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Home My WebLink About201-130MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Thursday, March 13, 2025 SUBJECT:Mechanical Integrity Tests TO: FROM:Bob Noble P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL Hilcorp North Slope, LLC S-107 PRUDHOE BAY UN AURO S-107 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 03/13/2025 S-107 50-029-23023-00-00 201-113-0 W SPT 6639 2011130 3200 1399 1396 1394 1397 253 306 310 310 REQVAR P Bob Noble 1/13/2025 2 year MIT-IA as per AA AIO 22F .001 to max injection pressure. 30 MinPretestInitial15 Min Well Name Type Test Notes: Interval P/F Well Permit Number: Type Inj TVD PTD Test psi API Well Number Inspector Name:PRUDHOE BAY UN AURO S-107 Inspection Date: Tubing OA Packer Depth 1179 3533 3470 3459IA 45 Min 60 Min Rel Insp Num: Insp Num:mitRCN250113162020 BBL Pumped:5.2 BBL Returned:4.6 Thursday, March 13, 2025 Page 1 of 1 9 9 9 9 9 9 999 99 9 9 9 9 9 year MIT-IA as per AA AIO 22F .001 James B. Regg Digitally signed by James B. Regg Date: 2025.03.13 10:10:33 -08'00' New Plugback Esets 7/31/2024 Well Name API Number PTD Number ESet Number Date CD2-15 PB1 50-103-20386-70-00 201-159 T39326 4-26-2002 CD2-15 PB2 50-103-20386-71-00 201-159 T39327 4-26-2002 1D-42L1 PB1 50-029-22979-70-00 205-078 T39328 8-3-2005 2N-304 PB1 50-103-20382-70-00 201-130 T39329 9-12-2001 Mitre 1 PB1 50-103-20409-70-00 202-026 T39330 7-23-2002 C-26L1 PB1 50-029-22634-70-00 203-076 T39331 9-17-2003 C-26L1 PB2 50-029-22634-71-00 203-076 T39332 9-17-2003 C-26L1 PB3 50-029-22634-72-00 203-076 T39333 9-17-2003 MPU E-32 PB1 50-029-23261-70-00 205-065 T39334 7-7-2005 S-04L1 PB1 50-029-23148-70-00 203-053 T39335 7-14-2005 S-04L1 PB2 50-029-23148-71-00 203-053 T39336 7-14-2005 MPU S-05 PB1 50-029-23100-70-00 202-137 T39337 6-2-2003 B-03 PB1 50-883-20095-70-00 198-059 T39338 11-6-2003 07-28B PB1 50-029-21770-70-00 209-037 T39339 6-29-2009 16-23A PB1 50-029-22050-70-00 201-054 T39340 6-2-2003 W-34A PB1 50-029-21867-70-00 203-058 T39341 2-6-2004 SP30-W01 PB1 50-629-23476-70-00 212-142 T39342 11-14-2012 V-207L4 PB1 50-029-23390-71-00 208-070 T39343 9-11-2008 W-215 PB1 50-029-23172-70-00 203-131 T39344 9-12-2003 2N-304 PB1 50-103-20382-70-00 201-130 T39329 9-12-2001 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 Annular Communication Surveillance 23-Jun-2021Well Name:3K-108 Start Date:23-Jun-2021 21-Sep-2021Days:90 End Date:21-Sep-2021 50 60 70 80 90 100 110 120 130 140 150 0 200 400 600 800 1000 1200 1400 1600 23-Jun-2126-Jun-2129-Jun-212-Jul-215-Jul-218-Jul-2111-Jul-2114-Jul-2117-Jul-2120-Jul-2123-Jul-2126-Jul-2129-Jul-211-Aug-214-Aug-217-Aug-2110-Aug-2113-Aug-2116-Aug-2119-Aug-2122-Aug-2125-Aug-2128-Aug-2131-Aug-213-Sep-216-Sep-219-Sep-2112-Sep-2115-Sep-2118-Sep-2121-Sep-21Temperature (degF)Pressure (PSI)Pressure Summary WHP IAP OAP WHT 0 100 200 300 400 500 600 700 800 900 23-Jun-2126-Jun-2129-Jun-212-Jul-215-Jul-218-Jul-2111-Jul-2114-Jul-2117-Jul-2120-Jul-2123-Jul-2126-Jul-2129-Jul-211-Aug-214-Aug-217-Aug-2110-Aug-2113-Aug-2116-Aug-2119-Aug-2122-Aug-2125-Aug-2128-Aug-2131-Aug-213-Sep-216-Sep-219-Sep-2112-Sep-2115-Sep-2118-Sep-21Injection Rate (BPD or MSCFD)Injection Rate Summary DGI MGI PWI SWI BLPD Annular Communication Surveillance 3K-108 90-Day Bleed History WELL_ID TIME STR-PRES END-PRES DIF-PRES CASING SERVICE 3K-108 6/30/21 1193 1265 -72 INNER SWI 3K-108 11/10/16 1100 1320 -220 INNER SWI 3K-108 4/6/14 165 304 -139 INNER SWI 3K-108 5/17/09 225 1300 -1075 INNER SWI OUTER 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 ... .r STATE OF ALASKA •SKA OIL AND GAS CONSERVATION CESSION REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon H Plug Perforations H Fracture Stimulate LJ Pull Tubing LJ Operations shutdown LJ Performed: Suspend ❑ Perforate ❑ Other Stimulate ❑ Alter Casing ❑ Change Approved Program ❑ Plug for Redrill ❑ Perforate New Pool ❑ Repair Well ❑ Re-enter Susp Well ❑ Other: Change Lift (Jet Pump to GL.1_ 2.Operator 4.Well Class Before Work: 5.Permit to Drill Number: Name: ConocoPhillips Alaska, Inc. Development ❑✓ Exploratory ❑ 201-130 3.Address: Stratigraphic H Service ❑ 6.API Number: P.O.Box 100360,Anchorage,Alaska 99510 50-103-20382-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL 380053 KRU 2N-304 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): OA Kuparuk River Field/Tarn Oil Pool 11.Present Well Condition Summary: Total Depth measured 10052 feet Plugs measured feet true vertical 5875 feet Junk measured feet Effective Depth measured 9911 feet Packer measured feet true vertical 5760 feet true vertical feet Casing Length Size MD TVD Burst Collapse Structural Conductor 117' 16" 152' 152' RECEIVED Surface 2896' 7 5/8" 2930' 2306' Intermediate Production 10006' 5 1/2" 10037' 5863' APR 1 8 2018 Liner 9225' 4 1/2" 9246' 5244' Perforation depth Measured depth 9592-9602' feet AOGCC True Vertical depth 5507-5515' feet Tubing(size,grade,measured and true vertical depth) 2 3/8" L-80 9190' 5203' Packers and SSSV(type,measured and true vertical depth) No Packer- tubing stbbd into seal assy. 9183' 5198' 12.Stimulation or cement squeeze summary: Intervals treated(measured): NIA %i Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 219 297 115 2315 270 Subsequent to operation: 339 208 67 1086 273 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations H Exploratory H Development 2 Service ❑ Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16.Well Status after work: Oil El Gas ❑ WDSPL H Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ H SUSP H SPLUIG H 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: 318-081 Authorized Name: Adam Childs Contact Name: Adam Childs Authorized Title: Staff Petroleum Engineer Contact Email: adam...childs• co..co Authorized Signature: Date: (1f Iii/13 Contact Phone: 263-4690 VT1- 4P-7117- I Form 10-404 Revised 4/2017 A `/,u//8/ PR / 3 11116 Submit Original Only RBDM tk` • • Date Event Summary 3/20/18 Lift Gas jumper MOC completed, Sundry Approved. 2N-304 returned to production on gas lift II it ISI • KUP PROD 2N-304 ConocoPhillips a° e s Well es MI( &MD TD Wellbore Field Name Wellbore Status ncr) (ftKB) Act Btm(ftKB) AIdGkd,II1L:, - 501032038200 TARN PARTICIPATING AREA PROD 68.37 2,808.89 10,052.0 (.orrocoYlulkps Comment H2S(ppm) Date Annotation End DateKB-Grd(ft) Rig Release Date -• SSSV:_NIPPLE 60 1/14/2010 Last WO: 12/21/2013 I 40.54 8/15/2001 2N-304.4/18/201811:13:04 AM _Last Tag Vertical schematic(actual _ -Annotation Depth(ORB) End Date Last Mod By Last Tag.RKB 9,601.0 2/21/2018 fergusp Last Rev Reason Annotation End Date Last Mod By Rev Reason:OPEN CMU,SET POGLM 3/26/2018 pproven HANGER,29.5 1121-m � Casing Strings Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)... Wt/Len(I...Grade Top Thread CONDUCTOR 16 15.062 35.0 152.0 152.0 62.58 H-40 WELDED I' - II Casing Description OD(in) ID(in) Top(RKB) Set Depth(ftKB) Set Depth(ND)... VVt/Len(I...Grade Top Thread SURFACE 7 5/8 6.875 342 2,930.3 2,305.5 29.70 L-80 BTCM 11_ Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...VW/Len(I...Grade Top Thread PRODUCTION 51/2 4.950 31.4 10,037.0 5,862.5 15.50 L-80 BTCM 1l I I 5.5"X3.5"Casing @Description 9262' OD(In) ID(in) Top(ftKB) Set Depth MB) Set Depth(TVD)...Wt/Leng...Grade Top Thread Li TIE BACK LINER 4.5" 4 1/2 3.920 29.3 9,246.0 5,244.0 11.60 L80 HYD 111Liner Details wu Nominal ID Top(ftKB) Top(TVD)(ftKB) Top Incl C) Item Des Com (in) 9,185.6 5,199.4 42.97 XO Reducing X-O 3-5/8"ACME X 4.5"11.68 L-80 HYD 513 2.700 9,186.4 5,200.0 42.95 SBE BAKER 3 5/8"(2.69"ID)SEAL BORE EXTENSION 2.690 -,-ti CONDUCTOR,35.0-152.0' 9,223.5 5,227.3 42.27 NIPPLE CAMCO 2.813"X-NIPPLE 2.813 9,241.6 5,240.7 42.05 LOCATOR BAKER LOCATOR COUPLING 4.50" 2.990 9,243.0 5,241.8 42.03 SEAL ASSY BAKER GBH-22 SEAL ASSY(17.50') 2.990 I Tubing Strings Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft..Set Depth(TVD)(...Wt(Ib/ft) Grade Top Connection TUIBNG WO 23/8 1.995 29.5 9,190.0 5,202.6 4.60 L80 IBTM • Completion Details SURFACE;34.2-2,930.3 Top(TVD) Top Inc! Nominal Top(ftKB) (ftKB) C) Item Des Com ID(In) 29.5 29.5 021 HANGER FMC GEN V TUBING HANGER 1.995 ® 9,096.0 5,135.1 45.52 SLEEVE-0 BAKER CMU SLIDING SLEEVE(1.875"BX)-OPENED 2/21/2018 1.870 POGLM;9,098.0 •I(.1 9,139.5 5,166.0 44.17 NIPPLE CAMCO X NIPPLE 1.875" 1.875 SLEEVE-0;9,098.0 .I, 9,181.6 5,196.5 43.08 LOCATOR BAKER LOCATOR 40-26 GBH-22 1.970 9,183.0 5,197.5 43.04 SEAL ASSY BAKER 40-26 GBH BONDED SEAL ASSEMBLY(20.05') 1.970 NI Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) 111 Top(ND) Top Incl Top(ftKB) (ftKB) C) Des Com Run Date ID(in) NIPPLE;9,139.5 • ! 9,096.0 5,135.1 45.52 POGLM 2.375"POGLM W/1/4"OV INSTALLED 2/21/2018 0.250 I (SN:36521908)ON 1.875"X-LOCK IN SELECT POSITION,PASS THROUGH CMU Perforations&Slots Shot _ Dens LOCATOR;9,181.8 :I Top(TVD) Btm(TVD) (shots/ft(ftKB) Btm(RKB) (ftKB) (ORB) Zone Date ) Type Com . 9,592.0 9,602.0 5,506.8 5,514.6 BERMUDA,2N- 11/12/2001 4.0 IPERF 2.5"HSD,BH Chgs,180 e 304 deg phase,45/227 deg orient SEAL ASSY;9,1830 ■ Stimulations&Treatments IProppant Designed(Ib) Proppant In Formation(Ib) Date 11/17/2001 I Stimulations&Treatments Vol Clean Pump Stg M Top(ftKB) 1 9,592.0 Btm(ftKB) Date Stim/Treat Fluid (bbl) Vol Slurry(bbl) 9,602.0 11/17/2001 Notes:General&Safety ! End Date Annotation s 11/19/2010 NOTE:View Schematic w/Alaska Schematic9.0 2/7/2013 NOTE:WORKOVER TIE BACK LINER 4.5.;29.3- %246.0 939,248.0 •i' I FRAC;9,592.0 (PERF;9,592.0-9,602.0 I PRODUCTION 5.8/X3.5" 9267;31.4-10,037.0 I • y OF TR • y-0,\I/7...'6.� THE STATE Alaska Oil and Gas �, of Conservation Commission _,,�: ALAS .E2 �� 333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 ain: 907.279.1433 °A'ALAB�t MFax: 907.276.7542 www.aogcc.alaska.gov David Neville Staff Petroleum Engineer ConocoPhillips Alaska, Inc. SCANNED P.O Box 100360 Anchorage,AK 99510 Re: Kuparuk River Field, Tarn Oil Pool, KRU 2N-304 Permit to Drill Number: 201-130 Sundry Number: 318-081 Dear Mr.Neville: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown,a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, CIOCCr-1. -- Hollis S. French Sl Chair DATED this day of March,2018. RBDMS1 MAR 2 12018 0 • RECEIVED STATE OF ALASKA P;113 �� 201 ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 L, 1.Type of Request: Abandon ❑ Plug Perforations❑ Fracture Stimulate ❑ Repair Well ❑ Operations shutdown❑ Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing ❑ Change Approved Program❑ Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other: Change artificial lift n 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: Co jttpv»+p fp&L- ConocoPhillips Alaska,Inc. Exploratory ❑ Development ❑✓ 201-130 ' 3.Address: Stratigraphic ❑ Service ❑ 6.API Number: P.O.Box 100360,Anchorage,Alaska 99510 50-103-20382-00' 7. If perforating: 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? NA , KRU 2N-304 Will planned perforations require a spacing exception? Yes ❑ No LJ( Mb 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL 380053 Kuparuk River Field/Tarn Oil Pool • 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth TVD: MPSP(psi): Plugs(MD): Junk(MD): 10052 5875 ' 9911 • . 5760 None None Casing Length Size MD TVD Burst Collapse CONDUCTOR 117' 16" 152' 152' SURFACE 2896' 7 5/8" 2930' 2306' PRODUCTION 10006' 5 1/2" 10037' 5863' INNER LINER 9225' 4 1/2" 9246' 5244' Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 9592-9602 ' 5507-5515 2 3/8" L-80 9190 Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): SSSV=None. No packer: tubing stabbed into seal assy. SSSV=None. No packer: tubing stabbed into seal assy at 9183'MD,5198'TVD. 12.Attachments: Proposal Summary Q Wellbore schematic Q 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stratigraphic❑ Development 0 Service ❑ 14.Estimated Date for 15.Well Status after proposed work: Commencing Operations: 3/1/2018 OIL Q • WINJ ❑ WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name: David Neville Contact Name: David Neville Authorized Title: Staff Petroleum Engineer Contact Email: David.J.Neville(a�conocophillips.com Q 2/20g//2�/) Contact Phone: 265-6220 (x Authorized Signature: Date: / 1 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: z r - 0'3' Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: Post Initial Injection MIT Req'd? Yes ❑ No Spacing Exception Required? Yes ❑ No V Subsequent Form Required: /( 4° APPROVED BY Approved by: k-VOnCOMMISSIONER THE COMMISSION Date: 3 11 Lei f Form 10-403 Revised 4/2017 Approved appli at �fl� II� 1No t rom the date of approval. �/iRS�bsr�t xi �J`� , ` VVV pp Attachments in Duplicate • 2N-304 • DESCRIPTION SUMMARY OF PROPOSAL ConocoPhillips Alaska Inc. is seeking approval to change the artificial lift method from Surface Powered Jetpump (SPJP)to gaslifted production in Tarn well 2N-304.'The objective of this work is to reduce water handling costs and corrosion tendency, extending the economic life of the well. A passing MIT of the inner annulus was performed to 3500 psi on 2/20/2018. Changing artificial lift to gaslift involves pulling the jetpump from 9096' RKB and the standing valve from 9140' RKB. A packoff gaslift mandrel installed across the sliding sleeve at 9096' RKB will provide the path for lift gas to enter the tubing. ~ KUP PROD 410 2N-304 ConocoPhillips ' 4 Well Attributes Max Angle&MD TD 1 la,.,k,-,,lift,.. Wellbore API/UWI Field Name Wellbore Status Inc!(°) MD(ftKB) Act Btm(ftKB) �gp, 501032038200 TARN PARTICIPATING AREA PROD 68.37 2,808.89 10,052.0 ... . Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date 21/-304,2/14/20147.1142 AM SSSV:NIPPLE 60 1/14/2010 Last WO: 12/21/2013 40.54 8/15/2001 Vertical ccheraatc(actual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date Last Tag:SLM 9,574.0 2/3/2014 Rev Reason:TAG,OPEN CMU,SET JET PUMP hipshkf 2/13/2014 ....................................................................................................... &STANDING VLV I I Casing Strings Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread HANGER,295 I ,;,, CONDUCTOR 16 15.062 35.0 152.0 152.0 62.58 H-40 WELDED Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)...Wt/Len(I...Grade Top Thread SURFACE 75/8 6.875 34.2 2,930.3 2,305.5 29.70 L-80 BTCM '� Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)...Wt/Len(I...Grade Top Thread 1' PRODUCTION 51/2 4.950 31.4 10,037.0 5,862.5 15.50 L-80 BTCM 1 E 5.5"X3.5"@ 9262' Ili Casing Description OD(in) ID(in) Top(ftKB) 'Set Depth(ftKB) Set Depth(ND)...Wt/Len(I...Grade Top Thread TIE BACK LINER 4.5" 4 1/2 3.920 29.3 9,246.0 5,244.0 11.60 L80 HYD { Liner Details Nominal lD Top(ftKB) Top(ND)(ftKB) Top Incl 1°) Item Des Com (in) 9,185.6 5,199.4 42.97 XO Reducing X-0 3-5/8"ACME X 4.5"11.W L-80 HYD 513 2.700 ,.../11;mucm111.1ww++11.1•"1 • 11, ... ,L:11112/ 9,186.4 5,200.0 42.95 SBE BAKER 3 5/8"(2.69"ID)SEAL BORE EXTENSION 2.690 9,223.5 5,227.3 42.27'NIPPLE CAMCO 2.813"X-NIPPLE 2.813 9,241.6 5,240.7 42.05 LOCATOR BAKER LOCATOR COUPLING 4.50" 2.990' .�.h.�CONDUCTOR,35.0-152.0 9,243.0 5,241.8 42.03 SEAL ASSY BAKER GBH-22 SEAL ASSY(17.50') 2.990 Tubing Strings Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft...Set Depth(ND)(...Wt(Ib/ft) Grade Top Connection TUIBNG WO 23/8 1.995 29.5 9,190.0 5,202.6 4.60 L80 IBTM Completion Details Nominal ID Top(ftKB) Tap(ND)(ftKB) Top Incl(°) Item Des Com (in) SURFACE;34.2-2,930.3-- A 29.5 29.5 0.21 HANGER FMC GEN V TUBING HANGER 1.995 9,096.0 5,135.1 45.52 SLEEVE-O BAKER CMU SLIDING SLEEVE(1.875"BX)oPENED 1.870 2/3/14 SLEEVE-0;9,096.09,13.5 5,166.0 44.17 IPPLE CAMCO X NIPPLE 1.875" 1.875 JET PUMP;9,096.01 li iii 9,181.6 5,196.5 43.08 LOCATOR BAKER LOCATOR 40-26 GBH-22 1.970 =' 9,183.0 5,197.5 43.04 SEAL ASSY BAKER 40-26 GBH BONDED SEAL ASSEMBLY(20.05') 1.970 Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) I Top(ND) Top Incl Top(ftKB) To; 11 Des Com Run Date ID(in) NIPPLE;9,139.5 74' 9,096.0 5,135.1 45.52 JET PUMP RC JET PUMP ON 1.875"X-LOCK(SN:PH-1168/ 2/9/2014 1.875 8A RATION=8 NOZZLE,8 THROAT/OAL-53"_ VALVE;9,139.5 9,139.5 5,166.0 44.18 VALVE WFT MP-1 PUMP-THRU STANDING VALVE ON 2/9/2014 1.875 1.875"X-LOCK(35"OAL/VLV SET TO 800 PSI DP/NEED 14"OF.625"PRONG TO ED) Perforations&Slots Shot Dens Top(ND) Btm(ND) (shots/f LOCATOR;9,181 6 Top(ftKB) Btm(ftKB) (ftKB) (ftKB) Zone Date t) Type Com w 9,592.0 9,602.0 5,506.8 5,514.6 BERMUDA, 11/12/2001 4.0 IPERF 2.5"HSD,BH Chgs,180 :. 2N-304 deg phase,45/227 deg orient owe SEAL ASSY,9,t830 Stimulations&Treatments in Mm Top Max Btm (rde? Depth Depth Top(TVD) Btm(ND) 'ir (ftKB) (ftKB) (ftKB) (ftKB) Type Date Com 9,592.0 9,602.0 5,506.8 5,514.6 FRAC 11/17/2001 BERMUDA FRAC,219,000#12/18 CARBOLITE,10 PPA ON PERFS Notes:General&Safety End Date Annotation II 11/19/2010 NOTE'View Schematic w/Alaska Schematic9.0 2/712013 NOTE:WORKOVER pee. I l TIE BACK LINER 4.5;29.3- 9,246.0 `7 " FRAC;9,592.0 IPERF. 9,592.0-9,602.0 I I I PRODUCTION 5.5"X3.5" 9262`31.4-10,037.0 2-o\ - \3o 2_53-10 WELL LOG TRANSMITTAL DATA LOGGED 2/5/2015 M K BENDER To: Alaska Oil and Gas Conservation Comm. January 21, 2015 Attn.: Makana Bender 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 FER 0 K 015 RE: Plug Setting Record: 2N-304 Run Date: 1/15/2015 (,)(3 C The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Chris Gullett, Halliburton Wireline& Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 FRS_ANC@halliburton.com 2N-304 Digital Data in LAS format, Digital Log Image file 1 CD Rom 50-103-20382-00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline& Perforating Attn: Chris Gullett 6900 Arctic Blvd. Anchorage, Alaska 99518 iC/ 1 Office: 907-273-3527 Fax: 907-273-3535 FRS_ANC@halliburton.com Date: Signed: ✓wir'a'h'a-4 6.-eiteair OF 7`4, • r \ l�j � THE STATE Alaska Oil and Gas of Conservation Commission =_ ALASKA GOVERNOR SEAN PARNELL 333 West Seventh Avenue 0 ^ytF- Anchorage, Alaska 99501-3572 ALAS Main: 907.279.1433 Fax: 907.276.7542 Jonathan Coberly t ,�,.A�N� 2,b` � Sr. Wells Engineer Alaska, Inc. P.O. Box 100360 cq e)l., 130 Anchorage, AK 99510 Re: Kuparuk River Field, Tarn Oil Pool, 2N-304 Sundry Number: 313-424 Dear Mr. Coberly: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, ed-g47 Cathy P. Foerster Chair, Commissioner DATED this Z/ day of September, 2013. Encl. STATE OF ALASKA ALSA OIL AND GAS CONSERVATION COM•ION _LA$ AUG 0 5 2013 , APPLICATION FOR SUNDRY APPROVALS ck" 07s `:/z4(!3 20 AAC 25.280 AOG CC 1.Type of Request: Abandon 1 Rug for Redrill r Perforate New Pool r Repair w ell Change Approved Program 1 Suspend Rug Perforations r Perforate r Pull Tubing Time Extension Operational Shutdown r Re-enter Susp.Well F Stimulate r Alter casing 1;►. Other: r 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Development Exploratory r 201-130• 3.Address: Stratigraphic F Service 6.API Number: P. O. Box 100360,Anchorage,Alaska 99510 50-103-20382-00• 7.If perforating, What 8.Well Name and Number: Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require spacing exception? Yes F No 2N-304+- 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL 380053. Kuparuk River Field/Tam Oil Pool' 11. PRESENT WELL CONDITION SUMMARY Total depth MD(ft): Total Depth TVD(ft): Effective Depth MD(ft): Effective Depth TVD(ft): Plugs(measured): Junk(measured): 10052- 5875 . 9911' • 5760'• 9290' • none Casing Length Size MD TVD Burst Collapse CONDUCTOR 117 16 152' 152' SURFACE 2896 7.625 2930' 2306' PRODUCTION 10006 5.5 10037' 5863' Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 9592-9602• 5507-5515 3.5 L-80 9247 Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft) no packer NIPPLE-CAMCO'DS'nipple @ .MD=511 TVD=511 • 12.Attachments: Description Summary of Proposal r" 13. Well Class after proposed work: Detailed Operations Program 1 BOP Sketch F Exploratory 1— Stratigraphic IF Development lw, Service 14.Estimated Date for Commencing Operations: 11/13 15. Well Status after proposed work: _worn:in Oil Wi Gas r WDSPL r Suspended 16.Verbal Approval: Date: vi...c WINJ r GINJ ( WAG r Abandoned `"" Commission Representative: 4/24/13 GSTOR F SPLUG 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Jonathan Coberly @ 265-1013 Email: Jonathan.Coberly@cop.com Printed Name Jonathan oberl Title: Sr.Wells Engineer Signature Phone:265-1013 Date $•2-2o(3 Commission Use Only Sundry Number:313-470(4 Conditions of approval: Notify Commission so that a representative may witness Plug Integrity -` BOP Test VMechanical Integrity Test "-` Location Clearance ... REV)MS OCT 1 0 2' Other: /3op rest to cF OO 12 5.-z Spacing Exception Required? Yes ❑ No [✓]/ Subsequent Form Required: � 9 .— T___a 4, cpM g p E APPROVED BY N Z7 `I Approved by: A ovcd application is vallq igrl l31 PrI Rths from thTC 01�t2 OTI ��OVaI. Date: Form 10-403(Revised 10/2012)/ 1 ORIGINAL Submit Form and Attachments in Duplicate >''n VLF' �'/ /f.3 ,/. .0 • RECEIVED AUG 052013 ConocoPhillips AOGCC Alaska P.O. BOX 100360 ANCHORAGE,ALASKA 99510-0360 August 2,2013 Commissioner Dan Seamount State of Alaska Alaska Oil&Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage,Alaska 99501 Dear Commissioner Seamount: ConocoPhillips Alaska, Inc. hereby applies for an Application for Sundry Approval to workover the Kuparuk Producer 2N-304(PTD 201-130). 2N-304 was spud and completed into the Bermuda interval in 2001. It has been producing through jet pump artificial lift since 2002. The well was shut in due to a failed MIT of the tubing in August 2011. The well was producing approximately 270 bopd before the well was shut in. During the rig workover to replace the tubing in February 2013, the casing failed a pressure test to 3,500 psi. A 5/20/2013 post rig workover PDS Leak Detect log indicated that the leak had occurred between 6,180' RKB and 6,200' RKB. The WRP set in the 3 'h" casing will be removed prior to rigging up. The well is currently shut in at the surface with kill weight fluid in the wellbore. In order to return the well to jet pumped/gas lifted production this well has been identified as a candidate for an expense rig workover. The rig workover will install a 4 'h" tie-back liner with a 2 3/8" jet pump/concentric gas lift completion. The purpo - •f •'_ ig workover is to install a barrier that will replace the failed 5 '/2"casing barrier. The new 4 'h"x 5 'A"a ulus will be able to be monitored for signs of pressure communication during production. ' -: •vise us on any new wavering requirements 7 because of this completion design. ~' If you have any questions or require any further information, please contact me at 265-1013 or Jonathan.Coberly@cop.com. Sincerely, Jonathan Coberly Senior Wells Engineer CPAI Drilling&Wells • • 2N-304 Rig Workover Install 4 1/2" Tie-back Liner/2 3/8" Tubing (PTD #: 201-130) Current Status: Tarn well 2N-304 is a Bermuda producer. The well is currently shut in due to a failing MIT-IA brought on by the previous rig workover. Scope of Work: Pull 3 'h"tubing,install 4'/2"tie-back liner,install 2'/g"jet pump/concentric gas lift completion. General Well info: MASP: 1,465 psi Reservoir pressure/TVD: Bermuda—2,016 psi/5,511' TVD(7.1 EMW)measured 12/4/2012 Updated SBHP planned during pre-rig. Wellhead type/pressure rating: FMC Gen 5,3 'V$"5M tree x 11"5M top flange Nordic 3 BOP configuration: Annular/Pipe Rams/Blind Rams/Mud Cross/Pipe Rams MIT results: MIT-T: Passed on 2/17/2013 (during RWO) MIT-IA: Failed on 2/17/2013 (during RWO) Well Type: Producer Estimated Start Date: September 27,2013 Production Engineers: Deanna Van Dam/Mike Balog Workover Engineer: Jonathan Coberly(265-1013/Jonathan.Coberly @cop.com) Proposed Pre-Rig Work: 1. RU slickline: Pull catcher and WRP. Get new SBHP. Open CMU. RD slickline. 2. FTLDS. Set BPV. Proposed Procedure: 1. MIRU. Pull BPV. Circulate KWF. Install BPV. ND tree. 2. Install blanking plug. NU BOPE. Function and PT BOP rams,choke manifold,and annular to 3,500 psi. 1,'" 3. Pull the blanking plug. Pull BPV. 4. BOLDS,PU on tubing hanger. Reverse circulate KWF. POOH w/completion tubing. 6. RIH with tie-back liner assembly to SBR. Engage seal assembly into the SBR until fully located. Space out seal assembly. 7. Reverse circulate the 4 'A"x 5 'A" annulus to corrosion inhibited KWF followed by diesel freeze protect. Land the 4 'h"tie-back liner. PT liner. Monitor annulus for returns. 8. RU E-line. RIH and set a WRP in the 4 'A"liner. PT/DDT the WRP. Set catcher on the WRP. RD E-line. 9. ND BOPE. Cut excess liner. Install packoffs. NU new tubing head. Pressure test packoffs. NU BOPE. Pressure test BOPE to 3,500 psi. 10. RU slickline. Pull catcher. Pull WRP. RD slickline. 11. RIH w/new 2 3/8"completion tubing to the SBE. Engage seal assembly into the SBE until fully located. Space out seal assembly. Swap the well over to corrosion inhibited fluid. Land the tubing. 12. PT 2 3/8" tubing to 3,000 psi. Bleed tubing to 2,500 psi. PT the IA to 3,500 psi (chart for 30 minutes). Drawdown IA then tubing. 13. RU slickline. RIH and open CMU. RD slickline. 14. Monitor well for flow. Pull landing joint. Set TWC. PT the two way check valve by pressuring up on the IA. 15. ND BOP. NU new tree. Pressure test tree and tubing hanger packoffs to 5,000 psi. Pull TWC. 16. Freeze protect with diesel. Set BPV. RDMO. Proposed Post-Rig Work: 1. Pull BPV. 2. Run jet pump/gas lift design 3. Reset the well houses and flow lines. 4. Turn well over to Operations. • • ConocoPhillips Well: 2N-304 2013 RWO PROPOSED COMPLETION API: 501032038200 PTD: 201-130 X 4— 1.875"'X'Nipple at 500'RKB Wellhead: FMC Gen 5 Conductor Casing: �o kin v0 (0 C 16"62.58#H-40 Welded 66 A ■ lV I3 Surface Casing: °N1- f ( 75/8"29.7#L80BTCM ; J . 01 1 j1 Production Casing: 5-1/2" 15.5# L-80 BTCM 3-1/2"9.3# L-80 EUE 44 — Production Casing Leak (between 6,180'RKB and 6,200'RKB) Production Tie-Back Liner: 5 Ifs 4-1/2" 11.6# L-80 HYD 513 (N Production Tubing: t R. 3��'I /R J,r 2-3/8"4.6#L-80 IBT a 1- k e \`0 crnl� q f— Bak CMU tiding Sleeve w/1.875"'X'Nipple a.VG_c n i 6p p;' t-e ,� • w, 11 yrr,,I tv/Us, pu,-t-eof rr .rip 1 &is0 ✓af le �– 20'Baker SBE w/Baker 40-26 GBH-22 Locator Seal Assembly `. = 4— Baker 80-40 Casing Seal Recepticle w/15' IWO Baker GBH-22 Seal Assembly J1 Bermuda Perforations Last Updated: 2-Aug-13 Updated by: JRC . KUP 2N-304 ConocoPhillips i,"� ,'3` Well Attributes Max Angle&MD TD . Alaska,Inc Welibore API/UWI Field Name Well Status Inc!(°) MD(ftKB) Act Btm(ftKB) . ([xncnNWhps 501032038200 TARN PARTICIPATING AREA PROD 68.37 2,808.89 10,052.0 Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date "' SSSV:NIPPLE 60 1/14/2010 Last WO: 2/19/2013 40.54 8/15/2001 Well Config:-2N-304,326/20131 37:15 PM Schematic•Actual Annotation Depth(ftKB) End Date Annotation Last Mod...End Date Last Tag:SLM 9,608.0 12/4/2012 Rev Reason:Show SS Closed,SOV NOT sheared osborl 3/26/2013 Casing Strings HANGER.29 ;.. Casing Description String 0... String ID...'Top(ftKB) Set Depth(f...Set Depth(ND)...String Wt...String.. String Top Thrd mg! CONDUCTOR 16 15.062 35.0 152.0 152.0 62.58 H-40 WELDED ....,,i Casing Description String 0... String ID...Top(ftKB) Set Depth(t...Set Depth(ND)...String Wt...String...String Top Thrd Fp SURFACE 75/8 6.875 34.2 2,930.3 2,305.5 29.70 L-80 BTCM Casing Description String 0... String ID...Top(ftKB) Set Depth(f...Set Depth(TVD)...String Wt..String...String Top Thrd PRODUCTION 51/2 4.950 31.4 10,037.0 5,862.5 15.50 L-80 BTCM P 5.5"x3.5"@ 9262' 7 Tubing Strings 71 Tubing Description String 0... String ID...Top(ftKB) Set Depth(f...Set Depth(ND)...String Wt..String...String Top Thrd TUBING WO 3 1/2 2.992 29.5 9,247.0 5,244.7 I 9.30 L-80 I IBTM Completion Details CONDUCTOR. Top Depth 35-152 (TVD) Top Intl Noml... Top(ftKB) (ftKB) (°) Item Description Comment ID(In) MI 29.5 29.5 0.80 HANGER FMC GEN V TUBING HANGER 3.500 NIPPLE,511 art 510.8 510.5 4.98 NIPPLE CAMCO'DS'NIPPLE w/2.875"PROFILE 2.875 IV 9,178.0 5,193.9 42.84 SLEEVE-C BAKER HB MODEL CMU SLIDING SLEEVE w2817'DS PROFILE 2.812 (RAN CLOSED) 9,229.3 5,231.5 41.63 LOCATOR BAKER NO GO LOCATOR 2.970 9,230.1 5,232.1 41.63 SEAL ASSY BAKER GBH-22 BONDED SEAL ASSEMBLY 2.970 Other In Hole(W!reline retrievable plugs,valves,pumps,fish,etc.) Top Depth (ND) Top Intl ACE. Top(ftKB) (ftKB) (°) Description Comment Run Date ID(In) SURF 9,283.0 5,271.6 41.40 CATCHER CATCHER SET ON TOP OF WRP 1/10/2013 0.000 9,290.0 5,276.9 41.38 PLUG 2.69"WRP 1/7/2013 0.000 MI Perforations&Slots GAS LIFT, Shot 3.117 Top(ND) Bim TVD ( ) Dens Top(ftKB)Btm(ftKB) (ftKB) (ftKB) Zone Date (oh... Type Comment 9,592.0 9,602.0 5,506.8 5,514.6 BERMUDA, 11/122001 4.0 IPERF 2.5"HSD,BH Chgs,180 deg phase, 2N-304 45/227 deg orient ■ IR Stimulations&Treatments GAS LIFT, Bottom 5.591 ': Min Top Max Btm Top Depth Depth - Depth Depth (ND) (TVD) (ftKB) (ftKB) (ftKB) (ftKB) Type Data Comment IIIII 9,592.0 9,602.0 5,506.8 5,514.6 FRAC 11/17/2001 BERMUDA FRAC,219,0008 12/18 CARBOLITE,10 PPA ON PERFS GAS LIFT,_ Emil Notes:General&Safety ' End Date Annotation 11/19/2010 NOTE:View Schematic w/Alaska Schematic9.0 2/19/2013 NOTE:POST WO-final pressure test up to 3400 psi on 3500 psi test,CSG lost pressure;Engr reviewing GAS LIFT, Li. 9,445 GAS LIFT, 9.122 SLEEVE-C. 9,176 . .].. LOCATOR, 9,229 l SEAL ASSY, 9,230 CATCH,29ER,3 9 PLUG,9.290 MandfBt Details A1 D ilm -44U`, Top Depth Top Port S,,, (ND) Inc! OD Valve Latch Size TRO Run N...Top(ftKB) (ftKB) (°( Make Model (In) Sery Type Type (in) (psi) Run Date Corn... 1 3,117.2 2,393.9 60.48 Camco KBG-2-9 DMY Integ... 1.000 2/17/2013 IPERF. 1 3,117.2 2,393.9 60.48 Camco KBG-2-9 1 GAS LIFT DMY INT 0.000 0.0 2/18/2013 9592-9,602-\\ _. 2 5,591.3 3,493.0 64.87 Camco KBG-2-9 Dummy Integ... 1.000 2/17/2013 FRAC,9592 I 2 5,591.3 3,493.0 64.87 Camco KBG-2-9 1 GAS LIFT DMY INT 0.000 0.0 2/17/2013 3 7,263.7 4,247.9 63.22 Camco KBG-2-9 Dummy Integ... 1.000 2/172013 3 7,263.7 4,247.9 63.22 Camco KBG-2-9 1 GAS LIFT DMY INT 0.000 0.0 2/17/2013 4 8,444.6 4,785.5 64.16 Camco KBG-2-9 1 GAS LIFT DMY INT 0.000 0.0 2/172013 PRODUCTION 5.5'035"ill 4 8,444.6 4,785.5 64.16 Camco KBG-2-9 Dummy Integ... 1.000 2/17/2013 31-10,0L It 9,122.4 5,153.7 43.53 Camco KBG-2-9 1 GAS LIFT SOV INT 0.000 0.0 2/172013 NOT TD(2N-3044), Shear 10,052 r STATE OF ALASKA ALA OIL AND GAS CONSERVATION COMOSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Abandon la Repair w ell giv Rug Perforations r Perforate E Other f Alter Casing r Rill Tubing F.- Stimulate - Frac I"`"` Waiver r Time Extension E Change Approved Program i'"°Operat. Shutdow n E Stimulate - Other I Re -enter Suspended Well j'"°° 2. Operator Name: 4. Well Class Before Work: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development Id Exploratory [ _ _ 201 -130 3. Address: 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 Stratigraphic J" Service 50- 103 - 20382 -00 7. Property Designation (Lease Number): 8. Well Name and Number: ADL 380053 - 2N -304 9. Logs (List Togs and submit electronic and printed data per 20AAC25.071): 10. Field /Pool(s): none Kuparuk River Field / Tarn Oil Pool 11. Present Well Condition Summary: Total Depth measured 10052 feet Plugs (measured) 9290 true vertical 5875 feet Junk (measured) none Effective Depth measured 9911' feet Packer (measured) none true vertical 5760 feet (true vertical) none Casing Length Size MD TVD Burst Collapse CONDUCTOR 117 16 152 152 SURFACE 2896 7.625 2930 2306 PRODUCTION 10006 5.5 10037 5863 RECEIVED a• M =a.R 12, f'O; Perforation depth: Measured depth: 9592 -9602 { True Vertical Depth: 5507 - 5515 " E '�' SCANNED AFR 19 2013 Tubing (size, grade, MD, and TVD) 3.5, L -80, 9247 MD, 5245 TVD Packers & SSSV (type, MD, and TVD) no Packer no SSSV 12. Stimulation or cement squeeze summary: Intervals treated (measured): not applicable Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil - Bbl Gas - Mcf Water - Bbl Casing Pressure Tubing Pressure Prior to well operation shut - Subsequent to operation shut - 14. Attachments 15. Well Class after work: Copies of Logs and Surveys run Exploratory 1 Development Ni - Service r Stratigraphic r 16. Well Status after work: ®Oil I✓ Gas E WDSPL E Daily Report of Well Operations xxX GSTOR E WINJ I"` WAG E GINJ r SUSP E SPLUG r 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: none Contact Jonathan Coberly (a 265 -1013 Email Jonathan.Coberly a.conocophillips.com Printed Name Jonathan Cobe Title Wells Engineer Signature Phone: 265 -1013 Date 3 ..1/ -2015 RBDMS MAR 12 2013 -X " �'- 4 Form 10 -404 Revised 10/2012 Ad 1'2' 113 Submit Original Only KUP 2N -304 Conoc 040 Well Attributes Max Angle & MD TD Alaskd. Ill(;. Wollbore APSUWI Field Name Well Status Inc' ( °) MD OMB) Act Btm (ftKB) 501032038200 TARN PARTICIPATING AREA PROD 68.37 2,808.89 10,052.0 GanocciPhilitps Comment H2S (ppm) Date Annotation End Date KB-Ord (11) Rig Release Date - SSSV: NIPPLE 60 1/14/2010 Last WO: 2/19/2013 40.54 8/15/2001 Well Canna: -2N -304, 2/22/20136:46.11 AM Schematic - Aetoi Annotation Depth (ftKB) End Date Annotation Last Mod ...774 Last Tag: SLM 9,608.0 12/4/2012 Rev Reason: WORKOVER osborl 2/21/2013 Casing Strings Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd HANGER. 29 A IMI CONDUCTOR 16 15.062 35.0 152.0 152.0 62.58 H WELDED ", Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD( ... String Wt... String ... String Top Thrd "./ SURFACE 75/8 6.875 34.2 2,930.3 2,305.5 29.70 L - 80 BTCM Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd PRODUCTION 51/2 4.950 31.4 10,037.0 5,862.5 15.50 L -80 BTCM 5.5 "x3.5" @ 9262' { Tubing Strings ` Tubing Description String 3 0... String ID 2 ... Top (ft 29. K 5 B) Set 9 Dept7.h 0 (1... Set Depth 5 (TVD)... String 9 L -8 Wt... String 0 ... String TIBTop M Thrd TUBING WO I 1/2 I I I I Completion Details Top Depth CONDUCTOR, 35152 (TVD) Top Inc! Nomi... RKB) ption Top (ftKB) ( 0) Item Desert Comment ID (in) IN 29.5 29.5 0.80 HANGER FMC GEN V TUBING HANGER 3.500 NIPPLE, 511 - - 1 L f 510.8 510.5 4.98 NIPPLE CAMCO'DS' NIPPLE w /2.875" PROFILE 2.875 n , 9,178.0 5,193.9 42.84 SLEEVE BAKER HB MODEL CMU SLIDING SLEEVE w/2812" DS PROFILE 2.812 9,229.3 5,231.5 41.63 LOCATOR BAKER NO GO LOCATOR 2.970 9,230.1 5,232.1 41.63 SEAL ASSY BAKER GBH -22 BONDED SEAL ASSEMBLY 2.970 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) 1 1j Top Depth 11 II (TVD) Top Incl Top (ftKB) (ftKB) 0) Description Comment Run Date ID (in) SURFACE, J IL 9,283.0 5,271.6 41.40 CATCHER CATCHER SET ON TOP OF WRP 1/10/2013 0.000 34 9,290.0 5,276.9 41.38 PLUG 2.69" WRP 1/7/2013 0.000 Perforations & Slots l Shot GAS LIFT. (TVD) Btm (TVD) Darts 3.117 - Top (RKB) Btm (RKB) (ftKB) (ftKB) Zone Date (sh °. Type Comment - 9,592.0 9,602.0 5,506.8 5,514.6 BERMUDA, 11/12/2001 4.0 IPERF 2.5" HSD, BH Chgs, 180 deg phase, . Stimulations & Treatments 2N -304 45/227 deg orient - Bottom GAS LIT, _ Min Top Max Btm Top Depth Depth .1 Depth Depth (TVD) (TVD) (ftKB) (MB) (ftKB) (ftKB) Type Date Comment - 9,592.0 9,602.0 5,506.8 5,514.6 FRAC 1 1/17/2001 BERMUDA FRAC, 219,000# 12/18 CARBOLITE, 10 PPA ON PERFS Notes: General & Safety GAS LIF, End Date Annotation 7'26T4 _ _ _ 11/19/2010 NOTE: View Schematic w/ Alaska Schematic9.0 9/10/2011 NOTE: LEAK DETECT LOG - LEAK ZONES @ 5948' 8 5476 2/19/2013 NOTE: POST WO -final pressure test up to 3400 psi on 3500 psi test, CSG lost pressure; Engr reviewing Ell GAS LT, e ,a IF as 1 GAS LIFT, 9,122 - SLEEVE. 9,178 Ell LOCATOR, - 9.229 SEAL ASSY. 9.230 t lr CATCHER, 9,263 `•• PLUG.9,290 Mandrel Details Top Depth Top Port (TVD) Inc' OD Valve Latch Size TRO Run N... Top(ftKB) (RKB) 0) Make Model (in) Sere Type Type (In) (psi) Run Date Com... 1 3,117.2 2,393.9 60.48 Camco KBG -2 -9 1 GAS LIFT DMY INT 0.000 0.0 2/18/2013 IPERF, 2 5,591.3 3,493.0 64.87 Camco KBG -2 -9 1 GAS LIFT DMY INT 0.000 0.0 2/17/2013 RAC. 9,592 - - 3 7,263.7 4,247.9 63.22 Camco KBG -2 -9 1 GAS LIFT DMY INT 0.000 0.0 2/17/2013 9,592 It. 4 8,444.6 4,785.5 64.16 Camco KBG -2 -9 1 GAS LIFT DMY INT 0.000 0.0 2/17/2013 5 9,122.4 5,153.7 43.53 Camco KBG -2 -9 1 GAS LIFT SOV INT 0.000 0.0 2/17/2013 PRODUCTION 5.550.5"e 9282', 31- 10,037 , TD (2N-304). 10,052 • • ConocoPhillips Time Log & Summary We {/New Web Reporting Report Well Name: 2N - 304 Rig Name: NORDIC 3 Job Type: RECOMPLETION Rig Accept: 2/9/2013 9:30:00 PM Rig Release: 2/19/2013 4:00:00 PM Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 02/07/2013 24 hr Summary Move Nordic Rig 3 from 2T -pad to 2M -Pad. Went on Cold Shutdown @ 17:45 hrs 12:00 18:00 6.00 MIRU MOVE MOB P Move Nordic Rig 3 from 2T -pad to 2M -Pad. 18:00 00:00 6.00 MIRU MOVE MOB T Field went on Cold Weather Shutdown @ 17:45 hrs on 2 -7 -13. Set rig down and Standby for weather. 02/08/2013 Cold weather restrictions lifted at 15:00 and continue moving Nordic Rig 3 from 2M -Pad toward 2N -304. 00:00 15:30 15.50 MIRU MOVE MOB T Standby on 2M Pad for Cold Weather Restrictions to lift 15:30 20:30 5.00 MIRU MOVE OTHR P Cold Weather Restrictions lifted at 15:17 hrs, Mobilize Peak cats from Dead Horse, warm up drive system during waiting period. 20:30 00:00 3.50 MIRU MOVE MOB P Begin moving rig from 2M -pad towards 2L -Pad 02/09/2013 Continue moving Rig to 2N -304, Spot Rig and Berm Up, RU Equipment 00:00 06:15 6.25 MIRU MOVE MOB P Continue moving rig from 2M -pad to 2N -304 06:15 12:30 6.25 MIRU MOVE MOB T Rig on hold- cold weather shut down @ 06:15 hr at 2N -304, man camp on 2T -08 12:30 20:30 8.00 MIRU MOVE RURD P Weather Restrictions lifted. PJSM, Set 30'x30' Liner withT -Mats around Well, Hang Tree in Cellar, Set 100'x50' Liner with Plywood for Rig. 20:30 21:30 1.00 MIRU MOVE RURD P Pull over Well witness by DSO Suitor, Spot and Level Rig, Nordic Rig #3 accepted at 21:30 hrs. 21:30 00:00 2.50 MIRU MOVE RURD P Berm Up Rig and spot Equipment 02/10/2013 Pull BPV, Circulate well to 8.6 ppg SW, Perform 30 minute No Flow Test, Install BPV and test to 1k psi from below- down IA. ND Tree, Install Blanking Plug. NU 11" BOPE. 00:00 07:00 7.00 MIRU MOVE RURD P Load pits with 530 bbls of sea water. Spot and berm up Kill Tank and RU Hardine. Continue prepping location. 07:00 09:30 2.50 COMPZ WHDBO MPSP P pre -job safety meeting with FMC service , load lubicator on rig. pick up and make up to XMas tree. Test, lubicator to 1500 psi OK. remove, BPV. jaid down and load out lubicator. Page 1 of 8 • • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 09:30 10:00 0.50 COMPZ WHDBO PRTS P help PJSM blow air thru killline to tank pumped 20 bbls of 9.5# brine. tested line to 250,3500 psi monitor line for leaks. Test ok. 10:00 12:00 2.00 COMPZ WELCTI KLWL P opened up well tubing 20 psi entercasing 20 psi, outercasing 250 psi. reverse circulate well with 200 bbls of sea water ICP 680 psi @ 2BPM . sea water surface to surface. in crease on OA of 120 psi = 350 psi. FCP = 1300 psi @2BPM 12:00 14:00 2.00 COMPZ WELCTL OPNW P Monitor well for flow for while waiting for well head hand to arrive from KOC - had small flow, close in showed 30 psi. 14:00 16:00 2.00 COMPZ WELCTL CIRC P Circulate with 191 bbls of 8.5+ ppg Sea water, surface to surface @ 2 bpm @ 680 psi. 16:00 17:00 1.00 COMPZ WELCTL OWFF P Monitor well, slight flow. SWI, allow to balance and open well up with no flow. Monitor well for 30 minutes - No flow. 17:00 17:30 0.50 COMPZ WHDBO MPSP P Set BPV and test from below at 250 / 1,000 psi for 10 minutes - good test. 17:30 18:30 1.00 COMPZ WHDBO NUND P PJSM, ND Tree and Install Blanking Plug 18:30 00:00 5.50 COMPZ WHDBO NUND P PJSM, NU 11" BOPE 02/11/2013 Test BOPE 250 / 3500 psi, Pull Blanking Plug and BPV, Unland Hanger and circulate 8.6 ppg SW, Load tally and drfit PH -6 DP. 00:00 07:30 7.50 COMPZ WHDBO BOPE P PJSM, Conduct Initial BOPE Test @ 250 / 3,500 psi w/3 -1/2" testloint. 24 hr notice was given to AOGCC on 2 -8 -13 @ 19:08 hrs and Right to witness _wa_ was waived byChuck Sheve on 2 -8 -13 @ 19:21 hrs. Conduct Draw down System Pressure - 2900 psi After Closure - 1850 psi 200 PSI gain - 18 seconds System Pressure - 96 Seconds 4 -N2 bottle ave. - 2000 psi 07:30 08:00 0.50 COMPZ WHDBO BOPE P PJSM RD test equipment and blew down hard line 08:00 09:00 1.00 COMPZ WHDBO BOPE P PJSM pulled BPV. 09:00 10:00 1.00 0 9,250 COMPZ WHDBO BOPE P PJSM install landing jt. IA had small flow riggged up 2" hose and monitor well. Well stabilized no flow. RD hose. Page 2 of 8 Time Logs • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 10:00 12:00 2.00 9,250 9,250 COMPZ RPCOM PULL P Backed out hanger retention screws and tested to 250/ 3500 psi for 10 mins. pulled up to 200K including block weight. seal assembly didnot pull free, pressured up on tubing to 1800 psi and hydrauliced out seal assembly. 12:00 13:30 1.50 9,250 9,250 COMPZ RPCOM CIRC P circulated convetional with 220 bbls sea water 8.5# @ 950 psi @ 2 BPM 13:30 16:00 2.50 9,250 9,150 COMPZ RPCOM PULL P worked tubing up to 9150 ft. while circulating conventional @ 900 psi with tubing dragging 20K over. Laid down hanger and pulled pup jts and 1 jt 3.5 9.3# L -80 8rd tubing. 16:00 00:00 8.00 9,150 9,150 COMPZ RPCOM CIRC P Circulate well Conventional w/ 8.5# sea water. uploaded 3.5 PH -6 hydril tubing into the pipe shed. 02/12/2013 Load, Rack, Drift and Tally PH -6 DP while circulating 8.6 ppg SW at 1.5 bpm- 980 psi. POOH Laying down 3 -1/2" Tubing to 8700', Pulling heavy 80k# drag. Pump out each Joint with Top Drive at 1.5- 3 bpm. 00:00 16:30 16.50 9,150 9,150 COMPZ RPCOM CIRC P Circulate well Conventional w/ 8.6# sea water. uploaded 3.5 PH -6 hydril tubing into the pipe shed and drift with 2.625" 1.5 bpm @ 980 psi. 16:30 17:00 0.50 9,150 9,150 COMPZ RPCOM SFTY P 30 Minute static test - pass. PJSM for POOH. 17:00 23:30 6.50 9,150 8,700 COMPZ RPCOM PULL P Inital P/U weight 135K, started to increase in drag up to 180K. Work first joint up /down. 185K up / 65K down. Start pumping and work first joint up P/U weight 140K. 1 bpm @ 280 psi. 1.5 bpm 980 psi. Add 2 Drums of 776 for concentration of —0.6% and vis up fluid to 35 lsrv. Continue Pumping out to 8700', up 90k #, down 50k #. 23:30 00:00 0.50 8,700 8,700 COMPZ RPCOM CIRC P Circulate Bottoms Up at 3 bpm - 1280 psi. Medium to Heavy fine scale returns over shaker. 02/13/2013 Finish POOH with 3 -1/2" Tubing- extensive external corrosion noted on tubing from 6420' - 5056' with aditional areas of isolated pittin from 5400' to surface, MU 5 -1/2" Casing Scraper BHA #1 and RIH to 800' at midnight. 00:00 00:30 0.50 8,700 8,700 COMPZ RPCOM CIRC P Continue to circulate Bottoms Up at 3 bpm - 1280 psi. Medium to Heavy fine scale returns over shaker. 00:30 02:00 1.50 8,700 8,300 COMPZ RPCOM PULL P Continue Pumping out of the hole. Pulling 90 k# while pumping at 3 bpm - 650 psi. 02:00 09:00 7.00 8,300 6,400 COMPZ RPCOM PULL P Blow Down Top Drive and Continue POOH dry. 100k# up wt with pumps off. 09:00 17:30 8.50 6,400 0 COMPZ RPCOM PULL P Joints number 91 - 135 had heavy scale build up. Joints number 91 - surface sections of pitting & erosion. Pictures taken and flagged the pipe. Page 3 of 8 • • Time Logs Date From To Dur S. Depth E. Death Phase Code Subcode T Comment 17:30 19:30 2.00 0 0 COMPZ RPCOM PULD P Load Tools, Clear Floor, and Prep to Pick up BHA #1 - 5 -1/2" Casing Scraper 19:30 20:30 1.00 0 0 COMPZ RPCOM PRTS P PJSM, Pressure Test Casing - 1500 psi for 15 minutes. Good Test 20:30 22:30 2.00 0 0 COMPZ RPCOM PULD P PJSM, PU BHA #1. Casing Scraper. 22:30 23:00 0.50 0 0 COMPZ RPCOM PULD P PJSM, Changeout Floor Equipment. RD Eckles due to difficulty biting on short PH -6 DP Tool Joints. RU Spinners. 23:00 00:00 1.00 0 800 COMPZ RPCOM TRIP P PJSM, PU PH6 DP and RIH to 800'. Up 42k #. 02/14/2013 Clean Casing with 5 -1/2" Casing Scaper Assembly BHA #1 to 9252', Circulating BU until clean every 2000' 00:00 02:00 2.00 800 2,000 COMPZ RPCOM TRIP P Continue RIH from 800' to 2000'. Up 55k# 02:00 02:30 0.50 2,000 2,000 COMPZ RPCOM CIRC P Circulate 33 bbls at 4 bpm at 500 psi. Minimal Returns 02:30 04:30 2.00 2,000 4,000 COMPZ RPCOM TRIP P Continue RIH from 2000' to 4000'. Upwt72k# 04:30 07:00 2.50 4,000 4,000 COMPZ RPCOM CIRC P Circulate at 3 bpm - 360 psi. Heavy Returns over Shakers. Circulate 100 bbls until clean. Conduct No -flow check. Stop Totco data for 15 minutes while extracting previous well file. Continue with job. 07:00 09:30 2.50 4,000 6,000 COMPZ RPCOM TRIP P Continue to RIH to 6000' 09:30 10:30 1.00 6,000 6,000 COMPZ RPCOM CIRC P Circulate B/U - 93K up 72K down weight. Pumping 4 bpm @ 740psi. Schmoo coming across the shakers. Cleaned up, pumped total 145 bbls. Flow check for 15 minutes. 10:30 12:30 2.00 6,000 8,000 COMPZ RPCOM TRIP P Continue to RIH to 8000' 12:30 17:00 4.50 8,000 9,103 COMPZ RPCOM CIRC P Circulate B/U - Up 110K / Down 72K - Pumping 5 bpm @ 1380 psi. Heavy scale, sand and schmoo coming over the shakers. Pumped total of 647 bbls while cycling pipe for good clean up. Roughly 6.5 B /U. Flo -check for 15 minutes. Continue to RIH to 9103'. Up 155k #, Down 85k# 17:00 18:30 1.50 9,103 9,252 COMPZ RPCOM TRIP P Wash down to 9252' with Mule Shoe no -go to 9242'. Down Weight 84K, • Up weight 105K prior to Tag. 18:30 20:00 1.50 9,252 9,252 COMPZ RPCOM CIRC P Work Pipe up and down while circulate —3 bottoms up 338 bbls at 5 bpm- 1450 psi. Medium returns taper off to light. BDTD 20:00 21:00 1.00 9,252 7,500 COMPZ RPCOM TRIP P PJSM, POOH to 7500'. Up 105k #, down 78k# 21:00 22:00 1.00 7,500 7,500 COMPZ RPCOM CIRC P Circulate 113 bbls at 5bpm - 1180 psi. Light solid returns over shakers. BDTD 22:00 23:00 1.00 7,500 9,250 COMPZ RPCOM TRIP P PJSM, RIH to 9230' and wash down to 9252', Tag no -go, pull up 2'. Page 4 of 8 • • Time Logs Date From To Dur S. Depth E. Death Phase Code Subcode T Comment 23:00 00:00 1.00 9,250 9,250 COMPZ RPCOM CIRC P Circulate 220 bbls at 5 bpm - 1450 psi. Very light solids over shakers. 02/15/2013 POOH with 5 -1/2" Casing Scraper from 9250' laying down DP, PT Casing to 2500 psi- good test, RU HES _ Eline and log CAST M from 9240' to surface for 5 -1/2" Casing corrosion inspection. 00:00 02:00 2.00 9,250 - 9,250 OMPf RPCOM — CIRC P At 9250', Pump 35 bbls FlowZan Sweep followed by 210 bbls of clean 8.6 ppg SW at 3 bpm- 1000 psi. BDTD 02:00 06:30 4.50 9,250 6,400 COMPZ RPCOM TRIP P PJSM, POOH with BHA #1, Laying Down DP. 06:30 08:00 1.50 6,400 6,400 COMPZ RPCOM CIRC P Hi -line power tripped off. Stop and switch power back to rig supply. Ciculate B/U while waiting on power swap & unload DP from shed. Circulate 108 bbls at 5 bpm at 1580 psi- Clean Returns. BDTD 08:00 15:00 7.00 6,400 491 COMPZ RPCOM TRIP P Continue TOOH laying down DP to 491', NFT, Static 15:00 16:30 1.50 491 0 COMPZ RPCOM PULD P PJSM, LD BHA #1 Casing Scraper 16:30 18:00 1.50 0 0 COMPZ RPCOM PRTS P PJSM. PT 5 -1/2" Casing to 2500 psi for 30 minutes and chart. OA 150 psi before and after. Good Test. 18:00 18:30 0.50 0 0 COMPZ RPCOM PULD P PJSM. Rig up Dutch Riser. 18:30 00:00 5.50 0 0 COMPZ RPCOM ELOG P PJSM with HES E -Line. RU and RIH with CAST -M Log to 9240' and log to Surface at 20 fpm. 02/16/2013 Log CAST -M from 9240' to Surface for Casing internal corrosion inspection. Rig Down HES E -Line. Pick up and run 3 -1/2" Completion- in progreess. 00:00 06:30 6.50 0 0 COMPZ RPCOM ELOG P PJSM with HES E -Line. RU and RIH with CAST -M Logto 9240' and log Q_ Surface at 20 fpm. Rig down E -line, continue to Load, Drift and Strap Completion 06:30 13:00 6.50 0 0 COMPZ RPCOM PUTB P Rig down Dutch riser, load, strap and tally completion string. Load into liner tally for proper completion space out. Inspect casing Togs. 13:00 13:30 0.50 0 0 COMPZ RPCOM PULD P PJSM - Running completion string. P/U & inspect seal assembly. 13:30 18:00 4.50 0 2,800 COMPZ RPCOM RCST P Start to RIH with completion string as per tally to 2800'. 56k# up 18:00 20:00 2.00 2,800 2,800 COMPZ RPCOM SFTY P Safety review of well control incident. 20:00 00:00 4.00 2,800 6,260 COMPZ RPCOM RCST P Continue RIH with completion string as per tally to 6260'. 75k# up 02/17/2013 Locate and Spaceout 3 -1/2" Completion, Circulate 180 bbls of Corrosion Inhibited SW. Land Hanger, PT Tbg 1; 13000 psi- Pass. Casing PT failed at 3400 psi. Set TWC and ND BOPE. NU Tree, PT Tree and Hanger PO 250 / 5000 psi- Pa ss. _ 00:00 03:00 3.00 6,260 9,210 COMPZ RPCOM RCST P Continue RIH with completion string as per tally from 6260' to 9210'. 95k# up, 73k# Down Page 5 of 8 • • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 03:00 04:30 1.50 9,210 9,251 COMPZ RPCOM RCST P Continue RIH pumping 3/4 bpm and pressure up to 160 psi at 9235'. Continue on down 16' and stack out 7k# at 9251'. Pressure up to 400 psi down tubing and hold. No flow, seals engaged. Space out does not require any pups giveing a 6.74' spaceout. 04:30 06:30 2.00 9,251 9,210 COMPZ RPCOM CIRC P Pull up and lay down two joints and MU Hanger. RI and reverse circulate 180 bbls of Corrosion Inhibited Brine at 3 bpm. 06:30 07:30 1.00 9,210 9,251 COMPZ RPCOM THGR P Drain the stack, Land 11" X 3.5" tubing hanger, RILDS. Up weight 95K / 73K down. 07:30 09:30 2.00 9,251 9,251 COMPZ RPCOM PRTS P Set up rig floor and cellar to pressure test. Start pressure = Tubing 0, IA 0, OA = 150 Tubing test 3000_psi -_good test for 15 minutes, IA 0, OA 150, bleed tubing down to 2500 psi. Start testing IA - tubing pressure climbed to 3000 psi with IA, bleed tubing down to 2500 again, IA 3000 psi. Increase IA to 3400 psi and pressure dropped off to 40_0 psi, Tubing pressure dropped to 2200 psi. OA 200 psi. 09:30 11:30 2.00 9,251 9,251 COMPZ RPCOM PRTS X Double isolate all surface valves to IA. Test one more time to eliminate surface lines. Start IA 400 psi, Tubing 2200psi, OA 200 psi Increase IA to 1000 psi, Tubing increased to 2500 psi, OA no change 200 psi. Bleed down IA to zero & tubing slightly dropped to 1900 psi. (Slow leak off) Bleed down tubing to zero - IA slowly climbing to 200 psi. Call town to discuss options. Bleed IA to zero, slow climb to 100 psi. 11:30 12:30 1.00 9,251 9,251 COMPZ RPCOM PRTS X Bleed IA down to zero, no build up. Set up to pump down the tubing to 3500 psi to test Tubing string & lower WRP @ 9290'. Start Tubing zero, IA zero, OA 150 Finish tubing 3480, IA 190 psi, OA 150. Hold for 5 minutes. Slight leak off on IA from 190 down to 160. Tubing pressure tested. 12:30 13:00 0.50 9,251 9,220 COMPZ RPCOM SFTY X No flo check - PJSM for unlanding completion string and tubing hanger. Page 6of8 • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 13:00 15:00 2.00 9,220 9,220 COMPZ RPCOM PRTS X BOLDS - P/U tubing hanger to the rig floor P/U weight 95K. Combo test against WRP - started to inject after 800 psi, pumping 12 spm, slolwy pressure up to 1100 psi. Shut down, leak off to 600 psi. Test Failed. Bleed off. Called town. 15:00 17:00 2.00 9,220 0 COMPZ RPCOM PRTS X No flow test, PJSM - land seal assembly and tubing hanger. Pressure test Tubing to 3000 psi for 30 minutes against WRP. Good Test. 17:00 17:30 0.50 0 0 COMPZ RPCOM MPSP P Lay down Landing Joint. Install TWC. 17:30 20:00 2.50 0 0 COMPZ RPCOM NUND P PJSM, ND BOPE 20:00 22:00 2.00 0 0 COMPZ RPCOM NUND P PJSM, NU Tree Adapter and Tree 22:00 00:00 2.00 0 0 COMPZ RPCOM PRTS P Test Packoff Void 250/5000 psi - Good test. Test Tree 250 / 5000 psi - Good test. 02/18/2013 Pull TWC. Slip and Cut Drill Line. RU SL and Pull DV from GLM #1 at 3117', LRS Freeze Protect Well with 65 bbls diesel, Reset DV in GLM #1, RD SL, Set BPV. Prepare to RDMO- Weather Hold 00:00 01:30 1.50 0 0 COMPZ RPCOM PRTS P Continue Test Tree 250 / 5000 psi - Good test. 01:30 02:00 0.50 0 0 COMPZ RPCOM MPSP P Pull TWC 02:00 03:30 1.50 0 0 COMPZ RPCOM SLPC P Slip and Cut Drill Line 03:30 07:30 4.00 0 0 COMPZ WHDBO OTHR T Waiting on Weather 07:30 12:00 4.50 0 0 COMPZ WHDBO RURD P PJSM with Nordic, HES, LRS for rigging up to freeze protect well. Discuss cold weather operations, secondary containment and well requirements. Start spotting equipment and riggin up SL. Load lubricator into the rig & put the loader back in the shop. Heat up diesel to 70 degrees, rig up LRS to cellar squeeze manifold. Hook up and pressure test lines and HES lubricator to the tree. 12:00 13:30 1.50 0 0 COMPZ WHDBO PRTS P Crew change - PJSM for freeze protecting the well. Pressure test Lubricator and tree. 13:30 16:00 2.50 0 0 COMPZ WHDBO FRZP P RIH - Pull Dummy valve in GLM #1 (3117') Equalize between Tubing & IA. POOH. Freeze protect pumping down IA taking returns up the tubing using 64 bbls of 70 degree diesel. 2 bpm - 600 psi. 16:00 17:00 1.00 0 0 COMPZ WHDBO MPSP P RIH & set Dummy valve in GLM #1 (3117'). POOH 17:00 18:00 1.00 0 0 COMPZ WHDBO PRTS P Pressure test tubing & Dummy valve to 3000psi. Good test. 18:00 19:30 1.50 0 0 COMPZ WHDBO RURD P FJS1VIr ig W SL°LRS 19:30 20:00 0.50 0 0 COMPZ WHDBO MPSP P Set BPV Page 7 of 8 s • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 20:00 21:00 1.00 0 0 COMPZ WHDBO RLOC P Dress Tree and secure Cellar 21:00 00:00 3.00 0 0 DEMOB MOVE OTHR T Cold Weather Shut Down 02/19/2013 Cold Weather Shutdown- RDMO Rig release at 16:00 hrs. 00:00 12:00 12.00 0 0 DEMOB MOVE OTHR T Cold Weather Shut Down. Waited for the temperatures to rise above Minus 40. Cold Weather vairance signed and PJSM discussed regarding personnel, equipment and third party requirements. 12:00 16:00 4.00 0 0 DEMOB MOVE MOB P RDMO, Pull off the well, dispatch Peak trucks to move the camp. " *RIg Release @ 16:00 hrs * "* I I Page 8 of 8 • •. 2.0V 2.oeC WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. September 15, 2011 Attn.: Howard Okland 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 SCANNED APR 2 3 2013 RE: Leak Detect Log: 2N -304 Run Date: 9/10/2011 The technical data listed below is being submitted herewith. Pleas a ddress afly problems or concerns to the attention of: Klinton Wood, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 2N -304 Digital Data in LAS format, Digital Log Image file 1 CD Rom 50- 103 - 20382 -00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Klinton Wood 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907 - 273 -3527 Fax: 907 - 273 -3535 klinton.wood @halliburton.com Date: ` 4 6 0 1 IA Signed: Saa" 8544. • • WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. August 24, 2011 Attn.: Howard Okland 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 r `)(? RE: Multifinger Imaging Tool (MIT): 2N -304 Run Date: 8/10/2011 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Klinton Wood, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 2N -304 Digital Data (LAS), Digital Log file, Casing Inspection Report, 3D Viewer 1 CD Rom 50-103-20382-00 \, (Atitj\ PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Klinton Wood 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907 - 273 -3527 Fax: 907 - 273 -3535 klinton.wood @halliburton.com Date: Signed: la Cia • plIS l — 13 0 Ill • WELL LOG TRANSMITTAL II° PROACTIVE DIAGNOSTIC SERVICES, INC. To: AOGCC Christine Mahnken 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 (907) 659 -5102 AYEC) AUG ` .' 20'!) 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 attention of : ProActive Diagnostic Services, Inc. RECEIVED Attn: Robert A. Richey 130 West International Airport Road AUG 1 9 2011 Suite C Anchorage, AK 99518 Fax: (907) 245 -8952 - ON • -' 1 A 1) Cali. :e.ort 09- Aug -11 2L -307 1 Report / CD 50- 103- P6'EB2 -00 / 2) Caliper Report 10- Aug-11 2N -304 1 Report / CD - 1 1 '1 71 6 .� 03 8.t Signed • , ■ I / • Date : 2 N A- v` . ( L Print Name: ��".►w -Z �`la.�� PROACTIVE DIAGNOSTIC SERVICES, INC., 130 W. INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907)2454951 FAx: (907)245 -8952 E-MAIL : PDSANCHORAGEOMEMORYLOG.COM WEBSITE : WWW.MEMORYLOG.COM D:\Archives\MIT Archives \ 2011\ 08- August\2L- 307 \CPAI_Kup_Caliper_Template \CD_ Parts \ConocoPhillips_Transmit.docx a_cS i_J I • • Multi- Finger Caliper I Log Results Summary I Company: ConocoPhillips Alaska, Inc. Well: 2N-304 Log Date: August 10, 2011 Field: Tarn Log No. : 10259484 ZX70 State: Alaska I Run No.: 3 API No.: 50-103-20382-00 Pipet Desc.: 3.5 " 9.3 Ib. L-80 EUE 8rd Top Log Intvll.: Surface Pipet Use: Tubing Bot. Log Intvll.: 9,585 Ft. (MD) I Inspection Type : Corrosive & Mechanical Damage COMMENTS : I This caliper data is correlated to tubing tally dated August 14, 2001. This log was run to assess the condition of the tubing and casing with respect to corrosive and mechanical damage. The caliper recordings indicate the 3.5" tubing logged appears to be in good condition, with no I significant wall penetrations, areas of cross - sectional wall loss or I.D. restrictions. This is the second time a caliper has been run in this well and the 3.5" tubing has been logged. A I comparison of the current and previous log (July 15, 2009) indicates no change in corrosive damage during the time between logs. A graph illustrating the difference in maximum recorded wall penetrations on a joint - by -joint basis between the current and previous log is included in this report. t The summary report is an interpretation of data provided by Halliburton Well Services. MAXIMUM RECORDED WALL PENETRATIONS: I No significant wall penetrations (> 15 %) are recorded. I MAXIMUM RECORDED CROSS - SECTIONAL METAL LOSS: No significant areas of cross - sectional wall loss (> 4 %) are recorded. I MAXIMUM RECORDED ID RESTRICTIONS: No significant I.D. restrictions are recorded. I Mandrel Orientation August 10, I 2N -304 Joint No. Tool ConocoPhillips Alaska, Inc. Tarn 2011 Deviation Mandrel No. Latch Orientation 81.2 69 1 4:00 I 187.2 63 2 12:30 257.2 64 3 4:00 289.2 44 4 5:30 II I Field Engineer: J. Conrad Analyst: HY. Yang Witness: B. Boehme ProActive Diagn,. lc. / P.O. Box 1369, Stafford, TX 77497 Phone: (281) or (888) 565 -9085 Fax: (281) 565 -1369 E -mail: PDS @memorylog.com I Prudhoe Bay Field Office Phone: (907) 659 -2307 Fax: (907) 659 -2314 1 2■-1S,1 —t'0 1 • • Correlation of Recorded Damage to Borehole Profile 1 ■ Pipe 1 3.5 in. (43.4' - 9569.7') Well: 2 N-304 Field: Tarn I Company: Country: ConocoPhillips Alaska, Inc. USA Survey Date: August 10, 2011 1 1 . Approx. Tool Deviation ■ Approx. Borehole Profile 1 71 40 `� 1292 GLM 1 80 ( 2544 1 IP 120 3814 1 _ 160 5068 0 GLM 2 Z 200 6337 a o p 240 7591 I GLM 3 • GLM 4 280 8863 r 300 9570 III 50 100 Damage Profile (% wall) / Tool Deviation (degrees) 1 1 Bottom of Survey = 300 1 1 t • • Maximum Recorded Penetration I S .. • Comparison To Previous Well: 2N -304 Survey Date: August 10, 2011 I Field: Tarn Prev. Date: July 15, 2009 Company: ConocoPhillips Alaska, Inc. Tool: UW MFC 24 Ext. No. 10000429 Country: USA Tubing: 3.5" 9.3 Ib L -80 EUE 8rd 1 Overlay Difference Max. Rec. Pen. (mils) Diff. in Max. Pen. (mils) I 0 50 100 150 200 250 -100 -50 0 50 100 0.1 0.1 1 7 7 16 16 I 26 26 36 36 '_- 46 -- 46 I 56 56 66 66! 76 76 83 83 93 93 103 103 t. 113 113 s I 123 123 133 133 E 143 t E 143 o Z 153 Z 153 1 . 163 0 163 1 173 173 183 183 3 I 190 190 3 200 200 210 210 220 _ 220 I 230 230 5 240 2 40 2. 250 250 I 257 257 267 267 n 277 — 277 287 287 3 290 1 290 a I 48 24 0 24 • August 10, 2011 •July 15, 2009 Approx. Corrosion Rate (mpy) 1 1 1 1 • • I PDS Report Overview ti 4 Body Region Analysis I Well: 2N -304 Survey Date: August 10, 2011 Field: Tarn Tool Type: UW MFC 24 Ext. No. 10000429 (HAL) Company: ConocoPhillips Alaska, Inc. Tool Size: 1.69 I Country: USA No. of Fingers: 24 Tubing: 3.5 in. 9.3 ppf L -80 EUE 8rd Analyst: HY. Yang Tubing: Nom.OD Weight Grade & Thread Nom.ID Nom.Upset Upper len. Lower len. 3.5 in. 9.3 ppf L -80 EUE 8rd 2.992 in. 3.5 in. 6.0 in. 6.0 in. 1 I Penetration(% wall) r Damage Profile (% wall) 400 Penetration body Metal loss body 0 50 100 0 1 300 -� 1 200 1 100 47 0 -Al III 0 to 20 to 40 to over GLM 1 = =- 20% 40% 85% 85% 95 Number of joints analysed (total = 31 7) 1 317 0 0 0 145 1 Damage Configuration ( body) y , 10 GLM 2 1 193 _- 5 1_- 1 243 A GLM 3 0 I Isolated General Line Other Hole / a Pitting Corrosion Corrosion Damage Pos. Hole GLM 4 'i• I Number of joints damaged (total = 3) 3 0 0 0 0 Bottom of Survey = 300 i 1 1 1 1 • • PDS REPORT JOINT TABULATION SHEET I Pipe: 3.5 in. 9.3 ppf L -80 EUE 8rd Well: 2N -304 Body Wall: 0.254 in. Field: Tarn I Upset Wall: 0.254 in. Company: Country: ConocoPhillips Alaska, Inc. Nominal I.D.: 2.992 in. USA Survey Date: August 10, 2011 I Joint Jt. Depth Pen. Pen. Pen. Metal Min. Damage Profile No. (Ft.) Upset Body % Loss I.D. Comments (% wall) (Ins.) (Ins.) % (Ins.) 0 50 100 I 0.1 43 0 0.02 7 1 2.98 Pup 0.2 46 0 0.02 7 2 2.89 Pup 0.3 56 0 0.02 9 1 2.92 Pup 0.4 66 0 0.02 8 0 2.92 Pup 1 71 0 0.02 8 2 2.92 I 2 102 0 0.03 10 2 2.91 3 133 0 0.02 9 2 2.92 4 164 0 0.03 10 2 2.92 5 195 0 0.02 9 2 2.94 I 6 227 0 0.03 10 2 2.90 7 258 0 0.03 10 2 2.92 8 289 0 0.02 7 2 2.93 9 319 0 0.01 6 2 2.91 I 10 351 0 0.03 10 2 2.93 11 382 0 0.02 9 2 2.94 12 413 0 0.01 6 1 2.94 13 445 0 0.01 6 1 2.94 I 14 476 0 0.02 7 2 2.95 14.1 507 0 0 0 0 2.88 Camco DS Nipple W/ No Go Profile 15 509 0 0.02 7 1 2.92 16 540 0 0.01 6 2 2.92 17 572 0 0.02 9 2 2.93 I 18 603 0 0.03 10 2 2.93 19 634 0 0.02 7 2 2.93 20 666 0 0.02 7 2 2.90 21 697 0 0.02 7 2 2.92 22 728 0 0.01 6 2 2.95 23 760 0 0.02 7 2 2.94 24 791 0 0.02 7 1 2.92 25 823 0 0.02 9 1 2.92 I 26 27 854 0 0.02 9 2 2.92 885 0 0.02 6 2 2.93 28 916 0 0.03 10 2 2.91 29 948 0 0.01 6 1 2.93 30 979 0 0.02 8 2 2.95 I 31 1010 0 0.02 9 1 2.95 32 1042 0 0.02 8 2 2.95 33 1073 0 0.02 7 2 2.92 34 1104 0 0.02 7 2 2.93 I 35 1135 36 1167 0 0.01 5 1 2.94 0 0.02 9 2 2.96 37 1198 0 0.02 7 2 2.95 38 1229 0 0.02 8 2 2.94 I 39 1261 0 0.02 7 2 2.93 40 1292 0 0.02 6 3 2.91 41 1323 0 0.02 8 2 2.93 42 1354 0 0.01 6 2 2.95 43 1386 0 0.02 7 2 2.93 44 1417 0 0.02 7 2 2.94 45 1448 0 0.02 9 2 2.92 rat I Metal Loss ion Body 1 Page 1 Penet 1 1 • • PDS REPORT JOINT TABULATION SHEET I Pipe: 3.5 in. 9.3 ppf L-80 EUE 8rd Well: 2N -304 Body Wall: 0.254 in Field: Tarn I Upset Wall: 0.254 in. Company: Country: ConocoPhillips Alaska, Inc. Nominal I.D.: 2.992 in. USA Survey Date: August 10, 2011 I Joint Jt. Depth Pen. Pen. Pen. Metal Min. Damage Profile No. (Ft.) Upset Body % Loss I.D. Comments (% wall) (Ins.) (Ins.) % (Ins.) 0 50 100 I 46 1480 0 0.03 11 2 2.92 47 1511 0 0.02 9 3 2.94 48 1542 0 0.01 6 2 2.94 49 1574 0 0.02 8 2 2.94 50 1605 0 0.02 9 4 2.93 I 51 1636 0 0.03 11 2 2.92 52 1668 0 0.03 11 2 2.92 ix 53 1699 0 0.02 7 1 2.90 54 1731 0 0.02 7 1 2.93 I 55 1762 0 0.02 6 2 2.91 56 1793 0 0.01 6 1 2.91 57 1825 0 0.01 6 2 2.93 58 1856 0 0.02 7 2 2.92 I 59 1888 0 0.02 7 2 2.92 60 1919 0.01 6 2 2.92 61 1950 0 0.01 5 1 2.92 62 1982 0 0.02 6 1 2.92 I 63 2013 0 0.02 8 2 2.91 64 2044 0 0.03 11 1 2.90 65 2076 0 0.02 7 2 2.89 66 2107 0 0.01 6 2 2.91 67 2139 0 0.02 6 1 2.91 I 68 2170 0 0.02 7 2 2.94 69 2201 0 0.02 9 1 2.91 70 2232 0 0.02 9 2 2.94 71 2263 0 0.02 9 2 2.90 I 72 2295 0 0.01 6 1 2.92 73 2326 0 0.01 6 2 2.91 74 2358 0 0.01 6 1 2.94 75 2389 0 0.01 6 2 2.92 I 76 2420 0 0.03 11 1 2.90 77 2450 0 0.01 5 2 2.91 78 2482 0 0.02 7 2 2.91 79 2513 0.04 0.03 12 2 2.94 80 2544 0.03 0.03 11 2 2.89 I 81 2576 0 0.02 7 2.90 81.1 2607 0 0.03 11 0 2.93 Pup 81.2 2613 0 0 0 0 2.87 GLM 1 (Latch @ 4:00) 81.3 2619 0 0.03 10 1 2.95 Pup I 82 2625 0 0.01 6 2 2.92 83 2657 0 0.02 9 2.92 84 2688 0 0.02 7 _. 2.91 85 2719 0 0.02 7 2 2.89 I 86 2751 87 2782 0 0.02 7 2 2.91 0 0.03 10 2 2.95 O 88 2813 0 0.02 7 2 2.92 ■ 89 2845 0 0.02 7 2 2.94 r 90 2875 0 0.02 7 1 2.92 I 91 2907 0 0.02 8 1 2.93 92 2938 0 0.02 7 2 2.90 I Penetration I Metal Loss Body 1 Page 2 Penetra 1 • • PDS REPORT JOINT TABULATION SHEET I Pipe: 3.5 in. 9.3 ppf L -80 EUE 8rd Well: 2N -304 Body Wall: 0.254 in. Field: Tarn I Upset Wall: 0.254 in. Company: Country: ConocoPhillips Alaska, Inc. Nominal I.D.: 2.992 in. USA Survey Date: August 10, 2011 I Joint Jt. Depth I'm. Pen. Pen. Metal Min. Damage Profile No. (Ft.) Upset Body % Loss I.D. Comments (°/0 wall) (Ins.) (Ins.) % (Ins.) 0 50 100 I 93 2970 0 0.02 8 1 2.90 94 3000 0 0.02 7 2 2.93 95 3030 O 0.02 7 2 2.92 96 3062 0 0.02 7 2 2.95 97 _ 3093 0 0.01 6 2 2.91 I 98 3125 0 0.02 7 2 2.93 99 3156 0 0.01 6 2 2.93 100 3187 0 0.01 6 2 2.92 101 3219 0 0.01 6 1 2.96 I 102 3249 103 3281 0 0.02 8 2 2.92 O 0.02 9 2 2.94 • 104 3312 0 0.03 11 2 2.95 105 3343 0 0.01 6 1 2.90 I 106 3375 0.03 0.03 11 1 2.97 107 3406 0 0.02 7 2 2.93 108 3437 0 0.02 8 2 2.95 3 109 3469 0 0.02 9 2 2.91 I 110 3500 0 0.01 6 2 2.92 111 3531 0 0.02 7 1 2.93 112 3563 0 0.02 8 3 2.91 113 3594 0 0.03 10 2 2.92 ■ 114 3625 0 0.02 9 3 2.92 I 115 3657 116 3688 0 0.01 5 1 2.93 0 0.01 6 2 2.91 117 3720 0 0.02 7 2 2.92 118 3751 0.06 0.02 9 2 2.92 I 119 3782 0 0.01 6 2 2.92 120 3814 0 0.02 9 2 2.94 121 3845 0 0.02 7 2 2.89 122 3877 0 0.02 7 1 2.94 I 123 3908 0 0.01 6 2 2.91 124 3940 0 0.01 6 2 2.93 125 3971 0 0.01 5 2 2.91 126 4003 0 0.01 6 1 2.92 127 4034 0 0.02 7 2 2.90 I 128 4065 0 0.01 6 2 2.94 129 4097 0 0.02 7 2 2.95 130 4128 0 0.02 6 2 2.94 131 4159 0 0.02 7 1 2.94 I 132 4191 0 0.02 6 2 2.93 133 4222 0 0.02 7 2 2.94 134 4253 0 0.02 7 1 2.89 135 4284 0 0.03 11 2 2.92 ■ I 136 4316 0 0.03 10 2 2.90 ■ 137 4348 0 0.03 11 2 2.93 138 4379 0 0.01 6 2 2.92 139 4410 0 0.03 12 2 2.91 I 140 4441 0 0.01 6 2 2.92 141 4473 0 0.02 9 2 2.92 142 4504 0 0.02 7 2 2.92 ' Penetration Body I Page 3 Metal Loss Body 1 1 • • PDS REPORT JOINT TABULATION SHEET I Pipe: 3.5 in. 9.3 ppf L -80 EUE 8rd Well: 2N -304 Body Wall: 0.254 in. Field: Tarn I Upset Wall: 0.254 in. Company: Country: ConocoPhillips Alaska, Inc. Nominal I.D.: 2.992 in. USA Survey Date: August 10, 2011 I Joint Jt. Depth Pen. Pen. Pen. Metal Min. Damage Profile No. (Ft.) Upset Body % Loss I.D. Comments (% wall) (Ins.) (Ins.) % (Ins.) 0 50 100 I 143 4536 0 0.01 6 1 2.89 144 4567 0 0.02 9 2 2.90 145 4598 0 0.02 8 1 2.90 146 4630 0 0.01 6 2 2.91 147 4661 0 0.02 7 2.91 I 148 4692 0 0.01 t: 2 2.91 149 4724 0 0.02 7 2 2.93 150 4755 0 0.02 9 2 2.90 151 4786 0 0.03 12 3 2.92 I 152 4818 0.03 0.02 9 2 2.96 153 4849 0 0.03 11 2 2.93 154 4880 0 0.03 11 2 2.93 155 4911 0 0.03 11 2 2.92 I 156 4943 0 0.03 11 2 2.94 157 4974 0 0.03 11 4 2.94 158 5005 0 0.02 7 2 2.93 159 5037 0 0.02 9 2 2.92 I 160 5068 0 0.01 6 2 2.94 161 5100 0 0.01 6 1 2.91 162 5131 0 0.03 11 2 2.95 163 5163 0 0.02 9 2 2.94 164 5194 0 0.02 8 2 2.93 I 165 5225 0 0.02 7 3 2.92 166 5257 0 0.02 7 2 2.93 167 5288 0 0.03 10 2 2.94 168 5319 0 0.03 11 2.92 I 169 5351 0 0.02 7 _ 2.93 170 5382 0 0.02 7 2 2.93 171 5413 0.03 0.04 15 2 2.94 172 5445 0 0.02 7 2 2.91 I 173 5476 0 0.02 6 2 2.94 174 5507 0 0.03 11 _s 2.93 175 5539 0 0.03 10 2 2.91 176 5570 0 0.02 8 2 2.94 177 5601 0 0.02 9 2 2.93 178 5633 0 0.01 6 2 2.95 179 5664 0 0.03 12 3 2.95 180 5695 0 0.03 12 2 2.91 181 5726 0 0.02 9 2 2.91 I 182 5758 0 0.02 8 2 2.94 183 5789 0 0.02 7 2 2.93 184 5820 0 0.01 6 2 2.93 185 5852 0 0.03 13 2 2.93 186 5883 0 0.02 9 2 2.92 187 5914 0 0.02 7 2 2.93 187.1 5946 0 0.04 15 2 2.92 Pup 187.2 5951 0 0 0 0 2.88 GLM 2 (Latch @ 12:30) I 187.3 5957 0 0.03 11 1 2.96 Pup 188 5963 0 0.02 7 2 2.94 189 5995 0 0.03 10 2 2.91 I Penetration Bod y Metal Loss Body Page 4 Penetra 1 1 • • PDS REPORT JOINT TABULATION SHEET I Pipe: 3.5 in. 9.3 ppf L -80 EUE 8rd Well: 2N -304 Body Wall: 0.254 in. Field: Tarn I Upset Wall: 0.254 in. Company: ConocoPhillips Alaska, Inc. Nominal I.D.: 2.992 in. Country: USA Survey Date: August 10, 2011 I Joint Jt. Depth Pen. Pen. Pen. Metal Min. Damage Profile No. (Ft.) Upset Body % Loss I.D. Comments (°/0 wall) (Ins.) (Ins.) % (Ins.) 0 50 100 I 190 6026 0 0.03 10 1 2.95 191 6057 ■ 0.02 7 2.92 II 192 6088 0 0.03 13 2 2.94 I 193 6119 0 0.02 9 2 2.97 ■ 194 6150 0.03 0.03 11 2 2.91 ■ I 195 6180 0 0.02 9 2 2.94 i 196 6211 0 0.02 9 2 2.92 In 197 6243 0 0.02 9 1 2.94 198 6274 0 0.02 9 2 2.93 I 199 6306 0 0.03 11 2 2.93 200 6337 0 0.02 n 2 2.92 201 6368 0 0.02 2.92 202 6400 0 0.01 2.93 I 203 6431 0 0.02 ') _ 2.91 204 6462 0 0.02 8 3 2.92 205 6494 t_1.03 0.03 11 3 2.95 ill 206 6525 0 0.02 9 2.92 I 207 6556 0 0.02 9 2.92 208 6588 0 0.03 11 2.88 209 6619 0 0.02 7 2.91 210 6650 0 0.02 7 2 2.91 211 6682 0 0.03 10 1 2.94 I 212 6713 213 6744 0 0.03 10 2 2.92 0 0.03 10 2 2.90 214 6776 0 0.03 10 2 2.93 215 6807 0 0.02 8 2 2.91 I 216 6839 0 9 ■ 2.91 217 6870 0 0.01 6 2.93 218 6901 t i 0.02 9 2 2.91 I 219 6933 0 0.02 8 2 2.91 h I 220 6964 0 0.02 ti _ 0 2.93 221 6995 0 0.02 2.93 222 7027 0 0.03 10 2.94 223 7058 0 0.02 7 _ 2.93 224 7089 0 0.02 7 _ 2.93 ' 225 7121 0 0.02 9 3 2.91 226 7152 O 0.02 2.91 227 7184 0 0.02 2.92 228 7215 0 0.02 8 2 2.97 I 229 7246 230 7278 0 0.02 9 2 2.93 0 0.02 7 2 2.92 231 7309 0 0.02 0 1 2.93 232 7341 0 0.02 0 3 2.93 I 233 7372 3.05 0.03 11 2.96 234 7403 0 0.03 10 2.95 235 7435 0 0.03 12 _ 2.94 236 7466 0 0.02 72 2.93 237 7497 0 0.03 12 2 2.94 I 238 7528 0 0.02 8 2 2.94 239 7560 0 0.02 9 2 2.91 ' Pene Penetration Body tration Loss Body Page 5 1 1 • • PDS REPORT JOINT TABULATION SHEET I Pipe: 3.5 in. 9.3 ppf L -80 EUE 8rd Well: 2N -304 Body Wall: 0.254 in. Field: Tam I Upset Wall: 0.254 in. Company: Country: ConocoPhillips Alaska, Inc. Nominal LU.: 2.992 in. USA Survey Date: August 10, 2011 I Joint Jt. Depth Pen. Pen. I'en. Met,d Min. Damage Profile No. (Ft.) Upset Body % loss I.D. Comments (% wall) (Ins.) (Ins.) _ (Ins.) 0 50 100 I 240 7591 0 0.02 2.92 241 7622 0 0.01 2.94 242 7654 0 0.02 '1 2 2.91 C 243 7685 0 0.03 11 2 2.93 244 7717 i 0.03 11 2 2.93 I• I 245 7748 0 0.03 11 2 2.92 246 7779 0 0.02 9 2 2.97 247 7810 0 0.03 11 2 2.92 248 7842 0 0.03 10 2 2.92 I 249 7873 0 0.01 6 1 2.94 250 7904 0 0.03 11 2 2.94 251 7936 0 0.02 7 2 2.91 252 7967 0 0.02 9 2 2.92 I 253 7999 254 8030 0 0.03 10 2 2.93 0 0.03 12 2 2.93 V 255 8062 0.04 0.03 12 2 2.91 ■ 256 8093 0 0.02 9 2.93 li 257 8124 0 0.02 .: 2.92 M 257.1 8156 0.03 0.03 12 2 2.94 Pup 257.2 8161 0 0 0 0 2.90 GLM 3 (Latch @ 4:00) 257.3 8168 0 0.03 11 1 2.96 Pup 258 8173 0 0.02 9 2 2.92 I 259 8205 9 2.95 260 8236 0 0.03 10 2 2.93 PS 261 8268 0 0.02 7 2 2.91 262 8299 0 0.02 9 4 2.95 I 263 8330 0 0.02 9 3 2.92 264 8362 0 0.02 9 2 2.97 VI 265 8393 0 0.03 112 2.94 266 8425 0 0.01 6 2 2.96 I 267 8456 0 0.02 7 1 2.92 268 8487 0 0.02 9 3 2.95 269 8518 0 0.03 11 3 2.91 270 8550 0 0.02 9 2 2.92 271 8581 0 0.01 6 2 2.92 I 272 8613 0 0.02 9 3 2.92 II 273 8644 0 0.03 11 2 2.93 a 274 8675 0 0.02 7 2 2.91 V 275 8706 0 0.01 6 2 2.92 I II 276 8738 0 0.03 I0 l' 2.95 277 8769 0 0.02 2.91 278 8800 0 0.03 10 2.90 279 8832 0 0.02 0 2.91 I 280 8863 0.03 0.03 2.92 281 8894 0 0.02 4 2 2.91 282 8926 .WI 0.02 7 3 2.91 283 8957 0 0.02 7 2 2.94 I 284 8988 0 0.02 7 2 2.90 285 9019 0.08 0.03 10 3 2.90 286 9050 0 0.03 10 2 2.96 to I Penetra Loss in Body Page 6 1 1 1 • • PDS REPORT JOINT TABULATION SHEET I Pipe: 3.5 in. 9.3 ppf L -80 EUE 8rd Well: 2N -304 Body Wall: 0.254 in. Field: Tarn I Upset Wall: 0.254 in. Company: Country: ConocoPhillips Alaska, Inc. Nominal I.D.: 2.992 in. USA Survey Date: August 10, 2011 I Joint Jt. Depth Pen. Pen. Pen. Metal Min. Darnage Profile No. (Ft.) Upset Body % Loss I.D. Comments (% wall) (Ins.) (Ins.) % (Ins.) 0 50 100 I 287 9081 0 0.01 6 2 2.89 288 9113 0 0.02 9 2 2.93 289 9144 0 0.03 11 3 2.94 289.1 9175 0.04 0.03 11 0 2.93 Pup 289.2 9181 0 0 0 0 2.88 GLM 4 (Latch @ 5:30) I 289.3 9187 0 0.03 12 0 2.93 Pup 290 9193 0 0.02 9 2 2.90 290.1 9221 0 0 0 0 2.71 Baker CMU Sliding Sleeve (Opened 7/14/09) 290.2 9228 0 0.02 8 2 2.88 Pup I 290.3 9240 0 0 0 0 2.73 Camco D- Nipple W/ No Go Profile 290.4 9241 0.0 3 0.03 10 1 2.87 Pup 290.5 9247 0 0.03 12 2 2.95 Baker Seal Assembly. Shallow Line of Pits. 290.6 9263 0 0 0 0 2.99 Cross -over I 290.7 9265 0 0 0 0 3.85 Tubing Tail 290.8 9269 0 0.03 12 2 2.91 Pup 291 9279 0 0.03 11 2 2.91 Top of 3.5" Liner. 292 9310 0 0.03 12 2 2.89 I 293 9341 0.03 0.03 11 2 2.91 294 9373 0.04 0.03 13 2 2.92 Shallow Pitting. 295 9404 0 0.02 9 2 2.91 296 9435 0 0.02 6 2 2.92 296.1 9466 0.03 0.03 10 2 2.91 Pup I 297 9476 0 0.03 11 2 2.92 298 9508 0 0.01 6 2 2.90 299 9539 0 0.03 11 2 2.91 300 9570 0 0.03 13 3 2.91 Shallow Line of Pits. I Penetrat I Metal Loss ion Body 1 1 1 1 1 1 Page 7 1 1 I . \ KUP 2N -304 ConocoPhillips ) Attributes gle & MD TD Wd Reid APIiUWl tl No Well Status Inc! (° M)(m(B) Ad Biro (M03) Ai"" "'', ' II. 501032038200 TARN PARTICIPATING AREA PROD 68.37 2808.89 10,052.0 ... Comment N2S 1ppml Dale Arvmtation End Date KB-Grd (R) Rig Release Date I v✓eIl « rea.- 2 hemac - Actual oa oaaiF NIPPLE 20 1/13/2009 Last WO: 40.54 8/15/2001 Schematic - Actual Arrwtatlon Depth (RKB) End Date Amotatlon Last Mod By End Date Last Tag: SLM 9,584.0 7/14/2009 Rev Reason: Open CMU. Set Pump, Tag Imosbor 7/20/2009 Casing Strings I DD String ID Set Depth Set Depth (WD( 541109 wt 5[11119 li Casing Description On) (In) Top (mCB) (MCB) (Ibsllry Gnarls string Top mm c05035000 CONDUCTOR 16 15.062 0.0 152.0 152.0 62.58 H-40 WELDED 152 SURFACE 7518 6.875 0.0 2,930.0 (RKB) 2,305.4 29.70 L-80 BTC -MOD PRODUCTION 51/2 4.950 0.0 9,243.0 5,241.7 15.50 L-80 BTC -MOD LINER 3 1/2 2.992 9,263.0 10,036.0 5,861.7 9.30 L -80 EUE -8rd • SFT9 VLV. 495 1 I = Tubing Strings 5111119 OD string ID Set Depth Set Depth (TVD) String Wt String Tubing Description (In) (In) Top ( 404 5) (OKB) (NCB) (ItisM Grade ) Gre string Top Dud 31/2 2.992 0.0 9,266.0 5,258.9 9.30 L -80 EUE-8RD Other In Hole (AII Jewelry: Tubing Run & Retrievable, Fish, etc.) Top Depth i (1VD) Top Ind GAS LIFT, Top(0K8) MKS) C) Description Comment 2.809 4 95 494.8 4.93 SFTY VLV CAMCO'DS' NIPPLE W /NO GO PROFILE 8/14/2001 2.875 2,604 2,183.6 67.62 GAS LIFT CAMCO/KBG- 2- 9/1 /DMY /INT /!l Comment STA 1 Run Date ID (n) 8/14 /2001 2.900 5,948 3,652.4 61.41 GAS LIFT CAMCO/KBG- 2- 9 /1 /DMY /INT /// Comment: STA 2 8/14/2001 2.900 8,159 4,658.8 63.58 GAS LIFT CAMCO/KBG- 2- 911 /DMY /INT /! /Comment: STA3 8/14/2001 2.900 I • SURFACE 9,182 5,196.8 42.79 GAS LIFT CAMCO/KBG- 2- 9/1 /DMY/INT!// Comment STA 4 3/28/2002 2.900 z 930 9,225 5,228.3 41.65 SLEEVE-0 BAKER CMU SLIDING SLEEVE - OPENED 7/14 /2009 8/14/2001 2.813 9,225 5,228.3 41 -65 PUMP RC JET PUMP 10 -8 RATIO, 910 NOZZLE, 911 THROAT, 7/19/2009 0.000 • • OAL= 47" I 9,241 5,240.2 41.58 NIPPLE CAMCO'D' NIPPLE W /NO GO PROFILE 8/14/2001 2.750 9,243 5,241.7 41.58 CSR BAKER CASING SEAL RECEPTCLE 8/14/2001 4.000 9,249 5,246.2 41.55 SEAL BAKER GBH-22 SEAL ASSEMBLY 8/14/2001 3.000 £A6 LIFT, i ' ' 9,266 5,258.9 41.48 TTL 8/14/2001 2.992 5 ``'48 Inn 10,035 5,860.9 35.57 SHOE 8/14/2001 2.992 I ill Perforations & Sly Shot Top (TVD) atm(TVD) Dens 0:s LIFT Top (N(B) 131311(MM) (MB) (RKB) Zone Date O 1 YPe Comment 6,169 .11 9,592 9,602 5,506.8 5,514.6 BERMUDA, 11/12/2001 4.0 IPERF 2.5" HSD, BH Chgs, 180 deg phase, i 2N -304 45/227 deg orient Comment I Stimulation 8. Treatments ' Bottom Mn Top Max Biro Top Depth Depth Depth De (ND) (ND) B) (MOB (MOB (OEB) MKB) AI. Date I I 9,5920 9,6020 5,506.8 5,514.6 FRAC 11/17/2001 BERMUDA FRAC, 219,000# 12/18CARBOLITE, 10 PPA ON PERFS GAS LIFT, / 9482 1 1 SLEEVE-O. 9.225 PUMP. 9.225 I Mr 1 NIPPLE. 9,211 ' 1 — 11 TUBING XO, r i.` , 9,242 PRODUCTION, 9.243 • CSR, 9,243 7 E 1 SEAL. 9,249 I TUBING 262 - 9,262 II 1 TTL 9.266 1 i IPERF. 9592 - 9,52 1 FRAC, 9,5992 1 LINER, 19036 10,05 7D QN305 2 1 1 • • _ __~ ~., e_ ,. ~'~a~dacaiv~ ~ia~n~srec ~~~a~s.~.s, ~~ic. ~~ ~~ . -~ ~~~ ~ - ~~ i o: :~[~GCC Christine Mahnken ~33 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, lnc. Attn: Robert A. Richey 130 West International Airport Road Suite C Anchorage, AK 99518 Fax: (907) 245-8952 1 J Caliper Report~./t(1r 15,Ju1-09 2N-304 1 Report/ EDE 5~-029-20382-00 2] ~ U ~ -1~ ~ ISCf C~.3 ~ wat~ 6wis~+J ~ l 1~ .i ': t~ U V~1 ~~~>~ ~ ~ ! 1 ~ ~ /: Signed : ~ \~ ~~'~----- L/ Print Name: Date : PROACTNE DIAGNOSTIC SERVICES, fNC., 130 W. INTERNATIONAL AIRPORT RD SURE C, ANCHORACiE, ALC 99518 PHONE:f907)245-8951 FAX: (907~245-88952 E-NIAI~ : ... _ , _ °: ' WEBSITE : ~°°. ~ C:\Documents and Setbngs\Owner\Desktop\Tratismit_Conoco.docx , ~ ~ _ ~ ~ • Memory Muiti•Finger Calip~r & MTT Log Results ~ummary Company: ConocaPhillips Alaska, Inc. Well: 2N-304 Log Date: July 15, 2009 Field: Tarn Log No. : 10572 State: Alaska Run No.: 2(MIT & MTT) API No.: 50-103-20382-00 Pipe1 Desc.: 3.5" 9.31b. L-80 BTC-MOD Top Log In#v11.: Surtace Pipe'I Use: Tubing Bot. Log Intvl1.: 9,266 Ft. (MD) Pipe2 Desc.: 3.5" 9.3 Ib. L-80 EUE-8RD Top Log Intvll2: 9,263 Ft. (MD) Pipe2 Use: Liner Bot. Log Intvl2.: 9,302 Ft. (MD) Pipe3 Desc.: 5.5" 15.5 Ib. L-80 BTC-MOD Top Log Intvl3.: Surface Pipe3 Use: Production Casing Bot. Log Intv13.: 9,297 Ft. (MD) (MtT only) '~~ ~ Inspection Type : Corrosive 8 Mechanical Damage lnspec~ion ' COMMENTS : The data in this log is tied into the Baker Sliding Sleeve ~ 9,225' (Driller's Qepth). ' This is the secpnd time this welt has been logged with a 24 Arrn Caliper and a 12 Arm Magnetic Thickness Tool (MTT). The Magnetic Thickness Tool responds to the totai thickness of inetal of the 3.5" tubing / 3.5" liner and 5.5" production casing. A single 8Hz pass was made at 20 fpm. ' The additional metal volume of the 7.625° surface casinv prevented the rrormal functioninq of the MTT so no interpretab/e results are available from fhe end of the 7. 625" surtace casinv to surface. COMPARISON TO PREVIOUS MTT LOG RE~ULTS: A comparison of the current 8Hz pass to the previous 10Hz pass (November 3, 200~ indicates no significant change in metal thickness during the time be#ween logs. A log piot overlay (2,923' - 3,300') of the average metal thicknesses recorded by the MTT for the current and previous log is incfuded in this report. , INTERPRETATI~N OF CALIPER L4G RESULTS : This log was run to assess the condition of the tubing and liner with respect to interna! corrosive and mechanical damage. The caliper recmrdings indicate the 3.5" tubing and liner logged are in good condition, with no significant wall penetrations, areas of cross-sectional vvall loss, or I.D. rest~ictions recorded. This is the second time a PDS caliper has been run in this well and the 3.5" tubing has been logged. A comparison of the current and previous log (November 2, 2007j indicates no change in the internal condition of the tubing during the time between logs. A graph i{lus#rating the difference in maximum recorded penetrations on a jaint-by joint basis between the current and previous log is included in this report. I' ProActive Diagnostic Servicea, Inc. / P,~. Box 1369, Stafford, TX 7749? ~hone; {281) or (888) 565-9085 Fax: (281) 565-1369 E-mail: PDS~amemorylog.com Prudhoe Bay Field Office Phone~ (907) 659-2307 Fax; {90%) b59-2314 I ' , ~b ~ - t3 v ~ ~5 ~r~3 • • 3.5" Tubing 8~ Liner - MAXtMUM RECORDED WALL PENETRATIONS: No significant wall penetrations (> 17%) are recorded throughout the tubing and liner logged. 3.5" Tubing ~ Liner - MAXIMUM RECORDED CROSS-SECTIONAL METAL LOSS: No significant areas of cross-sectional wall loss (> 5%) are recorded throughout the tubing and liner lagged. 3.5" Tubing 8~ Liner - MAXIMUM RECURDED ID RESTRICTIONS: No significant I.D. restrictions are recorded throughout the tubing and liner logged. INTERPRETATION OF MTT LOG RESULTS : The 8Hz M7T log resuPts cover the interval from 2,923' to 9,297'. A plot of average metal thickness relative to the calibration points on a joint-by joint basis is included in this report, indicating relative metal loss ranging from 0-7% throughout the logged interval (ranging mostly from 4% to 7% over the interval of 4,930' - 8,150'). Changes in metal vofume are relative to the calibration points at 8,815' and 9,285', where the readings are assumed to represent undamaged pipe. Atl other readings are relative to these reference points, which include influences from the 3.5° tubing / 3.5" liner and 5.5" production casing. A maximum overall metal volume loss of 7% is indicated in tubing joint 165 (5,186' - 5,217'), where numerous possible isolated metal loss recordings are indicated. The recordings apparently exhibit varying isolated event patterns resembling lines of isolated metal loss with some broader areas of distribution. Some periodic tool surge is indicated throughout the logged intervat, which may exaggerate some of the individual sensor readings. However, #hese patterns of isolated meta! loss indications point ta potential areas of minor volumetric metaf loss to the outside of the tubing or more significant damage to the production casing. Details of the 8Nz MT7 recordings over the interval (4,966'-5,250') are included in this report to show these pattems. The percent circumferential metat loss expressed in this summary is a percentage of the total metal that the ' tool is responding to, which includes influences from the 3.5" and 5.5" pipe. If all of the metal loss is specific to the 5.5" production casing, the percent metal loss ftom that pipe alone is probably higher than the numbers expressed. The metal loss indicated could be from either or both the 3.5" tubing / 3.5" liner or 5.5" production casing. ' ' ~ ' Field Engineer. G. Etherton Analyst: C. Wa/drop (caliper) / HY. Yang & J. Burton (MT~ Witness: C. Fitzpatrick ProACtive Diagnostic Services, Inc. / P.Q. Box 1369, StafFord, TX 77497 : PDa~~r~e~mory og.cor Prudhoe Bay Fie d Office Phone: {907) 659-230? Fax: (90?) 659-2314 , ' i • Correlation of Recorded Damage to Borehole Profile ~ Pipe 1 3.5 in (2.9' - 9276.0') Weli: Field: Company: Country: Survey Date: 2 N-304 Tarn ConocoPhillips (Alaska), Inc. USA luly 15, 2009 ^ Approx. Tool Devia6on ^ Approx. Borehole Profile 1 8 25 759 50 t546 75 ` ~ 2334 GLM 1 100 3136 125 3922 150 4709 ~ ~ ~ ~ 17 S 5497 ,,; GLM 2 ~ c Z 200 6298 Q c v ° O 225 : 7086 250 _ 7872 GLM 3 . 275 8676 GLM 4 292 9276 0 50 100 Damage Profile (% wall) / Tool Deviation (degrees) Bottom of Survey = 292 • u Maximum Recorded Penetration ~ `~~ Comparison To Previous Well: 2N-304 Survey Date: July 15, 2009 Field: Tam Prev. Date: N ovember 2, 2007 Company: ConxoPhillips (Alaska), Inc Tool: UW MFC 24 Ext. No. 218370 Country: USA Tuhing: 3.5" 93 Ib I_~0 EUF.-fiRD Overlav Ma~c. Rec. Pen . (mils) 0 5 0 1 00 1 50 20 0 25 0 0.1 8 17 27 37 47 57 67 77 84 94 104 114 124 ~ 134 ; in~ z_ ~ 154 ° 164 174 184 191 201 211 221 231 241 251 258 268 2 78 288 lub.~ ~`.:'fin~i .~rc~ „~1,,•~ :. -~r+c Difference ~ • PDS Report Overview ~. s.. Body Region Analysis Well: 2 N-304 Survey Date: )uly 15, 2009 Field: Tarn Tool Type: UW MFC 24 Ext. No. 218370 Company: ConocoPhillips (Alaska), Inc. Tool Size: 1.69 Country: USA No. of Fingers: 24 Anal st: C. Waldro Tubing: Nom.OD Weight Grade & Thread Nom.ID Nom. Upset Upper le~. Lower len. 3.5 ins 93 f L-80 EUE-8RD 2.992 ins 3.5 ins 6.0 ins 6.0 ins Penetration and Metal Loss (% wall) ~ penetration body ~ metal loss body 200 150 100 50 ~ 0 l0 1 to 10 to 20 to 40 to over 1`% 10% 20% 40% 85% 85% Number of'oints anal sed total = 306 pene. 8 188 110 0 0 0 loss 177 129 0 0 0 0 Damage Co~guretion ( body ) 10 0 isolated general line ring hole / poss pitting corrosion corrosian cwrosion ible hole Number of "oints dama ed total = 0 0 0 0 0 0 Damage Profile (% wall) ~ penetration body _,;-, metal loss body 0 50 100 n GLM 1 GLM 2 GI_M 3 GLM 4 Bottom of Survey = 292 Analysis Overview page 2 ~ PDS REPORT JOINT TABI, Pipe: 3.5 in 9.3 ppf L-80 EUE-8RD Well: Body Wall: 0.254 in Field: Upset Wall: 0.254 in Company: Nominal I.D.: 2.992 in Country: Survey Date: • ~LATION SHEET 2 N-304 Tam ConocoPhillips (Alaska), Inc. USA July 1 S, 2009 Joint No. Jt. Depth (Ft.) I'~~u. t1F~s~~i (Im.) Pen. Body (Ins.) I'en. °ro ~tc~~al I~~~s "~~ Min. I.D. (Ins.) Comments Damage Profile (%wall) 0 50 100 .1 3 l1 0.01 ~ I .97 P P 1 8 t~ 0.01 5 u 2.88 1.1 21 U 0.02 7 ~~ 2.91 PUP 1.2 31 u 0. 2 t~ u 2.92 PUP 2 35 u 0.01 5 1 2.93 3 66 i~ 0.01 i 2.92 4 98 ~? 0.02 '; f 2.92 5 129 ~~ 0.02 - 2.91 6 160 ~~ 0.02 t3 I 2.93 7 192 ~ ~ 0.02 ~~ .94 8 223 U 0.01 4 ~' 2.92 9 255 t1 0.02 t3 2.95 10 285 l) 0.01 ~ ! 2.91 11 316 ~~ 0.01 •1 i 2.94 12 348 U 0.03 I' 2.43 13 379 ~~ 0.02 ~~ I 2.94 14 411 ~ ~ 0.02 ~) ~ ~ 2.94 15 442 ~~ 0.01 ~ I 2.94 15.1 473 l~ 0 0 tl 2.88 Camco DS N e W No Co Profile 16 475 t~ 0.01 4 I 2.92 17 506 u 0.03 1O 1 2.93 18 538 l~ 0. 1 5 2.92 19 570 U 0.02 ~) 2.92 20 602 tt 0.03 1~ I 2.92 1 633 ~~ 0. 2 - I 2.92 22 665 ~~ 0.03 I 1 I 2.92 23 696 u 0.01 > ~ I .93 24 728 ~~ 0.03 1 ~~ ' 2.93 25 759 ~) 0.01 ~ _' 2.93 26 790 u 0.02 ti I 2.91 27 822 t~ 0.03 13 1 2.90 28 853 i~ 0.01 6 I 292 29 885 U 0.01 6 I 2.91 30 917 ~) 0.01 ~ I 2.92 31 948 ~ ~ 0.02 ~) _' 2.93 32 980 i~ 0.02 ~) 1 2.92 33 1011 u .01 2 I 2.93 34 1042 ~ ~ 0.02 8 ~' 2.90 35 1074 u 0.01 6 1 2.91 36 1105 U 0.02 t3 I 2.93 37 1137 l~ .O1 4 1 .94 38 1168 U 0.02 9 I 2.94 39 1200 ~~ 0.01 ~ I 2.93 40 1231 U 0.03 1 Z 2.92 41 1263 ~! 0.02 - i 2.93 42 1294 i~ 0.02 i 2.92 43 1326 u 0.01 -1 I 2.93 44 1357 c~ 0.02 r9 I 2.93 45 1389 ~~ 0.01 5 _' 2.94 46 1420 ~1 0.03 ll~ ' 2.92 Penetration Body ~ Metal Loss Body Page 1 • PDS REPORT JOiNT TABI. Pipe: 3.5 in 9.3 ppf L-80 EUE-8RD Well: Body Wall: 0.254 in Field: Upset Wall: 0.254 in Company: Nominal I.D.: 2.992 in Country: Survey Date: • ~LATION SHEET 2 N-304 Tarn ConocoPhillips (Alaska), Inc. USA )uly 15, 2009 Joint No. Jt. Depth (Ft.) I'~~n. 11F~,~~t (Ins.) Pen. Body (Ins.) Pen. °4, ~Ict,~l loss °~~~ Min. I.D. Qns.) Comments Damage Profile (%wall) 0 50 100 47 1452 (1 0.02 8 _' 2.91 48 1483 U 0.03 I"3 ~ 2.92 49 1515 c~ 0.03 1 1 1 .92 50 1546 t? 0.00 1 t~ 2.93 51 1578 ~~ 0.03 1 I I 2.92 52 1609 (~ 0.01 -3 2.90 53 1641 ~ ~ 0.01 ~ 2.92 54 1672 ~ i 0.04 1~1 2.91 55 1704 l) 0.03 I 1 I 2.92 56 1735 U 0.02 7 _' 2.9 57 1767 U 0.01 ? 1 2.92 58 1798 ~~ 0.01 c, s .93 59 1830 c1 0.01 4 2.9 60 1861 ~ ~ 0.03 ~I > 2.93 61 1893 U 0.03 I( 2.92 62 1924 ~ ) 0.01 t~ .93 63 1956 ~ ~ 0.01 `} 2.92 64 1987 ~ ~ 0.03 1 ~ .92 65 2019 u 0.03 12 I .92 66 2050 ~~ 0.03 13 2.93 67 208 ~) 0.01 ~ 2.93 68 2113 l1 0.03 13 I 2.91 69 2145 ~ 1 0.02 t3 Z 2.92 70 2177 O 0.04 1' ~ 2.91 71 2208 U 0. ~, ' 2.92 72 2240 ~? 0.04 1,' -F 292 7 2271 ~~ 0.03 I.s u 2.91 74 2303 u 0.01 5 I 2.96 75 2334 U 0.03 1 U I .94 76 2365 U 0.02 9 1 2.91 77 2396 (~ 0.03 13 1 2.91 78 2426 U 0.03 11 ~ 2.92 79 2459 ~ 1 0.02 ~i I 2.93 80 2491 (? 0.01 b , 2.94 81 2522 ~) 0.03 I(i 2.89 82 2554 u 0.03 1~ ' 2.91 82.1 2585 U 0.03 l i 2.93 PUP 82.2 2591 ~1 0 ~~ U N A GLM 1 Latch @ 5:00 82.3 2597 U 0.01 4 _' 2.94 PUP 83 2603 u 0.03 12 2 2.93 84 2635 U OAZ 7 _' 2.93 85 2666 l) 0.02 9 ~ 2.92 86 2698 l~ 0.02 ~ 1 2.91 87 2729 U 0.01 -1 I 2.96 88 2760 U 0.00 1 i~ .92 89 2 792 U 0.03 13 I 2.91 90 2824 t) 0.03 1:~ I 2.93 91 2856 u OA2 t9 ! 2.90 92 2 88 ~~ 0.03 12 ' 2.94 93 2919 i~ 0.04 l:~ 2.91 Penetration Body Metal Loss Body Page 2 • PDS REPORT JOINT TABI. Pipe: 3.5 in 93 ppf L-80 EUE-8RD Well: Body Wall: 0.254 in Field: Upset Wail: 0.254 in Company: Nominal I.D.: 2.992 in Country: Survey Date: • ~LATION SHEET 2 N-304 Tarn ConocoPhillips (Alaska), Inc. USA july 15, 2009 )oint No. Jt Depth (Ft) I'~~n. l 1E~t~~t (Irr;.i Pen. Body (Ins.) Pc~n. °i~, ~1~~t,~l I c~ss ~~ Min. I_D. (Ins.) Comments Damage Profile (%wall) 0 50 100 94 2950 U 0.02 ~) I 2.92 95 2980 ~~ 0.02 7 2.96 96 3011 ~~ 0.03 1~' 2.93 97 042 ~~ 0.03 1 Z 2.92 98 3073 ~: ~ 0.01 _' I .95 99 3104 c? 0 03 1"t ' 2.93 100 3136 U .02 9 I 2.93 101 3167 i) 0.02 4 2.93 102 3199 ~~ 0.03 1 1 I 2.93 103 3230 t1 0.00 1 U 2.94 1 4 3261 ~~ 0.03 1 Z ! 2.91 105 3293 ~~ 0. 3 1~~ ? 2.93 106 3324 ~~ Q.02 t; i 2.93 107 3355 i~ 0.03 i l I 2.91 108 3387 l? 0.03 I_' I 2.92 109 3418 ~~ 0.03 11 -~ 2.93 110 3450 ! ~ 0.01 ~ ' 2.92 111 3482 ~ 1 0.01 5 I 2.92 112 3513 U 0.03 i l I 2.93 113 3545 cr 0.04 14 I 2.91 114 3576 U 0.03 12 I 2.91 115 3608 t~ 0.03 11 2.92 116 3639 (i 0.00 1 ~~ 2.92 117 3670 t) 0.03 1 i I 2.91 118 3 0 U 0.03 12 .' 2.93 119 3733 U 0.03 11 ' 2.93 120 3765 l) 0.0 l I 2.93 121 3797 O 0.03 1 t) 2.92 122 3828 ~1 0.04 14 2.91 123 3860 0 0.03 i l I 2.94 124 3891 ~? 0.03 11 I 2.94 125 3922 t~ 0.01 6 I 2.92 126 3954 u 0.02 9 I 2.93 127 3985 l1 0.04 17 1 2.90 128 4017 tl 0.03 12 _' 2.91 129 4Q48 t) 0.02 9 I 2.91 130 4079 ~) 0.03 13 _' 2.90 131 4111 ~~ 0.03 l:t 1 2.91 132 4143 U 0. 1 4 l~ 2. 4 133 4174 U 0.03 11 ~' 2.92 134 42 6 l1 0.04 15 I 2.92 135 4237 U 0.04 14 I 2.92 136 4269 ~) 0.03 1~ _' 2.93 137 4300 l1 0.04 1 i 2.91 138 4332 (1 0.04 14 2.93 139 4363 ~~ 0.02 9 ~' 2.92 140 4395 U 0.01 2 I 2.91 141 442 7 U 0.02 7 I 2.96 142 4458 (~ 0.03 1 1 2.92 143 4489 !) 0.01 Z I 2.93 Penetration Body ~ Metal Loss Body Page 3 ~ PDS REPORT JOINT TABI, Pipe: 3.5 in 9.3 ppf L-80 EUE-8RD Well: Body Wall: 0.254 in Field: Upset Wall: 0.254 in Company: Nominal I.D.: 2.992 in Country: Survey Date: • i LATI O N S H EET 2 N-304 Tarn ConocoPhillips (Alaska), Inc. USA July 15, 2009 )oint No. Jt. Depth (Ft.) I'~~n. l ~F,~c~t (In~.) Pen. Body (Ins.) Pc~n. ",~~ ~t~~~al I~~s~ ~~ Min. I.D. (lns.) Comments Darnage Profile (% wall) 0 50 100 144 4520 ~~ Q.04 1-1 I 2.92 145 4551 ~t 0.02 ~~ .96 146 4583 !~ 0.01 ' I 2.91 147 4614 t% 0.03 L s .91 148 4646 t~ 0.03 1.; I 2.92 149 4678 ~~ 0.04 15 ' 2.91 150 4709 ~~ 0.03 1O I 2.93 151 4741 ~ ~ 0.01 ~ ' .96 152 4772 u 0.04 17 2 92 153 4804 l~ 0.04 1 b ~ 2.91 154 4835 i~ 0.01 ~' I 2. 15 4f367 U 0.01 ~_' I 2 6 156 4898 U 0.02 ~~ I 2.91 157 49'L9 ~~ 0.03 1 U I 2.93 15F3 4961 ! a .02 9 ' .91 159 4993 !~ 0.02 ~~ 1 .92 160 5024 ~~ 0.03 1 Z I 2.90 161 5056 t) 0.01 ~1 t t 2.95 162 5087 U 0.03 11 I 292 163 5119 l) 0.03 11 ~ 2.93 164 5151 t) 0.01 -1 .97 165 5183 ~~ 0.02 t S I 2.94 16 5214 U 0.03 1 t~ 2.91 167 5246 ~~ 0.03 13 2.91 168 5277 u .03 1; 2.90 169 5309 i~ 0.01 5 ' 2.96 170 5340 ~~ 0.03 1 1 _' 2.91 171 5371 (1 0.02 t3 ~ r 2.94 172 5403 i~ 0.03 I~ 2 92 173 5435 t~ 0.01 6 i 2.96 174 5466 ~~ 0.03 1U t~ 93 175 5497 ~~ 0.01 f, _' 2.92 176 5529 ~? 0.02 ~3 2.94 177 5560 ~1 0.03 I~I I 2.92 178 5592 ~~ 0.02 <S i 2.96 179 5623 ~~ 0.03 1 Z 2.92 180 5655 U 0 0 8 I 2.91 7 81 5686 U 0.02 ~3 2.90 182 5718 t1 0.02 I 2.94 183 5749 ~1 O.OI ~i I 2.92 184 5780 U 0. 4 15 .91 185 5812 ~ 1 0.02 - I 2.96 7 86 5843 !) 0.03 1 1 2.92 187 5874 ~~ 0.03 1 1 I 2.92 188 5906 i~ 0.02 7 I 2.91 188.1 5938 ~~ 0.02 ~~ I 2.92 PUP 188. 5943 U 0 i) {~ N A GLM 2 Latch ~ 12:30 188.3 5949 t1 0.02 i I 2.96 PUP 189 5955 ~~ 0.01 Z ~~ 2.95 190 5986 ~~ 0.03 12 2.91 Penetration Body Metal Loss Body Page 4 , • • PDS REPORT JOINT TABULATION SHEEf , Pipe: 3.5 in 9.3 ppf L-80 EUE-8RD Well: 2N-304 Body Wall: 0.254 in Field: Tarn , Upset Wall: 0.254 in Company: ConocoPhillips (Alaska), Inc. Nominal I.D.: 2.992 in Country: USA Survey Date: July 15, 2009 Joint No. Jt Depth (Ft) I'~~n. UE~.~~t Iln..) Pen. Body (Ins.) I'~~n. °i~, :~1c~t.il I~~5~ °« Min. I.D. (Ins.) Comments Damage Profile (%wall) 0 50 100 191 6018 ~~ 0.03 11 ~ 2.91 1 2 050 ~~ 0.01 (~ I .95 193 6080 ~~ 0.04 15 ! 2.93 194 6111 ~~ 0.01 ? I 2.91 195 6142 U 0.03 1 U ; 2.89 196 6172 U 0.02 ~) _' 2.9 197 6204 ~~ 0.01 ' I 2.97 198 6236 ~~ .01 ~ I 2.97 199 6267 l1 0.03 Ii~ ~ 2.92 200 6298 l1 0.02 i ~ 2.94 201 6329 ~~ 0.03 I? i~ 2.91 202 6361 U 0.02 ~~ ~' 2.90 203 6392 ~~ 0.02 t~ ~ ~ 2.92 204 6424 ~~ 0.02 _' 2.97 205 6455 ~t 0.02 1 2.95 206 6487 ~) 0.04 I' 1 2.91 207 6518 i i 0.01 ~? I 2.95 20 550 u 0.01 (, I .93 209 658 ~ ~ 0.0 12 _' .96 210 6612 i~ 0.00 1 I 2.92 211 6644 (~ 0.01 Z 1 2.97 212 6676 ~ 1 0.01 -~ 1 .94 13 6707 ~) 0.02 9 I 2.91 214 6739 u 0.03 1:~ ~ 2.89 215 6771 ~~ 0.01 ~' I 2.94 216 6802 (~ 0.04 I i I 2.90 217 6834 u 0.03 l~ 1 2.89 218 6865 i~ 0.03 13 I 2.91 219 6897 (~ 0.03 11 I 2.94 220 6928 l~ 0.03 13 ? 2.91 221 69 0 (~ 0.02 ' 1 .93 222 6991 ~ ~ 0.02 ~) _' 2.93 223 7020 (1 0.01 ~; 1 2.92 224 7052 ~~ 0.03 1 I 2.91 25 7086 ~) 0.01 4 2.96 226 7117 ~ ~ 0.04 I~ 2.90 27 7148 U 0. 1 _' 1 2.91 228 7180 ~~ 0.01 _' I 2.95 229 7212 u 0.01 ? u 2.96 230 7243 ~~ 0.03 1 U ? 2.91 231 7275 ~~ 0.03 11 I .9 232 7306 u 0.02 ti ' 2.95 233 7337 t~ 0.01 ~' I 2.96 234 7369 i~ 0.02 ti 2.95 235 7400 ~) 0.01 ~ I 2.95 236 7431 i~ 0.03 I' ~~ 2.91 237 7463 ~~ 0.01 d I 2.95 238 7494 u 0.02 9 _' 2.92 239 7525 i~ 0.03 11 I .93 240 7558 +~ 0.01 ,! 1 2.90 ~ Penetration Body Metal Loss Body Page 5 • PDS REPORT JOINT TABI, Pipe: 3.5 in 93 ppf L-80 EUE-8RD Well: Body Wall: 0.254 in Field: Upset Wall: 0.254 in Company: Nominal I.D.: 2.992 in Country: Survey Date: • ~LATION SHEET 2 N-304 Tarn ConocoPhillips (Alaska), Inc. USA July 15, 2009 Joint No. Jt. Depth (Ft.) I'~~n. l lE~~c~t (Irr..) Pen. Body (Ins.) Pc~n. °i, ~1c~t.~l 10~. ~~ Min. I.D. (Ins.) Comments Damage Profile (%wall) 0 50 100 241 7589 i 1 0.01 4 I 2 90 242 7621 U 0.02 7 I 2.94 243 7652 l~ 0.0 14 I 2.89 244 7683 U 0.02 r; I 2.95 245 7715 ~~ 0.03 1 ~' 2.92 246 77 6 t) 0.03 12 I 2.90 247 7778 U 0.02 i ' 2.96 248 7809 ~~ 0.07 ,' I 2.92 249 7840 (! 0.03 ll) I 2.9 250 7872 ~! 0.01 5 I 2.94 251 7903 t! 0.01 ~l ~1 2.93 252 7935 U 0.02 t3 l 2.9b 253 7966 u 0.04 I5 1 2.90 254 7998 u 0.02 Fs I 2.97 255 8029 U 0.04 I-1 I 2.91 256 8061 t) 0.01 i ! 2.93 257 8091 U 0.02 ~~ 2.92 258 8123 U 0.02 ~) ' 2.92 258.1 8154 t~ 0.02 ~~ ~ 2.93 PUP 258.2 8160 +~ 0 U t~ NA GLM 3 Latch~4:00 258.3 8164 ~~ 0.01 ? ~~ .96 PUP 259 8172 i i 0.01 I 2.95 260 8204 U 0.01 ? I 2.94 261 8235 l~ 0.00 I I 2.92 262 8267 O 0.04 I b I 2.91 263 8298 U 0.02 7 1 2.91 264 83 9 U 0.00 1 i~ 2.95 265 8360 t) 0.02 8 1 2.97 266 8392 i~ 0.03 11 (1 2.93 267 8421 !~ 0.02 ~) I 2.92 268 8455 U 0.01 4 ~ 2.93 269 8486 i~ 0.03 13 2.91 2 70 8519 i) 0.02 t3 _' 2.94 271 8551 ~) 0.01 ? I 2.97 272 8582 t~ 0.03 I~ I .91 273 8614 I) 0.01 5 I 2.95 274 8644 U 0.03 I; ! 2.90 275 8676 U 0.01 ..' I 2.94 276 8707 U 0.00 ~' I 2.95 277 II739 ~~ 0.01 ~..' 1 2.95 278 8771 +~ 0.01 ~' I 2.96 279 8802 ~~ 0.02 7 ' 2.95 280 8833 ~~ 0.01 ~1 I 2.96 281 8865 ~~ 0.01 5 i 2.93 282 8896 i) 0.02 ~) 2.94 283 8928 ~? 0.02 ~) ~ 2.93 284 8960 U 0.01 i I 2.95 285 8990 U 0.04 14 I 2.91 286 9022 l) 0.0 13 ! 2.89 287 9052 !~ 0.01 4 2 2.96 ~Penetration Body Metal Loss Body Page 6 ~ PDS REPORT JOINT TABI, Pipe: 3.5 in 9.3 ppf L-80 EUE-8RD Well: Body Wall: 0.254 in Field: Upset Wall: 0.254 in Company: Nominal I.D.: 2.992 in Country: Survey Date: • iLATION SHEET 2 N-304 Tarn ConocoPhillips (Alaska), Inc USA )uly ~ 5, 2ooa )oint No. Jt. Depth (Ft.) Pc~n. llE„~~t ~In,.) Pen. Body Qns.) P<~n. ",~~ ~1~~i,il los, °~~ Min. I.D. (Ins.) Comments Damage Profile (%wall) 0 50 100 288 9083 ~? 0.03 11 I 2.91 289 9115 ~) 0.02 ~ .94 290 9145 ~) 0.03 12 .' 2.95 290.1 9178 O 0.02 7 .' 2.94 PUP 290.2 9182 U 0 (1 t~ N A GLM 4 Latch ~ 1:00 2903 9186 U 0.01 1 I 2.94 PUP 291 9196 u 0.04 I~M1 I .91 291.1 9225 ~? 0 U i~ 2.81 Baker Mll Slidin Sleeve 291.2 9229 ~~ 0.00 ' l 2.93 PUP 2913 9241 U 0 U ~~ 2J5 Carnco D-Ni le W No Go Pro ~le 291.4 9243 c) 0.00 I i~ 2.92 PUP 91.5 9 49 O 0 ll t~ 3.00 Bake C6 -2 al Assembl 291.6 9259 U 0 U ta 2.96 X-Over 291.7 9265 0 0 (1 ~~ 2.99 Tu in Tail 291.8 9267 U 0.04 1 ~ _' 2.91 PUP 292 9276 ~~ 0.01 > I 2.9 To of 3.5" Liner Penetration Body Metal Loss Body Page 7 • Comparison to Previous fU~Log ~verlay 2N-304 P~~ o~,~.i~ sE.~g, ~~. July 15, 2009 and November 2, 2007 Database File: d:lwarriorldatal2n-3041comp.db Dataset Pathname: run/comp Presentation Format: comp Dataset Creation: Fri Jul 17 20:07:34 2409 Charted by: Depth in Feet scaled 1:300 -50 Delta Metal Thickness 2009 (8Hz} (%) 50 -50 Delta Metal Thickness '?007 (10Hz) (%) 50 2920 2940 ~960 ~980 3000 3020 ~Q40 3060 3080 3140 Metal 31~0 ~ • Average Recorded Metal Thickness Relative to Calibration Point 3.5" Tubing / 5.5" Production Casing Well: 2N-304 Field: Tarn Company: ConocoPhillips (Alaska), Inc Country: USA Survey Date: July 15, 2009 ^ D ecrease ^ In crease 100 3136 125 3922 150 4709 175 5497 GLM 2 ~ ~ ~ 200 6298 ~ E ~ ~ ._ z .~ ~ ~- ° 225 7086 ~ 250 7872 GLM 3 275 8676 GLM 4 s~atrg slee~e ~ ~s w+pWe Seal Assy. / XO! TTL 292 9276 - SO% 0 5 0% C hange in Metal Thick ness (% ) Bottom of Survey = 292 ing . 162 Metal 51~0 Tubing Jt. 163 5140 ~Tool Tubing Jt. 164 Collar1 5180 7% Metal Colla Tool Jar ~~ Apparent Isolated Met~l 5~0C'API~i Tubing Jt. 165 Apparent ~~ Tool Jar Tubing Jt. 166 Metal Thickness~40 4% Metal Loss Tu bing Colla -50 Delta Metal Thickness (%) 50 a 0 Line Speed (ft/min) -200 ~ ^ -6.8 Metal MTTP~1 (rad) MTTP1 ~ (rad) Isolated Metal Isolated Metal Isolated Metal Isolated Metal Isolated Metal Isolated 12 3.2 . KUP 2N-304 ConocoPhillips "~~~"~~~ al,,,-., ~ .... ~~.. WaAbweAPVU1M 501032038270 ReltlNane We118t~ue TARN PARTICIPATINGAREA PROD Mdnllon~ 69.37 hD~tl(8) TohIDK~1~N 3,111.68 10,052.0 ... i2 d5 ss VM ... . Comne[ NIPPLE ... H2 (ppn) 65 7/1/2008 Last WO: te litl pq g RNease DYe 40.54 &15/2001 MioGtlon ~ BM D~e BW Date Last Tag: 9.580 0 SI92008 Rev Reason: RESET 7UMP 8I71/2008 Casin 8tri a s e~ ~ wc G Dewiptlon OD ID To p IN~) (~°) (mM4 ~a0e TopTlteW coNwcroR, CONDUCTOR 16 15.062 0.0 152.0 152.0 62.58 H-40 WELDED ~SZ SURFACE 75/8 6.875 0.0 2.930A 2,305.4 29J0 L-80 BTC-MOD ~ PRODUCTION 5 1/2 4.950 0.0 9,243.0 5,247.7 15b0 L-80 B C-MOD ~ sssv.svs LINER 31/2 2.992 9,263.0 10,036.0 5.861J 9.30 L-80 EUE~rd Tubin Sbi ~ ~ na o Pn ~ r~a sd o rom ~,vo~ mKa ~ ro~a .~ Tw ,~•~~ TUBING 31l2 2.992 0.0 9,266.0 5,258.9 9.30 L~0 EUE-8RD Otlrer In Hole A ll Jawel : Tub Run 8 Ratriava Fish e~c. op ~mm~rt Run ate p cns uFr 495.0 SSSV NIPPLE CAMCO'DS' NIPP LE WMO GO P ROFILE &14/2001 2.875 . 1~oa 2.604.0 GAS LIFT CAMCO/ G 2-9VtIDMV/INT//! Comment: STA 1 8/14I2001 2.9W 5.948.0 GAS ll C O/KBG 2A11/DMY/INT!/ Conrnenc STA 2 SI142001 2.900 8,159.0 GASLIFT CAAACOMBG 2~IilDMY/1 1/ICommenc STA3 8/1 1 2.900 ~ 9.782.O GASLIFT CAMCOMBG 2El1/DMYANT///Commenk S A4 3/282002 2.900 SURFACE ~ 9.225.O SLEEVE-O BAKER MU IJDINGSL.EEVE-OPEN 11(.i12007 8/142001 2.873 , 2,xw 9,225.0 PUMP 3' JETPUMP ( SN# AR-1013, 1Q8 RATIO: pt M 71 THRO ~ &9/2008 9,241.0 NIPPL CA CO'D' NI PPLE WMO GO PROFILE &14l200 2J50 9,242.0 XO 74/2001 4.000 9,243.0 CSR BAI~R CASIN G SEAL RECEPTCLE &14l2001 4.000 9.249.0 SEAL BAI~R GBH-7 1 SEALlSSEMBIY 81142001 3.000 9,262.0 XO 8l14/2001 2.960 ~~ ~~~. 9.2 .0 L &142001 2.992 s.eee 10.035.0 SHO &142b01 2.992 PeAoralfons Top (Ty~ 86n (iw) De~K GA5 T~V ~w ~h11(III(B~ ~8) ~tlCB{ ZMIe ~~-~ D0t! CAIMItlf 8 159 9,592.0 9,602A 5,506.8 5 514. IPERF BERMUDA 2N-304 4.0 11/72/2007 2.5" HSD, BH Clgs, 180 deg phase, 45/227 deg aient Stimulations & T rsa~u~t s Mn Tap I~Yx &m aP~ aP~ (~W I~I Mh Calm enl 9,592.0 9.602.0 11/17f1001 FRAC BERMUDA FRAC, 219,O OQp 12/18 CARB OLITE 10 PPA ON PERFS cas uFr. 9.782 S~EEVE-0. 9.2I5 PUMP, 8 ~75 NIP~LE. 9141 x0.9I41 :~~ PfiOWCTION. 9,1<3 CSR. 9 243 SF,Pl, 9,7a9 X0.9162 ]~ TfL. 9 266 IPERF. ' 8.59]-9.607 FRAC. 9,591 LINER. 10 036 TD (2N304). 10,057 .~5 • WELL L4G T1~~4/1/~'M/T7~4L Prolsictive 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 BP Exploration (Alaska), Inc. Petrotechnical Data Center Attn: Andy Farmer LR2-1 900 E Benson Blvd Anchorage, Alaska 99508 and ProActive Diagnostic Services, Inc. Attn: Robert A. Richey 130 West International Airport Road Suite C Anchorage, AK 99518 Fax: (907) 2458951 Zvi-~3v '~ ~s~4a 1) Caliper / NETT 02-Nov-07 2N-304 1 Report / EDE 50.103-20382-00 ~ :~3 ,> ~ , Date Signed : ~1 , X ~ i'{~1f 1 ^L, ~ ~ Print Name: ~~ ~ i 1`I ~ ,~ !U th ~n ~ ~~~o~.. . PROACTIVE DIAGNOSTIC SERVICES, INC., 130 W. INTERNATIONAL AIRPORT RD SURE C, ANCHORAGE, AK 99518 PHONE: (907)246-8951 FAX: (997)245-96962 E-MAIL: pdsanchorar~eCa~rreemor*.lloq.com WEBSRE: Wv~r~r.memor; to .cam D:\MesOV_Copy_~ PDSANG20~odZ_WordlDistn~hu6on\Tiarisutittal_Sheet\'[ym~smit_Origina-_New.doc • • Company: Log Date: Log No. Run No.: Pipet Desc.: Pipet Use: Pipet Desc.: Pipet Use: COMMENTS Memory MultaFinger Caliper tog Results Summary ConocoPhillips Alaska, Inc. Weli: November 2, 2007 Field: 8647 State: 1 API No.: 3.5" 9.31b. L-80 BTC-MOD Top Log tntvl1.: Tubing Bot. Log Intvll.: 5.5" 15.5 Ib. L-80 BTC-MOD lop Log Intv11.: Production Casing Bot. Log Intvl1.: Corrosive & This /og is tied into the GLM 4 ~ 9,182' (Dril/er's depth). 2N-304 Kuparuk Alaska 50-103-20382-00 Surtace 9,231 Ft. (MD) Surtace 9,231 Ft. (MD) This is the fast tog of this well made a 24 Arm Caliper and a 12 Arm Magnetic Thickness Toot (MTT). The caliper records internal features of the 3.5" tubing and the MTT responds to the total thickness of me#aI of the 3.5"tubing and 5.5" production casing. The additional metal volume of the 7.625" surface casing prevented the normal functioning of the MTT, resulting in a loss of interpretable data from the bottom of the 7`.625" surfacing casing upward (surface to 2,939'). ' INTERPR~ TIQII~,QF CALIPER LOG RESULTS This log was run to assess the condition of the 3.5" tubing with respect to corrosive and mechanical damage. '' The caliper recordings indicate that the 3.5" tubing interval logged ~s in good condition with respell to corrosive damage. No signficant wall penetrations (>17%), areas of significant cross-sectional metal loss (> 4%j orsignificant LD. res#rictions are recorded. ' 3.5" Tubing -MAXIMUM RECORDED WALL PENETRATIONS: No sign cant wal! penetrations (> 17%) are recorded. 3.5" Tubing -MAXIMUM RECORDED CROSS-SECTIONAL METAL LOSS: No areas of significant cross-sectional metal loss (> 4%j are recorded. 3.5" Tubing -MAXIMUM RECORDED ID RESTRICTIONS: No signifcant l.D. restrictions are recorded. INTERPRETATION OF MTT LOG RESULTS : The MTT log results cover the interval from 2,939' to 9,231'. The recordings above this interval are un- interpretable due to the increased meta! volume of the 7.625" surface casing. Average recorded {ass of metal thickness relative to the calibration point is 3% to 7% throughout the interval Logged (2,939' - 9,231'). ProActive Qiagnostic Services, Inc. % P.O. Box 1369, Sta`fors~, TX 77497 ~' ~+ Phone: (231) ar (888) 565-9085 Fax: (281) 565-1369 E-mail: PDS~ memorylog.co Ci -,,, ~,~:~ ' Prudhoe Bay Field O{fice Phone: (907 659-2307 Fax: (907) 659-2314 ~~laska C7i1 ~ ias ~0~~3~. a:,~rrtri~i~~i~~ . ~ =~r~c>~~re aar~-~3~ ~ ~ s~9a 1 ~ • The percent circumferential metal loss expressed in this summary is a percentage of the total metal that the " " ' pipe. If aN of the metal loss is specific tool is responding to, which includes influences from the 3.5 and 5.5 to the 5.5" surtace casing, the percent metal loss from that pipe alone is probably higher than the numbers expressed. The metal loss indicated could be from eikher or both the 3.5" tubing or 5.5" production casing. ' Due to the concentric pipe strings in the log interval, the MTT response is qualitative -indicating an overatl increase or decrease in metal surrounding the tool, but nat distinguishing in which pipe string the change in metal thickness occurs. In this log, the MTT was calibrated down hole (8,939'), where the readings are ' assumed to represent undamaged tubing and casing. All other readings are relative to this reference point, which include influences from the 3.5" tubing and 5.5" production casing. The original MTT data recorded in this wel! exhibited a high signal to noise ratio throughout the data set, and ' was high-pass filtered error to being analyzed. White this filtering of the original data may have masked some high frequency isolated damage indications, it shoo/d have no significant effect on the measurement of overall circumferential metal loss discussed in this analysis. Field Engineer: K. Miller Analyst: B. Qi (caliper)/M. Lawrence & J.Burton (MTT) Witness: C. Kennedy ~ ' ProActive Diagnostic Services, Inc. / P.J. Box 1369, Stafford, TX 77497 Phone: (281) or (888) 565-9085 Fax; (281) 565-1369 E-mail: PDS@memorylog.com Prudhoe Bay Field Jffice Phone: (907} 659-2347 Fax: (947) 659-2314 i • PDS Report Overview ~ ~w Body Region Analysis Well: 2N-304 Survey Date: November 2, 2007 Field: Kuparuk Tool Type: UW MFC 24 No. 214320 Company: ConocoPhillips Alaska, Inc. Tool Size: 1.69 Country: USA No. of Fingers: 24 Anal t: B. i Tubing: Nom.OD Weight Grade & Thread Nom.ID Nom. Upset Upper len. Lower len. 3.5 ins 9.3 f L-80 2.992 ins 3.5 ins 6.0 ins 6.0 ins Penetration and Metal Loss (°k wall) ~ penetration body metal bss body 200 150 100 50 0 0 ro 1 to 10 ro 1% 10% 20% 20 ro 40 ro over 40% 85% 85% Number of ~oints anal se d rota) = 302 pene. 0 199 103 loss 141 161 0 0 0 0 0 0 0 Damage Configuration (body ) 60 40 20 0 isolated general line ring hde /pons pitting corrosion corrosion corrosion ible hole Number of 'Dints dama ed total = 54 54 0 0 0 0 Damage Profde (% wall) ~ penetration body ~ metal loss body 0 50 100 0 GLM 1 96 GLM 2 194 GLM 3 GLM 4 Bottom of Surveys 291.1 Analysis Overview page 2 Pipe: Body Wall: Upset Wall: Nominal LD.: ~ ~ PDS REPORT JOINT TABULATION SHEEP 3.5 in 9.3 ppf L-80 Well: 2N-304 0.254 in Field: Kuparuk 0.254 in Company: ConocoPhilips Alaska, Inc. 2.992 in Country: USA Survey Date: November 2, 2007 Joint No. Jt. Depth (Ft.) I'~~n. Uhsc~t (Ins.) Pen. Body (Ins.) Pc~n. % Metal Ic~ss "~~ Min. LD• (Ins.) Comments Damage Profile (%wall) 0 50 100 .1 34 (1 0. 1 2 1 2.95 PUP 1 39 ~~ 0.0 12 a 2.8 1.1 66 a 0.03 11 ~1 2.89 PUP 1.2 77 U 0.03 10 U 2.90 PUP 2 81 U 0.0 ~) 1 2.89 3 112 U 0.0 3 1 2.89 4 143 ~ ~ 0.03 I :, ~ 2.89 hallow itti 5 175 l t 0.02 ~) 2.89 6 206 U 0.0 I1 1 2.92 7 237 U 0.03 10 7 2.89 8 269 U 0.02 9 I 2.91 300 O 0.01 4 2.91 10 33 tt 0.02 ~~ i 2.90 11 62 t I 0.01 6 1 2.92 12 3 3 tt .02 9 1 2. 2 13 424 It 0.03 1 U 1 292 14 456 t ~ 0. 2 9 ~ .93 5 4$7 t~ 0.01 6 2.9 1 .1 518 ~ ~ 0 0 tt 2.88 DS Ni e 16 520 t ~ 0.02 i t) 2.91 17 5 1 t~ 0.02 ~i I .91 18 583 t ~ 0.02 ~? i 2.90 19 614 U 0 03 10 _' 2.92 20 645 It 0.03 12 ~ 2.91 21 6 It 0 02 8 1 .90 22 708 t ~ 0.02 7 1 2.90 23 738 tt 0. 3 10 1 2.92 24 770 tt 0.02 ~~ I 2.91 2 802 O 0.02 7 .90 26 833 tt 0.02 7 I 2.90 2 7 863 l) 0.0 7 I 2.89 28 895 0 0.02 f3 1 2.90 29 926 a 0.02 9 2.91 30 958 U 0.03 11 I 2.91 31 989 t ~ 0.03 1 ~ I 2.9 32 1020 a 0.03 1 ~' I 2.91 33 1052 U 0.01 6 2.92 34 1083 U 0.01 6 _' 2.89 35 1115 (t 0.02 ~ 2.8 36 1145 tt 0.03 1 ~ I 2.92 Shallow 'tin . 37 1177 0 0.03 11 ? 2.93 38 1208 U 0.02 ~) 1 2.92 39 1239 i t 0.03 I U 1 2.91 40 1270 I~ 0.02 8 2 2.92 41 1301 t) 0.0 9 1 .93 42 133 a 0.03 1 U 2 2.91 4 1365 a 0.0 7 tt 44 1395 l t 0.02 7 1 .92 45 14 6 ~ ~ 0.03 11 :? 2.9 46 14.18 0.04 I _t 2.90 Shallow itti Penetration Body Metal Loss Body Page 1 • PDS REPORT JOINT TABULATION SHEEP Pipe: 3.5 in 9.3 ppf L-80 Body Wall: 0.254 in Upset Wafl: 0.254 in Nominal I.D.: 2.992 in WeN: 2N-304 Field: Kuparuk Company: ConocoPhilips Alaska, Inc. Country: USA Survey Date: November 2, 2007 Joint No. Jt. Depth (FtJ I'c~n. UI>tc~l (Im. } Pen. Body (Ins.) Pen. %> Mc~l,il Ic~sS ~~ Min. LD• (Ins.) Comments Damage Profile (%wall) 0 50 100 47 1489 t~ 0.03 l a _' 2.90 Shallow i "n . 48 1521 ~) 0.03 11 _' 2.91 49 1552 I ~ .02 t~ _' 2.91 0 1584 U 0.04 I ~l _' 2.91 allow 'ttin 1 1615 U .02 2.91 5 144 U 0.03 I i 2.90 Shallow i 53 1663 U 0.04 I I 2.90 Sh I ittin Lt. De sits. 54 1694 l~ 0.03 I Z I 2.89 55 1725 U 0.03 I ~ _' 2.90 Shallow ittin . 56 1757 tl 0.0 t3 1 .96 5 1789 U 0.0 1 t 1 2. 6 58 18 0 0 0 0 L3 I 2.91 hallow i Un . 59 1852 (1 0 03 12 2.90 60 188 a 0.03 1 3 2.91 Sh low i tin . 61 1914 l) 0.03 I s I 2.91 allow 't6n . 62 1946 ~ 1 0.03 11 ~ 2.91 63 978 U 0.03 1 3 1 2.91 hallow it9n . 64 009 U 0.04 15 ' 0 h• low it 65 041 U 0.02 ti 1 .93 66 2072 U 0.04 15 I 2.89 Shallow ittin . 67 103 t~ 0.0 I _i I 2.91 hallow 'ttin . 6 2135 tl 0.04 I.3 1 2.90 Shall w it6n . 69 66 U 0.0 1 ~ _' 2.91 70 2198 t) 0.02 ~) 1 2.96 71 U ~) 72 2261 I? 0.04 15 2.90 Shallow ittin . 73 2293 t~ 0.03 11 .91 74 2324 t) 0.02 ti _' 2.93 75 355 a .03 1 I .9 Shallow ittin . 76 2387 I ~ 0.02 ti ? 2.91 77 2418 I ~ 0.03 I ~ t 2.91 Shallow ittin . 78 2448 U 0.02 7 2.91 79 2480 l) 0.03 1U 1 2.94 80 2512 tl 0.04 14 _' 2.92 Shallow 'ttin . 81 2544 U 0.04 14 5 2.89 Shallow 'ttin . 82 2574 t1 0.03 13 2 2.90 Shallow ittin . 2.1 606 O 0. 3 11 ~ 2.94 P P 82.2 2612 u 0 U ~~ N A CLM 1 Latch ®4:30 2.3 620 I ~ 0.02 t5 _' 2.92 PUP 83 2623 t) 0.02 7 1 2.93 84 6 5 (~ 0.02 9 Z 2.92 85 2687 l) 0.03 1 Z 2.91 Shallow it6n . 86 717 ll .0 8 1 .93 87 2749 ll 0.04 16 2.91 Shallow ittin . 88 7 ll 0.04 1-1 _' 2. hallow ittin . 89 2812 n 0.03 I u I 2.90 90 2843 u 0 7 I .94 91 2875 tl 0.02 ff I 2.90 9 2906 ~ ~ 0.03 t ~ ~ I .91 93 2938 0.02 2.88 Penetration Body Metal Loss Body Page 2 i • PDS REPORT JOINT TABULATION SHEET Pipe: 3.5 in 9.3 ppf L~0 Body Wall: 0.254 in Upset WaB: 0.254 in Nominal I.D.: 2.992 in Well: 2N-304 Field: Kuparuk Company: ConocoPhilips Alaska, Inc. Country: USA Survey Date: November 2, 2007 Joint No. )t. Depth (Ft,) I'e~n. UI~~~~t (his.) Pen. Body (Ins.) I'c~n. "rb ~~tc~i.~l Ic>sc °~~ Min. LD. (Ins.) Comments Damage Profile (%wall) 0 50 100 4 2969 l) 0.03 12 I 2.91 95 2998 t~ 0.03 11 1 .90 96 3030 a 0.02 £i 1 .95 97 061 tt 0.04 15 1 .91 Shallow 'ttin . 98 3093 U 0 03 11 I 2.91 99 3124 U .02 £~ _' 2.91 1 3155 U 0.03 1 u ~ 2.92 101 3187 a 0.03 1 ~ I 2.92 10 1 U 0.0 ~~ .92 103 249 U .0 £3 ~ 2.94 104 3 81 t? 0.0 7 I 2.90 10 3312 ~ ~ 0 04 1 V Z 2.92 Sh low 'tU 106 3344 U 0.02 ~I _' 2. 2 107 337 t~ 0. I1 1 .89 108 3407 l~ 0.02 ~) 1 2.9 109 38 I ~ 0.03 10 1 2.92 110 3470 ~) 0.02 `~ 1 .91 11 3501 c~ .0 13 ~' 2.90 Shal w it' 11 3532 t~ 0.0 7 I .93 113 3564 l1 0.02 9 1 2.91 114 3595 (1 0.03 12 t) 2.90 1 5 3626 t) 0.03 I I 2.91 hall 'tUn . 116 3658 t ~ 0.0 8 1 2.93 117 3690 t) 0.0 `> ~' 2.90 11 37 a 03 I Z .9 119 3753 U 0.03 11 1 2.91 120 37$4 a 0.01 6 I 2.91 121 3815 t) 0.03 1 1 _' 2.91 Shallow 'ttin . 122 3847 l~ 0.02 `~ .90 123 3879 t) 0.02 £3 I 2.93 124 3909 t) .03 I3 1 .93 Shallow itOn 125 3941 U 0.03 13 1 2.91 Shallow 'tUn . 126 397 a 0.03 11 1 .91 127 4004 t) 0.0 1 U _' 2.89 1 8 403 a 0.02 £3 .94 129 4065 t) 0.03 11 I 2.91 3 4097 t1 0.03 I i ? 2.89 w 't' 131 4129 t~ 0.02 £3 I 2.94 13 4160 It 0. 4 1-1 1 2.92 hallow 't' 133 4192 a 0.02 9 1 2.95 134 4 23 U 0.02 f3 1 .90 135 4255 to 0.02 £~ U 2.91 136 4285 ~! 0 1(1 2 .93 137 4317 l~ 0.02 (i I 2.95 138 43 U 0.03 13 _' 2. 1 I w 't ' 139 4380 U 0.02 ~~ ! 2.91 140 441 ~ ~ 0.01 ~ .91 141 4443 U 0.02 £~ I 2.91 42 4474 t 1 0.0 i I 91 143 4505 t~ 0.0 ~) 2.93 Penetration Body Metal Loss Body Page 3 PDS REPORT JOINT TABULATION SHEET Pipe: 3.5 in 9.3 ppf L-80 WeN: 2N-304 Body Wall: 0.254 in Field: Kuparuk Upset WaN: 0.254 in Company: ConocoPhilips Alaska, Inc. Nominal I.D.: 2.992 in Country: USA Survey Date: November 2, 2007 Joint No. Jt. Depth (Ft.) I'crn. Upset (Ins.) Pen. Body (Ins.) Pc~n. % ~Ictal I oss °~<~ Min. LD• (Ins.) Comments Damage Profile (% wall) 0 50 100 144 4537 O 0.03 I1 1 .90 145 4568 t) 0.0 £'' . 4 1 4599 U 0. 3 12 I .91 147 63 0 D 03 11 1 2.91 148 4662 U 0. ti I 2 95 14 4693 U 0. 3 1 Z 1 .91 15 4724 i) 0. 3 12 I 151 4756 U 0.02 tt I 2.94 152 478 U 0.0 ~) =i 2. 0 1 3 4 19 U 0 2 £3 I 95 154 4850 a 0.0 ~ t .9 1 S U 0.03 13 I .8 alto 156 491 U 0.04 16 ' .89 Shallow 'ttin . 157 4944 t) 0 02 is 2 93 1 8 4975 U .0 9 .91 1 9 5006 t) .02 ~ I 2.91 160 50 U 0.02 ~ ' 2.91 1 5070 U 0.01 5 2 16 5100 U 0. 3 11 2. 8 163 5132 U 0.0 t3 I 4 164 5163 0 0 03 1 1 _' .91 1 5 195 U 0.04 I -1 .90 166 5227 ~) 0.02 t3 2. 0 167 5258 tt 0.04 14 _' 2.89 Shallow ~tUn . 168 5 9 ~) 0.02 ~~ I .9 169 5321 U 0.02 7 Z 2.91 170 5 52 U 0.02 £3 1 .93 171 5383 O 0.03 13 _' 2.91 Shallow itfin . 1 5414 U .03 l .91 allow 't' 173 5446 ~) 0.04 1 ~ I 2.89 Shallow 'ttin . 174 5478 t) O.OZ 7 2.94 175 5509 a 0.02 ti ~' 2.90 Lt De its. 176 5541 ~~ 0.02 ~~ .8 177 5572 O 0.02 tt _' 2.93 178 603 ~ 0.02 ~) ~' 2.91 179 5635 U 0.02 ~~ I 2.92 1 5666 l) 0.02 8 I 2 1 181 5697 U 0.02 8 ~' 2.91 18 57 a 0.0 ~) 2. 9 183 5759 t) 0.04 I5 :' 2.91 Shallow it6n . 184 5790 t) 0.02 ct 2 2.90 185 58 3 t t 0.0 t3 I 2.94 1 6 5853 U . 4 15 2 .90 ~t~ 187 5885 O 0.02 E3 :' .94 1 5916 t) 0.0 t3 _' 2.95 188.1 5947 0 0.02 ~~ 1 2.91 PUP 188.2 5953 ~l 0 u t t N A LM 2 t h e 800 188.3 5960 ~ ~ 0.01 4 I 2.95 PUP 189 5964 0.02 ~ ~ I 1 190 5997 0.02 t) ' 2.94 Penetration Body Metal Loss Body Page 4 Pipe: Body Wall: Upset Wall: Nominal I.D.: ~ ~ PDS REPORT JOINT TABULATION SHEET 3.5 in 9.3 ppf L-80 Well: 2N-304 0.254 in Field: Kuparuk 0.254 in Company: ConocoPhilips Alaska, Inc. 2.992 in Country: USA Survey Date: November 2, 2007 Joint No. Jt. Depth (FtJ f'c•n. UI„~~t Ilns.} Pen. Body (Ins.) I'c~n. % 1Ac•t,~l logs °"<~ Min. LD• (Ins.) Comments Damage Profile (%wall) 0 50 100 191 6028 ~ t 0.03 12 -~ 2.93 19 605 a .0 1O 2 2.89 193 6089 (t 0. 3 1 I Z 2.93 194 6120 U 0. 2 7 .91 195 6152 a .0 t3 ~~ .91 196 6181 (t 0.02 `~ _' .91 197 621 ~ t 0. 1 ' I .90 198 6245 t1 0.02 £~ ~) 2.95 1 6 7 tt .01 5 I 92 200 6306 a 0.03 12 1 2.91 201 6337 It 0.03 10 ~' 2.92 Lt. De i 202 637 It 0.02 ~ 1 2 94 203 40 U 0 0 I _' 2.91 04 434 ~~ 0.0 r3 -1 2.95 205 646 (t 0. 3 1 u ! .91 2 6497 (t 0.04 I ~1 5 2.90 hall w it6n . 207 65 8 t t 0 02 t3 1 .92 08 559 ~ t 0.0 I ~' .90 09 59 (t 0.0 t3 I 2.94 10 6623 ~ t 02 .91 11 654 ~ t 0.03 1 ~ t ? .89 21 6 6 (t .0 7 1 3 21 6717 a 0. 3 12 2.90 214 6749 (t 0.01 5 I 2.88 1 67 U 00 8 ~ 5 216 6811 (t 0.03 1 1 2.90 217 6843 U 0. 2 ~t I .90 218 6875 (t 0.02 ~ _' 2.94 219 6 6 t t 0.02 ~ 2.89 220 6937 ~t 0.03 I_' I 2.90 Shallow 'ttin . 221 6970 u 0 02 is I 2.93 222 7000 I t 0.02 ~~ 2.93 2 7031 U 0.03 11 .' 2.90 224 7062 ~ t 0.02 t3 I 2.90 225 7094 ~ t 0.03 1 tt 1 2.91 226 7125 (t 0.02 fi 2.94 227 7156 U 1 ~~ I 2.9 228 7187 U 0.02 7 2 2.90 2 7 19 U .02 ti 1 2.91 230 7250 0 0.02 7 1 2.92 2 1 7 8 U 0.02 7 Q 2.9 232 7313 (1 0.03 11 2 2.91 33 7345 (? 0.03 13 ? 2. 9 S Ilow 't'n 234 7377 (~ 0.04 L5 ~ 2.90 235 7408 ~t .02 ~ 1 2. 4 236 7439 a 0.02 r3 2 2.92 2 7 7471 U 0.0 1 Z ~' 2.90 238 7502 (1 0.02 ~) ~' 2.91 239 75 4 tt 6 2.9 240 7565 ~ t 0.04 1 ~ 2.91 Shallow ittin . Penetration Body Metal Loss Body Page 5 ~ ~ PDS REPORT JOINTTABUTATION SHEEP Pipe: 3.5 in 9.3 ppf L-80 Body Wall: 0.254 in Upset Waq: 0.254 in Nominal I.D.: 2.992 in Well: 2N-304 Field: Kuparuk Company: ConocoPhilips Alaska, Inc. Country: USA Survey Date: November 2, 2007 Joint No. Jt. Depth (Ft.) Pen. Upset (lns.) Pen. Body (Ins.) Pc~n. % :Metal I ~»s `k> Min. LD• (Ins.) Comments Damage Profile (% wall) 0 50 100 241 7596 (~ 0.02 t9 1 .94 242 7628 0 0.03 11 ? .93 43 7658 0 .02 `~ ' 8 44 7691 l) 0.02 7 1 2.94 45 77 2 l) 0 0 ~~ I .91 246 7 5 tl 0.03 I I t .93 247 7784 (1 0. 7 1 . 0 248 7815 U 0.01 t~ I .91 249 7847 (1 0.02 6 1 2.90 50 7879 U 0.01 5 ~' 2.93 2 1 7910 0 0.0 11 I .91 5 7941 t~ 9 2.90 2 3 7973 U 0.03 10 ~' 2.90 2 4 8004 U 0.0 ~) . 0 55 80 5 U 0.02 t3 .' 2.95 256 8066 t) 0. 2 ~) ; 2.89 57 98 a 0.03 I U i~ 2 91 258 130 ~) .02 7 2.93 58.1 8161 U 0. 2 7 u 2.98 P P 258. 8164 U 0 0 tl N A LM 3 Latch ®11:4 258.3 8173 t) 0.0 1 1 2 2 92 PUP 5 8181 ~~ 0.0 ti ~~ 9 260 8 10 U 0.01 6 t~ 2.92 261 8241 0 0.02 t3 ~ 2.92 6 827 U 0.02 8 1 .94 263 8305 l) 0.03 13 Z 2.90 Shal ow 't6n . 264 8336 l1 0.01 5 2.90 265 8367 t~ 0.02 ti 1 2.95 266 8399 l) .02 `) 2.91 267 8431 t~ 0.03 1 3 I 2.92 Sh Ilow 't6 268 8462 (~ 0.02 1 .90 269 8495 U 0.02 i ' 2.92 270 8526 t~ 00 8 1 .93 271 8557 t) 0.02 9 ~ 2.91 72 8588 a 0.0 12 _' 2.91 273 8619 t ! 0.01 5 ? 2.91 274 8 9 (~ . 3 10 > 1 75 8682 t I 0.02 ~~ I 2.91 276 8713 t1 0.02 ~) 2 2. 2 2 77 8744 t ~ 0.02 t3 ~? 2.91 278 8776 a .03 1 ~ I 2.91 279 8807 U 0.02 is ~ 2.90 280 8838 i ~ 0.0 ~ 1 90 281 8869 ~~ 0.02 7 ~ 2.91 28 8901 ~l 0.02 8 ~i .94 2 3 8931 t ~ 0.02 ti ~' 2.92 2 8963 U 0.0 `~ 2 2.94 285 8994 a 0.02 `~ 1 2.91 2£36 9026 ~' 0.0 .94 2Fii 9056 ~ 0.02 2.90 Penetration Body Metal Loss Body Page 6 r PDS REPORT JOINT TABULATION SHEET Pipe: 3.5 in 9.3 ppf L-80 Well: ZN-304 Body Wall: 0.254 in Field: Kuparuk Upset WaN: 0.254 in Company: ConocoPhilips Alaska, Inc. Nominal I.D.: 2.992 in Country: USA Survey Date: November 2, 2007 Joint No. Jt. Depth (Ft.) Pen. Ulsc~t (Ins.) Pen. Body (Ins.) Pen. % Metal Loss `~~~ Min. LD• (Ins.) Comments Damage Profile (%wall) 0 50 100 288 9087 tt 0.01 6 I 2.91 28 9119 O 0.02 8 ~ 2.93 290 9150 t~ 0.04 17 .93 Shallow ~t'n . 290.1 9182 l> 0.03 11 ~ 2.94 P P 290.2 9186 tt 0 ~ tt N A GLM 4 Latch ~ 1:00 290.3 91 4 t1 0.03 11 2 2.94 PUP 291 9198 ~? 0.02 '> _' 2.94 291.1 9229 ~~ 0 U tt 2.81 Slidin Sleeve __ Penetration Body Metal Loss Body Page 7 ~ i Average Recorded Metal Thickness Relative to Calibration Point Pipe 1 3.5 in (2938.1' - 9229.1') Well: 2N-304 Field: Kuparuk Company: ConocoPhillips Alaska, Inc Country: USA Survey Date: November 2, 2007 Decrease ^ Increase 100 3155 125 3941 150 4724 175 5509 GLM 2 _ ~ ~ 200 6306 LL ~ .~ Z t Y ~ ° 225 7094 0 250 7879 GLM 3 275 8682 GLM 4 291.1 9229 -50% 0 50% Change in Metal Thickness (%) Bottom of Survey = 291.1 • KRU 2N-304 ConocoPhillips Alaska, Inc. • • ConocoPhillips aas~ P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 October 4, 2007 Mr. Tom Maunder Alaska Oil & Gas Commission NCB ~ ~ 2pU? 333 West 7~` Avenue, Suite 100 Anchorage, AK 99501 ~~~ Dear Mr. Maunder: ~~~ ~Q Enclosed please find a (revised 10/3/07)spreadsheet with a list of wells from the Kuparuk field (KRU). Each of these wells was found to have a void in the conductor. These voids were filled with a 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 top jobs were pumped on September 9, 2007 and the corrosion inhibitor/sealant was pumped on September 16-27, 2007. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. This spreadsheet is a revised format for the original submitted on 9/28/07 Please call myself at 907-659-7506, or M.J. Loveland at 659-7043 if you have any questions. Sincerely, ~ ~ ~--~ on Arend ConocoPhillips Well Integrity Field Supervisor • • ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations {10-404) Date Kuparuk Field 9/28/2007 Well Name PTD # initial top of cement Vol. of cement um ed Final top of cement Cement top off date Corrosion inhibitor Corrosion inhibitor/ sealant date ft bbls ft al 2L-303 201-239 7' 7" 1.2 18" 9/9/2007 7.5 9/16/2007 2L-309 205-210 13' 3" 2 18" 9/9/2007 7.5 9/16/2007 2N-302 201-115 5' 11" na 5" 11" na 39.5 9/16!2007 2N-313 198-091 5' 0.75 18" 9/9!2007 2N-335 198-204 20" na 20" na 13 9/16/2007 2N-347 200-063 21' 4 18" 9/9/2007 6 9/16/2007 2N-348 201-142 4' 8" 1.5 12" 9/9/2007 4.5 9/16!2007 2N-303 200-169 5" n/a 5" n/a 1 9/27/2007 2N-304 201-130 10" n/a 10" n/a 4.5 9/27/2007 2N-305 200-135 12" n!a 12" n/a 7.5 9/27/2007 2N-307 199-017 14" n/a 14" n/a 4.5 9/27/2007 2N-308 199-010 5" n/a 5" n/a 1 9/27/2007 2N-309 199-021 9" n/a 9" n/a 2 9/27/2007 2N-311 206-179 12" n/a 12" n/a 10 9/27/2007 2N-313 198-091 18" n/a 18" n/a 2 9/27/2007 2N-314 200-193 26" n/a 26" n/a 7 9/27/2007 2N-315 19&190 6" n/a 6" n/a 3 9/27/2007 2N-317 198-143 5" n/a 5" n/a 1 9/27/2007 2N-318 200-100 10" n/a 10" n!a 1 9/27/2007 2N-319 198-197 5" n/a 5" n/a 9.5 9/27/2007 • ConocoPhillips a~~ P.O. BOX 100360 ANCHORA6E,ALASKA 99510-0360 September 28, 2007 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7~` Avenue, Suite 100 Anchorage, AK 99501 Dear Mr. Maunder: ~, Nov a $ 2007 ~~C~ Q~T '~Fo A!$ske Di/~ ~~ ~ 2 ZOp j s a~e~o ~g~ C~lssi on a ~o~,t3 Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRLJ). Each of these wells was found to have a void in the conductor. These voids were filled with a 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 top jobs were pumped on September 9, 2007 and the corrosion inhibitorlsealanttyas pumped on September 16-27, 2007. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please call myself at 907-659-7043, if you have any questions. Sincerely, ,. /~ M.J. vel d ConocoPhillips Well Integrity Projects Supervisor • ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) Date Kuparuk Fieid 9/28/2007 Well Name P7D # Initial top of cement Vol. of cement um ed Final top of cement Cement top off date Corrosion inhibitor Corrosion inhibitor! sealant date ft bbls ft al 2L-~03 201-239 7' 7" 1.2 18" 9/9/2007 7.5 9/16/2007 2L-309 205-210 13' 3" 2 18" 9/9!2007 7.5 9/16/2007 2N-302 201-115 5' 11" na 5" 11" na 39.5 9!16/2007 2N-313 198-091 5' 0.75 18" 9/9/2007 2N-335 198-204 9" na 20" na 13 9!16!2007 2N-347 200-063 21 ` 4 18" 9/9/2007 6 9/16/2007 2N-348 201-142 4' 8" 1.5 12" 9/9/2007 4.5 9/16!2007 2N-303 200-169 5" n/a 5" n/a 1 9/27/2007 2N-304 201-130 10" n/a 10" n!a 4.5 9/27/2007 2N-305 200-135 12" n/a 12" n!a 7.5 9127/2007 2N-307 199-017 14" n!a 14" n/a 4.5 9/27/2007 2N-308 199-010 5" n/a 5" n/a 1 9!2712007 2N-309 199-021 9" n/a 9" n/a 2 9/27/2007 2N-311 206-179 12" nia 12" n/a 10 9/27/2007 2N-313 198.091 5" n/a 5" nia 2 9/27/2007 2N-314 200-193 26" n/a 26" n!a 7 9/27/2007 2N-315 198-190 6" nia 6" n/a 3 9!27!2007 2N-317 198-143 5" n/a 5" nia 1 9/27/2007 2N-318 200-100 10" n/a 10" n1a 1 9/27/2007 2N-319 198-197 5" n/a 5" n/a 9.5 9/27/2007 Û/o ,,.,.,..,.........--..""~----- 01/02/07 Schlumberger NO. 4092 Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Company: {";';-,: \).~::;'~.~\~ 'stANNED JAN 0 8 2007 ~{-/ðÒ Field: Kuparuk Well BL CD Color Job# Log Description Date 2N-304 11416232 FBHP SURVEY 10/30/06 1 2N-304 11296737 FBHP SURVEY 11/04/06 1 1D-109 N/A INJECTION PROFILE 11/27/06 1 1J-136 (REDO) 11534188 USIT 12/10/06 1 1R-18 N/A 5BHP/DD 12/18/06 1 1G-16 11551836 INJECTION PROFILE 12/19/06 1 1D-103 11548555 INJECTION PROFILE 12/20/06 1 3K-09A N/A SBHP SURVEY 12/22/06 1 3K-26 N/A 5BHP SURVEY 12/22/06 1 3K-18 11551838 SBHP SURVEY 12/23/06 1 2N-326 11551840 SBHP SURVEY 12/24/06 1 35-19 11548564 PRODUCTION PROFILE 12/25/06 1 2M-10 11551841 PRODUCTION PROFILE 12/25/06 1 2M-16 11551842 INJECTION PROFILE 12/26/06 1 2A-20 11548565 INJECTION PROFILE 12/26/06 1 2M-15 11551843 PRODUCTION PROFILE 12/27/06 1 2M-22 11538773 PRODUCTION PROFILE 12/28/06 1 1J·184 11538775 PRODUCTION PROFILE 12/30/06 1 Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. . . e e MICROFILMED 07/25/06 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE F:\LaserFiche\CvrPgs _ Inserts\Microfilm _ Marker.doc J '3 b~v DATA SUBMITTAL COMPLIANCE REPORT 11/25/2003 Jpw.-J. })JV1~ -<"01 I API No, 50-103-20382-00-00 Operator CONOCOPHILLIPS ALASKA INC Well Name/No. KUPARUK RIV U TARN 2N-304 Permit to Drill 2011300 Completion Date 11/12/2001 "..----- Completion Status UIC N Current Status 1-01L 1-01L 1 0052 - TVD 5875 - MD --- --- - --- -------------- REQUIRED INFORMATION Directional su~e~____~ y-~, Samples No Mud Log No ------ -- DATA INFORMATION (data taken from Logs Portion of Master Well Data Maint) Types Electric or Other Logs Run: Well Log Information: ^~--- Interval OH/ Start Stop CH Received Comments 120 10415 Open 11/13/2001 120 10415 Open 11/13/2001 2875 10366 Open 'Ißf 120 10415 Open 11/13/2001 Open 9/12/2001 Directional Survey PB1 Open 9/12/2001 Directional Survey PB1 Open 9/12/2001 Directional Survey DIGITAL DATA Open 9/12/2001 Directional Survey 2839 9959 Open 11/29/2001 120 10415 Open 11/13/2001 .-----. Open 9/12/2001 Directional Survey DIGITAL DATA Open 9/12/2001 Directional Survey Open 9/12/2001 Directional Survey Open 9/12/2001 Directional Survey DIGITAL DATA Open 9/12/2001 Directional Survey DIGITAL DATA Open 9/12/2001 Directional Survey -----.--- - " Sample Set Number Comments Logl Electr Data Digital Dataset Type Med/Frmt Number ~ C Pdf L--, 0464 UD C Pdt +-ÉD D itHf C Pdf L-1-0464 ~D i ~ i c¡..E D D Log Log Run Scale Media No final final Name ---.- ----------- ..lnd(jcti()OJRé$išìi\ ~~~U~~::¡lX:N ¡QI J ~ vt.{ (.'w{/... '1 ((,N~ Is h'iJ (~ó y1 1 final FINAL FINAL Directional Survey PB1 Directional Survey PB1 Directional Survey FINAL ~ i ~D C ~ C Pdf ~D FINAL 1 Directional Survey --tO460 VÐ464 final FINAL Directional Survey MWD I~ FINAL FINAL Directional Survey MWD Directional Survey GYRO Directional Survey GYRO I ¿VRpt I ~ ! I dH> í FINAL D FINAL Directional Survey PB1 MWD D ¡~ . FINAL Directional Survey PB1 MWD Well Cores/Samples Information: Interval Start Stop Received Sent Name DATA SUBMITTAL COMPLIANCE REPORT 11/25/2003 Permit to Drill 2011300 Well Name/No. KUPARUK RIV U TARN 2N-304 Operator CONOCOPHILLIPS ALASKA INC API No. 50-103-20382-00-00 MD 10052 TVD 5875 Completion Date 11/12/2001 Completion Status 1-01L Current Status 1-01L UIC N ADDITIONAL INFORMATION Well Cored? Y [¡j) Chips Received? Y i M ~ Daily History Received? ~ éÝ)N Formation Tops Analysis Received? ~ -'C'- ---- ---- Comments: Compliance Reviewed By: ~ Dale: ~ ID - !J 0 .~ - '~ -;~ --- - -- Re: Jet Pumped \Vells Subject: Re: Jet Pun1ped Wells From: "NSK Problem \Vell SUp\'" <n 1617@Jconocophillips.con1> Date: Sat, 7 Dee 2001 14:07:01 -0900 To: Tom Maunder <tom_n1aunder@'admin.state.ak.us> CC: "n 1617" <n 1617@:!conocophil1ips.com> Tom: I requested a list of surface powered jet pump wells from our PEls. The following should be the current total for the Kuparuk area: West Sak wells: 1C-123 \PTD 2010840) was recently S1 for high watercut 1C-135 \PTD 2012200) is a huff and puff well and was recently put on water injection cycle CPF 2 are as follows: 2L-307 (PTD 1982560) 2 L - 3 13 (PTD 1 98 2 190 ) 2L-315 (PTD 1982180) 2L-321 (PTD 1982620) 2L-325 (PTD 1982090) 2N-303 (PTD 2001690) ,'~ 2N-304 (PTD 2011300) 2N-305 (PTD 2001350) 2N-318 (PTD 2001000) 2N-319 (PTD 1981970) 2N-332 (PTD 2000790) 2N-337 (PTD 1981220) 2N-339 (PTD 1981000) 2P-415 (PTD 2012260) There are no surface powered jet pump wells at CPF3. I hope this answers your question. Let me know if you need more information. Jerry Dethlefs ConocoPhillips Problem Well Supervisor Tom Maunder <te,m maundel"';!'adrnin.state.ctk.us> 12/06/2002 09:00 AM To: NSK Problem Well Supv/PPCO@Phillips cc: Subject: Jet Pumped Wells Pete and or Jerry, I have some emails f h'l' rom aWl e back regarding che wells out there on jet pumps. Would you please provide an updated listing of the wells presently on jet pumps In greater KRU?? Thanks in advance. To (, MEMORANDUM ( State of Ajaska Alaska Oil and Gas Conservation Commission \ TO: Cammy 0 Taylor cD Chairman DATE: June 13, 2002 THRU: Tom Maunder JltG>~ P.I. Supervisor V;j~ -. ~l~d FROM: Chuck Scheve Petroleum Inspector NON- CONFIDENTIAL SUBJECT: Mechanical Integrity Tests BPX S Pad PBU Au rora Packer Depth Pretest Initial 15 Min. 30 Min. Well S-104 Type Inj. S TV.D. 4988 Tubing 2000 2000 2000 2000 Interval I P.T.D. 200-1960 Type test P Test psi 1247 Casing 550 2020 2000 2000 P/F P Notes: Well S-107 Type Inj. S TV.D. 6639 Tubing 1920 1920 1920 1920 Interval I P.T.D. 201-130 Type test P Test psi 1660 Casing 1500 2500 2440 2440 P/F P Notes: Well Type Inj. T.V.D. Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: Well Type Inj. TV.D. Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: Well Type Inj. T.V.D. Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: Type INJ. Fluid Codes F = FRESH WATER INJ. G = GAS INJ. S = SALT WATER INJ. N = NOT INJECTING Type Test M= Annulus Monitoring P= Standard Pressure Test R= Internal Radioactive Tracer Survey A= Temperature Anomaly Survey D= Differential Temperature Test Interval 1= Initial Test 4= Four Year Cycle V= Required by Variance W= Test during Workover 0= Other (describe in notes) Test's Details I traveled to BPXs S Pad and witnessed the initial MIT on wells S-104 and S-l 07. The pretest tubing and casing pressures were observed and found to be stable. The casings were then pressured up and observed for 30 minutes with all 3 wells demonstrating good mechanical integrity. M.LT's performed: ~ Attachments: Number of Failures: Q Total Time during tests: 3 hours cc: M IT report form 5/12/00 L.G. MIT PBU S Pad 6-13-02 CS.xls 6/20/2002 SENT BY: 1-10- 2 ; 9:23AM ; PH I LL I PS AI{ I NC--~ (' :# 11 2 ~ PhonQ:~612 ARCO Alaska, I ne. Fax To: Mr. Steve Davies From: Sharon Allsup-Drètke Fax: 9-907-276-7542 Date: January 10, 2002 Phone: Page.: 1 fte: Perf data for 2N-304 CC~ 0 Urgent 0 For RevitMI 0 Please Com",_nt 0 Please Reply D Please Recycle .Comments: Mr. Davies: Here is the perforation information for 2N-304 as requested. If you have any questions, please feel free to call me at 263-4612. Thanks, Sharon RECE\\JED JÞ~\ .'\ G 2002 . , . «\ft\\ßS\O\\ ka ou &. Gas Cons. GO ~as l\f\choratJe ( j ( PHilliPS Alaska, Inc. A Subsidiary of PHILLIPS PETROLEUM COMPANY Post Office Box 100360 Anchorage, Alaska 99510-0360 C. Mallary Phone (907) 265-6434 Fax: (907) 265-6224 December 19, 2001 Commissioner Cammy Oechsli Taylor State of Alaska Alaska Oil & Gas Conservation Commission 333 West ih Avenue Suite 100 Anchorage, Alaska 99501 Subject: Completion Report for 2N-304 (201-130/301-237) Dear Commissioner: Phillips Alaska, me. submits the attached Completion Report for the drilling operations on the Tarn well 2N-304. If you have any questions regarding this matter, please contact Brian Noel at 265-6979. Sincere, ßktÎßø C. Mallary Drilling Engineering Supervisor P AI Drilling % ¡U.j(á7 CMlskad RECEIVED DEC 2 0 2001 Alaska Oil & Gas Cons. Commission Anchorage OR\G\NAL ( STATE OF ALASKA f ALASKA OIL AND GAS CONSERVATION COMMI~SION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of well Classification of Service Well Oil 0 Gas 0 Suspended 0 Abandoned 0 Service 0 2. Name of Operator 7. Pennit Number Phillips Alaska, Inc. 201-130/301-237 3. Address 8. API Number P. O. Box 100360, Anchorage, AK 99510-0360 50-103-20382-00 / 50-103-20382-70 4. Location of well at surface ,.,- -",,-,.,-_..-_.,..~..,..~ 9. Unit or Lease Name 3' FNL 515' FEL Sec. 3 T9N R7E UM' ::C":,~:'~I:>:)~: ~ (ASP:461078,59120O4) I~~ Kuparuk River Unit At Top ~roducing ,n'terval' , , i. ( :':;\;> '. :/{ ~ '1:1 fÐ 10. Well Number ~ (I I I.- 921' FNL, 359' FEL, Sec. 35, T10N, R7E'iurvt\:Ë~L-¡E::t ¡ (ASP: 466530, 5916339) &Jrf~- . . . 2N-3O4 / 2N-3O4PB 1 At Total Depth t _.~b..--~. i U¡,C ~ 11. Field and Pool 677' FNL, 101' FEL, Sec. 35, T10N, R7E,1UM,..."'m,-~"--"'~(ASP: 466788, 5916581) :--..~.~~: Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. Tarn River Pool RKB 153.9' feet ADL 380053 ALK 4601 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. Or Aband. 15. Water Depth, if offshore 16. No. of Completions July 13, 2001 August 11, 2001 August 15, 2001 N/A feet MSL 1 17. Total Depth (MD + TVD) 18. Plug Back Depth (MD + TVD) 19. Directional Survey 20. Depth where SSSV set 21. Thickness of Pennafrost 10052' MD 1 5875' TVD 9911' MD 1 5760' TVD YES 0 No 0 N/A feet MD 1216' (approx) 22. Type Electric or Other Logs Run GRlRes/Neu Dens 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 16" 62.5# H-40 Surface 152' 24" 193 sx AS 1 7.625" 29.7# L-80 Surface 2930' 9.875" 335 sx AS Lite & 246 sx Class G 5.5" x 15.5# L-80 Surface 9243' 6.75" 92 sx Class G & 320 sx Class G 3.5" 9.3# L-80 9263' 10036' 6.75" included above 2N-304PB1 cement plug dressed off to 2939' 24. Perforations open to Production (MD + TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 3.5" 9266' 9243' (CSR) 9592' - 9602' MD 5507' - 5515' TVD 4 spf 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED kick off plug 3241' to 2830' 100 sx Class G cement retainer set at 8525' 96 sx Class G plug back 9437' to 9565' 48 sx Class G plug back squeeze 10255' - 9605' 157 sx Class G see attachment for frac data 27. PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) December 5, 2001 Flowing Date of Test Hours Tested Production for OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO 12/17/2001 6 hours Test Period> 459 710 10 100 1972 Flow Tubing Casing Pressure Calculated OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY - API (corr) press. 259 psi 1428 psi 24-Hour Rate> 1577 3110 39 not available 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and pressence of oil, gas or water. Submit core chips. RECEIVED N/A DEC 2 0 2001 . Alaska Oil & Gas Cons. Commissiõn Anchorage Form 10-407 Rev. 7-1-80 CONTINUED ON REVERSE SIDE Submit in duplicate 0 RIG I N A LR B 0 M 5 B Fl (lJAN I I 2002 29. GEOLOGIC MARKER! 30. FORMATION TESTS NAME MEAS.DEPTH TRUE VERT. DEPTH Include interval tested, pressure data, all fluids recovered and gravity. GOR, and time of each phase. T3.1 T-3 T-2 9433' 9468' 9605' 5385' 5411' 5517' Annulus left open - freeze protected with diesel. 31. LIST OF ATTACHMENTS Summary of Daily Operations, Directional Survey 32. I h~reby 7at the f:llomng is lru ¡:~:;t of my kn~edg. Signed ~ ~ ~ Tma Drilling Engin~~ring SuDaIV;>o, C. Mallary c;?' Questions? Brian Noel 265-6979 Date /;z/tì 4 Prepared by Sharon Allsup-Drake INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1: Classification of Service wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, Other-explain. RECEIVED Item 28: If no cores taken, indicate "none". DEC 2 0 2001 Form 10-407 OR I GI NAL Alaska Oil & Gas Cons. Commission Anchorage ..... ..... -"" (PHILLIPS) ID ~ (' ( Page 1 of 10 PHilliPS ALASKA INC. Operations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 2N-304 2N-304 ROT - DRILLING Nabors Nabors 16E 7/13/2001 7/14/2001 7/15/2001 7/16/2001 Date Sub From - To Hours Code Code Phase 03:00 - 12:00 12:00 - 15:00 15:00 - 18:00 18:00 - 20:30 20:30 - 21 :00 21 :00 - 21 :30 21 :30 - 22:00 22:00 - 23:30 23:30 - 00:00 00:00 - 06:00 06:00 - 07:00 07:00 - 10:00 10:00 - 10:30 10:30 - 00:00 00:00 - 10:00 10:00 - 12:00 12:00 - 12:30 12:30 - 13:00 13:00 - 17:30 17:30 - 19:00 19:00 - 20:00 20:00 - 22:00 22:00 - 00:00 00:00 - 00:30 00:30 - 04:00 04:00 - 06:00 06:00 - 06:30 06:30 - 10:30 10:30 -13:30 13:30 - 14:00 14:00 - 15:00 15:00 - 17:00 9.00 MOVE RURD MOBMIR 3.00 WELCTL NUND PROD 3.00 DRILL 2.50 DRILL RIRD PROD PULD PROD 0.50 WELCTL SFTY PROD 0.50 DRILL SFTY PROD 0.50 DRILL 1.50 DRILL 0.50 DRILL 6.00 DRILL 1.00 DRILL 3.00 DRILL 0.50 DRILL 13.50 DRILL 10.00 DRILL 2.00 DRILL 0.50 DRILL 0.50 DRILL 4.50 DRILL 1.50 DRILL 1.00 DRILL 2.00 DRILL 2.00 DRILL 0.50 DRILL 3.50 DRILL CIRC PROD DRLG PROD SURV PROD DRLG SURFAC TRIP SURFAC PULD SURFAC TRIP SURFAC DRLG SURFAC DRL.G SURFAC CIRC SURFAC WIPR SURFAC CIRC SURFAC WIPR SURFAC PULD SURFAC PULD SURFAC WIPR SURFAC CIRC SURFAC OBSV SURFAC TRIP SURFAC 2.00 CASE RURD 0.50 CASE SFTY 4.00 CASE RUNC 3.00 CEMEN" CIRC 0.50 CEMEN" PULD 1.00 CEMENì CIRC 2.00 CEMENì PUMP SURFAC SURFAC SURFAC SURFAC SURFAC SURFAC SURFAC Spud Date: 7/14/2001 End: 8/15/2001 Group: Start: 7/13/2001 Rig Release: 8/15/2001 Rig Number: 16E Description of Operations Move in and rig up Nabors 16E, had to wait on truck to move Ball mill until 0730 hrs., before rig could be moved. Move rig from 2N-302 to 2N-304 well, level rig. Accept rig at 1200 hrs. 07/13/2001 N/U diverter Ready rig for spud, build berm around cellar and inclose, take on spud mud, change shaker screens, Set Sperry Sun equipment in pipe shed. Had accident, Ball Mill operator pinched little finger on left had in chain hoist trolly, breaking bone in finger. He was checked out by medical in Kuparuk and sent to town for further attention. P/U BHA, strap and caliper, set motor for 1 112 degrees, tag fill at 91' KB Have accum. drill and diverter drill. Hold pre-spud meeting in Rose room on the rig, with crews and service company personal. Fill hole and circ., check for leaks on rig equipment. Drill to bottom of conductor, F/91' to 155' Spud new formation at 2230 hrs. 07/13/01 Drill F/155' to 230' Circ. and survey with Sperry Sun Gyro 1.3 degrees, w/185 asimuth Drill from 230' to 595', 1 hr. slide time, 1.75 hr Rot. time, 2.25 gyro time POOH to P/U MWD Change out BHA, P/U Sperry Sun MWD TIH, no problems Drill from 595' to 1950' MD, 1843' TVD Slide time = 5.5 hrs., Rot. time = 4 hrs. Seen gas from hydrates from 1267' to 1447' Drill from 1950' to 2945' MD, 2310' TVD Slide 3.75 hrs. Rotate 4.25 hrs. Pump sweep, circ. and condo hole, flow check, pump dry job. POOH 3 stds., hole swabbing, RIH to bottom Circ. bottoms up, check for gas, everything ok. POOH 5 stds, 2500', hole started swabbing, pump out of hole to 2300', POOH to 1650', pump out of hole to surface. UD MWD and associated BHA P/U Hole opener and associated BHA TIH to bottom, seen no tight hole to bottom. Pump sweep, circ. and condo hole, circ. out a large amount of cuttings, plugged flow line at one time. Circ., check for flow, pump dry job. POOH to run casing, hole was in good shape, no drag. UD Hole opener and stabilizer. Rig up to run 7 5/8" casing Pre-job safety meeting RIH with 67 jts. 7 5/8" 29.7# L-80 BTC-MOD casing, set at 2930' Circ. and cond mud prior to cementing UD fillup tool, P/U cementing head Circ. and condo for cement Pump 10 bbls. fresh water, tested lines to 3500 psi., pumped 40 bbls. Printed: 9/24/2001 3:24:20 PM ~ ~ ~ ~~PHILLIPS ) Ira ~ Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date 7/16/2001 7/17/2001 7/18/2001 7/19/2001 7/20/2001 ( { PHilliPS ALASKA INC. Operations Summary Report 2N-304 2N-304 ROT - DRILLING Nabors Nabors 16E Page 2 of 10 Spud Date: 7/14/2001 End: 8/15/2001 Group: Start: 7/13/2001 Rig Release: 8/15/2001 Rig Number: 16E Description of Operations Sub From - To Hours Code Code Phase 15:00 - 17:00 17:00 - 18:00 18:00 - 21:30 21 :30 - 22:30 22:30 - 00:00 00:00 - 03:30 03:30 - 04:30 04:30 - 07:00 07:00 - 11 :30 11 :30 - 16:00 16:00 - 17:30 17:30 - 19:30 19:30 - 20:00 20:00 - 21 :30 21 :30 - 22:00 22:00 - 23:00 23:00 - 00:00 00:00 - 00:30 00:30 - 01 :30 01 :30 - 02:00 02:00 - 03:00 03:00 - 23:00 23:00 - 00:00 - 01 :30 01 :30 - 03:45 03:45 - 04:00 04:00 - 06:00 06:00 - 07:45 07:45 - 08:30 08:30 - 00:00 00:00 - 14:00 2.00 CEMEN" PUMP SURFAC CW100 ( 7.5 bpm @ 825 psi), drop bottom plug, pump 50 bbls. 10.2 ppg. MudPush (7.5 bpm @ 810 psi) wIred dye, pump 335 sx.lead (265 bbls.) @ 10.7 ppg. (7.5 bpm @ 950 psi.), 246 sx. tail cmt. (51.4 bbls.) @ 15.8 ppg. (6.1 bpm @ 1575 psi.), drop top plug, displace cmt. w/10 bbls. wash water followed with 120.1 bbls. 10 ppg. mud @ 8 bpm @ 850 psi., slow rate to 3 bpm @ 600 psi, bumped plug w/1100 psi, floats held ok. Had 133 bbls good cement to surface and good returns through out job. UD cement head and landing joint. clear rig floor. NID diverter, UD casing running equip., rig down cementing hose from top drive, reistall kelly hose N/U FMC GEN. V Well head, test to 1000 psi N/U BOP's Nipple up BOP, Change top drive fl 5" to 4" Lay down jars & accel. from derrick Rig to test BOP, Set test plug, Fill stack, Repair riser flange leak Test BOP equip. to 250 PSI low & 5000 PSI high, Annular to 250 PSI low & 3500 PSI high - Test waived by AOGCC Pick up BHA, Program tools, Load sources RIH tag cmt. @ 2690' Drill hard cement fl 2690' to 2842' (float collar) Circ. btm's up Test 7-5/8" casing 2500 PSI -30 min. Drill out float collar While drilling out float collar rubber plug and bit hydralic up hole and bent 3 jts. drill pipe, Lay down same Drill out remainder of float equip. and cement Drld float cllr + cmenbt + float shoe & new formation to 2965'. Dipslaced dirty mud with new mud prior to F.I.T. Peformed F.I.T. to 16.0 ppg EMW (810 psi wI 9.3 ppg mud & 2317' TVD). Circulated and established PWD baseline for clean hole. Drld 6-3/4" hole fl 2965 - 5590'. Swept hole as necessary. Drlg with no downhole losses and drilling with maximum ROP that still keeps us under the PWD hardline of 1.5 ppg over clean hole ECD. Circulated hole and plans are for two sweeps and a minimum of 4 bottoms up prior to flow checking and making wiper trip to the 7-5/8" shoe. Finished circ'g hole clean and conditioning mud for wiper trip. Circ'd until PWD ECD showed hole had cleaned up. POOH to 7-5/8" shoe. Hole in excellent condition, did not have to work any spots. POOH at good rate until several hundred feet below Camp sands, slowed trip speed to avoid any potential for swabbing in that area. Observed well for flow, no flow. PJSM. Slipped & Cut 62' of drlg line. Serviced TDS and drawworks. TIH. Washed last stand to bottom, no fill. Minor gas on bottoms up. Caught mud sample from mud that had been across Camp Sd interval and no indications of CO2 contamination to mud. Drld 6-3/4" hole from 5590 - 7351' MD I (4181' TVD). AST= 1.25 hrs & ART = 8.25 hrs. Drld 6-3/4" hole f/7351' - 8550'. During this time, we spent over 2 hrs 1.00 CEMENl RURD SURFAC 3.50 WELCTL NUND SURFAC 1.00 WELCTL NUND 1.50 WELCTL NUND 3.50 CASE NUND 1.00 DRILL PULD 2.50 WELCTL BOPE 4.50 WELCTL BOPE 4.50 DRILL 1.50 DRILL 2.00 DRILL 0.50 DRILL 1.50 CASE 0.50 DRILL 1.00 DRILL SURFAC SURFAC PROD PROD PROD PROD PULD PROD TRIP PROD DRLG PROD CIRC PROD DEaT PROD DRLG PROD OTHR PROD 1.00 DRILL DRLG PROD 0.50 CEMEN" DSHO PROD 1.00 CEMEN"' CIRC PROD 0.50 CEMEN"' FIT PROD 1.00 DRILL 20.00 DRILL DRILL 1.50 DRILL 2.25 DRILL CIRC PROD DRLG PROD CI RC PROD CIRC PROD WI PR PROD 0.25 DRILL OBSV PROD 2.00 RIGMNT RURD PROD 1.75 DRILL WIPR PROD 0.75 DRILL WIPR PROD 15.50 DRILL 14.00 DRILL DRLG PROD DRLG PROD I Printed: 9/24/2001 3:24:20 PM ....... ..... ...... ~'PHILLIPS ~ 1m ~ Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date 7/20/2001 7/21/2001 7/22/2001 7/23/2001 ( ( Page 3 of 10 PHilliPS ALASKA INC. Operations Summary Report 2N-304 2N-304 ROT - DRILLING Nabors Nabors 16E Sub From -To Hours Code Code Phase 00:00 - 14:00 14:00 - 16:15 16: 15 - 16:30 16:30 - 16:45 16:45 - 22:00 22:00 - 22:15 22:15 - 22:45 22:45 - 00:00 00:00 - 01 :00 01 :00 - 08:00 08:00 -11:00 11 :00 - 12:00 12:00 - 14:30 14:30 - 00:00 00:00 - 16:30 16:30 - 20:00 20:00 - 23:30 23:30 - 00:00 00:00 - 00:30 00:30 - 10:30 10:30 - 12:30 14.00 DRILL 2.25 DRILL 0.25 DRILL 0.25 DRILL 5.25 DRILL 0.25 DRILL 0.50 DRILL 1.25 DRILL 1.00 DRILL 7.00 DRILL 3.00 DRILL 1.00 DRILL 2.50 DRILL 9.50 DRILL 16.50 DRILL 3.50 DRILL 3.50 DRILL 0.50 DRILL 0.50 DRILL 10.00 DRILL 2.00 DRILL DRLG PROD CIRC PROD OBSV PROD CIRC PROD TRIP PROD OBSV PROD CI RC PROD DRLG PROD TRI P PROD PULD PROD TRIP TRIP PROD PROD TRIP PROD DRLG PROD DRLG PROD CIRC PROD WIPR PROD CIRC PROD CIRC PROD TRIP PROD PULD PROD Spud Date: 7/14/2001 End: 8/15/2001 Group: Start: 7/13/2001 Rig Release: 8/15/2001 Rig Number: 16E Description of Operations . messing with trying to keep good MWD logging signals + PWD + directional data. Troubles started around 05:00 hrs. AST = 2 hrs + ART = 5.25 hrs. Unable to keep real time logging signal or get directional data or PWD data. Circulated annulus clean with 2 sweeps & 4 bottoms up. Conditioned the mud to 10.9 pH. Flow checked well, no flow. Slugged pipe. POOH to 7-5/8" shoe. Had to stop and defoam the trip tank a couple of times & mess with a slug that failed about 8 stands before the shoe. POOH slow across Camp Sds. Hole looks beautiful, no more than 5-10,000 Ibs excess drag at occassional spots. Had to trip slower overall to avoid swabbing. Flow checked well, no flow. (This is to check Camp Sands). Circulated out remains of first slug. Pumped another slug (dry job). Continued POOH. Finished POOH to BHA. Finished POOH to BHA. PJSM. Handled BHA, downloaded MWD e-Iog data. UD 10' pony MDC that was between top stab and motor. (With it in the string, the BHA has a building tendency, too long of a belly). Checked bit, OK. Checked float, OK. The tool failure cause was a cracked and broken poppit that goes on top of the pulsar. This poppet is what creates the mud pulse as it enters the orifice. Tested new tools at surface. TIH to 7-5/8" shoe @ 2930'. Serviced TDS & Circ'd bottoms up. TIH to 4030' ( 530' below top Camp Sd interval) & circ'd bottoms up. Mud had been affected (please note DIMS mud check for 3600'). It appears to be more from mud dehydration than CO2. The mud weight was up to 10.1 I FV up from 44 to 72. The pf/mf spread did not change enough to suggest main cause to be CO2. The dehydration theory is additionally supported to hole fill during tripping. From 4400-3500' (+/-), the hole fill ranged from 0.6 - 1.2 bbls/std (theoretical is 0.5). Acted like wall cake wiped off of sd intervals and thus taking some fluid to build a new cake. Finished TIH. Washed last std down. Hole looks good, no problems on TIH. No measurable gas on bottoms up. (Note: Went back to PLANNED time here as I had planned on a wiper trip). Drld 6-3/4" hole f/ 8550 - 9324' md / 5150' tvd. ART= 6.5 hrs & AST= 1 hr. Flow chck'd first two connections after drilling into Iceberg form, no flow. Drld 63/4" hole f/ 9324' - 10415'md/5932'tvd. From 9700 - 10225' control drld under 100 ftlhr, as per geological guidance. Control drld that same interval with as close to constant parameters as possible. ART = 10.75 hrs & AST = 1.25 hrs. Circu & Condition - Pump 2 Wt HiNis Sweeps - Circu total 4 BU I total 13,450 stks. Wiper trip to 8515' (Last trip point 8550') - No swab I No Tight hole ecountered Circu & Condition - Pump Wt HiNis Sweep Finished circ'g and conditioning mud. Pumped 2 bottoms up this time. PWD ECD cleaned up to "theoretical clean hole". POOH, laying down the accelerator and top jar. Finish POOH to BHA. PJSM about nuclear sources. Removed soureces and guts to MWD's Printed: 9/24/2001 3:24:20 PM ........... ... ~~PHlLùPS~. IUj ~ Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 7/23/2001 7/24/2001 7/25/2001 Date ( ( Page 4 of 10 PHilliPS ALASKA INC. Operations Summary Report 2N-304 2N-304 ROT - DRILLING Nabors Nabors 16E Spud Date: 7/14/2001 End: 8/15/2001 Group: Start: 7/13/2001 Rig Release: 8/15/2001 Rig Number: 16E Description of Operations Sub From - To Hours Code Code Phase 10:30 - 12:30 12:30 - 13:30 13:30 - 15:00 15:00 - 15:45 15:45 - 16:00 16:00 - 22:00 22:00 - 22:30 22:30 - 00:00 00:00 - 12:00 12:00 - 13:00 13:00 - 17:30 17:30 - 19:30 19:30 - 21 :00 21:00 - 21:30 21 :30 - 23:00 23:00 - 00:00 00:00 - 01 :30 01 :30 - 10:30 10:30 - 12:00 12:00 - 13:30 13:30 - 14:30 2.00 DRILL PULD PROD 1.00 DRILL PULD PROD 1.50 CASE RURD PROD 0.75 WAlTON ORDR PROD 0.25 CASE 6.00 CASE SFTY PROD RUNC PROD 0.50 CASE CIRC PROD 1.50 CASE RUNC PROD 12.00 CMPL TN RUNT PROD 1.00 CMPL TN RUNT PROD 4.50 CEMENl CIRC PROD 2.00 CEMENl PUMP PROD 1.50 CEMEN' OTHR PROD 0.50 CEMEN" RURD PROD 1.50 WELLSR DEaT PROD 1.00 DRILL PULD PROD 1.50 WELLSR NUND PROD 9.00 WELLSR PULD PROD 1.50 WELLSR PULD PROD 1.50 WELLSR PULD PROD 1.00 WELLSR SEep PROD '. and downloaded e-Iog data. Finished laying down mud motor + PDC bit, etc. Pulled wear bushing. RlU casing running eqpt. Waited on in town analysis of downloaded e-Iog data to determine if casing is to be run or a sideetrack. PJSM with respect to running casing. P/U shoe track and thread locked 1st four connections. F.Shoe + 3 its + F.Cllar + 1 jt + baffle. Continue running casing as per program. Circu BU @ 2892' (Jt #73) Con't Run 51/2" Csg Ran 5.5" Csg - Circu BU @ 4000' & then 6631'. Able to circulate 2.5 bpm without losses @ 6631'. RIH and had to start pushing the casing with topdrive wt f/7400' - 7606'. Circ'd wI 20% returns. Slowed pumps to 10 spm and eventually up to 20 spm @ 90% returns. RIH to 7855' & unable to push thru. Unable to pump thru initially. After 30 min of working pipe, went thru the spot. RIH to 9010' without having to push anymore & circ'd b/u. Had to start at 10 spm wI 10-20% returns. Slowly got up to 25 spm & 90% returns. M/U Hanger - LID fillup tool. P/U Lnd Jt & CMT Head. Landed hanger without pumps, no fill. **Note** Total Ran 23 jts- 3.5" 9.3# L-80 BTC-M and 227 Jts 5.5" 15.5# L-80 EUE 8rd Mod. Centrilized per well program. Circu & Condition- Total circ'd 8085 stks or 4 b/u. (PJSM & Batch Up). Had to start pumping at low spm with heavy losses. Added barafibre during the last circulation point. After barafibre made it around... slowly worked our spm up to 46 spm with +1- 90+ returns. Worked pipe up and down thru out. P/U= 190-200k and S/O= 112-110k. Pumped 10 bfw & tested cmt lines to 3500 psi. Batch mixed tail slurry. Pumped 40 bbls chemical wash, dropped bottom plug, pumped 50 bbls of mudpush + 33 bbls of lead cmt @ 13 ppg + 68 bbls of tail cmt @ 15.8-16.0 ppg. Opened cmt head & dropped top plug. Pumped 8 bbls of perf pill + 86 bfw using the rig pumps...... casing pressured up to 2000 psi. (Total displaced 94 bbls of 235 bbls to landing baffle). By calculation.... 10.4 bbls of Mudpush went thru the bottom plug before it plugged off. Bled 2000 psi off ( to try & back surge whatever plugged the bottom plug). Re-pressured up to 2000 psi & bled off. Pressured up to 3500 psi & bled off. Broke cmtg line at cmt head and pumped to confirm no lines blocked, OK. Checked all valves. RID landing joint. RID casing eqpt. Observed well, still slowly giving some mud back... of the mud that had been lost during circulation. Drained stack & installed 5-1/2" packoff. Tested packoff to 5000 psi - 10 minutes, OK. Ran and set wear bushing. CIO bails - RID Csg fill line - RlU to LID 4" DP from derrick LID Flex DCs ,Jars - LID 315 its 4" DP from derrick CIO Elevators - Clean all 5.5" Csg equip from rig floor - Move 16 stds of 5" DP from left side of derrick to the right side of derrick to make" L" shaped "Cradle" to rack 2 7/8" DP in derrick. P/U 27/8" Handling Tools cIa Bttm pipe Rams to 2 7/8" Printed: 9/24/2001 3:24:20 PM ( ( PageS of 1 0 PHilliPS ALASKA INC. Operations Summary Report Legal Well Name: 2N-304 Common Well Name: 2N-304 Event Name: ROT - DRILLING Contractor Name: Nabors Rig Name: Nabors 16E Date From- To Hours Code Sub Phase Code 7/25/2001 14:30 - 20:30 6.00 WELCTL BOPE PROD 20:30 - 23:00 2.50 WELLS PULD PROD 23:00 - 00:00 1.00 WELLS PULD PROD 7/26/2001 00:00 - 00:30 0.50 WELLS CIRC PROD 00:30 - 02:00 1.50 WELLS PULD PROD 02:00 - 03:00 1.00 WELLS PULD PROD 03:00 - 09:00 6.00 WELLS PULD PROD 09:00 - 20:00 11.00 WELLS MILL PROD 20:00 - 21 :30 1.50 WELLS CIRC PROD 21 :30 - 00:00 2.50 WELLS MILL PROD 7/27/2001 00:00 - 05:30 5.50 WELLS MILL PROD 05:30 - 06:00 0.50 WELLS CIRC PROD 06:00 - 07:00 1.00 WELLS CIRC PROD 07:00 - 19:00 12.00 WELLS MILL PROD 19:00 - 19:30 0.50 WELLS CIRC PROD 19:30 - 00:00 4.50 WELLS MILL PROD 7/28/2001 00:00 - 08:30 PROD 08:30 - 09:00 0.50 WELLS CIRC PROD 09:00 - 17:00 8.00 WELLS MILL PROD 17:00 - 20:00 3.00 WELLS CIRC PROD 20:00 - 21 :30 1.50 WELLS CIRC PROD 21 :30 - 22:30 1.00 WELLS CIRC PROD 22:30 - 23:00 0.50 WELLS CIRC PROD 23:00 - 00:00 1.00 WELLS MILL PROD 7/29/2001 2.00 WELLS MILL 1.00 WELLS CIRC 1.50 WELLS TRIP 1.00 WELLS CIRC 3.00 WELLS TRIP PROD PROD PROD PROD PROD 00:00 - 02:00 02:00 - 03:00 03:00 - 04:30 04:30 - 05:30 05:30 - 08:30 08:30 - 09:30 1.00 WELLS CIRC PROD Spud Date: 7/14/2001 End: 8/15/2001 Group: Start: 7/13/2001 Rig Release: 8/15/2001 Rig Number: 16E Description of Operations Test BOPs & Choke Manif - Test all 250/5000 psi Annular test 250/3500 psi -No failures- AOGCC waived witness test. CIO Top Drive Saver Sub to 2 7/8" AOH R/U to P/U 43/4" CO BHA Blow dn circulating lines. P/U BHA# 10 (CMT clean out assy) M/U Kelly hose to topdrive - Shallow test Mud Motor. TIH P/U 2 7/8" DP 10.40# S135 w/AOH connections out of pipe shed- Started washing down fl +1- 3800'. Tagged cement sheath @ 3871'. Drlg cmt sheath 3871' to 3910'. Cautiously drld fl 3800 - 3950'. This was to avoid risks of hanging up with rubber going around BHA. Should have been @ 3950' (this is 1 bbl difference in displacement). Started drlg in stands and raised Rap limit to 150 ftIhr from 3950 - 4519' .. Not taking any wt to drill. Getting soft-firm cmt at shakers. Did not get much rubber back, so we will be carefull POOH when we do. Drain Pit #6 - Evaluate for CMT & solids buildup - No CMT or solids - Refill pits wI FW Drlg CMT 4519' to 4790' Drld cement f/4790' - 5270' - Pump 10 bbl Mud sweeps as needed to clean hole, essentially every stand. CBU Drain & Clean Pit #6 - Clean flow line & Possum bellies on shakers Drld cement f/5270' - 6314' - Pump 10 bbl Mud sweeps as needed to clean hole, every stand. At the 6000' range (+1-), we started getting stringers of harder cement. Prior to this, not requiring any WOB. Drain Pit #6 and evaluate for green cmt Drlg cement f/6314' to 6690' - Pump 10 bbl Mud sweeps as needed to clean hole Drld cement fl 6690' - 7349' - Pump sweeps as needed to clean hole. First hard streak of cement f/7305 - 7483'. Rap dropped from 140 ftIhr to 20 - 30 - 50 ftlhr. ROP increased after this point. Drained & cleaned pit #6 - Check for Solids & cement - Refill wI FW Drld cement fl 7349' - 8000' - Pumped sweeps as needed to clean hole Pump 2 I 30 bbl sweeps, back to back to insure clean hole Clean Pit #6 & Possum bellies on all shakers - Take on 290 bbls 11.2ppg mud. Will del ute to 9.6ppg & displace well over to mud. Displaced well over to 9.7 ppg mud. Cleaned pits to receive new mud. Drld cement fl 8000' - 8017'. Hard cement stinger. NOTE: 7-5/8" X 5-1/2" ANNULUS = 0 PSI Cleaned out cement f/8017 - 8200' (+/-) and washed to 8300'. Circ'd bottoms up, as this should be below the last of the cement. TIH to 8580'. Circ'd bottoms up, no cement. (Precautionary) TIH & hit bridge @ 9099'. Washed thru bridge 9099-9119' (20'). TIH & hit bridge @ 9355'. Washed thru bridge @ 9355-9370' (15' total & hard at first). TIH & hit bridge @ 9509'. Washed 9509 - 9524' (15') and TIH to 9550'. (( These bridges appear to be barite... the sample looked like reversed wetting of barite, oatmeal looking)). Circ'd bottoms up to get heavy 11 + ppg Mud Push out of hole - had 400 psi additional pressure. Printed: 9/24/2001 3:24:20 PM (' ( PHILLIPS ALASKA INC. Operations Summary Report Legal Well Name: 2N-304 Common Well Name: 2N-304 Event Name: ROT - DRILLING Contractor Name: Nabors Rig Name: Nabors 16E Date From - To Hours Code Sub Phase Code 7/29/2001 09:30 - 11 :30 2.00 WELLS TRIP PROD 11 :30 - 13:00 1.50 WELLS CIRC PROD 13:00 - 17:00 4.00 WELLS CIRC PROD 17:00 - 18:00 1.00 WELLS TRIP PROD 18:00 - 00:00 6.00 WELLS TRIP PROD 7/30/2001 00:00 - 00:30 0.50 WELLS TRIP PROD 00:30 - 02:00 1.50 WELLS TRIP PROD 02:00 - 04:30 2.50 WELLS TRIP PROD 04:30 - 05:30 1.00 WELLS OTHR PROD 05:30 - 06:30 1.00 WELLS OTHR PROD 06:30 - 11 :00 4.50 WELLS TRIP PROD 11 :00 - 12:00 1.00 WELLS WASH PROD 12:00 - 18:00 6.00 WELLS WASH PROD 18:00 - 21 :30 3.50 WELLS CIRC PROD 21 :30 - 00:00 2.50 WELLS TRIP PROD 7/31/2001 00:00 - 05:00 5.00 WELLS TRIP PROD 05:00 - 08:00 3.00 WELLS OTHR PROD 08:00 - 14:00 6.00 WELLS NUND PROD 14:00 - 16:30 2.50 WELLS OTHR PROD 16:30 - 21 :30 5.00 WELLS PERF PROD Page 6 of 10 Spud Date: 7/14/2001 End: 8/15/2001 Group: Start: 7/13/2001 Rig Release: 8/15/2001 Rig Number: 16E Description of Operations Finished washing down from 9550' with spotty bridges down to 9634'. We could not run without pumps to this point, had to pump. Slid down & tagged 5-1/2" x 3-1/2" crossover @ 9640', repeated this to confirm... Pump 10 bbl sweep above XO @ 9640' Circu & Condition Mud per Bariod Rep. Had to bring the pH, the yield point & the fluid loss into line for the upcoming cement job. This is the last opportunity to get it ready. PJSM - R/U to TOH w/2 7/8" DP TOH - SIB 2 7/8" DP in derrick. Note: 7-5/8" x 5-1/2" annulus = 0 psi Con't TOH - SLM ( 7.81' shorter than DP tally - this is understandable as 2-7/8" dp bows in the derrick). UD BHA ,Mud Motor,bit sub & 4-3/4" mill. Virtually no wear on the mill. P/U 2.75" Mill Assy & 21 jts 2.0625" CS Hydrill pipe Slip & Cut Drill Line Service Rig & TD Con't TIH Tag XO @ 9640' Circu @ 40 SPM , 1800 psi - Attempt to work 2.75" Mill down 3-1/2" tubing...no luck. Picked up and established torque values. Parameters of 50 rpm @ 2500 ft-Ibs & 30 spm (551ft/min annular velocity). Wash & Ream 9630' to 10273' (Top of Landing Baffle). It was a mix of washing and drilling, as we had bridges thru most of it. Washed down the last 30' to the landing collar. We added 2 drums of mud lubricant and back ground torque dropped from 2500 to 2000 ft-Ibs. Circ'd for 15 minutes. Pulled back to 9650' , Circu Hi Vis Sweep #1 (15 bbls) and @ 40 bbls in to sweep pulled back to 9630'. Started Hi Vis Sweep #2 (30 bbls) at this time and pumped clear to surface. On last circulation spotted EP mud lube thru complete circu system. Should help WLL. Monitor Well 1 0 min (Static) - TOH SPECIAL NOTE: The 7-5/8" x 5-1/2" annulus had 175 psi on it at 14:30 hrs. Bled to zero in 5 minutes thru 1/2" needle valve, LEL= 500+. In 2 hrs, pressure back to 45 psi. At midnight, pressure= 105 psi. Lubricated it 4 times, giving 20minutes for mud to pirculate down. Each time we pressured 100 psi over gauge pressure and then bled this down + the hydrostatic volume we added. First two bleed offs was airy gas. 3rd time mostly mud. 4th time mud. At 03:30 the annulus= 32 psi. POOH, Lay down 2-1/16" DP & 2.75" mill Assembly Clear floor, PJSM, Remove Stripe-O-Matic, Nipple down Riser and set back on floor Nipple up Shooting flange to Hydril, PJSM, Rig up Schlumberger, Test lubricator to 1000 PSI RIH wI Gauge & junk basket wI GRICCL, Stopped @ 9630' (5-1/2" x 3-112" XO) Change out lubricators & test same to 1000 PSI, RIH w/2", 6spf, 60 deg. phase guns & shot @ 10255' to 10257', POOH & close Blind rams. Printed: 9/24/2001 3:24:20 PM legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date 7/31/2001 8/1/2001 ,( ~ I. (" Page 7 of 10 PHilliPS ALASKA INC. Operations Summary Report 2N-304 2N-304 ROT - DRilLING Nabors Nabors 16E 16:30 - 21:30 From - To Hours Code 21 :30 - 00:00 00:00 - 05:00 Phase 2.50 WELLS CIRC 5.00 WELLS PERF PROD PROD 5.00 WELLS CIRC PROD 05:00 - 07:00 2.00 WELLS 07:00 - 09:30 2.50 WELLS 09:30 - 18:30 9.00 WELLS SEaT PROD 18:30 - 22:30 4.00 WELLS SEaT PROD 22:30 - 00:00 1.50 WELLS SEOP PROD 8/2/2001 00:00 - 01 :30 1.50 WELLS CIRC PROD 01 :30 - 03:00 1.50 WELLS CIRC PROD 8/3/2001 03:00 - 05:00 05:00 - 08:30 08:30 -11:30 11:30 -13:00 13:00 - 15:30 15:30 - 16:00 16:00 - 19:00 19:00 - 00:00 00:00 - 03:00 03:00 - 04:00 04:00 - 07:00 07:00 - 08:30 08:30 - 10:00 10:00 - 12:00 12:00 - 12:30 12:30 - 15:30 Spud Date: 7/14/2001 End: 8/15/2001 Group: Start: 7/13/2001 Rig Release: 8/15/2001 Rig Number: 16E Description of Operations Note: Lubricate & Displace 12% LEL gas f/7-5/8"x 5-112- annulus w/1.77 bbls 9.7 ppg mud Rig & Attempt to circ. 5-1/2" csg.- working press. f/750 PSI to 500 PSI in attempt to circ well with very little returns. Establish partical returns thru holes @ 10255'-10257' up 5-1/2" x 7-5/8" annulus at rate of 1/2 bpm @ 800 PSI, Lost total returns after pumping total of 135 bbls 9.7 ppg mud and had total of 28.7 bbls return. Rig down Schlumberger wire line, lubricator & shooting flange Nipple up Riser & Strip-O-Matic Note; Pressure build up 500 psi on 5-1/2" csg. due to breathing, Bleed off pressure and slowly flow back 10 bbls mud Rig & test BOPE to 250 & 5000 psi, hydrill to 250- 3500 psi, IBOP failed, Test waived by AOGCC Chuck Sheave Change out IBOP & retest to 250-5000 psi- ok Observe well - Static, Pull 5-1/2" x 7-5/8" pack-off, Make up & install 5-1/2" full open safety valve & landing jt. Rig to circ. 5-1/2" csg. Work pressure from 0 psi to 2500 psi to unplug holes @ 10255'- 10257', Established injection rate of 1/2 bpm @ 1150 psi, Pumped total of 30 bbls with no returns up 5-1/2"x 7-5/8" annulus. Rig down circ. head & landing jt., Reset pack-off in well head & test to 5000 psi Set wear bushing, Nipple down Strip-O-Matic & Riser, Nipple up Shooting flange Rig Schlumberger & Test lubricator to 1050 psi RIH, Correlate & shoot 6 spf 60 degree phase F/9565' - 9567' POOH & lay down gun- all shots fired Attempt to eirc. 5-1/2"x 7-5/8" ann. - no good, Injection rate 1/2 bpm @ 900 psi Rig down Schlumberger, Nipple down shooting flange, Nipple up Riser & strip-o-matic Make up & RIH w/ Baker K-1 cmt retainer RIH w/ Baker K-1 cmt retainer & tag TOL, Pull up & set ret. @ 9605', Test DP to 3500 psi Circ. & condo mud f/ squeeze job Rig to squeeze holes @ 10255'-10257', Stab into ret., Est. injection rate of .5 bpm @ 1300 psi wI very little (2 bbls) returns up 5-1/2"x 7-5/8" annulus, Pull out of ret., Circ. btm's up (Gas 100 units) Stab into ret., Pump 2 bbls fresh water ahead, Test lines to 3500 psi, Batch mix & pump 32.5 bbls (157 sxs) Class G cmt. @ 15.8 ppg wI 0.4%D167, 0.3%D65, 0.2%D46, 0.1%XE920, at rate of 2 bpm @ 1550 psi, Disp. cmt. w/3 bbls fresh water behind followed by 40 bbls 9.7 ppg mud @ final rate of 2 bpm @ 2500 psi, 5-1/2"x 7-5/8" ann. returns increased after cmt. arrived at holes @ 10255'- 10257', Calc. 6.5 bbls cmt. traveled up ann. to a TOC of 10054' in annulus, CIP @ 0745 hrs 8/3/01, Pull out of ret. & reverse circ. trace of cmt. Circ. & cond mud f/ P & A plug #2 Pipe @ 9600', Pump 5 bbls fresh water, Batch mix 10 bbls (48 sxs) 15.8 ppg Class G cmt. w/0.35%D167, 0.3%D65, 0.2%D46, 0.09%XE920, Disp. w/ 1.5 bbls water followed by 37.4 bbls 9.7 ppg mud, Calc TOC 9185', POOH to 8930' Circ. DP & hole clean Close rams & squeeze 6 bbls cmt. thru holes @ 9565' - 9567', Initial NUND ABANDN PERF ABANDN 1.00 ABAND CIRC ABANDN 3.00 ABAND DPST ABANDN 3.00 WELLS 1.50 WELLS 2.50 WELLS 0.50 WELLS 5.00 WELLS TRIP 3.00 ABAND TRIP ABANDN ABANDN ABANDN ABANDN ABANDN ABANDN 1.50 ABAND PLUG ABANDN 1.50 ABAND CIRC ABANDN 2.00 ABAND PLUG ABANDN 0.50 ABAND CIRC ABANDN 3.00 ABAND PLUG ABANDN Printed: 9/24/2001 3:24:20 PM ( ( PHilliPS ALASKA INC. Operations Summary Report Legal Well Name: 2N-304 Common Well Name: 2N-304 Event Name: ROT - DRILLING Contractor Name: Nabors Rig Name: Nabors 16E Date From -To Hours Code Sub Phase ,Code 8/3/2001 12:30 - 15:30 3.00 ABAND PLUG ABANDN 15:30 - 16:30 1.00 ABAND CIRC ABANDN 16:30 - 22:00 5.50 ABAND TRIP ABANDN 22:00 - 00:00 2.00 ABAND NUND ABANDN 8/4/2001 00:00 - 01 :30 1.50 ABAND RURD ABANDN 01 :30 - 05:00 3.50 ABAND PERF ABANDN 05:00 - 07:00 2.00 ABAND NUND ABANDN 07:00 - 13:30 13:30 - 14:30 6.50 ABAND TRIP ABANDN 1.00 ABAND CIRC ABANDN 14:30 - 16:00 1.50 ABAND PLUG ABANDN 16:00 -18:00 2.00 ABAND OTHR ABANDN 18:00 -18:30 0.50 ABAND TRIP ABANDN 18:30 - 20:00 1.50 ABAND CIRC ABANDN 20:00 - 00:00 4.00 ABAND TRIP ABANDN 8/5/2001 00:00 - 04:00 4.00 ABAND TRIP ABANDN 04:00 - 07:30 3.50 ABAND TRIP ABANDN 07:30 - 09:30 2.00 ABAND CUTP ABANDN 09:30 - 11 :30 2.00 ABAND TRIP ABANDN 11 :30 - 12:30 1.00 ABAND CIRC ABANDN 12:30 - 13:30 WLHD ABANDN 13:30 - 14:30 JAR ABANDN 14:30 - 15:30 1.00 ABAND WLHD ABANDN 15:30 -18:00 2.50 ABAND TRIP ABANDN 18:00 -19:30 1.50 ABAND CUTP ABANDN 19:30 - 22:00 2.50 ABAND CIRC ABANDN 22:00 - 23:30 1.50 ABAND TRIP ABANDN 23:30 - 00:00 0.50 ABAND WLHD ABANDN 8/6/2001 00:00 - 00:30 0.50 ABAND WLHD ABANDN 00:30 - 01 :00 0.50 ABAND RTRV ABANDN 01:00 - 01:30 0.50 ABAND CIRC ABANDN 01 :30 - 02:00 0.50 ABAND PULD ABANDN 02:00 - 07:30 5.50 ABAND RTRV ABANDN 07:30 - 09:30 2.00 ABAND TRIP ABANDN Page 8 of 10 Spud Date: 7/14/2001 End: 8/15/2001 Group: Start: 7/13/2001 Rig Release: 8/15/2001 Rig Number: 16E Description of Operations rate.8 bpm @ 3200 psi - Final rate 1.0 bpm @ 2000 psi, CIP @ 1235 hrs 8/3/01 Calc. TOC 9437', Hold pressure Bleed 600 psi off well, Open well, Circ. btm's up POOH lay retainer running tool Nipple down riser & strip-o-matic, Nipple up lubricator Rig Schlumberger wire line & guns, Test lubricator to 1000 psi RIH wI perf. guns & shoot 6 spf f/8575'- 8577', POOH Rig down SWS, Lubricator & Shooting flange, Nipple up riser & strip-o-matic Note; Est. injection rate of .5 bpm @ 1300 psi- and noticed small returns to 5-1/2"x 7-5/8" annulus Make up Baker K-1 cmt. retainer, RIH to 8525' Set retainer @ 8525', Test DP to 3000 psi, Circ. Btm's up above retainer Stab into retianer, Open 5-1/2"x 7-5/8" annulus, Est. injection rate of .5 bpm @ 1500 psi, After 10 bbls press. broke down to 750 psi, Est. injection rate at 2 bpm @ 1150 psi, Pumped total of 20 bbls wI no returns up annulus With 5-1/2"x 7-5/8" annulus open, Batch mix 20 bbls (96 sxs) 15.8 ppg Class G cmt. w/0.35% D167, 0.3% D65, 0.2% D46, 0.09% XE920, Pump 5 bbls fresh water, Test lines to 3500 psi, Pump 20 cmt at rate of 2 bpm @ 1300 - 800 psi, Displace cmt w/2 bbls fresh water followed by 32.2 bbls 9.7 ppg mud at rate of 750 - 1300 psi, Had no returns up 5-1/2"x 7-5/8" annulus thru out job, CIP 1747 hrs 8?4?01, Pull out and dump 4 bbls cmt on top of retainer TOC 8357' POOH to 8000' Circ. clean (trace of cmt), Rig & test 5-1/2" csg to 2500 psi f/30 min.-OK POOH & lay down excess DP Lay down excess 2-7/8" DP Make up & RIH to 3125' w/ 5-1/2" csg cutter (strap in on hook) Cut 5-1/2" csg. @ 3125'- Not very good indications of cut Monitor well, POOH & LID csg. cutter Rig & attempt to circ. 5-1/2"x 7-5/8" annulus- No good- 5-1/2" tested to 750 psi Rig & pull wear bushing & 5-1/2"x 7-5/8" pack-off Pick up spear & Attempt to pull 5-1/2" csg.-No good, Had good stretch on csg.- pipe should be free if cut. Reset 5-1/2"x 7-5/8" pack-off & test to 5000 psi Change cutters in 5-1/2" csg. cutter & RIH to 3123' Cut 5-1/2" csg @ 3123' - Had good indications of cut Rig to circ. 5-1/2"x 7-5/8" annulus, Close rams & circ. annulus thru choke- thick mud, low gas, final circ rate 2 bpm at 630 psi, no mud loss, Monitor well, Dry pipe POOH & Lay down cutter Rig & pull wear bushing & 5-1/2"x 7-5/8" pack-off Pull 5-1/2"x 7-5/8" pack off Pick up 5-1/2" spear & Pull 5-1/2" csg hanger to floor Circ btm's up (Gas 750 units) Lay down 5-1/2" csg spear & circ. head Pull & lay down 5-1/2" csg. (5-1/2" Stub @ 3124' by csg measurements) Set wear bushing, Rig & RIH w/ open ended 2-7/8" DP to 3550' Printed: 9/24/2001 3:24:20 PM - ~ -oA. ~'PHlLùPs '> . IW) ~ { ( Page 9 of 10 PHilliPS ALASKA INC. Operations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 2N-304 2N-304 ROT - DRILLING Nabors Nabors 16E . Sub Hours Code Code Date 8/6/2001 8/7/2001 8/8/2001 8/9/2001 8/10/2001 8/11/2001 8/12/2001 8/13/2001 From -To 09:30 - 10:30 10:30 - 12:00 12:00 - 13:00 13:00 - 13:30 13:30 - 15:00 15:00 - 20:00 20:00 - 21 :30 21 :30 - 23:00 23:00 - 00:00 00:00 - 13:00 13:00 - 14:30 14:30 - 22:00 22:00 - 00:00 00:00 - 02:30 02:30 - 03:30 03:30 - 04:30 04:30 - 05:30 05:30 - 06:30 06:30 - 09:00 09:00 - 13:00 13:00 - 14:00 14:00 - 00:00 00:00 - 17:00 17:00 - 20:00 20:00 - 22:30 22:30 - 23:30 23:30 - 00:00 00:00 - 01 :00 01:00 - 01:30 01 :30 - 00:00 00:00 - 19:30 19:30 - 22:30 22:30 - 00:00 00:00 - 02:30 02:30 - 05:30 05:30 - 15:00 15:00 - 16:30 16:30 - 18:30 18:30 - 21:00 21 :00 - 00:00 00:00 - 10:00 Phase 1.00 ABANDI\ CIRC ABANDN 1.50 ABANDI\ CIRC ABANDN 1.00 CEMEN" PLUG PROD 0.50 DRILL 1.50 DRILL 5.00 DRILL 1.50 DRILL 1.50 DRILL 1.00 DRILL 13.00 DRILL 1.50 DRILL 7.50 DRILL TRIP PROD CIRC PROD TRIP PROD RIRD PROD RIRD PROD PULD PROD PULD PROD RIRD PROD OTHR PROD 2.00 DRILL TRIP PROD 2.50 DRILL PULD PROD 1.00 RIGMNT RURD PROD 1.00 RIGMNT RSRV PROD 1.00 DRILL TRIP PROD 1.00 DRILL REAM PROD 2.50 DRILL DRLG PROD 4.00 DRILL DRLG PROD 1.00 DRILL CIRC PROD 10.00 DRILL DRLG PROD 17.00 DRILL DRLG PROD 3.00 DRILL CIRC PROD 2.50 DRILL WIPR PROD 1.00 RIGMNT RSRV PROD 0.50 DRILL WIPR PROD 1.00 DRILL WIPR PROD 0.50 DRILL CIRC PROD 22.50 DRILL DRLG PROD 19.50 DRILL 3.00 DRILL 1.50 DRILL 2.50 DRILL 3.00 DRILL 9.50 DRILL 1.50 CASE 2.00 CASE 2.50 CASE 3.00 CASE 10.00 CASE DRLG PROD CI RC PROD WI PR PROD WIPR PROD CI RC PROD TRIP PROD RURD PROD RUNC PROD RURD PROD RUNC PROD RUNC PROD Spud Date: 7/14/2001 End: 8/15/2001 Group: Start: 7/13/2001 Rig Release: 8/15/2001 Rig Number: 16E Description of' Operations Circ. btm's up, Spot 9 bbls 300 + vis, 9.7 ppg pill f/3550' to 3123' POOH to 3241', Circ. hole clean PJSM, Batch mix 20.8 bbls, 15.8 ppg Class G cmt wI 0.2% D46, 0.3% D65, 0.65% S1, 0.4% D167, Pump 8.4 bbls fresh water ahead, 20.8 bbls cmt at rate of 3.8 bpm @ 1300 psi, Displace cmt w/ 1 bbl fresh water behind followed by 9 bbls 9.7 ppg mud at final rate of 3.3 bpm @ 750 psi, CIP @ 1248 hrs 8/6/01, Calc TOC 2830' w/ 35% wash out in 6-3/4" hole, Had good circ thru out POOH to 2400' Circ. Hole & pipe clean ( No cmt on btm's up) Lay down 2-7/8" DP Clear rig floor of 2-7/8" equip., Move 5" DP in derrick Change pipe rams to 4"x 7", Rig to P/U 4" DP Pick up 4" DP Pick up 4" DP to drill 6-3/4" hole Change top drive over to HT38 4" DP Test BOPE to 250 low & 5000 high, Hydril to 250 low & 3500 high, Btm 4" x 7" pipe rams leaked changed out same to 4", Retest same OK Test witnessed By AOGCC Chuck Sheave Pick up BHA Make up BHA, Load sources, Program tools. Cut & slip drilling line 69' Service top drive, Drawworks RIH & Tag cmt @ 2860' Drill out cmt f/ 2860' to 2939' Orient motor, Time drill & sidetrack well f/ 2939' to 3034' AST = 1 hr Drill fl 3034' to 3414' AST = .5 hr ART = 2.25hrs Change over to new mud, Perform PWD base line Drill f/ 3414' to 4572' ART = 5.75 hrs AST = 1.5 hrs Drill f/ 4572' to 6680' AST = 1.5 hrs ART = 10 hrs Pump sweep, Circ. hole clean, Monitor well, Dry pipe Wipe hole to shoe, Max drag 20K - hole in good shape, (Precautionary back ream f/ 3130' to 2939' to smooth out kick off window) Service Top drive & Drawworks RIH RIH to 6680' - Hole in good shape Fill pipe, Break circ. & stair step pump to full speed Drill f/ 6680' to 8833' AST = 6.25 hrs ART = 10.0 hrs (Began 2deg/100' drop @ 8400') Drill f/ 8833' to 10052' TD AST= 5.75 hrs ART= 10 hrs Pump sweep & Circ hole clean, Monitor well, Dry pipe Begin Wiper trip to 5900' - No excess drag, Hole in good shape Finish wiping hole to 5,900'- No excess drag, hole in good shape, Monitor well- OK, RIH to 10,052'- OK Pump sweep, Circ & cond mud f/ csg, Monitor well, Dry pipe POOH -hole in great shape, Remove R/A sources, Down load tools, Lay down BHA Pull wear bushing, Rig to run 3-1/2" csg. PJSM, Run 24 its. 3-1/2" csg & equip. Rig to run 5-1/2" csg, Install fill up tool Run 5-1/2" csg. Run 3-1/2"x 5-1/2" csg., Circ @ 2885',3995',6560',8490' - Had tight spots @ 6380',6460',7270',8130', Make up hanger ..i- Printed: 9/24/2001 3:24:20 PM ~ .... ~ ~~PHILLIPS) I~ -~ ~ Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 8/13/2001 8/14/2001 8/15/2001 Date "1" ( ( Page 1 0 of 10 PHilliPS ALASKA INC. Operations Summary Report 2N-304 2N-304 ROT - DRILLING Nabors Nabors 16E .. . Sub From -To Hours Code Code Phase 10:00 - 12:00 12:00 - 12:30 12:30 - 15:00 15:00 - 17:30 17:30 - 18:00 18:00 - 19:00 19:00 - 20:00 20:00 - 00:00 00:00 - 08:00 08:00 - 09:00 09:00 - 10:00 10:00 - 10:30 10:30 - 12:00 12:00 - 14:00 14:00 - 16:00 16:00 -17:00 17:00 - 00:00 00:00 - 05:00 05:00 - 06:30 06:30 - 09:00 09:00 - 13:00 13:00 - 14:30 2.00 CASE CIRC PROD 0.50 CEMEN" PULD PROD 2.50 CASE CI RC PROD 2.50 CEMEN" PUMP PROD 0.50 CEMEN" PULD 1.00 CMPL TN NUND 1.00 CMPL TN RURD 4.00 CMPL TN RUNT 8.00 CMPL TN RUNT PROD CMPL TN CMPL TN CMPL TN CMPL TN 1.00 CMPL TN CIRC CMPL TN 1.00 CMPL TN DEaT CMPL TN 0.50 CMPLTN CIRC CMPLTN 1.50 CMPLTN SOHO CMPLTN 2.00 CMPL TN DEaT CMPL TN 2.00 CMPLTN FRZP CMPLTN 1.00 CMPL TN RURD CMPL TN 7.00 CMPLTN OTHR CMPLTN 5.00 CMPLTN TRIP CMPLTN 1.50 RIGMNT RURD CMPL TN 2.50 DRILL RIRD CMPL TN 4.00 CMPL TN NUND CMPL TN 1.50 CMPL TN SEaT CMPL TN Spud Date: 7/14/2001 End: 8/15/2001 Group: Start: 7/13/2001 Rig Release: 8/15/2001 Rig Number: 16E Description of Operations Circ. btm's up slowly @ 2-3 bpm @ 700 psi (Very low to no mud losses) Rig down fill up tool, Install cmt. head Circ & condo mud @ 3-4 bpm @ 600 psi Mix & pump 10 bbls CW1 00, Test lines to 3500 psi, 20 bbls CW1 00, 10 bbls fresh water, 40 bbls 11.0 ppg MudPUSH, 92 sxs (32.8 bbls) Class G Lead cmt. @ 13.0 ppg w/0.2%D46, 8.0%D20, 0.2%D65, 0.6%D167, 0.06%D800, Followed by 320 sxs (68.6 bbls) Class G Tail cmt. @ 15.8 ppg w/3.0%D53, 0.6%D65, 0.12%D800, 0.2gal/sk D47, 2.0%gal/sk D600G, Drop top & btm plug as 1, Flush lines, Displace cmt. wI 7 bbls 3 ppb N-Vis pill, Followed by 215.9 bbls fresh water (Total actual 222.9 bbls - Calculated 226.0 bbls), Pumped entier job at 4 bpm wlfinal rate of 4 bpm @ 1350 psi, Bumped plug w2000 psi, CIP @ 1720 hrs 8/13/01, Had good circ.thru out job, Calc. TOC 7764' Lay down cmt. head & landing jt. Install & test FMC pack off to 5000 psi - OK Rig down casing equip. & clear floor Rig & run 3-1/2" completion string Pick up & run 3-1/2" Completion string, Tag Casing seal receptacle @ 9243' Circ. btm's up Rig & test csg. to 3500 psi f/30 min. -OK Circ. hole clean Space out & Pick up hanger, Landing jt. & Land tbg, Run in lock down screws Rig & test tbg to 3500 psi for 15 min. then test annulus to 3500 psi for 15 min., Shear Camco shear valve Pump 60 bbls diesel down 5-1 12" x 3-1/2" annulus and let U-tube with 3-1/2" tbg. to freeze protect well Rig down pump lines, Lay down landing jt., Set BPV Rig & lay down 4" DP from derrick Note; Perform leak off test on 5-1 12 "x 7-5/8" annulus with 9.7 ppg mud, Leak off was 880 psi, Press bled to 600 psi in 10 min., Flush and freeze protect 5-1/2"x 7-5/8" annulus with 100 bbls fresh water followed by 30 bbls diesel Finished laying down 4" HT-38 drillpipe from derrick (stds 54 - 107). Slipped & Cut 102' drlg line. Changed bttm pipe ram f/4" to 4-1/2" X 7" VBR. Changed topdrive sub f/4" HT-38 to 5" DP. Blew down pumps & choke & kill lines. Nippled up 5" tree. Tested packoff, OK. Pulled BPV and installed 2 way check. Tested tree to 5000 psi, pulled 2 way check & installed BPV. Rig released to 2N-348 rig move @ 14:30 hrs 15 Aug 01. Final DIMS report for 2N-304. Printed: 9/24/2001 3:24:20 PM ( ( WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Lisa Weepie 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 November 15, 2001 RE: MWD Formation Evaluation Logs 2N-304, AK-MM-11122 ~DI" '30 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Jim Galvin, Sperry-Sun Drilling Services, 6900 Arctic Blvd., Anchorage, AK 99518 2N-304: Digital Log Images 1 CD Rom REceiVED NOV 2 9 2001 Alaska Oil & Gas Cons, CCUi1miSSion ,4nckorage . (' ( WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn. : Lisa Weepie 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 November 12,2001 RE: MWD Formation Evaluation Logs 2N-304, AK-MM-11122 ;:)Q/- J?Y) 1 LIS formatted CD Rom with verification listing. API#: 50-103-20382-00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING THE A TT ACHED COpy OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Service Attn: Jim Galvin 6900 Arctic Blvd. Anchorage, Alaska 99518 SigneC~ ~~ Date: R -CE'VED NOV 292001 Alaska Oil & Gas ¡""...,... ';"'<\'lns. ~"fJmmj$..~ion ,4fi(;~rage SchlulI~epgep Schlumberger Technology Corporation, by and through is Geoquest Division 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 A TIN: Sherrie Well Job # Log Description 2K-27 2L-317A 2N-304 2N-307 2N-325 2N-331 2N-343 2N-349A STATIC BOTIOMHOLE PRESSURE WATERFLOW LOGJRST-C WIPSP SBHP & JEWELRY LOG INJECTION PROFILE INJECTION PROFILE INJECTION PROFILE INJECTION PROFILE INJECTION PROFILE SIG~ (, Ch~ Date 11/07/01 11/08/01 11/12/01 11/09/01 11/11/01 11/11/01 11/13/01 11/13/01 NO. 1641 Company: Field: BL Sepia Alaska Oil & Gas Cons Comm AUn: Lisa Weepie 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Kuparuk CD Color 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 RECEIVED DATE: NeV 2 7 2001 Please sign and return one copy of this transmittal to Sherrie at the above address or fax to (907) 561-8317. Than~ Oil & Gas Cons. Commission AncOOr'age 11/26/01 ~, ~... ( ( WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Corom. Attn.: Lisa Weepie 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 October 31,2001 RE: MWD Formation Evaluation Logs 2N-304 PB1, AK-MM-11122 aOJ~'. J3ó The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Jim Galvin, Sperry-Sun Drilling Services, 6900 Arctic Blvd., Anchorage, AK 99518 2N-304 PBl: Digital Log Images 1 CD Rom RECEIVED NOV 1:5 2001 Alaska Oil & Gas Cons. COmm'tlia ,Anchorage ... n 'I ~¡ "I WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Lisa Weepie 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: MWD Formation Evaluation Logs 2N-304 PB1, AK-MM-11122 ~O J- 1 ~~n 1 LDWG formatted Disc with verification listing. API#: 50-103-20382-70 ( October 24, 2001 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING THE A TT ACHED COpy OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Service Attn: Jim Galvin 6900 Arctic Blvd. Anchorage, Alaska 99518 Date: Signe~ RECEIVED OCT 3 1 2001 Alaska Oil & Gas Cons. Commission Anchorage ~~. -, ( ( . Olo/-/:Jj 07-Sep-01 AOGCC 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 Re: Distribution of Survey Data for Well 2N-304PB1 MWD Dear Dear Sir/Madam: Enclosed are two survey hard copies and 1 disk Tie-on Survey: 546.00' MD Window / Kickoff Survey , MD Projected Survey: 10,415.00' MD (if applicable) Please call me at 273-3545 if you have any questions or concerns. Regards, William T. Allen Survey Manager Attachment(s) RECEIVED SEP 1 2 2001 ..\1»:;.,(-(.," .)¡, Ò' ,-",.~i~.' "~I(;O~:"A;i...!i¡.,:,;:~IP; ¡ih,¡\,')~\'~ij!: , . ", ',:)J Q fY}, - \ -... c c-cs ------- Kuparuk River Unit Nolth Slope, Alaska Kuparuk 2N, Slot 2N-304 2N-304PB 1MWD Job No. AKMM11122, Surveyed: 22 July, 2001 SURVEY REPORT 7 September, 2001 Your Ref: A PI50 1032038270 Surface Coordinates: 5912003.77 N, 461078.43 E (700 10' 13.9335" N, 1500 18' 47.6898" W) Kelly Bushing: 153.63ft above Mean Sea Level -._' 5ipera""y-5UI! DAILLING- SERVICES A Halliburton Company Survey Ref: svy9616 Sperry-Sun Drilling Services Survey Report for 2N-304PB1 MWD Your Ref: API50 1 032038270 Job No. AKMM11122, Surveyed: 22 July, 2001 . North Slope, Alaska Kuparuk River Unit Kuparuk 2N Measured Sub-Sea Vertical Local Coordinates, Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) . (ft) (ft) (°/1 OOft) 546.00 5.100 123.000 391.94 545.57 10.93 S 10.47 E 5911992.79 N 461088.84 E 1.17 Tie On Point MWD Magnetic "~ 651.41 5.460 121.690 496.90 650.53 16.12 S 18.66 E 5911987.56 N 461097.01 E 0.360 4.22 745.40 6.870 113.900 590.34 743.97 20.74 S 27.61 E 5911982.89 N 461105.93 E 1.741 8.20 836.35 8.340 105.060 680.49 834.12 24.66 S 38.95 E 5911978.91 N 461117.25 E 2.061 14.49 933.48 12.200 96.610 776.06 929.69 27.67 S 55.95 E 5911975.81 N 461134.24 E 4.256 25.73 1022.89 14.710 90.890 863.01 1016.64 28.94 S 76.69 E 5911974.44 N 461154.97 E 3.174 40.97 1114.83 16.890 89.840 951.47 1105.10 29.08 S 101.72 E 5911974.17 N 461180.00 E 2.391 60.24 1208.85 19.600 91.860 1040.76 1194.39 29.56 S 131.15 E 5911973.54 N 461209.43 E 2.959 82.70 1300.56 20.440 93.670 1126.92 1280.55 31.08 S 162.51 E 5911971.85 N 461240.77 E 1.138 105.98 1395.28 19.670 85.910 1215.92 1369.55 31.00 S 194.92 E 5911971.77 N 461273.19 E 2.922 131.10 1488.90 21.890 77.670 1303.46 1457.09 26.15 S 227.69 E 5911976.45 N 461305.99 E 3.916 159.52 1580.98 26.370 70.630 1387.49 1541.12 15.69 S 263.78 E 5911986.72 N 461342.13 E 5.775 194.06 1675.66 30.610 64.510 1470.70 1624.33 1.67 N 305.41 E 5912003.86 N 461383.84 E 5.432 237.26 1773.82 35.280 60.820 1553.06 1706.69 26.26 N 352.74 E 5912028.21 N 461431.30 E 5.176 289.46 1867.34 39.730 57.310 1627.24 1780.87 55.59 N 401.51 E 5912057.29 N 461480.22 E 5.277 345.77 1961.54 44.290 54.700 1697.22 1850.85 90.87 N 453.72 E 5912092.31 N 461532.61 E 5.183 408.51 2054.16 48.880 52.790 1760.86 1914.49 130.68 N 507.93 E 5912131.83 N 461587.02 E 5.177 475.67 2150.80 53.050 51.970 1821.71 1975.34 176.50 N 567.36 E 5912177.35 N 461646.69 E 4.365 550.69 2244.53 57.630 50.560 1875.01 2028.64 224.75 N 627.47 E 5912225.29 N 461707.04 E 5.040 627.76 - 2337.35 62.270 48.880 1921.48 2075.11 276.70 N 688.72 E 5912276.92 N 461768.57 E 5.238 708.06 2435.80 65.170 48.120 1965.06 2118.69 335.19 N 754.82 E 5912335.07 N 461834.97 E 3.026 796.26 2527.05 68.190 48.070 2001 .18 2154.81 391.15 N 817.18 E 5912390.71 N 461897.61 E 3.310 879.97 2621.48 67.730 48.320 2036.62 2190.25 449.50 N 882.43 E 5912448.72 N 461963.16 E 0.545 967.41 2715.15 68.320 46.740 2071.67 2225.30 508.15 N 946.50 E 59-12507.04 N 462027.53 E 1.686 1054.15 2808.88 68.370 46.970 2106.26 2259.89 567.72 N 1010.06 E 5912566.29 N 462091.39 E 0.234 1141.07 2885.51 68.310 45.090 2134.54 2288.17 617.16N 1061.31 E 5912615.47 N 462142.90 E 2.281 1212.05 3013.82 68.510 47.180 2181.76 2335.39 699.83 N 1147.32 E 5912697.69 N 462229.34 E 1.523 1330.98 3111.68 69.370 46.850 2216.93 2370.56 762.10 N 1214.13 E 5912759.61 N 462296.46 E 0.933 1422.12 3207.44 68.980 47.210 2250.97 2404.60 823.10 N 1279.62 E 5912820.28 N 462362.26 E 0.538 1511.44 3301.12 68.510 48.130 2284.93 2438.56 881.90 N 1344.16 E 5912878.74 N 462427.11 E 1.044 1598.63 _.-.~~- 7 September, 2001 - 10:44 Page 2 of 6 DrillQuest 2.00.08.005 Sperry-Sun Drilling Services Survey Report for 2N-304PB1 MWD Your Ref: AP/501032038270 Job No. AKMM11122, Surveyed: 22 July, 2001 . North Slope, Alaska Kuparuk River Unit Kuparuk 2N Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northlngs Eastlngs Northlngs Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (o/100ft) 3398.15 67.370 47.670 2321.37 2475.00 942.18 N 1410.88 E 5912938.68 N 462494.14 E 1.254 1688.45 3495.73 65.900 48.120 2360.07 2513.70 1002.24 N 1477.34 E 5912998.40 N 462560.91 E 1.565 1777.92 -'- 3591.88 63.460 49.160 2401.19 2554.82 1059.68 N 1542.56 E 5913055.50 N 462626.42 E 2.719 1864.77 3686.87 63.320 49.690 2443.74 2597.37 1114.92 N 1607.07 E 5913110.41 N 462691.21 E 0.520 1949.68 3782.95 63.050 49.560 2487.08 2640.71 1170.46 N 1672.40 E 5913165.62 N 462756.82 E 0.306 2035.41 3879.00 63.790 49.800 2530.06 2683.69 1226.04 N 1737.89 E 5913220.86 N 462822.60 E 0.802 2121.30 3974.98 64.630 49.440 2571.82 2725.45 1282.03 N 1803.72 E 5913276.51 N 462888.72 E 0.938 2207.70 4071.37 64.020 48.390 2613.58 2767.21 1339.12 N 1869.20 E 5913333.26 N 462954.49 E 1.168 2294.53 4167.19 64.760 48.010 2655.00 2808.63 1396.71 N 1933.61 E 5913390.52 N 463019.20 E 0.851 2380.86 4265.94 63.060 49.100 2698.42 2852.05 1455.42 N 2000.08 E 5913448.88 N 463085.97 E 1.987 2469.48 4358.68 63.180 49.270 2740.35 2893.98 1509.48 N 2062.69 E 5913502.62 N 463148.85 E 0.209 2552.17 4454.03 64.000 49.120 2782.77 2936.40 1565.29 N 2127.33 E 5913558.1 0 N 463213.78 E 0.871 2637.54 4550.62 64.820 48.870 2824.49 2978.12 1622.45 N 2193.07 E 5913614.92 N 463279.81 E 0.880 2724.62 4647.33 63.950 48.910 2866.29 3019.92 1679.79 N 2258.77 E 5913671.92 N 463345.81 E 0.900 2811.78 4744.20 64.220 48.560 2908.63 3062.26 1737.25 N 2324.26 E 5913729.04 N 463411.60 E 0.428 2898.86 4841.81 65.180 48.380 2950.34 3103.97 1795.76 N 2390.33 E 5913787.21 N 463477.96 E 0.998 2987.04 4935.28 65.980 48.230 2988.99 3142.62 1852.37 N 2453.87 E 5913843.50 N 463541.80 E 0.868 3072.08 5032.74 64.700 48.420 3029.65 3183.28 1911.26 N 2520.03 E 5913902.05 N 463608.26 E 1.325 3160.58 5129.95 63.180 48.590 3072.35 3225.98 1969.12 N 2585.44 E 5913959.57 N 463673.96 E 1.571 3247.84 5224.54 63.400 48.800 3114.87 3268.50 2024.89 N 2648.91 E 5914015.01 N 463737.72 E 0.306 3332.29 -"~- 5324.71 64.210 48.680 3159.09 3312.72 2084.17 N 2716.48 E 5914073.94 N 463805.59 E 0.816 3422.12 5418.43 65.190 48.510 3199.14 3352.77 2140.21 N 2780.03 E 5914129.65 N 463869.43 E 1.058 3506.79 5515.20 65.980 49.360 3239.14 3392.77 2198.09 N 2846.46 E 5914187.19 N 463936.16 E 1.143 3594.87 5610.61 64.170 48.350 3279.35 3432.98 2255.01 N 2911.62 E 5914243.78 N 464001.61 E 2.126 3681.34 5707.01 64.430 47.860 3321.15 3474.78 2313.02 N 2976.28 E 5914301.45 N 464066.56 E 0.532 3768.12 5803.01 65.510 48.230 3361.77 3515.40 2371.17 N 3040.97 E 5914359.27 N 464131.55 E 1.178 3855.01 5899.22 66.510 48.650 3400.88 3554.51 2429.48 N 3106.74 E 5914417.24 N 464197.62 E 1.113 3942.84 5997.11 64.840 48.430 3441.20 3594.83 2488.53 N 3173.58 E 5914475.95 N 464264.77 E 1. 718 4031.98 6089.84 63.380 48.830 3481.69 3635.32 2543.67 N 3236.19 E 5914530.76 N 464327.65 E 1.622 4115.35 6188.30 64.130 49.800 3525.23 3678.86 2601.23 N 3303.15 E 5914587.98 N 464394.92 E 1.167 4203.63 - ------------- 7 September, 2001 - 10:44 Page 3 of 6 DrillQuest 2.00.08.005 Sperry-Sun Drilling Services Survey Report for 2N-304PB1 MWD Your Ref: A PI50 1 032038270 Job No. AKMM111221 Surveyed: 22 JulYI 2001 . North Slope, Alaska Kuparuk River Unit Kuparuk 2N Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (°/1 OOft) 6285.77 64.490 49.820 3567.49 3721.12 2657.92 N 3370.25 E 5914644.32 N 464462.30 E 0.370 4291.45 6379.91 65.230 50.410 3607.48 3761.11 2712.56 N 3435.64 E 5914698.63 N 464527.98 E 0.969 4376.67 -~- 6477.25 63.450 49.140 3649.63 3803.26 2769.22 N 3502.63 E 5914754.94 N 464595.26 E 2.174 4464.40 6573.12 62.840 49.180 3692.94 3846.57 2825.15 N 3567.34 E 5914810.53 N 464660.25 E 0.637 4549.90 6668.78 63.800 49.040 3735.89 3889.52 2881.10 N 3631.96 E 5914866.15 N 464725.16 E 1.012 4635.34 6764.50 64.550 48.660 3777.59 3931.22 2937.80 N 3696.83 E 5914922.52 N 464790.32 E 0.861 4721.46 6861.21 64.560 48.690 3819.14 3972.77 2995.46 N 3762.42 E 5914979.84 N 464856.20 E 0.030 4808.73 6954.97 65.290 48.590 3858.88 4012.51 3051.58 N 3826.16 E 5915035.63 N 464920.23 E 0.785 4893.60 7049.25 64.180 49.180 3899.11 4052.74 3107.65 N 3890.39 E 5915091.37 N 464984.75 E 1.306 4978.82 7149.95 64.150 49.290 3943.00 4096.63 3166.83 N 3959.03 E 5915150.19 N 465053.70 E 0.103 5069.43 7242.82 64.980 49.240 3982.88 4136.51 3221.56 N 4022.58 E 5915204.59 N 465117.53 E 0.895 5153.27 7339.36 65.920 49.260 4022.99 4176.62 3278.88 N 4089.11 E 5915261.57 N 465184.35 E 0.974 5241.06 7436.64 65.320 49.850 4063.15 4216.78 3336.36 N 4156.54 E 5915318.70 N 465252.07 E 0.828 5329.64 7531.78 64.890 50.250 4103.20 4256.83 3391.77 N 4222.69 E 5915373.78 N 465318.51 E 0.591 5415.94 7628.01 65.240 50.690 4143.77 4297.40 3447.31 N 4290.00 E 5915428.97 N 465386.10 E 0.552 5503.20 7724.66 63.660 50.120 4185.45 4339.08 3502.88 N 4357.19 E 5915484.20 N 465453.58 E 1.719 5590.39 7821.75 62.620 49.420 4229.32 4382.95 3558.82 N 4423.32 E 5915539.79 N 465519.99 E 1.249 5676.99 7918.97 62.980 49.400 4273.76 4427.39 3615.08 N 4488.98 E 5915595.72 N 465585.94 E 0.371 5763.44 8015.21 63.540 49,200 4317.06 4470.69 3671.13 N 4554.14 E 5915651.43 N 465651.39 E 0.611 5849.37 8116.35 64.280 48.720 4361.54 4515.17 3730.77 N 4622.65 E 5915710.71 N 465720.21 E 0.847 5940.16 ---- 8208.27 64.830 48.360 4401.03 4554.66 3785.72 N 4684.85 E 5915765.35 N 465782.69 E 0.695 6023.11 8307.28 63.470 48.050 4444.20 4597,83 3845.11 N 4751.28 E 5915824.39 N 465849.42 E 1.402 6112.12 8396.05 63.470 47.240 4483.85 4637.48 3898,61 N 4809.97 E 5915877.59 N 465908.39 E 0.816 6191.44 8497.00 62.690 47.310 4529.56 4683.19 3959.68 N 4876.10 E 5915938.32 N 465974.83 E 0.775 6281.29 8591.16 59.210 48.190 4575.27 4728.90 4015.03 N 4937.01 E 5915993.35 N 466036.02 E 3.785 6363.48 8687.91 58.940 47.970 4624.99 4778.62 4070.48 N 4998.76 E 5916048.48 N 466098.06 E 0.340 6446.39 8782.53 56.790 48.890 4675.32 - 4828.95 4123.64 N 5058.70 E 5916101.34 N 466158.27 E 2.417 6526.45 8879.66 55.610 49.070 4729.35 4882.98 4176.62 N 5119.59 E 5916154.00 N 466219.44 E 1.225 6607.13 8975.37 54.330 49.350 4784.29 4937.92 4227.82 N 5178.93 E 5916204.90 N 466279.03 E 1.359 6685.47 9070.30 53.420 48.760 4840.26 4993.89 4278.06 N 5236.85 E 5916254.84 N 466337.21 E 1.082 6762.12 c -.-c- c- - ---- 7 September, 2001 - 10:44 Page 4 of 6 DrillQuest 2.00.08.005 Sperry-Sun Drilling Services Survey Report for 2N-304PB1 MWD Your Ref: AP/501032038270 Job No. AKMM111226 Surveyed: 22 JUlY6 2001 . North Slope, Alaska Kuparuk River Unit Kuparuk 2N Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azlm. Depth Depth Northlngs Eastlngs Northlngs Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (0/100ft) 9162.28 52.320 49.840 4895.78 5049.41 4325.89 N 5292.44 E 5916302.38 N 466393.05 E 1.519 6835.43 9260.60 51.390 49.790 4956.51 5110.14 4375.78 N 5351.51 E 5916351.97 N 466452.37 E 0.947 6912.74 ~- 9356.68 50.580 49.800 5016.99 5170.62 4423.97 N 5408.52 E 5916399.86 N 466509.64 E 0.843 6987.39 9453.35 49.250 50.190 5079.24 5232.87 4471.52 N 5465.17 E 5916447.12 N 466566.53 E 1.410 7061.34 9548.58 47.450 49,940 5142.52 5296.15 4517.19 N 5519.74 E 5916492.51 N 466621 .32 E 1.900 7132.49 9645.53 46.400 49.250 5208.73 5362.36 4563.09 N 5573.66 E 5916538.13 N 466675.49 E 1.201 7203.30 9740.13 45.300 48.980 5274.63 5428.26 4607.52 N 5624.98 E 5916582.30 N 466727.03 E 1.181 7271.15 9834.35 44.350 49.300 5341.45 5495.08 4650.97 N 5675.21 E 5916625.49 N 466777.49 E 1.036 7337.54 9934.11 43.270 49.600 5413.44 5567.07 4695.87 N 5727.69 E 5916670.12 N 466830.19 E 1.102 7406.59 10031.10 42.340 50.480 5484.60 5638.23 4738.20 N 5778.20 E 5916712.19 N 466880.92 E 1.140 7472.49 10126.81 41.070 51.320 5556.05 5709.68 4778.36 N 5827.61 E 5916752.09 N 466930.53 E 1 .450 7536.16 10225.08 39.940 51.360 5630.77 5784.40 4818.23 N 5877.45 E 5916791.71 N 466980.58 E 1.150 7599.98 10317.96 38.900 50.640 5702.52 5856.15 4855.34 N 5923.28 E 5916828.58 N 467026.61 E 1.223 7658.96 10354.32 38.510 51.060 5730.90 5884.53 4869.70 N 5940.91 E 5916842.85 N 467044.31 E 1.293 7681.69 10415.00 38.510 51.060 5778.38 5932.01 4893.44 N 5970.30 E 5916866.44 N 467073.82 E 0.000 7719.48 Projected Survey All data is in Feet (US) unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to RKB (153.63' MSL). Northings and Eastings are relative to 2' FNL & 514' FEL. ~ Magnetic Declination at Surface is 25.608° (13-Aug-01) The Dogleg Severity is in Degrees per 100 feet (US). Vertical Section is from 2' FNL & 514' FEL and calculated along an Azimuth of 50.661° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 10415.00ft., The Bottom Hole Displacement is 7719.48ft, in the Direction of 50.661° (True). ~~- ---m___~_--_m -~- ---- ~_~_n~__~__- ~ 7 September, 2001 - 10:44 Page 5 of 6 DrlllQuest 2.00.08.005 Kuparuk River Unit Comments ~""""" Measured Depth (ft) 546.00 10415.00 Sperry-Sun Drilling Services Survey Report for 2N-304PB1 MWD Your Ref: AP/50 1 032038270 Job No. AKMM111221f Surveyed: 22 JulYIf 2001 Station Coordinates TVD Northings Eastings (ft) (ft) (ft) 545.57 5932.01 10.93 S 4893.44 N Survey tool program for 2N-304PB1 MWD From Measured Vertical Depth Depth (ft) (ft) 0.00 546.00 ~- 0.00 545.57 7 September, 2001 - 10:44 To Measured Vertical Depth Depth (ft) (ft) 546.00 10415.00 545.57 5932.01 n- ~----- ~ Comment 10.47 E 5970.30 E Tie On Point Projected Survey Survey Tool Description Tolerable Gyro (2N-304PB1Gyro) MWD Magnetic (2N-304PB1 MWD) Page 6 of 6 . North Slope, Alaska Kuparuk 2N DrlllQuest 2.00.08.005 (' AOGCC 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 ( é).OJ-/30 07 -Sep-O 1 Re: Distribution of Survey Data for Well 2N-304 MWD Dear Dear Sir/Madam: Enclosed are two survey hard copies and 1 disk Tie-on Survey: 2,885.51 ' MD Window / Kickoff Survey , MD Projected Survey: 10,052.00' MD (if applicable) Please call me at 273-3545 if you have any questions or concerns. Regards, William T. Allen Survey Manager Attachment(s) RECEIVED SEP 1 2 2001 AlasKô Uil & Gas Cons, r;ommissíon Am:;ttnrage n- ...J (Y) " . .......... a CD ._¿~ Kuparuk River Unit North Slope, Alaska Kuparuk 2N, Slot 2N-304 2N-304 MWD Job No. AKMM11122, Surveyed: 11 August, 2001 SURVEY REPORT 7 September~ 2001 Your Ref: API501032038200 Surface Coordinates: 5912003.77 N, 461078.43 E (70010' 13.9335" N, 150018' 47.6898" W) Kelly Bushing: 153.63ft above Mean Sea Level " ""...-- 55 P E!""'" Y - 5U" ~ILLING SÎ!æAVlces A Halliburton Company Survey Ref: svy9600 Sperry-Sun Drilling Services Survey Report for 2N-304 MWD Your Ref: A P/50 1 032038200 Job No. AKMM11122~ Surveyed: 11 August~ 2001 . North Slope, Alaska Kuparuk River Unit Kuparuk 2N Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northlngs Eastlngs Northlngs Eastlngs Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) eft) (a/100ft) 2885.51 68.310 45.090 2134.54 2288.17 617.16 N 1061.31 E 5912615.47 N 462142.90 E 1206.81 Tie On Point 2939.00 65.670 49.920 2155.46 2309.09 650.42 N 1097.58 E 5912648.54 N 462179.34 E 9.665 1256.00 c~ 2960.55 64.620 50.640 2164.52 2318.15 662.92 N 1112.62 E 5912660.96 N 462194.45 E 5.738 1275.55 3058.15 59.380 54.630 2210.34 2363.97 715.24 N 1181.02 E 5912712.93 N 462263.12 E 6.468 1361.52 3151.04 60.460 60.360 2256.92 2410.55 758.39 N 1248.78 E 5912755.73 N 462331.09 E 5.462 1441.01 3245.34 60.410 58.590 2303.46 2457.09 800.05 N 1319.43 E 5912797.02 N 462401.96 E 1.633 1521.73 3342.47 62.390 56.890 2349.95 2503.58 845.57 N 1391.53 E 5912842.17 N 462474.29 E 2.553 1606.06 3436.61 63.800 54.670 2392.55 2546.18 892.78 N 1460.94 E 5912889.03 N 462543.94 E 2.582 1689.45 3526.12 65.840 52.790 2430.64 2584.27 940.71 N 1526.23 E 5912936.62 N 462609.48 E 2.968 1770.20 3629.32 66.350 51 .420 2472.46 2626.09 998.66 N 1600.68 E 5912994.18 N 462684.22 E 1.310 1864.43 3725.33 66.190 50.430 2511.10 2664.73 1054.06 N 1668.91 E 5913049.23 N 462752.74 E 0.959 1952.28 3821.29 66.370 50.000 2549.70 2703.33 1110.28 N 1736.42 E 5913105.10 N 462820.54 E 0.451 2040.12 3917.14 64.720 51.020 2589.38 2743.01 1165.76 N 1803.75 E 5913160.24 N 462888.15 E 1.975 2127.34 4014.55 63.130 49.190 2632.19 2785.82 1221.87 N 1870.88 E 5913216.00 N 462955.57 E 2.348 2214.82 4109.79 62.690 49.100 2675.57 2829.20 1277.34 N 1935.01 E 5913271.14 N 463019.99 E 0.470 2299.61 4206.73 62.990 48.280 2719.82 2873.45 1334.27 N 1999.80 E 5913327.74 N 463085.06 E 0.814 2385.86 4302.89 62.470 47.830 2763.88 2917.51 1391 .40 N 2063.37 E 5913384.54 N 463148.93 E 0.682 2471.31 4398.26 62.800 47.580 2807.71 2961.34 1448.40 N 2126.02 E 5913441.22 N 463211.87 E 0.417 2555.98 4493.09 62.820 47.220 2851.05 3004.68 1505.50 N 2188.11 E 5913497.99 N 463274.25 E 0.338 2640.29 4590.58 63.040 46.170 2895.41 3049.04 1565.04 N 2251.28 E 5913557.21 N 463337.73 E 0.985 2727.01 c~--- 4686.87 62.950 45.790 2939.13 3092.76 1624.65 N 2312.97 E 5913616.51 N 463399.73 E 0.364 2812.66 4783.51 63.580 49.560 2982.62 3136.25 1682,75 N 2376.77 E 5913674.27 N 463463.83 E 3.544 2898.92 4879.15 63.440 48.710 3025.28 3178.91 1738.75 N 2441.51 E 5913729.94 N 463528.85 E 0.809 2984.52 4975.42 63.080 48.590 3068.60 3222.23 1795.55 N 2506.05 E 5913786.41 N 463593.68 E 0.390 3070.49 5071.13 63.230 48.560 3111.82 3265.45 1852.05 N 2570.08 E 5913842.58 N 463658.00 E 0.159 3155.88 5166.51 63.600 47.630 3154.50 3308.13 1909.02 N 2633.56 E 5913899.22 N 463721.77 E 0.954 3241.15 5262.79 63.670 47.630 3197.26 3350.89 1967.16 N 2697.29 E 5913957.03 N 463785.80 E 0.073 3327.38 5360.11 63.890 46.940 3240.26 3393.89 2026.38 N 2761.44 E 5914015.92 N 463850.25 E 0.675 3414.64 5455.35 64.600 48.130 3281.64 3435.27 2084.29 N 2824.72 E 5914073.50 N 463913.83 E 1.350 3500.38 5553.02 65.080 47.070 3323.17 3476.80 2143.90 N 2890.00 E 5914132.78 N 463979.41 E 1.098 3588.74 -- ---------- ----- 7 September, 2001 - 10:34 Page 2 of 5 DrlllQuest 2.00.08.005 Sperry-Sun Drilling Services Survey Report for 2N-304 MWD Your Ref: A PI 50 1 032038200 Job No. AKMM11122~ Surveyed: 11 August~ 2001 . North Slope, Alaska Kuparuk River Unit Kuparuk 2N Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azlm. Depth Depth Northlngs Eaellng. Northlngs Eastlngs Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) CO/100ft) 5649.01 64.550 48.810 3364.02 3517.65 2202.09 N 2954.48 E 5914190.64 N 464044.20 E 1.731 3675.58 5745.12 63.080 50.180 3406.43 3560.06 2258.11 N 3020.05 E 5914246.32 N 464110.06 E 1.994 3761.82 ~ 5841.77 62.810 49.830 3450.39 3604.02 2313.43 N 3085.99 E 5914301.30 N 464176.28 E 0.427 3847.89 5935.94 62.330 49.390 3493.77 3647.40 2367.59 N 3149.65 E 5914355.13 N 464240.22 E 0.657 3931.47 6033.13 61.510 49.230 3539.52 3693.15 2423.50 N 3214.67 E 5914410.70 N 464305.53 E 0.856 4017.22 6127.92 61.620 48.410 3584.66 3738.29 2478.38 N 3277.41 E 5914465.26 N 464368.54 E 0.770 4100.57 6221.99 61.390 48.630 3629.53 3783.16 2533.14 N 3339.35 E 5914519.70 N 464430.76 E 0.319 4183.24 6319.83 62.880 47.220 3675.26 3828.89 2591.10 N 3403.54 E 5914577.33 N 464495.25 E 1.985 4269.70 6413.47 62.830 47.240 3717.99 3871.62 2647.68 N 3464.71 E 5914633.60 N 464556.71 E 0.057 4352.98 6510.03 62.880 47.190 3762.04 3915.67 2706.05 N 3527.77 E 5914691.64 N 464620.07 E 0.069 4438.85 6605.48 63.200 47.140 3805.32 3958.95 2763.89 N 3590.16 E 5914749.16 N 464682.76 E 0.338 4523.87 6702.47 64.010 48.460 3848.43 4002.06 2822.24 N 3654.52 E 5914807.18 N 464747.41 E 1.478 4610.72 6800.26 63.740 48.210 3891.49 4045.12 2880.61 N 3720.11 E 5914865.21 N 464813.30 E 0.359 4698.51 6898.08 64.820 49.870 3933.95 4087.58 2938.37 N 3786.66 E 5914922.63 N 464880.15 E 1.886 4786.63 6989.99 64.600 50.310 3973.21 4126.84 2991.69 N 3850.40 E 5914975.62 N 464944.17 E 0.495 4869.72 7087.16 63.840 50.360 4015.47 4169.10 3047.54 N 3917.76 E 5915031.12 N 465011.81 E 0.784 4957.20 7184.45 63.430 50.610 4058.68 4212.31 3103.01 N 3985.01 E 5915086.24 N 465079.34 E 0.480 5044.35 7280.79 63.100 51.320 4102.02 4255.65 3157.19 N 4051.84 E 5915140.08 N 465146.45 E 0.742 5130.35 7370.20 62.460 50.500 4142.92 4296.55 3207.32 N 4113.55 E 5915189.90 N 465208.42 E 1.085 5209.83 7471.67 62.790 49.480 4189.57 4343.20 3265.26 N 4182.56 E 5915247.47 N 465277.73 E 0.950 5299.92 7567.63 62.800 49.830 4233.44 4387.07 3320.51 N 4247.61 E 5915302.39 N 465343.06 E 0.325 5385.26 7665.43 62.830 47.090 4278.13 4431.76 3378.19 N 4312.72 E 5915359.74 N 465408.46 E 2.492 5472.24 7759.44 62.380 46.980 4321.39 4475.02 3435.08 N 4373.79 E 5915416.31 N 465469.83 E 0.490 5555.65 7856.59 62.510 46.260 4366.33 4519.96 3494.23 N 4436.39 E 5915475.14 N 465532.74 E 0.671 5641.69 7953.18 62.460 46.040 4410.95 4564.58 3553.58 N 4498.17 E 5915534.17 N 465594.82 E 0.209 5727.23 8045.91 62.390 45.540 4453.88 4607.51 3610.89 N 4557.09 E 5915591.18 N 465654.03 E 0.484 5809.27 8144.72 63.570 46.130 4498.77 4652.40 3672.22 N 4620.23 E 5915652.18 N 465717.49 E 1.307 5897.14 8240.84 63.510 45.850 4541.60 4695.23 3732.01 N 4682.12 E 5915711.65 N 465779.68 E 0.268 5983.06 8333.65 63.430 48.160 4583.06 4736.69 3788.63 N 4742.85 E 5915767.96 N 465840.70 E 2.229 6066.02 8431.41 64.290 48.920 4626.13 4779.76 3846.73 N 4808.62 E 5915825.72 N 465906.77 E 1.123 6153.77 - ------ 7 September, 2001 - 10:34 Page 3 of 5 DrillQuest 2.00.08.005 Sperry-Sun Drilling Services Survey Report for 2N-304 MWD Your Ref: A PI50 1 032038200 Job No. AKMM11122, Surveyed: 11 August, 2001 . North Slope, Alaska Kuparuk River Unit Kuparuk 2N Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azlm. Depth Depth Northlngs EBetlngs Northlngs EBetlngs Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) CO/100ft) 8529.49 63.340 49.760 4669.41 4823.04 3904.08 N 4875.38 E 5915882.72 N 465973.83 E 1.236 6241.79 8622.47 60.990 49.070 4712.82 4866.45 3957.56 N 4937.82 E 5915935.89 N 466036.54 E 2.611 6324.00 -- 8721.69 59.390 49.300 4762.14 4915.77 4013.83 N 5002.98 E 5915991.82 N 466101.98 E 1.625 6410.09 8817.53 57.430 50.870 4812.35 4965.98 4066.22 N 5065.58 E 5916043.88 N 466164.86 E 2.476 6491.71 8914.06 56.070 50.830 4865.27 5018.90 4117.19 N 5128.18 E 5916094.53 N 466227.72 E 1.409 6572.40 9010.00 49.370 52.330 4923.35 5076.98 4164.63 N 5187.93 E 5916141.66 N 466287.71 E 7.093 6648.63 9107.09 45.020 52.360 4989.31 5142.94 4208.14 N 5244.31 E 5916184.88 N 466344.31 E 4.480 6719.74 9202.62 42.530 49.310 5058.29 5211.92 4249.83 N 5295.56 E 5916226.31 N 466395.77 E 3.416 6785.79 9298.24 41.340 48.350 5129.42 5283.05 4291.89 N 5343.66 E 5916268.12 N 466444.09 E 1.414 6849.68 9394.54 40.930 48.320 5201.95 5355.58 4334.00 N 5390.99 E 5916309.99 N 466491.64 E 0.426 6913.02 9491.45 40.020 47.950 5275.67 5429.30 4375.98 N 5437.83 E 5916351.73 N 466538.70 E 0.971 6975.92 9587.21 39.170 48.470 5349.46 5503.09 4416.66 N 5483.34 E 5916392.17 N 466584.41 E 0.953 7036.94 9682.40 37.490 47.620 5424.13 5577.76 4456.12 N 5527.24 E 5916431.40 N 466628.52 E 1.850 7095.96 9778.14 37.410 47.220 5500.13 5653.76 4495.51 N 5570.11 E 5916470.57 N 466671.59 E 0.267 7154.15 9874.59 36.490 44.940 5577.22 5730.85 4535.71 N 5611.88 E' 5916510.56 N 466713.56 E 1.711 7212.03 9969.04 35.570 44.320 5653.60 5807.23 4575.24 N 5650.91 E 5916549.89 N 466752.79 E 1.048 7267.40 10052.00 35.570 44.320 5721.08 5874.71 4609.77 N 5684.62 E 5916584.24 N 466786.69 E 0.000 7315.48 Projected Survey , All data is in Feet (US) unless otherwise stated. Directions and coordinates are relative to True North. ---- Vertical depths are relative to AKB (153.63' MSL). Northings and Eastings are relative to 2' FNL & 514' FEL. Magnetic Declination at Surface is 25.608° (13-Aug-01) The Dogleg Severity is in Degrees per 100 feet (US). Vertical Section is from ST @ 3030' MD and calculated along an Azimuth of 49.235° (True): Based upon Minimum Curvature type calculations, at a Measured Depth of 10052.000., The Bottom Hole Displacement is 7318.80ft., in the Direction of 50.961° (True). -_.h__. -.- - . --~- .----------------.---- 7 September, 2001 - 10:34 Page 4 of 5 DrlllQuest 2.00.08.005 Kuparuk River Unit Comments ~~" Measured Depth (ft) 2885.51 10052.00 Sperry-Sun Drilling Services Survey Report for 2N-304 MWD Your Ref: A PI5o 1 032038200 Job No. AKMM11122, Surveyed: 11 August, 2001 Station Coordinates TVD Northings Eastings (ft) (ft) (ft) 2288.17 5874.71 617.16 N 4609.77 N Survey tool program for 2N-3O4 MWD From Measured Vertical Depth Depth (ft) (ft) 0.00 546.00 ~- ---- ._-- ..~--- 7 September, 2001 - 10:34 0.00 545.57 To Measured Vertical Depth Depth (ft) (ft) Comment 1061.31 E 5684.62 E Tie On Point Projected Survey Survey Tool Description 546.00 10052.00 545.57 Tolerable Gyro (2N-304PB1Gyro) 5874.71 MWD Magnetic (2N-304MWDPB1) . - -...- --- Page 5 of 5 . North Slope, Alaska Kuparuk 2N -~_. -_u_.-... DrlllQuest 2.00.08.005 ( ( ~DJ~/3/) 07-Sep-01 AOGCC 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 Definative Surveys Re: Distribution of Survey Data for Well 2N-304 Dear Dear Sir/Madam: Enclosed are two survey hard copies and 1 disk Tie-on Survey: 2,885.51 ' MD Window / Kickoff Survey , MD Projected Survey: 10,052.00' MD (if applicable) Please call me at 273-3545 if you have any questions or concerns. Regards, William T. Allen Survey Manager Attachment(s) RECEIVED SEP 1 2 2001 Alaska Oíl &. Gas Cons. Commission Anchorage .. . .. ..' Kuparuk River Unit North Slope, Alaska Kuparuk 2N, Slot 2N-304 2N-304 Job No. AKZZ11122, Surveyed: 11 August, 2001 SURVEY REPORT 7 September, 2001 DEFINITIVE .-, Your Ref: API1032038200 Surface Coordinates: 5912003.77 N, 461078.43 E (70010' 13.9335" N, 150018' 47.6898" W) Kelly Bushing: 153. 63ft above Mean Sea Level 55 P ar r Y - 5 U .., . DFtILCING 'seA. vices A Halliburton Company ~. Survey Ref: svy9613 '" .. Sperry-Sun Drilling Services Survey Report for 2N-304 Your Ref: API1032038200 Job No. AKZZ11122, Surveyed: 11 August, 2001 . North Slope, Alaska Kuparuk River Unit Kuparuk 2N Measured Sub-Sea Vertical . Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (°/1 OOft) 2885.51 68.310 47.860 2134.54 2288.17 610.33 N 1066.90 E 5912608.60 N 462148.45 E 1206.58 Tie On Point -.. 2939.00 65.670 49.920 2155.45 2309.08 642.70 N 1103.98 E 5912640.79 N 462185.70 E 6.076 1255.81 2960.55 64.620 50.770 2164.51 2318.14 655.18 N 1119.03 E 5912653.19 N 462200.82 E 6.046 1275.36 3058.15 59.380 54.820 2210.33 2363.96 707.31 N 1187.58 E 5912704.97 N 462269.63 E 6.498 1361.31 3151.04 60.460 60.540 2256.91 241 0.54 750.24 N 1255.48 E 5912747.55 N 462337.75 E 5.453 1440.77 3245.34 60.410 58.730 2303.44 2457.07 791.70 N 1326.24 E 5912788.64 N 462408.73 E 1.670 1521.44 3342.47 62.390 56.960 2349.94 2503.57 837.10 N 1398.43 E 5912833.66 N 462481.14 E 2.591 1605.75 3436.61 63.800 54.470 2392.54 2546.17 884~39 N 1467.77 E 5912880.60 N 462550.73 E 2.794 1689.15 3526.12 65.840 52.510 2430.63 2584.26 932.59 N 1532.87 E 5912928.46 N 462616.07 E 3.020 1769.92 3629.32 66.350 51.140 2472.45 2626.08 990.90 N 1607.03 E 5912986.39 N 462690.54 E 1.310 1864.17 3725.33 66.190 50.100 2511.09 2664.72 1046.66 N 1674.97 E 5913041.80 N 462758.76 E 1.006 1952.04 3821.29 66.370 49.690 2549.69 2703.32 11 03.26 N 1742.16 E 5913098.05 N 462826.24 E 0.434 2039.88 3917.14 64.720 50.630 2589.37 2743.00 1159.15 N 1809.15 E 5913153.60 N 462893.52 E 1.939 2127.12 4014.55 63.130 48.970 2632.18 2785.81 1215.62 N 1875.98 E 5913209.72 N 462960.64 E 2.238 2214.60 4109.79 62.690 48.710 2675.56 2829.19 1271.42 N 1939.82 E 5913265.20 N 463024.76 E 0.522 2299.39 4206.73 62.990 48.040 2719.81 2873.44 1328.72 N 2004.29 E 5913322.16 N 463089.53 E 0.688 2385.63 4302.89 62.470 47.790 2763.87 2917.50 1386.00 N 2067.72 E 5913379.12 N 463153.25 E 0.588 2471.08 4398.26 62.800 47.500 2807.70 2961.33 1443.07 N 2130.31 E 5913435.86 N 463216.14 E 0.439 2555.75 ,-.. 4493.09 62.820 47.140 2851.04 3004.67 1500.25 N 2192.32 E 5913492.72 N 463278.44 E 0.338 2640.05 4590.58 63.040 46.000 2895.40 3049.03 1559.93 N 2255.36 E 5913552.08 N 463341.79 E 1.065 2726.77 4686.87 62.950 45.680 2939.12 3092.75 1619.69 N 2316.91 E 5913611.53 N 463403.64 E 0.310 2812.41 4783.51 63.580 49.320 2982.61 3136.24 1677.98 N 2380.53 E 5913669.49 N 463467.56 E 3.426 2898.65 4879.15 63.440 48.610 3025,27 3178.90 1734.18 N 2445.10 E 5913725.35 N 463532.42 E 0.680 2984.25 4975.42 63.080 48.350 3068.59 3222.22 1791.17 N 2509.47 E 5913782.01 N 463597.08 E 0.445 3070.22 5071 .13 63.230 48.250 3111.81 3265.44 1847.98 N 2573.23 E 5913838.49 N 463661.13 E 0.182 3155.60 5166.51 63.600 47.210 3154.49 3308.12 1905.35N 2636.35 E 5913895.53 N 463724.54 E 1.049 3240.87 5262.79 63.670 47.250 3197.25 3350.88 1963.93 N 2699.67 E 5913953.79 N 463788.17 E 0.082 3327.08 5360.11 63.890 46.680 3240.25 3393.88 2023.51 N 2763.49 E 5914013.04 N 463852.29 E 0.572 3414.32 5455.35 64.600 47.980 3281.63 3435.26 2081.64 N 2826.56 E 5914070.85 N 463915.66 E 1.438 3500.04 5553.02 65.080 47.080 3323.16 3476.79 2141.33 N 2891.77 E 5914130.20 N 463981.17E 0.968 3588.41 7 September, 2001 - 9:54 Page 2 of 5 DrlllQuest 2.00.08.005 .. Sperry-Sun Drilling Services Survey Report for 2N-304 Your Ref: AP/1032038200 Job No. AKZZ11122, Surveyed: 11 August, 2001 . North Slope, Alaska Kuparuk River Unit Kuparuk 2N Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) e/1 OOft) 5649.01 64.550 49.150 3364.01 3517.64 2199.33 N 2956.43 E 5914187.86 N 464046.13 E 2.028 3675.25 ~~-, 5745.12 63.080 50.520 3406.42 3560.05 2254.96 N 3022.33 E 5914243.15 N 464112.32 E 1.994 3761.49 5841. 77 62.810 50.100 3450.38 3604.01 2309.93 N 3088.56 E 5914297.78 N 464178.83 E 0.477 3847.54 5935.94 62.330 49.650 3493.76 3647.39 2363.79 N 3152.47 E 5914351 .32 N 464243.02 E 0.663 3931.12 6033.13 61.510 49.490 3539.51 3693.14 2419.40 N 3217.75 E 5914406.59 N 464308.58 E 0.856 4016.87 6127.92 61.620 48.480 3584.65 3738.28 2474.10N 3280.64 E 5914460.97 N 464371.75 E 0.944 4100.22 6221.99 61.390 48.570 3629.52 3783.15 2528.86 N 3342.58 E 5914515.40 N 464433.97 E 0.259 4182.89 6319.83 62.880 47.210 3675.25 3828.88 2586.86 N 3406.74 E 5914573.07 N 464498.43 E 1.957 4269.35 6413.47 62.830 47.220 3717.98 3871.61 2643.46 N 3467.89 E 5914629.36 N 464559.87 E 0.054 4352.63 6510.03 62.880 47.030 3762.03 3915.66 2701.92 N 3530.86 E 5914687.49 N 464623.14 E 0.183 4438.50 6605.48 63.200 46.910 3805.31 3958.94 2759.97 N 3593.05 E 5914745.23 N 464685.63 E 0.353 4523.51 6702.47 64.010 48.290 3848.42 4002.05 2818.55 N 3657.21 E 5914803.48 N 464750.09 E 1.524 4610.35 6800.26 63.740 48.050 3891 .48 4045.11 2877.11 N 3722.63 E 5914861.69 N 464815.81 E 0.353 4698.13 6898.08 64.820 49.900 3933.94 4087.57 2934.94 N 3789.12 E 5914919.19 N 464882.59 E 2.030 4786.25 6989.99 64.600 50.200 3973.20 4126.83 2988.31 N 3852.82 E 5914972.22 N 464946.57 E 0.380 4869.34 7087.16 63.840 50.250 4015.46 4169.09 3044.28 N 3920.07 E 5915027.85 N 465014.11 E 0.784 4956.83 7184.45 63.430 50.670 4058.67 4212.30 3099.78N 3987.29 E 5915083.00 N 465081.61 E 0.572 5043.98 7280.79 63.100 51.290 4102.01 4255.64 3153.95 N 4054.14 E 5915136.83 N 465148.74 E 0.669 5129.98 .-.... 7370.20 62.460 50.740 4142.91 4296.54 3203.97 N 4115.94 E 5915186.53 N 465210.80 E 0.901 5209.45 7471.67 62.790 49.780 4189.56 4343.19 3261.57 N 4185.23 E 5915243.78 N 465280.38 E 0.901 5299.54 7567.63 62.800 50.000 4233.43 4387.06 3316.56 N 4250.50 E 5915298.42 N 465345.93 E 0.204 5384.88 7665.43 62.830 47.200 4278.12 4431.75 3374.08 N 4315.75 E 5915355.61 N 465411.47 E 2.547 5471.86 7759.44 62.380 47.070 4321.38 4475.01 3430.86 N 4376.93 E 5915412.08 N 465472.94 E 0.494 5555.27 7856.59 62.510 46.350 4366.32 4519.95 3489.92 N 4439.62 E 5915470.81 N 465535.94 E 0.671 5641.31 7953.18 62.460 45.950 4410.94 4564.57 3549.27 N 4501.40 E 5915529.84 N 465598.02 E 0.371 5726.85 8045.91 62.390 45.460 4453.87 4607.50 3606.67 N 4560.23 E 5915586.94 N 465657.15 E 0.474 5808.89 8144.72 63.570 46.070 4498.76 4652.39 3668.07 N 4623.30 E 5915648.01 N 465720.53 E 1.315 5896.75 8240.84 63.510 45.580 4541 .59 4695.22 3728.04 N 4685.01 E 5915707.66 N 465782.56 E 0.461 5982.65 8333.65 63.430 47.750 4583.05 4736.68 3785.02 N 4745.41 E 5915764.33 N 465843.24 E 2.094 6065.60 8431.41 64.290 48.650 4626.12 4779.75 3843.51 N 4810.83 E 5915822.49 N 465908.96 E 1.207 6153.34 7 September, 2001 - 9:55 Page 3 of 5 DrlllQuest 2.00.08.005 . .. .. Sperry-Sun Drilling Services Survey Report for 2N-304 Your Ref: AP/1032038200 Job No. AKZZ11122, Surveyed: 11 August, 2001 . . North Slope, Alaska Kuparuk River Unit Kuparuk 2N Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (o/100ft) 8529.49 63.340 49.430 4669.40 4823.03 3901.21 N 4877.29 E 5915879.84 N 465975.72 E 1.203 6241.36 .~. 8622.47 60.990 48.970 4712.81 4866.44 3954.92 N 4939.53 E 5915933.24 N 466038.24 E 2.565 6323.57 8721.69 59.390 49.220 4762.13 4915.76 4011.30 N 5004.60 E 5915989.27 N 466103.59 E 1.627 6409.66 8817.53 57.430 50.770 4812.34 4965.97 4063.78 N 5067.12E 5916041.44 N 466166.38 E 2.466 6491.28 8914.06 56.070 50.790 4865.26 5018.89 4114.82 N 5129.66 E 5916092.16 N 466229.18 E 1 .409 6571.98 9010.00 49.370 52.500 4923.34 5076.97 4162.20 N 5189.45 E 5916139.23 N 466289.22 E 7.126 6648.20 9107.09 45.020 52.450 4989.30 5142.93 4205.58 N 5245.93 E 5916182.32 N 466345.92 E 4.481 6719.30 9202.62 42.530 49.41 0 5058.28 5211.91 4247.19 N 5297.25 E 5916223.66 N 466397.45 E 3.411 6785.34 9298.24 41 .340 48.530 5129.41 5283.04 4289.13 N 5345.46 E 5916265.36 N 466445.88 E 1.388 6849.24 9394.54 40.930 48.510 5201.94 5355.57 4331.09 N 5392.92 E 5916307.07 N 466493.55 E 0.426 6912.59 9491.45 40.020 48.250 5275.66 5429.29 4372.87 N 5439.94 E 5916348.61 N 466540.79 E 0.955 6975.48 9587.21 39.170 48.500 5349.45 5503.08 4413.42 N 5485.57 E 5916388.91 N 466586.62 E 0.903 7036.51 9682.40 37.490 47.710 5424.12 5577.75 4452.83 N 5529.51 E 5916428.10 N 466630.77 E 1.838 7095.53 9778.14 37.410 47.040 5500.12 5653.75 4492.25 N 5572.35 E 5916467.31 N 466673.81 E 0.434 7153.72 9874.59 36.490 44.620 5577.21 5730.84 4532.63 N 5613.94 E 5916507.47 N 466715.60 E 1.784 7211.58 9969.04 35.570 44.1 00 5653.59 5807.22 4572.35 N 5652.78 E 5916546.99 N 466754.65 E 1.026 7266.94 10052.00 35.570 44.1 00 5721.07 5874.70 4607.01 N 5686.36 E 5916581.47 N 466788.41 E 0.000 7315.00 Projected Survey ,~.~ All data is in Feet (US) unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to AKB (153.63' MSL). Northings and Eastings are relative to 2' FNL & 514' FEL. Magnetic Declination at Surface is 25.609° (13-Aug-01) The Dogleg Severity is in Degrees per 100 feet (US). Vertical Section is from 2' FNL & 514' FEL and calculated along an Azimuth of 49~235° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 10052.00ft., The Bottom Hole Displacement is 7318.42ft., in the Direction of 50.986° (True). 7 September, 2001 - 9:55 Page 4 of 5 DrillQuest 2.00.08.005 # I- - I. Kuparuk River Unit Comments Measured Depth (ft) 2885.51 10052.00 Sperry-Sun Drilling Services Survey Report for 2N-3O4 Your Ref: API1032038200 Job No. AKZZ11122, Surveyed: 11 August, 2001 . 610.33 N 4607.01 N Survey tool program for 2N-3O4 North Slope, Alaska Kuparuk 2N Station Coordinates TVD Northings Eastings (ft) (ft) (ft) 2288.17 5874.70 Fro m Measured Vertical Depth Depth (ft) (ft) '. 0.00 546.00 0.00 545.57 To Measured Vertical Depth Depth eft) (ft) Comment --- 1066.90 E 5686.36 E Tie On Point Projected Survey Survey Tool Description 546.00 10052.00 545.57 Tolerable Gyro (2N-304PB1Gyro) 5874.70 AK-6 BP _IFR-AK (2N-304PB1) ---. 7 September, 2001 - 9:55 Page 5 of 5 DrlllQuest 2.00.08.005 Date 08/24/01 08/25/01 11/11/01 11/12/01 11/17/01 11/19/01 11/22/01 12/02/01 f 2N-304 Event History ( Comment TAGGED FILL @ 9891' WL. DRIFTED TBG W/ 22' X 2.65" DUMMY GUN TO 9650' WLM. IN PROGRESS. [TAG] REPLACED SOY W/ DV @ 9182' RKB, PT TBG & CASING TO 3000# HELD [GLV, PT TBG-CSG] PERFORMED A FCO TO PBTD OF 9898.3' CTMD. SWEPT WITH 20 BBLS DIESEL GEL. THREE TUBING VOLUME'S OF SLICK SEA WATER. WELL FREEZE PROTECTED TO 2500'. WELL TO REMAIN ON STay FOR CONTINUATION OF PRODUCTION PREP WORK. [FCO] INITIAL PERFORATIONS COMPLETED 9592'-9602' W/2.5" HSD @ 4 SPF - 35B UP, RDX CHARGES (BIGHOLE) - 180 PHASED - 45/225 DEGS ORIENTED. PRESSURED WELL TO 4000 PSI PRIOR TO SHOT. OBTAINED JEWELRY LOG. OBTAINED SBHP OF 2490 PSI @ 9597'. [PERF, PRESSURE DATA] PUMPED INITIAL FRAC JOB. PLACED 219M# 12/18 PROPPANT BEHIND PIPE, 10 PPA AT PERFS. SAW TSO DURING 4 PPA FLAT STAGE. GOT 57 BBLS FLUSH AWAY, -10 BBLS DIESEL INTO WELL, HAD NWBSO. PLACED 97% OF DESIGN, LEFT 8M# IN WELLBORE. [FRAC-REFRAC] PERFORMED A FCO TO 9889.2' CTMD. WASHED MANDRELLS ON WAY OUT OF HOLE. WELL FREEZE PROTECTED TO 5500'. RETURNS <1-1 LOSS OF 1 BBL PER 10 PUMPED, WITH PERFS OPEN WHILE ON SLICK SEA WATER. WHEN PUMPING SLICK DIESEL RETURNS 1-1. [FCO] TAGGED FILL @ 9324' RKB. EST. 278' FILL. INSTALLED 5/16"OV @ 9182' RKB. [TAG, GLV] PERFORMED A FCO TO 9887.1' CTMD. RETURNS 1-1 UNTIL PREFS WERE OPENED. LOST 20 BBLS WHILE ATTEMPTING TO REGAIN RETURNS. UTILIZED 110 BBLS OF DIESEL GEL FOR SAND LIFT. APPEARS SAND FELL OUT OF GEL AROUND 4800'. PULLING OVERWEIGHT IN THIS AREA. Page 1 of 1 12/17/2001 (' AOGCC 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 Definative Surveys Re: Distribution of Survey Data for Well 2N-304PB1 Dear Dear Sir/Madam: Enclosed are two survey hard copies and 1 disk Tie-on Survey: 546.00' MD Window / Kickoff Survey , MD Projected Survey: 10,415.00' MD (if applicable) ( ~O/-IW 07-Sep-01 Please call me at 273-3545 if you have any questions or concerns. Regards, William T. Allen Survey Manager Attachment(s) RECEIVED SEP 12 2001 Alaska Oil & Gas Cons. CommÌ98iOn Anchorage DEFINITIVE Kuparuk River Unit North Slope, Alaska Kuparuk 2N, Slot 2N-304 2N-304PB 1 Job No.AKZZ11122, Surveyed: 22 July, 2001 -, SURVEY REPORT 7 September, 2001 Your Ref: API501032038270 Surface Coordinates: 5912003.77 N, 461078.43 E (700 10' 13.9335" N, 1500 18' 47.6898" W) Kelly Bushing: 153.63ft above Mean Sea Level .-- spar'r'Y-5UI'l DRILLING seRVIc:es A Halliburton Company Survey Ref: svy9612 Sperry-Sun Drilling Services Survey Report for 2N-304PB1 Your Ref: AP/501032038270 Job No.AKZZ11122~ Surveyed: 22 Ju/y~ 2001 . North Slope, Alaska Kuparuk River Unit Kuparuk 2N Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (°/1 OOft) 546.00 5.100 123.000 391.94 545.57 10.93 S 10.47 E 5911992.79 N 461088.84 E 1.26 Tie On Point -~" AK-6 BP _IFR-AK 651.41 5.460 122.000 496.90 650.53 16.14 S 18.65 E 5911987.54 N 461096.99 E 0.352 4.34 745.40 6.870 114.130 590.34 743.97 20.81 S 27.57 E 5911982.82 N 461105.89 E 1.746 8.34 836.35 8.340 105.200 680.49 834.12 24.76 S 38.90 E 5911978.81 N 461117.20 E 2.069 14.65 933.48 12.200 96.720 776.06 929.69 27.81 S 55.90 E 5911975.67 N 461134.19 E 4.258 25.95 1022.89 14.710 90.900 863.01 1016.64 29.09 S 76.64 E 5911974.28 N 461154.92 E 3.186 41.26 1114.83 16.890 89.900 951.47 1105.10 29.25 S 101.67 E 5911973.99 N 461179.94 E 2.389 60.61 1208.85 19.600 91.830 1040.76 1194.39 29.73 S 131.09 E 5911973.36 N 461209.37 E 2.953 83.18 1300.56 20.440 93.660 1126.92 1280.55 31.25 S 162.45 E 5911971.69 N 461240.72 E 1.143 106.59 1395.28 19.670 85.940 1215.92 1369.55 31.17 S 194.86 E 5911971.59 N 461273.13 E 2.908 131.83 1488.90 21.890 77.890 1303.46 1457.09 26.40 S 227.65 E 5911976.20 N 461305.94 E 3.859 160.33 1580.98 26.370 70.740 1387.49 1541.12 16.04 S 263.77 E 5911986.37 N 461342.11 E 5.801 194.91 1675.66 30.610 64.71 0 1470.70 1624.33 1.20 N 305.44 E 5912003.40 N 461383.87 E 5.406 238.15 1773.82 35.280 61.120 1553.06 1706.69 25.59 N 352.89 E 5912027.54 N 461431.44 E 5.155 290.37 1867.34 39.730 57.620 1627.24 1780.87 54.65 N 401.81 E 5912056.36 N 461480.51 E 5.274 346.68 1961.54 44.290 54.510 1697.22 1850.85 89.89 N 454.04 E 5912091.33 N 461532.93 E 5.320 409.45 2054.16 48.880 53.060 1760.86 1914.49 129.66 N 508.29 E 5912130.81 N 461587.38 E 5.084 476.63 2150.80 53.050 52.240 1821.71 1975.34 175.20 N 567.94 E 5912176.05 N 461647.26 E 4.365 551.65 ~- 2244.53 57.630 50.840 1875.01 2028.64 223.16 N 628.27 E 5912223.69 N 461707.84 E 5.038 628.72 2337.35 62.270 49.090 1921.48 2075.11 274.84 N 689.75 E 5912275.06 N 461769.58 E 5.258 709.02 2435.80 65.170 48.470 1965.06 2118.69 333.01 N 756.14 E 5912332.89 N 461836.27 E 2.999 797.22 2527.05 68.190 48.41 0 2001.18 2154.81 388.59 N 818.83 E 5912388.15 N 461899.25 E 3.310 880.92 2621.48 67.730 48.800 2036.62 2190.25 446.47 N 884.49 E 5912445.69 N 461965.21 E 0.620 968.37 2715.15 68.320 47.690 2071.67 2225.30 504.32 N 949.29 E 5912503.20 N 462030.30 E 1.267 1055.14 2808.88 68.370 48.170 2106.26 2259.89 562.69 N 1013.96 E 5912561.24 N ~ 462095.27 E 0.479 1142.13 2885.51 68.310 47.860 2134.54 2288.17 610.33 N 1066.90 E 5912608.60 N 462148.45 E 0.384 1213.25 3013.82 68.510 47.520 2181.75 2335.38 690.64 N 1155.12 E 5912688.46 N 462237.09 E 0.292 1332.35 3111.68 69.370 47.100 2216.92 2370.55 752.56 N 1222.25 E 5912750.04 N 462304.53 E 0.966 1423.49 3207.44 68.980 47.510 2250.96 2404.59 813.25 N 1288.03 E 5912810.39 N 462370.63 E 0.571 1512.80 3301.12 68.510 48.390 2284.92 2438.55 871.73 N 1352.86 E 5912868.53 N 462435.76 E 1.009 1599.99 7 September, 2001 - 9:04 Page 2 of 6 DrlllQuest 2.00.08.005 Sperry-Sun Drilling Services Survey Report for 2N-304PB1 Your Ref: API501032038270 Job No. AKZZ11122!! Surveyed: 22 July!! 2001 . North Slope, Alaska Kuparuk River Unit Kuparuk 2N Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings. Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) CO/100ft) 3398.15 67.370 48.070 2321.37 2475.00 931.63 N 1419.93 E 5912928.09 N 462503.13 E 1.214 1689.81 ._." 3495.73 65.900 48.590 2360.06 2513.69 991.19 N 1486.84 E 5912987.30 N 462570.35 E 1.584 1779.28 3591.88 63.460 49.690 2401.18 2554.81 1048.05 N 1552.56 E 5913043.82 N 462636.36 E 2.740 1866.14 3686.87 63.320 50.450 2443.73 2597.36 1102.56 N 1617.69 E 5913097.99 N 462701.77 E 0.730 1951.06 3782.95 63.050 50.210 2487.07 2640.70 1157.30 N 1683.69 E 5913152.39 N 462768.05 E 0.359 2036.80 3879.00 63.790 50.310 2530.05 2683.68 1212.21 N 1749.74 E 5913206.97 N 462834.38 E 0.776 2122.69 3974.98 64.630 50.070 2571.81 2725.44 1267.54 N 1816.13 E 5913261.95 N 462901.05 E 0.904 2209.10 4071 .37 64.020 48.840 2613.57 2767.20 1324.01 N 1882.14 E 5913318.08 N 462967.35 E 1.313 2295.94 4167.19 64.760 48.440 2654.99 2808.62 1381.11 N 1946.99 E 5913374.84 N 463032.50 E 0.859 2382.27 4265.94 63.060 49.560 2698.42 2852.05 1439.29 N 2013.92 E 5913432.68 N 463099.72 E 2.000 2470.90 4358.68 63.180 49.330 2740.35 2893.98 1493.07 N 2076.77 E 5913486.14 N 463162.85 E 0.256 2553.59 4454.03 64.000 49.510 2782.76 2936.39 1548.63 N 2141.63 E 5913541 .36 N 463227.99 E 0.876 2638.95 4550.62 64.820 49.290 2824.48 2978.11 1605.32 N 2207.77 E 5913597.71 N 463294.43 E 0.873 2726.03 4647.33 63.950 49.300 2866.29 3019.92 1662.19 N 2273.88 E 5913654.24 N 463360.83 E 0.900 2813.20 4744.20 64.220 48.950 2908.62 3062.25 1719.21 N 2339.76 E 5913710.92 N 463427.00 E 0.428 2900.28 4841.81 65.180 48.770 2950.34 3103.97 1777.27 N 2406.22 E 5913768.64 N 463493.76 E 0.998 2988.47 4935.28 65.980 48.640 2988.98 3142.61 1833.43 N 2470.16 E 5913824.47 N 463557.99 E 0.865 3073.50 5032.74 . 64.700 48.800 3029.64 3183.27 1891.87 N 2536.72 E 5913882.56 N 463624.85 E 1.322 3162.00 5129.95 63.180 48.960 3072.35 3225.98 1949.29 N 2602.50 E 5913939.65 N 463690.92 E 1.571 3249.27 .-~- 5224.54 63.400 49.130 3114.86 3268.49 2004.68 N 2666.32 E 5913994.71 N 463755.02 E 0.283 3333.72 5324.71 64.210 49.000 3159.08 3312.71 2063.57 N 2734.22 E 5914053.25 N 463823.23 E 0.817 3423.54 5418.43 65.190 48.670 3199.13 3352.76 2119.34 N 2798.00 E 5914108.69 N 463887.30 E 1.093 3508.21 5515.20 65.980 49.610 3239.13 3392.76 2176.99 N 2864.65 E 5914165.99 N 463954.23 E 1.204 3596.28 5610.61 64.170 48.930 3279.34 3432.97 2233.44 N 2930.21 E 5914222.11 N 464020.09 E 2.004 3682.76 5707.01 64.430 48.630 3321.14 3474.77 2290.67 N 2995.55 E 5914279.01 N 464085.72 E 0.389 3769.56 5803.01 65.510 48.810 3361.76 3515.39 2348.06 N 3060.92 E 5914336.06 N 464151.38 E 1.138 3856.47 5899.22 66.510 49.200 3400.88 3554.51 2405.72 N 3127.26 E 5914393.37 N 464218.02 E 1.103 3944.32 5997.11 64.840 48.990 3441 .20 3594.83 2464.13 N 3194.68 E 5914451.43 N 464285.74 E 1.717 4033.46 6089.84 63.380 49.200 3481.69 3635.32 2518.75 N 3257.72 E 5914505.73 N 464349.07 E 1.588 4116.84 6188.30 64.130 50.340 3525.23 3678.86 2575.78 N 3325.14 E 5914562.42 N 464416.78 E 1.288 4205.12 7 September!! 2001 - 9:04 Page 3 of 6 DrillQuest 2.00.08.005 . Sperry-Sun Drilling Services Survey Report for 2N-304PB1 Your Ref: API501032038270 Job No. AKZZ11122, Surveyed: 22 July, 2001 . North Slope, Alaska Kuparuk River Unit Kuparuk 2N Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (°/1 OOft) 6285.77 64.490 50.240 3567.48 3721.11 2631.90 N 3392.72 E 5914618.19 N 464484.64 E 0.381 4292.95 ,---- 6379.91 65.230 50.650 3607.47 3761.10 2686.17 N 3458.42 E 5914672.12 N 464550.62 E 0.879 4378.17 6477.25 63.450 49.480 3649.62 3803.25 2742.48 N 3525.70 E 5914728.08 N 464618.19 E 2.125 4465.89 6573.12 62.840 49.510 3692.93 3846.56 2798.04 N 3590.73 E 5914783.30 N 464683.51 E 0.637 4551.39 6668.78 63.800 49.340 3735.88 3889.51 2853.63 N 3655.65 E 5914838.56 N 464748.71 E 1.016 4636.84 6764.50 64.550 48.950 3777.58 3931.21 2909.99 N 3720.82 E 5914894.59 N 464814.17 E 0.865 4722.95 6861.21 64.560 48.900 3819.13 3972.76 2967.37 N 3786.66 E 5914951.63 N. 464880.30 E 0.048 4810.22 6954.97 65.290 48.930 3858.87 4012.50 3023.18 N 3850.66 E 5915007.11 N 464944.59 E 0.779 4895.09 7049.25 64.180 49.450 3899.11 4052.74 3078.91 N 3915.19 E 5915062.50 N 465009.41 E 1.279 4980.30 7149.95 64.150 49.480 3942.99 4096.62 3137.81 N 3984.08 E 5915121.05 N 465078.59 E 0.040 5070.91 7242.82 64.980 49.540 3982.88 4136.51 3192.27 N 4047.86 E 5915175.18 N 465142.66 E 0.896 5154.75 7339.36 65.920 49.470 4022.99 4176.62 3249.29 N 4114.64 E 5915231.86 N 465209.73 E 0.976 5242.53 7436.64 65.320 50.040 4063.14 4216.77 3306.54 N 4182.27 E 5915288.75 N 465277.65 E 0.816 5331.11 7531.78 64.890 50.320 4103.19 4256.82 3361.80 N 4248.55 E 5915343.68 N 465344.22 E 0.525 5417.40 7628.01 65.240 50.760 4143.76 4297.39 3417.26 N 4315.92 E 5915398.78 N 465411.87 E 0.552 5504.66 7724.66 63.660 50.380 4185.45 4339.08 3472.64 N 4383.27 E 5915453.82 N 465479.51 E 1.673 5591.85 7821.75 62.620 49.520 4229.31 4382.94 3528.37 N 4449.58 E 5915509.20 N 465546.09 E 1.331 5678.45 7918.97 62.980 49.500 4273.75 4427.38 3584.51 N 4515.34 E 5915565.01 N 465612.14 E 0.371 5764.89 8015.21 63.540 49.300 4317.05 4470.68 3640.44 N 4580.59 E 5915620.61 N 465677.69 E 0.611 5850.80 .-. 8116.35 64.280 49.320 4361 .53 4515.16 3699.66 N 4649.47 E 5915679.47 N 465746.87 E 0.732 5941.60 8208.27 64.830 49.010 4401.03 4554.66 3753.94 N 4712.27 E 5915733.42 N 465809.94 E 0.671 6024.56 8307.28 63.470 48.560 4444.19 4597.82 3812.64 N 4779.30 E 5915791.78 N 465877.27 E 1.433 6113.59 8396.05 63.470 47.590 4483;85 4637.48 3865.71 N 4838.39 E 5915844.55 N 465936.63 E 0.978 6192.91 8497.00 62.690 47.490 4529.55 4683.18 3926.47 N 4904.79 E 5915904.97 N 466003.35 E 0.778 6282.75 8591.16 59.210 48.220 4575.27 4728.90 3981.71 N 4965.81 E 5915959.88 N 466064.65 E 3.757 6364.93 8687.91 58.940 48.040 4624.99 4778.62 4037.10N 5027.61 E 5916014.96 N 466126.74 E 0.321 6447.82 8782.53 56.790. 48.790 4675.31 4828.94 4090.28 N 5087.53 E 5916067.83 N 466186.93 E 2.369 6527.86 8879.66 55.610 49.230 4729.35 4882.98 4143.22 N 5148.46 E 5916120.46 N 466248.13 E 1.272 6608.52 8975.37 54.330 49.340 4784.28 4937.91 4194.35 N 5207.86 E 5916171.28 N 466307.79 E 1.341 6686.85 9070.30 53.420 49.140 4840.25 4993.88 4244.41 N 5265.94 E 5916221 .04 N 466366.13 E 0.974 6763.50 7 September, 2001 - 9:04 Page 4 of 6 Dril/Quest 2.00.08.005 ~ Sperry-Sun Drilling Services Survey Report for 2N-304PB1 Your Ref: API501032038270 Job No. AKZZ11122, Surveyed: 22 July, 2001 . North Slope, Alaska Kuparuk River Unit Kuparuk 2N Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) CO/100ft) 9162.28 52.320 49.790 4895.77 5049.40 4292.07 N 5321.67 E 5916268.41 N 466422.10 E 1.322 6836.80 ._,- 9260.60 51.390 49.900 4956.50 5110.13 4341.93 N 5380.76 E 5916317.97 N 466481.45 E 0.950 6914.11 9356.68 50.580 49.940 5016.98 5170.61 4390.00 N 5437.88 E 5916365.74 N 466538.82 E 0.844 6988.74 9453.35 49.250 50.110 5079.23 5232.86 4437.51 N 5494.56 E 5916412.96 N 466595.74 E 1.382 7062.69 9548.58 47.450 49.650 5142.51 5296.14 4483.36 N 5548.97 E 5916458.53 N 466650.39 E 1.924 7133.83 9645.53 46.400 49.070 5208.72 5362.35 4529.48 N 5602.71 E 5916504.38 N 466704.36 E 1.168 7204.62 9740.13 45.300 48.920 5274.62 5428.25 4574.02 N 5653.94 E 5916548.65 N 466755.82 E 1.168 7272.46 9834.35 44.350 49.590 5341.44 5495.07 4617.37 N 5704.25 E 5916591.74 N 466806.36 E 1.126 7338.84 9934.11 43.270 50.080 5413.43 5567.06 4661.91 N . 5757.03 E 5916636.01 N 466859.36 E 1.135 7407.89 10031.10 42.340 51.000 5484.59 5638.22 4703.80 N 5807.91 E 5916677.64 N 466910.45 E 1.155 7473.79 10126.81 41.070 51.450 5556.05 5709.68 4743.68 N 5857.54 E 5916717.26 N 466960.29 E 1.363 7537.46 10225.08 39.940 51.550 5630.76 5784.39 4783.41 N 5907.50 E 5916756.74 N 467010.45 E 1.152 7601.29 10317.96 38.900 51.010 5702.51 5856.14 4820.30 N 5953.51 E 5916793.39 N 467056.65 E 1.179 7660.26 10354.32 38.510 51.250 5730.89 5884.52 4834.57 N 5971.21 E 5916807.57 N 467074.43 E 1.149 7683.00 10415.00 38.510 51.250 5778.37 5932.00 4858.22 N 6000.68 E 5916831.06 N 467104.02 E 0.000 7720.78 Projected Survey All data is in Feet (US) unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to RKB (153.63' MSL). Northings and Eastings are relative to 2' FNL & 514' FEL. ~-. Magnetic Declination at Surface is 25.609° (13-Aug-01) The Dogleg Severity is in Degrees per 100 feet (US). Vertical Section is from 2' FNL & 514' FEL and calculated along an Azimuth of 51.006° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 10415.00ft., The Bottom Hole Displacement is 7720.78ft., in the Direction of 51.006° (True). 7 September, 2001 - 9:04 Page 5 of 6 DrlllQuest 2.00.08.005 . . \ # ', . Kuparuk River Unit Comments Measured Depth (ft) 546.00 10415.00 Sperry-Sun Drilling Services Survey Report for 2N-304PB1 Your Ref: API501032038270 Job No. AKZZ11122, Surveyed: 22 July, 2001 . 10.93 S 4858.22 N Survey tool program for 2N-304PB1 North Slope, Alaska Kuparuk 2N Station Coordinates TVD Northings Eastings (ft) (ft) (ft) 545.57 5932.00 From Measured Vertical Depth Depth (ft) (ft) 0.00 546.00 0.00 545.57 To Measured Vertical Depth Depth (ft) (ft) 546.00 10415.00 545.57 5932.00 Comment -. 10.47 E 6000.68 E Tie On Point Projected Survey Survey Tool Description Tolerable Gyro (2N-304PB1 Gyro) AK-6 BP _IFR-AK (2N-304PB1) .--. ". 7 September, 2001 - 9:04 Page 6 of 6 DrlllQuest 2.00.08.005 (' (' aD /-/31) 07-Sep-01 AOGCC 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 Definative Surveys Re: Distribution of Survey Data for Well 2N-304 GYRO Dear Dear Sir/Madam: Enclosed are two survey hard copies and 1 disk Tie-on Survey: Window / Kickoff Survey Projected Survey: 0.00' MD 'MD 0.00' MD (if applicable) Please call me at 273-3545 if you have any questions or concerns. Regards, William T. Allen Survey Manager RECEIVED SEP 1 2 2001 Attachment(s) Alaska Oil & Gas Cons. Commission An chorage ~ --.:. . , ---. c '""ð '-- ~.."...., .. Kuparuk River Unit North Slope, Alaska Kuparuk 2N, Slot 2N-304 2N-304PB 1 Gyro Job No. AKFO11122, SURVEY REPORT 7 September, 2001 DEFINjlIVi: Your Ref: API 501032038270 Surface Coordinates: 5912003.77 N, 461078.43 E (700 10'13.9335" N, 150018' 47.6898" W) Kelly Bushing: 153.63ft above Mean Sea Level spe""y-5UI! DRILLING SERVices A Halliburton Company Survey Ref: 5vy9580 Kuparuk River Unit Measured Depth (ft) -- 0.00 180.00 271.00 362.00 453.00 546.00 IntI. Azim. Sperry-Sun Drilling Services Survey Report for 2N-304PB1 Gyro Your Ref: API 501032038270 Job No. AKFO11122, . 0.000 0.000 1.300 185.000 1.600 199.000 2.200 102.000 3.300 118.000 5.100 123.000 North Slope, Alaska Kuparuk 2N Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Depth Northings Eastlngs Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (°/1 OOft) -153.63 0.00 O.OON O.OOE 5912003.77 N 461078.43 E 0.00 Tolerable Gyro 26.35 179.98 2.038 0.18W 5912001.74 N 461078.24 E 0.722 -1.42 117.33 270.96 4.268 0.68W 5911999.51 N 461077.73 E 0.508 -3.22 208.29 361.92 5.838 0.61 E 5911997.94 N 461079.01 E 3.158 -3.20 299.19 452.82 7.428 4.63 E 5911996.32 N 461083.03 E 1 .463 -1.08 391.94 545.57 10.938 10.47 E 5911992.79 N 461088.84 E 1.973 1.24 All data is in Feet (US) unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to RKB (153.63' MSL). Northings and Eastings are relative to 2' FNL & 5141 FEL. Magnetic Declination at Surface is 25.635° (14-Jul-01) The Dogleg Severity is in Degrees per 100 feet (US). Vertical Section is from SHL (per As-Built) and calculated along an Azimuth of 50.947° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 546.00ft., The Bottom Hole Displacement is 15.13ft., in the Direction of 136.243° (True). 0_- Survey tool program for 2N-304PB1 Gyro Fro m Measured Vertical Depth Depth (ft) (ft) 0.00 0.00 7 September, 2001 - 8:55 To Measured Vertical Depth Depth (ft) (ft) Survey Tool Description 546.00 Tolerable Gyro 545.57 Page 2 of 2 DrillQuest 2.00.08.005 ( STATE OF ALASKA ( ALASKA Oil AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS t~(3 ~ry~ Description summary of proposal_X Detailed operations program - BOP sketch - i Refer to attached morning drilling report for LOT test, surface cement details and casing detail sheets, schematic - I 14. Estimated date for commencing operation 15. Status of well classification as: August 3, 2001 16. If proposal was verbally approved J/)fNtA ~'.I August 2,2001 Name of approver Tom Maunder ttIf",,> Date approved Service- 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. 1. Type of request: Abandon _X Suspend - Alter casing - Repair well - Change approved program - Operational shutdown - Plugging - Pull tubing - 5. Type of Well: Development _X Exploratory - Stratigraphic - 2. Name of Operator Phillips Alaska, Inc. 3. Address P. O. Box 100360 Anchorage, AK 99510-0360 4. Location of well at surface Service - 3' FNl, 515' FEl, Sec. 3, T9N, R7E, UM At top of productive interval 707' FNl, 147' FEl, Sec. 35, T10N, R7E, UM At effective depth (as proposed) At total depth 560' FNl, 24' FWl, Sec. 36, T10N, R7E, UM 12. Present well condition summary Total depth: measured true vertical (as proposed) Effective depth: 1 0415' 5735' 1 0415' 5735' Junk (measured) feet feet Plugs (measured) measured true vertical feet feet Cemented Casing Conductor Surface Production Length 82' 2895' 9595' 770' Size 16" 7.625" 5.5" x 3.5" 193 sx AS 1 335 sx AS Lite, 246 sx Class G not cemented Perforation depth: measured 10255' - 1 0257' true vertical 5774' - 5775' Tubing (size, grade, and measured depth None Packers & SSSV (type & measured depth) None 13. Attachments Oil__X ~- ~ Signed \ -. --L \ Ã '"-- L - C. Mallarv , Title: Drilling Engineering Supervisor FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness Plug integrity X BOP Test - Location clearance- Mechanical Integrity Test - Subsequent form required 10- Approved by order of the Commission ORiGINAl SIGNED BY J. .Heusser Form 10-403 Rev 06/15/88 . ORIGINAL Re-enter suspended well - Time extension - Stimulate - Variance - Perforate - 6. Datum elevation (DF or KB feet) RKB 34.6 feet 7. Unit or Property name Other - Kuparuk River Unit 8. Well number 2N-304 9. Permit number I approval number 201-130 10. API number 50-103-20382-00 11. Field I Pool Kuparuk River Field I Tarn River Pool Measured Depth 117' 2930' 9630' 1 0400' True vertical Depth 117' 2300' 5363' 5726' RECEIVED AUG 0 3 2001 Alaska Oil & Gas Cons. Commission Anchorage Gas- Suspended - Questions? Brian Noe/265-6979 !/~(Ol Date Prepared by Sharon Allsup-Drake Approval no'3öl- a'67 4a~Q~~~~~~c~~~~~~~ W<L\ \ ~~ Date 'is/ 7/ n I Commissioner , SUBMIT IN TRIPLI CATE (' /' ( Brian D Noel 08/03/01 02:26 PM To: Tom Maunder <tom_maunder@admin.state.ak.us> cc: Randy L. Thomas/PPCO@ Phillips, Chip Alvord/PPCO@ Phillips, Charles R Mallary/PPCO@ Phillips Subject: Re: P&A of 2N-304...201-130[j Tom - Sending the 403 over today for the plugging operations. Have also decided on a sidetrack plan: 1) Cut & pull 5-1/211 casing at +/-3125' (surface casing shoe is at 2930') 2) Spot 300' of high vis mud inside the 5-1/2" (3550-3250') 3) Lay in 100 sx (20.8 bbl) 15.8 ppg class G from 3250-2830' (cement 100' inside 5-1/2", across 6-3/411 open hole (35% excess), and 100' inside surface casing. 4) Drill out and kick off cement to low side well and redrill 6-3/411 hole to TD (BHL 300' to south of 2N-304 permitted target). Waiting on the directional plan from Sperry and will forward to you. Rig is in contact with the slope Inspectors. Earliest may be ready to drill ahead off cement plug is noon Monday 8/6. Will keep you advised. Thanks - Brian Tom Maunder <tom_maunder@admin.state.ak.us> Tom Maunder <tom_maunder@admin.state.ak.us> 08/02/01 02:09 PM To: Brian D Noel/PPCO@ Phillips cc: AOGCC North Slope Office <aogcc_prudhoe_bay@admin.state.ak.us>, Julie Heusser <julie_heusser@admin.state.ak.us> Subject: Re: P&A of 2N-304...201-130 ( ( Brian, Your proposal to abandon the lower wellbore sections of 2N-304 has been reviewed. Abandonment is proposed due to your bottom wiper plug landing and sealing the pipe, resulting in no cement placed outside the production casing. After cleanout, an attempt to break circulation via deep perforations was not successful. You have proposed to abandon the cased hole sections with either circulation squeezes and/or block squeezes. Your proposed plugging plan addresses the requirements to isolate formation fluids to their native strata. You have approval to proceed with your plans. I am copying this email to the Inspectors. Please have your rig supervisor stay in touch with the Inspector so that some or all of the activities may be witnessed. As we further discussed, the plan beyond plugging is to cut and pull the casing as deep as possible to effect a sidetrack. I understand that the ultimate depth that the casing may be cut is presently unknown. When the casing is cut and recovered, the stub must be covered with cement in accord with the regulations. That plug will likely be your kick off plug. When these details are determined, copy us with the updated plan and information. Please keep us informed as your operations proceed. You should plan to get us a 403 for the plugging operations. The documents I presently have may be attached. As the ultimate sidetrack operation proceeds, provided your replacement BHL is less than 500' away from the "lost" BHL you will not need to apply for a new PTD. At a minimum, please provide the new directional plan when it is finalized. Good luck, please call with any questions. Torn Maunder, PE Petroleum Engineer AOGCC Brian D Noel wrote: > Tom - > On well 2N-304 Nabors 16E drilled a 6-3/4" hole with 9.7 ppg LSND mud to TD > of 10,415' and ran 5-1/2" by 3-1/2" casing. During the cement job the > lead plug landed on stroke but plugged off, leaving spacer and the cement > inside the casing. Have since drilled out the 4200' of cement and cleaned > out to the landing collar at 10,273'. Perf'd from 10,255-257' and > attempted to circulate annulus without success. Propose to abandon this > wellbore and redrill. Following P&A plan to isolate hydrocarbon bearing > zones submitted for your review: > > 1) Perf 5-1/2" casing from 9565-9567'. > drill pipe, set at 9605'. > 2) Sting into retainer, attempt to establish circulation through perfs at > 10,255' for circulating squeeze. Pump 30 bbls 15.8 ppg class G (3-1/2" tbg > volume & 6-3/4" by 3-1/2" annular volume), to bring cement above the > Bermuda sands to the crossover. > 3) Unsting, reverse circulate above retainer to clean up wellbore and then > pump 10 bbls 15.8 ppg'class G, squeeze 6 bbls through perfs at 9565', > leaving 4 bbls inside pipe (+/-150' on top of retainer), POH. > 4) Perf 5-1/2" casing from 8575-8576'. Run 5-1/2" cement retainer on drill > pipe, set at 8525'. > 5) Sting into retainer and pump 10 bbls 15.8 ppg class G below retainer, > squeeze 6 bbls through perfs at 8575', leaving 4 bbls inside pipe (+/-150' > on top of retainer), POH. > 6) Unsting, circulate to clean up wellbore, pressure test 5-1/2" casing to > 2500 psi, POH. Run 5-1/2" cement retainer on ( > > I'll fax wellbore diagram. > needed. > > Thanks - Brian D tom_maunder. vcf 265-6979 ( Let me know what additional information is ( Tarn 2N-304 Producer P t"'.. f .,.E{ GurreAt Status ~ È A Conductor 16" 62.5# H-40 (117' MD / 117' TVD) Surface csg. 75/8" 29.7# L-80 BTCM (2930' MD I 2300' TVD) All Depths Reference Nabors 16E RKB Production csg. 5-1/2" 15.5# L-80 BTC Mod run from XO/CSR to surface (9630' MD I 5363' TVD) Production csg. 3-1/2" 9.3# L-80 EUE 8rd Mod run TD to XO/CSR (10,400' MD I 5726' TVD) ~/ :::~"~;/; ~'< Pe,--¡ -/ j/ \,.,/ / " f '/ <I II / -:¡~ " ;4\ /~ "il i:::t .' ~/ ~., , ,,// 1/ / ,/ / ( " \j I / ,I ~ K~'-7S- - FsS7(,' ( PHilliPS Alaska, Inc. A Subsidiary of PHilLIPS PETROLEUM COMPANY f~R.~ fI(T,~~ ~ (~D) l ~Ps '----...-. TeE ~ E «"G- <::;::::- C" \'/ G t 0 -'> '. t V t.. é ~~~"' \J--.'~ '\ l5 ~ 9f~ù T7- I 9 c¡ go ~f"f , c¡ s-<.ø~ - c¡ s~ "7 [Baker 5-1/2" XO . CSR top sub (w/ locator seat) Baker 80-405-1/2" x 3-1/2" Casing Seal Receptacle (CSR - 17' seal bore) Baker 3-1/2" XO to EUE 8rd Mod Total length = 41.42' Future Thru-Tubing Perforations ,/ I':' / / '/ /' '/ '";:>o('f'> /. \ '- \: / " I I (J, 'Ls-S- - 7.S" 1 BDN 7 ~ C?"( z. { 0 I (" Tarn 2N-304 Plugback Planned P&A Conductor 16" 62.5# H-40 (117' MO /117' TVO) Surface csg. 7 5/8" 29.7# L-80 BTCM (2930' MO I 2300' TVO) All Depths Reference Nabors 16E RKB Production csg. 5-1/2" 15.5# L-80 BTC Mod run from XO/CSR to surface (9630' MO I 5363' TVO) Production csg. 3-1/2" 9.3# L-80 EUE 8rd Mod run TO to XO/CSR (10,400' MD 15726' TVO) 15.8 ppg 'G' cement Kick-off plug 7 bbl high vis LSND Mud 9.7 ppg LSND iCi__.' ~'-I¡ 9.7 ppg LSND - r: CD E CD u . (' PHilliPS Alaska, Inc. A Subsidiary of PHILLIPS PETROLEUM COMPANY Cement plug 3250' - 2830' 5-1/2" casing cut at 3125' Perfs: 8575' - 8576' at 6 spf Baker 'K-1' cement retainer at 8525' Perfs: 9565' - 9567' at 6 spf Baker 'K-1' cement retainer at 9605' [Baker 5-1/2" XO - CSR top sub (w/ locator seat) Baker 80-40 5-1/2" x 3-1/2" Casing Seal Receptacle (CSR - 17' seal bore) Baker 3-1/2" XO to EUE 8rd Mod Total length = 41.42' Perfs: 10,255' - 10,257' at 6 spf BON 8/3/01 ~ ( ~ 1f ffi11f Œ lID ~ !A\ ~!A\ ~ ~ ffi1 (' AlAS IiA. 0 IL AND GAS CONSERVATI ON COMMISSION TONY KNOWLES. GOVERNOR 333 w. -¡rn AVENUE. SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 James Trantham Drilling Engineering Supervisor Phillips, Alaska, Inc. PO Box 100360 Anchorage AK 99501Name Re:. Kuparuk River Unit 2N-304 Phillips, Alaska, Inc. Permit No: 201-130 Sur Loc: 3' FNL, 515' FEL, See 3, T9N, R7E, UM Btmhole Loc. 560' FNL, 24' FWL, Sec. 36, T10N, R7E, UM Dear Mr. Trantham: Enclosed is the approved application for permit to drill the above referenced well. The permit to drill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. Annular disposal of drilling wastes will not be approved for this well until sufficient data is submitted to ensure that the requirements of 20 AAC 25.080 are met. Annular disposal of drilling waste will be contingent on obtaining a well cemented surface casing confirmed by a valid Formation Integrity Test (FIT). Cementing records, FIT data, and any CQLs must be submitted to the Commission for approval on form 10-403 prior to.. the start of disposal operations. Please note that any disposal of fluids generated from this drilling operation which are pumped down the surface/production casing annulus of a well approved for annular disposal on 2N Pad must comply with the requirements and limitations of 20 AAC 25.080. Approval of this pennit to drill does not authorize disposal of drilling waste in a volume greater than 35,000 barrels through the annular space of a single well or to use that well for disposal purposes for a period longer than one year. , ( f Pennit No: 201-130 Page 2 of2 Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25 035. Sufficient notice (approximately 24 hours) must be given to allow a representative of the Commission to witness a test of BOPE installed prior to drilling new hole. Notice may be given by contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. Daniel T. Seamount, Jr. Commissioner BY ORDER OF THE COMMISSION DATED this IZ+< day of July, 2001 jj c/Enclosures cc: Department ofFish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. 1b. Type of well. Exploratory 0 Stratigraphic Test 0 Service 0 Development Gas 0 Single Zone 0 5. Datum elevation (OF or KB) RKB 34.6 feet 6. Property Designation Kuparuk River Field ADL 380053 ALK 4601 Tarn River Pool 7. Unit or property Name 11. Type Bond (see 20 MC 25.0251) Kuparuk River Unit Statewide 8. Well number Number 2N-304 # 59-52-180 9. Approximate spud date Amount July 12, 2001 $200,000 14. Number of acres in property 15. Proposed depth (MD and TVD) 2560 10336' MD 15861 ' TVD 17. Anticipated pressure (see 20 AAC 25.035 (e)(2)) Maximum surface 2061 psig At total depth (TVD) 2658 psig Settlno Depth RECEIVED JUN 29 LO01 AI ka on & Gas cons. commission as . Anchorage l \ " " ( STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 1 a. Type of work: Drill 0 Redrill 0 Re-entry 0 Deepen 0 2. Name of Operator Phillips Alaska, Inc. 3. Address P.O. Box 100360 Anchorage, AK 99510-0360 4. Location of well at surface 3' FNL, 515' FEL, Sec. 3, T9N, R7E, UM At top of productive interval 707' FNL, 147' FEL, Sec. 35, T10N, R7E, UM At total depth 560' FNL, 24' FWL, Sec. 36, T10N, R7E, UM 12. Distance to nearest property line 13. Distance to nearest well 707' @ Target feet 2N-305 11' @ 400' 16. To be completed for deviated wells Kickoff depth: 400' MD 18. Casing program size feet Maximum hole angle 64.6° Too TVD 34.6' 34.6' 34.6' 5282' Hole 24" Casino 16" Specifications Grade Coupling H-40 Weld L-80 BTCM L-80 LTC-Mod L-80 EUE 8rd Moc 34.6' 9517' Bottom TVD 117' 2300' 5282' 5861' Length 82.4' 2903.4' 9482.4' 819' MD 34.6' 34.6' Weight 62.5# 29.6# 15.5# 9.3# MD 117' 2938' 9517' 10336' 9.875" 6.75" 6.75" 7.625" 5.5" X 3.5" 19. To be completed for Redrlll, Re-entry, and Deepen Operations. Present well condnion summary Total Depth: measured true vertical Plugs (measured) feet feet Effective Depth: feet feet Junk (measured) measured true vertical Casing Conductor Surface Production Length Size Measured depth Cemented Liner Perforation depth: measured true vertical dnA. it' J- tl s-- Development Oil 0 Multiple Zone ø 10. Field and Pool Quantnv of Cement (include staoe data) 193 sx AS I 300 sx AS Lite & 240 sx Class G 70 sx Class G & 370 bbls GasBLOK included above True Vertical depth 20. Attachments Filing fee 0 Property Plat 0 BOP Sketch 0 Diverter Sketch 0 Drilling program 0 Drilling ~uid program 0 Time vs depth plot DRefraction analysis 0 Seabed report 0 20 AAC 25.050 requirements 0 21. I hereby CE rtify that the foregoing is true and correct to the best of my knowledge Questions? Brian NoeI265-697~ Sig"ed V)'\A o~} I f) .JJ~ írañt1íam ' \..,.Id.~'"7 Title: Drílling Engineering SupsNÍsor Permn Number 20/ - /,?é1 Conditions of approval Samples required Hydrogen sulfide measures 0 Yes Required working pressure for BOPE D2M; Other: Commission Use Onl\ Approval date '7 ß~ 0 / Mud log required' I Directional survey required [81 0 10M;D 0 ~30P '-'-"-'f)" by order of Approved by API number 50- /0,3 - 2- CJ 3 ~ 2- 0 Yes J8J No ~ No 0 3M' 0 SM' , 1- ' " " ORIGINAL SIGNED BY 6'Ó~ f?:?' 14\..- ;.l VuJ~",- 0 Taylor Seamount the commission Commissioner Form 10-401 Rev. 12/1/85. C~' r.. """'~i ~('""'I. ~ ~\ 11\ 1 ~ I "I \ ¡ I I \. t.,,- Date '~"8J Lt"\Ì,£;V l "". ., hv "",- AII""'...-lÌr::ikt See cover letter for other requirements 0 Yes ~ No Yes 0 No Date 1'/;c2hl I /- Submit in triplicate ( ~ ¡Jlication for Permit to Drill, Well 2N-304 Revision No.o Saved: 28-Jun-O1 Permit It - Kuparuk Well 2N-304 (Tarn) Application for Permit to Drill Document MoximizE We-II ValUE; Table of Contents 1. Well Name.................. ...... ............ ..... .... ............................ ................ ........ ......... .......2 Requirements of 20 AAC 25.005 (f)........................................................................................................2 2. Location Sum mary .......... .............. ...... ........ ............................... ...... ........ ................2 Requirements of 20 AAC 25.005(c)(2) ...... "..""."."".... ........................... "".."""""""'..""""" ........ .....2 Requirements of 20 AAC 25.050(b)........................................................................................................2 3. Blowout Prevention Equipment Information ......................................................... 3 Requirements of 20 AAC 25.005(c)(3) ...................................................................................................3 4. Dri II i ng Hazards Information...................... ...................................... .......................3 Requirements of 20 AAC 25.005 (c)( 4) "".""."""""""""'.""""".".""....""""...""'.""""""""""".."'" 3 5. Procedure for Conducting Formation Integrity Tests ........................................... 3 Requirements of 20 AAC 25.005 (c)(5) """"""."""",."."""""".""""",.""".""""",..."."",.""""""."" 3 6. Casing and Cementing Program .............................................................................3 Requirements of 20 AAC 25. 005(c)(6) .......... ........, ................................................................................ 3 7. Diverter System Information........ .............. ............................... ........ ...... ................4 Requirements of 20 AAC 25.005(c)(7) ...................................................................................................4 8. Dri II i ng FI u id Program .......... ........ ...... ..... ......... ............... ........... ...... ....... ..... ........ ... 4 Requirements of 20 AAC 25.005(c)(B) ...................................................................................................4 9. Abnormally Pressured Formation Information ...................................................... 5 Requirements of 20 AAC 25.005 (c)(9) ..................................................................................................5 10. Seismic Analysis ..................... ..... ............... ............................... ........ .... ........ ...... .... 5 Requirements of 20 AAC 25.005 (c)(10) ................................................................................................5 11. Seabed Condition Analysis .....................................................................................5 Requirements of 20 AAC 25.005 (c)(11) ......................................... ....................................................... 5 12. Evidence of Bond i ng................................... ....... .................................... ........ ....... ... 5 Requirements of 20 AAC 25.005 (c)(12) ................................................................................................5 13. Proposed Dri II i ng Program... ............... ........................... ......................... ..... ....... .... 5 2N-304 PERMIT IT DOC Page 1 of 6 Printed: 28-Jun-O1 " ~. ( ,Jlication for Permit to Drill, We1l2N-304 Revision No.O Saved: 28-Jun.O1 Requirements of 20 AAC 25.005 (c)(13) ................................................................................................5 14. Discussion of Mud and Cuttings Disposal and Annular Disposal....................... 6 Requirements of 20 AAC 25.005 (c)(14) ................................................................................................6 1fi.Attact1J11E!nts ............................................................................................................. 6 Attachment 1 Directional Plan................................................................................................................6 Attachment 2 Drilling Hazards.............................................................................................6 Attachment 3 Well Schematic..............................................................................................6 1. WE!ll NaJ11E! Requirements of 20 AAC 25.005 (f) Each well must be Identified by a unique name designated by the operator and a unique API number ass~qned by the comm/~<)Sion under 20 MC 25.040(b). For a well with multiple well branches, each branc/7 must similarly be Identified by a unique name and API number by adding a suffix to tl7e name designated for the well by the operator and to the number assigned to the well by the commis.."iof7. The well for which this application is submitted will be designated as 2N-304. 2. Location SuJ11J11ary Requirements of 20 AAC 25.005(c)(2) An application for a Permit to Drill must be accompanied by each o{the following items, except fvr an item already on file with the commission and Identified in the application: (2) a plat identi{yli7g the property and the propelty's owners and showing (A)ti7e coordinates of the proposed location of the well at the slJrface/ at the top of each objective formation and at tatal depth referenced to govemmental.':>-ection línes, (8) the coordinates or the propo!:7-ed location of the well at the surlace, referenced to the state plane coordinate system fvr this state as maintained by the National Geodetic Survey in the National Oceanic and Atmospherk.: Administration~ (C) ti,e proposed depth of l!7e well at the top of each objective ('Ormation and at total depth; Location at Surface I 3' FNL, 515' FEL, Sec 3, T9N, R7E, UM NGS Coordinates RKB Elevation 153.9' AMSL Northings: 5,912,004 Eastings: 461,078 Pad Elevation 119.3' AMSL Location at Top of Productive Interval Ku aruk "A3" Sand NGS Coordinates Northings: 5,916,552 707' FNL, 147' FEL, Sec 35, T10N, R7E, UM Eastings: 466,743 9717' 5424' 5270' Location at Total De th 560' FNL 24' FWL NGS Coordinates Northings: 5,916,836 Eastings: 467,075 10 336' 5861 ' 5707' and (D) other 1Ì7formation required by 20 AAC 25.0S0(b)/ Requirements of 20 AAC 25.050(b) Ifa well is to be intentionally deviate4 the application for a Permit to Dnll (Form 10..401) must (1) include a plat~ drawn to a sUItable scale/ showing the path of the proposed wellbore/ including all adjacent wellbores within 200 feet of any portion of the proposed well/ Please see Attachment 1: Directional Plan 2N-304 PERMIT IT. DOC Page 2 of 6 Printed: 28-Jun-O1 ( (, r>lication for Permit to Drill, Well 2N-304 Revision No.O Saved: 28-Jun-O1 and (2) for all wells witl7in 200 feet of the proposed wellbore (A) list the names of the operators of those well~ 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 (B) state that the applicant is the only affected owner. The Applicant is the only affected owner. 3. Blowout Prevention Equipment Information Requirements of 20 AAC 25.005(c)(3) An application for a Pel7nit to Drill must be accompanied by each of the following Item~ except for an Item already on fìle with the commission and identified in the application: (3) a diagram and desCliption of the blowout prevention equipment (BOPE) as required by 20 MC 25,035, 20 AAC 25.03~ or 20 AAC 25. 03~ as applicable; Please reference BOP schematics on file for Nabors 16E. 4. Drilling Hazards Information Requirements of 20 AAC 25.005 (c)(4) An application for a Permit to Drlïlmu.:.7 be accompanied by eadJ of the following l1em5; except: for an item already on file with the commission and identified in the application: (4) information on drilling ha2ard.:,~ inäuding (A) the maximum downhole pressure that may be encounterect criteria used to determine it, and maximum potential surface pressure based on a methane gradient; Based on offset well data, the expected reservoir pressure in the T3 Bermuda sand for the Tarn well 2N- 304 is -2660 psi at 5424' tvd, 0.49 psi/ft or 9.4 ppg EMW (equivalent mud weight). The maximum potential surface pressure (MPSP) while drilling 2N-304 is calculated using above reservoir pressure, a gas gradient of 0.11 psi/ft, and top of the T3 Bermuda sand target at 5424' tvd: MPSP =(5424 ft)*(0.49 - 0.11 psi/ft) = 2061 psi (8) data on potential gas zone5/ The well bore is not expected to penetrate any gas zones. and (C) data conæming potential caU$e$ of hole problems sl.1(.17 as abnOlmally geo-pres$ured $trata, lost circulation zone5; and zones that have a propensity for differential $t'ÍC.*ing; Please see Attachment 2 - Drilling Hazards Summary 5. Procedure for Conducting Formation Integrity Tests Requirements of 20 AAC 25.005 (c)(5) An application for a Permit to Drill must be accompðnied by each of the f"ollowing item~ except ("or an item already 017 file with the commi!;,-sion and Identified in the applicðtion: (5) a description of the procedure for conductliJg ('Ormation integnty tests, as required under 20 AAC 25,O30(f); Drill out surface casing shoe and perform LOT test or FIT (maximum of 16 ppg EMW) in accordance with the Kuparuk LOT / FIT procedure, that Phillips Alaska has 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 f"ollowing items, except for an item already 0/7 file with the commi:.-sion and Identified in the application: (6) a complete propos-ed casinq and cementing program as required by 20 AAC 25:030" and a descripbÒn of any slotted liner, pre.. perforated liner, or !;:'T.reen to be installed; 2N-304 PERMIT IT. DOC Page 3 of 6 Printed: 28-Jun-O1 ( .(' ¡Jlication for Permit to Drill, Well 2N-304 Revision No.o Saved: 28-Jun-O1 Casing and Cementing Proclram I Hole Top atm Csg/Tbg Size Weigh Length MO/TVO MO/TVO 00 (in) (in) t (lb/ft) Grade Connection (ft) (ft) (ft) Cement Pro_oram 16 24 62.5 H-40 Welded 117' 35'/35' 152'/152' 193 sx 15.8 ppg ASl 7-5/8 9-7/8 29.7 L-80 BTC 2903' 35'/35' 2938'/2300' Lead: 300 sx 10.7 ppg AS Lite Tail: 240 sx 15.8 ppg 'G' w/ add. Planned TOC=Surface 5-1/2 x 6-3/4 15.5 L-80 BTC-Mod 9482' 35'/35' 9517'/5282' Lead: 70 sx 13 ppg 'G' 3-1/2 9.3 L-80 EUE 8rd 819' 9517'/5282' 10,336'/5861' w/ add. Mod Tail: 370 sx 15.8 ppg 'G' w/ Gasblok Planned TOC=8141' 3-1/2 9.3 L-80 EUE 8rd 9482' 35' / 35' 9517'/5282' Mod 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 file with the comrm:"sion and identified in the application: (7) a diagram and description of the diverter 5ystem as required by 20 AAC 25:035~ UfJle5:¡;; this requirement is waived by the commission under 20 AAC 2S:035(h)(2}: Please reference diverter schematic on file for Nabors 16E. 8. Drilling Fluid Program Requirements of 20 AAC 25.005(c)(B) An application for a Permit to Drill must be accompanied by each of the followìng item:;,~ except for an ìtem already on file with the commì.~jon and Identified in the applicat7Ón: (8) a drilling fluid program, including a diagram and description of the drì//ìng fluid system, as required by 20 AAC 25'.0..'13/ Drilling will be done using mud systems having the following properties: Spud to surface casin oint Extended bentonite slur Drill out to TO LSND 9.5-10.2 50-120* 25- 35 16-26 10-20 15-40 7-15 9.5-10 +10 9-10.5 35-50 5-20 6-20 2-6 4-8 <6 throu h a 9-10 <11 *Spud mud should be adjusted to a FV between 100-120 sec/qt to drill gravel beds Diagram of Nabors 16E Mud System on file. 2N-304 PERMIT IT. DOC Page 4 of 6 Printed: 28-Jun-O1 ( ( plication for Permit to Drill, Well 2N-304 Revision No.O Saved: 28-Jun-O1 Drilling fluid practices will be in accordance with appropriate regulations stated in 20 AAC 25.033. 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 tile following Items¡ except for an Item already on file with the commission and Identified in the application: (9) for an exploratory or stratigraphic test wel¿ a tabulation setting out the depths of predicted abnom7ally geo-pressured strata as reqU/J-ed by 20 MC 25.0J3(f)/ N/ A - 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 Dlill 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 stratigrapl7ic test well a se/'5mic refraction or reflection an(Jlysis as required by 20 AAC 25. 061 (a),,' N/A - 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 Perrmt to Drill must' be acr:ompanied by each of the to/lowing Item5~ except for an item already on file with the commission and identified in the application: (11) for a well drilled from an ofts/JOre platform" mobtle bottom-founded struäurt.~ jack-up fig" or floating drilling vessel an analysis of seabed conditions as required by 20 AAC 25,061{b),.' N/ A - 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,. exæpt for an item already on file with the COmmi!:i..<;jon and identitìed in the application: (12) evidence showing that the requirements of 20 AAC 25.025 {Bonding}have been mef~' Evidence of bonding for Phillips Alaska, Inc. is on file with the Commission. 13. Proposed Drilling Program Requirements of 20 AAC 25.005 (c)(13) An application for a Permit to Drill must be accompanied by each of the following items,. except for an item a/ready on file with the commi!;"'sion a/7d Identified i/7 the application: The proposed drilling program is listed below. Please refer as well to Attachment 3, Well Schematic. 1. MIRU Nabors 16E. 2. Install diverter system. 3. Drill 9.875" hole to 7-5/8" surface casing point according to directional plan. 4. Run and cement 7-5/8" 29.7#, L-SO BTC-Mod casing string to surface. Employ lightweight permafrost cement lead slurry and pump adequate excess to ensure cement reaches the surface. If cement does not circulate to surface, perform stage or top job. Install and test BOPE to 5000 psi. Test casing to 2,000 psi. 5. Drill out cement and 20' of new hole. Perform LOT/FIT, but do not exceed 16.0 ppg EMW. 6. Drill 6-3/4" hole to TO according to directional plan. Run LWD logging equipment with GR, resistivity, density-neutron tools. Note: If significant hydrocarbon zones are present above the Tarn, sufficient cement will be pumped for isolation in accordance with 20 AAC 25.030(d)(3)(C). 7. Run and cement 5-1/2" L-80 BTC-Mod Csg X 3-1/2" L-80 Srd EUE-Mod tapered production casing string with Baker casing seal receptacle at crossover point. 8. Run 3-1/2" L-80 8rd EUE-Mod completion assembly. Sting into polished seal bore with seal assembly and pressure test tubing and annulus to 3,500 psi. 9. Set TWC and ND BOPE. Install and pressure test production tree. 2N-304 PERMIT IT ODe Page 5 of 6 Printed: 28-Jun-O1 ,( ( plication for Permit to Drill, Well 2N-304 Revision No.O Saved: 28-Jun-O1 10. Secure well. Rig down and move out. 11. Handover well to Operations Personnel. Note: Cement quality log and MIT will be run after rig moves off well. 14. Discussion of Mud and Cuttings Disposal and Annular Disposal Requirements of 20 AAC 25.005 (c)(14) An application for a Permrt to Drill mustc be accompanied by each of the following ItemSr except for an rtem already on file wit/7 the commission and identified "1 the application: (14) a general description of how the operator plans to dispose a/drilling mud and cuttings and a statement of whether the operator intends to request authorization LInder 20 MC 25.080 for an annular disposal operation in the wel/./ Waste fluids generated during the drilling process will be disposed of down a permitted annulus on 2N pad or hauled to a KRU Class II disposal well. All cuttings will be disposed of either down a permitted annulus on 2N pad or hauled to the Prudhoe Bay Field for temporary storage and eventual processing for injection down an approved disposal well. At the end of drilling operations, an application may be submitted to permit 2N-304 for annular pumping of fluids occurring as a result of future drilling operations on 2N pad. 15. Attachments Attachment 1 Directional Plan Attachment 2 Drilling Hazards Summary Attachment 3 Well Schematic. 2N-304 PERMIT IT. DOC Page 6 of 6 Printed: 28-Jun-O1 ( ( 2N-304 Drillin~ Hazards Summar'l (to be posted in Rig Floor Doghouse Prior to Spud) (See Well Plan for further discussion of these risks) 9-7/811 Hole /7-5/8" Casinq Interval Event Risk Level Conductor Broach Low Well Collision Low Running Coal and Low Gravel Shakerrrrough Cuttings Low S stem Overflow Gas Hydrates Moderate Shoe Fracture/Lost Returns during cement .ob Low Miti ation Strate Set 120' of conductor. Monitor cellar continuousl durin interval Careful well planning and surveying, adherence to anti-collision olic Elevated mud viscosity from spud and high densit swee s Controlled ROP Mud gas detection, controlled drilling, increased mud weights, lower viscosity, cold make-up water, and pre-treat with lecithin Reduced pump rates, and lightweight tail cement 6-3/4" Hole / 5-1/2" x 3-1/2" CasinQ Interval Event Sticky clay and tight hole first 2000' below shoe Hole cleaning in long, hi h an Ie tan ent Swabbing Camp sands durin tri Elevated pressure in sand lenses in Iceber Risk Level Low Moderate Moderate Low Miti ation Strate Attention to hole cleaning and wiper trips using PWD to monitor Good drilling practices and mud lubes Mud weight at 9.6 ppg by cao marker, control tri seed, flow checks Flow checks while drilling interval. Have not encountered drillin to east of 2N ad. 2N-304 Drilling Hazards Summary. doc 06/28/01 Page 1 of 1 t ( 2N-304 Tarn Development Well CemCADE Summary 75/8",29.6# Surface Casing in 9 7/8" Open Hole. Single Stage Design. TD @ 2938' MD, 45% Excess below Permafrost, 300% Excess above Permafrost Base ofPermafrost @ 1216' MD, Port Collar contingency @ 1021' MD REVISED 6/5/01 by KVT Pumpin2 Sequence: Pump 40 bbls CWI00 Wash, Drop Bottom Plug, 50 bbls Spacer @ 10.2 ppg. 237 bbls of 10.7 ppg Lead SluITY, 50 bbls of 15.8 ppg Tail SluITY, Drop Top Plug, Displace (approx 131 bbls). Lead Slurry: ASLite @ 10.7 ppg, Class G + 50%DI24, 9.0%D44, 0.4%D46, 30%D53, 1.5%SI, 1.5%D79 - 4.44 f13lsk Above Permafrost: 7 5/8" x OH (300% excess): (1216') x 0.2148 ft3/ft x 4.00 = Below Permafrost: 75/8" x OH (45% excess): (2138'-1216') x 0.2148 f13lft x 1.45 = Total: 1044.8 ft3 + 287.2 f13 = 1332 ft3 14.44 ft3/sk = 1044.8 ft3 287.2 ft3 1332 f13 300 sks - Round up to 300 sks Have 260 additional sacks ASLite on hand for port collar/top job - if needed. Tail Slurry: 15.8 ppg Class G + 1 %SI, 0.2%D46, 0.3%D65 - 1.17 ft3/sk Below Permafrost: 75/8" x OH: (2938'-2138') x 0.2148 ft3/ft x 1.45 = 80' shoe joint: 80' x 0.2578 ft3/ft = 249.2 f13 20.6 ft3 Total: 249.2 ft3 + 20.6 f13 = 269.8 ft3 11.17 f13/sk = 269.8 f13 231 sks - Round up to 240 sks CemCADE* Summary: Fluid Sequence: Outlined Above Circulation and Cementing: Mud circulation over 10-11 BPM risks formation breakdown. Circulation and cementing at or under 8 bpm is within safe ECD to avoid breaking down any formations. Recommend dropping displacement rate towards end of displacement, if necessary, to maintain 1: 1 returns. Recommended cementing displacement rate is 8 BPM for mud removal and avoiding breakdown. Run dye or LCM marker in spacer to provide insight into decision for port collar or top job contingency. Expected pressure to bump plug is 430 psi. At 8 BPM, U-tubing (vacuum) expected, 10 minutes, 2-3 minutes prior to and 6-8 minutes after dropping top plug. Mud: 9.5 to 10.0 ppg or lower, Pv =15 to 20, Ty = 15 to 20 or lower - As thin and as light as possible to aid in the removal of mud during the cement job. This is the most important part of the cement job. Kevin Tanner can be reached at the office or by cellular for additional details andlor assistance on this job design. 230-6628(M) or 265-6205(0) ( ( 2N-304 Tarn Development Well CemCADE Summary 5 1/2" 15.5# x 3 1/2" 9.3# Production Casing in 6 3/4" Open Hole TD @ 10336' MD, 100% Excess in Open Hole. Crossover @ 9379' MD, Top Of Cement @ 8141' MD. 738' of Lead Cement (500' above top of the Iceberg Formation @ 8641' MD) 1457' of Tail Cement (500' above the top of the crossover) REVISED 6/28/01 by KVT Pumpin2 Sequence: 10 bbls FW, 40 bbls CW100 Wash, 50 bbls MudPUSH XL Spacer @ 11.0 ppg, 25 bbls of 13 ppg Lead, Drop plug, 79 bbls of 15.8 ppg GasBLOK, Drop Plug, Displace (approx. 231 bbls.) Lead Slurry: Cement from 8879' to 8141' Volume: 2.00 x (8879'-8141') x (0.0835 ft3/ft) = Yield = 1.99 ft3/sk Total sacks = 123.2 ft3/1.99 ft3/sk = 62 sacks. Round up to 70 sacks 123.2 ft3 Composition: 13.0 ppg Class G wI 0.65%D800, 0.2%D046, 0.1 %D065, 8.0%D020 & 0.6%D167 per lab testing @ 160 BHST, 130 BHCT - 3.5 to 4.5 hour thickening time Tail Slurry: Cement from 10336' to 8879' + 80' shoe volume Volume: 5 1/2" x OH: 2.00 x (9379' -8879') x (0.0835 ft3/ft) = 83.5 ft3 3 1/2" X OH: 2.00 x (10336'-9379') x (0.1817 ft3/ft) + (80') x (0.0488 ft3/ft) = 351.7 ft3 Yield = 1.2 ft3/sk Total sacks = (83.5 + 351.7) ft3/1.2 ft3/sk = 363 sacks. Round up to 370 sacks Composition: 15.8 ppg GasBLOK wI Class G + D53, D600, D135, D800, D047, D065, per lab testing @ 160 BHST, 130 BHCT - 3.5 to 4.5 hour thickening time CemCADE Summary: Pumping sequence: Outlined above Circulation: Simulated mud circulation over 6 bpm risks formation breakdown. Verify with company man on location. Cementing and displacing: Rates @ 4 bpm or under are within the safe operating limits. Recommend dropping the displacement rate 20 bbls prior to bumping the plug @ 1300 psi. No V-tubing is expected. Centralizers: Recommend 2/1 across the zone of interest. Mud: Recommend Pv = 15 to 20 and YP = 15 to 20 @ 10.0 or under for effective mud removal Kevin Tanner can be reached regarding this program at the following numbers: 265-6205( office), 230-6628( cell) ( Tarn 2N-304 Producer Proposed Completion Schematic Conductor 16" 62.5# H-40 (117' MD 1117' TVD) Surface csg. 75/8" 29.7# L-80 BTCM (+1- 2938' MD 12300' TVD) All Depths Reference Nabors 16E RKB Production csg. 5-1/2" 15.5# L-80 BTC Mod run from XO/CSA to surface (+1- 9517' MD 15282' TVD) Production csg. 3-1/2" 9.3# L-80 EUE 8rd Mod run TD to XO/CSA (+1- 10,336' MD 15861' TVD) ~ (. PHilliPS Alaska, Inc. A Subsidiary of PHILLIPS PETROLEUM COMPANY J. 3-1/2" 5M FMC Gen 5 tubing hanger with 3-1/2" L-80 EUE 8rd Mod pin down I. 3-1/2" L-80 9.3# EUE 8AD-Mod tubing to surface H. 3-1/2" Camco 'DS' landing nipple with 2.875" No-Go profile set at +1-500' G. 3-1/2" L-80 9.3# EUE 8AD-Mod tubing to 'OS' landing nipple wi 3-1/2" x 1" Cameo 'KBG-2-9' Mandrel wI DV and latch, use TVD to space out as follows: GLM# TVD +I-MD 1 TBD' TBD' 2 TBD' TBD' 3 TBD' TBD' Note: Each GLM should have 6' L-80 handling pups installed on top and bottom F. 3-1/2" X 1" Camco 'KBG-2-9' Mandrel wI DCK (3000 psi csg to tbg shear) and latch at +1-9460 md wI 3-1/2" x 6' L-80 handling pups installed on top & bottom of GLM E. 1 it 3-1/2" L-80 9.3# EUE 8AD-Mod tubing D. 3-1/2" Baker 'CMU' sliding sleeve with 2.813" Camco profile C. 12' pup jt 3-1/2" L-80 9.3# EUE 8AD-Mod tubing B. 3-1/2" Cameo 'D' landing nipple with 2.75" No-Go profile A. Baker 3-1/2" 'GBH-22' Locator Seal Assembly wI 15' of seals & locator 3-1/2" x 6' handling pup installed on top. EUE 8AD-Mod box up [Baker XO - CSA top sub (locator seat) Baker 80-40 5-1/2" x 3-1/2" Casing Seal Aeceptacle (CSA) Baker XO - set at +1- 9517' MD 15282' TVD (200' MD above T3 top) Future Thru- Tubing Perforations BDN, 6/28/01, v2 1000 2000 ....... m ~ e;. 3000 .$::. Õ. 4) 0 B ~ 4) > 4000 5000 6000 DrillOuest 2.00.09.001 0 I SHL: X = 461078.0' E & Y = 5912004.0' N I' I(I:'FNL &ß*4' FEL,Sec. 3-T9N-R7E) ~. H.tc- ~fS' Fel- Phillips Alaska, Inc. North Slope, Alaska Kuparuk River Unit 2N Pad 2N-304 (wpO2) ./ Begin Dir @ 2.000o/100ft (in 9-7/8" Hote): 4oo.00ft MD, 400.00ft TVO /' / Increase in Dir Rate @ 3.000°/1000: 900.0Oft MD, 897.47ftTVD / / Increase in Dir Rate @ 4.500O/100ft: 1097.40ft MO, 1090.17ftTVD " . -- - -~ --- _BæjePer!Jlajj:osL 1203.90' TIn --, -- - --- L)¡.dY<,sL~ 1459.90' TVD i j - t--- --- - ! I Current Well Properties I Well: 2N-304 (wp02) I Horizontal Coordinates: Ref. Global Coordinates: 5912004.00 N, 461078.00 E I Ref. Structure: 65.38 N, 276.98 E ! Ref. Geographical Coordinates: 70010'13.9358" N, 1500 18' 47.7023"W - (2' FNL & 514' FEL, Sec. 3 - T9N - R7E) 153.90ft above Mean Sea Level / End Oir, Start Sail @ 64.610° : 2362.82ft MO, 2053.23ft TVD / -- - .ß>JS.-LWe.1ISakrWSIOi 20/3.90'TVD ~ 7.5}8' Casing 2938.35' MD 2300.00 TVD ~'c- RKB Elevation: 7-518" Csg Pt ... Orin 6-3/4" Hole to TD .-- 1---- - ~- --. --, --_. --- - - ---- I i 0 1000 Scale: 1 inch = 1oo0ft 2000 North Reference: I Units: I True North Feet (US) ----- Begin Dir@ 2.000°11000: 8466.5Oft MD, 4670.35ft NO ,-. End Dir, Start Sail @ 45.000° : / 9447,48ft MD, 5232.99ft TVD // f3 5.123'J(), II'/! 3-1/2" Liner 10336.00' MD 5861.27' TVD I Total Depth : 10336.00ft MD, 5861.27ft TVD (560' FNl & 24' FWl, Sec. 36 - T10N - R7E) 3000 4000 6000 7000 8000 9000 5000 Section Azimuth: 50.9470 (True North) -- repared by: Dave Egedahl 5000 4000 3000 2000 1000 DrillQuest 2.00.09.001 -1000 ! I ! ! I i , SHL: ~ = 461078.?' E ; ! & Y - 5912004.0 N j, 12.' ~NL &.s.1<í=EL,f5"ff r Sec. 3-T9N-R7E) - ¡ 0 ----- -1000 Scale: 1 inch = 1000ft ^"';-. ~o'- Æ..,<:.,:l' i'-= ~ .~\). ~. .¡y~v . 0<:- èl e;;e 1000 2000 3000 7-5IfJ' Casing 2938.35' MD 2300.00' TVD ~- "- 7-5/8" Csg Pt... Orin 6-314" Hole to TO .'" " End Dir, Start Sail @ 64.610° : 2362.82ft MD, 2053.23ft TVD Eastings 4000 5000 6000 7000 Total Depth: 10336.00ft MD, 5861.27ft TVO (560' FNl & 24' FWL, Sec. 36 - T1 ON - R7E 5000 End Dir, Start Sail @ 45.000° : 9447.48« MD, 5232.99ft TVD 3-112' Liner 10336.00 MD 5861.27' TVD -, .-~ -', Begin Oir @ 2.000"f100ft: 8466.5Oft MD, 4670.35ft TVD I T1 (2N-3Ò4)@5423.9OTVD'--lj' I 4577.08 N & 5641.53 E oISHi FO7' FNL & 147' FEL, Sec. 35 - TION --~"!) 4000 3000 en 0> c: .s:::. t: 0 Z w\. ,N ..-.\ W Reference is True North 2000 ~', Current Well Properties Well : 2N-304 (wpO2) Horizontal Coordinates: Ref. Global Coordinates: 5912004.00 N, 461078.00 E . Ref. Structure: 65.38 N, 276.98 E I Ref. Geographical Coordinates: 70° 10' 13.9358" N, 150° 18' 47.7023- W I (2' FNL & 514' FEL, Sec. 3 - T9N - R7E) RKB Elevation: 153.9Oft above Mean Sea Level I North Reference: True North Units: Feet (US) 1000 - - - - - - - - - - - - - - - - - - - - - - - - - -- - --- - ----- - 0 ; \ \ ---.... Increase in Dir Rate @ 4.5<xn100ft: 1097.4Oft MD, 1090.17ft TVD I \ Increase in Dir Rate @ 3.0000J100ft: 9OO.00ft MD, 897A7ft TVD Begin Dir @ 2.0000/100ft (in 9-71f!j' Hole): 4OO.00ft MD, 4OO.00ft TVD 0 2000 3000 Eastings 1000 4000 5000 6000 7000 Kuparuk River Unit 2N-304 (wpO2) :o"i':if{%'4tff;.';'-;:;;-'ftt¥:'i?;;o1,$'X2);:;ii:'¡"¡"W,i"3%2iiiff'£:f'iBÜi:%'::'i","';1',~ilii:~!i'§\~f*~?,,*-}~l~.&%..~X1§*3:»'?~'\'i&~*Z-~-š'f~@*¡;%'i~E?ø&~~if,j'~%%B.~Ç,ð;~~~7g'Ç~~);j~3;g~JZ~;i¡;'f'!f{gj!i!£¿'",i;;};i';~f:tS-;':?"¿~"::f;/:~;i;>'t"/';';::,-j; '~<"<':~'/:" :.;-: ',-c~",',i:C, - !.-:; ~'-' :.'-. >,.' :;. ; ',- -. ' ,.': ',---,' MD loc Azim. SSTVD TVD NIS EIW Y. ~ DLS v.s. Comment (ft) (Deg) (De g) (ft) (ft) ~ft) !~ (ft) (ft) (°/1 OOft) (ft) 'i'Ø'.;:/:g¿%"",,"-"'7G:?-w5si!-"<'i~;§Ú;~,,~5~~:-£:4§,;¡p,-",~¡'¡:>:"";:':~}';:~~"'2;"'4ß"'$E~'i!,io;:",~""',:;:".""&:<*,,,,;:,:¡;~øß'.~'¡'}'jffØ¡'Þ.~B;;:~ff.~;t,þ'~""&"j:"'-~%é-%;'-{";:~"~;'".;;¿c'?'A';:;'<'~",,,"";~;¿~'",,,:;'Ç!!'$,7;r,3/Bð-.à:t';'-';;-""'-,;;i:""3rii'",,,~:'-"èc£',cc;~-;C-,'¿(/c" ,:;,'~_:,-:c:._,-,;" ;p,'c,>' "'" j/, .~ '-,:- -:,:: c-'-"',-,-:',, c/- - -, -' ", '. .: ._-.: -,c- -', '",,' 0.00 0.00 0.00 -153.90 0.00 0.00 N 0.00 E 5912004.00 N 461078.00 E 0.00 SHL 400. 00 0.00 0.00 246.10 400 . 00 0.00 N 0.00 E 5912004.00 N 461078.00 E 0.00 0.00 Begin Dir 1.- 900 . 00 10.00 120.00 743.57 897.47 21.76 S 37.69 E 5911982.05 N 461115.58 E 2.00 15.56 Increase DLS 1097.40 15.00 105.00 936.27 1090.17 36.96 S 77 .24 E 5911966.65 N 461155.05 E 3.00 36.70 Increase DLS 1215.98 18.04 89.46 1050.00 1203.90 40.76 S 110.45 E 5911962.67 N 461188.24 E 4.50 60.09 Base Permafrost 1493.97 27.92 69.29 1306.00 1459.90 17.24 S 214.78 E 5911985,65 N 461292.69 E 4.50 155.93 Top West Sak 2276.94 60.88 50.29 1860.00 2013.90 275.37 N 663.58 E 5912275.96 N 461742.99 E 4.50 688.81 Base West Sak (WS 1 0) 2362.82 64.61 49.16 1899.33 2053.23 324.73 N 721.81 E 5912325.01 N 461801.47 E 4.50 765.12 End Dir, Start Sail 2938.35 64.61 49.16 2146.10 2300.00 664.74 N 1115.16 E 5912663.00 N 462196.57 E 0.00 1284.81 7-5/8" Csg Pt, Drill 6-3/4" Hole 3441.87 64.61 49.16 2362.00 2515.90 962.22 N 1459.30 E 5912958.70 N 462542.23 E 0.00 1739.47 cao (Kia) 3558.48 64.61 49.16 2412.00 2565.90 1031.11 N 1539.00 E 5913027.18 N 462622.28 E 0.00 1844.77 Camp S5 6697.64 64.61 49.16 3758.00 3911.90 2885.67 N 3684.51 E 5914870.68 N 464777.30 E 0.00 4679.34 C50 7325.01 64.61 49.16 4027.00 4180.90 3256.31 N 4113.29 E 5915239.11 N 465207.98 E 0.00 5245.83 C40 (K5) 7691.16 64.61 49.16 4184.00 4337.90 3472.63 N 4363.54 E 5915454.14 N 465459.35 E 0.00 5576.46 C37 8466 . 50 64.61 49.16 4516.45 4670.35 3930.69 N 4893.46 E 5915909.47 N 465991.61 E 0.00 6276.57 Begin Dir 8640.96 61.12 49.16 4596.00 4749.90 4032.20 N 5010.90 E 5916010.37 N 466109.57 E 2.00 6431.73 Iceberg 9103.47 51,88 49.17 4851.00 5004.90 4284.10 N 5302.40 E 5916260.78 N 466402.36 E 2.00 6816.80 T7 9447.48 45.00 49.18 5079.09 5232.99 4452.28 N 5497.06 E 5916427.95 N 466597.89 E 2.00 7073.93 End Dir, Start Sail 1-- 9578.87 45.00 49.18 5172.00 5325.90 4513.01 N 5567.37 E 5916488.32 N 466668.51 E 0.00 7166.79 T3,1 9717.47 45.00 49.18 5270.00 5423.90 4577.08 N 5641.53 E 5916552.00 N 466743.00 E 0.00 7264.75 T3, Target - T1 (2N-304) 9858.89 45.00 49.18 5370.00 5523.90 4642.44 N 5717.21 E 5916616.98 N 466819.01 E 0.00 7364,70 T2 10035.67 45.00 49.18 5495.00 5648.90 4724.16 N 5811.81 E 5916698.20 N 466914.03 E 0.00 7489.64 C35 (K3) 10336.00 45.00 49.18 5707.37 5861.27 4862.98 N 5972.52 E 5916836.20 N 467075.45 E 0.00 7701.91 Total Depth '3'~'i!ii.~4';':~,,;;¡;¡;-j:'t2'fi'!"}:X4£¿~~'BB):~;'-~l'Pg§.~î$1~~-"{¿.;:"};-."'~i'.""')J'~~~~'<"~"Þffi'JiiP"¥i?:;iiC~R-~"'&"";:.òj>5""ð:ifi¥4~~~-t?}~;¡';¡:i'fili§~~.€¥g1'§;2.:¿è*~""-'-'A¡::'-?', ¿~~?,-)i¥!:%';:51--:'§i§Y-w.'>&¥;;:é?~:'Y/;5,'t- 'c';"';'X'(ê."é¿OC:,c::C:/¡ ; ¿.:: c" . ,':-,.',':' . >-, ,c. i, ~:c 'T '-'-..'-',', --,.- - J ' co:' :-,. ( Sperry-Sun Anticollision Report Company: Phillips Alaska Inc. Field: Kuparuk River Unit Reference Site; Kuparuk 2N Pad Reference Welt. 2N-304 Pian Reference Wellpath: 2N-304 GLOBAL SCAN APPLIED: All wellpaths ,,1thin 200'+ JOO/IOOO of reference Interpolation Method: MD Interval: 100.00 ft Depth Range: 153.90 to 10336.00 ft Maximum Radius: 5000.00 ft Ðate:6113/2001 ( Time: 15:25:26 Page: I Well: 2N-304 Plan. True North Nabors 16E Rig @ 2N-304153.9 Db: Sybase Principal Plan & PLANNED PROGRAM ISCWSA Ellipse Tray Cylinder North Ellipse + Casing Co-ørdiDate(NE) Reference:' Vertical (TVD) Rererence: Survey Program for Definitive WeUpath Date: 5121/2001 Validated: No Planned From To Survey ft ft 153.90 600.00 800.00 10336.00 Planned: 2N-304 WP02 V1 Planned: 2N-304 WP02 V1 Version: Toolcode 7 Reference: Emir Model: Scan Method: Error Surface: Tool Name CB-GYRO-SS Camera based gyro single shots MWD+IFR-AK-GAl-SC MWD+IFR AK CAl see 7-5/8" 3-1/2" Summary '.'..'~~~ .".,.,.,.". .'--7"?()«::)~el'Þ"~~T~."..'."'.W~l1þät; ",'.' Kuparuk 2N Pad Kuparuk 2N Pad Kuparuk 2N Pad Kuparuk 2N Pad Kuparuk 2N Pad Kuparuk 2N Pad Kuparuk 2N Pad Kuparuk 2N Pad Kuparuk 2N Pad Kuparuk 2N Pad Kuparuk 2N Pad Kuparuk 2N Pad Kuparuk 2N Pad Kuparuk 2N Pad 2N-302 Plan 2N-303 2N-305 2N-307 2N~308 2N..309 2N-313 2N-314 2N--315 2N-316 2N-317 2N-318 2N-319 2N-320 2N-302 V5 Plan: 2N-302 2N-303 V2 2N~305 V3 2N-307 V6 2N-308 V2 2N..309 V2 2N-313 V2 2N-314 V1 2N-315 V2 2N-316 va 2N-317V2 2N-318 V2 2N-319 V2 2N-320 V2 ~.~7' 601.08 399.93 399.87 399.98 498.14 399.99 299.99 153.90 299.99 399.94 495.31 299.99 399.99 399.98 Offset ~~~. 600.00 400.00 400.00 400.00 500,00 400.00 300.00 153.90 300.00 400.00 SOO.OO 300.00 400.00 400.00 ~~<~~ . .' " , . , ,. 31.69 10.27 17.19 5.31 11.30 5.57 45.55 5.64 55.92 7.11 75.09 5.25 135.26 3.65 149.64 0.73 165.40 3.83 180.63 5.43 196.13 6.75 209.95 3.52 225.50 5.37 237.01 5.29 ',.'...',.DAU.~_"..;;.~.~att,boæn..'...".,','.,.'. '.'.' '.,..,.'. ..v...\V~fnt~ ~ 'hi .,.." ,..,' 21.42 Pass: Major Risk 11.91 Pass: Major Risk 5.78 Pass: Major Risk 39.90 Pass: Major Risk 48.82 Pass: Major Risk 69.84 Pass: Major Risk 131.61 Pass: Major Risk 148.91 Pass: Major Risk 161.58 Pass: Major Risk 115.20 Pass: Major Risk 189,38 Pass: Major Risk 206.44 Pass: Major Risk 220.13 Pass: Major Risk 231.78 Pass: Major Risk .~" '- ", I '" 'S § ~ 00 v :::. ~ q;; c :l j'j' :::. PHILd....s Alaska, Inc. A Subsidiary of PHILLIPS PETROLEUM COMPANY ( Phillips Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510 Ms. Cammy Oechsli Taylor Commissioner Alaska Oil and Gas Conservation Commission 333 West th Avenue, Suite 100 Anchorage, AK 99501 (907) 279-1433 RECEIVED JUN 29 2001 June 28, 2001 Alaska Oil & Gas Cans. Commission Anchorage Re: Application for Permit to Drill: KRU 2N-304 Surface Location: Target Location: Bottom Hole Location: 3'FNL,515'FEL,Sec.3,T9N,R7E 707'FNL,147'FEL,Sec.35,T10N,R7E 560'FNL,24'FWL,Sec.36,T10N,R7E Dear Ms. Commissioner: Phillips Alaska, Inc. hereby applies for a Permit to Drill an onshore development well KRU 2N-304. The well will be drilled and completed using Nabors 16E. Please utilize documents on file for this rig. Subject to AOGCC approval, fluids and cuttings generated from drilling the well will be pumped down an approved and existing annulus on Drillsite 2N, or hauled to an approved Prudhoe or GKA Class II disposal wel, The following people are the designated contacts for reporting responsibilities to the Commission: A) Completion Report Sharon Allsup-Drake, Drilling Technologist (20 AAC 25.070) 263-4612 B) Geologic Data and Logs (20 AAC 25.071) Bill Morris, Geologist 263-4588 If you have any questions or require further information, please contact Brian Noel at (907) 265-6979 or James Trantham at (907) 265-6434. ~ , ~-- \ rw,~ ames Trantham Drilling Engineering Supervisor I~ II.'. ~ American Express~ Cash Advance Draft 148 PAY TO THE ORDER OF DATE 28 J (./~ z.tc;/ 82--40/1021 It-ðGcc sl/oo.oo -- DOLLARS Issued by Integrated Payment System, Inc. E"Blewood. CoIoDdo PERIOD ENDING Payable at Norwest Bank of Grand junction - Downtown. NA Grand junction. CoIoDdo I: ~ 0 è ~ 0 0 ... 0 0 I: a 5 III 0 ~ ? 5 0 0 0 5 :Ii b III 0 ~... 8 CHECK 1 STANDARD LETTER DEVELOPMENT v DEVELOPMENT REDRILL EXPLORATION INJECTION WELL INJECTION WELL RED RILL ( TRANSMIT AL LETTER CHECK LIST CIRCLE APPROPRIATE LETTER/PARAGRAPHS TO BE INCLUDED IN TRANSMITTAL LETTER ( WELL NAME CHECK WHAT APPLIES ADD-ONS (OPTIONS) MULTILATERAL (If api number last two (2) digits are between 60-69) PILOT HOLE (PH) ANNULAR DJSPOSAL WNO ANNULAR DISPOSAL <-> YES ANNULAR DISPOSAL THIS WELL ZtJ/?64 "CLUE" The permit is for a new wellbore segment of existing well . Permit No, API No. . Production should continue to be reported as a function of the original API number stated above. In accordance with 20 AAC 25.005(t), all records, data and logs acquired for the pilot hole must be clearly differentiated in both name (name on permit plus PH) and API number (50 -70/80) from records, data and logs acquired for well (name on permit). Annular disposal has not been requested. . . Annular Disposal of drilling wastes will not be approved. . . Annular Disposal of drilling wastes will not be approved. . . DISPOSAL INTO OTHER Please note that an disposal of fluids generated. .. ANNULUS ( V) YES + SPACING EXCEPTION Templates are located m drive\jody\templates zAf~ Enclosed is the approved application for permit to drill the above referenced well. The permit is approved subject to full compliance with 20 AAC 25.055. Approval to peñorate and produce is contingent upon issuance of a conservation order approving a spacing exception. (Companv Name) will assume the liability of any protest to the spacing exception that may occur. WELL PERMIT CHECKLIST FIELD & POOL <-¡ ~d / h .5 " ADMINISTRATION 1. Permittee attached. . . . . . . . . . . . . . . . . . . . . . . 2. Lease number appropriate. . . . . . . . . . . . . . . . . . . 3. Unique well name and number. .. . . . . . . . . . . . . . . . 4. Well located in a defined pool.. . . . . . . . . . . . . . . . . 5. Well located proper distance from drilling unit boundary. . . . 6. Well located proper distance from other wells.. . . . . . . . . 7. Sufficient acreage available in drilling unit.. . . . . . . . . . . 8. If deviated, is well bore plat included.. . . . . . . . . . . . . . 9. Operator only affected party.. . . . . . . . . . . . . . . . . . 10. Operator has appropriate bond in force. . . . . . . . . . . . . 11. Permit can be issued without conservation order. . . . . . . . 12. Permit can be issued without administrative approval.. . . . . 13. Can permit be approved before 15-day wait.. . . . . . . . . . 14. Conductor string provided. . . . . . . . . . . . . . . . . . . 15. Surface casing protects all known USDWs. . .'. . . . . . . . 16. CMT vol adequate to circulate on conductor & surf csg. . . . . 17. CMT vol adequate to tie-in long string to surf csg. . . . . . . . 18. CMT will cover all known productive horizons. . . . . . . . . . 19. Casing designs adequate for C, T, 8 & permafrost. . . . . . . 20. Adequate tankage or reserve pit.. . . . . . . . . . . . . . . . 21. If a re-drill, has a 10-403 for abandonment been approved. . . 22. Adequate wellbore separation proposed.. . . . . . . . . . . . Y N 23. If diverter required, does it meet regulations. . . . . . . . . . N 24. Drilling fluid program schematic & equip list adequate. . . . . N 25. 80PEs, do they meet regulation. . . . . . . . . . . . . . . . Y N 26. 80PE press rating appropriate; test to psig. Y N 27. Choke manifold complies w/API RP-53 (May 84). . . . . . . . Y 'N 28. Work will occur without operation shutdown. . . . . . . . . . , N 29. Is presence of H2S gas probable.. . . . . . . . . . . . . . . . Y ~ 30. Permit can be issued w/o hydrogen sulfide measures. . . . . Y N / 31. Data presented on potential overpressure zones. . . . . . . Y Y. ø ./Î 32. Seismic analysis of shallow gas zones. . . . . . . . . . . . . Y/ N ¿f~ .. /-/ R -,D}T~ 33. Seabed condition survey (if off-shore). . . . . . . . . . . . . //y N / ., ANNUL~DISp/OSAL3345' C;~t:ct name/Phon:. for WeekdlY Ptrh~grelSS reports [exploratory oyIÝJ Y N '1)",>\"".'»\ ì "-\è "'" orr~ ~\\ ~,<:""\o.'!.i ~\o..\<,..""r\\ """'I 11>«: <>'l'pI~';)~. . I proper cemen Ing recor s, IS p an ~'Il Ç\ftbt- c ~£...f..'t ~ or- D t:L) u.... 6 oP . . . (A) will contain waste in asuitable receiving zone; . . . . . . Y N r l~ ' O. \ .' -...) "'-R.Allo~ '. ,- IV "'\ (8) will not contaminate. freshwater; or cause drilling w Y N to surface; . (C) will not impair mechanical integrity of t ell used for disposal; Y N (D) will not damage producing format' or impair recovery from a Y N pool; and E will not circumvent 20- GEOLOGY: ENGINEERING: ~þ~ PR ;:~ì~1 ENGINEERING APPR DATE ~t¡tÞ ~{¡,7tp/ /'ff:!m ~ / r;;- GEOLOGY APPR DATE 25.252 or 20 AAC 25.412. Y N UIC/Annular COMMISSION: WM 89s-(.of JM~ÎIII/D J WELL NAME .0. / V! e.V ,-- ~ J ./ t~W ,-- c:\msoffice\wordian\diana\checklist (rev. 11/01/100) PROGRAM: exp - dev 'r- redrll GEOL AREA g.- <7 c> , Y N Y N Y N Y N Y N Y N Y N Y N Y N Y N Y N Y N Y N N N Y N Y N Y N Y N Y. N wellbore seg _ann. disposal para req - III C C) ON/OFF SHORE D^ ) . . serv UNIT# c 0 Z 0 -I :e ~ ( -I m P~~~_J J'4~~ ~i 1'..; ~ Ll/l ÁJ - --... - Z -I :::r: - fA » ::0 m » ( Comments/Instructions: j ~. ~' Well History File APPENDIX " Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. . To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special' effort has been made to chronologically , . organize this category of information. ~I (: aO)-¡30 Sperry-Sun Drilling Services LIS Scan Utility $Revision: 3 $ LisLib $Revision: 4 $ Wed Oct 24 11:52:55 2001 Reel Header Service name............ .LISTPE Date.....................01/10/24 Origin...................STS Reel Name............... . UNKNOWN Continuation Number..... .01 Previous Reel Name...... . UNKNOWN Comments...... .'..'....' .STS LIS Tape Header Service name............ .LISTPE Date.....................01/10/24 Origin...................STS Tape Name............... . UNKNOWN Continuation Number..... .01 Previous Tape Name...... . UNKNOWN Comments................ .STS LIS Physical EOF Comment Record TAPE HEADER Kuparuk River Unit MWD/MAD LOGS # WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: # JOB DATA (Tarn) JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 2 AK-MM-11122 T. MCGUIRE R. ROSS # SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: MSL 0) # WELL CASING RECORD Writing Library. Scientific Technical Services Writing Library. Scientific Technical Services 2N-304 PB1 501032038270 PHILLIPS Alaska, Inc. Sperry-Sun Drilling Services 24-0CT-01 MWD RUN 3 AK-MM-11122 T. MCGUIRE R. ROSS 3 9N 7E 3 515 .00 153.63 119.30 ( (' 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 6.750 7.625 2930.0 # REMARKS: 1. ALL DEPTHS ARE MEASURED DEPTHS (MD) UNLESS OTHERWISE NOTED. 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTH (TVD). 3. MWD RUN 1 WAS DIRECTIONAL ONLY AND IS NOT PRESENTED. 4. MWD RUNS 2 & 3 WERE DIRECTIONAL WITH DUAL GAMMA RAY (DGR) UTILIZING GEIGER-MUELLER TUBE DETECTORS, ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4), COMPENSATED THERMAL NEUTRON POROSITY (CTN), AND STABILIZED LITHO-DENSITY (SLD). 5. MWD DATA ARE CONSIDERED PDC PER E-MAIL FROM D. SCHWARTZ, PHILLIPS ALASKA, DATED 10/02/01. 6. MWD RUNS 2 & 3 REPRESENT WELL 2N-304 PB1 WITH API#:50-103-20382-70. THIS WELL REACHED A TOTAL DEPTH (TD) OF 10415'MD / 5932'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 TNPS = SMOOTHED MATRIX, FIXED SIZE) . SBD2 = SMOOTHED BULK DENSITY-COMPENSATED (LOW-COUNT BIN) . SCO2 = SMOOTHED STANDOFF CORRECTION (LOW-COUNT BIN). SNP2 = SMOOTHED NEAR DETECTOR ONLY PHOTOELECTRIC ABSORPTION FACTOR (LOW-COUNT BIN) . SLDSLIDE = NON-ROTATED INTERVALS ACCOUNTING FOR BIT-TO-SENSOR DISTANCE. FORMATION EXPOSURE TIME. THERMAL NEUTRON POROSITY (SANDSTONE HOLE PARAMETERS USED IN POROSITY LOG PROCESSING: HOLE SIZE: MUD WEIGHT: MUD FILTRATE SALINITY: FORMATION WATER SALINITY: 6.75" 9.6 ppg 500-800 ppm chlorides 19,149 ppm chlorides (' FLUID DENSITY: MATRIX DENSITY: LITHOLOGY: $ l ~. 1.0 g/cm3 2.65 g/cm3 SANDSTONE File Header Service name............ .STSLIB.001 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .01/10/24 Maximum Physical Record. .65535 File Type................LO Previous File Name...... .STSLIB.OOO Comment Record FILE HEADER FILE NUMBER: EDITED MERGED MWD Depth shifted and DEPTH INCREMENT: # FILE SUMMARY PBU TOOL CODE NPHI NCNT FCNT GR RPX RPS RPM RPD FET PEF RHOB DRHO ROP $ 1 clipped curves; all bit runs merged. .5000 START DEPTH 2840.5 2840.5 2840.5 2875.5 2882.5 2882.5 2882.5 2882.5 2882.5 2884.5 2926.0 2926. 0 2933.5 STOP DEPTH 10329.0 10329.0 10329.5 10366.0 10373.0 10373.0 10373.0 10373.0 10373.0 10344.5 10344.5 10344.5 10415.0 # BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH -------- BASELINE DEPTH $ # MERGED PBU MWD MWD $ DATA SOURCE TOOL CODE # REMARKS: BIT RUN NO 2 3 MERGED MAIN PASS. $ MERGE TOP 2840.5 8550.5 MERGE BASE 8550.5 10415.0 # Data Format Specification Record Data Record Type..................O Data Specification Block Type.....O Logging Direction................ . Down Optical log depth units.......... .Feet Data Reference Point............. . Undefined Frame Spacing................... ..60 .1IN Max frames per record............ . Undefined Absent value......................-999 ( ( Depth Units....................... Datum Specification Block sub-type...O Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD FT/H 4 1 68 4 2 GR MWD API 4 1 68 8 3 RPX MWD OHMM 4 1 68 12 4 RPS MWD OHMM 4 1 68 16 5 RPM MWD OHMM 4 1 68 20 6 RPD MWD OHMM 4 1 68 24 7 FET MWD HOUR 4 1 68 28 8 NPHI MWD PU-S 4 1 68 32 9 FCNT MWD CNTS 4 1 68 36 10 NCNT MWD CNTS 4 1 68 40 11 RHOB MWD G/CM 4 1 68 44 12 DRHO MWD G/CM 4 1 68 48 13 PEF MWD BARN 4 1 68 52 14 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 2840.5 10415 6627.75 15150 2840.5 10415 ROP MWD FT/H 0 440.31 193.821 14964 2933.5 10415 GR MWD API 29.36 272.91 126.124 14982 2875.5 10366 RPX MWD OHMM 1.22 154.86 4.71006 14982 2882.5 10373 RPS MWD OHMM 1. 23 2000 5.38535 14982 2882.5 10373 RPM MWD OHMM 1.28 2000 8.48461 14982 2882.5 10373 RPD MWD OHMM 0.16 2000 11.6278 14982 2882.5 10373 FET MWD HOUR 0.17 65.56 1.27298 14982 2882.5 10373 NPHI MWD PU-S 11.31 63.1 33.2803 14978 2840.5 10329 FCNT MWD CNTS 100.23 950.44 285.882 14979 2840.5 10329.5 NCNT MWD CNTS 13959.4 36494.1 21257.8 14978 2840.5 10329 RHOB MWD G/CM 1.98 3.26 2.37039 14838 2926 10344.5 DRHO MWD G/CM -0.03 0.89 0.0841603 14838 2926 10344.5 PEF MWD BARN 1.43 13.39 3.9431 14921 2884.5 10344.5 First Reading For Entire File......... .2840.5 Last Reading For Entire File.......... .10415 File Trailer Service name............ .STSLIB.001 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .01/10/24 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...... .01/10/24 ,1,1 (. Maximum Physical Record. .65535 File Type............... .LO Previous File Name...... .STSLIB.001 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE NCNT FCNT NPHI GR RPD FET RPM RPS RPX PEF DRHO RHOB ROP $ 2 ( header data for each bit run in separate files. 2 .5000 START DEPTH 2840.5 2840.5 2840.5 2875.5 2882.5 2882.5 2882.5 2882.5 2882.5 2884.5 2926.0 2926.0 2933.5 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TO DRI LLER (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 SLD CTN $ # STOP DEPTH 8454.5 8455.0 8454.5 8491.5 8498.5 8498.5 8498.5 8498.5 8498.5 8470.0 8470.0 8470.0 8550.5 BOTTOM) TOOL TYPE DUAL GAMMA RAY ELECTROMAG. RESIS. 4 STABILIZED LITHO DEN COMP THERMAL NEUTRON 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): 20-JUL-01 Insite 66.16 Memory 8550.0 62.7 69.4 TOOL NUMBER PB02091FHAGR4 PB02091FHAGR4 PB02091FHAGR4 PB02091FHAGR4 6.750 Water 9.60 44.0 10.8 550 Based (' ( FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: 5.0 1.700 .980 3.200 2.200 70.0 127.0 70.0 70.0 # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type..................O Data Specification Block Type.....O Logging Direction................ . Down Optical log depth units.......... .Feet Data Reference Point............. . Undefined Frame Spacing.................... .60 .1IN Max frames per record............ .Undefined Absent value......................-999 Depth Units....................... Datum Specification Block sub-type...O Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD020 FT/H 4 1 68 4 2 GR MWD020 API 4 1 68 8 3 RPX MWD020 OHMM 4 1 68 12 4 RPS MWD020 OHMM 4 1 68 16 5 RPM MWD020 OHMM 4 1 68 20 6 RPD MWD020 OHMM 4 1 68 24 7 FET MWD020 HOUR 4 1 68 28 8 NPHI MWD020 PU-S 4 1 68 32 9 FCNT MWD020 CNTS 4 1 68 36 10 NCNT MWD020 CNTS 4 1 68 40 11 RHOB MWD020 G/CM 4 1 68 44 12 DRHO MWD020 G/CM 4 1 68 48 13 PEF MWD020 BARN 4 1 68 52 14 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 2840.5 8550.5 5695.5 11421 2840.5 8550.5 ROP MWD020 FT/H 0 440.31 210.824 11235 2933.5 8550.5 GR MWD020 API 29.36 272.91 123.923 11233 2875.5 8491.5 RPX MWD020 OHMM 1.46 154.86 4.7809 11233 2882.5 8498.5 RPS MWD020 OHMM 1.49 2000 5.74809 11233 2882.5 8498.5 RPM MWD020 OHMM 1.56 2000 9.89579 11233 2882.5 8498.5 RPD MWD020 OHMM 0.16 2000 14.038 11233 2882.5 8498.5 FET MWD020 HOUR 0.17 65.56 1.27693 11233 2882.5 8498.5 NPHI MWD020 PU-S 13.89 63.1 34.7425 11229 2840.5 8454.5 FCNT MWD020 CNTS 100.23 915.23 259.429 11230 2840.5 8455 NCNT MWD020 CNTS 13959.4 34592.5 20504 11229 2840.5 8454.5 ( RHOB MWD020 G/CM DRHO MWD020 G/CM PEF MWD020 BARN 1.98 -0.03 1.43 2.74 0.6 13.39 2.3371111089 0.0854432 11089 3.8997811172 First Reading For Entire File........ ..2840.5 1ast Reading For Entire File.......... .8550.5 File Trailer Service name............ .STS1IB.002 Service Sub 1evel Name... Version Number.......... .1.0.0 Date of Generation...... .01/10/24 Maximum Physical Record. .65535 File Type............... .10 Next File Name.......... .STS1IB.003 Physical EOF File Header Service name............ .STS1IB.003 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .01/10/24 Maximum Physical Record. .65535 File Type............... .LO Previous File Name...... .STSLIB.002 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE NPHI NCNT FCNT PEF RHOB DRHO GR RPM RPS RPD FET RPX ROP $ 3 ( 2926 2926 2884.5 8470 8470 8470 header data for each bit run in separate files. 3 .5000 START DEPTH 8455.0 8455.0 8455.5 8470.5 8470.5 8470.5 8492.0 8499.0 8499.0 8499.0 8499.0 8499.0 8551.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: STOP DEPTH 10329.0 10329.0 10329.5 10344.5 10344.5 10344.5 10366.0 10373.0 10373.0 10373.0 10373.0 10373.0 10415.0 22-JUL-01 Insite 66.16 (' DATA TYPE (MEMORY OR REAL-TIME): TO 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 SLD CTN $ BOTTOM) TOOL TYPE DUAL GAMMA RAY ELECTROMAG. RESIS. 4 STABILIZED LITHO DEN COMP THERMAL NEUTRON # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type................ ..0 Data Specification Block Type... ..0 Logging Direction............... ..Down Optical log depth units.......... .Feet Data Reference Point............. . Undefined Frame Spacing.................... .60 .1IN Max frames per record............ . Undefined Absent value..................... .-999 Depth Units....................... Datum Specification Block sub-type...O ( Memory 10415.0 38.5 59.2 TOOL NUMBER PB02091FHAGR4 PB02091FHAGR4 PB02091FHAGR4 PB02091FHAGR4 6.750 Water 9.60 44.0 9.9 450 4.8 Based 3.200 1.890 3.500 2.700 80.0 140.0 80.0 80.0 Name Service Order DEPT ROP MWD030 GR MWD030 Units Size Nsam Rep Code Offset Channel FT 4 1 68 0 1 FT/H 4 1 68 4 2 API 4 1 68 8 3 ( ( RPX MWD030 OHMM 4 1 68 12 4 RPS MWD030 OHMM 4 1 68 16 5 RPM MWD030 OHMM 4 1 68 20 6 RPD MWD030 OHMM 4 1 68 24 7 FET MWD030 HOUR 4 1 68 28 8 NPHI MWD030 PU-S 4 1 68 32 9 FCNT MWD030 CNTS 4 1 68 36 10 NCNT MWD030 CNTS 4 1 68 40 11 RHOB MWD030 G/CM 4 1 68 44 12 DRHO MWD030 G/CM 4 1 68 48 13 PEF MWD030 BARN 4 1 68 52 14 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 8455 10415 9435 3921 8455 10415 ROP MWD030 FT/H 3.68 379.15 142.594 3729 8551 10415 GR MWD030 API 55.55 213.49 132.718 3749 8492 10366 RPX MWD030 OHMM 1.22 19.82 4.4978 3749 8499 10373 RPS MWD030 OHMM 1.23 15.93 4.29849 3749 8499 10373 RPM MWD030 OHMM 1.28 13.85 4.25632 3749 8499 10373 RPD MWD030 OHMM 1.31 14.66 4.406 3749 8499 10373 FET MWD030 HOUR 0.18 26.57 1.26114 3749 8499 10373 NPHI MWD030 PU-S 11.31 42.69 28.9007 3749 8455 10329 FCNT MWD030 CNTS 209.83 950.44 365.122 3749 8455.5 10329.5 NCNT MWD030 CNTS 17554.6 36494.1 23515.5 3749 8455 10329 RHOB MWD030 G/CM 2.24 3.26 2.46883 3749 8470.5 10344.5 DRHO MWD030 G/CM -0.02 0.89 0.0803654 3749 8470.5 10344.5 PEF MWD030 BARN 2.61 7.01 4.07222 3749 8470.5 10344.5 First Reading For Entire File......... .8455 Last Reading For Entire File.......... .10415 File Trailer Service name............ .STSLIB.003 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .01/10/24 Maximum Physical Record. .65535 File Type............... .LO Next File Name.......... .STSLIB.004 Physical EOF Tape Trailer Service name............ .LISTPE Date.....................01/10/24 Origin...................STS Tape Name............... . UNKNOWN Continuation Number..... .01 Next Tape Name.......... . UNKNOWN Comments................ .STS LIS Writing Library. Scientific Technical Services Reel Trailer Service name............ .LISTPE Date.....................01/10/24 (' Origin...................STS Reel Name.............. ..UNKNOWN Continuation Number..... .01 Next Reel Name.......... . UNKNOWN Comments................ .STS LIS Physical EOF Physical EOF End Of LIS File Writing Library. ( Scientific Technical Services ( { Sperry-Sun Drilling Services LIS Scan Utility 2n-304.tapx $Revision: 3 $ LisLib $Revision: 4 $ Fri Nov 02 14:44:19 2001 Reel Header Service name........... ..LISTPE Date.....................01/11/02 Origin...................STS Reel Name............... . UNKNOWN Continuation Number.. ... .01 Previous Reel Name..... ..UNKNOWN Comments................ .STS LIS Tape Header Service name........... ..LISTPE Date.....................01/11/02 Origin...................STS Tape Name............... . UNKNOWN Continuation Number..... .01 Previous Tape Name..... ..UNKNOWN Comments................ .STS LIS Physical EOF Comment Record TAPE HEADER Kuparuk River Unit MWD/MAD LOGS # WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: # JOB DATA (Tarn) JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 2 AK-MM-11122 P. SMITH M. THORTON # SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: MSL 0) # WELL CASING RECORD Writing Library. Scientific Technical Services Writing Library. Scientific Technical Services 2N-304 501032038200 PHILLIPS Alaska, Inc. Sperry-Sun Drilling Services 02-NOV-01 3 9N 7E 3 515 .00 153.63 119.30 OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 6.750 7.625 2930.0 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING # REMARKS: 1. THIS WELL WAS SIDETRACKED FROM WELL 2N-304 PB1 AT ABOUT 2939'MD/ 2309.08'TVD(JUST BELOW THE 7 5/8" CASING SHOE). THE TIE-IN POINT WAS 2885.51'MD/2288.17'TVD. 2N-304 PB1 WAS ABANDONED Page 1 a Of,,- /Sö (' ( 2n-304.tapx AFTER PROBLEMS WERE ENCOUNTERED WHILE CEMENTING THE PRODUCTION CASING. THE BOTTOM HOLE LOCATION FOR THE REDRILL WAS MOVED ABOUT 300' TO THE SOUTH OF THAT OF 2N-304 PB1. 2. ALL DEPTHS ARE MEASURED DEPTHS (MD) UNLESS OTHERWISE NOTED. 3. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTH (TVD) UNLESS OTHERWISE NOTED. 4. MWD RUN 1 (2N-304 PB1) WAS DIRECTIONAL ONLY AND IS NOT PRESENTED. 5. MWD RUN 2 WAS DIRECTIONAL WITH DUAL GAMMA RAY (DGR) UTILIZING GEIGER-MUELLER TUBE DETECTORS, ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4), COMPENSATED THERMAL NEUTRON POROSITY (CTN), AND STABILIZED LITHO-DENSITY (SLD). 6. THE SLD TOOL FAILED AT 8625'MD/4868'TVD, SO THERE ARE NO DENSITY DATA BELOW THAT DEPTH. 7. FIELD NEUTRON DATA WERE PROCESSED USING A FORMATION WATER SALINITY OF 50,000 PPM CHLORIDES. DATA FOR FINAL PRESENTATION WERE REPROCESSED USING A SALINITY VALUE OF 19,149 PPM CHLORIDES. 8. MWD DATA ARE CONSIDERED PDC PER E-MAIL FROM D. SCHWARTZ, PHILLIPS ALASKA, DATED 10102/01. 9. MWD RUN 2 REPRESENTS WELL 2N-304 WITH API#: 50-103-20382-00. THIS WELL REACHED A TOTAL DEPTH (TD) OF 10052'MD 1 5874.70'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. TNPS = SMOOTHED THERMAL NEUTRON POROSITY (SANDSTONE MATRIX, FIXED HOLE SIZE) . SBD2 = SMOOTHED BULK DENSITY-COMPENSATED (LOW-COUNT BIN) . SC02 = SMOOTHED STANDOFF CORRECTION (LOW-COUNT BIN). SNP2 = SMOOTHED NEAR DETECTOR ONLY PHOTOELECTRIC ABSORPTION FACTOR (LOW-COUNT BIN) . SLDSLIDE = NON-ROTATED INTERVALS ACCOUNTING FOR BIT-TO-SENSOR DISTANCE. PARAMETERS USED IN POROSITY LOG PROCESSING: HOLE SIZE: MUD WEIGHT: MUD FILTRATE SALINITY: FORMATION WATER SALINITY: 6.75" 9.6 ppg 500-800 ppm chlorides 19,149 ppm chlorides Page 2 ( FLUID DENSITY: MATRIX DENSITY: LITHOLOGY: $ File Header Service name. .... ........STSLIB.001 Service Sub Level Name... Version Number....... ....1.0.0 Date of Generation...... .01/11/02 Maximum Physical Record..65535 File Type........ ......, .LO Previous File Name..... ..STSLIB.OOO Comment Record FI LE HEADER FILE NUMBER: EDITED MERGED MWD Depth shifted and DEPTH INCREMENT: # FILE SUMMARY PBU TOOL CODE FCNT NCNT NPHI PEF DRHO RHOB GR FET RPD RPM RPS RPX ROP $ 1 f 2n-304.tapx 1.0 g/cm3 2.65 g/cm3 SANDSTONE clipped curves; all bit runs merged. .5000 START DEPTH 2839.0 2839.5 2839.5 2853.5 2857.5 2857.5 2874.5 2881.5 2881.5 2881.5 2881.5 2881.5 2930.5 STOP DEPTH 9959.0 9959.0 9959.0 8645.0 8628.0 8628.0 9995.5 10002.5 10002.5 10002.5 10002.5 10002.5 10052.0 # 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 2 2839.0 10052.0 $ # REMARKS: MERGED MAIN PASS. $ # Data Format Specification Record Data Record Type......... .........0 Data Specification Block Type.....O Logging Direction....... ......... . Down Optical log depth units. ......... .Feet Data Reference Point.... ........ ..Undefined Frame Spacing.................... .60 .1IN Max frames per record............ .Undefined Absent value......................-999 Depth Units....................... Datum Specification Block sub-type. ..0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD FT/H 4 1 68 4 2 GR MWD API 4 1 68 8 3 RPX MWD OHMM 4 1 68 12 4 RPS MWD OHMM 4 1 68 16 5 RPM MWD OHMM 4 1 68 20 6 RPD MWD OHMM 4 1 68 24 7 FET MWD HOUR 4 1 68 28 8 NPHI MWD PU-S 4 1 68 32 9 FCNT MWD CNTS 4 1 68 36 10 Page 3 ( NCNT MWD RHOB MWD DRHO MWD PEF MWD 4 4 4 4 CNTS G/CM G/CM BARN (' 1 1 1 1 68 68 68 68 2n-304.tapx 40 11 44 12 48 13 52 14 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 2839 10052 6445.5 14427 2839 10052 ROP MWD FT/H 0.75 401.49 185.543 14244 2930.5 10052 GR MWD API 39.79 247.69 125.964 14243 2874.5 9995.5 RPX MWD OHMM 1.13 1805.62 4.56146 14243 2881.5 10002.5 RPS MWD OHMM 0.89 1635.38 4.74618 14243 2881.5 10002.5 RPM MWD OHMM 0.22 2000 14.814 14243 2881.5 10002.5 RPD MWD OHMM 0.06 2000 15.5599 14243 2881.5 10002.5 FET MWD HOUR 0.19 574.6 5.80247 14243 2881. 5 10002.5 NPHI MWD PU-S 12.77 60.21 34.7418 14240 2839.5 9959 FCNT MWD CNTS 101.51 1001.25 280.487 14241 2839 9959 NCNT MWD CNTS 13789.1 35058.2 20914.3 14240 2839.5 9959 RHOB MWD G/CM 1.4 3.28 2.27748 11542 2857.5 8628 DRHO MWD G/CM -0.07 1. 02 0.057957 11542 2857.5 8628 PEF MWD BARN 0.2 13.46 3.4257 11584 2853.5 8645 First Reading For Entire File.... .... ..2839 Last Reading For Entire File......... ..10052 File Trailer Service name........... ..STSLIB.001 Service Sub Level Name... Version Number....... ....1.0.0 Date of Generation... ....01/11/02 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.... ...01/11/02 Maximum Physical Record..65535 File Type................LO Previous File Name...... .STSLIB.001 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE FCNT NCNT NPHI PEF DRHO RHOB GR FET RPD RPM RPS RPX ROP 2 header data for each bit run in separate files. 2 .5000 START DEPTH 2839.0 2839.5 2839.5 2853.5 2857.5 2857.5 2874.5 2881. 5 2881. 5 2881.5 2881. 5 2881. 5 2930.5 STOP DEPTH 9959.0 9959.0 9959.0 8645.0 8628.0 8628.0 9995.5 10002.5 10002.5 10002.5 10002.5 10002.5 10052.0 Page 4 ( $ # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE DGR EWR4 SLD CTN $ BOTTOM) TOOL TYPE DUAL GAMMA RAY ELECTROMAG. RESIS. 4 STABILIZED LITHO DEN COMP THERMAL NEUTRON # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type............. .....0 Data Specification Block Type.....O Logging Direction................ . Down Optical log depth units.......... .Feet Data Reference Point............. .Undefined Frame Spacing.................... .60 .1IN Max frames per record............ .Undefined Absent value................. .... .-999 Depth Units....................... Datum Specification Block sub-type...O (I.; 1'1 \ 2n-304.tapx ll-AUG-01 Insite 66.16 Memory 10052.0 2939.0 10052.0 35.6 66.4 TOOL NUMBER PBO2035HAGR4 PBO2035HAGR4 PBO2035HAGR4 PBO2035HAGR4 9.875 LSND 9.70 45.0 10.9 500 4.6 2.200 1. 020 1. 980 1. 950 64.0 145.8 64.0 64.0 Name Service Order units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD020 FT/H 4 1 68 4 2 GR MWD020 API 4 1 68 8 3 RPX MWD020 OHMM 4 1 68 12 4 RPS MWD020 OHMM 4 1 68 16 5 RPM MWD020 OHMM 4 1 68 20 6 RPD MWD020 OHMM 4 1 68 24 7 FET MWD020 HOUR 4 1 68 28 8 NPHI MWD020 PU-S 4 1 68 32 9 Page 5 ~ \ ( 2n-304.tapx FCNT MWD020 CNTS 4 1 68 36 10 NCNT MWD020 CNTS 4 1 68 40 11 RHOB MWD020 G/CM 4 1 68 44 12 DRHO MWD020 G/CM 4 1 68 48 13 PEF MWD020 BARN 4 1 68 52 14 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 2839 10052 6445.5 14427 2839 10052 ROP MWD020 FT/H 0.75 401.49 185.543 14244 2930.5 10052 GR MWD020 API 39.79 247.69 125.964 14243 2874.5 9995.5 RPX MWD020 OHMM 1.13 1805.62 4.56146 14243 2881.5 10002.5 RPS MWD020 OHMM 0.89 1635.38 4.74618 14243 2881. 5 10002.5 RPM MWD020 OHMM 0.22 2000 14.814 14243 2881.5 10002.5 RPD MWD020 OHMM 0.06 2000 15.5599 14243 2881. 5 10002.5 FET MWD020 HOUR 0.19 574.6 5.80247 14243 2881.5 10002.5 NPHI MWD020 PU-S 12.77 60.21 34.7418 14240 2839.5 9959 FCNT MWD020 CNTS 101.51 1001.25 280.487 14241 2839 9959 NCNT MWD020 CNTS 13789.1 35058.2 20914.3 14240 2839.5 9959 RHOB MWD020 G/CM 1.4 3.28 2.27748 11542 2857.5 8628 DRHO MWD020 G/CM -0.07 1. 02 0.057957 11542 2857.5 8628 PEF MWD020 BARN 0.2 13.46 3.4257 11584 2853.5 8645 First Reading For Entire File...... ... .2839 Last Reading For Entire File.......... .10052 File Trailer Service name..... ...... ..STSLIB.002 Service Sub Level Name... Version Number..... ..... .1.0.0 Date of Generation... ... .01/11/02 Maximum Physical Record. .65535 File Type.. ....... ...... .LO Next File Name... ..,... ..STSLIB.003 Physical EOF Tape Trailer Service name........ .... .LISTPE Date.....................01/11/02 Origin...................STS Tape Name........... .... . UNKNOWN Continuation Number.... ..01 Next Tape Name....... ... . UNKNOWN Comments............ .... .STS LIS Writing Library. Scientific Technical Services Reel Trailer Service name......... ... .LISTPE Date.....................01/11/02 Origin...................STS Reel Name............ ... . UNKNOWN Continuation Number.. ... .01 Next Reel Name.... ..... ..UNKNOWN Comments.................STS LIS Writing Library. Scientific Technical Services Physical EOF Physical EOF End Of LIS File Page 6