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Home My WebLink About208-130C:\Users\grgluyas\AppData\Local\Microsoft\Windows\INetCache\Content.Outlook\R97USUAM\2024-07-29_15999_KRU_3K-108_CaliperSurvey_LogData_Transmittal.docx DELIVERABLE DISCRIPTION Ticket #Field Well # API #Log Description Log Date 15999 KRU 3K-108 50-029-23395-00 Caliper Survey w/ Log Data 29-Jul-24 DELIVERED TO Company & Address DIGITAL FILE # of Copies LOG PRINTS # of Prints CD’s # of Copies 1 AOGCC Attn: Natural Resources Technician 333 W. 7th Ave., Suite 100 Anchorage, Ak. 99501-3539 Delivered By: CPAI Sharefile ______________________________ _____________________________________ Date received Signature ______________________________ ______________________________________ PLEASE RETURN COPY VIA EMAIL TO: DIANE.WILLIAMS@READCASEDHOLE.COM READ CASED HOLE, INC., 4141 B STREET, SUITE 308, ANCHORAGE, AK 99503 PHONE: (907)245-8951 E-MAIL :READ-Anchorage@readcasedhole.com WEBSITE :WWW.READCASEDHOLE.COM C:\Users\grgluyas\AppData\Local\Microsoft\Windows\INetCache\Content.Outlook\R97USUAM\2024-07-02_15993_KRU_3K-108_CaliperSurvey_LogData_Transmittal.docx DELIVERABLE DISCRIPTION Ticket # Field Well # API # Log Description Log Date 15993 KRU 3K-108 50-029-23395-00 Caliper Survey w/ Log Data 02-Jul-24 DELIVERED TO Company & Address DIGITAL FILE # of Copies LOG PRINTS # of Prints CD’s # of Copies 1 AOGCC Attn: Natural Resources Technician 333 W. 7th Ave., Suite 100 Anchorage, Ak. 99501-3539 Delivered By: CPAI Sharefile ______________________________ _____________________________________ Date received Signature ______________________________ ______________________________________ PLEASE RETURN COPY VIA EMAIL TO: DIANE.WILLIAMS@READCASEDHOLE.COM READ CASED HOLE, INC., 4141 B STREET, SUITE 308, ANCHORAGE, AK 99503 PHONE: (907)245-8951 E-MAIL : READ-Anchorage@readcasedhole.com WEBSITE : WWW.READCASEDHOLE.COM 208-130 T39137 Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2024.07.09 14:58:41 -08'00' C:\Users\grgluyas\AppData\Local\Microsoft\Windows\INetCache\Content.Outlook\R97USUAM\2024-07-02_15992_KRU_3K-108_LeakPointSurvey_Transmittal.docx DELIVERABLE DISCRIPTION Ticket # Field Well # API # Log Description Log Date 15992 KRU 3K-108 50-029-23395-00 LeakPoint Survey 02-Jul-24 DELIVERED TO Company & Address DIGITAL FILE # of Copies LOG PRINTS # of Prints CD’s # of Copies 1 AOGCC Attn: Natural Resources Technician 333 W. 7th Ave., Suite 100 Anchorage, Ak. 99501-3539 Delivered By: CPAI Sharefile ______________________________ _____________________________________ Date received Signature ______________________________ ______________________________________ PLEASE RETURN COPY VIA EMAIL TO: DIANE.WILLIAMS@READCASEDHOLE.COM READ CASED HOLE, INC., 4141 B STREET, SUITE 308, ANCHORAGE, AK 99503 PHONE: (907)245-8951 E-MAIL : READ-Anchorage@readcasedhole.com WEBSITE : WWW.READCASEDHOLE.COM 208-130 T39134 Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2024.07.08 09:36:59 -08'00' CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Wallace, Chris D (OGC) To:AOGCC Records (CED sponsored) Subject:FW: KRU 3K-108 (PTD 208-130) report of suspect IA pressure fall off Date:Friday, December 8, 2023 11:33:12 AM Attachments:AnnComm Surveillance TIO for 3K-108.pdf From: Byrne, Jan <Jan.Byrne@conocophillips.com> Sent: Thursday, December 7, 2023 1:37 PM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Cc: Earhart, Will C <William.C.Earhart@conocophillips.com> Subject: KRU 3K-108 (PTD 208-130) report of suspect IA pressure fall off Chris, KRU 3K-108 (PTD 208-130) is displaying suspect IA pressure fall off. Operations has charged the IA pressure multiple times, but the IA pressure has slowly fallen off post charging. We plan to mobilize DHD to the well to perform an MITIA, charge the IA, and set up for a 30 day monitor. If the well fails the MITIA it will be shut in and freeze protected. Any required paperwork for continued injection or corrective action will be submitted once the path forward has been determined. A 90-day TIO trend and wellbore schematic are attached. Please let me know if you disagree or have any questions with this plan. Regards, Jan Byrne Well Integrity Specialist | ConocoPhillips Alaska O: (907) 265-6471 | M: (808) 345-6886 3K-108 90-Day Bleed History WELL DATE STR-PRES END-PRES DIF-PRES CASING 3K-108 2023-10-16 820 1275 455 IA 3K-108 2023-11-30 800 1300 500 IA 3K-108 2023-12-03 980 1390 410 IA 3K-108 2023-12-04 1288 1387 99 IA Casing Strings Casing Description CONDUCTOR String O... 20 String ID ... 19.124 Top (ftKB) 43.0 Set Depth (f... 120.0 Set Depth (TVD) ... 120.0 String Wt... 94.00 String ... H-40 String Top Thrd WELDED Casing Description SURFACE String O... 13 3/8 String ID ... 12.415 Top (ftKB) 42.7 Set Depth (f... 3,069.7 Set Depth (TVD) ... 2,223.3 String Wt... 68.00 String ... L-80 String Top Thrd BTC Casing Description INTERMEDIATE String O... 9 5/8 String ID ... 8.835 Top (ftKB) 39.9 Set Depth (f... 8,015.8 Set Depth (TVD) ... 3,576.9 String Wt... 40.00 String ... L-80 String Top Thrd BTC-m Casing Description D-SAND WINDOW String O... 9 5/8 String ID ... 8.000 Top (ftKB) 7,280.0 Set Depth (f... 7,297.0 Set Depth (TVD) ... 3,483.4 String Wt... 40.00 String ... L-80 String Top Thrd BTCM Casing Description Liner Seal Bore Diverter String O... 7 String ID ... 4.790 Top (ftKB) 7,272.9 Set Depth (f... 7,379.4 Set Depth (TVD) ... 3,501.0 String Wt... String ... String Top Thrd Liner Details Top (ftKB) Top Depth (TVD) (ftKB)Top Incl (°)Item Description Comment Nomi... ID (in) 7,272.9 3,477.0 76.49 DIVERTER Seal Bore Diverter-- length above collet profile f/ RAM Hanger 7.750 7,275.9 3,477.8 76.58 DIVERTER Seal Bore Diverter, --Length below collet profile, 4.790 7,343.2 3,494.1 78.62 ANCHOR MLHR Production Anchor (Above 120k Collet) 3.910 7,347.7 3,495.0 78.75 ANCHOR MLHR Production Anchor (Below 120k Collet) 3.910 7,363.8 3,498.2 79.24 SEAL ASSY Baker 192-47 Non-Locating Seal Assy. 3.870 7,376.8 3,500.5 79.64 SEAL ASSY Baker 192-47 Seal Assy. 3.870 Casing Description B-SAND LINER String O... 3 1/2 String ID ... 2.930 Top (ftKB) 7,334.4 Set Depth (f... 13,150.4 Set Depth (TVD) ... 3,682.5 String Wt... 9.20 String ... L-80 String Top Thrd SLHT Liner Details Top (ftKB) Top Depth (TVD) (ftKB)Top Incl (°)Item Description Comment Nomi... ID (in) 7,334.4 3,492.3 78.35 PACKER Baker MLZXP liner Hanger Packer- above collet profile 6.520 7,347.0 3,494.9 78.73 PACKER Baker MLZXP liner Hanger Packer- below collet OD 8.42"/ID 6.184" 6.184 7,355.7 3,496.6 79.00 HANGER Baker Flex-Lock Hanger 7"x 9-5/8"/8.29" ODx6.18" ID 6.180 7,362.4 3,497.9 79.20 SBR 190-47 CSG Sealbore receptacle 4.750 13,149.1 3,682.4 86.92 WLEG Baker Guide shoe 4.25" OD Tubing Strings Tubing Description B-SAND TUBING String O... 3 1/2 String ID ... 2.992 Top (ftKB) 37.0 Set Depth (f... 7,302.4 Set Depth (TVD) ... 3,484.8 String Wt... 9.20 String ... L-80 String Top Thrd IBTM Completion Details Top (ftKB) Top Depth (TVD) (ftKB)Top Incl (°)Item Description Comment Nomi... ID (in) 37.0 37.0 -0.04 HANGER Vetco Gray Dual 13-3/8" x 3-1/2" x 3-1/2" 3.500 540.0 539.5 5.77 NIPPLE 3-1/2" Camco "DS" Nipple w/ 2.875" Profile 2.875 7,200.7 3,470.3 81.07 PACKER Baker "GT" Retrievable Dual Packer (40K Shear Release) 7,226.5 3,474.5 80.79 NIPPLE 3-1/2" Camco "DS" Nipple w/ 2.812" No-Go Profile (EUE 8rd B x P) 2.812 7,270.1 3,481.5 80.32 SEAL Baker 7" x 9-5/8" "Ram" Dual Seal Module (Above Collet) 2.700 7,296.6 3,483.3 77.20 SEAL Baker 7" x 9-5/8" "Ram" Dual Seal Module (Below Collet) 2.700 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top Depth (TVD) (ftKB) Top Incl (°)Description Comment Run Date ID (in) 8,050.0 3,576.6 89.47 SWELL PKR SWELL PACKER (WATER ACTIVATED) 12/1/2008 3.500 8,492.0 3,589.9 89.60 SWELL PKR SWELL PACKER (WATER ACTIVATED) 12/1/2008 3.500 8,967.0 3,593.6 88.70 SWELL PKR SWELL PACKER (WATER ACTIVATED) 12/1/2008 3.500 9,450.0 3,604.8 88.77 SWELL PKR SWELL PACKER (WATER ACTIVATED) 12/1/2008 3.500 9,987.0 3,601.7 90.17 SWELL PKR SWELL PACKER (WATER ACTIVATED) 12/1/2008 3.500 10,491.0 3,612.8 89.66 SWELL PKR SWELL PACKER (WATER ACTIVATED) 12/1/2008 3.500 10,994.0 3,615.4 89.23 SWELL PKR SWELL PACKER (WATER ACTIVATED) 12/1/2008 3.500 11,450.0 3,627.5 84.79 SWELL PKR SWELL PACKER (WATER ACTIVATED) 12/1/2008 3.500 12,080.0 3,641.3 88.58 SWELL PKR SWELL PACKER (WATER ACTIVATED) 12/1/2008 3.500 12,570.0 3,658.8 86.09 SWELL PKR SWELL PACKER (WATER ACTIVATED) 12/1/2008 3.500 12,860.0 3,678.2 92.04 SWELL PKR SWELL PACKER (WATER ACTIVATED) 12/1/2008 3.500 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB)Zone Date Shot Dens (sh...Type Comment 8,207.6 8,239.0 3,580.4 3,583.9 WS B, 3K-108 12/1/2008 99.0 SLOTS Resinject Reslink Screen 8,653.6 8,685.0 3,589.6 3,589.7 WS B, 3K-108 12/1/2008 99.0 SLOTS Resinject Reslink Screen 9,253.4 9,284.8 3,598.7 3,599.9 WS B, 3K-108 12/1/2008 99.0 SLOTS Resinject Reslink Screen 9,733.3 9,764.7 3,604.1 3,603.5 WS B, 3K-108 12/1/2008 99.0 SLOTS Resinject Reslink Screen 10,266.5 10,297.9 3,603.5 3,606.2 WS B, 3K-108 12/1/2008 99.0 SLOTS Resinject Reslink Screen 10,742.6 10,774.0 3,613.6 3,614.1 WS B, 3K-108 12/1/2008 99.0 SLOTS Resinject Reslink Screen 11,220.5 11,251.9 3,622.8 3,623.2 WS B, 3K-108 12/1/2008 99.0 SLOTS Resinject Reslink Screen 11,819.4 11,850.6 3,631.3 3,632.2 WS B, 3K-108 12/1/2008 99.0 SLOTS Resinject Reslink Screen 12,459.8 124.0 3,654.6 124.0 WS B, 3K-108 12/1/2008 99.0 SLOTS Resinject Reslink Screen 13,056.0 13,087.4 3,678.0 3,679.2 WS B, 3K-108 12/1/2008 99.0 SLOTS Resinject Reslink Screen Comment SSSV: NIPPLEWell Config: MULTIPLE LATERALS - 3K-108, 4/3/2012 10:27:33 AM Schematic - Actual TD (3K-108), 13,180 B-SAND LINER, 7,334-13,150 SLOTS, 13,056-13,087 SWELL PKR, 12,860 SWELL PKR, 12,570 SLOTS, 12,460 SWELL PKR, 12,080 SLOTS, 11,819-11,851 SWELL PKR, 11,450 SLOTS, 11,221-11,252 SWELL PKR, 10,994 SLOTS, 10,743-10,774 SWELL PKR, 10,491 SLOTS, 10,266-10,298 SWELL PKR, 9,987 SLOTS, 9,733-9,765 SWELL PKR, 9,450 SLOTS, 9,253-9,285 SWELL PKR, 8,967 SLOTS, 8,654-8,685 SWELL PKR, 8,492 SLOTS, 8,208-8,239 SWELL PKR, 8,050 NTERMEDIATE, 40-8,016 D-Sand Liner Tie-back/RAM, 7,268-7,382 Liner Seal Bore Diverter, 7,273-7,379 SEAL, 7,297 D-SAND WINDOW, 7,280-7,297 Dual Seal, 7,271 SEAL, 7,270 Dual Seal, 7,269 JOINT MANDREL, 7,265 NIPPLE, 7,231 NIPPLE, 7,226 PACKER, 7,205 PACKER, 7,201 PACKER, 7,201 PACKER, 7,200 SURFACE, 43-3,070 GAS LIFT, 2,518 SLEEVE, 2,513 NIPPLE, 540 NIPPLE, 539 CONDUCTOR, 43-120 HANGER, 37 HANGER, 37 Annotation Last Tag: Depth (ftKB) End Date Annotation Rev Reason: WELL REVIEW Last Mod By osborl End Date 4/3/2012 KUP KB-Grd (ft) 0.34 Rig Release Date 12/27/2008 Annotation Last WO: End Date 3K-108 H2S (ppm) Date Mandrel Details Stn Top (ftKB) Top Depth (TVD) (ftKB) Top Incl (°)Make Model OD (in)Serv Valve Type Latch Type Port Size (in) TRO Run (psi)Run Date Com... 1 2,518.0 2,041.2 69.33 CAMCO KBG-2-9 1 Gas Lift DMY DCK-3 0.000 0.0 12/22/2008 ... TD Act Btm (ftKB) 13,180.0 Well Attributes Wellbore API/UWI 500292339500 Field Name NE WEST SAK Well Status INJ Max Angle & MD Incl (°) 92.35 MD (ftKB) 11,589.63 Notes: General & Safety End Date Annotation 12/31/2008 NOTE: MULTI-LATERAL WELL w/DUAL TUBING STRINGS 12/31/2008 NOTE: View schematic w/Alaska Schematic9.0 Well Config: MULTIPLE LATERALS - 3K-108, 4/3/2012 10:27:33 AM Schematic - Actual TD (3K-108), 13,180 B-SAND LINER, 7,334-13,150 SLOTS, 13,056-13,087 SWELL PKR, 12,860 SWELL PKR, 12,570 SLOTS, 12,460 SWELL PKR, 12,080 SLOTS, 11,819-11,851 SWELL PKR, 11,450 SLOTS, 11,221-11,252 SWELL PKR, 10,994 SLOTS, 10,743-10,774 SWELL PKR, 10,491 SLOTS, 10,266-10,298 SWELL PKR, 9,987 SLOTS, 9,733-9,765 SWELL PKR, 9,450 SLOTS, 9,253-9,285 SWELL PKR, 8,967 SLOTS, 8,654-8,685 SWELL PKR, 8,492 SLOTS, 8,208-8,239 SWELL PKR, 8,050 NTERMEDIATE, 40-8,016 D-Sand Liner Tie-back/RAM, 7,268-7,382 Liner Seal Bore Diverter, 7,273-7,379 SEAL, 7,297 D-SAND WINDOW, 7,280-7,297 Dual Seal, 7,271 SEAL, 7,270 Dual Seal, 7,269 JOINT MANDREL, 7,265 NIPPLE, 7,231 NIPPLE, 7,226 PACKER, 7,205 PACKER, 7,201 PACKER, 7,201 PACKER, 7,200 SURFACE, 43-3,070 GAS LIFT, 2,518 SLEEVE, 2,513 NIPPLE, 540 NIPPLE, 539 CONDUCTOR, 43-120 HANGER, 37 HANGER, 37 KUP KB-Grd (ft) 0.34 Rig Release Date 12/27/2008 3K-108 ... 1 Guhl, Meredith D (CED) From:Wallace, Chris D (CED) Sent:Wednesday, October 20, 2021 8:58 AM To:AOGCC Records (CED sponsored) Subject:FW: KRU 3K-108 (PTD 208-130) Update and return well to normal status Attachments:3K-108 90 day TIO trend 10.20.21.pdf From: Well Integrity Specialist CPF1 & CPF3 <n1617@conocophillips.com> Sent: Wednesday, October 20, 2021 8:09 AM To: Wallace, Chris D (CED) <chris.wallace@alaska.gov> Cc: Earhart, Will C <William.C.Earhart@conocophillips.com> Subject: RE: KRU 3K‐108 (PTD 208‐130) Update and return well to normal status Chris, Subsequent the previous correspondence DHD technicians located and repaired three minor surface jewelry leaks on the IA. Once the surface jewelry had been tightened up the IA was left with an elevated pressure for the monitor period. The IA has exhibited no signs of IA pressure fall off during the monitor period. CPAI intends to return the well to ‘normal’ status at this time. A 90 day TIO trend is attached. Please let me know if you disagree or have any questions with this plan. Regards, Jan Byrne Well Integrity Specialist ConocoPhillips Alaska, Inc. Office phone: (907) 659-7224 Cell phone: (808) 345-6886 From: Well Integrity Specialist CPF1 & CPF3 Sent: Tuesday, September 21, 2021 9:52 AM To: Wallace, Chris D (DOA) <chris.wallace@alaska.gov> Cc: Earhart, Will C <William.C.Earhart@conocophillips.com> Subject: KRU 3K‐108 (PTD 208‐130) Report of suspect annular communication Chris, KRU 3K‐108 (PTD 208‐130) is exhibiting suspect IA pressure decrease that does not appear correlative to the injection rate or temperature. The plan is for DHD to perform initial diagnostic testing. If the testing passes the IA pressure will be left elevated and the well will be placed on a 30 day monitor. The proper paperwork for continued injection or corrective action will be submitted upon the conclusion of the testing and monitor period. A 90 day TIO trend and wellbore schematic are attached. Please let me know if you disagree or have any questions with this plan. 2 Regards, Jan Byrne Well Integrity Specialist ConocoPhillips Alaska, Inc. Office phone: (907) 659-7224 Cell phone: (808) 345-6886 1 Guhl, Meredith D (CED) From:Wallace, Chris D (CED) Sent:Wednesday, September 22, 2021 7:09 AM To:AOGCC Records (CED sponsored) Subject:FW: KRU 3K-108 (PTD 208-130) Report of suspect annular communication Attachments:3K-108 90 day TIO trend 9.21.21.pdf; 3K-108.pdf From: Well Integrity Specialist CPF1 & CPF3 <n1617@conocophillips.com> Sent: Tuesday, September 21, 2021 9:52 AM To: Wallace, Chris D (CED) <chris.wallace@alaska.gov> Cc: Earhart, Will C <William.C.Earhart@conocophillips.com> Subject: KRU 3K‐108 (PTD 208‐130) Report of suspect annular communication Chris, KRU 3K‐108 (PTD 208‐130) is exhibiting suspect IA pressure decrease that does not appear correlative to the injection rate or temperature. The plan is for DHD to perform initial diagnostic testing. If the testing passes the IA pressure will be left elevated and the well will be placed on a 30 day monitor. The proper paperwork for continued injection or corrective action will be submitted upon the conclusion of the testing and monitor period. A 90 day TIO trend and wellbore schematic are attached. Please let me know if you disagree or have any questions with this plan. Regards, Jan Byrne Well Integrity Specialist ConocoPhillips Alaska, Inc. Office phone: (907) 659-7224 Cell phone: (808) 345-6886 MEMORANDUM TO: Jim Reggper K 6 5 P.I. Supervisor FROM: Austin McLeod Petroleum Inspector NON -CONFIDENTIAL State of Alaska Alaska Oil and Gas Conservation Commission DATE: Thursday, May 13, 2021 SUBJECT: Mechanical Integrity Tests ConocoPhillips Alaska, Inc. 3K-108 KUPARUK RIV U WSAK 3K-108 Ste: Inspector Reviewed By: P.I. Suprv, Comm Well Name KUPARUK RIV U WSAK 3K-108 API Well Number 50-029-23395-00-00 Inspector Name: Austin McLeod Permit Number: 208-130-0 Inspection Date: 5/52021 Insp Num: mitSAM210506073727 Rel Insp Num: Packer Well 3K-108 Type Inj W TVD PTD 2081300 (Type Test srr Test psi BBL Pumped: 33 BBL Returned: '—- P/F Interval 4vRTST � _--- Notes: MITIA Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min 3471 - Tubing 300 - 700 700 �ITTI700 1500 - IA 145 2000.1 196501930 33 - OA 168 168 - 168 168 P ✓ Thursday, May 13, 2021 Page 1 of 1 Regg, James B (CED) PM Z,061 300 From: CPF3 Prod Engrs <n1223@conocophillips.com> Sent: Monday, January 25, 2021 5:23 PM� To: Regg, James B (CED) Cc: Well Integrity Specialist CPF1 & CPF3; NSK Prod Engr Specialist; NSK Optimization Engr; CPF3 Ops Supv; CPF3 DS Lead Techs; Kozak, Devin; Braun, Michael (Alaska) Subject: RE: Defeated LPP/SSV on well 3K-108 (PTD# 208-130) M r. Regg, The low pressure pilot on injection well 3K-108 (PTD# 208-130) has been returned to normal operation now that the injection pressure has increased sufficiently to put the LPP in service in accordance with "Administrative Approval No. CO 4068.001". Regards, Rachel Kautz/Kaelin Ellis CPF3 Production Engineer ConocoPhillips Alaska, Inc. 907-659-7871 From: CPF3 Prod Engrs Sent: Monday, January 25, 20212:44 PM To: Regg, James B (CED) <jim.regg@alaska.gov> Cc: Well Integrity Specialist CPF1 & CPF3 <n1617@conocophillips.com>; NSK Prod Engr Specialist <n1139@conocophillips.com>; NSK Optimization Engr <n2046@conocophillips.com>; CPF3 Ops Supv (n2070@conocophillips.com) <n2070@conocophillips.com>; CPF3 DS Lead Techs <n1105@conocophillips.com>; Kozak, Devin <Devin.Kozak@conocophillips.com>; Braun, Michael (Alaska) <Michael.Bra un@conocophillips.com> Subject: Defeated LPP/SSV on well 3K-108 (PTD# 208-130) Mr. Regg, The low pressure pilot (LPP) on injection well 3K-108 (PTD# 208-130) has just been defeated as of January 25, 2021. The well has been shut in since October 2020 awaiting a surface line repair. The repair was recently completed and the well was returned to injection today, but the wellhead pressure has not risen high enough to place the LPP in service. The well currently shows 210 psi wellhead injection pressure and an injection rate of 1000 BWPD. The LPP and surface safety valves (SSV) have been tagged and their status is recorded in the "Drill Site Defeated Safety Device Log", where it is referred to as 3K -108D. The AOGCC will be notified when the injection pressure has increased to above 250 psig and the LPP/SSV function is returned to normal, in accordance with "Administrative Approval No. CO 406B.001." Please let me know if you have any questions. Regards, Pro �(3c� Regg, James B (CED) From: CPF3 Prod Engrs <n1223@conocophillips.com>n Sent: Tuesday, September 10, 2019 6:10 AM vyGJ Cl f /a'ci To: Regg, James B (CED) a a Cc: Valentine, Doug K; NSK Prod Engr Specialist Subject: 3K-108 Defeated LPP/SSV --(PTD# 208-1300) --Returned to Service Mr. Regg, The low pressure pilot (LPP) on injection well 3K-108 (PTD# 208-1300) was returned to service at approximately 1400 hrs on Monday September 8, 2019. At that point we had increased the injection rate to 600 BWPD and the injection pressure rose to 370 psig and was rising. Thanks, I Kenneth Lloyd Martin/Kaelin Ellis PERA/CPF3 Production Engineers Ph: (907) 659-7871 From: CPF3 Prod Engrs Sent: Sunday, September 08, 2019 5:20 PM To: jim.regg@alaska.gov Cc: Valentine, Doug K <Doug.K.Valentine@conocophillips.com>; NSK Prod Engr Specialist <ni139@conocophillips.com> Subject: 3K-108 Defeated LPP/SSV --(PTD# 208-1300) per CO 4068.001 Mr. Regg, The low pressure pilot (LPP) on injection well 3K-108 (PTD# 208-1300) is defeated today, Sunday September 8, 2019. 3K-108 had been shut in since July 4, 2019 due to the CPF3 Seawater Tank preventing SW injection. We are ramping up injection slowly to the West Sak injectors at DS 3K. 3K-108 is currently at wellhead injection pressure of 260 psig (decreasing) and injection rate of 300 bbls of water per day. The LPP and surface safety valves (SSV) have been tagged and their status is recorded in the "Facility Defeated Safety Device Log", where this well is referred to as 3K -308D. The AOGCC will be notified when the injection pressure has increased to above 250 psi and is stable, and the LPP/SSV function is returned to normal operation, in accordance with "Administrative Approval No. CO 406B.001". Please let me know if you have any concerns or questions, lqUc. 3K--(06 p7ts Zee 1300 Regg, James B (CED) From: CPF3 Prod Engrs <n1223@conocophillips.com> Sent: Sunday, September 8, 2019 5:20 PM To: Regg, James B (CED) 6 Cc: Valentine, Doug K; NSK Prod Engr Specialist Subject: 3K-108 Defeated LPP/SSV --(PTD# 208-1300) per CO 40613.001 Mr. Regg, The low pressure pilot (LPP) on injection well 3K-108 (PTD# 208-1300) is defeated today, Sunday September 8, 2019. 3K-108 had been shut in since July 4, 2019 due to the CPF3 Seawater Tank preventing SW injection. We are ramping up injection slowly to the West Sak injectors at DS 3K. 3K-108 is currently at wellhead injection pressure of 260 psig (decreasing) and injection rate of 300 bbls of water per day. The LPP and surface safety valves (SSV) have been tagged and their status is recorded in the "Facility Defeated Safety Device Log", where this well is referred to as 3K -308D. The AOGCC will be notified when the injection pressure has increased to above 250 psi and is stable, and the LPP/SSV function is returned to normal operation, in accordance with "Administrative Approval No. CO 4068.001". Please let me know if you have any concerns or questions, Thanks, Kenneth Lloyd Martin/Kaelin Ellis PERA/CPF3 Production Engineers Ph: (907) 659-7871 Pager: (907) 659-7000 pp# 328 • ! MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO Jim Regg DATE: Tuesday,May 16,2017 P.I.Supervisor -Qee I C1 1+( 7 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 3K-108 FROM: Chuck Scheve KUPARUK RIV U WSAK 3K-108 Petroleum Inspector Src: Inspector Reviewed By: P.I.Suprv\jn _— NON-CONFIDENTIAL Comm Well Name KUPARUK RIV U WSAK 3K-108 API Well Number 50-029-23395-00-00 Inspector Name: Chuck Scheve Permit Number: 208-130-0 Inspection Date: 5/9/2017 Insp Num: mitCS170511070909 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 3K-108 Type Inj W' TVD 3471 ' Tubing 553 554 554 . 553 - PTD 2081300 Type Test SPT Test psi 1500 IA 1540 2300 2270 - 2260 BBL Pumped: 1A BBL Returned: 1.2 p OA 166 167 - 167_ 167 , Interval 4YRTST P/F P Notes: %WE® I_J1 I 1 201? Tuesday,May 16,2017 Page 1 of 1 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: DATE: Wednesday,May 15,2013 Jim Regg I i l P.I.Supervisor (`' �� SUBJECT: Mechanical Integrity Tests ' CONOCOPHILLIPS ALASKA INC 3K-108 FROM: Bob Noble KUPARUK RIV U WSAK 3K-I08 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry -J -- NON-CONFIDENTIAL Comm Well Name KUPARUK RIV U WSAK 3K-108 API Well Number 50-029-23395-00-00 Inspector Name: Bob Noble Permit Number: 208-130-0 Inspection Date: 5/12/2013 Insp Num: mitRCNl30513061331 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min 3K 08 T Yp 1960 ,� Well -1 e In W 'TVD 3471 IA 1320 2000 ' . 1970 PTD! 2081300 • 1Type Test',SPT Test psi 1500 OA 160 160 160 160 . I P/F " Tubing ___ y__ 700 700 Interval 'avRTST � P 700 700 ■ L Notes: Duel Comp.well,Short string pressures were,695,695,695,695 SCANNED FEB 2 0 2014 Wednesday,May 15,2013 Page 1 of 1 DATA SUBMITTAL COMPLIANCE REPORT 312/2010 Permit to Drill 2081300 Well Name/No. KUPARUK RIV U WSAK 3K-108 Operator CONOCOPHILLIPS ALASKA INC API No. 50-029-23395-00-00 MD 13180 ND 3684 Completion Date 12!27/2008 Completion Status 1 WIND Current Status 1 WINJ IC Y REQUIRED INFORMATION Mud Log No .Samples No Directional Survey Yes ,% DATA INFORMATION Types Electric or Other Logs Run: GR/RES, USIT (data taken from Logs Portion of Master Well Data Maint Well Log Information: Log/ Electr Data ,Digital Dataset Log Log Run Interval OH / Typ ~Med/Frmt Number Name Scale Media No Start Stop CH Received Comments C Exc Directional Survey 0 8020 Open 10/13/2008 NAD27 and NAD83 on CD Directional Survey ~~ ~~_ 0 8020 Open 10/13/2008 NAD27 ~ R t Caliper log 6904 7274 Case 12/31!2008 Mem Multi Finger Caliper Log Resuits Summ (NO TRANSMITTAL) ' C ED C Pds 17323 aliper log 6904 7274 Case 12/31/2008 Mem Multi Finger Caliper Log Results Summ (NO TRANSMITTAL) Caliper log 6649 7269 Case 12/31/2008 Mem Multi Finger Caliper Log Results Summ (NO TRANSMITTAL) C Pds 17324 'Caliper log 6649 7269 Case 12/31/2008 Mem Multi Finger Caliper Log Results Summ (NO TRANSMITTAL) Caliper log 7240 7273 Case 12/31/2008 Mem Multi Finger Caliper Log Results Summ (NO TRANSMITTAL) C Pds 17325 caliper log 7240 7273 Case 12/31/2008 Mem Multi Finger Caliper Log Results Summ (NO TRANSMITTAL) Sonic 5 Col 2200 7970 Case 12/31/2008 USIT, Cement, GR, CCL 23-Nov-2008 C Pds 17356 ~ic 2200 7970 Case 12/31/2008 USIT, Cement, GR, CCL 23-Nov-2008 DATA SUBMITTAL COMPLIANCE REPORT 3/2/2010 ~Pe~rmit to Drill 2081300 Well Name/No. KUPARUK RIV U WSAK 3K-108 Operator CONOCOPHILLIPS ALASKA INC "MD 13180 TVD 3684 Completion Date 12/27/2008 Completion Status 1WINJ Current Status 1WINJ t LIS Verification 3031 13180 Open 2/20/2009 LIS Veri, GR, FET, RPD, RPS, RPM, RPX, ROP ~~ C Lis ~ ''~~ 17602t~mduction/Resistivity 3031 13180 Open 2/20/2009 LIS Veri, GR, FET, RPD, RPS, RPM, RPX, ROP L Induction/Resistivity 25 Col 120 13180 Open 2/20/2009 MD ROP, EWR, DGR 28- ~' Nov-2009 og Induction/Resistivity 25 CoI 120 3684 Open 2/20/2009 TVD EWR, DGR 28-Nov- ~ 2009 ~.€~D C ~ 17603'" Induction/Resistivity 120 13180 Open 2/20/2009 EWR logs in PDS, EMF II and CGM graphics i ~„ Injection Profile 2 Col 7650 12900 Case 11/25/2009 Spectra Flow, (PROF ~/ C Pds 18994~'Injection Profile 7650 12900 Case 11/25/2009 Spectra Flow, (PROF Well Cores/Samples Information: Name ADDITIONAL INFORMATION Well Cored? Y~ Chips Received? `~ / N Analysis Y+M-~"" Received? Sample Interval Set Start Stop Sent Received Number Comments Daily History Received? Formation Tops ~/ N API No. 50-029-23395-00-00 UIC Y Comments: Compliance Reviewed By: Date: L~ WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. Attn.: Christine Mahnken 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Water Flow Log: 3K-108 Run Date: l0i 13/2009 November 13, 2009 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention o£ Rafael Barreto, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 3K-108 Digital Data in LAS format, Digital Log Image file, Interpretation Report 1 CD Rom 50-029-23395-00 Spectra Flow Log 1 Color Log 50-029-23395-00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRAi'VSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Rafael Barreto 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-273-3527 Fax: 907-273-3535 rafae L ban etoChalliburton. com /~`~~G/ Date: Signed: s • ConocoPhillips ~~~ P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 November 3, 2009 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Dear Mr. Maunder: ~$ ~.~~, ~l~:~f ' -;s 1:~~°°. ~;t~misso~ ~1"~" €'a(j6 a~$'l3 D$ 3 K" ~ Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRil). Each of these wells was found to have a void in the conductor. These voids were filled with cement if needed and corrosion inhibitor, engineered to prevent water from entering the annular space. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treatments took place and meets the requirements of form 10-404, Report of Sundry Operations. The cement was pumped September 200i and October 13th 2009. The corrosion inhibitor/sealant was pumped October 15th and 31St + November 1St and 2nd 2009. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please call MJ Loveland or Perry Klein at 907-659-7043, if you have any questions. ~mcerely, Perry Klei ConocoPhillips Well Integrity Projects Supervisor ti ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) Kuparuk Field Date 11/3/09 2C. 2D, 2Z & 3K Pad Well Name API # PTD # Initial top o cement Vol. of cement um ed Final top of cement Cement top off date Corrosion inhibitor Corrosion inhibitor/ sealant date ft bbls ft al 2C-01 50029209620000 1830830 17" NA 17" NA 2.12 10/15/2009 2C-02 50029209720000 1830930 12" NA 12" NA 2.97 10/15/2009 2C-03 50029209680000 1830890 10" NA 10" NA 3.82 10/15/2009 2C-04 50029209730000 1830940 17" NA 17" NA 2.12 10/15/2009 2C-05 50029209780000 1830990 18" NA 18" NA 3.4 10/31/2009 2C-06 50029209790000 1831000 28" NA 28" NA 7.65 10/15/2009 2C-08 50029209740000 1830950 27" NA 27" NA 6.8 10/15/2009 2C-09 50029212370000 1842210 22" NA 22" NA 5.1 10/15/2009 2C-10 50029212300000 1842140 54' 5.5 22" 10/13/2009 4.67 10/31/2009 2C-11 50029212310000 1842150 38' 5.3 26" 10/13/2009 5.52 10/31/2009 2C-12 50029212220000 1842060 25' 4.5 26" 10/13/2009 6.8 10/31/2009 2C-13 50029212230000 1842070 20" NA 20" NA 3.4 10/15/2009 2D-01 50029211940000 1841710 38" NA 38" NA 6.8 10/31/2009 2D-07 50029211690000 1841430 20" NA 20" NA 2.12 10/31/2009 2D-09 50029211370000 1841030 28" NA 28" NA 4.67 10/31/2009 2D-10 50029211350000 1841010 21" NA 28" NA 2.97 11/1/2009 2D-11 50029211340000 1840990 19" NA 19" NA 2.55 11!1/2009 2D-12 50029211310000 1840940 18" NA 18" NA 2.55 11/1/2009 2D-15 50029211840000 1841600 NS NA NS NA 1.7 11/1/2009 2Z-01A 50029209530100 2071110 14" NA 14" NA 1.7 11/1/2009 2Z-02 50029209600000 1830800 18" NA 18" NA 5.1 11/2/2009 2Z-03 50029209640000 18$0850 24" NA 24" NA 5.5 11/2/2009 2Z-06 50029209570000 1830770 10'9" 2.5 7" 9/20/2009 2.12 11 /1 /2009 2Z-14 50029213610000 1851070 24" NA 24" NA 3.4 11/1/2009 2Z-16 50029213630000 1851090 20" NA 20" NA 1.7 11 /1 /2009 2Z-18 50029218840000 1881330 37'6" 6.5 39" 9/20/2009 8.9 11 /2/2009 2Z-22 50029225240000 1941470 16" NA 16" NA 5.95 11/1/2009 2Z-23 50029225440000 1950100 17" NA 17" NA 3.4 11/1/2009 3K-103 50029233920000 2081150 29" NA 29" NA 11.9 11/2/2009 3K-108 50029233950000 2081300 24" NA 24" NA 4.25 11/2/2009 • MEMORANDUM TO: Jim Regg 1\C,~~ ~` /~~~`~ P.I. Supervisor FROM: Chuck Scheve Petroleum Inspector State of Alaska Alaska Oil and Gas Conservation Commission DATE: Wednesday, May 20, 2009 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 3K-108 KUPARUK RIV U WSAK 3K-108 Src: Inspector Reviewed By: P.I. Suprv~ NON-CONFIDENTIAL Comm KUPARUK RIV U WSAK 3K-108 ApI Well Number: 50-029-23395-00-00 Inspector Name: Chuck Scheve Well Name: 5/15/2009 mitCS090515171219 Permit Number: 208-130-0 Inspection Date: Insp Num: Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well sK-IOS Type Inj. W TVD 3471 IA i Isoo z2so zz6o 2z6o P.T.D zoslsoo TypeTest SPT Test psi Isoo OA Iso I6o I6o I6o 4YRTST P ~ Tubing 600 600 600 600 Interval P~ Notes' Pretest pressures observed and found stable. Well demonsVated good mechanical integrity. ~ Pagelofl Wednesday, May 20, 2009 • ~ WELL LOG TRANSMITTAL To: State of Alaska January 9, 2009 Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West 7~' Avenue, Suite 100 Anchorage, Alaska RE: MWD Formation Evaluation Data 3K-108 AK-MW-6005292 1 LDWG formatted CD Rom with verification listing. API#: 50-029-23 3 95-00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry Drilling Services Attn: Bryan Burinda 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-273-3536 Fax: 907-273-3535 Bryan.Burinda@halliburton.com ~.,~ Date ~ ~~ Signed: vza. ~o~_t3z~ r~~~a ~-~ .~ Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Friday, February 13, 2009 3:38 PM To: 'Eggemeyer, Jerome C.'; Hartwig, Dennis D Subject: RE: 3K-108 (208-130) and 3K-108L1 (208-133) -- AGAIN Jerome, Thanks for the additional information. Tom Page 1 of 3 From: Eggemeyer, Jerome C. [mailto:Jerome.C.Eggemeyer@conocophillips.com] Sent: Friday, February 13, 2009 3:33 PM To: Hartwig, Dennis D; Maunder, Thomas E (DOA) Subject: RE: 3K-108 (208-130) and 3K-108L1 (208-133) -- AGAIN Tom, Definitely some complex completions and a hero's effort on getting them in the ground. To add one point to what dennis already said; we usually flow the mud out of the well through the slotted liner (no problem with damage or plugging since there is a lot of area). when running the resinject it is impossible to flow the mud back because it will certainly plug the tiny nozzles and therefore we have to circulate the well to a fluid that does not have to be flowed back. Lots of fluids to clean things ups as dennis mentions and the ultimate issue is that we can not flow the mud back prior to starting injection into these completions. thanks, Jerome From: Hartwig, Dennis D Sent: Friday, February 13, 2009 11:28 AM To: 'Maunder, Thomas E (DOA)' Cc: Alvord, Chip; Eggemeyer, Jerome C. Subject: RE: 3K-108 (208-130) and 3K-108L1 (208-133) -- AGAIN Tom, As far as the 13-3/8 hangup issues, the initial. attempt to get the 13-318 dawn. was unsuccessful so after a cleanout, we went back in with a different shoe. The new shoe, a silver bullet aluminum shoe, offers a profile which is more conducive to overcoming ledges etc. After drilling the intermediate hole we spent several days getting the BHA hung up shallow inside of the 13-3/8" pipe. We finally got the BHA out of the hole and made a cleanout run to bottom vtirith a reverse circulation junk basket and recovered several. large pieces of aluminum which is the likely cause of our problems. Alpine runs smaller sizes of the silver bullet as a matter of course and has never had any issues. Our issue may have resulted from drilling out with a rock bit as opposed to a PDG as well as setting the 13- 3/8 slightly off bottom. The caustic and acid washes were a preface to running the ResInject screens. Integral to the screens-are very small nozzles (2.Smm diameter) which we were very worried about plugging. The caustic and acid were performed to remove any casing scale which might plug off the nozzles during liner installation. Page 2 of 3 The dual completions were the first in the world to employ this particular level s junction. I would be happy to stop over sometime and describe in more detail the basis of design and detailed completion construction. Thanks...Dennis Dennis Hartwig Drilling Engineer Greater Kuparuk Area ConocoPhillips Alaska - ATO-1592 Office :907-265-6862 Cell :907-575-7109 Fax :907-265-1535 From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov] Sent: Friday, February 13, 2009 10:51 AM To: Hartwig, Dennis D Cc: Alvord, Chip; Eggemeyer, Jerome C. Subject: RE: 3K-108 (208-130) and 3K-108L1 (208-133) -- AGAIN Dennis, et al, Further to my earlier message, a couple of comments/observations. WOW, you certainly got practice tripping lots of different tubulars!! Any determination what was the hold-up in the 13-3/8"? Alignment appeared to be the issue with the tubing. I note that a comment is included that the 9-5/8" casing/cementing job was planned with slips. I think this is a good move due to the uncertainty of successfully landing a mandrel hanger when the focus is improving the cement job as much as possible with pipe movement. One of my pet peeves is when I see "emergency slips". Slips are slips and their purpose is to allow the pipe to be properly set in tension regardless of where it is ultimately "set". I think that the focus can sometimes be too much on landing the hanger and not on promoting the best cement job possible. After the OSD, caustic and acid washes of the 9-5/8" casing are performed. What was the purpose here? I have seen such operations in other wells, but usually in advance of gravel packs and such. Thanks in advance, Tom From: Maunder, Thomas E (DOA) Sent: Friday, February 13, 2009 10:33 AM To: 'Hartwig, Dennis D'; Allsup-Drake, Sharon K Subject: RE: 3K-108 (208-130) and 3K-108L1 (208-133) Not a problem. I will make the change. From: Hartwig, Dennis D [mailto:Dennis.D.Hartwig@conocophillips.com] Sent: Friday, February 13, 2009 10:32 AM To: Maunder, Thomas E (DOA); Allsup-Drake, Sharon K Subject: RE: 3K-108 (208-130) and 3K-108L1 (208-133) Tom, You are correct, on the 407, block 23 should be checked to OPEN, since the screen intervals are open to injection. I apologize for the oversight. 2/13/2009 Regards...Dennis Dennis Hartwig Drilling Engineer Greater Kuparuk Area ConocoPhillips Alaska - ATO-1592 Office :907-265-6862 Cell :907-575-7 l04 Fax :907-265-1535 From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov] Sent: Friday, February 13, 2009 9:27 AM To: Hartwig, Dennis D; Allsup-Drake, Sharon K Subject: 3K-108 (208-130) and 3K-108L1 (208-133) Page 3 of 3 Sharon and Dennis, I am reviewing the 407s submitted for these wells. On the 407, block 23 (perforation section), it is checked that these intervals are NOT open to production or injection. I don't believe that this is correct. The well may not be in operation, however the intervals are open. Am I missing something here? I think for "not open" to apply that some sort of plug needs to be in place. I look forward to your reply. Tom Maunder, PE AOGCC 2/13/2009 r i~'C:iA1~ICAL INTEGRITY :REPORT ~~~-~~z, BUD D__..: ~ ~~~_ OPER ~ FZELD ~.~:~~ ~~Z~ ~ > ?~ ~~- \o~sLs. ~ I a~~~ NUS ER ;.ELI ~1~- ~ ~`~ - to~S L"~,. =_~G rC~~~~~_ ~ . ~. ~~\~~~ VS .~, r LL DAT e TD : '~~\~~ ?~D.. 3~~ 'I'VD ; . BTD : ~~ ~~~ ?~iD ~~ \ T~7D lasing ~~~~ Shoe _ ~~~ tID 3~S TVD ~ yV . ~ (~... ?~ ~~ T4`~i ~_:,er . SCceQ~ Shoe : '~ T`TD ; .CP . ?-~ ~''~~ ~~t _ ~o~,v 3'~~ Packer ~~O ~ ':-'~ T'Ti Set at _ole S~ce ~ and Perfs ~~1~ to \~15~ ~. 'Za co4S 11~-1`13 :~i.'r'.~?~=CST, INTEGRITY - P4.RT # Ynru' 4s ?ress Test: _? 15 min ~0 min Cor~ents '~*' CHA?~T I CST, INTE GR2TY - PART_ # Z r-~r a \'1 bbd Cement Volumes : A~t_ Liner Cs~ 5~~ s~ DV t~11~, ~tsoo' ~~~6xS '~~ ~b~.s C,ut -rol to cover Hers eoretical TOC ~ 3~Zo1~S ='SD3~ Cement Bond Log (Yes or No) ~,~°3 Zn AOGCC File .it` ~~. CBL Lvaluation, tone aoove perfs S'c~r+~c pC~.'"~.`~\G SC~~ht C~FCaC"'- ~~ v.~1~©~--.~ ~ tl \00 ~ 1py~'s- tsO~y-stn h ~~Z~C~~ t~roducti on I.og: Type .Evaluation CONC;LJS:ONS ?arm i I ?art r 2 . ~~ ~S ~~~~C~~~ Maunder, Thomas E (DOA) From: Hartwig, Dennis D [Dennis.D.Hartwig@conocophillips.com] Sent: Friday, February 13, 2009 10:32 AM To: Maunder, Thomas E (DOA); Allsup-Drake, Sharon K Subject: RE: 3K-108 (208-130) and 3K-108L1 (208-133) Torn, Page 1 of 1 You are correct, on the 407, block 23 should be checked to OPEN, since the screen intervals are open to injection, l apologize for the oversight, Regards...Dennis Dennis Hartwig Drilling Engineer Greater Kupanak Area ConocoPhillips Alaska - ATO-1592 Office :907-265-6862 Cell :907-575-7109 Fax :9~7-265-155 From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov] Sent: Friday, February 13, 2009 9:27 AM To: Hartwig, Dennis D; Allsup-Drake, Sharon K Subject: 3K-108 (208-130) and 3K-108L1 (208-133) Sharon and Dennis, I am reviewing the 407s submitted for these wells. On the 407, block 23 (perforation section), it is checked that these intervals are NOT open to production or injection. I don't believe that this is correct. The well may not be in operation, however the intervals are open. Am I missing something here? I think for "not open" to apply that some sort of plug needs to be in place. I look forward to your reply. Tom Maunder, PE AOGCC Zi13i2oa9 3K-103 - Doyon 15 -Current st~us Page 1 of 4 - Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Thursday, February 05, 2009 11:50 AM To: 'Sale, Julie J' Cc: 'Wharton, Paul K'; 'Downey, Allison ; 'Spenceley, Neil'; Dennis Hartwig Subject: RE: 3K-103 (208-115), 3K-103L1 (208-116), 3K-108 (208-130) and 3k-108L1 (208-133) Julie, et al, I was checking fifes over here regarding these wells. It appears that 3K-108 and -109L1 are also equipped with individual tubing strings. if this is correct, separate volumes should be reported for each string similar to 3K-103 and -103L1. Thanks in advance. Call or message with any questions. Tom Maunder, PE AOGCC From: Maunder, Thomas E (DOA) Sent: Tuesday, January 27, 2009 1:37 PM To: Safe, Julie J Cc: Wharton, Paul K; Downey, Allison; Spenceley, Neil; Machal, Gloria; Davies, Stephen F (DOA); Roby, David S (DOA); McMains, Stephen E (DOA) Subject: RE: 3K-103 (208-115) and 3K-103Li (208-116} Yes, Julie that is correct. Call or message with any questions. Tom Maunder, PE AOGCC From: Sale, Julie J [mailto:Julie.J.Sale@conocophillips.com] Sent: Tuesday, January 27, 2009 1:26 PM To: Maunder, Thomas E (DOA) Cc: Wharton, Paul K; Downey, Allison; Spenceley, Neil; Machal, Gloria Subject: RE: 3K-103 (208-115) Thomas, Does this give you the information you are needing fram ConocoPhillips? Proposed Reporting_~tiethod On the AOGCC Monthly Injection Report {10-406), we typically report well level injection for multi-laterals because all injection goes through one meter at the surface. In this case we will have separate surface injection meters for each string so we have the ability to report afi the wellborelstring level. Julie J. Sale ConocoPhillips Supervisor Revenue and Regulatory Upstream Accounting Alaska 930 G POB / Bartlesville, OK 74004 918-661-3523 (w} /918-914-3bb9 (c} 918-b62-1702 (fax) 620-778-4906 (personal-cell} julie.j.sale@conocophillips.com 2/13/2009 3K-103 - Doyon 15 -Current st~s From: Spenceley, Neil Sent: Tuesday, January 27, 2009 11:31 AM To: Maunder, Thomas E (DOA) Cc: Wharton, Paul K; Downey, Allison; Sale, Julie J Subject: RE: 3K-103 (208-115) TC} m, • As per our conversation We Will report the 3K injection volumes as folit~WS: Page 2 of 4 The Well Will he split i tWO (3K-103 and 3K-103L1) to he reported as separate rate streams injecting into the 1~lst Sak oil pool. Please let me knout if you Would like to see it reported differently. Thanks, Neil From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov] Sent: Tuesday, January 27, 2009 8:14 AM To: Spenceley, Neil Subject: FW: 3K-103 (208-115) Here is that message trail. From: Downey, Allison [mailto:Allison.Downey@ConocoPhillips.com] Sent: Tuesday, )anuary 13, 2009 8:47 AM To: Maunder, Thomas E (DOA) Cc: Roby, David S (DOA); Davies, Stephen F (DOA); McMains, Stephen E (DOA); Hartwig, Dennis D; Sale, Julie J Subject: RE: 3K-103 (208-115) Tom, l am working the 3K-103 reporting issue with the Revenue Accounting group. U11e uvill have an ensurer for you soon on how the dual string injection will be reported. The well is not in service yet but is expected to start injection this week. Allison Allison Downey CIS Technical Data Management Gonoco}'hillips Alaska, Inc. 907-263-4299 From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov] Sent: Monday, )anuary 12, 2009 3:00 PM To: Hartwig, Dennis D; Downey, Allison 2/13/2009 3K-103 - Doyon 15 -Current st~s Cc: Roby, David S (DOA); Davies, Stephen F (DOA); McMains, Stephen E (DOA) Subject: RE: 3K-103 (208-115) Dennis, Thanks. We will look forward to Allison's contact. Tom Maunder, PE AOGCC From: Hartwig, Dennis D [mailto:Dennis.D.Hartwig@conocophillips.com] Sent: Monday, January 12; 2009 2:56 PM To: Maunder, Thomas E (DOA) Cc: Roby, David S (DOA); Davies, Stephen F (DOA); McMains, Stephen E (DOA) Subject: RE: 3K-103 (208-115) Tam., Page 3 of 4 I have forwarded on your questions to Allison Downey (~llison.clo«-n~y cr:co~~ocoph;illips.cor~~). Allison has l"ieen tasked with setting up A"I`DB to store the lateral specific injection data separately as opposed to commingled. I left a phone message for Allison and will continue to follow up until your questions are answered. Regards...Dennis Dennis I3art~vig :Drilling Engineer Greater Kuparuk Area ConocoPhillips Alaska - ATO-1592 Office :907-265-6862 Cell :907-575-7:109 F'ax :907-2b5-1535 From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov] Sent: Monday, January 12, 2009 1:40 PM To: Hartwig, Dennis D Cc: Roby, David S (DOA); Davies, Stephen F (DOA); McMains, Stephen E (DOA) Subject: RE: 3K-103 (208-115) Thanks Dennis. Also, do you know if the well has been placed in operation? As we have looked into the particulars for this well several questions regarding the injection reporting have come up. To our knowledge, this is the first dual tubing, multi-lateral well into the WS and likely on the slope. !believe there are a few other dual tubing single penetration WS wells. In most cases, neither production nor injection is "credited" to laterals since everything is commingled in the wellbore. That is not the case here where the separate volumes in each string can be determined. f am not sure who would be the one to comment on how the injection volumes would be reported, however it appears that is a question that should be asked. I'd appreciate if you could forward this portion of the message on for comment. Call or message with any questions. Tom Maunder, PE AOGCC From: Hartwig, Dennis D [mailto:Dennis.D.Hartwig@conocophillips.com] Sent: Monday, January 12, 2009 12:42 PM 2/13/2009 3K-103 - Doyon 15 -Current st~s . Page 4 of 4 To: Maunder, Thomas E (DOA) Subject: RE: 3K-103 (208-115) Tom., I will look into these issues and get back to you ASAP...Dennis Dennis Hartwig Drilling Engineer Greater Kuparuk Area ConocuPhillips Alaska - ATO-1592 Oftice :907-265-6862 Cell :907-575-7109 Fax :907-265-li~5 2/13/2009 • Page 1 of 3 Maunder, Thomas E (DOA) From: CPF3 Prod Engrs [n1223@conocophillips.com] Sent: Thursday, February 05, 2009 3:35 PM To: Maunder, Thomas E (DOA); CPF3 DS Lead Techs Cc: CPF3 Prod Supt; Regg, James B (DOA); NSK Problem Well Supv; NSK Well Integrity Proj Subject: RE: "NE WestSak Injector 3K-108 (208-130)".~~ ®~_,~~ ~~~_~~"~ Tom, Sorry for any confusion. ft was indeed the pilots for both strings; 3K-108 LPP and HPP 3K-108L1 LPP and HPP that were taken out and then put back into service. You are correct that both the 3k103 and 3k-108 are dual tubing string injectors. Therefore, each string has a HPP and LPP. We will try to be more specific and use the nomenclature as you have described below. Please call or message if you have any questions or need more information. Thank you ~~`>~ a~~-_ r r ~ .lon Conc~io f Tim Rlelo ~~ 1 1, Co ConocoPhillips Alaska, Inc. CPF3 Production Engineers Email: N1223@conocophillips,com Ph. (907} 559-7871 Fax. (907} 559-1805 From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov] Sent: Thursday, February 05, 2009 12:00 PM To: CPF3 DS Lead Techs Cc: CPF3 Prod Engrs; CPF3 Prod Supt; Regg, James B (DOA); NSK Problem Well Supv; NSK Well Integrity Proj Subject: RE: "NE West Sak Injector 3K-108 (208-130)". Wayne, et al, I have had a chance to review the files. It appears that there are two individual tubing strings here, one far 3K- 108 and the other for 3K-108L1. Were the low pressure pilots defeated for both strings? If that is the case, the messages should have included the information for both strings/valves. This could have also been the case for 3K-103 and 3K-103L1. If you or one of the engineers could provide the information far the pilots that were defeated and then placed back in service for each string, it will be appreciated. Just reply to this message. Equipping these wells with dual strings makes the reporting a bit more complicated when the pilots are defeated. !t seems appropriate where dual strings are involved to make sure that the specific string with the defeated pilot is clearly identified (-108 or 108L1 } or send separate messages for each string. Call or message with any questions. I look forward to your reply. Tom Maunder, PE AOGCC From: Maunder, Thomas E (DOA) Sent: Tuesday, February 03, 2009 4:58 PM 2/13/2009 • Page 2 of 3 • To: 'CPF3 DS Lead Techs' Cc: CPF3 Prod Engrs; CPF3 Prod Supt Subject: RE: "NE West Sak Injector 3K-108 (208-130)". Wayne, et al, I will have to check the files tomorrow. It appears I have messages regarding both 3K-108 and 3K-103. Tom Maunder, PE AOGCC From: CPF3 DS Lead Techs [mailto:n1105@conocophillips.com] Sent: Tuesday, February 03, 2009 4:41 PM To: Maunder, Thomas E (DOA) Cc: CPF3 Prod Engrs; CPF3 Prod Supt; CPF3 DS Lead Techs Subject: RE: "NE West Sak Injector 3K-108 (208-130)". Tom, I hope I am sending this to the correct person. As we don't currently have one of our P,E.'s on the slaps: 3K-108 LPP`s where satisfied and put back in service 2/03f09 ~ 16:30 If 1 need to do something else please let me know. Thank you very much. Wayne Griebef CPF3 DS Lead From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov] Sent: Tuesday, February 03, 2009 3:02 PM To: CPF3 Prod Engrs; Regg, James B (DOA) Ce: NSK Prod Engr Specialist; Targac, Gary; CPF3 Prod Supt; Allsup-Drake, Sharon K; CPF3 DS Lead Techs; NSK Problem Well Supv Subject: RE: Tim, When you send a message such as this, please include a title. Specifically for a well with a defeated safety valve the title should in this case read "NE West Sak Injector 3K-108 (208-130)". Thanks in advance. Call or message with any questions. Tom Maunder, PE From: CPF3 Prod Engrs [mailto:n1223@conocophillips.com] Sent: Monday, February 02, 2009 6:32 PM To: Maunder, Thomas E (DOA); Regg, James B (DOA) Cc: NSK Prod Engr Specialist; Targac, Gary; CPF3 Prod Supt; Allsup-Drake, Sharon K; CPF3 DS Lead Techs; NSK Problem Well Supv Subject: Tom /Jim, This email is to notify the AOGCC that the North East West Sak (NEWS) Injector 3K-108 Low Pressure Pilots (LPP) are defeated as of 2/2/2009. This is in accordance with "Administrative Approval No. CO 4066.001" The LPP and SSV (Surface Safety Valve) have been tagged and recorded on the "Facility Defeated Safety Device Log." The 3K-108 was brought on injection today, 2/02/2009. It is anticipated that injection pressure will increase above 250 psi within a few days. Current injection rate is 640 BWPD at 200 psi injection pressure in the B lateral and 430 BWPD at 235 psi injection pressure in the D lateral. 2/13/2009 • ~ Page 3 of 3 The AOGCC will be notified when the injection pressure has increased above 250 psi and the LPP functions are returned to normal. Tim Nelson /John Condio ConocoPhillips Alaska, Inc. CPF3 Production Engineers Email: N1223@conocophillips.com Ph. (907) 659-7871 Fax. (907) 659-7806 2/13/2009 r~ U ConocoPhillips January 22, 2009 G. C. Alvord GKA Drilling Leader Drilling & Wells P. O. Box 100360 Anchorage, AK 99510-0360 Phone: 907-265-6120 RECEIVED Commissioner JAI 2 6 2009 State of Alaska Alaska pit & Gas Cons. Commissi Alaska Oil & Gas Conservation Commission on 333 West 7th Avenue Suite 100 Anchorage Anchorage, Alaska 99501 Subject: Well Completion Reports for 3K-108 and 3K-108L1 Dear Commissioner: ConocoPhillips Alaska, Inc. submits the attached Well Completion Reports for the recent drilling operations on the Kuparuk wells 3K-~08 and 3K-108L1. If you have any questions regarding this matter, please contact me at 265-6120 or Dennis Hartwig @ 265-6862. Sincerely, ~ • ~~ G. C. Alvord GKA Drilling Team Lead CPAI Drilling GCA/skad ~"~l~~~~ RE~~1'~f~D STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION JAN 2 6 ZOOS WELL COMPLETION OR RECOMPLETION REPORT AND LOG _ 1a. Well Status: Oil ^ Gas Plugged Abandoned Suspended 20AAC 25.105 20AAC 25.110 GINJ ^ WINJ ~ WDSPL ^ WAG ^ Other ^ No. of Completions: Development ~]'1C~i0faQ~bloratory ^ Service ^~ Stratigraphic Test ^ 2. Operator Name: ConocoPhillips Alaska, Inc. 5. Date Comp., Susp., orAband.: December 27, 2008 ~ 12. Permit to Drill Number: 208-130 / 308-327 3. Address: P. O. Box 100360, Anchorage, AK 99510-0360 6. Date Spudded: September 5, 2008 ' 13. API Number: 50-029-23395-00 4a. Location of Well (Governmental Section): Surface: 1472' FSL, 319' FWL, Sec. 35, T13N, R9E, UM 7. Date TD Reached: November 28, 2008 14. Well Name and Number: 3K-108 Top of Productive Horizon: 330' FNL, 110' FEL, Sec. 35, T13N, R9E, UM 8. KB (ft above MSL): 74.1' RKB Ground (ft MSL): 33.4' AMSL " 15. Field/Pool(s): Kuparuk River Field Total Depth: 1004' FNL, 238' FEL, Sec. 36, T13N, R9E, UM 9. Plug Back Depth (MD + ND): 13117' MD / 3681' TVD West Sak Oil Pool . 4b. Location of Well (State Base Plane Coordinates): Surface: x- 529306 y- 6008466 Zone- 4 10. Total Depth (MD + ND): , 13180' MD / 3684' ND • 16. Property Designation: ALK 25519 TPI: x- 534139 y- 6011964 Zone- 4 Total Depth: x- 539294 • - 6011316 • Zone- 4 11. SSSV Depth (MD + ND): nipple @ 540' MD / 539' TVD 17. Land Use Permit: 2555 18. Directional Survey: Yes Q No ^ (Submit electronic and printed information per 20 AAC 25.050) 19. Water Depth, if Offshore: N/A (ft MSL) 20. Thickness of Permafrost (ND): approx. 1654' TVD . 21. Logs Obtained (List all logs here and submit electronic and printed information per 20 AAC 25.071): GRlRES, USIT 22. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTH ND HOLE TI CORD G AMOUNT CASING SIZE WT. PER FT. GRADE TOP BOTTOM TOP BOTTOM SIZE CEMEN N RE PULLED 20" 154# 43' 160' 43' 160' 42" 436 sx AS I 13.375" 68# L-80 43' 3070' 43' 2223' 16" 702 sx AS Lite, 225 sx AS II 9.625" 40# L-80 40' 8016' 40' 3575' 12.25" 540 sx DeepCRETE 3.5" 9.2# L-80 7348' 13150' 3495' 3683' 6.75" screens /blank 23. Open to production or injection? Yes o If Yes, list each 24. TUBING RECORD Interval open (MD+ND of Top & Bottom; Perforation Size and Number): SIZE DEPTH SET (MD) PACKER SET 8208'-8239' MD 3580'-3584' ND 12460'- 12491' MD 3655'-3656' 3.5" 7302' 7201' 8654'-8685' MD 3588'-3589' ND 9253'-9285' MD 3599'-3600' ND 13056'-13087' MD 3679'-3681' 25. ACID, FRACTURE, CEMENT SQUEEZE, ETC. 9733'-9765' MD 3604'-3604' ND DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED 10267'-10298' MD 3604'-3606' ND na 10743'-10774' MD 3614'-3614' TV 11221'-11252' MD 3623'-3623' NI 11819'-11851' MD 3631'-3632' TV 26. PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) waiting to be brought on-line Date of Test Hours Tested Production for Test Period --> OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO Flow Tubing Casing Pressure Calculated 24-Hour Rate -> OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY - APl (corr) 27. CORE DATA Conventional Core(s) Acquired? Yes No Q Sidewall Cores Acquired? Yes ^ No Q • If Yes to either question, list formations and intervals cored (MD+ND of top and bottom of each), and summarize lithology and presence of oil, gas or water (Submit separate sheets with this form, if needed). Submit detailed descriptions, core chips, photographs and laboratory analytical results per 20 AAC 25.071. "` ,~~,~ - ~R27•~t /Z. y NONE tt ~ r~~'1 t Form 10-407 Revised 2/2007 AFL ~E~ ~ :.:. L~oG CONTINUED ON REVERSE SIDE ~'~ ~'Z~Y' 28. GEOLOGIC MARKERS (List all formations and markers encountered): 29. FORMATION TESTS NAME MD TVD Well tested? Yes ~ No , If yes, list intervals and formations tested, Permafrost -Top ground surface ground surface briefly summarizing test results. Attach separate sheets to this form, if Permafrost -Bottom 1891' (est) 1654' (est) needed, and submit detailed test information per 20 AAC 25.071. Ugnu C 4600' 2731' Ugnu B 5878' 3136' Ugnu A 6226' 3259' N sand 6760' 3400' K-13 6882' 3422' West Sak D 7280' 3483' West Sak C 7558' 3528' West Sak B 7958' 3570' N/A Formation at total depth: West Sak B 30. LIST OF ATTACHMENTS Summary of Daily Operations, Directional Survey nnis Hartwig @ 265-6862 31. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: ~ Printed Name Chi Ivord Title: Alaska Drilling Manager l~L; ro'[ Date Ph Si ') ^ t one gna ure i ~,~ ` ~ LQ INSTRUCTIONS 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. Submit a well. schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. Item 1a: Classification of Service wells: Gas injection, water injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 4b: TPI (Top of Producing Interval). Item 8: The Kelly Bushing and Ground level elevations in feet above mean sea level. 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: Report true vertical thickness of permafrost in Box 20. Provide MD and TVD for the top and base of permafrost in Box 28. 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, or Other (explain). Item 27: Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Submit detailed description and analytical laboratory information required by 20 AAC 25.071. Item 29: Provide a list of intervals tested and the corresponding formation, and a brief summary of this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Form 10-407 Revised 2/2007 !_ .J Conoco'hiflps Time Log & Summary LNelNfew web RepoKing Report Well Name: 3K-108 Rig. Name: DOYON 15 Job Type: DRILLING ORIGINAL Rig Accept: 9/4/2008 9:00:00 AM Rig Release: 9/22/2008 6:00:00 AM Time Logs _____ _ Date From To Dur S. De th E. De th Phase Code Subcode T Comment __ 9/03/2008 2a hr summary Finsihed operations on 3K-09A, moving to 3K-108 20:00 00:00 4.00 0 0 MIRU DRILL RURD P RD Rock Washer and moved same, prepped drilling module for moving, performed PJSM prior to skidding the floor, raised stompers, moved mats, prepped and moved pits, moved sub off of 3k-09A+ 9!04/2008 Continued moving sub to 3K-108, lowered stompers, spotted pits, skid floor and secure same, bermed around rig, spotted rock washer, connected flow line, connected mud lines, choke and water lines, accepted rig at 09:00 hrs, 9/4/08, re ared to PU 5"drill i e, 00:00 03:15 3.25 0 0 MIRU MOVE MOB P Continued moving sub and spotted over 3K-108, lowered stompers and spotted pits, skid floor and secured same 03:15 09:00 5.75 0 0 MIRU MOVE PSIT P Bermed around rig, RU beaver slide and lay herculite for rock washer, RU steam and H2O to rig, spotted rock washer, finished berming up around rock washer, connected mud lines, choke line and water lines, accepted ri 09:00 hrs 9/3/08 09:00 14:00 5.00 0 0 MIRU MOVE PSIT P Installed surface riser and drip pan, installed diverter line, hooked up accumulator lines to bag and knife valve 14:00 16:00 2.00 0 0 MIRU DRILL PULD P Changed out saver sub on top drive to a 4 1/2" IF pin, loaded shed with BHA and 144 'oints of 5" drill i e 16:00 16:45 0.75 0 0 MIRU DRILL SFTY P Held PJSM for running 5" drill pipe and hand tools involved 16:45 18:00 1.25 0 0 MIRU DRILL PULD P Started to PU 5"drill pipe and stand back in derrick, 18:00 20:00 2.00 0 0 MIRU DRILL PULD P Started mixing up spud mud while continuin to PU 5"drill i e 20:00 21:00 1.00 0 0 MIRU WELCTt BOPE P PU one stand of 5"drill pipe and RIH, tagged at 80 feet, function tested bag and knife blade on diverter as er Lou Grimaldi of the AOGCC. 21:00 00:00 3.00 0 0 MIRU DRILL PULD P Continued to PU a total of 38 stands of 5" drill pipe, PU directional BHA for 16" surface hole at re ort time 9/05/2008 Continued PU 5" drill pipe, MU directional drilling BHA, spudded @ 07:30 hrs 9/6/08, drilling ahead at report time 00:00 02:00 2.00 0 0 MIRU DRILL PULD P Continued PU 5"drill pipe, total of 48 stands in the derrick Pag$ 1 of &5 Time Logs Date From To Dur S De th E. Depth Phase Code __ Subcode T Comment _ 02:00 02:45 0.75 0 0 MIRU DRILL OTHR P Flood conductor and riser and pressure tested surface equipment to 3000 si 02:45 03:30 0.75 0 0 SURFAC DRILL PULD P MU BHA #1 as per the directional driller 03:30 04:00 0.50 0 0 SURFAC DRILL OTHR P RU Halliburton Gyro System 04:00 06:00 2.00 0 0 SURFA( DRILL PULD P Continued PU BHA #1 06:00 09:00 3.00 0 255 SURFAC DRILL DDRL P MU MWD and programmed tool, RIH to 80', spudded well at 07:30 hours 9/5/08, Drilled to 255' MD (255' ND), WO6:7-8K, TO on bottom: 2K, TO off bottom: 2K,GPM:450 w/700 psi, PU Wt: 85K, SO Wt: 85K, Rot. Wt:82K, ART: 1.01, AST:0, ADT: 1.03, 09:00 10:45 1.75 255 255 SURFA( DRILL PULD P POOH from 255' to 68', MU additional DC's, HWDP and jars while runnin back in the hole 10:45 18:00 7.25 255 682 SURFA( DRILL DDRL P Directionally drilled from 255' to 682'MD (682' ND) WOB:18-20K, RPM: 50, TO off btm:5K, TQ on btm:4-5K, GPM: 475 @ 890 psi, PU Wt: 105K, SO Wt:108K, Rot Wt: 110K, ART: 1.05, AST: 2.17, ADT: 3.22 GYRO as needed. 18:00 00:00 6.00 682 1,056 SURFA( DRILL DDRL P Directionally drilled from 682' to 1056' MD (1040' ND), WO6:30K, RPM:50, TQ Off:2-3K, TQ On:5-8K, GPM:550 @ 1260 psi,PU Wt: 110K, SO Wt:: 110K, Rot Wt: 110K, ART: .5, ASTL: 2.2, ADT: 2,7 9/06/2008 Directionally drilled to 2,443' MDTD (2,010' ND) 00:00 06:00 6.00 1,056 1,493 SURFA( DRILL DDRL P Directionally drilled from 1056' to 1493' MD, (1409' ND), WOB:30K, RPM:50, TQ Off:3K, TQ on:8K, GPM:550 @ 1530 psi, PU Wt: 130K, SO Wt: 112K, Rot Wt: 118K, ART: .53 hrs, AST: 2.4 hrs, ADT: 2.93 hrs 06:00 12:00 6.00 1,493 1,815 SURFA( DRILL DDRL P Directionally drilled from 1493' to 1815' MD (1650' ND), WO6:30K, RPM: 50, TQ Off: 3-6K, TQ On: 7-8K, GPM: 652 @ 1620 psi, PU Wt: 125K, SO Wt: 115K, Rot Wt: 120K, ART:.18 hrs, AST: 3.0 hrs, ADT: 3.18 hrs 12:00 18:00 6.00 1,815 2,158 SURFA( DRILL DDRL P Directionally drilled from 1815' to 2158' MD, (1857' ND), WOB: 30K, RPM: 50, TQ Off: 3-6K, TQ On: 7-8K, GPM: 652 @ 1790 psi, PU Wt: 135K, SO Wt: 118K, Rot Wt: 120K, ART:.63 hrs, AST: 1.82 hrs, ADT: 2.45 hrs ~'~a 2 €~f 6* 1 J i TimeLogs __ ___ _ T Comment . De th E. De th Ph e Code Su6code Date From To Dur S 18:00 19:30 1.50 _ 2,158 2,158 SURFA( DRILL _ CIRC ~ P Rotated and reciprocated while circulating bottoms up prior to backreaming out of hole, pumping high vis sweep at 710 gpm at report time 19:30 00:00 4.50 2,158 2,443 SURFA( DRILL DDRL P Directionally drill from 2158' to 2443' MD (2010'TVD), WOB: 25-30K, RPM: 50, TO Off: 6K, TQ On: 10K, GPM:595 @ 1870 psi„ PU Wt: 145K, SO Wt: 118, Rot Wt: 125K, ART:.58 hrs, AST:.75 hrs, ADT: 1.46 hrs 9/07/2008 Directional drilled to TD (3,082') CBU, BROOH, Lay down BHA, R/U Tesco casing running tool, RIH w/ 2,150' of 13 3/8 "casing. Run into a bridge or dog leg. Attempted to work casing shoe thru it, could not make any hole. 00:00 04:30 4.50 2,443 3,082 SURFA( DRILL DDRL P Continue directional drilling 16" surface hole fr MD 2,226' TVD (T.D.), WOB = 15K, RPM = 50, TO. OFF= 6-7 K FT. LBS, TQ. ON = 10 - 15 K FT. LBS, GPM = 600, PSI. ON = 1,820, PSI. OFF = 1,610, Flow out = 37%, UWT = 150 K, SLK WT = 128 K, ROT WT. = 128 K, Total bit hours = 20.72, Jar hrs.= 19.42, ART= 1.71, AST .75, ADT = 2.46 04:30 07:15 2.75 3,082 3,082 SURFA( DRILL CIRC P ROT. & Recip. while pumping high vis. sweep from 3,082' MD. to 3,014' w/ GPM = 750, PSI. OFF 2,140', RPM = 60, TQ OFF = 7-8 K FT. LBS, Flow out 43 %. 07:15 11:30 4.25 3,082 828 SURFA( DRILL REAM P Back ream out of the hole from 3,082' to 852' MD/ UP WT.= 115 K, Down WT. = 100 K w/ 750 GPM/ Flow out = 40 %/RPM = 60/ TO = 7-8 K/ PSI. = 1,950,/ Slow down @ 1950' to 450 GPM, 26% flow out, 910 si., 60 RPM, 4-5 TO. 11:30 12:00 0.50 828 352 SURFA( DRILL TRIP P POH w/elevators from 828' MD to 352' MD, UP WT = 95 K, DN WT = 95 K. 12:00 12:45 0.75 352 70 SURFA( DRILL TRIP P POH w/ BHA from 352' MD to 70' MD HWDP, Jars, drill collars 12:45 13:00 0.25 70 70 SURFA( DRILL DHEQ P Plug into MWD download same. 13:00 13:30 0.50 70 0 SURFA( DRILL TRIP P POH w/ BHA/ 70' Lay down MWD, Motor, Bit. 12.25 bbl. loss on tri . 13:30 14:00 0.50 0 0 SURFA( DRILL RURD P Clear and clean rig floor. 14:00 14:30 0.50 0 0 SURFA( DRILL SFTY P PJSM for rigging up Tesco casing.. running tool, and P/U 13 3/8" 68 ppf L -80 BTC casin . 14:30 16:00 1.50 0 0 SURFA( CASING RURD P R/U Tesco handling equipment. 16:00 22:45 6.75 0 2,158 SURFA( CASING RNCS P Run 13 3/8" casing, filling every 5 joints and monitor displacement, pipe uit oin 2 158' MD, PU WT.= 220 K S/O WT. I~~~ ~ ~~ ss ~~ Time Logs _ Date From To Dur S. De th E. De th Ph se Code_ Subcod_e T Comment 22:45 00:00 1.25 2,158 2,158 SURFA( CASING RNCS T Work pipe while CBU @ 6.5 BPM, 170 psi. Flow out = 30 % ,continue to work i e down. 9/08/2008 Continue jetting and driving casing @ 2,150', pump a 12 ppg pill in casing, POOH w/ casing . RIH w/ BHA #2, wi a and ream from 2,000' to 2,200', worked host reamer thru area where casin sto ed. 00:00 05:15 5.25 2,158 2,158 SURFA( CASING DRVE T Continue to work casing down thru obstruction, jetting w/ pumps from 6 BPM to 20 BPM 320 si. 05:15 05:30 0.25 2,158 2,158 SURFAC CASING CIRC T Pump a 60 bbl. 12 ppg pill. 05:30 06:00 0.50 2,158 2,158 SURFAC CASING OTHR T R/U to UD 13 3/8" casin 06:00 08:00 2.00 2,158 2,065 SURFA( CASING RNCS T POOH from 2,158' to 2'065' w/ UP WT.= 220 K, DN WT.= 150 K, RIH from 2065' to 2150' MD w/ UP WT.= 220 K, DN WT.= 150 K. 08:00 18:30 10.50 2,065 0 SURFA( CASING RNCS T POOH w/ 13 3/8" casing 68 oof. L-80. B .from 2,158' monitor hole on trip tank. Cut and la down shoe 'oint. 18:30 19:15 0.75 0 0 SURFA( CASING RURD T R/D esco and clean floor. 19:15 00:00 4.75 0 1,976 SURFA( DRILL REAM T P!U BHA #2 for wi er run, upload MWD and shallow test same. RIH to 1, 976' 9/09/2008 TIH with cleanout 16" assembly, back ream w/Ghost reamer, POOH and UD BHA, Run 13 3/8" casing and land out 3,069' Bottom of float shoe. 42.7 RKB to load shoulder. 00:00 00:30 0.50 1,976 2,450 SURFA( DRILL TRIP T Continue to TIH from 1,976' to 2,450', slight obstuction @ 2,100 to 2,158' MD, 10 K 00:30 02:00 1.50 2,450 2,350 SURFA( DRILL REAM T Back ream from 2450' MD to 2,350' MD, which put 16" Ghost reamer in suspect area. RPM = 60, TO = 6 K, GPM = 740, psi. = 2,250, flow out = 42% 02:00 02:30 0.50 2,350 3,082 SURFA( DRILL REAM T TIH on elevators from 2,450' to 3,082' hole slick 02:30 02:45 0.25 3,082 3,082 SURFA( DRILL REAM T Monitor well (static) 02:45 06:00 3.25 3,082 1,880 SURFA( DRILL REAM T Pump 57 bbl. sweep (wt= 9.35 ppg.,Vis - 260) BROOH from 3,082 MD to 1,880'MD @ 650 GPM, 1,920 PSI. Flow = 37%, RPM =60, TQ = 7-8 K, PU WT.=140 K, SO WT. _ ' 115 K 06:00 07:30 1.50 1,880 355 SURFA( DRILL TRIP T POOH on elevators from 1,880' MD to 355', Monitor hole on tri tank. 07:30 08:00 0.50 355 0 SURFA( DRILL PULD T Clear floor R/U rack back & UD BHA, Monitor hole on tri tank. 08:00 08:15 0.25 0 0 SURFA( DRILL SFTY T PJSM for UD BHA w/ DD& MWD Re .Monitor hole on tri tank. 08:15 10:15 2.00 0 0 SURFA( DRILL PULD T UD BHA w/MWD rep.from 355' MD Moitor hole on tri tank. 10:15 10:45 0.50 0 0 SURFA( DRILL PULD T R/D 5" handling equipment & short bails. Monitor hole on tri tank. 10:45 11:00 0.25 0 0 SURFA( CASING RNCS T PJSM on R/U Tesco casing running tool as per Tesco rep. Monitor hole on tri tank. age 4 of S Time Logs _ _ ~i T Comment i De th Phase Code Subcode From To Dur S De th E. Date _____ 11:00 _ 11:30 0.50 0 _ 0 SURFA( CASING _ RURD T M/U Tesco casing running tool. 11:30 12:45 1.25 0 0 SURFA( CASING RURD T Bring centralizer to the floor, R/U ton s & do collar for 13 3/8" 12:45 13:00 0.25 0 0 SURFA( CASING SFTY T PJSM for TIH w/ 13 3/8" L-80 - 68 ppf surface casing w/ Tesco rep. Monitor hole on tri tank. 13:00 19:00 6.00 0 2,158 SURFA( CASING RNCS T TIH w/ 13 3/8" casin Monitoring fill every 5 joints and up and down weights and chart same. Casing went thru led a or do le fine. 19:00 21:00 2.00 2,158 3,082 SURFA( CASING RNCS P TIH w/ 13 3/8" casing Monitoring fill every 5 joints and up and down wei hts and chart same. 21:00 22:45 1.75 3,082 3,082 SURFA( CASING RNCS P M/U hanger & landing joint circulate down and space out landing ring @ 42.7 RKB. Recip & circulate while ri in down Tesco rennin tool. 22:45 00:00 1.25 3,082 3,082 SURFA( CASING RNCS P Load plugs in cement head and R/U cementers while circulating and conditionin mud. 9/10/2008 Condition mud to cement 13 3/8 casing, pump 786 bbls. of Arcticset II cement, displace cement w/ rig pump getting 100 bbls. excess cement back. Nipple down deverter and nipple up ROPE and test. AOGCC waived witness b John Cris . 00:00 00:30 0.50 3,069 3,069 SURFA( CEMEN" PULD P R/U cemant head. 00:30 03:30 3.00 3,069 3,040 SURFA( CEMEN" CIRC P Continue to circulate and condition mud, Thin back mud to 15 yield point and dropped the weight to 9.6. reci rocate i e 30' while circulatin . 03:30 03:45 0.25 3,040 3,069 SURFA( CEMEN" SFTY P PJSM w/ cementers / DDI /truck drivers and CPAI Re s. 03:45 04:00 0.25 3,069 3,069 SURFA( CEMEN" SFEO P Pump 10 bbls. of chemical wash, test lines to 3,000 si. 04:00 06:45 2.75 3,069 3,069 SURFA( CEMEN" SOEZ P Pumped 65 bbls chemical wash, containing CW 100 and D185 dispersant for low temperatures, MO45 antifoaming agent, DO47 antifoam DO46 all purpose anti foam D46. Pumped 76 bbls. D970- MUDPUSH II Fresh water based spacer w/ 2 gals.of red cement marker dye. Dropped bottom plug, pump 560 bbls.10.7 702 sks .of ARCS TICSFT ~ ~+~ ~ ~~~1 ^smPnt 6809) followed by 99 bbls. 225 sks of ARCTICSET II 12 .tail cement. Reciprocate casing until 93 bbls. of cement went around the shoe, became sticky. Landed casing in load shoulder. Page v €~f 65 i Time Lo s _ Date From To Dur S. De th E. De th Ph e Code Subcode T Comment 06:45 08:15 1.50 3,069 3,069 SURFAC CEMEN" DISP P _ Pumped 20 bbls of water followed by 423 bbls. of 9.6 ppg. mud displaced w/ rig pumps @ 7 BPM, plug bumped on calculated strokes - 4,233. Slow down pump rate to 3 BPM, 400 psi. Pressure up to 500 _ psi. held for 5 mins. Check floatsl ood 08:15 09:45 1.50 3,069 3,069 SURFA( CEMEN" PULD P R/D elevators, bails & cement head, blow down lines, R/D cementers, clean its. 09:45 13:00 3.25 3,069 3,069 SURFAC WELCTL NUND P N/D diverter equipment, continue to clean its, clean foor dri an. 13:00 14:30 1.50 3,069 3,069 SURFA( WELCTL ROPE P N/U wellead and test connection to 250 si. low and 5,000 si. hi h. 14:30 16:00 1.50 3,069 3,069 SURFAC WELCTL BOPE P N/U BOPE 16:00 16:15 0.25 3,069 3,069 SURFA( MOVE SFTY P PJSM on skidding rig floor. 16:15 18:00 1.75 3,069 3,069 SURFA( MOVE PSIT P Skid floor over the hole 5" to center u i e. 18:00 22:00 4.00 3,069 3,069 SURFA( WELCTL BOPE P N/U BOPE, C/O 2 7/8" rams w/ 9 5/8" 22:00 23:00 1.00 3,069 3,069 SURFAC WELCTL BOPE P R/U BPOE test equipment, upper & lower wear bushings, running tool & set lu s, 4" test'oint. 23:00 00:00 1.00 3,069 3,069 SURFA( WELCTL BOPE P Swap upper and lower pipe rams. U er = 9 5/8", lower = 3 1 /2" x 6" 9/11/2008 Finished w/ ROPE test, RIH w/ BOT reverse basket, cut drlg line, continue in the hole, CBU, test casing to 3,000 si. ood Wash over fish washer POOH w/ fish. P/U drillin assembl . 00:00 00:15 0.25 SURFAC WELCTL BOPE P Continue to swap upper and lower rams, clean its. 00:15 01:00 0.75 SURFAC WELCTL ROPE P Fill surface equipment to test. 01:00 06:00 5.00 SURFAC WELCTL BOPE P Test BOPE (Witness of test waived by AOGCC inspector John Crisp) Tested - 4", 5" and 9 5/8" rams 250 si. low and 3000 si. hi h 06:00 12:00 6.00 SURFAC WELCTL BOPE P Continue to test BOPE to 250 psi. low and 3,000 si. hi h.test H dril 12:00 13:00 1.00 SURFAC WELCTL BOPE P Preform a Koomey draw down 3,050 psi. starting pressure, 1,500 psi, functioned w/ bottles only, 55 seconds for the first 200 psi, build up w /elctreic pump only, 3 min. 28 sec. to build to 3050 psi w/electric pump and air pumps, 5 bottle average= 2,450 psi. With 9 5/8" test joint, test 9 5!8" upper pipe rams, test choke and kill HCR. 13:00 13:30 0.50 SURFAC WELCTL BOPE P Pull test plug/ joint & R/D test equipment. Blow down choke lines to stack & poor boy, Blow down lines on stack. 13:30 14:00 0.50 SURFAC WELCTL BOPE P Install wear bushing and run in lock down screws 14:00 14:15 0.25 SURFA( FISH SFTY P PJSM for making up fish BHA. l~~c~c~ 6 ~sf 55 • i Time Logs _ _. _ __ !Date From To Dur S___D_ epth E. De th Phase Code Subcod_ e, T Comment ___ _ _ „ 14:15 16:30 2.25 SURFA( FISH PULD T Make up reverse basket BHA w/ Baker rep. TIH to 942' MD monitor hole on tri tank. 16:30 17:00 0.50 SURFA( FISH PULD T TIH pick up DP on elevators w/ BHA # 3 as er BOT re .from 942' to 13 17:00 17:15 0.25 0 SURFA( RIGMNT SFTY T PJSM on cutting drilling line 17:15 19:45 2.50 1,323 1,323 SURFA( RIGMNT RGRP T Cut 143' w/ 17 wraps and slip the same, monitor hole on trip tank. Service top drive, blocks, drawworks & ease crown. 19:45 21:30 1.75 1,323 2,973 SURFA( FISH TRIP T TIH on elevators from pipe shed w/ BHA # 3 from 1,323' MD to 2973' MD Monitor well on tri tank. 21:30 22:45 1.25 2,973 2,973 SURFA( CASING CIRC T CBU to balance mud for casin test @ 2,973' MD- 10 BPM, 790 psi. flow = 37% total stks. = 8300 22:45 00:00 1.25 2,973 2,973 SURFAt CASING DHEQ T Blow down top drive and rig up test um ,test casin to 3,000 si. 9/12/2008 RIH w/ BHA # 4 drill float equipment out, change mud system to 8.8 ppg. LSND, preform LOT = 12.9 ppg. EMW.Drill ahead 3 699' 00:00 00:30 0.50 2,973 2,973 SURFA( CASING DHEQ T Continue to test 13 3/8" casing to_ 3,000 si. for 30 mins. 00:30 00:45 0.25 2,973 2,973 SURFA( CASING DHEO T R/D test equipment 00:45 01:00 0.25 2,973 2,982 SURFA( FISH WASH T P/U a single F/shed, drop a 1"ball @ 5 bpm, 280 psi. flow = 25%, stage up 775 BPM 2,760 psi. flow, 48% ROT =125K, RPM =50, TO =7 K 01:00 01:30 0.50 2,982 2,982 SURFA( FISH WASH T Continue to wash over fish as per Baker fisherman, tagged plug @ 9982' M D 01:30 03:15 1.75 2,982 25 SURFA( FISH TRIP T Blow down top drive, POOH on elevators from 2,982' 03:15 04:45 1.50 25 0 SURFA( FISH TRIP T UD fishing BHA Caught fish- (41/2" x 1/2 "washer. MD 04:45 05:00 0.25 0 0 SURFA( DRILL PULD P Clean and clear floor 05:00 07:15 2.25 0 SURFA( DRILL CIRC P P1U BHA # 4 as per D.D. to 82' monitor hole on tri tank. 07:15 07:45 0.50 80 80 SURFA( DRILL TRIP P POOH to 60' upload MWD, TIH back to 80' MD 07:45 09:30 1.75 80 368 SURFA( DRILL TRIP P Continue to M/U BHA # 4, TIH to 368' shallow test MWD 09:30 11:00 1.50 368 2,937 SURFA( DRILL TRIP P TIH from 368' to 2,937' MD, P/U WT= 138 K, S/O WT. =100 K, RT WT = 128K, flow out = 42 % and 1630 si. 11:00 11:15 0.25 2,937 2,997 SURFA( DRILL REAM P ROT & wash in hole from 2,937' MD, to 2,979' 11:15 12:00 0.75 2,997 3,032 SURFA( CEMEN" DRLG P Drill float a ui ment & shoe trac from 2,979' to 3,032' MD, WOB = 2-6 K RPM =50, TO OFF = 7-10 K FT lbs. ON = 9-10 K ft lbs., GPM = 660, PSI. ON = 1,810', PSI. OFF =1,740', Flow out = 44 %, PU WT =160 K, S/0 WT.= 105 K, ROT WT =128 K ECD = 9.58 p;~t~~, ~ ~f 65 Time Logs _ _ Date From To Dur S. De th E. De th Phase Code Subcode T Comment 12:00 14:45 2.75 3,032 3,082 SURFA( CEMEN" DRLG P Drill float equipment & shoe track from 3,032' to 3,082' MD, WOB = 2-6 K RPM =50, TQ OFF = 7-10 K FT lbs. ON = 9-10 K ft lbs., GPM = 660, PSI. ON = 1,810', PSI. OFF =1,740', Flow out = 44 %, PU WT =160 K, S/0 WT.= 105 K, ROT WT =128 K ECD = 9.58 14:45 15:00 0.25 3,082 3,102 SURFA( DRILL DDRL P Directional drill intermediate from 3,082' to 3,102' MD, WOB = 2-8 K RPM =80, TO OFF = 7-8 K FT lbs. ON = 6-10 K ft lbs., GPM = 850, PSI. ON = 2,600', PSI. OFF =2,580', Flow out = 49 %, PU WT =158 K, S/0 WT.= 108 K, ROT WT =130 K ECD = 9.72, Bit hrs.=.12, Jar hrs. _ 19.51, ART =.12, AST = 0, ADT = .12 15:00 16:00 1.00 3,102 3,102 SURFA( DRILL CIRC P ROT & Recip. from 3,102' MD to 3 032' MD while dis lacing well to 8.8 . LSDN. GPM = 845. PSI. OFF= 1,970, RPM = 50, TQ OFF = 7-9 K, Floe out = 50 %, Pumped 8,037 strokes. 16:00 17:00 1.00 3,102 3,102 SURFA( DRILL TRIP P POOH on elevators from 3,102' MD & R/U for leak off test. P/U WT = 160 K, S/O WT = 110 K RT WT = 130 K. 17:00 19:00 2.00 3,102 3,102 SURFA( DRILL LOT P Preform a LOT as per CPAI, test MW= 8.8 ppg. /Leak off pressure = 475, EMW =12.9 ppg. and R/D test e ui ment. 19:00 19:15 0.25 3,102 3,102 INTRM1 DRILL CIRC P Obtain drilling parameters, Tag bottom 3,102' MD 19:15 00:00 4.75 3,102 3,699 INTRM1 DRILL DDRL P Directional drill ahead from 3,1.02'to 3,699' MD, 2,437' TVD. GPM =800. PSI. =1,930, SPM =190, RPM = 100, TO ON=10 K,TQOFF=7K, ROT WT = 130 K, S/O WT = 112 K, P/U WT = 158 K Gas units = 58, ECD's = 9.17, Bit hrs. = 2.25, Jar hrs. = 21.76, ART = 1.51, ADT = 2.25 SPR's @ 3,509' MD, SPM/PSI. _ #1 =20/130, 30/160, # 2 = 20/120, 30/160 9/13/2008 Directional drill 12 1/4 intermediate hole from 3,699' to 5,983' 00:00 06:00 6.00 3,699 4,270 INTRM1 DRILL DDRL P Continue directional drill ahead from 3,699' MD to 4,270' MD, GPM =790, PSI. = 2,010, SPM = 190, RPM = 100, TO ON = TO OFF = 8 K, TO ON=10 K, ROT WT.=130 K, DN WT. = 112 K, UP WT. =158 K, Gas uints = 58, ECD's = 9.37, BIT hrs. _ 5.15, Jar hrs. = 24.54, AST = 2.58, ART = 2.57, ADT = 5.15 raga 8 of 6S • Time Logs Date From To D ur S De th E. De th Phase Code Subcode T Comment 06:00 12:00 __ 6.00 4,270 4,841 INTRM1 DRILL DDRL P _ Continue directional drill ahead from 4,270' MD to 4,841' MD, 2800 TVD, GPM =700, PSI. = 1,880 ON, PSI.ON=1820, SPM = 100, RPM = 100, TO ON =11 K TQ OFF = 8-9 K, ROT WT. = 140 K, DN WT. = 112 K, UP WT. =170 K, Gas uints = 58, ECD's = 9.50, BIT hrs. = 7.78, Jar hrs. = 27.26, AST = .62, ART = 2.57, ADT = 2.72 12:00 16:45 4.75 4,841 5,508 INTRM1 DRILL DDRL P Continue directional drill ahead from 4,841' MD to 5,508' MD, 3,009' TVD, GPM =700, PSI.OFF = 2,200 ON, PSI.ON= 2,360, SPM = 100, RPM = 100, TO ON =11 K TQ OFF = 8-9 K, ROT WT.=142 K,DNWT.=118 K, UP WT. =180 K, Gas uints = 58, ECD's = 9.70, BIT hrs. = 10.39, Jar hrs. = 29.78, AST = .15, ART =2.37, ADT = 252 16:45 17:30 0.75 5,508 5,508 INTRM1 DRILL CIRC P ROT& RECIP. while circulating a 36 bbl. High vis. sweep from 5,508' MD to 5410' MD, GPM = 750, PSI OFF = 2 200, RPM = 100, TQ OFF 9 K, Floe out = 38 %, UP WT. = 180 K, S/O WT.= 118K, RT WT.= 142 K. Pumped 13,418', moderate increase in cuttings, ECD prior to pumping sweep = 9,70 ppg/ ECD w/ sweep out of hole = 9.37 17:30 18:00 0.50 5,508 5,545 INTRM1 DRILL DDRL P Continue directional drill intermediate 12 1/4" hole from 5,508' MD to 5,545' MD, 3,022' TVD, WT on Bit =10K, GPM =750, PSI.ON =2,030, PSI.OFF = 1900, SPM = 100, RPM = 100, TQ OFF = 10 K, TQ ON = 11 K, ROT WT. = 142 K, DN WT. = 120 K, UP WT.=183 K, Gas uints = 63, ECD's = 9.53 ppg, BIT hrs. = 10.78, Jar hrs. =30.17, AST = .39, ART = 0, ADT = .39 18:00 00:00 6.00 5,545 5,983 INTRM1 DRILL DDRL P Continue directional drill intermediate 12 1.4 hole from 5,545' MD to 5,983' MD, 3,172' TVD, WT on Bit =20 K, GPM =750, PSI.ON =2,210, PSI.OFF = 1890', SPM = 100, Flow out = 38 %, RPM = 100, TQOFF=13 K, TO ON=12 K, ROT WT.=150 K,DNWT'.=123 K, UP WT.=200 K, Gas uints = 63, ECD's = 9.49 ppg, BIT hrs. =13.52, Jar hrs. =32.91,AST=5.41,ART=8.11, ADT = 13.52 9/14/2008 Drilling from 5,983' to 6,332', sweep hole and circulate out, BROOH to 5,129' due to slow ROP, TIH shot surve s, from 6,144' to 6,294' MD,drill ahead to 7,146' ~ m ~ l I Time Logs _ _ Date _ From To Dur S De th E. De th Phase Code Subcode T Comment 00:00 05:45 5.75 5,983 6,332 INTRM1 DRILL DDRL P Continue directional drill intermediate 12 1/4 hole from 5,983' MD to 6,332' MD, 3,292' TVD, WT on Bit =20 K, GPM =750, PSI.ON =2260, PSI.OFF = 2,060', SPM = 100, Flow out = 38 %, RPM = 100, TO OFF=17 K,TQON=12-15K, ROT WT. = 150 K, DN WT. = 114 K, UP WT.= 217 K, Gas uints = 69, ECD's = 9.38 ppg, BIT hrs. =16.61, Jar hrs. = 36.61, AST = 2.75, ART = .34, ADT = 3.09. SPR's @ 5,601' #1 MP/ 20 SPM = 160/ 30 = 190 psi. # 2 MP/ 20 SPM 160 psi./ 30 SPM = 190 psi. 05:45 06:00 0.25 6,332 6,332 INTRM1 DRILL CIRC P ROT &Circ. pumped a 50 bbl. sweep (9 9.6 ppg / 250 vis.) 838 Gpm, 2,350 PSI.42 % flow out, 120 RPM, 10 -17 K. TQ. 06:00 06:45 0.75 6,332 6,332 INTRM1 DRILL CIRC P ROT &Circ. While circulating high vis sweep from 6,332' to 6,227' MD GPM = 830 psi. PSI. OFF = 2,330, RPM = 120, TQ OFF = 12-18 K, Flow out = 42 %, UP WT = 205 K, S/O WT = 118, TR WT = 152 K, Pum 11,585 SKS. 06:45 07:00 0.25 6,332 6,332 INTRM1 DRILL CIRC P Obtain SPR @ 6,330' 07:00 10:00 3.00 6,332 5,129 INTRMI DRILL REAM P BOOH. Due to slow ROP from 6,267' to 5,129' MD GPM. PSI.= 2,110, RPM = 100, TO OFF = 11-18, Flow out = 40 %, P/U WT.= 200 K, S/O WT. = 108 K, RT WT. = 142 K, 10:00 11:45 1.75 5,129 6,332 INTRMI DRILL TRIP P TIH from 5,129' MD to 6,332' MD, shot deviation surveys @ 6,144' MD, 6,194' MD, 6,294' @ 6,294' MD, P/U WT.= 200 K , S/O WT. 108 k, RT WT.= 142 K. 11:45 12:00 0.25 6,332 6,340 INTRM1 DRILL DDRL P Continue directional drill intermediate 12 1/4" hole from 6,322' MD to 6340' MD, 3,295' TVD, WT on Bit =20 K, GPM = 800, PSI.ON = 2,360', PSI.OFF = 2,150', SPM = 100, Flow out = 40 %, RPM = 100, TO OFF=17 K,TQON=15-20K, ROT WT. = 200 K, DN WT. = 115 K, P/U WT.= 200 K, Gas uints = 69, ECD's = 9.43 ppg, BIT hrs. =16.81, Jar hrs. = 36.81, AST = 0, ART = .20, ADT=.20 F~tJe 1tl c~F ~ • Time Logs 'i _ _ __ Date ___ From To _ Dur S De th E. Depth Phase Code Subcode T Comment __ 12:00 18:00 6.00 6,340 6,714 INTRM1 DRILL DDRL P Continue directional drill intermediate 12 1/4 hole from 6,340' MD to 6,714' MD, 3 394' TVD, WT on Bit =25 K, GPM = 800, PSI.ON = 2,360', PSI.OFF = 2,150', SPM = 100, Flow out = 40 %, RPM = 100, TO OFF=17 K, TOON=15-18K, ROT WT. = 150 K, DN WT. = 115 K, P/U WT.= 205 K, Gas uints = 69, ECD's = 9.34 ppg, BIT hrs. = 19.84, Jar hrs. = 39.23, AST = 1.89, ART =1.14, ADT= 3.03. 18:00 00:00 6.00 6,714 7,146 INTRM1 DRILL DDRL P Continue directional drill intermediate 12 1/4" hole from 6,714' MD to 7,146' MD, 3,462' TVD, WT on Bit = 25 K, GPM = 800, PSI.ON = 2,380', PSI.OFF = 2,150', SPM = 100, Flow out = 40 %, RPM = 100, TO OFF=13 K, TOON=14-15K, ROT WT. = 150 K, DN WT. = 121 K, P/U WT.= 190 K, Gas uints = 63, ECD's = 9.64 ppg, BIT hrs. =22.71, Jar hrs. = 42.10, AST = 1.5, ART =1.37, ADT= 2.87. 9/15/2008 Drill 12 1/4" hole to 8, 020' TD, Pumped a high vis. sweep BROOH to 6,080' String packed off and lost returns .Worked pipe down the hole slowly, established returns @ 6,800', staged pumps up to 850 BPM, um ed a nut lu / hi h vis. swee to cleanu hole. 00:00 06:00 6.00 7,146 7,500 INTRM1 DRILL DDRL P Continue directional drill intermediate 12 1/4" hole from 7,146' MD to 7,500' MD, 3,519' TVD, WT ON Bit = 15 K, GPM = 790, PSI.ON = 2,510', PSI.OFF = 2,340', SPM = 100, Flow out = 38 %, RPM = 100, TO OFF=I4 K, TO ON=15 K, ROT WT. = 151 K, DN WT. = 121 K, P/U WT.= 193 K, Gas uints = 63, ECD's = 9.77 ppg, BIT hrs. =24.90, Jar hrs. =44.29, AST = .51, ART =1.68, ADT= 2.19. 06:00 12:00 6.00 7,500 7,960 INTRM1 DRILL DDRL P Continue directional drill intermediate 12 1/4" hole from 7,500' MD to 7,960' MD, 3,568' TVD, WT ON Bit = 22 K, GPM = 790, PSI.ON = 2,760', PSI.OFF = 2,650', SPM = 100, Flow out = 40 %, RPM = 100, TQOFF=10 K, TOON=13-14K, ROT WT. = 165 K, DN WT. = 135 K, P/U WT.= 200 K, Gas uints = 63, ECD's = 9.77 ppg, BIT hrs. =28.41, Jar hrs. =47.80, AST = .62, ART =2.89, ADT= 3.51. Page 11 of ~~ l J Time Loys Dat_e_ From To _ Dur S De th E. De th Phase Code Subcode T Comment 12:00 12:30 0.50 7,960 8,020 INTRM1 DRILL DDRL P Continue directional drill intermediate 12 1/4" hole from 7960' MD to 8,020' MD, 3,575' TVD, WT ON Bit = 22 K, GPM = 790, PSI.ON = 2,780', PSI.OFF = 2,760', SPM = 100, Flow out = 40 %, RPM = 100, TO OFF=10 K, TOON=13-14K, ROT WT. = 165 K, DN WT. = 135 K, P!U WT.= 200 K, Gas uints = 40, ECD's = 9.68 ppg, BIT hrs. = 28.41, Jar hrs. = 48.15, AST = ,ART = .35, A DT= 3.51. 12:30 14:30 2.00 8,020 8,020 INTRM1 DRILL CIRC P Pump 60 bbls. sweep (9.6 ppg. 250 vis.) GPM.= 850, PSI. 2,980, flow 40 %, RPM = 120, TQ = 13-14, Circ. total of 21,900 strokes.. 14:30 15:00 0.50 8,020 8,020 INTRM1 DRILL OWFF P Monitor well and obtain SPR's @ 8,020' #1 MP( 20 SPM)= 170 psi. (30 SPM.) = 210 psi. # 2 MP (20 SPM) = 170 psi. (30 SPM) = 210 si. 15:00 18:00 3.00 8,020 6,652 INTRM1 DRILL REAM P BROOH from 8,020' to 6,652' MD, GPM 850, PSI 2,840' PSI. = 2,840', Flow out = 40 %, RPM = 120, TQ =14-25 K, P/U 208 k, S/O WT. = 135 K, ROT = 168 K. 18:00 19:15 1.25 6,652 6,080 INTRM1 DRILL REAM P BROOH from 6,652' to 6,080', pulling string @ 10 feet per min. GPM = 850, PSI. = 2,500, Flow = 40 RPM =120, TQ = 14-15, P/U WT = 193K. Pipe pulled tight and packed off lost returns. 19:15 22:30 3.25 6,080 6,800 INTRM1 DRILL REAM T Lost returns and slack off weight, worked the string down from_6.Il80' to 6,800' w/slow pump and 200 - 500 psi. rpm @ 20. Established returns and slowl sta ed u um s. 22:30 00:00 1.50 6,800 6,840 INTRMI DRILL CIRC P Circulate @ 425 GPM pumping a (9.1 ppg. 250 vis sweep) w/ 15 lbs. per bbl. of medium nut plug. Pumped sweep @ 600 GPM, 1300 psi. P/U WT. and S/O WT. back to normal. 9/16/2008 Continue pumping a nut plug/ high vis. sweep to cleanup hole, recip and rotate 6800 to 6840', RIH to 6900', backream out of the hole pumping 850 gpm w/pulling speed 6' to 10'/min- monitor ECD's and record PU & SO wt's every 5 stands. Once inside of the casing shoe @ 3070', circulate bottom's up (900 gpm) while recip and rotating inside of casing, then pump a 60 bbl sweep (9.2 ppg/ 250+ vis) surface to surface, continue to circulate 6 more bottom's up, monitor well, pump a dry job, drop haggard drill pipe wiper, pull out of the hole on elevators laying down 5"drill pipe to 490'. Hole pulled tight @ 490' (35k overpull), work past obstruction, pull out to 170'- another obstruction, work past, pull out to 77.85' and another obstruction. Try to work past with no change in position of obstruction (12.13" stab @ the seal sub or wear bushing). Try working up to free- no good, run 2 stands in the hole, pickup and obstruction appears alongside of BHA again. Make up remainin BHA #4 to run out the casin shoe. Tri in the hole with BHA #4 to 2083' at midni ht. I~~g® i~ €sf 6~ i Time Logs Date From To Dur S. De th E. De th_ Phase Code Subcode T Comment 00:00 00:30 0.50 6,840 6,840 INTRM1 DRILL CIRC P Continue pumping sweep (9.1 ppg/ 250 vis/ 15 ppb med nut plug) @ 600 GPM, 1300 psi, 32% flow. P/U WT. and S/O WT. back to normal. Rotate 90 r m w/ 14k ft/Ibs of for ue 00:30 00:45 0.25 6,840 6,900 INTRM1 DRILL TRIP P Trip in the hole from 6840' to 6900' on elevators. PU wt 190k, SO 115k, Rot wt 150k. 00:45 06:00 5.25 6,900 5,100 INTRMI DRILL REAM P Continue to backream out of the hole from 6900' to 5100'. Pulling speed 6'-10'/minute as the hole allows. Monitor ECD's and record PU and SO wt's every 5 stands. Pumping 850 gpm w/ 2240 psi 40% flow out. Rotate 120 rpm w/ 12k ft/Ibs of for ue. 06:00 10:00 4.00 5,100 3,035 INTRM1 DRILL REAM P Continue to backream out of the hole from 6900' to 5100'. Pulling speed 6'-10'/minute as the hole allows. Monitor ECD's and record PU and SO wt's every 5 stands. Pumping 850 gpm w/ 2250 psi 41 % flow out. Rotate 120 rpm w/ 15-16k ft/Ibs of for ue. 10:00 13:15 3.25 3,035 3,035 INTRM1 DRILL CIRC P Circulate bottom's up 3035'. Pumping 900 gpm w/ 2030 psi 43% flow. Rotate and recip. Rotate 120 rpm w/ 4-9k ft Ibs of torque. Pumped a total of 31900 strokes (3216 bbls). After pumping a bottom's up a 60 bbl sweep (9.2 ppg/ 250+ vis) was um ed until hole cleaned u . 13:15 13:30 0.25 3,035 3,035 INTRM1 DRILL OWFF P Monitor well, ok. Pump a 15 bbl dry job (11.1 ppg). Install haggard ID pipe wi er in the drill strip . 13:30 15:30 2.00 3,035 490 INTRM1 DRILL TRIP P Pull out of the hole laying down 5" drill pipe.PU wt 145k, SO wt 112k. Monitor well on the tri tank. 15:30 17:30 2.00 490 490 INTRM1 DRILL TRIP T Encounter 35k overpull 490'. Attem t to work thru obstruction. 17:30 18:00 0.50 490 78 INTRM1 DRILL TRIP P PJSM on laying down BHA. Drain stack to watch for the obstruction. Laying odwn the BHA. Another slight overpull @ 170', work up the hole to 78' bit de th. 18:00 18:45 0.75 78 78 INTRM1 DRILL TRIP T Stand back flex collars and attempt to pull through tight spot @ 78'. 30k overpull. Attempt to pull through tight s ot. No o. 18:45 20:45 2.00 78 78 INTRM1 DRILL TRIP T Remove lift sub, make up crossover and then top drive. Attempt to work BHA past tight spot several times, rotating 20 rpm. Stalling out with 13k fUlbs of torque with 20K overpull @ 78'. F~~a~~ 13 of S~ l J Time Logs __ Date_ From To_ Dur _ S. De th E. De th Phase Code Subcode T Corliment 20:45 21:15 0.50 78 275 INTRM1 DRILL TRIP T Trip in the hole to 275' attempting to clear obstruction. Work pipe @ 275' and observed 15k overpull while rotating 20 rpm w/ 1 k ft Ibs of torque. Stalled out, went down and freed up. PU wt 85k, SO wt 85k, Rot wt 85k. 21:15 21:45 0.50 275 78 INTRM1 DRILL TRIP T Pull out of the hole to 78'. Obstruction still at 78' bit depth (This puts the top of the stabilizer blades at the Vetco Gray seal sub (12.375" ID . 21:45 22:00 0.25 78 78 INTRM1 DRILL CIRC T Attempt to work past 78' while pumpng 440 gpm w/ 420 psi. Unable to work ast. 22:00 23:00 1.00 78 371 INTRM1 DRILL PULD T Make up BHA # 4 which was artiall laid down. 23:00 00:00 1.00 371 2,083 INTRM1 DRILL TRIP T Trip in the hole to 2083' at midnight. 9/17/2008 Continue trip in the hole with BHA #4 from 2083' to 3416', circulate bottom's up while rotating/reciprocating from 3416' to 3321', Pull out of the hole to 3321', continue to recip and rotate pipe while circulating a 50 bbl sweep (9.1 ppg/250+ vis), once sweep was to surface, pull out of the hole from 3321' to 2845' (casing shoe @ 3069'), continue to circulate and recip pipe from 2875' to 2750' till hole clean, monitor well- static, pull out of the hole to 77.5' (while tripping noticed overpull of 40k @ 920' and 490'), unable to work past obstruction @ 77.5' (stabilizer top @ Vetco Gray seal sub @ 41.4' RKB). Make up the BHA and pickup drill pipe, while running in the hole to 2750', continue trip in the hole from the derrick to 5602', circulate 320 bbls, continue trip in to TD @ 8020'. Reciprocate/Rotate while pumping a sweep, a total of 1389 bbls was pumped. Monitor well- static. Backream out of the hole to 3798' midni ht. 00:00 01:15 1.25 2,083 3,416 INTRM1 DRILL TRIP T Trip in the hole from 2083' to 3416'. Monitor displacement on the trip tank. 01:15 02:30 1.25 3,416 3,321 INTRM1 DRILL CIRC T Circulate ,recip and rotate. Working pipe from 3416' to 3321'. Pumping 850 gpm w/ 2550 psi, 40% flow. Rotate 120 m w/ 8k ft Ibs of for ue. 02:30 03:15 0.75 3,321 3,226 INTRMI DRILL CIRC T Pull out of the hole a stand. Circulate recip and rotate. Working pipe from 3321' to 3226'. Pump a 50 bbl sweep (9.1 ppg/ 250+ vis). Pumping 850 gpm w/ 2550 psi, 40% flow. Rotate 120 rpm w/ 8k ft Ibs of torque. Circulated a total of 1375 bbls including the first bottom's up prior to um in the swee . 03:15 03:45 0.50 3,226 2,845 INTRMI DRILL TRIP T Pull out of the hole on elevators. Monitor displacement on the trip tank. Pro er fill. 03:45 04:15 0.50 2,845 2,845 INTRM1 DRILL CIRC T Reciprocate/Rotate from 2845' to 2750' (inside of the 13-3/8" casing). Pumping 850 gpm w/ 2100 psi, 40% flow. Rotate 120 rpm w/ 6k ft Ibs of for ue. 04:15 04:30 0.25 2,845 2,845 INTRM1 DRILL OWFF T Monitor well- static. 04:30 06:00 1.50 2,845 846 INTRM1 DRILL TRIP T Pull out of the hole on elevators from 2845' to 846'. Pulled 40k over @ .920'. Slacked off then picked up and __ _ _. got by the obstruction ~ Monitor well on the tri tank. ~,,;_~> ° S ,~f Fib • Time Logs _ Date From To Dur S De th E. Depth_ Phase Code Subcode T Comment 06:00 07:00 1.00 846 490 INTRM1 DRILL TRIP T Pull out of the hole on elevators from 2845' to 846'. Pulled 40k over @ 920'. Slacked off then picked up and got by the obstruction. Monitor well on the tri tank. 07:00 07:45 0.75 490 77 INTRMI DRILL TRIP T Stand back BHA to 77' of BHA still in the hole. The top of the iter ra al blade.. stabilizer to the seal sub 41.40'. 07:45 09:45 2.00 77 77 INTRM1 DRILL TRIP T Try to work up. Pulled 25k over free PU wt. Rotate 30 r m and stalled out when pulled into obstruction .(torque limit set 10k ft Ibs 09:45 12:00 2.25 77 2,750 INTRM1 DRILL TRIP T Make up BHA, then pickup drill pipe from the pipe shed to 2750'. Monitor dis lacement on the tri tank. 12:00 13:15 1.25 2,750 5,062 INTRMI DRILL TRIP T Continue trip in the hole from the. derrick to 5062'. Monitor dis lacement on the tri tank. 13:15 14:00 0.75 5,062 5,062 INTRMI DRILL CIRC T Circulate and reciprocate pipe @ 5062'. Pumping 850 gpm w/ 2240 psi 40% flow. Rotate 100 rpm w/ 10k ft Ibs of troque. Pump a total of 320 bbls.No gains or losses. PU wt 175k, SO wt 108k. 14:00 15:00 1.00 5,062 8,020 INTRM1 DRILL TRIP T Continue trip in the hole to TD 8020'. Monitor well on the trip tank. Dis lacement correct. 15:00 17:30 2.50 8,020 8,020 INTRM1 DRILL CIRC T Reciprocate and work pipe from 8020' to 7960'. Circulate 820 gpm w/ 2980 psi 40% flow. Rotate 120 rpm w/ 10-17k ft Ibs of torque. Pump a 60 bbl high vis sweep (9.1 ppg/280 vis). Moderate increase in cuttings. Pumped a total of 1389 bbls. PU wt 140, SO wt 110k, Rot wt 160k. 17:30 17:45 0.25 8,020 8,020 INTRMI DRILL OWFF T Monitor well-- static. 17:45 18:00 0.25 8,020 7,865 INTRM1 DRILL REAM T Backream out of the hole from TD @ 8020'. Pumping 820 gpm w/ 2980 psi 40% flow. Rotate 120 rpm w/ 14-15k ft Ibs of torque. Traveling speed 40'/min. 18:00 00:00 6.00 7,865 3,798 INTRMI DRILL REAM T Continue to backream out of the hole from 7865' to 3798'. Pumping 850 gpm w/ 2900-2250 psi 40% flow. Rotate 120 rpm w/ 14-13k ft Ibs of for ue. Travelin seed 40'/min. 9/18/2008 Backream out of the hole from 3798' to 3036', circulate bottom's up, pump a 50 bbl sweep, then two more bottom's up, monitor well, pullout of the hole to BHA @ 371', monitor well- static, work BHA to 148', drain stack and flush with water, drain again, stand back flex collars, attemt to work through obstruction starting at 81', pull bit to the floor, inspect bit and stabilizers, Lay down BHA #4, download MWD, inspect top drive, pull wear bushing, install test plug, inspect upper and lower ram cavities, test door seals to 250 psi and 3000 psi-OK. Pull test plug, install wear bushing, pickup/make up BHA #5, the add Halliburton 13-3/8" storm packer, RIH to center of element @ 106', test 13-3/8" casing and Vetco Gray MB22A wellhead to 3000 psi-OK, run in to center of element @ 1058', test casing to 1500 psi-OK. Pull out and lay down storm packer. Picku /makeu 6 'oints of 5" drill i e, run in the hole to 1809'. Pane I5 ~f 65 Time Logs Date From To Dur _ S. Degth_ E. De th Phase Code Subcode T _ _ _ Cor7~ment _ 00:00 01:00 1.00 3,798 3,036 INTRMI DRILL REAM T Continue to backream out of the hole from 3798'. Pumping 850 gpm w/ 2250 to 2130 psi 40% flow. Rotate 120 rpm w/ 7k ft Ibs of torque. Travelin seed 40'/min. 01:00 02:30 1.50 3,036 3,036 INTRM1 DRILL CIRC T Circulate and condition mud 3036'. Pumping 850 gpm w/ 2150 psi 40% flow. Rotate 120 rpm w/ 6k ft Ibs of torque. Pump a bottom's up, then a 50 bbf sweep (9.1 ppg/ 300+ vis), circ sweep out of the hole plus 2 more bottom's up. A total of 1620 bbls were circulated. ECD's were 9.47 ppg before and 9.36 ppg after. PU wt 132k , SO wt 128k, Rot wt 132k. 02:30 02:45 0.25 3,036 3,036 INTRM1 DRILL OWFF T Monitor well-- static. 02:45 04:30 1.75 3,036 371 INTRM1 DRILL TRIP T Pull out of the hole on elevators from 3036' from 371'. Hole took 5 bbls over calculated fill. 04:30 04:45 0.25 371 371 INTRM1 DRILL OWFF T Monitor well. Dropping slightly in the stack- a rox .63 b h. 04:45 05:15 0.50 371 148 INTRM1 DRILL TRIP T Work the BHA. Stand back the HWDP and 'ars. Pickup 30' of flex collars. 05:15 06:00 0.75 148 148 INTRM1 DRILL OTHR T Drain the BOP stack. Flush the BOP stack w/ approx 20 bbls of water. Suck the water back out of the stack. 06:00 06:15 0.25 148 85 INTRM1 DRILL TRIP T Stand back the flex drill collars. 06:15 06:30 0.25 85 81 INTRM1 DRILL TRIP T Make up a crossover and 15' pup joint. Continue to pull BHA until ullin a ainst somethin 81'. 06:30 09:15 2.75 81 0 INTRM1 DRILL TRIP T Attempt to work thru obstruction. Worked u to 45' then a eap red to not want to move again. Finally worked throu h the wellhead. 09:15 09:30 0.25 0 0 INTRM1 DRILL OTHR T Inspect stabilizer, motor an it. 09:30 10:15 0.75 0 0 INTRM1 DRILL PULD T Lay down BHA #4. 10:15 11:00 0.75 0 0 INTRM1 DRILL OTHR T Download MWD. Grease crown and ins ect sheaves. 11:00 11:45 0.75 0 0 INTRM1 DRILL PULD T Finish laying down BHA #4. 11:45 12:00 0.25 0 0 INTRM1 RIGMNT SVRG T Inspect the top drive. 12:00 12:30 0.50 0 0 INTRM1 WELCTL OTHR T Pull the Vetco Gray 13-3/8" x 12-5/16" by 59-1/2" ong wear u i - .Set lower test lu . 12:30 13:30 1.00 0 0 INTRM1 WELCTL OTHR T Open up the doors on the upper and lower pipe rams. Inspect the ram cavity's for foreign material- none found. 13:30 14:00 0.50 0 0 INTRM1 WELCTL BOPE T Rig up to test BOP ram door seals. 14:00 15:00 1.00 0 0 INTRM1 WELCTL BOPE T Test door seals on upper and lower i e rams to 250 psi low and 3000 si hi h. OK Time Logs Date From_ To Dur__~_S. Depth E. Depth Phase Code Subcode T Com me nt 9/18/2008 _ _ __ _ za hr summary Backream out of the hole from 3798' to 3036', circulate bottom's up, pump a 50 bbl sweep, then two more bottom's up, monitor well, pullout of the hole to BHA @ 371', monitor well- static, work BHA to 148', drain stack and flush with water, drain again, stand back flex collars, attemt to work through obstruction starting at 81', pull bit to the floor, inspect bit and stabilizers, Lay down BHA #4, download MWD, inspect top drive, pull wear bushing, install test plug, inspect upper and lower ram cavities, test door seals to 250 psi and 3000 psi-OK. Pull test plug,. install wear bushing, pickup/make up BHA #5, the add Halliburton 13-3/8" storm packer, RIH to center of element @ 106', test 13-3/8" casing and Vetco Gray M622A wellhead to 3000 psi-OK, run into center of element @ 1058', test casing to 1500 psi-OK. Pull out and lay down storm packer. Picku /makeu 6 'oints of 5"drill i e, run in the hole to 1809'. 15:00 15:30 0.50 0 0 INTRM1 WELCTL BOPE T Rig down test equipment. 15:30 15:45 0.25 0 0 INTRM1 WELCTL OTHR T Install the Vetco Gray 13-3/8" x 12-5/16" by 59-1/2" long wear bushin . 15:45 16:00 0.25 0 0 INTRM1 DRILL PULD T Bring tools to the floor for BHA #5 Cleanout/testin assembl 16:00 17:00 1.00 0 0 INTRM1 DRILL PULD T Lay down the jars and 3 flex drill collars from the derrick. 17:00 17:15 0.25 0 0 INTRM1 DRILL SFTY T Pre job safety meeting on picking up BHA #5. 17:15 18:00 0.75 0 79 INTRM1 DRILL PULD T Pickup and makeup BHA #5 to 79' Cleanout assembl 18:00 19:15 1.25 79 476 INTRM1 DRILL PULD T Continue to makeup Baker assembly BHA #5 to 476'. 19:15 19:45 0.50 476 586 INTRM1 DRILL PULD T Pickup and makeup Halliburton, 13-5/8" RTTS/storm packers run in the hole with center of element 106'. Reverse circulating junk basket 586'. Set test acker. 19:45 20:30 0.75 586 586 INTRM1 DRILL OTHR T Test the 13-3/8" casin , 106', wellhead and hydril to 3000 psi. Hold 10 minutes. Lost 60 psi- ood test. Chart test. 20:30 21:00 0.50 586 1,538 INTRM1 DRILL TRIP T Run in the hole to set RTTS/Storm packer. With the reverse circulating junk basket @ 1538.65' and the center of the elements of the storm acker 1058.3', se acker. 21:00 21:30 0.50 1,538 1,538 INTRM1 DRILL OTHR T Test the casing against the hydril to 1 10 minutes Lost 10 psi- ood test. Chart test. 21:30 21:45 0.25 1,538 1,538 INTRM1 DRILL OTHR T Blow down the top drive and kill line. 21:45 22:30 0.75 1,538 476 INTRM1 DRILL TRIP T Trip out of the hole with the Halliburton 13-5/8" RTTS/storm packer. Hole took proper dis lacement. 22:30 23:00 0.50 476 476 INTRM1 DRILL PULD T Lay down the Halliburton storm acker. 23:00 00:00 1.00 476 1,809 INTRM1 DRILL TRIP T Pickup/makeup 6joints of 5" drill i e then tri in the hole to 1809' Page 17 of 55 C~ Time Logs Date From To Dur S De th E. De th Ph se Code Subcode T Comment 9/19/2008 24 hr summary Run in the hole with BHA #5 (Cleanout run) from 1809' to 3713', attempt to unplug BHA, POOH to 3086', work and unplug string, circ, trip in the hole circulating as neccessary to keep string unplugged, , circ down last 50', tag bottom, pickup-increase circ rate to 820 gpm -reciprocate and work pipe, pump a 60 bbl sweep (10.1 ppg/250+ vis), circ out of hole. drop 1"steel ball, circulate to activate reverse circulating junk basket, tag bottom, make a foot of hole, pull out of the hole to 5521', pump a 20 bbl dry job, continue to pull out on elevators, noticed a little drag with Baker tools at the shoe (2k overpull), rotate till up inside of 13-3/8" casing, continue to pull out of the hole. Lay down BHA #5, clean floor, lay down 88 joints of 5" HWDP from the derrick, pull wear bushing. Remove bales and elevators on top drive, rig up Tesco casing running tool, PJSM on running casing, Run 9-518" 40 ppf L-80 BTC-m casing using TESCO running tool to 875' (20 jts in the hole . 00:00 01:15 1.25 1,809 3,718 INTRM1 DRILL TRIP T Continue trip in with BHA #5 from 1809' to 3718' 01:15 01:45 0.50 3,718 3,718 INTRM1 DRILL CIRC T ~n lu ed. Attem t to unplug. 01:45 02:30 0.75 3,718 3,086 INTRM1 DRILL TRIP T Pull out of the hole to 3086'. Hole took ro er dis lacement. 02:30 03:00 0.50 3,086 3,086 INTRM1 DRILL CIRC T Work to unplu strip -successful) . Circulate pumping 6 bpm w/ 530 psi 19% flow, pumping 8 bpm w/ 810 psi 22% flow. Rotate 30 rpm w/ 3-4k ft Ibs of for ue. 03:00 06:15 3.25 3,086 6,748 INTRM1 DRILL TRIP T Continue trip into the 12-1/4" open hole with BHA #5, circulate as needed to keep string from being lu ed. 06:15 06:30 0.25 6,748 6,748 INTRM1 DRILL CIRC T Break circulation @ 6748'. Obtain PU and SO wt's. Pumping 35 gpm w/ 280 psi 13% flow. PU wt 175k, SO wt110K 06:30 07:30 1.00 6,748 7,977 INTRM1 DRILL TRIP T Continue trip into the 12-1/4" open hole with BHA #5, circulate as needed to keep string from being lu ed. 07:30 09:00 1.50 7,977 8,020 INTRM1 DRILL CIRC T Break circulation @ 6977'. Circ and tag bottom. Pumping 820 gpm w/ 2940 psi 41 % flow. PU wt 200k, SO wt 130K, Rot wt 160k. Rotate 30 rpm w/ 9k ft Ibs of torque. After pumping 200 bbls, pump a 60 bbl sweep (10.1 ppg/250+ vis). Circulated a total of 1724 bbls. 09:00 09:30 0.50 8,020 8,020 INTRM1 DRILL CIRC T Drop Baker Oil Tool 1"steel ball to activate reverse circulation. Pump ball down @ 273 gpm w/ 470 psi 20% flow. Ball on seat after pumping 90.7 bbls. 09:30 09:45 0.25 8,020 8,020 INTRMI DRILL CIRC T Circulate and reciprocate with Baker Oil Tools reverse circulating junk basket on bottom- make a foot. Pumping 680 gpm w/ 2390 psi 36% flow. 09:45 11:00 1.25 8,020 5,521 INTRM1 DRILL TRIP T Pull out of the hole on elevators to 5521'. PU wt 200k, SO wt 135k. Monitor displacement on the trip tank. 11:00 11:30 0.50 5,521 5,521 INTRM1 DRILL CIRC T Pump a 20 bbl dry job. P~y~: 1~ cf 65 ~J l J Time Logs Date From To Dur _ S De th E. De th Phase Code Subcode T_ Comment 11:30 12:30 1.00 5,521 3,127 INTRM1 DRILL TRIP T Pull out of the hole on elevators to 3808'. Monitor displacement on the tri tank. 12:30 12:45 0.25 3,127 3,069 INTRM1 DRILL TRIP T Noticed 2K overpull @ 3127'. Slack off, rotate Baker BHA trough the shoe with 20 r m. 12:45 13:45 1.00 3,069 476 INTRM1 DRILL TRIP T Pull out of the hole on elevators to 476:5'. Monitor displacement on the trip tank. Hole took 2 bbls over calculated. 13:45 14:15 0.50 476 85 INTRM1 DRILL PULD T POOH stand back HWDP, then lay down Baker Oil Tools BHA to 85' 14:15 15:00 0.75 85 0 INTRM1 DRILL PULD P Lay down BHA #5, check junk basket for debris. A little bit in the Boot baskets. 15:00 15:45 0.75 0 0 INTRM1 DRILL OTHR P Clean and clear rig floor. 15:45 17:00 1.25 0 0 INTRM1 DRILL PULD P Lay down 33 joints of 5" HWDP from the derrick. 17:00 17:30 0.50 0 0 INTRM1 DRILL OTHR P Pull Vetco Gray 13-3/8" OD x 12-5/16" ID x 59-1/2" long wear bushin . 17:30 18:00 0.50 0 0 INTRM1 CASING RURD P Remove drilling elevators and bales from top drive. Rig up TESCO Casing drilling system to run the 9-5/8"_ Casin . 18:00 18:30 0.50 0 INTRM1 RIGMNT SVRG P Service top drive and blocks. 18:30 19:00 0.50 0 INTRM1 CASING SFTY P Pre job safety meeting with TESCO reps on rigging up the casing running tool. 19:00 19:30 0.50 0 INTRM1 CASING RURD P Continue to rig up TESCO casing runnin a ui ment. 19:30 20:30 1.00 0 0 INTRM1 CASING RURD P Rig up GBR spiders, prepare rig floor, rig up low pressure fillup line for casin fillu . 20:30 20:45 0.25 0 0 INTRM1 CASING SFTY P Pre job safety meeting with rig team on running 9-5/8" 40 ppf L-80 BTC-m casing. Meeting covered TESCO tool, normal casing pre job safety information, including running order of casin and 'ewele C , Time Low Date From To Dur S De th E. De th Phase Code Subcode T Comment 20:45 00:00 3.25 0 875 INTRM1 CASING RNCS P Run 9-5/8" 40 ppf L-80 BTC intermediate casing. Run Weatherford model 303 float shoe, 2 joints, Weatherford model 402 float collar, check floats-OK, then 14 more joints, 20' pup joint then the window joint (Jt # 17). The first 4 connections were Bakerlocked. Continue running casing, filling every 5 joints. Tandem rise centralizers were run on jt # 1 (5' and 8' above the shoe -over stop rings), then on jt # 3 (10' above the float collar- on a stop ring and the collar), centralizers were run on collars up to jt # 16, jt # 17 did not have a centralizer, then over collars of joints --planned to joint # 63. A total of 68 will be run. A stop was placed in the middle of jt # 16 and #18, centralizers went over the stops. Depth at midnight 875' (Jt # 20 in the hole). PU wt 108k, SO wt 105k 9/20/2008 Continue running 9-5/8" 40 ppf L-80 BTC-m casing using TESCO running tool from 875' (20 jts in the hole) to 3018' (70 jts), circulate bottom's up, Continue to run 9-5/8" to 6347', circulate 181 bbls, continue to run casing to 8015', rig down TESCO, rig up Dowell cement head, circulate, cement per plan, bump plug, check floats, PU stack, set slips with 280k on weight indicator, cutoff casing, dress same, install packoff, Nipple up BOP stack, in'ect lastic for 9-5/8". 00:00 04:00 4.00 875 3,018 INTRM1 CASING RNCS P Continue to run 9-5/8" 40 ppf L-80 BTC intermediate casing with tandem rise centralizers over collars up to jt # 63 (66 centralizers to here). Ran from 875' (Jt # 20) to 3018' Qt # 70). PU wt 167k, SO wt 132k. Monitor displacement-OK. Record PU and SO wt's every 10 jt's in casin .Fill eve 10 'ts. 04:00 04:30 0.50 3,018 3,018 INTRM1 CASING CIRC P Circulate bottom's up at the 13-3/8" shoe. Circulated 4 bpm w/ 120 psi 15% flow, then 5 bpm w/ 130 psi. 17% flow, and then 7 bpm w/ 150 psi 20% flow. Circulated a total of 220 bbls. 9.1 MW in 9.2 MW out. Hole takin ro er dis lacement. 04:30 06:00 1.50 3,018 4,240 INTRM1 CASING RNCS P Continue to run 9-5/8" 40 ppf L-80 BTC intermediate from 3018' Qt # 70) to 4240' (100 jts in the hole). PU wt 197k, SO wt 135k. Monitor displacement. Record PU and SO wt's every 5 jt's in open hole. Fill eve 10 'ts. .____ ~ ~ a __ _ -- ,~ ,,.~ ,~ , Time Logs - -- Date From_ To Dur S De th E. De th Phase __ Code Subcode T Comment 06:00 09:00 3.00 4,240 6,347 INTRM1 CASING RNCS P Continue to run 9-5/8" 40 ppf L-80 BTC intermediate from 4240' (100 jts) to 6347' (Jt # 150 in the hole). PU wt 250k, SO wt 132k. Monitor displacement. Record PU and SO wt's every 5 jt's in open hole. Fill eve 10 'ts. 09:00 09:45 0.75 6,347 6,347 INTRM1 CASING CIRC P Circulate @ 6347' (150 jts in the hole) Circulated 7 bpm w/ 200 psi 21 % flow. Circulated a total of 181 bbls. Hole taking proper dis lacement. 09:45 11:30 1.75 6,347 8,015 INTRM1 CASING RNCS P Continue to run 9-5/8" 40 ppf L-80 BTC intermediate from 6347' to 8015' . Install tandem rise centralizer on collar of jt # 186 and # 187. PU wt 290k, SO wt 138k. Monitor displacement. Record PU and SO wt's every 5 jt's in open hole. Fill eve 10 'ts. 11:30 11:45 0.25 8,015 8,015 INTRM1 CASING RURD P Rig down TESCO casing running tool. 11:45 12:15 0.50 8,015 8,015 INTRM1 CEMEN- RURD P Rig up Dowell 9-5/8"cementing head and lines. 12:15 14:15 2.00 8,015 8,015 INTRM1 CEMEN" CIRC P Circulate bottom's u 801 '. Reci rocate i e 26' to 30'. Pumping 7 bpm w/ 290 psi 20% flow. PU wt 275k, SO wt 135k. Circulated a total of 791 bbls. PJSM on cement job while circulating. Mud properties prior to cementing MW in 9.1+, MW out 9.2 , Vis in 48, vis out 58. PV/YP= 14/15. 10 min els = 14. 14:15 15:45 1.50 8,015 8,015 INTRMI CEMEN" OTHR P Switch over to Dowell/Schlumberger. Dowell pump 10 bbls CW 100 (8.34 ppg) @ 4 bpm w/ 100 psi, test lines to 3500 psi, pump another 40 bbls CW 100 (8.34 ppg) @ 4 bpm w/ 100.. psi, mix and pump 50.46 bbls mud push (11.0 ppg) @ 4 bpm w/ 120 psi, drop bottom plug, mix and pump 212.12 bbls Dee Crete cement 540 sx) (Yield 2.24 cuft/sk) (Mix water 7.567 gal/sk) 12.5 ppg, pumping 4.6 bpm w/ 200 psi ,drop top plug and kick out with 5 bbls of water, swap to rig pumps for displacement. Reci rocate i e 26' to 30'. ' ?~ ~1 ~;{ ij r} ... .J Time Logs - _ __ __ _ Date -- From To Dur S Depth E_ De th - Ph e Code Subcode T - Comment 15:45 17:30 1.75 8,015 8,015 INTRM1 CEMEN' DISP P _ ~_ Rig displace cement @ 7 bpm w/ 110 psi initial and final 500 psi w/ 9.3 ppg brine. Full returns throughout (19%). Reciprocate 26' to 30' stroke until 70.6 bbls of cement around shoe ,then quit reciprocation. Slowed down to 3 bpm last 20 bbl prior to bumping plug. Bump plug on calculated strokes. Increase pressure to 1000 psi, hold 5 minutes, bleed off to check floats. OK. CIP 1730 hrs 9/20/2008. 17:30 18:00 0.50 8,015 8,015 INTRM1 CEMEN" RURD P Rig down cementing equipment, drain .stack, vacuum out landin 'pint. 18:00 19:30 1.50 8,015 8,015 INTRM1 WELCTL NUND P Nipple down wellhead to PU BOP stack and set slips. (Break made between casing spool and tubing spool on wellhead) Remove choke line on BOPE stack. 19:30 20:15 0.75 8,015 8,015 INTRM1 CASING OTHR P Flush bowl, center the casinglnstall 9-5/8" slips with 280k on wt indicator (75k on slips). Job was planned and set on sli s. 20:15 21:30 1.25 8,015 0 INTRM1 CASING OTHR P Using Wachs casing cutter, cutjt# 189 leaving 33.16' below load shoulder. 21:30 21:45 0.25 0 0 INTRM1 CASING RURD P Rig down elevators. Lay down cutoff and landin 'pint. 21:45 22:45 1.00 0 0 INTRM1 CASING OTHR P Dress the cutoff- then install the 9-5/8" ackoff. 22:45 23:45 1.00 0 0 INTRM1 WELCTI NUND P Nipple up BOP stack. 23:45 00:00 0.25 0 0 INTRM1 WELCTI OTHR P Inject plastic in 9-5/8" packoff. 9/21 /2008 Finish injecting plastic for 9-5/8" packoff, test 9-5/8" packoff to 2500 psi f/ 10 min, nipple up BOP stack, perform infectivity test on 13-3/8" x 9-5/8" annulus, test choke line break to 250 and 3000 psi, flush outer annulus w/ 201 bbls of water 3 bpm w/ 610 psi, pickup BHA #6 (Kill string), pickup/run in hole with 4" drill pipe, makeup tubing hanger, land hanger with bit @ 2317', run in lockdown screws, test hanger void to 5000 psi, install two way check, nipple down BOP stack, nipple up Vetco Gray tree, test hanger void to 5000 psi, test tree to 250 psi and 5000 psi, lay down drill pipe from derrick. 13 stands still left to be layed down after midnight. Little Rd freeze protected the 13-3/8" x 9-5/8" annulus with 137 bbls of diesel. Final rate .5 bpm w/ 600 psi. Static 400 psi after shut down. Little red freeze protected the BHA #6 (Kill string) and the BHA x 9-5/8" annulus with 170 bbls of diesel. Final rate 3.7 b m w/ 450 si. 00:00 00:30 0.50 0 0 INTRM1 WELCTL OTHR P Finish injecting plastic in 9-5/8" packoff. Test seals on the packoff to 2500 psi. Lower seal did not test.. Retor ued lockdown screws, then attempted to test again. No test a ain- w Id onl hold 400 si. 00:30 01:45 1.25 0 0 INTRM1 DRILL PULD P Rig up bales for the top drive. Install bell uide. Brin BHA to the floor. 01:45 02:15 0.50 0 0 INTRM1 WELCTL OTHR T Rein'ect plastic for 9-5/8" packoff. Obtain a 2500 psi test, hold for 10 minutes (80% collapse of 9-5/8" casin = 2472 si . ~~ m.~ m l~ ~_ Tirne Logs_ - _- - -- _ Date From To Dur S. De th E. De th Phase Code Subcode T Cor,iment 02:15 03:00 0.75 0 0 _ INTRM1 WELCTL - NUND P - -- _ Nipple up choke line on 13-5/8" BOP stack. 03:00 03:45 0.75 0 0 INTRM1 DRILL LOT P Rig up to the 13-5/8" x 9-5/8", annulus and attempt to test with BOP test pump (1/4 bpm)_ Unable to obtain valid LOT--pumping too slow, 10 gal/min pressured to 350 psi and uit um in . 03:45 04:00 0.25 0 0 INTRM1 DRILL SFTY P Pre job safety meeting for picking up BHA/Kill strin . 04:00 04:30 0.50 0 10 INTRM1 DRILL PULD P Make up BHA #6 (Kill string/Drilfout) er directional driller. 04:30 05:00 0.50 0 0 INTRM1 WELCTL OTHR P Rig down test pump from 9-5/8" x 13-3/8" annulus. Rig up #2 mud pump to the annulus. Rig up test um to choke manifold to test choke line connection. 05:00 05:30 0.50 0 0 INTRM1 DRILL LOT T LOT on 13-5/8" x 9-5/8" annulus with rig pump pumping .6 bpm. Top of cement @ estimated 5300', 13-3/8"shoe @ 2069.73' (TVD 2227'). Leak off 466 psi = 13.2 ppg LOT. Pumped a total of 10.08 bbls. Bleed back after test. 05:30 06:45 1.25 0 0 INTRM1 WELCTI BOPE P Crew change and continue rigging up to test choke line connection.Test choke line connection to 250 psi and 3000 psi, chart test, leak @ 2500 psi, tighten connection, retest, hold test f/ 5 minutes each. Cleaning pits and rockwasher. 06:45 07:00 0.25 0 0 INTRM1 WELCTI OTHR P Rig down testing equipment. 07:00 07:15 0.25 0 0 INTRM1 RPCOM FRZP P Begin flushing 13-3/8" x 9-5/8" ... e annulus with water. Initial rate of 1 bpm w/ 280 psi, final circ pressure 3 bpm w/ 610 psi. Pumped a total of 201 bbls. 07:15 08:00 0.75 10 196 INTRM1 DRILL PULD P Continue to pickup BHA #6. Continue to flush 13-3/8" x 9-5/8" annulus. 08:00 08:30 0.50 196 567 INTRM1 DRILL PULD P Pickup 4"drill pipe fromn the pipe shed, run in the hole to 567'. Rig down equipment used to flush the 13-3/8" x 9-5/8" annulus. Initial rate of 1 bpm w/ 280 psi, final circ pressure 3 bpm w/ 610 psi. Pumped a total of 201 bbls. 08:30 09:45 1.25 567 2,273 INTRM1 DRILL PULD P Continue to pickup 4"drill pipe fromn the pipe shed, run in the hole from 567' to 2273'. 09:45 10:30 0.75 2,273 2,273 INTRM1 DRILL OTHR P Pickup tubing hanger, makeup landin joint, drain stack, blow down kill and choke lines. ~ e~ ®m ~ __ ®~ ~.~ m. _ Time Logs Date _ From To Dur S De th E. De th Phase Code Subcode T Comment 10:30 11:15 0.75 2,273 2,317 INTRM1 RPCOM PULD P _ Run in the hole with tubing hanger (4.909 MCA top x 4-1/2" IBT-m pin pup), and land string with 8-1/2" bit 2317' (1952.4 TVD) . PU wt 110k, SO wt 105k. 11:15 13:00 1.75 2,317 0 INTRM1 WELCTI BOPE P Run in the lockdown screws. Test tubing hanger to 5000 psi. Remove and laydown landing joint. Continue cleanin its and rockwasher. 13:00 13:45 0.75 INTRM1 RPCOM OTHR P Install two way check. Clean rig floor dri ans. 13:45 16:00 2.25 INTRM1 RPCOM NUND P Nipple down BOP stack. Continue to clean drip pans, continue cleaning rockwasher. 16:00 16:30 0.50 INTRM1 RIGMN7 SVRG P Change oil and filters in the top drive while still cleanin dri ans. 16:30 17:15 0.75 INTRM1 RPCOM NUND P Set back BOP stack, continue to ni le down. 17:15 20:00 2.75 INTRM1 RPCOM NUND P Nipple up Vetco Gray tree. Test hanger void to tree adapter to 5000 si. 20:00 20:30 0.50 INTRM1 WELCTI BOPE P Rig up Little Red, test lines to 1500 si. 20:30 21:00 0.50 INTRM1 WELCTI BOPE P Test tree to 250 psi low and 5000 psi. Hold each 10 minutes. OK. RU to lay down drill pipe from derrick using mousehole. Laying down 5" drill pipe from derrick. Little Red freeze protect the 13-3/8" x 9-5/8"annulus with 137 bbls of diesel to 2335' RKB (1964' TVD 21:00 21:45 0.75 INTRM1 WELCTI BOPE P Pull two way check 21:45 22:30 0.75 INTRM1 RPCOM RURD P Install tree cap w/ 2" 1502 thread half. Laying down 5" drill pipe from derrick. 22:30 22:45 0.25 INTRM1 RPCOM RURD P Rig up to freeze protect the BHA #6 and 9-5/8"annulus with Little Red. La in down 5"drill i e f/derrick. 22:45 23:45 1.00 INTRM1 RPCOM FRZP P Little Red test lines to 2000 psi, then freeze protect the kill string and 9-5/8" x BHA # 6. Initial circ rate 1bpm w/ 150 psi, increase rate to 2 by w/ 300 psi, 3 bpm w/ 450 psi, pump most ofjob at 3.7 bpm w/ initial 700 psi and final of 450 psi while pumping. Pumped a total of 170 bbls taking returns to the pits. Freeze protected to the bit Cal 2317' RKB (1952' TVD) Continue laying down 5"drill pipe from the derrick. 23:45 00:00 0.25 INTRM1 RPCOM RURD P Rig down Little Red. 38 stands still in Derrick at midnight. We will lay down 14 more stands, leaving a total of 25 stands while moving to next well. 9~ ~ d . 1., ~ ~ Time Logs Date From To Dur ___S Depth E. Depth Phase .Code Subcode T Comment ___ _ __ 9/22/2008 24 hr Summary 14 stands still left to be layed down after midnight, setting BPV with lubricator, secure well, lay down drill i e, sli and cut drillin line. Ri released 0600 hrs 9/22/2008. 00:00 00:30 0.50 INTRM1 RPCOM RURD P Blow down Little Red lines, and lines to its after freeze rotection. 00:30 03:00 2.50 INTRMI WELCTI OTHR P Set back pressure valve usin lubricator. Had trouble setting valve because of no standard tree height. Could not use spring tip on lubricator. Well secured @ 0300 hrs 9/22/08. Outer annulus pressure 200 si. IA zero, tubin zero. 03:00 05:00 2.00 INTRM1 DRILL PULD P Continue to lay down 14 stands of 5" drill pipe from derrick and remove from the i e shed. 05:00 06:00 1.00 INTRM1 RIGMN? SVRG P Slip and cut 128' 1-3/8" drilling line. Rig released for move to 3K-103 @ 0600 hrs 6/22/2008. 11/19/2008 ~` ~ 108 ~QQ-~`"T`~~`~ S`~ ~ eleased ri from 3K-103 and be an move to 3K g g p - 22:00 22:30 0.50 0 0 MIRU MOVE SFTY P PJSM -skidding rig floor. 00:30 01:15 0.75 0 0 MIRU MOVE DMOB P Skid rig floor. 01:15 01:30 0.25 0 0 MIRU MOVE SFTY P PJSM -raising stompers on sub. 01:30 02:00 0.50 0 0 MIRU MOVE DMOB P Raising stomper on sub. 11 /20/2008 Move pit module and sub to 3K-108. Spot rig over well and connect up lines. Spot and hard line open top tanks and solids control van. Load pits with brine for displacement. Displace freeze protect diesel from well to o en to tank. Be in ni le down of tree. 00:00 01:00 1.00 0 0 MIRU MOVE DMOB P Preparing Pit module for moving off of mats 01:00 01:30 0.50 0 0 MIRU MOVE SFTY P PJSM -moving Pit module from 3K-103 to 3K-108 01:30 03:00 1.50 0 0 MIRU MOVE MOB P Move Pit module. 03:00 03:30 0.50 0 0 MIRU MOVE SFTY P PJSM -moving sub from 3K-103 to 3K-108 03:30 04:00 0.50 0 0 MIRU MOVE MOB P Stage mats for move off of 3K-103 04:00 06:00 2.00 0 0 MIRU MOVE MOB P Move Sub off of 3K-103. 06:00 15:00 9.00 0 0 MIRU MOVE MOB P Move sub onto mats and spot over 3K-108. Move pit module up onto mats and spot next to sub. Connect up lines & interconnects, spot rockwasher and cuttings bins, berm up arond rig. Sim ops -spotting open top tanks, berms and hardline. Spot and berm Solids Control Van. 15:00 15:00 0.00 0 0 MIRU MOVE MOB P Rig Accepted at 15:00 15:00 16:00 1.00 0 0 MIRU MOVE MOB P Load pits with brine for displacing diesel. Load BHA in i e shed. 16:00 18:00 2.00 0 0 MIRU CASING OTHR P Connect annulus to hard line to open top tanks. Make up high pressure hoses to secondary kill line. Run hard lines to Solids Control Van. m ~ ~ ~._.......___ - ..~._.e. _.. ~ .._...- ~ ~ - : _. ..; t+,~ ~~ ., Tirne Logs - -- Date _From To Dur S De th E Depth Phase Code Subcode T Comment 18:00 19:30 1.50 0 0 MIRU WELCTL NUND P Pull back pressure valve. 19:30 21:00 1.50 0 0 MIRU CASING RURD P Blow air to open top tanks. Flood lines with brine and pressure test to 1000 psi for 5 minutes. Check lines, ressure held. 21:00 21:30 0.50 0 0 MIRU CASING RURD P Rig upon kill string , 21:30 22:00 0.50 0 0 MIRU CASING SFTY P PJSM - dis lacin diesel from well to o een to tank. 22:00 23:00 1.00 0 0 MIRU CASING CIRC P Displace well to brine at 6.5 bpm, 950 psi. Calculated displacement 164 bbls, um ed 192 bbls. 23:00 23:30 0.50 0 0 MIRU CASING RURD P Blow down and rig down lines, install back ressure valve. 23:30 00:00 0.50 0 0 MIRU WELCTL NUND P Nipple down tree. 11!21 /2008 Nipple up BOPE and change out pipe rams. Test BOPE -passed. Pick up and stand back 5"drill pipe. 00:00 00:30 0.50 0 0 MIRU WELCTL NUND P Nipple down tree and dress tubing han er. 00:30 01:00 0.50 0 0 MIRU WELCTI SFTY P PJSM -nipple up BOP stack and chan a rams. 01:00 03:30 2.50 0 0 MIRU WELCTL NUND P Nipple up stack, riser, choke and kill lines. Ri u BOPE test a ui ment 03:30 06:00 2.50 0 0 MIRU WELCTL NUND P Chan a to rams to 3-1/2" x 6"and bottom rams to 2-7/8" x 5" 06:00 09:30 3.50 0 0 MIRU WELCTL NUND P Button up rams doors, rig upturn buckles, bell nipple, flowline, drip pan, fill up line and upper flange on riser. Center u stack. 09:30 12:00 2.50 0 0 MIRU WELCTL BOPE P Rig up to test BOPE. Make up crossover and overshot tool for Vetco hanger. RIH per Vetco rep. Grease and line up choke manifold. Fill stack with water. 12:00 18:00 6.00 0 0 MIRU WELCTL BOPE P Witness waived by Chuck Sheave AOGCC.Test rams with 3-1/2" and 4" test joints. Test bag with 3-1/2" test joint. Test choke manifold, upper IBOP, Tower IBOP, HCR kill, HCR choke and dart valve. 250 psi low and 3000 si hi h. 18:00 18:45 0.75 0 0 . MIRU WELCTL BOPE P Test blind rams and perform accumulator drawdown test. Starting pressure 3025 psi, cycle valves, 1600 psi on accumulator. 30 seconds for 200 psi increase and 2 minutes 54 seconds to full charge, 3050 si. 5 bottle avera a 2450 s i. 18:45 19:00 0.25 0 0 MIRU WELCTL BOPE T Change out hose on iron roughneck. Install 5" test'oint 19:00 20:00 1.00 0 0 MIRU WELCTL BOPE P Test bag, upper and lower rams with 5" test ~oint. Test manual choke. 20:00 20:45 0.75 0 0 MIRU WELCTL BOPE P Rig down test equipment and blow down lines. 20:45 21:15 0.50 0 0 MIRU RIGMNT SVRG P Service drawworks. Clear and clean rig floor. Install mouse hole in rotary table. _... _ ~ ®_ .~ _..~......wa. ~~at~~ ~6 ~g r~ ~ ~ Time Logs Date From To Dur S. Depth E. De th Phase Code Su code T Comment 21:15 21:30 0.25 0 0 MIRU DRILL SFTY P PJSM -picking up 5"drill pipe. 21:30 00:00 2.50 0 0 MIRU DRILL PULD P Pick up 5"drill pipe from shed and stand back. 11 /22/2008 Pick up and stand back 5"drill pipe. Pull tubing hanger and lay down. Run and set wear ring. Single in hole and tag float equipment.Perform caustic wash and started acid wash. Held a man down in derrick drill with Ku aruk Emer enc Services.. 00:00 01:00 1.00 0 0 MIRU DRILL PULD P Pick up 5"drill pipe from shed and stand back. 01:00 01:30 0.50 0 0 MIRU RPCOM SFTY P PJSM- pulling landing joint. 01:30 02:15 0.75 0 2,317 MIRU RPCOM RCST P Pick up landing joint and pull hanger / kill string.,Hanger came free with 20k overpull. PU wt 110k, SO wt 105k. 02:15 03:00 0.75 2,317 2,317 MIRU RPCOM RCST P Lay down hanger and crossover. 03:00 03:15 0.25 2,317 2,317 MIRU DRILL TRIP P Change out handling equipment from 5" to 4". 03:15 04:00 0.75 2,317 2,744 MIRU DRILL TRIP P Single in hole with 4" drill pipe (waiting on crossovers to run wear bushin ) 04:00 06:00 2.00 2,744 2,744 MIRU DRILL OTHR P Make up crossovers and wear ring running tool to 4" drill pipe. Set wear rin and run in lockdown screws. 06:00 07:00 1.00 2,744 2,744 MIRU DRILL OTHR P Breakout wear ring running tool and crossovers and la down. 07:00 09:45 2.75 2,744 6,045 MIRU DRILL TRIP P Continue to single in hole with 4"drill i e. 09:45 11:00 1.25 6,045 6,640 MIRU DRILL TRIP P Change out handling equipment and sin le in hole with 5"drill i e. 11:00 13:30 2.50 6,640 6,640 MIRU DRILL SFTY P Hold mandown in derrick drill with Kuparuk Emergency Services. A dummy was placed in the derrick and emergency services crew was hoisted into derrick with basket. Dummy was loaded into basket and lowered to waitin ambulance. 13:30 14:30 1.00 6,640 7,856 MIRU DRILL TRIP P Single in hole with 5" drill pipe. 14:30 15:15 0.75 7,856 7,934 MIRU DRILL TRIP P Wash down to float equipment pumping 3 bpm, 180 psi. Set down 6k. 15:15 16:15 1.00 7,934 7,920 MIRU DRILL CIRC P Pick up off bottom and circulate bottoms u at 15 b m, 2200 si. 16:15 17:30 1.25 7,920 7,920 MIRU CASING DHEO P Ri u and test casin to 3000 si for 30 minutes. Go t t. 17:30 17:45 0.25 7,920 7,920 MIRU CASING SFTY P PJSM -caustic wash 17:45 18:00 0.25 7,920 7,920 MIRU CASING OTHR P Blow down hardline to tanks and pressure test to 1000 psi. Blow down after test. 18:00 18:15 0.25 7,920 7,920 MIRU CASING SFTY P PJSM with night crew on caustic wash P €: ~f ~i Time Logs - _ , Date From To Dur S. Depth E. De th Phase Code Subcode T Comment _- - 18:15 20:45 2.50 7,920 7,920 MIRU CASING CIRC P Perform caustic wash on 9-5/8" casin .Pumping sequence using rig pump, 20 bbls hi-vis brine spacer, 75 bbls caustic, 50 bbls hi-vis brine spacer, displaced with 616 bbls of brine. Diverted last 253 bbls of dis lacement too en to tank. 20:45 22:00 1.25 7,920 7,920 MIRU CASING CIRC P Circulate 2 bottoms up pumping 15 b m, 2860 si. 22:00 22:30 0.50 7,920 7,920 MIRU CASING RURD P Rig up hardlines to Schlumberger um in unit for acid wash 22:30 23:00 0.50 7,920 7,920 MIRU CASING SFTY P PJSM -acid wash. 23:00 00:00 1.00 7,920 7,920 MIRU CASING CIRC P Perform acid wash on 9-5/8" casing. Pumping sequence using Schlumberger pumping unit, 5 bbls water, 20 bbls hi-vis brine spacer, 30 bbls 15% HCL acid, 43 bbls hi-vis brine spacer, 5 bbls water. After midnight, displaced with 607 bbls brine using rig pump. Diverted last 188 bbls of displacement to open top tank. 11 /23/2008 Displaced 30 bbl acid wash with brine. Drilled out float equipment and 20' of new hole for LOT. Performed LOT, 14.3 EMW. Run in hole with USIT to in tools and tractor on wireline. 00:00 03:30 3.50 7,920 7,920 MIRU CASING CIRC P Displaced HCL acid and spacers with 607 bbls brine using rig pump. Diverted last 188 bbls of dis lacement to o en to tank. 03:30 04:00 0.50 7,920 7,920 MIRU CASING RUNL P Rig down Schlumberger hardline runnin u to ri floor. 04:00 05:00 1.00 7,920 8,020 INTRM1 DRILL REAM P Tag float equipment at 7925' MD and drill shoe track. Pumping 500 gpm, 1620 psi, rotating 120 rpm. Displace well over to OBM while drilling shoe track. 05:00 06:00 1.00 8,020 8,040 INTRM1 DRILL DRLG P Drill 20' of new hole for LOT. Pumping 500 gpm, 1620 psi, rotating 120 m. 06:00 07:45 1.75 8,040 8,040 INTRM1 DRILL CIRC P Circulate 2 bottoms up to clean hole for LOT. Pum in 364 m, 1850 si 07:45 08:00 0.25 8,040 8,040 INTRM1 DRILL CIRC P Record slow pump rates. 08:00 09:00 1.00 8,040 7,950 INTRM1 DRILL LOT P Pick up into casing and perform LOT. ~ Formation broke at 950 psi, 1 4. g EMW. Chart recorder malfunctioned and test was not charted. 09:00 09:30 0.50 7,950 7,950 PROD1 DRILL OWFF P Monitor well -static 09:30 12:15 2.75 7,950 196 PROD1 DRILL TRIP P Pump dry job and POOH to BHA. Hole took ro er fill on tri . 12:15 13:00 0.75 196 0 PROD1 DRILL PULD P Lay down BHA. 13:00 13:30 0.50 0 0 PROD1 DRILL PULD P Clear and clean rig floor. 13:30 13:45 0.25 0 0 PROD1 EVALWE SFTY P PJSM -rigging up and running USIT to son wireline & tractor. 13:45 16:30 2.75 0 0 PROD1 EVALWE RURD P Pick up and rig up wireline sheaves and tools. Ener ize tools and test. ~ _ m ~.~ _~._.a .. ~ - ~ ~ ~ ~ Time Logs _ _ --- Date From To D ur S Depth E_Depth Phase Code Subcode T Cor7~ment 16:30 00:00 _ __ 7.50 0 _ 7,500 PROD1 EVALWE ELOG P _____ RIH with USIT logging tools. 11 /24/2008 Obtained cement bond logs for intermediate casing cement. Picked up, made up and ran in hole to casing shoe with drillin assembl . Sli and cut drillin line and serviced ri . Be an drillin B sand lateral. 00:00 04:00 4.00 7,500 8,015 PROD1 EVALWE ELOG P Obtaining cement bond logs using Schlumberger USIT logging tool and tractor. Tractored in hole from 2600' to 7970' WLM. Stopped to record mud properties every 500' on TIH. Logged 7970 to 7400' WLM, tractored back to bottom and then to ed from 7970' to 2200' WLM. 04:00 05:45 1.75 8,015 0 PROD1 EVALWE RURD P POOH with wireline, rig down sheaves and laid down wireline to in tools. 05:45 06:00 0.25 0 0 PROD1 EVALWE OTHR P Clear and clean rig floor, Prepare tools for makin u drillin BHA. 06:00 07:30 1.50 0 PROD1 DRILL PULD P Pick up and make up drilling BHA er DD and MWD re s. 07:30 08:15 0.75 PROD1 DRILL PULD P Download MWD. 08:15 09:00 0.75 464 PROD1 DRILL PULD P Pick up and make up remaning BHA. 09:00 09:15 0.25 464 464 PROD1 DRILL DHEQ P Shallow pulse test MWD pumping 280 m, 1600 si. Good test. 09:15 12:00 2.75 464 5,182 PROD1 DRILL TRIP P TIH on elevators with 4"drill pipe, monitoring displacement via trip tank, recording weights every 10 stands. PU wt 130k, SO wt 105k 12:00 14:00 2.00 5,182 6,164 PROD1 DRILL TRIP P Single in hole with 5" drill pipe, monitorin dis lacement via tri tank. 14:00 15:15 1.25 6,164 7,948 PROD1 DRILL TRIP P TIH on elevators with 5"drill pipe, monitoring displacement via trip tank, recording weights every 10 stands. PU wt 175k, SO wt 110k 15:15 15:30 0.25 7,948 7,948 PROD1 RIGMNT SVRG P Blow down top drive and hang blocks. 15:30 15:45 0.25 7,948 7,948 PROD1 RIGMNT SFTY P PJSM -slip and cut drilling Tine 15:45 17:00 1.25 7,948 7,948 PROD1 RIGMNT SVRG P Slip and cut 115' of drilling line. Ins ect drawworks and brake ads. 17:00 17:15 0.25 7,948 7,948 PROD1 RIGMNT SVRG P Unhang blocks and tie back hanging line in derrick. 17:15 18:00 0.75 7,948 7,948 PROD1 RIGMNT SVRG P Service drawworks, topdrive, blocks and crown. 18:00 18:15 0.25 7,948 8,040 PROD1 DRILL TRIP P TIH to TD, 8040' MD 18:15 21:45 3.50 8,040 8,236 PROD1 DRILL DDRL P Begin drilling B-Lateral. Experiencing intermittent problems with resistivity and At Bit Inclinitaion tools. Switch MWD modes, change drilling parameters in attempt to get good readin s. 21:45 22:15 0.50 8,236 8,236 PROD1 DRILL CIRC T Rotate and reciprocate while repairing hardline between solids control van and rockwasher. ~~ _ ~_ ®m~m~ ~ ~ u Time Low Date From To Dur S. De th E. De th Phase Code Subcode T Comment 22:15 00:00 1.75 8,236 8,314 PROD1 DRILL DDRL P Drilling B-Lateral. Continue having intermittent problems with resistivity and At Bit Inclinitaion tools. Continue troubleshootin while drillin ahead. 11 /25/2008 Continued drilling B sand lateral while trouble shooting MWD. Decision made to trip for MWD. Tripped out of hole, changed out MWD and tripped back in. Recorded 8 surveys in open hole during trip and relogged last 40' of hole. Resumed drillin B sand lateral. 00:00 02:00 2.00 8,314 8,471 PROD1 DRILL DDRL P Drilling B-Lateral. Contin~avir~ intermittent problems with resistive and At Bit Inclinitaion tools. Continued troubleshooting while drilling ahead. Decision made to trip for MWD. 02:00 02:15 0.25 8,471 8,471 PROD1 DRILL OWFF T Monitor well -static 02:15 02:45 0.50 8,471 7,950 PROD1 DRILL TRIP T POOH 5 stands on elevator. Hole taking proper fill. PU wt 180k, SO wt 120k. 02:45 03:00 0.25 7,950 7,950 PROD1 DRILL OWFF T Monitor well -static. 03:00 03:15 0.25 7,950 7,950 PROD1 DRILL CIRC T Pump 25 bbl dry job and blow down to drive. 03:15 07:45 4.50 7,950 369 PROD1 DRILL TRIP T POOH on elevators, monitoring hole fill via trip tank, recording weights every 10 stands. PU wt 120k, So wt 110k. 07:45 08:00 0.25 369 369 PROD1 DRILL OWFF T Pull stripping rubbers and monitor well. Well static. 08:00 08:30 0.50 369 112 PROD1 DRILL TRIP T Rack back BHA in derrick. 08:30 09:00 0.50 112 61 PROD1 DRILL TRIP T POOH and download MWD. Clear and clean ri floor. 09:00 09:30 0.50 61 0 PROD1 DRILL PULD T Lay down MWD tools. Inspect motor and bit - ok. 09:30 11:15 1.75 0 61 PROD1 DRILL PULD T Pickup backup MWD tools and u load. 11:15 11:45 0.50 61 370 PROD1 DRILL TRIP T TIH with BHA from derrick. 11:45 12:15 0.50 370 370 PROD1 DRILL CIRC T Shallow pulse test MWD pumping 301 gpm, 1900 psi -good test. Blow down top drive. PU wt 88k, SO wt 90k. 12:15 16:00 3.75 370 7,950 PROD1 DRILL TRIP T TIH on elevators to intermediate casing shoe. Recording weights every 10 stands. Fill at 5285' MD & 7950' MD. Check MWD on each fill - MWD ood. 16:00 16:30 0.50 7,950 7,950 PROD1 RIGMNT SVRG P Service crown, blocks, top drive and drawworks. 16:30 18:00 1.50 7,950 8,431 PROD1 DRILL TRIP T TIH taking surveys at 8237', 8241', 8245', 8249', 8332', 8421', and 8431' M D. 18:00 19:00 1.00 8,431 8,471 PROD1 DRILL REAM T Wash in hole to TD while getting logs for geologist. Pumping 300 gpm, 3040 si, rotatin 120 r m. 19:00 00:00 5.00 8,471 8,937 PROD1 DRILL DDRL P Resume drilling B sand lateral. 11 /26/2008 Drilling B sand lateral. Stop to take checkshot surveys and resumed drilling ___ ~ ~ Tirne Logs Date From To Dur S De th_ __E Depth Phase Code Subcode T Cor7iment ___ 00:00 04:30 4.50 8,937 9,379 PROD1 DRILL DDRL P Drilling B sand lateral. 04:30 05:45 1.25 9,379 9,284 PROD1 DRILL SRVY T DD did not get the expected turn out of a slide and on the next survey showed an excessive rate of turn. Discussed with Sperry ROC. Stand back 3 stands and reshoot survey @ 9091' bit depth. Took 5 additional surve s on tri back to bottom. 05:45 08:15 2.50 9,284 9,284 PROD1 DRILL CIRC T Rotate and reciprocate while troubleshootin surve s, Pumping 315 m, 3180 si, rotatin 120 r m. 08:15 08:45 0.50 9,284 9,379 PROD1 DRILL TRIP P Trip back to bottom 08:45 18:00 9.25 9,379 10,215 PROD1 DRILL DDRL P Resume drilling B sand lateral. 18:00 00:00 6.00 10,215 10,728 PROD1 DRILL DDRL P Drilling B sand lateral. 11 /27/2008 Drilling B sand lateral. 00:00 12:00 12.00 10,728 11,852 PROD1 DRILL DDRL P Drilling B sand lateral 12:00 17:30 5.50 11,852 12,233 PROD1 DRILL DDRL P Drilling B sand lateral 17:30 17:45 0.25 12,233 12,233 PROD1 DRILL OWFF P Monitor well -static 17:45 18:00 0.25 12,233 11,704 PROD1 DRILL TRIP P Short trip 5 stands. Pu wt 198k, So wt 110k. 18:00 18:15 0.25 11,704 11,704 PROD1 DRILL OWFF P Monitorwell-static. 18:15 18:45 0.50 11,704 12,233 PROD1 DRILL TRIP P Trip back to bottom. PU wt 200k, SO wt 110k. 18:45 00:00 5.25 12,233 12,708 PROD1 DRILL DDRL P Drilling B sand lateral. 11 /28/2008 Drilled B sand lateral to TD 13180' MD. Circulated hole clean, short tripped and circulated 3 additional bottoms u . O ened circulation sub and circulated casin clean. 00:00 06:30 6.50 12,708 13,180 PROD1 DRILL DDRL P Drilled B sand lateral to TD, 13180' MD 06:30 14:45 8.25 13,180 13,180 PROD1 DRILL CIRC P Circulated hole clean. Pumped 50 bbl hi-vis sweep at TD. Sweep returned 200 strokes over calculated and observed 10% cuttings increase when sweep returned. Circulated total of 4.5 bottoms up at 319 gpm, 3310 psi. PU wt 210k, SO wt 110k, rotatin wt 153k. Max as 1382 units 14:45 15:00 0.25 13,180 13,180 PROD1 DRILL OWFF P Monitor well -falling 15:00 16:45 1.75 13,180 11,760 PROD1 DRILL TRIP P Short trip 15 stands recording weights every 5 stands. PU wt 200k, SO wt 112k. 16:45 17:30 0.75 11,760 13,180 PROD1 DRILL TRIP P TIH to TD recording weights every 5 stands. PU wt 200k, SO wt 105k. 17:30 19:30 2.00 13,180 13,180 PROD1 DRILL CIRC P Circulate 1 bottoms up at 319 gpm, 3320 psi, rotating 120 rpm. PU wk 200k, SO wt 105k, rotatin wt 145 k. Time Lo sc~ - -- -- - D~te From To Dur S De th - E. De th Phase Code Subcode T Comment 19:30 22:15 2.75 13,180 13,180 PROD1 DRILL CIRC - - P - ---- Circulate 17 bbl sweep with 25 ppb coarse safe-card to gauge hole washout. Sweep was not seen at surface. Gathered up team and discussed circulating another sweep. Decision made not to circulate second sweep. Circulated total of 2+ bottoms u at 317 m, 3300 si 22:15 22:45 0.50 13,180 13,180 PROD1 DRILL CIRC P Drop 2" ball to open PBL circulation sub and pump down at 3 bpm. Ball on seat and circ sub opened at 1058 strokes. 22:45 00:00 1.25 13,180 13,180 PROD1 DRILL CIRC P Circulating thru circ sub to clean casin at 800 m, 2900 si. 11 /29/2008 Circulated casing clean pumping thru circulation sub. Closed circ sub and tripped out of hole with drilling BHA. Picked up hole opener with ghost reamer and tripped to bottom. Observed tight spot at 10602' MD. Worked tight spot and tripped to bottom. Mixed breaker and began spotting trucks while circulating on bottom. 00:00 01:00 1.00 13,180 13,180 PROD1 DRILL CIRC P Circulating thru circ sub to clean casing at 800 gpm, 2900 psi. Rotating drill string for 2.5 min every 15 min 01:00 01:30 0.50 13,180 13,180 PROD1 DRILL CIRC P Drop circ sub closing balls and pump down. Balls on seat at 754 strokes. Pressured up to 3250 psi and sheared ball set to close sub. Vefied closed by pumping until MWD signal detected at surface. 01:30 01:45 0.25 13,180 13,180 PROD1 DRILL OWFF P Monitor well -static 01:45 02:00 0.25 13,180 13,180 PROD1 DRILL CIRC P Pump 30 bbl dry job and blow down to drive. 02:00 08:00 6.00 13,180 5,182 PROD1 DRILL TRIP P POOH on elevators recording weights every 5 stands in open hole and every 10 stands in casing. PU wt 130k, SO wt 110k. 08:00 08:30 0.50 5,182 5,182 PROD1 DRILL PULD P Break out circ sub and relieve balls from ball catcher. 08:30 09:15 0.75 5,182 5,182 PROD1 DRILL CIRC P Pump dry job, blow down top drive and change over to 4" handling e ui ment. 09:15 11:15 2.00 5,182 370 PROD1 DRILL TRIP P POOH on elevators to BHA. Lost 37 bbls to hole on tri out. 11:15 11:30 0.25 370 370 PROD1 DRILL OWFF P Monitor well -falling 11:30 13:00 1.50 370 0 PROD1 DRILL PULD P Rack back HWDP, jars, bumper sub and flex collars. Plug in and turn off MWD (will download MWD in pipeshed). Lay down MWD, stabilizer, float sub and motor. 13:00 13:30 0.50 0 0 PROD1 WELLPF OTHR P Clear and clean rig floor, prep tools for ickin u hole o ener BHA. 13:30 14:30 1.00 0 299 COMPZ WELLPF PULD P Pick up and run in hole with hole o ener assembl . 14:30 17:30 3.00 299 7,986 COMPZ WELLPF TRIP P TIH to casing shoe on elevators, monitoring displacement via trip tank, recordin wei hts eve 10 stands. ~ ~ Time Logs Date __ From To Dur S De th E. De th Phase Code Subcode T Comment 17:30 18:00 0.50 7,986 7,986 COMPZ WELLPF SVRG P Service rig, top drive, lower and upper IBOP, crown and drawworks. 18:00 20:00 2.00 7,986 10,602 COMPZ WELLPF TRIP P TIH on elevators. Stacking out on concretion. 20:00 21:00 1.00 10,602 10,724 COMPZ WELLPF REAM P Make top drive connection. Wash and ream thru right spot. POOH and attempt to trip past with and without pumps and rotation. Spot ghost reamer at tight spot and work up and down to open up hole. Ream until ghost reamer passes without pumps or rotation. 21:00 22:00 1.00 10,724 13,101 COMPZ WELLPF TRIP P TIH on elevators 22:00 22:15 0.25 13,101 13,180 COMPZ WELLPF REAM P Wash and ream to bottom. 22:15 00:00 1.75 13,180 13,180 COMPZ WELLPF CIRC P Circulating on bottom pumping 312 gpm, 1870 psi, rotating 50 rpm. Started mixing breaker at E pit and s ottin trucks at ri . 11 /30/2008 Spotted breaker in open hole. Pulled up in casing and displaced hi-vis brine from breaker job with brine. Pulled out of hole and ri ed u to run liner. Ran 3-1/2" liner with screens and swell ackers. 00:00 02:00 2.00 13,180 13,180 COMPZ WELLPF CIRC P Circulating on bottom pumping 312 gpm, 1870 psi, rotating 50 rpm. Preparing for displacement. Circulated total of 2 bottoms u . 02:00 02:30 0.50 13,180 13,180 COMPZ WELLPF RURD P Rigging up for displacement. Flush OBM from mud pumps and pull suction screens. Fill its with LVT and brine. Finish hookin u trucks 02:30 03:00 0.50 13,180 13,180 COMPZ WELLPF SFTY P PJSM -one with truck drivers and truck pusher and a second with rig crew. 03:00 06:00 3.00 13,180 13,180 COMPZ WELLPF CIRC P Spot breaker in open hole. Pumped the following: 25 bbls 7.1 ppg LVT, 75 bbls 9.8 ppg spacer, 438 bbls 9.2 ppg hi-vis brine, 239 bbls 9.5 ppg breaker and 130 bbls 9.2 brine. 06:00 06:15 0.25 13,180 13,180 COMPZ WELLPF OWFF P Monitor well -falling 06:15 10:00 3.75 13,180 7,682 COMPZ WELLPF TRIP P POOH on elevators 333' into intermediate casing. Recorded weights every 5 stands. PU wt 160k, SO wt 128k, rotatin wt 140k. 10:00 10:15 0.25 7,682 7,682 COMPZ WELLPF SFTY P PJSM -displacing hi-vis brine from well. 10:15 11:15 1.00 7,682 7,682 COMPZ WELLPF CIRC P Displace hi-vis brine from well with brine. 11:15 11:30 0.25 7,682 7,682 COMPZ WELLPF OWFF P Monitor well -falling 11:30 14:30 3.00 7,682 299 COMPZ WELLPF TRIP P POOH on elevators to BHA recording wei hts eve 10 stands. 14:30 14:45 0.25 0 COMPZ WELLPF OWFF P Monitor well -falling 14:45 15:30 0.75 299 0 COMPZ WELLPF PULD P Rack back HWDP, jars, bumper sub and flex collars. Lay down stabilizer, cross overs, ghost reamer and hole opener. Lost 30.5 bbls to hole during tri out. _~ . ~ _s ~ - _~ m---_ __ _, ~~ .... _____ ... _ -- i ~ ~~ A~ ~~ • Time Logs Date From To Dur S Depth E. Depth_ Phase Code Subcode T Cor7iment 15:30 17:15 1.75 0 0 COMPZ RPCOM PULD P Rig up tools for handling slim hole directional assembly. Pick up slim hole assembly and torque up connections. 17:15 17:45 0.50 0 0 COMPZ RPCOM RURD P Rig up 3-1/2" handling tools. 17:45 18:00 0.25 0 0 COMPZ RPCOM SFTY P PJSM -running liner. 18:00 00:00 6.00 0 5,709 COMPZ RPCOM RCST P Runnin 3-1l2" B sand lateral liner with screens and swell ackers. 12/01 /2008 Run and set liner with MLZXP hanger packer. Pull out of hole and pickup whipstock and milling assembly. Make u and run in hole with whi stock and mills. 00:00 00:30 0.50 5,709 5,709 COMPZ RPCOM SFTY P PJSM in pipeshed -picking up han er acker assembl 00:30 02:15 1.75 5,709 5,914 COMPZ RPCOM RCST P Pick up and RIH with seal bore recepticle, extension joint, MLZXP hanger packer and 1 stand of drill pipe. PU wt 110k SO wt 100k, rotating wt 108k, rotating torque @ 30 r m 2.5k ftlbs. 02:15 02:45 0.50 5,914 5,914 COMPZ RPCOM DHEO P Shallow pulse test MWD pumping 95 m, 510 si. ood test. 02:45 03:15 0.50 5,914 6,390 COMPZ RPCOM RCST P TIH with liner on 5"drill pipe. 03:15 04:15 1.00 6,390 6,390 COMPZ RIGMNT RGRP T Replace hose on iron roughneck. Sim ops -inspect and service drawworks. 04:15 10:15 6.00 6,390 13,150 COMPZ RPCOM RCST P TIH with liner on drill pipe recording weights every 10 stands, monitoring displacement via trip tank. Rotated thru tight spots then continued in on elevators. Rotated last 4 stands down. Tagged bottom at 13188' MD. and picked up to setting depth. PU wt 190k, SO wt 125k, rotating wt 150k, rotating torque at 35 rpm 10k ft lbs. 10:15 10:45 0.50 13,150 13,150 COMPZ RPCOM CIRC P Orient hanger 22L pumping 110 gpm, 650 si. 10:45 12:15 1.50 13,150 7,334 COMPZ RPCOM CIRC P Break connection and drop ball. Pump down at 107 gpm, 630 psi. Ball on seat at 744 strokes. Set han er acker and release runnin tool. Pick up and confirm released. Close ipe rams and test packer to 2500 sifor5 minutes. Pressure held. 12:15 12:30 0.25 7,334 7,245 COMPZ RPCOM TRIP P POOH on elevators. 12:30 13:30 1.00 7,245 7,245 COMPZ RIGMNT SVRG P Inspect and service blocks, top drive and drawworks. 13:30 15:45 2.25 7,245 60 COMPZ RPCOM TRIP P POOH on elevators with liner running tools. 15:45 17:15 1.50 60 0 COMPZ RPCOM PULD P Lay down liner running tools and slim hole MWD. 17:15 18:00 0.75 0 0 PROD2 STK PULD P Pick up whipstock subs and handling e ui ment. • • `~ Time Logs Date From To Dur S. De th E De th Phase Code Subcode T Cor7iment 18:00 18:30 0.50 0 0 PROD2 STK PULD P Pick up and rack back MWD and millin assembl . 18:30 21:15 2.75 0 66 PROD2 STK PULD P Make up whipstock, subs and anchor. Orient whipstock and anchor. 21:15 22:15 1.00 66 66 PROD2 STK WPST P Make up milling assembly/MWD to whipstock and orient MWD to whi stock. 22:15 00:00 1.75 66 2,916 PROD2 STK WPST P TIH with whipstock and milling assembly on 5"drill pipe. Monitoring dis lacement via tri tank. 12/02/2008 Continue to run in hole with whipstock and 8-1/2"mills, MAD pass 6249' to 6298' (GR 6120' to 6169'), continue RIH to 7347', set whipstock (MLZXP collet depth 7347.67'), pull test 20k over, shear with 50k down, Top of whipstock @ 7280', circulate bottom's up, displace to OBM, mill window (TOW 7280', BOW 7297'), then 33' of 8-1/2" open hole to 7330', work window with mills, circulate a sweep to clean hole, monitor well- static, perform a 13 ppg FIT, rig down equipment, trip out to 5775', pump a dry job, continue ulling out of the hole to 185', la down bha to 84', download MWD, continue to la down millin assembl ,flush BOP stack. 00:00 02:15 2.25 2,916 6,249 PROD2 STK WPST P TIH with whipstock and milling assembly on 5"drill pipe. Monitoring dis lacement via tri tank. 02:15 02:45 0.50 6,249 6,298 PROD2 EVALFN OTHR P MAD pass 6249' to 6298' (GR depth 6120' to 6169'). Pumping 650 gpm w/ 1900 si-- 52% flow out. 02:45 03:30 0.75 6,298 7,200 PROD2 STK WPST P Continue trip in with whipstock assembl . 03:30 04:00 0.50 7,200 7,347 PROD2 STK WPST P Make top drive connection, circulate 650 gpm w/ 1980 psi--52% flow out, and orient whipstock to 25R. Pu wt 175k, SO wt 135k. 04:00 04:15 0.25 7,347 7,280 PROD2 STK WPST P Set whipstock (collet @ 7347.67'), (pulled tested 20k), set down 50k and shear off. PU wt 168k, SO wt 130k, Rot wt 150k. Rot 30 rpm w/ ®~ 6-7k ft Ibs of torque. Pumping 650 gpm w/ 2040 psi--52% flow out. Tag to of whi stock 7280'. 04:15 05:30 1.25 7,280 7,280 PROD2 STK CIRC P Circulate bottoms up with brine and displace well to OBM. Pumping 630 gpm w/ 2900 psi--53% flow out. Circulate 564 bbls. 05:30 13:3 8.00 7,280 7,297 PROD2 STK WPST P Mill window in the 9-5/8" 40 ppf L-80 casin .Pumping 630 gpm w/ 2900 psi--53% flow out. Rotate 70 to 120 rpm w/ 7-9k ft Ibs of torque. Weight ~~L_ QI ~„ ©~ ~ ~ on mills 0 to 6k. Top of window 7280', bottom of window 7297'. Pump a 30 bbl swee 9.2 / 150 vis . 13:30 15:30 2.00 7,297 7,330 PROD2 STK WPST P Continue to mill 33' of 8-1/2" open hole below bottom of window. Pumping 630 gpm w/ 2900 psi--53% flow out. Rotate 70 to 120 rpm w/ 7-9k ft Ibs of torque. Weight on mills 8 to 4k. ® ~ ~ ~. -e~s®®_ ~" a~; °~ s~f 6 • Tinte Logs ~ Date From To Dur S. De th E. De th Phase Code Subcode T Comment 15:30 17:30 2.00 7,330 7,330 PROD2 STK CIRC P Rotate and reciprocate from 7330' to 7279' to cleanup window. Pump a 35 bbl 9.2 ppg 150 vis sweep. Pumping 625 gpm w/ 2700 psi--52% flow out. PU wt 168k, SO wt 130k, Rot wt 150k. Rotate 120 rpm w/ 7k ft Ibs of for ue. 17:30 18:00 0.50 7,330 7,255 PROD2 STK OTHR P Monitor well- static. Rig up for FIT. 18:00 18:45 0.75 7,255 7,255 PROD2 STK CIRC P Perform a 13 ppg Formation integrity test. Pumping down drill pipe and annulus with the ri test um . 18:45 19:15 0.50 7,255 7,255 PROD2 STK TRIP P Rig down testing equipment. Blow down lines. 19:15 20:00 0.75 7,255 5,775 PROD2 STK TRIP P Trip out with milling assembly. Monitor well on the tri tank. 20:00 20:15 0.25 5,775 5,775 PROD2 STK CIRC P Pump a dry job. Blow down the top drive. 20:15 21:45 1.50 5,775 185 PROD2 STK TRIP P Continue to pull out of the hole with the milling assembly. Monitor well on the tri tank. 21:45 22:00 0.25 185 84 PROD2 STK PULD P Lay down BHA. 22:00 22:30 0.50 84 84 PROD2 STK OTHR P Download Sperry Sun MWD. 22:30 23:30 1.00 84 0 PROD2 STK PULD P Continue to laydown BHA. 23:30 00:00 0.50 0 0 PROD2 STK OTHR P Flush BOP stack. Pumping 850 gpm w/ 300 psi--61 % flow out. Rotate 30 r m. Clean and clear ri floor. 12/03/2008 Continue to flush BOP stack after milling, blow down choke line and top drive, rig up/test BOPE to 250 psi low and 3000 psi high.(Witness of test by AOGCC inspector John Crisp). Rig down 3-1/2" test joint, PJSM, change element on annular. Test annular with 5", 3-1/2"and 4" test joint, blow down lines, set Vetco/Gray wear bushing, change out lower IBOP and saver sub on the top drive. Rig up/test IBOP, rig down testing e ui ment, clear floor, service ri icku and make u drillin assembl for drillin "D" lateral. 00:00 00:30 0.50 0 0 PROD2 STK OTHR P Continue to flush BOP stack. Pumping 850 gpm w/ 300 psi--61 flow out. Rotate 30 rpm. Clean and clear ri floor. 00:30 01:00 0.50 0 0 PROD2 STK OTHR P Blow down chokel line and top drive. 01:00 02:15 1.25 0 0 PROD2 WELCTL OTHR P Rig up to test BOPE. ~.,....~_ ~.,... _ ....._a l ~ Time Low Date _ From To Dur S Depth E De th Phase Code Subcode T --- _ . _ -- Comment 02:15 10:15 8.00 0 0 PROD2 WELCTL BOPE P Test BOPE. Witness of test by AOGCC inspector John Crisp. Tested to 250 psi low and 3000 psi high. Chart all tests. Hold each test for 5 minutes. Tested with 3-1/2" and 5" test joint on upper (3-1/2" x 6" variable bore rams), lower (2-7/8" x 5" variable bore rams), and the annular. Tested all valves in the choke manifold, tested kill line valves, choke line valves and kill line. Tested two 4" floor safety valves, one 4" IBOP, 5" floor safety valve and 5" IBOP valve. Note: Lower pipe rams had to be cycled to hold, valve #17 in the choke manifold was serviced with grease to hold. Lower IBOP on the top drive failed. Annular failed with 3-1/2" test ~oint. 10:15 10:45 0.50 0 0 PROD2 WELCTL OTHR T Hydril not able to hold pressure. Lay down 3 1/2" test joint and rig down test a ui ment. 10:45 11:00 0.25 0 0 PROD2 WELCTL SFTY T PJSM on changing Hydril element 11:00 12:45 1.75 0 0 PROD2 WELCTL EQRP T Change out Hydril Element 12:45 13:45 1.00 0 0 PROD2 WELCTL OTHR T Pick up 5" test joint and rig up test equipment. Break-in new element by functioning 2 times each with 450 psi, 600 psi & 800 psi of closing ressure. 13:45 18:00 4.25 0 0 PROD2 WELCTL BOPE P Resume testing BOPE. Tested to 250 psi low and 3000 psi high. Chart all tests. Hold each test for 5 minutes. Tested with 3-1/2", 4" and 5" test joint with the annular. Tested with 4" test joint on upper (3-1/2" x 6" variable bore rams), lower (2-7/8" x 5" variable bore rams). Install Vetco/Gray wear bushing 13-7/16" OD x 9" ID x 38" Ion 18:00 19:00 1.00 0 0 PROD2 WELCTL OTHR P Blow down choke manifold, choke and kill lines. 19:00 20:30 1.50 0 0 PROD2 WELCTL EQRP T Change out lower IBOP on the top drive. Chan a saver sub as well. 20:30 21:00 0.50 0 0 PROD2 WELCTL OTHR P Rig up to test lower IBOP: 21:00 22:00 1.00 0 0 PROD2 WELCTL BOPE P Test lower IBOP to 250 psi low and 3000 psi high. Hold each test 5 minutes. OK. Chart test 22:00 22:30 0.50 0 0 PROD2 WELCTL OTHR P Rig down testing equipment. 22:30 23:00 0.50 0 0 PROD2 RIGMNT SVRG P Clean and clear rig floor. Service top drive. 23:00 00:00 1.00 0 96 PROD2 DRILL PULD P Pickup/make up drilling assembly for drilling "D" lateral (motor with 1.22 deg bend). Monitor well on the trip tank. Tirne Logs. Date From__To D_ur S. Depth E Depth Phase Code Subcode T Cor7iment 12/04/2008 24 hr summary Continue to pickup and make up 6-3/4" drilling assembly for drilling "D" lateral, shallow test MWD @ 96', continue with BHA to 370', trip in the hole with 4" drill pipe to 5840', change elevators, install circulating sub and crossover to 5" drill pipe, continue trip in with 5"drill pipe to 7186'. Slip and cut 145' of drilling line, adjust brakes, service rig. Continue trip to 7330 (Top of window @ 7280'), directional drill the "D" lateral to 8424', circualte 1073 bbls prior to pulling out to install two more stands of 4"drill pipe and check torque on service break of circ sub, monitor well-static, trip out to 5840', check torque on sub, install two more stands of 4", chan a elevators to 5", clean floor. 00:00 01:00 1.00 96 96 PROD2 DRILL OTHR P Upload Sperry Sun MWD 01:00 01:15 0.25 96 96 PROD2 DRILL CIRC P Shallow pulse test MWD tools. Pumping 260 gpm w/ 1490 psi--35% flow out. 01:15 01:45 0.50 96 370 PROD2 DRILL PULD P Continue to pickup/make up drilling assembly for drilling "D" lateral (motor with 1.22 deg bend). Monitor well on the tri tank. 01:45 03:30 1.75 370 5,840 PROD2 DRILL TRIP P Trip in the hole with 4"drill pipe. Monitor displacement on the trip tank. Fill i e eve 25 stands. 03:30 03:45 0.25 5,840 5,945 PROD2 DRILL TRIP P Change elevators to 5". Make up Downhole devices PBL sub and XT 39 to 4-1/2" IF crossover. 03:45 04:30 0.75 5,945 7,186 PROD2 DRILL TRIP P Continue trip in the hole with 5"drill i e. 04:30 06:00 1.50 7,186 7,186 PROD2 RIGMNT SVRG P Slip and cut 145' of 1-3/8" drilling line. Adjust brakes. Aquire SPR's. Grease crown. 06:00 06:30 0.50 7,186 7,330 PROD2 DRILL TRIP P Continue trip in the hole with 5"drill pipe. Note: Top of window 7280', bottom of window 7297'. No problems going throu h wind 06:30 12:00 5.50 7,330 7,810 PROD2 DRILL DDRL P Directional drill 6-3/4" "D" lateral. Max as observed 617 units. 12:00 18:00 6.00 7,810 8,346 PROD2 DRILL DDRL P Directional drill 6-3/4" "D" lateral. Max as observed 1083 units. 18:00 19:00 1.00 8,346 8,424 PROD2 DRILL DDRL P Directional drill 6-3/4" "D" lateral. Max as observed 551 units. 19:00 21:30 2.50 8,424 8,424 PROD2 DRILL CIRC P Circulate prior to short trip to install two stands of 4"drill pipe and check torque on service break of circulating sub.Circulate a total of1073 bbls. Pumping 320 gpm w/ 3100 psi--33% flow out. Rotate 110 rpm w/ 5k ft Ibs of for ue. 21:30 21:45 0.25 8,424 8,424 PROD2 DRILL OWFF P Monitor well- static. Blow down the to drive. 21:45 23:15 1.50 8,424 5,840 PROD2 DRILL TRIP P Trip out of the hole to the circualting sub. Pulled through window good. Monitor well on the tri tank. 23:15 23:30 0.25 5,840 5,840 PROD2 DRILL OTHR P Break the circulating sub, check and clean connections, redope, torque service break to 19200 ft Ibs of torque. Change handling equipment to 4". ®~. ® ~ ~ -_ • • Time Logs -- Date From To Dur S De th E. De th Phase Code Subcode T Comment ---_ _ -- 23:30 23:45 0.25 5,840 6,037 PROD2 DRILL TRIP P Trip in the hole with two more stands of 4" drill pipe (Total of 60 stands of 4"drill i e 23:45 00:00 0.25 6,037 6,037 PROD2 DRILL OTHR P Change elevators to 5". Clean and clear ri floor. 12/05/2008 Trip in the hole to 8424', acquire a replacement generator for the SWACO solids control van from ASRC, wire enerator/ check rotation, continue to directional drill the "D" lateral from 8424' to 10611'. 00:00 01:45 1.75 6,037 8,424 PROD2 DRILL TRIP P TIH with 5" DP. Monitor dis lacement on tri tank 01:45 06:00 4.25 8,424 8,924 PROD2 DRILL DDRL P Directional drill 6-3/4" "D" lateral. Max as observed 1741 units 06:00 06:45 0.75 8,924 9,050 PROD2 DRILL DDRL P Directional drill 6-3/4" "D" lateral. Max as observed 617 units. 06:45 09:30 2.75 9,050 9,050 PROD2 DRILL CIRC T Recip and circulate while waiting on replacement generator for MI solids control van 09:30 12:00 2.50 9,050 9,358 PROD2 DRILL DDRL P Directional drill 6-3l4" "D" lateral. Max as observed 2021 units. 12:00 18:00 6.00 9,358 9,959 PROD2 DRILL DDRL P Directional drill 6-3/4" "D" lateral. Max as observed 1022 units. 18:00 00:00 6.00 9,959 10,611 PROD2 DRILL DDRL P Directional drill 6-3/4" "D" lateral. Max as observed 1347 units. 12/06/2008 Continue to directional drill the 6-3/4" "D" lateral from 10611' to 12975'. 00:00 06:00 6.00 10,611 11,181 PROD2 DRILL DDRL P Directional drill 6-3/4" "D" lateral. Max as observed 674 units. 06:00 12:00 6.00 11,181 11,846 PROD2 DRILL DDRL P Directional drill 6-3/4" "D" lateral. Max as observed 1551 units. 12:00 18:00 6.00 11,846 12,512 PROD2 DRILL DDRL P Directional drill 6-3/4" "D" lateral. Max as observed 885 units. 18:00 00:00 6.00 12,512 12,975 PROD2 DRILL DDRL P Directional drill 6-3/4" "D" lateral. Max as observed 1350 units. 12/07/2008 Continue to directional drill the 6-3/4" "D" lateral from 12975' to 13189', circulate and reciprocate from 13189' to 13124', pump a 25 bbl sweep (9.4 ppg/ 200 vis), continue to circulate, monitor well- fluid falling slowly, short trip to 11686' and back to bottom @ 13189', circulate, pull two singles to place downhole devices circulating sub above the window, pump 1-/2" ball to open circ sub, after open- circulate at 500 gpm for a bottom's up+ then 800 gpm for 4 more bottom's up, pickup asingle- drop two 1-3/8" steel balls to close tool, acquire slow pump rates-verify tool shut, monitor well, pull out of the hole to 11754', pump a 27 bbl dry job, continue to ull out of the hole to 9947' midni ht. 00:00 03:15 3.25 12,975 13,189 PROD2 DRILL DDRL P Directional drill 6-3/4" "D" lateral. Max as observed 1350 units. 03:15 10:00 6.75 13,189 13,189 PROD2 DRILL CIRC P Circulate, pumping 320 to 296 gpm w/ 3570 to 3020 psi, rotate 120 rpm w/ 10k ft lbs. PU wt 188k, SO wt while rotating 145k, rotating and recip.from 13189'to 13,124'. Max as observed 838 units. 10:00 11:45 1.75 13,189 13,189 PROD2 DRILL CIRC P Pump 25 BBL, 9.4 ppg, 200 vis swee 11:45 12:30 0.75 13,189 13,189 PROD2 DRILL CIRC P Circulate, pumping 320 to 296 gpm w/ 3570 to 3020 psi, rotate 120 rpm w/ 10k ft lbs. PU wt 188k, SO wt while rotating 145k. rotating and recip.from 13189' to 13,124'. Max gas observed 278 units. Circulated over 5 Bottom's u ~ ~ ~ __~~~® ~m_ e_ ~ a Time Logs _ - --~ - Date__ From To Dur S, Depth E. De th Phase Code_ Subcode T_ Comment _ _ 12:30 13:00 0.50 13,189 13,189 PROD2 DRILL OWFF P Monitored well -fluid level falling slowl ,Install air sli s 13:00 14:30 1.50 13,189 11,686 PROD2 DRILL TRIP P POOH on elevators from 13,189' to 11,686' monitoring fill on TT. PU wt 185k, SO wt 110k. Record PU and SO wt's ever 5 stands. 14:30 14:45 0.25 11,686 11,686 PROD2 DRILL OWFF P Monitored well -fluid level falling slow) 14:45 15:30 0.75 11,686 13,189 PROD2 DRILL TRIP P TIH on elevators from 11,686' to 13189' monitoring fill on TT. Record PU and SO wt's every 5 stands. PU wt 190k, SO wt 100k. 15:30 17:30 2.00 13,189 13,189 PROD2 DRILL CIRC P Circulate, pumping 285 gpm w/ 2970 psi, rotate 120 rpm w/ 10k ft lbs. PU wt 190k, SO wt while rotating 145k. Rotating and recip.from 13189' to 13,124'. Pum ed a Bottom's u +. 17:30 18:00 0.50 13,189 13,112 PROD2 DRILL PULD P Pull out of hole to place the Downhole devices PBL circulating sub above the top of the window 7280' . La down two sin les. 18:00 18:30 0.50 13,112 13,112 PROD2 DRILL CIRC P Drop 1-1/2" activating ball to open sub, pump ball down at 5 bpm w/ 1740 psi - 27% flow out, for 740 strokes, then slow down to 1.5 bpm w/ 300 psi -11 % flow out, till ball on seat (1030 strokes). Pressure dropped from 500 psi to 380 psi indicatin orts o ened. 18:30 20:30 2.00 13,112 13,112 PROD2 DRILL CIRC P Circulate through the downhole devices PBL sub. Reciprocate from 13112; to 13050' (work PBL sub 7270' to 7208'). Pumped 500 gpm w/ 1350 psi- 45% flow out for 5500 strokes, then increased flow to 600 gpm w/ 1730 psi- 50 % flow out, 700 gpm w/ 2250 psi- 54% flow out, and finally 800 gpm w/ 2780 psi- 58% flow out. Pumped a total of 2085 bbls 5.5 BU. 20:30 21:00 0.50 13,112 13,112 PROD2 DRILL TRIP P pickup a single. Drop two 1-3/8" steel balls to close circulating sub. Pump balls down @ 5 bpm w/ 330 psi- 26% flow out for 500 strokes, then slow to 1.5 bpm w/ 220 psi- 9% flow out till balls on seat after 680 strokes. Pressuredup to 3410 psi to blow ball seat and close tool. 21:00 21:30 0.50 13,112 13,112 PROD2 DRILL CIRC P With circulation sub closed, obtain slow pump rates. # 1 mp 20 spm 480 psi, 30 spm 830 psi. #2 mp 20 spm 490 psi, 30 spm 810 psi. Verify tool is closed. 21:30 21:45 0.25 13,112 13,112 PROD2 DRILL OWFF P Monitor well- static. Blow down the to drive. e ~ ~ ~~® ®.. _ ,~ ~ _ ~~~~r~ ~~ ~~ ~;~ Time Logs _- Date From To Dur S. De th E. De th Phase Code Subcode T Comment 21:45 22:45 1.00 13,112 11,754 PROD2 __ DRILL TRIP _ P Pull out of the hole on elevators. Monitor displacement on the trip tank. Obtain PU and SO wt's every 5 stands. 22:45 23:00 0.25 11,754 11,754 PROD2 DRILL CIRC P Pump a 27 bbl dryjob (11.2 /71vis .Blow down the to drive. 23:00 00:00 1.00 11,754 9,947 PROD2 DRILL TRIP P Continue to pull out of the hole on elevators. Monitor displacement on the trip tank. Record PU and SO wt's ever 5 stands. 12/08/2008 Continue to pull out of the hole from 9947' to 6039', change handling tools to 4", break circ sub (retrieve 2 steel balss, 1 torlon ball), retorque sub/LD same, continue to pull out with drilling assembly, lay down BHA, download, continue to lay down bha. Clear and clean floor. PJSM, PU/MU/RIH with hole opener/cleanout assembly to 1900'. Conduct table top Rig evacuation drill. Continue to trip in to 5894', change handling tools to 5", Install string magnet on top of first single of 5", continue trip in to 9522' (obstruction), work hole t4 9616' continue to 12049' (obstruction). work hole to 12089' continue to 12592'. work hole fa 12659'. Continue trip to TD @ 13189'. Rotate and reciprocate to clean hole prior to displacement to 9.5 ppg VersOut breaker brine. 00:00 02:15 2.25 9,947 6,039 COMPZ DRILL TRIP P Continue to pull out of the hole on elevators. Monitor displacement on the trip tank. Record PU and SO wt's every 5 stands in open hole, every 10 stands in casin . 02:15 02:30 0.25 6,039 5,842 COMPZ DRILL TRIP P C/O from 5" handling tools to 4" and continue POOH 02:30 02:45 0.25 5,842 5,842 COMPZ DRILL RURD P Break connection on PBL Sub, Removed two steel balls and one Trolon ball. 02:45 05:00 2.25 5,842 370 COMPZ DRILL TRIP P Continue to pull out of the hole on elevators. Monitor displacement on the trip tank. Record PU and SO wt's eve 10 stands. 05:00 07:30 2.50 370 0 PROD2 DRILL PULD P Continue POOH laying down BHA and downloading MWD. Monitor dis lacement on the tri tank. 07:30 07:45 0.25 0 COMPZ WELLPF RURD P Clear floor and RU for BHA #12. 07:45 08:30 0.75 296 COMPZ WELLPF PULD P PJSM, MU BHA#12 to 296' 08:30 09:15 0.75 296 1,900 COMPZ WELLPF TRIP P TIH on elevators W/BHA #12 on 4" DP. Monitoring displacement on trip tank. Recording PUW & SOW every 10 stands. 09:15 09:45 0.50 1,900 1,900 COMPZ WELLPF SFTY P Table top Rig evacuation drill 09:45 11:15 1.50 1,900 5,894 COMPZ WELLPF TRIP P TIH on elevators W/BHA#12 on 4" DP. Monitoring displacement on trip tank. Recording PUW & SOW every 10 stands. 11:15 11:45 0.50 5,894 5,894 COMPZ WELLPF PULD P C/O to 5" handling equipment. PU ma net on to of first 'oint of 5" DP 11:45 13:00 1.25 5,894 9,522 COMPZ WELLPF TRIP P TIH on elevators W/BHA#12 on 5" DP. Monitoring displacement on trip tank. Recording PU wt & SO wt eve 10 stands. 13:00 14:15 1.25 9,522 9 616 COMPZ WELLPF UREM P Circ and rotate through obstruction. Pumping 7 bpm w/ 1410 psi-32% flow out. ~ ~~._._____ _ _ ~~. ~. ~e ~ a ~~ ®_ ~ ~~~~ ~f~ • Time Logs _ _ __ Date From To Dur S_Depth E De th Phase Code__ Subcode T Comment __ _ 14:15 15:15 1.00 9,616 12,049 COMPZ WELLPFTRIP P TIH on elevators W/BHA#12 on 5" DP. Monitoring displacement on trip tank. 15:15 16:00 0.75 12,049 12,089 COMPZ WELLPF UREM P Circ and rotate through obstruction. Pumping 5 bpm w/ 1050 psi- 26% flow out. Rotate 60 rpm w/ 9-10k ft Ibs of for ue. 16:00 16:30 0.50 12,089 12,592 COMPZ WELLPF TRIP P TIH on elevators W/BHA #12 on 5" DP. Monitoring displacement on trip tank. 16:30 16:45 0.25 12,592 12,659 COMPZ WELLPF UREM P Circ and rotate through obstruction. Pumping 5 bpm w/ 1050 psi- 26% flow out. Rotate 60 rpm w/ 9-10k ft Ibs of for ue. 16:45 17:15 0.50 12,659 13,189 COMPZ WELLPF TRIP P TIH on elevators W/BHA #12 on 5" DP to TD. Monitoring displacement on tri tank. Obtain aramiters. 17:15 23:45 6.50 13,189 13,189 COMPZ WELLPF CIRC P Rotate and reciprocate from 13,129' to 13,189' (magnet depth 7,259' tq 7 199' CBU @ 320 GPM, 2050 PSI- 32% flow out. Rotate 120 RPM, 10K tq. Max gas observed 215 units. Circulated 2907 bbls (5+ BU). Note: While circulating: Held pre job safety meeting with truck drivers and derrick hand. Cleaned trip tank, blow down line to stack. Blow down secondary kill line. Held pre job safety meeting with rig crew after VersOut breaker was mixed into one truck and truck was s otted. 23:45 00:00 0.25 13,189 13,189 COMPZ WELLPF OTHR P Flush both mud pumps with 9.2 ppg brine. Flush kill line with 9.2 ppg brine. 12/09/2008 Displace from 9.2 OBM to 9.5 ppg VersOut breaker brine, monitor well, pull out of the hole with hole opener/cleanout assembly to 6924' (window @ 7280'), pre job safety meeting, displace vis brine out of hole to 9.2 ppg brine @ 6924', displace to 9.2 ppg brine, monitor well, continue to pull out of the hole, lay down hole opener assembly. Clean floor, make up Baker whipstock retrieval assembly, run in the hole, clean slot, pull free, set back a stand, circulate bottom's up, obtain slow pump rates, monitor well, drop a 2.38" rabbit in the drill i e, ull out of the hole with the whi stock to 4795' midni ht. ~ __ ®~® ~__~ _ m ~~ Time Logs Date From To Dur S Depth E. De th Phase Code Subcode T Comment _ ___ 00:00 03:15 _ 3.25 13,189 13,189 COMPZ WELLPF CIRC P . Dis lace 9.2 OBM from well, change over to Versa out Breaker in the open hole. Work pipe from 13189 to 1129', rotate 50 rpm w/initial 10k ft Ibs/ final was 14k ft Ibs. PU wt prior 185k and 193k after, SO wt before 128k and after 118k, Rotating weight prior 153k and 153k after. Torque 10k before and 14k after. Pumping 5 bpm. Pump 25 bbls of LVT (6.8 ppg), 75 bbls Transition spacer (9.7 ppg), 408 bbls vis brine (9.2 ppg)w/ 1.75 % safe tube, 285 bbls VersOut Breaker (9.5 ppg), follow with 110 bbls of brine w/ 1.75% safe lube.(9.2 ppg). Initial circulating pressure 1040 psi, final 910 psi. Flush hoses back to the trucks after um in . 03:15 03:30 0.25 13,189 13,189 COMPZ WELLPF OWFF P Monitor well- taking a little. Blow down the to drive. 03:30 08:00 4.50 13,189 6,924 COMPZ WELLPF TRIP P Pull out of the hole on elevators. Record PU and SO wt's every 5 stands in open hole, every 10 stands in the casing. Hole taking 12 bph over calculated dis lacment. Monitor well on the tri tank. 08:00 08:30 0.50 6,924 6,924 COMPZ WELLPF SFTY P Pre job safety meeting on displacement from vis brine (9.2 ppg) to brine 9.2 08:30 09:00 0.50 6,924 6,924 COMPZ WELLPF PULD P Bring tools to the floor for next BHA. Work logistics to get trucks lined up for dis lacement. 09:00 10:15 1.25 6,924 6,924 COMPZ WELLPF CIRC P Displace from vis brine to brine (9.2 ppg) w/ .6% safe tube. Pumping 5 bpm w/ 390 psi-27% flow out, 6 bpm w/ ??? psi, 7.5 bpm w/ 810 psi-35% flow out. Reciprocate from 6924' to 6844'. Rotate 50 rpm w/ 5-6k ft Ibs of torque, final of 4k ft Ibs. PU wt 150k, SO wt 125k, Rot wt 148k.. 10:15 10:45 0.50 6,924 6,924 COMPZ WELLPF OWFF P Monitor well- slight losses, calculated @ 6 bph. Blow down top drive. 10:45 11:15 0.50 6,924 5,897 COMPZ WELLPF TRIP P Pull out of the hole. Monitor well on the tri tank. 6 b hover calculated. 11:15 11:30 0.25 5,897 5,897 COMPZ WELLPF OTHR P Change elevators from 5" to 4". 11:30 13:15 1.75 5,897 299 COMPZ WELLPF TRIP P Continue to pull out of the hole. Monitor well on the trip tank with 6 b h losses. 13:15 14:30 1.25 299 0 COMPZ WELLPF PULD P Lay down hole opener BHA. Monitor well on the trip tank. Hole took 67 bbls over calculated for tri . 14:30 14:45 0.25 0 0 COMPZ WELLPF OTHR P Clear and clean rig floor. Monitor well on the tri tank w/ 7 b h losses. ~~ .~ s~ .~ e ® m~ ~e® ~ ~~a 4~ ~,~f ~i~ __~® -- - # ! Time Logs T __-- - -- - -- ----- - - _ - - Date From To _ _ Dur S De th E. De th Phase Code Subcode T Comment ~~ - - - - - 14:45 15:30 0.75 0 159 COMPZ FISH PULD P Pickup/ make up whipstock retrieval Monitor well on the trip tank w/ 7 b h losses. 15:30 18:30 3.00 159 7,199 COMPZ FISH TRIP P Trip in the hole with retieving hook assembly with a string magnet to pull whipstock. Monitor well on the tri tank. 4-6 b hover calculated. 18:30 20:15 1.75 7,199 7,286 COMPZ FISH FISH P PU wt w/o pumps 170k, SO wt with pumps 175k. SO wt 122k w/o pumps, SO wt with pumps 132k. Work hook to find slot of whipstock. After locating slot, rotate pipe 180 de ,then wash from 7291' to 7281' (Slot of whipstock @ 7286') pumping 67 spm w/ 720 psi-32% flow out. Max gas observed 446 units. Pulled whipstock assembly free with 205k. Fluid in the hole dropped confirming "B" lat o en to wellbore. Pumping 50 spm w/ 640 psi- 23% flow out (loss of 6% on flow meter). Approx 40 bbl er hour losses. 20:15 20:30 0.25 7,286 7,268 COMPZ FISH TRIP P Pulled whipstock assembly free with 205k on weight indicator (30K over). Fluid in the hole dropped confirming "B" lat open to wellbore. Pull a stand and set back (bottom of anchor @ 7268' . 20:30 22:00 1.50 7,268 7,268 COMPZ FISH CIRC P Circulate at 30 spm w/ 160 psi- 13% flow out, increase pump rate to 50 spm w/ 410 psi-23% flow out after 80 bbls pumped. Pumped a total of 527 bbls (BU 375 bbls). Losses of 47 b h. Max as 20 units. 22:00 22:15 0.25 7,268 7,268 COMPZ FISH CIRC P Acquire slow pump rates. Mud pump #1, 20 spm/30 spm= 90/160 psi. Mud pump #2: 20spm/30 s m=80/150 si. 22:15 22:30 0.25 7,268 7,268 COMPZ FISH OTHR P Monitor well. 40 bph losses. Drop a 2.38" hollow rabbit with 120' of wire to rabbit drill i e. 22:30 00:00 1.50 7,268 4,795 COMPZ FISH TRIP P Pull out of the hole with whipstock. Monitor well on the tri tank. 12/10/2008 Continue to pull out of the hole with the whipstock from 4795' to whipstock retrieval BHA, lay down BHA (retrieved rabbit at the jars). Lay down whipstock assembly (mills appeared to walk off slide to the right, anchor to whipstock orientation appears that whipstock face is right of anchor 7 degrees). Clean magnets, lay down Baker tools from rig floor. Clean and clear rig floor. PU casing tools to run Seal Bore Diverter. Pickup and make up Seal Bore Diverter, orient face of Seal Bore Diverter 17 deg right of MLHR Anchor, run in the hole on 5"drill pipe to latch collet into the "B" lateral MLZXP @ 7347.67' (bottom of seals 7379.42', profile for RAM hanger will be 7275.89'). Set down ,pull test, set down10k, pressure test to 2500 psi (IBP, Seals). Release from Seal Bore Diverter. Pull out of the hole with running tools. Lay down tools, break and lay down whipstock assembly. Rig up to run liner for "D" lateral, pre job safety meeting, run 3-1/2" 9.2 ppf L-80 SLHT screen & blank liner to 5824' midni ht, chan a elevators to 5". ms ~ .. ~ .. m ® m ~_ ~e d®e Time Logs _ - _ _-- - - Date__ From _ To_ _ _ _Dur S Depth E Depth., Phase Code Subcode _ T_ _Comment _ 00:00 02:15 2.25 4,795 228 COMPZ FISH TRIP P Pull out of the hole with whipstock. Monitor well on the trip tank. Retrieved the 2-3l8" rabbit with wire- landed on the jars. Lost 101 bbls over calculated displacment. Losses are 28 to 23 bbl er hour from midni ht to 2 am. 02:15 03:00 0.75 228 69 COMPZ FISH PULD P Lay down BHA (retrieved 2-3/8" rabbit at the 'ars . 03:00 05:00 2.00 69 0 COMPZ FISH PULD P Lay down whipstock assembly (mills appeared to walk off slide to the right, anchor to whipstock orientation appears that whipstock face is right of anchor 7 de rees). 05:00 05:15 0.25 0 0 COMPZ FISH PULD P Clean magnets, lay down Baker tools from rig floor. Clean and clear ri floor. 05:15 05:45 0.50 0 0 COMPZ CASING RURD P PU casing tools to run Seal Bore Diverter. 05:45 06:00 0.25 0 0 COMPZ CASING SFTY P Pre job safety meeting on picking up Seal Bore Diverter 06:00 06:45 0.75 0 115 COMPZ CASING RUNL P Pickup and make up Seal Bore Diverter. Note: fluid loss: From midni ht to 0600 hrs = 150 bbls 06:45 07:00 0.25 115 115 COMPZ CASING OTHR P Orient MLHR Anchor to Seal Bore Diverter (Face opening oriented 17 de rees ri ht of anchor . 07:00 07:30 0.50 115 288 COMPZ CASING RUNL P Make up Seal Bore Diverter running assembl BHA. 07:30 11:15 3.75 288 7,379 COMPZ CASING RUNL P Run 4-1/2" Seal Bore assembly in the hole on 5"drill i e. 11:15 11:30 0.25 7,379 7,379 COMPZ CASING RUNL P Engage Seal Bore MLHR anchor into "B" lateral MLZXP acke ,seals isolating holes in the Casing Seal Bore receptacle of "B" lateral, slacked off to engage MLHR Production Anchor. Set down 22k, pull tested to 255k (75k overpull). Set down 10k, then test seals & IBP to 2500 psi for 5 min.. Test good. Bleed pressure down to 1000 psi, pickup to release running tool, bleed pressure to zero. PU wt 179K, SO wt 135k, Block wt 75k. Note: Fluid losses wre 25 bph prior to sealin off the "B" lateral. Fluid losses to the "B" lateral are now isolated. Well now takin 6 b h 11:30 13:45 2.25 7,379 181 COMPZ CASING RUNL P Pull out of the hole with Seal Bore Diverter running tools. Monitor losses on the trip tank. Losses are 5 to 6 b h. 13:45 14:45 1.00 181 0 COMPZ CASING OTHR P Lay down running tools for the Seal Bore diverter. Clean ma nets. 14:45 15:45 1.00 0 0 COMPZ FISH PULD P Pickup whipstock BHA from pipe shed and break connection. Lay down same. m e .m® _® _ ~~_e Time Logs _ _ Date From To Dur S De th E. De th Phase Code Subcode T Comment __. _ _ - - 15:45 16:30 0.75 0 0 COMPZ CASING RURD P Rig up to run 3-1/2" 9.2 ppf L-80 SLHT Screen/Blank liner for the "D" lateral. 16:30 17:00 0.50 0 0 COMPZ CASING SFTY P Pre job safety meeting on running liner. 17:00 18:00 1.00 0 604 COMPZ CASING RUNL P Run 3-1/2" 9.2 ppf L-80 SLHT lir]~r with Reslink screens and TAM freeca s water activated swell acker., Note: Fluid losses from 0600 tq 1800 hrs = 219 bbls. 18:00 23:45 5.75 604 5,824 COMPZ CASING RUNL P Continue to run 3-1/2" 9.2 ppf L-80 SLHT liner with Reslink screens and TAM freecaps (water activated swell packer). Monitor well on the trip tank with 5 to 6 bph losses. PU wt 110k, SO wt 102k 23:45 00:00 0.25 5,824 5,824 COMPZ CASING OTHR P Change out handling equipment to 5". 12/11 /2008 Continue to run 3-1/2" 9.2 ppf L-80 SLHT screen & blank liner from 5824' to 5878', Rig down GBR tools, MU BHA for running liner, run in the hole on 5" drill pipe, exit Seal Bore Diverter ramp @ 7285.32' (no problems), Continue to run in the hole to 11516', rotating through tight spots @ 9900' and 10904'-11504', worked through obstruction @ 11504' to 11516'. Attempt to go deeper with no progress. Pull out of the hole from 11516' to 11474' (tight). With the top of the liner @ 11477', drop a 29/32" ball to release liner, pull running tools from 5660' to 5619'. Noticed overpull, worked free, continue pulling out with running tools to 5082'. Slip and cut drilling line. Service the rig. Continue pulling out, lay down the Baker running tool- Junk ring slide downbecause thread ring had unscrewed- thread ring was deformed. Change out the HRD-E liner running tool. Make u remainin BHA, tri in to 3981' with assembl . 00:00 00:45 0.75 5,824 5,878 COMPZ CASING RUNL P MU Baker RAM hanger assembly to 5878'. 00:45 01:15 0.50 5,878 5,878 COMPZ CASING RURD P Rig down GBR tongs. Bring completion tools to floor, then to pipe shed. Clear and clean ri floor. 01:15 01:30 0.25 5,878 6,052 COMPZ CASING RUNL P MU running BHA. Magnets, boot baskets, HWDP to 6052'. PU wt 118k, SO wt 110k. Rot wt 112k w/ 30 r m-for ue 3500 ft lbs. 01:30 03:00 1.50 6,052 7,384 COMPZ CASING RUNL P Run in hole with 5"drill pipe. Exit seal Bore diverter ramp @ 7285.32', No indication of any problems. Parameters @ 7000' were: PU wt 132k, SO wt 120k, Rot wt 125k w/ 30 m - 4k ft Ibs of for ue. 03:00 09:30 6.50 7,384 11,516 COMPZ CASING RUNL P Running liner in open hole from 7385'. to 1.1,516' MD. Rotating through tight spots at 9,900' MD, and 10 904' to 11504' MD. Worked throu h obstruction at 11,504' to 11, 516' MD. 09:30 10:45 1.25 11,516 11,516 COMPZ CASING RUNL T Attempt to work through obstruction at 11,516' MD 45 RPM, 13.5K TO, PU 182K, ROT 142K - no ro ress mm ~~ ®® I _ _.._ ~.e.-- ~ ~ _-® ....~.~.. _ _ _. ~ ~_ .__~ .._._ .__. _ _ _ L. Time Lo s Date From To Dur S. De th E. De th Phase Code Subcode T Comment 10:45 12:00 1.25 11,516 11,516 COMPZ CASING RUNL T Attempt to POOH from 11,516' MD hun u at 11 474' worked pipe with 40 to 45 RPM, 13.5K TQ, max pull 310K. No progress. PU wt 182k, Rot wt 142k, no down wt. Fluid losses 9.5 b h. 12:00 14:30 2.50 11,516 11,477 COMPZ CASING RUNL T Continue to work "D" lateral liner.from 11500' to 11474', roate 40 rpm w/ 13500 ft Ibs of torque. Maximum pull to 310k on weight indicator. Monitor well on the trip tank. 14:30 15:30 1.00 11,477 11,477 COMPZ CASING CIRC T With liner shoe 11477' and top o"f liner 5605.76'. Drop a 29/32" ball to release from liner. Pump ball down @ 3 bpm w/ 180 psi- 17% flow out. Ball on seat after 680 strokes. Pressure to 3500 psi. Pickup 7.5', then pressure up to 4500 psi to blow ball seat. Blow down the to drive. 15:30 16:30 1.00 5,660 5,619 COMPZ CASING RUNL T Pull running tools from 5660' to 5619'. Noticed overpull while pulling running tools out of the RAM Hanger. Work free. Pulled 50k over. Monitor well on the tri tank. 16:30 16:45 0.25 5,619 5,082 COMPZ CASING RUNL T Continue to pull out of the hole with runnin tools to 5082'. 16:45 17:45 1.00 5,082 5,082 COMPZ RIGMNT SVRG T Slip and cut 150' of 1-3/8"drilling line. Monitor well on the trip tank with 10 b h losses. 17:45 18:45 1.00 5,082 5,082 COMPZ RIGMNT SVRG T Service rig, crown sheaves, top drive and drawworks. 18:45 20:00 1.25 5,082 0 COMPZ CASING RUNL T Continue to pull out of the hole with running tools from 5082' to surface. Monitor well on trip tank w/ 30 bbls over calculated fro the tri . 20:00 22:15 2.25 0 0 COMPZ CASING OTHR T Lay down Baker liner running tool to the pipe shed. Junk cover had slid down the assembly because threaded ring had unscrewed. Threaded ring deformed. Remove Junk rin and thread form assembl . 22:15 22:45 0.50 0 45 COMPZ FISH PULD T Change out the HRD-E liner running tool. Drift assembl to 2.45". 22:45 23:00 0.25 45 174 COMPZ FISH PULD T Make up remaining BHA to 174.20'. 23:00 00:00 1.00 174 3,981 COMPZ FISH TRIP T Trip in the hole to 3981' with assembly to engage RAM liner han er f/ the "D" lateral. _, ~ Pat,~~ Time Logs _ __ -- --~ Date --- -- From To Dur S. De th E._De~ih_ Phase Code Sub_code__ T Comment _ _ 12/12/2008 24 hr Summary Finish making up Liner retrieval BHA (HRD-E), trip in f/ 3981' with assembly to 5591' engage fish with top of RAM hanger @ 5605.76', work pipe to try and make hydraform centralizers at the bottom of the joints of liner (able to work pipe 14' f/11485' to 11471'), break off single. Rig up Schlumberger WL, run in the hole with wireline (unable to get to planned cut depth of 7371.44'), attempt to pump down @ 5 bpm w/ 190 psi, no good. Cut liner on jt # 149, estimated 2' down from box (estimated 6570'). Pull out of the hole with wireline, rig down Schlumberger wireline. Pull out of the hole with fish. Rig up GBR, lay down RAM hanger and 31 joints of 3-1/2" liner (29 jts + 2 Reslink screens= 31 joints+ cutoff 3.4' of jt # 149 , 29 hydraforms centralizers, 2 TAM freecaps (swell packers), rig down GBR, strap and rabbit joints layed down. Total length of fish from top of Ram Liner hanger = 969.73', bring Baker fishing tools to the floor, MU BHA to 28'. Note: To of RAM Han er 5601.76' + 969.73' = To of fish 3-1/2" liner 6571.49'. 00:00 01:00 1.00 3,981 5,591 COMPZ FISH TRIP T Continue to trip in the hole to 5591' with assembly to engage RAM liner han er f/ the "D" lateral.. 01:00 05:15 4.25 5,591 11,473 COMPZ FISH TRIP T PU single (31.79') and a 15.23' pup jnt. Obtain parameters prior to tagging up. UP 175K, DN 130K, ROT 140K, RPM 30 w/ 6k ft Ibs of torque. Tagged up at 5606' (top of Liner Han er , SO and latch u with retreivin tool.. Shoe at 11477. Worked pipe to shift H droforms to pin end of liner Jnts. Park string with shoe at 11473' (estimated 15k overpull), top of RAM hanger @ 5601.76'. 05:15 09:30 4.25 11,473 11,473 COMPZ FISH ELNE T With string sitting in slips. R~ U _ Schlumberger Wire line to cut liner w/ 2-3/8" chemical cutter. 09:30 12:15 2.75 11,473 6,570 COMPZ FISH ELNE T Schlumberger wire line run in the hole. Attempt to pump down @ 5 bpm w/ 190 psi- 25% flow out. Could not et as dee as planned 7371' cut depth. Cut liner @ estimated 6570' with 2-3/8" chemical cutter. Cut liner 't # 149 a rox 2' below to of box. 12:15 13:30 1.25 6,570 6,570 COMPZ FISH ELNE T Pull out of the hole with Schlumber er wireline. 13:30 15:00 1.50 6,570 6,570 COMPZ FISH ELNE T RD Schlumberger wire line unit. 15:00 17:00 2.00 6,570 977 COMPZ FISH TRIP T POOH with 5"drill pipe from estimated 6570' to Baker liner running tool with RAM hanger. Did not notice any overpull. PU wt 158k. Fluid losses a rox 11 b h. 17:00 18:00 1.00 977 977 COMPZ FISH RURD T Rig up GBR to break and lay down liner. 18:00 21:45 3.75 974 0 COMPZ FISH PULD T Lay down Baker liner running tool with Ram Hanger. Then lay down a total of 31 its + cut off (3.4' of jt # 149): 29 joints of 3-1 /2" 9.2 ppf L-80 SLHT liner, (2) Reslink screens, (29) 6-1/8" Hydraforms, (2) TAM freecap swell packers (freecaps were still in original position on the joints). Total length of fish from top of RAM hanger is 969.73' la ed down. 21:45 22:15 0.50 0 0 COMPZ FISH RURD T Rig down GBR tools. ~~, ~ an . Time Loss_ Subcode T Comment D e th Phase Code Date From To I~ur S. De th E - 22:15 22:45 0.50 28 __ _ _ COMPZ _ FISH OTHR T Clean and clear floor. Bring tools to floor for overshot run. Measure cutoff to be 3.40". Strap and rabbitjoints layed down. Will not rabbit to 2.867" as originally. Attempt to rabbit to 2.85", all will not rabbit. Some would not rabbit to 2.76". 22:45 00:00 1.25 0 28 COMPZ FISH PULD T Make up Baker Fishing BHA: Overshot w/ 3-1/2" mill control packoff and grapple, crossover, 7-3/4" Bowen Lub Bumper Sub, 7-3/4" Bowen Oil Jar, crossover to 28'. 12/13/2008 Finish making up Fishing BHA from 28' to 119', run in the hole to 6494' with overshot, space outwith drill pipe, rotate over liner, pickup 13k over, set in slips, pre job safety meeting, rig up Schlumberger WL, run in the hole with 2-3/8" chemical cutter to 6828', pump down wireline (5 bpm w! 1410 psi) to 7479'. Pickup wireline to cut approximate 2' below box of joint # 124 (approx 7371.4'). Pull out with wireline, rig down Schlumberger wireline. Pickup, lay down spaceout pups, lay down two singles of 5"drill pipe to 7199'. Finish rigging down Schlumberger wireline. Pull out of hole with fishing BHA and fish, lay down BHA, lay down fish 799.22' :(cuttoff jt with overshot, 24 jts+ 1 Reslink screen + 1.27' cutoff on jt #124, 24 hydraform centralizers, two freecaps). Note: Top of fish (3-1/2" liner) @ 6571.49' + 799.22' = 7370.71' =top ofjt # 124 left in the hole. Clean floor, pickup tools to the floor, make up dummy overshot assembly, run in the hole to 7245', PU wt 175k, SO wt 132k, Rot wt 150k w/8k ft Ibs of torque- 20 rpm. Obtain pump parameters: 20 spm w/ 70 psi, 30 s m = 70 si, 40 s m = 100 si, 50 s m = 160 si. Tri in hole slow and to to of 3-1/2" liner 7373.13'. 00:00 00:15 0.25 28 119 COMPZ FISH PULD T Finish making up BHA to fish 3-1/2" liner. 00:15 03:00 2.75 119 6,494 COMPZ FISH TRIP T Trip in the hole with 5"drill pipe to 6494' with overshot. PU wt 165k, SO wt 135k. 03:00 04:00 1.00 6,494 6,572 COMPZ FISH PULD T Pickup two singles, 31.79' then 31.85', follow with a 15.23' pup and a 5.01. Tag liner top @ 6574.78' swallow to 6577.11' Set down 15k, icku to 178k on wt indicator. 04:00 04:15 0.25 6,572 6,572 COMPZ FISH SFTY T Pre job safety meeting. 04:15 07:15 3.00 6,572 6,572 COMPZ FISH RURD T Rig up Schlumberger wireline. 07:15 09:30 2.25 6,572 6,572 COMPZ FISH ELNE T Run in the hole with wireline and 2-3/8" chemical cutter to 6828' pumped down @ 5 bpm w/ 1410 psi to .7479'. Pulled back up and cut liner at ~ 7371.4'. Cut liner jt # 124 a rox 2' below to of box. 09:30 15:15 5.75 7,371 0 COMPZ FISH TRIP T POOH with 5" drill pipe from estimated 7371" to Baker Overshot. Did not notice any overpull. PU wt 170k. Fluid losses a rox 8 b h. 15:15 15:45 0.50 0 0 COMPZ FISH TRIP T LD BHA and rig up GBR ®e_ a -____® ~ ® ~ _ - ~ ~ ,..,~. Time Logs _ ___ I Date From __ To Dur S De th ---- E De to Phase Code Subcode T Comment _ 15:45 18:00 2.25 0 0 COMPZ FISH TRIP T POOH with 25 jnts of liner and one Resinject Reslink screen. Lay down fish 79922' :(cuttoff jt #149 with overshot 27.84', 24 jts+ 1 Reslink screen + 127' cutoff on jt #124 (left 29.96' in the hole) , 24 hydraform centralizers, two freecaps). Note: Top of fish (3-1/2" liner) was @ 571.49' + 79922' = 7370.71' = toa of jt # 124 left in the hole. Note: fluid losses from 0600 to 1800 hrs = 181 bbls of brine. 18:00 18:30 0.50 0 0 COMPZ FISH OTHR T Clean and clear rig floor. 18:30 19:00 0.50 0 0 COMPZ CASING RUNL T Pick tools to the rig floor. 19:00 19:30 0.50 0 0 COMPZ CASING SFTY T Pre job safety meeting 19:30 21:00 1.50 0 331 COMPZ CASING RUNL T Pickup BHA: Make up the overshot assembl dumm run. 21:00 23:15 225 331 7,245 COMPZ CASING RUNL T Run overshot dummy assembly in the hole on 5"drill i e. 23:15 23:30 025 7,245 7,245 COMPZ CASING RUNL T Obtain parameters: PU wt 175k, SO wt 132k, Rot wt 150k w/ 8k ft Ibs of torque- 20 rpm. Pump 2 bpm w/ 70 psi-14% flowout, 3 bpm w/ 70 psi-16% flow out, 4 bpm w/ 110 psi-22% flow out, 5 bpm w/ 160 psi 27% flow out. 23:30 00:00 0.50 7,245 7,373 COMPZ CASING RUNL T Work down slow and to to of 3-1/2" liner with cutlip guide of overshot 7373.13' with 4k. 12/14/2008 Pick up above top of 3-1/2" "D" lat liner, rotate down slow to 7373' w/ 20 rpm and 8k ft Ibs of torque. Rotating wt 150k. slack of to 7396' (should have no-go out at 7385.58'), saw a little bit of flicker on wt indicator @ 7382', but continued to 7396' along side of liner, pumped 20 spm with 50 psi-10% flow out, 30 spm w/ 80 psi-17% flow out (not over liner). Picked up above top of liner, went down slow to 7386' w/ 8k setting down on no-go (Did not even see top of liner). Pumped 20 spm w/ 290 psi- 8% flow out, confirming over liner. Picked up above liner again, tagged top @ 7313.13', picked up above top, rotated to 7313', slacked off and no-go again at 7386'. Note: Did not see anything at the top of the SealBore Diverter, also did not see anything at the ramp going into open hole. Note: Cutlip guide to no go = 12.45' measured, packoff up .95' from cutlip guide (packoff to no go 11.49'). Monitor well, POOH, UD BHA, redress overshot with 3-1/2"grapple and mill control packoff, clean & clear floor, MU/RIH with tie in D lat liner assembly, RIH on 5" drill pipe to 7334', PU 175k, SO wt 130k, .Rot wt 152k, work over liner top @ 7373', slack off to 7377', pull test to 10k over (185k, verify over liner), continue down to latch in RAM hanger w/ 40k (no indication of snap in), pull to 30k over, set down 55k on collet. Drop 29/32" ball to release RAM Hanger, pump down @ 3bpm, pressure to 2750 psi to release. Pull out of the hole laying down 5" drill pipe to 173', Lay down BHA and liner running tool. Remove Baker tools from floor. Pre job safety meeting on laying down 11 stands of 5"drill pipe and 62 stands of 4" drill pipe from the derrick. Lay down all 5", chan a elevators to la down 62 stands of 4"drill i e ~ w ®_ _ ~ .~.-. ~ ~ ~ ~a~ ~u ~~f Time Logs _ Date From To Dur S De th E. Depth Phase Code Subcode T _Comment _ _~ 00:00 00:45 0.75 7,373 7,386 COMPZ CASING RUNL T Pick up above top of 3-1/2" "D" lat liner, rotate down slow to 7373' w/ 20 rpm and 8k ft Ibs of torques Rotating wt 150k. slack of to 7396' (should have no-go out at 7385.58'), saw a little bit of flicker on wt indicator @ 7382', but continued to 7396' along side of liner, pumped 20 spm with 50 psi-10% flow out, 30 spm w/ 80 psi-17% flow out (not over liner). Picked up above top of liner, went down slow to 7386' w/ 8k setting down on no-go (Did not even see to of liner). Pumped 20 spm w/ 290 psi- 8%floty out, confirming over liner. Picked up above liner again, tagged top @ 7313.13', picked up above top, rotated to 7313', slacked off and no-go again at 7386'. Note: Did not see anything at the top of the SealBore Diverter, also did not see anything at the ramp going into open hole. Note: Cutlip guide to no go = 12.45' measured, packoff up .95' from cutli uide ackoff to no 0 11.49' . 00:45 03:30 2.75 7,386 331 COMPZ CASING RUNL T Pickup above top of liner, monitor well- losses of 9 bph. Pull out of the h ole on elevators. Monitor well on the trip tank. hole took 33 bbls over calculated for tri . 03:30 05:00 1.50 331 0 COMPZ CASING RUNL T Lay down BHA (Dummy tie in to u er lateral . 05:00 05:45 0.75 0 0 COMPZ CASING OTHR T Inspect overshot. Saw signs of setting on liner top. Obtain pictures. Break and dress overshot with a 3-1 /2"grapple and mill control ackoff. Tor ue connections. 05:45 06:30 0.75 0 0 COMPZ CASING OTHR T Lay down Bakerjars and Bumper sub. Pickup a Bumper sub for tie back run. Clean and clear ri floor. 06:30 08:15 1.75 0 294 COMPZ CASING RUNL T Make up liner tie in BHA, clean ma nets. 08:15 11:30 3.25 294 5,600 COMPZ CASING RUNL T Run in the hole with liner tie in assembl from 294' to 5600'. ~ ~ Time Lois --- Date _ From To Dur S De th E De th Phase -- Code Subcode T Comment - 11:30 13:15 1.75 5,600. 11,473 COMPZ - CASING -- RUNL P Continue to run in the hole with "D" lateral tie in assembly f/ 5600' to 7334', obtained parameters: Up 175K/ Dn 130K, Rot wt 152k w/ 7k ft Ibs of torque. Pumping 3 bpm w/ 160 psi- 16% flow out. Continue RIH to 7373' tagging liner top with 4K. Rotate down with overshot to 7377'. Pulled up with 185K to verify overshot engaged liner. Continued down to 7381 to latch RAM hanger into Seal Bore Diverter. Set down 40k on RAM Hanger, no noticeable latch in. Pull 30k over ,then set down 55k on collet.. 13:15 14:15 1.00 11,473 7,620 COMPZ CASING CIRC P Drop 29/32" ball to release Liner running tool, pumping @ 3 bpm with 160 psi-16% flow out. Ball landed and seated after 1050 strokes, pressured up to 2750 releasing liner running tool. Note: Fluid losses from 0600 hrs to 1800 hrs: 86 bbls. 14:15 19:45 5.50 7,620 173 COMPZ CASING RUNL P POOH LD 5" DP from 7620' to 173' 19:45 20:45 1.00 173 0 COMPZ DRILL PULD P LD liner running BHA. Total fluid lost on tri was 55 bbls over calculated. 20:45 22:00 1.25 0 0 COMPZ DRILL PULD P Lay down Baker tools from rig floor. Clear and clean floor. 22:00 22:15 0.25 0 0 COMPZ DRILL SFTY P Pre Job safety meeting on laying down drill i e from the derrick. 22:15 22:45 0.50 0 0 COMPZ DRILL PULD P Pickup mousehole, install in rotary table. Monitoring well on the trip tank. 22:45 23:45 1.00 0 0 COMPZ DRILL PULD P Lay down 11 stands of 5"drill pipe from derrick, usin the mouse hole. 23:45 00:00 0.25 0 0 COMPZ DRILL OTHR P Change elevators to 4". Then planning to -ay down 62 stands of 4" dp from the derrick. Monitoring well on the tri tank. 12/15/2008 Lay down 62 stands of 4" drill pipe from the derrick, change handling tools, pre job safety meeting. Pickup/Make up/run in the hole with 33 joints of 3-1/2" 9.2 ppf L-80 IBT-m tubing, pull out of the hole (change seal rings) stand back on the driller's side for the "D" lateral completion. Pickup/make up/ run in the hole with 143 joints of 3-1/2" 9.2 ppf L-80 IBT-m tubing, service rig, continue to run in the hole with tubing a total of 231 joints (77 stands). Pull out of the hole 8 stands and stand back on the off driller's side for the mainbore completion. Shut down for weather- Phase III for entire Kuparuk field. Note: The wind died down after midnight thirty, Roads and pads was contacted as to the status and when the could clear the road to 3K ad. Will check back after 3 or 4 am. 00:00 05:15 5.25 0 0 COMPZ DRILL PULD P Lay down 62 stands of 4" dp from the derrick. Monitoring well on the trip tank. 05:15 05:45 0.50 0 0 COMPZ DRILL OTHR P Clean and clear rig floor. 05:45 07:00 1.25 0 0 COMPZ RPCOM RURD P Change out handling equipment to icku 3-1/2" tubin . Ri u GBR. 07:00 07:15 0.25 0 COMPZ RPCOM SFTY P Pre job safety meeting on picking up tubin . mm ~_....__.._... ®® ~~...w® ®~ ~ : _ ~ ag. 3~ F 3.F J C Time Logs Date From To Dur S De th E_ . Depth_ Phase Code Subcode _ T _ Comment _ ___ 07:15 08:00 0.75 0 1,020 COMPZ RPCOM PULD P Pickup 33 joints of 3-1/2" 9.2 ppf L-80 IBT-m tubing, run in the hole. All tubing was drifted to 2.91 ". Monitor 6 b h losses on the tri tank. 08:00 08:45 0.75 1,020 0 COMPZ RPCOM TRIP P Pull out of the hole with 3-1/2" 9.2 ppf L-80 IBT-m tubin , chan a seal rings, stand back on driller's side of, rrick for L1 D lateral com letion. 08:45 13:15 4.50 0 4,428 COMPZ RPCOM PULD P Pickup/MU/RIH ~ 9.2 ppf L-80 IBT-m tubing for mainbore< All tubing was drifted to 2.91". Monitor 6 bph losses on the trip tank. 143 'ts icked u 13:15 14:45 1.50 4,428 4,428 COMPZ RIGMNT SVRG P Service rig. 14:45 16:00 1.25 4,428 7,168 COMPZ RPCOM PULD P Continue to pickup/MU/RIH with 231 joints of 9.2 ppf L-80 IBT-m tubing for mainbore. All tubing was drifted to 2.91 ". Monitor 6 bph losses on the tri tank. 16:00 16:30 0.50 7,168 6,417 COMPZ RPCOM TRIP P Pull out of the hole with 3-1/2" 9.2 ppf L-80 IBT-m tubing, change seal rings, stand back on off driller's side of derrick for mainbore completion. 8 stands out of the hole. 16:30 00:00 7.50 6,417 6,417 COMPZ RPCOM WOW T Phase III weather in the entire Kuparuk field. Shut down operations on ri waitin on weather. 12/16/2008 Shut down for weather- Phase III for entire Kuparuk field. Road to 3K cleared and resumed work at 05:00 hours. Pull out of the hole with 3-1/2" tubing for mainbore and stand back on off driller's side of derrick. Total of 77 stands on the off driller's side to use on the main bore lateral. Single in hole with 261 joints of 3-1/2" tubing for D-Lateral completion. Pulled out of hole with tubing and racked back on driller's side. Shut down 2 hours for investigation and review of smashed finger incident. Chan ed out rams in BOP stack for dual com letion strin . 00:00 04:45 4.75 6,417 6,417 COMPZ RPCOM WOW T Shut down for weather- Phase III for entire Kuparuk field. Note: The wind died down after midnight thirty, checked back after 3 am. Roads and Pads are working the main roads, hoping to get to Phase II by shift change. Security says it is still bad from 1 O back to the base camp. Security called 0437 hrs. Main roads are phase II, trying to get to phase I by 5 am. Roads and pads has already made a pass to 3K pad. Tourpusher called Roads & pads. Our road is good. Pre job safety meeting, then work will start 0500 hrs. ~~ ~3 ~~ ~~ a~~~ S~S\~ ~~ Time Lois - - -_ _ - - Date_ From To Dur S, Depth E. De th Phase Code Subcode T Comment _ __ 04:45 05:00 0.25 6,417 6,417 COMPZ RPCOM SFTY P Pre job safety meeting on trip out of the hole with 3-1/2" 9.2 ppf L-80 IBT-m tubing, standing back on the off driller's side for the main bore. Chan a out seal rin s. 05:00 08:00 3.00 6,417 0 COMPZ RPCOM TRIP P Pull out of the hole with 3-1/2" 9.2 ppf L-80 IBT-m tubing, change seal rings, stand back on off driller's side of derrick for mainbore completion. Will be a total of 77 stands on the off driller's side to use on the main bore lateral. 08:00 14:00 6.00 0 7,068 COMPZ RPCOM TRIP P Pickup/MU/RIH with 231 joints of 9.2 ppf L-80 IBT-m tubing for D-Lateral. All tubing was drifted to 2.91". Monitor 5-7 bph losses on the trip tank. 14:00 16:45 2.75 7,068 270 COMPZ RPCOM TRIP P Pull out of the hole with 3-1/2" 9.2 ppf L-80 IBT-m tubing, change seal rings, stand back on driller's side of derrick for D-Lateral completion. Total of 87 stands on the driller's side to use on the D-Lateral. 16:45 18:45 2.00 270 270 COMPZ RPCOM SFTY T Shut down operations after crew members hand was pinched between elevators and stump. Man was taken to the medic for evaluation. Initial investigation by Doyon Safety, Tool usher and Com an Man. 18:45 19:15 0.50 270 0 COMPZ RPCOM TRIP P Resume POOH with D-lateral com letion strin . 19:15 19:30 0.25 0 0 COMPZ RPCOM RURD P Rig down handling equipment. 19:30 20:30 1.00 0 0 COMPZ WELCTL BOPE P Pull wear ring, run test plug on 5" drill pipe and kelly up with top drive to hold test plug while changing rams. 20:30 23:00 2.50 0 0 COMPZ WELCTL BOPE P Change out upper and lower rams. Pull variables and install dual strip rams. Crew change. Crew that was delayed b weather on 12/15 arrived at ri . 23:00 23:15 0.25 0 0 COMPZ WELCTL SFTY P PJSM -finish changing rams. 23:15 00:00 0.75 0 0 COMPZ WELCTL BOPE P Tighten rams doors. 12/17/2008 Test BOPE. Witness waived by AOGCC Lou Grimaldi. Run in hole with dual seal module and packer. Begin runnin dual tubin strip . 00:00 00:30 0.50 0 0 COMPZ WELCTL SFTY P PJSM -rigging up test equipment and test BOPE. 00:30 01:45 1.25 0 0 COMPZ WELCTL BOPE P Pull 5" test joint leaving test plug in hole. Fill stack with water and RIH with dual string test joint. Rig up test e ui ment o_.Ga ~: ~;t ~ ! ~ Time Logs -- Date __ From --_- -- To Dur S. Depth E. De th Phase Code Subcode T Comment_ 01:45 05:30 3.75 _ 0 0 COMPZ WELCTL BOPE P est BOPE. Tested upper and lower dual rams, two floor safety values, choke manifold, blind rams, upper and lower IBOP. Total of 34 components tested. Hydril not tested. Accumulator drawdown test starting pressure 3000 psi, after functioning values pressure 1500 psi, 55 seconds for 200 psi increase and 3 minutes, 18 seconds to full charge, 3050 psi. 5 bottle average pressure 2400 psi. Sim ops, brings tubing pups to rig floor. Witness waived by AOGCC Lou Grimaldi. 05:30 06:15 0.75 0 0 COMPZ WELCTL BOPE P Pull test plug, rig down test e ui ment and blow down lines. 06:15 06:30 0.25 0 0 COMPZ RPCOM SFTY P PJSM -Rigging up long bails and 3-1/2"dual string handleing e ui ment. 06:30 08:15 1.75 0 0 COMPZ RPCOM RURD P Rig up long bails and 3-1 /2" dual strin handlein a ui ment. 08:15 09:00 0.75 0 0 COMPZ RPCOM RURD P Clear and clean rig floor in preparation for tubing run. Grease upper and lower IBOP. Make up floor valves. 09:00 09:30 0.50 0 0 COMPZ RPCOM SFTY P Crew change, PJSM -running dual tubin strin . 09:30 13:00 3.50 0 110 COMPZ RPCOM RCST P Pick up and make up dual seal module and dual strip acker. 13:00 14:00 1.00 110 110 COMPZ RPCOM RURD P Move service loop in derrick for elevators due to hi h winds. 14:00 18:00 4.00 110 2,072 COMPZ RPCOM RCST P Run 3-1/2" dual tubing string from derrick. Record weights and balance strip wei ht eve 5 stands. 18:00 00:00 6.00 2,072 4,900 COMPZ RPCOM RCST P Continue to Run 3-1/2"dual tubing string from derrick. Record weights and balance string weight every 5 stands. 12/18/2008 Run and land dual completion string. Attemp to set packer and could not build pressure in main bore. Begin trouble shooting, attempting to find leak path. Rig up slickline for trouble shooting. After midnight: Ran slickline to 6600' MD, pressured up to 1000 psi and held for 5 minutes. Pressure held. Pressured u several times to work i e, max ressure 1300 si. 00:00 05:30 5.50 4,900 7,288 COMPZ RPCOM RCST P Continue to Run 3-1/2"dual tubing string from derrick. Record weights and balance string weight every 5 stands. PU wt 155k, So wt 112k 05:30 05:45 0.25 7,288 7,288 COMPZ RPCOM RCST P Snapped Dual Seal Module into collet and set down 10k. Snapped out of collet wi h 17 05:45 06:30 0.75 7,288 7,238 COMPZ RPCOM RCST P POOH and stand back one stand from each tubing string. Rig up to um corrosion inhibited brine. 06:30 09:00 2.50 7,238 7,238 COMPZ RPCOM CIRC P Pump 290 bbls corrosion inhibited brine from vac truck and displaced from tubing with 63 bbls from pits. Pum ed at 3 b m, 190 si. _. __ m .~ ~.., ~ ~ _ _ m 3 ~~ ~~ €;~; i Time LocJs _ D__a_te __ From _ To Dur S. Depth E. De th Phase Code Subcode T Comment _ __ 09:00 10:00 1.00 7,238 7,238 COMPZ RPCOM HOSO P Blow down lines, space out tubing string. Pups installed under 1st stand of tubin . 10:00 10:15 0.25 7,238 7,238 COMPZ RPCOM SFTY P PJSM -making up hanger and landin ~oints. 10:15 12:00 1.75 7,238 7,238 COMPZ RPCOM RCST P Make up hanger and landing joints. Rig down slips and tongs, drain stack. 12:00 12:45 0.75 7,238 7,288 COMPZ RPCOM RCST P RIH with tubin han er. Observed collect snap in. Set down 10k and picked up to 165k. Continue slacking off to shear Dual String Module, 38k down continue slackin off to shear seal shroud 16k down. Land han er. 12:45 14:30 1.75 0 0 COMPZ RPCOM RCST P Run in lock down screws and test hanger, good test. Lay down landing joints and installtwo-way check valves. Test to of han er, ood test. 14:30 15:00 0.50 0 0 COMPZ RPCOM PACK P Pull two-way check valve from main bore, close blind rams and pressure up to set packer. Would not build pressure. Getting returns from annulus. 15:00 16:30 1.50 0 0 COMPZ RPCOM PACK T Install landing joint in main bore and pump down mainbore, still not building pressure. Pull two-way check from D-lateral and installed landing joint. Pumped down D-Lateral takin returns from annulus. 16:30 19:00 2.50 0 0 COMPZ RPCOM CIRC T Circulate dye marker down main bore to estimate location of leak path. Pumping 3 bpm, 280 psi. Stopped after 3252 strokes corrosion inhibited brine at surface and no dye to surface. Conference call with down to discuss options. Plan forward rig up slickline, replace shear out valve in gas lift mandrel and run oor bo hole finder. 19:00 19:30 0.50 0 0 COMPZ RPCOM SFTY T PJSM -working around CI brine on rig floor. Review MSDS with mud en ineer. 19:30 20:00 0.50 0 0 COMPZ RPCOM CIRC T Rig up and pump down D-lateral tubing to obtain rates and pressures to compare with hanger/overshot run. 2 bpm / 340 psi, 3 bpm / 800 psi, 3.5 bpm / 1100 psi. Pumped total of 187 strokes. 20:00 21:15 1.25 0 0 COMPZ RPCOM SLKL T Spotting slickline unit, bring sheaves and wire to ri floor. 21:15 22:45 1.50 0 0 COMPZ RPCOM CIRC T Resume pumping down main bore looking for dye marker while rigging up slick line. Pumping 3 bpm / 280 psi. Observed dye marker at shakers ` at 4700 strokes (calculated surface to surface 4420 strokes, with losses 5100 strokes . ®m~ _._._..~~~--~ ---...~ - r°-e~ _~__ ~®~_ ~~®~~~ $~e~tje ~€~ ~`~ r,z. i Time Logs Date_ From__ To Dur S De th E. Dzpth Phase Code Subcode _T_ Comment 22:45 00:00 1.25 0 0 COMPZ RPCOM SLKL T Rig up slickline tools and BOPE. 12/19/2008 Unable to pressure upon main bore, continue trouble shooting. Rig up slickline and run hole finder to 6600' MD. No leaks found. Make drift run with slickline to 7289' MD. Unland tubing strings and stroke pipe in attem t to seat main bore stin er in seals. No success. Be in ullin dual tubin strin . 00:00 01:15 1.25 0 0 COMPZ RPCOM SLKL T Rig up slickline tools and BOPE. 01:15 01:30 0.25 0 0 COMPZ RPCOM SLKL T slickline tools stacking out at tubing han er. 01:30 01:45 0.25 0 0 COMPZ RPCOM SLKL T PJSM -rigging down slickline BOP and tools, ullin landin 'oint. 01:45 02:45 1.00 0 0 COMPZ RPCOM SLKL T Rig down slickline BOP, pull main bore landing joint. ID=2.25", too small for any slickline tools. Pull Lateral landing joint. ID=2.98". Swap landin 'oints. 02:45 03:30 0.75 0 0 COMPZ RPCOM SLKL T Rig up slickline BOP and tools. 03:30 04:30 1.00 0 6,600 COMPZ RPCOM SLKL T Run hole finder to max depth and still be able to shear pin and activiate tool. 04:30 05:15 0.75 6,600 6,600 COMPZ RPCOM SLKL T Pressure up to 1000 psi and hold for 5 minutes. Pressure held, no leaks from 0' to 6600' MD. Pressure up several times to try and elongate tubin . 05:15 06:00 0.75 6,600 0 COMPZ RPCOM SLKL T POOH with slickline. Stop on the way out of hole to pressure up on mainbore tubing, pumping past hole finder tool string. Pumped 3 bpm, 280 psi, not building pressure, getting returns up annulus. Pull slickline tools to surface. 06:00 08:45 2.75 0 0 COMPZ RPCOM SLKL T Waiting on Proactive Service Diagnostic Tools (PSD) caliper coming from Deadhorse. E-line on location. Discussing options with town. 08:45 12:00 3.25 0 0 COMPZ RPCOM SLKL T Make a drift run for caliper on slickline to 7289' MD. POOH and rig down slickline tools. 12:00 17:15 5.25 0 0 COMPZ RPCOM RCST T Rig up dual string handleing equipment and lines to pump down main bore. Back out lock down screws on tubing hanger and hobble one mud pump. Stroke tubing string 12' pumping while slacking off the first 6'. Reland hanger, run in lock down screws, test hanger and pump down main bore. Still not building pressure. Repeat process stroking 16', 17' & 20'. No success. 17:15 18:00 0.75 0 0 COMPZ RPCOM RCST T Pick up on tubing string and unsnap Dual Seal Module. Reland DSM and han er. Retest. No success. 18:00 18:15 0.25 0 0 COMPZ RPCOM RURD T Rig down lines and prepare to pull tubin strin s. . w........_... ® ~~ ®~ ~ ~. ~ ~_. I~~t~e n7 tit xia • Time Logs Date From To Dur S Depth E Depth Phase Code Subcode T Comment 18:15 18:30 0.25 7,240 7,200 COMPZ RPCOM PULD T Pull tubinc han er to ricl floor. No overpull observed when unsnapping Dual Seal Module. PU wt 155k, So wt 112k. 18:30 19:00 0.50 7,200 7,200 COMPZ RPCOM SFTY T PJSM -laying down dual tubing han er 19:00 20:45 1.75 7,200 7,200 COMPZ RPCOM PULD T Lay down hanger and landing joints. 20:45 21:15 0.50 7,200 7,200 COMPZ RPCOM PULD T Clear and clean rig floor. 21:15 21:45 0.50 7,200 7,200 COMPZ RPCOM SFTY T PJSM -pulling dual tubing string. 21:45 00:00 2.25 7,200 6,754 COMPZ RPCOM PULD T Pull 4 stands and 9 space out pups. PU wt 150k, SO wt 112k. 12/20/2008 Pull out of hole with dual completion string, racking tubing in derrick. Lay down dual packer and dual seal assembly. Change rams and test. Service rig. Rig up to run in hole with single tubing string with slick, dumm run. 00:00 00:30 0.50 6,754 6,754 COMPZ RPCOM SFTY T Stop and discuss job. What is going well, what can we do better. 00:30 06:00 5.50 6,754 4,200 COMPZ RPCOM PULD T POOH with dual tubing string, pups and jewelry. PU wt 125k, SO wt 110k. 06:00 12:00 6.00 4,200 150 COMPZ RPCOM PULD T POOH with dual tubing string to dual acker assembl . 12:00 12:45 0.75 150 150 COMPZ RPCOM PULD T Change out handleing equipment, clear and clean rig floor, rig up to lay down Baker DSM and Packer. 12:45 16:15 3.50 0 0 COMPZ RPCOM PULD T POOH with dual string packer, extension joints and dual seal module. Lay down tools and send to Deadhorse for servicing. Clear and clean ri floor. 16:15 17:00 0.75 0 0 COMPZ WELCTI EQRP T Chan a out one set of dual rams. Put sin le variables in to ram cavit . 17:00 18:30 1.50 0 0 COMPZ RIGMNT SVRG P Slip and cut drilling line. 18:30 20:00 1.50 0 0 COMPZ RIGMNT SVRG P Service topdrive, blocks and crown. Unhan blocks. 20:00 21:00 1.00 0 0 COMPZ WELCTI BOPE T Rig up for BOP test, fill stack with water. 21:00 21:30 0.50 0 0 COMPZ WELCTL SFTY T PJSM - testin BOP~eviewed COP /Rowan 67 lockdown screw incident. 21:30 22:00 0.50 0 0 COMPZ WELCTL BOPE T Test variable rams and annular reventor. Good test. 22:00 22:45 0.75 0 0 COMPZ WELCTL BOPE T Pull test plug and set wear ring. 22:45 23:00 0.25 0 0 COMPZ RPCOM SFTY T PJSM -rigging up 3-1/2" handling e ui ment with GBR. 23:00 23:45 0.75 0 0 COMPZ RPCOM RURD T Rig up handleing tools. 23:45 00:00 0.25 0 0 COMPZ RPCOM SFTY T PJSM -making up slick stinger and tripping in hole from derrick. Reviewed DDI rocedures. 12/21 /2008 Run in hole with single tubing string with slick stinger and attempt to stab into mainbore seals in seal bore diverter with no success. Washed over seal bore diverter and made repeated attempts to stab into seals. Discussed options with town and decision made to run caliper tools to determine orientation of ram hanger. First tali er run was inconclusive. s° _: v • i ~ Time Logs Date From To Dur S. De th E. Depth Phase Code Subcode T Comment - -- 00:00 00:15 0.25 0 0 COMPZ RPCOM RURD T Cut and dress mule shoe on end of slick stin er for dumm run. 00:15 01:00 0.75 0 50 COMPZ RPCOM RCST T Pick up and run slick stinger, extension joint and "DS" nipple. Ad'ust bails. 01:00 05:30 4.50 50 7,312 COMPZ RPCOM RCST T RIH with 3-1/2" mainbore tubing string from off driller side. Attempt to stab stinger into seal bore diverter with no success. PU wt 112k, SO wt 98k 05:30 06:30 1.00 7,312 7,312 COMPZ RPCOM CIRC T Wash over seal bore diverter slide, rotate pipe 1/4 turns, attempting to stab into seals. Pumped 5 bpm, 460 si. No success. 06:30 07:30 1.00 7,312 7,315 COMPZ RPCOM CIRC T Pick up single, RIH until tagged up in D-Lateral and set down 3k. Broke off si! ngle,Pumped 2 bpm / 110 psi, 3 bpm / 230 psi, 4 bpm / 410 psi, 5 b m/710 si. 07:30 08:15 0.75 7,315 7,295 COMPZ RPCOM RCST T Work pipe attempting to stab into mainbore seals. Rotate pipe 1/8 turns. No success. 08:15 10:00 1.75 7,295 7,270 COMPZ RPCOM CIRC T Wash over seal bore diverter slide, Pumped 7 bpm / 830 psi, 10 bpm / 1540 psi. Conference call to discuss o tions 10:00 11:00 1.00 7,270 7,295 COMPZ RPCOM RCST T Attempt to Stab into mainbore seals, no success. 11:00 12:00 1.00 7,295 7,268 COMPZ RPCOM RCST T Rack back 1 stand, pick up 3 - 6' pups and single. Park in slips at top of ram han er. 12:00 12:15 0.25 7,268 7,268 COMPZ RPCOM SFTY T PJSM -rigging up slickline 12:15 15:00 2.75 7,268 7,268 COMPZ RPCOM SLKL T Rig up and RIH with slickline 2.824" swedge. Located DS nipple at 7235' WLM. Pumped swedge down from 6800' WLM. POOH with wireline tools. 15:00 15:45 0.75 7,268 7,268 COMPZ RPCOM SLKL T Pick up wireline memory caliper tools. 15:45 18:30 2.75 7,268 7,268 COMPZ RPCOM SLKL T RIH with caliper tools. Pumped down from 6775' WLM. Wait for tool to activiate and caliper upper ram hanger. Observed 900# overpull when POOH with activiated cali er. 18:30 19:15 0.75 7,268 7,268 COMPZ RPCOM SLKL T Lay down slickline tools. Download data and send to Houston for evaluation. 19:15 23:45 4.50 7,268 7,268 COMPZ RPCOM WOOR T Waiting on caliper log evaluation. Discuss options with town. Crew workin on PMs and cleanin ri . 23:45 00:00 0.25 7,268 7,268 COMPZ RPCOM SLKL T Caliper log inconclusive. Bad data when tools hung up down hole. Decision made to make another attempt to log upper ram hanger helix. Time Logs Date From To Dur _ _S pe~t_h E Depth Phase Code_ _ Subcode T Comment -- _ 12/22/2008 24 hr Summary Make 2 slickline runs and record four caliper logs of ram hanger helix. Discuss options for plan forvvard with town. Ri u and be in ullin dumm tubin strip with slick stin er. 00:00 02:45 2.75 7,268 7,268 COMPZ RPCOM SLKL T Finish rigging up slickline caliper tools and RIH, pumping down at 4 bpm from 6600' WLM. Set tool on depth and POOH across hanger to check for hangups. One of three passes hung up. Set tool on depth, 7298' WLM, and wait for caliper to activiate. Sim ops: crew cleaning rig, BOP stack, pits and pipe shed. Continue workin on PMs. 02:45 03:45 1.00 7,268 7,268 COMPZ RPCOM SLKL T POOH with slickline logging upper ram hanger. Tools hung up and pulled 450# over. Determined later that overpull was the result of the upper centralizer entering to tubing tail. 03:45 04:15 0.50 7,268 7,268 COMPZ RPCOM SLKL T Breakout slickline tools. Download data and sent to Houston. 04:15 05:45 1.50 7,268 7,268 COMPZ RPCOM WOOR T Waiting on caliper log evaluation. Caliper log better than first run but not good enou h to see helix. Discuss options with town. Decision made to make another slickline run. Tool will be programmed to make multiple passes without coming out of hole. Sim ops: crew cleaning rig, working PMs and ins ectin au er bearin s. 05:45 06:15 0.50 7,268 7,258 COMPZ RPCOM SLKL T Pick tubing string up so that tubing tail is 10' above ram hanger top. This will make room for the calliper and centralizers to exit the hanger top before enterin the tubin tail. 06:15 07:30 1.25 7,258 7,258 COMPZ RPCOM SLKL T Make up slickline tool string. slickline crew chap ed out. 07:30 11:00 3.50 7,258 7,258 COMPZ RPCOM SLKL T RIH with caliper tool pumping down from 6200' WLM. Wait for tool to activiate and made three logging asses before POOH. 11:00 12:00 1.00 7,258 7,258 COMPZ RPCOM SLKL T Breakout slickline tools, download data and send to Houston. 12:00 16:15 4.25 7,258 7,258 COMPZ RPCOM WOOR T Waiting on caliper log evaluation. Caliper log shows hanger pro erl oriented. Sim ops: loading pipe shed with 5" drill i e and ri u to ull tubin . 16:15 16:45 0.50 7,258 7,258 COMPZ RPCOM SFTY T PJSM -rigging down slickline, BOPE, sheaves and sending tools down beaver slide. 16:45 17:45 1.00 7,258 7,258 COMPZ RPCOM SLKL T Rig down slickline. • Time Logs _ -- iDate From To Dur S. De th E De th Phase Code Subcode T Comment 17:45 18:00 0.25 7,258 7,258 COMPZ RIGMN7 SFTY T PJSM -replacing camera in derrick 18:00 19:00 1.00 7,258 7,258 COMPZ RIGMN7 RGRP T Install new camera in derrick. 19:00 21:00 2.00 7,258 7,258 COMPZ RPCOM WOOR T Inspect and service drawworks and to drive. Clear and clean ri floor. 21:00 21:45 0.75 7,258 7,258 COMPZ RPCOM RURD T Rig down long bails, rig up and ad'ust short bails for ullin tubin . 21:45 22:00 0.25 7,258 7,258 COMPZ RPCOM SFTY T PJSM -pulling tubing and racking back in derrick. 22:00 00:00 2.00 7,258 4,749 COMPZ RPCOM PULD T POOH with 3-1/2" tubing with slick stin er. 12/23/2008 Pulled out of hole with slick stinger racking back tubing. Sent stinger extension joint to Deadhorse to be bent. Ran in hole with slick stinger, extension joint and MWD. Stabbed into seals and pressure tested good. Pulled out of hole. 00:00 02:45 2.75 4,749 0 COMPZ RPCOM PULD T POOH with 3-1/2" tubing with slick stinger. Break out slick stinger extension joint and hot shot to Baker Production to be bent. 02:45 09:15 6.50 0 0 COMPZ RPCOM WOEO T Extension joint being bent. Crew servicing rig, change oil in top drive and iron rough neck, inspect saver sub and powerwash top drive. Work on PMs 09:15 09:45 0.50 0 0 COMPZ RPCOM SFTY T PJSM -picking up and making up slim hole MWD strin . 09:45 11:45 2.00 0 175 COMPZ RPCOM PULD T Pick up stinger, bent extension joint and MWD. 11:45 12:45 1.00 175 175 COMPZ RPCOM CIRC T Rig up and circulate for shallow pulse test of MWD. Pump 110 gpm, 230 si. Good test. 12:45 17:00 4.25 175 7,283 COMPZ RPCOM RCST T TIH with 3-1/2" tubing from derrick. PU wt 110k. SO wt 98k. 17:00 17:45 0.75 7,283 7,283 COMPZ RPCOM RURD T Rig up to circulate and orient bent 'oint for stabbin seal bore diverter. 17:45 19:30 1.75 7,283 7,300 COMPZ RPCOM CIRC T String at 135L, rotate to 152R and attempt to stab sti ~o .Rotate tubing to 175R, slacked off and stabbed into seals on de th. Continue slacking off until began stacking weight. Tested seals with 2500 si. Good test. Pick up and stab stinger second time to confirm de ths. All ood. 19:30 20:15 0.75 7,300 7,300 COMPZ RPCOM RURD T Rig down and blow down lines. Rig u 3-1 /2" handlin tools. 20:15 20:30 0.25 7,300 7,300 COMPZ RPCOM SFTY T PJSM -POOH with slick stringer, bent'oint and slim hole MWD. 20:30 00:00 3.50 7,300 100 COMPZ RPCOM PULD T POOH with 3-1/2" tubing rackin back in derrick. 12/24/2008 Layed down MWD, bent extension joint and slick stinger. Changed rams and tested with dual tubing test 'oint. Ri u and run Dual Seal Module, Extension Joints and Dual Packer followed b 69 stands of tubin . 00:00 00:15 0.25 100 100 COMPZ RPCOM SFTY T PJSM -laying down MWD, extension 'oint and slick stin er 00:15 02:00 1.75 100 0 COMPZ RPCOM PULD T Lay down BHA, handling tools and clear ri floor. ®_a s ~e m P ~~ .~ r~ Time Lo s 9--- - _ _ ____ Date From _To Dur S De th E._De~th _Phase Code Subcode T Cornnient 02:00 02:30 0.50 0 0 COMPZ WELCTL OTHR T Pull wear bushing and set test plug. 02:30 02:45 0.25 0 0 COMPZ WELCTL SFTY T PJ; aM -changing upper pipe rams 02:45 03:45 1.00 0 0 COMPZ WELCTL OTHR T Change upper pipe rams to dual 3-1 '2" 03:45 04:15 0.50 0 0 COMPZ WELCTL BOPE T Ri„c up BOPE test equipment, run 3-1'2"dual strin test ~oint 04:15 05:45 1.50 0 0 COMPZ WELCTL BOPE T Tes t upper pipe rams with dual string tes joint. Troubleshoot leaking test lu . 05:45 07:15 1.50 0 0 COMPZ WELCTL OTHR T Ric; down test equipment, pick up stagy :k washer and wash stack. 07:15 08:00 0.75 0 0 COMPZ WELCTL OTHR T Gre ase upper and lower IBOPs, re3se drawworks. 08:00 09:00 1.00 0 0 COMPZ WELCTL BOPE T Insiall test plug and run dual string tes 'oint. 09:00 09:30 0.50 0 0 COMPZ WELCTL BOPE T Te: .t top rams, 250 psi low, 3000 psi hi i 09:30 10:15 0.75 0 0 COMPZ WELCTL BOPE T Ric down test equipment and blow do~~ on lines 10:15 10:30 0.25 0 0 COMPZ RIGMNT SFTY T PJ='>M -working on camera in derrick 10:30 11:00 0.50 0 0 COMPZ RIGMNT RGRP T Trc ubleshoot camera in derrick, no suc ,cess 11:00 11:15 0.25 0 0 COMPZ RPCOM SFTY T PJ >M -rigging up long bails and dual strii~ handlin a ui ment 11:15 13:00 1.75 0 0 COMPZ RPCOM RURD T Ric, down short bails and rig up long bai~"s. Rig up dual string handling tocj Is. 13:00 13:30 0.50 0 0 COMPZ RPCOM SFTY T PJ1iM -running Dual Seal Module, Ex°ension Joints and Dual Packer. 13:30 18:00 4.50 0 115 COMPZ RPCOM RCST T Piclk up and run Dual Seal Module, E~nension Joints and Dual Packer. 18:00 18:15 0.25 115 115 COMPZ RPCOM SFTY T PJ:iM - TIH with dual tubing string from derrick. 18:15 00:00 5.75 115 2,400 COMPZ RPCOM RCST T TIFI with dual tubing string. 12/25/2008 Ran dual tubing string to TD. Spaced out, spotted corrosion inhibited brine and landed tubing strings. Made quick pressure test of mainbore seals, pressure held, seals engaged! Ate Christmas Dinner. Attempted to seal dual packer with no success. Troubleshooting packer setting, discuss options with town. (Packer set and tested at 02:00, 12/26 00:00 06:00 6.00 2,400 6,829 COMPZ RPCOM RCST T Tri in hole with dua- r duction_ tubin , up weight 145k, down weight 112k, balance string weights every 5 dual stands 06:00 08:30 2.50 6,829 7,236 COMPZ RPCOM RURD T Trip in hole with dual production tubing, up weight 155k, down weight 110k, balance string last time before sna in into collet 08:30 09:45 1.25 7,236 7,281 COMPZ RPCOM HOSO T Sna in to RAM Hanger Collett at 7281 ft with 8k Ibs down, 150k Ibs over ull to 170k to sna out 09:45 11:00 1.25 7,281 7,251 COMPZ RPCOM HOSO T Pull from 7281ft to 7143 ft, add in 4 pups (22.95' in B Main String) and 5 pups (22.46' D Lateral) below one stand on both strin s T+me Logs _ Date From To Dur S. De th E. De th Phase Code Subcode T Comment 11:00 12:15 1.25 7,251 7,251 COMPZ RPCOM OTHR T Rig to pump corrosion inhibited brine down main tubin and u annulus 12:15 14:15 2.00 7,251 7,251 COMPZ RPCOM CIRC T Pump 290 bbls corrosion inhibited brine @ 3 bpm displaced with 63bbls brine down main tubing, 240psi, 31 bbls lost ast 6 hours 14:15 14:30 0.25 7,251 7,251 COMPZ RPCOM OTHR T Rig down circulating head and blow down lines. 14:30 14:45 0.25 7,251 7,251 COMPZ RPCOM SFTY T PJSM -picking up and making up dual tubin han er 14:45 16:15 1.50 7,251 7,251 COMPZ RPCOM RCST T Pick up and make up dual string han er. 16:15 16:45 0.50 7,251 7,288 COMPZ RPCOM HOSO T Snap DSM into Ram Hanger_17 ft in, set down 8k, pull to 163k (8k over up weight to confirm latch), slack off to shear DSM (28k), slack off 17' and obs rvecLlateral shroud shear Set down last 3' and landed han er. 16:45 17:15 0.50 7,288 7,288 COMPZ RPCOM DHEQ T Run in 4 Lock Down screws rig up and test main bore tubing seals to 500psi, 15 minutes, pressure held, charted test. 17:15 18:00 0.75 7,288 7,288 COMPZ RPCOM DHEQ T Run in all lock down screws, test hanger body seals to 5000 si/10minutes, ood test. 18:00 18:15 0.25 0 0 COMPZ RPCOM SFTY T PJSM -pulling landing joints and settin two wa check valves. 18:15 20:00 1.75 0 0 COMPZ RPCOM DHEQ T Pull landing joints, install Vetco two way check valves, rig down tubing handlin a ui ment, clean mud its 20:00 20:45 0.75 0 0 COMPZ RPCOM RURD T Rig up to test tubing hanger metal seals. 20:45 21:15 0.50 0 0 COMPZ RPCOM DHEO T Close blind rams and pressure test tubing hanger to 5000psi/10 minutes. ood test. 21:15 21:30 0.25 0 0 COMPZ RPCOM DHEQ T Pull two way check valve from mainbore tubin . 21:30 21:45 0.25 0 0 COMPZ RPCOM DHEQ T Close blind rams and pressure up on mainbore tubing to 1000 psi and hold for 5 minutes. Pressure held, good test. 21:45 00:00 2.25 0 0 COMPZ RPCOM PACK T Continue pressuring up to 3000 psi and hold for 15 minutes to set packer. Bleed tubing pressure to 1500 psi and pump down annulus. Not building pressure in annulus packer not set. Pressure mainbore tubing to 4000 psi and hold 15 minutes. Bleed down to 1500 psi and pump down annulus. Packer not seta Pressure up on tubing to 4000 psi and pump down annulus, not building pressure. Discuss options with town. Recheck surface equipment. Continue troubleshootin . 12/26/2008 Set dual string packer, then two way check valves. Change upper and lower pipe rams, reorient BOP stack and set on stum . Ni le u and test tree. _ _.~ ®m®®® ~s~ ~-,~ n ~x i ~ i Time Logs ___ _ Comment Date Frorn To Dur S De th E. De th Phase Code Subcode T__ 00:00 02:00 2.00 0 0 COMPZ RPCOM PACK _ T Packer not setting, continue troubleshooting. Checking surface equipment. Discuss options with town. Surge pumps to 3600 psi and bleed off rapidly Restest annulus holding pressure. Test annulus to 2500 si with 1500 si on mainbore_ tubin .Good test. 02:00 02:15 0.25 0 0 COMPZ RPCOM PACK P Rig down test equipment and blow down lines. 02:15 02:45 0.50 0 0 COMPZ RPCOM SFTY P PJSM -setting two way check valve in mainbore and ri in down lines. 02:45 03:00 0.25 0 0 COMPZ RPCOM RCST P Set two-way check in mainbore tubing hanger. Offset two-way check in D-Lateral to check for ressure. 03:00 03:15 0.25 0 0 COMPZ WELCTI SFTY P PJSM -changing upper & lower pipe rams. 03:15 06:30 3.25 0 0 COMPZ WELCTI OTHR P Change out upper and lower pipe rams. 06:30 07:00 0.50 0 0 COMPZ WELCTL SFTY P PJSM -nipple down stack, rotating mud cross. 07:00 09:30 2.50 0 0 COMPZ WELCTI NUND P Nipple down riser, flow line, bell nipple and turnbuckles. Break bolt on mud cross., Cleanin rockwasher. 09:30 10:00 0.50 0 0 COMPZ WELCTL SFTY P PJSM -picking up stack and rotating mud cross. 10:00 11:30 1.50 0 0 COMPZ WELCTI NUND P Pick up stack and rotate mud cross. 11:30 12:00 0.50 0 0 COMPZ WELCTL OTHR T Clean up diesel spilled inside rig from heater tank vent line. 12:00 15:30 3.50 0 0 COMPZ WELCTI NUND P Tighten breaks on mud cross, pick u stack and rack back on stum . 15:30 16:00 0.50 0 0 COMPZ RPCOM SFTY P PJSM -picking up and nippling up tree 16:00 17:30 1.50 0 0 COMPZ RPCOM NUND P Pick up and nipple up tree. 17:30 19:15 1.75 0 0 COMPZ RPCOM DHEQ P Rig up and test seal between wellhead and tree, 250 psi low / 5000 high. Hold each for 10 minutes. Good tests. 19:15 19:45 0.50 0 0 COMPZ RPCOM RURD P Rig up to test tree. 19:45 20:00 0.25 0 0 COMPZ RPCOM SFTY P PJSM -flooding and testing tree. 20:00 20:30 0.50 0 0 COMPZ RPCOM DHEQ P Flood D-Lateral side of tree with diesel from Little Red Services. Test to 250 psi. Rig up and flood B-Lateral (mainbore). Actuator valve leaking. Stop operation. Vetco calling su ervisor. 20:30 21:45 1.25 0 0 COMPZ RPCOM NUND T Rig down and lay down D-Lat actuator, make up flange to tree. Flood D-Lat side of tree. 21:45 22:30 0.75 0 0 COMPZ RPCOM DHEQ P Test B-Lat tree to 5000 psi, good Sgst. Test D-Lat to 250 asi / 5000 si. Tree cap leaked on 5000 psi test. 22:30 23:00 0.50 0 0 COMPZ RPCOM DHEQ T Change out O-ring in tree cap. r r~..._ _.__-..~........ ~ ~ ®_ -~ ~ ® ~ _ ~~~ ,> ^, <~t ~i Tirne Logs - I - _ Date From To _Dur S. D~t_h_ E. Depth Phase Code _ Suhcode T Comment 23:00 23:45 0.75 0 0 COMPZ RPCOM DHEQ P Test B-Lat, mainbore, side of tree 250 si / 5000 si. Good test. 23:45 00:00 0.25 0 0 COMPZ RPCOM NUND T Changed out short stud between tree and wellhead. Retest void 250 psi / 5000 si. Good test. 12/27/2008 Test tree, freeze protect well, set back pressure valves and move off well. RIG RELEASED AT 13:00 00:00 02:30 2.50 0 0 COMPZ RPCOM FRZP P Nipple up lubricator and pull two-wa check valve from mainbore. Turn tree cap flange to line up tree cap with. D-Lateral tubin .Nipple up lubricator and ull twi-wa check from D-Lat. 02:30 03:00 0.50 0 0 COMPZ RPCOM FRZP P Rig up for freeze protecting well. 03:00 03:15 0.25 0 0 COMPZ RPCOM SFTY P PJSM -shearing out gas lift mandrel and freeze rotectin well. 03:15 06:30 3.25 0 0 COMPZ RPCOM FRZP P Sheared out valve at 1600 psi and pumped 163 bbls @ 1 bpm down the annulus taking returns up the mainbore tubing. Circulated until diesel seen at surface. Rig down from mainbore and rig up on D-Lat tubing. Bullheaded 25 bbls of diesel down D-Lat tubing at 1 bpm. Sim ops: rig up and begin laying down tubin from derrick. 06:30 07:00 0.50 0 0 COMPZ RPCOM FRZP P Rig down from freeze protect and blow down lines. Sim ops; cleaning its. 07:00 11:00 4.00 0 0 COMPZ RPCOM NUND P Rig up lubricator and set Back Pressure Valve in D-Lat tubing. Rotate tree cap and install BPV in mainbore tubin . 11:00 12:00 1.00 0 0 COMPZ RPCOM SFEQ P Test tree cap 250 psi / 5000 psi, ood test. 12:00 13:00 1.00 0 0 COMPZ RPCOM RURD P Re-install gauges on tree, clean cellar box and record final pressures (mainbore tubing 0 psi, D-Lateral tubing 200 psi, (9-5/8' x tubing annulus 0 psi, 12-1 /4" x 9-5/8" annulus 120 psi). RIG RELEASE 13:00 ~_..._ ~ ..,. m. ........ ..........-~_____...,.~_~. .....,. _...__.~.~. ..,.,....,....,.....,..~.........,.~, • • ConocoPhillips(Alaska) Inc. Kuparuk River Unit Kuparuk 3K Pad 3K-108 Permit to Drill: 208-130 API: 50-029-23395-00 Definitive Survey Report 13 January, 2009 ~x 5p~rry Drilling ~ervice~ ConocoPhillips or its affiliates Definitive Survey Repoli Company: ConocoPhillips(Alaska) Inc. Local Co-ordinate Reference: We113K-108 Project: Kuparuk River Unit TVD Reference: 3K-108 @ 74.14ft (Doyon 15) Site: Kuparuk 3K Pad MD Reference: 3K-108 @ 74.14ft (Doyon 15) Well: 3K-108 North Reference: True Wellbore: 3K-108 Survey Calculation Method: Minimum Curvature t~esign: 3K-108 Database: EDM Alaska Prod v16 Project Kuparuk River Unit Map System: US State Plane 1927 (6cact 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 _ 3K-108 Well Position +N/-S 0.00 ft Northing: 6,008,466.47ft Latitude: 70° 26' 3.152 N +E/-W 0.00 ft Easting: 529,306.29 ft ~ Longitude: 149° 45' 39.922 W Position Uncertainty 0.00 ft Wellhead Elevation: ft Ground Level: 33.40ft - Wellbore 3K-108 Magnetics Model Name Sample Date Declination (°) BGGM2007 12/20/2008 22.43 --- ,Design SK-108 Audit Notes: Version: 1.0 Phase: ACTUAL Vertical Section: Depth From (TVD) +N/-S (ft) (ft) L _ 40.74 0.00 Dip Angle Field Strength (°) InTI 80.90 57.653 Tie On Depth: 40.74 +E/-W Direction Ift) (°) 0.00 50.00 Survey Program Date From To (ft) (ft) Survey (Wellbore) Tool Name Description 90.00 461.00 3K-108 Gyro (3K-108) CB-GYRO-SS Camera based gyro single shot 498.34 13,107.32 3K-108 MWD+SAG+CA+IIFR+MS (3K-1 MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC Survey Survey Date 9/5/2008 12: 9!5/2008 12: Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E!-W Northing Easting DLS Section (ft) (°) (°) (ft) (ft) (ft) (ft) (ft) (ft) (°1100') (ft) Survey Tool Name 40.74 0.00 0.00 40.74 -33.40 O.OU O.UO 6,UU8,466.47 525,306.29 0.00 0.00 UNDEFINED 90.00 0.50 69.28 90.00 15.86 0.08 0.20 6,008,466.55 529,306.49 1.02 0.20 CB-GYRO-SS (1) 120.00 0.49 56.48 120.00 45.86 0.19 0.43 6,008,466.67 529,306.72 0.37 0.43 CB-GYRO-SS (1) 135.00 0.51 58.10 135.00 60.86 0.26 0.54 6,008,466.74 529,306.83 0.16 0.54 CB-GYRO-SS (1) 180.00 0.67 65.00 180.00 105.86 0.48 0.95 6,008,466.96 529,307.23 0.39 0.95 CB-GYRO-SS (1) 225.00 0.81 81.39 224.99 150.85 0.64 1.50 6,008,467.12 529,307.79 0.56 1.50 CB-GYRO-SS (1) 241.00 0.86 69.38 240.99 166.85 0.70 1.73 6,008,467.18 529,308.01 1.14 1.73 CB-GYRO-SS (1) 286.00 1.05 76.74 285.98 211.84 0.91 2.44 6,008,467.40 529,308.73 0.50 2.44 CB-GYRO-SS (1) 331.00 1.54 56.82 330.97 256.83 1.32 3.36 6,008,467.81 529,309.64 1.40 3.36 CB-GYRO-SS (1) 365.00 2.47 64.71 364.95 290.81 1.87 4.42 6,008,468.36 529,310.70 2.80 4.42 CB-GYRO-SS (1) 376.00 2.30 64.70 375.94 301.80 2.07 4.83 6,008,468.56 529,311.11 1.55 4.83 CB-GYRO-SS (1) 421.00 3.09 63.02 420.89 346.75 3.00 6.73 6,008,469.50 529,313.00 1.76 6.73 CB-GYRO-SS (1) 461.00 4.40 63.55 460.81 386.67 4.17 9.06 6,008,470.68 529,315.33 3.28 9.06 CB-GYRO-SS (1) 1/13/2009 11:00:57AM Page 2 COMPASS 2003.16 Build 42F w w ConocoPhillips or its affiliates Definitive Survey Report Company: ConocoPhillips(Alaska) Inc ...Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Database: Well 3K-108 3K-108 @ 74.14ft (Doyon 15) 3K-108 @ 74.14ft (Doyon 15) True Minimum Curvature EDM Alaska Prod v16 Project: Kuparuk River Unit Site: Kuparuk 3K Pad Wel I: 3K-108 Wellbore: 3K-108 Design: 3K-108 Survey MD Inc Azi TVD TVDSS +NI-5 Iftl (°) 1°1 Iftl Iftl Iftl 496.34 5.03 55.43 498.02 423.88 5.64 543.40 5.81 58.45 542.88 468.74 7.84 594.48 6.48 55.84 593.66 519.52 10.81 618.07 5.99 53.00 617.11 542.97 12.30 690.23 7.28 50.12 688.79 614.65 17.50 785.50 11.15 46.87 782.81 708.67 27.67 879.52 15.82 45.83 874.22 800.08 42.82 974.27 20.38 46.15 964.25 890.11 63.26 1,069.98 24.05 47.98 1,052.84 978.70 87.87 1,165.56 25.82 45.79 1,139.51 1,065.37 115.43 1,260.77 29.71 44.29 1,223.75 1,149.61 146.79 1,355.84 34.12 45.07 1,304.43 1,230.29 182.50 1,451.46 38.20 44.94 1,381.61 1,307.47 222.38 1,545.48 37.94 44.14 1,455.63 1,381.49 263.70 1,641.99 42.58 45.12 1,529.26 1,455.12 308.06 1,737.16 45.50 41.90 1,597.67 1,523.53 356.06 1,831.90 48.60 40.30 1,662.22 1,588.08 408.32 1,926.57 48.19 40.70 1,725.08 1,650.94 462.15 2,021.64 52.75 39.75 1,785.57 1,711.43 518.13 2,116.77 52.37 38.37 1,843.41 1,769.27 576.78 2,212.61 55.88 38.23 1,899.56 1,825.42 637.71 2,307.20 59.36 39.76 1,950.21 1,876.07 699.77 2,402.58 63.82 41.21 1,995.58 1,921.44 763.55 2,497.60 68.41 42.31 2,034.05 1,959.91 828.33 2,546.64 70.63 41.85 2,051.21 1,977.07 862.42 2,593.00 72.43 42.00 2,065.89 1,991.75 895.14 2,687.05 71.81 40.58 2,094.77 2,020.63 962.39 2,782.60 70.41 40.22 2,125.70 2,051.56 1,031.23 2,878.24 68.62 39.67 2,159.17 2,085.03 1,099.91 2,973.33 71.61 39.26 2,191.51 2,117.37 1,168.94 3,040.17 70.46 39.95 2,213.23 2,139.09 1,217.64 3,083.70 69.11 40.36 2,228.28 2,154.14 1,248.86 3,178.37 68.62 41.05 2,262.41 2,188.27 1,315.80 3,274.37 69.68 39.57 2,296.58 2,222.44 1,384.21 3,368.98 72.74 40.78 2,327.05 2,252.91 1,452.63 3,464.61 70.97 41.32 2,356.83 2,282.69 1,521.16 3,559.43 69.80 41.08 2,388.66 2,314.52 1,588.37 3,654.27 69.64 40.63 2,421.53 2,347.39 1,655.65 3,749.28 68.83 42.38 2,455.22 2,381.08 1,722.18 3,844.67 70.66 41.37 2,488.24 2,414.10 1,788.82 Map Map Vertical +E/-W Northing Easting DLS Section (ft) (ft) (ft) (°1100') (ft) Survey Tool Name 11.75 6,OOo,472.10 529,310.02 1.9i 11.75 MWD+IFR-iiiti-CAZ-SC (2) 15.40 6,008,474.38 529,321.65 1.74 15.40 MWD+IFR-AK-CAZ-SC (2) 19.99 6,008,477.36 529,326.23 1.42 19.99 MWD+IFR-AK-CAZ-SC (2) 22.07 6,008,478.86 529,328.31 2.45 22.07 MWD+IFR-AK-CAZ-SC (2) 28.59 6,008,484.08 529,334.80 7.85 28.59 MWD+IFR-AK-CAZ-SC (2) 39.95 6,008,494.30 529,346.12 4.10 39.95 MWD+IFR-AK-CAZ-SC (2) 55.78 6,008,509.51 529,367.89 4.97 55.78 MWD+IFR-AK-CAZ-SC (2) 76.95 6,008,530.03 529,382.98 4.81 76.95 MWD+IFR-AK-CAZ-SC (2) 103.47 6,008,554.74 529,409.40 3.90 103.47 MWD+IFR-AK-CAZ-SC (2) 132.86 6,008,582.41 529,438.68 2.09 132.86 MWD+IFR-AK-CAZ-SC (2) 164.21 6,008,613.89 529,469.90 4.15 164.21 MWD+IFR-AK-CAZ-SC (2) 199.56 6,008,649.74 529,505.11 4.66 199.56 MWD+IFR-AK-CAZ-SC (2) 239.44 6,008,689.77 529,544.83 4.27 239.44 MWD+IFR-AK-CAZ-SC (2) 280.11 6,008,731.25 529,585.33 0.59 280.11 MWD+IFR-AK-CAZ-SC (2) 323.93 6,008,775.77 529,628.97 4.85 323.93 MWD+IFR-AK-CAZ-SC (2) 369.43 6,008,823.94 529,674.28 3.87 369.43 MWD+IFR-AK-CAZ-SC (2) 414.99 6,008,876.38 529,719.62 3.50 414.99 MWD+IFR-AK-CAZ-SC (2) 460.96 6,008,930.38 529,765.38 0.54 460.96 MWD+IFR-AK-CAZ-SC (2) 508.28 6,008,986.54 529,812.48 4.86 508.28 MWD+IFR-AK-CAZ-SC (2) 555.88 6,009,045.37 529,859.84 1.22 555.88 MWD+IFR-AK-CAZ-SC (2) 604.00 6,009,106.49 529,907.72 3.66 604.00 MWD+IFR-AK-CAZ-SC (2) 654.27 6,009,168.74 529,957.74 3.92 654.27 MWD+IFR-AK-CAZ-SC (2) 708.74 6,009,232.72 530,011.95 4.86 708.74 MWD+IFR-AK-CAZ-SC (2) 766.60 6,009,297.72 530,069.55 4.95 766.60 MWD+IFR-AK-CAZ-SC (2) 797.38 6,009,331.94 530,100.20 4.61 797.38 MWD+IFR-AK-CAZ-SC (2) 826.76 6,009,364.76 530,129.45 3.89 826.76 MWD+IFR-AK-CAZ-SC (2) 885.83 6,009,432.24 530,188.24 1.58 885.83 MWD+IFR-AK-CAZ-SC (2) 944.42 6,009,501.30 530,246.55 1.51 944.42 MWD+IFR-AK-CAZ-SC (2) 1,001.94 6,009,570.20 530,303.80 1.95 1,001.94 MWD+IFR-AK-CAZ-SC (2) 1,058.77 6,009,639.45 530,360.35 3.17 1,058.77 MWD+IFR-AK-CAZ-SC (2) 1,099.06 6,009,688.30 530,400.45 1.98 1,099.06 MWD+IFR-AK-CAZ-SC (2) 1,125.40 6,009,719.62 530,426.66 3.22 1,125.40 MWD+IFR-AK-CAZ-SC (2) 1,182.99 6,009,786.78 530,483.98 0.85 1,182.99 MWD+IFR-AK-CAZ-SC (2) 1,241.02 6,009,855.41 530,541.74 1.82 1,241.02 MWD+IFR-AK-CAZ-SC (2) 1,298.80 6,009,924.05 530,599.24 3.45 1,298.80 MWD+IFR-AK-CAZ-SC (2) 1,358.48 6,009,992.81 530,658.64 1.93 1,358.48 MWD+IFR-AK-CAZ-SC (2) 1,417.31 6,010,060.24 530,717.20 1.26 1,417.31 MWD+IFR-AK-CAZ-SC (2) 1,475.50 6,010,127.75 530,775.13 0.48 1,475.50 MWD+IFR-AK-CAZ-SC (2) 7,534.37 6,010,194.50 530,833.73 1.92 1,534.37 MWD+IFR-AK-CAZ-SC (2) 1,594.10 6,010,261.36 530,893.19 2.16 1,594.10 MWD+IFR-AK-CAZ-SC (2) 1/13/2009 11:00:57AM Page 3 COMPASS 2003.16 Build 42F • ConocoPhillips or its affiliates Definitive Survey Report Company: ConocoPhillips(Alaska) Inc. Local Co-ordinate Reference: We11 3K-108 Project: Kupa ruk River Unit ND Reference: 3K-1 08 @ 74.14ft (Doyon 15) Site: Kupa ruk 3K Pad MD Reference: 3K-1 08 @ 74.14ft (Doyon 15) Well: 3K-108 North Reference: True Wellbore: 3K-108 Survey Ca lculation Met hod: Minimum Curvature Design: 3K-108 _ Aatabase: EDM Alaska Prod v16 r- Survey - - - { Map Map Vertical MD Inc Azi ND NDSS +N/-S +E!-W Northing Easting DLS Section (h) (°) (°) (ft) (ft) (ft) (ft) (ft) (ft) (°1100') (ft) Survey Tool Name 3,940.42 70.1?. 40.79 2,520.39 2,446.25 1,856.85 1,653.41 6,010,329.62 560,953.22 0.79 1,653.41 MWD+IFR-AK-GAZ-SG X21 4,035.22 71.35 41.25 2,551.64 2,477.50 1,924.33 1,712.10 6,010,397.32 531,010.65 1.37 1,712.10 MWD+IFR-AK-CAZ-SC (2) 4,130.76 68.18 41.43 2,584.68 2,510.54 1,991.62 1,771.31 6,010,464.84 531,069.58 3.32 1,771.31 MWD+IFR-AK-CAZ-SC (2) 4,225.08 70.65 41.15 2,617.84 2,543.70 2,057.96 1,829.57 6,010,531.41 531,127.57 2.63 1,829.57 MWD+IFR-AK-CAZ-SC (2) 4,318.70 71.23 41.69 2,648.41 2,574.27 2,124.32 1,888.11 6,010,597.98 531,185.85 0.83 1,888.11 MWD+IFR-AK-CAZ-SC (2) 4,414.77 73.62 41.78 2,677.42 2,603.28 2,192.66 1,949.07 6,010,666.55 531,246.54 2.49 1,949.07 MWD+IFR-AK-CAZ-SC (2) 4,510.83 73.38 42.03 2,704.70 2,630.56 2,261.21 2,010.59 6,010,735.34 531,307.78 0.35 2,010.59 MWD+IFR-AK-CAZ-SC (2) 4,606.43 72.46 42.01 2,732.78 2,658.64 2,329.10 2,071.76 6,010,803.46 531,368.67 0.96 2,071.76 MWD+IFR-AK-CAZ-SC (2) 4,701.58 73.16 41.45 2,760.90 2,686.76 2,396.93 2,132.26 6,010,871.53 531,428.90 0.93 2,132.26 MWD+IFR-AK-CAZ-SC (2) 4,796.48 72.50 41.70 2,788.92 2,714.78 2,464.76 2,192.43 6,010,939.59 531,488.80 0.74 2,192.43 MWD+IFR-AK-CAZ-SC (2) 4,891.14 71.91 41.54 2,817.85 2,743.71 2,532.14 2,252.29 6,011,007.19 531,548.39 0.64 2,252.29 MWD+IFR-AK-CAZ-SC (2) 4,987.45 71.39 41.42 2,848.17 2,774.03 2,600.63 2,312.84 6,011,075.91 531,608.67 0.55 2,312.84 MWD+IFR-AK-CAZ-SC (2) 5,082.48 72.87 40.69 2,877.33 2,803.19 2,668.83 2,372.24 6,011,144.34 531,667.79 1.72 2,372.24 MWD+IFR-AK-CAZ-SC (2) 5,177.41 72.22 40.48 2,905.80 2,831.66 2,737.60 2,431.16 6,011,213.33 531,726.43 0.72 2,431.16 MWD+IFR-AK-CAZ-SC (2) 5,272.11 72.09 40.67 2,934.82 2,860.68 2,806.07 2,489.79 6,011,282.03 531,784.79 0.24 2,489.79 MWD+IFR-AK-CAZ-SC (2) 5,369.10 71.70 40.31 2,964.96 2,890.82 2,876.18 2,549.65 6,011,352.36 531,844.36 0.53 2,549.65 MWD+IFR-AK-CAZ-SC (2) 5,464.31 70.85 40.74 2,995.53 2,921.39 2,944.72 2,608.24 6,011,421.13 531,902.68 0.99 2,608.24 MWD+IFR-AK-CAZ-SC (2) 5,557.39 69.69 43.29 3,026.95 2,952.81 3,009.81 2,666.87 6,011,486.44 531,961.05 2.86 2,666.87 MWD+IFR-AK-CAZ-SC (2) 5,652.28 69.71 46.54 3,059.88 2,985.74 3,072.83 2,729.70 6,011,549.70 532,023.62 3.21 2,729.70 MWD+IFR-AK-CAZ-SC (2) 5,747.59 70.59 49.02 3,092.25 3,018.11 3,133.06 2,796.08 6,011,610.18 532,089.76 2.62 2,796.08 MWD+IFR-AK-CAZ-SC (2) 5,842.39 70.23 50.47 3,124.04 3,049.90 3,190.77 2,864.24 6,011,668.15 532,157.69 1.49 2,864.24 MWD+IFR-AK-CAZ-SC (2) 5,937.39 69.55 54.40 3,156.71 3,082.57 3,245.15 2,934.93 6,011,722.80 532,228.16 3.95 2,934.93 MWD+IFR-AK-CAZ-SC (2) ~ 6,032.89 67.84 56.94 3,191.41 3,117.27 3,295.33 3,008.39 6,011,773.27 532,301.41 3.06 3,008.39 MWD+IFR-AK-CAZ-SC (2) 6,127.77 69.13 60.75 3,226.22 3,152.08 3,340.97 3,083.91 6,011,819.20 532,376.75 3.98 3,083.91 MWD+IFR-AK-CAZ-SC (2) 6,200.70 70.87 64.51 3,251.17 3,177.03 3,372.46 3,144.76 6,011,850.93 532,437.47 5.40 3,144.76 MWD+IFR-AK-CAZ-SC (2) 6,250.37 71.97 67.30 3,267.00 3,192.86 3,391.67 3,187.74 6,011,870.31 532,480.36 5.77 3,187.74 MWD+IFR-AK-CAZ-SC (2) 6,286.30 71.83 68.92 3,278.16 3,204.02 3,404.41 3,219.43 6,011,883.16 532,512.00 4.30 3,219.43 MWD+IFR-AK-CAZ-SC (2) 6,317.78 72.17 69.18 3,287.89 3,213.75 3,415.11 3,247.39 6,011,893.98 532,539.91 1.34 3,247.39 MWD+IFR-AK-CAZ-SC (2) 6,411.71 72.30 72.17 3,316.56 3,242.42 3,444.71 3,331.79 6,011,923.90 532,624.19 3.03 3,331.79 MWD+IFR-AK-CAZ-SC (2) 6,509.38 73.76 75.02 3,345.07 3,270.93 3,471.08 3,421.39 6,011,950.62 532,713.68 3.17 3,421.39 MWD+IFR-AK-CAZ-SC (2) 6,602.58 76.41 79.32 3,369.06 3,294.92 3,491.05 3,509.17 6,011,970.94 532,801.37 5.29 3,509.17 MWD+IFR-AK-CAZ-SC (2) 6,651.82 78.02 81.44 3,379.96 3,305.82 3,499.07 3,556.51 6,011,979.14 532,848.68 5.32 3,556.57 MWD+IFR-AK-CAZ-SC (2) 6,698.75 78.74 82.76 3,389.42 3,315.28 3,505.39 3,602.05 6,011,985.64 532,894.18 3.15 3,602.05 MWD+IFR-AK-CAZ-SC (2) 6,795.20 80.40 85.32 3,406.88 3,332.74 3,515.23 3,696.38 6,011,995.85 532,988.46 3.13 3,696.38 MWD+IFR-AK-CAZ-SC (2) 6,890.30 79.92 88.37 3,423.13 3,348.99 3,520.39 3,789.92 6,012,001.38 533,081.98 3.20 3,789.92 MWD+IFR-AK-CAZ-SC (2) 6,985.68 81.58 92.03 3,438.47 3,364.33 3,520.05 3,884.04 6,012,001.41 533,176.09 4.17 3,884.04 MWD+IFR-AK-CAZ-SC (2) 7,081.09 81.59 91.54 3,452.43 3,378.29 3,517.11 3,978.38 6,011,998.84 533,270.43 0.51 3,978.38 MWD+IFR-AK-CAZ-SC (2) 7,176.21 81.34 93.83 3,466.55 3,392.41 3,512.71 4,072.34 6,011,994.80 533,364.39 2.40 4,072.34 MWD+IFR-AK-CAZ-SC (2) 7,271.04 80.31 92.03 3,481.67 3,407.53 3,507.92 4,165.83 6,011,990.38 533,457.89 2.17 4,165.83 MWD+IFR-AK-CAZ-SC (2 7,362.66 79.21 92.22 3,497.96 3,423.82 3,504.58 4,255.92 6,011,987.40 533,547.99 1.22 ~ 4,255.92 MWD+IFR-AK-CAZ-SC (2) 1/13/2009 11:1)0:57AM Page 4 COMPASS 2003.16 Bulld 42F ConocoPhillips or its affiliates Definitive Survey Report Company: ConocoPhillips(Alaska) Inc. Local Co-ordinate Reference: We11 3K-108 Project: Kuparuk River Unit ND Reference: 3K-108 @ 74.14ft (Doyon 15) Site: Kuparuk 3K Pad MD Refere nce: 3K-108 @ 74.14ft (Doyon 15) Well: 3K-108 North Reference: True Wellbore: 3K-108 Survey Ca lculation Meth od: Minimum Cu rvature Design: 3K-108 Database: EDM Alaska Prod v16 Survey i i i Map Map Vertical MD Inc Azi ND NDSS +NI-S +E/-W Northing Easting DLS Section (ft) (°) (°) (ft) (ft) (ft) (ft) (ft) (ft) (°1100') (ft) Survey Tool Name 7,454.24 6L55 52.77 3,512.52 3,438.73 3,500.64 4,346.18 6,011,983.02 533,632.25 3.09 4,346.18 MWD+IFR-Ak-CAZ-SC (2) 7,504.13 81.87 93.43 3,519.92 3,445.78 3,497.97 4,395.50 6,011,981.34 533,687.58 1.33 4,395.50 MWD+IFR-AK-CAZ-SC (2) 7,546.08 81.78 93.43 3,525.89 3,451.75 3,495.49 4,436.95 6,011,979.02 533,729.03 0.21 4,436.95 MWD+IFR-AK-CAZ-SC (2) 7,638.18 82.06 92.63 3,538.83 3,464.69 3,490.67 4,528.01 6,011,974.56 533,820.10 0.91 4,528.01 MWD+IFR-AK-CAZ-SC (2) 7,730.74 81.70 92.40 3,551.90 3,477.76 3,486.65 4,619.55 6,011,970.90 533,911.65 0.46 4,619.55 MWD+IFR-AK-CAZ-SC (2) 7,822.47 87.06 91.94 3,560.88 3,486.74 3,483.19 4,710.74 6,011,967.80 534,002.84 5.86 4,710.74 MWD+IFR-AK-CAZ-SC (2) 7,864.44 86.97 92.02 3,563.07 3,488.93 3,481.74 4,752.63 6,011,966.52 534,044.73 0.29 4,752.63 MWD+IFR-AK-CAZ-SC (2) 7,915.06 85.29 91.84 3,566.49 3,492.35 3,480.04 4,803.10 6,011,965.02 534,095.21 3.34 4,803.10 MWD+IFR-AK-CAZ-SC (2) 7,975.38 84.78 91.71 3,571.71 3,497.57 3,478.18 4,863.17 6,011,963.39 534,155.27 0.87 4,863.17 MWD+IFR-AK-CAZ-SC (2) 8,069.31 89.07 89.70 3,576.75 3,502.61 3,477.03 4,956.93 6,011,962.61 534,249.03 5.04 4,956.93 MWD+IFR-AK-CAZ-SC (2) 8,164.30 87.10 87.31 3,579.92 3,505.78 3,479.51 5,051.82 6,011,965.46 534,343.90 3.26 5,051.82 MWD+IFR-AK-CAZ-SC (2) 8,259.46 86.23 87.66 3,585.46 3,511.32 3,483.68 5,146.73 6,011,970.00 534,438.78 0.99 5,146.73 MWD+IFR-AK-CAZ-SC (2) 8,355.50 89.69 87.78 3,588.87 3,514.73 3,487.49 5,242.62 6,011,974.19 534,534.64 3.60 5,242.62 MWD+IFR-AK-CAZ-SC (2) 8,450.54 89.38 87.06 3,589.65 3,515.51 3,491.77 5,337.56 6,011,978.84 534,629.56 0.82 5,337.56 MWD+IFR-AK-CAZ-SC (2) 8,545.73 89.88 87.23 3,590.26 3,516.12 3,496.51 5,432.63 6,011,983.96 534,724.60 0.55 5,432.63 MWD+IFR-AK-CAZ-SC (2) 8,641.99 90.80 88.19 3,589.69 3,515.55 3,500.36 5,528.81 6,011,988.18 534,820.75 1.38 5,528.81 MWD+IFR-AK-CAZ-SC (2) ~ 8,735.36 89.01 87.42 3,589.84 3,515.70 3,503.93 5,622.10 6,011,992.12 534,914.03 2.09 5,622.10 MWD+IFR-AK-CAZ-SC (2) 8,830.50 89.38 88.34 3,591.18 3,517.04 3,507.45 5,717.17 6,011,996.01 535,009.07 1.04 5,717.17 MWD+IFR-AK-CAZ-SC (2) 8,926.15 88.64 88.83 3,592.83 3,518.69 3,509.82 5,812.77 6,011,998.75 535,104.65 0.93 5,812.77 MWD+IFR-AK-CAZ-SC (2) 9,020.21 89.01 93.03 3,594.76 3,520.62 3,508.29 5,906.78 6,011,997.59 535,198.65 4.48 5,906.78 MWD+IFR-AK-CAZ-SC (2) 9,117.28 89.57 96.93 3,595.97 3,521.83 3,499.86 6,003.46 6,011,989.55 535,295.35 4.06 6,003.46 MWD+IFR-AK-CAZ-SC (2) 9,212.14 88.33 96.88 3,597.70 3,523.56 3,488.46 6,097.61 6,011,978.52 535,389.54 1.31 6,097.61 MWD+IFR-AK-CAZ-SC (2) 9,306.35 88.03 97.28 3,600.70 3,526.56 3,476.86 6,191.06 6,011,967.28 535,483.02 0.53 6,191.06 MWD+IFR-AK-CAZ-SC (2) 9,401.26 88.33 94.19 3,603.71 3,529.57 3,467.38 6,285.43 6,011,958.18 535,577.43 3.27 6,285.43 MWD+IFR-AK-CAZ-SC (2) 9,496.89 89.20 93.49 3,605.77 3,531.63 3,460.98 6,380.82 6,011,952.15 535,672.83 1.17 6,380.82 MWD+IFR-AK-CAZ-SC (2) 9,593.08 91.54 92.91 3,605.15 3,531.01 3,455.61 6,476.85 6,011,947.16 535,768.87 2.51 6,476.85 MWD+IFR-AK-CAZ-SC (2) j 9,687.88 90.00 92.71 3,603.88 3,529.74 3,450.96 6,571.53 6,011,942.88 535,863.56 1.64 6,571.53 MWD+IFR-AK-CAZ-SC (2) 9,782.42 90.80 94.82 3,603.22 3,529.08 3,444.75 6,665.86 6,011,937.05 535,957.90 2.39 6,665.86 MWD+IFR-AK-CAZ-SC (2) 9,878.29 90.43 95.47 3,602.19 3,528.05 3,436.16 6,761.33 6,011,928.83 536,053.40 0.78 6,761.33 MWD+IFR-AK-CAZ-SC (2) 9,973.46 90.12 98.88 3,601.73 3,527.59 3,424.27 6,855.74 6,011,917.31 536,147.85 3.60 6,855.74 MWD+IFR-AK-CAZ-SC (2) 10,068.17 90.49 99.26 3,601.23 3,527.09 3,409.34 6,949.27 6,011,902.75 536,241.42 0.56 6,949.27 MWD+IFR-AK-CAZ-SC (2) 10,163.27 89.07 102.37 3,601.59 3,527.45 3,391.50 7,042.66 6,011,885.28 536,334.88 3.59 7,042.66 MWD+IFR-AK-CAZ-SC (2) 10,259.01 86.92 103.55 3,604.94 3,530.80 3,370.04 7,135.90 6,011,864.19 536,428.19 2.56 7,135.90 MWD+IFR-AK-CAZ-SC (2) 10,354.16 87.53 103.05 3,609.55 3,535.41 3,348.18 7,228.39 6,011,842.69 536,520.75 0.83 7,228.39 MWD+IFR-AK-CAZ-SC (2) 10,447.66 89.14 102.51 3,612.26 3,538.12 3,327.51 7,319.53 6,011,822.38 536,611.97 1.82 7,319.53 MWD+IFR-AK-CAZ-SC (2) 10,542.91 89.82 103.49 3,613.13 3,538.99 3,306.08 7,412.33 6,011,801.32 536,704.84 1.25 7,412.33 MWD+IFR-AK-CAZ-SC (2) 10,639.09 90.12 102.98 3,613.18 3,539.04 3,284.06 7,505.96 6,011,779.67 536,798.54 0.62 7,505.96 MWD+IFR-AK-CAZ-SC (2) 10,734.96 89.44 101.78 3,613.55 3,539.41 3,263.51 7,599.60 6,011,759.49 536,892.25 1.44 7,599.60 MWD+IFR-AK-CAZ-SC (2) 10,829.44 88.95 101.72 3,614.88 3,540.74 3,244.27 7,692.09 6,011,740.62 536,984.81 0.52 7,692.09 MWD+IFR-AK-CAZ-SC (2) 10,924.48 90.68 101.60 3,615.18 3,541.04 3,225.06 7,785.16 6,011,721.78 537,077.95 1.82 7,785.16 MWD+IFR-AK-CAZ-SC (2) 1/13/2009 11:00:57AM Page 5 COMPASS 2003.16 Build 42F ConocoPhillips or its affili ates Definitive Survey Report Company: ConocoPhillips(Alaska) Inc. Local Co-ordinate Reference: We113K-108 Project: Kuparuk River Unit TVD Reference: 3K-108 @ 74.14ft (Doyon 15) Site: Kuparuk 3K Pad MD Refere nce: 3K-108 @ 74.14ft (Doyon 15) Well: 3K-1 08 North Reference: True Wellbore: 3K-1 08 Survey Ca lculation Meth od: Minimum Cu rvature Design: 3K-1 08 Database: EDM Alaska Prod v16 'Survey Map Map Vertical MD Inc Azi TVD TVDSS +NI-S +EI-W Northing Easting DLS Section (ft) (°) (°) (ft) (ft) (ft) (ft) (ft) (ft) (°1100') (ft) Survey Tool Name 11,019.02 22.70 101.69 .3,615.69 3,541.55 3,205.97 7,877.81 6,019,703.05 537,1 i0.66 2.10 i,2i7.21 MWD+IFR-AK-CAZ-SC (2) 11,114.33 88.64 99.86 3,617.90 3,543.76 3,188.17 7,971.35 6,011,685.62 537,264.26 1.92 7,971.35 MWD+IFR-AK-CAZ-SC (2) 11,208.77 87.59 99.28 3,621.01 3,546.87 3,172.48 8,064.42 6,011,670.29 537,357.39 1.27 8,064.42 MWD+IFR-AK-CAZ-SC (2) 11,304.92 88.40 99.60 3,624.38 3,550.24 3,156.72 8,159.21 6,011,654.91 537,452.23 0.91 8,159.21 MWD+IFR-AK-CAZ-SC (2) 11,399.43 87.84 700.92 3,627.48 3,553.34 3,139.89 8,252.16 6,011,638.45 537,545.23 1.52 8,252.16 MWD+IFR-AK-CAZ-SC (2) 11,494.84 87.22 101.72 3,631.59 3,557.45 3,121.18 8,345.63 6,011,620.11 537,638.76 1.06 8,345.63 MWD+IFR-AK-CAZ-SC (2) 11,589.63 92.35 101.07 3,631.94 3,557.80 3,102.46 8,438.52 6,011,601.75 537,731.71 5.46 8,438.52 MWD+IFR-AK-CAZ-SC (2) 11,633.13 91.54 101.77 3,630.47 3,556.33 3,093.85 8,481.13 6,011,593.31 537,774.36 2.46 8,481.13 MWD+IFR-AK-CAZ-SC (2) 11,685.01 90.62 102.46 3,629.49 3,555.35 3,082.97 8,531.84 6,011,582.63 537,825.11 2.22 8,531.84 MWD+IFR-AK-CAZ-SC (2) 11,780.91 88.52 101.37 3,630.21 3,556.07 3,063.17 8,625.67 6,011,563.20 537,919.00 2.47 8,625.67 MWD+IFR-AK-CAZ-SC (2) 11,875.31 88.15 100.99 3,632.95 3,558.81 3,044.87 8,718.24 6,011,545.27 538,011.63 0.56 8,718.24 MWD+IFR-AK-CAZ-SC (2) 11,969.05 87.84 101.09 3,636.23 3,562.09 3,026.93 8,810.19 6,011,527.70 538,103.64 0.35 8,810.19 MWD+IFR-AK-CAZ-SC (2) 12,065.30 87.90 99.52 3,639.81 3,565.67 3,009.73 8,904.81 6,011,510.86 538,198.33 1.63 8,904.81 MWD+IFR-AK-CAZ-SC (2) 12,160.78 87.90 97.58 3,643.31 3,569.17 2,995.54 8,999.17 6,011,497.05 538,292.72 2.03 8,999.17 MWD+IFR-AK-CAZ-SC (2) 12,255.45 87.10 97.71 3,647.44 3,573.30 2,982.96 9,092.90 6,011,484.84 538,386.50 0.86 9,092.90 MWD+IFR-AK-CAZ-SC (2) 12,348.46 88.83 99.53 3,650.74 3,576.60 2,969.03 9,184.80 6,011,471.27 538,478.44 2.70 9,184.80 MWD+IFR-AK-CAZ-SC (2) 12,444.62 88.64 99.45 3,652.86 3,578.72 2,953.18 9,279.62 6,011,455.79 538,573.31 0.21 9,279.62 MWD+IFR-AK-CAZ-SC (2) 12,540.15 86.73 98.75 3,656.72 3,582.58 2,938.08 9,373.86 6,011,441.07 538,667.61 2.13 9,373.86 MWD+IFR-AK-CAZ-SC (2) 12,635.34 84.68 98.03 3,663.85. 3,589.71 2,924.23 9,467.77 6,011,427.59 538,761.55 2.28 9,467.77 MWD+IFR-AK-CAZ-SC (2) 12,729.56 84.75 98.41 3,672.53 3,598.39 2,910.82 9,560.62 6,011,414.54 538,854.45 0.41 9,560.62 MWD+IFR-AK-CAZ-SC (2) 12,825.77 88.77 103.22 3,677.97 3,603.83 2,892.80 9,654.92 6,011,396.89 538,948.81 6.51 9,654.92 MWD+IFR-AK-CAZ-SC (2) 12,874.18 91.91 103.69 3,677.68 3,603.54 2,881.53 9,702.00 6,011,385.81 538,995.93 6.56 9,702.00 MWD+IFR-AK-CAZ-SC (2) 12,920.64 91.48 103.45 3,676.31 3,602.17 2,870.64 9,747.14 6,011,375.10 539,041.11 1.06 9,747.14 MWD+IFR-AK-CAZ-SC (2) 13,016.42 88.39 103.29 3,676.42 3,602.28 2,848.49 9,840.31 6,011,353.32 539,134.36 3.23 9,840.31 MWD+IFR-AK-CAZ-SC (2) 13,107.32 86.92 103.50 3,680.14 3,606.00 2,827.45 9,928.66 6,011,332.63 539,222.78 1.63 9,928.66 MWD+IFR-AK-CAZ-SC (2) ,13,180.00 86.92 103.50 3,684.04 .3,609.90 2,810.51 9,999.23 6,011,315.97 ~ 539,293.41 0.00 9,999.23 PROJECTED to TD 1/13/2009 11:00:57AM Page 6 COMPASS 2003.16 Build 42F --_. KUP 3K-108 ~. ~ py Cd~~4rl ll~~~p~r ,~ Well Attributes Max angle & MD --- - TD ~ Ai',a"d11:1Tk.. '~ 1 Wellbore APVUWI Field Name ' ~ Well Status Prod/Inj Type Ilncl (°) MD (ftKB) l Acl Btm (ftKB) , 1600292339600. WEST SAK 11,58963 INJ SWI 92.35 13,180.0 WHI GOnfg MUL IPLE LATERALS 3K 1U6,'21s!i2U0II'V 45 Schematic AcWal _ IComment H2S (ppm) fly AM S$SV: NIPPLE l Annotation De th ftKB End Date Last Tag: p ( ) ~ (Date ~A otation End Date ~KB-Grd (H) _ Last WO: 0.34 Annotation IRev Reason: NEW WELL Rig Release Date 12/27/2008 End Date 12/31/2008 RANGER, 13- '~: '= ~ Casin Stria s HANGER. 2s --- - - Casing Descnption CONDUCTOR Casing Descnption String 0... ' 20 String 0... String ID ... 19.124 String ID ... Top (ftKB) 42.0 Top (NKB) Set Depth (f... 162.0 Set Depth (f... Set Depth (ND) .. 162.0 Set Depth (ND) ... String W[... 94.00 Siring Wt... String String ... Str ng Top Thrd Stang Top Thrd ~ ( Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (ND) ... String Wt... I M~ERMEDIATE 9518 8.835 39.9 8,015.8 3,576.9 40.00 Casing Description String 0... String ID ... Top (ftKB) Sat Depth (f... Set Depth (ND) .. . (String Wt... Seal Bore Diverter 7 4.790 7,272.9 7,379.4 3 501.0 ' Casing Description String 0... String ID ... Top (ftKB) Sat Depth (f... Set Depth (ND) .. . 'String Wf... B-SAND LINER 3 1/2 2.930 7,334.4 13,150.4 3,683.9 9.20 coNDUCTOR, ___ - Liner Details 42-162 ~ Top Depth i I (ND) Top Inc! I SURFACE 133/8 12.415 42.7 3,069.7 2,223.3 68.00 L-80 BTC NIPPLE, 515 NIPPLE, 528 SLEEVE, 2,489 GAS LIFT, 2,506 SURFACE, 43-3.070 Packer Dual 7 17fi Pad~er -oval, 7,m Packer -Dual, 7,181 Packet-Dual, ],186 Packer -Dual, 7,189 Packer-Dual, Deal seal, 7,253 Deal seal, 7.247 Dual Seal, 7,258 SEAL ASSY, 7.279 Dual Seal. 7,285 Seal Bore Divener, ],2]3-7,379 D Lateral tie back 8 RAM han0er. T.268~7.382 PLUG, 7,438- -- TERMED WTE,_ -.__ 40 8 016 screen, _ , - 8 2068.239 Screen, y I ! -_ 8.654-6.665 ~°' I ! -. Srzeen, 9,253-9,285 -^ I ~ - Srseen,_. _.._.__~; -_ 9,733-9.765 -.. ~ I i Svee 10,266-10,298 '" Sae _ I i ._ 10,]43-10,7]4---'-- -- ~ I ~ m. Sheen, 11,221-11,2521- --------+: ;s Seen. ~, I I ~, 11,819-11,851 \-_ _ acre n, 12.460 "-' e Soee 13,056-13.0(17 - i ~ ^ 8-SAND~_ -_~ LINER, e,: :"+ 7,33d-13,150 IIe~1I TD (3K-108), _ - P 13.180 -"'_-" - SLHT -__ lker MLZXP liner Hanger Packer- below collet OD 8.42"/ID 6.184" tker Flex-Lock Hanger 7"x 9-818"/8.29" ODx6.1S" ID __ 10-07 CSG Sealbore receptacle w/ (2) 3/8" hole o~1.180 deg apart 6.3" 7x4.76"ID (ftKB( Set Depth (i... Set Depth (ND) .. String Wt... Str g String Top T 24 9 I 7,290 3 ~. 3 481.7 9 20_ L 80 --- IBTM Top Inc! (°) Item 14.9 24.9 -U.1(i HANOEH I VetCO Gray UUaI 13-318" x 3-1/1" X 3-1lL" w/ S. /16" MCA I Op UOnnEC[IOn S.6UU 527.9 1 527.5 5.61 NIPPLE ~ ~ __._. 3-1/2" Camco "DS" Nipple w/ 2.875" Profile (EUE 8rd) (4.27" O.D.) _- - 2.875 7,186.4 3,468.1 81.23 ~~ Packer -Dual ! -- _-- Baker "GT" Dual Packer Mandrel (3-7/2"NU (Ord Boz z Pln) - - 2.930 7,188.6 3,468.4 81.21 Packer- Dual Baker 9-S/8" x 3-1/2" "GT" ReMevable Dual Packer (40K Shear Release) 7,192.2 3,469.01 81.77 Packer -Dual Baker "GT" Dual Packer Mandrel (3-7/2" NU tOrtl Box x Pln) 2.920 -- - 7,214.4 - 3,472.6 80.93 NIPPLE - - - 3-1/2" Camco "DS" Nipple w/ 2.812" No-Go Prof le (EUE Snl B x P) - 2.872 7,222.8 3,474.0 80.83 Extension Jt Baker 3.38", L-80, "DSM" Extension Joint (3.220" SSDS Box x Pin) 2.720 7,252.6 3,478.6 80.51 Dual Seal Baker 3.38", L-80, "DSM" Extension Joint Mandrel (3.220" SSDS Box z 2.700 Pin) 7,258.1 3,479.5 80 46 Dual Seal Baker 7" x 9-6/8" "Ram" Dual Seal Module (Above Collet) 2.700 7.284.8 1 3,480.2 76.84 Dual Seal Baker 7" x 9-5/8" "Ram" Dual Seal Module (Below Collet) 2.700 10.61 81.51 9,733.3 9,7647 10,266.5. 10,297.9 10,742.6 10,774.0 I 11,22Q6 11,251.9 11,819.4 11,850.6 12,459.81 124 0 13.056.01 13.087.4 1 _ _ Comment Run Date ! ID IBP IN B-LINER w(-3' CaC03 ON TOP OF IT 12/2712008 10. Dens B, 3K-108 12/12008 99.0 Screen Resinject Reslink Screen B, 3K-108 12/1/2005 99.0 Screen Resinject Reslink Screen B, 3K-108 12/1/2008 99.0 Screen - _ _ Resinject Reslink Screen B, 3K-108 1211/2008 99.0 Screen Resinject Reslink Screen B, 3K-108 12/12008 99 0 Screen Resinject Reslink Screen B, 3K-108 12/1/2008 99.0 Screen Resinject Reslink Screen Port OD Valve Latch I Size TRO R Make Model ~ (In) Serv Type Type 1 (in) (psi) Run Date Comm - -- 1 Ilr AMCO KBG-2-9 1 Gas Llft DMY DCK-3 0 0 0 12/22/2008 13-3/8" Casing Shoe 3070' MD, 2223' TVD (70.5 deg) Can©c©P~rli~ps 0~.~ ~ ~'~;ti S 539'MD-2.875"DS Nipple 2008 West Sak Dual Injector System ~r~ t~Sg / 540'MD~2.875"DS Nipple with Level 5 Rotating self-Aligning Multilateral (RAMrm~ System 2513' MD- CMD Sliding Sleeve, 3~/:" X 2613" BX Profile ~~ 2518'MD-GLM, Camco, 3~'/x"xi"K8G2~g West Sak 3K-108 7198' MD- Antl-Rotation Clamp Dual Tubing Strings 3 '/" 9.3# IBTM wISCC L-80, 2.992" ID, 2.867" DrHt 7222' MD- Tubing Swivel Sub /7231' MD- 2.750" D Nipple 7201' MD- 3~/::" x 9.5/8" GT Dual Packer 7226' MD- 2.813" DS Nipple 7270' MD- 3~/:" x 3~%' x 9.5/8" Dual f Seal Module for RAM Hanger / 7288' MD- 7" X 9.5/8" RAM Hanger ~ry~ainment Specifications 7" X 9-5/8" RAM Junction Malnbore Drift: 3.68" Lateral Drift: 5.80" RAM Hanger/Seal Bore Dlvener OD: 8.375" Overall Length of RAM Junction: 38.3 ft Seal Bore Dlverter Running Tool: FJD RAM Hanger Running Tool: HRD-E 3-Y" x 3'/," 9-5/8" Dual Seal Module DSM OD 7.62" Lateral Seal Assembly OD• 3 75" Lateral lD' 2.69" Malnbore Seal Stinger OD: 3.08" Malnbore ID'. 2.69" 7382' MD- Sealbore 4.75"ID 7379' MD- 5-'/." Bowen Overshot 5.75" OD 7343' MD- MLHR Production Anchor ~'sM s ~o~ BB/(PI' ~I( TOOiS As Completed TD 13189' MD, 3630' TVD Liner Shoe 11473 MD, 3560' TVD (90 deg) 7364' MD-Seal Assembly ` \~ \ 4.75" seal OD J 3.875"ID 'B' Sand Lateral 3~ '." G.3q Liner with Hydril 563 and TD ~ I SLHT 13180' MD, 3684' TVD (87 deg) Idit~ i 1 ~ ~ i a y, ~ ~ e4 - ~:.. ~ . - L,. it er $h Oe 9.518" Casing Shoe, 40.1)#, L-50 BTC .3.50' MD, 3682' TVD 8016' MD, 3575' TVD (88 deg) (87 deg) 7273' MD-4-'/:" x 9.5/8" RAM Seal Bore Dlverter~ (saol for Dnal seal Moarne 4%" 12.6# IBTM 8 Hydril 521 Tuk D-Sand Casing Exit 7280' MD, 3483' TVD (80 deg) 'D' Sand Lateral 3'/:" 9.3M Liner with SLHT connections 7335' MD-7" X 9.518" ML: Liner Hanger Packer ~~~ ~~ TI~,4/1/lt+~/T°~~L ProActive Diagnostic Services, Inc. To: AOGCC Christine Mahnken 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 (907] 659-5102 RE : Cased Hole/Open Hole/Mechanical Logs and/or Tubing Inspection(Caliper/ MTT] The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the following ProActive Diagnostic Services, Inc. Attn: Robert A. Richey 130 West International Airport Road Suite C Anchorage, AK 99518 Fax: (907j 245-8952 1) Caliper Report 22-Dec-08 3K 108 (run 3) 1 Report / EDE 50-029-23395^00 2) ao~ -~3~ I'7 32 ~ ~ ~-<3a5- ~~ a3 Signed : Date Print Name: ~ i=zr~,A.v (~,~ PROACTNE DIAGNOSTIC SERVICES, INC., 130 W. INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245-8951 Fax: (907)245-88952 E-MAIL: ~cdrar'~hc~r~rc~~(c~rr'~rr~cas~t~Bbc~°isarr~ WE831TE: va~~JVa.rs~vmA~a:-s~i~~l~t~,_~~r; "') C:\DocumeNs and Settings\Owner\Desktop\Transmit_Conoco.docx Memory Mufti-Finger Caliper Log Results Summary Company: CanocoPhi#lips Alaska, Inc. Well: 3K-108 Log Date: December 22, 2008 Field: West Sak Log No.: 7291 State: Alaska Run No.: 3 API No:: 50-029-23395-00 Pipet Desc.: "L-1" RAM Hanger Assembly Top Lag Intel: 7,240 Ft. (MD) Pipet Use: Hanger Bot. Log Intel: 7,273 Ft. (MD) Inspection Type : Collet Orientation Inspection COMMENTS This caliper data is tied i»to the tap of the L€M col%t @ 7,268.36' (Dril/er's Depth). This log was run to assess the engagement of the "L-1" RAM hanger assembly. Two runs were made at 50fpm and 60fpm respectively. 3-D log plots of the 50 fpm and 60 fpm caliper recordings are included in this report. The caliper hung-up momentarily during the 60fpm pass in the "DSM" Extension Joint above the LEM collet from 7,244' to 7,258'. The caliper recordings indicate light deposits in the "DSM" Extension Joint and in the collet of the "L-1" RAM hanger assembly. Field Engineer. Wm. McCrossan Analyst: C. Waldrop & M_ Lawrence Witness: M. Thornton ProActive Diagnostic Services, Inc. / P.O. Box 1369, Stafford, TX 7?49? Phone: (281} or (888) 565-9085 Fax: (281} 565-1369 E-mail: PDS@memorylog.com Prudhoe Bay Field Office Phone: (907) 659-2307 Fax: (907} 659-2314 ~~~ 13c~ t X325 PDS Multifinger Caliper 3D Log Plot ~, S ` Company : ConocoPhillips Alaska, Inc. Field : West Sak Well : 3K-108 Date : December 22, 2008 Description : Detail of 50 FPM Caliper Recordings Across "L-1 "RAM Hanger Assembly • PDS Multifinger Caliper 3D Log Plot ~~ ~ ~~_ Company : ConocoPhillips Alaska, Inc. Field : West Sak Well : 3K-108 Date : December 22, 2008 Description : Detai- of 60 FPM Caliper Recordings Across "L-1 "RAM Hanger Assembly Baker Slick Stinger 7245 7250 "~sM" 7255 Extension Joint Mandrel Travel (21.27') Hang~Jp 7260 T265 Upper Ram 7270 Hanger LEM Collet Profile #~ '~~ti;t ~ ~~ ~ . ~3 ~, +T S~~i `~= = . R. t_:, ~ ~'R ~- t ~~, y~;~^7t ~ x war w ~Ir r r ~r it r w w w rs w. w r~ ~ ~r Insulated Conductor. 20" 94N K-i5 x 34" 0.312 WT+I- ~' ~-~ ConocoPhillips 2B7,.D,,,PP„ 2008 West Sak Dual Injector System 2.679 DS MppN with Level 5 Rotating self-Aligning j~,ultilateral (RAMT^^) System eLM, Caeto, S•Y.• x t• KBDYB OLM, Cwr-., a.55•x,•1(BDYA West Sak ,3318" caging snee. 3K-108 3300' MD, 7113' ND Dual hbinp Strings Roh9onel AligmmaM Bub 3•%° 8.3N, L-60, T.9S2° W, 2867• Drill 2.812• DB Niggle 9•K' z 9-LS' raT Dual Paekr 9•K• X 9•K' x 9~31Y Dual Seal / Montle for RAN Xangar r X 9~5A• RAM Xargar Faguipment Specifications 7"X9.5/8" RAM Junction Mainbore Drift: 3.88• Lateral Drill: 5.88• RAM Hang«ISeal sore Deserter OD: 8.375' OvaraB Length of RAMJunclia+: 38.3 R Heal Bore Diverter Running Tool: FJD RAM Hmger Running Tool: NRD-E 3-'/a" x 3-'/:" 9.5/8" Dual Seal Module DsMOD: zs2• Latent Heal Assembly OD: 3.75' Lateral lD: 286• Mainbore Saal Htlnger OD: 3.08• MaMbore b: 2.69• s.anaro Raceptad. 4.75° D As Planned DSand 8021' 8 Send 543D' Total Drilled Footage 19136' Caeing Shoe 13114' MD, 3629' ND MLFNI Protluctlan McMr SW Aaswnhy a,7s° sw oD 9A75•D ~' Sand Lateral ax- a.aNLerw van sLlrr coon«tlons &518" Casing Shoe, 4 .ON, L-80 BTC 7686' MD, 3533' ND 1111~NE s Baker Ott Tonle •i • Casing Shoe 1311T MD, 3679' ND 6Sand caeing Exil 7093' M0, 3456' ND (60 deg) 1•X• 9.3N LmM N1Dr SLNr eonnaetlorrs 475° s S-5f8" RAM Soul Ban D1vMtel ~ IsBDI rer DwX SeN ModNa s-u• tt.a uTM Tubklg / r x ssa• MLZ~ Lher Narrgar PaeXar Memory Multi-Finger Caliper ~, Log ResuEts Summary Company: ConocoPhillips Alaska, Inc. Well: 3K-108 Lag Date:. December 22, 2008 Field: West Sak Log No.: 7291 State: Alaska Run No.; 2 API No.: 50-029-23395-00 Pipet Desc.: 3.5" 9.3 Ib. L-80 Tap Log Intvl: 6,649 Ft. (MD) Pipet Use: Tubing Bot. Log Intvl: 7,269 Ft. (MD) Inspection Type : Collet Orientation Inspection COMMENTS This caliper data is tied into the top of the LEM collet @ 7,268.36` (Driller's Depth). This log was run to assess the orientation of the LEM collet in the "RAM" dual seal bore diverter assembly. The caliper hung-up in the "Ram" dual seal bore diverter assembly from _7,258' to 7,267'. The caliper recordings indicate deposits in the "RAM" dual seal bore diverter assembly that mask the surface of the LEM collet resulting in the inability to determine the orientation of the collet. 3-D log plots of the caliper recordings from 7,210' to 7,269' and 7,256' to 7,269' are included in this report. No significant wall penetrations or areas of cross-sectional wall loss are recorded. The caliper recordings indicate the 3.5" tubing appears to be in good condition with respect to internal corrosive and mechanical damage, with no significant wall penetrations, areas of crass-sectional wall loss, or I.D. restrictions recorded. This is the second time a PDS Caliper. has been run in this well and the second time the "RAM" dual seal bore diverter assembly has been logged. Field Engineer: Wrn. McCrossan Analyst: C. Waldrop Witness: M. Thornton ProActive Diagnostic Services, Inc. / P.O. Box 1369, Stafford, TX 77497 Phone: {281) or (888) 565-9485 Fax: (281) 565-1369 E-mail: PDSC~memorylog.com Prudhoe Bay Field Office Phone: (907) 659-2307 Fax: (907) 659-2314 a o~-r3~ ~ ~-3ay PDS Multifinger Caliper 3D Log Plot ~. _ _S Company : ConocoPhillips Alaska, Inc. Field : West Sak Well : 3K-108 Date : December 22, 2008 Description : Detail of Caliper Recordings Across "RAM" Dual Seal Bore Diverter Assembly • PDS Multifinger Caliper 3D Log Plot ~~_ . _ ~~. Company : ConocoPhillips Alaska, Inc. Field : West Sak Well : 3K-108 Date : December 22, 2008 Description : Detail of Caliper Recordings Across "RAM" Dual Seal Bore Diverter Assembly >• ~ ~ ~ r ~ ~ r ~ s ~ ~ r ~ ~ ~ ~ r ~ I nsuleted Conductor: 2a' s4a K-55x34° 0.312 WT +!- 80' y -. ConocoPhillips 2.,,,.,~„,,,a 2008 West Sak Dual Injector System 1.873°OS Nlppk with Level 5 Rotating self-Aligning J~ultilateral (RAMrM) DLM, Cameo, 9.X• x," %902A System DLM, Camce, 9-X°a,°R.D2d West Sak 133!8" Casing Shoe 3 K-108 3300' MD, 2213' ND Dual Tubing Strings weal Alignment Sub 3-X' 8.38, L-86, 2.982" 2.887" DrHf ~ Rotatl 28'12" OB Nipple 8d3° x 8.518.OT Dual hexer 9-X° x 8-X° x 83/8• Dual foal / MOaala for MM Nenger 7° % 88R• RAM Nangar Eauit3ment Specifications 7"X9.5/8" RAM Junction Mdn6ore DrNt: 3.Bi" Laterd Drift: S.a0" RAM Hanger/Seal Bwe Dlrerter OD: 8.375' Ovsratl Length of RAM Junction: 3a.3 N Sad Bore Dlverter Running Tool: FJD RAM Hanger Runnlnp Tool: HRD-E 3-Y:" x 3.Ya" 9.5/8" Dual Seal Module DSM OD: 7.82' Lateral Sed Assembly 00: 3.75' Lateral ID: 2.88" Mdnborc 4ed Stlngw OD: 3.68" Mdnbore 10: 2.69" MLNl Plvauctlen Anchor BW Aafan6ty 0.73.9oN DD 8.875• ID 9•Sl8" Casing Shoe, 4dOft, L-90 BTC 7688' MD, 3533' TVD !/ii saw 13alur,:Al Tmk ~I • Casing Shoe 1311T MD, 3675' TVD D-SarNf Casing Exit 7093' MD, 3459' ND (BOdeg) °D' Sand Lateral 8•X• 938 Llnar w8tl1 SLNT eew-etloln As Planned Lateral Lenotht DSend 6021' B Send 5430' Total Drilled Footaoe 19139' Casing Shoe 13114' MD, 3629' ND 8•X' x P3/8" RAM Eeal Boro DWartM ~ IaBDltwOtW feNMOtlWa 9•X• ,1.88 W1M Tubhq / 7• % 83R" MLI%P L6iar HarWR h<kar Sadboro RaeaptxN i.75^ D 'fl' Sand Lateral ax.- 8.8sLInr vMh 8LM cannootlons ~ • • Memory Multi-Finger Caliper Log Results Summary Company: ConocoPhillips Alaska, Inc, WeR: 3K-108 Log Date: December 21, 2008 Field: West Sak Log No.: 7291 State: Afaska Run No.: 1 API No.: 50-029-23395-00 Pipet Desc.: 3.5" 9.3 Ib. L-80 Top Log Intvl: 6,904 Ft. (MD) Pipet Use: Tubing Bot. Log fntvl: 7,274 Ft. (MD) Inspection Type : Collet Orientation Inspection COMMENTS This caliper data is tied into the top of the LEM collet @ 7,268.36' (Driller's Depth). This log was run to assess the orientation of the LEM collet in the "RAM" dual seal bore diverter assembly. The caliper hung-up in the "Ram" dual seal bore diverter assembly from 7,250' to 7,267'. The caliper recordings indicate deposits in the "RAM" dual seal bore diverter assembly that mask the surtace of the LEM collet resulting in the inability to determine the orientation of the collet. A 3-D log plot of the caliper recordings across this interval is inGuded in this report. No significant wall penetrations or areas of cross- sectional wall loss are recorded. The caliper recordings indicate the 3.5" tubing appears to be in good condition with respect to internal corrosive and mechanical damage, with no signilcant wall penetrations, areas of cross-sectional wall loss, or I.D. restrictions recorded. i~ i~ i~ i~ ~i n Field Engineer: Wm. AAcCrossan Analyst: C. Waldrop Witness: M. Thornton ProActive Diagnostic Services, Inc. J P.O. Box 1369, Stafford, TX 77497 Phone: {281) or {888} 565-9085 Fax: (281) 565-1369 E-mail: PDS@memorylog.com Prudhoe Bay Field Office Phone: (907) 659-2307 Fax: {907) 659-2314 X05"-/30 1 ~3 a3 • PDS Multifinger Caliper 3D Log Plot ~_, Company : ConocoPhillips Alaska, Inc. Field : West Sak Well : 3K-108 Date : December 21, 2008 Description : Detail of Caliper Recordings Across "RAM" Dual Seal Bore Diverter Assembly ~r ~ ~ ~ N^r ~ ~ tt^ir ~ 1. r ~ ~ r ~ ~ ~ r ~ Insulated Conductor: 29' 84# K-55x34" 0.312 WT H• 80' 1r•'` ConocoPhillips 2.„r~q~1e 2008 West Sak Dual Injector System 4.e=s•DgNIppM with Leve15 Rotating self signing ~•ultilateral (RAMTM) System GLM, Cameo, H/h• x 1' %gOZJ ,~M,~e,,.X.x,.~.D2., West Sak ,3318" casing shoe 31{-108 3300' MD, 2213' ND Dust Tctring Strings Rohtlonal Alignment Sub 3-'/.• 9.311, L-8g, 4.882• ID, 2.887' Dr8! 2.StY D8 Nipple 9•X' Y 9.5/a• OT Dual Paekr 8•X'Y7•X•x 9•La•DUil9W f Module rr MMNangr / 7` % ad2' RAM Nangr ~guilDment Specifications 7"X9-5/8" RAM Junction t4ilnborc Drip: 3.68' Lateral Drill: i.80' RAM Hanger/Sea1 Borc Diverter OD: 8.375" Overall Lergth of RAM Junction: 38.3 n sail Bore Divedr Rumtirtg Tool: FJD RAM Hanger Running Tool: HRD-E 3-'h" x 1'r4" 9°St8" Dual Seal Module OSM OD: 7.82' Lileril Seil Assembly OD: 3.75° Lileral 1D: 289' Milnbore Seal Stlnger OD: 3.08• Mainborc ID: 289" gailbre Recaptacla a.»• o As Planned Lateral Leneths DSand 8021' B Sand 5430' 7ota1 Drilled Footage 19139' Casing Shoe 13174' MD, 3629 TVD MLNR Productlon Merwr S W AsaartBy •.~s• sw o0 "=s•1D 'B' Sand Lateral 9H' a.911Lb1r vdM fLM cannoetlons &519' Caaing Shoe, 4 . Oq, L-80 BTC 7666' MD, 3533' TVD ~1t Tnn>5 •i i~~ Casing Shoe 1311T MD, 3875 TVD D-Sand Casing Exn 7093' MD, 3459 TVD (BO deg) 9=J • c.9t Llnr vdlh sLM connectlons 4X' x 9•Sle• RAM fpl gore Dlvrtr ~ IsgDl ror Dail gw Medals 4•Y.• 12.B11gTM TubMg / r x esro• MLZxr LMr Hangr Pacbw ~~rii~'11~~61-~ft~ Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth i Prl ,~~ ~ 7 r 1 ~ ,. ,..- ~, NO. 5005 Company: Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Well Job # Log Description Date BL Kuparuk Color CD 12/17/08 2X-10 11978476 PRODUCTION PROFILE / - f 08/17/08 1 1 2V-09 12100460 PRODUCTION PROFILE (p 11/16/08 1 1 1Y-06A 12100461 PRODUCTION PROFILE 11/17/08 1 1 2X-12A 12100464 PRODUCTION PROFILE Gj '~- 11/21/08 1 1 2U-08 12096574 PRODUCTION PROFILE - 11/28/08 1 1 3K-108 12100466 USIT 11/23/08 1 1 3K-30 12097433 LDL - ( 11/28/08 1 1 30-01 12097434 LDL -~ ~- 11/29/08 1 1 1E-04 12097436 LDL 'I' 11/30/08 1 1 3A-04 12097432 INJECTION PROFILE Z - 11/27/08 1 1 iH-16 12096581 PRODUCTION PROFILE ~ - 12/05/08 1 1 3A-06 12114994 BAKER LOWER STRADDLE PACKER 11/26/08 1 1 2U-14 12096578 INJECTION PROFILE C - j 12/02/08 1 1 1G-06 12096580 INJECTION PROFILE 12/04/08 1 1 2V-10 12096582 PRODUCTION PROFILE 12/06/08 1 1 3F-01 12086694 PRODUCTION PROFILE 12/07/08 1 1 2W-14 12086695 INJECTION PROFILE I 12/08/08 1 1 iJ-102 12086701 INJECTION PROFILE - 12/14/08 1 1 i D-07 12114999 USIT _ ~ 12/15/08 1 1 3C-02 12114997 INJECTION PROFILE - ~ 3 12/13/08 1 1 2T-18 12086703 INJECTION PROFILE ~ 12/17/08 1 1 i Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. Notification to resume operati~ 3K-108 ~ Page 1 of 1 Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Monday, November 17, 2008 11:50 AM To: Hartwig, Dennis D Cc: Winfree, Michael Alex (Jr.); Lowry, Scott L; DOA AOGCC Prudhoe Bay Subject: RE: Notification to resume operations 3K-108 Dennis, Thanks for the notification. As usual, be sure the rig contacts the Inspectors regarding the BOP test. Tom Maunder, PE AOGCC From: Hartwig, Dennis D [mailto:Dennis.D.Hartwig@conocophillips.com] Sent: Monday, November 17, 2008 10:46 AM To: Maunder, Thomas E (DOA) Cc: Winfree, Michael Alex (Jr.); Lowry, Scott L Subject: Notification to resume operations 3K-108 Tom, On September 22 (56 days ago), Doyon 15 temporarily released from 3K-108 after setting the 9-5/8" intermediate casing and setting a kill string. While we have had our setbacks on the current 3K-103, it appears that we may finishing on a strong note and releasing off of 3K-103 as early as 11/18/2008. Please accept this Email as notification that CPAI will resume operations on the 3K-108 in 24-48 hours. I may be contacted on my cell phone 907-980-1433 if further questions arise. Regards..Dennis Hartwig CPAI Alaska 2/5/2009 8-Oct-08 AOGCC Attn: Christine Mahnken 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 Re: Distribution of Survey Data for Well 3K-108 Dear Dear Sir/Madam: Enclosed are 2 survey hard copy(s) and a disk with the *.PTT and *.PDF files. Tie-on Survey: Window /Kickoff Survey: Projected Survey: 40.74 ' MD 0.00 ' MD (if applicable) 8020.00 ' M D PLEASE ACKNOWLEDGE RECEIPT BY SENDING AN EMAIL TO Steve.Parkinson@HALLIBURTON.COM OR SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Steve Parkinson 6900 Arctic Blvd. Anchorage, AK 99518 Date ~ 3 ~ ~~~~ Signed T Please call me at 273-3534 if you have any questions or concerns. Regards, Steve Parkinson Survey Manager Attachment(s) ~~$-I~~ • ~ r ~,~ ~;, ~~ a } €I ~°~ a ~ I~x~ ~ ~~ i ~--~ r:-,°~, -:a L 's ~.~ ~..~ ~~ ~ ,~~ 'rte ~-" ~ I ~~ fie; ~,~- +~,~ ALASSA OIL A1~TD GA.S C01~T5ER~A7'IO1~T COl-'II~II5SIOIQ Mike Winfree Drilling Engineer ConocoPhillips Alaska Inc: PO Box 100360 333 W. 7th AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Anchorage, AK 99510 Re: Kuparuk River Field, West Sak Oil Pool, 3K-108 Sundry Number: 308-327 Dear Mr. Winfree: 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 ff 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, G~I~~~`" Cathy P. Foerster Commissioner DATED this ~2 day of September, 2008 SARAH PALIN, GOVERNOR Encl. •ConocoPhillips Alaska, Inc. Post Office Sox 100360 Anchorage, Alaska 99510-0360 Telephone 907-276-1215 September 11, 2008 Alaska Oil and Gas Conservation Commission 333 West 7t" Avenue, Suite 100 Anchorage, Alaska 99501 Re: Sundry Permit: Operational Shutdown 3K-108 Dear Commissioner: ConocoPhillips ConocoPhillips Alaska, Inc. hereby applies for a sundry permit for an operational shutdown on 3K-108. As stated in the 3K-108 Application for a Permit to Drill, ConocoPhillips will temporarily shutdown operations on 3K-108 after cementing the intermediate casing, and move to 3K-103. The estimated date to shutdown operations is September 14th 2008 and the estimated date operations will resume is October 24th, 2008. Drilling the surface and intermediate intervals on 3K-108 provides additional time for long lead completion equipment to be delivered for the 3K-103 completion operations. Please find attached the form 10-403 and plan of operations. If you have any questions or require further information, please contact Mike A. Winfree at 265-6820. Since el Mike A. free Drilling ineer cc: 3K-108 Well File /Sharon Allsup Drake ATO 1530 Chip Alvord ATO 1570 Mike A. Winfree ATO 1452 Dennis Hartwig ATO 1592 Steve McKeever ATO 1550 ~,~ STATE OF ALASKA ALP, OIL AND GAS CONSERVATION COM~O~J ~ ~~,}~ ~"`'' ` APPLICATION FOR SUNDR`f~~~~~/,;A~.S ~~~ 20 AAC 25280 ,~ Pi!'?S, (~;n>h~~~ ~~ ~~ cr- 1. Type of Request: Abandon ^ Suspend ^ Operational shutdown Q Perforate' ' 'r~~~~~ Waiv 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 ^ 208-1300 3. Address: Stratigraphic ^ Service ^ 6. API Number: P.O. Box 100360 Anchorage, AK 99510-0360 50-029233950000 7. If perforating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number: property line where ownership or landownership changes: Spacing Exception Required? Yes ^ No Q 3K-108 9. Property Designation: 10. KB Elevation (ft): 11. Field/Pool(s): ADL 25519 40' AGL 73.8 AM Kuparuk River Field/West Sak Oil Pool 12. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 7,688' 3,540' Casing Length Size MD TVD Burst Collapse Structural Conductor 120 20" 120 120 Surface 3,029 13-3/8" 68 Ib/ft 3,069 2,213 5,020 psi 2,260 psi Intermediate 7,648 9-5/8" 40 Ib/ft 7,688 3,540 5,750 psi 3,090 psi Production Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): Packers and SSSV Type: Packers and SSSV MD (ft): 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 9/14/2008 16. Well Status after proposed work: Commencing Operations: Oil ^ Gas ^ Plugged ^ Abandoned ^ 17. Verbal Approval: Date: WAG ^ GINJ ^ WINJ ^~ WDSPL ^ Commission Representative: 18. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Printed Name A. l~_ Title D~lk.3~•t ~-~,Sr,y~,~ Signature ~ Phon~s-6820 Date 9 ~~ Z~1a COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: ~g' ' O~. Plug Integrity ^ BOP Test ^ Mechanical Integrity Test ^ Location Clearance ^ Other: tL i~U-t` t~p~ l'C`~ CS~"'C `Q h vJ~Cc V~~QE~~~~~®~.~ ~ 5~ ~'i~ ACC r~Sv~~7~`tpt~ ~ "~ ® rc.C`4~~~,leS ~~ S~ ~ t _ ^~ 'r~ot~C~ G~ ~~lS ~ Subsequent Form Required: ~, ~ V ~ (_~ VG~S 1 aO (~0.~~-S ~~~ c! ~ ~~~~. i ~ ~ `~.l APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: / ~ Z - v r -. ^ ~ ~ ~ ~ ~ ~ ~ S ~'~ ~~p ~ Sub D licate Form 10-403 evised 6/2006 ~ 2oQB ~ 7i``~b ~~ ~~ i West Sak: 3K-108 Temporary Shutdown of Drilling Operations -Program outline 1. Run 9-5/8", 40# L80, BTC Mod casing and set in slips. 2. RU Cementers and pump intermediate cementjob displacing with 9.3 ppg brine. 3. Install 9-5/8" packoff and test to 5000 psi. 4. Flush 13-3/8" x 9-5/8" annulus with water, followed by diesel. 5. PU and RIH with kill string. Kill String - 8-1/2" Bit - Bit sub - 2 stds drill collars - 4" XT-39 Drill Pipe - 4" XT-39 X 4-1/2" IBT Crossover - Single Tubing Hanger 6. Land single tubing hanger in mandrel and run in lock down screws. 7. Test hanger seals to 5000 psi. 8. Test casing to 3000 psi for 30 min. 9. Set BPV. 10. ND BOP's. _ 11. NU single tubing bonnet, manual master valve and tree cap. 12. RD and move off 3K-108. 13. Post rig 3K-108, RU hot oil truck to displace to diesel freeze protect. . • Page 1 of 1 Maunder, Thomas E (DOA) From: Winfree, Michael Alex (Jr.) [Michael.A.Winfree@conocophillips.comJ Sent: Tuesday, August 19, 2008 4:21 PM To: Maunder, Thomas E (DOA) Cc: Alvord, Chip; Noel, Brian Subject: RE: 3K-108 (208-130) Tom, I will add the MIT and cement quality log requirement to the permit package. Thank you for accommodating our rig schedule changes with an accelerated permit application review. Mike A. unfree 9C?7.265.6t32~ From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov] Sent: Tuesday, August 19, 2008 2:52 PM To: Winfree, Michael Alex (7r.) Cc: Alvord, Chip; Noel, Brian Subject: 3K-108 (208-130) Michael, Chip and Brian, 1 just noted that 1 did not include the requirement for a MIT and cement quality log on the permit for this well. A IfSIT log is planned in step 26 of the procedure. Please add this message to the permit package. Thanks. Call or message with any questions. Tom Maunder, PE AOGCC ., ~% C~ 9/30/2008 ~- l~J Maunder, Thomas E (DOA) From: Winfree, Michael Alex (Jr.) [Michael.A.Winfree@conocophillips.com] Sent: Friday, August 15, 2008 10:43 AM To: Maunder, Thomas E (DOA) Cc: McKeever, Steve Subject: RE: 3K-108 Permit to Drill Application: Section 13 Revision Page 1 of 3 Tom, The present schedule to spud 3K-108 is now August 25th 2008. Doyon 15 is currently moving from 3C pad and should arrive at 3K pad 8/19/08. Doyon will rig up over 3K-09 for a RWO to be completed 8/24/08. 3K-108 will follow this rig workover with an expected spud date of 8/25/2008. Please let me know if you need additional information regarding the timing of the Doyon 15 rig schedule. Thank you, Mike A. Winfree ~G~7.=~~. i32~ From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov] Sent: Friday, August 15, 2008 7:56 AM To: Winfree, Michael Alex (Jr.) Subject: RE: 3K-108 Permit to Drill Application: Section 13 Revision Michael, When we spoke yesterday, I believe you mentioned that the urgency regarding this permit had subsided. Is that the case? If so, would you please provide a comment regarding the present schedule for spud? I look forward to your reply. Tom Maunder, PE AOGCC From: Winfree, Michael Alex {]r.) [mailto:Michael.A.Winfree@conocophillips.com] Sent: Thursday, August 14, 2008 4:29 PM To: Maunder, Thomas E (DOA) Subject: 3K-108 Permit to Drill Application: Section 13 Revision Mr. Maunder, t3elow is a revision of Section 13 of the Permit to Drill Application for wef13K-108 that includes the kill string operations, ~~ ~ ~~~~ ,~ Please call if you require additional information. Thank You. Mike A. Winfree e ~ ~ s ~ ~/~s 8/15/2008 dom. ~ l4~ ~ ~ ~ ~ ALASSA OIL Al~TD GA.S CO1~T5ERQA~`IO1~T COMZrII55IO1~T Chip Alvord Drilling Team Leader ConocoPhillips Alaska Inc. PO Box 100360 Anchorage AK 99510-0360 SARAH PALIN, GOVERNOR 333 W. 7th AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Re: Kuparuk River Field, West Sak Oil Pool, 3K-108 ConocoPhillips Alaska Inc. Permit No: 208-130 Surface Location: 1473' FSL, 319' FWL, SEC. 35, T13N, R9E, UM Bottomhole Location: 994' FNL, 238' FEL, SEC. 36, T13N, R9E, UM Dear Mr. Alvord: Enclosed is the approved application for permit to drill the above referenced service well. I The permit is approved subject to full compliance with 20 AAC 25.055 and CO 406B. Approval to drill the well to the intended Bottomhole location and produce/inject is contingent upon issuance of a conservation order approving a spacing exception. ConocoPhillips assumes the liability of any protest to the spacing exception that may occur. 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). DATED thisl~ day of August, 'ncerel ~ Daniel T. Seamount, Jr. Chair 2008 /~A STATE OF ALASKA ~ ~ ALASKA OIL AND GAS CONSERVATION COMMISSION - ° ~~ PERMIT TO DRILL 20 AAC 25.005 - 1a. Type of Work: Drill ^/ Re-drill ^ Re-entry ^ 1 b. Current Well Class: Exploratory ^ Development Oil ^ Stratigraphic Test ^ Service ^~ Development Gas ^ Multiple Zone^ Single Zone ^ 1 c. Specify if well is proposed fora Coalbed Methane ^ Gas Hydrates ^ Shale Gas ^ 2. Operator Name: ConocoPhillips Alaska, Inc. 5. Bond: ~ Blanket Single Well Bond No. 59-52-180 11. Well Name and Number: 3K-108 3. Address: P.O. Box 100360 Anchorage, AK 99510-0360 6. Proposed Depth: MD: 13118' TVD: 3675' 12. Field/Pool(s): Kuparuk River Field 4a. Location of Well (Governmental Section): Surface: 1473' FSL, 319' FWL, Sec. 35, T13N, R9E, UM 7. Property Designation: ADL 25519 West Sak Oil Pool Top of Productive Horizon: 307' FNL, 332' FEL, Sec. 35, T13N, R9E, UM 8. Land Use Permit: ALK 2555 13. Approximate Spud Date: 8/18/2008 Total Depth: 994' FNL, 238' FEL, Sec. 36, T13N, R9E, UM 9. Acres in Property: 2560 14. Distance to Nearest Property: 236' 4b. Location of Well (State Base Plane Coordinates): Surface: x- 529306 y- 6008466 Zone- 4 10. KB Elevation (Height above GL): 40' AMSL feet 15. Distance to Nearest Well within Pool: 3K-102L1 , 1179' @ 1393q' 16. Deviated wells: Kickoff depth: 400 ft. Maximum Hole Angle: 90° deg 17. Maximum Anticipated Pressures in psig (see 20 AAC 25.035) Downhole: 1764 psig Surface: 1360 psig 18. Casing Program if ti S Setting Depth Quantity of Cement Size pec ica ons Top Bottom c. f. or sacks Hole Casing Weight Grade Coupling Length MD ND MD ND (including stage data) 40" 20"x34" 94# K-55 Welded 80' 40' 40' 120' 120' 260 cf ArcticCRETE 16" 13.375" 68# L-80 BTC 3500' 40' 40' 3500' 2287' 700 sx AS Lite, 220 sx DeepCRETE 12.25" 9-5/8" 40# L-80 BTCM 7688' 40' 40' 7688' 3533' 590 sx DeepCRETE 6.75" 3.5" 9.3# L-80 SLHT 5924' 7193' 3476' 13117' 3675' screens, no cement 19 PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re-Entry Operations) Total Depth MD (ft): Total Depth ND (ft): Plugs (measured) Effective Depth MD (ft): Effective Depth ND (ft): Junk (measured) Casing Length Size Cement Volume MD ND Conductor/Structural Surface Intermediate Production Liner Perforation Depth MD (ft): Perforation Depth ND (ft): 20. Attachments: Filing Fee ^ BOP Sketch Drilling Program ~ Time v. Depth Plot ^ Shallow Hazard Analysis ~ Property Plat ^ Diverter Sketch ^ Seabed Report ^ Drilling Fluid Program ^/ 20 AAC 25.050 requirements Q 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 unfree @ 265-6820 Printed Name Chip Alvord Title Drilling Team Leader Signature ~ ~~ /~/~~ /' ~ ~ Q ~v ~ ~~ Phone Z G S _ G ~ ~ ~ Date ~~l Z~d~ / l '('~'" ' • f h r 11 D Commission Use Only Permit to Drill NumberaO~~~~ API Number: 50 oa~ 3 ~QDO~ Permit Approval Date: $ • ~ See cover letter for other requirements Conditions of approval : If box is checked, well may not be used to explore for, test, or produce Coalbed me~ane, gas hydrates, or gas contained in shales: Samples req'd: Yes ^ No rLJd Mud log req'd: Yes ^ No Other: \® ~t ~®~ ~ '~~ H2S measures: Yes ^ No ~ Directional svy req'd: Yes ~ No t~EC-"~~LC~~~ ~CSa~`tph ~-~~©V~i ~ , ' C~~c~ C~~~t ~Mi '^~Q(~~'t~l-~t°~ I f .~~ APPROVED`BY THE COMMISSION DATE: ,COMMISSIONER Form 10-401 Revised 12/2005 p; ~ ~ ~ ~ ~ ~ ~ ~ ~ L. Submit in Duplicate Conoco~l hillips ~ Alaska Post Office Box 100360 Anchorage, Alaska 99510-0360 G. Alvord Phone (907) 265-6120 August 11, 2008 Alaska Oil and Gas Conservation Commission 333 West 7t" Avenue Suite 100 Anchorage, Alaska 99501 Re: Applications for Permit to Drill, West Sak Injector, 3K-108, 3K-108 L1 Dear Commissioners: ~, p ~~ ConocoPhillips Alaska, Inc. hereby applies for Permits to Drill for an onshore injector well, a horizontal well in the West Sak "B"and "D" sands. The main bore of the well will be designated 3K-108, and the lateral bore of the well will be designated 3K-108L1. 3K-108 and 3K-108L1 will require a spacing exception as the toe of each lateral is planned to be 238' from the Milne Point lease line. A formal request for this spacing exception has been submitted separately from this drilling permit application. If ConocoPhillips is unable to obtain the spacing exception, we are prepared to shorten the laterals, presented in this application, to conform to the 500' spacing described in 20 AAC 25.055. The expected spud date for 3K-108 is next Monday, August 18th. Originally this well was scheduled for mid-October, after a well on 3H pad in Kuparuk. But wet, soft roads will make the move to and from 3H pad difficult and time consuming. ConocoPhillips hopes to move instead to 3K-108, allowing the rig to stay on 3K pad until after hard freeze up. To ensure there are no long lead delivery issues for the completion equipment due to this accelerated schedule, the plan is to drill, case, and cement only the surface and intermediate holes on 3K-108, then move to 3K-103 and drill and complete the well as planned. After 3K-103 is completed, the rig will move back over 3K-108 to drill and complete both laterals. "Batch" drilling the surface and intermediate hole sections on 3K-108 will allow time for delivery of the long lead completion equipment for both the 3K-108 and 3K-103 wells. Please find attached for the review of the Commission, forms 10-401 and the information required by 20 ACC 25.005 for each of these well bores. ConocoPhillips Alaska, Inc. would also like to request an accelerated review of this permit application due the change in spud date. If you have any questions or require any further information, please contact Mike A. Winfree at 265-6820. Sincerely, ~---=~1 ~l~-C G. Alvord Greater Kuparuk Area Drilling Team Leader A~tion for Permit to Drill, Well 3K-108 Revision No.0 Saved: 12-Aug-08 Permit It -West Sak Well #3K-108 Application for Permit to Drill Document Table of Contents 1. Well Name ................................................................................................................. 2 Requirements of 20 AAC 25.005 (t) ....................................................................................................... 2 2. Location Summary ................................................................................................... 2 Requirements of 20 AAC 25.005(c)(2) ................................................................................................... 2 Requirements of 20 AAC 25.050(b) ....................................................................................................... 3 3. Blowout Prevention Equipment Information ......................................................... 3 Requirements of 20 AAC 25.005(c)(3) ................................................................................................... 3 4. Drilling Hazards Information ................................................................................... 3 Requirements of 20 AAC 25.005 (c)(4) .................................................................................................. 3 5. Procedure for Conducting Formation Integrity Tests ........................................... 4 Requirements of 20 AAC 25.005 (c)(5) .................................................................................................. 4 6. Casing and Cementing Program ............................................................................ 4 Requirements of 20 AAC 25.005(c)(6) ................................................................................................... 4 7. Diverter System Information ................................................................................... 5 Requirements of 20 AAC 25.005(c)(7) ................................................................................................... 5 8. Drilling Fluid Program ............................................................................................. 5 Requirements of 20 AAC 25.005(c)(8) ................................................................................................... 5 Surface Hole Mud Program (extended bentonite) .................................................................................. 5 Intermediate Hole Mud Program (LSND) ............................................................................................... 5 Lateral Mud Program (MI VersaPro Mineral Oil Base) ........................................................................... 5 9. Abnormally Pressured Formation Information ..................................................... 6 Requirements of 20 AAC 25.005 (c)(9) .................................................................................................. 6 10. Seismic Analysis ..................................................................................................... 6 Requirements of 20 AAC 25.005 (c)(10) ................................................................................................ 6 11.Seabed Condition Analysis .....................................................................................6 Requirements of 20 AAC 25.005 (c)(11) ................................................................................................ 6 3K-108 PERMIT /T.doc Page 1 of 8 r ~ ~ ~ Printed: 12-Aug-08 ~ation for Permit to Drill, Well 3K-108 Revision No.O Saved: 12-Aug-08 12. Evidence of Bonding ............................................................................................... 6 Requirements of 20 AAC 25.005 (c)(12) ................................................................................................ 6 13. Proposed Drilling Program ..................................................................................... 6 Requirements of 20 AAC 25.005 (c)(13) ................................................................................................ 6 14. Discussion of Mud and Cuttings Disposal and Annular Disposal ....................... 8 Requirements of 20 AAC 25.005 (c)(14) ................................................................................................ 8 15. Attachments ............................................................................................................. 8 Attachment 1 Directional Plan .................................................................................................................. Attachment 2 Drilling Hazards Summary ................................................................................................. Attachment 3 Doyon 15 West Sak 3ksi BOP Configuration ........................................................ Attachment 4 Cement Loads and CemCADE Summary ......................................................................... Attachment 5 Well Schematic ................................................................................................................. Attachment 6 Quarter mile radius Injector effects ..................................................................... 1. Well Name Requirements of 20 AAC 25.005 (1) Each well must be identified by a unique name designated by the operator and a unique API number assigned by the commission under 20 AAC 25.040(b). For a well with multiple well branches, each branch must similarly be identified by a unique name and API number by adding a suffix to the name designated for the well by the operator and to the number assigned to the well by the commission. The well for which this Application is submitted will be designated as 3K-108. 2. Location Summary Requirements of 20 AAC 25.005(c)(2) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (2) a plat identifying the property and the property's owners and showing (A)the coordinates of the proposed location of the well at the surface, at the top of each objective formation, and at total depth, referenced to governmental section lines. (8) the coordinates of the proposed location of the well at the surface, referenced to the state plane coordinate system for this state as maintained by the National Geodetic Survey in the National Oceanic and Atmospheric Administration; (C) the proposed depth of the well at the top of each objective formation and at total depth; Location at Surface 1473' FSL 319' FWL Section 35 T13N R09E ASP Zone 4 NAD 27 Coordinates RKB Elevation 74.3' AMSL Northings 6,008,466' Eastings: 529,306' Pad Elevation 34.3' AMSL Location at Top of Productive Interval 307' FNL, 332' FEL, Section 35, T13N, R09E West Sak "B" Sand ASP Zone 4 NAD 27 Coordinates Measured De th RKB: 7 676' Northings: 6,011,986' Eastings: 533,917' Total Vertical De th RKB: 3,533' Total Vertical De th, SS: 3,459' Location at Total De th 994' FNL 238' FEL Section 36 T13N R09E ASP Zone 4 NAD 27 Coordinates Measured De th, RKB: 13,118' Northings: 6,011,326' Eastings: 539,294' Total Vertical De th, RKB: 3 675' Total Vertical De th SS: 3,601' OR161NAL 3K-108 PERMIT IT.doc Page 2 of 8 Printed: 12-Aug-08 and (D) other information required by 20 AAC 25.050(b); ~ation for Permit to Drill, Well 3K-108 Revision No.O Saved: 12-Aug-08 3K-108 will require a spacing exception as the toe of the lateral is planned 238' from the Milne Point lease line. A formal request for this spacing exception has been subimtted separately from this drilling permit application. Requirements of 20 AAC 25.050(b) If a well is to be intentionally deviated, the application for a Permit to Drill (Form 10-401) must (i) include a plat, drawn to a suitable scale, showing the path of the proposed wellbore, including all adjacent wellbores within 200 feet of any portion of the proposed well; Please see Attachment 1: Directional Plan 3K-108 and (2) for all wells within 200 feet of the proposed wellbore (A) list the names of the operators of those wells, to the extent that those names are known or discoverable in public records, and show that each named operator has been furnished a copy of the application by certified mail; or (8) state that the applicant is the only affected owner. The Applicant is the only affected owner. 3. Blowout Prevention Equipment Information Requirements of 20 AAC 25.005(c)(3) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (3) a diagram and description of the blowout prevention equipment (BOPS) as required by 20 AAC 25.035, 20 AAC 25.036, or 20 AAC 25.037, as applicable; An API 13-5/8" x 5,000 psi BOP stack (RSRRA) will be utilized to drill and complete well 3K-108. For all drilling, casing and liner operations the stack will be equipped with 3-1/2" to 6" variable bore rams in the uppermost ram cavity, blind rams in the middle cavity, and 9-5/8" rams in the lowermost cavity. For the dual 3-1/2" completion operations the stack will be equipped with dual 3-1/2" rams in the uppermost ram cavity, blind rams in the middle cavity, and dual 3-1/2" rams in the lowermost cavity. The additional set of dual 3-1/2" rams is required since the Annular preventer will be ineffective while running dual 3-1/2" strings simultaneously. See attached diagram entitled "Doyon 15 West Sak 3ksi BOP Configuration" Upon initial nipple up and at intervals of no more than 14 days thereafter, a test plug will be set below the lowermost rams, the annular preventer will be tested to 1,500 psi and the blind rams and upper rams will be tested to 3,000 psi. (This test will test the shell and end connections of the lowermost ram). The lowermost rams will be closed and tested to 3,000 psi on a 9-5/8" OD. Prior to running the dual 3-1/2" completion, a test plug will be installed below the lower most rams, the upper and lower ram cavities will be equipped with dual 3-1/2" rams and tested to 3,000 psi. Please see information on the Doyon Rig 15 blowout prevention equipment placed on file with the Commission. 4. Drilling Hazards Information Requirements of 20 AAC 25.005 (c)(4) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (4) information on drilling hazards, including (A) the maximum downhole pressure that maybe encountered, criteria used to determine it, and maximum potential surface pressure based on a methane gradient; The expected reservoir pressures in the West Sak sands in the 3K area are 0.48 psi/ft, or 9.0 ppg EMW (equivalent mud weight). 3K-108 PERMIT IT.doc Page 3 of 8 ~' ~ ~ ~ Printed: 12-Aug-OS ~L ~ation for Permit to Drill, Well 3K-108 Revision No.O Saved: 12-Aug-08 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 "B" sand formation is 1,360 psi: MPSP = (3,675 ft TVD)(0.48 - 0.11 psi/ft) = 1,360 psi (8) data on potential gas zones; The well bore is not expected to penetrate any gas zones. and (C) data concerning potential causes of hole problems such as abnormally geo-pressured strata, lost circulation zones, and zones that have a propensity for differential sticking; Please see Attachment 2: 3K-108 Drilling Hazards Summary. 5. Procedure for Conducting Formation Integrity Tests Requirements of 20 AAC 25.005 (c)(5) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the applicatioh: (5) a description of the procedure for conducting formation integrity tests, as required under 20 AAC 25.0300; 3K-108 will be completed with a 9-5/8" intermediate casing landed in the West Sak B 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. 6. Casing and Cementing Program Requirements of 20 AAC 25.005(c)(6) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (6) a complete proposed casing and cementing program as required by 20 AAC 25.030, and a description of any slotted liner, pre- perforated liner, or screen to be installed; Casing and Cementing Program See also Attachment 3: Cement Summary Hole Top Btm Csg/Tbg Size Weight Length MD/TVD MD/TVD OD in) in Ib/ft Grade Connection ft ft ft Cement Pro ram 20 x 34 40 94 K55 Welded 80 40 / 40 120'/ 120' Cemented to surface with 260 cf ArcticCRETE Cemented to Surface with 13-3/8 16 68 L-80 BTC 3,500' 0/0 3,500'/2,287' 700 sx ASLite Lead, 220 sx DeepCRETE Tail Cement Top planned @ 4,418'MD / 2,626TVD 9-5/8 12-1/4 40 L-80 BTCM 7,688' 0 / 0 7,688'/ 3,533' CementeDeepCRETE.12.5 ppg 3-1/2 blank Wlth 6-3/4" B Sand Lateral 9.3 L-80 SLHT 5,924' 7,193 / 3,476 13,117'/ 3,675' Screens - no cement ResInject (3K-108) screens 3-1/2 blank with 6-3/4" D Sand Lateral 9.3 L-80 SLHT 6,021' 7,093/ 3,459 13,114'/ 3,629' Screens - no cement ResInject (3K-108 Li) screens 3K-108 PERMIT IT.doc Page 4 of 8 Printed: 12-Aug-08 ORIGINAL ~ation for Permit to Drill, Well 3K-108 Revision No.0 Saved: 12-Aug-08 7. Diverter System Information Requirements of 20 AAC 25.005(c)(7) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on frle 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); A 21-1/4", 2000 psi annular with a 16"diameter diverter line will be the diverter system used in the drilling of 3K-108. Please see diagrams of the Doyon 15 diverter system on file with the Commission. 8. Drilling Fluid Program Requirements of 20 AAC 25.005(c)(8) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (8) a drilling fluid program, including a diagram and description of the drilling fluid system, as required by 20 AAC 25.033; Drilling will be done with muds having the following properties over the listed intervals: Surface Hole Mud Program (extended bentonite) S ud to Base of Permafrost Base of Permafrost to 13-3/8" Casin Point Initial Value Final Value Initial Value Final Value Density (ppg) 8.8 9.2 9.2 9.5 Funnel Viscosity 150 250 200 300 (seconds) Yield Point 50 70 30 50 (cP) Plastic Viscostiy 30 55 15 20 (Ib/100 st) pH 9.0 9.5 9.0 9.5 AP- Filtrate NC 8.0 8.0 8.0 cc / 30 min)) Intermediate Hole Mud Program (LSND) 13-3/8" Cs Shoe to 9-5/8" Cs Point Value Density (ppg) 8.8 - 9.2 Funnel Viscosity 45 - 60 seconds) Plastic Viscostiy 12 - 18 (!b/100 sf) Yield Point 18-24 (cP) API Filtrate 4 - 6 cc / 30 min)) Chlorides (mg/I) <500 pH 9.0 - 10.0 MBT <18.0 Lateral Mud Program (MI VersaPro Mineral Oil Base) B 8~ D sand laterals Value Densit ( 9.0 - 9.3 Plastic Viscostiy 15 - 25 (lb/100 sfJ Yield Point 15 - 20 (cP) HTHP Fluid loss (ml/30 min @ <4.0 200 si & 150° Oil /Water Ratio 70 / 20 Electrical 650 - 900 Stabilit 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 15. ORIGINAL 3K-108 PERMIT IT.doc Page 5 of 8 Printed: 12-Aug-08 ~J ~tion for Permit to Drill, Well 3K-108 Revision No.O Saved: 12-Aug-08 9. Abnormally Pressured Formation Information Requirements of 20 AAC 25.005 (c)(9) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (9) for an exploratory or stratigraphic test well, a tabulation setting out the depths of predicted abnormally geo-pressured strata as required by 20 AAC 25.033(f); Not applicable: Application is not for an exploratory or stratigraphic test well. 10. Seismic Analysis Requirements of 20 AAC 25.005 (c)(10) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (10) for an exploratory or stratigraphic test well, a seismic refraction or reflection analysis as required by 20 AAC 25.061 (a); Not applicable: Application is not for an exploratory or stratigraphic test well. 11.Seabed Condition Analysis Requirements of 20 AAC 25.005 (c)(11) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (li) for a well drilled from an offshore platform, mobile bottom-founded structure, jack-up rig, or floating drilling vessel, an analysis of seabed conditions as required by 20 AAC 25.061(b); Not applicable: Application is not for an offshore well. 12. Evidence of Bonding Requirements of 20 AAC 25.005 (c)(12) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (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 application for a Permit to Dril! must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: The osed drilling program is listed below. Please refer also to Attachment 4, Well Schematic. 1. Excavate ce 'nstall cellar box, set and cement 20" x 34" insulated conductor to +/- 120' RKB. Install landing ring on c ctor. 2. Move in /rig up Doyon 5. Install 21-1/4"Annular with 16"diverter line and function test. 3. Spud and directionally drill 16" o casing point at +/- 3,300 MD / 2,213' TVD as per directional plan. Run Gyro and MWD tools as require directional monitoring. 4. Run and cement 13-3/8", 68#, L80, BTC cas o surface. Displace cement with mud and, pressure test casing to 2500 psi for 30 minutes and record res Perform top job if required. 5. Remove diverter system, install and test 13-5/8" x 5,000 OP's as described above in Section 3 above and test to 3,000 psi (annular preventer to 1500 psi). Notify C 24 hrs before test. 6. PU 12-1/4" bit and 8"drilling assembly, with MWD, LWD, PWD and otor. RIH, clean out cement to top of float equipment. Re-test casing if cement is tagged more than 1 et above the float collar. 7. Drill out cement and between 20' and 50' of new hole. Perform formation integrl t to leak off, recording results. 8. Directionally drill to 9-5/8" casing point at 7,688' MD / 3,534' TVD, the prognosis top of the B .Pull out of hole backreaming to the surface casing shoe. SUPERSEDED ~~'~°~~~----~0 R I G I NA L 3K-108 PERMIT IT.doc Page 6 of 8 Printed: 12-Aug-OS 9. Rt.31~9• Corr a 10. Install ~ation for Permit to Drill, Well 3K-108 Revision No.0 Saved: 12-Aug-08 5/8", 40# L80, BTC Mod casing to surface. (top of cement to be 4,418 MD / 2,627' TVD which ponds to 500' above the Ugnu C formation.) x 9-5/8" packoff and test to 5000 psi. 11. Flush 13- 12. PU 8-1/2" Rc test casing if x 9-5/8"annulus with water, followed by diesel. 13. Drill out cement al Perform formation and 6-3/4" cleanout assembly. RIH, clean out cement to top of float equipment. Re- fit is tagged more than 100 feet above the float collar. etween 20' and 50' of new hole. Displace hole to lateral drilling OBM mud. int rity test to leak off, recording results. 14. POOH with 8-1/2" clea 15. Run USIT log to evaluate assembly. bond on intermediate casing. 16. PU 6-3/4" Rock Bit and 4-3/4" 'lling assembly including MWD, LWD, PWD and rotary steerable tool. RIH and directionally drill 6-3/4" hole TD at +/- 13,117' MD / 3,675' TVD as per directional plan. 17. At TD Circulate 4 bottoms up with r 'rotation and rotation. Open up PBL circulation sub and circulate 9-5/8" casing clean at increased flow es for 4 bottoms. Close circ sub & displace to clear weighted brine. Pump out of Hole if necessary. 18. PU and run 3-1/2" blank liner, ResInject sc ns and TAM swell packers. 19. Land liner, set liner hanger at 7,193'/ 3,476' POOH. Note: Remaining operations are covered under the 3 08L1 Application for Permit to Drill, and are provided here for information only. 20. Run and set Baker Gent WindowMaster whipstock TVD, the top of the D sand. 21. Mill 8-1/2" window. POOH. 22. Pick up 6-3/4"drilling assembly with LWD, MWD, PWD and at window point of +/- 7,094' MD / 3,459' SUP~~~~~ED rn~~ cl-ccrnhl.+.~=-L.._ nrL.. _- _--- 23. Drill to TD of D sand lateral at +/- 13,114 MD / 3,629' TVD, as per sectional plan. 24. Circ'Glate 4 bottoms up with reciprocation and rotation. Open up PBL ulation sub and circulate 9-5/8" casing clean at increased flowrates for 4 bottoms. Close circ sub & displ to clear weighted brine. Pump out of Hole if necessary. 25. RIH with whipstock retrieval tool. Retrieve whipstock and POOH. 26. RIH and set Baker Seal Bore diverter 27. PU and run 3-1/2" blank liner, ResInject screens and TAM .swell packers with Baker 'Tools RAM Hangar system. 28. Land Baker RAM hanger in Baker seal bore diverter. Release hanger running tool. POOH ing down drill pipe as required. 29. PU 3-1/2" Baker dual seal module, dual GT packer and dual 3-1/2" injection completion and- to depth. Land tubing. Set BPV 30. Nipple down BOPE, nipple up tree and test. Pull BPV. 31. Freeze protect well with diesel by pumping into 3-1/2" x 9-5/8"annulus, taking returns from tubing an allowing to equalize. (If the schedule and equipment availability allows, the Wells Group will freeze protect the well post rig). 32. Set BPV and move rig off. 3K-108 PERMIT IT.doc Page 7 of 8 Printed: 12-Aug-08 oRiciNa~ 907.265.8820 t~irecf 907242.026 Ceti ru.gc~.vi~ 13. Proposed Drilling Program Requirements of 20 AAC 25 005 (c)(13) . 'If- ~^ L~lr. ...f ~S" ~?E,~Cc't?!'?~8,~71~-'u ??4~C'c3~;, Jr <','!' r'`?iJ~:i ii7.f~'I~1 ; °',ht,e., %?tc.?: ;.z°?;?7 3, ~:~t?,6 .;,? t1~ Yi?~:~3 !'ft~ !`.{.3,) z'1 (:iy:'}? Ul ~l7u tI L ~';'C'[~ Ct1%~lil~[? (7'?~}'Ic7111F The proposed drilling program is listed below. Please refer also to Attachment 4, Well Schematic. 1. Excavate cellar, install cellar box, set and cement 20"x34" insulated conductor to +J- 120' RKB. Install landing ring on conductor. 2. Move in /rig up Doyon Rig 15. Install 21-1/4" Annular with 16" diverter line and function test. 3. Spud and directionally drill 16" hole to casing point at +/- 3,300 MD / 2,213` TVD as ~r direcdonal plan. Run Gyro and MWD tools as required for directional monitoring. 4. Run and cement 13-3/8", 68#, L80, BTC casing to surface. Displace cement with mud and, pressure test casing to 2500 psi for 30 minutes and record results. Perform top job if required. 5. Remove diverter system, install and test 13-5/8° x 5,000 psi BOP's as described above in Section 3 above and test to 3,000 psi (annular preventer to 1500 psi). Notify AOGCC 24 hrs before test. 6. PU 12-1/4" bit and 8"drilling assembly, with MWD, LWD, PWD and mud motor. RIH, clean out cement to top of float equipment. Re-test casing if cement is tagged more than 100 feet above the float collar. 7. Grill out cement and between 20' and 50' of new hole. Pertorm formation integrity test to teak off, recording results. 8. Directionalty drill to 9-5/8" casing point at 7,688' MD / 3,534' TVD, the prognosis top of the B sand. Pull out of hole backreaming to the surface casing shoe. 9. Run 9-5J8", 40# t_80, BTC Mod casing to surface. (top of cement to be 4,418 MD / 2,627' TVD which corresponds to 500' above the Ugnu C formataon.) 10. Install 9-5/8" packoff and test to 5000 psi. 11. Flush 13-3/8" x 9-5/8" annulus with water, followed by diesel. ~.~. ~v ~ia~ a~i~ i%vliss e~h. S~s43~y. 13. i_t:isii Siiyie ie.i~J"ii3CJ' it~3r'+r~r in ^landrei and i"i.ln ill It1C~< ~~,Q.'`J~; SCracytrS. ~.f'r. ~ ~$~ p~%aC-v~( tv 3vt~v~rSi. r5. itiv ~~~'S. it;. sev ~i'sly.r. txiuEily iJvn~Lt, TaSi~G~ r~i T?~St v~I :r^ c~~T t c Ca~~'.~~~..~, C g`\ ^.Y.,. .L I. {ii~.1 anc; Iiit~~l~ v1~7 .J\-i4l~ LU 3i\-.I.UJ. \ j~,~L\ V``'~''~0~~ :./ u. ~ii ~€@ cants Cu^a"'iipieee .:i. _v.x, E. i''sv. ~~J". 1'1IKi3 3i~`3.Ub. '>s~ r:, 1. ~ n a i ~ t t~ a t:.:. +..ssec:ati rue prG~S~liit:, a.+iii'~, n~pp ~. cv.n 'e 21. Install anti test 13-5/8" x 5,000 psi BOP's as described above in Section 3 above and test to 3,000 psi s caniai,i c:r pr ~^}~~ 3.'-00 psi}. P~ctify ,e~?GCC 2? ilrs hefo-e test. i ~ s`.,a a ~c, to :~ Z~. a ust t~SsE j~s is sij ~i,it vi E Evan, 23. PU 8-1/2" Rock Bit and 6-3/4" cleanout assembly. RiH, clean out cement to top of float equipment, Re-test casing if cement is tagged more than i00 feet above the float collar. 24. Drill out cement and between 20' and 50' of new hole. Displace hole to lateral drilling OBM mud. Perform formation integrity test to leak off, recording results. 25. POOH with 8-1i2" cleanout assembly. 8/15/2008 r arc ~ ut ~ • 26. Run USIT b9 to evaluate cement bond on intermediate casing. 27. PU 6-3/4" Rock Bit and 4-3/4" drilling assembly including MWD, LWD, PWD and rotary steerable tool RIH and directionally drill 6-3/4" hose to TD at +/- 13,117 MD / 3,675' TVD as per directional plan. 28, At TD Circulate 4 bottoms up with reciprocation and rotation. Open up PBL circulation sub and circulate 9- 5/8" casing clean at increased flow rates for 4 bottoms. Close circ sub & displace to clear weighted brine. Pump out of Hole if necessary. 29. PU and run 3-1/2" blank liner, ResInject screens and TAM swell packers. 30. Land liner, set liner hanger at 7,193'/ 3,476'TVD. POOH. Note: Remaining operations are covered under the 3K-108L1 Application for Permit to Drill, and are provided here for information only. 31. Run and set Baker Gent WindowMaster whipstock system, at window point of +/- 7,094' MD / 3,459' TVD, the top of the D sand. 32. Mill 8-1/2" window, POOH. 33. P'rck up 6-3/4"drilling assembly with LWD, MWD, PWD and rotary steerable tool. RIH. 34. Drill to TD of D sand lateral at +/- 13,114 MD (3,629' Ti/D, as per directional plan. 35. Circulate 4 bottoms up with reciprocation and rotation. Open up PBL circulation sub and circulate 9-5/8" casing clean at increased flowrates for 4 bottoms. Close circ sub & displace to clear weighted brine. Pump out of Hole if necessary. 36. RIH with whipstock retrieval tool. Retrieve whipstock and POOH. 37. RIH and set Baker Seal Bore diverter 38. PU and run 3-1/2" blank liner, ResInject screens and TAM swell packers with Baker Oil Tools RAM Hangar system. 39. Land Baker RAM hanger in Baker seal bore diverter. Release hanger running tool. POOH laying down drill pipe as required. 40. PU 3-1/2" Baker dual seal module, dual GT packer and dua13-1/2" injection completion and RIH to depth. Land tubing. Set BPV 41. Nipple down BOPS, nipple up tree and test. Pui1 BPV. 42. Freeze protect well with diesel by pumping into 3-1/2" x 9-5/8" annulus, taking returns from tubing and allowing to equalize. (If the schedule and equipment availability allows, the Wel{s Group wits freeze protect the well post rFg). 43. Set BPV and move rig off. 8/15/2008 • ~ation for Permit to Drill, Well 3K-108 Revision No.0 Saved: 12-Aug-08 14. Discussion of Mud and Cuttings Disposal and Annular Disposal Requirements of 20 AAC 25.005 (c)(14) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (i4) a general description of how the operator plans to dispose of drilling mud and cuttings and a statement of whether the operator intends to request authorization under 20 AAC 25.080 for an annular disposal operation in the well.; Waste fluids generated during the drilling process will be disposed of either by pumping authorized fluids into a permitted annulus on 3K 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 3K Pad, hauled to the Prudhoe Bay Grind and Inject Facility for temporary storage and eventual processing for injection down an approved disposal well, or stored, tested for hazardous substances, and (if free of hazardous substances) used on pads and roads in the Kuparuk area in accordance with a permit from the State of Alaska. ConocoPhillips Alaska may in the future request authorization for the use of this well for annular disposal operations. 15. Attachments Attachment 1 Directional Plan Attachment 2 Drilling Hazards Summary Attachment 3 Doyon 15 West Sak 3ksi BOP Configuration Attachment 4 Cement Loads and CemCADE Summary Attachment 5 Well Schematic Attachment 6 Quarter mile radius Injector effects 3K-108 PERMIT IT.doc n ~ ~ ~ ~ ~ ~ Page 8 of 8 {K` Printed: 12-Aug-08 ConocoPhillips (Alaska) Inc. -Kup2 Kuparuk River Unit Kuparuk 3K Pad Plan 3K-108 (E12) -Slot 3K-108* Staked 3K-108 Plan: 3K-108 (wp09) Standard Proposal Report 05 August, 2008 c:;, Sperry Drilling Services ORIGINAL ' -( ~y Project: Kuparuk River Unit WELL DETAILS: Plan3K-108(EI2) NAD1927(NADCONCONUS) Alaska Zone 04 ~„`ALL~ ~(JA ~ ~ Site: Kuparuk 3K Pad Ground Level: 34.30 Sperry Gr illing 8®rviaes Well: Plan 3K-108 (E12) +N/-S +F1-W Northing Eashng Latittude Longitude Slot -2500 Wellbore: 3K-108 0.00 0.00 6008466.45 529306.39 70° 26' 3.151 N 149° 45' 39.919 W 3K-108* Staked Design: 3K-108 (wp09) FORMATION TOP DETAILS TVDPath TVDssPath MDPath Formation -2000 1586.01 1511.71 1773.90 3 1655.15 1580.85 1892.83 PFrost 1804.20 1729.90 2195.13 K15 2414.21 2339.91 3843.36 T3+800 -1500 2811.41 2737.11 4917.81 Ugnu C 3061.64 2987.34 5594.71 Ugnu B 3213.79 3139.49 6031.79 Ugnu A 3323.89 3249.59 6409.51 N -1000 3458.99 3384.69 7091.87 WSak D 3498.69 3424.39 7324.31 WSak C 3532.89 3458.59 7676.54 WSak B -500 SHL: 1473' FSL, 319' FWL -Sec35-T13N-R09E 0 CASING DETAILS ' TVD TVDSS MD Size Nazne 2213.34 2139.04 3300.00 13-3/8 13 3/8" O 500 500 ' ' 3459.31 3385.01 7093.71 9-5/8 9 5/8" TOW 38 9-5/8 9 5/8" 63 7688 93 3459 3533 Surtace Csg @ 33 FWL -Sec35-T13N-R09E FNL, 1643 2213' TVD: 2338 00' MD . . . " ~ , 3675.30 3601.00 13117.62 3-I/2 31/2 1000 X000 0 ~~l T3 1~p0 / T13N-R09E 35 0' FEL S ' ' ' " J s 1500 o PF t o ec - - TVD: 303 FNL, 91 MD, 3459 TOW 7094 9 5/8 @ ~~ a _ , ros _ _~o 0 p 0 -K15---- --rLO 00 0 ~ ' ' ' ~ 2000 `5 0 ~ TVD: 30T FN r Int. Casing @ 7688' MD, 3534 FEL -Sec35-T13N-R09E L, 320 ~ r 00 0 ' 0 ' 238' FEL - Sec36-T13N-ROf 994' FNL 3675' TVD ' MD , 0 ; , , : BHL @ 13118 , po r ~ o , I > 00 -r3+aoo------------ -- ' yo ~ I ~ 25 , b 0o I ~ ~ Ugnu C 13 3/8" 00 0 ° ~ --UgnuB-------------- - - 0 0 I ~ ~n . ,' ° I 3000 _ _ _ _, Ugnu A _ _ _ _ _ _ _ _ _ _ _ _ o o _ _ _ _ _ _ _ <0 0 0' 0 0 0 0 \I G - - - - - - - - - - - - - - - - - - p - - - - - - - - - - ~ - - - ~ - - - ~ - - - - _ - -Q - _ -6 _ _ -p - - -~ - - ~- - ' ~ - . 'O- - . ~- - _ ~- - (J' W - - - - - - _ - - - - _ - ---N---------------- a --------- --- -rc ,rn m rn rn ' s ° ----------- -------------- -- - ----- --- _ _ -~ __ ------------- --~ -----=-------r-- -- - - ------=T°------ ---- -- 3500 -~= -~WSakD__________ _____________~ _ -- ~p ) 3K-108 L1 w09 `` `` WSak C o 9 5/8" TOW I ' o ' ' I I I ~~ 3K-108 (wp09) I I I 9 5/8" ~ I I 4000 WSak B I I ~ I I I i i 13 1/2" I I I I 3K-108 Dlop (02/04/08) , 3K-E12 CP2 (9/11/07) I i 3K-E12 CP4 (9/11/07) II 4500 3K-E12 CP1 (9/11/07) 3K-E12 CP3 (9/11/07) 3K-108 Toe 6000 tlliii Ills sill ~~~ ~~ ~~ ~~ -500 0 500 1000 1500 2000 2500 3000 3500 4000 4500 5000 5500 6000 6500 7000 7500 8000 8500 9000 9500 10000 10500 11000 11500 Vertical Section at 90.00° (1250 ft/in) `'f ConocoPhillips ~A~.{~f~~~T~~ B~a~r•ry Orillioq Il~rwlao 6500 6000 4500 4000 Surface Csg L 33~ G 3000 0 u1 N 2500 t .C C 0 2000 t ~ 1500 -1000 -1500 0 SI{L: 1473' FSL, 319' FWL- Sec35=C13N-R09E Project: Kuparuk River Unit WELL DETAILS: Plan 3K-108 (E12) NAD 1927 (NADCON CONUS) Alaska Zone 04 Site: Kuparuk 3K Pad Well: Plan 3K-108 (E12) Ground Level: 34.30 Wellbore: 3K-108 +N/-S +E/-W Northing Fasting Latittude Longitude Slot • ° ' ' Staked 39.919 W 3K-108 3.151 N 149 45 0.00 0.00 6008466.45 529306.39 70° 2G Plan: 3K-108 (wp09) REFERENCE INFORMATION Co-ordinate (N/E) Reference: Well Plan 3K-108 (E12) -Slot 3K-108' Staked, True North Vertical (TVD) Reference: 74.3' (34.3'+q0) @ 74.30f1 Measured Depth Reference: 74.3' (34.3'+40) @ 74.30ft Calculation Melhod: Minimum Curvature CASING DETAILS TVD TVDSS MD Size Name 2213.34 2139.04 3300.00 13-3/8 l3 3/8" 3459.31 3385.01 7093.71 9-5/8 9 5/8" TOW 3533.93 3459.63 7688.38 9-5/8 9 5/8" 3675.30 3601.00 13117.62 3-12 31/2" Int. Casing @ 7688' MD, 3534' TVD: 30T FNL, 320' FEL- Sec35-TI3N-R09E i i i BHL rr 13118' MD, 3675' TVD: 994' FNL, ?38' FEL - Sec3G-TI3N-R09E 0 3 3 I/2" T M Azimuths to True North Magnetic North: 17.98° Magnetic Field Strength:57263.7snT Dip Angle: 79.80° Date: 10/12/2007 Model: BGGM2007 ~i III i i i -ID00 -500 0 500 1000 1500 2000 2500 3000 3500 4000 4500 5000 5500 6000 6500 7000 7500 8000 8500 9000 9500 10000 10500 I100n West(-)/East + 1250 lt/in) ~' (> ~ ConocoPhiilips aasK~ • Halliburton -Sperry ~~~~' Standard Proposal Report Database: EDM 2003.16 Single User Db Company: ConocoPhillips (Alaska) Inc. -Kup2 Project: Kuparuk River Unit Site: Kuparuk 3K Pad Well: Plan 3K-108 (E12) Wellbore: 3K-108 Design: 3K-108 (wp09) 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 Local Co-ordinate Reference: Well Plan 3K-108 (E12) -Slot 3K-108" Staked TVD Reference: 74.3' (34.3'+40) @ 74.30ft MD Rcfcrencc: 74.3' (34.3'+40) @ 74.30ft North Reference: True Survey Calculation Method: Minimum Curvature - j Site Kuparuk 3K Pad -- Site Position: Northing: 6,008,428.74ft Latitude: 70° 26' 2.780 N From: Map Easting: 529,306.18ft Longitude: 149° 45' 39.930 W Position Uncertainty: 0.00 ft Slot Radius: 0" Grid Convergence: 0.23 ° Well __ Plan 3K-108 ~E12) -Slot 3K-108` Staked Well Position +N/-S 0.00 ft Northing: 6,008,466.45 ft Latitude: 70° 26' 3.151 N +E/-W 0.00 ft Easting: 529,306.39 ft Longitude: 149° 45' 39.919 W Position Uncertainty 0.00 ft Wellhead Elevation: ft Ground Level: 34.30ft Wellbore 3K-108 Magnetics Model Name Sample Date Declination Dip Angle Field Strength L bggm2007 10/12/2007 23.08 80.89 57,624 Design 3K-108 (wp09) Audit Notes: Version: 14 Phase: PLAN Tie On Depth: 40.00 Vertical Section: Depth From (TVD) +N/-S +E/-W D irection (ft) (ft) (ft) (°) 40.00 0.00 0.00 90.00 8/5/2008 10:36:45AM Page 2 COMPASS 2003.16 Buitd 42F t ~ ~ ~ ~ 1 Y~ Ha lliburton -Sperry ~~°~" Standard Prop osal Report Database: EDM 2003.1 6 Single User Db Local Co-o rdinate Reference: .Well Plan 3K-108 (E12) -Slot 3K-108' Staked Company: ConocoPhill ips (Alaska) Inc. -Kup2 ND Reference: 74.3' ( 34.3'+40) @ 74.30ft Project: Kuparuk River Unit MD Refere nce: 74.3' (34.3'+40) @ 74.30ft Site: Kuparuk 3K Pad North Refe rence: True Well: Plan 3K-108 (E12) Survey Cal culation Method: Minim um Curvature Wellbore: 3K-108 Design: 3K-108 (wp09) Plan Sections Measured Vertical ND Dogleg Buitd Turn ~ Depth Inclination Azimuth Depth System +Nl-S +E/-W Rate Rate Rate Tool Face (ft) (°) (°) (ft) ft (ft) (ft) (°/100ft) (°/100ft) (°/100ft) (°) 40.00 0.00 0.00 40.00 -34.30 0.00 0.00 0.00 0.00 0.00 0.00 340.00 0.00 0.00 340.00 265.70 0.00 0.00 0.00 0.00 0.00 0.00 702.17 10.86 50.00 700.00 625.70 22.01 26.23 3.00 3.00 0.00 50.00 1,797.74 54.55 41.51 1,600.00 1,525.70 443.26 420.49 4.00 3.99 -0.77 350.00 1,897.74 54.55 41.51 1,658.00 1,583.70 504.26 474.48 0.00 0.00 0.00 0.00 2,241.67 68.30 41.27 1,822.10 1,747.80 730.34 673.68 4.00 4.00 -0.07 -0.94 5,581.12 68.30 41.27 3,056.62 2,982.32 3,062.41 2,720.46 0.00 0.00 0.00 0.00 6,793.64 80.00 90.43 3,407.21 3,332.91 3,508.24 3,751.38 4.00 0.96 4.05 84.12 7,093.64 80.00 90.43 3,459.30 3,385.00 3,506.02 4,046.82 0.00 0.00 0.00 0.00 7,273.64 80.00 90.43 3,490.56 3,416.26 3,504.69 4,224.08 0.00 0.00 0.00 0.00 7,440.30 85.00 90.43 3,512.30 3,438.00 3,503.45 4,389.26 3.00 3.00 0.00 0.00 7,658.30 85.00 90.43 3,531.30 3,457.00 3,501.82 4,606.43 0.00 0.00 0.00 0.00 7,688.30 85.00 90.43 3,533.92 3,459.62 3,501.60 4,636.31 0.00 0.00 0.00 0.00 7,861.85 90.21 90.46 3,541.17 3,466.87 3,500.25 4,809.64 3.00 3.00 0.02 0.33 8,157.40 90.21 90.46 3,540.11 3,465.81 3,497.87 5,105.18 0.00 0.00 0.00 0.00 8,194.12 89.20 90.01 3,540.30 3,466.00 3,497.72 5,141.90 3.00 -2.74 -1.23 -155.86 8,194.63 89.20 90.03 3,540.31 3,466.01 3,497.72 5,142.41 3.00 0.00 3.00 90.00 9,341.36 89.20 90.03 3,556.30 3,482.00 3,497.21 6,289.02 0.00 0.00 0.00 0.00 9,727.19 88.88 101.60 3,562.77 3,488.47 3,458.22 6,672.16 3.00 -0.08 3.00 91.66 11,090.08 88.88 101.60 3,589.30 3,515.00 3,184.28 8,006.98 0.00 0.00 0.00 .0.00 11,134.48 88.49 100.33 3,590.32 3,516.02 3,175.84 8,050.56 3.00 -0.90 -2.86 -107.43 12,079.94 88.49 100.33 3,615.30 3,541.00 3,006.43 8,980.38 0.00 0.00 0.00 0.00 12,141.82 86.63 100.35 3,617.94 3,543.64 2,995.33 9,041.19 3.00 -3.00 0.03 179.38 13,117.62 86.63 100.35 3,675.30 3,601.00 2,820.39 9,999.47 0.00 0.00 0.00 0.00 8/5/2008 10:36:45AM Q Page 3 COMPASS 2003.16 Build 42F f l ~ ~ ~ ~i~ ~~~ Database: EDM 2003.16 Single User Db Company: ConocoPhillips (Alaska) Inc. -Kup2 Project: Kuparuk River Unit Site: Kuparuk 3K Pad well: Plan 3K-108 (E12) Wellbore: 3K-108 Design: 3K-108 (vap09) Planned Survey Measured Vertical Depth Inc lination Azimuth Depth TVDss (ft) (°) (°) (ft) ft 40.00 0.00 0.00 40.00 -34.30 SHL: 1473' FSL, 199' FWL - Sec35-T13N-R09E 100.00 0.00 0.00 100.00 25.70 200.00 0.00 0.00 200.00 125.70 300.00 0.00 0.00 300.00 225.70 340.00 0.00 0.00 340.00 265.70 400.00 1.80 50.00 399.99 325.69 500.00 4.80 50.00 499.81 425.51 600.00 7.80 50.00 599.20 524.90 700.00 10.80 50.00 697.87 623.57 702.17 10.86 50.00 700.00 625.70 800.00 14.73 47.33 795.38 721.08 900.00 18.71 45.73 891.14 816.84 1,000.00 22.69 44.67 984.66 910.36 1,100.00 26.68 43.91 1,075.51 1,001.21 1,200.00 30.67 43.34 1,163.23 1,088.93 1,300.00 34.66 42.89 1,247.39 1,173.09 1,400.00 38.66 42.52 1,327.60 1,253.30 1,500.00 42.65 42.21 1,403.45 1,329.15 1,600.00 46.65 41.95 1,474.58 1,400.28 1,700.00 50.64 41.71 1,540.64 1,466.34 1,773.90 53.60 41.56 1,586.01 1,511.71 T3 1,797.74 54.55 41.51 1,600.00 1,525.70 1,800.00 54.55 41.51 1,601.31 1,527.01 1,892.83 54.55 41.51 1,655.15 1,580.85 PFrost 1,897.74 54.55 41.51 1,658.00 1,583.70 1,900.00 54.64 41.51 1,659.31 1,585.01 2,000.00 58.64 41.43 1,714.29 1,639.99 2,100.00 62.64 41.36 1,763.31 1,689.01 2,195.13 66.44 41.30 1,804.20 1,729.90 K15 2,200.00 66.64 41.30 1,806.14 1,731.84 2,241.67 68.30 41.27 1,822.10 1,747.80 2,300.00 68.30 41.27 1,843.67 1,769.37 2,400.00 68.30 41.27 1,880.63 1,806.33 2,500.00 68.30 41.27 1,917.60 1,843.30 2,600.00 68.30 41.27 1,954.57 1,880.27 2,700.00 68.30 41.27 1,991.54 1,917.24 2,800.00 68.30 41.27 2,028.50 1,954.20 2,900.00 68.30 41.27 2,065.47 1,991.17 3,000.00 68.30 41.27 2,102.44 2,028.14 3,100.00 68.30 41.27 2,139.41 2,065.11 3,200.00 68.30 41.27 2,176.38 2,102.08 Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: • Halliburton -Sperry Standard Proposal Report Well Plan 3K-108 (E12) -Slot 3K-108" Staked 74.3' (34.3'+40) @ 74.30ft 74.3' (34.3'+40) @ 74.30ft True Minimum Curvature Map Map +N/_g +E/-W Northing Fasting DLS Vert Section (ft) (ft) (ft) (ft) -34.30 0.00 0.00 6,008,466.45 529,306.39 0.00 0.00 0.00 0.00 6,008,466.45 529,306.39 0.00 0.00 0.00 0.00 6,008,466.45 529,306.39 0.00 0.00 0.00 0.00 6,008,466.45 529,306.39 0.00 0.00 0.00 0.00 6,008,466.45 529,306.39 0.00 0.00 0.61 0.72 6,008,467.06 529,307.11 3.00 0.72 4.31 5.13 6,008,470.78 529,311.50 3.00 5.13 11.36 13.54 6,008,477.86 529,319.88 3.00 13.54 21.74 25.91 6,008,488.29 529,332.21 3.00 25.91 22.01 26.23 6,008,488.56 529,332.52 3.00 26.23 36.37 42.44 6,008,502.98 529,348.68 4.00 42.44 56.19 63.29 6,008,522.89 529,369.45 4.00 63.29 81.12 88.34 6,008,547.91 529,394.40 4.00 88.34 111.02 117.48 6,008,577.92 529,423.42 4.00 117.48 145.75 150.57 6,008,612.78 529,456.36 4.00 150.57 185.15 187.44 6,008,652.32 529,493.08 4.00 187.44 229.02 227.92 6,008,696.34 529,533.38 4.00 227.92 277.15 271.81 6,008,744.64 529,577.08 4.00 271.81 329.30 318.89 6,008,796.97 529,623.95 4.00 318.89 385.22 368.94 6,008,853.08 529,673.77 4.00 368.94 428.81 407.68 6,008,896.82 529,712.34 4.00 407.68 443.26 420.49 6,008,911.32 529,725.09 4.00 420.49 444.64 421.71 6,008,912.70 529,726.30 0.00 421.71 501.27 471.82 6,008,969.52 529,776.19 0.00 471.82 504.26 474.48 6,008,972.52 529,778.83 0.00 474.48 505.64 475.70 6,008,973.91 529,780.05 4.00 475.70 568.21 531.00 6,009,036.69 529,835.10 4.00 531.00 633.58 588.62 6,009,102.27 529,892.45 4.00 588.62 698.06 645.34 6,009,166.97 529,948.91 4.00 645.34 701.42 648.28 6,009,170.34 529,951.84 4.00 648.28 730.34 673.68 6,009,199.36 529,977.13 4.00 673.68 771.07 709.43 6,009,240.23 530,012.71 0.00 709.43 840.91 770.72 6,009,310.29 530,073.72 0.00 770.72 910.74 832.01 6,009,380.36 530,134.73 0.00 832.01 980.57 893.30 6,009,450.43 530,195.74 0.00 893.30 1,050.41 954.59 6,009,520.50 530,256.75 0.00 954.59 1,120.24 1,015.88 6,009,590.56 530,317.76 0.00 1,015.88 1,190.08 1,077.17 6,009,660.63 530,378.77 0.00 1,077.17 1,259.91 1,138.47 6,009,730.70 530,439.78 0.00 1,138.47 1,329.74 1,199.76 6,009,800.77 530,500.79 0.00 1,199.76 1,399.58 1,261.05 6,009,870.83 530,561.80 0.00 1,261.05 8/5/2008 10:36:45AM Page 4 COMPASS 2003.16 Build 42F ~!2!GINAL Halliburton -Sperry ~~~s "~" Standard Proposal Report Database: EDM 2003.16 Single User Db Local Co-ordinate Reference: ~~~>~_ Well Plan 3K-108 (E12) -Slot 3K-108" Staked Company: ConocoPhillips (Alaska) Inc. -Kup2 ND Reference: 74.3' (34.3'+40) @ 74.30ft Project: Kuparuk River Unit MD Reference: 74.3' (34.3'+40) @ 74.30ft Site: Kuparuk 3K Pad North Reference: True Well: Plan 3K-108 (E12) Survey Calculation Method: Minimum Curvature Wellbore: 3K-108 Desiyn: 3K-108 (wp09) Planned Survey Measured Vertical Map Map Depth Inclination Azimuth Depth NDss +N/-S +E/_yy Northing Easting DLS Vert Section (ft) (°) (°) (ft) ft (ft) (ft) (ft) (ft) 2,139.04 3,300.00 68.30 41.27 2,213.34 2,139.04 1,469.41 1,322.34 6,009,940.90 530,622.81 0.00 1,322.34 Surface Csg @ 3300' MD, 2213' ND: 2338 ' FNL, 1643' FWL- Sec35-T13N-R09 E - 13 3/8" 3,400.00 68.30 41.27 2,250.31 2,176.01 1,539.25 1,383.63 6,010,010.97 530,683.82 0.00 1,383.63 3,500.00 68.30 41.27 2,287.28 2,212.98 1,609.08 1,444.92 6,010,081.04 530,744.83 0.00 1,444.92 3,600.00 68.30 41.27 2,324.25 2,249.95 1,678.91 1,506.21 6,010,151.10 530,805.84 0.00 1,506.21 3,700.00 68.30 41.27 2,361.21 2,286.91 1,748.75 1,567.50 6,010,221.17 530,866.85 0.00 1,567.50 3,800.00 68.30 41.27 2,398.18 2,323.88 1,818.58 1,628.79 6,010,291.24 530,927.86 0.00 1,628.79 3,843.36 68.30 41.27 2,414.21 2,339.91 1,848.86 1,655.37 6,010,321.62 530,954.32 0.00 1,655.37 T3+8Q0 3,900.00 68.30 41.27 2,435.15 2,360.85 1,888.42 1,690.09 6,010,361.30 530,988.87 0.00 1,690.09 4,000.00 68.30 41.27 2,472.12 2,397.82 1,958.25 1,751.38 6,010,431.37 531,049.88 0.00 1,751.38 4,100.00 68.30 41.27 2,509.09 2,434.79 2,028.08 1,812.67 6,010,501.44 531,110.89 0.00 1,812.67 4,200.00 68.30 41.27 2,546.05 2,471.75 2,097.92 1,873.96 6,010,571.51 531,171.90 0.00 1,873.96 4,300.00 68.30 41.27 2,583.02 2,508.72 2,167.75 1,935.25 6,010,641.57 531,232.91 0.00 1,935.25 4,400.00 68.30 41.27 2,619.99 2,545.69 2,237.59 1,996.54 6,010,711.64 531,293.92 0.00 1,996.54 4,500.00 68.30 41.27 2,656.96 2,582.66 2,307.42 2,057.83 6,010,781.71 531,354.93 0.00 2,057.83 4,600.00 68.30 41.27 2,693.92 2,619.62 2,377.25 2,119.12 6,010,851.78 531,415.94 0.00 2,119.12 4,700.00 68.30 41.27 2,730.89 2,656.59 2,447.09 2,180.41 6,010,921.84 531,476.96 0.00 2,180.41 4,800.00 68.30 41.27 2,767.86 2,693.56 2,516.92 2,241.71 6,010,991.91 531,537.97 0.00 2,241.71 4,900.00 68.30 41.27 2,804.83 2,730.53 2,586.76 2,303.00 6,011,061.98 531,598.98 0.00 2,303.00 4,917.81 68.30 41.27 2,811.41 2,737.11 2,599.19 2,313.91 6,011,074.46 531,609.84 0.00 2,313.91 Ugnu C 5,000.00 68.30 41.27 2,841.79 2,767.49 2,656.59 2,364.29 6,011,132.05 531,659.99 0.00 2,364.29 5,100.00 68.30 41.27 2,878.76 2,804.46 2,726.42 2,425.58 6,011,202.11 531,721.00 0.00 2,425.58 5,200.00 68.30 41.27 2,915.73 2,841.43 2,796.26 2,486.87 6,011,272.18 531,782.01 0.00 2,486.87 5,300.00 68.30 41.27 2,952.70 2,878.40 2,866.09 2,548.16 6,011,342.25 531,843.02 0.00 2,548.16 5,400.00 68.30 41.27 2,989.67 2,915.37 2,935.93 2,609.45 6,011,412.32 531,904.03 0.00 2,609.45 5,500.00 68.30 41.27 3,026.63 2,952.33 3,005.76 2,670.74 6,011,482.38 531,965.04 0.00 2,670.74 5,581.12 68.30 41.27 3,056.62 2,982.32 3,062.41 2,720.46 6,011,539.22 532,014.53 0.00 2,720.46 5,594.71 II 68.36 41.85 3,061.64 2,987.34 3,071.86 2,728.84 6,011,548.70 532,022.87 4.00 2,728.84 Ugnu B 5,600.00 68.38 42.08 3,063.59 2,989.29 3,075.52 2,732.13 6,011,552.37 532,026.14 4.00 2,732.13 5,700.00 68.87 46.34 3,100.05 3,025.75 3,142.24 2,797.05 6,011,619.34 532,090.79 4.00 2,797.05 5,800.00 69.46 50.58 3,135.63 3,061.33 3,204.19 2,866.99 6,011,681.56 532,160.48 4.00 2,866.99 5,900.00 70.15 54.78 3,170.17 3,095.87 3,261.07 2,941.61 6,011,738.73. 532,234.87 4.00 2,941.61 6,000.00 70.94 58.93 3,203.48 3,129.18 3,312.61 3,020.54 6,011,790.57 532,313.59 4.00 3,020.54 6,031.79 71.21 60.25 3,213.79 3,139.49 3,327.83 3,046.47 6,011,805.89 532,339.46 4.00 3,046.47 Ugnu A 6,100.00 71.82 63.05 3,235.42 3,161.12 3,358.54 3,103.40 6,011,836.83 532,396.26 4.00 3,103.40 6,200.00 72.79 67.13 3,265.82 3,191.52 3,398.65 3,189.79 6,011,877.27 532,482.48 4.00 3,189.79 6,300.00 73.84 71.15 3,294.54 3,220.24 3,432.74 3,279.28 6,011,911.71 532,571.83 4.00 3,279.28 6,400.00 74.97. 75.14 3,321.44 3,247.14 3,460.65 3,371.44 6,011,939.98 532,663.87 4.00 3,371.44 6,409.51 75.08 75.52 3,323.89 3,249.59 3,462.98 3,380.33 6,011,942.34 532,672.75 4.00 3,380.33 N 6,500.00 76.16 79.08 3,346.38 3,272.08 3,482.24 3,465.82 6,011,961.94 532,758.16 4.00 3,465.82 8/5/2008 10:36:4 AM Page 5 COMPASS 2003.16 Build 42F ~I~IN~L ~~'~ ~~ Database: EDM 2003.16 Single User Db Company: ~onocoPhillips (Alaska) Inc. -Kup2 Project: uparuk River Unit Site: uparuk 3K Pad Well: Ian 3K-108 (E12) Wellbore: K-108 Design: 3K-108 (vrp09) Planned Survey Halliburton -Sperry Standard Proposal Report Local Co-ordinate Reference: Well Plan 3K-108 (E12) -Slot 3K-108` Staked TVD Reference: 74.3' (34.3'+40) @ 74.30ft MD Reference: 74.3' (34.3'+40) @ 74.30ft North Reference: True Survey Calculation Method: Minimum Curvature Measured Vertical Depth Inclination Azi muth Depth TVDss +N/-S +E/-W (ft) (°) (°) (ft) ft (ft) (ft) 6,600.00 77.42 82.98 3,369.24 3,294.94 3,497.40 3,561.97 6,700.00 78.73 86.85 3,389.92 3,315.62 3,506.06 3,659.40 6,793.64 80.00 90.43 3,407.21 3,332.91 3,508.24 3,751.38 6,800.00 80.00 90.43 3,408.31 3,334.01 3,508.20 3,757.65 6,900.00 80.00 90.43 3,425.68 3,351.38 3,507.46 3,856.13 7,000.00 80.00 90.43 3,443.04 3,368.74 3,506.72 3,954.61 7,091.87 80.00 90.43 3,458.99 3,384.69 3,506.04 4,045.08 WSak D 7,093.64 80.00 90.43 3,459.30 3,385.00 3.506.02 4,046.82 3K-108 Dtop (02/04108) 7,100.00 ~ 80.00 90.43 3,460.40 3,386.10 3,505.98 4,053.08 7,200.00 80.00 90.43 3,477.77 3,403.47 3,505.24 4,151.56 7,273.64 ' 80.00 90.43 3,490.56 3,416.26 3,504.69 4,224.08 7,300.00 ' 80.79 90.43 3,494.96 3,420.66 3,504.50 4,250.07 7,324.31 ' 81.52 90.43 3,498.69 3,424.39 3,504.32 4,274.09 WSak C 7,400.00 83.79 90.43 3,508.37 3,434.07 3,503.75 4,349.15 7,440.30 85.00 90.43 3,512.30 3,438.00 3,503.45 4,389.26 7,500.00 85.00 90.43 3,517.51 3,443.21 3,503.01 4,448.73 7,600.00 85.00 90.43 3,526.22 3,451.92 3,502.26 4,548.35 7,658.30 ' 85.00 90.43 3,531.30 3,457.00 3,501.82 4,606.43 7,676.54 85.00 90.43 3,532.89 3,458.59 3,501.68 4,624.59 WSak B 7,688.30 85.00 90.43 3,533.92 3,459.62 3,501.60 4,636.31 7,688.38 85.00 90.43 3,533.93 3,459.63 3,501.60 4,636.39 Int. Casing @ 7688' MD, 3534' TVD: 307' FNL, 320' FE L - Sec35-T13N-R09E 7,700.00 ', 85.35 90.43 3,534.90 3,460.60 3,501.51 4,647.97 7,800.00 88.35 90.45 3,540.40 3,466.10 3,500.74 4,747.80 7,861.85 ' 90.21 90.46 3,541.17 3,466.87 3,500.25 4,809.64 7,900.00 ' 90.21 90.46 3,541.04 3,466.74 3,499.94 4,847.79 8,000.00 90.21 90.46 3,540.68 3,466.38 3,499.14 4,947.79 8,100.00 90.21 90.46 3,540.32 3,466.02 3,498.33 5,047.78 8,157.40 90.21 90.46 3,540.11 3,465.81 3,497.87 5,105.18 8,194.12 89.20 90.01 3,540.30 3,466.00 3,497.72 5,141.90 3K-E12 CP1 (9/11107) 8,194.63 89.20 90.03 3,540.31 3,466.01 3,497.72 5,142.41 8,200.00 89.20 90.03 3,540.38 3,466.08 3,497.72 5,147.78 8,300.00 89.20 90.03 3,541.78 3,467.48 3,497.67 5,247.77 8,400.00 ', 89.20 90.03 3,543..17 3,468.87 3,497.63 5,347.76 8,500.00 89.20 90.03 3,544.57 3,470.27 3,497.59 5,447.75 8,600.00 89.20 90.03 3,545.96 3,471.66 3,497.54 5,547.74 8,700.00 89.20 90.03 3,547.36 3,473.06 3,497.50 5,647.73 8,800.00 89.20 90.03 3,548.75 3,474.45 3,497.45 5,747.72 8,900.00 89.20 90.03 3,550.14 3,475.84 3,497.41 5,847.71 9,000.00 ', 89.20 90.03 3,551.54 3,477.24 3,497.37 5,947.70 Map Map Northing Easting DLS Vert Section (ft) (ft) 3,294.94 6,011,977.47 532,854.23 4.00 3,561.97 6,011,986.52 532,951.62 4.00 3,659.40 6,011,989.06 533,043.59 4.00 3,751.38 6,011,989.04 533,049.85 0.00 3,757.65 6,011,988.68 533,148.32 .0.00 3,856.13 6,011,988.33 533,246.79 0.00 3,954.61 6,011,988.01 533,337.26 0.00 4,045.08 6,011,988.00 533,339.00 0.00 4,046.82 6,011,987.98 533,345.27 0.00 4,053.08 6,011,987.62 533,443.74 0.00 4,151.56 6,011,987.36 533,516.25 0.00 4,224.08 6,011,987.27 533,542.24 3.00 4,250.07 6,011,987.19 533,566.26 3.00 4,274.09 6,011,986.92 533,641.31 3.00 4,349.15 6,011,986.77 533,681.42 3.00 4,389.26 6,011,986.56 533,740.88 0.00 4,448.73 6,011,986.20 533,840.49 0.00 4,548.35 6,011,985.99 533,898.56 0.00 4,606.43 6,011,985.93 533,916.73 0.00 4,624.59 6,011,985.89 533,928.45 0.00 4,636.31 6,011,985.89 533,928.52 0.00 4,636.39 9 5/8" 6,011,985.85 533,940.10 3.02 4,647.97 6,011,985.47 534,039.93 3.00 4,747.80 6,011,985.22 534,101.76 3.00 4,809.64 6,011,985.06 534,139.91 0.00 4,847.79 6,011,984.65 534,239.90 0.00 4,947.79 6,011,984.24 534,339.89. 0.00 5,047.78 6,011,984.01 534,397.28 0.00 5,105.18 6,011,984.00 534,434.00 3.00 5,141.90 6,011,984.00 534,434.51 3.00 5,142.41 6,011,984.02 534,439.87 0.00 5,147.78 6,011,984.37 534,539.85 0.00 5,247.77 6,011,984.72 534,639.83 0.00 5,347.76 6,011,985.07 534,739.81 0.00 5,447.75 6,011,985.41 534,839.79 0.00 5,547.74 6,011,985.76 534,939.77 0.00 5,647.73 6,011,986.11 535,039.75 0.00 5,747.72 6,011,986.46 535,139.73 0.00 5,847.71 6,011,986.81 535,239.71 0.00 5,947.70 8/5/2008 10:3ti:45AM Page 6 COMPASS 2003. i6 Build 42F ORIGINAL ~~ ~ . Database: EDM 2003.16 Single User Db Company: ConocoPhillips (Alaska) Inc. -Kup2 Project: Kuparuk River Unit Site: Kuparuk 3K Pad Well: Plan 3K-108 (E12) Wellbore: 3K-108 Design: 3K-108 (wp09) Planned Survey Measured Vertical Depth Inclination Azimuth Depth (ft) (°) (°) (ft) 9,100.00 89.20 90.03 9,200.00 89.20 90.03 9,300.00 89.20 90.03 9 341.36 89.20 90.03 , 3K-E12 CP2 (9/11/07) 9,400.00 89.15 9,500.00 89.07 9,600.00 88.98 9,700.00 88.91 9,727.19 88.88 9,800.00 88.88 9,900.00 88.88 10,000.00 88.88 10,100.00 88.88 10,200.00 88.88 10,300.00 88.88 10,400.00 88.88 10,500.00 88.88 10,600.00 88.88 10,700.00 88.88 10,800.00 88.88 10,900.00 88.88 11,000.00 88.88 11,090.08 88.88 3K-E72 CP3 (9/11107) 11,100.00 88.80 11,134.48 88.49 11,200.00 88.49 11,300.00 88.49 11,400.00 88.49 11,500.00 88.49 11,600.00 88.49 11,700.00 88.49 11,800.00 88.49 11,900.00 88.49 12,000.00 88.49 12,079.94 88.49 3K-E12 CP4 (9111/U7) 12,100.00 87.88 12,141.82 86.63 12,200.00 86.63 12,300.00 86.63 12,400.00 86.63 12,500.00 86.63 12,600.00 86.63 3,552.93 3,554.33 3,555.72 3,556.30 Halliburton -Sperry Standard Proposal Report Local Co-ordinate Reference: Well Plan 3K-108 (E12) -Slot 3K-108" Staked ND Reference: 74.3' (34.3'+40) @ 74.30ft MD Reference: 74.3' (34.3'+40) @ 74.30ft North Reference: True Survey Calculation Method: Minimum Curvature Map Map TVDss +Ni-S +E/-W Northing Easting DLS Vert Section ft (ft) (ft) (ft) (ft) 3,478.63 3,478.63 3,497.32 6,047.69 6,011,987.16 535,339.69 0.00 6,047.69 3,480.03 3,497.28 6,147.68 6,011,987.51 535,439.67 0.00 6,147.68 3,481.42 3,497.23 6,247.67 6,011,987.86 535,539.65 0.00 6,247.67 3,482.00 3,497.21 6,289.02 6,011,988.00 535,581.00 0.00 6,289.02 91.78 3,557.14 3,482.84 3,496.29 6,347.65 6,011,987.30 535,639.62 3.00 6,347.65 94.78 3,558.70 3,484.40 3,490.56 6,447.46 6,011,981.97 535,739.45 3.00 6,447.46 97.78 3,560.40 3,486.10 3,479.62 6,546.84 6,011,971.42 535,838.86 3.00 6,546.84 100.78 3,562.24 3,487.94 3,463.50 6,645.50 6,011,955.69 535,937.57 3.00 6,645.50 101.60 3,562.77 3,488.47 3,458.22 6,672.16 6,011,950.52 535,964.25 3.00 6,672.16 101.60 3,564.19 3,489.89 3,443.59 6,743.48 6,011,936.16 536,035.62 0.00 6,743.48 101.60 3,566.13 3,491.83 3,423.49 6,841.42 6,011,916.45 536,133.62 0.00 6.,841.42 101.60 3,568.08 3,493.78 3,403.39 6,939.36 6,011,896.74 536,231.63 0.00 6,939.36 101.60 3,570.03 3,495.73 3,383.29 7,037.30 6,011,877.02 536,329.64 0.00 7,037.30 101.60 3,571.97 3,497.67 3,363.19 7,135.24 6,011,857.31 536,427.65 0.00 7,135.24 101.60 3,573.92 3,499.62 3,343.09 7,233.18 6,011,837.60 536,525.66 0.00 7,233.18 101.60 3,575.87 3,501.57 3,322.99 7,331.12 6,011,817.89 536,623.67 0.00 7,331.12 101.60 3,577.81 3,503.51 3,302.89 7,429.06 6,011,798.17 536,721.67 0.00 7,429.06 101.60 3,579.76 3,505.46 3,282.79 7,527.00 6,011,778.46 536,819.68 0.00 7,527.00 101.60 3,581.71 3,507.41 3,262.69' 7,624.94 6,011,758.75 536,917.69 0.00 7,624.94 101.60 3,583.65 3,509.35 3,242.59 7,722.88 6,011,739.03 537,015.70 0.00 7,722.88 101.60 3,585.60 3,511.30 3,222.49 7,820.82 6,011,719.32 537,113.71 0.00 7,820.82 101.60 3,587.55 3,513.25 3,202.39 7,918.76 6,011,699.61 537,211.72 0.00 7,918.76 101.60 3,589.30 3,515.00 3,184.28 8,006.98 6,011,681.85 537,300.00 0.00 8,006.98 101.31 3,589.50 3,515.20 3,182.31 8,016.70 6,011,679.92 537,309.73 3.00 8,016.70 100.33 3,590.32 3,516.02 3,175.84 8,050.56 6,011,673.58 537,343.61 3.00 8,050.56 100.33 3,592.05 3,517.75 3,164.10 8,114.99 6,011,662.10 537,408.08 0.00 8,114.99 100.33 3,594.69 3,520.39 3,146.18 8,213.34 6,011,644.57 537,506.49 0.00 8,213.34 100.33 3,597.33 3,523.03 3,128.26 8,311.69 6,011,627.04 537,604.90 0.00 8,311.69 100.33 3,599.98 3,525.68 3,110.35 8,410.03 6,011,609.50 537,703.30 0.00 8,410.03 100.33 3,602.62 3,528.32 3,092.43 8,508.38 6,011,591.97 537,801.71 0.00 8,508.38 100.33 3,605.26 3,530.96 3,074.51 8,606.72 6,011,574.44 537,900.11 0.00 8,606.72 100.33 3,607.90 3,533.60 3,056.59 8,705.07 6,011,556.91 537,998.52 0.00 8,705.07 100.33 3,610.55 3,536.25 3,038.67 8,803.41 6,011,539.38 538,096.92 0.00 8,803.41 100.33 3,613.19 3,538.89 3,020.75 8,901.76 6,011,521.85 538,195.33 0.00 8,901.76 100.33 3,615.30 3,541.00 3,006.43 8,980.38 6,011,507.84 538,274.00 0.00 8,980.38 100.33 3,615.94 3,541.64 3,002.83 9,000.10 6,011,504.32 538,293.73 3.00 9,000.10 100.35 3,617.94 3,543.64 2,995.33 9,041.19 6,011,496.99 538,334.85 3.00 9,041.19 100.35 3,621.36 3,547.06 2,984.90 9,098.33 6,011,486.78 538,392.02 0.00 9,098.33 100.35 3,627.24 3,552.94 2,966.97 9,196.54 6,011,469.24 538,490.28 0.00 9,196.54 100.35 3,633.11 3,558.81 2,949.05 9,294.74 6,011,451.70 538,588.55 0.00 9,294.74 100.35 3,638.99 3,564.69 2,931.12 9,392.94 6,011,434.16 538,686.81 0.00 9,392.94 100.35 3,644.87 3,570.57 2,913.19 9,491.15 6,011,416.62 538,785.08 0.00 9,491.15 8/5/2008 10:36:45AM Page 7 COMPASS 2003. i6 Build 42F nRIGINAL • 1 • • Halliburton -Sperry '~"' Standard Proposal Report Database: ~, EDM 2003.16 Single User Db Local Co-ordinate Reference: Well Plan 3K-108 (E12) -Slot 3K-108"` Staked Company: ConocoPhillips (Alaska) Inc. -Kup2 TVD Reference: 74.3' (34.3'+40) @ 74.30ft Project: Kuparuk River Unit MD Reference: 74.3' (34.3'+40) @ 74.30ft Site: Kuparuk 3K Pad North Reference: True Well: Plan 3K-108 (E12) Survey Calculation Method: Minimum Curvature Wellbore: 3K-108 Design: 3K-108 (vvp09) Planned Survey Measured Vertical Map Depth Inclination Azimuth Depth TVDss +N/-S +E/_yy Northing (ft) ( °) l°) (ft) ft (ft) (ft) (ft) 12,700.00 86.63 100.35 3,650.75 3,576.45 2,895.26 9,589.35 6,011,399.07 12,800.00 86.63 100.35 3,656.63 3,582.33 2,877.33 9,687.55 6,011,381.53 12,900.00 86.63 100.35 3,662.51 3,588.21 2,859.40 9,785.76 6,011,363.99 13,000.00 86.63 100.35 3,668.39 3,594.09 2,841.47 9,883.96 6,011,346.45 13,100.00 86.63 100.35 3,674.26 3,599.96 2,823.54 9,982.17 6,011,328.91 13,117.62 86.63 100.35 3,675.30 3,601.00 2,820.39 9,999.47 6,011,325.82 3K-108 Toe Targets Target Name Map Fasting DLS Vert Section (ft) 3,576.45 538,883.34 0.00 9,589.35 538,981.60 0.00 9,687.55 539,079.87 0.00 9,785.76 539,178.13 0.00 9,883.96 539,276.40 0.00 9,982.17 539,293.71 0.00 9,999.47 - hiUmiss target Dip Angle Dip Dir. TVD +N/-S +E/-W -Shape (°) (°) (ft) (ft) (ft) 3K-108 Dtop (02/04/08) 0.21 90.43 3,459.30 3,506.02 4,046.82 - plan hits target - Point Northing Fasting (ft) (ft) 6,011,988.00 533,339.00 3K-E12 CP3 (9/11/07) 1.51 90.43 3,589.30 3,184.28 8,006.98 6,011,681.85 537,300.00 - plan hits target - Polygon Point 1 3,589.30 3,184.28 8,006.98 6,011,681.85 537,300.00 Point 2 3,614.98 3,006.50 8,979.81 6,011,507.90 538,273.43 3K-108 Toe 0.00 0.26 3,675.30 2,820.39 9,999.47 6,011,325.82 539,293.71 - plan hits target - Point 3K-E12 CP2 (9/11/07) 1.08 90.43 3,556.30 3,497.21 6,289.02 6,011,988.00 535,581.00 - plan hits target - Polygon Point 1 3,556.30 3,497.21 6,289.02 6,011,988.00 535,581.00 Point 2 3,588.73 3,184.40 8,007.06 6,011,681.96 537,300.08 3K-E12 CP4 (9/11/07) 0.00 0.00 3,615.30 3,006.43 8,980.38 6,011,507.84 538,274.00 - plan hits target - Point 3K-E12 CP1 (9/11/07) 0.80 90.03 3,540.30 3,497.72 5,141.90 6,011,984.00 534,434.00 - plan hits target - Polygon Point 1 3,540.30 3,497.72 5,141.90 6,011,984.00 534,434.00 Point 2 3,556.31 3,497.17 6,288.63 6,011,987.95 535,580.61 Casing Points Measured Vertical Casing Hole ', Depth Depth Diameter Diameter ~~ (ft) (ft) Name (~~) ( ) 3,300.00 2,213.34 13 3/8" 13-3/8 16 7,688.38 3,533.93 9 5/8" 9-5/8 12-1/4 13,117.62 3,675.30 3 1 /2" 3-1 /2 6-3/4 8/5/2008 10:36:45AM Page 8 COMPASS 2003.16 Build 42F ~~ ~~~t~~ •, • Halliburton -Sperry t~ ~ . ~;~.~ ~.: Standard Proposal Report Database: EDM 2003.16 Single User Db ..Local Co-ordinate Reference: Well Plan 3K-108 (E12) -Slot 3K-108' Staked Company: ConocoPhillips (Alaska) Inc. -Kup2 TVD Reference: 74.3' (34.3'+40) @ 74.30ft Project: Kuparuk River Unit MD Reference: 74.3' (34.3'+40) @ 74.30ft Site: Kuparuk 3K Pad North Reference: True Well: Plan 3K-108 (E12) Survey Calculation Method: Minimum Curvature Wellbore: 3K-108 Design: 3K-108 (wp09) Formations Measured Vertical Vertical Dip Depth Depth Depth SS Dip Direction ° ', (ft) (ft) ft Name L'tthology (°) ( ) 7,676.54 3,532.89 WSak B 7,324.31 3,498.69 WSak C 6,031.79 3,213.79 Ugnu A 5,594.71 3,061.64 Ugnu B 6,409.51 3,323.89 N 1,773.90 1,586.01 T3 7,091.87 3,458.99 WSak D 2,195.13 1,804.20 K15 3,843.36 2,414.21 T3+800 4,917.81 2,811.41 Ugnu C 1,892.83 1,655.15 PFrost ~_ 'Plan Annotations i Measured Vertical Local Co ordinates Depth Depth +N/-S +E/-W (ft) (ft) (ft) (ft) Comment 40.00 40.00 0.00 0.00 SHL: 1473' FSL, 199' FWL -Sec35-T13N-R09E 3,300.00 2,213.34 1,469.41 1,322.34 Surtace Csg @ 3300' MD, 2213' TVD: 2338' FNL, 1643' FWL -Sec35-T13N- 7,688.38 3,533.93 3,501.60 4,636.39 Int. Casing @ 7688' MD, 3534' TVD: 307' FNL, 320' FEL -Sec35-T13N-R09E 13,117.62 3,675.30 2,820.39 9,999.47 BHL @ 13118' MD, 3675' TVD: 994' FNL, 238' FEL - Sec36-T13N-R09E 8/5/2008 10:36:45AM Page 9 COMPASS 2003.16 Build 42F ConocoPhillips (Alaska) Inc. -Kup2 Kuparuk River Unit Kuparuk 3K Pad Plan 3K-108 (E12) 3K-108 3K-108 (wp09) ~ err Lr~1l~rl ,'~l~-c~r~r~~+~s ~ Clearance Summary .~. ~ Anticollision Report I~ 27 June, 2008 Trav. Cylinder North Proximity Scan on Current Survey Data (North Reference) Reference Design: Kuparuk 3K Pad -Plan 3K-108 (E12) - 3K-108 - 3K-108 (wp09) Well Coordinates: 6,008,218.39 N, 1,669,337.76E (70° 26' 02.11" N, 149° 45' 51.20" W) Datum Height: 74.3' (34.3'+40) @ 74.30ft Scan Range: 0.00 to 13,117.70 ft. Measured Depth. Scan Radius is 1,507.77 ft . Clearance Factor cutoff is Unlimited. Max Ellipse Separation is Unlimited Geodetic Scale Factor Applied Version: 2003.16 Build: 42F Scan Type: GLOBAL FILTER APPLIED: All wellpaths within 200'+ 100/1000 of reference Scan Type: 25.00 ![-1A1.La~ 1~3 U RTC 1'~1 Sperry Drilling Services C~ SURVEY PROGRAM Date: 20118-06-iGT00:00:00 Validated: Yes Version: 14 Depth Prom Depth To Survey/Plan Tool 40.00 600.00 31~-108 (wp09) (3K 108) CSGYRO-SS 600.00 13117.24 3I~-108 (wp09) (3K 108) MWD+IFR-Ali-CA~SC 0 3K-E8 w 3 K-0 sK-a ^~-~ 3K-36 (wp0 ;;~•'-" 3K-37 (w, 3K•E 90 L~ ~~ ; i 1 ~ ' 160 ~ ~ 1 i ~ ~ 3K-2 3K-0 ,ih ~~; , ~ ~ 1. ~I"'"') 3K-0 3'r<-0'Ji Travelling Cylinder Azimuth (TFO+AZI) ~°] vs Centre to Centre Separation X200 ft/inJ Details: Plan 3K-108 (E12) North American Datum 1983 Alaska Zone 4 Ground Level: 34.30 +NI-S +EI-W Northing Easting Latittude Longitude Slot 0.00 0.00 6008218.39 1669337.76 70° 26' 2.106 N 149° 45' 51.202 W REFERENCE INFORMATION Co-ordinate (NIE) Reference: Well Plan 3K-108 (E12), True North Vertical (ND) Reference: 74.3' (34.3'+40) ~ 74.30ft Section (VS) Reference: Slot - (O.OON, O.OOE) Measured Depth Reference: 74.3' (34.3'+40) @ 74.30ft Calculation Method: Minimum Curvature ConocoPhillips (Alaska) Inc. -Kup2 Calculation Method: Minimum Curvature Error System: ISCWSA Scan Method: Trav. Cylinder North Error Surtace: Elliptical Conic Warning Method: Rules Based From Colour To MD 40 262 262 512 512 762 762 1012 1012 1262 1262 1512 1512 ....... _ _. _._ 1762 1762 -- 2012 2012 2262 2262 2512 2512 2762 2762 3012 3012 4012 4012 5012 5012 6012 6012 7012 7012 8012 8012 9012 9012 10012 10012 11012 11012 12012 12012 - --~ 13012 13012 14012 14012 -- - -~ 15012 90 Travelling Cylinder Azimuth (TEO+AZI) ~°] vs Centre to Centre Separa6ou [50 ft/inl SECTION DETAILS Sec MD Inc Azi ND +N/-S +E/-W DLeg TFace VSec Target 1 ao.oa o.oo a.oo ao.oa o.oo o.oo 0.09 0.00 0.00 2 340.00 0.00 0.00 340.OO 0.00 0.00 0.00 0.00 0.00 3 702.17 10 B6 50.00 700.00 22.01 26.23 3.00 50.00 26.23 4 1797.74 54.55 41.51 1600.00 443.26 420.49 4.00 350.00 420.49 5 1897.74 54.55 41.51 1658.00 504.26 474.48 0.00 0.00 474.48 6 2241.68 68.30 41.26 7822.71 730.36 673.67 4.00 -0.97 673.67 7 5581.02 68.30 41.26 3056.57 3062.63 2720.07 0.00 0.00 2720.07 8 6793.71 80.00 90.43 3407.21 3508.60 3751.11 4.00 84.12 3751.11 9 7093 71 80.00 90 43 3459.30 3506.38 4046.54 0.00 0.00 4046.54 3K-108 Dtop (02/04/08) 70 7273.71 80.00 90.43 3490.56 3505.05 4223.80 0.00 0.00 4223.80 11 7440.38 85.00 90.43 3512.30 3503.81 4388.99 3.00 0.00 4388.99 12 7658.38 85.00 90.43 3531.30 3502.17 4606.15 0.00 0.00 4606.75 73 7688.38 85.00 90.43 3533.92 3501.95 4636.04 0.00 0.00 4636.04 14 7861.92 90.21 90.45 3541.77 3500.62 4809.35 3.00 0.21 4809.35 15 8157.63 90.21 90.45 3540.11 3498.30 5105.06 0.00 0 00 5105.06 16 8194.20 89.20 90.01 3540.30 3458.15 5141.63 3 00 -156.38 5141.63 3K-108 CP I 17 8194.58 89.20 90.02 3540.31 3498.15 5142.00 3.00 90.00 5142.00 18 9341.44 89.20 90.02 3556.30 3497.73 6288.75 0.00 0.00 6288.75 3K-108 CP2 19 9727.27 88.88 101.59 3562.77 3458.76 6671.90 3.00 91.66 6677.90 20 11090.16 88.88 101.59 3589.30 3184.91 8006.73 0.00 0.00 8006.73 3K-108 CP3 21 11134.47 88.49 100.33 3590.32 3176.49 8050.21 3.00 -107.46 8050.21 22 12079.74 88.49 100.33 3615.30 3007.12 8979.85 0.00 0.00 8979.85 3K-108 CP4 23 12747.56 86.63 100.34 3677.93 2996.04 9040.62 3.00 179.57 9040.62 24 13117 70 86.63 100.34 3675 30 2821.15 9999.24 0.00 0.00 9999.24 3K-108 Toe ANTI-COLLISION Interpolation Method: MD, interval: 25.00 Depth Range From: 40.00 To 13117.70 Centre Distance: 1507.77 Reference: Plan: 3K-108 (wp09) (Plan 3K-108 (E12)/3K-108) 180 L~ ConocoPhillips (Alaska) Inc. -Kup2 ~~~~~~~ Kuparuk River Unit Anticollision Report for Plan 3K-108 (E12) - 3K-108 (wp09) Trav. Cylinder North Proximity Scan on Current Survey Data (North Reference) Reference Design: Kuparuk 3K Pad -Plan 3K-108 (E12) - 3K-108 - 3K-108 (wp09) Scan Range: 0.00 to 13,117.70 ft. Measured Depth. Scan Radius is 1,507.77 ft . Clearance Factor cutoff is Unlimited. Max Ellipse Separation is Unlimited Measured Minimum @Measured Ellipse @Measured Clearance Summary Based on Site Name Depth Distance Depth Separation Depth Factor Minimum Separation Warning Comparison Well Name - Wellbore Name -Design (ft) (ft) (ft) (ft) ft Kuparuk 3K Pad 3K-01 - 3K-01 - 3K-01 355.11 36.87 355.11 27.77 350.00 4.049 Centre Distance Pass -Major Risk 3K-01 - 3K-01 - 3K-01 601.16 40.31 601.16 24.47 600.00 2.546 Clearance Factor Pass -Major Risk 3K-02 - 3K-02 - 3K-02 354.99 61.76 354.99 52.81 350.00 6.901 Centre Distance Pass -Major Risk 3K-02 - 3K-02 - 3K-02 428.44 62.86 428.44 51.88 425.00 5.725 Clearance Factor Pass -Major Risk 3K-03 - 3K-03 - 3K-03 354.86 86.50 354.86 77.55 350.00 9.666 Centre Distance Pass -Major Risk 3K-03 - 3K-03 - 3K-03 427.69 87.44 427.69 76.47 425.00 7.972 Clearance Factor Pass -Major Risk 3K-04 - 3K-04 - 3K-04 378.81 109.99 378.81 100.37 375.00 11.435 Centre Distance Pass -Major Risk 3K-04 - 3K-04 - 3K-04 450.98 111.15 450.98 99.52 450.00 9.560 Clearance Factor Pass -Major Risk 3K-05 - 3K-05 - 3K-05 130.30 137.85 130.30 135.06 125.00 49.435 Centre Distance Pass -Major Risk 3K-05 - 3K-05 - 3K-05 402.34 139.83 402.34 129.59 400.00 13.652 Clearance Factor Pass -Major Risk 3K-06 - 3K-06 - 3K-06 255.29 161.23 255.29 155.96 250.00 30.571 Centre Distance Pass -Major Risk 3K-06 - 3K-06 - 3K-06 449.24 163.23 449.24 153.71 450.00 17.149 Clearance Factor Pass -Major Risk 3K-07 - 3K-07 - 3K-07 354.38 186.69 354.38 179.25 350.00 25.114 Centre Distance Pass -Major Risk 3K-07 - 3K-07 - 3K-07 425.01 187.56 425.01 178.57 425.00 20.858 Clearance Factor Pass -Major Risk 3K-08 - 3K-O8 - 3K-08 255.30 212.62 255.30 206.42 250.00 34.303 Centre Distance Pass -Major Risk 3K-08 - 3K-08 - 3K-08 424.13 213.99 424.13 203.12 425.00 19.677 Clearance Factor Pass -Major Risk 3K-09 - 3K-09 - 3K-09 354.16 237.38 354.16 229.69 350.00 30.846 Centre Distance Pass -Major Risk 3K-09 - 3K-09 - 3K-09 423.55 238.33 423.55 229.09 425.00 25.793 Clearance Factor Pass -Major Risk 3K-09 - 3K-09A - 3K-09A 377.31 235.74 377.31 226.15 375.00 24.580 Centre Distance Pass -Major Risk 3K-09 - 3K-09A - 3K-09A 446.67 236.83 446.67 225.28 450.00 20.496 Clearance Factor Pass -Major Risk 3K-102 - 3K-102 - 3K-102 576.33 551.67 576.33 539.67 625.00 45.967 Centre Distance Pass -Major Risk 3K-102 - 3K-102 - 3K-102 635.59 552.09 635.59 539.17 700.00 42.723 Clearance Factor Pass -Major Risk 3K-102 - 3K-102L1 - 3K-102L1 576.33 551.67 576.33 539.67 625.00 45.967 Centre Distance Pass -Major Risk 3K-102 - 3K-102L1 - 3K-102L1 635.59 552.09 635.59 539.17 700.00 42.723 Clearance Factor Pass -Major Risk 3K-102 - 3K-102L1 PB1 - 3K-102L1 P61 576.33 551.67 576.33 539.67 625.00 45.967 Centre Distance Pass -Major Risk 3K-102 - 3K-102L1 P61 - 3K-102L1 P61 635.59 552.09 635.59 539.17 700.00 42.723 Clearance Factor Pass -Major Risk 3K-19 - 3K-19 - 3K-19 85.20 25.01 85.20 23.07 75.00 12.872 Centre Distance Pass -Major Risk 3K-19 - 3K-19 - 3K-19 110.20 25.16 110.20 22.72 100.00 .10.304 Clearance Factor Pass -Major Risk • 27 June, 2008 - 14:54 Page 2 of 6 COMPASS ConocoPhillips (Alaska) Inc. -Kup2 Ha-~~~BURTOrv Kuparuk River Unit Anticollision Report for Plan 3K-108 (E12) - 3K-108 (wp09) Trav. Cylinder North Proximity Scan on Current Survey Data (North Reference) Reference Design: Kuparuk 3K Pad -Plan 3K-108 (E12) - 3K-108 - 3K-108 (wp09) Scan Range: 0.00 to 13,117.70 ft. Measured Depth. Scan Radius is 1,507.77 ft . Clearance Factor cutoff is Unlimited. Max Ellipse Separation is Unlimited Measured Minimum @Measured Ellipse @Measured Clearance Summary Based on Site Name Depth Distance Depth Separation Depth Factor Minimum Separation Warning Comparison Well Name - Wellbore Name -Design (ft) (ft) (ft) (ft) ft 3K-19 - 3K-19 - Gyro(861) +IFR Projection 85.20 25.01 85.20 22.96 75.00 12.186 Centre Distance Pass -Major Risk 3K-19 - 3K-19 - Gyro(861) +IFR Projection 110.20 25.16 110.20 22.61 100.00 9.862 Clearance Factor Pass -Major Risk 3K-20 - 3K-20 - 3K-20 180.64 49.50 180.64 45.21 175.00 11.531 Centre Distance Pass -Major Risk 3K-20 - 3K-20 - 3K-20 576.58 53.79 576.58 41.12 575.00 4.245 Clearance Factor Pass -Major Risk 3K-22 - 3K-22 - 3K-22 992.85 86.96 992.85 69.46 1,025.00 4.968 Centre Distance Pass -Major Risk 3K-22 - 3K-22 - 3K-22 1,016.16 86.99 1,016.16 69.18 1,050.00 4.885 Clearance Factor Pass -Major Risk 3K-22 - 3K-22A - 3K-22A 992.85 86.96 992.85 69.46 1,025.00 4.968 Centre Distance Pass -Major Risk 3K-22 - 3K-22A - 3K-22A 1,016.16 86.99 1,016.16 69.18 1,050.00 4.885 Clearance Factor Pass -Major Risk 3K-23 - 3K-23 - 3K-23 372.63 123.69 372.63 116.51 375.00 17.233 Centre Distance Pass -Major Risk ~-~ 3K-23 - 3K-23 - 3K-23 444.71 124.36 444.71 115.81 450.00 14.552 Clearance Factor Pass -Major Risk 3K-24 - 3K-24 - 3K-24 467.63 147.02 467.63 137.99 475.00 16.285 Centre Distance Pass -Major Risk 3K-24 - 3K-24 - 3K-24 515.37 147.62 515.37 137.54 525.00 14.651 Clearance Factor Pass -Major Risk 3K-25 - 3K-25 - 3K-25 99.00 174.97 99.00 172.90 100.00 84.435 Centre Distance Pass -Major Risk ~„ 3K-25 - 3K-25 - 3K-25 419.19 176.67 419.19 168.65 425.00 22.027 Clearance Factor Pass -Major Risk 3K-26 - 3K-26 - 3K-26 371.84 199.11 371.84 191.95 375.00 27.795 Centre Distance Pass -Major Risk r,-,,, 3K-26 - 3K-26 - 3K-26 418.65 199.49 418.65 191.44 425.00 24.775 Clearance Factor Pass -Major Risk 3K-27 - 3K-27 - 3K-27 224.00 224.32 224.00 219.84 225.00 50.088 Centre Distance Pass -Major Risk 3K-27 - 3K-27 - 3K-27 348.31 225.22 348.31 218.39 350.00 33.016 Clearance Factor Pass -Major Risk e~ M ~ Plan 3K-108 (E12) - 3K-108 L1 - 3K-108 L1 (wp09) ~r IPA .„.,~ - Plan 3K-D8 - 3K-D8 - 3K-D8 wp01 1,067.54 84.01 1,067.54 63.81 1,025.00 4.158 Clearance Factor Pass -Major Risk Plan 3K-E10 - 3K-E10 - 3K-E10 wp01 1,684.23 76.44 1,684.23 44.13 1,575.00 2.366 Clearance Factor Pass -Major Risk Plan 3K-E8 - 3K-E8 - 3K-E8 wp02 982.18 86.03 982.18 66.70 950.00 4.452 Clearance Factor Pass -Major Risk Prelim: 3K-36 - 3K-36 - 3K-36 (wp01) 325.00 75.30 325.00 68.39 325.00 10.908 Centre Distance Pass -Major Risk Prelim: 3K-36 - 3K-36 - 3K-36 (wp01) 519.63 76.20 519.63 65.04 525.00 6.830 Clearance Factor Pass -Major Risk Prelim: 3K-37 - 3K-37 - 3K-37 (wp01) 298.50 12.50 298.50 5.73 300.00 1.848 Centre Distance Pass -Major Risk Prelim: 3K-37 - 3K-37 - 3K-37 (wp01) 373.33 12.76 373.33 4.37 375.00 1.521 Clearance Factor Pass -Major Risk Kuparuk 3R Pad 27 June, 2008 - 14:54 Page 3 of 6 COMPASS ConocoPhillips (Alaska) Inc. -Kup2 ~'"~~~..L~~~T~N Kuparuk River Unit Anticollision Report for Plan 3K-108 (E12) - 3K-108 (wp09) Survev tool program From (ft) 40.00 600.00 To (ft) 600.00 3K-108 (wp09) 13,117.24 3K-108 (wp09) Survey/Plan Survey Tool L J Ellipse error terms are correlated across survey tool tie-on points. Calculated ellipses incorporate surface errors. Separation is the actual distance between ellipsoids. Distance Between centres is the straight line distance between wellbore centres. Clearance Factor =Distance Between Profiles / (Distance Between Profiles -Ellipse Separation). '~ All station coordinates were calculated using the Minimum Curvature method. CB-GYRO-SS MWD+IFR-AK-CAZ-SC 27 June, 2008 - 14:54 Page 4 of 6 COMPASS ConocoPhillips (Alaska) Inc. -Kup2 HALLIBURTC~N Kuparuk River Unit Anticollision Report for Plan 3K-108 (E12) - 3K-108 (wpO9) Direction and Coordinates are relative to True North Reference. Vertical Depths are relative to 74.3' (34.3'+40) @ 74.30ft. Northing and Easting are relative to Plan 3K-108 (E12). Coordinate System is US State Plane 1983, Alaska Zone 4. Central Meridian is -150.00°, Grid Convergence at Surface is: 0.22 °. ^~ ~..~ Ladder Plot ~-- Pla IJ•124, Plan IJ•124, IJ-134 (wp05)V4 .~--3K• 1,3K-01,3K•01 Vi 3K- 2,3K-02,3K•02 VI 3K• 3, 3K•03, 3K•03 V1 3K- 4, 3K•04, 3K•04 V1 ~ 3K• 5, 3K•05, 3K-D3 V1 ~ 3 K• 8, 3 K•06, 3K•06 VI O 3K- 7,3K•07,3K•07V1 t!> c~- 3 K- 8, 3 K•08, 3K-08 VI ~ O 3 K- 3K• 9, 3 K•09. 3K-09 V4 9, 3K-09 A, 3K•09A V1 ~L] 3K- 02, 3K-102, 3K-102 VO Q 3K- 02,3K•102L1,3K•102L1 VO . N 3K• 02, 3K-1D2L1 P81,3K•102LiP81 VO 3K• 9, 3K•19, 3K•19 V8 O L ~, 3K• 9, 3K•19, Glrtv(881)+ I rolection C N 3K• 0, 3K•2D, 3K-20 V14 (~ 3K• 2,3K•22,3K-22 V3 ~ 3 K• 2, 3 K-22 A, 3K•22A V1 ~ 3K- 3, 3K-23, 3K•23 V2 ~ O 3K- 4, 3K-24, 3K•24 V12 (, 3K- 5,3K-25,3K-25 V1 3K• 8,3K-26,3K-26V1 3K- 7, 3K-27, 3K•27 V3 Pla 3K-1D8 (E12),3K-108 L1,3K-1 D8 L1 (wp09)V8 Q ~~JQQ ~JO OO ~~JOO ~QQQQ 12~jQQ -~„ -- Pla 3 K-08, 3K-D8, 3K-D8 wpD 1 V4 M ~;;m Pla easured Depth (~~00 ftlin) `~ 3K-E10,3K-E10, 3K-E10 wp01 V5 ~ Pla 3K-E8, 3K-E8, 3K-E8 wp02 V8 27 June, 2008 - 14:54 Page 5 of 6 COMPASS HALLIBURTC3N ConocoPhillips (Alaska) Inc. -Kup2 Kuparuk River Unit Anticollision Report for Plan 3K-108 (E12) - 3K-108 (wp09) wa.s.J ^~~ ..~~ ~~ t Clearance Factor Plot: Measured Depth versus Separation(Clearance) Factor fo AO 8ZS _ 7S0 .S 6~5 0 U m Q SAO io `m Q. ~ 33S 2S0 I~S oAa Measured Depth (2500 ftAn) ~~ "~' 116, 10.118, Plan M1 Vi ~ 1J•124, Plan 1J•i24, iJ-134 (wp05)V4 )1, 3K01,3K-01 Vi )2, 3K-02, 3K-02 V1 13, 3K•03, 3K-03 V1 )4, 3K•04, 3K-04 V1 I5, 3K•05,3K•05 V1 I8, 3K•08, 3K•OB Vt I7, 3K•D7,3K•07 Vi 18, 3K-08, 3K•08 V1 )9, 3K-09, 3K-09 V4 )9, 3K-09A 3K-09AV1 102, 3K•102, 3K•102 VO 102, 3K-102 Li, 3K-102 Li fro 102,3K-102L1PB1,3K-102L1P81 bU 19, 3K-19,3K-19 VB 19, 3K-19, Gyro(881)+ IfR Projection Vl 20, 3K-20, 3K-20 V14 22, 3K•22,3K-22 V3 22, 3K•22fL 3K-22AVi 23, 3K-23, 3K•23 V2 24, 3K-24, 3K-24 V12 25, 3K-25, 3K•25 Vt 26, 3K-28, 3K•38 V1 27, 3K•27, 3K-27 V2 i 3K-108 (Ei2), 3K-108 L1, 3K-108 L1 (urp09) V8 i 3K-DB, 3K-08, 3K D8 wpDi V4 i 3K-E1 D, 3K-E10, 3K-E10 wpD1 V5 i 3K-E8, 3K-E8, 3K-E8 wp02 ~fl Iim:3K-30, 3K-38, 3K-30 (wpD1) VO 27 June, 2008 - 14.54 Page 6 of 6 COMPASS 3K-108~rillin~ Hazards S+~mmary (SEE WELL PLAN AND ATTACHMENTS FOR DETAILED DISCUSSION OF THESE RISKS) 16" Open Hole / 13-3/8" Casing Interval Hazard Risk Level Miti anon Strate Broach of Conductor Low Monitor cellar continuously during interval. Gas Hydrates Moderate Control drill, Reduced pump rates, Reduced drilling fluid temperatures, Additions of Lecithin Running Sands and Gravels Low Maintain planned mud parameters, Increase mud weight, use weighted sweeps. Hole swabbing on trips Moderate Trip speeds, proper hole filling (use of trip sheets), pumping out 12-1/4" Open Hole / 9-5/8" Casing Interval Hazard Risk Level Miti anon Strate Running Sands and Gravels Low Maintain planned mud parameters, Increase mud weight, use weighted sweeps. Gas Hydrates Low Control drill, reduced pump rates, reduced drilling fluid temperatures, additions of Driltreat. Stuck Pipe Low Good hole cleaning, pre-treatment with lost circulation material, stabilized BHA, decreased mud weight Abnormal Reservoir Pressure Low BOP training and drills, increased mud weight. Lost circulation Moderate Reduced pump rates, mud rheology, LCM Hole swabbing on trips Moderate Trip speeds, proper hole filling (use of trip sheets), pumping out 6-3/4" Open Hole / 3-1/2" Liner Interval Hazard Risk Level Miti anon Strate Abnormal Reservoir Low Stripping drills, shut-in drills, increased mud weight. Pressure Stuck Pipe Low Good hole cleaning aided by circulation sub and cuttings bed impellers, PWD tools monitoring and analysis, decreased mud weight Lost Circulation Moderate Reduced pump rates, mud rheology, LCM program, additional fluid stored on location during completion run. Hole Swabbing on Trips Moderate Trip speeds, proper hole filling (use of trip sheets),pumping out or backreaming {"'` ~ 3K-108 Drilling Hazards Summary.doc '~ ~ 1 ~ ± p, 8/11/2008137:56 PM Drill String Valves To be tested to 250 psi and 3,000 psi at initial installation and every 14 days thereafter. 13-5 Annular To be tested to 250 psi and 1,500 psi at initial installation and every 14 days thereafter. 13-5 Double Ram Upper Rams: 3-'/z' to 6" variables To be tested to 250 psi and 3,000 psi at initial installation and every 14 days thereafter. For Dual 3-'/2" completion operations, 3-'/2" dual rams to be installed and tested to 250 psi and 3,000 psi prior to completion run Lower Rams: Blind To be tested to 250 psi and 3,000 psi at initial installation and every 14 days thereafter. Choke and Kill Line Valves ~- To be tested to 250 psi and 3,000 psi at initial installation and every 14 days thereafter. 13-5 Single Ram Rams to fit Intermediate Casing: 7-5/8" or 9-5/8" To be tested to 250 psi and 3,000 psi only before ~_ running casing. For Dual 3-'/z" completion operations, 3-'/z" dual rams to be installed and tested to 250 psi and 3,000 psi prior to completion run ~ Wellhead Valves tested to 3,000 psi upon assembly 13-5 BOP 3K diagram. vsd ConocOPhillips Doyon 15 West Sak 3 ksi Sheet 1 of 1 BOP Configuration prepared by Dennis /L 0,8 Alaska IGWAL Rig: Doyon 15 Location: West Sak Client: ConocoPhillips Alaska, Inc. Revision Date: 7/10/2008 Prepared by: Maureen Torrie Location: Anchorage, AK Phone: (907) 265-6336 Mobile: (907) 952-0445 email: mtorrie@slb.com < TOC at Surtace Previou s Csg. < 20", 94# casing at 120' MD I ~, < Base of Permafrost at 1,892' MD (1,655' TVD) _ < Top of Tail at 2,500' MD < 13 3/8", 68.0# casing in 16" OH TD at 3,300' MD (2,213' TVD) * Mark of Schlumberger ~: CemCADE Preliminary Job Design 13 3/8" Surface Preliminary Job Design based on limited input data. For estimate purposes only. Schlumberger Volume Calculations and Cement Systems Volumes are based on 250% excess in the permafrost and 35% excess below the permafrost. The top of the tail slurry is designed to be at 2,500' MD. Lead Slurry Minimum pump time: 310 min. (pump time plus 120 min.) ARCTICSET Lite @ 10.7 ppg - 4.45 ft3/sk 1.0190 ft3/ft x (80') x 1.00 (no excess) = 81.5 ft3 0.4206 ft3/ft x (1892' - 80') x 3.50 (250% excess) = 2667.4 ft3 0.4206 ft3/ft x (2500' - 1892') x 1.35 (35% excess) = 345.2 ft3 81.5 ft3 + 2667.4 ft3+ 345.2 ft3 = 3094.1 ft3 3094.1 ft3 / 4.45 ft3/sk = 695.3 sks Round up to 700 sks Have 320 sks of additional Lead on location for Top Out stage, if necessary. Tail Slurry Minimum pump time: 220 min. (pump time plus 120 min.) DeepCRETE @ 12.0 ppg - 2.46 ft3/sk 0.4206 ft3/ft x (3300' - 2500') x 1.35 (35% excess) = 454.2 ft3 0.8315 ft3/ft x 80' (Shoe Joint) = 66.5 ft3 454.2 ft3 + 66.5 ft3 = 520.7 ft3 520.7 ft3/ 2.46 ft3/sk = 211.7 sks Round up to 220 sks BHST = 42~, Estimated BHCT = 66~. (BHST calculated using a gradient of 2.2`F/100 ft. below the permafrost) PUMP SCHEDULE Pump Rate Stage Stage Time Cumulative Stage Volume Time (bpm) bbl) (min) (min) CW 100 5 75 15.0 15.0 Drop Bottom Plug 15.0 30.0 MudPUSH II 6 75 12.5 42.5 Lead Slurry 6 555 92.5 135.0 Tail Slurry 7 96 13.7 148.7 Drop Top Plug 5.0 153.7 Water 5 20 4.0 157.7 Switch to Rig Pum s 5.0 162.7 Displacement 7 437 62.4 225.1 Slow Rate 3 20 6.7 231.8 MUD REMOVAL Recommended Mud Properties: 9 ppg, Pv < 15, TY < 15. As thin and light as possible to aid in mud removal during cementing. Spacer Properties: 10.5 ppg MudPUSH" II, Pv = 17-21, TY = 20-25 Centralizers: Recommend 1 per joint across zones of interest, and 2 per joint for bottom 8 joints for proper cement placement. ~,.~i~ ~~ • Rig: Doyon 15 Location: West Sak Client: ConocoPhillips Alaska, Inc. Revision Date: 8/5/2008 Prepared by: Maureen Torrie Location: Anchorage, AK Phone: (907) 265-6336 Mobile: (907) 952-0445 email: mtorrie@slb.com Previous Csg. < 13 3/8", 68.0# casing at 3,300' MD < Top of Tail at 4,418' MD < 9 5/8", 40.0# casing in 12 1/4" OH ~; ~~ TD at 7,888' MD (3,534' TVD) ~: CemCADE Preliminary Job Design 9.625" Longstrin Preliminary Job Design based on limited input data. For estimate purposes only. Schlumberger Volume Calculations and Cement Systems Volumes are based on 25% excess. Tail slurry is designed for 3270' MD above the intermediate casing shoe. Tail Slurry Minimum thickening time: 270 min. (Pump time plus 120 min.) DeepCRETE @ 12.5 ppg - 2.25 ft3/ft 0.3132 ft3/ft x 3270' x 1.25 (25% excess) = 1280.2 ft3 0.4341 ft3/ft x 80' (Shoe Joint) = 34.7 ft3 1280.2 ft3+34.7 ft3= 1314.9 ft3 1314.9 ft3/ 2.25 ft3/sk = 584.4 sks Round up to 590 sks BHST = 71 ~, Estimated BHCT = 56~. (BHST calculated using a gradient of 2.2/100 ft. below the permafrost) PUMP SCHEDULE Pump Stage Stage Cumulative Rate Volume Time Time Stage (bpm) (bbl) (min) (min) Comments CW100 5 50 10.0 10.0 Start Pumping Wash Drop Bottom Plug 10.0 20.0 MudPUSH I I 5 50 10.0 30.0 Start Pumping Spacer Tail Slurry 5 236 47.2 77.2 Mix and Pump Tail Slurry Drop Top Plug 5.0 82.2 Pump Water 5 20 4.0 86.2 Switch to Rig Pump 5.0 91.2 Displacement 7 548 78.3 169.5 Start Displacement Slow Rate 3 20 6.7 176.2 Slow Rate to Bump Plug MUD REMOVAL Recommended Mud Properties: 8.9 ppg, Pv < 15, TY < 22. As thin and light as possible to aid in mud removal during cementing. Spacer Properties: 11.0 ppg MudPUSH" II, Pv = 19-22, TY = 22-29 Centralizers: Recommend 2 per joint across zones of interest for proper cement placement. OR161NAL ~^ V ' Insulated Conductor: 20" 94# K-55x34" 0.312 WT +l- 80' ConocoPhillips 2876"DS Nipple 2008 West Sak Dual Injector System 2.876"DSNlpple with Level 5 Rotating self-Aligning Multilateral (RAMT"") System GLM, Cameo, 3-'/." x 1" KBG2-9 GLM, Cameo,}%^z1"KBG2-9 West Sak 13-318" Casing Shoe 3 K-108 3300' MD, 2213' ND Dual Tubing Strings Rotational Alignment Bub 3-'/:" 9.3#, L-80, 2.992" ID, 2.867" Drift 0® 2.612" DB Nipple 3-Y:" z 9-618" GT Dual Packer _ 3-•r,° x 3-%•• x s-sra•• Deal seal / Motlule for RAM Hangar / 7" X 9-618" RAM Hanger D-Sand Casing Exit 7093' MD, 3459' ND (80 deg) 'D' Sand Lateral 3-%" 9.3# Llner with SLHT connectlons 4%" x 9.618" RAM Seal Bore Dlverter (SB0) for Dual Seal Motlule 3-%" 72.6# IBTM Tubing 7" X 9-618" MLZ%P Llner Hangar Packer Sealbora ReceptacM 0.76" ID MLHR Production Anchor Seal Assembly 4.76" Seal OD 3.876" ID 9-518" Casing Shoe, 40:0#, L-80 BTC 7688' MD, 3533' ND sBker oa •rDGIS Casing Shoe 13117' MD, 3675' ND -- ®~®® As Planned Lateral Lengths D-Sand 6021' B Sand 5430' Total Drilled Footage 19139' Casing Shoe 13114' MD, 3629' ND 'B' Sand Lateral 3-Y." 9.3# Llner wl[h SLHT connections ConocoPhillips ConocoPhillips Alaska, Inc. Kuparuk River Unit Kuparuk 3K Pad _~ } ; ~ ~,. Plan: 3K-108 (wp09) ~ 1/4 Mile Pool Scan Sperry Drilling Services July 8, 2008 HALLIBiURTON Grilling and Formation Evaluation n U Closest in POOL .,._... ~°~" op+"'~ Closest A roach: Reference Well: 3K-10 8 w 09 Plan Offset Well: 3K-20 Coords. - Coords. - ASP ASP 3-D ctr-ctr Meas. Subsea N(+)/S(-) View VS Meas. Subsea N(+)/S(-) View VS Distance. De th Incl. An le TRUE Azi. ND E + /W(- 90° Comments De th Incl. An le TRUE Azi. ND E +)/W - 90° Comments POOL Min Distance POOL Min Distance (1578.08 ft) in POOL (1578.08 ft) in POOL (7093.71 - 13114.13 (7093.71 - 13114.13 MD) to 3K-108 L1 MD) to 3K-20 (3365 - (wp09) Plan (3365 - 1578.08 E:i<>s..;~. ,~ 7650 90.05 90.01 3394.49 6011734.3 1673926 4601.58 3575 NDss) 6597.37 63.05 68.16 3584.99 6010167.8 1673919 4588.86 3575 NDss) Closest A roach: Reference Well : 3K-10 8 L1 w 09 Plan Offset Well: 3K-102L1 Coords. - Coords. - ASP ASP 3-D ctr-ctr Meas. Subsea N(+)/S(-) View VS Meas. Subsea N(+)/S(-) View VS Distance. Depth Incl. An le TRUE Azi. ND E + /W - 90° Comments Depth Incl. An le TRUE Azi. ND E +)/W - 90° Comments POOL Min Distance POOL Min Distance (1175.29 ft) in POOL (1175.29 ft) in POOL (7093.71 - 13114.13 (7093.71 - 13114.13 MD) to 3K-108 L1 MD) to 3K-102L1 (wp09) Plan (3365 - ' 1175.29 13000 86.65 100.34 3548.271 6011097.9 1679214 9887.147 (3365 - 3575 TVDss) 14081 89.19 97.42 3422.034 6009944.5 1679026 9695.162 3575 NDss) Closest A roach: Reference Well : 3K-10 8 w 09 Plan Offset Weil: 3K-102 Coords. - Coords. - ASP ASP 3-D ctr-ctr Meas. Subsea N(+)IS(-) View VS Meas. Subsea N(+)/S(-) View VS Distance. Depth Incl. An le TRUE Azi. ND E + /W - 90° Comments Depth Incl. An le TRUE Azi. ND E + /W - 90° Comments POOL Min Distance POOL Min Distance (1179.35 ft) in POOL (1179.35 ft) in POOL (7093.71 - 13114.13 (7093.71 - 13114.13 MD) to 3K-108 L1 MD) to 3K-102 (3365 (wp09) Plan (3365 - 1179.35 12875 86.65 100.34 3540.97 6011119.8 1679091 9764.39 3575 NDss) 13939.23 86.88 98.8 3575.91 6009959.5 1678883 9555.1 3575 NDss) POOL Summary Template1.xls 7/8/2008 1:32 PM r Project: Kuparuk River Unit Site: Kuparuk 3K Pad Well: Plan 3K-108 (E12) Wellbore: 3K-108 Plan: 3K-108 (wp09) 6171 5829 5486 5143 4800 4457 4114 3771 ~86 43 ,.o~s.~ ' q00 1371 686 343 0 -343 1371 1714 REFERENCE INFORMATION Coordinate (N/E) Reference: Well Plan 3K-108 (E12), True North Vertical (ND) Reference: Mean Sea Level Measured Depth Reference: 74.3' (34.3'+40) @ 74.30fl Calculation Method: Minimum Curvature WELL DETAILS: Plao 3K-103 (F.12) Ground Lcvel: 34.30 +N/-S +E/-W Northing Fasting Latittude Longitude 0.00 U.00 6008218.39 1669337.7E 70° 26' 2.106 N49° 45' 51.202 W stet a c >° a 7 T M Azimuths to True North Magnetic North: 23.08° Magnetic Field Strength: 57623.3snT Dip Angle: 80.88° Dale: 10/16/2007 Model: BGGM2007 -686 -343 -0 343 686 L029 1371 1714 2057 2400 2743 3086 3429 3771 4114 4457 4800 5143 5486 5829 6171 (;514 6857 7200 7543 7886 8229 8571 8914 9257 9600 9943 1(128(; 10629 10971 11314 West(-)/East(+) (1200 ft/in) ~"~ ConocoPhillips Project: Kuparuk River Unit • Site: Kuparuk 3K Pad Well: Plan 3K-108 (E12) Wellbore: 3K-108 Design: 3K-108 (wp09) - , .....a..... .-. ....-..-...._....._...,.._........... I - ..~ ,...d-.__....-..~.., 3K-102L1----- - - 3K-10 s ~~~(v • • ~ i ~1 Paui FC. Wham®n Staff iLandrvean P.O. Box 100360 -Suite ATO 1482 ''~ 11 Anchorage, Alaska 99510-0360 Phone (907) 263-4076 Fax (907) 263-4966 Alaska, InC. Paul.K.Wharton@conocophillips.com August 4, 2008 .~ vi 'f a Certl led Mai Return Receipt Requested ~! Chairman Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage, Alaska 99501 Re: Request for Exception to 20 AAC 25.055 3K-108 and 3K-108L1 wells Kuparuk River Unit Dear Chairman: Reference is made to ConocoPhillips Alaska, Inc.'s ("ConocoPhillips") application for a spacing exception for the KRU 3K-108 well and 3K-108 L1 well dated July 22, 2008. Filed herewith is the non-objection of BP Exploration ("Alaska") Inc., the owner of the offsetting tract (ADL 25517). If you have any questions or require anything further from ConocoPhillips in order to process the application, please let me know. Very truly yours, U Grp ~ ~~.~~ Paul K. Wharton Staff Landman cc: D.J. (Don) Dunham G.C. (Glenn) Frederick R.L. (Sonny) Rix Neil Spenceley R.L. Skillern Chris Wyatt, chris.wyatt ,~bp.com • ~~a~8 K. l~9~ar~®~ Staff Landa~ara ,. ~~i Alaska, Inc. July 22, 2008 D.J. Dunham BP Exploration (Alaska) Inc. 900 E. Benson Boulevard P.O. Box 196612 (MB4-2) Anchorage, AK 99519-6612 Re: 3K-108 and 3K-108L1 Well Spacing Exception Dear Don: P.O. Box 100360 -Suite ATO 1482 Anchorage, Alaska 99510-0360 Phone (907) 263-4076 Fax (907) 263-4966 Paul. K. Wharton@conocophillips.com As you know ConocoPhillips Alaska Inc. ("ConocoPhillips") and the other Kuparuk River Unit Working Interest Owners ("KRU WIGS") are planning to drill the 3K-108 and the lateral 3K-108 L1 (collectively hereinafter the "Well") to the West Sak interval within KRU Tract 4, ADL 25519. The Well is planned to be drilled as an injector from the 3K pad generally north and east towards the boundary with the Milne Point Unit ("MPU"), tract ADL 25517. In order to allow the Well to cross a fault and provide water injection support to the toe of 3K-102 the Well is planned to be drilled within 238 feet of the boundary with MPU lease ADL 25517. Because of its proximity to the MPU, the Well wilt require a well spacing exception from the Alaska Oil and Gas Conservation Commission ("AOGCC"). ConocoPhillips on its own behalf and on behalf of KRU WIOs has filed of even date herewith the attached request for a well spacing exception with the AOGCC. ConocoPhillips requests that BP indicate its non-objection as MPU owner to the attached well spacing exception. Please execute this letter in the space provided below and return to the undersigned for filing with the AOGCC. Thank you for your consideration in this regard and please call the undersigned at • 3K-108 well spacing exception non-objection July 22, 2008 Page 2 263-4076 with any questions. Very truly yours, ~~~ %~ ~[~~u~~ Paul K. Wharton Staff Landman BP Exploration Alaska, Inc. hereby indicates its non-objection to allowing the 31<-108 and 3K-108 L1 wells described above to be drilled within 238' more or less of the boundary of the Milne Point Unit lease ADL 25517. ~~~ ~ y' ~, 'I i~t,~ Name: ~ . ~ ~ l~ ~ U Title: Y r~ ~ ' n cc: Glenn Frederick Craig Haymes Chris Wyatt (Room R.L. Skillern Neil Spenceley 1341) chris.wyatt(cr~.bp.com Date: Z BOPE for dual tubing comple~ Page 1 of ~-. Maunder, Thomas E (DOA) From: Hartwig, Dennis D [Dennis.D.Hartwig@conocophillips.com] Sent: Monday, June 09, 2008 4:30 PM To: Maunder, Thomas E (DOA) Subject: RE: BOPE for dual tubing completion The initial completion will be run with Doyon 15 and subsequent workovers probably by Nordic 3 Dennis From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov] Sent: Monday, June 09, 2008 4:26 PM To: Hartwig, Dennis D Subject: RE: BOPE for dual tubing completion Thanks Dennis. I forgot to ask, what rig. I presume Nordic 3. Tom From: Hartwig, Dennis D [mailto:Dennis.D.Hartwig@conocophillips.com] Sent: Monday, June 09, 2008 4:00 PM To: Maunder, Thomas E (DOA) Subject: RE: BOPE for dual tubing completion Tom, 3K-103 and 3K-108 are the primary candidates at this time -both are planned as injectors. No plans as yet to include the dual completion design with producers. Work involved will be both the initial completion and workover. With the complex directional profile of the well and tight clearances it would be unlikely that we could land the second string if run they are run individually. The basis of design for the dual completion is thus; • allow better access/intervention to the individual laterals . isolate the west sak B and D-sands to allow for vertical conformance and avoid breakthrough events from producer to injector. • Utilize passive flow control devices in the laterals (ResInject screens) to gain lateral conformance and also avoid breakthrough events. Thanks Dennis Hartwig Drilling Engineer Greater Kuparuk Area ConocoPhillips Alaska - ATO-1592 Office :907-265-6862 Cell :907-980-1433 Fax :907-265-1535 From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov] Sent: Monday, June 09, 2008 3:17 PM To: Hartwig, Dennis D 2/5/2009 BOPE for dual tubing compl~n Subject: RE: BOPE for dual tubing completion Page 2 of ~- . Dennis, Will this work be initial completion or just workover? Can you identify what wells might be candidates? Are they producers, injectors or could a given well have production in one string and injection in the other? Thanks in advance, Tom Maunder, PE AOGCC From: Hartwig, Dennis D [mailto:Dennis.D.Hartwig@conocophillips.com] Sent: Monday, June 09, 2008 3:13 PM To: Maunder, Thomas E (DOA) Subject: BOPE for dual tubing completion Tom, Upcoming 3K West Sak work (3rd quarter of 08) will involve dua13-1/2" tubing completions where we will run both strings simultaneously. AOGCC BOPE requirements for drilling operations with an MPSP of less than 3000psi require at least three preventers which include: • Pipe rams • Blind rams • Annular For our dual tubing case, where the annular will most probably not provide a barrier, will another set of dual rams be acceptable in place of the annular? In that case we would run the following; Top cavity - Dua13-1/2" rams Middle cavity -Blind rams Lower cavity - Dua13-1/2" rams Thank-you Dennis Hartwig Drilling Engineer Greater Kuparuk Area ConocoPhillips Alaska - ATO-1592 Office :907-265-6862 2/5/2009 6050000 6000000 5950000 5900000 5850000 EPA Aquifer Exemption - 40 CFR 147.102 (b)(3) 400000 500000 600000 700000 800000 Alaska Department of Natural Resources Land Administration System Page 1 of~ ~ • . ,;: ~ f ~..:~- _~r;, ~.~ ., _- ~ t ~;i - F' .r ~asdR~`s Sa~t~cf~State Cabins a~tt>I~1 R~5+D41P~5 Alaska DNR Case summary File Type: ADL File Number: 25519 ~ Printable Case Fife_$ummary See Township, Range, Section and Acreage? Yes ~> No New Search LAS Menu ~ Case Abstract ~ Case Detail ~ Land Abstract ,, File: ADL 2~~19 '~~~~'s' Search for Status Plat Updates .=~~ of 08%1i''~'OOS Customer: 000106346 CQNOCOPHILLIPS ALASKA, INC. ATTENTION: LAND MANAGER PO BOX 100360 ANCHORAGE AK 995100360 Case Type: 78~k OIL & GAS LEASE COMP DNR Unit: 780 OTL AND GAS File Location: DOG DIV OiL AND GAS Case Status: 35 ISSUED 'Status Date: 0 I /25/1965 Total Acres: 2560.000 Date Initiated: 11/02/1964 Office ofprimafyResponsibility_ DOG D1V OIL AND GAS Last Transaction Date: 12/0712005 Case Subtype: ~~ NORTH SLOPE Last Transaction: DR DOCUMENT RECORDED Meridicrr~: Li Tcrn~fls~{rr~~: 013N IZ~m,L=c.~ 009E Sectzr~n: ~5 Se~~~iu1t ~ lc~t~i~~~~: 641) Search Plats Meridian: t_! T~nrrze{liJ~: U I iN 1:~r»,~~: 00~>I : .~'rcti~»t.~ ?6 S'c'%11071 , Icres: 640 M'YI(~I[UL' ~_ ~llll'n.S~ll~7: ~~ ] _~N l1[ln~~E': On~~E, ~('CI1lNl.' i t ~~~'~ /l(~ll .' ~C"Yf,'S: 6~1~) ~~Nr1c~IcU1.~ ~_' ~ON'nS{!1~): ~) ~ i~] [~((/l~~TC'.' (~~)~)f; ~~('CIIUJl.' ~6 ~ti~~'Ch(~71 : 1[_'rC'.~': 6~~~ LegaE llescription 11-OZ-196 ~~ * * SALE NOTICE LEGAL DESCRIPTION * ~` U-3-1-16 ALI SECTION 25. TI3N, R9E, UM 6=t0 ALL SECTION?6, " " " 6;~0 ALL SECTION 3~. " " " 6-~0 ALL SGCTI(~N 36. " " " 6-~0 CONTAINING 2. ~ 60 ACRES, MORE OR LESS http://www.dnr.state. ak.us/las/Case_Summary. cfm?FileType=ADL&FileNumber=25 519&... 8/ 13/2008 TRANSMITTAL LETTER CHECKLIST WELL NAME _ ,~.~,C~ .~j~- fQ~ PTD# os70~~,,31,~~ Developmeitt~ / Service Exploratory Stratigraphic Test Non-Conventional Well FIELD: ~t~i~A.e!/~ ~'ii~F..,,L POOL: w~~'T ~'A,r ~~ Circle Appropriate Letter /Paragraphs to be Included in Transmittal Letter CHECK ADD-ONS WHAT (OPTIONS) TEXT FOR APPROVAL LETTER APPLIES MULTI LATERAL The permit is for a new wellbore segment of existing well (If last two digits in API number are permit No. . AP[ No. 50- - between 60-69) Production should continue to be reported as a function of the original API number stated above. PILOT HOLE In acconiance with 20 AAC 25.005(f), alt records, data and logs acquired for the pilot hole must be clearly differentiated in both well name ( PH) and AP[ 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 contingept upon issuance of a conservation order approving a spacing exception. _ C,oracp ~ ~~ \~ p ~, assumes the liability ofany protest to the spacing exception that may occur. DRY DITCH Alf dry ditch sample sets submitted to the Commission must be in SAMPLE no greater than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals throu tar et zones. Non-Conventional please note the following special condition of this permit: Well production or production testing of coal bed methane is not allowed for (name of wetD until after (Comoanv Name) has designed and implemented a water well testing program to provide baseline data on water quality and quantity.. (Comoanv Name) must contact the Commission to obtain advance approval of such water well testing ro Rev: 1!112008 WELL PERMIT CHECKLIST Field & Pool KUPARUK RIVER, WEST SAKOIL -490150 Well Name: KUPARUK RIV U WSAK 3K-108 Program SER Weil bore seg ^ PTD#:2081300 Company CONOCOPHILLIPS ALASKA INC Initial Classlfype SER 1 PEND GeoArea 890 Unit 11160 OnlOff Shore ~__ Annular Disposal [' Administratlon 1 Pe[mitfee attached- - - - - - - - - - - - - - - - - - - - - - NA - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - -- - -- - Yes - - -- -- - -- - -- - - ----- - -- -- - - --- -- 2 -Lease number appropnate____________________ ___ 3 Uniqueweltnameandnumbe[---- -- - --- --- -- - -- - Yes- - - -- - --- --- - -- -- - -- -- - - - - -- --- - -- --- -- ------ Yes - - - - - ---- - - ---- -- --- --- - - ---- 4 Welliecatedina_detinedpooi_-_-___------------------ 5 Well locatedPtaperdistance_f[omdrillinguniiboundary----------------------Yes---------------- ----- - -- - - - -- -- -- - - - -- -- --- -- - 6 Well located Proper distance from otherwells- - - - - - - - - - - - - - - -Yes - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - _ .. Yes 2560 acres.- - - - -- --- -- -- -- -- - - -- -- --- ------ - 9 10 11 Appr Date 12 ACS 811312008 14 15 16 17 Engineering 18 19 20 21 22 26 27 Appr Date 26 TEM 811312008 29 .~ 31 32 33 34 Geology 35 36 Appr Date 37 ACS 6!1312008 38 39 Sufficient acreage available In dnihng unrt- - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - If deviatsd~ is weilbo_re Plat_included - - - - - - - - - - - - - - - -Yes - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - Opetator oniyaffected party- - - - - - - - - - - - - - - - - - - - - - - - - - - - - -~0- - - - _ BP is opetatar of the Mfine Point Leases, LeKer received from BP with their apRrovai_fotwell.- _ _ _ - _ _ _ _ _ _ _ _ Operator bas.aPRroRrlate bond in_force - - - - - - - - - - - - - - - - - - - - - - Yes - - - - - Blanket Q2r~ # 59-52Q180• - - - - - - - - - - - - - - - - - - - - - - - - - - - - Permitcanbets9UeSJwlthoutCOnserYation4fder- - -- -- -- '- --- - - -Ko - - ------ -- -- - - -- ------ --------- -- -- -- ---- -- -- -- - Pe[mitcanba issued withoutadminiattative_aPRroval------------------------- Y~ --- - -- -- ---- - -- - -- --- -- --- -- --- --- -- - ----- --- - Canpe~itpeapRrovedbefors15-daywait-- - --- -- -- ------- _- Yes -- -- - -- ------ - -- -- -- -- -- -- - -- - --- -- - - --- -- - elllocated witbinarea and_slrata authorized by_lnjection 0rde[ # (put 10# in.comments)_(FOr_ W--- Yes _ _ _ _ . _ _ AIO-2B, - - _ _ - _ _ _ _ _ _ . - _ _ _ _ _ _ - _ _ _ - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - Aliwegs-v~ithin114_mileaieaof[evievuidentifiad(Fo[9etvicewelionly)_______________ Yes--_. _____.--.------------------- -- ----- --- ~- - -- -- --- -- Pre-produced inle~or; duration of Pre production less than 3 montbs_ (For service welt only) _ - NA - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - ~ - - - - - - - - - - - - - - - - - - Ptonconven, ga .c9nforms So AS$1,05.030(1.1.A)~(1.2.A-D) - - - - - - - - - - - - -KA- - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - Conductorstring.provlded---- - - -- - - -- ---- -- -- -- Yes-- - NA ----- -- - -- - -- --- -- ----- -- -- ---- - --- - --- AI(aquiferaexempted.40CFR_147.1Q2_(b~(~)•----------------------------------- ---- SurfacecasingRroteetsan known USDWS.__.-___--.------------- - -- -- -- --- CMT-voladequateto circulate onconductor8surfcs g-- - - --- -- -- -- - Yes__- - -------------------------.-------- -- ------ -- - - - -- --- - voladequate torte-in long string to surf csg- - - - - - - - - - - - - CMT K0- - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - _ C~IT_will cavar_aJlknown_productiya6orizons------------------------------ ~0- --- ---Sereen-liner_completionplanned,_______.____------------- -- - - - - -- CasingdesignsadequatefotG,T 13&_pe_rmafrost - ---- - -- -- - Yes- Yes -------- - - - ----- --- -- -- --- - - -- --- -- ---- - Rig equipped with steel pits. No_raserve pit planned._ AI!waste_to aPRroved disRosal weli(s)~ - - _ - _ _ _ - - . _ - - Adequate tankage_or reserve Pit - - - - - - - - - - - - - - - - - - - - - - - - - - - _ _ _ . _ - . Ifa_ra~dtili,has-a 10.403fQrabandonmentheenaRP-roved-------------------- - NA----- Yes ------------------------- -------- -- - - - - -- -- --- -- Proximity analysis perfo[med. T[aveung cylinder path calculated, Gyros likey-in surface hole, _ - - . _ - _ _ _ _ . _ Adequate wehbore separationproposed- - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - _ _ _ - - _ If diverterre4uired,doesitmeetregulations- --- - - -- - - -- -- Yes-- Yes --- -- - - - -- -- ---------- -- --- - ---------------- Maximum expected fomlafion pressure 9,0_EMW.. MW planned uR to 9,5_ppg in-1225" bole and 92_ppg In-zone. - Drilling flujdprogram schematic & equip listadequate_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ - BOP1=s,-do they meet regulation - - - - - - - - - - - - - - - - BQPI=_press rating appropriate; test to_(put psig in comments)_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ -Yes - _ Yes _ - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - . _ . - MASP calculated at 1336 psi. 5K stack arrangement vflth csg [erns in lower sat. 3000_psi BOP test-planned. _ _ - Choke_manif4ld COmRliaswlAPI_RP-53 (May 84) - - - - - - - - - - - - - -Yes - No - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - drilled wfth 3K-103 to-production casingpoint. Ope[atiQns-resumed after $K-1 Q3_finishad_ _ . _ vVell will be "batch" Work vnh occu[ withoutop~ration shutdown_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ - _ _ _ tJo - _ _ _ _ repoded in $K W$ production, tt2S may be present in lift gas and Ml. _ Rig has_ sensors and alarms. _ _ 1125 is npt is presence of H2S gas probable _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Mechan'lcai condition of wells within AQR verified (For service well gniy) _ _ _ _ _ _ __ _ _ _ _ _ _ - _ _ _Yes _ _ - _ _ - _ - _ _ _ 1 proximate Kuraruk weU has surface casing set below WS._ WS_proximfty in-zon@.. No issues idanfified. _ _ _ - _ PetmBcanbeissuedwtohydrogen_sutfidameasutes------------------------ -Yes-- ----NoH2SreportedfromtheWast Sak.---------------------------------- - -- -- Data_p_resentedanRotentialQVerpressurezones-------------------- ------ -Yes--- -------------------- - - - -- --- ----- - -- -- -- -- -- . -- - Seismx analysis ofshallow gas zones- - - - - - - - - - - - - - - - - - - - - - - NA- - ---- - --- --- - -- -- -- -- - - - -- ----- - Seabedcondition survey.{if off-shote) - - - - - - - - - - - - - - - - - - - ~A- - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - Contact namelphone for weeky_Rrogress reports [exploratory only] - - -- --- Y~- - - -MikeWinfreer265r(1820. -- - -- -- --- -- --- -- - -- -- ---- -- Geologic Engineering blic Date A spacing exception is required to complete this watt to TD (See cover letter). Well will drill and set intermediate casing only. Commissioner: Date: Commissioner: Date m toner After another well has been completed, rig will return for completion to TD, with spacing exceetion. ~,~-08 ~~ iNelt History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. t ,y 3k-108.txt Sperry-Sun Drillin Services LIS Scan Utility $Revision: 3 $ LisLib $Revision: 4 $ Thu Jan 15 16:06:38 2009 Reel Header Service name .............LISTPE Date . ...................09/01/15 Ori9in ...................STS Reel Name. .... ........UNKNOWN Continuation Number......01 Previous Reel Name.......UNKNOWN Comments .................STS LIS writing Library. Tape Header Service name .............LISTPE Date . ...................09/01/15 Origin ...................STS Tape Name. .... ........UNKNOWN Continuation Number......01 Previous Tape Name.......UNKNOWN Comments .................STS LIS Writing Library Physical EOF Comment Record TAPE HEADER Kuparuk River unit MWD/MAD LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: scientific Technical Services scientific Technical services 3K-108 500292339500 ConocoPhillips Alaska Inc. Sperry Drilling Services 15-JAN-09 MWD RUN 4 MWD RUN 5 w-0006005292 w-0006005292 P. ORTH P. ORTH M. THORNTON F. HERBERT MWD RUN 3 W-0006005292 A. MUNRO G. RIZEK SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL O) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD 35 13N 9E 1472 319 74.14 33.40 Page 1 ~ ~ (oC~7 i 3 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING REMARKS: 3k-108.txt OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 12.250 13.375 3070.0 6.750 9.625 8015.0 1. ALL DEPTHS ARE BIT DEPTHS UNLESS OTHERWISE NOTED. THESE DEPTHS ARE MEASURED DEPTH (MD). 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTH (TVD). 3. MWD RUN 1 WAS DIRECTIONAL ONLY - NO DATA ARE PRESENTED. MWD RUN 2 WAS A CLEAN-OUT RUN - NO PROGRESS WAS MADE. 4. MWD RUNS 3-5 COMPRISED DIRECTIONAL, DUAL GAMMA RAY (DGR) UTILIZING GEIGER-MUELLER TUBE DETECTORS, ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4), DRILL STRING DYNAMICS SENSOR-ROTATING (DDS-R), AND PRESSURE WHILE DRILLING (PWD). MWD RUNS 4,5 ALSO INCLUDED AT-BIT INCLINATION (ABI). THERE IS A GAP IN THE EWR4 DATA BETWEEN 8045'MD AND 8090'MD DUE TO A TOOL FAILURE. 5. MWD DATA ARE CONSIDERED PDC PER E-MAIL FROM JEFFREY HARRISON (CPAI) TO BRYAN BURINDA DATED 03-APR-2008. 6. MWD RUNS 1-5 REPRESENT WELL 3K-108 WITH API#: 50-029-23395-00. THIS WELL REACHED A TOTAL DEPTH (TD) OF 13180'MD/3684'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. SLIDE = NON-ROTATED INTERVALS REFLECTING BIT DEPTHS. ALL DATA CURVES ARE SMOOTHED TO A STEP OF 0.5 FT, WITH A WINDOW OF 0.6 FT, EXCEPT FOR ROP AND GAMMA RAY, WHICH ARE BOTH SMOOTHED TO A 1.1 FT WINDOW. ALL DATA HAS A GAP FILL OF 5 FT APPLIED. File Header Service name... .......STSLIB.001 Service Sub Level Name... version Number...........1.0.0 Page 2 3k-108.txt Date of Generation.......09/01/15 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......STSLI6.000 Comment Record FILE HEADER FILE NUMBER: EDITED MERGED MWD Depth shifted and DEPTH INCREMENT: FILE SUMMARY PBU TOOL CODE GR FET RPD RPS RPM RPX ROP 1 • clipped curves; all bit runs merged. .5000 START DEPTH 3031.5 3055.0 3055.0 3055.0 3055.0 3055.0 3082.5 STOP DEPTH 13121.5 13128.5 13128.5 13128.5 13128.5 13128.5 13180.0 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 3031.5 8020.0 MwD 4 8020.0 8471.0 MWD 5 8471.0 13180.0 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 Po~nt ..............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 HR 4 1 68 20 6 GR MWD API 4 1 68 24 7 ROP MWD FPH 4 1 68 28 8 Page 3 • 3k-108.txt First Last Name servi ce unit Min Max Mean Nsam Reading Reading DEPT FT 3031.5 13180 8105.75 20298 3031.5 13180 RPD MWD OHMM 3.17 2000 24.5273 19976 3055 13128.5 RPM MWD OHMM 4.46 2000 22.6856 19976 3055 13128.5 RPS MWD OHMM 4.07 2000 20.6533 19976 3055 13128.5 RPX MWD OHMM 3.77 2000 19.9695 19976 3055 13128.5 FET MWD HR 0.09 1686.42 4.48219 19976 3055 13128.5 GR MWD API 13.86 128.27 66.5397 20181 3031.5 13121.5 ROP MWD FPH 0.49 1244.54 238.633 20196 3082.5 13180 First Reading For Entire File..........3031.5 Last Reading For Entire File...........13180 File Trailer Service name... .......STSLIB.001 service sub Level Name... version Number. ........1.0.0 Date of Generation.......09/01/15 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.......09/01/15 Maximum Physical Record..65535 File Type. ............Lo Previous File Name.......5TSL26.001 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 SGRC 3031.5 7970.0 SFXE 3055.0 7962.0 SEXP 3055.0 7962.0 5E5P 3055.0 7962.0 SEMP 3055.0 7962.0 SEDP 3055.0 7962.0 SROP 3082.5 8020.0 LOG HEADER DATA DATE LOGGED: 15-SEP-08 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 74.11 DATA TYPE (MEMORY OR REAL-TIME): Memory Page 4 • 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 VENDOR TOOL CODE DGR EWR4 3k-108.txt BOTTOM) TOOL TYPE DUAL GAMMA RAY 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 (DEG F) 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 C~ 8020.0 3082.0 8020.0 67.8 87.1 TOOL NUMBER 242561 230192 12.250 3070.0 Polymer 8.80 58.0 9.8 200 5.2 1.250 72.0 .870 105.8 1.100 72.0 2.000 72.0 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 HR 4 1 68 20 6 GR MWD030 API 4 1 68 24 7 ROP MWD030 FPH 4 1 68 28 8 Page 5 • • 3k-lO8.txt First Last Name service unit Min Max Mean Nsam Reading Reading DEPT FT 3031.5 8020 5525.75 9978 3031.5 8020 RPD MWD030 OHMM 3.17 2000 17.7 9815 3055 7962 RPM MWD030 OHMM 4.46 1979.63 16.8695 9815 3055 7962 RPS MWD030 OHMM 4.07 153.91 13.916 9815 3055 7962 RPX MWD030 OHMM 3.77 2000 11.6115 9815 3055 7962 FET MWD030 HR 0.09 135.18 1.65296 9815 3055 7962 GR MWD030 API 13.86 128.27 71.5416 9878 3031.5 7970 ROP MWD030 FPH 1.87 1244.54 244.472 9876 3082.5 8020 First Reading For Entire File..........3031.5 Last Reading For Entire File...........8020 File Trailer Service name... .......STSLI6.002 service sub Level Name... version Number. ........1.0.0 Date of Generation.......09/01/15 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.......09/01/15 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......STSLI6.002 Comment Record FILE HEADER FILE NUMBER: 3 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 4 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH SFXE 7962.5 8419.0 SESP 7962.5 8419.0 SEXP 7962.5 8419.0 SEMP 7962.5 8419.0 SEDP 7962.5 8419.0 SGRC 7970.5 8413.0 SROP 8020.5 8471.0 LOG HEADER DATA DATE LOGGED: 25-NOV-08 sOFTWARE Page 6 • 3k-108.txt SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 74.11 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 8471.0 TOP LOG INTERVAL (FT): 8020.0 BOTTOM LOG INTERVAL (FT): 8471.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 86.2 MAXIMUM ANGLE: 89.7 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 268169 EWR4 Electromag Resis. 4 148579 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 6.750 DRILLER'S CASING DEPTH (FT): 8015.0 BOREHOLE CONDITIONS MUD TYPE: Mineral Oil Base MUD DENSITY (LB/G): 9.20 MUD VISCOSITY (S): 80.0 MUD PH: .O MUD CHLORIDES (PPM): 33000 FLUID LOSS (C3): 4.5 RESISTIVITY (OHMM) AT TEMPERATURE (DEG F) MUD AT MEASURED TEMPERATURE (MT): .000 .O MUD AT MAX CIRCULATING TERMPERATURE: .000 82.4 MUD FILTRATE AT MT: .000 .O MUD CAKE AT MT: .000 .O 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 MWD040 OHMM 4 1 68 4 2 RPM MWD040 OHMM 4 1 68 8 3 RPS MWD040 OHMM 4 1 68 12 4 RPX MWD040 OHMM 4 1 68 16 5 Page 7 i • 3k-108.txt FET MWD040 HR 4 1 68 20 6 GR MWD040 API 4 1 68 24 7 ROP MwD040 FPH 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 7962.5 8471 8216.75 1018 7962.5 8471 RPD MWD040 OHMM 4.85 2000 82.8598 742 7962.5 8419 RPM MWD040 OHMM 11.47 2000 36.7053 742 7962.5 8419 RPS MWD040 OHMM 10.3 2000 40.9602 742 7962.5 8419 RPX MWD040 OHMM 10.29 2000 41.167 742 7962.5 8419 FET MWD040 HR 0.2 1686.42 87.9421 742 7962.5 8419 GR MWD040 API 29.73 79.55 54.9018 886 7970.5 8413 ROP MWD040 FPH 0.57 1038.13 230.444 902 8020.5 8471 First Reading For Entire File..........7962.5 Last Reading For Entire File...........8471 File Trailer Service name... .......STSLIB.003 Service Sub Level Name... Version Number. ........1.0.0 Date of Generation.......09/01/15 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.......09/01/15 Maximum Physical Record..65535 File Type. ............Lo Previous File Name.......STSLI6.003 Comment Record FILE HEADER FILE NUMBER: 4 RAW MWD curves and log BIT RUN NUMBER: DEPTH INCREMENT: FILE SUMMARY VENDOR TOOL CODE SGRC SEMP SEXP SEDP SFXE SESP SROP header data for each bit run in separate files. 5 .5000 START DEPTH 8413.5 8419.5 8419.5 8419.5 8419.5 8419.5 8471.5 STOP DEPTH 13121.5 13128.5 13128.5 13128.5 13128.5 13128.5 13180.0 Page 8 • 3k-108.txt LOG HEADER DATA DATE LOGGED: 28-NOV-08 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 74.11 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 13180.0 TOP LOG INTERVAL (FT): 8471.0 BOTTOM LOG INTERVAL (FT): 13180.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 84.7 MAXIMUM ANGLE: 92.4 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 184054 EWR4 Electromag Resis. 4 223565 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 6.750 DRILLER'S CASING DEPTH (FT): 8015.0 BOREHOLE CONDITIONS MUD TYPE: Mineral Oil Base MUD DENSITY (LB/G): 9.20 MUD VISCOSITY (S): 71.0 MUD PH: .O MUD CHLORIDES (PPM): 30000 FLUID LOSS (C3): 3.0 RESISTIVITY (OHMM) AT TEMPERATURE (DEG F) MUD AT MEASURED TEMPERATURE (MT): .000 .O MUD AT MAX CIRCULATING TERMPERATURE: .000 100.4 MUD FILTRATE AT MT: .000 .O MUD CAKE AT MT: .000 .O 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 Logyin 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 MWD050 OHMM 4 1 68 4 2 Page 9 • 3k-108.txt RPM MWD050 oHMM 4 1 68 8 3 RPS MWD050 OHMM 4 1 68 12 4 RPX MwD050 OHMM 4 1 68 16 5 FET MWD050 HR 4 1 68 20 6 GR MWD050 API 4 1 68 24 7 ROP MwD050 FPH 4 1 68 28 8 First Last Name Service unit Min Max Mean Nsam Reading Reading DEPT FT 8413.5 13180 10796.8 9534 8413.5 13180 RPD MWD050 OHMM 6.05 2000 27.0465 9419 8419.5 13128.5 RPM MWD050 OHMM 5.93 2000 27.6418 9419 8419.5 13128.5 RPS MwD050 OHMM 6 2000 26.0742 9419 8419.5 13128.5 RPX MWD050 OHMM 5.91 2000 27.0091 9419 8419.5 13128.5 FET MWD050 HR 0.16 17.9 0.85564 9419 8419.5 13128.5 GR MWD050 API 34.7 95.15 62.3879 9417 8413.5 13121.5 ROP MWD050 FPH 0.49 695.6 233.294 9418 8471.5 13180 First Reading For Entire File..........8413.5 Last Reading For Entire File...........13180 File Trailer Service name... .......STSLI6.004 Service Sub Level Name... version Number. ........1.0.0 Date of Generation.......09/01/15 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.005 Physical EOF Tape Trailer Service name .............LISTPE Date . ...................09/01/15 Origin ...................STs Tape Name. .... ........UNKNOWN continuation Number......01 Next Tape Name...........UNKNOWN Comments .................STS LIS Reel Trailer Service name .............LISTPE Date . ...................09/01/15 Ori9in ...................STS Reel Name. .... ........UNKNOWN Continuation Number......01 Next Reel Name...........UNKNOWN Comments .................STS LIS Physical EoF writing Library writing Library. Page 10 scientific Technical services scientific Technical services • 3k-108.txt Physical EOF End Of LIS File Page 11