D DP. Singled in hole w/ completion tubing and S/B. Rigged up Centrilift and-began R/U motor and ESP. 04/21/06 SET 46.01' X 3.80" OD ESP PUMP (W/CHECK) @ 86' SLM (TOP OF PUMP @ 40' SLM ). SET D&D PACKOFF ASSEMBLY, 5' SPACER, AND STINGER ASSEMBLY (94 3/4" OAL) AND SET ONTOP OF PUMP @ 40' SLM. TEST TBG. TO 1000 PSI FOR 10 MIN. (HELD SOLID ). SET 4 1/2 SLIP .04/22/06 Ran ESP and associated completion. Halliburton Company Survey Report Cum pang: ConucoPhillipsAlaska Inc . I)atc: 5r3,'~006 link: 14.55.49 Pa;;c: 1 1 irld: Kuparuh River Unit Cu-urdinatc(\I:) Kc Ccrcncc: Well: 1J-152. True North , Site: Kuparuk 1J Pad ~~crtical (Ilt)~ ILe~i~ rence: iJ-15?L2 109-G ~1cll: 1J-152 Sccliun (~~51 Itcfcrc ucc: Well i0 00N,0-OOE 180-OOAzi) ~1'cllpath: 1J-152L2 Sun~e~ Calculation ~Icthud: Minimum Curvatu re Uh: Oracle Field: Kuparuk River Unit North Slope Alaska United States Map System:US State Plane Coordinate System 1 927 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-152 Slot Name: Well Position: +N/-S 83.97 ft Northing: 5946002 .32 ft Latitude: 70 15 47.084 N +E/-W -163.96 ft Easting : 558625 .36 ft Longitude: 149 31 33.778 W Position Un certainty: 0.00 ft Wellpath: 1J-152L2 Drilled From: 1J-152PB1 500292329861 Tie-on Depth: 5347.73 ft Current Da tum: 1J-152L2: Height 109 .00 ft Above System D atum: Mean Sea Level Magnetic Data:. 4/17/2006 Declination: 24.12 deg Field Strength: 57565 nT Mag Dip Angle: 80.77 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 Definifive Wellpath Date: 5/3/2006 Validated: No - Version: 1 Actual From To Sur~tey.. Toolcode Tool Name ft ft 90.00 537.00 1 J-152P61 gyro (90.00-537.00) CB-GYRO-SS Camera based gyro single shot 656.75 5347.73 1 J-152PB1 (656.75-7605.55) (0) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 5403.00 13076.42 1 J-152L2 (5403.00-13076.42) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC Survey VD Incl lzim lll1 S~,SI~FU \,;ti 1;!~~ ~lapA ~Ia~iF luol ft deg deg ft ft ft ff ft ft 28.00 0.00 0.00 28.00 -81.00 0.00 0.00 5946002.32 558625.36 TIE LINE 90.00 . 0.31 153.79 90.00 -19.00 -0.15 0.07 5946002.17 558625.44 CB-GYRO-SS 169.00 0.33 240.18 169.00 60.00 -0.46 -0.03 5946001.86 558625.33 CB-GYRO-SS 257.00 0.37 215.61 257.00 148.00 -0.81 -0.41 5946001.50 558624.95 CB-GYRO-SS 353.00 0.61 342.02 353.00 244.00 -0.58 -0.75 5946001.74 558624.61 CB-GYRO-SS 445.00 2.63 346.08 444.95 335.95 1.94 -1.41 5946004.25 558623.93 CB-GYRO-SS 537.00 4.04 349.64 536.80 427.80 7.17 -2.50 5946009.47 558622.80 CB-GYRO-SS 656.75 7.14 348.99 655.96 546.96 18.63 -4.68 5946020.91 558620.53 MWD+IFR-AK-CAZ-SC 747.98 11.14 348.52 746.02 637.02 32.84 -7.52 5946035.10 558617.58 MWD+IFR-AK-CAZ-SC 839.68 13.86 349.80 835.53 726.53 52.33 -11.23 5946054.56 558613.72 MWD+IFR-AK-CAZ-SC 931.01 14.42 353.74 924.10 815.10 74.40 -14.41 5946076.60 558610.38 MWD+IFR-AK-CAZ-SC 1020.87 16.90 354.31 1010.62 901.62 98.53 -16.92 5946100.70 558607.67 MWD+IFR-AK-CAZ-SC 1120.48 20.55 357.30 1104.94 995.94 130.41 -19.18 5946132.56 558605.17 MWD+IFR-AK-CAZ-SC 1213.13 22.43 356.92 1191.14 1082.14 164.31 -20.90 5946166.44 558603.19 MWD+IFR-AK-CAZ-SC 1273.52 24.12 356.30 1246.62 1137.62 188.13 -22.31 5946190.25. 558601.59 MWD+IFR-AK-CAZ-SC 1306.74 26.79 355.67 1276.61 1167.61 202.37 -23.32 5946204.48 558600.47 MWD+IFR-AK-CAZ-SC 1397.20 33.70 353.74 1354.71 1245.71 247.70 -27.60 5946249.77 558595.84 MWD+IFR-AK-CAZ-SC 1491.41 39.81 355.12 1430.16 1321.16 303.78 -33.02 5946305.80 558589.98 MWD+IFR-AK-CAZ-SC 1584.09 46.04 357.97 1498.00 1389.00 366.75 -36.73 5946368.73 558585.78 MWD+IFR-AK-CAZ-SC 1677.37 44.16 357.94 1563.84 1454.84 432.77 -39.09 5946434.74 558582.91 MWD+IFR-AK-CAZ-SC 1769.27 43.33 359.13 1630.23 1521.23 496.29 -40.71 . 5946498.23 558580.79 MWD+IFR-AK-CAZ-SC 1859.90 45.61 356.18 1694.91 1585.91 559.71 -43:34 5946561.62 558577.66 MWD+IFR-AK-CAZ-SC 1952.12 49.11 352.59 1757.38 1648.38 627.19 -50.04 5946629.04 558570.44 MWD+IFR-AK-CAZ-SC 2043.67 52.60 342.96 1815.24 1706.24 696.39 -65.18 5946698.11 558554.76 MWD+IFR-AK-CAZ-SC ~ 2136.92 55.91 333.37 1869.79 1760.79 766.45 -93.40 5946767.94 558526.01 MWD+IFR-AK-CAZ-SC 2229.42 57.89 326.70 1920.35 1811.35 833.49 -132.11 5946834.68 558486.78 i MWD+IFR-AK-CAZ-SC ~ 2323.46 61.30 323.86 1967.94 1858.94 900.11 -178.32 5946900.93 558440.06 MWD+IFR-AK-CAZ-SC 2415.35 59.74 326.15 2013.17 1904.17 965.63 -224.20 5946966.08 558393.67 MWD+IFR-AK-CAZ-SC • Halliburton Company Survey Report ['nm~i:ui~: ConoroPhillips Alaska Inc. llatc: 5/3/2006 lime: 14:55:49 Pa~_c: Field: Ku paruk River U nit Cu-or dinate(\I~:) llcfcrrncc Well: 1J-152. True North tiitc: Ku paruk 1 J Pad ~ crtic al ("f~'D) F{cfcrencc_ 1 J -152L2: 109.0 ~~cll: 1 J -152 ~ectiu n ~~5~ Refere nce: Well (QOON,O OOE.130 OOAzij ~Vcllpatli: 1J -152 L2 Gine} (alculatiun ~lcthod: Mi nimum Curvatu re Dh: Oracle Gn ccc X11) lucl ~zim ll U Sc~ 7 \ U \/1 1~:;ti~' ~Ia~~S ~lap[~: 71x11 ft deg deg ft rt ft ft ft ft 2507.53 61.17 322.16 2058.63 1949.63 1030.60 -271.16 5947030.68 558346.21 MWD+IFR-AK-CAZ-SC 2600.04 57.97 321.79 2105.48 1996.48 1093.43 -320.29 5947093.12 558296.60 MWD+IFR-AK-CAZ-SC 2694.14 58.26 320.11 2155.19 2046.19 1155.48 -370.62 5947154.77 558245.79 MWD+IFR-AK-CAZ-SC 2737.89 57.29 318.61 2178.52 2069.52 1183.56 -394.72 5947182.66 558221.47 MWD+IFR-AK-CAZ-SC 2824.65 56.33 316.70 2226.02 2117.02 1237.23 -443.62 5947235.94 558172.16 MWD+IFR-AK-CAZ-SC 2917.67 56.95 310.44 2277.20 2168.20 1290.72 -499.88 5947288.99 558115.50 MWD+IFR-AK-CAZ-SC 3010.82 58.11 305.21 2327.23 2218.23 1338.87 -561.93 5947336.65 558053.07 MWD+IFR-AK-CAZ-SC 3106.49 58.00 297.13 2377.91 2268.91 1380.84 -631.30 5947378.07 557983.39 MWD+IFR-AK-CAZ-SC 3199.84 57.91 291.80 2427.47 2318.47 1413.59 -703.28 5947410.25 557911.16 MWD+IFR-AK-CAZ-SC 3293.54 57.09 284.95 2477.86 2368.86 1438.50 -778.20 5947434.58 557836.06 MWD+IFR-AK-CAZ-SC 3386.38 56.42 278.35 2528.79 2419.79 1454.18 -854.18 5947449.66 557759.97 MWD+IFR-AK-CAZ-SC 3480.31 57.70 271.98 2579.90 2470.90 1461.24 -932.62 5947456.11 557681.48 MWD+IFR-AK-CAZ-SC 3573.11 57.79 264.56 2629.48 2520.48 1458.87 -1010.98 5947453.13 557603.15 MWD+IFR-AK-CAZ-SC 3666.73 56.46 257.70 2680.34 2571.34 1446.79 -1088.60 5947440.45 557525.64 MWD+IFR-AK-CAZ-SC 3760.80 55.63 251.72 2732.91 2623.91 1426.25 -1163.81 5947419.33 557450.59 MWD+IFR-AK-CAZ-SC 3853.77 55.26 245.94 2785.68 2676.68 1398.63 -1235.17 5947391.15 557379.46 MWD+IFR-AK-CAZ-SC 3945.47 53.52 240.08 2839.10 2730.10- 1364.85 -1301.57 .5947356.87 557313.33 MWD+IFR-AK-CAZ-SC 4039.70 55.93 231.1$ 2893.59 2784.59 1321.43 -1364.90 5947312.95 557250.34 MWD+IFR-AK-CAZ-SC 4131.77 57.12 225.10 2944.40 2835.40 1270.20 -1422.04 5947261.29 557193.61 MWD+IFR-AK-CAZ-SC 4225.31 58.72 218.73 2994.12 2885.12 1211.24 -1474.91 5947201.93 557141.20 MWD+IFR-AK-CAZ-SC 4318.68 62.42 211.13 3040.04 2931.04 1144.60 -1521.34 5947134.93 557095.31 MWD+IFR-AK-CAZ-SC 4412.45 62.54 205.36 3083.39 2974.39 1071.39 -1560.66 5947061.42 557056.55 MWD+IFR-AK-CAZ-SC 4505.47 65.67 199.24 3124.04 3015.04 .994.00 -1592.34 5946983.80 557025.48 MWD+IFR-AK-CAZ-SC 4599.02 64.31 198.33 3163.59 3054.59 913.74 -1619.64 5946903.34 556998.81 MWD+IFR-AK-CAZ-SC 4693.03 65.96 193.22 3203.14 3094.14 831.69 -1642.79 5946821.12 556976.30 MWD+IFR-AK-CAZ-SC 4784.50 65.62 191.43 3240.66 3131.66 750.20 -1660.60 5946739.49 556959.13 MWD+IFR-AK-CAZ-SC 4879.26 64.36 190.69 3280.72 3171.72 665.92 -1677.08 5946655.10 556943.31 MWD+IFR-AK-CAZ-SC 4974.57 67.36 187.23 3319.70 3210.70 580.03 -1690.59 5946569.11 556930.47 MWD+IFR-AK-CAZ-SC 5068.20 69.45 185.25 3354.16 3245.16 493.49 -1700.04 5946482.52 556921.69 MWD+IFR-AK-CAZ-SC 5161.20 72.44 182.54 3384.53 3275.53 405.81 -1705.99 5946394.80 556916.43 MWD+IFR-AK-CAZ-SC 5254.29 77.35 182.62 3408.78 3299.78 316.06 -1710.04 5946305.02 556913.08 MWD+IFR-AK-CAZ-SC 5347.73 76.10 181.87 3430.23 3321.23 225.19 -1713.60 5946214.14 556910.22 MWD+IFR-AK-CAZ-SC 5403.00. 77.14 182.02 3443.02 ~ 3334.02 171.45 -1715.42 5946160.39 556908.82 MWD+IFR-AK-CAZ-SC 5481.79 76.19 180.82 3461.20 3352.20 94.81 -1717.33 5946083.75 556907.51 MWD+IFR-AK-CAZ-SC 5574.40 87.10 179.44 3474.63 3365.63 3.32 -1717.52 5945992.27 556908.03 MWD+IFR-AK-CAZ-SC 5667.87 93.58 179.60 3474.08 3365.08 -90.09 -1716.74 5945898.87 556909.54 MWD+IFR-AK-CAZ-SC 5756.94 94.02 178.04 3468.18 3359.18 -178.95 -1714.91 5945810.05 556912.06 MWD+IFR-AK-CAZ-SC 5849.00 92.88 178.33 3462.64 3353.64 -270.79 -1712.00 5945718.23 556915.69 MWD+IFR-AK-CAZ-SC 5940.49 92.64 180°57 3458.23 3349.23 -362.16 -1711.12 5945626.88 556917.28 MWD+IFR AK-CAZ-SC 6034.68 91.83 182.87 3454.56 3345.56 -456.23 -1713.94 5945532.80 .556915:18 MWD+IFR-AK-CAZ-SC 6128.44 92.09 181.19 3451.35 3342.35 -549.88 -1717.26 5945439.14 556912.59 MWD+IFR-AK-CAZ-SC 6221.94 92.10 180.62 3447.93 3338.93 -643.30 -1718.74 5945345.72 556911.85 MWD+IFR-AK-CAZ-SC 6315.48 91.96 178.64 3444.62 3335.62 -736.78 -1718.14 5945252.26 556913.18 MWD+IFR-AK-CAZ-SC 6409.00 92.77 180.75 3440.76 3331.76 -830.21 -1717.64 5945158.84 556914.40 MWD+IFR-AK-CAZ-SC 6502.95 93.08 180.54 3435.96 3326.96 -924.03 -1718.69 5945065.03 556914.08 MWD+IFR-AK-CAZ-SC 6597.34 92.64 182.88 3431.25 3322.25 -1018.25 -1721.51 5944970.79 556912.00 MWD+IFR-AK-CAZ-SC 6690.76 89.38 184.22 3429.61 3320.61 -1111.47 -1727.29 5944877.55 556906.94 MWD+IFR-AK-CAZ-SC 6783.94 88.32 183.75 3431.48 3322.48 -1204.40 -1733.76 5944784.57 556901.19 MWD+IFR-AK-CAZ-SC 6876.32 85.36 184.84 3436.57 3327.57 -1296.37 -1740.67 5944692.56 556895.00 MWD+IFR-AK-CAZ-SC 6971.05 85.67 183.89 3443.98 3334.98 -1390.53 -1747.86 5944598.35 556888.55 MWD+IFR-AK-CAZ-SC ' 7064.29 87.73 183.38 3449.34 3340.34 -1483.43 -1753.76 5944505.43 556883.37 MWD+IFR-AK-CAZ-SC 7157.49 91.03 184.07 3450.35 3341.35 -1576.41 -1759.81 5944412.41 556878.04 . MWD+IFR-AK-CAZ-SC Halliburton Company. Survey Report (~~unp:ui~: ConocoPhillips Alaska Irc. I)atc_ 5,'3/20C6 Iimc: 14:55.49 Pa~c: 3 Iicl~t: Ku paruk River Unit Cu-ur din~~tclSla K cfcrcucc Well: 1J-'152, True North tiitc: Ku paruk iJ Pad ~crtic al (Il I)I Kc( crcncc: 1J -152L2: 109.0 Nell: 1 J -152 ~ectiu u (~~) Kcfcrc ucc Well (0.OON,O.OOE.130 OOAzi) Ncllpnth: 1J -152L2 Sin~c~Calculatimi ~lclhod: P~li nimumCurvatu re Uh: Oracle ~uncc X11) lucl ~ziui llD ti~tillD \:ti I~:.'~1 ~la~i,A" tila~il~: Tniil ft deg deg ft ft ft ft ft ft 7249.86 89.49 182.36 3449.93 3340.93 -1668.63 -1764.99 5944320.16 556873.58 MWD+IFR-AK-CAZ-SC 7343.44 91.22 178.57 3449.35 3340.35 -1762.18 -1765.75 5944226.61 556873.55 MWD+IFR-AK-CAZ-SC 7434.83 91.53 177.51 3447.16 3338.16 -1853.49 -1762.63 5944135.34 556877.39 MWD+IFR-AK-CAZ-SC 7501.20 92.26 177.37 3444.97 3335.97 -1919.76 -1759.66 5944069.10 556880.86 MWD+IFR-AK-CAZ-SC 7613.93 94.74 178.01 3438.08 3329.08 -2032.18 -1755.13 5943956.73 556886.27 MWD+IFR-AK-CAZ-SC 7708.22 91.93 178.02 3432.60 3323.60 -2126.24 -1751.87 . 5943862.71 556890.27 MWD+IFR-AK-CAZ-SC 7800.42 90.77 177.61 3430.43 3321.43 -2218.35 -1748.35 5943770.64 556894.50 MWD+IFR-AK-CAZ-SC 7893.69 92.39 179.37 3427.86 3318.86 -2311.54 -1745.90 5943677.48 556897.68 MWD+IFR-AK-CAZ-SC 7985.71 91.20 181.31 3424.97 3315.97 -2403.51 -1746.44 5943585.52 556897.85 MWD+IFR-AK-CAZ-SC 8082.99 91.02 180.94 3423.09 3314.09 -2500.75 -1748.35 5943488.27 556896.70 MWD+IFR-AK-CAZ-SC 8177.45 91.03 179.76 3421.40 3312.40 -2595.19 -1748.93 5943393.84 556896.86 MWD+IFR-AK-CAZ-SC 8276.93 91.52 183.72 3419.18 3310.18 -2694.58 -1751.95 5943294.44 556894.61 MWD+IFR-AK-CAZ-SC 8373.82 88.42 182.73 3419.24 3310.24 -2791.31 -1757.40 5943197.68 556889.91 MWD+IFR-AK-CAZ-SC 8470.77 91.04 184.89 3419.69 3310.69 -2888.03 -1763.84 5943100.92 556884.23 MWD+IFR-AK-CAZ-SC 8566.90 90.28 182.47 3418.58 3309.58 -2983.95 -1770.01 5943004.97 556878.81 MWD+IFR-AK-CAZ-SC 8663.57 89.66 180.35 3418.64 3309.64 -3080.58 -1772.39 5942908.33 556877.18 MWD+IFR-AK-CAZ-SC 8760.74 91.65 182.37 3417.52. 3308.52 -3177.71 -1774.69 5942811:20 556875.63 MWD+IFR AK-CAZ-SC 8856.61 89.34 182.21 3416.70 3307.70 -3273.49 -1778.52 5942715.40 556872.55 MWD+IFR-AK-CAZ-SC 8953.98 88.80 179.33 3418.28 3309.28 -3370.83 -1779.83 5942618.06 556872.00 MWD+IFR-AK-CAZ-SC 9050.13 88.24 175.05 3420.76 3311.76 -3466.81 -1775.12 5942522.13 556877.45 MWD+IFR-AK-CAZ-SC 9146.64 88.43 174.13 3423.57 3314.57 -3562.85 -1766.03 5942426.17 556887.30 MWD+IFR-AK-CAZ-SC 9242.79 90.48 174.96 3424.48 3315.48 -3658.55 -1756.89 5942330.55 556897.18 MWD+IFR-AK-CAZ-SC 9338.73 91.15 175.36 3423.12 3314.12 -3754.14 -1748.79 5942235.04 556906.02 MWD+IFR-AK-CAZ-SC 9437.02 92.20 177.18 3420.24 3311.24 -3852.17 -1742.40 5942137.07 556913.17 MWD+IFR-AK-CAZ-SC 9532.27 93.62 177.44 3415.41 3306.41 -3947.19 -1737.94 5942042.10 556918.37 MWD+IFR-AK-CAZ-SC 9628.94 90.70 174.68 3411.76 3302.76 -4043.55 -1731.30 5941945.81 556925.76 MWD+IFR-AK-CAZ-SC 9728.13 92.76 177.67 3408.77 3299.77 -4142.45 -1724.68 5941846.96 556933.14 MWD+IFR-AK-CAZ-SC 9821.45 91.75 176.89 3405.10 3296.10 -4235.59 -1720.26 5941753.87 556938.29 MWD+IFR-AK-CAZ-SC 9919.88 89.53 173.21 3404.00 3295.00 -4333.63 -1711.77 5941655.91 556947.55 MWD+IFR-AK-CAZ-SC 10016.40 90.72 177.07 3403.79 3294.79 -4429.78 -1703.59 5941559.84 556956.47 MWD+IFR-AK-CAZ-SC 10112.56 91.52 181.77 3401.91 3292.91 -4525.89 -1702.62 5941463.75 556958.19 MWD+IFR-AK-CAZ-SC 10209.75 89.41 181.83 3401.12 3292.12 -4623.02 -1705.67 5941366.60 556955.90 MWD+IFR-AK-CAZ-SC 10306.64 92.59 183.34 3399.43 3290.43 -4719.78 -1710.04 5941269.82 556952.28 MWD+IFR-AK-CAZ-SC 10402.23 92.56 184.04 3395.13 3286.13 -4815.08 -1716.18 5941174.49 556946.88 MWD+IFR-AK-CAZ-SC .10499.57 89.59 182.95 3393.30 3284.30 -4912.21 -1722.12 5941077.33 556941.70 MWD+IFR-AK-CAZ-SC 10596.87 90.84 182.81 3392.94 3283.94 -5009.38 -1727.01 5940980.13 556937.57 MWD+IFR-AK-CAZ-SC 10692.41 89.91 182.87 3392.31 3283.31 -5104.80 -1731.74 5940884.68 556933.58 MWD+IFR-AK-CAZ-SC 10789.07 89.17 182.93 3393.09 3284.09 -5201.33 -1736.63 5940788.12 556929.45 MWD+IFR-AK-CAZ-SC 10884.91 89.17 181.46 3394.48 3285.48 -5297.09 -1740.30 5940692.35 556926.52 MWD+IFR-AK-CAZ-SC 10983.89 91.59 178.30 3393.82 3284.82 -5396.05 -1740.09 5940593.41 556927.50 MWD+IFR-AK-CAZ-SC 11079.69 .89.72 177.08 3392.73 3283.73 -5491.76 -1736.23 5940497.74 556932.10 MWD+IFR-AK-CAZ-SC 11175.57 91.65 180.62 3391.58 3282.58 -5587.59 -1734.31 5940401.93. 556934.77 MWD+IFR-AK-CAZ-SC 11269.56 87.17 180.32 3392.55 3283.55 -5681.55 -1735.08 5940307.98 556934.73 .MWD+IFR-AK-CAZ-SC 11362.17 88.62 181.76 3395.95 3286.95 -5774.08 -1736.76 5940215.45 556933.78 MWD+IFR-AK-CAZ-SC 11457.94 92.34 183.48 3395.15 3286.15 -5869.72 -1741.13 5940119.78 .556930.14 MWD+IFR-AK-CAZ-SC 11551.94 92.13 181.73 3391.48 3282.48 -5963.55 -1745.40 5940025.93 556926.61 MWD+IFR-AK-CAZ-SC 11646.40 91.64 180.53. 3388.37 3279.37 -6057.94 -1747.26 5939931.54 556925.48 MWD+IFR-AK-CAZ-SC 11740.59 93.50 179.67 3384.15 3275.15 -6152.03 -1747.43 5939837.46 556926.05 MWD+IFR-AK-CAZ-SC 11832.10 93.31 178.93 3378.72 3269.72 -6243.37 -1746.31 5939746.14 556927.87 MWD+IFR-AK-CAZ-SC 11921.40 91.94 179.20 3374.63 3265.63 -6332.56 -1744.86 5939656.97 556930.02 MWD+IFR-AK-CAZ-SC 12012.58 91.88 178.48 3371.59 3262.59 -6423.67 -1743.01 5939565.89 556932.58 MWD+IFR-AK-CAZ-SC 12103.87 91.45 178.24 3368.93 3259.93 -6514.89 -1740.40 5939474.71 556935.90 MWD+IFR-AK-CAZ-SC ' 12194.20 92.26 179.64 3366.01 3257.01 -6605.15 -1738.73 5939384.47 556938.27 MWD+IFR-AK-CAZ-SC Halliburton Company Survey Report Company: ConoroPhillipsAlaska Inc. Ficid: Kuparuk River U nit tine: Kuparuk 1J Pad ti ell: 1 J-152 ~', cllpaui: 1 J-152L2 ~ur~ c~ X11) luel lzim ft deg deg 12285.78 89.59 175.19 12375.44 92.52 176.48 12467.20 92.75 178.65 12556.17 92.31 178.28 12645.96 90.39 178.16 12736.90 89.16 178.00 12827.90 90.23 179.15 12922.35 89.47 182.63 13016.08 87.36 178.75 13076.42 89.69 182.82 13112.00 ~. 89.69 182.82 ihuc: 513/2006 lino: 14.5549 Page: ~ Cn-~~rdinate(\I:) Reference: Well: 1J-152.. True North Vertical (I~ I)) Rclircucc: 1J-152L2: 109.0 Section (~~) Reference Well (0-OON,O-OOE180.OOAzi) Sun~ev Calculi[ion >lethod: Minimum Curvature D1.: grade ll~U Scti Il'U V'S 1~a~1 ~lapA ~IapF: ~fnul ft ft ft ft ft ft 3364.53 3255.53 -6696 .60 -1734.60 5939293 .07 556943 .11 MWD+IFR-AK-CAZ-SC 3362.88 3253.88 -6785 .99 -1728.09 5939203. 73 556950 .32 MWD+IFR-AK-CAZ-SC 3358.66 3249.66 -6877 .57 -1724.20 5939112. 20 556954 .93 MWD+IFR-AK-CAZ-SC 3354.73 3245.73 -6966 .42 -1721.82 5939023. 38 556958 .00 MWD+IFR-AK-CAZ-SC 3352.62 3243.62 -7056 .14 -1719.03 5938933. 69 556961 .48 MWD+IFR-AK-CAZ-SC 3352.98 3243.98 -7147. 02 -1715.98 5938842. 84 556965 .24 MWD+IFR-AK-CAZ-SC 3353.46 3244.46 -7237. 99 -1713.72 5938751. 90 556968 .21 MWD+IFR-AK-CAZ-SC 3353.71 3244.71 -7332. 41 -1715.18 5938657. 48 556967 .48 MWD+IFR-AK-CAZ-SC 3356.30 3247.30 -7426. 08 -1716.31 5938563. 82 556967 .08 MWD+IFR-AK-CAZ-SC 3357.86 3248.86 -7486. 37 -1717.14 5938503. 52 556966 .72 MWD+IFR-AK-CAZ-SC 3358:05 • 3249.05 -7521. 91 -1718.89 5938467. 98 - 556965 .25. PROJECTED to TD Halliburton Company Survey Report ('nm~run~: ConocoPhillipsAlaska Inc. 1>atc 5,'3:'2006 finis 140944 Pae: t ficl~l: Kuparuk River Unit C~~-iinlinatclAI~:) Re ference Well: 1J-152. True North tine: Kuparuk 1J Pad ~`rrtical (fell) Refe rence: 1J-152L2PB1. 10 9-0 ~~cll: 1J-152 Scrtiun IBS) Referen ce: Udell lO.OON.O-OOE.180.OOAzi1 Aell~~:u6: 1J-152L2PB1 tiune~ (~:ilculatiun ~Icthu~l: Minimum Curvatu re Ub: Oracle Field: Kuparuk River Unit North Slope Alaska United States Map System:US State Plane Coordin ate System 1 927 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-152 Slot Name: Welt Position: +N/-S 83.97 ft Northing: 5946002. 32 ft Latitude: 70 15 47.084 N +E/-W -163.96 ft Easting : 558625. 36 ft Longitude: 149 31 33.778 W Position Un certainty: 0.00 ft Wellpath: 1J-152L2P81 Drilled From: 1J-152PB1 500292329872 Tie-on Depth: 5347.73 ft Current Da tum: 1 J-152L2P61: Height 109. 00 ft Above System D atum: Mean Sea Level Magnetic Data: 3/10/2006 Declination: 24.16 deg Field Strength: 57565 nT Mag Dip Angle: 80.77 deg Vertical Section: 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: 5/3/2006 Validated: No Version: 1 Actual From To Survey Toolcode Tool Name ft ft 90.00 537.00 1 J-152P61 gyro (90.00-537.00) CB-GYRO-SS Camera based gyro single shot 656.75 5347.73 1J-152PB1 (656.75-7605.55) (0) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 5403.00 5932.69 1J-152L2P B1 (5403.00-5932.69) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC Survey SID Incl ~zim l1 D ti~,c ~I1D __ \ S f X11 Tip,A~ ~la~~l: fool ft deg deg ft ft ft ft ft ft 28.00 0.00 0.00 28.00 -81.00 0.00 0.00 5946002.32 558625.36. TIE LINE 90.00 0.31 153.79 90.00 -19.00 -0.15 0.07 5946002.17 558625.44 CB-GYRO-SS 169.00 0.33 240.18 169.00 60.00 -0.46 -0.03 5946001.86 558625.33 CB-GYRO-SS 257.00 0.37 215.61 257.00 148.00 -0.81 -0.41 5946001.50 558624.95 CB-GYRO-SS 353.00 0.61 342.02 353.00 244.00 -0:58 -0.75 5946001.74 558624.61 CB-GYRO-SS 445.00 2.63 346.08 444.95 335.95 1.94 -1.41 5946004.25 558623.93 CB-GYRO-SS 537.00 4.04 349.64 536.80 427.80 7.17 -2.50 5946009.47 558622.80 CB-GYRO-SS 656,75 7.14 348.99 655.96 546.96 18.63 -4.68 5946020.91 558620.53 MWD+IFR-AK-CAZ-SC 747.98 11.14 348.52 746.02 637.02 32.84 -7.52 5946035.10 558617.58 MWD+IFR-AK-CAZ-SC 839.68 13.86 349.80 835.53 726.53 52.33 -11.23 5946054.56 558613.72 MWD+IFR-AK-CAZ-SC 931.01 14.42 353.74 924.10 815.10 74.40 -14.41 5946076.60 558610.38 - MWD+IFR-AK-CAZ-SC 1020.87 16.90 354.31 1010.62 901.62 98.53 -16.92 . 5946100.70 558607.67 MWD+IFR-AK-CAZ-SC 1120.48 20.55 357.30 1104.94 995.94 130.41 -19.18 5946132.56 558605.17 MWD+IFR-AK-CAZ-SC 1213.13 22.43 356.92 1191.14 1082.14 164.31 -20.90 5946166.44 558603.19 MWD+IFR-AK-CAZ-SC 1273.52 24.12 356.30 1246.62 1137.62 188.13 -22.31 5946190.25 558601.59 MWD+IFR-AK-CAZ-SC . 1306.74 26.79 355.67 1276.61 1167.61 202.37 -23.32 5946204.48 558600.47 MWD+IFR-AK-CAZ-SC 1397.20 33.70 353.74 1354.71 1245.71 247.70 -27.60 5946249.77 558595.84 MWD+IFR-AK-CAZ-SC 1491.41 39.81 355.12 1430.16 1321.16 303.78 -33.02 5946305.80 558589.98 MWD+IFR-AK-CAZ-SC 1584.09 46.04 357.97 1498.00 1389.00 366.75 -36.73 5946368.73 558585.78 MWD+IFR-AK-CAZ-SC 1677.37 44.16 357.94 1563.84 1454.84 432.77 -39.09 5946434.74 558582.91 MWD+IFR-AK-CAZ-SC 1769.27 43.33 359.13 1630.23 1521.23 496.29 -40.71 5946498.23 558580.79 MWD+IFR-AK-CAZ-SC 1859.90 45.61 356.18 1694.91 1585.91 559.71 -43.34 5946561.62 558577.66 MWD+IFR-AK-CAZ-SC 1952.12 49.11 352.59 1757.38 1648.38 627.19 -50.04 5946629.04 558570.44 MWD+IFR-AK-CAZ-SC 2043.67 52.60 342.96 1815.24 1706.24 696.39 -65.18 5946698.11 558554.76 MWD+IFR-AK-CAZ-SC 2136.92 55.91 333.37 1869.79 1760.79 766.45 -93.40 5946767.94 558526.01 MWD+IFR-AK-CAZ-SC I 2229.42 57.89 326.70 1920.35 1811:35 833.49 -132.11 5946834.68 558486.78 MWD+IFR-AK-CAZ-SC 2323.46 61.30 323.86 1967.94 1858.94 900.11 -178.32 5946900.93 .558440.06 MWD+IFR-AK-CAZ-SC 2415.35 59.74 326.15 2013.17 1904.17 965.63 -224.20 5946966.08 558393.67 MWD+IFR-AK-CAZ-SC ~ Halliburton Compan~ Survey Report ('omp:m~: ConocoPhillips Alaska Inc. I icl~l: Kup aruk River U nit tiiic: Kup aruk 1J Pad ~1 cll: 1 J-1 52 ~1~cUlrirh: 1 J-1 52LZPB 1 tiunc~ ~IU lucl ~zim ft dey deg 2507.53 61.17 322.16 2600.04 57.97 321.79 2694.14 58.26 320.11 2737.89 57.29 318.61 2824.65 56.33 316.70 2917.67 56.95 310.44 3010.82 58.11 305.21 3106.49 58.00 297.13 3199.84 57.91 291.80 3293.54 57.09 284.95 3386.38 56.42 278.35 3480.31 57.70 271.98 3573.11 57.79 264.56 3666.73 56.46 257.70 3760.80 55.63 251.72 3853.77 55.26 245.94 3945.47 53.52 240.08 4039.70 55.93 231.18 4131.77 57.12 225.10 4225.31 58.72 218.73 4318.68 62.42 211.13 4412.45 62.54 205.36 4505.47 65.67 199.24 4599.02 64.31 198.33 4693.03 65.96 193.22 4784.50 65.62 191.43 4879.26 64.36 190.69 4974.57 67.36 187.23 5068.20 69.45 185.25 5161.20 72.44 182.54 5254.29 77,35 182.62 5347.73 76.10 181.87 5403.00 77.14 182.02 5492.21 83.01 183.11 5558.32 86.09 183.90 5619.33 86.5$ 184.63 5653.10 87.40 185.03 5744.30 92.04 186.12 5839.70 91.58 186.60 5932.69 92.29 184.21 6024.00 92.29 184.21 I)arc: 5/3/2006 Time: 14.0944 I'ac _' ('u-unlinalc(\E) Rcfcrcncr. Well: 1J-152. True North ~'crtical f~ll I)) Ncfercncc 1J-152L2PB1: 109.0 Sce~iun IFtiI Ilcferencec Well (O OON.0.OOE.180.OOAzi) Snncv (alailation ~lcthod: Minimum Curvature Ilh: Oracle 71 U Scs 11U \,'S f~ l~' ft ft ft ft 2058.63 1949.63 1030.60 -271.16 2105.48 1996.48 1093.43 -320.29 2155.19 2046.19 1155.48 -370.62 2178.52 2069.52 1183.56 -394.72 2226.02 2117.02 1237.23 -443.62 2277.20 2168.20 1290.72 -499.88 2327.23 2218.23 1338.87 -561.93. 2377.91 2268.91 1380.84 -631.30 2427.47 2318.47 1413.59 -703.28 2477.86 2368.86 1438.50 -778.20 2528.79 2419.79 1454.18 -854.18 2579.90 2470.90 1461.24 -932.62 2629.48 2520.48 1458.87 -1010.98 2680.34 2571.34 1446.79 -1088.60 2732.91 2623.91 1426.25 -1163.81 2785.68 2676.68 1398.63 -1235.17 2839.10 2730.10 1364.85 -1301.57 2893.59 2784.59 1321.43 -1364.90 2944.40 2835.40 1270.20 -1422.04 2994,12 2885.12 1211.24 -1474.91 3040.04 2931.04 1144.60 -1521.34 3083.39 2974.39 1071.39 -1560.66 3124.04 3015.04 994.00 -1592.34 3163.59 3054.59 913.74 -1619.64 3203.14 3094.14 831.69 -1642.79 3240.66 3131.66 750.20 -1660.60 3280.72 3171.72 665.92 -1677.08 3319.70 3210.70 580.03 -1690.59 3354.16 3245.16 493.49 -1700.04 3384.53 3275.53 405.81 -1705.99 3408.78 3299.78 316.06 -1710.04 3430.23 3321.23 225.19 -1713.60 3443,02 3334.02 171.45 -1715.42 3458.39 3349.39 83.70 -1719.36 3464.67 3355.67 18.02 -1723.39 3468.57 3359.57 -42.69 -1727.92 3470.35 3361.35 -76.30 -1730.75 3470.79 3361.79 -167.04 -1739.61 3467.78 3358.78 -261.80 -1750.17 3464.64 3355.64 -354.32 -1758.93 3460.99 3351.99 -445.31 -1765.63 ~lahA ~IahF. ~fi~pl ft ft 5947030.68 558346.21 MWD+IFR-AK-CAZ-SC 5947093.12 558296.60 MWD+IFR-AK-CAZ-SC 5947154.77 558245.79 MWD+IFR-AK-CAZ-SC 5947182.66 558221.47 MWD+IFR-AK-CAZ-SC 5947235:94 558172.16 MWD+IFR-AK-CAZ-SC 5947288.99 558115.50 MWD+IFR-AK-CAZ-SC 5947336.65 558053.07 MWD+IFR-AK-CAZ-SC 5947378.07 557983.39 MWD+IFR-AK-CAZ-SC 5947410.25 557911.16 MWD+IFR-AK-CAZ-SC 5947434.58 557836.06 MWD+IFR-AK-CAZ-SC 5947449.66 557759.97 MWD+IFR-AK-CAZ-SC 5947456.11 557681.48 MWD+IFR-AK-CAZ-SC 5947453.13 557603.15 MWD+IFR-AK-CAZ-SC 5947440.45 557525.64 MWD+IFR-AK-CAZ-SC 5947419.33 557450.59 MWD+IFR-AK-CAZ-SC 5947391.15 557379.46 MWD+IFR-AK-CAZ-SC 5947356.87 557313.33 MWD+IFR-AK-CAZ-SC 5947312.95 557250:34 MWD+IFR-AK-CAZ-SC 5947261.29 557193.61. MWD+IFR-AK-CAZ-SC 5947201.93 557141.20 MWD+IFR-AK-CAZ-SC 5947134.93 .557095.31 MWD+IFR-AK-CAZ-SC 5947061.42 557056.55 MWD+IFR-AK-CAZ-SC 5946983.80 557025.48 MWD+IFR-AK-CAZ-SC 5946903.34 556998.81 MWD+IFR-AK-CAZ-SC 5946821.12 556976.30 MWD+IFR-AK-CAZ-SC 5946739.49. 556959.13 MWD+IFR-AK-CAZ-SC 5946655.10 556943.31 MWD+IFR-AK-CAZ-SC 5946569.11 556930.47 MWD+IFR-AK-CAZ-SC 5946482.52 556921.69 MWD+IFR-AK-CAZ-SC 5946394.80 556916.43 MWD+IFR-AK-CAZ-SC 5946305.02 556913.08 MWD+IFR-AK-CAZ-SC 5946214.14 556910.22 MWD+IFR-AK-CAZ-SC , 5946160.39 556908.82 MWD+IFR-AK-CAZ-SC 5946072.62 556905.56. MWD+IFR-AK-CAZ-SC 5946006.92 556902.05 MWD+IFR-AK-CAZ-SC 5945946.18 556898.00 MWD+IFR-AK-CAZ-SC 5945912.56 556895.42 MWD+IFR-AK-CAZ-SC 5945821.76 556887.27 MWD+IFR-AK-CAZ-SC 5945726.92 556877.44 MWD+IFR-AK-CAZ-SC 5945634.35 556869.41 MWD+IFR-AK-CAZ-SC 5945543.32 556863.42 PROJECTED to TD ~~~~ ~ ~ ~ , ~ ~ ~ 1 ~~ ~ , ~ ,~ FRANK H. MURKOWSKI, GOVERNOR ~'~~~~ ~7~A Ou! A~D Vro-7 ~ 333 W. 7"' AVENUE, SUITE 100 COrTSER~A1`IO1~T COI~IDIISSIOI~T ; ANCHORAGE, ALASKA 99501-3539 Randy Thomas 3 PHONE c9o~) z~s-ia33 Greater Kuparuk Area Drilling Team Leader FAx ~so'~ 2's-'Sa2 ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510-0360 Re: Kuparuk River, 1J-152L2 ConocoPhillips Alaska, Inc. Permit No: 206-018 Surface Location: 2191' FSL, 2582' FEL, Sec. 35, T 11 N, R 10E, UM Bottomhole Location: 52' FNL, 958' FWL, Sec. 11, T10N, RlOE Dear Mr. Thomas: Enclosed is the approved application for permit to drill the above referenced development well. This permit to drill does not exempt you from obtaining additional permits or 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. 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) 659-3607 (pager). Sincerely, Cath P. Foerster s.f- Commissioner DATED this 3 ~ day of January, 2006 cc: Department of Fish 8v Game, Habitat Section w/ o encl. Department of Environmental Conservation w/ o encl. ~~Ei~/ED ~ ~ STATE OF ALASKA ~ ~i ,IA ~ `~ 6 2~~6 ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL Alaska Oil ~ Gas Cons. Commission 20 AAC 25.005 Anchorage 1a. Type of Work: Drill ~ Redrill Re-entry ^ 1b. Current Well Class: Exploratory ~~ t~ Development Oil ~3~-~>Multiple Zone ^ Stratigraphic Test ^ Servi 'i~~t Development Gas ^ ~~. Fj,-~~s~'Single Zone Q 2. Operator Name: ConocoPhillips Alaska, Inc. 5. Bond: ~ Blanket Single Well Bond No. 59-52-180 ' 11. Well Name and Number: 1J-152L2 3. Address: P.O. Box 100360 Anchorage, AK 99510-0360 6. Proposed Depth: MD: 12940' TVD: 3347' ~ 12. Field/Pool(s): Kuparuk River Field 4a. Location of Well (Governmental Section): Surface: 2191' FSL, 2582' FEL, Sec. 35, T11 N, R10E, UM 7. Property Designation: ADL 25661 & 25662 ~ West Sak Oil Pool Top of Productive Horizon: 2370' FSL, 980' FWL, Sec. 35, T11 N, R10E - 8. Land Use Permit: ALK 471 & 2177 13. Approximate Spud Date: 3/26/2006 Total Depth: ~ 52' FNL, 958' FWL, Sec. 11, T10N, R10E 9. Acres in Property: 2560 14. Distance to Nearest Pro a <3 miles p '~'~ 4b. Location of Well (State Base Plane Coordinates): Surface: x- 558625 - y- 5946002 ' Zone- 4 10. KB Elevation (Height above GL): 28' RKB / 108' AMSL 15. Distance to Nearest Well within Pool: , 1213' @ 12912' 16. Deviated wells: Kickoff depth: 5232 ~ ft. Maximum Hole Angle: g3° deg 17. Maximum Anticipated Pressures in psig (see zo AAC 25.035) Downhole: 1547 psig' Surface: 1169 psig ' 18. Casing Program ecifications S Setting Depth Quantity of Cement Size p Top Bottom c. f. or sacks Hole Casing Weight Grade Coupling Length MD TVD MD TVD (including stage data) 42" 20x34" 94# K-55 Welded 80' 28' 28' 108' 108' 260 cf ArcticCrete 13.5" 10.75" 45.5# L-80 BTC 2825' 28' 28' 2825' 2204' 530 sx AS Lite, 180 sx DeepCrete 9-7/8" 7-5/8" 29.7# L-80 BTCM 6353' 28' 28' 6353' 3639' 360 sx DeepCrete 6.75" 4.5" 12.6# L-80 IBTM 770$' 5232' 3437' 12940'' 3347' ' slottexl liner 19 PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re-Entry Operations) Total Depth MD (ft): Total Depth TVD (ft): Plugs (measured) Effective Depth MD (ft): Effective Depth TVD (ft): Junk (measured) Casing Length Size Cement Volume MD TVD Structural Conductor Surface Intermediate Production Liner - refer to 1 F-01A Perforation Depth MD (ft): ~ ^.~(~~y~ Perforation Depth TVD (ft): 20. Attachments: Filing Fee d BOVP Sketch Drilling Program ~ Time v. Depth Plot Shallow Hazard Analysis ~ Property Plat ^ Diverter Sketch ^ Seabed Report ^ Drilling Fluid Program Q 20 AAC 25.050 requirements 0 21. Verbal Approval: Commission Representative: Date: 22. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Mike Greener @ 263-4820 Printed Name Randy Thomas Title Greater Kuparuk Area Drilling Team Leader Signature ` ~ ,~ Phone L6S' 6$ yp Date ~C2,~la~ P ha n 11 Dr k Commission Use Only Permit to Drill Number: ~..~~ ~ ~~ ~~ API Number: 2 G._~ 50- (,~ L~~' 2_J ~/ ~~ ~ ~ Permit Approval Date: `"~ ~ See cover letter for other requirements Conditions of approval : Q per` 3~~~`~~f'-S Samples required` Yes ^ No Mud log required Yes ^ No [~' Hydrogen sulfide measures Yes ^ No ~ Directional survey required Yes []` No ^ Other: APPROVED BY Approved by: THE COMMISSION Date: J ' 3( `_ ~ ~ f g ~. @ dom. Form 10-401 Revised 06/2004 ~ ~ ~ S;µ„t Submit in Duplicate • Permit It -West Sak Well #1J-152 L2 ~~`~~ r.~ +~k Application for Permit to Dri/l Document, I~Ia~cWll M¢ x 4 Y 1 i z$ +Nel l vviu e Table of Contents 1. Well Name .....................................................................................................................2 Requirements of 20 AAC 25.005 (f) .................................................................... ........................... 2 2. Location Summary .......................................................................................................2 Requirements of 20 AAC 25A05(c)(2) ................................................................................................ 2 Requirements of 20 AAC 25A50(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 25A05(c)(6) ................................................................................................ 4 7. Diverter System Information ...................................................................................... 4 Requirements of 20 AAC 25.005(c)(7) ................................................................................................ 4 8. Drilling Fluid Program ................................................................................................. 4 Requirements of 20 AAC 25.005(c)(8) ................................................................................................ 4 Lateral Mud Program (Ml 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)(17) ............................................................................................. 5 12. Evidence of Bonding ...................................................................................................5 Requirements of 20 AAC 25.005 (c)(?2) ............................................................................................. 5 ~~~ ~ a ~ _ a. ~ ~ r. ,.b Appl~ for Permit to Drill, Well 1 J-152 l2 Revision No.O Saved: 23-Jan-06 1J-152L2 PERMIT !T Page 1 of 6 Printed: 23-Jan-06 • App~n for Permit to Drill, Well 1J-152 l2 Revision No.O Saved: 24-Jan-46 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 7 Directional Plan ............................................................................................................. 6 Attachment 2 Drilling Hazards Summary ............................................................................................. 6 Attachment 3 Well Schematic ............................................................................................................. 6 1. Well Name Requirements of 20 AAC 25.005 (f) Each we//must be identified by a unique name designated by the operator and a unique API number assigned by the commission under 20 AAC Z5.040(b). For a we// with multiple well branches, each branch must similar/y be identified by a unique name and API number by adding a suffix to the name designated for the we// by the operator and to the number assigned to the we// by the commission. The well for which this Application is submitted will be designated as 1J-152 L2. 2. Location Summary Requirements of 20 AAC 25.005(c)(2) An app/ication for a Permit to Dri//must be accompanied by each of the fol%wing items, except for an item a/ready on Fle with the commission and identified in the application: (Z) a plat identifying the property and the property`s owners and showing (A)che coordinates of the proposed location of the we// at the surface, at the top of each objective formation, and at total depth, referenced to govemmenta/ section lines. (B) 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 we/I at the top of each objective formation and at total depth; Location at Surface 2,191' FSL, 2,582' FEL, Section 35, T11N, R10E ASPZone4NAD27Coordinates RKBE/evation 108.0'AMSL Northings: 5,946,002 Eastings: 558,625 Pad E/evation 80.0' AMSL Location at Top of Productive Interval West Sak "D" Sand 2,370' FSL, 980' FWL, Section 35, T11N, R10E ASP Zone 4 NAD 27 Coordinates Measured De th, RKB: 5, 232 Northings: 5,946,167 Eastings: 556,906 Tota/1/ertica/De th, RKB: 3,437 Total I/ertical De th, SS.- 3,328 Location at Total De th 52' FNL 958' FWL, Section 11, T10N R10E ' ASP Zone 4 NAD 27 Coordinates Measured De th, RKB: 12,940 Northings: 5,938,467 Eastings: 556,952 Total ~ertica/ De th, RKB: 3,347 Total I/ertica/Depth, SS.- 3,238 and (D) other information required by 20 AAC 25. u50(b),~ 1J-152L2 PERMl7 !T Page 2 of 6 Printed: 24-Jan-06 • App~n for Permit to Drill, Well 1 J-152 L2 Revision No.O Saved: 23-Jan-46 Requirements of 20 AAC 25.050(b) If a wel/ is to be intentionally deviated, the applJcation for a Permit to Dri/1(Form 10-401) must (I) inc/ude a p/at, drawn to a suitable sca/e, showing the path of the proposed we//bore, including a/l adjacent we//bores within 200 feet of any portion of the proposed we/% Please see Attachment 1: Directional Plan and (2) for a1/ we//s within 200 feet of the praposed cve//bore (A) list the names of the operators of those we//s, to the extent that those names are known or discoverab/e in public records, and show that each named operator has been furnished a copy of the application by certified mail; or (B) state that the applicant is the on/y affected owner The Applicant is the only affected owner. 3. Blowout Prevention Equipment Information Requirements of 20 AAC 25.005(c)(3) An app/ication for a Permit to Dri/l must be accvmpanied by each of the fo/%wmg items, except for an item a/ready 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, ZO AAC 25.036, or 20 AAC 25.037, as app/icab/e,• An API 13-5/8" x 5,000 psi BOP stack (RSRRA) will be utilized to drill and complete well iJ-152 L2. 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 accvmpanied by each of the fo/%wing items, except for an item a/ready on fi/e with the commission and identified in the application.• (4) information on dri//mg hazards, including (A) the maximum downho% pressure that may be 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 1J 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 1,169 psi, calculated thusly: MPSP =(3,437 ft TVD)(0.45 - 0.11 psi/ft) =1,169 psi ' (B) data on potential gas zones,' The well bore is not expected to penetrate any gas zones. and (C) data concerning potentia/ causes of ho% problems such as abnorma//y geo pressured strata, /ost circu/anon zones, and zones that have a propensity for differentia/sticking; Please see Attachment 2: 1J-152 L2 Drilling Hazards Summary. ~ 5. Procedure for Conducting Formation Integrity Tests Requirements of 20 AAC 25.005 (c)(5) An app/ication for a Permit to Dri// must be accampanied by each of the fo/%wing items, except for an item a/ready on file with the cammission and identified in the application: (5) a description of the procedure for conducting formation integrity tests, as required under ZO AAC 2s. 030(>7; The parent wellbore, 1J-152, 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. 7J-152L2 PERMlT lT Page 3 of fi Printed: 23-Jan-06 • App~n for Permit to Drill, Well 1 J-152 L2 Revision No.O Saved: 23-Jan-06 6. Casing and Cementing Program Requirements of 20 AAC 25.005(c)(6) An app/ication for a Permit to Dri// must be accompanied by each of the fol/owing items, except for an item a/ready on fi/e with the commission and identified in the app/icatioir. (6) a complete proposed casing and cementing program as required by 20 AAC 25.030, and a description ofany slotted /ine~ pre- perforated lined or screen to be installed; Casin and Cementin Pro ram Hole Top Bfm Csg/Tbg Size Weigh Length MD/TVD MD/TVD OD in in t !b/ft Grade Connection ft ft R Cement Pro ram 4-1/2 6-3/4" A Sand 12.6 L-80 IBTM 4,270 5,618 / 3,520 9,888 / 3,632 Slotted- no cement Slotted Lateral (1]-152) 4-1/2 6-3/4" B Sand 12.6 L-80 IBTM 7,727 5,518/ 3,502 13,245 / 3,423 slotted- no cement Slotted Lateral (1J-152 Ll) 4-1/2 6-3/4" D sand 12.b L-80 IBTM 7,708 5,232/ 3,437 12,940 / 3,347. Slotted- no cement Slotted Lateral (1J-152 L2) 7. Diverter System Information Requirements of 20 AAC 25.005(c)(7) An app/ication for a Permit to Dri/i must be accompanied by each of the fol/owing 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 25.035(h)(2),- No diverter system will be utilized during operations on 1J-152 L2. 8. Drilling Fluid Program Requirements of 20 AAC 25.005(c)(8) An application for a Permit to Dri/(must be accompanied by each of the fo0owing items, except for an item already on !</e with the commission and identified /n the app/ication: (8) a dri/Gng fluid program, including a diagram and description of the dri//mg fluid system, as required by 20 AAC2S.033; Drilling will be done with muds having the following properties over the listed intervals: Lateral Mud Program (MI VersaPro, Mineral Oil Base) Value Density (ppg 8.6 Plastic Viscostiy 15-25 (lb/100 stj Yield Point 18 28 (cP HTHP Fluid loss (ml/30 min <4 0 @ 200psi & . 150° Oil /Water 70 / 30 Ratio Electrical 650-900 Stability i Drilling fluid practices will be in accordance with appropriate regulations stated in 20 AAC 25.033. Please see information on file with the Commission for diagrams and descriptions of the fluid system of Doyon Rig 141. 1J-952L2 PERMIT lT Page 4 0{& Printed: 23-Jan-06 • Appl~ for Permit to Drill, Well 1 J-152 L2 Revision No.O Saved: 23-Jan-46 9. Abnormally Pressured Formation Information Requirements of 20 AAC 25.005 (c)(9) An app/ication for a Permit to Dri/l must be accompanied by each of the fo/%wing items, except for an item a/ready on fi/e with the commission and identified in the app/icatio~z~ (9) for an exp/oratory or stratigraphic test well, atabu/anon setting out the depths of predicted abnormally geo pressured strata as required by ZO 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 app/ication for a Permit to Dri// must be accompanied by each of the fo!/owing items, except for an item already on fr/e with the commission and identified in the application: (10) For an exp/oratory or stratigraphic test weU a seismic refraction or reflection analysis as required by ZO AAC 25.061(aJ,• 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 app/ication for a Permit to Dri/l must be accompanied by each of the fo/%wing items, except for an item a/ready on fl/e with the commission and identified in the application: (11J for a we// dri//ed from an offshore platform, mobi/e bottom-founded structure, jack-up rig, or floating dri//ing vess% an ana/ysis of seabed conditions as required by 20 AAC25.061(b},- Not applicable: Application is not for an offshore well. 12. Evidence of Bonding Requirements of 20 AAC 25.005 (c)(12) An app/ication for a Permit to Dri/I must be accompanied by each of the fo/%wing items, except for an item a/ready on fi/e with the commission and identified in the app/ication: (12) 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 app/ication for a Permit to Dri// must be accompanied by each of the fo/%wing items, except for an item a/ready on file with the commission and identified in the app/ication: The proposed drilling program is listed below. Please refer also to Attachment 3, Well Schematic. Note: Previous operations are covered under the 1J-152 Application for Permit to Drill. 1. Run and set Baker WindowMaster whipstock system, at window point of 5,232' MD / 3,437' TVD, the top of the D sand. 2. Mill 6-3/4"window. POOH. i 3. Pick up 6-3/4"drilling assembly with LWD and MWD and PWD. RIH. 4. Drill to TD of D sand lateral at 12,940' MD / 3,347' 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. 7. PU and run 4-1/2"slotted liner. 13. RIH, until liner hanger is just above window. Orient hanger to window and land hanger. 9. Release hanger running tool. POOH. 1J-152L2 PERMIT lT Page 5 of fi Printed: 23-Jan-06 • Applt~ for Permit to Drill, Well 1 J-152 L2 Revision No.0 Saved: 23-Jan-06 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. 11. POOH, laying down drill pipe as required. 12. PU completion as required and RIH to depth. Land tubing. Set BPV. 13. Nipple down BOPE, nipple up tree and test. Pull BPV. 14. Freeze protect well with diesel. 14. Discussion of Mud and Cuttings Disposal and Annular Disposal Requirements of 20 AAC 25.005 (c)(14) An app/ication for a Permit to Dri// mustc be accompanied by each of the fo/lowing items, except for an item a/ready on fi/e with the commission and identified in the app/ication: (14) a genera/ description of how the operator p/ans 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 disposa/ operation in the we/%; 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 iJ Pad, hauled to the Prudhoe Bay Grind and Inject Facility for temporary storage and eventual processing for injection down an approved dispasal 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 1J-952L2 PERMIT !T Page 6 of & Printed: 23-Jan-06 k ~. • • ConocoPhillip-s Alaska ConocoPhillips Alaska (Kuparuk) Kuparuk River Unit Kuparuk 1J Pad Plan 1J-152 -Slot 1J-152 1 J -152 L2 Plan: 1J-152 L2 (wp05) Proposal Report 17 January, 2006 HALLIE~~.1RTON ~~~~k~ > d J Q r ~ N ~ 3 3 7 ~ ~ J r r Q Q. ~ ~ C 3 ~ L Ya o~ ~ r V ~ ~ a~~~d a 2 0 H ¢ g m = J C J Q S yy i..f.~ j0 V O C V v ~~ODN NO' ~~ E w nv . 0 N 0 o a " '~ ~ \ m J ~p N U f0 Q (A - V ~I ~: W o ~ ~m01~ m ~ tao J N M ~ r - ~ ~ O! M a ~rnmNnNNmmO w ... ' / ~ 0 ~NmmthNmMn~ y pOplO [G UfONIt~}OSf ~tOmN N CItNOO m a Q Z Q MN O ~ Mf0 T N ~ ~ / / g t +f d ~ o o °cooo°ao o Q C DN 01 Nu'~~ ~ W . /r / py y ~ ~ ~ U / ~ a } NtD O iNN MtM+) M ~~~~ ~ ROO ~ / ZrNM V NmnmO~ N~ t +_) _ / : r M M 'i N IN W 0 Z H N M U N >J W 6~] J W O M N 31 -°o ~ c O O H N J ~~ ~; ~. a o o 0 ~u~}000L) O 3 n F- o u V M p V u~ Q. 3 ~' c J ~ ~ ~ ~ N J N m n -_ _ I- N J N I ~ O d 3 N r Y] O 3 N O 3 . ~ N J N N 7 ~~ n n e~ m 3 0 0 O O D ~ n c~ n O N V r N .- _ N Z ~'_°~ m C0 m ~ ~ v ~ d N, ~ ~ ~ ~ J j n' F- C C+ c0 W ~ C_ t+? Q ~ .. J ~ W ~ O W ~ 3 ~ ~ ~~~ ~° o zQ o v; N o Wo + 00 ~c ~ Z" O O '7 O O ~ V a~- O ~ O ~._. u~ M O O ~ O O M (~ O ~ N (SS U o ~ o ~ N O O lCJ O O O O N 0 O O 0 0 0 :Top of Window - 2370ft FSL 8 980ft FW L -Sec 35 - T11 N_ R10E, 5232ft MD, 3437ft ND -~ ~ - - - - 10 3/4" ~ 0 1500 r `" oo PI DOO 1000 2 330 lp, L2 : BtUn of Window =Drill 30' Rathole, 5244ft MD, 3440ft ND I ~_ 500 ~ ~ 7 5/8" L2 : Build @ 8°/100ft, 5274ft MD, 3446ft ND - _ _ _ _ _. _ _ _ _ ` ` _ 0 _ _ ~ ~ i ~L2 : Continue Build @ 5°/100ft, 5445ft MD, 3462ft ND ~ ~ i183° -500 _ ~~ -- l2 : Continue Geosteer in D-Sand, 5958tt MD, 3433f1 N~ L2 : Sail @ 93.3°, 5481ft MD, 3460ft ND X180° 1000 1J-152 LZ T7 (wp05 1 Drillers Target - defines a corridor with allowable deviation from plan of +/- 50ft while in production zone c ~_ O O O .C 1= O Z r 7 O ~ 1 J-152 (wp05) @ 9888' M D ~ - _ - _ _ - - - - - - 1J-152 L2 (wp05) -12940'M~ 1J-152 L1 (wp05) @ 13245'MD 1J-152 L2 T2 (wp05 WELL DETAILS: Plan 1J-152 Ground Level: 81.00 +N/-S +El-W Northing Easling Latittude Longitude Slot 0.00 0.00 5946002.32 558625.36 70°15'47.084N 149`31'33.778W 1J-152 180° 1 J-152 L2 T4 (wp05 190° T M gnetic North: 24.64° Nlagnelic Field Strength 57570.6nT Dip Angle: 80.72° Dale: 9/3/2004 Model: BGGM2004 a~.t,_I~ ~~ -., _ Sperryt DriilEisvg Services I . - ~1J-152 L2 TS (wpi) ~~ CASING DETAILS - ' ~ No TVD MD Name Size k.41/2~~ 1 2204.00 2825.33 10 314" 10-3/4 - 2 3437.00 5231.62 7 5J8" 7-5/8 3 3347.0012939.90 d 112" 4-1 /2 L2 : BHL @ 52ft FNL & 958ft FW L -Sec 11 - T10N - R 10E, 12940ft MD,3347f1 NDl -5000 -4500 -4000 -3500 -3000 -2500 -2000 -1500 -1000 -500 0 500 1000 1500 2000 2500 r-' ~ ~ Halliburton Energy Services -~aclueuAYOr~: ~~'~~~~~~ Planning Report -Geographic - _°~ ~Ua~k~z Sperry f5ritling So~,rices Database: EDM 2003.11 Single User Db Local Co-ordinate Reference: Well Plan 1J-152 -Slot 1J-152 Company: ConocoPhillips Alaska (Kuparu k} TVD Reference: Planned RKB @ 109.OOft (Doyon 141 {28+81)) Project: Kuparuk River Unit MD Reference: Planned RKB @ 109.OOft (Doyon 141 (28+81)) Site: Kuparuk 1J Pad North Reference: True Well: Plan 1J-152 Survey Calculation Method: Minimum Curvature Wellbore: 1J-152 L2 Design: 1J-152 L2 (wp05) 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 1J-152 -Slot 1J-152 _ __ Well Position +N/-S 0.00 ft Northing: 5,946,002.32 ft Latitude: 70° 15' 47.084" N +E/-W 0.00 ft Easting: 558,625.36 ft Longitude: 149° 31' 33.778" W Position Uncertainty 0.00 ft Wellhead E levation: ft Ground Level: 81.OOft Wellbore 1J-152 L2 I, Magnetics Model Name Sample Date Declination Dip Angle Field Strength ' (°) (°) (nT) i bggm2004 9/3/2004 24.64 80.72 57,571 - - I _ Design 1J-152 L2 (wp05 ) Audit Notes: Version: Phase: PLAN Tie On Depth: 5,231.61 Vertical Section: Depth From (TVD) +N/-S +E/-W Direction i (ft) (ft) (ft) (°) i 28.00 0.00 0.00 180.00 1/17/2006 10:11:48AM Page 2 of 8 ~~~~t COMPASS 2003.11 Build 48 ~--' Halliburton Energy Services HAI.LiBtJRTt3N' Ct?C1t~Ct~i11~§ Planning Report -Geographic - m_ -~ lUa,,~a C) ! l Database: EDM 2003.11 Single User Db Company: ConocoPhillips Alaska (Kuparuk} Project: Kuparuk River Unit Site: Kuparuk 1J Pad Well: Plan 1J-152 Wellbore: 1J-152 ~2 Design: 1J-152 L2 (wp05) Sorry r p ng 5~fwt~e~ Local Co-ordinate Reference: Well Plan 1J-152 -Slot 1J-152 TVD Reference: Planned RKB @ 109.OOft (Doyon 141 (28+81 }j MD Reference: Planned RKB @ 109.OOft (Doyon 141 (28+81 }j North Reference: True Survey Calculation Method: Minimum Curvature Plan Summary Measured Vertical Dogleg Build Turn Depth Inclination Azimuth Depth +N!-S +E/-W Rate Rate Rate TFO (ft} ~~) ~~) (ft) ({fj (ft) (°/100ft) (°/100ft) (°/100ft) ~o) 5,231.61 76.00 184.00 3,437.00 178.47 -1,718.19 0.00 0.00 0.00 0.00 5,243.61 77.91 184.00 3,439.71 166.81 -1,719.01 15.90 15.90 0.00 0.00 5,273.61 77.91 184.00 3,445.99 137.55 -1,721.06 0.00 0.00 0.00 0.00 5,445.14 91.63 184.00 3,461.59 -32.44 -1,732.94 8.00 8.00 0.00 0.00 5,481.46 93.30 183.29 3,460.03 -68.66 -1,735.25 5.00 4.60 -1.97 -23.13 5,958.12 93.30 183.29 3,432.59 -543.74 -1,762.52 0.00 0.00 0.00 0.00 6,036.44 91.63 179.74 3,429.22 -621.95 -1,764.58 5.00 -2.13 -4.53 -115.16 6,536.44 91.63 179.74 3,415.00 -1,121.74 -1,762.32 0.00 0.00 0.00 0.00 6,717.36 86.20 179.68 3,418.42 -1,302.56 -1,761.40 3.00 -3.00 -0.04 -179.33 6,966.14 86.20 179.68 3,434.90 -1,550.79 -1,759.99 0.00 0.00 0.00 0.00 7,137.74 91.35 179.75 3,438.56 -1,722.29 -1,759.14 3.00 3.00 0.04 0.82 8,137.74 91.35 179.75 3,415.00 -2,722.00 -1,754.77 0.00 0.00 0.00 0.00 8,284.95 86.93 179.80 3,417.20 -2,869.16 -1,75420 3.00 -3.00 0.04 179.29 8,510.81 86.93 179.80 3,429.28 -3,094.69 -1,753.43 0.00 0.00 0.00 0.00 8,638.70 90.77 179.73 3,431.85 -3,222.53 -1,752.91 3.00 3.00 -0.06 -1.12 10,338.70 90.77 179.73 3,409.00 -4,922.36 -1,744.90 0.00 0.00 0.00 0.00 10,383.79 91.67 179.73 3,408.04 -4,967.44 -1,744.69 2.00 2.00 0.00 0.00 11,139.17 91.67 179.73 3,386.00 -5,722.49 -1,741.13 0.00 0.00 0.00 0.00 11,160.86 91.24 179.71 3,385.45 -5,744.17 -1,741.03 2.00 -2.00 -0.07 -177.89 12,939.91 91.24 179.71 3,347.00 -7,522.79 -1,732.15 0.00 0.00 0.00 0.00 1f17/2006 10:11:48AM Page 3 of 8 I"0° ~ A 1 ?i ~9 xa~, COMPASS 2003.11 Build 48 t)t'1C~-CQ1~1~5 Alaska Database: EDM 2003.11 Single User Db Company: ConocoPhillips Alaska (Kuparuk Project: Kuparuk River Unit Site: Kuparuk 1J Pad Well: Plan 1J-152 Wellbore: 1J-152 L2 Design: 1J-152 L2 (wp05) Planned Survey 1J-152 L2 (wp05) ~J Haliiburton Energy Services t-+~n~~iBUAron~ Planning Report -Geographic - _ T . SpetTY drilling ~errrrices Local Co-ordinate Reference: Well Plan 1J-152 -Slot 1J-152 TVD Reference: Planned RKB @ 109.OOft (Doyon 141 {28+8~1 }) MD Reference: Planned RKB @ 109.OOft (Doyon 141 (28+81j1 North Reference: True .Survey Calculation Method: Minimum Curvature - Map Map MD Inclination Azimuth TVD SSTVD +N/-S +E/.W Northing Easting DLSEV Vert Section (ft} (°) (°) (ft) (ft) ~ (ft) (ft) Ift) (ft) (°/100ft) (ft) ~i 5,231.61 76.00 184.00 3,437.00 3,328.00 178.47 -1,718.19 5,946,167.39 556,905.99 0.00 -178.47 L2 : Top of Window - 2370ft FSL 8, 980ft FWL -Sec 35 - T11 N - R10E, 5232ft MD, 3437ft TVD - 7 518" 5,243.61 77.91 184.00 3,439.71 3,330.71 166.81 -1,719.01 5,946,155.73 556,905.27 15.90 -166.81 L2 : Bttm of Window - Dritl 30' Ra thote, 5244ft MD, 3440ft ND 5,264.10 77.91 184.00 3,444.00 3,335.00 146.82 -1,720.41 5,946,135.73 556,904.03 0.00 -146.82 5,273.61 77.91 184.00 3,445.99 3,336.99 137.55 -1,721.06 5,946,126.45 556,903.45 0.00 -137.55 L2 : Build @ 8°I100ft, 5274ft Mb, 3446ft TVD 5,300.00 80.02 184.00 3,451.04 3,342.04 111.71 -1,722.86 5,946,100.60 556,901.85 7.99 -111.71 5,400.00 88.02 184.00 3,461.46 3,352.46 12.58 -1,729.79 5,946,001.43 556,895.69 8.00 -12.58 5,445.14 91.63 184.00 3,461.59 3,352.59 -32.44 -1,732.94 5,945,956.39 556,892.89 8.00 32.44 L2 : Continue Build @ 5°/100ft, 5445ft MD, 346 2ft TVD 5,481.46 93.30 183.29 3,460.03 3,351.03 -68.66 -1,735.25 5,945,920.16 556,890.87 5.00 68.66 L2 : Sail @ 93.3°, 5481 ft MD, 3460ft TVD 5,500.00 93.30 183.29 3,458.96 3,349.96 -87.14 -1,736.31 5,945,901.68 556,889.95 0.00 87.14 5,600.00 93.30 183.29 3,453.21 3,344.21 -186.81 -1,742.03 5,945,801.98 556,885.00 0.00 186.81 5,700.00 93.30 183.29 3,447.45 3,338.45 -286.48 -1,747.75 5,945,702.27 556,880.06 0.00 286.48 5,800.00 93.30 183.29 3,441.69 3,332.69 -386.15 -1,753.47 5,945,602.57 556,875.11 0.00 386.15 5,900.00 93.30 183.29 3,435.94 3,326.94 -485.82 -1,759.19 5,945,502.87 556,870.17 0.00 485.82 5,958.12 93.30 183.29 3,432.59 3,323.59 -543.74 -1,762.52 5,945,444.92 556,867.30 0.00 543.74 L2 : Continue Geosteer in D- Sand, S958ft MD, 3433ft TVD 6,000.00 92.41 181.39 3,430.51 3,321.51 -585.54 -1,764.23 5,945,403.12 556,865.92 5.00 585.54 6,036.44 91.63 179.74 3,429.22 3,320.22 -621.95 -1,764.58 5,945,366.71 556,865.84 5.00 621.95 6,100.00 91.63 179.74 3,427.41 3,318.41 -685.48 -1,764.30 5,945,303.19 556,866.62 0.00 685.48 6,200.00 91.63 179.74 3,424.57 3,315.57 -785.44 -1,763.84 5,945,203.25 556,867.86 0.00 785.44 6,300.00 91.63 179.74 3,421.73 3,312.73 -885.40 -1,763.39 5,945,103.30 556,869.09 0.00 $85.40 6,400.00 91.63 179.74 3,418.88 3,309.88 -985.36 -1,762.93 5,945,003.36 556,870.32 0.00 985.36 6,500.00 91.63 179.74 3,416.04 3,307.04 -1,085.32 -1,762.48 5,944,903.42 556,871.55 0.00 1,085.32 6,536.44 91.63 179.74 3,415.00 3,306.00 -1,121.74 -1,762.32 5,944,867.00 556,872.00 0.00 1,121.74 1J-152 L2 T1 (wp05} 6,600.00 89.72 179.72 3,414.25 3,305.25 -1,185.29 -1,762.02 5,944,803.46 556,872.80 3.00 1,185.29 6,700.00 86.72 179.68 3,417.35 3,308.35 -1,285.23 -1,761.49 5,944,703.54 556,874.10 3.00 1,285.23 6,717.36 86.20 179.68 3,418.42 3,309.42 -1,302.56 -1,761.40 5,944,686.21 556,874.33 3.00 1,302.56 6,800.00 86.20 179.68 3,423.89 3,314.89 -1,385.02 -1,760.93 5,944,603.77 556,875.44 0.00 1,385.02 6,900.00 86.20 179.68 3,430.52 3,321.52 -1,484.80 -1,760.37 5,944,504.01 556,876.78 0.00 1,484.80 6,966.14 86.20 179.68 3,434.90 3,325.90 -1,550.79 -1,759.99 5,944,438.02 556,877.66 0.00 1,550.79 7,000.00 87.22 179.69 3,436.84 3,327.84 -1,584.59 -1,759.81 5,944,404.23 556,878.11 3.00 1,584.59 7,100.00 90.22 179.73 3,439.08 3,330.08 -1,684.56 -1,759.31 5,944,304.28 556,879.39 3.00 1,684.56 7,137.74 91.35 179.75 3,438.56 3,329.56 -1,722.29 -1,759.14 5,944,266.55 556,879.86 3.00 1,722.29 7,200.00 91.35 179.75 3,437.09 3,328.09 -1,784.53 -1,758.86 5,944,204.32 556,880.61 0.00 1,7$4.53 7,300.00 91.35 179.75 3,434.74 3,325.74 -1,884.50 -1,758.43 5,944,104.36 556,881.83 0.00 1,884.50 7,400.00 91.35 179.75 3,432.38 3,323.38 -1,984.48 -1,757.99 5,944,004.41 556,883.04 0.00 1,984.48 7,500.00 91.35 179.75 3,430.02 3,321.02 -2,084.45 -1,757.56 5,943,904.45 556,884.25 0.00 2,084.45 7,600.00 91.35 179.75 3,427.67 3,318.67 -2,184.42 -1,757.12 5,943,804.50 556,885.47 0.00 2,184.42 7,700.00 91.35 179.75 3,425.31 3,316.31 -2,284.39 -1,756.68 5,943,704.54 556,886.68 0.00 2,284.39 7,800.00 91.35 179.75 3,422.96 3,313.96 -2,384.36 -1,756.25 5,943,604.59 556,887.90 0.00 2,384.36 1/17/2006 10:11:48AM Page 4 of 8 COMPASS 2003.11 Build 48 ~~~~'. ~--' Hallib urton Energy Serv ices T CfC1t)Ct3p`~i~~l~i5'- Plan i R t ra hi G o WA ----,.~ LLIBU - .. R OfV _ _ w. n ng epor - e g p c 1~la ska '°~S- De91~7ng Se~tvices Database: EDM 2003.11 Sin gle User Db Lo cal Co-ordinate Reference: Well Plan 1J-1 52 -Slot 1J-1 52 Company: ConocoPhillips Al aska (Kuparu k) TV D Reference: Planned RKB @ 109.OOft (Doyon 141 (2 8+81)) Project: Kuparuk River Un it MD Reference: Planned RKB @ 109.OOft (Doyon 141 (2 8+81;1 Site: Kuparuk 1J Pad No rth Reference : True Well: Plan 1J-152 Su rvey Calculati on Method: Minimum Curv ature Wellbore: 1J-152 L2 Design: 1J-152 L2 (wp05) Planned Survey 1J-152 L2 ( wp05) - _ __ Map Map MD Inclination Azimuth TVD SSTVD +N/-S +E1-W Northing Easting DLSEV Vert Section (ft) (°) (°) (ft) (ft) (ft) (ft) (ft) (ft) (°f100ftj (ft) ~' 7,900.00 91.35 179.75 3,420.60 3,311.60 -2,484.33 -1,755.81 5,943,504.63 556,889.11 0.00 2,484.33 8,000.00 91.35 179.75 3,418.25 3,309.25 -2,584.30 -1,755.37 5,943,404.68 556,890.33 0.00 2,584.30 8,100.00 91.35 179.75 3,415.89 3,306.89 -2,684.27 -1,754.94 5,943,304.72 556,891.54 0.00 2,6$4.27 8,137.74 91.35 179.75 3,415.00 3,306.00 -2,722.00 -1,754.77 5,943,267.00 556,892.00 0.00 2,722.00 1J-152 L2 T2 (wp05) 8,200.00 89.48 179.77 3,414.55 3,305.55 -2,784.26 -1,754.51 5,943,204.75 556,892.74 3.00 2,784.26 8,284.95 86.93 179.80 3,417.20 3,308.20 -2,869.16 -1,754.20 5,943,119.87 556,893.72 3.00 2,869.16 8,300.00 86.93 179.80 3,418.01 3,309.01 -2,884.19 -1,754.15 5,943,104.84 556,893.89 0.00 2,884.19 8,400.00 86.93 179.80 3,423.36 3,314.36 -2,984.04 -1,753.81 5,943,005.00 556,895.00 0.00 2,984.04 8,500.00 86.93 179.80 3,428.71 3,319.71 -3,083.90 -1,753.47 5,942,905.16 556,896.12 0.00 3,083.90 8,510.81 86.93 179.80 3,429.28 3,320.28 -3,094.69 -1,753.43 5,942,894.37 556,896.24 0.00 3,094.69. 8,600.00 89.61 179.75 3,431.97 3,322.97 -3,183.84 -1,753.09 5,942,805.24 556,897.28 3.00 3,183.84 8,638.70 90.77 179.73 3,431.85 3,322.85 -3,222.53 -1,752.91 5,942,766.55 556,897.76 3.00 3,222.53 8,700.00 90.77 179.73 3,431.02 3,322.02 -3,283.83 -1,752.62 5,942,705.26 556,898.52 0.00 3,283.83 8,800.00 90.77 179.73 3,429.68 3,320.68 -3,383.82 -1,752.15 5,942,605.29 556,899.77 0.00 3,383.82 8,900.00 90.77 179.73 3,428.33 3,319.33 -3,483.81 -1,751.68 5,942,505.32 556,901.02 0.00 3,483.81 9,000.00 90.77 179.73 3,426.99 3,317.99 -3,583.80 -1,751.21 5,942,405.34 556,902.27 0.00 3,583.80 9,100.00 90.77 179.73 3,425.65 3,316.65 -3,683.79 -1,750.74 5,942,305.37 556,903.52 0.00 3,683.79 9,200.00 90.77 179.73 3,424.30 3,315.30 -3,783.78 -1,75027 5,942,205.39 556,904.77 0.00 3,783.78 9,300.00 90.77 179.73 3,422.96 3,313.96 -3,883.77 -1,749.80 5,942,105.42 556,906.02 0.00 3,883.77 9,400.00 90.77 179.73 3,421.61 3,312.61 -3,983.76 -1,749.33 5,942,005.45 556,907.27 0.00 3,983.76 9,500.00 90.77 179.73 3,420.27 3,311.27 -4,083.75 -1,748.85 5,941,905.47 556,908.52 0.00 4,083.75 9,600.00 90.77 179.73 3,418.93 3,309.93 -4,183.74 -1,748.38 5,941,805.50 556,909.77 0.00 4,183.74 9,700.00 90.77 179.73 3,417.58 3,308.58 -4,283.73 -1,747.91 5,941,705.53 556,911.02 0.00 4,283.73 9,800.00 90.77 179.73 3,416.24 3,307.24 -4,383.72 -1,747.44 5,941,605.55 556,912.27 0.00 4,383.72 9,900.00 90.77 179.73 3,414.90 3,305.90 -4,483.71 -1,746.97 5,941,505.58 556,913.52 0.00 4,483.71 10,000.00 90.77 179.73 3,413.55 3,304.55 -4,583.70 -1,746.50 5,941,405.61 556,914.77 0.00 4,583.70 10,100.00 90.77 179.73 3,412.21 3,303.21 -4,683.69 -1,746.03 5,941,305.63 556,916.02 0.00 4,683.69 10,200.00 90.77 179.73 3,410.86 3,301.86 -4,783.68 -1,745.56 5,941,205.66 556,917.27 0.00 4,783.68 10,300.00 90.77 179.73 3,409.52 3,300.52 -4,883.67 -1,745.09 5,941,105.69 556,918.52 0.00 4,883.67 10,338.70 90.77 179.73 3,409.00 3,300.00 -4,922.36 -1,744.90 5,941,067.00 556,919.00 0.00 4,922.36 1J-152 L2 T3 (wp05) 10,383.79 91.67 179.73 3,408.04 3,299.04 -4,967.44 -1,744.69 5,941,021.92 556,919.56 2.00 4,967.44 10,400.00 91.67 179.73 3,407.57 3,298.57 -4,983.64 -1,744.61 5,941,005.72 556,919.77 0.00 4,983.64 10,500.00 91.67 179.73 3,404.65 3,295.65 -5,083.60 -1,744.14 5,940,905.78 556,921.02 0.00 5,083.60 10,600.00 91.67 179.73 3,401.73 3,292.73 -5,183.56 -1,743.67 5,940,805.84 556,922.26 0.00 5,183.56 10,700.00 91.67 179.73 3,398.81 3,289.81 -5,283.51 -1,743.20 5,940,705.90 556,923.51 0.00 5,283.51 10,800.00 91.67 179.73 3,395.90 3,286.90 -5,383.47 -1,742.73 5,940,605.96 556,924.76 0.00 5,383.47 10,900.00 91.67 179.73 3,392.98 3,283.98 -5,483.43 -1,742.26 5,940,506.02 556,926.01 0.00 5,483.43 11,000.00 91.67 179.73 3,390.06 3,281.06 -5,583.38 -1,741.79 5,940,406.08 556,927.26 0.00 5,583.38 11,100.00 91.67 179.73 3,387.14 3,278.14 -5,683.34 -1,741.32 5,940,306.14 556,928.51 0.00 5,683.34 11,139.17 91.67 179.73 3,386.00 3,277.00 -5,722.49 -1,741.13 5,940,267.00 556,929.00 0.00 5,722.49 1J-152 L2 T4 (wp05) 11,160.86 91.24 179.71 3,385.45 3,276.45 -5,744.17 -1,741.03 5,940,245.32 556,929.27 2.00 5,744.17 11,200.00 91.24 179.71 3,384.60. 3,275.60 -5,783.30 -1,740.83 5,940,206.19 556,929.77 0.00 5,783.30 11,300.00 91.24 179.71 3,382.44 3,273.44 -5,883.28 -1,740.33 5,940,106.24 556,931.05 0.00 5,883.28 11,400.00 91.24 179.71 3,380.28 3,271.28 -5,983.25 -1,739.83 5,940,00628 556,932.33 0.00 5,983.25 11,500.00 91.24 179.71 3,378.12 3,269.12 -6,083.23 -1,739.33 5,939,906.32 556,933.61 0.00 6,083.23 11,600.00 91.24 179.71 3,375.96 3,266.96 -6,183.21 -1,738.83 5,939,806.36 556,934.88 0.00 6,183.21 1/17/2006 10:11:48AM Page 5 of 8 COMPASS 2003. ? 1 Build 48 ORIGINAL r.-' ~ Halliburton Energy Serv ices HA-L ~BURTt'~N' i ~'~~~~~~~ Planning Report -Geographic . _m_.~-°- ~. °° -~~ ~ ~-~-~ ~ Alaska ~ Drl~ll~ng S~tvices Database: EDM 2003.11 Sin gle User Db Local Co-ordina te Reference: Well Plan 1J-1 52 -Slot 1J-152 Company: ConocoPhillips Al aska (Kuparu k) ND Reference: Planned RKB @ 109.OOft (Doy on 141 (2 8+81 ~j Project: Kuparuk River Un it MD Reference: Planned RKB @ 109.OOft (Doy on 141 (2 8+81 )) Site: Kuparuk 1J Pad North Reference: True Well: Plan 1J-152 Survey Calculat ion Method: Minimum Gurv ature Wellbore: 1J-152 L2 Design: 1J-152 L2 (wp05) Planned Sur vey 1J-152 L2 (wp05) Map Map MD Inclination Azimuth ND SSND +N/-S +E/-W Northing Easting DLSEV Vert Section (ft) (°) (°~ (ft) (ft) (ft) (fti (ft) (ft) (°/100ftj (ft} 11,700.00 91.24 179.71 3,373.80 3,264.80 -6,283.18 -1,738.34 5,939,706.40 556,936.16 0.00 6,283.18 11,800.00 91.24 179.71 3,371.64 3,262.64 -6,383.16 -1,737.84 5,939,606.44 556,937.44 0.00 6,383.16 11,900.00 91.24 179.71 3,369.47 3,260.47 -6,483.13 -1,737.34 5,939,506.48 556,938.72 0.00 6,483.13 12,000.00 91.24 179.71 3,367.31 3,258.31 -6,583.11 -1,736.84 5,939,406.52 556,939.99 0.00 6,583.11 12,100.00 91.24 179.71 3,365.15 3,256.15 -6,683.08 -1,736.34 5,939,306.56 556,941.27 0.00 6,683.08 12,200.00 91.24 179.71 3,362.99 3,253.99 -6,783.06 -1,735.84 5,939,206.61 556,942.55 0.00 6,783.06 12,300.00 91.24 179.71 3,360.83 3,251.83 -6,883.03 -1,735.34 5,939,106.65 556,943.83 0.00 6,883.03 12,400.00 91.24 179.71 3,358.67 3,249.67 -6,983.01 -1,734.84 5,939,006.69 556,945.10 0.00 6,983.01 12,500.00 91.24 179.71 3,356.51 3,247.51 -7,082.98 -1,734.34 5,938,906.73 556,946.38 0.00 7,082.98 12,600.00 91.24 179.71 3,354.35 3,245.35 -7,182.96 -1,733.84 5,938,806.77 556,947.66 0.00 7,182.96 12,700.00 91.24 179.71 3,352.18 3,243.18 -7,282.93 -1,733.34 5,938,706.81 556,948.94 0.00 7,282.93 12,800.00 91.24 179.71 3,350.02 3,241.02 -7,382.91 -1,732.85 5,938,606.85 556,950.21 0.00 7,382.91 12,900.00 91.24 179.71 3,347.86 3,238.86 -7,482.89 -1,732.35 5,938,506.89 556,951.49 0.00 7,482.89 12,939.91 91.24 179.71 3,347.00 3,238.00 -7,522.79 -1,732.15 5,938,467.00 556,952.00 0.00 7,522.79 L2 : BHL @ 52ft FNL & 958ft FWL - Sec 11 - T10 N - R10E, 12940ft MD,3347ft ND - 4112" -1J-152 L2 TS (wp05) s' 1/17/2006 10:11:48AM Page 6 of 8 COMPASS 2003.11 Build 48 ~~ ~ ~-` Halliburton Ener Services 9Y ~~1'1CfCC)~'3i~t Pl t G hi i R HALLIBURTL7N - --- -„ ann epor - eograp ng c !flasks Sperry Dri111ing Serarrices Database: EDM 2003.11 Single User Db Local Co-ordinate Reference: Well Plan 1J-152 -Slot 1J-152 Company: ConocoPhillips Alaska (Kuparu k) TVD Reference: Planned RKB @ 109.OOft (Doyon 141 {28+81)) Project: Kuparuk River Unit MD Reference: Planned RKB @ 109.OOft (Doyon 141 (28+81)) Site: Kuparuk 1J Pad North Reference: True Well: Plan 1J-152 Survey Calculation Method: Minimum Curvature Wellbore: 1 J-152 L2 Design: 1J-152 L2 (wp05) __ Geologic Targets 1J-152 L2 TVD Target Name +N/-S +E/-W Northing Easting (ft) -Shape ft ft (ft) (ft) 3,437.00 1J-152 L2 DD Poly (wp05) 178.47 -1,718.19 5,946,167.39 556,905.99 - Polygon Point 1 -50.00 0.00 5,946,167.00 556,856.00 Point 2 -64.75 -210.52 5,945,956.39 556,842.89 Point 3 -94.33 -721.83 5,945,444.92 556,817.30 Point4 -94.13 -1,299.82 5,944,867.00 556,822.00 Point 5 -86.58 -2,900.08 5,943,267.00 556,842.00 Point 6 -76.71 -5,100.44 5,941,067.00 556,869.00 Point 7 -72.94 -5,900.57 5,940,267.00 556,879.00 Point 8 -63.96 -7,700.87 5,938,467.00 556,902.00 Point 9 36.05 -7,701.65 5,938,467.00 557,002.00 Point 10 27.07 -5,901.35 5,940,267.00 556,979.00 Point 11 23.29 -5,101.22 5,941,067.00 556,969.00 Point 12 13.42 -2,900.86 5,943,267.00 556,942.00 Point 13 5.88 -1,300.60 5,944,867.00 556,922.00 Point 14 5.68 -722.61 5,945,444.92 556,917.30 Point 15 35.26 -211.30 5,945,956.39 556,942.89 Point 16 50.00 0.00 5,946,167.78 556,955.99 3,386.00 1J-152 L2 T4 {wp05) -5,722.49 -1,741.13 5,940,267.00 556,929.00 - Point 3,415.00 1J-152 L2 T1 (wp05) -1,121.74 -1,762.32 5,944,867.00 556,872.00 - Point 3,415.00 1J-152 L2 T2 (wp05) -2,722.00 -1,754.77 5,943,267.00 556,892.00 - Point 3,409.00 1J-152 L2 T3 {wpp5) -4,922.36 -1,744.90 5,941,067.00 556,919.00 - Point 3,347.00 1J-152 L2 T5 {wp05) -7,522.79 -1,732.15 5,938,467.00 556,952.00 - Point ~ Prognosed Casing Points Measured Vertical Depth Depth (ft) (ft) 2,825.33 2,204.00 5,231.62 3,437.00 12,939.90 3,347.00 Casing Hole Diameter (~~) Diameter (") 10/4 13-1f2 7-5l8 9-7/8 4-1/2 6-314 1/17!2006 10:11:48AM Page 7 of 8 COMPASS 2003.11 Build 48 ~~ ~--` Halliburton Energy Services HALt~.lBUt~Tt7tV c~Ctc~+~~hili 5 - Planning Report -Geographic Alaska Database: EDM 2003.11 Single User Db Company: ConocoPhillips Alaska (Kuparuk) Project: Kuparuk River Unit Site: Kuparuk 1J Pad Well: Plan 1J-152 Wellbore: 1 J-152 L2 Design: 1J-152 L2 (wp05) Prognosed Formation Intersection Points aperrY ~1r;tlNttg $errvices Local Co-ordinate Reference: Well Plan 1J-152 -Slot 1J-152 TVD Reference: Planned RKB @ 109.OOft (Doyon 141 (28+81)) MD Reference: Planned RKB @ 109.OOft (Doyon 141 (28+81)) North Reference: True Survey Calculation Method: Minimum Curvature Measured Vertical Depth Inclination Azimuth Depth +NI-E +E/-W (ft) (~) (~) (ftJ !ft) (ft) Name 1,689.59 47.14 355.00 1,541.00 513.51 -44.93 Base of Perm 1,870.86 52.87 349.56 1,659.00 649.83 -62.23 T3 2,368.62 55.59 324.44 1,942.00 1,028.03 -20922 K15 2,825.33 53.89 299.80 2,204.00 1,281.77 -480.10 T3 + 5$0 3,950.55 53.45 230.74 2,869.00 1,21722 -1,331.81 Ugnu C 4,275.65 57.66 211.66 3,054.00 1,016.32 -1,506.16 Ugnu B 4,427.38 60.55 203.48 3,132.00 901.01 -1,566.21 Ugnu A 4,820.76 6524 193.58 3,306.00 562.84 -1,664.61 K13 5,264.10 77.91 184.00 3,444.00 146.82 -1,720.41 West Sak D 1/17/2006 10:11:48AM ,Page 8 of 8 COMPASS 2003.11 Build 48 ~ • ConocoPhillips Alaska ConocoPhillips Alaska (Kuparuk) Kuparuk River Unit Kuparuk 1J Pad Plan 1J-152 1 J -152 L2 Anticollision Summary 17 January, 2006 ~A~~..~~i ~~T~ Sperry -ri~~in~ Ser~~~+~ SCRPEI' PKOGRAII NAD 27 ASP Zone 4 : WELL DETAILS: Plan 1J-152 ConocoPhillips Alaska (Kuparuk) ANTI-COLLISION SETTINGS Uate: 2W601-17T'UO:OO:W ~'slidahd: l~es 1'enimc Ground Level: 81.00 Drilling & Wells Interpolation Method: MD Interval: SOStations *N/-S +EI-W Northing Easting Latittude Longitude Slot West Sak Uepth fi~mn Uepth T° 8unrylPlen Twl Depth Range From: 5231.61 To 12939.91 0.00 0.00 59411002.32 558825.36 70°75'47.084N 149°31'33.778W 1J-152 28.110 799.00 CB-G]RO-S8 Maximum Range:1521.fi7826704813 Calculation Method: Minimum Curvature 800.OU 5231.61 31RU+IPR-.4K-C.4ZSC Reference: Plan: 1J-152 L2 (wp05) Error System: ISCWSA 5231.61 12939.91 ]J-1.5212 (xp05) 3CWU+IFR-AK-C'AZSC Scan Method: Trav. Cylinder North Error Surface: Elliptical Conic Warning Method: Rules Besed 330 ~~ 270 so 25 210 150 From Colour To MD 0 5200 5200 5500 5500 6000 6000 6500 6500 7000 180 7000 7500 7500 8000 8000 8500 8500 9000 Travelling Cylinder Azimuth (TFO+AZI) ~°] vs Centre tD Centre Separation ]150 ft/in] 9000 ° -- 9500 9500 10000 10000 10500 10500 11000 11000 11500 11500 12000 12000 12500 REFERENCE INFORMATION Coordinate (NIE) Reference: Well Plan 1J-152 -Slot 1J-152, True North Vertical (ND) Reference: Planned RKB @ 109.DOtt (Doyon 147 (28+81)) Section (VS) Reference: Slot -1J-152(O.DON, O.OOE) Measured Depth Reference: Planned RKB @ 109.00([ (Doyon 141 (28+81)) Calculation Method: Minimum Curvature 180 Travelling Cylinder Azimuth (TFO+AZI) [°~ vs Centre [D Centre Separation (IS ft/in( SECTION DETAILS Sac MD Inc Azi TVD +NlS +EI-W DLeg TFace VSec Target 1 5231.81 78.00 164.00 3437.00 178.47 -1718.19 0.00 0.00 -178.47 2 5243.61 77.91 784.00 3439.71 186.81 -1719.01 15.90 0.00 -166.81 3 5273.61 77.91 784.00 3445.99 137.55 -7727.06 0.00 0.00 -137.55 4 5445.14 91.83 164.00 3461.59 -32.44 -1732.94 8.00 0.00 32.44 5 5481.48 93.30 183.29 3460.03 -88.86 -1735.25 5.00 •23.13 88.68 6 5958.12 93.30 183.29 3432.59 543.74 -1762.52 0.00 0.00 543.74 7 6036.44 97.63 779.74 3429.22 521.95 -1764.58 5.00 -175.18 827.95 8 6536.44 91.63 179.74 3415.00 -1121.74 -1762.32 0.00 0.00 1127.74 1J-152 L2 T1 (wp05) 9 6717.38 88.20 179.68 3418.42 -7302.56 -1781.40 3.00 -779.33 1302.56 10 6966.14 86.20 179.68 3434.90 -1550.79 -1759.99 0.00 0.00 7550.79 11 7137.74 91.35 179.75 3438.58 -1722.29 -1759.14 3.00 0.82 1722.29 12 8137.74 91.35 179.75 3415.00 -2722.00 -1754.77 0.00 0.00 2722.00 1J-152 L2 T2 (wp05) 13 8284.95 86.93 179.80 3417.20 -2869.16 -1754.20 3.00 179.29 2869.18 id 8510.61 86.93 179.80 3429.28 -3094.89 -1753.43 0.00 0.00 3094.89 15 8638.70 90.77 179.73 3431.85 -3222.53 -1752.91 3.00 -1.12 3222.53 16 70338.70 90.77 179.73 3409.00 4922.36 -1744.90 0.00 0.00 4922.36 1J-152 L2 T3 (wp05) 17 10383.79 97.67 77973 3408.04 ~196L44 -1744.69 2.00 0.00 4967.44 18 11139.17 91.67 179.73 3388.00 -5722.49 -1747.13 0.00 0.00 5722.49 1J-152 L2 T4 (wp05) 79 17760.86 97.24 179.77 3385.45 -5744.17 -7747.03 2.OD -777.89 5744.77 20 12939.91 91.24 179.71 3347.00 -7522.79 -1732.15 0.00 0.00 7522.79 1 J-152 L2 T5 (wp05) C~'tt~+~~Pt~illi~s A,lasr,D_ • Halliburton Energy Services FiAL.1.1BURTC#N Anticollision Report _ .~--~-~_- ,~u.-. --°° -.~° ~rperry Dt~INng Services Company: ConocoPhillips Alaska (Kuparuk) Project: Kuparuk River Unit Reference Site: Kuparuk 1J Pad Site Error: O.OOft Reference Well: Plan 1J-152 Well Error: O.OOft Reference Wellbore 1J-152 L2 Reference Design: 1J-152 L2 (wp05) Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Output errors are at Database: Offset ND Reference: Well Plan 1J-152 -Slot 1J-152 Planned RKB @ 109.OOft (Doyon 141 (28+81 )) Planned RKB @ 109.OOft (Doyon 141 (28+81)1 True Minimum Curvature 2.00 sigma EDM 2003.11 Single User Db Reference Datum Reference 1J-152 L2 (wp05) Filter type: GLOBAL FILTER APPLIED: All wellpaths within 200'+ 100!1000 of referE Interpolation Method: MD Interval 50.OOft Error Model: ISCWSA Depth Range: 5,231.61 to 12,939.91ft Scan Method: Trav. Cylinder North Results Limited by: Maximum center-center distance of 1,491.19ft Error Surface: Elliptical Conic Warning Levels evaluated at: 0.00 Sigma Survey Tool Program Date 1/17/2006 From To (ft) (ft) Survey (Wellbore) 28.00 799.00 1J-152 (wp05) (1J-152) 800.00 5,231.61 1J-152 (wp05) (1J-152) 5,231.61 12,939.91 1J-152 L2 (wp05) (1J-152 L2) Tool Name Description CB-GYRO-SS Camera based gyro single shot MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 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 1!17/2006 10:22:31AM Page 2 of 3 COMPASS 2003.11 Build 48 - .~~~ ~~ • ~-' Halliburton Energy Services HAL.LIBtJRTQN t~iC~~l°tillrp5 Anticollision Report _ .umy. Alaska Sperry 6rithng 3grv7+c~es Company: ConocoPhillips Alaska (Kuparuk) Local Co-ordinate Reference: Well Plan 1J-152 -Slot 1J-152 Project: Kuparuk River Unit ND Reference: Planned RKB @ 109.OOft (Doyon 141 (28+81)1 Reference Site: Kuparuk 1J Pad MD Reference: Planned RKB @ 109.OOft (Doyon 141 (28+81)i Site Error: O.OOft North Reference: True Reference Well: Plan 1J-152 Survey Calculation Method: Minimum Curvature Well Error: O.QOft Output errors are at 2.00 sigma Reference Wellbore 1J-152 L2 Database: EDM 2003.11 Single User Db Reference Design: 1J-152 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 1J-154 - 1J-154 - 1J-154 Rig 11,019.19 9,063.00 1,255.46 223.43 1,032.03 Pass -Major Risk 1J-154 - 1J-154 L1 - 1J-154 L1 12,911.97 10,950.00 1,212.91 284.56 928.35 Pass -Major Risk 1J-154 - 1J-154 L2 - 1J-154 L2 12,933.73 10,950.00 1,253.73 287.68 966.05 Pass -Major Risk 1 J-164 - 1 J-164 - 1 J-164 Out of range 1J-164 - 1J-164 L1 - 1J-164 L1 Out of range 1 J-164 - 1 J-164 L2 - 1 J-164 L2 Out of range 1J-164 - 1J-164 L2 P61 - 1J-164 L2 PB1 Out of range Plan 1J-102 - 1J-102 - 1J-102 (wp04) Out of range Plan 1J-102 - 1J-102 L1 - 1J-102 L1 (wp03) Out of range Plan 1J-102 - 1J-102 L2 - 1J-102 L2 (wp03) Out of range Plan 1J-103 -Plan 1J-103 - 1J-103 (wp01) BHI Out of range Plan 1J-105 -Plan 1J-105 - 1J-105 (wp01) BHI Out of range Plan 1J-107 -Plan 1J-107 - 1J-107 (wp01) BHI Out of range Plan 1J-109 -Plan 1J-109 - 1J-109 (wp04) Out of range Plan 1J-111 -Plan 1J-111 - 1J-111 (wp02) Out of range Plan 1J-123 Kuparuk Prelim - 1 J-23 E Lat - 1 J-23 6,289.63 4,450.00 435.08 103.59 331.49 Pass -Major Risk Plan 1J-123 Kuparuk Prelim - 1J-23 Pilot -1J-23 F 6,289.63 4,450.00 435.08 103.59 331.49 Pass -Major Risk Plan 1J-123 Kuparuk Prelim - 1J-23 W Lat - 1J-23 6,289.63 4,450.00 435.08 103.59 331.49 Pass -Major Risk Plan 1J-152 - 1J-152 -1J-152 (wp05) 5,249.99 5,250.00 0.41 2.06 -1.65 FAIL - No Errors Plan 1J-152 - 1J-152 L1 -1J-152 L1 (wp05) 5,249.99 5,250.00 0.41 2.06 -1.65 FAIL - No Errors Plan 1J-156 - 1J-156 L1 - 1J-156 L1 (wp02) 5,845.95 3,850.00 896.25 99.36 796.89 Pass -Major Risk Plan 1J-156 - 1J-156 L2 - 1J-156 L2 (wp02) 5,845.95 3,850.00 896.25 99.36 796.89 Pass -Major Risk Plan 1J-156 -Plan 1J-156 - 1J-156 (wp02) 5,845.95 3,850.00 896.25 99.36 796.89 Pass -Major Risk Plan 1J-158 - 1J-158 - 1J-158 (wp2A) BHI Out of range Plan 1J-159 - 1J-159 - 1J-159 (wp06j Out of range Plan 1J-159 - 1J-159 L1 - 1J-159 L1 (wp06) Out of range Plan 1J-159 - 1J-159 L2 - 1J-159 L2 (wp06) 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 1 J-162 - 1 J-162 L2 - 1 J-162 L2 (wp3.1) Out of range Plan 1J-166 - 1J-166 - 1J-166 5,258.66 3,650.00 590.03 75.39 514.64 Pass -Major Risk Plan 1J-166 - 1J-166 L1 - 1J-166 L1 (wp07) 5,250.83 3,650.00 616.08 76.31 539.77 Pass -Major Risk Plan 1J-166 - 1J-166 L1 - 1J-166 L1 Rig 5,258.66 3,650.00 590.03 75.39 514.64 Pass -Major Risk Plan 1J-166 - 1J-166 L2 -1J-166 L2 (wp07) 5,250.83 3,650.00 616.08 76.31 539.77 Pass -Major Risk Plan 1J-170 -Plan 1J-170 - 1J-170 (wp02) 6,920.62 3,999.98 1,050.04 102.68 947.36 Pass -Major Risk Plan 1J-170 -Plan 1J-170 L1 - 1J-170 L1 (wp02) 6,920.62 3,999.98 1,050.04 102.69 947.35 Pass -Major Risk Plan 1J-170 -Plan 1J-170 L2 - 1J-170 L2 (wp02) 6,920.62 3,999.98 1,050.04 102.69 947.35 Pass -Major Risk Plan 1J-173 Kuparuk - 1J-73 E Lateral - 1J-73 E L 6,582.22 4,299.98 33529 101.21 234.07 Pass -Major Risk Plan 1J-173 Kuparuk - 1 J-73 Kuparuk - 1J-73 W L 6,582.22 4,299.98 33529 101.21 234.07 Pass -Major Risk Plan 1J-173 Kuparuk - 1J-73 Pilot - 1J-173 Pilot (v 6,582.22 4,299.98 335.29 101.21 234.07 Pass -Major Risk Plan 1J-178 -Plan 1J-178 - 1J-178 (wp01) 10,206.39 5,950.00 1,351.79 155.71 1,196.08 Pass -Major Risk Plan 1J-180 -Plan 1J-180 - 1J-180 (wp01) 12,572.38 8,100.00 821.17 242.60 578.57 Pass -Major Risk Plan 1J-182 - 1J-182 - 1J-182 (vvp05) 12,91.2.72 8,450.00 170.81 25.50 145.31 Pass -Minor 1/200 Plan 1J-182 - 1J-182 L1 - 1J-182 L1 (wp05) 12,912.72 8,450.00 170.81 0.51 170.30 Pass -Minor 1!200 Plan 1J-184 - 1J-184 - 1J-184 (wp09) 12,936.76 8,299.97 1,399.17 303.36 1,095.81 Pass -Major Risk Plan 1J-184 - 1J-184 L1 - 1J-184 L1 (wp09) 12,936.76 8,299.97 1,399.17 303.41 1,095.76 Pass -Major Risk WSP-02 -WSP-02 -WSP-02 Out of range WSP-1 S -WSP-1 S -WSP-1 S Out of range CC -Min centre to center distance or covergent point, SF -min separation factor, ES -min ellipse separation 1/17!2006 10:22:31AM Page 3 of 3 COMPASS 2003.11 Build 48 C -152L~rilling Hazard~um (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 ation Strate Abnormal Reservoir Pressure Low Stripping drills, shut-in drills, increased mud wei ht. Stuck Pipe Low Good hole cleaning, PWD tools, hole o ener runs, decreased mud wei ht Lost Circulation Low Reduced um rates, mud rheolo , LCM Hole Swabbing on Trips Moderate Trip speeds, proper hole filling (use of trip sheets , um in out, backreamin 1J-152L2 Drilling Hazards Summary ' ~~,~ ~ Prepared by Mike Greener iE 1/23/2006 7:14 AM insulated Conductor Casino. 211". 94-. K55 ~ id", 03 L"' \\"I ii ~ ~.- RO' ~IU ~~. ~~ P7 v Cf wd rn r. ~ n S ~ A 2 3 ~• ^ m ~. =- e 0 ~~~0 rt ~- e a ~~ V N Wellhead / Tubiug Head /Tree, 10-3ld" r 4-';:", 5,000 ksi TLbhte String: 4-1/2", 12.6 N, L-80, LBTM (2) Gas Lift Mandrels, C'AMC'O 4•U2" x 1" Model KMBG wl dummy vah~es, one (u+. 100' MD & one C. 150' MD, both aze both dowmhole recombination 10.3/4", 68N, L-80, BTC, R3 C:. 2,825' MD / 2,204' TVD ~~ L. 53.9 degrees TD 13-1 ?" hole ~ }_ (I I Gns Lift Mandrel, CAMCG d- I i2" x 1" Model KMBG w! dummy wake (n;., one (11 set (u.. 2,400' MD, 1,959' TVD. (1) Gas Lift h1andrel, CAMCD 4-1'2" s 1" Model KMBG w' dummy valve, ~; < T deg, 5,(1(1(1' MD, 3.373' TVD. Electric Submersible Pump, Cenirili ft 418 HP motor, with FC6000 wireline deployed pump. Bottom at 6,193' h1D, 3,fi20' TVD 152 L2 "D" Sand Window ~.: 5,232' M D/ 3,d3 T T V D Top of R est Sak B 5,518' DID 13,502' TVD ----' Lateral Entry Module d] (LEM), Baker, with seal bore attd ZXP packer above. t '3 ~ ~~ s c S Tubing, 4-'r." 1BTM, from LEM to A2 Lmer, with seal stem and CAMCD 3.562" "DB" nipple. Seal bore and ZXP packer for A2 Ivter +/- 90' below "B" window Top of Rest Sak A (k 6 i53' hiD 13,530' TVD ~ "D" Liner, 4-11:', 12.SH, L80~fDTIGI, R3 (0.125" s 2.5" slots, 32 per foot, 5.9°~0 open area) 1~J-~S~ L~ `'~ 152 Ll "B" Sand Window ~_. 5,518' MD ~ 3,502' TVD 80 de`uees "B"Liner, d-U2", 12.8#, L8Q, LBTM, R3 (0.125" x 2.5" slots, 32 per toot, S.9 % open area) 7.5/8", dOti, L-8Q, BTCM, R3 C'sg C 6,353' MD i 3,530' TVD C~. 85 degrees TD 9.7/8" hole A2 Sand Liner, d-1/2", 12.Ra, L80, LBTM, R3 ! z stoned a,td 4i blmilc, constrictors jot irolnrron 6-314" D scud lateral TD 12,940' MD / 3,347 T VD Angle 91:L4 degrees I1-152 L1: 6-3/d" "B" sand lateral TD 13,245' MD / 3,423' ThD Angle 91.01 degrees IJ-152: 6-3/d A2 sand lateral TD 9,888' MD ! 3,632' TVD Angle 90.97 degrees • r] • TRANSMITTAL LETTER CHECKLIST WELL NAME ~~C.~ ~ '~ '_ /S Z ~ ~., ~J 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 ,~ir_LC / ~ /S Z (If last two digits in permit No. ZLIa'`n~C, API No. 50- ~~ - Z?>~-`i~' - API number are between 60-69) Production should continue to be reported as a function of the original API number stated above. PILOT HOLE In accordance with 20 AAC 25.005(f), all records, data and logs acquired for the pilot hole must be clearly differentiated in both well name ( PH) and API number (50- - -) from records, data and logs acquired for well SPACING The permit is approved subject to full compliance with 20 AAC EXCEPTION 25.055. Approval to perforate and produce /inject is contingent upon issuance of a conservation order approving a spacing exception. assumes the liability of any protest to the spacing exception that may occur. DRY DITCH All dry ditch sample sets submitted to the Commission must be in SAMPLE no greater than 30' sample intervals from beiow the permafrost or from where samples are first caught and 10' sample intervals through target zones. Please note the following special condition of this permit: Non-Conventional production or production testing of coal bed methane is not allowed Well for (name of well) until after (Company NameZhas designed and implemented a water well testing program to provide baseline data on water quality and quantity. (Company NameZmust contact the Commission to obtain advance approval of such water well testing ro ram. Rev: 1/25/06 C:\j ody\transmittal_checklist ~ r 0^ 0 ~ N ;i ~ 0 0 m p- c fp N o ~o ~ ~ ~ = ~ c ,I ° o c c - , ~ c a, °, 3 m, ~, °` N , ~ o ~ ~ ~ ~ ~ ~ ~ ~ ~ ; ~ ~ c ; ~ ; , °~ ~ ~ ~ ; ~ ~~ aoi U o w ~ c O N ~ ~ m' a; v ~ ~ ~ o ~ ~ ~ ~ o a. . a ~ ~ ~ ~ ~ o' M. ~' a. ; 'c Q . ^ . - o ~ o. H, ~ N ~ a ~ ~ y. o. a o. rte, , ~ o E O O. Q. ~ T N, ~ ~ ~ ~ c` ~ ~ ~ ~ ~ ~ 4 ~ O, 4 O ~ ~ O ~ C U a QQ m ;~ ~, a. 3. m o, 3 0 o N ~ Z ~ o n ~ ~ 3 ~~ ~ ° ~ ~ c' ~, c c o c4 d `~ •~, Q. w •3, ~ t N a N Ok O O ~ O ~ 3, ~ ~ ~ p~ ~, ~ ~ ~ ~~ ~ C: ~ ~ ~~ , ~ , ~ N O ~~ ~~ Q. 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Q Q o, Q. a~, Q; a~, Q. a~, a~ a~: a~, m. o, Q; a~, a~, Q; Q; Q; j a z, }, }, r, r, r, }, ~- }, r, ~-, ~-, r z, z, z, z z, z z z z, z, r, z, }, z ~- r, ~- >-• ~, z, z, ~-, r, z z, z T , , , , , , , c ° I ~ ~_ . N. E. _ N. 3. ~ ~ ~ , , - ~ o, ,~ , , ~, ~, • j , : , c_' Z: ° , ~, '~ p •o O ; ~ ~, o o, Z ~, o ~, a. -o. a~ ~ ~, , Y ` d In . ~, ~ ~, ah ° ~ c~ a ~ o, o. w, ~ N• 4 .O~ a. O. a` N~ 0~ ~ C. a~ ~ p, ~ ~ V• ~ • ~ N• f6• N ~ 'C' Q , ~ y ~ v. ~ a' a~, ~ o, ~ c ~ a, N, w. w., a~ ~ o M +" 3 ; i O ~ ~~ .O N a0 y, U• ~ N ~ N' 3 W , O > C O, , D: ~ ~ a. N. N ~ U _ s. ~ ` ~, ~ N • m 3 3, o N ~ ~ _, rn s°O ~; c, N: ~, v o, uM•>, ~: Q N' y' m' N m .. Z ~ o c. .o v ' ' ~: ° c. • a ~ , a~, m. g .n. ~ o, , c, ° m. ' > , o. o, o rn m m. t, ~ ~' c, ° ~ ~ c o , N ~ Q c E . E . '~ a, c; ~ ~ ~ m. o ~ c ~ N, ~ ~ ~ ~ a~ i ~ ~; a~ i a a : , ~ o ~~ Q i o o -a ° ~ ~ a o v. a o, m N o ~~ o, 3, o o, rn ° ~j ., '~ an d a. ~ a~ c, O o. ~ d, ~ •3, o o ~, N ,~ ° T •~ 'N • Y Q w?: N °, ~ ~ ~ m, a N { ° ~ L. t, ~ ~ ~ ° u?, a ~ -°, m N ~ ° o p °, N w m: M ~ ._ o, N L rn o w a O a 3 o _ O. -- ~ 3, m ~ U , , . c, y ° ~, ~+, pi ~ 3, 3; a m p, ~ ~, . . , .. ° , N~ ~ a_ '~, , ~~ 3 m , ~, , o °. ~ ~ o v N. N• pr ~ ~' 0 3, ~ f6 ° o W O U o d °. o ~ -p a, ~ ~ o m a~ n ~, ~ o _ m. E a o > o o. o a v ~ o o' o, N ~°' E' a °' E' ~ `6' °> o m o a ~' Z °' c d J ~~ d ; a' N' N' .O~ U, O: 3, >~ fl. C U~ U' fl: O p Y' a' O ~ N' (6' O O' V} ~_, T C' O' O, d ~ = U. ~ ~: O O O OS N .~ 4 N, N, ~ .~..~ ~; '~~~ O, . -~ ~ 0- f6 . -~ fd (6. O O O O ~~ ~ T 'C U 3, _, a .N, O N O: 4 v a m ~ ~: ~ a fl. ~, 3 y, ~6, a> 3 c, :p, rn ~ ~? o* ar a`~ c Y; ~; ~; 'S ° ~, ~6 0, ~ o j °, m >, " ~ ii U °, ~, ~, w a~, ~ m: -a o s, c c . °, ~ m ~ ~, ~ N , 3, :a o, N ~, o °~ m: c: m: c o, m, ~" Z ~°>-' 'c 3. m v c~' c' d o o ~ ~ ~ ~, N; ~, ~ o, °, _ ~, ~ = •- ~: -a. ~ ~ a a ~, % c. ~? ~, ~, ° ° ~ _, ~ ~ o, a o, a ° ~ o o _, ~ o, o, ~, ~, ~ ~ 3 rn ~ ~, a ~ 3. v N ~ a a ~' O J ~ E; ~; v -' - -' ~ a ~ `n ~ ~ c -~ 3, o: ~~ ~; '`0 c F- I- '~ s `~ ~ ~ ~ d; o, '~ ~ a cLi ~ ° ~' m c, m Y T a~ o, • c: °~~ °~ °~ ° ~ ' ' a i a 4 4 , a~ , a~ m °~' - ' ~' U, . t, o, ° ~ , ~ ~, ~ i, a a, a i, ca a, ~ ~- - O. O, s. ° ' ~ a~ ~ , a~ a~ o, D ~~ U c a, ~, ~: ~; ~ , U, "_; ~ O, O: a; a; U ~ ¢, o... Q, U, v>, U, U, U, U, Q, - Q, _ _, D; m, m, U, ~ , ~'; ~, d, °, U, m, U, ~ W ~ . V D ~ N M '7 ~ CO h 00 O W N ~ M V ~ ~ M O Q) O N N M N N N cr N ~ Cfl N N h OD N N O O N N M M M M I M M ~l') (o M M f~ a0 M M O M U o o o ~ ~ f _ ~ N ~ N ~ N . U O W O ~ ' ~ M ~ 0 O._ w O a 6 ~ ~ M ~ M ~ _ l N g H d ~ ~ ~ ~ C ~ U~ a ¢ a Q m o a Q w -- ~ Qa .. t ,%~ J ~ ,,. • Well History File APPENDIX Information of detailed nature that is not particularly germane io the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify rending information, information of this nature is accumulated at the end of tl~e file under APPENDIX. No special effort has been made to chronologically . organize this category of information. Sperry-Sun Ding Services LIS Scan Utility ~~~o-Ol,r~ ~f ~~ $Revision: 3 $ LisLib $Revision: 4 $ Wed Jun 21 14:28:29 2006 Reel Header Service name .............LISTPE Date .....................06/06/21 Origin ...................STS Reel Name ................UNKNOWN Continuation Number......01 Previous Reel Name.......UNKNOWN Comments .................STS LIS Writing Library. Scientific Technical Services Tape Header Service name .............LISTPE Date .....................06/06/21 Origin ...................STS Tape Name ................UNKNOWN Continuation Number......01 Previous Tape Name.......UNKNOWN Comments .................STS LIS Writing Library. Scientific Technical Services Physical EOF Comment Record TAPE HEADER West Sak MWD/MAD LOGS WELL NAME: 1J-152 L2 API, NUMBER: 500292329861 OPERATOR: ConocoPhillips Alaska, Inc. LOGGING COMPANY: Sperry Drilling Services TAPE CREATION DATE: 21-JUN-06 JOB DATA MWD RUN 3 MWD RUN 11 MWD RUN 12 JOB NUMBER: W- 0004263658 W-0004263658 W-0004263658 LOGGING ENGINEER: T. GALVIN P. ORTH T. GALVIN OPERATOR WITNESS: D. GLADDEN D. GLADDEN D. GLADDEN MWD RUN 13 MWD RUN 14 JOB NUMBER: W- 0004263658 W-0004263658 LOGGING ENGINEER: T. GALVIN T. GALVIN OPERATOR WITNESS: D. GLADDEN D. GLADDEN SURFACE LOCATION SECTION: 35 TOWNSHIP: 11N RANGE: l0E FNL: FSL: 2191 FEL: 2582 FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: 109.00 GROUND LEVEL: 81.00 WELL CASING RECORD OPEN HOLE CASING DRILLERS ~ BIT S (IN) SIZE (IN) DEPTH (FT) 1ST STRING 9.875 10.750 2774.0 2ND STRING 6.750 7.875 5403.0 3RD STRING PRODUCTION STRING REMARKS: 1. ALL DEPTHS ARE MEASURED DEPTHS UNLESS OTHERWISE NOTED. THESE DEPTHS ARE BIT DEPTHS. 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTHS (TVD). 3. THIS WELL IS AN OPEN-HOLE SIDETRACK EXITING THE 1J-152 L2 PB1 WELLBORE AT 5445'MD/3453'TVD. 4. MWD RUNS 1 & 2 WERE DIRECTIONAL ONLY - NO DATA ARE PRESENTED. 5. MWD RUNS 3,12-14 COMPRISED DIRECTIONAL, DUAL GAMMA RAY (DGR) UTILIZING GEIGER-MUELLER TUBE DETECTORS, ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4), AND PRESSURE WHILE DRILLING (PWD) MWD RUNS 12-14 ALSO INCLUDED AT-BIT INCLINATION (ABI) MWD RUNS 12,14 ADDITIONALLY INCLUDED GEOPILOT 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 1-3,11-14 REPRESENT WELL 1J-152 L2 WITH API#: 50-029-23298-61. THIS WELL REACHED A TOTAL DEPTH (TD) OF 13112'MD/3358'TVD. SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRC = SMOOTHED GAMMA RAY COMBINED. SEXP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (EXTRA SHALLOW SPACING). SESP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (SHALLOW SPACING). SEMP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (MEDIUM SPACING). SEDP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (DEEP SPACING). SFXE = SMOOTHED FORMATION EXPOSURE TIME (DEEP SPACING). 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.......06/06/21 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. 0 DEPTH INCREMENT: .500 FILE SUMMARY PBU TOOL CODE START DEPTH STOP DEPTH GR 2741.5 13055.0 FET 2760.0 13062.0 RPD 2760.0 13062.0 RPM. 2760.0 13062.0 RPX 2760.0 13062.0 RPS 2760.0 13062.0 ROP 2787.5 13112.0 BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH MERGED DATA SOURCE PBU TOOL CODE MWD MWD MWD MWD MWD BIT RUN NO MERGE TOP 3 2741.5 11 5403.5 12 5442.0 13 5445.5 14 7572.0 REMARKS: MERGED MAIN PASS. MERGE BASE 5403.0 5442.0 5445.0 7572.0 13112.5 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 2741.5 13112 7926.75 20742 2741.5 13112 RPD MWD OHMM 1.71 2000 54.9519 20605 2760 13062 RPM MWD OHMM 2.2 2000 57.7136 20605 2760 13062 RPS MWD OHMM 2.5 2000 58.1791 20605 2760 13062 RPX MWD OHMM 3.05 2000 90.0884 20605 2760 13062 FET MWD HOUR 0.12 5 11.09 1.22463 20605 2760 13062 GR MWD API 26.27 125.3 68.612 20628 2741.5 13055 ROP MWD FT/H 0.14 970.9 174.209 20650 2787.5 13112 First Reading For Entire File..........2741.5 Last Reading For Entire Fi1~.........13112 File Trailer Service name .............STSLIB.001 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/06/21 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.002 Physical EOF File Header Service name .............STSLIB.002 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/06/21 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 BIT RUN NUMBER: 3 DEPTH INCREMENT: .5000 FILE SUMMARY • for each bit run in separate files. VENDOR TOOL CODE START DEPTH STOP DEPTH GR 2741.5 5403.0 RPX 2760.0 5403.0 RPM 2760.0 5403.0 RPD 2760.0 5403.0 RPS 2760.0 5403.0 FET 2760.0 5403.0 ROP 2787.5 5403.0 LO G HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): 23-MAR-06 Insite 66.37 Memory 5403.0 2787.0 5403.0 53.5 84.9 TOOL NUMBER 119546 105242 9.875 2774.0 BOREHOLE CONDITIONS MUD TYPE: Other MUD DENSITY (LB/G) 9.00 MUD VISCOSITY (S): 60.0 MUD PH: 9.9 MUD CHLORIDES (PPM): 300 FLUID LOSS (C3) 4.8 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT) 2.800 65.0 MUD AT MAX CIRCULATING TERMPERATURE: 1.880 100.0 MUD FILTRATE AT MT: 2.350 65.0 MUD CAKE AT MT: 2.700 65.0 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 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 2741.5 5403 4072.25 5324 2741.5 5403 RPD MWD030 OHMM 1.71 2000 21.1294 5287 2760 5403 RPM MWD030 OHMM 2.2 1597.77 13.7199 5287 2760 5403 RPS MWD030 OHMM 2.5 1922.05 13.0304 5287 2760 5403 RPX MWD030 OHMM 3.05 1353.33 11.8987 5287 2760 5403 FET MWD030 HOUR 0.12 68.15 1.53472 5287 2760 5403 GR MWD030 API 26.27 125.3 67.8778 5324 2741.5 5403 ROP MWD030 FT/H 0.14 653.26 145.852 5232 2787.5 5403 First Reading For Entire File..........2741.5 Last Reading For Entire File...........5403 File Trailer Service name .............STSLIB.002 Service Sub Level Name... Version Number...........1.0.0 Date of Generation....../06/21 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.003 Physical EOF File Header Service name .............STSLIB.003 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/06/21 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: 11 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH ROP 5403.5 5442.0 LOG HEADER DATA DATE LOGGED: 10-APR-06 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 66.37 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT) 5442.0 TOP LOG INTERVAL (FT) 5403.0 BOTTOM LOG INTERVAL (FT) 5442.0 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) 5403.0 BOREHOLE CONDITIONS MUD TYPE: Mineral Oil Base MUD DENSITY (LB/G): 8.80 MUD VISCOSITY (S) 69.0 MUD PH: .0 MUD CHLORIDES (PPM): 111000 FLUID LOSS (C3) 2.0 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT) .000 .0 MUD AT MAX CIRCULATING TERMPERATURE: .000 71.6 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 .1IN 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 MWD110 FT/H 4 1 68 4 2 C First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 5403.5 5442 5422.75 78 5403.5 5442 ROP MWD110 FT/H 1.36 46.78 16.7224 78 5403.5 5442 First Reading For Entire File..........5403.5 Last Reading For Entire File...........5442 File Trailer Service name .............STSLIB.003 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/06/21 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.......06/06/21 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: 12 DEPTH INCREMENT: .5000 FILE SUMMARY ~ VENDOR TOOL CODE START TH STOP DEPTH RPD 5403.5 5445.0 GR 5403.5 5445.0 RPX 5403.5 5445.0 RPM 5403.5 5445.0 RPS 5403.5 5445.0 FET 5403.5 5445.0 ROP 5442.5 5445.0 LO G HEADER DATA DATE LOGGED: 12-APR-06 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 66.37 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT) 5445.0 TOP LOG INTERVAL (FT) 5442.0 BOTTOM LOG INTERVAL (FT) 5445.0 $IT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 86.1 MAXIMUM ANGLE: 94.5 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 178505 EWR4 Electromag Resis. 4 159439 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) 6.750 DRILLER'S CASING DEPTH (FT) 5403.0 BOREHOLE CONDITIONS MUD TYPE: Mineral Oil Base MUD DENSITY (LB/G) 8.80 MUD VISCOSITY (S) 79.0 MUD PH: .0 MUD CHLORIDES (PPM): 24500 FLUID LOSS (C3): 3.4 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT) .000 .0 MUD AT MAX CIRCULATING TERMPERATURE: .000 89.6 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 Bloc~ub-type...0 • Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 RPD MWD120 OHMM 4 1 68 4 2 RPM MWD120 OHMM 4 1 68 8 3 RPS MWD120 OHMM 4 1 68 12 4 RPX MWD120 OHMM 4 1 68 16 5 FET MWD120 HOUR 4 1 68 20 6 GR MWD120 API 4 1 68 24 7 ROP MWD120 FT/H 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 5403.5 5445 5424.25 84 5403.5 5445 RPD MWD120 OHMM 3.81 20 13.2518 84 5403.5 5445 RPM MWD120 OHMM 6.89 16.63 13.7086 84 5403.5 5445 RPS MWD120 OHMM 10.04 31.14 15.0004 84 5403.5 5445 RPX MWD120 OHMM 8.26 1713.08 79.0039 84 5403.5 5445 FET MWD120 HOUR 0.65 511.09 68.1796 84 5403.5 5445 GR MWD120 API 62.47 93.36 75.5351 84 5403.5 5445 ROP MWD120 FT/H 19.82 52.95 36.1567 6 5442.5 5445 First Reading For Entire File..........5403.5 Last Reading For Entire File...........5445 File Trailer Service name .............STSLIB.004 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/06/21 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.......06/06/21 Maximum Physical Record..65535 File Type ................LO Previous File Name.......STSLIB.004 Comment Record FILE HEADER FILE NUMBER: 5 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 13 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH ROP 5445.5 7572.0 GR 5445.5 7512.0 FET 5445.5 7518.5 RPX 5445.5 7518.5 RPS 5445.5 7518.5 RPM 5445.5 7518.5 RPD 5445 LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: 7518.5 14-APR-06 Insite 66.37 Memory 7572.0 5445.0 7572.0 76.2 93.1 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 Electromag Resis. 4 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3) RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format Specification Record Data Record Type ..................0 Data Specification Block Type.....0 Logging Direction .................Down Optical log depth units...........Feet Data Reference Point ..............Undefined Frame Spacing .....................60 .lIN Max frames per record .............Undefined Absent value ......................-999 Depth Units ....................... Datum Specification Block sub-type...0 TOOL NUMBER 178505 159439 6.750 5403.0 Mineral Oil Base 8.80 66.0 .0 23500 3.0 000 .0 000 115.0 000 .0 000 .0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 RPD MWD130 OHMM 4 1 68 4 2 RPM MWD130 OHMM 4 1 68 8 3 RPS MWD130 OHMM 4 1 68 12 4 ~ RPX MWD130 OHMM 4 1 68 16 5 FET MWD130 HOUR 4 1 68 20 6 GR MWD130 API 4 1 68 24 7 ROP MWD130 FT/H 4 1 68 28 8 Fi rst Last Name Service Unit Min Max Mean Nsam Re ading Reading DEPT FT 5445.5 7572 6508.75 4254 5445.5 7572 RPD MWD130 OHMM 9.62 124.28 51.9903 4147 5445.5 7518.5 RPM MWD130 OHMM 9.31 123.38 53.7632 4147 5445.5 7518.5 RPS MWD130 OHMM 8.98 126.3 50.3004 4147 5445.5 7518.5 RPX MWD130 OHMM 9.07 1829.84 59.1018 4147 5445.5 7518.5 FET MWD130 HOUR 0.2 23.19 0.636069 4147 5445.5 7518.5 GR MWD130 API 48.72 123.7 72.8097 4134 5445.5 7512 ROP MWD130 FT/H 0.58 360.52 198.604 4254 5445.5 7572 First Reading For Entire File..........5445.5 Last Reading For Entire File...........7572 File Trailer Service name .............STSLIB.005 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/06/21 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.006 Physical EOF File Header Service name .............STSLIB.006 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/06/21 Maximum Physical Record..65535 File Type ................LO Previous. File Name.......STSLIB.005 Comment Record FILE HEADER FILE NUMBER: 6 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 14 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 7512.5 13055.0 RPX 7519.0 13062.0 RPD 7519.0 13062.0 FET 7519.0 13062.0 RPM 7519.0 13062.0 RPS 7519.0 13062.0 ROP 7572.5 13112.5 LOG HEADER DATA DATE LOGGED: 19-APR-06 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VE~N: 66.37 • DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT) 13112.0 TOP LOG INTERVAL (FT) 7572.0 BOTTOM LOG INTERVAL (FT) 13112.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 87.2 MAXIMUM ANGLE: 93.6 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 178505 EWR4 Electromag Resis. 4 159439 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) 6.750 DRILLER'S CASING DEPTH (FT) 5403.0 BOREHOLE CONDITIONS MUD TYPE: Mineral Oil Base MUD DENSITY (LB/G): 8.80 MUD VISCOSITY (S): 72.0 MUD PH: .0 MUD CHLORIDES (PPM): 19500 FLUID LOSS (C3) 2.6 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT) .000 .0 MUD AT MAX CIRCULATING TERMPERATURE: .000 115.0 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 .1IN 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 MWD140 OHMM 4 1 68 4 2 RPM MWD140 OHMM 4 1 68 8 3 RPS MWD140 OHMM 4 1 68 12 4 RPX MWD140 OHMM 4 1 68 16 5 FET MWD140 HOUR 4 1 68 20 6 GR MWD140 API 4 1 68 24 7 ROP MWD140 FT/H 4 1 68 28 8 ~rst Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 7512.5 13112.5 10312.5 11201 7512.5 13112.5 RPD MWD140 OHMM 18.71 2000 72.5043 11087 7519 13062 RPM MWD140 OHMM 18.77 2000 80.5037 11087 7519 13062 RPS MWD140 OHMM 18 2000 82.983 11087 7519 13062 RPX MWD140 OHMM 17.89 2000 139.049 11087 7519 13062 FET MWD140 HOUR 0.2 16.68 0.789632 11087 7519 13062 GR MWD140 API 32.02 102.93 67.3468 11086 7512.5 13055 ROP MWD140 FT/H 0.4 970.9 179.402 11081 7572.5 13112.5 First Reading For Entire File..........7512.5 Last Reading For Entire File...........13112.5 File Trailer Service name .............STSLIB.006 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/06/21 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.007 Physical EOF Tape Trailer Service name .............LISTPE Date .....................06/06/21 Origin ...................STS Tape Name ................UNKNOWN Continuation Number......01 Next Tape Name...........UNKNOWN Comments .................STS LIS Writing Library. Reel Trailer Service name .............LISTPE Date .....................06/06/21 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 ,. Sperry-Sun Drl~liing Services • LIS Scan Utility $Revision: 3 $ ~~~~~~ ~ ~`' ~ ~ ~ LisLib $Revision: 4 $ Wed Jun 21 15:36:32 2006 Reel Header Service name .............LISTPE Date .....................06/06/21 Origin ...................STS Reel Name ................UNKNOWN Continuation Number......01 Previous Reel Name.......UNKNOWN Comments .................STS LIS Writing Library. Scientific Technical Services Tape Header Service name .............LISTPE Date ........ ............06/06/21 Origin ...................STS Tape Name ................UNKNOWN Continuation Number......01 Previous Tape Name.......UNKNOWN Comments .................STS LIS Writing Library. Scientific Technical Services Physical EOF Comment Record TAPE HEADER West Sak MWD/MAD LOGS WELL NAME: 1J-152 L2 PB1 API NUMBER: 500292329872 OPERATOR: ConocoPhillips Alaska, Inc. LOGGING COMPANY: Sperry Drilling Services TAPE CREATION DATE: 21-JUN-06 JOB DATA MWD RUN 3 MWD RUN 11 MWD RUN 12 JOB NUMBER: W-0004263658 W-0004263658 W-0004263658 LOGGING ENGINEER: T. GALVIN P. ORTH T. GALVIN OPERATOR WITNESS: D. GLADDEN D. GLADDEN D. GLADDEN SURFACE LOCATION SECTION: 35 TOWNSHIP: 11N RANGE: l0E FNL: FSL: 2191 FEL: 2582 FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: 109.00 GROUND LEVEL: 81.00 WELL CASING RECORD OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 1ST STRING 9.875 10.750 2774.0 2ND STRING 6.750 7.875 5403.0 3RD STRING PRODUCTION STRING REMARKS: ~ • 1. ALL DEPTHS ARE MEASURED DEPTHS UNLESS OTHERWISE NOTED. THESE DEPTHS ARE BIT DEPTHS. 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTHS (TVD). 3. THIS WELLBORE WAS EFFECTED BY MEANS OF A WHIPSTOCK, THE TOP OF WHICH WAS POSITIONED AT 5403'MD/3443'TVD WITHIN THE RUN 3 INTERVAL OF THE 1J-152 PB1 WELLBORE. 4. MWD RUNS 1 & 2 WERE DIRECTIONAL ONLY - NO DATA ARE PRESENTED. 5. MWD RUNS 3,12 COMPRISED DIRECTIONAL, DUAL GAMMA RAY (DGR) UTILIZING GEIGER-MUELLER TUBE DETECTORS, ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4), AND PRESSURE WHILE DRILLING (PWD) MWD RUN 12 ALSO INCLUDED AT-BIT INCLINATION (ABI) AND GEOPILOT ROTARY STEERABLE BHA (GP) THE WHIPSTOCK WAS POSITIONED, THE WINDOW MILLED, AND 27' OF NEW HOLE WERE DRILLED.. DURING MWD RUN 11. ONLY SROP DATA ARE PRESENTED FOR RUN 11. MWD DATA OVER THE RUN 11 INTERVAL WERE ACQUIRED WHILE RIH FOR RUN 12. 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 1-3,11,12 REPRESENT WELL 1J-152 L2 PB1 WITH API#: 50-029-23298 -72. THIS WELL REACHED A TOTAL DEPTH (TD) OF 6024'MD/3461'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.......06/06/21 Maximum Physical Record..65535 File Type ................LO Previous File Name.......STSLIB.000 Comment Record FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted DEPTH INCREMENT: FILE SUMMARY PBU TOOL CODE GR FET RPD RPS RPM RPX ROP and clippe~urves; .5000 START DEPTH 2741.5 2760.0 2760.0 2760.0 2760.0 2760.0 2787.5 all bit runs merged. STOP DEPTH 5967.0 5974.0 5974.0 5974.0 5974.0 5974.0 6024.0 ~~ BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH MERGED DATA SOURCE PBU TOOL CODE BIT RUN NO MERGE TOP MERGE BASE MWD 3 2741.5 5403.0 MWD 11 5403.5 5442.0 MWD 12 5442.0 6024.0 REMARKS: MERGED MAIN PASS. Data Format Specification Record Data Record Type ..................0 Data Specification Block Type.....0 Logging Direction .................Down Optical log depth units...........Feet Data Reference Point ..............Undefined Frame Spacing .....................60 .lIN Max frames per record .............Undefined Absent value ......................-999 Depth Units ....................... Datum Specification Block sub-type...0 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 2741.5 6024 4382.75 6566 2741.5 6024 RPD MWD OHMM 1.71 2000 24.325 6429 2760 5974 RPM MWD OHMM 2.2 1597.77 18.3789 6429 2760 5974 RPS MWD OHMM 2.5 1922.05 17.5188 6429 2760 5974 RPX MWD OHMM 3.05 1713.08 18.2608 6429 2760 5974 FET MWD HOUR 0.12 511.09 2.33355 6429 2760 5974 GR MWD API 26.27 125.3 68.7458 6452 2741.5 5967 ROP MWD FT/H 0.14 653.26 145.141 6474 2787.5 6024 First Reading For Entire File..........2741.5 Last Reading For Entire File...........6024 • • File Trailer Service name .............STSLIB.001 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/06/21 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.002 Physical EOF File Header Service name .............STSLIB.002 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/06/21 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: 3 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 2741.5 5403.0 FET 2760.0 5403.0 RPX 2760.0 5403.0 RPS 2760.0 5403.0 RPM 2760.0 5403.0 RPD 2760.0 5403.0 ROP 2787.5 5403.0 LOG HEADER DATA DATE LOGGED: 23-MAR-06 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 66.37 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT) 5403.0 TOP LOG INTERVAL (FT) 2787.0 BOTTOM LOG INTERVAL (FT) 5403.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 53.5 MAXIMUM ANGLE: 84.9 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 119546 EWR4 ELECTROMAG. RESIS. 4 105242 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) 9.875 DRILLER'S CASING DEPTH (FT) 2774.0 BOREHOLE CONDITIONS MUD .TYPE: ~ Other • MUD DENSITY (LB/G): 9.00 MUD VISCOSITY (S) 60.0 MUD PH: 9.9 MUD CHLORIDES (PPM): 300 FLUID LOSS (C3) 4.8 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT) 2.800 65.0 MUD AT MAX CIRCULATING TERMPERATURE: 1.880 100.0 MUD FILTRATE AT MT: 2.350 65.0 MUD CAKE AT MT: 2.700 65.0 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 .1IN 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 MWD30 OHMM 4 1 68 16 5 FET MWD030 HOUR 4 1 68 20 6 GR MWD30 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 2741.5 5403 4072.25 5324 2741.5 5403 RPD MWD030 OHMM 1.71 2000 21.1294 5287 2760 5403 RPM MWD030 OHMM 2.2 1597.77 13.7199 5287 2760 5403 RPS MWD030 OHMM 2.5 1922.05 13.0304 5287 2760 5403 RPX MWD30 OHMM 3.05 1353.33 11.8987 5287 2760 5403 FET MWD030 HOUR 0.12 68.15 1.53472 5287 2760 5403 GR MWD30 API 26.27 125.3 67.8778 5324 2741.5 5403 ROP MWD030 FT/H 0.14 653.26 145.852 5.232 2787.5 5403 First Reading For Entire File..........2741.5 Last Reading For Entire File...........5403 File Trailer Service name .............STSLIB.002 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/06/21 Maximum Physical Record~535 • File Type ................LO Next File Name...........STSLIB.003 Physical EOF File Header Service name .............STSLIB.003 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/06/21 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: 11 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH ROP 5403.5 5442.0 LOG HEADER DATA DATE LOGGED: 10-APR-06 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 66.37 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT) 5442.0 TOP LOG INTERVAL (FT) 5403.0 BOTTOM LOG INTERVAL (FT) 5442.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGT~E : . 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) 5403.0 BOREHOLE CONDITIONS MUD TYPE: Mineral Oil Base MUD DENSITY (LB/G) 8.80 MUD VISCOSITY (S) 69.0 MUD PH: .0 MUD CHLORIDES (PPM): 111000 FLUID LOSS (C3) 2.0 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT) .000 .0 MUD AT MAX CIRCULATING TERMPERATURE: .000 71.6 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 .1IN 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 MWD110 FT/H 4 1 68 4 2 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 5403.5 5442 5422.75 78 5403.5 5442 ROP MWD110 FT/H 1.36 46.78 16.7224 78 5403.5 5442 First Reading For Entire File..........5403.5 Last Reading For Entire File...........5442 File Trailer Service name .............STSLIB.003 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/06/21 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.......06/06/21 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: 12 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH RPX 5403 5974.0 RPD 5403.5 5974.0 RPM 5403.5 5974.0 GR 5403.5 5967.0 RPS 5403.5 5974.0 FET 5403.5 5974.0 ROP 5442.5 6024.0 LOG HEADER DATA DATE LOGGED: 12-APR-06 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 66.37 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT) 6024.0 TOP LOG INTERVAL (FT) 5442.0 BOTTOM LOG INTERVAL (FT) 6024.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 86.1 MAXIMUM ANGLE: 94.5 TOOL STRING (TOP TO BOTTOM) • VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 178505 EWR4 Electromag Resis. 4 159439 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 6.750 DRILLER'S CASING DEPTH (FT) 5403.0 BOREHOLE CONDITIONS MUD TYPE: Mineral Oil Base MUD DENSITY (LB/G) 8.80 MUD VISCOSITY (S) 79.0 MUD PH: .0 MUD CHLORIDES (PPM): 24500 FLUID LOSS (C3) 3.4 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT) .000 .0 MUD AT MAX CIRCULATING TERMPERATURE: .000 89.6 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 MWD120 OHMM 4 1 68 4 2 RPM MWD120 OHMM 4 1 68 8 3 RPS MWD120 OHMM 4 1 68 12 4 RPX MWD120 OHMM 4 1 68 16 5 FET MWD120 HOUR 4 1 68 20 6 GR MWD120 API 4 1 68 24 7 ROP MWD120 FT/H 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 5403.5 6024 5713.75 1242 5403.5 6024 RPD MWD120 OHMM 3.81 92.4 39.1197 1142 5403.5 5974 RPM MWD120 OHMM 6.89 104.87 39.9481 1142 5403.5 5974 RPS MWD120 OHMM 10.04 111.85 38.2983 1142 5403.5 5974 RPX MWD120 OHMM 8.26 1713.08 47.7152 1142 5403.5 5974 FET MWD120 HOUR 0.24 511.09 6.03179 1142 5403.5 5974 GR MWD120 API 52.38 95.68 72.8423 1128 5403.5 5967 ROP MWD120 FT/H 4.28 335.18 150.553 1164 5442.5 6024 First Reading For Entire File..........5403.5 Last Reading For Entire File...........6024 File Trailer Service name .............STSLIB.004 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/06/21 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.005 Physical EOF Tape Trailer Service name .............LISTPE Date .....................06/06/21 Origin ...................STS Tape Name ................UNKNOWN Continuation Number......01 Next Tape Name. .........UNKNOWN Comments .................STS LIS Writing Library. Reel Trailer Service name .............LISTPE Date .....................06/06/21 Origin ...................STS Reel Name ................UNKNOWN Continuation Number......01 Next Reel Name...........UNKNOWN Comments .................STS LIS Writing Library. Physical EOF Scientific Technical Services Scientific Technical Services Physical EOF • • End Of LIS File