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Home My WebLink About206-122C:\Users\grgluyas\AppData\Local\Microsoft\Windows\INetCache\Content.Outlook\I1OGWE08\2024-05-23_23026_KRU_1J-115_EVCamera_Transmittal.docx DELIVERABLE DISCRIPTION Ticket # Field Well # API # Log Description Log Date 23026 KRU 1J-115 50-029-23320-00 EV Camera (part1) 23-May-24 DELIVERED TO Company & Address DIGITAL FILE # of Copies LOG PRINTS # of Prints CD’s # of Copies 1 AOGCC ***Please note there are 24 images and 37 videos. I was unable to unable to just do 1 Attn: Natural Resources Technician upload. There are 4 parts to this upload*** 333 W. 7th Ave., Suite 100 Anchorage, Ak. 99501-3539 Delivered By: CPAI Sharefile ______________________________ _____________________________________ Date received Signature ______________________________ ______________________________________ PLEASE RETURN COPY VIA EMAIL TO: DIANE.WILLIAMS@READCASEDHOLE.COM READ CASED HOLE, INC., 4141 B STREET, SUITE 308, ANCHORAGE, AK 99503 PHONE: (907)245-8951 E-MAIL : READ-Anchorage@readcasedhole.com WEBSITE : WWW.READCASEDHOLE.COM 206-122 T38876 Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2024.06.06 10:08:46 -08'00' C:\Users\grgluyas\AppData\Local\Microsoft\Windows\INetCache\Content.Outlook\I1OGWE08\2024-05-16_21180_KRU_1J-115_CaliperSurvey_Transmittal.docx DELIVERABLE DISCRIPTION Ticket # Field Well # API # Log Description Log Date 21180 KRU 1J-115 50-029-23320-00 Caliper Survey 16-May-24 DELIVERED TO Company & Address DIGITAL FILE # of Copies LOG PRINTS # of Prints CD’s # of Copies 1 AOGCC Attn: Natural Resources Technician 333 W. 7th Ave., Suite 100 Anchorage, Ak. 99501-3539 Delivered By: CPAI Sharefile ______________________________ ______________________________________ Date received Signature PLEASE RETURN COPY VIA EMAIL TO: DIANE.WILLIAMS@READCASEDHOLE.COM READ CASED HOLE, INC., 4141 B STREET, SUITE 308, ANCHORAGE, AK 99503 PHONE: (907)245-8951 E-MAIL : READ-Anchorage@readcasedhole.com WEBSITE : WWW.READCASEDHOLE.COM 206-122 T38863 Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2024.05.30 10:27:18 -08'00' C:\Users\grgluyas\AppData\Local\Microsoft\Windows\INetCache\Content.Outlook\I1OGWE08\2024-05-17_22181_KRU_1J-115_EVCameraJob_Transmittal.docx DELIVERABLE DISCRIPTION Ticket # Field Well # API # Log Description Log Date 21181 KRU 1J-115 50-029-23320-00 EV Camera Job 17-May-24 DELIVERED TO Company & Address DIGITAL FILE # of Copies LOG PRINTS # of Prints CD’s # of Copies 1 AOGCC Attn: Natural Resources Technician 333 W. 7th Ave., Suite 100 Anchorage, Ak. 99501-3539 Delivered By: CPAI Sharefile ______________________________ ______________________________________ Date received Signature PLEASE RETURN COPY VIA EMAIL TO: DIANE.WILLIAMS@READCASEDHOLE.COM READ CASED HOLE, INC., 4141 B STREET, SUITE 308, ANCHORAGE, AK 99503 PHONE: (907)245-8951 E-MAIL : READ-Anchorage@readcasedhole.com WEBSITE : WWW.READCASEDHOLE.COM 206-122 T38843 Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2024.05.22 11:14:04 -08'00' C:\Users\grgluyas\AppData\Local\Microsoft\Windows\INetCache\Content.Outlook\I1OGWE08\2024-05-12_22601_KRU_1J-115_CaliperSurvey_LogData_Transmittal.docx DELIVERABLE DISCRIPTION Ticket # Field Well # API # Log Description Log Date 22601 KRU 1J-115 50-029-23320-00 Caliper Survey we/ Log Data 12-May-24 DELIVERED TO Company & Address DIGITAL FILE # of Copies LOG PRINTS # of Prints CD’s # of Copies 1 AOGCC Attn: Natural Resources Technician 333 W. 7th Ave., Suite 100 Anchorage, Ak. 99501-3539 Delivered By: CPAI Sharefile ______________________________ ______________________________________ Date received Signature PLEASE RETURN COPY VIA EMAIL TO: DIANE.WILLIAMS@READCASEDHOLE.COM READ CASED HOLE, INC., 4141 B STREET, SUITE 308, ANCHORAGE, AK 99503 PHONE: (907)245-8951 E-MAIL : READ-Anchorage@readcasedhole.com WEBSITE : WWW.READCASEDHOLE.COM 206-122 T38826 Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2024.05.20 12:57:56 -08'00' 1. Operations Susp Well Insp Plug Perforations Fracture Stimulate Pull Tubing Operations shutdown Performed: Install Whipstock Perforate Other Stimulate Alter Casing Change Approved Program Mod Artificial Lift Perforate New Pool Repair Well Coiled Tubing Ops Other: Development Exploratory Stratigraphic Service 6. API Number: 7. Property Designation (Lease Number): 8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071): 10. Field/Pool(s): 11. Present Well Condition Summary: Total Depth measured 13720'feet None feet true vertical 3911' feet None feet Effective Depth measured 13720'feet 5962', 6198', 6652'feet true vertical 3911' feet 3521', 3574', 3670'feet Perforation depth Measured depth True Vertical depth Tubing (size, grade, measured and true vertical depth) 4-1/2" L-80 6223' MD 3578' TVD Packers and SSSV (type, measured and true vertical depth) 5962' MD 6198' MD 6652' MD N/A 3521' TVD 3574' TVD 3670' TVD N/A 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: N/A 13a. Prior to well operation: Subsequent to operation: 13b. Pools active after work: West Sak Oil Pool 15. Well Class after work: Daily Report of Well Operations Exploratory Development Service Stratigraphic Copies of Logs and Surveys Run 16. Well Status after work: Oil Gas WDSPL Electronic Fracture Stimulation Data GSTOR GINJ SUSP SPLUG Sundry Number or N/A if C.O. Exempt: Authorized Name and Digital Signature with Date: Contact Name: Contact Email: Authorized Title: Contact Phone: 3009' 2215' Burst Collapse Production Liner 7467' 7056' Casing 3808' 4-1/2" 7493' 13708' 3910' 2983' 108'Conductor Surface Intermediate 20" 10-3/4" 78' measured TVD 7-5/8" STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 206-122 50-029-23320-00-00 P.O. Box 100360 Anchorage, AK 99510 3. Address: ConocoPhillips Alaska, Inc. N/A 5. Permit to Drill Number:2. Operator Name 4. Well Class Before Work: ADL0025650, ADL0025661 Kuparuk River Field/ West Sak Oil Pool KRU 1J-115 Plugs Junk measured Length measured true vertical Packer Representative Daily Average Production or Injection Data Casing Pressure Tubing Pressure 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 595 Gas-Mcf MD 150 Size 108' 1600 1000700 1000 1801700 200 N/A Sr Pet Eng: Sr Pet Geo: Sr Res Eng: WINJ WAG 400 Water-BblOil-Bbl 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. N/A Packer: ZXP Liner Top Packer Packer: ZXP Liner Top Packer Packer: Baker HRD ZXP LTP SSSV: None Will Parker will.parker@conocophillips.com (907) 265-6239Senior Production Engineer Alternating Slotted Pipe: 7234-7614', 7786-8127', 8382-11770', 12157-12546', 12719-13360', 13533-13664' Alternating Slotted Pipe: 3778-3817', 3821-3823', 3821-3842', 3864-3889', 3894-3909', 3905-3908' Form 10-404 Revised 10/2022 Due Within 30 days of Operations Submit in PDF format to aogcc.permitting@alaska.gov By Grace Christianson at 9:12 am, Jul 19, 2023 DTTMSTART JOBTYP SUMMARYOPS 6/19/2023 REPAIR WELL PULLED 4-1/2" SLIPSTOP FROM 5452' RKB, EQUALIZE & PULLED 4-1/2" PACKOFF FROM 5454' RLB, PULLED SUMMIT ESP PUMP FROM 5460' RKB, JARRED FOR 45min ON ACCESS MOTOR @ 5510' RKB, NO MOVEMENT, IN PROGRESS 6/20/2023 REPAIR WELL ATTEMPT TO PULL 4 1/2 ACCESS MOTOR @ 5510' RKB JARRED ON MOTOR FOR 3.75 Hrs. NO MOVMENT. JOB SUSPENDED FOR PLAN FORWARD. 6/24/2023 REPAIR WELL LATCH UP TO ESP MOTOR AT 5510' RKB. HIT 11 JAR LICKS. NO MOVEMENT. VIBRATE WITH TEMPRESS FOR AN HOUR. MOTOR COMES FREE. TRAPPED IN PANCAKE FLANGE FOR SLICKLINE TO RETRIEVE. 6/27/2023 REPAIR WELL RECOVER 4 1/2 ACCESS MOTOR FROM PANCAKE FLANGE, CLEAN DRIFT W/ 3" BAILER TO 6115' RKB, BRUSH n' FLUSH TBG TO 6015' RKB, SET 3.813" PXX PLUG @ 5918' RKB. IN PROGRESS. 6/28/2023 REPAIR WELL PULLED SOV @ 5319' RKB (SHEARED), SET DV @ SAME, CLOSED ACCESS CMD @ 5497' RKB, SET ACCESS ISO SLEEVE @ 5550' RKB, LOAD TBG & IA W/ 150 BBLS INHIBITED SW & 95 BBLS DIESEL U-TUBE FREEZE PROTECT, CMIT TBG x IA 2500 (PASS). IN PROGRESS. 6/29/2023 REPAIR WELL PULLED 4 1/2 ACCESS ISO SLEEVE @ 5505' RKB, CLOSED 3.81 CMD @ 5595' RKB, SET 4 1/2 ACCESS ISO SLEEVE @ 5550' RKB, MIT IA FAILED, RAN SLICKLINE LDL (PONYTAIL) LEAK @ STA #2 @ 5319' RKB, PULLED DV @ SAME, RAN POCKET POKER IN TO STA #2 @ 5319' RKB POCKET CLEAR. IN PROGRESS. 6/30/2023 REPAIR WELL SET DV @ 5319' RKB, MIT IA 2500 PSI (PASS), PULLED 4 1/2 ACCESS ISO SLEEVE @ 5550' RKB, PULLED 3.72" BAIT SUB & EQ PRONG @ 5909' RKB, PULLED 3.813 PXX PLUG BODY @ 5918' RKB, SET 4 1/2 ACCESS ISO SLEEVE @ 5550' RKB, MIT IA 2500 (FAILED), PULLED & INSPECTED ISO SLEEVE NO DAMAGE, SET NEW 4 1/2 ACCESS ISO SLEEVE @ 5550' RKB MIT IA (FAILED). IN PROGRESS. 7/2/2023 REPAIR WELL MIT IA (FAILED) WITH SAME LEAK OFF RATE 200 PSI PER MIN, GOOD TBG TEST W/ 4 1/2 HOLE FINDER @ 5371' RKB, CONFIRM ACCESS CMD CLOSED @ 5497' RKB, PULLED 4 1/2 ACCESS ISO SLEEVE @ 5550' RKB NO DAMAGE, SET NEW 4 1/2 ACCESS ISO SLEEVE W/ O-RING'S @ 5550' RKB MIT IA (FAILED) 100 PSI LEAK OFF PER MIN, SET 4 1/2 SLIP STOP @ 5411' RKB. IN PROGRESS. 7/3/2023 REPAIR WELL MIT IA (FAILED W/ SAME 100 PSI LEAK OFF RATE, SET 4 1/2 D&D PLUG 5408' RKB, SET 4 1/2 SLIP STOP CATCHER @ 5405' RKB, PULLED DV's @ 5319' & 3149' RKB, SET OV & GLV @ SAME, MIT TBG 2500 (PASS), PULLED 4 1/2 SLIP STOP CATCHER @ 5405' RKB, EQUALIZED 4 1/2 D&D PLUG @ 5408' RKB. IN PROGRESS. 7/4/2023 REPAIR WELL JAR ON 4-1/2" D&D PLUG @ 5408' RKB FOR 5hrs, NO MOVEMENT, IN PROGRESS 7/5/2023 REPAIR WELL PULLED 4-1/2" D&D PLUG & 4-1/2" SLIPSTOP FROM 5408' RKB, JOB COMPLETE. 1J-115 Convert ESP to Gas Lift Summary of Operations Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: Pulled Motor, Closed Sliding Sleeves, set Access IsoSleeve, Installed GLD 1J-115 7/4/2023 rogerba Notes: General & Safety Annotation End Date Last Mod By NOTE: MULTI-LATERAL WELL: 1J-115 (A-SAND), 1J-115L1 (B-SAND), 1J-115L2 (D-SAND) 11/27/2006 lmosbor NOTE: CMT complete annulus top to bttm (1903) Halliburton Bowl Patch w/Overshot to tie back 10/23/2006 osborl Casing Strings Csg Des OD (in)ID (in)Top (ftKB) Set Depth (ftKB) Set Depth (TVD) (ftKB)Wt/Len (lb/ft)Grade Top Thread CONDUCTOR 20 19.12 30.0 108.0 108.0 94.00 K-55 WELDED SURFACE 10 3/4 9.95 26.0 3,009.0 2,214.9 45.50 L-80 BTC INTERMEDIATE 7 5/8 6.87 26.3 7,493.0 3,808.4 29.70 L-80 BTCM B LINER LEM 4 1/2 3.86 6,198.0 6,704.9 3,680.9 12.60 L80 IBT-SCC B LINER HH 4 1/2 4.00 6,530.9 6,797.7 3,698.7 11.60 L80 BTC D LINER HH 4 1/2 3.48 6,533.2 6,797.7 3,698.7 11.60 L-80 BTCM A-SAND LINER 4 1/2 3.48 6,652.0 13,708.0 3,909.9 11.60 L-80 Buttress Thread Tubing Strings: string max indicates LONGEST segment of string Top (ftKB) 22.2 Set Depth 5,994.7 Set Depth 3,529.5 String Ma 4 1/2 Tubing Description Tubing Completion Upper Wt (lb/ft) 12.60 Grade L-80 Top Connection Hyd 563 ID (in) 3.96 Completion Details: excludes tubing, pup, space out, thread, RKB... Top (ftKB) Top (TVD) (ftKB) Top Incl (°)Item Des OD Nominal (in)Com Make Model Nominal ID (in) 22.2 22.2 0.00 Hanger 10.750 Tubing Hanger, Vetco-Gray MB222A offset 10 3/4 x 4 1/2 w/ false bowl Vault SN:5256 461-2 3,149.1 2,278.8 61.14 Mandrel 4.500 GLM, Camco, KBMG, 4-/2" x 1" SLB KBMG 3.892 5,318.9 3,277.8 64.56 Mandrel 4.500 GLM, Camco, KBMG, 4-/2" x 1" SLB KBMG 3.893 5,427.5 3,324.4 64.61 Gauge Mandrel 4.500 4-1/2" OPSIS Gauge Mandrel HES HES OPSIS 3.898 5,497.1 3,354.2 64.70 Sliding sleeve (C) 5.500 Gas Venting Sliding Sleeve (closed 06/30/2023) 4 1/2",12.6#,L-80, Vam Top Box x 5 1/2" Vam FJL Box AccessE SP Sliding Sleeve 3.910 5,501.1 3,355.9 64.70 Motor Shroud 5.500 Motor Shroud 5 1/2" 23#, Vam FJL Pin x Pin Access ESP 3.893 5,517.7 3,363.0 64.73 Motor Centralizer 5.500 Motor Centralizer, 5 1/2" 23# Vam FJL Box x Box Access ESP 3.893 5,519.2 3,363.7 64.73 Motor Shroud 5.500 Motor Shroud, 5 1/2" 23# Vam FJL Pin x Pin Access ESP 3.893 5,542.2 3,373.5 64.86 Motor Centralizer 5.500 Motor Centralizer, 5 1/2" 23# Vam FJL Box x Box Access ESP 3.893 5,543.7 3,374.1 64.89 Motor Shroud 5.500 Motor Shroud, 5 1/2" 23# Vam FJL Pin x Pin Access ESP 4.548 5,550.0 3,376.8 65.01 Annular Connection Port 5.950 Ann Connection Port 5", 18# Vam FJL Box x 4 1/2" 12.6# Vamtop Box SN# ACPTX20D0052 Access ESP ACP Ser # ACPTX2 1M0070 3.860 5,573.6 3,386.6 65.49 Profile Sub 4.967 B-Profile, 4 1/2", 12.6#, L-80 Vamtop Box x Box Access ESP 3.913 5,587.1 3,392.2 65.75 No-go nipple 5.200 3.813" No Go Profile, 4.5" Vam Box x HYD563 Box Access ESP 3.813 5,595.9 3,395.8 65.93 Sleeve - Sliding (C) 5.000 Baker 4 1/2" CMD, GOT Sliding Sleeve (closed 06/29/2023), w/ 3.81 BX profile Baker CMD GOT Sliding Sleeve w/ BX Profile 3.810 5,613.9 3,403.1 66.29 Mandrel 4.500 4-1/2" x 1 Chemical Injection Mandrel, HES HES HT4805 9 3.958 5,918.3 3,508.1 72.60 Nipple - X 5.200 4.5" x 3.813" X Nipple 563 B x P HES 3.813 5,967.7 3,522.3 74.07 Locator 5.500 Baker 5 1/2" Locator Baker 192-47 GBH-22 LTSA 3.880 5,968.1 3,522.4 74.09 Seal Assembly 4.750 Baker 192-47 GBH-22 LSTA Seal Assembly w/ spacer tubes (4.85' from fully located) Baker 3.880 Top (ftKB) 5,962.8 Set Depth 6,223.3 Set Depth 3,577.9 String Ma 4 1/2 Tubing Description Tubing Completion Lower Wt (lb/ft) 12.60 Grade L-80 Top Connection HYD 563 ID (in) 3.93 Completion Details: excludes tubing, pup, space out, thread, RKB... Top (ftKB) Top (TVD) (ftKB) Top Incl (°)Item Des OD Nominal (in)Com Make Model Nominal ID (in) 5,962.8 3,520.9 73.93 Packer (Liner Top) 6.875 7 5/8" x 5 1/2" ZXP Liner Top Packer w/ 10.96' SBR 5.75" ID Baker ZXP Liner Top Packer 5.750 5,982.5 3,526.3 74.52 SBE (Seal Bore Extension) 6.270 190-47 L-80 Seal Bore Extension Baker 190-47 4.750 SLOTS; 8,382.0-11,770.0 SLOTS; 7,786.0-8,127.0 INTERMEDIATE; 26.3-7,493.0 SLOTS; 7,234.0-7,614.0 B LINER HH; 6,530.9-6,797.7 D LINER HH; 6,533.2-6,797.7 B LINER LEM; 6,198.0-6,704.9 Nipple - X; 6,059.9 Packer (Liner Top); 5,962.8 Nipple - X; 5,918.2 Mandrel; 5,613.9 Sleeve - Sliding (C); 5,595.9 ISO-SLEEVE; 5,550.0 Sliding sleeve (C) ; 5,497.1 Gauge Mandrel; 5,427.5 Mandrel; 5,318.9 Mandrel; 3,149.1 SURFACE; 26.0-3,009.0 CONDUCTOR; 30.0-108.0 Hanger; 22.3 6,085.5 3,551.7 76.66 D Liner LEM 4.500 LEM (Below Hook Hanger) SBR 3.688" Baker LEM - Below Hook Hanger 3.688 6,220.0 3,577.4 80.83 Seal Assembly 4.750 190-47, Non-Location Seal Assembly. (2' seals on bottom) 6.76' from fully located Baker 190-47 3.900 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB)Top Incl (°)Des Com Make Model SN Run Date ID (in) 5,550.0 3,376.8 65.01 ISO-SLEEVE Access ACP ISO sleeve. (11.3' OAL) Added 4 O-rings to packing stack in attempts to get sleeve to hold MITIA pressure 7/2/2023 2.970 Mandrel Inserts : excludes pulled inserts Top (ftKB) Top (TVD) (ftKB) Top Incl (°) St ati on No /S Serv Valve Type Latch Type OD (in) TRO Run (psi)Run Date Com Make Model Port Size (in) 3,149.1 2,278.8 61.14 1 GAS LIFT GLV BK 1 1,463.0 7/3/2023 0.188 5,318.9 3,277.8 64.56 2 GAS LIFT OV BK 1 0.0 7/3/2023 0.313 Liner Details: Excludes Liner, Pup, Joints, casing, float, sub, shoe... Top (ftKB) Top (TVD) (ftKB) Top Incl (°)Item Des OD Nominal (in)Com Make Model Nominal ID (in) 6,198.0 3,573.9 81.03 PACKER 6.280 7-5/8" x 5-1/2" ZXP liner top packer 4.970 6,217.0 3,576.9 80.87 SBR 6.280 Casing Seal Bore Receptacle 4.750 6,236.7 3,580.0 80.58 XO BUSHING 5.990 Cross Over Bushing 3.960 6,626.0 3,663.9 76.47 NIPPLE 5.200 DB-6 Nipple 3.563 6,658.4 3,671.2 77.38 BENT JT 4.500 Bent Joint 3.860 6,607.1 3,659.4 75.93 ECP 5.630 BAKER PZ EXTERNAL CASING PACKER 3.900 6,769.4 3,693.4 79.12 BENT JT 4.520 3.960 6,608.9 3,659.8 75.98 ECP 4.550 External Casing Packer 3.900 6,767.6 3,693.0 79.11 BENT JT 4.520 Bent joint w/ muleshoe 3.960 6,652.0 3,669.8 77.20 PACKER 7.630 BKER HRD ZXP LINER TOP PACKER 5.500 6,671.0 3,674.0 77.74 NIPPLE 6.070 'RS' PACKOFF SEAL NIPPLE 4.870 Perforations & Slots Top (ftKB)Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB)Linked Zone Date Shot Dens (shots/ft)Type Com 7,234.0 7,614.0 3,777.7 3,817.3 WS A2, 1J-115 10/26/2006 32.0 SLOTS ALL PERFS IN WELL: Alternating solid/slotted pipe - 0.125"x2.5" @ 4 circumferential adjacent rows, 3" centers staggered 18 deg, 3' non-slotted ends 7,786.0 8,127.0 3,820.8 3,822.7 WS A2, 1J-115 10/26/2006 32.0 SLOTS 8,382.0 11,770.0 3,820.6 3,842.0 WS A2, 1J-115 10/26/2006 32.0 SLOTS 12,157.0 12,546.0 3,864.3 3,888.7 WS A2, 1J-115 10/26/2006 32.0 SLOTS 12,719.0 13,360.0 3,893.6 3,909.3 WS A2, 1J-115 10/26/2006 32.0 SLOTS 13,533.0 13,664.0 3,905.1 3,907.6 WS A2, 1J-115 10/26/2006 32.0 SLOTS SLOTS; 8,382.0-11,770.0 SLOTS; 7,786.0-8,127.0 INTERMEDIATE; 26.3-7,493.0 SLOTS; 7,234.0-7,614.0 B LINER HH; 6,530.9-6,797.7 D LINER HH; 6,533.2-6,797.7 B LINER LEM; 6,198.0-6,704.9 Nipple - X; 6,059.9 Packer (Liner Top); 5,962.8 Nipple - X; 5,918.2 Mandrel; 5,613.9 Sleeve - Sliding (C); 5,595.9 ISO-SLEEVE; 5,550.0 Sliding sleeve (C) ; 5,497.1 Gauge Mandrel; 5,427.5 Mandrel; 5,318.9 Mandrel; 3,149.1 SURFACE; 26.0-3,009.0 CONDUCTOR; 30.0-108.0 Hanger; 22.3 Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: Pulled ESP, Packoff, Slip Stop & SOV, C/O Gas Lift 1J-115L1 12/1/2019 pproven Notes: General & Safety Annotation End Date Last Mod By NOTE: MULTI-LATERAL WELL: 1J-115 (A-SAND), 1J-115L1 (B-SAND), 1J-115L2 (D-SAND) 11/27/2006 lmosbor Casing Strings Csg Des OD (in)ID (in)Top (ftKB) Set Depth (ftKB) Set Depth (TVD) (ftKB)Wt/Len (lb/ft)Grade Top Thread B-SAND LINER 4 1/2 3.48 6,742.5 13,912.9 3,774.3 11.60 L80 BTCM Liner Details: Excludes Liner, Pup, Joints, casing, float, sub, shoe... Top (ftKB) Top (TVD) (ftKB) Top Incl (°)Item Des OD Nominal (in)Com Make Model Nominal ID (in) 6,742.5 3,657.1 91.33 SLEEVE 6.400 HR liner setting sleeve 5.010 6,765.6 3,656.4 92.15 SBR 5.540 Receptacle Joint 4.970 6,800.6 3,655.0 91.68 XO BUSHING 5.730 Cross Over Bushing 3.960 13,873.6 3,771.1 85.44 XO Reducing 3.500 CROSSOVER REDUCING 4.5x3.5" 2.992 Perforations & Slots Top (ftKB)Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB)Linked Zone Date Shot Dens (shots/ft)Type Com 6,540.0 13,166.0 3,642.5 3,747.6 WS B, 1J-115L1 11/20/2006 32.0 SLOTS ALL PERFS IN WELL: Alternating solid/slotted pipe - 0.125"x2.5" @ 4 circumferential adjacent rows, 3" centers staggered 18 deg, 3' non-slotted ends 6,804.0 11,330.0 3,654.9 3,719.4 WS B, 1J-115L1 11/5/2006 32.0 SLOTS ALL PERFS IN WELL: Alternating solid/slotted pipe - 0.125"x2.5" @ 4 circumferential adjacent rows, 3" centers staggered 18 deg, 3' non-slotted ends 13,382.0 13,940.0 3,748.4 WS B, 1J-115L1 11/20/2006 32.0 SLOTS ALL PERFS IN WELL: Alternating solid/slotted pipe - 0.125"x2.5" @ 4 circumferential adjacent rows, 3" centers staggered 18 deg, 3' non-slotted ends SLOTS; 6,540.0-13,166.0 SLOTS; 6,804.0-11,330.0 INTERMEDIATE; 26.3-7,493.0 B LINER LEM; 6,198.0-6,704.9 Nipple - X; 6,059.9 Packer (Liner Top); 5,962.8 Nipple - X; 5,918.2 Mandrel; 5,613.9 Sleeve - Sliding (C); 5,595.9 ISO-SLEEVE; 5,550.0 Sliding sleeve (C) ; 5,497.1 Gauge Mandrel; 5,427.5 Mandrel; 5,318.9 Mandrel; 3,149.1 SURFACE; 26.0-3,009.0 CONDUCTOR; 30.0-108.0 Hanger; 22.3 Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: Pulled ESP, Packoff, Slip Stop & SOV, C/O Gas Lift 1J-115L2 12/1/2019 pproven Notes: General & Safety Annotation End Date Last Mod By NOTE: MULTI-LATERAL WELL: 1J-115 (A-SAND), 1J-115L1 (B-SAND), 1J-115L2 (D-SAND) 11/27/2006 lmosbor Casing Strings Csg Des OD (in)ID (in)Top (ftKB) Set Depth (ftKB) Set Depth (TVD) (ftKB)Wt/Len (lb/ft)Grade Top Thread D-SAND LINER 4 1/2 3.48 6,305.3 13,985.0 3,704.5 11.60 L-80 BTCM Liner Details: Excludes Liner, Pup, Joints, casing, float, sub, shoe... Top (ftKB) Top (TVD) (ftKB) Top Incl (°)Item Des OD Nominal (in)Com Make Model Nominal ID (in) 6,305.3 3,592.6 82.04 SLEEVE 6.400 BAKER 'HR' SETTING SLEEVE 5.000 6,325.2 3,595.3 82.38 SBR 5.720 RECEPTACLE JOINT 4.900 6,361.1 3,599.6 83.82 XO BUSHING 5.740 CROSSOVER BUSHING 3.930 Perforations & Slots Top (ftKB)Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB)Linked Zone Date Shot Dens (shots/ft)Type Com 11,631.0 12,104.0 3,647.0 3,649.2 WS D, 1J-115L2 11/5/2006 32.0 SLOTS ALL PERFS IN WELL: Alternating solid/slotted pipe - 0.125"x2.5" @ 4 circumferential adjacent rows, 3" centers staggered 18 deg, 3' non-slotted ends 12,190.0 13,874.0 3,649.9 3,700.2 WS D, 1J-115L2 11/5/2006 32.0 SLOTS ALL PERFS IN WELL: Alternating solid/slotted pipe - 0.125"x2.5" @ 4 circumferential adjacent rows, 3" centers staggered 18 deg, 3' non-slotted ends SLOTS; 11,631.0-12,104.0 INTERMEDIATE; 26.3-7,493.0 Nipple - X; 6,059.9 Packer (Liner Top); 5,962.8 Nipple - X; 5,918.2 Mandrel; 5,613.9 Sleeve - Sliding (C); 5,595.9 ISO-SLEEVE; 5,550.0 Sliding sleeve (C) ; 5,497.1 Gauge Mandrel; 5,427.5 Mandrel; 5,318.9 Mandrel; 3,149.1 SURFACE; 26.0-3,009.0 CONDUCTOR; 30.0-108.0 Hanger; 22.3 C:\Users\kmjunke\AppData\Local\Microsoft\Windows\INetCache\Content.Outlook\99RGP1KB\2023-04-16_21134_KRU_1J-115_CaliperSurvey_LogData_Transmittal.docx DELIVERABLE DISCRIPTION Ticket # Field Well # API # Log Description Log Date 21134 KRU 1J-115 50-029-23320-00 Caliper Survey w/ Log Data 16-Apr-23 DELIVERED TO Company & Address DIGITAL FILE # of Copies LOG PRINTS # of Prints CD’s # of Copies 1 AOGCC Attn: Natural Resources Technician 333 W. 7th Ave., Suite 100 Anchorage, Ak. 99501-3539 Delivered By: CPAI Sharefile ______________________________ ______________________________________ Date received Signature PLEASE RETURN COPY VIA EMAIL TO: DIANE.WILLIAMS@READCASEDHOLE.COM READ CASED HOLE, INC., 4141 B STREET, SUITE 308, ANCHORAGE, AK 99503 PHONE: (907)245-8951 E-MAIL : READ-Anchorage@readcasedhole.com WEBSITE : WWW.READCASEDHOLE.COM PTD: 206-122 T37611 Kayla Junke Digitally signed by Kayla Junke Date: 2023.04.20 10:40:45 -08'00' CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Loepp, Victoria T (OGC) To:Phillips, Ron L Subject:Re: KRU 1J-115 (Sundry 322-315) Date:Monday, June 6, 2022 3:45:36 PM Attachments:Sundry_322-315_060222.pdf Approval is granted with two downhole plugs. Victoria Sent from my iPhone On Jun 6, 2022, at 12:35 PM, Phillips, Ron L <Ron.L.Phillips@conocophillips.com> wrote: Victoria, During the Kuparuk 1J-115 RWO, Nabors 7ES found 3 bad lock down screws in the tubing head. Instead of drilling them out we plan to set and pressure test two down hole plugs with kill weight 8.5 ppg seawater, remove the BOPE and swap out the upper tubing head (spool) with a new one. Reinstall the BOPE and pressure test the breaks. Since this was not in the Sundry Notice I am sending this email to inform you of our plan forward. Please let me know if you have any questions. Thanks, Ron Phillips Senior RWO Engineer ConocoPhillips Alaska 907-317-5092 ATO-06-656 5HJJ-DPHV%2*& )URP+ROFRPE6HDQ6HDQ+ROFRPE#QDERUVFRP! 6HQW0RQGD\-XQH$0 7R5HJJ-DPHV%2*&'2$$2*&&3UXGKRH%D\%URRNV3KRHEH/2*& PLFKDHOONQHDOH#FRQRFRSKLOOLSVFRP*UHJ6+REEV#FRQRFRSKLOOLSVFRP &F&R]E\.HOO\+HQVRQ-DPHV16.5:2&0<HDURXW3DXO 6XEMHFW%23(7HVW.58- $WWDFKPHQWV1DERUV(6%237HVW[OV[ ^ĞĂŶ,ŽůĐŽŵď ϳ^dŽŽůƉƵƐŚĞƌ EKZ^Z/>>/E'/E͘ KĨĨŝĐĞϵϬϳͲϲϳϬͲϲϭϯϮDŽďŝůϵϬϳͲϯϱϱͲϭϬϰϭ ƐĞĂŶ͘ŚŽůĐŽŵďΛŶĂďŽƌƐ͘ĐŽŵ ΎΎΎΎΎΎΎΎΎΎΎΎΎΎΎΎΎΎΎΎΎΎΎΎΎΎΎΎΎΎΎ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ll BOPE reports are due to the agency within 5 days of testing* SSu b m i tt t o :jim.regg@alaska.gov; AOGCC.Inspectors@alaska.gov; phoebe.brooks@alaska.gov Owner/Contractor: Rig No.:7ES DATE: 6/4/22 Rig Rep.: Rig Phone: 670-6132 Operator: Op. Phone:670-6130 Rep.: E-Mail Well Name: PTD #22061220 Sundry #322-315 Operation: Drilling: Workover: x Explor.: Test: Initial: x Weekly: Bi-Weekly: Other: Rams:250/3000 Annular:250/3000 Valves:250/3000 MASP:722 MISC. INSPECTIONS: TEST DATA FLOOR SAFETY VALVES: Test Result Test Result Quantity Test Result Location Gen.P Well Sign P Upper Kelly 1FP Housekeeping P Rig P Lower Kelly 1P PTD On Location P Hazard Sec.P Ball Type 1P Standing Order Posted P Misc.NA Inside BOP 1P FSV Misc 0NA BOP STACK:Quantity Size/Type Test Result MUD SYSTEM:Visual Alarm Stripper 0NATrip Tank PP Annular Preventer 1 13 5/8" T 90 P Pit Level Indicators PP #1 Rams 1 3 1/2" x 5 1/2"P Flow Indicator PP #2 Rams 1 Blinds P Meth Gas Detector PP #3 Rams 1 2 7/8" x 5 NT H2S Gas Detector PP #4 Rams 0NAMS Misc 0NA #5 Rams 0NA #6 Rams 0NA Quantity Test Result Choke Ln. Valves 1 3 1/8" Gate P Inside Reel valves 0NA HCR Valves 2 3 1/8" Gate P Kill Line Valves 2 3 1/8" & 2"P Check Valve 0NAACCUMULATOR SYSTEM: BOP Misc 2 2 1/16 Gate P Time/Pressure Test Result System Pressure (psi)3000 P CHOKE MANIFOLD:Pressure After Closure (psi)1450 P Quantity Test Result 200 psi Attained (sec)22 P No. Valves 16 P Full Pressure Attained (sec)135 P Manual Chokes 1P Blind Switch Covers: All stations Yes Hydraulic Chokes 1P Nitgn. Bottles # & psi (Avg.): 5@2015 P CH Misc 0NA ACC Misc 0NA Test Results Number of Failures:1 Test Time:11.5 Hours Repair or replacement of equipment will be made within 0 days. Remarks: AOGCC Inspection 24 hr Notice Yes Date/Time 06-03-22 / 10:40 Waived By Test Start Date/Time:6/4/2022 11:00 (date) (time)Witness Test Finish Date/Time:6/4/2022 22:30 BOPE Test Report Notify the AOGCC of repairs with written confirmation to: AOGCC.Inspectors@alaska.gov Matt Herrera Nabors Tested with 4 1/2" Test Jt., Top drive upper IBOP leaked, Replaced valve - good test Kelly Cozby/Sean Holcomb ConocoPhillips Dale Rowell / Kevin Barr KRU 1J-115 Test Pressure (psi): nskrwo.cm@conocophillips.com Form 10-424 (Revised 02/2022) 2022-0604_BOP_Nabors7ES_KRU_1J-115 9 99 9 9 9 999 9 9 9 9 -5HJJ Top drive upper IBOP leaked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y Samantha Carlisle at 10:05 am, May 20, 2022 Ron Phillips Digitally signed by Ron Phillips Date: 2022.05.19 14:27:10 -08'00' ; 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James B (OGCI; DOA AOGCC Prudhoe Bay; Brooks, Phoebe L IOGCI; NSK RWO CM; Hobbs, Grea S; Kneale, Michael L Cc: Henson, James; Medina, Johnnv Subject: Nabors 7ES O4-03-22 BOP Test Date: Tuesday, April 5, 2022 5:03:57 PM Attachments: Nabors 7ES O4-03-22.xlsx CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. Thanks, Kelly Cozby Nabors Alaska Drilling Rig 7ES Rig Manager Office 907-670- 6132 Cell 907-715-9055 NABORS EMAIL NOTICE - This transmission may be strictly proprietary and confidential. If you are not the intended recipient, reading, disclosing, copying, distributing or using the contents of this transmission is prohibited. If you have received this in error, please reply and notify the sender (only) and delete the message. Unauthorized interception of this e-mail is a violation of federal criminal law. This communication does not reflect an intention by the sender or the sender's principal to conduct a transaction or make any agreement by electronic means. Nothing contained in this message or in any attachment shall satisfy the requirements for a writing, and nothing contained herein shall constitute a contract or electronic signature under the Electronic Signatures in Global and National Commerce Act, any version of the Uniform Electronic Transactions Act, or any other statute governing electronic transactions. STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report *All BOPE reports are due to the agency within 5 days of testing* Submit to: iim.regg(@alaska.gov; AOGCC.Inspectors(a�alaska.gov; phoebe.brooks(c2)alaska.gov Owner/Contractor: Nabors Rig No.: 7ES DATE: 4/3/22 ✓ Rig Rep.: Tony Morales/Sean Holcomb Rig Phone: 670-6132 Operator: ConocoPhillips Op. Phone: 670-6130 Rep.: Mark Adams / K Barr E-Mail nskrwo.cM@conocophillips.com Well Name: KRU 1J-115 PTD # 2061220 ✓ Sundry #_ 322-109 ✓ Operation: Drilling: Workover: x ✓ Explor.: Test: Initial: x Weekly: Bi-Weekly: Other: Test Pressure (psi): Rams: 250/3000 Annular: 250/3000 Valves: 250/3�� MASP: 722 MISC. INSPECTIONS: TEST DATA FLOOR SAFETY VALVES: Test Result Test Result Quantity Test Result Location Gen. P Well Sign P Upper Kelly 1 P Housekeeping P Rig P Lower Kelly 1 P PTD On Location P Hazard Sec. P Ball Type 2 P Standing Order Posted P Misc. NA Inside BOP 1 P FSV Misc 0 NA BOP STACK: Quantity Size/Type Test Result MUD SYSTEM: Visual Alarm Stripper 0 NA Trip Tank P P Annular Preventer 1 13 5/8" T 90 P Pit Level Indicators P P #1 Rams 1 2 7/8"x 5" P Flow Indicator P P #2 Rams 1 Blinds P Meth Gas Detector P P #3 Rams 1 3 1/2" x 5 1/2" P H2S Gas Detector P P #4 Rams 0 NA MS Misc 0 NA #5 Rams 0 NA #6 Rams 0 NA Quantity Test Result Choke Ln. Valves 1 3 1/8" Gate P Inside Reel valves 0 NA HCR Valves 2 3 1/8" Gate P Kill Line Valves 2 3 1/8" & 2" P Check Valve 0 NA ACCUMULATOR SYSTEM: BOP Misc 2 2 1/16 Gate P Time/Pressure Test Result System Pressure (psi) 3000 P CHOKE MANIFOLD: Pressure After Closure (psi) 1550 P Quantity Test Result 200 psi Attained (sec) 18 P No. Valves 16 P Full Pressure Attained (sec) 145 P Manual Chokes 1 P Blind Switch Covers: All stations Yes Hydraulic Chokes 1 P Nitgn. Bottles # & psi (Avg.): 5@ 2020 P CH Misc 0 NA ACC Misc 0 NA ✓ Test Results Number of Failures: 0 Test Time: 7.0 Hours Repair or replacement of equipment will be made within 0 days. Notify the AOGCC of repairs with written confirmation to: AOGCC.Ins Remarks: Tested with 3 1/2" & 41/2" test jnts., Annular tested on the 3 1/2" jnt AOGCC Inspection 24 hr Notice Yes Date/Time 4/01/2022 13:23 Waived By Lou Laubenstein Test Start Date/Time: 4/3/2022 11:00 (date) (time) ✓ Witness Test Finish Date/Time: 4/3/2022 18:00 J. Regg; 4/5/2022 Form 10-424 (Revised 02/2022) 2022-0403_BOP_Nabors7ES_KRU_1J-115 RECEIVED By Meredith Guhl at 7:53 am, Mar 04, 2022 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25-280 1. Type of Request: Abandon ❑ Plug Perforations ] Fracture Stimulate ❑ Repair Well ❑ Operations shutdown ] Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing ❑� Change Approved Program ❑ Plug for Redrill ❑ Perforate New Pool ] Re-enter Susp Well ❑ Alter Casing ❑ Other: ESP CO J 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc Exploratory ❑ Development 0 Stratigraphic ❑ Service ❑ 206-122 3. Address: 6. API Number: P.O. Box 100360, Anchorage, AK 99510 50-029-23320-00 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? n/a Will planned perforations require a spacing exception? Yes ❑ No U KRU U-115 9. Property Designation (Lease Number): 10. Field/Pool(s): ADL 25650 ADL 25661 Kuparuk River Field / West Salk Oil Pool 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): 13720' 3911' 13708' 3908' 722 psi NA NA Casing Length Size MD TVD Burst Collapse Structural Conductor 78' 20" 108' 108' Surface 2983' 10.75" 3009' 2215' Intermediate Production 7467' 7.625" 7493' 3808' Liner 7056' 4.5" 13708' 3910' Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): SILT LNR 7234'-13664' SILT LNR 3778'-3909' 4.5" L-80 5494' Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): Viking Vented PKR / BKR ZXP LTP / BKR HRD ZXP LTP 5094'MD & 31807VD / 6198'MD & 3574'TVD / 6652'MD & 36707VD 12. Attachments: Proposal Summary J Wei Ibore schematic U 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch Exploratory ❑ Stratigraphic ❑ Development ] Service ❑ 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: 3/15/2022 OIL U WINJ ❑ WDSPL ❑ Suspended ❑ GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ 16. Verbal Approval: Date: Commission Representative: GINJ ❑ Op Shutdown ] Abandoned ] 17. 1 hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name: Ron Phillips Contact Name: Ron Phillips Authorized Title: Sr. Wells Engineer Contact Email: Ron.L.PhillipsC@conocophillips.com Ron Phil I i ps Digitally signed by Ron Phillips Contact Phone: 907-265-6312 Dace: 2022.03.0315:2223-0900 Authorized Signature: Date: COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 322-109 Plug Integrity ❑ BOP Test Mechanical Integrity Test ❑ Location Clearance ❑ Other: BOPE test to 3000 psig Annular preventer pressure test to 2500 psig Post Initial Injection MIT Req'd? Yes ] No X ,1 ,1 Spacing Exception Required? Yes ] No � Subsequent Form Required: 10-404 Jeremy Digitally signed y by Jeremy Price APPROVED BY 3/9/22 Date: 2022.03.09 Approved by: Price COMMISSIONER THE COMMISSION Date: 17:23:40-09'00' Commdts 3/9/2022 lComm. JSr Pet EngVTL 3/9/22 1 ISr Pet GeoDLB 03/04/2022 1SrResEng 'SR-3/4i Form 10-403 Revised 3/2020 Approvedl application is valia for 12 months trom the sate of approval. RBDMS SJC 0311223/4 --vr, �' ConocoPh i I I i ps Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 March 3, 2022 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Dear Commissioner: ConocoPhillips Alaska, Inc. hereby submits an Application for Sundry Approval to work over Kuparuk River Field/ West Sak Producer 1J-115 (PTD# 206-122). Well 1J-115 was drilled and completed in 2006 as a tri-lateral horizontal producer in the West Sak A2, B and D sands. The objective of this RWO is to pull the failed ESP, perform a clean out run, set a lateral entry module in the West Sak D sand window and run a new ESP completion. If you have any questions or require any further information, please contact me at 265-6312. Digitally signed by Ron Ron Phillips Date: 2022.03.03 15:22:49 -09,00, Ron L Phillips Senior Wells Engineer CPAI Drilling and Wells U-115 RWO Procedure Kuparuk River Field/West Sak Producer PTD #206-122 Current Operations: This well is currently shut-in and awaiting a RWO. Scope of Work: Pull the existing 4-1/2" ESP completion, install a `D' sand LEM and install a new 4-1/2" ESP completion. General Well info: Well Type: MPSP: Static BHP: Wellhead type/pressure rating: BOP configuration: MIT results: SR Engineer: Workover Engineer: Producer 722 psi using 0.1 psi/ft gradient 1100 psi / 3647' TVD (5.8 ppg EMW) Vetco Gray MB-222A, 5M psi top flange Annular / Pipe Rams / Blind Rams / Pipe Rams MIT-T passed — 12/6/2019 MIT-TxIA passed — 9/13/17 IC POT & PPPOT passed — 2/16/22 TBG POT &PPPOT passed — 2/16/22 (upper TBG-POT and TIFLfailed — 2/16/22) Sydney Autry (265-6813/ sydney.autry@conocophillips.com) Ron Phillips (263-6312/ Ron.L.Phillips@ConocoPhillips.com) Pre -Rig Work 1. Dummy GLMs at 3344' and leave the GLM at 5023' open as a circulation point. 2. FT LDS done 2/16/22 3. Grease tree valves. Workover Procedure 1. MIRU Nabors 7ES on 1J-115. 2. Record shut-in pressures on the T & IA. If there is pressure, bleed off IA and/or tubing pressure and complete 30-minute NFT. Verify well is dead. Circulate KWF as needed. 3. Set BPV and confirm as barrier, ND Tree, NU BOPE and test to 250/3,000 psi. Test annular 250/3,000 psi. 4. Pull BPV, MU landing joint and BOLDS. 5. Pull the TBG hanger and Viking packer free and lay down the ESP completion. 6. MU and RIH with a clean out BHA. POOH. 7. MU seal assembly, LEM and ZXP liner top packer on drill pipe, set LEM in D sand window. 8. Set packer and POOH laying down drill pipe. 9. MU and RIH with 4-'/Z" ESP completion. 10. Just before landing completion circulate IA to Cl seawater. 11. Stab into seal bore extension, space out and land the tubing hanger. 12. Pressure test tubing to 3000 psi for 30 minutes on chart. 13. Pressure test inner annulus to 2500 psi for 30 minutes on chart. 14. Confirm pressure tests, then shear out SOV with pressure differential. 15. Install BPV. 16. ND BOPE. NU tree. 17. Pull BPV and freeze protect well. 18. RDMO. Post -Rig Work 1. Reset well house(s) and flowlines of adjacent wells. 2. RU Slickline. Pull SOV, run and set Access ESP motor and Summit pump. 3. Handoff to operations to put back on production. 1J-115 Proposed Schematic 4-1/2" Vetco Gray TBG hanger 20" 154# X-52 shoe @108'MD 10-3/4" 45.5# L-80 shoe @ 3,009' MD West Sak'D' sand LEM @ 6108' MD 7-5/8" 29.7# L-80 shoe @ 7493 MD Completion 4-1/2" 12.6# L-80 HYD-563 Tubing to surface 4-1/2"x1" Camco KBMG gas lift mandrels @ 3172' & 5346' MD Hallibuton down ff�t @ 5374' MD Access ESP with ACP @ 5550' MD Baker CMU Sliding sleeve 3.812" BX @ 5581' MD Chemical Injection Mandrel @ 5609' MD Baker ZXP 5-1/2x7-5/8 Packer @ 6103' MD X-nipple just below packer @ 6169' MD Baker ZXP 5-1/2x7-5/8 Packer @ 6217' MD With Iso sleeve installed so we can PT Tubing. Weat Sak'D' sand 4-1/2" 11.6# L-80 BTC blank and slotted LNR @ 6094'-13,985' MD West Sak'B' sand 4-1/2" 11.6# L-80 BTC blank and slotted LNR @ 6529'-13,913' MD West Sak'A2' sand 4-1/2" 11.6# L-80 BTC blank and slotted LNR @ 13,708' MD *Insulated conductor, 20" 94# K55 x 34" 0.312", set at 108' MD. *Wellhead / Tubing Head / Tree, 10-3/4" x 4-1/2", 5,000 psi. Tubing String /4-1/2" 12.6#, L-80, IBTM 3.958" ID, 3.833" Drift 1901' MD - 7-5/8' Baker Pack - Off Overshot and Bowl Assembly, w/'H' ES Cementer on top 10-3/4" 45.5# Casing Shoe, set @ 3009' MD, 2215' TVD, 65 deg Inc 6086' MD - 4-1/2" X 7-5/8" Model'B' HOOK Hanaer I Entry Module I Assembly 3' MD - Camco 4-1/2" X 1" KBMG, 2408' TVD, 61 deg MD - GLM, Camco 4-1/2" X 1" KBMG, 3128' TVD, 62 deg 5510' MD - Bottom of Motor Centralizer Centralift 418 HP KMHFER 2610 / 98 ConocoPhillips West Sak 7-5/8" Producer 1J-115 Tri-Lateral Completion D-sand Window 'D' Sand Lateral at 6094' MD, 3553' TVD, 77 deg 4.1/2" 11.6# L-80 BTC Blank and Slotted Liner 6160' MD - Payzone ECP %fth-- 1 i 3-1/2" Guide Shoe \6305' MD - 5.1/2" Tieback Sleeve 6350' MD - 4-1/2" bent muleshoe 6198' MD - 5-1/2" X 7-5/8" ZXP Liner Top Packer with Hold Downs r— 5-1/2" X 7-5/8" ZXP Liner Top Packer with Hold Downs — Casing Sealbore Receptacle 4.75" ID Orienting Profile Iti Automatic Alignment of LEM Positive Latching Collet Indicates Correct Location Seal Bore for Lateral Isolation - 3.68" ID Access Window Positive Lateral Access Via Thru-Tubing Diverter Seal Bore for Lateral Isolation - 3.68" ID Isolation Seal Asembly 4.75" Seal OD 3.875" Seal ID 6217' MD - Casing Sealbore Receptacle 4.75" ID 6531' MD - 4-1/2" X 7.5/8" Model'B' HOOK Hanger Seal Bon 3.68" ID 4-1/2" Liner Shoe, 11.6#, L-80 BTC Set @ 13985' MD, 3704' TVD 6520' MD - Lateral Entry Module (LEM) 4.1/2" 12.6# Tubing 'B' Sand Lateral B-sand Window at 6529' MD, 3600' TVD, 90 deg 4-1/2" 11.6# L-80 BTC Blank and Slotted Liner 6609' MD - Payzone ECP 6742' MD - 5-1/2" Tieback Sleeve 6798' MD - 4-1/2" bent muleshoe 6625' MD - 3.562" DB Nipple -1th X ZXP Liner Top Packer r Hold D with Hold Downs / 5.1/2" X 7-5/8" Flex Lock 6652' MD -Liner Hanger/ Packer Liner Hanger Assembly 6683' MD - Casing Sealbore Receptacle, 4.75" ID x 20' © Baker Hughes 2005. This document may not be reproduced or distributed, in whole or in part, in any form or by any means electronic or mechanical, including photocopying, recording, or by any information storage and retrieval system now known or hereafter invented, without written permission from Baker Hughes Inc. s HUGHES Baker Oil Tools Final As Run Lateral Entry Module (LEMI With Diverters and Isolation Lateral Access Diverter Lateral Isolation Diverter GS Running Tool String Installed Installed (3.00" Lateral Drift) (2.50" ID Mainbore Drift) 'GS' Profile for Coil Connector ,Running/Retrieving (1.00' Length) Snap In/Snap Out vBack Pressure Valve ✓ Positive Locating�� (1.60' Length) Collet Lateral Isolation r Flow-Thru Swivel Seals (1.25' Length) ✓ Lateral Diverter Hydraulic Ramp _/ Disconnect Isolation/ Mainbore— � I (1.50' Length) Diverter Sleeve GS Spear (1.50' Length) Lateral Isolation 6.85 ft Approx. Seals OAL* *Jars may be required in highly deviated 1 18.5' Diverter Length 18.5' Sleeve Length or deep applications (6' approx length). 3-1/2" Guide Shoe 4-1/2" Liner Shoe, 11.0, L-80 BTC Set @ 13913' MD, 3773' TVD 6705' MD - Bottom of Seal Assembly 4.75" Seal OD 'AT Sand Lateral , 3.875" ID 4.1/2" 11.6# L-80 BTC Blank and Slotted Liner 7-5/8", 29.7#, Casing Shoe, Set at @ 7493' MD, 3808' TVD, 88 deg inc Eauioment Soecifications 4-1/2" X 7-5/8" HOOK Hanger Mainbore Drift: 5.32" Mainbore Drift, with diverter: 4.63" Lateral Drift, no diverter or LEM: 3.88" Lateral Drift, w/ diverter, no LEM: 3.88" Lateral/Mainbore Diverter OD: 6.75" 4-1/2" Lateral Entry Module Mainbore Drift: 3.65" Mainbore Drift, w/ isolation sleeve: 2.50" Lateral Drift, w/ coil diverter: 3.00" OD of Diverter and Sleeve: +/- 3.89" Diverter and Sleeve Length: +/- 18.5' 4.1/2" Eccentric Guide Shoe 4-1/2" Casing Shoe, 11.6# L-80 BTC Set @ 13708' MD, 3908' TVD KUP PROD WELLNAME U-115 WELLBORE U-115 ConoCoPhillips r Alaska, Inc. ... Well Attributes I Max Angle & MD TD Field Name Wellbore API/UWI Wellbore Status WEST SAK 500292332000 PROD Incl (') MD (ftKB) Act 92.39 13,474.70 13,720.0 Btm (ftKB) Comment H2S (ppm) Date Annotation End Date KB-Grd (ft) Rig SSSV: NONE Last WO: 9/6/2017 32.20 11/28/2006 Release Dale Multiple Laterals, 1J-115, 12/27/201912:04:20 PM Last Tag Vertical schematic (actual) Annotation Depth (ftKB) End Data Wellbore Last Mod By ......................................... .............................. ........... HANGER; 22.3 .AN CONDUCTOR; 30.0-108.0L _ SURFACE; 26.0-3,009.0- GAS LIFT; 3,344.3 GAS LIFT; 5,022.8 PACKER; 5,094.0 GAS LIFT; 5,200.2 GAUGE; 5,389.0 ESP Intake; 5,453.4 Upper Tandem; 5,464.0 Lower Tandem; 5,470.8 ESP Motors; s,an.7 J MOTOR GAUGE; 5,490.1 Centralizer; 5,492.0 1 B LINER LEM; 6,198.0-6,704.9 B LINER HH; 6,530.9-6,797.7 D LINER HH; 6,533.2-6,797.7 SLOTS; 7,234.0-7,614.0- INTERMEDIATE; 26.3-7,493.0 SLOTS; 7,786.0.8,127.0 SLOTS; 8,382.0-11,770.0 _ SLOTS; 12,157.0-12,546.0 _ _ SLOTS; 12,719.0-13,360.0 -_ -_ SLOTS; 13,533.0-13,664.0 _ A -SAND LINER; 6,652.0- 13,708.0 Last Tag: 1J-115 Imosbor Last Rev Reason Annotation End Date Wellbore Last Mod By Rev Reason: Pulled ESP, Packoff, Slip Stop & SOV, C/O Gas Lift 12/1/2019 Jjhansen8 Casing Strings Casing Description CONDUCTOR OD (in) 20 ID (in) 19.12 Top (ftKB) 30.0 Set Depth (ftKB) 108.0 Set Depth (TVD)... 108.0 Wt/Len (I... 94.00 Grade K-55 Top Thread WELDED Casing Description SURFACE OD (in) 10314 ID (in) 9.95 Top (ftKB) 26.0 Set Depth (ftKB) 3,009.0 Set Depth (TVD)... 2,214.9 WtlLen (I... 45.50 Grade L-80 Top Thread BTC Casing Description INTERMEDIATE OD (in) 7 5/8 ID (in) 6.87 Top (ftKB) 26.3 Set Depth (ftKB) 7,493.0 Set Depth (TVD)... 3,808.4 WtlLen (I... 29.70 Grade L-80 Top Thread BTCM Casing Description B LINER LEM OD (in) 41/2 ID (in) 3.86 Top (ftKB) 6,198.0 Set Depth (ftKB) 6,704.9 Set Depth (TVD)... 3,680.9 WtlLen (I... 12.60 Grade L80 Top Thread IBT-SCC Liner Details Top INKS) Top (TVD) (ftKB) Top Incl (") Item Des Com Nominal ID (in) 6,198.0 3,573.9 81.03 PACKER 7-5/8" x 5-1/2" ZXP liner top packer 4.970 6,217.0 3,576.9 80.87 SBR Casing Seal Bore Receptacle 4.750 6,236.7 3,580.0 80.58 XO BUSHING Cross Over Bushing 3.960 6,520.3 3,638.1 76.47 HANGER LEM (above hook hanger) 3.688 6,530.9 3,640.6 76.26 HANGER LEM (inside hook hanger) 3.688 6,626.0 3,663.9 76.47 NIPPLE DB-6 Nipple 3.563 6,658.4 3,671.2 77.38 BENTJT Bent Joint 3.860 6,701.61 3,680.3 78.36 SEALASSY Seal assembly 3.860 Casing Description OD (in) ID (in) Top (ftKB) Set Depth (ftKB) Set Depth (TVD)... WtlLen (I... Grade Top Thread B LINER HH 41/2 4.00 6,530.9 6,797.7 3,698.7 11.60 L80 BTC Liner Details Top (ftKB) Top (TVD) (ftKB) Top Incl (") Item Des Com Nominal ID (in) 6,530.9 3,640.6 76.26 HANGER Hook Hanger (below window) 5.610 6,608.9 3,659.8 75.98 ECP External Casing Packer 3.900 6,767.6 3,693.0 79.11 BENT JT Bent joint w/ muleshoe 3.960 Casing Description OD (in) ID (in) Top (ftKB) Set Depth (ftKB) Set Depth (TVD)... WtlLen (I... Grade Top Thread D LINER HH 4 1/2 3.48 6,533.2 6,797.7 3,698.7 11.60 L-80 BTCM Liner Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Com Nominal ID (in) 6,533.2 3,641.1 76.21 HANGER BAKER MODEL PZ HOOK HANGER (INSIDE CSG) 3.950 6,550.0 3,645.2 75.88 HANGER BAKER MODEL PZ HOOK HANGER (OUTSIDE CSG) 3.950 6,607.1 3,659.4 75.93 ECP BAKER PZ EXTERNAL CASING PACKER 3.900 6,769A 3,693A 79,12 BENT IT i3.960 Casing Description A -SAND LINER OD (in) 41/2 ID (in) 3.48 I Top (ftKB) 6,652.0 Set Depth (ftKB) 13,708.0 Set Depth (TVD)... 3,909.9 WtlLen (I... 11.60 Grade L-80 Top Thread Buttress Thread Liner Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Com Nominal ID (in) 6,652.0 3,669.8 77.20 PACKER BIKER HRD ZXP LINER TOP PACKER 5.500 6,671.0 3,674.0 77.74 NIPPLE 'RS' PACKOFF SEAL NIPPLE 4.870 6,673.9 3,674.6 77.82 HANGER FLEX -LOCK LINER HANGER 4.850 6,683.8 3,676.6 78.04 SBE 190-47 SEAL BORE EXTENSION 4.750 Tubing Strings Tubing Description String Ma... ID (in) Top (ftKB) Set Depth (ft.. Set Depth (TVD) (... Wt (lb/ft) Grade lop Connection TUBING 41/2 3.9E 22.3 5.493.9 3,352.8 12.60 L-80 TXPM Completion Details Top (ftKB) Top (TVD) (ftKB) Top Incl I, Item Des Com Nominal ID (in) 22.3 22.3 0.00 HANGER Tubing Hanger, Vetco-Gray MB222A offset 10 314 x 4 1/2 w/false bowl 3.900 5,094.0 3,179.6 63.62 PACKER Viking Vented Packer SN: VCT-PO-17-335-2 3.902 5,389.0 3,307.9 64.59 GAUGE WeIILIft Discharge Gauge Unit, Centrilift 3.958 5,453.4 3,335.5 64.63 ESP Intake TTC Drilled Crossover, Centrilift 5,464.0 3,340.0 64.65 Upper Tandem Upper Tandem Seal Section, Centrilift 5,470.8 3,343.0 64.66 Lower Tandem Lower Tandem Seal Section, Centrilift 5,477.7 3,345.9 64.67 ESP Motors ESP Motor, Centrilift, 175HP/318OV/34A 5,490.1 3,351.2 64.69 MOTOR GAUGE WellLift E Motor Gauge Unit, Centrilift 5,492.0 3,352.0 64.69 Centralizer Motor Centralizer, Centrilift Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Den (shots/ft ) Type Com 7,234.0 7,614.0 3,777.7 3,817.3 WS A2, 1J-115 10/26/2006 32.0 SLOTS ALL PERFS IN WELL: Alternating solid/slotted pipe - 0.125"x2.5" @ 4 circumferential adjacent rows, 3" centers staggered 18 deg, 3' non -slotted ends 7,786.0 8,127.0 3,820.8 3,822.7 WS A2, 1J-115 10/26/2006 32.0 SLOTS 8,382.0 11,770.0 3,820.6 3,842.0 WS A2, 1J-115 10/26/2006 32.0 SLOTS 12,157.0 12,546.0 3,864.3 3,888.7 WS A2, 1J-115 10/26/2006 32.0 SLOTS 12,719.0 13,360.0 3,893.6 3,909.3 WS A2, 1J-115 10/26/2006 32.0 SLOTS 13,533.0 13,664.0 3,905.1 3,907.6 WS A2, 1J-115 10/26/2006 32.0 SLOTS KUP PROD WELLNAME 1J-115 WELLBORE 1J-115 Cono� Phillips Alaska, Inc, Multiple Laterals, 1J-115, 12/27/201912:04:21 PM Mandrel Inserts Vertical schematic (actual) St at! on Top (ND) Valve Latch Port Size TRO Run HANGER; 22.3 N Top (ftKB) (ftKB) Make Model OD (in) Sery Type Type (in) (psi) Run Date Com IJ 1 3,344.3 2,375.9 Camco KBMG 4 1/2 GAS LIFT GLV BK 0.188 1,475.0 12/6/2019 2 5,022.8 3,147.8 Camco KBMG 4 1/2 GAS LIFT OV BK 0.313 0.0 12/6/2019 3 5,200.2 3,226.6 Camco KBMG 4 1/2 GAS LIFT DMY BK 0.000 0.0 12/4/2019 Notes: General & Safety End Dale Annotation 9/6/2017 NOTE: WO �N CONDUCTOR; 30.0-108.0L 1 4/24/2011 NOTE: View Schematic w/Alaska Schematic9.0 11/27/2006 NOTE: MULTI -LATERAL WELL: 1J-115 (A -SAND), 1J-11511 (B-SAND), 1J-1151_2 (D-SAND) SURFACE; 26.0-3,009.0— GAS LIFT; 3,344.3 GAS LIFT; 5,022.8 PACKER; 5,094.0 GAS LIFT; 5,200.2 GAUGE; 5,389.0 ESP Intake; 5,453.4 Upper Tandem; 5,464.0 Lower Tandem; 5,470.8 ESP Motors; 5,4" 7 MOTOR GAUGE; 5,490.1 Centralizer; 5,492.0 ) B LINER LEM; 6,198.0-6,704.9 B LINER HH; 6,530.9-6,797.7 D LINER HH; 6,533.2-6,797.7 SLOTS; 7,234.0-7,614.0� INTERMEDIATE; 26.3-7,493.0 I L SLOTS; 7,786.0-8,127.0 SLOTS; 8, 382.0-11,770.0 — SLOTS; 12,157.0-12,546.0 SLOTS; 12,719.0-13,360.0 SLOTS; 13,533.0-13,664.0 — — A -SAND LINER; 6,652.0- 13,708.0 KUP PROD WELLNAME U-115 WELLBORE 1J-115L1 ConoCoPhillips r Well Attributes I Max Angle & MD TD Alaska, Inc. Field Name WEST SAK Wellbore API/UWI Wellbore Status 500292332060 PROD lmd (°) MD (ftKB) 93.40 111,626.88 Act Bt. (ftKB) 13,922.0 Comment H2S (ppm) Date Annotation End Date KB-Grd (A) Rig Release Data ... SSSV: NONE I Last two. 32.20 11/28/2006 Multiple Laterals, 1J-115L1, 12/27/2019 12:07:10 PM Last Tag Vertical schematic (actual) Annotation Depth (ftKB) End Data Wellbore Last Mod By Last Tag: I I 1J-11511 Mimosbor .............................................................................. Last Rev Reason HANGER; 22.3 Annotation End Data Wellbore Last Mod By Rev Reason: Pulled ESP, Packoff, Slip Stop & SOV, C/O Gas Lift 12/1/2019 MR pproven Casing Strings Casing Description OD (in) ID (in) Top (ft(B) Set Depth (ftKB) Set Depth (TVD)... WVLen (I... Grade Top Thread B-SAND LINER 41/2 3.48 6,742.5 13,912.9 3,774.3 11.60 L80 BTCM Liner Details Nominal ID Top (ftKB) Top (TVD) (ftKB) Top Incl (°) It.. Des Corn (in) 6,742.5 3,657.1 91.33 SLEEVE HR liner setting sleeve 5.010 6,765.6 3,656.4 92.15 SBR Receptacle Joint T970 6,800.6 3,655.0 91.68 XO BUSHING Cross Over Bushing 3.960 MP CONDUCTOR; 30.0-108.0 13,873.6 3,771.1 85.44 XO Reducing CROSSOVER REDUCING 4.5x3.5" 2.992 Perforations & Slots Shot Den Top (TVD) Btm (TVD) (shots/ft Top (ftKB) Btm (ftKB) (ftKB) ("KB) Linked Zone Date ) Type Co. 6,540.0 13,166.0 3,642.5 3,747.E S B, 1J-115L1 11/20/2006 32.0 SLOTS ALL PERFS IN WELL: Alternating solid/slotted pipe SURFACE; 26.0-3,009.0— - 0.125"x2.5" @ 4 circumferential adjacent rows, 3" centers staggered 18 deg, 3' non -slotted ends GAS LIFT; 3.344.3 6,804.0 11,330.0 3,654.9 3,719.4 WS B, 1J-115L1 11/5/2006 32.0 SLOTS ALL PERFS IN WELL: Alternating solid/slotted pipe - 0.125"x2.5" @ 4 circumferential adjacent rows, 3" centers staggered GAS LIFT; 5,022.8 18 deg, 3' non -slotted ends 13,382.0 13,940.0 3,748.4 WS B, 1J-115Ll 11/20/2006 32.0 SLOTS ALL PERFS IN WELL: Alternating solid/slotted pipe - 0.125"x2.5" @ 4 PACKER; 5,094.0 circumferential adjacent rows, 3" centers staggered 18 deg, 3' non -slotted ends Notes: General & Safety End Date Annotation GAS LIFT; 5,200.2 4/24/2011 NOTE: View Schematic w/Alaska Schematic9.0 11/27/2006 NOTE: MULTI -LATERAL WELL: 1J-115 (A -SAND), 1J-11511 (B-SAND), 1J-1151-2 (D-SAND) GAUGE; 5,389.0 ESP Intake; 5,453.4 Upper Tandem; 5,464.0 Lower Tandem; 5,470.8 ESP Motors; 5,477.7 MOTOR GAUGE; 5,490.1 Centralizer; 5,492.0 1 B LINER LEM; 6,198.0-6,704.9 INTERMEDIATE; 26.3-7,493.0 L SLOTS; 6,804.0-11,330.0 SLOTS; 6,540.0-13,166.0 SLOTS; 13,382.0-13,940.0 B-SAND LINER; 6,742.5- 13,912.9 KUP PROD WELLNAME U-115 WELLBORE 1J-115L2 ConoCoPhillips r Well Attributes I Max Angle & MD TD Alaska, Inc. Field Name Wellbore API/UWI Wellbore Status WEST SAK 500292332061 PROD Incl (°) MD (ftKB) 93.34 6'584.06 Act Btm (ftKB) 14,000.0 Comment H2S (ppm) Date Annotation End Date KB-Grd (ft) Rig Release Data ... SSSV: NONE Last two. 32.20 11/28/2006 Multiple Laterals, 1J-115L2, 12/27/201912:07:36 PM Last Tag Vertical schematic (actual) Annotation Depth (111,06) End Data Wellbore Last Mod By Last Tag: I 1J-11512 Mimosbor ............................................................. Last Rev Reason HANGER; 22.3 II Annotation End Date Wellbore Last Mod By Rev Reason: Pulled ESP, Packoff, Slip Stop & SOV, C/O Gas Lift 12/1/2019 FEEMEMENIERipproven Casing Strings Casing Description OD (in) ID (in) lop (ftKB) Set Depth (ftKB) Set Depth (TVD)... Wt/Len (I... Grad e lop Thread D-SAND LINER 41/2 3.48 6,305.3 13,985.0 I 3,704.5 11.60 L-80 BTCM Liner Details -4Nominal ID Top (ftKB) Top (TVD) (ftKB) Top Incl (°) It.. Des Corn (in) 6,305.3 3,592.6 82.04 SLEEVE BAKER'HR' SETTING SLEEVE 5.000 6,325.2 3,595.3 82.38 SBR RECEPTACLE JOINT 4.900 6,361.1 3,599.6 83.82 XO BUSHING CROSSOVER BUSHING 3.930 Perforations & Slots Shot Den ,M7 CONDUCTOR; 30_0-108.0 Top (ftKB) Bt. (ftKB) Top (TVD) (ftKB) St. (TVD) (ftKB) Linked Zone Date (shots/ft ) Type Com 11,631.0 12,104.0 3,647.0 3,64g.2 WS D, 1J-115L2 11/5/2006 32.0 SLOTS ALL PERFS IN WELL: Alternating solid/slotted pipe - 0.125"x2.5" @ 4 circumferential adjacent rows, 3" centers staggered 18 deg, 3' non -slotted ends 12,190.0 13,874.0 3,649.9 3,700.2 WS D, lJ-115L2 11/5/2006 32.0 SLOTS ALL PERFS IN WELL: Alternating solid/slotted pipe - 0.125"x2.5" @ 4 circumferential adjacent rows, 3" centers staggered 18 deg, 3' non -slotted ends SURFACE; zs.o 3,6os.o— Notes: General & Safety End Date Annotation GAS LIFT; 3,344.3 4/24/2011 NOTE: View Schematic w/Alaska Schematic9.0 11/27/2006 NOTE: MULTI -LATERAL WELL: 1J-115 (A -SAND), 1J-11511 (B-SAND), 1J-11512 (D-SAND) GAS LIFT; 5,022.8 PACKER; 5,094.0 — GAS LIFT; 5,200.2 GAUGE; 5,389.0 ESP Intake; 5,453.4 Upper Tandem; 5,464.0 Lower Tandem; 5,470.8 ESP Motors; 5,477.7 MOTOR GAUGE; 5,490.1 Centralizer; 5,492.0 INTERMEDIATE; 26.3-7,493.0 a4 SLOTS; 11,631.0-12,104.0 SLOTS; 12,190.0-13,874.0 D-SAND LINER; 6,305.3-� 13,985.0 r. r— e STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS DEC 3 0 2019 1. Operations Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Pull Tubing ❑ AA deft ❑ Performed: Suspend ❑ Perforate ❑ Other Stimulate ❑ Alter Casing EssFryha�tdown El A=-'6v(fd'zgram ❑ Plug for Redrill ❑ 'erforate New Pool ❑ Repair Well ❑ Reenter Susp Well ❑ Convert ESP to GL ❑� 2. Operator 4. Well Class Before W k,:�/ 5. Permit to Drill Number: Name: ConocoPhillips Alaska, Inc. Development ;yr Exploratory ❑ Stratigraphic ❑ Service 206-122 3. Address: P. O. Box 100360, Anchorage, Alaska 6. API Number: 99510 4� 50-029-23320-00 7. Property Designation (Lease Number): 8. Well Name and Number: KRU 1 J-115 ADL 25650 25661 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): N/A 10. Field/Pool(s): Ku aruk River Field / West Sak Oil Pool 11. Present Well Condition Summary: Total Depth measured 13,720 feel Plugs measured none feet true vertical 3911 feet Junk measured none feet Effective Depth measured 13,708 feet Packer measured 5094, 6198, 6652 feet true vertical 3,908 feet true vertical 3180, 3574, 3670 feet Casing Length Size MD TVD Burst Collapse Conductor 78' 20" 108' 108, Surface 2,983' 10.75" 3,009, 2,215' Intermediate 7,467' 7,625" 7,493' 3,808' Liner 7,056' 4.5" 13,708' 3,910' Perforations: Horizontal slotted liner Measured depth: 7,234'-13,664' feet True Vertical depth: 3,778'-3,909' feet Tubing (size, grade, measured and true vertical depth) 4.5 " L-80 5,494' MD 3,353' TVD Packers and SSSV (type, measured and true vertical depth) Viking Vented Packer 5,094' MD 3,180' TVD Baker ZXP LinerTop packer 6,198' MD 3,574' TVD Baker HRD ZXP Liner Top Packer 6,652' MD 3,670' TVD SSSV TYPE: N/A 12. Stimulation or cement squeeze summary: Intervals treated (measured): NA Treatment descriptions including volumes used and final pressure: NA 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mct Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: Shut -In 0 0 650 150 Subsequent to operation: 589 533 598 885 200 14. Attachments (required per 20 AAC 25.070, 25.o71, s 25,283) 15. Well Class after work: WW;Service, Daily Report of Well Operations ❑' Exploratory ❑ Development Stmtigraphic ❑ Copies of Logs and Surveys Run ❑ 16. Well Status after work: Oil 0 Gas ❑ WDSPL ❑ Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP ❑ SPLUG ❑ 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: N/A Contact Name: Sydney Autry Authorized Name: Sydney Autry Authorized Title: Senior Petroleum Engineer Contact Email: sydney.autry@cop.com �2 Contact Phoge;-8Q6&68,1�3,.�r Authorized Signature: Date: Z /t% of11410 RBDMS�OEC 3 12019 DEC 3 0 2019 AOGC(; Submit Original Only Form 10-404 Revised 4/2017 ConocoPhillips December 27, 2019 AOGCC Commissioner State of Alaska, Oil & Gas Conservation Commission 333 W. 7th Ave., Suite 100 Anchorage, AK 99501 Dear Commissioner, Sydney Autry Senior Drillsite Petroleum Engineer ConocoPhillips Alaska, Inc. 700 G St. Anchorage, AK 99501 Phone: (907) 265-6813 KRU 1J-115 was an ESP lifted well with vented packer that recently experienced a downhole motor failure and has required a conversion to backup gas lift in order to reinstate production. The vented packer vent valves have been dumped and locked out on surface, along with the downhole conversion work from ESP to gas lift and passing CMIT/MITT/IA DDT. The current status of the well is "packered gas lift" with a dead ESP motor downhole. Enclosed you will find 10-404 forms for 1J-115, 1J-115L1 & 1J-115L2 (PTD 206-122, 206-123, & 206-124), the 10-426 form detailing the post downhole conversion MITs, and a summary of well events. Sincerely, Sydney Autry Senior Drillsite Petroleum Engineer ConocoPhillips Alaska, Inc. 700 G St. Anchorage, AK 99501 Phone: (907) 265-6813 1J-115 DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary 11/23/19 Attem t to BOL 1J-115 ESP unsuccessfully 11/25/19 Confirm ESP motor is bad, progress plans to convert to backup gas lift. 11/26/19 Dump packer vent valves, lockout on surface 12/01/19 Pull Sli stop/Packoff/ESP 12/04/191 Complete circ out of IA (plug set 12/3/19), Perform CMIT - PASS to 2500 psi 12/06/19 1 Install Gas Lift Design, Obtain MITT & IA DDT 12107/19 BOL 1J-115 to gas lift production 12/14/19 Troubleshoot high control line pressure - determined to be thermal (liquidpacked) 12118/19 1 Surveillance of control line pressure - both vent valve lines at 0 psi STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Submit to: Iim.rega(aalaska oovLOGICC.InsgectonsAalaskal Phoebe brooksCdalaska.aov OPERATOR: ConocoPhillips Alaska Inc FIELD / UNIT / PAD: Kuparuk / KRU / 1J Pad DATE: 12/04/19 OPERATOR REP: Justin Penfold AOGCC REP: chnswallaciagaila k o Well 11-115 Pressures: Pretest Initial 15 Min. 30 Min. 45 Min, 60 Min. PTO 2190940 TyPe Inj N Tubing 0 2490 2390 2350 Type Test P Packer TVD 3180 BBL Pump 2.5 IA 0 250D 2420 2390 I Interval O Test psi 1500 BBL Return 2.3 OA 0 20 20 20 Result P Notes: Diagnostic CMIT for conversion from ESP to Gaslifled Production Well Pressures: Pretest Inital 15 Min. 30 Min. 45 Min. 60 Min. Tubing Type Test D IA Interval i OA Result Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. FPTD ;lnj Tubing Type Test D IA Interval i OA Result Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Tubing Type Test Packer TVD EEL Pump IA Interval Test psi BBL Return OA Result Notes: Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test BBLPump IA IntervalBBL RrTVD Return OA Result es TYPE INJ codes W=Water G = Gas a = slurry I = Indusldal Wasteeader N = Not Injecting TYPE TEST Codes INTERVAL Codes Result Codes P = Pressure Tell I = Initial Test P =Pass O= Other(deswbe in Notes) 4=Four Year Cycle F=Fail V = Required by Vanance I = Inconclusive 0= Other (describe in notes) Farm 10-426 (Revised 01/2017) MIT KRU 1J-115 diagnostic CMIT TxIA 12-04-11,A. !sljjp_`� KUP PROD WELLNAME U-115 WELLBORE 1J-115 ConOcoPhif'i Alaska 1G. . Well Attributes Max, AngB13 F _ ntT v vxllmuaW4 "Ap-I--a-. 9cl1 ,M a) Acr MD1MO Ba13 lBNam Cmmminr IH2SI,Pll Oak Pnnohtlan FM Da@ SSSV: NONE LasIWO 9 DOM NGGNre) Sea TOM 11/2M2006 a.. -Dale MJessila1vm141J-115. INPlAIP13W XPM Last Tel VMeL acMms. laGuatlAnnool OepminKM) Eric Dale W 1aarMm BY ww.ER.2z.3 CONDUCTOR, L.Dlmo .n.MFT:aaw.e . 1.11sozze PACKER:Soeap car urr:.moz G9LGE:5]90 a Terall y;�o Laterpmem:5,a]U,n ESP Mekm: D4nr MOTOR GAVice. s.awa un1�r. 5..p20 1 1 e MNER LEA. . 1. me 104.9 e'lar HH a5so.86nn U UNaa HH: s.53R.Xarger] SLOTS.72aa.OTmao- INT..E..E: gr,el.0 stoisl 7.705.0a,12T.-- - - - SLOTS, e.amov.T2o.p-- - _ _ _ _ .Lora: 215L0,12Sp 0- _ .Lois .LOT.. OsTaGlawao-- - XNARD LINER: sASSELD 13.2CB0 lass Tag'. 1J-11 +, Imosmr Last Rev Reason Annoml wanmre l ola m8 Rev ReasoO.-Pulled, ESP, Paclw6_ Slip Stops SOV, CA) Gas Eik 1ol'ArI9a1e I.Y115 ILansen Casing Strings caanp Dessidgllnl 00NDUCTOR DD(al 20 ID0n) 1912 Permits) 300 Set DepN goal 108.0 set aeNn lT ]DI .. 1080 9400 CUInp Deaulpticn SURFACE OD llnl 10314 IO 6n1 995 Tpp DtNMI 26.0 SN Depin (11K81 3.0090 Sat DCglr jlVp)... 2,214.9 WVLen.. 4550 OnlnpDnaptl[nODpnl >SIS ID6n1 6,8) 'llllllMl 26.3 eel DepN lnkel ]4930 Set DapM (rYU1... 3,808.4 WIMen p.. 29.>0 jKM eINTERMEDIATE f4,970 CealnpOeaeIIn1IDOn) 8 LINER LEM 410 3BE Tep 1AKB) 6.1NO sR..Pgg IIKBI 6)04.9 ast DeIn(not TUBS .(11.. 12.60Liner Details Top girl loplNelle n Top Intl T Ikm Oes COm al lD.L.Bieos.00i rSB'x5V2"ZXP 6.198.3,5]39 8103 PACKER ]- IiOer loppacker 9]0 6,217.0 3.576.9 80,87 SBR Casing seolong speo'nacle 4750 6,236.7 3,580.0 S0.58 XO BUSHING COOS Ovel Bushing SRI 3 3,61 ]64] HANGER LEM peovehookam0eq BB 6.530.9 3.640.6 7626 HANGER LEM(mAge Look Lan9e0 3.688 6.6260 3663.9 ]6,4] NIPPLE OB 6Nipple 3.563 Isfil 3,671.2 BENTJT Bent JOinl 8w 67016 3,111 ]8.31 SEALAS11 Seal asSeJnbly 3.860 casing Oescelptlm ODQnI ID gg TOp se BLMER HH 4112 4.IX1 6530.9 ael OepN (nKBI SR OepYIrND)... WbLT p.. GmEe 6.>9Z> 3,69H] i1 G0 L80 TOpThf2a4 eTC Liner Details lip Inner Top INOI 1n in TOP Intl l'I as D No Ilnl 9 3,6466 ]626 HANGER HOOIt Harlgtl HAPP, LMnepWl 5.610 6SUBI 3.659.8 7598 ECP Battered Casing Pa&e1 3.WO 6.]6].6 WF 3.693.0 ]9.11 BENTJT Bent pint cal or fien oe 3960 Caelne tee Op 10 pa1reL HH 412) 3.408) 6,53Togil32) Q)9UMRB) sg Bmm BsXg_.1vJul�a10-Grace ioPTLrmn 80 BTCM Liner Details TO,gi Top(TVDI PA1.1 op ncl l'1 km 0ez cm. ,min (ln 110 65332 3,641.1 7621 HANGER BAKER MODEL PZ HOOK HANGER (INSIDE CSGi 3.9W 6.5500 3.645.2*6� BAKER MODEI PZ HOOK HANGER (OUTSIDE CSG) 3,950 6,60].1 36694BAKER PZ XTERNAL CASING PACKER 3,W0 6,]6 A 36934 3.960 Caainp Des[rlptlu, LINER OD lln)l 41R Oepin llKel >08.0 Sal OOpin jIVOI... 3,909.9 WtlIm 11... 1160 Ggee L-80 TOPThrWASAND Entrees Mere Liner Details TOP lnnal T tpvol(nxa) rt TO,.I lon, Dea No SO) 6.652.0 3,669.8 R20 PACKER BKER PRO ZXP LINER TOP PACKER 5500 6,6710 3674.0 7774 NIPPLE 'RS' RACKOFF SEAL NIPPLE 4.BID 6,673.9 3674.6 ]L82 HANGER FLEX -LOCK LINER HANGER 48W 6.683.8 3,676.6 ]604 SEE 191 SEAL BORE EXTENSION Tubing Strings ola^60escnpnm aMlp Ma...111)(1.) TeP rune) eel DepM n-ISR.PN Loot L.. Wt 0.) .pale Tep Oolm . TUBING 412 3.96 22.3 6493.9 3,352.8 12.60 L-80 TXPM Completion Details Top mice In(rvgr (race) TpPk[l I') k Immea Qom Nominal m nr a 22.3 OOD HANGER Tutim,Hanger. VetcoGTry MB222A offsel 10314 x 4 IN carries bowl 3.900 50940 3.179.6 63.62 PACKER Viking Ventral Packer SN: VCT-PO-17-3352 _3 5.389.0 3. ]9 64.59 GAUGE WeIIDD Discharge Gauge Una, Cslnbiift 3.958 5,453.4 3.335.5 64.fi3 ESP Intake TTC Ddiled Cr.SR.Oa Csnbilift 5464.0 3,3400 64.asUp per Tandem U WM Tandem Seal Season. CemnA 54708 $3430 64K6 Laser TanEem Lowe+ Tmull Seal Semon CenhiliD 5,4777 3,3459 6467 ESPMpt.,S ESPMotol. Cominiih, 175HPr31BOV134A 5,4901 3.3512 64.Be MOTORGAUGE WeBLIk E Motor Gauge Unit CenlriliD 5,492.0 33520 64,69 Centralizer Mors Cemrellzel, Campoin Perforations & Slots TOTIIMa) eim6140 Topss) 3.77 lmlrvm .Irma mzone oaO Den Ivnoum ) Type ],234.0 ].616A 3.A]] 38173 WSP2.1J-1 t012fi12006 32.08LOT5 ALL indo,pNWELL - 0126tin95obbsiOHen Pipe -etapol IO,S" La) 4 mmumieWooly sw"nl ws,3'centersotted ros 18 tle93'non-slatteJ erMs ],]86.0 6.127G 3 8 36 7 WSA21J-115 10/2WM_ 22.0 SLOTS 8.382.0 11,700 38ffi6 3842.0 W A2. 1J-115 10/26/200$ 32. SLOTS 12.1570 1 ,646.0 3664.3 3868.7 WI 1J-115 pvoivZ008 i32.0 SLOTS .83,6 3.9093WSA2,1J-116 ID/26I2006 320SLOTS 13,533.0 13.6640 3,9051 3.90zfi WS P2, 1J-115 1012612008 I 32.0 SLOTS KUP PROD WELLNAME 1J-115 WELLBORE 1J_115 ConocoPhillips � 41aska.lGo. Mu6ldc ltlerM.N. s. 12rz]FA 13 rzmz�vM Mandrel Inserts Vellolulemwc Rclull St tl WWGER: p,3� R Top (RNe) 3. T(1K.) IRNO) 2,147 MaF Camme MWeI KBMG OII Rn) 4112 GAS LIFT Valve TyPe GLV La1cM1 1 PoHSIx Ilnl TRO Run 1,05.0 1.10 Run Odfe 1 19 COm 2 2 5.9 Cameo KBMG a v2 GAS LIFT OV BK 0.313 09 12/62019 J 2 5,2p02 3,228.8 3LVs6 Ca. KBMG Otl2 GAS LIFT DMV aK OUW 0.01214121119 Notes: General & Safety Enp Gale nnnovaon 9/6299 NOTE: WG cCM TOR30.Ue(00 41 12G11 1 NOTEyew SCM1emalic wlAWska'PO,PM, 1112➢2906 lwTE MULTLLATERALWELL iJ-115(ABAND),U-1150(94111) 1141119D�SAND) SUR STE', MCL3CM.O- 6R6 LIFT; 33N 3 GO$ LIFT; 3W3.a PTLHESLS a0 W6 LIFI; S. A33 WUGE. S3x.0 ESP YilaMfl 5.6531 Upm, T.. siMO Lower TaM—, S.aroe ESP S.an] MOTOR GAUGE; E..I LeM4mr.5 i920 ) a LINER M., IIx.08,iW,e aUI R HH, 6.EOS SLE.19)i O S,ER HH; 6.533, ZSM7 i I` 1 aLOT6'. i, 23e.0.1614a� WTERMEOIATE. 2617 Y,D 6LOTs, SLOTs.G�2U11.: SLOTS', I2,157612S16,0� 6LOT6: 12]19 0.13, 3m.O� SLOTS. 135]3U13.F61.0�� A-EAN0 LINER; 1852.0 13]INO— r. r— e STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS DEC 3 0 2019 1. Operations Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Pull Tubing ❑ AA deft ❑ Performed: Suspend ❑ Perforate ❑ Other Stimulate ❑ Alter Casing EssFryha�tdown El A=-'6v(fd'zgram ❑ Plug for Redrill ❑ 'erforate New Pool ❑ Repair Well ❑ Reenter Susp Well ❑ Convert ESP to GL ❑� 2. Operator 4. Well Class Before W k,:�/ 5. Permit to Drill Number: Name: ConocoPhillips Alaska, Inc. Development ;yr Exploratory ❑ Stratigraphic ❑ Service 206-122 3. Address: P. O. Box 100360, Anchorage, Alaska 6. API Number: 99510 4� 50-029-23320-00 7. Property Designation (Lease Number): 8. Well Name and Number: KRU 1 J-115 ADL 25650 25661 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): N/A 10. Field/Pool(s): Ku aruk River Field / West Sak Oil Pool 11. Present Well Condition Summary: Total Depth measured 13,720 feel Plugs measured none feet true vertical 3911 feet Junk measured none feet Effective Depth measured 13,708 feet Packer measured 5094, 6198, 6652 feet true vertical 3,908 feet true vertical 3180, 3574, 3670 feet Casing Length Size MD TVD Burst Collapse Conductor 78' 20" 108' 108, Surface 2,983' 10.75" 3,009, 2,215' Intermediate 7,467' 7,625" 7,493' 3,808' Liner 7,056' 4.5" 13,708' 3,910' Perforations: Horizontal slotted liner Measured depth: 7,234'-13,664' feet True Vertical depth: 3,778'-3,909' feet Tubing (size, grade, measured and true vertical depth) 4.5 " L-80 5,494' MD 3,353' TVD Packers and SSSV (type, measured and true vertical depth) Viking Vented Packer 5,094' MD 3,180' TVD Baker ZXP LinerTop packer 6,198' MD 3,574' TVD Baker HRD ZXP Liner Top Packer 6,652' MD 3,670' TVD SSSV TYPE: N/A 12. Stimulation or cement squeeze summary: Intervals treated (measured): NA Treatment descriptions including volumes used and final pressure: NA 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mct Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: Shut -In 0 0 650 150 Subsequent to operation: 589 533 598 885 200 14. Attachments (required per 20 AAC 25.070, 25.o71, s 25,283) 15. Well Class after work: WW;Service, Daily Report of Well Operations ❑' Exploratory ❑ Development Stmtigraphic ❑ Copies of Logs and Surveys Run ❑ 16. Well Status after work: Oil 0 Gas ❑ WDSPL ❑ Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP ❑ SPLUG ❑ 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: N/A Contact Name: Sydney Autry Authorized Name: Sydney Autry Authorized Title: Senior Petroleum Engineer Contact Email: sydney.autry@cop.com �2 Contact Phoge;-8Q6&68,1�3,.�r Authorized Signature: Date: Z /t% of11410 RBDMS�OEC 3 12019 DEC 3 0 2019 AOGC(; Submit Original Only Form 10-404 Revised 4/2017 ConocoPhillips December 27, 2019 AOGCC Commissioner State of Alaska, Oil & Gas Conservation Commission 333 W. 7th Ave., Suite 100 Anchorage, AK 99501 Dear Commissioner, Sydney Autry Senior Drillsite Petroleum Engineer ConocoPhillips Alaska, Inc. 700 G St. Anchorage, AK 99501 Phone: (907) 265-6813 KRU 1J-115 was an ESP lifted well with vented packer that recently experienced a downhole motor failure and has required a conversion to backup gas lift in order to reinstate production. The vented packer vent valves have been dumped and locked out on surface, along with the downhole conversion work from ESP to gas lift and passing CMIT/MITT/IA DDT. The current status of the well is "packered gas lift" with a dead ESP motor downhole. Enclosed you will find 10-404 forms for 1J-115, 1J-115L1 & 1J-115L2 (PTD 206-122, 206-123, & 206-124), the 10-426 form detailing the post downhole conversion MITs, and a summary of well events. Sincerely, Sydney Autry Senior Drillsite Petroleum Engineer ConocoPhillips Alaska, Inc. 700 G St. Anchorage, AK 99501 Phone: (907) 265-6813 1J-115 DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary 11/23/19 Attem t to BOL 1J-115 ESP unsuccessfully 11/25/19 Confirm ESP motor is bad, progress plans to convert to backup gas lift. 11/26/19 Dump packer vent valves, lockout on surface 12/01/19 Pull Sli stop/Packoff/ESP 12/04/191 Complete circ out of IA (plug set 12/3/19), Perform CMIT - PASS to 2500 psi 12/06/19 1 Install Gas Lift Design, Obtain MITT & IA DDT 12107/19 BOL 1J-115 to gas lift production 12/14/19 Troubleshoot high control line pressure - determined to be thermal (liquidpacked) 12118/19 1 Surveillance of control line pressure - both vent valve lines at 0 psi STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Submit to: Iim.rega(aalaska oovLOGICC.InsgectonsAalaskal Phoebe brooksCdalaska.aov OPERATOR: ConocoPhillips Alaska Inc FIELD / UNIT / PAD: Kuparuk / KRU / 1J Pad DATE: 12/04/19 OPERATOR REP: Justin Penfold AOGCC REP: chnswallaciagaila k o Well 11-115 Pressures: Pretest Initial 15 Min. 30 Min. 45 Min, 60 Min. PTO 2190940 TyPe Inj N Tubing 0 2490 2390 2350 Type Test P Packer TVD 3180 BBL Pump 2.5 IA 0 250D 2420 2390 I Interval O Test psi 1500 BBL Return 2.3 OA 0 20 20 20 Result P Notes: Diagnostic CMIT for conversion from ESP to Gaslifled Production Well Pressures: Pretest Inital 15 Min. 30 Min. 45 Min. 60 Min. Tubing Type Test D IA Interval i OA Result Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. FPTD ;lnj Tubing Type Test D IA Interval i OA Result Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Tubing Type Test Packer TVD EEL Pump IA Interval Test psi BBL Return OA Result Notes: Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test BBLPump IA IntervalBBL RrTVD Return OA Result es TYPE INJ codes W=Water G = Gas a = slurry I = Indusldal Wasteeader N = Not Injecting TYPE TEST Codes INTERVAL Codes Result Codes P = Pressure Tell I = Initial Test P =Pass O= Other(deswbe in Notes) 4=Four Year Cycle F=Fail V = Required by Vanance I = Inconclusive 0= Other (describe in notes) Farm 10-426 (Revised 01/2017) MIT KRU 1J-115 diagnostic CMIT TxIA 12-04-11,A. !sljjp_`� KUP PROD WELLNAME U-115 WELLBORE 1J-115 ConOcoPhif'i Alaska 1G. . Well Attributes Max, AngB13 F _ ntT v vxllmuaW4 "Ap-I--a-. 9cl1 ,M a) Acr MD1MO Ba13 lBNam Cmmminr IH2SI,Pll Oak Pnnohtlan FM Da@ SSSV: NONE LasIWO 9 DOM NGGNre) Sea TOM 11/2M2006 a.. -Dale MJessila1vm141J-115. INPlAIP13W XPM Last Tel VMeL acMms. laGuatlAnnool OepminKM) Eric Dale W 1aarMm BY ww.ER.2z.3 CONDUCTOR, L.Dlmo .n.MFT:aaw.e . 1.11sozze PACKER:Soeap car urr:.moz G9LGE:5]90 a Terall y;�o Laterpmem:5,a]U,n ESP Mekm: D4nr MOTOR GAVice. s.awa un1�r. 5..p20 1 1 e MNER LEA. . 1. me 104.9 e'lar HH a5so.86nn U UNaa HH: s.53R.Xarger] SLOTS.72aa.OTmao- INT..E..E: gr,el.0 stoisl 7.705.0a,12T.-- - - - SLOTS, e.amov.T2o.p-- - _ _ _ _ .Lora: 215L0,12Sp 0- _ .Lois .LOT.. OsTaGlawao-- - XNARD LINER: sASSELD 13.2CB0 lass Tag'. 1J-11 +, Imosmr Last Rev Reason Annoml wanmre l ola m8 Rev ReasoO.-Pulled, ESP, Paclw6_ Slip Stops SOV, CA) Gas Eik 1ol'ArI9a1e I.Y115 ILansen Casing Strings caanp Dessidgllnl 00NDUCTOR DD(al 20 ID0n) 1912 Permits) 300 Set DepN goal 108.0 set aeNn lT ]DI .. 1080 9400 CUInp Deaulpticn SURFACE OD llnl 10314 IO 6n1 995 Tpp DtNMI 26.0 SN Depin (11K81 3.0090 Sat DCglr jlVp)... 2,214.9 WVLen.. 4550 OnlnpDnaptl[nODpnl >SIS ID6n1 6,8) 'llllllMl 26.3 eel DepN lnkel ]4930 Set DapM (rYU1... 3,808.4 WIMen p.. 29.>0 jKM eINTERMEDIATE f4,970 CealnpOeaeIIn1IDOn) 8 LINER LEM 410 3BE Tep 1AKB) 6.1NO sR..Pgg IIKBI 6)04.9 ast DeIn(not TUBS .(11.. 12.60Liner Details Top girl loplNelle n Top Intl T Ikm Oes COm al lD.L.Bieos.00i rSB'x5V2"ZXP 6.198.3,5]39 8103 PACKER ]- IiOer loppacker 9]0 6,217.0 3.576.9 80,87 SBR Casing seolong speo'nacle 4750 6,236.7 3,580.0 S0.58 XO BUSHING COOS Ovel Bushing SRI 3 3,61 ]64] HANGER LEM peovehookam0eq BB 6.530.9 3.640.6 7626 HANGER LEM(mAge Look Lan9e0 3.688 6.6260 3663.9 ]6,4] NIPPLE OB 6Nipple 3.563 Isfil 3,671.2 BENTJT Bent JOinl 8w 67016 3,111 ]8.31 SEALAS11 Seal asSeJnbly 3.860 casing Oescelptlm ODQnI ID gg TOp se BLMER HH 4112 4.IX1 6530.9 ael OepN (nKBI SR OepYIrND)... WbLT p.. GmEe 6.>9Z> 3,69H] i1 G0 L80 TOpThf2a4 eTC Liner Details lip Inner Top INOI 1n in TOP Intl l'I as D No Ilnl 9 3,6466 ]626 HANGER HOOIt Harlgtl HAPP, LMnepWl 5.610 6SUBI 3.659.8 7598 ECP Battered Casing Pa&e1 3.WO 6.]6].6 WF 3.693.0 ]9.11 BENTJT Bent pint cal or fien oe 3960 Caelne tee Op 10 pa1reL HH 412) 3.408) 6,53Togil32) Q)9UMRB) sg Bmm BsXg_.1vJul�a10-Grace ioPTLrmn 80 BTCM Liner Details TO,gi Top(TVDI PA1.1 op ncl l'1 km 0ez cm. ,min (ln 110 65332 3,641.1 7621 HANGER BAKER MODEL PZ HOOK HANGER (INSIDE CSGi 3.9W 6.5500 3.645.2*6� BAKER MODEI PZ HOOK HANGER (OUTSIDE CSG) 3,950 6,60].1 36694BAKER PZ XTERNAL CASING PACKER 3,W0 6,]6 A 36934 3.960 Caainp Des[rlptlu, LINER OD lln)l 41R Oepin llKel >08.0 Sal OOpin jIVOI... 3,909.9 WtlIm 11... 1160 Ggee L-80 TOPThrWASAND Entrees Mere Liner Details TOP lnnal T tpvol(nxa) rt TO,.I lon, Dea No SO) 6.652.0 3,669.8 R20 PACKER BKER PRO ZXP LINER TOP PACKER 5500 6,6710 3674.0 7774 NIPPLE 'RS' RACKOFF SEAL NIPPLE 4.BID 6,673.9 3674.6 ]L82 HANGER FLEX -LOCK LINER HANGER 48W 6.683.8 3,676.6 ]604 SEE 191 SEAL BORE EXTENSION Tubing Strings ola^60escnpnm aMlp Ma...111)(1.) TeP rune) eel DepM n-ISR.PN Loot L.. Wt 0.) .pale Tep Oolm . TUBING 412 3.96 22.3 6493.9 3,352.8 12.60 L-80 TXPM Completion Details Top mice In(rvgr (race) TpPk[l I') k Immea Qom Nominal m nr a 22.3 OOD HANGER Tutim,Hanger. VetcoGTry MB222A offsel 10314 x 4 IN carries bowl 3.900 50940 3.179.6 63.62 PACKER Viking Ventral Packer SN: VCT-PO-17-3352 _3 5.389.0 3. ]9 64.59 GAUGE WeIIDD Discharge Gauge Una, Cslnbiift 3.958 5,453.4 3.335.5 64.fi3 ESP Intake TTC Ddiled Cr.SR.Oa Csnbilift 5464.0 3,3400 64.asUp per Tandem U WM Tandem Seal Season. CemnA 54708 $3430 64K6 Laser TanEem Lowe+ Tmull Seal Semon CenhiliD 5,4777 3,3459 6467 ESPMpt.,S ESPMotol. Cominiih, 175HPr31BOV134A 5,4901 3.3512 64.Be MOTORGAUGE WeBLIk E Motor Gauge Unit CenlriliD 5,492.0 33520 64,69 Centralizer Mors Cemrellzel, Campoin Perforations & Slots TOTIIMa) eim6140 Topss) 3.77 lmlrvm .Irma mzone oaO Den Ivnoum ) Type ],234.0 ].616A 3.A]] 38173 WSP2.1J-1 t012fi12006 32.08LOT5 ALL indo,pNWELL - 0126tin95obbsiOHen Pipe -etapol IO,S" La) 4 mmumieWooly sw"nl ws,3'centersotted ros 18 tle93'non-slatteJ erMs ],]86.0 6.127G 3 8 36 7 WSA21J-115 10/2WM_ 22.0 SLOTS 8.382.0 11,700 38ffi6 3842.0 W A2. 1J-115 10/26/200$ 32. SLOTS 12.1570 1 ,646.0 3664.3 3868.7 WI 1J-115 pvoivZ008 i32.0 SLOTS .83,6 3.9093WSA2,1J-116 ID/26I2006 320SLOTS 13,533.0 13.6640 3,9051 3.90zfi WS P2, 1J-115 1012612008 I 32.0 SLOTS KUP PROD WELLNAME 1J-115 WELLBORE 1J_115 ConocoPhillips � 41aska.lGo. Mu6ldc ltlerM.N. s. 12rz]FA 13 rzmz�vM Mandrel Inserts Vellolulemwc Rclull St tl WWGER: p,3� R Top (RNe) 3. T(1K.) IRNO) 2,147 MaF Camme MWeI KBMG OII Rn) 4112 GAS LIFT Valve TyPe GLV La1cM1 1 PoHSIx Ilnl TRO Run 1,05.0 1.10 Run Odfe 1 19 COm 2 2 5.9 Cameo KBMG a v2 GAS LIFT OV BK 0.313 09 12/62019 J 2 5,2p02 3,228.8 3LVs6 Ca. KBMG Otl2 GAS LIFT DMV aK OUW 0.01214121119 Notes: General & Safety Enp Gale nnnovaon 9/6299 NOTE: WG cCM TOR30.Ue(00 41 12G11 1 NOTEyew SCM1emalic wlAWska'PO,PM, 1112➢2906 lwTE MULTLLATERALWELL iJ-115(ABAND),U-1150(94111) 1141119D�SAND) SUR STE', MCL3CM.O- 6R6 LIFT; 33N 3 GO$ LIFT; 3W3.a PTLHESLS a0 W6 LIFI; S. A33 WUGE. S3x.0 ESP YilaMfl 5.6531 Upm, T.. siMO Lower TaM—, S.aroe ESP S.an] MOTOR GAUGE; E..I LeM4mr.5 i920 ) a LINER M., IIx.08,iW,e aUI R HH, 6.EOS SLE.19)i O S,ER HH; 6.533, ZSM7 i I` 1 aLOT6'. i, 23e.0.1614a� WTERMEOIATE. 2617 Y,D 6LOTs, SLOTs.G�2U11.: SLOTS', I2,157612S16,0� 6LOT6: 12]19 0.13, 3m.O� SLOTS. 135]3U13.F61.0�� A-EAN0 LINER; 1852.0 13]INO— PTD '?o6-/Zz Loepp, Victoria T (CED) From: Well Integrity Compliance Specialist CPF1 & 2 <n1617@conocophillips.com> Sent: Thursday, November 28, 2019 3:46 PM To: Schwartz, Guy L (CED); Loepp, Victoria T (CED) Cc: Autry, Sydney; NSK West Sak Prod Engr Subject: RE: [EXTERNAL]RE: 11-115 (PTD# 206-122) ESP conversation to lift gas with Viking duel vented ESP packer. Attachments: KRU WSAK 1J-115 ESP-GL CONVERSION.pdf Follow Up Flag: Follow up Flag Status: Flagged Guy - Attached is the procedure to convert 11-115 from an ESP producer to a GL producer. At the time of completion, a 10- 404 will be submitted along with the 10-426s for the MITs conducted during testing. Happy Thanksgiving to you and your family. Dusty Freeborn/Jan Byrne Wells Integrity & Compliance Specialist ConocoPhillips Alaska, Inc. Office phone: (907) 659-7224 Cell phone: (907) 830-9777 WELLS TEAM From: Schwartz, Guy L (CED) <guy.schwartz@alaska.gov> Sent: Wednesday, November 27, 2019 2:48 PM To: Well Integrity Compliance Specialist CPF1 & 2 <n1617@conocophillips.com>; Loepp, Victoria T (CED) <victo ria.loepp@a laska.gov> Cc: Autry, Sydney <Sydney.Autry@conocophillips.com>; NSK West Sak Prod Engr <n1638@conocophillips.com> Subject: [EXTERNAL]RE: 1J-115 (PTD# 206-122) ESP conversation to lift gas with Viking duel vented ESP packer. Dusty, Send me a procedure by email to convert to GL. Should be able to do this without a sundry. Will require a 10-404 after the conversion however. Guy Schwartz Sr. Petroleum Engineer AOGCC 907-301-4533 cell 907-793-1226 office CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Guy Schwartz at f907-793-1226 ) or (Guv schwartznalaska.00_v). From: Well Integrity Compliance Specialist CPF1 & 2 <n1617@conocophillips.com> Sent: Wednesday, November 27, 2019 1:20 PM To: Loepp, Victoria T (CED) <victoria.loepp@alaska.gov>; Schwartz, Guy L (CED) <euy.schwartz@alaska.aov> Cc: Autry, Sydney <Svdnev.Autry@conocophillips.com>; NSK West Sak Prod Engr <n1638@conocophi1lips.com> Subject: 1J-115 (PTD# 206-122) ESP conversation to lift gas with Viking duel vented ESP packer. Victoria/Guy- 1J-115 (PTD# 206-122) is an ESP oil producer in which the ESP motor has failed. The well is equipped with a 6.690" Viking duel vented ESP packer that CPAI intends to cycle closed and convert the well to lift gas until a rig work over can be performed sometime during Q3 of 2020. The integrity of the packer will be tested with an MIT -IA once it is in the closed position. Is there any associated paperwork that needs to be submitted for the conversion of an ESP oil producer to a gas lifted oil producer via closing the vented packer? I appreciate the guidance in advance. Dusty Freeborn/Jan Byrne Wells Integrity & Compliance Specialist ConocoPhillips Alaska, Inc. Office phone: (907) 659-7224 Cell phone: (907) 830-9777 WELLS TEAM conocx)lt "Wvs KRU WSAK 1J-115 Description Summary of Proposal. Well Work Justification & Objectives (and date required if appropriate): 1J-115 was just determined to have a failed motor (suspect water leaked into boot seal near pothead). The plan forward is to convert to gas lift while awaiting a RWO. Please pull the pump/packoff, perform a flush of the IA, and install a GLD. Risk/Job Concerns: -Thru-Tubing conveyed ESP (NOT RIGLESS) --> no access below motor to laterals (no D LEM anyway) -Significant drift issues around GLMs when pulling pump/packoff -Vented packer vent valves have been closed & control lines locked out/tagged by DSO on 11/26/19 -Vented packer at 5094' RKB - AOGCC will require 10-404 after ESP to gas lift convertion testing has been completed. Steps: DSL 1. Call for jumper line to be hooked from IA to available flow line. 2. Pull slipstop at 5401' 3. Pull D&D packoff at 5403' 4. Pull Summit pump at 5411' 5. Set Quadco 4.5" RBP at —5222' (upper collar of first full joint at 5217') 6. Set catcher on RBP at 5222' 7. Pull SOV in station #3 (5200') 8. Set DV in station #3 (5200') 9. Pull DV in station #2 (5023') 10. Pump 135 bbls of 1% CRW SW and 85 bbls diesel down tubing taking returns up IA to available flow line. U-tube to freeze protect. 11. Perform CMIT-TxIA to 2500 psi. Record initial, 15 and 30 min TIO pressures. A. If CMIT-TxIA fails, trouble shoot failure mechanism. B. If CMIT-TxIA passes, proceed to step 12. 12. Set OV in station #2 (5023') 13. Pull DV in station #1 (3344') 14. Set GLV in station #1(3344') 15. Perform MIT-T to 2500 psi. Record initial, 15 and 30 min TIO pressures. A. If MIT-Tfails, trouble shoot failure mechanism. B. If MI I-T passes, proceed to step 16. 16. Perform IA DDT to confirm vented packer vent valves holding. Record initial, 15 and 30 min pressures. A. If IA DDT fails, trouble shoot failure mechanism. A. If IA DDT passes, proceed to step 17. 17. Pull catcher at from top of RBP at 5222' RKB 18. Pull RBP from 5222' 19. Turn well over to operations. Confirm testing results with WICS prior to bringing the well on production. Run the following gas lift design based on HagedomBrown hydraulic correlation, 1033 BLPD, 50% Water Cut, 1500 Mscfd lift gas, 300 FGOR, kickoff pressure of 1300.0 psi, and Camco_BK valves. Surf. Surf. TRO MD Valve Valve Port Open Close Press GLM (RKB) Size Name Size Press Press 60" F 1 3340 1" Camco_BK 3/16" 1300 1267 1475 2 5027 1" Camco_BKO-3 5/16" ------ Orifice ------ r77) 70t,—/22 Loepp, Victoria T (DOA) From: Autry, Sydney <Sydney.Autry@conocophillips.com> Sent: Thursday, January 10, 2019 9:04 AM To: Loepp, Victoria T (DOA) Cc: Subject: Thank you Victoria! Thanks, Simek, Jill RE: [EXTERNAL]KRU Requirements 1J-115(PTD 206-122, Sundry 318-374) Vented Packer Testing Sydney Autry Senior Petroleum Engineer (Viscous) - West Sak 1E/1J ConocoPhillips Alaska, Inc. Sydney.Autry@conocophillips.com W:907-265-6813 C:907-342-7606 From: Loepp, Victoria T (DOA) <victoria.loepp@alaska.gov> Sent: Thursday, January 10, 2019 8:44 AM To: Autry, Sydney <Sydney.Autry@conocophillips.com> Cc: Simek, Jill <Jill.Simek@conocophillips.com> Subject: [EXTERNAL]KRU 1J-115(PTD 206-122, Sundry 318-374) Vented Packer Testing Requirements Sydney and Jill, Summarized below are Packer Vent Valves — SVS Testing Requirements Inner Annulus (IA) SSV is part of the well SVS; test in conjunction with the well's other SVS components. Test consists of: o Verify both tubing and IA SSV's stroke closed (function test) o Verify both SSV's hold pressure differential (performance test) o Verify the vented packer panels dump pressure (function test) Document IA SSV performance test on separate SVS Test Report; 0 1 report shows test results for normal components; 2nd report shows results for IA SSV o Document the packer vent panel dumps in remarks of IA SSV test report - IA SSV and vented packer panel tests count towards pad statistics We are not requiring a drawdown test of the packer vent valves. Let me know if any clarification is needed. These packer vent valve testing requirements have concurrence between the AOGCC and the CPAI KRU Field Superintendent. Victoria Victoria Loepp Senior Petroleum Engineer State of Alaska Oil & Gas Conservation Commission 333 W.7th Ave Anchorage, AK 99501 Work: (907)793-1247 Victoria.LoeppCa2alaska.cov requirements for vented packer completions may be modified based on these discussions. For KRU 1J-155, please continue with the testing requirements that we have discussed. Please stand by. Thanx, Victoria Victoria Loepp Senior Petroleum Engineer State of Alaska Oil & Gas Conservation Commission 333 W. 7th Ave Anchorage, AK 99501 Work: (907)793-1247 Victoria. Loepprdalaska.aov CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Victoria Loepp at (907)793-1247 or Victo6o.Loepp@oIosko.gov From: Loepp, Victoria T (DOA) Sent: Wednesday, November 28, 2018 9:13 AM To:'Simek, Jill' <Jill.Simek@conocophillips.com> Cc: Autry, Sydney <Sydney.Autry@conocophillips.com> Subject: KRU 1J-155(PTD 206-122, Sundry 318-374) Vented Packer Testing Requirements Jill, Autry, Approval is granted for the Vented Packer Testing Requirements as listed below and modified based on our Nov 14, 2018 meeting. These testing requirements must be included with the approved sundry for vented packer ESP producer 1J-155(PTD 206-122, Sundry 318-374). Thanx, Victoria Victoria Loepp Senior Petroleum Engineer State of Alaska Oil & Gas Conservation Commission 333 W. 7th Ave Anchorage, AK 99501 Work: (907)793-1247 Victoria. Loerm0alaska.aov CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Victoria Loepp at (907)793-1247 or Victoria.Loeoo@alaska.aov From: Simek, Jill <Jill.Simek@conocophillips.com> Sent: Monday, November 26, 2018 3:31 PM To: Loepp, Victoria T (DOA) <victoria.loepp@alaska.gov> Thanx, Victoria Victoria Loepp Senior Petroleum Engineer State of Alaska Oil & Gas Conservation Commission 333 W. 7th Ave Anchorage, AK 99501 Work: (907)793-1247 Victoria. LoeooClalaska.00v CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Victoria Loepp at (907)793-1247 or victoria LoeoD@alaska.aov From: Autry, Sydney <Svdnev.Autry@conocophillips.com> Sent: Thursday, November 1, 2018 1:20 PM To: Loepp, Victoria T (DOA) <victoria.loepp@alaska.aov> Cc: Simek, Jill <Jill.Simek@conocophillips.com> Subject: RE: [EXTERNAL]RE: Vented Packer Testing Requirements Meeting Victoria, Yes, Nov 14th at loam will work for us. Thank you, Sydney From: Loepp, Victoria T (DOA) <victoria.loepp@alaska.aov> Sent: Thursday, November 1, 2018 12:02 PM To: Autry, Sydney <Svdney.Autry@conocophillips.com> Subject: Re: [EXTERNAL]RE: Vented Packer Testing Requirements Meeting We are available 11/14/18 in the morning; will 10 AM work? Sent from my iPhone On Nov 1, 2018, at 11:20 AM, Loepp, Victoria T (DOA) <victoria.loepp@alaska.aov> wrote: Our slope inspector is available in town for the meeting on 11/13. 1 will check to see if he has other availability. From: Autry, Sydney <Sydney.Autry@conocophillips.com> Sent: Thursday, November 1, 2018 11:15 AM To: Loepp, Victoria T (DOA) <victoria.loepp@alaska.gov> Cc: Simek, Jill <1ill.Simek@conocophillips.com> Subject: RE: [EXTERNAL]RE: Vented Packer Testing Requirements Meeting Victoria, The 13th is a bit busy for us. Is there a time on the 14t' or 15th that would work for you? Our last meeting on this subject was —October, 2017. We would like a refresher on the vented packer valve operation and discussion of the testing requirements and timing. Could you please come into our office on Thursday, 11/1/18 at 10 am or 2 pm to meet with our inspector? Please provide a more detailed schematic of the vented packer valve. Thanx, Victoria Victoria Loepp Senior Petroleum Engineer State of Alaska Oil & Gas Conservation Commission 333 W. 71h Ave Anchorage, AK 99501 Work: (907)793-1247 Victona.Loeoo(a.alaska.aov CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Victoria Loepp of (907)793-1247 or V ictoria.Loeoo@alaska.aov From: Autry, Sydney<Svdnev.Autrv@conocophillips.com> Sent: Tuesday, October 16, 2018 4:21 PM To: Loepp, Victoria T (DOA) <victoria.loepp@alaska.eov> Cc: Simek, Jill <Jill.Simek@conocoohillips.com> Subject: RE: Vented Packer Testing Requirements Victoria, Just checking in on the formal vented packer testing approval. Please let me know if the testing requirements below are still sufficient for formal approval of vented packer operation with offset VRWAG. Once approval is received, ConocoPhillips will progress the annual Draw Down Test (DDT) at 1J-115 and commence VRWAG at 1J-127 upon completion of the passing DDT. Thank you, Sydney Autry Senior Petroleum Engineer (Viscous) - West Sak 1E/1J ConocoPhillips Alaska, Inc. Sydney.Autry@conocophillips.com W:907-265-6813 C:907-342-7606 From: Autry, Sydney Sent: Wednesday, October 3, 2018 3:31 PM To: 'victoria.loepp@alaska.sov' <victoria.loepo@alaska.l=_ov> Cc: Simek, Jill<Jill.Simek@conocoohillips.com>; Senden, R. Tyler 7 Thank you, Sydney Autry Senior Petroleum Engineer (Viscous) - West Sak 1E/1J ConocoPhillips Alaska, Inc. Sydney.Autry@conocophillips.com W:907-265-6813 C:907-342-7606 <Viking Vented Packer Summary for AOGCC.pptx> PTO 206 -l2z Loepp, Victoria T (DOA) From: Autry, Sydney<Sydney.Autry@conocophillips.com> Sent: Thursday, January 10, 2019 9:04 AM To: Loepp, Victoria T (DOA) Cc: Simek, Jill Subject: RE: [EXTERNAL]KRU 1J-115(PTD 206-122, Sundry 318-374) Vented Packer Testing Requirements Thank you Victoria! Thanks, Sydney Autry Senior Petroleum Engineer (Viscous) - West Sak IE/1J ConocoPhillips Alaska, Inc. Sydney.Autry@conocophillips.com W:907-265-6813 C:907-342-7606 From: Loepp, Victoria T (DOA) <victoria.loepp@alaska.gov> Sent: Thursday, January 10, 2019 8:44 AM To: Autry, Sydney<Sydney.Autry@conocophill ips.com> Cc: Simek, Jill <Jill.Simek@conocophillips.com> Subject: [EXTERNAL]KRU 1J-115(PTD 206-122, Sundry 318-374) Vented Packer Testing Requirements Sydney and Jill, Summarized below are Packer Vent Valves - SVS Testing Requirements - Inner Annulus (IA) SSV is part of the well SVS; test in conjunction with the well's other SVS components. Test consists of: o Verify both tubing and IA SSV's stroke closed (function test) o Verify both SSV's hold pressure differential (performance test) o Verify the vented packer panels dump pressure (function test) - Document IA SSV performance test on separate SVS Test Report; 0 1 report shows test results for normal components; 2nd report shows results for IA SSV o Document the packer vent panel dumps in remarks of IA SSV test report - IA SSV and vented packer panel tests count towards pad statistics We are not requiring a drawdown test of the packer vent valves. Let me know if any clarification is needed. These packer vent valve testing requirements have concurrence between the AOGCC and the CPAI KRU Field Superintendent. Victoria Victoria Loepp Senior Petroleum Engineer State of Alaska Oil 8 Gas Conservation Commission 333 W. 7th Ave Anchorage, AK 99501 Work: (907)793-1247 V ictoria. LoeppdMalaska. aov CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged Information. The unauthorized review, use or disclosure of such information may violate state or federal law. It you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Victoria Loepp at (907)793-1247 or Victoria.Loeipp@alaska.gov From: Loepp, Victoria T (DOA) Sent: Thursday, January 10, 2019 7:50 AM To: 'Autry, Sydney' <Sydney.Autry@conocophillips.com> Cc:'jill.simek@conocophillips.com' <lill.simek@conocophillips.com> Subject: RE: [EXTERNAL]FW: KRU 1J-115(PTD 206-122, Sundry 318-374) Vented Packer Testing Requirements Yes, I have the new testing requirements and will forward them later today. From: Autry, Sydney <Sydney.Autry@conocophillips.com> Sent: Thursday, January 10, 2019 6:13 AM To: Loepp, Victoria T (DOA) <victoria.loepp@alaska,Rov>; Simek, Jill <AII.Simek@conocophillips.com> Subject: RE: [EXTERNAL)FW: KRU iJ-115(PTD 206-122, Sundry 318-374) Vented Packer Testing Requirements Victoria, Do we have any more clarity on whether the SSV on the annuli will change our testing requirements? I believe 1J pad testing will be coming up later this month & I intend to have the DDT completed for the 1J-115 vented packer (testing frequency should not impact this, just subsequent tests). Thanks, Sydney Autry Senior Petroleum Engineer (Viscous) - West Sak lE/1J ConocoPhillips Alaska, Inc. Sydney.Autry@conocophillips.com W:907-265-6813 C:907-342-7606 From: Loepp, Victoria T (DOA) <victoria.loepp@alaska.gov> Sent: Wednesday, November 28, 2018 11:31 AM To: Simek, Jill<Jill.Simek@conocophillips.com>; Autry, Sydney<Svdnev.Autry@conocophillips.com> Subject: [EXTERNAL]FW: KRU 1J-115(PTD 206-122, Sundry 318-374) Vented Packer Testing Requirements 1J-115 From: Loepp, Victoria T (DOA) Sent: Wednesday, November 28, 201810:19 AM To: 'Simek, Jill' <Jill.Simek@conocophillips.com> Cc:'Autry, Sydney'<Svdney.Autrv@conocophillips.com> Subject: RE: KRU 1J-155(PTD 206-122, Sundry 318-374) Vented Packer Testing Requirements Jill, Sydney, Jim Regg, our Inspections Supervisor has been meeting with CPAI Operations management concerning performance testing of the SSV systems. It has been noted that a SSV on the annuli is present on some wells. The testing requirements for vented packer completions may be modified based on these discussions. For KRU 1J-155, please continue with the testing requirements that we have discussed. Please stand by. Thanx, Victoria Victoria Loepp Senior Petroleum Engineer State of Alaska Oil & Gas Conservation Commission 333 W. 7th Ave Anchorage, AK 99501 Work: (907)793-1247 Victoria. Loe000alaska.00v CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC(, State of Alaska and is for the sole use of the intended recipient(s(, It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Victoria Loepp at (907(793-1247 or victoria Loeop@alaska aov From: Loepp, Victoria T (DOA) Sent: Wednesday, November 28, 2018 9:13 AM To:'Simek, Jill' <Jill.Simek@conocophillips.com> Cc: Autry, Sydney <SVdneV.Autry@conocophillips.com> Subject: KRU 1J-155(PTD 206-122, Sundry 318-374) Vented Packer Testing Requirements Jill, Autry, Approval is granted for the Vented Packer Testing Requirements as listed below and modified based on our Nov 14, 2018 meeting. These testing requirements must be included with the approved sundry for vented packer ESP producer 1J-155(PTD 206-122, Sundry 318-374). Thanx, Victoria Victoria Loepp Senior Petroleum Engineer State of Alaska Oil & Gas Conservation Commission 333 W. 7th Ave Anchorage, AK 99501 Work: (907)793-1247 Victoria. LoepoPalaska aov CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC(, State of Alaska and is for the sole use of the intended recipient(s(. It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Victoria Loepp at (9071793-1247 or victoria Loeoo@alaska aov From: Simek, Jill <JiII.Simek@conocophillips.com> Sent: Monday, November 26, 2018 3:31 PM To: Loepp, Victoria T (DOA) <victoria.loepp@alaska.eov> Cc: Autry, Sydney <Sydney.Autry@conocophillips.com> Subject: RE: [EXTERNAL]Vented Packer Testing Requirements - Revised Victoria, Per November 14 meeting, the revised testing is as follows. Let me know if this matches AOGCC notes from the meeting. Thanks! Jill 1J-115 VENT VALVE PACKER TESTING 1. Performance Testing - Semi -Annually • Test in conjunction with State Witnessed Safety Valve System testing, at matching test frequency i. Per 20 AAC 25.265(h)(5), the safety valve test is done "semi- annually, not to exceed 210 days between tests, unless the commission prescribes a different testing interval based on test performance results". • Tests low pressure pilot to ensure proper operation when flow line low pressure threshold is exceeded i. Isolate low pressure pilot from downhole vent valve ii. Trip the low pressure pilot and record the trip pressure as required in 20 AAC 25.265 and per existing Safety Valve System test procedures • State Witnessed with 24 hours' notice required 2. Draw Down Testing - Semi -Annually • Test in conjunction with State Witnessed Safety Valve System testing, at matching test frequency L Per 20 AAC 25.265(h)(5), the safety valve test is done "semi- annually, not to exceed 210 days between tests, unless the commission prescribes a different testing interval based on test performance results". • Draw Down Test with vent valve in closed position to ensure valve and packer will hold pressure i. Close vent valve ii. Bleed IA iii. Monitor for build up • State Witnessed with 24 hours' notice required From: Loepp, Victoria T (DOA) <victoria.loepp@alaska.zov> Sent: Monday, November 26, 2018 11:27 AM To: Simek, Jill <Jill.Simek@conocophillips.com> Cc: Autry, Sydney<SydneV.Autry@conocophillips.com> Subject: [EXTERNAL)Vented Packer Testing Requirements - Revised Could you please provide the revised vented packer testing requirements based on our meeting on November 14, 2018? 4 Thanx, Victoria Victoria Loepp Senior Petroleum Engineer State of Alaska Oil & Gas Conservation Commission 333 W. 7th Ave Anchorage, AK 99501 Work: (907)793-1247 Victoria. Loepp(&alaska.nov CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCCI, State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Victoria Loepp at (907)793-1247 or VIC1orIa.Loeop@alaska aov From: Autry, Sydney<Svdney.Autry@conocophillips.com> Sent: Thursday, November 1, 2018 1:20 PM To: Loepp, Victoria T (DOA) <victoria.loepp@alaska.gov> Cc: Simek, Jill <1ill.Simek@conocophillips.com> Subject: RE: [EXTERNAL]RE: Vented Packer Testing Requirements Meeting Victoria, Yes, Nov 141" at loam will work for us. Thank you, Sydney From: Loepp, Victoria T (DOA) <victoria.loepp@alaska.eov> Sent: Thursday, November 1, 2018 12:02 PM To: Autry, Sydney <Sydney.Autry@conocophillips.com> Subject: Re: [EXTERNAL]RE: Vented Packer Testing Requirements Meeting We are available 11/14/18 in the morning; will 10 AM work? Sent from myiPhone On Nov 1, 2018, at 11:20 AM, Loepp, Victoria T (DOA) <victoria.loepp@alaska.Qov> wrote: Our slope inspector is available in town for the meeting on 11/13. 1 will check to see if he has other availability. From: Autry, Sydney <Sydney.Autrv@conocophillips.com> Sent: Thursday, November 1, 2018 11:15 AM To: Loepp, Victoria T (DOA) <victoria.loepp@alaska.aov> Cc: Simek, Jill <1ill.Simek@conocophillips.com> Subject: RE: [EXTERNAL)RE: Vented Packer Testing Requirements Meeting Victoria, The 131" is a bit busy for us. Is there a time on the 14th or 15t" that would work for you? Thank you, Sydney Autry Senior Petroleum Engineer (Viscous) - West Sak lE/1J ConocoPhillips Alaska, Inc. Sydney.Autry@conocophillips.com W:907-265-6813 C:907-342-7606 From: Loepp, Victoria T (DOA) <victoria.loepp@alaska.gov> Sent: Thursday, November 1, 2018 9:49 AM To: Autry, Sydney <Svdnev.Autrv@conocophillips.com> Cc: Simek, Jill <Jill.Simek@conocophillips.com> Subject: RE: [EXTERNAL]RE: Vented Packer Testing Requirements Meeting Could we schedule this meeting for 11/13/18? 10 AM? From: Loepp, Victoria T (DOA) Sent: Monday, October 29, 2018 4:48 PM To: Autry, Sydney<Svdnev.Autrv@conocophillips.com> Cc: Simek, Jill <Jill.Simek@conocophillips.com> Subject: Re: [EXTERNAL]RE: Vented Packer Testing Requirements Meeting Yes, 10 AM, 11/8/18. Sent from my Whone On Oct 29, 2018, at 4:37 PM, Autry, Sydney <Sydney.Autry@conocophillips.com> wrote: Victoria, Jill will be COTO this Thursday. Does next Thursday morning work for you? Attached is material we shared last fall. Thanks, Sydney Autry Senior Petroleum Engineer (Viscous) - West Sak 1E/1J ConocoPhillips Alaska, Inc. Sydney.Autry@conocophillips.com W:907-265-6813 C:907-342-7606 From: Loepp, Victoria T (DOA) <victoria.loepp@alaska.eov> Sent: Monday, October 29, 2018 3:11 PM To: Autry, Sydney<Svdney.Autrv@conocophillips.com> Cc: Simek, Jill <Jill.Simek@conocophillips.com> Subject: [EXTERNAL]RE: Vented Packer Testing Requirements Meeting Sydney, Jill, Our last meeting on this subject was -October, 2017. We would like a refresher on the vented packer valve operation and discussion of the testing requirements and timing. Could you please come into our office on Thursday, 11/1/18 at 10 am or 2 pm to meet with our inspector? Please provide a more detailed schematic of the vented packer valve. Thank, Victoria Victoria Loepp Senior Petroleum Engineer State of Alaska Oil 8 Gas Conservation Commission 333 W. 7th Ave Anchorage, AK 99501 Work: (907)793-1247 Victoria. LoeppPalaska.00v CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Victoria Loepp at (907)793-1247 or Victoria Loeoo@alaska.aov From: Autry, Sydney <Sydney.Autry@conocoohillips.com> Sent: Tuesday, October 16, 2018 4:21 PM To: Loepp, Victoria T (DOA) <victoria.loepp@alaska.¢ov> Cc: Simek, Jill <Jill.Simek@conocophillips.com> Subject: RE: Vented Packer Testing Requirements Victoria, Just checking in on the formal vented packer testing approval. Please let me know if the testing requirements below are still sufficient for formal approval of vented packer operation with offset VRWAG. Once approval is received, ConocoPhillips will progress the annual Draw Down Test (DDT) at 1J-115 and commence VRWAG at 1J-127 upon completion of the passing DDT. Thank you, Sydney Autry Senior Petroleum Engineer (Viscous) - West Sak lE/1J ConocoPhillips Alaska, Inc. Sydney.Autry@conocophillips.com W:907-265-6813 C:907-342-7606 From: Autry, Sydney Sent: Wednesday, October 3, 2018 3:31 PM To:'victoria.loepp@alaska.aov' <victoria.loepp@alaska.gov> Cc: Simek, Jill<Jill.Simek@conocophillips.com>; Senden, R. Tyler 7 <R.Tvler Senden@conocophillips.com>; Braun, Michael (Alaska) <Michael Braun conocophillips.com>; NSK Well Integrity Supv CPF1 and 2 <n1617@conocophillips.com>; NSK Fieldwide Operations Supt <n2072 @conoco phi l I i Ps.com> Subject: Vented Packer Testing Requirements Victoria, Per the recently approved sundry (318-374) to convert 1J- 127 (PTD 206-047) from WINJ to WAG, ConocoPhillips plans to start treating the offset vented packer ESP producer 1J-115 (PTD 206-122) as a packered ESP producer. The vented packer testing previously discussed and noted in sundry #318-374 is noted below: 1. Function Testing - Semi -Annually • Test in conjunction with State Witnessed Safety Valve System testing, at matching test frequency I. Per 20 AAC 25.265(h)(5), the safety valve test is done "semi-annually, not to exceed 210 days between tests, unless the commission prescribes a different testing interval based on test performance results". • Tests low pressure pilot to ensure proper operation when flow line low pressure threshold is exceeded I. Isolate low pressure pilot from downhole vent valve ii. Trip the low pressure pilot and record the trip pressure as required in 20 AAC 25.265 and per existing Safety Valve System test procedures • State Witnessed with 24 hours' notice required 2. Draw Down Testing - Annually • Draw Down Test with vent valve in closed position to ensure valve and packer will hold pressure i. Close vent valve ii. Bleed IA iii. Monitor 30 minutes for build up iv. Passing test will have a stabilizing pressure trend and a final pressure at or below 50psi. • Test independently of State Witnessed Safety Valve system testing 3. Mechanical Integrity Test - 4 years • Per AOGCC Guidance Bulletin 10-02B ConocoPhillips is requesting formal approval of the above stated vented packer testing requirements in order to commence VRWAG (viscosity reducing water alternating gas) operations at injector 1J-127 per approved Sundry #318-374. 8 Thank you, Sydney Autry Senior Petroleum Engineer (Viscous) - West Sak 1E/1J ConocoPhillips Alaska, Inc. Sydney.Autry@conocophillips.com W:907-265-6813 c:907-342-7606 <Viking Vented Packer Summary for AOGCC.pptx> � • zo6i22 WELL LOG TRANSMITTAL #904526147 To: Alaska Oil and Gas Conservation Comm. Attn.: Natural Resource Technician 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 SCANNED SF'' 2 8 211 i8 RE: Plug Set Record: 1J-115 Run Date: 12/22/2017 29696 September 19, 2018 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of. Fanny Sari, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 FRS—ANC@halliburton.com 1J-115 Digital Data in LAS format, Digital Log Image file � /EID 1 CD Rom 50-029-23320-00 gece1tl sg2120% P,OGCC PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Fanny Sari 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-275-2605 FRS—ANC@halliburton.com Date: Z Signed: STATE OF ALASKA ALA OIL AND GAS CONSERVATION COMMINION REPORT OF SUNDRY WELL OPERATIONS OCI 10 3 Z017 1. Operations Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Pull Tubing ❑ jeygprs�Shertdown ❑ Performed: Suspend El Perforate El Other Stimulate ❑ Alter Casing ❑ C ( gram ❑ Plug for Redrill ❑ 'erforate New Pool ❑ Repair Well 0 Re-enter Susp Well ❑ Other: n Yek7 tCd Pxr E, 2. Operator Name: ConocoPhillips Alaska, Inc. 4. Well Class Before Work: 5. Permit to Drill Number: rv►'► Development p Exploratory ❑ Stratigraphic❑ Service ❑ 206-122 3. Address: P. O. Box 100360, Anchorage, Alaska 6. API Number: 99510 50-029-23320-00 7. Property Designation (Lease Number): 8. Well Name and Number: KRU 1 J-115 ADL 25661, ADL 25650 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pool(s): N/A Kuparuk River Field / West Sak Oil Pool 11. Present Well Condition Summary: Total Depth measured 13,720 feet Plugs measured None feet true vertical 3,911 feet Junk measured None feet Effective Depth measured 13,708 feet Packer measured 5094, 6198, 6652 feet true vertical 3,908 feet true vertical 3180, 3574, 3670 feet Casing Length Size MD TVD Burst Collapse CONDUCTOR 78 feet 20 108' MD 108 TVD SURFACE 2,983 feet 10 3/4 " 3,009' MD 2215 TVD INTERMEDIATE 7,467 feet 7 5/8 " 7,493' MD 3808 TVD A -SAND LINER 7,056 feet 4 1/2 " 13,708' MD 3910 TVD Tubing (size, grade, measured and true vertical depth) 4.5 " L-80 5,494' MD 3,353' TVD Packers and SSSV (type, measured and true vertical depth) PACKER = VIKING VENTED PACKER 5, 094' MD 3,180' TVD PACKER = UP LINER TOP PACKER 6,198' MD 3, 574' TVD PACKER = BAKER HRD ZXP LINER TOP PACKER 6,652' MD 3,670' TVD SSSV = NONE 12. Stimulation or cement squeeze summary: Intervals treated (measured): N/A SCANNED NOV'0201 Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: Shut -In 0 0 0 0 Subsequent to operation: 1385 133 1133 150 179 14. Attachments (required per 20 AAC 25.070, 25.071, a 25.283) 15. Well Class after work: Daily Report of Well Operations Exploratory ❑ Development l] Service ❑ Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16. Well Status after work: Oil 0 Gas ❑ WDSPL ❑ Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP❑ SPLUG❑ 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: N/A Contact Name: Ron Phillips Authorized Name: Ron L. Phillips Contact Email: Ron.L.Phillips@cop.com Authorized Title: Sr. Wells Engineer ? Contact Phone: (907) 265-6312 �f A7 Authorized Signature: Date: ! Form 10-404 Revised 4/2017 t-n 10l G `L- — `10///R13pMS I,\, OCT - 3 2017 Submit Original Only Operations Summary (with Timelog Depths) 1J-115 Rig: DOYON 14 Job: RECOMPLETION Time Log Start Depth Start Time End Time Dur (hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth (ftKB)', 8/24/2017 8/24/2017 2.00 MIRU MOVE RURD P RD the rig floor. Drain and clean the 0.0 0.0 21:00 23:00 mud pumps. Clean the conveyor, remove the chute and install the cover plate. 8/24/2017 8/25/2017 1.00 MIRU MOVE RURD P Skid the conveyor to rig move 0.0 0.0 23:00 00:00 position. 8/25/2017 8/25/2017 1.00 MIRU MOVE RURD P Continue to skid the conveyor to rig 0.0 0.0 00:00 01:00 move position. 8/25/2017 8/25/2017 1.00 MIRU MOVE RURD P PJSM. Skid the rig floor into moving 0.0 0.0 01:00 02:00 position. 8/25/2017 8/25/2017 1.75 MIRU MOVE MOB P PJSM. Jack up the rig, move the rig 0.0 0.0 02:00 03:45 off well 2Z-13A and stage on the pad in position for installing the rear booster. 8/25/2017 8/25/2017 1.75 MIRU MOVE RURD P Pick the BOP stack off the stump, 0.0 0.0 03:45 05:30 install DSA, place in the cradle and. secure for transport. 8/25/2017 8/25/2017 1.75 MIRU MOVE RURD P Install the rear booster and function 0.0 0.0 05:30 07:15 test. 8/25/2017 8/25/2017 1.25 MIRU MOVE MOB P Move the rig on mats around the end 0.0 0.0 07:15 08:30 of the reserve pit toward 2Z-pad entrance. 8/25/2017 8/25/2017 2.00 MIRU MOVE WAIT T Rig fell through the pad with the ODS 0.0 0.0 08:30 10:30 rear wheel after getting off rig mats. Crib up underneath wheels, insert mats under rig and pull the rig on mats. 8/25/2017 8/25/2017 1.00 MIRU MOVE MOB P Move the rig across 2G pad without 0.0 0.0 10:30 11:30 mats then on mats over pipelines to spine road. 8/25/2017 8/25/2017 3.00 MIRU MOVE MOB P Move the rig 1.2 miles on the spine 0.0 0.0 11:30 14:30 road to Oliktok Y. 8/25/2017 8/25/2017 0.25 MIRU MOVE WAIT P Wait to allow traffic to bypass around 0.0 0.0 14:30 14:45 the rig. SimOps: Inspect the moving system. 8/25/2017 8/25/2017 2.75 MIRU MOVE MOB P Move the rig 1.9 miles from the Oliktok 0.0 0.0 14:45 17:30 Y to 1A access. 8/25/2017 8/25/2017 1.75 MIRU MOVE WAIT P Wait at 1A access for field change out 0.0 0.0 17:30 19:15 8/25/2017 8/26/2017 4.75 MIRU MOVE MOB P Move the rig 2.1 miles from 1A Access 0.0 0.0 19:15 00:00 to 0.5 miles past 3 way stop towards 1 J pad. 8/26/2017 8/26/2017 1.00 MIRU MOVE MOB P Move the rig an addition 0.5 miles for 0.0 0.0 00:00 01:00 a total of 1 mile from the 3 way stop and the ODS rear tires sank into the road. 8/26/2017 8/26/2017 2.75 MIRU MOVE WAIT T Lay mats behind the rig. Place 0.0 0.0 01:00 03:45 dunnage under the ODS rear tires. Move the rig back onto mats and fill the hole with dirt. Lay out mats in front of the rig over soft area of the road. 8/26/2017 8/26/2017 3.25 MIRU MOVE MOB P Move the rig 1.5 miles to 1J access 0.0 0.0 03:45 07:00 road. 8/26/2017 8/26/2017 1.00 MIRU MOVE MOB P Move the rig 0.1 miles down 1J 0.0 0.0 07:00 08:00 access road on mats. Move the rig off rig mats onto portable road and started to sink into the road. Move the rig back up onto mats. Page 1/14 Report Printed: 9/25/2017 Operations Summary (with Timelog Depths) fY y f "td s 1J-115 Rig: DOYON 14 Job: RECOMPLETION Time Log Start Depth Start Time ' '. End Time Dur (hr) :', Phase Op Code Activity Code Time P-T-X Operation (W)'. End Depth (ftKS)', 8/26/2017 8/26/2017 2.00 MIRU MOVE WAIT T PU the portable road, fill the hole with 0.0 0.0 08:00 10:00 dirt and lay out mats. 8/26/2017 8/26/2017 0.50 MIRU MOVE MOB P Move the rig 0.2 miles down 1J 0.0 0.0 10:00 10:30 access road to 1 D rear entrance. 8/26/2017 8/26/2017 2.50 MIRU MOVE WAIT P Lay out mats on 1J access road. 0.0 0.0 10:30 13:00 SimOps: Extend #2 conveyor and general housekeeping. 8/26/2017 8/26/2017 0.50 MIRU MOVE WAIT T Move the rig into left hand curve 0.0 0.0 13:00 13:30 towards 1 J pad and the front ODS tires sank into the road. Place a mat under the rear of the rig. Place dunnage and plywood under the ODS front tires. 8/26/2017 8/26/2017 1.50 MIRU MOVE MOB T Move the rig back to 1 D rear entrance. 0.0 0.0 13:30 15:00 8/26/2017 8/26/2017 1.00 MIRU MOVE WAIT T Repair the road and lay out mats. 0.0 0.0 15:00 16:00 8/26/2017 8/26/2017 1.50 MIRU MOVE MOB P Move the rig 0.5 miles from 1 D rear 0.0 0.0 16:00 17:30 entrance towards 1J pad. While pulling up onto mats the DS rear tires retracted. Stop and set down the rig on mats. 8/26/2017 8/26/2017 4.00 MIRU MOVE RGRP T Trouble shoot the DS rear moving 0.0 0.0 17:30 21:30 system. Change out pressure relief valve. 8/26/2017 8/26/2017 0.50 MIRU MOVE MOB P Move the rig 0.1 miles and the ODS 0.0 0.0 21:30 22:00 rear tires sunk into the road. 8/26/2017 8/26/2017 0.75 MIRU MOVE WAIT T Place mats behind the rig and place 0.0 0.0 22:00 22:45 plywood under the ODS rear tires. 8/26/2017 8/26/2017 0.75 MIRU MOVE MOB T Move the rig back, lay 0.0 0.0 22:45 23:30 dunnage/plywood into the front of the hole and move the rig back onto mats. 8/26/2017 8/27/2017 0.50 MIRU MOVE WAIT T Pick up the plywood and dunnage. Fill 0.0 0.0 23:30 00:00 the hole with dirt/gravel. 8/27/2017 8/27/2017 7.50 MIRU MOVE WAIT P PU rig mats on the road and lay out in 0.0 0.0 00:00 07:30 front of the rig. Lay out remaining rig mats on 1J pad. SimOps: RU the drag chain. Scrub the rig floor and doghouse. General housekeeping. 8/27/2017 8/27/2017 0.50 MIRU MOVE MOB P Move the rig to the end of the rig mats. 0.0 0.0 07:30 08:00 8/27/2017 8/27/2017 2.00 MIRU MOVE WAIT P Double stack mats behind the rig. 0.0 0.0 08:00 10:00 SimOps: General housekeeping. 8/27/2017 8/27/2017 0.50 MIRU MOVE MOB P Move the rig back on double mats. 0.0 0.0 10:00 10:30 8/27/2017 8/27/2017 2.50 MIRU MOVE WAIT P Lay out double stacked mats. 0.0 0.0 10:30 13:00 SimOps: General housekeeping. 8/27/2017 8/27/2017 0.50 MIRU MOVE MOB P Move the rig to the end of the rig mats. 0.0 0.0 13:00 13:30 8/27/2017 8/27/2017 1.50 MIRU MOVE WAIT P Double stack mats behind the rig. 0.0 0.0 13:30 15:00 SimOps: General housekeeping. 8/27/2017 8/27/2017 0.50 MIRU MOVE MOB P Move the rig back on double mats. 0.0 0.0 15:00 15:30 Page 2/14 Report Printed: 9/25/2017 Operations Summary (with Timelog Depths) U-115 Rig: DOYON 14 Job: RECOMPLETION Time Log Start Depth 'I Start Time End Time Dur (hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth (ftKB)', 8/27/2017 8/27/2017 0.50 MIRU MOVE WAIT P Lay out double stacked mats. 0.0 0.0 15:30 16:00 SimOps: General housekeeping. 8/27/2017 8/27/2017 0.50 MIRU MOVE OTHR P Take on rig fuel and transfer methanol 0.0 0.0 16:00 16:30 from behind the rig to fluid trailer in. front of the rig for 1 J operations. 8/27/2017 8/27/2017 0.50 MIRU MOVE WAIT P Continue to lay out double stacked 0.0 0.0 16:30 17:00 mats. 8/27/2017 8/27/2017 1.00 MIRU MOVE MOB P Move the rig to the end of the rig mats. 0.0 0.0 17:00 18:00 8/27/2017 8/27/2017 1.75 MIRU MOVE WAIT P Double stack mats behind the rig. 0.0 0.0 18:00 19:45 SimOps: General housekeeping. 8/27/2017 8/27/2017 1.00 MIRU MOVE MOB P Move the rig back on double mats. 0.0 0.0 19:45 20:45 8/27/2017 8/27/2017 1.50 MIRU MOVE WAIT P Lay out double stacked mats. 0.0 0.0 20:45 22:15 SimOps: General housekeeping. 8/27/2017 8/27/2017 0.75 MIRU MOVE MOB P Move the rig to the end of the rig mats. 0.0 0.0 22:15 23:00 8/27/2017 8/28/2017 1.00 MIRU MOVE WAIT P Double stack mats behind the rig. 0.0 0.0 23:00 00:00 SimOps: General housekeeping. 8/28/2017 8/28/2017 0.75 MIRU MOVE WAIT P Continue to double stack mats behind 0.0 0.0 00:00 00:45 the rig. SimOps: General housekeeping. 8/28/2017 8/28/2017 1.00 MIRU MOVE MOB P Move the rig back on double mats. 0.0 0.0 00:45 01:45 8/28/2017 8/28/2017 1.50 MIRU MOVE WAIT P Lay out double stacked mats. 0.0 0.0 01:45 03:15 SimOps: General housekeeping. 8/28/2017 8/28/2017 0.75 MIRU MOVE MOB P Move the rig to the end of the rig mats. 0.0 0.0 03:15 04:00 8/28/2017 8/28/2017 1.25 MIRU MOVE WAIT P Double stack mats behind the rig. 0.0 0.0 04:00 05:15 SimOps: General housekeeping. 8/28/2017 8/28/2017 0.75 MIRU MOVE MOB P Move the rig back on double mats. 0.0 0.0 05:15 06:00 8/28/2017 8/28/2017 1.75 MIRU MOVE WAIT P Lay out double stacked mats. 0.0 0.0 06:00 07:45 SimOps: General housekeeping. 8/28/2017 8/28/2017 0.50 MIRU MOVE MOB P Move the rig to the end of the rig mats. 0.0 0.0 07:45 08:15 8/28/2017 8/28/2017 0.75 MIRU MOVE WAIT P Double stack mats behind the rig. 0.0 0.0 08:15 09:00 SimOps: General housekeeping. 8/28/2017 8/28/2017 1.00 MIRU MOVE MOB P Move the rig back on double mats. 0.0 0.0 09:00 10:00 8/28/2017 8/28/2017 0.75 MIRU MOVE WAIT P Lay out double stacked mats. 0.0 0.0 10:00 10:45 SimOps: General housekeeping. 8/28/2017 8/28/2017 0.75 MIRU MOVE MOB P Move the rig to the end of the rig mats. 0.0 0.0 10:45 11:30 8/28/2017 8/28/2017 0.75 MIRU MOVE WAIT P Double stack mats behind the rig. 0.0 0.0 11:30 12:15 SimOps: General housekeeping. Page 3/14 Report Printed: 9/25/2017 Operations Summary (with Timelog Depths) Y� U-115 Rig: DOYON 14 Job: RECOMPLETION Time Log Start Depth (Start Time End Time our (hr) Phase > Op Code :Activity Code:' Time P-T-X Operation (ftKB) End Depth (ftKB) 8/28/2017 8/28/2017 0.75 MIRU MOVE MOB P Move the rig back on double mats. 0.0 0.0 12:15 13:00 8/28/2017 8/28/2017 0.50 MIRU MOVE OTHR P Transfer methanol from the back of 0.0 13:00 13:30 the rig to fluid trailer in the front of the rig for 1J operations. 8/28/2017 8/28/2017 0.75 MIRU MOVE WAIT P Lay out double stacked mats. 0.0 0.0 13:30 14:15 SimOps: General housekeeping. 8/28/2017 8/28/2017 0.75 MIRU MOVE MOB P Move the rig to the end of the rig mats. 0.0 0.0 14:15 15:00 8/28/2017 8/28/2017 1.00 MIRU MOVE WAIT P Double stack mats behind the rig. 0.0 0.0 15:00 16:00 SimOps: General housekeeping. 8/28/2017 8/28/2017 0.50 MIRU MOVE MOB P Move the rig back on double mats. 0.0 0.0 16:00 16:30 8/28/2017 8/28/2017 1.00 MIRU MOVE WAIT P Lay out double stacked mats. 0.0 0.0 16:30 17:30 SimOps: General housekeeping. 8/28/2017 8/28/2017 1.00 MIRU MOVE MOB P Move the rig to the end of the rig mats. 0.0 0.0 17:30 18:30 8/28/2017 8/28/2017 2.00 MIRU MOVE WAIT P Double stack mats behind the rig. 0.0 0.0 18:30 20:30 SimOps: General housekeeping. 8/28/2017 8/28/2017 0.50 MIRU MOVE MOB P Move the rig back on double mats. 0.0 0.0 20:30 21:00 8/28/2017 8/28/2017 1.50 MIRU MOVE WAIT P Lay out double stacked mats. 0.0 0.0 21:00 22:30 SimOps: General housekeeping. 8/28/2017 8/28/2017 1.00 MIRU MOVE MOB P Move the rig to the end of the rig mats. 0.0 0.0 22:30 23:30 8/28/2017 8/29/2017 0.50 MIRU MOVE WAIT P Double stack mats behind the rig. 0.0 0.0 23:30 00:00 SimOps: General housekeeping. 8/29/2017 8/29/2017 0.50 MIRU MOVE MOB P Move the rig back on double mats. 0.0 0.0 00:00 00:30 8/29/2017 8/29/2017 1.00 MIRU MOVE WAIT P Lay out double stacked mats. 0.0 0.0 00:30 01:30 SimOps: General housekeeping. 8/29/2017 8/29/2017 1.00 MIRU MOVE MOB P Move the rig to 1J pad. 0.0 0.0 01:30 02:30 8/29/2017 8/29/2017 0.50 MIRU MOVE MOB P Move the rig down I pad close to 1J- 0.0 0.0 02:30 03:00 115 and position the rig to remove the rear booster. 8/29/2017 8/29/2017 1.00 MIRU MOVE RURD P Remove the rear booster. 0.0 0.0 03:00 04:00 8/29/2017 8/29/2017 1.00 MIRU MOVE RURD P Place cradle with BOP stack into the 0.0 0.0 04:00 05:00 cellar. Install the bell nipple on top of the BOP stack, remove the BOP stack from the cradle, set on the stump and secure. 8/29/2017 8/29/2017 2.00 MIRU MOVE MOB P Spot rig over 1J-115. Level and shim 0.0 0.0 05:00 07:00 rig 8/29/2017 8/29/2017 1.00 MIRU MOVE RURD P Skid rig floor to drilling position. 0.0 0.0 07:00 08:00 8/29/2017 8/29/2017 2.50 MIRU MOVE RURD P Rig up mud lines below rig floor. Rig 0.0 0.0 08:00 10:30 up top drive interconnect. Move shop from 2Z to 1J pad. Secure stairs and handrails. Take on rig water. Spot and berm cuttings tank. Page 4114 Report Printed: 9/25/2017 Operations Summary (with Timelog Depths) ,. U-115 +: • s' x Rig: DOYON 14 Job: RECOMPLETION Time Log , Start Depth Start Time End Time Dur (hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth (ftKB) 8/29/2017 8/29/2017 2.50 MIRU MOVE RURD P Perform house keeping around rig. 0.0 0.0 10:30 13:00 Spot truck shop on 1J pad. Install new cuttings tank conveyor chute. 8/29/2017 8/29/2017 4.50 MIRU WELCTL RURD P Take on 140' fresh water in pits. Rig 0.0 0.0 13:00 17:30 up circ lines in cellar. Rig up koomey hydraulic lines to BOPE. Mobilize X- O's to rig floor. Accept rig at 13:00 hrs 8/29/17. 8/29/2017 8/29/2017 0.50 MIRU WELCTL RURD P Remove tree cap. Rig up Vetco 0.0 0.0 17:30 18:00 Lubricator. 8/29/2017 8/29/2017 0.50 MIRU WELCTL SEQP P PJSM-Test lubricator to 2500 psi. 0.0 0.0 18:00 18:30 8/29/2017 8/29/2017 0.75 MIRU WELCTL MPSP P Pull BPV. Lay down lubricator. Tubing 0.0 0.0 18:30 19:15 pressure=500 psi / IA = 775 psi 8/29/2017 8/29/2017 3.00 MIRU WELCTL RURD P Pressure test circ lines and lines to 0.0 0.0 19:15 22:15 flow back tanks to 2500 psi. Blow down lines. Remove top flange on tree. Rig up LRS. 8/29/2017 8/30/2017 1.75 MIRU WELCTL WAIT T Wait on pump in flange for tree. 0.0 22:15 00:00 8/30/2017 8/30/2017 0.50 MIRU WELCTL RURD P NU 1502 x 4-1/8" 5M Integral and Tie 0.0 0.0 00:00 00:30 into kill tank lines 8/30/2017 8/30/2017 0.50 MIRU WELCTL OTHR P IA=775 psi, Tubing=500 psi. Bleed off 0.0 0.0 00:30 01:00 TBG / IA pressure to kill tank. 8/30/2017 8/30/2017 2.00 MIRU WELCTL CIRC P RU Little Red Services and PT 0.0 0.0 01:00 03:00 treating lines to 2,500 psi. Good. Pump 100 bbls of 150°F of LEPD Diesel down the IA with No returns to Kill tank. Allow diesel to soak while rigging down LRS. 8/30/2017 8/30/2017 3.00 MIRU WELCTL CIRC P Circulate 100 bbls of 140°F 3% KCL 0.0 0.0 03:00 06:00 at 6 bpm at 660 psi with No returns. Close in TBG and Pump down IA with 170 BBLS of 140°F 3% KCL fluid at 8 bpm @ 1,450 psi. Shut down and Monitor well for 30 minutes - well on vac - after 30 minutes TBG and IA had no fluid movement. RD Circulating equipment and blow down lines. 8/30/2017 8/30/2017 0.50 MIRU WHDBOP MPSP P Dry rod in BPV 0.0 0.0 06:00 06:30 8/30/2017 8/30/2017 2.00 MIRU WHDBOP NUND P ND ESP TBG Adadpter- Function 0.0 0.0 06:30 08:30 ULDS and Obtain RKB Measurements. 8/30/2017 8/30/2017 4.50 MIRU WHDBOP NUND P NU 13-5/8" 5M x 2-ft spacer spool.NU 0.0 0.0 08:30 13:00 BOPE w/ 2-7/8 x 5" VBR's in the upper and lower rams. Install Pinching Nipple along with connecting Choke and Kill lines to mud cross. 8/30/2017 8/30/2017 1.00 MIRU WHDBOP RURD P Rig up to test BOPE. Fill stack. 0.0 0.0 13:00 14:00 1 Conduct PJSM on testing BOPE. Page 5114 Report Printed: 9/25/2017 " Operations Summary (with Timelog Depths) f f - } 1J-115 Rig: DOYON 14 Job: RECOMPLETION Time Log '.Start Time End Time Dur.(hr) Phase Op Code Activity Code `S Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB)', 8/30/2017 8/30/2017 7.50 MIRU WHDBOP BOPE P Perform initial BOPE Test. All tests 0.0 0.0 14:00 21:30 250/2500 psi for 5 mins each.24 hr. notice was given at 06:44 hrs. on 8-29 -17 and Witnessed by Matt Herrera on 8-30-17.Test #1 w/4-1 /2" Test joint - 2- 7/8 — 5" VBR's Lower Pipe Rams Test #2 w/4-1/2" Test joint - Annular, CM 12, 13, and Upper IBOP, 3" Demco — Valve#20 Test #3 w/4-1/2" Test joint - 2-7/8 — 5" VBR's Upper Pipe Rams, CM 9, 11, and Lower IBOP, Kill HCR Test #4 w/4-1/2" Test joint - 2-7/8 — 5" VBR's Upper Pipe Rams, CM 5,8,10, HT-38 TIW, Manual Kill Test #5 w/4-1/2" Test joint - 2-7/8 — 5" VBR's Upper Pipe Rams, CM 4,67, HT-38 Dart Test #6 w/4-1/2" Test joint - 2-7/8 — 5" VBR's Upper Pipe Rams, CM 2, 4-1/2" EUE TIW Valve Test #7 w/2 7/8" Test joint- 2-7/8 — 5" VBR's Lower Pipe Rams Test #8 w/2- 7/8" Test joint - Annular Test #9 w/2-7/8" Test joint - 2-7/8 — 5" VBR's Upper Pipe Rams, CM 1,3Test #10 - Choke line HCR Test #11 - Choke line manual valveTest #12- Blind RamsTest #13- Hydraulic choke A, Manual choke B.Tested gas alarms and PVT system Accumulator System:System Pressure: 2925 psi. PSI after Closure: 1600 psi. 200 PSI Attained: 45 Seconds. Full PSI Attained: 218 Seconds.Number of N2 Bottles = 6 @ 2058 psi AVG. 8/30/2017 8/30/2017 0.50 MIRU WHDBOP RURD P Rig down BOPE test equipment. Blow 0.0 0.0 21:30 22:00 down TD, choke line, kill line and choke manifold. 8/30/2017 8/30/2017 1.00 MIRU WHDBOP MPSP P Rig up dry rod. Sting into BPV. 0.0 0.0 22:00 23:00 Monitor well. Pull BPV. Lay down dry rod. Tubing on vacuum. 8/30/2017 8/31/2017 1.00 COMPZN RPCOMP RURD P Mobilize Centrilift tools to rig floor. 0.0 0.0 23:00 00:00 8/31/2017 8/31/2017 1.75 COMPZN RPCOMP ALFT P PJSM-Rig up Centrilift ESP sheave 0.0 0.0 00:00 01:45 and string lead rope through elephant trunk. 8/31/2017 8/31/2017 1.00 COMPZN RPCOMP RURD P Pick up and make up X-C's to landing 0.0 0.0 01:45 02:45 joint. Make up landing joint to hanger. 8/31/2017 8/31/2017 1.25 COMPZN RPCOMP PULL P BOLDS. Pull hanger free w/175K. Pull 0.0 5,479.0 02:45 04:00 hanger to rig floor. PU=107K. Test and remove penetrator. Test ESP cable. Connect ESP cable to lead rope. 8/31/2017 8/31/2017 0.75 COMPZN RPCOMP PULL P Lay down hanger and landing joint. 5,479.0 5,447.0 04:00 04:45 Page 6/14 Report Printed: 9/25/2017 Operations Summary (with Timelog Depths) 1 J-115 Rig: DOYON 14 Job: RECOMPLETION Time Log '.' Start Depth Start Time ': End Time Dur (hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB)'. End'; Depth (ftKB)', 8/31/2017 8/31/2017 5.25 COMPZN RPCOMP PULL P POOH laying down 4 1/2" IBT ESP 5,447.0 2,864.0 04:45 10:00 completion to 2864' MD. Pump 3.5 bbis 3% KCL water into hole every 15 jts. 8/31/2017 8/31/2017 0.50 COMPZN RPCOMP SFTY P PJSM-Clear ice from derrick. 2,864.0 2,864.0 10:00 10:30 8/31/2017 8/31/2017 3.50 COMPZN RPCOMP PULL P POOH laying down 4 1/2" IBT ESP 2,864.0 62.0 10:30 14:00 completion from 2864' MD to 62' MD. Pump 3.5 bbls 3% KCL water into hole every 15 jts. 8/31/2017 8/31/2017 2.50 COMPZN RPCOMP ALFT P Inspect and lay down ESP pump, seal 62.0 0.0 14:00 16:30 and motor assy. Observed short in motor splice. Recover 96 Cannon clamps, 2 flat guards, 3 protectalizers and 3 SS bands. 8/31/2017 8/31/2017 1.50 COMPZN RPCOMP ALFT P Rig down ESP cable and elephant 0.0 0.0 16:30 18:00 trunk. Clear rig floor of ESP equipment. Pump 10 bbls of 3% KCL water into hole every hour. 8/31/2017 8/31/2017 1.00 COMPZN RPCOMP RURD P Clean and clear rig floor. Pump 10 0.0 0.0 18:00 19:00 bbls of 3% KCL water into hole every hour. 8/31/2017 8/31/2017 0.50 COMPZN WELLPR BHAH P Mobilize clean out BHA #1 to rig floor. 0.0 0.0 19:00 19:30 Pump 5 bbls of 3% KCL water into hole every half hour. 8/31/2017 8/31/2017 1.00 COMPZN WELLPR BHAH P PJSM- Make up clean out BHA#1 and 0.0 0.0 19:30 20:30 lay down to pipe shed. Pump 5 bbls of 3% KCL water into hole every half hour. 8/31/2017 8/31/2017 0.50 COMPZN WELLPR SVRG P Service and inspect top drive. 0.0 0.0 20:30 21:00 8/31/2017 8/31/2017 2.50 COMPZN WELLPR PULD P Make up 2 7/8" Hyd 511 mule shoe. 0.0 1,213.0 21:00 23:30 Pick up and RIH w/2 7/8" P110 6.4ppf Hyd 511 tubing from surface to 1213' MD. PU=45K SO=50K Pump 5 bbls of 3% KCL water into hole every half hour. 8/31/2017 9/1/2017 0.50 COMPZN WELLPR RURD P Change out 2 7/8" handling 1,213.0 1,213.0 23:30 00:00 equipment. Lay down bail extensions. 9/1/2017 9/1/2017 0.50 COMPZN WELLPR BHAH P Pick up Baker casing scraper, boot 1,213.0 1,265.0 00:00 00:30 baskets x3 and string magnets x2 to 1265' MD 9/1/2017 9/1/2017 4.75 COMPZN WELLPR PULD P RIH picking up 4" DP from pipe shed 1,265.0 6,065.0 00:30 05:15 from 1265' MD to 6065' MD. 103K Up wt, 80K Dn Fill the hole with 5 bbls of 3% KCL water into hole every half hour. 9/1/2017 9/1/2017 0.50 COMPZN WELLPR PULD P Continue to RIH w/ from 6,065-ft to 6,065.0 6,204.0 05:15 05:45 6,204-ft and Tag up w/ 5K down 9/1/2017 9/1/2017 1.00 COMPZN WELLPR WASH P Attempt to wash down from 6,204-ft at 6,204.0 6,211.0 05:45 06:45 6 bpm at 280 psi, wash down to 6,211 -ft, Hard tag - had 100 bbl loss. PU to 6,191-ft - for fluid management. Page 7/14 Report Printed: 912512017 Operations Summary (with Timelog Depths) 1J-115 Rig: DOYON 14 Job: RECOMPLETION Time Log" Start Depth Start Time End Time our (hr) r Phase Op Code Activity Code. Time P-T-X Operation (ftKB). End Depth (ftKB) 9/1/2017 9/1/2017 3.75 COMPZN WELLPR OTHR P While conducting Fluid management, 6,191.0 6,191.0 06:45 10:30 the rig crew conducted Slip and cut 53 -ft of 1-1/8" drilling line while conducting Simultaneous operations of 4-1/2" 12.6#, L-80 Tenaris XP BTC w/ seal ring R3 Completion tubular's - loading, strapping and drifting w/ 3.833" Drift 9/1/2017 9/1/2017 0.50 COMPZN WELLPR TRIP P While conducting Fluid management, 6,191.0 5,149.0 10:30 11:00 the rig crew conducted Drill pipe management and pulled 11 Stds from 6,191-ft to 5,149-ft 9/1/2017 9/1/2017 1.00 COMPZN WELLPR PULD P PU and RIH w/ Cleanout BHA from 5,149.0 6,188.0 11:00 12:00 5,149-ft to 6,188-ft 9/1/2017 9/1/2017 3.00 COMPZN WELLPR OTHR P While conducting Fluid management, 6,188.0 6,188.0 12:00 15:00 the rig crew conducted Simultaneous operations of 4-1/2" 12.6#, L-80 Tenaris XP BTC w/ seal ring R3 Completion tubular's - loading, strapping and drifting w/ 3.833" Drift. Loading Centrilift ESP completion components. 9/1/2017 9/1/2017 2.00 COMPZN WELLPR TRIP P PJSM-POOH from 6188' MD to 1297' 6,188.0 1,297.0 15:00 17:00 MD. Fill hole with 1 1/2 x displacement. 9/1/2017 9/1/2017 0.50 COMPZN WELLPR BHAH P Lay down cleanout BHA to pipeshed. 1,297.0 1,234.0 17:00 17:30 Minimal metal on magnets and junk baskets were empty. 9/1/2017 9/1/2017 0.50 COMPZN WELLPR RURD P Change out handling equipment to 2 1,234.0 1,234.0 17:30 18:00 7/8". 9/1/2017 9/1/2017 1.00 COMPZN WELLPR PULD P Lay down 41 joints of 2 7/8 HYD 5?1 1,234.0 0.0 18:00 19:00 tubing. 9/1/2017 9/1/2017 0.75 COMPZN WELLPR RURD P Clean and clear rig floor. 0.0 0.0 19:00 19:45 9/1/2017 9/1/2017 2.00 COMPZN WELLPR TRIP P Make up 2 7/8" muleshoe with casing 0.0 5,977.0 19:45 21:45 scraper and magnets. RIH to 5977' MD. Pump 5 bbls of 3% KCL water into hole every half hour. 9/1/2017 9/2/2017 2.25 COMPZN WELLPR PULD P POOH laying down 4" DP from 5977' 5,977.0 3,893.0 21:45 00:00 MD to 3893' MD. Fill hole with 1 1/2 x displacement. 9/2/2017 9/2/2017 3.00 COMPZN WELLPR PULD P POOH laying down 4" DP from 3893' 3,893.0 41.0 00:00 03:00 MD to 41' MD. Fill hole with 1 1/2 x displacement. Lay down total of 189 jts DP. 9/2/2017 9/2/2017 0.75 COMPZN WELLPR BHAH P Clean off magnets and lay down BHA. 41.0 0.0 03:00 03:45 Minimal metal on magnets. 9/2/2017 9/2/2017 2.25 COMPZN WELLPR BHAH P Clean and clear rig floor of equipment 0.0 0.0 03:45 06:00 not needed for completion to allow for space 9/2/2017 9/2/2017 2.75 COMPZN RPCOMP RURD P Rig up 5-1/2 Tongs for running 0.0 0.0 06:00 08:45 completion with torque turn on 4-1/2" 12.6# L-80 Tenaris TXP ESP completion. Bring 2-5000-ft spools of .25" stainless steel control line to rig floor and spot. String ESP cable over sheave to rig floor and tie off. Page 8/14 Report Printed: 9/25/2017 Operations Summary (with Timelog Depths) 1J-115 Rig: DOYON 14 Job: RECOMPLETION Time Log Start Depth Start Time End Time Dur (hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth (ftKB) 9/2/2017 9/2/2017 5.25 COMPZN RPCOMP ALFT P PJSM, PU, MU and RIH w/ 2-3/8 x 0.0 111.0 08:45 14:00 5.85" OD centralizer, WellLift E Motor Gauge Unit, 5.62" OD 175HP / 3180V / 34A Motor and 2- 5.13" Tandem Seal sections - service the same equipment with CL 5 mineral oil and until air was removed from system. MU and RIH w/ TTC coupler and with drilled pump intake holes, 6-ft X-O pup jt., 10-ft TXP pup jt, 1 - jt of 4- 1/2 12.6#, L-80 TXP R3, 6-ft pup X-O pup jt, 4-1/2 Well Lift discharge gauge, 6-ft X-O pup jt. to 111-ft POOH, defeat crown o matic - in order to PU high enough to install tech wire to Well lift E Motor gauge unit. Note: 111-ft is the maximum length for this section due to derrick height constraints. Install .25" Tec wire to Well Lift E Motor Gauge Unit, Install MILE to Top of Motor and clamp with 4-single Channel clamps toTandem seal sections, then install 3 - dual channel clamps, one every coupling to the Well Lift discharge gauge. Make ' splice on Tec wire to the Gauge. Meg ESP Cable - 4.02 Gigs, 85°F Motor temp, 59°F @ Sensor. 9/2/2017 9/2/2017 1.50 COMPZN RPCOMP PUTB P Pick up 4 joints 4 1/2" 12.6# L-80 111.0 346.0 14:00 15:30 TXPM tubing. Calibrate tourqe turn, installing dual channel Grippy clamps each joint. Make up GLM w/DV and one joint tubing. 9/2/2017 9/2/2017 0.75 COMPZN RPCOMP ALFT P Rig up slickline. 346.0 346.0 15:30 16:15 9/2/2017 9/2/2017 1.25 COMPZN RPCOMP ALFT P RIH w/pump on slickline and set. 346.0 346.0 16:15 17:30 Shear and release from pump. RIH w/tubing pack -off assy on slickline. Set and release from pack -off assy. RIH and set pressure test tool on slick line. 9/2/2017 9/2/2017 0.50 COMPZN RPCOMP PRTS P Pressure test pack -off to 1000 psi/15 346.0 346.0 17:30 18:00 min. Charted. 9/2/2017 9/2/2017 0.50 COMPZN RPCOMP ALFT P Pull test tool w/slickline. Set slip stop 346.0 346.0 18:00 18:30 then junk catcher on slick line. Rig down slick line. 9/2/2017 9/2/2017 0.75 COMPZN RPCOMP RURD P Make up one joint tubing with pre- 346.0 388.0 18:30 19:15 installed WRP set mid joint.. Rig up to test WRP. 9/2/2017 9/2/2017 0.50 COMPZN RPCOMP PRTS P Pressure test WRP to 4000 psi/15 388.0 388.0 19:15 19:45 min. Charted. 9/2/2017 9/2/2017 0.25 COMPZN RPCOMP RURD P Rig down test equipment 388.0 388.0 19:45 20:00 Page 9114 Report Printed: 9/25/2017 Operations Summary (with Timelog Depths) 1J-115 Rig: DOYON 14 Job: RECOMPLETION Time Log Start Depth Start Time:-. End Time Dur (hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End. Depth (ttKB) 9/2/2017 9/3/2017 4.00 COMPZN RPCOMP ALFT P Make up Viking Vented Packer. 388.0 415.0 20:00 00:00 Perform through packer ESP cable splice. Sim-ops/Rig up Camco sheaves. Pump 5 bbls 3% KCL water in hole every 30 mins Meg ESP Cable - Phase to ground 3.74 gigaohms, Phase to Phase-4.8 ohms, 73.1 °F Motor temp. 9/3/2017 9/3/2017 0.75 COMPZN RPCOMP ALFT P Meg ESP Cable - Phase to ground 415.0 415.0 00:00 00:45 3.74 gigaohms, Phase to Phase-4.8 ohms. Sim-ops/Install control lines on packer vent valves. 9/3/2017 9/3/2017 4.25 COMPZN RPCOMP PUTB P Pick up and RIH from 415' MD to 415.0 1,889.0 00:45 05:00 1889' MD w/4 1/2" 12.6# 1-80 TXP tubing w/ESP cable and control lines. Install a dual channel Grippy clamp on each joint. Test ESP cable and fill tubing every 1000'. Pump 5 bbls 3% KCL water in hole every 30 mins. 9/3/2017 9/3/2017 1.25 COMPZN RPCOMP PUTB T Generator used to power ESP 1,889.0 1,889.0 05:00 06:15 spooling unit went down. Trouble shoot generator. Change electrical plug on spooler and plug into rig. 9/3/2017 9/3/2017 9.25 COMPZN RPCOMP PUTB P Pick up and RIH from 1889' MD to 1,889.0 5,450.0 06:15 15:30 5450' MD w/4 1/2" 12.6# 1-80 UP tubing w/ESP cable and control lines. Install a dual channel Grippy clamp on each joint. Test ESP cable and fill tubing every 1000'. Pump 5 bbls 3% KCL water in hole every 30 mins. PU=111K SO=80K 9/3/2017 9/3/2017 0.50 COMPZN RPCOMP ALFT P Meg ESP Cable - Phase to ground 5,450.0 5,450.0 15:30 16:00 4.13 gigaohms, Phase to Phase-4.4 ohms. 9/3/2017 9/3/2017 1.50 COMPZN RPCOMP THGR P PJSM-Make up hanger and landing 5,450.0 5,480.0 16:00 17:30 joint 9/3/2017 9/3/2017 1.50 COMPZN RPCOMP ALFT P Make ESP cable hanger splice. 5,480.0 5,480.0 17:30 19:00 Connect ESP cable to penetrator. 9/3/2017 9/3/2017 1.75 COMPZN RPCOMP ALFT T Meg and test ESP cable through 5,480.0 5,480.0 19:00 20:45 penetrator. Ground indicated. Disconnect from penetrator and retest. Ground indicated. Change out megger and Simpson meter. Ground indicated. Consult with workover , engineer. Decision made to POOH to locate ESP cable ground. 9/3/2017 9/3/2017 1.25 COMPZN RPCOMP THGR T Connect ESP cable to penetrator. 5,480.0 5,503.0 20:45 22:00 Install control lines onto hanger. Land hanger. RILDS. Lay down landing joint. 9/3/2017 9/3/2017 0.50 COMPZN RPCOMP SLKL T Rig up Dutch Riser. 5,503.0 5,503.0 22:00 22:30 9/3/2017 9/3/2017 1.00 COMPZN RPCOMP SLKL T Spot slickline unit. Clear rig floor of 5,503.0 5,503.0 22:30 23:30 unnecessary tools. Mobilize slickline tools to rig floor. 9/3/2017 9/4/2017 0.50 COMPZN RPCOMP SLKL T Rig up slickline equipment. 5,503.0 5,503.0 23:30 00:00 9/4/2017 9/4/2017 0.50 COMPZN RPCOMP SLKL IT Make up slickline tools 5,503.0 5,503.0 00:00 00:30 j Page 10/14 Report Printed: 9/25/2017 Operations Summary (with Timelog Depths) 1J-115 Rig: DOYON 14 Job: RECOMPLETION Time Log Start, Depth Start Time', End Time fur (hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth (ftKB)' 9/4/2017 9/4/2017 1.00 COMPZN RPCOMP SLKL T RIH w/kick over tool. Latch up SOV 5,503.0 5,503.0 00:30 01:30 and jar free. POOH w/slickline. 9/4/2017 9/4/2017 0.25 COMPZN RPCOMP SLKL T Rig down slickline. 5,503.0 5,503.0 01:30 01:45 9/4/2017 9/4/2017 0.25 COMPZN RPCOMP SLKL T Rig down Dutch Riser. 5,503.0 5,503.0 01:45 02:00 9/4/2017 9/4/2017 0.50 COMPZN RPCOMP PULL T Make up landing joint. BOLDS. Pull 5,503.0 5,480.0 02:00 02:30 hanger to rig floor. Hanger free at 110K. PU=107K. 9/4/2017 9/4/2017 0.50 COMPZN RPCOMP ALFT T Disconnect ESP power cable and 5,480.0 5,480.0 02:30 03:00 control lines from hanger. 9/4/2017 9/4/2017 0.25 COMPZN RPCOMP PULL T Lay down hanger and landing joint- 5,480.0 5,450.0 03:00 03:15 9/4/2017 9/4/2017 0.25 COMPZN RPCOMP RURD T Change out handling equipment to 4 5,450.0 5,450.0 03:15 03:30 1/2". 9/4/2017 9/4/2017 9.75 COMPZN RPCOMP PULL T POOH and lay down 4 1/2" 12.6# L-80 5,450.0 415.0 03:30 13:15 TXP tubing w/ESP cable and control lines. Remove dual channel Grippy clamps from each connection from 5450' MD to 415' MD. 9/4/2017 9/4/2017 1.50 COMPZN RPCOMP ALFT T Disconnect ESP power cable above 415.0 415.0 13:15 14:45 packer. Test cable below packer. Grounded. Test cable above packer. Good. (30,30,32 gigaohms). Lay down packer. 9/.4/2017 9/4/2017 0.50 COMPZN RPCOMP PUTB T Pick up two joints tubing and RIH to 415.0 495.0 14:45 15:15 495' MD. 9/4/2017 9/4/2017 1.25 COMPZN RPCOMP SLKL T PJSM-Rig up slickline. Pressure up to 495.0 495.0 15:15 16:30 1000 psi above WRP. Pull WRP. Rig down slickline. 9/4/2017 9/4/2017 1.00 COMPZN RPCOMP PULL T Lay down tubing from 495' MD to 297' 495.0 297.0 16:30 17:30 MD. ESP power cable damaged at GLM #1. 9/4/2017 9/4/2017 0.50 COMPZN RPCOMP PULL T Lay down GLM and 4 joints tubing to 297.0 105.0 17:30 18:00 the discharge guage. 9/4/2017 9/4/2017 0.75 COMPZN RPCOMP ALFT T Cut ESP cable at MLE splice. Test 105.0 105.0 18:00 18:45 MLE. Good. Spool power cable over sheave with rope to spooler. 9/4/2017 9/4/2017 1.50 COMPZN RPCOMP ALFT T Change out power cable spools in 105.0 105.0 18:45 20:15 spooler. 9/4/2017 9/4/2017 0.50 COMPZN RPCOMP ALFT T Pull up and inspect pump, seals and 105.0 105.0 20:15 20:45 motor. TEC wire damaged at top of motor. MLE good. RIH removing TEC wire. 9/4/2017 9/5/2017 3.25 COMPZN RPCOMP ALFT T Service ESP seal assy. 105.0 30.0 20:45 00:00 9/5/2017 9/5/2017 1.00 COMPZN RPCOMP ALFT T Prep and install .25 TEC wire to Motor 30.0 55.0 00:00 01:00 Gauge Unit. 9/5/2017 9/5/2017 4.00 COMPZN RPCOMP ALFT T Perform MLE splice. RIH. Install 3 - 55.0 111.0 01:00 05:00 dual channel clamps, one every coupling to the Well Lift discharge gauge. Make splice on Tec wire to the Gauge. Test power cable. 9/5/2017 9/5/2017 1.00 COMPZN RPCOMP PUTB T Pick up 4 joints 4 1/2" 12.6# L-80 111.0 384.0 05:00 06:00 TXPM tubing. Calibrate tourqe turn, installing dual channel Grippy clamps each joint. Make up GLM w/DV and one joint tubing. Pick up one joint tubing with preset RBP. Page 11/14 Report Printed: 9/25/2017 Operations Summary (with Timelog Depths) 1J-115 Rig: DOYON 14 Job: RECOMPLETION Time Log ' Start Depth Start Time ` .End Time Dur (hr) Phase Op Code Activity Code '' Time P T X Operation (ftKB) End. Depth (ftK6), 9/5/2017 9/5/2017 1.25 COMPZN RPCOMP PRTS T Rig up test equipment. Test RBP to 384.0 384.0 06:00 07:15 4000 psi. Unable to test. 9/5/2017 9/5/2017 0.75 COMPZN RPCOMP PUTB T Rig down test equipment. PU and RIH 384.0 466.0 07:15 08:00 2 joints tubing to 466' MD. 9/5/2017 9/5/2017 1.00 COMPZN RPCOMP SLKL T Rig up slickline. 466.0 466.0 08:00 09:00 9/5/2017 9/5/2017 2.00 COMPZN RPCOMP SLKL T RIH w.equalizer prod. Pressue up 466.0 466.0 09:00 11:00 above RBP to 500 psi. Engage prod and equalize pressure. Make up retrieval tool. RIH and pull RBP, RIH and set RBP at 382' MD. 9/5/2017 9/5/2017 1.00 COMPZN RPCOMP PRTS T Rig up test equipment. Test RBP to 466.0 466.0 11:00 12:00 4000 psi/15 min. Charted. 9/5/2017 9/5/2017 0.50 COMPZN RPCOMP SLKL T Rig down slickline. 466.0 466.0 12:00 12:30 9/5/2017 9/5/2017 1.25 COMPZN RPCOMP PUTB T Lay down 2 joints tubing. Make up 466.0 415.0 12:30 13:45 Viking vented packer. 9/5/2017 9/5/2017 1.75 COMPZN RPCOMP ALFT T PJSM-Cut ESP power cable. Spool up 415.0 415.0 13:45 15:30 on spooler. Change out power cable spools. 9/5/2017 9/5/2017 0.50 COMPZN RPCOMP ALFT T PJSM-Pull ESP power cable over 415.0 415.0 15:30 16:00 sheave in derrick. 9/5/2017 9/5/2017 2.00 COMPZN RPCOMP ALFT T Perform through packer ESP cable 415.0 415.0 16:00 18:00 splice. Pump 5 bbls 3% KCL water in hole every 30 mins 9/5/2017 9/6/2017 6.00 COMPZN RPCOMP ALFT T Meg ESP Cable -Tested bad. Showing 415.0 415.0 18:00 00:00 150 megohms phase to ground. Disconnect cable from top side of packer. Meg cable through packer. Showing 242 megohms. Tighten lower connections, replace seal boot and' reconnect. Meg cable through packer. Showing 12.6 gigohms. Good test. Reconnect upper connection. Meg from spooler through packer. Showing 25 megohms. Bad test. Disconnect at top of packer. Meg to spooler. Reading 26 megohms. Bad test. Meg through packer. Reading 13 gigohms. Good test. Replace upper connection on all three phases and lower connection due to improper armor protector. Replace lower connectors on cable side. Meg to spooler. Reading 8 gigohms. Good test. Reconnect upper connections. Meg from spooler through packer. Reading 22 megohms. Bad test. Disconnect upper connections. Observed bad connection on tri-lead side. Replace all three upper connections. Meg through packer. Reading 13 gigohms. Good test. Meg from upper connection to spooler. Reading 6.2 gigohms. Good test. Reconnect upper connection. Meg from spooler through packer. Reading 8.43 gigohms. Good test. Page 12114 Report Printed: 9/25/2017 Operations Summary (with Timelog Depths) 1J-115 Rig: DOYON 14 Job: RECOMPLETION Time Log ; Start Time End Time Dur (hr) Phase Op Code Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB), 9/6/2017 9/6/2017 0.75 COMPZN RPCOMP ALFT T Continue to trouble shoot ESP power 415.0 415.0 00:00 00:45 cable. Meg from upper connection to spooler. Reading 6.2 gigohms. Good test. Reconnect upper connection. Meg from spooler through packer. Reading 8.43 gigohms. Good test. 9/6/2017 9/6/2017 13.50 COMPZN RPCOMP PUTB T Pick up and RIH from 415' MD to 415.0 5,410.0 00:45 14:15 5410' MD w/4 1/2" 12.6# L-80 TXP tubing w/ESP cable and control lines. Install a dual channel Grippy clamp on each joint. Torque turn each connection. Make up torque 7K ft/lbs Test ESP cable and fill tubing every 1000'. Pump 5 bbls 3% KCL water in hole every 30 mins. 9/6/2017 9/6/2017 2.25 COMPZN RPCOMP HOSO T PU 3 space out pup joints (9.88', 9.88', 5,410.0 5,464.0 14:15 16:30 5.85'), x-o and hanger. Orient hanger to alignment pin. Make up landing joint and rig to pump.. Ran 137 dual channel Grippy clamps, 4 single channel equipment Grippy clamps and 1 SS band. PU=111 K SO=80K. Nd rejects, no remakes. 9/6/2017 9/6/2017 0.50 COMPZN RPCOMP ALFT T Test power cable. Phanse to phase=4 5,464.0 5,464.0 16:30 17:00 ohms, phase to ground =5.5 gigohms. Good test.Tie in vent lines. Install penetrator. 9/6/2017 9/6/2017 1.25 COMPZN RPCOMP ALFT T Make hanger ESP power cable splice. 5,464.0 5,464.0 17:00 18:15 9/6/2017 9/6/2017 0.50 COMPZN RPCOMP ALFT P Test power cable through penetrator. 5,464.0 5,464.0 18:15 18:45 Phase to phase =4 ohms. Phase to ground =5.6 gigohms. Good test. 9/6/2017 9/6/2017 1.25 COMPZN RPCOMP CRIH P Pump 190 bbls inhibited 8.5 ppg 3% 5,464.0 5,464.0 18:45 20:00 KCL water down IA. Sim-ops/Pressure test control lines to 3000 psi/15 mins. Bleed off control line pressure to close vent valves. 9/6/2017 9/6/2017 3.00 COMPZN RPCOMP RGRP T Lost high line power. Trouble shoot 5,464.0 5,464.0 20:00 23:00 electrical system. High line breaker failed. Attempt to put rig engine on line. High line breaker closed while putting engine online. Deenergize high line and remove high line breaker. Showing AC ground fault. Trouble shoot and discover debris on buss behind high line breaker. Rig off hi -line at 20:00 hrs. 9/6/2017 9/7/2017 1.00 COMPZN RPCOMP THGR P Connect control lines to spools. Land 5,464.0 5,494.0 23:00 00:00 hanger. PU=111 K SO=80 9/7/2017 9/7/2017 0.50 COMPZN RPCOMP THGR P RILDS 5,494.0 5,494.0 00:00 00:30 9/7/2017 9/7/2017 1.00 COMPZN RPCOMP THGR P Test upper and lower hanger seals to 5,494.0 5,494.0 00:30 01:30 250/5000 psi 15 mins each. 9/7/2017 9/7/2017 0.75 COMPZN RPCOMP PACK P Set packer. Pressure up tubing to 5,494.0 5,494.0 01:30 02:15 4000 psi and hold for 15 mins. Bleed pressure to 0. Pressure up tubing to 4000 psi and hold for 5 mins. 9/7/2017 9/7/2017 0.75 COMPZN RPCOMP PRTS P Test tubing to 3000 psi for 30 min. 5,494.0 5,494.0 02:15 03:00 Charted. Page 13/14 Report Printed: 9/25/2017 Operations Summary (with Timelog Depths) f 1J-115 Rig: DOYON 14 Job: RECOMPLETION Time Log Start Depth Start Time End Time Dur (hr). Phase Op Code :Activity Code Time. P-T-X Operation (ftKB) End Depth (ftKB)j 9/7/2017 9/7/2017 1.00 COMPZN RPCOMP PRTS P Bleed tubing to 2000 psi. Test IA to 5,494.0 5,494.0 03:00 04:00 2500 psi for 30 min. Charted. Bleed off tubing and shear SOV. 9/7/2017 9/7/2017 0.50 COMPZN RPCOMP RURD P Blow down lines. Rig down test 5,494.0 0.0 04:00 04:30 equipment. Lay down landing joint. 9/7/2017 9/7/2017 0.25 COMPZN WHDBOP MPSP P Pick up T bar. Set type HP BPV. Lay 0.0 0.0 04:30 04:45 down T bar. 9/7/2017 9/7/2017 0.75 COMPZN WHDBOP RURD P Blow down top drive, choke and kill 0.0 0.0 04:45 05:30 Iines.Pull and lay down mouseholes. Tie off control lines. Rig down control line sheaves. 9/7/2017 9/7/2017 2.00 COMPZN WHDBOP NUND P Pull Riser. Nipple down BOPE and set 0.0 0.0 05:30 07:30 on stump. 9/7/2017 9/7/2017 2.00 COMPZN WHDBOP NUND P PJSM-Test ESP power cable. Good. 0.0 0.0 07:30 09:30 Feed control lines through adapter, flange. Make up adapter flange and tree. Terminate packer vent valves control lines. 9/7/2017 9/7/2017 0.50 COMPZN WHDBOP PRTS P Test hanger void and seals to 0.0 0.0 09:30 10:00 250/5000 psi for 15 mins. Witnessed by Co -man. Sim-ops/Perform BWM. 9/7/2017 9/7/2017 0.50 COMPZN WHDBOP MPSP P Set test dart. Rig up to test tree. 0.0 0.0 10:00 10:30 9/7/2017 9/7/2017 1.00 COMPZN WHDBOP PRTS P Test tree to 250/5000 psi for 15 mins. 0.0 0.0 10:30 11:30 Witnessed by Co -man. 9/7/2017 9/7/2017 0.50 COMPZN WHDBOP MPSP P Pull test dart and BPV. 0.0 0.0 11:30 12:00 9/7/2017 9/7/2017 1.25 COMPZN WHDBOP FRZP P Rig up to freeze protect well. 0.0 0.0 12:00 13:15 9/7/2017 9/7/2017 0.50 COMPZN WHDBOP ALFT P Make final check on ESP power cable. 0.0 0.0 13:15 13:45 Good. 9/7/2017 9/7/2017 1.25 COMPZN WHDBOP FRZP P Test lines to 2500 psi. Pump 105 bbls 0.0 0.0 13:45 15:00 diesel down IA taking returns up tubing to pits. 2 bpm, ICP=260 psi FCP=500 psi. 9/7/2017 9/7/2017 1.25 COMPZN WHDBOP FRZP P Allow diesel to U-tube. Sim-ops/Prep 0.0 0.0 15:00 16:15 rig for move. 9/7/2017 9/7/2017 0.50 COMPZN WHDBOP PRTS P Test control lines to 3000 psi/15 min. 0.0 0.0 16:15 16:45 Secure well. Release rig at 18:00 hrs 9/7/17 9/7/2017 9/7/2017 0.50 COMPZN WHDBOP MPSP P Blow down lines. Set Type H bpv 0.0 0.0 16:45 17:15 9/7/2017 9/7/2017 0.75 COMPZN WHDBOP ALFT P Pressure up control line to 3000 psi to 0.0 0.0 17:15 18:00 open vent valves. Pump 10 bbls diesel down IA at 1 bpm to confirm valves are open. Well on vacuum. Leave vent valves open. Page 14114 Report Printed: 9/25/2017 ConocoPhillips West Sak 7-5/8" Producer 1J-115 Tri-Lateral Completion D-sand Window 'D' Sand Lateral at 6094' MD, 3553' TVD, / 77 deg 4-112" 11.6# L-80 BTC Blank and Slotted Liner - 6160' MD - Payzone ECP 1 i 3-1/2" Guide Shoe 4-1/2" Liner Shoe, 11.6#, L-80 BTC Set @ 13985' MD, 3704' TVD \ 6305' MD-5-1/2" Tieback Sleeve 6086' MD - 4-1/2" X 7SI8" 6350MD-4-1/2" bent muleshoe Model'B' HOOK Hanaer 6198' MD - 5-1 /2" X 75/8" ZXP Liner Top Packer with Hold Downs Assembly 5-112" X 7-518" ZXP Liner Top Packer with Hold Downs — Casing Sealbore Receptacle 4.75" ID Orienting Profile Automatic Alignment of LEM Positive Latching Collet '—� Indicates Correct Location Seal Bore for Lateral Isolation - 3.68" ID Access Window Positive Lateral Access Via Thru-Tubing Diverter Seal Bore for Lateral Isolation - 3.68" ID Isolation Seal Asembly 4.75" Seal OD 3.875" Seal ID 6520' MD - Lateral Entry Module (LEM) 1111' MD - Casing Se a lbore Receptacle 4.75" ID /f 6531' MD-4-1I2" X 75/8" Model'B' HOOK Hanaer Seal Bori 3.68" ID 4-1/2" 12.6# Tubing 'B' Sand Lateral B-sand Window at 6529' MD, 3600' TVD, 90 deg 4-1/2" 11.6# L-80 BTC Blank and Slotted Liner .,- 6609' MD - Payzone ECP ` 6742' MD-5-1/2" Tieback Sleeve 6798' MD - 4-112" bent muleshoe 6625' MD - 3.562" DS Nipple 5-112" X ZXP Liner Top Packer /r with Holdld Do Downs / 5-1 /2" X 75/8" 6652' MD - Liner Hanger I Packer Flex Lock Assembly Liner Hanger 6683' MD - Casing Sealbore Receptacle, 4.75" ID x 20' © Baker Hughes 2005. This document may not be reproduced -distributed, in Whole -in part, in any form or by any means electronic or mechanical, including photocopying, recording, a by any Information storage and retrieval system now known or hereafter Invented, Wth—twritten permission from Baker Hughes Inc. BAKER HUGHES Baker Oil Toots Final As Run Lateral Entry Module (LEM) With Diverters and Isolation Lateral Access Diverter Lateral Isolation Diverter GS Running Tool String Installed Installed (3.00, Lateral Drift) (2.50" ID Mainbore Drift) 'GS' Profile for Coil Connector Running/Retrieving (1.00'Length) Snap In/Snap Out r Back Pressure Valve ✓ Positive LocatingmlE (1.60' Length) Collet Lateral Isolation r Flow-Thru Swivel Seals (1.25' Length) �\ Lateral Diverter Ramp `/Hyaulic Discodrnnect (1.50' Length) Isolation/ Mainbore Diverter Sleeve GS Spear 1 (1.50'Length) Lateral Isolation�� 6.85 ft Approx. - Seals OAL' 'Jars may be required in highly deviated 18.5' Diverter Length 18.5' Sleeve Length or deep applications (6' approx length). 1 1 1 3-1/2" Guide Shoe 4-1/2" Liner Shoe, 11.6#, L-80 BTC Set @ 13913' MD, 3773' TVD 6705' MD - Bottom of Seal Assembly 4.75" Seal OD 'AT Sand Lateral , 3.875" ID 4-112" 11.6# L-80 BTC Blank and Slotted Liner Eguipment Specifications 4-1/2" X 7-518" HOOK Hanger Mainbore Drift: 5.32" Mainbore Drift, with diverter: 4.63" Lateral Drift, no diverter or LEM: 3.88" Lateral Drift, w/ diverter, no LEM: 3.88" Lateral/Mainbore Diverter OD: 6.75" 4-1/2" Lateral Entry Module Mainbore Drift: 3.65" Mainbore Drift, w/ isolation sleeve: 2.50" Lateral Drift, w/ coil diverter: 3.00" OD of Diverter and Sleeve: +/- 3.89" Diverter and Sleeve Length: +1-18.5' 4-1/2" Eccentric / Guide Shoe -/ 4-1/2" Casing Shoe, 11.6# L-80 BTC Set @ 13708' MD, 3908' TVD 7.5/8", 29.7#, Casing Shoe, Set at @ 7493' MD, 3808' TVD, 88 deg Inc °w°T'"` 20D6 West Sak7d18" Trl4ateral Completion •Producer pate: Drawn 6Y: ReNtlon Ne.: July 30, 2008 Dave Bjork 1 0 • _ _ �- Conductor Casing, 20", 94#, K55 @ 108'MD� Surface Casing 10-3/4", 45.5#, L-80 BTC Wellhead/Tubing head/Tree 5,000 psi I —115 Final Completion Schematic 09/27/17 7-5/8" Tieback/ CMT to surface @ 1,902' MD Gas Lift Mandrel, CAMCO 4-1/2" x V Model KBMG w/ DV @ 3,344' MD @ 3,009' MD / 2,215' TVD Tubing String: 4-1/2", 12.6 #, L-80 TXP ESP Cable CA 2 z'/." SS Control Line Gas Lift Mandrel, CAMCO 4-1/2" x 1" For Vented Packer Model KBMG w/ SOV @ 5,023' MD y 'n [=7 '0 Gas Lift Mandrel, CAMCO 4-1/2" x 1" 7 Model KBMG w/ DV @ 5,200, MD Viking 4-%" x 7-5/8" Dual Vented Packer �7 d @ 5,094' MD G C A WellLift Discharge Gauge Unit 5,389' MD Motor 5,478' MD Gauge 5,490' MD Centralizer 5,492' MD / RS Packoff Seal Nipple (ID= 6.07") 5-1/2" HYD563 XO 4-'/:" BTC ESP tangent: ` ZXP Liner Top Packer 5390'-5510' MD; @ 6,652' MD 65 degree, <1 dogleg See 1J-115 Multi-lat drawing.pdf = Intermediate Casing for Tri-Lateral Completion 7-5/9", 29.7#, L-80 BTCM @ 7,493' MD �rt KUP Y&D 11-115 Ct?i'i=)k11ffiWell Attribute Max Angle D jTD iAla,*a Ir1C.9MlvveIIWreAPI/UWl I Field Name jWelWoreStatus ncl (°) MD (ftKB) Act Btm (ftKB) WESTSAK PROD NONE I I ILast WO: 1 9/6/2017 1 32.201 11/28/2006 arte:a mans acty Annotation Depth (ftKB) End Date Annotation Last Mod Ely End Date .......................................... HANGER; 22.3 Last Tag: Rev Reason: Workover jennalt I 10/3/2017 Casing rings Casing Description OD (in) ID (in) Top (ftKB) Set Depth (ftKB) Set Depth (TVD)... WtlLen (I... Grade Top Thread CONDUCTOR 20 19.124 30.0 108.0 108.0 94.00 K-55 WELDED Casing Description OD (in) ID (in) Top (ftKB) Set Depth (ftKB) Set Depth (TVD)... WtlLen (L.. Grade Top Thread SURFACE 10 314 9.950 26.0 3,009.0 2,214.9 45.50 L-80 BTC Casing Description OD (in) ID (in) Top (ftKB) Set Depth (ftKB) Set Depth (TVD)... WtlLen (I Grade Top Thread INTERMEDIATE 75/8 6,875 26.3 7,493.0 3,808.4 29.70 L-80 BTCM Casing Description OD (in) ID (in) Top (ftKB) Set Depth (ftKB) Set Depth (TVD)... WtlLen (I... Grade Top Thread CONDUCTOR; 30.0-106.o B LINER LEM 4 1/2 3.860 6,198.0 6,704.9 3,680.9 1260 L80 IBT-SCC Liner Details Top (ftKB) Top (TVD) (ftKB) Top Incl r) Item Des Com Nominal ID (in) 6,198.0 3,573.9 81.03 PACKER -5/8" x 5-1/2" ZXP liner top packer 4.970 6,217.0 3,576.9 80.87 SBR Casing Seal Bore Receptacle 4.750 6,236.7 3,580.0 80.58 XO BUSHING Cross Over Bushing 3.960 SURFACE; 28.03,008.0-. 6,520.3 3,638.1 76.47 HANGER LEM (above hook hanger) 3.688 GAS LIFT; 3,344.3 6,530.9 3,640.6 76.26 HANGER LEM (inside hook hanger) 3.688 6,626.0 3,663.9 76.47 NIPPLE DB-6 Nipple 3.563 6,658.4 3,671.2 77.38 1 BENT JT IBentioint 3.860 GAS LIFT; 5,022.E 6,701.6 78.3E 1 SEAL ASSY Seal assembly 3.860 j�680.3 Casing Description OD (in) ID (in) Top (ftKB) Set Depth (ftKB) Set Depth (TVD)... WtlLen (I... Grade Top Threatl - >a B LINER HH 41/2 4.000 6,530.9 6,797.7 3, 698.7 11.60 L80 BTC PACKER; 5,094.0 Liner Details Top (ftKB) Top (TVD) (ftKB) I Top Inc, C) Item Des Can Nominal to (in) 6,530.9 3,640.6 76.26 HANGER Hook Hanger (below window) 5.610 GAS LIFT; 5,200.2 6,608.9 3,659.8 75.98 ECP External Casing Packer 3.900 6,767.6 3,693.01 79.11 BENTJT Bentjoint w/ muleshoe 3.960 GAUGE; 5,389.0 Casing Description OD (in) ID (in) Top (ftKB) Set Depth (ftKB) Set Depth (TVD)... WtlLen (I... Grade Top Thread D LINER HH 4112 3.47E 6,533.2 6,797.7 3,698.7 11.60 L-80 BTCM Liner Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Co. Nominal ID (in) ESP Intake; 5,453.4 SLIPSTOP; 5,459.1 PACKOFF; 5,460.3 6,533.2 3,641.1 76.21 HANGER BAKER MODEL PZ HOOK HANGER (INSIDE CSG) 3.950 Upper Tandem; 5,464.0 Lower Tandem; 5,470.8 ESP Moors; 5,477.7 6,550.0 3,645.2 75.88 HANGER BAKER MODEL PZ HOOK HANGER OUTSIDE GSG) 3.950 MOTOR GAUGE; 5,490.1 Centralizer, 5,4920 6,607.1 3,659.4 75.93 ECP BAKER PZ EXTERNAL CASING PACKER 3,900 6,769.4 3,693.4 79.12 BENT JT 3.960 Casing Description OD (In) ID (in) Top (ftKB) Set Depth (ftKB) Set Depth (TVD)... WtlLen (I... Grade Top Thread A -SAND LINER 41/2 3,476 6,652.0 13,708.0 3,909.9 11.60 L-80 Buttress Thread Liner Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Com Nominal ID (in) 6,652.0 3,669.8 77.20 PACKER BIKER HRD ZXP LINER TOP PACKER 5.500 6,671.0 3,674.0 77.74 NIPPLE 'RS' PACKOFF SEAL NIPPLE 4.870 6,673.9 3,674.6 77.82 HANGER FLEX -LOCK LINER HANGER 4.850 6,683.8 3,676.6 78.04 SBE 190-47 SEAL BORE EXTENSION 4.750 Tubing Strings Tubing Description String Ma... ID (in) Top (ftKB) Set Depth (ft.. Set Depth (TVD) (... Wt (Ib/ft) Gratle Top Connection TUBING 41/2 3.958 22.3 5,493.9 3,352.8 12.60 L-80 TXPM Completion Details Top (ftKB) Top (TVD) (ftKB) Top Incl (') Item Des Com NominallD (in) 22.3 22.3 0.00 HANGER Tubing Hanger, Vetco-Gray MB222A offset 10 3/4 x 4 1/2 1900 w/false bowl 5,094.0 3,179.6 63.62 PACKER Viking Vented Packer SN: VCT-PO-17-335-2 1902 5,389.0 3,307.9 64.59 GAUGE WeIILift Discharge Gauge Unit, Centrilift 3.958 - 5,453.4 3,335.5 64.63 ESP Intake TTC Drilled Crossover, Centrilift 5,464.0 3,340.0 64.65 Upper Upper Tandem Seal Section, Centrilift Tandem B LINER LEM; 6,196.46,704,9 5,470.8 3,343.0 64.66 Lower Lower Tandem Seal Section, Centrilift Tandem 5,477.7 3,345.9 64.67 ESP Motors ESP Motor, Centrilift, 175HP/3180V/34A 5,490.1 3,351.2 64.69 MOTOR WeIILift E Motor Gauge Unit, Centrilift B LINER HH; 8,530.98,787.7 GAUGE D LINER HH; 6,533.28,797.7 5,492.0 3,352.0 64,69 Centralizer Motor Centralizer, Centrilift Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB) Top Incl Des Des Com Run Date ID (in) SLOTS; 7,234.0-7,614.0-. INTERMEDIATE; 28b7,093.0 5,455.6 3,336.4 64.63 JUNK JUNK CATCHER SET ON SLIPSTOP 9/2/2017 CATCHER _ 5,459.1 3,337.9 64.64 SLIPSTOP SLIPSTOP SET ON PACKOFF 9/2/2017 SLOTS; 7,786.0-8,127.0 _ 5,460.3 3,338.5 64.64 PACKOFF PACKOFF SET ON ESP PUMP 9/2/2017 SLOTS 6,362.0-11,770.0 SLOTS; 1z157.0.12,546D SLOTS; 12,719.0-13,360.0 SLOTS; 13,533.0-13,654.0 A -SAND LINER; 6,6520- 13,708.0� {{{ 4.ono �hiliips '`"' KUP �D � 7J-9'15 Alaska, in0. Mytpple Literals-1J 115, 1013/20173:06:21 PM arena emaac aowal. HANGER; 22.3 Perforations o Shot Den Top (RKB) Bt. (RKB) Top(TVD) (RKB) Btm(TVD) (RKB) Zone Date (shots/ R) Type Co. 7,234.0 7,614.0 3,777.7 3,817.3 115 WS A2, 1J- 10/26/2006 32.0 SLOTS ALL PERFS IN WELL: Alternating solid/slotted pipe - 0.125'S2.5" @ 4 circumferential adjacent CONDUCTOR; 30.0-108.0 rows, 3" centers staggered 18 deg, 3' non -slotted ends 7,786.0 8,127.0 3,820.8 3,822.7 WS A2, 1J- 10/26/2006 32.0 SLOTS 115 8,382.0 11,770.0 3,820.6 3,842.0 WS A2, 1J- 10/26/2006 32.0 SLOTS 115 SURFACE; 26.0-3,0D9.0— 12,157.0 12,546.0 3,864.3 3,888.7 WS A2, 1J- 10/26/2006 32.0 SLOTS 115 GAS LIFT; 3,344.3 12,719.0 13,360.0 3,893.6 3,909.3 WS A2, 1J- 10/26/2006 32.0 SLOTS 115 13,533.0 13,664.0 3,905.1 3,907.6 WS A2, 1J- 10/26/2006 32.0 SLOTS GAS LIFT; 5,022.8 115 Mandrel Inserts st PACKER; 5,094.0 ah NTop Top (RKB) (TVD) (RKB) Make Model OD (in) Serv, Valve Type Latch Type PortSize (in) TRO Run (psi) Run Date Co. 11 3,344.31 2,375.9 Camco KBMG 4 1/2 GAS LIFT DMY BEK-5 0.000 0.0 9/6/2017 GAS LIFT; 5,200.2 2 5,022.8 3,147.8 Camco KBMG 4112 GAS LIFT SOV BK-5 0,000 0.0 9/6/2017 3 5,200.2 3,226.E Camco KBMG 4 112 GAS LIFT DMY BK-5 0.000 0.0 9/6/2017 Notes: General & Safety GAUGE, 5,389.0 End Date Annotation 10/23/2006 NOTE: CMT complete annulus top to bttm (1903) Halliburton Bowl Patch /Overshot to tie back 11/27/2006 NOTE: MULTI -LATERAL WELL: 1J-115 (A -SAND), 1J-11511 (B-SAND), 1J-1151-2 (D-SAND) ESP Intake; 5,45 SLIPSTOP; 5,459.1 4/24/2011 NOTE: View Schematic w/Alaska Schematic9.0 9/6/2017 NOTE: WO PACKOFF; 5,460.3 Upper Tandem; 5,464.0 Lower Tandem; 5,470.8 ESP Motors; 5,477.7 MOTOR GAUGE; 5,490.1 Centralizer, 5,492.0 B LINER LEM, 6,198.0E,704.9 B LINER HH; 6,530.9-6,797.7 D LINER HH; 6.533.2-6,7977 SLOTS; 7,234.0-7,614.0— INTERMEDIATE, 26.3-7 493.0 SLOTS; 7,786.0-8, 127.0 SLOTS, 8,3820-11,770.0 SLOTS; 12,157.0-12,546.0 SLOTS; 12,719.0-13,300.0 SLOTS, 13,533.0-13.664.0 A -SAND LINER, 6,652.0- 13,708.0� 10 tiro Loepp, Victoria T (DOA) From: Simek, Jill <Jill.Simek@conocophillips.com> Sent: Monday, September 18, 201710:52 AM To: Loepp, Victoria T (DOA) Cc: Autry, Sydney Subject: FW: 1J-115 Vented Packer Completion Attachments: Viking Vented Packer Summary_Ops.pptx Follow Up Flag: Follow up Flag Status: Flagged Victoria, In anticipation of converting 1.1 pad to VRWAG, I am looking at 1J producers to ensure that they will meet requirements of AOGCC Area Injection Order 2C. Per AOGCC Area Injection Order 2C, "VRWAG is authorized in the West Sak Oil Pool; VRWAG must be conducted in accordance with the process described in the VRWAG Application" (Modification of Area Injection Order 2B for Injection of Enriched Hydrocarbon Gas in the West Sak Oil Pool, dated July 31, 2013). As stated in the VRWAG Application, this includes utilizing a tubing and packer completion in all producers within a % mile radius of offset VRWAG injectors. One of these producers,11-115, has recently been recompleted with the vented packer and ESP completion we discussed last year (see email thread below). Currently, the well is operating the same as a packerless ESP (ie. formation gas diverted up tubing x production casing "IA" annulus and tied back into the produced fluid line at surface), through the use of the Viking 4 % " x 7-5/8" dual vented packer. A summary of the completion is attached, for your reference. ConocoPhillips intends to submit a 10-403 Application for Sundry Approvals for conversion of 1.1 injectors once the project has received internal approvals. Please let me know if the State anticipates any issues allowing continued operation of 1J-115 after offset VRWAG injection is introduced. Thank you, Jill Simek ConocoPhillips Alaska Staff Well Integrity Engineer 700 G Street, ATO 1854, Anchorage, AK 99501 Phone: 907-263-4131 1 Cell: 907-980-7503 From: Simek, Jill Sent: Tuesday, November 08, 2016 8:53 AM To: 'Loepp, Victoria T (DOA)' <victoria.loepp@alaska.gov>; Schwartz, Guy L (DOA) <guy.schwartz@alaska.gov> Cc: Sullivan, Michael <Michael.Sullivan@conocophillips.com> Subject: RE: 11-115 Vented Packer Completion Victoria/Guy, Further to our discussion on the vented packer system for ESP wells operating in VRWAG fields: It is our recommendation that the packer vent valves operate separately from one other, independently open/close from the SSV, and also shut during an ESD where the SSV trips. The proposal (and attached P&ID) for the controlling the vent valves is as follows: 1. A separate skimpy panel will be installed for each vent valve to be controlled independently a. Total of three panels in wellhouse (1 for SSV, and 1 for each vent valve) 2. Packer vent valves will be tied into existing SSV trip logic a. A solenoid will be installed in each Skimpy panel that will trip the packer vents on any ESD or process condition that trip the SSV To move forward with our design, ConocoPhillips is asking the AOGCC to approve the vented packer/completion design as meeting the requirements for AIO 2c. Please advise if additional information is required. Thanks, Jill Simek ConocoPhillips Alaska Staff Well Integrity Engineer 700 G Street, ATO 1302, Anchorage, AK 99501 Phone: 907-263-4131 1 Cell: 907-980-7503 From: Loepp, Victoria T (DOA) [mailto:victoria.loepp@alaska.gov] Sent: Wednesday, July 13, 20161:45 PM To: Simek, Jill <Jill.Simek@conocophillips.com> Subject: [EXTERNAL]RE: 1J-115 Vented Packer Completion Hi Jill, We would like a review of the vent valve control flow logic. Perhaps an instrumentation person can address the vent valve control and how it would be tied into the safety valve system if it is. Some P&IDs might be useful. Caelus does utilize these valves but they are tied into the safety valve system. Hope this helps. Thanx, Victoria Victoria Loepp Senior Petroleum Engineer State of Alaska Oil & Gas Conservation Commission 333 W. 7th Ave Anchorage, AK 99501 Work: (907)793-1247 Victoria. LoeppOalaska.gov CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Victoria Loepp at (907)793-1247 or Victoria. Loepp@alaska.gov From: Simek, Jill [mailto:Jill.SimekCaaconocophillips.com] Sent: Wednesday, June 22, 2016 11:09 AM To: Loepp, Victoria T (DOA) Subject: 13-115 Vented Packer Completion Victoria, Per our discussion: 1J-115 (PTD# 206-122) is a West Sak packerless ESP well, currently operating on backup gas lift while being evaluated for repair. In addition to ESP replacement, the planned workover will include packer installation to meet AOGCC requirements for Viscosity Reducing Water Alternating Gas (VRWAG) in offset injectors. Per AOGCC Area Injection Order 2C, "VRWAG is authorized in the West Sak Oil Pool; VRWAG must be conducted in accordance with the process described in the VRWAG Application" (Modification of Area Injection Order 2B for Injection of Enriched Hydrocarbon Gas in the West Sak Oil Pool, dated July 31, 2013). As stated in the VRWAG Application, this includes utilizing a tubing and packer completion in all producers within a X mile radius of offset VRWAG injectors. The chosen packer design for 1J-115 is a 7-5/e x 4-1/2" Viking feed-thru packer with 1.375" vent valve. The vent valve consists of a hydraulically actuated piston with fail -close mechanism. For ESP operation, the vent valve would be operated in the open position for venting gas up the tubing x production casing annulus (IA). Should annular isolation be required, the packer vent valve would be closed via surface hydraulic control line. The vented packer will be considered a separate system from the safety valve system and will be monitored as such. ConocoPhillips policy is to function and pressure test the vented packer system annually. During testing, the vent valve will be closed and a negative pressure test performed to confirm integrity of the vented packer system. A failed test will indicate non-compliance of the NO 2C operating conditions for VRWAG, thus offset gas injection will not be permitted until vented packer integrity is restored. The proposed schematic for 1J-115 is attached for your reference. Please advise if you have questions or disagree with this plan. Jill Simek ConocoPhillips Alaska Staff Well Integrity Engineer 700 G Street, ATO 1854, Anchorage, AK 99501 Phone: 907-263-4131 1 Cell: 907-980-7503 u Conductor Casing, 20", 940,K55 6.690" packer in 7-5/8" casing I08'MD� Surface Casing 10.3!4", 45.50, L-80 BTC !0 3,009' M D t 2,215' TV D 2x %" SS Control lines for Vented Packer — 5J8' is s11rfsCe trT 1,902' MD Gas lift mandrel Dummy (ESP) Unloading GLV (GL) ESP cable Gas lift mandrel Dummy (ESP) OV (GL) Gas lift mandrel SO (ESP) Vented Packer 5094' MD/ 3180' TVD • Intake 5,480' MD ---- Motor 5,494' MD — Gauge 5,506' MD - Centralizer 5,508' MD Z%P liner Top Packer �O 6,652' MD a Intermediate Geeing 7-5.18', 29.7k,1: 80 BTCM @ 7,493' MD • Hydraulically set at 5094' MD/ 3180' TVD — 4000 psi min. setting pressure — 5000 psi pressure rating • 2x 3/4" NPT in upper secondary connection — Equipped with gas vent valves — 2x 1/4" stainless steel control lines running to surface • Deployed in ESP lifted producers with offset gas injection — Within a quarter mile radius of offset gas injection • 9/1/2017 WOG 4 Yr. MIT -IA — Annual —ve pressure test ConocoPhillips Viking ESP Vented Packer October 4, 2017 ConocoPhillips Use Only • F((0 K. �I1. ..;'_; ter; NUMBER 105049-00 2 105050-00 1 3 105051-00 PISTON INSERT 1 4 105052-00 &VANGABAPIM SOTTOM SUB DIE SPRING 1 1 5 105063-00 B 6 10518-1-00 B 7 006-00-14 BACKUP RING 13.95 OD ID 9.85 - 15`$i GLASS{5%MOLY TEFLON 2 B 8 N/A O-RING BS110 (9.19M.M ID - VITON 1 B 9 006' 00-24 BACKUP RING 23.95 0:) X ID 19.85 - 15% GLAS515%.HOLY TEF=ON 2 B 10 N/A 0--,ING 115116 f 13.72V,..M ID; -VfT0N 1 B 11 1024;2 00 114" NPT PLASTIC PLUG 1 Ll .225 j • Upper Connection: 1/4" NPT be • Lower Connection: 3/4" NPT pi • Pressure Rating: 5000 psi • Start to open pressure: 3000 p� • Fully Closed pressure: 2500 psi • Max OD: 1.228" • Operating Piston Area: 0.117 in • Flow Area: 0.2 in2 • Overall Length: 10.4 in ConocoPhillips • • Pdoker -M -M-6 tied M. enstiap SSV trip logic. _._---.i---------------- Q Q Packer vent aantrol ' © �.N 3ne15 dfe Sepdrdte and = R independent horn each � �" Olher. � (MtlA {I ' �96a a tt a V! t¢ICk n 5{ S F sLNi ! \IO R.k .4'Li '�j li1_�ftCf 110. III -I__ tlPBkl "' I � v YRIIT$ O1WLI � _ I�S r� i y (+Cp tSftC. JCL '1` - nKtis a .µ n g. Y � —� i �b Mife IkaA Ip � xwnA r at•�ea IMaA la As +NkU IMYi 1 + - r INDEPENDENT HYDRAULIC -•r-b ii R+aA • CONTROL LINES TO REDUNDANT GAS VENT VALVES_ P-W09 iit M 1n !*E+7plE:t WpA�LWµEC9d k1OCM4CiC4 � M h=t +. A11 M'mEaDFS aA tv= 0, M IDbt01Ek. P Fta. _ --. _._..... nMGA DA. WC'd 17APK il-1�Btl$+R-1nWa Wr[9 YeIaIN[RE RB uif]ro faR f![x Nq nd 9fYl Qj Y.IW4N IYE. B IRT. VM GYN 1'BRaIYFIF IBIC I!Y guarm Ai'mA Y1 Nl{)ERMi T9CG:BK IxiNn 1:F ML Mat WY�R YRL Q Af:[(p K A St�1' fdi ny9F,[ to J+Ij6a-tp! 1paY �� Its / Q ]. V% LCQED a `LC1M% nDolu NMXIR TX NJ1 M It. { Z sn oxF' ENIS .1 A5 wEn X Nt QSP'.C1M Rlw Afr! YA PMnM a 1H wL umw n. 1, kA.YI{ut RI s cM Wom a Mw 4NDl a[CE "IN m,Rx IM. 4a D'Ir WK ! Q {_ Sta 1rtY —xv !IUIYB ELL>E/D swt DR A LL -a Y. Y Lf ^ �., 5 91Wf IN16 Raw "'XI T r I 1 ftSt rEICLR {, B A wm la Ka SOI(S 1] Ml. 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IN d. tlatR a11111L.KK IMI YIIQ r_ i � (W 1) AN L3�-° EfC�XII gr"a" Op i l 1 n. rM-Is Net \EMIIBY MIUM ., tMk Comm fldR J7 • t(r ••�•, • Three skimpy panels in well house — 1 for SSV and 2 for each vent valves — Vent valves to be controlled independently • Packer vent valves are tied into the SSV trip logic Con04WHIPS Well house set-up October4, 2017 ConocoPhillips Use Only d e ►dd �4 i 7--.J 0 1� r-o 206-fZz Loepp, Victoria T (DOA) From: Simek, Jill <Jill.Simek@conocophillips.com> Sent: Tuesday, July 19, 2016 2:44 PM To: Loepp, Victoria T (DOA) Subject: RE:1J-115 Vented Packer Completion Attachments: MPD-DIJW-2021-001.pdf Follow Up Flag: Flag Status. Follow up Flagged Victoria, Sorry for delayed response. We have been discussing your questions with the vent valve vendor, Viking Completion Technology, and our Surface Engineering group. The final MID has not been generated as we are still at proof of concept stage and have not requested funding for final design work. I do have a preliminary drawing (attached) that shows the vent valve control in red. I hope this will suffice. We would install a second control panel (separate to Safety Valve control panel) for operation of the vent valve. Comments from Viking regarding the control line install are below. The control line from the valve to surface would be run with tubing clamps on every coupling. The tubing hanger must be ported to accept both lines. The lines should be fed through the tubing hanger and not terminated at each side. Parker type thermocouples hold and seal the control lines at the tubing hanger. The lines would exit the wellhead at a bulkhead and then be routed and connected to the control manifold. Let me know if you have more questions. Jill Simek ConocoPhillips Alaska Staff Well Integrity Engineer 700 G Street, ATO 1854, Anchorage, AK 99501 Phone: 907-263-4131 1 Cell: 907-980-7503 SCANM FED 0 6 20, 17 From: Loepp, Victoria T (DOA)[mailto:victoria.loepp@alaska.eov) Sent: Wednesday, July 13, 20161:45 PM To: Simek, Jill <Jill.Simek@conocophillips.com> Subject: [EXTERNAL]RE: 1J-115 Vented Packer Completion Hi Jill, We would like a review of the vent valve control flow logic. Perhaps an instrumentation person can address the vent valve control and how it would be tied into the safety valve system if it is. Some P&IDs might be useful. Caelus does utilize these valves but they are tied into the safety valve system. Hope this helps. 0 Thanx, Victoria Victoria Loepp Senior Petroleum Engineer State of Alaska Oil & Gas Conservation Commission 333 W. 7th Ave Anchorage, AK 99501 Work: (907)793-1247 Victoria. Loepp aaalaska.gov CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Victoria Loepp at (907)793-1247 or Victoria. Loepp@alaska.gov From: Simek, Jill fmailto:Jill.Simek(abconocophillips.com] Sent: Wednesday, June 22, 2016 11:09 AM To: Loepp, Victoria T (DOA) Subject: U-115 Vented Packer Completion Victoria, Per our discussion: 1J-115 (PTD# 206-122) is a West Sak packerless ESP well, currently operating on backup gas lift while being evaluated for repair. In addition to ESP replacement, the planned workover will include packer installation to meet AOGCC requirements for Viscosity Reducing Water Alternating Gas (VRWAG) in offset injectors. Per AOGCC Area Injection Order 2C, "VRWAG is authorized in the West Sak Oil Pool; VRWAG must be conducted in accordance with the process described in the VRWAG Application" (Modification of Area Injection Order 2B for Injection of Enriched Hydrocarbon Gas in the West Sak Oil Pool, dated July 31, 2013). As stated in the VRWAG Application, this includes utilizing a tubing and packer completion in all producers within a X mile radius of offset VRWAG injectors. The chosen packer design for 1J-115 is a 7-5/8" x 4-1/2" Viking feed-thru packer with 1.375" vent valve. The vent valve consists of a hydraulically actuated piston with fail -close mechanism. For ESP operation, the vent valve would be operated in the open position for venting gas up the tubing x production casing annulus (IA). Should annular isolation be required, the packer vent valve would be closed via surface hydraulic control line. The vented packer will be considered a separate system from the safety valve system and will be monitored as such. ConocoPhillips policy is to function and pressure test the vented packer system annually. During testing, the vent valve will be closed and a negative pressure test performed to confirm integrity of the vented packer system. A failed test will indicate non-compliance of the AIO 2C operating conditions for VRWAG, thus offset gas injection will not be permitted until vented packer integrity is restored. The proposed schematic for 1.1-115 is attached for your reference. Please advise if you have questions or disagree with this plan. Jill Simek ConocoPhillips Alaska Staff Well Integrity Engineer 700 G Street, ATO 1854, Anchorage, AK 99501 Phone: 907-263-4131 1 Cell: 907-980-7503 0 to . sec ac ws mu 2". 5.000 psi. String L-80. IOTM i.833" Drift MD - Camco 4-112" X 1" KBMG. 2401114111 deg -5,000' MD - Viking Feed-Thru ESP Packer w Gas Vent Valve 5510. MD - Bottom of Motor Centralizer Centralift 418 HP KMHFER 2610 + 98 ConocoPhillips West Sak 7-5/8" Producer 1J-115 Tri-Lateral Completion D-sand Window - 'D' Sand Lateral at 6094' MD. 3553' TVD. 77 deg 4-1:2" 11.6# L-80 BTC Blank and Slotted : Liner �- 6160' - Payzone ECP �� r . 3-112" Guide Shce 4.112" Liner Shoe. 11.6#, L-80 OTC �\ 6Set a 13985' MD. 3704- TVD 305' MD - 5-112" Tieback Sleeve 6350' MD -4-12" bent muleshoe 198' MD - 5-112" X 7-518" ZXP Liner Top Packer with Hold Downs 621b MD eCall al SaleRcepla 4.75" ID t 6531' MD-4.112" X 7-5/8" Model'B' HOOK Hanger Seal Bon 3.68" ID 6520' MD - Lateral Entry Module (LEM( 4-12" 12.6# Tubing 'B' Sand Lateral B-sand Window at 6529' MD. 3600' TVD. 90 deg 4-112" 11.6# L-80 BTC Blank and Slotted Liner _ 6609' MD - Payzone ECP 6742' MD - 5-12" Tieback Sleeve 6798' MD - 4.112" bent mulishoe 6625' MD - 3.562" DB Nipple ZXP Liner Top Packer f wilt) Hold DOwne 5-1(2" X 75$ 6652' MD - Liner Hanger 1 Packer Flex Lock Assembly Liner Hanger / 6683' MD - Casing Seolbore Receptacle. 4.75" ID x 20' Baker Oil Tools Final As Run With Diverters and Isolation Lateral Access Dlvarter Lateral 1501a60f1 Diverter GS Running Tool string Ihnalled Installed 13.00" Lateral Drift) (2.50" ID Mainbore DrBq 8Im 'GS' Profike fa - Coil ComectaLengthl ZRtnniogReirieving 11.00' ` I �. ? � Snap Irt'Snap Out . - Back Pressure Valve Positive Locating— O.60' Length) Collet Lateral Isclaaon --' .-- Flow-Thru Swivel `. seals 1 11.26Length! 1: .� Lateral Diverter �-Hydraulic i'•., Ramp Disconnect` 11.51T Length) ,� Iso Wtiat' Mainbore' -" ' Diverter Sleeve _ -._ GS spew `- (1.50' Length) Lateral hoWdon' _ 6.85 ft Approx. II seals OAL' _. 1 lay be required in higlNy deviated 18.5 Diverter Length 18.5' Sleeve Length applications I6' approx lishour). 3-12" Guide Shoe 4-1i2" Liner Shoe. 11.6#. L-80 OTC Set (G• 13913- MD. 3773- TVD 6705' MD - Bottom of Seal Assembly 4.75"Seal OD 'A2' Sand Lateral , 3.875" ID Eauipment Specifications 4.1/2" X 7.6/8" HOOK Hanger Mainbore Drift: 5.32" Mainbore Drift. with diverter: 4.63" Lateral Drift. no diverter or LEM: 3.88" Lateral Drift, wl divert", no LEM: 3.88" Lateral/Mainbore Diverter OD: 6.75" 4-1/2" Lateral Entry Module Mainbore Drift: 3.65" Mainbore Drift, wi isolation sleeve: 2.50" Lateral Drift, wl roil diverter: 3.00" CD! Diverter and Sleeve: ^!- 3.89" Diverter and Sleeve Length: d-18.5' 4-112" 11.6# L-80 BTC16. Blank and Slated Liner 4-112" Eccentric Guide Shoe 4.1/2- Casing Shoe. 11.0 L-80 OTC Ilk Set @ 13708' MO. 3908' TVD 7.5 8". 29.7#. Casing Shoe, Set a. ;d, '493' MD. 3608'TVD. 88 deg 'rc NOTES 1. ALL INSTRUMENTS ARE TAGGED WITH AN ADDITIONAL PREFIX - TO INDICATE DRILL SITE 1J. EXAMPLE: PI-1000 IS PI-TJI000 WHERE INSTRUMENTS ARE REPEATED FOR EACH WELL, THE SAME H� NUMBER WILL BE USED FOR EACH INSTRUMENT USING THE STANDARD 201E A - LOCAL CONTROL INSTRUMENT NUMBERING PROCEDURE, EXCEPT THAT THE WELL NUMBER WILL BE INCLUDED AS A SUFFIX, FOR EXAAPLE'FIT-IJ1000-101' HS >01A HS Q 2. VSD LOCATED IN ELECTRICAL MODULE, INSTRUMENT TAG NUMBERS FOR 4 HS 92019A ROV BPCS EACH VSD'S COMPONENTS ARE ASSOCIATED WITH THE RESPECTIVE PUMP PER THE VSD PORTION OF THE WELL NUMBER MATRIX. 20 �' 201 3. BREAK-OUT FLANGES FOR REMOVAL OF LATERAL SPOOL PIECE o BETWEEN TRUNK LINE AND DIVERT VALVE. Q4. ESD VALVE LOCATED OUTSIDE WELLHEAD SHELTER FOR WELL SHUT-IN, M 5. SKIMPY HDCP HAS FUSIBLE PLUG. I TEST (NOTE 3) 3' TEST HEADER 6. tN ADDITION TO VSD SIGNALS, OCS WILL SHUT DOWN ESP - -_ 4'PC-iJ63FKC7MPD-DIJY-2867 ��- �-t—� DRIVE & SSV ON THE FOLLOWING: 4` 1 PIT-1J9350 HIGH OR LOW PRESSURE 001 PIT-1J5301 HIGH PRESSURE 1 VGC11 ` i'VGCWB ZSC-`-J9350 INDICATES CLOSED WNOTE A3 11} PAD ESO HAND SWITCHES (ON P&ID MPO-DIJB-2006) i 7. HIGH.- POINT VENT. o HS 9201AA ' LOCAL CONTROL 8. SHEAR RELIEF VALVE PROVIDED FOR DOWNHOLE RELIEF. SET AT 20DO PSID. ROV BPCS 9, BLEED RING FOR FUTURE CHEMICAL INJECTION. 10, VALVE MOUN'ED ON SSV AT TAPPED FLANGE. 11. LOCATEED ON SIDE OF P'PE. 4'PRODUCTION 1201A 12.CUSHION TEE, (NOTE 3} 3' PRODUCTION HEADER --- 4"PC-iJ62-FKC7 13. LMIT SWTCHES ZSC-935D AND 250-9350 N1RED THROUGH ROV-92O2 FOR A♦PD-DiJY-2067 04, _. .t—i, SIGNAL. ROY POWER LOSS WILL AFFECT LIMIT SWITCH SIGNAL. I VGCWB 1 VGCW SHT. 001 14, PRESSURE PILOTS SET TO 400 PSIG BASED UPON THE POTENTIAL FOR NOTE 11) `NOTE 11) TUBE RUPTURE IN HO PRODUCTION EXCHANGERS. I& LIMIT SWITCHES ZSC-9351 AND ZSO-9351 WIRED THROUGH ROV-9207 FOR SIGNAL. ROV POWER LOSS WILL AFFECT LIMIT SWITCH SIGNAL. 16. SPEC. BLIND CLOSED EXCEPT DURING GAS LIFT OPERATION. 17. INTERLOCK ACTIVE ONLY DURING GAS UFT OPERATION FOR PIT-5302 LOW PRESSURE AND FIT-1401 REVERSE FLOW. 18. SET BELOW NORMAL GAS LIFT WELL PRESSURE. (NOTE 11) FKC7 EKD7 19. SET FOR REVERSE FLOW. Y"VGC 20. HOT OIL TRUCK CONNECTION. (NOTE 16} � 2' (NOE LIFT GAS T 3) 1 i j2' "GM �.. -1J16-EKD7 i�MPD-DIJY-2067 VPCLA SH7. 001 7) TIT BPCS Tl 20 20 3 l�BpCo NC 4NS Z( 7 207 207 207 POSITION INDICATION LOCAL CONTROL �- WELLHEAD SHELTER YA211088BESP ► AREA: IJ MODULE: 1JWH UNIT: D1 ccN& ConoCON hips DS1J WELL 115 CAM FILE NO. Alaska, Inc. P&ID WAMN: S. O'CONNOR M11- COWN cCHOWDHURY M E. EWSAK ESP/GL PRODUCTION WELL N. SCALE: DATE: REORAMM FROM: JOB NO: SUB JOB Nor,ORAM9NO N0. BARt: REN. NONE 10 14 03�� ROSENBLUTH NSDK 0000 MPD-DIJW-2021 I 001 of 4 7--1i2.o MAY 0 6 1015 WELL LOG TRANSMITTAL #903130597 To: Alaska Oil and Gas Conservation Comm. Attn.: Makana Bender 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Gas Lift Survey: 1J-115 Run Date: 2/17/2016 April 27, 2016 DATA LOGGED 5 VL/201 to M.K.BENDER 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 Digital Data in LAS format, Digital Log Image file 50-029-23320-00 Gas Lift Survey (Field Print) 50-029-23320-00 1 CD Rom 1 color log 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 Office: 907-273-3527 Fax: 907-273-3535 FRS—ANC@halliburton.com Date: Signed: ✓a��v ''✓`��'""C rt; • STATE OF ALASKA • ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS [B 0 1 ?Oi 1. Operations Abandon j! Plug Perforations Fracture Stimulate j Pull Tubing Operations shutdown r Performed: Suspend r Perforate Other Stimulate Casing Alter � 9 Change Approved Program Plug for Redrill r Perforate New Pool Repair Well j Re-enter Susp Well Other: ESP to GL I✓ 2. Operator Name: 4. Well Class Before Work: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development r Exploratory Stratigraphic �"' Service �"' 206-122 3. Address: 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-029-23320-00 7. Property Designation (Lease Number): 8. Well Name and Number: ADL 25661, 25650 WSAK 1J-115 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pool(s): Kuparuk River Field / West Sak Oil Pool 11. Present Well Condition Summary: Total Depth measured 13720 feet Plugs (measured) None true vertical 3911 feet Junk (measured) None Effective Depth measured 13708 feet Packer (measured) 6652 true vertical 3908 feet (true vertical) 3670 Casing Length Size MD TVD Burst Collapse CONDUCTOR 78 20 108 108' SURFACE 2983 18 3009 2214' INTERMEDIATE 7467 7.625 7493 3804' A -SAND LINER 7056 7.63 13708 3910' Perforation depth: Measured depth: 7234-7614,7786-8127,8382-11770,12157-12546,12719-13664 True Vertical Depth: 3777-3817,3820-3823,3821-3842,3864-3889,3894-3908 Tubing (size, grade, MD, and TVD) 4.5, L-80, 5511 MD, 3360 TVD Packers & SSSV (type, MD, and TVD) SSSV=NONE MD=O TVD=O Packer MD= 6652 TVD= 3670 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 679 326 260 180 179 Subsequent to operation 711 3459 323 650 200 14. Attachments (required per 20 AAC 25.070, 25.071, &25.283) 15. Well Class after work: Daily Report of Well Operations rv— Exploratory r` Development rv— Service r Stratigraphic 16. Well Status after work: Oil r Gas r— WDSPL Copies of Logs and Surveys Run r Printed and Electronic Fracture Stimulation Data GSTOR r WINJ r WAG r GINJ r— SUSP r— SPLUG i— 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 315-767 Contact Darrell Humphrey/Bob Christensen Email: n1139 conocophillips.com Printed Name Darrell Humphrey Title: NSK Production Engineering Specialist Signature "�:> Phone: 659-7535 Date / ^ Z q • /� Form 10-404 Revised 5/2015 "T - L<« 1 L RBDMS LL FEB 0 1 2016 Submit Original Only • • 1J-115 DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary 01/04/161 Convert well to gaslift. Bring well on production. 12/12/15 (AC EVAL) : GAS MIT -IA PASSED. 12/09/15 12/08/1 DEPLOY 4 1/2 CATCHER SUB; PULLED DV @ SET GLV @ 3415' RKB; PULLED DV @ SET OV @ 4981' RKB; PULLED CATCHER & 4 1/2 TTCESP @ 5400' RKB. JOB COMPLETE. 5 PULLED 4 1/2 TBG STOP @ 5385' RKB; OBTAIN GOOD TBG TEST W/ HOLEFINDER @ 5391' RKB; PULLED 4 1/2 D&D PACKOFF ASSEMBLY @ 5391' RKB (KOBE KNOCKOUT GONE / FLOW CUT); UNSEAT 4 1/2 TTCESP @ 5400' SLM (LEFT PUMP @ 5365' SLM). IN PROGRESS. A& KUP PROD . 11-115 COnoeolhillips Attributes Well Attributes Angle & MD TD Maxx A A�51fa, Inc. 50ell W¢Ilbore APIIUWI Field Name Wellbore Status WEST SAK PROD ncl (°) MD (ftKB) Act 13,474.70 Dim (ftKB) 13,720.0 ... Comment 112E (ppm) I Date SSSV: NONE Annotation End Date Last WO: KS-Grd (fl) I Rig Release to 32.20 11/28/2006 Multiple Laterals - iJ-115, 12/1412015 2'06'4O PM Vertical schematic actual Annotation Depth (ftKB) End Dale Annotation I Last Mod By End Date Last Tag: I Rev Reason: GLV C/O, PULLED ESP PUMP, pproven I 5/7/2013 -�� SLIPSTOP,PACKOFF & TTC-ESP asmg nngs Casing Description OD (in) ID (in) Top (ftKB) Set Depth (ftKB) Set Depth (TVD)... Wt/Len (I... Grade Top Thread CONDUCTOR 20 19.124 30.0 108.0 108.0 94.00 K-55 WELDED HANGER; 21.9 Casing Description OD (in) ID (in) Top (ftKB) Set Depth (ftKB) Set Depth (TVD)... WVLen (I... Grade Top Thread ,. I SURFACE 10 3/4 9.950 26.0 3,009.0 2,214.9 45.50 L-80 BTC - Casing Description OD (in) ID (in) Top (ftKB) Set Depth (ftKB) Set Depth (TVD)... WVLen (I... Gratle Top Thread INTERMEDIATE 7 5/8 6.875 26.3 7,493.0 3.808.4 29.70 L-80 BTCM Casing Description OD (in) ID (in) Top (ftKB) Set Depth (ftKB) Set Depth (TVD)... WVLen (I... Grade Top Thread B LINER LEM 41/2 3,860 6,198.0 6,704.9 3,680.9 12.60 L80 IBT-SCC CONDUCTOR; 30.0.108.0 Liner Details Nominal ID Top IRKS) Top (TVD) (ft(B) Top Incl (°) Item Des Core (In) 6,198.0 3,573.9 81.03 PACKER 7-5/8" x 5-1/2" ZXP liner top packer 4.970 6,217.0 3,576.9 80.87 SBR Casing Seal Bare Receptacle 4.750 6,236.7 3,580.0 80.58 XO BUSHING Cross Over Bushing 3.960 6,520.3 3,638.1 76.47 HANGER LEM (above hook hanger) 3.688 SURFACE; 26.0-3,009.0- 6,530.9 3,640.6 76.26 HANGER LEM (inside hook hanger) 3.688 6,626.0 3,663.9 76.47 NIPPLE DB-6 Nipple 3.563 ESP MANDREL; 3,414.5 6,658.4 3,671.2 77.38 BENT JT Bent Joint 3.860 6,701.E 1 3,680.3 78.36 SEAL ASSY Seal assembly 3.860 ESP MANDREL; 4,980.5 Casing Description OD (in) ID (in) Top (ftKB) Set Depth (ftKB) D).VLen Set Depth (TV.. W(I... Gratle Top Thread B LINER HH 41/2 4.000 6,530 91 6,79771 3,698.71 11.60 L80 BTC I Liner Details DISCHARGE; 5,371.8 - Top (ftKB) Top (TVD) (ftKB) Top Inel (°) Item Des Core Nominal ID (in) 6,530.9 3,640.6 76.26 HANGER Hook Hanger (below window) 5.610 6,608.9 3,659.8 75.98 ECP External Casing Packer 3.900 INTAKE; 5,448.4 I SEAL; 5,458.E 6,767.6 3,693.0 79.11 BENT JT Bent joint w/ muleshoe 3.960 MOTOR; 5,472.6 Casing Description OD (in) ID (in) Top (ftKB) Set Depth (ftKB) Set Depth (TVD)... WVLen (1... Grade Top Thread GAUGE; 5,506.5 DLINER HH 41/2 3.47E Q533.2 6,797.7 3,698.7 11.60 L-80 BTCM CENTRALIZER; 5,508.8 Liner Details Nominal ID Top (ftKB) Top (TVD) (ftKB) Top Inc[ (°) Item Des Core (i n) 6,533.2 3,641.1 76.21 HANGER BAKER MODEL PZ HOOK HANGER (INSIDE CSG) 3.950 _ 6,550.0 3,645.2 75.88 HANGER BAKER MODEL PZ HOOK HANGER (OUTSIDE 3.950 CSG) 6,607.1 3,659.4 75.93 ECP BAKER PZ EXTERNAL CASING PACKER 3.900 6,769A 3,693A 79.12 BENTJT 3.960 Casing Description OD (in) ID (in) Top (ftKB) Set Depth (ftKB) Set Depth (TVD)... WVLen (I Grade Top Thread A -SAND LINER 4 112 3.476 6,652.0 13,708.0 3,909.9 11.60 L-80 Buttress Thread Liner Details Nominal ID Top (ftKB) Top (TVD) (ftKB) Top [net (°) Item Des Co. (in) 6,652.0 3,669.8 77.20 PACKER BKER HRD ZXP LINER TOP PACKER 5.500 6,671.0 3,674.0 77.74 NIPPLE 'RS' PACKOFF SEAL NIPPLE 4.870 6,673.9 3,674.6 77,82 HANGER FLEX -LOCK LINER HANGER 4.850 6,683.8 3,676.6 78.04 SBE 190-47 SEAL BORE EXTENSION 4.750 Tubing Strings Tubing Description String Ma... ID (in) Top (ftKB) Set Depth (ft. Sel Depth (TVD) (... Wt (Iblft) Grade Top Connection TUBING 41/2 3958 21.9 5.510.8 3.360.0 12.60 L-80 IBTM Completion Details Nominal ID Top (ftKB) Top (TVD) (ftKB) I Top Met V) Item Des Core (in) _ 21.9 21.91 0.00 HANGER Vetco Gray 11 "x 4-1/2" Hgr w/ 4.909" MCA Top Conn. 4.409 - 5,371.8 3,300.5 64,59 DISCHARGE A -Well Discharge Sub 3.833 5,448.4 3,333.4 64.62 INTAKE TTC Crossoverw/ Screen Intake (5.13" O.D.) 0.000 5,458.8 3,337.8 64.64 SEAL Tandem Seal Section GSB 3 DB AB/HSN PFSA (5.13" O. 0.000 B LINER LEM; 6,198.0$704.9 5,472.6 3,343.7 64.6E MOTOR Motor 418 HP KMHFER 2610 / 98 (5.62" O.D.) 0.000 5,506.5 3,358.2 64.71 GAUGE A -Well I pump guage (4.375" O.D.) 0.000 5,508.6 3,359.1 64.72 CENTRALIZE Motor Centralizer (5.85" O.D.) 4.500 R B LINER HH; 6.530.9-6,797.7 D LINER HH; 6,533.2-6,797.7 Perforations & Slots Shot Dens Top (TVD) St. (TVD) (shotslf SLOTS; 7,234.0-7,614.0 Top (ftKB) seen IRKS) (ftKB) (ftKB) Zone Date t) Type Core 7.234.0 7,614.0 3,777.7 3,817.3 WS A2, 1J- 10/26/2006 32.0 SLOTS ALL PERFS IN WELL: INTERMEDIATE; 26.3-7,493.0 115 Alternating solid/slotted pipe-0.125"x2.5" @ 4 circumferential adjacent SLOTS; 7,788.0-E,127 .0 _ _ rows, 3" centers staggered 18 deg, 3' non -slotted ends - 7,786.0 8,127.0 3,820.8 3,822.7 WS A2, 1J- 10/26/2006 32.0 SLOTS SLOTS; 8,382.0-11,770.0 _ _ 115 - 8,382.0 11,770.0 3,820.6 3,842.0 WS A2, 1J- 10/26/2006 32.0 SLOTS SLOTS; 12,157.0-12,546.0 - 115 - 12,157.0 12,546.0 3,864.3 3,888.7 WS A2, 1J- 10/26/2006 32.0 SLOTS 115 SLOTS; 12,719.0-13.360.0 12,719.0 13,360.0 3,893.6 3,909.3 WS A2, 1J- 10/26/2006 32.0 SLOTS - 115 13,533.0 13,664.0 3,905.1 3,907.6 WS A2, 1J- 10/26/2006 32.0 SLOTS SLOTS; 13,533.0-13,884D - 115 A -SAND LINER; 6,652.0- 13,708.0' KUP PROD 0 U-115 THE STATE GOVERNOR BILL WALKER Gary Targac CPF1 Dev. Supervisor ConocoPhillips Alaska, Inc. _ / n P.O. Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, West Sak Oil Pool, WSAK 1J-115 Sundry Number: 315-767 Dear Mr. Targac: Conservation Commission 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 www.aogcc.olaska.gov Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Cathy . Foerster Chair DATED this 3 f ay of December, 2015 Encl. • STATE OF ALASKA 0 ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 DEC 3 0 2015 UUM" 1. Type of Request: Abandon Plug Perforations Fracture Stimulate Repair Well F Operations Shutdown Suspend F Perforate Other Stimulate FPull Tubing F, Change Approved Program Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing f- Other: Convert to GAS LIFT F. 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. ' Exploratory Development r,,— • 206-122 3, Address: 6. API Number: Stratigraphic Service j P. 0. Box 100360, Anchorage, Alaska 99510 50-029-23320-00• 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? n/a Will planned perforations require a spacing exception? Yes -� No / WSAK 1 J-115 9. Property Designation (Lease Number): 10. Field/Pool(s): ADL 25661 and 25650 - Kuparuk River Field/West Sak Oil Pool . 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): 13,720' 3,911' 1270 none none Casing Length Size MD TVD Burst Collapse Structural Conductor 78' 20" 108' 108' Surface 2,983' 10 3/4 3,009' 2,214' Intermediate 7,467' 7 5/8 7,493' 3,804' Production Liner 7,056' 4 1/2 13,708' 3,910' Perforation Depth MD (ft): ✓ Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 7234-7614,7786-8127,8382- 3777-3817,3820-3823,3821- 41/2 L-80 5,511' 1177012157-12546,12719- 3842,3864-3889,3894- 13664 3908 Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): ZXP LINER TOP PACKER, BAKER HRD ZXP LINER TOP PACKER 6198=MD, 3573=TVD 6652+MD, 3670=TVD SSV: NONE 12. Attachments: Proposal Summary 0 Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory r- Stratigraphic F Development • Service 14. Estimated Date for 12/30/2015 15. Well Status after proposed work: Commencing Operations: OIL r • WINJ WDSPL Suspended GAS F_ WAG F GSTOR F_ SPLUG F'' 16. Verbal Approval: Date: Commission Representative: GINJ Op Shutdown Abandoned 17. 1 hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Contact Gary Targac Email Gary.Targac@cop.com Printed Name Gary Targac@265-6586 Title CPF1 Dev. Supervisor E-2Z3o I IS Signature Phone: 265-6586 Date COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 36--7 Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: Post Initial Injection MIT Req'd? Yes ❑ No Spacing Exception Required? Yes ❑ No Subsequent Form Required: l U — (i 4 APPROVED BY Approved by: C MMISSIONER THE COMMISSION Date: /Z� �. •-� it Fo Form 10-403 Revi d 11/21s %%*ft*cqa@pItVnW IlLyalid for 12 months from the date of amproval. VT-4 iz/3///�:" 4>YA a1h Attachments in Duplicate • 0 1J-115 CONVERT FROM ESP TO GAS LIFT PROPOSAL "1J-115 tri-lateral producer with 4-1/2" L-80 tubing was completed November 2006 in the West Sak D, B, and A sands. The well was originally completed with an electric submersible pump (ESP) set at 5,449' RKB. The motor recently failed on 12/5/2015, halting production and COPA converted the completion to gas lift by pulling the pump, a dummy valve, and a shear out valve. A gas lift valve was set at 3,415' RKB and an orifice valve was set at 4,981' RKB. COPA is seeking approval to utilize the current completion to gas lift the well at 1.5 MMcf/d at a stabilized pressure of 900 psi in order to bring the well online. This is to avoid needing a rig workover to pull the current assembly out of the well. The well passed an MIT -IA after the original completion was installed to 3000 psi on 10/11/2006. The kickoff pressure for the gas lift design is 1270 psi, but this would only be in the first 8 hours. Conoco`Phillips Alaska. Inc. I�III�R.PIFSTSF1C76116iri KUP �D �r Well Attribu Wellbore APUUWI Field Name Wellbore: 500292332000 WEST SAK PROD Comment H2S (ppm) Date Annotatioi o�ofi-.1s AM SSSV: NONE Last WO: U-115 rn 13,474.701 13, 32.201 11/28/2006 Vertical sc maac actual Annotation Depth (ftKB) End Date Annotation Last Mod By End Date Last Tag: Rev Reason: GLV C/O, PULLED ESP PUMP, pproven 5/7/2013 I SLIPSTOP,PACKOFF & TTC-ESP asing rings Casing Description OD (in) ID (in) Top (ftKB) Set Depth (ftKB) Set Depth (TVD)... WULen (I... Grade Top Thread CONDUCTOR 20 19.124 30.0 108.0 108.0 94.00 K-55 WELDED HANGER; 21.9 Casing Description OD (in) ID (in) Top (ftKB) Set Depth (ftKB) Set Depth (TVD)... WULen (L Grade Top Thread i. SURFACE 10 3/4 9.950 26.0 3,009.0 2,214.9 45.50 L-80 BTC Casing Description OD (in) ID (in) Top (ftKB) Set Depth (ftKB) Set Depth (TVD)... WULen g... Grade Top Thread INTERMEDIATE 75/8 6.875 26.3 7,493.0 3,808.4 29.70 L-80 BTCM Casing Description OD (in) ID (in) Top (ftKB) Set Depth (ftKB) Set Depth (TVD)... WULen (I... Grade Top Thread LINER LEM 4 112 3.860 6,198.0 6,704.9 3,680.9 12.60 L80 IBT-SCC CONDUCTOR30A-1080 yB Liner Details Nominal ID Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Com (in) 6,198.0 3,573.9 81.03 PACKER 7-5/8" x 5-1/2" ZXP liner top packer 4,970 6,217.0 3,576.9 80.87 SBR Casing Seal Bore Receptacle 4.750 6,236.7 3,580.0 80.58 XO BUSHING Cross Over Bushing 3.960 6,520.3 3,638.1 76.47 HANGER LEM (above hook hanger) 3.688 SURFACE; 26.0-3.0090- 6,$30.9 3,640.E 76.26 HANGER LEM (inside hook hanger) 3.688 ESP MANDREL3.4145 ', 6,626.0 3,663.9 76.47 NIPPLE DB-6 Nipple 3.563 6,658.4 3,671.2 77.38 BENTJT Bent Joint 3.860 6,701.E 3,680.3 78.3E SEAL ASSY Seal assembly 3.860 ESP MANDREL; 4,980.5 Casing Description OD (in) ID (in) Top (ftKB) Set Depth (ftKB) Set Depth (TVD)... WULen (I... Grade Top Thread B LINER HH 4 112 4,000 6,530.9 6,797.7 3,698.7 11.60 L80 BTC Liner Details Nominal ID DISCHARGE; 5,371.8 Top (ftKB) Top (TVD) (ftKB) Top Incl I-) Item Des Com (in) 6,530.9 3,640.6 76.26 HANGER Hook Hanger (below window) 5.610 6,608.9 3,659.8 75.98 ECP External Casing Packer 3.900 INTAKE; 5,448.4 SEAL; 5,458.E 6,767.6 3,693.0 79.11 BENT JT Bentjoint w/ muleshoe 3.960 MOTOR; 5,472.E Casing Description OD (in) ID (in) Top (ftKB) Set Depth (ftKB) Set Depth (TVD)... WULen (I... Grade Top Thread GAUGE; 5,506.5 D LINER 1- 4 1 22 3.47E 6,533.2 6,797.7 3,698.7 11.60 L-80 BTCM CENTRALIZER, 5,508E Liner Details Nominal ID Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Com (in) 6,533.2 3,641.1 76.21 HANGER BAKER MODEL PZ HOOK HANGER (INSIDE CSG) 3.950 ROW 6,550.0 3,645.2 75.88 HANGER BAKER MODEL PZ HOOK HANGER (OUTSIDE 3.950 CSG) 6,607.1 3,659.4 75.93 ECP BAKER PZ EXTERNAL CASING PACKER 3.900 6,769.4 3,693.4 79.12 BENT JT 3.960 Casing Description OD (in) ID (in) Top (ftKB) Set Depth (ftKB) Set Depth (TVD)... WULen (1... Grade Top Thread A -SAND LINER 4 112 3.47E 6,652.0 13,708.0 31909.9 11.60 L-80 Buttress Thread Liner Details Nominal ID Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Com (in) 6,652.0 3,669.8 77.20 PACKER BKER HRD ZXP LINER TOP PACKER 5.500 6,671.0 3,674.0 77.74 NIPPLE 'RS' PACKOFF SEAL NIPPLE 4.870 6,673.9 3,674.6 77.82 HANGER FLEX -LOCK LINER HANGER 4.850 6,683.8 3,676.6 78.04 SBE 190-47 SEAL BORE EXTENSION 4.750 Tubing Strings Tubing Description String Ma... ID (in) Top (ftKB) Set Depth (R. Set Depth (TVD) (... Wt (Ib/tQ Grade Top Connection TUBING 41/2 3.958 21.9 5,510.8 3,360.6 12.60 L-80 IBTM Completion Details Nominal ID Top (ftKB) Top (TVD) (ftKB) I Top Incl V) Item Des Com (in) 21.9 21.9 0.00 HANGER Vetco Gray 11"x 4-1/2" Hgr w/ 4.909" MCA Top Conn. 4.409 5,371.8 3,300.5 64.59 DISCHARGE A -Well Discharge Sub 3.833 5,448.4 3,333.4 64.62 INTAKE TTC Crossover w/ Screen Intake (5.13" O.D.) 0.000 B LINER LEM, 6,198.06,704.9 5,458.8 3,337.8 64.64 SEAL Tandem Seal Section GSB 3 DB AB/HSN PFSA (5.13" 0. 0.000 5,472.6 3,343.7 64.66 MOTOR Motor 418 HP KMHFER 2610 / 98 (5.62" O.D.) 0.000 5,506,5 3,358.2 1 64.71 GAUGE A -Well I pump guage (4.375" O.D.) 0.000 5,508.6 3,359.1 64.72 CENTRALIZE Motor Centralizer (5.85" O.D.) 4.500 R 1 I B LINER HH; fi 530. 96,797.7 Periorations �w�� SiPts aT D LINER HH', 6.533.2-6,797.7 Shot Den Top (TVD) Elm (TVD) (shots/ SLOTS', 7,2340-7,6140- Top (ftKB) B[m(ftKB) (ftKB) (ftKB) Zone Date ft) Type Com 7,234.0 7,614.0 3,777.7 3,817.3 WS A2, 1J- 10/26/2006 32.0 SLOTS ALL PERFS IN WELL: INTERMEDIATE; 26.3-7,493.0 115 Alternating solid/slotted -� pipe -0.125"x2.5"@4 circumferential adjacent SLOTS; 7,7860-8.1270 rows, 3" centers - - staggered 18 deg, 3' non -slotted ends SLOTS; 8,382.0-11n0 0 - 7,786.0 8,127.0 3,820.8 3,822.7 WS 115 A2, 1J- 10/26/2006 32.0 SLOTS 8,382.0 11,770.0 3,820.6 3,842.0 WS A2, 1J- 10/26/2006 32.0 SLOTS 43LOTs; 12,157.0-12.5460 _ 115 12,157.0 12,546.0 3,864.3 3,888.7 WS A2, 1J- 10/26/2006 32.0 SLOTS - 115 SLOTS, 12,719.0-13,360.0 - _ 12,719.0 13,360.0 3,893.6 3,909.3 WS A2, 1J- 10/26/2006 32.0 SLOTS 115 SLOTS, 13,533.0-13,664.0 13,533.0 13,664.0 3,905.1 3,907.6 WS A2, 1J- 10/26/2006 32.0 SLOTS A -SAND LINER, 6,652.0- 13,708.0' " 115 • 0 Loepp, Victoria T (DOA) From: Targac, Gary <Gary.Targac@conocophillips.com> Sent: Wednesday, December 30, 2015 4:08 PM To: Loepp, Victoria T (DOA) Subject: RE: West Sak 1J-115(PTD 206-122) Report of failed ESP Victoria, here's what Brent had in the database for 12/12/15: GAS MIT -IA Passed. Initial TWO = sil35/280/35. T FL @ 1290'. IA FL @ 3755'. OA FL near surface (bled 10 psi of OA checking FL). Pressurized IA to 535 psi w/ AL in 10 min, TWO = 140/535/25. T FL @ 1218'. IA FL @ 3809'. 15 min T/I/O = 140/525/25. T FL 1248'. IA FL @ 3834'. Pressurized IA to 685 psi w/ AL in 10 min. T/I/O = 145/685/25. T FL @ 1218'. IA FL @ 4735'. 15 min T/1/0 = 140/680/25. T FL @ 1248'. IA FL @ 4769'. Pressurized IA to 730 psi w/ AL in 5 min. T/I/O = 150/730/25. T FL @ 1164'. IA FL @ 5219'. 15 min T/1/0 = 170/705/25. T FL @ 1044'. IA FL @ 5113'. 30 min T/l/O = 170/690/25. T FL @ 1020'. IA FL @ 5053'. Pressurized IA to 740 psi w/ AL in 5 min. TWO = 185/740/25. T FL @ 948'. IA FL @ 5310'. 15 min TWO = 230/705/25. T FL @ 798'. IA FL @ 5125'. IA pressure is passing through OV increasing T psi @ an extremely slow rate, swapped AL to T to speed up equalization rate. Pressurized T to 550 psi w/ AL in 15 min. TWO = 550/705/25. T FL @ 3550'. IA FL @ 5033'. 15 min T/l/O = 550/700/25. T FL @ 3798'. IA FL @ 5066'. Pressurized T to 700 psi w/ AL in 15 min. TWO = 700/705/25. T FL @ 4698'. IA FL @ 5040'. 15 min TWO = 690/705/25. T FL @ 4709'. IA FL @ 5060'. Pressurized T to 760 psi w/ AL in 10 min. TWO = 760/710/25. T FL @ 5342'. IA FL @ 4981' (ov). 15 min TWO = 755/705/25. T FL unchanged. IA FL @ 5073'. Swapped back to IA. Pressurized IA to 815 psi w/ AL in 10 min. TWO = 815/815/25. T FL @ 5795'. IA FL @ 5795'. 15 min TWO = 805/805/25. T FL @ 5847'. IA FL @ 5847'. 30 min TWO = 800/805/25. T FL unchanged. IA FL unchanged. 45 min T/1/0 = 800/805/25. T FL unchanged. IA FL unchanged. 60 min T/I/O = 800/805/25. T FL unchanged. IA FL unchanged. OA FL remained near surface through the job. Final T/l/O = si800/805/25. On 12/13/15: T/I/0= si800/800/25 T-FL @ 5911' IA -FL @ 5911' Let me know if you need anything else. From: Loepp, Victoria T (DOA) [mailto:victoria.loepp(abalaska.gov) Sent: Wednesday, December 30, 2015 3:46 PM To: Targac, Gary Subject: [EXTERNAL]RE: West Sak 1J-115(PTD 206-122) Report of failed ESP Brent said there was a gas MIT done recently up to a certain pressure. Do you have the results of that recent MIT? From: Targac, Gary [mailto:Gary.Targac()conocophillins com] Sent: Wednesday, December 30, 2015 9:16 AM To: Loepp, Victoria T (DOA); Schwartz, Guy L (DOA) Cc: Kanady, Randall B Subject: RE: West Sak 13-115(PTD 206-122) Report of failed ESP Ok, thx Victoria. Yes, same well. Tough to track down over the holidays with people out but I'm working on getting the 403 to you today. Gary From: Loepp, Victoria T (DOA) [mailto:victoria.loepp(abalaska.gov] Sent: Wednesday, December 30, 2015 9:04 AM To: Targac, Gary Cc: Schwartz, Guy L (DOA) • • Subject: [EXTERNAL]FW: West Sak 13-115(PTD 206-122) Report of failed ESP This is the email I sent a couple of weeks ago requesting a 10-403 for conversion from ESP to gas lift. Is this the same well you were inquiring about today Gary? From: Loepp, Victoria T (DOA) Sent: Wednesday, December 16, 2015 10:53 AM To: 'NSK Problem Well Supv' Subject: RE: West Sak 13-115(PTD 206-122) Report of failed ESP Brent, Please submit a 10-403 to include the gas MIT performed, anticipated lift pressure and TIO info as well as WBS and well history. Thanx, Victoria From: NSK Problem Well Supv[mailto:nl617(a)conocophillips.com] Sent: Friday, December 11, 2015 11:22 AM To: Schwartz, Guy L (DOA); Loepp, Victoria T (DOA) Cc: NSK Problem Well Supv; NSK West Sak Prod Engr; NSK Prod Engr Specialist Subject: West Sak 13-115(PTD 206-122) Report of failed ESP Victoria, Guy West Sak Packerless ESP producer 1J-115(PTD 206-122) has experienced a failed ESP motor. The ESP motor grounded out and failed which will require a RWO to repair. The plan forward while awaiting the repair is to put the well back on production with gaslift. An OV will be installed in the mandrel at 4981' and that is intended to be the lift point. Looking through the PTD I could not find where a gaslift backup was mentioned as in some of the others. Is a 10-404 sufficient for the change in lift service or does a 10-403 need to be submitted? Please advise as to the appropriate paperwork required. Attached is a 90 day TIO plot and wellbore schematic for reference. Please let me know if you have any questions. TIIIO Plot-1J-115 25D 200 150 ro IL 10� 53 r 12-Sep-15 25-Sep-15 08-Oct-15 21-Oct-15 O3-Nov-15 16-Nov-15 29-Nov-15 Date Brent Rogers / Kelly Lyons Problem Wells Supervisor ConocoPhillips Alaska, Inc. Desk Phone (907) 659-7224 Pager (907) 659-7000 pgr. 909 • • Image Project Well History File Cover Page XFiVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. _0(- ]CI -a Well History File Identifier Organizing (done) 7ANor Items: ❑ Greyscale Items: ❑ Poor Quality Originals: ❑ Other: NOTES: 0,.o.,,ae iuuiimiiuiuii DI TsAL DATA Dikettes, No. 5 ❑ Other, No/Type: Re,<a„Neede, Illllllllflllllllll OVERSIZED (Scannable) ❑ Maps: ❑ Other Items Scannable by a Large Scanner OVERSIZED (Non -Scannable) ❑ Logs of various kinds: ❑ Other:: BY: Maria Date: /s/ Project Proofing III IIIII IIIII IIIII BY: Maria Date: /s/ Scanning Preparation x 30 = + TOTAL PAGES_ (Count does not include cover sheet) BY: Maria J2 Date: 1 , �C /s/ Production Scanning Stage 9 Page Count from Scanned File: (Count does include cover sheet) Page Count Matches Number in Scanning Preparation: ,YES NO BY: Maria Date: ! 1 �/07 /s/ IMP Stage 1 If NO in stage 1, page(s) discrepancies were found: YES NO BY: Maria Date: /s/ Scanning is complete at this point unless rescanning is required. II I II �I (I I I' II I (III ReScanned III IIIIIIIIIII IIIII BY: Maria Date: /s/ Comments about this file: Quality Checked III IIIII III II'I II 10/6/2005 Well History File Cover Page.doc MICROFILMED 6/30/2010 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE C:\temp\Temporary Internet Files\OLK9\Microfilm_Marker.doc DATA SUBMITTAL COMPLIANCE REPORT 10/13/2008 Permit to Drill 2061220 Well Name/No. KUPARUK RIV U WSAK 1J-115 Operator CONOCOPHILLIPS ALASKA INC API No. 50-029-23320-00-00 MD 13720 TVD 3910 Completion Date 11/28/2006 Completion Status 1-OIL Current Status 1-OIL UIC N REQUIRED INFORMATION Mud Log No Samples No Directional Survey Yes DATA INFORMATION Types Electric or Other Logs Run: GR/Res, Dens/Neu (data taken from Logs Portion of Master Well Data Maint Well Log Information: Log/ Electr Data Digital Dataset Log Log Run Interval OH / Type Med/Frmt Number Name Scale Media No Start Stop CH Received Comments og Sonic 5 Col 1 10 2410 Open 10/25/2006 USIT, GR, CCL 17-Oct- 2006 '��`E11D D Asc Directional Survey 12466 13720 Open 1/29/2007 QED D Asc Directional Survey 28 8405 Open 1/29/2007 PB 1 D Asc Directional Survey 7985 8405 Open 1/29/2007 PB 2 D D Asc Directional Surrey 8826 12018 Open 1/29/2007 PB 3 �ED D Asc Directional Survey 11626 12829 Open 1/29/2007 PB 4 C Lis 14507 Induction/Resistivity 0 0 Open 3/16/2007 LIS VERI for 206-122 - 206- 124 (L1 and L2) with multiple plugbacks t 14507 LIS Verification 2993 13720 Open 3/21/2007 LIS Veri GR, ROP, FET f(pt 14507 LIS Verification 2993 8405 Open 3/21/2007 P131 LIS Veri GR, ROP, FET Rpt 14507 LIS Verification 2993 9190 Open 3/21/2007 P132 LIS Veri GR, ROP, FET 1pt 14507 LIS Verification 2993 12018 Open 3/21/2007 PB3 LIS Veri GR, ROP, FET Rpt 14507 LIS Verification 2993 12829 Open 3/21/2007 PB4 LIS Veri GR, ROP, FET (pH' C 15864 Gamma Ray 108 13720 Open 1/31/2008 MD and TVD for EWR in PDF, EMF CGM graphics 'ED C 15865 Gamma Ray 108 8405 Open 1/31/2008 PB1 MD and TVD for EWR, ROP, DGR in PDF, EMF, CGM graphics 'ED C 15866 Gamma Ray 108 8405 Open 1/31/2008 P132 MD and TVD for EWR, ROP, DGR in PDF, EMF, CGM graphics DATA SUBMITTAL COMPLIANCE REPORT 10/13/2008 Permit to Drill 2061220 Well Name/No. KUPARUK RIV U WSAK 1J-115 Operator CONOCOPHILLIPS ALASKA INC API No. 50-029-23320-00-00 MD 13720 TVD 3910 Completion Date 11/28/2006 Completion Status 1-OIL Current Status 1-OIL UIC N C 15867 Gamma Ray 108 12018 Open 1/31/2008 P133 MD and TVD for EWR, ROP, DGR in PDF, / EMF, CGM graphics tI C 15868 Gamma Ray 108 12829 Open 1/31/2008 PB4 MD and TVD for EWR, ROP, DGR in PDF, EMF, CGM graphics Well Cores/Samples Information: Sample Interval Set Name Start Stop Sent Received Number Comments ADDITIONAL INFORMATION Well Cored? Y / ql Daily History Received? Chips Received? Y_ Formation Tops N Analysis Received? Comments: Compliance Reviewed By: Date: 40 • ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 Sept 6, 2008 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7tn Avenue, Suite 100 Anchorage, AK 99501 Dear Mr. Maunder: ate''`a- � Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRU). Each of these wells was found to have a void in the conductor. These voids were filled with cement if needed and corrosion inhibitor, engineered to prevent water from entering the annular space. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treatments took place and meets the requirements of form 10-404, Report of Sundry Operations. The cement was pumped August 28th, 2008. The corrosion inhibitor/sealant was pumped August 29th, Sept 5-6t",2008. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please call MJ Loveland or Perry Klein at 907-659-7043, if you have any questions. Sincerely, Perry Klei ConocoPhillips Well Integrity Projects Supervisor ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top -off Report of Sundry Operations (10404) Kuparuk Field Date 9/6/2008 Well Name PTD # Initial top of cement Vol. of cement pumped Final top of cement Cement top off date Corrosion inhibitor Corrosion inhibitor/ sealant date ft bbls ft gal 1A-17 190-151 SF NA SF NA 2.55 8/29/2008 1A-18 190-153 21' 2.80 27" 8/28/2008 1A-20 190-162 21' 2.80 25" 8/28/2008 7.65 8/29/2008 1A-25 190-167 14' 1.90 25" 8/28/2008 7.65 8/29/2008 1J-101 205-182 6" NA 6" NA 1.28 9/5/2008 1J-102 206-110 7" NA 7" NA 1.70 9/5/2008 1J-103 206-114 7" NA 7" NA 1.28 9/5/2008 1 J-105 207-027 1 8" NA 8" NA 1.28 9/5/2008 1J-107 207-107 7" NA 7" NA 1.28 9/5/2008 1J-109 206-050 14" NA 14" NA 8.08 9/5/2008 1J-115 206-122 10" NA 10" NA 2.55 9/5/2008 1J-118 206-176 5" NA 5" NA 6.80 9/5/2008 1 J-120 1 207-045 4" NA 4" NA 2.55 9/5/2008 1 J-127 206-047 6" NA 6" NA 1.70 9/5/2008 1 J-135 207-038 8" NA 8" NA 1.70 9/6/2008 1J-136 206-154 9" NA 9" NA 1.70 9/6/2008 1J-137 206-108 12" NA 12" NA 5.10 9/6/2008 1 J-154 205-035 4" NA 4" NA 4.67 9/6/2008 1 J-156 206-067 8" NA 8" NA 5.95 9/6/2008 1 J-159 206-005 20" NA 20" NA 14.87 9/6/2008 1J-160 207-015 20" NA 20" NA 7.23 9/6/2008 1J-164 205-144 20" NA 20" NA 11.90 9/6/2008 1 J-176 207-099 6" NA 6" NA 1.28 9/6/2008 1J-184 206-044 1 8" 1 NA 8" 1 NA 1 1.28 1 9/6/2008 -• 0 WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Ceresa Tolley 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: MWD Formation Evaluation Logs 1J-115 January 18, 2008 AK-MW-4650390 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Rob Kalish, Sperry Drilling Services, 6900 Arctic Blvd., Anchorage, AK 99518 1J-115+PB1+PB2+PB3+PB4+L1+L1PB1+L1PB2+L2+L2PB1+L2PB2: Digital Log Images 1 CD Rom 50-029-23320-00,60,61,70,71,72,73,74,75,76,77 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry Drilling Services Attn: Rob Kalish 6900 "Ivd.l �' Anch'o�a , *191k 8- AN Date: r 3 Signed: '96Co - lag I" J 56(- << p�3 # 1 S`a Cod p-3 l #- t 5-t%ko 006-12,11 �a 15N 73 11 WELL LOG TRANSMITTAL To: State of Alaska February 26, 2007 Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West 71h Avenue, Suite 100 Anchorage, Alaska RE: MWD Formation Evaluation Logs: 1J-115 PB1 PB2 PB3 PB4 Ll PB1 L1 PB2 Ll L2 PB1 L2 PB2 L2, AK-MW-4528227 1 LDWG formatted CD Rom with verification listing. APl#: 50-029-23320-00, 70, 71, 72, 73, 74, 75, 60, 76, 77, 61 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry Drilling Services Attn: Rob Kalish 6900 Arctic Blvd. Anchorage, Alaska 99518 ��R 6 2n017 � : j �J p sy Date: Signed: 06(40 -- t D -� 14l s-&�- 0o(�-i3y /Zq( - 1 Randy Thomas Kuparuk Drilling Team Leader Drilling & Wells P. O. Box 100360 Anchorage, AK 99510-0360 Conocn-& Phi I I i ps Phone: 907-265-6830 January 10, 2007 Commissioner State of Alaska �V ED Alaska Oil & Gas Conservation Commission ;AN 1 ��/ 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501� Ancharne Subject: Well Completion Reports for 1 J-115, 1 J-115L1 and 1 J-1151-2 Dear Commissioner: ConocoPhillips Alaska, Inc. submits the attached Well Completion Reports for the recent drilling operations on the West Sak wells 1J-115, 1J-115L1, 1J-115L2. If you have any questions regarding this matter, please contact me at 265-6830 or Mike Greener at 263-4820. Sincerely, R. Thomas' Kuparuk Drilling Team Leader CPAI Drilling RT/skad 0 STATE OF ALASKA 9 ALASKA OIL AND GAS CONSERVATION COMMISSION 12007 WELL COMPLETION OR RECOMPLETION REPORTIAN 4109 commission 1a. Well Status: Oil a Gas Li Plugged Abandoned Lj Suspended ❑ WAG ❑ 20AAC 25.105 20AAC 25.110 GINJ ❑ WINJ ❑ WDSPL ❑ No. of Completions _ Other, 1b. Well Class:v 2aF(1 al Development Q exploratory ❑ Service ❑ Stratigraphic Test El 2. Operator Name: ConocoPhillips Alaska, Inc. 5. Date Comp., Susp., orAband.: November 28, 2006 12. Permit to Drill Number: 206-122 / 3. Address: P. O. Box 100360, Anchorage, AK 99510-0360 6. Date Spudded: October 2, 2006 ' 13. API Number: 50-029-23320-00 ' 4a. Location of Well (Governmental Section): Surface: 1973' FSL, 2380' FEL, Sec. 35, T1IN, R10E, UM At Top Productive Horizon: 871' FNL, 928' FWL, Sec. 36, T11N, R10E, UM Total Depth: 96' FSL, 639' FWL, Sec. 24, T11 N, R10E, UM 7. Date TD Reached: October 25, 2006 y 14. Well Name and Number: 1 J-115 8. KB Elevation (ft): 28' RKB 15. Field/Pool(s): Kuparuk River Field West Sak Oil Pool 9. Plug Back Depth (MD + TVD): 13708' MD / 3908' TVD 4b. Location of Well (State Base Plane Coordinates): Surface: x- 558830 y- 5945785 Zone-4 TPI: x- 562116 y- 5948248 Zone-4 Total Depth: x- 561771 - - 5954491 Zone-4 10. Total Depth (MD + TVD): • 13720' MD / 3910' TVD 16. Property Designation: ADL 25661 & 25650 11. Depth where SSSV set: none 17. Land Use Permit: ALK 471, 468 18. Directional Survey: Yes ❑✓ No ❑ 19. Water Depth, if Offshore: N/A feet MSL 20. Thickness of Permafrost: 2267' MD 21.Logs Run: GR/Res, Dens/Neu 22. CASING, LINER AND CEMENTING RECORD CASING SIZE WT. PER FT. GRADE SETTING DEPTH MD SETTING DEPTH TVD HOLE SIZE CEMENTING RECORD AMOUNT PULLED TOP BOTTOM TOP BOTTOM 20" 94# K-55 28' 110, 28' 110, 42" 260 cf ArcticCRETE 10.75" 45.5# L-80 28' 3010' 28' 2215' 13.5" 534 sx AS Lite, 274 sx DeepCrete 7-5/8" 29.7# L-80 28' 7493' 28' 3808' 9-7/8" 446 sx Class G 4,5" 11.6# L-80 6652' 13708' 3675' 3908' 1 6.75" Islotted liner - refer to attachment for details 23. Perforations open to Production (MD + TVD of Top and Bottom Interval, Size and Number; if none, state "none"): slotted liner from 7234'-7614', 7786'-8127', 8382'-11770', 12157'-12546', 12719'-13360', 13533'-13664' 24. TUBING RECORD SIZE DEPTH SET (MD) PACKER SET 4.5" 5448' 6652' 25. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED n/a 26. PRODUCTION TEST Date First Production December 29, 2006 Method of Operation (Flowing, gas lift, etc.) ESP Lift Oil Producer - shares production with 1 J-1151-1 and 1 J-115L2 Date of Test 1/6/2007 Hours Tested 24 hours Production for Test Period --> OIL-BBL 2577 GAS-MCF 1272 WATER-BBL 70 CHOKE SIZE 100% GAS -OIL RATIO 494 Flow Tubing press. 234 psi Casing Pressure not available Calculated 24-Hour Rate -> OIL-BBL 2711 GAS-MCF 1198 WATER-BBL 70 OIL GRAVITY - API (corr) not available 27. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water (attach separate sheet, if necessary). Submit core chips; if none, state "none". NONE //• Z$•pG Form 10-407 Revised 12/2003 �„ � �.. CONTINUED ON REVERSE / a�• % i a ,♦ f -1 28. 29. VW GEOLOGIC MARKERS FORMATION TESTS NAME MD TVD Include and briefly summarize test results. List intervals tested, and attach detailed supporting data as necessary. If no tests were conducted, state "None". 1 J-115 Top West Salk A2 7451' 3805' Base West Sak A2 13720' 3910' 1 J-115PB1 TD 8404' 3828' N/A 1J-115PI32 TD 9190, 3813' 1 J-115PB3 TD 12018' 3844' 1J-115PB4 TD 12829' 3896' 30. LIST OF ATTACHMENTS Summary of Daily Operations, Directional Survey 31. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Mike Greener @ 263-4820 Printed Nam Randy Thomas Title: Greater Kuparuk Area Drilling Team Leader Signature t Phone 7"6 S- 64 3 iD Date 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 la: Classification of Service wells: Gas injection, water injection, Water -Alternating -Gas Injection, salt water disposal, water supply for injection, observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 4b: TPI (Top of Producing Interval). Item 8: the Kelly Bushing elevation in feet abour mean low low water. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). Item 20: True vertical thickness. Item 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, Other (explain). Item 27: If no cores taken, indicate "none". Item 29: List all test information. If none, state "None". Form 10-407 Revised 12/2003 1J-115'A2' Sand Liner Detail well: 1J-115 4-112" Slotted and Blank Liner Date: 10/26/2006 Ct?ii"1t1;3coPhilli ; s Alaska, Inc. DEPTH Jt Number Num of Jts COMPLETE DESCRIPTION OF EQUIPMENT RUN Page 1 LENGTH TOPS 6652.01 6652.01 6652.01 6652.01 >< - 4" DP to Surface =_> 6652.01 XO 3 1/2 IF x 4" HT 39 T 6652.01 Baker Liner setting tool with pup jt 6652.01 5.5"x 7.63" Baker "HRD" ZXP Liner Top Pkr 19.03 6652.01 "RS" Packoff Seal Nipple, 6.07" OD / 4.87" ID 2.84 6671.04 5.5" X 7.63" "Flex -Lock" Liner Hgr, 6.59" OD/ 4.85" ID 9.89 6673.88 190-47 Seal Bore Ext, 6.29" OD / 4.75" ID 19.41 6683.77 XO Sub 5.5"Hyd 563 X 4.5", BTC 5.99"OD X 3.94" ID 1.44 6703.18 4 1/2" Pup Jt, 12.6 ppf, L-80 3.78 6704.62 Jts 151 to 163 13 Jts 4-1/2" BTC 11.6 ppf, L-80 Casing `(Blanks) 526.02 6708.40 Jts 142 to 150 9 AS 4-1/2" BTC 11.6 ppf, L-80 Slotted Casing 379.29 7234.42 Jts 138to 141 4 As 4-1/2" BTC 11.6 ppf, L-80 Casing *(Blanks) 171.88 7613.71 Jts 130 to 137 8 As 4-1/2" BTC 11.6 ppf, L-80 Slotted Casing 341.62 7785.59 Jts 124 to 129 6 Jts 4-1/2" BTC 11.6 ppf, L-80 Casing *(Blanks) 255.21 8127.21 Jts 45 to 123 79 Jts 4-1/2" BTC 11.6 ppf, L-80 Slotted Casing 3387.67 8382.42 Jts 36 to 44 9 Jts 4-1/2" BTC 11.6 ppf, L-80 Casing *(Blanks) 387.23 11770.09 Jts 27 to 35 9 Jts 4-1/2" BTC 11.6 ppf, L-80 Slotted Casing 388.96 12157.32 Jts 23 to 26 4 As 4-1/2" BTC 11.6 ppf, L-80 Casing *(Blanks) 173.19 12546.28 Jts 8 to 22 15 As 4-1/2" BTC 11.6 ppf, L-80 Slotted Casing 640.47 12719.47 Jts 4 to 7 4 Jts 4-1/2" BTC 11.6 ppf, L-80 Casing *(Blanks) 173.51 13359.94 Jts 1 to 3 3 Jts 4-1/2" BTC 11.6 ppf, L-80 Slotted Casing 130.11 13533.45 4-1/2" BTC 11.6 ppf, L-80 Casing *(Blanks) 43.13 13663.56 4 1/2" Silver Bullet Shoe 1.31 13706.69 END OF SHOE ==> 13708.00 TD 6-3/4" hole @ 13,720.' MD / 3910.' TVD (87.28 deg.) Shoe @ 13,708. MD TVD 3908.' ( 87.28 deg) Had to rotate liner last 32' dn. Run 1 spiro liner per jt. Put stop ring in middle of jt with the centrailizer floating on the bttm half of joint. on joints #2 thru Jts #150 & 1 on Jt # 154, # 160 = 162 total We will run torque rings in the TOP 4000' of the liner. Joint # 69 thru Jt# 163 - Start rings @ # 69 everything after that gets a torque. Ran total of 41 its Blank= 1730.17' and 123 'ts Slotted= 5268.12 ', Slots are 0.125" w Up Wt 190K w/ 32 2.5" long x .125" @ 4 Circumferential adjacent rows, 3" Centers Dn Wt OK staggered 18 deg., 3 ft. non -slotted ends. Ran Constrictor packers @ 12,718' Block Wt 35K 12,534', 12,135', 11,781', 8375', 8134', 7786', & 7621' = 9 total Ran shoe joint slick. Torqued liner w/o torque rings to 3000 ft-lbs, w/ torque rings to 5200 ft/lbs Used Run-N-Seal thread compound on all connections. All drifted w/ 3.875" rabbit. Supervisors: D. Gladden / D. Heim / D. Hartwig 10/02/2006 08:45 11:30 2.75 0 223 SURFAC DRILL DRLG P Spud well @ 8:45 10-2-06=Clean out from 0' to 1 10'Drlg from 110' to223 MD ADT-1.95 P/U 45k Rot-45k S/0-45k. 11:30 12:00 0.50 223 223 SURFAC DRILL TRIP P POH to pick up MWD & Flex collars, 12:00 12:30 0.50 223 223 SURFAI DRILL PULD P Lay down float sub -pick up pre programed MWD & float orient -pick up UBHO sub. 12:30 13:00 0.50 223 223 SURFAC DRILL SFTY P PJSM=Hang sheave -pick up & rig up wireline Gyro survey equipment. 13:00 13:30 0.50 223 223 SURFAC DRILL TRIP P Pick up & run in hole w/ 3 (8" non mag flex collars 13:30 00:00 10.50 223 911 SURFAC DRILL DDRL P Drlg. from 223' to 911' MD (TVD 900') (WL Gyro surveys) Start build @ 439'. Ast-3 hrs. Art-2.93 hrs. P/U 76k S/O 75k Rot 75k Tq on 3-4k Off-1-2k. Max _ as 47 units. 10/03/2006 00:00 00:15 0.25 911 911 SURFAC DRILL SFTY P PJSM-Topic=Drlg. surface hole. 00:15 12:00 11.75 911 1,961 SURFAC DRILL DDRL P Drlg. from 911'to 1961' MD 1766' TVD ADT-8.78 AST-5.04 ART-3.74 P/U 92k S/O 80k ROT 85k TQ on 5k off 3k. 12:00 12:15 0.25 1,961 1,961 SURFAC DRILL SFTY P PJSM-Topic=DrIg surface hole & scrubbing. 12:15 23:30 11.25 1,961 3,020 SURFAC DRILL DDRL P Drlg. from 1961' to 3020' TD of surface hole. (TVD 2219') ART 4.47 hrs. AST-2.98 hrs. ADT 7.45 hrs. P/U 100k S/O 75k ROT 85k TQ on 6k off 4k Max Gas 1469 units. 23:30 00:00 0.50 3,020 3,020 SURFAC DRILL TRIP P BROOK for wiper trip. 10/04/2006 00:00 02:00 2.00 3,020 722 SURFAC DRILL TRIP P BROOH from 3020' to 722' @ 687 GPM 2050 psi 80 rpm P/U 110k S/O 73k. 02:00 02:45 0.75 722 3,020 SURFAC DRILL TRIP P RIH from 722' to 3020'. 02:45 04:45 2.00 3,020 3,020 SURFAC DRILL CIRC P Circulate & condition mud for csg. 04:45 07:00 2.25 3,020 725 SURFAC DRILL TRIP P POH from 3020' to 725'. 07:00 09:00 2.00 725 0 SURFAC DRILL PULD P Lay down BHA #1=XO-3 nmdc,s-UBHO sub -float sub-MPT w/ dir-NM pressure drop sub -stab -motor -bit. 09:00 09:30 0.50 0 0 SURFAC DRILL OTHR P Clear & clean rig floor. 09:30 10:00 0.50 0 0 SURFAC DRILL OTHR P Dummy run w/ hanger. 10:00 12:00 2.00 0 0 SURFAC CASIN( RURD P Rig up to run 10 3/4" Csg. 12:00 12:15 0.25 0 0 SURFAC CASIN( SFTY P PJSM-Topic=Running 10 3/4" Csg. 12:15 18:00 5.75 0 3,009 SURFAC CASIN( RNCS P Run 73 jts. & 19' pup of 10 3/4" 45.50# buttress csg. Fill every jt. wash @ 109'-1326 to 1350'. Circ. @ 1527'. Wash @ 1858-to 1920. Wash from 2919' to 3009 & land csg. I ■■r 1 18:00 18:30 18:30 19:15 19:15 21:00 21:00 100:00 00:00 00:45 00:45 01:45 01:45 05:30 05:30 06:30 06:30 08:00 08:00 12:00 12:00 13:00 13:00 115:00 15:00 16:45 16:45 17:30 17:30 18:30 18:30 21:15 21:15 22:30 22:30 23:30 23:30 00:00 )06 00:00 01:00 0.50 3,009 3,009 ISURFACCASIN( CIRC P JCBU @ 7.5 BPM 500 psi -reciprocate pipe 20'. 0.75 3,009 3,009 SURFAC CASIN( RURD P Lay down fill up tool -blow down top drive & make up cement head. 1.75 3,009 3,009 SURFAC CASIN( CIRC P Circ. & condition mud for cementing -reciprocate 20'. Hold PJSM while circ. 3.00 3,009 3,009 SURFAC CEMEI` DISP P Pump 10 bbl CW 1.00-test lines to 3500# ok-pump40 bbl CW 100 pump 50 bbls 10.5# mud push -drop bottom plug -pump 425 bbls 10.7 lead cement & 75 bbls 124 tail cement -drop top plug -pump 20 bbls water & displace w/ 261 bbls mud -cement returns 650 strokes into displacement-195 bbls cement returns -bumped plug on calculated strokes. floats held. Reciprocated 10-20' during cement 'ob. 0.75 3,009 3,009 SURFAC DRILL OTHR P Perform csg. test to 3000# chart same for 30 mins. 1.00 3,009 3,009 SURFAC DRILL OTHR P Flush riser & drain same -Lay down cs . & cementing equipment. 3.75 3,009 3,009 SURFAC DRILL RURD P Nipple down surface diverter. 1.00 3,009 3,009 SURFAC DRILL RURD P Nipple up & orient + test adapter sub 5000# for 10 mins. OK. 1.50 3,009 3,009 SURFAC DRILL RURD P Nipple up bope. 4.00 3,009 3,009 SURFAC DRILL OTHR P Test bope 250- 3000 OK. 1.00 3,009 3,009 SURFAC DRILL OTHR P PJSM=Pull test plug -set wear ring -blow down choke & lines -pick up short bails. 2.00 3,009 3,009 SURFAC DRILL PULD P RIH-pick up 30 its. 5" dp (Drift & clean threads)RIH w/ 3 stands HWDP-Lay down 9 its HWDP-stand back 10 stands 5" DP. 135 3,009 3,009 SURFAC DRILL PULD P Pick up BHA #2 & MWD tools. 0.75 3,009 3,009 SURFAC DRILL OTHR P Program MWD. 1.00 3,009 3,009 SURFAC DRILL PULD P Pick up & RIH 3 flex collars -jars & HWDP-shallow pulse test @ 445'. 2.75 3,009 3,009 SURFAC DRILL PULD P Continue run in hole picking up ghost reamer & 78 singles. Wash 2888 to 2917. 1.25 3,020 3,040 SURFAC DRILL DRLG P Drill float equipment cement & 20' new hole. 1.00 3,040 3,040 SURFAC DRILL OTHR T Trouble shoot MWD (Cycle pumps for mode switching. 0.50 3,040 3,040 SURFAC DRILL LOT P Rig up for LOT. 1.00 3,040 3,040 SURFAC DRILL LOT P Perform LOT (15.5 PPG) Rig down same. 10/06/2006 01:00 01:30 0.50 3,040 3,040 SURFAC DRILL DHEQ T Pump on MWD. Attempt to get Mwd working from failure prior to LOT. Flow check -pump pill & blow down top d rive. 01:30 02:45 1.25 3,040 449 INTRMI DRILL TRIP T POH from 3040' to 449'. 02:45 03:15 0.50 449 0 INTRM1 DRILL TRIP T Rack back HWDP-Jars & NMDC,S 03:15 03:45 0.50 0 0 INTRM1 DRILL OTHR T Down load MWD. 03:45 04:15 0.50 0 0 INTRMI DRILL PULD T Lay down TM HOC, RLL w/ DGR+ EWR, DM NM HOC 04:15 04:45 0.50 0 0 INTRM1 DRILL PULD T Pick up DM NM,HOC,RLLw/ DGR+EWR,TM HOC=BHA #3. 04:45 05:15 0.50 0 0 INTRM1 DRILL OTHR T UP load MWD. 05:15 05:45 0.50 0 449 INTRM1 DRILL TRIP T RIH w/ NMDC,s & HWDP. 05:45 06:00 0.25 449 449 INTRM1 DRILL DHEQ T Shallow test MWD. 06:00 07:00 1.00 449 3,040 INTRM1 DRILL TRIP T RIH-wash & ream 3015' to 3040'. No fill. 07:00 12:00 5.00 3,040 3,582 INTRM1 DRILL DDRL P Drlg. from 3040' to 3582'. TVD 2487'. ART 1.14 AST 1.77 ADT 2.91 hrs. P/U 112k S/O 75k RT 87k TQ 6k. 12:00 12:15 0.25 3,582 3,582 INTRM1 DRILL SFTY P PJSM-Topic=Connections. 12:15 00:00 11.75 3,582 4,817 INTRM1 DRILL DDRL P Drlg. from 3582' to 4817' MD. TVD=3054'. ART-2.79 AST-5.0 ADT-7.79 hrs. P/U-145k S/0-77k RT-97k TQ-5k ECD-10.01 Max gas-67 units. 10/07/2006 00:00 02:00 200 4,817 5,008 INTRM1 DRILL DDRL P Drlg. from 4817' to 5008' MD. TVD=3141' 02:00 02:30 0.50 5,008 5,008 INTRM1 DRILL OTHR T Trouble shoot & change out MWD transducer on stand pipe manifold. 02:30 12:00 9.50 5,008 5,918 INTRMI DRILL DDRL P Drlg. from 5008' to 5918' MD. TVD=3508' ART-3.05 hrs. AST-5.02 hrs. P/U-155k S/0-81 k ROT-105k TQ-on 9k off 10-12k ECD-10.04 Max gas 55 units. Jars-204.67 hrs. SPR #1-30s m-310 psi. #2-30 s m-330 psi. 12:00 12:15 0.25 5,918 5,918 INTRM1 DRILL SFTY P PJSM-Topic=Making connections -pinch points -tongs -etc. 12:15 00:00 11.75 5,918 7,102 INTRM1 DRILL DDRL P Drlg. from 5918' to 7102' MD. TVD-3753'. AST=3.35 hrs. ART=5.19 hrs. ADT=8.54 hrs. P/U-145k S/0-87k RT-107k TQ-9k on 9-10k off. ECD-10.6 Max as-556 units. Jars-213.21 10/08/2006 00:00 04:30 4.50 7,102 7,498 INTRM1 DRILL DDRL P PJSM-Drlg. from 7102' to 7498' MD. TVD 3808'. ART=2.16 AST=1.23 ADT=3.39 hrs.-P/U-146k S/O-84k-ROT 106k-TQ-on9k off 9-11k ECD-10.3 Max gas-137 units Jar hrs. 216.6 9 0 10/0812006 04:30 05:30 1.00 7,498 7,498 INTRMI DRILL CIRC P Survey -rack back 1 stand DP -pump 30 bbls. weighted hi vis sweep-150 spm-630 gpm-2170 psi-TQ 11 k=no returns of extra cutting on return of sweep. 05:30 11:00 5.50 7,498 3,015 INTRIV111 DRILL TRIP P Monitor well (Static) BROOH @ 150 10/09/2006 10:00 11:00 1.00 7,498 7,498 INTRMI CEMEN SFEQ P Rig up csg. testing equipment. Test csg. to 3000# 30 mins. Chart same. OK 11:00 12:00 1.00 7,498 7,498 INTRM1 CEMEIN RURD P Rig down testing & cementing equipment. 12:00 12:30 0.50 7,498 7,498 INTRM1 CEMEIN OTHR P Blow down cement lines & lay down cs . tools. 12:30 14:00 1.50 7,498 71498 INTRM1 CEMEJ OTHR P Nipple down BOPE-pull 140k Set slips & slack off-Vaccume out & cut cs . 14:00 16:00 2.00 7,498 7,498 INTRM1 CEMEN OTHR P Install packoff-nipple up bope-test packoff void w/ 3800# (10 min. test) set mouse hole. 16:00 21:30 5.50 7,498 7,498 INTRM1 CEMEN PULD P PJSM & lay down 5" drill pipe in mousehole. 21:30 00:00 2.50 7,498 7,498 INTRM1 CEMEN OTHR P PJSM= Change out saver sub P/U jaws & stab guide -Prepare to remove stabbing board. 10/10/2006 00:00 00:30 0.50 0 0 INTRM1 CASIN( OTHR P Change saver sub and prep to remove stabbing board 00:'30 02:30 2.00 0 0 INTRM1 WELCT BOPE P Hold pre -job safety meeting and rig up to test BOPE. Test pipe rams and annular with 4" drill pipe. Test 4" TIW and dart valves to 250/3000 psi. UD stabbing board. (Chuck Scheve, AOGCC waived witnessing BOPE test). 02:30 03:00 0.50 0 0 INTRMI CASIN( OTHR P Set wear bushing., 03:00 07:00 4.00 0 6,138 INTRM1 DRILL PULD P Pre -job safety meeting. Pickup 198 joints of 4" XT-39 drill pipe and RIH to 6,138'. 07:00 10:30 3.50 6,138 0 INTRMI DRILL TRIP P POOH from 6,138' w/4" d.p. (Installed 36 super -sliders) and rack in derrick. (45 stds total with su ersliders 10:30 10:45 0.25 0 0 INTRMI DRILL OTHR P Clear rig floor 10:45 12:00 1.25 0 1,271 INTRMI DRILL PULD P RIH picking up 41 joints of 4" HWDP 12:00 13:00 1.00 1,271 0 INTRMI DRILL TRIP P POOH standing back HWDP and picking up jars 13:00 15:30 2.50 0 365 INTRMI DRILL PULD P MU BHA #4 RIH to 365', MU 6 3/4" bit #3 on geopilot rotary steerable with MWD, programmed MWD then RIH with 3-NMFDC's, HWDP and jars to 365' 15:30 20:30 5.00 365 7,365 INTRMI DRILL TRIP P RIH with BHA #4 from 365' to 7,365', PU 201 jts of 4" DP out of pipe shed RIH to 6,620' then RIH out of derrick to 7,365' 20:30 20:45 0.25 7,365 7,365 INTRM1 RIGMN SFTY P Held PJSM on slip and cutting of drlg line. 20:45 21:45 1.00 7,365 7,365 INTRMI RIGMN SVRG P Slip and cut 66' of drlg line, inspect drawworks brakes and crown-o-matic 21:45 22:00 0.25 7,365 7,400 INTRM1 DRILL CIRC P Est circ and washed down from 7,365' and tagged cement above flt collar at 7.400' (FC na 7.404') 0 10/10/2006 22:00 23:30 1.50 7,400 7,498 INTRMI CEME� DRLG P Drilled out plugs, fit collar at 7,404% shoe track and fit shoe at 7,493' then cleaned out to btm at 7,498', 2-4K wob, 50 rpm's, 75 spm, 267 gpm at 1,600psi 23:30 00:00 0.50 7,498 7,523 INTRM1 DRILL DDRL P Drilled 25' of new hole from 7,498' to. 7,523' MD/3,811' TVD, ADT .22 hrs, 24K wob, 50 rpm's, 75 spm, 267 gpm at 1,600 psi, rot wt 85K, up wt 105K, do wt 70K, torque off btm 2K ft-Ibs, on btm 3K ft-Ibs, jar hrs 135.86, 8.65 MOBM, ave ECD 9.68 ppg 10/11/2006 00:00 00:30 0.50 7,523 7,523 INTRM1 DRILL CIRC P Circ btms up at 7,523' for LOT, evened MW in and out at 8.6 ppg, 85 spm, 300 gpm at 2,400 psi, 100 rpm's and 4K ft-Ibs torque, est PWD base line with a clean hole ECD of 9.6 ppg 00:30 01:30 1.00 7,523 7,523 INTRM1 DRILL LOT P RU and performed LOT to 11.6 ppg EMW, 590 psi, 3,808' TVD with 8.6 ppg MOBM 01:30 10:00 8.50 7,523 8,404 PROM DRILL DDRL P Directionally drilled 6 3/4" hole in A2 sand lateral with Geopilot from 7,523' to 8,404' MD/3,827' TVD (881') ADT 5.36 hrs, 5-1 OK wob, 100 rpm's, 85 spm, 300 gpm at 2,560 psi, off/on btm torque 5K ft-Ibs, rot wt 84K, up wt 118K, do wt 62K, 8.7 ppg MOBM, ave ECD 10.2 ppg, ave BGG, 50 units, max gas 151 units 10:00 10:30 0.50 8,404 8,404 PROM DRILL CIRC NP Circ hole while geologist spoke to town, decision was made to pull back and sidetrack well. 10:30 11:00 0.50 8,404 8,023 PRODI STK TRIP NP POOH from 8,404' to 8,023', st wt up 125K, do wt 62K 11:00 14:00 3.00 8,023 8,050 PROD1 DRILL DDRL NP Troughed well for sidetracking from 8,023' to 8,050' 14:00 17:00 3.00 8,050 8,060 PROW DRILL DDRL NP Time drilled to sidetrack well, sidetracked well at 8,050' MD/ 3,818' TVD, drilled from 8,050'to 8,055' at 27hr, 8,055' to 8,060' at 107hr 17:00 19:45 2.75 8,060 8,404 PROM DRILL DDRL NP Sidetracked well drilling 6 3/4" hole from 8,060' to 8,404', (344) ADT 1.66 hrs 19:45 00:00 4.25 8,404 8,930 PROM DRILL DDRL P Cont to directionally drill 6 3/4" hole in A2 sand lateral with Geopilot from 8,404' to 8,930' MD/3,818' TVD (526') ADT 2.34 hrs, 5-10K wob, 115 rpm's, 85 spm, 300 gpm at 2,700 psi, off/on btm torque 5K ft-Ibs, rot wt 85K, up wt 115K, do wt 60K, 8.7 ppg MOBM, ave ECD 10.45 ppg, ave BGG, 60 units, max gas 256 units, (concretion from 8,906'to 8,909') 10/1212006100:00 102:00 1 2.00 18,930 19,190 DRILL DDRL P Cont to directionally drill 6 3/4" hole in A2 sand lateral with Geopilot from 8,930' to 9,190' MD/3,813' TVD (260') ADT 1.46 hrs, 5-1 OK wob, 115 rpm's, 85 spm, 300 gpm at 2,650 psi, off/on btm torque 5K ft-Ibs, rot wt 85K, up wt 115K, do wt 60K, 8.7 ppg MOBM, ave ECD 10.5 ppg, ave BGG, 50 units, drilled out of zone at 8,960', decision was made to pull back and sidetrack well 02:00 02:30 0.50 9,190 8,860 PROW DRILL TRIP NP POOH from 9,190' to 8,860', st wt up 130K, do wt 60K 02:30 04:15 1.75 " 8,860 8,885 PROD1 DRILL DDRL NP Troughed well for sidetracking from 8,860' to 8,885' 04:15 07:45 3.50 8,885 8,896 PROD1 DRILL DDRL NP Time drilled to sidetrack well, sidetracked well at 8,885' MD/3,818' TVD, drilled from 8,885' to 8,890' at 27hr then from 8,890' to 8,896' at 57hr, ADT 3.5 hrs 07:45 10:15 2.50 8,896 9,190 PROM DRILL DDRL NP Sidetracked well drilling from 8,896' to 9,190' 294' ADT 1.74 hrs 10:15 20:00 9.75 9,190 10,355 PROM DRILL DDRL P Cont to directionally drill 6 3/4" hole in A2 sand lateral with Geopilot from 9,190' to 10,355' MD/3,821' TVD (1,165') ADT 6.28 hrs, 4-12K wob, 95-110 rpm's, 87 spm, 310 gpm at 2,900 psi, off/on btm torque 6K ft-Ibs, rot wt 85K, up wt 127K, do wt 59K, 8.7 ppg MOBM, ave ECD 10.8 ppg, ave BGG, 80 units, max gas 986 units, pumped 35 bbl wt'd (2# over mw) hi vis sweep at 9,500' with 25% increase in cuttings, pumped an add. 35 bbl wt'd hi vis sweep at 10,275' 20:00 20:45 0.75 10,355 10,355 PROW DRILL CIRC P Fin circ out wt'd hi vis sweep and had a 10% increase in cuttings, circ at 310 gpm at 3,000 psi and 120 rpm's, initial ECD was 10.88 ppg and after sweep was out of the hole ECD was 10.64 ppg, took SPR's 20:45 00:00 3.25 10,355 10,728 PROD1 DRILL DDRL P Drilled 6 3/4" hole in A2 sand lateral with Geopilot from 10,355' to 10,728' MD/3,836' TVD (373') ADT 1.69 hrs, 4-12K wob, 115 rpm's, 87 spm, 310 gpm at 3,000 psi, off/on btm torque 6-7K ft-Ibs, rot wt 83K, up wt 134K, do wt 55K, 8.7 ppg MOBM, ave ECD 10.86 ppg, ave BGG, 80 units, max oas 226 units. iar hrs 162.89 i 10/13/2006 00:00 12:00 12.00 10,728 11,662 PROW DRILL DDRL P Drilled 6 3/4" hole in A2 sand lateral with Geopilot from 10,728' to 11,662' MD/3,839' TVD (934') ADT 9.92 hrs, 5-15K wob, 90-120 rpm's, 85 spm, 300 gpm at 2,900 psi, off/on btm torque 7K ft-Ibs, rot wt 80K, up wt 145K, do wt 42K, 8.7+ ppg MOBM, ave ECD 10.9 ppg, ave BGG, 60 units, max gas 160 units 12:00 15:30 3.50 11,662 12,018 PROD1 DRILL DDRL P Drilled 6 3/4" hole in A2 sand lateral with Geopilot from 11,662' to 12,018' MD/3,843' TVD (356') ADT 2.24 hrs, 5-14K wob, 110-120 rpm's, 85 spm, 300 gpm at 2,850 psi, off/on btm torque 7K ft-Ibs, rot wt 82K, up wt 152K, do wt 40K, 8.7+ ppg MOBM, ave ECD 10.9 ppg, ave BGG, 40 units, pumped wt'd hi vis sweep (2# over MW) at 11,775' with 10%increase in cuttings and at 11,942' and had 5% increase in cuttings, NOTE: Drilled out of zone at 11,752' MD/ 3,839' TVD and decision was made to pull back and sidetrack well 15:30 16:30 1.00 12,018 11,662 PROM DRILL TRIP NP Pumped out of hole from 12,018' to 11,662', pumped out at 300 gpm at 2,800 psi, st wt up 135K, do wt 50K 16:30 17:45 1.25 11,662 11,690 PROW DRILL DDRL NP Troughed well for sidetracking from 11,662'to 11,690' 17:45 21:15 3.50 11,690 11,734 PROM DRILL DDRL NP Time drilled to sidetrack well, sidetracked well at 11,690' MD/ 3,840' TVD, time drilled from 11,690' to 11,734', ADT 3.5 hrs 21:15 00:00 2.75 11,734 11,849 PROW DRILL DDRL NP Sidetracked well drilling from 11,734' to 11,849' 115' ADT .83 hrs 10/14/2006 00:00 01:45 1.75 11,849 12,018 PROM DRILL DDRL NP Fin drilling sidetrack from 11,849' to 12,018' MD/3,854' TVD, ADT 1.57 hrs 01:45 14:00 12.25 12,018 12,829 PROW DRILL DDRL P Drilled 6 3/4" hole in A2 sand lateral with Geopilot from 12,018' to 12, 829' MD/3,895' TVD (811') ADT 9.17 hrs, 5-20K wob, 100-120 rpm's, 85 spm, 300 gpm at 3,000 psi, off/on btm torque 8K ft-Ibs, rot wt 80K, up wt 160K, do wt 38K, 8.7+ ppg MOBM, ave ECD 11.0 ppg, ave BGG, 40 units, max gas 113 units, pumped wt'd hi vis sweep (2# over MVV) at 12,688' with 10% increase in cuttings. Concretions: 12016'- 12030', 12104'-12121', 12596'-12605', 12727'-12731', 12818'-12820', 12827'-12829'. 14:00 15:30 1.50 12,829 12,829 PROW DRILL CIRC T Circ hole while troubleshooting geopilot, unable to get geopilot to respond to commands, decision was made to POOH and change out tool 10/14/2006 15:30 7.00 12,829 7,463 PROD1 DRILL REAM T Backreamed out of hole from 12,829' I22:30 to 7,557' then POOH on elevators to 7,463' (csg shoe @ 7943'), BROOH at 300 gpm, 2700 psi and 100 rpm's with no problems 22:30 22:45 0.25 7,463 7,463 PROD1 DRILL OWFF T Monitored well -static, pumped dry job 22:45 00:00 1.25 7,463 4,657 PROD1 DRILL TRIP T POOH on elevators from 7,463' to 4,657'. 10/15/2006 00:00 01:15 1.25 4,657 368 PROD1 DRILL TRIP T Fin POOH on elevators from 4,657'to BHA #4 at 368', calc fill on trip out of hole 77 bbls, actual fill 114 bbls. 01:15 02:45 1.50 368 89 PROD1 DRILL PULD T POOH and stood back HWDP and jars, downloaded MWD 02:45 03:30 0.75 89 0 PROD1 DRILL PULD T LID MWD, POOH and found geopilot tool had parted at the drive shaft thru the reference housing leaving 14' of geopilot and bit in the hole, recovered 2.28' of 16.19' of the tool, est TOF @ 12,815' 03:30 04:00 0.50 0 0 PROD1 DRILL OTHR T Cleared rig floor 04:00 07:00 3.00 0 0 PROD1 RIGMN SVRG P Serviced rig while waiting on fishing tools, serviced top drive and inspected saver sub, held PJSM then slip and cut 65' of drlg line, serviced drawworks and iron roughneck 07:00 08:00 1.00 0 25 PROD1 FISH PULD T PU Baker fishing tools to rig floor, MU fishing BHA #5 RIH to 25', MU 6 1/4" short catch overshot with 514f' grapple, bumper sub, jars, fit sub and XO 08:00 14:00 6.00 25 12,804 PROW FISH TRIP T RIH with BHA #5 from 25' to 12,804', no problems going past sidetracks 14:00 14:45 0.75 12,804 12,813 PROD1 FISH FISH T Est circ at 12,804' at 25 spm, 88 gpm, 475 psi, rot wt 86K, up wt 153K, do wt 40K, 25-30 rpms with 6-8K off btm torque, RIH and tagged TOF at 12,813' (est TOF @ 12,816), worked over fish, saw no increase in pump pressure, PU and had 20K over up wt, sat down and lost 2% PU to 200K and had 45K drag and after jars hit had an up wt of 173K 14:45 15:00 0.25 12,813 12,813 PROD1 FISH OTHR T Monitored well -static, pumped dry job and blew down top drive 15:00 22:45 7.75 12,813 0 PROD1 FISH TRIP T POOH on elevators from 12,813' to fishing BHA #5 and recovered geopilot and bit, calc fill on trip out 77 bbls, actual 91 bbls. 22:45 00:00 1.25 0 0 PROD1 FISH PULD T LD bit, geopilot and overshot in pipshed, LID bumper sub and jars then cleaned rig floor, left fish made up in one piece i 10/16/2006 00:00 01:45 1.75 0 2,450 PROW DRILL OTHR T PU and MU Baker 7 5/8" lock set retrievable bridge plug and RIH to 2,450' and set same, st wt up 60K, set 25K wt do on BP 01:45 02:00 0.25 2,450 2,450 PROD1 DRILL OTHR T Tested RBP to 1,500 psi for 10 min and ck ok. 02:00 03:00 1.00 2,450 2,450 PROD1 DRILL OTHR T Displaced hole over from 8.7 ppg MOBM to fresh water at 2,450' 03:00 04:30 1.50 2,450 0 PROW DRILL OTHR T Monitored well -static, POOH from 2,450' and LD Baker setting tool 04:30 06:15 1.75 0 1,813 PROD1 DRILL OTHR T MU Baker multi -string cutter and RIH to 1,813' 06:15 06:30 0.25 1,813 1,860 PROW DRILL OTHR T Est circ at 1,813' at 180 gpm, 500 psi, 50 rpm's with 1 K ft-lbs torque, rot wt `) r `f'1 57K, up wt 57K,dn wt 57K, reduced WIN � pump pressure to 200 psi and dropped down locating collar at 1,832' and 1,875', PU to 1,860' and increased pump pressure to 500 psi and made cut on csg, saw 200 psi decrease in C pressure after cutting csg at 1,860'. Stopped pumps and PU into csg then with 500 psi slid down and found cut with same pressure drop and stacked out 15K to verify cut. 06:30 08:45 2.25 1,860 1,860 PROD1 DRILL OTHR T RU and attempted to pump down 7 5/8" x 10 3/4" OA, pressured up to 2,000 psi, press. dropped slowly to 1,880. press. up on DP to 2,000 psi with no leak off, pressured back up on OA to 2,500 psi with no leak off. 08:45 09:45 1.00 1,860 0 PROW DRILL OTHR T POOH from 1,860' and LID Baker multi -string cutter, cutters showed to have opened up and cut csg 09:45 10:15 0.50 0 0 PROW DRILL OTHR T Pulled wear bushing 10:15 10:45 0.50 0 0 PROD1 DRILL OTHR T RU and pulled 7 5/8" pack -off 10:45 12:15 1.50 0 0 PROW DRILL OTHR T MU Baker 7 5/8" csg spear and stung into csg, worked csg st wt up to 200K while holding 1,000 psi on csg with no movement or leak off of press., LID csg spear. Ran stretch calc's, had 3 1/4" of stretch with 50K over pull putting free Pt at +/-1,400' 12:15 12:45 0.50 0 0 PROD1 DRILL OTHR T Installed wear bushing 12:45 13:30 0.75 0 1,950 PROW DRILL OTHR T MU 4" mule shoe and RIH open ended on 4" DP to 1,950'. 13:30 16:45 3.25 1,950 1,950 PROD1 DRILL OTHR T Circ hole at 1,950' with 91 deg water, circ hole at 95 spm, 320 gpm, 200 psi, st wt ur) 57K 10/16/2006 16:45 00:00 7.25 1,950 1,950 PROM DRILL OTHR T RU Little Red and cont. to circ hole while raising water temp to 145 deg, circ hole at 320 gpm at 200 psi, reached 140 deg water in and 134 deg water out at 20:30 hrs, temp at 24:00 hrs was 145 deg. in and 140 deg. out. Sim-Ops: Began to bring stabbing board to rig floor. 10/17/2006 00:00 02:00 2.00 1,950 1,950 PROD1 DRILL OTHR T Cont. to circ hole with 145 deg water, circ hole at 320 gpm at 200 psi, temp in at 145 deg. and 140 deg. out. Sim-Ops: Fin re -hanging stabbing board. 02:00 02:45 0.75 1,950 0 PROD1 DRILL OTHR T POOH from 1950' and LD mule shoe 02:45 03:15 0.50 0 0 PROD1 DRILL OTHR T Pulled wear bushing 03:15 06:00 2.75 0 0 PROM DRILL OTHR T MU 7 5/8" csa spear and latched onto csg, tagged up with spear 8" higher than previous tag, PU to 200K st wt, did not see slips PU out of csg bowl, had PU at 140K before, observed fluted hanger and stack PU 1/2" to 3/4" when PU to 200K, pressured up to 1,000 psi and had no leak off, LD csg spear. 06:00 08:15 2.25 0 0 PROD1 DRILL OTHR T Inspected drawwork brakes and repaired hyd. line while waiting on E-line, RU floor for wireline 08:15 11:00 2.75 0 0 PROD1 DRILL OTHR T Held PJSM then RU Schlumberger (SWS) wireline, MU USIT logging tools and surface tested, swapped tools around and dropped AMS tool then retested and ck'd ok 11:00 13:45 2.75 0 0 PROD1 DRILL OTHR T RIH with USIT bond logging tools to 2,410', POOH logging to 100', LD logging tools and RD SWS, Log . shows est TOC at 700', 40% bond at 1,300' and 60% bond at 1,860' (cut 13:45 14.00 0.25 0 0 PROM DRILL OTHR T Installed wear bushing 14:00 17:00 3.00 0 0 PROD1 DRILL OTHR T Waited on csg cutter, due to mis-communication cutter was sent to Deadhorse 17:00 18:00 1.00 0 1,860 PROD1 DRILL OTHR T MU 7 5/8" csg cutter and RIH with cutter to 1,850', est circ at 180 gpm at 500 psi, rot at 55 rpm's with 1 K ft-Ibs torque, rot wt 57K, up wt 57K, do wt 57K, RIH and located cut at 1,860' and pressured dropped to 200 psi at 180 m. 18:00 19:00 i 1.00 1,860 1,860 PROM DRILL OTHR T Rotated cutter on cut at 1,860' for 1 hr at 55 rpm's, 1 K ft-Ibs torque, increased pump rate to 80 spm, 285 gpm at 500 psi and while working cutter pressure decreased to 250 psi after 1 hr. 10/17/2006 19:00 20:00 1.00 1,860 0 PROM DRILL OTHR T POOH and LD csg cutter, knives originally were 2 1/4" long, after cut were worn down to 2" 20:00 20:45 0.75 0 1,960 PROM DRILL OTHR T RIH with mule shoe on 4" DP to 1,960' 20:45 22:30 1.75 1,960 1,960 PROW DRILL OTHR T Dumped sand down DP to spot 30' of sand on top of BP 22:30 23:30 1.00 1,960 0 PROW DRILL OTHR T POOH from 1,960' with mule shoe 23:30 00:00 0.50 0 0 PROD1 DRILL OTHR T Pulled wear bushing 10/18/2006 00:00 00:30 0.50 0 0 PROM DRILL OTHR T MU 7 5/8" spear, tagged up and PU on csg, worked st wt up to 250K with no csg movement and observed fluted hanger and csg move up 1 1/2", pressured up to 1,000 psi w/no leakoff 00:30 02:00 1.50 0 1,306 PROM DRILL OTHR T Installed wear bushing then MU 7 5/8" csg cutter and RIH, located csg collar at 1,321'then PU 15'to 1,306' 02:00 02:15 0.25 1,306 1,306 PROW DRILL OTHR T Est circ at 178 gpm at 500 psi, st wt up 52K, do wt 50K, rot wt 52K, 55 rpm's and 1 K ft-lbs torque then cut csg at 1,306', saw press, drop along with hearing csg jump in slips and well u-tubing 02:15 02:30 0.25 1,306 1,306 PROW DRILL OTHR T Allowed well to U-tube, stabilized in 5 min, monitored well- static 02:30 03:30 1.00 1,306 0 PROD1 DRILL OTHR T POOH and LD csg cutter, pulled wear bushing 03:30 04:00 0.50 0 1,306 PROM DRILL OTHR T MU spear, PU on 7 5/8" csg and csg pulled free at 80K up wt 04:00 06:30 2.50 1,306 1,286 PROM DRILL OTHR T ND BOP stack, PU 20' and recovered slips, NU stack 06:30 07:00 0.50 1,286 1,286 PROM DRILL OTHR T Est circ then pumped 35 bbl Safe-Surf-0- pill and circ hole clean with water, circ at 450 gpm at 130 psi, st wt at 70K 07:00 10:45 3.75 1,286 0 PROM DRILL OTHR T Held PJSM, RU and POOH LD 7 5/8" csg, LD 2-cut pieces (48'), 29 full jts (1,231') and 13 tandem rise cent. total rec'd 1,279', RD handling tools and cleared rig floor 10:45 13:30 2.75 0 413 PROM DRILL OTHR T PU and MU Baker 7 5/8" csg spear,. bumper sub, oil jars then PU and RIH with 12-6 1/2" DC's and eccelarator jars RIH to 413'. BHA st wt 62K 13:30 14:00 0.50 413 1,306 PROM DRILL OTHR T RIH from 413' to TO at 1,306', st wt up 72K, do 72K 14:00 14:45 0.75 1,306 1,306 PROM DRILL OTHR T Latched onto 7 5/8" csg stub at 1,306' and worked st wt up from 75K over st wt to 228K, (300K total) working jars and attempting to circ hole, press, up to 1,000 psi with no leak off or pipe movement. 10 3/4" csg flute or stack did not move. 10/18/2006 14:45 15:30 0.75 1,306 1,306 PROD1 DRILL OTHR T Circ hole at 1,306', added Duo-vis to water to vis up, circ hole at 320 gpm at 500 psi 15:30 17:30 2.00 1,306 0 PROW DRILL OTHR T POOH from 1,306', stood back DC's and LD csg spear 17:30 19:00 1.50 0 11440 PROD1 DRILL OTHR T Installed wear bushing, MU 7 5/8" csg cutter and RIH to 1,440', st wt up 54K, do wt 54K 19:00 19:45 0.75 1,440 1,476 PROM DRILL OTHR T Est circ at 117 gpm at 225 psi, st wt up 54K, do wt 54K, rot at 60 rpm's 1 K ft-lbs torque, located collar at 1,491' then PU to 1,476' and cut 7 5/8" csg, took 5-8 min's to cut, worked cutter an add. 15 min, saw decrease in Pressure when csg was cut. 19:45 21:15 1.50 1,476 0 PROM DRILL OTHR T POOH from 1,476' and LD cutter, cutters were worn down 1/4" from 2 1/4" 21:15 23:00 1.75 0 1,253 PROD1 DRILL OTHR T MU 7 5/8" csg spear & RIH with jars and 12- 6 1/2" DC's, RIH to 1,253', st wt up 73K, do wt 73K 23:00 23:15 0.25 1,253 1,306 PROD1 DRILL OTHR T RIH from 1,253' and tagged top of stump at 1,306', st wt up 73K, set' spear then PU to 130K and csg pulled free, didn't even hit the jars, st wt 75K 23:15 00:00 0.75 1,306 1,286 PROW DRILL OTHR T PU 20'to 1,286' and Circ hole clean, Circ at 300 gpm at 250 psi, st wt after circ hole 71 K 10/19/2006 00:00 01:30 1.50 1,286 0 PROW DRILL OTHR T POOH with csg spear from 1,286' after making cut at 1,476', rec'd stub 01:30 03:00 1.50 0 0 PROM DRILL OTHR T RU and POOH LD 7 5/8" csg, LD 2-cut pieces 43' and 3-full jts 128' and 2-tandum rise cent., RD tongs 03:00 04:15 1.25 0 1,562 PROM DRILL OTHR T MU 7 5/8" csg cutter & RIH to 1,535', est circ at 175 gpm at 500 psi, 55 rpm's, 1 K ft-lbs torque, rot wt 54K, up wt 55K, do wt 55K, RIH and located collar at 1,577', PU to 1,562' 04:15 04:45 0.50 1,562 1,562 PROM DRILL OTHR T Cut 7 5/8" csg at 1,562', saw 250 psi drop in press. after cut, rotated on cut 15 min after press. loss 04:45 06:00 1.25 1,562 0 PROM DRILL OTHR T POOH and LD csg cutter 06:00 07:45 1.75 0 1,562 PROD1 DRILL OTHR T RIH with 7 5/8" csg spear with jars and DC's, RIH to stub at 1,476', st wt 74K, speared csg, PU 75K over st wt hitting jars twice, pressured up to 1,000 psi and csg came free, st wt up 90K 07:45 10:15 2.50 1,562 0 PROM DRILL OTHR T POOH from 1,562', LD csg spear and then LD 7 5/8" csg, LD 2-cut pieces 43' and 1-full jt 43' with 1-tandum rise cent. 10:15 10:45 0.50 0 0 PROD1 DRILL OTHR T Pulled wear bushing and cleared rig floor 10/19/2006 10:45 15:30 4.75 0 0 PROD1 WELCT BOPE P RU and tested ROPE, tested rams, valves and manifold to 250 psi low and 3,000 psi high including annular preventer, tested with 4" DP and tetsed all gas detectors. NOTE: Jeff Jones with AOGCC witnessed BOP test 15:30 15:45 0.25 0 0 PROD1 DRILL OTHR T Installed wear bushing 15:45 17:30 1.75 0 1,533 PROW DRILL OTHR T MU 7 5/8" csg spear, jars and DC's, RIH to 1,533' 17:30 18:00 0.50 1,533 1,562 PROW DRILL OTHR T Est circ and washed down from 1,533' to top of csg stub at 1,562' then circ btms up, circ btms up at 500 gpm at 350 psi, st wt up 74K, do wt 74K 18:00 18:45 0.75 1,562 1,562 PROD1 DRILL OTHR T Speared csg and attempted to jar csg loose with no success, with 74K st wt, worked csg PU on string to 175K over st wt, after jarring`on pipe would PU to 300K st wt with no movement, would pressure up to 1,200 psi with no leak off 18:45 19:00 0.25 1,562 1,562 PROW DRILL OTHR T Circ btms up at 1,562', circ at 400 m at 400 psi 19:00 20:30 1.50 1,562 0 PROM DRILL OTHR T POOH and LD csg spear 20:30 21:45 1.25 0 1,628 PROW DRILL OTHR T MU 7 5/8" csg cutter and RIH to 1,628', st wt up 55K, do 55K 21:45 22:30 0.75 1,628 1,648 PROW DRILL OTHR T Est circ at 95 gpm at 200 psi, RIH from 1,628' and located collar at 1,663', PU 16to 1,648', press. up to 500 psi at 170 gpm, 60 rpm's with 1 K ft-lbs, torque, cut 7 5/8" csg at 1,648', took approx 5-7 min's to cut csg, rotated on cut an add. 15 min, lost 400 psi while cutting csg. 22:30 00:00 1.50 1,648 0 PROM DRILL OTHR T POOH and LD cutter 10/20/2006 00:00 01:00 1.00 0 1,562 PROW DRILL OTHR T MU 7 5/8" csg spear, jars and DC's, RIH to 1,562' , st wt up 75K, do 75K 01:00 01:30 0.50 1,562 1,648 PROD1 DRILL OTHR T PU on csg stub at 1,562' , pulled stub free after hitting jars twice and pulling to 200K and put 1,000 psi pump on hole, pulled cut free at 1,648' 01:30 03:30 2.00 1,648 0 PROD1 DRILL OTHR T POOH from 1,648' and LD spear, LD 2-cut pieces 42' and 1 full jt 42' with 1 tandem cent. 03:30 04:45 1.25 0 1,626 PROM DRILL OTHR T MU 7 5/8" csg spear, jars and DC's, RIH to 1,626', st wt up 75K, do 75K 04:45 05:00 0.25 1,626 1,648 PROW DRILL OTHR T Washed down from 1,626'to 1,648' then circ btms up, circ at 470 gpm at 500 psi, st wt up & do 75K 05:00 05:45 0.75 1,648 1,648 PROM DRILL OTHR T Speared csg at 1,648' and attempted to jar csg free from 1,860', pulled 275K working jars then pulling to 300K after and attempted to circ at 1,000 psi, no movement 10/20/2006 05:45 07:15 1.50 1,648 1 0 PROM DRILL JOTHR T I Released spear and POOH from 1,648', LD spear 07:15 09:00 1.75 0 1,730 PROD1 DRILL OTHR T MU csg cutter & RIH, located collar at 1,745', PU and cut csg at 1,730' 09:00 09:30 0.50 1,730 1,820 PROM DRILL OTHR T RIH with csg cutter from 1,730' and made a second cut at 1,820' 09:30 10:30 1.00 1,820 0 PROD1 DRILL OTHR T POOH from 1,820' and LD cutter 10:30 12:45 2.25 0 1,730 PROD1 DRILL OTHR T MU csg spear, jars and DC's, RIH and speared stub at 1,648', hit jars once and pressured up to 500 psi and csg came free from cut at 1,730' 12:45 15:00 2.25 1,730 0 PROM DRILL OTHR T POOH from 1,730', LD spear and 2-cut pieces 41.8' and 1-full it 41.95' with 1-tandum rise cent. 15:00 16:30 1.50 0 1,730 PROM DRILL OTHR T MU csg spear assembly and RIH to cut at 1,730', st wt up and do 77K, 16:30 17:00 0.50 1,730 1,730 PROM DRILL OTHR T Attempted to get inside 7 5/8" csg stub at 1,730' with no success, setting down and unble to rotate or pump and go deeper. 17:00 18:30 1.50 1,730 0 PROM DRILL OTHR T POOH from 1,730' to spear, btm uide, aint was off and shinne 18:30 20:30 2.00 0 1,637 PROM DRILL OTHR T MU 3 1/2" mule shoe with 10' pup on spear assembly then RIH to 1,637' 20:30 21:30 1.00 1,637 1,648 PROM DRILL OTHR T Est circ at 500 gpm at 400 psi, st wt up 76K, do wt 74K, washed down with mule shoe thru stub at 1,648' down to 1,658', pumped 35 bbl hi vis sweep and circ hole clean 21:30 21:45 0.25 1,648 1,648 PROD1 DRILL OTHR T Worked packoff into stub, took several attempts then cont to spear csg stub, hit jars once at 250K then pulled to 300 after jars hit, pressured up and ackoff didn't hold. 21:45 00:00 2.25 1,648 50 PROM DRILL OTHR T POOH from 1,820' to 50' standing back 3 of 4 DC's. NOTE Had PJSM with new crew due to weekly crew change while POOH. 10/21/2006 00:00 02:00 2.00 50 0 PROM DRILL OTHR T Fin POOH from 50' to csg spear, had to cut 6" off top of stub to retrieve spear and grapple, POOH LD 2-cuts 1-13.84' & 1-32.1 T. 02:00 02:30 0.50 0 1,800 PROM DRILL OTHR T RIH with 3 1/2" mule shoe to 1,800' 02:30 03:30 1.00 1,800 2,050 PROD1 DRILL OTHR T Washed down from 1,800'to 2,050', no problem going thru cut at 1,860', circ 1 1/2 X btms up and clean at shakers, circ at 550 gpm, 500 psi and 40 r m's 03:30 04:00 0.50 2,050 0 PROM DRILL OTHR T POOH from 2,050' and LD mule shoe 04:00 05:15 1.25 0 1,911 PROM DRILL OTHR T MU 7 5/8" csg cutter with mule shoe and RIH to 1,911', set down on cut at 1,860 and rotated slow to clear cut, st wt uD 57K. do 57K 10/21/2006 05:15 06:00 0.75 1,911 1,903 PROM DRILL OTHR T RIH and located collar at 1,918', PU 15' and cut csg at 1,903', took 10 min to make cut, rotated on cut an add. 15 min. 06:00 07:30 1.50 1,903 0 PROM DRILL OTHR T Blew down top drive and POOH LD csq cutter 07:30 10:00 2.50 0 1,869 PROM DRILL OTHR T MU 7 5/8" csg spear assembly and RIH to 1,869' 10:00 11:00 1.00 1,869 1,869 PROM DRILL OTHR T Jarred on btm cut at 1,869', (csg cut f/1,860'-1,903'), hit jars 16 times working st wt up to250K and 1,200 psi with no movement 11:00 11:45 0.75 1,869 1,840 PROM DRILL OTHR T Released spear and PU to upper cut to 1,840' (upper cutf/1,820'-1,860') worked jars 4X PU to 250K st wt with 1,000 psi and csg came free, attempted to release grapple to RIH to lower cut and was unable to release from tool. 11:45 15:30 3.75 1,840 0 PROM DRILL OTHR T POOH from 1,860' to spear, had to cut top 6" off of stub to release tool from stub, LD 2-cut pieces, 39.82' total 15:30 16:45 1.25 0 2,100 PROM DRILL OTHR T RIH with 3 1/2" mule shoe on 4" DP to 2,100', no problems going thru cut at 1,860' 16:45 17:30 0.75 2,100 2,100 PROM DRILL OTHR T Pumped 35 bbl hi vis sweep (water & duovis) and circ 2X btms up and was clean at the shakers, circ hole at 600 m, 400 psi, 60 r m's 17:30 18:45 1.25 2,100 0 PROM DRILL OTHR T POOH from 2,100' and LD mule shoe 18:45 19:45 1.00 0 0 PROM DRILL OTHR T Slip and cut 65' of drlg line 19:45 22:15 2.50 0 1,826 PROM DRILL OTHR T MU 7 5/8" spear assembly with bumper sub, oil jars and 12 6 1/2" DC's and changed out grapples, RIH to 1,826', st wt up 79K, do wt 71K 22:15 22:45 0.50 1,826 1,860 PROM DRILL OTHR T Washed down from 1,826'to TOF at 1,860' then circ 1 1/2X btms up, circ at 550 gpm at 450 psi 22:45 23:15 0.50 1,860 1,903 PROM DRILL OTHR T RIH to 1,878' with grapple, stacked out 2' from no go, jarred on fish up to 250K and 1,200 pis, after 5th hit pipe moved up hole 3', after 6th hit and 1,000 psi fish came free at 1,903' 23:15 00:00 0.75 1,903 1,703 PROM DRILL OTHR T Blew down top drive and POOH from 1,903'to 1,730' 10/22/2006 00:00 01:45 1.75 1,703 0 PROM DRILL OTHR T Fin. POOH from 1,703' and LD csg spear, LD 2-cut pieces 41.03' with cent. between stub and no-go, cleared rig floor 01:45 02:30 0.75 0 2,335PROM DRILL OTHR T MU and RIH with mule shoe on DP to 10/22/2006 02:30 04:30 2.00 2,335 2,335 PROM DRILL OTHR T Pumped 35 bbl hi vis sweep and circ out of hole, circ at 600 gpm at 650 psi and 50 rpm's, cleaned out mud pit then displaced hole over from FW to 9.8 ppg brine, circ at 600 gpm, 940 psi and 50 rpm's 04:30 05:30 1.00 2,335 0 PROD1 DRILL OTHR T Blew down top drive and POOH from 2,335' & LID mule shoe 05:30 08:30 3.00 0 1,847 PROM DRILL OTHR T MU 9 5/8" x 8 3/4" washover shoe, 1-jt washpipe, 2-7" boot baskets and accel. jars and RIH with 12-6 1/2" DC's and 4" DP to 1,847', st wt up 79K 08:30 11:00 2.50 1,847 1,916 PROD1 DRILL OTHR T Est circ at 215 gpm, 240 psi, 50 rpm's, 2K ft-Ibs torque, rot wt 75K, up wt 79K, do wt 70% then washed down from 1,847' overtop of stub at 1,903' to 1,916', set 8-1 OK wt do on collar and was unable to go deeper 11:00 13:30 2.50 1,916 0 PROD1 DRILL OTHR T POOH from 1,916', stood back DC's and LID boot baskets, WP and wash shoe, had several small pieces of metal and cement in boot baskets 13:30 16:00 2.50 0 1,903 PROM DRILL OTHR T MU csg spear assembly and RIH to 1,903' ands eared csg stub 16:00 16:30 0.50 1,903 1,903 PROD1 DRILL OTHR T RU and tested csg stub and collar to 2,000 psi for 10 min, good test 16:30 19:30 3.00 1,903 0 PROM DRILL OTHR T Blew down top drive and POOH from 1,903', POOH to 6 1/2" DC's, LD 12 DC's ands ear assembly 19:30 20:30 1.00 0 0 PROD1 DRILL OTHR T Pulled wear bushing and cleared rig floor 20:30 22:30 2.00 0 0 PROM DRILL OTHR T RU to run 7 5/8" csg and changed out elevator bales, held PJSM with rig crew, tong operator, Baker & HES tool operator on running of csg with overshot, packoff and cementing stage tool. 22:30 00:00 1.50 0 112 PROD1 DRILL OTHR T MU Baker 7 5/8" bowl overshot with 7 5/8" packoff with HES type H-ES cementer, thread locked btm 2 conn. RIH with 3 jts of 7 5/8", 29.7#, L-80 BTCM csg with torque rings to 112' 10/23/2006 00:00 02:30 2.50 112 1,865 PROD1 DRILL OTHR T Cont RIH with 7 5/8" csg to 1,865', st wt up 76K, do wt 75K 02:30 03:00 0.50 1,865 1,903 PROM DRILL OTHR T Est rotation at 1,865' at 20 rpm's with 75K rot wt and 1300 ft-Ibs torque, RIH with 7 5/8" csg from 1,865' and tagged top of stub at 1,903% rotated overshot w/dressoff shoe on ID overtop 1', slacked off and set csg grapple, had to circ do to btm out on stub, set 30K wt dn. 03:00 03:30 0.50 1,903 1,903 PROM DRILL OTHR T Blew down top drive and MU Halliburton's cement head w/plug, PU 30K over st wt to 105K 10/23/2006 03:30 03:45 0.25 1,903 1,903 PROM DRILL OTHR T Pressure tested packoff to 1,000 psi for 10 min, good test, pressured up and opened cement stage tool at 2,500 psi (Note: tool was pinned with 4 pins set too en at 2,200psi) 03:45 04:15 0.50 1,903 1,903 PROD1 DRILL OTHR T Circ 2X csg cap with 9.8 brine and water prior to cementing at 1,903' at 252 gpm at 250 psi 04:15 05:30 1.25 , 1,903 1,903 PROM DRILL OTHR T Cemented 7 5/8" tie -back, Dowell pumped 10 bbls water, pressure tested lines to 3,500 psi, pumped 30 bbls of water (40 total), mixed and puimped 90 bbls, 446 sxs, class "G" cement with additives at 15.8 ppg and 1.17 yield, ave 4 3/4 bpm at 200 psi, dropped HES plug and Dowell chased with 20 bbls water, turned over to the rig and fin displacing cement with water, ave 5 bpm at initial press. of 250 psi, final press. 850 psi, bumped plug on calc disp. pressured up to 2,100 psi, tool shifted closed at 1,700 psi, held 2 min and ck ok, bled off and tool was closed. CIP at 05:20 hrs, had 5 bbls of 14.8 ppg cmt back followed by 8 bbls of 15.2 ppg cmt at suface when plug bumped. 05:30 06:15 0.75 1,903 11903 PROW DRILL OTHR T Flushed out stack then ND wellhead and stack, PU to 150K st wt (75K over st wt) and landed csg in the slips. 06:15 08:15 2.00 1,903 11903 PROM DRILL OTHR T RD HES cement head, cut off 7 5/8" csg (30.34') & LD same, installed packoff and NU wellhead and stack, pressure tested packoff to 3,800 psi for 10 min and ck'd ok 08:15 09:00 0.75 0 0 PROM DRILL OTHR T Flushed out stack with stack washing tool at 285 gpm at 150 psi and 50 r m's, then installed wear bushing 09:00 15:00 6.00 0 0 PROD1 DRILL OTHR T While W.O.C, MU 15 stds of hybrid push pipe and stood back, (2- 4 3/4" DC's & 1 jt-HWDP on top) then PU and stood back 7 add. stds of 4" DP then cleared rig floor 15:00 17:15 2.25 0 1,898 PROM DRILL OTHR T MU 6 3/4" mill tooth bit, 2-boot baskets and RIH with 10 stds hybrid push pipe and jars then RIH tagging up on plug at 1,898' (HES cmt tool @ 1, 899' 17:15 18:45 1.50 1,898 1,900 PROD1 DRILL OTHR T Drilled out HES cement plug at 1,898' to 1,900', 5-6K wob, 70 rpm's, 1 K ft-lbs torque, 220 gpm at 350 psi, worked bit thru cmt tool several times and ck'd ok, st wt up 72K, do wt 68K 18:45 20:15 1.50 1,900 2,439 (PROM DRILL OTHR T I RIH washing down from 1,900' and tagged up at 2,439' (RBP @ 2,450') 10/23/2006 20:15 20:45 0.50 2,439 2,439 PROD1 DRILL OTHR T Pumped 35 bbl hi vis sweep and circ out of hole, had no increase in cuttings back from the sweep, circ hole at 500 gpm, 450 psi and 50 r m's 20:45 22:15 1.50 2,439 0 PROD1 DRILL OTHR T Blew down top drive and POOH from 2,439', stood back push pipe and LD bit and boot baskets, no recovery in baskets 22:15 00:00 1.75 0 947 PROD1 DRILL OTHR T MU Baker 6 3/4" x.4 3/4" reverse circ junk basket, 2- 4 3/4" boot baskets, bumper sub, oil jar and 10 stds of hybrid ush pipe RIH to 947' 10/24/2006 00:00 00:15 0.25 947 2,441 PROW DRILL TRIP T PJSM- RIH from 947' to 2441'. 00:15 00:45 0.50 2,441 2,444 PROD1 DRILL OTHR T Wash over top of bridge plug from 2441' to 2444'. 00:45 01:00 0.25 2,444 2,444 PROD1 DRILL CIRC T Circ. bottoms up @ 100 spm 1500 psi. 01:00 01:30 0.50 2,444 947 PROD1 DRILL TRIP T Lay down single -blow down top drive- oh to 947'. 01:30 02:30 1.00 947 0 PROD1 DRILL PULD T Rack back 5 stands push pipe -lay down xo-oil jars -bumper sub -bit sub-2 4 3/4" boot baskets-xo & reverse circa junk basket. 02:30 03:00 0.50 0 0 PROD1 DRILL OTHR T Clear rig floor -lay all tools out beaver slide. 03:00 03:30 0.50 0 21100 PROD1 DRILL TRIP T Make up bridge plug retrieving tool & RIH to 2100'. 03:30 04:00 0.50 2,100 2,100 PROD1 DRILL DHEQ T Test casing 2000 psi leaked off down hole. 04:00 04:15 0.25 2,100 2,100 PROD1 DRILL OTHR T Rig down head pin & cement hose -blow down same. 04:15 04:30 0.25 2,100 2,438 PROD1 DRILL TRIP T RIH to 2438'. 04:30 04:45 0.25 2,438 2,438 PROD1 DRILL CIRC T Pump sweep -displace well to mobm 110 spm- 650 psi 40 rpm. 04:45 05:00 0.25 2,438 2,438 PROD1 DRILL OTHR T 10pen+closed unloader-released. 05:00 05:45 0.75 2,438 2,438 PROD1 DRILL DHEQ T Test 7 5/8" csg. 2000 psi 30 mins. OK Chart same. 05:45 07:00 1.25 2,438 2,438 PROD1 DRILL CIRC T Release from bridge plug & CBU @ 3 bpm 150 psi -flow check static -blow down top drive. 07:00 08:45 1.75 2,438 0 PROD1 DRILL TRIP T POH with bridge plug & lay down same. 08:45 10:30 1.75 0 0 PROD1 DRILL PULD T Pick up & make up BHA V. Up Load MWD. 10:30 12:00 1.50 0 742 PROD1 DRILL OTHR T RIH to 742'-shallow test MWD @ 280 m w/ 1800 psi. 12:00 15:00 3.00 742 7,493 PROD1 DRILL TRIP T Continue RIH from 742' to 7493'. Filling pipe every 20 stands. 15:00 00:00 9.00 7,493 12,520 PROD1 DRILL TRIP T Wash & Ream in hole from 7493' to 12520' @ 70 spm 245 gpm 3000 psi 80 rpm TQ 6k. Line up tool face for buildina trench & sidetrackino. 10/25/2006 00:00 00:15 0.25 12,520 12,520 PROD1 DRILL I SFTY 00:15 00:30 0.25 12,520 12,560 PROW DRILL OTHR 00:30 06:00 5.50 12,560 12,829 PROD1 DRILL DDRL 06:00 12:00 6.00 12,829 13,162 PROD1 DRILL DDRL 12:00 122:45 1 10.75 113,162 113,720 JPROD1 I DRILL I DDRL 22:45 100:00 1 1.25 113,720 113,612 jPROD1 I DRILL ( TRIP 10/26/2006 00:00 00:15 0.25 13,612 13,612 PROD1 I DRILL I SFTY 00:15 00:30 1 0.25 113,612 112,801 1PROD1 I DRILL ITRIP 00:30 01:30 1.00 112,801 13,720 PROD1 DRILL TRIP 01:30 04:30 3.00 13,720 13,720 1PROD1/I DRILL I CIRC 04:30 104:45 04:45 106:30 06:30 106:45 06:45 10:30 10:30 10:45 10:45 12:00 12:00 15:45 15:45 16:15 16:15 17:15 17:15 18:00 18:00 118:15 18:15 120:30 20:30 121:15 21:15 122:30 0.25 13,720 13,720 PROW DRILL I SFTY 1.75 13,720 13,720 PROW DRILL CIRC 0.25 13,720 13,720 PROW DRILL OTHR 3.75 13,720 7,485 PROD1 DRILL TRIP 0.25 7,485 7,485 PROD1 DRILL OTHR 1.25 7,485 5,804 PROD1 DRILL TRIP 3.75 5,804 80 PROD1 DRILL TRIP 0.50 80 80 PROD1 DRILL OTHR 1.00 80 0 PROD1 DRILL PULD 0.75 0 0 COMPZP DRILL OTHR 0.25 0 0 COMPZI,CASIN( SFTY 2.25 10 12,585 ICOMPZN CASIN( RNCS 0.75 2,585 2,585 ICOMPZICASIN(JOTHR 1.25 2,585 15,410 jCOMPZ CASIN( RNCS T I PJSM-Topic=Drilling Ahead. T Troughing from 12520' to 12560' MD. T Drlg. 6 3/4" hole from 12560' to 12,829' P Drlg. new hole from 12829' to 13162' MD-3902' TVD. ADT 2.92 AST 1.02 ART 1.9. P/U 175k S/O 0 ROT 95k TQ 9k Max gas 61 units ECD 11.1 SPR 20 spm 600 psi 30 spm 870 psi. P Drlg. 6 3/4" horizontal hole w/ motor in A -sand lateral from 13162' to 13720' MD 3910 TVD 77 spm 270 gpm 3800 psi 90 rpm TQ 9k . ADT 5.20 AST 3.48 ART 1.72 P/U 185k S/O o ROT 100k max gas 79 units ECD 11.3 P BROOH from 13720' to 13612' @ 77 spm 3800 psi 90 rpm TQ 8k @ 40 f m. P PJSM-Topic=BROOH & RIH. P tOOH from 13612'to 12801'. 90 M 298 qpm 4000 psi 10k TQ. P Wash & ream from 12801' to 13720'. Same rate. P Pump weighted hi-vis sweep @ 284 gpm 4000 psi 90 rpm -reciprocate string 60-70 f m. P PJSM-Topic=Displacing mobm to sfobm. P Displace well to SFOBM @ 277 gpm 3950 psi 90 rpm. P Blow down top drive -flow check well (Static) lay down single DP. P POH from 13705' to 7485' P Flow check well @ shoe (Static). P POH from 7485' to 5804'. P POH from 5804' to 80'. P Download MWD. P Lay down MWD-drain motor -break bit. P Clear & clean floor -rig up casing tools. P PJSM-Topic=Running 4.5" slotted liner. P Running 4 1/2" slotted liner w/ blanks from 0 to 2585'. T Change out split hydraulic hose on scate. P Running 4 1/2" slotted liner w/ blanks from 2585 to 5410'. 10/26/2006 22:30 23:00 0.50 5,410 5,410 COMPZ CASIN( OTHR NP Found it. # 126 to have 2 torque rings in collar, layed down & replaced joint w/ one of equal length. 23:00 00:00 1.00 5,410 6,034 COMPZP CASIN( RNCS P Running 4 1/2" slotted liner w/ blanks from 5410 to 6034'. 10/27/2006 00:00 00:15 0.25 6,034 6,034 COMPZ CASIN( SFTY P PJSM-Topic=running 4 1/2" slotted liner. 00:15 00:45 0.50 6,034 7,060 COMPZP CASIN( RNCS P Picking up 4 1/2" slotted liner w/ blanks from 6034' to 7060'. Make up seal bore extention & ZXP liner top packer. 00:45 04:15 3.50 7,060 13,678 COMPZ CASIN( RUNL P Run in hole w/ 4 1/2" slotted liner on 4" drill pipe from 7060' to13678'. 04:15 04:30 0.25 13,678 13,709 COMPZ CASIN( RUNL P Rotate liner down from 13678' to 13720'. Tagged bottom w/ 20k. P/U 190k S/O o Rot 95k TQ 1 Ok. Pick up to 13709'. Drop 1 3/4" ball. 04:30 05:00 0.50 13,709 13,709 COMPZt CASIN( CIRC P Pump ball down -set hanger @ 2000 psi. Set ZXP @ 3000 psi. Release @ 4000 psi. 05:00 05:15 0.25 13,709 13,709 COMPZ CASIN( DHEQ P Test ZXP + Annulus 1000 psi 10 mins. chart same OK. 05:15 08:00 2.75 13,709 0 COMPZ CASIN( OTHR P Blow down top drive flow check well (Static) POH from 6653' to liner running tool. 08:00 08:30 0.50 0 0 COMPZ CASIN( OTHR P Service break & lay down liner running tool. 08:30 09:00 0.50 0 0 COMPZI CASINC OTHR P Clear & clean rig floor. 09:00 10:00 1.00 0 0 COMPZ CASIN( OTHR P Slip & cut 71' drlg. line. 10:00 10:30 0.50 0 0 COMPZP CASIN( OTHR P Service top drive. 10:30 12:00 1.50 0 0 PROD2 DRILL PULD P Pick up whipstock assembly, make up window mill, lower watermellon mill -upper string mill-1 it. hwdp-make up seals 4.64'-stop-unloader-lift sub 2.70' 3 1/2" dp 31.81'-32.00' & 31.90'. 12:00 12:30 0..50 0 150 PROD2 DRILL PULD P PJSM-Pick up whipstock & mills (pinned 35k shear) Pick up & orient MWD pick up bumper sub. 12:30 13:00 0.50 150 150 PROD2 DRILL OTHR P Program MWD. 13:00 13:45 0.75 150 515 PROD2 DRILL TRIP P RIH w/ 3 stands hybred pipe & spt @ 515'. 13:45 16:30 2.75 515 5,970 PROD2 DRILL TRIP P RIH w/ whipstock mill assembly -fill pipe Q 3315' & break circ. @ 5970'. 16:30 17:00 0.50 5,970 5,970 PROD2 DRILL OTHR P Mad Pass 5770' to 5840'. Orient tool face @ 11left. 17:00 17:45 0.75 5,970 5,970 PROD2 DRILL LOT P LOT @ 11.2 ppg emw. 17:45 18:30 0.75 5,970 6,522 PROD2 DRILL TRIP P RIH tag liner @ 6661' (P/U 123k S/O 65k) Orient 141-set anchor & confirm w/ 1 Ok over pull -shear off w/ 35k Establish rotation ROT wt. 80k. 18:30 19:00 0.50 6,522 6,522 IPROD2 DRILL CIRC P Displace well w/ 8.7 ppg OBM. 10/27/2006 19:00 21:30 2.50 6,522 6,541 PROD2 DRILL MILL P Mill'B' Lateral window from 6529'to 1 I 6541' (Pump 30 bbl hi vis sweep @ 6536'). 21:30 22:15 0.75 6,541 6,559 PROD2 DRILL DDRL P Drill from 6541' to 6559'.(Gauge hole to 6543' 22:15 23:15 1.00 6,559 6,559 PROD2 DRILL REAM P Ream window & open hole interval 6527-6559' Circ: sweep out -check kill `S7L_ Q e ' rates P/U 108k S/O 70k ROT 80k. Slide thru window interval without pump. OK Monitor well pump pill & blow down top drive. 23:15 00:00 0.75 6,559 5,000 PROD2 DRILL TRIP P POH for drilling assembly SLM. 10/28/2006 00:00 00:15 0.25 6,175 6,175 PROD2 DRILL SFTY P PJSM-Topic=tripping out of hole. 00:15 01:30 1.25 6,175 115 PROD2 DRILL TRIP P POH from 6175' to 115'. (SLM .70 difference. 01:30 02:00 0.50 115 115 PROD2 DRILL OTHR P Down load MWD. 02:00 02:45 0.75 115 0 PROD2 DRILL PULD P Lay down MWD-milling assembly. 02:45 03:15 0.50 0 0 PROD2 DRILL OTHR P Clear & clean floor. 03:15 03:30 0.25 0 0 PROD2 DRILL OTHR P Drain stack pick up test it. & wear ring puller -pull wear ring & lay down same. 03:30 04:00 0.50 0 0 PROD2 DRILL OTHR P Pick up stack washer -flush stack & lay down same. 04:00 04:15 0.25 0 0 PROD2 DRILL OTHR P Pick up test it. & wear ring tool -set wear ring & lay down running tool. 04:15 04:30 0.25 0 0 PROD2 DRILL SFTY P PJSM-Topic=Changing saver sub. 04:30 05:30 1.00 0 0 PROD2 DRILL OTHR P Change saver sub. 05:30 06:45 1.25 0 0 PROD2 DRILL PULD P Make up BHA #9-bit-motor-nonmag float sub-stab-dmhoc-slimphase 4 w/d r+ewr hsae- wd-tm collar. 06:45 08:00 1.25 0 0 PROD2 DRILL OTHR P Up load MWD. 08:00 10:45 2.75 0 6,457 PROD2 DRILL TRIP P Continue make up BHA#9-1 stand non mag flex dc,s-xo-4 its. hwdp jars-1 it. hwd - RIH to 6457'.'. 10:45 11:00 0.25 6,457 6,559 PROD2 DRILL OTHR P Orient 10 deg. left -went thru window no problems. 11:00 12:00 1.00 6,559 6,574 PROD2 DRILL DDRL P Drlg. from6559' to 6574'. ADT-.11 AST .11 12:00 00:00 12.00 6,574 7,108 PROD2 DRILL DDRL P PJSM & drlg. 6 3/4" hole in'B' Lateral from 6574' to 7108'. (TVD 3657') AST-6.48 ART-1.88 ADT-8.36 P/U 112k S/O 65k ROT 85k TQ 5k ECD 9.8 Max gas 89 units. 10/29/2006 00:00 00:15 0.25 7,108 7,108 JPROD2 DRILL SFTY P PJSM-Topic=Drilling. 00:15 09:00 8.75 7,108 7,522 PROD2 DRILL DDRL P DrIg. 6 3/4" Horizontal hole from 7108' to 7522'. TVD 3691 P/U 115k S/O 64k ROT 84k TQ 5k ECD 9.8 Max gas 95 units.(Well out of zone.) 10/29/2006 09:00 09:15 0.25 7,522 DRILL TRIP NP POH from 7522' to 7111'. For 17,111 JPROD2 sidetracking. 09:15 10:15 1.00 7,111 7,155 JPROD2 DRILL OTHR NP Start troughing well to 7155'. For open hole sidetrack. 10:15 12:00 1.75 7,155 7,209 PROD2 DRILL DDRL NP Sidetracking well from 7155' to 7209' TVD 3662'. AST .48 hrs. 12:00 12:15 0.25 7,209 7,209 PROD2 DRILL SFTY NP PJSM-Topic=Hazard recognition. 12:15 16:30 4.25 7,209 7,522 PROD2 DRILL DDRL NP Drlg. from 7209' to 7522'. TVD 3670'. 16:30 00:00 7.50 7,522 7,922 PROD2 DRILL DDRL P Drlg. 6 3/4" horizontal hole in 'B' Lateral from 7522' to 7922' MD / 3673' TVD, PR 85 spm, 303 gpm, PP 3240, Torq OffBtt 5-6k , On btt 5-6k, ECD's 10.09, Max bg gas 86 units, Hrs on jars 24.88, Drlg total 88' of concretions, AST = 1.97 hrs ART= 2.59 hrs. 10/30/2006 00:00 00:15 0.25 7,922 7,922 PROD2 DRILL SFTY P PJSM-Topic=Drilling: 00:15 12:00 11.75 7,922 8,468 PROD2 DRILL DDRL P Drlg. 6 3/4" horizontal hole in'B' Lateral from 7922' to 8486'. TVD 3683'. ADT-8.79 AST-1.31 ART-7.48 P/U-120k S/0-64k ROT-84k TQ- 7k ECD-10.1 Max as-76 units. 12:00 12:15 0.25 8,468 8,468 PROD2 DRILL SFTY P PJSM-Topic=Drlg. & pinch points. 12:15 14:15 2.00 8,468 8,650 PROD2 DRILL DDRL P Drlg. from 8486' to 8650'. ART-1.1 AST-.83 ADT 1.93. 14:15 15:30 1.25 8,650 8,650 PROD2 DRILL SRVY NP After drlg. concretion @ 8630'-8635'-check survey @ 8650'-showed 29 deg. dogleg (30-35k) overpull & unable to slide @ 40-35k S/O wt. POH to 8414' for sidetrack #2. Orient 180 for sidetracking. 15:30 16:00 0.50 8,414 8,444 PROD2 DRILL DRLG NP Troughing from 8414' to 8444'. 16:00 21:30 5.50 8,444 8,650 PROD2 DRILL DDRL NP Drlg. from 8444' to 8650'. TVD 3638'. ART-.92 AST-2.48 ADT-3.40 hrs. 21:30 00:00 2.50 8,650 8,788 PROD2 DRILL DDRL P Drlg. 'B' Lateral from 8650' to 8788'. TVD 3689'. ART-.43 AST-.67 ADT-1.1 hrs. P/U 122k S/0-62k ROT-85k TQ-6k ECD-10.3 Max gas-90 units. SPR-25 s m 590 psi. 35 s m 880 psi. 10/31/2006 00:00 00:15 0.25 8,788 8,788 PROD2 DRILL SFTY P PJSM-Topic=Drilling Ahead. 00:15 12:00 11.75 8,788 9,547 PROD2 DRILL DDRL P Drig. 6 3/4" Horizontal hole in 'B' Lateral from 8788' to 9547'. TVD-3699'. ADT-7.18 AST-2.78 ART-4.4 hrs. P/U 125k S/O 60k ROT 83k TQ 7k ECD 10.6 Max gas 70 units. 12:00 12:15 0.25 9,547 9,547 JPROD2 DRILL SFTY P PJSM-Topic=Drlg. & connections. 10/31/2006 12:15 00:00 11.75 9,547 10,303 PROD2 DRILL DDRL P Drlg. 6 3/4" Horizontal hole in'B' Lateral from 9547' to 10303' MD. TVD 3703'. ADT-7.72 AST-2.64 ART-5.08 hrs. P/U 135k S/O 47k ROT 82k TQ 8k ECD 10.5 Max Gas 102 units. 11/01/2006 00:00 00:15 0.25 10,303 10,303 PROD2 DRILL SFTY P PJSM-Topic=Drlg. Ahead. 00:15 10:45 10.50 10,303 10,749 PROD2 DRILL DDRL P Drlg. 6 3/4" Horizontal hole in'B' Lateral from 10303' to 10749'. TVD 3712'. ADT-7.67 AST 3.7 ART-3.97 hrs. P/U 140k S/0-47k ROT-84k TQ-8-9k ECD-10.8 Max as-94 units. 10:45 12:00 1.25 10,749 10,471 PROD2 DRILL TRIP P Flow check -(Static) BROOH from 10749' to 10471'. 88 spm-3580 psi-90 rpm 8k TQ. 12:00 12:15 0.25 10,471 10,471 PROD2 DRILL SFTY P PJSM-Topic=BROOH. 12:15 15:30 3.25 10,471 6,457 PROD2 DRILL TRIP P Continue BROOH from 10471' to 6737' & POH from 6737' to 6457'. (Entered Window Slick). 15:30 17:00 1.50 6,457 6,457 PROD2 DRILL CIRC P Pump 35 bbl. hi-vis weighted sweep. Circ. & reciprocate around,@ 300 gpm 3100 psi 100 rpm (Returned 10% Excess) Continued circ second bottoms up. -monitor well -Static. Pump ill & blow down top drive. 17:00 20:00 3.00 6,457 0 PROD2 DRILL TRIP P POH-Lay down agitator & XO,S continue poh & stand back HWDP, ars & flex collars. 20:00 21:00 1.00 0 0 PROD2 DRILL OTHR P I Download MWD. 21:00 22:00 1.00 0 0 PROD2 DRILL PULD P Lay down MWD,stab,float sub,motor & bit. Clear floor. 22:00 22:15 0.25 0 0 PROD2 DRILL SFTY P PJSM-Topic=Test bope-high pressure. 22:15 23:00 0.75 0 0 PROD2 DRILL OTHR P Pull wear ring -set test plug -fill stack & choke. Make up floor valves -rig up test manifold. 23:00 00:00 1.00 0 0 PROD2 DRILL OTHR P Test BOPE 250-3000 psi. ( Witness test waived by Lou Grimaldi AOGCC 11/02/2006 00:00 00:15 0.25 0 0 PROD2 DRILL SFTY P PJSM-Topic=Testing BOPS. 00:15 03:00 2.75 0 0 PROD2 DRILL OTHR P Continue testing bope 250-3000 psi. OK. 03:00 03:30 0.50 0 0 PROD2 DRILL OTHR P Install wear ring. 03:30 04:30 1.00 0 0 PROD2 DRILL OTHR P Slip & cut 40' drlg. line. 04:30 05:00 0.50 0 0 PROD2 DRILL OTHR P Service top drive & drawworks. 05:00 06:00 1.00 0 0 PROD2 DRILL PULD P Pick up & make up BHA #10. 06:00 06:30 0.50 0 87 PROD2 DRILL OTHR P Upload MWD. 06:30 08:30 2.00 87 2,236 IPROD2 DRILL TRIP P RIH from 87'to 2236'. 11/02/2006 08:30 08:45 0.25 2,236 2,236 PROD2 DRILL �DHEQ P Shallow test MWD & break in bearings on geopilot. 08:45 10:00 1.25 2,236 6,530 PROD2 DRILL TRIP P Continue RIH from 2236' to 6530'. 10:00 10:30 0.50 6,530 61599 PROD2 DRILL OTHR NP Attempt to work geopilot assembly thru window. Would not go past 6599'. 50k overpull. 30k slack off. 10:30 12:00 1.50 6,599 3,075 PROD2 DRILL TRIP NP POH from 6599' to 3075'. 12:00 13:30 1.50 3,075 87 PROD2 DRILL TRIP NP Continue poh from 3075' to 87'. 13:30 14:00 0.50 87 0 PROD2 DRILL OTHR NP Download MWD-stand back MWD- eo ilot & bit. 14:00 15:15 1.25 0 0 PROD2 DRILL PULD NP Pick up hole opener assembly. 15:15 17:30 2.25 0 6,580 PROD2 DRILL TRIP NP RIH to 6580'. P/U 97k S/O 64k ROT 80k TQ 5k. 17:30 19:00 1.50 6,580 6,673 PROD2 DRILL REAM NP Ream & dress window 6580' to 6673'. Taking wt. @ top of window w/ window mill. 80 RPM 5-7k TQ. 19:00 20:00 1.00 6,673 6,767 PROD2 DRILL REAM NP Ream & Back ream from 6673' to 6767'. (2 passes) Set back stand & dress window from 6605' hole opener depth -window mill @ 6529' to 6673'. (1 pass -clean) Ream & backream 6673' to 6767'. Clean 20:00 21:15 1.25 6,767 6,767 PROD2 DRILL CIRC NP I Pump hi-vis weighted sweep around @ 300 gpm 1200 psi & 80 rpm. 21:15 21:45 0.50 6,767 6,487 PROD2 DRILL OTHR NP Work mill thru window without pump from 6760' to 6487'. 10 k bobble @ 6612'. 21:45 00:00 2.25 6,487 325 PROD2 DRILL TRIP NP Flow check -static. Pump pill -blow down top drive & poh from 6487' to 325'. 11/03/2006 00:00 00:15 0.25 325 325 PROD2 DRILL SFTY P PJSM-Topic=Tripping 00:15 00:45 0.50 325 0 PROD2 DRILL PULD NP Continue POH-lay down BHA #11. 00:45 01:00 0.25 0 0 PROD2 DRILL OTHR NP Clear & clean floor. 01:00 01:45 0.75 0 0 PROD2 DRILL PULD NP Pick up BHA #12. Upload MWD. 01:45 02:15 0.50 0 1,292 PROD2 DRILL TRIP NP RIH to 1292'. 02:15 02:45 0.50 1,292 1,292 PROD2 DRILL OTHR NP Shallow test MWD. 02:45 04:15 1.50 1,292 6,903 PROD2 DRILL TRIP NP RIH from 1292' to 6797'. Tagged up on concretion. Took 30k worked thru to 6903. 04:15 05:00 0.75 6,903 6,996 PROD2 DRILL REAM NP Reamed from 6903' to 6996'. 270 gpm 2000 psi 5-10k TQ P/U 105k S/O 65k. 05:00 07:00 2.00 6,996 9,797 PROD2 DRILL TRIP P Continue RIH =(Reamed from 8490 to 8583' & 8673' to 8704'. RIH to 9797'. 07:00 08:45 1.75 9,797 10,749 PROD2 DRILL REAM P Cautios ream from 9797' to 10749'. (No Fill 08:45 12:00 3.25 10,749 11,070 IPROD2 DRILL DDRL P Drlg. 6 3/4" Horizontal hole in'B' ( Lateral from 10749' to 11070'. 0 • 11/03/200612:00 12:15 0.25 11,070 11,070 PROD2 DRILL SFTY P I PJSM-Topic=Drilling. 12:15 00:00 11.75 11,070 12,103 PROD2 DRILL DDRL P Drlg. 6 3/4" Horizontal hole in 'B' Lateral from 11070' to 12103'. ADT 7.65 hrs. P/U-150k S/0-0 ROT-87k TQ-8-10k ECD-11.1 Max gas 181 units SPR-35 s m 890 psi. 11/04/2006 00:00 12:00 12.00 12,103 13,113 PROD2 DRILL DDRL P Drlg.6 3/4" Horizontal hole in 'B' Lateral from 12103' to 13113'. TVD 3752'. Fault @ 12145' MD TVD 3717'. 15' down throw to north -stayed in sand. ART 8.47 hrs. P/U-177k S/0-0 ROT-100k TQ-10k ECD-11.3 Max gas 121 units. 12:00 12:15 0.25 13,113 13,113 PROD2 DRILL SFTY P PJSM-Topic=making connections with new crew member. 12:15 21:30 9.25 13,113 13,922 PROD2 DRILL DDRL P Drlg. 6 3/4" Horizontal hole in 'B' Lateral from 13113' to 13922'. TVD-3773. ART-6.81 hrs. (Pump 35 bbl-vis wt. sweep) 21:30 22:00 0.50 13,922 13,922 PROD2 DRILL CIRC P Circ. sweep out (25% excess) Survey -check kill rates -monitor well -static. 22:00 00:00 2.00 13,922 12,665 PROD2 DRILL TRIP P BROOH w/ 307 gpm 3500 psi 130 rpm @ 60-70 fpm from 13922 to 12665. P/U-202k S/O- N/A ROT A 15k TQ 10k ECD-11.3 Maxgas-1 15 units 11/05/2006 00:00 07:30 7.50 12,665 6,530 PROD2 DRILL TRIP P BROOH from 12665' to 6530'. 3150 psi-130 rpm-300 gpm-TQ-9k. 3k overpull thru window. 07:30 08:45 1.25 6,530 6,530 PROD2 DRILL CIRC P Circ. bottoms up x 3 @ 85 spm-300 m-2200 psi TQ-5k. 08:45 11:30 2.75 6,530 10,635 PROD2 DRILL TRIP P RIH to 10635'-work thru tight spots @ 10339' & 10579'. 11:30 12:00 0.50 10,635 10,824 PROD2 DRILL REAM P Ream in hole from 10635' to 10824'. 40 s m 930 psi. 100 rm-TQ 8k. 12:00 12:15 0.25 10,824 10,825 PROD2 DRILL SFTY P PJSM-Topic=Reaming. 12:15 14:30 2.25 10,825 10,922 PROD2 DRILL REAM P Continue wash & ream from 10824' to 13922'. No Fill 14:30 17:00 2.50 10,922 10,922 PROD2 DRILL CIRC P Circ. & reciprocate -Pump 35 bbl. hi-vis weighted sweep @ 300 gpm 3900 psi-130 rpm -returned 25% excess. Continue circ max gas 66 units ECD 11.2 17:00 18:30 1.50 10,922 10,922 PROD2 DRILL CIRC P Displace well with 569 bbls. 8.7# SFOBM. Monitor well (Static) Blow down top drive. 18:30 00:00 5.50 10,922 4,288 PROD2 DRILL TRIP P POH from 13922' to 4288' (Pulled thru window slick 11/06/2006 00:00 01:15 1.25 4,288 91 PROD2 DRILL TRIP P PJSM- continue POH from 4288' to 91'. 01:15 02:00 0.75 91 91 PROD2 DRILL OTHR P Download MWD 02:00 03:15 1.25 91 0 IPROD2 DRILL PULD P Lay down BHA #12. 11/06/2006 03:15 03:45 0.50 0 0 fOMPZl' CASIN( SFTY P PJSM-Topic=running 4 1/2" slotted liner. 03:45 07:45 4.00 0 7,068 COMPZ CASIN( RNCS P RIH w/ 4 112" slotted liner 165its. P/U-84k S/O 57k. 07:45 08:45 1.00 7,068 7,068 COMPZ CASIN( OTHR P Make up receptacle -liner setting sleeve & running tool -establish rotating parameters with liner on drill pipe. 20 rpm 2-3k S/o 62k P/U rot-77k. 08:45 11:00 2.25 7,068 12,779 COMPZ CASIN( RUNL P RIH w/ liner on drill pipe from 7068' to 12779' ran out of down wt. P/U 165k. 11:00 12:00 1.00 12,779 13,153 COMPZ CASIN( RUNL P Rotate liner from 12779'to 13153'. 20 rpm 7k TQ 70k down weight. 12:00 12:15 0.25 13,153 13,153 COMPZ CASIN( SFTY P PJ SM-To pic= Rotate in hole with liner. 12:15 13:00 0.75 13,153 13,922 COMPZ CASIN( RUNL P Continue run in hole with liner rotating from 13153' to 13922'. P/U 170k. 13:00 14:00 1.00 13,922 13,912 COMPZ CASIN( OTHR P P/U to 13900' & drop ball -rotate & tag @ 13922'. Pick up to 13912'-pump ball on seat & pressure up to 3500#-release liner & confirm with 115k P/U-pressure up & shear out @ 4450 psi. '13' lateral top of liner @ 6742 MD. monitor well -static. 14:00 16:15 2.25 13,912 0 COMPZ CASIN( OTHR P POH from 6742'to 0.0 16:15 16:30 0.25 0 0 COMPZ CASIN( SFTY P PJSM-Topic=Cut & slip drlg. line (pinch points-wickers & hand placement) 16:30 17:30 1.00 0 0 COMPZ CASIN( OTHR P Cut & slip 74' drlg. line -inspect & adjust brakes -check crown-o-matic-lube blocks & top drive. 17:30 18:30 1.00 0 0 COMPZ CASIN( OTHR P Pick up whipstock retrieving assembl . 18:30 20:15 1.75 0 6,489 COMPZ CASIN( OTHR P RIH w/ fishing assembly from 0.0 to 6489'. 20:15 21:00 0.75 6,489 6,529 COMPZJ CASIN( OTHR P Wash -orient & latch whipstock @ 6529; Work & jar same free. Monitor well -static -blow down top drive. 21:00 00:00 3.00 6,529 0 COMPZ CASIN( OTHR P POH-Stand back DC,S & lay down oil jars. 11/07/2006 00:00 01:15 1.25 0 0 COMPZ RPCOh PULD P Fin POOH & LD whipstock and seal assembly, cleared rig floor 01:15 02:00 0.75 0 0 COMPZ RPCOh RURD P RU 4 1/2" handling tools and held PJSM on running hook hanger 02:00 04:00 2.00 0 375 COMPZ RPCOh PULD P MU hook hanger assembly with ECP packer and MWD tool, RIH 1 std of DP to 375' and shallow tested MWD 04:00 07:30 3.50 375 6,804 COMPZ RPCOIV TRIP P RIH with hook hanger assembly from 375' and tagged up in mother bore at 6,715' POOH to 6,529' RIH and tagged XO at 6,804' 11/07/2006 07:30 08:30 1.00 6,804 6,531 COMPZ RPCON TRIP P PU Hooked hanger 1st at 6,796', unhooked and went deeper hooking btm of assembly at 6,804', unhooked and re -hooked at same spot setting 30K wt down, top of hook hanger at 6,531' 08:30 09:00 0.50 6,531 6,531 COMPZ RPCON DHEQ P Dropped ball and pumped down to seat, pressured up to 2,000 psi then increased to 2,800 psi and inflated ECP pkr with 1/4 bbl of SFMOBM, released running tool. 09:00 10:00 1.00 6,531 6,431 COMPZ RPCOh CIRC P POOH 1 std to 6,431' and circ btms up at 290 gpm at 925 gpm, max gas 31 units 10:00 13:00 3.00 6,431 0 COMPZ RPCON TRIP P Monitored well -static, POOH from 6,431' and LID hook hanger running tool and MWD tool, cleared rig floor. 13:00 13:30 0.50 0 0 COMPZ RPCON RURD P RU to run LEM assembly and held PJSM 13:30 15:30 2.00 0 519 COMPZ RPCOA PULD P MU " B" sand LEM assembly with MWD, RIH with 4 1/2" bent it with seals, 1-it 4 1/2" tbg, DB-6 nipple 2, its tbg, 1-pup it, LEM assembly with 9 its of 4 1/2", 12.6#, L-80 IBTM tbg, CSBR and ZXP pkrRiH to 519', st wt up and do 40K 15:30 18:45 3.25 519 6,681 COMPZ RPCON TRIP P RIH with LEM from 519', shallow tested MWD at 610', cunt to R I H to 6;681', st wt up 11 OK, do wt 56K 18:45 19:30 0.75 6,681 6,704 COMPZt RPCOh OTHR P Est circ and obtained LEM orientation rotated string 90 then slacked off and saw seals go thru hook assembly then latched LEM, with pump on LEM was oriented to 19 deg left oh high side(orig window cut at 16 deg left), PU 30 K over st wt W/O unlatching to confim snap in and then set 30K back down 19:30 20:00 0.50 6,704 6,198 COMPZ RPCOh OTHR P Dropped 1 3/4" ball and pumped onto seat, pressured up to 2,500 psi to set ZXP packer, press. up to 3,200 psi and saw neautralizer tool shift, then pressured up to 4,200 psi to release from LEM, set top of ZXP packer at 6,198' 20:00 20:15 0.25 6,198 6,198 COMPZ RPCON DHEQ P Pressure tested ZXP pkr and annulus to 2,500 psi for 10 min, good test and charted same 20:15 22:00 1.75 6,198 20 COMPZP RPCON TRIP P PU to 105K and running tool was released from LEM, POOH from 6,198' to the running tool, hole fill took 2.7 bbls over calc fill 22:00 23:15 1.25 20 0 COMPZI1 RPCON PULD P POOH and LID LEM running tool and MWD tool, cleared riq floor I AJOW 2MOW � W71=11 MWEI �'XWOWUAWAU V�XZW'Wevlfl: lrlfrd %.AMU �"'Z'OULIUQUtIR! A A_U W tWOMP", 11/0712006 23:15 bom 0.75 0 0 COMPZl' RPCON OTHR P RIH with 3 stds super sliders, POOH with 1 std inspecting 2 sliders and found to be worm in the body area of slider 11/08/2006 00:00 00:15 0.25 0 0 COMPZl' RPCON OTHR P POOH and inspected super sliders and observed slight wear on tube of DP 00:15 01:30 1.25 0 0 PROW RIGIVIN SVRG P Changed out top drive saver sub 01:30 03:15 1.75 0 150 PROD3 STK PULD P MU whipstock assembly RIH to 150', MU seal assembly, 2-jts 3 1/2" DP with pup jt for space out then MU anchor and whipstock along with mills RIH to 150' 03:15 04:45 1.50 150 215 PROD3 STK PULD P MU MWD tool, oriented and uploaded I I same, MU bumper sub RIH to 215' 04:45 07:45 3.00 215 5,949 JPROD3 STK TRIP P RIH to 400'and shallow tested MWD, cont to RIH to 5,949' 07:45 09:30 1.75 5,949 6,094 PROW STK OTHR P Made MADD pass of K-1 3 from 5,949' to 6,019', (corr MWD 4') RIH and tagged top of B Lat LEM at 6,198', oriented whipstock to 12 deg. left of high side, setting same with top of whipstock at 6,094' 09:30 10:00 0.50 6,094 6,094 PROW STK CIRC P Displaced hole over from SFMOBM I I I I back to 8.7 ppg MOBM 10:00 13:30 3.50 6,094 6,108 PROW STK WPST P Milled window in 7 5/8" csg for "D" sand lateral from 6,094' to 6,108', milled window at 5-1 OK WOM, 90-110 rpm's, 5-6K ft-lbs torque, 80 spm, 290 gpm at 1,850 psi, rot wt 88K, up wt 106K, do wt 75K 13:30 16:15 2.75 6,108 6,142 PROW STK WPST P Cont to mill window and drilled from 6,108' to 6,142' MD/3,564'TVD, gauge hole to 6,124', pumped sweep at 6,132'. 16:15 17:00 0.75 6,142 6,142 PRODS STK CIRC P Fin circ sweep out of the hole with 20% increase in cuttings and fin circ hole clean while working the mills thru the window, circ at 290 gpm, 1,850 psi, monitored well -static, pumped dry job 17:00 19:00 2.00 6,142 115 PRODS STK TRIP P POOH with milling assembly from 6,142' to MWD at 115'. 19:00 20:00 1.00 115 0 PROW STK PULD P Downloaded MWD and POOH LD same along with the mills, upper mill was full gauge 20:00 20:30 0.50 0 0 PROD3 STK OTHR P Flushed out BOP stack and cleared rig floor. 20:30 00:00 3.50 0 1,600 PROD3 DRILL OTHR P RIH with 4" DP to 1,600' adjusting super sliders down 1-2'while RIH, have RIH with 17 of 45 stds as of time. 11/09/20100:00 02:15 2.25 1,600 4,230 PROW DRILL OTHR —report P Cont to RIH relocating super sliders down 1-2'on 4" DP, RIH with an add. 28 stds (45 total) to 4,230' 11/09/2006 02:15 03:45 1.50 4,230 0 PRODS DRILL OTHR P Monitored well -static, POOH from 4,230' standing back DP on drillers side 03:45 05:15 1.50 0 11220 PROD3 DRILL OTHR P RIH with 13 stds of 4" DP installing 1 super slider per jt, (39 total) RIH to 1,220' 05:15 06:00 0.75 1,220 0 PROD3 DRILL OTHR P POOH from 1,220'standing back 13 stds of add. DP with super sliders on drillers side (58 total stds w/super sliders in derrick 06:00 08:15 2.25 0 368 PRODS DRILL PULD P MU 6 3/4" BHA # 14 with Geopilot RIH to 368'. MU 6 3/4" Hycalog concretion bit with Geopilot, MWD and LWD tools uploading same. 08:15 09:15 1.00 368 450 PROD3 DRILL DHEQ P RIH with BHA #14 from 368' to 450' and shallow tested MWD tool theca broke in seals on Geopilot. 09:15 11:30 2.25 450 6,062 PROD3 DRILL TRIP P RIH from 450' to 6,062' 11:30 12:00 0.50 6,062 6,142 PROD3 DRILL REAM P Est circ at 6,062' then washed down thru window at 6,094' to 6,108', cont to wash and ream to btm at 6,142'. PU wt 97K, do wt 65K 12:00 13:30 1.50 6,142 6,245 PRODS DRILL DDRL P Drilled 6 3/4" hole in "D" sand from 6,142' to 6,245' MD/3,573' TVD (103') ADT .89 hrs, 5-91K wob, 60-100 rpm's, 82 spm, 293 gpm at 2,150 psi, off and on btm torque 4-5K ft-lbs, rot wt 86K, up wt 11 OK, do wt 67K, clean hole ECD with 8.7 ppg MOBM is 9.6 ppg, ave ECD 9.7 ppg, max gas 63 units, 88.6 hrs on jars. NOTE: Drilled concretion at 6,203' and saw 25 deg. dogleg at Geopilot 13:30 14:45 1.25 6,245 6,060 PROD3 DRILL CIRC T POOH to 6,060' and circ btms up while evaluating Geopilot tool, attempted to send commands to tool and tool would not take the command, decision was made to POOH, circ hole at 293 gpm at 2,000 psi 14:45 16:30 1.75 6,060 85 PRODS DRILL TRIP T POOH from 6,060' to 85', stood back HWDP, jars and NMFDC's 16:30 18:30 2.00 85 0 PROD3 DRILL PULD T Downloaded MWD, POOH LD MWD and Geopilot, found Geopilot housing swelled slightly at the electronics housing connection with oil leaking from housing 18:30 20:00 1.50 0 85 PROD3 DRILL PULD T MU BHA #15 with backup Geopilot tool and RR Hycalog concretion bit with MWD/LWD RIH to 85' then uploaded the MWD tool. 20:00 20:45 0.75 85 365 PROD3 DRILL DHEQ T RIH with HWDP, jars and NMFDC's to 365' then shallow tested MWD and broke in seals on Geopilot 20:45 22:15 1.50 365 6,062 PROD3 DRILL TRIP T RIH with BHA #15 from 365' to 6,062' 11/09/2006 22:15 23:00 0.75 6,062 6,162 JPROD3 DRILL ICIRC T Est circ and washed down from 6,062' thru the window to 6,162'. 23:00 00:00 1.00 6,162 6,180 PRODS DRILL DDRL T Troughing well from 6,162' to 6,180' to low side of hole to sidetrack around concretion. 11/10/2006 00:00 00:30 0.50 6,162 6,180 PRODS DRILL DDRL T Cont to troughing hole from 6,162' to 6,180' 00:30 02:45 2.25 6,180 6,187 PRODS DRILL DDRL T Time drilled to lowside hole from 6,180' to 6,187', time drilled at 3'/hr, ADT 2 hrs. 02:45 06:45 4.00 6,187 6,245 PRODS DRILL DDRL T Cont to lowside hole from 6,187' to 6,245', ADT 2.08 hrs 06:45 12:00 5.25 6,245 6,619 PRODS DRILL DDRL P Drilled 6 3/4" hole in "D" sand lateral with geopilot from 6,245' to 6,619' MD/ 3,598' TVD (374') ADT 3.82 hrs, 8-11 K wob, 70-90 rpm's, 80 spm, 284 gpm, 2,050 psi, torque on and off btm 5K ft-Ibs, rot wt 84K, up wt 110K, do wt 64K, max gas 65 units, 8.75 ppg MOBM, ave ECD 9.8 12:00 21:00 9.00 6,619 7,230 PRODS DRILL DDRL P Drilled 6 3/4" hole in "D" sand lateral with geopilot from 6,619' to 7,230' MD/ 3,597' TVD (611') ADT 6.17 hrs, 4-1 OK wob, 120 rpm's, 87 spm, 309 gpm, 2,350 psi, torque on and off btm 5K ft-Ibs, rot wt 85K, up wt 110K, do wt 67K, ave BGG 65 units, max gas 125 units, 8.75 ppg MOBM, ave ECD 9.85 ppg. Hole began walking right 3-4 deg/100' and would go out of target, decision was made to pull back and sidetrack well. NOTE: Drilled thru several concretions 21:00 21:30 0.50 7,230 6,902 JPROD3 DRILL TRIP NP POOH from 7,230' to 6,902' 21:30 23:00 1.50 6,902 6,930 PRODS DRILL DDRL NP Troughed well from 6,902' to 6,930' 23:00 00:00 1.00 6,930 6,931 PRODS DRILL DDRL NP Began to time drill well for sidetracking, drilled from 6,930' to 6,931' MD/3,593' TVD, ADT .5 hr. 11/11/2006 00:00 01:00 1.00 6,931 6,935 PRODS DRILL DDRL NP Cont to time drill for sidetracking well from 6,931' to 6,935', ADT 1 hr 01:00 06:45 5.75 6,935 7,230 PRODS DRILL DDRL NP Drilled 6 3/4" hole from 6,935' to 7,230' MD/ 3,595' TVD, ADT 5.9 hrs, drilled thru several concretions, (7,230' was oriq. hole depth prior to sidetrack) 11/11/2006 06:45 10:45 4.00 7,230 7,540 PROD3 DRILL DDRL P Directionally drilled 6 3/4" hole with geopilot from 7,230' to 7,540' MD/ 3,600' TVD (310'), ADT 1.8 hrs, 5-8K wob, 110 rpm's, 80 spm, 285 gpm, 2,100 psi, on/off btm torque 5K ft-Ibs, rot wt 81 K, up wt 110K, do wt 60K, 8.7 ppg MOBM, ave ECD 9.9 ppg, ave BGG 40 units, max gas 210 units, still unable to overcome right hand turn with geopilot after sidetracking well. Decison was made to POOH and RIH with motor assembly 10:45 13:30 2.75 7,540 6,062 PROD3 DRILL REAM T Backreamed out of hole from 7,540' to 6,249', then pumped out of hole thru window to 6,062', BROOH at 100 rpm's, 270 gpm at 1,850 psi. no roblems BROOK 13:30 13:45 0.25 6,062 6,062 PROD3 DRILL OWFF T Monitored well -static, pumped dry job 13:45 16:00 2.25 6,062 92 PROD3 DRILL TRIP T POOH from 6,062' to 92', stood back HWDP, jars and NMFDC's 16:00 18:15 2.25 92 0 PROD3 DRILL PULD T Downloaded MWD then POOH LD geopilot and bit, cleared rig floor. 18:15 20:15 2.00 0 90 PROD3 DRILL PULD T MU BHA #16 with new Hycalog concretion bit on a 1.5 deg. bend motor and MWD/LWD RIH to 90' then uploaded MWD 20:15 21:45 1.50 90 1,227 PROD3 DRILL TRIP T RIH from 90' to 1,134', then shallow tested MWD at 270 gpm, 1,600 psi, MU Andergauge Agitator and shock tool RIH to 1,227', checked pressure and at 270 gpm had 1,900 psi (300 psi increase from Agitator tool). 21:45 00:00 2.25 1,227 6,082 PROD3 DRILL TRIP T RIH from 1,227' to 6,082' 11/12/2006 00:00 01:00 1.00 6,082 6,082 PROD3 RIGMN SVRG P Slip and cut 65' of drlg line 01:00 02:30 1.50 6,082 7,540 PROD3 DRILL TRIP T Cont to RIH from 6,082' to btm at 7,540`, above TOW at 6,082' oriented to 14 deg. left, RIH and tagged top of window at 6,094', (WS was originally set at 14 left) PU and oriented to high side and went thru window, RIH to 7,483' then washed 57' to btm at 7,540 with no other problems 02:30 12:00 9.50 7,540 8,133 PROD3 DRILL DDRL P Directionally drilled 6 3/4" hole with 1.5 deg bend motor in "D" sand lateral from 7,540' to 8,133' MD/ 3,607' TVD (593') ART 2.69 hrs, AST 3.09 hrs, 2-5K wob, 80 rpm's, 74 spm, 265 gpm, off btm pressure 2,600 psi, on btm 2,700 psi, off btm torque 5K ft-Ibs, on btm torque 6K ft-Ibs, rot wt 80K, up wt 120K, do wt 62K, 8.75 ppg MOBM, ave ECD 10.15 ppg, ave BGG 35 units, max gas 102 units, drilled thru 6 concretions for a total of 50'. 11/12/2006 12:00 00:00 12.00 8,133 8,806 PRODS DRILL DDRL P Directionally drilled 6 3/4" hole with 1.5 deg bend motor in "D" sand lateral from 8,133' to 8,806' MD/ 3,616' TVD (673') ART 4.79 hrs, AST 2.11 hrs, 2-1 OK wob, 80 rpm's, 85 spm, 300 gpm, off btm pressure 3,150 psi, on btm 3,300 psi, off btm torque 6K ft-Ibs, on btm torque 7K ft-Ibs, rot wt 83K, up wt 125K, do wt 58K, 8.7 ppg MOBM, ave ECD 10.0 ppg, ave BGG 35 units, max gas 93 units, drilled thru 9 concretions for a total of 74'. 11/13/2006 00:00 12:00 12.00 8,806 9,460 PROD3 DRILL DDRL P Directionally drilled 6 3/4" hole with 1.5 deg bend motor in "D" sand lateral from 8,806' to 9,460' MD/ 3,617' TVD (654') ART 3.52 hrs, AST 3.85 hrs, 5-8K wob, 80 rpm's, 77 spm, 274 gpm, off btm pressure 2,800 psi, on btm 2,950 psi, off btm torque 6,500K ft-Ibs, on btm torque 7K ft-Ibs, rot wt 80K, up wt 135K, do wt 54K, 8.65 ppg MOBM, ave ECD 10.2 ppg, ave BGG 35 units, max gas 80 units, drilled thru 5 concretions for a total of 70'. 12:00 14:15 2.25 9,460 9,660 PRODS DRILL DDRL P Drilled from 9,460' to 9,660' MD/3,618', 200' ART 2.55 hrs, AST .54 hrs 14:15 14:30 0.25 9,660 9,660 PRODS DRILL SFTY P Held kick while drilling drill, met before and after drill and had a good response during the drill and debriefing 14:30 00:00 9.50 9,660 10,174 PRODS DRILL DDRL P Directionally drilled 6 3/4" hole with 1.5 deg bend motor in "D" sand lateral from 9,660'to 10,174' MD/ 3,622' TVD (514') ART 3.49 hrs, AST 1.07 hrs, 5-8K wob, 85 rpm's, 80 spm, 280 gpm, off btm pressure 3,150 psi, on btm 3,300 psi, off btm torque 7K ft-Ibs, on btm torque 7K ft-Ibs, rot wt 83K, up wt 147K, do wt 48K, 8.7 ppg MOBM, ave ECD 10.5 ppg, ave BGG 35 units, max gas 92 units, drilled thru 6 concretions for a total of 50'. Pumped, wt'd hi vis sweep at 10,084' with 20% increase in cuttings 11/14/2006 00:00 04:00 4.00 10,174 10,330 PRODS DRILL DDRL P Directionally drilled 6 3/4" hole with 1.5 deg bend motor in "D" sand lateral from 10,174' to 10,330' MD/ 3,632` TVD (154') ART 1.59 hrs, AST 1.23 hrs, 5-8K wob, 85 rpm's, 80 spm, 280 gpm, off btm pressure 3,100 psi, on btm 3,250 psi, off btm torque 8K ft-Ibs, on btm torque 8K ft-Ibs, rot wt 84K, up wt 153K, do wt 40K, 8.7 ppg MOBM, ave ECD 10.5 ppg, ave BGG 35 units, max gas 76 units, drilled thru 2 concretions for a total of 39'. 11/14/2006 04:00 04:15 0.25 10,330 10,330 PROD3 DRILL SFTY P Held kick while drilling drill, had a good response from the crew and good discussion after the drill with the crew. Circ hole to clear BHA during drill 04:15 04:30 0.25 10,330 10,330 PROD3 DRILL OWFF P Monitored well -static 04:30 07:15 2.75 10,330 8,697 PROD3 DRILL REAM P Backreamed out of the hole from 10,330' to 8,697', BROOH at 80 rpm's with 6-9K ft-Ibs torque, 275 gpm at 3,000 psi 07:15 09:00 1.75 8,697 5,989 PROD3 DRILL TRIP P POOH wet on elevators from 8,697' thru window to 5,989' (TOW @ 6,094'), oriented to high side and pulled thru window with no problems 09:00 10:00 1.00 5,989 5,989 PROD3 DRILL CIRC P Circ 2 X btms up at 5,989', circ at 300 gpm at 2,900 psi, 40 rpm's and 4K ft-Ibs torque 10:00 12:30 2.50 5,989 90 PROD DRILL TRIP P Monitored well -static, pumped dry job and POOH from 5,989' to 90', stood back HWDP, jars and NMFDC's 12:30 14:45 2.25 90 0 PROD3 DRILL PULD P Downloaded MWD; POOHLD BHA #16, LID MWD and motor, cleared rig floor 14:45 15:15 0.50 0 0 PROD3 DRILL PULD P Pulled wear bushing 15:15 00:00 8.75 0 0 PROD3 WELCT BOPE P RU and began testing BOPE, testing rams, valves and manifold to 250 psi low and 3,000 psi high including annular, manual choke line valve failed, changed out same and re tested and ck'd ok. NOTE: Jeff Jones with AOGCC waived witnessing of test. 11/15/2006 00:00 01:15 1.25 0 0 PROD3 WELCT BOPE P Fin. testing BOPE, tested both VBR's and annular with 4 1/2" tb , RD 01:15 01:30 0.25 0 0 PROD3 DRILL PULD P Installed wear bushing 01:30 02:15 0.75 0 0 PROD3 RIGMN SVRG P Serviced top drive and inspected saver sub and weight indicator 02:15 04:30 2.25 0 85 PROD3 DRILL PULD P MU BHA #17 RIH to 85', MU 6 3/4" RR Hycalog concretion bit with new Geopilot tool and LWD/MWD tool, uploaded MWD 04:30 05:00 0.50 85 416 PROD3 DRILL TRIP P R I H with BHA #17 from 85' to 416'. 05:00 05:30 0.50 416 416 PROD3 DRILL DHEQ P Shaloow tested MWD and broke in seals on Geo ilot. 11/15/2006 05:30 11:45 6.25 416 10,330 PRODS DRILL TRIP P RIH from 416' to btm at 10,330, RIH thru window with no prob., cont RIH and set down at 7,900', washed down from 7,900' to 8,115' (215'), RIH from 8,115' and set down at 8,675' (560% washed down from 8,675' to 8,769' (94'), RIH from 8,769' to 10,076' (1,307') and washed down from 10,070' to btm at 10,330% washed at 280 gpm, 2,650 psi, 100 rpm's with 7K ft-Ibs torque 11:45 00:00 12.25 10,330 10,585 PRODS DRILL DDRL P Directionally drilled 6 3/4" hole with Geopilot in "D" sand lateral from 10,330' to 10,585' MD/ 3,640' TVD (255') ADT 8.81 hrs, 5-1 OK wob, 125 rpm's, 86 spm, 305 gpm, 2,750 psi, off btm torque 7.51K ft-Ibs, on btm torque 7K ft-Ibs, rot wt 85K, up wt 140K, do wt 40K, 8.65 ppg MOBM, ave ECD 10.5 ppg, ave BGG 30 units, max gas 80 units, drilled thru 6 concretions for a total of 48'. 11/16/2006 00:00 12:00 12.00 10,585 11,185 PRODS DRILL DDRL P Directionally drilled 6 3/4" hole with Geopilot in "D" sand lateral from 10,585' to 11,185' MD/ 3,650' TVD (600') ADT 8.22 hrs, 3-1 OK wob, 90-100 rpm's, 72-86 spm, 250-305 gpm, 2,000 to 2,600 psi, off btm torque 8K ft-Ibs, on btm torque 8K ft-Ibs, rot wt 83K, up wt 145K, do wt 35K, (blk wt) 8.7 ppg MOBM, ave ECD 10.4 ppg, ave BGG 40 units, max gas 97 units, drilled thru 8 concretions for a total of 74'. 12:00 00:00 12.00 11,185 11,941 PRODS DRILL DDRL P Directionally drilled 6 3/4" hole with Geopilot in "D" sand lateral from 11,185' to 11,94V MD/ 3,648' TVD (756') ADT 7.97 hrs, 4-8K wob, 120 rpm's, 86 spm, 305 gpm, 2,700 psi, off btm torque 8.5K ft-Ibs, on btm torque 8.51K ft-Ibs, rot wt 83K, up wt 155K, do wt 35K, (blk wt) 8.7 ppg MOBM, ave ECD 10.9 ppg, ave BGG 50 units, max gas 103 units, drilled thru 1 concretion for a total of 6'. 0 • 11/17/2006100:00 112:00 1 12.00 111,941 112,688 IPROD3 I DRILL I DDRL 12:00 1 13:45 1 1.75 112,688 112,874 JPROD3 I DRILL I DDRL P Directionally drilled 6 3/4" hole with Geopilot in "D" sand lateral from 11,941' to 12,688' MD/ 3,669' TVD (74T) ADT 8.38 hrs, 5-91K wob, 120 rpm's, 86 spm, 305 gpm, 2,600 psi, off btm torque 9K ft-Ibs, on btm torque 9K ft-Ibs, rot wt 87K, up wt 175K, do wt 35K, (blk wt) 8.7 ppg MOBM, ave ECD 10.9 ppg, ave BGG 40 units, max gas 330 units, drilled thru 7 concretions for a total of 47'. Pumped 35 bbl wt'd (2# over mw) hi vi sweep at 12,220' and had 30% increase in cuttings back from sweep P Drilled from 12,688' to 12,874' MD/ 3,672' TVD (186') ADT 1.75 hrs, pumped 35 bbl wt'd hi vis sweep (2# over mw) Sperry Sun's Geo-Span 13:45 15:00 1.25 12,874 12,874 PRODS DRILL CIRC NP Changed out Sperry Sun's Geo-span unit on rig floor due to washout and fin circ out sweep, had 15% increase in cuttings back from sweep, circ hole at 270 gpm at 2,250 psi and 120 rpm's 15:00 00:00 9.00 12,874 13,154 PRODS DRILL DDRL P Directionally drilled 6 3/4" hole with Geopilot in "D" sand lateral from 12,874' to 13,154' MD/ 3,689' TVD (280') ADT 5.87 hrs, 8-91K wob, 120-130 rpm's, 86 spm, 305 gpm, 3,250 psi, off btm torque 1 OK ft-Ibs, on btm torque 9K ft-Ibs, rot wt 85K, up wt 180K, do wt 35K, (blk wt) 8.7 ppg MOBM, ave ECD 11.3 ppg, ave BGG 35 units, max gas 83 units, drilled thru 2 concretions for a total of 45'. Pumped 35 bbl wt'd (2# over mw) hi vi sweep at 13,015' and had a 15% increase in cuttings back from sweep 11/18/2006 00:00 10:15 10.25 13,154 13,924 PRODS DRILL DDRL P Directionally drilled 6 3/4" hole with Geopilot in "D" sand lateral from 13,154' to 13,924' MD/ 3,702' TVD (770') ADT 6.7 hrs, 4-91K wob, 130 rpm's, 88 spm, 305 gpm, 3,500 psi, off btm torque 10.51K ft-Ibs, on btm torque 1 OK ft-Ibs, rot wt 87K, up wt 190K, do wt 35K, (blk wt) 8.7 ppg MOBM, ave ECD 11.55 ppg, ave BGG 35 units, max gas 83 units 140 10:15 12:00 1.75 13,924 13,924 PRODS RIGMN SVRG P Changed out swivel packing on top drive, Stood back 1 std then MU circ. head pin and circ hole at 125 gpm at 810 psi while changing out swivel. • 11/18/2006 12:00 13:15 1.25 13,924 14,000 PROD3 DRILL DDRL P Drilled 6 3/4" hole from 13,924' to 14,000' MD/3,705' TVD (76') ADT .78 hrs, "D" lateral T.D. 4-9K wob, 130 rpm's, 88 spm, 305 gpm, 3,500 psi, off btm torque 10.5K ft-Ibs, on btm torque 1 OK ft-Ibs, rot wt 87K, up wt 190K, do wt 35K, (blk wt) 8.7 ppg MOBM, ave ECD 11.55 ppg, ave BGG 35 units, max qas 83 units 140 13:15 13:45 0.50 14,000 14,000 PROD3 DRILL CIRC P Circ hole to clear BHA, took slow pump rates and monitored well -static. 13:45 00:00 10.25 14,000 7,368 PROD3 DRILL REAM P Backreamed out of hole from 14,000' to 7,368'. BROOH at 300 gpm, 3,150 psi and 100 rpm's with 7K ft-Ibs torque, no problems BROOK 11/19/2006 00:00 01:00 1.00 7,368 6,061 PROD3 DRILL REAM P Cont to BROOH from 7,368' to 6,248'. BROOH at 310 gpm, 2,300 psi and 130 rpm's, POOH from 6,248' thru window to 6,061' TOW @ 6,094' 01:00 02:15 1.25 6,061 6,061 PROD3 DRILL CIRC P Circ hole clean at 6,061', pumped 35 bbl wt'd hi vis sweep (2# over mw) and circ out of hole with no increase in cuttings, circ an add. btms up and hole was clean, circ hole at 312 gpm at 2,300 psi and 100 rpm's 3K ft-Ibs torque 02:15 03:45 1.50 6,061 6,061 PROD3 RIGMN SVRG P Held PJSM then slip and cut 71' of drIg line and serviced top drive. 03:45 11:30 7:75 6,061 14,000 PROD3 DRILL TRIP P RIH from 6,061' to 10,350' when we lost down wt, washed and reamed from 10,350' to 13,800', washed down at 50 spm, 178 gpm at 1,500 psi and 100 rpm's, increased rates washing down from 13,800' to 14,000' at 312 gpm, 3,800 psi and 120 rpm's. no other problems RIH. 11:30 15:15 3.75 14,000 14,000 PROD3 DRILL CIRC P Circ btms up at 14,000', circ btms up at 312 gpm at 3,700 psi and 120 rpm's, then displaced hole over from 8.7 ppg MOBM to 8.7 ppg SFMOBM, circ hole at 290 gpm at 3,300 psi and 120 rpm's, st wt up 225K 15:15 15:45 0.50 14,000 14,000 PRODS DRILL OWFF P Monitored well -static, dropped 1 7/8" rabbit on a wire. 15:45 21:45 6.00 14,000 367 PROD3 DRILL TRIP P POOH wet on elevators from 14,000' to BHA #17 at 367', calc hole fill 79 bbls, actual fill 99 bbls. 21:45 22:45 1.00 367 85 PROD3 DRILL PULD P POOH from 367'to 85' LD HWDP, jars and NMFDC's 22:45 00:00 1.25 85 85 PROD3 DRILL PULD P Downloaded MWD and began to LD same 11/20/2006 00:00 01:00 1.00 85 0 PROD3 DRILL PULD P Fin POOH and LID BHA #17, cleared rig floor. 01:00 01:30 0.50 0 0 COMPZ CASIN(I RURD P RU Doyon's 4 1/2" liner running equip. 11/20/2006 01:30 01:45 0.25 0 0 COMPZ CASIN( SFTY P Held PJSM with rig crew, tong operator and Baker rep on running of liner and hazard's associated with the 'ob. 01:45 06:30 4.75 0 7,618 COMPZ CASIN( PUTB P RIH with 4 1/2" "D" lateral liner to 7,618', PU and RIH with 177 jts of 4 1/2", 11.6#, L-80 BTC liner, ran 9 blanks and 168 slotted, used torque rings on jts 65 thru 177, 177 stop rings and 177 H draform centralizers. 06:30 07:30 1.00 7,618 7,782 COMPZ CASIN( PUTB P MU Baker receptacle jt with "HR" liner running sleeve and liner running tool, RIH with 1 std of DP to 7,782', est rot at 20 rpm's and 3K ft-Ibs torque, st wt up 87K, do wt 57K and 72K rot. wt 07:30 10:45 3.25 7,782 12,323 COMPZ CASIN( RUNL P RIH with liner on 4" DP from 7,782' and ran out of slack off wt at 12,323' 10:45 14:00 3.25 12,323 13,985 COMPZ CASIN( RUNL P Rotated liner down from 12,323' to 13,967' when torque limited out at 20 rpm's and 11 K ft-Ibs torque, increased torque to 12.5K and est circ then washed liner down from 13,976' and tagged btm at 14,000', picked up to 13,985'. wash and rotated liner down at 124 gpm at 500 psi, 30 rpm's and 12.5k ft-Ibs torque, liner wt up 225K, rotating wt 90K, rot. do wt 75K 14:00 15:00 1.00 13,985 6,305 COMPZ CASIN( OTHR P Dropped 1 3/4" setting ball and pumped down to seat at 3 bpm, 500 psi, with ball on seat pressured up to 3,000 psi to release liner, then pressured up to 4,000 psi to shear ball seat, (took 3 attempts to shear) PU and liner was released, st wt up 150K. 15:00 15:15 0.25 6,305 6,305 COMPZ CASIN( OTHR P Monitored well -static 15:15 18:45 3.50 6,305 0 COMPZ CASIN( RUNL P POOH from 6,305', while POOH thru window washed across whipstock slide then cont. to POOH and LID Baker's liner running tool, cleared rig floor. 18:45 19:45 1.00 0 241 COMPZ FISH PULD P MU Bakers whipstock retrieving assembly RIH to 241', MU ret. hook, 1-jt HWDP, bumper sub, oil jar, flt sub, XO and 2-stds hybrid pushpipe 19:45 22:15 2.50 241 6,099 COMPZIN FISH TRIP P RIH with whipstock retrieving assembly from 241' to 6,099' to whipstock slot ! 0 11/20/2006 22:15 00:00 1.75 6,099 6,099 COMPZ FISH FISH P Est circ at 188 gpm at 500 psi, st wt up 11 OK, do wt 67K then began to attempt whipstock, 1st by washing across WS face then W/O pump, sat down in slot twice with no hook. Note while PU to above WS, would pull 20K over at 6,088, slack off and rotate string to free up and PU to clear above 6,088, happened a couple of times but were able to get above spot. 11/21/2006 00:00 02:15 2.25 6,099 6,099 COMPZ FISH FISH P Made several attempts to hook whipstock-unsuccessfull. P/U-115k S/0-65k ROT-85k. 02:15 02:30 0.25 6,099 6,099 COMPZ FISH OTHR P Flow Check -Static -Blow down top d rive. 02:30 05:00 2.50 6,099 0 COMPZ FISH TRIP P POH-Lay down retrieving hook-1 it. 3 1/2" HWDP-bumper sub -oil jars-xo & float sub. 05:00 05:30 0.50 0 0 COMPZ FISH OTHR P Clear & clean rig floor 05:30 06:00 0.50 0 0 COMPZ FISH OTHR P Service drawworks & top drive. 06:00 07:00 1.00 0 0 COMPZ FISH OTHR P Slip & cut 45' drlg. line. 07:00 07:30 0.50 0 241 COMPZ FISH PULD P P/U & M/U another retrieving hook assembly. Hook-1 it. 3 1/2" hwdp-bumper sub -oil jars -float sub-xo-2 stands hybrid push pipe. 07:30 08:45 1.25 241 6,027 COMPZt FISH TRIP P RIH from 241' to 6027'. filling pipe every 20 stands. 08:45 09:45 1.00 6,027 61099 COMPZ FISH FISH P Make several attempts to retrieve whipstock @ 6099'. Will not engage Ion up stroke. 09:45 10:00 0.25 6,099 6,099 COMPZ FISH OTHR P Flow check static -blow down top drive. 10:00 12:00 2.00 6,099 241 COMPZ FISH TRIP P POH from 6099' to 241'. 12:00 12:30 0.50 241 0 COMPZ FISH TRIP P Finish POH from 241'. Lay down bent hook assembly. Pick up Hook w/ more a ressive bend to it. 12:30 16:15 3.75 0 6,099 COMPZ FISH TRIP P RIH w/ bent hook assembly to 6099'. Wash past slot in whipstock -made several attemps to latch hook -decision made to POH. 16:15 18:00 1.75 6,099 0 COMPZ FISH TRIP P POH from 6099' to 0.0 Lay down bent hook. 18:00 18:45 0.75 0 0 COMPZ FISH PULD T Pick up box tap & make up on bha. 18:45 20:45 2.00 0 4,064 COMPZ FISH TRIP T RIH to 4064'. Bolt broke on top drive. 20:45 23:00 2.25 4,064 4,064 JCOMPZ FISH OTHR T New bolts installed in stand jump on top drive. 23:00 00:00 1.00 4,064 CCOMPZ FISH TRIP T Continue RIH from 4064' to 6025'. 0 • 11/22/2006 00:00 02:00 2.00 6,025 6,110 COMPZP FISH FISH T Made several attemps to engage fish with box tap. Worked string from 6025' to 6110' with & without Rotation & pumps. P/U 115k S/O 65k ROT 85k. 02:00 02:15 0.25 6,110 61110 COMPZ FISH OTHR T Flow check -static -blow down top drive. 02:15 04:00 1.75 6,110 66 JCOMPZ FISH TRIP T POH from 6110.0 to 66'. 04:00 04:30 0.50 66 0 COMPZP FISH PULD T Lay down fishing assembly. 04:30 05:00 0.50 0 0 JCOMPZ FISH OTHR T Clear & clean rig floor. 05:00 05:30 0.50 0 220 COMPZ FISH PULD T P/U & M/U washover assembly. Washover shoe- (2) 6 3/8" TSWP Extention,s-boot basket -bumper sub -oil jars -float sub-xo-2 stands hybrid dc,s. 220.41'. 05:30 07:30 2.00 220 6,039 COMPZ FISH TRIP T RIH from 220' to 6039'. 07:30 11:15 3.75 6,039 6,100 COMPZP FISH MILL T Milling over whipstock from 6091' to - 6100'. 11:15 12:00 0.75 6,100 6,100 COMPZ FISH CIRC T Pump hi vis super sweep 35 bbls. @ 10 b m 1900 psi. 12:00 12:30 0.50 6,100 6,100 COMPZ FISH CIRC T Circ. sweep out @ 10 bpm 1900 psi. Flow check well -blow down top drive. 12:30 15:15 2.75 6,100 0 COMPZ FISH TRIP T POH & lay down BHA. 15:15 20:30 5.25 0 6,100 COMPZP FISH TRIP T M/U 6 5/8" overshot W/ 4 3/4" Grapple-RIH to 6032'-break circ. @ 40 spm-400 psi-P/U 105k S/O 65k. Run overshot over fish from 6092' to 6100'. Gain 10k on wt. hole swabbing indicating fish on. 20:30 21:30 1.00 6,100 6,100 COMPZ FISH CIRC T CBU-no gas on bottoms up. 21:30 21:45 0.25 6,100 6,001 COMPZ FISH TRIP T POH to 6001'. Monitor well -static. Blow down top drive. 21:45 00:00 2.25 6,001 3,380 COMPZP FISH TRIP T POH from 6001' to 3380'. 55 fpm easy in & out of slips. no slack off -no rotation. 11/23/2006 00:00 01:00 1.00 3,380 0 COMPZt FISH TRIP T POH w/ overshot (No Fish) 01:00 01:30 0.50 0 0 COMPZJ FISH OTHR T Clear & Clean rig floor. 01:30 02:00 0.50 0 0 COMPZP FISH OTHR T Redress overshot to 4 5/8" Basket grapple. 02:00 04:00 2.00 0 6,100 JCOMPZ FISH TRIP T RI to 6100'. 04:00 04:30 0.50 6,100 6,100 JCOMPZ FISH FISH T Work overshot from 6085' to 6100'. Would not grab fish. 04:30 06:45 2.25 6,100 0 COMPZP FISH TRIP T POH from 6100' to 0.0 06:45 07:30 0.75 0 0 JCOMPZ FISH PULD T Lay down overshot assembly. 07:30 08:00 0.50 0 0 JCOMPZ FISH OTHR T Clear & clean rig floor. 0 • 11/23/2006 08:00 08:30 0.50 0 0 COMPZ FISH I OTHR T Service top drive & drawworks. 08:30 09:45 1.25 0 0 COMPZI FISH I WOEQ T Wait on washpipe & boot baskets. 09:45 11:00 1.25 0 241 COMPZP FISH PULD T Make up washpipe assembly. Washover shoe-xo-washpipe-boot basket-xo-boot basket X 2-xo-bumper sub -oil jar -float sub-xo- 2 stands h bred push pipe. 11:00 12:00 1.00 241 723 COMPZP FISH TRIP T, RIH to 723'. 12:00 13:30 1.50 723 6,100 COMPZP FISH TRIP T RIH from 723' to 6044'. P/U 105k S/O 67k ROT 84k. Break circ. @ 48 spm 425 psi. ROT 50 rpm TQ 4k Took wt. 6100'. 13:30 16:00 2.50 6,100 6,133 COMPZP FISH MILL T Start milling @ 6100'. 100 rpm 31 spm 300 psi 4-7k TQ. 5-6k wt. on shoe. Mill to 6102', lost bit wt. & TQ, slacked off to bottom out anchor & went in open hole to 6133 . 16:00 17:00 1.00 6,133 6,080 COMPZ FISH CIRC T POH from 6133' to 6080' & circ. hi vis sweep around. 17:00 20:00 3.00 6,080 0 COMPZ FISH TRIP T Monitor well. Static -blow down top drive. POH from 6080' to 0.0. Lay down 5 3/4" washpipe assembly. Recovered 1 4' piece of whipstock & 1 8" piece. Small pieces of cocretions. 20:00 00:00 4.00 0 5,018 COMPZt FISH TRIP T ashpipe assembly & RIH to 5018'. 11/24/2006 00:00 00:15 0.25 5,018 6,092 COMPZ FISH TRIP T Continue trip in hole from 5018' to 6092'. 00:15 04:30 4.25 6,092 6,103 COMPZ FISH MILL T Wash over & mill from 6092' to 6103'. 80 rpm 45 spm 500 psi 5-10k TQ. 04:30 05:15 0.75 6,103 6,103 COMPZ FISH CIRC T CBU=pump hi vis sweep @ 75 spm 1150 psi 80 rpm. 05:15 05:30 0.25 6,103 6,103 COMPZ FISH OTHR T Flow check static -blow down top drive. 05:30 07:15 1.75 6,103 0 COMPZP FISH TRIP T POH from 6103' to 0.0 07:15 07:30 0.25 0 0 COMPZIN FISH OTHR T Change out washover shoe. 07:30 09:15 1.75 0 6,103 . COMPZIN FISH TRIP T RIH to 6103'. 09:15 12:00 2.75 6,103 6,104 COMPZP FISH MILL T Milling on whipstock from 6103' to 6104.5' @ 100 rpm 5-7 TQ 5-10k on shoe 31 s m 350 psi. 12:00 13:00 1.00 6,104 6,104 COMPZ FISH MILL T Continue milling on whipstock @ 6104.5 w/ no progress. Monitor well static. 13:00 15:00 2.00 6,104 0 COMPZP FISH TRIP T Blow down top drive & POH. 15:00 16:15 1.25 0 0 COMPZ FISH PULD T Lay down milling assembly & pick up overshot assembly dressed w/ 4.6875" basket grapple. 16:15 18:00 1.75 0 6,046 COMPZ FISH TRIP T RIH w. overshot assembly to 6046'. P/U 105k S/O 70k. 11/24/2006 18:00 18:30 0.50 6,046 6,101 COMPZt FISH FISH T Washed down to & over fish @ 6092 to 6101'. Bottomed out. Pull 10k over string wt. Bled jars & pulled 60k over & worked to 115k over -fish came loose. gained 5k on string wt. lost 13 bbls. fluid to well. 18:30 20:15 1.75 6,101 6,101 COMPZ FISH CIRC T CBU @ 3.5 bpm 360 psi (Max gas units 56) loss total 30 bbis. to well. monitor well. (Static) 20:15 22:30 2.25 6,101 0 COMPZt FISH TRIP T POHw/fish. 22:30 23:30 1.00 0 0 COMPZ FISH PULD T Lay down jars, bumper sub, Float sub, xo,s, & boot baskets. 23:30 00:00 0.50 0 0 COMPZ FISH PULL T Lay down washpipe & Fish. 100% Recovery. 11/25/2006 00:00 01:30 1.50 0 0 COMPZ FISH PULD T Lay down washpipe & whipstock -remove all baker fishing tools & rest of space out off bottom of fish. 01:30 02:00 0.50 0 0 COMPZ1, FISH OTHR T Clean rig floor. 02:00 02:30 0.50 0 0 COMPZ CASIN( RURD P Rig up casing tools for hook hanger assembly. 02:30 04:30 2.00 0 272 COMPZP CASIN( OTHR P PJSM-Make up hook hanger assembly with inner string MWD & orient same. 04:30 08:00 3.50 272 6,100 COMPZf CASIN( RUNL P RI w/ hook hanger on drill pipe. 08:00 08:30 0.50 6,100 6,100 COMPZ CASIN( OTHR P Made three attempts before going thru window. 08:30 11:00 2.50 6,100 6,103 COMPZ DRILL OTHR P Orient hook hanger47 Deg. to right @ 6103' MD. 11:00 12:00 1.00 6,103 6,103 COMPZ CASIN( OTHR P Drop 29/32" ball. Pump down same @ 2.5 b m 600 psi. 12:00 12:30 0.50 6,103 6,103 COMPZt CASIN( OTHR P With ball on seat -pressure up 200# increments to 2700 psi (Inflate ECP) Pressure dropped to 570 psi. Bled to 0. Pressure up to 800 psi -release from hook hanger. Monitor well Static 12:30 14:30 2.00 6,103 0 COMPZ CASIN( OTHR P I Blow Down Top Drive & POH. 14:30 16:00 1.50 0 0 COMPZ CASIN( RURD P Lay down running tools & MWD-clear & clean rig floor. Monitor well Static. 16:00 16:30 0.50 0 0 COMPZ DRILL OTHR P Drain Stack -pull wear ring -pick up 2 7/8" test't. & seat test plug. 16:30 17:30 1.00 0 0 COMPZ DRILL OTHR P PJSM- & change lower pipe rams to 2 7/8". 17:30 18:30 1.00 0 0 COMPZt DRILL OTHR P Test lower rams 250-3000 psi. Pull test plug -set wear ring & lay down test jt. 18:30 19:15 0.75 0 0 COMPZI DRILL OTHR P Rig up 2 7/8" Handling tools. 19:15 19:30 0.25 0 0 COMPZ DRILL SFTY P PJSM-Topic=Handling & running 2 7/8" clean out string. 19:30 21:00 1.50 0 703 +COMPZ DRILL PULD P Run in hole to 703' picking up 2 7/8" - - tbq. Riq down 2 7/8" handling tools. 11/25/2006 21:00 22:30 1.50 703 6,210 fOMPZl' DRILL TRIP P RIH from 703' to 6210'. Tag up & break circ. 22:30 23:30 1.00 6,210 6,210 COMPZ DRILL CIRC P Pump 30 bbl. hi-vis sweep @ 8.5 bpm 1470 psi. Monitor well -static. 23:30 00:00 0.50 6,210 6,000 COMPZP DRILL OTHR P Blow down top drive & POH. 11/26/2006 00:00 01:30 1.50 6,211 704 COMPZP DRILL TRIP P POH from 6211' to 704'. 01:30 01:45 0.25 704 704 COMPZP DRILL OTHR P Rig up to lay down 2 7/8" tbg. 01:45 03:45 2.00 704 0 COMPZP DRILL PULD P Layed down 24 jts. 704' 2 7/8" tbg. 03:45 04:15 0.50 0 0 COMPZt DRILL OTHR P Clear & clean rig floor. 04:15 05:15 1.00 0 0 COMPZP DRILL OTHR P Slip & cut 71.5' drlg. line. 05:15 05:30 0.25 0 0 COMPZP DRILL OTHR P Service top drive. 05:30 05:45 0.25 0 0 COMPZP DRILL OTHR P Rig up to lay down drill pipe. 05:45 12:00 6.25 0 0 COMPZP DRILL PULD P Lay down 15 stands hybred push pipe-7 stands hwdp & 141 jts. 4" drill pipe out of mouse hole. 12:00 12:15 0.25 0 0 COMPZP DRILL SFTY P PJSM-Topic=laying down pipe from mouse hole. 12:15 17:30 5.25 0 0 COMPZt DRILL PULD P Continue laying down 4" drill pipe from derrick (279 jts) 17:30 19:00 1.50 0 0 COMPZP DRILL OTHR P Pull wear ring -lay down mouse hole -clear floor of drl . tools. 19:00 19:30 0.50 0 0 COMPZ DRILL OTHR P Lubricate rig -top drive & blocks. 19:30 21:00 1.50 0 0 COMPZIN RPCOh PULD P Hoist centralift tools & equipment to rig floor. 21:00 21:15 0.25 0 0 COMPZ RPCOh SFTY P PJSM-Topic=picking up centralift motor -etc. 21:15 22:30 1.25 0 0 COMPZ RPCOA PULD P Pick up motor -tandem seal section-TTC xo w/ screen intake. 22:30 00:00 1.50 0 0 COMPZP RPCON OTHR P Hang cable sheave -rig up esp cable & tie in to motor. 11/27/2006 00:00 00:15 0.25 COMPZ RPCOh SFTY P PJSM : Running ESP Completion - Hazard recognition - Discussed & reviewed running detail and all know hazards. 00:15 01:30 1.25 COMPZP RPCOh RCST P Con't to MU A -Well discharge sub 01:30 03:45 2.25 COMPZP RPCOh SLKL P RU Wire line unit - Run pump in tbg - Install & test packoff to 800 psi - Install Tbg stop. 03:45 12:00 8.25 COMPZP RPCOh RCST P Con't run tbg 4.5" 12.6# L80 IBTM - Tested cable continuity on jts # 30,66, 90 & 120. All "OK" - Had 120 jts ran at end of tower. Dn wt 62k 12:00 12:15 0.25 COMPZ RPCOh SFTY P PJSM : Running ESP Completion - Hazard recognition - Discussed & reviewed running detail and all know hazards. 11 /27/2006112:15 114:30 1 2.25 14:30 119:30 1 5.00 19:30 20:15 0.75 20:15 120:30 1 0.25 20:30 22:00 1.50 22:00 00:00 1 2.00 11 /28/2006100:00 101:30 1 1.50 10 10 01:30 106:30 1 5.00 10 10 06:30 07:30 1.00 0 0 07:30 10:00 2.50 0 )MPZN RPCONJ RCST IP lCon't running ESP 4.5" tbg completion per detail - test cable @ 150 its in "OK" - Ran total 172 its tbg, 2 pup its, 2 - KBMG GLM ( Lower dummy, upper w/ 2K sheer tbg to csg and Tbg hanger w/ full it of tbg . ESP used 7 SS flat bands - 3 protectolizer clamps - 2 flat guards - 99 cannon clamps. At depth Up wt 100K, Dn wt 66K. Motor centralizer 5510' MD / 3360' TVD, Pump intake @ 5448' MD / 3333' TVD - 64.62 deg. MPZ RPCOR HOSO P MU Landing it and tbg hanger (2 way check installed) Test cable "OK" - Splice and Tie in tbg hanger Pentrator MPZ RPCOh HOSO P Test Pentrator Continuity "OK'- Land Tbg ( 31 K on Hanger) Motor Cert @ 5510' MD / 3360' TVD / 64.72 deg - RILDS - Bk out LJ - Test upper and lower hanger seals 5000 psi for 15 min each "OK" Vetco rep Ty Kunutson MPZ RPCOh SFTY P PJSM - Discuss ND BOP's - Plan work and discuss all know hazards - Stress hazard assessment and recognition. MPZ RPCOh NUND P ND BOPs - Change out bttm rams to 5.. MPZ RPCOh NUND P NU Tree - Install actuator valves - Preform final continuity test on ESP "OK" MPZ RPCOh NUND P Continue nipple up tree -test well head to tree void 5000 psi held 5 mins. OK, Tested tree to 5000 psi held 5 mins. OK. Pulled 2 way check. Rigged up to freeze protect well. VIPZ RPCOh FRZP P PJSM-Pumped 246 bbls. diesel, 206 bbls. returns @ .5-1.75 bpm 250-500 psi Pumped 16 bbl. before returns. VIPZINRPCON OTHR P Rig up lubricator -set back pressure valve. Rig down lubricator & secure well. NPZ RPCOh OTHR P I Clean pits -clean cellar. (Rig release @ 10:00 hrs. 11-28-2006. 0 0 Halliburton Company Survey Report 0 0 Halliburton Company Survey Report j Company,: ConvcoPhillipsAlaska Inc. - Date: 12f19/2006' '. Time: 13:45:37 Page: 2 FSeld:, Kuparuk River Unit • Co-ordinate(NE) Reference: Well: 1J115, True North Sete- Kuparuk 1J Pad vertical (TVI3)Reference: 1J-115:1 4 _. Well: 1J-115 Section (VS)Reference: Well (0.€ION 0.00E,0.0{fAz1) Wellpaths 1J-115 Survey Calculation Method: Minimum Curvature Db: Oracle Survey MD Incl Azim TVD Sys TVD N/S E/W MapN MOPE Tool ft deg deg ft It ft ft ft ft 2004.98 60.06 94.39 1786.68 1677.68 -78.09 662.93 5945712.48 559493.09 MWD+IFR-AK-CAZ-SC� 2052.33 61.37 94.72 1809.84 1700.84 -81.37 704.10 5945709.52 559534.28 MWD+IFR-AK-CAZ-SC 2099.08 65.15 94.08 1830.88 1721.88 -84.57 745.72 5945706.65 559575.91 MWD+IFR-AK-CAZ-SC 2146.11 66.24 94.32 1850.23 1741.23 -87.70 788.46 5945703.85 559618.68 MWD+IFR-AK-CAZ-SC 2195.14 65.38 94.46 1870.32 1761.32 -91.13 833.06 5945700.77 559663.29 MWD+IFR-AK-CAZ-SC 2243.32 65.22 94.86 1890.46 1781.46 -94.68 876.68 5945697.56 559706.94 MWD+IFR-AK-CAZ-SC 2290.05 65.23 95.29 1910.04 1801.04 -98.44 918.95 5945694.13 559749.23 MWD+IFR-AK-CAZ-SC 2384.30 66.21 92.85 1948.80 1839.80 -104.53 1004.63 5945688.71 559834.95 MWD+IFR-AK-CAZ-SC 2431.35 66.51 91.83 1967.67 1858.67 -106.29 1047.70 5945687.29 559878.03 MWD+IFR-AK-CAZ-SC 2479.29 65.14 92.38 198T30 1878.30 -107.89 1091.40 5945686.03 559921.74 MWD+IFR-AK-CAZ-SC 2525.10 64.21 92.41 2006.89 1897.89 -109.62 1132.78 5945684.62 559963.12 MWD+IFR-AK-CAZ-SC 2574.27 64.84 92.04 2028.04 1919.04 -111.35 1177.13 5945683.24 560007.48 MWD+IFR-AK-CAZ-SC 2621.23 65.32 92.80 2047.83 1938.83 -113.14 1219.68 5945681.78 560050.04 MWD+IFR-AK-CAZ-SC 2668.37 64.85 93.77 2067.69 1958.69 -115.59 1262.36 5945679.66 560092.74 MWD+IFR-AK-CAZ-SC 2716.31 63.56 93.99 2088.55 1979.55 -118.51 1305.43 5945677.08 560135.82 MWD+IFR-AK-CAZ-SC 2764.95 62.48 93.85 2110.61 2001.61 -121.48 1348.67 5945674.45 560179.08 MWD+IFR-AK-CAZ-SC 2792.69 63.61 94.72 2123.19 2014.19 -123.33 1373.33 5945672.80 560203.75 MWD+IFR-AK-CAZ-SC 2858.21 64.46 95.53 2151.88 2042.88 -128.59 1432.00 5945667.99 560262.45 MWD+IFR-AK-CAZ-SC 2923.29 65.79 94.45 2179.25 2070.25 -133.72 1490.81 5945663.32 560321.30 MWD IFR-AK-CAZ-SC 2953.10 65.83 94.21 2191.47 2082.47 -135.77 1517.93 5945661.48 560348.43 MWD IFR-AK-CAZ-SC 3020.46 64.26 94.73 2219.88 2110.88 -140.53 1578.81 5945657.20 560409.34 MWD+IFR-AK-CAZ-SC 3066.57 63.09 96.12 2240.33 2131.33 -144.44 1619.95 5945653.62 560450.50 MWD+IFR-AK-CAZ-SC 3115.25 62.06 96.47 2262.75 2153.75 -149.17 1662.90 5945649.22 560493.48 MWD+IFR-AK-CAZ-SC 3161.89 60.79 95.77 2285.06 2176.06 -153.54 1703.62 5945645.17 560534.24 MWD+IFR-AK-CAZ-SC 3207.64 59.59 95.17 2307.81 2198.81 -157.33 1743.14 5945641.69 560573.78 MWD+IFR-AK-CAZ-SC 3257.07 59.30 95.67 2332.93 2223.93 -161.35 1785.51 5945638.00 560616.18 MWD+IFR-AK-CAZ-SC 3302.16 60.64 95.08 2355.50 2246.50 -165.00 1824.38 5945634.65 560655.07 MWD+IFR-AK-CAZ-SC 3351.77 61.76 94.04 2379.40 2270.40 -168.46 1867.71 5945631.54 560698.42 MWD+IFR-AK-CAZ-SC 3397.36 61.52 94.13 2401.05 2292.05 -171.31 1907.73 5945628.99 560738.46 MWD+IFR-AK-CAZ-SC 3445.60 61.94 94.01 2423.90 2314.90 -174.33 1950.11 5945626.31 560780.85 MWD+IFR-AK-CAZ-SC 3541.93 64.26 92.53 2467.48 2358.48 -179.22 2035.87 5945622.09 560866.64 MWD+IFR-AK-CAZ-SC 3587.60 63.76 92.85 2487.50 2378.50 -181.14 2076.87 5945620.48 560907.65 MWD+IFR-AK-CAZ-SC 3637.30 63.20 92.99 2509.69 2400.69 -183.41 2121.28 5945618.57 560952.08 MWD+IFR-AK-CAZ-SC 3683.58 62.11 93.43 2530.95 2421.95 -185.71 2162.33 5945616.59 560993.14 MWD+IFR-AK-CAZ-SC 3730.50 61.48 93.54 2553.12 2444.12 -188.22 2203.60 5945614.39 561034.42 MWD+IFR-AK-CAZ-SC 3783.12 62.18 92.50 2577.96 2468.96 -190.67 2249.92 5945612.31 561080.76 MWD+IFR-AK-CAZ-SC 3826.51 61.89 92.49 2598.31 2489.31 -192.33 2288.21 5945610.95 561119.05 MWD+IFR-AK-CAZ-SC 3873.70 62.90 92.02 2620.18 2511.18 -193.98 2329.99 5945609.63 561160.84 MWD+IFR-AK-CAZ-SC 3921.50 64.20 91.19 2641.47 2532.47 -195.18 2372.77 5945608.77 561203.63 MWD+IFR-AK-CAZ-SC 3975.48 62.84 89.69 2665.54 2556.64 -195.55 2421.08 5945608.77 561251.94 MWD+IFR-AK-CAZ-SC 4011.14 63.44 87.24 2681.65 2572.65 -194.70 2452.88 5945609.87 561283.72 MWD+IFR-AK-CAZ-SC 4065.80 63.59 84.65 2706.03 2597.03 -191.24 2501.68 5945613.71 561332.49 MWD+IFR-AK-CAZ-SC 4111.07 63.08 82.85 2726.35 2617.35 -186.83 2541.89 5945618.43 561372.66 MWD+IFR-AK-CAZ-SC 4161.60 62.71 82.07 2749.37 2640.37 -180.93 2586.48 5945624.68 561417.20 MWD+IFR-AK-CAZ-SC 4207.41 62.05 81.09 2770.61 2661.61 -174.99 2626.63 5945630.93 561457.30 MWD+IFR-AK-CAZ-SC 4302.87 60.78 75.96 2816.31 2707.31 -158.35 2708.74 5945648.22 561539.27 MWD+IFR-AK-CAZ-SC 4397.88 61.00 71.95 2862.54 2753.54 -135.41 2788.49 5945671.78 561618.83 MWD+IFR-AK-CAZ-SC 4444.65 61.15 70.43 2885.16 2776.16 -122.21 2827.24 5945685.28 561657.47 MWD+IFR-AK-CAZ-SC 4493.15 62.09 66.97 2908.22 2799.22 -106.71 2866.99 5945701.09 561697.09 MWD+IFR-AK-CAZ-SC 4587.16 63.03 60.70 2951.58 2842.58 -69.92 2941.81 5945738.45 561771.61 MWD+IFR-AK-CAZ-SC 4681.64 63.67 55.12 2993.98 2884.98 -25.08 3013.30 5945783.84 561842.75 MWD+IFR-AK-CAZ-SC 4776.45 63.61 48.37 3036.12 2927.12 27.48 3079.96 5945836.91 561908.99 MWD+IFR-AK-CAZ-SC 4872.66 62.93 42.02 3079.43 2970.43 87.98 3140.89 .5945897.88 561969.44 MWD+IFR-AK-CAZ-SC 0 # Halliburton Company Survey Report Company: ConocoPMlllips Alaska Inc. Date: 12/19/2006 Time: 13:45:31 Page: 3 Field: Kuparuk River Unit..., , Co-ordinate(NE) Reference. Well: 1J=-1IS, True North Site: Kupan k 1.1 PadVertical(TYD)'Reference: IJ-115:109.0 Well: 1J-11s "Section (VS) Reference: Well (0.40N,0.00E,0.O0Azi Welipath 1J-115 Survey Calculation Method: Minimum Curvature Db: Oracle Survey MD Inel Azim TVD Sysm N/S E/W ' MapN. Mapt Tool ft deg deg ft it It ft ft ft 4966.48 62.78 36.83 3122.25 3013.25 152.43 3193.89 5945962.74 562021.92 MWD+IFR-AK-CAZ-SC 5061.23 63.60 30.93 3165.02 3056.02 222.60 3240.99 5946033.27 562068.47 MWD+IFR-AK-CAZ-SC 5154.55 63.67 26.34 3206.48 3097.48 295.96 3281.04 5946106.94 562107.94 MWD+IFR-AK-CAZ-SC 5249.86 64.52 23.85 3248.12 3139.12 373.60 3317.39 5946184.85 562143.68 MWD+IFR-AK-CAZ-SC 5344.89 64.58 23.84 3288.96 3179.96 452.08 3352.08 5946263.59 562177.75 MWD+IFR-AK-CAZ-SC 5440.16 64.61 24.40 3329.83 3220.83 530.62 3387.25 5946342.40 562212.30 MWD+IFR-AK-CAZ-SC 5537.28 64.76 24.25 3371.36 3262.36 610.62 3423.41 5946422.67 562247.84 MWD+IFR-AK-CAZ-SC 5630.91 66.63 19.01 3409.92 3300.92 689.92 3454.82 5946502.20 562278.63 MWD+IFR-AK-CAZ-SC 5724.54 69.47 14.47 3444.93 3335.93 773.05 3479.79 5946585.52 562302.94 MWD+IFR-AK-CAZ-SC 5818.75 70.89 10.45 3476.88 3367.88 859.57 3498.90 5946672.18 562321.37 MWD+IFR-AK-CAZ-SC 5915.97 72.53 6.28 3507.41 3398.41 950.88 3512.30 5946763.57 562334.06 MWD+IFR-AK-CAZ-SC 6011.71 75.39 0.95 3533.87 3424.87 1042.66 3518.07 5946855.39 562339.11 MWD+IFR-AK-CAZ-SC 6106.21 77.01 355.82 3556.43 3447.43 1134.36 3515.47 5946947.06 562335.80 MWD+IFR-AK-CAZ-SC 6199.94 81.12 356.20 3574.21 3465.21 1226.14 3509.07 5947038.78 562328.68 MWD+IFR-AK-CAZ-SC 6296.29 79.71 354.23 3590.25 3481.25 1320.81 3501.15 5947133.37 562320.02 MWD+IFR-AK-CAZ-SC 6390.76 77.22 353.37 3609.14 3500.14 1412.82 3491.16 5947225.30 562309.31 MWD+IFR-AK-CAZ-SC 6485.62 77.17 350.57 3630.17 3521.17 1504.41 3478.24 5947316.77 562295.68 MWD+IFR-AK-CAZ-SC 6582.32 75.23 350.18 3653.23 3544.23 1596.99 3462.54 5947409.22 562279.26 MWD+IFR-AK-CAZ-SC 6677.73 77.93 349.85 3675.37 3566.37 1688.38 3446.45 5947500.47 562262.45 MWD+IFR-AK-CAZ-SC 6740.64 79.05 349.68 3687.93 3578.93 1749.04 3435.49 5947561.04 562251.03 MWD+IFR-AK-CAZ-SC 6774.90 79.13 349.38 3694.41 3585.41 1782.12 3429.38 5947594.07 562244.65 MWD+IFR-AK-CAZ-SC 6820.64 79.62 349.05 3702.84 3593.84 1826.28 3420.97 5947638.16 562235.90 MWD+IFR-AK-CAZ-SC 6869.70 79.71 348.67 3711.65 3602.65 1873.64 3411.64 5947685.43 562226.20 MWD+IFR-AK-CAZ-SC 6920.08 78.89 348.80 3721.00 3612.00 1922.19 3401.97 5947733.90 562216.16 MWD+IFR-AK-CAZ-SC 477 2 7. 6963.44 79.06 348.21 3729.29 3620.29 1963.89 3393.49 5947775.54 562 0 35 MWD+IFR-AK-CAZ-SC 7011.09 79.51 348.78 3738.15 3629.15 2009.77 3384.15 5947821.34 562197.66 MWD+IFR-AK-CAZ-SC 7059.70 80.03 349.22 3746.78 3637.78 2056.73 3375.03 5947868.22 562188.16 MWD+IFR-AK-CAZ-SC j7105.01 79.52 350.15 3754.83 3645.83 2100.60 3367.04 5947912.02 562179.84 MWD+IFR-AK-CAZ-SC 7152.78 79.58 349.75 3763.49 3654.49 2146.86 3358.84 5947958.20 562171.28 MWD+IFR-AK-CAZ-SC 7201.56 80.00 350.40 3772.14 3663.14 2194.14 3350.57 5948005.42 562162.63 MWD+IFR-AK-CAZ-SC 7247.80 80.34 349.79 3780.03 3671.03 2239.03 3342.73 5948050.24 562154.45 MWD+IFR-AK-CAZ-SC 7343.46 82.25 349.16 3794.51 3685.51 2331.99 3325.46 5948143.05 562136.45 MWD+IFR-AK-C - AZ SC 7364.59 83.90 349.62 3797.06 3688.06 2352.60 3321.60 5948163.64 562132.43 MWD+ IFR-AK-CAZ-SC 7438.37 85.10 348.79 3804.13 3695.13 2424.74 3307.84 5948235.66 562118.11 MWD+IFR-AK-CAZ-SC 7457.95 85.54 348.80 3805.73 3696.73 2443.89 3304.05 5948254.77 562114.17 MWD+IFR-AK-CAZ-SC 7518.39 85.68 349.15 3810.35 3701.35 2503.04 3292.53 5948313.82 562102.19 MWD+IFR-AK-CAZ-SC 7550.16 85.61 351.21 3812.77 3703.77 2534.25 3287.12 5948344.99 562096.54 MWD+IFR-AK-CAZ-SC 7612.44 86.31 351.20 3817.15 3708.15 2595.64 3277.62 5948406.30 562086.56 MWD+IFR-AK-CAZ-SC 7649.57 87.73 354.26 3819.08 3710.08 2632.42 3272.93 5948443.04 562081.58 MWD+IFR-AK-CAZ-SC 7678.59 88.34 353.83 3820.08 3711.08 2661.27 3269.92 5948471.85 562078.35 MWD+IFR-AK-CAZ-SC 7706.17 88.70 353.92 3820.79 3711.79 2688.68 3266.98 5948499.24 562075.19 MWD+IFR-AK-CAZ-SC 7751.45 90.76 355.60 3821.01 3712.01 2733.77 3262.85 5948544.29 562070.71 MWD+IFR-AK-CAZ-SC 7799.38 89.67 354.42 3820.83 3711.83 2781.51 3258.68 5948592.00 562066.17 MWD+IFR-AK-CAZ-SC 7892.95 91.11 353.30 3820.19 3711.19 2874.54 3248.67 5948684.93 562055.43 MWD+IFR-AK-CAZ-SC 7985.44 89.92 352.48 3819.36 3710.36 2966.31 3237.22 5948776.61 562043.27 MWD+IFR-AK-CAZ-SC 8078.81 88.13 352.83 3820.95 3711.95 3058.90 3225.29 5948869.09 562030.62 MWD+IFR-AK-CAZ-SC 8081.00 87.84 353.93 3821.02 3712.02 3061.07 3225.04 5948871.26 562030.35 MWD+IFR-AK-CAZ-SC 8173.08 88.27 350.40 3824.15 3715.15 3152.23 3212.49 5948962.30 562017.09 MWD+IFR-AK-CAZ-SC 8266.42 91.12 350.83 3824.65 3715.65 3244.31 3197.28 5949054.25 562001.16 MWD+IFR-AK-CAZ-SC 8311.52 92.22 351.46 3823.33 3714.33 3288.85 3190.34 5949098.73 561993.87 MWD+IFR-AK-CAZ-SC 8360.15 92.28 352.02 3821.42 3712.42 3336.94 3183.36 5949146.76 561986.51 MWD+IFR-AK-CAZ-SC 8452.71 91.53 352.19 3818.35 3709.35 3428.57 3170.65 5949238.28 561973.09 MWD+IFR-AK-CAZ-SC 0 0 Halliburton Company Survey Report I Company. ConocoPhillips Alaska Inc. � Date: 12/19/2006 Time: 13:45:37 -� Page: Field: Kuparuk River Unit Co-ordinate(NE) Reference: Well: IJ-y 15, True North Site: Kuperuk 1J Pad Vertical (TV )Reference: 1.1-115:109.0 Well:: 1J-115 Section (VS) Reference: Well {O.00N,O.OQEO.00Azi} ellpatb: 1J-115 Survey Calculation Method: Minimum Curvature Db: ©racle Survey 7MD Incl Azim TVD SysTVD ik/S FJVV MapN MapE Tool j ft deg deg ft ft ft It ft 4 - 8545.65 89.98 353.01 3817.12 3708.12 3520.72 3158.68 5949330.33 561960.41 MWD+IFR-AK-CAZ-SC 8640.45 90.24 353.36 3816.94 3707.94 3614.85 3147.43 5949424.36 561948.42 MWD+IFR-AK-CAZ-SC 8733.19 89.74 352.33 3816.96 3707.96 3706.87 3135.88 5949516.28 561936.15 MWD+IFR-AK-CAZ-SC 8826.57 89.68 352.64 3817.43 3708.43 3799.44 3123.67 5949608.75 561923.22 MWD+IFR-AK-CAZ-SC 8885.00 89.72 351.85 3817.73 3708.73 3857.34 3115.78 5949666.57 561914.88 MWD+IFR-AK-CAZ-SC 8916.66 88.43 351.67 3818.25 3709.25 3888.67 3111.25 5949697.86 561910.10 MWD+IFR-AK-CAZ-SC 9012.13 88.14 352.01 3821.10 3712.10 3983.13 3097.70 5949792.20 561895.82 MWD+IFR-AK-CAZ-SC 9106.47 87.96 354.85 3824.31 3715.31 4076.78 3086.91 5949885.76 561884.30 MWD+IFR-AK-CAZ-SC 9199.69 87.89 355.45 3827.69 3718.69 4169.61 3079.04 5949978.52 561875.70 MWD+IFR-AK-CAZ-SC 9292.84 91.12 0.80 3828.49 3719.49 4262.66 3075.99 5950071.53 561871.93 MWD+IFR-AK-CAZ-SC 9387.60 91.42 1.42 3826.39 3717.39 4357.38 3077.83 5950166.25 561873.03 MWD+IFR-AK-CAZ-SC 4 .42 MWD+ 9 80 89 90 1. 1 24.90 3715. 44 .2 5 61874.76 IFR-AK-CAZ SC 6 38 90 50.62 3080 9 950259.50 5 9573.70 89.37 0.61 3825.07 3716.07 4543.41 3082.09 5950352.30 561875.84 MWD+IFR-AK-CAZ-SC 9666.19 90.18 356.82 3825.43 3716.43 4635.86 3080.02 5950444.72 561873.04 MWD+IFR-AK-CAZ-SC 9711.54 90.12 355.63 3825.31 3716.31 4681.11 3077.03 5950489.94 561869.70 MWD+IFR-AK-CAZ-SC 9760.00 89.31 353.81 3825.55 3716,55 4729.36 3072.57 5950538.15 561864.87 MWD+IFR-AK-CAZ-SC i 9853.60 89.44 353.30 3826.57 3717.57 4822.37 3062.07 5950631.06 561853.64 MWD+IFR-AK-CAZ-SC 9946.91 88.19 355.70 3828.50 3719.50 4915.22 3053.13 5950723.83 561843.97 MWD+IFR-AK-CAZ-SC 10040.51 88.26 358.47 3831.40 3722.40 5008.64 3048.37 5950817.20 561838.48 MWD+IFR-AK-CAZ-SC 10134.01 88.45 0.77 3834.09 3725.09 5102.10 3047.75 5950910.64 561837.13 MWD+IFR-AK-CAZ-SC 10228.22 92.30 0.20 3833.47 3724.47 5196.28 3048.55 5951004.82 561837.20 MWD+IFR-AK-CAZ-SC 10320.98 89.86 359.78 3831.72 3722.72 5289.02 3048.53 5951097.54 561836.46 MWD+IFR-AK-CAZ-SC 10415.08 89.81 359.27 3831.99 3722.99 5383.11 3047.75 5951191.62 561834.94 MWD+IFR-AK-CAZ-SC 10508.27 89.19 359.55 3832.81 3723.81 5476.29 3046.79 5951284.78 561833.25 MWD+IFR-AK-CAZ-SC 10601.05 88.94 0.11 3834.32 3725.32 5569.06 3046.52 5951377.54 561832.25 MWD+IFR-AK-CAZ-SC 10694.96 89.38 358.33 3835.70 3726.70 5662.95 3045.24 5951471.40 561830.24 MWD+IFR-AK-CAZ-SC 10787.01 88.82 359.42 3837.14 3728.14 5754.97 3043.43 5951563.40 561827.72 MWD+IFR-AK-CAZ-SC 10879.62 88.63 358.65 3839.20 3730.20 5847.54 3041.87 5951655.94 561825.43 MWD+IFR-AK-CAZ-SC 10973.06 89.01 359.36 3841.13 3732.13 5940.95 3040.25 5951749.33 561823.08 MWD+IFR-AK-CAZ-SC 11067.06 89.94 359.99 3841.99 3732.99 6034.94 3039.72 5951843.30 561821.81 MWD+IFR-AK-CAZ-SC 11103.04 89.24 359.84 3842.25 3733.25 6070.92 3039.66 5951879.28 561821.48 MWD+IFR-AK-CAZ-SC 11159.29 89.75 1.66 3842.74 3733.74 6127.16 3040.40 5951935.52 561821.78 MWD+IFR-AK-CAZ-SC 11253.06 90.61 2.41 3842.45 3733.45 6220.87 3043.73 5952029.24 561824.37 MWD+IFR-AK-CAZ-SC 11345.50 89.93 1.79 3842.01 3733.01 6313.24 3047.12 5952121.63 561827.04 MWD+IFR-AK-CAZ-SC 11439.00 88.44 2.31 3843.34 3734.34 6406.67 3050.46 5952215.07 561829.65 MWD+IFR-AK-CAZ-SC 11532.84 90.75 2.72 3844.01 3735.01 6500.41 3054.58 5952308.83 561833.04 MWD+IFR-AK-CAZ-SC 11626.47 91.91 2.95 3841.83 3732.83 6593.90 3059.21 5952402.35 561836.94 MWD+IFR-AK-CAZ-SC 11690.00 90.89 2.46 3840.28 3731.28 6657.34 3062.20 5952465.80 561839.44 MWD+IFR-AK-CAZ-SC 11718.87 88.58 1.93 3840.41 3731.41 6686.19 3063.31 5952494.65 561840.32 MWD+IFR-AK-CAZ-SC 11762.26 88.01 0.90 3841.70 3732.70 6729.54 3064.38 5952538.01 561841.05 MWD+IFR-AK-CAZ-SC 11813.06 88.52 1.20 3843.24 3734.24 6780.31 3065.31 5952588.78 561841.58 MWD+IFR-AK-CAZ-SC 11906.87 87.08 358.79 3846.84 3737.84 6874.04 3065.30 5952682.50 561840.84 MWD+IFR-AK-CAZ-SC 11999.81 85.79 359.51 3852.62 3743.62 6966.79 3063.93 5952775.22 561838.74 MWD+IFR-AK-CAZ-SC 12044.14 85.48 358.47 3856.00 3747.00 7010.98 3063.15 5952819.41 561837.62 MWD+IFR-AK-CAZ-SC 12092.99 86.36 358.72 3859.47 3750.47 7059.69 3061.95 5952868.10 561836.04 MWD+IFR-AK-CAZ-SC 12144.54 85.10 358.33 3863.31 3754.31 7111.08 3060.63 5952919.47 561834.32 MWD+IFR-AK-CAZ-SC 12186.34 86.11 359.26 3866.51 3757.51 7152.75 3059.75 5952961.13 561833.12 MWD+IFR-AK-CAZ-SC 12280.15 86.41 0.41 3872.63 3763.63 7246.36 3059.48 5953054.72 561832.12 MWD+IFR-AK-CAZ-SC 12373.37 86.16 0.17 3878.67 3769.67 7339.38 3059.96 5953147.74 561831.86 MWD+IFR-AK-CAZ-SC 12466.24 86.54 359.92 3884.59 3775.59 7432.06 3060.03 5953240.41 561831.21 MWD+IFR-AK-CAZ-SC 12523.00 87.66 0.95 3887.46 3778.46 7488.75 3060.46 5953297.09 561831.20 MWD+IFR-AK-CAZ-SC 12569.09 84.57 0.31 3890.58 3781.58 7534.72 3060.96 5953343.06 561831.34 MWD+IFR-AK-CAZ-SC 12613.59 87.63 0.79 3893.61 3784.61 7579.11 3061.39 5953387.45 561831.42 MWD+IFR-AK-CAZ-SC 0 9 Halliburton Company Survey Report Company: ConocoPhillips Alaska Inc. Date: 12115i2006 ,, Time: 13:46:37 " Page: S- Field: Kuparuk River unit Co-ordinate(1 ) Reference: Wet1:1J!-115, "true North i Site: Kuparvk 1J Pad Vertical (TVD) Reference: 1J 115 109.0- Well- 1J-115 Section (VS)Reference: MIE '(0`b0N,0.D0E,0.00Azi) Wellpath: 1J7115 Survey Calculatiou'Method: Miriirnum Curvature rDb. Oracle Survey MD Intl Azim TVD Sys TVD N/S E/W MapN . :'_ MauE Tool ft deg deg It ft: ft It ft ft 12660.72 90.96 1.49 3894.19 3785.19 7626.22 3062.33 5953434.56 561831.99 MWD+IFR-AK-CAZ-SC 12705.41 90.31 1.42 3893.69 3784.69 7670.89 3063.46 5953479.24 561832.78 MWD+IFR-AK-CAZ-SC 12751.86 89.95 1.13 3893.59 3784.59 7717.33 3064.50 5953525.68 561833.45 MWD+IFR-AK-CAZ-SC 12795.96 90.52 359.78 3893.40 3784.40 7761.43 3064.85 5953569.77 561833.46 MWD+IFR-AK-CAZ-SC 12841.97 90.02 0.17 3893.19 3784.19 7807.44 3064.83 5953615.77 561833.08 MWD+IFR-AK-CAZ-SC 12887.54 88.24 358.70 3893.88 3784.88 7853.00 3064.38 5953661.32 561832.27 MWD+IFR-AK-CAZ-SC 12934.32 88.12 358.12 3895.37 3786.37 7899.74 3063.08 5953708.05 561830.61 MWD+IFR-AK-CAZ-SC 12978.03 87.90 357.27 3896.88 3787.88 7943.38 3061.32 5953751.67 561828.51 MWD+IFR-AK-CAZ-SC 13024.08 87.93 357.81 3898.56 3789.56 7989.36 3059.35 5953797.63 561826.18 MWD+IFR-AK-CAZ-SC 13068.66 87.89 356.48 3900.18 3791.18 8033.86 3057.13 5953842.10 561823.61 MWD+IFR-AK-CAZ-SC 13114.93 87.81 356.51 3901.92 3792.92 8080.01 3054.30 5953888.22 561820.42 MWD+IFR-AK-CAZ-SC 13158.14 87.04 355.37 3903.86 3794.86 8123.06 3051.25 5953931.25 561817.03 MWD+IFR-AK-CAZ-SC 13205.13 89.10 356.68 3905.44 3796.44 8169.91 3047.99 5953978.07 561813.41 MWD+IFR-AK-CAZ-SC 13247.52 88.30 355.28 3906.41 3797.41 8212.18 3045.02 5954020.31 561810.11 MWD+IFR-AK-CAZ-SC 13292.89 88.57 355.84 3907.65 3798.65 8257.40 3041.51 5954065.50 561806.25 MWD+IFR-AK-CAZ-SC 13341.83 88.36 355.62 3908.96 3799.96 8306.19 3037.87 5954114.25 561802.22 MWD+IFR-AK-CAZ-SC 13384.29 90.78 355.83 3909.27 3800.27 8348.52 3034.70 5954156.56 561798.73 MWD+IFR-AK-CAZ-SC 13474.72 92.39 356.70 3906.77 3797.77 8438.72 3028.81 5954246.70 561792.14 MWD+IFR-AK-CAZ-SC 13565.58 90.03 356.19 3904.86 3795.86 8529.38 3023.18 5954337.30 561785.80 MWD+IFR-AK-CAZ-SC 13655.97 87.04 354.48 3907.17 3798.17 8619.43 3015.83 5954427.28 561777.75 MWD+IFR-AK-CAZ-SC .13720.00 87.04 354.48 3910.47 3801.47 8683.08 3009.68 5954490.87 561771.10 PROJECTED to TD I* Halliburton Company Survey Report 0 0 Halliburton Company Survey Report Company- Conocophillips Alaska Inc.,,,_Date: - 12/1912006 Time: 12:40 12 Page: 2 Field: Kupanak River Unit Co-ordinate(Ng) Reference:-, Well: I J-115, Tit s North. Site: Kuparuk 1J Pad Vertical (TVD)Reference: 1J-115P61' 109.0 Well: 1J-115 Section (VS) Reference: Well (O.00N,0:00E,0.00Azi) Wellpathf 1J-11 PBf Survey Calcalatiou Method: Minimum Curvature Db: Oracle Survey MD Ioci A;dm TVD Sys TVD N/S E/W MapN Mapi Tool 4 deg 'deg ft, ft °. ft ft ft ft 2195.14 65.38 94.46 1870.32 1761.32 -91.13 833.06 5945700.77 559663.29 MWD+IFR-AK-CAZ-SC 2243.32 65.22 94.86 1890.46 1781.46 -94.68 876.68 5945697.56 559706.94 MWD+IFR-AK-CAZ-SC 2290.05 65.23 95.29 1910.04 1801.04 -98.44 918.95 5945694.13 559749.23 MWD+IFR-AK-CAZ-SC 2384.30 66.21 92.85 1948.80 1839.80 -104.53 1004.63 5945688.71 559834.95 MWD+IFR-AK-CAZ-SC 2431.35 66.51 91.83 1967.67 1858.67 -106.29 1047.70 5945687.29 559878.03 MWD+IFR-AK-CAZ-SC 2479.29 65.14 92.38 1987.30 1878.30 -107.89 1091.40 5945686.03 559921.74 MWD+IFR-AK-CAZ-SC 2525.10 64.21 92.41 2006.89 1897.89 -109.62 1132.78 5945684.62 559963.12 MWD+IFR-AK-CAZ-SC 2574.27 64.84 92.04 2028.04 1919.04 -111.35 1177.13 5945683.24 560007.48 MWD+IFR-AK-CAZ-SC 2621.23 65.32 92.80 2047.83 1938.83 -113.14 1219.68 5945681.78 560050.04 MWD+IFR-AK-CAZ-SC 2668.37 64.85 93.77 2067.69 1958.69 -115.59 1262.36 5945679.66 560092.74 MWD+IFR-AK-CAZ-SC 2716.31 63.56 93.99 2088.55 1979.55 -118.51 1305.43 5945677.08 560135.82 MWD+IFR-AK-CAZ-SC 2764.95 62.48 93.85 2110.61 2001.61 -121.48 1348.67 5945674.45 560179.08 MWD+IFR-AK-CAZ-SC 2792.69 63.61 94.72 2123.19 2014.19 -123.33 1373.33 5945672.80 560203.75 MWD+IFR-AK-CAZ-SC 2858.21 64.46 95.53 2151.88 2042.88 -128.59 1432.00 5945667.99 560262.45 MWD+IFR-AK-CAZ-SC 2923.29 65.79 94.45 2179.25 2070.25 -133.72 1490.81 5945663.32 560321.30 MWD+IFR-AK-CAZ-SC 2953.10 65.83 94.21 2191.47 2082.47 -135.77 1517.93 5945661.48 560348.43 MWD+IFR-AK-CAZ-SC 3020.46 64.26 94.73 2219.88 2110.88 -140.53 1578.81 5945657.20 560409.34 MWD+IFR-AK-CAZ-SC 3066.57 63.09 96.12 2240.33 2131.33 -144.44 1619.95 5945653.62 560450.50 MWD+IFR-AK-CAZ-SC 3115.25 62.06 96.47 2262.75 2153.75 -149.17 1662.90 5945649.22 560493.48 MWD+IFR-AK-CAZ-SC 3161.89 60.79 95.77 2285.06 2176.06 -153.54 1703.62 5945645.17 560534.24 MWD+IFR-AK-CAZ-SC 3207.64 59.59 95.17 2307.81 2198.81 -157.33 1743.14 5945641.69 560573.78 MWD+IFR-AK-CAZ-SC 3257.07 59.30 95.67 2332.93 2223.93 -161.35 1785.51 5945638.00 560616.18 MWD+IFR-AK-CAZ-SC 3302.16 60.64 95.08 2355.50 2246.50 -165.00 1824.38 5945634.65 560655.07 MWD+IFR-AK-CAZ-SC 3351.77 61.76 94.04 2379.40 2270.40 -168.46 1867.71 5945631.54 560698.42 MWD+IFR-AK-CAZ-SC 3397.36 61.52 94.13 2401.05 2292.05 -171.31 1907.73 5945628.99 560738.46 MWD+IFR-AK-CAZ-SC 3445.60 61.94 94.01 2423.90 2314.90 -174.33 1950.11 5945626.31 560780.85 MWD+IFR-AK-CAZ-SC 3541.93 64.26 92.53 2467.48 2358.48 -179.22 2035.87 5945622.09 560866.64 MWD+IFR-AK-CAZ-SC 3587.60 63.76 92.85 2487.50 2378.50 -181.14 2076.87 5945620.48 560907.65 MWD+IFR-AK-CAZ-SC 3637.30 63.20 92.99 2509.69 2400.69 -183.41 2121.28 5945618.57 560952.08 MWD+IFR-AK-CAZ-SC j 3683.58 62.11 93.43 2530.95 2421.95 -185.71 2162.33 5945616.59 560993.14 MWD+IFR-AK-CAZ-SC 3730.50 61.48 93.54 2553.12 2444.12 -188.22 2203.60 5945614.39 561034.42 MWD+IFR-AK-CAZ-SC 3783.12 62.18 92.50 2577.96 2468.96 -190.67 2249.92 5945612.31 561080.76 MWD+IFR-AK-CAZ-SC 3826.51 61.89 92.49 2598.31 2489.31 -192.33 2288.21 5945610.95 561119.05 MWD+IFR-AK-CAZ-SC 3873,70 62.90 92.02 2620,111 2511,18 -193.98 2329,99 5945609,63 561160,84 MWD+IFR-AK-CAZ-SC 3921.50 64.20 91.19 2641.47 2532.47 -195.18 2372.77 5945608.77 561203.63 MWD+IFR-AK-CAZ-SC 3975.48 62.84 89.69 2665.54 2556.54 -195.55 2421.08 5945608.77 561251.94 MWD+IFR-AK-CAZ-SC 4011.14 63.44 87.24 2681.65 2572.65 -194.70 2452.88 5945609.87 561283.72 MWD+IFR-AK-CAZ-SC 4065.80 63.59 84.65 2706.03 2597.03 -191.24 2501.68 5945613.71 561332.49 MWD+IFR-AK-CAZ-SC 4111.07 63.08 82.85 2726.35 2617.35 -186.83 2541.89 5945618.43 561372.66 MWD+IFR-AK-CAZ-SC 4161.60 62.71 82.07 2749.37 2640.37 -180.93 2586.48 5945624.68 561417.20 MWD+IFR-AK-CAZ-SC 4207.41 62.05 81.09 2770.61 2661.61 -174.99 2626.63 5945630.93 561457.30 MWD+IFR-AK-CAZ-SC 4302.87 60.78 75.96 2816.31 2707.31 -158.35 2708.74 5945648.22 561539.27 MWD+IFR-AK-CAZ-SC 4397.88 61.00 71.95 2862.54 2753.54 -135.41 2788.49 5945671.78 561618.83 MWD+IFR-AK-CAZ-SC 4444.65 61.15 70.43 2885.16 2776.16 -122.21 2827.24 5945685.28 561657.47 MWD+IFR-AK-CAZ-SC 4493.15 62.09 66.97 2908.22 2799.22 -106.71 2866.99 5945701.09 561697.09 MWD+IFR-AK-CAZ-SC 4587.16 63.03 60.70 2951.58 2842.58 -69.92 2941.81 5945738.45 561771.61 MWD+IFR-AK-CAZ-SC 4681.64 63.67 55.12 2993.98 2884.98 -25.08 3013.30 5945783.84 561842.75 MWD+IFR-AK-CAZ-SC 4776.45 63.61 48.37 3036.12 2927.12 27.48 3079.96 5945836.91 561908.99 MWD+IFR-AK-CAZ-SC 4872.66 62.93 42.02 3079.43 2970.43 87.98 3140.89 5945897.88 561969.44 MWD+IFR-AK-CAZ-SC 4966.48 62.78 36.83 3122.25 3013.25 152.43 3193.89 5945962.74 562021.92 MWD+IFR-AK-CAZ-SC 5061.23 63.60 30.93 3165.02 3056.02 222.60 3240.99 5946033.27 562068.47 MWD+IFR-AK-CAZ-SC 5154.55 63.67 26.34 3206.48 3097.48 295.96 3281.04 5946106.94 562107.94 MWD+IFR-AK-CAZ_SC 0 Halliburton Company Survey Report Compaur: ConocoPhillips Alaska Inc. - -- Date. 12/19/2o06 Time: 12:49:12 Page: ' 3 Meld: Kupanak River Unit Co-ordinate(NL) Reference Welt: 1J-115, True North Site: Kuparuk 1J Pad 'Vertical (TVD}.Reference: IJ-115PBI: 109.0 Well: 1J-115 Section (VS)Reference: Well (U.00N,0.00E,0.QG4) Wellpatht 1J-115P61 Survey Calculation Method: Mininfum Curvature Dt►z =Oracle Survey MDInd Azim TV]) Sys M, N/S " E/W MapN MapE Tool It deg deg ft ft = ft It " . It 'tt 5249.86 64.52 23.85 3248.12 3139.12 373.60 3317.39 5946184.85 562143.68 MWD+IFR-AK-CAZ-SC 5344.89 64.58 23.84 3288.96 3179.96 452.08 3352.08 5946263.59 562177.75 MWD+IFR-AK-CAZ-SC 5440.16 64.61 24.40 3329.83 3220.83 530.62 3387.25 5946342.40 562212.30 MWD+IFR-AK-CAZ-SC 5537.28 64.76 24.25 3371.36 3262.36 610.62 3423.41 5946422.67 562247.84 MWD+IFR-AK-CAZ-SC i 5630.91 66.63 19.01 3409.92 3300.92 689.92 3454.82 5946502.20 562278.63 MWD+IFR-AK-CAZ-SC 5724.54 69.47 14.47 3444.93 3335.93 773.05 3479.79 5946585.52 562302.94 MWD+IFR-AK-CAZ-SC 5818.75 70.89 10.45 3476.88 3367.88 859.57 3498.90 5946672.18 562321.37 MWD+IFR-AK-CAZ-SC 5915.97 72.53 6.28 3507.41 3398.41 950.88 3512.30 5946763.57 562334.06 MWD+IFR-AK-CAZ-SC 6011.71 75.39 0.95 3533.87 3424.87 1042.66 3518.07 5946855.39 562339.11 MWD+IFR-AK-CAZ-SC 6106.21 77.01 355.82 3556.43 3447.43 1134.36 3515.47 5946947.06 562335.80 MWD+IFR-AK-CAZ-SC 6199.94 81.12 356.20 3574.21 3465.21 1226.14 3509.07 5947038.78 562328.68 MWD+IFR-AK-CAZ-SC 6296.29 79.71 354.23 3590.25 3481.25 1320,81 3501.15 5947133.37 562320.02 MWD+IFR-AK-CAZ-SC 6390.76 77.22 353.37 3609.14 3500.14 1412.82 3491.16 5947225.30 562309.31 MWD+IFR-AK-CAZ-SC 6485.62 77.17 350.57 3630.17 3521.17 1504.41 3478.24 5947316.77 562295.68 MWD+IFR-AK-CAZ-SC 6582.32 75.23 350.18 3653.23 3544.23 1596.99 3462.54 5947409.22 562279.26 MWD+IFR-AK-CAZ-SC 6677.73 77.93 349.85 3675.37 3566.37 1688.38 3446.45 5947500.47 562262.45 MWD+IFR-AK-CAZ-SC 6740.64 79.05 349.68 3687.93 3578.93 1749.04 3435.49 5947561.04 562251.03 MWD+IFR-AK-CAZ-SC 6774.90 79.13 349.38 3694.41 3585.41 1782.12 3429.38 5947594.07 562244.65 MWD+IFR-AK-CAZ-SC 6820.64 79.62 349.05 3702.84 3593.84 1826.28 3420.97 5947638.16 562235.90 MWD+IFR-AK-CAZ-SC 6869.70 79.71 348.67 3711.65 3602.65 1873.64 3411.64 5947685.43 562226.20 MWD+IFR-AK-CAZ-SC 6920.08 78.89 348.80 3721.00 3612.00 1922.19 3401.97 5947733.90 562216.16 MWD+IFR-AK-CAZ-SC 6963.44 79.06 348.21 3729.29 3620.29 1963.89 3393.49 5947775.54 562207.35 MWD+IFR-AK-CAZ-SC 7011.09 79.51 348.78 3738.15 3629.15 2009.77 3384.15 5947821.34 562197.66 MWD+IFR-AK-CAZ-SC 7059.70 80.03 349.22 3746.78 3637.78 2056.73 3375.03 5947868.22 562188.16 MWD+IFR-AK-CAZ-SC 7105.01 79.52 350.15 3754.83 3645.83 2100.60 3367.04 5947912.02 562179.84 MWD+IFR-AK-CAZ-SC 7152.78 79.58 349.75 3763.49 3654.49 2146.86 3358.84 5947958.20 562171.28 MWD+IFR-AK-CAZ-SC 7201.56 80.00 350.40 3772.14 3663.14 2194.14 3350.57 5948005.42 562162.63 MWD+IFR-AK-CAZ-SC 7247.80 80.34 349.79 3780.03 3671.03 2239.03 3342.73 5948050.24 562154.45 MWD+IFR-AK-CAZ-SC 7343.46 82.25 349.16 3794.51 3685.51 2331.99 3325.46 5948143.05 562136.45 MWD+IFR-AK-CAZ-SC 7364.59 83.90 349.62 3797.06 3688.06 2352.60 3321.60 5948163.64 562132.43 MWD+IFR-AK-CAZ-SC 7438.37 85.10 348.79 3804.13 3695.13 2424.74 3307.84 5948235.66 562118.11 MWD+IFR-AK-CAZ-SC 7457.95 85.54 348.80 3805.73 3696.73 2443.89 3304.05 5948254.77 562114.17 MWD+IFR-AK-CAZ-SC 7518.39 85.68 349.15 3810.35 3701.35 2503.04 3292.53 5948313.82 562102.19 MWD+IFR-AK-CAZ-SC 7550.16 85.61 351.21 3812.77 3703.77 2534.25 3287.12 5948344.99 562096.54 MWD+IFR-AK-CAZ-SC 7612.44 86.31 351.20 3817.15 3708.15 2595.64 3277.62 5948406.30 562086.56 MWD+IFR-AK-CAZ-SC 7649.57 87.73 354.26 3819.08 3710.08 2632.42 3272.93 5948443.04 562081.58 MWD+IFR-AK-CAZ-SC 7678.59 88.34 353.83 3820.08 3711.08 2661.27 3269.92 5948471.85 562078.35 MWD+IFR-AK-CAZ-SC 7706.17 88.70 353.92 3820.79 3711.79 2688.68 3266.98 5948499.24 562075.19 MWD+IFR-AK-CAZ-SC 7751.45 90.76 355.60 3821.01 3712.01 2733.77 3262.85 5948544.29 562070.71 MWD+IFR-AK-CAZ-SC 7799.38 89.67 354.42 3820.83 3711.83 2781.51 3258.68 5948592.00 562066.17 MWD+IFR-AK-CAZ-SC 7892.95 91.11 353.30 3820.19 3711.19 2874.54 3248.67 5948684.93 562055.43 MWD+IFR-AK-CAZ-SC 7985.44 89.92 352.48 3819.36 3710.36 2966.31 3237.22 5948776.61 562043.27 MWD+IFR-AK-CAZ-SC 8078.81 88.13 352.83 3820.95 3711.95 3058.90 3225.29 5948869.09 562030.62 MWD+IFR-AK-CAZ-SC 8171.88 89.07 353.50 3823.22 3714.22 3151.28 3214.22 5948961.37 562018.82 MWD+IFR-AK-CAZ-SC 8265.50 88.45 353.43 3825.25 3716.25 3244.27 3203.57 5949054.26 562007.44 MWD+IFR-AK-CAZ-SC 8360.39 89.38 354.70 3827.04 3718.04 3338.63 3193.76 5949148.54 561996.90 MWD+IFR-AK-CAZ-SC 8405.00 89.38 354.70 3827.53 3718.53 3383.05 3189.64 5949192.92 561992.43 PROJECTED to TD 0 Halliburton Company Survey Report Company: CanoclPhillips Alaska Inc. Date: ; 12/1912006 ` Time- -13:12:11 Page i Field: Kupartlk River Unit Co-ordinate(NE) Reference: Well: 1Jµ1163 True North site: Kuparuk 1J Pad Vertical (TVD)Reference: 1J-115P82: 109.0 Well: 1J-115 Section (VS)Reference: Well(0.t10N;0.00E,0.00Azi) Wellpath 1J 1.15P62 Survey Calculation Method:. Minimum Curvature Db: Oracle Field: Kuparuk River Unit North Slope Alaska United States Map System:US State Plane Coordinate System 1927 Map Zone: Alaska, Zone 4 Geo Datum: NAD27 (Clarke 1866) Coordinate System: Well Centre j Sys Datum: Mean Sea Level Geomagnetic Model: bggm2006 Well: 1 J-115 Slot Name: Well Position: +N/-S-134.58 ft Northing: 5945785.38 ft Latitude: 70 15 44.934 N +E/-W 38.63 ft Easting : 558829.63 ft Longitude: 149 31 27.882 W L Position Uncertainty: 0.00 ft Wellpath: 1J-115PB2 Drilled From: 1J-115PB1 - 500292332071 Tie -on Depth: 7985.44 ft Current Datum: 1 J-115PB2: Height 109.00 It Above System Datum: Mean Sea Level Magnetic Data: 9/25/2006 Declination: 23.78 deg Field Strength: 57610 nT Mag Dip Angle: 80.80 deg Vertical Section: Depth From (TVD) +N/-S +E/-W Direction ft ft ft deg 28.00 0.00 0.00 _ 0.00 Survey Program for Definitive Wellpath Date: 12/19/2006 Validated: No Version: 1 Actual From To Survey Toolcode Tool Name ft ft 50.00 1016.00 1J-115PB1 gyro (50.00-1016.00) CB -GYRO -SS Camera based gyro single shot 1147.04 7985.44 1J-115PB1 (1147.04-8360.39) (3 MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 8081.00 9155.93 1J-115PB2 (8081.00-9155.93) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC Survey MD: Incl Azim TVD Sys TVD NIS E/W MapN MapE. Tool 77 ft deg deg ft ft ft ft ft 28.00 0.00 0.00 28.00 -81.00 0.00 0.00 5945785.38 558829.63 TIE LINE 50.00 0.20 101.96 50.00 -59.00 -0.01 0.04 5945785.37 558829.67 CB -GYRO -SS 100.00 0.19 134.36 100.00 -9.00 -0.08 0.18 5945785.30 558829.81 CB -GYRO -SS 172.00 0.07 306.93 172.00 63.00 -0.14 0.23 5945785.24 558829.86 CB -GYRO -SS 260.00 0.07 81.28 260.00 151.00 -0.10 0.24 5945785.28 558829.87 CB -GYRO -SS 356.00 0.12 272.58 356.00 247.00 -0.09 0.20 5945785.29 558829.83 CB -GYRO -SS 447.00 1.38 98.80 446.99 337.99 -0.25 1.19 5945785.14 558830.82 CB -GYRO -SS 540.00 3.65 90.60 539.90 430.90 -0.45 5.26 5945784.97 558834.89 CB -GYRO -SS 632.00 6.87 83.95 631.50 522.50 0.10 13.66 5945785.58 558843.28 CB -GYRO -SS 734.00 12.14 85.32 732.06 623.06 1.62 30.43 5945787.23 558860.04 CB -GYRO -SS 828.00 14.65 87.39 823.50 714.50 2.96 52.15 5945788.75 558881.76 CB -GYRO -SS 923.00 16.60 93.22 914.99 805.99 2.75 77.71 5945788.74 558907.31 CB -GYRO -SS 1016.00 19.62 96.55 1003.37 894.37 0.22 106.49 5945786.43 558936.11 CB -GYRO -SS 1147.04 19.73 100.48 1126.77 1017.77 -6.31 150.10 5945780.24 558979.76 MWD+IFR-AK-CAZ-SC 1239.14 20.76 99.26 1213.18 1104.18 -11.77 181.50 5945775.03 559011.20 MWD+IFR-AK-CAZ-SC 1336.46 25.69 100.98 1302.58 1193.58 -18.56 219.25 5945768.53 559049.00 MWD+IFR-AK-CAZ-SC 1430.30 32.19 97.67 1384.67 1275.67 -25.78 264.04 5945761.66 559093.84 MWD+IFR-AK-CAZ-SC 1527.05 34.57 97.87 1465.45 1356.45 -32.98 316.78 5945754.88 559146.63 MWD+IFR-AK-CAZ-SC 1623.88 39.43 96.68 1542.76 1433.76 -40.32 374.57 5945747.99 559204.47 MWD+IFR-AK-CAZ-SC 1717.45 47.02 98.39 1610.90 1501.90 -48.79 438.04 5945740.02 559267.99 MWD+IFR-AK-CAZ-SC 1763.81 49.23 98.35 1641.84 1532.84 -53.81 472.19 5945735.26 559302.18 MWD+IFR-AK-CAZ-SC 1812.39 49.81 98.48 1673.38 1564.38 -59.22 508.74 5945730.14 559338.77 MWD+IFR-AK-CAZ-SC 1859.85 51.05 98.27 1703.61 1594.61 -64.55 544.94 5945725.10 559375.00 MWD+IFR-AK-CAZ-SC 1909.19 52.88 97.27 1734.01 1625.01 -69.80 583.44 5945720.15 559413.54 MWD+IFR-AK-CAZ-SC 1956.90 56.75 96.14 1761.50 1652.50 -74.34 622.16 5945715.91 559452.29 MWD+IFR-AK-CAZ-SC 2004.98 60.06 94.39 1786.68 1677.68 -78.09 662.93 5945712.48 559493.09 MWD+IFR-AK-CAZ-SC 2052.33 61.37 94.72 1809.84 1700.84 -81.37 704.10 5945709.52 559534.28 MWD+IFR-AK-CAZ-SC 2099.08 65.15 94.08 1830.88 1721.88 -84.57 745.72 5945706.65 559575.91 MWD+IFR-AK-CAZ-SC Halliburton Company Survey Report Company: ConocoPhiliips Alaska Inc. J'ield: Kuparuk River Unit Site: Kuparuk 1J Pad Well: 1 J-115 Wellpath 1J-115PB2 Survey Date: 12/19/2006 Time: 13:12:11 _._ Page: Z ,- Co-ordinate(NE)Reference. - Weil: U-115, True North 'Vertical (TVD)Reference: 1J7115P132: 109.€I Section (V$) Reference: Weir (0.00N,0.00E,0.00Azi) Survey Calculation Method: Minimum Curvature Db: Oracle F MI) Incl Airm TVD Sys TVD' ; N/S E/W MapN Nlapl Fool ft deg . dog ft ft ft ft ft . ft -- 2146.11 66.24 94.32 1850.23 1741.23 -87.70 788.46 _ 5945703.85 559618.68 -- MWD+IFR-AK-CAZ-SC 2195.14 65.38 94.46 1870.32 1761.32 -91.13 833.06 5945700.77 559663.29 MWD+IFR-AK-CAZ-SC 2243.32 65.22 94.86 1890.46 1781.46 -94.68 876.68 5945697.56 559706.94 MWD+IFR-AK-CAZ-SC 2290.05 65.23 95.29 1910.04 1801.04 -98.44 918.95 5945694.13 559749.23 MWD+IFR-AK-CAZ-SC 2384.30 66.21 92.85 1948.80 1839.80 -104.53 1004.63 5945688.71 559834.95 MWD+IFR-AK-CAZ-SC 2431.35 66.51 91.83 1967.67 1858.67 -106.29 1047.70 5945687.29 559878.03 MWD+IFR-AK-CAZ-SC 2479.29 65.14 92.38 1987.30 1878.30 -107.89 1091.40 5945686.03 559921.74 MWD+IFR-AK-CAZ-SC 2525.10 64.21 92.41 2006.89 1897.89 -109.62 1132.78 5945684.62 559963.12 MWD+IFR-AK-CAZ-SC 2574.27 64.84 92.04 2028.04 1919.04 -111.35 1177.13 5945683.24 560007.48 MWD+IFR-AK-CAZ-SC 2621.23 65.32 92.80 2047.83 1938.83 -113.14 1219.68 5945681.78 560050.04 MWD+IFR-AK-CAZ-SC 2668.37 64.85 93.77 2067.69 1958.69 -115.59 1262.36 5945679.66 560092.74 MWD+IFR-AK-CAZ-SC 2716.31 63.56 93.99 2088.55 1979.55 -118.51 1305.43 5945677.08 560135.82 MWD+IFR-AK-CAZ-SC 2764.95 62.48 93.85 2110.61 2001.61 -121.48 1348.67 5945674.45 560179.08 MWD+IFR-AK-CAZ-SC 2792.69 63.61 94.72 2123.19 2014.19 -123.33 1373.33 5945672.80 560203.75 MWD+IFR-AK-CAZ-SC 2858.21 64.46 95.53 2151.88 2042.88 -128.59 1432.00 5945667.99 560262.45 MWD+IFR-AK-CAZ-SC 2923.29 65.79 94.45 2179.25 2070.25 -133.72 1490.81 5945663.32 560321.30 MWD+IFR-AK-CAZ-SC 2953.10 65.83 94.21 2191.47 2082.47 -135.77 1517.93 5945661.48 560348.43 MWD+IFR-AK-CAZ-SC 3020.46 64.26 94.73 2219.88 2110.88 -140.53 1578.81 5945657.20 560409.34 MWD+IFR-AK-CAZ-SC 3066.57 63.09 96.12 2240.33 2131.33 -144.44 1619.95 5945653.62 560450.50 MWD+IFR-AK-CAZ-SC 3115.25 62.06 96.47 2262.75 2153.75 -149.17 1662.90 5945649.22 560493.48 MWD+IFR-AK-CAZ-SC 3161.89 60.79 95.77 2285.06 2176.06 -153.54 1703.62 5945645.17 560534.24 MWD+IFR-AK-CAZ-SC 3207.64 59.59 95.17 2307.81 2198.81 -157.33 1743.14 5945641.69 560573.78 MWD+IFR-AK-CAZ-SC 3257.07 59.30 95.67 2332.93 2223.93 -161.35 1785.51 5945638.00 560616.18 MWD+IFR-AK-CAZ-SC 3302.16 60.64 95.08 2355.50 2246.50 -165.00 1824.38 5945634.65 560655.07 MWD+IFR-AK-CAZ-SC 3351.77 61.76 94.04 2379.40 2270.40 -168.46 1867.71 5945631.54 560698.42 MWD+IFR-AK-CAZ-SC 3397.36 61.52 94.13 2401.05 2292.05 -171.31 1907.73 5945628.99 560738.46 MWD+IFR-AK-CAZ-SC 3445.60 61.94 94.01 2423.90 2314.90 -174.33 1950.11 5945626.31 560780.85 MWD+IFR-AK-CAZ-SC 3541.93 64.26 92.53 2467.48 2358.48 -179.22 2035.87 5945622.09 560866.64 MWD+IFR-AK-CAZ-SC i 3587.60 63.76 92.85 2487.50 2378.50 -181.14 2076.87 5945620.48 560907.65 MWD+IFR-AK-CAZ-SC 3637.30 63.20 92.99 2509.69 2400.69 -183.41 2121.28 5945618.57 560952.08 MWD+IFR-AK-CAZ-SC 3683.58 62.11 93.43 2530.95 2421.95 -185.71 2162.33 5945616.59 560993.14 MWD+IFR-AK-CAZ-SC 3730.50 61.48 93.54 2553.12 2444.12 -188.22 2203.60 5945614.39 561034.42 MWD+IFR-AK-CAZ-SC 3783.12 62.18 92.50 2577.96 2468.96 -190.67 2249.92 5945612.31 561080.76 MWD+IFR-AK-CAZ-SC 3826.51 61.89 92.49 2598.31 2489.31 -192.33 2288.21 5945610.95 561119.05 MWD+IFR-AK-CAZ-SC 3873.70 62.90 92.02 2620.18 2511.18 -193.98 2329.99 5945609.63 561160.84 MWD+IFR-AK-CAZ-SC 3921.50 64.20 91.19 2641.47 2532.47 -195.18 2372.77 5945608.77 561203.63 MWD+IFR-AK-CAZ-SC 3975.48 62.84 89.69 2665.54 2556.54 -195.55 2421.08 5945608.77 561251.94 MWD+IFR-AK-CAZ-SC 4011.14 63.44 87.24 2681.65 2572.65 -194.70 2452.88 5945609.87 561283.72 MWD+IFR-AK-CAZ-SC 4065.80 63.59 84.65 2706.03 2597.03 -191.24 2501.68 5945613.71 561332.49 MWD+IFR-AK-CAZ-SC 4111.07 63.08 82.85 2726.35 2617.35 -186.83 2541.89 5945618.43 561372.66 MWD+IFR-AK-CAZ-SC 4161.60 62.71 82.07 2749.37 2640.37 -180.93 2586.48 5945624.68 561417.20 MWD+IFR-AK-CAZ-SC 4207.41 62.05 81.09 2770.61 2661.61 -174.99 2626.63 5945630.93 561457.30 MWD+IFR-AK-CAZ-SC 4302.87 60.78 75.96 2816.31 2707.31 -158.35 2708.74 5945648.22 561539.27 MWD+IFR-AK-CAZ-SC 4397.88 61.00 71.95 2862.54 2753.54 -135.41 2788.49 5945671.78 561618.83 MWD+IFR-AK-CAZ-SC 4444.65 61.15 70.43 2885.16 2776.16 -122.21 2827.24 5945685.28 561657.47 MWD+IFR-AK-CAZ-SC 4493.15 62.09 66.97 2908.22 2799.22 -106.71 2866.99 5945701.09 561697.09 MWD+IFR-AK-CAZ-SC 4587.16 63.03 60.70 2951.58 2842.58 -69.92 2941.81 5945738.45 561771.61 MWD+IFR-AK-CAZ-SC 4681.64 63.67 55.12 2993.98 2884.98 -25.08 3013.30 5945783.84 561842.75 MWD+IFR-AK-CAZ-SC 4776.45 63.61 48.37 3036.12 2927.12 27.48 3079.96 5945836.91 561908.99 MWD+IFR-AK-CAZ-SC i 4872.66 62.93 42.02 3079.43 2970.43 87.98 3140.89 5945897.88 561969.44 MWD+IFR-AK-CAZ-SC 4966.48 62.78 36.83 3122.25 3013.25 152.43 3193.89 5945962.74 562021.92 MWD+IFR-AK-CAZ-SC 5061.23 63.60 30.93 3165.02 3056.02 222.60 3240.99 5946033.27 562068.47 MWD+IFR-AK-CAZ-SC Halliburton Company Survey Report Company: ConocoPhillips Arlaska Inc Dare: 12/1912006 Time: 13:12:11 Page: 3 Reid: Kupanuk River Unit Co-ordinate(NE) Retercmce: Well: '1 J-115, True North Site: Kuparuk 1J Pad Vertical (TVD)Reference- 1J-115p : 109.0 Well: 1 J-115 Section (VS) Reference: Well (O.00N,O.00E,O.00Azi) Wellpath: 1 JAI SP82 Survey Calculation Method: Minimum Curvature Db Oracle Survey MD t Incl. Azini TVD.; .SysTVD /S E/W MOON MapE Coei ft deg deg ft ft ', ft ft ft ft 5154.55 63.67 26.34 3206.48 3097.48 295.96 3281.04 5946106.94 562107.94 MWD+IFR-AK-CAZ-SC 5249.86 64.52 23.85 3248.12 3139.12 373.60 3317.39 5946184.85 562143.68 MWD+IFR-AK-CAZ-SC 5344.89 64.58 23.84 3288.96 3179.96 452.08 3352.08 5946263.59 562177.75 MWD+IFR-AK-CAZ-SC 5440.16 64.61 24.40 3329.83 3220.83 530.62 3387.25 5946342.40 562212.30 MWD+IFR-AK-CAZ-SC 5537.28 64.76 24.25 3371.36 3262.36 610.62 3423.41 5946422.67 562247.84 MWD+IFR-AK-CAZ-SC 5630.91 66.63 19.01 3409.92 3300.92 689.92 3454.82 5946502.20 562278.63 MWD+IFR-AK-CAZ-SC 5724.54 69.47 14.47 3444.93 3335.93 773.05 3479.79 5946585.52 562302.94 MWD+IFR-AK-CAZ-SC 5818.75 70.89 10.45 3476.88 3367.88 859.57 3498.90 5946672.18 562321.37 MWD+IFR-AK-CAZ-SC 5915.97 72.53 6.28 3507.41 3398.41 950.88 3512.30 5946763.57 562334.06 MWD+IFR-AK-CAZ-SC 6011.71 75.39 0.95 3533.87 3424.87 1042.66 3518.07 5946855.39 562339.11 MWD+IFR-AK-CAZ-SC 6106.21 77.01 355.82 3556.43 3447.43 1134.36 3515.47 5946947.06 562335.80 MWD+IFR-AK-CAZ-SC 6199.94 81.12 356.20 3574.21 3465.21 1226.14 3509.07 5947038.78 562328.68 MWD+IFR-AK-CAZ-SC 6296.29 79.71 354.23 3590.25 3481.25 1320.81 3501.15 5947133.37 562320.02 MWD+IFR-AK-CAZ-SC 6390.76 77.22 353.37 3609.14 3500.14 1412.82 3491.16 5947225.30 562309.31 MWD+IFR-AK-CAZ-SC 6485.62 77.17 350.57 3630.17 3521.17 1504.41 3478.24 5947316.77 562295.68 MWD+IFR-AK-CAZ-SC 6582.32 75.23 350.18 3653.23 3544.23 1596.99 3462.54 5947409.22 562279.26 MWD+IFR-AK-CAZ-SC 6677.73 77.93 349.85 3675.37 3566.37 1688.38 3446.45 5947500.47 562262.45 MWD+IFR-AK-CAZ-SC 6740.64 79.05 349.68 3687.93 3578.93 1749.04 3435.49 5947561.04 562251.03 MWD+IFR-AK-CAZ-SC 6774.90 79.13 349.38 3694.41 3585.41 1782.12 3429.38 5947594.07 562244.65 MWD+IFR-AK-CAZ-SC 6820.64 79.62 349.05 3702.84 3593.84 1826.28 3420.97 5947638.16 562235.90 MWD+IFR-AK-CAZ-SC 6869.70 79.71 348.67 3711.65 3602.65 1873.64 3411.64 5947685.43 562226.20 MWD+IFR-AK-CAZ-SC 6920.08 78.89 348.80 3721.00 3612.00 1922.19 3401.97 5947733.90 562216.16 MWD+IFR-AK-CAZ-SC 6963.44 79.06 348.21 3729.29 3620.29 1963.89 3393.49 5947775.54 562207.35 MWD+IFR-AK-CAZ-SC 7011.09 79.51 348.78 3738.15 3629.15 2009.77 3384.15 5947821.34 562197.66 MWD+IFR-AK-CAZ-SC 7059.70 80.03 349.22 3746.78 3637.78 2056.73 3375.03 5947868.22 562188.16 MWD+IFR-AK-CAZ-SC 7105.01 79.52 350.15 3754.83 3645.83 2100.60 3367.04 5947912.02 562179.84 MWD+IFR-AK-CAZ-SC 7152.78 79.58 349.75 3763.49 3654.49 2146.86 3358.84 5947958.20 562171.28 MWD+IFR-AK-CAZ-SC 7201.56 80.00 350.40 3772.14 3663.14 2194.14 3350.57 5948005.42 562162.63 MWD+IFR-AK-CAZ-SC 7247.80 80.34 349.79 3780.03 3671.03 2239.03 3342.73 5948050.24 562154.45 MWD+IFR-AK-CAZ-SC 7343.46 82.25 349.16 3794.51 3685.51 2331.99 3325.46 5948143.05 562136.45 MWD+IFR-AK-CAZ-SC 7364.59 83.90 349.62 3797.06 3688.06 2352.60 3321.60 5948163.64 562132.43 MWD+IFR-AK-CAZ-SC 7438.37 85.10 348.79 3804.13 3695.13 2424.74 3307.84 5948235.66 562118.11 MWD+IFR-AK-CAZ-SC 7457.95 85.54 348.80 3805.73 3696.73 2443.89 3304.05 5948254.77 562114.17 MWD+IFR-AK-CAZ-SC 7518.39 85.68 349.15 3810.35 3701.35 2503.04 3292.53 5948313.82 562102.19 MWD+IFR-AK-CAZ-SC 7550.16 85.61 351.21 3812.77 3703.77 2534.25 3287.12 5948344.99 562096.54 MWD+IFR-AK-CAZ-SC 7612.44 86.31 351.20 3817.15 3708.15 2595.64 3277.62 5948406.30 562086.56 MWD+IFR-AK-CAZ-SC 7649.57 87.73 354.26 3819.08 3710.08 2632.42 3272.93 5948443.04 562081.58 MWD+IFR-AK-CAZ-SC 7678.59 88.34 353.83 3820.08 3711.08 2661.27 3269.92 5948471.85 562078.35 MWD+IFR-AK-CAZ-SC 7706.17 88.70 353.92 3820.79 3711.79 2688.68 3266.98 5948499.24 562075.19 MWD+IFR-AK-CAZ-SC 7751.45 90.76 355.60 3821.01 3712.01 2733.77 3262.85 5948544.29 562070.71 MWD+IFR-AK-CAZ-SC 7799.38 89.67 354.42 3820.83 3711.83 2781.51 3258.68 5948592.00 562066.17 MWD+IFR-AK-CAZ-SC 7892.95 91.11 353.30 3820.19 3711.19 2874.54 3248.67 5948684.93 562055.43 MWD+IFR-AK-CAZ-SC 7985.44 89.92 352.48 3819.36 3710.36 2966.31 3237.22 5948776.61 562043.27 MWD+IFR-AK-CAZ-SC 8081.00 87.84 353.93 3821.23 3712.23 3061.17 3225.92 5948871.37 562031.23 MWD+IFR-AK-CAZ-SC 8173.08 88.27 350.40 3824.35 3715.35 3152.33 3213.38 5948962.41 562017.97 MWD+IFR-AK-CAZ-SC 8266.42 91.12 350.83 3824.85 3715.85 3244.41 3198.16 5949054.36 562002.04 MWD+IFR-AK-CAZ-SC 8311.52 92.22 351.46 3823.53 3714.53 3288.95 3191.22 5949098.84 561994.75 MWD+IFR-AK-CAZ-SC 8360.15 92.28 352.02 3821.63 3712.63 3337.04 3184.24 5949146.87 561987.40 MWD+IFR-AK-CAZ-SC 8452.71 91.53 352.19 3818.55 3709.55 3428.67 3171.53 5949238.39 561973.97 MWD+IFR-AK-CAZ-SC 8545.65 89.98 353.01 3817.32 3708.32 3520.82 3159.56 5949330.44 561961.29 MWD+IFR-AK-CAZ-SC 8640.45 90.24 353.36 3817.14 3708.14 3614.95 3148.31 5949424.47 561949.30 MWD+IFR-AK-CAZ-SC -- 8733.19 - 89.74 352.333 381716 3708.16 3706.97 3136.76 5949516.39 561937.04 MWD+IFR-AK-CAZ-SC 8826.57 89.68 352.64 3817.63 3708.63 3799.55 3124.55 5949608.86 561924.10 MWD+IFR-AK-CAZ-SC Halliburton Company Survey Report Survey 8919.80 89.75 351.38 3818.09 3709.09 3891.87 3111.59 5949701.06 561910.42 MWD+IFR-AK-CAZ-SC 9012.81 90.37 349.91 3818.00 3709.00 3983.64 3096.47 5949792.70 561894.59 MWD+IFR-AK-CAZ-SC 9105.07 91.48 353.21 3816.51 3707.51 4074.87 3082.94 5949883.82 561880.34 MWD+IFR-AK-CAZ-SC 9155.93 91.79 354.35 3815.06 3706.06 4125.41 3077.43 5949934.31 561874.44 MWD+IFR-AK-CAZ-SC 9190.00 91.79 354.35 3813.99 3704.99 4159.30 3074.07 5949968.17 561870.82 PROJECTED to TD Halliburton Company Survey Report Company: ConocoPhillips Alaska Inc. _ Date 12/IWOW `- Time: 13:24:21 Page. , # _.. Reid: Kuparuk River Unit Co-ordinate(NE) Deference: WeIt:1J-1IS, True North Site Kuparuk 1J Pad' Vertical(TVD)Reference: 1j t5PB3: 1WO Well- 1J-115 Section (VS)Reference: Welt (O.00N,O.00E,O.00Azt) Wellpath 1J-115PS3 Survey Calculation Method: Minimum Curvature . Db: Oracle,.,,,',;'i Field: Kuparuk River Unit North Slope Alaska United States Map Systcm:US State Plane Coordinate System 1927 Map Zone: Alaska, Zone 4 Geo Datum: NAD27 (Clarke 1866) Coordinate System: Well Centre Sys Datum: Mean Sea Level Geomagnetic Model: bggm2006 Well: 1 J-115 Slot Name: Well Position: +N/-S-134.58 ft Northing: 5945785.38 ft Latitude: 70 15 44.934 N +E/-W 38.63 ft Easting : 558829.63 ft Longitude: 149 31 27.882 W Position Uncertainty: 0.00 ft W lle path 1J-115PB3 Drilled From: 1J-115PB2 500292332072 Tie -on Depth: 8826.57 ft Current Datum: 1 J-115PB3: Height 109.00 ft Above System Datum: Mean Sea Level Magnetic Data: 9/25/2006 Declination: 23.78 deg Field Strength: 57610 nT Mag Dip Angle: 80.80 deg Vertical Section: Depth From (TVD) +N/-S +E/-W Direction ft ft It deg 28.00 0.00 0.00 0.00 Survey Program for Definitive Wellpath Date: 12119/2006 Validated: No Version: 1 Actual From To Survey Toolcode Tool Name ft ft 50.00 1016.00 1J-115PB1 gyro (50.00-1016.00) CB -GYRO -SS Camera based gyro single shot 1147.04 7985.44 1J-115PB1 (1147.04-8360.39) (3 MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 8081.00 8826.57 1 J-115PB2 (8081.00-9155.93) (4 MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 8885.00 11981.36 1J-115PB3 (8885.00-11981.36) MWD+IFR-AK_CAZ-SC MWD+IFR AK CAZ SCC Survey MD: Incl Azim TVD Sys TVD N/S E/W MapN MapE . ft deg deg ft ft ft ft ft It -Tool 28.00 0.00 0.00 28.00 -81.00 0.00 0.00 5945785.38 558829.63 � TIE LINE %00 0.20 101.96 50.00 -59.00 -0.01 0.04 5945785.37 558829.67 CB -GYRO -SS 100.00 0.19 134.36 100.00 -9.00 -0.08 0.18 5945785.30 558829.81 CB -GYRO -SS 172.00 0.07 306.93 172.00 63.00 -0.14 0.23 5945785.24 558829.86 CB -GYRO -SS 260.00 0.07 81.28 260.00 151.00 -0.10 0.24 5945785.28 558829.87 CB -GYRO -SS 356.00 0.12 272.58 356.00 247.00 -0.09 0.20 5945785.29 558829.83 CB -GYRO -SS 447.00 1.38 98.80 446.99 337.99 -0.25 1.19 5945785.14 558830.82 CB -GYRO -SS 540.00 3.65 90.60 539.90 430.90 -0.45 5.26 5945784.97 558834.89 CB -GYRO -SS 632.00 6.87 83.95 631.50 522.50 0.10 13.66 5945785.58 558843.28 CB -GYRO -SS 734.00 12.14 85.32 732.06 623.06 1.62 30.43 5945787.23 558860.04 CB -GYRO -SS 828.00 14.65 87.39 823.50 714.50 2.96 52.15 5945788.75 558881.76 CB -GYRO -SS 923.00 16.60 93.22 914.99 805.99 2.75 77.71 5945788.74 558907.31 CB -GYRO -SS 1016.00 19.62 96.55 1003.37 894.37 0.22 106.49 5945786.43 558936.11 CB -GYRO -SS 1147.04 19.73 100.48 1126.77 1017.77 -6.31 150.10 5945780.24 558979.76 MWD+IFR-AK-CAZ-SC 1239.14 20.76 99.26 1213.18 1104.18 -11.77 181.50 5945775.03 559011.20 MWD+IFR-AK-CAZ-SC 1336.46 25.69 100.98 1302.58 1193.58 -18.56 219.25 5945768.53 559049.00 MWD+IFR-AK-CAZ-SC 1430.30 32.19 97.67 1384.67 1275.67 -25.78 264.04 5945761.66 559093.84 MWD+IFR-AK-CAZ-SC 1527.05 34.57 97.87 1465.45 1356.45 -32.98 316.78 5945754.88 559146.63 MWD+IFR-AK-CAZ-SC 1623.88 39,43 96.68 1542.76 1433.76 -40.32 374.57 5945747.99 559204.47 MWD+IFR-AK-CAZ-SC 1717.45 47.02 98.39 1610.90 1501.90 -48.79 438.04 5945740.02 559267.99 MWD+IFR-AK-CAZ-SC 1763.81 49.23 98.35 1641.84 1532.84 -53.81 472.19 5945735.26 559302.18 MWD+IFR-AK-CAZ-SC 1812.39 49.81 98.48 1673.38 1564.38 -59.22 508.74 5945730.14 559338.77 MWD+IFR-AK-CAZ-SC 1859.85 51.05 98.27 1703.61 1594.61 -64.55 544.94 5945725.10 559375.00 MWD+IFR-AK-CAZ-SC j 1909.19 52.88 97.27 1734.01 1625.01 -69.80 583.44 5945720.15 559413.54 MWD+IFR-AK-CAZ-SC 1956.90 56.75 96.14 1761.50 1652.50 -74.34 622.16 5945715.91 559452.29 MWD+IFR-AK-CAZ-SC 2004.98 60.06 94.39 1786.68 1677.68 -78.09 662.93 5945712.48 559493.09 MWD+IFR-AK-CAZ-SC 2052.33 61.37 94.72 1809.84 1700.84 -81.37 704.10 5945709.52 559534.28 MWD+IFR-AK-CAZ-SC Halliburton Company Survey Report Company: CongccrPhillips P laska Inc. Field: Kuparuk River Unit E Site: Ku aruk 1J Pad p Well: 11-115 Wellpath': 1J-115PB3 Survey Bate: 12f1-912006 =. T➢me: 13:244 21 Page: 2" ; Co-ordinate(NE) Refe e: Well. IJ-1IS, Truce Nbith Vertical (Tl•'D) Reference-, 1J-115PB3: 1090 -, Section (VS) Reference .. Well (0.00N,O.00 0.00Azi) Surrey Calculation Method: Minimum Curvature Db: Oracle' MD Ioci Azim , "i UD Sys TVD N/S , E/W MapN MapE Tool ft deg deg-' ft It it it it ft, 2099.08 65.15 94.08 1830.88 1721.88 -84.57 745.72 5945706.65 559575.91 MWD+IFR-AK-CAZ-SC 2146.11 66.24 94.32 1850.23 1741.23 -87.70 788.46 5945703.85 559618.68 MWD+IFR-AK-CAZ-SC 2195.14 65.38 94.46 1870.32 1761.32 -91.13 833.06 5945700.77 559663.29 MWD+IFR-AK-CAZ-SC 2243.32 65.22 94.86 1890.46 1781.46 -94.68 876.68 5945697.56 559706.94 MWD+IFR-AK-CAZ-SC 2290.05 65.23 95.29 1910.04 1801.04 -98.44 918.95 5945694.13 559749.23 MWD+IFR-AK-CAZ-SC 2384.30 66.21 92.85 1948.80 1839.80 -104.53 1004.63 5945688.71 559834.95 MWD+IFR-AK-CAZ-SC 2431.35 66.51 91.83 1967.67 1858.67 -106.29 1047.70 5945687.29 559878.03 MWD+IFR-AK-CAZ-SC 2479.29 65.14 92.38 1987.30 1878.30 -107.89 1091.40 5945686.03 559921.74 MWD+IFR-AK-CAZ-SC 2525.10 64.21 92.41 2006.89 1897.89 -109.62 1132.78 5945684.62 559963.12 MWD+IFR-AK-CAZ-SC 2574.27 64.84 92.04 2028.04 1919.04 -111.35 1177.13 5945683.24 560007.48 MWD+IFR-AK-CAZ-SC 2621.23 65.32 92.80 2047.83 1938.83 -113.14 1219.68 5945681.78 560050.04 MWD+IFR-AK-CAZ-SC 2668.37 64.85 93.77 2067.69 1958.69 -115.59 1262.36 5945679.66 560092.74 MWD+IFR-AK-CAZ-SC 2716.31 63.56 93.99 2088.55 1979.55 -118.51 1305.43 5945677.08 560135.82 MWD+IFR-AK-CAZ-SC 2764.95 62.48 93.85 2110.61 2001.61 -121.48 1348.67 5945674.45 560179.08 MWD+IFR-AK-CAZ-SC 2792.69 63.61 94.72 2123.19 2014.19 -123.33 1373.33 5945672.80 560203.75 MWD+IFR-AK-CAZ-SC 2858.21 64.46 95.53 2151.88 2042.88 -128.59 1432.00 5945667.99 560262.45 MWD+IFR-AK-CAZ-SC 2923.29 65.79 94.45 2179.25 2070.25 -133.72 1490.81 5945663.32 560321.30 MWD+IFR-AK-CAZ-SC 2953.10 65.83 94.21 2191.47 2082.47 -135.77 1517.93 5945661.48 560348.43 MWD+IFR-AK-CAZ-SC 3020.46 64.26 94.73 2219.88 2110.88 -140.53 1578.81 5945657.20 560409.34 MWD+IFR-AK-CAZ-SC 3066.57 63.09 96.12 2240.33 2131.33 -144.44 1619.95 5945653.62 560450.50 MWD+IFR-AK-CAZ-SC 3115.25 62.06 96.47 2262.75 2153.75 -149.17 1662.90 5945649.22 560493.48 MWD+IFR-AK-CAZ-SC 3161.89 60.79 95.77 2285.06 2176.06 -153.54 1703.62 5945645.17 560534.24 MWD+IFR-AK-CAZ-SC 3207.64 59.59 95.17 2307.81 2198.81 -157.33 1743.14 5945641.69 560573.78 MWD+IFR-AK-CAZ-SC 3257.07 59.30 95.67 2332.93 2223.93 -161.35 1785.51 5945638.00 560616.18 MWD+IFR-AK-CAZ-SC 3302.16 60.64 95.08 2355.50 2246.50 -165.00 1824.38 5945634.65 560655.07 MWD+IFR-AK-CAZ-SC 3351.77 61.76 94.04 2379.40 2270.40 -168.46 1867.71 5945631.54 560698.42 MWD+IFR-AK-CAZ-SC 3397.36 61.52 94.13 2401.05 2292.05 -171.31 1907.73 5945628.99 560738.46 MWD+IFR-AK-CAZ-SC 3445.60 61.94 94.01 2423.90 2314.90 -174.33 1950.11 5945626.31 560780.85 MWD+IFR-AK-CAZ-SC 3541.93 64.26 92.53 2467.48 2358.48 -179.22 2035.87 5945622.09 560866.64 MWD+IFR-AK-CAZ-SC 3587.60 63.76 92.85 2487.50 2378.50 -181.14 2076.87 5945620.48 560907.65 MWD+IFR-AK-CAZ-SC 3637.30 63.20 92.99 2509.69 2400.69 -183.41 2121.28 5945618.57 560952.08 MWD+IFR-AK-CAZ-SC 3683.58 62.11 93.43 2530.95 2421.95 -185.71 2162.33 5945616.59 560993.14 MWD+IFR-AK-CAZ-SC 3730.50 61.48 93.54 2553.12 2444.12 -188.22 2203.60 5945614.39 561034.42 MWD+IFR-AK-CAZ-SC 3783.12 62.18 92.50 2577.96 2468.96 -190.67 2249.92 5945612.31 561080.76 MWD+IFR-AK-CAZ-SC 3826.51 61.89 92.49 2598.31 2489.31 -192.33 2288.21 5945610.95 561119.05 MWD+IFR-AK-CAZ-SC 3873.70 62.90 92.02 2620.18 2511.18 -193.98 2329.99 5945609.63 561160.84 MWD+IFR-AK-CAZ-SC 3921.50 64.20 91.19 2641.47 2532.47 -195.18 2372.77 5945608.77 561203.63 MWD+IFR-AK-CAZ-SC 3975.48 62.84 89.69 2665.54 2556.54 -195.55 2421.08 5945608.77 561251.94 MWD+IFR-AK-CAZ-SC 4011.14 63.44 87.24 2681.65 2572.65 -194.70 2452.88 5945609.87 561283.72 MWD+IFR-AK-CAZ-SC 4065.80 63.59 84.65 2706.03 2597.03 -191.24 2501.68 5945613.71 561332.49 MWD+IFR-AK-CAZ-SC 4111.07 63.08 82.85 2726.35 2617.35 -186.83 2541.89 5945618.43 561372.66 MWD+IFR-AK-CAZ-SC 4161.60 62.71 82.07 2749.37 2640.37 -180.93 2586.48 5945624.68 561417.20 MWD+IFR-AK-CAZ-SC 4207.41 62.05 81.09 2770.61 2661.61 -174.99 2626.63 5945630.93 561457.30 MWD+IFR-AK-CAZ-SC 4302.87 60.78 75.96 2816.31 2707.31 -158.35 2708.74 5945648.22 561539.27 MWD+IFR-AK-CAZ-SC 4397.88 61.00 71.95 2862.54 2753.54 -135.41 2788.49 5945671.78 561618.83 MWD+IFR-AK-CAZ-SC 4444.65 61.15 70.43 2885.16 2776.16 -122.21 2827.24 5945685.28 561657.47 MWD+IFR-AK-CAZ-SC 4493.15 62.09 66.97 2908.22 2799.22 -106.71 2866.99 5945701.09 561697.09 MWD+IFR-AK-CAZ-SC 4587.16 63.03 60.70 2951.58 2842.58 -69.92 2941.81 5945738.45 561771.61 MWD+IFR-AK-CAZ-SC 4681.64 63.67 55.12 2993.98 2884.98 -25.08 3013.30 5945783.84 561842.75 MWD+IFR-AK-CAZ-SC 4776.45 63.61 48.37 3036.12 2927.12 27.48 3079.96 5945836.91 561908.99 MWD+IFR-AK-CAZ-SC 4872.66 62.93 42.02 3079.43 2970.43 87.98 3140.89 5945897.88 561969.44 MWD+IFR-AK-CAZ-SC 4966.48 62.78 36.83 3122.25 3013.25 152.43 3193.89 5945962.74 562021.92 MWD+IFR-AK-CAZ-SC 5061.23 63.60 30.93 3165.02 3056.02 222.60 3240.99 5946033.27 562068.47 MWD+IFR-AK-CAZ-SC Halliburton Company Survey Report Company: C6noc6Phillips Alaska Inc. - - -- Date: 12l1912006 Time: ' 13:2*11 _- page: 3 Field: Kuparuk River Unit Co-ordinate(NE)Reference:. Well: 1J-1 15, True North Site:Kuparuk 1J Pad Vertical (TVD) Reference 1J-115PI33: 109.0 Well. 1J-115 Section (VS)ReferenceWell (O.60N,0.00E,0.00Azi) Wellpafh 1J-115P63 Survey Calculation Method: Minimum Curvature Db- Oracle Survey MD Incl Azim. TVD Sys TVD N/S E1W MapN Ma PIETool ft deg deg ft ft ft ft it it 5154.55 63.67 26.34 3206.48 3097.48 295.96 3281.04 5946106.94 562107.94 MWD+IFR-AK-CAZ-SC 5249.86 64.52 23.85 3248.12 3139.12 373.60 3317.39 5946184.85 562143.68 MWD+IFR-AK-CAZ-SC 5344.89 64.58 23.84 3288.96 3179.96 452.08 3352.08 5946263.59 562177.75 MWD+IFR-AK-CAZ-SC 5440.16 64.61 24.40 3329.83 3220.83 530.62 3387.25 5946342.40 562212.30 MWD+IFR-AK-CAZ-SC 5537.28 64.76 24.25 3371.36 3262.36 610.62 3423.41 5946422.67 562247.84 MWD+IFR-AK-CAZ-SC 5630.91 66.63 19.01 3409.92 3300.92 689.92 3454.82 5946502.20 562278.63 MWD+IFR-AK-CAZ-SC 5724.54 69.47 14.47 3444.93 3335.93 773.05 3479.79 5946585.52 562302.94 MWD+IFR-AK-CAZ-SC 5818.75 70.89 10.45 3476,88 3367,811 859.57 3498.90 5946672,18 562321.37 MWD+IFR-AK-CAZ-SC 5915.97 72.53 6.28 3507.41 3398.41 950.88 3512.30 5946763.57 562334.06 MWD+IFR-AK-CAZ-SC 6011.71 75.39 0.95 3533.87 3424.87 1042.66 3518.07 5946855.39 562339.11 MWD+IFR-AK-CAZ-SC 6106.21 77.01 355.82 3556.43 3447.43 1134.36 3515.47 5946947.06 562335.80 MWD+IFR-AK-CAZ-SC 6199.94 81.12 356.20 3574.21 3465.21 1226.14 3509.07 5947038.78 562328.68 MWD+IFR-AK-CAZ-SC 6296.29 79.71 354.23 3590.25 3481.25 1320.81 3501.15 5947133.37 562320.02 MWD+IFR-AK-CAZ-SC 6390.76 77.22 353.37 3609.14 3500.14 1412.82 3491.16 5947225.30 562309.31 MWD+IFR-AK-CAZ-SC 6485.62 77.17 350.57 3630.17 3521.17 1504.41 3478.24 5947316.77 562295.68 MWD+IFR-AK-CAZ-SC 6582.32 75.23 350.18 3653.23 3544.23 1596.99 3462.54 5947409.22 562279.26 MWD+IFR-AK-CAZ-SC 6677.73 77.93 349.85 3675.37 3566.37 1688.38 3446.45 5947500.47 562262.45 MWD+IFR-AK-CAZ-SC 6740.64 79.05 349.68 3687.93 3578.93 1749.04 3435.49 5947561.04 562251.03 MWD+IFR-AK-CAZ-SC 6774.90 79.13 349.38 3694.41 3585.41 1782,12 3429,38 5947594,07 562244,65 MWD+IFR-AK-CAZ-SC 6820.64 79.62 349.05 3702.84 3593.84 1826.28 3420.97 5947638.16 562235.90 MWD+IFR-AK-CAZ-SC 6869.70 79.71 348.67 3711.65 3602.65 1873.64 3411.64 5947685.43 562226.20 MWD+IFR-AK-CAZ-SC 6920.08 78.89 348.80 3721.00 3612.00 1922.19 3401.97 5947733.90 562216.16 MWD+IFR-AK-CAZ-SC 6963.44 79.06 348.21 3729.29 3620.29 1963.89 3393.49 5947775.54 562207.35 MWD+IFR-AK-CAZ-SC 7011.09 79.51 348.78 3738.15 3629.15 2009.77 3384.15 5947821.34 562197.66 MWD+IFR-AK-CAZ-SC 7059.70 80.03 349.22 3746.78 3637.78 2056.73 3375.03 5947868.22 562188.16 MWD+IFR-AK-CAZ-SC 7105.01 79.52 350.15 3754.83 3645.83 2100.60 3367.04 5947912.02 562179.84 MWD+IFR-AK-CAZ-SC 7152.78 79.58 349.75 3763.49 3654.49 21486 358 3 .84 5947958.20 562171.28 MWD IFR-AK-CAZ-SC 6 7201.56 80.00 350.40 3772.14 3663.14 2194.14 3350.57 5948005.42 562162.63 MWD+IFR-AK-CAZ-SC 7247.80 80.34 349.79 3780.03 3671.03 2239.03 3342.73 5948050.24 562154.45 MWD+IFR-AK-CAZ-SC 7343.46 82.25 349.16 3794.51 3685.51 2331.99 3325.46 5948143.05 562136.45 MWD+IFR-AK-CAZ-SC 7364.59 83.90 349.62 3797.06 3688.06 2352.60 3321.60 5948163.64 562132.43 MWD+IFR-AK-CAZ-SC 7438.37 85.10 348.79 3804.13 3695.13 2424.74 3307.84 5948235.66 562118.11 MWD+IFR-AK-CAZ-SC 7457.95 85.54 348.80 3805.73 3696.73 2443.89 3304.05 5948254.77 562114.17 MWD+IFR-AK-CAZ-SC 7518.39 85.68 349.15 3810.35 3701.35 2503.04 3292.53 5948313.82 562102.19 MWD+IFR-AK-CAZ-SC 7550.16 85.61 351.21 3812.77 3703.77 2534.25 3287.12 5948344.99 562096.54 MWD+IFR-AK-CAZ-SC 7612.44 86.31 351.20 3817.15 3708.15 2595.64 3277.62 5948406.30 562086.56 MWD+IFR-AK-CAZ-SC 7649.57 87.73 354.26 3819.08 3710.08 2632.42 3272.93 5948443.04 562081.58 MWD+IFR-AK-CAZ-SC 7678.59 88.34 353.83 3820.08 3711.08 2661.27 3269.92 5948471.85 562078.35 MWD+IFR-AK-CAZ-SC 7706.17 88.70 353.92 3820.79 3711.79 2688.68 3266.98 5948499.24 562075.19 MWD+IFR-AK-CAZ-SC 7751.45 90.76 355.60 3821.01 3712.01 2733.77 3262.85 5948544.29 562070.71 MWD+IFR-AK-CAZ-SC 7799.38 89.67 354.42 3820.83 3711.83 2781.51 3258.68 5948592.00 562066.17 MWD+IFR-AK-CAZ-SC 7892.95 91.11 353.30 3820.19 3711.19 2874.54 3248.67 5948684.93 562055.43 MWD+IFR-AK-CAZ-SC 7985.44 89.92 352.48 3819.36 3710.36 2966.31 3237.22 5948776.61 562043.27 MWD+IFR-AK-CAZ-SC 8078.81 88.13 352.83 3820.95 3711.95 3058.90 3225.29 5948869.09 562030.62 MWD+IFR-AK-CAZ-SC 8081.00 87.84 353.93 3821.02 3712.02 3061.07 3225.04 5948871.26 562030.35 MWD+IFR-AK-CAZ-SC 8173.08 88.27 350.40 3824.15 3715.15 3152.23 3212.49 5948962.30 562017.09 MWD+IFR-AK-CAZ-SC 8266.42 91.12 350.83 3824.65 3715.65 3244.31 3197.28 5949054.25 562001.16 MWD+IFR-AK-CAZ-SC 8311.52 92.22 351.46 3823.33 3714.33 3288.85 3190.34 5949098.73 561993.87 MWD+IFR-AK-CAZ-SC 8360.15 92.28 352.02 3821.42 3712.42 3336.94 3183.36 5949146.76 561986.51 MWD+IFR-AK-CAZ-SC 8452.71 91.53 352.19 3818.35 3709.35 3428.57 3170.65 5949238.28 561973.09 MWD+IFR-AK-CAZ-SC 8545.65 89.98 353.01 3817.12 3708.12 3520.72 3158.68 5949330.33 561960.41 MWD+IFR-AK-CAZ-SC 8640.45 90.24 353.36 3816.94 3707.94 3614.85 3147.43 5949424.36 561948.42 MWD+IFR-AK-CAZ-SC Halliburton Company Survey Report Company: ConocoPhillips Alaskalne. Date: 12/43/2006 Time: 13:24 21 Page. 4 Field Kuparuk River unit Co-ordinate(NE) Reference. Well:'"IJ 1IS True North: Site Kuparuk 1.1 Pad Vertical,(TVD) Reference- U-115P133 109:0 Well: U-115 Section (VS) Reference--' Well (0.00N,O:OOEI O;OGAzi) � Wellpath 1J-115PB3 Survey Calculation Method: � I inimum Curvature Db: Oracle Survey MD Incl Azim TVD Sys TVD N/S E/W MapN MapE Torn ft deg deg ft ft 4 ft ft it - 8733.19 89.74 352.33 3816.96 3707.96 3706.87 3135.88 5949516.28 561936.15 MWD+IFR-AK-CAZ-SC 8826.57 89.68 352.64 3817.43 3708.43 3799.44 3123.67 5949608.75 561923.22 MWD+IFR-AK-CAZ-SC 8885.00 89.72 351.85 3817.73 3708.73 3857.34 3115.78 5949666.57 561914.88 MWD+IFR-AK-CAZ-SC I 8916.66 88.43 351.67 3818.25 3709.25 3888.67 3111.25 5949697.86 561910.10 MWD+IFR-AK-CAZ-SC 9012.13 88.14 352.01 3821.10 3712.10 3983.13 3097.70 5949792.20 561895.82 MWD+IFR-AK-CAZ-SC 9106.47 87.96 354.85 3824.31 3715.31 4076.78 3086.91 5949885.76 561884.30 MWD+IFR-AK-CAZ-SC 9199.69 87.89 355.45 3827.69 3718.69 4169.61 3079.04 5949978.52 561875.70 MWD+IFR-AK-CAZ-SC 9292.84 91.12 0.80 3828.49 3719.49 4262.66 3075.99 5950071.53 561871.93 MWD+IFR-AK-CAZ-SC 9387.60 91.42 1.42 3826.39 3717.39 4357.38 3077.83 5950166.25 561873.03 MWD+iFR-AK-CAZ-SC 9480.89 90.42 1.61 3824.90 3715.90 4450.62 3080.29 5950259.50 561874.76 MWD+IFR-AK-CAZ-SC 9573.70 89.37 0.61 3825.07 3716.07 4543.41 3082.09 5950352.30 561875.84 MWD+IFR-AK-CAZ-SC 9666.19 90.18 356.82 3825.43 3716.43 4635.86 3080.02 5950444.72 561873.04 MWD+IFR-AK-CAZ-SC 9711.54 90.12 355.63 3825.31 3716.31 4681.11 3077.03 5950489.94 561869.70 MWD+IFR-AK-CAZ-SC 9760.00 89.31 353.81 3825.55 3716.55 4729.36 3072.57 5950538.15 561864.87 MWD+IFR-AK-CAZ-SC 9853.60 89.44 353.30 3826.57 3717.57 4822.37 3062.07 5950631.06 561853.64 MWD+IFR-AK-CAZ-SC 9946.91 88.19 355.70 3828.50 3719.50 4915.22 3053.13 5950723.83 561843.97 MWD+IFR-AK-CAZ-SC 10040.51 88.26 358.47 3831.40 3722.40 5008.64 3048.37 5950817.20 561838.48 MWD+IFR-AK-CAZ-SC 10134.01 88.45 0.77 3834.09 3725.09 5102.10 3047.75 5950910.64 561837.13 MWD+IFR-AK-CAZ-SC 10228.22 92.30 0.20 3833.47 3724.47 5196.28 3048.55 5951004.82 561837.20 MWD+IFR-AK-CAZ-SC 10320.98 89.86 359.78 3831.72 3722.72 5289.02 3048.53 5951097.54 561836.46 MWD+IFR-AK-CAZ-SC 10415.08 89.81 359.27 3831.99 3722.99 5383.11 3047.75 5951191.62 561834.94 MWD+IFR-AK-CAZ-SC 10508.27 89.19 359.55 3832.81 3723.81 5476.29 3046.79 5951284.78 561833.25 MWD+IFR-AK-CAZ-SC 10601.05 88.94 0.11 3834.32 3725.32 5569.06 3046.52 5951377.54 561832.25 MWD+IFR-AK-CAZ-SC 10694.96 89.38 358.33 3835.70 3726.70 5662.95 3045.24 5951471.40 561830.24 MWD+IFR-AK-CAZ-SC 10787.01 88.82 359.42 3837,14 3728.14 5754.97 3043.43 5951563.40 561827.72 MWD+IFR-AK-CAZ-SC 10879.62 88.63 358.65 3839.20 3730.20 5847.54 3041.87 5951655.94 561825.43 MWD+IFR-AK-CAZ-SC 10973.06 89.01 359.36 3841.13 3732.13 5940.95 3040.25 5951749.33 561823.08 MWD+IFR-AK-CAZ-SC 11067.06 89.94 359.99 3841.99 3732.99 6034.94 3039.72 5951843.30 561821.81 MWD+IFR-AK-CAZ-SC I 11103.04 89.24 359.84 3842.25 3733.25 6070.92 3039.66 5951879.28 561821.48 MWD+IFR-AK-CAZ-SC 11159.29 89.75 1.66 3842.74 3733.74 6127.16 3040.40 5951935.52 561821.78 MWD+IFR-AK-CAZ-SC 11253.06 90.61 2.41 3842.45 3733.45 6220.87 3043.73 5952029.24 561824.37 MWD+IFR-AK-CAZ-SC 11345.50 89.93 1.79 3842.01 3733.01 6313.24 3047.12 5952121.63 561827.04 MWD+IFR-AK-CAZ-SC 11439.00 88.44 2.31 3843.34 3734.34 6406.67 3050.46 5952215.07 561829.65 MWD+IFR-AK-CAZ-SC 11532.84 90.75 2.72 3844.01 3735.01 6500.41 3054.58 5952308.83 561833,04 MWD+IFR-AK-CAZ-SC 11626.47 91.91 2.95 3841.83 3732.83 6593.90 3059.21 5952402.35 561836.94 MWD+IFR-AK-CAZ-SC 11719.30 90.42 2.24 3839.94 3730.94 6686.61 3063.41 5952495.08 561840.41 MWD+IFR-AK-CAZ-SC 11812.13 90.49 0.57 3839.21 3730.21 6779.41 3065.68 5952587.88 561841.96 MWD+IFR-AK-CAZ-SC 11907.00 88.75 0.04 3839.84 3730.84 6874.27 3066.19 5952682.74 561841.73 MWD+IFR-AK-CAZ-SC 11981.36 86.77 359.19 3842.74 3733.74 6948.57 3065.69 5952757.02 561840.65 MWD+IFR-AK-CAZ-SC 12018.00 86.77 359.19 3844.81 3735.81 6985.15 3065.17 5952793.59 561839.85 PROJECTED to TD Halliburton Company Survey Report Company: ConowPhillips Alaska Inc.. Date: 12/1912006 ' � Time f3:37:02 Page: � I � Field: Kuparuk River Unit Co-ordinate(NE) Reference lftieil: 1J':115, True North '- Site: Kuparuk 1J Pad Vertical (TVD) Reference: 1J415PB4: 109.0 Neil: 1 J-115 Section (VS) !References Well (0.✓ 0N,0.00E 0.00Azt) Wellpath: 1J-115P64 Survey Calculation Methods Minimum Curvature Db:, Oracle Field: Kuparuk River Unit - North Slope Alaska United States Map System:US State Plane Coordinate System 1927 Map Zone: Alaska, Zone 4 Geo Datum: NAD27 (Clarke 1866) Coordinate System: Well Centre Sys Datum: Mean Sea Level Geomagnetic Model: bggm2006 Well: 1 J-115 Slot Name: Well Position: +N/-S-134.58 ft Northing: 5945785.38 ft Latitude: 70 15 44.934 N +E/-W 38.63 ft Easting : 558829.63 it Longitude: 149 31 27.882 W Position Uncertainty: 0.00 ft Wellpath: 1J-115PB4 Drilled From: 1J-115PB3 500292332073 Tie -on Depth: 11626.47 ft Current Datum: 1 J-115PB4: Height 109.00 ft Above System Datum: Mean Sea Level Magnetic Data: 9/25/2006 Declination: 23.78 deg Field Strength: 57610 nT Mag Dip Angle: 80.80 deg Vertical Section: Depth From (TVD) +N/-S +E/-W Direction it it ft deg 28.00 0.00 0.00 0.00 Survey Program for Definitive Wellpath Date: 12/19/2006 Validated: No Version: 1 Actual From To Survey Toolcode Tool Name it ft 50.00 1016.00 1J-115PB1 gyro (50.00-1016.00) CB -GYRO -SS Camera based gyro single shot 1147.04 7985.44 1 J-115PB1 (1147.04-8360.39) (3 MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 8081.00 8826.57 1J-1151362 (8081.00-9155.93) (4 MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 8885.00 11626.47 1J-11513133 (8885.00-11981.36) ( MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 11690.00 12791.74 1J-115PB4 (11690.00-12791.74) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC Survey MD Ioci Azim TVD Sys TVD N/S E/W MapN - - MapE Tool it deg deg It ft it it it it 28.00 0.00 0.00 28.00 -81.00 0.00 0.00 5945785.38 558829.63 TIE LINE 50.00 0.20 101.96 50.00 -59.00 -0.01 0.04 5945785.37 558829.67 CB -GYRO -SS 100.00 0.19 134.36 100.00 9.00 0.08 0.18 5945785.30 558829.81 CB -GYRO -SS 172.00 0.07 306.93 172.00 63.00 -0.14 0.23 5945785.24 558829.86 CB -GYRO -SS 260.00 0.07 81.28 260.00 151.00 -0.10 0.24 5945785.28 558829.87 CB -GYRO -SS 356.00 0.12 272.58 356.00 247.00 -0.09 0.20 5945785.29 558829.83 CB -GYRO -SS 447.00 1.38 98.80 446.99 337.99 -0.25 1.19 5945785.14 558830.82 CB -GYRO -SS 540.00 3.65 90.60 539.90 430.90 -0.45 5.26 5945784.97 558834.89 CB -GYRO -SS 632.00 6.87 83.95 631.50 522.50 0.10 13.66 5945785.58 558843.28 CB -GYRO -SS 734.00 12.14 85.32 732.06 623.06 1.62 30.43 5945787.23 558860.04 CB -GYRO -SS 828.00 14.65 87.39 823.50 714.50 2.96 52.15 5945788.75 558881.76 CB -GYRO -SS 923.00 16.60 93.22 914.99 805.99 2.75 77.71 5945788.74 558907.31 CB -GYRO -SS 1016.00 19.62 96.55 1003.37 894.37 0.22 106.49 5945786.43 558936.11 CB -GYRO -SS 1147.04 19.73 100.48 1126.77 1017.77 -6.31 150.10 5945780.24 558979.76 MWD+IFR-AK-CAZ-SC 1239.14 20.76 99.26 1213.18 1104.18 -11.77 181.50 5945775.03 559011.20 MWD+IFR-AK-CAZ-SC 1336.46 25.69 100.98 1302.58 1193.58 -18.56 219.25 5945768.53 559049.00 MWD+IFR-AK-CAZ-SC 1430.30 32.19 97.67 1384.67 1275.67 -25.78 264.04 5945761.66 559093.84 MWD+IFR-AK-CAZ-SC 1527.05 34.57 97.87 1465.45 1356.45 -32.98 316.78 5945754.88 559146.63 MWD+IFR-AK-CAZ-SC 1623.88 39.43 96.68 1542.76 1433.76 -40.32 374.57 5945747.99 559204.47 MWD+IFR-AK-CAZ-SC 1717.45 47.02 98.39 1610.90 1501.90 -48.79 438.04 5945740.02 559267.99 MWD+IFR-AK-CAZ-SC 1763.81 49.23 98.35 1641.84 1532.84 -53.81 472.19 5945735.26 559302.18 MWD+IFR-AK-CAZ-SC 1812.39 49.81 98.48 1673.38 1564.38 -59.22 508.74 5945730.14 559338.77 MWD+IFR-AK-CAZ-SC 1859.85 51.05 98.27 1703.61 1594.61 -64.55 544.94 5945725.10 559375.00 MWD+IFR-AK-CAZ-SC 1909.19 52.88 97.27 1734.01 1625.01 -69.80 583.44 5945720.15 559413.54 MWD+IFR-AK-CAZ-SC 1956.90 56.75 96.14 1761.50 1652.50 -74.34 622.16 5945715.91 559452.29 MWD+IFR-AK-CAZ-SC 2004.98 60.06 94.39 1786.68 1677.68 -78.09 662.93 5945712.48 559493.09 MWD+IFR-AK-CAZ-SC Halliburton Company Survey Report Company: ConocoPhillips Alaska Inc. Date: 12/19/2006 « Time 13:37:02 Page: 2 field: Kuparuk River Unit Co-ordinate(NE) Reference: Well:1 J-115, True, North ' Site: Kuparuk 1.1 Pad Vertical (TVU)Reference: 1J-115P64: 109.0 Well. 1J-115 Section{VSylieferenc . � WWH;(O.00N,O.00EO. WAZI) WeIlpathf 1J-115P64 Survey Calculation Method: itAxllmum Curvature Db: Oracle Survey MD Incl Azim TYD Sys TVD N/S E/W MapN MapE Tool. ft Qeg, deg ft It ft ft ft ft 2052.33 61.37 94.72 1809.84 1700.84 -81.37 704.10 5945709.52 559534.28 MWD+IFR-AK-CAZ-SC 2099.08 65.15 94.08 1830.88 1721.88 -84.57 745.72 5945706.65 559575.91 MWD+IFR-AK-CAZ-SC 2146.11 66.24 94.32 1850.23 1741.23 -87.70 788.46 5945703.85 559618.68 MWD+IFR-AK-CAZ-SC 2195.14 65.38 94.46 1870.32 1761.32 -91.13 833.06 5945700.77 559663.29 MWD+IFR-AK-CAZ-SC 2243.32 65.22 94.86 1890.46 1781.46 -94.68 876.68 5945697.56 559706.94 MWD+IFR-AK-CAZ-SC 2290.05 65.23 95.29 1910.04 1801.04 -98.44 918.95 5945694.13 559749.23 MWD+IFR-AK-CAZ-SC 2384.30 66.21 92.85 1948.80 1839.80 -104.53 1004.63 5945688.71 559834.95 MWD+IFR-AK-CAZ-SC 2431.35 66.51 91.83 1967.67 1858.67 -106.29 1047.70 5945687.29 559878.03 MWD+IFR-AK-CAZ-SC 2479.29 65.14 92.38 1987.30 1878.30 -107.89 1091.40 5945686.03 559921.74 MWD+IFR-AK-CAZ-SC 2525.10 64.21 92.41 2006.89 1897.89 -109.62 1132.78 5945684.62 559963.12 MWD+IFR-AK-CAZ-SC 2574.27 64.84 92.04 2028.04 1919.04 -111.35 1177.13 5945683.24 560007.48 MWD+IFR-AK-CAZ-SC 2621.23 65.32 92.80 2047.83 1938.83 -113.14 1219.68 5945681.78 560050.04 MWD+IFR-AK-CAZ-SC 2668.37 64.85 93.77 2067.69 1958.69 -115.59 1262.36 5945679.66 560092.74 MWD+IFR-AK-CAZ-SC 2716.31 63.56 93.99 2088.55 1979.55 -118.51 1305.43 5945677.08 560135.82 MWD+IFR-AK-CAZ-SC 2764.95 62.48 93.85 2110.61 2001.61 -121.48 1348.67 5945674.45 560179.08 MWD+IFR-AK-CAZ-SC 2792.69 63.61 94.72 2123.19 2014.19 -123.33 1373.33 5945672.80 560203.75 MWD+IFR-AK-CAZ-SC 2858.21 64.46 95.53 2151.88 2042.88 -128.59 1432.00 5945667.99 560262.45 MWD+IFR-AK-CAZ-SC 2923.29 65.79 94.45 2179.25 2070.25 -133.72 1490.81 5945663.32 560321.30 MWD+IFR-AK-CAZ-SC 2953.10 65.83 94.21 2191.47 2082.47 -135.77 1517.93 5945661.48 560348.43 MWD+IFR-AK-CAZ-SC 3020.46 64.26 94.73 2219.88 2110.88 -140.53 1578.81 5945657.20 560409.34 MWD+IFR-AK-CAZ-SC 3066.57 63.09 96.12 2240.33 2131.33 -144.44 1619.95 5945653.62 560450.50 MWD+IFR-AK-CAZ-SC 3115.25 62.06 96.47 2262.75 2153.75 -149.17 1662.90 5945649.22 560493.48 MWD+IFR-AK-CAZ-SC 3161.89 60.79 95.77 2285.06 2176.06 -153.54 1703.62 5945645.17 560534.24 MWD+IFR-AK-CAZ-SC 3207.64 59.59 95.17 2307.81 2198.81 -157.33 1743.14 5945641.69 560573.78 MWD+IFR-AK-CAZ-SC 3257.07 59.30 95.67 2332.93 2223.93 -161.35 1785.51 5945638.00 560616.18 MWD+IFR-AK-CAZ-SC 3302.16 60.64 95.08 2355.50 2246.50 -165.00 1824.38 5945634.65 560655.07 MWD+IFR-AK-CAZ-SC 3351.77 61.76 94.04 2379.40 2270.40 -168.46 1867.71 5945631.54 560698.42 MWD+IFR-AK-CAZ-SC 3397.36 61.52 94.13 2401.05 2292.05 -171.31 1907.73 5945628.99 560738.46 MWD+IFR-AK-CAZ-SC 3445.60 61.94 94.01 2423.90 2314.90 -174.33 1950.11 5945626.31 560780.85 MWD+IFR-AK-CAZ-SC 3541.93 64.26 92.53 2467.48 2358.48 -179.22 2035.87 5945622.09 560866.64 MWD+IFR-AK-CAZ-SC 3587.60 63.76 92.85 2487.50 2378.50 -181.14 2076.87 5945620.48 560907.65 MWD+IFR-AK-CAZ-SC 3637.30 63.20 92.99 2509.69 2400.69 -183.41 2121.28 5945618.57 560952.08 MWD+IFR-AK-CAZ-SC 3683.58 62.11 93.43 2530.95 2421.95 -185.71 2162.33 5945616.59 560993.14 MWD+IFR-AK-CAZ-SC 3730.50 61.48 93.54 2553.12 2444.12 -188.22 2203.60 5945614.39 561034.42 MWD+IFR-AK-CAZ-SC 3783.12 62.18 92.50 2577.96 2468.96 -190.67 2249.92 5945612.31 561080.76 MWD+IFR-AK-CAZ-SC 3826.51 61.89 92.49 2598.31 2489.31 -192.33 2288.21 5945610.95 561119.05 MWD+IFR-AK-CAZ-SC 3873.70 62.90 92.02 2620.18 2511.18 -193.98 2329.99 5945609.63 561160.84 MWD+IFR-AK-CAZ-SC 3921.50 64.20 91.19 2641.47 2532.47 -195.18 2372.77 5945608.77 561203.63 MWD+IFR-AK-CAZ-SC 3975.48 62.84 89.69 2665.54 2556.54 -195.55 2421.08 5945608.77 561251.94 MWD+IFR-AK-CAZ-SC 4011.14 63.44 87.24 2681.65 2572.65 -194.70 2452.88 5945609.87 561283.72 MWD+IFR-AK-CAZ-SC 4065.80 63.59 84.65 2706.03 2597.03 -191.24 2501.68 5945613.71 561332.49 MWD+IFR-AK-CAZ-SC 4111.07 63.08 82.85 2726.35 2617.35 -186.83 2541.89 5945618.43 561372.66 MWD+IFR-AK-CAZ-SC 4161.60 62.71 82.07 2749.37 2640.37 -180.93 2586.48 5945624.68 561417.20 MWD+IFR-AK-CAZ-SC 4207.41 62.05 81.09 2770.61 2661.61 -174.99 2626.63 5945630.93 561457.30 MWD+IFR-AK-CAZ-SC 4302.87 60.78 75.96 2816.31 2707.31 -158.35 2708.74 5945648.22 561539.27 MWD+IFR-AK-CAZ-SC 4397.88 61.00 71.95 2862.54 2753.54 -135.41 2788.49 5945671.78 561618.83 MWD+IFR-AK-CAZ-SC 4444.65 61.15 70.43 2885.16 2776.16 -122.21 2827.24 5945685.28 561657.47 MWD+IFR-AK-CAZ-SC 4493.15 62.09 66.97 2908.22 2799.22 -106.71 2866.99 5945701.09 561697.09 MWD+IFR-AK-CAZ-SC 4587.16 63.03 60.70 2951.58 2842.58 -69.92 2941.81 5945738.45 561771.61 MWD+IFR-AK-CAZ-SC 4681.64 63.67 55.12 2993.98 2884.98 -25.08 3013.30 5945783.84 561842.75 MWD+IFR-AK-CAZ-SC 4776.45 63.61 48.37 3036.12 2927.12 27.48 3079.96 5945836.91 561908.99 MWD+IFR-AK-CAZ-SC 4872.66 62.93 42.02 3079.43 2970.43 87.98 3140.89 5945897.88 561969.44 MWD+IFR-AK-CAZ-SC 4966.48 62.78 36.83 3122.25 3013.25 152.43 3193.89 5945962.74 562021.92 MWD+IFR-AK-CAZ-SC Halliburton Company Survey Report Company. ConocoPhillips Alaska Inc. irate: 12/1912006 � Time: 13:37 02 � Page:. m„, 3 Meld: Kupanik River Unit Co-ordinate(NE) Reference: Well: 1J-115, True North, Site: Kuparuk 1J PadVertical (TVD) Reference: 1J-1I6PB4. IWO Well: 1J-115 Section (VS) Reference: Well (0.00N,4.00E,0b0AZI) Weilpath:: 1J-115PB4 Survey Calculation Method: Minimum Curvature Db: Oracle" Survey MD lncl Azim TVl) Sys Ti'I) N1S E1W MapN MapE Tool ft deg deg R ft" ft ft ft It' 5061.23 63.60 30.93 3165.02 3056.02 222.60 3240.99 5946033.27 562068.47 MWD+IFR-AK-CAZ-SC 5154.55 63.67 26.34 3206.48 3097.48 295.96 3281.04 5946106.94 562107.94 MWD+IFR-AK-CAZ-SC 5249.86 64.52 23.85 3248.12 3139.12 373.60 3317.39 5946184.85 562143.68 MWD+IFR-AK-CAZ-SC 5344.89 64.58 23.84 3288.96 3179.96 452.08 3352.08 5946263.59 562177.75 MWD+IFR-AK-CAZ-SC 5440.16 64.61 24.40 3329.83 3220.83 530.62 3387.25 5946342.40 562212.30 MWD+IFR-AK-CAZ-SC 5537.28 64.76 24.25 3371.36 3262.36 610.62 3423.41 5946422.67 562247.84 MWD+IFR-AK-CAZ-SC 5630.91 66.63 19.01 3409.92 3300.92 689.92 3454.82 5946502.20 562278.63 MWD+IFR-AK-CAZ-SC 5724.54 69.47 14.47 3444.93 3335.93 773.05 3479.79 5946585.52 562302.94 MWD+IFR-AK-CAZ-SC 5818.75 70.89 10.45 3476.88 3367.88 859.57 3498.90 5946672.18 562321.37 MWD+IFR-AK-CAZ-SC 5915.97 72.53 6.28 3507.41 3398.41 950.88 3512.30 5946763.57 562334.06 MWD+IFR-AK-CAZ-SC i 6011.71 75.39 0.95 3533.87 3424.87 1042.66 3518.07 5946855.39 562339.11 MWD+IFR-AK-CAZ-SC 6106.21 77.01 355.82 3556.43 3447.43 1134.36 3515.47 5946947.06 562335.80 MWD+IFR-AK-CAZ-SC 6199.94 81.12 356.20 3574.21 3465.21 1226.14 3509.07 5947038.78 562328.68 MWD+IFR-AK-CAZ-SC 6296.29 79.71 354.23 3590.25 3481.25 1320.81 3501.15 5947133.37 562320.02 MWD+IFR-AK-CAZ-SC 6390.76 77.22 353.37 3609.14 3500.14 1412.82 3491.16 5947225.30 562309.31 MWD+IFR-AK-CAZ-SC 6485.62 77.17 350.57 3630.17 3521.17 1504.41 3478.24 5947316.77 562295.68 MWD+IFR-AK-CAZ-SC 6582.32 75.23 350.18 3653.23 3544.23 1596.99 3462.54 5947409.22 562279.26 MWD+IFR-AK-CAZ-SC 6677.73 77.93 349.85 3675.37 3566.37 1688.38 3446.45 5947500.47 562262.45 MWD+IFR-AK-CAZ-SC 6740.64 79.05 349.68 3687.93 3578.93 1749.04 3435.49 5947561.04 562251.03 MWD+IFR-AK-CAZ-SC 6774.90 79.13 349.38 3694.41 3585.41 1782.12 3429.38 5947594.07 562244.65 MWD+IFR-AK-CAZ-SC 6820.64 79.62 349.05 3702.84 3593.84 1826.28 3420.97 5947638.16 562235.90 MWD+IFR-AK-CAZ-SC 6869.70 79.71 348.67 3711.65 3602.65 1873.64 3411.64 5947685.43 562226.20 MWD+IFR-AK-CAZ-SC 6920.08 78.89 348.80 3721.00 3612.00 1922.19 3401.97 5947733.90 562216.16 MWD+IFR-AK-CAZ-SC 6963.44 79.06 348.21 3729.29 3620.29 1963.89 3393.49 5947775.54 562207.35 MWD+IFR-AK-CAZ-SC 7011.09 79.51 348.78 3738.15 3629.15 2009.77 3384.15 5947821.34 562197.66 MWD+IFR-AK-CAZ-SC 7059.70 80.03 349.22 3746.78 3637.78 2056.73 3375.03 5947868.22 562188.16 MWD+IFR-AK-CAZ-SC j 7105.01 79.52 350.15 3754.83 3645.83 2100.60 3367.04 5947912.02 562179.84 MWD+IFR-AK-CAZ-SC 7152.78 79.58 349.75 3763.49 3654.49 2146.86 3358.84 5947958.20 562171.28 MWD+IFR-AK-CAZ-SC 7201.56 80.00 350.40 3772.14 3663.14 2194.14 3350.57 5948005.42 562162.63 MWD+IFR-AK-CAZ-SC 7247.80 80.34 349.79 3780.03 3671.03 2239.03 3342.73 5948050.24 562154.45 MWD+IFR-AK-CAZ-SC 7343.46 82.25 349.16 3794.51 3685.51 2331.99 3325.46 5948143.05 562136.45 MWD+IFR-AK-CAZ-SC 7364.59 83.90 349.62 3797.06 3688.06 2352.60 3321.60 5948163.64 562132.43 MWD+IFR-AK-CAZ-SC I 7438.37 85.10 348.79 3804.13 3695.13 2424.74 3307.84 5948235.66 562118.11 MWD+IFR-AK-CAZ-SC 7457.95 85.54 348.80 3805.73 3696.73 2443.89 3304.05 5948254.77 562114.17 MWD+IFR-AK-CAZ-SC 7518.39 85.68 349.15 3810.35 3701.35 2503.04 3292.53 5948313.82 562102.19 MWD+IFR-AK-CAZ-SC 7550.16 85.61 351.21 3812.77 3703.77 2534.25 3287.12 5948344.99 562096.54 MWD+IFR-AK-CAZ-SC 7612.44 86.31 351.20 3817.15 3708.15 2595.64 3277.62 5948406.30 562086.56 MWD+IFR-AK-CAZ-SC 7649.57 87.73 354.26 3819.08 3710.08 2632.42 3272.93 5948443.04 562081.58 MWD+IFR-AK-CAZ-SC 7678.59 88.34 353.83 3820.08 3711.08 2661.27 3269.92 5948471.85 562078.35 MWD+IFR-AK-CAZ-SC 7706.17 88.70 353.92 3820.79 3711.79 2688.68 3266.98 5948499.24 562075.19 MWD+IFR-AK-CAZ-SC 7751.45 90.76 355.60 3821.01 3712.01 2733.77 3262.85 5948544.29 562070.71 MWD+IFR-AK-CAZ-SC 7799.38 89.67 354.42 3820.83 3711.83 2781.51 3258.68 5948592.00 562066.17 MWD+IFR-AK-CAZ-SC 7892.95 91.11 353.30 3820.19 3711.19 2874.54 3248.67 5948684.93 562055.43 MWD+IFR-AK-CAZ-SC 7985.44 89.92 352.48 3819.36 3710.36 2966.31 3237.22 5948776.61 562043.27 MWD+IFR-AK-CAZ-SC 8078.81 88.13 352.83 3820.95 3711.95 3058.90 3225.29 5948869.09 562030.62 MWD+IFR-AK-CAZ-SC 8081.00 87.84 353.93 3821.02 3712.02 3061.07 3225.04 5948871.26 562030.35 MWD+IFR-AK-CAZ-SC 8173.08 88.27 350.40 3824.15 3715.15 3152.23 3212.49 5948962.30 562017.09 MWD+IFR-AK-CAZ-SC 8266.42 91.12 350.83 3824.65 3715.65 3244.31 3197.28 5949054.25 562001.16 MWD+IFR-AK-CAZ-SC 8311.52 92.22 351.46 3823.33 3714.33 3288.85 3190.34 5949098.73 561993.87 MWD+IFR-AK-CAZ-SC 8360.15 92.28 352.02 3821.42 3712.42 3336.94 3183.36 5949146.76 561986.51 MWD+IFR-AK-CAZ-SC 8452.71 91.53 352.19 3818.35 3709.35 3428.57 3170.65 5949238.28 561973.09 MWD+IFR-AK-CAZ-SC 8545.65 89.98 353.01 3817.12 3708.12 3520.72 3158.68 5949330.33 561960.41 MWD+IFR-AK-CAZ-SC Halliburton Company Survey Report Company: ConocoPhiliips Alaska Inc. Dare: 12/1912006 " Time: "13:3T02 Page. "% 4 field: Kuparuk River Unit Co-ordinate(NE) Reference: well: 1,-115, "True Norio Site: Kullaruk 1 J Pad Vertical (TVD) Reference. 1 J-115PB4: 109 0 " Well: 1J-115 Section (VS) Reference: Well (O 00N,0.00EO.00Azi) Weiipath: 1 J-115PB4 _ Survey Calculation Method- Minimum Curvature Db: Oracle Survey MD ncl Azim TVD_ Sys'I .N/S EJW MapN' MspE Tool ft deg ---eg "=ft ------ - ft ft " - - - - ft it -- - 8640.45 90.24 353.36 3816.94 3707.94 3614.85 3147.43 5949424.36 561948.42 MWD+IFR-AK-CAZ-SC 8733.19 89.74 352.33 3816.96 3707.96 3706.87 3135.88 5949516.28 561936.15 MWD+IFR-AK-CAZ-SC 8826.57 89.68 352.64 3817.43 3708.43 3799.44 3123.67 5949608.75 561923.22 MWD+IFR-AK-CAZ-SC 8885.00 89.72 351.85 3817.73 3708.73 3857.34 3115.78 5949666.57 561914.88 MWD+IFR-AK-CAZ-SC 8916.66 88.43 351.67 3818.25 3709.25 3888.67 3111.25 5949697.86 561910.10 MWD+IFR-AK-CAZ-SC 9012.13 88.14 352.01 3821.10 3712.10 3983.13 3097.70 5949792.20 561895.82 MWD+IFR-AK-CAZ-SC 9106.47 87.96 354.85 3824.31 3715.31 4076.78 3086.91 5949885.76 561884.30 MWD+IFR-AK-CAZ-SC 9199.69 87.89 355.45 3827.69 3718.69 4169.61 3079.04 5949978.52 561875.70 MWD+IFR-AK-CAZ-SC 9292.84 91.12 0.80 3828.49 3719.49 4262.66 3075.99 5950071.53 561871.93 MWD+IFR-AK-CAZ-SC 9387.60 91.42 1.42 3826.39 3717.39 4357.38 3077.83 5950166.25 561873.03 MWD+IFR-AK-CAZ-SC 9480.89 90.42 1.61 3824.90 3715.90 4450.62 3080.29 5950259.50 561874.76 MWD+IFR-AK-CAZ-SC 9573.70 89.37 0.61 3825.07 3716.07 4543.41 3082.09 5950352.30 561875.84 MWD+IFR-AK-CAZ-SC 9666.19 90.18 356.82 3825.43 3716.43 4635.86 3080.02 5950444.72 561873.04 MWD+IFR-AK-CAZ-SC 9711.54 90.12 355.63 3825.31 3716.31 4681.11 3077.03 5950489.94 561869.70 MWD+IFR-AK-CAZ-SC 9760.00 89.31 353.81 3825.55 3716.55 4729.36 3072.57 5950538.15 561864.87 MWD+IFR-AK-CAZ-SC 9853.60 89.44 353.30 3826.57 3717.57 4822.37 3062.07 5950631.06 561853.64 MWD+IFR-AK-CAZ-SC 9946.91 88.19 355.70 3828.50 3719.50 4915.22 3053.13 5950723.83 561843.97 MWD+IFR-AK-CAZ-SC 10040.51 88.26 358.47 3831.40 3722.40 5008.64 3048.37 5950817.20 561838.48 MWD+IFR-AK-CAZ-SC 10134.01 88.45 0.77 3834.09 3725.09 5102.10 3047.75 5950910.64 561837.13 MWD+IFR-AK-CAZ-SC 10228.22 92.30 0.20 3833.47 3724.47 5196.28 3048.55 5951004.82 561837.20 MWD+IFR-AK-CAZ-SC 10320.98 89.86 359.78 3831.72 3722.72 5289.02 3048.53 5951097.54 561836.46 MWD+IFR-AK-CAZ-SC 10415.08 89.81 359.27 3831.99 3722.99 5383.11 3047.75 5951191.62 561834.94 MWD+IFR-AK-CAZ-SC 10508.27 89.19 359.55 3832.81 3723.81 5476.29 3046.79 5951284.78 561833.25 MWD+IFR-AK-CAZ-SC 10601.05 88.94 0.11 3834.32 3725.32 5569.06 3046.52 5951377.54 561832.25 MWD+IFR-AK-CAZ-SC i 10694.96 89.38 358.33 3835.70 3726.70 5662.95 3045.24 595 1471.40 561830.24 MWD+IFR-AK-CAZ-SC 10787.01 88.82 359.42 3837.14 3728.14 5754.97 3043.43 5951563.40 561827.72 MWD+IFR-AK-CAZ-SC 10879.62 88.63 358.65 3839.20 3730.20 5847.54 3041.87 5951655.94 561825.43 MWD+IFR-AK-CAZ-SC 10973.06 89.01 359.36 3841.13 3732.13 5940.95 3040.25 5951749.33 561823.08 MWD+IFR-AK-CAZ-SC 11067.06 89.94 359.99 3841.99 3732.99 6034.94 3039.72 5951843.30 561821.81 MWD+IFR-AK-CAZ-SC 11103.04 89.24 359.84 3842.25 3733.25 6070.92 3039.66 5951879.28 561821.48 MWD+IFR-AK-CAZ-SC 11159.29 89.75 1.66 3842.74 3733.74 6127.16 3040.40 5951935.52 561821.78 MWD+IFR-AK-CAZ-SC 11253.06 90.61 2.41 3842.45 3733.45 6220.87 3043.73 5952029.24 561824.37 MWD+IFR-AK-CAZ-SC 11345.50 89.93 1.79 3842.01 3733.01 6313.24 3047.12 5952121.63 561827.04 MWD+IFR-AK-CAZ-SC 11439.00 88.44 2.31 3843.34 3734.34 6406.67 3050.46 5952215.07 561829.65 MWD+IFR-AK-CAZ-SC 11532.84 90.75 2.72 3844.01 3735.01 6500.41 3054.58 5952308.83 561833.04 MWD+IFR-AK-CAZ-SC 11626.47 91.91 2.95 3841.83 3732.83 6593.90 3059.21 5952402.35 561836.94 MWD+IFR-AK-CAZ-SC 11690.00 90.89 2.46 3840.28 3731.28 6657.34 3062.20 5952465.80 561839.44 MWD+IFR-AK-CAZ-SC 11718.87 88.58 1.93 3840.41 3731.41 6686.19 3063.31 5952494.65 561840.32 MWD+IFR-AK-CAZ-SC 11762.26 88.01 0.90 3841.70 3732.70 6729.54 3064.38 5952538.01 561841.05 MWD+IFR-AK-CAZ-SC 11813.06 88.52 1.20 3843.24 3734.24 6780.31 3065.31 5952588.78 561841.58 MWD+IFR-AK-CAZ-SC 11906.87 87.08 358.79 3846.84 3737.84 6874.04 3065.30 5952682.50 561840.84 MWD+IFR-AK-CAZ-SC 11999.81 85.79 359.51 3852.62 3743.62 6966.79 3063.93 5952775.22 561838.74 MWD+IFR-AK-CAZ-SC 12044.14 85.48 358.47 3856.00 3747.00 7010.98 3063.15 5952819.41 561837.62 MWD+IFR-AK-CAZ-SC 12092.99 86.36 358.72 3859.47 3750.47 7059.69 3061.95 5952868.10 561836.04 MWD+IFR-AK-CAZ-SC 12144.54 85.10 358.33 3863.31 3754.31 7111.08 3060.63 5952919.47 561834.32 MWD+IFR-AK-CAZ-SC 12186.34 86.11 359.26 3866.51 3757.51 7152.75 3059.75 5952961.13 561833.12 MWD+IFR-AK-CAZ-SC 12280.15 86.41 0.41 3872.63 3763.63 7246.36 3059.48 5953054.72 561832.12 MWD+IFR-AK-CAZ-SC 12373.37 86.16 0.17 3878.67 3769.67 7339.38 3059.96 5953147.74 561831.86 MWD+IFR-AK-CAZ-SC 12466.24 86.54 359.92 3884.59 3775.59 7432.06 3060.03 5953240.41 561831.21 MWD+IFR-AK-CAZ-SC 12560.50 88.40 1.63 3888.75 3779.75 7526.21 3061.30 5953334.56 561831.75 MWD+IFR-AK-CAZ-SC 12653.35 87.83 0.42 3891.80 3782.80 7619.00 3062.96 5953427.34 561832.68 MWD+IFR-AK-CAZ-SC 12746.95 89.32 0.17 3894.13 3785.13 7712.56 3063.44 5953520.90 561832.43 MWD+IFR-AK-CAZ-SC 12791.74 88.13 359.42 3895.13 3786.13 7757.34 3063.28 5953 565.67 561831.92 MWD+IFR-AK-CAZ-SC Halliburton Company Survey Report Survey MD IgcI it de Ali teg ; TVD Sys T"UA N/S E/W- MapN ft ft : ft fi tt MapE Tool ft 12829.00 88.13 359.42 3896.34 3787.34 7794.58 3062.91 5953602.90 -- -J 561831.26 PROJECTED to TO • • AOGCC Librarian 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 Re: Distribution of Survey Data for Well 1 J-115 Dear Dear Sir/Madam: Enclosed is one disk with the *.PTT and *.PDF files. Tie -on Survey: 12,466.24' MD Window / Kickoff Survey 12,523.00' MD (if applicable) Projected Survey: 13,720.00' MD PLEASE ACKNOWLEDGE RECEIPT BY SENDING AN EMAIL TO Timothy.Allen@HALLIBURTON.COM OR SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry -Sun Drilling Services Attn: Timothy Allen 6900 Arctic Blvd. Anchorage, AK 99518 Date21 Signed Please call me at 273-3534 if you have any questions or concerns. Regards, Timothy Allen Survey Manager Attachment(s) 28-Dec-06 0;�06-I xJL 28-Dec-06 AOGCC Librarian 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 Re: Distribution of Survey Data for Well 1J-115PB1 Dear Dear Sir/Madam: Enclosed is one disk with the *.PTT and *.PDF files. Tie -on Survey: 28.00' MD Window / Kickoff Survey ' MD (if applicable) Projected Survey: 8,405.00' MD PLEASE ACKNOWLEDGE RECEIPT BY SENDING AN EMAIL TO Timothy.Allen@HALLIBURTON.COM OR SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry -Sun Drilling Services Attn: Timothy Allen 6900 Arctic Blvd. Anchorage, AK 99518 Date A9 rJen. Ibl-27, Signed — L11 69e�:dl Please call me at 273-3534 if you have any questions or concerns. Regards, Timothy Allen Survey Manager Attachment(s) 0 • AOGCC Librarian 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 Re: Distribution of Survey Data for Well 1 J-115PB2 Dear Dear Sir/Madam: Enclosed is one disk with the *.PTT and *.PDF files. Tie -on Survey: 7,985.44' MD Window / Kickoff Survey 8,050.00' MD (if applicable) Projected Survey: 8,405.00' MD PLEASE ACKNOWLEDGE RECEIPT BY SENDING AN EMAIL TO Timothy.Allen@HALLIBURTON.COM OR SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry -Sun Drilling Services Attn: Timothy Allen 6900 Arctic Blvd. Anchorage, AK 99518 Please call me at 273-3534 if you have any questions or concerns. Regards, Timothy Allen Survey Manager Attachment(s) 28-Dec-06 ;�,6b—►X1.. • • AOGCC Librarian 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 Re: Distribution of Survey Data for Well 1 J-115PB3 Dear Dear Sir/Madam: Enclosed is one disk with the *.PTT and *.PDF files. Tie -on Survey: 8,826.57' MD Window / Kickoff Survey 8,885.00' MD (if applicable) Projected Survey: 12,018.00' MD PLEASE ACKNOWLEDGE RECEIPT BY SENDING AN EMAIL TO Timothy.Allen@HALLIBURTON.COM OR SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry -Sun Drilling Services Attn: Timothy Allen 6900 Arctic Blvd. Anchorage, AK 99518 Date q Ada Signed �Lj Please call me at 273-3534 if you have any questions or concerns. Regards, Timothy Allen Survey Manager Attachment(s) 28-Dec-06 �'0�-(JLz • • AOGCC Librarian 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 Re: Distribution of Survey Data for Well 1J-115PB4 Dear Dear Sir/Madam: Enclosed is one disk with the *.PTT and *.PDF files. Tie -on Survey: 11,626.47' MD Window / Kickoff Survey 11,690.00' MD (if applicable) Projected Survey: 12,829.00' MD PLEASE ACKNOWLEDGE RECEIPT BY SENDING AN EMAIL TO Timothy.Allen@HALLIBURTON.COM OR SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry -Sun Drilling Services Attn: Timothy Allen 6900 Arctic Blvd. Anchorage, AK 99518 Date cl dr, ok$17 Signed Please call me at 273-3534 if you have any questions or concerns. Regards, Timothy Allen Survey Manager Attachment(s) 28-Dec-06 dos-- I a)- RE: [Fwd: 7-5/8" Cement Record— 1J-115] • E I lere is the daily reports. I am still trying to get the cement report in a format to send to you. It will be coming. -----Original Message ----- From: Thomas Maunder [mailto:tom_maunder@admin.state.ak.us] Sent: Wednesday, December 20, 2006 1:24 PM To: Greener, Mike R.; Reilly, Patrick J Cc: Thomas, Randy L Subject: [Fwd: 7-5/8" Cement Record--13-115] All, I am taking the shotgun approach here. I haven't heard back from David so I wanted to make sure someone was checking on this information. Thanks, Tom Maunder, PE AOGCC ------- Original Message-------- Subject:7-5/8" Cement Record--1J-115 Date:Tue, 19 Dec 2006 16:25:04 -0900 From:Thomas Maunder <tom maunder(4:admin. state. ak. us> Organization: State of Alaska To:David Nugent <David.A.Nugent(i conocophillips.com> David, I am reviewing the application for 11-118. Since this is an injector, I need to review the wells within 1/4 mile that penetrate the WS. I have been able to do all wells except 1J-115. I don't believe the 407 has been filed yet, at least it is not in our file. I was wondering if you could send some sort of summary regarding that cement job. Essentially I like to see the last bit of drilling and then the operations up through the next LOT. Thanks in advance. Call or message with any questions. Tom Maunder, PE AOGCC Content -Description: 1J-115 intermediate.pdf 1J-115 intermediate.pdf Content -Type: application/octet-stream Content -Encoding: base64 � 1 of 1 2/22/2007 1:36 PM .. YME Top (ftKB) Bottom (ftKB) !Full Return? ! Cmnt Rtrn (bbl) ITop Plug? Bottom Plug? 0.0 3,009.0 Yes 195.0 Yes i Yes ! Initial Pump Rate (bbl/min) Final Pump Rate (bbl/min) Average Pump Rate (bbl/min) Final Pump Pressure (psi) Plug Bump Pressure (psi) 5 5 5 700.0 900.0 Pipe Reciprocated? Reciprocation Stroke Length (ft) !Reciprocation Rate (spm) Pipe Rotated? _ Pipe RPM (rpm) Yes 20.00 No - --- Depth tagged (ftKB) .� — Tag Method Depth Plug Drilled Out To (ftKB) — Drill Out Diameter (in) --- Drill Out Date L�S�tS.i' }/et1Y8t'4� ,7 � 3•._i�£, ., .r�''. - 2 r �/ .�.v_. '' ....,. ... ::� �y/ -''., _.'�,� Fluid Type J�.°.�"-.:::.u�'3>:s£ I Fluid Description I Amount (sacks) 'Class Volume Pumped (bbl) Lead Cement 534 ! ASL 425.0 Estimated Top (ftKB) Estimated Bottom (ftKB) Percent Excess Pumped (%) !Yield (f 3/sack) rMix H2O Ratio (gal/sack) 0.0 3,009.0 350.0 1 4.45 Thickening Time (hrs) 20.70 1st Compressive Strength (psi) Free Water (%) Density (lb/gal) Plastic Viscosity (cp) 10.70 Fluid Type Fluid Description Amount (sacks) Tail Cement 274 Estimated Top (ftKB) Estimated Bottom (ftKB) Percent Excess Puml 1,980.0 3,009.0 35.0 Free Water (%) Density (Ib/gal) Plastic Viscosity (cp) 12.00 Low Temp Retarder Ititemt�tilate �Gas�it ��°" ,• 1O'� �Sti 17 Ott ..... Cementing Start Date Cementing End Data 10/8/2006 10/9/2006 Evaluation Method TCement Evaluation Results Top (ftKB) 4,000.0 Initial Pump Rate (bbl/t 6 Pipe Reciprocated? Yes !Depth tagged (ftKB) itttttexitate Ct#itten Fluid Type I Intermediate Cement Estimated Top (ftKB) 4,000.0 ,Free Water(%) ICem�r lt Flu' la" i Fluid Loss Control 7,498.0 Final Pump Rate (bbl 3 Reciprocation Stroke 20.00 Tag Method 7,498.0 DeepCrete ick) 2.47 1 Time (hrs) 1 J-115 Yes 0.0 1 Yes Average Pump Rate (bbl/min) !Final Pump Pressure I 6 900.0- — Reciprocation Rate (spm) Pipe Rotated? 1 1 No Depth Plug Drilled Out To (ftKB) Drill Out Diameter (in) Amount (sacks) Class G Percent Excess Pumped (%) Yield (ft°/sack) 25.0 2.24 Plastic Viscosity (cp) Thickening Time (hrs) 3.80 75.0 (gal/ 8.20 Bottom Plug? Yes __—._-_._.--------- Plug Bump Pressure 1,500.0 Pipe RPM (rpm) Drill Out Date Volume Pumped (bbl 78.0 Mix H2O Ratio (gal/si 7.47 8 0:00 4:30 4.50INTRMI DRILL DDRL P 7,102.0 8 4:30 530 1.00INTRMI DRILL CIRC P 7,498.0 8 5:30 I1:00 5.50INTRMI DRILL TRIP P 7,498.0 8 11:00 12:00 1.00INTRMI DRILL CIRC P 3,015.0 8 12:00 12:30 0.50INTRM1 DRILL CIRC P 3,015.0 8 12:30 13:30 1.00INTRMI DRILL TRIP P 3,015.0 8 13:30 14:30 1.00INTRMI DRILL PULD P 449.0 8 14:30 15:15 0.75INTRMI DRILL OTHR P 0.0 8 15:15 16:15 1.00INTRMI DRILL PULD P 0.0 8 16:15 17:00 0.75INTRMI DRILL OTHR P 0,0 8 17:00 18:15 1.25INTRMI CASING RURD P 0.0 8 18:15 1830 0.25INTRMI CASING SFTY P 0.0 8 18:30 21:15 2.75INTRMI CASING RNCS P 0.0 Non -rig 8 21:15 22:30 1.25INTRMI CASING OTHR T "„'',SurfaceEgp 2,132.0 8 22:30 0:00 1.50INTRMI CASING RNCS P 2,132.0 9 0:00 430 4.50INTRMI CASING RNCS P 3,201.0 9 4:30 5:30 1.00INTRMI CASING CIRC P 7,498.0 9 5:30 6:15 0.75INTRMI CASING RURD P 7,498.0 9 6:15 730 1.25INTRMI CEMENT CIRC P 7,498.0 9 7:30 10:00 2.50INTRMI CEMENT DISP P 7,498.0 9 10:00 I1:00 1.00INTRMI CEMENT SFEQ P 7,498.0 9 11:00 12:00 1.00INTRMI CEMENT RURD P 7,498.0 9 12:00 12:30 0.50INTRMI CEMENT OTHR P 7,498.0 9 12:30 14:00 1.50INTRMI CEMENT OTHR P 7,498.0 9 14:00 16:00 2.00INTRMI CEMENT OTHR P 7,498.0 9 16:00 21:30 5.50INTRMI CEMENT PULD P 7,498.0 9 21:30 000 2,50INTRMI CEMENT OTHR P 7,498.0 10 0:00 0:30 0.50INTRMI CASING OTHR P 0.0 10 0:30 2:30 2.00INTRMI WELCTL BOPE P 0.0 10 2:30 3:00 0.50INTRMI CASING OTHR P 0.0 PJSM-Drlg. from 7102' to 7498' NO. TVD 3808'. ART--2.16 AST-1.23 ADT=3.39 his.-P/U-146k S/O-84k-ROT 106k-TQ-on9k off 9-1 1 k ECD- 7,498.0 10.3 Max gas-137 units Jar hrs. 216.6 Survey -rack back I stand DP -pump 30 bbls. weighted hi vis sweep-150 spm-630 gpm-2170 psi-TQ 1 lk=no returns of extra cutting on return of 7,498.0 sweep. Monitor well (Static) BROOH @ 150 spin-630 gpm-2150 psi-40-45 fpm 3,015.0 TQ 9-12k- BROOH to 3015'. Pump 30 bbls. weighted hi vis sweep X 3 bottoms up @ 150 spm 610 3,015.0 gpm-1640 psi P/U 95k S/O 71k. Continue circ. 3 X bottoms up -monitor well -pump 55 bbls. (Steel tube pill) & spot w/ 105 bbls including slug. Blow down top drive & 3,015.0 standpipe. 449.0 POH-lay down ghost reamer-poh to HWDP-monitor well. 0.0 Lay down HWDP-jars & flex collars. 0.0 Down load MWD. 0.0 Lay down MWD-stab-float sub -motor & Bit. 0.0 Pull wear ring -clear & clean floor. 0.0 Rig up to run 7 5/8" 29.7# L80-BTCm csg. 0.0 PJSM-Topic=Running 7 5/8" csg. 2,132.0 Running 7 5/8" csg.-check floats -fill everyjt. run 50 jts. to 2132'. Lay down fill up tool -blow down top drive -change out cup seal on fill up 2,132.0 tool -break circ.-check fill up tool -OK. 3,201.0 Continue running 7 5/8" csg. from 2132' to 3201'. PJSM-Continue running 7 5/8" csg. from 3201' to 7498'. P/U 190k S/O 7,498.0 75k. Circ. & condition mud thru fill up tool @ 7 bpm 800 psi. Reciprocate 7,498.0 pipe 20'. 7,498.0 Lay down till up tool & pick up cement head. 7,498.0 Circ. & condition mud 7 bpm 680 psi 293 gpm P/U 175k S/O 75k. Pump 10 bbl. CW 100-pressure test cement lines to 3500 psi. Pump 65 bbl. CW 100. Drop bottom plug. Pump 78 bbl. mud push @ 11#. 175 bbls. tail cement @ 12.5#. Drop bottom plug Pump 2 bbl. water. Displace w/ rig pump @ 6 bpm w/ Oil base mud. Bump plug on calculated strokes. Cement in place @ 10:00 AM 10-9-06. Bleed off 7,498.0 Floats held. Rig up csg. testing equipment. Test csg. to 3000# 30 mins. Chart same. 7,498.0 OK, 7,498.0 Rig down testing & cementing equipment. 7,498.0 Blow down cement lines & lay down csg. tools. Nipple down BOPE-pull 140k Set slips & slack off-Vaccume out & cut 7,498.0 csg. Install packoff-nipple up bope-test packoff void w/ 3800# (10 min. test) 7,498.0 set mouse hole. 7,498.0 PJSM & lay down 5" drill pipe in mousehole, PJSM= Change out saver sub P/U jaws & stab guide -Prepare to remove 7,498.0 stabbing board. 0.0 Change saver sub and prep to remove stabbing board Hold pre job safety meeting and rig up to test BOPE. Test pipe rams and annular with 4" drill pipe. Test 4" TIW and dart valves to 250/3000 psi. L/D stabbing board. (Chuck Scheve, AOGCC waived witnessing BOPE 0.0 test). 0.0 Set wear bushing. • 10 3:00 7:00 4.00INTRMI DRILL PULD P 0.0 10 7:00 10:30 3.50INTRMI DRILL TRIP P 6,138.0 10 10:30 10:45 0.25INTRMI DRILL OTHR P 0.0 10 10:45 12:00 1.251NTRM1 DRILL PULD P 0.0 10 12:00 13:00 LOOINTRMI DRILL TRIP P 1,271.0 10 13:00 15:30 2.50INTRMI DRILL PULD P 0.0 10 15:30 20:30 5.00INTRMI DRILL TRIP P 365.0 10 20:30 20:45 0.25INTRMI RIGMNT SFTY P 7,365.0 10 20:45 2145 1.00 INTRMI RIGMNT SVRG P 7,3650 10 21:45 2200 0,25INTRMI DRILL CIRC P 7,365.0 10 22:00 23:30 1.50INTRMI CEMENT DRLG P 7,400.0 10 23:30 000 0.50INTRMI DRILL DDRL P 7,498.0 11 0:00 0:30 0.50INTRMI DRILL CIRC P 7,523.0 11 0:30 1:30 1.00INTRMI DRILL LOT P 7,523.0 Pre job safety meeting. Pickup 198joints of 4" XT-39 drill pipe and RIH 6,138.0 to 6,138'. POOH from 6,138' w/ 4" d.p. (installed 36 super -sliders) and rack in 0.0 derrick. (45 stds total with supersliders) 0.0 Clear rig floor 1,271.0 RIH picking up 41 joints of 4" HWDP 0.0 POOH standing back HWDP and picking up jars MU BHA #4 RIH to 365', MU 6 3/4" bit #3 on geopilot rotary steerable with MWD, programmed MWD then RIH with 3-NMFDC's, HWDP and 365.0 jars to 365' RIH with BHA #4 from 365' to 7,3651, PU 201 jts of 4" DP out of pipe 7,365.0 shed RIH to 6,620' then RIH out of derrick to 7,365' 7,365.0 Held PJSM on slip and cutting of drlg line. Slip and cut 66' of drlg line, inspect drawworks brakes and crown-o- 7,365.0 matic Est circ and washed down from 7,365' and tagged cement above fit collar 7,400.0 at 7,400' (FC @ 7,404') Drilled out plugs, flt collar at 7,404', shoe track and fit shoe at 7,493' then cleaned out to btm at 7,498', 24K wob, 50 rpm's, 75 spin, 267 gpm at 7,498.0 1,600 psi Drilled 25' of new hole from 7,498' to 7,523' MD/3,81 F TVD, ADT .22 hrs, 24K wob, 50 rpm's, 75 spm, 267 gpm at 1,600 psi, rot wt 85K, up wt 105K, do wt 70K, torque off btm 2K ft-Ibs, on btm 3K ft-Ibs, jar hrs 7,523.0 135.86, 8.65 MOBM, ave ECD 9.68 ppg Circ btms up at 7,523' for LOT, evened MW in and out at 8.6 ppg, 85 spin, 300 gpm at 2,400 psi, 100 rpm's and 4K ft-Ibs torque, est PWD 7,523.0 base line with a clean hole ECD of 9.6 ppg RU and performed LOT to 11.6 ppg EMW, 590 psi, 3,808' TVD with 8.6 7,523.0 ppg MOBM 0 0 SeaNeeberger Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Well Job # RIECHVEO cz(2� - 1 0a Log Description I1"[•ZII31tc Company: Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Kuparuk Date BL Color CD 10/25/06 MKMMT-M' 1710, . 0--- 'ED= i . 0--- • LJ Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. Re: 1J-115 Operations and Plan forward 0 0 Steve, D Thanks for keeping us informed. Good luck with the operations. Tom Maunder, PE AOGCC McKeever, Steve wrote, On 10/22/2006 7:27 PM: Hello Winton and Tom - Following up on my phone conversation with Winton earlier this afternoon regarding operations on the West Sak well 1J-115 that Doyon 141 is drilling: Following the cement job on the 7-5/8" intermediate casing, attempts to down squeeze freeze protection fluid into the 10-3/4" x 7-5/8" were unsuccessful. Options for repair were considered as drilling of the lower lateral continued. Midway through the lateral tools became available, and freeze protection operations were started. A retrievable bridge plug was set at 2450 feet in the 7-5/8" casing and the casing was cut at 18601. Attempts to pull the casing in one piece were unsuccessful and a series of cuts and pulls were made to retrieve all the casing above 1903' Last night we attempted to wash over the casing stub down past the next collar in preparation to back off the stub, then screw in another string of casing back to surface. We were unable to wash past the collar, and proceed with the back off operation. Rather than proceeding with our original plan of screwing in the tieback string, we are now planning to run a tieback string of casing equipped with an overshot on bottom. The overshot will be equipped with a pack off rated at 3000 psi. Once the overshot is run over the top of the casing down hole, we will pressure test the casing, then open a stage tool, and fill the 10-3/4" x 7-5/8" annulus with Class G cement. For further details of the operations to date, and our plans, please see attached *.pdf file. Winton has given verbal approval of our plan to tieback the casing with the overshot, and cement the casing annulus to surface. We expect to run the casing tonight (Sunday) and cement it first thing tomorrow morning. Please let me know if any formal paperwork other than the completion report will be required to document this change in operations. Thanks kindly, Steve McKeever Senior Drilling Engineer ConocoPhillips Alaska, Inc. phone: 907.265.6826 cell: 907.351.5004 fax: 907.265.1535 "What could be more interesting than finding out why covariance rotates the axes of an ellipse of uncertainty?" - Angus Jamieson, Chairman, ISCWSA 1 of 1 10/23/2006 8:24 AM 0 0 1J-115 Operations Summary Start Date Last 24hr Sum 10/21/06 Fin POOH & LD csg cut F/1730' to 1820', MU mule shoe & RIH to 2050', circ hole clean, POOH, MU 7 5/8" csg cutter, RIH & cut csg @ 1903', POOH, MU csg spear & RIH, speared csg above btm cut @ 1903', jarred same w/no movement, PU to upper cut to 184o' & jarred top cut free, attempted to release spear to RIH to lower cut w/no success, POOH w/cut F/1860', had to cut csg over grapple to release same, MU mule shoe & RIH to 2,100', circ hole clean, POOH, slip & cut drlg line, MU csg spear & RIH Latched onto cut at 1,903' & jarred free, began POOH to 1,730'. 10/20/06 RIH W/csg spear, pulled cut loose F/1562' to 1648', POOH & LD csg, RIH W/csg spear, attempted to pull cut F/1648' to 1860'W/no movement, RIH W/cutter & cut csg @ 1730', RIH & cut csg @ 1820', POOH, RIH W/spear, speared csg, POOH W/cut F/1648' to 1730', RIH W/csg spear & attempted to get inside cut @ 1730, no go, POOH, MU 3 1/2" mule shoe on spear, RIH circ sweep & circ clean above cut, worked packoff and spear into TOF, PU and jarred cut free, 10/19/06 POOH F/1,476' & LD 2-cut pieces & 3-full jts 7 5/8" csg, RIH & cut csg @ 1,562', POOH & RIH W/csg spear, speared csg & POOH LD 2-cut pieces & 1-full jt of csg, RU & tested BOPE 250/3,000 psi, MU spear & RIH, jarred on csg at 1,562'W/no movement, POOH, MU cutter & 10/18/06 Attempted to pull csg free @ 1,860'W/no success, LD spear, MU csg cutter & RIH, cut csg @ 1,306', POOH, MU Spear & PU & csg was cut, ND BOP's, pulled slips & NU BOP's, Circ hole clean. POOH LD 29 jts of 7 5/8" csg & 2-cut pieces with 13 cent. MU spear with 12 -6 1/2" DC's, RIH, speared csg @ 1,306' & jarred on csg from cut @ 1,860'w/no movement, POOH, MU cutter, RIH & cut csg at 1,476', POOH, MU spear & RIH, speared csg stub @ 1,306', PU 75K over st wt 10/17/06 Fin Circ 145 deg water around F/ 1,950' while re -hanging stabbing board, POOH W/mule shoe, MU 7 5/8" csg spear & PU on csg to 200K st wt, observed 10 3/4" csg flute & stack move 1/2-3/4" in., press. up to 1,000 psi, no leak off, LD Spear, RU & Ran USIT bond Log, RIH W/cutter and worked cutter at cut for 1 hr, POOH, RIH OE DP to 1,960' & dumped 30' of sand on top of BP & POOH. NOTE Attempted to pull csg at 1,860' W/No Movement, cut csg at 1,306', ND & Pulled 10/16/06 RIH & set RPB @ 2,450', RIH W/7 5/8" csg cutter & cut csg @ 1,860', RU & Attempted to pump down DP & OA, press. up on DP to 2,000 psi & OA to 2,500 psi w/no movement, POOH & LD csg cutter, pulled 7 5/8" packoff, speared 7 5/8" csg & worked up to 200K st wt w/1,000 psi on csg w/no movement or press. loss, LD spear, RIH W/OE DP to 1,950' & circ warm water around 10/15/06 Fin POOH, downloaded MWD, POOH & found geopilot and bit was left in hole (fish length 14') est TOF @ 12,815', serviced rig, MU Baker fishing assembly BHA #5 & RIH, tagged TOF 12,813', worked over fish and saw increase in PU wt, no increase in pressure, POOH on elevators and recovered fish, LD same and cleared rig floor. NOTE: After 24:00 hrs, Set ret. bridge plug at 2,450', tested to 1,500 psi and displace hole over to fresh water & POOH LD running tool 10/14/06 Fin sidetracking well from 11,849' to 12,018' and cont to drill 6 3/4" hole from 12,018' to 12,829' when geopilot tool failed, BROOH to shoe then cont to POOH on elevators to 4,657'. NOTE After POOH & downloading MWD, POOH & discovered geopilot was left in the hole 10/13/06 Drilled 6 3/4" hole from 10,728' to 12,018', drilled out of zone A Casing Fishing and ReRunning Procedure West Sak Well 13-115 Run and Cement Overshot and Casing — Plan Forward on 10/22. 4pm Interval Procedure: 5 pm, Sunday, 10/22: Top of 7-5/8" Casing is a cut at 1903'. We were unable to work a burn shoe and washpipe past the collar below the cut at 1923'. Rig is running in hole with spear and pack to do pressure tests. 1. RIH with spear and and pack off. Set pack off between top of stub at 1903' and next collar at 1923'. Test down drill pipe to 2000 psi for 10 minutes, testing 7-5/8" casing below pack off. Close BOP on drill pipe and test 10-3/4" casing by drill pipe annulus to 2000 psi for 10 minutes. (10-3/4" shoe LOT was 15.5 ppg on 10/5). Circulate clean, POOH with spear and pack off. 2. Circulate clean, POOH. 3. Rig up and run casing, as follows: ➢ Cut lip guide with internal cutting structure to size top of casing stub to 7-5/8" OD. ➢ Overshot grapple assembly ➢ Pack off rubber ➢ XO's as required to get to 7-5/8" BTC connection. ➢ Halliburton Type H ES Cementing tool, pinned with 4 pins to open at 2,200 psi. ➢ 7-5/8 inch casing to surface Run Tesco Torque Rings in all connections Baker Lok bottom connections Run 1 Weatherford 7-518 x 9-518' or 7-5/8"x 9-1/8"so/id straight bladed centralizer (stand off band) per joint, letting them float on the joint. Ensure all collars on casing have new AB seal rings installed. Consider running a centralizer just under the well head to help centralize the casing while setting the slips Space out to utilize top drive to engage overshot. Space out to ensure no casing collar is across well head bowl where casing slips will set. 1. Tag up on casing top at 1903' and rotate slowly down, milling top of stub. Engage overshot and set down on top of casing. Pull up 30,000 lb over weight of tie back string. Test inside of casing to 1500 psi for 10 minutes. Slowly increase pressure to +/- 2200 psi and open the ES cementer. 2. Circulate at least 1-1/2 times pipe volume. 3. Rig up cementers and pump cement job. Use Halliburton's ES plug and plug dropping head. ➢ Fill and test surface lines ➢ Pump 30 barrels fresh water. ➢ Pump +/- 90 barrels (430 sacks Class G with additives; Yield = 1.17 cf per sack), 4 hours thickening time. ➢ Drop Halliburton ES closing plug. ➢ Displace with rig pumps at +/- 5 bpm. Bump plug and pressure up to close ES tool per Halliburton Service hand. Cement with pipe in tension — 35,000 lb over string weight. Obtain and review the Test Report from Dowe//s North Slope Lab on the job blend prior to pumping the cement. DO NOT pump cement if there are any doubts as to cement quality, quantities, pumping times or thickening times If necessary, confer with the responsible Drilling Engineer or Dr/l//ng Team Leader. Batch mix cement if possible. Catch samples to monitor setting time. Ensure Dowel/ is testing compressive strengths ofjob mix using the Ultrasonic Cement Ana/yzer. Contact Dowe/ prior to drilling out. Do not drill out ES closing plug until compressive strength of at least 500 psi is reached. 4. Lift stack and immediately clean bowl where slips will be installed. Prior to setting slips ensure no free water or mud is above top of cement. Fill any voids below slips with diesel, install slips. Land casing with at least 75,000 Ibs on slips. Steve McKeever, 10/22/2006 13-115 Casing Fishing and Rerunning Procedure Page 1 • 0 Casing Fishing and ReRunning Procedure West Sak Well 1.7-115 Cut off casing, install pack off, nipple up wellhead and BOPE. Test pack off per Vetco procedure. Test flange break on well head. 5. After cement has reached a compressive strength of at least 500 psi (see note in Step 6), RIH with dumb iron drilling assembly and drill out ES closing plug. POOH 6. PU globe basket with junk baskets and RIH to top of sand above bridge plug. Work baskets and pick up any junk. Clean off sand to top of bridge plug. POOH. 7. PU bridge plug retrieving tool and RIH to +/- 2100 feet. Test casing to 2,500 psi for 30 minutes, charting test. Continue in hole and displace hole to Oil Base Drilling Mud. Retrieve bridge plug. Monitor fluid level upon releasing bridge plug. POOH with bridge plug. 8. PU same 6-3/4" bit and drilling assembly as before. RIH to 2500' and. Continue in hole to bottom and complete drilling A lateral. Return to well plan procedure. Steve McKeever, 10/22/2006 13-115 Casing Fishing and Rerunning Procedure Page 2 Re: I J- 115 0 Mike, a(3 C:, - I do appreciate the update, however when there is a major change in the plans/operations on a well the notice should be given prior to beginning the alternate work. Based on the situation you describe, I agree that failing to deal with a freezable annulus prior to moving on is not prudent. Please continue to keep us advised. Tom Maunder, PE AOGCC Greener, Mike R. wrote, On 10/ 17/2006 9:49 AM: To bring you up to date on an issue we have on the IJ-1 15. We were unable to freeze protect the 7-5/8" x 10-3/4" annulus on the well.. Could not pump into it. We determined that this was a condition. that we could not leave without fixing. We had a rotary steerable failure in the.A lateral and after we got out of the hole we decided to fix the freeze protect problem. Our plan was to cut the 7-5/8" below the permafrost freeze line (1,700' based on West Sak field temperature log). We went in and cut the casing at 1,860' and tried to circulate. No success. We do not suspect that cement is this high in the well as other conditions (mud returns during curt job, recip of pipe) do not indicate that cement came that high. Planned top was to be 4,000' for the cement. Current operation: We are running a USIT to determine what and. where the stuck point is at. There is suspicion that the pipe cut was not complete. We have other wells (3S-23 )A) where the initial cut was not enough. While we are looking at the log we are going back in to attempt to cut again in the same place. More to come. Mike Greener <<Greener, Mike R..vcf>> 1 of 1 10/23/2006 12:11 PM STATE OF ALASKA 11/09/04 OIL AND GAS CONSERVATION COMMISSION BOPE Test Report Submit to: iim re a ;,Dadmin.state.ak.us, aogcc prudhoe bavcadrnin.state.ak.us bc,b fleckenstein,Dadrr-.in state.auis Contractor: Doyon Rig No.: 141 DATE: 10/10/2006 Rig Rep.: Patrick F. Krupa Rig Phone: 659-7115 Rig Fax: 659-7103 Operator: Conoco/Phillips Alaska Op. Phone: 659-7170 Op. Fax: 659-7103 Rep.: Guy Whitlock Field/Unit & Well No.: Kuparuk 1J-115 PTD # 206-122 Operation: Drlg: X Test: Initial: X Test Pressure: Rams: 250/3000 MISC. INSPECTIONS: Test Result Location Gen.: P Well Sign Housekeeping: P Drl. Rig PTD On Location P Hazard Sec. Standing Order Posted P BOP STACK: Workover: Explor.: Weekly: Bi-Weekly Annular:250/3000 Valves:250/3000 TEST DATA FLOOR SAFETY VALVES: Test Result Quantity Test Resu P Upper Kelly 1 NT P Lower Kelly 1 NT P Ball Type 1 P Inside BOP 1 P Quantity Size Test Result Annular Preventer 1 13 5/8" P Pipe Rams 1 3 1/2''X 6" P Lower Pipe Rams 1 7 5/8" NT Blind Rams 1 Blind NT Choke Ln. Valves 1 3 1/8" NT HCR Valves 1 3 1/8" NT Kill Line Valves 1 3 1/8" NT Check Valve 1 31/8" NA MUD SYSTEM: Visual Test Alarm Test Trip Tank P NA Pit Level Indicators P P Flow Indicator P P Meth Gas Detector NT NT H2S Gas Detector NT NT Test Results CHOKE MANIFOLD: Quantity Test Res No. Valves 14 NT Manual Chokes 1 NT Hydraulic Chokes 1 NT ACCUMULATOR SYSTEM: Time/Pressure Test RE System Pressure NT Pressure After Closure NT 200 psi Attained NT Full Pressure Attained NT Blind Switch Covers: All stations P Nitgn. Bottles (avg): Number of Failures: 0 Test Time: 4.0 Hours Components tested All Repair or replacement of equipment will be made within 0 days. Notify the North Slope Inspector 659-3607, follow with written confirmation to Superviser at: jim reggQadmin.state, ak.us. Remarks: The annular, variable rams. and 4" floor valves were only tested because the 5" drill pipe was changed out with 4" and the last BOP test was on 10/5. 24 HOUR NOTICE GIVEN YES X NO Date 10/09/06 Time 8:OOAM Test start Finish Waived By Chuck Schieve Witness J. Piper/ D. Heim BOP Test (for rigs) BFL 11/09/04 BOP-Doyon 141-10-10-06.xis E Randy Thomas Greater Kuparuk Area Drilling Team Leader ConocoPhillips Alaska, Inc. PO Box 100360 Anchorage, AK 99510-0360 FRANK H. MURKOWSKI, GOVERNOR 333 W. 7" AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Re: Kuparuk River Field, West Sak Oil Pool, 1J-115 ConocoPhillips Alaska, Inc. Permit No: 206-122 Surface Location: 1973' FSL, 2380' FEL, SEC. 35, T11N, RlOE, UM Bottomhole Location: 91' FSL, 4620' FEL, SEC. 24, T 11 N, R 10E, UM Dear Mr. Thomas: Enclosed is the approved application for permit to drill the above referenced development well. This permit to drill does not exempt you from obtaining additional permits or an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). DATED this day of August, 2006 cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. Conocofhilfips Alaska Post Office Box 100360 Anchorage, Alaska 99510-0360 Randy Thomas Phone (907) 265-6830 Email: Randy.L.Thomas@conocophillips.com August 15t" , 2006 Alaska Oil and Gas Conservation Commission 333 West 7t" Avenue Suite 100 Anchorage, Alaska 99501 C RECEIVED AUG 1 6 2006 Alaska Oil & Gas Cons. Commission Anchorage Re: Applications for Permit to Drill, West Sak Producer, 13-115, 13-115 L1, 1J-115 L2 Dear Commissioners: ConocoPhillips Alaska, Inc. hereby applies for Permits to Drill for an onshore production well, a trilateral horizontal well in the West Sak "A2", "B" and "D" sands. The main bore of the well will be designated 13- 115, and the lateral bores of the well will be designated 13-115L1 and 13-1151-2. Please find attached for the review of the Commission forms 10-401 and the information required by 20 ACC 25.005 for each of these well bores. The expected spud date of 11-115 is October 2nd, 2006. If you have any questions or require any further information, please contact Mike Greener at 263-4820. Sincerely, 00 Randy Thomas Greater Kuparuk Area Drilling Team Leader 0 STATE OF ALASKA Ski.) ALASKA OIL AND GAS CONSERVATION COMMISSION RECEIVED AUG 1 6 2006 PERMIT TO DRILL Alaska Oil & Gas Cons. Commission 20 AAC 25.005 Anchorage 1 a. Type of Work: Drill ❑✓ Re -drill ❑ Re-entry ❑ 1 b. Current Well Class: Exploratory ❑ Development Oil ❑ Stratigraphic Test ❑ Service ❑ Development Gas ❑ Multiple Zone❑ Single Zone Q 1 c. Specify if well is proposed for: Coalbed Methane ❑ Gas Hydrates ❑ Shale Gas ❑ 2. Operator Name: ConocoPhillips Alaska, Inc. 5. Bond: ✓ Blanket Single Well Bond No. 59-52-180 ' 11. Well Name and Number: 1J-115 ` 3. Address: P.O. Box 100360 Anchorage, AK 99510-0360 6. Proposed Depth: MD: 13762' ` TVD: 3907' 12. Field/Pool(s): Kuparuk River Field West Sak Oil Pool 4a. Location of Well (Governmental Section): Surface: 1973' FSL, 2380' FEL, Sec. 35, T11 N, R10E, UM ' Top of Productive Horizon: 4369' FSL, 4329' FEL, Sec. 36, T11 N, R10E, UM • Total Depth: 91' FSL, 4620' FEL, Sec. 24, T11 N, R10E, UM 7. Property Designation: ADL 25661 & 25650 8. Land Use Permit: ALK 471, 468 13. Approximate Spud Date: 10/2/2006 9. Acres in Property: 2560 14. Distance to Nearest Property: < 3 miles ' 4b. Location of Well (State Base Plane Coordinates): Surface: x- 558830 y- 5945785 Zone- 4 10. KB Elevation (Height above GL): 28' RKB feet 15. Distance Nearest _/0ZG Well within Pool: 1 DD-38 , 581' @ 1 727' 16. Deviated wells: Kickoff depth: 500 ft. Maximum Hole Angle: 90° deg 17. Maximum Anticipated Pressures in psig (see 20 AAC 25.035) Downhole: 1758 psig Surface: 1328 psig 18. Casing Program Size Specifications Setting Depth Quantity of Cement c. f. or sacks Top Bottom Hole Casing Weight Grade Coupling Length MD TVD MD TVD (including stage data) 42" 20" x 34" 94# K-55 Welded 80' 28' 28' 108' 108' 260 cf ArcticCRETE 13.5" 10.75" 45.5# L-80 BTC 3007' 28' 28' 3007' 2231' 490 sx AS Lite, 180 sx DeepCRETE 9-7/8" 7-5/8" 29.7# L-80 BTCM 7458' 28' 28' 7458' 3809' 440 sx DeepCRETE 6.75" 4.5" 11.6# L-80 BTC 7166' 6596' 3630' 13762' 3907' slotted liner 19 PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re -Entry Operations) Total Depth MD (ft): Total Depth TVD (ft): Plugs (measured) Effective Depth MD (ft): Effective Depth TVD (ft): Junk (measured) Casing Length Size Cement Volume MD TVD Conductor/Structural Surface Intermediate Production Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): 20. Attachments: Filing Fee ❑✓ BOP Sketch Li Drilling Program 21 Time v. Depth Plot ❑ Shallow Hazard Analysis ✓ Property Plat ❑ Diverter Sketch ❑ Seabed Report ❑ Drilling Fluid Program Q 20 AAC 25.050 requirements ❑✓ 21. Verbal Approval: Commission Representative: Date: 22. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Mike Greener @ 263-4820 Printed Name Randy Thomas Title Greater Kuparuk Area Drilling Team Leader Signature t� D / s Phone Date i Prepared by SharonI k PF Commission Use Only Permit to Drill /� Number: .2—O// — Z Z API Number: ,( 50- 029 "�2C) _06 Permit Ap rov/al Date: • 1 T See cover letter for other requirements Conditions of approval : If box is checked, well may not be used to explore for, test, or produce coalbed methane, gas hydrates, or as contained in shales: h C Samples req'd: Yes ❑ No � M og req'd: Yes ❑ No [� Other: 33�S� �?]D•Iim_Sv c H2S measures: Yes ❑ No Dire s req'd: Yes [✓]' No ❑ APPROVED BY THE COMMISSION DATE: V K I A I 'COMMISSIONER Form 10-401 Revised 12/2005 / Submit in Duplicate ation for Permit to Drill, Well 1 J-115 Revision No.0 Saved: 15-Aug-06 Permit It - West Sak Well #1 J-115 "d r.� +t Application for Permit to Drill Document' iMmiX'ei M* x I M i Z 0 Well Yp14e Table of Contents 1. Well Name................................................................................................................. 2 Requirements of 20 AAC 25.005 (1)....................................................................................................... 2 2. Location Summary................................................................................................... 2 Requirements of 20 AAC 25.005(c)(2)................................................................................................... 2 Requirements of 20 AAC 25.050(b)....................................................................................................... 3 3. Blowout Prevention Equipment Information......................................................... 3 Requirements of 20 AAC 25.005(c)(3)................................................................................................... 3 4. Drilling Hazards Information................................................................................... 3 Requirements of 20 AAC 25.005(c)(4).................................................................................................. 3 5. Procedure for Conducting Formation Integrity Tests ........................................... 4 Requirements of 20 AAC 25.005(c)(5).................................................................................................. 4 6. Casing and Cementing Program............................................................................ 4 Requirements of 20 AAC 25.005(c)(6)................................................................................................... 4 7. Diverter System Information................................................................................... 4 Requirements of 20 AAC 25.005(c)(7)................................................................................................... 4 8. Drilling Fluid Program............................................................................................. 4 Requirements of 20 AAC 25.005(c) (8)................................................................................................... 4 Surface Hole Mud Program (extended bentonite).................................................................................. 5 Intermediate Hole Mud Program (extended bentonite).......................................................................... 5 Lateral Mud Program (MI VersaPro Mineral Oil Base)........................................................................... 5 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..................................................................................... 6 Requirements of 20 AAC 25.005(c)(11)................................................................................................ 6 1J-115 PERMIT IT Page 1 of 8 Printed. 15-Aug-06 ORIGINAL • ation for Permit to Drill, Well 1 J-115 Revision No.0 Saved: 15-Aug-06 12. Evidence of Bonding............................................................................................... 6 Requirements of 20 AAC 25.005(c)(12)................................................................................................ 6 13. Proposed Drilling Program..................................................................................... 6 Requirements of 20 AAC 25.005(c)(13)................................................................................................ 6 14. Discussion of Mud and Cuttings Disposal and Annular Disposal ....................... 8 Requirements of 20 AAC 25.005(c)(14)................................................................................................ 8 15. Attachments............................................................................................................. 8 Attachment1 Directional Plan................................................................................................................ 8 Attachment 2 Drilling Hazards Summary ............................................................................................... 8 Attachment 3 Cement Loads and CemCADE Summary ....................................................................... 8 Attachment4 Well Schematic............................................................................................................... 8 Attachment 5 114 Mile Radius Effect for Injector......................................................................8 1. Well Name Requirements of 20 AAC 25.005 (0 Each well must be identified by a unique name designated by the operator and a unique API number assigned by the commission under 20 AAC 25.040(b). For a well with multiple well branches, each branch must similarly be identified by a unique name and API number by adding a suffix to the name designated for the well by the operator and to the number assigned to the well by the commission. The well for which this Application is submitted will be designated as 13-115. 2. Location Summary Requirements of 20 AAC 25.005(c)(2) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (2) a plat identifying the property and the property's owners and showing (A)the coordinates of the proposed location of the well at the surface, at the top of each objective formation, and at total depth, referenced to governmental section lines. (B) the coordinates of the proposed location of the well at the surface, referenced to the state plane coordinate system for this state as maintained by the National Geodetic Survey in the National Oceanic and Atmospheric Administration; (C) the proposed depth of the well at the top of each objective formation and at total depth; Location at Surface 1 973' FSL, 2,380' FEL, Section 35, T11N, R10E ASP Zone 4 NAD 27 Coordinates Northings: 5,945,785 Eastings: 558,830 RKB Elevation 109.0' AMSL Pad Elevation 81.0' AMSL Location at Top of Productive Interval 4,369' FSL, 4,329' FEL, Section 36, T11N, R10E West Sak "A2" Sand ASP Zone 4 NAD 27 Coordinates Measured Depth, RKB: 7,458 Northings: 5,948,207 Eastings: 552,139 Total Vertical Depth, RKB: 3,809 Total Vertical Depth, SS: 3,700 Location at Total Depth 91' FSL 4,620' FEL Section 24 T11N, R10E ASP Zone 4 NAD 27 Coordinates Northings: 5,954,487 Eastings: 561,793 Measured Depth, RKB: 13,762 Total Vertical Depth, RKB: 3,907 Total Vertical Depth, SS: 3,798 1J-115 PERMIT IT Page 2 of 8 Printed: 15-Aug-06 I GINA L �ation for Permit to Drill, Well 1 J-115 Revision No.0 Saved: 15-Aug-06 and (D) other information required by 20 AAC 25.050(b); Requirements of 20 AAC 25.050(b) If a well is to be intentionally deviated, the application for a Permit to Drill (Form 10-401) must (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 and (2) for all wells within 200 feet of the proposed wellbore (A) list the names of the operators of those wells, to the extent that those names are known or discoverable in public records, and show that each named operator has been furnished a copy of the application by certified mail; or (B) state that the applicant is the only affected owner. The Applicant is the only affected owner. 3. Blowout Prevention Equipment Information Requirements of 20 AAC 25.005(c)(3) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (3) a diagram and description of the blowout prevention equipment (BOPS) as required by 20 AAC 25.035, 20 AAC 25.036, or 20 AAC 25.037, as applicable; An API 13-5/8" x 5,000 psi BOP stack (RSRRA) will be utilized to drill and complete well 13-115. For all operations the stack will be equipped with 3-1/2" to 6" variable bore rams in the uppermost ram cavity, blind rams in the middle cavity, and 7-5/8" rams in the lowermost cavity. See attached diagram entitled "Doyon 141 West Sak 2004 3ksi BOP Configuration" for clarification. Upon initial nipple up, and at intervals of no more than 14 days thereafter, a test plug will be set below the lowermost rams, the annular preventer will be tested to 1,500 psi and the blind rams and upper rams will be tested to 3,000 psi. (This test will test the shell and end connections of the lowermost ram). The lowermost rams will be closed and tested to 3,000 psi on a 7-5/8" OD. 4. Drilling Hazards Information Requirements of 20 AAC 25.005 (c)(4) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (4) information on drilling hazards, including (A) the maximum downhole pressure that may be encountered, criteria used to determine it, and maximum potential surface pressure based on a methane gradient; The expected reservoir pressures in the West Sak sands in the 13 area are 0.45 psi/ft, or 8.7 ppg EMW (equivalent mud weight). These pressures are predicted based on the undisturbed West Sak pressure gradient. The maximum potential surface pressure (MPSP) based on the above maximum pressure gradient, a methane gradient (0.11), and the deepest planned vertical depth of the West Sak A2 sand formation is 1,328 psi, calculated thusly: MPSP = (3,907 ft TVD)(0.45 - 0.11 psi/ft) = 1,328 psi (B) data on potential gas zones; The well bore is not expected to penetrate any gas zones. ' and (C) data concerning potential causes of hole problems such as abnormally geo-pressured strata, lost circulation zones, and zones that have a propensity for differential sticking; Please see Attachment 2: 13-115 Drilling Hazards Summary. 1J-115 PERMIT IT Page 3 of 8 I NAL Printed: 15-Aug-06 a'i • f ation for Permit to Drill, Well 1 J-115 Revision No.0 Saved: 15-Aug-06 5. Procedure for Conducting Formation Integrity Tests Requirements of 20 AAC 25.005 (c)(5) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (5) a description of the procedure for conducting formation integrity tests, as required under 20 AAC 25.030(f); 13-115 will be completed with 7-5/8" intermediate casing landed at the top of the West Sak A2 sand. The casing shoe will be drilled out and a formation integrity test will be performed in accordance with the "Formation Integrity Test Procedure" that ConocoPhillips Alaska placed on file with the Commission. 6. Casing and Cementing Program Requirements of 20 AAC 25.005(c)(6) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (6) a complete proposed casing and cementing program as required by 20 AAC 25.030, and a description of any slotted liner, pre - perforated liner, or screen to be installed, Hole Top Btm sgITbg Size Weigh Length MD/TVD MD/TVD D in in t Ib/ft Grade Connection ft ft ft) Cement Program 20 x 34 42 94 K55 Welded 80 28 / 28 108 / 108 Cemented to surface with 260 cf ArcticCRETE 10-3/4 13-1/2 45.5 L-80 BTC special drift 3,007 28 / 28 3,007 /2,231 Cemented to Surface with 490 sx ASLite Lead, 180 sx DeepCRETE Tail 7-5/8 9-7/8 29.7 L-80 BTCM 7,458 28 / 28 7,458 / 3,809 Cement Top planned @ 4,000' MD / 2,704' TVD. Cemented w/ 440 sx DeepCRETE 4-1/2 6-3/4" A Sand 11.6 L-80 BTC 7,166 6,596 / 3,630 13,762 / 3,907 Slotted— no cement slotted Lateral (13-115) 6-3/4" B and 11.6 L-80 BTC 7,456 6,4 ,648 13,954 / 3,767 S o e — no cement slotted Lateral (13-115 L1) 4-1/2 6-3/4" D Sand 11.6 L-80 BTC 7,861 6,159 / 3,574 14,020 / 3,707 Slotted— no cement slotted Lateral (13-115 1-2) 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 commission and identified in the application: (7) a diagram and description of the diverter system as required by 20 AAC 25.035, unless this requirement is waived by the commission under 20 AAC 25.035(h)(2); A 21-1/4", 2000 psi annular with a 16" diameter diverter line will be the diverter system used in the drilling of U-115. Please see diagrams of the Doyon 141 diverter system on file with the Commission. 8. Drilling Fluid Program Requirements of 20 AAC 25.005(c)(8) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (8) a drilling fluid program, including a diagram and description of the drilling fluid system, as required by 20 AAC 25.033; Drilling will be done with muds having the following properties over the listed intervals: 1J-115 PERMIT IT Page 4 of 8 ORIGINAL Printed: 15-Aug-06 • �tion for Permit to Drill, Well U-115 Revision No.0 Saved: 15-Aug-06 Surface Hole Mud Program (extended bentonite) Spud to Base of Permafrost Base of Permafrost to 10-3/4" Casing Point Initial Value Final Value Initial Value Final Value Density (ppg) 8.9 9.2 9.5 9.6 Funnel Viscosity 150 250 200 300 seconds Yield Point 50 70 30 50 (cP) Plastic Viscosdy 20 45 15 20 ►b/100 s pH 8.5 9.0 8.5 9.0 API Filtrate NC +— 8.0 5.0 7.0 (cc / 30 min)) *9.6 ppg if hydrates are encountered ' Intermediate Hole Mud Program (LSND) Lateral Mud Program (MI VersaPro Mineral Oil Base) A/B/D sand laterals 10-3/4" Csg Shoe to 7-5/8" Csg Point Value Density (ppg) 9.0 - 9.1 Funnel Viscosity 45 - 60 (seconds) Plastic Viscosdy 12 - 18 Ib/100 st) Yield Point 26 - 35 (CP) API Filtrate 4-6 (cc / 30 min)) Chlorides (mg/1) <500 pH 9.0 - 9.5 MBT <20.0 Value Density ( 8.6 Plastic Viscostiy 15 - 25 (Ib/100 s Yield Point 18 - 28 cP HTHP Fluid loss (m1/30 min @ <4.0 200 si & 150° Oil / Water Ratio 70 / 30 Electrical >600 Stability Drilling fluid practices will be in accordance with appropriate regulations stated in 20 AAC 25.033. Please see information on file with the Commission for diagrams and descriptions of the fluid system of Doyon Rig 141. 9. Abnormally Pressured Formation Information Requirements of 20 AAC 25.005 (c)(9) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (9) for an exploratory or stratigraphic test well, a tabulation setting out the depths of predicted abnormally geo-pressured strata as required by 20 AAC 25.033(f); Not applicable: Application is not for an exploratory or stratigraphic test well. 10. Seismic Analysis Requirements of 20 AAC 25.005 (c)(10) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (10) for an exploratory or stratigraphic test well, a seismic refraction or reflection analysis as required by 20 AAC 25.061(a); Not applicable: Application is not for an exploratory or stratigraphic test well. 1J-115 PERMIT IT Page 5 of 8 Printed: 15-Aug-06 ^^IGINAL �ation for Permit to Drill, Well 1J-115 Revision No.0 Saved: 15-Aug-06 11. Seabed Condition Analysis Requirements of 20 AAC 25.005 (c)(11) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (11) for a well drilled from an offshore platform, mobile bottom -founded structure, jack -up rig, or floating drilling vessel, an analysis of seabed conditions as required by 20 AAC 25.061(b); Not applicable: Application is not for an offshore well. 12. Evidence of Bonding Requirements of 20 AAC 25.005 (c)(12) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (12) evidence showing that the requirements of 20 AAC 25.025 {Bonding}have been met; Evidence of bonding for ConocoPhillips Alaska, Inc. is on file with the Commission. 13. Proposed Drilling Program Requirements of 20 AAC 25.005 (c)(13) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: The proposed drilling program is listed below. Please refer also to Attachment 4, Well Schematic. 1. Excavate cellar, install cellar box, set and cement 20" x 34" insulated conductor to +/- 108' RKB. Install landing ring on conductor. 2. Move in / rig up Doyon Rig 141. Install 21-1/4" Annular with 16" diverter line and function test. 3. Spud and directionally drill 13-1/2" hole to casing point at +/- 3,007' MD / 2,231' TVD as per directional plan. Run MWD tools as required for directional monitoring. 4. Run and cement 10-3/4", 45.5#, L80, BTC casing to surface. Displace cement with mud and, pressure test casing to 2500 psi for 30 minutes and record results. Perform top job if required. 5. Remove diverter system, install and test 13-5/8" x 5,000 psi BOP's as described above in Section 3 above and test to 3,000 psi (annular preventer to 1500 psi). Notify AOGCC 24 hrs before test. 6. PU 9-7/8" bit and 6-1/4" drilling assembly, with MWD, LWD & PWD. RIH, clean out cement to top of float equipment. Re -test casing if cement is tagged more than 100 feet above the float collar. 7. Drill out cement and between 20' and 50' of new hole. Perform formation integrity test to leak off, recording results. (ECD's modeled to be less than 11.0 ppg) 8. Directionally drill to 7-5/8" casing point at 7,458' MD / 3,809' TVD, the prognosis top of the A2 sand. 9. Run 7-5/8", 29.7# L80, BTC Mod casing to surface. Pump cement and displace with mud (top of cement to be 4,000' MD / 2,704' TVD if Ugnu C formation is oil bearing. Top of cement to be 500 feet (MD) above shallowest oil bearing sand.). Pressure test casing to 3,000 psi for 30 minutes and record results. 10. Install wellhead x 7-5/8" packoff and test to 5000 psi. 11. Flush 10-3/4" x 7-5/8" annulus with water, followed by diesel. 12. PU 6-3/4" PDC Bit and 4-3/4" drilling assembly, with MWD, and LWD logging tools. RIH, clean out cement to top of float equipment. Re -test casing if cement is tagged more than 100 feet above the float collar 13. Drill out cement and between 20' and 50' of new hole. Displace hole to lateral drilling mud. Perform formation integrity test to leak off, recording results. (Expected ECD's in 6-3/4" lateral modeled to be less than 12.5 ppg). 14. Directionally drill 6-3/4" hole to TD at +/- 13,762' MD / 3,907' TVD as per directional plan. 1J-115 PERMIT IT Page 6 of 8 Printed: 15-Aug-06 DR!GINAL • �ation for Permit to Drill, Well 1 J-115 Revision No.0 Saved: 15-Aug-06 15. POOH, back reaming out of lateral to 7-5/8" shoe. TIH to bottom & displace to solids -free oil based mud. POOH on elevators. QCc..irti��- 16. PU and run 4-1/2" slotted liner. p 17. Land liner, set liner hanger @ +/- 6,596' MD / 3,666' TVD. POOH. I` - Note: Remaining operations are covered under the 0-1151-1 Application for Permit to Drill, and are provided here for information only. 18. Run and set Baker WindowMaster whipstock system, at window point of +/- 6,498' MD / 3,648' TVD, the top of the B sand. 19. Mill 6-3/4" window. POOH. 20. Pick up 6-3/4" drilling assembly with LWD and MWD and PWD. RIH. a(DG `D—S 21. Drill to TD of B sand lateral at +/- 13,954' MD / 3,767' TVD, as per directional plan. 22. POOH, back reaming out of lateral to window. TIH to bottom & displace to solids -free oil based mud. POOH on elevators. 23. RIH with whipstock retrieval tool. Retrieve whipstock and POOH. 24. PU and run 4-1/2" slotted liner. 25. RIH, until liner hanger is just above window. Orient hanger to window and land hanger. 26. Release hanger running tool. POOH. 27. Make up junction isolation / re-entry assembly (Lateral Entry Module or LEM) and RIH to depth. Orient and set packer atop assembly and release from assembly. POOH. Note: Remaining operations are covered under the 13-1151-2 Application for Permit to Drill, and are provided here for information only. 28. Run and set Baker WindowMaster whipstock system, at window point of +/- 6,159' MD / 3,574' TVD, the top of the D sand. 29. Mill 6-3/4" window. POOH. t4 30. Pick up 6-3/4" drilling assembly with LWD and MWD and PWD. RIH. 31. Drill to TD of D sand lateral at +/- 14,020' MD / 3,707' TVD, as per directional plan. 32. POOH, back reaming out of lateral to window. TIH to bottom & displace to solids -free oil based mud. POOH on elevators. 33. RIH with whipstock retrieval tool. Retrieve whipstock and POOH. 34. PU and run 4-1/2" slotted liner. 35. RIH, until liner hanger is just above window. Orient hanger to window and land hanger. 36. Release hanger running tool. POOH. 37. Make up junction isolation / re-entry assembly (Lateral Entry Module or LEM) and RIH to depth. Orient and set packer atop assembly and release from assembly. 38. POOH, laying down drill pipe as required. 39. PU completion and ESP as required and RIH to depth. Land tubing. Set BPV. 40. Nipple down BOPE, nipple up tree and test. Pull BPV. 41. Freeze protect well with diesel. 1J-115 PERMIT IT Page 7 of 8 Printed. 15-Aug-06 ORIGINAL • ation for Permit to Drill, Well 1 J-115 Revision No.0 Saved: 15-Aug-06 42. Set BPV and move rig off. 14. Discussion of Mud and Cuttings Disposal and Annular Disposal Requirements of 20 AAC 25.005 (c)(14) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (14) a general description of how the operator plans to dispose of drilling mud and cuttings and a statement of whether the operator intends to request authorization under 20 AAC 25.080 for an annular disposal operation in the well.; Waste fluids generated during the drilling process will be disposed of either by pumping authorized fluids into a permitted annulus on 11 Pad, or by hauling the fluids to a KRU Class II disposal well. All cuttings generated will be disposed of either down a permitted annulus on 11 Pad, hauled to the Prudhoe Bay Grind and Inject Facility for temporary storage and eventual processing for injection down an approved disposal well, or stored, tested for hazardous substances, and (if free of hazardous substances) used on pads and roads in the Kuparuk area in accordance with a permit from the State of Alaska. ConocoPhillips Alaska may in the future request authorization for the use of this well for annular disposal operations. 15.Attachments Attachment 1 Directional Plan Attachment 2 Drilling Hazards Summary Attachment 3 Cement Loads and CemCADE Summary Attachment 4 Well Schematic 1J-115 PERMIT IT Page 8 of 8 Printed: 15-Aug-06 ORIGINAL ConocoPhillips Alaska ConocoPhillips Alaska Inc. Kuparuk River Unit Kuparuk 1J Pad Plan 1J-115 - Slot 1J-115 Plan: 1J-115 (wp05) Proposal Report 17 June, 2006 awlif 10.1 Sperry Drilling Services ORIGINAL FM y C� ? IIIII J v ° ao N 0.1 c uj a IIIII (p o AM ++f aim LLmFYF»>Y$S5�¢¢ Y 7 7 O Nd= (n E =0 N a �MO�YiA Am meNO100101 W MO\Ob O�Ob Ab°p�Old� m M m0- a LIL d III I I M � O 1(1 Z�nd Fw W O °G O O. Y. °o n N O. a'ObmO NNnb�tid 01Mbb Oaon Mo m.-Mn�My nmd f��NMdmubmm�bmA '••) � � Q% � YY •• — O III I \ � III I I \\� W J m J 0 O 0 ��m� a O NmNdN^nmd\n^n.-om i>„4„�� t06 III I I III I g d 1. O Z Q NOdbNdmOlbbO MmNb e'/P9MMtblh MhO Vi a III 1 Fm- r O d n > � 111 I ❑ocoo �ObO O LL Y00000pp0000noob 0000000 OOOMOOb C IIII I-�mn Moo N Op 01 N M M a�o�ri�\e \e r�aie(e adooi of �nmMmo+ebn.-�mNo Obb �NOI�M dhb bA m � � � NNMMMMMMMM M (.� � � IIII I I I� 1"' �• M Z�N M IS II I 1 r I1 1 I I 1 � QQ 8C � II II I m o� IS � C\\U � 1 ppa 1 I 1 II II I II I m $ �3 m °d\ 1 �� C e 61 LI 1 1 m ~ egp `o ! E \ ®1 I \ 32 \\ j tii m o\ E t 0 co Do O C b 0 0 1.1 w \ \ 1 I \ \ \ \ \ \ I I I I G\ \\\ Oe \\ \ \\ \ \ \\ III I \\\ \ \\ \ \\ \\ 0 0081 ffi g m \\ \\ \\ \\ \ \ III11 I c ------------------ e \ \ \ \ �� 1 I III11 I/ "'JJJIiii 333$JJJffi IIII IYIln;l 0 0 0 0 0 0 0 0 0 0 o O o 0 0 0 0 0 0 In 0 o 0 0 \n \n 0 0 o In � ems► � IIWISOOOI�Ul�O 0 0 o \n �lVa� enll 0 0 0 o In o "' "' v \n v o � \n � 0 rn HALLIBURTON Sperry Drilling �rviai ConocoPhillips Alaska 8000 5500 1J-116 BHL @ 13762ft MD, 3907ftTVD - 41 ' DD Polygon Describes a corridor 100' wide with a 50'+/- allowance ENV from the proposed wellbore. 1 J-115 DID Polygon @ 95% (wp05) CASING DETAILS No TVD MD Name Size 1 2231.00 3006.65 10 314" 10-3/4 2 3809.68 7458.19 7 5/8" 7-5/8 3 3907.00 13761.99 4112" 4-1/2 WELL DETAILS: Plan U-115 Ground Level: 81.00 +N/-S+E/-W Northing Easting Latittude Longitude Slot 0.00 0.005945785.38 558829.6370°15'44.934NI49°31'27.882W 1J-115 T 1 ,zimuths to True North Magnetic North: 24.07° Magnetic Field Strength: 57564.9nT Dip Angle: 80.77° Date: 5/31/2006 Model: BGGM2005 Continue Geosteering in uppr Lober of A2-Sand, 9011ft MD, 383" 1J-115 T8 Toe (wp05 ---------- ---------------- ------------- -------------- Sall @ 86° Inc : 7468ft MD, 381OR TV I 1J-116 T3 A2top (wp05 Continue Build @ 4°/100ft , 733311 MD, 3793ft - sail @ or inc: 7686ft MD, 3817R Tv 7 5/8" 7468R MD, 3610R 350° Continue Build @ 4°/100ft , 7478ft MD, 3811ft 1J-115 T2 Btop (wp05 Sall @ 80° Inc: 6498ft MD, 3648ft TV 350` Continue Build @ 4°/100ft Continue Build 4°/10011t, 700ft MD, 700ft TVO 1 1J-115 T1 Dtop (wp05 Sail 77°Inc 8 350°A� Base Penn Sail @ 40° Inc : 1681ft MD.15WR - - - KOP @ SOOft MD, 500R TVD - Build @ 2.6°/1 1 i Sall @ 77° Inc : 6080ft MD, 3656R TVO Continue Tum @ 4°/100ft i 1 1 � I � I � 10 3/4" 3007 ft MD, 2231ft TV 1 i I c � I i o I 1 N i h 1 I � 1 I 1 I o I I I Continue TuMBulld @ 5°/100ft , 5641ft MD, 3377ft TV Sall @ 64.6° Inc : 2168ft MD, 1872ft TV Begin Pump Tangent - Sall @ 64.6°, 6209ft MD, 3234ft Continue Build @ 6°/1100ft ,1681ft MD,1576ft Continue Tum @ 5°/100ft , 3968ft MD, 2543ft 2600 -1500 -1600 -500 0 500 1000 1500 2000 2500 3000 3500 4000 4500 5000 5500 it l M I n 1Aes1(-ka1t(+) (1000 Win) HALLIBURTON V-1 , • Halliburton Energy Services • (-nnnrnP UIl! S Alaska Planning Report - Geographic SjwnY Drilling ServWes Datebbso: EDM_2003.11_b48 6O Cis-ordinst6 Refer0000*. Well Plan 1J-115 - Slot 1J-115 Company: ConocoPhillips Alaska Inc. TVD Reference: Plan RKB @ 109.00ft (Doyon 141 (28 + 81)) Project: Kuparuk River Unit MD Reference: Plan RKB @ 109.00ft (Doyon 141 (28 + 81))> Site; Kuparuk 1J Pad North Roorence: True Wett:, Plan 1 J-115 Survey Gaictat%n Method: Minimum Curvature Weitbore: Plan 1 J-115 Design; 1J-115 (wp05) Project Kuparuk River Unit, North Slope Alaska, United States Map System: US State Plane 1927 (Exact solution) System Datum: Mean Sea Level Goo Datum: NAD 1927 (NADCON CONUS) Using Well Reference Point Map Zone: Alaska Zone 04 Using geodetic scale factor Veit Plan 1 J-115 - Slot 1 J-115 Well Position +N/-S 0.00 ft Northing: 6,945,785.38 ft Latitude: 70° 15' 44.934" N +E/-W 0.00 ft Easting: 568,829.63 ft Longitude: 149° 31' 27.882" W Position Uncertainty 0.00 ft Wellhead Elevation: ft Ground Level: 81.00ft }i'tfetibore Plan 1J-115 ......... , BGGM2005 5/31/2006 24.07 80.77 57,565 D*qn 1J-115 (wp05) Audit Notes: Version: Phase: PLAN Tie On Depth: 28.00 28.00 0.00 0.00 0.00 611712006 11:16:19AM Page 2 of 10 COMPASS 2003.11 Build 50 ConocoPhillip5 Alaska EDM 2003.11 b48 Locat Go-ordins ConocoPhillips Alaska Inc, :tVt ftef0t*nce: Kuparuk River Unit M© Etdference: . Kuparuk 1J Pad 460 Reference.' Plan 1J-115 $*Vey Caicuiatt Plan 1J-115 1J-115 (wp05) Halliburton Energy Services Planning Report - Geographic Well Plan 1J-115 - Slot 1J-115 Plan RKB @ 109.00ft (Doyon 141 (28 + 81)) Plan RKB @ 109 00ft (Doyon 141 (28 + 81)) True Minimum Curvature 0 HALLIBURTON Sperry Drilling Services Plan Summary Meaeured Vertical CWgg Buitd ,- Turn #lfeptti Incline€ton Azfmuth t pth +>,tls +E[-W Ram t td• ' i i} (ftj 1. # (°Host) `" rogolt (01100ft) {°) 28.00 0.00 0.00 28.00 0.00 0.00 0.00 0.00 0.00 0.00 500.00 0.00 0.00 500.00 0.00 0.00 0.00 0.00 0.00 0.00 700.25 5.01 95.00 700.00 -0.76 8.71 2.50 2.50 0.00 95.00 1,580.68 40.22 95.00 1,500.00 -29.81 340.70 4.00 4.00 0.00 0.00 1,680.68 40.22 95.00 1,576.35 -35.44 405.03 0.00 0.00 0.00 0.00 2,168.41 64.61 95.00 1,871.58 -68.87 787.17 5.00 5.00 0.00 0.00 3,968.41 64.61 95.00 2,643.38 -210.60 2,407.12 0.00 0.00 0.00 0.00 5,209.41 64.61 25.43 3,234.45 297.45 3,294.72 5.00 0.00 -5.61 -106.59 5,540.70 64.61 25.43 3,376.52 567.75 3,423.21 0.00 0.00 0.00 0.00 6,079.61 77.00 0.00 3,556.00 1,059.24 3,529.70 5.00 2.30 -4.72 -67.40 6,159.61 77.00 0.00 3,574.00 1,137.19 3,529.70 0.00 0.00 0.00 0.00 6,403.19 77.00 350.00 3,628.93 1,373.29 3,509.04 4.00 0.00 -4.11 268.87 6,423.19 77.00 350.00 3,633.42 1,392.48 3,505.66 0.00 0.00 0.00 0.00 6,498.19 80.00 350.00 3,648.38 1,464.85 3,492.90 4.00 4.00 0.00 0.00 7,333.19 80.00 350.00 3,793.37 2,274.67 3,350.11 0.00 0.00 0.00 0.00 7,458.19 85.00 350.00 3,809.68 2,396.68 3,328.59 4.00 4.00 0.00 0.00 7,478.19 85.00 350.00 3,811.43 2,416.30 3,325.13 0.00 0.00 0.00 0.00 7,585.72 89.17 351.04 3,816.89 2,522.20 3,307.46 4.00 3.88 0.97 14.07 9,011.08 89.17 351.04 3,837.47 3,930.04 3,085.60 0.00 0.00 0.00 0.00 9,222.22 90.00 359.45 3,839.00 4,140.26 3,068.13 4.00 0.39 3.98 84.42 9,568.22 90.00 359.45 3,839.00 4,486.24 3,064.80 0.00 0.00 0.00 0.00 9,585.88 89.50 359.63 3,839.08 4,503.90 3,064.66 3.00 -2.82 1.02 160.10 10,267.39 89.50 359.63 3,845.00 5,185.37 3,060.27 0.00 0.00 0.00 0.00 10,274.52 89.30 359.57 3,845.07 5,192.50 3,060.22 3.00 -2.87 -0.87 -163.23 11,236.69 89.30 359.57 3,856.88 6,154.57 3,052.97 0.00 0.00 0.00 0.00 11,267.79 90.23 359.57 3,857.01 6,185.66 3,052.74 3.00 3.00 0.00 0.09 11,767.79 90.23 359.57 3,855.00 6,685.65 3,048.98 0.00 0.00 0.00 0.00 11,799.39 89.28 359.53 3,855.13 6,717.25 3,048.74 3.00 -3.00 -0.13 -177.57 12,267.93 89.28 359.53 3,861.00 7,185.74 3,044.89 0.00 0.00 0.00 0.00 12,303.28 88.22 359.49 3,861.77 7,221.08 3,044.59 3.00 -3.00 -0.12 -177.74 13,762.00 88.22 359.49 3,907.00 8,679.04 3,031.56 0.00 0.00 0.00 0.00 611712006 11:16:19AM Page 3 of 10 COMPASS 2003.11 Build 50 ORIGINAL Halliburton Energy Services HALLIBUFpTON C©nocoPhillip5 Planning Report - Geographic Aim Sperryriiifng Servtees EDM 2003.11_b48 f oCaf o-ordfnate ftfetonaet Well Plan 1 J-115 -Slot 1 J-115 ConocoPhillips Alaska Inc. TVb heteranFe, ; Plan RKB @ 109,OOft (Doyon 141 (28 + 81)) Kuparuk River Unit MD Reference: Plan RKB @ 109.00ft (Doyon 141 (28 + 81)) Kuparuk 1J Pad North Referrencd; True Plan 1 J-115 Survrey Calculation Method: Minimum Curvature Plan 1J-115 1 J-115 (wp05) 1 J-115 (wp05) 28.00 0.00 0.00 28.00 -81.00 0.00 1J-115 SHL @ 1973ft FSL & 2380ft FEL - Sec 35 - T11 N - R1 OE 100.00 0.00 0.00 100.00 -9.00 0.00 200.00 0.00 0.00 200.00 91.00 0.00 300.00 0.00 0.00 300.00 191.00 0.00 400.00 0.00 0.00 400.00 291.00 0.00 500.00 0.00 0.00 500.00 391.00 0.00 KOP @ 500ft MD, 500ft TVD - Build @ 2.5°/100ft 600.00 2.50 95.00 599.97 490.97 -0.19 700.00 5.00 95.00 699.75 590.75 -0.76 700.25 5.01 95.00 700.00 591.00 -0.76 Continue Build @ 4°/100ft , 700ft MD, 700ft TVD 800.00 9.00 95.00 798.98 689.98 -1.82 900.00 13.00 95.00 897.13 788.13 -3.48 1,000.00 17.00 95.00 993.70 884.70 -5.74 1,100.00 21.00 95.00 1,088.24 979.24 -8.57 1,200.00 25.00 95.00 1,180.27 1,071.27 -11.98 1,300.00 29.00 95.00 1,269.36 1,160.36 -15.93 1,400.00 33.00 95.00 1,355.06 1,246.06 -20.42 1,500.00 37.00 95.00 1,436.96 1,327.96 -25.42 1,580.68 40.22 95.00 1,500.00 1,391.00 -29.81 Base Perm Sail @ 40° Inc : 1581ft MD, 1500ft TVD 1,600.00 40.22 95.00 1,514.75 1,405.75 -30.89 1,600.33 40.22 95.00 1,515.00 1,406.00 -30.91 Base Perm 1,680.68 40.22 95.00 1,576.35 1,467.35 -35.44 Continue Build @ 5°/100ft , 1681ft MD, 1576ft TVD 1,700.00 41.19 95.00 1,591.00 1,482.00 -36.53 1,782.40 45.31 95.00 1,651.00 1,542.00 -41.45 T3 1,800.00 46.19 95.00 1,663.28 1,554.28 -42.55 1,900.00 51.19 95.00 1,729.27 1,620.27 -49.10 2,000.00 56.19 95.00 1,788.47 1,679.47 -56.12 2,100.00 61.19 95.00 1,840.42 1,731.42 -63.56 2,168.41 64.61 95.00 1,871.58 1,762.58 -68.87 Sail @ 64.6° Inc: 2168ft MD, 1872ft TVD 2,200.00 64.61 95.00 1,885.13 1,776.13 -71.36 2,300.00 64.61 95.00 1,928.01 1,819.01 -79.23 2,381.61 64.61 95.00 1,963.00 1,854.00 -85.65 K15 2,400.00 64.61 95.00 1,970.88 1,861.88 -87.10 2,500.00 64.61 95.00 2,013.76 1,904.76 -94.98 2,600.00 64.61 95.00 2,056.64 1,947.64 -102.85 2,700.00 64.61 95.00 2,099.52 1,990.52 -110.72 2,800.00 64.61 95.00 2,142.39 2,033.39 -118.60 2,900.00 64.61 95.00 2,185.27 2,076.27 -126.47 0.00 5,945,785.38 . 558,829.63 - 0.00 0.00 0.00 5,945,785.38 558,829.63 0.00 0.00 0.00 5,945,785.38 558,829.63 0.00 0.00 0.00 5,945,785.38 558,829.63 0.00 0.00 0.00 5,945,785.38 558,829.63 0.00 0.00 0.00 5,945,785.38 558,829.63 0.00 0.00 2.17 5,945,785.21 558,831.81 2.50 -0.19 8.69 5,945,784.69 558,838.32 2.50 -0.76 8.71 5,945,784.69 558,838.35 2.50 -0.76 20.82 5,945,783.72 558,850.46 4.00 -1.82 39.82 5,945,782.21 558,869.47 4.00 -3.48 65.59 5,945,780.16 558,895.26 4.00 -5.74 98.01 5,945,777.57 558,927.69 4.00 -8.57 136.92 5,945,774.47 558,966.63 4.00 -11.98 182.13 5,945,770.87 559,011.86 4.00 -15.93 233.42 5,945,766.78 559,063.18 4.00 -20.42 290.54 5,945,762.23 559,120.34 4.00 -25.42 340.70 5,945,758.24 559,170.52 4.00 -29.81 353.12 5,945,757.25 559,182.95 0.00 -30.89 353.33 5,945,757.23 559,183.16 0.00 -30.91 405.03 5,945,753.11 559,234.88 0.00 -35.44 417.58 5,945,752.11 559,247.44 5.00 -36.53 473.81 5,945,747.63 559,303.70 5.00 -41.45 486.37 5,945,746.63 559,316.27 5.00 -42.55 561.17 5,945,740.67 559,391.11 5.00 -49.10 641.42 5,945,734.28 559,471.41 5.00 -56.12 726.50 5,945,727.50 559,556.54 5.00 -63.56 787.17 5,945,722.67 559,617.23 5.00 -68.87 815.59 5,945,720.41 559,645.68 0.00 -71.36 905.59 5,945,713.24 559,735.73 0.00 -79.23 979.04 5,945,707.38 559,809.22 0.00 -85.65 995.59 5,945,706.07 559,825.77 0.00 -87.10 1,085.58 5,945,698.90 559,915.82 0.00 -94.98 1,175.58 5,945,691.73 560,005.87 0.00 -102.85 1,265.58 5,945,684.56 560,095.91 0.00 -110.72 1,355.58 5,945,677.39 560,185.96 0.00 -118.60 1,445.57 5,945,670.22 560,276.01 0.00 -126.47 611712006 11:16:19AM Page 4 of 10 COMPASS 2003.11 Build 50 ORIGINAL 0 0 V, Halliburton Energy Services IHp►�Lreii.�R-raEnr ConioCoPhiil s Planning Report -Geographic Alaska Spon'y Drilling Servies Database: EDM 2003.11 b48 Local Co=ordinate Reference: Well Plan 1 J-115 - Slot 1 J-115 ConocoPhillips Alaska Inc. TVD Roforert : � Plan RKB @ 109.00ft (Doyon 141 (28 + 81)) Project: Kuparuk River Unit MD Reference:, Plan RKB @ 109OOft (Doyon 141 (28 + 81)) Bites ; �Kuparuk 1J Pad "renca, True =,Plan 1J-115 Sun►cair Caicuiaton tlfietttbd Minimum Curvature Wetibore: `° Plan 1 J-115 Desigo: - ;1 J-115 (wp05) 1J-11�5 (wp05) _ eE:, 3,000.00 64.61 95.00 2,228.15 2,119.15 -134.35 1,535.57 5,945,663.05 560,366.06 0.00 -134.35 3,006.65 64.61 95.00 2,231.00 2,122.00 -134.87 1,541.56 5,945,662.57 560,372.04 0.00 -134.87 10 3/4" @ 3007 ft MD, 2231ft TVD -1838ft FSL & 839ft FEL - Sec 35 - T11 N - R10E - T3+550 -10 3/4" 3,100.00 64.61 95.00 2,271.03 2,162.03 -142.22 1,625.57 5,945,655.88 560,456.10 0.00 -142.22 3,200.00 64.61 95.00 2,313.91 2,204.91 -150.09 1,715.56 5,945,648.71 560,546.15 0.00 -150.09 3,300.00 64.61 95.00 2,356.78 2,247.78 -157.97 1,805.56 5,945,641.54 560,636.20 0.00 -157.97 3,400.00 64.61 95.00 2,399.66 2,290.66 -165.84 1,895.56 5,945,634.37 560,726.25 0.00 -165.84 3,500.00 64.61 95.00 2,442.54 2,333.54 -173.71 1,985.56 5,945,627.20 560,816.29 0.00 -173.71 3,600.00 64.61 95.00 2,485.42 2,376.42 -181.59 2,075.55 5,945,620.03 560,906.34 0.00 -181.59 3,700.00 64.61 95.00 2,528.29 2,419.29 -189.46 2,165.55 5,945,612.86 560,996.39 0.00 -189.46 3,800.00 64.61 95.00 2,571.17 2,462.17 -197.33 2,255.55 5,945,605.69 561,086.44 0.00 -197.33 3,900.00 64.61 95.00 2,614.05 2,505.05 -205.21 2,345.55 5,945,598.52 561,176.48 0.00 -205.21 3,968.41 64.61 95.00 2,643.38 2,534.38 -210.60 2,407.12 5,945,593.62 561,238.09 0.00 -210.60 Continue Turn @ 5°/100ft , 3968ft MD, 2643ft TVD 4,000.00 64.17 93.32 2,657.04 2,548.04 -212.66 2,435.52 5,945,591.77 561,266.51 5.00 -212.66 4,100.00 62.90 87.92 2,701.63 2,592.63 -213.65 2,524.99 5,945,591.49 561,355.97 5.00 -213.65 4,200.00 61.85 82.40 2,748.02 2,639.02 -206.19 2,613.23 5,945,599.63 561,444.14 5.00 -206.19 4,300.00 61.02 76.78 2,795.87 2,686.87 -190.35 2,699.56 5,945,616.15 561,530.33 5.00 -190.35 4,400.00 60.42 71.09 2,844.81 2,735.81 -166.24 2,783.33 5,945,640.90 561,613.90 5.00 -166.24 4,500.00 60.07 65.35 2,894.47 2,785.47 -134.05 2,863.90 5,945,673.72 561,694.22 5.00 -134.05 4,600.00 59.98 59.57 2,944.46 2,835.46 -94.03 2,940.66 5,945,714.34 561,770.65 5.00 -94.03 4,623.07 59.99 58.24 2,956.00 2,847.00 -83.71 2,957.76 5,945,724.79 561,787.67 5.00 -83.71 Ugnu C 4,700.00 60.13 53.81 2,994.41 2,885.41 -46.47 3,013.03 5,945,762.46 561,842.64 5.00 -46.47 4,800.00 60.53 48.07 3,043.94 2,934.94 8.26 3,080.44 5,945,817.71 561,909.62 5.00 8.26 4,900.00 61.18 42.39 3,092.67 2,983.67 69.74 3,142.40 5,945,879.66 561,971.09 5.00 69.74 5,000.00 62.06 36.80 3,140.23 3,031.23 137.51 3,198.43 5,945,947.86 562,026.58 5.00 137.51 5,100.00 63.16 31.30 3,186.26 3,077.26 211.05 3,248.10 5,946,021.78 562,075.67 5.00 211.05 5,121.67 63.43 30.13 3,196.00 3,087.00 227.69 3,257.99 5,946,038.50 562,085.43 5.00 227.69 Ugnu B 5,200.00 64.47 25.93 3,230.41 3,121.41 289.80 3,291.04 5,946,100.85 562,117.99 5.00 289.80 5,209.41 64.61 25.43 3,234.45 3,125.45 297.45 3,294.72 5,946,108.54 562,121.61 5.00 297.45 Begin Pump Tangent - Sail @ 64.6°, 5209ft MD, 3234ft TVD 5,300.00 64.61 25.43 3,273.30 3,164.30 371.37 3,329.85 5,946,182.71 562,156.16 0.00 371.37 5,378.58 64.61 25.43 3,307.00 3,198.00 435.48 3,360.33 5,946,247.06 562,186.14 0.00 435.48 Ugnu A 5,400.00 64.61 25.43 3,316.18 3,207.18 452.96 3,368.64 5,946,264.59 562,194.31 0.00 452.96 5,500.00 64.61 25.43 3,359.07 3,250.07 534.54 3,407.43 5,946,346.48 562,232.45 0.00 534.54 5,540.70 64.61 25.43 3,376.52 3,267.52 567.75 3,423.21 5,946,379.80 562,247.98 0.00 567.75 Continue Turn/Build @ 5°/100ft , 5541ft MD, 3377ft TVD 5,600.00 65.78 22.43 3,401.40 3,292.40 616.95 3,445.03 5,946,429.16 562,269.41 5.00 616.95 5,700.00 67.88 17.49 3,440.77 3,331.77 703.33 3,476.37 5,946,515.78 562,300.07 5.00 703.33 5,760.78 69.23 14.56 3,463.00 3,354.00 757.69 3,491.98 5,946,570.26 562,315.25 5.00 757.69 K13 5,800.00 70.12 12.70 3,476.63 3,367.63 793.43 3,500.64 5,946,606.06 562,323.63 5.00 793.43 5,900.00 72.49 8.06 3,508.69 3,399.69 886.58 3,517.68 5,946,699.33 562,339.93 5.00 886.58 611712006 11:16:19AM Page 5 of 10 COMPASS 2003.11 Build 50 ORIGINAL Halliburton Energy Services HALLIGURTON ConocoPhillips Planning Report - Geographic Aaska Sperry Drilling Services EDM 2003.11 b48 Local Co-(indfiiatwR ConocoPhillips Alaska Inc. TvD Reference: Kuparuk River Unit Kuparuk 1J Pad North I Reftrenc#�: Plan 1J-115 Survey ,Calculation I Plan 1J-115 1 J-1 15 (wp05) Well Plan I J-1 15 - Slot 1 J-1 15 Plan RKB @ 109.00ft (Doyon 141 (28 + 81)) Plan RK13 @ 109.00ft (Doyon 141 (28 + 81)) True Minimum Curvature i*Ianrred Sure 1 J-1 15 (wp05) map 16,clinatton Azlm, uth TM TVO +W-S +F Nofthlnq:-�' LSEV 04 6,000.00 74.97 3.53 3,536.72 3,427.72 982.05 3,527.33 5,946,794.86 562,348.85 5.00 982.05 6,079.61 77.00 0.00 3,556.00 3,447.00 1,059.24 3,529.70 5,946,872.06 562,350.61 5.00 1,059.24 Sail@ 77o Inc : 6080ft MD, 3556ftTVD 6,100.00 77.00 0.00 3,560.59 3,451.59 1,079.10 3,529.70 5,946,891.92 562,350.45 0.00 1,079.10 6,159.61 77.00 0.00 3,574.00 3,465.00 1,137.19 3,529.70 5,946,950.00 562,350.00 0.00 1,137.19 Continue Turn @ 4*/100ft, 6160ft MD, 3574ft TVD - WSAK D - 1J-115 T1 Dtop (wp05) 6,200.00 76.97 358.34 3,583.09 3,474.09 1,176.53 3,529.13 5,946,989.33 562,349.12 4.00 1,176.53 6,300.00 76.95 354.24 3,605.66 3,496.66 1,273.73 3,522.83 5,947,086.47 562,342.06 4.00 1,273.73 6,345.82 76.97 352.36 3,616.00 3,507.00 1,318.05 3,517.62 5,947,130.75 562,336.51 4.00 1,318.05 WSAK C 6,400.00 77.00 350.13 3,628.21 3,519.21 1,370.23 3,509.58 5,947,182.85 562,328.06 4.00 1,370.23 6,403.19 77.00 350.00 3,628.93 3,519.93 1,373.29 3,509.04 5,947,185.91 562,327.50 4.00 1,373.29 Sail @ 77'Inc & 350*Azi : 6403ft MD, 3629ft TVD 6,423.19 77.00 350.00 3,633.42 3,524.42 1,392.48 3,505.66 5,947,205.07 562,323.97 0.00 1,392.48 Continue Build @ V/1100ft, 6423ft MD, 3633ft TVD 6,498.19 80.00 350.00 3,648.38 3,539.38 1,464.85 3,492.90 5,947,277.33 562,310.64 4.00 1,464.85 Sall@ 80* Inc: 6498ft MD, 3648ftTVD -WSAK B-lJ-115T2Btop(wpO5) 6,500.00 80.00 350.00 3,648.69 3,539.69 1,466.60 3,492.59 5,947,279.08 562,310.32 0.00 1,466.60 6,600.00 80.00 350.00 3,666.05 3,557.05 1,563.59 3,475.49 5,947,375.92 562,292.46 0.00 1,563.59 6,700.00 80.00 350.00 3,683.42 3,574.42 1,660.57 3,458.39 5,947,472.76 562,274.61 0.00 1,660.57 6,737.90 80.00 350.00 3,690.00 3,581.00 1,697.33 3,451.91 5,947,509.46 562,267.84 0.00 1,697.33 A4 6,800.00 80.00 350.00 3,700.78 3,591.78 1,757.56 3,441.29 5,947,569.60 562,256.75 0.00 1,757.56 6,900.00 80.00 350.00 3,718.15 3,609.15 1,854.54 3,424.19 5,947,666.44 562,238.90 0.00 1,854.54 6,962.49 80.00 350.00 3,729.00 3,620.00 1,915.15 3,413.50 5,947,726.95 562,227.74 0.00 1,915.15 A3 7,000.00 80.00 350.00 3,735.51 3,626.51 1,951.53 3,407.08 5,947,763.28 562,221.04 0.00 1,951.53 7,100.00 80.00 350.00 3,752.88 3,643.88 2,048.51 3,389.98 5,947,860.12 562,203.18 0.00 2,048.51 7,200.00 80.00 350.00 3,770.24 3,661.24 2,145.50 3,372.88 5,947,956.95 562,185.33 0.00 2,145.50 7,300.00 80.00 350.00 3,787.61 3,678.61 2,242.48 3,355.78 5,948,053.79 562,167.47 0.00 2,242.48 7,333.19 80.00 350.00 3,793.37 3,684.37 2,274.67 3,350.11 5,948,085.94 562,161.54 0.00 2,274.67 Continue Build @ 4'/100ft, 7333ft MD, 3793ft TVD 7,400.00 82.67 350.00 3,803.43 3,694.43 2,339.71 3,338.64 5,948,150.87 562,149.57 4.00 2,339.71 7,458.19 85.00 350.00 3,809.68 3,700.68 2,396.68 3,328.59 5,948,207.76 562,139.08 4.00 2,396.68 Sail@ 85* Inc - 7468ft MD, 3810ftTVD -75/8"@ 7468ftMD, 3810ftTVD -4369ftFSL&4329ftFEL- Sec 36-TllN-RlOE-A2-75/8" 7,473.31 85.00 350.00 3,811.00 3,702.00 2,411.52 3,325.98 5,948,222.57 562,136.35 0.00 2,411.52 7,478.19 85.00 350.00 3,811.43 3,702.43 2,416.30 3,325.13 5,948,227.35 562,135.47 0.00 2,416.30 Continue Build @4*/100ft, 7478ftMD, 3811ftTVD 7,500.00 85.85 350.21 3,813.17 3,704.17 2,437.72 3,321.40 5,948,248.74 562,131.56 3.99 2,437.72 7,585.72 89.17 351.04 3,816.89 3,707.89 2,522.20 3,307.46 5,948,333.10 562,116.96 4.00 2,522.20 Sall @ 89* Inc : 7586ft MD, 3817ft TVD 7,600.00 89.17 351.04 3,817.10 3,708.10 2,536.31 3,305.23 5,948,347.19 562,114.63 0.00 2,536.31 ORIGINAL vr" Halliburton Energy Services HALLIBURT N ConocoPhillt 5 Planning Report - Geographic laSka Sperry Drilling Sere�ieses t5atetiase; _EDM_2003.11_b48 Lct Ctz-dtdinte i2efErtnce: Well Plan 1 J-115 -Slot 1 J-115 COM1104: ConocoPhillips Alaska Inc. Will Reference: Plan RKB @ 109.00ft (Doyon 141 (28 + 81')) Project: Kuparuk River Unit Mfl' Refers tce: Plan RKB @ 109.00ft (Doyon 141 (28 + 81)) Slte: ' Kuparuk 1J Pad Mortlt ieferehGe True Well: Plan 1J-115 survey Galculatwh Method: Minimum Curvature 1Nellbore: Plan 1J-115 i)esign: 1J-115 (wp05) Plaettskd Survey 1 J 115 (wp05) MA Inclination Azimuth Tvp ssTVD +All-S +E/.yy IVtarthi Eastlg t} REV YertSecttt . °> . tl (} {) (ft) �). ,;(ft i f{�ttft} 7,700.00 89.17 351.04 3,818.54 3,709.54 2,635.08 3,289.67 5,948,445.82 562,098.30 0.00 2,635.08 7,800.00 89.17 351.04 3,819.98 3,710.98 2,733.85 3,274.10 5,948,544.46 562,081.96 0.00 2,733.85 7,900.00 89.17 351.04 3,821.43 3,712.43 2,832.62 3,258.54 5,948,643.10 562,065.63 0.00 2,832.62 8,000.00 89.17 351.04 3,822.87 3,713.87 2,931.39 3,242.97 5,948,741.73 562,049.29 0.00 2,931.39 8,100.00 89.17 351.04 3,824.32 3,715.32 3,030.16 3,227.41 5,948,840.37 562,032.96 0.00 3,030.16 8,200.00 89.17 351.04 3,825.76 3,716.76 3,128.93 3,211.84 5,948,939.01 562,016.63 0.00 3,128.93 8,300.00 89.17 351.04 3,827.20 3,718.20 3,227.70 3,196.28 5,949,037.64 562,000.29 0.00 3,227.70 8,400.00 89.17 351.04 3,828.65 3,719.65 3,326.47 3,180.72 5,949,136.28 561,983.96 0.00 3,326.47 8,500.00 89.17 351.04 3,830.09 3,721.09 3,425.24 3,165.15 5,949,234.92 561,967.62 0.00 3,425.24 8,600.00 89.17 351.04 3,831.54 3,722.54 3,524.01 3,149.59 5,949,333.55 561,951.29 0.00 3,524.01 8,700.00 89.17 351.04 3,832.98 3,723.98 3,622.78 3,134.02 5,949,432.19 561,934.95 0.00 3,622.78 8,800.00 89.17 351.04 3,834.42 3,725.42 3,721.55 3,118.46 5,949,530.83 561,918.62 0.00 3,721.55 8,900.00 89.17 351.04 3,835.87 3,726.87 3,820.33 3,102.89 5,949,629.46 561,902.29 0.00 3,820.33 9,000.00 89.17 351.04 3,837.31 3,728.31 3,919.10 3,087.33 5,949,728.10 561,885.95 0.00 3,919.10 9,011.08 89.17 351.04 3,837.47 3,728.47 3,930.04 3,085.60 5,949,739.03 561,884.14 0.00 3,930.04 Continue Geosteering in Uppr Lober of A2-Sand, 9011ft MD, 3837ft TVD 9,100.00 89.52 354.58 3,838.49 3,729.49 4,018.24 3,074.48 5,949,827.13 561,872.33 4.00 4,018.24 9,200.00 89.91 358.56 3,838.98 3,729.98 4,118.04 3,068.51 5,949,926.87 561,865.58 4.00 4,118.04 9,222.22 90.00 359.45 3,839.00 3,730.00 4,140.26 3,068.13 5,949,949.09 561,865.02 4.01 4,140.26 9,300.00 90.00 359.45 3,839.00 3,730.00 4,218.03 3,067.38 5,950,026.84 561,863.67 0.00 4,218.03 9,400.00 90.00 359.45 3,839.00 3,730.00 4,318.03 3,066.42 5,950,126.82 561,861.93 0.00 4,318.03 9,500.00 90.00 359.45 3,839.00 3,730.00 4,418.02 3,065.46 5,950,226.79 561,860.19 0.00 4,418.02 9,568.22 90.00 359.45 3,839.00 3,730.00 4,486.24 3,064.80 5,950,295.00 561,859.00 0.00 4,486.24 1J-115 T4 (wp05) 9,585.88 89.50 359.63 3,839.08 3,730.08 4,503.90 3,064.66 5,950,312.65 561,858.72 3.00 4,503.90 9,600.00 89.50 359.63 3,839.20 3,730.20 4,518.02 3,064.57 5,950,326.77 561,858.52 0.00 4,518.02 9,700.00 89.50 359.63 3,840.07 3,731.07 4,618.01 3,063.93 5,950,426.75 561,857.09 0.00 4,618.01 9,800.00 89.50 359.63 3,840.94 3,731.94 4,718.01 3,063.28 5,950,526.72 561,855.67 0.00 4,718.01 9,900.00 89.50 359.63 3,841.81 3,732.81 4,818.00 3,062.64 5,950,626.70 561,854.24 0.00 4,818.00 10,000.00 89.50 359.63 3,842.68 3,733.68 4,918.00 3,061.99 5,950,726.68 561,852.81 0.00 4,918.00 10,100.00 89.50 359.63 3,843.55 3,734.55 5,017.99 3,061.35 5,950,826.65 561,851.39 0.00 5,017.99 10,200.00 89.50 359.63 3,844.41 3,735.41 5,117.98 3,060.70 5,950,926.63 561,849.96 0.00 5,117.98 10,267.39 89.50 359.63 3,845.00 3,736.00 5,185.37 3,060.27 5,950,994.00 561,849.00 0.00 5,185.37 1J-115 T5 (wp05) 10,274.52 89.30 359.57 3,845.07 3,736.07 5,192.50 3,060.22 5,951,001.13 561,848.89 3.00 5,192.50 10,300.00 89.30 359.57 3,845.39 3,736.39 5,217.98 3,060.02 5,951,026.60 561,848.50 0.00 5,217.98 10,400.00 89.30 359.57 3,846.61 3,737.61 5,317.97 3,059.27 5,951,126.57 561,846.97 0.00 5,317.97 10,500.00 89.30 359.57 3,847.84 3,738.84 5,417.96 3,058.52 5,951,226.55 561,845.44 0.00 5,417.96 10,600.00 89.30 359.57 3,849.07 3,740.07 5,517.95 3,057.77 5,951,326.52 561,843.90 0.00 5,517.95 10,700.00 89.30 359.57 3,850.29 3,741.29 5,617.94 3,057.01 5,951,426.49 561,842.37 0.00 5,617.94 10,800.00 89.30 359.57 3,851.52 3,742.52 5,717.93 3,056.26 5,951,526.46 561,840.83 0.00 5,717.93 10,900.00 89.30 359.57 3,852.75 3,743.75 5,817.92 3,055.51 5,951,626.43 561,839.30 0.00 5,817.92 11,000.00 89.30 359.57 3,853.98 3,744.98 5,917.91 3,054.75 5,951,726.40 561,837.77 0.00 5,917.91 11,100.00 89.30 359.57 3,855.20 3,746.20 6,017.89 3,054.00 5,951,826.37 561,836.23 0.00 6,017.89 11,200.00 89.30 359.57 3,856.43 3,747.43 6,117.88 3,053.25 5,951,926.34 561,834.70 0.00 6,117.88 11,236.69 89.30 359.57 3,856.88 3,747.88 6,154.57 3,052.97 5,951,963.02 561,834.13 0.00 6,154.57 11,267.79 90.23 359.57 3,857.01 3,748.01 6,185.66 3,052.74 5,951,994.11 561,833.66 3.00 6,185.66 11,300.00 90.23 359.57 3,856.88 3,747.88 6,217.88 3,052.50 5,952,026.32 561,833.16 0.00 6,217.88 11,400.00 90.23 359.57 3,856.48 3,747.48 6,317.87 3,051.75 5,952,126.30 561,831.63 0.00 6,317.87 611712006 11:16:19AM Page 7 of 10 COMPASS 2003.11 Build 50 ^21GINAL -` Halliburton Energy Services • ConocoPhilhps Planning Report - Geographic Alaska Database: EDM_2003.11 b48 Cornea r: ConocoPhillips Alaska Inc. Project Kuparuk River Unit site: Kuparuk 1J Pad Well: Plan 1 J-115 wellbo e: -, Plan 1 J-19 5 Deis: 1 J-115 (wp05) 1J-115(wp05) HALL IBURTON sporry Drilling services i1,co-ordinswReference: Well Plan 1J-115 Slot 1J-115 11,500.00 90.23 359.57 3,856.07 3,747.07 6,417.87 3,050.99 5,952,226.27 561,830.10 0.00 6,417.87 11,600.00 90.23 359.57 3,855.67 3,746.67 6,517.87 3,050.24 5,952,326.25 561,828.57 0.00 6,517.87 11,700.00 90.23 359.57 3,855.27 3,746.27 6,617.86 3,049.49 5,952,426.23 561,827.04 0.00 6,617.86 11,767.79 90.23 359.57 3,855.00 3,746.00 6,685.65 3,048.98 5,952,494.00 561,826.00 0.00 6,685.65 1J-115 T6 (wp05) 11,799.39 89.28 359.53 3,855.13 3,746.13 6,717.25 3,048.74 5,952,525.60 561,825.50 3.00 6,717.25 11,800.00 89.28 359.53 3,855.14 3,746.14 6,717.86 3,048.73 5,952,526.21 561,825.50 0.00 6,717.86 11,900.00 89.28 359.53 3,856.39 3,747.39 6,817.85 3,047.91 5,952,626.18 561,823.89 0.00 6,817.85 12,000.00 89.28 359.53 3,857.65 3,748.65 6,917.84 3,047.09 5,952,726.15 561,822.29 0.00 6,917.84 12,100.00 89.28 359.53 3,858.90 3,749.90 7,017.83 3,046.27 5,952,826.12 561,820.69 0.00 7,017.83 12,200.00 89.28 359.53 3,860.15 3,751.15 7,117.81 3,045.45 5,952,926.09 561,819.09 0.00 7,117.81 12,267.93 89.28 359.53 3,861.00 3,752.00 7,185.74 3,044.89 5,952,994.00 561,818.00 0.00 7,185.74 1J-115 T7 (wp05) 12,300.00 88.32 359.49 3,861.67 3,752.67 7,217.80 3,044.62 5,953,026.05 561,817.48 3.00 7,217.80 12,303.28 88.22 359.49 3,861.77 3,752.77 7,221.08 3,044.59 5,953,029.33 561,817.42 3.00 7,221.08 12,400.00 88.22 359.49 3,864.77 3,755.77 7,317.75 3,043.72 5,953,125.98 561,815.80 0.00 7,317.75 12,500.00 88.22 359.49 3,867.87 3,758.87 7,417.69 3,042.83 5,953,225.91 561,814.13 0.00 7,417.69 12,600.00 88.22 359.49 3,870.97 3,761.97 7,517.64 3,041.94 5,953,325.84 561,812.45 0.00 7,517.64 12,700.00 88.22 359.49 3,874.07 3,765.07 7,617.59 3,041.04 5,953,425.76 561,810.78 0.00 7,617.59 12,800.00 88.22 359.49 3,877.17 3,768.17 7,717.54 3,040.15 5,953,525.69 561,809.11 0.00 7,717.54 12,900.00 88.22 359.49 3,880.27 3,771.27 7,817.49 3,039.26 5,953,625.62 561,807.43 0.00 7,817.49 13,000.00 88.22 359.49 3,883.37 3,774.37 7,917.43 3,038.36 5,953,725.55 561,805.76 0.00 7,917.43 13,100.00 88.22 359.49 3,886.47 3,777.47 8,017.38 3,037.47 5,953,825.48 561,804.08 0.00 8,017.38 13,200.00 88.22 359.49 3,889.57 3,780.57 8,117.33 3,036.58 5,953,925.40 561,802.41 0.00 8,117.33 13,300.00 88.22 359.49 3,892.67 3,783.67 8,217.28 3,035.68 5,954,025.33 561,800.73 0.00 8,217.28 13,400.00 88.22 359.49 3,895.78 3,786.78 8,317.23 3,034.79 5,954,125.26 561,799.06 0.00 8,317.23 13,500.00 88.22 359.49 3,898.88 3,789.88 8,417.17 3,033.90 5,954,225.19 561,797.39 0.00 8,417.17 13,600.00 88.22 359.49 3,901.98 3,792.98 8,517.12 3,033.00 5,954,325.12 561,795.71 0.00 8,517.12 13,700.00 88.22 359.49 3,905.08 3,796.08 8,617.07 3,032.11 5,954,425.05 561,794.04 0.00 8,617.07 13,762.00 88.22 359.49 3,907.00 3,798.00 8,679.04 3,031.56 5,954,487.00 561,793.00 0.00 8,679.04 1J-115 BHL @ 13762ft MD, 3907ft TVD : 91ft FSL & 4620ft FEL -Sec 24 - T11 N - R10E - 41/211 -1J-115 T8 Toe (wp05) 611712006 11:16:19AM Page 8 of 10 COMPASS 2003.11 Build 50 Halliburton Energy Services HALLIBURTON Conoc©Phillips Planning Report - Geographic ----- DrilliAlaska Suss Database: EDM 2003.11_b48 compatty: ConocoPh llips Alaska Inc. Pe]ect: Kuparuk River Unit )tg Kuparuk 1J Pad Well; Plan 1J-115 Wellbore: Plan 1J-1`15 Design: 1J-115 (wp05) Sperry M Well Plan 1 J-115 - Slot 1 J-115 Plan RKB @ 109.00ft (Doyon 141 (28 + 81)) Plan RKB @ 109.00ft (Doyon 141 (28 + 81)) True Minimum Curvature _.._r_ 3,809.68 1J-115 T3 A2top (wp05) 2,396.68 3,328.59 5,948,207.76 562,139.08 - Point 3,907.00 1J-115 T8 Toe (wp05) 8,679.04 3,031.56 5,954,487.00 561,793.00 - Point 3,811.00 1J-115 DID Polygon (a) 95% (wp05) 2,602.17 3,392.23 5,948,413.72 562,201.10 - Polygon Point 1 -150.01 1.17 5,948,413.72 562,051.10 Point 2 -153.47 20.79 5,948,433.31 562,047.49 Point 3 -170.92 126.36 5,948,538.73 562,029.21 Point -357.28 1,332.32 5,949,743.08 561,833.46 Point -374.11 1,538.49 5,949,949.09 561,815.02 Point -377.43 1,884.47 5,950,295.00 561,809.00 Point 7 -377.57 1,902.12 5,950,312.65 561,808.72 Point 8 -381.96 2,583.59 5,950,994.00 561,799.00 Point 9 -382.02 2,590.72 5,951,001.13 561,798.89 Point 10 -389.25 3,552.79 5,951,963.02 561,784.14 Point 11 -389.49 3,583.89 5,951,994.11 561,783.66 Point 12 -393.25 4,083.87 5,952,494.00 561,776.00 Point 13 -393.49 4,115.48 5,952,525.60 561,775.51 Point 14 -397.34 4,583.96 5,952,994.00 561,768.00 Point 15 -397.79 4,622.09 5,953,032.12 561,767.25 Point 16 -420.68 6,077.34 5,954,487.00 561,733.00 Point 17 -320.67 6,076.55 5,954,487.00 561,833.00 Point 18 -297.78 4,621.31 5,953,032.12 561,867.25 Point 19 -297.33 4,583.18 5,952,994.00 561,868.00 Point 20 -293.48 4,114.69 5,952,525.60 561,875.51 Point 21 -293.24 4,083.09 5,952,494.00 561,876.00 Point22 -289.48 3,583.11 5,951,994.11 561,883.66 Point 23 -289.25 3,552.01 5,951,963.02 561,884.14 Point24 -282.01 2,589.94 5,951,001.13 561,898.89 Point 25 -281.96 2,582.81 5,950,994.00 561,899.00 Point26 -277.56 1,901.34 5,950,312.65 561,908.72 Point27 -277.42 1,883.69 5,950,295.00 561,909.00 Point 28 -274.10 1,537.71 5,949,949.09 561,915.02 Point29 -257.27 1,331.54 5,949,743.08 561,933.46 Point 30 -70.92 125.58 5,948,538.73 562,129.21 Point 31 -53.46 20.01 5,948,433.31 562,147.49 Point 32 -50.00 0.39 5,948,413.72 562,151.10 3,574.00 1J-115 T1 Dtop (wp05) 1,137.19 3,529.70 5,946,950.00 562,350.00 Point 3,861.00 1J-115 T7 (wp05) 7,185.74 3,044.89 5,952,994.00 561,818.00 Point 3,648.38 1J-115 T2 Btop (wp05) 1,464.85 3,492.90 5,947,277.33 562,310.64 Point 3,855.00 1J-115 T6 (wp05) 6,685.65 3,048.98 5,952,494.00 561,826.00 Point 3,845.00 1J-115 T5 (wp05) 5,185.37 3,060.27 5,950,994.00 561,849.00 Point 3,839.00 1J-115 T4 (wp05) 4,486.24 3,064.80 5,950,295.00 561,859.00 Point 611712006 11:16:19AM Page 9 of 10 COMPASS 2003.11 Build 50 h • • r: Halliburton Energy Services � �� IBURTON ConocoPIIl I s Planning Report - Geographic Sperry Drilling Services Da�t>ase: _EDM_2003.11_b48 Local Co-ordinate Reference: Well Plan 1J-1/5 Slot 1J-115 Dorriperiy: ConocoPhillips Alaska Inc. TYD t2ePerence: Plan RKB @ 109.00ft (Doyon 141 (2$ + 81)} Protect; Kuparuk River Unit MD.Reference: Plan RKB @ 109.00ft (Doyon 141 (28 + 81)) ; Site; Kuparuk 1 J Pad North Reference: True Werl. ` Plan 1 J-115 Survey Caicuiation Method; Minimum Curvature Welrbore: Plan 1 J-115 Design: 1J-115 (Wp05) Progn©sed Casing Points Measured Vertical`•; Casing Hole Depth Mpth Diameter Diameter: 3,006.65 2,231.00 10-3/4 13-1/2 7,458.19 3,809.68 7-5/8 9-7/8 13,761.99 3,907.00 4-1/2 6-3/4 Proghosed Formation Intersection Points Measured ferticar 1,600.33 40.22 95.00 1,515.00 -30.91 353.33 1,782.40 45.31 95.00 1,651.00 -41.45 473.81 2,381.61 64.61 95.00 1,963.00 -85.65 979.04 3,006.65 64.61 95.00 2,231.00 -134.87 1,541.55 4,623.07 59.99 58.24 2,956.00 -83.71 2,957.76 5,121.67 63.43 30.13 3,196.00 227.69 3,257.99 5,378.58 64.61 25.43 3,307.00 435.48 3,360.33 5,760.78 69.23 14.56 3,463.00 757.69 3,491.98 6,159.61 77.00 0.00 3,574.00 1,137.19 3,529.70 6,345.82 76.97 352.36 3,616.00 1,318.05 3,517.62 6,498.19 80.00 350.00 3,648.37 1,464.85 3,492.90 6,737.90 80.00 350.00 3,690.00 1,697.33 3,451.91 6,962.49 80.00 350.00 3,729.00 1,915.15 3,413.50 7,458.19 85.00 350.00 3,809.68 2,396.68 3,328.59 611712006 11:16:19AM Page 10 of 10 ORIGINAL Base Perm T3 K15 T3+550 Ugnu C Ugnu B Ugnu A K13 WSAK D WSAK C WSAK B A4 A3 A2 COMPASS 2003.11 Build 50 0 ConocoPhillips Alaska ConocoPhillips Alaska Inc. Kuparuk River Unit Kuparuk 1J Pad Plan 1J-115 Plan 1 J-115 Anticollision Report 17 June, 2006 • Sperry Drilling Services '?R!GINAL SURVEY PROGRAM Dwc:20Kb05-157W:00:00 Validated:Yes Version: Depth From Depth To Survey/Plan Tout 28.01) 800.00 IJ-I15(xp05) CB -GYRO -SS 8W.00 13762.00 IJ-115(ap05) MWD+IFR-AK-CAZSC 1 J-03 WSP-15 � o WSP-I NAD 27 ASP Zone 4: WELL DETAILS: Plan 1J-115 ConocoPhillips Alaska ANTI -COLLISION SETTINGS Ground Level: 81.00 Engineering Interpolation Method: MD Interval: 50Stations +N/-S +E/-W Northing Easting Latihude Longitude Slot Calculation Method: Minimum Curvature Depth Range From: 28.00 To 13762.00 0.00 0.00 5945785.38 558829.63 70'15'44.934N 149'31'27.882W 1J-115 Error System: ISCWSA Maximum Range:1573.39980334661 Scan Method: Tray. Cylinder North Reference: Plan: 1J-115 (wp05) Error Surface: Elliptical Conic Warning Method: Rules Based 0 1J-109 (wp05) 1J-111 (wp03) i 180 15-23 Pilot(wp01) Travelling Cylinder Azimuth (TFO+AZI)101 vs Centre to Centre Separation 175 f /inj REFERENCE INFORMATION Coordinate (N/E) Reference: Well Plan iJ-115 - Slot 1J-115, True North Vertical (TVD) Reference: Plan RKB @ 109.00ft (Doyon 141 (28+81)) Section (VS) Reference: Slot-1J-115(O.00N, O.00E) Measured Depth Reference: Plan RKB @ 109.00ft (Doyon 141 (28 + 81)) Calculation Method: Minimum Curvature 330 p02) 300 1 J-122 (wp02) 90 WSP-04 A240 30 rrAA,.Ww.= Sh. 60 - 30 180 From Colour To MD Travelling Cylinder Azimuth (TFO+AZI) 1°1 vs Centre to Centre Separation 115 Win] 28 250 SECTION DETAILS 250 500 Sec MD Inc Ai TVD +WS +E/-W DLeg TFace VSec Target 500 750 1 21.00 0.00 0.01 28.00 0.000.00 0.00 0.00 0.00 ' 2 So0.0o 0.00 0.00 500.00 0.00 0.00 0.00 0.00 0.00 750 '"" 1000 3 700.25 5.01 95.00 700.00 -0.76 8.71 2.50 95.00 -0.76 u,) 4 1580.68 40.22 95.00 1500.00 -29.81 340.70 4.00 0.00 -29.81 1000 1250 5 1680.68 40.22 95.00 1576.35 -35.44 405.03 0.00 0.00 -35.44 1250 1500 6 2168.41 64.61 95.00 1871.58 -68.87 787.17 5.00 0.00 -68.81 7 3968.41 64.61 95.00 2643.38 -210.60 2407.12 0.00 0.00 -210.60 1500 1750 8 5209.41 64.61 25.43 3234.45 297.45 3294.72 5.00 -106.59 297.46 1750 2000 9 6540.70 64.61 25.43 3376.52 567.75 3423.21 0.00 0.00 567.75 10 6079.61 77.00 0.00 3556.00 1019.24 3529.70 5.00 -67.40 1059.24 2000 2250 11 6159.61 77.00 0.00 3574.00 11,7.19 3529.70 0.00 0.00 1137.19 1J-1IS T1 Dtop (wp05) 2250 2500 12 6403.19 77.00 350.00 3628.93 1373.29 3509.04 4.00 268.87 1373.29 13 6423.19 77.00 350.00 3633.42 1392.48 3505.66 0.00 0.00 1392.48 2500 3000 14 6498.19 80.00 350.00 3648.38 1464.85 3492.90 4.00 0.00 1464.85 1 J-115 T2 Stop (wp05) 15 7333.19 80.00 350.00 3793.37 2274.67 3350-11 0.00 0.00 2274.67 3000 4000 i6 7458.19 85.00 350.00 3809.68 2396.68 3328.59 4.00 0.00 2396.68 1J-115 T3 A2top (wp05) 4000 5000 17 7478.19 85.00 350.00 3811A3 2416.30 3325.13 0.00 0.00 2416.30 18 7585.72 89.17 351.04 3816.89 2522.20 3307.46 4.00 14.07 2522.20 5000 6000 19 9011.08 89.17 351.04 3837.84 3930.04 3085.60 0.00 0.00 3930.04 6000 7000 20 :222.22 90.00 359.45 3839.00 4140.26 3068.13 4.00 84.42 4140.26 21 568.22 90.00 359.45 3839.00 4486.24 3064':0 0.00 0.00 4486.24 1J-115 T4 (wp05) 7000 8000 22 9585.88 89.50 359.63 3839.08 4503.90 3064' 6 3.00 160.10 4503,90 8000 9000 23 10267.39 89.50 359.63 3845.00 5185.37 3060'27 0.00 0.00 5185'37 1J-115 TS (wp05) 24 10274.52 89.30 359.57 3845.07 5192.50 3060.22 3.00 -163.23 5192,50 9000 1000 2511236.69 89.30 35 9.5 7 3856.88 6154.57 3052.97 0.00 0.00 6154.57 2611267.79 90.23 359.57 3857.01 6185.66 3052.74 3.00 0.09 6185.66 10000 14 27 11767.79 90.23 359.57 3855.00 6685.65 3048.98 0.00 0.00 6685.65 1J-115 T6 (wpO5) 28 11799.39 89.28 359.53 3855.13 6717.25 3048.74 3.00 -177.57 6717.25 29 12267.93 89.28 359.53 3861.00 7185.74 3044.59 0.00 0.00 7185.74 1J-115 77 (wp05) 30 12303.28 88.22 359.49 3861.77 7221.08 3044.59 3.00 -177.74 7221.08 31 13762.00 88.22 359.49 3907.00 8679.04 3031.56 0.00 0.00 8679.04 1J-115 T8 Toe (wp05) Halliburton Energy Services HALLISURTQN ConocoPhillips Anticollision Report Alaska Sperry Drilling Services Company: ConocoPhillips Alaska Inc. t Ewa# Co otdlnate Refen9nca:. " Well Plan 1 J-115 - Slot 1 J-115 Rrojec Kuparuk River Unit TV[# ReirDrence: Plan RK6 @ 109:00ft (Doyon 141 (28 + 81)) Reference site: Kuparuk 1 J Pad iv i"Reference: Plan RKB @ 109.00ft (Doyon 141 (28 + 81)) Site Error'. North Reference: True Refer+rrrce Welk ? Plan 1J-115 survey *8#ciu#at#oftNleUtod:' ".' Minimum Curvature We#i Error: O:OOft output ertoe a are at 2.00 sigma Reference Wellbohi " , Plan 1J-11b Database; EDM_2003.11_b48 Reference Design:" fifiset T o Reference: Reference Datum Filter type: GLOBAL FILTER APPLIED: All wellpaths within 200'+ 100/1000 of reference Interpolation Method: MD Interval 50.00ft Error Model: ISCWSA Depth Range: Unlimited Scan Method: Tray. Cylinder North Results Limited by: Maximum center -center distance of 1,573.40ft Error Surface: Elliptical Conic Warning Levels evaluated at: 0.00 Sigma iurvey Tool Program Date'0117/2006 From To (ft) po Survey 1We#lbotv) 'cool Name Descripilon 28.00 800.00 1 J-115 (wp05) (Plan 1 J-115) CB -GYRO -SS Camera based gyro single shot 800.00 13,762.00 1J-115 (wp05) (Plan 1J-115) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC CC - Min centre to center distance or covergent point, SF - min separation factor, ES - min ellipse separation 611712006 12:32:26PM Page 2 of 5 COMPASS 2003.11 Build 50 IGINAL 1 • • ♦.' Halliburton Energy Services HALLIBURTQN ConocoPhillips Anticollision Report Alaska Sperry Drilling Services company:, ConocoPhillips Alaska Inc. tacal CtT orcllaate Refietice: Well Plan 1J-115 - Slot 1 J-415 Kuparuk River Unit Plan RKB @ 109.00ft (Doyon 141 (28 + 81)) ,Reiarence trite: Kuparuk 1J Pad MD Reference: Plan RKB @ 109.00ft (Doyon 141 (28 + 81)) ifte•�rror O.00ft North Reference: True ReferencW eellx Plan 1J-115 $WveycalettlatiotTMethotl:'. Minimum Curvature AfgN error: O.00ft Outprit alrors are at ` !. 2.00 sigma Reference Wellbore , Plan 1J-115 Database. _EDM_2003.11_b48 Reference Design: Ofm*t Vw RefererMIK Reference Datum �itn►mary Kuparuk 1D Pad 1 D-36 - 1 D-36 - 1 D-36 1 D-36 - 1 D-36 - 1 D-36WP4(Baker) 1 D-36 - 1 D-361-1 - 1 D-36L1 1 D-36 - 1 D-361-2 - 1 D-361-2 1 D-38 - 1 D-38 - 1 D-38 1 D40 - 1 D-40 - 1 D-40 1 D-40 - 1 D-40A - 1 D-40A 13,727.00 7,650.00 580.51 13,748.80 7,100.00 1,117.03 13,751.59 7,100.00 1,120.17 Out of range Out of range Out of range Out of range 250.40 410.71 Pass - Major Risk 235.94 887.47 Pass - Major Risk 235.76 890.97 Pass - Major Risk CC - Min centre to center distance or covergent point, SF - min separation factor, ES - min ellipse separation 6/17/2006 12.3226PM Page 3 of 5 COMPASS 2003.11 Build 50 �0, R, I G I N A L b " Halliburton Energy Services HALLIBURTON ConoeoPhillips Anticollision Report Alaska Sperry Drilling Services ConocoPhillips Alaska Inc. Kuparuk River Unit Kuparuk 1J Pad 0.00ft Plan 1J-115-- 0 00ft Plan 1J-115 :a'-ordinste Reference: Well Plan 1 J-115 - Slot 1 J-115 rfarence: Plan RKB @ 109.00ft (Doyon 141 (28 + 81)) Terence: Plan RKB @ 109.00ft (Doyon 141 (28 + 81)) Zeference: True Calcalation Method; ` Minimum Curvature error* ste at 2.00 sigma ISe, EDM 2003.11_b48 WD Reference: Reference Datum Stmnary Reference offset Centre to No-Ga, , Afiow' We Measured Measured Cerdre Dista nce t tiean Wilarnnw ' Site dame Depth Depth distance (ft) wProrrt-Plan' �• 0ffsetWWeIt-,W411bore=Design . {1ti (ft) MY{tt1 Kuparuk 1J Pad 1 J-03 - 1 J-03 - 1 J-03 541.62 550.00 144.05 9.98 134.07 Pass - Major Risk 1 J-10 - 1 J-10 - 1 J-10 444.74 450.00 159.43 8.51 150.93 Pass - Major Risk 1 J-154 - 1 J-154 - 1 J-154 545.95 550.00 248.15 12.01 236.14 Pass - Major Risk 1J-154 - 1J-154 L1 - 1J-154 L1 545.95 550.00 248.15 12.01 236.14 Pass- Major Risk 1 J-154 - 1 J-154 L2 - 1 J-154 L2 545.95 550.00 248.15 12.01 236.14 Pass - Major Risk 1 J-159 - 1 J-159 - 1 J-159 592.68 600.00 173.16 13.05 160.11 Pass - Major Risk 1J-159 - 1J-159 L1 - 1J-159 L1 592.68 600.00 173.16 13.05 160.11 Pass - Major Risk 1J-159 - 1J-159 L1 PB1 - 1J-159 L1 PB1 592.68 600.00 173.16 13.05 160.11 Pass - Major Risk 1J-159 - 1J-159 L1 P132 - 1J-159 L1 P132 592.68 600.00 173.16 13.05 160.11 Pass - Major Risk 1 J-159 - 1 J-159 L2 - 1 J-159 L2 592.68 600.00 173.16 13.05 160.11 Pass - Major Risk 1J-159 - 1J-159 PB1 - 1J-159 PB1 592.68 600.00 173.16 13.05 160.11 Pass - Major Risk 1 J-164 - 1 J-164 - 1 J-164 594.41 600.00 148.40 12.96 135.45 Pass - Major Risk 1 J-164 - 1J-164 L1 - 1 J-164 L1 594.41 600.00 148.40 12.96 135.45 Pass - Major Risk 1 J-164 - 1 J-164 L2 - 1 J-164 L2 594.41 600.00 148.40 12.96 135.45 Pass - Major Risk 1J-164 - 1J-164 L2 P131 - 1J-164 L2 P131 594.41 600.00 148.40 12.96 135.45 Pass - Major Risk 1 J-166 - 1 J-166 - 1 J-166 547.53 550.00 157.82 12.03 145.79 Pass - Major Risk 1 J-166 - 1 J-166 L1 - 1 J-166 L1 547.53 550.00 157.82 12.03 145.79 Pass - Major Risk 1J-166 - 1J-166 L1 P131 - 1J-166 L1 P131 547.53 550.00 157.82 12.03 145.79 Pass - Major Risk 1 J-166 - 1 J-166 L2 - 1 J-166 L2 547.53 550.00 157.82 12.03 145.79 Pass - Major Risk 1J-166 - 1J-166 L2 P131 - 1J-166 L2 P61 547.53 550.00 157.82 12.03 145.79 Pass - Major Risk 1 J-168 - 1 J-168 - 1 J-168 299.98 300.00 179.09 6.55 172.54 Pass - Major Risk 1 J-168 - 1 J-168 L1 - 1 J-168 L1 299.98 300.00 179.09 6.55 172.54 Pass - Major Risk 1 J-168 - 1 J-168 L2 - 1 J-168 L2 299.98 300.00 179.09 6.55 172.54 Pass - Major Risk 1J-168 - 1J-168 L2 PB1 - 1J-168 L2 P61 299.98 300.00 179.09 6.55 172.54 Pass - Major Risk Plan 1 J-103 - 1 J-103 - 1 J-103 (wp03) - North Heel 399.97 400.00 260.95 8.66 252.29 Pass - Major Risk Plan 1 J-103 - 1 J-103 L1 - 1 J-103 L1 (wp03) - North Has 399.97 400.00 260.95 8.66 252.29 Pass - Major Risk Plan 1 J-103 - 1 J-103 L2 - 1 J-103 L2 (wp03) - North Hee 399.97 400.00 260.95 8.66 252.29 Pass - Major Risk Plan 1J-105 - Plan 1J-105 - 1J-105 (wp02) 499.89 500.00 221.51 10.84 210.68 Pass - Major Risk Plan 1 J-107 - Plan 1 J-107 - 1 J-107 (wp02) 597.43 600.00 181.49 13.00 168.50 Pass - Major Risk Plan 1 J-109 - Plan 1 J-109 - 1 J-109 (wp05) 536.91 550.00 120.75 11.82 108.93 Pass - Major Risk Plan 1J-111 - Plan 1J-111 - 1J-111 (wp03) 598.80 600.00 80.85 13.13 67.72 Pass - Major Risk Plan 1J-112 Kuparuk Prelim - 1J-12 E Lateral - 1J-12 635.70 650.00 61.29 13.83 47.47 Pass - Major Risk Plan 1J-112 Kuparuk Prelim - 1J-12 Pilot- 1J-12 Pilot 635.70 650.00 61.29 13.83 47.47 Pass - Major Risk Plan 1 J-112 Kuparuk Prelim - Plan 1 J-12 W Lateral 635.70 650.00 61.29 13.83 47.47 Pass - Major Risk Plan 1J-115 - Plan 1J-115 L1 - 1J-115 L1 (wp05) 6,499.97 6,499.97 0.00 0.60 -0.60 FAIL - No Errors Plan 1J-115 - Plan 1J-115 L2 - 1J-115 L2 (wp05) 6,199.98 6,200.00 1.29 0.60 0.69 Pass - No Errors Plan 1 J-118 - Plan 1 J-118 - 1 J-118 (wp02) 449.89 450.00 61.30 9.75 51.55 Pass - Major Risk Plan 1J-120 - Plan 1J-120 - 1J-120 (wp01) 450.99 450.00 100.55 8.98 91.57 Pass - Major Risk Plan 1J-122 - Plan 1J-122 - 1J-122 (wp02) 2,512.67 2,399.99 100.86 66.05 55.09 Pass - Major Risk Plan 1 J-123 Kuparuk Prelim - 1 J-23 E Let - 1 J-23 E Let 989.29 1,000.00 152.45 20.68 131.78 Pass - Major Risk Plan 1J-123 Kuparuk Prelim - 1J-23 Pilot - 1J-23 Pilot 989.29 1,000.00 152.45 20.68 131.78 Pass - Major Risk Plan 1J-123 Kuparuk Prelim - 1J-23 W Let - 1J-23 W La 989.29 1,000.00 152.45 20.68 131.78 Pass - Major Risk Plan 1J-124 - Plan 1J-124 - 1J-124 (wp01) BHI 387.79 400.00 181.87 8.39 173.48 Pass - Major Risk Plan 1J-127 - 1J-127 - 1J-127 1,241.84 1,250.00 194.29 25.04 169.29 Pass - Major Risk Plan 1J-127 - 1J-127 L1 - 1J-127 L1 Rig Surveys 1,241.84 1,250.00 194.29 25.04 169.29 Pass - Major Risk Plan 1J-127 - 1J-127 L1 P131 - 1J-127 L1 PB1 Rig Surve 1,241.84 1,250.00 194.29 25.04 169.29 Pass - Major Risk Plan 1J-127- 1J-127 P131 - 1J-127 P131 Rig Surveys 1,241.84 1,250.00 194.29 25.04 169.29 Pass- Major Risk Plan 1J-127 - 1J-127 PB2 - 1J-127 P132 Rig Surveys 1,241.84 1,250.00 194.29 25.04 169.29 Pass - Major Risk Plan 1 J-127 - Plan 1 J-127 L2 - 1 J-127 L2 (wp04) 1,193.06 1,200.00 199.77 23.96 175.81 Pass - Major Risk Plan 1J-127 - Plan 1 J-127 L2 - 1J-127 L2 Rig Surveys 1,241.84 1,250.00 194.29 25.04 169.29 Pass - Major Risk Plan 1J-130 - Plan 1J-130 - 1J-130 (wp02) 387.97 400.00 301.04 8.55 292.49 Pass - Major Risk Plan 1J-156 - 1J-156 - 1J-156 (wp05) 350.00 350.00 216.99 7.58 209.42 Pass - Major Risk CC - Min centre to center distance or covergent point, SF - min separation factor, ES - min ellipse separation 61171200612:32:26PM Page 4 of 5 COMPASS 2003.11 Build 50 • ConocoPhitlips Alaska ConocoPhillips Alaska Inc. Kuparuk River Unit Kuparuk 1J Pad 0.00ft Plan 1J-115 0.00ft Plan 1J-115 Halliburton Energy Services HALLIBURTON Anticollision Report Spent' Drilling Services Local Co-ordinate References Well Plan 1 J-115 -Slot 1 J-115 Tvl7 Reference; Plan RKB @ 109.00ft (Doyon 141 (28 + 81)) Mb Refer nce: Plan RKB @ 109.00ft (Doyon 141 (28 + 81)) #orth Reference; True $unle)t Calculation Method; Minimum Curvature Output actors are at 2.00 sigma Database; EDM 2003.11 b48 Offset `rVI7 Reference; Reference Datum Kuparuk 1.1 Pad Plan 1J-156 - 1J-156 L1 - 1J-156 L1 (wp05) 350.00 350.00 216.99 7.58 209.42 Pass - Major Risk Plan 1 J-156 - 1 J-156 L2 - 1 J-156 L2 (wp05) 350.00 350.00 216.99 7.58 209.42 Pass - Major Risk Plan 1 J-158 - 1 J-158 - 1 J-158 (wp03) 351.00 350.00 189.56 7.44 182.12 Pass - Major Risk Plan 1 J-160 - Plan 1 J-160 - 1 J-160 (wp01) BH I 299.99 300.00 167.47 6.49 160.98 Pass - Major Risk Plan 1J-162 - 1J-162 - 1 J-162 (wp03.1-North Heel) 300.99 300.00 148.40 6.35 142.05 Pass - Major Risk Plan 1J-162 - 1J-162 L1 - 1J-162 L1 (wp3.1) 300.99 300.00 148.40 6.25 142.15 Pass - Major Risk Plan 1 J-162 - 1 J-162 L2 - 1 J-162 L2 (wp3.1) 300.99 300.00 148.40 6.25 142.15 Pass - Major Risk Plan 1J-170 - 1J-170 - 1J-170 Rig Surveys 349.94 350.00 201.55 7.73 193.82 Pass - Major Risk Plan 1J-170 - 1 J-170 L1 - 1 J-170 L1 Rig Surveys 349.94 350.00 201.55 7.73 193.82 Pass - Major Risk Plan 1 J-170 - 1 J-170 L2 - 1 J-170 L2 (wp06) 349.94 350.00 201.55 7.73 193.82 Pass - Major Risk Plan 1 J-170 - 1 J-170 L2 - 1 J-170 L2 Rig Surveys 349.94 350.00 201.55 7.73 193.82 Pass - Major Risk Plan 1 J-170 - 1 J-170 P131 - 1 J-170 P61 349.94 350.00 201.55 7.73 193.82 Pass - Major Risk Plan 1 J-170 - 1 J-170 PB2 - 1J-170 PB2 Rig Surveys 349.94 350.00 201.55 7.73 193.82 Pass - Major Risk Plan 1 J-173 Kuparuk - 1J-73 E Lateral - 1 J-73 E Let 633.49 650.00 248.68 13.80 234.88 Pass - Major Risk Plan 1J-173 Kuparuk- 1J-73 Kuparuk- 1J-73 W Let 633.49 650.00 248.68 13.80 234.88 Pass - Major Risk Plan 1 J-173 Kuparuk - 1 J-73 Pilot - 1J-173 Pilot (wp 633.49 650.00 248.68 13.80 234.88 Pass - Major Risk WSP-02 - WSP-02 - WSP-02 790.59 800.00 102.87 16.67 86.20 Pass - Major Risk WSP-03 - WSP-03 - WSP-03 804.97 800.00 47.24 20.82 26.42 Pass - Major Risk WSP-04 - WSP-04 - WSP-04 844.60 850.00 11.90 4.71 7.20 Pass - Minor 1/10 WSP-05 - WSP-05 - WSP-05 991.35 1,000.00 68.62 26.49 42.13 Pass - Major Risk WSP-06 - WSP-06 - WSP-06 1,094.64 1,100.00 125.10 28.60 96.50 Pass - Major Risk WSP-07 - WSP-07 - WSP-07 1,097.99 1,100.00 179.44 32.16 147.28 Pass - Major Risk WSP-08 - WSP-08 - WSP-08 1,209.46 1,200.00 228.07 61.55 184.03 Pass - Major Risk WSP-09 - WSP-09 - WSP-09 1,250.05 1,250.00 292.80 30.58 262.22 Pass - Major Risk WSPA 1 - WSP-11 - WSPA 1 1,682.80 1,700.00 392.72 42.76 350.76 Pass - Major Risk WSP-15 - WSPA 5 - WSP-15 685.27 700.00 165.06 16.62 148.44 Pass - Major Risk WSP-1 S - WSP-1 S - WSP-1 S 784.48 800.00 228.56 30.51 200.02 Pass - Major Risk WSP-20 - WSP-20 - WSP-20 600.00 600.00 188.13 14.97 173.16 Pass - Major Risk CC - Min centre to center distance or covergent point, SF - min separation factor, ES - min ellipse separation 611712006 12.32,26PM Page 5 of 5 COMPASS 2003.11 Build 50 ConocoPhillips Alaska ConocoPhillips Alaska (Kuparuk) Kuparuk River Unit Kuparuk 1J Pad Plan 1J-115 - Slot 1J-115 Plan: 1J-115 (wp05) 1/4 Mile Scan 15 July, 2006 w Sperry Drilling Services 0 R Iro I NI A L Offset Well Min Dist in Pool ft to Ref well MD Min Dist Ref Well MD Min Dist in Pool 2717 4675 1 J-115 14020 1 D-06 1 D-36 1864 6226 - 1 J-115 14020 1D-38 1231 5975 1J-115 14020 1D-40 1176 6075 1J-115 __ 1J-115 14020 1D-42 2907 4775 14020 1 D-102 747 7378 = 1 J-115 14020 1 D-134 1526 5850 1 J-115 14020 1 D-137 1455 5350 ;, 1 J-115 14020 1 J-03 384 6900 1 J-115 7150 1J-127 1231 12325 11-115 14020 ** Red Wells Denote Violation of 1320' Distance while in the production interval Project: Kuparuk River Unit \ Site: Kuparuk 11.1 Pad Well: Plan 1J-115 Wellbore: Plan 1J-115 Plan: 1J-115 (wp05) 1 J-168 i J-166 10.10 CASING DETAILS 1D1 1J-170 1J-164 1D-13 1 D-42 No ND MD Name Size 1 2231.00 3006.65 10 3/4" 10-3/4 1J-10 1J-101 2 3809.68 7458.19 7 5/8" 7-5/8 - 1D-06 3 3907.0013761.99 4 1 /2" 4-1/2 1 J-09 1J-1151/4 Mile @ Toe (wp05) 1 D-40 1 J-127 WSP wells 1 D-36 1D-38 i e. 1J-156in 1J-152 ---- ____ progress 1J-154 1J-1151/4 Mile @ Heel (wp05) 10 3/4" 1J-03 1 J-159 WSAK 5 1J-102 to be drill d Existing or wells in progress which Aug 2006 1J-109 in violate the 1/4 mile radius progress 1J-184 surrounding planned 1J-115 production zone are; 1J-1a 1 D-38, 1 D-40, 1 D-102, 1 J-127 & 1 J-0 1J-133 IM to be drilled Aug 2006 O 10625 10000 1J-127 L2 -' 9375 - - - _ 1J-127 11-1 - 8750 1J-127 ------ `---------==1 1 I I 8125 1 D-42 j 7500 6875 1 D 42L1 6250 I I I 5625 I I I I I O u7 I N 1 5000 + 1 D-40A I t O I Z I 4375 � I I � N 1D-40 - - - -- I 1 3750 I I I 3125 I I I 1 1 2500 I I I I 1875 1 I I I 1 1250 I I 1 625 Project: Kuparuk River Unit Site: Kuparuk 1J Pad Well: Plan 1J-115 Wellbore: Plan 1J-115 1D-102 Plan: 1J-115 (wp05) _ 1 D-102L1 I I I 1J-1151/4 Mlle Toe (wp05 I 359" I 360' 360° 360° 360' 359° 351. 3W 350° ?S- I I I I 1 I I I I I ------_ 1D-38 I I 1 I I 1 I I I I 1 I 1 I I I T M Azimuthso True Nortr iJ-03 I I , I I I I I I I -- - - - - - - - -- - - - - - - - - ' 1J-115 1/4 Mlle @ Heel (wp05 Shown are Existing wells which violate the 1320' radius surrounding the 1 J-115 production Zone; 1 D-38,1 D-4 1 D-102, 1 J-127, 1 J-03 -1250 -625 0 625 1250 1875 2500 3125 3750 4375 5000 5625 6250 6875 7500 West( -)/East(+) (1250 ft/in) ConocoPhillips Alaska 1J-1154brilling Hazards SOnmary (SEE WELL PLAN AND ATTACHMENTS FOR DETAILED DISCUSSION OF THESE RISKS) 13-1/2" Open Hole / 10-3/4" Casing Interval Hazard Risk Level Mitigation Strategy Broach of Conductor Low Monitor cellar continuously during interval. Gas Hydrates Moderate , Control drill, Reduced pump rates, Reduced drilling fluid temperatures, Additions of Driltreat. Running Sands and Low Maintain planned mud parameters, Increase Gravels mud weight, use weighted sweeps. Hole swabbing on trips Moderate Trip speeds, proper hole filling (use of trip sheets), pumping out 9-7/8" Open Hole / 7-5/8" Casing Interval Hazard Risk Level Mitigation Strategy Running Sands and Low Maintain planned mud parameters, Increase Gravels mud weight, use weighted sweeps. Gas Hydrates Low Control drill, reduced pump rates, reduced ' drilling fluid temperatures, additions of Driltreat. Stuck Pipe Low Good hole cleaning, pre-treatment with lost circulation material, stabilized BHA, decreased mud weight Abnormal Reservoir Low BOP training and drills, increased mud weight. Pressure Lost circulation Low Reduced pump rates, mud rheology, LCM Hole swabbing on trips Moderate Trip speeds, proper hole filling (use of trip sheets), pumping out 6-3/4" Open Hole / 4-1/2" Liner Interval Hazard Risk Level Mitigation Strategy Abnormal Reservoir Low Stripping drills, shut-in drills, increased mud Pressure weight. Stuck Pipe Low Good hole cleaning, PWD tools, hole opener runs, decreased mud weight Lost Circulation Low Reduced pump rates, mud rheology, LCM Hole Swabbing on Trips Moderate Trip speeds, proper hole filling (use of trip sheets),pumping out, backreaming 1J-115 Drilling Hazards Summary ' + prepared by Shane Cloninger 511212006 1:08 PM Rig: Doyon 141 Location: West Sak Client: ConocoPhillips Alaska, Inc. Revision Date: 5/18/2006 Prepared by: Mike Martin Location: Anchorage, AK Phone: (907) 263-4207 Mobile: (907) 748-6900 email: martinl3@slb.com < TOC at Previous Csg. < 16", 62.6# casing at 80' MD < Base of Permafrost at 1,603' MD (1,517' TVD) < Top of Tail at 1,980' MD < 10 3/411, 45.5# casing in 13 1/2" OH TD at 2,780' MD (2,150' TVD) Mark of Schlumberger • schluffibugep CemCADE! Preliminary Job Design 10 3/ " Surface Sing Preliminary Job Design based on limited input data. For estimate purposes only. Volume Calculations and Cement Systems Volumes are based on 250% excess in the permafrost and 35% excess below the permafrost. The top of the tail slurry is designed to be at 1,980' MD. Lead Slurry Minimum pump time: 210 min. (pump time plus 90 min.) ARCTICSET Lite @ 10.7 ppg - 4.45 ft3/sk 0.6381 ft3/ft x (80') x 1.00 (no excess) = 51 ft3 0.3637 ft3/ft x (1603' - 80') x 3.50 (250% excess) = 1938.7 ft3 0.3637 ft3/ft x (1980' - 1603') x 1.35 (35% excess) = 185.1 ft3 51 ft3 + 1938.7 ft3+ 185.1 ft3 = 2174.8 ft3 2174.8 ft3 / 4.45 ft3/sk = 488.7 sks Round up to 490 sks Have 270 sks of additional Lead on location for Top Out stage, if necessary. Tail Slurry Minimum pump time: 150 min. (pump time plus 90 min.) DeepCRETE @ 12.0 ppg - 2.47 ft3/sk 0.3637 ft3/ft x (2780' - 1980') x 1.35 (35% excess) = 392.8 ft3 0.5400 ft3/ft x 80' (Shoe Joint) = 43.2 ft3 392.8 ft3 + 43.2 ft3 = 436 ft3 436 ft3/ 2.47 ft3/sk = 176.5 sks Round up to 180 sks BHST = 46°F, Estimated BHCT = 63°F. (BHST calculated using a gradient of 2.6°F/100 ft. below the permafrost) PUMP SCHEDULE Pump Rate Stage Stage Time Cumulative Stage (bpm) Volume (min) Time (bbl) (min) CW100 5.0 10.0 2.0 2.0 Pressure test lines 0.0 0.0 10.0 12.0 CW100 5.0 40.0 8.0 20.0 Drop botom plug 0.0 0.0 5.0 25.0 MUDPUSH II 6.0 50.0 8.3 33.3 ASL 7.0 397.7 56.8 90.1 DeepCRETE 6.0 77.7 12.9 103.0 Drop top plug 0.0 0.0 5.0 108.0 Water 5.0 20.0 4.0 112.0 Switch to rig 0.0 0.0 5.0 117.0 Mud 7.0 230.7 33.0 150.0 Slow & bump plug 3.0 9.0 3.0 153.0 MUD REMOVAL Recommended Mud Properties: 9.6 ppg, Pv < 15, Ty < 15. As thin and light as possible to aid in mud removal during cementing. Spacer Properties: 10.5 ppg MudPUSH" II, Pv ? 17-21, Ty ? 20-25 Centralizers: Recommend 2 per joint on the shoe track and 1 per joint thru the tail slurry cement column. Schlumbugep CemCADE*well cementing recommendation for 101/4" Surface Casing Operator : CPAI Well 1J-115 TL Country : USA Field West Sak State : Alaska Prepared for : Mike Greener Location 1J Pad Proposal No. : V1 (wp03) Service Point Prudhoe Bay Date Prepared : May 18, 2006 Business Phone (907) 659-2434 FAX No. (907) 659 -2538 Prepared by Phone E-Mail Address Mike Martin (907) 263-4207 martinl3gsib.com Disclaimer Notice: This information is presented in good faith, but no warranty is given by and Schlumberger assumes no liability for advice or recommendations made concerning results to be obtained from the use of any product or service. The results given are estimates based on calculations produced by a computer model including various assumptions on the well, reservoir and treatment. The results depend on input data provided by the Operator and estimates as to unknown data and can be no more accurate than the model, the assumptions and such input data. The information presented is Schlumberger's best estimate of the actual results that may be achieved and should be used for comparison purposes rather than absolute values. The quality of input data, and hence results, may be improved through the use of certain tests and procedures which Schlumberger can assist in selecting. The Operator has superior knowledge of the well, the reservoir, the field and conditions affecting them. If the Operator is aware of any conditions whereby a neighboring well or wells might be affected by the treatment proposed herein it is the Operator's responsibility to notify the owner or owners of the well or wells accordingly. Prices quoted are estimates only and are good for 30 days from the date of issue. Actual charges may vary depending upon time, equipment, and material ultimately required to perform these services. Freedom from infringement of patents of Schlumberger or others is not to be inferred. * Mark of Schlumberger • 0 Client CPAI Well 1J-115TL String 103/4Surface District Prudhoe Bay Country USA Loadcase 1075Surface Section 1: well description Configuration : Casing Stage : Single Rig Type : Land Mud Line : 0.0 ft Total MD : 2780.0 ft BHST : 46 degF Bit Size : 13 1/2 in ft Q G 0 0 co Well 0 P-Frost Sandstone T3 Sandstone K15 Sandstone TD Lithology 1j-115 cement.cfw ; 05-182006 ; LoadCase 1075 Surface ; Version wcs-cem45_89 Schlumberger (x 1000) psi L-5— 1.0 1.5 Formation Press. Page 2 ORIGINAL Client CPAI Well 1J-115 TL Stri ng 10 314 Surface District Prudhoe Bay Country USA Loadcase 1075 Surface Previous String MD OD Weight ID (ft) (in) (lb/ft) (in) 80.0 20 94.0 19.124 Landing Collar MD : 2700.0 ft Casing/liner Shoe MD : 2780.0 ft SI POOP Casing/Liner MD OD Joint Weight ID Grade Collapse Burst Thread (ft) (in) (ft) (Ib/ft) (in) (psi) (psi) 2780.0 10 3/4 40.0 45.5 9.950 M-65 2270 4230 STC Mean OH Diameter : 13.500 in Mean Annular Excess : 156.3 % Mean OH Equivalent Diameter: 16.925 in Total OH Volume : 751.4 bbl (including excess) Caliper and Hole Size Data MD Caliper Excess Equiv. Diann. (ft) (in) N (in) 1603.0 13.500 250.0 18.681 2780.0 13.500 35.0 14.338 Geothermal Temperature Profile MD TVD Temperature Gradient (ft) (ft) (degF) (degF/100ft) 0.0 0.0 25 0.0 1603.0 1517.0 29 0.3 2780.0 2149.6 46 1.0 Page 3 1j-115 cennent.cfw; 05-182006; LoadCase 1075 Surface; Version wcs-cem45_89 Client CPAI Well 1J-115 -115TL TL String 10 3/4 Surface District Prudhoe Bay Country USA Loadcase 1075 Surface Max. Deviation Angle : 63 deg Max. DLS : 5.023 deg/100ft MD (ft) Directional Survey TVD Deviation (ft) (deg) Data Azimuth (deg) Dogleg Sev. de /100ft) 0.0 0.0 0.0 0.0 0.000 100.0 100.0 0.0 0.0 0.000 200.0 200.0 0.0 0.0 0.000 300.0 300.0 0.0 0.0 0.000 400.0 400.0 0.0 0.0 0.000 500.0 500.0 0.0 0.0 0.000 600.0 600.0 2.5 95.0 -2.500 700.3 700.0 5.0 95.0 2.504 800.0 799.0 9.0 95.0 4.000 900.0 897.1 13.0 95.0 4.000 1000.0 993.7 17.0 95.0 4.000 1100.0 1088.2 21.0 95.0 4.000 1200.0 1180.3 25.0 95.0 4.000 1300.0 1269.3 29.0 95.0 4.000 1400.0 1355.0 33.0 95.0 4.000 1500.0 1436.9 37.0 95.0 4.000 1580.7 1500.0 40.2 95.0 3.991 1600.0 1514.7 40.2 95.0 0.000 1680.7 1576.3 40.2 95.0 0.000 1700.0 1591.0 41.2 95.0 5.023 1800.0 1663.3 46.2 95.0 5.000 1900.0 1729.2 51.2 95.0 5.000 2000.0 1788.4 56.2 95.0 5.000 2100.0 1840.4 61.2 95.0 5.000 2136.2 1857.3 63.0 95.0 4.997 2200.0 1886.3 63.0 95.0 0.000 2300.0 1931.7 63.0 95.0 0.000 2400.0 1977.1 63.0 95.0 0.000 2500.0 2022.5 63.0 95.0 0.000 2600.0 2067.9 63.0 95.0 0.000 2700.0 2113.3 63.0 95.0 0.000 2780.0 2149.6 63.0 95.0 0.000 Formation Data MD Frac. Pore Name Lithology (ft) (lb/gal) (lb/gal) 1603.0 12.50 8.20 P-Frost 1783.0 12.50 8.70 T3 Sandstone 2358.0 12.50 8.70 K15 Sandstone 2780.0 12.50 8.70 TD Sandstone Page 4 1j-115 cement.cfw; 05-182006 ; WadCase 1075 Surface; Version wcs-cem45_89 ORIGINAL • eCPAI Well Schlumilopp Well 1J-115TL String 103/4Surface District Prudhoe Bay Country USA Loadcase 1075Surface Section 2: centralizer placement Top of centralization :1980.0 ft Bottom Cent. MD :2770.0 ft Casing Shoe :2780.0 ft NB of Cent. Used :22 NB of Floating Cent. :0 Centralizer Placement Bottom MD Nbr. Cent. / Cent. Name Code Min. STO @ Depth (ft) Joint M (ft) 2700.0 18 1/1 S1104610-10 3/4-6-46 31.3 2000.0 (3/16")B 2780.0 4 2/1 S1104610-10 3/4-6-46 84.6 2710.0 (3/16")B Centralizer Description Centralizer Tests Cent. Name Code Casing Max. Min. OD Rigid Origin Hole Size Running Restoring OD OD (in) (in) Force Force (in) (in) (Ibf) (lbf) S1104610-10 3/4-6- 10 3/4 15.874 11.874 No Houma 13.500 708.15 1450.02 46 (3/16")B (1) - Centralizer performance data is based on tests by WEATHERFORD as per the current API 10D specifications Page 5 1j-115 cement.cfw ; 05-182006 ; LoadCase 1075 Surface: Version wcscem45_89 ORIGINAL • • Client CPAI Well 1J-115 TL String 10 3/4 Surface District Prudhoe Bay Country USA Loadcase 1075 Surface Section 3: fluid description Mud DESIGN Fluid No: 1 Density Mud Type : WBM Job volume CW100 DESIGN Fluid No: 2 Density Job volume MUDPUSH II DESIGN Fluid No: 3 Density Job volume Water Fluid No:4 Density Job volume ASL DESIGN Fluid No: 5 Density Rheo. Model : BINGHAM p1, At temp. : 65 degF Ty DESIGN BLEND SLURRY Name : G Mix Fluid : 20.722 gal/sk Dry Density : 199.77 Ib/ft3 Yield : 4.45 ft3/sk Sack Weight: 94 lb Porosity : 62.3 % BASE FLUID Type : Fresh water Density :8.32 lb/gal DeepCRETE DESIGN Fluid No: 6 Density Rheo. Model : BINGHAM p„ At temp. : 63 degF Ty DESIGN BLEND SLURRY Name : G Mix Fluid : 8.231 gal/sk Dry Density : 199.77 Ib/ft3 Yield : 2.47 ft3/sk Sack Weight: 94 lb Porosity : 44.5 % BASE FLUID Type : Fresh water Density : 8.32 lb/gal Additives Code Conic. Function D046 0.600 %BWOC ANTIFOAM B160 0.170 %BWOC Low Temp Dis D186 0.100 gal/sk blend ACCELERATOR shhlrler 9.60 lb/gal 239.7 bbl 8.32 lb/gal 50.0 bbl 10.50 lb/gal 50.0 bbl 8.32 lb/gal 20.0 bbl 10.70 lb/gal 28.660 cP 16.97 Ibf/100ft2 Job volume : 397.7 bbl Quantity : 502.35 sk Solid Fraction : 37.7 % Base Fluid : 20.153 gal/sk 12.00 lb/gal 105.064 cP 11.81 Ibf/100ft2 Job volume : 77.7 bbl Quantity : 176.48 sk Solid Fraction : 55.5 % Base Fluid : 8.131 gal/sk Page 6 1j-115 cement.cfw; 05-182006; LoadCase 1075 Surface; Version wcs-cem45_89 0 1 � R\ ! G- 11 1 Nt� 41 A I � � Client CPAI Well 1J-115 TL String 103/4Surface District Prudhoe Bay Country USA Loadcase 1075 Surface Section 4: fluid seauence sc I r er Pv : 15.000 cP Tv : 30.00 Ibf/100ft2 Displacement Volume 259.7 bbl Total Volume 835.1 bbl TOC 0.0 ft Name Volume (bbl) Ann. Len (ft) Top (ft) Fluid Sequence Density (lb/gal) Rheology CW100 50.0 0.0 8.32 viscosity: 5. 000 cP MUDPUSH II 50.0 0.0 10.50 Pv.23.000 cP Ty:30.00 Ibf/100ft2 ASL 397.7 1980.0 0.0 10.70 P%.28.660 cP Ty:16.97 Ibf/100ft2 DeepCRETE 77.7 800.0 1980.0 12.00 Pv.105.064 cP Ty:11.81 Ibf/100ft2 Water 20.0 2492.0 8.32 viscosity: 1. 000 cP Mud 239.7 0.0 9.60 Pv.15.000 cP Ty:30.00 Ibf/100ft2 Static Security Checks : Frac 7 psi at 80.0 ft Pore 10 psi at 80.0 ft Collapse 2042 psi at 2700.0 ft Burst 4230 psi at 0.0 ft Csg.Pump out 35 ton Section 5: pumping schedule Name Flow Rate (bbl/min) Volume (bbl) Pumping Schedule Stage Time Cum.Vol (min) (bbl). Inj. Temp. (degF) Comments CW100 5.0 10.0 2.0 10.0 80 Pause 0.0 0.0 10.0 0.0 80 Pressure test lines CW100 5.0 40.0 8.0 50.0 80 Pause 0.0 0.0 5.0 0.0 80 Drop bottom plug MUDPUSH II 6.0 50.0 8.3 50.0 80 ASL 7.0 397.7 56.8 397.7 80 DeepCRETE 6.0 77.7 12.9 77.7 80 Pause 0.0 0.0 5.0 0.0 80 Drop top plug Water 5.0 20.0 4.0 20.0 80 Pause 0.0 0.0 5.0 0.0 80 Switch to rig Mud 7.0 230.7 33.0 230.7 80 Mud 3.0 9.0 3.0 239.7 80 Slow & bump plug Total 02:33 835.1 bbl hr:mn Dynamic Security Checks: Frac 7 psi at 80.0 ft Pore 0 psi at 80.0 ft Collapse 2042 psi at 2700.0 ft Burst 4010 psi at 0.0 ft Page 7 1j-115 cemenccfw ; 05-182006 ; LoadCase 1075 Surface; Version wcscem45_89 i0l R, I G I N A L 0 Client CPAI Well 1J-115TL String 10 3/4 Surface District Prudhoe Bay Country USA Loadcase 1075 Surface ft o" O 0 0 N 1.M Fluid Sequence 00 Schiemherger lb/gal 8 12 16 --- Hydrostatic i �. Min. Hydrostatic �— Max. Dynamic y I 117 — Calc. VVHP I — — Min. Dynamic i N i ---• Frac — ---- _ _ __-_ ------ ----, - ��. Pore i 1 Q i i 1 1 1 � i I I i , 1 I i I i 1 1 .p..,.e....-«-p...«-.« - 1 i i l l E i i Q-t------_-• 0 _.-._.--_•--� 100 1 200 i i 4 E 1 1 E I Time (min) ' 1 De th = 2780 ft 0 __ Annular Velocity ,-------J i i i t 1 t p I 1 Oi i 1 1 I t > • ^I I/ i E I i i 1 i i ! 1 i i 1 C Q III .Irl i ii 1• 1 L E.�E__�___2__L-_!__E O4-La 0 ------------,1ui._.-.---.-.-•y 100 200 Dynamic Well Security Time (min) 0 20 40 bu au Iv. Time (min) Fluids at 2780 ft ........ .................... --- ---•---; _ _--, _._._ '- � -•---• o o I,1 I , I r i Ir� .Iti t I 1 1 t I T I A ! ! tl I 1 I 'II 7 a1i --------------- 1 •-----------r------- _. r - - - - r------ -----1- Y---•-•- -- --�'- -- - - - - i 0 20 40 60 80 100 120 140 160 Time (min) ray 1j-115 cementcfw ; 05-162006 ; LoadCase 1075 Surface ; Version wcs-cem45-69 ORIGINAL Client CPAI Well 1J-115TL String 103/4Surface District Prudhoe Bay Country USA Loadcase 1075 Surface 1j-115 cement.cfw; 05-182006 ; LoadCase 1075 Surface; Version wcs-cem45_89 Page 9 Rig: Doyon 141 Location: West Sak Client: ConocoPhillips Alaska, Inc. Revision Date: 5/18/2006 Prepared by: Mike Martin Location: Anchorage, AK Phone: (907) 263A207 Mobile: (907) 748-6900 email: martinl3@slb.com Previous Csg. < 10 3/4", 45.5# casing at 2,780' MD < Top of Tail at 4,000' MD < 7 5/8", 29.7# casing in 9 7/8" OH TD at 7,607' MD (3,811' TVD) • Schlumbeillgep CemCA®E Prelimma ,tob Design I, 7-5/8r I nterm edi6tk Casing Preliminary Job Design based on limited input data. For estimate purposes only. Volume Calculations and Cement Systems Volumes are based on 25% excess. Tail slurry is designed for 500' MD above Ugnu C - (3607' MD annular length). Tail Slurry Minimum thickening time: 190 min. (Pump time plus 90 min.) DeepCRETE @ 12.5 ppg - 2.25 ft3/ft 0.2148 ft3/ft x 3607' x 1.25 (25% excess) = 968.5 ft3 0.2578 ft3/ft x 80' (Shoe Joint) = 20.6 ft3 968.5 ft3 + 20.6 ft3 = 989.1 ft3 989.1 ft3/ 2.25 ft3/sk = 439.6 sks Round up to "0 sks BHST = 90°F, Estimated BHCT = 76°F. (BHST calculated using a gradient of 2.6°F/100 ft. below the permafrost) PUMP SCHEDULE Pump Rate Stage Stage Time Cumulative Stage (bpm) Volume (min) Time (bbl) (min) CW100 5.0 10.0 2.0 2.0 Pressure test lines 0.0 0.0 10.0 12.0 CW100 5.0 65.0 13.0 25.0 Drop bottom plug 0.0 0.0 5.0 30.0 MUDPUSH II 5.0 75.0 15.0 45.0 DeepCRETE 5.0 176.1 35.2 80.2 Drop top plug 0.0 0.0 5.0 85.2 Water 5.0 20.0 4.0 89.2 Switch to rig 0.0 1 0.0 5.0 94.2 Mud 6.0 316.6 1 52.8 147.0 Slow & bump plug 3.0 9.0 1 3.0 150.0 MUD REMOVAL Recommended Mud Properties: 8.9 ppg, Pv < 15, Ty < 15. As thin and light as possible to aid in mud removal during cementing. Spacer Properties: 11.0 ppg MudPUSH" II, Pv ? 19-22, Ty ? 22-29 Centralizers: Recommend 2 Tandem Rise Centraliziers per joint on the shoe track and 1 Tandem Rise Centralizer per joint across the West Sak and the Ugnu formations. gg `gF�` Al�; schlumbugep CemCADE*well cementing recommendation for 7-5/8" Intermediate Casing Operator : CPAI Well 1J-115 TLP Country : USA Field West Sak State : Alaska Prepared for : Mike Greener Location Proposal No. : V1 (WP03) Service Point Prudhoe Bay Date Prepared : May 18, 2006 Business Phone (907) 659-2434 FAX No. (907) 659 -2538 Prepared by Phone E-Mail Address Mike Martin (907) 263-4207 martinl39slb.com Disclaimer Notice: This information is presented in good faith, but no warranty is given by and Schlumberger assumes no liability for advice or recommendations made concerning results to be obtained from the use of any product or service. The results given are estimates based on calculations produced by a computer model including various assumptions on the well, reservoir and treatment. The results depend on input data provided by the Operator and estimates as to unknown data and can be no more accurate than the model, the assumptions and such input data. The information presented is Schlumberger's best estimate of the actual results that may be achieved and should be used for comparison purposes rather than absolute values. The quality of input data, and hence results, may be improved through the use of certain tests and procedures which Schlumberger can assist in selecting. The Operator has superior knowledge of the well, the reservoir, the field and conditions affecting them. If the Operator is aware of any conditions whereby a neighboring well or wells might be affected by the treatment proposed herein it is the Operator's responsibility to notify the owner or owners of the well or wells accordingly. Prices quoted are estimates only and are good for 30 days from the date of issue. Actual charges may vary depending upon time, equipment, and material ultimately required to perform these services. Freedom from infringement of patents of Schlumberger or others is not to be inferred. Mark of Schlumberger C'Ri IG INA Client CPAI Well 1J-115 TLP String 7-5/8 Intermediate District Prudhoe Bay Country USA Loadcase 758Intermediate Section 1: well description Configuration : Casing Stage : Single Rig Type : Land Mud Line : 0.0 ft Total MD : 7607.0 ft BHST : 89 degF Bit Size : 9 718 in ft 0 0 o- rn 0 0 o' to 0 0 o' 1-- CD 0 0 OD Schlumbergcr (x 1000) psi Well Lithology Formation Press. 1j-115 TLP cement.cfw ; 05-182006 ; LoadCase 758 Intermediate; Version wcs-cem45_89 Page 2 ORIGINAL Client CPAI sc I r er Well 1J-115 TLP String 7-5/8 Intermediate District Prudhoe Bay Country USA Loadcase 758Intermediate Previous String MD OD Weight ID (ft) (in) (lb/ft) (in) 2780.0 10 3/4 45.5 9.950 Landing Collar MD : 7527.0 ft Casing/liner Shoe MD : 7607.0 ft Casing/Liner MD OD Joint Weight ID Grade Collapse Burst Thread (ft) (in) (ft) (lb/ft) (in) (psi) (psi) 7607.0 7 5/8 40.0 29.7 6.875 L-80 4790 6890 BTC MD (ft) Frac. (lb/gal) Formation Data Pore Name (lb/gal) Lithology 4513.0 12.50 8.20 Ugnu C Sandstone 5159.0 12.50 8.20 Ugnu B Sandstone 5357.0 12.50 8.20 Ugnu A Sandstone 5500.0 12.50 8.40 K-13 6131.0 12.50 8.40 West Sak D Sandstone 6399.0 12.50 8.40 West Sak C Sandstone 6578.0 12.50 8.40 West Sak B Sandstone 6800.0 12.50 8.40 West Sak A4 Sandstone 7062.0 12.50 8.40 West Sak A3 Sandstone 7607.0 12.50 8.40 West Sak A2 Sandstone Geothermal Temperature Profile MD TVD Temperature Gradient (ft) (ft) (degF) (degF/100ft) 0.0 0.0 25 0.0 1603.0 1517.4 30 0.3 2780.0 2149.6 46 1.0 4513.0 2948.7 67 1.4 6100.0 3537.7 82 1.6 7607.0 3810.8 89 1.7 Page 3 1j-115 TLP cement.ctw; 05-182006 ; LoadCase 758 Intermediate; Version wcs-cem45_89 wqI� Client CPAI Well 1J-115 TLP String 7 - 5/8 1 ntermed iate District Prudhoe Bay Country USA Loadcase 758Intermediate sc I rger Mean OH Diameter : 9.875 in Mean Annular Excess : 25.0 % Mean OH Equivalent Diameter: 10.361 in Total OH Volume : 503.4 bbl (including excess) Max. Deviation Angle : 85 deg Max. DLS : 5.027 deg/100ft MD (ft) Directional Survey Data TVD Deviation Azimuth (ft) (deg) (deg) Dogleg Sev. (deg/100ft) 0.0 0.0 0.0 0.0 0.000 100.0 100.0 0.0 0.0 0.000 200.0 200.0 0.0 0.0 0.000 300.0 300.0 0.0 0.0 0.000 400.0 400.0 0.0 0.0 0.000 500.0 500.0 0.0 0.0 0.000 600.0 600.0 2.5 95.0 -2.500 700.3 700.0 5.0 95.0 2.504 800.0 799.0 9.0 95.0 4.000 900.0 897.1 13.0 95.0 4.000 1000.0 993.7 17.0 95.0 4.000 1100.0 1088.2 21.0 95.0 4.000 1200.0 1180.3 25.0 95.0 4.000 1300.0 1269.3 29.0 95.0 4.000 1400.0 1355.0 33.0 95.0 4.000 1500.0 1436.9 37.0 95.0 4.000 1580.7 1500.0 40.2 95.0 3.991 1600.0 1514.7 40.2 95.0 0.000 1680.7 1576.3 40.2 95.0 0.000 1700.0 1591.0 41.2 95.0 5.023 1800.0 1663.3 46.2 95.0 5.000 1900.0 1729.2 51.2 95.0 5.000 2000.0 1788.4 56.2 95.0 5.000 2100.0 1840.4 61.2 95.0 5.000 2136.2 1857.3 63.0 95.0 4.997 2200.0 1886.3 63.0 95.0 0.000 2300.0 1931.7 63.0 95.0 0.000 2400.0 1977.1 63.0 95.0 0.000 2500.0 2022.5 63.0 95.0 0.000 2600.0 2067.9 63.0 95.0 0.000 2700.0 2113.3 63.0 95.0 0.000 2780.8 2150.0 63.0 95.0 0.000 2800.0 2158.7 63.0 95.0 0.000 2900.0 2204.1 63.0 95.0 0.000 3000.0 2249.5 63.0 95.0 0.000 3100.0 2294.9 63.0 95.0 0.000 3200.0 2340.3 63.0 95.0 0.000 3300.0 2385.7 63.0 95.0 0.000 3400.0 2431.1 63.0 95.0 0.000 3500.0 2476.5 63.0 95.0 0.000 3600.0 2521.9 63.0 95.0 0.000 3700.0 2567.3 63.0 95.0 0.000 3800.0 2612.7 63.0 95.0 0.000 3886.2 2651.8 63.0 95.0 0.000 3900.0 2658.1 62.9 94.2 -4.992 4000.0 2704.3 62.1 88.7 -5.006 4100.0 2751.4 61.6 83.0 -4.992 Page 4 ij-115 TLP cement.cfw ; 05-182006 ; LoadCase 758 Intermediate; Version wcs-cem45_89 R ,9 ,>< Client CPAI Well 1J-115 TLP String 7-5/8 Intermediate District Prudhoe Bay Country USA Loadcase 758Intermediate Ypa MD (ft) Directional Survey Data ND Deviation Azimuth (ft) (de) (deg) Dogleg Sev. (deg/1 00ft) 4200.0 2799.2 61.3 77.3 -5.006 4300.0 2847.2 61.3 71.6 -5.000 4400.0 2895.1 61.5 65.9 4.998 4500.0 2942.5 61.9 60.3 5.000 4600.0 2989.1 62.5 54.7 4.998 4700.0 3034.6 63.4 49.2 5.004 4800.0 3078.4 64.5 43.7 4.997 4881.1 3112.7 65.5 39.4 5.002 4900.0 3120.5 65.5 39.4 -0.000 5000.0 3161.9 65.5 39.4 0.000 5100.0 3203.3 65.5 39.4 0.000 5200.0 3244.7 65.5 39.4 0.000 5237.6 3260.3 65.5 39.4 0.000 5300.0 3285.8 66.1 36.0 4.999 5400.0 3325.5 67.2 30.7 4.997 5500.0 3363.3 68.4 25.5 5.007 5600.0 3399.0 69.8 20.3 4.999 5700.0 3432.2 71.3 15.3 4.996 5800.0 3462.8 73.0 10.4 5.003 5900.0 3490.5 74.8 5.5 5.001 6000.0 3515.1 76.7 0.7 4.994 6015.1 3518.6 77.0 0.0 5.027 6095.1 3536.6 77.0 0.0 0.000 6100.0 3537.7 77.0 359.8 4.035 6121.8 3542.6 77.0 358.9 -3.973 6200.0 3560.2 76.9 355.7 -4.001 6300.0 3582.8 77.0 351.6 4.004 6338.7 3591.5 77.0 350.0 3.998 6388.7 3602.8 77.0 350.0 0.000 6400.0 3605.2 77.4 350.0 4.003 6463.7 3617.7 80.0 350.0 3.999 6500.0 3624.0 80.0 350.0 0.000 6600.0 3641.4 80.0 350.0 0.000 6700.0 3658.7 80.0 350.0 0.000 6800.0 3676.1 80.0 350.0 0.000 6900.0 3693.5 80.0 350.0 0.000 7000.0 3710.8 80.0 350.0 0.000 7100.0 3728.2 80.0 350.0 0.000 7200.0 3745.6 80.0 350.0 0.000 7300.0 3762.9 80.0 350.0 0.000 7349.9 3771.6 80.0 350.0 0.000 7400.0 3780.3 80.0 350.0 0.000 7401.7 3780.6 80.0 350.0 0.000 7481.7 3794.5 80.0 350.0 0.000 7500.0 3797.5 80.7 350.0 4.002 7607.0 3810.8 85.0 350.0 3.990 1j-115 TLP cement.cfw ; 05-182006; LoadCase 758 Intermediate; Version wcs-cem45_89 Page 5 • Client CPAI Well 1 J-115 TLP String 7-5/8 Intermediate District Prudhoe Bay Country USA Loadcase 758Intermediate Section 2: centralizer placement Top of centralization :4300.0 ft Bottom Cent. MD :7597.0 ft Casing Shoe :7607.0 ft NB of Cent. Used :74 NB of Floating Cent. :0 Schlemherger Centralizer Placement Bottom MD Nbr. Cent. / Cent. Name Code Min. STO @ Depth (ft) Joint N (ft) 5527.0 30 1/1 7-5/8 TR 76TR 0.0 5509.7 5927.0 0 0/0 0.0 5527.0 7527.0 40 1/1 7-5/8 TR 76TR 0.0 5944.3 7607.0 4 2/1 7-5/8 TR 76TR 92.7 7607.0 Centralizer Description Centralizer Tests Cent. Name Code Casing Max. Min. OD Rigid Origin Hole Size Running Restoring OD OD (in) (in) Force Force (in) (in) (Ilo) (Ibfl 7-5/8 TR 76TR 7 5/8 10.500 9.000 No Weatherford (1) 9.875 375.00 3168.00 (1) - Centralizer performance data is based on tests by WEATHERFORD as per the current API 10D specifications Page 6 1j-115 TLP cement.cfw; 05-182006; LoadCase 758 Intermediate; Version wcs-cem45_89 ORIGINAL Client CPAI Well 1 J -115 TLP String 7-5/8 Intermediate District Prudhoe Bay Country USA Loadcase 758Intermediate Section 3: fluid description Mud DESIGN Fluid No: 1 Density : 8.90 lb/gal Mud Type : WBM Job volume : 325.6 bbl CW100 DESIGN Fluid No: 2 Density : 8.32 lb/gal Job volume : 75.0 bbl MUDPUSH II DESIGN Fluid No: 3 Density : 11.00 lb/gal Job volume : 75.0 bbl SG1 r r DeepCRETE DESIGN Fluid No:4 Density : 12.50 lb/gal Rheo. Model : HERSCHEL_B. k : 8.69E-31bf.s^n/ft2 At temp. :80degF n :0.833 Ty :0.00lbf/100ft2 Gel Strength : (Ibf/100ft2) DESIGN BLEND SLURRY Name : G Mix Fluid : 7.558 gal/sk Dry Density : 199.77 Ib/ft3 Yield : 2.25 ft3/sk Sack Weight : 94 Ib Porosity : 44.9 % BASE FLUID Type : Fresh water Density : 8.32 lb/gal Additives Code Conc. Function D046 0.600 %BWOC ANTIFOAM B160 0.600 %BWOC Low Temp Dis D167 0.300 %BWOC FLUID LOSS D 186 0.140 gal/sk blend ACCELERATOR Fluid No: 5 Water Job volume : 176.1 bbl Quantity : 439.48 sk Solid Fraction : 55.1 % Base Fluid : 7.418 gal/sk Density :8.33lb/gal Job volume : 20.0 bbl 1j-115 TLP cement.dw; 05-182006; LoadCase 758 Intermediate; Version wcscem45_89 Page 7 ORIGINAL 0 Client CPAI Well 1J-115 TLP String 7-5/8 Intermediate District Prudhoe Bay Country USA Loadcase 758Intermediate schinkpoep Section 4: fluid sequence Original fluid Mud 8.90 lb/gal k : 1.13E-2 Ibf.s^n/ft2 n : 0.517 Tv : 6.47 Ibf/100ft2 Displacement Volume 345.6 bbl Total Volume 671.7 bbl TOC 4000.0 ft Fluid Sequence Name Volume Ann. Len Top Density Rheology (bbl) (ft) (ft) (lb/gal) CW100 75.0 1889.4 470.6 8.32 k:6.68E-31bf.s^n/ft2 n:0.177 Tv:0.00lbf/100ft2 MUDPUSH II 75.0 1639.9 2360.1 11.00 k:8.59E-2 Ibf.s^n/ft2 n:0.279 TY:11.82 Ibf/100ft2 DeepCRETE 176.1 3607.0 4000.0 12.50 k:8.69E-31bf.s^n/ft2 n:0.833 Tv:0.001bf/100ft2 Water 20.0 7091.4 8.33 k:6.94E-31bf.s^n/ft2 n:0.281 Tv:0.071bf/100ft2 Mud 325.6 0.0 8.90 k:1.13E-2lbf.s^n/ft2 n:0.517 Tv:6.471bf/100ft2 Static Security Checks : Frac 426 psi at 2780.0 ft Pore 54 psi at 2780.0 ft Collapse 4374 psi at 7527.0 ft Burst 6845 psi at 2360.1 ft Cs .Pump out 44 ton Section 5: pumping schedule Name Flow Rate (bbl/min) Volume (bbl) Pumping Schedule Stage Time Cum.Vol (min) (bbl). Inj. Temp. (degF) Comments CW100 5.0 10.0 2.0 10.0 80 Pause 0.0 0.0 10.0 0.0 80 Pressure test lines CW100 5.0 65.0 13.0 75.0 80 Pause 0.0 0.0 5.0 0.0 80 Drop bottom plug MUDPUSH II 5.0 75.0 15.0 75.0 80 DeepCRETE 5.0 176.1 35.2 176.1 80 Pause 0.0 0.0 5.0 0.0 80 Drop top plug Water 5.0 20.0 4.0 20.0 80 Pause 0.0 0.0 5.0 0.0 80 Switch to rig Mud 6.0 316.6 52.8 316.6 80 Mud 3.0 9.0 3.0 325.6 80 Slow & bump plug Total 02:29 671.7 bbl hr:mn Dynamic Security Checks: Frac 154 psi at 7607.0 ft Pore 41 psi at 2780.0 ft Collapse 4313 psi at 452.7 It Burst 6283 psi at 0.0 ft Page 8 1j-115 TLPcement.ctw; 05-182006; LoadCase 758Intermediate; Version wcs-cem45_89 ORIGINAL • 0 Client CPAI Well 1J-115TLP String 7-5/8 Intermediate District Prudhoe Bay Country USA Loadcase 758Intermediate Section 6: WELLCLEAN II Simulator ft O — 0 o - v G 0 G 0 CID G G O O G G co 0no r0 Std Betw. Cent. Cement Coverage Cement Coverage 80 100 Schlumhergcr Fluids Concentrations Risk Mud on the Wall z 4500 4500 4500- _ 4500 5000 5000 5000- 1#1 �fJJ 5000 5500 5500 T 5500- } 5500 r a 6000 t 6000 n a 8000 - 6000 n 5500 6500 5500- 6800 7000 7000 7000- 7000 7500 7500 7500- 7500 O 2 0 � Mud MUDPUSH II High Low Water CW100 Medium None DeepCRETE Page 9 1j-115 TLP cement.cfw: 05-182006; LoadCase 7581niermedlate Version wcs cem45_89 ORIGINAL Client CPAI Well 1J-115 TLP String 7-5/8 Intermediate District Prudhoe Bay Country USA Loadcase 758Intermediate ft 0- 0 o' v 0 lb/gal 8 12 16 .L_____1____T._i ---- Hydrostatic i --- Min. Hydrostatic -- Max. Dynamic , -- — Min. Dynamic i — Frac 1 i — Pore i E Schlutopoer 0 50 100 150 Time (min) De th = 7607 ft OF , ON �-� Annular Velocity i >= -•-•-------------------� p r- t. i i i t I > i i i jl Q r y i 0 50 100 150 Fluid Sequence Dynamic Well Security Time (min) —� ---------------------- r----•-----------•- 7 Frac -- Pore I 1 H drosta t'c 1 i___-_-_-_--_ i. �_=_=_= y- -•-•- - - i I I I i 1 i 1 i i 1 N _.----------- __ _ .. _ __ __ _ _ _ ... OJ _ Q----------_-_--- .-.--_-_ _-_----.--_ �-._._.-._._._._._._--------- H._-_.--_-_-_-_------•--- 'i'—•-----------1-•-•-•-------•T------'.._....-'r---'•--•--------ri--•---------•-------- --------------- 0 0 20 40 60 80 100 120 140 160 Time (min) Fluids at 7607 ft Ln ----. -----.---------------'-'-•-'- ---'r - --- - ,-- --- ------ 1 �----- - r t i i 1 1 1 e e R--.F�•Y.•^.:-_.r r s r r r r i t 1 '� �i "r 't m l i -.-f"i-•-t-•- -- -i----t--i--•'t•-•t t t F �`' _. .t r.. i i i 3. i t +-i• i 1--4-•-f-- 4---t t h i- N 1 ..��. I 1 1 1 i ! 1 -_ -V Xj i '. ��.4...--_ __.. ....-.. ...__ ... _rip .. T - -± 4----} a -4---} } } 1 }S - . ! t- 4 i "-'-Y_._'_._•-...-.Y-.-•_....._......T---------------- -`• r •-----Y-._..._._._._.i._._.-._ .. .T.__..__....-..___ i 0 20 40 60 80 100 120 140 160 Time (min) Page 10 1j-115 TLP cementcfw; 05-182006; LoadCase 7581ntennediate; Version wcstem45_89 ORIGINAL Wellhead / Tubing Head / Tree, 10-3/4" x 4'/x", 5,000 ksi Insulated Conductor Casing, 20", 94#, K55 x 34", 0.312" WT @ +/- 80' MD Tubing String: 4-12", 12.6 #, L-80, IBTM 10-3/4", 45.5#, L-80, BTC, R3 @ 2,781' MD / Z 150' TVD �P @ 63 degrees TD 13-1/2" hole Top of L1gnu C 10 4,500' MD / 2,840' TVD - Top of West Sak B (a7 10 6,400' MD / 3,533' TVD Lateral Entry Module #1 (LEM), Baker, with seal bore and ZXP packer above. Tubing, 4-'/2" IBTM, from LEM to - A2 Liner, with seal stem and CAMCO 3.562" "DB" nipple. Seal bore and ZXP packer for liner +/- 90' below "B" ndow Top of West Sak A * 6,800' MD / 3,567' TVD -� (1) Gas Litt Mandrel, CAMCO 4-1/2" x I" Model KMBG w/ dummy valve @, one (1) set @ 2,400' MD, 1,97T TVD. - (1) Gas Lift Mandrel, CAMCO 4-1/2" x 1" Model KMBG w/ dummy valve, @ < 72 deg, 5,000' MD, 3, l62' TVD. Electric Submersible Pump, Centrllift 413 HP motor, with FC6000 wireline deployed pump. Bottom at 5,237' MD, 3,260' TVD 152 L2 "D" Sand Window @ 6,095' MD / 3,53T TVD 77 degrees "D" Liner, 4-1/2", 11.6#, L80, BTC, R3 1J-152 L2: (0.125" x 2.5" slots, 32 per foot, 5.9"/6 open area) 6-3/4" D sand lateral TD 13,955 MD / 3,708' TVD \ Angle 88 degrees 152 LI "B" Sand Window @ 6,464' MD / 3,618' TVD 1J-152 Ll: 80 degrees "B" Liner, 4-12", 11.6#, 1,80, BTC, R3 &3/4" "B" sand lateral (0.125" x 23" slots, 32 per foot, 5.9% open area) TD 13,89I' MD / 3,767' TVD Angle 88 degrees it 80, BTC, a 1 � � ; l R3 '/: slotted and '/: blank, constrictors jor TD 13,701' MD / 3,90T TVD l rsolation Angle 88 degrees 7-5/8", 29.7#, L-80 TCM, R3 Csg @ 7,606' / 3,811' TVD @ 85 de e� • SHARON K. ALLSUP-DRAKE 1155 CONOCOPHILLIPS ATO1530 %6 700 G ST. , DATE G tV c _ .551 /441 ANCHORAGE AK 99501 PAY TO THE � y% � / l w[ j 1D /co CO ORDER OF v c/mow a� S DOLLARS �1..... 1RMOrganChaSe � j Valid Up To 5000 Dollars JPMorgan Chase Bank, N.A. Columbus, OH MEMO 1:044LLSSL0 S28?471907927111LL55 f 1i TRANSMITTAL LETTER CHECKLIST WELL NAME )eje6C PTD# 2_06:' - /2-2, Development Service Exploratory Stratigraphic Test Non -Conventional Well Circle Appropriate Letter / Paragraphs to be Included in Transmittal Letter CHECK ADD-ONS TEXT FOR APPROVAL LETTER WHAT (OPTIONS) j APPLIES i MULTI LATERAL ! The permit is for a new wellbore segment of existing well (If last two digits in I API number are I Permit No. API No. 50- - - j between 60-69) Production should continue to be reported as a function of the original API number stated above. PILOT HOLE In accordance with 20 AAC 25.005(f), all records, data and logs j acquired for the pilot hole must be clearly differentiated in both well name ( PH) and API number I (50- - -_) from records, data and logs I acquired for well i SPACING j The permit is approved subject to full compliance with 20 AAC EXCEPTION 25.055. Approval to perforate and produce / inject is contingent upon issuance of a conservation order approving a spacing j exception. assumes the j liability of any protest to the spacing exception that may occur. j DRY DITCH All dry ditch sample sets submitted to the Commission must be in j i SAMPLE I no greater than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals j through target zones. Non -Conventional Please note the following special condition of this permit.. i Well production or production testing of coal bed methane is not allowed for (name of well) until after (Company Name) has designed and j implemented a water well testing program to provide baseline data j on water quality and quantity. (Company Name) must contact the Commission to obtain advance approval of such water well testing Rev: 1/25/06 C:`jody\transmittal_checklist Field & Pool KUPARUK RIVER, WEST SAK OIL - 490150 Well Name: KUPARUK RIV U WSAK 1J-115 Program DEV Well bore seg ❑ PTD#: 2061220 Company CONOCOPHILLIPS ALASKA INC Initial ClasslType DEV / PEND GeoArea 890 Unit 11160 On/Off Shore On Annular Disposal ❑ Administration 1 Permit fee attached- - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - Yes _ - - . _ _ _ - - - _ _ - ------------------------------------------------------------- 2 Lease number appropriate- - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - Yes - _ - - - - _ Surface location and top productive interval in ADL 025661;_ TD in ADL 025650----------------- 3 Uniquewell_nameandnumber------------------------------------- Yes-------------------------------- -- ------------------------- 4 Welllocatedin_a-defined_pool--------------------------------------- Yes ------- KuparukRiver, West_SakUl-Pool -490150,- governed _by -CO 406B_------___-____-_____------- 5 Well located proper distance from drilling unit_bounda y _ - . _ _ _ - - - - - - Yes - - - - - _ _Well is more than 500 feet from an external property line. 6 Well located proper distance from other wells_ _ Yes _ _ _ _ CO 406B, Rule 3: no restrictions as well spacing except that no_pay shall be opened in a well closer 7 Sufficient acreage available in drilling unit _ _ Yes than 500 feet to external property line where ownership_ or landownership changes, 8 ifdeviated,is_wellboreplat-included ___________________________________ Yes_______________ ------------------------------------------------------------ 9 Operator onlyaff_ectedparty--------------------------------------- Yes --------------------------------------------- 10 Operator has.appropriatebondinforce-------------------------------- Yes------------------------------- 11 Permit can be issued without conservation order_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes - _ - - _ _ - _ - - - - - - - - - - - - - - - - - - - - - - - - - - - - - _ _ _ _ - - - - - - - - - - - - - - - _ _ - - _ - _ _ - - _ _ - - - - - - - Appr Date 12 Permitcan be issued without administrativ_e_approval - - - - - - - - - - - - - - - - - - - - - - - - - Yes - - - _ - - - - . - - _ _ - _ _ - _ _ _ _ _ _ _ - _ - - - - - - - - - - - - - - - - - - - _ _ - - - _ - _ - - - - _ - - - - - - - - - - - - - _ - - - SFD 8/16/2006 13 Can permit be approved before 15-day wait Yes 14 Well located within area arid -strata authorized by Injection Order # (put 10# in -comments)- (For NA_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 15 All wells within 1/4_mile area of review identified (For service well only) _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ NA_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 16 Pre -produced injector: duration -of pre production Less than 3 months_ (For_service well only) _ NA- - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - _ _ - - - 17 Nonconven, gas conforms to AS31.05.030Q.1.A),(j 2.A-D) - - - - - - - - - - - - - - - - - - - - - N_A_ - _ - - _ ---------------------------------------------------------------------- Engineering 18 Conductor string -provided - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - Yes - - - - - - - - - - - - - 19 Surface casing_protectsall_knownUSDWa______________ NA_ Allaquifersexempted,40CFR_147.102(_-3)- ------------_----__--------------__---_- 20 CMT_v_ol adequate_to circulate- on conductor & surf mg - - - - - - - - - - - - - - - - - - - - - - - Yes - - - - - - - - - - - - _ - - _ ---------------------------------------------------------- 21 CMT_vol_ adequate_to tie-in long string to surf csg_ ,- - - - - - - - - - - - - - - - - - - - - - - - - - No_ _ _ _ _ _ _ _ All hydrocarbons will be covered, Annular disposal_may be proposed._ - _ _ _ - - _ _ _ _ _ _ _ _ _ _ _ _ _ _ - - - _ _ _ 22 CMT-will cover all known -productive horizons_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ N_o_ - - - - - - - Slotted liner completion planned.- _ - _ - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - _ _ _ _ _ _ _ - - - - - - - 23 Casing designs adequate forC,T,B&_permafrost------------------ Yes_ - - - - - - - - - - - - - - - - -_-------------------- - - - - - - - - - - - - - - - - - - - - - 24 Adequate -tankage- or reserve pit - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - Yes - - - _ _ - - Rig is_equipped with steel -pits. -No reserve_ pit planned. All waste to approved annulus or disposal well. _ _ _ _ 25 If_a_re-drill, has -a- 10-403 for abandonment been approved _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ NA_ _ _ _ - - - - - - - - - - - 26 Adequate -well bore separationp[oposed_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _Yes _ _ _ _ _ _ _ Proximity_analysis performed. Traveling cylinder plot_inci - - _Gyros possible. _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 27 If diverterrequired. does itmeet regulations _____________.-________________ Yes_______--_-_--__-__-------_----_______--____-_-_----------------__--------- Appr Date 28 Drilling fluid- program schematic_& equip -list-adequate - - - - - - - - - - - - - - - - - - - - - - Yes - - - - - - - Maximum expected formation pressure 8.7_EMW._ Planned MW 8.6_ppg or_as-needed ._ _ _ _ _ _ _ _ - _ _ - _ - - - - TEM 8/18/2006 29 _B_OPEs,_do they meet regulation - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - Yes _ - - _ _ _ _ - ' 30 BOPE_press rating appropriate; test to -(put psig in comments)_ - - - - - - - - - - - Yes - - _ - - _ _ MASP calculated at 1328 psi, 3K equipment set up and test pressure_ planned__ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ YV .j 31 Choke_manifold complies w/API_RP-53 (May 64)- - - - - - - - - - - - - - - - - - - - - - - Yes - - - ----------------------------------------------------------------- 32 Work will occur without operation shutdown- - - - - - - - - - - - - - - - - - - - - - - - - - - - - - Yes - - - - - - - _ _ _ - - - _ _ - - _ _ _ _ - - - - - - - - - _ - _ - _ - _ - - - - _ _ _ - - - - - - - - - - - - - - - - _ - - _ _ _ _ _ - - _ - - - - 33 Is presence of H2S gas probable- - - - - - - - - - - - - - - - - - - - - - - - - - - - - No - _ - - - - _ H2S has not been reported at 1J-pad .- - _ - _ _ _ - _ - _ - _ _ - - - - - - - - - - - - - - - - - - _ _ _ - - _ _ - - - _ - - - 34 Mechanical -condition of wells within AOR verified (For service well only) _ _ _ _ _ _ _ _ _ _ _ _ _ _ NA_ _ _ - - _ _ _ - _ - - - - - - - - - - - - - - - - _ - - _ - - - - - - - - - _ _ - - - - - _ _ _ _ _ _ _ _ _ - - - _ - _ _ - _ - _ - _ _ _ _ _ - _ - _ Geology 35 Permit_can be issued w/o hydrogen_ sulfide measures _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ _ _ - - - - Nearby -well bore in pool, 1 D-102, measured 5_ppm_H2S_in 7/2005_ Rig has _sensors & alarms. 36 Data_presented on potential overpressure zones - - - - - - - - - - - - - - - - - - - - - - - - - - - Yes - - - - - _ _ Expected res._pressure is-8.7ppg EMW, will be drilled with 8.6 ppg oil -based mud. Mud weight will be Appr Date 37 Seismic -analysis of shallow gas -zones _ - _ - - _ _ _ ------------------------- NA_ - _ - - - - - adjusted as needed. - No shallow -gas expected. _ _ - - _ - - - - _ ------------------------------ SFD 8/16/2006 38 Seabed condition survey_(if -shore - - - - - - - - - - - - - - - - - - - - - - - - - off_) NA_ _Mud program notes use of 9.6 ppg mud if hydrates are_encountered, _ _ _ _ _ _ _ - _ - - 39 Contact name/phone for weekly- progress reports [exploratory only] _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ NA_ _ _ _ Geologic Engineering Publi Date: Date Date West Sak A sand producer. This well will the the main well bore for a tri-lateral production well. SFD Commissioner: Commissioner: C er • 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. 0 Sperry -Sun Drilling Services LIS Scan Utility $Revision: 3 $ LisLib $Revision: 4 $ Wed Feb 21 15:02:43 2007 Reel Header Service name.............LISTPE Date .....................07/02/21 origin...................STS Reel Name................UNKNOWN Continuation Number ...... 01 Previous Reel Name....... UNKNOWN Comments.................STS LIS Writing Library Tape Header Service name.............LISTPE Date .....................07/02/21 origin...................STS Tape Name................UNKNOWN Continuation Number ...... 01 Previous Tape Name....... UNKNOWN Comments.................STS LIS Writing Library Physical EOF Comment Record TAPE HEADER West Sak MWD/MAD LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER OPERATOR WITNESS JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: Scientific Technical Services Scientific Technical Services 1J-115 500292332000 ConocoPhillips Alaska, Inc Sperry Drilling Services 21-FEB-07 MWD RUN 3 MWD RUN 4 MWD RUN 5 MW-000465039 MW-000465039 MW-000465039 T. GALVIN T. GALVIN T. GALVIN G. WHITLOCK G. WHITLOCK G. WHITLOCK MWD RUN 6 MWD RUN 7 MWD RUN 8 MW-000465039 MW-000465039 MW-000465039 T. GALVIN T. GALVIN P. ORTH G. WHITLOCK G. WHITLOCK D. GLADDEN SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: # WELL CASING RECORD 35 11N 10E 1973 2380 109.00 81.00 OPEN HOLE CASING DRILLERS I'-1 SdT BIT SIZE (IN) SIZE (IN) DEPTH (FT) 1ST STRING 9.875 10.750 3009.0 2ND STRING 6.750 7.625 7493.0 3RD STRING PRODUCTION STRING # REMARKS: 1. ALL DEPTHS ARE MEASURED DEPTHS UNLESS OTHERWISE NOTED. THESE DEPTHS ARE BIT DEPTHS. 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTHS (TVD). 3. THIS WELL IS AN OPEN -HOLE SIDETRACK EXITING THE 1J-115 PB4 WELLBORE AT 12523'MD/3887'TVD. 4. MWD RUN 1 WAS DIRECTIONAL ONLY - NO DATA ARE PRESENTED. 5. MWD RUNS 2-8 COMPRISED DIRECTIONAL, DUAL GAMMA RAY (DGR) UTILIZING GEIGER- MUELLER TUBE DETECTORS, ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4), AND PRESSURE WHILE DRILLING (PWD). MWD RUNS 4-7 ALSO INCLUDED GEO-PILOT ROTARY STEERABLE BHA (GP). NO MWD DATA WERE ACQUIRED ON MWD RUN 2 DUE TO AN MWD FAILURE. 6. DEPTH SHIFTING OF MWD DATA WAS WAIVED PER E-MAIL, DATED 12/16/04, FROM M. WERNER (CPAI) TO R. KALISH (SDS). MWD DATA ARE CONSIDERED PDC. 7. MWD RUNS 1-8 REPRESENT WELL 1J-115 WITH API#: 50-029-23320-00. THIS WELL REACHED A TOTAL DEPTH (TD) OF 13720'MD/3910'TVD. SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRC = SMOOTHED GAMMA RAY COMBINED. SEXP = SMOOTHED PHASE SHIFT -DERIVED RESISTIVITY (EXTRA SHALLOW SPACING). SESP = SMOOTHED PHASE SHIFT -DERIVED RESISTIVITY (SHALLOW SPACING). SEMP = SMOOTHED PHASE SHIFT -DERIVED RESISTIVITY (MEDIUM SPACING). SEDP = SMOOTHED PHASE SHIFT -DERIVED RESISTIVITY (DEEP SPACING). SFXE = SMOOTHED FORMATION EXPOSURE TIME (DEEP SPACING). SLIDE = NON -ROTATED INTERVALS REFLECTING BIT DEPTHS. File Header Service name.............STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 07/02/21 Maximum Physical Record..65535 File Type................LO Previous File Name ....... STSLIB.000 Comment Record FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE START DEPTH STOP DEPTH GR 2993.5 13654.5 RPD 2995.0 13661.5 RPS 2995.0 13661.5 RPM 2995.0 13661.5 FET 2995.0 13661.5 RPX 2995.0 13661.5 ROP 3040.5 13720.0 BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH MERGED DATA SOURCE PBU TOOL CODE MWD MWD MWD MWD MWD MWD BIT RUN NO MERGE TOP 3 2993.5 4 7498.0 5 8050.5 6 8885.5 7 11690.5 8 12523.5 REMARKS: MERGED MAIN PASS. MERGE BASE 7498.0 8050.0 8885.0 11690.0 12523.0 13720.0 # Data Format Specification Record Data Record Type..................0 Data Specification Block Type ..... 0 Logging Direction.................Down Optical log depth units ........... Feet Data Reference Point..............Undefined Frame Spacing.....................60 .1IN Max frames per record.............Undefined Absent value.......................999 Depth Units ....................... Datum Specification Block sub -type ... 0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 RPD MWD OHMM 4 1 68 4 2 RPM MWD OHMM 4 1 68 8 3 RPS MWD OHMM 4 1 68 12 4 RPX MWD OHMM 4 1 68 16 5 FET MWD OHMM 4 1 68 20 6 GR MWD API 4 1 68 24 7 ROP MWD FT/H 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 2993.5 13720 8356.75 21454 2993.5 13720 RPD MWD OHMM 0.23 2000 27.9723 21334 2995 13661.5 RPM MWD OHMM 0.65 2000 31.6298 21334 2995 13661.5 RPS MWD OHMM 0.2 2000 21.7639 21334 2995 13661.5 RPX MWD OHMM 0.9 2000 22.0413 21334 2995 13661.5 FET MWD OHMM 0.12 255.82 1.17113 21334 2995 13661.5 GR MWD API 24.09 122.12 69.7223 21323 2993.5 13654.5 ROP MWD FT/H 0.12 636.55 209.644 21360 3040.5 13720 First Reading For Entire File .......... 2993.5 Last Reading For Entire File ........... 13720 File Trailer Service name.............STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 07/02/21 Maximum Physical Record..65535 File Type................LO Next File Name ........... STSLIB.002 Physical EOF File Header Service name.............STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 07/02/21 Maximum Physical Record..65535 File Type................LO Previous File Name ....... STSLIB.001 Comment Record FILE HEADER FILE NUMBER: 2 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 3 DEPTH INCREMENT: .5000 # FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 2993.5 7451.0 RPD 2995.0 7443.5 RPM 2995.0 7443.5 RPS 2995.0 7443.5 FET 2995.0 7443.5 RPX 2995.0 7443.5 ROP 3040.5 7498.0 LOG HEADER DATA DATE LOGGED: 08-OCT-06 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 72.13 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 7498.0 TOP LOG INTERVAL (FT): 3040.0 BOTTOM LOG INTERVAL (FT): 7498.0 BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: 59.3 MAXIMUM ANGLE: 85.5 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 103770 EWR4 ELECTROMAG. RESIS. 4 127479 # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 9.875 DRILLER'S CASING DEPTH (FT): 3009.0 # BOREHOLE CONDITIONS MUD TYPE: Other MUD DENSITY (LB/G): 9.10 MUD VISCOSITY (S): 58.0 MUD PH: 8.4 MUD CHLORIDES (PPM): 100 FLUID LOSS (C3): 6.8 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): 4.100 70.0 MUD AT MAX CIRCULATING TERMPERATURE: 3.040 96.8 MUD FILTRATE AT MT: 5.400 65.0 MUD CAKE AT MT: 3.300 65.0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format Specification Record Data Record Type..................0 Data Specification Block Type ..... 0 Logging Direction.................Down Optical log depth units ........... Feet Data Reference Point..............Undefined Frame Spacing.....................60 .1IN Max frames per record.............Undefined Absent value.......................999 Depth Units ....................... Datum Specification Block sub -type ... 0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 RPD MWD030 OHMM 4 1 68 4 2 RPM MWD030 OHMM 4 1 68 8 3 RPS MWD030 OHMM 4 1 68 12 4 RPX MWD030 OHMM 4 1 68 16 5 FET MWD030 HOUR 4 1 68 20 6 GR MWD030 API 4 1 68 24 7 ROP MWD030 FT/H 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 2993.5 7498 5245.75 9010 2993.5 7498 RPD MWD030 OHMM 1.9 2000 17.3949 8898 2995 7443.5 RPM MWD030 OHMM 1.48 1651.33 14.8698 8898 2995 7443.5 RPS MWD030 OHMM 0.2 136.25 13.4381 8898 2995 7443.5 RPX MWD030 OHMM 0.9 131.81 12.6341 8898 2995 7443.5 FET MWD030 HOUR 0.17 56.28 0.931726 8898 2995 7443.5 GR MWD030 API 24.09 122.12 70.5094 8916 2993.5 7451 ROP MWD030 FT/H 7.57 636.55 208.837 8916 3040.5 7498 First Reading For Entire File .......... 2993.5 Last Reading For Entire File ........... 7498 File Trailer Service name.............STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 0 s Date of Generation ....... 07/02/21 Maximum Physical Record..65535 File Type................LO Next File Name ........... STSLIB.003 Physical EOF File Header Service name.............STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 07/02/21 Maximum Physical Record..65535 File Type................LO Previous File Name ....... STSLIB.002 Comment Record FILE HEADER FILE NUMBER: 3 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 4 DEPTH INCREMENT: .5000 # FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH RPD 7444.0 8050.0 FET 7444.0 8050.0 RPS 7444.0 8050.0 RPM 7444.0 8050.0 RPX 7444.0 8050.0 GR 7451.5 8050.0 ROP 7498.5 8050.0 LOG HEADER DATA DATE LOGGED: 11-OCT-06 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 68.18 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 8050.0 TOP LOG INTERVAL (FT): 7498.0 BOTTOM LOG INTERVAL (FT): 8050.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 85.7 MAXIMUM ANGLE: 91.1 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 156436 EWR4 Electromag Resis. 4 162742 # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 6.750 DRILLER'S CASING DEPTH (FT): 7493.0 BOREHOLE CONDITIONS MUD TYPE: Mineral Oil Base MUD DENSITY (LB/G): 8.80 MUD VISCOSITY (S): 74.0 MUD PH: .0 MUD CHLORIDES (PPM): 26000 FLUID LOSS (C3): 3.8 0 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 ... 0 0 .000 .0 .000 97.0 .000 .0 .000 .0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 RPD MWD040 OHMM 4 1 68 4 2 RPM MWD040 OHMM 4 1 68 8 3 RPS MWD040 OHMM 4 1 68 12 4 RPX MWD040 OHMM 4 1 68 16 5 FET MWD040 HOUR 4 1 68 20 6 GR MWD040 API 4 1 68 24 7 ROP MWD040 FT/H 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 7444 8050 7747 1213 7444 8050 RPD MWD040 OHMM 0.23 2000 81.6044 1213 7444 8050 RPM MWD040 OHMM 0.65 2000 100.344 1213 7444 8050 RPS MWD040 OHMM 6.44 2000 29.5445 1213 7444 8050 RPX MWD040 OHMM 5.01 2000 28.8257 1213 7444 8050 FET MWD040 HOUR 0.18 69.73 6.87074 1213 7444 8050 GR MWD040 API 29.69 102.74 67.1852 1198 7451.5 8050 ROP MWD040 FT/H 30.15 386.42 216.237 1104 7498.5 8050 First Reading For Entire File.......... 7444 Last Reading For Entire File ........... 8050 File Trailer Service name.............STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 07/02/21 Maximum Physical Record..65535 File Type................LO Next File Name ........... STSLIB.004 i Physical EOF File Header Service name.............STSLIB.004 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 07/02/21 Maximum Physical Record..65535 File Type................LO Previous File Name ....... STSLIB.003 Comment Record FILE HEADER FILE NUMBER: 4 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 5 DEPTH INCREMENT: .5000 # FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 8050.5 8885.0 RPX 8050.5 8885.0 FET 8050.5 8885.0 ROP 8050.5 8885.0 RPD 8050.5 8885.0 RPS 8050.5 8885.0 RPM 8050.5 8885.0 LOG HEADER DATA DATE LOGGED: 12-OCT-06 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 68.18 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 8885.0 TOP LOG INTERVAL (FT): 8050.0 BOTTOM LOG INTERVAL (FT): 8885.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 87.8 MAXIMUM ANGLE: 92.3 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 156436 EWR4 Electromag Resis. 4 162742 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 6.750 DRILLER'S CASING DEPTH (FT): 7493.0 BOREHOLE CONDITIONS MUD TYPE: Mineral Oil Base MUD DENSITY (LB/G): 8.80 MUD VISCOSITY (S): 81.0 MUD PH: .0 MUD CHLORIDES (PPM): 21000 FLUID LOSS (C3): 3.6 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): .000 .0 MUD AT MAX CIRCULATING TERMPERATURE: .000 104.0 MUD FILTRATE AT MT: .000 .0 MUD CAKE AT MT: .000 .0 # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: Data Format Specification Record Data Record Type..................0 Data Specification Block Type ..... 0 Logging Direction.................Down Optical log depth units ........... Feet Data Reference Point..............Undefined Frame Spacing.....................60 .1IN Max frames per record.............Undefined Absent value.......................999 Depth Units ....................... Datum Specification Block sub -type ... 0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 RPD MWD050 OHMM 4 1 68 4 2 RPM MWD050 OHMM 4 1 68 8 3 RPS MWD050 OHMM 4 1 68 12 4 RPX MWD050 OHMM 4 1 68 16 5 FET MWD050 HOUR 4 1 68 20 6 GR MWD050 API 4 1 68 24 7 ROP MWD050 FT/H 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 8050.5 8885 8467.75 1670 8050.5 8885 RPD MWD050 OHMM 12.24 66.53 34.0975 1670 8050.5 8885 RPM MWD050 OHMM 10.43 82.79 40.34 1670 8050.5 8885 RPS MWD050 OHMM 9.65 97.71 36.9006 1670 8050.5 8885 RPX MWD050 OHMM 9.5 125.86 41.4908 1670 8050.5 8885 FET MWD050 HOUR 0.16 10.86 0.396431 1670 8050.5 8885 GR MWD050 API 46.98 101.51 67.401 1670 8050.5 8885 ROP MWD050 FT/H 0.2 379.84 246.559 1670 8050.5 8885 First Reading For Entire File .......... 8050.5 Last Reading For Entire File ........... 8885 File Trailer Service name.............STSLIB.004 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 07/02/21 Maximum Physical Record..65535 File Type................LO Next File Name ........... STSLIB.005 Physical EOF File Header Service name.............STSLIB.005 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 07/02/21 0 0 Maximum Physical Record..65535 File Type................LO Previous File Name ....... STSLIB.004 Comment Record FILE HEADER FILE NUMBER: 5 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 6 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH RPX 8885.5 11690.0 GR 8885.5 11690.0 FET 8885.5 11690.0 RPS 8885.5 11690.0 RPD 8885.5 11690.0 ROP 8885.5 11690.0 RPM 8885.5 11690.0 LOG HEADER DATA DATE LOGGED: 13-OCT-06 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 68.18 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 11690.0 TOP LOG INTERVAL (FT): 8885.0 BOTTOM LOG INTERVAL (FT): 11690.0 BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: 87.9 MAXIMUM ANGLE: 92.3 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 156436 EWR4 Electromag Resis. 4 162742 $ # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 6.750 DRILLER'S CASING DEPTH (FT): 7493.0 BOREHOLE CONDITIONS MUD TYPE: Mineral Oil Base MUD DENSITY (LB/G): 8.80 MUD VISCOSITY (S): 79.0 MUD PH: .0 MUD CHLORIDES (PPM): 18500 FLUID LOSS (C3): 3.6 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): .000 .0 MUD AT MAX CIRCULATING TERMPERATURE: .000 111.0 MUD FILTRATE AT MT: .000 .0 MUD CAKE AT MT: .000 .0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format Specification Record Data Record Type..................0 Data Specification Block Type ..... 0 Logging Direction.................Down Optical log depth units ........... Feet Data Reference Point..............Undefined Frame Spacing.....................60 .1IN Max frames per record.............Undefined Absent value.......................999 Depth Units ....................... Datum Specification Block sub -type ... 0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 RPD MWD060 OHMM 4 1 68 4 2 RPM MWD060 OHMM 4 1 68 8 3 RPS MWD060 OHMM 4 1 68 12 4 RPX MWD060 OHMM 4 1 68 16 5 FET MWD060 HOUR 4 1 68 20 6 GR MWD060 API 4 1 68 24 7 ROP MWD060 FT/H 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 8885.5 11690 10287.8 5610 8885.5 11690 RPD MWD060 OHMM 13.29 1307.18 38.4249 5610 8885.5 11690 RPM MWD060 OHMM 11.89 2000 50.0649 5610 8885.5 11690 RPS MWD060 OHMM 10.26 102.93 32.3644 5610 8885.5 11690 RPX MWD060 OHMM 7.51 77.58 33.9457 5610 8885.5 11690 FET MWD060 HOUR 0.12 9.15 0.517426 5610 8885.5 11690 GR MWD060 API 36.82 98.26 65.8482 5610 8885.5 11690 ROP MWD060 FT/H 1.07 614.69 230.722 5610 8885.5 11690 First Reading For Entire File .......... 8885.5 Last Reading For Entire File ........... 11690 File Trailer Service name.............STSLIB.005 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 07/02/21 Maximum Physical Record..65535 File Type................LO Next File Name ........... STSLIB.006 Physical EOF File Header Service name.............STSLIB.006 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 07/02/21 Maximum Physical Record..65535 File Type................LO Previous File Name ....... STSLIB.005 Comment Record FILE HEADER FILE NUMBER: 6 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 7 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH RPX 11690.5 12523.0 RPS 11690.5 12523.0 FET 11690.5 12523.0 RPM 11690.5 12523.0 GR 11690.5 12523.0 RPD 11690.5 12523.0 ROP 11690.5 12523.0 $ LOG HEADER DATA DATE LOGGED: 14-OCT-06 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 68.18 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 12523.0 TOP LOG INTERVAL (FT): 11690.0 BOTTOM LOG INTERVAL (FT): 12523.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 85.1 MAXIMUM ANGLE: 89.3 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 156436 EWR4 Electromag Resis. 4 162742 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 6.750 DRILLER'S CASING DEPTH (FT): 7493.0 BOREHOLE CONDITIONS MUD TYPE: Mineral Oil Base MUD DENSITY (LB/G): 8.70 MUD VISCOSITY (S): 79.0 MUD PH: .0 MUD CHLORIDES (PPM): 18500 FLUID LOSS (C3): 3.8 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): .000 .0 MUD AT MAX CIRCULATING TERMPERATURE: .000 111.0 MUD FILTRATE AT MT: .000 .0 MUD CAKE AT MT: .000 .0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format Specification Record Data Record Type..................0 Data Specification Block Type ..... 0 Logging Direction.................Down 0 + Optical log depth units ........... Feet Data Reference Point..............Undefined Frame Spacing.....................60 .1IN Max frames per record.............Undefined Absent value.......................999 Depth Units ....................... Datum Specification Block sub -type ... 0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 RPD MWD070 OHMM 4 1 68 4 2 RPM MWD070 OHMM 4 1 68 8 3 RPS MWD070 OHMM 4 1 68 12 4 RPX MWD070 OHMM 4 1 68 16 5 FET MWD070 HOUR 4 1 68 20 6 GR MWD070 API 4 1 68 24 7 ROP MWD070 FT/H 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 11690.5 12523 12106.8 1666 11690.5 12523 RPD MWD070 OHMM 4.9 46.95 16.538 1666 11690.5 12523 RPM MWD070 OHMM 4.84 154.72 17.8173 1666 11690.5 12523 RPS MWD070 OHMM 4.66 100.26 15.5984 1666 11690.5 12523 RPX MWD070 OHMM 4.61 69.25 15.6571 1666 11690.5 12523 FET MWD070 HOUR 0.21 9.86 0.751363 1666 11690.5 12523 GR MWD070 API 46.14 96.85 75.1629 1666 11690.5 12523 ROP MWD070 FT/H 0.12 457.5 170.957 1666 11690.5 12523 First Reading For Entire File .......... 11690.5 Last Reading For Entire File ........... 12523 File Trailer Service name.............STSLIB.006 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 07/02/21 Maximum Physical Record..65535 File Type................LO Next File Name ........... STSLIB.007 Physical EOF File Header Service name.............STSLIB.007 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 07/02/21 Maximum Physical Record..65535 File Type................LO Previous File Name ....... STSLIB.006 Comment Record FILE HEADER FILE NUMBER: 7 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 8 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH RPM 12523.5 13661.5 ROP 12523.5 13720.0 RPX 12523.5 13661.5 RPS 12523.5 13661.5 RPD 12523.5 13661.5 GR 12523.5 13654.5 FET 12523.5 13661.5 LOG HEADER DATA DATE LOGGED: 25-OCT-06 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 66.37 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 13720.0 TOP LOG INTERVAL (FT): 12523.0 BOTTOM LOG INTERVAL (FT): 13720.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 84.6 MAXIMUM ANGLE: 92.4 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 17851 EWR4 Electromag Resis. 4 159439 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 6.750 DRILLER'S CASING DEPTH (FT): 7493.0 BOREHOLE CONDITIONS MUD TYPE: Mineral Oil Base MUD DENSITY (LB/G): 8.80 MUD VISCOSITY (S): 87.0 MUD PH: .0 MUD CHLORIDES (PPM): 18750 FLUID LOSS (C3): 3.0 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): .000 .0 MUD AT MAX CIRCULATING TERMPERATURE: .000 104.0 MUD FILTRATE AT MT: .000 .0 MUD CAKE AT MT: .000 .0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: # Data Format Specification Record Data Record Type..................0 Data Specification Block Type ..... 0 Logging Direction.................Down Optical log depth units ........... Feet Data Reference Point..............Undefined Frame Spacing.....................60 .1IN Max frames per record.............Undefined Absent value.......................999 Depth Units ....................... Datum Specification Block sub -type ... 0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 RPD MWD080 OHMM 4 1 68 4 2 RPM MWD080 OHMM 4 1 68 8 3 RPS MWD080 OHMM 4 1 68 12 4 RPX MWDO80 OHMM 4 1 68 16 5 FET MWD080 HOUR 4 1 68 20 6 GR MWD080 API 4 1 68 24 7 ROP MWD080 FT/H 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 12523.5 13720 13121.8 2394 12523.5 13720 RPD MWD080 OHMM 4.76 119.51 18.8571 2277 12523.5 13661.5 RPM MWD080 OHMM 4.27 89.34 18.8176 2277 12523.5 13661.5 RPS MWD080 OHMM 4.2 57.13 17.4469 2277 12523.5 13661.5 RPX MWD080 OHMM 4.05 38.38 16.2654 2277 12523.5 13661.5 FET MWD080 HOUR 0.19 255.82 1.55624 2277 12523.5 13661.5 GR MWD080 API 51.77 110.52 75.2761 2263 12523.5 13654.5 ROP MWD080 FT/H 10.73 590.27 161.392 2394 12523.5 13720 First Reading For Entire File .......... 12523.5 Last Reading For Entire File ........... 13720 File Trailer Service name.............STSLIB.007 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 07/02/21 Maximum Physical Record..65535 File Type................LO Next File Name ........... STSLIB.008 Physical EOF Tape Trailer Service name.............LISTPE Date .....................07/02/21 origin...................STS Tape Name................UNKNOWN Continuation Number ...... 01 Next Tape Name ........... UNKNOWN Comments.................STS LIS Writing Library. Reel Trailer Service name.............LISTPE Date .....................07/02/21 origin...................STS Reel Name................UNKNOWN Continuation Number ...... 01 Next Reel Name ........... UNKNOWN Comments.................STS LIS Writing Library Physical EOF Physical EOF Scientific Technical Services Scientific Technical Services End Of LIS File S 0 Sperry -Sun Drilling Services LIS Scan Utility $Revision: 3 $ LisLib $Revision: 4 $ Fri Feb 23 08:32:57 2007 Reel Header Service name.............LISTPE Date .....................07/02/23 origin...................STS Reel Name................UNKNOWN Continuation Number ...... 01 Previous Reel Name....... UNKNOWN Comments.................STS LIS Writing Library. Tape Header Service name.............LISTPE Date .....................07/02/23 origin...................STS Tape Name................UNKNOWN Continuation Number ...... 01 Previous Tape Name....... UNKNOWN Comments.................STS LIS Writing Library Physical EOF Comment Record TAPE HEADER West Sak MWD/MAD LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: # JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 3 W-0004650390 T. GALVIN G. WITLOCK SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING OPEN HOLE BIT SIZE (IN) 9.875 6.750 Scientific Technical Services Scientific Technical Services 1J-115 PB1 500292332070 ConocoPhillips Alaska, Inc Sperry Drilling Services 23-FEB-07 MWD RUN 4 W-0004650390 T. GALVIN G. WITLOCK 35 11N 10E 1973 2380 109.00 81.00 CASING DRILLERS SIZE (IN) DEPTH (FT) 10.750 3009.0 7.625 7493.0 0C (D -(JD lY 6-6-�' REMARKS: 1. ALL DEPTHS ARE MEASURED DEPTHS UNLESS OTHERWISE NOTED. THESE DEPTHS ARE BIT DEPTHS. 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTHS (TVD). 3. MWD RUN 1 WAS DIRECTIONAL ONLY - NO DATA ARE PRESENTED. 4. MWD RUNS 2-4 COMPRISED DIRECTIONAL, DUAL GAMMA RAY (DGR) UTILIZING GEIGER- MUELLER TUBE DETECTORS, ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4), AND PRESSURE WHILE DRILLING (PWD). MWD RUN 4 ALSO INCLUDED GEO-PILOT ROTARY STEERABLE BHA (GP). NO MWD DATA WERE ACQUIRED ON MWD RUN 2 DUE TO AN MWD FAILURE. 5. DEPTH SHIFTING OF MWD DATA WAS WAIVED PER E-MAIL, DATED 12/16/04, FROM M. WERNER (CPAI) TO R. KALISH (SDS). MWD DATA ARE CONSIDERED PDC. 6. MWD RUNS 1-4 REPRESENT WELL 1J-115 PB1 WITH API#: 50-029-23320-70. THIS WELL REACHED A TOTAL DEPTH (TD) OF 8405'MD/3828'TVD. SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRC = SMOOTHED GAMMA RAY COMBINED. SEXP = SMOOTHED PHASE SHIFT -DERIVED RESISTIVITY (EXTRA SHALLOW SPACING). SESP = SMOOTHED PHASE SHIFT -DERIVED RESISTIVITY (SHALLOW SPACING). SEMP = SMOOTHED PHASE SHIFT -DERIVED RESISTIVITY (MEDIUM SPACING). SEDP = SMOOTHED PHASE SHIFT -DERIVED RESISTIVITY (DEEP SPACING). SFXE = SMOOTHED FORMATION EXPOSURE TIME (DEEP SPACING). SLIDE = NON -ROTATED INTERVALS REFLECTING BIT DEPTHS. File Header Service name.............STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 07/02/23 Maximum Physical Record..65535 File Type................LO Previous File Name ....... STSLIB.000 Comment Record FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE START DEPTH GR 2993.5 RPD 2995.0 FET 2995.0 RPS 2995.0 RPM 2995.0 RPX 2995.0 ROP 3040.5 all bit runs merged. STOP DEPTH 8347.0 8354.5 8354.5 8354.5 8354.5 8354.5 8405.0 BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH # MERGED DATA SOURCE PBU TOOL CODE MWD MWD BIT RUN NO MERGE TOP MERGE BASE 3 2993.5 7498.0 4 7498.0 8405.0 # REMARKS: MERGED MAIN PASS. $ Data Format Specification Record Data Record Type..................0 Data Specification Block Type.....0 Logging Direction.................Down Optical log depth units ........... Feet Data Reference Point..............Undefined Frame Spacing.....................60 .1IN Max frames per record.............Undefined Absent value.......................999 Depth Units ....................... Datum Specification Block sub -type ... 0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 RPD MWD OHMM 4 1 68 4 2 RPM MWD OHMM 4 1 68 8 3 RPS MWD OHMM 4 1 68 12 4 RPX MWD OHMM 4 1 68 16 5 FET MWD HOUR 4 1 68 20 6 GR MWD API 4 1 68 24 7 ROP MWD FT/H 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 2993.5 8405 5699.25 10824 2993.5 8405 RPD MWD OHMM 0.23 2000 24.7769 10720 2995 8354.5 RPM MWD OHMM 0.65 2000 24.8136 10720 2995 8354.5 RPS MWD OHMM 0.2 2000 15.4863 10720 2995 8354.5 RPX MWD OHMM 0.9 2000 14.7591 10720 2995 8354.5 FET MWD HOUR 0.17 69.73 1.58002 10720 2995 8354.5 GR MWD API 24.09 122.12 70.5482 10708 2993.5 8347 ROP MWD FT/H 4.25 636.55 207.911 10730 3040.5 8405 First Reading For Entire File .......... 2993.5 Last Reading For Entire File ........... 8405 File Trailer Service name.............STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 07/02/23 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 ....... 07/02/23 Maximum Physical Record..65535 File Type................LO Previous File Name ....... STSLIB.001 Comment Record FILE HEADER FILE NUMBER: 2 RAW MWD Curves and log header data BIT RUN NUMBER: 3 DEPTH INCREMENT: .5000 FILE SUMMARY for each bit run in separate files. VENDOR TOOL CODE START DEPTH STOP DEPTH GR 2993.5 7451.0 FET 2995.0 7443.5 RPX 2995.0 7443.5 RPS 2995.0 7443.5 RPM 2995.0 7443.5 RPD 2995.0 7443.5 ROP 3040.5 7498.0 LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: m W TOOL STRING (TOP TO BOTTOM) 08-OCT-06 Insite 72.13 Memory 7498.0 3040.0 7498.0 59.3 85.5 VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 103770 EWR4 ELECTROMAG. RESIS. 4 127479 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 9.875 DRILLER'S CASING DEPTH (FT): 3009.0 BOREHOLE CONDITIONS MUD TYPE: Other MUD DENSITY (LB/G): 9.10 MUD VISCOSITY (S): 58.0 MUD PH: 8.4 MUD CHLORIDES (PPM): 100 FLUID LOSS (C3): 6.8 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): 4.100 70.0 MUD AT MAX CIRCULATING TERMPERATURE: 3.040 96.8 MUD FILTRATE AT MT: 5.400 65.0 MUD CAKE AT MT: 3.300 65.0 NEUTRON TOOL • MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: # Data Format Specification Record Data Record Type..................0 Data Specification Block Type ..... 0 Logging Direction.................Down Optical log depth units ........... Feet Data Reference Point..............Undefined Frame Spacing.....................60 .1IN Max frames per record.............Undefined Absent value.......................999 Depth Units ....................... Datum Specification Block sub -type ... 0 Name Service Order Units Size Nsam Rep Code Offset Channel 0 DEPT FT 4 1 68 0 1 RPD MWD030 OHMM 4 1 68 4 2 RPM MWD030 OHMM 4 1 68 8 3 RPS MWD030 OHMM 4 1 68 12 4 RPX MWD030 OHMM 4 1 68 16 5 FET MWD030 HOUR 4 1 68 20 6 GR MWD030 API 4 1 68 24 7 ROP MWD030 FT/H 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 2993.5 7498 5245.75 9010 2993.5 7498 RPD MWD030 OHMM 1.9 2000 17.3949 8898 2995 7443.5 RPM MWD030 OHMM 1.48 1651.33 14.8698 8898 2995 7443.5 RPS MWD030 OHMM 0.2 136.25 13.4381 8898 2995 7443.5 RPX MWD030 OHMM 0.9 131.81 12.6341 8898 2995 7443.5 FET MWD030 HOUR 0.17 56.28 0.931726 8898 2995 7443.5 GR MWD030 API 24.09 122.12 70.5094 8916 2993.5 7451 ROP MWD030 FT/H 7.57 636.55 208.837 8916 3040.5 7498 First Reading For Entire File .......... 2993.5 Last Reading For Entire File ........... 7498 File Trailer Service name.............STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 07/02/23 Maximum Physical Record..65535 File Type................LO Next File Name ........... STSLIB.003 Physical EOF File Header Service name.............STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 07/02/23 Maximum Physical Record..65535 File Type................LO Previous File Name ....... STSLIB.002 Comment Record FILE HEADER FILE NUMBER: 3 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 4 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH RPX 7444.0 8354.5 RPD 7444.0 8354.5 RPM 7444.0 8354.5 FET 7444.0 8354.5 RPS 7444.0 8354.5 GR 7451.5 8347.0 ROP 7498.5 8405.0 LOG HEADER DATA DATE LOGGED: 11-OCT-06 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 68.18 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 8405.0 TOP LOG INTERVAL (FT): 7498.0 BOTTOM LOG INTERVAL (FT): 8405.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 85.7 MAXIMUM ANGLE: 91.1 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 156436 EWR4 Electromag Resis. 4 162742 # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 6.750 DRILLER'S CASING DEPTH (FT): 7493.0 BOREHOLE CONDITIONS MUD TYPE: Mineral Oil Base MUD DENSITY (LB/G): 8.80 MUD VISCOSITY (S): 74.0 MUD PH: .0 MUD CHLORIDES (PPM): 26000 FLUID LOSS (C3): 3.8 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): .000 .0 MUD AT MAX CIRCULATING TERMPERATURE: .000 97.0 MUD FILTRATE AT MT: .000 .0 MUD CAKE AT MT: .000 .0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): • REMARKS: 11 Data Format Specification Record Data Record Type..................0 Data Specification Block Type ..... 0 Logging Direction.................Down Optical log depth units ........... Feet Data Reference Point..............Undefined Frame Spacing.....................60 .1IN Max frames per record.............Undefined Absent value.......................999 Depth Units ....................... Datum Specification Block sub -type ... 0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 RPD MWD040 OHMM 4 1 68 4 2 RPM MWD040 OHMM 4 1 68 8 3 RPS MWD040 OHMM 4 1 68 12 4 RPX MWD040 OHMM 4 1 68 16 5 FET MWD040 HOUR 4 1 68 20 6 GR MWD040 API 4 1 68 24 7 ROP MWD040 FT/H 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 7444 8405 7924.5 1923 7444 8405 RPD MWD040 OHMM 0.23 2000 60.8279 1822 7444 8354.5 RPM MWD040 OHMM 0.65 2000 73.3755 1822 7444 8354.5 RPS MWD040 OHMM 6.44 2000 25.4889 1822 7444 8354.5 RPX MWD040 OHMM 5.01 2000 25.1368 1822 7444 8354.5 FET MWD040 HOUR 0.18 69.73 4.74603 1822 7444 8354.5 GR MWD040 API 29.69 102.74 70.7412 1792 7451.5 8347 ROP MWD040 FT/H 4.25 386.42 203.362 1814 7498.5 8405 First Reading For Entire File.......... 7444 Last Reading For Entire File ........... 8405 File Trailer Service name.............STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 07/02/23 Maximum Physical Record..65535 File Type................LO Next File Name ........... STSLIB.004 Physical EOF Tape Trailer Service name.............LISTPE Date .....................07/02/23 origin...................STS Tape Name................UNKNOWN Continuation Number ...... 01 Next Tape Name ........... UNKNOWN Comments.................STS LIS Writing Library. Reel Trailer Service name.............LISTPE Date .....................07/02/23 Scientific Technical Services 0 • 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 • Sperry -Sun Drilling Services LIS Scan Utility $Revision: 3 $ LisLib $Revision: 4 $ Fri Feb 23 09:46:22 2007 Reel Header Service name.............LISTPE Date .....................07/02/23 origin...................STS Reel Name................UNKNOWN Continuation Number ...... 01 Previous Reel Name....... UNKNOWN Comments.................STS LIS Writing Library Tape Header Service name.............LISTPE Date .....................07/02/23 origin...................STS Tape Name................UNKNOWN Continuation Number ...... 01 Previous Tape Name....... UNKNOWN Comments.................STS LIS Writing Library. • Scientific Technical Services Scientific Technical Services Physical EOF Comment Record TAPE HEADER West Sak MWD/MAD LOGS # WELL NAME: 1J-115 PB2 API NUMBER: 500292332071 OPERATOR: ConocoPhillips Alaska, Inc LOGGING COMPANY: Sperry Drilling Services TAPE CREATION DATE: 23-FEB-07 # JOB DATA MWD RUN 3 MWD RUN 4 MWD RUN 5 JOB NUMBER: W-0004650390 W-0004650390 W-0004650390 LOGGING ENGINEER: T. GALVIN T. GALVIN T. GALVIN OPERATOR WITNESS: G. WITLOCK G. WITLOCK G. WITLOCK SURFACE LOCATION SECTION: 35 TOWNSHIP: 11N RANGE: 10E FNL: FSL: 1973 FEL: 2380 FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: 109.00 GROUND LEVEL: 81.00 WELL CASING RECORD OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 1ST STRING 9.875 10.750 3009.0 2ND STRING 6.750 7.625 7493.0 3RD STRING PRODUCTION STRING 0a,-1"�Q l`fSb REMARKS: 9 0 1. ALL DEPTHS ARE MEASURED DEPTHS UNLESS OTHERWISE NOTED. THESE DEPTHS ARE BIT DEPTHS. 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTHS (TVD). 3. THIS WELL IS AN OPEN -HOLE SIDETRACK EXITING THE 1J-115 PB1 WELLBORE AT 8050'MD/3820'TVD. 4. MWD RUN 1 WAS DIRECTIONAL ONLY - NO DATA ARE PRESENTED. 5. MWD RUNS 2-5 COMPRISED DIRECTIONAL, DUAL GAMMA RAY (DGR) UTILIZING GEIGER- MUELLER TUBE DETECTORS, ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4), AND PRESSURE WHILE DRILLING (PWD). MWD RUNS 4 & 5 ALSO INCLUDED GEO-PILOT ROTARY STEERABLE BHA (GP). NO MWD DATA WERE ACQUIRED ON MWD RUN 2 DUE TO AN MWD FAILURE. 6. DEPTH SHIFTING OF MWD DATA WAS WAIVED PER E-MAIL, DATED 12/16/04, FROM M. WERNER (CPAI) TO R. KALISH (SDS). MWD DATA ARE CONSIDERED PDC. 7. MWD RUNS 1-5 REPRESENT WELL 1J-115 PB2 WITH API#: 50-029-23320-71. THIS WELL REACHED A TOTAL DEPTH (TD) OF 9190'MD/3813'TVD. SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRC = SMOOTHED GAMMA RAY COMBINED. SEXP = SMOOTHED PHASE SHIFT -DERIVED RESISTIVITY (EXTRA SHALLOW SPACING). SESP = SMOOTHED PHASE SHIFT -DERIVED RESISTIVITY (SHALLOW SPACING). SEMP = SMOOTHED PHASE SHIFT -DERIVED RESISTIVITY (MEDIUM SPACING). SEDP = SMOOTHED PHASE SHIFT -DERIVED RESISTIVITY (DEEP SPACING). SFXE = SMOOTHED FORMATION EXPOSURE TIME (DEEP SPACING). SLIDE = NON -ROTATED INTERVALS REFLECTING BIT DEPTHS. File Header Service name.............STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 07/02/23 Maximum Physical Record..65535 File Type................LO Previous File Name ....... STSLIB.000 Comment Record FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE START DEPTH STOP DEPTH GR 2993.5 9132.0 FET 2995.0 9139.5 RPD 2995.0 9139.5 RPS 2995.0 9139.5 RPM 2995.0 9139.5 RPX 2995.0 9139.5 ROP 3040.5 9190.0 BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH MERGED DATA SOURCE PBU TOOL CODE MWD MWD MWD BIT RUN NO MERGE TOP 3 2993.5 4 7498.0 5 8050.5 REMARKS: MERGED MAIN PASS. MERGE BASE 7498.0 8050.0 9190.0 # Data Format Specification Record Data Record Type..................0 Data Specification Block Type ..... 0 Logging Direction.................Down Optical log depth units ........... Feet Data Reference Point..............Undefined Frame Spacing.....................60 .1IN Max frames per record.............Undefined Absent value......................-999 Depth Units ....................... Datum Specification Block sub -type ... 0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 RPD MWD OHMM 4 1 68 4 2 RPM MWD OHMM 4 1 68 8 3 RPS MWD OHMM 4 1 68 12 4 RPX MWD OHMM 4 1 68 16 5 FET MWD HOUR 4 1 68 20 6 GR MWD API 4 1 68 24 7 ROP MWD FT/H 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 2993.5 9190 6091.75 12394 2993.5 9190 RPD MWD OHMM 0.23 2000 26.3383 12290 2995 9139.5 RPM MWD OHMM 0.65 2000 27.1147 12290 2995 9139.5 RPS MWD OHMM 0.2 2000 18.4046 12290 2995 9139.5 RPX MWD OHMM 0.9 2000 18.3734 12290 2995 9139.5 FET MWD HOUR 0.16 69.73 1.42666 12290 2995 9139.5 GR MWD API 24.09 122.12 70.2689 12278 2993.5 9132 ROP MWD FT/H 0.2 636.55 213.763 12300 3040.5 9190 First Reading For Entire File .......... 2993.5 Last Reading For Entire File ........... 9190 File Trailer Service name.............STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 07/02/23 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 ....... 07/02/23 Maximum Physical Record..65535 File Type................LO Previous File Name ....... STSLIB.001 Comment Record FILE HEADER FILE NUMBER: 2 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 3 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 2993.5 7451.0 FET 2995.0 7443.5 RPX 2995.0 7443.5 RPS 2995.0 7443.5 RPM 2995.0 7443.5 RPD 2995.0 7443.5 ROP 3040.5 7498.0 LOG HEADER DATA DATE LOGGED: 08-OCT-06 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 72.13 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 7498.0 TOP LOG INTERVAL (FT): 3040.0 BOTTOM LOG INTERVAL (FT): 7498.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 59.3 MAXIMUM ANGLE: 85.5 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 103770 EWR4 ELECTROMAG. RESIS. 4 127479 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 9.875 DRILLER'S CASING DEPTH (FT): 3009.0 BOREHOLE CONDITIONS MUD TYPE: Other MUD DENSITY (LB/G): 9.10 MUD VISCOSITY (S): 58.0 MUD PH: 8.4 MUD CHLORIDES (PPM): 100 FLUID LOSS (C3): 6.8 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): 4.100 70.0 MUD AT MAX CIRCULATING TERMPERATURE: 3.040 96.8 MUD FILTRATE AT MT: 5.400 65.0 MUD CAKE AT MT: 3.300 65.0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: Data Format Specification Record Data Record Type..................0 Data Specification Block Type ..... 0 Logging Direction.................Down Optical log depth units ........... Feet Data Reference Point..............Undefined Frame Spacing.....................60 .1IN Max frames per record.............Undefined Absent value.......................999 Depth Units ....................... Datum Specification Block sub -type ... 0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 RPD MWD030 OHMM 4 1 68 4 2 RPM MWD030 OHMM 4 1 68 8 3 RPS MWD030 OHMM 4 1 68 12 4 RPX MWD030 OHMM 4 1 68 16 5 FET MWD030 HOUR 4 1 68 20 6 GR MWD030 API 4 1 68 24 7 ROP MWD030 FT/H 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 2993.5 7498 5245.75 9010 2993.5 7498 RPD MWD030 OHMM 1.9 2000 17.3949 8898 2995 7443.5 RPM MWD030 OHMM 1.48 1651.33 14.8698 8898 2995 7443.5 RPS MWD030 OHMM 0.2 136.25 13.4381 8898 2995 7443.5 RPX MWD030 OHMM 0.9 131.81 12.6341 8898 2995 7443.5 FET MWD030 HOUR 0.17 56.28 0.931726 8898 2995 7443.5 GR MWD030 API 24.09 122.12 70.5094 8916 2993.5 7451 ROP MWD030 FT/H 7.57 636.55 208.837 8916 3040.5 7498 First Reading For Entire File .......... 2993.5 Last Reading For Entire File ........... 7498 File Trailer Service name.............STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 07/02/23 Maximum Physical Record..65535 File Type................LO Next File Name ........... STSLIB.003 Physical EOF File Header Service name.............STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 07/02/23 Maximum Physical Record..65535 File Type................LO Previous File Name ....... STSLIB.002 Comment Record FILE HEADER FILE NUMBER: 3 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 4 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH FET 7444.0 8050.0 RPS 7444.0 8050.0 RPX 7444.0 8050.0 RPM 7444.0 8050.0 RPD 7444.0 8050.0 GR 7451.5 8050.0 ROP 7498.5 8050.0 LOG HEADER DATA DATE LOGGED: 11-OCT-06 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 68.18 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 8050.0 TOP LOG INTERVAL (FT): 7498.0 BOTTOM LOG INTERVAL (FT): 8050.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 85.7 MAXIMUM ANGLE: 91.1 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 156436 EWR4 Electromag Resis. 4 162742 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 6.750 DRILLER'S CASING DEPTH (FT): 7493.0 BOREHOLE CONDITIONS MUD TYPE: Mineral Oil Base MUD DENSITY (LB/G): 8.80 MUD VISCOSITY (S): 74.0 MUD PH: .0 MUD CHLORIDES (PPM): 26000 FLUID LOSS (C3): 3.8 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) ft MUD AT MEASURED TEMPERATURE (MT): .000 .0 MUD AT MAX CIRCULATING TERMPERATURE: .000 97.0 MUD FILTRATE AT MT: .000 .0 MUD CAKE AT MT: .000 .0 NEUTRON TOOL MATRIX: MATRIX DENSITY: 11 HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: Data Format Specification Record Data Record Type..................0 Data Specification Block Type ..... 0 Logging Direction.................Down Optical log depth units ........... Feet Data Reference Point..............Undefined Frame Spacing.....................60 .1IN Max frames per record.............Undefined Absent value.......................999 Depth Units ....................... Datum Specification Block sub -type ... 0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 RPD MWD040 OHMM 4 1 68 4 2 RPM MWD040 OHMM 4 1 68 8 3 RPS MWD040 OHMM 4 1 68 12 4 RPX MWD040 OHMM 4 1 68 16 5 FET MWD040 HOUR 4 1 68 20 6 GR MWD040 API 4 1 68 24 7 ROP MWD040 FT/H 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 7444 8050 7747 1213 7444 8050 RPD MWD040 OHMM 0.23 2000 81.6044 1213 7444 8050 RPM MWD040 OHMM 0.65 2000 100.344 1213 7444 8050 RPS MWD040 OHMM 6.44 2000 29.5445 1213 7444 8050 RPX MWD040 OHMM 5.01 2000 28.8257 1213 7444 8050 FET MWD040 HOUR 0.18 69.73 6.87074 1213 7444 8050 GR MWD040 API 29.69 102.74 67.1852 1198 7451.5 8050 ROP MWD040 FT/H 30.15 386.42 216.237 1104 7498.5 8050 First Reading For Entire File.......... 7444 Last Reading For Entire File ........... 8050 File Trailer Service name.............STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 07/02/23 Maximum Physical Record..65535 File Type................LO Next File Name ........... STSLIB.004 Physical EOF File Header Service name.............STSLIB.004 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 07/02/23 Maximum Physical Record..65535 File Type................LO Previous File Name ....... STSLIB.003 Comment Record FILE HEADER FILE NUMBER: 4 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 5 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH RPM 8050.5 9139.5 RPX 8050.5 9139.5 ROP 8050.5 9190.0 RPD 8050.5 9139.5 GR 8050.5 9132.0 FET 8050.5 9139.5 RPS 8050.5 9139.5 # LOG HEADER DATA DATE LOGGED: 12-OCT-06 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 68.18 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 9190.0 TOP LOG INTERVAL (FT): 8050.0 BOTTOM LOG INTERVAL (FT): 9190.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 87.8 MAXIMUM ANGLE: 92.3 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 156436 EWR4 Electromag Resis. 4 162742 # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 6.750 DRILLER'S CASING DEPTH (FT): 7493.0 BOREHOLE CONDITIONS MUD TYPE: Mineral Oil Base MUD DENSITY (LB/G): 8.80 MUD VISCOSITY (S): 81.0 MUD PH: .0 MUD CHLORIDES (PPM): 21000 FLUID LOSS (C3): 3.6 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): .000 .0 MUD AT MAX CIRCULATING TERMPERATURE: .000 104.0 MUD FILTRATE AT MT: .000 .0 MUD CAKE AT MT: .000 .0 # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: Data Format Specification Record Data Record Type..................0 Data Specification Block Type ..... 0 Logging Direction.................Down Optical log depth units ........... Feet Data Reference Point..............Undefined Frame Spacing.....................60 .1IN Max frames per record.............Undefined Absent value.......................999 Depth Units ....................... Datum Specification Block sub -type ... 0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 RPD MWD050 OHMM 4 1 68 4 2 RPM MWD050 OHMM 4 1 68 8 3 RPS MWD050 OHMM 4 1 68 12 4 RPX MWD050 OHMM 4 1 68 16 5 FET MWD050 HOUR 4 1 68 20 6 GR MWD050 API 4 1 68 24 7 ROP MWD050 FT/H 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 8050.5 9190 8620.25 2280 8050.5 9190 RPD MWD050 OHMM 6.72 74.38 32.0936 2179 8050.5 9139.5 RPM MWD050 OHMM 5.73 82.79 36.3524 2179 8050.5 9139.5 RPS MWD050 OHMM 5.37 97.71 32.4841 2179 8050.5 9139.5 RPX MWD050 OHMM 5.28 125.86 35.9917 2179 8050.5 9139.5 FET MWD050 HOUR 0.16 10.86 0.417155 2179 8050.5 9139.5 GR MWD050 API 46.08 112.09 70.985 2164 8050.5 9132 ROP MWD050 FT/H 0.2 379.84 231.828 2280 8050.5 9190 First Reading For Entire File .......... 8050.5 Last Reading For Entire File ........... 9190 File Trailer Service name.............STSLIB.004 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 07/02/23 Maximum Physical Record..65535 File Type................LO Next File Name ........... STSLIB.005 Physical EOF Tape Trailer Service name.............LISTPE Date .....................07/02/23 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 .....................07/02/23 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 F Sperry -Sun Drilling Services LIS Scan Utility $Revision: 3 $ LisLib $Revision: 4 $ Fri Feb 23 10:37:51 2007 Reel Header Service name.............LISTPE Date .....................07/02/23 Origin...................STS Reel Name................UNKNOWN Continuation Number ...... 01 Previous Reel Name....... UNKNOWN Comments.................STS LIS Writing Library. Tape Header Service name.............LISTPE Date .....................07/02/23 origin...................STS Tape Name................UNKNOWN Continuation Number ...... 01 Previous Tape Name....... UNKNOWN Comments.................STS LIS Writing Library. Physical EOF a Scientific Technical Services Scientific Technical Services Comment Record TAPE HEADER West Sak MWD/MAD LOGS WELL NAME: 1J-115 PB3 API NUMBER: 500292332072 OPERATOR: ConocoPhillips Alaska, Inc LOGGING COMPANY: Sperry Drilling Services TAPE CREATION DATE: 23-FEB-07 JOB DATA MWD RUN 3 MWD RUN 4 MWD RUN 5 JOB NUMBER: W-0004650390 W-0004650390 W-0004650390 LOGGING ENGINEER: T. GALVIN T. GALVIN T. GALVIN OPERATOR WITNESS: G. WITLOCK G. WITLOCK G. WITLOCK MWD RUN 6 JOB NUMBER: W-0004650390 LOGGING ENGINEER: T. GALVIN OPERATOR WITNESS: G. WHITLOCK SURFACE LOCATION SECTION: 35 TOWNSHIP: 11N RANGE: 10E FNL: FSL: 1973 FEL: 2380 FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: 109.00 GROUND LEVEL: 81.00 WELL CASING RECORD OPEN HOLE CASING DRILLERS 0()G-ca0 1g5b} 0 BIT SIZE (IN) SIZE (IN) DEPTH (FT) 1ST STRING 9.875 10.750 3009.0 2ND STRING 6.750 7.625 7493.0 3RD STRING PRODUCTION STRING REMARKS: 1. ALL DEPTHS ARE MEASURED DEPTHS UNLESS OTHERWISE NOTED. THESE DEPTHS ARE BIT DEPTHS. 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTHS (TVD). 3. THIS WELL IS AN OPEN -HOLE SIDETRACK EXITING THE 1J-115 PB2 WELLBORE AT 8885'MD/3817'TVD. 4. MWD RUN 1 WAS DIRECTIONAL ONLY - NO DATA ARE PRESENTED. 5. MWD RUNS 2-6 COMPRISED DIRECTIONAL, DUAL GAMMA RAY (DGR) UTILIZING GEIGER- MUELLER TUBE DETECTORS, ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4), AND PRESSURE WHILE DRILLING (PWD). MWD RUNS 4-6 ALSO INCLUDED GEO-PILOT ROTARY STEERABLE BHA (GP). NO MWD DATA WERE ACQUIRED ON MWD RUN 2 DUE TO AN MWD FAILURE. 6. DEPTH SHIFTING OF MWD DATA WAS WAIVED PER E-MAIL, DATED 12/16/04, FROM M. WERNER (CPAI) TO R. KALISH (SDS). MWD DATA ARE CONSIDERED PDC. 7. MWD RUNS 1-6 REPRESENT WELL 1J-115 PB3 WITH API#: 50-029-23320-72. THIS WELL REACHED A TOTAL DEPTH (TD) OF 12018'MD/3844'TVD. SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRC = SMOOTHED GAMMA RAY COMBINED. SEXP = SMOOTHED PHASE SHIFT -DERIVED RESISTIVITY (EXTRA SHALLOW SPACING). SESP = SMOOTHED PHASE SHIFT -DERIVED RESISTIVITY (SHALLOW SPACING). SEMP = SMOOTHED PHASE SHIFT -DERIVED RESISTIVITY (MEDIUM SPACING). SEDP = SMOOTHED PHASE SHIFT -DERIVED RESISTIVITY (DEEP SPACING). SFXE = SMOOTHED FORMATION EXPOSURE TIME (DEEP SPACING). SLIDE = NON -ROTATED INTERVALS REFLECTING BIT DEPTHS. File Header Service name.............STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 07/02/23 Maximum Physical Record..65535 File Type................LO Previous File Name ....... STSLIB.000 Comment Record FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE START DEPTH STOP DEPTH GR 2993.5 11960.5 RPD 2995.0 11967.5 RPS 2995.0 11967.5 RPM 2995.0 11967.5 FET 2995.0 11967.5 RPX 2995.0 11967.5 ROP 3040.5 12018.0 BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH # MERGED DATA SOURCE PBU TOOL CODE MWD MWD MWD MWD BIT RUN NO MERGE TOP MERGE BASE 3 2993.5 7498.0 4 7498.0 8050.0 5 8050.5 8885.0 6 8885.5 12018.0 REMARKS: MERGED MAIN PASS. Data Format Specification Record Data Record Type..................0 Data Specification Block Type ..... 0 Logging Direction.................Down Optical log depth units ........... Feet Data Reference Point..............Undefined Frame Spacing.....................60 .1IN Max frames per record.............Undefined Absent value.......................999 Depth Units ....................... Datum Specification Block sub -type ... 0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 RPD MWD OHMM 4 1 68 4 2 RPM MWD OHMM 4 1 68 8 3 RPS MWD OHMM 4 1 68 12 4 RPX MWD OHMM 4 1 68 16 5 FET MWD HOUR 4 1 68 20 6 GR MWD API 4 1 68 24 7 ROP MWD FT/H 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 2993.5 12018 7505.75 18050 2993.5 12018 RPD MWD OHMM 0.23 2000 29.6776 17946 2995 11967.5 RPM MWD OHMM 0.65 2000 33.9257 17946 2995 11967.5 RPS MWD OHMM 0.2 2000 22.5161 17946 2995 11967.5 RPX MWD OHMM 0.9 2000 22.9782 17946 2995 11967.5 FET MWD HOUR 0.12 69.73 1.14248 17946 2995 11967.5 GR MWD API 24.09 122.12 69.1123 17935 2993.5 11960.5 ROP MWD FT/H 0.2 636.55 219.196 17956 3040.5 12018 First Reading For Entire File .......... 2993.5 Last Reading For Entire File ........... 12018 File Trailer Service name.............STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 07/02/23 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 ....... 07/02/23 Maximum Physical Record..65535 File Type................LO Previous File Name ....... STSLIB.001 Comment Record FILE HEADER FILE NUMBER: 2 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 3 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 2993.5 7451.0 RPD 2995.0 7443.5 RPM 2995.0 7443.5 RPX 2995.0 7443.5 RPS 2995.0 7443.5 FET 2995.0 7443.5 ROP 3040.5 7498.0 LOG HEADER DATA DATE LOGGED: 08-OCT-06 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 72.13 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 7498.0 TOP LOG INTERVAL (FT): 3040.0 BOTTOM LOG INTERVAL (FT): 7498.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 59.3 MAXIMUM ANGLE: 85.5 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 103770 EWR4 ELECTROMAG. RESIS. 4 127479 # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 9.875 DRILLER'S CASING DEPTH (FT): 3009.0 # BOREHOLE CONDITIONS MUD TYPE: Other MUD DENSITY (LB/G): 9.10 MUD VISCOSITY (S): 58.0 MUD PH: 8.4 MUD CHLORIDES (PPM): 100 FLUID LOSS (C3): 6.8 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): 4.100 70.0 MUD AT MAX CIRCULATING TERMPERATURE: 3.040 96.8 MUD FILTRATE AT MT: 5.400 65.0 MUD CAKE AT MT: 3.300 65.0 # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format Specification Record Data Record Type..................0 Data Specification Block Type ..... 0 Logging Direction.................Down Optical log depth units ........... Feet Data Reference Point..............Undefined Frame Spacing.....................60 .1IN Max frames per record.............Undefined Absent value.......................999 Depth Units ....................... Datum Specification Block sub -type ... 0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 RPD MWD030 OHMM 4 1 68 4 2 RPM MWD030 OHMM 4 1 68 8 3 RPS MWD030 OHMM 4 1 68 12 4 RPX MWD030 OHMM 4 1 68 16 5 FET MWD030 HOUR 4 1 68 20 6 GR MWD030 API 4 1 68 24 7 ROP MWD030 FT/H 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 2993.5 7498 5245.75 9010 2993.5 7498 RPD MWD030 OHMM 1.9 2000 17.3949 8898 2995 7443.5 RPM MWD030 OHMM 1.48 1651.33 14.8698 8898 2995 7443.5 RPS MWD030 OHMM 0.2 136.25 13.4381 8898 2995 7443.5 RPX MWD030 OHMM 0.9 131.81 12.6341 8898 2995 7443.5 FET MWD030 HOUR 0.17 56.28 0.931726 8898 2995 7443.5 GR MWD030 API 24.09 122.12 70.5094 8916 2993.5 7451 ROP MWD030 FT/H 7.57 636.55 208.837 8916 3040.5 7498 First Reading For Entire File .......... 2993.5 Last Reading For Entire File ........... 7498 File Trailer Service name.............STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 07/02/23 Maximum Physical Record..65535 File Type................LO Next File Name ........... STSLIB.003 Physical EOF File Header Service name.............STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 07/02/23 Maximum Physical Record..65535 File Type................LO Previous File Name ....... STSLIB.002 Comment Record FILE HEADER FILE NUMBER: 3 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 4 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH RPX 7444.0 8050.0 FET 7444.0 8050.0 RPM 7444.0 8050.0 RPD 7444.0 8050.0 RPS 7444.0 8050.0 GR 7451.5 8050.0 ROP 7498.5 8050.0 # LOG HEADER DATA DATE LOGGED: 11-OCT-06 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 68.18 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 8050.0 TOP LOG INTERVAL (FT): 7498.0 BOTTOM LOG INTERVAL (FT): 8050.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 85.7 MAXIMUM ANGLE: 91.1 # TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 156436 EWR4 Electromag Resis. 4 162742 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 6.750 DRILLER'S CASING DEPTH (FT): 7493.0 BOREHOLE CONDITIONS MUD TYPE: Mineral Oil Base MUD DENSITY (LB/G): 8.80 MUD VISCOSITY (S): 74.0 MUD PH: .0 MUD CHLORIDES (PPM): 26000 FLUID LOSS (C3): 3.8 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): .000 .0 MUD AT MAX CIRCULATING TERMPERATURE: .000 97.0 MUD FILTRATE AT MT: .000 .0 MUD CAKE AT MT: .000 .0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format Specification Record Data Record Type..................0 Data Specification Block Type ..... 0 Logging Direction.................Down Optical log depth units ........... Feet Data Reference Point..............Undefined Frame Spacing.....................60 .1IN Max frames per record.............Undefined Absent value.......................999 Depth Units ....................... Datum Specification Block sub -type ... 0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 RPD MWD040 OHMM 4 1 68 4 2 RPM MWD040 OHMM 4 1 68 8 3 RPS MWD040 OHMM 4 1 68 12 4 RPX MWD040 OHMM 4 1 68 16 5 FET MWD040 HOUR 4 1 68 20 6 GR MWD040 API 4 1 68 24 7 ROP MWD040 FT/H 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 7444 8050 7747 1213 7444 8050 RPD MWD040 OHMM 0.23 2000 81.6044 1213 7444 8050 RPM MWD040 OHMM 0.65 2000 100.344 1213 7444 8050 RPS MWD040 OHMM 6.44 2000 29.5445 1213 7444 8050 RPX MWD040 OHMM 5.01 2000 28.8257 1213 7444 8050 FET MWD040 HOUR 0.18 69.73 6.87074 1213 7444 8050 GR MWD040 API 29.69 102.74 67.1852 1198 7451.5 8050 ROP MWD040 FT/H 30.15 386.42 216.237 1104 7498.5 8050 First Reading For Entire File.......... 7444 Last Reading For Entire File ........... 8050 File Trailer Service name.............STSLIB.003 Service Sub Level Name... version Number ........... 1.0.0 Date of Generation ....... 07/02/23 Maximum Physical Record..65535 File Type................LO Next File Name ........... STSLIB.004 Physical EOF File Header Service name.............STSLIB.004 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 07/02/23 Maximum Physical Record..65535 File Type................LO Previous File Name ....... STSLIB.003 Comment Record FILE HEADER FILE NUMBER: 4 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 5 DEPTH INCREMENT: .5000 # FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH RPS 8050.5 8885.0 FET 8050.5 8885.0 RPM 8050.5 8885.0 RPX 8050.5 8885.0 GR 8050.5 8885.0 RPD 8050.5 8885.0 ROP 8050.5 8885.0 LOG HEADER DATA DATE LOGGED: 12-OCT-06 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 68.18 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 8885.0 TOP LOG INTERVAL (FT): 8050.0 BOTTOM LOG INTERVAL (FT): 8885.0. BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 87.8 MAXIMUM ANGLE: 92.3 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 156436 EWR4 Electromag Resis. 4 162742 # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 6.750 DRILLER'S CASING DEPTH (FT): 7493.0 # BOREHOLE CONDITIONS MUD TYPE: Mineral Oil Base MUD DENSITY (LB/G): 8.80 MUD VISCOSITY (S): 81.0 MUD PH: .0 MUD CHLORIDES (PPM): 21000 FLUID LOSS (C3): 3.6 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): .000 .0 MUD AT MAX CIRCULATING TERMPERATURE: .000 104.0 MUD FILTRATE AT MT: .000 .0 MUD CAKE AT MT: .000 .0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: # Data Format Specification Record Data Record Type..................0 Data Specification Block Type ..... 0 Logging Direction.................Down Optical log depth units ........... Feet Data Reference Point..............Undefined Frame Spacing.....................60 .1IN Max frames per record.............Undefined Absent value.......................999 Depth Units ....................... Datum Specification Block sub -type ... 0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 RPD MWD050 OHMM 4 1 68 4 2 RPM MWD050 OHMM 4 1 68 8 3 RPS MWD050 OHMM 4 1 68 12 4 RPX MWD050 OHMM 4 1 68 16 5 FET MWD050 HOUR 4 1 68 20 6 GR MWD050 API 4 1 68 24 7 ROP MWD050 FT/H 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 8050.5 8885 8467.75 1670 8050.5 8885 RPD MWD050 OHMM 12.24 66.53 34.0975 1670 8050.5 8885 RPM MWD050 OHMM 10.43 82.79 40.34 1670 8050.5 8885 RPS MWD050 OHMM 9.65 97.71 36.9006 1670 8050.5 8885 RPX MWD050 OHMM 9.5 125.86 41.4908 1670 8050.5 8885 FET MWD050 HOUR 0.16 10.86 0.396431 1670 8050.5 8885 GR MWD050 API 46.98 101.51 67.401 1670 8050.5 8885 ROP MWD050 FT/H 0.2 379.84 246.559 1670 8050.5 8885 First Reading For Entire File .......... 8050.5 Last Reading For Entire File ........... 8885 File Trailer Service name.............STSLIB.004 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 07/02/23 Maximum Physical Record..65535 File Type................LO Next File Name ........... STSLIB.005 Physical EOF File Header Service name.............STSLIB.005 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 07/02/23 Maximum Physical Record..65535 0 File Type................LO Previous File Name ....... STSLIB.004 Comment Record FILE HEADER FILE NUMBER: 5 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 6 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH RPM 8885.5 11967.5 ROP 8885.5 12018.0 RPX 8885.5 11967.5 RPS 8885.5 11967.5 RPD 8885.5 11967.5 GR 8885.5 11960.5 FET 8885.5 11967.5 LOG HEADER DATA DATE LOGGED: 13-OCT-06 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 68.18 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 12018.0 TOP LOG INTERVAL (FT): 8885.0 BOTTOM LOG INTERVAL (FT): 12018.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 87.9 MAXIMUM ANGLE: 92.3 # TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 156436 EWR4 Electromag Resis. 4 162742 # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 6.750 DRILLER'S CASING DEPTH (FT): 7493.0 BOREHOLE CONDITIONS MUD TYPE: Mineral Oil Base MUD DENSITY (LB/G): 8.80 MUD VISCOSITY (S): 79.0 MUD PH: .0 MUD CHLORIDES (PPM): 18500 FLUID LOSS (C3): 3.6 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): .000 .0 MUD AT MAX CIRCULATING TERMPERATURE: .000 111.0 MUD FILTRATE AT MT: .000 .0 MUD CAKE AT MT: .000 .0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: S Data Format Specification Record Data Record Type..................0 Data Specification Block Type ..... 0 Logging Direction.................Down Optical log depth units ........... Feet Data Reference Point..............Undefined Frame Spacing.....................60 .1IN Max frames per record.............Undefined Absent value.......................999 Depth Units ....................... Datum Specification Block sub -type ... 0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 RPD MWD060 OHMM 4 1 68 4 2 RPM MWD060 OHMM 4 1 68 8 3 RPS MWD060 OHMM 4 1 68 12 4 RPX MWD060 OHMM 4 1 68 16 5 FET MWD060 HOUR 4 1 68 20 6 GR MWD060 API 4 1 68 24 7 ROP MWD060 FT/H 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 8885.5 12018 10451.8 6266 8885.5 12018 RPD MWD060 OHMM 6.32 1307.18 35.9911 6165 8885.5 11967.5 RPM MWD060 OHMM 5.91 2000 46.6236 6165 8885.5 11967.5 RPS MWD060 OHMM 5.42 102.93 30.339 6165 8885.5 11967.5 RPX MWD060 OHMM 5.34 77.58 31.7428 6165 8885.5 11967.5 FET MWD060 HOUR 0.12 9.15 0.521679 6165 8885.5 11967.5 GR MWD060 API 36.82 111.93 67.9271 6151 8885.5 11960.5 ROP MWD060 FT/H 1.07 614.69 227.166 6266 8885.5 12018 First Reading For Entire File .......... 8885.5 Last Reading For Entire File ........... 12018 File Trailer Service name.............STSLIB.005 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 07/02/23 Maximum Physical Record..65535 File Type................LO Next File Name ........... STSLIB.006 Physical EOF Tape Trailer Service name.............LISTPE Date .....................07/02/23 origin...................STS Tape Name................UNKNOWN Continuation Number ...... 01 Next Tape Name ........... UNKNOWN Comments.................STS LIS Writing Library Reel Trailer Service name.............LISTPE Date .....................07/02/23 origin...................STS Scientific Technical Services 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 0 Sperry -Sun Drilling Services LIS Scan Utility $Revision: 3 $ LisLib $Revision: 4 $ Mon Feb 26 10:09:03 2007 Reel Header Service name.............LISTPE Date .....................07/02/26 origin...................STS Reel Name................UNKNOWN Continuation Number ...... 01 Previous Reel Name....... UNKNOWN Comments.................STS LIS Writing Library. Tape Header Service name.............LISTPE Date .....................07/02/26 origin...................STS Tape Name................UNKNOWN Continuation Number ...... 01 Previous Tape Name....... UNKNOWN Comments.................STS LIS Writing Library Physical EOF Comment Record TAPE HEADER West Sak MWD/MAD LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: # JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: Scientific Technical Services Scientific Technical Services 1J-115 PB4 500292332073 ConocoPhillips Alaska, Inc Sperry Drilling Services 26-FEB-07 MWD RUN 3 MWD RUN 4 MWD RUN 5 W-0004650390 W-0004650390 W-0004650390 T. GALVIN T. GALVIN T. GALVIN G. WHITLOCK G. WHITLOCK G. WHITLOCK MWD RUN 6 MWD RUN 7 W-0004650390 W-0004650390 T. GALVIN T. GALVIN G. WHITLOCK G. WHITLOCK # SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD OPEN HOLE _c a 2 35 11N 10E 1973 2380 109.00 81.00 CASING DRILLERS t�5C5� 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING REMARKS: 0 • BIT SIZE (IN) SIZE (IN) DEPTH (FT) 9.875 10.750 3009.0 6.750 7.625 7493.0 1. ALL DEPTHS ARE MEASURED DEPTHS UNLESS OTHERWISE NOTED. THESE DEPTHS ARE BIT DEPTHS. 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTHS (TVD). 3. THIS WELL IS AN OPEN -HOLE SIDETRACK EXITING THE 1J-115 PB3 WELLBORE AT 11690'MD/3840'TVD. 4. MWD RUN 1 WAS DIRECTIONAL ONLY - NO DATA ARE PRESENTED. 5. MWD RUNS 2-7 COMPRISED DIRECTIONAL, DUAL GAMMA RAY (DGR) UTILIZING GEIGER- MUELLER TUBE DETECTORS, ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4), AND PRESSURE WHILE DRILLING (PWD). MWD RUNS 4-7 ALSO INCLUDED GEO-PILOT ROTARY STEERABLE BHA (GP). NO MWD DATA WERE ACQUIRED ON MWD RUN 2 DUE TO AN MWD FAILURE. 6. DEPTH SHIFTING OF MWD DATA WAS WAIVED PER E-MAIL, DATED 12/16/04, FROM M. WERNER (CPAI) TO R. KALISH (SDS). MWD DATA ARE CONSIDERED PDC. 7. MWD RUNS 1-7 REPRESENT WELL 1J-115 PB4 WITH API#: 50-029-23320-73. THIS WELL REACHED A TOTAL DEPTH (TD) OF 12829'MD/3896'TVD. SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRC = SMOOTHED GAMMA RAY COMBINED. SEXP = SMOOTHED PHASE SHIFT -DERIVED RESISTIVITY (EXTRA SHALLOW SPACING). SESP = SMOOTHED PHASE SHIFT -DERIVED RESISTIVITY (SHALLOW SPACING). SEMP = SMOOTHED PHASE SHIFT -DERIVED RESISTIVITY (MEDIUM SPACING). SEDP = SMOOTHED PHASE SHIFT -DERIVED RESISTIVITY (DEEP SPACING). SFXE = SMOOTHED FORMATION EXPOSURE TIME (DEEP SPACING). SLIDE = NON -ROTATED INTERVALS REFLECTING BIT DEPTHS. File Header Service name.............STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 07/02/26 Maximum Physical Record..65535 File Type................LO Previous File Name ....... STSLIB.000 Comment Record FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: FILE SUMMARY PBU TOOL CODE GR FET RPX RPM RPD RPS ROP 5000 START DEPTH 2993.5 2995.0 2995.0 2995.0 2995.0 2995.0 3040.5 STOP DEPTH 12771.0 12778.5 12778.5 12778.5 12778.5 12778.5 12829.0 BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH MERGED DATA SOURCE PBU TOOL CODE MWD MWD MWD MWD MWD BIT RUN NO MERGE TOP 3 2993.5 4 7498.0 5 8050.5 6 8885.5 7 11690.5 REMARKS: MERGED MAIN PASS. MERGE BASE 7498.0 8050.0 8885.0 11690.0 12829.0 # Data Format Specification Record Data Record Type..................0 Data Specification Block Type ..... 0 Logging Direction.................Down Optical log depth units ........... Feet Data Reference Point..............Undefined Frame Spacing.....................60 .1IN Max frames per record.............Undefined Absent value.......................999 Depth Units ....................... Datum Specification Block sub -type ... 0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 RPD MWD OHMM 4 1 68 4 2 RPM MWD OHMM 4 1 68 8 3 RPS MWD OHMM 4 1 68 12 4 RPX MWD OHMM 4 1 68 16 5 FET MWD HOUR 4 1 68 20 6 GR MWD API 4 1 68 24 7 ROP MWD FT/H 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 2993.5 12829 7911.25 19672 2993.5 12829 RPD MWD OHMM 0.23 2000 28.8956 19568 2995 12778.5 RPM MWD OHMM 0.65 2000 32.8739 19568 2995 12778.5 RPS MWD OHMM 0.2 2000 22.1096 19568 2995 12778.5 RPX MWD OHMM 0.9 2000 22.5178 19568 2995 12778.5 FET MWD HOUR 0.12 69.73 1.12123 19568 2995 12778.5 GR MWD API 24.09 122.12 69.2012 19556 2993.5 12771 ROP MWD FT/H 0.12 636.55 215.186 19578 3040.5 12829 First Reading For Entire File .......... 2993.5 Last Reading For Entire File ........... 12829 File Trailer Service name.............STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 07/02/26 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 ....... 07/02/26 Maximum Physical Record..65535 File Type................LO Previous File Name ....... STSLIB.001 Comment Record FILE HEADER FILE NUMBER: 2 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 3 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 2993.5 7451.0 RPD 2995.0 7443.5 RPM 2995.0 7443.5 RPX 2995.0 7443.5 RPS 2995.0 7443.5 FET 2995.0 7443.5 ROP 3040.5 7498.0 LOG HEADER DATA DATE LOGGED: 08-OCT-06 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 72.13 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 7498.0 TOP LOG INTERVAL (FT): 3040.0 BOTTOM LOG INTERVAL (FT): 7498.0 BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: 59.3 MAXIMUM ANGLE: 85.5 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 103770 EWR4 ELECTROMAG. RESIS. 4 127479 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 9.875 DRILLER'S CASING DEPTH (FT): 3009.0 # BOREHOLE CONDITIONS MUD TYPE: Other MUD DENSITY (LB/G): 9.10 MUD VISCOSITY (S): 58.0 MUD PH: 8.4 MUD CHLORIDES (PPM): 100 FLUID LOSS (C3): 6.8 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): 4.100 70.0 MUD AT MAX CIRCULATING TERMPERATURE: 3.040 96.8 MUD FILTRATE AT MT: 5.400 65.0 MUD CAKE AT MT: 3.300 65.0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: # Data Format Specification Record Data Record Type..................0 Data Specification Block Type ..... 0 Logging Direction.................Down Optical log depth units ........... Feet Data Reference Point..............Undefined Frame Spacing.....................60 .1IN Max frames per record.............Undefined Absent value.......................999 Depth Units ....................... Datum Specification Block sub -type ... 0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 RPD MWD030 OHMM 4 1 68 4 2 RPM MWD030 OHMM 4 1 68 8 3 RPS MWD030 OHMM 4 1 68 12 4 RPX MWD030 OHMM 4 1 68 16 5 FET MWD030 HOUR 4 1 68 20 6 GR MWD030 API 4 1 68 24 7 ROP MWD030 FT/H 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 2993.5 7498 5245.75 9010 2993.5 7498 RPD MWD030 OHMM 1.9 2000 17.3949 8898 2995 7443.5 RPM MWD030 OHMM 1.48 1651.33 14.8698 8898 2995 7443.5 RPS MWD030 OHMM 0.2 136.25 13.4381 8898 2995 7443.5 RPX MWD030 OHMM 0.9 131.81 12.6341 8898 2995 7443.5 FET MWD030 HOUR 0.17 56.28 0.931726 8898 2995 7443.5 GR MWD030 API 24.09 122.12 70.5094 8916 2993.5 7451 ROP MWD030 FT/H 7.57 636.55 208.837 8916 3040.5 7498 First Reading For Entire File .......... 2993.5 Last Reading For Entire File ........... 7498 File Trailer Service name.............STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 07/02/26 Maximum Physical Record..65535 File Type................LO Next File Name ........... STSLIB.003 Physical EOF File Header Service name.............STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 07/02/26 Maximum Physical Record..65535 File Type................LO Previous File Name ....... STSLIB.002 Comment Record FILE HEADER FILE NUMBER: 3 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 4 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH FET 7444.0 8050.0 RPX 7444.0 8050.0 RPD 7444.0 8050.0 RPS 7444.0 8050.0 RPM 7444.0 8050.0 GR 7451.5 8050.0 ROP 7498.5 8050.0 LOG HEADER DATA DATE LOGGED: 11-OCT-06 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 68.18 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 8050.0 TOP LOG INTERVAL (FT): 7498.0 BOTTOM LOG INTERVAL (FT): 8050.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 85.7 MAXIMUM ANGLE: 91.1 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 156436 EWR4 Electromag Resis. 4 162742 # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 6.750 DRILLER'S CASING DEPTH (FT): 7493.0 BOREHOLE CONDITIONS MUD TYPE: Mineral Oil Base MUD DENSITY (LB/G): 8.80 MUD VISCOSITY (S): 74.0 MUD PH: .0 MUD CHLORIDES (PPM): 26000 FLUID LOSS (C3): 3.8 0 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): .000 MUD AT MAX CIRCULATING TERMPERATURE: .000 MUD FILTRATE AT MT: .000 MUD CAKE AT MT: .000 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: # Data Format Specification Record Data Record Type..................0 Data Specification Block Type ..... 0 Logging Direction.................Down Optical log depth units ........... Feet Data Reference Point..............Undefined Frame Spacing.....................60 .1IN Max frames per record.............Undefined Absent value.......................999 Depth Units ....................... Datum Specification Block sub -type ... 0 Name Service Order Units Size Nsam Rep Code Offset Channel .0 97.0 .0 .0 DEPT FT 4 1 68 0 1 RPD MWD040 OHMM 4 1 68 4 2 RPM MWD040 OHMM 4 1 68 8 3 RPS MWD040 OHMM 4 1 68 12 4 RPX MWD040 OHMM 4 1 68 16 5 FET MWD040 HOUR 4 1 68 20 6 GR MWD040 API 4 1 68 24 7 ROP MWD040 FT/H 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 7444 8050 7747 1213 7444 8050 RPD MWD040 OHMM 0.23 2000 81.6044 1213 7444 8050 RPM MWD040 OHMM 0.65 2000 100.344 1213 7444 8050 RPS MWD040 OHMM 6.44 2000 29.5445 1213 7444 8050 RPX MWD040 OHMM 5.01 2000 28.8257 1213 7444 8050 FET MWD040 HOUR 0.18 69.73 6.87074 1213 7444 8050 GR MWD040 API 29.69 102.74 67.1852 1198 7451.5 8050 ROP MWD040 FT/H 30.15 386.42 216.237 1104 7498.5 8050 First Reading For Entire File.......... 7444 Last Reading For Entire File ........... 8050 File Trailer Service name.............STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 07/02/26 Maximum Physical Record..65535 File Type................LO Next File Name ........... STSLIB.004 • Physical EOF • File Header Service name.............STSLIB.004 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 07/02/26 Maximum Physical Record..65535 File Type................LO Previous File Name ....... STSLIB.003 Comment Record FILE HEADER FILE NUMBER: 4 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 5 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH RPX 8050.5 8885.0 RPM 8050.5 8885.0 RPS 8050.5 8885.0 RPD 8050.5 8885.0 FET 8050.5 8885.0 ROP 8050.5 8885.0 GR 8050.5 8885.0 LOG HEADER DATA DATE LOGGED: 12-OCT-06 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 68.18 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 8885.0 TOP LOG INTERVAL (FT): 8050.0 BOTTOM LOG INTERVAL (FT): 8885.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 87.8 MAXIMUM ANGLE: 92.3 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 156436 EWR4 Electromag Resis. 4 162742 $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 6.750 DRILLER'S CASING DEPTH (FT): 7493.0 # BOREHOLE CONDITIONS MUD TYPE: Mineral Oil Base MUD DENSITY (LB/G): 8.80 MUD VISCOSITY (S): 81.0 MUD PH: .0 MUD CHLORIDES (PPM): 21000 FLUID LOSS (C3): 3.6 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): .000 .0 MUD AT MAX CIRCULATING TERMPERATURE: .000 104.0 MUD FILTRATE AT MT: .000 .0 MUD CAKE AT MT: .000 .0 # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: # Data Format Specification Record Data Record Type..................0 Data Specification Block Type ..... 0 Logging Direction.................Down Optical log depth units ........... Feet Data Reference Point..............Undefined Frame Spacing.....................60 .1IN Max frames per record.............Undefined Absent value.......................999 Depth Units ....................... Datum Specification Block sub -type ... 0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 RPD MWD050 OHMM 4 1 68 4 2 RPM MWD050 OHMM 4 1 68 8 3 RPS MWD050 OHMM 4 1 68 12 4 RPX MWD050 OHMM 4 1 68 16 5 FET MWD050 HOUR 4 1 68 20 6 GR MWD050 API 4 1 68 24 7 ROP MWD050 FT/H 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 8050.5 8885 8467.75 1670 8050.5 8885 RPD MWD050 OHMM 12.24 66.53 34.0975 1670 8050.5 8885 RPM MWD050 OHMM 10.43 82.79 40.34 1670 8050.5 8885 RPS MWD050 OHMM 9.65 97.71 36.9006 1670 8050.5 8885 RPX MWD050 OHMM 9.5 125.86 41.4908 1670 8050.5 8885 FET MWD050 HOUR 0.16 10.86 0.396431 1670 8050.5 8885 GR MWD050 API 46.98 101.51 67.401 1670 8050.5 8885 ROP MWD050 FT/H 0.2 379.84 246.559 1670 8050.5 8885 First Reading For Entire File .......... 8050.5 Last Reading For Entire File ........... 8885 File Trailer Service name.............STSLIB.004 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 07/02/26 Maximum Physical Record..65535 File Type................LO Next File Name ........... STSLIB.005 Physical EOF File Header Service name.............STSLIB.005 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 07/02/26 • • Maximum Physical Record..65535 File Type................LO Previous File Name ....... STSLIB.004 Comment Record FILE HEADER FILE NUMBER: 5 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 6 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH RPX 8885.5 11690.0 FET 8885.5 11690.0 RPS 8885.5 11690.0 RPM 8885.5 11690.0 GR 8885.5 11690.0 RPD 8885.5 11690.0 ROP 8885.5 11690.0 LOG HEADER DATA DATE LOGGED: 13-OCT-06 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 68.18 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 11690.0 TOP LOG INTERVAL (FT): 8885.0 BOTTOM LOG INTERVAL (FT): 11690.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 87.9 MAXIMUM ANGLE: 92.3 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 156436 EWR4 Electromag Resis. 4 162742 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 6.750 DRILLER'S CASING DEPTH (FT): 7493.0 BOREHOLE CONDITIONS MUD TYPE: Mineral Oil Base MUD DENSITY (LB/G): 8.80 MUD VISCOSITY (S): 79.0 MUD PH: .0 MUD CHLORIDES (PPM): 18500 FLUID LOSS (C3): 3.6 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): .000 .0 MUD AT MAX CIRCULATING TERMPERATURE: .000 111.0 MUD FILTRATE AT MT: .000 .0 MUD CAKE AT MT: .000 .0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # • REMARKS: • Data Format Specification Record Data Record Type..................0 Data Specification Block Type ..... 0 Logging Direction.................Down Optical log depth units ........... Feet Data Reference Point..............Undefined Frame Spacing.....................60 .1IN Max frames per record.............Undefined Absent value.......................999 Depth Units ....................... Datum Specification Block sub -type ... 0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 RPD MWD060 OHMM 4 1 68 4 2 RPM MWD060 OHMM 4 1 68 8 3 RPS MWD060 OHMM 4 1 68 12 4 RPX MWD060 OHMM 4 1 68 16 5 FET MWD060 HOUR 4 1 68 20 6 GR MWD060 API 4 1 68 24 7 ROP MWD060 FT/H 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 8885.5 11690 10287.8 5610 8885.5 11690 RPD MWD060 OHMM 13.29 1307.18 38.4249 5610 8885.5 11690 RPM MWD060 OHMM 11.89 2000 50.0649 5610 8885.5 11690 RPS MWD060 OHMM 10.26 102.93 32.3644 5610 8885.5 11690 RPX MWD060 OHMM 7.51 77.58 33.9457 5610 8885.5 11690 FET MWD060 HOUR 0.12 9.15 0.517426 5610 8885.5 11690 GR MWD060 API 36.82 98.26 65.8482 5610 8885.5 11690 ROP MWD060 FT/H 1.07 614.69 230.722 5610 8885.5 11690 First Reading For Entire File .......... 8885.5 Last Reading For Entire File ........... 11690 File Trailer Service name.............STSLIB.005 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 07/02/26 Maximum Physical Record..65535 File Type................LO Next File Name ........... STSLIB.006 Physical EOF File Header Service name.............STSLIB.006 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 07/02/26 Maximum Physical Record..65535 File Type................LO Previous File Name ....... STSLIB.005 Comment Record FILE HEADER FILE NUMBER: 6 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 7 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH RPM 11690.5 12778.5 ROP 11690.5 12829.0 RPS 11690.5 12778.5 RPD 11690.5 12778.5 GR 11690.5 12771.0 FET 11690.5 12778.5 RPX 11690.5 12778.5 $ LOG HEADER DATA DATE LOGGED: 14-OCT-06 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 68.18 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 12829.0 TOP LOG INTERVAL (FT): 11690.0 BOTTOM LOG INTERVAL (FT): 12829.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 85.1 MAXIMUM ANGLE: 89.3 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 156436 EWR4 Electromag Resis. 4 162742 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 6.750 DRILLER'S CASING DEPTH (FT): 7493.0 BOREHOLE CONDITIONS MUD TYPE: Mineral Oil Base MUD DENSITY (LB/G): 8.70 MUD VISCOSITY (S): 79.0 MUD PH: •0 MUD CHLORIDES (PPM): 18500 FLUID LOSS (C3): 3.8 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): .000 .0 MUD AT MAX CIRCULATING TERMPERATURE: .000 111.0 MUD FILTRATE AT MT: .000 .0 MUD CAKE AT MT: .000 .0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format.Specification Record Data Record Type..................0 Data Specification Block Type ..... 0 Logging Direction.................Down Optical log depth units ........... Feet Data Reference Point..............Undefined Frame Spacing.....................60 .1IN Max frames per record.............Undefined Absent value.......................999 Depth Units ....................... Datum Specification Block sub -type ... 0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 RPD MWD070 OHMM 4 1 68 4 2 RPM MWD070 OHMM 4 1 68 8 3 RPS MWD070 OHMM 4 1 68 12 4 RPX MWD070 OHMM 4 1 68 16 5 FET MWD070 HOUR 4 1 68 20 6 GR MWD070 API 4 1 68 24 7 ROP MWD070 FT/H 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 11690.5 12829 12259.8 2278 11690.5 12829 RPD MWD070 OHMM 4.9 67.21 17.9867 2177 11690.5 12778.5 RPM MWD070 OHMM 4.84 154.72 18.8408 2177 11690.5 12778.5 RPS MWD070 OHMM 4.66 100.26 15.6377 2177 11690.5 12778.5 RPX MWD070 OHMM 4.61 69.25 15.3972 2177 11690.5 12778.5 FET MWD070 HOUR 0.19 9.86 0.804194 2177 11690.5 12778.5 GR MWD070 API 46.14 96.85 75.0147 2162 11690.5 12771 ROP MWD070 FT/H 0.12 457.5 178.265 2278 11690.5 12829 First Reading For Entire File .......... 11690.5 Last Reading For Entire File ........... 12829 File Trailer Service name.............STSLIB.006 Service Sub Level Name... version Number ........... 1.0.0 Date of Generation ....... 07/02/26 Maximum Physical Record..65535 File Type................LO Next File Name ........... STSLIB.007 Physical EOF Tape Trailer Service name.............LISTPE Date .....................07/02/26 origin...................STS Tape Name................UNKNOWN Continuation Number ...... 01 Next Tape Name ........... UNKNOWN Comments.................STS LIS Writing Library Reel Trailer Service name.............LISTPE Date .....................07/02/26 origin...................STS Reel Name................UNKNOWN Continuation Number ...... 01 Next Reel Name ........... UNKNOWN Comments.................STS LIS Writing Library Scientific Technical Services Scientific Technical Services • • Physical EOF Physical EOF End Of LIS File