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206-124
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 14000'feet None feet true vertical 3705' feet None feet Effective Depth measured 14000'feet 5962'feet true vertical 3705' feet 3521'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 N/A 3521' 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 D-Sand Liner 7467' 7680' Casing 3808' 4-1/2" 7493' 13985' 3704' 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 206-124 50-029-23320-61-00 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-115L2 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 SSSV: None Will Parker will.parker@conocophillips.com (907) 265-6239Senior Production Engineer Alternating Slotted Pipe: 1631-12104', 12190-13874' Alternating Slotted Pipe: 3647-3649', 3650-3700' 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 9:19 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 DEC 3 0 REPORT OF SUNDRY WELL OPERATIONS Zp19 1. Operations Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Pull Tubing ❑iL�tdown E]Performed: Suspend ❑ Perforate E] Other Stimulate E] Alter Casing E]h e J r ogram ❑ Plug for Redrill ❑ Perforate New Pool ❑ Repair Well ❑ Re-enter Susp Well ❑ Convert ESP to GL ❑� 2. Operator 4. Well Class Before Work: 5. Permit to Drill Number: Name: ConocoPhllllps Alaska, Inc. Development EfVf✓ Exploratory ❑ 206-124 Stratigraphic ❑ Service 3. Address: P. O. Box 100360, Anchorage, Alaska 6. API Number: 99510 1/7-1' 50-029-23320-61 7. Property Designation (Lease Number): 8. Well Name and Number: KRU 1J-115L2 ADL 25650 25661 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): N/A 10. Field/Pool(s): Ku aruk River Field / West Salk Oil Pool 11. Present Well Condition Summary: Total Depth measured 13,985 feet Plugs measured none feet true vertical 3,705 feet Junk measured none feel Effective Depth measured 13,874 feet Packer measured 5094, 6198, 6652 feet true vertical 3,700 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 7,680' 4.5" 13,985' 3,705' Perforations: Horizontal slotted liner Measured depth: 11,631'-13,874' feet True Vertical depth: 3,647'-3,700' 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-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: Shut-In 0 0 650 150 Subsequent to operation: 1 589 533 1598 885 1 200 14. Attachments (required per 20 AAC 25.070, 25.071, s 25.283) 15. Well Class after work: F1 Daily Report of Well Operations ❑� Exploratory ❑ Development Service Stratigraphic ❑ 16. Well Status after work: Oil Q Gas ❑ WDSPL ❑ Copies of Logs and Surveys Run ❑ Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP ❑ SPLUG ❑ 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: N/A Contact Name: Sydney Autry Sydney Aut Authorized Name: y y �' Contact Email: sydney.autry@cop.com Authorized Title: Senior Petroleum Engineer Contact Phone: 907-265-6813 Date: � Z� �l1 Authorized Signature: J VTL 3/4E/aa A 7/Yl�azo L1,"F� �g�j�$'"`"DEC 3 12019 Form 10-404 Revised 4/2017 Submit Original Only c. ily/ 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 U-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-1151-2 DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary 11/23/19 Attempt to BOL 1J-115 ESP unsuccessfully 11/25/191 Confirm ESP motor is bad, progress plans to convert to backup gas lift. 11/26/19 Dump packer vent valves, lockout on surface 12/011191 Pull Slipsto /Packoff/ESP 12/04/19 1 Complete circ out of IA (plug set 1213/19), Perform CMIT - PASS to 2500 psi 12/06/191 Install Gas Lift Design, Obtain MITT & IA DDT 12/07/19 BOL 1J-115 to gas lift production 12/14119 Troubleshoot high control line pressure - determined to be thermal (liquid packed) 12118/191 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: m reaq@alaska.pov: AOGCC Inspect0rs(aaIaSka.Qo_w phoebe brooks(rAalaska.cov chris wallace(dalaska.aov OPERATOR: FIELD I UNIT/ PAD: DATE: OPERATOR REP: AOGCC REP: ConowPhillips Alaska Inc Kuparuk / KRU / 1J Pad Justin Fanfold Well 1J-115 Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. O= Other (describe in Notes) PTD 2190940 Type Inj N Tubing 0 2490 2390 2350 Type Test P Packer TVD 3180 BBL Pump 2.5 IA 0 2500 2420 2390 Interval O Test psi 1500 BBL Return 2.3 OA 0 20 20 20 Result P Notes: Diagnostic CMIT for conversion from ESP to Gaslifted production Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD I 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 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: TYPE INJ Codes W = Water G=Gas S = Slurry I = Industrial Wastewater N = Not Injecting Forrn 10426 (Revised 01/2017) MIT KRU U-115 diagnostic CMIT TxIA 12-04-09.xlsx INTERVAL Codes Result Codes TYPE TEST Codes P=Pressure Test 1=Initial Test P=Pass O= Other (describe in Notes) 4=Four Year Cyde F=Fail V = Required by Vanarm 1= Inconclusive O = Other (describe in notes) Forrn 10426 (Revised 01/2017) MIT KRU U-115 diagnostic CMIT TxIA 12-04-09.xlsx ,II KUP PROD WELLNAME 1J•115 WELLBORE 1J-115 C0rj0C6phI"jpS IVaska.InO Well Attributes Max Angle 8 MD TD Flew Name Wextlon APuuWI Wellhae sills and fl MDr..) 92.39 13.04 70 AH ESP U(B) 131Y20.0 COmmM1 N31(pp n Dale Annnldtlpl EM Deb KB -0:E jIP SSSV NONE Les1W0 9162017 3220 RIB Rtlease Doh 11262006 Mime ltl.mis. a-115, D babano 110421 PM Last Tag v.nouClammlc(anw0 Announn, amme(eKe) o.Unb wenlwre an bM Dy XFNGER: ZL3- MI LORI R. Y Ums.n RURFALE SE0,s0ObO_ Gnni I sm.D Gas UPT EM PACKER: S.tms.n GRIJ1.s2I0.x GALUE. 5,349.0 DO ESP hosen sasaa ma Times. saaa.o Lover Tandem: 5,4)0.8 EBP M.mna.mr MOTUNUAIGE:5 a., b neems:6 9L0 7 e ua.. LEM: ones .Da.704a e LINER RR, aSEo.Ba,rs7.T UUNE KR. s.X _E7W.T { SLOTS. 1.2M 01.0. B- I NMRMERUTE.Wfi TAAP sLois: z7asoslno-' - _ - - SLOTS a,a92Dn110.0�- - _ - SLOTS. 12157 OIXAs.o�_ _ - SLOTS:13]190,a390.0� sLois: L3,501&ILX64.O� - ASAND LINER: a Y10 37C80 Last Tag limosabop Last Rev Reason mllw� Ertl Dale LasI Mo49y Rev Reable Pulled ESP.Packo6. SAPSAPBSOV, CIOGes Lifl eal,sHe iJ-015e jbareen8 Casing Strings [rima DasnnpxM oD an1 to llni TaP 1abi sce PaPa(.Kai sdoepiX IT'D).. WULM n.. areae roprleaa CONDUCTOR 20 19.12 30.0 108.11 108.0 94.00 KSS WELDED LaYnp DeaW ptlM OD lln) ID lln TaPIXKBI Bal otpN (ryl(BI AloapN (NDt... WIILen (I... Gratle SURFACE 103/4 9.95 26.0 3.p08.0 2,214.9 45.50 L-80 ;1, Top Tl♦W OTC IOU Caaing Deic PtlT OP llnl lD llnl Tap (RK8) Ses paptll lryKID Bat 0np11r II... OR ThpTIIrW INTERMEDIATE J5/8 6.87 i63 ].4930 3,0438.4 29.]0 L-80 BTCM Cadnp..6 p.. loans) ID Ore Tap(nKB) belIabei...) .1 PROD FLUN., WDLan g. I Gra. TapTM1rYtl B LINER LEM 412 3.86 61198.0 5704.9 3,680.9 12.W LBO 1BT SCC Liner Details TUP(nke, TopLI TOPlnclr) em De: com RombalD on, 6.198.o 3,5739 81.03 PACKER 75&DR Stl2' ZXP linenoPPENOLr 4.9]0 6,2170 3.5769 W87 SBR Casing Sam Bore Recepwa, 6>50 6,236] 3,580.0 8058 XO BUSHING Crass Over BUSNng 3980 6.520.3 3,638.1 7547 HANGER LEM(above book ImMerl 3686 6,530.9 3,fi406 7626 HANGER LEM(inside Look banged 36M GAQ&C 36639 7647 NIPPLE DBS Nipple 3.563 6.6584 3.6712 77.38 BENT JT Bent Joim 3.8W 3,fi80.3 78.36 SEAL ASSY Seal assmoaly 3860 6aslnBDescrlp.n ODII) ID (ln) TISonop lnKa) Bet OepN (1VP)... Wr/bn p... GrMe ALINER HH 412 4.00 6,5309 67977 3.698) tt 60 L8o Tap Tlretl BTC Liner Details TOPmKa) ioplTVD)l�ne) TOPmn I°) uem Des Com omnia ID onI 5.53019 3.640.6 76 HANGER Hook Hinew below window) 5.610 6.608.9 3:6598 75.98 ECP Ektemal Casing Packer 3.900 6.767.6 3,fi93.0 7911 UINI JT Beljoint raueshOm 3.960 Caslna Descrl.Y ODgn) ID MI TW (mase Sm.."'mea SNOPMane'd. VNIen (1._GraUP TopTR7. DLINER HH 4112 3.48 8.633.2 6]97.] 3.6987 1160 L-80 BTCM Liner Details rop ll6 Toplry lopin.l") Pan Deb a ID oUnl 8.533. 3,6411 7821 HANGER BAKER MODEL PZ HOOK HANGER (INSIDE CSG) 3.959 IPS.) 6,550.0 3,6452 75W HAN ER BAKER MODEL PZ HOOK HANGER (OUTSIDE CSG) 3.950 6.507.1 3,659 7593 ECP BAKER PZ EXTERNAL CASING PACKER 3.900 5769.4. 36934 7912 BENT JT 3.960 Caslnp De ;t; A -SAND LINER OOPn) 410 0iR 348 Top(KKBI G,fi52.p bel OepIIDKIR 13.7p6.01160 Sal CepN ONO)...velum (1.. Gl. 1-80 Top Tlrreal Confess Cafes Liner Details iop (ran, TOP (ND)INKB) Top Incl l° rem Des Com inemIn) lP Ila) 6652.0 3.6698 iJ2o PACKER BKER HROZXPLINER TOP PACKER 5.500 ,6]1.0 36]4.0 ]7] NIPPLE 'RS' RACKOFF SEAL NIPPLE 4.8]0 Qfi73.9 3.6]4.6 A. HANGER FLEXIOCK LINER HANGER 4.850 6,6838 3,676.6 7804 SBE 19047 SEAL BORE EXTENSION Tubing Strings TUE1nB 0escrlptlY bMnp MP.. III TW IKKBI Set DepN (n. SeI D¢pM INO)I... wV ("m GraOe Tap ConneatlM TUBING 412 3.96 1'1.3 5.4939 3352.8 12.60 660 TXPM Completion Details TOPmol TOWN Deb TOPlne9l RKPI flm MI Nlm) er. VebcaGrsy MB22M offso LI &4 X41f2vakine 3.900 22.3 223 DOG HANGER TT�rgHangD 5094. 317 6 63.62 PACKER ViSONVentndPacker SIN VCT -10-177352 3.902 5 ND 3,30].9 64.59 GAUGE WiHLFftDiAGUuge Una, Cenld6X 3.958 5,4534 3,3355 64.63 ESP Intake TTCDrilled Crossover, Ceneaift 5,464.0 334 0 64; Upper Tandem UPPa Tandem Seal Senior, Cadone 5,00.8 3,3430 64.66 Lower Tandem Loud Terbem Seal BELL., Cenuililt 54777 3.3459 611.6 ESP MOIMS ESP Moto,. Contain. 175HP61 WVI34A 5490.1 8.3512 61.69 MOTOR GAUGE WEILIX E Maor GaURe Unit CoatoNX 5.492.0 3.352.0 64. Centralizer MIXor CSMratizer, Centr9iX Perforations 8 Slots nPIKKBI T7, -pan) almlTee, FornbR n TInKa) Buse, UPD. Zme Dens DM 1iomen, Dale 1 Type WELL 0 ],6140 3,777.7 3. 7.3 A2, 1j-1 1p12612006 32.0 SLOTS ALL PERFS IN AXereaung sadien"Ad Dan -0125"x25'@4 CNindon. aialsoRmannl mess, 3- centers slaggai 18 ad,, 3non-slotted ends ], 0 , 3.8.8 3822.7 8 12].0 20 WSP2.1J-115 10/26/2008 32.0 SLOTS 8.3820 117]00 3,8206 38420 WS P2, 1J-115 10126/2006 32.0 SLOT3 12,1570 12,546.0 3,6643 3.8887 WSA21J-n5 10262006 32.0 SLOTS 12,]19.0 13,360.0 3,893.fi 3.9W.3 WS A2, 1J-115 ID/2fi/200 32.0 SL T 13.533.0 11,664.0 3,905.1 3.907.6 WSA2 1J-115 1012612006 I 320 SLOTS COIIOCc;P11llIjX(611� KUP PROD WELLNAME IJ -115 WELLBORE 1J-115 aeska.lnC. MUXple Lelerels, IJ115, 1]R](A191$d31 PM Mandrel Inserts VerM1alaelwnatic laeVxll SL atl .ER, on N +V InKL,M01 TopIN01 001121 6ery Va Ne Type LaWn Type PON Size TRO Run 0-) (p81) Run GA. Conn 1 3,344.3 2.375.9 lcnm6Ge KBMG 4112 GAS LIFT GLV &( 0.188 L4J5.0 IM019 2 5.022.8 3,14}.8 Cfimco KBMG 41 GAS LIFT OV &( 0.313 0012/012019 3 5,2002 3.2266'.. KBMG 4112 GAS UFT DMY BK 0000 OA 12/42019 Notes: General & Safety . srsnon No*e wo CONDUCTOR', 30.6103.0 4I 4 9 1 NDTE: U $[11NR0(K W1A85k0 $UP(IIMiC9.0 1112112006 NOTE. MULTI -LATERAL WELL IJ-115(ASAND), II-115LI (8 -SAND). 11-1151-210SAN0) 6URGACE 1d,G3W3.0� GASU,T,3.3 3 cAs uXT.50ua AAGNER: SCYi.O GAS UE 5SJG2 WGE 51%0 ESPunAA.54S14 P prTerEem; $969.0 .Tencem, ESPeblen',54]]] uOTGRGAUGE',SLW.1 Cenrelmr. S.YA.O 0 LINED LEM fi.1lV.O6.]M.9 tl LI NER M1. 5591983]] O LINER NY', 6,MMM .] I SLOTS',],14.6]619011 ' NTER.EOIATE, 26.6? 9RG.0— SLOT6:]]93.DAIP.O� SLOTS ;B.611770 — SLOTS ,1$167G12,516.0— SLOTS 12]18013.3®.0—_ 6LOTS 13533613841.0�� I� ISANO..ER 6.852.6 11 13]INO KUP PROD WELLNAME 1.1115 WELLBORE 1J -115L2 ConocoMillips Well rtes Max Angle 8 MD 7D NaSka.lnc. me FItlJ Name W 12'APWW1 VhJWose Ohlus 93 4 MOIN(BI Avt OM RW.B1 9334 6.5840fi 14,000.0 CwnmeM XaalpOml pale AnMldtlon EMI Oab NBG141R1 Rle Release Dab SSSV NONELag W0. 32.20 11/2&2008 evtry teev, N.II5I1. Ia2TSO1012c� m PM Last Tag ver4mxMmdmlecln.X Annohim peominRB1 End Date wmlWre LaE Bob ey Lag Tag 11,11 .i IITOSOOI Last Rev Reason XPXGER'.II3— Annolailonnd Date WeIIMre Last MoO By Rev Reason NOW ESP. Packp%. Slip SwP 8 SOV, CIO Gas Lift 12/1/2(119 iJ-11 OL pp'.v, Casing Strings easmp Dezcnpnnn OD nnl D-9AN0 LINER 4V2 IO nnl Ta Mon semepm mXBl set Moo RV 1L n'tlLen a.. wade IDp1Mw0 34B 6,305.3 1.1,985.0 3.1045 1160 L-80 BTCM Liner Details rop nMel I Tdolrvg lnMe) p S Top mn p sem com Xn On 6.305.3 3,5926 82.045LEIvE BAKER'HR' SETTING SLEEVE 5000 6,326.2 .1595.3 8288 I 56R RECEPTACLE JOINT 4.900 6.361.1 3. 83.62 WI3USHING ROSSOVERBUSMING 3.939 Perforations & Slots DN- CANDucrOR; 3]oJOIR iop(nxal Blm lnxel mpm0) InxBl Blm(NO) Ina61 xm zone a.. 1 type 11,631.0 12,104.0 3,642.0 3,6%,2 WB DI IJ -115L2 1V92006 2 32.0 SLOTS ALL PERFS IN WELI Alternating SOIINskneU p,,e -0125-v2 F @4 XTLMIerBntialad'.] rows.3 cemels gaggeee6 18 deg. 3'..,O!WtOd eras 12,190.0 13,8760 649.9 3,)00.2 WSD.1}115L2 11192006 32.0 SLOTS ALL PERFS IN WELL. ABelnaang soliSej,RO pipe -0125'X 5-@4 MCOmleremial aQacem rows, 3".MerS SR'., epi 18 Beg. 3'nwu,I tad enCS SURFACE W S3.A9.0— Notes: General 8 Safety moon GAs uFf D3u3 404QOII NOTE 'VeveS OTSS w/AlaSka SCROTWIc9.a 11/27 O6 NOTE: VM I 1-ATERAL VvLL 1J-115 (A -SAND). 1J -115L1 6 -SAND), 1J -115L2 (D3 ND GAG LIFT.50Y[.B PACKER BOLO W6LIFT: S.Zil.2 WESea ESV 4s W; 50.531 UpevT Mem',Si C .e Tamem;$,.Me ESP L•gon; SLTT.T MOTOR DAUO E: S.J:TI.1 CeMN_: Ss420 ' MTERMEDIATE:2n1T.490—J SLOTS. 11631012 1W.p SLOTS: 12.150.613.0240 — I P6WOLIXER:13. ` 1350 . . _ • STATE OF ALASKA • „RECEIVED ALASKA OIL AND GAS CONSERVATION COMMISSION FEB 0 1 2016 REPORT OF SUNDRY WELL OPERATIONS ICC 1.Operations Abandon r Plug Perforations r Fracture Stimulate r Pull Tubing r ' pe atioris shutdown r Performed: Suspend r Perforate r Other Stimulate r Alter Casing r Change Approved Program r Plug for Redrill r Perforate New Pool r Repair Well r Re-enter Susp Well r Other: ESP to GL f 2.Operator Name: 4.Well Class Before Work: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development Exploratory r 206-124 3.Address: 6.API Number: Stratigraphic r Service r P. O. Box 100360,Anchorage,Alaska 99510 50-029-23320-61 7. Property Designation(Lease Number): 8.Well Name and Number: ADL 25661,25650 WSAK 1J-115L2 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 14000 feet Plugs(measured) None true vertical 3705 feet Junk(measured) None Effective Depth measured 13985 feet Packer(measured) 0 true vertical 3704 feet (true vertical) 0 Casing Length Size MD TVD Burst Collapse D-SAND LINER 7680 4.5 13985 3704' $CAN NEV t,'n , 1:` Perforation depth: Measured depth: 11631-12104, 12190-13874 True Vertical Depth: 3647-3651, 3650-3700 Tubing(size,grade,MD,and TVD) 4.5, L-80, 5511 MD, 3360 TVD Packers&SSSV(type,MD, and ND) NONE-Type Not Found (Manual Entry Required) @ 0 MD and 0 TVD 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 r Exploratory r Development r Service r Stratigraphic r Copies of Logs and Surveys Run r16.Well Status after work: Oil r Gas r WDSPL r Printed and Electronic Fracture Stimulation Data r GSTOR r WINJ r 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 Signature11II Phone:659-7535 Date 4^ -V� / • 29 • /!,o Form 10-404 Revised 5/2015 VT` 2-1t4!!Je RBDMS Lt- FEB 0 1 2016 Submit Original Only 4v.l,41 . - • 1J-115L2 • 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. ',, KUP 1J-115L2 ConoccPhillipS •D. Well attributes Max Angle&non TD AlaskaIno Wellbore API/UWI Field Name Well Status Incl(°) MD(BOB) Act Btm(BOB) 500292332061 WEST SAK PROD 93.34 6,584.06 14,000.0 Comment H2S(ppm) Date Annotation End Date KB-Ord(ft) Rig Release Date •• Wen Corns Multiple Laterals-1J-115L2,5/720131:32:06 PM _�SSSV:NONE 0 8/14/2012 Last WO: 32.20 11/28/2006 Schematic-Actual Annotation Depth MOB) End Date Annotation Last Mod By End Date Last Tag: Rev Reason:WELL REVIEW o_sborl 5/7/2013 Casing Strings Casing Description String O.. String (ft(B) Set Depth(1...Set Depth(TVD)... String Wt...String... String Top Thrd D-SAND LINER 4 1/2 3.476 6,305.3 13,985.0 3,704.5 11.60 L-80 BTCM ) Liner Details Top Depth (TVD) Top Incl Nomi... Top(ftKB) OMB) (°) Item Description Comment ID(In) I 6,305.3 3,592.6 82.04 SLEEVE BAKER'HR'SETTING SLEEVE 5.000 t. 6,325.2 3,595.3 82.38 SBR RECEPTACLE JOINT 4.900 HANGER.22 6,361.1 3,598.6 83.05 XO BUSHING CROSSOVER BUSHING 3.930 Perforations g ei sd =. Shot Top(TVD) Btm(TVD) Dens Top(ftKB)Btm(RKB) (RKB) (ftKB) Zone Date (sh•-• Type Comment 11,631.0 12,104.0 3,647.0 3,651.0 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" all centers staggered 18 deg,3' non-slotted ends IR CONDUCTOR, 12,190.0 13,874.0 3,650.01 3,7002 WS D,1J-115L2 11/5/2006 32.0 SLOTS ALL PERFS IN WELL:Alternating 30408 solid/slotted pipe-0.125"x2.5"@4 circumferential adjacent rows,3" centers staggered 18 deg,3' non-slotted ends Notes:General&Safety , End Date Annotation 3 11/27/2006 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 SURFACE. 26-3009 II I ESP MANDREL. j' 3,415 ESP . . • MANDREL, - moill 4.981 - _... DISCHARGE, 5.372 la lb ar SLIPSTOP. 5.385 PACKOFF. � 5,391 iE at ESP PUMP, 5.400 1.,.I}. INTAKE,5,448 l SEAL,5.459 ( k t MOTOR,5,473 GAUGE.5,506 <GC:U CENTRALIZER. 5509 NTERMEDIATE, 26-7,493 1 .41 li.,'Ilii H SLOTS,_all 1115 11,631-12,104 I SLOTS. 12,19013,874-I , Mandrel Details Top Depth Top Port ■ • S,•, (TVD) Incl OD Valve Latch Size TRO Run I N...Top(8KB) (RKB) (°) Make Model (in) Sery Type Type (in) (psi) Run Date Com... D-SAND 1 3,414.5 2,408.9.61.19 CAMCO KBMG 1 ESP SOV BEK 0.000 0.0 1127/2006 LINER, 6.31X>13.985 2 4,980.5 3,129.0 63.54 CAMCO KBMG 1 ESP DMY BK-5 0.000 0.0 11272006 TD(1J-115L2), 14,000 • Imaci~ Prc~jeet Well hli~fio~y file ~+r~~er Page XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available ire the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. a ~~j- ,~~ ~- Well History File Identifier Organizing (done) RES AN Color Items: ^ Greyscale Items: ^ Poor Quality Originals: ^ Other: NOTES: ~. ,waded iuuiiiiiuiuuii DIGI AL DATA Diskettes, No.3 ^ Other, No/Type: . He,~a~~eecea IIIiIIIIIYIIIIIII OVERSIZED (Scannable) ^ Maps: ^ Other Items Scannable by a Large Scanner OVERSIZED (Non-Scannable) ^ Logs of various kinds: ^ Other:: BY: Maria Date: ` Is/ Project Proofing III IIIIII IIIII II III BY: Maria Date: /s/ Scanning Preparation ~ x 30 = ~ + ~~ =TOTAL PAGES ~ ~- (Count does not include cover sheet) BY: Maria Date: ~ /s/ Production Scanning Stage 1 Page Count from Scanned File: ~~~ (Count does include cover eet) Pa e Count Matches Number in Scannin Pre oration: ~~ YES NO 9 g p BY: Maria Date: /~~ ~ /s/ r ~,! I, i Stage 1 If NO in stage 1, page(s) discrepancies were found: YES NO BY: Maria Date: /s/ Scanning is complete at this point unless rescanning is required. II I II II II I II II I I III ReScanned III II'IIIIIIII VIII BY: Maria Date: /s/ Comments about this file: Quality Checked III II'III III IIII II P 10/6/2005 Well History File Cover Page.doc %~ 1L--c. ?.u-v ~ DATA SUBMITTAL COMPLIANCE REPORT 10/13/2008 Permit to Drill 2061240 Well Name/No. KUPARUK RIV U WSAK 1J-115L2 Operator CONOCOPHILLIPS ALASKA INC MD 14000 TVD 3705 Completion Date 11/28/2006 Completion Status 1-OIL Current Status 1-OIL API No. 50-029-23320-61-00 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 D Asc Directional Survey ~D D Asc Directional Survey ~ED D Asc Directional Survey ~¢t 14509 LIS Verification ,~Rpt 14509 LIS Verification ~ Rpt 14509 LIS Verification ~8' C 15872 Gamma Ray C 15873 Gamma Ray C 15874 Gamma Ray Well Cores/Samples Information: Interval Name Start Stop Samples No Directional S (data taken from Logs Portion of Master Well Data Maint Log Log Run Interval Scale Media No Start Stop OH / CH Received Comments 6905 14000 Open 1/29/2007 6011 6245 Open 1/29/2007 PB 1 6121 7230 Open 1/29/2007 PB 2 2993 14000 Open 3/21/2007 LIS Veri GR, ROP, FET 2993 6245 Open 3/21!2007 PB1 LIS Veri GR, ROP, FET 2993 7230 Open 3/21!2007 PB2 LIS Veri GR, ROP, FET 108 14000 Open 1/31/2008 MD and TVD on ROP, DGR and EWR in PDF, EMF and CGM graphics 108 6245 Open 1/31/2008 PB1 MD and TVD on ROP, DGR and EWR in PDF, EMF and CGM graphics 108 7230 Open 1/31/2008 P62 MD and TVD on ROP, DGR and EWR in PDF, EMF and CGM graphics Sample Set Sent Received Number Comments DATA SUBMITTAL COMPLIANCE REPORT 10/13/2008 Permit to Drill 2061240 Well Name/No. KUPARUK RIV U WSAK 1J-115L2 Operator CONOCOPHILLIPS ALASKA INC MD 14000 TVD 3705 ADDITIONAL INFORMATION Well Cored? Y f~ Chips Received? Y~~ Analysis Y / N Received? Comments: Completion Date 11/28/2006 Completion Status 1-OIL Daily History Received? Formation Tops Current Status 1-OIL ~/ N API No. 50-029-23320-61-00 UIC N Compliance Reviewed By: Date: w 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+PB1+PB2+PB3+PB4+L1+L1PB1+L1PB2+L2+L2PB1+L2PB2: Digital Log Images 1 CD Rom 50-029-23320-00,60,61,70,71,72,73,74,75,76,77 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry Drilling Services Attn: Rob Kalish 6900 A~r Blvd. ~' } "' Anclib Alaska 99518°' Date: ' ~ ~ ~ ~ - ~~' Signed: V ~-raa ~ ts~~~r X73 t ~~5 ~(a5 ~a ~ ~~~~ p c33 ~' 15~ C~~ t~3y ~ l 5 ~~ ao~ -/23 ~` i s ~~4 p~ ~ ~ - s'fs~o P~ 15~'~i • January 18, 2008 ~ot~-t2y ~ 1S`f ~2 ~B 1 ~IS~~3 ~$ 2 '~ 15~ ~ ~- WELL LOG TRANSVITTTAL 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 Ll PB1 L1 PB2 Ll L2 PBl 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 A_ND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry Drilling Services Attn: Rob Kalish 6900 Arctic Blvd. Anchorage, Alaska 99518 r~' .~. ~ t Date: Signed: ~ ,: ,t . _ . a°4;w ConocoPhillips 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 STATE OF ALASKA • ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT ,~,~ ~ ~ ~ 207 a~~~~.Q~ 1a. Well Status: Oil ^ Gas Plugged Abandoned ^ Suspended WAG ^ 20AAC 25.105 20AAC 25.110 GINJ ^ WINJ ^ WDSPL ^ No. of Completions _ Other _ 1b. Well Class: . ~ ° Development ^/ , ' ' ~""' F~t~atory ^ Service ^ Stratigraphic Test ^ 2. Operator Name: GonocoPhillips Alaska, Inc. 5. Date Comp., Susp., or Aband.: November 28, 2006 ~ 12. Permit to Drill Number: 206-124 ~/ 3. Address: P. O. Box 100360, Anchorage, AK 99510-0360 6. Date Spudded: ~~J• ~ tp ' ~GtCyer~2, 2006 t•i~'~' 13. API Number: 50-029-23320-61 ' 4a. Location of Well (Governmental Section): Surface: 1973' FSL, 2380' FEL, Sec. 35, T11N, R10E, UM ~ 7. Date TD Reached: November 18, 2006 14. Well Name and Number: 1J-115L2 At Top Productive Horizon: 2185' FNL, 1138' FWL, Sec. 36, T11 N, R10E, UM 8. KB Elevation (ft): 2g' RKg 15. Field/Pool(s): Kuparuk River Field Total Depth: 369' FSL, 639' FWL, Sec. 24, T11 N, R10E, UM 9. Plug Back Depth (MD + ND): 13985' MD / 3704 ' TVD West Sak Oil Pool 4b. Location of Well (State Base Plane Coordinates): Surface: x- 558830 ' y- 5945785 • Zone- 4 10. Total Depth (MD + ND): 14000' MD / 3705' ND 16. Property Designation: ADL 25661 & 25650 TPI: x- 562337 y- 5946936 Zone- 4 Total Depth: x- 561769 - 5954764 , 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: ~f- W ' (~D~f`t~ /YJD~ 35`S~ `?"/D GR/Res, Dens/Neu ~ /• t'f-+~~ 22. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTH ND 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 6038' 13985' 3552' 3704' 6.75" slotted liner - refer to attachment for details 23. Pertorations open to Production (MD + ND 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 6160' slotted liner from 6539'-13165', 13381'-13939' 25. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED n/a 26. PRODUCTION TEST Date First Production January 29, 2006 Method of Operation (Flowing, gas lift, etc.) ESP Lift Oil Producer -shares production with 1J-115 and 1J-115L1 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 RA7lo 494 Flow Tubing press. 234 psi Casing Pressure not available Calculated 24-Hour Rate -> OIL-BBL 2711 GAS-MCF 1198 WATER-BBL 70 OIL GRAVITY -API (corr) not available 27. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water (attach separate sheet, if necessary). Submit core chips; if none: state "none". ~~-~^°--~ ~CfiiMl£L~~-'Tl17N ~`~' DATE .O NONE VER( !c0 `s: Form 10-407 Revised 12/2003 CONTINUED ON REVERSE ! ~ _'° _ - I~,~ ~~ r~ 28. 29. GEOLOGIC MARKERS FORMATION TESTS NAME MD TVD Include and briefly summarize test results. List intervals tested, and attach detailed supporting data as necessary. If no tests were conducted, state "None". 1J-115L2 Top West Sak D 6095' 3554' Base West Sak D 14000' 3705' 1J-115L2PB1 TD 6245' 3576' N/A 1J-115L2P62 TD 7230' 3597' 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 Nap~e .~ Rand Thomas Title: Greater Kuoaruk Area Drilling Team Leader , > D t 1 ~ ~ ~~ '7 ~~ ~ ~ ~ -~ ~ 1'- a e Signature \. Phone ~, j ~ ! j~ - - - - - 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 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). Item 20: True vertical thickness. Item 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, Other (explain). Item 27: If no cores taken, indicate "none". Item 29: List all test information. If none, state "None". Form 10-407 Revised 12/2003 _ 1J-115'8' Lateral Liner Detail well: 1J-115L2 `~ 4-7/2" S/oited and Blank Liner Dater 11/5/2006 ~t~~t~Ct~~~'11~~~~J5 PLOP & DROP AEaska, Inc, DEPTH Jt Number .; ...~:.~ :.::, ...... Num of Jts ~~ ~, . <>::~- ,.,. COMPLETE DESCRIPTION OF EQUIPMENT RUN Page 1 . ......._ LENGTH TOPS 6735.55 6735.55 6735.55 ~~:;.> :-;>~:.;;. 6735.55 6735.55 6735.55 XO 6735.55 Running Tool (Does not stay in hole) 6.92 6735.55 Baker "H R" Liner Setting Sleeve, 5 1/2" ID 5.01" 12.91 6742.47 5-1/2" New VAM pin x H dril 521 Box XO 4.87" ID 1.17 6755.38 5-1 /2" H521 pin x 5-1/2" H521pin XO 4.90" ID 1.38 6756.55 5 1/2" BTCM, 15.5 ppf, L-80 Pup Jt ID 4.98" 7.65 6757.93 5 1/2" Hydril 521, 15.5 ppf L-80 Receptacle Jt ID 4.97" 35.03 6765.58 5-1/2" H521 x 4-1/2" BTC Crossover Bushing ID 3.96" 1.40 6800.61 4-1/2", 11.6ppf, L-80 BTC Pup Joint ID 3.96" 1.98 6802.01 Jts so to ~s5 106 Jts 4-1/2" BTC, 11.6 ppf, L-80 Slotted Casing 4526.16 6803.99 Jts 53 to 59 7 Jts 4-1/2" BTC, 11.6 ppf, L-80 Blank Casing 301.34 11.330.15 Jts 42 to 52 11 Jts 4-1/2" BTC, 11.6 ppf, L-80 Slotted Casing 472.28 11631.49 Jts 40 to 41 2 Jts 4-1/2" BTC, 11.6 ppf, L-80 Blank Casing 86.09 12103.77 Jts 1 to 3s 39 Jts 4-1/2" BTC, 11.6 ppf, L-80 Slotted Casing 1683.69 12189.86 XO Sub 4 1/2" BTC X 3-1 /2" IBT 1.39 13873.55 XO Sub 3 1/2"-IBT X 3-1/2" EUE 5.92 . .13874.94 3-1/2" BTC, Straight Joint ID 2.602" 31.47 13880.86 Weathertord 3-1/2" Float shoe .59 13912.33 Bottom of guide shoe 13912.92'. 13912.92 Shoe 13,9.1292' MD / 3773' TVD (Rathole 15') 13912.92 TD 6-3/4" hole 13922' MD / 3775' TVD (85.18deg,) 13922.00 Top of Window 6529' MD Bottom of Window 6541' MD Run 1 Hydraform centralizer floating on the bttm half of each joint. Put a stop ring in the middle of the joints. Ran 165 total, 4.5" x 6.375" Hydraform 2-blade cent & 165 stop rings Ran total of 9 jts Blank =. 38T and 156 jts Slotted= 6681' ,Slots are On Btm Up Wt 170K w/ (32) 2.5" long x.125" 4 Circumferential. adjacent rows, 3" Centers Rotating UP Wt 125K staggered 18 deg., 3 ft. non-slotted ends Rot Dn Wt 72K Block Wt 32K Liner & running tool only, up wt 77K, do wt 62K Used Run-N-Seal thread compound on all connections. All drifted w/ 3.875" rabbit. Supervisors: Guy Whitlock/ Dink Heim/Dan Lowe l J L I Time L~ - ---- --- - - Date From 7o Dur S. Deptti E. Depth Phase Code Subcode T COM 11/07/2006 23:15 00:00 _ ___ 0.75 _ 0 _ 0 - COMPZ RPCOM1 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 RPCOR 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 ~~ ~ ~ t~ ~~ t' ti W ('_ ` `v ~ with pup jt for space out then MU ill ~~ ~ ~ anchor and whipstock along with m s rE ~~ ~ 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', (corr MWD 4') RIH and tagged top of B Lat LEM at 6,198', oriented whipstock to 12 deg. left of high side, setting same with top of 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 MOBM 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 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' _ ~~ ~_ ---~---- Page 3 ~t L Z.- ~,a~ Time Logs _ Date From To Dur S. De th E. De th Phase Code Subcode T COM ___ 11/09/2006 02:15 03:45 1.50 4,230 0 PRODS DRILL OTHR P Monitored well-static, POOH from 4,230' standing back DP on drillers side 03:45 05:15 1.50 0 1,220 PRODS DRILL OTHR P RIH with 13 stds of 4" DP installing 1 super slider per jt, (39 total) RIH to 1,220' 05:15 06:00 0.75 1,220 0 PRODS DRILL OTHR P POOH from 1,220' standing back 13 stds of add. DP with super sliders on drillers side (58 total stds w/super sliders in derrick 06:00 08:15 2.25 0 368 PRODS DRILL PULD P MU 6 3/4" BHA # 14 with Geopilot RIH to 368'. MU 6 3/4" Hycalog concretion bit with Geopilot, MWD and LWD tools u loadin same. 08:15 09:15 1.00 368 450 PRODS DRILL DHEQ P RIH with BHA #14 from 368' to 450' and shallow tested MWD tool then broke in seals on Geo ilot. 09:15 11:30 2.25 450 6,062 PRODS DRILL TRIP P RIH from 450' to 6,062' 11:30 12:00 0.50 6,062 6,142 PRODS DRILL REAM P Est circ at 6,062' then washed down thru window at 6,094' to 6,108', cont to wash and ream to btm at 6,142'. PU wt 97K, do wt 65K 12:00 13:30 1.50 6,142 6,245 PRODS DRILL DDRL P Drilled 6 3/4" hole in "D" sand from 6,142' to 6,245' MD/3,573' TVD (103') ADT .89 hrs, 5-9K wob, 60-100 rpm's, 82 spm, 293 gpm at 2,150 psi, off and on btm torque 4-5K ft-Ibs, rot wt 86K, up wt 110K, do wt 67K, clean hole ECD with 8.7 ppg MOBM is 9.6 ppg, ave ECD 9.7 ppg, max gas 63 units, 88.6 hrs on jars. NOTE: Drilled concretion at 6,203' and saw 25 deg. do le at Geo ilot 13:30 14:45 1.25 6,245 6,060 PRODS DRILL CIRC T POOH to 6,060' and circ btms up while evaluating Geopilot tool, attempted to send commands to tool and tool would not take the command, decision was made to POOH, circ hole at 293 mat 2,000 si 14:45 16:30 1.75 6,060 85 PRODS DRILL TRIP T POOH from 6,060' to 85', stood back HWDP, ~ars and NMFDC's 16:30 18:30 2.00 85 0 PRODS DRILL PULD T Downloaded MWD, POOH LD MWD and Geopilot, found Geopilot housing swelled slightly at the electronics housing connection with oil leaking from housin 18:30 20:00 1.50 0 85 PRODS DRILL PULD T MU BHA #15 with back up Geopilot tool and RR Hycalog concretion bit with MWD/LWD RIH to 85' then u loaded the MWD tool. 20:00 20:45 0.75 85 365 PRODS DRILL DHEQ T RIH with HWDP, jars and NMFDC's to 365' then shallow tested MWD and broke in seals on Geo ilot 20:45 22:15 1.50 365 6,062 PRODS DRILL TRIP T RIH with BHA #15 from 365' to 6,062' ~g~ 31 cat ~~ Time Logs --- - Date From To Dur S_ Depth E_ Depth Phase Code Subcode_ T COM 11/09/2006 22:15 23:00 0.75 6,062 6,162 PROD3 DRILL CIRC T Est circ and washed down from 6,062' thru the window to 6,162'. 23:00 00:00 1.00 6,162 6,180 PROD3 DRILL DDRL T Troughing well from 6,162' to 6,180' to low side of hole to sidetrack around concretion. 11/10/2006 00:00 00:30 0.50 6,162 6,180 PROD3 DRILL DDRL T Cont to troughing hole from 6,162' to 6,180' 00:30 02:45 2.25 6,180 6,187 PROD3 DRILL DDRL T Time drilled to lowside hole from 6,180' to 6,187', time drilled at 3'/hr, ADT 2 hrs. 02:45 06:45 4.00 6,187 6,245 PROD3 DRILL DDRL T Cont to lowside hole from 6,187' to 6,245', ADT 2.08 hrs 06:45 12:00 5.25 6,245 6,619 PROD3 DRILL DDRL P Drilled 6 3/4" hole in "D" sand lateral with geopilot from 6,245' to 6,619' MD/ 3,598' ND (374') ADT 3.82 hrs, 8-11 K wob, 70-90 rpm's, 80 spm, 284 gpm, 2,050 psi, torque on and off btm 5K ft-Ibs, rot wt 84K, up wt 110K, do wt 64K, max gas 65 units, 8.75 ppg MOBM, ave ECD 9.8 12:00 21:00 9.00 6,619 7,230 PROD3 DRILL DDRL P Drilled 6 3/4" hole in "D" sand lateral with geopilot from 6,619' to 7,230' MD/ 3,597' ND (611') ADT 6.17 hrs, 4-10K wob, 120 rpm's, 87 spm, 309 gpm, 2,350 psi, torque on and off btm 5K ft-Ibs, rot wt 85K, up wt 110K, do wt 67K, ave BGG 65 units, max gas 125 units, 8.75 ppg MOBM, ave ECD 9.85 ppg. Hole began walking right 3-4 deg/100' and would go out of target, decision was made to pull back and sidetrack well. NOTE: Drilled thru several concretions 21:00 21:30 0.50 7,230 6,902 PROD3 DRILL TRIP NP POOH from 7,230' to 6,902' 21:30 23:00 1.50 6,902 6,930 PROD3 DRILL DDRL NP Troughed well from 6,902' to 6,930' 23:00 00:00 1.00 6,930 6,931 PROD3 DRILL DDRL NP Began to time drill well for sidetracking, drilled from 6,930' to 6,931' MD/3,593' ND, ADT .5 hr. 11/11/2006 00:00 01:00 1.00 6,931 6,935 PROD3 DRILL DDRL NP Cont to time drill for sidetracking well from 6,931' to 6,935', ADT 1 hr 01:00 06:45 5.75 6,935 7,230 PROD3 DRILL DDRL NP Drilled 6 3/4" hole from 6,935' to 7,230' MD/ 3,595' ND, ADT 5.9 hrs, drilled thru several concretions, (7,230' was on .hole de th riot to sidetrack ~~ 32 of 4 'Time Logs _ i Date From To D~ir S. De th E. Depth Phase Cade Subcode T COM 11/11/2006 06:45 ~ 10:45 _ 4.00 7,230 7,540 PROD3 DRILL DDRL ___ P _ _ __ Directionally drilled 6 3/4" hole with geopilot from 7,230' to 7,540' MD/ 3,600' TVD (310'), ADT 1.8 hrs, 5-8K wob, 110 rpm's, 80 spm, 285 gpm, 2,100 psi, on/off btm torque 5K ft-Ibs, rot wt 81 K, up wt 110K, do wt 60K, 8.7 ppg MOBM, ave ECD 9.9 ppg, ave BGG 40 units, max gas 210 units, still unable to overcome right hand turn with geopilot after sidetracking well. Decison was made to POOH and RIH with motor assembl 10:45 13:30 2.75 7,540 6,062 PROD3 DRILL REAM T Backreamed out of hole from 7,540' to 6,249', then pumped out of hole thru window to 6,062', BROOH at 100 rpm's, 270 gpm at 1,850 psi. no roblems BROOH. 13:30 13:45 0.25 6,062 6,062 PROD3 DRILL OWFF T Monitored well-static, pumped dry job 13:45 16:00 2.25 6,062 92 PROD3 DRILL TRIP T POOH from 6,062' to 92', stood back HWDP, 'ars and NMFDC's 16:00 18:15 2.25 92 0 PROD3 DRILL PULD T Downloaded MWD then POOH LD eo ilot and bit, cleared ri floor. 18:15 20:15 2.00 0 90 PROD3 DRILL PULD T MU BHA #16 with new Hycalog concretion bit on a 1.5 deg. bend motor and MWD/LWD RIH to 90' then u loaded MWD 20:15 21:45 1.50 90 1,227 PROD3 DRILL TRIP T RIH from 90' to 1,134', then shallow tested MWD at 270 gpm, 1,600 psi, MU Andergauge Agitator and shock tool RIH to 1,227', checked pressure and at 270 gpm had 1,900 psi (300 psi increase from A itator tool . 21:45 00:00 2.25 1,227 6,082 PROD3 DRILL TRIP T RIH from 1,227' to 6,082' 11/12/2006 00:00 01:00 1.00 6,082 6,082 PROD3 RIGMN SVRG P Slip and cut 65' of drlg line 01:00 02:30 1.50 6,082 7,540 PROD3 DRILL TRIP T Cont to RIH from 6,082' to btm at 7,540', above TOW at 6,082' oriented to 14 deg. left, RIH and tagged top of window at 6,094', (WS was originally set at 14 left) PU and oriented to high side and went thru window, RIH to 7,483' then washed 57' to btm at 7,540 with no other roblems 02:30 12:00 9.50 7,540 8,133 PROD3 DRILL DDRL P Directionally drilled 6 3/4" hole with 1.5 deg bend motor in "D" sand lateral from 7,540' to 8,133' MD! 3,607' ND (593') ART 2.69 hrs, AST 3.09 hrs, 2-5K wob, 80 rpm's, 74 spm, 265 gpm, off btm pressure 2,600 psi, on btm 2,700 psi, off btm torque 5K ft-Ibs, on btm torque 6K ft-Ibs, rot wt 80K, up wt 120K, do wt 62K, 8.75 ppg MOBM, ave ECD 10.15 ppg, ave BGG 35 units, max gas 102 units, drilled thru 6 concretions for a total of 50'. P~~ 33 ~f Time Logs Date From To Dur S, Depth __ E_ Depth Phase Code _ Subcode T COM _ __ 11/12/2006 12:00 00:00 12.00 8,133 8,806 PROD3 DRILL DDRL P Directionally drilled 6 3/4" hole with 1.5 deg bend motor in "D" sand lateral from 8,133' to 8,806' MD/ 3,616' ND (673') ART 4.79 hrs, AST 2.11 hrs, 2-10K wob, 80 rpm's, 85 spm, 300 gpm, off btm pressure 3,150 psi, on btm 3,300 psi, off btm torque 6K ft-Ibs, on btm torque 7K ft-Ibs, rot wt 83K, up wt 125K, do wt 58K, 8.7 ppg MOBM, ave ECD 10.0 ppg, ave BGG 35 units, max gas 93 units, drilled thru 9 concretions for a total of 74'. 11/13/2006 00:00 12:00 12.00 8,806 9,460 PROD3 DRILL DDRL P Directionally drilled 6 3/4" hole with 1.5 deg bend motor in "D" sand lateral from 8,806' to 9,460' MD/ 3,617' ND (654') ART 3.52 hrs, AST 3.85 hrs, 5-8K wob, 80 rpm's, 77 spm, 274 gpm, off btm pressure 2,800 psi, on btm 2,950 psi, off btm torque 6,500K ft-Ibs, on btm torque 7K ft-Ibs, rot wt 80K, up wt 135K, do wt 54K, 8.65 ppg MOBM, ave ECD 10.2 ppg, ave BGG 35 units, max gas 80 units, drilled thru 5 concretions for a total of 70'. 12:00 14:15 2.25 9,460 9,660 PROD3 DRILL DDRL P Drilled from 9,460' to 9,660' MD/3,618', 200' ART 2.55 hrs, AST .54 hrs 14:15 14:30 0.25 9,660 9,660 PROD3 DRILL SFTY P Held kick while drilling drill, met before and after drill and had a good response during the drill and debriefing after. 14:30 00:00 9.50 9,660 10,174 PROD3 DRILL DDRL P Directionally drilled 6 3/4" hole with 1.5 deg bend motor in "D" sand lateral from 9,660' to 10,174' MD/ 3,622' ND (514') ART 3.49 hrs, AST 1.07 hrs, 5-8K wob, 85 rpm's, 80 spm, 280 gpm, off btm pressure 3,150 psi, on btm 3,300 psi, off btm torque 7K ft-Ibs, on btm torque 7K ft-Ibs, rot wt 83K, up wt 147K, do wt 48K, 8.7 ppg MOBM, ave ECD 10.5 ppg, ave BGG 35 units, max gas 92 units, drilled thru 6 concretions for a total of 50'. Pumped wt'd hi vis sweep at 10,084' with 20% increase in cuttin s 11/14/2006 00:00 04:00 4.00 10,174 10,330 PROD3 DRILL DDRL P Directionally drilled 6 3/4" hole with 1.5 deg bend motor in "D" sand lateral from 10,174' to 10,330' MD/ 3,632' ND (154') ART 1.59 hrs, AST 1.23 hrs, 5-8K wob, 85 rpm's, 80 spm, 280 gpm, off btm pressure 3,100 psi, on btm 3,250 psi, off btm torque 8K ft-Ibs, on btm torque 8K ft-Ibs, rot wt 84K, up wt 153K, do wt 40K, 8.7 ppg MOBM, ave ECD 10.5 ppg, ave BGG 35 units, max gas 76 units, drilled thru 2 concretions for a total of 39'. ~~~ ~ Pay 34 caf 46 Time Logs _ Date From To ~ur___ S. Depth E. De th Phase Code. Subcode T COM _ _ _ 11/14/2006 04:00 04:15 0.25 10,330 10,330 PROD3 DRILL SFTY P Held kick while drilling drill, had a good response from the crew and good discussion after the drill with the crew. Circ hole to clear BHA during drill 04:15 04:30 0.25 10,330 10,330 PROD3 DRILL OWFF P Monitored well-static 04:30 07:15 2.75 10,330 8,697 PROD3 DRILL REAM P Backreamed out of the hole from 10,330' to 8,697', BROOH at 80 rpm's with 6-9K ft-Ibs torque, 275 gpm at 3,000 si 07:15 09:00 1.75 8,697 5,989 PROD3 DRILL TRIP P POOH wet on elevators from 8,697' thru window to 5,989' (TOW @ 6,094'), oriented to high side and pulled thru window with no roblems 09:00 10:00 1.00 5,989 5,989 PROD3 DRILL CIRC P Circ 2 X btms up at 5,989', Circ at 300 gpm at 2,900 psi, 40 rpm's and 4K ft-Ibs for ue 10:00 12:30 2.50 5,989 90 PROD3 DRILL TRIP P Monitored well-static, pumped dry job and POOH from 5,989' to 90', stood back HWDP, 'ars and NMFDC's 12:30 14:45 2.25 90 0 PROD3 DRILL PULD P Downloaded MWD, POOH LD BHA #16, LD MWD and motor, cleared rig floor 14:45 15:15 0.50 0 0 PROD3 DRILL PULD P Pulled wear bushing 15:15 00:00 8.75 0 0 PROD3 WELCT BOPE P RU and began testing BOPE, testing rams, valves and manifold to 250 psi low and 3,000 psi high including annular, manual choke line valve failed, changed out same and re tested and ck'd ok. NOTE: Jeff Jones with AOGCC waived witnessing of test. 11/15/2006 00:00 01:15 1.25 0 0 PROD3 WELCT BOPE P Fin. testing BOPE, tested both VBR's and annular with 4 1/2" tb , RD 01:15 01:30 0.25 0 0 PROD3 DRILL PULD P Installed wear bushing 01:30 02:15 0.75 0 0 PROD3 RIGMN SVRG P Serviced top drive and inspected saver sub and wei ht indicator 02:15 04:30 2.25 0 85 PROD3 DRILL PULD P MU BHA #17 RIH to 85', MU 6 3/4" RR Hycalog concretion bit with new Geopilot tool and LWD/MWD tool, u loaded MWD 04:30 05:00 0.50 85 416 PROD3 DRILL TRIP P RIH with BHA #17 from 85' to 416'. 05:00 05:30 0.50 416 416 PROD3 DRILL DHEO P Shaloow tested MWD and broke in seals on Geo ilot. rage 35 srf 45 Time Lo s g - --- ----- ------ -- Date From To Dur S. De th E. De th Phase Code Subcode T COM __ - 11!15/2006 _ 05:30 11:45 6.25 416 10,330 PROD3 DRILL TRIP ~ P ~ - -_ RIH from 416' to btm at 10,330, RIH thru window with no prob., cont RIH and set down at 7,900', washed down from 7,900' to 8,115' (215'), RIH from 8,115' and set down at 8,675' (560'), washed down from 8,675' to 8,769' (94'), RIH from 8,769' to 10,076' (1,307') and washed down from 10,070' to btm at 10,330', washed at 280 gpm, 2,650 psi, 100 rpm's with 7K ft-Ibs for ue 11:45 00:00 12.25 10,330 10,585 PROD3 DRILL DDRL P Directionally drilled 6 3/4" hole with Geopilot in "D" sand lateral from 10,330' to 10,585' MD/ 3,640' ND (255') ADT 8.81 hrs, 5-10K wob, 125 rpm's, 86 spm, 305 gpm, 2,750 psi, off btm torque 7.5K ft-Ibs, on btm torque 7K ft-Ibs, rot wt 85K, up wt 140K, do wt 40K, 8.65 ppg MOBM, ave ECD 10.5 ppg, ave BGG 30 units, max gas 80 units, drilled thru 6 concretions for a total of 48'. 11/16/2006 00:00 12:00 12.00 10,585 11,185 PROD3 DRILL DDRL P Directionally drilled 6 3/4" hole with Geopilot in "D" sand lateral from 10,585' to 11,185' MD/ 3,650' ND (600') ADT 8.22 hrs, 3-10K wob, 90-100 rpm's, 72-86 spm, 250-305 gpm, 2,000 to 2,600 psi, off btm torque 8K ft-Ibs, on btm torque 8K ft-Ibs, rot wt 83K, up wt 145K, do wt 35K, (blk wt) 8.7 ppg MOBM, ave ECD 10.4 ppg, ave BGG 40 units, max gas 97 units, drilled thru 8 concretions for a total of 74'. 12:00 00:00 12.00 11,185 11,941 PROD3 DRILL DDRL P Directionally drilled 6 3/4" hole with Geopilot in "D" sand lateral from 11,185' to 11,941' MD/ 3,648' ND (756') ADT 7.97 hrs, 4-8K wob, 120 rpm's, 86 spm, 305 gpm, 2,700 psi, off btm torque 8.5K ft-Ibs, on btm torque 8.5K ft-Ibs, rot wt 83K, up wt 155K, do wt 35K, (blk wt) 8.7 ppg MOBM, ave ECD 10.9 ppg, ave BGG 50 units, max gas 103 units, drilled thru 1 concretion for a total of 6'. °~ ~ ice ;~~ ~t 4 Time Logs ~ Date From To Dur S. De th E. De th _ Phase _ Cade Subcode T _ COM 11/17/2006 00:00 __ 12:00 _ 12.00 11,941 12,688 PROD3 DRILL DDRL P Directionally drilled 6 3/4" hole with Geopilot in "D" sand lateral from 11,941' to 12,688' MD/ 3,669' ND (747') ADT 8.38 hrs, 5-9K wob, 120 rpm's, 86 spm, 305 gpm, 2,600 psi, off btm torque 9K ft-Ibs, on btm torque 9K ft-Ibs, rot wt 87K, up wt 175K, do wt 35K, (blk wt) 8.7 ppg MOBM, ave ECD 10.9 ppg, ave BGG 40 units, max gas 330 units, drilled thru 7 concretions for a total of 47'. Pumped 35 bbl wt'd (2# over mw) hi vi sweep at 12,220' and had 30% increase in cuttings back from swee 12:00 13:45 1.75 12,688 12,874 PROD3 DRILL DDRL P Drilled from 12,688' to 12,874' MD/ 3,672' ND (186') ADT 1.75 hrs, pumped 35 bbl wt'd hi vis sweep (2# over mw) Sperry Sun's Geo-Span washed out. 13:45 15:00 1.25 12,874 12,874 PROD3 DRILL CIRC NP Changed out Sperry Sun's Geo-span unit on rig floor due to washout and fin circ out sweep, had 15% increase in cuttings back from sweep, circ hole at 270 mat 2,250 si and 120 r m's 15:00 00:00 9.00 12,874 13,154 PROD3 DRILL DDRL P Directionally drilled 6 3/4" hole with Geopilot in "D" sand lateral from 12,874' to 13,154' MD/ 3,689' ND (280') ADT 5.87 hrs, 8-9K wob, 120-130 rpm's, 86 spm, 305 gpm, 3,250 psi, off btm torque 10K ft-Ibs, on btm torque 9K ft-Ibs, rot wt 85K, up wt 180K, do wt 35K, (blk wt) 8.7 ppg MOBM, ave ECD 11.3 ppg, ave BGG 35 units, max gas 83 units, drilled thru 2 concretions for a total of 45'. Pumped 35 bbl wt'd (2# over mw) hi vi sweep at 13,015' and had a 15% increase in cuttin s back from swee 11/18/2006 00:00 10:15 10.25 13,154 13,924 PROD3 DRILL DDRL P Directionally drilled 6 3/4" hole with Geopilot in "D" sand lateral from 13,154' to 13,924' MD/ 3,702' ND (770') ADT 6.7 hrs, 4-9K wob, 130 rpm's, 88 spm, 305 gpm, 3,500 psi, off btm torque 10.5K ft-Ibs, on btm torque 10K ft-Ibs, rot wt 87K, up wt 190K, do wt 35K, (blk wt) 8.7 ppg MOBM, ave ECD 11.55 ppg, ave BGG 35 units, max as 83 units 140 10:15 12:00 1.75 13,924 13,924 PROD3 RIGMN SVRG P Changed out swivel packing on top drive, Stood back 1 std then MU circ. head pin and circ hole at 125 gpm at 810 si while chan in out swivel. Paa~~ 37 caf 4S j 'i Time Logs ~ -__ _-- ____- Date From To Dur S De th E. De th Pha e Code Subcode T COM - ~ 11/18/2006 - 12:00 13:15 1.25 13,924 14,000 PROD3 DRILL DDRL P Drilled 6 3/4" hole from 13,924' to 14,000' MD/3,705' TVD (76') ADT .78 hrs, "D" lateral T.D. 4-9K wob, 130 rpm's, 88 spm, 305 gpm, 3,500 psi, off btm torque 10.5K ft-Ibs, on btm torque 10K ft-Ibs, rot wt 87K, up wt 190K, do wt 35K, (blk wt) 8.7 ppg MOBM, ave ECD 11.55 ppg, ave BGG 35 units, max as 83 units 140 13:15 13:45 0.50 14,000 14,000 PROD3 DRILL CIRC P Circ hole to clear BHA, took slow um rates and monitored well-static. 13:45 00:00 10.25 14,000 7,368 PROD3 DRILL REAM P Backreamed out of hole from 14,000' to 7,368'. BROOH at 300 gpm, 3,150 psi and 100 rpm's with 7K ft-Ibs for ue, no roblems BROOH. 11/19/2006 00:00 01:00 1.00 7,368 6,061 PROD3 DRILL REAM P Cont to BROOH from 7,368' to 6,248'. BROOH at 310 gpm, 2,300 psi and 130 rpm's, POOH from 6,248' thru window to 6,061' TOW 6,094' 01:00 02:15 1.25 6,061 6,061 PROD3 DRILL CIRC P Circ hole clean at 6,061', pumped 35 bbl wt'd hi vis sweep (2# over mw) and circ out of hole with no increase in cuttings, circ an add. btms up and hole was clean, circ hole at 312 gpm at 2,300 psi and 100 rpm's 3K ft-Ibs for ue 02:15 03:45 1.50 6,061 6,061 PROD3 RIGMN SVRG P Held PJSM then slip and cut 71' of drl line and serviced to drive. 03:45 11:30 7.75 6,061 14,000 PROD3 DRILL TRIP P RIH from 6,061' to 10,350' when we lost down wt, washed and reamed from 10,350' to 13,800', washed down at 50 spm, 178 gpm at 1,500 psi and 100 rpm's, increased rates washing down from 13,800' to 14,000' at 312 gpm, 3,800 psi and 120 rpm's. no other roblems RIH. 11:30 15:15 3.75 14,000 14,000 PROD3 DRILL CIRC P Circ btms up at 14,000', circ btms up at 312 gpm at 3,700 psi and 120 rpm's, then displaced hole over from 8.7 ppg MOBM to 8.7 ppg SFMOBM, circ hole at 290 gpm at 3,300 psi and 120 r m's, st wt u 225K 15:15 15:45 0.50 14,000 14,000 PROD3 DRILL OWFF P Monitored well-static, dropped 1 7/8" rabbit on a wire. 15:45 21:45 6.00 14,000 367 PROD3 DRILL TRIP P POOH wet on elevators from 14,000' to BHA #17 at 367', talc hole fill 79 bbls, actual fill 99 bbls. 21:45 22:45 1.00 367 85 PROD3 DRILL PULD P POOH from 367' to 85' LD HWDP, jars and NMFDC's 22:45 00:00 1.25 85 85 PROD3 DRILL PULD P Downloaded MWD and began to LD same 11/20/2006 00:00 01:00 1.00 85 0 PROD3 DRILL PULD P Fin POOH and LD BHA #17, cleared ri floor. 01:00 01:30 0.50 0 0 COMPZ CASINC RURD P RU Doyon's 4 1/2" liner running equip. -----~-- -- f'ae ~8 cf 45 n Time Logs _ _ _ _ Date From To _ Our S. De th E. Depth, Phase Cade Subcode T COM __ _ 11/20/2006 01:30 01:45 0.25 0 0 COMPZ CASIN( SFTY P Held PJSM with rig crew, tong operator and Baker rep on running of liner and hazard's associated with the 'ob. 01:45 06:30 4.75 0 7,618 COMPZ CASIN( PUTS P RIH with 4 1/2" "D" lateral liner to 7,618', PU and RIH with 177 jts of 4 1/2", 11.6#, L-80 BTC liner, ran 9 blanks and 168 slotted, used torque rings on jts 65 thru 177, 177 stop rings and 177 H draform centralizers. 06:30 07:30 1.00 7,618 7,782 COMPZ CASIN( PUTB P MU Baker receptacle jt with "HR" liner running sleeve and liner running tool, RIH with 1 std of DP to 7,782', est rot at 20 rpm's and 3K ft-Ibs torque, st wt u 87K, do wt 57K and 72K rot. wt 07:30 10:45 3.25 7,782 12,323 COMPZ CASIN( RUNL P RIH with liner on 4" DP from 7,782' and ran out of slack off wt at 12,323' 10:45 14:00 3.25 12,323 13,985 COMPZ CASIN( RUNL P Rotated liner down from 12,323' to 13,967' when torque limited out at 20 rpm's and 11 K ft-Ibs torque, increased torque to 12.5K and est circ then washed liner down from 13,976' and tagged btm at 14,000', picked up to 13,985'. wash and rotated liner down at 124 gpm at 500 psi, 30 rpm's and 12.5k ft-Ibs torque, liner wt up 225K, rotatin wt 90K, rot. do wt 75K 14:00 15:00 1.00 13,985 6,305 COMPZ CASIN( OTHR P Dropped 1 3/4" setting ball and pumped down to seat at 3 bpm, 500 psi, with ball on seat pressured up to 3,000 psi to release liner, then pressured up to 4,000 psi to shear ball seat, (took 3 attempts to shear) PU and liner was released, st wt u 150K. 15:00 15:15 0.25 6,305 6,305 COMPZ CASIN( OTHR P Monitored well-static 15:15 18:45 3.50 6,305 0 COMPZ CASIN( RUNL P POOH from 6,305', while POOH thru window washed across whipstock slide then cont. to POOH and LD Baker's liner running tool, cleared rig floor. 18:45 19:45 1.00 0 241 COMPZ FISH PULD P MU Bakers whipstock retrieving assembly RIH to 241', MU ret. hook, 1-jt HWDP, bumper sub, oil jar, flt sub, XO and 2-stds h brid ush i e 19:45 22:15 2.50 241 6,099 COMPZ FISH TRIP P RIH with whipstock retrieving assembly from 241' to 6,099' to whi stock slot ~~~~~~~ Page 39 csf 4v a Time Logs _ Date From To Dur S. De th E. De th Phase Code Subcode T COM '_ 11/20/2006 22:15 00:00 1.75 6,099 6,099 COMPZ FISH FISH P Est circ at 188 gpm at 500 psi, st wt up 110K, do wt 67K then began to attempt whipstock, 1st by washing across WS face then W/O pump, sat down in slot twice with no hook. Note while PU to above WS, would pull 20K over at 6,088, slack off and rotate string to free up and PU to clear above 6,088, happened a couple of times but were able to et above s ot. 11/21/2006 00:00 02:15 2.25 6,099 6,099 COMPZ FISH FISH P Made several attempts to hook whipstock-unsuccessfull. P/U-115k S/O-65k ROT-85k. 02:15 02:30 0.25 6,099 6,099 COMPZ FISH OTHR P Flow Check-Static-Blow down top drive. 02:30 05:00 2.50 6,099 0 COMPZ FISH TRIP P POH-Lay down retrieving hook-1 jt. 3 1/2" HWDP-bumper sub-oil jars-xo & float sub. 05:00 05:30 0.50 0 0 COMPZ FISH OTHR P Clear & clean rig floor 05:30 06:00 0.50 0 0 COMPZ FISH OTHR P Service drawworks & top drive. 06:00 07:00 1.00 0 0 COMPZ FISH OTHR P Slip & cut 45' drlg. line. 07:00 07:30 0.50 0 241 COMPZ FISH PULD P P/U & M/U another retrieving hook assembly. Hook-1 jt. 3 1/2" hwdp-bumper sub-oil jars-float sub-xo-2 stands h brid ush i e. 07:30 08:45 1.25 241 6,027 COMPZ FISH TRIP P RIH from 241' to 6027'. filling pipe eve 20 stands. 08:45 09:45 1.00 6,027 6,099 COMPZ FISH FISH P Make several attempts to retrieve whipstock @ 6099'. Will not engage on u stroke. 09:45 10:00 0.25 6,099 6,099 COMPZ FISH OTHR P Flow check static-blow down top drive. 10:00 12:00 2.00 6,099 241 COMPZ FISH TRIP P POH from 6099' to 241'. 12:00 12:30 0.50 241 0 COMPZ FISH TRIP P Finish POH from 241'. Lay down bent hook assembly. Pick up Hook w/ more a ressive bend to it. 12:30 16:15 3.75 0 6,099 COMPZ FISH TRIP P RIH w/ bent hook assembly to 6099'. Wash past slot in whipstock-made several attemps to latch hook-decision made to POH. 16:15 18:00 1.75 6,099 0 COMPZ FISH TRIP P POH from 6099' to 0.0 Lay down bent hook. 18:00 18:45 0.75 0 0 COMPZ FISH PULD T Pick up box tap & make up on bha. 18:45 20:45 2.00 0 4,064 COMPZ FISH TRIP T RIH to 4064'. Bolt broke on top drive. 20:45 23:00 2.25 4,064 4,064 COMPZ FISH OTHR T New bolts installed in stand jump on to drive. 23:00 00:00 1.00 4,064 COMPZ FISH TRIP T Continue RIH from 4064' to 6025'. P~~ ~~ csf A.5 s • Time Logs _ _ Date From To Dur S. De th E Depth_ Phase _ Code Subcode T COM _ _ __ 11/23/2006 08:00 08:30 0.50 0 0 COMPZ FISH OTHR T Service top drive & drawworks. 08:30 09:45 1.25 0 0 COMPZ FISH WOEO T Wait on washpipe & boot baskets. 09:45 11:00 1.25 0 241 COMPZ FISH PULD T Make up washpipe assembly. Washovershne-xo-washpipe-boot basket-xo-boot basket X 2-xo-bumper sub-oil jar-float sub-xo- 2 stands h bred ush i e. 11:00 12:00 1.00 241 723 COMPZ FISH TRIP T RIH to 723'. 12:00 13:30 1.50 723 6,100 COMPZ FISH TRIP T RIH from 723' to 6044'. P/U 105k S/O 67k ROT 84k. Break circ. @ 48 spm 425 psi. ROT 50 rpm TQ 4k Took wt. 6100'. 13:30 16:00 2.50 6,100 6,133 COMPZ FISH MILL T Start milling @ 6100'. 100 rpm 31 spm 300 psi 4-7k TO. 5-6k wt. on shoe. Mill to 6102', lost bit wt. & TQ, slacked off to bottom out anchor & went in o en hole to 6133'. 16:00 17:00 1.00 6,133 6,080 COMPZ FISH CIRC T POH from 6133' to 6080' &circ. hi vis swee around. 17:00 20:00 3.00 6,080 0 COMPZ FISH TRIP T Monitor well. Static-blow down top drive. POH from 6080' to 0.0. Lay down 5 3/4" washpipe assembly. Recovered 1 4' piece of whipstock & 1 8" iece. Small feces of cocretions. 20:00 00:00 4.00 0 5,018 COMPZ FISH TRIP T ashpipe assembly & RIH to 5018'. 11/24/2006 00:00 00:15 0.25 5,018 6,092 COMPZ FISH TRIP T Continue trip in hole from 5018' to 6092'. 00:15 04:30 4.25 6,092 6,103 COMPZ FISH MILL T Wash over & mill from 6092' to 6103'. 80 r m 45 s m 500 si 5-10k TQ. 04:30 05:15 0.75 6,103 6,103 COMPZ FISH CIRC T CBU=pump hi vis sweep @ 75 spm 1150 si 80 r m. 05:15 05:30 0.25 6,103 6,103 COMPZ FISH OTHR T Flow check static-blow down top drive. 05:30 07:15 1.75 6,103 0 COMPZ FISH TRIP T POH from 6103' to 0.0 07:15 07:30 0.25 0 0 COMPZ FISH OTHR T Change out washover shoe. 07:30 09:15 1.75 0 6,103 COMPZ FISH TRIP T RIH to 6103'. 09:15 12:00 2.75 6,103 6,104 COMPZ FISH MILL T Milling on whipstock from 6103' to 6104.5' @ 100 rpm 5-7 TQ 5-10k on shoe 31 s m 350 si. 12:00 13:00 1.00 6,104 6,104 COMPZ FISH MILL T Continue milling on whipstock @ 6104.5 w/ no progress. Monitor well static. 13:00 15:00 2.00 6,104 0 COMPZ FISH TRIP T Blow down top drive & POH. 15:00 16:15 1.25 0 0 COMPZ FISH PULD T Lay down milling assembly & pick up overshot assembly dressed w/ 4.6875" basket ra le. 16:15 18:00 1.75 0 6,046 COMPZ FISH TRIP T RIH w. overshot assembly to 6046'. P/U 105k S/O 70k. f~ag~ 42 cif 45 Time Lois _ Date From To Dur S. De th E. De th Phase Code Subcode T COM 11/24/2006 18:00 18:30 0.50 6,046 6,101 COMPZ FISH FISH T Washed down to & over fish @ 6092 to 6101'. Bottomed out. Pull 10k over string wt. Bled jars & pulled 60k over & worked to 115k over-fish came loose. gained 5k on string wt. lost 13 bbls. fluid to well. 18:30 20:15 1.75 6,101 6,101 COMPZ FISH CIRC T CBU @ 3.5 bpm 360 psi (Max gas units 56) loss total 30 bbls. to well. monitor well. Static 20:15 22:30 2.25 6,101 0 COMPZ FISH TRIP T POH w/ fish. 22:30 23:30 1.00 0 0 COMPZ FISH PULD T Lay down jars, bumper sub, Float sub, xo,s, & boot baskets. 23:30 00:00 0.50 0 0 COMPZ FISH PULL T Lay down washpipe & Fish. 100% Recove 11/25/2006 00:00 01:30 1.50 0 0 COMPZ FISH PULD T Lay down washpipe & whipstock-remove all baker fishing tools & rest of space out off bottom of fish. 01:30 02:00 0.50 0 0 COMPZ FISH OTHR T Clean rig floor. 02:00 02:30 0.50 0 0 COMPZ CASIN( RURD P Rig up casing tools for hook hanger assembl . 02:30 04:30 2.00 0 272 COMPZ CASIN( OTHR P PJSM-Make up hook hanger assembly with inner string MWD & orient same. 04:30 08:00 3.50 272 6,100 COMPZ CASIN( RUNL P RIH w/ hook hanger on drill pipe. 08:00 08:30 0.50 6,100 6,100 COMPZ CASINC OTHR P Made three attempts before going thru window. 08:30 11:00 2.50 6,100 6,103 COMPZ DRILL OTHR P Orient hook hanger 47 Deg. to right @ 6103' MD. 11:00 12:00 1.00 6,103 6,103 COMPZ CASINC OTHR P Drop 29/32" ball. Pump down same @ 2.5 b m 600 si. 12:00 12:30 0.50 6,103 6,103 COMPZ CASINC OTHR P With ball on seat-pressure up 200# increments to 2700 psi (Inflate ECP) Pressure dropped to 570 psi. Bled to 0. Pressure up to 800 psi-release from hook han er. Monitor well Static 12:30 14:30 2.00 6,103 0 COMPZ CASINC OTHR P Blow Down Top Drive & POH. 14:30 16:00 1.50 0 0 COMPZ CASINC RURD P Lay down running tools &MWD-clear & clean ri floor. Monitor well Static. 16:00 16:30 0.50 0 0 COMPZ DRILL OTHR P Drain Stack-pull wear ring-pick up 2 7/8" test 't. & seat test lu . 16:30 17:30 1.00 0 0 COMPZ DRILL OTHR P PJSM- & change lower pipe rams to 2 7/8". 17:30 18:30 1.00 0 0 COMPZ DRILL OTHR P Test lower rams 250-3000 psi. Pull test plug-set wear ring & lay down test 't. 18:30 19:15 0.75 0 0 COMPZ DRILL OTHR P Rig up 2 7/8" Handling tools. 19:15 19:30 0.25 0 0 COMPZ DRILL SFTY P PJSM-Topic=Handling & running 2 7/8" clean out strin . 19:30 21:00 1.50 0 703 COMPZ DRILL PULD P Run in hole to 703' picking up 2 7/8" tb . Ri down 2 7/8" handlin tools. ~~~}~e 4 ~f 45 ~1 ~ J Time Logs -- --- - - Date From To Dur _S._Depth E. Depth Phase Code Subco_de_T COM ____ 11/25/2006 21:00 22:30 1.50 703 6,210 COMPZ DRILL TRIP P RIH from 703' to 6210'. Tag up & break circ. 22:30 23:30 1.00 6,210 6,210 COMPZ DRILL CIRC P Pump 30 bbl. hi-vis sweep @ 8.5 bpm 1470 si. Monitor well-static. 23:30 00:00 0.50 6,210 6,000 COMPZ DRILL OTHR P Blow down top drive & POH. 11/26/2006 00:00 01:30 1.50 6,211 704 COMPZ DRILL TRIP P POH from 6211' to 704'. 01:30 01:45 0.25 704 704 COMPZ DRILL OTHR P Rig up to lay down 2 7/8" tbg. 01:45 03:45 2.00 704 0 COMPZ DRILL PULD P Layed down 24 jts. 704' 2 7/8" tbg. 03:45 04:15 0.50 0 0 COMPZ DRILL OTHR P Clear & clean rig floor. 04:15 05:15 1.00 0 0 COMPZ DRILL OTHR P Slip & cut 71.5' drlg. line. 05:15 05:30 0.25 0 0 COMPZ DRILL OTHR P Service top drive. 05:30 05:45 0.25 0 0 COMPZ DRILL OTHR P Rig up to lay down drill pipe. 05:45 12:00 6.25 0 0 COMPZ DRILL PULD P Lay down 15 stands hybred push pipe-7 stands hwdp & 141 jts. 4"drill i e out of mouse hole. 12:00 12:15 0.25 0 0 COMPZ DRILL SFTY P PJSM-Topic=laying down pipe from mouse hole. 12:15 17:30 5.25 0 0 COMPZ DRILL PULD P Continue laying down 4"drill pipe from derrick 279 'ts 17:30 19:00 1.50 0 0 COMPZ DRILL OTHR P Pull wear ring-lay down mouse hole-clear floor of drl .tools. 19:00 19:30 0.50 0 0 COMPZ DRILL OTHR P Lubricate rig-top drive & blocks. 19:30 21:00 1.50 0 0 COMPZ RPCOA PULD P Hoist centralift tools & equipment to ri floor. 21:00 21:15 0.25 0 0 COMPZ RPCOh SFTY P PJSM-Topic=picking up centralift motor-etc. 21:15 22:30 1.25 0 0 COMPZ RPCOA PULD P Pick up motor-tandem seal section-TTC xo w/ screen intake. 22:30 00:00 1.50 0 0 COMPZ RPCOh OTHR P Hang cable sheave-rig up esp cable & tie in to motor. 11/27/2006 00:00 00:15 0.25 COMPZ RPCOh SFTY P PJSM :Running ESP Completion - Hazard recognition -Discussed & reviewed running detail and all know hazards. 00:15 01:30 1.25 COMPZ RPCOh RCST P Con't to MU A-Well discharge sub 01:30 03:45 2.25 COMPZ RPCOh SLKL P RU Wire line unit -Run pump in tbg - Install & test packoff to 800 psi - Install Tb sto . 03:45 12:00 8.25 COMPZ RPCOh RCST P Con't run tbg 4.5" 12.6# L80 IBTM - Tested cable continuity on jts # 30,66, 90 & 120. All "OK" -Had 120 jts ran at end of tower. Dn wt 62k 12:00 12:15 0.25 COMPZ RPCOh SFTY P PJSM :Running ESP Completion - Hazard recognition -Discussed & reviewed running detail and all know hazards. F~~q~ 44 cif s1.~ Halliburton Company Survey Report Company: ConocoPhillips Alaska Inc. Date: 12/19/2006 ___ Time: 14:55:59 Page: 1 Field: Kuparuk River Unit Co-ordinate(NE) Reference: Well: 1J-115, True North Site: Kuparuk 1J Pad Vertical (TVD) Reference: 1J-115L2: 109.0 Well: 1J-115 Section (VS) Reference: Well (O.OON,O.OOE,O.OOAzi) Wellpath: 1J-115L2 Survey Calculation Method: Minimum Curvature Dh: Oracte Field: Kuparuk River Unit North Slope Alaska I I United States ~ 4 Map System:US State Plane Coordinate System 1927 Map Zone: Alaska, Zone 4 Geo Datum; NAD27 (Clarke 1866) Coordinate System: Well Centre Sys Datum: Mean Sea Level Geomagnetic Model: bggm2006 Well: 1 J-115 Slot Name: We1I 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-115L2 Drilled From: 1J-115L2P62 50029232061 Tie-on Depth: 6905.22 ft Current Datum: 1J-115L2: 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 Definitive Wellpath Date: 12/19/2006 Validated: No Version: 2 Actual From To Survey Toolcode Tool Name ft ft ~ 50.00 1016.00 1J-115PB1 gyro (50.00-1016.00) CB-GYRO-SS Camera based gyro single shot i 1147.04 6011.71 1 J-115P61 (1147.04-8360.39) (3 MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 6094.00 6121.47 1 J-115L2PB1 (6094.00-6210.71) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 6180.00 6905.22 1J-115L2PB2 (6180.00-7192.81) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 6930.00 13963.37 1J-115L2 (6930.00-13963.37) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC Survey - - __ __ ____ MD [ucl ALlnl -'PVD Sys TVD IVi5 EIN' btapN 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 T1E LINE 50.00 0.20 101.96 50.00 -59.00 -0.01 0.04 5945785.37 558829.67 CB-GYRO-SS 100.00 0.19 134.36 100.00 -9.00 -0.08 0.18 5945785.30 558829.81 CB-GYRO-SS 172.00 0.07 306.93 172.00 63.00 -0.14 0.23 5945785.24 558829.86 CB-GYRO-SS 260.00 0.07 81.28 260.00 151.00 -0.10 0.24 5945785.28 558829.87 CB-GYRO-SS 356.00 0.12 272.58 356.00 247.00 -0.09 0.20 5945785.29 558829.83 CB-GYRO-SS 447.00 1.38 98.80 446.99 337.99 -0.25 1.19 5945785.14 558830.82 CB-GYRO-SS 540.00 3.65 90.60. 539.90 430.90 -0.45 5.26 5945784.97 558834.89 CB-GYRO-SS 632.00 6.87 83.95 631.50 522.50 0.10 13.66 5945785.58 558843.28 CB-GYRO-SS 734.00 12.14 85.32 732.06 623.06 1.62 30.43 5945787.23 558860.04 CB-GYRO-SS 828.00 14.65 87.39 823.50 714.50 2.96 52.15 5945788.75 558881.76 CB-GYRO-SS ' 923.00 16.60 93.22 914.99 805.99 2.75 77.71 5945788.74 558907.31 CB-GYRO-SS 1016.00 19.62 96.55 1003.37 894.37 0.22 106.49 5945786.43 558936.11 CB-GYRO-SS 1147.04 19.73 100.48 1126.77 1017.77 -6.31 150.10 5945780.24 558979.76 MWD+IFR-AK-CAZ-SC 1239.14 20.76 99.26 1213.18 1104.18 -11.77 181.50 5945775.03 559011.20 MWD+IFR-AK-CAZ-SC 1336.46 25.69 100.98 1302.58 1193.58 -18.56 219.25 5945768.53 559049.00 MWD+IFR-AK-CAZ-SC 1430.30 32.19 97.67 1384.67 1275.67 -25.78 264.04 5945761.66 559093.84 MWD+IFR-AK-CAZ-SC 1527.05 34.57 97.87 1465.45 1356.45 -32.98 316.78 5945754.88 559146.63 MWD+IFR-AK-CAZ-SC 1623.88 39.43 96.68 1542.76 1433.76 -40.32 374.57 5945747.99 559204.47 MWD+IFR-AK-CAZ-SC 1717.45 47.02 98.39 1610.90 1501.90 -48.79 438.04 5945740.02 559267.99 MWD+IFR-AK-CAZ-SC 1763.81 49.23 98.35 1641.84 1532.84 -53.81 472.19 5945735.26 559302.18 MWD+IFR-AK-CAZ-SC 1812.39 49.81 98.48 1673.38 1564.38 -59.22 508.74 5945730.14 559338.77 MWD+IFR-AK-CAZ-SC 1859,85 51.05 98.27 1703.61 1594.61 -64.55 544.94 5945725.10 559375.00 MWD+IFR-AK-CAZ-SC 1909,19 52.88 97.27 1734.01 1625.01 -69.80 583.44 5945720.15 559413.54 MWD+IFR-AK-CAZ-SC 1956.90 56.75 96.14 1761.50 1652.50 -74.34 622.16 5945715.91 559452.29 MWD+IFR-AK-CAZ-SC '~ 2004.98 60.06 94.39 1786.68 1677.68 -78.09 662.93 5945712.48 559493.09 MWD+IFR-AK-CAZ-SC Halliburton Company Survey Report Company: ConocoPhillips Alaska Inc. Date: 12/19/2006 Time: 14:55:59 ..._ .............. Pale: 2 .. Field:. Ku paruk River Unit Co-or dinate (NE)Reference: WeII: 1J-11 5, Tru e North Site: Ku paruk 1J Pad Vertical(TVD) Reference: 1J-11512: 1 09.0 WeII: 1J-115 Sectio n (VS) Keference: WeII (O.OON,O.OOE,O.OOAzi) Wellpath: 1 J -115L2 Survey Calc ulatio ___ n Method: Minimum C urvat __ ure Db: Oracle _ __ __ Su rvct ,~iD Incl Azim 'TVD SysTVD 'S/S E/yV MapN 1ViapE Tool 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 MWD+IFR-AK-CAZ-SC 2243.32 65.22 94. 86 1890 .46 1781. 46 -94 .68 876. 68 5945697. 56 559706. 94 MWD+IFR-AK-CAZ-SC 2290.05 65.23 95. 29 1910 .04 1801. 04 -98 .44 918. 95 5945694. 13 559749. 23 MWD+IFR-AK-CAZ-SC 2384.30 66.21 92. 85 1948 .80 1839. 80 -104 .53 1004. 63 5945688. 71 559834. 95 MWD+IFR-AK-CAZ-SC 2431.35 66.51 91. 83 1967. 67 1858. 67 -106 .29 1047. 70 5945687. 29 559878. 03 MWD+IFR-AK-CAZ-SC 2479.29 65.14 92. 38 1987. 30 1878. 30 -107 .89 1091. 40 5945686. 03 559921. 74 MWD+tFR-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 MWO+IFR-AK-CAZ-SC 2716.31 63.56 93. 99 2088 .55 1979. 55 -118 .51 1305. 43 5945677. 08 560135. 82 MWD+IFR-AK-CAZ-SC 2764.95 62.48 93. 85 2110 .61 2001. 61 -121 .48 1348. 67 5945674. 45 560179. 08 MWD+IFR-AK-CAZ-SC 2792.69 63.61 94. 72 2123 .19 2014. 19 -123 .33 1373. 33 5945672. 80 560203. 75 MWD+IFR-AK-CAZ-SC 2858.21 64.46 95. 53 2151 .88 2042. 88 -128 .59 1432. 00 5945667. 99 560262. 45 MWD+IFR-AK-CAZ-SC ~ 2923.29 65.79 94. 45 2179 .25 2070. 25 -133 .72 1490. 81 5945663. 32 560321. 30 MWD+IFR-AK-CAZ-SC 2953.10 65.83 94. 21 2191 .47 2082. 47 -135 .77 1517. 93 5945661. 48 560348. 43 MWD+IFR-AK-CAZ-SC . 3020.46 64.26 94. 73 2219 .88 2110 .88 -140 .53 1578 .81 5945657. 20 560409. 34 MWD+IFR-AK-CAZ-SC 3066.57 63.09 96. 12 2240 .33 2131 .33 -144 .44 1619 .95 5945653. 62 560450. 50 MWD+IFR-AK-CAZ-SC 3115.25 62.06 96. 47 2262 .75 2153 .75 -149 .17 1662 .90 5945649. 22 560493. 48 MWD+IFR-AK-CAZ-SC 3161.89 60.79 95. 77 2285 .06 2176 .06 -153 .54 1703 .62 5945645. 17 560534. 24 MWD+IFR-AK-CAZ-SC 3207.64 59.59 95. 17 2307 .81 2198 .81 -157 .33 1743 .14 5945641. 69 560573. 78 MWD+IFR-AK-CAZ-SC 3257.07 59.30 95. 67 2332 .93 2223 .93 -161 .35 1785 .51 5945638. 00 560616. 18 MWD+IFR-AK-CAZ-SC 3302.16 60.64 95. 08 2355 .50 2246 .50 -165 .00 1824 .38 5945634. 65 560655. 07 MWD+IFR-AK-CAZ-SC 3351.77 61.76 94. 04 2379 .40 2270 .40 -168 .46 1867 .71 5945631. 54 560698. 42 MWD+IFR-AK-CAZ-SC 3397.36 61.52 94. 13 2401 .05 2292 .05 -171 .31 1907 .73 5945628. 99 560738. 46 MWD+IFR-AK-CAZ-SC 3445.60 61.94 94, 01 2423 .90 2314 .90 -174 .33 1950 .11 5945626. 31 560780. 85 MWD+IFR-AK-CAZ-SC I ~ 3541.93 64.26 92. 53 2467 .48 2358 .48 -179 .22 2035 .87 5945622. 09 560866. 64 MWD+IFR-AK-CAZ-SC ' 3587.60 63.76 92. 85 2487 .50 2378 .50 -181 .14 2076 .87 5945620. 48 560907. 65 MWD+IFR-AK-CAZ-SC 3637.30 63.20 92 .99 2509 .69 2400 .69 -183 .41 2121 .28 5945618. 57 560952. 08 MWD+IFR-AK-CAZ-SC 3683.58 62.11 93 .43 2530 .95 2421 .95 -185 .71 2162 .33 5945616. 59 560993. 14 MWD+IFR-AK-CAZ-SC 3730.50 61.48 93 .54 2553 .12 2444 .12 -188 .22 2203 .60 5945614. 39 561034. 42 MWD+IFR-AK-CAZ-SC 3783.12 62.18 92. 50 2577 .96 2468 .96 -190 .67 2249 .92 5945612. 31 561080. 76 MWD+IFR-AK-CAZ-SC 3826.51 61.89 92. 49 2598 .31 2489 .31 -192 .33 2288 .21 5945610. 95 561119. 05 MWD+IFR-AK-CAZ-SC 3873.70 62.90 92. 02 2620 .18 2511 .18 -193 .98 2329 .99 5945609. 63 561160. 84 MWD+IFR-AK-CAZ-SC 3921.50 64.20 91. 19 2641 .47 2532 .47 -195 .18 2372 .77 5945608. 77 561203. 63 MWD+IFR-AK-CAZ-SC 3975.48 62.84 89. 69 2665 .54 2556 .54 -195 .55 2421 .08 5945608. 77 561251. 94 MWD+IFR-AK-CAZ-SC 4011.14 63.44 87. 24 2681 .65 2572 .65 -194 .70 2452 .88 5945609. 87 561283. 72 MWD+IFR-AK-CAZ-SC 4065.80 63.59 84 .65 2706 .03 2597 .03 -191 .24 2501 .68 5945613. 71 561332. 49 MWD+IFR-AK-CAZ-SC 4111.07 63.08 82 .85 2726 .35 2617 .35 -186 .83 2541 .89 5945618. 43 561372. 66 MWD+IFR-AK-CAZ-SC 4161.60 62.71 82 .07 2749 .37 2640 .37 -180 .93 2586 .48 5945624. 68 561417. 20 MWD+IFR-AK-CAZ-SC ~ 4207.41 I 62.05 81 .09 2770 .61 2661 .61 -174 .99 2626 .63 5945630. 93 561457. 30 MWD+IFR-AK-CAZ-SC 4302.87 60.78 75 .96 2816 .31 2707 .31 -158 .35 2708 .74 5945648. 22 561539. 27 MWD+IFR-AK-CAZ-SC 4397.88 61.00 71 .95 2862 .54 2753 .54 -135 .41 2788 .49 5945671. 78 561618. 83 MWD+IFR-AK-CAZ-SC 4444.65 61.15 70 .43 2885 .16 2776 .16 -122 .21 2827 .24 5945685. 28 561657. 47 MWD+IFR-AK-CAZ-SC 4493.15 62.09 66 .97 2908 .22 2799 .22 -106 .71 2866 .99 5945701. 09 561697. 09 MWD+IFR-AK-CAZ-SC 4587.16 63.03 60 .70 2951 .58 2842 .58 -69 .92 2941 .81 5945738. 45 561771. 61 MWD+IFR-AK-CAZ-SC 4681.64 63.67 55 .12 2993 .98 2884 .98 -25 .08 3013 .30 5945783. 84 561842. 75 MWD+IFR-AK-CAZ-SC 4776.45 63.61 48 .37 3036 .12 2927 .12 27 .48 3079 .96 5945836. 91 561908. 99 MWD+IFR-AK-CAZ-SC 4872.66 62.93 42 .02 3079 .43 2970 .43 87 .98 3140 .89 5945897. 88 561969. 44 MWD+IFR-AK-CAZ-SC 4966.48 62.78 36 .83 3122 .25 3013 .25 152 .43 3193 .89 5945962. 74 562021. 92 MWD+IFR-AK-CAZ-SC i Halliburton Company Survey Report Company: ConocoPhiilips Alaska Inc. Date: 12/19/2006 Time: 14:55:59 Page: 3 Field: Kuparuk River Unit Co-ordinate(NE) Reference: Well: 1J-115,True North Site: Kuparuk 1J Pad Vertical (TVD)Rcference: 1J-115L2. 109.0 Well: 1J-115 Section (VS)Keference: .Well (O.OON,O.OOE,O.OOAzi) Wellpath: 1J-115L2 Survey Calculation Method: Minimum Curvature Db: Oracle __ ___ _ ' S u r~ ev AtD Incl Azim TVD SysTVD N/S E/W MapN btapE Toot ft deg deg ft ft ft ft ft ft '; 5061.23 63.60 30.93 3165.02 3056.02 222.60 3240.99 5946033.27 562068.47 MWD+IFR-AK-CAZ-SC 5154.55 63.67 26.34 3206.48 3097.48 295.96 3281.04 5946106.94 562107.94 MWD+IFR-AK-CAZ-SC 5249.86 64.52 23.85 3248.12 3139.12 373.60 3317.39 5946184.85 562143.68 MWD+IFR-AK-CAZ-SC 5344.89 64.58 23.84 3288.96 3179.96 452.08 3352.08 5946263.59 562177.75 MWD+IFR-AK-CAZ-SC 5440.16 64.61 24.40 3329.83 3220.83 530.62 3387.25 5946342.40 562212.30 MWD+IFR-AK-CAZ-SC 5537.28 64.76 24.25 3371.36 3262.36 610.62 3423.41 5946422.67 562247.84 MWD+IFR-AK-CAZ-SC I 5630.91 66.63 19.01 3409.92 3300.92 689.92 3454.82 5946502.20 562278.63 MWD+IFR-AK-CAZ-SC 5724.54 69.47 14.47 3444.93 3335.93 773.05 3479.79 5946585.52 562302.94 MWD+IFR-AK-CAZ-SC 5818.75 70.89 10.45 3476.88 3367.88 859.57 3498.90 5946672.18 562321.37 MWD+IFR-AK-CAZ-SC 5915.97 72.53 6.28 3507.41 3398.41 950.88 3512.30 5946763.57 562334.06 MWD+IFR-AK-CAZ-SC 6011.71 75.39 0.95 3533.87 3424.87 1042.66 3518.07 5946855.39 562339.11 MWD+IFR-AK-CAZ-SC III ~ ~ 6094.00 76.79 356.48 3553.67 3444.67 1122.49 3516.27 5946935.20 562336.69 MWD+IFR-AK-CAZ-SC 6121.47 77.39 356.00 3559.80 3450.80 1149.21 3514.52 5946961.90 562334.72 MWD+IFR-AK-CAZ-SC I 6180.00 80.29 355.08 3571.13 3462.13 1206.45 3510.05 5947019.10 562329.81 MWD+IFR-AK-CAZ-SC ' 6209.13 78.63 357.07 3576.46 3467.46 1235.02 3508.09 5947047.65 562327.63 MWD+IFR-AK-CAZ-SC 6303.26 82.01 3.45 3592.30 3483.30 1327.74 3508.53 5947140.37 562327.35 MWD+IFR-AK-CAZ-SC L I 6332.99 82.51 4.99 3596.30 3487.30 1357.12 3510.70 5947169.76 562329.29 MWD+IFR-AK-CAZ-SC 6398.63 85.57 4.79 3603.12 3494.12 1422.16 3516.27 5947234.83 562334.34 MWD+IFR-AK-CAZ-SC 6430.98 87.74 4.11 3605.01 3496.01 1454.36 3518.77 5947267.04 562336.59 MWD+IFR-AK-CAZ-SC 6490.64 91.70 2.12 3605.30 3496.30 1513.91 3522.01 5947326.62 562339.37 MWD+IFR-AK-CAZ-SC 6584.05 93.34 357.02 3601.19 3492.19 1607.20 3521.32 5947419.88 562337.94 MWD+IFR-AK-CAZ-SC 6677.90 91.15 356.37 3597.51 3488.51 1700.81 3515.91 5947513.44 562331.81 MWD+iFR-AK-CAZ-SC 6771.11 90.48 355.03 3596.19 3487.19 1793.75 3508.92 5947606.31 562324.09 MWD+IFR-AK-CAZ-SC II i 6822.96 91.98 353.07 3595.07 3486.07 1845.30 3503.55 5947657.82 562318.32 MWD+IFR-AK-CAZ-SC 6863.05 90.90 353.30 3594.07 3485.07 1885.10 3498.79 5947697.57 562313.25 MWD+IFR-AK-CAZ-SC 6905.22 90.48 351.00 3593.56 3484.56 1926.87 3493.03 5947739.29 562307.17 MWD+IFR-AK-CAZ-SC 6930.00 90.75 351.41 3593.29 3484.29 1951.35 3489.24 5947763.74 562303.19 MWD+IFR-AK-CAZ-SC 6956.72 89.22 350.23 3593.30 3484.30 1977.73 3484.98 5947790.08 562298.72 MWD+IFR-AK-CAZ-SC 7014.76 90.99 349.38 3593.19 3484.19 2034.85 3474.71 5947847.12 562288.00 MWD+IFR-AK-CAZ-SC ! 7049.72 89.04 349.04 3593.18 3484.18 2069.19 3468.17 5947881.40 562281.19 MWD+IFR-AK-CAZ-SC 7143.79 89.38 348.83 3594.48 3485.48 2161.50 3450.11 5947973.56 562262.42 MWD+IFR-AK-CAZ-SC 7236.99 89.00 350.83 3595.80 3486.80 2253.22 3433.66 5948065.14 562245.25 MWD+IFR-AK-CAZ-SC 7330.66 89.13 354.54 3597.33 3488.33 2346.10 3421.74 5948157.92 562232.60 MWD+IFR-AK-CAZ-SC II 7366.14 89.25 355.13 3597.83 3488.83 2381.44 3418.54 5948193.22 562229.14 MWD+IFR-AK-CAZ-SC 7396.25 88.69 356.06 3598.37 3489.37 2411.45 3416.23 5948223.21 562226.59 MWD+IFR-AK-CAZ-SC 7423.59 89.32 358.28 3598.84 3489.84 2438.75 3414.88 5948250.50 562225.03 MWD+IFR-AK-CAZ-SC 7450.50 89.06 359.19 3599.23 3490.23 2465.65 3414.29 5948277.39 562224.22 MWD+IFR-AK-CAZ-SC 7462.29 88.87 358.67 3599.44 3490.44 2477.44 3414.07 5948289.18 562223.91 MWD+IFR-AK-CAZ-SC 7474.79 88.82 358.14 3599.69 3490.69 2489.93 3413.72 5948301.66 562223.46 MWD+IFR-AK-CAZ-SC 7505.02 89.01 0.27 3600.26 3491.26 2520.15 3413.30 5948331.88 562222.81 MWD+IFR-AK-CAZ-SC 7527.36 88.90 0.52 3600.67 3491.67 2542.49 3413.45 5948354.21 562222.79 MWD+IFR-AK-CAZ-SC I 7590.26 89.19 357.63 3601.72 3492.72 2605.36 3412.44 5948417.07 562221.28 MWD+IFR-AK-CAZ-SC 7620.75 88.41 356.96 3602.36 3493.36 2635.81 3411.00 5948447.51 562219.61 MWD+IFR-AK-CAZ-SC 7713.05 89.68 351.54 3603.90 3494.90 2727.60 3401.76 5948539.21 562209.65 MWD+IFR-AK-CAZ-SC 7789.10 89.07 347.48 3604.73 3495.73 2802.36 3387.91 5948613.85 562195.22 MWD+IFR-AK-CAZ-SC 7806.45 89.02 347.53 3605.02 3496.02 2819.29 3384.16 5948630.75 562191.34 MWD+IFR-AK-CAZ-SC ~ 7899.09 85.30 344.81 3609.61 3500.61 2909.11 3362.05 5948720.39 562168.53 MWD+IFR-AK-CAZ-SC 7958.92 87.13 344.70 3613.56 3504.56 2966.71 3346.36 5948777.86 562152.39 MWD+IFR-AK-CAZ-SC 7993.39 89.10 343.90 3614.69 3505.69 2999.87 3337.03 5948810.94 562142.81 MWD+IFR-AK-CAZ-SC 8087.46 90.75 342.21 3614.81 3505.81 3089.85 3309.62 5948900.70 562114.69 MWD+IFR-AK-CAZ-SC 8180.74 90.62 342.30 3613.70 3504.70 3178.69 3281.19 5948989.30 562085.57 MWD+IFR-AK-CAZ-SC i 8223.62 90.81 342.12 3613.16 3504.16 3219.52 3268.09 5949030.02 562072.15 MWD+IFR-AK-CAZ-SC Halliburton Company Survey Report ', Company: ConocoPhillips Alaska Inc. Date: 1 211 912 0 06 Time: 14:55:59 Pate: 4 Field: Kuparuk River Unit Co-ordinate(NE) Reference: Well: 1 J-115, True North ', Sitr. Kuparuk 1J Pad Vertical (TVD)Referencr. 1J-115L2: 109.0 Nell: 1 J-115 Section (VS) Reference: Well (O.OON,O.OOE,OAOAzi) ~i'ellpath: 1J-115L2 Survey Calculation Method: Minimum Curvature Db: Oracle __ ' __ _ __ Survev NLD Incl Azim T~~ SysTVD ~~/S E/~'1' MapN MapE Tool ft deg deg ft ft ft ft ft ft __ 8274.03 90.92 343.41 3612.40 3503.40 3267.66 3253.16 5949078.04 562056.85 MWD+IFR-AK-CAZ-SC 8322.80 90.85 342.36 3611.65 3502.65 3314.26 3238.81 5949124.52 562042.13 MWD+IFR-AK-CAZ-SC 8367.19 91.23 342.50 3610.84 3501.84 3356.57 3225.41 5949166.72 562028.41 MWD+IFR-AK-CAZ-SC 8433.34 90.12 342.89 3610.06 3501.06 3419.72 3205.73 5949229.71 562008.24 MWD+IFR-AK-CAZ-SC 8505.22 88.93 344.42 3610.66 3501.66 3488.69 3185.51 5949298.52 561987.48 MWD+IFR-AK-CAZ-SC 8555.11 88.88 344.77 3611.61 3502.61 3536.78 3172.26 5949346.49 561973.85 MWD+IFR-AK-CAZ-SC 8600.14 87.23 343.48 3613.14 3504.14 3580.07 3159.95 5949389.68 561961.21 MWD+IFR-AK-CAZ-SC 8646.70 87.15 342.96 3615.42 3506.42 3624.59 3146.52 5949434.09 561947.44 MWD+IFR-AK-CAZ-SC 8685.40 89.71 342.88 3616.48 3507.48 3661.57 3135.16 5949470.97 561935.79 MWD+IFR-AK-CAZ-SC 8742.44 90.07 342.89 3616.59 3507.59 3716.08 3118.37 5949525.35 561918.58 MWD+IFR-AK-CAZ-SC 8833.66 88.45 346.35 3617.77 3508.77 3804.01 3094.19 5949613.08 561893.71 MWD+IFR-AK-CAZ-SC 8866.91 87.83 347.97 3618.85 3509.85 3836.41 3086.80 5949645.42 561886.07 MWD+IFR-AK-CAZ-SC ~ 8927.07 87.76 348.49 3621.17 3512.17 3895.26 3074.54 5949704.17 561873.35 MWD+IFR-AK-CAZ-SC ~I 9020.27 90.60 350.93 3622.50 3513.50 3986.94 3057.89 5949795.70 561855.99 MWD+IFR-AK-CAZ-SC 9056.59 90.56 350.41 3622.13 3513.13 4022.77 3052.01 5949831.49 561849.82 MWD+IFR-AK-CAZ-SC 9113.75 90.85 352.60 3621.43 3512.43 4079.30 3043.56 5949887.94 561840.94 MWD+IFR-AK-CAZ-SC 'i 9206.82 91.10 355.50 3619.84 3510.84 4171.84 3033.92 5949980.40 561830.57 MWD+IFR-AK-CAZ-SC it 9253.35 89.35 355.65 3619.66 3510.66 4218.23 3030.33 5950026.75 561826.62 MWD+IFR-AK-CAZ-SC 9300.52 88.21 355.80 3620.67 3511.67 4265.26 3026.81 5950073.75 561822.74 MWD+IFR-AK-CAZ-SC 9343.94 89.55 357.16 3621.51 3512.51 4308.59 3024.15 5950117.05 561819.74 MWD+IFR-AK-CAZ-SC 9393.13 91.84 358.14 3620.92 3511.92 4357.73 3022.13 5950166.17 561817.34 MWD+IFR-AK-CAZ-SC 9487.19 91.83 359.50 3617.91 3508.91 4451.72 3020.20 5950260.13 561814.67 MWD+IFR-AK-CAZ-SC 9579.81 89.74 358.83 3616.64 3507.64 4544.31 3018.85 5950352.70 561812.59 MWD+IFR-AK-CAZ-SC 9674.17 89.94 357.36 3616.90 3507.90 4638.62 3015.71 5950446.97 561808.72 MWD+IFR-AK-CAZ-SC 9764.33 91.77 0.39 3615.55 3506.55 4728.74 3013.94 5950537.06 561806.25 MWD+IFR-AK-CAZ-SC 9829.37 89.57 0.48 3614.79 3505.79 4793.77 3014.43 5950602.09 561806.23 MWD+IFR-AK-CAZ-SC 9856.78 88.51 0.91 3615.25 3506.25 4821.17 3014.77 5950629.49 561806.35 MWD+IFR-AK-CAZ-SC 9900.57 88.39 359.70 3616.44 3507.44 4864.94 3015.00 5950673.26 561806.24 MWD+IFR-AK-CAZ-SC 9945.76 88.44 0.88 3617.69 3508.69 4910.11 3015.23 5950718.43 561806.12 MWD+IFR-AK-CAZ-SC 10037.37 88.77 0.29 3619.92 3510.92 5001.69 3016.16 5950810.00 561806.34 MWD+IFR-AK-CAZ-SC 10127.57 88.94 1.79 3621.72 3512.72 5091.86 3017.80 5950900.17 561807.27 MWD+IFR-AK-CAZ-SC 10218.65 87.15 1.67 3624.83 3515.83 5182.84 3020.55 5950991.16 561809.31 MWD+IFR-AK-CAZ-SC 10283.21 86.79 0.12 3628.24 3519.24 5247.30 3021.55 5951055.62 561809.81 MWD+IFR-AK-CAZ-SC 10363.85 87.18 0.57 3632.48 3523.48 5327.82 3022.04 5951136.14 561809.66 MWD+IFR-AK-CAZ-SC 10411.47 87.04 1.70 3634.88 3525.88 5375.37 3022.98 5951183.69 561810.23 MWD+IFR-AK-CAZ-SC 10504.63 88.35 3.35 3638.63 3529.63 5468.36 3027.08 5951276.70 561813.61 MWD+IFR-AK-CAZ-SC ', 10598.30 90.52 6.97 3639.55 3530.55 5561.63 3035.51 5951370.02 561821.30 MWD+IFR-AK-CAZ-SC ~, I~ 10691.75 89.76 8.22 3639.33 3530.33 5654.26 3047.86 5951462.73 561832.93 MWD+IFR-AK-CAZ-SC 10755.00 89.27 6.86 3639.86 3530.86 5716.95 3056.16 5951525.49 561840.74 MWD+IFR-AK-CAZ-SC 10784.95 89.52 6.05 3640.18 3531.18 5746.71 3059.52 5951555.27 561843.87 MWD+IFR-AK-CAZ-SC 10839.00 88.83 4.11 3640.96 3531.96 5800.54 3064.31 5951609.13 561848.23 MWD+IFR-AK-CAZ-SC 10878.15 88.59 2.99 3641.84 3532.84 5839.61 3066.73 5951648.20 561850.35 MWD+IFR-AK-CAZ-SC 10971.45 90.27 3.13 3642.76 3533.76 5932.77 3071.71 5951741.39 561854.60 MWD+IFR-AK-CAZ-SC 11065.43 90.63 2.58 3642.03 3533.03 6026.63 3076.39 5951835.28 561858.55 MWD+IFR-AK-CAZ-SC 11158.87 91.43 1.39 3640.35 3531.35 6119.99 3079.63 5951928.66 561861.06 MWD+IFR-AK-CAZ-SC ~, 11252.59 88.26 359.32 3640.60 3531.60 6213.69 3080.21 5952022.35 561860.91 MWD+IFR-AK-CAZ-SC 11345.27 88.59 359.19 3643.15 3534.15 6306.33 3079.00 5952114.96 561858.98 MWD+IFR-AK-CAZ-SC 11440.19 88.90 355.13 3645.23 3536.23 6401.09 3074.30 5952209.68 561853.54 MWD+IFR-AK-CAZ-SC 11532.64 90.02 353.29 3646.10 3537.10 6493.06 3064.98 5952301.56 561843.49 MWD+IFR-AK-CAZ-SC 11624.79 89.02 352.30 3646.87 3537.87 6584.48 3053.42 5952392.88 561831.22 MWD+IFR-AK-CAZ-SC 11668.57 88.96 351.67 3647.64 3538.64 6627.82 3047.32 5952436.17 561824.78 MWD+IFR-AK-CAZ-SC 11718.30 90.21 352.95 3648.00 3539.00 6677.10 3040.66 5952485.39 561817.74 MWD+IFR-AK-CAZ-SC 11776.65 89.32 355.10 3648.24 3539.24 6735.13 3034.59 5952543.36 561811.22 MWD+IFR-AK-CAZ-SC • Halliburton Company Survey Report i Company: ConocoPhillips Alaska Inc. Date: 12/19!2006 Time: 14:55:59 Page: 5 Field:. Kuparuk River Unit Co-ordinate(NE) Reference:. Well: 1J-115, True North Site: Kuparuk 1J Pad Vertical (TVD) Reference: 1J-115L2: 109.0 Well: 1 J-115 Section (VS) Reference: Well (O.OON,O.OOE,O.OOAzi) Wellpath: 1J-115L2 Survey Calculation Method: Minimum Curvature Dh: Oracle Su r~°cy MD Inc! Azim TVD Sys TVD ?S/S EIW MapV MapE Tool ft deg deg ft ft ft ft ft ft '~ 11812.17 89.58 356.00 3648.58 3539.58 6770.54 3031.83 5952578.75 561808.19 MWD+IFR-AK-CAZ-SC 11862.59 90.08 357.64 3648.73 3539.73 6820.88 3029.04 5952629.06 561805.00 MWD+IFR-AK-CAZ-SC 11905.33 89.89 357.53 3648.74 3539.74 6863.58 3027.24 5952671.74 561802.86 MWD+IFR-AK-CAZ-SC 11964.97 90.51 358.26 3648.54 3539.54 6923.18 3025.05 5952731.32 561800.21 MWD+IFR-AK-CAZ-SC ~ 11998.76 90.13 357.71 3648.35 3539.35 6956.95 3023.86 5952765.07 561798.75 MWD+IFR-AK-CAZ-SC j 12092.29 89.08 356.56 3648.99 3539.99 7050.36 3019.18 5952858.43 561793.35 MWD+IFR-AK-CAZ-SC 12185.88 89.77 357.49 3649.93 3540.93 7143.81 3014.33 5952951.84 561787.76 MWD+IFR-AK-CAZ-SC 12279.61 88.65 357.19 3651.22 3542.22 7237.43 3009.98 5953045.41 561782.68 MWD+IFR-AK-CAZ-SC 12372.55 87.72 356.98 3654.17 3545.17 7330.21 3005.25 5953138.14 561777.24 MWD+IFR-AK-CAZ-SC 12468.68 86.05 358.15 3659.39 3550.39 7426.10 3001.17 5953233.99 561772.41 MWD+IFR-AK-CAZ-SC 12559.00 88.36 359.96 3663.80 3554.80 7516.29 2999.69 5953324.15 561770.22 MWD+IFR-AK-CAZ-SC 12653.94 87.47 0.28 3667.25 3558.25 7611.17 2999.89 5953419.02 561769.68 MWD+IFR-AK-CAZ-SC ii 12746.12 88.35 1.14 3670.61 3561.61 7703.28 3001.03 5953511.13 561770.10 MWD+IFR-AK-CAZ-SC ~, 12838.82 88.59 1.51 3673.09 3564.09 7795.92 3003.17 5953603.77 561771.52 MWD+IFR-AK-CAZ-SC 12932.11 86.17 0.40 3677.35 3568.35 7889.09 3004.72 5953696.95 561772.34 MWD+IFR-AK-CAZ-SC 13026.78 88.36 2.19 3681.87 3572.87 7983.62 3006.86 5953791.48 561773.74 MWD+IFR-AK-CAZ-SC 13119.91 86.04 359.64 3686.42 3577.42 8076.61 3008.35 5953884.47 561774.50 MWD+IFR-AK-CAZ-SC 13213.16 86.93 0.28 3692.13 3583.13 8169.69 3008.28 5953977.53 561773.71 MWD+IFR-AK-CAZ-SC 13305.94 89.22 0.19 3695.25 3586.25 8262.41 3008.67 5954070.24 561773.37 MWD+IFR-AK-CAZ-SC 13399.30 91.57 1.81 3694.61 3585.61 8355.74 3010.29 5954163.58 561774.27 MWD+IFR-AK-CAZ-SC i 13489.50 91.37 3.15 3692.29 3583.29 8445.82 3014.20 5954253.68 561777.46 MWD+IFR-AK-CAZ-SC j 13580.36 89.32 1.23 3691.75 3582.75 8536.61 3017.67 5954344.48 561780.23 MWD+IFR-AK-CAZ-SC 13671.37 88.59 0.02 3693.41 3584.41 8627.59 3018.66 5954435.46 561780.51 MWD+IFR-AK-CAZ-SC i 13762.25 87.85 357.29 3696.23 3587.23 8718.40 3016.53 5954526.24 561777.67 MWD+IFR-AK-CAZ-SC 13853.60 88.10 357.84 3699.46 3590.46 8809.61 3012.65 5954617.41 561773.08 MWD+IFR-AK-CAZ-SC 13892.66 87.78 358.31 3700.86 3591.86 8848.62 3011.34 5954656.40 561771.46 MWD+IFR-AK-CAZ-SC 13942.93 87.66 359.16 3702.86 3593.86 8898.84 3010.23 5954706.61 561769.96 MWD+IFR-AK-CAZ-SC 13963.37 87.73 359.66 3703.68 3594.68 8919.26 3010.02 5954727.02 561769.59 MWD+IFR-AK-CAZ-SC .14000.00 87.73 359.66 3705.13 ~ 3596.13 8955.86 3009.80 5954763.62 ~ 561769.09, PROJECTED to TD • i Halliburton Company Survey Report Company: ConocoPhillips Alaska Inc . Date: 12/19/2006 Time: 14:39:26 Page: 1 Field: Kuparuk River Unit Co -ordinate(NE) Reference: Well: 1J-115, T rue North Site: Kuparuk 1J Pad Vertieal(TVll)Re ference: 1J-115L2PB1: 109.0 Well: 1J-115 Section (VS) Refer ence: Well (O.OON,O.OOE,O.OOAzi) y~'ellpath: 1J-115L2P61 Survey Calculation Ntethod: Minimum Curvature Db: Orade __ ___ i 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 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-115L2PB1 Drilled From: 1J-115PB1 ~ ~ 500292332076 Tie-on Depth: 6011.71 ft Current Datum: 1 J-115L2P61: 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 Angl e: 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: 4 Actual From To Survey Toolcode Tool Name ft ft 50.00 1016.00 1J-115PB1 gyro (50 .00-1016.00) CB-GYRO-SS Camera based gyro si ngle shot 1147.04 6011.71 1J-115PB1 (1147.04-8360.39) (3 MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 6094.00 6210.71 1J-115L2P61 (6094. 00-6210.71) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC Survey --_ (VID Incl Azim TVD Sys T~'D N/S E/W 1•IapN 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 i 447.00 1.38 98.80 446.99 337.99 -0.25 1.19 5945785.14 558830.82 CB-GYRO-SS 540.00 3.65 90.60 539.90 430.90 -0.45 5.26 5945784.97 558834.89 CB-GYRO-SS 632.00 6.87 83.95 631.50 522.50 0.10 13.66 5945785.58 558843.28 CB-GYRO-SS 734.00 12.14 85.32 732.06 623.06 1.62 30.43 5945787.23 558860.04 CB-GYRO-SS 828.00 14.65 87.39 823.50 714.50 2.96 52.15 5945788.75 558881.76 CB-GYRO-SS 923.00 16.60 93.22 914.99 805.99 2.75 77.71 5945788.74 558907.31 CB-GYRO-SS 1016.00 19.62 96.55 1003.37 894.37 0.22 106.49 5945786.43 558936.11 CB-GYRO-SS 1147.04 19.73 100.48 1126.77 1017.77 -6.31 150.10 5945780.24 558979.76 MWD+IFR-AK-CAZ-SC 1239.14 20.76 99.26 1213.18 1104.18 -11.77 181.50 5945775.03 559011.20 MWD+IFR-AK-CAZ-SC 1336.46 25.69 100.98 1302.58 1193.58 -18.56 219.25 5945768.53 559049.00 MWD+IFR-AK-CAZ-SC ', 1430.30 32.19 97.67 1384.67 1275.67 -25.78 264.04 5945761.66 559093.84 MWD+IFR-AK-CAZ-SC 1527.05 34.57 97.87 1465.45 1356.45 -32.98 316.78 5945754.88 559146.63 MWD+IFR-AK-CAZ-SC 1623.88 39.43 96.68 1542.76 1433.76 -40.32 374.57 5945747.99 559204.47 MWD+IFR-AK-CAZ-SC 1717.45 47.02 98.39 1610.90 1501.90 -48.79 438.04 5945740.02 559267.99 MWD+IFR-AK-CAZ-SC 1763.81 49.23 98.35 1641.84 1532.84 -53.81 472.19 5945735.26 559302.18 MWD+IFR-AK-CAZ-SC 1812.39 49.81 98.48 1673.38 1564.38 -59.22 508.74 5945730.14 559338.77 MWD+IFR-AK-CAZ-SC 1859.85 51.05 98.27 1703.61 1594.61 -64.55 544.94 5945725.10 559375.00 MWD+IFR-AK-CAZ-SC 'i 1909.19 52.88 97.27 1734.01 1625.01 -69.80 583.44 5945720.15 559413.54 MWD+IFR-AK-CAZ-SC 1956.90 56.75 96.14 1761.50 1652.50 -74.34 622.16 5945715.91 559452.29 MWD+IFR-AK-CAZ-SC 2004.98 60.06 94.39 1786.68 1677.68 -78.09 662.93 5945712.48 559493.09 MWD+IFR-AK-CAZ-SC 2052.33 61.37 94.72 1809.84 1700.84 -81.37 704.10 5945709.52 559534.28 MWD+IFR-AK-CAZ-SC 2099.08 65.15 94.08 1830.88 1721.88 -84.57 745.72 5945706.65 559575.91 MWD+IFR-AK-CAZ-SC • • Halliburton Company Survey Report Company: ConocoPhillips Alaska Inc. Date: 12/19!2006 Time.: 14:39:26 Page: 2 Field: Ku paruk Rive r Unit Co-ordinate(NE) Reference: Well: 1J-11 5, T rue North Site: Ku pan~k 1J P ad Vertical (fV D) Reference: 1J-115L2P61: 109.0 Nell: 1J -115 Sectio n (VS) Reference: Well (O.OON,O.OOE,O.OOAzi) ~Vcllpath: 1J -115L2PB1 Survey Calc ulation Method: Minimum C urvature Db: Oracle Survey _ _ __ b1D Inc! .4zim TVD Sys TVD N/S E/~N MapN MapE Tool ft deg deg ft ft ft ft ft ft __ 2146. 11 66. 24 94. 32 1850.23 1741. 23 -87. 70 788. 46 5945703. 85 559618. 68 MWD+IFR-AK-CAZ-SC 2195. 14 65. 38 94. 46 1870.32 1761. 32 -91. 13 833. 06 5945700. 77 559663. 29 MWD+IFR-AK-CAZ-SC 2243. 32 65. 22 94. 86 1890.46 1781. 46 -94. 68 876. 68 5945697. 56 559706. 94 MWD+IFR-AK-CAZ-SC 2290. 05 65. 23 95 .29 1910.04 1801 .04 -98. 44 918. 95 5945694. 13 559749. 23 MWD+IFR-AK-CAZ-SC ~I 2384. 30 66. 21 92 .85 1948.80 1839 .80 -104. 53 1004. 63 5945688. 71 559834. 95 MWD+IFR-AK-CAZ-SC 2431. 35 66. 51 91 .83 1967.67 1858 .67 -106. 29 1047. 70 5945687. 29 559878. 03 MWD+IFR-AK-CAZ-SC 2479. 29 65. 14 92 .38 1987.30 1878 .30 -107. 89 1091. 40 5945686. 03 559921. 74 MWD+IFR-AK-CAZ-SC 2525. 10 64. 21 92 .41 2006.89 1897 .89 -109. 62 1132. 78 5945684. 62 559963. 12 MWD+IFR-AK-CAZ-SC 2574. 27 64. 84 92 .04 2028.04 1919 .04 -111. 35 1177. 13 5945683. 24 560007. 48 MWD+IFR-AK-CAZ-SC 2621. 23 65. 32 92 .80 2047.83 1938 .83 -113. 14 1219. 68 5945681. 78 560050. 04 MWD+IFR-AK-CAZ-SC 2668. 37 64. 85 93 .77 2067.69 1958 .69 -115. 59 1262. 36 5945679. 66 560092. 74 MWD+IFR-AK-CAZ-SC 2716. 31 63. 56 93 .99 2088.55 1979 .55 -118. 51 1305. 43 5945677. 08 560135. 82 MWD+IFR-AK-CAZ-SC 2764. 95 62. 48 93 .85 2110.61 2001 .61 -121. 48 1348. 67 5945674. 45 560179. 08 MWD+IFR-AK-CAZ-SC 2792. 69 63. 61 94. 72 2123.19 2014 .19 -123. 33 1373. 33 5945672. 80 560203. 75 MWD+IFR-AK-CAZ-SC 2858. 21 64. 46 95 .53 2151.88 2042 .88 -128. 59 1432. 00 5945667. 99 560262. 45 MWD+IFR-AK-CAZ-SC 2923. 29 65. 79 94 .45 2179.25 2070 .25 -133. 72 1490. 81 5945663. 32 560321. 30 MWD+IFR-AK-CAZ-SC 2953. 10 65. 83 94 .21 2191.47 2082 .47 -135. 77 1517. 93 5945661. 48 560348. 43 MWD+IFR-AK-CAZ-SC 3020. 46 64. 26 94 .73 2219.88 2110 .88 -140. 53 1578. 81 5945657. 20 560409. 34 MWD+IFR-AK-CAZ-SC 3066. 57 63. 09 96 .12 2240.33 2131 .33 -144. 44 1619. 95 5945653. 62 560450. 50 MWD+IFR-AK-CAZ-SC ', 3115. 25 62. 06 96 .47 2262.75 2153 .75 -149. 17 1662. 90 5945649. 22 560493. 48 MWD+IFR-AK-CAZ-SC ~i 3161. 89 60. 79 95 .77 2285.06 2176 .06 -153. 54 1703. 62 5945645. 17 560534. 24 MWD+IFR-AK-CAZ-SC I~ 3207. 64 59. 59 95 .17 2307.81 2198 .81 -157. 33 1743. 14 5945641. 69 560573. 78 MWD+IFR-AK-CAZ-SC 3257. 07 59. 30 95 .67 2332.93 2223 .93 -161. 35 1785. 51 5945638. 00 560616. 18 MWD+IFR-AK-CAZ-SC 3302. 16 60. 64 95 .08 2355.50 2246 .50 -165. 00 1824. 38 5945634. 65 560655. 07 MWD+IFR-AK-CAZ-SC 3351. 77 61. 76 94 .04 2379.40 2270 .40 -168. 46 1867. 71 5945631. 54 560698. 42 MWD+IFR-AK-CAZ-SC ~i 3397. 36 61. 52 94 .13 2401.05 2292 .05 -171. 31 1907. 73 5945628. 99 560738 .46 MWD+IFR-AK-CAZ-SC 3445. 60 61. 94 94 .01 2423.90 2314 .90 -174. 33 1950. 11 5945626. 31 560780. 85 MWD+IFR-AK-CAZ-SC 3541. 93 64. 26 92 .53 2467.48 2358 .48 -179. 22 2035. 87 5945622. 09 560866 .64 MWD+IFR-AK-CAZ-SC 3587. 60 63. 76 92 .85 2487.50 2378 .50 -181. 14 2076. 87 5945620. 48 560907. 65 MWD+IFR-AK-CAZ-SC 3637. 30 63. 20 92 .99 2509.69 2400 .69 -183. 41 2121. 28 5945618. 57 560952. 08 MWD+IFR-AK-CAZ-SC 3683. 58 62. 11 93 .43 2530.95 2421 .95 -185. 71 2162. 33 5945616. 59 560993. 14 MWD+IFR-AK-CAZ-SC 3730. 50 61. 48 93 .54 2553.12 2444 .12 -188. 22 2203. 60 5945614. 39 561034. 42 MWD+IFR-AK-CAZ-SC 3783. 12 62. 18 92 .50 2577.96 2468 .96 -190. 67 2249. 92 5945612. 31 561080. 76 MWD+IFR-AK-CAZ-SC 3826. 51 61. 89 92 .49 2598.31 2489 .31 -192. 33 2288. 21 5945610. 95 561119. 05 MWD+IFR-AK-CAZ-SC 3873. 70 62. 90 92 .02 2620.18 2511 .18 -193. 98 2329. 99 5945609. 63 561160. 84 MWD+IFR-AK-CAZ-SC 3921. 50 64. 20 91 .19 2641.47 2532 .47 -195. 18 2372. 77 5945608. 77 561203 .63 MWD+IFR-AK-CAZ-SC ~ 3975. 48 62. 84 89 .69 2665.54 2556 .54 -195. 55 2421. 08 5945608. 77 561251 .94 MWD+IFR-AK-CAZ-SC 4011. 14 63. 44 87 .24 2681.65 2572 .65 -194. 70 2452. 88 5945609 .87 561283 .72 MWD+IFR-AK-CAZ-SC 4065. 80 63. 59 84 .65 2706.03 2597 .03 -191. 24 2501. 68 5945613 .71 561332 .49 MWD+IFR-AK-CAZ-SC 4111. 07 63. 08 82 .85 2726.35 2617 .35 -186. 83 2541. 89 5945618 .43 561372 .66 MWD+IFR-AK-CAZ-SC 4161. 60 62. 71 82 .07 2749.37 2640 .37 -180. 93 2586. 48 5945624 .68 561417 .20 MWD+IFR-AK-CAZ-SC 4207. 41 62. 05 81 .09 2770.61 2661 .61 -174. 99 2626. 63 5945630 .93 561457 .30 MWD+IFR-AK-CAZ-SC 4302. 87 60. 78 75 .96 2816.31 2707 .31 -158. 35 2708. 74 5945648. 22 561539 .27 MWD+IFR-AK-CAZ-SC 4397. 88 61. 00 71 .95 2862.54 2753 .54 -135. 41 2788. 49 5945671. 78 561618 .83 MWD+IFR-AK-CAZ-SC 4444. 65 61. 15 70 .43 2885.16 2776 .16 -122. 21 2827. 24 5945685 .28 561657 .47 MWD+IFR-AK-CAZ-SC ~~ 4493. 15 62. 09 66 .97 2908.22 2799 .22 -106. 71 2866. 99 5945701 .09 561697 .09 MWD+IFR-AK-CAZ-SC 4587. 16 63. 03 60 .70 2951.58 2842 .58 -69. 92 2941. 81 5945738 .45 561771 .61 MWD+IFR-AK-CAZ-SC 4681. 64 63. 67 55 .12 2993.98 2884 .98 -25. 08 3013. 30 5945783 .84 561842 .75 MWD+IFR-AK-CAZ-SC 4776. 45 63. 61 48 .37 3036.12 2927 .12 27. 48 3079. 96 5945836 .91 561908 .99 MWD+IFR-AK-CAZ-SC I, 4872. 66 62 .93 42 .02 3079.43 2970 .43 87. 98 3140. 89 5945897 .88 561969 .44 MWD+IFR-AK-CAZ-SC 4966. 48 62 .78 36 .83 3122.25 3013 .25 152. 43 3193. 89 5945962 .74 562021 .92 MWD+IFR-AK-CAZ-SC 5061. 23 63 .60 30 .93 3165.02 3056 .02 222. 60 3240. 99 5946033 .27 562068 .47 MWD+IFR-AK-CAZ-SC • Halliburton Company Survey Report __ __ Company: ConocoPhillips Alaska Inc. Date: 12/19/2006 Time: 14:39:26 Page: 3 Field: Kuparuk River Unii Co-ordinate(VE) Keference: Well: 1J-115, True North Site: Kuparuk 1J Pad Vertical (TVD) Reference: 1J-115L2P61: 109A Well: 1 J-115 .Section (VS) Reference: Well (O.OON;O.OOE,O.OOAzi) Wellpath: 1J-115L2PB1 Survey Calculation Method: Minimum Curvature Db: Oracle Survey __ ___ ___ D1D Incl Azim TVD Sys TVD N/S ElW D4apN MapE Tool 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 ~i 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 I 6094.00 76.79 356.48 3553.67 3444.67 1122.49 3516.27 5946935.20 562336.69 MWD+IFR-AK-CAZ-SC 6121.47 77.39 356.00 3559.80 3450.80 1149.21 3514.52 5946961.90 562334.72 MWD+IFR-AK-CAZ-SC 6185.04 80.54 355.00 3571.97 3462.97 1211.40 3509.62 5947024.05 562329.34 MWD+)FR-AK-CAZ-SC 6210.71 87.95 355.00 3574.54 3465.54 1236.83 3507.39 5947049.45 562326.92 MWD+IFR-AK-CAZ-SC 6245.00 87.95 355.00 3575.77 3466.77 1270.97 3504.41 5947083.56 562323.66 PROJECTED to TD • Halliburton Company Survey Report • Company: ConocoPhillips Alaska Inc. ___ _ _ Date: 12!19/2006 Time: 14:46:25 __ Page: I Field: Kuparuk River Unit Co-ordinate(NE)Reference: Well: 1J-115, Tr ue North Site: KuparuklJPad Vertical (TVD)Re fercncr. 1J-115L2PB2:1 09.0 WeII: 1 J-115 Section (VS) Refer ence: Well (O.OON,O.OOE,O.OOAzi) Wellpath: 1J-115L2PB2 Survey Calculation Method: Minimum Curva ture 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: WeII Position: +N/-S -134.58 ft North ing: 594578 5.38 ft Latitude: 70 15 44.934 N +E/-W 38.63 ft Easti ng : 558829.63 ft Longitude: 149 31 27.882 W Position Uncertainty: 0.00 ft Wellpath: 1J-115L2P62 Drilled From: 1J-115L2PB1 500292332077 Tie-on Depth: 6121.47 ft Current Datum: 1J-115LZPB2: Height 109.00 ft Above System Datum: Mean Sea Level Magnetic Data: 9/25/2006 Declination: 23.78 deg Field Strength: 57610 nT Vertical Section: Depth From (TVD) +N/-S Mag Dip Angl +E/-W e: 80.80 deg Direction ft ft ft deg 28.00 ~ 0.00 0.00 0.00 I , -- _ - Survey Program for Definitive Wellpath _ Date: 12/19/2006 Validated: No Version: 3 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 6011.71 1 J-115P61 (1147.04-8360.39) (3 MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SC C 6094.00 6121.47 1 J-115L2P61 (6094 .00-6210.71) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SC C 6180.00 7192.81 1J-115L2PB2 (6180 .00-7192.81) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC Survey J1D Inc! Azim TVD Sys TVD V'/S E/N' MapN ~11apE 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 ~I 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 i 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 1239.14 20.76 99.26 121$.18 1104.18 _ 11.77 181.50 4 1.2 59 5775.03 55901 0 + - MWD IFR AK- AZ-SC C 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.Ofi 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. Date: 12/19!2006 Time: 14:46:25 Page: 2 Field: Ku paruk River Unit Co-or dinate(NE) Reference: Well: 1 J-11 5, True North Site: Ku paruk 1J Pad Vertical ('1'VD)Reference: 1J-115L2P62: 109.0 Nell: 1J -115 Sectio n (VS ) Reference: Well (O.OON,O. OOE,O.OOAzi) ~!'cllpath: 1J -115 L2P62 __ - Surve ___ y Calculation Method: _ _ _ Minimum C urv ature Db: Oracte __ ___ Survey --__ MD Inc! Azim TVD Sys TVD ~lS E/W MnpN Mapb: Tool ft deg deg ft ft ft ft ft ft 2099.08 65. 15 94 .08 1830 .88 1721 .88 -84 .57 745 .72 5945706. 65 559575. 91 MWD+IFR-AK-CAZ-SC 2146.11 66. 24 94. 32 1850 .23 1741 .23 -87 .70 788 .46 5945703. 85 559618. 68 MWD+IFR-AK-CAZ-SC 2195.14 65. 38 94. 46 1870 .32 1761 .32 -91 .13 833 .06 5945700. 77 559663. 29 MWD+IFR-AK-CAZ-SC 2243.32 65. 22 94. 86 1890 .46 1781 .46 -94 .68 876 .68 5945697. 56 559706. 94 MWD+IFR-AK-CAZ-SC 2290.05 65. 23 95. 29 1910 .04 1801 .04 -98 .44 918 .95 5945694. 13 559749. 23 MWD+IFR-AK-CAZ-SC ~ 2384.30 66. 21 92. 85 1948 .80 1839 .80 -104 .53 1004 .63 5945688. 71 559834. 95 MWD+tFR-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 i 2923.29 65. 79 94. 45 2179 .25 2070 .25 -133 .72 1490 .81 5945663. 32 560321. 30 MWD+IFR-AK-CAZ-SC t 2953.10 65. 83 94. 21 2191 .47 2082 .47 -135 .77 1517 .93 5945661. 48 560348. 43 MWD+IFR-AK-CAZ-SC i 3020.46 64. 26 94. 73 2219 .88 2110 .88 -140 .53 1578 .81 5945657. 20 560409. 34 MWD+IFR-AK-CAZ-SC 3066.57 63. 09 96. 12 2240 .33 2131 .33 -144 .44 1619 .95 5945653. 62 560450. 50 MWD+IFR-AK-CAZ-SC 3115.25 62. 06 96 .47 2262 .75 2153 .75 -149 .17 1662 .90 5945649. 22 560493. 48 MWD+IFR-AK-CAZ-SC 3161.89 60. 79 95 .77 2285 .06 2176 .06 -153 .54 1703 .62 5945645. 17 560534. 24 MWD+IFR-AK-CAZ-SC 3207.64 59. 59 95 .17 2307 .81 2198 .81 -157 .33 1743 .14 5945641. 69 560573. 78 MWD+IFR-AK-CAZ-SC 3257.07 59. 30 95 .67 2332 .93 2223 .93 -161 .35 1785 .51 5945638. 00 560616. 18 MWD+IFR-AK-CAZ-SC 3302.16 60. 64 95 .08 2355 .50 2246 .50 -165 .00 1824 .38 5945634. 65 560655. 07 MWD+IFR-AK-CAZ-SC 3351.77 61. 76 94 .04 2379 .40 2270 ,40 -168 .46 1867 .71 5945631. 54 560698. 42 MWD+IFR-AK-CAZ-SC 3397.36 61. 52 94. 13 2401 .05 2292 .05 -171 .31 1907 .73 5945628. 99 560738. 46 MWD+IFR-AK-CAZ-SC !i 3445.60 61. 94 94. 01 2423 .90 2314 .90 -174 .33 1950 .11 5945626. 31 560780. 85 MWD+IFR-AK-CAZ-SC 3541.93 64. 26 92 .53 2467 .48 2358 .48 -179 .22 2035 .87 5945622. 09 560866. 64 MWD+IFR-AK-CAZ-SC 3587.60 63. 76 92 .85 2487 .50 2378 .50 -181 .14 2076 .87 5945620. 48 560907. 65 MWD+IFR-AK-CAZ-SC 3637.30 63. 20 92 .99 2509 .69 2400 .69 -183 .41 2121 .28 5945618. 57 560952. 08 MWD+IFR-AK-CAZ-SC 3683.58 62. 11 93 .43 2530 .95 2421 .95 -185 .71 2162 .33 5945616. 59 560993. 14 MWD+IFR-AK-CAZ-SC 3730.50 61. 48 93 .54 2553 .12 2444 .12 -188 .22 2203 .60 5945614. 39 561034. 42 MWD+IFR-AK-CAZ-SC 3783.12 62. 18 92 .50 2577 .96 2468 .96 -190 .67 2249 .92 5945612. 31 561080. 76 MWD+IFR-AK-CAZ-SC 3826.51 61. 89 92 .49 2598 .31 2489 .31 -192 .33 2288 .21 5945610. 95 561119. 05 MWD+IFR-AK-CAZ-SC 3873.70 62. 90 92 .02 2620 .18 2511 .18 -193 .98 2329 .99 5945609. 63 561160. 84 MWD+IFR-AK-CAZ-SC 3921.50 64. 20 91 .19 2641 .47 2532 .47 -195 .18 2372 .77 5945608. 77 561203. 63 MWD+IFR-AK-CAZ-SC 3975.48 62. 84 89 .69 2665 .54 2556 .54 -195 .55 2421 .08 5945608. 77 561251. 94 MWD+IFR-AK-CAZ-SC 4011.14 63. 44 87 .24 2681 .65 2572 .65 -194 .70 2452 .88 5945609. 87 561283. 72 MWD+IFR-AK-CAZ-SC 4065.80 63. 59 84 .65 2706 .03 2597 .03 -191 .24 2501 .68 5945613. 71 561332. 49 MWD+IFR-AK-CAZ-SC 4111.07 63. 08 82 .85 2726 .35 2617 .35 -186 .83 2541 .89 5945618. 43 561372. 66 MWD+IFR-AK-CAZ-SC 4161.60 62. 71 82 .07 2749 .37 2640 .37 -180 .93 2586 .48 5945624. 68 561417. 20 MWD+IFR-AK-CAZ-SC 4207.41 62. 05 81 .09 2770 .61 2661 .61 -174 .99 2626 .63 5945630. 93 561457. 30 MWD+IFR-AK-CAZ-SC 4302.87 60. 78 75 .96 2816 .31 2707 .31 -158 .35 2708 .74 5945648. 22 561539. 27 MWD+IFR-AK-CAZ-SC 4397.88 61. 00 71 .95 2862 .54 2753 .54 -135 .41 2788 .49 5945671. 78 561618. 83 MWD+IFR-AK-CAZ-SC 4444.65 61. 15 70 .43 2885 .16 2776 .16 -122 .21 2827 .24 5945685. 28 561657. 47 MWD+IFR-AK-CAZ-SC ~ 4493.15 62. 09 66 .97 2908 .22 2799 .22 -106 .71 2866 .99 5945701. 09 561697. 09 MWD+IFR-AK-CAZ-SC 4587.16 63. 03 60 .70 2951 .58 2842 .58 -69 .92 2941 .81 5945738. 45 561771. 61 MWD+IFR-AK-CAZ-SC 4681.64 63. 67 55 .12 2993 .98 2884 .98 -25 .08 3013 .30 5945783. 84 561842. 75 MWD+IFR-AK-CAZ-SC 4776.45 63. 61 48 .37 3036 .12 2927 .12 27 .48 3079 .96 5945836. 91 561908. 99 MWD+IFR-AK-CAZ-SC 4872.66 62. 93 42 .02 3079 .43 2970 .43 87 .98 3140 .89 5945897. 88 561969. 44 MWD+IFR-AK-CAZ-SC 4966.48 62. 78 36 .83 3122 .25 3013 .25 152 .43 3193 .89 5945962. 74 562021. 92 MWD+IFR-AK-CAZ-SC ', 5061.23 63. 60 30 .93 3165 .02 3056 .02 222 .60 3240 .99 5946033. 27 562068. 47 MWD+IFR-AK-CAZ-SC 'i • Halliburton Company Survey Report __ __ Company: ConocoPhillips Alaska Inc. Date: 12/19/2006 Time: 14:46:25 Page:. 3 Field: Kuparuk River Unit Co-ordinate(NE) Reference:. Well: 1J-115True North Site: Kuparuk 1J Pad Vertical (TV D) Reference: 1J-115L2P62:109.0 Well: 1J-115 Section (VS) Reference: Well (O.OON,O.OOE,O.OOAzi) ~4cllpath: 1J-115L2P62 Survey Calculation Method: Minimum Curvature Db: Oracle Sunet ~1D [ncl Azim TVD SysTVD N/S E/W ~1apN MapE 'f'ool 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 i 5537.28 64.76 24.25 3371.36 3262.36 610.62 3423.41 5946422.67 562247.84 MWD+IFR-AK-CAZ-SC I' 5630.91 66.63 19.01 3409.92 3300.92 689.92 3454.82 5946502.20 562278.63 MWD+IFR-AK-CAZ-SC 5724.54 69.47 14.47 3444.93 3335.93 773.05 3479.79 5946585.52 562302.94 MWD+IFR-AK-CAZ-SC 5818.75 70.89 10.45 3476.88 3367.88 859.57 3498.90 5946672.18 562321.37 MWD+IFR-AK-CAZ-SC 7 7 WD+IFR-AK-CAZ-SC ' 5915.97 72.53 6.28 3507.41 3398.41 950.88 3512.30 5946 63 5 562334.06 M 6011.71 75.39 0.95 3533.87 3424.87 1042.66 3518.07 5946855.39 562339.11 MWD+IFR-AK-CAZ-SC 6094.00 76.79 356.48 3553.67 3444.67 1122.49 3516.27 5946935.20 562336.69 MWD+IFR-AK-CAZ-SC 6121.47 77.39 356.00 3559.80 3450.80 1149.21 3514.52 5946961.90 562334.72 MWD+IFR-AK-CAZ-SC 6180.00 80.29 355.08 3571.13 3462.13 1206.45 3510.05 5947019.10 562329.81 MWD+IFR-AK-CAZ-SC 6209.13 78.63 357.07 3576.46 3467.46 1235.02 3508.09 5947047.65 562327.63 MWD+IFR-AK-CAZ-SC ~ 6303.26 82.01 3.45 3592.30 3483.30 1327.74 3508.53 5947140.37 562327.35 MWD+IFR-AK-CAZ-SC 6332.99 82.51 4.99 3596.30 3487.30 1357.12 3510.70 5947169.76 562329.29 MWD+IFR-AK-CAZ-SC 6398.63 85.57 4.79 3603.12 3494.12 1422.16 3516.27 5947234.83 562334.34 MWD+IFR-AK-CAZ-SC 6430.98 87.74 4.11 3605.01 3496.01 1454.36 3518.77 5947267.04 562336.59 MWD+IFR-AK-CAZ-SC 6490.64 91.70 2.12 3605.30 3496.30 1513.91 3522.01 5947326.62 562339.37 MWD+IFR-AK-CAZ-SC 6584.05 93.34 357.02 3601.19 3492.19 1607.20 3521.32 5947419.88 562337.94 MWD+IFR-AK-CAZ-SC i 6677.90 91.15 356.37 3597.51 3488.51 1700.81 3515.91 5947513.44 562331.81 MWD+IFR-AK-CAZ-SC 47 6.31 4. MWD+IFR-AK-CAZ-SC 6771.11 90.48 355.03 3596.19 3487.19 1793.75 3508.92 59 60 56232 09 6822.96 91.98 353.07 3595.07 3486.07 1845.30 3503.55 5947657.82 562318.32 MWD+IFR-AK-CAZ-SC 6863.05 90.90 353.30 3594.07 3485.07 1885.10 3498.79 5947697.57 562313.25 MWD+IFR-AK-CAZ-SC 6905.22 90.48 351.00 3593.56 3484.56 1926.87 3493.03 5947739.29 562307.17 MWD+IFR-AK-CAZ-SC 6957.07 91.05 351.86 3592.87 3483.87 1978.13 3485.31 5947790.49 562299.04 MWD+IFR-AK-CAZ-SC 7051.76 88.68 353.93 3593.09 3484.09 2072.08 3473.60 5947884.34 562286.60 MWD+IFR-AK-CAZ-SC 7102.49 88.64 356.24 3594.28 3485.28 2122.61 3469.25 5947934.82 562281.86 MWD+IFR-AK-CAZ-SC 7144.23 89.01 357.90 3595.13 3486.13 2164.28 3467.12 5947976.48 562279.40 MWD+IFR-AK-CAZ-SC 7192.81 88.44 359.61 3596.21 3487.21 2212.84 3466.06 5948025.02 562277.97 MWD+IFR-AK-CAZ-SC i 7230.00 88.44 359.61 3597.22 3488.22 2250.01 3465.81 5948062.18 562277.42 PROJECTED to TD C 28-Dec-06 AOGCC Librarian 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 Re: Distribution of Survey Data for Well 1 J-115 L2 Dear Dear Sir/Madam: Enclosed is one disk with the *.PTT and *.PDF files. Tie-on Survey: 6,905.22' MD Window /Kickoff Survey 6,930.00' MD (if applicable) Projected Survey: 14,000.00' 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) ~o~ - t ~y • 28-Dec-06 AOGCC Librarian 333 W . 7th Ave. Suite 100 Anchorage, AK 99501 Re: Distribution of Survey Data for Well 1J-115 L2 PB1 Dear Dear Sir/Madam: Enclosed is one disk with the *.PTT and *.PDF files. Tie-on Survey: 6,011.71 ' MD Window /Kickoff Survey 6,094.00' MD (if applicable) Projected Survey: 6,245.00' 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) 2~~- 11~a • 28-Dec-06 AOGCC Librarian 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 Re: Distribution of Survey Data for Well 1 J-115 L2 PB2 Dear Dear Sir/Madam: Enclosed is one disk with the *.PTT and *.PDF files. Tie-on Survey: 6,121.47' MD Window /Kickoff Survey 6,180.00' MD (if applicable) Projected Survey: 7,230.00' 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 t~ r / ~ / _ , Date r111 clt.. ~~07 Signed Please call me at 273-3534 if you have any questions or concerns. Regards, Timothy Allen Survey Manager Attachment(s) • Randy Thomas Greater Kuparuk Area Drilling Team Leader ConocoPhillips Alaska, Inc. PO Box 100360 Anchorage, AK 99510-0360 FRANK H. MURKOWSKI, GOVERNOR 333 W. 7T" AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Re: Kuparuk River Field, West Sak Oil Pool, 1J-115L2 ConocoPhillips Alaska, Inc. Permit No: 206-124 Surface Location: 1973' FSL, 2380' FEL, SEC. 35, T 11 N, R 10E, UM Bottomhole Location: 368' FSL, 4617' FEL, SEC. 24, T 11 N, R 10E, UM Dear Mr. Thomas: Enclosed is the approved application for permit to drill the above referenced development well. This permit to drill does not exempt you from obtaining additional permits or an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. When providing notice for a representative of the Commission to witness an required test, contact the Commission's petroleum field inspector at (907)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 1~ RECEIVED AUG 1 6 2006 PERMIT TO DRILL Alaska Oil & Gas Cons. Commission 20 AAC 25.005 1a. Type of Work: Drill Q Re-drill ^ Re-entry ^ 1b. Current Well Class: Exploratory Development Oil ^/ Stratigraphic Test ^ Service ^ Development Gas ^ Multiple Zone ^ Single Zone ^/ 1c. Specify if well is proposed for: Coalbed Methane ^ Gas Hydrates ^ Shale Gas ^ 2. Operator Name: ConocoPhillipsAlaska, Inc. 5. Bond: / Blanket Single Well Bond No. 59-52-180 ~ 11. Well Name and Number: 1J-115L2 ' 3. Address: P.O. Box 100360 Anchorage, AK 99510-0360 6. Proposed Depth: MD: 14020' • TVD: 3707' 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: 3109' FSL, 4129' FEL, Sec. 36, T11 N, R10E, UM ' 8. Land Use Permit: ALK 471, 468 13. Approximate Spud Date: 10/16/2006 Total Depth: 368' FSL, 4617' 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 1~D' tancg toJVe~e~st ~~ ~~ Well within Pool: none , 8 . ~G-~ 16. Deviated wells: Kickoff depth: 6159 ` ft. Maximum Hole Angle: 93° deg 17. Maximum Anticipated Pressures in psig (see 20 AAC 25.035) Downhole: 1668 psig Surface: 1298 psig 18. Casing Program S if ti Setting Depth Quantity of Cement Size ons pec ica 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 7861' 6159' 3574' 14020' 3707' 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/Structu ra I Surface Intermediate Production Liner Perforation Depth MD (ft): ~ J 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 ^/ 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 `~i~dZ~'~ • ~°~ ~i r~ Phone Date P r h n All r k Commission Use Only Permit to Drill Number: Z.dW~- t/+~ API Number: 50- ~2 / ~233~ ~t1p' 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 [~ Mu g re 'd: Yes ^ No [~ Other:~~OOPS `~~'p'~S~ CxS ~i:~~/ ,H2S measures: Yes ^ No irecti q'd: Yes [~ No ^ ED BY THE COMMISSION DATE: ~ O ,COMMISSIONER Form 10-401 Revised 12/2005 ~ ~~~ ~ `~ = '-~~' -° ~~ ~ Submit in Duplicate v ,/~ l~~ .4~ 8. /G -off • Appli~ for Permit to Drill, Well 1J-115 L2 Revision No.O Saved: 15-Aug-06 Permit It -West Sak Well #1J-115 L2 Application for Permit to Drill Document V~~~I VQi,ue 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)(8) ................................................................................................... 4 Lateral Mud Program (MI VersaPro Mineral Oil ease) ........................................................................... 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 1J-115L2 PERMIT /T Page 1 of 6 Printed: 15-Aug-06 ~ ~` ~ . ~ ~~ ~ -~ • Appli~ for Permit to Drill, Well 1 J-115 L2 Revision No.O 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 Aftachment 1 Directional Plan ................................................................................................................ 6 Attachment 2 Drilling Hazards Summary ............................................................................................... 6 Aftachment 3 Well Schematic ................................................................................................................ 6 1. Well Name Requirements of 20 AAC 25.005 (f) Each well must be identified by a unique name designated by the operator and a unique API number 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 L2. 2. Location Summary Requirements of 20 AAC 25.005(c)(2) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on frle 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 3,109' FSL, 4,129' FEL, Section 36, T11N, R10E West Sak °D" Sand ASP Zone 4 NAD 27 Coordinates Measured De th, RKB: 6 159 Northings: 5,946,950 Eastings: 562,350 Total Vertical De th, RKB: 3,574 Total Vertical De th, SS: 3 465 Location at Total De th 368' FSL 4,617' FEL, Section 24, T11N, R10E ASP Zone 4 NAD 27 Coordinates Measured De th, RKB: 14,020 Northings: 5,954,764 Eastings: 561,793 Total Vertical De th, RKB: 3,707 Total Vertical De th, SS: 3 598 and (D) other information required by 20 AAC 25.050(6); 1J-115L2 PERMIT IT Page 2 of 6 Printed: 15-Aug-06 • Appli~ for Permit to Drill, Well 1 J-115 L2 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 10-40i) 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 (t3) 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 (t30PE) 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 the well. 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 1J area are 0.45 psi/ft, or 8.7 ppg EMW (equivalent mud weight). Pressures are predicted based on the undisturbed West Sak pressure gradient. The maximum potential surface pressure (MPSP) based on the above maximum pressure gradient, a methane gradient (0.11), and the deepest planned vertical depth of the West Sak ~~D" sand formation is 1,298 psi, calculated thusly: MPSP = (3,707 ft TVD)(0.45 - 0.11 psi/ft) = 1,298 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: 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 25.0300; 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. ~~ M1 s t ~~ n '~ ~~ t~ u ~ ~.rt. 1J-115L2 PERMIT IT Page 3 of 6 Printed: 15-Aug-O6 C Appli~ for Permit to Drill, Well 1 J-115 L2 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; Casing and Cementing Program See also Attachment 3: Cement Summary 7. Diverter System Information Requirements of 20 AAC 25.005(c)(7) r, 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 1J-115 L2. 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 s 15 - 25 Yield Point (cP) 18 - 28 HTHP Fluid loss (ml/30 min @ 200 si & 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-115L2 PERMIT IT Page 4 of 6 z ~~ : _ Printed: 15-Aug-O6 Hole Top Btm Csg/Tbg Size Weigh Length MD/TI/D MD/TVD OD in in t Ib/ft Grade Connection ft ft ft Cement Pro ram 4-1/2 6-3/4" A Sand 11.6 L-80 BTC 7,166 6,596 / 3,630 13,762 / 3,907 Slotted- no cement slotted Lateral (1]-115) 4-1/2 6-3/4" a sand 11.6 L-80 BTC 7,456 6,498 / 3,648 13,954 / 3,767 Slotted- no cement 4-1/2 6-3/4" D Sand 11.6 L-80 BTC 7,861 6,159 / 3,574 14,020 / 3,707 Slotted- no cement slotted Lateral (iJ-115 L2) i • Appli~ for Permit to Drill, Well 1 J-115 L2 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 25.033(f); Not applicable: Application is not for an exploratory or stratigraphic test well. 10. Seismic Analysis Requirements of 20 AAC 25.005 (c)(10) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (10) for an exploratory or stratigraphic test well, a seismic refraction or reflection analysis as required by 20 AAC 25.061(a); Not applicable: Application is not for an exploratory or stratigraphic test well. 11.Seabed Condition Analysis Requirements of 20 AAC 25.005 (c)(11) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (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 +/- 6,159' MD / 3,574' TVD, the top of the D 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 D sand lateral at +/- 14,020' MD / 3,707' 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-115L2 PERMIT IT Page 5 of 6 Printed: 15-Aug-06 b x k ~ ~ ~; • Appli~ for Permit to Drill, Well 1 J-115 L2 Revision No.0 Saved: 15-Aug-O6 10. Make up junction isolation / re-entry assembly (Lateral Entry Module or LEM) and RIH to depth. Orient and set packer atop assembly and release from assembly. 11. POOH, laying down drill pipe as required. 12. PU completion as required and RIH to depth. Land tubing. Set BPV. 13. Nipple down BOPE, nipple up tree and test. Pull BPV. 14. Freeze protect well with diesel. 15. Set BPV and move rig off. 14. Discussion of Mud and Cuttings Disposal and Annular Disposal Requirements of 20 AAC 25.005 (c)(14) An application for a Permit to Drill 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 iJ 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-115L2 PERMIT IT Page 6 of 6 Printed: 15-Aug-06 • • ~..~ ConocoPhillips Alaska ConocoPhillips Alaska Inc. 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Q C ` ? q ~ ~ rn ~ ~~vr ~•3 O cf ;a J N~wri a y ~ Q C~~~~ z.-N~ O 3w ~ , Y~C~~o a 0 E F m`m~~3 C C ~°oo }~ e-v. °o ~ QQ N YYaa,Jr, v ..~ i : y ~~ 1y ~ O r O O O O O O O O O O l 7 O O O O ~ O N O O a ~~ O N ~ ~ O t` N O f^O O ~ N O V N M O M l N ~ r t` N a ( ui~'0 056) (+)UI ~oN/(-)U lnoS ~ ~-` Halliburton Energy Services H.a~.L~eugni Canaco Ph~lli s p Planning Report -Geographic ~ Sperry Drilling Services Database: _EDM_2003.11_b48 Local Co-ordinate Reference: WeIF Plan 1J-115 -Slot 1J-115 Company: ConocoPhillips Alaska Inc. TVD Reference: Plan RK6 @ 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 Reference: True ' Well: Plan 1J-115 Survey Calculation Method: Minimum Curvature Wellbore: Plan 1J-115 L2 Design: 1 J-115 L2 (wp05) Project Kuparuk River Unit, North Slope Alaska, United States Map System: US State Plane 1927 (Exact solution) System Datum: Mean Sea Level Geo Datum: NAD 1927 (NADCON CONUS) Using Well Reference Point Map Zone: Alaska Zone 04 Using geodetic scale factor Well Plan 1 J-115 -Slot 1 J-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 Elevation: ft Ground Level: 81.OOft Wellbore Plan 1J-115 L2 Magnetics Model Name Sample Date Declination Dip Angle Field Strength BGGM2005 5/15/2006 24.09 80.77 57,565 Design 1J-115 L2{wp05) Audit Notes: Version: Phase: PLAN Tie On Depth: 6,159.61 Vertical Section: Depth From (TVD) +N/-S +E/-W Direction (ft) (ft) (ft) (°) 28.00 0.00 0.00 0.00 6/17/2006 11:24:48AM Page 2 of 8 COMPASS 2003.11 Build 50 ~~ ~< }:~ ,~ f Conacal~hitlips Alaska Database: _EDM_2003.11_b48 Company: ConocoPhillips Alaska Inc. Project: Kuparuk River Unit Site: Kuparuk 1J Pad Well: Plan 1J-115 Wellbore: Plan 1J-115 L2 Design: 1J-115 L2 (wp05) Sp~mf ng ~ Local Co-ordinate Reference: Well Plan 1J-115 -Slot 1J-115 TVD Reference: Plan RKB @ 109.OOft (Doyon 141 (28 + 81)) MD Reference: Plan RKB @ 109.OOft (Doyon 141 (28 + 81)) North Reference: True Survey Calculation Method: Minimum Curvature Plan Summary Measured Vertical Dogleg Build Turn Depth Inclination Azimuth Depth +N/-S +E!-W Rate Rate Rate TFO (ft1 (°) (°) (ft) (ft) (ft) ('/100ft) (°/100ft) (°/100ft) l°) 6,159.61 77.00 0.00 3,574.00 1,137.18 3,529.70 0.00 0.00 0.00 0.00 6,171.61 78.91 0.00 3,576.50 1,148.92 3,529.70 15.90 15.90 0.00 0.00 6,201.61 78.91 0.00 3,582.27 1,178.36 3,529.70 0.00 0.00 0.00 0.00 6,485.06 93.00 350.43 3,602.27 1,459.07 3,506.00 6.00 4.97 -3.38 325.42 6,685.06 93.00 350.43 3,591.80 1,656.01 3,472.79 0.00 0.00 0.00 0.00 6,779.96 89.21 350.33 3,589.98 1,749.54 3,456.94 4.00 -4.00 -0.10 -178.53 8,974.42 89.21 350.33 3,620.41 3,912.63 3,088.47 0.00 0.00 0.00 0.00 9,203.21 90.00 359.45 3,622.00 4,140.26 3,068.13 4.00 0.35 3.99 85.06 9,549.21 90.00 359.45 3,622.00 4,486.24 3,064.80 0.00 0.00 0.00 0.00 9,574.97 89.25 359.63 3,622.17 4,512.01 3,064.60 3.00 -2.92 0.70 166.43 10,248.40 89.25 359.63 3,631.00 5,185.37 3,060.27 0.00 0.00 0.00 0.00 10,250.69 89.28 359.57 3,631.03 5,187.65 3,060.25 3.00 1.23 -2.73 -65.72 11,424.71 89.28 359.57 3,645.85 6,361.55 3,051.42 0.00 0.00 0.00 0.00 11,448.82 90.00 359.57 3,646.00 6,385.66 3,051.24 3.00 3.00 0.00 0.09 11,748.82 90.00 359.57 3,646.00 6,685.65 3,048.98 0.00 0.00 0.00 0.00 11,772.32 89.30 359.53 3,646.14 6,709.15 3,048.80 3.00 -3.00 -0.17 -176.75 12,248.97 89.30 359.53 3,652.00 7,185.74 3,044.89 0.00 0.00 0.00 0.00 12,285.37 88.21 359.64 3,652.79 7,222.14 3,044.63 3.00 -2.98 0.30 174.25 14,020.17 88.21 359.64 3,707.00 8,956.05 3,033.72 0.00 0.00 0.00 0.00 6/17/2006 1124:48AM Hall~burton Energy Services if-trQl~.~r ~ ulAr©It~)I Planning Report -Geographic ~ ©~~~~ ~ lcss Page 3 of 8 j t ..,.,~ COMPASS 2003.11 Build 50 `Ir' ConatoPh~itips AIBSIca Database: _EDM_2003.11_b48 Company: ConocoPhillips Alaska Inc. Project: Kuparuk River Unit Site: Kuparuk 1J Pad Well: Plan 1J-115 Wellbore: Plan 1 J-115 L2 Design: 1 J-115 L2 (wp05) Halliburton Energy Services LL~I~ru'TO Planning Report -Geographic ~*rY Dsllling ~rvicss Local Co-ordinate Reference: WeII 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)) North Reference: True Survey Calculation Method: Minimum Curvature Planned Survey 1 J-115 L2 (wp05) Map Map MD Inclination Azimuth TVD SSTVD +N!-S +E/-W Northing Easting DLSEV Vert Section lft) (°) (°) !ft) Iftl lft) (ft1 (ft) (ft) (°/100ft) (ft) 6,159.61 77.00 0.00 3,574.00 3,465.00 1,137.18 3,529.70 5,946,950.00 562,350.00 0.00 1,137.18 L2 : TOW @ 6159.62ft M D, 3574.OOft TVD - 3109ft FSL 8 4129ft FEL -Sec 36 - T11 N - R10E - 7 5/8" 6,171.61 78.91 0.00 3,576.50 3,467.50 1,148.92 3,529.70 5,946,961.73 562,349.91 15.90 1,148.92 L2 : BOW @ 6171.62ft MD, 3576.5 1ft TVD 6,200.00 78.91 0.00 3,581.97 3,472.97 1,176.78 3,529.70 5,946,989.59 562,349.69 0.00 1,176.78 6,201.61 78.91 0.00 3,582.27 3,473.27 1,178.36 3,529.70 5,946,991.17 562,349.68 0.00 1,178.36 L2 : Build @ 6 °1100ft to 93° Inc - 6202ft MD, 3582ft TVD 6,300.00 83.78 356.63 3,597.08 3,488.08 1,275.54 3,526.83 5,947,088.31 562,346.04 6.00 1,275.54 6,400.00 88.76 353.28 3,603.58 3,494.58 1,374.90 3,518.04 5,947,187.59 562,336.49 6.00 1,374.90 6,485.06 93.00 350.43 3,602.27 3,493.27 1,459.07 3,506.00 5,947,271.65 562,323.78 6.00 1,459.07 L2 : Sail @ 93 ° Inc : 6485ft MD, 3602ft TVD 6,500.00 93.00 350.43 3,601.49 3,492.49 1,473.77 3,503.52 5,947,286.34 562,321.19 0.00 1,473.77 6,600.00 93.00 350.43 3,596.26 3,487.26 1,572.25 3,486.91 5,947,384.67 562,303.82 0.00 1,572.25 6,685.06 93.00 350.43 3,591.80 3,482.80 1,656.01 3,472.79 5,947,468.31 562,289.04 0.00 1,656.01 L2 : Continue Geosteering in D-Sand, 6685ft M D, 3592ft TVD 6,700.00 92.40 350.41 3,591.10 3,482.10 1,670.72 3,470.31 5,947,483.00 562,286.45 3.99 1,670.72 6,779.96 89.21 350.33 3,589.98 3,480.98 1,749.54 3,456.94 5,947,561.70 562,272.47 4.00 1,749.54 6,800.00 89.21 350.33 3,590.26 3,481.26 1,769.29 3,453.58 5,947,581.43 562,268.95 0.00 1,769.29 6,900.00 89.21 350.33 3,591.64 3,482.64 1,867.86 3,436.78 5,947,679.86 562,251.39 0.00 1,867.86 7,000.00 89.21 350.33 3,593.03 3,484.03 1,966.43 3,419.99 5,947,778.28 562,233.83 0.00 1,966.43 7,100.00 89.21 350.33 3,594.42 3,485.42 2,065.00 3,403.20 5,947,876.71 562,216.27 0.00 2,065.00 7,200.00 89.21 350.33 3,595.80 3,486.80 2,163.58 3,386.41 5,947,975.14 562,198.71 0.00 2,163.58 7,300.00 89.21 350.33 3,597.19 3,488.19 2,262.15 3,369.62 5,948,073.56 562,181.15 0.00 2,262.15 7,400.00 89.21 350.33 3,598.58 3,489.58 2,360.72 3,352.83 5,948,171.99 562,163.60 0.00 2,360.72 7,500.00 89.21 350.33 3,599.96 3,490.96 2,459.29 3,336.04 5,948,270.42 562,146.04 0.00 2,459.29 7,600.00 89.21 350.33 3,601.35 3,492.35 2,557.86 3,319.25 5,948,368.84 562,128.48 0.00 2,557.86 7,700.00 89.21 350.33 3,602.74 3,493.74 2,656.43 3,302.46 5,948,467.27 562,110.92 0.00 2,656.43 7,800.00 89.21 350.33 3,604.12 3,495.12 2,755.00 3,285.67 5,948,565.70 562,093.36 0.00 2,755.00 7,900.00 89.21 350.33 3,605.51 3,496.51 2,853.57 3,268.88 5,948,664.13 562,075.80 0.00 2,853.57 8,000.00 89.21 350.33 3,606.90 3,497.90 2,952.14 3,252.09 5,948,762.55 562,058.24 0.00 2,952.14 8,100.00 89.21 350.33 3,608.28 3,499.28 3,050.71 3,235.30 5,948,860.98 562,040.68 0.00 3,050.71 8,200.00 89.21 350.33 3,609.67 3,500.67 3,149.28 3,218.51 5,948,959.41 562,023.13 0.00 3,149.28 8,300.00 89.21 350.33 3,611.06 3,502.06 3,247.85 3,201.71 5,949,057.83 562,005.57 0.00 3,247.85 8,400.00 89.21 350.33 3,612.44 3,503.44 3,346.42 3,184.92 5,949,156.26 561,988.01 0.00 3,346.42 8,500.00 89.21 350.33 3,613.83 3,504.83 3,444.99 3,168.13 5,949,254.69 561,970.45 0.00 3,444.99 8,600.00 89.21 350.33 3,615.22 3,506.22 3,543.56 3,151.34 5,949,353.11 561,952.89 0.00 3,543.56 8,700.00 89.21 350.33 3,616.60 3,507.60 3,642.13 3,134.55 5,949,451.54 561,935.33 0.00 3,642.13 8,800.00 89.21 350.33 3,617.99 3,508.99 3,740.70 3,117.76 5,949,549.97 561,917.77 0.00 3,740.70 8,900.00 89.21 350.33 3,619.38 3,510.38 3,839.27 3,100.97 5,949,648.39 561,900.22 0.00 3,839.27 8,974.42 89.21 350.33 3,620.41 3,511.41 3,912.63 3,088.47 5,949,721.65 561,887.15 0.00 3,912.63 9,000.00 89.29 351.35 3,620.75 3,511.75 3,937.88 3,084.40 5,949,746.86 561,882.88 3.99 3,937.88 9,100.00 89.64 355.34 3,621.68 3,512.68 4,037.18 3,072.82 5,949,846.06 561,870.52 4.00 4,037.18 9,200.00 89.99 359.32 3,622.00 3,513.00 4,137.05 3,068.16 5,949,945.88 561,865.08 4.00 4,137.05 9,203.21 90.00 359.45 3,622.00 3,513.00 4,140.26 3,068.13 5,949,949.09 561,865.02 4.00 4,140.26 9,300.00 90.00 359.45 3,622.00 3,513.00 4,237.05 3,067.20 5,950,045.86 561,863.34 0.00 4,237.05 9,400.00 90.00 359.45 3,622.00 3,513.00 4,337.04 3,066.24 5,950,145.83 561,861.60 0.00 4,337.04 9,500.00 90.00 359.45 3,622.00 3,513.00 4,437.04 3,065.28 5,950,245.81 561,859.86 0.00 4,437.04 8/17/2006 11;24:48AM Page 4 of 8 COMPASS 2003.11 Build 50 ~..s' a w., J ., ~o..~`'3 :..xa ~ • ~.-' H alliburton Energy Services IE"~URTC~N AIC ! ~Ot"IOCC)~11~~1~35 Planning Report -Geographic . _ H Alaska Sperry E>trilitng Sarvleea Database: EDM_2003.11 b48 Local Co-ordinate Reference: Well Plan 1J-115.-$lot 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 Reference: True Well: Plan 1J-115 Survey Calculation Method: Minimum Curvature Wellbore: Plan 1J-115 L2 Design: 1J-115 L2 (wp05) Planned Survey 1J-115 L2 (wp05) Map Map MD Inclination Azimuth TVD SSTVD +N/-S +E/-W Northing Easting DLSEV Vert Section (ft) (°) (°) (ft) Ift1 (ft) (ft) Ift) (ft) (°/100ft) (ftl 9,549.21 90.00 359.45 3,622.00 3,513.00 4,486.24 3,064.80 5,950,295.00 561,859.00 0.00 4,486.24 1J-115 L2 T1 (wp05) 9,574.97 89.25 359.63 3,622.17 3,513.17 4,512.01 3,064.60 5,950,320.76 561,858.59 3.00 4,512.01 9,600.00 89.25 359.63 3,622.50 3,513.50 4,537.03 3,064.44 5,950,345.78 561,858.24 0.00 4,537.03 9,700.00 89.25 359.63 3,623.81 3,514.81 4,637.02 3,063.79 5,950,445.75 561,856.81 0.00 4,637.02 9,800.00 89.25 359.63 3,625.12 3,516.12 4,737.01 3,063.15 5,950,545.72 561,855.39 0.00 4,737.01 9,900.00 89.25 359.63 3,626.43 3,517.43 4,837.00 3,062.51 5,950,645.69 561,853.96 0.00 4,837.00 10,000.00 89.25 359.63 3,627.74 3,518.74 4,936.99 3,061.86 5,950,745.67 561,852.54 0.00 4,936.99 10,100.00 89.25 359.63 3,629.05 3,520.05 5,036.98 3,061.22 5,950,845.64 561,851.11 0.00 5,036.98 10,200.00 89.25 359.63 3,630.37 3,521.37 5,136.97 3,060.58 5,950,945.61 561,849.69 0.00 5,136.97 10,248.40 89.25 359.63 3,631.00 3,522.00 5,185.37 3,060.27 5,950,994.00 561,849.00 0.00 5,185.37 1J-115 L2 T2 ( wp05) 10,250.69 89.28 359.57 3,631.03 3,522.03 5,187.65 3,060.25 5,950,996.28 561,848.97 3.00 5,187.65 10,300.00 89.28 359.57 3,631.65 3,522.65 5,236.96 3,059.88 5,951,045.58 561,848.21 0.00 5,236.96 10,400.00 89.28 359.57 3,632.91 3,523.91 5,336.95 3,059.13 5,951,145.55 561,846.68 0.00 5,336.95 10,500.00 89.28 359.57 3,634.18 3,525.18 5,436.94 3,058.37 5,951,245.52 561,845.14 0.00 5,436.94 10,600.00 89.28 359.57 3,635.44 3,526.44 5,536.93 3,057.62 5,951,345.49 561,843.61 0.00 5,536.93 10,700.00 89.28 359.57 3,636.70 3,527.70 5,636.92 3,056.87 5,951,445.46 561,842.08 0.00 5,636.92 10,800.00 89.28 359.57 3,637.96 3,528.96 5,736.91 3,056.12 5,951,545.43 561,840.54 0.00 5,736.91 10,900.00 89.28 359.57 3,639.22 3,530.22 5,836.89 3,055.37 5,951,645.40 561,839.01 0.00 5,836.89 11,000.00 89.28 359.57 3,640.49 3,531.49 5,936.88 3,054.61 5,951,745.38 561,837.48 0.00 5,936.88 11,100.00 89.28 359.57 3,641.75 3,532.75 6,036.87 3,053.86 5,951,845.35 561,835.94 0.00 6,036.87 11,200.00 89.28 359.57 3,643.01 3,534.01 6,136.86 3,053.11 5,951,945.32 561,834.41 0.00 6,136.86 11,300.00 89.28 359.57 3,644.27 3,535.27 6,236.85 3,052.36 5,952,045.29 561,832.88 0.00 6,236.85 11,400.00 89.28 359.57 3,645.54 3,536.54 6,336.84 3,051.60 5,952,145.26 561,831.34 0.00 6,336.84 11,424.71 89.28 359.57 3,645.85 3,536.85 6,361.55 3,051.42 5,952,169.96 561,830.96 0.00 6,361.55 11,448.82 90.00 359.57 3,646.00 3,537.00 6,385.66 3,051.24 5,952,194.06 561,830.59 3.00 6,385.66 11,500.00 90.00 359.57 3,646.00 3,537.00 6,436.83 3,050.85 5,952,245.23 561,829.81 0.00 6,436.83 11,600.00 90.00 359.57 3,646.00 3,537.00 6,536.83 3,050.10 5,952,345.21 561,828.28 0.00 6,536.83 11,700.00 90.00 359.57 3,646.00 3,537.00 6,636.83 3,049.35 5,952,445.19 561,826.75 0.00 6,636.83 11,748.82 90.00 359.57 3,646.00 3,537.00 6,685.65 3,048.98 5,952,494.00 561,826.00 0.00 6,685.65 1J-115 L2 T3 (wp05) 11,772.32 89.30 359.53 3,646.14 3,537.14 6,709.15 3,048.80 5,952,517.50 561,825.63 3.00 6,709.15 11,800.00 89.30 359.53 3,646.48 3,537.48 6,736.82 3,048.57 5,952,545.17 561,825.19 0.00 6,736.82 11,900.00 89.30 359.53 3,647.71 3,538.71 6,836.81 3,047.75 5,952,645.14 561,823.59 0.00 6,836.81 12,000.00 89.30 359.53 3,648.94 3,539.94 6,936.80 3,046.93 5,952,745.11 561,821.99 0.00 6,936.80 12,100.00 89.30 359.53 3,650.17 3,541.17 7,036.79 3,046.11 5,952,845.08 561,820.39 0.00 7,036.79 12,200.00 89.30 359.53 3,651.40 3,542.40 7,136.78 3,045.29 5,952,945.05 561,818.78 0.00 7,136.78 12,248.97 89.30 359.53 3,652.00 3,543.00 7,185.74 3,044.89 5,952,994.00 561,818.00 0.00 7,185.74 1J-115 L2 T4 (wp05) 12,285.37 88.21 359.64 3,652.79 3,543.79 7,222.14 3,044.63 5,953,030.39 561,817.45 3.00 7,222.14 12,300.00 88.21 359.64 3,653.25 3,544.25 7,236.76 3,044.54 5,953,045.01 561,817.25 0.00 7,236.76 12,400.00 88.21 359.64 3,656.37 3,547.37 7,336.71 3,043.91 5,953,144.94 561,815.84 0.00 7,336.71 12,500.00 88.21 359.64 3,659.50 3,550.50 7,436.66 3,043.28 5,953,244.87 561,814.43 0.00 7,436.66 12,600.00 88.21 359.64 3,662.62 3,553.62 7,536.60 3,042.65 5,953,344.80 561,813.02 0.00 7,536.60 12,700.00 88.21 359.64 3,665.75 3,556.75 7,636.55 3,042.02 5,953,444.73 561,811.61 0.00 7,636.55 12,800.00 88.21 359.64 3,668.87 3,559.87 7,736.50 3,041.39 5,953,544.66 561,810.20 0.00 7,736.50 12,900.00 88.21 359.64 3,672.00 3,563.00 7,836.45 3,040.76 5,953,644.60 561,808.79 0.00 7,836.45 6/17/2006 11:24:48AM Page 5 of 8 COMPASS 2003.11 Build 50 `~' '~ wn ~ ~ ~ Conc~cc~Phillips Alaska Database: _EDM_2003.11_b48 Local Co-ordinate Reference: Company: ConocoPhillips Alaska Inc. TVD Reference: Project: Kuparuk River Unit MD Reference: Site: Kuparuk 1J Pad North Reference: Well: Plan 1J-115 Survey Calculation Method: Wellbore: Plan 1J-115 L2 Design: 1J-115 L2 (wp05) i IE-rAU.~eu~-or Sperry Drlltn8 Servilces Well Plan 1 J-115 -Slot 1 J-115 Plan RKB @ 109.OOft (Doyon 141 (28 + 81)) Plan RKB @ 109.OOft (Doyon 141 (28 + 81 p True Minimum Curvature Planned Survey 1J-115 L2 (wp05) Map Map MD Inclination Azimuth TVD SSTVD +N/-S +E/-W Northing Easting DLSEV Vert Section (ft) (°) (°) (ft) (ft) (ft) lft) (ft) (ftl (°I100ft) (ft) 13,000.00 88.21 359.64 3,675.12 3,566.12 7,936.40 3,040.13 5,953,744.53 561,807.38 0.00 7,936.40 13,100.00 88.21 359.64 3,678.25 3,569.25 8,036.35 3,039.51 5,953,844.46 561,805.97 0.00 8,036.35 13,200.00 88.21 359.64 3,681.37 3,572.37 8,136.30 3,038.88 5,953,944.39 561,804.56 0.00 8,136.30 13,300.00 88.21 359.64 3,684.50 3,575.50 8,236.25 3,038.25 5,954,044.32 561,803.15 0.00 8,236.25 13,400.00 88.21 359.64 3,687.62 3,578.62 8,336.20 3,037.62 5,954,144.25 561,801.74 0.00 8,336.20 13,500.00 88.21 359.64 3,690.75 3,581.75 8,436.15 3,036.99 5,954,244.19 561,800.33 0.00 8,436.15 13,600.00 88.21 359.64 3,693.87 3,584.87 8,536.10 3,036.36 5,954,344.12 561,798.92 0.00 8,536.10 13,700.00 88.21 359.64 3,697.00 3,588.00 8,636.05 3,035.73 5,954,444.05 561,797.51 0.00 8,636.05 13,800.00 88.21 359.64 3,700.12 3,591.12 8,735.99 3,035.10 5,954,543.98 561,796.10 0.00 8,735.99 13,900.00 88.21 359.64 3,703.25 3,594.25 8,835.94 3,034.48 5,954,643.91 561,794.69 0.00 8,835.94 14,000.00 88.21 359.64 3,706.37 3,597.37 8,935.89 3,033.85 5,954,743.84 561,793.28 0.00 8,935.89 ' 14,020.17 88.21 359.64 3,707.00 3,598.00 8,956.05 3,033.72 5,954,764.00 561,793.00 0.00 8,956.05 L2 BHL @ 14020ft MD, 3707ft TVD : 368ft FSL & 4617ft FEL -Sec 24 - T11N - R10E - 4 1/2" 6/17/2006 11:24:48AM Page 6 of 8 COMPASS 2003.11 Build 50 Halliburton Energy Services Planning Report -Geographic ~ "~ j.. v ¢. t i1 ~, tr,.. ~' , ~ Halliburton Energy Services CortocoRh'Ht s Ha~L~su~Tlc~N ~ Planning Report -Geographic Sperry Drilling Services 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 (Doyon141 (28 + 81 p Project Kuparuk River unit MD Reference: Plan RKB @ f09.00ft (Doyon 141 (28 + 81)) Site: Kuparuk 1JPad North Reference: True , Well: Plan 1J-115 Survey Calculation Method: Minimum Curvature Wellbore: Plan 1J-115 L2 Design: 1J-115 L2 (wp05) Geologic Targets Plan 1J-115 L2 TVD Target Name +N(-S +E/-W Northing Easting (ft) -Shape ft ft (ft) (ft) 3,646.00 1J-115 L2 T3 (wp05) 6,685.65 3,048.98 5,952,494.00 561,826.00 - Point 3,622.00 1J-115 L2 T1 (wp05) 4,486.24 3,064.80 5,950,295.00 561,859.00 - Point 3,631.00 1J-115 L2 T2 (wp05) 5,185.37 3,060.27 5,950,994.00 561,849.00 - Point 3,652.00 1J-115 L2 T4 (wp05) 7,185.74 3,044.89 5,952,994.00 561,818.00 - Point 3,707.00 1J-115 L2 T5 Toe (wp05) 8,956.05 3,033.72 5,954,764.00 561,793.00 - Point 3,537.00 1J-115 L2 DD Poly (da 95%(wp05) 1,137.19 3,529.70 5,946,950.00 562,350.00 - Polygon Point 1 -50.00 0.39 5,946,950.00 562,300.00 Point 2 -50.00 12.12 5,946,961.73 562,299.91 Point 3 -50.00 41.57 5,946,991.17 562,299.68 Point 4 -69.13 268.24 5,947,217.67 562,278.78 Points -491.61 2,777.68 5,949,723.49 561,836.75 Point 6 -511.58 3,003.47 5,949,949.09 561,815.02 Point? -514.90 3,349.45 5,950,295.00 561,809.00 Point 8 -515.11 3,375.21 5,950,320.76 561,808.59 Point 9 -519.44 4,048.57 5,950,994.00 561,799.00 Point 10 -519.45 4,050.85 5,950,996.28 561,798.97 Point 11 -528.29 5,224.75 5,952,169.96 561,780.96 Point 12 -528.46 5,248.85 5,952,194.06 561,780.60 Point 13 -530.72 5,548.85 5,952,494.00 561,776.00 Point 14 -530.90 5,572.35 5,952,517.50 561,775.63 Point 15 -534.81 6,048.94 5,952,994.00 561,768.00 Point 16 -535.25 6,088.03 5,953,033.08 561,767.26 Point 17 -559.98 7,819.36 5,954,764.00 561,729.00 Point 18 -459.98 7,818.58 5,954,764.00 561,829.00 Point 19 -435.24 6,087.25 5,953,033.08 561,867.26 Point 20 -434.81 6,048.16 5,952,994.00 561,868.00 Point 21 -430.90 5,571.57 5,952,517.50 561,875.63 Point 22 -430.71 5,548.07 5,952,494.00 561,876.00 Point 23 -428.46 5,248.07 5,952,194.06 561,880.60 Point 24 -428.28 5,223.97 5,952,169.96 561,880.96 Point 25 -419.44 4,050.07 5,950,996.28 561,898.97 Point 26 -419.43 4,047.79 5,950,994.00 561,899.00 Point 27 -415.10 3,374.43 5,950,320.76 561,908.59 Point 28 -414.89 3,348.67 5,950,295.00 561,909.00 Point 29 -411.57 3,002.69 5,949,949.09 561,915.02 Point 30 -391.61 2,776.90 5,949,723.49 561,936.75 Point 31 30.87 267.46 5,947,217.67 562,378.78 Point 32 50.00 40.78 5,946,991.17 562,399.68 Point 33 50.00 11.34 5,946,961.73 562,399.91 Point 34 50.00 -0.39 5,946,950.00 562,400.00 6/17/2006 11:24:48AM t+°~~ t Page 7 of 8 ;. COMPASS 2003.11 Build 50 f 4 ~ . ~Ot10CQ~11~~Ip5 Alaska Halliburton Energy Services Planning Report -Geographic Database: _EDM 2003.11 b48 Local Co-ordinate Reference: Company: ConocoPhillipsAlaska Inc. TVD Reference: Project: Kuparuk River Unit MD Reference: Site: Kuparuk 1J Pad North Reference: Well: Plan 1J-115 Survey Calculation Method: Wellbore: Plan 1 J-115 L2 Design: 1 J-115 L2 (wp05) HAI.I..lIE~UR7©N Sperry Drilling. Servltea Well Plan 1J-115 -Slot 1J-115 Plan RKB @ 109.OOft (Doyon 141 (28 + 81 p Plan. RKB @ 109.OOft (Doyon 141 (28 + 81 p True ; Minimum Curvature Prognosed Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (ft) (ft) ('~) (") 3,006.65 2,231.00 10-3/4 13-1/2 6,159.62 3,574.00 7-5/8 9-7/8 14,020.16 3,707.00 4-112 6-3/4 6/17/2006 11:24:48AM Page 8 of 8 COMPASS 2003.11 Build 50 • • ConocoPhillips Alaska ConocoPhillips Alaska Inc. Kuparuk River Unit Kuparuk 1J Pad Plan 1J-115 Plan 1 J-115 L2 Anticollision Report 14 July, 2006 ~ 9 Cn ~ 4 fa F ConocoPhilips Aiaska Company: ConocoPhillips Alaska Inc. Project: Kuparuk River Unit Reference Site: Kuparuk 1J Pad Site Error: O.OOft Reference Well: Plan iJ-115 Well Error: O.OOft Reference Wellbore Plan 1J-115 L2 Reference Design: 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 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: Maximum center-center distance of 1,882.19ft Error Surface: Warning Levels evaluated at: 0.00 Sigma ISCWSA Trav. Cylinder North Elliptical Conic Survey Tool Program Date 6!20/2006 From To (ft) (ft) Survey (Wellbore) Tool Name Description 28.00 800.00 1J-115 (wp05) (Plan 1J-115) CB-GYRO-SS Camera based gyro single shot 800.00 6,159.61 1J-115 (wp05) (Plan 1J-115) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 6,159.61 14,020.16 1J-115 L2 (wp05) (Plan 1J-115 L2) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC Summary Reference Offset Centre to No-Go Allowable Measured Measured Centre Distance Deviation Warning Site Name Depth Depth Distance (ft) from Plan Offset Well -Wellbore -Design (ft) (ft) (ft) (ft) Kuparuk 1J Pad Plan 1J-115 -Plan 1J-115 - 1J-115 (wp05) 6,199.95 6,199.98 1.29 8.27 -6.98 FAIL -Major Risk Plan 1J-115 -Plan 1J-115 L1 - 1J-115 L1 (wp05) 13,951.88 13,955.15 62.20 180.57 -118.37 FAIL -Major Risk CC -Min centre to center distance or covergent point, SF -min separation factor, ES -min ellipse separation 7/14/2006 3:01:11 PM Page 2 of 2 COMPASS 2003.11 Build 48 i µ % ~...;, ~ f A ~ ~~ 9 '~-:, ~ 1J-115L~Drillin~ Hazards ~mmar~ (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-115L2 Drilling Hazards Summary t°~ ~ ~~~ "~ ~ ~ prepared by Shane Cloninger ~`"'~_ ~ ~ 5/12/2006 1:10 PM 0 Insulated Conductor n Casing, 20", 94#, K55 x 0 I 34", 0 3 I2" WT Lr~i, ~ +/- 80' MD N ~~ i ~ y r~ w y rn x rn ~ S S~ B 3 ~~ ~• o o ~ ~ "~ 7 $' `o v e 6 !n 10-3/4", 45.5#, L-80, BTC, R3 ~ ` 2,781' MD / 2,150' TVD ~~ L#, 63 degrees TD 13-1/2" hole Top of Ugnu C ~a1 4,500' M D / 2,840' TVD -~ Wellhead /Tubing Head /Tree, 10-3/4" x 4-%", 5,000 ksi 'Cubing String: 4-I/2", 12.6 #, L-80, 16TH Top or west sak s 6,400' MD / 3,533' TVD - -~ Lateral Entry Module #1 (LEM), Baker, with seal bore and ZXP packer above. b 9 8, °. o ~ ,~ z '~ r N~~R a 5 ~ a: Tubing, 4-%" IBTM, from LEM to - A2 Liner, with seal stem and CAMCO 3.562" "DB" nipple. Seal bore and ZXP packer for A2 liner +/- 90' below "B" window 1'op of West Sak A ate, ~ 6,800' 111D / 3,567 TVD ~ 7-5/3", 29.7#, L-8Q, BTCM, R3 Csg ~ 7,G06' MD / 3 811' TVD @ 85 degrees TD 9-7/8" hole (1) Gas Lift Mandrel, CM(CO 4-I/2" x I" Model ICr[BG w/ dummy valve @, one (q set a 2,400' d(D, 1,977 TVU. (l) Gas Lift Mandrel, CAMCO 4-I/2" x I" Model KMBG w/ dununy valve, (~ < 72 deg, 5,000' MD, 3, 1G2' TVD. Electric Submersible Pump. Centrilift 418 HP motor, with FC6000 wireline deployed pump. Bottom at 5,237 MD, 3,260' TVD 152 L2 "D" Sand Window ~ 6,095' MD / 3,53T TVU 77 degrees "D" Liner, 4-1/2", I L6#, L80, BTC, R3 U-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' T VD le 88 degrees l ----- - --__ 6,464' MD / 3,618' TVD 11-152 L 1: 80 degrees "B" Liner, 4-1/2", 11.6#, L80, BTC, R3 6-3/4" "B" sand lateral (0.125" x 2.5" slots, 32 per foot, 5.9 % open area) TD 13,891' MD / 3,767 TVD Angle 88 degrees 1J-152: A2 Sand Liner, 4-t/2", 11.6#, L80, BTC, 6-3/4 A2 sand lateral R3 % slotted and'/: blank ctirtslriclucs jor TD 13,701' MD / 3 90T TVD csolndarr Angle 88 degrees ~ • TRANSMITTAL LETTER CHECKLIST WELL NAME ~/c G~ /..T~" ~~S G PTD# Z-L~(j ~-' /~ Development Service Exploratory Stratigraphic Test Non-Conventional Well Circle Appropriate Letter /Paragraphs to be Included in Transmittal Letter CHECK ADD-ONS TEXT FOR APPROVAL LETTER WHAT (OPTIONS) ~ APPLIES MULTI LATERAL The permit is for a new wellbore segment of existing / well ~~'~ ~~ l~~ V (If last two digits in permit No. Zli:' /ZZ , API No. 50-d2. - Z.33Z~ -~ . API number are between 60-69) I Production should continue to be reported as a function of the I original API number stated above. i PILOT HOLE In accordance with 20 AAC 25.005(f), all records, data and logs acquired for the pilot hole must be clearly differentiated in both well name ( PH} and API number (50- - -_~ from records, data and logs acquired for well SPACING The permit is approved subject to full compliance with 20 AAC EXCEPTION 25.055. Approval to perforate and produce /inject is contingent ~ upon issuance of a conservation order approving a spacing exception. assumes the ` liability of any protest to the spacing exception that may occur. DRY DITCH All dry ditch sample sets submitted to the Commission must be in SAMPLE no greater than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. Please note the following special condition of this permit: Non-Conventional production or production testing of coal bed methane is not allowed Well for (name of well) until after (Company NameZhas designed and implemented a water well testing program to provide baseline data on water quality and quantity. (Com any Name) must contact the Commission to obtain advance approval of such water well testing rogram. Rev: 1 /25/06 C: ~ j ody\transm itta(_check(ist s • CI ^ ~ N ~ , , m m o a , , N N LO ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ 0 , a 3 ~ ~ ~ m o W o L o, m n, s ~ ~ 4 + , ~, ~ ~ a N c i - a O w N f6 ~ , a; N N ~ p ~ ~ O ~~ ~ ~ ~ ~ ~ ~ Q ~ ~ L• L. ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ O. ~ ~ 'O. `p. ~ C. ~ ~ ~ C ~ ~ f0. ~ ~ O E G O O• o ~ ~ W. i~ ~ ~ >, a~ c ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ 4 ° ~ a, ~ O w, o. 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O. ~ N ~~ . pL N~ N~ Q 4 N, tll~ f0 ~~ N. U. .L.., ~, '~, H . d .. .~ ~ O: f3 f6 ' ' - ~~ f0. y~ ~ ~~ a N O ~~ ~ ° . ~ C. U, T ~'~ i ~° N. ~ a c N~ N. O a~ c• N O. . • O. v m u. O m ~, ~ s, ~, ~, p. a ~, ~, >; -, a~ -o a. v. •-, ~ f6 °' o m ~, .n. .n. a 3, c, -o' rn a w, ~ c a a, ;~ •y a~ a~ m c Y, > .~ ~, 9 ~ ~, L. ~, ~ °- o; ~ a~ w; o, °, ~ _ °~ ~, a ~, N ~ c~ E ii U m ~, ~, a~, a, :? ca, .D O. L, c c • a; c~, ~ 3~ is ~ •° `° `° ~, N _, 3, :° ~ o, ~+ c o f0 • ~ m, c a~, c ~ ~ ~- Z a~ ~ : 3~ ~ u~ m ~ ~ o o .~ o o E o ~, ° ~ iu ~', o o; c~, ~ ° _ -a u? • •-, a?~ a` ~ ~ °, ~ _ % nr ~ ; c ~? m, '~ o n m , ~ ~ ~ ~ . • ' y. ~, , . ' ' ` ~ y ` a o o °i ' ' ~ ~ ~ o 3 ~ ~ , ~~ `~' ' , v w a ' ' ' ~ m' ' s ' ' ' ' d' i' ' _„! Y' E; ~ , a~ m a; - - - ~, i m. ~ °~~ °~ °~ ° 'n 4 a ~, ~, ~, c 4 a~ a~ m 3. - c °' - ~' o t I-; F- c ` o ~ ~ ~ t= 'u ~ ~~ m a ~ > ° ~ a ~° ~_ ; O , ~ .; o o' O O L ~ c i °: ai ~ ~ ° m .N ~ a~ m ~ , 0 m O ~, U c , . a, -~ , ~, ~' ~' ~' cn, "=; Q O, a; a, U ~', Q; a; z, ~ V' ~, U, U. , U, U, ¢ , "--; ¢, ~=-; O', , m; m; U, 'S', '~', ~; a; o', . ~n, cn, U; - ~ - W d ' q~ ~7 `~ V ~ ~ N M _~ ~ (O f~ OD O O N M tt In f0 1~ ~ O O O N N N M I N N N l( ) CO I~ O N N N N Q1 O N N M M M M I M M to (O M M 1~ M M M O M _ C G O C w N w N ad+ N C V O W N ~ ~ ~ ~ ~ ~ ~ ~ o N O N ~ 1~ J N •~ d ~ O ~ ~t `C. p c •~ C ~ ° c Q. D (~ ? a s a w a m w a a w ~ ~ aLL acn r • Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding infom~ation, infom~ation of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. Sperry-Sun Drilling Services LIS Scan Utility $Revision: 3 $ LisLib $Revision: 4 $ Thu Feb 22 14:18:33 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 Scientific Technical Services Scientific Technical Services Physical EOF Comment Record TAPE HEADER West Sak MWD/MAD LOGS WELL NAME: 1J-115 L2 API NUMBER: 500292332061 OPERATOR: ConocoPhillips Alaska, Inc LOGGING COMPANY: Sperry Drilling Services TAPE CREATION DATE: 22-FEB-07 JOB DATA MWD RUN 3 MWD RUN 17 MWD RUN 18 JOB NUMBER: W-0004650390 W-0004650390 W-0004650390 LOGGING ENGINEER: T. GALVIN P. ORTH R. REPLOGLE OPERATOR WITNESS: G. WHITLOCK G. WHITLOCK G. WHITLOCK MWD RUN 19 MWD RUN 20 MWD RUN 21 JOB NUMBER: W-0004650390 W-0004650390 W-0004650390 LOGGING ENGINEER: R. REPLOGLE R. REPLOGLE R. REPLOGLE OPERATOR WITNESS: G. WHITLOCK G. WHITLOCK G. WHITLOCK MWD RUN 22 JOB NUMBER: W-0004650390 LOGGING ENGINEER: T. GALVIN OPERATOR WITNESS: D. GLADDEN SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) 35 11N l0E 1973 2380 ~~`t ~~~ s KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD OPEN HOLE BIT SIZE (IN) 1ST STRING 9.875 2ND STRING 6.750 3RD STRING PRODUCTION STRING REMARKS: 109.00 81.00 CASING DRILLERS SIZE (IN) DEPTH (FT) 10.750 3009.0 7.625 6094.0 1. ALL DEPTHS ARE MEASURED DEPTHS UNLESS OTHERWISE NOTED. THESE DEPTHS ARE BIT DEPTHS. 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTHS (TVD). 3. THIS WELL IS AN OPEN-HOLE SIDETRACK EXITING THE 1J-115 L2PB2 WELLBORE AT 6930'MD/3593'TVD. 4. MWD RUN 1 WAS DIRECTIONAL ONLY - NO DATA ARE PRESENTED. 5. MWD RUNS 2,3,18-22 COMPRISED DIRECTIONAL, DUAL GAMMA RAY (DGR) UTILIZING GEIGER-MUELLER TUBE DETECTORS, ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4), AND PRESSURE WHILE DRILLING (PWD) MWD RUNS 18-20,22 ALSO INCLUDED GEO-PILOT ROTARY STEERABLE BHA (GP). NO MWD DATA WERE ACQUIRED ON MWD RUN 2 DUE TO AN MWD FAILURE. LWD TOOLS WERE NOT INCLUDED FOR RUNS 15 & 16. SROP DATA ONLY ARE PRESENTED FOR RUN 17. 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 1-3,17-22 REPRESENT WELL 1J-115 L2 WITH API#: 50-029-23320-61. THIS WELL REACHED A TOTAL DEPTH (TD) OF 14000'MD/3705'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 13942.0 RPD 2995.0 13949.5 RPM 2995.0 13949.5 RPS 2995.0 13949.5 RPX 2995.0 13949.5 FET 2995.0 13949.5 ROP 3040.5 14000.0 U BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH MERGED DATA SOURCE PBU TOOL CODE BIT RUN NO MERGE TOP MERGE BASE MWD 3 2993.5 6094.0 MWD 17 6094.5 6142.0 MWD 18 6142.0 6180.0 MWD 19 6180.5 6930.0 MWD 20 6930.5 7540.0 MWD 21 7540.0 10330.0 MWD 22 10330.0 14000.0 REMARKS: MERGED MAIN PASS. Data Format Specification Record Data Record Type ..................0 Data Specification Block Type.....0 Logging Direction .................Down Optical log depth units...........Feet Data Reference Point ..............Undefined Frame Spacing .....................60 .lIN Max frames per record .............Undefined Absent value ......................-999 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order DEPT RPD MWD RPM MWD RPS MWD RPX MWD FET MWD GR MWD ROP MWD Name Service Unit DEPT FT Units Size Nsam Rep Code Offset Channel FT 4 1 68 0 1 OHMM 4 1 68 4 2 OHMM 4 1 68 8 3 OHMM 4 1 68 12 4 OHMM 4 1 68 16 5 HOUR 4 1 68 20 6 API 4 1 68 24 7 FT/H 4 1 68 28 8 First Last Min Max Mean Nsam Reading Reading 2993.5 14000 8496.75 22014 2993.5 14000 RPD MWD OHMM 0.45 RPM MWD OHMM 1.48 RPS MWD OHMM 0.2 RPX MWD OHMM 0.9 FET MWD HOUR 0.18 GR MWD API 24.09 ROP MWD FT/H 0.11 i 2000 43.2122 21910 2995 13949.5 1651.33 41.4649 21910 2995 13949.5 2000 42.0119 21910 2995 13949.5 2000 40.2608 21910 2995 13949.5 789.66 2.52471 21910 2995 13949.5 122.12 68.886 21898 2993.5 13942 504.41 165.782 21920 3040.5 14000 First Reading For Entire File..........2993.5 Last Reading For Entire File...........14000 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 BIT RUN NUMBER: 3 DEPTH INCREMENT: .5000 FILE SUMMARY for each bit run in separate files. VENDOR TOOL CODE START DEPTH STOP DEPTH GR 2993.5 6094.0 RPD 2995.0 6094.0 RPS 2995.0 6094.0 FET 2995.0 6094.0 RPM 2995.0 6094.0 RPX 2995.0 6094.0 ROP 3040.5 6094.0 LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: 08-OCT-06 Insite 72.13 Memory 6094.0 3040.0 6094.0 59.3 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 6094 4543.75 6202 2993.5 6094 RPD MWD030 OHMM 1.9 2000 17.1564 6199 2995 6094 RPM MWD030 OHMM 1.48 16 51.33 13.2227 6199 2995 6094 RPS MWD030 OHMM 0.2 32.54 11.5075 6199 2995 6094 RPX MWD030 OHMM 0.9 33.68 11.0955 6199 2995 6094 FET MWD030 HOUR 0.18 56.28 1.09762 6199 2995 6094 GR MWD030 API 24.09 1 22.12 66.1715 6202 2993.5 609.4 ROP MWD030 FT/H 9.61 5 04.41 202.305 6108 3040.5 6094 First Reading For Entire File..........2993.5 Last Reading For Entire File...........6094 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: 17 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH ROP 6094.5 6142.0 LOG HEADER DATA DATE LOGGED: 07-NOV-06 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 72.13 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT) 6142.0 TOP LOG INTERVAL (FT) 6094.0 BOTTOM LOG INTERVAL (FT) 6142.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 76.8 MAXIMUM ANGLE: 76.8 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) 6094.0 BOREHOLE CONDITIONS MUD TYPE: Mineral Oil Base MUD DENSITY (LB/G) 8.80 MUD VISCOSITY (S) 70.0 MUD PH: .0 MUD CHLORIDES (PPM): 113000 FLUID LOSS (C3) 2.8 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): .000 .0 MUD AT MAX CIRCULATING TERMPERATURE: .000 91.4 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 ROP MWD170 FT/H 4 1 68 4 2 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 6094.5 6142 6118.25 96 6094.5 6142 ROP MWD170 FT/H 0.3 39.58 14.3557 96 6094.5 6142 First Reading For Entire File..........6094.5 Last Reading For Entire File...........6142 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: 18 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH RPX 6094.5 6180.0 RPD 6094.5 6180.0 RPM 6094.5 6180.0 GR 6094.5 6180.0 RPS 6094.5 6180.0 FET 6094.5 6180.0 ROP 6142.5 6180.0 s LOG HEADER DATA DATE LOGGED: 09-NOV-06 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 72.13 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT) 6180.0 TOP LOG INTERVAL (FT) 6142.0 BOTTOM LOG INTERVAL (FT) 6180.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 76.8 MAXIMUM ANGLE: 88.0 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) 6094.0 BOREHOLE CONDITIONS MUD TYPE: Mineral Oil Base MUD DENSITY (LB/G) 8.80 MUD VISCOSITY (S) 68.0 MUD PH: .0 MUD CHLORIDES (PPM): 27000 FLUID LOSS (C3) 3.8 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT) .000 .0 MUD AT MAX CIRCULATING TERMPERATURE: .000 86.0 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 MWD180 OHMM 4 1 68 4 2 RPM MWD180 OHMM 4 1 68 8 3 RPS MWD180 OHMM 4 1 68 12 4 RPX MWD180 OHMM 4 1 68 16 5 FET MWD180 HOUR 4 1 68 20 6 GR MWD180 API 4 1 68 24 7 ROP MWD180 FT/H 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 6094.5 6180 6137.25 172 6094.5 6180 RPD MWD180 OHMM 0.45 74.22 34.6219 172 6094.5 6180 RPM MWD180 OHMM 2.09 67.51 30.5091 172 6094.5 6180 RPS MWD180 OHMM 8.42 77.68 31.3408 172 6094.5 6180 RPX MWD180 OHMM 6.37 77.58 30.917 172 6094.5 6180 FET MWD180 HOUR 0.4 789.66 157.315 172 6094.5 6180 GR MWD180 API 51.83 85.87 71.4623 172 6094.5 6180 ROP MWD180 FT/H 21.7 302.46 173.722 76 6142.5 6180 First Reading For Entire File..........6094.5 Last Reading For Entire File...........6180 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: 19 n DEPTH INCREMENT: .5000 FI LE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH RPD 6180.5 6930.0 ROP 6180.5 6930.0 GR 6180.5 6930.0 RPX 6180.5 6930.0 RPM 6180.5 6930.0 FET 6180.5 6930.0 RPS 6180.5 6930.0 LO G HEADER DATA DATE LOGGED: 10-NOV-06 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 72.13 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT) 6930.0 TOP LOG INTERVAL (FT) 6180.0 BOTTOM LOG INTERVAL (FT) 6930.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 78.6 MAXIMUM ANGLE: 93.3 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 178505 EWR4 Electromag Resis. 4 159439 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) 6.750 DRILLER'S CASING DEPTH (FT) 6094.0 BOREHOLE CONDITIONS MUD TYPE: Mineral Oil Base MUD DENSITY (LB/G) 8.80 MUD VISCOSITY (S) 68.0 MUD PH: .0 MUD CHLORIDES (PPM): 27000 FLUID LOSS (C3) 4.0 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT) .000 .0 MUD AT MAX CIRCULATING TERMPERATURE: .000 100.4 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 Specifica tion Block sub- type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 RPD MWD190 OHMM 4 1 68 4 2 RPM MWD190 OHMM 4 1 68 8 3 RPS MWD190 OHMM 4 1 68 12 4 RPX MWD190 OHMM 4 1 68 16 5 FET MWD190 HOUR 4 1 68 20 6 GR MWD190 API 4 1 68 24 7 ROP MWD190 FT/H 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 6180.5 6930 6555.25 1500 6180.5 6930 RPD MWD190 OHMM 10.72 122.97 39.1303 1500 6180.5 6930 RPM MWD190 OHMM 10.37 133.78 35.873 1500 6180.5 6930 RPS MWD190 OHMM 10.57 161.93 36.0524 1500 6180.5 6930 RPX MWD190 OHMM 10.41 150.19 33.9002 1500 6180.5 6930 FET MWD190 HOUR 0.3 18.43 0.788787 1500 6180.5 6930 GR MWD190 API 46.72 97.22 74.7142 1500 6180.5 6930 ROP MWD190 FT/H 0.38 353.85 143.171 1500 6180.5 6930 First Reading For Entire File..........6180.5 Last Reading For Entire File...........6930 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 File Header Service name .............STSLIB.006 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.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: 20 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH FET 6930.5 7489.5 ROP 6930.5 7540.0 RPX 6930.5 7489.5 • GR 6930.5 7482.0 RPM 6930.5 7489.5 RPD 6930.5 7489.5 RPS 6930.5 7489.5 LO G HEADER DATA DATE LOGGED: 11-NOV-06 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 72.13 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT) 7540.0 TOP LOG INTERVAL (FT) 6930.0 BOTTOM LOG INTERVAL (FT) 7540.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 88.7 MAXIMUM ANGLE: 90.8 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 178505 EWR4 Electromag Resis. 4 159439 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) 6.750 DRILLER'S CASING DEPTH (FT) 6094.0 BOREHOLE CONDITIONS MUD TYPE: Mineral Oil Base MUD DENSITY (LB/G): 8.70 MUD VISCOSITY (S) 72.0 MUD PH: .0 MUD CHLORIDES (PPM): 26250 FLUID LOSS (C3) 3.0 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT) .000 .0 MUD AT MAX CIRCULATING TERMPERATURE: 104.400 104.0 MUD FILTRATE AT MT: .000 .0 MUD CAKE AT MT: .000 .0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format Specification Record Data Record Type ..................0 Data Specification Block Type.....0 Logging Direction .................Down Optical log depth units...........Feet Data Reference Point ..............Undefined Frame Spacing .....................60 .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 MWD200 OHMM 4 1 68 4 2 RPM MWD200 OHMM 4 1 68 8 3 RPS MWD200 OHMM 4 1 68 12 4 RPX MWD200 OHMM 4 1 68 16 5 FET MWD200 HOUR 4 1 68 20 6 GR MWD200 API 4 1 68 24 7 ROP MWD200 FT/H 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 6930.5 7540 7235.25 1220 6930.5 7540 RPD MWD200 OHMM 40.88 91.27 53.1172 1119 6930.5 7489.5 RPM MWD200 OHMM 37.64 96.91 53.6498 1119 6930.5 7489.5 RPS MWD200 OHMM 29.78 139.7 59.8338 1119 6930.5 7489.5 RPX MWD200 OHMM 24.11 118.7 59.2294 1119 6930.5 7489.5 FET MWD200 HOUR 0.18 12.71 1.35833 1119 6930.5 7489.5 GR MWD200 API 46.64 87.59 69.2847 1104 6930.5 7482 ROP MWD200 FT/H 0.27 320.17 191.375 1220 6930.5 7540 First Reading For Entire File..........6930.5 Last Reading For Entire File...........7540 File Trailer Service name .............STSLIB.006 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.007 Physical EOF File Header Service name .............STSLIB.007 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.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: 21 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 7482.5 10264.5 RPM 7490.0 10271.5 FET 7490.0 10271.5 RPS 7490.0 10271.5 RPX 7490.0 10271.5 RPD 7490.0 10271.5 ROP 7540.5 10330.0 LOG HEADER DATA • DATE LOGGED: 14-NOV-06 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 72.13 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT) 10330.0 TOP LOG INTERVAL (FT): 7540.0 BOTTOM LOG INTERVAL (FT) 10330.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 85.3 MAXIMUM ANGLE: 91.8 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 178505 EWR4 Electromag Resis. 4 159439 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) 6.750 DRILLER'S CASING DEPTH (FT) 6094.0 BOREHOLE CONDITIONS MUD TYPE: Mineral Oil Base MUD DENSITY (LB/G) 8.70 MUD VISCOSITY (S) 72.0 MUD PH: .0 MUD CHLORIDES (PPM): 26250 FLUID LOSS (C3) 3.0 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT) .000 .0 MUD AT MAX CIRCULATING TERMPERATURE: 114.800 114.8 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 MWD210 OHMM 4 1 68 4 2 RPM MWD210 OHMM 4 1 68 8 3 RPS MWD210 OHMM 4 1 68 12 4 RPX MWD210 OHMM 4 1 68 16 5 FET MWD210 HOUR 4 1 68 20 6 GR MWD210 API 4 1 68 24 7 ROP MWD210 FT/H 4 1 68 28 8 • s First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 7482.5 10330 8906.25 5696 7482.5 10330 RPD MWD210 OHMM 20.66 274.01 55.3002 5564 7490 10271.5 RPM MWD210 OHMM 19.25 120.48 50.246 5564 7490 10271.5 RPS MWD210 OHMM 17.06 149.55 51.7029 5564 7490 10271.5 RPX MWD210 OHMM 16.03 193.26 50.3046 5564 7490 10271.5 FET MWD210 HOUR 0.24 16.59 1.33031 5564 7490 10271.5 GR MWD210 API 40.89 94.57 71.4935 5565 7482.5 10264.5 ROP MWD210 FT/H 0.77 504.37 156.42 5580 7540.5 10330 First Reading For Entire File..........7482.5 Last Reading For Entire File...........10330 File Trailer Service name .............STSLIB.007 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.008 Physical EOF File Header Service name .............STSLIB.008 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.007 Comment Record FILE HEADER FILE NUMBER: 8 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 22 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 10265.0 13942.0 FET 10272.0 13949.5 RPS 10272.0 13949.5 RPX 10272.0 13949.5 RPM 10272.0 13949.5 RPD 10272.0 13949.5 ROP 10330.5 14000.0 LOG HEADER DATA DATE LOGGED: 18-NOV-06 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 72.13 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT) 14000.0 TOP LOG INTERVAL (FT) 10330.0 • • BOTTOM LOG INTERVAL (FT) 14000.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 86.1 MAXIMUM ANGLE: 91.6 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 087225 EWR4 Electromag Resis. 4 130908 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) 6.750 DRILLER'S CASING DEPTH (FT) 6094.0 BOREHOLE CONDITIONS MUD TYPE: Mineral Oil Base MUD DENSITY (LB/G): 8.70 MUD VISCOSITY (S) 86.0 MUD PH: .0 MUD CHLORIDES (PPM): 24000 FLUID LOSS (C3) 3.0 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): .000 .0 MUD AT MAX CIRCULATING TERMPERATURE: 114.800 114.8 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 MWD220 OHMM 4 1 68 4 2 RPM MWD220 OHMM 4 1 68 8 3 RPS MWD220 OHMM 4 1 68 12 4 RPX MWD220 OHMM 4 1 68 16 5 FET MWD220 HOUR 4 1 68 20 6 GR MWD220 API 4 1 68 24 7 ROP MWD220 FT/H 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 10265 14000 12132.5 7471 10265 14000 RPD MWD220 OHMM 14.22 1 159.3 55.5531 7356 10272 13949.5 n LJ RPM MWD220 OHMM 13.61 RPS MWD220 OHMM 13.02 RPX MWD220 OHMM 11.91 FET MWD220 HOUR 0.21 GR MWD220 API 46.66 ROP MWD220 FT/H 0.11 1155.74 58.1659 7356 10272 13949.5 2000 59.1418 7356 10272 13949.5 2000 55.$716 7356 10272 13949.5 33.53 1.54282 7356 10272 13949.5 106.31 67.8933 7355 10265 13942 303.82 144,772 7340 10330.5 14000 First Reading For Entire File..........10265 Last Reading For Entire File...........14000 File Trailer Service name .............STSLIB.008 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.009 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 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 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 16:10:40 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 Comment Record TAPE HEADER West Sak MWD/MAD LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: i Scientific Technical Services Scientific Technical Services 1J-115 L2 PB1 500292332076 ConocoPhillips Alaska, Inc Sperry Drilling Services 22-FEB-07 MWD RUN 3 MWD RUN 17 MWD RUN 18 W-0004650390 W-0004650390 W-0004650390 T. GALVIN P. ORTH R. REPLOGLE G. WHITLOCK G. WHITLOCK G. WHITLOCK SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD OPEN HOLE BIT SIZE (IN) 1ST STRING 9.875 2ND STRING 6.750 3RD STRING PRODUCTION STRING 35 11N l0E 1973 2380 109.00 81.00 CASING DRILLERS SIZE (IN) DEPTH (FT) 10.750 3009.0 7.625 6094.0 ~~° ~ ~~~ l~(S OGl 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 6094' MD/3554'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 17. ONLY SROP DATA ARE PRESENTED FOR THIS RUN. 4. MWD RUN 1 WAS DIRECTIONAL ONLY - NO DATA ARE PRESENTED. 5. MWD RUNS 2,3,18 COMPRISED DIRECTIONAL, DUAL GAMMA RAY (DGR) UTILIZING GEIGER-MUELLER TUBE DETECTORS, ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4), AND PRESSURE WHILE DRILLING (PWD). MWD RUN 18 ALSO INCLUDED GEO- PILOT ROTARY STEERABLE BHA (GP) NO MWD DATA WERE ACQUIRED ON MWD RUN 2 DUE TO AN MWD FAILURE. LWD TOOLS WERE NOT INCLUDED FOR RUNS 15 & 16. 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 1-3,17,18 REPRESENT WELL 1J-115 L2PB1 WITH API#: 50-029-23320-76. THIS WELL REACHED A TOTAL DEPTH (TD) OF 6245'MD/3572'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 6187.5 FET 2995.0 6194.5 RPD 2995.0 6194.5 RPS 2995.0 6194.5 RPM 2995.0 6194.5 RPX 2995.0 6194.5 ROP 3040.5 6245.5 BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH MERGED DATA SOURCE PBU TOOL CODE MWD MWD MWD BIT RUN NO MERGE TOP 3 2993.5 17 6094.0 18 6142.0 REMARKS: MERGED MAIN PASS. MERGE BASE 6094.0 6142.0 6245.5 Data Format Specification Record Data Record Type ..................0 Data Specification Block Type.....0 Logging Direction .................Down Optical log depth units...........Feet Data Reference Point ..............Undefined Frame Spacing .....................60 .lIN Max frames per record .............Undefined Absent value ......................-999 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 RPD MWD OHMM 4 1 68 4 2 RPM MWD OHMM 4 1 68 8 3 RPS MWD OHMM 4 1 68 12 4 RPX MWD OHMM 4 1 68 16 5 FET MWD HOUR 4 1 68 20 6 GR MWD API 4 1 68 24 7 ROP MWD FT/H 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 2993.5 6245.5 4619.5 6505 2993.5 6245.5 RPD MWD OHMM 0.45 2000 17.8616 6400 2995 6194.5 RPM MWD OHMM 1.48 1651.33 13.9055 6400 2995 6194.5 RPS MWD OHMM 0.2 88.63 12.2963 6400 2995 6194.5 RPX MWD OHMM 0.9 94.45 11.8874 6400 2995 6194.5 FET MWD HOUR 0.18 789.66 5.29718 6400 2995 6194.5 GR MWD API 24.09 122.12 66.3097 6389 2993.5 6187.5 ROP MWD FT/H 0.3 504.41 198.603 6411 3040.5 6245.5 First Reading For Entire File..........2993.5 Last Reading For Entire File...........6245.5 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 6094.0 FET 2995.0 6094.0 RPX 2995.0 6094.0 RPS 2995.0 6094.0 RPM 2995.0 6094.0 RPD 2995.0 6094.0 ROP 3040.5 6094.0 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) 6094.0 TOP LOG INTERVAL (FT) 3040.0 BOTTOM LOG INTERVAL (FT) 6094.0 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 6094 4543.75 6202 2993.5 6094 RPD MWD030 OHMM 1.9 2000 17.1564 6199 2995 6094 RPM MWD030 OHMM 1.48 1651.33 13.2227 6199 2995 6094 RPS MWD030 OHMM 0.2 32.54 11.5075 6199 2995 6094 RPX MWD030 OHMM 0.9 33.68 11.0955 6199 2995 6094 FET MWD030 HOUR 0.18 56.28 1.09762 6199 2995 6094 GR MWD030 API 24.09 122.12 66.1715 6202 2993.5 6094 ROP MWD030 FT/H 9.61 504.41 202.305 6108 3040.5 6094 First Reading For Entire File..........2993.5 Last Reading For Entire File...........6094 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: 17 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH ROP 6094.0 6142.0 LOG HEADER DATA DATE LOGGED: 07-NOV-06 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 72.13 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT) 6142.0 TOP LOG INTERVAL (FT}: 6094.0 BOTTOM LOG INTERVAL (FT) 6142.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 76.8 MAXIMUM ANGLE: 76.8 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) 6094.0 BOREHOLE CONDITIONS MUD TYPE: Mineral Oil Base MUD DENSITY (LB/G) 8.80 MUD VISCOSITY (S) 70.0 MUD PH: .0 MUD CHLORIDES (PPM): 113000 FLUID LOSS (C3) 2.8 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT) .000 .0 MUD AT MAX CIRCULATING TERMPERATURE: .000 91.4 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 ROP MWD170 FT/H 4 1 68 4 2 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 6094 6142 6118 97 6094 6142 ROP MWD170 FT/H 0.11 39.58 14.2089 97 6094 6142 First Reading For Entire File..........6094 Last Reading For Entire File...........6142 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: 18 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH RPX 6094.5 6194.5 RPD 6094.5 6194.5 RPM 6094.5 6194.5 GR 6094.5 6187.5 RPS 6094.5 6194.5 FET 6094.5 6194.5 ROP 6142.5 6245.5 LOG HEADER DATA DATE LOGGED: 09-NOV-06 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 72.13 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT) 6245.0 TOP LOG INTERVAL (FT) 6142.0 BOTTOM LOG INTERVAL (FT) 6245.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 76.8 MAXIMUM ANGLE: 88.0 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) 6094.0 BOREHOLE CONDITIONS MUD TYPE: Mineral Oil Base MUD DENSITY (LB/G) 8.80 MUD VISCOSITY (S) 68.0 MUD PH: .0 MUD CHLORIDES (PPM): 27000 FLUID LOSS (C3) 3.8 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT) .000 .0 MUD AT MAX CIRCULATING TERMPERATURE: .000 86.0 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 MWD180 OHMM 4 1 68 4 2 RPM MWD180 OHMM 4 1 68 8 3 RPS MWD180 OHMM 4 1 68 12 4 RPX MWD180 OHMM 4 1 68 16 5 FET MWD180 HOUR 4 1 68 20 6 GR MWD180 API 4 1 68 24 7 ROP MWD180 FT/H 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 6094.5 6245.5 6170 303 6094.5 6245.5 RPD MWD180 OHMM 0.45 87.32 39.6113 201 6094.5 6194.5 RPM MWD180 OHMM 2.09 77.05 34.9653 201 6094.5 6194.5 RPS MWD180 OHMM 8.42 88.63 36.6255 201 6094.5 6194.5 RPX MWD180 OHMM 6.37 94.45 36.3108 201 6094.5 6194.5 FET MWD180 HOUR 0.4 789.66 134.815 201 6094.5 6194.5 GR MWD180 API 51.83 85.87 70.8943 187 6094.5 6187.5 ROP MWD180 FT/H 11.33 302.46 174.813 207 6142.5 6245.5 First Reading For Entire File..........6094.5 Last Reading For Entire File...........6245.5 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. 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 Physical EOF Scientific Technical Services Scientific Technical Services Physical EOF End Of LIS File Sperry-Sun Drilling Services LIS Scan Utility $Revision: 3 $ LisLib $Revision: 4 $ Fri Feb 23 08:01:09 2007 Reel Header Service name .............LISTPE Date .....................07/02/23 Origin ...................STS Reel Name ................UNKNOWN Continuation Number......01 Previous Reel Name.......UNKNOWN Comments .................STS LIS Writing Library. Tape Header Service name .............LISTPE Date .....................07/02/23 Origin ...................STS Tape Name ................UNKNOWN Continuation Number......01 Previous Tape Name.......UNKNOWN Comments .................STS LIS Writing Library. Physical EOF Scientific Technical Services Scientific Technical Services Comment Record TAPE HEADER West Sak MWD/MAD LOGS WELL NAME: 1J-115 L2 PB2 API NUMBER: 500292332077 OPERATOR: ConocoPhillips Alaska, Inc LOGGING COMPANY: Sperry Drilling Services TAPE CREATION DATE: 22-FEB-07 JOB DATA MWD RUN 3 MWD RUN 17 MWD RUN 18 JOB NUMBER: W-0004650390 W-0004650390 W-0004650390 LOGGING ENGINEER: T. CALVIN P. ORTH R. REPLOGLE OPERATOR WITNESS: G. WHITLOCK G. WHITLOCK G. WHITLOCK MWD RUN 19 JOB NUMBER: W-0004650390 LOGGING ENGINEER: R. REPLOGLE OPERATOR WITNESS: G. WHITLOCK SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD 35 11N l0E 1973 2380 109.00 81.00 OPEN HOLE CASING DRILLERS ~~-tay r~t~a`~ 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING REMARKS: BIT SIZE (IN) SIZE (IN) DEPTH (FT) 9.875 10.750 3009.0 6.750 7.625 6094.0 1. ALL DEPTHS ARE MEASURED DEPTHS UNLESS OTHERWISE NOTED. THESE DEPTHS ARE BIT DEPTHS. 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTHS (TVD). 3. THIS WELL IS AN OPEN-HOLE SIDETRACK EXITING THE 1J-115 L2PB1 WELLBORE AT 6180'MD/3571'TVD. 4. MWD RUN 1 WAS DIRECTIONAL ONLY - NO DATA ARE PRESENTED. 5. MWD RUNS 2,3,18,19 COMPRISED DIRECTIONAL, DUAL GAMMA RAY (DGR) UTILIZING GEIGER-MUELLER TUBE DETECTORS, ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4), AND PRESSURE WHILE DRILLING (PWD) MWD RUNS 18 & 19 ALSO INCLUDED GEO-PILOT ROTARY STEERABLE BHA (GP) NO MWD DATA WERE ACQUIRED ON MWD RUN 2 DUE TO AN MWD FAILURE. LWD TOOLS WERE NOT INCLUDED FOR RUNS 15 & 16. SROP DATA ONLY ARE PRESENTED FOR RUN 17. 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 1-3,17-19 REPRESENT WELL 1J-115 L2PB2 WITH API##: 50-029-23320-77. THIS WELL REACHED A TOTAL DEPTH (TD) OF 7230'MD/3597'TVD. SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRC = SMOOTHED GAMMA RAY COMBINED. SEXP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (EXTRA SHALLOW SPACING). SESP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (SHALLOW SPACING) . SEMP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (MEDIUM SPACING). SEDP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (DEEP SPACING). SFXE = SMOOTHED FORMATION EXPOSURE TIME (DEEP SPACING). SLIDE = NON-ROTATED INTERVALS REFLECTING BIT DEPTHS. File Header Service name .............STSLIB.001 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......07/02/23 Maximum Physical Record..65535 File Type ................LO Previous File Name.......STSLIB.000 Comment Record FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE START DEPTH GR 2993.5 RPS 2995.0 RPM 2995.0 FET 2995.0 RPD 2995.0 RPX 2995.0 ROP 3040.5 all bit runs merged. STOP DEPTH 7172.0 7179.0 7178.5 7179.0 7179.0 7179.0 7230.0 BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH MERGED DATA SOURCE PBU TOOL CODE MWD MWD MWD MWD BIT RUN NO MERGE TOP MERGE BASE 3 2993.5 6094.0 17 6094.5 6142.0 18 6142.0 6180.0 19 6180.5 7230.0 REMARKS: MERGED MAIN PASS. Data Format Specification Record Data Record Type ..................0 Data Specification Block Type.....0 Logging Direction .................Down Optical log depth units...........Feet Data Reference Point ..............Undefined Frame Spacing .....................60 .lIN Max frames per record .............Undefined Absent value ......................-999 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 RPD MWD OHMM 4 1 68 4 2 RPM MWD OHMM 4 1 68 8 3 RPS MWD OHMM 4 1 68 12 4 RPX MWD OHMM 4 1 68 16 5 FET MWD HOUR 4 1 68 20 6 GR MWD API 4 1 68 24 7 ROP MWD FT/H 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 2993.5 7230 5111.75 8474 2993.5 7230 RPD MWD OHMM 0.45 2000 23.4567 8369 2995 7179 RPM MWD OHMM 1.48 1651.33 19.9758 8368 2995 7178.5 RPS MWD OHMM 0.2 161.93 19.176 8369 2995 7179 RPX MWD OHMM 0.9 150.19 18.4902 8369 2995 7179 FET MWD HOUR 0.18 789.66 4.23851 8369 2995 7179 GR MWD API 24.09 122.12 67.9745 8358 2993.5 7172 ROP MWD FT/H 0.3 504.41 185.656 8380 3040.5 7230 • First Reading For Entire File..........2993.5 Last Reading For Entire File...........7230 File Trailer Service name .............STSLIB.001 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......07/02/23 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.002 Physical EOF File Header Service name .............STSLIB.002 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......07/02/23 Maximum Physical Record..65535 File Type ................LO Previous File Name.......STSLIB.001 Comment Record FILE HEADER FILE NUMBER: 2 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 3 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 2993.5 6094.0 RPM 2995.0 6094.0 RPD 2995.0 6094.0 RPX 2995.0 6094.0 FET 2995.0 6094.0 RPS 2995.0 6094.0 ROP 3040.5 6094.0 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) 6094.0 TOP LOG INTERVAL (FT) 3040.0 BOTTOM LOG INTERVAL (FT) 6094.0 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 6094 4543.75 6202 2993.5 6094 RPD MWD030 OHMM 1.9 2000 17.1564 6199 2995 6094 RPM MWD030 OHMM 1.48 1651.33 13.2227 6199 2995 6094 RPS MWD030 OHMM 0.2 32.54 11.5075 6199 2995 6094 RPX MWD030 OHMM 0.9 33.68 11.0955 6199 2995 6094 FET MWD030 HOUR 0.18 56.28 1.09762 6199 2995 6094 GR MWD030 API 24.09 122.12 66.1715 6202 2993.5 6094 ROP MWD030 FT/H 9.61 504.41 202.305 6108 3040.5 6094 First Reading For Entire File..........2993.5 Last Reading For Entire File...........6094 File Trailer Service name .............STSLIB.002 Service Sub Level Name... • • Version Number...........1.0.0 Date of Generation.......07/02/23 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.003 Physical EOF File Header Service name .............STSLIB.003 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......07/02/23 Maximum Physical Record..65535 File Type ................LO Previous File Name.......STSLIB.002 Comment Record FILE HEADER FILE NUMBER: 3 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 17 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH ROP 6094.5 6142.0 LOG HEADER DATA DATE LOGGED: 07-NOV-06 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 72.13 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT) 6142.0 TOP LOG INTERVAL (FT) 6094.0 BOTTOM LOG INTERVAL (FT) 6142.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 76.8 MAXIMUM ANGLE: 76.8 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) 6094.0 BOREHOLE CONDITIONS MUD TYPE: Mineral Oil Base MUD DENSITY (LB/G) 8.80 MUD VISCOSITY (S) 70.0 MUD PH: .0 MUD CHLORIDES (PPM): 113000 FLUID LOSS (C3) 2.8 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT) .000 .0 MUD AT MAX CIRCULATING TERMPERATURE: .000 91.4 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 ROP MWD170 FT/H 4 1 68 4 2 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 6094.5 6142 6118.25 96 6094.5 6142 ROP MWD170 FT/H 0.3 39.58 14.3557 96 6094.5 6142 First Reading For Entire File..........6094.5 Last Reading For Entire File...........6142 File Trailer Service name .............STSLIB.003 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......07/02/23 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.004 Physical EOF File Header Service name .............STSLIB.004 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......07/02/23 Maximum Physical Record..65535 File Type ................LO Previous File Name.......STSLIB.003 Comment Record FILE HEADER FILE NUMBER: 4 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 18 DEPTH INCREMENT: .5000 • • FI LE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 6094.5 6180.0 FET 6094.5 6180.0 RPX 6094.5 6180.0 RPD 6094.5 6180.0 RPS 6094.5 6180.0 RPM 6094.5 6180.0 ROP 6142.5 6180.0 LO G HEADER DATA DATE LOGGED: 09-NOV- 06 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 72.13 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT) 6180.0 TOP LOG INTERVAL (FT) 6142.0 BOTTOM LOG INTERVAL (FT) 6180.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 76.8 MAXIMUM ANGLE: 88.0 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) 6094.0 BOREHOLE CONDITIONS MUD TYPE: Mineral Oil Base MUD DENSITY (LB/G) 8.80 MUD VISCOSITY (S) 68.0 MUD PH: .0 MUD CHLORIDES (PPM): 27000 FLUID LOSS (C3) 3.8 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT) .000 .0 MUD AT MAX CIRCULATING TERMPERATURE: .000 86.0 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 MWD180 OHMM 4 1 68 4 2 RPM MWD180 OHMM 4 1 68 8 3 RPS MWD180 OHMM 4 1 68 12 4 RPX MWD180 OHMM 4 1 68 16 5 FET MWD180 HOUR 4 1 68 20 6 GR MWD180 API 4 1 68 24 7 ROP MWD180 FT/H 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 6094.5 6180 6137.25 172 6094.5 6180 RPD MWD180 OHMM 0.45 74.22 34.6219 172 6094.5 6180 RPM MWD180 OHMM 2.09 67.51 30.5091 172 6094.5 6180 RPS MWD180 OHMM 8.42 77.68 31.3408 172 6094.5 6180 RPX MWD180 OHMM 6.37 77.58 30.917 172 6094.5 6180 FET MWD180 HOUR 0.4 789.66 157.315 172 6094.5 6180 GR MWD180 API 51.83 85.87 71.4623 172 6094.5 6180 ROP MWD180 FT/H 21.7 302.46 173.722 76 6142.5 6180 First Reading For Entire File..........6094.5 Last Reading For. Entire File...........6180 File Trailer Service name .............STSLIB.004 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......07/02/23 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.005 Physical EOF Fiie Header Service name .............STSLIB.005 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......07/02/23 Maximum Physical Record..65535 File Type ................LO 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: 19 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH RPX 6180.5 7179.0 ROP 6180.5 7230.0 RPD 6180.5 7179.0 GR 6180.5 7172.0 RPM 6180.5 7178.5 • FET 6180.5 7179.0 RPS 6180.5 7179.0 LO G HEADER DATA DATE LOGGED: 10-NOV-06 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 72.13 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT) 7230.0. TOP LOG INTERVAL (FT) 6180.0 BOTTOM LOG INTERVAL (FT) 7230.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 78.6 MAXIMUM ANGLE: 93.3 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 178505 EWR4 Electromag Resis. 4 159439- $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) 6.750 DRILLER'S CASING DEPTH (FT) 6094.0 BOREHOLE CONDITIONS MUD TYPE: Mineral Oil Base MUD DENSITY (LB/G) 8.80 MUD VISCOSITY (S) 68.0 MUD PH: .0 MUD CHLORIDES (PPM): 27000 FLUID LOSS (C3) 4.0 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT) .000 .0 MUD AT MAX CIRCULATING TERMPERATURE: .000 100.4 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 MWD190 OHMM 4 1 68 4 2 RPM MWD190 OHMM 4 1 68 8 3 ti RPS MWD190 OHMM 4 1 68 12 4 RPX MWD190 OHMM 4 1 68 16 5 FET MWD190 HOUR 4 1 68 20 6 GR MWD190 API 4 1 68 24 7 ROP MWD190 FT/H 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 6180.5 7230 6705.25 2100 6180.5 7230 RPD MWD190 OHMM 10.72 122.97 42.043 1998 6180.5 7179 RPM MWD190 OHMM 10.37 133.78 40.0314 1997 6180.5 7178.5 RPS MWD190 OHMM 10.57 161.93 41.9211 1998 6180.5 7179 RPX MWD190 OHMM 10.41 150.19 40.3631 1998 6180.5 7179 FET MWD190 HOUR 0.3 18.43 0.805686 1998 6180.5 7179 GR MWD190 API 46.72 97.22 73.3084 1984 6180.5 7172 ROP MWD190 FT/H 0.38 353.85 145.496 2100 6180.5 7230 First Reading For Entire File..........6180.5 Last Reading For Entire File...........7230 File Trailer Service name .............STSLIB.005 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......07/02/23 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.006 Physical EOF Tape Trailer Service name .............LISTPE Date .....................07/02/23 Origin ...................STS Tape Name................UNKNOWN Continuation Number......01 Next Tape Name...........UNKNOWN Comments .................STS LIS Writing Library Reel Trailer Service name .............LISTPE Date .....................07/02/23 Origin ...................STS 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
