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206-123
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 13922'feet None feet true vertical 3775' feet None feet Effective Depth measured 13922'feet 5962', 6198'feet true vertical 3775' feet 3521', 3574'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 N/A 3521' TVD 3574' 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 B-Sand Liner 7467' 7170' Casing 3808' 4-1/2" 7493' 13913' 3774' 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 206-123 50-029-23320-60-00 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-115L1 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 SSSV: None Will Parker will.parker@conocophillips.com (907) 265-6239Senior Production Engineer Alternating Slotted Pipe: 6540-13166', 13382-13940' Alternating Slotted Pipe: 3642-3748', 3748-3774' 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 9:15 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 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 ❑ Operations shutdown ❑ Performed: Suspend ❑ Perforate ❑ Other Stimulate ❑ Alter Casing ❑AQf�d�,,rr� eJ Program ElPlug for Redrill Elerforate New Pool E] RepairWell ElRe-enter Susp Well ❑ AI G=ESP to GL ❑v 2. Operator Name: ConocoPhillips Alaska, Inc. 4. Well Class Before Work: 5. Permit to Drill Number: Development Er VT-L� Exploratory ❑ 206-123 Stratigraphic ❑ Service jg 6. API Number: 3. Address: P. O. Box 100360, Anchorage, Alaska 99510 v r'' 50-029-23320-60 7. Property Designation (Lease Number): 8. Well Name and Number: ADL 25650 25661 KRU 1 J-115L1 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): N/A 10. Field/Pool(s): Kuparuk River Field / West Sak Oil Pool 11. Present Well Condition Summary: Total Depth measured 13,913 feet Plugs measured none feet true vertical 3,774 feet Junk measured none feet Effective Depth measured 13,874 feet Packer measured 5094, 6198, 6652 feet true vertical 3,771 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 7,170' 4.5" 13,913' 3,774' Perforations: Horizontal slotted liner Measured depth: 6,804'-13,874' feet True Vertical depth: 3,655'-3,771' 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-W7 F 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, 25.071, s 25.283) 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 Q Gas ❑ WOSPL ❑ 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 Authorized Name: Sydney Autry Contact Name: Sydney Autry Authorized Title: Senior Petroleum Engineer Contact Email: sydney.autry@cop.com Authorized Signature: Date: 12129"<9 Contact Phone: 907-265-6813 IV 3/f /,20 '-�r ?f/y/70 ;?o RBDMS*DEC 3 12019 Form 10-404 Revised 4/2017 Submit Original Only 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-1151-1 DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary 11/23/19 Attem t to BOL 1J-115 ESP unsuccessfully 11/25/19 1 Confirm ESP motor is bad, progress plans to convert to backup gas lift. 11/26/19 Dump packer vent valves, lockout on surface 12/01119 Pull Slipstop/Packoff/ESP 12/04/19 1 Complete circ out of IA(plug set 12/3/19), Perform CMIT - PASS to 2500 psi 12/06/19 Install Gas Lift Design, Obtain MITT & IA DDT 12/07/19 BOL 1J-115 to gas lift production 12/14/19 Troubleshoot high control line pressure - determined to be thermal (liquid packed) 12/18/19 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: Lm.reoolb)alaskaaovr A013CC.Insdectors0alaska.00v. phoebe.brooksCrdalaska.00v OPERATOR: ConocoPhillips Alaska Inc, FIELD / UNIT / PAD: Kuparuk / KRU / IJ Pad DATE: 12/04/19 OPERATOR REP: Justin Penfold AOGCC REP: chnisv allactsaalaska gov Well 1J•115 Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD 2190940 Type Inj N Tubing 0 2490 2390 2350 Type Test P Packer TVD 3180 BBLPump 2.5 IA 0 2500 2420 2390 Interval O Test psi 1500 1 BBL Return 2.3 OA 0 20 20 20 Result P Notes: Diagnostic CMIT for conversion from ESP to Gaslifted production Well Pressures: Pretest Intel 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL 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 Packer TVD BBL 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 Packer TVD BBLPump 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 Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result tea: TYPE [NJ Codes W = Water G = Gas a = St., 1= Industrial Wastewater N = Not Infecting TYPE TEST Codes INTERVAL Cotler Reeve Codes P = Pressure Test I = Initial Test P = Pass O= Other(desonbe In Notes) 4=Four Year Cycle F=Fail V = Required by Vedan. I = Inconclusive O = Other (describe in notes) Form 10-426 (Revised 01/2017) MIT KRU U-115 diagnostic CMITTAA 12-00-19.xlsx v KUP PROD WELLNAME U-115 WELLBORE U-115 CbriowPhillip$ \ Alaska. IOc. 1 Well Attributes Max Angle &MD TD l smo xalne ZO Apguwl wepmre aewa mclpl uomNal acl can lmcal T 92.39 134]4.)0 13720.0 Cg11mM1 X151ppm1 n. AMM18aM EM OVIa NabN IN ern Release D.F. SSSV'. NONE 4=7 916209 3220 111282006 MMtipM u,Nnc a4ls.,ue7rm,e,zw zc eN. Last Tag wniulxeema',t1-1 11 nnnoueon oepinlnn01 Ell Data wm enbe empe av XAxcE6.n3 1� Ap/CON011CTOR; 30010$0L svRrACE: zs w.gm.0- GASUm. 3saa.3 - ws un.soae PACKER; s0940 cAs urTa.vD.v not S.O >BB ESp1Nals 54534 uvMe radem; E.. brver Tertem; v,ODS ESP. MOTOR GPLGE aAH0.1 cemsper. . ) A LINER LEM a19e.0a.]pa.9 aLINER DD R530 A-tern7 D UNER XXI SEERS6m11 SLEDS: Lba.DZEPIO- WTERMEDATe Xa-7,4930 _ akors:z]esOeJn.D-� - - - - SIOT&knkgr Dfl TmO� _ UOTs. lx,111 o-¢54e.o- - - SLOTa.+a719G13.3w.0-- -_ -_ OCTA; 19533.O13SMO�� - A3ANO LINEe:0.85gO 13.]080 Lasa TaB' I J-115 Imgsbgr Last Rev Reason Annommn Ena Dale a Lan Mop av Rev Reason: Pulled ESP. Packoff, Slip Smp 8 SOV, G9 Gas Lill 12)1/2019 15115 Ihansen8 Casing Strings eating DasenLem oDlml ID OmI TopIN(el semepm Imetal set Depm rNDl-. w1AM P.. Gema CONDUCTOR 20 19.12 30.0 108.0 106.0 940(1 K-55 Tap TXreW WELDED CssInODemn"N'S OR ID (to) Top(OKED set Oepminn6) Set DeNn IND),., WM-M D.. GnJo Top Tn SURFACE 10314 995 26.0 x,609.0 2,214.9 45.60 480 BTC CaaleO DesOnppon 0011n) ID on) Toperes) sel ngenjol Sat DOOR DVO)... WYLell ll. Gra4e Tap TM1r"m INTERMEDIATE 7516 6.87 26.3 7,493.0 3,6084 29.]0 LW 'TCM Cann, DeaEnpgm OO (In) IDpnl TOPHOO1 Sar Oepq lnN01 Sn DapM (IYDI... WYIm (I_. Grave iopreru4 B LINER LEM 4Y2 38fi 6,198.0 6.704.9 3,680.9 12.60 L80 IBT-SCC Liner Details Topinxal Top JI ma) Top mal E) em pe. Nommu lD m 5198.0 3,573S 8 03 PACKER 7-518' K 5.112' Z]M' Rare top packer 4a70 6.170 3576.9 80.8) SBR Casing Seal Bogie Remarkra6e 4,750 8.236.7 3580.0 80.58 XO BUSHING OTDOONSBushing Base 5520.3 3,636.1 7647 HANGER LEM(ahove hppk haver) 38 6,530,9 364D.fi 76.26 HANGER LEM Onslrlehoohfiangen 3688 5626.0 36639 )64) rvIPPLE DB -6 Nipple 3.553 6584 3,fi)12 7]38 BENT JT Bent Joint 3.8W 6.]016 3,680.3 7836 SEALASSY Seal assembly 3.860 Casing Description ODlinl IO BnI TOp(FI(6) Se1DepMInNB) Set OepLn (NO)... MNLM D.,. Gra4e Toprm®4 BONER HE 4112 4.00 6.530.9 679n a,fi987 1LfiD Lao BTC Liner Details Toplexa Top rv011nRR) TOPma I') em DOIn) omb 10 6,530.9 3.64 6 76. HANGER Heck Ham9er(bel. RAER W) ell 56069 3,fi59.8 )5.98 ECP Ememal Casing Packer 3.900 57676 3.6930 7911 BENUT sem lav wl rem arwe 3.960 Casing 0eicrl OO ( pNl(NDj.., WtlLM (1., S, TaplhrM pLINER HHptl� 4112 3481 6,5332x1 6,797.7m°Nal J698.> 11.fi0 L-80 BTCM Liner Details n rop (xel Top LIVED RNB) Top Incl E) Ircm dei Nominal IS Onl 6533.2 3641.1 Yg.2 HANGER SINKER MODEL PZ HOOK HANSER(INSIDE CSG) 3,950 6.550.0 36452 7588 HANGER BAKER MODEL PZ HOOK DANGER (OUTSIDE CSG) 3.950 6, W'1 3,6594 7593 ECP BAKER PZ, EXTERNALEASING PACKER 3.900 6,7694 36034 7912 BENT JT 3960 Casing OeacnpeM A -SAND LINER OO gal 41/2 IDgn) 3.48 Taq (Itl(Dj 6,fi52.0 Seto pm IM1NO) 13]08.0 Sel apin(MI).. 3.9099 WgLM II.. 11.60 GTaCe U80 TOO TnraaO Buttress nread Liner Details Top Imetal rnp PAID) TRIP) Top I1.1rl lam De: mmD Unl 6,652.0 3,689.8 77.20 PACKER BKER HND ZXP LINER TOP PACKER 5,500 ]74 NIPPLE 'RS'PACK FFEA4NIPPLE 4.8)0 56710 3.6]4:0 ;!"IH 6,6>39 36]4.6 J>62 HANGER FLEX -LOCK LINER HANGER 4.860 6,683.8 3676.6 78 SBE 19GA7 SEAL BORE EXTENSION 4750 Tubing Strings ruWng Oescmpaon Selog TO -JR, on) Top (DKa) sal Oepm ln-Sarlbpi(NDI(,�Wlptlltl reep. Top Gwmwaan TUBING 412 7.96 22.3 5,59x.9 3,3528 12.60 L -W TXPM Completion Details iopINT01 erm Top lSKIP (eKal EI mDev Co. Nominal DSO 22.3 223 060 HANGER Tubing Hanger VNco-Gray MB2Ztk offset 10314 x 412WRaae 3.900 hgw4 5.0 0 3]79.6 62 PACKER Viking VentU Pecker SN: VCT-POLiTT3 2 3. 2 5.389,0 3,M7.9 64 GAUGE WeIWft Dlscbwg Gaugeuna,CeM,ilift 3.95 54534 =3M fi463 ESP lmake TTCsover DDREOCros. Cenlmift 5.464.0 3.340.9 Upper Tandem Upper Tampm, Seal Section. Cemlilift 54708 3,3430 64.88 Lower Tandem Lower Tandem Seal SeelOn, Cenkilift 54777 33459 6467 ESP Motors ESP MmorCemdiin D5HINSTR 134A 5,49D.1 3351.2 MBILL MOTOR GAUGE WeMbftE ks Gauge Unil, Canino --64M 5,492.0 33520 Centralizer MMor Cemrxlizer, Cenulift Perforations & Slots TopOKBI Manl I roplrvDl (RNB) avmlrvq RN.) LI14NZone Star Den Iehaum I. I Type 7.234.0 761411 77 ,8 ]3 WS A2 J-115 1012612006 32.0 BLOTS AIL PFRFS IN WELL AgemOr, ammUckned pipe -0 G,5"4 5' @ 4 G rarrialimati xQaCEd rows. 3' camels ackweg 18 CAN 3'nk'sIaned eMs 7,786 0 8.12].0 3.820.8 3,822.7 W A2.1J-11 101 32.0 SLOTS Lime ii.ro0 --3T25-6 3842.o WSA21111 10126/2008 20 SLOTS 12,1570 12,546.0 3,864.3 3,8887 WSA&1Y115 TO/262008 32.0 SLOTS 1 ,]19.0 13.360.0 3.893G 3993 W. P2, 11,115 102812006 32.0 SLOTS 13.533.0 13664.0 3,905.1 3,90'6 WSA2. 11115 1026/200fi 32,0 SLOTS '`� KUP PROD WELLNAME 1J-115 WELLBORE iJ-115 ConocoP11ll1p5 Alaska, Inc. x,NNe bMnL. uns. l2mrm13,xwz, PM Mandrel Inserts ven..IwLm.r�lenLn S1 as .EFL S2.S- io01M1KB1 TOF' IN01 IIIKB) Mahe Motlei O011p) SBry Wlve Type Type TyRo PorI510e Iln1 IW1) 1 Run OOM1 TSpall Com i 3,]44.3 2.375.9 Cm HBM 41 GAS LIET GLV BK 0.188 t,d]5.0 1 1 2 5,022.8 3.147.8 R KBMG 412 GAS LIFT V BK 0.313 0.0 12762019 3 5.200.2 3.226.8 CSnlco KOMG 41(1 GABLIFT DMY BK 0000 I 0.0 12/42019 Notes: General 8 Safety Entl OBI, A,n..n.n 91612017 NOTE WO nni GONOMTOFLS00,10000L I I I I 41242011 NOTE View SChemdtic wiAWska SchemdiC9.0 1112712036 NOTE MULTI -LATERAL WELL 1J -115(A -SAND), iJ-11511 (B -SAND), IJ-115L2(D-SAND) i SURFACE'. 26G,F H0— 1 L GAS LIR:33 S GASUFT'.SOii.B PACKER', 544.0 OASLIR:5N32 GVIGE. 5YR.0 ESP Me4e; 50.53• Uµw TaMem, 5,161.0 L wup Tan0em; 5ATo7 E3Pkb E F' MOTON WUGE;SISJ901 GMreAmr.50.920 ) B LIXEN IEM', fi.ISaPa.]M.9 B UNEP XH. RESn"?R7l O LINER K.M A.W7 1 SLOTS, 7.2L.6>b10.O— ' f INTERMEDIATE', M6 7430 SLOTS: 7. OR, 1270— SLOTS',&�20.,,,P00�� - SLOTS, 121ST CIE... SLOTS. 137150133L'.0— SLOTS, 13113.013664.0 - - 4AANOUNERSSE3.0 13]m0 A"\ KUP PROD WELLNAME U-115 WELLBORE 1J -115L1 Lonocophinn Maz Angle$MD TD aB4k8 )(� FIHa Name weIIWRApuuWl PRMesbluz Indl"t MOnd(el pC1BM 1p1(6) 93d0 11,628.M 13,922.0 Comment SSSV NONE M261ppml OMe Mnotetlm Ea pale I(B GN(Ip qlg Release oab Lastw0- 32.20 nl2&2006 MJ11Pk Lalenit1JA15L1, 122)IA19120)tO PM Last Tag Inul.... Rhood" Annoomod Oepin IRNB1 En00a1e W¢IlCore Laa[MW ey Last Ta,. 1J-115Li Impsbol .ER, 22]_ Last Rev Reason nno""' End Dole wMIM,e Wa1MW By Rev Reason: Potlp ESP. Packofl. Slip Slop 8 SOV, CIO as Lift 1211/2019 —115L1 ppmveo Casing Strings ...... ... ........ ....... a Caalne Donod"on I GO 111 B -SAND LINER 4 U2 IDOnI Top(MS) Se10ePMIrtNB1 3.48 6.942.5 13,912.9 flee OeGhffv(— w✓cmp.. GAIN TOPmea% 3,/43 11,60 LM "CM Liner Details ioP IaNB) D[s incl In Com Iln) 6 >425 3,657:1 9t33 SLEEVE HR4M8vRRg AIeeve 5,010 6765,6 3,fi56.0 9 15 SBR Receptacle Joint 4g70 CONDUCTOR: 30.01p40 8.8006 ,6550 91. XO BUSHING Cross Ove16U61nng 3989 1387).6 3,77111 8&UjXORdGMGg CROSWVERREDUCING45x3S- 2g Perforations 8 Slots roT PmgB) am mgel ToplrvDl (, B1 Bmllrval ..., unxM zone Gae Go- IA. ryce Com 6.540.0 13.1880 $542.5 37476WS., 1619.1 11120/2006 320 SLOTS PERPS IN WELL. p0eea s0Nd3btletl pipe 6URFACE, 260].0.90-0 1K1- .12$"Y2 ,5"@4 126 OlCumrHenlwlaGeWnl rows. 3' LErcers slaggerea GAa un:33w.] 1a aega• rrP,1-smnea eqe. 8,8040 11.330.0 3654.9 3,719.4 WSB.IJ-118L1 11ISI2M MD SLOTS ALL PERES IN WELL AXernabog GoIdIsl011ea ppe f -O t25"v2S" @4 "< GaDmreleprlal acia6am ews urr; sone rows, 3-toRoo, snaggerm 18 111 , T non-tth. errds 13.3820 13,940.0 3]48.4 WSB.1J-11511 1@0/2008 32.0 3L0TS ALLPERFSINWELL Aflematiog htt ilkslmlea pipe PACNER.5.0 CNNrllre1en1wI.d,aCen1 rows. 9' tamers sleggerM 18 aa9.3nml-slottad endl Notes: General $ Safety GAR U1. E. End Dale MnOod" 4 412011 NOTE. View SChARMt'Cw(Alaska SChEMa .0 L It WARNS NOTE: MULTI-IATERALWELL. 1J-115 (ASAND). 0 1101 (B -SAND), 11-1192 (D.SAND) GAME. 5349.8 E8Phnot. GJ53A Roar Tandem: SlBfa L— I.... s.47G E SP Noum: S.A)i) NO TOR GAUGE: 5490 .1 .nota,: 51929 i B LINER LFM, 61. ",IIN.9 INTERMFDNTE. 3637,1930 1 BLOTS: 6.eb.411, E. BLOT.: 1. 0-11 0. y�y BLOT8:1]382013.9W.0� j 8GAM LREER. 6.)425 139120 • • FEB 01 2015 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION , OCC REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon fl Plug Perforations r Fracture Stimulate r Rill Tubing r Operations shutdown r Performed: Suspend r Perforate r Other Stimulate r Alter Casing rChange Approved Program r Rug for Redrill r Perforate New Pool r Repair Well r Re-enter Susp Well r- Other: ESP to GL r 2.Operator Name: 4.Well Class Before Work: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development ? Exploratory r 206-123 3.Address: 6.API Number: Stratigraphic r Service P. O. Box 100360,Anchorage,Alaska 99510 50-029-23320-60 7.Property Designation(Lease Number): 8.Well Name and Number: ADL 25661,25650 WSAK 1J-115L1 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 13922 feet Plugs(measured) NONE true vertical 3775 feet Junk(measured) NONE Effective Depth measured 13913 feet Packer(measured) 0 true vertical 3773 feet (true vertical) 0 Casing Length Size MD TVD Burst Collapse B-SAND LINER 7170 4.5 13913 3774' Perforation depth: Measured depth: 6804-11330,11631-12104,12190-13873 True Vertical Depth: 36545-3719,3721-3715,3718-3771 fi %� I Tubing(size,grade,MD,and TVD) 4.5, L-80, 5511 MD,3360 TVD `y Packers&SSSV NONE 12.Stimulation or cement squeeze summary: Intervals treated(measured): Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 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 p Exploratory r Development p- Service r Stratigraphic r Copies of Logs and Surveys Run j-'" 16.Well Status after work: Oil r Gas r WDSPL r Printed and Electronic Fracture Stimulation Data r GSTOR r WINJ E WAG r GINJ r SUSP r SPLUG r 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: 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 ` Form 10-404 Revised 5/2015 ATL �� g�!L Submit Original Only 4? /,4AC RBDMS u. FEB 0 1 2016 • 1J-115L1 DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary 01/04/16 Convert well to gaslift. Bring well on production. 12/12/15 (AC EVAL) : GAS MIT-IA PASSED. 12/09/15 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. 12/08/15 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 4111 1J-115L1 ConocoPhillips $ Well Attributes Max Angle&MD TD Alaska.Inc. WellboreAPI/UWI Field Name Well Status Incl(°) MD(ftKB) Act Btm(ftKB) can000 Ntrps"'. 500292332060 WEST SAK PROD 93.40 11,626.88 13,922.0 Comment H2S(ppm) Date Annotation End Date KB-Ord(ft) Rig Release Date -" SSSV:NONE 0 8/14/2012 Last WO: 32.20 11/28/2006 Weli Confi9:Multiple Laterals-1J-115L1,5/72013 1:31:17 PM ' Schematic-Actual Annotation Depth(ftKB) End Date [Annotation Last Mod By End Date Last Tag: LRev Reason:WELL REVIEW osborl 5/7/2013 L C Casing Strings Str 0.. Strin ID...[Top6(77213)5 'Set Depth(f...Set Depth(ND)...String Wt...(String...(String Top Thrd 9 P 9 9 B-SAND LINER 41/2 3476 6,742.5 13,912.9 3,774.3 11.60 L80 BTCM -__ Liner Details Top Depth (ND) Top Incl Noml... Top(ftKB) (ftKB) (°) Item Description Comment ID(In) 6,742.5 3,658.8 94.68 SLEEVE HR liner setting sleeve 5.010 HANGER.22 - 6,765.6 3,656.6 93.48 SBR Receptacle Joint 4.970 6,800.7 3,648.4 84.70 XO BUSHING Cross Over Bushing 3.960 13,873.6 3,771.1 85.44 XO Reducing CROSSOVER REDUCING 4.5x3.5" 2.992 Perforations&Slots iirt Shot 11/ Top(TVD) Btm(ND) Dens ill Top(ftKB)B(m(ftKB) (ftKB) (MB) Zone Date (eh-•• Type Comment CONDUCTOR. 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 35-108 '30-108 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 3,648.8 3,719.1 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 3,749.4 WS B,1J-115L1 11/20/2006 32.0 SLOTS ALL PERFS IN WELL:Alternating solid/slotted pipe-0.125"x2.5"@ 4 su2RF6-3A,009CE,_ circumferential adjacent rows,3" centers staggered 18 deg,3' non-slotted ends ESP MANDREL, 3,415 Notes:General&Safety End Date Annotation I 11272006 NOTE:MULTI-LATERAL WELL:1J-115(A-SAND),1J-115L1(B-SAND),1J-115L2(D-SAND) 4/24/2011 NOTE:View Schematic w/Alaska Schematic9.0 ESP MANDREL, 4,981 I . DISCHARGE, -TA : 5,372 SA gg gE SLIPSTOP, y— 5,385 (a PACKOF 5,3911 ESP PUMP, 5,400 1\' J f INTAKE,5,448 SEAL 5,459e/ MOTOR,5,473 rr GAUGE,5,508 CENTRALIZER. 5.509 7 B LINER LEM, 6,198-8,705 NTERMEDIATE, 26-7,493 lig S. 41 :.W iip SLOTS, _ 6,804-11,330 SLOTS. 6.540.13188 kT ,.SLOTS. 1) 13.382-13,940 1Mandrel Details i - .... Top Depth Top ............. Port S... (ND) Incl OD Valve Latch Sloe TRO Run B-SAND N...Top(ftKB) (ftKB) (1 Make Model (in) Sere Type Type ON (Pei) Run Date Com... LINER, 1 3,414.5 2,408.9 61.19 CAMCO KBMG 1 ESP SOV BEK 0.000 0.0 11/27/2006 8,743.13,913 TD(1J-115L1), 2 4,980.5 3,129.0 63.54 CAMCO KBMG 1 ESP DMY BK-5 0.000 0.0 11/27/2006 13.922 Image Project Well History File Cover Page XHVZE This page identifies those ifiems 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. ~~ - ~~~ Well History File Identifier Organizing (done) ..o,aea mumiuumiii Re,~~~eea~ iuiumuiiiiuii RE AN Color Items: ^ Greyscale Items: ^ Poor Quality Originals: ^ Other: DIGIT L DATA Diskettes, No. ^ Other, No/Type: OVERSIZED (Scannable) ^ Maps: ^ Other Items Scannable by a Large Scanner OVERSIZED (Non-Scannable) ^ Logs of various kinds: NOTES: BY: Maria Date: 1 ~ ^ Other: /s/ Project Proofing III II~III IIIII II III BY: Maria Date: ~ /s/ Scanning Preparafion ~) . x 30 = ~ + =TOTAL PAGES (Count does not include cover sheet) BY: Maria Date: /~~ ~~ /s/ Production Scanning Stage 1 Page Count from Scanned File: -f (Count does include cov sheet) Page Count Matches Number in Scanning Preparation: YES NO BY: Maria Date: f ~~~~ /s/ Stage 1 If NO in stage 1, pages} discrepancies were found: YES NO BY: Maria Date: /s! Scanning is complete at this point unless rescanning is required. II I II II I!I I II II I I III ReScanned III IIIIIIIIIII IIIII BY: Maria Date: /s/ Comments about this file: Quality Checked II I II VIII III II'I II 10/6/2005 Well History File Cover Page.doc ~ ra~.~ ~~ DATA SUBMITTAL COMPLIANCE REPORT 10/13/2008 Permit to Drill 2061230 Well Name/No. KUPARUK RIV U WSAK 1J-115L1 Operator CONOCOPHILLIPS ALASKA INC API No. 50-029-23320-60-00 MD 13922 TVD 3775 Completion Date 11/28/2006 Completion Status 1-OIL Current Status 1-OIL UIC N REQUIRED INFORMATION Mud Log No DATA INFORMATION Types Electric or Other Logs Run: GR/Res, Dens/Neu Well Log Information: Log/ Electr Data Digital Dataset Type Med/Frmt Number Name ~~ Samples No Directional Survey Yes (data taken from Logs Portion of Master Well Data Maint Log Log Run Interval OH / Scale Media No Start Stop CH Received Comments `ED D Asc Directional Survey I D Asc Directional Survey ~ D Asc Directional Survey ',"Rpt 14508 LIS Verification ''/Rpt 14508 LIS Verification ~ Rpt 14508 LIS Verification v C 15869 Gamma Ray f~ C 15870 Gamma Ray ~C 15871 Gamma Ra y Well Cores/Samples Information: 8365 13922 Open 1/29/2007 6485 7522 Open 1/29/2007 PB 1 7154 8650 Open 1/29/2007 PB 2 2993 13922 Open 3/21/2007 LIS Veri GR, ROP FET 2993 7522 Open 3/21/2007 PB1 LIS Veri GR, ROP FET 2993 8650 Open 3/21/2007 PB2 LIS Veri GR, ROP FET 108 13922 Open 1/31/2008 TVD and MD of ROP, DGR, EWR in PDF, EMF, and CGM graphics 108 7522 Open 1/31/2008 P61 TVD and MD of ROP, DGR, EWR in PDF, EMF, and CGM graphics 108 8650 Open 1/31/2008 PB2 TVD and MD of ROP, DGR, EWR in PDF, EMF, and CGM graphics Sample Interval Set Name Start Stop Sent Received Number Comments DATA SUBMITTAL COMPLIANCE REPORT 10/13/2008 r Pe mit to Drill 2061230 Well Name/No. KUPARUK RIV U WSAK 1J-115L1 O erator CONOCOPHILLIPS ALASKA INC p MD 13922 TVD 3775 ADDITIONAL INFORMATJ~ON Well Cored? Y N Chips Received? ~~C.L.DI~- Analysis ~41~1i Received? Comments: Compliance Reviewed By: ___.. Completion Date 11/28/2006 Completion Status 1-OIL ~^~C, urrent Status 1-OIL Daily History Received? ~-'"° Formation Tops ~N Date: API No. 50-029-23320-60-00 UIC N 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 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+PBl+PB2+PB3+PB4+Ll+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: ~ ~ ' ~ lv~tl. ~ ~ Anch~~a. 1~ska 995R1'8~ Date: Signed: ~ ~ - raa ~ r s~~ ~, ~~', 1 ~~S ~S(~5- p33 ~15`6Co~ aaG,-~23 ~ is~s~4 Phi ! ~ ~ S~s~ P~ ls~~i January 18, 2008 ~o~-r2~i ~ is'~ ~a t`~3 - a15~73 P13 2 '~ 15fs ~ ~I WELL LOG TRANSMITTAL To: State of Alaska February 26, 2007 Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West 7t" Avenue, Suite 100 Anchorage, Alaska RE: MWD Formation Evaluation Logs: 1J-115 PB1 PB2 PB3 PB4 L1 PBl L1 PB2 L1 L2 PB1 L2 PB2 L2, AK-MW-4528227 1 LDWG formatted CD Rom with verification listing. API#: 50-029-23320-00, 70, 71, 72, 73, 74, 7~, 60, 76, 77, 61 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETLRNING A COPY OF THE TRANSNIITTAL LETTER TO THE ATTENTION OF: Sperry Drilling Services Attn: Rob Kalish 6900 Arctic Blvd. Anchorage, Alaska 99518 ,;~ ~ ~~, :~~~ Date: Signed: ,( --.,-~: ~b~-1~~ 1~l~USS ;~~~-t ~y `~.~ SLR \~ Conoco~illips January 10, 2007 • Randy Thomas Kuparuk Drilling Team Leader Drilling & Wells P. O. Box 100360 Anchorage, AK 99510-0360 Phone: 907-265-6830 Commissioner - State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Subject: Well Completion Reports for 1 J-115, 1 J-115L1 and 1 J-115L2 Dear Commissioner: ConocoPhillips Alaska, Inc. submits the attached Well Completion Reports for the recent drilling operations on the West Sak wells 1 J-115, 1 J-115L1, 1 J-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 '~~~-i7 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT ,~y~~ - ~':`; ', ~ ~ ~~~7 AND,~O~ _ 1a. Well Status: Oil ^/ Gas Plugged Abandoned Suspended ^ WAG ^ 20AAC 25.105 20AAC 25.110 GINJ ^ WINJ ^ WDSPL ^ No. ofCompletions_ Other_ 1b. Well Class: Development ^/ "`t` tPR~ory ^ Service ^ StratigraphicTest^ 2. Operator Name: ConocoPhillips Alaska, Inc. 5. Date Comp., Susp., ~ or Aband.: November 28, 2006 12. Permit to Drill Number: 206-123 / 3. Address: P. O. Box 100360, Anchorage, AK 99510-0360 6. Date Spudded: .~~J October , 2006~L`~'o7 13. API Number: 50-029-23320-60 4a. Location of Well (Governmental Section): Surface: 1973' FSL, 2380' FEL, Sec. 35, T11 N, R10E, UM ~ 7. Date TD Reached: November 4, 2006 14. Well Name and Number: 1J-115L1 At Top Productive Horizon: 1789' FNL, 1098' FWL, Sec. 36, T11 N, R10E, UM 8. KB Elevation (ft): 28' RKg 15. Field/Pool(s): Kuparuk River Field Total Depth: 312' FSL, 658' FWL, Sec. 24, T11 N, R10E, UM 9. Plug Back Depth (MD + TVD): ~ 13913' MD / 3773' TVD - West Sak Oil Pool 4b. Location of Well (State Base Plane Coordinates): Surface: x- 558830 ~ y- 5945785 Zone- 4 10. Total Depth (MD + TVD): 13922' MD / 3775' TVD 16. Property Designation: ADL 25661 & 25650 TPI: x- 562294 y- 5947331 Zone- 4 Total Depth: x- 561788 • 5954708 ~ Zone- 4 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: l.C, ' I1t~ ~ s2q' ~ /1Z~! j(p T1/.A GRJRes, Dens/Neu /~ ~' 21~• ° 7 22. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTH TVD HOLE AMOUNT CASING SIZE WT. PER FT. GRADE TOP BOTTOM TOP BOTTOM SIZE CEMENTING RECORD PULLED 20" 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 6529' 13913' 3640' 3773' 6.75" slotted liner - refer to attachment for details 23. Perforations open to Production (MD + TVD of Top and Bottom 24. TUBING RECORD Interval, Size and Number; if none, state "none"): SIZE DEPTH SET (MD) PACKER SET tubing in main wellbore 6609' slotted liner from 6804'-11330', 11631'-12104', 12190'-13873' ' 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 1J-115 and 1J-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 (err) 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". y vt?(ai~ x ~ t:%he Lt.t~ NONE ~ -'~~~~ ~1E9l~iEl~ ~+ Form 10-407 Revised 12/2003 CONTINUED ON REVERSE ~~~ c ~ ADO fOn .e~ t /~. y~D7 L za. zs. GEOLOGIC MARKERS FORMATION TESTS NAME MD TVD Include and briefly summarize test results. List intervals tested, and attach detailed supporting data as necessary. If no tests were conducted, state "None". 1J-115L1 Top West Sak B ~ 6501' 3634' Base West Sak B 13922' 3775' 1J-115L1PB1 TD 7522' 3639' N/A 1J-115L1P62 TD 8650' 3687' 30. LIST OF ATTACHMENTS Summary of Daily Operations, Directional Survey 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Mike Greener @ 263-4820 Printed Name Randv Thomas Title: Greater Kuoaruk Area Drillino Team Leader l~l ~ ~~ 7 ~1 ~' ---^---~-~- Phone Date Signature \ ~-~+~ "Z~ S`~ 73 3 ~ INSTRUCTIONS Prepared by Sharon Allsup-Drake General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1a: Classification of Service wells: Gas injection, water injection, Water-Alternating-Gas Injection, salt water disposal, water supply for injection, observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 4b: TPI (Top of Producing Interval). Item 8: the Kelly Bushing elevation in feet abour mean low low water. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 73: 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 28: 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 r~ 1J-115'D' Lateral Liner Detail Weu: 1J-115L2 `~. 4-7/2" Slotted and Blank Liner Date: 11/20/2006 ~t?f"~UC~QP~'11I~Ip5 PLOP & DROP Alaska, tna, DEPTH Jt Number Num of Jts COMPLETE DESCRIPTION OF EQUIPMENT RUN Page 1 LENGTH TOPS 6296.86 6296.86 .~:: ..: _< =' R :-: ;. :. r ..... «. .. . 6296.86 6296.86 6296.86 6296.86 ..... - 6296.86 6296.86. 6296.86 XO 1.41 6296.86 Running Tool (Does not stay in hole) 7.00 6298.27 Baker "H R" Liner Setting Sleeve, 6.4" OD x 5.0" ID 13.04 6305.27 5-1/2" BTC pin x Hydril 521 Box XO 4.95" LD 6.85 6318.31 5 1/2" Hydril 521, 15.5 ppf. L-80 Receptacle Jt ID 4.90" 35.93 6325.16 5-1/2" H521 x 4-1/2" BTC XO Bushing ID 3.96" 1.46 6361.09 4-1/2", 11.6ppf, L-80 BTC Pup Joint ID 3.96" 3.83 6362.55 Jts 174 to 177 4 Jts 4-1/2" BTC, 11.6 ppf, L-80 Blank Casing 173.14 6366.38 Jts 19 to 173 155 Jts 4-1/2" BTC, 11.6 ppf, L-80 Slotted Casing 6626.04 6539.52 Jts 14 to 18 5 Jts 4-1/2" BTC, 11.6 ppf, L-80 Blank Casing 215.96 13165.56 Jts ~ to 13 13 Jts 4-1/2" BTC, 11:6 ppf, L-80 Slotted Casing 558.40 13381,52 .Shoe Jt 4-1 /2" BTC, 11.6 ppf, L-80 Blank Casing 43.33 13939.92 Weathertord 4-1/2" Float shoe 1.75 13983.25 Bottom of guide shoe 13985.00 Torque Rings ran on Jts # 65 thru # 177= 114 total Shoe 13,985' MD / 3704' TVD (Rathole 15') TD 6-3/4" hole 14,000' MD / 3705' TVD (87.73 deg.) Top of D Lat Window 6,094' MD Bottom of Window 6,108' M D Run 1 Hydraform centralizer floating on the bttm half of each joint. Put a stop ring in the middle of the joints. Ran177 total, 4.5"x 6.375" Hydraform 2-blade cent 8~ 177 stop rings Ran total of 9 jts Blank = 389.10' and 168 jts Slotted= 7184.44' ,Slots are On Btm Up Wt 225K w/ (32) 2.5" long x .125" 4 Circumferential adjacent rows, 3" Centers Rotating UP Wt 90K staggered 18 deg., 3 ft. non-slotted ends Rot Dn Wt 75K Block Wt 35K Liner & running tool only, up wt 87K, do wt 57K Used Run-N-Seal thread compound on all connections. All drifted w/ 3.875" rabbit. Supervisors: Dearl Gladden/Peter Wilson/Dennis Hardwig ~~~ -Time Logs _--_ -- - _ --- --- _ - - - -- -- - -- - -~, I Date From To_ Dur S.-D~th E Depth Phase- Code Subcod_ e__-T_ COM- _ _ 10/27/2006 19:00 21:30 2.50 6,522 6,541 PROD2 DRILL MILL P Mill'B' Lateral window from 6529' to 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 ~~ ~~ s ~ i r ` ` ® d ~ t~ ` ) ~ rates P/U 108k S/O 70k ROT 80k. Slide. thru window interval without `T ~- ~ ,~~~ ©~ pump. OK Monitor well pump pill & blow down to 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 testjt. & wear ring uller- ull wear rin & la down same. 03:30 04:00 0.50 0 0 PROD2 DRILL OTHR P Pick up stack washer-flush stack & la down same. 04:00 04:15 0.25 0 0 PROD2 DRILL OTHR P Pick up testjt. & wear ring tool-set wear rin 8< la down runnin 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 jts. hwdp jars-1 jt. 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 roblems. 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 365T) AST-6.48 ART-1.88 ADT-8.36 P/U 112k S/O 65k ROT 85k TO 5k ECD 9.8 Max as 89 units. 10/29/2006 00:00 00:15 0.25 7,108 7,108 PROD2 DRILL SFTY P PJSM-Topic=Drilling. 00:15 09:00 8.75 7,108 7,522 PROD2 DRILL DDRL P Drlg. 6 3/4" Horizontal hole from 7108' to 7522'. TVD 3691 P/U 115k S/O 64k ROT 84k TO 5k ECD 9.8 Max gas 95 units. Well out of zone.} ~ 1~ ev ~f 45 ~ ~ I Time Logs- _-_ ---- Date From To D~;r~ S--Llepth, E Depth..Phase Code _ 5ubcodP _T _COPn 10/29/2006 09:00 09:15 0.25 7,522 7,111 PROD2 DRILL TRIP NP POH from 7522' to 7111'. For sidetrackin D9:15 10:15 1.00 7,111 7,155 PROD2 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/O-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 sidetrackin . 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' Lateratfrom 8650'to 8788': TVD 3689'. ART-.43 AST-.67 ADT-1.1 hrs. P/U 122k S/O-62k ROT-85k TO-6k ECD-10.3 Max gas-90 units. SPR-25 s m 590 si. 35 s m 880 si. 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 PRODZ DRILL DDRL P Drlg. 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 as 70 units. 12:00 12:15 0.25 9,547 9,547 PROD2 DRILL SFTY P PJSM-Topic=Drlg. & connections. ~ ~~ ~ s ~ Time Logs D_ ate From To Our S- Depth E Depth_ Phase Code Sub~ode _T COM - -- - - - 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 TO 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/O-47k ROT-84k TO-8-9k ECD-10.8 Max es-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 r m 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 to 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 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 b Lou Grimaldi AOGCC 11/02/2006 00:00 00:15 0.25 0 0 PROD2 DRILL SFTY P PJSM-Topic=Testing BOPE. 00:15 03:00 2.75 0 0 PROD2 DRILL OTHR P Gontinue 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 PROD2 DRILL TRIP P RIH from 8T to 2236'. -- --- -- - ~~~~ 25 of 45 ~ ' Time Logs ~ Date Fror7i To Dur ___ S Depth E Depth. Phase Code Subcode T COM_ _ __ _ 11/02/2006 08:30 08:45 0.25 2,236 2,236 PROD2 DRILL DHEQ P Shallow test MWD & break in bearin son eo ilot: 08:45 10:00 1.25 2,236 6,530 PROD2 DRILL TRIP P Continue RIH from2236' to 6530'. 10:00 10:30. 0.50 6,530 6,599. PROD2 DRILL OTHR NP Attempt to work geopilot assembly thru window. Would not go past 6599'.. 50k over ull. 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 8T. 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 TO 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 Pump hi-vis weighted sweep around @ 300 m 1200 si & 80 r m. 21:15 21:45 0.50 6,767 6,487 PROD2 DRILL OTHR NP Work mill thru window without pump from 6760' to 648T. 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 upon concretion. Took 30k worked thru to 6903. 04:15 05:00 0.75 6,903 6,996 PRODZ DRILL REAM NP Reamed from 6903' to 6996'. 270 gpm 2000 si 5-10k TQ PIU 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. PROD2 DRILL DDRL P Drlg. 6 3/4" Horizontal hole in'B' Lateral from 10749' to 11070'. _ _ ~ ___ _- - - ----- ---- ~, 2~ ~f45 Tirne Lis . Date Fro~7~ To Dur S. De th E. Le nth Pha ;.~.. Cede... Subcede . T_ _ C0~~1 - --- --- 11/03/200612:00 12:15 0.25 11,070 11,070 PROD2 DRILL SFTY P PJSM-Topic=Drilling. 12:15 00:00 11.75 11,070 12,103 PROD2 DRILL DDRL P Drlg. 63/4" Horizontal hole in'B' Lateral from 11070' to 12103'. ADT 7.65 hrs. P/U-150k S/O-0 ROT-87k TQ-8-10k ECD-11.1 Max gas 181 units SPR-35 s m 890 si. 11/04/2006 00:00 12:00 12.00 12,103 13,113 PROD2 DRILL DDRL P Drlg. 63/4" 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/O-0 ROT-100k TO-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. swee ) 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/0- N/A ROT -115k TQ 10k ECD-11.3 Max as-115 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 over ull 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 si 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 si. 100 r m-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 to 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 PROD2 DRILL PULD P Lay down BHA #12. ~. ~`f ~5 i • Time Lo s I Date From To Dur S De ih E. De nth Phase Code Subcode T COM 11/06/2006 03:15 03:45 0.50 0 0 COMPZ 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 1/2".slotted liner 165 jts. 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 r m 2-3k S/o 62k P/U rot-77k. 08:45 11:00 2.25 7,068 12,779 COMPZ CASINC 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 linerfrom 12779'to 13153'. 20 r m 7k TQ 70k down wei ht. 12:00 12:15 0.25 13,153 13,153 COMPZ CASIN( SFTY P PJSM-Topic=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. 'B' 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 drtg. line (pinch points-wickers & hand lacement 16:30 17:30 1.00 0 0 COMPZ CASIN( OTHR P Cut & slip 74' drlg.line-inspect & adjust brakes-check crown-o-matic-tube blocks & to 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 COMPZ CASINC OTHR P Wash-orient & latch whipstock @ 6529; Work & jar same free. Monitor well-static-blow down to drive. 21:00 00:00 3.00 6,529 0 COMPZ CASIN( OTHR P POH-Stand back DC,S & lay down oil 'ars. 11/07/2006 00:00 01:15 1.25 0 0 COMPZ RPCOh PULD P Fin POOH & LD whipstock and seal assembl ,cleared ri floor 01:15 02:00 0.75 0 0 COMPZ RPCOh RURD P RU 4 1/2" handling tools and held PJSM on runnin hook han er 02:00 04:00 2.00 0 375 COMPZ RPCOR 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 RPCOti 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' - -- :~ Time Logs ~_ Date-_ Fr~,m To __- Dur_ S. De th E Depth Pease C~,~Je Subcode T COM 11/07/2006 07:30 08:30 1.00 6,804 6,531 COMPZ RPCOh 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 RPCOh 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 runnin 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 RPCOh TRIP P Monitored well-static, POOH from 6,431' and LD hook hanger running tool and MWD tool, cleared ri .floor. 13:00 13:30 0.50 0 0 COMPZ RPCOh RURD P RU to run LEM assembly and held PJSM 13:30 15:30 2.00 0 519 COMPZ RPCOh PULD P MU "B" sand LEM assembly with MWD, RIH with 4 1/2" bentjtwith seats, 1 jt 4 1/2" tbg, DB-6 nipple 2, jts tbg, 1-pup jt, LEM assembly with 9 jts of 4 1/2", 12:6#, L-80 IBTM tbg, CSBR and ZXP pkr RIH to 519', st wt u and do 40K 15:30 18:45 3.25 519 6,681 COMPZ RPCOh TRIP P RIH with LEM from 519', shallow tested MWD at 610', cont to RIH to 6,681', st wt u 110K, do wt 56K 18:45 19:30 0.75 6,681 6,704 COMPZ 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 RPCOh 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 COMPZ RPCOh TRFP 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 talc fill 22:00 23;15 1.25 20 0 COMPZ RPCOh PULD P POOH and LD LEM running tool and MWD tool, cleared ri floor ~ '0 of 45 _1 ~ ~ Tirne Lo~s_ Ca,e From To Dur 5 De th E. De~th,,Phase Code . Subcode T _ _ COM_ - _ _ _ ~ - - - 11/07/2006 23:15 00;00 0.75 0 0 COMPZ RPCOh OTHR P RIH with 3 stds of 4" DP with super sliders, POOH with 1 std inspecting 2 sliders and found to be worm in the bod area of slider 11/08/2006 00:00 00:15 0.25 0 0 COMPZ RPCOh OTHR P POOH and inspected super sliders and observed slight wear on tube of DP 00:15 01:30 1.25 0 0 PROD3 RIGMN 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 same, MU bum er sub RIH to 215' 04;45 07:45 3.00 215 5,949 PROD3 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 PROD3 STK OTHR P Made MADD pass of K-13 from 5,949' to 6,019', (tort 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 whi stock at 6,094' 09:30 10:00 0.50 6,094 6,094 PROD3 STK CIRC P Displaced hole over from SFMOBM back to 8.7 M B 10:00 13:30 3.50 6,094 6,108 PROD3 STK WPST P Milled window. in 7 5/8" csg for "D" sand lateral from 6,094' to 6,108', milled window at 5-10K WOM, 90-110 L ~ [~ < ~ -- ~-~"'`, rpm's, 5-6K ft-Ibs 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 PROD3 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 PROD3 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 •ob 17:00 19:00 2.00 6,142 115 PROD3 STK TRIP P POOH with milling assembly from 6,142' to MWD at 115'. 19:00 20:00 1.00 115 0 PROD3 STK PULD P Downloaded MWD and POOH LD same along with the mills, upper mill was full au e 20:00 20:30 0.50 0 0 PROD3 STK OTHR P Flushed out BOP stack and cleared ri 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 re ort time. 11/09/2006 00:00 02:15 2.25 1,600 4,230 PROD3 DRILL OTHR P Cont to RIH relocating super sliders down 1-2' on 4" DP, RIH with an add. 28 stds 45 total to 4,230' ~~~~ 313 0 =~ Halliburton Company Survey Report Company: ConocoPhillips Alaska Inc. Date: 12!19!2006 Time: 14:21:19 __ Page: 1 Field: Kuparuk River Unit Co-ordinate(NE) Keference: Well: 1J-115, Tru e North Site: Kuparuk 1J Pad Vertical (TVD) Re ference: 1J-115L1: 109.0 Well: 1J-115 Section (VS) Reference: Well (O.OON,O.OOE,O,OOAzi) Wellpath: 1J-115L1 __ --- Survey Calculation iVtethod: Minimum Curvat -- ure Db; Oracle __ -- _ ii 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 Sy stem: Well Centre j Sys Datum: Mean Sea Level Geomagnetic Model; bggm2006 _ Well: 1J-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 - __ - Wellpath: 1J-115L1 Drilled From: 1J-115L1P62 500292322060 D C 1 11 L1 Tie-on Depth: 1 8365.95 ft D L l M S urrent atum: : J- 5 Height 0 9.00 ft Above System atum: eve ean ea ~~ 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 Definkive Wellpath _ __ Date: 12/19/2006 Validated: No Version: 1 i Actual From To Survey Toolcode Tool Name ft ft 50.00 1016.00 1J-115P61 gyro (50 .00-1016.00) CB-GYRO-SS Camera based gyro single shot ', 1147.04 6485.62 1J-115P61 (1147.04-8360.39) (3 MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 6529.00 7154.83 1J-115L1P61 (6529. 00-7476.96) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC i 7201.93 8365.95 1J-115L1 PB2 (7201. 93-8603.98) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC t ~I 8414.00 13888.03 1J-115L1 (8414.00-13888.03) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC Survey _ _ _ _ i`9D Inc! Azim TVD Sys TVD N/S F,/V1' MapN M11apE Tool ft deg deg ft ft ft ft ft ft LL 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 ~I 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 i 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: 14:21:19 Page: 2 Field: Ku paruk River Uni t Co-or dinate(~E) Reference: Well: 1J-11 5, True North Site: Ku paruk 1J Patl Vertical ("fVD) Reference: 1J-115L1: 109.0 Nell: 1 J -115 Sectio n (VS ) Reference: WeII (O.OON,O.OOE,O.OOAzi) ~Vcllpath: 1J -115 L1 Surve y Calculation >Viethud: Minimum C urvat ure Dh: Oracle Survey MD Incl Azim TVD Sys TVD N/S E/~V ~IapN MapE 'l'out ft deg ___ deg ft ft 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 i 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 'i 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 i 3066. 57 63. 09 96 .12 2240. 33 2131 .33 -144. 44 1619 .95 5945653. 62 560450. 50 MWD+IFR-AK-CAZ-SC i 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 I~ 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 I 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 'i 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 i 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+tFR-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 Halliburton Company Survey Report Comp:u~y: ConocoPhillips Alaska Inc. Date: 1 211 9/2 006 Time: 14:21:19 Page: 3 Field: Kuparuk River Unit Co-ordinate(iyiE) Refereocc Well: 1J-115, True North Site: Kupanak 1J Pad Vertical (7`VD) Reference: 1J-115L1: 109.0 Well: 1J-115 Section (V'S) Reference: Well (O.OON,O.OOE,O.OOAzi) Wellpath: 1J-115L1 Survey Calculation Method: Minimum Curvature Db: Oracle Su r~'ev ' MD Incl Azim TVD Sys TVD NiS E/1V D1apN MapE Tool ft deg deg ft ft ft ft ft ft - _ __ I 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 Ili 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 6529.00 76.30 350.40 3640.12 3531.12 1546.05 3471.26 5947358.35 562288.37 MWD+IFR-AK-CAZ-SC 6541.00 78.90 350.18 3642.70 3533.70 1557.60 3469.28 5947369.88 562286.31 MWD+IFR-AK-CAZ-SC 6595.09 82.84 349.19 3651.28 3542.28 1610.13 3459.72 5947422.33 562276.33 MWD+IFR-AK-CAZ-SC III 6645.22 86.56 348.30 3655.91 3546.91 1659.07 3449.98 5947471.20 562266.21 MWD+IFR-AK-CAZ-SC 6687.80 89.40 347.55 3657.41 3548.41 1700.68 3441.08 5947512.73 562256.99 MWD+IFR-AK-CAZ-SC 6781.00 92.69 349.62 3655.71 3546.71 1792.01 3422.64 5947603.90 562237.83 MWD+IFR-AK-CAZ-SC '~, I 6875.77 87.80 349.96 3655.30 3546.30 1885.25 3405.84 5947696.99 562220.31 MWD+IFR-AK-CAZ-SC I I, 6968.94 91.65 348.86 3655.75 3546.75 1976.81 3388.72 5947788.41 562202.48 MWD+IFR-AK-CAZ-SC 7061.80 88.57 348.33 3655.57 3546.57 2067.82 3370.36 5947879.27 562183.41 MWD+IFR-AK-CAZ-SC 7154.83 87.33 349.42 3658.90 3549.90 2159.04 3352.43 5947970.34 562164.76 MWD+IFR-AK-CAZ-SC 7201.93 84.40 351.71 3662.30 3553.30 2205.38 3344.72 5948016.61 562156.70 MWD+IFR-AK-CAZ-SC 7248.53 85.23 351.83 3666.51 3557.51 2251.31 3338.08 5948062.48 562149.70 MWD+IFR-AK-CAZ-SC ~!i 7296.67 85.35 350.09 3670.46 3561.46 2298.69 3330.54 5948109.80 562141.79 MWD+IFR-AK-CAZ-SC 7341.33 87.44 351.60 3673.27 3564.27 2342.69 3323.45 5948153.74 562134.36 MWD+IFR-AK-CAZ-SC 7387.96 89.17 353.94 3674.65 3565.65 2388.92 3317.59 5948199.92 562128.14 MWD+IFR-AK-CAZ-SC ~, I 7434.96 91.02 353.75 3674.57 3565.57 2435.65 3312.55 5948246.60 562122.73 MWD+IFR-AK-CAZ-SC 7475.62 91.22 353.99 3673.78 3564.78 2476.07 3308.21 5948286.98 562118.08 MWD+IFR-AK-CAZ-SC i 7528.10 90.23 353.95 3673.11 3564.11 2528.25 3302.70 5948339.12 562112.16 MWD+IFR-AK-CAZ-SC 7575.11 88.99 352.65 3673.43 3564.43 2574.94 3297.21 5948385.75 562106.31 MWD+IFR-AK-CAZ-SC 7621.68 89.61 352.60 3674.00 3565.00 2621.12 3291.23 5948431.88 562099.97 MWD+IFR-AK-CAZ-SC 7666.52 89.86 353.03 3674.21 3565.21 2665.61 3285.63 5948476.32 562094.02 MWD+IFR-AK-CAZ-SC 7715.23 90.91 352.04 3673.88 3564.88 2713.90 3279.30 5948524.56 562087.31 MWD+IFR-AK-CAZ-SC 7760.71 91.46 352.32 3672.94 3563.94 2758.95 3273.11 5948569.55 562080.77 MWD+IFR-AK-CAZ-SC 7808.60 90.04 351.55 3672.31 3563.31 2806.36 3266.39 5948616.90 562073.69 MWD+IFR-AK-CAZ-SC 7856.46 89.43 351.99 3672.54 3563.54 2853.73 3259.54 5948664.21 562066.47 MWD+IFR-AK-CAZ-SC 7901.68 87.95 350.25 3673.57 3564.57 2898.39 3252.56 5948708.81 562059.14 MWD+IFR-AK-CAZ-SC 7951.48 89.18 348.35 3674.82 3565.82 2947.31 3243.32 5948757.65 562049.52 MWD+IFR-AK-CAZ-SC 7995.49 89.37 348.94 3675.37 3566.37 2990.45 3234.66 5948800.72 562040.52 MWD+IFR-AK-CAZ-SC 8039.61 89.67 349.83 3675.74 3566.74 3033.81 3226.53 5948844.02 562032.05 MWD+IFR-AK-CAZ-SC 8089.77 89.92 350.46 3675.92 3566.92 3083.23 3217.94 5948893.36 562023.08 MWD+IFR-AK-CAZ-SC 8133.09 89.00 349.77 3676.33 3567.33 3125.91 3210.51 5948935.97 562015.31 MWD+IFR-AK-CAZ-SC 8182.69 89.00 350.89 3677.20 3568.20 3174.79 3202.18 5948984.79 562006.60 MWD+IFR-AK-CAZ-SC 8229.45 89.12 351.53 3677.96 3568.96 3221.00 3195.03 5949030.93 561999.10 MWD+IFR-AK-CAZ-SC ~, 8275.41 90.04 351.52 3678.30 3569.30 3266.46 3188.26 5949076.33 561991.97 MWD+IFR-AK-CAZ-SC ! 8321.08 89.86 350.70 3678.34 3569.34 3311.58 3181.20 5949121.39 561984.56 MWD+IFR-AK-CAZ-SC 8365.95 88.81 350.38 3678.86 3569.86 3355.83 3173.83 5949165.58 561976.84 MWD+IFR-AK-CAZ-SC Halliburton Company Survey Report Company: ConocoPhillips Alaska Inc. Field: Kuparuk River Unit Site: Kuparuk 1J Pad Well: 1J-115 Wellpath: 1 J-11511 Sun~ey I MD Inc! Azim TVD ft deg deg ft _- 8414.00 88.17 352.09 3680.1 8461.25 87.13 352.09 3682.0' 8496.93 86.49 351.40 3684.0: 8522.19 86.76 349.99 3685.5• 8554.17 87.67 350.22 3687.0! III 8604.39 88.71 349.90 3688.6 ~' 8648.82 88.46 350.01 3689.71 II 8695.34 89.57 351.46 3690.5' 8742.89 89.26 351.64 3691.01 8786.84 88.05 352.92 3692.0: 8833.79 89.41 353.20 3693.1; 8879.80 89.80 352.44 3693.4; ', 8928.64 89.68 353.85 3693.6 ~, 8973.33 .89.40 354.01 3694.0; 9020.00 90.88 355.09 3693.9; ', 9072.68 90.85 354.24 3693.1; 9116.46 90.54 353.67 3692.5' 9160.35 90.56 353.97 3692.1 9209.47 89.00 356.80 3692.31 9255.46 88.39 357.00 3693.41 9301.08 88.94 357.86 3694.4 9351.89 89.46 357.70 3695.1 9395.50 89.49 357.34 3695.5 9445.86 89.00 357.60 3696.2 9488.88 88.62 359.13 3697.1 9536.05 88.29 358.76 3698.4 9582.86 91.25 358.82 3698.5' ~I 9629.80 91.60 359.21 3697.4 ', 9676.08 88.94 358.07 3697.2 9722.93 88.11 357.15 3698.4 9768.86 89.08 359.57 3699.5 9818.12 88.19 0.50 3700.7 9862.65 88.50 0.30 3702.0 ' 9909.90 88.46 0.76 3703.2 9956.12 88.97 0.71 3704.2' 10002.72 89.04 1.00 3705.1 10050.85 89.12 1.27 3705.8 10144.02 90.10 0.78 3706.5 10237.34 91.22 0.47 3705.4 10280.75 90.99 359.05 3704.5 10329.60 88.80 358.52 3704.6 10423.14 89.06 357.65 3706.4 ~ 10516.86 88.32 358.82 3708.5 10558.70 88.81 358.92 3709.6, i 10609.27 89.31 358.08 3710.4 10653.20 90.35 358.34 3710.5 10702.84 88.82 358.97 3710.9 , 10786.88 89.69 0.78 3712.0 ' 10879.92 89.06 1.76 3713.0 10973.69 86.52 357.48 3716.6 11066.82 89.83 357.87 3719.6 11160.00 91.05 358.00 3718.9 11253.81 90.48 356.95 3717.6 Date: 12!19/2006 Time: 14:21:19 Page: 4 Co-ordioate(VE) Reference: Well: 1J-115, True North Vertical ('TVD) Reference: 1 J-1151.1: 109.0 Section (VS) Reference: Well (O.OON,O.OOE,O.OOAzi) Sun~ey Calculation 4tethod: Minimum Curvature Db: Oracle Sys TVD N/S E/W Map's ft ft ft ft __ 3571.13 3403.30 3166.51 5949212.99 3573.07 3450.06 3160.01 5949259.69 3575.05 3485.32 3154.90 5949294.90 3576.54 3510.20 3150.82 5949319.75 3578.09 3541.67 3145.33 5949351.17 3579.68 3591.11 3136.67 5949400.54 3580.78 3634.85 3128.92 5949444.21 3581.57 3680.75 3121.43 5949490.05 3582.06 3727.78 3114.44 5949537.02 3583.09 3771.32 3108.54 5949580.51 3584.13 3817.91 3102.87 5949627.05 3584.45 3863.56 3097.12 5949672.65 3584.67 3912.05 3091.29 5949721.08 3585.03 3956.49 3086.57 5949765.48 3584.92 4002.94 3082.13 5949811.90 3584.12 4055.39 3077.24 5949864.30 3583.59 4098.92 3072.63 5949907.79 3583.17 4142.56 3067.90 5949951.38 3583.36 4191.51 3063.95 5950000.29 3584.40 4237.42 3061.46 5950046.18 3585.47 4282.98 3059.42 5950091.72 3586.18 4333.75 3057.45 5950142.46 3586.58 4377.31 3055.56 5950186.01 3587.24 4427.62 3053.34 5950236.29 3588.13 4470.61 3052.11 5950279.27 3589.41 4517.76 3051.25 5950326.40 3589.59 4564.55 3050.26 5950373.18 3588.43 4611.47 3049.45 5950420.09 3588.21 4657.73 3048.35 5950466.34 3589.41 4704.52 3046.40 5950513.11 3590.54 4750.42 3045.09 5950558.99 3591.71 4799.66 3045.12 5950608.22 3593.00 4844.17 3045.43 5950652.73 3594.25 4891.40 3045.86 5950699.96 3595.29 4937.61 3046.46 5950746.16 3596.10 4984.20 3047.15 5950792.75 3596.87 5032.31 3048.10 5950840.87 3597.51 5125.46 3049.77 5950934.02 3596.43 5218.77 3050.79 5951027.32 3595.59 5262.17 3050.61 5951070.72 3595.68 5311.01 3049.57 5951119.54 3597.43 5404.48 3046.45 5951212.97 3599.57 5498.12 3043.56 5951306.59 3600.62 5539.94 3042.73 5951348.39 3601.45 5590.49 3041.41 5951398.92 3601.58 5634.40 3040.04 5951442.81 3601.94 5684.02 3038.87 5951492.42 3603.03 5768.05 3038.69 5951576.44 3604.05 5861:06 3040.75 5951669.45 3607.66 5954.73 3040.13 5951763.10 3610.63 6047.72 3036.36 5951856.05 3609.91 6140.83 3033.00 5951949.13 3608.66 6234.54 3028.87 5952042.80 ~tapE _ Tool ft 561969.15 MWD+IFR-AK-CAZ-SC 561962.29 MWD+IFR-AK-CAZ-SC 561956.90 MWD+tFR-AK-CAZ-SC 561952.63 MWD+IFR-AK-CAZ-SC 561946.90 MWD+IFR-AK-CAZ-SC 561937.85 MWD+IFR-AK-CAZ-SC 561929.76 MWD+IFR-AK-CAZ-SC 561921.91 MWD+IFR-AK-CAZ-SC 561914.56 MWD+IFR-AK-CAZ-SC 561908.32 MWD+IFR-AK-CAZ-SC 561902.28 MWD+IFR-AK-CAZ-SC 561896.18 MWD+IFR-AK-CAZ-SC 561889.97 MWD+IFR-AK-CAZ-SC 561884.90 MWD+IFR-AK-CAZ-SC 561880.10 MWD+IFR-AK-CAZ-SC 561874.79 MWD+IFR-AK-CAZ-SC 561869.85 MWD+IFR-AK-CAZ-SC 561864.78 MWD+IFR-AK-CAZ-SC 561860.45 MWD+IFR-AK-CAZ-SC 561857.60 MWD+IFR-AK-CAZ-SC 561855.20 MWD+IFR-AK-CAZ-SC 561852:84 MWD+IFR-AK-CAZ-SC 561850.61 MWD+IFR-AK-CAZ-SC 561847.99 MWD+IFR-AK-CAZ-SC 561846.43 MWD+IFR-AK-CAZ-SC 561845.20 MWD+IFR-AK-CAZ-SC 561843.84 MWD+IFR-AK-CAZ-SC 561842.67 MWD+IFR-AK-CAZ-SC 561841.21 MWD+IFR-AK-CAZ-SC 561838.89 MWD+IFR-AK-CAZ-SC 561837.22 MWD+IFR-AK-CAZ-SC 561836.86 MWD+IFR-AK-CAZ-SC 561836.83 MWD+IFR-AK-CAZ-SC 561836.89 MWD+IFR-AK-CAZ-SC 561837.13 MWD+IFR-AK-CAZ-SC 561837.46 MWD+IFR-AK-CAZ-SC 561838.03 MWD+IFR-AK-CAZ-SC 561838.97 MWD+IFR-AK-CAZ-SC 561839.26 MWD+IFR-AK-CAZ-SC 561838.74 MWD+IFR-AK-CAZ-SC 561837.32 MWD+IFR-AK-CAZ-SC 561833.47 MWD+IFR-AK-CAZ-SC 561829.85 MWD+IFR-AK-CAZ-SC 561828.70 MWD+IFR-AK-CAZ-SC 561826.98 MWD+IFR-AK-CAZ-SC 561825.27 MWD+IFR-AK-CAZ-SC 561823.71 MWD+IFR-AK-CAZ-SC 561822.87 MWD+IFR-AK-CAZ-SC 561824.21 MWD+IFR-AK-CAZ-SC 561822.86 MWD+IFR-AK-CAZ-SC 561818.36 MWD+IFR-AK-CAZ-SC 561814.27 MWD+IFR-AK-CAZ-SC 561809.41 MWD+IFR-AK-CAZ-SC i Halliburton Company Survey Report Company: ConocoPhillips Alaska Inc. Date: 12(19/2006 Time: 14:21:19 Page: 5 Field: Kuparuk River Unit Co-ordinate(NE) Reference: WeII: 1J-115, True North Site: Kuparuk 1J Pad Vertical (TVD) Reference: 1J-115L1: 109.0 Well: 1J-115 Section (VS) Reference: Well (O.OON,O.OOE,O.OOAzi) Wellpath: 1J-115L1 Survey Calculation Method: Minimum Curvature Db: Oracle tiun cv MD Incl Azim TVD Sys TVD N/S ElW M11apN 61apE Tool ft deg deg ft ft ft ft ft ft 11347.79 86.14 358.43 3720.43 3611.43 6328.38 3025.08 5952136.59 561804.89 MWD+IFR-AK-CAZ-SC 11441.44 88.21 358.38 3725.05 3616.05 6421.88 3022.48 5952230.06 561801.56 MWD+IFR-AK-CAZ-SC 11534.71 91.80 358.31 3725.04 3616.04 6515.09 3019.79 5952323.24 561798.14 MWD+IFR-AK-CAZ-SC 11626.88 93.40 0.54 3720.86 3611.86 6607.15 3018.86 5952415.28 561796.49 MWD+IFR-AK-CAZ-SC 11721.22 92.52 1.08 3715.99 3606.99 6701.36 3020.19 5952509.48 561797.09 MWD+IFR-AK-CAZ-SC 11810.81 90.23 1.76 3713.84 3604.84 6790.89 3022.41 5952599.02 561798.61 MWD+IFR-AK-CAZ-SC 11902.33 90.49 1.89 3713.26 3604.26 6882.36 3025.33 5952690.50 561800.81 MWD+IFR-AK-CAZ-SC ', 11992.04 89.43 3.09 3713.33 3604.33 6971.98 3029.22 5952780.14 561804.00 MWD+IFR-AK-CAZ-SC 12081.89 88.51 2.58 3714.94 3605.94 7061.71 3033.67 5952869.89 561807.75 MWD+IFR-AK-CAZ-SC 12172.02 87.89 2.61 3717.77 3608.77 7151.70 3037.75 5952959.90 561811.12 MWD+IFR-AK-CAZ-SC 12262.84 86.09 1.86 3722.54 3613.54 7242.32 3041.28 5953050.54 561813.95 MWD+IFR-AK-CAZ-SC 12354.72 87.40 1.81 3727.76 3618.76 7334.00 3044.22 5953142.24 561816.17 MWD+IFR-AK-CAZ-SC 12445.54 87.27 2.32 3731.98 3622.98 7424.66 3047.49 5953232.91 561818.73 MWD+IFR-AK-CAZ-SC 12535.78 87.71 2.20 3735.93 3626.93 7514.75 3051.04 5953323.01 561821.58 MWD+IFR-AK-CAZ-SC 12580.06 88.27 1.56 3737.49 3628.49 7558.98 3052.50 5953367.25 561822.69 MWD+IFR-AK-CAZ-SC 12627.17 88.01 359.95 3739.01 3630.01 7606.06 3053.12 5953414.32 561822.94 MWD+IFR-AK-CAZ-SC I 12717.41 88.51 0.00 3741.75 3632.75 7696.25 3053.08 5953504.51 561822.20 MWD+IFR-AK-CAZ-SC 12805.78 89.44 358.48 3743.34 3634.34 7784.60 3051.91 5953592.84 561820.33 MWD+IFR-AK-CAZ-SC 12895.78 88.94 357.78 3744.61 3635.61 7874.54 3048.97 5953682.74 561816.70 MWD+IFR-AK-CAZ-SC ', 12986.82 88.14 357.60 3746.93 3637.93 7965.48 3045.30 5953773.64 561812.32 MWD+IFR-AK-CAZ-SC 13077.33 90.13 357.65 3748.29 3639.29 8055.89 3041.55 5953864.02 561807.86 MWD+IFR-AK-CAZ-SC 13170.44 90.86 357.56 3747.49 3638.49 8148.92 3037.66 5953957.00 561803.24 MWD+IFR-AK-CAZ-SC ~~ 13261.27 89.05 359.00 3747.56 3638.56 8239.70 3034.93 5954047.75 561799.81 MWD+IFR-AK-CAZ-SC i 13351.65 89.94 358.53 3748.36 3639.36 8330.06 3032.99 5954138.08 561797.16 MWD+IFR-AK-CAZ-SC 13441.64 89.87 0.26 3748.51 3639.51 8420.04 3032.04 5954228.04 561795.50 MWD+IFR-AK-CAZ-SC i 13532.74 88.32 0.94 3749.95 3640.95 8511.12 3032.99 5954319.11 561795.74 MWD+IFR-AK-CAZ-SC i 13623.70 85.84 359.72 3754.58 3645.58 8601.95 3033.51 5954409.94 561795.56 MWD+IFR-AK-CAZ-SC 13714.69 86.35 358.50 3760.78 3651.78 8692.71 3032.10 5954500.68 561793.44 MWD+IFR-AK-CAZ-SC 13808.26 86.60 359.02 3766.53 3657.53 8786.09 3030.08 5954594.02 561790.69 MWD+tFR-AK-CAZ-SC ~ 13888.03 85.18 359.14 3772.25 3663.25 8865.64 3028.80 5954673.56 561788.79 MWD+IFR-AK-CAZ-SC i .13922.00 85.18 359.14 3775.10 3666.10 8899.48 3028.30 5954707.39 ~ 561788.02 ~ PROJECTED to TD • Halliburton Company Survey Report • Company: ConocoPhillips Alaska Inc. Date: 12/19/2006 " Time: 13:56:56 Page: 1 Field: Kuparuk River Unit Co-ordinatc(NE) Reference: Well: 1J-115, True North Site: Kuparuk 1J Pad Vertical (TVD) Reference: 1J-115L1PB1: 109A Well: 1J-115 Section (VS) Reference: Well (O.OON,O.OOE,O.OOAzi) Wellpath: 1J-115L1PB1 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 Sys Datum: Mean Sea Level Geomagnetic Model: bggm2006 ~~ Well: 1J-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 Wellpath: 1 J-115L1 PB1 Drilled From: 1 J-115PB1 500292332074 Tie-on Depth: 6485.62 ft Current Datum: 1 J-115L1 P81: Height 109.00 ft Above System Datum: Mean Sea Level Magnetic Data: 9/25/2006 Field Strength: 57610 nT Declination: 23.78 deg 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 -- - r- 50.00 1016.00 1J-115P61 gyro (50.00-1016.00) CB-GYRO-SS Camera based gyro single shot 1147.04 6485.62 1J-115P61 (1147.04-8360.39) (3 MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC ~I 6529.00 7476.96 1J-115L1PB1 (6529.00-7476.96) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC Survey D~tD Lrel Azim '1"VD Sys TVD N/S E/W MapN MapE 'Tool ft deg deg ft 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 ~'I 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 it 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 IFR-AK- AZ- C MWD C S 1956.90 56.75 96.14 1761.50 1652.50 -74.34 622.16 5945715.91 559452.29 MWD+IFR-AK-CAZ-SC 'i 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 i • Halliburton Company Survey Report Company: ConocoPhillips Alaska Inc, Field: Kuparuk River Unit Site: Kuparuk 1J Pad Nell: 1 J-115 ~Vellpath: 1 J-115L1 PB1 Survev __ ___ bID Inc! Azim TVD Sys Tb~ ft deg deg ft ft 2146.11 66.24 94.32 1850.23 1741.23 2195.14 65.38 94.46 1870.32 1761.32 2243.32 65.22 94.86 1890.46 1781.46 2290.05 65.23 95.29 1910.04 1801.04 2384.30 66.21 92.85 1948.80 1839.80 2431.35 66.51 91.83 1967.67 1858.67 2479.29 65.14 92.38 1987.30 1878.30 2525.10 64.21 92.41 2006.89 1897.89 2574.27 64.84 92.04 2028.04 1919.04 2621.23 65.32 92.80 2047.83 1938.83 2668.37 64.85 93.77 2067.69 1958.69 2716.31 63.56 93.99 2088.55 1979.55 2764.95 62.48 93.85 2110.61 2001.61 2792.69 63.61 94.72 2123.19 2014.19 2858.21 64.46 95.53 2151.88 2042.88 2923.29 65.79 94.45 2179.25 2070.25 2953.10 65.83 94.21 2191.47 2082.47 3020.46 64.26 94.73 2219.88 2110.88 3066.57 63.09 96.12 2240.33 2131.33 '~ 3115.25 62.06 96.47 2262.75 2153.75 3161.89 60.79 95.77 2285.06 2176.06 3207.64 59.59 95.17 2307.81 2198.81 3257.07 59.30 95.67 2332.93 2223.93 ~ 3302.16 60.64 95.08 2355.50 2246.50 3351.77 61.76 94.04 2379.40 2270.40 3397.36 61.52 94.13 2401.05 2292.05 3445.60 61.94 94.01 2423.90 2314.90 3541.93 64.26 92.53 2467.48 2358.48 ~, 3587.60 63.76 92.85 2487.50 2378.50 3637.30 63.20 92.99 2509.69 2400.69 3683.58 62.11 93.43 2530.95 2421.95 3730.50 61.48 93.54 2553.12 2444.12 3783.12 62.18 92.50 2577.96 2468.96 3826.51 61.89 92.49 2598.31 2489.31 3873.70 62.90 92.02 2620.18 2511.18 3921.50 64.20 91.19 2641.47 2532.47 3975.48 62.84 89.69 2665.54 2556.54 !~ ', 4011.14 63.44 87.24 2681.65 2572.65 j 4065.80 63.59 84.65 2706.03 2597.03 4111.07 63.08 .82.85 2726.35 2617.35 4161.60 62.71 82.07 2749.37 2640.37 4207.41 62.05 81.09 2770.61 2661.61 ~I~ 4302.87 60.78 75.96 2816.31 2707.31 4397.88 61.00 71.95 2862.54 2753.54 4444.65 61.15 70.43 2885.16 2776.16 4493.15 62.09 66.97 2908.22 2799.22 4587.16 63.03 60.70 2951.58 2842.58 4681.64 63.67 55.12 2993.98 2884.98 4776.45 63.61 48.37 3036.12 2927.12 4872.66 62.93 42.02 3079.43 2970.43 4966.48 62.78 36.83 3122.25 3013.25 ~, 5061.23 63.60 30.93 3165.02 3056.02 Date: 12119!2006 Time:. 13:56:56 Page: 2 Co-ordinate(NE) Reference: Well: 1J-115, True North Vertical (TVll) Reference: 1 J-115L1 PB1: 109.0 Section (VS) Reference: Well (O.OON,O.OOE,O.OOAzi) Sun~ey Calculation Method: Minimum Curvature Db: Oracle N/S H;/yti' I1fapN ft ft ft -87. 70 788 .46 5945703. 85 -91. 13 833 .06 5945700. 77 -94. 68 876 .68 5945697. 56 -98. 44 918 .95 5945694. 13 -104. 53 1004 .63 5945688. 71 -106. 29 1047 .70 5945687. 29 -107. 89 1091 .40 5945686. 03 -109. 62 1132 .78 5945684. 62 -111. 35 1177 .13 5945683. 24 -113. 14 1219 .68 5945681. 78 -115. 59 1262 .36 5945679. 66 -118. 51 1305 .43 5945677. 08 -121. 48 1348 .67 5945674. 45 -123. 33 1373 .33 5945672. 80 -128. 59 1432 .00 5945667. 99 -133. 72 1490 .81 5945663. 32 -135. 77 1517 .93 5945661. 48 -140. 53 1578 .81 5945657. 20 -144. 44 1619 .95 5945653. 62 -149. 17 1662 .90 5945649. 22 -153. 54 1703 .62 5945645. 17 -157. 33 1743 .14 5945641. 69 -161. 35 1785 .51 5945638. 00 -165. 00 1824 .38 5945634. 65 -168. 46 1867 .71 5945631. 54 -171. 31 1907 .73 5945628. 99 -174. 33 1950 .11 5945626. 31 -179. 22 2035 .87 5945622. 09 -181. 14 2076 .87 5945620. 48 -183. 41 2121 .28 5945618. 57 -185. 71 2162 .33 5945616. 59 -188. 22 2203 .60 5945614. 39 -190. 67 2249 .92 5945612. 31 -192. 33 2288 .21 5945610. 95 -193. 98 2329 .99 5945609. 63 -195. 18 2372 .77 5945608. 77 -195. 55 2421 .08 5945608. 77 -194. 70 2452 .88 5945609. 87 -191. 24 2501 .68 5945613. 71 -186. 83 2541 .89 5945618 .43 -180. 93 2586 .48 5945624 .68 -174. 99 2626 .63 5945630 .93 -158. 35 2708 .74 5945648 .22 -135. 41 2788 .49 5945671 .78 -122. 21 2827 .24 5945685 .28 -106. 71 2866 .99 5945701 .09 -69. 92 2941 .81 5945738 .45 -25. 08 3013 .30 5945783 .84 27. 48 3079 .96 5945836 .91 87. 98 3140 .89 5945897 .88 152. 43 3193 .89 5945962 .74 222. 60 3240 .99 5946033 .27 b1apE Tool ft 559618.68 MWD+IFR-AK-CAZ-SC 559663.29 MWD+IFR-AK-CAZ-SC 559706.94 MWD+IFR-AK-CAZ-SC 559749.23 MWD+IFR-AK-CAZ-SC 559834.95 MWD+IFR-AK-CAZ-SC 559878.03 MWD+IFR-AK-CAZ-SC 559921.74 MWD+IFR-AK-CAZ-SC 559963.12 MWD+IFR-AK-CAZ-SC 560007.48 MWD+IFR-AK-CAZ-SC 560050.04 MWD+IFR-AK-CAZ-SC 560092.74 MWD+IFR-AK-CAZ-SC 560135.82 MWD+IFR-AK-CAZ-SC 560179.08 MWD+IFR-AK-CAZ-SC 560203.75 MWD+IFR-AK-CAZ-SC 560262.45 MWD+IFR-AK-CAZ-SC 560321.30 MWD+IFR-AK-CAZ-SC 560348.43 MWD+IFR-AK-CAZ-SC 560409.34 MWD+IFR-AK-CAZ-SC 560450.50 MWD+IFR-AK-CAZ-SC 560493.48 MWD+IFR-AK-CAZ-SC 560534.24 MWD+IFR-AK-CAZ-SC 560573.78 MWD+IFR-AK-CAZ-SC 560616.18 MWD+IFR-AK-CAZ-SC 560655.07 MWD+IFR-AK-CAZ-SC 560698.42 MWD+IFR-AK-CAZ-SC 560738.46 MWD+IFR-AK-CAZ-SC 560780.85 MWD+IFR-AK-CAZ-SC 560866.64 MWD+IFR-AK-CAZ-SC 560907.65 MWD+IFR-AK-CAZ-SC 560952.08 MWD+IFR-AK-CAZ-SC 560993.14 MWD+IFR-AK-CAZ-SC 561034.42 MWD+IFR-AK-CAZ-SC 561080.76 MWD+IFR-AK-CAZ-SC 561119.05 MWD+IFR-AK-CAZ-SC 561160.84 MWD+IFR-AK-CAZ-SC 561203.63 MWD+IFR-AK-CAZ-SC 561251.94 MWD+IFR-AK-CAZ-SC 561283.72 MWD+IFR-AK-CAZ-SC 561332.49 MWD+IFR-AK-CAZ-SC 561372.66 MWD+IFR-AK-CAZ-SC 561417.20 MWD+IFR-AK-CAZ-SC 561457.30 MWD+IFR-AK-CAZ-SC 561539.27 MWD+IFR-AK-CAZ-SC 561618.83 MWD+IFR-AK-CAZ-SC 561657.47 MWD+IFR-AK-CAZ-SC 561697.09 MWD+IFR-AK-CAZ-SC 561771.61 MWD+IFR-AK-CAZ-SC 561842.75 MWD+IFR-AK-CAZ-SC 561908.99 MWD+IFR-AK-CAZ-SC 561969.44 MWD+IFR-AK-CAZ-SC 562021.92 MWD+IFR-AK-CAZ-SC 562068.47 MWD+IFR-AK-CAZ-SC • ' Halliburton Company Survey Report __ Company: ConocoPhillips Alaska Inc. Date: 12/19/2006 Time: 13:56:56 Page: 3 Field: Kuparuk River Unit Co-ordinate(NE) Reference: Well: 1J-115, True North Site: Kuparuk 1J Pad Vertieat(TVD)Reference: 1J-115L1P61: 109A Well: 1 J-115 Section (VS) Reference: Well (O.OON,O.OOE,O.OOAzi} Wellpath: 1J-115L1PB1 Survey Calculation Method: Minimum Curvature Db: Oracle Survev __ _ _ __ D1D Incl Azim TVD Svs TVD N/S E/W b1apN MapP; "Pool 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 i 6529.00 76.30 350.40 3640.12 3531.12 1546.05 3471.26 5947358.35 562288.37 MWD+IFR-AK-CAZ-SC 6541.00 78.90 350.18 3642.70 3533.70 1557.60 3469.28 5947369.88 562286.31 MWD+IFR-AK-CAZ-SC 6595.09 82.84 349.19 3651.28 3542.28 1610.13 3459.72 5947422.33 562276.33 MWD+IFR-AK-CAZ-SC IFR-AK- AZ-SC 6645.22 86.56 348.30 3655.91 3546.91 1659.07 3449.98 5947471.20 562266.21 MWD C 6687.80 89.40 347.55 3657.41 3548.41 1700.68 3441.08 5947512.73 562256.99 MWD+IFR-AK-CAZ-SC 6781.00 92.69 349.62 3655.71 3546.71 1792.01 3422.64 5947603.90 562237.83 MWD+IFR-AK-CAZ-SC . 1 MWD+IFR-AK-CAZ-SC 6875.77 87.80 349.96 3655.30 3546.30 1885.25 3405.84 5947696.99 562220 3 6968.94 91.65 348.86 3655.75 3546.75 1976.81 3388.72 5947788.41 562202.48 MWD+IFR-AK-CAZ-SC 7061.80 88.57 348.33 3655.57 3546.57 2067.82 3370.36 5947879.27 562183.41 MWD+IFR-AK-CAZ-SC 7154.83 87.33 349.42 3658.90 3549.90 2159.04 3352.43 5947970.34 562164.76 MWD+IFR-AK-CAZ-SC 7248.74 91.22 352.09 3660.09 3551.09 2251.70 3337.35 5948062.87 562148.96 MWD+IFR-AK-CAZ-SC 7342.10 93.44 351.94 3656.29 3547.29 2344.07 3324.39 5948155.13 562135.28 MWD+IFR-AK-CAZ-SC 7385.66 94.70 351.69 3653.20 3544.20 2387.08 3318.20 5948198.08 562128.76 MWD+IFR-AK-CAZ-SC 7435.08 95.60 351.67 3648.77 3539.77 2435.78 3311.08 5948246.72 562121.26 MWD+IFR-AK-CAZ-SC ', 7476.96 96.35 352.67 3644.41 3535.41 2477.05 3305.41 5948287.93 562115.27 MWD+IFR-AK-CAZ-SC 7522.00 96.35 352.67 3639.43 3530.43 2521.44 3299.69 5948332.28 562109.21 PROJECTED to TD Halliburton Company Survey Report Company: ConocoPhillips Alaska Inc. Da[e: 12/19/2006 Time:. 14:06:14 Page: 1 Field: Kuparuk River Unit Co-ordiuate(NE) Kefcrence: Well: 1 J-115, True North Site: KuparuklJPad Vertical (TVD)Reference: 1J-115L1P62: 109.0 Well: 1 J-115 Section (VS) Reference: Well (O.OON,O.OOE,@DOAzi) Wellpath: 1J-115L1PB2 ___ Survey Calculation Method: Minimum Curvature Db: Oracle _ __- ~~ Field: Kuparuk River Unit NorthSlope 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: 1J-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 ~ Wellpath: 1J-115L1P62 Drilled From: 1J-115L1PB1 500292332075 Tie-on Depth: 7154.83 ft Current Datum: 1 J-115L1 P62: 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 ft deg 28.00 _ 0.00 0.00 _ 0.00 Survey Program for Definkive Wellpath ~ ' Date: 12/19/2006 Validated: No Version: 1 Actual From To Survey Toolcode Tool Name ft ft 50.00 1016.00 1J-115P61 gyro (50.00-1016.00) CB-GYRO-SS Camera based gyro single shot 1147.04 6485.62 1J-115P61 (1147.04-8360.39) (3 MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 6529.00 7154.83 1J-115L1P61 (6529.00-7476.96) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 7201.93 8603.98 1J-115L1PB2 (7201.93-8603.98) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC Survey SID 6u1 Azim TVD Sys TVU N/S E/W' Mapti MapE Tnol ft deg deg ft 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 ~I 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 I 734.00 12.14 85.32 732.06 623.06 1.62 30.43 5945787.23 558860.04 CB-GYRO-SS I 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 j 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 • Halliburton Company Survey Report Company: ConocoPhillips Alaska Inc. Field: Kuparuk River Unit Site: Kuparuk 1J Pad Well: 1J-115 Wellpath: 1J-1151.1 PB7 Suiti~ev SID Inc! Azim TVD I ft deg deg ft 2099.08 65.15 94.08 1830.88 ~~ 2146.11 66.24 94.32 1850.23 2195.14 65.38 94.46 1870.32 I 2243.32 65.22 94.86 1890.46 2290.05 65.23 95.29 1910.04 2384.30 66.21 92.85 1948.80 2431.35 66.51 91.83 1967.67 2479.29 65.14 92.38 1987.30 2525.10 64.21 92.41 2006.89 2574.27 64.84 92.04 2028.04 2621.23 65.32 92.80 2047.83 2668.37 64.85 93.77 2067.69 2716.31 63.56 93.99 2088.55 ~~ 2764.95 62.48 93.85 2110.61 ~, 2792.69 63.61 94.72 2123.19 2858.21 64.46 95.53 2151.88 2923.29 65.79 94.45 2179.25 2953.10 65.83 94.21 2191.47 3020.46 64.26 94.73 2219.88 3066.57 63.09 96.12 2240.33 3115.25 62.06 96.47 2262.75 3161.89 60.79 95.77 2285.06 3207.64 59.59 95.17 2307.81 3257.07 59.30 95.67 2332.93 3302.16 60.64 95.08 2355.50 3351.77 61.76 94.04 2379.40 3397.36 61.52 94.13 2401.05 3445.60 61.94 94.01 2423.90 3541.93 64.26 92.53 2467.48 3587.60 63.76 92.85 2487.50 3637.30 63.20 92.99 2509.69 3683.58 62.11 93.43 2530.95 3730.50 61.48 93.54 2553.12 3783.12 62.18 92.50 2577.96 3826.51 61.89 92.49 2598.31 3873.70 62.90 92.02 2620.18 3921.50 64.20 91.19 2641.47 ~ 3975.48 62.84 89.69 2665.54 4011.14 63.44 87.24 2681.65 4065.80 63.59 84.65 2706.03 4111.07 63.08 82.85 2726.35 4161.60 62.71 82.07 2749.37 4207.41 62.05 81.09 2770.61 4302.87 60.78 75.96 2816.31 4397.88 61.00 71.95 2862.54 4444.65 61.15 70.43 2885.16 4493.15 62.09 66.97 2908.22 4587.16 63.03 60.70 2951.58 4681.64 63.67 55.12 2993.98 4776.45 63.61 48.37 3036.12 4872.66 62.93 42.02 3079.43 4966.48 62.78 36.83 3122.25 ii ' 5061.23 63.60 30.93 3165.02 Date: 12/19!2006 Time: 14:06:14 Page: ~ Co-ordinate(NE) Reference: Well: 1J-115, True North Vertical (TV D) Reference: 1J-115L1 PB2: 109.0 Section (VS) Reference: Well (O.OON,O.OOE,O.OOAzi) Surrey Calculation Illethod: Minimum Curvature Ub: Oracle Sys TVD N/S E/W MapN ft ft ft ft 1721. 88 -84. 57 745. 72 5945706 .65 1741. 23 -87. 70 788. 46 5945703 .85 1761. 32 -91. 13 833. 06 5945700 .77 1781. 46 -94. 68 876. 68 5945697 .56 1801. 04 -98. 44 918. 95 5945694 .13 1839. 80 -104. 53 1004. 63 5945688 .71 1858. 67 -106. 29 1047. 70 5945687 .29 1878. 30 -107. 89 1091. 40 5945686 .03 1897. 89 -109. 62 1132. 78 5945684 .62 1919. 04 -111. 35 1177. 13 5945683 .24 1938. 83 -113. 14 1219. 68 5945681 .78 1958. 69 -115. 59 1262. 36 5945679 .66 1979. 55 -118. 51 1305. 43 5945677 .08 2001. 61 -121. 48 1348. 67 5945674 .45 2014. 19 -123. 33 1373. 33 5945672 .80 2042. 88 -128. 59 1432. 00 5945667 .99 2070. 25 -133. 72 1490. 81 5945663 .32 2082. 47 -135. 77 1517. 93 5945661 .48 2110. 88 -140. 53 1578. 81 5945657 .20 2131. 33 -144. 44 1619. 95 5945653 .62 2153. 75 -149. 17 1662. 90 5945649 .22 2176. 06 -153. 54 1703. 62 5945645 .17 2198. 81 -157. 33 1743. 14 5945641 .69 2223. 93 -161. 35 1785. 51 5945638 .00 2246. 50 -165. 00 1824. 38 5945634 .65 2270. 40 -168. 46 1867. 71 5945631 .54 2292. 05 -171. 31 1907. 73 5945628 .99 2314. 90 -174. 33 1950. 11 5945626 .31 2358. 48 -179. 22 2035. 87 5945622 .09 2378. 50 -181. 14 2076. 87 5945620 .48 2400. 69 -183. 41 2121. 28 5945618 .57 2421. 95 -185. 71 2162. 33 5945616 .59 2444. 12 -188. 22 2203. 60 5945614 .39 2468. 96 -190. 67 2249. 92 5945612 .31 2489. 31 -192. 33 2288. 21 5945610 .95 2511. 18 -193. 98 2329. 99 5945609 .63 2532. 47 -195. 18 2372. 77 5945608 .77 2556. 54 -195. 55 2421. 08 5945608 .77 2572. 65 -194. 70 2452. 88 5945609 .87 2597. 03 -191. 24 2501. 68 5945613 .71 2617. 35 -186. 83 2541. 89 5945618 .43 2640. 37 -180. 93 2586. 48 5945624 .68 2661. 61 -174. 99 2626. 63 5945630 .93 2707. 31 -158. 35 2708. 74 5945648 .22 2753. 54 -135. 41 2788. 49 5945671 .78 2776. 16 -122. 21 2827. 24 5945685 .28 2799. 22 -106. 71 2866. 99 5945701 .09 2842. 58 -69. 92 2941. 81 5945738 .45 2884. 98 -25. 08 3013. 30 5945783 .84 2927. 12 27. 48 3079. 96 5945836 .91 2970. 43 87. 98 3140. 89 5945897 .88 3013. 25 152. 43 3193. 89 5945962 .74 3056. 02 222. 60 3240. 99 5946033 .27 ~IapE Tuul ft 559575.91 MWD+IFR-AK-CAZ-SC 559618.68 MWD+IFR-AK-CAZ-SC 559663.29 MWD+IFR-AK-CAZ-SC 559706.94 MWD+IFR-AK-CAZ-SC 559749.23 MWD+IFR-AK-CAZ-SC 559834.95 MWD+IFR-AK-CAZ-SC 559878.03 MWD+IFR-AK-CAZ-SC 559921.74 MWD+IFR-AK-CAZ-SC 559963.12 MWD+IFR-AK-CAZ-SC 560007.48 MWD+IFR-AK-CAZ-SC 560050.04 MWD+IFR-AK-CAZ-SC 560092.74 MWD+IFR-AK-CAZ-SC 560135.82 MWD+IFR-AK-CAZ-SC 560179.08 MWD+IFR-AK-CAZ-SC 560203.75 MWD+IFR-AK-CAZ-SC 560262.45 MWD+IFR-AK-CAZ-SC 560321.30 MWD+IFR-AK-CAZ-SC 560348.43 MWD+IFR-AK-CAZ-SC 560409.34 MWD+IFR-AK-CAZ-SC 560450.50 MWD+IFR-AK-CAZ-SC 560493.48 MWD+IFR-AK-CAZ-SC 560534.24 MWD+IFR-AK-CAZ-SC 560573.78 MWD+IFR-AK-CAZ-SC 560616.18 MWD+IFR-AK-CAZ-SC 560655.07 MWD+IFR-AK-CAZ-SC 560698.42 MWD+IFR-AK-CAZ-SC 560738.46 MWD+IFR-AK-CAZ-SC 560780.85 MWD+IFR-AK-CAZ-SC 560866.64 MWD+IFR-AK-CAZ-SC 560907.65 MWD+IFR-AK-CAZ-SC 560952.08 MWD+IFR-AK-CAZ-SC 560993.14 MWD+IFR-AK-CAZ-SC 561034.42 MWD+IFR-AK-CAZ-SC 561080.76 MWD+IFR-AK-CA2-SC 561119.05 MWD+IFR-AK-CAZ-SC 561160.84 MWD+IFR-AK-CAZ-SC 561203.63 MWD+IFR-AK-CAZ-SC 561251.94 MWD+IFR-AK-CAZ-SC 561283.72 MWD+IFR-AK-CAZ-SC 561332.49 MWD+IFR-AK-CAZ-SC 561372.66 MWD+IFR-AK-CAZ-SC 561417.20 MWD+IFR-AK-CAZ-SC 561457.30 MWD+IFR-AK-CAZ-SC 561539.27 MWD+fFR-AK-CAZ-SC 561618.83 MWD+IFR-AK-CAZ-SC 561657.47 MWD+IFR-AK-CAZ-SC 561697.09 MWD+IFR-AK-CAZ-SC 561771.61 MWD+IFR-AK-CAZ-SC 561842.75 MWD+IFR-AK-CAZ-SC 561908.99 MWD+IFR-AK-CAZ-SC 561969.44 MWD+IFR-AK-CAZ-SC 562021.92 MWD+IFR-AK-CAZ-SC 562068.47 MWD+IFR-AK-CAZ-SC • • Halliburton Company Survey Report Company: ConocoPhillips Alaska Inc. Date: 12!19/2006 ' l'ime: 14:06:14 Page: 3 Field: Kuparuk River Unit Co-ordinate(NE) Reference: Well: 1J-115, True North Site: Kuparuk 1J Pad Vertical (TVD) Reference: 1J-115L1P62: 109.0 Nell: 1J-115 Section (VS) Reference: Well (O.OON.O.OOE,O.OOAzi) Wellpxth: , 1J-t15L1 PB2 Survey Calcalation Method: Minimum Curvature Db: Oracle ' Sun°c~~ __ MD __ lncl Azim `t'VD Sys "t'VD N/S E/W MapN MapE Tool ft deg deg ft ft ft ft ft __ ft __ i, 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. I 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. I 71 75. 39 0. 95 3533 .87 3424 .87 1042 .66 3518. 07 5946855. 39 562339. 11 MWD+IFR-AK-CAZ-SC II 6106. 21 77. 01 355. 82 3556 .43 3447 .43 1134 .36 3515. 47 5946947. 06 562335. 80 MWD+IFR-AK-CAZ-SC i 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 6529. 00 76. 30 350. 40 3640 .12 3531 .12 1546 .05 3471 .26 5947358. 35 562288. 37 MWD+IFR-AK-CAZ-SC 6541. 00 78. 90 350. 18 3642 .70 3533 .70 1557 .60 3469 .28 5947369. 88 562286. 31 MWD+IFR-AK-CAZ-SC 6595. 09 82. 84 349. 19 3651 .28 3542 .28 1610 .13 3459 .72 5947422. 33 562276. 33 MWD+IFR-AK-CAZ-SC 6645. 22 86. 56 348. 30 3655 .91 3546 .91 1659 .07 3449 .98 5947471. 20 562266. 21 MWD+IFR-AK-CAZ-SC 6687. 80 89. 40 347. 55 3657 .41 3548 .41 1700 .68 3441 .08 5947512. 73 562256. 99 MWD+IFR-AK-CAZ-SC 6781. 00 92. 69 349. 62 3655 .71 3546 .71 1792 .01 3422 .64 5947603. 90 562237. 83 MWD+IFR-AK-CAZ-SC ~~ 6875. 77 87. 80 349. 96 3655 .30 3546 .30 1885 .25 3405 .84 5947696. 99 562220. 31 MWD+IFR-AK-CAZ-SC I 6968. 94 91. 65 348. 86 3655 .75 3546 .75 1976 .81 3388 .72 5947788. 41 562202. 48 MWD+IFR-AK-CAZ-SC I 7061. 80 88. 57 348. 33 3655 .57 3546 .57 2067 .82 3370 .36 5947879. 27 562183. 41 MWD+IFR-AK-CAZ-SC 7154. 83 87. 33 349. 42 3658 .90 3549 .90 2159 .04 3352 .43 5947970. 34 562164. 76 MWD+IFR-AK-CAZ-SC 7201. 93 84. 40 351. 71 3662 .30 3553 .30 2205 .38 3344 .72 5948016. 61 562156. 70 MWD+IFR-AK-CAZ-SC 7248. 53 85. 23 351. 83 3666 .51 3557 .51 2251 .31 3338 .08 5948062. 48 562149. 70 MWD+IFR-AK-CAZ-SC 7296. 67 85. 35 350. 09 3670 .46 3561 .46 2298 .69 3330 .54 5948109. 80 562141. 79 MWD+IFR-AK-CAZ-SC 7341. 33 87. 44 351. 60 3673 .27 3564 .27 2342 .69 3323 .45 5948153. 74 562134. 36 MWD+IFR-AK-CAZ-SC I 7387. 96 89. 17 353. 94 3674 .65 3565 .65 2388 .92 3317 .59 5948199. 92 562128. 14 MWD+IFR-AK-CAZ-SC 7434. 96 91. 02 353. 75 3674 .57 3565 .57 2435 .65 3312 .55 5948246. 60 562122. 73 MWD+IFR-AK-CAZ-SC ', 7475. 62 91. 22 353. 99 3673 .78 3564 .78 2476 .07 3308 .21 5948286. 98 562118. 08 MWD+IFR-AK-CAZ-SC 7528. 10 90. 23 353. 95 3673 .11 3564 .11 2528 .25 3302 .70 5948339. 12 562112. 16 MWD+IFR-AK-CAZ-SC 7575. 11 88. 99 352. 65 3673 .43 3564 .43 2574 .94 3297 .21 5948385. 75 562106. 31 MWD+IFR-AK-CAZ-SC 7621. I 68 89. 61 352. 60 3674 .00 3565 .00 2621 .12 3291 .23 5948431. 88 562099. 97 MWD+IFR-AK-CAZ-SC ~! 7666. 52 89. 86 353. 03 3674 .21 3565 .21 2665 .61 3285 .63 5948476. 32 562094. 02 MWD+IFR-AK-CAZ-SC I 7715. 23 90. 91 352. 04 3673 .88 3564 .88 2713 .90 3279 .30 5948524. 56 562087. 31 MWD+IFR-AK-CAZ-SC I 7760. 71 91. 46 352. 32 3672 .94 3563 .94 2758 .95 3273 .11 5948569. 55 562080. 77 MWD+IFR-AK-CAZ-SC I 7808. 60 90. 04 351 .55 3672 .31 3563 .31 2806 .36 3266 .39 5948616. 90 562073. 69 MWD+IFR-AK-CAZ-SC I 7856. 46 89. 43 351. 99 3672 .54 3563 .54 2853 .73 3259 .54 5948664. 21 562066. 47 MWD+IFR-AK-CAZ-SC 7901. 68 87. 95 350 .25 3673 .57 3564 .57 2898 .39 3252 .56 5948708. 81 562059. 14 MWD+IFR-AK-CAZ-SC 7951. 48 89. 18 348 .35 3674 .82 3565 .82 2947 .31 3243 .32 5948757. 65 562049. 52 MWD+IFR-AK-CAZ-SC 7995. 49 89. 37 348 .94 3675 .37 3566 .37 2990 .45 3234 .66 5948800. 72 562040. 52 MWD+IFR-AK-CAZ-SC 8039. 61 89. 67 349 .83 3675 .74 3566 .74 3033 .81 3226 .53 5948844. 02 562032. 05 MWD+IFR-AK-CAZ-SC 8089. 77 89. 92 350 .46 3675 .92 3566 .92 3083 .23 3217 .94 5948893. 36 562023. 08 MWD+IFR-AK-CAZ-SC 8133. 09 89. 00 349 .77 3676 .33 3567 .33 3125 .91 3210 .51 5948935. 97 562015. 31 MWD+IFR-AK-CAZ-SC 8182. 69 89. 00 350 .89 3677 .20 3568 .20 3174 .79 3202 .18 5948984. 79 562006. 60 MWD+IFR-AK-CAZ-SC 8229. 45 89. 12 351 .53 3677 .96 3568 .96 3221 .00 3195 .03 5949030. 93 561999. 10 MWD+IFR-AK-CAZ-SC 8275. 41 90. 04 351 .52 3678 .30 3569 .30 3266 .46 3188 .26 5949076. 33 561991. 97 MWD+IFR-AK-CAZ-SC 8321. 08 89. 86 350 .70 3678 .34 3569 .34 3311 .58 3181 .20 5949121. 39 561984. 56 MWD+IFR-AK-CAZ-SC 8365. 95 88: 81 350 .38 3678 .86 3569 .86 3355 .83 3173 .83 5949165. 58 561976. 84 MWD+IFR-AK-CAZ-SC ~I 8426. 03 88. 01 352 .52 3680 .53 3571 .53 3415 .22 3164 .90 5949224. 89 561967. 45 MWD+IFR-AK-CAZ-SC • Halliburton Company Survey Report Company: ConocoPhiltips Alaska Inc . Date: 12/19/2006 "Time: 14:06:14 Page: d Field: Kuparuk River Unit Co-ordinate(NE) Reference: Well: 1J-115, True North Site: Kuparuk 1J Patl Vertical (TVD) Reference: 1J-115L1 PB2: 109.0 Well: 1J-115 Section (VS) Reference: Well (O.OON,O.OOE,O.OOAzi) Wellpath: 1J-115L1 PB2 Survey Calculation !Method: Minimum. Curvature Db: Oracle Sun~ev __ MD Ind Azim TVD Sys TVD __ N/S E/W ~1apN MapE Tool ft deg deg ft ft ft ft ft ft ~ 8462.11 89.12 353.58 3681.43 3572.43 3451.02 3160.54 5949260.65 561962.81 MWD+IFR-AK-CAZ-SC 8510.37 87.14 354.27 3683.01 3574.01 3498.98 3155.43 5949308.57 561957.33 MWD+IFR-AK-CAZ-SC 8554.83 87.51 354.09 3685.08 3576.08 3543.16 3150.93 5949352.71 561952.48 MWD+IFR-AK-CAZ-SC 8603.98 89.66 353.96 3686.30 3577.30 3592.03 3145.81 5949401.53 561946.98 MWD+IFR-AK-CAZ-SC 8650.00 89.66 353.96 3686.57 3577.57 3637.79 3140.97 5949447.25 561941.78 PROJECTED to TD • • 28-Dec-06 AOGCC Librarian 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 Re: Distribution of Survey Data for Well 1J-115 L1 Dear Dear Sir/Madam: Enclosed is one disk with the *.PTT and *.PDF files. Tie-on Survey: 8,365.95' MD Window /Kickoff Survey 8,414.00' MD (if applicable) Projected Survey: 13,922.00' 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 ~ ! ~2 Signed Please call me at 273-3534 if you have any questions or concerns. Regards, Timothy Allen Survey Manager Attachment(s) ~ot,-~z3 • 28-Dec-06 AOGCC Librarian 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 Re: Distribution of Survey Data for Well 1J-115 L1 PB1 Dear Dear Sir/Madam: Enclosed is one disk with the *.PTT and *.PDF files. Tie-on Survey: 6,485.62' MD Window /Kickoff Survey 6,529.00' MD (if applicable) Projected Survey: 7,522.00' 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~C 1 ~)n~~0~") Signed Please call me at 273-3534 if you have any questions or concerns. Regards, Timothy Allen Survey Manager Attachment(s) asst-rz3 • • 28-Dec-06 AOGCC Librarian 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 Re: Distribution of Survey Data for Well 1 J-115 L1 PB2 Dear Dear Sir/Madam: Enclosed is one disk with the *.PTT and *.PDF files. Tie-on Survey: 7,154.83' MD Window /Kickoff Survey 7,154.83' MD (if applicable) Projected Survey: 8,650.00' 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 Signed Please call me at 273-3534 if you have any questions or concerns. Regards, Timothy Allen Survey Manager Attachment(s) ~d~- 1~.3 Randy Thomas Greater Kuparuk Area Drilling Team Leader ConocoPhillips Alaska, Inc. PO Box 100360 Anchorage, AK 99510-0360 FRANK Fl. 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-115L1 ConocoPhillips Alaska, Inc. Permit No: 206-123 Surface Location: 1973' FSL, 2380' FEL, SEC. 35, Tl 1N, RlOE, UM Bottomhole Location: 298' FSL, 4631' FEL, SEC. 24, T11N, RlOE, 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. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION ~~ RECEIVED AU G 1 6 2006 PERMIT TO DRILL Alaska Oil & Gas Cons. Commission 20 AAC 25.00 - Anchorage 1a. Type of Work: Drill Q Re-drill ^ Re-entry ^ 1b. Current Well Class: Exploratory Development Oil Q - Stratigraphic Test ^ Service ^ Development Gas ~ Multiple Zone^ Single Zon Q 1c. Specify if well is proposed for: Coalbed Methane ^ Gas Hydrates ^ Shale Gas ^ 2. Operator Name: ConocoPhillips Alaska, Inc. 5. Bond: ~ Blanket Single Well Bond N 59-52-180 11. Well. Name and Number: 1J-115L1 3. Address: P.O. Box 100360 Anchorage, AK 99510-0360 6. Propose Depth: MD: 13954' : TVD: 3767' 12. Field/Pool(s): Kuparuk River Field 4a. Location of Well (Governmental Section): Surface: 1973' FSL, 2380' FEL, Sec. 35, T11 N, R10E, UM " 7. Property Designation: ADL 25661 & 25650 West Sak Oil Pool Top of Productive Horizon: 3437' FSL, 4166' FEL, Sec. 36, T11 N, R10E, UM 8. Land Use Permit: ALK 471, 468 13. Approximate Spud Date: 10!9/2006 Total Depth: 298' FSL, 4631' FEL, Sec. 24, T11 N, R10E, UM 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. Dis$~nce to Nearest We within Pool: none , ~ fr ~, ~ ~~-/~Z ~~ 16. Deviated wells: Kickoff depth: 6498 ft. Maximum Hole Angle: g2° deg 17. Maximum Anticipated Pressures in psig (see 20 AAC 25.035) Downhole: 1695 psig ~ Surface: 1318 psig 18. Casing Program ifi S ti Setting Depth Quantity of Cement Size ons pec ca Top Bottom c. f. or sacks 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 7456' 6498' 3648' 13954' 3767' 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): ~~~~0~ Perforation Depth TVD (ft): 20. Attachments: Filing Fee _ BOP Sketch ^ Drilling Program ~ Time v. Depth Plot Shallow Hazard Analysis ~ Property Plat ^ Diverter Sketch ^ Seabed Report ^ Drilling Fluid Program ^/ 20 AAC 25.050 requirements 0 21. Verbal Approval: Commission Representative: Date: 22. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Mike Greener @ 263-4820 Printed Name Randy Thomas Title Greater Kuparuk Area Drilling Team Leader Signature a/~~ ~~~ Phone Date !~N' ~ Pr h n D k Commission Use Only Permit to Drill Number: ~.~(,~' ~ Z 3 API Number: 50- Q z„9~~ 33 Z-Z~ ' ~p U Permit Approval Date: See cover letter for other requirements Conditions of approval : If box is checked, well may not be used to explore for, test, or produce coalbed methane, gas hydrates, or gas contained in shales: Samples req'd: Yes ^ No ~ g req'd: Yes ^ No Other. ~O ~pS ~ ~~~ "~~S ~ H2S measures: Yes ^ No Dire onal y req'd: Yes [/r No ^ ` PROVED BY THE COMMISSION DATE: ,COMMISSIONER Form 10-401 Revised 12/2005 ~ ` "~ , ~ ~ ~ c ` f ~- k,, v ~ Submit i uplicate % k ~ E f ~ „ ~ ~ ~~ ~~~ 7,(~~ ,/~ aL • Appl~ for Permit to Drill, Well 1J-115 L1 O Revision No . Saved: 15-Aug-06 Permit It -West Sak Well #1J-115 L1 ~~~~ ... Application for Permit to Drill Document +~k ~VlaWell M p x i m i z~ +V~el I Vaiu e Table of Contents 1. Well Name ................................................................................................................. 2 Requirements of 20 AAC 25.005 (fl ....................................................................................................... 2 2. Location Summary ................................................................................................... 2 Requirements of 20 AAC 25.005(c)(2) ................................................................................................... 2 Requirements of 20 AAC 25.050(b) ....................................................................................................... 3 3. Blowout Prevention Equipment Information ......................................................... 3 Requirements of 20 AAC 25.005(c)(3) ................................................................................................... 3 4. Drilling Hazards Information ...................................................................................3 Requirements of 20 AAC 25.005 (c) (4) .................................................................................................. 3 5. Procedure for Conducting Formation Integrity Tests ........................................... 3 Requirements of 20 AAC 25.005 (c)(5) .................................................................................................. 3 6. Casing and Cementing Program ............................................................................ 3 Requirements of 20 AAC 25.005(c)(6) ................................................................................................... 4 7. Diverter System Information ................................................................................... 4 Requirements of 20 AAC 25.005(c)(7) ................................................................................................... 4 8. Drilling Fluid Program ............................................................................................. 4 Requirements of 20 AAC 25.005(c)(S) ................................................................................................... 4 Lateral Mud Program (MI VersaPro Mineral Oil Base) ........................................................................... 4 9. Abnormally Pressured Formation Information ..................................................... 5 Requirements of 20 AAC 25.005 (c)(9) .................................................................................................. 5 10. Seismic Analysis ..................................................................................................... 5 Requirements of 20 AAC 25.005 (c)(10) ................................................................................................ 5 11.Seabed Condition Analysis ..................................................................................... 5 Requirements of 20 AAC 25.005 (c)(11) ................................................................................................ 5 12. Evidence of Bonding ............................................................................................... 5 Requirements of 20 AAC 25.005 (c)(12) ................................................................................................ 5 s ~ ~ ~~~ T 1J-115L1 PERM/TIT Page 1 of 6 Printed: 15-Aug-06 • Appl~ for Permit to Drill, Well 1 J-115 L1 Revision No.0 Saved: 15-Aug-06 13. Proposed Drilling Program ..................................................................................... 5 Requirements of 20 AAC 25.005 (c)(13) ................................................................................................ 5 14. Discussion of Mud and Cuttings Disposal and Annular Disposal ....................... 6 Requirements of 20 AAC 25.005 (c)(14) ................................................................................................ 6 15. Attachments ............................................................................................................. 6 Attachment 1 Directional Plan ................................................................................................................ 6 Attachment 2 Drilling Hazards Summary ............................................................................................... 6 Attachment 3 Well Schematic ................................................................................................................ 6 1. Well Name Requirements of 20 AAC 25.005 (fl 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(6). For a well with multiple well branches, each branch must similarly be identified by a unique name and API number by adding a suffix to the name designated for the well by the operator and to the number assigned to the well by the commission. The well for which this Application is submitted will be designated as 1J-115 Ll. 2. Location Summary Requirements of 20 AAC 25.OO5(c)(2) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (2) a plat identifying the property and the property's owners and showing (A)the coordinates of the proposed location of the well at the surface, at the top of each objective formation, and at total depth, referenced to governmental section lines. (8) the coordinates of the proposed location of the well at the surface, referenced to the state plane coordinate system for this state as maintained by the National Geodetic Survey in the National Oceanic and Atmospheric Administration; (C) the proposed depth of the well at the top of each objective formation and at total depth; Location at Surface 1,973' FSL, 2,380' FEL, Section 35, T11N, R10E ASP Zone 4 NAD 27 Coordinates RKB Elevation 109.0' AMSL Northings: 5,945,785• Eastings: 558,830 ~ Pad Elevation 81.0' AMSL Location at Top of Productive Interval 3,437' FSL, 4,166' FEL, Section 36, T11N, R10E West Sak "B" Sand ASP Zone 4 NAD 27 Coordinates Measured De th RKB: 6,498 Northings: 5,947,277 Eastings: 562,310 Total Vertical De th, RKB: 3,648 Total Vertical De th, SS: 3,539 Location at Total De th 298' FSL, 4,631' FEL Section 24 T11N R10E ASP Zone 4 NAD 27 Coordinates Measured De th, RKB: 13,954 • Northings: 5,954,693 Eastings: 561,793 Total Vertical De th, RKB: 3,767 Total Vertical De th, SS: 3 658 and (D) other information required by 20 AAC 25.050(6); 1J-115L1 PERMIT IT Page 2 of 6 Printed: 15-Aug-O6 • Appl~ for Permit to Drill, Well 1 J-115 L1 Revision No.O Saved: 15-Aug-06 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 (e) 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 iJ-115 Li. Please see information on Doyon 141 blowout prevention equipment placed on file with the Commission. 4. Drilling Hazards Information Requirements of 20 AAC 25.005 (c)(4) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (4) information on drilling hazards, including (A) the maximum downhole pressure that maybe encountered, criteria used to determine it, and maximum potential surface pressure based on a methane gradient; The expected reservoir pressures in the West Sak sands in the iJ area are 0.45 psi/ft, or 8.7 ppg EMW (equivalent mud weight). Pressures are predicted based on the undisturbed West Sak pressure gradient. The maximum potential surface pressure (MPSP) based on the above maximum pressure gradient, a methane gradient (0.11), and the deepest planned vertical depth of the West Sak °B" sand formation is 1,318 psi, calculated thusly: MPSP = (3,767 ft TVD)(0.45 - 0.11 psi/ft) = 1,318 psi (8) data on potential gas zones; The well bore is not expected to penetrate any gas zones. and (C) data concerning potential causes of hole problems such as abnormally geo-pressured strata, lost circulation zones, and zones that have a propensity for differential sticking; Please see Attachment 2: 1J-115 L1 Drilling Hazards Summary. 5. Procedure for Conducting Formation Integrity Tests Requirements of 20 AAC 25.005 (c)(5) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (5) a description of the procedure for conducting formation integrity tests, as required under 20 AAC 25.030(1); The parent wellbore, iJ-115, will be completed with 7-5/8" intermediate casing landed in the West Sak A- Sand. The casing shoe will be drilled out and a formation integrity test will be performed in accordance with the ~~Formation Integrity Test Procedure" that ConocoPhillips Alaska placed on file with the Commission. 1J-115L1 PERMIT IT Page 3 of 6 Printed: 15-Aug-O6 ~r B ~ C ~~ ~ ii ti ~~ t ~- Appl~ for Permit to Drill, Well 1 J-115 L1 Revision No.O Saved: 15-Aug-06 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; Casin and Cementin Pro ram Hole Top Btm Csg/Tbg Size Weigh Length MD/TVD MD/TVD OD (in (in) t /b/ft) Grade Connection (ft (ft) (ft) Cement Program 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 ed Lateral 1J-11 4-1/2 6-3/4" B Sand 11.6 L-80 B 7,45 6,498 / 3,648 13,954 / 3,767 - no cement slotted Lateral (1J-115 Ll) __ -3/4" D Sand 11.6 L-80 BT ,861 6,159 / 3,57 , , ed= no cement Slotted Lateral (1J-115 L2) 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); No diverter system will be utilized during operations on iJ-115 L1. 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: Lateral Mud Program (MI VersaPro, Mineral Oil Base) Value Densit 8.6 Plastic Viscostiy (Ib/100 std 15 - 25 Yield Point (cP) 18 - 28 HTHP Fluid loss (ml/30 min @ 200psi & 150° <4.0 Oil /Water Ratio 70 / 30 Electrical Stabilit 650-900 Drilling fluid practices will be in accordance with appropriate regulations stated in 20 AAC 25.033. Please see information on file with the Commission for diagrams and descriptions of the fluid system of Doyon Rig 141. 1J-115L1 PERMIT IT Page 4 of 6 ~ ; - Printed: 15-Aug-06 ~~~ J • App for Permit to Drill, Well 1J-115 L1 Revision No.O Saved: 15-Aug-06 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 25.0330; 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: (i 0) for an exploratory or stratigraphic test well, a seismic refraction or reflection analysis as required by 20 AAC 25.061(a); Not applicable: Application is not-for an exploratory or stratigraphic test well. 11. Seabed Condition Analysis Requirements of 20 AAC 25.005 (c)(11) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (11) for a well drilled from an offshore platform, mobile bottom-founded structure, jack-up rig, or floating drilling vessel, an analysis of seabed conditions as required by 20 AAC 25.061(b); Not applicable: Application is not for an offshore well. 12. Evidence of Bonding Requirements of 20 AAC 25.005 (c)(12) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (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 3, Well Schematic. Note: Previous operations are covered under the 1J-115 Application for Permit to Drill. 1. Run and set Baker WindowMaster whipstock system, at window point of +/- 6,498' MD / 3,648' TVD, the top of the B sand. 2. Mill 6-3/4" window. POOH. 3. Pick up 6-3/4"drilling assembly with LWD and MWD and PWD. RIH. 4. Drill to TD of B sand lateral at +/- 13,954' MD / 3,767' TVD, as per directional plan. 5. POOH, back reaming out of lateral to window. TIH to bottom & displace to solids-free oil based mud. POOH on elevators. 6. RIH with whipstock retrieval tool. Retrieve whipstock and POOH. 7. PU and run 4-1/2" slotted liner. 8. RIH, until liner hanger is just above window. Orient hanger to window and land hanger. 9. Release hanger running tool. POOH. 1J-115L1 PERMIT /T Page 5 of 6 fr Printed: 15-Aug-O6 ®~I1~; Appl~ for Permit to Drill, Well 1J-115 L1 Revision No.0 Saved: 15-Aug-06 10. Make up junction isolation / re-entry assembly (Lateral Entry Module or LEM) and RIH to depth. Orient and set packer atop assembly and release from assembly. 11. POOH and prepare to drill the °D" sand lateral 1J-115 L2. 14. Discussion of Mud and Cuttings Disposal and Annular Disposal Requirements of 20 AAC 25.005 (c)(14) An application for a Permit to Drill mustc be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (i4) a general description of how the operator plans to dispose of drilling mud and cuttings and a statement of whether the operator intends to request authorization under 20 AAC 25.080 for an annular disposal operation in the well.; Waste fluids generated during the drilling process will be disposed of either by pumping authorized fluids into a permitted annulus on 1J Pad, or by hauling the fluids to a KRU Class II disposal well. All cuttings generated will be disposed of either down a permitted annulus on iJ Pad, hauled to the Prudhoe Bay Grind and Inject Facility for temporary storage and eventual processing for injection down an approved disposal well, or stored, tested for hazardous substances, and (if free of hazardous substances) used on pads and roads in the Kuparuk area in accordance with a permit from the State of Alaska. ConocoPhillips Alaska may in the future request authorization for the use of this well for annular disposal operations. 15. Attachments Attachment 1 Directional Plan Attachment 2 Drilling Hazards Summary Attachment 3 Well Schematic 1J-115L1 PERMIT IT Page 6 of 6 Printed: 15-Aug-06 ~~ ConocoPhillips Alaska ConocoPhillips Alaska Inc. Kuparuk River Unit Kuparuk 1J Pad Plan 1J-115 -Slot 1J-115 Plan 1J-115 L1 Plan: 1J-115 L1 (wp05) Proposal Report 17 June, 2006 A~~.~l Sperry Qrilling S~arvc~s ORIGINk~ Project: Site: Well: Wellbore: Plan: 1J-1 Kuparuk River Uni Kuparuk 1J Pad Plan 1J-115 Plan 1J-115 L1 15 L1 (wp05) ,,,- Co nocoPh i l l i s ~aL~,i~~RT°N -lazs p Sperry Drilling Services Alaska -950 CASING DETAILS No ND MD Name Size L1 : TOW ~ 6498ft MD, 3648ft ND 1 2231.00 3008.65 10 3/4" 10.3/4 -475 i 2 3648.38 6498.20 7 5/8" 7-5/8 3 3767.0013954.34 41/2" 4-1/2 ~ L1 : Bottom of Window, 6510ft MD, 3650ft ND 0 i i ~ i ~ ~ ~~ L7 : Build ~ 5°/100tt to 92° Inc - 6540ft MD, 3654ft N 475 c 0° ~ i ' ~ 5` i ~ ~ 10° ~ ~ i L1 : Sail ~ 92° Inc : 6743ft MD, 3665ft ND 950 15° ~ ~ i .~ 25° ' ~ 1425 v 30° 35° ~ ~ ~ ~ L1 : Continue Geosteering in B-Sand, 6943ft MD, 3658ft ND ~' 40° ~ ~ i i .~ (~-_1900 ~= $ U o i i II ~~/ ~ i ~ 10 314" , ~ ~ ~ ~' L1 BHL : 13954ft MD, 3767ft ND 65° ' ~ ~ 2375 ' 2850 ~ ~ Ii ~ i ~ ~ ~~ i ~ ~~ ~ h ~O o i ~ 3325 ^ ~ I ~ ~ / - ~ d i P UYO T 01 01 01 A ~ 97 OD W _ W pp pp _ dp c+D _~~Y_ -_ d no " o I o_ , -4112„ 3800 7 518 ~ 1 / 1 3 3 J 4275 1J-115 L1 T1 (wp05), 1J-115 L1 T2 (wp05) ~ 1J-115 L1 T3 (wp05) /'~ ~- _ ~ -' N 1J-115 L1 T4 (wp05) i1J-1 T5 Toe (wp05) ~ 4750 ` n c a -475 0 475 950 1425 1900 2375 2850 3325 3800 4275 4750 5225 5700 6175 6650 7125 7600 8075 8550 9025 Vertical Section at 0.00° (950 ft/in) • • r/ 1 ~ ~ ~ ~ o ~ ' ~ N+ o •~ '~ ~ ~ Q ~ ~ ~ _ ~ o ~ ~ ~ ~ \ ~ c ; ~ M 9 O N ~ ~_ m 0 f . ~ . ~ v V ~ o o, x ~ ~, ~ 0 ~ ~ ~ In ` o , ~ O ~ ~, ~ m .. ~ N ~ j \~ , J 1 J x ~ ~ m 1 ~ 1 I t0 C /0 N \~, -~ ~ ~ ~ ~ I 1 I 1 I V N J `~ ~ ~ ~ I \ ~ 1 I , C ~ ~ ~ 1 1 I C \ 11 I ~ \ ~ ~ 1 I 1 1 I N d ~ ` I 1 m ~ \ 1 I I ~ ~ I I J ~ 3 C C C U ~ 1 ~ , I ~ 1 I ~ 1 I o ' .. ~ , I 3 ~ J ` ~ 1 I J ' 1 ~ v~5 ~ \ ~ I u \ , I \ pp ~ q 1 'a ~ ~ ~\I l7 6 1 ~ _ _ ..,. ~ 1 W r , 'a o s ~ e o 0 0 0 0 0 0 ~ ~~ ~"- - - _ _-' ~ o0 \ ~ w ____ ... _- ~. " h Q i - / ~ N ~ ~ I I I I i I I 1 1 I 1 I I I I 1 I 1 1 I ~ , I 1 I I I I 1 ~ / I 1 I I I f ~ ~ I I 1 I 1 I I 1 Q~ 1 I I I 1 1 I I I I I I , ~ I I I I 1 1 I I 1 I 1 I I I I I 1 ~ y O N pO, O O O I 1 I 1 1 I _ ; 3 ; ; ; I I m 1 ~ 1 H H H F I 11 In ~ J ~ J ~ J ~ J ~ e- I I ~ i -N~I J r r r r p a ~.. r o O vi m a N ~ h ~ rndr;~ cn mQ. . ~ E M h ~ Z O ~ V $' tNO N rqM• ~ ~ M U ~oMo ~~~~ Nmn NthM 0 z.-N~ L a° i d V v ~ `4 3 {~ d O tQ O Z a3o add p 3w °' ° o ~o~ ~ o u ~„ _ I U ° '~ a ~ ! to O J ''. ~ .~... ~o O F i mo J;~ am I H ~Na ob6 of eS6 ~ o = O I 9 C 1 ~ 0 0 O d O A 0 0 Z N V t~0 W N r2 vt ~y^yNU 1~ o plln ~ y m Z AcC~ ~ V ~ pl p,pD L C ~ ~ rL j ~ ~A Q~ 0 rn °o m N 0 0 O O N O N ~ r^i O O ~ O ~ ~ t o ~ ,~ W N N I 2N O N O 0 r O O an 0 N N 0 O 0 M a ConacaPhill~ps Alaska Database: EDM 2003.11 b48 Local Co-ordinate Reference: Well Plan 1J-115 -Slot 1J-115 Company: ConocoPhillips Alaska Inc. TVD Reference: Plan RKB @ 109.OOft (Doyon 141. (28 + 81)) Project: Kuparuk River Unit MD Reference: Plan RKB @ 109.OOft (Doyon 141 (28 + 81 )) Site: Kuparuk 1J Pad North Ref®rence: True. Well: Plan 1J-115 Survey Calculation Method: Minimum Curvature Wellbore: Plan 1J-115 L1 Design: 1J-11511 (wp05) Project Kuparuk River Unit, North Slope Alaska, United States Map System: US State Plane 1927 (Exact solution) System Datum: Mean Sea Level Geo Datum: NAD 1927 (NADCON CONUS) Using Well Reference Point Map Zone: Alaska Zone 04 Using geodetic scale factor Well Plan 1J-115 -Slot 1J-115 Well Position +N/-S 0.00 ft Northing: 5,945,785.38 ft Latitude: 70° 15' 44.934" N +E/-W 0.00 ft Easting: 558,829.63 ft Longitude: 149° 31' 27.882" W Position Uncertainty 0.00 ft Wellhead E levation: ft Ground Level: 81.OOft Wellbore Plan 1J-115 L1 Magnetics Model Name Sample Date Declination Dip Angle Field Strength BGGM2005 5/15/2006 24.09 80.77 57,564 Design 1J-115 L1 (wp05) Audit Notes: Version: Phase: PLAN Tie On Depth: 6,498.19 Vertical Section: Depth From (TVD) +N/-S +E/-W Direction lft) (ft) (ft) (°) 2s.oo o.oo o.oo o.oo • Halliburton Energy Services Planning Report -Geographic HA:.1,.tE3U~TON Sperry ©riiling Services 6/17/2006 11:22:07AM Page 2 of 8 COMPASS 2003.11 Build 50 OR161~P.~ ' ~ ~ ~-- , Halliburton Energy Service s rBt ~A'rc~N ~-tA~l~ Conc~caPh~lt~ps Planning Report -Geographic . . --- Sperry Driiiling Senricsa Database: EDM 2003.11 b48 Local Co-ordinate Reference: Well Plan 1J-115 -Slot 1J-115 Company: ConocoPhillips Alaska lnc. TVD Reference: Plan RKB @ 109.OOft (Doyon 141 (28 + 81 p Project: KuparukRiver Unit MD Reference: Plan RKB @ 109,OOft (Doyon 141 (28 + 81)) Site: Kuparuk 1J Pad North Reference: True Well: Plan 1J-115 Survey Calculation Method: Minimum Curvature Wellbore: Plan 1J-115 L1 Design: 1 J-115 L1 (wp05) Plan Summary Measured Vertical Dogleg Build Turn Depth Inclination Azimuth Depth +N/-S +E!-W Rate Rate Rate TFO (ft) (,) (°) (ft) (ft) (ft) (°1100ft) (°/100ft) (°/100ft) (°) 6,498.19 80.00 350.00 3,648.37 1,464.85 3,492.90 0.00 0.00 0.00 0.00 6,510.19 81.91 350.00 3,650.26 1,476.52 3,490.84 15.90 15.90 0.00 0.00 6,540.19 81.91 350.00 3,654.48 1,505.77 3,485.68 0.00 0.00 0.00 0.00 6,742.83 92.00 350.90 3,665.24 1,705.06 3,452.16 5.00 4.98 0.44 5.12 6,942.83 92.00 350.90 3,658.26 1,902.42 3,420.55 0.00 0.00 0.00 0.00 6,999.34 89.17 350.91 3,657.68 1,958.22 3,411.62 5.00 -5.00 0.02 179.72 9,065.09 89.17 350.91 3,687.45 3,997.83 3,085.43 0.00 0.00 0.00 0.00 9,279.48 90.00 359.45 3,689.00 4,211.26 3,067.44 4.00 0.39 3.98 84.52 9,554.48 90.00 359.45 3,689.00 4,486.24 3,064.80 0.00 0.00 0.00 0.00 9,577.50 89.33 359.63 3,689.13 4,509.27 3,064.62 3.00 -2.90 0.79 164.81 10,253.66 89.33 359.63 3,697.00 5,185.37 3,060.27 0.00 0.00 0.00 0.00 10,255.75 89.33 359.57 3,697.02 5,187.46 3,060.25 3.00 -0.36 -2.98 -96.95 11,327.92 89.33 359.57 3,709.64 6,259.52 3,052.18 0.00 0.00 0.00 0.00 11,354.06 90.11 359.57 3,709.77 6,285.66 3,051.99 3.00 3.00 0.00 0.09 11,754.06 90.11 359.57 3,709.00 6,685.65 3,048.98 0.00 0.00 0.00 0.00 11,781.42 89.29 359.53 3,709.14 6,713.00 3,048.77 3.00 -3.00 -0.15 -177.20 12,254.21 89.29 359.53 3,715.00 7,185.74 3,044.89 0.00 0.00 0.00 0.00 12,289.43 88.24 359.61 3,715.76 7,220.95 3,044.63 3.00 -2.99 0.21 175.90 13,954.35 88.24 359.61 3,767.00 8,885.05 3,033.17 0.00 0.00 0.00 0.00 6/17/2006 11:22:07AM Page 3 of 8 COMPASS 2003.11 Build 50 Q COt"ft)CG1PI11~fip5 Alaska Halliburton Energy Services • Planning Report -Geographic Database: _EDM 2003.11 b48 Company: ConocoPhillips Alaska inc. Project: Kuparuk River Unit Site: Kuparuk 1J Pad Well: Plan 1J-1.1:5.. Wellbore: Plan 1J-115 L1 Design: 1J-115 L1 (wp05) HAL.LIBURTdBV Sperry Drilling Services - Local Co-ordinate Reference: Well Plan 1 J-115 -Slot 1 J-115. TVD Reference: Plan RKB @ 109:OOft (Doyon 141 (28 + 81)) MD Reference: Plan RKB @ 109.OOft (Doyon 141 (28 + 81 p North Reference: True Survey Calculation Method: Minimum Curvature Planned Survey 1J-115 L1 (wp05) Map MD Inclination Azimuth TVD SSTVD +N/-S +E/-W No ft ing (ft) (°) (°) (ft) (ft) (ftl (ft) ( ) 6,498.19 80.00 350.00 3,648.37 3,539.37 1,464.85 3,492.90 5,947,277.33 L1 : TOW @ 6498ft MD, 3648ft TVD - 3437ft FSL & 4166ft FEL -Sec 36 - T11 N - R10E - 7 518" 6,500.00 80.28 350.00 3,648.68 3,539.68 1,466.60 3,492.59 5,947,279.08 6,510.19 81.91 350.00 3,650.26 3,541.26 1,476.52 3,490.84 5,947,288.98 L1 : Bottom of Window, 6510ft MD, 3650ft TVD 6,540.19 81.91 350.00 3,654.48 3,545.48 1,505.77 3,485.68 5,947,318.19 L1:Build @ 5°/100ft to 92° Inc - 6540ft MD, 3654ft TVD 6,600.00 84.89 350.27 3,661.36 3,552.36 6,700.00 89.87 350.71 3,665.94 3,556.94 6,742.83 92.00 350.90 3,665.24 3,556.24 L1 : Sail @ 92° Inc : 6743ft MD, 3665ft TVD 6,800.00 92.00 350.90 3,663.24 3,554.24 6,900.00 92.00 350.90 3,659.75 3,550.75 6,942.83 92.00 350.90 3,658.26 3,549.26 L1 : Continu e Geosteering in B-Sand, 6943ft M D, 3658ft TVD 6,999.34 89.17 350.91 3,657.68 3,548.68 7,000.00 89.17 350.91 3,657.69 3,548.69 7,100.00 89.17 350.91 3,659.13 3,550.13 7,200.00 89.17 350.91 3,660.57 3,551.57 7,300.00 89.17 350.91 3,662.01 3,553.01 7,400.00 89.17 350.91 3,663.45 3,554.45 7,500.00 89.17 350.91 3,664.90 3,555.90 7,600.00 89.17 350.91 3,666.34 3,557.34 7,700.00 89.17 350.91 3,667.78 3,558.78 7,800.00 89.17 350.91 3,669.22 3,560.22 7,900.00 89.17 350.91 3,670.66 3,561.66 8,000.00 89.17 350.91 3,672.10 3,563.10 8,100.00 89.17 350.91 3,673.54 3,564.54 8,200.00 89.17 350.91 3,674.98 3,565.98 8,300.00 89.17 350.91 3,676.43 3,567.43 8,400.00 89.17 350.91 3,677.87 3,568.87 8,500.00 89.17 350.91 3,679.31 3,570.31 8,600.00 89.17 350.91 3,680.75 3,571.75 8,700.00 89.17 350.91 3,682.19 3,573.19 8,800.00 89.17 350.91 3,683.63 3,574.63 8,900.00 89.17 350.91 3,685.07 3,576.07 9,000.00 89.17 350.91 3,686.51 3,577.51 9,065.09 89.17 350.91 3,687.45 3,578.45 9,100.00 89.31 352.30 3,687.91 3,578.91 9,200.00 89.69 356.28 3,688.79 3,579.79 9,279.48 90.00 359.45 3,689.00 3,580.00 9,300.00 90.00 359.45 3,689.00 3,580.00 9,400.00 90.00 359.45 3,689.00 3,580.00 9,500.00 90.00 359.45 3,689.00 3,580.00 9,554.48 90.00 359.45 3,689.00 3,580.00 Map Fasting DLSEV Vert Section (ft) (°HOOft} (ft) 562,310.64 0.00 1,464.85 562,310.32 15.67 1,466.60 562,308.50 15.94 1,476.52 562,303.11 0.00 1,505.77 5.00 1,564.30 5.00 1,662.79 5.00 1,705.06 1,564.30 3,475.51 5,947,376.63 562,292.48 1,662.79 3,459.01 5,947,474.98 562,275.21 1,705.06 3,452.16 5,947,517.19 562,268.04 1,761.48 3,443.13 5,947,573.53 562,258.56 0.00 1,761.48 1,860.16 3,427.32 5,947,672.08 562,241.99 0.00 1,860.16 1,902.42 3,420.55 5,947,714.28 562,234.89 0.00 1,902.42 1,958.22 3,411.62 5,947,770.00 562,225.52 5.00 .1,958.22 1,958.86 3,411.52 5,947,770.65 562,225.41 0.00 1,958.86 2,057.60 3,395.73 5,947,869.25 562,208.85 0.00 2,057.60 2,156.33 3,379.94 5,947,967.85 562,192.29 0.00 2,156.33 2,255.07 3,364.15 5,948,066.45 562,175.73 0.00 2,255.07 2,353.80 3,348.36 5,948,165.05 562,159.17 0.00 2,353.80 2,452.54 3,332.57 5,948,263.64 562,142.61 0.00 2,452.54 2,551.27 3,316.78 5,948,362.24 562,126.06 0.00 2,551.27 2,650.01 3,300.98 5,948,460.84 562,109.50 0.00 2,650.01 2,748.74 3,285.19 5,948,559.44 562,092.94 0.00 2,748.74 2,847.48 3,269.40 5,948,658.04 562,076.38 0.00 2,847.48 2,946.21 3,253.61 5,948,756.64 562,059.82 0.00 2,946.21 3,044.95 3,237.82 5,948,855.24 562,043.26 0.00 3,044.95 3,143.68 3,222.03 5,948,953.84 562,026.70 0.00 3,143.68 3,242.42 3,206.24 5,949,052.44 562,010.14 0.00 3,242.42 3,341.15 3,190.45 5,949,151.04 561,993.58 0.00 3,341.15 3,439.89 3,174.66 5,949,249.64 561,977.02 0.00 3,439.89 3,538.62 3,158.87 5,949,348.23 561,960.46 0.00 3,538.62 3,637.36 3,143.08 5,949,446.83 561,943.90 0.00 3,637.36 3,736.09 3,127.29 5,949,545.43 561,927.34 0.00 3,736.09 3,834.83 3,111.50 5,949,644.03 561,910.78 0.00 3,834.83 3,933.56 3,095.71 5,949,742.63 561,894.22 0.00 3,933.56 3,997.83 3,085.43 5,949,806.81 561,883.44 0.00 3,997.83 4,032.36 3,080.34 5,949,841.30 561,878.08 4.00 4,032.36 4,131.84 3,070.40 5,949,940.69 561,867.36 4.00 4,131.84 4,211.26 3,067.44 5,950,020.07 561,863.79 4.00 4,211.26 4,231.78 3,067.25 5,950,040.58 561,863.43 0.00 4,231.78 4,331.77 3,066.29 5,950,140.56 561,861.69 0.00 4,331.77 4,431.77 3,065.33 5,950,240.53 561,859.95 0.00 4,431.77 4,486.24 3,064.80 5,950,295.00 561,859.00 0.00 4,486.24 1J-115 L1 T1 (wp05) 9 577 50 89.33 359.63 3 689.13 3 580.13 4 509.27 3,064.62 5,950,318.02 561,858.64 3.00 4,509.27 6/17/2006 11:22:07AM Page 4 of 8 COMPASS 2003.11 Build 50 '~ ~--' ~ Halliburton Energy Services • CortocoP~"lwlltps Planning Report -Geographic Alaska HAIL1~.tBCJRTQN Sperry DHlli[ng Services Database: EDM 2003.11 b48 Local Co-ordinate Reference: Well Plan 1J-115 - SIot1J-115 Company: ConocoPhllips Alaska Inc. TVD Reference: Plan RKB @ 109.OOft (Doyon 141 {2g + 81 )) Project: KuparuKRiver Unit MD Reference: Plan RKB @ 1D9.OOft (Doyon 141 (28 + 81)) Site: Kuparuk 1J Pad North Reference: True Well: Plan 1J-1.15 Survey Calculation Method: Minimum Curvature Wellbore: Plan 1J-115 L1 Design: 1J-115 L1 (wp05) Planned Survey 1J-115 L1 (wp05) Map Map MD Inclination Azimuth TVD SSTVD +N/-S +E/-W Northing Easting DLSEV Vert Section (ft) (') (') (ft) (ftl Ift) (ft) (ft) (ft) (°1100ftj (ft) 9,600.00 89.33 359.63 3,689.40 3,580.40 4,531.76 3,064.48 5,950,340.51 561,858.31 0.00 4,531.76 9,700.00 89.33 359.63 3,690.56 3,581.56 4,631.75 3,063.83 5,950,440.48 561,856.89 0.00 4,631.75 9,800.00 89.33 359.63 3,691.72 3,582.72 4,731.74 3,063.19 5,950,540.46 561,855.46 0.00 4,731.74 9,900.00 89.33 359.63 3,692.89 3,583.89 4,831.74 3,062.54 5,950,640.43 561,854.04 0.00 4,831.74 10,000.00 89.33 359.63 3,694.05 3,585.05 4,931.73 3,061.90 5,950,740.40 561,852.61 0.00 4,931.73 10,100.00 89.33 359.63 3,695.21 3,586.21 5,031.72 3,061.26 5,950,840.38 561,851.19 0.00 5,031.72 10,200.00 89.33 359.63 3,696.38 .3,587.38 5,131.71 3,060.61 5,950,940.35 561,849.76 0.00 5,131.71 10,253.66 89.33 359.63 3,697.00 3,588.00 5,185.37 3,060.27 5,950,994.00 561,849.00 0.00 5,185.37 1J-115 L1 T2 (wp05) 10,255.75 89.33 359.57 3,697.02 3,588.02 5,187.46 3,060.25 5,950,996.09 561,848.97 3.00 5,187.46 10,300.00 89.33 359.57 3,697.55 3,588.55 5,231.70 3,059.92 5,951,040.32 561,848.29 0.00 5,231.70 10,400.00 89.33 359.57 3,698.72 3,589.72 5,331.69 3,059.17 5,951,140.29 561,846.76 0.00 5,331.69 10,500.00 89.33 359.57 3,699.90 3,590.90 5,431.68 3,058.41 5,951,240.27 561,845.22 0.00 5,431.68 10,600.00 89.33 359.57 3,701.07 3,592.07 5,531.67 3,057.66 5,951,340.24 561,843.69 0.00 5,531.67 10,700.00 89.33 359.57 3,702.25 3,593.25 5,631.66 3,056.91 5,951,440.21 561,842.16 0.00 5,631.66 10,800.00 89.33 359.57 3,703.43 3,594.43 5,731.65 3,056.16 5,951,540.18 561,840.62 0.00 5,731.65 10,900.00 89.33 359.57 3,704.60 3,595.60 5,831.64 3,055.40 5,951,640.15 561,839.09 0.00 5,831.64 11,000.00 89.33 359.57 3,705.78 3,596.78 5,931.63 3,054.65 5,951,740.12 561,837.56 0.00 5,931.63 11,100.00 89.33 359.57 3,706.96 3,597.96 6,031.62 3,053.90 5,951,840.10 561,836.02 0.00 6,031.62 11,200.00 89.33 359.57 3,708.13 3,599.13 6,131.61 3,053.15 5,951,940.07 561,834.49 0.00 6,131.61 11,300.00 89.33 359.57 3,709.31 3,600.31 6,231.60 3,052.39 5,952,040.04 561,832.96 0.00 6,231.60 11,327.92 89.33 359.57 3,709.64 3,600.64 6,259.52 3,052.18 5,952,067.95 561,832.53 0.00 6,259.52 11,354.06 90.11 359.57 3,709.77 3,600.77 6,285.66 3,051.99 5,952,094.09 561,832.13 3.00 6,285.66 11,400.00 90.11 359.57 3,709.68 3,600.68 6,331.60 3,051.64 5,952,140.02 561,831.42 0.00 6,331.60 11,500.00 90.11 359.57 3,709.49 3,600.49 6,431.59 3,050.89 5,952,239.99 561,829.89 0.00 6,431.59 11,600.00 90.11 359.57 3,709.30 3,600.30 6,531.59 3,050.14 5,952,339.97 561,828.36 0.00 6,531.59 11,700.00 90.11 359.57 3,709.10 3,600.10 6,631.59 3,049.39 5,952,439.95 561,826.83 0.00 6,631.59 11,754.06 90.11 359.57 3,709.00 3,600.00 6,685.65 3,048.98 5,952,494.00 561,826.00 0.00 6,685.65 1J-115 L1 T3 (wp05) ' 11,781.42 89.29 359.53 3,709.14 3,600.14 6,713.00 3,048.77 5,952,521.35 561,825.57 3.00 6,713.00 11,800.00 89.29 359.53 3,709.37 3,600.37 6,731.58 3,048.62 5,952,539.93 561,825.27 0.00 6,731.58 11,900.00 89.29 359.53 3,710.61 3,601.61 6,831.57 3,047.80 5,952,639.90 561,823.67 0.00 6,831.57 12,000.00 89.29 359.53 3,711.85 3,602.85 6,931.56 3,046.98 5,952,739.87 561,822.07 0.00 6,931.56 12,100.00 89.29 359.53 3,713.09 3,604.09 7,031.55 3,046.16 5,952,839.84 561,820.47 0.00 7,031.55 12,200.00 89.29 359.53 3,714.33 3,605.33 7,131.54 3,045.34 5,952,939.81 561,818.87 0.00 7,131.54 12,254.21 89.29 359.53 3,715.00 3,606.00 7,185.74 3,044.89 5,952,994.00 561,818.00 0.00 7,185.74 1J-115 L1 T4 (wp05) 12,289.43 88.24 359.61 3,715.76 3,606.76 7,220.95 3,044.63 5,953,029.20 561,817.46 3.00 7,220.95 12,300.00 88.24 359.61 3,716.09 3,607.09 7,231.52 3,044.55 5,953,039.77 561,817.30 0.00 7,231.52 12,400.00 88.24 359.61 3,719.16 3,610.16 7,331.47 3,043.86 5,953,139.70 561,815.83 0.00 7,331.47 12,500.00 88.24 359.61 3,722.24 3,613.24 7,431.42 3,043.18 5,953,239.63 561,814.37 0.00 7,431.42 12,600.00 88.24 359.61 3,725.32 3,616.32 7,531.37 3,042.49 5,953,339.56 561,812.90 0.00 7,531.37 12,700.00 88.24 359.61 3,728.40 3,619.40 7,631.32. 3,041.80 5,953,439.50 561,811.43 0.00 7,631.32 12,800.00 88.24 359.61 3,731.47 3,622.47 7,731.27 3,041.11 5,953,539.43 561,809.96 0.00 7,731.27 12,900.00 88.24 359.61 3,734.55 3,625.55 7,831.22 3,040.42 5,953,639.36 561,808.49 0.00 7,831.22 13,000.00 88.24 359.61 3,737.63 3,628.63 7,931.17 3,039.73 5,953,739.29 561,807.02 0.00 7,931.17 13,100.00 88.24 359.61 3,740.71 3,631.71 8,031.12 3,039.05 5,953,839.23 561,805.55 0.00 8,031.12 13,200.00 88.24 359.61 3,743.78 3,634.78 8,131.07 3,038.36 5,953,939.16 561,804.08 0.00 8,131.07 13,300.00 88.24 359.61 3,746.86 3,637.86 8,231.02 3,037.67 5,954,039.09 561,802.61 0.00 8,231.02 6/17/2006 11:22:07AM Page 5 of 8 COMPASS 2003.11 Build 50 o ~ ~ ~~~r-4~~ • Halliburton Energy Services ~ HAL.L.IE3URTt'~N COC1C)CO~'"1lfAl5 Planning Report -Geographic -- Spent Drilling 5ervttsa Database: EDM 2003.11 b48 Local Co-ordinate Reference: Well Plan 1J-115 -Slot 1J-115 Company: ConocoPhllips Alaskalnc. TVD Reference: Plan RKB @ 109.OOft (Doyon 141 (28 + 81)) Project: Kuparuk River llnit MD Reference: Plan RKB @ 109.OOft (Doyon 141 (28 + 81)) Site: Kuparuk 1J Pad North Reference: True Well: Plan 1J-115 Survey Calculation Method: Minimum Curvature , Wellbore: Plan 1J-115 L1 Design: 1 J-115 L1 (wp05) Planned Survey 1J-115 L1 (wp05) Map Map MD Inclination Azimuth TVD SSTVD +N/-S +E/-W Northing Easting DLSEV Vert Section (ft) (°) (°I (ft) (ftl Ift) (ftl (ft) (ftl (°1100ft) (ft) 13,400.00 88.24 359.61 3,749.94 3,640.94 8,330.97 3,036.98 5,954,139.02 561,801.14 0.00 8,330.97 13,500.00 88.24 359.61 3,753.02 3,644.02 8,430.92 3,036.29 5,954,238.95 561,799.67 0.00 8,430.92 13,600.00 88.24 359.61 3,756.09 3,647.09 8,530.87 3,035.60 5,954,338.89 561,798.21 0.00 8,530.87 13,700.00 88.24 359.61 3,759.17 3,650.17 8,630.82 3,034.92 5,954,438.82 561,796.74 0.00 8,630.82 13,800.00 88.24 359.61 3,762.25 3,653.25 8,730.77 3,034.23 5,954,538.75 561,795.27 0.00 8,730.77 13,900.00 88.24 359.61 3,765.33 3,656.33 8,830.72 3,033.54 5,954,638.68 561,793.80 0.00 8,830.72 13,954.35 88.24 359.61 3,767.00 3,658.00 8,885.05 3,033.17 5,954,693.00 561,793.00 0.00 8,885.05 L1 BHL : 13954ft MD, 3767ft TVD : 298ft FSL & 4631ft FEL - Sec 24 - T11 N - R10E - 4 1!2" 6/17/2006 11;22:07AM Page 6 of 8 COMPASS 2003.11 Build 50 oR~~~~ ~' , ~ Halliburton Energy Services • eonacoPhill~ps Planning Report -Geographic Aeaska ~1~+-~u~uR-roN $parry Driilieig mss Database: EDM_2003.11_b48 Local Co-ordinate Reference: Well Plan 1J-115 -Slot 1J-115 Company: ConocoPhiliips Alaska Inc. TVD Reference: Plan RKB @ 109.OOft (Doyon 141 (28 + 81 )) Project: Kuparuk River lJnit MD Reference: Plarr RKB @ 109.OOft (Doyon 141 (28 + 81 )) Site: Kuparuk 1J Pad North Reference: l-rue Well: Ptan 1J-115 Survey Calculation Method: Minimum Curvature Wellbore: Plan 1J-115 L1 Design: 1 J-115 L1 (wp05) Geologic Targets Plan 1 J-115 L1 TVD Target Name +N/-S +E/-W Northing Easting (ft) -Shape ft ft (ft) (ft) 3,767.00 1J-115 L7 T5 Toe (wp05) 8,885.05 3,033.17 5,954,693.00 561,793.00 - Point 3,709.00 1J-115 L1 T3 (wp05) 6,685.65 3,048.98 5,952,494.00 561,826.00 - Point 3,689.00 1J-115 L1 T1 (wp05) 4,486.24 3,064.80 5,950,295.00 561,859.00 - Point 3,715.00 1J-115 L1 T4 (wp05) 7,185.74 3,044.89 5,952,994.00 561,818.00 - Point 3,697.00 1J-115 L1 T2 (wp05) 5,185.37 3,060.27 5,950,994.00 561,849.00 - Point 3,618.00 1J-116 L1 DD Poly C~ 95%(wp05) 1,493.64 3,487.82 5,947,306.08 562,305.34 - Polygon Point 1 -50.00 0.39 5,947,306.08 562,255.34 Point 2 -52.05 12.06 5,947,317.73 562,253.20 Point 3 -57.21 41.31 5,947,346.94 562,247.81 Point 4 -80.11 175.62 5,947,481.05 562,223.87 Points -450.55 2,425.81 5,949,728.06 561,835.90 Point6 -469.70 2,647.01 5,949,949.09 561,815.02 Point 7 -473.02 2,992.99 5,950,295.00 561,809.00 Point8 -473.20 3,016.02 5,950,318.02 561,808.64 Point 9 -477.56 3,692.12 5,950,994.00 561,799.00 Point 10 -477.57 3,694.21 5,950,996.09 561,798.97 Point 11 -485.64 4,766.27 5,952,067.95 561,782.53 Point 12 -485.83 4,792.41 5,952,094.09 561,782.13 Point 13 -488.84 5,192.40 5,952,494.00 561,776.00 Point 14 -489.05 5,219.75 5,952,521.35 561,775.57 Point 15 -492.93 5,692.49 5,952,994.00 561,768.00 Point 16 -493.35 5,729.69 5,953,031.19 561,767.29 Point 17 -517.66 7,391.90 5,954,693.00 561,730.00 Point 18 -417.65 7,391.12 5,954,693.00 561,830.00 Point 19 -393.34 5,728.91 5,953,031.19 561,867.29 Point 20 -392.92 5,691.71 5,952,994.00 561,868.00 Point 21 -389.05 5,218.97 5,952,521.35 561,875.57 Point 22 -388.83 5,191.61 5,952,494.00 561,876.00 Point 23 -385.83 4,791.63 5,952,094.09 561,882.13 Point 24 -385.63 4,765.49 5,952,067.95 561,882.53 Point 25 -377.56 3,693.43 5,950,996.09 561,898.97 Point 26 -377.55 3,691.34 5,950,994.00 561,899.00 Point 27 -373.19 3,015.24 5,950,318.02 561,908.64 Point 28 -373.01 2,992.21 5,950,295.00 561,909.00 Point 29 -369.69 2,646.23 5,949,949.09 561,915.02 Point 30 -350.54 2,425.03 5,949,728.06 561,935.90 Point 31 19.90 174.84 5,947,481.05 562,323.87 Point 32 42.79 40.53 5,947,346.94 562,347.81 Point 33 47.95 11.28 5,947,317.73 562,353.20 Point 34 50.00 -0.39 5,947,306.08 562,355.34 6/17/2006 11:22:07AM Page 7 of 8 COMPASS 2003.11 Build 50 ~~~~~ ~~ ~. ~, ~+~-'` , • Halliburton Energy Services ~ HAt.L.1BtTi~TC~N ConacoPho~l~rp~ Planning Report -Geographic Sperry Drilling Serv~ss Database: EDM 2003.11 b48 Local Co-ordinate Reference: WeIFPIan1J-115-SIot1J-115 Company: ConocoPhillps Alaska Inca TVD Reference: Plan RKB @ 1 Q9.OOft(Doyon 141 (28 + 81 )) Project: Kuparuk River Unite. MD Reference: Plan RKB ~ 109.OOf# (Doyon 141 (28 + 81)) Site: Kuparuk 1J Pad North Reference: True Well: Plan 1J-115 Survey Calculation Method: Minimum Curvature Wellbore: Plan 1J-115 L1 Design: 1 J-115 L1 (wp05) Prognosed Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter lft) (ft) (") (") 3,006.65 2,231.00 10-314 13-112 6,498.20 3,648.38 7-518 9-7/8 13,954.34 3,767.00 4-112 6-314 6/17/2006 11:22:07AM Page 8 of 8 COMPASS 2003.11 Build 50 ~.~~ • • ConocoPhillips Alaska ConocoPhillips Alaska Inc. Kuparuk River Unit Kuparuk 1J Pad Plan 1J-115 Plan 1J-115 L1 Anticollision Report 14 July, 2006 ~~'~_" s 4 • ~Qt1t?C©~11~~1[35 Alaska Company: ConocoPhi)lips Alaska Inc. Project: Kuparuk River Unit Reference Site: Kuparuk iJ Pad Site Error: O.OOft Reference Well: Plan 1 J-115 Well Error: O.OOft Reference Wellbore Plan 1J-115 Li Reference Design: Reference Filter type: NO GLOBAL FILTER: Using user defined selection & filtering criteria Interpolation Method: MD Interval 100.OOft Error Model: Depth Range: Unlimited Scan Method: Results Limited by: Mabmum center-center distance of 1,882.19ft Error Surface: Warning Levels evaluated at: 0.00 Sigma Survey Tool Program Date 7/14/2006 From To (ft) (ft) Survey (Wellbore) Tool Name Description 28.00 800.00 1 J-115 (wp05) (Plan 1 J-115) CB-GYRO-SS Camera based gyro single shot 800.00 6,498.19 1J-115 (wp05) (Plan 1J-115) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 6,498.19 13,954.34 1J-115 L1 (wp05) (Plan 1J-115 L1) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC Halliburton Company Anticollision Report Local Co-ordinate Reference TVD Reference: MD Reference: North Reference: Survey Calculation Method: Output errors are at Database: Offset TVD Reference: • Well Plan 1J-115 -Slot 1J-115 Plan RKB @ 109.OOft (Doyon 141 (28 + 81)) Plan RKB @ 109.OOft (Doyon 141 (28 + 81 )) True Minimum Curvature 2.00 sigma CPAI 2003.11 Reference Datum ISCWSA Trav. Cylinder North Elliptical Conic Summary Site Name Offset Well -Wellbore -Design Kuparuk 1J Pad Plan 1J-115 -Plan 1J-115 -1J-115 (wp05) Plan 1J-115 -Plan 1J-115 L2 - 1J-115 L2 (wp05) Reference Offset Centre to Measured Measured Centre Depth Depth Distance (ft) (ft) (ft) 13, 752.76 13, 762.00 146.30 13,903.25 13,899.94 62.22 No-Go Allowable Distance Deviation Warning (ft) from Plan (ft) 185.92 -39.62 FAIL -Major Risk 179.62 -117.40 FAIL -Major Risk CC -Min centre to center distance or covergent point, SF -min separation factor, ES -min ellipse separation 7/14/2006 2:59:45PM r .u P.'~ ~ ®fi2 COMPASS 2003.11 Build 48 1J-115L~rillin~ Hazards mammary (SEE WELL PLAN AND ATTACHMENTS FOR DETAILED DISCUSSION OF THESE RISKS) 6-3/4" Open Hole / 4-1/2" Liner Interval Hazard Risk Level Miti ation Strate Abnormal Reservoir Pressure Low Stripping drills, shut-in drills, increased mud 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-115L1 Drilling Hazards Summary ~ a ~ s ~ prepared by Shane Cloninger ~ K ~ ~ t~.--- 5/12/2006 1:09 PM n ~~ D ~. r 'r'1 ~ t*'1 y r~ -~ ~+ m _s.f ~ F S ~ ~~ ~ 3 ~ • o" ~~~ C n ~ -~~ ~"~' -' ro ~ "~" ~ ~ ~r c G,.. s c s b a k° ~~ e~ '.~ a~ Ws~ a o",~ Wellhead /Tubing Head /Tree, 10-3/4" x 4'/z", 5,000 ksi Insulated Conductor Casing, 20", 94#, K55 x 34", 0.312" WT +/- 80' MD 10-3/4", 45.5#, L-80, BTC, R3 @ 2,781' MD / 2,150' TVD ~~ @ G3 degrees TD 13-1/2" hole Top of Ugnu C n 4,500' MD / 2,840' TVD ~ Top of West Sak B (a7 6,400' SID / 3,533' TVD - -~ Lateral Entry Module #1 (LEM), Baker, with seal bore and ZXP packer above. 4r~ 6,464' h 80 degrees Tubing, 4-'/:" IBTM from LEM to AZ Liner, with seal stem and `'y CAMCO 3.562" "DB" nipple. ~ Seal bore and ZXP packer for A.'. liner +/- 90' below "B" window Top of West Sak A 6,800' MD / 3,567 TVD ~ 7-5/8", 29.7#, L-80, BTCM, R3 Csg @ 7,GOG' MD / 3,81 I' TVD @ 85 degrees TD 9-7/8" hole Tubing Stri ng. 4-1/2", 12.G #, L-80, IB'CM (1) Gas Lift Mandrel, CAh1CO 4-1/2" x I" Model Kr[BG w/ dwnmy valve @, one (I) set @ 2,400' bID, 1,977 TVD. (1) Gas Lift Mandrel, CAMCO 4-l/2" x 1" Model KMBG w/ dununy valve, @ < 72 deg, 5,000' MD, 3, IG2' TW. Electric Submersible Pump, Centrilift 418 HP motor, with FC6000 wireline deployed pump. Bottom al SZ3T MD, 3,260' TVD 152 L2 "U" Sand Window @ 6,095' MD / 3,53T TVD 77 degrees "D" Liner, 4-1/2", I LG#, L80, BTC, R3 IJ-152 L2: (0.125" x 2.5" slots, 32 per foot, 5.9 % open area) 6-3/4" D sand lateral TD 13,955' MD / 3,708' TW Angle 88 degrees TVD Il-152 L I 'B" Liner, 4-1/2", 11.6#, L80, BTC, R3 6-3/ send-lateral (0.125" x 2.5" slots, 32 per foot, 5.9 % open area) TD 13,891' MD / 3,7GT TW Angle 88 degrees 1.~~-\ISL~ A2 Sand Liner, 4-1/2", 11.6#, L80, BTC, --7r7TTA~nd lateral R3 '/z slotted and '/x blank c'onatricrorc jar TD 13,701' MD / 3,907 TVD rsolartrsr Angle 88 degrees • ~~vSM~TTA~ LETTER ~~ECKLIST WELL NAME ~~~ ~ o~" ~~~G Development Service Exploratory Stratigraphic Test Ion-Conventional Well Circle Appropriate Letter /Paragraphs to be Included in Transmittal Letter CHECK ~ ADD-ONS WHAT ~ (OPTIONS) APPLIES ~ TEXT FOR APPROVAL LETTER MULTI LATERAL The permit is for a new wellbore segment of existing ~ ~ well I~~~ /~~-~~~ (If last two digits in ~ permit No. Z~(o `/ZZ , API No. 50-Q~- 23320 -QO . i API number are between 60-69) Production should continue to be reported as a function of the ' , original API number stated above. PILOT HOLE I In accordance with 20 AAC 25.00~(f), all records, data and logs i ~ acquired for the pilot hole must be clearly differentiated in both well name ( PH) and API number j ~ (50- - -_) from records, data and logs f acquired for well SPACING ;The permit is approved subject to full compliance with 20 AAC EXCEPTION . 23.0>j. Approval to perforate and produce r' inject is contingent i upon issuance of a conservation order approving a spacing I ~ 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 SAMPLE ; no greater than 30' sample intervals from below the permafrost or j from where samples are first caught and 10' sample intervals !through target zones. Please note the following special condition of this permit: j ~ Non-Conventional i production or production testing of coal bed methane is not allowed j j Well ~~ for (name of well) until after (Companv Name) has designed and ~ i implemented a water well testing program to provide baseline data ~ on water quality and quantity. ~Com~anv Name) must contact the i Commission to obtain advance approval of such water well testing i program. Rev: 1 /25/06 C:Ajody\transmittal checklist WELL PERMIT CHEC~(LIST Field & Pool KUPARUK RIVER, WEST SAKOIL - 490150 Well Name: KUPARUK RIV U WSAK 1J-115L1 Program DEV Well bore seg r!^ PTD#:2061230 Company CONOCOPHILLIPS ALASKA INC Initial Classffype DEV / PEND GeoArea 890 Unit 11160 OnlOff Shore On Annular Disposal ^ Administration 1 Pe[mit_fee attached_ _ _ - - - - N_A_ West Sak$ Sand multilateral well blanch; fee waived per 20AAC 25.005(e}-- - - - - - - - - - - - - - - 2 Lease number appropriake_____________________________ ______ Yes- ---_--Top_productiveinterval inADL025661;_TDinADL025650._______________-___-______------- 3 Uniquewell_nameandnumbe[__________________________ __________ __Yes_ __-_-...._--__- 4 Well locatedin-a_definedpo4l_________________---.-____ ______------Yes- ___Kupa[ukRiver, West-$akOilPool-490150,_governed_byCO406B____----__--_----_-__-_--_ 5 VYell located proper distance from drilling unit_boundary_ - - - - - . _ . - Yes - - - - - - -Well is more than_ 509 feet from an external property line. - - - . . 6 Well located proper distance_ from_other Wells_ - - _ _ . _ _ - - _ _ - Yes . . _ - ... CO 4068, Rule 3:_ no restrictions as-to 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_an external_p_rope[ty/ine where ownership. or landownership changes- - - - - - - - - - - - - - - - - - 8 If_deyiated,is-weUboreplat_included-__.-____________.-.- -_-___ Yes- ----------------------------------------_____________ 9 Operator only affected party- - - - - - - - - - - - - Yes - - - 10 Operator has appropriate_bondinforce- --------- ----- -- --------- --Yes- --- -- -- -- ~-----~-------------- -------- --------------------- -- - 11 Permit_canbeissuedwithoutconserva_tignorder__________ _____ ____--_____Yes ____-.----__--_--__-_- - -- -- - - - Appr Date 12 Permit_can be issued without administrative_approval - _ - - _ - - - . - _ Yes - - - - .. _ - - - - - SFD 8/1612006 13 Can permit be approved before 15-day wait Yes 14 Well located within areaand_strataauthprizedby_InjectionOrder#(putlQ# in_comments)_(For_NA__ _-__-----------------_..-----...----..---_-._--__--__--_---__-________,. 15 All wells within 1f4_mile area of review identified (Far service well only) _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ IVA_ _ _ _ _ _ _ _ .... _ _ - _ _ _ _ _ _ _ - _ - 16 Pre-produced injector:dur_akinn.ofpre~[oductionl_essthan_3mgnths-(Forservfcewellonly)_NA__ __________________________________________________________________________ 17 Nonconven,gasconformstoAS31,05,030Q.1.A),Q.2.A-D)__,__ ____ ___-_--___ NA__ ______--_________________ ____--_- -.-_. Engineering 18 Conductor string-provided___ -__--..--.-_----------- ------------ NA__ ___--.Conduetorset_inmotherbore,_1_J-115(206-122).-_--.-_.-_--_-__--___-_______-_,--__---- 19 Surface casing-protects all known USDWs______________ ____ ____________ NA__ _____Allaquifersexempted,40CFR_147.102(b)_(3)._--_-.-_.-_-______---_--__-.__--_ 20 CMT-vol adegu_ate-to ci[culate-on conductor_ & surf csg _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ NA, _ _ _ _ _ _ _ Surface rosin set In 1J-115._ _ _ g-- - - - - - 21 CMT-vol_adeguate-to tie-in longstringtosurfcsg________________ ____________ NA_- ____..Production-casing set in_1J-115.-.___---_--_---_----____________________- 22 CMT-willcoverallknow.n-productiyehorizons_____________ ____ _________.- No-_ ____ Slotted linercgmpletionplanned._-______________----_--_----_--__---_----__----- 23 Casing designs adequate for C,-T B &_permafrost- - - -- - - - - - - - - - - NA- _ _ - _ - - MQtherbore metdesign specifications, NA for slatted liner, 24 Adequate tankage-or reserve pit - - .. - - .. - - - - - - - - - - - - - - - - - - -- - - Yes Rig js.equipped with steel_pits. No reserve-pitplanned: All waste to approved annulus or disposal well.- 25 If a_re-drill, has_a 10-403 for abandonment been approved - - - - - - - _ NA - - . - - . - _ - - - - - - - - 26 Adequate w-ellbore seperationproposed _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes . .. _ _ - . Proximity_ analysis performed, Nearest well segment is motherbore ~150'_tyd deeper.- _ _ - - _ _ _ _ _ - - - - - - - - 27 If_diverterrequired,doesitmeetregulations_______________ ___ ___________ NA-_ ______BQPStack_willalready_beinplace,________________--_-_-___-___------_____--_-__- Appr Date 28 Drilling fluid_ program schematic_$ equip listadequate_ - . - - - . - . - -Yes Maximum expected formation pressu[e 8,7_EMW, Planned-MW $:6ppg or_as needed-- - - -- - - - - - ----- - - TEM 811812006 29 BOPEs,dotheymeetregulation-_-____ _ ________________ ____________Yes- _--__--_.___________--_-----__--________--_________________________--_--__ 30 BOPS-press rating appropriate; test to.(put psig in comments}_ _ - - , - , _ Yes MASP calculated at 1318 psi. 3K equipment set up and test pressure_planned.. - . - - . - - - _ 31 Choke-manifold complieswlAPLRP-53(May84)________________ ____________Yes_ _-_______-- 32 Work willoccu[withoutoperationshutdown_,__-_-_-,_______ ____________Yes_ _________ _--- --- - 33 Ispresence_ofH2Sgasprobable___--------------------- -_-.--.--.- No-- _____H2Shasnotbeenrep4rtedak1J_pad._________-----_____---_.-_-._--.-_--__--_---- 34 Mechanical condition of wells withinAORyeri_fied(For_senricewellonly)__ ____________ NA-_ -.__..----___.____-_-__-..__.___-.-_---_-___-____________-_______ ______ Geology 35 Permit_can be issued w/o hydrogen_sulfide measures - - - - -- - -- - - - - Yes - - - Nearby well bore in-pool,1 D-102, measured 5.ppm_H2$ 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 pR9 oil-based mud. Mud weight will be - . - - - - . Appr Date 37 Seismic analysis-of shallow gas_zones_ - _ . - _ - . -- - NA_ _ - - _ _ _ _ adjusted as needed. _ .. _ - _ _ _ _ _ _ _ _ _ . .. . . . .. . .. . . .. . .. . _ _ - - SFD 8!16/2006 38 Seabed conditionsuryey_(ifoff-shore)---------------------- -------- NA-- ---------------------------------------------------------------- -.- 39 Contact name/phone for weekly progress reports_[explorztoryonly]_____ ____________ NA__ _--_____________----_.--___--_-___________-_______-_____-___-_----__ Geologic Engineering P Date: Date Date West Sak B sand producer. This is one of the well branches from tri-lateral production well KRU 1J•115. SFD Commissioner: Commission r: // L C issi ~ ~ ~ ~ r f ~ / ~ ~~ ~ I liD~i ! /~ I ~~~ ~ (J~ ~r/,/ ~ QV -j/' ~ • Well History f=ile 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 infom~ation, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made io chronologically . organize this category of information. i Sperry-Sun Drilling Services LIS Scan Utility $Revision: 3 $ LisLib $Revision: 4 $ Wed Feb 21 16:23:13 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 Scientific Technical Services Scientific Technical Services Comment Record TAPE HEADER West Sak MWD/MAD LOGS WELL NAME: 1J-115 L1 API NUMBER: 500292332060 OPERATOR: ConocoPhillips Alaska, Inc LOGGING COMPANY: Sperry Drilling Services TAPE CREATION DATE: 21-FEB-07 JOB DATA MWD RUN 3 MWD RUN 9 MWD RUN 10 JOB NUMBER: MW-000465039 MW-000465039 MW-000465039 LOGGING ENGINEER: T. GALVIN T. GALVIN T. GALVIN OPERATOR WITNESS: G. WHITLOCK D. GLADDEN D. GLADDEN MWD RUN 11 MWD RUN 12 MWD RUN 14 JOB NUMBER: MW-000465039 MW-000465039 MW-000465039 LOGGING ENGINEER: T. GALVIN T. GALVIN S. GREENE OPERATOR WITNESS: D. GLADDEN D. GLADDEN G. WHITLOCK SURFACE LOCATION SECTION: 35 TOWNSHIP: 11N RANGE: l0E 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 ~~~"~c7J ~`-tSCS~ BIT SIZE (IN) SIZE (IN) DEPTH (FT) 1ST STRING 9.875 10.750 3009.0 2ND STRING 6.750 7.625 6529.0 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 L1PB2 WELLBORE AT 8414'MD/3680'TVD. 4. MWD RUN 1 WAS DIRECTIONAL ONLY - NO DATA ARE PRESENTED. 5. MWD RUNS 2,3,10-14 COMPRISED DIRECTIONAL, DUAL GAMMA RAY (DGR) UTILIZING GEIGER-MUELLER TUBE DETECTORS, ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4), AND PRESSURE WHILE DRILLING (PWD) MWD RUN 14 ALSO INCLUDED GEO- PILOT ROTARY STEERABLE BHA (GP) NO MWD DATA WERE ACQUIRED ON MWD RUN 2 DUE TO AN MWD FAILURE. SROP DATA ONLY ARE PRESENTED FOR RUN 9. NO DATA WERE ACQUIRED ON RUN 13 DUE TO PROBLEMS WITH THE WINDOW. 6. .DEPTH SHIFTING OF MWD DATA WAS WAIVED PER E-MAIL, DATED 12/16/04, FROM M. WERNER (CPAI) TO R. KALISH (SDS) MWD DATA ARE CONSIDERED PDC. 7. MWD RUNS 1-3,9-14 REPRESENT WELL 1J-115 L1 WITH API#: 50-029-23320-60. THIS WELL REACHED A TOTAL DEPTH (TD) OF 13922'MD/3775'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; DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE START DEPTH GR 2993.5 RPS 2995.0 RPD 2995.0 RPM 2995.0 RPX 2995.0 FET 2995.0 ROP 3040.5 all bit runs merged. STOP DEPTH 13864.5 13871.5 13871.5 13871.5 13871.5 13871.5 13922.0 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 9 6529.5 10 6559.0 11 7155.5 12 8414.5 14 10749.0 REMARKS: MERGED MAIN PASS. MERGE BASE 6529.0 6559.0 7155.0 8414.0 10749.0 13922.0 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 Servi ce Unit Min Max Mean Nsam Reading Reading DEPT FT 2993.5 13922 8457.75 21858 2993.5 13922 RPD MWD OHMM 1.9 2000 66.2094 21754 2995 13871.5 RPM MWD OHMM 1.48 2000 48.6496 21754 2995 13871.5 RPS MWD OHMM 0.2 1888.5 39.8626 21754 2995 13871.5 RPX MWD OHMM 0.9 1996.15 38.8174 21754 2995 13871.5 FET MWD HOUR 0.17 497.22 1.30819 21754 2995 13871.5 GR MWD API 24.09 122.12 67.5877 21743 2993.5 13864.5 ROP MWD FT/H 0.7 750.7 175.383 21764 3040.5 First Reading For Entire File..........2993.5 Last Reading For Entire File...........13922 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 6529.0 RPM 2995.0 6529.0 RPS 2995.0 6529.0 RPD 2995.0 6529.0 FET 2995.0 6529.0 RPX 2995.0 6529.0 ROP 3040.5 6529.0 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) 6529.0 TOP LOG INTERVAL (FT) 3040.0 BOTTOM LOG INTERVAL (FT) 6529.0 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 13922 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 .lIN Max frames per record .............Undefined Absent value ......................-999 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 RPD MWD030 OHMM 4 1 68 4 2 RPM MWD030 OHMM 4 1 68 8 3 RPS MWD030 OHMM 4 1 68 12 4 RPX MWD030 OHMM 4 1 68 16 5 FET MWD030 HOUR 4 1 68 20 6 GR MWD030 API 4 1 68 24 7 ROP MWD030 FT/H 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 2993.5 6529 4761.25 7072 2993.5 6529 RPD MWD030 OHMM 1.9 2000 18.4911 7069 2995 6529 RPM MWD030 OHMM 1.48 1651.33 15.1103 7069 2995 6529 RPS MWD030 OHMM 0.2 83.19 13.4777 70.69 2995 6529 RPX MWD030 OHMM 0.9 76.8 12.7778 7069 2995 6529 FET MWD030 HOUR 0.17 56.28 1.03322 7069 2995 6529 GR MWD030 API 24.09 122.12 67.7374 7072 2993.5 6529 ROP MWD030 FT/H 9.61 636.55 204.819 6978 3040.5 6529 First Reading For Entire File..........2993.5 Last Reading For Entire File...........6529 a~ File Trailer 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 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: 9 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH ROP 6529.5 6559.0 LOG HEADER DATA DATE LOGGED: 27-OCT-06 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 72.13 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT) 6559.0 TOP LOG INTERVAL (FT) 6529.0 BOTTOM LOG INTERVAL (FT) 6559.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: .0 MAXIMUM ANGLE: .0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) 6.750 DRILLER'S CASING DEPTH (FT) 6529.0 BOREHOLE CONDITIONS MUD TYPE: Mineral Oil Base MUD DENSITY (LB/G) 8.80 MUD VISCOSITY (S) 62.0 MUD PH: .0 MUD CHLORIDES (PPM): 122000 FLUID LOSS (C3) 2.6 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT) .000 .0 MUD AT MAX CIRCULATING TERMPERATURE: .000 90.0 MUD FILTRATE AT MT: .000 .0 MUD CAKE AT MT: .000 .0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format Specification Record Data Record Type ..................0 Data Specification Block Type.....0 Logging Direction .................Down Optical log depth units...........Feet Data Reference Point ..............Undefined Frame Spacing .....................60 .lIN Max frames per record .............Undefined Absent value ......................-999 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD090 FT/H 4 1 68 4 2 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 6529.5 6559 6544.25 60 6529.5 6559 ROP MWD090 FT/H 1.43 48.02 19.9982 60 6529.5 6559 First Reading For Entire File..........6529.5 Last Reading For Entire File...........6559 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 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: 10 DE PTH INCREMENT: .5000 FI LE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH RPD 6529.5 7155.0 GR 6529.5 7155.0 RPM 6529.5 7155.0 FET 6529.5 7155.0 RPX 6529.5 7155.0 RPS 6529.5 7155.0 ROP 6559.5 7155.0 LOG HEADER DATA DATE LOGGED: 29-OCT- 06 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 72.13 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 7155.0 TOP LOG INTERVAL (FT) 6559.0 BOTTOM LOG INTERVAL (FT) 7155.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 82.8 MAXIMUM ANGLE: 93.4 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 151107 EWR4 Electromag Resis. 4 156404 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) 6.750 DRILLER'S CASING DEPTH (FT) 6529.0 BOREHOLE CONDITIONS MUD TYPE: Mineral Oil Base MUD DENSITY (LB/G) 8.80 MUD VISCOSITY (S) 63.0 MUD PH: .0 MUD CHLORIDES (PPM): 22500 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 r Frame Spacing .....................60 .lIN Max frames per record .............Undefined Absent value ......................-999 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 RPD MWD100 OHMM 4 1 68 4 2 RPM MWD100 OHMM 4 1 68 8 3 RPS MWD100 OHMM 4 1 68 12 4 RPX MWD100 OHMM 4 1 68 16 5 FET MWD100 HOUR 4 1 68 20 6 GR MWD100 API 4 1 68 24 7 ROP MWD100 FT/H 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 6529.5 7155 6842.25 1252 6529.5 7155 RPD MWD100 OHMM 12.19 2000 84.7254 1252 6529.5 7155 RPM MWD100 OHMM 10.62 2000 73.2908 1252 6529.5 7155 RPS MWD100 OHMM 10.06 950.71 67.704 1252 6529.5 7155 RPX MWD100 OHMM 6.34 1996.15 79.0369 1252 6529.5 7155 FET MWD100 HOUR 0.31 497.22 3.39347 1252 6529.5 7155 GR MWD100 API 38.73 116.28 62.2147 1252 6529.5 7155 ROP MWD100 FT/H 0.92 750.7 193.978 1192 6559.5 7155 First Reading For Entire File..........6529.5 Last Reading For Entire File...........7155 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 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: 11 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH FET 7155.5 8414.0 RPS 7155.5 8414.0 ~' RPD 7155.5 8414.0 ROP 7155.5 8414.0 GR 7155.5 8414.0 RPM 7155.5 8414.0 RPX 7155.5 8414.0 LOG HEADER DATA DATE LOGGED: 30-OCT- 06 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 72.13 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT) 8414.0 TOP LOG INTERVAL (FT) 7155.0 BOTTOM LOG INTERVAL (FT): 8414.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 84.4 MAXIMUM ANGLE: 91.5 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 151107 EWR4 Electromag Resis. 4 156404 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) 6.750 DRILLER'S CASING DEPTH (FT) 6529.0 BOREHOLE CONDITIONS MUD TYPE: Mineral Oil Base MUD DENSITY (LB/G) 8.80 MUD VISCOSITY (S) 63.0 MUD PH: .0 MUD CHLORIDES (PPM): 22500 FLUID LOSS (C3) 4.0 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT) .000 .0 MUD AT MAX CIRCULATING TERMPERATURE: .000 118.0 MUD FILTRATE AT MT: .000 .0 MUD CAKE AT MT: .000 .0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (iN): EWR FREQUENCY (HZ): REMARKS: Data Format Specification Record Data Record Type ..................0 Data Specification Block Type.....0 Logging Direction .................Down Optical log depth units...........Feet Data Reference Point ..............Undefined Frame Spacing .....................60 .lIN Max frames per record .............Undefined Absent value ......................-999 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel ~~ DEPT FT 4 1 68 0 1 RPD MWD110 OHMM 4 1 68 4 2 RPM MWD110 OHMM 4 1 68 8 3 RPS MWD110 OHMM 4 1 68 12 4 RPX MWD110 OHMM 4 1 68 16 5 FET MWD110 HOUR 4 1 68 20 6 GR MWD110 API 4 1 68 24 7 ROP MWD110 FT/H 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 7155.5 8414 7784.75 2518 7155.5 8414 RPD MWD110 OHMM 25.77 113.98 55.3031 2518 7155.5 8414 RPM MWD110 OHMM 21.78 107.07 49.4462 2518 7155.5 8414 RPS MWD110 OHMM 19.93 147.56 51.9056 2518 7155.5 8414 RPX MWD110 OHMM 17.61 165.08 50.6321 25.18 7155.5 8414 FET MWD110 HOUR 0.39 12.37 1.13733 2518 7155.5 8414 GR MWD110 API 39.1 87.84 65.4691 2518 7155.5 8414 ROP MWD110 FT/H 4.06 310.33 135.312 2518 7155.5 8414 First Reading For Entire File..........7155.5 Last Reading For Entire File...........8414 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: 12 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH ROP 8414.5 10749.0 GR 8414.5 10683.5 FET 8414.5 10690.5 RPX 8414.5 10690.5 RPS 8414.5 10690.5 RPM 8414.5 10690.5 RPD 8414.5 10690.5 `~ LOG HEADER DATA DATE LOGGED: O1-NOV-06 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 72.13 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT) 10749.0 TOP LOG INTERVAL (FT) 8414.0 BOTTOM LOG INTERVAL (FT) 10749.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 86.5 MAXIMUM ANGLE: 91.6 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 151107 EWR4 Electromag Resis. 4 156404 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) 6.750 DRILLER'S CASING DEPTH (FT) 6529.0 BOREHOLE CONDITIONS MUD TYPE: Mineral Oil Base MUD DENSITY (LB/G) 8.80 MUD VISCOSITY (S) 73.0 MUD PH: .0 MUD CHLORIDES (PPM): 24000 FLUID LOSS (C3) 3.6 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT) .000 .0 MUD AT MAX CIRCULATING TERMPERATURE: .000 118.4 MUD FILTRATE AT MT: .000 .0 MUD CAKE AT MT: .000 .0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format Specification Record Data Record Type ..................0 Data Specification Block Type.....0 Logging Direction .................Down Optical log depth units...........Feet Data Reference Point ..............Undefined Frame Spacing .....................60 .lIN Max frames per record .............Undefined Absent value ......................-999 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 RPD MWD120 OHMM 4 1 68 4 2 RPM MWD120 OHMM 4 1 68 8 3 RPS MWD120 OHMM 4 1 68 12 4 RPX MWD120 OHMM 4 1 68 16 5 FET MWD120 HOUR 4 1 68 20 6 GR MWD120 API 4 1 68 24 7 ,~~' ROP MWD120 FT/H 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 8414.5 10749 9581.75 4670 8414.5 10749 RPD MWD120 OHMM 18.47 380.59 52.01 4553 8414.5 10690.5 RPM MWD120 OHMM 16.71 2000 46.1837 4553 8414.5 10690.5 RPS MWD120 OHMM 17.33 1888.5 46.9077 4553 8414.5 10690.5 RPX MWD120 OHMM 16.37 121.07 43.8212 4553 8414.5 10690.5 FET MWD120 HOUR 0.29 7.2 1.08116 4553 8414.5 10690.5 GR MWD120 API 42.24 89.37 67.3664 4539 8414.5 10683.5 ROP MWD120 FT/H 0.7 322.45 138.266 4670 8414.5 10749 First Reading For Entire File..........8414.5 Last Reading For Entire File...........10749 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: 14 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 10684.0 13864.5 RPX 10691.0 13871.5 RPD 10691.0 13871.5 FET 10691.0 13871.5 RPS 10691.0 13871.5 RPM 10691.0 13871.5 ROP 10749.5 13922.0 LOG HEADER DATA DATE LOGGED: 04-NOV-06 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 72.13 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT) 13922.0 ~i TOP LOG INTERVAL (FT) 10749.0 BOTTOM LOG INTERVAL (FT) 13922.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 85.2 MAXIMUM ANGLE: 93.4 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 151107 EWR4 Electromag Resis. 4 156404 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) 6.750 DRILLER'S CASING DEPTH (FT) 6529.0 BOREHOLE CONDITIONS MUD TYPE: Mineral Oil Base MUD DENSITY (LB/G) 8.70 MUD VISCOSITY (S) 73.0 MUD PH: .0 MUD CHLORIDES (PPM): 22500 FLUID LOSS (C3) 3.4 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT) .000 .0 MUD AT MAX CIRCULATING TERMPERATURE: .000 118.4 MUD FILTRATE AT MT: .000 .0 MUD CAKE AT MT: .000 .0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format Specification Record Data Record Type ..................0 Data Specification Block Type.....0 Logging Direction......... ......Down Optical log depth units...........Feet Data Reference Point ..............Undefined Frame Spacing .....................60 .lIN Max frames per record .............Undefined Absent value ......................-999 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 RPD MWD140 OHMM 4 1 68 4 2 RPM MWD140 OHMM 4 1 68 8 3 RPS MWD140 OHMM 4 1 68 12 4 RPX MWD140 OHMM 4 1 68 16 5 FET MWD140 HOUR 4 1 68 20 6 GR MWD140 API 4 1 68 24 7 ROP MWD140 FT/H 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 10684 13922 12303 6477 10684 13922 RPD MWD140 OHMM 13.15 RPM MWD140 OHMM 11.85 RPS MWD140 OHMM 11.61 RPX MWD140 OHMM 11.28 FET MWD140 HOUR 0.2 GR MWD140 API 39.71 ROP MWD140 FT/H 1.46 2000 130.065 6362 10691 13871.5 2000 82.5162 6362 10691 13871.5 203.14 53.8924 6362 10691 13871.5 216.28 51.5786 6362 10691 13871.5 46.85 1.43344 6362 10691 13871.5 109.41 69.475 6362 10684 13864.5 366.39 184.207 6346 10749.5 13922 First Reading For Entire File..........10684 Last Reading For Entire File...........13922 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 Sperry-Sun Drilling Services LIS Scan Utility $Revision: 3 $ LisLib $Revision: 4 $ Thu Feb 22 09:11:59 2007 Reel Header Service name .............LISTPE Date .....................07/02/22 Origin ...................STS Reel Name ................UNKNOWN Continuation Number......01 Previous Reel Name.......UNKNOWN Comments .................STS LIS Writing Library Tape Header Service name .............LISTPE Date .....................07/02/22 Origin ...................STS Tape Name ................UNKNOWN Continuation Number......01 Previous Tape Name.......UNKNOWN Comments .................STS LIS Writing Library Physical EOF Scientific Technical Services Scientific Technical Services Comment Record TAPE HEADER West Sak MWD/MAD LOGS WELL NAME: 1J-115 L1 PB1 API NUMBER: 500292332074 OPERATOR: ConocoPhillips Alaska, Inc LOGGING COMPANY: Sperry Drilling Services TAPE CREATION DATE: 22-FEB-07 JOB DATA MWD RUN 3 MWD RUN 9 MWD RUN 10 JOB NUMBER: W-0004650390 W-0004650390 W-0004650390 LOGGING ENGINEER: T. CALVIN T. CALVIN T. CALVIN OPERATOR WITNESS: G. WHITLOCK D. GLADDEN D. GLADDEN SURFACE LOCATION SECTION: 35 TOWNSHIP: 11N RANGE: l0E 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 6529.0 3RD STRING PRODUCTION STRING REMARKS: 1. ALL DEPTHS ARE MEASURED DEPTHS UNLESS OTHERWISE NOTED. THESE DEPTHS ARE BIT DEPTHS. 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTHS (TVD). 3. THIS WELLBORE WAS DRILLED FROM A WHIPSTOCK, THE TOP OF WHICH WAS AT 6529' MD/3640'TVD, WITHIN THE RUN 3 INTERVAL OF THE 1J-115 PB1 WELLBORE. THE WHIPSTOCK WAS POSITIONED, THE WINDOW WAS MILLED, AND A BIT OF RAT HOLE WAS DRILLED DURING MWD RUN 9. ONLY SROP DATA ARE PRESENTED FOR THIS RUN. 4. MWD RUN 1 WAS DIRECTIONAL ONLY - NO DATA ARE PRESENTED. 5. MWD RUNS 2,3,10 COMPRISED DIRECTIONAL, DUAL GAMMA RAY (DGR) UTILIZING GEIGER-MUELLER TUBE DETECTORS, ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4), AND PRESSURE WHILE DRILLING (PWD) 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 1-3,9,10 REPRESENT WELL 1J-115 L1PB1 WITH API#: 50-029-23320-74. THIS WELL REACHED A TOTAL DEPTH (TD) OF 7522'MD/3639'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.......07/02/22 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 7457.0 FET 2995.0 7464.0 RPD 2995.0 7464.0 RPS 2995.0 7464.0 RPM 2995.0 7464.0 RPX 2995.0 7464.0 ROP 3040.5 7522.0 BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH MERGED DATA SOURCE PBU TOOL CODE MWD MWD MWD S BIT RUN NO MERGE TOP 3 2993.5 9 6529.5 10 6559.0 REMARKS: MERGED MAIN PASS. MERGE BASE 6529.0 6559.0 7522.0 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 .lIN Max frames per record .............Undefined Absent value ......................-999 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 RPD MWD OHMM 4 1 68 4 2 RPM MWD OHMM 4 1 68 8 3 RPS MWD OHMM 4 1 68 12 4 RPX MWD OHMM 4 1 68 16 5 FET MWD HOUR 4 1 68 20 6 GR MWD API 4 1 68 24 7 ROP MWD FT/H 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 2993.5 7522 5257.75 9058 2993.5 7522 RPD MWD OHMM 1.9 2000 28.3685 8939 2995 7464 RPM MWD OHMM 1.48 2000 23.6506 8939 2995 7464 RPS MWD OHMM 0.2 950.71 21.2864 8939 2995 7464 RPX MWD OHMM 0.9 1996.15 22.1524 8939 2995 7464 FET MWD HOUR 0.17 497.22 1.41138 8939 2995 7464 GR MWD API 24.09 130.65 69.2197 8928 2993.5 7457 ROP MWD FT/H 0.92 750.7 191.545 8964 3040.5 7522 First Reading For Entire File..........2993.5 Last Reading For Entire File...........7522 File Trailer Service name .............STSLIB.001 ~_ Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......07/02/22 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.......07/02/22 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 6529.0 FET 2995.0 6529.0 RPX 2995.0 6529.0 RPS 2995.0 6529.0 RPM 2995.0 6529.0 RPD 2995.0 6529.0 ROP 3040.5 6529.0 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) 6529.0 TOP LOG INTERVAL (FT) 3040.0 BOTTOM LOG INTERVAL (FT) 6529.0 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 .lIN Max frames per record ........ .....Undefined Absent value ................. .....-999 Depth Units .................. ..... Datum Specification Block sub -type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 RPD MWD030 OHMM 4 1 68 4 2 RPM MWD030 OHMM 4 1 68 8 3 RPS MWD030 OHMM 4 1 68 12 4 RPX MWD030 OHMM 4 1 68 16 5 FET MWD030 HOUR 4 1 68 20 6 GR MWD030 API 4 1 68 24 7 ROP MWD030 FT/H 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 2993.5 6529 4761.25 7072 2993.5 6529 RPD MWD030 OHMM 1.9 2000 18.4911 7069 2995 6529 RPM MWD030 OHMM 1.48 1651.33 15.1103 7069 2995 6529 RPS MWD030 OHMM 0.2 83.19 13.4777 7069 2995 6529 RPX MWD030 OHMM 0.9 76.8 12.7778 7069 2995 6529 FET MWD030 HOUR 0.17 56.28 1.03322 70.69 2995 6529 GR MWD030 API 24.09 122.12 67.7374 7072 2993.5 6529 ROP MWD030 FT/H 9.61 636.55 204.819 6978 3040.5 6529 First Reading For Entire File..........2993.5 Last Reading For Entire File...........6529 File Trailer Service name .............STSLIB.002 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......07/02/22 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.......07/02/22 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: 9 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH ROP 6529.5 6559.0 LOG HEADER DATA DATE LOGGED: 27-OCT-06 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 72.13 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT) 6559.0 TOP LOG INTERVAL (FT) 6529.0 BOTTOM LOG INTERVAL (FT) 6559.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: .0 MAXIMUM ANGLE: .0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) 6.750 DRILLER'S CASING DEPTH (FT) 6529.0 BOREHOLE CONDITIONS MUD TYPE: Mineral Oil Base MUD DENSITY (LB/G) 8.80 MUD VISCOSITY (S) 62.0 MUD PH: .0 MUD CHLORIDES (PPM): 122000 FLUID LOSS (C3) 2.6 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT) .000 .0 MUD AT MAX CIRCULATING TERMPERATURE: .000 90.0 MUD FILTRATE AT MT: .000 .0 MUD CAKE AT MT: .000 .0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format Specification Record Data Record Type ..................0 Data Specification Block Type.....0 Logging Direction .................Down Optical log depth units...........Feet Data Reference Point ..............Undefined Frame Spacing .....................60 .lIN Max frames per record .............Undefined Absent value ......................-999 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD090 FT/H 4 1 68 4 2 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 6529.5 6559 6544.25 60 6529.5 6559 ROP MWD090 FT/H 1.43 48.02 19.9982 60 6529.5 6559 First Reading For Entire File..........6529.5 Last Reading For Entire File...........6559 File Trailer Service name .............STSLIB.003 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......07/02/22 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.......07/02/22 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: 10 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH RPX 6529.5 7464.0 RPD 6529.5 7464.0 RPM 6529.5 7464.0 GR 6529.5 7457.0 RPS 6529.5 7464.0 FET 6529.5 7464.0 ROP 6559.5 7522.0 LO G HEADER DATA DATE LOGGED: 29-OCT-06 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 72.13 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT) 7522.0 TOP LOG INTERVAL (FT) 6559.0 BOTTOM LOG INTERVAL (FT) 7522.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 82.8 MAXIMUM ANGLE: 96.4 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 151107 EWR4 Electromag Resis. 4 156404 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) 6.750 DRILLER'S CASING DEPTH (FT) 6529.0 BOREHOLE CONDITIONS MUD TYPE: Mineral Oil Base MUD DENSITY (LB/G) 8.80 MUD VISCOSITY (S) 63.0 MUD PH: .0 MUD CHLORIDES (PPM): 22500 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 .lIN Max frames per record .............Undefined Absent value ......................-999 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 RPD MWD100 OHMM 4 1 68 4 2 ` • RPM MWD100 OHMM 4 1 68 8 3 RPS MWD100 OHMM 4 1 68 12 4 RPX MWD100 OHMM 4 1 68 16 5 FET MWD100 HOUR 4 1 68 20 6 GR MWD100 API 4 1 68 24 7 ROP MWD100 FT/H 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 6529.5 7522 7025.75 1986 6529.5 7522 RPD MWD100 OHMM 4.04 2000 65.7075 1870 6529.5 7464 RPM MWD100 OHMM 3.65 2000 55.9349 1870 6529.5 7464 RPS MWD100 OHMM 3.66 950.71 50.805 1870 6529.5 7464 RPX MWD100 OHMM 3.44 1996.15 57.5905 1870 6529.5 7464 FET MWD100 HOUR 0.31 497.22 2.8409 1870 6529.5 7464 GR MWD100 API 38.73 130.65 74.8681 18.56 6529.5 7457 ROP MWD100 FT/H 0.92 750.7 148.796 1926 6559.5 7522 First Reading For Entire File..........6529.5 Last Reading For Entire File...........7522 File Trailer Service name .............STSLIB.004 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......07/02/22 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.005 Physical EOF Tape Trailer Service name .............LISTPE Date .....................07/02/22 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 .....................07/02/22 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 . i Sperry-Sun Drilling Services LIS Scan Utility $Revision: 3 $ LisLib $Revision: 4 $ Thu Feb 22 09:50:14 2007 Reel Header Service name .............LISTPE Date .....................07/02/22 Origin ...................STS Reel Name ................UNKNOWN Continuation Number......01 Previous Reel Name.......UNKNOWN Comments .................STS LIS Writing Library Tape Header Service name .............LISTPE Date .....................07/02/22 Origin ...................STS Tape Name ................UNKNOWN Continuation Number......01 Previous Tape Name.......UNKNOWN Comments .................STS LIS Writing Library Physical EOF • Scientific Technical Services Scientific Technical Services Comment Record TAPE HEADER West Sak MWD/MAD LOGS WELL NAME: 1J-115 L1 PB2 API NUMBER: 500292332075 OPERATOR: ConocoPhillips Alaska, Inc LOGGING COMPANY: Sperry Drilling Services TAPE CREATION DATE: 22-FEB-07 JOB DATA MWD RUN 3 MWD RUN 9 MWD RUN 10 JOB NUMBER: W-0004650390 W-0004650390 W-0004650390 LOGGING ENGINEER: T. CALVIN T. CALVIN T. CALVIN OPERATOR WITNESS: G. WHITLOCK D. GLADDEN D. GLADDEN MWD RUN 11 JOB NUMBER: W-0004650390 LOGGING ENGINEER: T. CALVIN OPERATOR WITNESS: D. GLADDEN SURFACE LOCATION SECTION: 35 TOWNSHIP: 11N RANGE: l0E 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 ~~~, _ ~a3 ~~~ ~~ ~ # i BIT SIZE (IN) SIZE (IN) DEPTH (FT) 1ST STRING 9.875 10.750 3009.0 2ND STRING 6.750 7.625 6529.0 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 L1PB1 WELLBORE AT 7155'MD/3659'TVD. 4. MWD RUN 1 WAS DIRECTIONAL ONLY - NO DATA ARE PRESENTED. 5. MWD RUNS 2,3,10,11 COMPRISED DIRECTIONAL, DUAL GAMMA RAY (DGR) UTILIZING GEIGER-MUELLER TUBE DETECTORS, ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4), AND PRESSURE WHILE DRILLING (PWD) NO MWD DATA WERE ACQUIRED ON MWD RUN 2 DUE TO AN MWD FAILURE. SROP DATA ONLY ARE PRESENTED FOR RUN 9. 6. DEPTH SHIFTING OF MWD DATA WAS WAIVED PER E-MAIL, DATED 12/16/04, FROM M. WERNER (CPAI) TO R. KALISH (SDS) MWD DATA ARE CONSIDERED PDC. 7. MWD RUNS 1-3,9-11 REPRESENT WELL 1J-115 L1PB2 WITH API#: 50-029-23320-75. THIS WELL REACHED A TOTAL DEPTH (TD) OF 8650'MD/3687'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.......07/02/22 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 • i FILE SUMMARY PBU TOOL CODE START DEPTH STOP DEPTH GR 2993.5 8585.0 RPM 2995.0 8592.0 RPS 2995.0 8592.0 FET 2995.0 8592.0 RPD 2995.0 8592.0 RPX 2995.0 8592.0 ROP 3040.5 8650.0 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 3 2993.5 9 6529.5 10 6559.0 11 7155.5 REMARKS: MERGED MAIN PASS. MERGE BASE 6529.0 6559.0 7155.0 8650.0 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 .lIN Max frames per record .............Undefined Absent value ......................-999 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 RPD MWD OHMM 4 1 68 4 2 RPM MWD OHMM 4 1 68 8 3 RPS MWD OHMM 4 1 68 12 4 RPX MWD OHMM 4 1 68 16 5 FET MWD HOUR 4 1 68 20 6 GR MWD API 4 1 68 24 7 ROP MWD FT/H 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 2993.5 8650 5821.75 11314 2993.5 8650 RPD MWD OHMM 1.9 2000 35.4202 11195 2995 8592 RPM MWD OHMM 1.48 2000 30.428 11195 2995 8592 RPS MWD OHMM 0.2 950.71 29.39 11195 2995 8592 RPX MWD OHMM 0.9 1996.15 29.8791 11195 2995 8592 FET MWD HOUR 0.17 497.22 1.32456 11195 2995 8592 GR MWD API 24.09 122.12 66.6039 11184 2993.5 8585 ROP MWD FT/H 0.92 750.7 183.394 11220 3040.5 8650 First Reading For Entire File..........2993.5 Last Reading For Entire File...........8650 i • File Trailer Service name .............STSLIB.001 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......07/02/22 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.......07/02/22 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 6529.0 RPM 2995.0 6529.0 RPD 2995.0 6529.0 RPX 2995.0 6529.0 FET 2995.0 6529.0 RPS 2995.0 6529.0 ROP 3040.5 6529.0 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) 6529.0 TOP LOG INTERVAL (FT) 3040.0 BOTTOM LOG INTERVAL (FT) 6529.0 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 ......... .....Undefine d Frame Spacing ................ .....60 .lIN Max frames per record ........ .....Undefine d 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 6529 4761.25 7072 2993.5 6529 RPD MWD030 OHMM 1.9 2000 18.4911 7069 2995 6529 RPM MWD030 OHMM 1.48 1651.33 15.1103 7069 2995 6529 RPS MWD030 OHMM 0.2 83.19 13.4777 7069 2995 6529 RPX MWD030 OHMM 0.9 76.8 12.7778 7069 2995 6529 FET MWD030 HOUR 0.17 56.28 1.03322 7069 2995 6529 GR MWD030 API 24.09 122.12 67.7374 7072 2993.5 6529 ROP MWD030 FT/H 9.61 636.55 204.819 6978 3040.5 6529 First Reading For Entire File..........2993.5 Last Reading For Entire File...........6529 File Trailer Service name .............STSLIB.002 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......07/02/22 Maximum Physical Record..65535 • i 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.......07/02/22 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: 9 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH ROP 6529.5 6559.0 LOG HEADER DATA DATE LOGGED: 27-OCT-06 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 72.13 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT) 6559.0 TOP LOG INTERVAL (FT) 6529.0 BOTTOM LOG INTERVAL (FT) 6559.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: .0 MAXIMUM ANGLE: .0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) 6.750 DRILLER'S CASING DEPTH (FT) 6529.0 BOREHOLE CONDITIONS MUD TYPE: Mineral Oil Base MUD DENSITY (LB/G) 8.80 MUD VISCOSITY (S) 62.0 MUD PH: .0 MUD CHLORIDES (PPM): 122000 FLUID LOSS (C3) 2.6 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT) .000 .0 MUD AT MAX CIRCULATING TERMPERATURE: .000 90.0 MUD FILTRATE AT MT: .000 .0 MUD CAKE AT MT: .000 .0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format Specification Record Data Record Type ..................0 Data Specification Block Type.....0 Logging Direction .................Down Optical log depth units...........Feet Data Reference Point ..............Undefined Frame Spacing .....................60 .lIN Max frames per record .............Undefined Absent value ......................-999 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD090 FT/H 4 1 68 4 2 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 6529.5 6559 6544.25 60 6529.5 6559 ROP MWD090 FT/H 1.43 48.02 19.9982 60 6529.5 6559 First Reading For Entire File..........6529.5 Last Reading For Entire File...........6559 File Trailer Service name .............STSLIB.003 Service Sub Level Name... Version Number..... ....1.0.0 Date of Generation.......07/02/22 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.......07/02/22 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: 10 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 6529.5 7155.0 FET 6529.5 7155.0 RPX 6529.5 7155.0 RPD 6529.5 7155.0 RPS 6529.5 7155.0 RPM 6529.5 7155.0 ROP 6559.5 7155.0 LO G HEADER DATA DATE LOGGED: 29-OCT- 06 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 72.13 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT) 7155.0 TOP LOG INTERVAL (FT) 6559.0 BOTTOM LOG INTERVAL (FT) 7155.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 82.8 MAXIMUM ANGLE: 93.4 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 151107 EWR4 Electromag Resis. 4 156404 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) 6.750 DRILLER'S CASING DEPTH (FT) 6529.0 BOREHOLE CONDITIONS MUD TYPE: Mineral Oil Base MUD DENSITY (LB/G) 8.80 MUD VISCOSITY (S) 63.0 MUD PH: .0 MUD CHLORIDES (PPM): 22500 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 .lIN Max frames per record .............Undefined Absent value ......................-999 Depth Units ....................... Datum Specification Block sub-type...0 + • Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 RPD MWD100 OHMM 4 1 68 4 2 RPM MWD100 OHMM 4 1 68 8 3 RPS MWD100 OHMM 4 1 68 12 4 RPX MWD100 OHMM 4 1 68 16 5 FET MWD100 HOUR 4 1 68 20 6 GR MWD100 API 4 1 68 24 7 ROP MWD100 FT/H 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 6529.5 7155 6842.25 1252 6529.5 7155 RPD MWD100 OHMM 12.19 2000 84.7254 1252 6529.5 7155 RPM MWD100 OHMM 10.62 2000 73.2908 1252 6529.5 7155 RPS MWD100 OHMM 10.06 950.71 67.704 1252 6529.5 7155 RPX MWD100 OHMM 6.34 1996.15 79.0369 1252 6529.5 7155 FET MWD100 HOUR 0.31 497.22 3.39347 1252 6529.5 7155 GR MWD100 API 38.73 116.28 62.2147 1252 6529.5 7155 ROP MWD100 FT/H 0.92 750.7 193.978 1192 6559.5 7155 First Reading For Entire File..........6529.5 Last Reading For Entire File...........7155 File Trailer Service name .............STSLIB.004 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......07/02/22 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.......07/02/22 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: 11 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH RPX 7155.5 8592.0 ROP 7155.5 8650.0 RPD 7155.5 8592.0 GR 7155.5 8585.0 RPM 7155.5 8592.0 FET 7155.5 8592.0 RPS 7155.5 8592.0 • • LO G HEADER DATA DATE LOGGED: 30-OCT- 06 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 72.13 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT) 8650.0 TOP LOG INTERVAL (FT) 7155.0 BOTTOM LOG INTERVAL (FT) 8650.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 84.4 MAXIMUM ANGLE: 91.5 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 151107 EWR4 Electromag Resis. 4 156404 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) 6.750 DRILLER'S CASING DEPTH (FT) 6529.0 BOREHOLE CONDITIONS MUD TYPE: Mineral Oil Base MUD DENSITY (LB/G) 8.80 MUD VISCOSITY (S) 63.0 MUD PH: .0 MUD CHLORIDES (PPM): 22500 FLUID LOSS (C3) 4.0 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT) .000 .0 MUD AT MAX CIRCULATING TERMPERATURE: .000 118.0 MUD FILTRATE AT MT: .000 .0 MUD CAKE AT MT: .000 .0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format Specification Record Data Record Type ..................0 Data Specification Block Type.....0 Logging Direction .................Down Optical log depth units...........Feet Data Reference Point ..............Undefined Frame Spacing .....................60 .lIN Max frames per record .............Undefined Absent value ......................-999 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 RPD MWD110 OHMM 4 1 68 4 2 RPM MWD110 OHMM 4 1 68 8 3 RPS MWD110 OHMM 4 1 68 12 4 RPX MWD110 OHMM 4 1 68 16 5 FET MWD110 HOUR 4 1 68 20 6 ~~ - • GR MWD110 API 4 1 68 24 7 ROP MWD110 FT/H 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 7155.5 8650 7902.75 2990 7155.5 8650 RPD MWD110 OHMM 25.77 113.98 55.5809 2874 7155.5 8592 RPM MWD110 OHMM 21.78 107.07 49.4316 2874 7155.5 8592 RPS MWD110 OHMM 19.93 147.56 51.8376 2874 7155.5 8592 RPX MWD110 OHMM 17.61 165.08 50.5275 2874 7155.5 8592 FET MWD110 HOUR 0.39 12.37 1.13986 2874 7155.5 8592 GR MWD110 API 39.1 87.84 65.7228 2860 7155.5 8585 ROP MWD110 FT/H 4.06 310.33 132.453 2990 7155.5 8650 First Reading For Entire File..........7155.5 Last Reading For Entire File...........8650 File Trailer Service name .............STSLIB.005 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......07/02/22 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.006 Physical EOF Tape Trailer Service name .............LISTPE Date .....................07/02/22 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 .....................07/02/22 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
