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Home My WebLink About206-0061. Operations Susp Well Insp Plug Perforations Fracture Stimulate Pull Tubing Performed: Install Whipstock Perforate Other Stimulate Alter Casing Mod Artificial Lift Perforate New Pool Repair Well Coiled Tubing Ops Operations shutdown Change Approved Program Other: RPPG Pumping- Offset Well 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 11187'feet None feet true vertical 3506' feet None feet Effective Depth measured 11187'feet 4194', 4200', 4355'feet true vertical 3506' feet 3467', 3469', 3508' feet Perforation depth Measured depth True Vertical depth Tubing (size, grade, measured and true vertical depth) 4-1/2" L-80 4222' MD 3475' TVD Packers and SSSV (type, measured and true vertical depth) 4194' MD 4200' MD 4355' MD N/A 3467' TVD 3469' TVD 3508' TVD N/A 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: N/A Sr Pet Eng: Sr Pet Geo: Sr Res Eng: WINJ WAG 0 Water-BblOil-Bbl 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. 12. Stimulation or cement squeeze summary: Intervals treated (measured):RPPG pumped down 1J-154L1 (Injector) (See Well Events.) Treatment descriptions including volumes used and final pressure: Packer: Baker GBH-22 Packer Packer: ZXP Liner Top Packer Packer: ZXP Liner Top Packer SSSV: None Jan Byrne Jan.Byrne@conocophillips.com (907) 265-6471Staff Well Interventions Engineer Slotted Liner: 4590-4633', 4643-7891', 8278-10504', 10506-11127' Slotted Liner: 3554-3559', 3559-3511', 3525-3500', 3501-3507' 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) 553 Gas-Mcf MD 965 Size 108' 1233 5681698 0 1290 219 measured TVD 7-5/8" STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 206-006 50-029-23297-60-00 P.O. Box 100360 Anchorage, AK 99510 3. Address: ConocoPhillips Alaska, Inc. N/A 5. Permit to Drill Number:2. Operator Name 4. Well Class Before Work: ADL0025661, ADL0025662 Kuparuk River Field/ West Sak Oil Pool KRU 1J-159L1 Plugs Junk measured Length Production B Sand Liner 5548' 6601' Casing 3695' 4-1/2" 5575' 11161' 3506' 2333' 108'Conductor Surface Intermediate 20" 10-3/4" 77' 2364' 2206' Burst Collapse 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 2:24 pm, Aug 20, 2025 Digitally signed by Jan Byrne DN: OU=Wells Group, O=ConocoPhillips, CN=Jan Byrne, E=jan.byrne@conocophillips.com Reason: I have reviewed this document Location: Anchorage tower Date: 2025.08.20 11:27:54-08'00' Foxit PDF Editor Version: 13.1.6 Jan Byrne DSR-9/11/25 RBDMS JSB 082525 J.Lau 11/4/25 DTTMSTART JOBTYP SUMMARYOPS 7/21/2025 ACQUIRE DATA PUMP FULL BORE RPPG TO MBE AT 8389' RKB IN THE B SAND LATERAL. PUMPED 13933 LBS OF DAQING RPPG PRODUCT, FLUSH CALLED @ 913 PSI AND 835 BBL JSV. SLIGHT PSI INCREASE TO MAX PSI 935, JSV 835 BBLS. WELL TO REMAIN SHUT IN FOR 48 HRS FOR RPPG TO FULLY CROSSLINK 1J-154/ 1J-159 RPPG Treatment Summary of Operations Last Tag Annotation Depth (ftKB) Wellbore End Date Last Mod By Last Tag:1J-159 lmosbor Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: Recovered lost Type II diverter 1J-159 8/15/2021 appleha Notes: General & Safety Annotation End Date Last Mod By NOTE: PULLED B LAT ISO SLEEVE 6/7/2013 pproven NOTE: VIEW SCHEMATIC w/Alaska Schematic9.0REV 2/21/2009 lmosbor NOTE: MULTI-LATERAL WELL: 1J-159 (A-SAND), 1J-159L1 (B-SAND), 1J-159L2 (D-SAND) 5/11/2006 WV5.3 Conversio n 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 18.94 31.0 108.0 108.0 62.60 H-40 WELDED SURFACE 10 3/4 9.95 31.2 2,364.5 2,206.4 45.50 L-80 BTC PRODUCTION 7 5/8 6.87 26.6 5,575.1 3,695.3 29.70 L-80 BTCM L2 LINER LEM 4 1/2 3.96 4,189.2 4,386.3 3,515.8 12.60 L-80 IBT L1 LINER HH LEM 4 1/2 3.96 4,355.1 4,705.5 3,571.1 12.60 L-80 IBT A-SAND LINER 4 1/2 3.96 4,666.1 7,842.1 3,642.2 12.60 L-80 IBT Tubing Strings: "String Max Nominal OD" is the OD of the LONGEST segment in string Top (ftKB) 22.6 Set Depth … 4,222.2 Set Depth … 3,475.2 String Max No… 4 1/2 Tubing Description TUBING WO Wt (lb/ft) 12.60 Grade L-80 Top Connection IBTM 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) 22.6 22.6 0.00 HANGER 10.800 TUBING HANGER T&C Non- Upset 3.958 515.0 514.8 5.01 NIPPLE 5.210 CAMCO 'DB' NIPPLE 3.875 2,589.4 2,407.6 26.19 GAS LIFT 5.984 CAMCO KBG-2- 1R 3.938 4,093.6 3,434.6 69.05 GAS LIFT 5.984 CAMCO KBG-2- 1R 3.938 4,137.2 3,449.6 70.75 NIPPLE 5.210 CAMCO DB Nipple 3.812 4,147.6 3,453.0 71.16 GAUGE 6.700 GUARDIAN GAUGE CARRIER 3.850 4,193.8 3,467.2 73.06 LOCATOR 5.200 LOCATOR 3.880 4,194.5 3,467.4 73.08 SEAL ASSY 4.750 BAKER GBH-22 PACKER 3.880 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) 23.0 23.0 0.00 HEAT TRACE HEAT TRACE SET DURING 1/23/2008 WORKOVER 1/24/2008 0.000 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) 2,589.4 2,407.6 26.19 1 GAS LIFT GLV BK-5 1 1,530.0 2/19/2008 0.156 4,093.6 3,434.6 69.05 2 GAS LIFT OV BK 1 0.0 5/19/2016 0.219 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) 4,189.2 3,465.9 72.86 PBR 6.410 BAKER 190-47 PBR 5.750 4,200.2 3,469.1 73.32 PACKER 6.550 ZXP LINER TOP PACKER 4.950 4,227.5 3,476.6 74.48 XO Bushing 6.060 3.958 4,355.1 3,508.4 75.80 PACKER 7.500 ZXP LINER TOP PACKER 4.950 4,372.3 3,512.6 76.38 SBR 6.280 109-47 CASING SEAL BORE RECEPTACLE 4.750 4,391.9 3,517.1 77.04 XO BUSHING 6.060 CROSSOVER BUSHING 3.910 4,550.3 3,547.9 79.90 ABOVE HH 8.470 LEM ABOVE HOOK HANGER 4.020 4,560.9 3,549.7 80.16 INSIDE HH 8.470 LEM INSIDE HOOK HANGER 4.020 4,626.4 3,560.0 81.80 NIPPLE 5.000 CAMCO 'DB' NIPPLE 3.562 4,666.1 3,565.6 81.92 PACKER 6.540 "HRD" ZXP Liner Top Packer 5.5" X 7.6" 4.970 4,685.1 3,568.2 81.94 NIPPLE 6.070 "RS" Packoff Seal Nipple 5.5" 4.875 4,717.4 3,572.8 81.99 XO BUSHING 6.020 XO Bushing 3.92" ID, 6.02 OD 3.920 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 5,567.0 5,721.0 3,695.2 3,697.2 WS A2, 1J-159 2/23/2006 32.0 SLOTS SLOTTED LINER 0.125" x 2.5" x 32 spf @ 4 Circumferential adjacent rows, 3" Centers staggered 18 deg., 3 ft. non-slotted ends 5,845.0 6,091.0 3,694.4 3,688.1 WS A2, 1J-159 2/23/2006 32.0 SLOTS 6,399.0 7,810.0 3,681.8 3,642.2 WS A2, 1J-159 2/23/2006 32.0 SLOTS MULTIPLE LATERALS, 1J-159, 8/11/2025 2:27:49 PM Vertical schematic (actual) A-SAND LINER; 4,666.1-7,842.1 SLOTS; 6,399.0-7,810.0 SLOTS; 5,845.0-6,091.0 SLOTS; 5,567.0-5,721.0 PRODUCTION; 26.6-5,575.1 L1 LINER HH LEM; 4,355.1- 4,705.5 B-SAND LINER; 4,560.2- 11,161.1 L2 LINER LEM; 4,189.2-4,386.3 D-SAND LINER; 4,241.4- 10,859.6 GAUGE; 4,147.6 GAS LIFT; 4,093.6 GAS LIFT; 2,589.4 SURFACE; 31.2-2,364.5 HEAT TRACE; 23.0 NIPPLE; 515.0 CONDUCTOR; 31.0-108.0 KUP PROD KB-Grd (ft) 31.01 RR Date 3/13/2006 Other Elev… 1J-159 ... TD Act Btm (ftKB) 7,857.0 Well Attributes Field Name WEST SAK Wellbore API/UWI 500292329700 Wellbore Status PROD Max Angle & MD Incl (°) 93.86 MD (ftKB) 6,310.37 WELLNAME WELLBORE1J-159 Annotation Last WO: End Date 1/28/2008 H2S (ppm) 60 Date 8/11/2015 Comment SSSV: NIPPLE Last Tag Annotation Depth (ftKB) Wellbore End Date Last Mod By Last Tag:1J-159L1 lmosbor Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: WELL REVIEW 1J-159L1 2/9/2011 osborl Notes: General & Safety Annotation End Date Last Mod By NOTE: VIEW SCHEMATIC w/Alaska Schematic9.0REV 2/21/2009 lmosbor NOTE: MULTI-LATERAL WELL: 1J-159 (A-SAND), 1J-159L1 (B-SAND), 1J-159L2 (D-SAND) 3/12/2006 WV5.3 Conversio n 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 3.96 4,560.2 11,161.1 3,506.3 12.60 L-80 BTC 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) 4,585.2 3,553.6 81.67 SWIVEL 5.750 BAKER CASING SWIVEL 3.920 11,126.5 3,506.8 90.57 Cross over 3.500 4-1/2" IBT Box x 3-1/2" IBT Pin Crossover 2.992 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 4,590.0 4,633.0 3,554.3 3,559.1 WS B, 1J-159L1 3/3/2006 32.0 SLOTS SLOTTED LINER 0.125" x 2.5" x 32 spf @ 4 Circumferential adjacent rows, 3" Centers staggered 18 deg., 3 ft. non-slotted ends 4,643.0 7,891.0 3,559.9 3,510.6 WS B, 1J-159L1 3/3/2006 32.0 SLOTS 8,278.0 10,504.0 3,524.7 3,500.4 WS B, 1J-159L1 3/3/2006 32.0 SLOTS 10,506.0 11,127.0 3,500.5 3,506.8 WS B, 1J-159L1 3/3/2006 32.0 SLOTS MULTIPLE LATERALS, 1J-159L1, 8/11/2025 2:27:49 PM Vertical schematic (actual) B-SAND LINER; 4,560.2- 11,161.1 SLOTS; 10,506.0-11,127.0 SLOTS; 8,278.0-10,504.0 SLOTS; 4,643.0-7,891.0 SLOTS; 4,590.0-4,633.0 PRODUCTION; 26.6-5,575.1 L1 LINER HH LEM; 4,355.1- 4,705.5 L2 LINER LEM; 4,189.2-4,386.3 D-SAND LINER; 4,241.4- 10,859.6 GAUGE; 4,147.6 GAS LIFT; 4,093.6 GAS LIFT; 2,589.4 SURFACE; 31.2-2,364.5 HEAT TRACE; 23.0 NIPPLE; 515.0 CONDUCTOR; 31.0-108.0 KUP PROD KB-Grd (ft) 31.01 RR Date 3/13/2006 Other Elev… 1J-159L1 ... TD Act Btm (ftKB) 11,187.0 Well Attributes Field Name WEST SAK Wellbore API/UWI 500292329760 Wellbore Status PROD Max Angle & MD Incl (°) 92.41 MD (ftKB) 7,600.66 WELLNAME WELLBORE1J-159 Annotation Last WO: End Date 1/23/2008 H2S (ppm) 60 Date 8/11/2015 Comment SSSV: NIPPLE Last Tag Annotation Depth (ftKB) Wellbore End Date Last Mod By Last Tag:1J-159L2 lmosbor Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: WELL REVIEW 1J-159L2 5/10/2013 osborl Notes: General & Safety Annotation End Date Last Mod By NOTE: VIEW SCHEMATIC w/Alaska Schematic9.0REV 2/21/2009 lmosbor NOTE: MULTI-LATERAL WELL: 1J-159 (A-SAND), 1J-159L1 (B-SAND), 1J-159L2 (D-SAND) 3/12/2006 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 3.96 4,241.4 10,859.6 3,427.7 11.60 L-80 BTC 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) 4,266.4 3,486.4 76.78 SWIVEL 5.750 BAKER CSG SWIVEL - TENSION LOCK 3.960 4,320.8 3,497.0 80.81 SWELL PKR 6.300 3.960 4,876.8 3,503.3 91.74 SWELL PKR 6.300 3.960 10,825.3 3,430.4 94.42 XO Reducing 4.500 CROSSOVER 4.5x3.5" 3.958 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 4,890.0 7,847.0 3,502.9 3,443.6 WS D, 1J-159L2 3/10/2006 32.0 SLOTS SLOTTED LINER 0.125" x 2.5" x 32 spf @ 4 Circumferential adjacent rows, 3" Centers staggered 18 deg., 3 ft. non-slotted ends 8,174.0 10,823.0 3,459.1 3,430.6 WS D, 1J-159L2 3/10/2006 32.0 SLOTS MULTIPLE LATERALS, 1J-159L2, 8/11/2025 2:27:50 PM Vertical schematic (actual) D-SAND LINER; 4,241.4- 10,859.6 SLOTS; 8,174.0-10,823.0 SLOTS; 4,890.0-7,847.0 PRODUCTION; 26.6-5,575.1 L2 LINER LEM; 4,189.2-4,386.3 GAUGE; 4,147.6 GAS LIFT; 4,093.6 GAS LIFT; 2,589.4 SURFACE; 31.2-2,364.5 HEAT TRACE; 23.0 NIPPLE; 515.0 CONDUCTOR; 31.0-108.0 KUP PROD KB-Grd (ft) 31.01 RR Date 3/13/2006 Other Elev… 1J-159L2 ... TD Act Btm (ftKB) 10,884.0 Well Attributes Field Name WEST SAK Wellbore API/UWI 500292329761 Wellbore Status PROD Max Angle & MD Incl (°) 94.51 MD (ftKB) 10,841.96 WELLNAME WELLBORE1J-159 Annotation Last WO: End Date 1/23/2008 H2S (ppm) 60 Date 8/11/2015 Comment SSSV: NIPPLE STATE OF ALASKA A KA OIL AND GAS CONSERVATION COM ION REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon FT Plug Perforations r Fracture Stimulate FT Pull Tubing FT Operations Shutdown Performed: Suspend Perforate Other Stimulate Alter Casing r Change Approved Program r-- Plug Plug for Redrill Perforate New Pool FT Repair Well r Re-enter Susp Well Other:Crystal Seal MBE Trtmnt F 2.Operator Name: 4.Well Class Before Work: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Development F Exploratory n 206-006 3.Address: 6.API Number: P.O. Box 100360,Anchorage,Alaska 99510 Stratigraphic Service 50-029-23297-60 7.Property Designation(Lease Number): 8.Well Name and Number: ADL 25661,ADL 25662 KRU 1J-159L1 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): NONE Kuparuk River Field/West Sak Oil PoiVED 11.Present Well Condition Summary: MAY 18 2016 Total Depth measured 11187 feet Plugs(measured) None true vertical 3506 feet Junk(measured) None G CC Effective Depth measured 11159 feet Packer(measured) 4200,4355,4666, true vertical 3506 feet (true vertical) 3469, 3508,3567 Casing Length Size MD TVD Burst Collapse CONDUCTOR 77 20 108 108 SURFACE 2333 10 3/4 2365 2206 PRODUCTION 5547 7 5/8 4565 3595 B-SAND LINER 6601 4 1/2 11161 3506 Perforation depth: Measured depth: 4590-4633,4643-7891,8278-10504, 10506-11127 E� JANc 2.U17' True Vertical Depth: 3554-3559, 3560-3511, 3525-3500,3500-3507 � �� Tubing(size,grade,MD,and ND) 4.5, L-80,4222 MD, 3475 TVD Packers&SSSV(type,MD,and ND) PACKER-ZXP Liner Top Packer @44200 MD and 3469 ND, PACKER-ZXP Liner Top Packer @ 4355 MD and 3508 ND, PACKER HRD ZXP Liner Top Packer @ 4666 MD and 3567 ND SSSV: NONE 12.Stimulation or cement squeeze summary: Intervals treated(measured): NONE 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 384 - - - 175 Subsequent to operation 301 - - - 175 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations F Exploratory Development F 1 Service Stratigraphic Copies of Logs and Surveys Run FT 16.Well Status after work: Oil F Gas WDSPL Printed and Electronic Fracture Stimulation Data FT GSTOR FT WINJ WAG GINJ SUSP FT SPLUG 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: 315-661 Contact John Peirce Cad 265-6471 Email John.W.Peirce@conocophillips.com Printed Name John Peirce Title Sr. Wells Engineert Signature __.6-f:44-- ---,....: Phone:265-6471 Date S i s/i Form 10-404 Revised 5/ 5 IVTL q/z1/6, Submit Original Only A 9,-4 RBDMS 1,1; MAY 1 9 2016 • • 1J-159L1 /1J-102L1 DTTMS'JOBTYP SUMMARYOPS 4/26/16 MISC. Performed fullbore Crystal Seal MBE treatment @—1-3 bpm into MBE. CAPACITY Placed 2970#of 1-2-4 mesh Crystal Seal slurry @ average 0.27 ppg SUSTAINMENT concentration, Slurry was left underdisplaced w/41 bbls SW&35 bbls diesel. Note: will attach treatment report once available. 5/15/16 MISC. Clean out ice and slush from 400'down to 1,856'. Continue RIH performing CAPACITY a Fluff n' Stuff untilizing SSW w/Safelube down coil and backside. Clean SUSTAINMENT down to near lockup at 10,124' CTMD. No indications of CrystalSeal bridges or fill seen. Well freeze protected. ***Job complete*** KUP D 1J-159 ConocoPhiHips .L, Well Attribu Max AngleD TD Alaska,Inc, Wellbore API/UWI Field Name Wellbore Status ncl(1) MD)ftKB) Act Btm(ftKB) C 60 Ig,pv 500292329700 WEST SAK PROD 93.86 6,310.37 7,857.0 ... Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) "Rig Release Date MULTIPLE LATERALS-1J-159,5/18/201610.23.49 AM SSSV:NIPPLE Last WO: 1/28/2008 31.01 3/13/2006 Verhoal schematic(actual) 'Annotation Depth(ftKB) End Date Annotation Last Mod By 'End Date .� Last Tag: Rev Reason:WELL REVIEW osborl 5/10/2013 • HANGER;22.8 1111;.T... Casing Strings Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... WULen(I...Grade Top Thread ,,i,o5 CONDUCTOR 20 18.936 31.0 108.0 108.0 62.60 H-40 WELDED Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ORB) Set Depth(TVD)... WULen(I...Grade Top Thread SURFACE 103/4 9.950 31.2 2,364.5 2,206.4 45.50 L-80 _BTC Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...WULen(I...Grade Top Thread • PRODUCTION 7 5/8 6.875 26.6 5,575.1 3,695.3 29.70 L-80 BTCM • Casing Description OD(in) ID(in) Top(MB) 'Set Depth)ftKB) Set Depth(ND)...Wt/Len g...Grade Top Thread L2 LINER LEM 41/2 3.958 4,189.2 4,386.3 3,515.8 12.60 L-80 1ST .A./.CONDUCTOR;31.0.108.00-4-/' �v...��Liner Details Nominal ID NIPPLE;515.0 Top(ftKB) Top(TVD)(MB) Top Incl C) Item Des Com (in) 4,1892 3,465.9 72.86 PBR BAKER 190-47 PBR 5.750 HEAT TRACE;23.0 4,200.2 3,469.1 73.32 PACKER ZXP LINER TOP PACKER 4.950 1 4,208.2 3,471.3 73.66 SBE 'SEAL BORE EXTENSION 4.750 SURFACE;31.2-2,381.5 4,227.5 3,476.6' 74.48 XO Bushing 3.958 4,232.6 3,478.0 74.70 HANGER 1 LEM ABOVE HOOK HANGER 3.980 111 4,245.2 3,481.3 75.23 HANGER 2 LEM BELOW HOOK HANGER 3.980 GAS LIFT;2,569.4 4,341.0 3,505.0 75.66 SEAL ASSY LEM BAKER SEAL ASSEMBLY 3.880 a Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)... WULen(I...Grade Top Thread II L1 LINER HH LEM 41/2 3.958 4,355.1 4,705.5 3,571.1 12.60 L-80 IBT ME Liner Details Nominal ID Ill Top(ftKB) Top(ND)(ftKB) Top Incl C) Item Des Com (in) ill 4,355.1 3,508.4 75.80 PACKER ZXP LINER TOP PACKER 4.950 4,372.3 3,512.6 76.38 SBR 109-47 CASING SEAL BORE RECEPTACLE 4.750 GAS LIFT;4,083.8 1111 4,391.9 3,517.1 77.04 XO BUSHING CROSSOVER BUSHING 3.910 4,550.3 3,547.9 79.90 ABOVE HH LEM ABOVE HOOK HANGER 4.020 NIPPLE;4,137.2 4,560.9 3,549.7 80.16 INSIDE HH LEM INSIDE HOOK HANGER 4.020 GAUGE;4,147.6 [ss 4,626.4 3,560.0 81.80 NIPPLE CAMCO'DB'NIPPLE 3.562 I 4,702.3 3,570.6 81.97 SEAL ASSY BAKER SEAL ASSEMBLY 3.890 Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)... WULen(I...Grade Top Thread _ A-SAND LINER 41/2 3.958 4,666.1 7,842.1 3,642.2 12.60 L-80 IBT LOCATOR;4,193.6 r Liner Details Nominal ID jrm Top(ftKB) Top(ND)(ftKB) Top Incl I') Item Des Corn (in) SEAL ASSY;4,194.5 �. 4,666.1 3,565.6 81.92 PACKER "HRD"ZXP Liner Top Packer 5.5"X 7.6" 4.970 ;'I ; 4,685.1 3,568.2 81.94 NIPPLE "RS"Packoff Seal Nipple 5.5" 4.875 I' 4,688.0 3,568.6 81.95 HANGER FlexLock Liner Hanger 5.5"X 7.6" 4.853 4,697.8 3,570.0 81.96 SBE 190-47 Casing Seal Bore Ext.4.75"ID x 6.25"OD 4.750 1 'il li i4,717.4 3,572.8 81.99 XO BUSHING XO Bushing 3.92"ID,6.02 OD 3.920 • 0-SAND LINER;4,241.4- I11 I;. Tubing Strings 10,858.8 I) iI Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft..I Set Depth(TVD)(...Wt(Ibfft) Grade Top Connection I. TUBING WO 41/2 3.958 22.6 4,222.2 3,475.2 12.60 L-80 IBTM Completion Details • Nominal ID Top(ftKB) Top IND)(ftKB) Top Incl CI Item Des Com (in) ,,. ..r. 22.6 22.6 0.00 HANGER TUBING HANGER 3.958 =_- 515.0 514.8 5.01 NIPPLE CAMCO'DB'NIPPLE 3.875 L2 LINER LEM;4,189.2-4,386.3 ''.'�'. 4,1372 3,449.6 70.75 NIPPLE CAMCO DB Nipple 3.812 !JE' FF- 4,147.6 3,453.0 71.16 GAUGE GUARDIAN GAUGE CARRIER 3.850 4,193.8 3,467.2 73.06 LOCATOR LOCATOR 3.880 � � 4,194.5 3,467.4 73.08 SEAL ASSY BAKER GBH-22 PACKER 3.880 Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) B-SAND LINER;4,560.2- '11( g-�■. Top(ND) Top loci 11.1611 If Tii Top(ftKB) (ftKB) (°) Des Com Run Date ID(in) gt 4 23.0 23.0 0.00 HEAT HEAT TRACE SET DURING 1/23/2008 1/24/2008 0.000 TRACE WORKOVER Perforations&Slots Shot Dens Top(TVD) Btm(ND) (shoal Top(ftKB) Btm IftKB) (ftKB) (ftKB) Zone Date ft) Type Com 5,567.0 5,721.0 3,695.2 3,697.2 WS A2,1J- 2/23/2006 32.0 SLOTS SLOTTED LINER 0.125" ll1 159 x 2.5"x 32 spf @ 4 r..1 I Circumferential adjacent m rows,3"Centers L1 LINER HH LEM;4,355.1- n0 staggered ottd a dsg 3 ft. 4,705.51 111F. 5,845.0 6,091.0 3,694.4 3,688.1 WS A2,1J- 2/23/2006 32.0 SLOTS 159 6,399.0 7,810.0 3,681.8 3,642.2 WS A2,1J- 2/23/2006 32.0 SLOTS 159 T Mandrel Inserts 1 St ati PRODUCTION;28.8-5,575.1- onN Top(TVD) Valve Latch Port Size TRO Run SLOTS;5,567.0-5,721.0 Top(ftKB) (ftKB) Make Model OD)in) Sew Type Type )in) (psi) Run Date Corn - 1 2,589.4 2,407.6 CAMCO KBG-2- 1 GAS LIFT GLV BK-5 0.156 1,530.0 2/19/2008 1R 2 4,093.6 3,434.6 CAMCO KBG-2- 1 GAS LIFT OV BK-5 0.250 0.0 2/19/2008 1R SLOTS;5,845.0-6,091.0 - Notes:General&Safety SLOTS;6,399.0-7,810.0 ' End Date Annotation 'r 5/11/2006 NOTE:MULTI-LATERAL WELL:1J-159(A-SAND),1J-159L1(B-SAND),1J-159L2(D-SAND) A-SAND LINER;4,666.1-7,842.1 KUP D � 1J-159 ConocoPhillips ''" Alaska,Inc.. .. oPt,llan ••• MULTIPLE LATERALS-13-159,5/182016 10:23:49 AM Vertical schematic.(actual) 111 HANGER,22.6I'.,e{' �' Notes:General&Safety End Date Annotation 2/21/2009 NOTE:VIEW SCHEMATIC w/Alaska Schematic9.OREV Q —A-ti CONDUCTOR;31.0-108.0- NIPPLE;515.0 HEAT TRACE;23.0 SURFACE;31.2-2,364.5 GAS LIFT;2,5884 affl GAS LIFT;4,083.6 NIPPLE;4,137.2 GAUGE;4,147.6 LOCATOR;4193.8 SEAL ASSY.4,194 5 r"mom f,fI II D-SAND LINER;4,241 4- I,1 II10,859.6 J NER LEM 4,189.2-4,3863 111 1 /3-SAND LINER;4,580.2- ^ 11,161.1 rl 4 LI LINER HH LEM;4,355.1- _,I 4,705.5 PRODUCTION;26.6-5,575.1 , I SLOTS;5,567.0-5,721.0 SLOTS;5,845.08,081.0 SLOTS;6,398.0-7,810.0 A-SAND LINER;4,666.1-7,842.1 ''.3-:'*::;,,,, KUP 110JD 1J-159L1 COnocoPhillips s"41, Well Attribu Max AnglilD TD 4Ala, Inc, Wellbore APIIUWI Field Name Wellbore Status ncl CI MD(ftKB) Act Btm(ftKB) Gwmcophllh, 500292329760 WEST SAK PROD 92.41 7,600.66 11,187.0 ... Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date MULTIPLE LATERALS-12-159L1,5/18201610:25:06 AM SSSV:NIPPLE Last WO: 1/23/2008 31.01 3/13/2006 ,_..Venal pen &(actuah Annotation Depth(ftKB) End Date Annotation Last Mod By End Date Last Tag: Rev Reason:WELL REVIEW osborl 2/9/2011 I HANGER;22.6 NI .'aging btfings Casing Description OD(in) ID(in) Top(ftKB) Set Depth(MB) Set Depth(TVD)... WtILen(...Grade Top Thread B-SAND LINER 41/2 3.958 4,560.2 11,161.1 3,506.3 12.60 L-80 BTC I Liner Details Nominal ID Top(ftKB) Top(TVD)OMB) Top!nein Item Des Com (in) 4,560.2 3,549.6 80.14 HANGER 1 BAKER MODEL 91 F'HOOK HANGER(Outside 3.688 Casing 6.17') • 4,577.0 3,552.3 81.10 HANGER 2 BAKER MODEL B1 F'HOOK HANGER(Outside 3.688 • • Casing 6.17') _^-ti CONDUCTOR,31.0-108.0' 4,585.2 3,553.6 81.67 SWIVEL BAKER CASING SWIVEL 1920 NIPPLE;515.0 11,126.5 3,506.8 90.57 Cross over 4-1/2"IBT Box x 3-1/2"IBT Pin Crossover 2.992 I Perforations&Slots HEAT TRACE;23.0 I Shot ( Dens Top(ND) Btm(TVD) (shots/ Top(ftKB) Btm(MB) (ftKB) (MB) Zone Date tt) Type Com SURFACE;31.2-2,364.5 4,590.0 4,633.0 3,554.3 3,559.1 WS B,1J- 3/3/2006 32.0 SLOTS SLOTTED LINER 0.125" 159L1 x2.5"x32 spf@ 4 Circumferential adjacent 111 rows,3"Centers staggered 18 deg.,3 ft. GAS LIFT,2,589.4 41non-slotted ends in 4,643.0 7,891.0 3,559.9 3,510.6 WS B,1J- 3/3/2006 32.0 SLOTS 159L1 8,278.0 10,504.0 3,524.7 3,500.4 WS B,1J- 3/3/2006 32.0 SLOTS 159L1 If 10,506.0 11,127.0 3,500.5 3,506.8 WS 9,1J- 3/3/2006 32.0 SLOTS lit 159L1 - GAS LIFT,4,093.6 i Notes:General&Safety End Date Annotation 3/12/2006 NOTE:MULTI-LATERAL WELL: 1J-159(A-SAND),1J-159L1(B-SAND),1J-159L2(D-SAND) NIPPLE,4,137.2 2/21/2009 NOTE:VIEW SCHEMATIC w/Alaska Schematic9.OREV GAUGE,4,147.6 ilLOCATOR;4,193.8 IE I Y/_1 SEAL ASSY;4,194.5 1.''.11 NI II • D-SAND LINER,4,241.4- 'QIP, 10,859.6 L2 LINER LEM,4,189.2-4,386.3 � I ° PRODUCTION;26.6-5,5751 L1 LINER HH LEM,4,355.1-\ 4,705.5 Tii SLOTS;4,590.0-4,633.0 SLOTS;4,643.0-7,891.0 IF SLOTS,8,278.0-10,504.0 1 1 [ SLOTS,10,506.0-11,127.0 1 B-SAND LINER;4560.2 111["- - 11,161 1 OF 0)",\ sA THE STATE Alaska Oil and Gas ��►,; o � Conservation Commission s KA 333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main: 907 279 1433 OF ALAS"' Fax 907.276.7542 www.aogcc.alaska.gov John Peirce Sr. Wells Engineer `�' � ConocoPhillips Alaska, Inc. -- ©© P.O. Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, West Sak Oil Pool, KRU 1J-159L1 Sundry Number: 315-661 Dear Mr. Peirce: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Cathy P. oerster Chair 14— DATED this 4.4) day of October, 2015 Encl. RBDMSnU O 1 2015 STATE OF ALASKA Al KA OIL AND GAS CONSERVATION COMMON APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 1.Type of Request: Abandon r Plug Perforations fl Fracture Stimulate r Pull Tubing r Operations Shutdown fl Suspend r Perforate r Other Stimulate r Alter Casing r Change Approved Program Rug for Redrill r Perforate New Pool r Repair Well Re-enter Sus p p Well r Other:Crystal Seal MBE Treatment(yi 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. ` Exploratory r Development 206-006 3.Address: Stratigraphic r Service 6.API Number: P.O. Box 100360,Anchorage,Alaska 99510 50-029-23297-60 • 7.If perforating, What 8.Well Name and Number: Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require spacing exception? Yes r No 17 y KRU 1J-159L1 ' 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL 25661,25662 , Kuparuk River Field/West Sak Oil Pool 11. PRESENT WELL CONDITION SUMMARY Total depth MD(ft): Total Depth TVD(ft): Effective Depth MD(ft): Effective Depth TVD(ft): Plugs(measured): Junk(measured): 11187 • 3506 ` 11159' ' 3506' • none none Casing Length Size MD TVD Burst Collapse CONDUCTOR 77 20 108' 108' SURFACE 2333 10.75 2365' 2207' iD PRODUCTION 5547 7.625 5575' 3696' Nr _ '.„,a B-SAND LINER 6601 4.5 11161' 3506' I),~I 2 J. 2015 t-5 to (245 ACGCC Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): slotted liner from 4590'-11126' 3557-3507' 4.5 L-80 4222 Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft) PACKER-ZXP LINER TOP PACKER MD=4200 TVD=3469 PACKER-ZXP LINER TOP PACKER MD=4355 TVD=3508 PACKER-"HRD"ZXP LINER TOP PACKER MD=4666 TVD=3567 NIPPLE-CAMCO"DB"NIPPLE MD=515 TVD=515 12.Attachments: Description Summary of Proposal 13. Well Class after proposed work: Detailed Operations Program r BOP Sketch Exploratory Stratigraphic Development Service 14.Estimated Date for Commencing Operations: 15. Well Statusafafter,,pproposed work: 11/15/2015 OIL I/ WINJ r WDSPL r Suspended 16.Verbal Approval: Date: GAS r WAG fl GSTOR r SPLUG r Commission Representative: GINJ r Op Shutdown r Abandoned r 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: John Peirce @ 265-6471 Email: John.W.Peirce conocophillips.com Printed Name John Peirce Title: Sr.Wells Engineer Signaturedete. '46,7. 4......4:- r Phone:Phone:265-6471 Date 1p/20/1 Commission Use Only Sundry Number: Conditions of approval: Notify Commission so that a representative may witness 316- (p(a I Plug Integrity r BOP Test r Mechanical Integrity Test r Location Clearance Other: Spacing Exception Required? Yes D No Subsequent Form Required: /0 —4-O [- APPROVED BY _ Approved by: 7204-4.141.0"-- COMMISSIONER THE COMMISSION Date:/ -2 -/S tr TL to /7 5— Approved application is valid for month/ qm the date of approval. Submit Form and Form 10-403 Revised 5/2015 ORIGINAL 11 6j Attachments in Duplicate /o' f RBDMS� mmt 022015 • . 1J-102L1 to 1J-159L1 B Sand MBE Treatment Proposal 1J-102 Tri-Lat injector was drilled & completed in 2006 with laterals in West Sak A, B, & D sands. On 3/2/08, a 1J-102 MBE occurred to offset producer 1J-159. A 4/23/08 1J-102 main-bore IPROF saw all PWI entering 1J-102L1. A 2008 1J-102L1 (PROF RIH stuck the BHA in the B Diverter. After lengthy fishing to retrieve all of the fish, a B Iso-Sly was set 9/28/08 before diagnosing the B MBE location. 1J-102 was on PWI to A & D sands only until 2015. On 6/8/15, a Plug was set at 5081' RKB to isolate the A lat, then a B Diverter and a D Iso-Sly were set 6/9/15. A 6/10/15 IPROF in 1J-102L1 to 11109' MD found a heel MBE at -5350' RKB at the first slotted joint below the B LEM. On 9/18/15, a fullbore Crystal Seal job was pumped -3 bpm (per 10-403 Sundry Approval #315-449) to fill the B MBE. A total of 3,795 lbs of 4 mm Crystal Seal was displaced to the MBE resulting in final net treating pressure gain of 640 psi. This job took the largest Crystal Seal volume ever pumped to treat any West Sak MBE. On 9/23/15, 1J-102L1 was returned to PWI, but on 10/4/15 offset producer 1J-159 pressure & temperature rapidly increased indicating that the MBE treatment fromlJ-102L1 to 1J-159 had failed. The MBE volume is probably quite large and will need more Crystal Seal to seal it. A fullbore Crystal Seal Retreatment is proposed to seal the B MBE to return 1E-102L1 to PWI. Procedure: Pumping: 1) Fullbore pump a -10 bbl lnj test with Seawater to -3 bpm to verify good injectivity. Continue pumping Crystal Seal Slurry down tubing made with 4 mm mesh Crystal Seal at 0.25 ppg in Seawater to seal the B MBE. Hold constant -3 bpm Crystal Seal treatment rate to monitor MBE treatment response and possible Crystal Seal screenout during slurry pumping. If screenout develops, attempt to pump 80 bbls of Diesel Flush down tubing to displace Crystal Seal to B MBE. Tubular volume is 81 bbls from surface to MBE. If screenout is not seen, but 1000 psi max WHP target has been reached, swap to 35 bbls Diesel to FP to 2000' TVD followed by SD. RD. Coil Tubing: 2) RIH with 2" OD Jet Swirl Nozzle BHA to get through 2.25" ID CMU Iso-Sly (already set) to jet through Crystal Seal to as deep as possible to shear/ mechanically break all Crystal Seal remaining in the liner. POOH w/CT. RD. Put 1J-102L1 on PWI to evaluate results of the B MBE treatment for a period long enough to verify a successful B MBE treatment exists before executing remaining work. 3) RIH with IPROF BHA on CT to pass through 2.25" ID CMU Iso-Sly. Memory log down and up passes to verify the B MBE is sealed or still taking PWI. Wait 2 hours and then log a cool back pass. POOH with CT. RD CTU. Return 1J-102L1 to PWI service. If no indication of a B MBE, normal up PWI to all 3 laterals as follows: 4) RIH & pull the 2.25" ID Iso-Sly (from leaky CMU Sleeve) at 4631' RKB. 5) RIH & pull the 'D' Iso-Sly set across the D LEM at 4730' RKB to open the D lat to PWI. 6) RIH & pull the 'B' Diverter set in the B LEM at 5047' RKB. 7) RIH & pull Prong and 3.562" Plug set at 5081' to open the A lat to PWI. 8) RIH & set 2.25" ID Iso-Sly in CMU Slv at 4631' RKB to isolate leaky CMU Slv. Perform MIT-IA to verify good set integrity of Iso-Sly prior before returning 1J-102 to PWI service to all 3 laterals. ' KUP I 1J-159L1 ConocoPhillips $ Well Attributes Max Angle&MD TD A3Sh8,Inc, Wellbore APUUWI Field Name Well Status Ind(*) MD(ftKB) Act Btm(ftKB) Cr..,u�.ralbps ,R 500292329760 WEST SAK PROD 92.41 7,600.66 11,187.0 Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date wauco�nq.Mu�na�g_LATERALS-iJ-15su.s/1nrzo13eazlsAM SSSV:NIPPLE 75 8/14/2012 Last WO: 1/23/2008 31.01 3/13/2006 schematic'-Actual.. Annotation Depth(ftKB) End Date Annotation Last Mod By End Date Last Tag: Rev Reason:WELL REVIEW osborl 2/9/2011 Casing Strings Casing Description String 0... String ID...Top(ftKB) Set Depth(f...Set Depth(TVD)...String Wt...String... String Top Thrd HANGER.23 B-SAND LINER 41/2 3.958 4,560.2 11,161.1 3,506.3 12.60 L-80 BTC Liner Details Top Depth (TVD) Top Incl Nomi... Top(ftKB) (ftKB) r Item Description Comment ID(in) 4,560.2 3,549.6 80.14 HANGER 1 BAKER MODEL B1 F'HOOK HANGER(Outside Casing 6.17') 3.688 4,577.0 3,556.0 86.83 HANGER 2 BAKER MODEL B1 F'HOOK HANGER(Outside Casing 6.17') 3.688 4,585.2 3,556.7 86.97 SWIVEL BAKER CASING SWIVEL 3.920 11,126.5 3,506.8 90.57 Cross over 4-1/2"IBT Box x 3-1/2"IBT Pin Crossover 2.992 CONDUCTOR. Perforations&Slots 31-108 Shot NIPPLE,515 Top(TVD) Btm(TVD) Dens Top(ftKB)Btm(ftKB) (ftKB) (ftKB) Zone Date (sh•-- Type Comment 4,590.0 4,633.0 3,557.1 3,560.0 WS B,1J-159L1 3/3/2006 32.0 SLOTS SLOTTED LINER 0.125"x 2.5"x 32 HEAT TRACE, sof @ 4 Circumferential adjacent 23 rows,3"Centers staggered 18 deg.,3 ft.non-slotted ends ( 4,643.0 7,891.0 3,560.5 3,509.5 WS B,1J-159L1 3/3/2006 32.0 SLOTS SURFACE, - J L.I8,278.0 10,504.0 3,524.4 3,500.7 WS B,1J-159L1 3/3/2006 32.0 SLOTS 10,506 0 11,127.0 3,500.7 3,506.8 WS B,1J-159L1 3/3/2006 32.0 SLOTS ( 7 Notes:General&Safety II End Date Annotation GAS LIFT, y 3/12/2006 NOTE:MULTI-LATERAL WELL: 1J-159(A-SAND),1J 159L1(B-SAND),1J-159L2(D-SAND) 2,589 1 ` 221f2009 NOTE:VIEW SCHEMATIC w/Alaska Schematic9.0REV GAS LIFT, 4,094 at NIPPLE,4,137 IME GAUGE,4,148 ME LOCATOR, 4,194 SEAL ASSY, 4,195 • II L2 LINER LEM, / 4,189-4,386 SLOTS. 4,590-4,633 L1 LINER HH LEM, 4.3553.706 PRODUCTION, „ h 275575 4,643-7,891 SLOTS, SLOTS,_ 8,278.10,504 SLOTS, Mandrel Details 1050611127 Top Depth Top Port (ND) Incl OD Valve Latch Sire TRO Run N...Top(ftKB) IftKB) (°) Make Model (In) Sere Type Type (in) (psi) Run Date Com..._ B-SAND 1 2,589.4 2,407.1 25.48 CAMCO KBG-2-1R 1 GAS LIFT GLV BK-5 0.156 1,530.0 2/192008 L also-1f.1s1INER, 2 4,093.6 3,432.7 68.81 CAMCO KBG-2-1R 1 GAS LIFT OV BK-5 0.250 0.0 2/19/2008 TD(1J-159L1), 11,187 .. STATE OF ALASKA ALARAOIL AND GAS CONSERVATION COMISSION REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon r Plug Perforations r Fracture Stimulate r Pull Tubing r Operations Shutdown r Performed: Suspend r Perforate r Other Stimulate r Alter Casing r Change Approved Program r Rug for Redrill r Perforate New Pool r Repair Well r Re-enter Susp Well r Other:Crystal Seal MBE Treatmet7 2.Operator Name: 4.Well Class Before Work: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Development r Exploratory r 206-006 3.Address: 6.API Number: Stratigraphic r Service r P. O. Box 100360,Anchorage,Alaska 99510 50-029-23297-60 7.Property Designation(Lease Number): 8.Well Name and Number: ADL 25661,25662 KRU 1J-159L1 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): none Kuparuk River Field/West Sak Oil Pool 11.Present Well Condition Summary: Total Depth measured 11187 feet Plugs(measured) none true vertical 3506 feet Junk(measured) none Effective Depth measured 11159 feet Packer(measured) 4200,4355,4666 true vertical 3506 feet (true vertical) 3469, 3508, 3567 Casing Length Size MD TVD Burst Collapse CONDUCTOR 77 20 108 108 SURFACE 2333 10.75 2365 2207' PRODUCTION 5547 7.625 5575 3696 B-SAND LINER 6601 4.5 11161 3506 ,, 1 E E V Perforation depth: Measured depth: slotted liner from 4590'-11127' I " 21 2015 True Vertical Depth: 3557-3507' SCANNED �^y '� A C Tubing(size,grade,MD,and TVD) 4.5, L-80,4222 MD, 3475 TVD Packers&SSSV(type,MD,and TVD) PACKER-ZXP LINER TOP PACKER @ 4200 MD and 3469 TVD PACKER-ZXP LINER TOP PACKER @ 4355 MD and 3508TVD PACKER-"HRD"ZXP LINER TOP PACKER @ 4666 MD and 3567 TVD NIPPLE-CAMCO'DB'NIPPLE @ 515 MD and 515 TVD 12.Stimulation or cement squeeze summary: Intervals treated(measured): not applicable Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation na Subsequent to operation na 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations pi Exploratory r Development ' Service r Stratigraphic r Copies of Logs and Surveys Run r 16.Well Status after work: Oil 7 Gas r WDSPL r Printed and Electronic Fracture Stimulation Data r GSTOR rT 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: 315-451 Contact John Peirce a(�,265-6471 Email John.W.Peirceconocophillips.com Printed Name John Peirce Title Sr. Wells Engineer Signature74174: ® ✓ Phone:265-6471 Date iQ rZO(/.5—TW1 c l VTL t0/221/5- RBDMS CT 2 2 2015 Form 10-404 Revised 5/2015 . 14/2.0-6-- Submit Original Only j KUP 1J-159L1 ConocoPhillips 0° Well Attributes Max An.le&MD TD Wellhore APIA)WI Field Name Well Status Incl(°) MD(ftKB) Act Btm(ftKB) carndnwkpa 500292329760 WEST SAK PROD 92.41 7,600.66 11,187.0 ""' Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date well co�n9.Mu�r;PLE LArEHA�s-tJ-i sou,5/1azo1384�a8AM SSSV:NIPPLE 75 8/14/2012 Last WO: 1/23/2008 31.01 3/13/2006 Scnemalic-Actual Annotation Depth(ftKB) End Date Annotation Last Mod By End Date Last Tag: Rev Reason:WELL REVIEW osborl 2/9/2011 Casin• Strin r s ,,oz,,,_ign,pp Casing Description String 0... String ID...Top(ftKB) Set Depth(f...Set Depth(ND)...String Wt...String.. String Top Thrd HANGER,23 B-SAND LINER 4 1/2 3.958 4,560.2 11,161.1 3,506.3 12.60 L-80 _ BTC .. — Liner Details 111 Top Depth - -- - - -- - - — - — (TVD) Top Incl Need... Top(ftKB) (ftKB) (°) Item Description Comment ID(in) 3.688 4,560.2 3,549.6 80.14 HANGER 1 BAKER MODEL B1 F'HOOK HANGER(Outside Casing 6.17') 4,577.0 3,556.0 86.83 HANGER 2 BAKER MODEL B1 F'HOOK HANGER(Outside Casing 6.17') 3.688 4,585.2 3,556.7 86.97 SWIVEL BAKER CASING SWIVEL 3.920 11,126.5 3,506.8 90.57 Cross over 4-1/2"IBT Box x 3-12"IBT Pin Crossover 2.992 CONDUCTOR,__ Perforations,&Slots 31-108 Shot NIPPLE,515 ' Top(TVD) Btm(TVD) Dens Top(MB)Btm(ftKB) (ftKB) (ftKB) Zone Date OM- Type Comment 4,590.0 4,633.0 3,557.1 3,560.0 WS B,1J-159L1 3/3/2006 32.0 SLOTS SLOTTED LINER 0.125"x 2.5"x 32 HEAT TRACE, spf @ 4 Circumferential adjacent rows,3"Centers staggered 18 deg.,3 a ft.non-slotted ends 4,643.0 7,891.0 3,560.5 3,509.5 WS B,1J-159L1 3/3/2006 32.0 SLOTS SUR31-2,3FACE. 8,278.0 10,504.0 3,524.4 3,500.7 WS B,1J-159L1 3/3/2006 32.0 SLOTS 64 10,506.0 11,127.01 3,500.7 3,506.8 WS B,1J-159L1 3/3/2006 32.0,SLOTS S Notes:General&Safety - End Date Annotation GnsuFT, _ Ilr3/12/2006 NOTE:MULTI-LATERAL WELL: 1J-159(A-SAND),1J-159L1(B-SAND),1J-159L2(D-SAND) 2,589 2212009 NOTE:VIEW SCHEMATIC w/Alaska Schema8c9.OREV 1111 NW NI MI GAS LIFT, 4,094 Ell glill NIPPLE,4,137 XII/---- Ell GAUGE,4,148 :11/11111 IIIII LOCATOR, 4,794 SEAL ASSY, T`i—"' 4.195 - .I it L2 LINER LEM, 1 4,185-4.388 SLOTS, 4,590-4,633 L1 LINER HH LEM, 4,355-4,706 PRODUCTION, e H 27-5,575 11 li ii 4,64S3-7,891LOTS, _-- - SLOTS, --- 6278-10,504 SLOTS. Mandrel Details 1050611127 Top Depth Top Port (ND) Incl OD Valve Latch Size TRO Run, N...Top(ftKB) (ftKB) (°) Make Model (in) Sery Type Type (in) (Pal) Run Date Corn... B-SAND 1 2,589.4 2,407.1 25.48 CAMCO KBG-2-1R 1 GAS LIFT GLV BK-5 0.156 1,530.0 2/19/2008 4560-LIN R,\ t. 2 4,093.6 3,432.7 68.81 CAMCO'KBG-2-1R 1 GAS LIFT OV BK-S 0.250 0.0 2/19/2008 TO(1J-159L1), ,. la; 11,187 1J-102L1 WELL EVENTS SUMMARY DATE SUMMARY 9/2/2015 FCO ice plug from 40'to 75'. Peforate MBE interval in B Lateral from 5,328'to 5,333' RKB with SLB 2 inch Powerflow HSD guns (2006FP-6SPF, EHD 0.45", 4.5" PEN). Verified ASF. Next, set a 2.25" ID ISO-Sleeve at leaky CMU @ 4,631' RKB. Well left freeze protected and shut in. Well is now ready for Crystal Seal job Pinholed coil tubing @ 2,315'while POOH no spills. Will cut coil tubing in morning. 9/8/2015 BRUSH n' FLUSH TBG TAG ISO SLEEVE @ 4631' RKB, IN PROGRESS. 9/9/2015 SET 4 1/2 HOLE FINDER/CATCHER SUB ASSEMBLY @ 4631' RKB, PULLED DV @ 4486' RKB, LOADED TBG & IA WITH INHIBITED SEAWATER& DIESEL FREEZE PROTECT, SET DV @ 4486' RKB MIT IA PASS, PULLED HOLE FINDER ASSEMBLY @ 4631' RKB. COMPLETE. 9/17/2015 INJECTIVITY TEST W/S/W PUMPED10 BBLS@1 BPM PUMPED 10 BBLS @ 2BPM PUMPED 80 BBLS @ 3BPM FREEZE PROTECT TBG W/35 BBLS DIESEL JOB COMPLETE 9/18/2015 Pumped fullbore MBE treatment per design placing —290 bbls 3% KCL/4 mil Crystal Seal slurry into formation (3795#of CS). Displaced gel with 80 bbls diesel. Well left shut in. Note: Do not put on injection or bring offset producer online until after 06:00, 9/19. 9/21/2015 Injectivity test, 40 bbls dsl down tbg @ 1 bbl/min pressured up to 200 psi,job complete 10/5/2015 FREEZE PROTECT WELL W/2 BBL METHANOL 100% DOWN F/L FOLLOWED BY 38 BBL DIESEL DOWN TBG JOB COMPLETE 10/8/2015 LOG 24 ARM CALIPER SURVEY FROM 4650'TO SURFACE. LOG CORRELATED TO TUBING DETAIL RECORD DATED 03 OCT 2006. DATA SENT TO ANCHORAGE FOR FURTHER PROCESSING. JOB COMPLETE. w\��\�j/j�s7 THE STATE Alaska Oil and Gas E.,0,01-4 ,1 of/` T /\ l SJ( /�, Conservation Commission '' == 1�1 L1`1C INIT____ _ 333 West Seventh Avenue *h„ GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main: 907.279 1433 OF ALAS Fax. 907.276 7542 ),V.. www.aogcc alaska.gov i John Peirce Sr. Wells Engineer cao C - 006 ConocoPhillips Alaska, In P.O. Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, West Sak Oil Pool, KRU 1J-159L1 Sundry Number: 315-451 Dear Mr. Peirce: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Cathy . Foerster Chair DATED this 24;of July, 2015 Encl. RECEIVED STATE OF ALASKA , 3KA OIL AND GAS CONSERVATION COMIb.._,iION JUL 2 3 2015 APPLICATION FOR SUNDRY APPROVALS P7-S 71 z4KJ( S • 20 AAC 25.280 AO G G G 1.Type of Request Abandon r Rug Perforations r Fracture Stimulate r Pull Tubing r Operations Shutdown r Suspend r Perforate r Other Stimulate r Alter Casing r Change Approved Program r Rug for Redrill r Perforate New Pool r Repair Well r Re-enter Susp Well f— OtherCrystal Seal MBE Treatment 17 2 Operator Name. 4 Current Well Class 5 Permit to Drill Number ConocoPhillips Alaska, Inc. Exploratory r Development ly_ 206-006 • 3 AddressStratigraphic r Service r 6 API Number P.O. Box 100360,Anchorage,Alaska 99510 50-029-23297-60 7 If perforating, What 8 Well Name and Number Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require spacing exception? Yes r No r✓ KRU 1J-159L1 9 Property Designation(Lease Number) 10 Field/Pool(s). ADL 25661,25662 - Kuparuk River Field/West Sak Oil Pool • 11 PRESENT WELL CONDITION SUMMARY Total depth MD(ft) Total Depth TVD(ft) Effective Depth MD(ft) Effective Depth TVD(ft) Plugs(measured). Junk(measured) 11187 - 3506 - 11159' - 3506' - none none Casing Length Size MD TVD Burst Collapse CONDUCTOR 77 20 108' 108' SURFACE 2333 10 75 2365' 2207' PRODUCTION 5547 7.625 5575' 3696' B-SAND LINER 6601 4.5 11161' 3506' Perforation Depth MD(ft) Perforation Depth TVD(ft) Tubing Size Tubing Grade Tubing MD(ft) slotted liner from 4590'-11126'- 3557-3507' 4.5 L-80 4222 Packers and SSSV Type Packers and SSSV MD(ft)and TVD(ft) PACKER-ZXP LINER TOP PACKER MD=4200 TVD=3469 PACKER-ZXP LINER TOP PACKER MD=4355 TVD=3508 PACKER-"HRD"ZXP LINER TOP PACKER MD=4666 TVD=3567 NIPPLE-CAMCO"DB"NIPPLE MD=515 TVD=515 12 Attachments: Description Summary of Proposal r` 13 Well Class after proposed work Detailed Operations Program BOP Sketch r Exploratory r Stratigraphic E Development r , Service r 14 Estimated Date for Commencing Operations 15 Well Status_after proposed work. 8/1/2015 OIL IV WINJ r" WDSPL r Suspended r 16 Verbal Approval Date GAS r WAG r GSTOR r SPLUG r Commission Representative GINJ r Op Shutdown r" Abandoned r 17. I hereby certify that the foregoing is true and correct to the best of my knowledge Contact John Peirce @ 265-6471 Email John.W.Peirce(a7.conocophillips.com Printed Name John Peirce Title Sr.Wells Engineer Signature ti„ ,r _, Phone 263-4612 Date 7/22//15 Commission Use Only 1 Sundry Number. Conditions of approval Notify Commission so that a representative may witness 315- 961 Plug Integrity r BOP Test r Mechanical Integrity Test r Location Clearance i-- Other Other Spacing Exception Required? Yes ❑ No d Subsequent Form Required / 0 — 4 t2 4-- APPROVED BY II Approved byf;j4COMMISSIONER THE COMMISSION Date 7-2 _/- - Approv p ca l n s v li for 12 months fro the date of approval. vrt 7_/Z /� 0 h /y,� Submit Form and Form 10-403 Revised 5/2015 N -1/42) 423 ,� RBDM a ents' hca O� .�/ K✓� 411 T 1 5 KUP 1J-159L1 • ConocoPhillips Well Attributes Max Angle&MD TD AlaskaIncWellbore APIAJWI Field Name 'Well Status Inc!I.) MD(ftKB) Act Btm MKS) 500292329760 WEST SAK PROD 92.41 7,600.66 11,187.0 Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date Well Confyl:MULTIPLE LATERALS-1J-159L1,5/102013 8:47'.18 AM SSSV:NIPPLE 75 8/14/2012 Last WO: 1232008 31.01 3/13/2006 Schematic-Actual Annotation Depth(RKB) End Date Annotation Last Mod By End Date Last Tag: Rev Reason:WELL REVIEW osborl 2/92011 Casing Strings _ iirpm Casing Description String 0... String ID...Top(ftKB) Set Depth(f...Set Depth(TVD)...String Wt...String... String Top Thrd HANGER,23 'i B-SAND LINER 41/2 3.958 4,560.2 11,161.1 3,506.3 12.60 L-80 BTC Liner Details 'Top Depth - — - — - — (ND) Top lent Nomi lop(RKB) MB) (°) Item Deacdpdan Comment ID(in) 4,560.2 3,549.6 80.14 HANGER 1 BAKER MODEL B1 F'HOOK HANGER(Outside Casing 6.17) 3.688 - - 1 4,577.0 3,556.0 86.83 HANGER 2 BAKER MODEL B1 F'HOOK HANGER(Outside Casing 6.17) 3.688 4,585.2 3,556.7 86.97 SWIVEL BAKER CASING SWIVEL 3.920 11,126.5 3,506.8 90.57 Cross over 4-1/2"IBT Box x 3-1/2"IBT Pin Crossover 2.992 CONDUCTOR. 1 Perforations&Slots .. . 31-108 j�" To ND BtmShot NIPPLE,515 -- r P(TVD) (TVD) Dent Top(ftKB)Btm(RKB) (ftKB) (RKB) Zone Date (ah-- Type Comment 4,590.0 4,633.0 3,557.1 3,560.0 WS B,1J-159L1 3/3/2006 32.0 SLOTS SLOTTED LINER 0.125"x 2.5"x 32 HEAT TRACE, 23spf @ 4 Circumferential adjacent rows,3"Centers staggered 18 deg.,3 ft.non-slotted ends 4,643.0 7,891.0 3,560.5 3,509.5 WS B,1J-159L1 3/3/2006 32.0 SLOTS SURFACE, 8,278.0 10,504.0 3,524.4 3,500.7 WS B,1J-159L1 3/3/2006 32.0 SLOTS 31-2,364 10,506.0 11,127.0 3,500.7 3,506.8 WS B,1J-159L1 3/3/2006 32.0 SLOTS Notes:General&Safety End Date Annotation GAS LIFT 3/12/2006 NOTE:MULTI-LATERAL WELL: 1J-159(A-SAND),1J-159L1(B-SAND),1J-159L2(D-SAND) 2.589 t 2/21/2009 NOTE:VIEW SCHEMATIC w/Alaska Schematic9.OREV GAS LIFT, 4.094 NIPPLE,4,137 IL GAUGE,4,148 ' LOCATOR, 4,194 SEAL ASSY, 4,1W L2 LINER LEM. 4.189-0,386 sto SLOTS, 4.5904.633 L1 LINER HH LEM, 4,355-4,706 PRODUCTION, 27-5.575 N I H SLOTS, `_ 4,643-7,891 SLOTS, 8,278-10,504 SLOTS. Mandrel Details 1050611127 Top Depth Top Port 5.-- (TVD) not OD Valve Latch Size IRO Run N...Top(RKB) (KKK) (*) Make Model (in) Sore Type Type (in) (psi) Run Date Com... 8-SAND 1 2,589.4 2,407.1 25.48 CAMCO KBG-2-1R 1 GAS LIFT GLV BK-5 0.156 1,530.0 2/192008 456017NE6\ 2 4,093.6 3,432.7 68.81 CAMCO KBG-2-1R 1 GAS LIFT OV BK-5 0.250 0.0 2/192008 TD(1J-159L1), 11,187 1J-102L1 to 1J-159L1 B Sand MBE Treatment Proposal 1J-102 Tri-Lat injector was drilled & completed in 2006 with laterals in West Sak A, B, & D sands. On 3/2/08, a 1J-102 MBE occurred to offset producer 1J-159. A 4/23/08 1J-102 main-bore IPROF saw all PWI entering 1J-102L1. A 2008 1J-102L1 IPROF RIH stuck the BHA in the B Diverter. After lengthy fishing to retrieve all of the fish, a B Iso-Sly was set 9/28/08 (before diagnosing the B MBE location). 1J-102 was on PWI to A & D sands only until 2015. On 6/8/15, a Plug was set at 5081' RKB to isolate the A lat, then a B Diverter and a D Iso-Sly were set 6/9/15. An 6/10/15 IPROF in in 1J-102L1 to 11109' MD found a robust `heel' MBE at -5350' RKB at the first slotted joint below the B LEM. Note, the top of B lat plop & drop liner is -197' out in OH lateral below the B LEM (per 9/22/06 Liner Detail). A fullbore Crystal Seal treatment to seal the B MBE is proposed to return 1 E-102L1 to PWI. Procedure: E-line: 1) RIH with 5' perf gun on dual tractors to shoot 6 spf, 60 deg ph large hole perfs at 5328 - 5333' RKB. This perfs the middle of the first 4.5" slotted joint near the MBE at -5350' to allow better CrystalSeal entry through slotted liner to the B MBE. Fire gun. POOH. RD. Coil Tubing: 2) RIH & set 2.25" ID Iso-Sly in CMU Slv at 4631' RKB to isolate leaky CMU Slv for Crystal Seal job. Perform MITIA to verify good Iso-Sly set integrity. Pumping: 3) Fullbore pump -100 bbl Step Rate Inj Test (SRIT) with Seawater to 4 bpm to verify good injectivity. Select a steady treatment rate to hold constant during Crystal Seal treatment to monitor MBE treatment response, and possible Crystal Seal screenout during slurry pumping. After SRIT, continue FB pumping Crystal Seal Slurry stages at constant rate (target 3 - 4 bpm) to the B MBE. Pump all slurry concentrations using only 4 mm mesh Crystal Seal in 3% KCL Water, starting with 0.10 ppg slurry pumped down tubing. Volume of each stage is TBD during pumping based on treating pressure responses noted during pumping. Ramp stages at: 0.10, 0.15, 0.20, to a maximum of 0.25 ppg, or (if needed) swap to pumping Flush if indication of imminent screen out develops during slurry pumping. If screenout development is noted, attempt to pump 80 bbls of Diesel Flush down tubing to displace all Crystal Seal from well to the B MBE. Tubular volume = 81 bbls (surface to MBE). If screenout has not been seen, but it is time to call Flush, pump at least 35 bbls Diesel to FP to 2000' TVD, then SD. RD. Coil Tubing: 4) RIH with 2" OD Jet Swirl Nozzle BHA (to get through 2.25" ID CMU Iso-Sly set in step 2) on either 1.5", 1.75", or 2" OD CT (best CT OD option TBD) to jet through Crystal Seal down to as deep as possible to shear and mechanically break all Crystal Seal remaining in the liner. POOH w/CT. RD. Put 1J-102L1 on PWI to evaluate results of the B MBE treatment for a period long enough to verify that a successful B MBE treatment has been achieved prior to executing step 6 and beyond. 5) RIH with Slim IPROF BHA on CT to pass through 2.25" ID CMU Iso-Sly (set in step 2). Memory log down and up passes to verify if the B MBE is sealed off or still taking PWI. Wait 2 hours and then log a cool back pass. POOH with CT. RD CTU. Return 1J-102L1 to PWI service. If months have passed without obvious indications of a B MBE treatment failure, proceed to normal up the well to resume PWI to all 3 laterals as follows: Coil Tubing: 6) RIH & pull the 2.25" ID Iso-Sly (from leaky CMU Sleeve) at 4631' RKB. 7) RIH & pull the 'D' Iso-Sly set across the D LEM at 4730' RKB to open the D lat to PWI. 8) RIH & pull the 'B' Diverter set in the B LEM at 5047' RKB. 9) RIH & pull Prong and 3.562" Plug set at 5081' to open the A lat to PWI. 10) RIH & set 2.25" ID Iso-Sly in CMU Slv at 4631' RKB to isolate leaky CMU Slv. Perform an MITIA to verify good set integrity of Iso-Sly prior to returning 1J-102 to PWI service. Return 1J-102 to PWI service to all 3 laterals. • • Image Project Well History File Cover Page XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. ~Q ~ - ~ ©~ Well History File Identifier Organizing (done) RES AN Color Items: ^ Greyscale Items: ^ Poor Quality Originals: ^ Other: NOTES: BY: Maria _ Project Proofing BY: Maria Scanning Prep-ar~ation BY: ( Maria 1 Two-sided IIIII~IIIIIIIIIIIII DIGITAL DATA ~iskettes, No.~,,,,, ^ Other, No/Type: Date: Date: Re,~a~~e~ea iuumiiuiiiui OVERSIZED (Scannable) ^ Maps: ^ Other Items Scannable by a Large Scanner OVERSIZED (Non-Scannable) ^ Logs of various kinds: IIIIIIIIIIIIIIIIII w~P Production Scanning Stage 1 Page Count from Scanned File: __~__~ J (Count does include cover sheet) Page Count Matches Number in Scab nning Preparation: !~ YES NO BY: Maria Date: ~ 3 ©~ /s/ Stage 1 If NO in stage 1, page(s) discrepancies were found: YES NO BY: Maria x 30 = ~ + =TOTAL PAGES~~ C Count does not include cover sheet ( ) Date: ~ /s/ ~l Date: Scanning is complete at this point unless rescanning is required. "iuiuuiimiuu BY: Maria Date: /s/ Comments about this file: Quality Checked III IIIIII III III III 10/6/2005 Well History File Cover Page.doc ' STATE OF ALASKA S ALA OIL AND GAS CONSERVATION COMMSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Abandon r Repair well r Plug Perforations r Perforate r . Other pr, Pull L1 -LEM Pull Tubing Stimulate - Frac Wa iver Isolation Sleeve Alter Casing r _i g r r c Time Extension ('"" (B-sand) Change Approved Program r Operat. Shutdown r Stimulate - Other r Re -enter Suspended Well r 2. Operator Name: 4. Well Class Before Work: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. • Development J • Exploratory r 206 -006 " 3. Address: 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 Stratigraphic r Service r 50- 029- 23297 -60 • 7. Property Designation (Lease Number): 8. Well Name and Number: ADL025661; ADL025662 1J -159L1 • 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 11187 • feet Plugs (measured) None true vertical 3506 feet Junk (measured) None Effective Depth measured 11159 feet Packer (measured) 4200 true vertical 3506 feet (true vertical) 3469 Casing Length Size MD TVD Burst Collapse CONDUCTOR 77 20 108 108 0 0 SURFACE 2333 18.125 2364 2206 0 0 L2 LINER LEM 197 6.61 4386 3516 0 0 PRODUCTION 4538 7.625 4565 3550 0 0 L1 LINER HH LEI 210 8.47 4565 3550 0 0 B -SAND LINER 6601 7.03 11161 3506 0 0 Perforation depth: Measured depth: 4590 -4633; 4643 -7891; 8278 - 10504; 10506 -11127 True Vertical Depth: 3557 -3560; 3561 -3510; 3524 -3501; 3501 -3507 Tubing (size, grade, MD, and TVD) 4.5, L - 80, 4222 MD, 3467 TVD .. Packers & SSSV (type, MD, and TVD) PACKER - ZXP LINER TOP PKR @ 4200 MD and 3469 TVD S.`, t , t t 4 (•( NIPPLE - CAMCO DB NIPPLE @ 515 MD and 515 TVD 12. Stimulation or cement squeeze summary: Intervals treated (measured): SCANNED JUN 1 8 2013 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 984 348 434 770 188 Subsequent to operation 1007 341 455 907 196 14. Attachments 15. Well Class after work: Copies of Logs and Surveys run Exploratory r Development ro ` Service r Stratigraphic r 16. Well Status after work: Oil 17, . Gas r WDSPL r Daily Report of Well Operations X y GSTOR r WIND 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: N/A Contact Bob Christensen /Darrell Humphrey Email N1139(a)conocophillips.com Printed Name RO.ert D. Ch s.tensen Title NSK Production Engineering Specialist ' Signature / , '/ 41 ' Phone: 659 -7535 Date Z (c,/t VLP RE3 CAMS JUN 14 201 Form 10-404 Revised 12/2012 (p /144 13 ` ` V& Submit Original Only • 1J -159L1 • DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary 06/07/131RIH to 4553' CTMD, latch B lat Isolation sleeve. KUP • 1J -159L1 ConocoPhillips 6 *wig, Well Attributes Max Angle & MD TD Alaska Ii>C Welibore API /UWI Field Name Well Status Intl ( °) MD (ftKB) Act Btm (ftKB) 500292329760 WEST SAK PROD 92.41 7,600.66 11,187.0 Comment H2S (ppm) Date Annotation End Date KB (ft) Rig Release Date well ct„ r MULTIPLE LATERALS aJ lssu.5/torzol3 e.a7.te AM SSSV: NIPPLE 75 8/14/2012 Last WO: 1/23/2008 31.01 3/13/2006 ..athematic •Actual Annotation Depth (kKB) End Date Annotation Last Mod By End Date Last Tag Rev Reason. WELL REVIEW osborl 2/9/2011 Casing Strings String 0... Slring ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) String Wt... St ng ... IString Top Thrd h assn Descr t HANGER, 23 B-SAND LINER 4 1/2 3.958 4,560.2 11,161.1 3,506.3 12.60 L -80 BTC — — _ Liner Det _ _ Top Depth J — - — - — - (TVD) Top lne Nomi... Top (ftKB) (RK8) t°) Item Deseription Comment ID (in) 4,560.2 3,549.6 80.14 HANGER 1 BAKER MODEL B1 F'HOOK HANGER( Outside Casing 6.17') 3.688 4,577.0 3,556.0 86.83 HANGER 2 BAKER MODEL B1 F'HOOK HANGER( Outside Casing 6.17') 3.688 4,585.2 3,556.7 86.97 SWIVEL BAKER CASING SWIVEL 3.920 p 11,126.5 3,506.8 �5 90.57 Cross over 4 -1/2" IBT Box x 3-1/2" IBT Pin Crossover 2.992 CONDU P &SJOta_ . ...:: 3 -108 Shot NIPPLE, 515 -- Top (TVD) Btm (TVD) Dens Top (ftKB) Btm (ftKB) (ftKB) (ftKB) Zone Date (sh... Type Comment 4,590.0 4,633.0 3,557.1 3,560.0 WS B, 1J -159L1 3/3/2006 32.0 SLOTS SLOTTED LINER 0.125" x 2.5" x 32 HEAT TRACE• 3 spf @ 4 Circumferential adjacent 2 rows, 3" Centers staggered 18 deg., 3 8. non - slotted ends A 4,643.0 7,891.0 3,560.5 3,509.5 WS B, 1J -159L1 3/3/2006 32.0 SLOTS SURFACE,_ / 8,278.0 10,504.0 3,524.4 3,500.7 WS B, 1J -159L1 3/3/2006 32.0 SLOTS 31 2'364 10,506.0 11,127.0 3,500.7 3,506.8 WS B, 1J -159L1 3/3/2006 3, 32.0 SLOTS GAS End Date , 1J-1 an 3/12/2006 NOTE: MULTI LATERAL WELL: 1J -159 (A-SAND), 1J-159L1 (B- SAND), 1J-159L2 (D -SAND) LIFT, 2,509 22 12009 NOTE: VIEW SCHEMATIC w /Alaska Schematic9.OREV GAS ,0 4 4,094 NIPPLE, 4,137 4,148 LOCATOR, 4,194 SEALASSY, — - 4,195 1 _ I L2 LINER LEM M1 4,189.4,385 SLOTS, 4,590-4,633 11 LINER 1-19 LEM, 4,355-4,706 PRODUCTION, )I 27-5,575 SLOTS, 4,643-7,891 SLOTS, -- -- 8,278 - 10,504 SLOTS, Mandrel Details 10,506-11,127 _ Top Depth Top Port 5,,, (TVD) Intl OD Valve Latch Size TRO Run 8... Top (ftKB) (ftKB) ( °) Make Model (in) Sere Type Type (in) (psi) Ron Date Com... 13 1 2,589.4 2,407.1 25.48 CAMCO KBG -2 -1R 1 GAS LIFT GLV BK -5 0.156 1,530.0 2/19/2008 LINER, 2 4,093.6 3,432.7 68.81 CAMCO KBG -2 -1R 1 GAS LIFT OV BK -5 0.250 0.0 2/192008 4,560 - 11,161 ]g TD (1J- 15 11, ,187 ~^ ~~ ~Y r,+, . ~ ~~ 4 ~ ~ '~~ ~' ~ ~. ~ ~ i f A ~ y `. F, l ~. ~~ MICROFILMED 6/30/2010 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE C:\temp\Temporary Internet Files\OLK9\Microfilm_Marker.doc -- ~-~ ~ STATE OF ALASKA `'"' ` ~' ALASKA OIL AND GAS CONSERVATION COMMI $ION REPORT OF SUNDRY WELL OPE~B~~as Cans. Co~nf~nissian nrhnr~aE 1. operations Performed: Abandon ^ Repair Well ^ Plug Perforations ^ Stimulate ^ Other /^ Set L1-LEM Alter Casing ^ Pull Tubing ^ , Pertorate New Pool • ^ ~ Isolation Sleeve .Waiver ^ Time Extension ^ (e-saris) Change Apprpved Program ^ Operat. Shutdown^ Pertorate ,, ^ Re-enterSuspended Well ^ 2. Operator Name:. 4. Well Class Before-Work: 5. Permit to Drill Number. COnocoPhllhps Alaska, InC. Development ' I^ Exploratory ^ _ 206-006 3. Address:. Stratigraphic . ^ Service ^ 6. API Number. P. O. Box 100360, Anchorage, Alaska 99510 50-029-23297-60 7. KB Elevation (ft): 9, Well Name and Number. RKB 109' 1J-159L1 ~ 8. Property Designation: 10. Field/Pool(s): ADL 25661'& 25662 ~ Kuparuk River Field /West Sak Oil Pool 11. Present Well Condition Summary: Total Depth measured 11187 ~ feet true vertical 3506'., feet Plugs (measured) 4588' Effective Depth measured 11159' feet - Junk (measured) true vertical, 3506' feet Casing Length Size MD TVD Burst Collapse Structural CONDUCTOR 108' 20" 108' 108' SURFACE 2365' 10-3/4" 2365' 2207 PRODUCTION 5575' 7-5/8" 5575' 3695' WINDOW 1' 7" 4247 3482' WINDOW 0' 7" 4565' 3551' B-sand slotted Liner 6583' 4-1/2" 11160' P ' ' ' ' 350t~;.,~~~~ A~G ~ ~ ~~~$ . ' '~~ erforation depth: Measured depth: 4590 -4633; 4643 -789 -11127 1' 8278 -10504; 10506 true vertical depth: 3553'-3557 ; 3558'-351 1'; 3524'-3500'; 3500'-3507• Tubing (size, grade, and measured depth) 4-1 /2" , , 4386.36.' MD. " Packers &SSSV (type & measured depth) Packer = LEM Liner Top Packer PKR = 4355'. w .i.- ~~~ ~~ ~~~~~~`~ ~~~ SSSV=NIP SSSVr515' 12. Stimulation orcement squeeze summary: (u ," ~ ~~~~ ~ ~ vy4 ,~~ Intervals treated (measured)- N~q ~ ` Treatment descriptions including volumes used and final pressu re: 1~~ ~-Ca'C~~C`~~l'.iT'`~- `~'3 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casin .Pressure Tubin PressUte- Prior to welt operation 804 261 474 948 220 Subsequent to operation -'- 861 239 ' 14. Attachments " 15: V1(ell Class after work... Copies of Logs and Surveys run _ Exploratory ^ Development •~ Service ^ .Daily Report of Well Operations _X 16. Well Status after work: ' Oil^~ Gas^ - WAG^ GINJ^ WINJ ^ WDSPL^ 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: N/A contact Bob Christensen /Bob Buchholz Printed Name o D. istense Title Production Engineering Technician ~ ~ _ Signature Phone: 265-6471 ~ Date / tl ~ ~~~, BUG ~ ~ 1008 - Form 10-404 Revised 04/2006 ~; t `, ,..~ ~ ~ ~ /'-"~ i„„ Submit Original-Only ~dp' • • 1J-159L1 DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary 5/24/2008 MADE 3 PASSES ACROSS B SAND LEM WITH 2.2 OD JSN TO CLEAN AREA OF ISO SLEEVE.. USED 2.88" OD SIDI HIPP TRIPPER TO SET ISO SLEEVEACROSS B SAND • STATE OF ALASKA ~~ RECEiV~D ~ MAR 1 0 2008 ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATION~ ~~ Gas Cons. Comrr~sipn 1. Operations Performed: Abandon ^ Repair Well ~ Plug Pertorations ~ Stimulate ^ Other Alter Casing ^ Puli Tubing ^~ Pertorate New Pool ~ Waiver ^ Time Extension ^ Change Approved Program ^ Operat. Shutdown^ Perforate ~ Re-enter Suspended Well ^ 2. Operator Name: 4. Well Class Before Work: 5. Permit to Drill Number: COnOCOPhillips Alaska, InC. Development ^~ Exploratory ^ ~ 206-006 / 3. Address: stratigraphic ^ Service ^ 6. API Number: P. O. Box 100360, Anchora e, Alaska 99510 ~~ 50-029-2329~-60 7. KB Elevation (ft): 9. Well Name and Number: RKB 28' `~ 1J-159L1 - 8. Praperty Designation: 10. Field/Pool(s): . ~ ADL 25661 8~ 25662 " / ~ Kuparuk River Field / West Sak Oil Pool 11. Present Well Condition Summary: Total Depth measured 1118T ~ feet true vertical 3506'~ feet Plugs (measured) Effective Depth measured 11159' feet Junk (measured) true vertical 3506' feet Casing Length Size MD TVD Burst Collapse Structural CONDUCTOR 80' 20" 108' 108' SURFACE 2337' 10-3/4" 2365' 2207' PRODUCTION 5547' 7-5/8" 5575' 3696' LINER 6601' 4.5" 11161' 3506' PerForation depth: Measured depth: 4590'-4633', 4643'-7891' , 8278'-10504', 10506'-11127' true vertical depth: 3553'-3557', 3558'-3511' , 3524'-3500', 3500'-3507' v~ :.~Wb+e'1~~~s~iar` ~ti~~,'r . '3~ ti.~!.~~ Tubing (size, grade, and measured depth) 4-1/2" , L-80, 4795' MD. Packers & SSSV (type & measured depth) Liner top pkr @ a355' Camco'DB' nipple @ 519 72. Stimulation or cement squeeze summary: Intervals treated (measured) not applicable Treatment descriptions inctuding volumes used and frnal pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casin Pressure Tubin Pressure Prior to well operation 413 1561 55 -- 194 5ubsequent to operation 1722 1121 1906 - 230 14. Attachments 15. Well Class after work: Copies of Logs and Surveys run _ Exploratory ^ Development 0 Service ^ Daily Report of Well Operations _X 16. Well Status after work: Oil^~ Gas^ WAG~ GINJ^ WINJ ^ WDSPL^ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: none Contact Brett Packer Printed Name Brett Packe~;-~ ~ Title Wells Group Engineer 3~a /~ ~ ~\ Signature ~ Phone: 265-6845 Date ~ , Pre a h ron Alls Drake 263-4612 Form 10-404 Revised 04/2006 ~~~~~ ~ ~ ~~~ ~~ ~ ~ 3~~~8 ~ `~(a~ Submit Original Only ~ • ' KRU 1 J-159L1 ~~r~~~~a~~i~~~p~ ~t~~~ca~ ~~~. • ~ Cc~r~ocr~Ph~l~ips Time Log Summary 'I Wellv7ew Web Reportheq . . . :~ .. ~ _ ._ . a~~ ... . .,, . ,~ ~ ., . .:,,,. .~?~ .y °_ ~., z ;~.~,. ~ , .~."'~,..,. ,. ' , z~. x~ :-.~ ' ..~,>z~, _,~,. ~~.~ . .:-.._ : 'e. Well Name: 1J-159 Job Type: RECOMPLETION ~. . ,, ~. ~ . ~~ z. ~ , ~ .. ,,.. ~ , ~ , ~ ~.a~..e.~ .~ .~... E ~ ,,,z..,:: ~~, - ~c.a -w i •: a .,§g~ ,~~. 1`~~, (~ ,~-x 'f3. ,:__ , ..,,... ,.,.,.:.~ _,._ w-.. . _ .. . . ,_ . , ,: 01/18/2008 00:00 01:00 1.00 MIRU MOVE RURD P PJSM, R/D prep for rig move. 01:00 03:00 2.00 MIRU MOVE RURD P Move off well # 1J-152. Move over 1J-159. spot & level, berm up. Accepted rig @ 0300 hrs today, 1 /18/2007. 03:00 07:00 4.00 MIRU MOVE RURD P Roll down tarps, spot tanks, & e ui ment. 07:00 09:00 2.00 MIRU MOVE RURD P RU hardline to kill tank. Heat up Seawater w/hot oiL 09:00 10:30 1.50 PROD1 RPCOti RURD P PJSM, Pull BPV w/Lubricator. Some trouble linin u tools. 10:30 12:00 1.50 PROD1 RPCOh RURD P RU line in cellar, P!T w/air. P/T w/fluid to 2500 si. 12:00 15:00 3.00 PROD1 WELCT KLWL P Blow down hardline, start pumping well kill. IA pressure 480 psi and Tubing press 240 psi. Pumped @ 2 BPM 200 bbls hot seawater down annulus increasing rate to 4 BPM. Switched over and pumped 60 bbls hot seawater down tubing @ same rate. Shut down, check press. Small amount +/- 5 psi. Pumped another 50 bbls down tubing at same rate. Shut in monitor. 15:00 17:00 2.00 PROD1 WELCT KLWL P While monitoring well, changed out ESP spools. Check well for pressure 0 IA/ 0 tubing. RD Circ lines and Blow down lines to kill tank. 17:00 18:30 1.50 PROD1 WELCT BOPE P Install 4" H-BPV. ND and inspect tree. 18:30 23:30 5.00 PROD1 WELC BOPE P NU BOPE 23:30 00:00 0.50 PROD1 WELCT BOPE P Function Test and fill stack 01/19/2008 00:00 08:00 8.00 PROD1 WELC BOPE P Continue to BOPE 250/2500 psi 08:00 15:30 7.50 PROD1 WELCT BOPE T Change out choke valve #2 and retest 250/2500 si. 15:30 16:30 1.00 PROD1 RPCOti OTHR P Pull BPV. Bent T-bar made difficult to line u . 16:30 20:00 3.50 PROD1 RPCOti PULD T Attempt to screw in landing jt in hanger, bad thread. Ordered out another landin 't and s ear. 20:00 21:00 1.00 PROD1 FISH PULL T Engage hanger and pull to surface 90k u wf. Break out and la down frsh. 21:00 21:30 0.50 PROD1 RPCOh PULD P Pull and lay down pup jts and e line over sheeve and tie into s ooL ~ ~: ~~ ~ ~ _ ~,~~~~ \~~ . , , ~~ v ~ ~ :' ~ ~_ ~~.. ~~~ ~ ~ u ~..~ y : ~.yA,~ ~~.~ c~~; ~- - ~ ~ . „ . ~ a , ~U ; .Su~i. ; ~ ,~; __. _, ~ ~ ~ r~~~ ~ __ ~ 01/19/2008 21:30 22:30 1.00 PROD1 RPCOh CIRC P Attempt to fill hole w! 300 bbls 8.8 ppg 6% KCL never was able to circulate. 22:30 00:00 1.50 3,618 1,935 PROD1 RPCOh RCST P pooh f/ 3618' to 1935' w/ esp completion on 4 1/2 12.6# L-80 IBTM, standing back tubing and spooling up ESP cabie. 01/20/2008 00:00 05:00 5.00 1,935 73 PROD1 RPCOh RCST P Continue to Pooh w/ 4 1/2 Completion string. Found hole in tubing 1' down from tooi jt on 1 st jt above ESP @ 3590.0 +/- 05:00 07:00 2.00 73 0 PROD1 RPCOI~ PULD P Laid down ESP equipment. Recovered all bands and clamps except 6 stainless steel bands. 07:00 10:00 3.00 PROD1 RPCOh WOEQ T Waiting on slickline for fishing out 6 lost bands. Ciean rig floor, strap all e ui ment, or anize i e shed. 10:00 12:00 2.00 PROD1 FISH SLKL T Load new toois (scraper etc) in pipe shed. Rl1 drili pipe equipment, spinners elevators etc while waiting on slickline. 12:00 15:00 3.00 PROD1 FISH SLKL T PJSM. RU slickline. 15:00 20:00 5.00 PROD1 FISH SLKL T RIH with junk basket on slickline fishing for bands. First run retrieved 3 bands, second run retrieved 1 single band, third run 0 bands, 4th run 8-pcs. of inetal, 5th run filled junk bskt w/ 1.5' of scale, 6th run filled junk bskt w/ 2.0' of scale to depth of 4248' slm. RD slick line unit. 20:00 21:30 1.50 0 306 PROD1 RPCOh PULD T PJSM, PU and Rih w/ CSG Scraper Ass . 21:30 00:00 2.50 306 4,052 PROD1 RPCOh PULD T Rih PU Drill from pipe shed to 4052'. u wt 97k dn wt 75k 01/21/2008 00:00 01:00 1.00 4,052 4,240 PROD1 RPCOh PULD T Continue to Rih PU DP f/ 4052' U 4240' 27.0' in on 't # 122 01:00 01:30 0.50 PROD1 RIGMN SVRG P Service rig 01:30 03:00 1.50 4,240 306 PROD1 RPCOh TRIP T Pooh f/ 4240' to 306'. 03:00 04:00 1.00 306 0 PROD1 RPCOh PULD T Continue to Pooh w! BHA# 1 and breakdown & La down scra er ass . 04:00 08:00 4.00 0 292 PROD1 RPCOh PULD T PJSM, PU BHA #2, 7.625 Baker retrievamatic packer and Rih same to 3580 ft. 08:00 12:00 4.00 292 4,231 PROD1 RPCOti DHEQ T PJSM, set pkr at 3580 ft, fill hole. Test to 2500 psi. Release and re-set at 3850 ft. Test to 2500 psi. Release and re-set at 4231 ft. Test 2500 psi / 30 min. All tests successful. No re-tests. 12:00 15:00 3.00 4,231 0 PROD1 RPCOh TRIP T PJSM, release pkr, POH for clean out ass . 15:00 16:00 1.00 PROD1 RPCOh OTHR P Clean and clear rig floor. Remove tools from 16:00 16:30 0.50 PROD1 RPCOti OTHR P RD Spinners and RU Eckles ~ • • ~ ~ ~ r ~ ~ '~7'r"" DATA SUBMITTAL COMPLIANCE REPORT 5/20/2008 Permit to Drill 2060060 Well Name/No. KUPARUK RIV U WSAK 1J-159L1 Operator CONOCOPHILLIPS ALASKA INC API No. 50-029-23297-60-00 MD 11187 ND 3506 Completion Date 3/13/2006 Completion Status 1-OIL Current Status 1-OIL UIC N REQUIRED INFORMATION Mud Log No Samples No Directional Surve Yes DATA INFORMATI ON Types Electric or Other Logs Run: GR/Res, Dens/Neu (data taken from Logs Portion of Master Well Data Maint Well Log Information: Log/ Electr Data Digital Dataset Log Log Run Interval OH / Type Med/Frmt Number Name Scale Media No Start Stop CH Received Comments ~i FFpt 13935 LI S Verification 1,2 2325 11127 Open 6/8/2006 ! D Lis D 13935 'Induction/Resistivity 1,2 2325 11127 Open 6/8/2006 GR, EWR4, ABI, ROP, PWD, Geoplot 't.irpt 13934 LI S Verification 1,2 2325 4930 Open 6/8/2006 PB1 ~ i // '~CYD D Lis 139341"(nduction/Resistivity 1,2 2325 4930 Open 6!812006 PB 1 GR, EWR4, ABI, ROP, PWD, Geoplot ~ I i ftpt I 13933 LI S Verification 1,2 2325 6772 Open 6/8/2006 PB2 I D Lis /~ 13933/fnduction/Resistivity 1,2 2325 6772 Open 6/8/2006 PB 2 GR, EWR4, ABI, ', ROP, PWD, Geoplot ~ ED D Asc O Directional Survey 6292 11187 Open 6/27/2006 D Asc ! FD Directional Survey 4534 4987 Open 6/27/2006 PB 1 / (,END D Asc Directional Survey 4534 6832. Open 6/27/2006 PB 2 ~,16g Induction/Resistivity 25 Col 218 11187 Open 4/21/2008 MD ROP, DGR, EWR 1- Mar-2006 ~/~ ~~ I I~o9 Induction/Resistivity 25 Col 218 3505 Open 4/21/2008 ND DGR, EWR 1-Mar- 2006 '~(Jcbg Induction/Resistivity 25 Col 218 6$32 Open 4!21!2008 ND ROP, DGR, EWR 27- '; Feb-2008 ~.L~og Induction/Resistivity 25 Col 218 4987 Open 4/21/2008 MD ROP, DGR, EWR 27- ~ Feb-2008 ~ ~ (, C 16119 e Notes 0 0 Open 4/21/2008 MD and ND with P61 graphics w/ EMF, CGM and PDF Well Cores/Sampl es Information: Sample Interval Set Name Start Stop Sent Received Number Comments i DATA SUBMITTAL COMPLIANCE REPORT 5/20/2008 Permit to Drill 2060060 Well Name/No. KUPARUK RIV U WSAK 1J-159L1 Operator CONOCOPHILLIPS ALASKA INC MD 11187 TVD 3506 Completion Date 3/13!2006 Completion Status 1-OIL Current Status 1-OIL ADDITIONAL INFORMATION Well Cored? Y Chips Received? -~f-t-IV''- Analysis 'f-L~#~ Received? Comments: Daily History Received? ~ N Formation Tops ~J N Compliance Reviewed By: _ ___.__ Date: API No. 50-029-23297-60-00 UIC N i • • WELL LOG TRANSMITTAL To: State of Alaska April 10, 2008 Alaska Oil and Gas Conservation Comm. Attn.: Ceresa Tolley 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: MWD Formation Evaluation Logs 1 J-159+PB 1 +L 1 +L 1 PB l+L 1 PB2+L2 AK-MW-4150952 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-159+PB1+L1+L1PB1+L1PB2+L2 2" x 5" MD TC Logs: 1 Color Log 50-029-23297-00,60,61,70,71,72 2" x 5" TVD TC Logs: 1 Color Log 50-029-23297-00,60,61 Digital Log Images 1 CD Rom 5 0-029-23 2 97-00, 60, 61, 70, 71, 72 PB1, L1PB1 and L1PB2 have no TVD's. PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry Drilling Services Attn: Rob Kalish 6900 Arctic Blvd. Anchorage, Alaska 99518 Date: Signed:_ c~-6C~5 ~ i~~i ~ ao~ -ooh '~ l ~O c a6 ~y (i `~ ~ l~.V~`~- -__ ~G~G' V G® 1 2 2007 STATE OF ALASKA Alaska Oi4 & Gas Cons. CtN11mISStt~-ASKA OIL AND GAS CONSERVATION COMMISSION ~n~ti~.z~~ REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Abandon ^ Repair Well ^ Plug Perforations ^ Stimulate.. ^ Ofher ^/ ESP to GL i Alter Casing ^ Pull Tubing ^ Perforate New Pool ^ Waiver ^ Time Extension ^ Change Approved Program ^ Operat. Shutdown^ Perforate ^ Re-enter Suspended Well ^ 2. Operator Name: 4. Current Well Status: 5. Permit to Drill Number. ConocoPhillips Alaska, InC. Development 0 Exploratory ^ 206-006 / 3. Address: Stratigraphic ^ Service, ^ _ 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-029-23297-60 ' 7. KB Elevation (ft): 9. Well Name and Number: RKB 109' 1 J-159L1 ~ 8. Property Designation: 10. Field/Pool(s): ` ADL25661y&25662 Kuparuk River Field /West Sak Oil Pool ' 11. Present Well Condition Summary: Total Depth measured 11187 ~ feet true vertical 3506' ~' feet Plugs (measured) Effective Depth measured. 11159' feet Junk (measured) true vertical 3506' feet Casing Length Size MD TVD Burst Collapse Structural CONDUCTOR 108' 20" 108' 108' SURFACE 2256' 10-3/4" 2365' 2206' PRODUCTION 5466' 7-5/8" 5575' 3695' D-SAND WINDOI 1' 7" 4247 3481' B-SAND LINER 6601' 4-1/2" 11161' 3506' Perforation depth:. Measured depth: 4590-46334643-7891 8278-10504 10506-11127 WS B true vertical depth: 3553-3557 3558-3511 3524-3500 3500-3507 WS B Tubing (size, grade, and measured depth) 4-1/2" , L-8Q, 3633' MD : Packers &SSSV (type & measured depth) no packer no SSSV no SSSV 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 Casin Pressure Tubin Pressure Prior to well operation 710 ..~ 751 44 293 189 Subsequent to operation 737 - 1735 90 570 192 14. Attachments 15. Well Class after proposed work: Copies of Logs and Surveys run - Exploratory ^ Development ~ Service ^ Daily Report of Well Operations _X 16. Well Status after proposed work: Oi10 Gas ^ WAG ^ GINJ ^ WINJ ^ WDSPL ^ 17. !hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: contac~_ Bob Christensen rBob-Buchholz Printed Name Robert W Buchholz Title - Production Engineering Technician - Signature one 659-7535 Date / ~y~~~ S Qf~ SUN ~ 31007 /S~ G•~z .off ~,, ,j Form 10-404 Revised 04/2004 U K E ~ ~ ~ V ~ ~ ~ ~~ ~ Submit ink nl ~ ~ 1J-158L1 DESCRfPTION ®F W®RK C®MPLETED SUMMARY Date.. Event Summary 04/28/07 ESP Stopped producing. Diagnostics determine that there was aground downhole which will ~equire a rig workover to replace the rig deployed equipment. 05/07/07 Replaced sheared SOV with DV @ 2577" RKG. .05/11/07 Replaced. STA #2 with 5/16" orfice valve @ 3172' RKB. Replaced STA #1 DV with .188" °ORT,TRO=1375 @257T RKB.- 05/17/07 Well returned to service using gaslift. ~ %~ ~ py d r ~' } 4 u f fi,, ~ k F~ g r ~` ~ i~ ~ e ~ a P a I ~ + ~ ~ ~ a ~ "~ { t ~ ` ~ ~ ~ ." a.. ..a ~ w. ~:, u,~. . w.,.. uw.s :~ ;.. G._.,. .... e i... .i ,~.J a.. .. .~ ,_ s .. ALASIf1~ OII, g1~TD GAS COI~TSER~A~`I011T CO1~II~i15SIOlY Perry .Klein Problem Well Supervisor ConocoPhillips Alaska P.O. Box 100360 Anchorage, AK 99510-0360 Re: Kuparuk River Field, West Sak Oil Pool, 1J-159L1 Sundry Number: 307-160 Dear Mr. Klein: SARAH PALIN, GOVERNOR 333 W. 7th AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Enclosed is the unapproved Application for Sundry Approval relating to the above referenced well. We are returning your application for Sundry Approval unapproved. Since operating the well is equipped with gas lift if the ESP failed was described in the Application for Permit to Drill this sundry is not needed. DATED this .,~ aay of May, 2007 Encl. ~ p ~ ~vlo • ConocoPhillips ~~ P.O. BOX 100360 ANCHORAGE, AIASKA 99510-0360 May 7, 2007 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7~' Avenue, Suite 100 Anchorage, AK 99501 Dear Mr. Maunder: R~CE~VEp SAY 1 ~ 2007 Alaska Oil & has Cons. Co~nission Anchorage Enclosed please find 10-403 applications for Sundry Approval for ConocoPhillips Alaska, Inc. well 1J-159 PTD 206-005, 1J-159L1 PTD 206-006, and 1J-159L2 PTD 206007 to produce via gas lift until the failed ESP is replaced. Please call Marie McConnell or myself if you have any questions. Sincerely, Pe ein Problem Well Supervisor L_J Attachments '~' RECEIWED STATE OF ALASKA MAY 1 0 2007 ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVAbiaska oil & Gas Cons. Commission 20 AAC 25.280 Anchorage 1. Type Of Request: Abandon ^ Suspend ^ Operational Shutdown ^ Pertorate ^ Waiver Q ~ Other Alter casing ^ Repair well ^ Plug Perforations ^ Stimulate ^ Time Extension ^ Change approved program ^ Pull Tubing ^ Pertorate New Pool ^ Re-enter Suspended Well ^ 2. Operator Name: 4. Current Welt Class: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development Q Exploratory ^ .206-006 ` 3. Address: Stratigraphic ^ Service ^ 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-029-23297-60 e 7. If perforating, closest approach in pool(s) opened by this operation to nearest property line 8. Well Name and Number: where ownership or landownership changes: ~ o,~ Spacing Exception Required? YeS ^ / NO [~ ''Z~ 1J-159L1 ~ 9. Property Designation: fiD ~- ~fG4 / c~ ~(~42 7 ~ ~ 10. KB Elevation (ft): 41. Field/Pool(s): ` Kuparuk River Unit /' ~'~ RKB 109' Kuparuk River Field /West Sak Oil Pool 12. PRESENT WELL CONDITION SUMM Total depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs easured): Junk (measured): 11187 l 3506' r Casing Length Size MD TVD Burst Collapse .CONDUCTOR 108' 20" 108' 108 SURFACE 2256' 10-3/4" 2365' 2207 PRODUCTION 5466' 7-5/8" 3549 D-SAND WINDOW 1' 7" 4 4 3481 B-SAND WINDOW 1' 7" 4 6 ' 3550 Perforation Depth MD (ft): Perforation Dept D (ft): Tubing Size: Tubing Grade: Tubing MD (ft): Liner slots 4590-7891 & 8278-11127 B sands Liners is 355 3524 - 4-~ IZ" L-80 3633' Packers and SSSV Type: ers and SS V MD (ft) no packer no SSSV no SSSV 13. Attachments: Description Summary of I 14. Wey ass after pro osed work: Detailed Operations Program ^ O Sketch x Development ^~ Service ^ 15. Estimated Date for el at er proposed work: ~ Commencing Operations:. / / Dil Gas ^ Plugged ^ Abandoned ^ 17. Verbal Approval: ate: WA GINJ ^ WINJ ^ WDSPL ^ Commission Representative: 18. I here the foregoing i e an correct to the best of my knowledge. Contact: Perry klein /Marie McConnell Printed Name Per Klei Title: Problem Wells supervisor Signature Phone: 659-7224 Date: 05/07/07 Commission Use Onl Sundry Number: Conditions of approval: Notify Commission so that a representative may witness 3 ~ " Plug Integrity ^ BOP Test ^ Mechanical Integrity Test ^ Location Clearance ^ Other: ~~~ ~'~ MAY ~ ~ 200? Subsequent Form Required: APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: Form 10-403 Revised 06/2006 ~ Submi r. ~o .0.7 ~Oj r: ConocoPhillips Alaska, Inc. West Sak Injection Well 1J-159 (PTD 206005), 1J 159L1 (PTD 206006) & 1J-159L2 (PTD 20600?) SUNDRY NOTICE 10-403 VARIANCE REQUEST 05/07/2007 The purpose of this Sundry Notice is for approval to produce tri-lateral West Sak producer 1J- 159via gas lift until the failed ESP is replaced. The well is completed as an ESP (electric submersible pump) producer and does not have a packer. 1J-159 was completed in May, 2006 and produced via ESP until 04/28/07, at which time it was shut-in due to a downhole motor electrical failure. Prior to failure, the ESP had drawn the bottom hole pressure down to 780 psi. A RWO is planned to replace the failed ESP within the next 2 years. The tubing is configured with two gas lift mandrels at 2577' RKB (2396' TVD) and 3172' RKB (2905' TVD). An attempt to place this well on gaslift is desired until the well is worked over and the ESP completion replaced. Due to the deviation coiled tubing will be used to pull the ESP to give the produced fluids a path through the intake ports in the tubing. If the pump can not be pulled then the tubing will be perforated above the ESP. An unloading valve will be installed in the upper gas lift mandrel. The lower gas lift mandrel will not be accessible by slickline and an attempt to pull the dummy valve and replace it with an orifice valve will be made using an electric line tractor tool. Gas lift will be applied in the "standard" configuration; i.e., gas will be injected down the annulus and enter the tubing through the orifice valve or tubing holes. The last production test on 04/26/07 recorded 710 BOPD, 41 BWPD (S%WC), and 751 MSCF of gas. Attached is a wellbore diagram of the well. The following is a summary of the proposed plan: 1. The AOGCC approve this request for a time period not to exceed 24 months from the approval date; 2. Should a workover not be completed within the approved time period the AOGCC will be contacted for a review and discussion of the plan forward. ft_ J Subject:'Re:FW:1J-159 PTD # 206-005 ESP failure Fro~in; Thomas Maunder <tom_maunder a),adn~~in.state.ak.us> Date: Tue, 15 May 2007 15:52;17 -0800 To: NSK Problem We11Supv ~n161'7 c~coi~ocophillips.con2=~~ • ~V ~' ~~® Marie, I discussed this with Commissioner Foerster, your interpretation is correct. The well may be produced on gas lift. Call or message with any questions. Tom Maunder, PE AOGCC NSK Problem Well Supv wrote, On 5/15/2007 11:12 AM: Tom, The west sak engineers noted that gas lift backup was included in the PTD for these wells and were wandering if that would cover approval to gas lift the failed ESP. An excerpt of the PTD program for reference: 39. RU and run a 4 1/2" ESP completion with backup gaslift. 40. Space out tubing and land tubing in tubinghead. 41. Nipple down BOPE, nipple up tree and test, change over the hole to diesel. 42. Set BPV and RDMO Doyon 141. 43. Rig up wire line unit. Pull BPV. 44. Circulate out well with diesel through the ESP. 45. Set gas lift valves in mandrels. Operate well on gas lift until ESP facilities are ready. 46. Replace gas lift valves with blank dummy valves. 47. Place well on production with ESP. Marie From: Thomas Maunder [mailto:tom maunder@admin.state.ak,us] Sent: Monday, May 14, 2007 2:20 PM To: NSK Problem Well Supv Subject: Re: F111J: 1J-159 PTD # 206-005 ESP failure Marie, I have not seen the sundries yet. I will check to see if they are in-house. Tom ', NSK Problem Well Supv wrote, On 5/14/2007 2:14 PM: Tam, Last Monday, Perry Klein, submitted 10-403s to gas lift well 1 J-159 (wellbores 1 J-159, 1 J-159L1, & 1J-159L2} failed ESP while waiting on a RWU. Has AOGCC received the sundry applications? 1 of 2 5/22/2007 8:49 AM They may still be in the mail. I understand your work load, especially with the vacancies, so not intending to add any undue rush for approval. We'd just like to know as soon as practical once approval is granted for rate ',' optimization. Currently, the well is SI waiting on approval to gas lift. Operations is ready to start gas lifting as soon as commission approval is obtained, and they were wondering about timing. I'll let them know it will be a few weeks at least for paperwork processing. Thanks, Marie McConnell Problem Well Supervisor (907) 659-7224 n1617(a~conocophillips.com From: NSK Problem Well Supv Sent: Friday, May 04, 2007 9:57 AM To: 'Thomas Maunder' Cc: NSK West Sak Prod Engr Subject: 1J-159 PTD # 206-005 ESP failure Tom, 1 J-159 PTD # 206-005 ESP producers ESP failed 4/28. Centrilift has confirmed that the pump is grounded down hole and will require a RWO to repair /replace. Plan forward is to attempt to pull the pump with a coiled tubing unit in preparation to lift via the pump intake manifold. CPAI would like permission to temporarily produce the well on gas lift, not to exceed 30 days. ', If permission is granted and the test proves the well is economically viable a 10-403 will be submitted requesting permission to produce the well via gas lift until a rig work over is possible. Thanks in advance. Perry Klein Problem Well Supervisor office (907) 659-7224 Cell (907) 943-1244 Pager (907) 659-7000 x909 n1617(a~conocophillips.com 2 of 2 5/22/2007 8:49 AM L~ • 12-May-06 AOGCC Ceresa Tolley 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 DEFINITIVE Re: Distribution of Survey Data for Well 1 J-159 L1 Dear Dear Sir/Madam: Enclosed is one disk with the *.PTT and *.PDF files. Tie-on Survey: 6,292.98' MD Window /Kickoff Survey: 11,145.94' MD (if applicable) Projected Survey: 11,187.00' MD PLEASE ACKNOWLEDGE RECEIPT BY SENDING AN EMAIL TO CARL.ULRICH@HALLIBURTON.COM OR SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Carl Ulrich 6900 Arctic Blvd. Anchorage, AK 99518 Date uµ-~-~G Signed Please call me at 273-3545 if you have any questions or concerns. Regards, Carl Ulrich Survey Manager Attachment(s) • • 12-May-06 AOGCC Ceresa Tolley 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 DEFINITIVE Re: Distribution of Survey Data for Well 1J-159 L1 PB1 Dear Dear Sir/Madam: Enclosed is one disk with the *.PTT and *.PDF files. Tie-on Survey: 4,534.51 ' MD Window /Kickoff Survey: 4,901.50' MD (if applicable) Projected Survey: 4,987.00' MD PLEASE ACKNOWLEDGE RECEIPT BY SENDING AN EMAIL TO CARL.ULRICH@HALLIBURTON.COM OR SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Carl Ulrich 6900 Arctic Blvd. Anchorage, AK 99518 _„ ~ _ ~ , Date o2.7 ~v-r~.~A`l~i Signed ~~ Please call me at 273-3545 if you have any questions or concerns. Regards, Carl Ulrich Survey Manager Attachment(s) • 12-May-06 AOGCC Ceresa Tolley 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 DEFINITIVE Re: Distribution of Survey Data for Well 1J-159 L1 PB2 Dear Dear Sir/Madam: Enclosed is one disk with the *.PTT and *.PDF files. Tie-on Survey: 4,534.51 ' MD Window /Kickoff Survey: 6,758.99' MD (if applicable) Projected Survey: 6,832.00' MD PLEASE ACKNOWLEDGE RECEIPT BY SENDING AN EMAIL TO CARL.ULRICH@HALLIBURTON.COM OR SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Carl Ulrich 6900 Arctic Blvd. Anchorage, AK 99518 Date ~. 7 ~G Si ned A~ g Please call me at 273-3545 if you have any questions or concerns. Regards, Carl Ulrich Survey Manager Attachment(s) ~~ ro -c~~~ • • WELL LOG TRANSMITTAL To: State. of Alaska May 31, 2006 Alaska Oil and Gas Conservation Co. Attn.: Librarian 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: MWD Formation Evaluation Logs 1J-159 L1 PB2, AK-MW-4212091 1 LDWG formatted Disc with verification listing. A PI# : 50-029-23297-72 YLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry Drilling Services Attn: Rob Kalish 6900 Arctic Blvd. Anchorage, Alaska 99518 '~~ Date~~~l n~~ q~k~0il ~ Gas Cuns.l;ommisslon Ai~rhotage Signed: ____~__ 13933 • • WELL LOG TRANSMITTAL To: State of Alaska May 31, 2006 Alaska Oil and Gas Conservation Co. Attn.: Librarian 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: MWD Formation Evaluation Logs 1J-159 L1 PB1, AK-MW-4212091 1 LDWG formatted Disc with verification listing. API#: 50-029-23297-71 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTL+'NTTON OF: Sperry Drilling Services Attn: Rob Kalish 6900 Arctic Blvd. Anch~~owwrage, `Alaska 99518 t..r~ V JUN 0 8 2006 --- Date: Signed: ....°-W..°°"..~---__._~ 0~ & Gas Cons. Cantnlsslbn ~Inrh~ (:~%~ ~cc~ " ~ I3~3~~ ~~-~r5" • WELL LOG TRANSMITTAL • To: State of Alaska May 31, 2006 Alaska Oil and Gas Conservation Co. Attn.: Librarian 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: MWD Formation Evaluation Logs 1J-159 L1, AK-MW-4212091 1 LDWG formatted Disc with verification listing. API#: 50-029-23297-60 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry Drilling Services Attn: Rob Kalish 6900 Arctic Blvd. Anchorage, Alaska 99518 ~~ef-sr ~nnr. A135ka ON ~ Gas Cons• ~ At~~~ ~Gto -C ~b Signed: ~ !3935 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT r -~ AND LOG 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 Q Exploratory ^ Service ^ Stratigraphic Test^ 2. Operator Name: ConocoPhillips Alaska, Inc. 5. Date Comp., Susp., or Aband.: March 13, 2006 12. Permit to Drill Number: ?,1106-99t3'/ ~ 06 - aoC ,c• tG' 3. Address: P. O. Box 100360, Anchorage, AK 99510-0360 6. Date Spudded: ~ ~ (~.6 February , 2006 5• 13. API Number: 50-029-23297-60 4a. Location of Well (Governmental Section): Surface: 2035' FSL, 2545' FEL, Sec. 35, T11N, R10E, UM' 7. Date TD Reached: March 1, 2006 14. Well Name and Number: 1J-159L1 • At Top Productive Horizon: 1065' FSL, 1641' FEL, Sec. 35, T11 N, R10E UM 8. KB Elevation (ft): 28' RKg ~ 15. Field/Pool(s): Kuparuk River Field Total Depth: 262' FNL, 1856' FEL, Sec. 11, T10N, R10E, UM 9. Plug Back Depth (MD + TVD): 11159' MD / 3506' TVD West Sak Oil Pool 4b. Location of Well (State Base Plane Coordinates): Surface: x- 558664 y- 5945847 - Zone- 4 10. Total Depth (MD + TVD): - 11187' MD ! 3506' TVD 16. Property Designation: ADL 25661 & 25662 TPI: x- 559577 y- 5944884 Zone- 4 Total Depth: x- 559420 - 5938276 , Zone- 4 11. Depth where SSSV set: none 17. Land Use Permit: ALK 471 & 2177 18. Directional Survey: Yes ^/ No ^ 19. Water Depth, if Offshore: N/A feet MSL 20. Thickness of Permafrost: 2365' MD 21. Logs Run: •~' ~ OLtI S•GJ~ /~!a ~ 3~b ~ ~D GR/Res, Dens/Neu ,~j> S•%('•~(> 22. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTH TVD HOLE AMOUNT CASING SIZE WT. PER FT. GRADE TOP BOTTOM TOP BOTTOM SIZE CEMENTING RECORD PULLED 20" 62.58# H-40 28' 108' 28' 108' 42" 233 sx AS 1 10.75" 45.5# L-80 28' 2364' 28' 2207' 13.5" 469 sx Class G, 175 sx Class G 7-5/8" 29.7# L-80 28' 5575' 28' 3696' 9-7/8" 351 sx LiteCRETE 4.5" 12.6#/11.6# L-80 4560' 11161' 3549' 3506' 6.75" slotted liner 23. Pertorations open to Production (MD + TVD of Top and Bottom 24. TUBING RECORD Interval, Size and Number; if none, state "none"): SIZE DEPTH SET (MD) PACKER SET tubing in main wellbore 3633' 4666' slotted liner from 4590'-7891', 8278'-11126' MD 25. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED n/a 26. PRODUCTION TEST Date First Production May 5, 2006 Method of Operation (Flowing, gas lift, etc.) ESP oil producer -shares production with 1J-159 and 1J-159L2 Date of Test 5/10/2006 Hours Tested 14.5 hours Production for Test Period --> OIL-BBL 2316 GAS-MCF 1072 WATER-BBL 0 CHOKE SIZE 20% GAS-oll RATIO 506 Flow Tubing press. 32o psi Casing Pressure not available Calculated 2a-Hour Rate -> OIL-BBL 3659 GAS-MCF 1850 WATER-BBL 1 OIL GRAVITY -API (corr) 19° 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". ~~5 ~F~. ~~~ ~ ~ coos = .~ .~3 NONE ~~._ '~~ Form 10-407 Revised 12/2003 ORIGINAL CONTINUED ON REVERSE ~j ,,~~/G • ob G a za. zs. GEOLOGIC MARKERS FORMATION TESTS NAME MD TVD Include and briefly summarize test results. List intervals tested, and attach detailed supporting data as necessary. If no tests were conducted, state "None". 1J-159L1 West Sak B Sand 4566' 3551' Base West Sak B sand 11187' 3506' N/A 1 J-159L1 PB1 TD 4987' 3550' U- ~s`~~. eta-- ~~3~ 3 Sa~~ ~~ ~~~-o~ 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: Pat Reilly @ 265-6048 Printed Ran a Title: Greater Kuoaruk Area Drillino Team Leader Signature ~ S G ~ ,~ ~ Date Slf ~ ~6`6 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 • • ConocoPhillips Alaska Operations Summary Report Page 1 of 19 Legal-Well Name: 1J-.159 Common Well Name: 1J-159 Spud Date: 2/12/2006 Event Name: R07 -DRILLING Start: 2/11/2006 End: 3/13/2006 Contractor Name: n1334@ppco.com Rig Release: 3/13/2006 Group: Rig Name: Doyon 141 Rig Number. Date From - To Hours Code Code Phase Description of Operations 2/11/2006 12:00 - 14:00 ~ 2.00 I MOVE MOB MOVE 1 Disconnect all Electrical lines. Pull Swing arm over, and pin same in 14:00 - 18:00 I 4.001 MOVE 18:00 - 20:30 2.50 MOVE 20:30 - 22:00 1.50 MOVE 22:00 - 00:00 2.00 DRILL 2/12/2006 00:00 - 01:30 1.50 WELC' 01:30 - 03:00 1.50 RIGMt• 03:00 - 05:15 2.25 DRILL 05:15 - 06:30 06:30 - 07:00 07:00 - 08:00 08:00 - 09:15 09:15 - 09:45 09:45 - 10:30 10:30 - 11:15 0.75 DRILL 11:15 - 12:00 0.75 DRILL 12:00 - 13:30 I 1.501 DRILL 13:30 - 15:00 I 1.501 DRILL 15:00 - 16:30 I 1.501 DRILL 16:30 - 00:00 i 7.501 DRILL 12/13/2006 100:00 - 12:00 I 12.001 DRILL place. Continue prep for move. MOVE MOVE PJSM with crew & Peak Truck drivers. Discuss Safety issues and procedure for rig move. Lay matting boards down pulling sub base. Move Pipeshed modules, Rockwasher, Boilers, Motors and Pit Modules from 1J-166. Move Sub base & spot rig on well 1J-159. POSN MOVE Clean up 1 J-166 Well area, spot matting boards for complexes. Move & Spot Boilers, Motors and Pit Modules to rig. POSN MOVE Spot matting boards for for complexes. Move ~ Spot Pipeshed modules & Rockwasher to rig. Release Peak @ 2200 HRS. RIRD RIGUP Connect all Steam, Hydraulic, Air, 8 water lines. Connect electrical lines. Work on Rig acceptance checklist. Rig accepted @ 00:01 HRS 2/12/06. NUND RIGUP Install Riser Bell Nipple on Diveter System, and install 4" Valves on conductor. RGRP RIGUP Change out Saver Sub on Top Drive to 4 1/2" IF threads. PULD RIGUP Strap & Pick up 45 joints of 5" DP from pipe shed. Racking back in Derrick. 15 stands. of test waived by AOGCC Jeff Jones. Test witnessed by Co. Rep. Simops: Pull BHA equipment to rig floor. PULD RIGUP Pick up 5" HWDP, Drilling jars, and 3 NonMag Flex Drill Collars. Rack in Derrick. SFTY RIGUP Held PJSM with crew & DD's. Discuss safety issues and procedures for picking up BHA, and Spud. RKB to casing Head = 22.55' PULD SURFAC Make up 13 1/2" HTC MXC1 bit with 3 x 20's, & 1 x 13 jets (1.00'). 8" Sperry Drill Lobe 4/5 - 5.3 stage (28.69'), 8" WB type Stabilizer (4.42'), 8" Non Mag Float Sub (2.15'}, Bottleneck Crossover (2.47'), and 1 stand 5" HWDP (90.83'). CIRC SURFAC Prime mud pumps, and flood conductor. Test surface lines to 3000 PSI. No Leaks. DRLG SURFAC Drill 13 1/2" Surface hole from. 90' -130'. Pumps at 450 GPM - 420 PSI. 60 RPM's. 3K torque. ADT = .62 HRS. DRLG SURFAC Continue Drill 13 1/2" Surface hole from 130' -218'. Pumps at 430 GPM - 450 PSI. 60 RPM's. 3K torque. ADT = 1.85 HRS. TRIP SURFAC POOH 2 stands. Blow down Top Drive. PJSM with GYRO crew. RU Gyro Unit. PULD SURFAC Make up MWD assembly, 8" DWD KM8 (26.91'}, UBHO sub (3.45'). Orient MWD to motor. MU 1 stand Non Mag Flex Drill Collars (92.91'), and 5" HWDP. Break Circulation. NOTE: STarting JAR HRS = 130.72 DRLG SURFAC Drill 13 1/2" Surface hole from 218' - 615` (39T). Run Gyro survey every 91' for close approach issues & kick off. AST = 1.47 HRS, ADT = 5.04 HRS. Up WT = 74k, SO WT = 74K, ROT WT = 70K. TO on BTM = 3-4k, TO off BTM = 2K. JAR HRS total = 138.85. Pumps @ 480 GPM's - 900 PSI. Rotate @ 60 RPM's. WOB = 10 - 20K. Mud WT = 8.8 PPG Viscosity = 400. YP = 83, Gels = 26 / 59. with Solids @ 4.0 DRLG SURFAC Continue Drill 13 1/2" Surface hole from 615' -1634' (1019'). RD Gyro survey. AST = 4x07 HRS, ADT = 7.45 HRS, ART = 4.00 HRS. Up WT = 98k, SO WT = 90K, ROT WT = 95K. TQ on BTM = 4-6k, TO off BTM = I 5K. JAR HRS total = 146.58. Pumps @ 550 GPM's - 1750 PSI. Rotate i @ 65 RPM's. Max Gas = 54 units. WOB = 30 - 35K. Mud WT = 9.2 1.25 RIGMNT RSRV RIGUP Slip i;< Cut 60' of Drilling Line. 0.50 RIGMNT RSRV RIGUP Inspect & Service Top Drive. 1.00 DRILL OTHR RIGUP Pick up 1 Stand of DP. RIH & Perform Diverter Function test. Witness 1.251 DRILL 0.501 DRILL 0.75i DRILL Printed: 4/12/2006 1:53:21 PM ~ • ConocoPhillips Alaska Operations Summary Report Legal Well Name: Common Well Name Event Name: Contractor Name: Rig Name: 1 J-159 1 J-159 ROT -DRILLING n1334@ppco.com Doyon 141 Date From-To Hours Code Code. Phase 2/13/2006 ~ 00:00 - 12:00 12:00 - 18:45 18:45 - 20:00 20:00 - 21:00 21:00 - 21:30 21:30 - 22:00 22:00 - 00:00 2/14/2006 00:00 - 00:30 ~ 00:30 - 01:45 01:45 - 02:30 02:30 - 03:00 03:00 - 03:45 03:45 - 04:00 04:00 - 06:00 06:00 - 10:00 10:00 - 10:30 10:30 - 11:15 11:15- 12:00 12:00 - 12:30 i 12:30 - 15:30 12.00 ~ DRILL DRLG 6.751 DRILL I DRLG 1.25 DRILL CIRC 1.00 DRILL WIPR 0.501 DRILL (WIPR 0.50 DRILL CIRC 2.00 DRILL TRIP 0.50 DRILL TRIP 1.25 DRILL TRIP 0.75 DRILL PULD 0.50 DRILL PULD 0.75 DRILL PULD 0.25 DRILL OTHR 2.00 CASE RURD 4.00 CASE RUNC 0.50 CASE CIRC 0.75 CASE RURD 0.75 CASE CIRC 0.50 CASE ;CIRC 3.001 CEMENTI PUMP Page 2 of 19 Spud Date: 2/12/2006 Start: 2/11/2006 End: 3/13/2006 Rig Release: 3/13/2006 Group: Rig Number: Description of Operations SURFAC PPG Viscosity = 300. YP = 47, Gels = 22 / 38. with Solids @ 6.5 Total AST = 5.54 HRS, ART = 9.04 HRS. Survey @ 1449.84 MD 1411.87. TVD, INC = 25.21 DEG, AZ = 45.28 DEG. Total Bit HRS = 14.58 SURFAC Continue Drill 13 1/2" Surface hole from 1634' -2370' (736'). Run Gyro survey @ 1300' for close appraoch issues. AST = 1.82 HRS, ADT = 3.7 HRS, ART = 1.89 HRS. Up WT = 11 OK, SO WT = 97K, ROT WT = 103K. TQ on BTM = 5-6k, TO off BTM = 3K. JAR HRS total = 150.29 Pumps @ 700 GPM's - 2100 PSI. Rotate @ 75 RPM's. Max Gas = 54 units. WOB = 20 - 35K. Mud WT = 9.15 PPG Viscosity = 275. YP = 47, Gels = 22 / 38. with Solids @ 6.5. Total AST = 7.36 HRS, ART = 10:93 HRS. Survey @ 2322.58 MD 2169.4 TVD, INC = 28.82 DEG, AZ = 80.98 DEG. Released GYRO Unit @ 1400 HRS. Total Bit HRS = 18.29 SURFAC Circulate hole clean while reciprocating drill string @ 700 GPM's - 2100 PSI. SURFAC Attempt to POOH on elevators, observing proper hole fill. Overpull from 5 - 30K. Wipe through spots at 1900' & 1825'. Decision to run. back to bottom and pump out of hole, with no rotation. SURFAC Trip back to bottom @ 2370' on elevators. No issues on TIH. 5 Stands. SURFAC Circulate btms up @ 700 GPM's - 2100 PSI. 75 RPM's ~ 4K TO. SURFAC Pump out of hole, no rotation from 2370' - 1266'. (1104'). Observe no issues, and slight overpull @ 1300'. Pumps @ 500 GPM's - 1200 PSI, to keep from washing out 13 1/2" hole. Observe good cuttings at shakers but not excessive. SURFAC Pumped OOH from 1,266'. to 1,082' w/ 500 gpm, 1100 psi, SURFAC POOH from 1,082' to 61'. UD 15 jts HWDP. PUW=90K SOW=85K SURFAC UD 3 jts NMFDCs, UBHO sub, float sub. SURFAC Downloaded MWD. SURFAC UD stab, MWD, motor and flushed same. UD bit and cleared and cleaned rig floor. SURFAC Made a dummy run to check hanger. SURFAC Held PJSM. R/U to run 10 3/4" casing. SURFAC Ran 57 jts 10 3/4" casing to 2,364.47" w/ total 22 bowspring centralizers as follows: Ran 1 centralizer on stop collar 5' above shoe: Ran 2 centralizers one 10' above and one 10' below float collar. One centralizer per jt. #3-#19: One centralizer over collar on jt #56 and #57. SURFAC Circ'd BUs w/ Franks fill-up tool @ 6 bpm, 375 psi. PUW=140K SOW=95K. SURFAC R/D Franks fill-up tool, blew down TD, and installed cement head. SURFAC Conditioned mud through cement head. SURFAC ~ Cont'd to circ and cond. mud @ 6 bpm, 400 psi. PUW=145K SOW=95K Held PJSM. SURFAC Continue pumped an additional 50 bbls of CW 100 (50 bbls total), Followed by 50 bbls of 10.5 ppg mudpush w/ red dye, dropped btm plug, began mixing and pumping Arcticset lead slurry, Pumped 375.0 bbls (471 sxs} of lead cement at 10.7 ppg and 4.45 yield with additives, ave 6.6 bpm at 275 psi, Followed with 74.1 bbls (169 sxs) of DeepCrete tail cmt at 12.0 ppg and 2.46 yield with add., ave 4.8 bpm at 230 psi, shut down and dropped top plug, Kick plug out with 20 bbls fresh water,. Reciprocated casing 10' to 15' until 150 bbls cement around shoe then Printed: 4/12/2006 1:53:21 PM • • ConocoPhillips Alaska Operations Summary Report Legal Well Name: 1J-159 Common Well Name: 1J-159 Event Name: ROT -DRILLING Contractor Name: n1334@ppco.com Rig Name: Doyon 141 Date From - To Hours Code Code Phase 2/14/2006 12:30 - 15:30 3.00 f CEMENT PUMP 15:30 - 16:30 1.00 CEMENTRURD 16:30 - 18:00 1.50 WELCT NUND 18:00 - 20:00 2.00 WELCT NUND 20:00 - 23:30 3.50 WELCT NUND 23:30 - 00:00 , 0.50 WELCT NUND 12/15/2006 100:45 -100:45 10.00 WELCTI ~ BOPE 10:45 - 12:00 1.25 WELCT BOPE 12:00 - 15:15 3.25 WELCT BOPE i 15:15 - 19:30 4.25 WELCT BOPE 19:30 - 21:30 2.00 WELCT BOPE 21:30 - 00:00 2.50 WELCT BOPE 12/16/2006 100:00 - 00:30 I 0.501 WELCTI,I BOPE I 00:30 - 01:00 ' 0.50' DRILL ~ OTHR 01:00 - 02:30 I 1.50 RIGMNT; RSRV 02:30 - 03:00 ~ 0.50 DRILL ~~ RIRD , Page 3 of ~ 9 Spud Date: 2/12/2006 Start: 2/11/2006 End: 3/13/2006 Rig Release: 3/13/2006 Group: Rig Number: Description of Operations SURFAC ~ pipe became tight and landed on hanger, Up 135K, Dn 80K:.Turn over to rig and displace cement w/ 197 bbls (1967 stks to bump plug) of 9.5 ppg mud, Displaced cement at 7.0 bpm, Initial pump pressure 280 psi, max pressure at 7.0 bpm 320 psi, Observed red dye at shakers after pumping 135 bbls mud, Slowed. rate down to 3 bpm @ 280 psi 10 bbls prior to bumping plug, Bumped plug w/ 1100 psi, Held 10 min, Check floats- OK, CIP @ 1525 hrs 2/14/2006, Had full returns through out job with 72.1 bbls 10.7 ppg cement to surface, Shoe @ 2,364.47', TVD = 2,207. Float collar @ 2,279.47. Test Float Equipment. Floats held. SURFAC Flushed stack and flow line. R/D Schlumberger and pulled landing jt. SURFAC Nippled down diverter and knife valve, pulled riser, functioned and washed Hydril. Removed Hydril and diverter spool. SURFAC Cleaned wellhead and installed Vetco Gray 11".wellhead and tested to 5000 psi. SURFAC ~ Nippled up BOPS, 13 5/8" X 11" adapter spool, attached turnbuckles. ~ SURFAC P/U 11"wellhead equip. including test plugs, wear rings, and running tools. SURFAC Finished N/U BOPE. ,SURFAC PJSM - Dicuss testing BOP's & Safety Issues. Perform BOP test. As follows:(1) Tested 7.625" rams, HCR choke (2) 3.5"X6" top rams, HCR kill and choke valves, valves 1,12,13,14 (3) Top rams, manual kill, choke valves 9,11, auto IBOP (4) Top rams, manual kill, choke valves 5,8,10, manual IBOP (5) Top rams, manual kill, choke valve 4,6,7 (6) Top rams, manual kill, choke valve 2, 4" TIW valve (7) Top rams, manual kill, choke valve 3, 4" dart valve (8) Top rams, manual kill, HCR choke, 5" TIW valve (9) Top rams, manual kill, 5" dart valve, (10) Annular preventer, manual choke + kill (11) Perform Koomey test. System Pressure = 3000 PSI, Pressure after close = 1900 PSI. First 200 PSI attained in 49 secs, and full pressure attained in 3 min 39 secs. AVG pressure in Nitrogen bottles = 2300 PSI. (12) Blind rams. All test to 250 PSI -low, 3500 PSI High. AOGCC rep, Jeff Jones witnessed tests. SURFAC Unable to test Hydril against 5" test joint. Rubber element in need of C/O. R/U to replace element. SURFAC R!U scaffolding to access BOPE. While R/U scaffolding an incident ~ occured wherein an individual injured a finger: Taken to medic for examination, with scaffolding not fininshed or signed off. Scaffolding crew returned @ 1400 hrs. Work concluded @ 1515 hrs. SURFAC Changed out Hydril element and installed riser. SURFAC I Retrieved test plug, noted Hydril rubber on plug. Washed rubber off and retrieved plug. Checked seals. SURFAC ~ R/U 5" testjt and set test plug. Tested annular preventer to 250 / 3000 psi. UD 5" testjt and P/U 4" testjt. M/U test plug and RIH. Tested annular preventer to 250/3000 psi. SURFAC Finished testing annular to 250 / 3000 psi against 4" testjt. Performed I accumulator test after rebuild of 4-way valve. System Pressure = 3000 PSI, Pressure after close = 1800 PSI. First 200 PSI attained in 35 secs, and full pressure attained in 3 min 079 secs. AVG pressure in Nitrogen bottles = 2300 PSI. SURFAC Pulled test plug and installed wear ring. SURFAC Changed out saver sub from 4.5" IF to 4" XT-39. SURFAC Installed bails and elevators: Printed: 4/12/2006 1:53:21 PM s • ConocoPhillips Alaska Page 4 of 19 Operations Summary Report Legal Well Name: 1J-159 Common Well Name: 1J-159 Spud Date: 2/12/2006 Event Name: ROT -DRILLING Start: 2/11/2006 End: 3/13/2006 Contractor Name: n1334@ppco.com Rig Release: 3!13/2006 Group: Rig Name: Doyon 141 Rig Number: Date From - To Hours Code Code Phase Description of Operations 2/16!2006 ~ 03:00 - 08:00 5.00 DRILL ~ PULD SURFAC I P/U 150 jts 4" DP and racked back same (50 jts at atime). 08:00 - 12:00 4.00 DRILL PULD SURFAC I P/U and M/U BHA #2 including: Bit, Mud Motor, Sub -Float Stabilizer, 6 13/4" DM Collar-MWD, 6 3/4" Gamma/Res/PWDMCIM. 12:00 - 14:30 ~ 2.50 ! DRILL ;PULD ~ SURFAC 14:30 - 16:00 1.50 CASE MIT SURFAC 16:00 - 17:30 1.50 RIGMNT~ RGRP SURFAC 17:30 - 20:30 I 3.001 CEMENT! DSHO i SURFAC 20:30 - 22:00 1.501 CEMENTLOT ~ SURFAC 22:00 - 00:00 2.00 DRILL I DRLG ; INTRM1 12/17/2006 00:00 - 12:00 12.00 ~ DRILL I DRLG INTRM1 1200 - 00:00 I 12.001 DRILL I DRLG I INTRMI Held PJSM for nuclear sources. P/U 2 flex DCs, HWDP and jars, 3 stds 5" DP, and ghost reamer, 12 stands 5" DP, XO to 4" DP. Tagged up @ 2268' Circa and S/B 1 std. R/U and tested casing to 3000 psi for 30 mins. Repaired 4-way valve on accumulator (controlled top rams) ,bled air from new lines. Drilled out shoe track w/ 400 gpm, 950 psi, 2-5K WOB, TO=4-6, ROT=95K. .Tagged float @ 2,274' and shoe @ 2,360'. Drilled 25' of new hole to 2395' MD 2233' TVD. Swapped mud, R/U and performed LOT to 13.7 EMW w/ 550 psi at surface. R/D and blew down. Garnered SPRs. SPR#1=30stk/180psi, 40stk/230psi SPR#2=30stk/180psi, 40stk/240psi @ 2,395' MD / 2,233' TVD and 9.0 PPG. Drilled from 2,395' to 2,523' MD / 2,344' TVD. ART=0.36 AST=0.43 Jar Hrs=151.08 PUW=112K SOW=82K ROT=95K Continue Directional drill 9 7/8" Intermediate from 2,523' to 3,829' MD / 3,323' TVD. ADT =8.21 hrs ART=2.69 AST=5.52 Total Bit HRS=9.0. Total Jar HRS =159.29 PU WT = 135K, SO WT = 85K, ROT WT =105K. TO on/off=5-10/5-10K. Pumps, - 589 GPM's -1900 PSI. RPMs = 100. WOB = 5-20K. Mud Wt =9.00 PPG, Visc = 57, ECD = 9.59 PPG, Max gas = 62 Units. SPR#1=20stk/250psi,30stk/330psi SPR#2=20spm/260psi,30stkl320psi @ 3,736' MD/ 3,265' TVD 9.OMW Continue Directional drill 9 7/8" Intermediate from 3,829' to 4,483' MD / 3,531' TVD. ADT =8.2 hrs ART=4.64 AST=3.56 Total Bit HRS=17.2. Total Jar HRS =167.49 PU WT = 135K, SO WT = 81 K, ROT WT =98K. TO on/off=5-9/6-8K. Pumps - 564 GPM's -1925 PSI. RPMs = 100-110. WOB = 15-25K. Mud Wt =9.0+ PPG, Visc = 51, ECD = 9.6 PPG, Max gas =110 Units. Observed drilling through concretions from 4275'-4280',.4297'-4300', 4312'-4314',4320'-4327',4329'-4338', 4390'-4392'. SPR#1=20stk/180psi,30stk/230psi j i SPR#2=20spm/170psi,30stk/230psi @ 4,390' MD/ 3,516' TVD 9.0 MW 2/18/2006 ~ 00:00 - 06:30 6.50 DRILL DRLG INTRMI Continue Directional drill 9 7/8" Intermediate from 4,483' to 4,773' MD / 3,576' TVD. •ADT =4.72 hrs ART=4.46 AST=0.26 Total Bit HRS=21.92. Total Jar ~ HRS =172.21 ~ ~ PU WT = 135K, SO WT = 75K, ROT WT =95K. TO on/off=6/7K. ~ Pumps - 615 GPM's -2000 PSI. RPMs = 100-110. WOB = 5-35K. Mud i ~ j Wt =9.1+ ppG, Visc = 55, ECD = 9.63 PPG, Max gas =174 Units. ~ ~ j Observed drilling through concretions from 4625'-4635'. Printed: 4/12/2006 1:53:21 PM s • ConocoPhillips Alaska Operations Summary Report Legal Well Name: 1J-159 Common Well Name: 1J-159 Event Name: ROT -DRILLING Contractor Name: n1334@ppco.com .Rig Name: Doyon 141 Date From - To Hours Code Code Phase 2/18/2006 ~ 00:00 - 06:30 ~ 6.50 ~ DRILL. ~ DRLG ~ INTRM1 06:30 - 07:00 0.50 DRILL DEOT INTRM1 07:00 - 07:30 0.50 DRILL CIRC INTRMI 07:30 - 08:45 1.25 DRILL TRIP INTRM1 08:45 - 10:30 1.75 DRILL TRIP INTRMI 10:30 - 11:00 0.50 DRILL OBSV INTRM1 11:00 - 12:00 1.00 DRILL TRIP INTRM1 12:00 - 12:30 0.50 DRILL TRIP INTRM1 12:30 - 13:00 0.50 DRILL PULD INTRM1 13:00 - 13:15 0.25 DRILL PULD INTRMI 13:15 - 13:45 0.50 DRILL PULD INTRM1 13:45 - 14:15 0.50 DRILL PULD INTRMI 14:15 - 14:45 0.50 DRILL PULD INTRM1 14:45 - 15:30 0.75 DRILL PULD INTRM1 15:30 - 16:30 1.00 DRILL PULD INTRMI 16:30-17:30 1.00 DRILL PULD INTRM1 17:30 - 18:00 18:00 - 20:30 20:30 - 00:00 12/19/2006 100:00 - 08:00 08:00 - 09:15 09:15 - 12:00 12:00 - 12:30 0.501 DRILL I PULD I INTRM1 2.501 DRILL (TRIP I INTRMI 3.501 DRILL I DRLG ; INTRM1 Start: 2/11 /2006 Rig Release: 3/13/2006 Rig Number: Page 5 of 19 Spud Date: 2/12/2006 End: 3/13/2006 Group: Description of Operations SPR#1=20stk/180psi,30stk/230psi SPR#2=20spm/170psi,30stk/230psi @ 4,390' MD/ 3,516' TVD 9.0 MW MWD failed. Attempt to troubleshoot. Circa BU @ 625 gpm, 2250 psi. POOH from 4,673' to 3.926' MD w/ 40-80 excess drag. POOH from 3.926' to 2,056' MD w/ 500 gpm, 1400 psi. Checked flow, static. Changed over to 5" handling tools. Cont'd to POOH from 2,056' to 1,684'. POOH from 1,684' to 660'. SLM OOH (no correction). Fill Act=49 Calc=38. R/B HWDP and jars. UD 1 jt. NMFDCs. Held PJSM. Removed MWD source. P/U 1 jt. NMFDC, R/B 1 std NMFDC. Downloaded MWD. UD nuclear string w/ DGR, PWD, TM collar M/U BHA #3. Oriented, P/U DGR, PWD, nuclear string, TM collar. Uploaded MWD. P/U 1 std. NMFDCs, UD 1 jt. NMFDCs. SHT MWD w/ 119 spm, 830 psi. Held PJSM. Loaded source fro MWD. P/U 1 jt. NMFDC. TIH w/ HWDP and jars, 5 stds to 65T. TIH from 657' to 4,777'. Washed and reamed to 4,777' w/ 120 spm, 1600 psi, 90 rpm, TO=6-7K Continue Directional drill 9 7/8" Intermediate from 4,473' to 4,990' MD / 3,615' TVD. ADT =1.73 hrs ART=1.22 AST=0.51 Total Bit HRS=23.65. Total Jar HRS =173.94 PU WT = 135K, SO WT = 75K, ROT WT =92K. TO on/off=6-7K/6-7.5K. Pumps - 615 GPM's -2000 PSI. RPMs = 100-110. WOB = 5-35K. Mud Wt =9.1+PPG, Visc = 55, ECD = 9.71 PPG, Max gas =108 Units. Observed drilling through concretions from 4772'-4776', 4836'-4841', 4849'-4855'. SPR#1=20stk/220psi,30stkl300psi SPR#2=20spm/240psi,30stkl310psi @ 4,948' MD/ 3,612' TVD 9.1+ I MW 8.00 DRILL DRLG INTRMI Continue Directional drill 9 7/8" Intermediate from 4,990' to 5,580' MD / 3,696' TVD. ADT =6.95 hrs ART=3.13 AST=2.82 ~ Total Bit HRS=24.15. Total Jar HRS=180.89 PU WT = 135K, SO WT = 75K, ROT WT =92K. TQ on/off=7/7K. Pumps - 636 GPM's -2500 PSI. RPMs = 90. WOB = 15-20K. Mud Wt =9.25+ PPG, Visc = 55, ECD = 9.84 PPG, Max gas =108 Units. Observed drilling through concretions from 5072'-5076'. ~ I SPR#1=30stk/270psi,40stk/350psi I~ SPR#2=30spm/280psi,40stk/360psi @ 5,580' MD/ 3,696' TVD 9.1 MW 1.25 i DRILL CIRC ~ INTRMI 1 Circ'd a hi-vis weighted sweep + 1 BU @ 636 GPM, 2400 psi. Checked,. -flow static. 2.751 DRILL TRIP I INTRM1 ~ Pumped dry job, blew down TD. POOHfirom 5,511' to 2;988'. 0.50 DRILL TRIP. i INTRM1 POOH firom 2,988' to 2,053'. Changed over to 5" handling tools. Checked flow, static. Printed: 4!12/2006 1:53:21 PM d ~, • ConocoPhillips Alaska Operations Summary Report Legal Well Name: 1J-159 Common Well Name: 1J-159 Event Name: ROT -DRILLING Contractor Name: n1334@ppco.com Rig Name: Doyon 141 Date From - To Hours Code Sub Phase Code 2/19/2006 12:30 - 13:00 0.50 DRILL TRIP INTRM1 13:00 - 13:45 0.75 DRILL PULD INTRMI 13:45 - 14:30 0.75 DRILL I PULD INTRM1 14:30 - 15:00 0.50 DRILL I PULD ~ INTRM1 15:00 - 16:00 1.00 DRILL PULD INTRM1 16:00 - 16:30 0.50 DRILL OTHR INTRM1 16:30 - 17:30 1.00 CASE RURD INTRM1 17:30 - 21:15 3.75 CASE RUNC INTRM1 21:15 - 21:45 0.50 CASE CIRC INTRMI 121:45 - 00:00 2.25 CASE RUNC INTRMI 2/20/2006 100:00 - 00:30 0.50 CASE i RUNC INTRM1 00:30 - 01:45 1.25 CASE CIRC INTRM1 01:45 - 02:15 0.50 CASE RURD INTRM1 02:15 - 04:00 1.75 CEMENT CIRC INTRM1 04:00 - 06:15 2.25 CEMENT PUMP INTRM1 Page 6 of 19 Spud Date: 2/12/2006 Start: 2/11/2006 End: 313/2006 Rig Release: 3/13/2006 Group: Rig Number: Description of Operations UD 5" DP (45 jts) to 663'. UD 5 stds HWDP and jars. UD 1 NMFDC. Held PJSM on nuclear sources. UD 2 NMFDCs. Downloaded MWD. UD TM, nuclear string w/ DGR, PWD, DM, stab, F/S, motor, and bit. Cleared and cleaned rig floor. R/U to run 7 5!8" casing. Held PJSM. Ran 7 5/8" casing to 2319'. Circa pipe volume @ 3.5 BPM, 350 psi. Staged up as follows: 4.5 BPM, 300 psi; 5.5 BPM, 350 psi; 6.5 BPM, 400 psi. Cont'd running 7 5/8" casing to 4,312'. Cont'd to run casing from 4,312' to 5,567'. PUW=190K SOW=90K Circa w/ Franks tool staging up to 5 BPM, 450 psi. R/D Franks fill up tool, blew down TD: R/U cement head. Circa and cond mud for cement job @ 7 BPM, 450 psi. 'Pumped cement as follows: Fill both Mud pumps & lines with MOBM. Turn Rig over to Dowell lines. Dowell pumped 10 bbls CW 100 at 8.3 ppg at rate of 4.7 bpm @ 168 psi, Pressure tested lines to 4,000 psi, Then pumped 40 add. bbls of CW 100 at rate of 5.0 bpm @ 255 psi. Dropped btm plug then pumped 50 bbls of MudPush at 11.0 ppg at rate of 5.0 bpm @ 420 psi, then pumped 142 bbls, (351sxs - 25% over caliper) of DeepCrete cmt at 12.5 ppg, 2.25 yield with additives, avg 4.9 bpm at 750 psi, Reciprocated pipe with full returns 15' to 20'. Drop top plug and Dowell kicked top plug out with 10 bbls fresh water, @5 BPM 200 PSI. Rig displaced cement with 9.0 ppg OBM, Bumped plug after pumping 244 bbls MOBM (96% pump eff.) 2416 Strokes, avg 6.5 bpm while displacing cmt, Observed lift pressure as cement turned corner. Slowed pump rate to 3 bpm, @ 830 psi prior to bumping. Bumped plug to 1270 psi, ck floats and held. CIP at 0615.. hrs, 2-20-2006. Reciprocated pipe 10' to 20' until Mud PUSH at shoe, then recip. 10' until Cmt at shoe, then recip. 10' until 2000 stks looked a little ratty. Landed csg with Shoe @ 5575', Float Collar @5486', Calc TOC @ 2226, Had full returns thru out job. Well static after shut down. 06:15 - 07:15 1.001 CEMENTOTHR INTRMI 07:15 - 09:30 2.251 CASE OTHR ~ INTRMI 100:30 - 110:00 0.50 WELCT~I BOPE INTRM1 11:00 - 12:00 I 1.001 DRILL !LOT I INTRMI 12:00 - 13:00 ; 1.001 DRILL I RIRD !INTRMI 13:00 - 13:30 I 0.501 DRILL ! OTHR ' INTRM1 Checked floats, R/D cement head and blow down all lines. Shoe @ 5575'. RU and suck out MOBM from inside of 7 5/8"joint to below well head level. Nipple down BOP stack, and raise for installation of emergency slips. Set slips with 75K overpull on casing. R/U WACHS pneumatic cutter and cut casing as per Vetco Gray reps. PULD cut off joint. # 129 Cut off length = 36.02'. N/U BOPE and wellhead. Installed test plug and performed body test on BOPS 250 / 3000 psi for 5 min each. Inject 30 bbls H2O into the 10 7/8" X 7.5/8" annulus. Broke down w/ 7.7 ~bls and 860 psi. Final circ press. 710 psi. UD casing tools and neared rig floor. nstalled bails and 4" elevators. Flushed gas buster w/ H2O also lushed choke manifold. nstalled wear bushing and sim-oped by C/O 6" liners to 5.5" in mud Printed: 4!12/2006 1:53:21 PM i • ConocoPhillips Alaska Operations Summary Report Page 7 of 19 Legal Well Name: 1 J-159 Common Well Name: 1J-159 Spud Date: 2/12/2006 Event Name: ROT -DRILLING Start: 2/11/2006 End: 3/13/2006 Contractor Name: n1334@ppco.com Rig Release: 3/13/2006. Group: Rig Name: Doyon 141 Rig Number: Date From - To Hours Code Sub Code Phase Description of Operations 2/20/2006 13:00 - 13:30 0.50 DRILL OTHR INTRM1 pumps. Cleaned pits. 13:30 - 14:15 0.75 DRILL OTHR INTRM1 Loaded pipeshed w/ BHA and DP. 14:15 - 16:30 2.25 DRILL PULD INTRM1 P/U 30 stds 4" DP w/super-sliders. ~ 16:30 - 18:00 1.50 DRILL PULD INTRM1 POOH w/ 30 stds 4" DP w/ super-sliders and R/B. 18:00 - 19:00 1.00 DRILL PULD INTRM1 P/U 7 stds 4" HWDP, POOH and R/B same. 19:00 - 21:30 2:50 DRILL PULD INTRM1 P/U 10 stds hybrid DP and R/B same. 21:30 - 22:00 0.50 DRILL OTHR INTRM1 Cleared and cleaned rig floor. 22:00 - 23:30 1.50 RIGMNT RSRV INTRM1 Slipped and cut 58' drill Tine. Serviced TD and DWs. Sim-opd by flushing 10 7/8" X 7 5/8" annulus w/ 105 bbls H2O @ 2.5 BPM, 780 psi max, 700 psi FCP. 23:30 - 00:00 0.50 DRILL PULD INTRM1 ~ P/U BHA tools to rig floor. 2/21/2006 00:00 - 01:00 1.00 DRILL PULD INTRM1 M/U BHA from bit to TM HOC as follows: Bit, 5" Sperry Drill 6/7 6.0 Stg., Non Mag Float Sub, Non Mag String Stabilizer, 4 3/4" DM Hang Off Collar, 4 3/4" Slimphase 4 w/Gamma/Res, 4 3/4" PWD Collar, 4 3/4" TM Hang Off Collar. 01:00 - 02:00 1.00 DRILL PULD INTRM1 Uploaded MWD. 02:00 - 03:00 1.00 DRILL PULD INTRM1 P/U NMFDCs, HWDP, jars. Pulse tested MWD, blew down TD. I, 03:00 - 06:00 3.00 DRILL TRIP INTRM1 Singled in 39 jts 4" DP. P/U XO, Andergauge agitator, shock sub, XO (BHA length 1595') . P/U 12 jts 4" DP. Continued to RIH from 1,969' to 5,585'. Tagged float equip. 06:00- 06:30 0.50 DRILL CIRC INTRM1 Circ'd 1 BU @ 82 spm, 3200 psi. 06:30 - 08:00 1.50 CASE MIT INTRM1 R/U and tested 7 5/8" casing to 3000 psi for 30 mins. Good test, R/D. 08:00 - 09:30 1.50 CEMEN DSHO INTRM1 Drilled out FC, shoe track, and shoe + 25' of new hole to 5,605' MD w/ 277 gpm, 3400 psi, 100 rpm. PUW=105K SOW=75K ROT=90K. 09:30 - 10:30 1.00 CEMENTCIRC INTRMI Circ'd and cond. mud for LOT @ 277 gpm, 3400 psi. 10:30 - 11:00 0.50 CEMEN LOT INTRM1 R/U and performed LOT to .14.3 psi @ 5,605' MD / 3,695'. R/D equip. 11:00 - 12:00 1.00 DRILL DRLH PROD Drilled from 5,605' to 5,609' MD / 3,698' TVD. ADT=0.42 AST=0.42 TOon/off=3K ECD=9.81 Jar hrs=0.42 12:00 - 14:00 2.00 DRILL DRLH PROD Drilled from 5,609 to 5,810' MD / 3,694' TVD. Exited top of formation. ADT=1.71 AST=0.64 ART=1.07 Jar hrs=2.31 PUW=105K SOW=70K ROT=85K RPM=90 WOB=3-5K Pump #2=77 spm, 2500 psi. 14:00 - 19:30 ; 5.50 i DRILL ,DRLH PROD ;Pulled back to 5,613' MD. Low-sided and drilled from 5,613' to 5,810'. 19:30 - 00:00 4.50 DRILL DRLH PROD Drilled from 5,810 to 6,170' MD / 3,689' TVD. AST=3.20 ART=3.05 (Times from 1400 hrs) Total Jar and Bit hrs=8.38 PUW=105K SOW=70K ROT=85K RPM=80-100 WOB=3-10K Pump #1=78 spm, 2600 psi. ECD=10.19 Max Gas= 88 Concretions depths: 5655'-5660', 5696'-5701', 5709'-5710', 5767'-5769', 5795'-5800', 5803'-5810', 5824'-5826', 5852'-5854', 5868'-5870', 5880'-5882', 5890'-5893', 5954'-5957', 5981'-5992', 6004'-6006', 6010'-6018', 6079'-6082' SPR#1=20stW410psi, 30stk/620psi SPR#=20stk/440psi, 305tk/650psi @ 5,797' MD / 3,676' TVD 8.7 MW. KREVs for tour-10521 2/22/2006 ! 00:00 - 12:00 ! 12.00 ~ DRILL j DRLH ',PROD j Drilled from 6,170' to 7,275' MD / 3,652' TVD. Printed: 4/12/2006 1:53:21 PM ~ • ConocoPhillips Alaska Page 8 of 19 Operations Summary Report Legal Well Name: 1J-159 Common Well Name: 1J-159 Spud Date: 2/12/2006 Event Name: ROT -DRILLING Start: 2/11/2006 End: 3/13/2006 Contractor Name: n1334@ppco.com Rig Release: 3/13/2006 Group: Rig Name: Doyon 141 Rig Number. Date From - To Hours Code Phase Description of Operations Code ~ 2/22/2006 00:00 - 12:00 12.00 DRILL DRLH PROD ADT=6.23 AST=2.49 ART=3.74 Total Jar and Bit hrs=15.68 PUW=120K SOW=75K ROT=90K RPM=100 WOB=3-5K TQon/off=5K Pump #1=88 spm, 3200 psi. ECD=10.46 Max Gas= 88 SPR#1=20stk/430psi, 30stk/630psi SPR#2=20stk/440psi, 30stk/640psi @ 7,093' MD / 3,659' TVD 8.7+ MW. 12:00 - 17:15 5.25 DRILL DRLH PROD Drilled from 7,275' to 7,857' MD / 3,642' TVD. Pumped a weighted hi-vis sweep of 35 bbls @ 7,760' and observed a 35% increase in cuttings. ADT=3.65 AST=3.20 ART=0.45 Total Jar and Bit hrs=19.33 PUW=133K SOW=84K ROT=102K RPM=95-110 WOB=3-12K TQon/off=5K/5.5K Pump #1=92 spm, 3825 psi. ECD=10.68 Max Gas=53 KREVs=23400 Concretion depths: 7474-7481', 7520-7541', 7557-7571', 7580-7595', 7600-7609'. 17:15 - 17:30 0.25 DRILL OBSV PROD Garnered SPRs. Checked flow, static. SPR#1=20stk/440psi, 30stk/660psi SPR#2=20stk/460psi, 30stk/670psi @ 7,857 MD ! 3,642' TVD 8.7+ MW. 17:30 - 21:00 3.50 DRILL WIPR PROD BROOH from 7,857' to 5,570' w/ 78 spm, 3000 psi, 100 rpm, TO=5K. 21:00 - 21:30 0.50 DRILL CIRC PROD CBU @ work pipe from 5,570' to 5,519' w/ 100 rpm, TO=4K PUW=100K SOW=75K 21:30 - 21:45 0.25 DRILL OBSV PROD Checked flow, static. 21:45 - 23:00 1.25 DRILL WIPR PROD TIH from 5,519' to 7,857. 23:00 - 00:00 1.00 DRILL CIRC PROD Clrc'd hole clean @ 7,857' w/ 92 spm, 3800 psi, TQ=5K 2/23/2006 00:00 - 00:30 0.50 DRILL CIRC PROD Circ'd @ 925 spm, 3800 psi. PUW=124K SOW=80K ROT=98K TOoff=SK ECD=10.54 00:30 - 01:15 0.75 DRILL CIRC PROD Displaced well to SFOBM w/ 92 spm, 3800 psi. PUW=144K SOW=87K ROT=105K ECD=10.28 01:15 - 01:30 0.25 DRILL OBSV PROD Garnered SPRs. Blew down TD. Checked flow, static. 01:30 - 05:15 3.75 DRILL TRIP PROD UD 2 jts. POOH from 7,857' to 94'. UD XO, shock sub, Andergauge agitator, and XO. 05:15 - 06:00 0.75 DRILL ~ PULD PROD Downloaded MWD data. 06:00 - 06:30 0.50 DRILL PULD PROD Cont'd to UD BHA including: TM HOC, slimphase 4 w/ DGR and EWR, DM HOC, stab, float sub, motor and bit. 06:30 - 07:00 0.50 DRILL OTHR CMPLTN i Cleaned and cleared rig floor. 07:00 - 08:00 1.00 CASE RURD CMPLTN R/U to run 4.5" liner. Held PJSM. 08:00 - 10:45 2.75 CASE RUNC CMPLTN RIH w/ 4.5" liner as per detail to 3124'. Ran a total of 41 jts of blank pipe (1265.73') and 59 jts. of slotted pipe (1842.08'). 10:45 - 12:00 1.25 CASE RUNC CMPLTN ~ flexlock liner hanger, RS packoff seal nipple, P/U and M/U seal bore , HRD ZXP liner top packer, and liner running tool to 3,189'. 12:00 - 15:00 3.00 CASE. RUNL CMPLTN TIH w/ liner on DP to 7,857. Pulled up to 7,842'. Checked TO on i ~ supersliders while RIH. PUW=135K SOW=81 K 15:00 - 16:15 1.25 CASE ~ DEQT CMPLTN ~ Drop 1 1/2" ball, Position liner w/ shoe @ 7,842.07 i;< top of liner @ f ~ 4,666.13', Circ ball down w/ 35 spm and 400 psi. Pressure up to 2500 Printed: 4/12/2006 1:53:21 PM ~ • ConocoPhillips Alaska Operations Summary Report Legal Well Name: 1 J-159 Common Well Name: 1J-159 Event Name: ROT -DRILLING Contractor Name: n1334@ppco.com Rig Name: Doyon 141 Date From - To Hours Code Code Phase 2/23/2006 15:00 - 16:15 1.25 CASE i DEOT CMPLTN 16:15 - 16:45 0.50 DRILL CIRC CMPLTN 16:45 - 19:00 2.25 DRILL TRIP I CMPLTN 19:00 - 19:15 0.25 DRILL PULD CMPLTN 19:15 - 19:45 0.50 DRILL OTHR CMPLTN 19:45 - 22:00 2.25 DRILL ,PULD PROD2 22:00 - 22:45 22:45 - 23:00 23:00 - 00:00 2/24/2006 00:00 - 01:30 01:30 - 02:30 02:30 - 03:00 03:00 - 03:30 03:30 - 04:15 i 04:15 - 09:15 09:15 - 10:00 10:00 - 10:15 Page 9 of 19 Spud Date: 2/12/2006 Start: 2/11/2006 End: 3/13/2006 Rig Release: 3/13/2006 Group: Rig Number: Description of Operations PSI to set hanger. Set down 55K to set slips as per BOT rep, continue pressure up to 4200 PSI, to complete setting PKR. Bleed pressure, Rig up and pressure test down annulus to test PKR at 1000 PSI - 5 Minutes. P/U w/ 125K and pulled up 8'. RIH and tagged top of liner @ 4666.13'. Pulled up to 4,595'. Circa 1 BU w/ 80 spm, 1275 psi. Checked flow, static. POOH from 4,595' to 56'. UD running tool. Cleaned and cleared rig floor. P/U whipstock BHA as follows:Liner Seals, Locator Sub, Uploader Sub, 3 1/2" HWDP, Blanking Crossover Sub, Bottom Trip Anchor, Shear Disconnect Sub, Drain Sub, Debris Sub, Removable Whipstock, Window Mill,+Lower Mill+Upper Mill, HWDP, Non-Mag Float Sub w/ Spacer, 4 3/4" DM HOC, 4 3/4" Slimphase 4 w/ DGR & Res, 4 3/4" PWD, 4 3/4" TM HOC 0.75 DRILL PULD I PROD2 Uploaded MWD. 0.25 DRILL PULD I PROD2 P/U and M/U Lub Bumper Sub, Crossover Sub, Hybrid Drill Collars. 1.00 DRILL TRIP I PROD2 RIH from 392' to 1,792' MD. 1.50 WINDOWTRIP ~ PROD2 1.00 WINDOWOTHR PROD2 0.50 WIND01NrRIP PROD2 0.50 WINDOWSETW PROD2 0.75 WINDOWCIRC PROD2 5.00 WINDOWSTWP PROD2 0.75 WINDO TWP I PROD2 0.251 WINDOWOTHR I PROD2 10:15 - 12:00 1.75 WINDO~ TRIP PROD2 12:00 - 12:30 0.50 WINDOW TRIP PROD2 12:30 - 13:45 .1.25 WINDOW PULD PROD2 13:45 - 15:30 1.75 DRILL OTHR , PROD2 15:30 - 16:15 I 0.75 DRILL I OTHR ' PROD2 16:15 - 17:15 ~ 1.00 DRILL ~ PULD ~ PROD2 17:15 - 18:15 1.00 DRILL '~ PULD I PROD2 18:15 - 18:45. 0.50 DRILL !PULD ~ PROD2 Tour Note: Freeze protected 10 314" X 7 5/8" annulus w/ 85 bbls diesel ICP=1500 psi FCP= 1500 psi @ 1.4 bpm Cont'd to RIH form 1,792' to 3,843' MD. Filled pipe @ 2,559', 3,843'. Made MAD pass from 3,900' to 4,024' MD. Correlation within 1'. Cont'd to RIH from 4,024' to 4,659' MD. Established. PUW=120K and SOW=90K prior to setting trip anchor. Orient whipstock @ 11 deg left of high-side and set trip anchor after tagging A Lat ZXP as expected @ 4,666'. Pulled up to 130K to verify trip anchor st. Sheared off bolt w/ 60K downweight. Mill @ 4,565' MD=Top of B Lat window. Held PJSM and displaced well to MOBM @ 70 spm, 1500 psi. 'Milled window from 4,565' to 4,577. Milled 20' of gauge hole to total depth of 4,606'. PUW=112K SOW=92K ROT=95K TOon/ofF=6-7K/3.5K Pumped 30 bbl weighted hi-vis sweep (observed 50% increase in cuttings) w/ 64 spm, and 100 psi. Rotated through window w/ pumps on and 100 rpm. Repeated sliding. PUW=120K SOW=90K Garnered SPR. Flow checked well, static. Pumped dry job. SPR#1=25stks/350psi, 35stks/550psi SPR#2=25stks/370psi, 35stks/530psi @ 4,606' MD/ 3,557' TVD POOH from 4,606' to 1,224' MD. Checked sliders on the way OOH. Cont'd POOH from 1,224' to 290'. UD XO, downloaded MWD. UD MWD, NM FS, 1 jt 3.5`' HWDP, upper and lower window mills. Upper mill in gauge. Cleaned and cleared rig floor. Pulled wear bushing, flushed stack, set wear bushing. P/U 2 stds hybrid DP and 2 stds HWDP. Racked back in derrick. M/U BHA #6 as follows: Security PDC bit, Geo-pilot, flexcollar, DM, smart sub, slimpahse 4 w/ DGR and EWR, PWD, TM, NM FS, stab. Uploaded MWD. Cont'd to MU BHA w/ NMFDCs, 2 stds HWDP and jars. SHT MWD w! 84 spm, 298 gpm, 1350 psi. ~. ~ ~~ s ~~.~ Printed: 4/12/2006 1:53:21 PM • • ConocoPhillips Alaska Operations Summary Report Legal Well Name: 1J-159 Common Well Name: 1J-159 Event Name: ROT -DRILLING Contractor Name: n1334@ppco.com Rig Name: Doyon 14.1 Date From - To .Hours Code Sub Code 2/24/2006 18:45 - 20:00 I 1.25 1 DRILL (TRIP Phase PROD2 P/U 6 stds DP. TIH to 4,375' MD. Start: 2/11/2006 Rig Release: 3/13/2006 Rig Number: Description of Operations Page 10 of19~ Spud Date: 2/12/2006 End: 3/13/2006 Group: 20:00 - 21:00 1.00 RIGMNT RSRV I PROD2 ~ Cut and slipped drill line (38'). 21:00 - 21:30 0.50 RIGMNT RSRV ~ PROD2 I Serviced TD and inspected saver sub. 21:30 - 21:45 I 0.251 DRILL I TRIP I PROD2 21:45 - 22:15 0.50 DRILL DRLH PROD2 22:15 - 23:15 1.00 DRILL DRLH PROD2 23:15 - 00:00 0.751 DRILL l DRLH PROD2 12/25/2006 100:00 - 09:00 I 9.00 DRILL DRLH PROD2 09:00 - 09:30 0.50 DRILL I CIRC PROD2 09:30 - 10:00 0.50 DRILL ~ CIRC PROD2 10:00 - 12:00 2.00 I DRILL TRIP PROD2 12:00 - 12:45 I 0.751 DRILL I TRIP I PROD2 12:45 - 13:00 0.25 DRILL I PULD PROD2 13:00 - 13:45 0.75 DRILL ~ PULD PROD2 13:45 - 14:15 0.50 DRILL I PULD PROD2 14:15 - 15:00 0.75 DRILL PULD PROD2 15:00 - 15:30 0.50 DRILL ~ PULD PROD2 15:30 - 17:00 1.50 DRILL I TRIP PROD2 17:00 - 18:00 1.00 DRILL I TRIP ' PROD2 18:00 - 19:00 1.00 DRILL TRIP PROD2 19:00 - 19:15 0.25 DRILL ~ DEOT i PROD2 19:15 - 19:45 0.501 DRILL TRIP I PROD2 19:45 -.20:15 , 0.501 DRILL , TRIP i PROD2 20:15 - 20:45 I 0.50 !DRILL ':DRLH i PROD2 Established PUW=95K SOW=76K ROT=85K TO=3.5K w/ 70 spm and 1500 psi. Went through window to 4585' w/ no problems. Reamed to 4,606'. Drilled from 4,606' to 4,620' MD. Geo-Pilot not holding toolface. Troubleshot Geo-pilot. Pulled into casing and reset manually. Run back through window to bottom. Drilled from 4,620' to 4,624' MD / 3,559' TVD. ADT=0.52 PUW=95K SOW=76K ROT=85K TOon/off=4.5K/3.5K Total bit hrs=0.52 Total jar hrs=19.90 Drilled from 4,624' to 4,987 MD / 3,550' TVD. ADT=6.81 PUW=105K SOW=70K ROT=84K TOon/off=4K/4K ECD=9.61 Mas Gas=51 Total bit hrs=7.33 Total jar hrs=26.71 SPR#1=25stks/280psi, 30stks/430psi SPR#2=25stks/300psi, 30stks/440psi @ 4,966' MD/ 3,551' TVD 8.8 MW Stop drilling for geology. Out top of formation. CBU @ 91 spm, 2150 psi, ROT=100 TOoff=3K. Geo-Pilot failed. ABI failed which determines highside for toolface referencing. Checked flow, static. POOH from 4,987' to 4,553' w/ hole taking proper fill. Pumped dry job. Cont'd to POOH to 2,883'. POW=105K SOW=70K Cont'd to POOH from 2,883' to 91'. UD BHA including: NMFDCs, 2 stds HWDP and jars. Downloaded MWD tool. Cont'd to UD BHA including: stab, NM FS, TM, PWD, slimphase 4 w/ DGR and EWR, smart sub, DM, flex collar, geo-pilot, and Security PDC, bit M/U BHA #7 including: Reed Hycalog Bit, 5" Sperry Drill 6/7 6.0 Stg, Non Mag Float Sub, 4 3/4" DM Hang Off Collar, 4 3/4" slimphase 4 w/Gamma/Res, 4 3/4" PWD Collar, 4 3/4" TM Hang Off Collar. Uploaded MWD. P/U lstd NMFDCs, 2jts HWDP w/jars. TIH inserting Andergauge Agitator and XOs @ 2,598'. TIH from 356' to 4,530' MD. PUW=95KSOW=75K Oriented to the highside and slid through window w/ 86 spm, 3100 psi. Good pulse on MWD, slid through no problems to 4,675'. Attempted to get good pulse test MWD, no luck. Agitator interfering w/ signal @ this depth. POOH to 2,524'. UD 2 XOs and Andergauge Agitator w/shock sub. Tested MWD w/ 76 spm, 1600 psi. All tests successful. TIH from 2,524' to 4,553'. Oriented to the highside and slid through window w/ 77 spm, 1900 psi: Good pulse on MWD, slid through no problems to 4,680'. Drill trough for. low-side sidetrack from 4,680' to 4,687'. Printed: 4/12/2006 1:53:21 PM • r ConocoPhillips Alaska Operations Summary Report Legal Well Name: Common Well Name Event Name: Contractor Name: Rig Name: 1 J-159 1 J-159 ROT -DRILLING n1334@ppco.com Doyon 141 Start: 2/11 /2006 Rig Release: 3/13/2006 Rig Number: Page 11 of 19 Spud Date: 2/12/2006 End: 3/13/2006 Group: Date From - To Hours Code Sub Phase Code 12/25/2006 20:45 - 22:00 1.25 DRILL DRLH PROD2 22:00 - 00:00 2.00 DRILL ~ DRLH PROD2 Description of Operations Time drilled for low-side sidetrack from 4,687' to 4,710'. Drilled from 4,710' to 4,839' MD / 3,555' TVD. ADT=2.17 AST=1.93 ART=0.24 PUW=104K SOW=74K ROT=85KTQnn/off=4.5K/5K ECD=9.64 Mas Gas=50 Total bit hrs=2.17 Total jar hrs=28.88 SPR#1=20stks/280psi, 30stks/440psi SPR#2=20stks/300psi, 30stks/450psi @ 4,839' MD/ 3,555' ND 8.7+ MW 2/26/2006 00:00 - 01:30 1.50 DRILL ~ DRLH PROD2 Drilled from 4,839' to 4,987' MD. Back to measured depth before sidetrack operations began. i ADT=0.88 AST=0.62 ART=0.22 01:30 - 12:00 10.50 DRILL ~ DRLH PROD2 Drilled from 4,987 to 5,503' MD! 3,551' TVD. . ADT=8.06 AST=2.89 ART=5.17 PUW=104K SOW=70K ROT=82K TQon/off=4K/5K ECD=9.77 Mas Gas=76 Total bit hrs=11.11 Total jar hrs=37.82 Concretion Depths: 4977-4987', 5026-5037', 5045-5056', 5064-5090', 5120-5126', 5144-5148', 5168-5181', 5188-5200', 5203-5204', 5212-5230', 5248-5249',5288-5290', 5306-5320', 5327-5351', 5389-5393', 5400-5401', 5405-5412',5481-5488', 5494-5504'.. SPR#1=20stks/280psi, 30stks/440psi SPR#2=20stks/300psi, 30stks/450psi @ 4,839' MD/ 3,555' TVD 8.7+ 12:00 - 00:00 12.00 DRILL DRLH PROD2 Drilled from 5,503' to 6,508' MD / 3,529' TVD. ADT=8.86 AST=2.57 ART=6.29 PUW=105K SOW=68K ROT=82KTQon/off=5K/5.5K ECD=10.02 Mas Gas=123 Total bit hrs=19.97 Total jar hrs=46.68 Concretion Depths: 5551-5565', 5570-5584', 5587-5589',.5600-5605', 5611-5619', 5754-5760', 5803-5818', 5850-5852', 5983-5995', 6065-6075', 6097-6110', 6113-6115', 6141-6143', 6169-6173', 6268-6284', 6318-6323', 6334-6336', 6350-6353'. SPR#1=20stks/310psi, 30stks/480psi SPR#2=20stks/330psi, 30stks/490psi @ 5,886' MD/ 3,554' TVD 8.7+ 2/27/2006 ~ 00:00 - 03:30 3.50 DRILL DRLH PROD2 Drilled from 6,508' to 6,832' MD / 3,520' TVD. IADT=1.86 AST=0.71 ART=1.15 ~ PUW=108K SOW=64 ROT=81 K TQon/off=5K/5K ECD=10.02 Mas Gas=123 03:30 - 04:15 0.75 DRILL REAM PROD2 ' After looking at logs went out of zone @ 6,740' MD/ 3,526' TVD per gene. BROOH from 6,832' to 6,282' MD w/ 88 spm, 310 gpm, 2600 psi, 100 rpm. PUW=108K SOW=64K 04:15 - 05:15 1.00 DRILL DRLH PROD2 ~ Cut trough for sidetrack w/ 88 spm, 310 gpm, 2500 psi. 05:1.5 - 06:45 1.50 DRILL DRLH , PROD2 Time drilled from 6,289' to sidetrack point @ 6,294' MD /3,541' TVD. 06:45 - 12:00 I 5.25 DRILL DRLH ~ PROD2 Drilled from 6,294' to 6,714' MD / 3,540' ND. ~ ADT=4.78 AST=2.43 ART=2.35 PUW=110K SOW=65K ROT=82KTQon/off=5K/5K ~ I ECD=10.25 Mas Gas=84 Printed: 4/12/2006 1:53:21 PM • • ConocoPhillips Alaska Page 12 of ~g Operations Summary Report Legal Well Name: 1J-159 Common Well Name: 1J-159 Event Name: ROT -DRILLING Contractor Name: n1334@ppco.com Rig Name: Doyon 141 Date From - To Hours Code Code Phase 2/27/2006 06:45 - 12:00 12:00 - 12:30 5.25 DRILL DRLH PROD2 0.501 DRILL I DRLH I PROD2 12:30 -00:00 I 11.50; DRILL I DRLH i PROD2 12/28/2006 100:00 - 01:30 01:30 - 01:45 01:45 - 09:00 13/1 /2006 09:00 - 10:15 10:15 - 12:00 1.501 DRILL I DRLH I PROD2 0.25 DRILL CIRC PROD2 7.25 DRILL DRLH PROD2 1.251 DRILL (TRIP IPROD2 1.75 !DRILL ;DRLH ! PROD2 12:00 - 00:00 I 12.001 DRILL I DRLH I PROD2 00:00 - 12:00 I 12.001 DRILL I DRLH I PROD2 12:00 - 17:00 I 5.001 DRILL I DRLH I PROD2 17:00 - 18:00 I 1.001 DRILL i CIRC I PROD2 Spud Date: 2/12/2006 Start: 2/11/2006 End: 3/13/2006 Rig Release: 3/13/2006 Group: Rig Number. Description of Operations I Total bit hrs=26.61 Total jar hrs=53.32 Concretion Depths: 6318-6321', 6334-6336', 6350-6353', 6396-6398', 6489-6492',6521-6523' SPR#1=20stks/390psi, 30stks/560psi SPR#2=20stks/410psi, 30stks/580psi @ 6,707' MD/ 3,538' TVD 8:7+ Drilled from 6,714' to 6,832' MD / 3,536' TVD. ADT=0.73 AST=0.26 ART=0.47 PUW=106K SOW=65K ROT=81 K TOon/off=5K/5.5K Drilled from 6,832' to 7,843' MD / 3,510' TVD. ADT=6.37 AST=0.25 ART=6.12 PUW=105K SOW=62K ROT=81 K TOon/off=5K/5-6K ECD=10.44 Mas Gas=88 Total bit hrs=33.71 Total jar hrs=55.76 Concretion Depths: 7082-7092', 7248-7269', 7716-7721', 7731-7738', 7834-7844' SPR#1=20stks/400psi, 30stks/570psi SPR#2=20stks/420psi, 30stks/590psi @ 7735' MD/ 3,514' TVD 8.7+ KREVs=8008 Drilled f/ 7843' to 8049' (206') / 3513' TVD, ART= 1.13 hrs, AST= 0.11 hrs, ADT= 1.24 hrs, Up 110K, Dn 65K, Rot 81 K, Torque On/Off 5K/6K, Concretions @ 7834' to 7844'. Circ for geologist. Drilled f/ 8049' to 8473' (424') / 3519' TVD, ART= 2.4 hrs, AST= 1.94 hrs, ADT= 4.34 hrs, Up 120K, Dn 65K, Rot 85K, Torque On/Off 6K/6K, Concretions @ 8250' to 8258', 8405' to 8410', Ave ECD's 10.7 ppg, Max gas 54 units. POOH w/ 3 stands Hybrid pushPipe to 8204', Pick up & test Andergauge Agitator & shock sub for pressure increase, Had 600 psi @ 1250 gpm & 700 psi @ 300 gpm (good test), RIH w/ 3 stands HWDP to 8473'. Drilled f/ 8473' to 8610' (137') / 3523' TVD, ART= 0.52 hrs, AST= 0.17 hrs, ADT= 0.69 hrs, Up 115K, Dn 65K, Rot 84K, Torque On/Off 5K/5K, Ave ECD's 10.7 ppg, Max gas 54 units.. Drilled f/ 8610' to 9512' (902') / 3504' TVD, ART= 6.47 hrs, AST= 1.78 hrs, ADT= 8.25 hrs, Up 129K, Dn 75K, Rot 98K, Torque On/Off 7K/6.5K, Ave ECD's 10.8 ppg, Max gas 50 units, Concretions= 8610'-8612', 8622'-8627', 8654'-8664',. 8668'-8674', 8680'-8690', 8695'-8700', 8710'-8739', 8745'-8755', 8808'-8809', 8813'-8815', 9009'-9017', 9205'-9212'. Drilled f/ 9,512' to 10,712' (1200') / 3500' TVD, ART= 6.04 hrs, AST= 1.00 hrs, ADT= 7.04 hrs, Up 151 K, Dn 70K, Rot 104K, Torque On/Off 8K/9K, Ave ECD's 11.3 ppg, Max gas 58 units, Concretions= 9553'-9560', 9891'-9899', 9913'-9914', 9945'-9947',. 10190'-10198', 10202'-10213', 10230'-10240', .10390'-10397', 10401'-10415', 10424'-10434', 10439'-10440', 10488'-10493'. Drilled f/ 10,712' to 11,187' T.D. (475') / 3506' TVD, ART= 2.19 hrs, AST= 1.52 hrs, ADT= 3.71 hrs, WOB 4-12K, 312 gpm @ 3850 psi, Up 158K, Dn 67K, Rot 102K, Torque On/Off 8.5K/8.5K, Ave ECD's 11.22 ppg, Max gas 56 units, Pump Hi-vis sweep on last stand. K-Rev's 51799. Finish pumping Hi-vis weighted sweep out of hole at rate of 312 gpm @ 3900 psi -Had 10% increase of cuttings, ECD's 11.3 ppg, Monitor well - Static. Printed: 4/12/2006 1:53:21 PM • • ConocoPhillips Alaska Operations Summary Report Page 13 of 19 Legal Well Name: 1J-159 Common W ell Name: 1J-159 Spud Date: 2/12/2006 Event Nam e: ROT -D RILLIN G Start: 2/11/2006 End: 3/13/2006 Contractor Name: n1334@ ppco.co m Rig Release: 3/13/2006 Group: Rig Name: Doyon 1 41 Rig Number: Date From - To Hours Code Sub Phase Description of Operations Code 3/1/2006 18:00 - 00:00 6.00 DRILL WIPR PROD2 ~ Back ream out of hole at drilling rate 312 gpm @ 3800 to 2850 psi, 90 RPM, 8K Torque, Hole in very good shape but did have mild packing off @ 8160' & 7915'. 3/2/2006 00:00 - 02:45 2.75 DRILL WIPR PROD2 Back ream out of hole at drilling rate 310 gpm @ 2800 psi, 90 RPM, 6K 1 Torque, Hole in very good shape. 02:45 - 04:00 1.25 DRILL CIRC PROD2 Pump 30 bbl Hi-vis weighted sweep, Circ 3 times btm's up at 310 gpm @ 2800 psi, Had 10% Increase in cuttings w/ sweep. 04:00 - 06:15 2.25 WELCT BOPE PROD2 Pull 2 stands drill pipe, Pick up Agitator & shock sub- Break down same & crossover subs, Lay same back down, Pick up Baker 7-5/8" Storm packer, RIH & set @ 86' w/ bit @ 4468', Pull wear bushing. 06:15 - 11:00 4.75 WELCT BOPE PROD2 Test all BOPE to 250 psi low & 3000 psi high, Good test - No failures, Test all alarms, Test waived by AOGCC Jeff Jones. 11:00 - 12:45 1.75 WELCT BOPE PROD2 Set wear bushing, RIH to 86', Release packer, Monitor well -Static, Retrieve & lay down storm packer 12:45 - 16:15 3.50. DRILL TRIP PROD2 RIH with no problems to 11,145', Wash to 11,187'. 16:15 - 18:45 2.50 DRILL ~ CIRC PROD2 Pump 35 bbl Hi-vis weighted sweep, Circ 3 times btm's up at 291 gpm @ 3900 psi, 100 RPM, Torque 8K, Had 10% Increase in cuttings w/ ~ sweep. 18:45 - 20:00 1.25 DRILL CIRC PROD2 Change over to 8.7 ppg SFOBM at rate of 295 gpm @ 3850 psi, 100 RPM, Torque 9.5K, Up 165K, Dn 52K, Rot 105K, SPR's, Monitor well. 20:00 - 00:00 4.00 DRILL TRIP PROD2 Drop 1-7/8" Rabbit, POOH on elevators with no problem. 3/3/2006 00:00 - 02:00 2.00 DRILL TRIP PROD2 Monitor well @ 4550', POOH to 82'. 02:00 - 03:00 1.00 DRILL TRIP PROD2 Down load MWD tools. 03:00 - 04:00 1.00 DRILL TRIP PROD2 Lay down BHA, MWD tools, Motor & Bit. 04:00 - 06:45 2.75 WINDOV~ ITRIP CMPLT2 Make up Whipstock retrieving tools, RIH to 4497, Break circ. 06:45 - 07:15 0.50 WINDOW TRIP CMPLT2 Hook whipstock on depth @ 4570', Pull same loose w/ 85K over pull, Hole took 10 bbls mud. 07:15 - 08:00 0.75 WINDOW CIRC CMPLT2 POOH to 4497', Circ btm's up 220 gpm @ 950 psi, Lost 10 more bbls mud (Total 20 bbls). 08:00 - 12:30 4.50 CMPLTN CIRC CMPLT2 Monitor well-OK, POOH & Lay down whipstock & tools, Clean rig floor. 12:30 - 14:30 2.00 CASE RURD CMPLT2 Rig to run 4-1/2" liner, PJSM w/ all personnel, Bring jewelry 8~ tools to rig floor. 14:30 - 18:15 3.75 CASE PULR CMPLT2 Run 4-1/2" liner as per detail & tag crossover on A2 lateral @ 4717'. 18:15 - 19:30 1.25 CASE PULR CMPLT2 Pull back to above window @ 4565', Rotate and orient bent joint, RIH 8~ tag A2 lateral liner @ 471 T -Took 4 attempts to work thru window. 19:30 - 21:30 2.00 CASE PULR CMPLT2 ~ Continue running 4-1/2" liner (Total 158 jts.) to Hook hanger. 21:30 - 22:30 1.00 CASE PULR CMPLT2 ~ Pick up Baker Hook hanger, Sperry-Sun MWD and orient same. 22:30 - 00:00 1.50 CASE RUNL CMPLT2 RIH w/ 3 stands drill pipe to insure shoe past sidetrack @ 6832', Shallow test MWD -OK, Blow down top drive, Continue RIH to 7267'. 3/4/2006 ~ 00:00 - 01:30 1.50 CMPLTN RUNT CMPLT2 Cont RIH with Liner on drillpipe to 11,141'. P/U = 165k, S/O = 70k 01:30 - 02:45 1.25 CMPLTN OTHR CMPLT2 Orient Hook Hanger & Hook w/ top @ 4560', Pull up and turn 180 degrees, Run past 10', Pull up & Reorient to 1 L, .Slack off to 35k on hook, Toolface jumped around to 16 R, Top of hook hanger assembly N @ 4560.20' and Shoe @ 11,161.0T. 02:45 - 03:00 0.25 CMPLT OTHR CMPLT2 Drop ball and pumped down w/ 3 bpm, 1000 psi. Ball bumped at 415 stks and pressured up to 3000 psi. Released from liner P/U 125K 03:00 - 03:45 0.75 CMPLTN CIRC CMPLT2 Picked up off bottom and CBU at 4500' with 36 spm, 450 psi. 03:45 - 05:30 1.75 CMPLTN TRIP CMPLT2 Monitor well: static. POOH. Trip out displacement talc = 36.1 bbls, 05:30 - 07:45 2 25 CMPLTN PULD CMPLT2 actual 40.8 bbls. and Liner running tool. Break and UD BHA slimhole MWD R/U tongs ! . , , . i 07:45 - 09:30 1.75 CMPLTN PULD ~ CMPLT2 : Held PJSM. MIU LEM to 350.5'. Baker seal assembly (3.29'), XO Bent !j oint 4.5" IBT x STL (43.43'), 4.5" tubing (30.98), Camco DB nipple j LEM assembly 4 5" pup (9 84') (1 49') 5" IBT tubing (31 04') 4 ~ I . . , . . , , . Printed: 4/12/2006 1:53:21 PM • • ConocoPhillips Alaska Page 14 of 19 Operations Summary Report Legal Well Name: 1J-159 Common Well Name: 1J-159 Spud Date: 2/12/2006 Event Name: ROT -DRILLING Start: 2/11/2006 End: 3/13/2006 Contractor Name: n1334@ppco.com Rig Release: 3/13/2006 Group: Rig Name: Doyon 141 Rig Number: Date From - To Hours .Code Sub Phase Description of Operations Code 3/4!2006 ~ 07:45 - 09:30 1.75 CMPLTN PULD CMPLT2 (34.83'), 5 jts of 4.5" (153.22'), XO bushing (1.36'), Seal bore receptacle (19.69'), ZXP liner top packer (17.14'). Total tools to stay in hole. 350.5'. 09:30 - 09:45 0.25 CMPLTN RURD CMPLT2 09:45 - 12:00 2.25 CMPLTN RUNT CMPLT2 12:00 - 13:30 1.50 CMPLTN RUNT CMPLT2 13:30 - 16:30 3.00 CMPLTN PULD CMPLT2 16:30- 18:30 2.00 WINDOW PULD PROD3 18:30 - 19:15 0.75 WINDOV ~IPULD PROD3 19:15 - 22:00 2.75 WINDO ~ULD PROD3 22:00 - 22:30 0.50 WINDO RIP PROD3 22:30 - 23:30 1.00 WINDOW SETW PROD3 23:30 - 00:00 0.50 WINDOVYCIRC PROD3 3/5/2006 00:00 - 00:15 0.25 WINDOWCIRC PROD3 00:15 - 05:00 I 4.751 WINDOWSCML I PROD3 05:00 - 06:00 I 1.001 WINDOWSCML I PROD3 06:00 - 07:45 1.75 WINDOWTRIP PROD3 07:45 - 09:00 I 1.251 WINDOWPULD I PROD3 09:00 - 13:30 4.50 DRILL !PULD PROD3 13:30 - 16:00 I 2.501 DRILL I TRIP I PROD3 16:00 - 17:00 I 1.001 DRILL (TRIP I PROD3 17:00 - 20:15 3.25 DRILL DRLH ~ PROD3 20:15 - 21:00 0.75 DRILL DRLH j PROD3 21:00 - 00:00 3.00 DRILL DRLH PROD3 R/D csg equipment. RIH with LEM assembly. P/U = 98K, S/O = 80K Cont to RIH w/ LEM. Stab into hanger at 4560', P/U 125K, S/O = 95K. Set down with 30K, Pull test LEM to 15K over, Set back down with 30K and picked up to neutral weight. Drop ball and chase with 3 bpm @ 500 psi, 330 stks. Pressure up to 4000 psi. S/O with 30K. Pressure test ZXP to 1000 psi f/ 5 min- OK. P/U with overpull of 5K. Set back down and tagged liner top. Blow down top drive and kill line. POOH with running tools and UD. Clear and clean rig floor. MU whipstock assembly. Upload MWD. PU XO, 3 stands hybrid DP, and shallow test MWD. RIH to 3878'.. MAD pass from 3888' to 4006' @ 350' HR. Cont to RIH to 4355'. Set 22K on Baker trip anchor. PU 10K over and confirm trip anchor release. PU to 42K to shear off of whipstock. PU before 115K ~ SO 87K. After 107K & 80K. Whipstock set at 17 degree left high side. Displace well from SFOBM to drilling MOBM. Cont to displace over from SFOBM to MOBM. Pump @ 310 gpm & 2100 psi. Mill out window from 4246' to 4258'. Drill 5' of gauged hole to 4274'. SPR @ 4274' / 3488' TVD. pump #1:20 spm= 230psi 30 spm = 310 psi pump #2: 20 spm= 230psi 30 spm = 350 psi Work mills through window @ 60 rpm, 78 spm, 275 gpm, 1750 psi. Pumped 30 bbl hi vis sweeps @ 4255' 8 4274'. Able to slide through window with no pump problems. ~ Monitor well: static. Pump dry job. POOH to 96'. Trip out actual fill 38.3 bbls, Calc 32.85 bbls. LD BHA: XO, Bumper sub, down load MWD. Mill in gauge. Clean Rig floor. PUII wear pushing, flush stack, install wear bushing. PU BHA #9 including: Bit, motor, NMFS, DM HOC, MWD, PWD, TM ' HOC, Flex DC, HWDP & Jars. Upload MWD. RIH to 2685' and PU agitator. Continue to RIH to 4209'. Fill pipe. PJSM. Cut and slip 65' of drilling line. Calibrate depth. Inspect Saver sub. Establish circulation and go through window. Drilled from 4,247' to 4,486' MD / 3,505' TVD. Trouble getting detection from MWD due to agitator interference. Adjusted pump rate down from 330 gpm to 250 gpm and regained detection. Continued to drill from 4486' to 4766' MD / 3506' TVD. ADT=1.38 hrs. AST= 1.38 hrs Jar hrs=90.28 PUW=100K SOW=74K ROT=82K TOon/off=4/4K Max Gas=46 Units Max ECD=9.64 13/6/2006 ' 00:00 - 12:00 I 12.00 i DRILL I DRLH I PROD3 Drilled from 4,766' to 5,607 MD / 3481' TVD. ADT=6.76 hrs. AST= 1.64 hrs ART= 5.12 hrs Jar hrs=97.04 PUW=103K SOW=71 K ROT=82K TOon/off=4/5K Printed: 4!12!2006 1:5321 PM • • ConocoPhillips Alaska Page 15 of ~~ Operations Summary Report Legal Well Name: 1J-159 Common Well Name: 1J-159 Event Name: ROT -DRILLING Contractor Name: n1334@ppco.com Rig Name: Doyon 141 Date From - To Hours Code Code Phase 3/6/2006 i 00:00 - 12:00 I 12.001 DRILL ;DRLH I PROD3 12:00 - 00:00 I 12.001 DRILL I DRLH I PROD3 13/7/2006 ! 00:00 - 12:00 I 12.001 DRILL i DRLH I PROD3 12:00 - 00:00 I 12.001 DRILL ;DRLH I PROD3 13/8/2006 100:00 - 12:00 I 12.001 DRILL I DRLH I PROD3 12:00 - 20:15 ; 8.251 DRILL I DRLH PROD3 Spud Date: 2/12/2006 Start: 2/11/2006 End: 3/13/2006 Rig Release: 3/13/2006 Group: Rig Number: Description of Operations ~ Max Gas=52 Units Max ECD=10.01 SPR@ 4895'MD / 3502' TVD, #1@ 20spm/370 psi, 30spm/590 psi #2@ 20spml410 psi, 30spm/620 psi Concretion depths = 4857'-4859', 4867'-4870', 4919'-4925', 4947'-4948', 5013'-5015', 5020'-5024', 5034-5037', 5048'-5050', 5054'-5057', 5081'-5088', 5134'-5160', 5420'-5424', 5447'-5450' Drilled from 5,607 to 7,101' MD /3461' TVD. ADT=10.41 hrs. AST= 2.48 hrs ART= 7.93 hrs Jar hrs=107.45 PUW=110K SOW=65K ROT=85K TOon/off = 5-6/5-6K Max Gas=136 Units Max ECD=10.48 SPR@ 6074'MD / 3478' TVD, #1 @ 30spm/670 psi, 40spm/930 psi #2@ 30spm/710 psi, 40spm/970 psi Concretion depths =5607'-5608, 5650'-5651', 5667'-5670', 5700'-5702', 5720'-5722', 5793'-5799', 5900'-5902', 5930'-5931', 6015'-6019', 6566'-6569', 6593'-6597' Drilled from 7,101' to 8,167' MD / 3458' ND. ADT=8.07 hrs. AST= 1:25 hrs ART= 6.82 hrs Jar hrs=115.52 PUW=122K SOW=54K ROT=80K TOon/off = 5/5K Max Gas=137 Units Max ECD=10.65 SPR@ 7101'MD / 3461' TVD, #1 @ 20spm/480 psi, 30spm710 psi #2@ 20spm/480 psi, 30spm/720 psi Concretion depths =7473'/7476', 7585'/7586', 772T/7731' Drilled from 8,167' to 9437' MD / 3458' ND. ADT=8.67 hrs. AST= 2.15 hrs ART= 6.52 hrs Jar hrs=124.92 'PUW=118K SOW=54K ROT=85K TOon/off = 7/6K Max Gas=107 Units Max ECD=11.34 SPR@ 8502"MD / 3473' TVD, #1 @ 30spm/800 psi, 40spm/1080 psi #2@ 30spm/850 psi, 40spm/1140 psi Concretion depths =7800'/7802', 8093'/8101', 8129'/8140', 8596'/8601', 9418/9425" Drilled from 8,167 to 10372' MD / 3455' TVD ADT=8.37 hrs. AST= 1.5 hrs ART= 8.22 hrs Jar hrs=133.29 PUW=130K SOW=55K ROT=85K TOon/off = 8/7K Max Gas=88 Units Max ECD=11.27 SPR@ 10112' MD / 3424' ND, #1 @ 20spm/660. psi, 30spm/820 psi #2@ 20spm/640 psi, 30spm/840 psi Concretion depths =9984'/9989', 9993'/9998', 10008'/10012', 10030'/10037', 10110'!11115', 10120'110125', 10136'/10138', 10188'/10192', 10249'/10261', 10268'/10285', 10296'/10300', 10304'/10306', 10316'/10319' Drilled from 10372' MD to TD @ 10884' MD / 3424' ND. ADT=5.42 hrs. AST= 1.66 hrs ART=3.59 hrs Jar hrs=138.71 PUW=140K SOW=60K ROT=103K TQon/off = 8/7K Printed: 4/12!2006 1:53:21 PM • • ConocoPhillips Alaska Page 16 of 19 Operations Summary Report Legal Well Name: 1J-159 Common Well Name: 1J-159 Event Name: ROT -DRILLING Contractor Name: n1334@ppco.com Rig Name: Doyon 141 Date From - To Hours Code Sub Phase Code 3/8/2006 ~ 12:00 - 20:15 ~ 8.25 ~ DRILL DRLH ~ PROD3 20:15 - 00:00 3.75 DRILL REAM 3/9!2006 00:00 - 05:45 5.75 DRILL REAM 05:45 - 06:30 0.751 DRILL CIRC 06:30 - 10:30 4.00 DRILL TRIP 10:30 - 12:00 I 1.501 DRILL I CIRC 12:00 - 13:00 1.00 DRILL CIRC 13:00 - 20:15 7.25 DRILL TRIP 20:15 - 21:15 1.00 DRILL PULD 21:15 - 22:00 0.75 DRILL SURV 22:00 - 00:00 2.00 DRILL PULD 13/10/2006 00:00 - 00:45 0.75 WINDOWPULD 00:45 - 02:15 1.50 WINDOWTRIP 02:15 - 02:45 I 0.501 WINDOViITRIP 02:45 - 03:30 0.75 WINDOV~ ICIRC 03:30 - 06:15 2.75 WINDOV1 ITRIP 06:15 - 07:45 1.50 WINDOW PULD 07:45 - 08:30 0.75 WINDOW PULD 08:30 - 09:30 1.00 CASE I RURD 09:30 - 12:00. 2.50 CASE , PULR 12:00 - 16:30 I 4.501 CASE I PULR 16:30 - 17:30 i 1.00 CASE ~ PULR i 17:30 - 20:15 i 2.751 CASE I RUNL i PROD3 PROD3 PROD3 PROD3 I PROD3 PROD3 PROD3 PROD3 PROD3 PROD3 CMPLT3 CMPLT3 CMPLT3 CMPLT3 CMPLT3 CMPLT3 CMPLT3 CMPLT3 CMPLT3 CMPLT3 CMPLT3 CMPLT3 Spud Date: 2/12/2006 Start: 2/11/2006 End: 3/13/2006 Rig Release: 3/13/2006 Group: Rig Number: Description of Operations Units Max ECD=11.23 concretion depths =10370'/10415', 10424'/10426', 10471'/10474', 10488'/10513', 10715'/10730', 10795'/10805' ~irc clear BHA for 10 mins. Pump up survey. BROOH @ 90 rpm, TO 7K, 294-300 gpm, 4000/3500 psi. wont BROOH from 9159' to 4246' MD. Orinet High side and pull thru Nindow (no problems). 'U = 97k, SO = SOk, Rot = 86k, TO = 4k 'ump 35 BBI weighted High Vis sweep @ 4209'.. Circ SS x 1 bottoms ip @ 86 spm, 300 gpm, 3100 psi, Rot @ 60 rpm. orient High side, monitor well, RIH and check condition of Super-Sliders' on TIH. 21H to 10,808' MD and Wash and Ream from 10,808' to 10,884' MD. ;irc Hole Clean @ 10,884' MD. '8 spm, 275 gpm, 3900 psi, 100 rpm, Off Bttm TO = 7k drip OUT Actual Fill = 80.6 Bbls (46.3 Bbls Calc) -rip IN Actual Gain = 42 Bbls (40.81 Bbl Calc) )isplace well to SFOBM @ 80 spm and 3800 psi ... observe well. 'OOH w/ BHA #9 ... monitor T&D every 5 stands in open hole and very 10 stands in cased hole. .D BHA #9 )own Load MWD ;ontinue LD BHA #9 ... Clean Rig Floor -Revs = 20,067 AU BHA - MU retriving hook, 1 jt 3.5" HWDP, float sub, bumper sub, ars, XO, 2 stds Hybrid DCs.(total 261.60") tIH to 4,214" -Break Circu, 4 BPM @ 600 PSI -Wash down to 4,259' - 'ull back up to 4,235' -Put 1:5 rounds turn in string - Up wt 125K - Dn rt 97k. :ngage hook slot @ 4,252' -apply 75k over pull -Trip jar and pulled trip nchor free. Pull up to 4,232' MD :BU @ 4,232' - PR 4 BPM, 600 psi lonitor well -Static- POOH to 261' 'JSM - L/D BHA, Whipstock and Trip Anchor assy :lean rig floor -Remove all tools from rig floor '/U csg equip from beaver slide - PU slim .hole MWD tools - RU 4.5" sg tools. IH w/ 4.5" D Sand Liner - 50 jts (2,200') rip IN Actual Gain = 34 BBLs (Galt = 32.78 BBLs) rip OUT Actual Fill = 41 BBLs (Galt = 35.18 BBLs) IH w/ 4.5" D Sand Liner to 4,391' MD -Tag up - LD 2 jts of tubing and ull to 4,240' and turn pipe -attempt stab @ window3 times with same rocedure then continue RIH w/ Liner U Liner running tool and Slim Hole MWD - MU same and Orient -Rig own Casing Tools. IH w/ Liner on DP -Shallow test MWD on first stand -Continue RIH w/ Printed: 4/12/2006 1:53:21 PM • ConocoPhillips Alaska Page 17 of ~~ Operations Summary Report Legal Well Name: 1J-159 Common Well Name: 1J-159 Spud Date: 2!12/2006. Event Name: ROT -DRILLING Start: 2/11/2006 End: 3/13/2006 Contractor Name: n1334@ppco.com Rig Release: 3/13/2006 Group: Rig Name: Doyon 141 Rig Number: Date From - To Hours Code 3/10/2006 17:30 - 20:15 2.75 CASE 20:15 - 21:30 21:30 - 00:00 3/11 /2006 i 00:00 - 01:45 Sub Phase Code RUNL Description of Operations CMPLT3 DP to 10,785' Liner Depth CMPLT3 1.251 CASE I RUNL 2.501 CMPLTNITRIP 1.75 I CMPLTNI TRIP 01:45 - 02:15 ~ 0.501 CMPLTNI PULD 02:15 - 03:00 0.75 CMPLTN PULD 03:00 - 03:45 0.75 CMPLTN PULD 03:45 - 05:15 05:15 - 10:30 10:30 - 12:00 12:00 - 15:15 15:15 - 17:30 3/12/2006 17:30 - 22:30 22:30 - 00:00 00:00 - 01:00 00:00 - 01:00 01:00 - 01:30 01:00 - 01:30 01:30 - 02:00 01:30 - 02:00 02:00 - 06:30 02:00 - 06:30 06:30 - 07:00 06:30 - 07:00 07:00 - 10:00 1.50 RIGMNT RSRV 5.25 CMPLTN PULL 1.50 CMPLTN PULL 3.25 CMPLTN PULL 2.25 CMPLTN RURD 5.00 f CMPLTNI TRIP 1.50 CMPLTN TRIP 1.00 CMPLTN TRIP 1.00 CMPLTN TRIP 0.50 CMPLTN RURD 0.50 CMPLTN OTHR 0.50 CMPLTN RURD 0.50 CMPLTN PULD 4.50 CMPLTN RUNT 4.501 CMPLTNI RUNT I 0.50' CMPLTN SLIN ~ 0.50 CMPLTN SLIN 3.00 CMPLTN~SLIN 07:00 - 10:00 3.00 CMPLTNI SLIN 10:00 - 10:30 0.50 CMPLTN SLIN 10:00 - 10:30 0.50 CMPLTNI SLIN 10:30 - 12:00 , 1.50 CMPLTNI RUNT 10:30 - 12:00 I 1.501 CMPL 12:00 - 15:00 I 3.00! CMPL CMPLT3 CMPLT3 CMPLT3 CMPLT3 CMPLT3 CMPLT3 CMPLT3 CMPLT3 CMPLT3 CMPLT3 CMPLT3 CMPLT3 CMPLT3 CMPLT3 CMPLT3 CMPLT3 CMPLT3 CMPLT3 CMPLT3 CMPLT3 CMPLT3 CMPLT3 CMPLT3 CMPLT3 CMPLT3 CMPLT3 CMPLT3 RUNT ;CMPLT3 RUNT :CMPLT3 ' PU = 150k, SO = 57k Break Circ @ 35 SPM & 940 psi -Orient High Side and Tag up with 25k Wt - PuII Back up and turn 180? -Pass Thru window 10' - PU and Re-Orient High Side - Re-Tag with 25k -Drop ball and chase @ 3 BPM for 300 strokes -slow to 1.5 BPM and set ball @ 370 strokes.- Pressure up to 3,000 psi to actuate hydraulic set hanger- PU Wt now 125k - Attempt to blow ball seat with 4,000 psi - RU test pump and shear ball @ 4,350 psi -Rig down and Blow down. PJSM -Stand Back Hybrid and HWDP - PU 4 stands Sliders from Derrick and POOH removing Super Sliders (WWT Rep Present) PJSM - Con't POOH std bk 4" DP -Removing WWT supersliders from DP - 90 total. The SS's will be shipped to Anchorage to be serviced by WWT. Clean rig floor - UD all tools from rig floor- UD WWT super sliders for shipping -Wash rig floor Make Service breaks and UD Baker liner running tool & slim hole MWD Clear rig floor - UD Baker liner tool out beaver slid and all csg runnig tools, tongs, slips, bowl, ect, PJSM -Slip & Cut drill line (59') and service rig top drive. PJSM - UD 207 jts (69 stds) 4" DP from derrick thru/ mouse hole. Con't UD 9 stds Hybrid DCs (1 jt HWDP + 2 - 43/4" Sprial DC) Con't UD 3 stds Hybrid DCs & 9 stds of HWDP push pipe. UD Mouse hole -Clear and pick up rig floor -Pull tbg running tools to rig floor. RIH open ended w/ completion tbg picking up singles from pipe shed 111 jts) 37 stds POOH w/ completion tbg string and std bk in derrick: Cont POOH and std bk 4.5" tbg in derrick - (Total 37 stds in derrick) PJSM - Con't POOH std bk 4-1/2" Tbg string -Rack back 32 stands PU test jt and pull wear bushing - LD same PU Test Jt, Pull Wear ring, LD Same PJSM - PU and RU ESP Tools + Eqipment, clamps, hands tools. PU & RU ESP Tools & Equipment PJSM - PU/MU Motor centralizer,A well pump guage, Motor 418 HP, Tandem seal section, screen intake, 2 jts 4.5" SCC tbg, Discharge sub, 3 jts 4.5" SCC. Total 234.37' PJSM, PU & MU Motor Centralizer, Pump Guage, Tandem Seal Section, Screen Intake, 2 jts 4.5" Tbg, Discharge Sub, 3 more jts 4.5" Tbg w/ cable clamps RU Slick line unit to run ESP pump. RU Slickline Unit Run pump on slick line, set packoff and test to 1000 psi / 10 min, run and set pump lock. Wireline Pump Assy, Pack-offAssy, and Tbg Stop RD Slick line unit. RD Slickline Unit Cont to run 4.5" 12.6# L80 IBTM completion tbg. Ran total 17 jts, 1 GLM -Run cannon clamp every other connection. Cont RIH w/ 4.5" Tbg from derrick (17 jts, 1 GLM & clamps every other connection) Cont to run 4.5" 12.6# L80 IBTM completion tbg. With total 47 jts, 2 Printed: 4!12!2006 1:53:21 PM • ConocoPhillips Alaska Page 18 of 19 Operations Summary Report Legal Well Name: 1J-159 Common Well Name.: 1J-159 Spud Date: 2/12/2006 Event Name: ROT -DRILLING Start: 2/11/2006 End: 3/13/2006 Contractor Name: n1334@ppco.com Rig Release: 3/13/2006 Group: Rig Name: Doyon 141 Rig Number: Date From - To Hours Code Code Phase 3/12/2006 112:00 - 15:00 3.00 CMPLTNI RUNT ~ CMPLT3 12:00 - 15:00 I 3.001 CMPLTNI RUNT I CMPLT3 15:00 - 18:00 I 3.00 I CMPLTNI TRIP I CMPLT3 15:00 - 18:00 18:00 - 19:15 18:00 - 19:15 19:15 - 22:00 19:15 - 22:00 2.75 CMPLTN DEQT CMPLT3 22:00 - 00:00 2.00 CMPLTN RUNT CMPLT3 3.001 CMPLTNITRIP ;CMPLT3 Description of Operations GLM in hole -Run cannon clamp every other connection.. Control cable would not megger. Double checked meter and coil - NO Test. RIH w/ 4.5" Tbg from derrick w/ ESP clamps every other jt -Gas Lift w/ 2k Shearon top of jt #32 -Test line every 10 stands ... Make it to 1595.5' MD - 47 jts In Hole -ESP line did not test POOH checking for bad spot in control power cable. Pulled back to GLM #1 w/ 2K shear 1121' -Had smashed spots at each end of mandrel. Megger line and could still not get a reading. POOH standing Tbg back and testing ESP line - 1,121' -GLM w/ 2k Shear -line smashed in 2 places (@ top and bottom of concentric offset of GLM) Cut line -Test from truck to rig floor -Good ... Test down hole no good 1.25 CMPLTN TRIP CMPLT3 Con't to POOH GLM #2 - 525' -Cable smashed at top and bottom of ~ mandrel just like #1. Motor cable had been installed in the wrong place running along the GLM outside almost directly across from the concentric shoulder. 1.25 CMPLTN TRIP CMPLT3 ~ Cont POOH to bottom of ('Dummy') GLM @ 525' -Cable smashed in 2 places again (on top and on bottom of GLM) 2.75 CMPLTN TRIP I CMPLT3 ,Test line to Motor -Good -Make splice on Motor control line. 22:00 - 00:00 I 2.001 CMPLTNI RUNT I CMPLT3 3/13/2006 100:00 - 05:00 I 5.001 CMPLTNI RUNT I CMPLT3 05:00 - 06:30 1.50 CMPLTNI RUNT CMPLT3 06:30 - 08:45 2.25 CMPLTN. RURD CMPLT3 08:45 - 09:15 0.50 CMPLTN DEQT CMPLT3 09:15 - 10:00 0.75 CMPLTN RURD CMPLT3 10:00 - 11:30 1.50 CMPLTN NUND CMPLT3 11:30 - 12:00 0.50 CMPLTN DEQT CMPLT3 12:00 - 13:30 1.50 CMPLTN NUND CMPLT3 13:30 - 14:30 1.00 CMPLTN SEOT .. CMPLT3 14:30 - 15:30 I 1.001 CMPLTNI FRZP I CMPLT3 15:30 - 15:45 ; 0.25 ~ CMPLTN'; FRZP ;CMPLT3 ***NOTE*** Had to cut out 728' of Motor control cable. Will have to have two splices at top of hole. #1 -Splice on more cable #2 Splice on penetrator lead. Test Line down hole -Good Splice ESP cable -Test same -Good RIH w/ 4.5" completion string from derrick -ESP cable clamps every otherjt - 2K shear GLM @ 1,121'. RIH w/ 4.5" Completion String from derrick -ESP cable clamps every otherjt - 2k Shear GLM @ 1,121' Con't RIH w/ 4.5" ESP completion from derrick. Cannon clamp every otherjoint. Test cable every 1000' PU tbg hanger on full jt tbg, Orient hanger, MU landing joint Splice control cable to penetrator lead. Install penetrator and hookup to cable. Plug into penetrator and test cable. All test "OK" Land hanger - RILDS and torque to spec -Test upper and lower hanger seals to 5000 psi f/ 10 min "OK" (@ landing PU wt 133K - Dn wt 125K ) ND BOP stack and set back on stump. Test ESP Cable "OK" NU Vetco /Gray Production Tree Testing tree void to 5000K psi -Test tree to 5000K psi -Test ECP cable ..OK., Scaffold up around tree -Pull 2 way check -Rig up to Freeze protect well. We will pump 186 bbls diesel down the annulus and taking returns thru the tbg to the willis choke. PR Max 4 BPM. Start pumping 4 BPM = 600 psi and finish pumping 4 BPM 1050 psi. Pumped 186 bbls diesel Tbg psi 170 , IA 400, OA 0 Scaffold up around tree -Pull 2 way check -Rig up to Freeze protect well. We will pump 186 bbls diesel down the annulus and taking returns thru the tbg to the willis choke. PR Max 4 BPM. Printed: 4/1212006 1:53:21 PM • • ConocoPhillips Alaska Page 19 of 19 Operations Summary Report Legal Well Name: 1J-159 Common Well Name: 1J-159 Spud Date: 2/12/2006 Event Name: ROT -DRILLING Start: 2/11/2006 End: 3/13/2006 Contractor Name: n1334@ppco.com Rig Release: 3/13/2006 Group: Rig. Name: Doyon 141 Rig Number: Date From - To Hours Code Code Phase Description of Operations 3/13/2006 15:45 - 17:00 ~ 1.25 CMPLTN I FRZP ~ CMPLT3 Freeze protect well thru pump intake @ 3633' - Start pumping 4 BPM = 600 psi and finish pumping 4 BPM 1050 psi. Pumped 186 bbls diesel. Shut In well. Tbg Pressure 200, IA 400, OA 0 18:00 - 20:00 2.00 CMPLTN RURD CMPLT3 Install flow line hyd actuator valve. Install BPV w/ Lubricator 20:00 - 21:00 1.00 CMPLTN RURD CMPLT3 ASRC RD scaffold -Pick up and clean cellar -Secure Well i I t i I i i i i I i I ~ *"**Release Rig 2100 hrs 3/13/2006 Printed: 4!12/2006 1:53:21 PM Halliburton Company Global Report ('owp:ur~: Conoco Phillips Alaska Inc. I)stc: 4/11/2000 linrr: 1541:07 Pa,~c I Field: Kupanik River Unit Co-ordinate(\F) Reference: Well: 1J-159. Tru e Norfh Site: Kuparuk 1J Pad ~'crrir.rl ("I'~l1) Rclcrcuce: 1J-159LL 109-0 ~Frll: 1J-159 Secriun <<'S) ]Zcferencc_ Well (O OON,O OOEO-OOAzii ~1'cllpa[h: 1J-159L1 tiur~cc(~aleulatiuu ~lethud: Minimum Curvatu re - I)h: Orade Survey: Start Date: Company: Engineer: Tool: Tied-to: 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: bggm2005 Site: Kuparuk 1J Pad Site Position: Northing: 5945919.64 ft Latitude: 70 15 46.258 N From: Map Easting: 558789.95 ft Longitude: 149 31 29.007 W Position Uncertainty: 0.00 ft North Reference: True Ground Level 0.00 ft Grid Convergence: 0.45 deg WeII: 1J-159 Slot Name: Well Position: +N/-S -71.86 ft Northing: 5945846.80 ft - Latitude: 70 15 45.551 N +E/-W -126.82 ft Easting : 558663.71 ft "Longitude: 149 31 32.697 W Position Uncertainty: 0.00 ft Wellpath: 1J-159L1 Drilled From: 1J-159L1 PB2 500292329760 Tie-on Depth: 6292.98 ft Current Datum: 1 J-159L1: Height 109.00 ft Above System Datum: Mean Sea Level. Magnetic Data: 2/9/2005 Declination: 24.57 deg Field Strength: 57557 nT Mag Dip Angle: 80.76 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 DeSnitive Wellpath Date: 4/11/2006 Validated: No Version: 5 Actual From To Survey Toolcode Tool Name ft ft 50.00 717.00 1J-159PB1 gyro (50.00-717.00) CB-GYRO-SS Camera based gyro single shot 749.61 1403.57 1J-159 (717-1449) (749.61-1403 MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 1449.80 1549.80 1J-159P61 gyro(1449-1549) (144 CB-GYRO-SS Camera based gyro single shot 1619.68 4534.51 1 J-159 (1619.68-5751.68) (3) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 4565.00 6292.98 1 J-159L1 P62 (4565.00-6758.99) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 6294.00 11145.94 1J-159L1 (6294.00-11145.94) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC Survey _ ~1D Ines ~/Inl 1~1) yv$~1I) V'ti ~'j1~ 11a1)~~ ~~~:111~ IOfd ft deg deg ft ft ft ft ft ft 28.00 0.00 0.00 28.00 -81.00 0.00 0.00 5945846.80 558663.71 TIE LINE 50.00 0.36 208.13 50.00 -59.00 -0.06 -0.03 5945846.74 558663.68 CB-GYRO-SS 100.00 0.32 197.19 100.00 -9.00 -0.33 -0.15 5945846.47 558663.56 CB-GYRO-SS 200.00 0.32 216.08 200.00 91.00 -0.83 -0.39 5945845.97 558663.32 CB-GYRO-SS 264.00 0.65 197.76 264.00 155.00 -1.32 -0.61 5945845.48 558663.11 CB-GYRO-SS 355.00 0.37 95.03 354.99 245.99 -1.83 -0.48 5945844.96 558663.25 CB-GYRO-SS 444.00 2.89 49.19 443.95 334.95 -0.39 1.51 5945846.42 558665.22 CB-GYRO-SS 534.00 5.58 38.99 533.70 424.70 4.49 5.98 5945851.34 558669.65 CB-GYRO-SS ~ 626.00 8.98 35.44 624.94 515.94 13.82 12.96 5945860.72 558676.56 CB-GYRO-SS 717.00 13.78 33.39 714.13 605.13 28.67 23.05 .5945875.64. 558686.53 CB-GYRO-SS 749.61 14.47 29.58 745.75 636.75 35.45 27.20 5945882.46 558690.63 i MWD+IFR-AK-CAZ-SC ~ 842.05 16.42 27.05 834.85 725.85 57.13 38.84 5945904.23 558702.10 MWD+IFR-AK-CAZ-SC ~ .934.49 16.12 24.17 923.59 814.59 80.48 50.04 5945927.66 558713.11 MWD+IFR-AK-CAZ-SC 978.89 15.93 26.88 966.27 857.27 91.54 55.32 5945938.76 558718.31 MWD+IFR-AK-CAZ-SC 1025.72 15.66 29.47 1011.33 902.33 102.77 61.33 5945950.04 558724:23 MWD+IFR-AK-CAZ-SC i Halliburton Company Global Report Cmnp.an~: Conoco Phillips Alaska Inc. I~icl~l: Ku paruk P.iver Unit ~tiitc: Kuparuk 1J Pad ~1~-II: 1 J-159 ~1'cll~riW: 1 J-1 59L1 Sur~rc ~1U Im~l ~zini ft deg deg I)atc: 4,11/2000 Tiwc: 15:41'0? I'a~c: (~u-u nlin,ilcl ~~E:) licfcrcncc: NJe_ 1J-159, True North ~crtical (l~Ul Kcfcrcncc: 1J-159L1: 109.0 tit•ctiuu (~,ti~ lteferencc: Well (0-OON 0-OOEO OOAzij Sur~~cv ('>ileulatinn ~lcthod: Minimum Curvature Ub: Orarle Il D S., lll) \,'S ft ft ft 1063.68 15.73 30.50 1047.87 938.87 111.67 1124.97 15.49 33.39 1106.90 997.90 125.66 1217.44- 16.35 39.14 1195.83 1086.83 146.07 1309.86 20.27 41.59 1283.56 1174.56 168.14 1403.57 25.11 44.48 1369.99 1260.99 194.48 1449.80 25.72 48.64 1411.75 1302.75 208.11 1499.80 26.89 50.63 1456.57 1347.57 222.45 1549.80 26.01 51.60 1501.34 1392.34 236.43 1619.68 26.54 49.51 1564.00 1455.00 256.09 1680.87 29.46 51.24 1618.02 1509.02 274.39 .1772.82 30.78 54.80 1697.56 1588.56 302.11 1866.42 30.99 55.49 1777.89 1668.89 329.57 1959.63 32.44 57.34 1857.18 1748.18 356.66 2050.50 31.68 64.11 1934.22 1825.22 380.24 2144.19 30.77 69.13 2014.35 1905.35 399.52 2236.02 29.86 73.73 2093.63 1984.63 414.30 2300.28 28.53 78.34 2149.73 2040.73 421.88 2322.58 28.21 80.61 2169.36- 2060.36 423.82 - 2422.10 27.18 88.20 2257.50 2148.50 428.37 2479.77 25.89 92.10 2309.10 2200.10 428.32 2572.77 26.16 98.98 2392.69 2283.69 424.38 2668.69 26.35 108.60 2478.75 2369.75 414.28 2761.93 27.37 119.14 2561.98 2452.98 397.24 2852.14 28.67 128.27 2641.65 2532.65 373.72 2947.41 32.19 138.44 2723.84 2614.84 340.55 3041.26 35.21 147.66 2801.96 2692.96 298.95 3134.05 38.69 155.81 2876.15. 2767.15 249.84 3227.21 44.67 164.51 2945.75 2836.75 191.62 3320.49 51.09 171.09 3008.32 2899.32 124.06 3414.92 52.58 175.27 3066.69 2957.69 50.37 3507.84 52.22 175.12 3123.38 3014.38 -22.99 3601.74 51.76 175.40 3181.20 3072.20 -96.72 3695.29 51.60 174.04 3239.21 3130.21 -169.80 3789.71 55.75 174.70 3295.13 3186.13 -245.49 3882.32 60.01 172.71 3344.36 3235.36 -323.43 3977.16 64.36 175.95 3388.62 3279.62 -406.87 4071.75 68.20 177.90 3426.66 3317.66 -493.32 4165.31 71.85 179.96 3458.62 3349.62 -581.22 4257.98 75.77 184.29 3484.47 3375.47 -670.11 4350.48 75.65 184.46 3507.30 3398.30 -759.48 4443.58 78.77 184.05 3527.91 3418.91 -850.01 4534.51 79.50 182.66 3545.05 3436.05 -939.16 4565.00 80.26 183.53 3550.40 3441.40 -969.13 4687.00 88.77 185.56 3562.06 3453.06 -1090.07 4794.14 90.66 184.84 3562.59 3453.59 -1196.76 4890.99 91.73 184.92 3560.57 3451.57 -1293.24 4984.36 90.20 187.05 3559.00 3450.00 -1386.08 5078.08 91.34 187.04 3557.74 3448.74 -1479.08 5171.80 90.66 188.57 3556.10 3447.10 -1571.91 5265.25 90.65 188.35 3555.03 3446.03 -1664.34 5358.49 91.42 187.75 3553.35 3444.35 -1756.65 5451.73 90.57 188.99 3551.73 3442.73 -1848.88 E;ti1 11a~iA ~l:~pE: I'n~il ft ft ft 66.46 5945958.97 558729.30 MWD+IFR-AK-CAZ-SC 75.18 5945973.03 558737.91 MWD+IFR-AK-CAZ-SC 90.20 5945993.55 558752.76 MWD+IFR-AK-CAZ-SC 109.04 5946015.77 558771.43 MWD+IFR-AK-CAZ-SC 133.76 5946042.30 558795.94 MWD+IFR-AK-CAZ-SC 148.17 5946056.04 558810.24 CB-GYRO-SS 165.05 5946070.51 558827.01 CB-GYRO-SS 182.39 5946084.62 558844.23 CB-GYRO-SS 206.27 5946104.46 558867.96 MWD+IFR-AK-CAZ-SC 228.40 5946122.93 558889.95 MWD+IFR-AK-CAZ-SC 265.26 5946150.94 558926.59 MWD+IFR-AK-CAZ-SC 304.69 5946178.70 558965.80 MWD+iFR-AK-CAZ-SC 345.52 5946206.10 559006.40 MWD+IFR-AK-CAZ-SC 387.51 5946230.01 559048.21 MWD+IFR-AK-CAZ-SC 432.05 5946249.64 559092.59 MWD+IFR-AK-CAZ-SC 475.95 5946264.75 559136.37 MWD+IFR-AK-CAZ-SC 506.34 5946272.57 559166.70 -MWD+IFR-AK-CAZ-SC 516.76 5946274.59 559177.10 MWD+IFR-AK-CAZ-SC 562.70 5946279.50 559223.00 MWD+IFR-AK-CAZ-SC 588.45 5946279.65 559248.75 MWD+IFR-AK-CAZ-SC 629.00 5946276.02 559289.32 MWD+IFR-AK-CAZ-SC 670.08 5946266.25 559330.47 MWD+IFR-AK-CAZ-SC 708.43 5946249.50 559368.96 MWD+IFR-AK-CAZ-SC 743.55 5946226.27 559404.25 MWD+IFR-AK-CAZ-SC 778..36 5946193.37 559439.32 MWD+IFR-AK-CAZ-SC 809.45 5946152.01 559470.73 MWD+IFR-AK-CAZ-SC 835.66 5946103.12 559497.32 MWD+IFR-AK-CAZ-SC 856.38 5946045.07 559518.49 MWD+IFR-AK-CAZ-SC 870.78 5945977.63 559533.41 MWD+IFR-AK-CAZ-SC 879.56 5945904.02 559542.77 MWD+IFR-AK-CAZ-SC 885.73 5945830.71 559549.51 MWD+IFR-AK-CAZ-SC 891.85 5945757.04 559556.20 MWD+IFR-AK-CAZ-SC 898.60 5945684.02 559563.52 MWD+IFR-AK-CAZ-SC 906.05 5945608.40 559571.56 MWD+IFR-AK-CAZ-SC 914.68 5945530.54 559580.79 MWD+IFR-AK-CAZ-SC 922.91 5945447.18 559589.68 MWD+IFR-AK-CAZ-SC 927.54 5945360.77 559594.97 MWD+IFR-AK-CAZ-SC 929.16 5945272.90 559597.28 MWD+IFR-AK-CAZ-SC 925.83 5945183.99 559594.64 MWD+IFR-AK-CAZ-SC 918.99 5945094.57 559588.50 .MWD+IFR-AK-CAZ-SC 912.26 5945004.00 559582.47 MWD+IFR-AK-CAZ-SC 907.03 5944914.83 559577.94 MWD+IFR-AK-CAZ-SC 905.41 5944884.85 559576.56 MWD+IFR-AK-CAZ-SC 895.78 5944763.85 559567.87 MWD+IFR-AK-CAZ-SC 886.07 5944657.09 559558.99 MWD+IFR-AK-CAZ-SC 877.84 5944560.57 559551.51 MWD+IFR-AK-CAZ-SC 868.10 5944467.66 559542.50 MWD+IFR-AK-CAZ-SC 856:61 5944374.58 559531.73 MWD+IFR-AK-CAZ-SC 843.88 5944281.66 559519.73 MWD+IFR-AK-CAZ-SC 830.14 5944189.14 559506.71 MWD+IFR-AK-CAZ-SC 817.08 5944096.74 559494.37 MWD+IFR-AK-CAZ-SC 803.51 5944004.42 559481.52 MWD+IFR-AK-CAZ-SC • Halliburton Company! Global Report ('omp;~m: ConocoPhillipsAlaska Inc. 11atc : 4i 11%2006 l~imc: 15.41.07 Pa~c: 3 Field: Ku paruk River U nit Cu-o nlinatc(\I_') Re fcrcncr. W ell: 1J-159. True North ~~ite: Ku paruk 1J Pad ~'crti cal f1~~~111 Rcfc rcucc: 1J -159L1: 109.0 ~~ell: 1 J- 159 secti on (~'ti) Refere nce: W ell (O OON,O.OOEO-OOAzi) 1i'ell~r.~W: 1J- 159L1 tiun~ c~ f`.ilculatiun '.lcfhorl: Mi nimum Curvatu re Ub: Oracle Surcec III) Intl ~ziw llD 5~~ Ill) S _ti 1~:%ll ~lahA ~I.~hE ~fnnl ft deg deg ft ft ft ft ft ft 5545.87 92.20 188.09 3549.45 3440.45 -1941.94 789.54 5943911.26 559468.27 MWD+IFR-AK-CAZ-SC 5639.06 91.03 189.09 3546.83 3437.83. -2034.05 775.62 5943819.05 559455.OS MWD+IFR-AK-CAZ-SC 5733.34 88.62 187.52 3547.12 3438.12 -2127.33 762.01 5943725.68 559442.19 MWD+IFR-AK-CAZ-SC 5826.55 89.08 184.74 3548.99 3439.99 -2219.98 752.05 5943632.96 559432.96 MWD+IFR-AK-CAZ-SC 5919.32 89.22 184.28 3550.36 3441.36 -2312.45 744.76 5943540.45 559426.39 MWD+IFR-AK-CAZ-SC 6013.00 91.66 184.21 3549.64 3440.64 -2405.86 737.83. 5943446.99 559420.19 MWD+IFR-AK-CAZ-SC 6105.92 91.69 183.30 3546.93 3437.93 -2498.54 731.74 5943354.28 559414.83 MWD+IFR-AK-CAZ-SC 6199.82 91.71 180.53 3544.14 3435.14 -2592.34 728.61 5943260.47 559412.42 MWD+IFR-AK-CAZ-SC 6292.98 91.64 180.23 3541.42 3432.42 -2685.46 727.99 5943167.35 559412.53 MWD+IFR-AK-CAZ-SC 6294.00 91.66 180.23 3541.39 3432.39 -2686.48 727.99 5943166.34 559412.53 MWD+IFR-AK-CAZ-SC 6385.62 88.45 179.64 3541.30 3432.30 -2778.08 728.09 5943074.74 559413.35 MWD+IFR-AK-CAZ-SC 6479.08 89.36 178.80 3543.09 3434.09 -2871.52 729.36 5942981.33 559415.35 MWD+IFR-AK-CAZ-SC 6572.75 90.86 179.87 3542.91 3433.91 -2965.18 730.45 5942887.69 559417.17 MWD+IFR-AK-CAZ-SC 6665.66 90.86 181.08 .3541.51 3432.51 -3058.07 729.68 5942794.80 559417.12 MWD+IFR-AK-CAZ-SC 6759.57 92.27 177.10 3538.95 3429.95 -3151.91 731.17 5942700.98 559419.34 MWD+IFR-AK-CAZ-SC 6852.77 91.58 179.43 3535.82 3426.82 -3245.01 733.99 5942607.92 559422.89 MWD+IFR-AK-CAZ-SC 6946.93 90.12 181.70 3534.42 3425.42 -3339.15 733.06 5942513.79 559422.69 MWD+IFR-AK-CAZ-SC 7039.98 91.16 180.35 3533.38 3424.38 -3432.17 731.40 5942420.76 559421.75 MWD+IFR-AK-CAZ-SC 7133.70 91.89 181.67 3530.89 3421.89 -3525.84 729.74 5942327.09 559420.83 MWD+IFR-AK-CAZ-SC 7227.17 91.73 180.64 3527.93 3418.93 -3619.24 727.86 5942233.68 559419.67 MWD+IFR-AK-CAZ-SC 7320.94 91.79 180.16 3525.05 3416.05 -3712.97 727.21 5942139.97 559419.75 MWD+IFR-AK-CAZ-SC 7413.71 90.49 180.05 3523.21 3414.21 -3805.72 727.04 5942047.23 559420.30 MWD+IFR-AK-CAZ-SC 7507.08 90.97 182.26 3522.02 3413.02 -3899.05 725.16 5941953.89 559419.15 MWD+IFR-AK-CAZ-SC 7600.65 92.41 183.60 3519.26 3410.26 -3992.46 720.38 5941860.46 559415.10 MWD+IFR-AK-CAZ-SC 7694.31 91.57 182.27 3516.01 3407.01 -4085.93 715.58 5941766.96 559411.03 MWD+IFR-AK-CAZ-SC 7787.05 92.21 182.79 3512.95 3403.95 -4178.53 711.49 5941674.34 559407.66 MWD+IFR-AK-CAZ-SC 7879.69 90.61 180.88 3510.67 3401.67 -4271.09 708.53 5941581.77 559405:42 MWD+IFR-AK-CAZ-SC 7974.22. 88.95 181.12 3511.03 3402.03 -4365.60 706.88 5941487.26 559404.51 MWD+IFR-AK-CAZ-SC 8064.86 88.95 180.36 3512.69 3403.69 -4456.22 705.71 5941396.64 559404.04 MWD+IFR-AK-CAZ-SC 8158.66 85.18 180.49 3517.49 3408.49 -4549.88 705.01 5941302.99 559404.08 MWD+IFR-AK-CAZ-SC 8244.67 87.09 181.17 3523.29 3414.29 -4635.68 703.77 5941217.19 559403.50 MWD+IFR-AK-CAZ-SC 8340.30 90.24 183.40 3525.52 3416.52 -4731.19. 699.96 5941121.66 559400.44. MWD+IFR-AK-CAZ-SC 8431.45 92.08 182.12 3523.67 3414.67 -4822.21 695.57 5941030.62 559396.76 MWD+IFR-AK-CAZ-SC 8522.97 90.00 179.70 3522.01 3413.01 -4913.69 694.12 5940939.14 559396.02 MWD+IFR-AK-CAZ-SC 8614.63 90.42 179.06 3521.68 3412.68 -5005.34 695.11 5940847.51 559397.72 MWD+IFR-AK-CAZ-SC 8705.51 91.60 179.38 3520.07 3411:07 -5096.20 696.34 5940756.67 559399.67 MWD+IFR-AK-CAZ-SC 8794.70 91.79 179.78 3517.44 3408.44 -5185.35 697.00 5940667.54 559401.02 MWD+IFR-AK-CAZ-SC 8886.89 89.87 180.12 3516.10 3407.10 -5277.52 697.08 5940575.38 559401.81 MWD+IFR-AK-CAZ-SC 8978.16 90.49 178.79 3515.81 3406.81 -5368.78 697.95 5940484.13 559403.39 .MWD+IFR-AK-CAZ-SC 9068.45 90.06 177.70 3515.38 3406.38 -5459.03 700.71 5940393.92 559406.86 MWD+IFR-AK-CAZ-SC 9159.32 92.19 177.83 3513.60 3404.60 -5549.81 704.25 5940303.18 559411.11 MWD+IFR-AK-CAZ-SC 9250.74 91.29 179.78 3510.82 3401.82. -5641.16 706.16 5940211.85 559413.73 MWD+IFR-AK-CAZ-SC 93400 - 90-55 - -- TSO: t'r 3509.34-- - 3400x3-4 =5733:4r _-X06=75__ -59~OTT9:62, - 5594T4:53- - MWD+IFF~AK=C-AZ=SC 9431.93 91.60 181 .45 3507.67 3398 .67 -5822.31 705.04 5940030.72 559414 .02 MWD+IFR-AK-CAZ-SC 9521.09 92.03 182 .38 3504.85 3395 .85 -5911.37 702.06 5939941.64 559411 .73 MWD+IFR-AK-CAZ-SC 9613.09 92.10 180 .27 3501.53 3392. 53 -6003.28 699.93 5939849.73 559410 .32 MWD+IFR-AK-CAZ-SC 9704.19 90.77 179 .11 3499.25. 3390. 25 -6094.35 700.43. 5939758.68 559411 .53 MWD+IFR-AK-CAZ-SC 9793.78 90.00 178 .03 3498.65 3389. 65 -6183.91 702.66 5939669.15 559414 .46 MWD+IFR-AK-CAZ-SC 9885.48 90.24 179 .24 3498.46 3389. 46 -6275.58 704.85 5939577.50 559417 .36 MWD+IFR-AK-CAZ-SC 9977.50 89.20 182. 73 3498.91 3389. 91 -6367.57 703.27 5939485.51 559416 .49 MWD+IFR-AK-CAZ-SC 10071.54 89.07 181. 39 3500.33 3391. 33 -6461.54 699.89 5939391.53 559413 .84 MWD+IFR-AK-CAZ-SC 10166.57 89.38 182. 88 3501.61 3392. 61 -6556.49 696.35 5939296.56 559411 .05 MWD+IFR-AK-CAZ-SC 10259.72 90.61 180. 99 3501.62 3392. 62 -6649.58 693.20 5939203.46 559408. 63 MWD+IFR-AK-CAZ-SC Halliburton Company Global Report ('omp:w~: ConocoPhillips Alaska Inc. Hicl~: Kuparuk P,iver Unit tine: Kuparuk 1J Pad ~~~cl I: 1 J-159 ~~~cllpalh: 1J-159t_1 Surcc~ Date: 4/11/2006 Iimc: 15:41.01 P,~:;c: -t (:o-ordinatc(~~I.) Rcicrencc: WeIL 1J-159, Trua North ~ crlicnl II~D) Ilcfrrcnce: 1J-159L1: 109.0 Section (~S1 Itcfereuec: Well (0-OON,O OOE,O OOAzij Sur~~e~ (alculatiuu >Icthod: Minimum Curvature Db: Oracle ~1D Incl ~ziui llD ticti 11U \rti ft deg deg ft ft ft 10352.98 91.42 180.04. 3499.97 3390.97 -6742. 82 10445.83 88.88 181.24 3499.72 3390.72 -6835. 66 10540.22 90.22 179.10 3500.47 3391.47 -6930. 03 10633.31 89.79 177.45 3500.46 3391.46 -7023. 08 10727.89 90.00 176.24 3500.63 3391.63 -7117. 51 10821.30 88.64 177.58 3501.74 3392.74 -7210. 78 10914.69 88.70 180.84 3503.91 3394.91 -7304. 12 11007.93 88.70 181.34 3506.02 3397.02 -7397. 32 11101.63 90.12 182.99 3506.99 3397.99 -7490. 94 11145.94 90.92 181.30 3506.59 3397.59 -7535. 22 ' 11187.00 90.92 181.30 3505.93 • 3396.93 -7576. 26 1;;11 ~~lahS llapl~~. Cnnl ft ft ft 692.36 5939110.23 559408.51 MWD+IFR-AK-CAZ-SC 691.33 5939017.39 559408.20 MWD+IFR-AK-CAZ-SC 691.05 5938923.03 559408.66 MWD+IFR-AK-CAZ-SC 693.85 5938830.01 559412.18 MWD+IFR-AK-CAZ-SC 699.05 5938735.63 559418.12 MWD+IFR-AK-CAZ-SC 704.09 5938642.42 559423.88 MWD+IFR-AK-CAZ-SC 705.38 5938549.10 559425.90 .MWD+IFR-AK-CAZ-SC 703.60 5938455.90 559424.85 MWD+IFR-AK-CAZ-SC 700.06 5938362.26 559422.04 MWD+IFR-AK-CAZ-SC 698.40 5938317.98 559420.73 MWD+IFR-AK-CAZ-SC 697.47 5938276.93. 559420.12 PROJECTED to TD Halliburton Company Global Report ("omp:~nc: ConoroPhillipsAlaska Inc- U;irc: 4/11/2000 l~imr. 15.24.46 I'a~e: 1 I~icld: Kuparuk River Unit (,~o-orvlina[cfAFj Nc fcrencr. Well: 1J-159. Tru e North Site: Kuparuk 1J Pad ~"cr~icall f~l)t Kcfc rcnce: 1J-159L1PB1 10 9-0 ~~~ell: 1J-159 Section I~S1 Refere nce: Well i0 00N,0.00E,0 00A~ii Wellpath: 1J-159L1PE1 Sur~c} ('alculationil]cthod: Minimum Curvatu re Ub: Oracle Survey: Start Date: Company: Engineer: Tool: Tied-to: 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: bggm2005 Site: Kuparuk 1J Pad Site Position: Northing: 5945919.64 ft Latitude: 70 15 46.258 N From: Map Easfing: 558789.95 ft Longitude: 149 31 29.007 W Position Uncertainty: 0.00 ft North Reference: True Ground Level: 0.00 ft Grid Convergen ce: 0.45 deg Well: 1J-159 Slot Name: Well Position: +N/-S -71.86 ft Northing: 5945846.80 ft Latitude: 70 15 45.551 N +E/-W -126.82 ft Easting : 558663.71 ft Longitude: 149 31 32.697 W Position Uncertainty: 0.00 ft Wellpath: 1J-159L1 PB1 Drilled From: 1J-159PB1 500292329700 Tie-on Depth: 4534.51 ft Current Datum: 1J-159L1 PB1: Height 109.00 ft Above System D atum: Mean Sea Level Magnetic Data: 2/22/2006 Declination: 24.17 deg Field Strength: 57564 nT Mag Dip Angle: 80.77 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: 4/11/2006 Validated: No Version: 1 Actual From To Survey Toolcode Tool Name ft ft 50.00 717.00 1 J-159PB1 gyro (50.00-717.00) CB-GYRO-SS Camera based gyro single shot 749.61 1403.57 1 J-159 (717-1449) (749.61-1403 MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 1449.80 1549.80 1J-159P61 gyro(1449-1549) (144 CB-GYRO-SS Camera based gyro single shot 1619.68 4534.51 1 J-159 (1619 .68-5751.68) (3) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 4565.00 4901.50 1 J-159L1 P61 (4565.00-4901.50) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC Survey ~IU Inc! ,~iim llI) ti~~7lU \.'S 1':%~1' UapA ~I.~pE fool ft deg deg ft ft ft ft ft ft 28.00 0.00 0.00 28.00 -81.00 0.00 0.00 5945846.80 558663.71 TIE LINE 50.00 0.36 208.13 50.00 -59.00 -0.06 -0.03 5945846.74 558663.68 CB-GYRO-SS 100.00 .0.32 .197.19 100.00 -9.00 -0.33 -0.15 5945846.47 558663.56 CB-GYRO-SS 200.00 0.32 216.08 200.00 91.00 -0.83 -0.39 5945845.97 558663.32 CB-GYRO-SS 264.00 0.65 197.76 264.00 155.00 -1.32 -0.61 5945845.48 558663.11 CB-GYRO-SS 355,00 0.37 95.03 354.99 245.99 -1.83 -0.48 5945844.96 558663.25 CB-GYRO-SS 444.00 2.89 49.19 443.95 334.95 -0.39 1.51 5945846.42 558665.22 CB-GYRO-SS 534.00 5.58. 38.99 533.70 424.70 4.49 5.98 5945851.34 558669.65 CB-GYRO-SS 626.00 8.98 35.44 624.94 515.94 13.82 12.96 5945860.72 558676.56 CB-GYRO-SS 717.00 13.78 33.39 714.13 605.13 28.67 23.05 5945875.64 558686.53 CB-GYRO-SS 749.61 14.47 29.58 745.75 636.75 35.45 27.20 5945882.46 558690.63 MWD+IFR-AK-CAZ-SC 842.05 16.42 27.05 834.85 725.85 57.13 38.84 5945904.23 558702.10 MWD+IFR-AK-CAZ-SC 934.49 16.12 24.17 923.59 814.59 80.48 50.04 5945927.66 558713.11 MWD+IFR-AK-CAZ-SC 978.89 15.93 26.88 966.27 857.27 91.54 55.32 5945938.76 558718.31 MWD+IFR-AK-CAZ-SC 1025.72 15.66 29.47 1011.33 902.33 102.77 61.33 5945950.04 558724.23 MWD+IFR-AK-CAZ-SC Halliburton Company Global Report ('omp:u~c: ConocoPhillips Alaska Inc. 11atc 4111;2006 Ciuir. 15:24.46 Pale: .. I~icld: Ku paruk River U nit Cu-~inl iuatc(\F:) Ite fcrencc: Well: 1J-159, True North ~tiiic: Ku paruk 1J P2d ~~crticai ll~Ill1) Ilrfc rcncc: 1J -159L1PB1. 109.0 \~cll: 1J -159 ticctiuu 1~'SI Kc(err ucc: Well (O OON,QOOE O.OOAziI ~1'ellhath: 1J -159~1PB~ Surce~~ (~alculatinn Method: Mi nimum Curvatur e I)h: Oracle `ur~c~ stn I~,ei ~.~~~~ ivu ~~.I~n vs r-~~~ ~t:~i,v ~tahi~ r~,~,i ft deg deg ft ft ft ft ft ft 1063.68 15.73 30.50 104T.87 938.87 111.67 66.46 5945958.97 558729.30 MWD+IFR-AK-CAZ-SC 1124.97 15.49 33.39 1106.90 997.90 125.66 75.18 5945973.03 558737:91 MWD+IFR-AK-CAZ-SC 1217.44 16.35 39.14 1195.83 1086.83 146.07 90.20 5945993.55 558752.76 MWD+IFR-AK-CAZ-SC 1309.86 20.27 41.59 1283.56 1174.56 168.14 109.04 5946015.77 558771.43 MWD+IFR-AK-CAZ-SC 1403.57 25.11 44.48 1369.99 1260.99 194.48 133.76 5946042.30 558795.94 MWD+IFR-AK-CAZ-SC 1449.80 25.72 48.64 1411.75 1302.75 208.11 148.17 5946056.04 558810.24 CB-GYRO-SS 1499.80 26.89 50.63 1456.57 1347.57 222.45 165.05 5946070.51 558827.01 CB-GYRO-SS 1549.80 26.01 51.60 1501.34 1392.34 236.43 182.39 5946084.62 558844.23 CB-GYRO-SS 1619.68 26.54 49.51 1564.00 1455.00 256.09 20627 5946104.46 558867.96 .MWD+IFR-AK-CAZ-SC 1680.87 29.46 51.24 1618.02 1509.02 274.39 228.40 5946122.93 558889.95 MWD+IFR-AK-CAZ-SC 1772.82 30.78 54.80 1697.56 1588.56 302.11 265:26 5946150.94 558926.59 MWD+IFR-AK-CAZ-SC 1866.42 30.99 55.49 1777.89 1668.89 329.57 304.69 5946178.70 558965.80 MWD+IFR-AK-CAZ-SC 1959.63 32.44 57.34 1857.18 1748.18- 356.66 345.52 5946206.10 559006.40 MWD+IFR-AK-CAZ-SC 2050.50 31.68 64.11 1934.22 1825.22 380.24 387.51 5946230.01 559048.21 MWD+IFR-AK-CAZ-SC 2144.19 30.77 69.13 2014.35 1905.35 399.52 432.05 5946249.64 559092.59 MWD+IFR-AK-CAZ-SC 2236.02 29.86 73.73 2093.63. 1984.63 414.30 475.95 5946264.75 559136.37 MWD+IFR-AK-CAZ-SC 2300.28 28.53 78.34 2149.73 2040.73- 421.88 506.34 5946272.57 559166.70 MWD+IFR-AK-CAZ-SC 2322.58 28.21 80.61 2169.36 2060.36 423.82 516.76 5946274.59 559177.10 MWD+IFR-AK-CAZ-SC 2422.10 27.18: 88.20 2257.50 2148.50 428.37 562.70 5946279.50 b59223.00 MWD+IFR-AK-CAZ-SC 2479.77 25.89 92.10 2309.10 2200.10 428.32 588.45. 5946279.65 559248.75 MWD+IFR-AK-CAZ-SC 2572.77 26.16 98.98 2392.69 2283.69 424.38 629.00 5946276..02 559289.32 MWD+IFR-AK-CAZ-SC 2668.69 26.35 108.60 2478.75 2369.75 414.28 670.08 594626625 559330.47 MWD+IFR-AK-CAZ-SC 2761.93 27.37 119.14 2561.98 2452.98 397.24 708.43 5946249.50 559368.96 MWD+IFR-AK-CAZ-SC 2852.14 28.67 128.27 2641.65 2532.65 373.72 743.55 5946226.27 559404.25 MWD+IFR-AK-CAZ-SC 2947.41 32.19 138.44 2723.84 2614.84 340.55 778.36 5946193.37 559439.32 MWD+IFR-AK-CAZ-SC 3041.26 35.21 147.66 2801.96 2692.96 298.95 809.45 5946152.01 559470.73 MWD+IFR-AK-CAZ-SC 3134.05 38.69 155.81 2876.15 2767.15 249.84 835.66 5946103.12 559497.32 MWD+IFR-AK-CAZ-SC 3227.21 44.67 164.51 2945.75 2836.75 191.62 856.38 5946045.07 559518.49 MWD+IFR-AK-CAZ-SC 3320.49 51.09 171.09 3008.32 2899.32 124.06 870.78 5945977.63 559533.41 MWD+IFR-AK-CAZ-SC 3414.92 52.58 175.27 3066.69 2957.69 50.37 879.56 5945904.02 559542.77 MWD+IFR-AK-CAZ-SC 3507.84 52.22 175.12 3123.38 3014.38 -22.99 885.73 5945830.71 559549.51 MWD+IFR-AK-CAZ-SC 3601.74. 51.76 175.40 3181.20 3072.20 -96.72 891.85 5945757.04 559556.20 MWD+IFR-AK-CAZ-SC 3695.29 51.60 174.04 3239.21 3130.21 -169.80 898.60 5945684.02 559563.52 MWD+IFR-AK-CAZ-SC 3789.71 55.75 174.70 3295.13 3186.13 -245.49 906.05 5945608.40 559571.56 MWD+IFR-AK-CAZ-SC 3882.32 60.01 172.71 3344.36 3235.36 -323.43 914.68 5945530.54 559580.79 MWD+IFR-AK-CAZ-SC 3977.16 64.36 175.95 3388.62 3279.62 -406.87 922.91 5945447.18 559589.68 MWD+IFR-AK-CAZ-SC 4071.75 68.20 177.90 3426.66 3317.66 -493.32 927.54 5945360.77 559594.97 MWD+IFR-AK-CAZ-SC 4165.31 71.85 179.96 3458.62 3349.62 -581.22 929.16 5945272.90 559597.28 MWD+IFR-AK-CAZ-SC 4257.98 .75.77 184.29 3484.47 3375.47 -670.11 925.83 5945183.99 559594.64 MWD+IFR-AK-CAZ-SC 4350.48 75.65 184.46 3507.30 3398.30 -759.48 918.99 5945094.57 559588.50 MWD+IFR-AK-CAZ-SC 4443.58 78.77 184.05 3527.91 3418.91 -850.01 912.26 5945004.00 559582.47 MWD+IFR-AK-CAZ-SC 4534.51 79.50 182.66 3545.05 3436:05 -939.16 907.03 5944914.83 559577.94 MWD+IFR-AK-CAZ-SC 4565.00 80.26 183.53 3550.40 - 3441.40 -969.13 905.41 5944884.85 559576.56 MWD+IFR-AK-CAZ-SC 4709.79 90.36 185.94 3562.23 3453.23 -1112.74 893.49 5944741.16 559565.76 MWD+IFR-AK-CAZ-SC 4808.49 92.87 190.28 3559.45 3450.45 -1210.38 879.58 5944643.42 559552.61 MWD+IFR-AK-CAZ-SC 4901.50 92.92 189.74 3554.75 3445.75 -1301.86 863.44 5944551.83 559537.18 MWD+IFR-AK-CAZ-SC 4987.00 92.92 189.74 3550.39 3441.39 -1386.02 848.99 5944467.57 559523.39 PROJECTED to TD Halliburton Company • Global Report ('iuupan~: ConocoPhillips Alaska Inc. Daic: 4/11;2006 T;nn: 15:31.43 Pn~c: l 1 icl~: Kuparuk River Unit (~~~-urdinale~At~.) Ref erence: Well: 1J-159. True North tiitc: Kuparuk 1J Pad ~"crticil(II~U) Itcfcr cncc: 1J-159L1PB2 109 -0 ~~'ell: 1J-159 tiec[inn 1~~1 Referen ce: W211 (0.OON,O OOEO OOAzil ~~'cllpath: 1J-159L1PB2 Surcc~ (alculstiun ~ Icthud: Minii~ium Curvatu re I)h: Oracle Survey: Start Date: Company: Engineer: Tool: Tied-to: 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: bggm2005 Site: Kuparuk 1J Pad Site Position: Northing: 5945919.64 ft Latitude: 70 15 46.258 N From: Map Easting: 558789.95 ft Longitude: 149 31 29.007 W Position Uncertainty: 0.00 ft North Reference: True Ground Level 0.00 ft Grid Convergence: 0.45 deg Well: 1 J-159 Slot Name: Well Position: +N/-S -71.86 ft Northing: 5945846.80 ft Latitude: 70 15 45.551 N +E/-W -126.82 ft Easting : 558663.71 ft Longitude: 149 31 32.697 W Position Uncertainty: 0.00 ft Wellpath: 1J-159L1 PB2 Drilled From: 1 J-159P61 500292329772 Tie-on Depth: 4534.51 ft Current Datum: 1 J-159L1 PB2 Height 109.00 ft Above System Datum: Mean Sea Level Magnetic Data: 2/9/2006 Declination: 24.19 deg Field Strength: 57564 nT Mag Dip Angle: .80.77 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 Weltpath Date: 4/11/2006 Validated: No Version: 1 Actual From To Survey Toolcode Tool Name ft ft 50.00 717.00 1J-159PB1 gyro (50.00-717.00) CB-GYRO-SS Camera based gyro single shot 749.61 1403.57 1J-159 (717-1449) (749.61-1403 MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 1449.80 1549.80 1J-159P61 gyro(1449-1549) (144 CB-GYRO-SS Camera based gyro single shot 1619.68 4534.51 1J-159 (1619. 68-5751.68) (3) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 4565.00 6758.99 1 J-159L1 PB2 (4565.00-6758.99) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC Survey ~lU lucl ~iim ll D tips 1l~ l) \%S H::'~1~ ?lapA ~Iapl~; ~fuul ft deg deg ft ft ft ft ft ft 28.00 0.00 0.00 28.00 -81.00 0.00 0.00 5945846.80 558663.71 TIE LINE 50.00 0.36 208.13 50.00 -59.00 -0.06 -0.03 5945846.74 558663.68 CB-GYRO-SS 100.00 0.32 197.19 100.00 -9.00 -0.33 -0.15 5945846.47 558663.56 CB-GYRO-SS 200.00 0.32 216.08 200.00 91.00 -0.83 -0.39 5945845.97 558663.32 CB-GYRO-SS 264.00 0.65 197.76 264.00 155.00 -1.32 -0.61 5945845.48 558663.11 CB-GYRO-SS 355.00 0.37 95.03 354.99 245.99 -1.83 -0.48 5945844.96 558663.25 CB-GYRO-SS 444.00 2.89 49.19 443.95 334.95 -0.39 1.51 5945846.42 .558665.22 CB-GYRO-SS 534.00 5.58 38.99 533.70 424.70 4.49 5.98 5945851.34 .558669.65 CB-GYRO-SS 626.00 8.98. 35.44 624.94 515.94 13.82 12.96 5945860.72 558676.56 CB-GYRO-SS 717.00 13.78 33.39 714.13 605.13 28.67 23.05 5945875.64 558686.53 CB-GYRO-SS 749:61 14.47 29.58 745.75 636.75 35.45 27.20 5945882.46. 558690.63 MWD+IFR-AK-CAZ-SC 842.05 16.42 27.05 834.85 725.85 57.13 38.84 5945904.23 558702.10 MWD+IFR-AK-CAZ-SC .934.49 16.12 24.17 923.59 814.59 80.48 50.04 5945927.66 558713.11 MWD+IFR-AK-CAZ-SC 978.89 15.93 26.88 966.27 857.27 91.54 55.32 5945938.76 558718.31 MWD+IFR-AK-CAZ-SC 1025.72 15.66 29.47 1011.33 902.33 102.77 61.33 5945950.04 558724.23 MWD+IFR-AK-CAZ-SC P Halliburton Company. Global Report C~~mp:ui.: CunocoPhillipsAlaska Inc_ U:uc_ 4/11;2006 Iimc: 15:~1~43 I'a~c: I~ielil: Kuparuk River Unit Cn-uril inatc~AI:j Rc fcr~ncc: W ell_ 1J-159. True North ~i~c: Kup aruklJPed ~i~rtics l(f~ll)Kefer~rncc: 1J -159L1PB2109:0 ~~dl: iJ-1 59 ~ectiim (~~tilRefere nec W ell (O OON,O.OOE,O.OOAzij ~~'cllpsth: 1J-1 59LiPB2 tiunc~ Calculation~ blcthu~l: Mi nimum Curvatu re I)h: Oracle tiunc~ X11) Inrl ~iiui 11U S~~t I11) \ :ti 1~::~1' ~Ia~iA" ~laph~, 7~nnl ft deg dag ft ft ft ft ft ft 1063.68 15.73 30.50 1047.87 938.87 111.67 66.46 5945958.97 558729.30 MWD+IFR-AK-CAZ-SC 1124.97 15.49 33.39 1106.90 997.90 125.66 75.18 5945973.03 558737.91 MWD+IFR-AK-CAZ-SC 1217.44 16.35 39.14 1195.83 1086.83 146.07 90.20 5945993.55 558752.76 MWD+IFR-AK-CAZ-SC 1309.86 20.27 41.59 1283.56 1174.56 168.14 109.04 5946015.77 558771:43 MWD+IFR-AK-CAZ-SC 1403.57 25.11 44.48 1369.99 1260.99 194.48 133.76 .5946042.30 558795.94 MWD+IFR-AK-CAZ-SC 1449.80 25.72 48.64 1411.75 1302.75 208.11 148.17 5946056.04 558810.24 CB-GYRO-SS 1499.80 26.89 50.63 1456.57 1347.57 222.45 165.05 5946070.51 558827.01 CB-GYRO-SS 1549.80 26.01 51.60 1501.34 1392.34 236.43 182.39 5946084.62 558844.23 CB-GYRO-SS 1619.68 26.54 49.51 1564.00 1455.00 256.09 206.27 5946104.46 558867.96 MWD+IFR-AK-CAZ-SC 1680.87 29.46 51.24 1618.02 1509.02 274.39 228.40 5946122.93 558889.95 MWD+IFR-AK-CAZ-SC 1772.82 30.78 54.80 1697.56 1588.56 302.11 265.26 5946150.94 558926.59 MWD+IFR-AK-CAZ-SC 1866.42 30.99 55.49 1777.89 1668.89 329.57 304.69 5946178.70 558965.80 MWD+IFR-AK-CAZ-SC 1959.63 32.44 57.34 1857.18 1748.18 356.66 345.52 5946206.10 559006.40 MWD+IFR-AK-CAZ-SC. 2050.50 31.68 64.11 1934.22 1825.22 380.24 387.51 5946230.01 559048.21 MWD+IFR-AK-CAZ-SC 2144.19 30.77 69.13 2014.35 1905.35 399.52 432.05 5946249.64 559092.59 MWD+IFR-AK-CAZ-SC 2236.02 29.86 73.73 2093.63 1984.63 414.30 475.95 5946264.75 559136.37 MWD+IFR-AK-CAZ-SC 2300.28 28.53 78.34 2149.73 2040.73 421.88 506.34 5946272.57 559166.70 MWD+IFR-AK-CAZ-SC 2322.58 28.21 80.61 2169.36 2060.36 423.82 516.76 5946274.59 559177.10 MWD+IFR-AK-CAZ-SC 2422.10 27:18 88.20 2257.50 2148.50 428.37 562.70 5946279.50 559223.00 MWD+IFR-AK-CAZ-SC 2479.77 25.89 92.10 2309.10 2200.10 428.32 588.45 5946279.65 559248.75 MWD+IFR-AK-CAZ-SC 2572.77 26.16 98.98 2392.69 2283.69 424.38 629.00 5946276.02 559289.32 MWD+IFR-AK-CAZ-SC 2668.69 26.35 108.60 2478.75 2369.75 414.28 670.08 5946266.25 559330.47 MWD+IFR-AK-CAZ-SC 2761.93 27.37 119.14 2561.98 2452.98 397.24 708.43 5946249.50 559368.96 MWD+IFR-AK-CAZ-SC 2852.14 28.67 128.27 2641.65 2532.65 373.72 743.55 5946226.27 559404.25 MWD+IFR-AK-CAZ-SC 2947.41 32.19 138.44 2723.84 2614.84 340.55 778.36 5946193.37 559439.32 MWD+IFR-AK-CAZ-SC 3041.26 . 35.21 147.66 2801.96 2692.96 298.95 809.45 5946152.01 559470.73 MWD+IFR-AK-CAZ-SC 3134.05 38.69 155.81 2876.15 2767.15 249.84 835.66 5946103.12 559497.32 MWD+IFR-AK-CAZ-SC 3227.21 44.67 164.51 2945.75 2836.75 191.62 856.38 5946045.07 559518.49 MWD+IFR-AK-CAZ-SC 3320.49 51.09 171.09 3008.32 2899.32 124.06 870.78 5945977.63 559533.41 MWD+IFR-AK-CAZ-SC 3414.92 52.58 175.27 3066.69 2957.69 50.37 879.56 5945904.02 559542.77 MWD+IFR-AK-CAZ-SC 3507.84 52.22 175.12 3123.38 3014.38 -22.99 885.73 5945830.71 559549.51 MWD+IFR-AK-CAZ-SC 3601.74 51.76 175.40 3181.20 3072.20 -96.72 891.85 5945757.04 559556.20 MWD+IFR-AK-CAZ-SC 3695.29 51.60 174.04 3239.21 3130.21 -169.80 898.60 5945684.02 559563.52 MWD+IFR-AK-CAZ-SC 3789.71 55.75 174.70 3295.13 3186.13 -245.49 906.05 5945608.40 559571.56 MWD+IFR-AK-CAZ-SC 3882.32 60.01 172.71 3344.36 3235.36 -323.43 914.68 5945530.54 559580.79 MWD+IFR-AK-CAZ-SC 3977.16 64.36 175.95 3388.62 3279.62 -406.87 922.91 5945447.18 559589.68 MWD+IFR-AK-CAZ-SC 4071.75 68.20 177.90 3426.66 3317.66 -493.32 927.54 5945360.77 559594.97 MWD+IFR-AK-CAZ-SC 4165.31 71.85 179.96 3458.62 3349:62 -581.22 929.16 5945272.90 559597.28 MWD+IFR-AK-CAZ-SC 4257.98 75.77 184.29 3484.47 3375.47 -670.11 925.83 5945183.99 559594.64 MWD+IFR-AK-CAZ-SC 4350.48 75.65 184.46 3507.30 3398.30 -759.48 918.99 5945094.57 559588.50 MWD+IFR-AK-CAZ-SC 4443.58 78.77 184.05 3527.91 3418.91 -850.01 912.26 5945004.00 559582.47 MWD+IFR-AK-CAZ-SC 4534.51 79.50 182.66 3545.05 3436.05 -939.16 907.03 5944914.83 559577.94 MWD+IFR-AK-CAZ-SC ~ 4565.00 80.26 183.53 3550.40 3441.40 -969.13 905.41 5944884.85 559576.56 MWD+IFR-AK-CAZ-SC 4687.00 88.77 185.56 3562.06 3453.06 -1090.07 895.78 5944763.85 559567.87 MWD+IFR-AK-CAZ-SC 4794.14 90.66 184.84 3562.59 3453.59 -1196.76 886.07 5944657.09 559558.99 MWD+IFR-AK-CAZ-SC 4890.99 91.73 . 184.92 3560.57 3451.57 -1293.24 877.84 5944560.57 559551.51 MWD+IFR-AK-CAZ-SC 4984.36 90.20 187.05 3559.00 3450.00 -1386.08 868.10 5944467.66 559542.50 MWD+IFR-AK-CAZ-SC 5078.08 91.34 187.04 3557.74 3448.74 -1479.08 856.61 5944374.58 559531.73 MWD+IFR-AK-CAZ-SC 5171.80 90.66 188.57 3556.10 3447.10 -1571.91 843.88 5944281.66 559519.73. MWD+IFR-AK-CAZ-SC 5265.25 90.65 188.35 3555.03 3446.03 -1664.34 830.14 5944189.14 559506.71 MWD+IFR-AK-CAZ-SC I 5358.49 91.42 187.75 3553.35 3444.35 -1756.65 817.08 5944096.74 559494.37 MWD+IFR-AK-CAZ-SC 5451.73 90.57 188.99 3551.73 3442.73 -1848.88 803.51 5944004.42 559481.52 MWD+IFR-AK-CAZ-SC 5545.87 i 92.20 188.09 3549.45 3440.45 -1941.94 789.54 5943911.26 559468.27 MWD+IFR-AK-CAZ-SC Halliburton Company Global Report (~~unliau~: Conoco Phillips Alaska Inc. ficlJ: Ku paruk River U nit ~1i1c Ku paruk iJ Pad ~~ cI l: 1 J - 1 59 ~~"cllpath: 1 J -159L1 PB2 Sure c~ ~IU lucl ~zini ft deg deg 5639.06 91.03 189.09 5733.34 88.62 187.52 5826.55 89.08 184.74 5919.32 89.22 184.28 6013.00 91.66 184.21 6105.92 91.69 183.30 6199.82 91.71 180.53 6292.98 91.64 180.23 6386.57 93.05 180.03 6480.92 91.95 178.50 6572.85 91.29 181.14 6665.32 91.46 179.75 6758.99 93.44 179.12 6832.00 93.44 .179.12 Uatc: 4/11/2000 7~imc: 15.31'43 Pa~~e: 3 ( i-unliniitc(\1:1 Kcfcrcncc: Well. 1J-159, True North ~~crlical (f~~i11 Kcfcrcncc: 1J-159L1PB2 109.0 ticctiun (1ti1 Kcfcrcncc: Well (0.OON,0-OOEO OOA~i) tiur~~c<<alcul.~tion ~Icduxl: Minimum Curvature llh: Oracla C~1) tic, 11~D ~;5 I~:;l~' )lapA ft ft ft ft ft 3546.83 3437.83 -2034.05 775.62 5943819.05 3547.12 3438.12 -2127.33 762.01 5943725.68 3548.99 3439.99 -2219.98 752.05 5943632.96 3550.36 3441.36 -2312.45 744.76 5943540.45 3549.64 3440.64 -2405.86 737.83 5943446.99 3546.93 3437.93 -2498.54 731.74 5943354.28 3544.14 3435.14 -2592.34. 728.61 5943260.47 3541.42 3432.42 -2685.46 727.99 5943167.35 3537.59 3428.59 -2778.97 727.78 5943073.86 3533.47 3424.47 -2873.21 728.99 5942979:63 3530.87 3421.87 -2965.10 729.28 5942887.76 3528.66 3419.66 -3057.54 728.56 5942795.33 3524.65 3415.65 -3151.11 729.48 5942701.77 3520.27 3411.27 -3223.98. 730.60 5942628.92 ~lapF: Cnnl ft 559455.08 MWD+IFR-AK-CAZ-SC 559442.19 MWD+IFR-AK-CAZ-SC 559432.96 MWD+IFR-AK-CAZ-SC 559426.39 MWD+IFR-AK-CAZ-SC 559420.19 MWD+IFR-AK-CAZ-SC 559414.83 MWD+IFR-AK-CAZ-SC 559412.42 MWD+IFR-AK-CAZ-SC 559412.53 MWD+IFR-AK-CAZ-SC 559413.05 MWD+IFR-AK-CAZ-SC 559414.99 MWD+IFR-AK-CAZ-SC 559415.99 MWD+IFR-AK-CAZ-SC 559416.00 MWD+IFR-AK-CAZ-SC 559417.65 MWD+IFR-AK-CAZ-SC 559419.33 PROJECTED to TD KRU 1 J-159 ~ ~ Proposed Producer Z zap oho Confidential wells are red SFD 1/18/2006 IJ 1 Feei 0 1 ,000 2,000 3,000 4,004 • 1J-159L1 Geological Sidetrack Notification • • Subject: IJ-1 ~9L1 Geological Sidetrack Notfication From: "Reilh~, Patrick J" ~~_Patrick.J.Reilly(a~conocophillips.com? Date: Thu., d? i1-1ar ?(lOG 09:54:0 -09OQ To: Thomas l~~launder <ton~ maunder(~i?admin.state.ak.us Tom, ~~(~~~--~~j ~p There was a third geological sidetrack on this well. It occurred between the two sidetracks I have already reported. 1 apologize for the delayed notice, the company man and 1 had a misunderstanding. On Saturday morning 2/25 we had a rotary steerable At Bit Inclination failure. That failure coincided with a formation exit. The decision to sidetrack was made by the geology team at the rig on the way back into the hole with the new tools (Saturday night). The third sidetrack occurred early Monday morning. By Monday morning report time, there were two B lateral sidetracks but I thought there was only one. When I talked to the company man he mentioned that we now had two sidetracks. I assumed he meant two sidetracks total (One in the A lateral and one in the B lateral). However he meant two sidetracks in just the B lateral. I have provided a sidetrack summary for the well and the details of the "missing" sidetrack. SIDETRACK SUMMARY • A lateral sidetrack on 2/21/06 • 1St B lateral sidetrack on 2/25/06 (Details Below) • 2nd B lateral sidetrack on 2/27/06 The details of the sidetrack are as follows: Well: 1J-159L1 Rig: 141 Date: 2/25/06 Time: 2015 hrs Top of B lateral window: 4,565' MD of abandoned section: 4,680' - 4,987' We are planning to isolate the sidetrack with blank liner and constrictors to prevent any shale inflow. Please let me know if you need additional information. Pat Reilly ConocoPhillips Alaska Drilling & Wells (907) 265-6048 WORK (907) 244-5558 CELLULAR (907) 265-1535 FAX Patrick.J.Reilly@conocophillips.com 1 of 1 3/2/2006 3:01 PM RE: 1J-159 B Lateral Geological Sidetrack ~ # Subject: }ZE: 1J-159 B Lateral Geological Si~ictrack From: "Reilly, Patrick J" ~=-P:~tricL.J.Reilly(a.'conoc~ophillii~s.co:r~:~ Date: ti~lon. 27 Feb ?006 1 ti:3~:08 -0000 lo: Thoi~~as l~~launder atom n~aunder(~admin.state.ak.us' Unfortunately this is another sidetrack. You are correct, the correct nomenclature is 1J-159L1. ~~~ ~ ~~ Pat Reilly ConocoPhillips Alaska Drilling & Wells (907) 265-6048 WORK (907) 244-5558 CELLULAR (907) 265-1535 FAX Patrick.J. Reilly@conocophillips.com -----Original Message----- From: Thomas Maunder [mailto:tom_maunder@admin.state.ak.us] Sent: Monday, February 27, 2006 8:10 AM To: Reilly, Patrick J Subject: Re: iJ-159 B Lateral Geological Sidetrack Hi Pat, Is this another sidetrack? Also, it would appear that the well name should be 1J-159L1. If I have the nomenclature correct, A penetration is the motherbore, B penetration is L1 and D penetration is L2. Tom Maunder, PE AOGCC Reilly, Patrick J wrote, On 2/27/2006 7:59 AM: Tom, The details of the sidetrack are as follows: Well: 1 J-159 Rig: 141 Date: 2/27/06 Time: 0315 hrs Top of B Lateral Window: 4,565' MD of abandoned section: 6,292' - 6,832' We exited the top of the formation due to geologic uncertainty. We made a low side sidetrack. We are planning to isolate the sidetrack with blank liner and constrictors to prevent any shale inflow. If you need any additional information please contact me on my cell phone today. I will be out of the office most of the day. Thanks. Pat Reilly ConocoPhillips Alaska Drilling & Wells 1 of 2 2/27/2006 3:48 PM 206-006 ~ ~ . ~~ ~} ~ .~.d ~ ~~ COI~TSER'QA ~~ ~1 l~ ~~~ a~ ,'~ '~ '~ ~ i `~ '~~ ~ „ ~~ '' ~ 1'~, ~~~ ~~~ FRANK H. MURKOWSKI, GOVERNOR ~~ O~ ~ ~ ~ 333 W. 7~" AVENUE, SUITE 100 110 CO~IISSIO~ j~ ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 Randy Thomas Greater Kuparuk Area Drilling Team Leader ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510-0360 FAX (907j 27&7542 Re: Kuparuk River, 1J-159L1 ConocoPhillips Alaska, Inc. Permit No: 206-006 Surface Location: 2036' FSL, 2545' FEL, Sec. 35, T11N, RlOE, UM Bottomhole Location: 261' FNL, 1867' FEL, Sec. 11, TlON, R10E, 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. The permit is for a new wellbore segment of existing well KRU 1J-159, Permit No. 206-005, API 50-029-23297-00. Production should continue to be reported as a function of the original API number stated above. 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. Please provide at least twenty- four (24) hours notice for a representative of the Commission to witness any required test. Contact the Commission's petroleum field inspector at (907) 659- 3607 (pager). 206-006 Sincerely, • ~=~~~ Daniel T. Seamount Jr. Commissioner DATED this~day of January, 2006 cc: Department of Fish 8v Game, Habitat Section w/ o encl. Department of Environmental Conservation w/o encl. ConocoPhillips Alaska Post Office Box 100360 Anchorage, Alaska 99510-0360 Randy Thomas Phone (907)265-6830 Email: Randy.L.Thomas@conocophillips.com January 16, 2006 Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 • RECEIVED JAN 1 S 2006 Aleska Oil & bas Gons. Gommission . .Anchorage Re: Applications for Permit to Drill, West Sak Producer, 1J-159, 1J-159 Ll, 1J-159 L2 ~~ Dear Commissioners: ConocoPhillips Alaska, Inc. hereby applies for Permits to Drill for an onshore producer well, a trilateral horizontal well in the West Sak °A2", ~~B"and "D" sands. The main bore of the well will be designated 1J- 159, and the lateral bores of the well will be designated IJ-159L1 and iJ-159L2. Please find attached for the review of the Commission forms 10-401 and the information required by 20 ACC 25.005 for each of these well bores. The expected spud date of 1J-159 is February 9, 2006. If you have any questions or require any further information, please contact Pat Reilly at 265-6048. Sincerely, e-- l ---- Randy Thomas Greater Kuparuk Area Drilling Team Leader t~ RECEIVED STATE OF ALASKA ~~ ALASKA OIL AND GAS CONSERVATION COMMISSION ~AN Y $ ZOO6 PERMIT TO DRILL Alaska oil & Gas Cons. Commission 20 AAC 25.005 AnCliOta 1a. Type of Work: Drill / Redrill 1b. Current Well Class: Exploratory Development Oil / Multiple Zone ^ Re-entry ^ Stratigraphic Test ^ Service ^ Development Gas ^ Single Zone Q 2. Operator Name: 5. Bond: / Blanket Single Well 11. Well Name and Number: ConocoPhillips Alaska, Inc. Bond No. 59-52-180 1J-159L1 ' 3. Address: 6. Proposed Depth: 12. Field/Pool(s): P.O. Box 100360 Anchorage, AK 99510-0360 MD: 11205' ~ TVD: 3474' ~ Kuparuk River Field 4a. Location of Well~(Governmental S ction): 7. Property Designation: ~ 5' FEL, Sec. 35, T11 N, R10E, UM Surface~FSL; ADL 25661 & 25662 West Sak Oil Pool Top of Productive Horizon: 8. Land Use Permit: 13. Approximate Spud Date: 1063' FSL, 1641' FEL, Sec. 35, T11 N, R10E UM ' ALK 471 & 2177 2/9/2006 Total Depth: 9. Acres in Property: 14. Distance to 261' FNL, 1867' FEL, Sec. 11, T10N, R10E, UM ~ 2560 Nearest Property: 8693 4b. Location of Well (State Base Plane Coordinates): 10. KB Elevation 15. Distance to Nearest Surtace: x- 558664 ' y- 5945847 ~ Zone- 4 (Height above GL): 28' RKB feet Well within Pool: 1J-154 , 1201' @10794' 1&. Deviated wells: Kickoff depth: 4588 ' ft. 17. Maximum Anticipated Pressures in psig (see 20 AAC 25.035) Maximum Hole Angle: 92° deg Downhole: 1605 psig ' Surface: 1212 psig ~ 18. Casing Program S ifi ti Setting Depth Quantity of Cement Size pec ca ons 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 2364' 28' 28' 2392' 2207' 470 sx ASLite, 170 sx DeepCRETE 9-7/8" 7-5/8" 29.7# L-80 BTCM 5528' 28' 28' 5556' 3698' 350 sx DeepCRETE 6.75" 4.5" 12.6# L-80 IBTM 6617' 4588' .3548' 11205' 3474' slotted liner ~--o ~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 Structural Conductor Surface Intermediate Production ration Depth MD (ft): Perforation Depth TVD (ft): ~"~ 1 " '' (/~' 20. Attachments: Filing Fee C BOP Sketch ^/ Drilling Program / Time v. Depth Plot Shallow Hazard Analysis Property Plat ^ Diverter Sketch ^ Seabed Report ^ Drilling Fluid Program Q 20 AAC 25.050 requirements ^/ 21. Verbal Approval: Commission Representative: Date: 22. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Pat Reilly @ 265-6048 Printed Name Randy Thomas Title Greater Kuparuk Area Drilling Team Leader Signature ; \ Phone us--~~So Date i/16106 - P a rnAllu D Commission Use Only Permit to Drill // / API Number: -7 Permit Approval See cover letter Number: ZvCv '- ~~tC7 50- ~sz~~- ~~~.~ / " ~p~ Date: ~ ~ for other requirements Conditions of approval Samples required Yes ^ No [~ Mud log required Yes ^ No ^~~ Hydrogen sulfide measuresf~ Yes ^ No ~ Directional survey required Yes [~~ No ^ Other: 3~QSc~C'~cS~c~S(~~~5~¢~ . _ ~ APPROVED BY I ~ ' ~~ ~ D Approved bv: THE COMMISSION Date: Form 10-401 Revised 06/2004 €~,,1' € ~ t ~ ~ r~ ~ Submit in Duplicate App~n for Permit to Drill, Well 1J-159 L1 Revision No.O Saved: 13-Jan-06 Permit It -West Sak Well #1J-159 L1 Application for Permit to Dril/ Document will value Table of Contents 1. Well Name ................................................................................................................. 2 Requirements of 20 AAC 25.005 (t) ....................................................................................................... 2 2. Location Summary ................................................................................................... 2 Requirements of 20 AAC 25.005(c)(2) ...........................................................................................:....... 2 Requirements of 20 AAC 25.050(b) ....................................................................................................... 3 3. Blowout Prevention Equipment lnformation ......................................................... 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 Base) ........................................................................... 4 9. Abnormally Pressured Formation Information ..................................................... 5 Requirements of 20 AAC 25.005 (c)(9) .........................................................................................•-••••••- 5 10.Seismic Analysis ..................................................................................................... 5 Requirements of 20 AAC 25.005 (c)(10) .......................:........................................................................ 5 11.Seabed Condition Analysis ..................................................................................... 5 Requirements of 20 AAC 25.005 (c)(11) ........................................................................................••--•••. 5 12. Evidence of Bonding ............................................................................................... 5 Requirements of 20 AAC 25.005 (c)(12) ........................••••••••••................:..........•••-••••..............-•--••....... 5 1J-159L1 PERMIT IT Page 1 of 6 Printed: 13-Jan-O6 ORIGINAL • App for Permit to Drill, Well 1J-159 L1 Revision No.O Saved: 13-Jan-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 Aftachment 2 Drilling Hazards Summary ........................................................................:...................... 6 Aftachment 3 Well Schematic -• ............................................:....................------....................................... 6 1. Well Name Requirements of 20 AAC 25.005 (f) Fach well must be identified by a unique name designated by the operator and a unique API number assigned by the commission under 20 AAC25.040(b). For a well with multiple we/!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 we// by the commission. The well for which this Application is submitted will be designated as 1]-159 Ll. 2. Location Summary Requirements of 20 AAC 25.005(c)(2) An application for a Permit to Dri!/ must be accompanied by each of the fo/lowing items, except for an item already on fr/e with the commission and identified in the app/ication: (2) a p/at identifying the property and the property's owners and showing (A)the coordinates of the proposed location of the we// at the surface, at the top of each abject/ve formation, and at total depth, referenced to governmenta/section lines (B) the coordinates of the proposed location of the well at the surface, referenced to the state plane coordinate system for this state as maintained by the National Geodetic Survey in the National Oceanic and Atmospheric Administration; (C) the proposed depth of the well at the top of each objective formation and at total depth; Location at Surface 2,036' FSL, 2,545' FEL, Section 35, T11N, R10E ASPZone 4 NAD 27 Coordinates RKB Elevation 109.0' AMSL Northings; 5,945,846 Eastings; 558,663 Pad Elevation 81.0' AMSL Location at Top of Productive Interval West Sak "B" Sand 1,063' FSL, 1,641' FEL, Section 35, T11N, R10E ASP Zone 4 NAD 27 Coordinates Measured De th, RKB; 4, 588 Northings; 5,944,881 Eastings; 559,577 Total ~ertica/De th RKB,• 3,548 Total ~ertica/ De th, SS.• 3 438 Location at Total De th .261' FNL 1 86T FEL, Section 11, T10N, R10E ASP Zone 4 NAD 27 Coordinates Measured De th RKB,' 11 205 Northings; 5,938,277 Eastings: 559,409 Total ~erticalDe th, RKB,• 3 474 Total vertical De th SS.• 3,365 and (Q) other information required by 20AAC25.05D(b); 1J-159L1 PERMIT IT Page 2 of 6 Printed: 13-Jan-O6 ORIGINAL App~n for Permit to Drill, Well 1J-159 L1 Revision No.O Saved: 13-Jan-06 .Requirements of 20 AAC 25.050(b) Ifa welf is to be intentionally deviated, the application for a Permit to CJri1l (I=orm 10-401) must (Y) include a plat, drawn to a suitable scale, showing the path of the proposed wellbore, including al/adjacent we//bores within 200 feet afany pardon of the proposed well; Please see Attachment 1: Directional Plan and (2) for all we/!s within 200 feet of the proposed we/!bore (A) list the names of the operators of those wel/s, 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 certr`fred mail; or (B) state that the applicant is the only affected owner. The Applicant is the only affected owner. 3. Blowout Prevention Equipment Information Requirements of 20 AAC 25.005(c)(3) An application for a Permit to Drill must be accompanied by each of the following items, except for an i"tem a/ready on file with the commission and identified in the applcatian: (3) a diagram and description of the blowout prevention equipment (BOPS) as required by 20 AAC25.035, 20 AAC 25.036, or 20 AAC 25.037, as app/icabfe; 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 Dri/! must be accompanied by each of the fallowing items, except for an item already on file. with the. commission and identified in the app/ication; (4) information on drilling hazards, including (A) the maximum downho% pressure that maybe encountered, criteria used to determr"ne it, and maximum potentra! surface. pressure based on a methane gradient; The expected reservoir pressures in the West Sak sands in the iJ area are 0.45 psi/ft, or 8.7 ppg EMW ' (equivalent mud weight). Pressures are predicted based on the undisturbed West Sak pressure gradient. The maximum potential surface pressure (MPSP) based on the above maximum pressure gradient, a methane gradient (0.11), and the deepest planned vertical depth of the West Sak "B".sand formation is 1,230 psi, calculated thusly: MPSP =(3,566 ft TVD)(0.45 - 0.11 psi/ft) =1,212 psi (B) data on potentia/gas zones The well bore is not expected to penetrate any gas zones. and (C) data concerning potential causes of ho% problems such as abnorma/1y geo pressured strata, lost circulation zones, and zones that have a propensity for differentia/sticking; Please see Attachment 2: Drilling Hazards Summary. 5. Procedure for Conducting Formation Integrity Tests Requirements of 20 AAC 25.005 (c)(5) An app/ication for a Permit to Drill must be accompanied by each of the fo!/owing items, except for an item already on file with the commission and identified in the app/ication.• (5) a description of the procedure for conducting formation integrity tests, as required under 20 AAG 25.0300; The parent wellbore, 1J-159, will be completed with 7-5/8" intermediate casing landed in the West Sak A- Sand. The casing shoe will be drilled out and a formation integrity test will be performed in accordance with the "Formation Integrity Test Procedure" that ConocoPhillips Alaska placed on file with the Commission. 1J-159L1 PERMIT IT Page 3 of 6 Printed: 13-Jan-06 Appl~n for Permit to Drill, Well 1J-159 L1 Revision No.O Saved: 13-Jan-06 6. Casing and Cementing Program Requirements of 20 AAC 25.005(c)(6) An app/ication for a Permit to Drit! must be accompanied by each of the fo/lowing items, except for an item already on fr/e with the commission and identified in the app/icah"an: (6J a complete proposed casr`ng and cementing program as required by 20 AAC 25.030, and a description of any slotted /mer, pre- perforated liner, or screen to be installed; Casing and Cementing Program See also Attachment 3: Cement Summary Hole Top Btm Csg/Tbg Size Weigh Length MD/TVD MD/TVD OD in in t Ib/fl` Grade Connection ft ft ft Cement Pro ram 4-1/2 6-3/4" A Sand 12.6 L-80 IBTM 6,026 5,556 / 3,698 7,857 / 3,641 Slotted- no cement slotted Lateral (1J-159) 4-1/2 6-3/4" B Sand 12.6 L-80 IBTM 7,113 4,588/ 3,548 11,205 / 3,474 Slotted- no cement Slotted Lateral (1J-159 L1) 4-1/2 6-3/4" D Sand 12.6 L-80 IBTM 7,521 4,285/ 3,482 10,900 / 3,399 Slotted- no cement slotted Lateral (1J-159 L2) 7. Diverter System Information Requirements of 20 AAC 25.005(c)(7) An app/ication for a Permit to ©ri// must be accompanied by each of the fo!/owing items, except for an item a/ready on file with the commission and identified in the application: (7) a diagram and description of the diverter system as required by ZO AAC 25.035, unless this requirement is waived by the commission under 20 AAC 25.035(h)(2); No diverter system will be utilized during operations on iJ-159 L1. 8. Drilling Fluid Program Requirements of 20 AAC 25.005(c)(8) An application for a Permit to ©rfll must be accompanied by each of the following items, except for an item already on file wr`th the commission and identified in the application: (8) a dri/Ding fluid program, including a diagram and description of the drilling fluid system, as required by ZO 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 pp 8.6 Plastic Viscostiy Ib/100 s 15 - 25 Yield Point cP 18 - 28 HTHP Fluid loss (ml/30 min @ 200psi & <4.0 150° Oil /Water Ratio 70 / 30 Electrical Stabilit 650-900 1J-159L1 PERMIT IT Page 4 of 6 Printed: 13-Jan-06 !~~... Appl~ for Permit to Drill, Well 1J-159 L1 Revision No.O Saved: 13-Jan-06 Drilling fluid practices will be in accordance with appropriate regulations stated in 20 AAC 25.033. Please see information on file with the Commission for diagrams and descriptions of the fluid system of Doyon Rig 141. 9. Abnormally Pressured Formation Information Requirements of 20 AAC 25.005 (c)(9) An app/ication for a Permit to Drr/1 must be accompanied by each of the fo/lowing items, except far an item already on file with the commission and identified in the application.• (9) for an exp/oratory or stratigraphic test we!/, a tabulation set[rng out the depths of predicted abnormally geo pressured strata as required by 20 AAC25.033(!); Not applicable: Application is not for an exploratory or stratigraphic test well. 10. Seismic Analysis Requirements of 20 AAC 25.005 (c)(10) An app/ication for a Permit to Drr!! mast be accompanied by each of the fo//owing items, except for an item a/ready on file with the commission and identified in the application: (10) for an exploratory or stratigraphic test well, a seismic refraction ar 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 app/ication for a Permit to Drill must be accompanied by each of the fo/lowing items, except for an item a/ready on fr/e with the commission and identified in the application: (11) for a we/! drilled from an offshore platform, mobile bottom-founded structure, jack-up rig, or floating drilling vess% an analysis ofseabed conditions as required by 20 AAC25.061(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 fatlawing items, except for an item already on file with the commission and identified in the app/icatian: (12) evidence showing that the requirements of20 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 fo/Jawing items, except for an item a/ready 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 iJ-159 Application for Permit to Drill. 1. Run and set Baker WindowMaster whipstock system, at window point of 4,588' MD / 3,548' TVD, the top of the B sand. 2. Mill 6-3/4"window. POOH. 3. Pick up 6-3/4"drilling assembly with LWD and MWD and PWD. RIH. 4. Drill to TD of B sand lateral at 11,205' MD / 3,474' 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. 1 J-159L1 PERMIT /T Page 5 of 6 ~' ~ Printed: 13-Jan-06 Appl~ for Permit to Drill, Well 1J-159 L1 Revision No.O Saved: 13-Jan-O6 8. RIH, until liner hanger is just above window. Orient hanger to window and land hanger. 9. Release hanger running tool. POOH. 10. Make up junction isolation / re-entry assembly (Lateral Entry Module or LEM) and RIH to depth. Orient and set packer atop assembly and release from assembly. 11. POOH and prepare to drill the "D" sand lateral 1J-159 L2. 14. Discussion of Mud and Cuttings Disposal and Annular Disposal Requirements of 20 AAC 25.005 (c)(14) An application for a Permit to Drill mustc be accompanied by each of the fo/%wing items, except for an item already on F/e 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 1J 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. ConacoPhillips 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-159L1 PERMIT IT Page 6 of 6 Printed: 13-Jan-06 ORIGINAL • • ConocoPhillips Alaska ConocoPhillips Alaska (Kuparuk) Kuparuk River Unit Kuparuk 1J Pad Plan 1J-159 1J-159 L1 Plan: 1J-159 L1 (wp06) Proposal Report 14 December, 2005 HA~.~.L.1~Ui~TtN ORIGINAL -400 Project: Kuparuk River Unit Site: Kuparuk 1J Pad Well: Plan 1J-159 Wellbore: 1J-159 L1 Plan: 1J-159 L1 (wp06) to 3g° ~Lt: TO 4sa8ft MD, 3548ft rw ConOCOPllillips ~5° ~ Alaska 171° . ~ L1: BOW @ 4600ft MD, 3550ft TVD -Drill Out 30' RathoM i~ 180° ~~' L1: Build @ 5°H OOk to 90.7° tint - 4630ft MD, 3554ft N[ J _ __---- ----- L1: Sall @ 90.7° Inc : 4815ft MD, 3566ft ND --- 187^ _ _ _ ~1: Continue Dlr @ 5°/100ft , 5045ft MD, 3563ft M ~L1: Continue Dlr @ 3°/100ft , 5073ft MD, 3563ft M as° ` ~ - L1: Sail @ 91.5° Inc : 5156ft MD, 3562ft TVD 1J-159 L1 T1 (wp06) LEGEND $ Plan 1J-159, 1J-159, 1J-159 (wp06) VO $ 1J-159 L1 (wp06) c w O 0 r 0 Z t 0 1J-159 Lt T2 (wp06) _ 1J-159 L7 T3 (wp06) 1J-159 L7 U (wp0i~ __- - Lt: Contnue Dir @ 3°/100ft , 5895ft MD, 3543ft TV[ 181° `~'~ - Lt: Sall @ 91.4° Inc : 6131ft MD, 3537ft TVD 181 ° Lt: Continue GeoSteer in BSand 6481ft MD, 3529ft N 180° 180° iJ-159 Li T5 (wp06) _ _ I T M Magnetic North: 24.53° Magnetic Field Strength: 57579.1 nT Dip Angle: 80.72° Date: 11/28/2004 Model: BGGM2004 1J159 L1 T6 (wp06) I 1J-159 L1 T7 (wp06) -2400 -2000 -1600 -1200 -800 -400 0 400 180° CASING DETAILS No ND MD Name Size 1 2207.00 2392.47 10 3/4" 10-3/4 2 3547.88 4588.40 7 5/8" 7-5/8 3 3474.0011205.17 41/2" 4-1 /2 L7 : BHL @ 11205ft MD, 3474ft 180° ' -----..',,41/2° 800 1200 1600 __... a a"`t~M1l Sperry Drilling Services 2000 2400 2800 3200 ~ ~ m N NGiAe~- in r v dv. J A Q N ~ F 2~rv p ~ O C r Z m m O Q N R U porno omo ~~~v N ~ R N M M Z r N M z 111 w J O 3 m ~ ~ ~ Q m 3 ~ _ J ~ ~ a N ~i / p ,, f N 006 pN, V m J ~ M m p Y i M p ~ A O m q~ W 'O ~ ~ m 2 ~ ~ C m m M ~ ~\ 0 m m ~ 1 m m C ~ M \\ ~ m C 1 ~ . v C ~~ ~ ~ v ~ 088 O ~ x J ~ n J ~ .~ ~ a _ W > a J a °' 3 ~~~ Y ~ 3 ` ~ J i W ~ ~ Cf 3 3 ~ L r Y Ya o~ 4 ~ U r N C o~~~a a` a v M O O V c °m O 0 3 J N "f n 0 O O O O O O a ~~ ~ ~ m F J [D 0 C 3 m r J i0 H J N i > 1- N ~` Q ~ \ \~ m V C ~ ~ t ` 1 _ m Q N d C ~ \ ~ -- M C ~ ~ ` J ~ .. ~ ~ ~ ~ ~ J .. ~ ~ ~ ~ u ~ . ~ ~ ~ ~ 1 c ~ ~ \ 1 o rn ~~ \\~ ~ ~ ~ ~ \~ ~ ~ ~\ J \ ~ ~ \ ~ ~ `9 O M ~ j~ 7 Q \~ V ~ •C O '~ m ~ ~ J ~~+ N _ ____ o _ - __ _ 006 ~ ~ ~ ~ ~ I '' ~ V M ~ m p _ ' ' ~ - °Q~ J ~fJ v °~9 aU 3 °os 0 o Or ~Sb O N J v ~O M 0 eQ ~ ro O 3 p FN- J M ~ ' / - M ~~ ~~ 1° _,- o M p d C C ~' U J S Q , ' `~ t D In ~ U C \~ ~`\ in Oa ~` . \ ~\ ~ ~ fn J ~ . O G 3 J N 0 v ~_ O ~ v 0 0 O O 00 O M ~ c O O U o ~ c`N7 (n m U °o N N O O O O m 0 0 0 q m v ~~ ELLBORE TARGET DETAILS (MAP CO-ORDINAT Name TVD TVDSS +N/-S +EJ-W Northing Easting Shape 1J-159 L1 T6 (wp06) 3473.00 3364 -6603.04 693.94 5939250.00 559409.00 Point 1J-159 L1 T7 (wp06) 3474.00 3365 -7576.10 686.36 5938277.00 559409.00 Point 1J-159 L1 T5 (wp06} 3483.00 3374 -5852.99 699.78 5940000.00 559409.00 Point 1J-159 L1 T3 (wp06) 3502.00 3393 X952.87 714.59 5941900.00 559409.00 Point 1J-159 L1 T4 (wp06) 3517.00 3408 -4652.91 709.13 5941200.00 559409.00 Point 1J-159 L7 T2 (wp06) 3529.00 3420 -2852.82 726.16 5943000.00 559412.00 Point 1J-159 L1 T1 (wp 06) 3563.00 3454 -1453.65 855.07 5944400.00 559530.00 Point SECTION DETAILS Sec MD Inc Azi ND TVDss +N/S +E/-W Northing Easting DLeg TFace VSec Target 1 4588.39 80.000 184.00 3547.88 3438.88 -972.84 905.83 5944881.14 559577.01 0.00 0.000 972.84 2 4600.39 81.908 184.00 3549.76 3440.76 -984.67 905.01 5944869.31 559576.27 15.90 0.000 984.67 3 4630.39 81.908 184.00 3553.99 3444.99 -1014.29 902.94 5944839.67 559574.43 0.00 0.000 1014.29 4 4814.99 90.696 186.83 3565.88 3456.88 -1197.49 885.54 5944656.36 559558.47 5.00 17.937 1197.49 5 5045.48 90.696 186.83 3563.08 3454.08 -1426.32 858.13 5944427.35 559532.84 0.00 0.000 1426.32 6 5072.97 89.658 185.93 3563.00 3454 -1453.65 855.07 5944400.00 559530.00 5.00-139.009 1453.65 1J-159 L1 T1 {wp06} 7 5156.30 91.463 187.66 3562.18 3453.18 -1536.38 845.22 5944317.20 559520.79 3.00 43.782 1536.38 8 5895.25 91.463 187.66 3543.32 3434.32 -2268.50 746.75 5943584.41 559428.04 0.00 0.000 2268.50 9 6130.53 91.386 180.60 3537.47 3428.47 -2502.94 729.82 5943349.86 559412.94 3.00 -90.535 2502.94 10 6480.53 91.386 180.60 3529.00 3420 -2852.82 726.16 5943000.00 559412.00 0.00 0.000 2852.82 1J-159 L1 T2 (wp06} 11 6481.53 91.406 180.60 3528.98 3419.98 -2853.82 726.15 5942998.99 559412.00 2.00 7.597 2853.82 12 7580.97 91.406 180.60 3502.00 3393 -3952.87 714.59 5941900.00 559409.00 0.00 0.000 3952.87 1J-159 L1 T3 {wp06) 13 7728.38 88.463 180.43 3502.17 3393.17 -4100.26 713.26 5941752.62 559408.82 2.00-176.604 4100.26 14 8281.25 88.463 180.43 3517.00 3408 -4652.91 709.13 5941200.00 559409.00 0.00 0.000 4652.91 1J-159 L1 T4 {wp06) 15 8451.29 91.864 180.45 3516.52 3407.52 -4822.92 707.83 5941030.00 559409.03 2.00 0.333 4822.92 16 9481.94 91.864 180.45 3483.00 3374 -5852.99 699.78 5940000.00 559409.00 0.00 0.000 5852.99 1J-159 L1 T5 (wp06) 17 9539.10 90.720 180.45 3481.71 3372.71 -5910.14 699.34 5939942.86 559409.00 2.00-179.927 5910.14 1810232.08 90..720 180.45 3473.00 3364 -6603.04 693.94 5939250.00 559409.00 0.00 0.000 6603.04 1 J-159 L1 T6 {wp06) 1910271.85 89.x"25 180.45 3472.78 3363.78 -6642.81 693.63 5939210.23 559409.00 2.00 179.996 6642.81 2011205.18 89.925 180.45 3474.00 3365 -7576.10 686.36 5938277.00 559409.00 0.00 0.000 7576.10 1J-159 L7 T7 {wp06) ANNOTATIONS TVD TVDss MD Annotation 3547.88 3438.88 4588.40 L1: TOW @ 4588ft MD, 3548ft TVD -1063ft FSL & 1641ft FEL -Sec 35 - T11 N - R10E 3549.76 3440.76 4600.40 L1: BOW @ 4600ft MD, 3550ft TVD -Drill Out 30' Rathole 3553.99 3444.99 4630.40 L1: Build @ 5°/100ft to 90.7° lint - 4630ft MD, 3554ft TVD 3565.88 3456.88 4815.00 L1: Sail @ 90.7° Inc : 4815ft MD, 3566ft TVD 3563.08 3454.08 5045.48 L7: Continue Dir @ 5°/100ft , 5045ft MD, 3563ft TVD 3563.00 3454 5072.98 L1: Continue Dir @ 3°/100ft , 5073ft MD, 3563ft ND 3562.18 3453.18 5156.31 L1: Sail @ 91.5° Inc : 5156ft MD, 3562ft TVD 3543.32 3434.32 5895.26 L1: Continue Dir @ 3°/100ft , 5895ft MD, 3543ft TVD 3537.47 3428.47 6130.54 L1: Sail @ 91.4° Inc : 6131ft MD, 3537ft TVD 3529.00 3420 6480.54 L1: Continue GeoSteer in BSand 64$1ft MD, 3529Ft TVD 3474.00 3365 11205.17 L1 : BHL @ 11205ft MD, 3474ft TVD :261 FNL & 1867ft FEL -Sec 11 - T10N - R10E 'r' Halliburton Energy Services NALLBUAT1aN ~C3C1t~-CA~~"11~~t~'15 Planning Report -Geographic ----_~~_____.__ .~_ _.~~ Alaska $pae~- Drllting $ervfces _ _ Database: EDM 2003.11 Single User Db Local Co-ordinate Reference: Well Plan 1J-159 Company: ConocoPhillips Alaska (Kuparuk) TVD Reference: Planning RKB @ 109.OOft (Doyon 141 (28+81 )) Project: Kuparuk River Unit MD Reference: Planning RKB @ 109AOft (Doyon 141 (28+81)) Site: Kuparuk 1J Pad North Reference: True - Well: Plan 1J-159 Survey Calculation Method: Minimum Curvature Wellbore: 1J-159 L1 Design: 1J-159 L1 (wp06) Project Kuparuk River Unit, North Slope Alaska, United States Map System: US State Plane 1927 (Exact solution) System Datum: Mean Sea Level Geo Datum: NAD 1927 (NADCON CONUS) Using Well Reference Point Map Zone: Alaska Zone 04 Using geodetic scale factor Well Plan 1J-159 Well Position +WS 0.00 ft Northing: 5,945,846.80 ft Latitude: 70° 15' 45.551" N +E/-W 0.00 ft Easting: 558,663.71 ft Longitude: 149° 31' 32.697" W Position Uncertainty 0.00 ft Wellhead Elevation: ft Ground Level: 81.OOft Wellbore 1J-159 L1 Magnetics Model Name Sample Date Declination Dip Angle Field Strength BGGM2004 11/28/2004 24.531 80.724 57,579 Design Audit Notes: Version: Vertical Section: 1J-159 L1 (wp06) Phase: PLAN Depth From (TVD) +N/-S (ft) (ft) 28.00 0.00 Tie On Depth: +E/-W Direction (ft) (°) 0.00 180.00 4,588.39 12/14/2005 5:55:47PM Page 2 of 6 COMPASS 2003.118ui1d 48 ~~ '--' ~ Halliburton Energy Services HALLIBU~iTt'~N ~~!~~~~~~ Planning Report -Geographic ~-~---~ -~ Alaska $ry €3rllling Sear#ces Database: EDM 2003.11 Single User Db Local Co-ordinate Reference: Well Plan 1J-159 Company: ConocoPhillips Alaska (Kuparuk) TVD Reference: Planning RKB @ 109.OOft (Doyon 141 (28+81)) Project: Kuparuk River Unit MD Reference: Planning RKB @ 109.OOft (Doyon 141 (28+81)) Site: Kuparuk 1J Pad North Reference: True Well: Plan 1J-159 Survey Calculation Method: Minimum Curvature Wellbore: 1J-159 L1 Design: 1J-159 L1 (wp06) Plan Summary Measured Vertical Dogleg Build Turn Depth Inclination Azimuth Depth +Nf-S +E/-W Rate Rate Rate TFO (ft) (°) (°) (ft) (ft) (ft) (°/10Qft) (°/100ft) (°/100ft) (°) 4,588.39 80.000 184.00 3,547.88 -972.84 905.83 0.00 0.00 0.00 0.000 4,600.39 81.908 184.00 3,549.76 -984.67 905.01 15.90 15.90 0.00 0.000 4,630.39 81.908 184.00 3,553.99 -1,014.29 902.94 0.00 0.00 0.00 0.000 4,814.99 90.696 186.83 3,565.88 -1,197.49 885.54 5.00 4.76 1.53 17.937 5,045.48 90.696 186.83 3,563.08 -1,426.32 858.13 0.00 0.00 0.00 0.000 5,072.97 89.658 185.93 3,563.00 -1,453.65 855.07 5.00 -3.77 -3.28 -139.009 5,156.30 91.463 187.66 3,562.18 -1,536.38 845.22 3.00 2.17 2.08 43.782 5,895.25 91.463 187.66 3,543.32 -2,268.50 746.75 0.00 0.00 0.00 0.000 6,130.53 91.386 180.60 3,537.47 -2,502.94 729.82 3.00 -0.03 -3.00 -90.535 6,480.53 91.386 180.60 3,529.00 -2,852.82 726.16 0.00 0.00 0.00 0.000 6,481.53 91.406 180.60 3,528.98 -2,853.82 726.15 2.00 1.98 0.26 7.597 7,580.97 91.406 180.60 3,502.00 -3,952.87 714.59 0.00 0.00 0.00 0.000 7,728.38 88.463 180.43 3,502.17 -4,100.26 713.26 2.00 -2.00 -0.12 -176.604 8,281.25 88.463 180.43 3,517.00 -4,652.91 709.13 0.00 0.00 0.00 0.000 8,451.29 91.864 180.45 3,516.52 -4,822.92 707.83 2.00 2.00 0.01 0.333 9,481.94 91.864 180.45 3,483.00 -5,852.99 699.78 0.00 0.00 0.00 0.000 9,539.10 90.720 180.45 3,481.71 -5,910.14 699.34 2.00 -2.00 0.00 -179.927 10,232.08 90.720 180.45 3,473.00 -6,603.04 693.94 0.00 0.00 0.00 0.000 10,271.85 89.925 180.45 3,472.78 -6,642.81 693.63 2.00 -2.00 0.00 179.996 11,205.18 89.925 180.45 3,474.00 -7,576.10 686.36 0.00 0.00 0.00 0.000 12/14/2005 5:55:47PM Page 3 of 6 COMPASS 2003.19 BuBd 48 Q~ • +4r~~'ti+~V~ ~ ~ 1 -~aska Database: EDM 2003.11 Single User Db Company: ConocoPhillips Alaska (Kuparuk) Project: Kuparuk River Unit Site: Kuparuk 1J Pad Well: Plan 1J-159 Wellbore: 1J-159 L1 Design: 1J-159 L1 (wp06) Halliburton Energy Services wp-u.~euAYOrr Planning Report -Geographic ---_ _w_ ~ __ _ _ _~. ____~ Sperry' Drilling Services _ _ _ Local Co-ordinate Reference: Well Plan 1J-159 TVD Reference: Planning RKB @ 109.OOft (Doyon 141 (28+81 )) MD Reference: Planning RKB @ 109.OOft (Doyon 141 (28+81)) North Reference: True Survey Calculation Method: Minimum Curvature __ Planned Survey 1J-159 L1 (wp0&) Map Map MD Inclination Azimuth TVD SSTVD +NJ-S +E/-W Northing Easting DLSEV Vert Section Iftt (°) (°) lft) (ft1 (ft) (ft) eft) (ft) (°MOOft) (ft) 4,588.39 80.000 184.00 3,547.88 3,438.88 -972.84 905.83 5,944,881.14 559,577.01 0.00 972.84 L1: TOW @ 4588ft M D, 3548ft TVD -1063ft FSL & 1641ft FEL -Sec 35 - T11 N - R1 OE - 75/8" ~ 4,600.00 81.846 184.00 3,549.71 3,440.71 -984.28 905.03 5,944,869.69 559,576.30 15.90 98428 4,600.39 81.908 184.00 3,549.76 3,440.76 -984.67 905.01 5,944,869.31 559,576.27 15.90 984.67 L1: BOW @ 4600ft MD, 3550ft TVD -Drill Out 30' Rathole 4,630.39 81.908 184.00 3,553.99 3,444.99 -1,014.29 902.94 5,944,839.67 559,574.43 0.00 1,014.29 L1: Build @ 5°11008 to 90.7° lint - 4630ft MD, 3554ft TVD 4,700.00 85.219 185.07 3,561.79 3,452.79 -1,083.24 897.46 5,944,770.69 559,569.50 5.00 1,08324 4,800.00 89.981 186.60 3,565.97 3,456.97 -1,182.60 887.30 5,944,671.26 559,560.11 5.00 1,182.60 4,814.99 90.696 186.83 3,565.88 3,456.88 -1,197.49 885.54 5,944,656.36 559,558.47 5.01 1,197.49 L1: Sail @ 90.7° Inc : 4815ft MD, 3 566ft TVD 4,900.00 90.696 186.83 3,564.85 3,455.85 -1,281.89 875.43 5,944,571.89 559,549.02 0.00 1,281.89 5,000.00 90.696 186.83 3,563.64 3,454.64 -1,381.17 863.54 5,944,472.53 559,537.90 0.00 1,381.17 5,045.48 90.696 186.83 3,563.08 3,454.08 -1,426.32 858.13 5,944,427.35 559,532.84 0.00 1,426.32 L1: Continue Dir @ 5°/100ft , 5045ft MD, 3563ft TVD 5,072.97 89.658 185.93 3,563.00 3,454.00 -1,453.65 855.07 5,944,400.00 559,530.00 5.00 1,453.65 L1: Continue Dir @ 3°/100ft , 5073ft MD, 3563ft TVD -1J-159 L1 T1 (wp08) 5,100.00 90.243 186.49 3,563.02 3,454.02 -1,480.51 852.15 5,944,373.11 559,527.29 3.00 1,480.51 5,156.30 91.463 187.66 3,562.18 3,453.18 -1,536.38 845.22 5,944,317.20 559,520.79 3.00 1,536.38 L1: Sail @ 91.5° Mc : 5156ft MD, 3 5828 TVD 5,200.00 91.463 187.66 3,561.07 3,452.07 -1,579.67 839.39 5,944,273.87 559,515.30 0.00 1,579.67 5,300.00 91.463 187.66 3,558.52 3,449.52 -1,678.75 826.07 5,944,174.70 559,502.75 0.00 1,678.75 5,400.00 91.463 187.66 3,555.96 3,446.96 -1,777.82 812.74 5,944,075.53 559,490.20 0.00 1,777.82 5,500.00 91.463 187.66 3,553.41 3,444.41 -1,876.90 799.42 5,943,976.37 559,477.65 0.00 1,876.90 5,600.00 91.463 187.66 3,550.86 3,441.86 -1,975.97 786.09 5,943,87720 559,465.10 0.00 1,975.97 5,700.00 91.463 187.66 3,548.31 3,439.31 -2,075.05 772.77 5,943,778.03 559,452.55 0.00 2,075.05 5,800.00 91.463 187.66 3,545.75 3,436.75 -2,174.12 759.44 5,943,678.87 559,439.99 0.00 2,174.12 5,895.25 91.463 187.66 3,543.32 3,434.32 -2,268.50 746.75 5,943,584.41 559,428.04 0.00 2,268.50 L1: Continue Dir @ 3°MOOft , 5895ft MD, 3543ft TVD 5,900.00 91.461 187.52 3,54320 3,434.20 -2,273.20 746.12 5,943,579.70 559,427.45 2.99 2,273.20 6,000.00 91.431 184.52 3,540.68 3,431.68 -2,372.61 735.65 5,943,480.22 559,417.75 3.00 2,372.61 6,100.00 91.397 181.52 3,538.21 3,429.21 -2,472.43 730.39 5,943,380.38 559,413.26 3.00 2,472.43 6,130.53 91.386 180.60 3,537.47 3,428.47 -2,502.94 729.82 5,943,349.86 559,412.94 3.00 2,502.94 L7: Sail @ 91.4° Inc : 6 131ft MD, 3 537ft TVD 6,200.00 91.386 180.60 3,535.79 3,426.79 -2,572.39 729.09 5,943,280.42 559,412.75 0.00 2,572.39 6,300.00 91.386 180.60 3,533.37 3,424.37 -2,672.35 728.05 5,943,180.46 559,412.48 0.00 2,672.35 6,400.00 91.386 180.60 3,530.95 3,421.95 -2,772.32 727.00 5,943,080.50 559,412.22 0.00 2,772.32 6,480.53 91.386 180.60 3,529.00 3,420.00 -2,852.82 726.16 5,943,000.00 559,412.00 0.00 2,852.82 L1: Continue GeoSteer in BSand 8481ft MD, 3529ft TVD -1 J-159 L1 T2 (wp06j 6,481.53 91.406 180.60 3,528.98 3,419.98 -2,853.82 726.15 5,942,998.99 559,412.00 2.00 2,853.82 6,500.00 91.406 180.60 3,528.52 3,419.52 -2,872.28 725.95 5,942,980.54 559,411.95 0.00 2,872.28 6,600.00 91.406 180.60 3,526.07 3,417.07 -2,972.25 724.90 5,942,880.58 559,411.67 0.00 2,972.25 6,700.00 91.406 180.60 3,523.62 3,414.62 -3,072.21 723.85 5,942,780.62 559,411.40 0.00 3,072.21 6,800.00 91.406 180.60 3,521.16 3,412.16 -3,172.18 722.80 5,942,680.66 559,411.13 0.00 3,172.18 6,900.00 91.406 180.60 3,518.71 3,409.71 -3,272.14 721.75 5,942,580.70 559,410.86 0.00 3,272.14 12/14/2005 5:55:47PM Page 4 of 6 ORIGINAL COMPASS 2003.11 Build 48 • Cant~ccal'hilli~s ;l~sk=r Database: EDM 2003.11 Single User Db Company: ConocoPhillips Alaska (Kuparuk) Project: Kuparuk River Unit Site: Kuparuk 1J Pad Well: Plan 1J-159 Wellbore: 1J-159 L1 Design: 1J-159 L1 (wp06) Halliburton Energy Services WA4LIBURTt'~N Planning Report -Geographic --------~ -- ~- _ _ Sperry ()e311ing J~BrViCBS Local Co-ordinate Reference: Well Plan 1J-159 TVD Reference: Planning RKB @ 109.OOft (Doyon 141 (28+81)) MD Reference: Planning RKB @ 109.OOft (Doyon 141 (28+81)) North Reference: True Survey Calculation Method: Minimum Curvature Planned Survey 1J-159 L1 (wp06) Map Map MD Inclination Azimuth TVD SSTVD +N/-S +E/-W Northing Easting DLSEV Vert Section (ft) (°) C°) (ft) (ft) (ft) (ft) (ft) (ft) (°/100ft) (ftl 7,000.00 91.406 180.60 3,516.25 3,407.25 -3,372.10 720.70 5,942,480.74 559,410.58 0.00 3,372.10 7,100.00 91.406 180.60 3,513.80 3,404.80 -3,472.07 719.64 5,942,380.78 559,410.31 0.00 3,472.07 7,200.00 91.406 180.60 3,511.35 3,402.35 -3,572.03 718.59 5,942,280.82 559,410.04 0.00 3,572.03 7,300.00 91.406 180.60 3,508.89 3,399.89 -3,672.00 717.54 5,942,180.86 559,409.77 0.00 3,672.00 7,400.00 91.406 180.60 3,506.44 3,397.44 -3,771.96 716.49 5,942,080.90 559,409.49 0.00 3,771.96 7,500.00 91.406 180.60 3,503.99 3,394.99 -3,871.93 715.44 5,941,980.94 559,409.22 0.00 3,871.93 7,580.97 91.406 180.60 3,502.00 3,393.00 -3,952.87 714.59 5,941,900.00 559,409.00 0.00 3,952.87 1J-159 L1 T3 (wp06) 7,600.00 91.027 180.58 3,501.60 3,392.60 -3,971.89 714.39 5,941,880.97 559,408.95 2.00 3,971.89 7,700.00 89.030 180.46 3,501.55 3,392.55 -4,071.88 713.48 5,941,780.99 559,408.82 2.00 4,071.88 7,728.38 88.463 180.43 3,502.17 3,393.17 -4,100.26 713.26 5,941,752.62 559,408.82 2.00 4,100.26 7,800.00 88.463 180.43 3,504.09 3,395.09 -4,171.85 712.73 5,941,681.03 559,408.85 0.00 4,171.85 7,900.00 88.463 180.43 3,506.77 3,397.77 -4,271.81 711.98 5,941,581.08 559,408.88 0.00 4,271.81 8,000.00 88.463 180.43 3,509.46 3,400.46 -4,371.77 711.23 5,941,481.12 559,408.91 0.00 4,371.77 8,100.00 88.463 180.43 3,512.14 3,403.14 -4,471.73 710.49 5,941,381.17 559,408.94 0.00 4,471.73 8,200.00 88.463 180.43 3,514.82 3,405.82 -4,571.69 709.74 5,941,281.21 559,408.97 0.00 4,571.69 8,281.25 88.463 180.43 3,517.00 3,408.00 -4,652.91 709.13 5,941,200.00 559,409.00 0.00 4,652.91 1J-159 L1 T4 (wp06j 8,300.00 88.837 180.43 3,517.44 3,408.44 -4,671.66 708.99 5,941,181.26 559,409.01 2.00 4,671.66 8,400.00 90.837 180.44 3,517.72 3,408.72 -4,771.65 708.23 5,941,081.27 559,409.02 2.00 4,771.65 8,451.29 91.864 180.45 3,516.52 3,407.52 -4,822.92 707.83 5,941,030.00 559,409.03 2.00 4,822.92 8,500.00 91.864 180.45 3,514.93 3,405.93 -4,871.60 707.45 5,940,981.32 559,409.02 0.00 4,871.60 8,600.00 91.864 180.45 3,511.68 3,402.68 -4,971.55 706.67 5,940,881.39 559,409.02 0.00 4,971.55 8,700.00 91.864 180.45 3,508.43 3,399.43 -5,071.49 705.89 5,940,781.45 559,409.02 0.00 5,071.49 8,800.00 91.864 180.45 3,505.18 3,396.18 -5,171.44 705.11 5,940,681.51 559,409.02 0.00 5,171.44 8,900.00 91.864 180.45 3,501.92 3,392.92 -5,271.38 704.33 5,940,581.57 559,409.01 0.00 5,271.38 9,000.00 91.864 180.45 3,498.67 3,389.67 -5,371.32 703.55 5,940,481.64 559,409.01 0.00 5,371.32 9,100.00 91.864 180.45 3,495.42 3,386.42 -5,471.27 702.77 5,940,381.70 559,409.01 0.00 5,471.27 9,200.00 91.864 180.45 3,492.17 3,383.17 -5,57121 701.98 5,940,281.76 559,409.01 0.00 5,571.21 9,300.00 91.864 180.45 3,488.92 3,379.92 -5,671.16 701.20 5,940,181.82 559,409.00 0.00 5,671.16 9,400.00 91.864 180.45 3,485.66 3,376.66 -5,771.10 700.42 5,940,081.89 559,409.00 0.00 5,771.10 9,481.94 91.864 180.45 3,483.00 3,374.00 -5,852.99 699.78 5,940,000.00 559,409.00 0.00 5,852.99 1J-159 L1 T5 (wp06j 9,500.00 91.503 180.45 3,482.47 3,373.47 -5,871.05 699.64 5,939,981.95 559,409.00 2.00 5,871.05 9,539.10 90.720 180.45 3,481.71 3,372.71 -5,910.14 699.34 5,939,942.86 559,409.00 2.00 5,910.14 9,600.00 90.720 180.45 3,480.95 3,371.95 -5,971.03 698.86 5,939,881.97 559,409.00 0.00 5,971.03 9,700.00 90.720 180.45 3,479.69 3,370.69 -6,071.02 698.08 5,939,781.99 559,409.00 0.00 6,071.02 9,800.00 90.720 180.45 3,478.43 3,369.43 -6,171.01 697.30 5,939,682.00 559,409.00 0.00 6,171.01 9,900.00 90.720 180.45 3,477.17 3,368.17 -6,271.00 696.52 5,939,582.02 559,409.00 0.00 6,271.00 10,000.00 90.720 180.45 3,475.92 3,366.92 -6,370.99 695.75 5,939,482.04 559,409.00 0.00 6,370.99 10,100.00 90.720 180.45 3,474.66 3,365.66 -6,470.98 694.97 5,939,382.06 559,409.00 0.00 6,470.98 10,200.00 90.720 180.45 3,473.40 3,364.40 -6,570.96 694.19 5,939,282.07 559,409.00 0.00 6,570.96 10,232.08 90.720 180.45 3,473.00 3,364.00 -6,603.04 693.94 5,939,250.00 559,409.00 0.00 6,603.04 1J-159 L1 T6 (wp06) 10,271.85 89.925 180.45 3,472.78 3,363.78 -6,642.81 693.63 5,939,210.23 559,409.00 2.00 6,642.81 10,300.00 89.925 180.45 3,472.81 3,363.81 -6,670.96 693.41 5,939,182.09 559,409.00 0.00 6,670.96 10,400.00 89.925 180.45 3,472.94 3,363.94 -6,770.95 692.63 5,939,082.10 559,409.00 0.00 6,770.95 10,500.00 89.925 180.45 3,473.08 3,364.08 -6,870.95 691.85 5,938,982.11 559,409.00 0.00 6,870.95 12/14/2005 5:55:47PM Page 5 of 6 COMPASS 2003.11 Buifd 48 ~ ~ • rr-' Halliburton Energy Services HAL.LiBUIFtT`i7N ~~~~~~~~~~!~ Planning Report -Geographic ------~--- --- - ?,laaka Sperr~r Dri11ir1g ~ervtc®s Database: EDM 2003.11 Single User Db Local Co-ordinate Reference: Well Plan 1J-159 Company: ConocoPhillips Alaska (Kuparuk) TVD Reference: Planning RKB @ 109.OOft (Doyon 141 (28+81)) Project: Kuparuk River Unit MD Reference: Planning RKB @ 109.OOft (Doyon 141 (28+81)) Site: Kuparuk 1J Pad North Reference: True Well: Plan 1J-159 Survey Calculation Method: Minimum Curvature Wellbore: 1J-159 L1 Design: 1J-159 L1 (wp06) Planned Survey 1J-159 L1 (wp06) Map Map MD Inclination Azimuth TVD SSTVD +NI-S +E/-W Northing Easting DLSEV Vert Section (ft) (°) (°) (ft) (ftl (ft) (ft) (ft) (ft) (°/100ft) (ft) 10,600.00 89.925 180.45 3,473.21 3,364.21 -6,970.95 691.07 5,938,882.12 559,409.00 0.00 6,970.95 10,700.00 89.925 180.45 3,473.34 3,364.34 -7,070.95 690.29 5,938,782.13 559,409.00 0.00 7,070.95 10,800.00 89.925 180.45 3,473.47 3,364.47 -7,170.94 689.51 5,938,682.14 559,409.00 0.00 7,170.94 10,900.00 89.925 180.45 3,473.60 3,364.60 -7,270.94 688.73 5,938,582.15 559,409.00 0.00 7,270.94 11,000.00 89.925 180.45 3,473.73 3,364.73 -7,370.94 687.96 5,938,482.16 559,409.00 0.00 7,370.94 11,100.00 89.925 180.45 3,473.86 3,364.86 -7,470.93 687.18 5,938,382.16 559,409.00 0.00 7,470.93 11,200.00 89.925 180.45 3,473.99 3,364.99 -7,570.93 686.40 5,938,282.17 559,409.00 0.00 7,570.93 11,205.18 89.925 180.45 3,474.00 3,365.00 -7,576.10 686.36 5,938,277.00 559,409.00 0.00 7,576.10 L1 : BHL @ 11205ft MD, 3474ft TVD :261 FNL ~ 1867ft FEL -Sec 11 - T1 0N - R10E - 41/2" -1J-159 L1 T7 (wp06) Geologic Targets 1J-159 L1 - ---__ TVb Target Name +N/-S +E/-W Northing Easting (ft) -Shape ft ft (ft) (ft) 3,517.00 1J-159 L1 T4 {wp06} -4,652.91 709.13 5,941,200.00 559,409.00 - Point 3,474.00 1J-159 L1 77 {wp06) -7,576.10 686.36 5,938,277.00 559,409.00 - Point 3,502.00 1J-159 L1 T3 {wp06) -3,952.87 714.59 5,941,900.00 559,409.00 - Point 3,563.00 1J-159 L1 T1 {wp06) -1,453.65 855.07 5,944,400.00 559,530.00 - Point 3,483.00 1J-159 L1 T5 {wp06) -5,852.99 699.78 5,940,000.00 559,409.00 - Point 3,529.00 1J-159 L1 T2 {wp06) -2,852.82 726.16 5,943,000.00 559,412.00 - Point 3,473.00 1J-159 L1 T6 {wp06) -6,603.04 693.94 5,939,250.00 559,409.00 - Point Prognosed Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (ft) (ft) (") (~~) 2,392.47 2,207.00 10-3/4 13-112 4,588.40 3,547.88 7-518 9-7/8 11,205.17 3,474.00 4-1/2 6-3l4 12/14/2005 5:55:47PM Page 6 of 6 COMPASS 2003.11 Build 48 ~~/~ • ~ Conoco hillips Alaska ConocoPhillips Alaska (Kuparuk) Kuparuk River Unit Kuparuk 1J Pad Plan 1J-159 1J-159 L1 Anticollision Summary 14 December, 2005 1-IALLIF~t.#~TD1V ORIGINAL 51'Rl'El' PROGILI\I Ua1e: 2nOS 12-ORT00:0U:W Validated: Yes Yersimr Ueplh From lleplh Ta G~ney/Plan Taal 2R.nn Roo.oo c6-c51t0-ss 800.0[1 JSR8.39 \IRy+lF7t-AK-CAZS(' JSBR iY 11205.1& IJ-159 LI (wp06) \M~D+IFIt-AK-CAZSC 270 so 33~ 300 240 90 1 ConocoPhillips Alaska (Kupamk) Ddlling & Wells Slot West Sak Calculation Method: Minimum Curvature Emor System: ISCWSA Scan Method: Trav. Cylinder North Error Surface: Elliptical Conic Warning Method: Rules Based 30 25 2 60 1 5 1 1 120 25 210 150 180 Travelling Cylinder :1yinKlth (TFp+;~)1) [oj Ys Centre t0 Centre Separation [15 ft/in[ SECTION DETAILS From Colour To MD 0 4500 4500 5000 180 5000 5500 5500 6000 6000 6500 6500 7000 Travelling Cylinder Azimuth (TFO+AZI) ~°] vs Centre to Centre Separation ]75 ft/in] 7000 - 7soo 7500 8000 8000 8500 8500 9000 9000 9500 9500 10000 REFERENCE INFORMATION 10000 10500 10500 11000 Co-ordinate (W E) Reference: Well Plan iJ-159, True North Vertical (ND) Reference: Planning RKB @ 109.OOtt (Doyon 141 (28+81)) 11000 11500 SeMion (VS) Reference: Slot - (D.OON, O.OOE) Measured Depth Reference: Planning RKB @ 109.00(1 (Doyon 141 (28+81)) Calculation Method: Minimum Curvature Sec MD Inc Azi ND +N/-S +FJ-W DLeg TFace VSec Target 1 4588.3980.000 184.00 3547.68 -972.84 905.83 0.00 0.000 972.84 2 4600.3981.908 184.00 3549.76 -984.67 905.01 15.90 0.000 964.67 3 4630.3981.908 184.00 3553.99-1014.29 902.94 0.00 0.000 1014.29 4 4814.9990.696 186.83 3565.68.1197.49 885.54 5.00 17.937 1197.49 5 5045.4890.696 186.63 3563.06.1426.32 858.13 0.00 0.000 1426.32 6 5072.9789.658 185.93 3563.00.1453.65 855.07 5.00139.009 1453.fi5 1J-159 L1 Ti (wp06) 7 5156.3091.463 187.66 3562.18-1536.38 845.22 3.00 43.782 1536.38 B 5695.2591.463 187.66 3543.32.2268.50 746.75 0.00 0.000 2266.50 9 6130.5391.366 180.60 3537.47.2502.94 729.82 3.00 -90.535 2502.94 106480.5391.366 180.60 3529.00.2852.82 726.16 0.00 0.000 2852.82 1J•159 L1 T2 (wp06) 116481.5391.406 180.60 3526.98.2853.82 726.15 2.00 7.597 2853.82 127580.9791.406 180.60 3502.00-3952.87 714.59 0.00 0.000 3952.87 1J-159 L1 T3 (wp06) 137728.3888.463 180.43 3502.17.4100.26 713.26 2.00176.604 4100.26 148281.2586.463 180.43 3517.00-4652.91 709.13 0.00 0.000 4652.91 1J-159 L1 T4 (wp06) 158451.2991.864 180.45 3516.52-4822.92 707.83 2.00 0.333 4822.92 169481.9491.864 180.45 3483.00.5852.99 699.78 0.00 0.000 5852.99 1J-159 L1 T5(wp06) 179539.1090.720 180.45 3481.71.5910.14 699.34 2.00179.927 5910.14 180232.0890.720 180.45 3473.00-6603.04 693.94 0.00 0.000 6603.04 1J-159 L1 T6 (wp06) 190271.8589.925 180.45 3472.78.6642.81 693.63 2.00179.996 6642.81 201205.1889.925 180.45 3474.00-7576.10 686.36 0.00 0.000 7576.10 1J-159 L1 T7 (wp06) NAD 27 ASP Zone 4 : WELL DETAILS: Plan iJ-159 ANTI-COLLISION SETTINGS Ground Level: 81.00 Interpolation Method: MD Interval: 50Stations +NI-S +E/-W Northing Easting Latittude Longitude Depth Range From: 4588.39 To 11205.18 0.00 0.00 5945846.80 558663.71 70°15'45.551N 149°31'32.897W Maximum Range:1287.20945714833 Reference: Plan: 1J-159 Lt (wp06) ~-', Cc~rrocoP~illi~s Aia7ka Halliburton Energy Services Anticollision Report Company: ConocoPhillips Alaska (Kuparuk) Project: Kuparuk River Unit Reference Site: Kuparuk 1J Pad Site Error: O.OOft Reference Well: Plan 1J-159 Well Error: O.OOft Reference Wellbore 1J-159 L1 Reference Design: 1J-159 L1 (wp06j Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Output errors are at Database: Offset TVD Reference: Hs+-~u~wRTatlu 5p~erry ~r~liing Seni+3ce~ Well Plan 1 J-159 Planning RKB @ 109.OOft (Doyon 141 (28+g1)) Planning RKB @ 109.OOft (Doyon 141 (28+81)) True Minimum Curvature 1.00 sigma EDM 2003.11 Single User Db Offset Datum Reference 1J-159 L1 (wp06j Filter type: GLOBAL FILTER APPLIED: All wellpaths within 200'+ 100!1000 of referen Interpolation Method: MD Intenra150.00ft Error Model: ISCWSA Depth Range: 4,588.40 to 11,205.18ft Scan Method: Trav. Cylinder North Results Limited by: Maximum center-center distance of 1,317.72ft Error Surface: Elliptical Conic Warning Levels evaluated at: 0.00 Sigma Survey Tool Program Date 12/14/2005 From To (ft) (ft) Survey (Wellbore) 28.00 800.00 1J-159 (wp06) (1J-159) 800.00 4,588.39 1J-159 (wp06) (1J-159) 4,588.39 11,205.18 1J-159 L1 (wp06) (1J-159 L1) Tool Name Description CB-GYRO-SS Camera based gyro single shot MW D+IFR-AK-CAZ-SC MW D+IFR AK CAZ SCC MW D+IFR-AK-CAZ-SC MW D+IFR AK CAZ SCC CC -Min centre to center distance or covergent point, SF -min separation factor, ES -min ellipse separation 12/14/2005 6:14:54PM Page 2 of 3 COMPASS 2003.11 Buvdd 48 ~-, ~t~t'1C3Ct~~ Company: Project: Reference Site: Site Error: '~j~l~?5 Aaas'ka ConocoPhil4ips Alaska (Kuparuk) Kuparuk River Unit Kuparuk 1J Pad O.OOft Reference Well: Plan 1J-159 Well Error: O.OOft Reference Wellbore 1J-159 L1 Reference Design: 1J-159 L1 (wp06) HaUiburton Energy Services HALLtBtJRTC~N Anticollision Report °~°°~~ ~---~~~ °-~~-~ Sp$my bll^lllfng Service Local Co-ordinate Reference: Well Plan 1J-159 TVD Reference: Planning RKB @ 109.OOft (Doyon 141 (28+81)) MD Reference: Planning RKB @ 109.OOft (Doyon 141 (28+81 )) North Reference: True Survey Calculation Method: Minimum Curvature Output errors are at 1.00 sigma Database: EDM 2003.11 Single User Db Offset TVD Reference: Offset Datum Summary Site Name .Offset Well -Wellbore -Design Kuparuk 1J Pad 1J-154 - 1J-154 - 1J-154 Rig 1J-154 -1J-154 L1 - 1J-154 L1 1J-154 - 1J-154 L2 - 1J-154 L2 1J-164 -1J-164 L2 - 1J-164 L2 1J-168 -1J-168 - 1J-168 Rig 1J-168 - 1J-168 L1 - 1J-168 L1 Rig 1J-168 - 1J-168 L2 - 1J-168 L2 1J-168 - 1J-168 L2 PB1 - 1J-168 L2 P61 Rig Plan 1J-102 - 1J-102 - 1J-102 (wp03) Plan 1J-102 - 1J-102 L1 - 1J-102 L1 (wp03) Plan 1J-102 - 1J-102 L2 - 1J-102 L2 (wp03) Plan 1J-103 -Plan 1J-103 - 1J-103 (wp01) BHI Plan 1J-105 -Plan 1J-105 - 1J-105 (wp01) BHI Plan 1J-107 -Plan 1J-107 - 1J-107 (wp01) BHI Plan 1J-109 -Plan 1J-109 - 1J-109 (wp03) (S GullH Plan 1J-111 -Plan 1J-111 - 1J-111 (wp01) Plan 1J-136 - 1J-136 -1J-136 (wp03) Plan 1J-136 - 1J-136 L1 - 1J-136 L1 (wp03) Plan 1J-137 - 1J-137 - 1J-137 (wp03) Plan 1J-137 - 1J-137 L1 - 1J-137 L1 (wp03) Plan 1J-152 - 1J-152 - 1J-152 (wp04) Plan 1J-152 - 1J-152 L1 - 1J-152 L1 (wp04) Plan 1J-152 - 1J-152 L2 - 1J-152 L.2 (wp04) Plan 1J-156 -Plan 1J-156 - 1J-156 (wp02) Plan 1J-158 - 1J-158 -1J-158 (wp2A) BHI Plan 1J-159 - 1J-159 - 1J-159 (wp06) Plan 1J-159 - 1J-159 L2 - 1J-159 L2 (wp06) Plan 1J-160 -Plan 1J-160 - 1J-160 (wp01) BHI Plan 1J-162 - 1J-162 -1J-162 (wp03.1-North Heel) Plan 1J-162 - 1J-162 L1 - 1J-162 L1 (wp3.1) Plan 1J-162 - 1J-162 L2 - 1J-162 L2 (wp3.1) Plan 1J-170 -Plan 1J-170 - 1J-170 (wp02) Plan 1J-184 - 1J-184 -1J-184 (wp08) Plan 1J-184 - 1J-184 L1 - 1J-184 L1 (wp08) W SP-13 - W SP-13 - W SP-13 Reference Offset Centre to Measured Measured Centre Depth Depth Distance (ft} (ft) (ftj 8,570.90 8,550.00 1,243.85 10,027.69 10, 000.00 1,185.47 10, 794.00 10, 750.00 1, 201.42 4,600.39 5,799.98 1,049.26 4,590.48 5,799.98 1,035.38 4,630.39 5,850.00 1,038.46 9,275.76 6,650.00 1,136.39 9,275.76 6,650.00 1,136.39 11,201.97 8,450.00 219.88 11,201.97 8,450.00 219.88 4,599.98 4,599.98 0.19 10,905.05 10,900.09 74.61 11,197.97 8,399.97 1,082.65 11,197.97 8,399.97 1,082.65 4,588.39 3,950.00 431.43 No-Go Allowable Distance Deviation Warning (ft} from Plan (ft) 192.62 1,051.23 Pass -Major Risk 238.59 946.88 Pass -Major Risk 260.92 940.50 Pass -Major Risk Out of range Out of range Out of range Out of range Out of range 102.21 947.06 Pass -Major Risk 103.04 932.33 Pass -Major Risk 104.98 933.48 Pass -Major Risk Out of range Out of range Out of range Out of range Out of range 204.67 931.72 Pass -Major Risk 204.46 931.94 Pass -Major Risk 79.06 140.82 Pass - No Errors 79.06 140.82 Pass - No Errors Out of range Out of range Out of range Out of range Out of range 1.57 -1.38 FAIL - No Errors 38.67 35.94 Pass - No Errors Out of range Out of range Out of range Out of range Out of range 286.91 795.75 Pass -Major Risk 286.96 795.69 Pass -Major Risk 89.34 342.09 Pass -Major Risk CC -Min centre to center distance or covergent point, SF -min separation factor, ES -min ellipse separation 17/14/2005 6:14:54PM Page 3 of 3 COMPASS 2003.11 Bind 4$ ORIG~nin". 1~-159Li~rillin Hazards~umma (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 wei ht. Stuck Pipe Low Good hole cleaning, PWD tools, hole o ener runs decreased mud wei ht Lost Circulation Low Reduced um rates, mud rheolo , LCM Hole Swabbing on Trips Moderate Trip speeds, proper hole filling (use of trip sheets , um in out, backreamin ~ 1J-159L1 Drilling Hazards Summary 1/16/2006 9:08 AM Tubing String 4-112" 12.6#, L-80, IBTM 3.956" ID, 3.833" Drift Camco 4-112" X 1" KBMG, Gas Recombination LM, Camco 4-1 /2" X 1" KBMG 10.314" 68# Casing Shoe, set @ 2392' MD, 2207' TVD Bottom of Motor Centralizer Centralift 418 HP KMHFER 2610 198 D-sand Window at 4285' MD, i 3482' TVD 4-112" 12.6# L-BO Slotted Liner Every Joint ~onocoPhillips West Sak 7-5/8" Producer 1 J-159 Tri-Lateral Completion 'D' Sand Lateral 3-1 /2" Bent Joint 3-1 /2" Guide Shoe 4.112" Liner Shoe, 12.6#, L-80 IBTM Set @ 10901' MD, 3399' TVD 4-1/2" X 7-SIB" Model 'B' HOOK Hanger 5-112" X 7-518" ZXP~ Liner Top Packer with Hold Downs .~-- 5-112" X 7-SIB" ZXP Liner Top Packer with Hold Downs Casing Sealbore Receptacle 4.75" ID - Tubing Swivel, 4-112" - Orienting Profile Automatic Alignment of LEM - Positive Latching Collet Indicates Correct Location ~ Seal Bore for Lateral Isolation - 3.68" ID ~ Access Window Positive Lateral Access Via Thru-Tubing Diverter Seal Bore for Lateral Isolation - 3.68" ID Isolation Seal Asembly 4.75" Seal OD 3.875" Seal ID Casing Sealbore Receptacle 4.75"ID l 4-1 " X 7-5/8" Seal Borr 3.68" ID 4-112" 12.6# T Orienting Proille ((~~ r(~~/(~~~~ (( ' V ~ '1Jt„i °~ai B-sand Window 'g' Sand Lateral at 4588' MD, 3548' TVD 4-112" 12.6# L-80 Slotted As Planned Baker Oil Tools Late ral Entry Module (LEM) With Diverters and Isolation Lateral Access Diverter Lateral Isolation Diverter GS Running Tool Smng Installed Installed (3.00" Lateral Orin) (2.50" ID Mainbore DrIR) 'GS' Profile for ` ~'-Coil Connector 1RunninglRetrieving mi ~ j (1 00' Length) l ~' 1 !~ S ap INSnap Out r /P sitive Locahng ~+ ~ _ ~Back Pressure Valve ~ Collet '. I (1 60' Length) Lateral lsolanon ~~ ' I~ it Flow•Thru Swivel ~ ~ Seals (1.25' Length) / Lateral Diverter ~ Hydraulic Ramp Disconnect -• - Isolation/ Mainbore (1.50'Length) ~ Diverter Sleeve ~~ GS Spear (1.50' Length) ~ ~~ ~ Lateral lsolatlon Seals 8.85 ft Approx. DAC LJ ll 'Jars may be required in highly deviate0 18.5' Diverter Length 18.5' Sleeve Length I or deep appltcaYOns 16' approx lenothl. i Liner Every Joint / 3-112" Bent Joint ..~._.-_.~ ..~_..-__-_L~.._ ~ 3-t i2" Guide Shoe 4.112" Liner Shoe, 12.6#- L-80 IBTM Set @ 11205' MD, 72' TVD 3.562" DB Nipple 5-112" X 7-518" ZXP Liner Top Packer with Hold Downs 5-112" X 7-518" Flex Lock Liner Hanger I Packer Assembly at Liner Hanger +/-4700'MD Casing , Sealbore Receptacle, 4.75"ID m Baker Hughes 2005. This tloeumant may not be reprotlucatl or tllsldbutetl, In whole or In part, In any form or by any m s electronic or mechankal, Inclutling photocopying, recartling, or by eny InformaROn storage ens relrlavel system now known or haraafier Invented, without wrhten permisalon /rom Beker Hughes Int. Seal Assembly 4.75" Seal OD - 3.875"ID 'D' SanA Ilnrlulatinn I ataral 4-t12" 12.611 L-80 Slotted ~ Liner Every Joint 4-112" Eccentdc ~}\ / ,Guide Shoe Equipment Specifications 4-112" X 7-518" HOOK Hanger Mainbore Drift: 5.32" Mainbore Drift, with diverter: 4.63" Lateral Drift, no diverter or LEM: 3.88" Lateral Drift, w/diverter, no LEM: 3.88" Lateral/Mainbore Diverter OD: 6.75" 4-112" Lateral Entry Module Mainbore Drift: 3.65" Mainbore Drift, w/ isolation sleeve: 2.50" Lateral Drift, w/ coil diverter: 3.00" OD of Diverter and Sleeve: +/- 3.89" Diverter and Sleeve Length: +/- 18.5' 4-112" Casing Shoe, 12.6#, L-80 IBTM Set @ 7857' MD, 3641' TVD 7-5/B" Casing Shoe, Set at @ 5556' MD, 3698' TVD, 84 deg inc 2006 W est Bak r-6/a" Trl-lateral Completion - Protlucer ~Dr~wn BY; loon! try 16, 3006 Marc D. Kuck • • • • TRANSMITTAL LETTER CHECKLIST WELL NAME ~c-~.~ ~ ~ / ~~ ~" PTD# ~'~~Q ~~~~ '~~ Development Service Exploratory Stratigraphic Test 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 ~ ~ ~ / ~`~ ~~ (If last two digits in permit No.~, -c:~ ,API No. 50-C~Z -Z.~~ .7 - API number are between 60-69) Production should continue to be reported as a function of the original API number stated above. PILOT HOLE In accordance with 20 AAC 25.005(f), all records, data and logs 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 / infect 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 SAMPLE in no greater than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. Rev: 1/05/06 C:\jody\trans m ittal_checklist t • ^~^ ~ y ~ ~ ~ ~ , a, o a~ o. , : y y m ~ , c ~ a 3, ~ °' ~ , 3, , , r, , O L ~ a ~ ~ ~ ~ ~ ~ y. y' C~ N~ C' 7~ ] z U ~ v. ~ 3. ~ n E' o ~ w ~ ~ o, ~ a~' ~ ~ °o, m, o. ~, o y. ~ o (` U, ~, N. ~ ~ ~ ~ ~ ~ ~ ~ ~ ~~ X10'1, cD, ~ ~ ~ ~ Q ~ ~ a - ~, -a. ~, c. t, a: c. ~ a. y , ~ is i ~ ~' 3 Q ~ ~~ ~ c. ~ w~ ~ V~ y, Q C, ~ ~ ~ ~ ~ ~ ~ ~ ~ ,~~ ~~ N• N ~ ~ w a ~~ m ~, W, ~ y, ~ ~ ~ ~~ N. ~ y y' U T ~ O, ~ ~ N ,fl ~ ~ ~ ~ ~ O 2' w ~ N. N. ~ V c O^ N ~ O ~' ~~ N. ~ a O O, ~ O. O. 3~ ~, ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ t~ ~, ~ ~~ y~ f ~ >' O~ N d ~ p~ ~ , ~ ~ ~ Y m ~ c O. ~ ~, ~ , ~ ~ E ~ c ~ ~ 3 'N, ~, ~ ~ m °~ ~ o ai o m N ° o ~ w N, .~ ° 0 y' ~' ~ c y' 3' ~ ~ ' o. ~, ~ ~ C N Z ~ Y. f M. O N ~~ ~~ 0 ~ ~ ~ ~ ~ ~ ~ N f C U' w, ~~ ~ p: ~ ~ ~ T Y ~~ ~~ V U. c ~ ~ ~, N a y n , 0 ~, y, a ~~ ~ ~ ~ 7. s U ~~ , ~~ p, to ~ ~, y. ~~ 0.' ~ L~ ~ U• , .y.: m j Z N, ~, N, O~ ~~ ~ ~ ~ ~~ ~, ~~ O, O~ O~ m ~ `, ~~ ~~ Q~ N~ ~ X O f6 w , a~ ~ ~ o , a, y~ N, Uh y~ y~ y~ y y N, N, N, N, N, N, U/~ y~ y~ y y N, N, N, N, N a, a, a, a, a, a, a, a, O, a, y, N, y: a, N, ~ y a, N, y~ y, y, y~ N, N, N, N, ~ O, a, y, t/1, N, N, a, a, a, O. Z. ~', >-, ~', ~, ~, >', ~, ~", >', ~-, }', ~ Z, Z, Z, Z Z, Z, Z, Z, Z, Z, } Z, }~ Z, ~-~ }~ }, }: }~ Z, Z, }~ }~ Z, Z, Z T ~~ E. 3. ~ , - E. o , o. ~ ~ , , ~ ~ a1. ~ ~ c ~ y o o p. o ~ 'y ~° ~, o ~ L o~ E °~ Q I . , ~ E 3, ~, 3. o °~ ~ ~ m a'Ui N: y' y. ~ y. ~, rn ~ ~ y. ~ ~ L, ~ ~, E, ~, ~ a, ~ ~ y ~ `o. 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G ~ ~ C Q. d ~ `~ C N n ~ Q (n U ~~ a a , w a ' ~ a • Well History File APPENDIX C7 Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically . organize this category of information. • Sperry-Sun Drilling Services LIS Scan Utility $Revision: 3 $ LisLib $Revision: 4 $ Tue May 30 15:53:15 2006 Reel Header Service name .............LISTPE Date .....................06/05/30 Origin ...................STS Reel Name ................UNKNOWN Continuation Number......01 Previous Reel Name.......UNKNOWN Comments .................STS LIS Writing Library Tape Header Service name .............LISTPE Date .....................06/05/30 Origin ...................STS Tape Name ................UNKNOWN Continuation Number......01 Previous Tape Name.......UNKNOWN Comments .................STS LIS Writing Library Physical EOF ao~ -005 • c 3 `}3s Scientific Technical Services Scientific Technical Services Comment Record TAPE HEADER West Sak MWD/MAD LOGS WELL NAME: 1J-159 L1 API NUMBER: 500292329760 OPERATOR: ConocoPhillips Alaska, Inc. LOGGING COMPANY: Sperry Drilling Services TAPE CREATION DATE: 30-MAY-06 JOB DATA MWD RUN 2 MWD RUN 6 MWD RUN 7 JOB NUMBER: MW0004212091 MW0004212091 MW0004212091 LOGGING ENGINEER: P. ORTH T. GALVIN T. GALVIN OPERATOR WITNESS: D. GLADDEN M. THORTON M. THORTON MWD RUN 8 MWD RUN 9 JOB NUMBER: MW0004212091 MW0004212091 LOGGING ENGINEER: T. GALVIN T. GALVIN OPERATOR WITNESS: M. THORTON M. THORTON SURFACE LOCATION SECTION: 35 TOWNSHIP: 11N RANGE: l0E FNL: FSL: 2035 FEL: 2545 FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: 109.00 GROUND LEVEL: 81.00 WELL CASING RECORD OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 1ST STRING 9.875 10.750 2365.0 2ND STRING 6.750 7.875 4565.0 3RD STRING PRODUCTION STRING REMARKS: 1. ALL DEPTHS ARE MEASURED DEPTHS UNLESS OTHERWISE • • NOTED. THESE DEPTHS ARE BIT DEPTHS. 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTHS (TVD). 3. THIS WELL IS AN OPEN-HOLE SIDETRACK EXITING THE 1J-159 L1 PB2 WELLBORE AT 6294'MD/3541'TVD. 4. MWD RUN 1 WAS DIRECTIONAL ONLY - NO DATA ARE PRESENTED. 5. MWD RUNS 2,7-9 COMPRISED DIRECTIONAL, DUAL GAMMA RAY (DGR) UTILIZING GEIGER-MUELLER TUBE DETECTORS, ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4), AND PRESSURE WHILE DRILLING (PWD) RUN 7 ALSO INCLUDED GEO-PILOT ROTARY STEERABLE BHA (GP) MWD RUNS 7-9 INCLUDED AT-BIT INCLINATION (ABI) MWD RUN 2 POROSITY DATA ARE PRESENTED FOR THE 1J-159 PB1 WELLBORE ONLY. 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 1,2,6-9 REPRESENT WELL 1J-159 L1 WITH API#: 50-029-23297-60. THIS WELL REACHED A TOTAL DEPTH (TD) OF 11187'MD/3506'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.......06/05/30 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 2325.5 11127.5 RPD 2345.0 11134.5 RPS 2345.0 11134.5 RPM 2345.0 11134.5 FET 2345.0 11134.5 RPX 2345.0 11134.5 ROP 2370.5 11187.0 BASELINE CURVE FOR SHIFTS: • • CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH MERGED DATA SOURCE PBU TOOL CODE MWD MWD MWD MWD MWD BIT RUN NO MERGE TOP MERGE BASE 2 2325.5 4565.0 6 4565.5 4606.0 7 4606.0 4687.0 8 4687.5 6294.0 9 6294.5 11187.0 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 Servi ce Unit Min Max Mean Nsam Reading Reading DEPT FT 2325.5 11187 6756.25 17724 2325.5 11187 RPD MWD OHMM 0.64 2000 48.7482 17580 2345 11134.5 RPM MWD OHMM 0.77 2000 40.5949 17580 2345 11134.5 RPS MWD OHMM 0.54 2000 38.752 17580 2345 11134.5 RPX MWD OHMM 0.42 1793.2 35.8423 17580 2345 11134.5 FET MWD HOUR 0.19 168.87 1.85089 17580 2345 11134.5 GR MWD API 19.79 123.79 66.1237 17605 2325.5 11127.5 ROP MWD FT/H 0.24 1731.25 169.943 17634 2370.5 11187 First Reading For Entire File..........2325.5 Last Reading For Entire File...........11187 File Trailer Service name .............STSLIB.001 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/05/30 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.......06/05/30 Maximum Physical Record..65535 • z File Type ................LO Previous File Name.......STSLIB.-0O1 Comment Record FILE HEADER FILE NUMBER: 2 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 2 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 2325.5 4565.0 RPD 2345.0 4565.0 RPM 2345.0 4565.0 RPX 2345.0 4565.0 RPS 2345.0 4565.0 FET 2345.0 4565.0 ROP 2370.5 4565.0 LOG HEADER DATA DATE LOGGED: 18-FEB-06 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 68.18 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT) 4565.0 TOP LOG INTERVAL (FT) 2370.0 BOTTOM LOG INTERVAL (FT) 4565.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 25.9 MAXIMUM ANGLE: 81.9 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 216265 EWR4 ELECTROMAG. RESIS. 4 157645 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) 9.875 DRILLER'S CASING DEPTH (FT) 2365.0 BOREHOLE CONDITIONS MUD TYPE: Fresh Water Gel MUD DENSITY (LB/G) 9.00 MUD VISCOSITY (S) 51.0 MUD PH: 8.9 MUD CHLORIDES (PPM): 250 FLUID LOSS (C3) 5.0 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT) 2.900 65.0 MUD AT MAX CIRCULATING TERMPERATURE: 1.950 100.0 MUD FILTRATE AT MT: 3.000 65.0 MUD CAKE AT MT: 5.000 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 Specifica tion Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 RPD MWD020 OHMM 4 1 68 4 2 RPM MWD020 OHMM 4 1 68 8 3 RPS MWD020 OHMM 4 1 68 12 4 RPX MWD020 OHMM 4 1 68 16 5 FET MWD020 HOUR 4 1 68 20 6 GR MWD020 API 4 1 68 24 7 ROP MWD020 FT/H 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 2325.5 4565 3445.25 4480 2325.5 4565 RPD MWD020 OHMM 0.64 2000 28.5345 4441 2345 4565 RPM MWD020 OHMM 0.77 1749.02 14.0939 4441 2345 4565 RPS MWD020 OHMM 0.54 1136.14 12.1316 4441 2345 4565 RPX MWD020 OHMM 0.42 1440.52 11.4283 4441 2345 4565 FET MWD020 HOUR 0.19 113.21 2.04511 4441 2345 4565 GR MWD020 API 19.79 117.61 67.0693 4480 2325.5 4565 ROP MWD020 FT/H 3.3 481.14 173.353 4390 2370.5 4565 First Reading For Entire File..........2325.5 Last Reading For Entire File...........4565 File Trailer Service name ........... ..STSLIB.002 Service Sub Level Name. .. Version Number......... ..1.0.0 Date of Generation..... ..06/05/30 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.......06/05/30 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: 6 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH ROP 4565.5 4606.0 LOG HEADER DATA DATE LOGGED: 24-FEB-06 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 66.37 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT) 4606.0 • TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: 4565.0 4606.0 .0 .0 TOOL NUMBER 184054 6.750 4565.0 Mineral Oil Base 8.80 69.0 .0 111000 2.0 .000 .0 .000 70.5 .000 .0 .000 .0 Data Format Specification Record Data Record Type ..................0 Data Specification Block Type.....0 Logging Direction .................DOwn Optical log depth units...........Feet Data Reference Point ..............Undefined Frame Spacing .....................60 .lIN Max frames per record .............Undefined Absent value ......................-999 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD060 FT/H 4 1 68 4 2 Name Service Unit Min Max Mean Nsam DEPT FT 4565.5 4606 4585.75 82 ROP MWD060 FT/H 1.21 49.72 19.6425 82 First Reading For Entire File.... ......4565.5 Last Reading For Entire File..... ......4606 File Trailer Service name .............STSLIB.003 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/05/30 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.004 First Last Reading Reading 4565.5 4606 4565.5 4606 • • Physical EOF File Header Service name .............STSLIB.004 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/05/30 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: 7 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH RPX 4565.5 4687.0 FET 4565.5 4687.0 GR 4565.5 4687.0 RPM 4565.5 4687.0 RPD 4565.5 4687.0 RPS 4565.5 4687.0 ROP 4606.5 4687.0 LOG HEADER DATA DATE LOGGED: 25-FEB-06 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 66.37 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT) 4687.0 TOP LOG INTERVAL (FT) 4606.0 BOTTOM LOG INTERVAL (FT) 4687.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 86.8 MAXIMUM ANGLE: 93.1 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 184054 EWR4 Electromag Resis. 4 162742 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) 6.750 DRILLER'S CASING DEPTH (FT) 4565.0 BOREHOLE CONDITIONS MUD TYPE: Mineral Oil Base MUD DENSITY (LB/G) 8.80 MUD VISCOSITY (S) 70.0 MUD PH: .0 MUD CHLORIDES (PPM): 34000 FLUID LOSS (C3): 3.0 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT) .000 .0 MUD AT MAX CIRCULATING TERMPERATURE: .000 93.0 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 MWD070 OHMM 4 1 68 4 2 RPM MWD070 OHMM 4 1 68 8 3 RPS MWD070 OHMM 4 1 68 12 4 RPX MWD070 OHMM 4 1 68 16 5 FET MWD070 HOUR 4 1 68 20 6 GR MWD070 API 4 1 68 24 7 ROP MWD070 FT/H 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 4565.5 4687 4626.25 244 4565.5 4687 RPD MWD070 OHMM 5.13 149.12 64.0626 244 4565.5 4687 RPM MWD070 OHMM 12.21 101.1 48.0081 244 4565.5 4687 RPS MWD070 OHMM 13.45 82.42 43.2878 244 4565.5 4687 RPX MWD070 OHMM 14.77 174.81 41.2061 244 4565.5 4687 FET MWD070 HOUR 0.64 168.87 60.4152 244 4565.5 4687 GR MWD070 API 41.74 76.55 59.2319 244 4565.5 4687 ROP MWD070 FT/H 0.24 250.29 89.8858 162 4606.5 4687 First Reading For Entire File..........4565.5 Last Reading For Entire File...........4687 File Trailer Service name .............STSLIB.004 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/05/30 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.......06/05/30 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: 8 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH RPS 4687.5 6294.0 FET 4687.5 6294.0 RPM 4687.5 6294.0 RPX 4687.5 6294.0 GR 4687.5 6294.0 RPD 4687.5 6294.0 ROP 4687.5 6294.0 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: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 Electromag Resis. 4 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: 27-FEB-06 Insite 66.37 Memory 6294.0 4687.0 6294.0 86.2 93.4 TOOL NUMBER 184054 162742 6.750 4565.0 Mineral Oil Base 8.80 70.0 .0 27000 2.2 .000 .0 .000 115.0 .000 .0 .000 .0 Data Format Specification Record Data Record Type ............. .... .0 Data Specification Block Type .... .0 Logging Direction ............ .... .Down Optical log depth units...... .... .Feet Data Reference Point ......... .... .Undefined Frame Spacing ................ .... .60 .lIN Max frames per record ........ .... .Undefined Absent value ................. .... .-999 Depth Units .................. .... . Datum Specification Block sub -type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 RPD MWD080 OHMM 4 1 68 4 2 RPM MWDO80 OHMM 4 1 68 8 3 RPS MWD080 OHMM 4 1 68 12 4 RPX MWD080 OHMM 4 1 68 16 5 FET MWD080 HOUR 4 1 68 20 6 GR MWD080 API 4 1 68 24 7 ROP MWD080 FT/H 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 4687.5 6294 5490.75 3214 4687.5 6294 RPD MWD080 OHMM 17.85 300.75 61.2495 3214 4687.5 6294 RPM MWD080 OHMM 15.82 137.34 53.1112 3214 4687.5 6294 RPS MWD080 OHMM 16.2 117.93 51.2366 3214 4687.5 6294 RPX MWD080 OHMM 16.3 228.91 47.7466 3214 4687.5 6294 FET MWD080 HOUR 0.21 19.34 0.801534 3214 4687.5 6294 GR MWD080 API 37.91 88.03 60.6694 3214 4687.5 6294 ROP MWD080 FT/H 0.42 435.25 163.432 3214 4687.5 6294 First Reading For Entire File.... ......4687. 5 Last Reading For Entire File..... ......6294 File Trailer Service name .. ...........STSLIB.005 Service Sub Le vel Name... Version Number ...........1.0.0 Date of Genera tion.......06/05 /30 Maximum Physic al 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.......06/05/30 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: 9 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH RPM 6294.5 11134.5 ROP 6294.5 11187.0 RPX 6294.5 11134.5 RPS 6294.5 11134.5 RPD 6294.5 11134.5 GR 6294.5 11127.5 FET 6294.5 11134.5 LOG HEADER DATA DATE LOGGED: O1-MAR-06 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 66.37 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT) 11187.0 TOP LOG INTERVAL (FT) 6294.0 BOTTOM LOG INTERVAL (FT) 11187.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION {DEG MINIMUM ANGLE: 85.2 MAXIMUM ANGLE: 92.4 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 184054 EWR4 Electromag Resis. 4 162742 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) 6.750 DRILLER'S CASING DEPTH (FT) 4565.0 BOREHOLE CONDITIONS MUD TYPE: Mineral Oil Base MUD DENSITY (LB/G) 8.80 MUD VISCOSITY (S) 70.0 MUD PH: .0 MUD CHLORIDES (PPM): 23000 FLUID LOSS (C3): 2.0 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT) .000 .0 MUD AT MAX CIRCULATING TERMPERATURE: .000 118.4 MUD FILTRATE AT MT: .000 .0 MUD CAKE AT MT: .000 .0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format Specification Record Data Record Type ..................0 Data Specification Block Type.....0 Logging Direction .................DOwn Optical log depth units...........Feet Data Reference Point ..............Undefined Frame Spacing .....................60 .lIN Max frames per record .............Undefined Absent value ......................-999 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 RPD MWD090 OHMM 4 1 68 4 2 RPM MWD090 OHMM 4 1 68 8 3 RPS MWD090 OHMM 4 1 68 12 4 RPX MWD090 OHMM 4 1 68 16 5 FET MWD090 HOUR 4 1 68 20 6 GR MWD090 API 4 1 68 24 7 ROP MWD090 FT/H 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 6294.5 11187 8740.75 9786 6294.5 11187 RPD MWD090 OHMM 7.25 2000 53.4847 9681 6294.5 11134.5 RPM MWD090 OHMM 6.47 2000 48.4097 9681 6294.5 11134.5 RPS MWD090 OHMM 6.02 2000 46.7045 9681 6294.5 11134.5 RPX MWD090 OHMM 4.71 1793.2 42.9545 9681 6294.5 11134.5 FET MWD090 HOUR 0.23 10.69 0.634124 9681 6294.5 11134.5 GR MWD090 API 37.19 123.79 67.6729 9667 6294.5 11127.5 ROP MWD090 FT/H 0.94 1731.25 173.137 9786 6294.5 11187 First Reading For Entire File..........6294.5 Last Reading For Entire File...........11187 File Trailer • • Service name .............STSLIB.006 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/05/30 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.007 Physical EOF Tape Trailer Service name .............LISTPE Date .....................06/05/30 Origin ...................STS Tape Name ................UNKNOWN Continuation Number......01 Next Tape Name...........UNKNOWN Comments .................STS LIS Writing Library. Scientific Technical Services Reel Trailer Service name .............LISTPE Date .....................06/05/30 Origin ...................STS Reel Name ................UNKNOWN Continuation Number......01 Next Reel Name...........UNKNOWN Comments .................STS LIS Writing Library. Scientific Technical Services Physical EOF Physical EOF End Of LIS File 3 ao~ - Ov5 Sperry-Sun Drilling Services LIS Scan Utility $Revision: 3 S LisLib $Revision: 4 $ Tue May 30 15:42:22 2006 Reel Header Service name ............ .LISTPE Date .................... .06/05/30 Origin .................. .STS Reel Name ............... .UNKNOWN Continuation Number..... .01 Previous Reel Name...... .UNKNOWN Comments ................ .STS LIS Writing Library Tape Header Service name ............ .LISTPE Date .................... .06/05/30 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 MWD RUN 2 JOB NUMBER: MW0004212091 LOGGING ENGINEER: P. ORTH OPERATOR WITNESS: D. GLADDEN SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD #r3 ~i3~/ Scientific Technical Services Scientific Technical Services 1J-159 L1 PB1 500292329771 ConocoPhillips Alaska, Inc. Sperry Drilling Services 30-MAY-06 MWD RUN 6 MWD RUN 7 MW0004212091 MW0004212091 T. GALVIN T. GALVIN M. THORTON M. THORTON 35 11N l0E 2035 2545 109.00 81.00 OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 1ST STRING 9.875 10.750 2365.0 2ND STRING 6.750 7.875 4565.0 3RD STRING PRODUCTION STRING REMARKS: 1. ALL DEPTHS ARE MEASURED DEPTHS UNLESS OTHERWISE NOTED. THESE DEPTHS ARE BIT DEPTHS. 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTHS (TVD). 3. THIS LATERAL WAS DRILLED FROM A WHIPSTOCK, THE TOP • • OF WHICH WAS AT 4565'MD/ 3550'TVD, WITHIN THE RUN 2 INTERVAL OF 1J-159 PB1. THE WHIPSTOCK WAS SET, THE WINDOW MILLED, AND 29' OF RAT HOLE DRILLED DURING MWD RUN 6. 4. MWD RUN 1 WAS DIRECTIONAL ONLY - NO DATA ARE PRESENTED. 5. MWD RUNS 2,7 COMPRISED DIRECTIONAL, DUAL GAMMA RAY (DGR) UTILIZING GEIGER- MUELLER TUBE DETECTORS, ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4), AND PRESSURE WHILE DRILLING (PWD) RUN 7 ALSO INCLUDED GEO-PILOT ROTARY STEERABLE BHA (GP) AND AT-BIT INCLINATION (ABI) MWD RUN 2 POROSITY DATA ARE PRESENTED FOR THE 1J-159 PB1 WELLBORE ONLY. 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 1,2,6,7 REPRESENT WELL 1J-159 L1 PB1 WITH API#: 50-029-23297-71. THIS WELL REACHED A TOTAL DEPTH (TD) OF 4987'MD/3550'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.......06/05/30 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 2325.5 4930.5 FET 2345.0 4937.5 RPD 2345.0 4937.5 RPS 2345.0 4937.5 RPM 2345.0 4937.5 RPX 2345.0 4937.5 ROP 2370.5 4987.0 BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --- BASELINE DEPTH • MERGED DATA SOURCE PBU TOOL CODE BIT RUN NO MWD 2 MWD 6 MWD 7 REMARKS: MERGED MAIN PASS. MERGE TOP MERGE BASE 2325.5 4565.0 4565.5 4606.0 4606.0 4987.0 Data Format Specification Record Data Record Type ............. .....0 Data Specification Block Type .....0 Logging Direction ............ .....DOwn Optical log depth units...... .....Feet Data Reference Point ......... .....Undefined Frame Spacing ................ .....60 .lIN Max frames per record ........ .....Undefined Absent value ................. .....-999 Depth Units .................. ..... Datum Specification Block sub -type...0 Name Service Order Units Size Nsam Rep Code Offset Channel C] 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 2325.5 4987 3656.25 5324 2325.5 4987 RPD MWD OHMM 0.64 2000 37.5954 5186 2345 4937.5 RPM MWD OHMM 0.77 2000 26.293 5186 2345 4937.5 RPS MWD OHMM 0.54 2000 19.9524 5186 2345 4937.5 RPX MWD OHMM 0.42 1440.52 15.6658 5186 2345 4937.5 FET MWD HOUR 0.19 168.87 4.6948 5186 2345 4937.5 GR MWD API 19.79 120.18 66.6772 5211 2325.5 4930.5 ROP MWD FT/H 0.24 481.14 166.497 5234 2370.5 4987 First Reading For Entire File..........2325.5 Last Reading For Entire File...........4987 File Trailer Service name .............STSLIB.001 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/05/30 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.......06/05/30 Maximum Physical Record..65535 File Type ................LO Previous File Name.......STSLIB.001 Comment Record FILE HEADER FILE NUMBER: 2 RAW MWD • MERGED DATA SOURCE PBU TOOL CODE BIT RUN NO MWD 2 MWD 6 MWD 7 REMARKS: MERGED MAIN PASS. MERGE TOP MERGE BASE 2325.5 4565.0 4565.5 4606.0 4606.0 4987.0 Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type..... 0 Logging Direction ................. Down Optical log depth units........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .lIN Max frames per record ............. Undefined Absent value ...................... -999 Depth Units ....................... Datum Specification Block sub-type ...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 RPD MWD OHMM 4 1 68 4 2 RPM MWD OHMM 4 1 68 8 3 RPS MWD OHMM 4 1 68 12 4 RPX MWD OHMM 4 1 68 16 5 FET MWD HOUR 4 1 68 20 6 GR MWD API 4 1 68 24 7 ROP MWD FT/H 4 1 68 28 8 First Last Name Servi ce Unit Min Max Mean Nsam Reading Reading DEPT FT 2325.5 4987 3656.25 5324 2325.5 4987 RPD MWD OHMM 0.64 2000 37.5954 5186 2345 4937.5 RPM MWD OHMM 0.77 2000 26.293 5186 2345 4937.5 RPS MWD OHMM 0.54 2000 19.9524 5186 2345 4937.5 RPX MWD OHMM 0.42 1440.52 15.6658 5186 2345 4937.5 FET MWD HOUR 0.19 168.87 4.6948 5186 2345 4937.5 GR MWD API 19.79 120.18 66.6772 5211 2325.5 4930.5 ROP MWD FT/H 0.24 481.14 166.497 5234 2370.5 4987 First Reading For Entire File..........2325.5 Last Reading For Entire File...........4987 File Trailer Service name ............ .STSLIB.001 Service Sub Level Name.. . Version Number.......... .1.0.0 Date of Generation...... .06/05/30 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..... ..06/05/30 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: 2 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 2325.5 4565.0 FET 2345.0 4565.0 RPX 2345.0 4565.0 RPS 2345.0 4565.0 RPM 2345.0 4565.0 RPD 2345.0 4565.0 ROP 2370.5 4565.0 LOG HEADER DATA DATE LOGGED: 18-FEB-06 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 68.18 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT) 4565.0 TOP LOG INTERVAL (FT) 2370.0 BOTTOM LOG INTERVAL (FT) 4565.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 25.9 MAXIMUM ANGLE: 81.9 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 216265 EWR4 ELECTROMAG. RESIS. 4 157645 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) 9.875 DRILLER'S CASING DEPTH (FT) 2365.0 BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format Specification Record Data Record Type .............. ....0 Data Specification Block Type. ....0 Logging Direction ............. ....DOwn Optical log depth units....... ....Feet Data Reference Point .......... ....Undefined Frame Spacing ................. ....60 .lIN Max frames per record ......... ....Undefined Absent value .................. ....-999 Depth Units ................... .... Datum Specification Block sub- type...0 Fresh Water Gel 9.00 51.0 8.9 250 5.0 2.900 65.0 1.950 100.0 3.000 65.0 5.000 65.0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 RPD MWD020 OHMM 4 1 68 4 2 RPM MWD020 OHMM 4 1 68 8 3 RPS MWD020 OHMM 4 1 68 12 4 RPX MWD020 OHMM 4 1 68 16 5 FET MWD020 HOUR 4 1 68 20 6 GR MWD020 API 4 1 68 24 7 ROP MWD020 FT/H 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 2325.5 4565 3445.25 4480 2325.5 4565 RPD MWD020 OHMM 0.64 2000 28.5345 4441 2345 4565 RPM MWD020 OHMM 0.77 1749.02 14.0939 4441 2345 4565 RPS MWD020 OHMM 0.54 1136.14 12.1316 4441 2345 4565 RPX MWD020 OHMM 0.42 1440.52 11.4283 4441 2345 4565 FET MWD020 HOUR 0.19 113.21 2.04511 4441 2345 4565 GR MWD020 API 19.79 117.61 67.0693 4480 2325.5 4565 ROP MWD020 FT/H 3.3 481.14 173.353 4390 2370.5 4565 First Reading For En tire File... .......2325 .5 Last Reading For Ent ire File.... .......4565 File Trailer Service name ..... ........STSLIB.002 Service Sub Level Name... Version Number... ........1.0. 0 Date of Generation.......06/05/30 Maximum Physical Record..65535 File Type ........ ........LO Next File Name... ........STSL IB.003 Physical EOF File Header Service name .............STSLIB.003 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/05/30 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: 6 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH ROP 4565.5 4606.0 LOG HEADER DATA DATE LOGGED: 24-FEB-06 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 66.37 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT) 4606.0 TOP LOG INTERVAL (FT) 4565.0 BOTTOM LOG INTERVAL (FT) 4606.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: .0 MAXIMUM ANGLE: .0 • • TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 184054 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) 6.750 DRILLER'S CASING DEPTH (FT) 4565.0 BOREHOLE CONDITIONS MUD TYPE: Mineral Oil Base MUD DENSITY (LB/G) 8.80 MUD VISCOSITY (S) 69.0 MUD PH: .0 MUD CHLORIDES (PPM): 111000 FLUID LOSS (C3) 2.0 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT) .000 .0 MUD AT MAX CIRCULATING TERMPERATURE: .000 70.5 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 MWD060 FT/H 4 1 68 4 2 First Name Service Unit Min Max Mean Nsam Reading DEPT FT 4565.5 4606 4585.75 82 4565.5 ROP MWD060 FT/H 1.21 49.72 19.6425 82 4565.5 First Reading For Entire File..........4565.5 Last Reading For Entire File...........4606 File Trailer Service name .............STSLIB.003 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/05/30 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.004 Last Reading 4606 4606 Physical EOF File Header Service name .............STSLIB.004 • Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/05/30 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 f iles. BIT RUN NUMBER: 7 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH RPX 4565.5 4937.5 RPD 4565.5 4937.5 GR 4565.5 4930.5 RPM 4565.5 4937.5 FET 4565.5 4937.5 RPS 4565.5 4937.5 ROP 4606.5 4987.0 LOG HEADER DATA DATE LOGGED: 25-FEB-06 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 66.37 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT) 4987.0 TOP LOG INTERVAL (FT) 4606.0 BOTTOM LOG INTERVAL (FT) 4987.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 86.8 MAXIMUM ANGLE: 93.1 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 184054 EWR4 Electromag Resi s. 4 162742 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) 6.750 DRILLER'S CASING DEPTH (FT) 4565.0 BOREHOLE CONDITIONS MUD TYPE: Mineral Oil Base MUD DENSITY (LB/G) 8.80 MUD VISCOSITY (S) 70.0 MUD PH: .0 MUD CHLORIDES (PPM): 34000 FLUID LOSS (C3): 3.0 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT) .000 .0 MUD AT MAX CIRCULATING TERMPERATURE: .000 93.0 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 MWD070 OHMM 4 1 68 4 2 RPM MWD070 OHMM 4 1 68 8 3 RPS MWD070 OHMM 4 1 68 12 4 RPX MWD070 OHMM 4 1 68 16 5 FET MWD070 HOUR 4 1 68 20 6 GR MWD070 API 4 1 68 24 7 ROP MWD070 FT/H 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 4565.5 4987 4776.25 844 4565.5 4987 RPD MWD070 OHMM 5.13 2000 91.6085 745 4565.5 4937.5 RPM MWD070 OHMM 6.66 2000 99.0125 745 4565.5 4937.5 RPS MWD070 OHMM 6.29 2000 66.5729 745 4565.5 4937.5 RPX MWD070 OHMM 6.11 174.81 40.9256 745 4565.5 4937.5 FET MWD070 HOUR 0.27 168.87 20.4898 745 4565.5 4937.5 GR MWD070 API 41.74 120.18 64.2741 731 4565.5 4930.5 ROP MWD070 FT/H 0.24 250.29 142.802 762 4606.5 4987 First Reading For Entire File..........4565.5 Last Reading For Entire File...........4987 File Trailer Service name .............STSLIB.004 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/05/30 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.005 Physical EOF Tape Trailer Service name .............LISTPE Date .....................06/05/30 Origin ...................STS Tape Name ................UNKNOWN Continuation Number......01 Next Tape Name...........UNKNOWN Comments .................STS LIS Writing Library. Scientific Technical Services Reel Trailer Service name .............LISTPE Date .....................06/05/30 Origin ...................STS Reel Name ................UNKNOWN Continuation Number......01 Next Reel Name...........UNKNOWN Comments .................STS LIS Writing Library. Scientific Technical Services Physical EOF Physical EOF • • End Of LIS File flv 'off ~ x3933 Sperry-Sun Drilling Services LIS Scan Utility $Revision: 3 $ LisLib $Revision: 4 $ Tue May 30 16:32:34 2006 Reel Header Service name ............. LISTPE Date ..................... 06/05/30 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number...... 01 Previous Reel Name....... UNKNOWN Comments ................. STS LIS Writing Library Tape Header Service name ............. LISTPE Date ..................... 06/05/30 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-159 L1 PB2 API NUMBER: 500292329772 OPERATOR: ConocoPhillips Alaska, Inc. LOGGING COMPANY: Sperry Drilling Services TAPE CREATION DATE: 30-MAY-06 JOB DATA MWD RUN 2 MWD RUN 6 MWD RUN 7 JOB NUMBER: MW0004212091 MW0004212091 MW0004212091 LOGGING ENGINEER: P. ORTH T. GALVIN T. GALVIN OPERATOR WITNESS: D. GLADDEN M. THORTON M. THORTON MWD RUN 8 JOB NUMBER: MW0004212091 LOGGING ENGINEER: T. GALVIN OPERATOR WITNESS: M. THORTON SURFACE LOCATION SECTION: 35 TOWNSHIP: 11N RANGE: l0E FNL: FSL: 2035 FEL: 2545 FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: 109.00 GROUND LEVEL: 81.00 WELL CASING RECORD OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 1ST STRING 9.875 10.750 2365.0 2ND STRING 6.750 7.875 4565.0 3RD STRING PRODUCTION STRING REMARKS: 1. ALL DEPTHS ARE MEASURED DEPTHS UNLESS OTHERWISE • • NOTED. THESE DEPTHS ARE BIT DEPTHS. 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTHS (TVD). 3. THIS WELL IS AN OPEN-HOLE SIDETRACK EXITING THE 1J-159 L1 PB1 WELLBORE AT 4687'MD/3565'TVD. 4. MWD RUN 1 WAS DIRECTIONAL ONLY - NO DATA ARE PRESENTED. 5. MWD RUNS 2,7,8 COMPRISED DIRECTIONAL, DUAL GAMMA RAY (DGR) UTILIZING GEIGER-MUELLER TUBE DETECTORS, ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4), AND PRESSURE WHILE DRILLING (PWD) RUN 7 ALSO INCLUDED GEO-PILOT ROTARY STEERABLE BHA (GP) AND AT-BIT INCLINATION (ABI) MWD RUN 2 POROSITY DATA ARE PRESENTED FOR THE 1J-159 PB1 WELLBORE ONLY. 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 1,2,6-8 REPRESENT WELL 1J-159 L1 PB2 WITH API#: 50-029-23297-72. THIS WELL REACHED A TOTAL DEPTH (TD) OF 6832'MD/3520'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.......06/05/30 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 2325.5 FET 2345.0 RPM 2345.0 RPS 2345.0 RPD 2345.0 RPX 2345.0 ROP 2370.5 BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) all bit runs merged. STOP DEPTH 6772.5 6779.5 6779.5 6779.5 6779.5 6779.5 6832.0 i • 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-159 L1 PB1 WELLBORE AT 4687'MD/3565'TVD. 4. MWD RUN 1 WAS DIRECTIONAL ONLY - NO DATA ARE PRESENTED. 5. MWD RUNS 2,7,8 COMPRISED DIRECTIONAL, DUAL GAMMA RAY (DGR) UTILIZING GEIGER-MUELLER TUBE DETECTORS, ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4), AND PRESSURE WHILE DRILLING (PWD) RUN 7 ALSO INCLUDED GEO-PILOT ROTARY STEERABLE BHA (GP) AND AT-BIT INCLINATION (ABI) MWD RUN 2 POROSITY DATA ARE PRESENTED FOR THE 1J-159 PB1 WELLBORE ONLY. 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 1,2,6-8 REPRESENT WELL 1J-159 L1 PB2 WITH API#: 50-029-23297-72. THIS WELL REACHED A TOTAL DEPTH (TD) OF 6832'MD/3520'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.......06/05/30 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 cvrves~ all bit runs merged. DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE START DEPTH STOP DEPTH GR 2325.5 6772.5 FET 2345.0 6779.5 RPM 2345.0 6779.5 RPS 2345.0 6779.5 RPD 2345.0 6779.5 RPX 2345 .O 6'T'T 9 . S ROP 2370.5 6832.0 BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) • • - EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH MERGED DATA SOURCE PBU TOOL CODE BIT RUN NO MERGE TOP MERGE BASE MWD 2 2325 .5 4565.0 MWD 6 4565 .5 4606.0 MWD 7 4606 .0 4687.0 MWD 8 4687 .5 6832.0 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 Servi ce Unit Min Max Mean Nsam Reading Reading DEPT FT 2325.5 6832 4578.75 9014 2325.5 6832 RPD MWD OHMM 0.64 2000 48.0774 8870 2345 6779.5 RPM MWD OHMM 0.77 2000 35.5656 8870 2345 6779.5 RPS MWD OHMM 0.54 2000 31.0817 8870 2345 6779.5 RPX MWD OHMM 0.42 2000 28.1489 8870 2345 6779.5 FET MWD HOUR 0.19 168.87 3.03776 8870 2345 6779.5 GR MWD API 19.79 118.03 65.3085 8895 2325.5 6772.5 ROP MWD FT/H 0.24 481.14 168.821 8924 2370.5 6832 First Reading For Entire File..........2325.5 Last Reading For Entire File...........6832 File Trailer Service name .............STSLIB.001 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/05/30 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....... 06/05/30 Maximum Physical Record.. 65535 File Type ................ LO Previous File Name....... STSLIB.001 i • Comment Record FILE HEADER FILE NUMBER: 2 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 2 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 2325.5 4565.0 RPD 2345.0 4565.0 RPX 2345.0 4565.0 RPM 2345.0 4565.0 FET 2345.0 4565.0 RPS 2345.0 4565.0 ROP 2370.5 4565.0 LOG HEADER DATA DATE LOGGED: 18-FEB-06 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 68.18 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT) 4565.0 TOP LOG INTERVAL (FT) 2370.0 BOTTOM LOG INTERVAL (FT) 4565.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 25.9 MAXIMUM ANGLE: 81.9 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 216265 EWR4 ELECTROMAG. RESIS. 4 157645 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) 9.875 DRILLER'S CASING DEPTH (FT) 2365.0 BOREHOLE CONDITIONS MUD TYPE: Fresh Water Gel MUD DENSITY (LB/G) 9.00 MUD VISCOSITY (S) 51.0 MUD PH: 8.9 MUD CHLORIDES (PPM): 250 FLUID LOSS (C3) 5.0 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT) 2.900 65.0 MUD ;AT MAX CIRCULATING TERMPERATURE: 1.950 100.0 MUD :FILTRATE AT MT: 3.000 65.0 MUD CAKE AT MT: 5.000 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 Specificat ion Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 RPD MWD020 OHMM 4 1 68 4 2 RPM MWD020 OHMM 4 1 68 8 3 RPS MWD020 OHMM 4 1 68 12 4 RPX MWD020 OHMM 4 1 68 16 5 FET MWD020 HOUR 4 1 68 20 6 GR MWD020 API 4 1 68 24 7 ROP MWD020 FT/H 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 2325.5 4565 3445.25 4480 2325.5 4565 RPD MWD020 OHMM 0.64 2000 28.5345 4441 2345 4565 RPM MWD020 OHMM 0.77 1749.02 14.0939 4441 2345 4565 RPS MWD020 OHMM 0.54 1136.14 12.1316 4441 2345 4565 RPX MWD020 OHMM 0.42 1440.52 11.4283 4441 2345 4565 FET MWD020 HOUR 0.19 113.21 2.04511 4441 2345 4565 GR MWD020 API 19.79 117.61 67.0693 4480 2325.5 4565 ROP MWD020 FT/H 3.3 481.14 173.353 4390 2370.5 4565 First Reading For Entire File..........2325.5 Last Reading For Entire File...........4565 File Trailer Service name .......... ...STSLIB.002 Service Sub Level Name ... Version Number........ ...1.0.0 Date of Generation.... ...06/05/30 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.......06/05/30 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: 6 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH ROP 4565.5 4606.0 LOG HEADER DATA DATE LOGGED: 24-FEB-06 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 66.37 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT) 4606.0 TOP LOG INTERVAL (FT) 4565.0 BOTTOM LOG INTERVAL (FT) 4606.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S):' MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: .0 .0 TOOL NUMBER 6.750 4565.0 Mineral Oil Base 8.80 69.0 .0 111000 2.0 .000 .0 .000 70.5 .000 .0 .000 .0 Data Format Specification Record Data Record Type ..................0 Data Specification Block Type.....0 Logging Direction .................Down Optical log depth units...........Feet Data Reference Point ..............Undefined Frame Spacing .....................60 .lIN Max frames per record .............Undefined Absent value ......................-999 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD060 FT/H 4 1 68 4 2 First Name Service Unit Min Max Mean Nsam Reading DEPT FT 4565.5 4606 4585.75 82 4565.5 ROP MWD060 FT/H 1.21 49.72 19.6425 82 4565.5 First Reading For Entire File..........4565.5 Last Reading For Entire File...........4606 File Trailer Service name .............STSLIB.003 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/05/30 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.004 Last Reading 4606 4606 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: .0 MAXIMUM ANGLE: .0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) 6.750 DRILLER'S CASING DEPTH (FT) 4565.0 BOREHOLE CONDITIONS MUD TYPE: Mineral Oil Base MUD DENSITY (LB/G) 8.80 MUD VISCOSITY (S) 69.0 MUD PH: .0 MUD CHLORIDES (PPM): 111000 FLUID LOSS (C3): 2.0 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT) .000 .0 MUD AT MAX CIRCULATING TERMPERATURE: .000 70.5 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 MWD060 FT/H 4 1 68 4 2 First Name Service Unit Min Max Mean Nsam Reading DEPT FT 4565.5 4606 4585.75 82 4565.5 ROP MWD060 FT/H 1.21 49.72 19.6425 82 4565.5 First Reading For Entire File..........4565.5 Last Reading For Entire File...........4606 File Trailer. Service name .............STSLIB.003 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/05/30 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.004 Last Reading 4606 4606 • BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: .0 .0 TOOL NUMBER 6.750 4565.0 Mineral Oil Base 8.80 69.0 .0 111000 2.0 .000 .0 .000 70.5 .000 .0 .000 .0 Data Format Specification Record Data Record Type ..................0 Data Specification Block Type.....0 Logging Direction .................Down Optical log depth units...........Feet Data Reference Point ..............Undefined Frame Spacing .....................60 .lIN Max frames per record .............Undefined Absent value ......................-999 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD060 FT/H 4 1 68 4 2 First Name Service Unit Min Max Mean Nsam Reading DEPT FT 4565.5 4606 4585.75 82 4565.5 ROP MWD060 FT/H 1.21 49.72 19.6425 82 4565.5 First Reading For Entire File..........4565.5 Last Reading For Entire File...........4606 File Trailer Service name .............STSLIB.003 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/05/30 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.004 Last Reading 4606 4606 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: .0 MAXIMUM ANGLE: .0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) 6.750 DRILLER'S CASING DEPTH (FT) 4565.0 BOREHOLE CONDITIONS MUD TYPE: Mineral Oil Base MUD DENSITY (LB/G) 8.80 MUD VISCOSITY (S) 69.0 MUD PH: .0 MUD CHLORIDES (PPM): 111000 FLUID LOSS (C3) 2.0 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT) .000 .0 MUD AT MAX CIRCULATING TERMPERATURE: .000 70.5 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 MWD060 FT/H 4 1 68 4 2 First Name Service Unit Min Max Mean Nsam Reading DEPT FT 4565.5 4606 4585.75 82 4565.5 ROP MWD060 FT/H 1.21 49.72 19.6425 82 4565.5 First Reading For Entire File..........4565.5 Last Reading For Entire File...........4606 File Trailer Service name .............STSLIB.003 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/05/30 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.004 Last Reading 4606 4606 • • Physical EOF File Header Service name .............STSLIB.004 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/05/30 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: 7 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 4565.5 4687.0 FET 4565.5 4687.0 RPX 4565.5 4687.0 RPM 4565.5 4687.0 RPD 4565.5 4687.0 RPS 4565.5 4687.0 ROP 4606.5 4687.0 LOG HEADER DATA DATE LOGGED: 25-FEB-06 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 66.37 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT) 4687.0 TOP LOG INTERVAL (FT) 4606.0 BOTTOM LOG INTERVAL (FT) 4687.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 86.8 MAXIMUM ANGLE: 93.1 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 184054 EWR4 Electromag Resis. 4 162742 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) 6.750 DRILLER'S CASING DEPTH (FT) 4565.0 BOREHOLE CONDITIONS MUD TYPE: Mineral Oil Base MUD DENSITY (LB/G) 8.80 MUD VISCOSITY (S) 70.0 MUD PH: .0 MUD CHLORIDES (PPM): 34000 FLUID LOSS (C3) 3.0 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT) .000 .0 MUD AT MAX CIRCULATING TERMPERATURE: .000 93.0 MUD FILTRATE AT MT: .000 .0 MUD CAKE AT MT: .000 .0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: • S Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type..... 0 Logging Direction ................. DOwn Optical log depth units........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .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 MWD070 OHMM 4 1 68 4 2 RPM MWD070 OHMM 4 1 68 8 3 RPS MWD070 OHMM 4 1 68 12 4 RPX MWD070 OHMM 4 1 68 16 5 FET MWD070 HOUR 4 1 68 20 6 GR MWD070 API 4 1 68 24 7 ROP MWD070 FT/H 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 4565.5 4687 46 26.25 244 4565.5 4687 RPD MWD070 OHMM 5.13 149.12 64 .0626 244 4565.5 4687 RPM MWD070 OHMM 12.21 101.1 48 .0081 244 4565.5 4687 RPS MWD070 OHMM 13.45 82.42 43 .2878 244 4565.5 4687 RPX MWD070 OHMM 14.77 174.81 41 .2061 244 4565.5 4687 FET MWD070 HOUR 0.64 168.87 60 .4152 244 4565.5 4687 GR MWD070 API 41.74 76.55 59 .2319 244 4565.5 4687 ROP MWD070 FT/H 0.24 250.29 89 .8858 162 4606.5 4687 First Reading For Entire File..........4565.5 Last Reading For Entire File...........4687 File Trailer Service name ........... ..STSLIB.004 Service Sub Level Name. .. Version Number......... ..1.0.0 Date of Generation..... ..06/05/30 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.......06/05/30 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: 8 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH RPX 4687.5 6779.5 GR 4687.5 6772.5 • • RPD 4687.5 6779.5 FET 4687.5 6779.5 RPM 4687.5 6779.5 ROP 4687.5 6832.0 RPS 4687.5 6779.5 LOG HEADER DATA DATE LOGGED: 27-FEB-06 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 66.37 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT) 6832.0 TOP LOG INTERVAL (FT) 4687.0 BOTTOM LOG INTERVAL (FT) 6832.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 86.2 MAXIMUM ANGLE: 93.4 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 184054 EWR4 Electromag Resis . 4 162742 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) 6.750 DRILLER'S CASING DEPTH (FT) 4565.0 BOREHOLE CONDITIONS MUD TYPE: Mineral Oil B ase MUD DENSITY (LB/G) 8.80 MUD VISCOSITY (S) 70.0 MUD PH: .0 MUD CHLORIDES (PPM): 27000 FLUID LOSS (C3) 2.2 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT ) .000 .0 MUD AT MAX CIRCULATING TERMPERATURE: .000 115 .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 MWD080 OHMM 4 1 68 4 2 RPM MWD080 OHMM 4 1 68 8 3 RPS MWD080 OHMM 4 1 68 I2 4 RPX MWD080 OHMM 4 1 68 16 5 FET MWD080 HOUR 4 1 68 20 6 GR MWD080 API 4 1 68 24 7 ROP MWD080 FT/H 4 1 68 28 8 • • First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 4687.5 6832 5759.75 4290 4687.5 6832 RPD MWD080 OHMM 4.29 2000 67.8837 4185 4687.5 6779.5 RPM MWD080 OHMM 5.17 2000 57.6253 4185 4687.5 6779.5 RPS MWD080 OHMM 6.6 2000 50.4793 4185 4687.5 6779.5 RPX MWD080 OHMM 7.03 2000 45.1311 4185 4687.5 6779.5 FET MWD080 HOUR 0.21 19.34 0.74583 4185 4687.5 6779.5 GR MWD080 API 37.91 118.03 63.7727 4171 4687.5 6772.5 ROP MWDO80 FT/H 0.42 435.25 170.014 4290 4687.5 6832 First Reading For Entire File..........4687.5 Last Reading For Entire File...........6832 File Trailer Service name ............. STSLIB.005 Service Sub Level Name... Version Number........... 1.0.0 Date of Generation....... 06/05/30 Maximum Physical Record.. 65535 File Type ................ LO Next File Name........... STSLIB.006 Physical EOF Tape Trailer Service name .............LISTPE Date .....................06/05/30 Origin ...................STS Tape Name ................UNKNOWN Continuation Number......01 Next Tape Name...........UNKNOWN Comments .................STS LIS Writing Library. Scientific Technical Services Reel Trailer Service name .............LISTPE Date .....................06/05/30 Origin ...................STS Reel Name ................UNKNOWN Continuation Number......01 Next Reel Name...........UNKNOWN Comments .................STS LIS Writing Library. Scientific Technical Services Physical EOF Physical EOF End Of LIS File