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202-062
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. QD~ - tJ 0:!l.. Well History File Identifier Organizing (done) 0 Two-sided 1111111111111111111 0 Rescan Needed 1111111111111111111 RESCAN DIGITAL DATA œ(biskettes, No. ~ 0 Other, No/Type: OVERSIZED (Scannable) 0 Maps: 0 Color Items: 0 Greyscale Items: 0 Other Items Scannable by a Large Scanner 0 Poor Quality Originals: OVERSIZED (Non-Scannable) 0 Other: 0 Logs of various kinds: BY: Helen ~') 0 D~::q. ~9 / Olf Isl t11 P NOTES: Project Proofing BY: Helen ~ ~ I Date: 1, i¥l,Olf Isl Mf Scanning Preparation :3 x 30 =C¡D +b = TOTAL PAGES OIö (Count daBS no.. t Inctude cover ,fu,ejfl)l Jf) Date: 0 :/),,1, () if /5/ VVI V- i 1111111111111111111 BY: Helen ~~ria) Production Scanning Stage 1 Page Count from Scanned File: c:¡ b (Count does include cover sheet) Page Count Matches Number in Scanning Preparation: ~ YES, NO Heler~::~) Date 9. ':1/7 / ð if IfJ 'VtfP If NO in stage 1 page(s) discrepancies were found: YES NO Stage 1 BY: BY: Helen Maria BY: Helen Maria Date: /5/ I - I III1 Date: /5/ Quality Checked 1111111111111111111 Scanning is complete at this point unless rescanning is required. ReScanned Comments about this file: 8/24/2004 Well History File Cover Page.doc STATE OF ALASKA ALASKA OAND GAS CONSERVATION COMMISSI40 REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Abandon r Repair w ell r Plug Perforations r Stimulate r Other f Alter Casing r Rill Tubing Perforate New Pool r Waiver r Time Extension r Change Approved Program r Operat. Shutdow n r Perforate r Re -enter Suspended Well °- 2. Operator Name: 4. Well Class Before Work: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development r Exploratory r • 202 - 062 3. Address: 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 Stratigraphic Service r 50 -029- 23076 -60 ' CIO 7. Property Designation (Lease Number): 8. Well Name and Number: ADL 25649 • - 1C-104L1 9. Field /Pool(s): Kuparuk River Field / West Sak Oil Pool 10. Present Well Condition Summary: Total Depth measured 11539 feet Plugs (measured) None true vertical 3626 feet Junk (measured) None Effective Depth measured 11514 feet Packer (measured) none true vertical 3627 feet (true vertucal) none Casing Length Size MD TVD Burst Collapse CONDUCTOR 113 16 158 158 SURFACE 7002 7.625 7395' 3741' LINER D -SAND 4475 4" 11514 3627' 'all I . 0 P :k1 ,^ f`ir Perforation depth: Measured depth: 7202' - 11354' RECEIVED' True Vertical Depth: 3700' - 3632' AUG 16 2011 Tubing (size, grade, MD, and TVD) 4.5, L - 80, 6116 MD, 3392 TVD Mika 011 &Gas Caw Ge . Packers & SSSV (type, MD, and TVD) PACKER IN MAIN WELLBORE Ancfieraie NO SSSV 11. Stimulation or cement squeeze summary: Intervals treated (measured): not applicable Treatment descriptions including volumes used and final pressure: 12. Representative Daily Average Production or Injection Data Oil - Bbl Gas - Mcf Water - Bbl Casing Pressure Tubing Pressure Prior to well operation shut - Subsequent to operation shut - 13. Attachments 14. Well Class after work: Copies of Logs and Surveys run Exploratory r Development 17 ., Service r Stratigraphic r 15. Well Status after work: , OiI I' Gas r WDSPL r Daily Report of Well Operations XXXX GSTOR r WINJ r WAG r GINJ r SUSP r SPLUG E 16. 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 (a, 265 -6845 Printed Name Brett �J Packer re Title Wells Engineer Signature //��" 'ma - - - ` Phone: 265 -6845 Date g'// , �/ i f RBDMS AUG 16 2011:3 A-- g 5 Form 10 -404 Revised 10/2010 /,, el-7-279 Submit Original Only ConocoPhillips 0,27 • KU P • 1C -104L1 4 Well Attributes Max Angle & MI) TD At8(i148 Wel!bore APUUWI Field Name Ind (1 Well Status In MD (flKB) Act Btm (kKB) Cocem.4}?16Fpt I 500292307660 WESO SAK PROD 94.50 I 7,498.20 11,539.0 - -- - Comment H2S (ppm) Date Annotation End Date KB-Grd (N) Rig Release Date Wet C 1 J 11 :0732 AM SSSV. NONE 110 8/6/2009 i Last WOE 10/25/2007 I 4516 7/29/2002 Sd _ Annotation Depth (flKB) End Date Annotation Last Mod ... End Date Last Tag- Rev Reason: WORKOVER nlnam 8/15/2011 Casing Strings Casing Description String 0... String ID . ITOp (ftKB) Set Depth (f _.!Set Depth (TVD) ... String Wt... !String !String Top Thrd LINER D -SAND 5 3 550 I l 7,039.2 11,514.2 3,627.1 , t 9.50 I L-80 1 SLHT s:: - -- Liner Details _ - - — Top Depth -; (TVD) Top Inel Ntanl... Top (MB) (MKB) C) Item Deaorfptiun Commend ID (In) 7,039.2 3,680.1 76.12 HANGER BAKER FLANGED HOOK HANGER 5.630 • r : Q0.. 7,060.1 3,683.8 75.98 SWIVEL BAKER LINER SWIVEL SUB 4.000 . FIANGLP., 36 a,' 7,062.7 3,684.5 76.31X04.5x5.03 3.990 CONDUCTOR, 7,103.7 3,693.0 82.65 INDICATOR BAKER INDICATOR SUB 3.840 45 7,111.5 3,694.1 83.09 ECP BAKER PAYZONE ECP 3.930 7,166.3 3,699.1 88.51 SLEEVE BAKER CMD SLIDING LSEEVE -... 3.430 7,202.0 3,699.6 90 -11 XO 5x4 3.550 Wi 11,454.7 3,629.1 91 XO 5x4 3.550 CAS LIFT, 111t17 9191 11,493. 3,627.8 XO 3.5x5 2 970 ar 2 .870_ Perforations & Slots Shot Top (TOO) Bim (TVD) Dann Top (fl . Bnn (kKB1' _ (31998).6 (kKB) Zone Date lsh... Type Comment 7,202 KB) 11,3541 3,631.5 WS D, 1C-104L1 7282002 50.0 SLOTS Perfs thru 37 screens every 31' ?ACKER. 2991 alternating wdh solid liner Notes: General & Safety r _ End Date _Annotation 7/29/2002 NOTE: MULTI- LATERAL WELL B-SAND (1C -104), D -SAND (1C- 104L1) 10/112008 NOTE: View Schematic w/ Alaska Schematic9.0 ' 3 11 0 - 9272009 NOTE: LEAK DETECTED @ 6053' ELMD It GAUGE, 5.933 -' W . . w.,.. .: ..,,,,,,„ MOTOR, 6,039_ MOTOR. 6.052 -_- ,V. CONNECTOR, 6,066 -... PIPE ASSY, 6,079 COUPLING, 6,105 PIPE ASSY, 6,107 Illr PROFILE, 6,114 6 WINDOW L1, 01 7,47,064 SURFACE, N -.. 41 -7,395 ,-. A Top Depth Top Port (TVD) Ind 00 Valve Latch Sae TRO Run Sy (MR/ (7 Mahe Model fn) sere 1 Yp• TWp• lie) (peg Run Dab Cont... - 1 2,870.2 1,963.5 62.87 CAMCO KBMG 1 GAS LIFT DMY BK -5 0.000 0.0 7/312011 SLOTS. U 0 01 2 3,105.8 2,067.2 64.69 CAMCO KBMG 1 GAS LIFT DMY BK -5 0.000 0.0 7/31/2011 • 7202 - 1' . . 354 f1 l) al U U 01 i LINER D -SAND, ■ TO (1aPa104L11•, �- - - -. l 11,539 ConocoPnillips Time Log & Summary Weliview Web Reporting Report Well Name: 1C Rig Name: NORDIC 3 Job Type: RECOMPLETION Rig Accept: 7/10/2011 1:30:00 AM Rig Release: 8/2/2011 8:00:00 AM Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 07/08/2011 24 hr Summary Completed Well 1D-121. Released Rig. RDMO. Begin to move to 1C-Pad. 17:00 00:00 7.00 MIRU MOVE MOB P Continue to move Rig to 1C -Pad. 07/09/2011 Continue to mobilize Rig to 1C-Pad. Rig on Pad. 00:00 23:00 23.00 MIRU MOVE MOB P Mobilize Rig from 1D Pad, traveling to 1C -Pad. Rig on Pad at 22:30 hrs. 23:00 00:00 1.00 MIRU MOVE RURD P Set Rig over the 13 5/8" x 5K BOP components. Build same. 07/10/2011 Set 13 5/8" BOP Stack on the Stump. Move in and center Rig on 1C-104 Well Slot. Rig up Flow Back Tank and Filtration Farm. Take on filtered 8.6 lb/gal Sea Water w /3% KCL in Rig Pits. Test Lines. Pull BPV. Circulate and Kill Well. Install BPV. ND Tree. 00:00 01:30 1.50 MIRU MOVE RURD P Continue to build the 13 5/8" BOP Stack. Set on the Cellar Stump. 01:30 02:30 1.00 MIRU MOVE RURD P Move Rig over 1C -104 Well Slot. Level and berm up same. Accept Rig at 01:30 hrs 02:30 13:00 10.50 MIRU MOVE RURD P MIRU Flow back Tank and Lines. MIRU Filtration Farm. Spot Support Equipment. 13:00 13:15 0.25 COMPZ WELLPF SFTY P PJSM. Discuss Hazard with Pulling BPV. 13:15 14:00 0.75 COMPZ WELLPF KLWL P P/U Lubricator . Lubricate out BPV and UD same. ITP= 100 psi IAP= 105 psi. 14:00 14:30 0.50 COMPZ WELLPF EQRP P Wait On High -Line personnel to finish hooking shore power. 14:30 15:15 0.75 COMPZ WELLPF OTHR P Crane Showed up to remove ESP spool from Rig floor. PJSM with crane operator,rigger and rig crew. . Make lift to remove spool from rig floor and install another one. 15:15 15:30 0.25 COMPZ WELLPF SFTY P PJSM. Discuss hazard for killing the well. Page 1 of 24 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 15:30 17:30 2.00 COMPZ WELLPF KLWL P Fluid pack and PT lines 250/3000 psi. Start Pumping operation to kill well. Lead with 100 bbls diesel down IA taking returns up the Tubing at 4 BPM. Initial Circulating psi down IA 160 psi / 60 psi on the tubing. Swap over to 8.6 ppg brine @ 4 BPM, 220 psi down IA, 80 psi on the Tubing. Pressure at 50 bbl away, IA =120 psi / 50 psi on tubing, 100 bbls away, 70 psi IA / 110 psi tubing, 150 bbl away,50 psi IA / 110 psi tubing,200 bbls away, 50 psi IA / 40 psi tubing, 269 bbls away, 70 psi IA / 10 psi tubing. Pressure after shutting down pump, 0 IA / 0 Tubing. 17:30 18:00 0.50 COMPZ WELLPF KLWL P Shut down after 369 bbl total of 8.6 ppg brine pumped. Check level in return tank, (292 bbl total returns). Back on line pumping 8.6 ppg brine at 4 bpm, 70 psi on IA / 10 psi on tubing, until 8.6 ppg brine is at surface. 18:00 19:30 1.50 COMPZ WELLPF OWFF P Pumped another 70 bbls of 8.6 ppg Brine down IA before seeing good 8.6 ppg Brine back at surface. Shut down pump and monitor well for flow for 15 mins and Bullhead another 50 bbls of brine down Tubing. Monitor Well on a slight vacuum. 19:30 20:30 1.00 COMPZ RPEQP1NUND P PJSM. Rig down Kill Lines. Nipple down Production Tree. 20:30 00:00 3.50 COMPZ WELCTL NUND P PJSM. Nipple up 13 5/8" x 5K BOP Stack. 37/11/2011 Nipple up 13 5/8" x 5K BOP Stack. Perform initial BOPE Test. Pull Tubing Hanger. Single down the 4 1/2" Completion with ESP /HT/TEC Cables. 00:00 05:00 5.00 COMPZ WELCTL NUND P Continue to Nipple up BOPE. Install 2 3/8" Pipe Rams (solids) in the Upper Gate. Verify that 2 7/8" x 5 1/2" VBPRs are installed in the Lower Gate. 05:00 05:30 0.50 COMPZ WELLPF SFTY P PJSM. Discuss Hazard and Duty for Testing BOPE. 05:30 12:30 7.00 COMPZ WELLPF BOPE P Perform Initial BOP test. 12:30 14:00 1.50 COMPZ WELLPF EQRP T PJSM. Had to replace seals on Blind Rams. Rig testing equipment and test joint. Charge Up Hydraulic System. Page 2 of 24 • • Time Logs Date From To Dur S. Depth E. Death Phase Code Subcode T Comment 14:00 17:30 3.50 COMPZ WELLPF BOPE P Continue with BOP Test. Completed the initial BOPE Test per Conoco /Phillips and AOGCC requirements at 250/3,000 psi. Good. Perform Koomey draw -down test. Good. Pressure tests recorded on Chart. The State's right to witness the test was waived by B. Noble. Rig down Test Equipment. 17:30 18:00 0.50 COMPZ WHDBO MPSP P Pull Blanking Plug and BPV. 18:00 20:30 2.50 COMPZ WHDBOTHGR P PJSM. Make -up Landing Joint. BOLDS. Attempted to pull the Tubing Hanger free. Worked up to 80% of the tubing tensile strength plus Top Drive weigh (210K). Continue to work to pull free. No -Joy. Call out Steam Unit from the Wash -Bay. 20:30 21:30 1.00 COMPZ WHDBOTHGR P PJSM. with all. Discuss the hazards associated with working around steam. Wrap Wellhead and hook -up steam hose. Apply steam to Wellhead and pull 200K on Tubing Hanger. Hanger "popped free" after 15 minutes. Rig down Steam Unit and release. Tubing free with normal weight = 123K (includes Top Drive weight). 21:30 22:30 1.00 COMPZ RPCOM CIRC P Circulate and condition Well with 8.6 lb /gal, w /3% KCL at 4.0 bpm /90 psi. Total volume 275 bbls 22:30 00:00 1.50 6,227 6,196 COMPZ RPCOM THGR P Pull Tubing Hanger to floor. Disconnect TEC /HT /ESP cables from Hanger. Test and cut cable. Lay down Tubing Hanger and Landing Joint. 37/12/2011 Un -seat the Tubing Hanger and pull to the Floor. Circulate Well. RU to pull the 4 1/2" ESP /HT Completion. Single down 4 1/2" Tubing and spool ESP, HT, TEC Cables. Lay down ESP Assembly. Clean and Clear pipe she_ d. Test Annular with 2 3/8 test joint 250/3000. Set Wear Ring. PU MU Push Pipe and RIH to 217 -ft. 00:00 13:00 13.00 6,196 46 COMPZ RPCOM PULD P PJSM- Rig up to pull ESP /HT/TEC cables. POOH Single down 4 1/2 ESP completion to pipe shed. Number & Tally Tubing, Count Clamps. Page 3 of 24 • • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 13:00 15:00 2.00 46 0 COMPZ RPCOM PULD P At the tubing TTC crossover w /perforated intake, lay Down a total of 197 joints of 4 1/2" Tubing, joint 193 had a hole in the side of the tubing, 11' 7" feet from the pin end, that was the only hole found, the rest of tubing showed signs of heavy scale. Lay down the tandem seal section, ESP motor, and Phoenix gauge with motor centrilizer. Fluid Sample was taken from ESP motor. Lost a total of (9) SS flat bands and (1) 5 -ft Flat guard in hole. (3) protectolizers (457) 5 -ft dual channel Cannon clamps (3) 4 -ft dual channel Cannon clamps (4) 3 -ft dual channel Cannon clamps (4) 2 -ft dual channel Cannon clamps (52) single cross coupling clamps (103) dual cross coupling clamps (1) heat trace shoe (1) 6 -ft flat guard (33) SS bands 15:00 19:30 4.50 0 0 COMPZ RPCOM PULD P Load and un -load storage containers for ESP equipment. Clean and clear rig floor of clamps. Continue to load and tally Drill Pipe & PH -6 work string. 19:30 21:00 1.50 0 0 COMPZ WELLPF BOPE P RU test equipment, Pressure Test Annular to 250/3000 with 2 3/8 PH -6 test joint, LD test equipment. 21:00 21:30 0.50 0 0 COMPZ WELLPF OTHR P RIH and Set Wear Ring. 21:30 23:00 1.50 0 0 COMPZ WELLPF OTHR P Continue Tally ID, OD, and Fishnecks of all Push Pipe. 23:00 00:00 1.00 0 217 COMPZ WELLPF PULD P PU MU Push Pipe and RIH to 217 -ft. 37/13/2011 Load and Tally Push Pipe and 2 3/8 PH -6 work string. PU and RIH with Push Pipe and HWDP, POOH and stand back. PU BHA# 1 and RIH picking up DP to 2,060 -ft and set down, attempt to work thru - no luck. POOH and standing back. Change Head from 6 3/4 to 6 1/8 and RIH w/ BHA #2 to 2,093 -ft. POOH and Drop CSG Scraper. RIH w/ BHA #3 to 6,970 -ft. 00:00 05:00 5.00 217 1,820 COMPZ WELLPF PULD P Continue RIH with Push Pipe from 217 -ft to 1376 -ft, PU 15 joints HWDP to 1820 -ft. 05:00 06:30 1.50 1,820 1,820 COMPZ WELLPF CIRC P Kelly Up and Reverse Ciruclate to Work string until clean. 06:30 07:00 0.50 1,820 0 COMPZ WELLPF PULD P PJSM. POOH F/1820 ft standing back HWDP, Up wt =82k. 07:00 07:30 0.50 0 0 COMPZ WELLPF PULD T PJSM. Load Needed tools to Rig floor to clean down to hook hanger. 07:30 09:00 1.50 0 355 COMPZ FISH PULD T PJSM. M/U BHA #1. Reverse Jet Basket, String magnet,2 Boot basket,Scraper,Bumper sub and jars, w /HWDP and Intensifier. Page 4 of 24 • • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 09:00 10:30 1.50 355 2,060 COMPZ FISH TRIP T Single In w/ Clean Out Assembly on 3 1/2" Drill Pipe. Set Down with Junk Basket at 2060 ft. Up Wt =65k, Dn Wt =58k. 10:30 11:00 0.50 2,060 2,060 COMPZ FISH OTHR T MU to TD and Try to rotate passed tight spot or junk. TD Torque 1650# at 30 RPM, 1 -2K WOB. Started to rotate down and stalled top drive. Seen 4 -5k over pull after stall. Attempt one time with same results. Call Town Engineer. Discuss Option. PUH, fluid pack tubing and drop 7/8" ball and fluid pack to reverse circulate. 11:00 12:00 1.00 2,060 2,060 COMPZ FISH CIRC T PUH 30 ft and Fluid pack. Circulate at 8 bpm, 1410 psi, working DP up and Down while pumping and working junk basket, still seeing same tag depth at 2060 ft and seeing drag on tool string from 2045 ft down to tag depth. Tried rotating once at 5 rpm,with same results. 12:00 12:15 0.25 2,060 2,030 COMPZ FISH SFTY T PJSM. Discuss Hazard of TOOH. 12:15 13:15 1.00 2,030 355 COMPZ FISH TRIP T TOOH standing back DP to Inspect and Check junk and boot basket. 65k up weight. 13:15 13:30 0.25 355 0 COMPZ FISH PULD T Break Down BHA and Inspect BHA. Scraper look good with no marks, Boot basket were empty and junk basket was clean. Had metal from the housing of the ESP cable on the magnet. 13:30 14:30 1.00 0 0 COMPZ FISH OTHR T Wait on a smaller nose end for the junk basket. 14:30 15:00 0.50 0 355 COMPZ FISH PULD T PJSM. M/U BHA #2. Reverse Jet Basket, String magnet,2 Boot basket,Scraper,Bumper sub and jars, w /HWDP and Intensifier. 15:00 15:45 0.75 355 2,030 COMPZ FISH TRIP T TIH In w/ Clean Out Assembly on 3 1/2" Drill Pipe. 15:45 16:45 1.00 2,030 2,093 COMPZ FISH CIRC T Stop and Make -up to TD and Reverse Circulate down from 2,030 ft & stack out again at 2,060 ft with Junk Basket, able to work junk basket down to 2,093 if while stacking 15k down weight. Continue in hole and sat down hard with scraper assembly at 2,060 ft. Ciruclate up and down with junk basket and POOH. 16:45 17:00 0.25 2,093 355 COMPZ FISH TRIP T POOH f/ 2,093 -ft to 355 -ft. 17:00 17:30 0.50 355 0 COMPZ FISH TRIP T POOH with BHA #2, dropping out CSG scraper, clean magnets and inspect RCJB. 17:30 18:00 0.50 0 351 COMPZ FISH TRIP T RIH w/ BHA #3 to 351 -ft. Page 5 of 24 • • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 18:00 23:30 5.50 351 6,882 COMPZ FISH TRIP T Continue to RIH w/ BHA #3 on 3 1/2 DP from 351 -ft to 2,000 -ft. KU (kelly Up) and wash through tight spot at 2,060 -ft. Continue to RIH picking 3 1/2 DP to 5,507 -ft. Ran 2 stds of 3 1/2 HWDP and 13 stds of Hybrid push pipe to 6,882 -ft. 23:30 00:00 0.50 6,882 6,970 COMPZ FISH WASH T Kelly Up and wash down from 6,882 -ft to 6,970 at 8 bpm at 3,700 psi Rotating at 30 rpms at 3,900 ft/lbs free torque at 115k ROT wt. UP wt 155k DN wt 95k 07/14/2011 Continue to 0/0 from 6,970 -ft to 7,040 -ft. POOH and Inspect RCJB. ND Riser and NU 7" x 13 5/8 Shooting Flange. RU HES and PDS - RIH w/ 40 Arm Caliper tool to 6502 -ft and log back to 115 -ft where Wireline over pulled. 00:00 01:30 1.50 6,970 7,024 COMPZ FISH WASH T Continue to wash down from 6,970 -ft to 7,024 -ft. at 4 bpm at 780 psi. UP wt 155k DN wt 95k 01:30 07:00 5.50 7,024 351 COMPZ FISH TRIP T POOH f/ 7,024 -ft to 351 -ft 07:00 08:00 1.00 351 0 COMPZ FISH PULD T POOH, Lay down and inspect boot basket and junk basket. Had 2 small section of SS bands in the boot basket and 1 small peace inside junk basket and some armor from the ESP cable on the magnet. 08:00 11:00 3.00 0 0 COMPZ EVALWE NUND P Nipple Down Annular and Nipple Up Shooting Flange. Call Out E -line Crew. 11:00 12:00 1.00 0 0 COMPZ EVALWE OTHR T Wait On E -line Crew. Continue to Load PH -6 Tubing in Pipe Shed. 12:00 12:15 0.25 0 0 COMPZ EVALWE SFTY P E -Line on Location. Hold PJSM with E -line crew and Rig crew. 12:15 15:15 3.00 0 0 COMPZ EVALWE ELOG P Spot E -line equipment and Load tools to Rig Floor. 15:15 17:00 1.75 0 0 COMPZ EVALWE ELOG T Had to Re -head E -Line Cable. 17:00 19:00 2.00 0 0 COMPZ EVALWE ELOG T RIH with PDS Caliper (4 centralizers) / GR / CCL to 2052 -ft, attempt to pass- POOH and remove 2 of 4 centralizers. 19:00 20:00 1.00 0 0 COMPZ EVALWE ELOG T RIH with PDS Caliper (2 centralizers) / GR / CCL to 2052 -ft, unable to pass- POOH and add more weight to toolstring (TS weight 285 Ibs) 20:00 22:00 2.00 0 6,502 COMPZ EVALWE ELOG P RIH with PDS Caliper / GR / CCL, work Tool string through tight spots 2052 -ft to 2059 -ft, Continue RIH to 6183 -ft, work past easily and sat down at 6480 -ft, unable to work past 6485 -ft (74 degrees) after E -line Gamma Ray correlation, found depth to be 6502 -ft ELM 22:00 00:00 2.00 6,502 115 COMPZ EVALWE ELOG P Log up from 6502 -ft to Over Pull at 115 -ft. Page 6 of 24 • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode - T Comment J7/15/2011 24 hr Summary Evaluate Over Pull and POOH with PDS Caliper / GR/CCL from 115 -ft to Surface. RIH with GYRO /GR/CCL to 6502 -ft and log back to Surface, RD E -line. ND Shooting Flange. NU Annular. PU MU and RIH with 7 5/8 Casing Scraper Assembly (BHA #4) to 6995 -ft with little or no drag. POOH with BHA #4 to 6150 -ft. Slip and Cut 84 -ft Drilling Line. Continue POOH with BHA #4 to 1879 -ft. 00:00 02:30 2.50 115 0 COMPZ EVALWE ELOG P Over Pulled (500#) at 115 -ft, stuck in Grease Head and unable to RBIH. Inspect line at Grease Head with no visible signs of damage. Work wire free and RIH to 200 -ft. Bring on Charge pump at 2 bpm and wash line while POOH and Over Pull at 115 -ft. Monitor well for flow. PU Lubricator 4 -ft and inspect 50 -ft of line below Grease Head, no visible signs of damage. MU lubricator and pull 1000# over and POOH to surface. Data sent for Interpretation. 02:30 04:00 1.50 0 0 COMPZ EVALWE ELOG T Cut 300' and rehead line. remove Grease Head and install Dual stripper pack off. 04:00 04:15 0.25 0 0 COMPZ EVALWE ELOG P Standby for GYRODATA Tool checks. 04:15 06:00 1.75 COMPZ EVALWE ELOG P Rig Up GYRO, RIH and log continuous GYRO down. Station Stops © 50, 590, 690, 750. 06:00 10:00 4.00 2,092 6,504 COMPZ EVALWE ELOG P HES Crew Change. Continue RIH w/ Gyrodata tool string. Tools stop falling at 2092' try pass again, succeed, Log down for continuous GYRO survey making stops at 4250' and 6,504 feet. Log out for continuous Gyro Survey from 6504' to surface making stops at 4350', 2500', 750', 690', 590', to surface. 10:00 10:15 0.25 0 0 COMPZ EVALWESFTY P PJSM with E -Line and Rig Crew on Rigging down E -Line Tools. 10:15 11:00 0.75 0 0 COMPZ EVALWE PULD P Rig back and lay Gyrodata Tool string and E -line Tools and Equipment. 11:00 12:30 1.50 0 0 COMPZ EVALWE NUND P ND Shooting Flange and NU Annular. 12:30 13:30 1.00 0 45 COMPZ WELLPF PULD T PJSM with Baker Rep and Rig Crew. Load Tools to Rig Floor. MU 7 5/8" Scraper Assembly with 4 3/4" Bumper Sub on 3 1/2" Drill Pipe. 13:30 16:30 3.00 45 6,995 COMPZ WELLPF TRIP T Continue in hole with Scraper Assembly on 3 1/2" DP. Able to work 7 5/8" Scraper down to 6995.0 ft, leaving two foot of the Mule shoe passed the Hook hanger. PUH 10 feet. Up Wt =163k / Down Wt =90k 16:30 18:30 2.00 6,985 6,985 COMPZ WELLPF CIRC T Reverse Circulate 27 bbl High -Vis Sweep at 5 bpm and Circulate BU. ICP 140 psi FCP 210 psi. 18:30 19:30 1.00 6,985 6,110 COMPZ WELLPF TRIP T Blow Down Top Drive. Fill Trip Tank. POOH from 6985 -ft and stand back 10 stands of Push Pipe to 6110 -ft Page 7 of 24 • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 19:30 21:30 2.00 6,110 6,110 COMPZ WELLPF SLPC T PJSM- Hang Blocks, Slip and Cut 84 -ft of 1 -1/8" Drill Line and service draw works. 21:30 00:00 2.50 6,110 1,879 COMPZ WELLPF TRIP T . Continue to POOH from 6110 -ft standing back 5 stands of Push Pipe, 5 stands of HWDP and 34 stands of Drill Pipe to 1879 -ft. Up wt. 52k 37/16/2011 Continue POOH with BHA #4, LD KO. Load BHA #5. PU MU BHA #5 and change over floor equipment. PU MU and RIH with 4407 -ft of 2 3/8 PH -6 plus remainder of BHA #5. RIH with BHA #5 cleaning out from Top of Fill at 9748 -ft to 10180 -ft. 00:00 01:00 1.00 1,879 0 COMPZ WELLPF TRIP T Continue to POOH from 1879 -ft standing back remainder of DP and Scraper BHA, Lay Down same. 01:00 02:00 1.00 0 0 COMPZ WELLPF OTHR T Kick Out Scraper BHA #4 and load Clean Out BHA #5. Change over floor equipment. 02:00 08:00 6.00 0 4,407 COMPZ WELLPF TRIP P PJSM. M/U 2 3/8" Mule Shoe and Single in 2 3/8" PH 6 Tubing Down to 4,407 ft. Up Wt =52k. 08:00 09:00 1.00 4,407 4,780 COMPZ WELLPF PULD P PJSM, 0/0 Floor Equipment and Make Up BHA #5. String Magnet/Dual Boot Baskets /String Magnet/Bumper Sub /Jars // Pump Out Sub /9 jts. /HWDP /Intensifier and Drill Pipe 09:00 10:30 1.50 4,780 7,100 COMPZ WELLPFTRIP P Continue in hole with clean out assembly on 3 1/2" Drill Pipe. Set down at 7,038 ft ( bottom of hook hanger) able to work passed, continue down to 7,100 ft, stop and set top drive torque to 6k 10:30 11:00 0.50 7,100 7,261 COMPZ WELLPF CIRC P Continue down to 7,261 ft. Stop and circulated at 3 bpm, 900 psi to make sure Drill pipe is clear. 11:00 12:30 1.50 7,261 7,948 COMPZ WELLPFTRIP P Continue in hole with clean out assembly. Wt CK @ 7,680 ft, 105k up / 63k dn. Set down at 7,948 ft. 12:30 15:00 2.50 7,948 8,466 COMPZ WELLPF CIRC P Start Circulating at 4 bpm, 1700 psi, Rotating at 11 rpm, Torque at 2 -3k 15:00 18:00 3.00 8,466 9,350 COMPZ WELLPF CIRC P Continue to Circulate at 4 bpm, 1935 psi, rotating at 11 RPM, 2 -3k torque, cleaning blank section of 4" liner and slotted section 4" liner. Adding safe tube to the pit system to help with torque and drag, and circulating pressure. 18:00 00:00 6.00 9,350 10,180 COMPZ WELLPF CIRC P Continue to Circulate at 4 bpm at 2240 psi, 2 -3k torque at 10 rpm, Up 113k Down 63k, cleaning blank section of 4" liner and slotted section 4" liner. Adding safe lube to the pit system to help with torque and drag, and circulating pressure. Page 8 of 24 • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 07/17/2011 24 hr Summary Pick up out of 4" liner f/ 10,270 -ft to 7196 -ft to rebuild surface volume. Continue RIH w/ Clean out BHA. Clean out lower 4" liner f/ 10,257 -ft to 11,400 -ft. Circulate 4 bpm until clean @ 2300 psi with average 50% loses, 3100 ft/lb Torque @ 11 rpm, Up / Dn= 135k / 87k. POOH standing back Push Pipe and DP. LD- KO Clean out BHA. Change over floors to 2 3/8 equipment. 00:00 01:00 1.00 10,180 10,270 COMPZ WELLPF CIRC P Continue to Circulate at 4 bpm at 2240 psi, 2 -3k torque at 10 rpm, Up wt 113k Down wt 63k, cleaning blank section of 4" liner and slotted section 4" liner 10,180 -ft to 10,270 -ft. Adding safe tube to the pit system to help with torque and drag, and circulating pressure. 01:00 03:30 2.50 10,270 7,193 COMPZ WELLPF CIRC T Pick Up out of 4" Liner f/ 10270 -ft to 7193 -ft to rebuild Surface Volume. Unable to filter fluid and transport fluid to the rig at the same time. 03:30 11:00 7.50 7,193 7,193 COMPZ WELLPFCIRC P Build Surface Volume in spare up -right tanks. RIH with clean out assembly f/ 7193 -ft. 11:00 15:00 4.00 7,193 10,257 COMPZ WELLPF CIRC P Back on bottom with clean out assembly. M/U to TD and Continue to clean out blank section and slotted section of 4" Liner. Pump Rate 4 bpm, 2080 psi, rotating at 11 rpm, 2 -2.5k torque. Up wt= 118k / Dn Wt= 75k, rotating wt =85k. Set down on Fill at 10,257 ft. 15:00 17:30 2.50 10,257 11,400 COMPZ WELLPFCIRC P Able to clean 4" Liner down to 11,400 ft, while pumping at 4 bpm, 2290 psi, Rotating at 11 rpm, 3000 ft/lbs torque, average loses at 50 %, pumped high -vis sweep on every 1000 ft of liner clean, very little sand seen across shakers. Pumped another High -Vis sweep after reaching 11,400 ft and continue to circulate until clean. 17:30 22:00 4.50 11,400 4,780 COMPZ WELLPF TRIP P Blow Down Top Drive. POOH f/ 11,400 -ft, Up wt= 143k / Dn wt =90k standing back Push Pipe and Drill Pipe to 4780 -ft. 22:00 23:00 1.00 4,780 4,403 COMPZ WELLPF PULD P Lay down Intesifier / HWDP / Clean out BHA to 4403 -ft. Up wt =53k / Dn wt= 50k 23:00 00:00 1.00 4,403 4,403 COMPZ WELLPF SFTY P PJSM- Laying down 2 3/8 PH -6 Tubing. Table Top Man Down Drill. Change over floors to 2 3/8 equipment. 07/18/2011 Single out 2 3/8 PH -6. CIO Floors. PU -MU and RIH with 6 3/4 String Mill on Drill Pipe, will not pass 2078 -ft - with 15k Dn wt. POOH & LD BHA #6. Weekly BOPE test performed, witnessed by Jeff Jones. PU -MU and RIH with 4 1/4 IBP on 3 1/2 Drill Pipe to 5143 -ft. 00:00 04:00 4.00 4,403 0 COMPZ WELLPF PULD P Single out 2 3/8 PH -6 Tubing to pipe shed. Changed out Joint 129 due to bad Tread in box end, strapped and entered into Master sheet. Page 9 of 24 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 04:00 05:00 1.00 0 0 COMPZ WELLPF PULD T PJSM. Change over floors. Load String Mill Assembly to floor. 05:00 05:45 0.75 0 455 COMPZ WELLPF PULD T PU MU Mule shoe / 6 3/4 String Mill / 1 std Hybrid DC / Dual 4 3/4 Boot Baskets / Bit Sub / String Magnet / Bumper Sub / Jars / Pump Out Sub / 9 jts HWDP / Intensifier followed by 3 1/2 DP. 05:45 06:30 0.75 455 2,078 COMPZ WELLPF TRIP T Continue In hole with String Mill assembly on Drill Pipe. Set down at 2,050 -ft, stacked 4k down and fell thru, continue in slow and set down at 2,078 -ft, stacked 17k down no -go, puh 5 feet and try to rotate at 5 rpm and torque up. POOH 06:30 07:15 0.75 2,078 455 COMPZ WELLPF TRIP T PJSM. POOH standing back Drill Pipe. 07:15 08:00 0.75 455 0 COMPZ WELLPF PULD T Lay Down 6 3/4" String Mill Assembly. 08:00 16:00 8.00 0 0 COMPZ WELLPF BOPE P Set Test Plug and Perform Weekly BOP Test 250/3000 psi. Annular 250/3000 psi. witnessed by Jeff Jones. 16:00 17:00 1.00 0 0 COMPZ WELLPF BOPE T Inspect and Replace seals on the VPR's. 17:00 18:00 1.00 0 0 COMPZ WELLPF BOPE P Continue Testing BOPE, 250/3000 psi. 18:00 19:00 1.00 0 0 COMPZ WELLPF BOPE P Rig Down Test equipment. Pull Test Plug. Set Wear Ring. 19:00 00:00 5.00 0 5,143 COMPZ WELLPF PULD P PJSM. PU MU 4 1/4 IBP / Running Tool Assembly (BHA #7) and RIH on 3 1/2 Drill Pipe to 5143 -ft. Up wt= 93k / Down wt= 74k. 37/19/2011 POOH w/ IBP Running Tool. RIH w/ Retrieving head on DP to 6950 -ft. Dump 20 -ft sand on IBP. POOH with Retrieving head Assembly. P/T Casing 1500 psi. POOH f/ 6,980 -ft to 3,387 -ft. 00:00 01:30 1.50 5,143 6,974 COMPZ WELLPFTRIP P Continue RIH with 4 1/4 IBP on 3 1/2 Drill Pipe f/ 5143 -ft to 6974 -ft. Up wt= 137k, Down wt= 95k 01:30 01:45 0.25 6,974 6,947 COMPZ WELLPF PLUG P Kelly Up and pump pipe volume of 52 bbls at 3 bpm. ICP= 500 psi, FCP 570 psi, returns at 31 bbls. 01:45 02:15 0.50 6,974 7,000 COMPZ WELLPF PLUG P Drop 1/2" steel ball, add 1 joint HWDP and RIH 26' to 7000 -ft (bottom of IBP) bring pump on 1.5 bpm for 17 bbls and caught pressure. 02:15 03:15 1.00 7,000 6,970 COMPZ WELLPF PLUG P Pressure up IBP in 500 psi stages, 10 minutes each. Shear off IBP @ 2040 psi, Stack 5k down, Pick off clean to 6970 -ft. IBP set. 03:15 04:00 0.75 6,970 6,970 COMPZ WELLPF PRTS P Pressure Test against IBP tp 1450 psi, pressure bleeds back to 800 psi in 5 minutes then slows. Attempt same Pressure test with same results. 04:00 09:30 5.50 6,970 0 COMPZ WELLPF TRIP P POOH with IBP setting tool standing back DP. Page 10 of 24 IP Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 09:30 10:30 1.00 0 0 COMPZ WELLPF PULD P Lay Down Setting tool BHA 10:30 13:30 3.00 0 6,980 COMPZ WELLPF TRIP P PU Retrieving Head and RIH on DP to 6,980-ft 13:30 21:00 7.50 6,980 6,980 COMPZ WELLPF MPSP P Dump 400# 40 -20 river sand while pumping minimum rate. Pump 52 bbl pipe volume. Let sand settle above IBP for 1 hr. RIH to 6,980 -ft No tag. POOH to 6,534 -ft. and Reverse circulate 30 bbls at 2 bpm at 170 psi. RIH f/ 6,534 -ft to 6,980 -ft and Soft Tag Sand Top with 2k down. 21:00 21:30 0.50 6,980 6,980 COMPZ WELLPF PRTS T Pressure Test IBP in 7 5/8 Casing 1000 psi and IBP let loose. 21:30 21:45 0.25 6,980 6,980 COMPZ WELLPF SFTY T Held PJSM on POOH with BHA #8 21:45 00:00 2.25 6,980 3,387 COMPZ WELLPF TRIP T POOH from 6,980 -ft to 3,387 -ft as of midnight. 73k up wt, 63k do wt. 37/20/2011 Continue to POOH f/ 3,387 -ft to surface. PU and MU 6.5" OD CSG swage and RIH to 2,995 -ft with no issues. POOH and Continue to swage out to 6 3/4" from 2,050 -ft to 2,136 -ft. Fell out and slide to 2,160 -ft. 00:00 02:00 2.00 3,387 0 COMPZ WELLPF TRIP T POOH from 3,387 -ft to Surface and lay down "L" retreiving head assy. 02:00 04:00 2.00 0 772 COMPZ FISH PULD T PU, MU and RIH with BHA #9 (6.5" OD CSG swage assy) to 772 -ft. 04:00 05:30 1.50 772 2,995 COMPZ FISH TRIP T RIH w/ BHA #9 on 3 1/2" DP from 772 -ft. to 2,995 -ft. No issues with swage assembly. 05:30 08:00 2.50 2,995 0 COMPZ FISH SWDG T TOOH w/ BHA# 9. LD BHA #9. Load 6 5/8" and 6 3/4" swages in pipe shed. 08:00 10:30 2.50 0 2,995 COMPZ FISH PULD T PJSM. MU BHA # 10 6 5/8" Swage assembly. RIH w/ Swage on 3 1/2" DP to 2,995 -ft. Took 2-4K down weight from 2,077 -ft to 2,157 -ft, no other issues. 10:30 12:30 2.00 2,995 0 COMPZ FISH TRIP T TOOH w/ BHA# 10. LD BHA # 10. Page 11 of 24 • Time Logs Date From To Dur S. Death E. Depth Phase Code Subcode T Comment 12:30 00:00 11.50 0 2,160 COMPZ FISH PULD T PJSM. MU BHA # 11 6 3/4" Swage assembly. RIH w/ Swage on 3 1/2" DP to 6,800 -ft. Set down @ 2,050 -ft, start swaging on tight spots at 13:30. Continue to swedge thru to 2,057 -ft. - fell thru at 14:00 hrs. Pull back up above and slide thru with 15k down to Tag up at 2,074 -ft. Swedge thru to 2,078 -ft. Fell thru at 14:45 hrs and continue to RIH to 2,080 -ft and set down. At 15:45 hrs Conduct Top drive and derrick inspection. Begin swedging at 16:15 hrs from 2,080 -ft to 2,086 -ft and fell thru at 19:35 hrs to 2,108 -ft. Begin filling hole with 3% safe lube by vol. at 18:00 hrs at 15 bbl /hr rate and continue Swedge from 2,108 -ft to 2,112 -ft and fell thru at 22:00 hrs, slide down to 2,118 -ft at 23:00 hrs, work thru to 2,122 -ft and fell thru to 2,131 -ft. Work thru to 2,136 -ft and fell thru. RIH to 2,160 as of midnight. J7/21/2011 Continue RIH with 6 3/4 OD Casing Swage f/ 2,160 -ft to 3,061 -ft. Slip and Cut 1500 -ft Drill Line. PUH and work 6 3/4 OD Swage between 2,050 -ft and 2,136 -ft. POOH and check BHA and Joint tightness. Utilizing Daily Jars work 6 3/4 OD Casing Swage back and forth between tight areas 2,050 -ft and 2,083 -ft. Push 6 3/4 OD swage down through 2,083 -ft at 35k Down wt, Drag back up through 2,083 -ft at 30k. 00:00 02:00 2.00 2,160 3,061 COMPZ FISH SWDG T Continue R1H f/ 2,160 w/ 6 1/4 Casing Swage. Set down at 2,921 -ft, Drill string floating or pushing fill to 3,061 -ft. Pump down Annulus and string weight returns. PUH to 2,836 -ft at 01:30 clean. Set Slips. Maintain hourly hole fill. 02:00 05:30 3.50 2,836 28 COMPZ RIGMNTSLPC T Slip and Cut 1500 -ft Drill Line, Full Spool. Inspect Derrick prior to POOH. 05:30 07:00 1.50 2,836 2,050 COMPZ FISH SWDG T PUH f/ 2,836 -ft to 2,130 -ft and pulled 80k over string up wt of 90k. Jar thru after several jar hits. Continue to pull up to 2,050 -ft. Working 6 3/4" OD CSG swedge through tight areas. 07:00 11:00 4.00 2,050 2,108 COMPZ FISH SWDG T RIH and from 2,050 -ft through tight spot at 2,061 -ft with 10k down drag and tagged up 2,080 -ft. Swedge thru to 2,085 -ft and fell free. Pull back thru at 55k over string wt of 90k. Continue to swedge back and forth this area. Best drag seen was 35 to 40k over pull. RIH and set down at 2,108 -ft. 11:00 12:00 1.00 2,108 2,112 COMPZ FISH SWDG T Continue to swedge thru from 2,108 -ft to 2,112 -ft and fell thru. Continue to work this area, 60k over string wt of 90k was best seen. Page 12 of 24 • • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 12:00 14:45 2.75 2,112 2,112 COMPZ FISH OTHR T While swedging bolts broke at top drive and fell to rig floor. Suspend swedging operations and locate area that bolts fell from. Replace bolts and inspect equipment. 14:45 15:00 0.25 2,112 2,112 COMPZ FISH SFTY T Held PJSM on Tripping out of the hole and changing BHA. 15:00 16:30 1.50 2,112 0 COMPZ FISH TRIP T POOH with 6.75" OD CSG swedge from 2,112 -ft. to CSG swedge. 16:30 17:30 1.00 0 0 COMPZ FISH PULD T LD Intensifier and Fishing Jars. Inspect Casing Swage, small gouge down one side. PU fresh Intensifier and Daily Up /Down Jars. MU BHA #10- 6 3/4 OD Casing Swage. 17:30 18:30 1.00 0 795 COMPZ FISH TRIP T RIH with 6 3/4 OD Casing Swage Assembly checking all breaks on BHA to 795 -ft. 18:30 19:30 1.00 795 2,050 COMPZ FISH TRIP T Continue RIH adding Drill Pipe to BHA checking breaks on all stands to 2,050 -ft. Up wt= 70k, Dn wt= 60k 19:30 23:30 4.00 2,050 2,095 COMPZ FISH SWDG T Slid through 2,050 -ft with 10k down to 2,083 -ft. Swage down at 2,083 -ft total of 14 Daily Jar hits and fell thru at 2,089 -ft. PUH with 50k over pull. Swage thru same area 12 times improving each time until only 3 Daily Jars down to pass, PUH with 30k over pull through 2,083 -ft. 23:30 00:00 0.50 2,095 2,083 COMPZ FISH SWDG T MU to Top Drive. Attempt to push through 2,083 -ft. Remove 1 joint DP to reduce flex on surface pipe. MU to Top Drive. Push through tight area 35k down wt. PU through 2,083 -ft with 30k over pull as of midnight. 37/22/2011 Swage Down f/ 2,083 -ft through 2,136 -ft w/ 6 3/4 OD Casing Swage. POOH standing back DP, LD BHA #12. PU MU and RIH w/ 6.70" OD Drift on DP to 2,995 -ft with no issues. POOH standing back DP, LD BHA #13. PU MU and RIH w/ 6.43" max OD ALC Dummy Drift to 3,011 -ft with no issues. POOH with ALC Dummy Drift to 212 -ft as of midnight. 00:00 03:00 3.00 2,083 2,118 COMPZ FISH SWDG T Push 6 3/4 Casing Swage through 2,083 -ft using Top Drive at 35k down wt. Set down at 2,108 -ft. 14 Dailey Jars to pass through 2,108 -ft, PUH through 2,108 -ft at 55k over pull. Work back and forth until only 5 Daily Jars to pass 2,108 -ft, PUH 25k over pull to pass 2,108 -ft. Unable to push through with Top Drive. Work through to 2,118 -ft. 03:00 03:30 0.50 2,118 2,118 COMPZ FISH SWDG T Swage down through 2,118 -ft w/ 4 Dailey Jars down. PUH through 2,118 -ft w/ 40k over pull. work back and forth several times w/ same results Page 13 of 24 • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 03:30 04:30 1.00 2,118 2,245 COMPZ FISH SWDG T RIH to 2,131 -ft and sit down. 1 Daily Jar and fell through, PUH with 20K over pull, repeat 3 times with same results. RIH to 2,245 -ft. Up wt= 70k, Down wt= 60k. 04:30 08:30 4.00 2,245 2,080 COMPZ FISH SWDG T POOH with 6 3/4 OD swage f/ 2,245 -ft. Over Pull 20 -30k through tight areas at 2,131 -ft, 2,118 -ft and 2,108 -ft. Over Pull 100k at 2,080 -ft. Swage thru tight area 10 to 12 cycles from 2,080 -ft to 2,086 -ft with 30k slide. Conduct derrick inspection. 08:30 09:00 0.50 2,080 795 COMPZ FISH TRIP T POOH from 2,080 -ft to 795 -ft. to BHA #11 09:00 10:00 1.00 795 0 COMPZ FISH PULD T POOH and lay down 6.75" OD CSG Swage. OD of Swage 6.75 ", minor scratches only. 10:00 10:30 0.50 0 0 COMPZ FISH OTHR T Bring in tools and off load BHA #10 10:30 10:45 0.25 0 0 COMPZ FISH SFTY T Held PJSM on PU and MU BHA #11 (6.70" OD CSG Swage assy) 10:45 13:00 2.25 0 2,995 COMPZ FISH TRIP T PU and RIH w/ BHA #11 to 2,995 -ft. Most drag seen through from 2,100 -ft to 2,122 -ft was 1k slack off. clean to 2,995-ft. 13:00 14:30 1.50 2,995 959 COMPZ FISH TRIP T POOH from 2,995 -ft to BHA at 959 -ft. No over pull seen. 14:30 15:45 1.25 959 0 COMPZ FISH PULD T POOH with BHA from 959 -ft laying down un- needed components to surface. No marks on 6.70 drift. 15:45 17:00 1.25 0 0 COMPZ FISH PULD T Send out Baker Tools and 3 DC's. Clean and change over floors to run 4 1/2 Tubing. Bring in ALC equipment. 17:00 20:00 3.00 0 212 COMPZ FISH PULD T PJSM w crews. PU MU and RIH 6.43" max OD ALC (BHA #12) Dummy as per ALC to 212 -ft. Change over floors to run 3 1/2 DP. 20:00 22:00 2.00 212 3,011 COMPZ FISH TRIP T RIH w/ ALC Dummy Drift Assembly on 3 1/2 DP. 18 stds down (1952 -ft) 58k do wt / 60k up wt. No Drag seen in tight area 2,050 -ft thru 2,136 -ft. No Drag seen to 3,011 -ft. 22:00 23:30 1.50 3,011 212 COMPZ FISH TRIP T PJSM. POOH from 3,011 -ft with ALC Dummy Drift to 212 -ft BHA #12. No Drag seen thru tight areas. - 23:30 00:00 0.50 212 212 COMPZ FISH PULD T Change Over floor to LD 4 1/2 Tubing as of midnight. 37/23/2011 PU MU & RIH w/ "G" RBP- Test Plug Assembly. Unable to pass 3,343 -ft, PUH and set RBP at 3,303 -ft. Test 7 5/8 Casing to 1500 psi, Passed and Charted. POOH w/ RBP assembly standing back DP, LD BHA #15. PU MU & RIH w/ IBP Retrieving Head Assembly to 7,186 -ft. Attempt to latch IBP unsuccessful. 00:00 02:30 2.50 212 0 COMPZ FISH PULD T POOH and LD 6.43" max OD BHA #12 Dummy Drift as per ALC. Send out ALC equipment. Clean & C/O floors. Load Baker tools. Page 14 of 24 • Time Logs Date From To Dur S. Depth _E. Depth Phase Code Subcode T Comment 02:30 03 :30 1.00 0 123 COMPZ FISH PULD T PU MU Baker RBP, 1 std DP, Retrievamatic Test Plug Assembly to 123 -ft 03:30 09:45 6.25 123 3,343 COMPZ FISH TRIP T RIH w/ RBP BHA #13 on DP. Sat down at 3208 -ft. Kelly Up, Pump down 2 bpm and work down to 3,343 -ft. PU and set "G" plug at 3,303 -ft. 09:45 10:45 1.00 3,303 3,303 COMPZ FISH PRTS P Pressure test 7 5/8" CSG from 3,303 -ft to surface at 1,500 psi for 15 minutes. Lost 50 psi in first 5 minutes and lost 0 psi in last 10 minutes. Bleed off pressure. Latch on to "G" plug and release same. Allow elements to relax. 10:45 11:15 0.50 3,303 3,303 COMPZ FISH SFTY P Held PSJM on POOH with integrity testing equipment. 11:15 13:30 2.25 3,303 0 COMPZ FISH TRIP P POOH from 3,303 -ft. to surface and laydown test •aaker and "G" plug. 13:30 14:00 0.50 0 0 COMPZ FISH SFTY P Held PJSM with Rig crew and Baker hand on changing out floor equipment and MU of BHA 14:00 15:00 1.00 0 0 COMPZ FISH OTHR T Change over to 2 3/8 TBG equipment and off load Test Packer assy. 15:00 15:45 0.75 0 231 COMPZ FISH PULD T PU and MU BHA #16 ( IBP retrieval tool) to 231 -ft. 15:45 16:00 0.25 231 231 COMPZ FISH OTHR T Change over to 3 1/2 DP equipment 16:00 20:00 4.00 231 6,916 COMPZ FISH TRIP T RIH adding DP, Push Pipe and 3 stds HWDP to 6916 -ft. Up wt= 133k, Dn wt= 88k. Kelly Up, pump 2 bpm @ 120 psi, 3 bpm @ 320 psi, 4 bpm © 650 psi, 5 bpm @ 970 psi. 20:00 23:00 3.00 6,916 7,186 COMPZ FISH TRIP T Continue RIH slowly adding last 2 stds HWDP, Spike in pump pressure @ 7,032 -ft, PUH but did not latch IBP continue RIH passing Hook Hanger at 7,040 -ft pumping 3 bpm. Sat down 5k @ 7186 -ft, pump pressure spike to 480 psi. Attempt to latch IBP multiple times pumping up to 5 bpm to not pumping, PUH and rotating 1/8 and 1/4 turns for new grapple orientation, RIH at different speeds, setting down up to 10k several times, unable to latch IBP. 23:00 23:30 0.50 7,186 7,186 COMPZ FISH SFTY P PJSM- Handleing Halliburton TCP guns and tools. Tripping out, LD BHA. 23:30 00:00 0.50 7,186 7,186 COMPZ FISH OTHR P Bring in Halliburton TCP guns and tools to pipe shed as of midnight 07/24/2011 Bring in HES TCP equipment. POOH f/ 7,186 -ft w/ IBP Retrieving Head Ass'y standing back DP- LD BHA #16. PU MU & RIH w/ IBP Retrieving Head (Short Catch) Ass'y to 7,185 -ft. POOH w/ failed 4 1/4 IBP standing back DP- LD BHA #17. PU MU & RIH w/ HES TCP Gun Ass'y to 3,342 -ft as of midnight. 00:00 00:30 0.50 7,186 7,186 COMPZ FISH OTHR P Bring in Halliburton TCP guns and tools to pipe shed as of midnight 00:30 01:00 0.50 3,342 COMPZ FISH OWFF P BDTD and monitor well, well on vac. Page 15 of 24 1 • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 01:00 04:00 3.00 7,186 231 COMPZ FISH TRIP T POOH f/ 7,186 -ft with IBP Retrieving Head Ass'y standing back HWDP, Drill collars and Drill Pipe to BHA #13 at 231 -ft. 04:00 04:30 0.50 231 231 COMPZ FISH OTHR T Change floor over to 2 3/8 TBG equipment 04:30 05:00 0.50 231 0 COMPZ FISH PULD T POOH laying down BHA #16 - No fish, inspect IBP Overshot. No sign of trash inside OS. 05:00 05:30 0.50 0 231 COMPZ FISH PULD T PU Series 70 Over shot w/ 1.75" Grapple. RIH to 231 -ft 05:30 06:00 0.50 231 231 COMPZ FISH OTHR T Change floor over to 3 1/2 DP equipment 06:00 09:30 3.50 231 7,185 COMPZ FISH TRIP T RIH from 231 -ft to 7,185 -ft. 09:30 10:30 1.00 7,185 7,185 COMPZ FISH FISH T Attempt to engage fish, unable to see pressure increase. Munipulate overshot multiple times. 10:30 10 :45 0.25 7,185 7,185 COMPZ FISH SFTY T Held PJSM on Blowing down Top drive and POOH w/ 3 1/2 DP. 10:45 15:00 4.25 7,185 231 COMPZ FISH TRIP T Blow down Top drive, POOH with 3 1/2 DP from 7,185 -ft. to 231 -ft. 15:00 15:30 0.50 231 231 COMPZ FISH OTHR T Change floor over to 2 3/8 TBG equipment 15:30 16:00 0.50 231 0 COMPZ FISH PULD T POOH laying down BHA #17 - Recovered fish, inspect IBP, showed damage on bottom - possibly. No sign of trash inside OS. 16:00 16:30 0.50 0 0 COMPZ FISH OTHR T Send out Baker tools 16:30 17:00 0.50 0 0 COMPZ PERF SFTY P PJSM w/ HES on assembling Perf Guns, Gun Safety. 17:00 19:30 2.50 0 924 COMPZ PERF TRIP P PU & assemble 2 3/4" 6spf Millennium Gun BHA #18 as per HES and RIH to 924 -ft. Up wt= 45k, Dn wt= 45k 19:30 00:00 4.50 924 3,342 COMPZ PERF TRIP P Single In 2 3/8 PH -6, L -80 Tubing f/ 924 -ft to 3,342 -ft filling every 5 stands, Up wt= 53k, Dn wt= 48k 37/25/2011 Continue to RIH w/ HES TCP Gun Ass'y f/ 3,342 -ft to 11,380 -ft. Fire Guns @ 11,380 -ft. POOH from 11,380 -ft standing back DP to 8,850 -ft as of midnight. 00:00 01:30 1.50 3,342 4,405 COMPZ PERF TRIP P Single In 2 3/8 PH -6, L -80 Tubing f/ 3,342 -ft to 4,179 -ft, install 4.12" OD no -go, continue to single in 2 3/8 _ PH -6 to 4,405 -ft, install XO. 01:30 02:00 0.50 4,405 4,405 COMPZ PERF OTHR P Change Over Floors to run 3 1/2 Drill Pipe. 02:00 04:30 2.50 4,405 7,304 COMPZ PERF TRIP P Cintinue RIH w/ HES TCP Guns adding 3 1/2 DP f/ 4,405 -ft to 7,304-ft 04:30 05:30 1.00 7,304 7,304 COMPZ PERF SVRG P Service Rig,. 05:30 07 :00 1.50 7,304 7,304 COMPZ RIGMN7 RGRP T Change out Stuffing Box. Page 16of24 • • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 07:00 16:30 9.50 7,304 9,530 COMPZ PERF TRIP P Continue RIH w/ HES TCP Guns adding 3 1/2 DP f/ 7,304 -ft. to 7,445 -ft and set down. Rotate 1/4 turn coming up 10 -ft and run back thru with no problems. Continue to RIH and setdown at 7,542 -ft try work thru, no luck. Pump down DP till fluid at surface and shut in DP. Close annular and pump down IA at 5 bpm at 156 psi. for 30 bbls. RIH to 7,859 -ft and set down, flush annulus and continue to RIH having to wash by pert guns to 9,530 -ft and was able to work on in the with very little trouble to 16:30 19:30 3.00 9,530 11,369 COMPZ PERF TRIP P Continue RIH adding Hybrid DC and HWDP. Able to work on in with very little trouble to 11,362 -ft. Up wt= 152k, Dn wt =85k. Add working joint, sat down and Tagged lightly (5k do wt) at 11,378 -ft (15 -ft into working joint) Tagged same spot several times to confirm Tag. Get weight back (152k) at 11,374 -ft. PUH to 11,369 -ft (6 -ft into working joint) with 10 -ft RKB correction bottom Gun at 11,379 -ft. Pump pipe volume of 61 bbls, 2.3 bpm @ 1000 psi. 19:30 21:00 1.50 11,369 11,369 COMPZ PERF PERF P Mouse hole working joint and drop 5/8" steel ball at 21:10. Add working joint, Kelly up and position guns again at 11,369 -ft. 11,379 -ft with 10 -ft RKB correction. bring pumps on 3 bpm at 1400 psi. 21:00 21:45 0.75 11,369 11,369 COMPZ PERF PERF P 32 bbls away when 5/8" ball seats, continue pumping 3 bpm. Guns Fired at 3350 psi and pipe pressure immediatly falls back to 1400 psi at 3 bpm for another 8 bbls, good recirculation through firing head. 21:45 22:00 0.25 11,369 11,369 COMPZ PERF SFTY P PJSM- Tripping OOH standing back DP. monitor well for flow, well on vac. 22:00 00:00 2.00 11,369 8,850 COMPZ PERF TRIP P PJSM- POOH from 11,369 -ft standing back HWDP, DC and DP to 8850 -ft (Up wt= 110k) maintaining hole fill, well still on vac as of midnight. 37/26/2011 Continue to POOH from 8,850 -ft w /Drill Pipe. Single down the 2 3/8" PH -6 Pipe. Lay down 2 3/8" " DP Conveyed Perf Guns. Swap out ESP Spools w /Crane. RU Test Equipment. Begin Weekly BOPE Test. 00:00 02:30 2.50 8,850 4,405 COMPZ PERF TRIP P Continue POOH f/ 8,850 -ft standing back DP to 4,405 -ft maintaining hole fill. 02:30 03:00 0.50 4,405 4,405 COMPZ PERF SFTY P Kick while tripping drill. PJSM- Single Out 2 3/8 PH -6. 03:00 04:00 1.00 4,405 4,405 COMPZ PERF OTHR P PJSM. Change over floors to 2 3/8 equipment. Page 17of24 • • Time Logs _ Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 04:00 07:30 3.50 4,405 926 COMPZ PERF TRIP P Single out 2 3/8 PH -6 Tubing from 4,405 -ft to 926 -ft 07:30 09:30 2.00 926 0 COMPZ PERF PULD P POOH f/ 926 -ft breaking down 2 3/4" TCP guns as per HES and sending out. 09:30 12:00 2.50 0 0 COMPZ RPEQP1OTHR P Crane arrives on Location. PJSM. Spot Crane. Change of ESP Spools on Rig Floor. Change out TEC Wire Spools. 12:00 13:30 1.50 0 0 COMPZ RPEQP1BOPE P Clear and clean Floor. Pull Wear Bushing. Set Test Plug. Rig up Test Equipment. 13:30 00:00 10.50 0 0 COMPZ WELCTL BOPE P Begin BOPE Test per Conoco /Phillips and AOGCC requirements at 250/3,000 psi. 37/27/2011 Complete weekly BOPE Test. Pick -up Baker Inflatable Cement Retainer. Single in with 2 3/8" PH -6 Tbg, continue in w/3 1/2" DP, DC, and HWDP. Drop Ball and set ICR. Establish Injection rates. RU Cementers. Pump Cement as designed. POOH w/ Work String. 00:00 05:00 5.00 0 0 COMPZ WELCTL BOPE P Complete the weekly BOPE Test at 250/3,000 psi. Perform Koomey draw down test. Record all pressure tests on Chart. The State's right to witness the test was waived by C. Scheve. (Note: had to troubleshoot Choke Manifold and replace Choke Valve #2. Re - -test same). Pull Test Plug. Install Wear Bushing. Rig down Test Equipment. 05:00 05:30 0.50 0 0 COMPZ RIGMNTOTHR P Grease crown, blocks, and prep for BHA # 19 ICR 05:30 10:30 5.00 0 3,042 COMPZ CEMEN TRIP P PU /MU Baker Inflatable Cement Retainer on 2 3/8" PH -6 pipe. TIH on PH -6 to 3,042 -ft with no problems. 10:30 11:00 0.50 3,042 3,042 COMPZ CEMEN' PULD P Change out floor equipment for 3.5" DP 11:00 20:00 9.00 3,042 10,010 COMPZ CEMEN' TRIP P Continue in hole with Baker ICR to 9,994 -ft on 3.5" DP, 4 3/4" Drill collars, and 3 1/2" Heavy Weight Drill Pipe. 20:00 00:00 4.00 10,010 9,985 COMPZ CEMEN' PACK P Blow down top Drive. Space out with the center element of the ICR at 9,985 -ft. ( Cementers on Location and begin to rig -up). Drop 1/2" steel Setting Ball. Bring Pump on line at 0.75 bpm /150 psi and attempt to pump ball on seat (48 bbis pumped). Attempt to surge ball to go on seat. No -Joy. Dropped a second lighter 1/2" Ball. Bring Pump on line at 0.9 bpm. After 44 bbis away ball went on seat at 550 psi. Allow Element to inflate. Bump pressure up to 800 psi. Continue to allow element to inflate. Repeat same at 1,400 psi, 1,800 psi, and again at 2,200 psi. Page 18 of 24 • • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 07/28/2011 24 hr summary POOH and single down the DP String. Prep to PU the 4 1/2" Completion. RU S -Line to drift the 4 1/2" Tbg. Single in with 4 1/2" Tbg. Trip out and stand back the 4 1/2" Tbg in the Derrick. Prep to PU and service ALC and Centrilift Equip. 00:00 00:15 0.25 9,985 9,985 COMPZ CEMEN" PACK P With 2,200 psi on ball seat, set 5K down on the Inflatable Cement Retainer. Bring final pressure up and shear out ball seat at 2,750 psi. 00:15 00:30 0.25 9,985 9,985 COMPZ CEMEN" OTHR P Perform an injection test with 8.6 lb/gal Brine as follows: 1.0 bpm /300 psi, 2.0 bpm /1,050 psi, and at 3.0 bpm /2,200 psi. 00:30 01:00 0.50 9,985 9,985 COMPZ CEMEN P PJSM and operational meeting with All. 01:00 03:30 2.50 9,985 9,985 COMPZ CEMEN" CMNT P Batch up 66 bbls of 8.5 lb/gal Ultra LiteCRETE w/ 2 -3 lb /gal CemNet. Prime up with 5 bbls of Fresh Water. Pressure Test Line at 4,000 psi. Begin 8.97 lb/gal Cement at 1.7 bpm /825 psi. Increase rate to 2.0 bpm. 25 bbls Cement away, 2.0 bpm /1,720 psi, density 8.99 lb/gal. 40 bbls Cement away, 2.0 bpm /1,940 psi, density 8.96 lb/gal. 50 bbls Cement away, 2.0 bpm /2,100 psi, density 8.96 lb/gal. Reduce rate to 1.5 bpm/1,925 psi. 56.5 bbls Cement to ICR, 1.5 bpm /2,100 psi, density 8.96 lb/gal. 60 bbls cement away, 1.4 bpm /2,250 psi, density 8.6 lb/gal. End Cement with 66.6 bbls pumped, 1.4 bbls /2,540 psi. Begin 8.6 lb/gal Brine displacement. 15 bbls displaced, 1.3 bpm /2,900 psi. 25 bbls displaced, 1.3 bpm/2,935 psi. Reduce rate to 1.0 bpm. 35 bbls displaced, 1.0 bpm /2,820 psi. 45 bbls displaced, 3,010 psi. End displacement with 56.5 bbls pumped, 0.7 bpm /2,085 psi. ISIP = 1,425 psi. Monitor final DP pressure at 1,230 psi and stable (bottom flapper closed). Bleed Drill Pipe pressure down to 500 psi. and monitor stable. Bottom Flapper is holding. Un -sting from the ICR at 170K. 03:30 06:00 2.50 9,985 8,166 COMPZ RPEQP1TRIP P Lay down 1 Joint and the two space -out Pups. Pump 10 bbls down the Drill Pipe. POOH standing back the DC /HWDP Stands (will lay down later). 06:00 06:30 0.50 8,166 8,166 COMPZ RPEQPI OWFF P Monitor well for flow. Static losses 78 BPH. 06:30 08:00 1.50 8,166 6,747 COMPZ RPEQP1TRIP P TOOH from 8,166 -ft to 6,747 -ft, just above leg.Up 90K Down 65K 08:00 10:00 2.00 6,747 6,747 COMPZ RPEQP1OTHR P Slip & Cut drill line. Page 19 of 24 • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 10:00 14:00 4.00 6,747 4,150 COMPZ RPEQP1TRIP P Continue out of hole from 6,747 -ft to 4,150, started pulling back wet. Monitor well, circulate bottom ups, suspect cement stringer plugging up off, pressure up initially, dropped off. 14:00 15:00 1.00 4,150 3,042 COMPZ RPEQP1RURD P Continue out of hole from 4,150 -ft to 3,420 -ft to 2 3/8" PH -6. Change handling equipment. 15:00 18:00 3.00 3,042 0 COMPZ RPEQP1TRIP P Continue out of hole laying down 2 3/8" PH -6 Tubing. Lay down Baker ICR Stinger. 18:00 20:30 2.50 0 0 COMPZ RPEQP1RURD P Change floor equipment to handle Drill Collars and Heavy Weight Drill Plpe. Clear Pipe Shed of the 2 2/3" PH-6 tubing. Bring in first row of the 4 1/2" Completion Tubing. 20:30 22:00 1.50 0 1,739 COMPZ RPEQP1TRIP PJSM. Trip in with the remaining Drill Collar /Heavy Weight Drill Collars stands left in the Derrick. 22:00 00:00 2.00 1,739 0 COMPZ RPEQPI PULD P Single down all remaining 4 3/4" Drill collars and the 3 1/2" Heavy Weight Drill Pipe. X7/29/2011 Load Pipe Shed with the 4 1/2" Completion Tbg. PU 4 1/2" Tbg. RU S -Line and drift same. POOH and stand back 4 1/2" Tbg. Make -up and service the Outer Completion BHA. Begin to RIH the WLESP w /Feed -thru Packer Completion on 4 1/2" Tbg. 00:00 04:30 4.50 0 0 COMPZ RPCOM PUTB P Load 4 1/2 ", 12.6 lb /ft, L -80, IBTM -SCC Tubing in the Pipe Shed. Drift and tally same. Rig up Floor to handle same. 04:30 05:30 1.00 0 0 COMPZ RPCOM RURD P Change out floor equipment. 05:30 12:00 6.50 0 5,873 COMPZ RPCOM PUTB P Single in hole with 4.5" IBTM Completion Tubing only to 5,873 -ft. 12:00 15:30 3.50 5,873 5,873 COMPZ RPCOM SLKL P PJSM. RU Slickline equipment. RIH w/ 12' X 3.80" Dummy drift to 1,062 -ft. Unable to work drift through doglegs between 700' - 1,100 -ft. POOH w/ Drift. RIH w/ 3.82" Centralizer, drift tubing to 5,873 -ft, no problems. POOH. RD Slickline. 15:30 20:30 5.00 5,873 0 COMPZ RPCOM TRIP P PJSM. TOOH w/ 4.5" Completion tubing standing back in derrick (63 stands). 20:30 21:00 0.50 0 0 COMPZ RPCOM TRIP P Pull Wear Bushing. Clear Floor. 21:00 22:00 1.00 0 0 COMPZ RPCOM RCST P Hang ESP Cable and TEC Wire Sheaves. 22:00 00:00 2.00 0 0 COMPZ RPCOM RCST P PJSM. Begin to pick -up the Outer Completion BHA per ALC Service Reps. 07/30/2011 Complete running the Outer Completion BHA. RU S -Line and Drift Tbg. MU and RIH with ALC, Centrilift, Motor /Seal Section on S -Line. Continue to Run the 4 1/2" WLESP Completion Tbg, ESP Cable and TEC Wire. Page 20 of 24 • • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 00:00 03:30 3.50 0 467 COMPZ RPCOM RCST P Complete making up the Outer Completion BHA. Run 1 Stand of 4 1/2" Tubing. Make -up the Guardian Discharge Pressure Sub. Attach the TEC Wire. Run 3 Stands of 4 1/2" Tubing. 03:30 04:30 1.00 467 467 COMPZ RPCOM SLKL P PJSM. Rig up S -Line. Drft Tubing w/3.80" Drift, down to the NO -GO Sleeve at 467 -ft. POOH. Stand back S -LIne. 04:30 09:00 4.50 467 467 COMPZ RPCOM RCST P Assemble ESP assembly. 09:00 12:00 3.00 467 467 COMPZ RPCOM RCST P RIH w/ Motor assembly (39.9' TL) to 431 -ft. Verify engagement. Test motor, good test. 12:00 15:00 3.00 467 467 COMPZ RPCOM RCST P PU Pump assembly (33.15' TL) . RIH w/ pump assembly set @ 398 -ft, jar down twice, shear -off, POOH. RIH w/ Pack -off assembly with check valve (4.7' TL) set pack -off, POOH. RIH w/ Test test and set above pack -off, POOH. PT pack -off to 2,000 psi for 10 mins, good test, bleed off. RIH w/ pulling tool and pull test tool, POOH. RIH w/ 4.5" tubing stop to above pack -off, set stop, POOH. RD S/L equipment. 15:00 19:30 4.50 467 1,402 COMPZ RPCOM RCST P PJSM. Continue in hole with 4.5" completion tubing to 1,402 -ft. Rig up S -Line and drift the Tubing with a 3.80" x 12' Drift. The Drift sat down a 1,067 -ft (as expected). (Note: the 12 -ft long drift is unable to pass through at this depth due to a Wellbore Dog -Leg , not due to a tubing problem). Set Back S -Line. 19:30 22:00 2.50 1,402 2,338 COMPZ RPCOM RCST P Continue to run in with the 4 1/2" Completion Tubing, ESP Cable, and TEC Wire as designed to 2,338 -ft. Rig up s -Line and drift the Tubing with a 3 82" x 1' Drift down to 1,257 -ft, with no problems. Set back S -Line. 22:00 00:00 2.00 2,338 3,117 COMPZ RPCOM RCST P Continue to run in with the 4 1/2" Completion Tubing, ESP Cable, and TEC Wire. PU /MU the lower 4 1/2" x 1" GLM. PU /MU the Viking ESP Feed -Thru Packer. Make electrical checks. Good. Stop to splice ESP Cable and TEC Wire through the Packer. Up Weight = 75K. Down Weight = 60K. 07/31/2011 Complete running the 4 1/2" WLESP Completion as designed. MU Tbg Hanger. Splice in the ESP Cable and the TEC Wire. Perform electrical checks. Land Tbg Hanger. ND BOPE. NU Prod Tree. Test. 00:00 07:00 7.00 3,117 3,117 COMPZ RPCOM RCST P Splice ESP Cable and the TEC Wire through the Packer. Perform electrical checks. Good. Page 21 of 24 • • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 07:00 13:30 6.50 3,117 • 6,040 COMPZ RPCOM RCST P Continue in hole with 4.5" ESP completion from 3,117 to 6,040 -ft. Up /Down weight @ 6,040 -ft 113K / 67K. Make drift runs with 3,82" Centralizer every 1,000 -ft and make electrical integrity test, no problems. 13:30 14:30 1.00 6,040 6,040 COMPZ RPCOM RCST P PU /MU hanger assembly, drift with S/L to 3.82" centralizer, RD S/L equipment. 14:30 21:30 7.00 6,040 6,040 COMPZ RPCOM RCST P Install penetrator. Splice ESP/Tec wire to bottom of hanger. Perform electrical checks. Good. Up Weight = 113K. Down Weight = 67K. 95 ea Single Channel Clamps used. 97 ea Modified Single Channel Clamps used. 12 Stainless steel Bands used. 21:30 23:30 2.00 6,040 6,115 COMPZ RPEQP1THGR P PJSM. Land Tubing Hanger. RILDS. Test upper and lower Hanger Seals at 5,000 psi. Both good. Lay down Landing Joint. Pull Side Port Isolation Sleeve. Install BPV. 23:30 00:00 0.50 0 0 COMPZ WHDBO NUND P PJSM. Begin to nipple down the 13 5/8" BOP Stack. 38/01/2011 NU Tbg Head and Tree. Test. Pull TWCV. RU S -Line. Set WRP. FP Annulus w /Gel Diesel. Set Pkr. Pull DV from Lower GLM and FP Tbg. Set DV back in lower GLM. RD S -Line. Set BPV. Perform final Elect Checks. 00:00 04:00 4.00 0 COMPZ WHDBO NUND P Complete nipple down BOP Stack. Prep for long -term storage. 04:00 11:00 7.00 COMPZ WHDBO NUND P Nipple up Tubing Head Adapter and Tree. Pressure test tubing hanger void 5000 -psi for 10+ minutes. ALC and Centrilift both perform electrical integrity checks: Centrilift final 1390 -psi and 61.3 -deg F. Set BPV /two -way- checks and line up to PT tree. DSO dropped by to check on tree alignment: all good. PT hanger void to 250/5,000 psi. PT tree 250/5,000 psi for 10 mins, RD test equipment.. 11:00 16:30 5.50 COMPZ WHDBO SLKL P PJSM. RU S/L equipment, lubricator assembly, test lub. to 1,000 psi. RIH w/ 4.5" OK -1 to 3,105' -ft, locate lower mandrel for depth control, flag wire, POOH. RIH w/ HES DPU setting tool and Weatherford 4.5" WRP to 3,138 -ft, wait 30 mins for DPU to activate and set WRP, lose weight on string, stack weight on plug, POOH. Stand back lubricator and install cap on BOP's. Test WRP to 1,000 psi. Page 22 of 24 • • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 16:30 18:15 1.75 COMPZ RPCOM PACK P PJSM. RU LRS to casing and PT lines to 4,500 psi. Pump 74 bbls of Gelled Diesel down the 7 5/8" x 4 1/2" Annulus (ordered 85 bbls but did not get what we ordered). Continue to pump down the IA with 12 more barrels of plain Diesel. 18:15 18:45 0.50 COMPZ RPCOM PACK P Swap Lil' Red over to the Tubing side. Pump diesel down the Tubing at 0.5 bpm and pressure up to 4,500 psi. Hold pressure for 5 minutes. Bleed pressure back to "0" psi. Packer set. Pressure up one more time to 4,500 psi and hold for 5 minutes. Bleed back to "0 ". 18:45 19:30 0.75 COMPZ RPCOM PRTS P Swap Lil' Red back to the Annulus. Pressure up to 1,500 psi x 30 minutes to test the Packer and Casing. Good. Record test on chart. (Lost —125 psi in 30 minutes). Bleed pressure down to 750 psi and begin the decompression bleed -off schedule. 19:30 22:00 2.50 COMPZ RPCOM SLKL P PJSM. Rig up S -Line. Run in and set a Catcher Sub at 3,142 -ft. (Note: found that the WRP had moved down hole from the middle of the joint that it was set in to the next collar below during the setting of the Packer) POOH. Run in and pulled the Dummy Valve from the lower GLM at 3,105 -ft. POOH. Re -dress Dummy Valve and stab back on Well. 22:00 23:30 1.50 COMPZ RPCOM FRZP P S -Line start run in with the Dummy Valve. Lil' Red on line at 2.0 bpm /550 psi down the tubing with Diesel to freeze protect the tubing. Total Diesel pumped 50 bbls. S -Line set Dummy Valve back in the lower GLM at 3,105 -ft. Lil' Red pressure up on Tubing to 500 psi. Monitor at 500 psi. Dummy Valve set. Rig down and release Lil' Red. S -Line POOH. Lay down Lubricator. Complete rig down and release S -Line. Perform final electrical checks. Good. Final Guardian Pressure Sub reading = 1,380 psi /62 degs F. 23:30 00:00 0.50 COMPZ Set BPV. 08/02/2011 Clean Pits. Clean and secure Cellar. Disconnect from Shore Power. Release Rig. Begin scheduled Summer Maintenance. Page 23 of 24 • • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 00:00 08:00 8.00 COMPZ RIGMNT RURD P Clean Pits. Blow down Lines. Rig down Kill Tank Line. Clean and secure Cellar. Disconnect from Shore Power. Release Rig for Scheduled Summer Rig Maintenance. Page 24 of 24 • ~~L>a L~IL .` , g '1 ~3. PROAcrive DinyNOSrie SeRViees, Inc_ RE : Cased Hole/Open Hole/Mechanical Logs and /or Tubing Inspection(Caliper / MTT) To: AOGCC Christine Mahnken 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 (907) 659-5102 The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the following 1) Caliper Report 03-Ju1-10 1 C-133 1 Report / EDE 50-029-23013-00 2) MTf Report ProActive Diagnostic Services, Inc. Attn: Robert A. Richey 130 West International Airport Road Suite C Anchorage, AK 99518 Fax: (907j 245-8952 02-Ju1-10 1 C-104L1 1 ~R~~ejport 50-029-230 67 -60 X02-0~2 U~ ~o l - v3~ r ~ ~`~ ~ - ,~ ~ - ~~~ ~. ~ ~, Signed : Date : , , , G Print Name: PROACTNE DIAGNOSTIC SERVICES, INC., 130 W. INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (9071245-8951 FAX: (907)245-88952 E-MAIL : ~adsanc~ear3e~eCeJrraee~aors~9ost.c®rn WEBSITE : ~nrrr+nr.~erraanil~g.c~rn C:\Documen6 and Settings\Diane Williams\Desktop\Transmit_Conoco.docx • • ~S Memvey Magnetic Thickness. Tvvt Log. Results Summary Company: ConocoPhillips Alaska, Inc. Well: 1C-104L1 Log Date: July 2, 2010 Field: West Sak Log No.: 7426 State: Alaska Run No.: 2 (15t MTT} API No.: 50-029-23076-60 Pipet Desc.: 4.5" 12.6 Ib L-80 Top Log Intvl.: Surface Pipet Use: Tubing Bot. Log Intvl.: 222 Ft. (MD} Pipet Desc.: 7.625" 29.7 Ib L-80 BCTM Top Log Intvl.: Surface Pipet Use: surtace Casing Bot. Log Intvl.: 222 Ft. (MD) Pipe3 Desc.: 16" 62.5 Ib. H-40 Welded Top Log Intvl.: Surface Pipe3 Use: Conductor Pipe Bot. Log Intvl.: 158 Ft. (MD} Inspection Type : Corrosive 8 Mechanical Damage Inspection COMMENTS This MTT data is tied into the Mandrel Hanger @ 0'. This is the first 12 Arm Magnetic Thickness Tool (MTT) log of this well. The MTT responds to the total metal thickness of the 4.5" tubing, 7.625" surtace casing, with some influence from the 16" conductor pipe. Passes at 5Hz, 8Hz and 10Hz were made at 20 fpm. INTERPRETATION OF MTT LOG RESULTS The MTT log results cover the interval from surtace to 222'. Changes in metal volume are relative to the calibration points at 78' and 138', where the readings are assumed to represent undamaged pipe. All other readings are relative to these reference points, which include influences from the 4.5" tubing, 7.625" casing and 16" conductor pipe. A log plot overlay of the filtered average overall metal thickness recorded by the 5Hz, 8Hz and 10Hz passes is included in this report. This plot indicates metal loss over the intervals 4' - 40', 102' -110' and 110' - 114', with their maximum metal loss indicated in all three passes list in the table below. Maximum Metal Loss Depth 5Hz 8Hz lOHz 4' - 40' 6% 3% 2% 102' -110' 13% 9% 7% 110' - 114' 4°!0 4°10 4% The lower frequency passes show more metal loss response than the higher frequency passes over the ' intervals 4' - 40' and 102' -110'. Since the lower frequency magnetic signals are more capable of permeating metal further from the toot than the higher frequency signals, the response from the 5Hz pass is considered to be more representative of the relative overall metal loss from the outer concentric string(s) over these intervals. The uniformity of the spread in tool response at different logging frequencies across the entire first casing joint points to the probability the metal loss over the interval 4' - 40' may be a result of a casing joint ' manufactured with a slightly thinner wall or a slightly different material. The increasing change in tool response at different fogging frequencies over the interval 102' - 110' reveals the characteristic of corrosive metal loss over this interval. PraActive Diagnostic Sen~ices, Inc. / P.O. Box 1369, Stafford, TX 7797 Phone: (281) or (888) 565-9085 Fax: (281 565-1369 E-mail: PDSarr,iemor~,~log.com Prudhoe Bay Field ~ffiee Phone: (907) 659-2307 Fax: (907; 659-2314 boa-ova II' ~ • • A log plot of the entire 5Hz pass and an expanded log plot of -top 30' of the 5Hz pass are included in this report. Indications of general isolated metal loss are recorded throughout the majority of the interval logged in the 5Hz pass. ' The ercent circumferential metal loss ex ressed in this summa is a ercenta a of the total metal that the P p ry p 9 tool is responding to, which may include influences from the 4.5", 7.625" and 16" pipe. If all of the metal loss I~' is specific to the 7.625" surface casing, the percent metal loss from that pipe alone is probably higher than the numbers expressed. Some of the metal loss indicated could be from either the 4.5" tubing or 16" conductor. i~ ~' II i~ i~ i~ Field Engineer: Wm. McCrossan Analyst: HY. Yang Witness: P. Bessette ProActive Diagnostic Services, inc. J P.O. Box 1369, Stafford, TX 77497 Phone: (281) or (888) 565-9085 Fax: (281) 565-1369 E-mail: PDS~memorylcg.com 1 Prudhoe Bay Field Office Phone: (907) 659-2307 Fax: (907) 659-2314 i~ A o`~~,wErrs 5Hz~l-Iz and 10Hz Delta Metal Tl~cness Passes Overlay Q~ F s F~ ~~ N 1 C-104L1 July 2, 2010 PrtoAcrivc DinynosTic Scaviccs Database File: d:twarriorldatallc-10411\overlay.db Dataset Pathname: overlay Presentation Format: overlay Dataset Creation: Tue Jul 06 16:57:15 2010 Charted bY: Depth in Feet scaled 1:150 -50 Delta Metal Thickness 2010 (10Hz) (%) 50 -50 Delta Metal~Thickness 2010 (8Hz) (%) 50 -50 Delta Metal Thickness 2010 (5Hz) (°!°) 50 0 8Hz Delta Metal Thickness Delta Metal 10Hz Delta Metal 20 Cross-over 40 ing Col 60 80 Casing Collar. 1D0 • Bottom of 16" Conductor 120 140 160 Delta Metal Thickness 180 2Do 220 10Hz Delta Metal Thickness 8Hz Delta Metal Thickness -50 Delta Metal Thickness 2010 (10Hz) (%) 50 -50 Delta Metal Thickness 2010 (8Hz) (%) 50 -50 Delta Metal Thickness 2010 (5Hz) (%) 50 A o`~"' ~E"s Forded Magnetic Thickness ~g Data - 5Hz Pass Q4 ~n7 i` 1 C-104L1 July 2, 2010 Plt°.QCTIVE DIAyN°STIC SEf1VICF5 Database File: d:lwarriorldatal1c-10411t5hzpass.db Dataset Pathname: 5HzPass Presentation Format: mtt_20 Dataset Creation: Wed Jul 07 09:33:26 2010 Charted by: Depth in Feet scaled 1:150 -50 Delta Metal Thickness (%} 50 1.5 MTTP01 (rad) 21.5 0 ~ Line Speed (ft/min) -200 -16.1 MTTP12 (rad) 3.9 Tree _ _: ~, -r..,>~ -- _~ ___ _ _ Line S e ~Hanger~ - - _ ~ I -- 7.625" Collar ~ ~ s i ~' Delta Metal Thickness 1~ Tubing Jt. 1 Metal 4.5" Collar ~ i i Crass-over 4.5" Colla 625" Colla Tubing Jt. 2 50 5" Collar ~-#r~"}~ ~ ~ ~~ Tubing Jt. 3 625" Collar I I 4.5" Collar 3% Metal Metal 5" .625" Collar 100 • Tubing Jt. 4 ~s of 16" Conducts Tubing Jt. 5 150 5" Collar 625" 4.5" Collar Tubing Jt. 6 200 Tubing Jt. 7 Metal Thickness 4.~ ~oua ~ 7.625" Collar -50 Delta Metal Thickness (%) 50 1.5 0 Line Speed (ft/min)~ ~ -200 -16.1 MTTP01 {rad) 21.5 MTTP12 {rad) 3.9 Q`~~,wErrsAF ~ ~panded 5Hz Pass Magnetic~iickness Log Data Q~ `''s i` 1 C-104L1 July 2, 2010 P11OAC1lYE ~IAC~RBSiIC SERVICES Database File: d:lwarriorldatal1c-104111expanded 5hzpass.db Dataset Pathname: SHzPass Presentation Format: 22 Dataset Creation: Wed Jul 07 09:33:26 2010 Charted by: Depth in Feet scaled 1:60 0 Line Speed (ft/min) -200 2.2 MTTP01 (rad} 12.2 -50 Delta Metal Thickness (%) 50 -6.6 MTTP12 (rad} 3.4 - - ~ T _ __ ; ~ Tree i ` Lin e S pee d .Hanger. ___ _ 'i ~ i i ; 7 625 " C ll . o ar , `' Delt a M i etal i Thic kness ~ ~ ~ ~ ~ j ~'~ ~ }}~ 7 fP tk ~ __ ~ 4 Y S Tubing Jt. 1 -: "~ `( ~ a 20 ~ I i S` {y 6 % M t l L e a o ss t Kz ~ ~, 4 5" C ll ~ - i ~ ' . o ar _ i Cross-over a ~ ~ i : 'I - ~ 4.5" Co llar ~ ~ ' ~~ i . - g I -~ ~~ - :: -~ - I - - - - r~ ~ 4 Line Speed (ftJmin} -200 2.2 MTTP01 (rad) 12.2 -50 Delta Metal Thickness (%) 50 -6.6 MTTP12 (rad) 3.4 t 7 ,~ ^' {~c.I'+=C~ t1' t] ,'2~:~I k7 1': ~1 =c1~1 I'1~F '~L, ; -_~.av ~u~Q~1Ut?~.U3p PC~SPrudh~ 19?314 p.i ~ _~ _ Tubing Vffetl: ~ c-14a j 1Gi©4 New Cam /etion , Gate: ©ct.25,3047 ~~nQ~P~~~~,ns t ' Rig: Nabors 3S 'va~a' tr c Depth ~a ~F Numeiar [* .points Well Equipment Description and Comments Page . Length Tops ,~ ...: - b+stance to: "RKB" OR "An Distance You S eci s& 10 Vetco Gray 11"x4 112" Nanger 2.05 . 36.16 .;ts 195 fe 19 1 ,Jts 4 1,2",72.0#, L-8Q IBT-A,1 Tubizg. Made u in han er wl3' xover NSCTxI6TM 3z 81 - 36,37 .f:s 99 to 194 96 Jts 4 112",':2.6#, L-80 IBT-M Tubin 2979,!13 71.62 f•tea# Trace start top a1 "t. # 98 3050.G5 .its ?2 to 98 ; 27 Jts 4 112".12.6#, L-8C IBT-M Tub r 835.74 3650.05 d ir2",'2.6#, L-60 IBT-U Tubm Pup _ 9.82 3885.9 ~+.5" x 1" t{6G-2-1R w!DCK-2 SOV, BEK Latch 6.135 3:+95.x1 4 112",12.6#, L-80 IBT-M 7ubn Pup s.~9 39025 .Jts 5 :o't E7 Jts 4 'it",12.6#, L-30 lBT-M, Tubin 2091.2b 39!2.25 4 112":12 Ea#, L-30 IB7-M Tubing Pup ~~ s.?s E003.50 4,5"' x 1" KBG-2-iR w1 Dumm Valve, 8K Latch 6.86- 6013.29 4 1,'2".:12.6#. L-80 fBT-M Tubing Pup 9.79 6020.15 ,lts 3 to 4.._. 2 Jts q 1 !2", ^ 2 G#, L-$0 ! BT-CVl Tubin 03.35 6029.94 A 1,"2",12,8#, L-80 (BT-M Tubin Pu 9.44 6093.29 d.5" ~F~enix Discharge Sub IBT-M Box x Pin) 1.30 o1o2.s5 4 1!2",12.6#, L-80 18T-M Tubin Pup ~~ - ~_ 6 99 6103.99 .)s 1 tot '; zJts 4 1f2'" 12.6#, L-80IBT-M Tubin 63 12 0110.98 4 1I2",12.6#. L-$C IBT-M Tubing Pup ! 5.81 3!74.10 Tubin TTC crossover wlperforated intake t 0,62 6183.91, ~~ Tandem Seal Section GS63©B 73.s0 6194.53! ~ ESP Motor 19Q hp KMH 2415V14$A 78.72 620s.ss Phoenix MDT-XT Gua_ge ~ 1,8s 6z25.~5" MatorCentrili2er 1.92 6226,SSf szz$.sc' 1 ~ szzB gQ t 6228, 8Q ~_~_ 6228.80 &228.84 - -- 6228.8Q ; 0a28.8C 8228.fi0 _ s22a.aa - Gaza s0 saaa.a4 E'?1Ei,'14:c . Jt in Hanger is NSCT wifh Xover on bottom NSCT X IBTAA Up .V[ 92 K { 27 stainless steal `Hands, 55 single camps, 88 tbtsble clamps Dr t^Jt a2 K (457} S' cannel, (3) 4' channel, (4~ 3' channel, {5) 2` channel l31ocK Y1r+. t 2 K Supenrisors: Rrtk OverstreeftOave Chapman STATE OF ALASKA ~ ~' ~~~,~~, _. r ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS~~~~~ ~~ ~` "~' ~~""° omm~st~i 1. operations Performed: Abandon ^ Repair Well ^`~ Plug Perforations ^ Stimulate ^ Other 0 Install Tubing Alter Casing ^ Pull Tubing ^ Perforate New Pool ^ Waiver ^ Time Extension ^ Patch Change Approved Program ^ Operat. Shutdown ^ Perforate ^ Re-enter Suspended Well . ^ 2. Operator Name: 4. Well Class Before Work: .Permit to Drill Number: ConoeoPhillips Alaska, Inc. Development ~ Exploratory ^ 202-062 / 3. Address: Stratigraphic ^ service ^ .API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-029-23076-60 7. Property Designation (Lease Number): .Well Name and Number: ~' ADL 25649 1 C-104L1 9. Field/Pool(s) uparuk River Field /West Sak Oil Pool 10. Present Well Condition Summary: Total Depth measured ` 11539 feet Plugs (measured) feet true vertical 3626 feet Junk (measured) feet Effective Depth measured feet Packer (measured) feet true vertical feet Packer (true vertical) feet Casing Length Size MD TVD Burst Collapse Structural CONDUCTOR 122' 16" 158' 158' 1640 630 SURFACE 7359' 7-5/8" 7395' 3741' 6890 4790 LINER D-SAND 4475' 4" 11514' 3627' N Jl~l~ ~ ~ ~.O~C Perforation depth: Measured depth: 7202' - 11354' true vertical depth: 3631' - 3700 Tubing (size, grade, measured and true vertical depth) 4-1/2", L-80, 6229' MD, 3436'TVD Weatherford ER Patch from 6021' - 6134' RKB Packers &SSSV (type, measured and true vertical depth) No Packer No SSSV 11. Stimulation or cement squeeze summary: Intervals treated (measured) not appiicabie Treatment descriptions including volumes used and final pressure: 12. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casin Pressure Tubin Pressure Prior to well operation NA NA NA NA NA Subsequent to operation NA NA NA NA NA 13. Attachments .Well Class after work: Copies of Logs and Surveys run _ Exploratory ^ Development ~ Service ^ Daily Report of Well Operations X .Well Status after work: Oil Q Gas ^ WDSPL ^ GSTOR^ WAG^ GINJ ^ WINJ ^ SPLUG ^ 16. 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 Martin Walters / Brent Rogers Printed Name Martin W alte rs Title: Problem Wells Supervisor %y~ /~~ - ~ j Signature o~~' (G~~~~=~/ ` ~/~~ Phone: 659-7535 Date 6-Jan-2010 Form 10-404 Revised 7/2009 RBDMS JAN 14 2010 c~ Submit Original my 1 C-104 DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary 12/31/2009 1/3/2010 1/5/2010 iSET 4 1/2 D&D PACKOFF-STINGER ASSEMBLY (8.3' OAL) @ 6142' RKB. SET LOWER SECTION OF PATCH (52' 8" OAL) @ 6134' RKB. SET MIDDLE SECTION OF PATCH (52' 10" OAL) @ 6082' RKB. IN PROGRESS. DEPLOY CATCHER SUB, REPLACED DGLV @ 6013' RKB W/ 2000 PSI SOV. PULL CATCHER SUB @ 6040' RKB. JOB SUSPENDED DUE TO LENGTH OF UPPER PATCH ISSUE. SET 4 1/2 ER PACKER, SPACER PIPE, AND STINGER (20.33' OAL) @ 6044' RKB (TOP OF PACKER @ 6021' RKB) TESTED AGAINST CHECK IN PACKOFF @ 1000 PSI (GOOD TEST COMPLETE Summary SET WEATHERFORD ER PATCH OVER TUBING LEAKS FROM 6021' - 6134' RKB • • NOV 2 8 ~~~~ STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Alaska Oil & Ges Cdns. Cat'nmi~>t~dt1 REPORT OF SUNDRY WELL OPERATIONS Anchorage ~. Operations Pertormed: Abandon ^ Repair Well ^~ ~ Plug Pertorations ^ Stimulate ^ Other ^ Alter Casing ^ Pull Tubing ~ ~ Perforate 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 ^ 202-062 / - 3. Address: Stratigraphic ^ Service ^ 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-029-23076-60 7. KB Elevation (ft): 9. Well Name and Number: RKB 36' 1 C-104L1 8. Property Designation: ~ 10. Field/Pool(s): ADL 25649, ALK 467 Kuparuk River Field !West Sak Oil Pool 11. Present Well Condition Summary: Total Depth measured 11539' ~ feet true vertical 3626' feet Plugs (measured) Effective Depth measured not available feet Junk (measured) true vertical feet Casing Length Size MD ND Burst Collapse Structural CONDUCTOR 122' 16" 158' 158' SURF 7359' 7-5/8" 7395' 3696' LINER 4451' 4" x 4.5" 11514' 3627' Perforation depth: Measured depth: , 7202'-11354' r~~{~~ ~ ~E ~ ~ 2U~7 ~ L Vr true vertical depth: 3700'-3631' Tubing (size, grade, and measured depth) 4-1/2" , L-80, 6172' MD. Packers &SSSV (type & measured depth) Baker Payzone pkr @ 7112 ' no SSSV 12. Stimulation or cement squeeze summary: Intervals treated (measured) not applicable Treatment descriptions including volumes used and final pressure : 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casin Pressure Tubin Pressure Prior to well operation SI : -- Subsequent to operation 870 ' 28 1615 -- 230 14. Attachments 15. Well Class after work: Copies of Logs and Surveys run _ Exploratory ^ Development ^~ Service ^ Daily Report of Well Operations _X 16. Well Status after work: Oi10 ~ 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 NIA if C.O. Exempt: none Contact Brett Packer @ 265-6845 Printed Name Brett Packer ~ ~ ! Title Wells Group Engineer f ~ ~Z ~/O ~-- Signature ~i3 ~~ ~ C,~L Phone Date Pre aced b Sharon Allsu -Drake 263-4612 Form 10-404 Revised 04/20 6 ' ,' ~'~ ~ ~ ?~~t' /2''1/ ~7 Submit Original O y ~~~~ • • DATE Summary 10/19/07 Rigging down moving from 1J-137 to 1C-104. 10/20/07 Finish moving to 1C-104 and MIRU. Circ and kill well ND tree and NU Bope. Accepted Rig @ 08:30 hrs 10/20/2007. 10/21/07 Finish ND Tree and NU BOPE and Test 250/2500. Unland tbg and Start to Pooh laying down all of the production string. 10/22/07 Load new equipment and stap. Rih w/ new completion 1x1 to 4300' and electrical inspections and tests were good. ~ 10/23!07 RIH w/ new 4 1/2" ESP completion, check cable at 5,102', found that the cable had failed and also no communication w/ the Phoenix gauge. POOH and found that cable was cut at GLM #2. The cable had splipped around to the sharp edge on the pocket side and was cut. Pulled up to the MLE connection. Disconnected MLE and re-serviced the pump, replaced the gauges' control line and cut the cable at the MLE splice. Spooled off 225' of cable and re-spliced it at the MLE to eliminate an extra splice. Gean to RIH, put 2 bands on bottom and 2 bands on top of GLM #2 and will do the same on GLM #1 to keep the cable from slipping to the pocket side again. 10/24/07 At approx. 00:30 a new seal ring was dropped down the tubing with 13 stands in the hole. POOH and retrieved the seal ring off the top of the TTC crossover. Turn tools around and ran 15 stand in when H2S monintors went off. Well secured and evacuated rig as per procedure. Verified faulty alarm and monitored cellar, pits and rig floor with hand held monitors until rig electrician fixed the monitors. (AOGCC -Lou Grimaldi was notified @ 08:12) Check cable and continue to RIH. Started running heat trace @ 3014' Began making the cable splices for the heat trace and power cable at 23:00. 10/25/07 Finished running completion. Test all cables, heat trace, and Phoenix guages. ND ROPE, NU tree test to 5000 psi. released rig @ 09:00 10/25/2007 10/25/07 Pump Freeze protection with diesel pumped 45 bbls down tubing and 75 bbls down the annulus. BPV still installed 11/07/07 TAGGED ESP SPLINE @ 6166' SLM, CONFIRMED CLEAR. SET 4-1/2 TTCESP (46.06' OAL - 140FC2700) @ 6166' SLM. SET PACKOFF ASSEMBLY WITH KOBE KNOCK OUT, DART CHECK AND STINGER (100" OAL) @ 6120' SLM. SET CATCHER ON PACKOFF @ 6112' SLM. PULLED DV @ 6021' RKB. 11/08/07 SET SOV @ 6021' RKB. PULLED SOV AND SET DV @ 3860' RKB. PULLED CATCHER. TESTED PACKOFF 1000 PSI, GOOD. SET SLIP STOP ON PACKOFF @ ,, 6114' SLM. COMPLETE. i ' ConocoRh~lt~ps Alaskaa Ind. y-1x41.1 _ -APL' Heat Trace ~ ~ SSSV Type: I (13014, ~ i~- OD:1.000) Annular Fluid: Reference Lo Last Ta i 1292307b60 I .~~ • KRU 1 C-104L1 20D An le TS: de ?9/2002 Angle @ TD: 92 deg @ 11539 V25/2007 Rev Reason: WORKOVER Last U date: 10/31/2007 539 ftKB TUBING Last Tag Date: I Max Hole Angle: 195 deg (~ 7498 (0-6172, _ -. _.. oD:a.soo, Casin Strin -ALL COMMON STRINGS _ ID:3s5e) Descri ion Size To Bottom TVD Wt Grade Thread ~. CONDUCTOR 16.000 0 158 158 62.50 H-40 WELDED ,,, ~ SURF/PROD 7.625 0 7395 3696 29.70 L-80 BTCM D-SAND LINER 4.500 7040 7202 3700 12.60 L-80 NSCT CSG WINDOW 6.625 7043 7044 3681 0.00 to 1C-104L1 Casing String - D-SAND LINER (Alternatingf 31' blank pipe ~ 37' Excluder 2000 screen 4"x4.5") SEAL (6159-6172, OD:5.130) GAUGE (6189b191, OD:6.250) TUBING (above screens) 4.500 7171 7202 ~ - 3700 12.60 ~ L-80 ~ NSCT ~ SCREEN 4.800 7202 11354 3631 12.60 T L-8~ NSCT ~ Tubing String - T11-61[~[G - - _ Size _ Top Bottum ND W[ Grade ~ Thread 4.500 0 61?2 3-11-1 12-60 L-80 NSCT 'Perforations Summary Interval TVD Zone Status Ft SPF Date T Comment 1 7202 - 11354 3700 - 3631 WS D 4152 50 7/28/2002 Screens Perfs thru 37' screens every 31' - - - I _ Gas Lift MandrelsNalves - - - - - St MD TVD Man Mfr Man Type V Mfr V Type V OD Latch Port TRO Date Run Vlv Cmnt 1 3860 2390 CAMCO KBG-2-1R SOV 1.0 BEK 0.000 0 10/25/200 2 5977 3337 CAMCO KBG-2-1R DMY 1 0 BK 0.000 0 10/25/200 ~theT pSti~s, equip., etc .) - C©MPI.ETION De h TVD T e Descri lion ID 1 1 Heat Trace HEAT TRACE 3014' TO SURFACE 0.000 36 36 HANGER ABB VETCO GRAY TUBING HANGER 3.900 6067 3373 SUB PHOENIX DISCHARGE PRESSURE SUB 3.948 -- ,,,,,, ~ 6148 3404 XO INTAKE CROSSOVER INTAKE 0.000 ~ ~ 6159 3409 SEAL CENTRILIFT TANDEM SEAL SECTION 0.000 6172 3414 MOTOR CENTRIFLIFT 190 HP MOTOR 0.000 6189 3420 GAUGE PHOENIX MS-2 GAUGE 0.000 6191 3421 Centralizer CENTRILIFT MOTOR CENTRALIZER 0.000 _Other (plugs, equip., etc.). - D-SAND LINER DETAIL - De h TVD T e Descri ion ID 7040 3680 HANGER BAKER FLANGED HOOK LINER HANGER 5.630 7061 3685 SUB BAKER LINER SWIVEL SUB 4.000 7104 3693 SUB BAKER INDICATOR SUB 3.840 j 7112 3694 PACKER BAKER PAYZONE PACKER 20' SEAL 3.930 11512 3627 SHOE - 3.500 - ~General Notes Perf (7202-11354) e e MICROFILMED 07/25/06 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE F:\LaserFiche\CvrPgs _Inserts\Microfilm _ Marlœr.doc ) ) Jim Ennis Wells Group Engineer Drilling & Wells ConocJPhillips P. O. Box 100360 Anchorage, AK 99510-0360 Phone: 907-265-1544 f, "",', "',"~,',' ,:,',¡'''''~ ,,',"""''1. ,','"i""""'" . . r~('.".".f j"""", ~ ..~ ~CJ;3I \.J .91'':'II'''l.l~ October 20, 2005 I',:, :;p,.i .,,1 .f"j '~~ Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 «1,' ft\ft;'r ~Od-- V Subject Reports of Sundry Well Operations for 1 C-1 04 & 1 C-1 04L 1 Dear Commissioner: ConocoPhillips Alaska, Inc. submits the attached Reports of Sundry Well Operations for the recent workover on the West Sak multilateral 1 C-1 04 and 1 C-1 04L 1 to replace the failed ESP. If you have any questions regarding this matter, please contact me at 265-1544. Sincerely, .\' ,~, ~',4 'Y~ J. Ennis V\ 'e lis Group Engineer CPA I Drilling and Wells ~A' i\iNIt:L) &..I()lI f¡¡ "¡ ',:!(in1ÿ vw ,P1:I e¡;. ~, t \.,1 ,)L ~....1 \'11~4. J E/skad STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS Alaska Oil & Gas Cons. Gommïssil Amhorage Abandon 0 Repair Well 0 Plug Perforations 0 Stimulate 0 Other U Alter Casing 0 Pull Tubing 0 Perforate New Pool 0 Waiver 0 Time Extension 0 Change Approved Program 0 Operat. ShutdownD Perforate 0 Re-enter Suspended Well 0 2. Operator Name: 4. Current Well Status: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development 0 Exploratory 0 202-062 1 3. Address: Stratigraphic 0 Service 0 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-029-23076-60 7. KB Elevation (ft): 9. Well Name and Number: RKB 36' 1C-104L 1 1. Operations Performed: ) ) RECEIVED OCT 2 4 Z005 8. Property Designation: ADL 25649, ALK 467 11. Present Well Condition Summary: Total Depth Effective Depth Casing Structural CONDUCTOR SURF/PROD SCREEN LINER Perforation depth: 10. Field/Pool(s): Kuparuk River Field 1 West Sak Oil Pool measured 11539' feet true vertical 3626' feet measured 11514' feet true vertical 3627' feet Length Size MD 122' 16" 158' 7359' 7-5/8" 7395' 4451' 4.5" 11514' 162' 4.5" 7202' Plugs (measured) Junk (measured) TVD Burst Collapse 158' 3696' 3627' 3700' Measured depth: screens from 7202'-11354' true vertical depth: 3700'-3632' Tubing (size, grade, and measured depth) 4-1/2" L-80, 6172' MD. RBDMS 8Ft OCT .2 5 2005 Packers & sssv (type & measured depth) Baker payzone packer @ 7112' no SSSV 12. Stimulation or cement squeeze summary: Intervals treated (measured) none 13. Treatment descriptions including volumes used and final pressure: Representative Daily Average Production or Injection Data Gas-Mef Water-Bbl 122 721 189 657 15. Well Class after proposed work: Exploratory 0 Development 0 Service 0 16. Well Status after proposed work: oil0 GasD WAG 0 GINJD WINJ 0 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: Oil-Bbl 1186 701 Casinç¡ Pressure Tubinç¡ Pressure 324 369 Prior to well operation Subsequent to operation 14. Attachments Copies of Logs and Surveys run _ Daily Report of Well Operations _X WDSPL 0 Contact ~im nn" is@265-1544 Printed Name (\ ~. . ...~~,n¿s S~n~uœ ~- Title Phone Wells Group Engineer L i ./ Date i 0 )., ~ a.$ Preoared bv haron IIsuo-Drake 263-4612 ORIGINAL Form 10-4C4 Revised 04/2004 Submit Original Only TUBING (0-6172, 00:4,500, 10:3.958) SURF/PROD (0-7395, 00:7.625, Wt:29.70) PRES SUB (6072-6073, 00:5.000) PUMP (6144-6145, 00:3,500) COLLAR (6145-6149, 00:5.130) MOTOR (6149-6155, 00:5.620) SEAL (6155-6185, 00:5.130) GAUGE (6185-6187, 00:6.250) Centralizer (6187-6188, 00:6.000) Perf (7202-11354) SCREEN (7202-11354, 00:4,800, Wt:12,60) ConocoPhilllP$ AlasJat Inc. 1C-l04L 1 API: 500292307660 SSSV Type: NONE ...... L.. Rev Reason: WORKOVER, set Pump, SOV Last Update: 10/7/2005 Grade Thread H-40 WELDED L-80 BTCM L-80 NSCT to 1C-104L1 Casing String· D-SAND LINER (Alternatlngf 31' blank pipe & 37' Excluder 2000 screen 4"x4.5") Description Size Top Bottom TVD Wt Grade Thread TUBING (above blanks) 5.030 7040 7171 3699 12.60 L-80 NSCT TUBING (above screens) 4.500 7171 7202 3700 12.60 L-80 NSCT SCREEN 4.800 7202 11354 3631 12.60 L-80 NSCT Tubing String - TUBING Size I Top 4.500 0 Perforations .Summary Interval TVD 7202 - 11354 3700 - 3631 ) KRU £-1 04L 1 Annular Fluid: Well Type: PROD Orig 7/29/2002 Completion: Last W/O: 9/10/2005 Angle (â> TS: deg (â> Angle @ TD: 92 deg @ 11539 Reference Log: 36.1' RKB Ref Log Date: Last Tag: TD: 11539 ftKB Last Tag Date: Max Hole Angle: 95 deg (â> 7498 Casing String - ALL COMMON STRINGS Description Size Top CONDUCTOR 16.000 0 SURF/PROD 7.625 0 D-SAND LINER 4.500 7040 CSG WINDOW 6.625 7043 Bottom 158 7395 7202 7044 TVD 158 3696 3700 3681 Wt 62.50 29.70 12.60 0.00 Bottom 6172 Wt I Grade I 12.60 L-80 Thread NSCT TVD 3414 Zone WSD Status Ft SPF Date Type Comment 4152 50 7/28/2002 Screens Perfs thru 37' screens every 31' Gas Lift Mandrels/Valves St MD TVD Man Man Type V Mfr V Type V OD Latch Port TRO Date Mfr Run 3864 2391 CAMCO KBG-2 DMY 1.0 BK 0.000 0 9/10/2005 2 6021 3354 CAMCO KBG-2 SOV 1.0 BK 0.000 0 10/1/2005 Other:plugs,eqUlp., etc.) - D.;SAND JEWELRY Depth TVD Type 7040 3680 HANGER 7061 3685 SUB 7104 3693 SUB 7112 3694 PACKER 11512 3627 SHOE ,Other 'plugs, equip., etc.) - COMMON JEWELRY : Depth ' TVD Type Description I 36 36 HANGER ABB VETCO GRAY TUBING HANGER 6072 3375 PRES SUB PHOENIX DISCHARGE PRESSURE SUB 6144 3403 PUMP SET 41/2 TTC ESP ( 44.85' OAL ) @ 6144' RKB. SET 41/2 D&D PACKOFF W/ KOBE KNOCK OUT AND STINGER ASSEMBLY ( 1021/4" OAL) (â> 6099' RKB. SET 41/2 SLIP STOP (â> 6093' RKB set 10/212005 TCC CROSSOVER COLLAR CENTRIFLlFT 190 HP MOTOR CENTRILlFT TANDEM SEAL SECTION PHOENIX MS-2 GAUGE CENTRILlFT MOTOR CENTRALIZER Description BAKER FLANGED HOOK LINER HANGER BAKER LINER SWIVEL SUB BAKER INDICATOR SUB BAKER PA YZONE PACKER (20') SEAL 6145 3403 COLLAR 6149 3405 MOTOR 6155 3407 SEAL 6185 3419 GAUGE 6187 3420 Centralizer GeneràlNotes Date I Note 7/29/2002 MULTI-LATERAL WELL: B-SAND (1C-104), D-SAND (1C-104L1) Vlv Cmnt ID 5.630 4.000 3.840 3.930 3.500 ID 4.500 0.000 0.000 5.000 0.000 0.000 0.000 0.000 'ì ) ) Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: ...... . .... . . ", .. .. ...... . . ... ... . . .' ", " , ",'" " ." .. . . "." ,"- ".. '. .... .'... ... ...... . ····.·.·.·..···..·i' ...... .·...·.·.q;é9·<?êgþt"l~llig$.~4~~~ÇJ.·... ...... ·····...·.··.....i...·..·. .. ".:.:. ..... ..::."" :. .'. ".. ......... '. ...... ." "." . :..... ":.."...' '". .... ..... ,". ..... .. .. . . ... . . .. ... .. . . .. '. ...... . . . . ..' . ..... . . ," ". ............ ....... ... ."..".. ,. . ..". .. .' ."... .".. .. ""'. .' . ·········Ç>,~~~:ti'~~~..·.·..~.·.~·.rJ1i~·r¥.:;····Rl~·P9tt·..... 1 C-1 04 1 C-1 04 WORKOVER/RECOMP Start: 9/3/2005 Rig Release: 9/10/2005 Rig Number: Spud Date: 6/24/2002 End: 9/10/2005 Group: Nabors 3S ··D~·tê .... .···,:#rJ~;;Tø; . !Hqùr$··(jb.d~ .'~~~< ... Ph~s~;·· .... .... .. 9/2/2005 9/3/2005 16:00 - 00:00 00:00 - 06:00 06:00 - 09:00 9/4/2005 09:00 - 12:00 I 12:00 - 13:00 13:00 - 00:00 00:00 - 13:30 13:30 - 18:00 9/5/2005 18:00 - 20:00 I 120:00 - 00:00 : 00:00 - 05:00 05:00 - 11 :00 11 :00 - 13:30 13:30 - 14:00 14:00 - 16:32 16:32 -17:10 9/6/2005 117:10 - 18:00 118:00 - 21 :00 121 :00 - 00:00 I 100:00 - 06:00 , i 06:00 - 07:30 I 9/7/2005 ! 07:30 - 07:45 07:45 - 12:00 i ' I ! 112:00-13:00 ! I I I 113:00 - 16:00 116:00-18:00 I I 118:00 - 00:00 I 100:00 - 11 :45 i 1 , .," .... . .. ......".... ...". ...... ",',' ", ',' . . .." " .............. '.. :.......:..... :.:.... . .... . . :.: ....::.,.,...." .:.:........ ............ ., " , ." ".": ,....,.,...., " ,,',' ,,"', ... .' ··.·~e~~~!ptÎQt1Ç)f:·9perêlt¡~n~: .. 8.00 MOVE DMOB DEMOB Rig down and prepare to move rig from 1B-15 to 1C-104 6.00 MOVE DMOB DEMOB Rig down and prepare to move rig from 1B-15 to 1C-104 3.00 MOVE MOB MOVE Rig on location and spotted. Herculite layed out and mats dwn. Back in pits and pipe shed. Prepare to raise derrick. Install pump lines. Welders to begin on pits. Mechanics begin on transmission prep. Rig accept @ 1300 9-3-2005 Begin repairs on pits and transmission replacement. ((Code 8)) Continue repairs on pits and transmission replacement. Crane on location @ 7:00 AM ((Code 8)) Lou Grimaldi waived the witness of the BOP test at 13:45. Still working on rig. Begin pumping KWF of 3% KCL water at 2.5 BPM dwn tubing at 650 PSI. 180 DEG. Taking returns up the IA. Returns 1-1. After 275 BBLS away begin losing returns. By 310 BBLS away lost all returns. Set BPV 0 PSI WHP. DECOMP Rig repairs completed as far as they can go, waiting on parts. Nipple down well-head DECOMP I· Nipple up BOP's DECOMP Nipple up BOP's DECOMP I Testing BOP's PASSED DECOMP Prepare to pull BPV. Rig up Centrilift spooling unit and sheaves. Install empty spool. 0.50 WELLSR NUND DECaMP Pull BPV. Initial gas bubbles venting through poppet valve. After pulling BPV Liquid level in BOPE dropped out of sight. 2.53 WELLSR NUND DECaMP 'nstalllanding joint. Continue rigging up Centrilift. 0.63 FISH PULL DECOMP I Pull hanger out of bowl. 125K up wt to pull out. Wt dropped to 72K free hanging wt. 130 BBL in pit 1 - 127 BBL in pit 2. initial tally. 0.83 WELCTL OBSV DECOMP Monitor well for fluid after injecting 10 BBLS into IA. Shot fluid level 1 0 min intervials for 40 min. Fluid level consistant at 150' below LDS. RURD DECOMP Continue rigging up Centrilift equipment. PULL DECOMP I, Pull production tubing with up weight of 72K standing back, spool ESP and heat trace cables. One 9.78' pup and one 1.18' pup have bad I threads and will be taken out of the string. PULL DECOMP, Continue pulling production tubing standing back, spool ESP and heat I trace cables 1.50 FISH PULL I DECOMP . Tower meeting continue out of hole, filling hole with metal displacement I every 5 stands and pumping an extra 5 bbls each hour. Heat trace out ,. . of well in one piece. 0.251 WELCTW OBSV DECOMP I Shoot two fluid levels. Fluid level = 178' Continue to POOH. 4.25, FISH 'I PULL DECOMP All the tubing out of the hole. Cable" 1- leg grounded, Motor lead I , : I insulation in good shape, Failure in the power cable. Begin breaking I I, down pump. Found spline/coupling damaged and worn, bearing I I I I· shattered. 1.00! FISH .OTHR: DECOMP Pump out of hole; lay down equipment. Clean up rig floor. Order out I ; , I necessary crossovers for re-running tubing and test packer/RBP. Note: 1 I I : All clamps/channel accounted for, missing (2) stainless bands. 3.00 I WAITONI EQIP 'DECOMP ·1· Wait for crossovers. Set wear ring. RD ESP cable 2.00· WELLSR OTHR IWRKOVR Make room in pits for fluid; pu":,p 20 bbls SW/KCL into well. Let settle Ii· I and call out DHD to shoot a fluid level. Level at 252'. 6.00. WELLSR: TRIP I WRKOVR I Begin running RBP/test packer on original 4-1/2" completion string. 11.75 i WELLS~ TRIP ! WRKOVR I' Continue running in hole with RBP and test packer on NSCT I I I . completion string. Layed down 10 jts of NSCT 4-1/2" tubing with ,corrosion pits or gualded threads. Will replace with 4-1/2" IBT. I ! 3.00 MOVE RURD RIGUP 1.00 MOVE RURD RIGUP 11.00 RIGMNT RGRP RIGUP 13.50 RIGMNT RGRP RIGUP 4.50 RIGMNT RGRP RIG UP 2.00 WELCTL NUND 4.00 I WELCTL NUND 5.00 WELCTL NUND 6.00 WELCTL BOPE 2.50 WELLSR NUND 3.00 FISH 3.00 FISH 6.00 FISH Printed: 10/18/2005 2:50:34 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: :) ) . . . '" . .: .." :." . .".. . .... ..... .,,". ....".;." ,,,,,": , ..,..... . .. .. ... . . .:" ;".. .,... . .":" . '. .::. .' " "'.. .. .' .. . ... : .. < ,'::"", ".....,.....,... ','....' .", ..,....,: ".'. ,:..,..:....'.. .:g9~~~q~~:itl~·þ~.~~~~~c:I...·. ................ : . ...". ,". .... .. ...... ,..... . ........, :",,',',', " ,"" ",,",' " ',' , '". ...:........ :." :... ..... -:." ",". ":". :..:".:"": ...........;. ..............: .'.. ....: .. ......: '" . .'. ". . ... ..... .. ",','.,':,."""'.,':,,,",,",':',"",::',"."'" .."',',"',,',".,""""",",',,'"':,':,"',',,',"':'.,',',',,":'."":"""'::,,',",.,',,',.,'" ,'''':'.,', ",,':',:,,',',,',:', ",""',:,'.'"",,',,', ,':"',:,'. '.':",,":, ":"""'"',,',.',:,,,,,,":""",'.""""',:,':'",',',",": .. .....: .,.... .:...". ··,,~p~~~~i:~'~'$J·.fflm@:~~EeP~rt··· ". 1 C-1 04 1 C-1 04 WORKOVER/RECOMP Start: 9/3/2005 Rig Release: 9/10/2005 Rig Number: Spud Date: 6/24/2002 End: 9/10/2005 Group: Nabors 3S 9/7/2005 11:45 -12:30 , 12:30 -13:30 I 13:30 -15:00 15:00 - 17:00 I 17:00 -18:00 I 18:00 - 22:00 22:00 - 00:00 9/8/2005 00:00 - 04:45 04:45 - 06:00 06:00 - 10:00 10:00 - 18:00 9/9/2005 18:00 - 00:00 00:00 - 01 :30 01 :30 - 06:00 I ! 06:00 - 14:30 ! 14:30 -15:30 I I ; I I 115:30 -19:30 I I ! 19:30 - 20:30 I I i I ¡ ! 20:30 - 00:00 I I I 100:00 - 00:30 , ,00:30 - 01 :00 I 101 :00 - 06:00 ¡ 106:00 -10:00 I i I 9/10/2005 0.75\ WELLSR PLGM IWRKOVR At +-7000' (13' in on jt 140). Attempt to rotate pipe with power tongs; , unable to get pipe to turn static with 4000# of torque. Attempt to turn ! I I while raising/lower pipe...able to rotate slightly, pipe "torquing up" to I 14000#, back out of it with power tongs- get back nearly all torque. Call I I Workover Engineer to discuss options. 1.00, WELLSR TRIP I WRKOVR i Pull out of hole to 6200'; re-attempt to set RBP. Same results. Unable I I to set plug, torqued up again while trying to rotate. 1.50 I WELLSR PLGM I WRKOVR Pull out of to 4980' orig RKB (20' of stand #32 showing). RIW=32k, I \ I I PUW=50k, Block Wgt=1 Ok. Rotate w/ power tongs 4 turns. Back off I I I torque. Stack wgt, 10k. Pick up to 75k- RKB appears set. Work pipe . and release fom RKB. Pull 1 jt. 2.00 WELLSR! DEOT IWRKOVR! Rig up to PIT casing. Top off hole with fluid, approx 15 bbls to fill. Shut '1 I !I pipe rams and pressure up on casing to 2500 psi. Chart and watch for I I 1/2 hr. Good PIT; casing pressure bleed off 50 psi to 2450 in 30 mins. ! I Bleed off pressure. WELLSR CIRC I' WRKOVR Circulate crude back to tiger tank until clean SW/KCL is seen across I shaker. Shut down. 4.00 WELLSR PLGM WRKOVR I Run back in hole with jt of IBT to retrieve RBP. Ran back in hole with remainder of IBT tubing. 2.00 WELLSR TRIP WRKOVR I Pull out of hole laying down 32 jts of IBT tubing and strapping out of hole with remainder of IBT and NSCT. 4.75 WELLSR TRIP WRKOVR Continue pulling out of hole with RBP & test packer re-strapping pipe. 1.25 WELLSR TRIP I WRKOVR NO test packer and RBP. Clear rig floor. Pull wear ring. 4.00 CMPLTN RUNT CMPLTN Pick up 4.5",12.6#, L-80 ESP completion equipment. Rig up sheave for I power cable. Break out crossovers from orig completion needed in new. I Shot fluid level= 240'. 8.00 CMPL TN RUNT CMPL TN Run motor assembly in hole; top off with oil, bleed air. make up seal I II assembly. Perform voltage test, verify gauge function- good. Continue ! running completion. Perform prejob safety meeting. 6.00 CMPL TN RUNT I CMPL TN i Cont. to run 4.5" ESP completion. Shoot fluid level= 150'. 1.50 CMPL TN RUNT CMPL TN I Rig up Heat Trace spool and sheave in derrick. 4.50 CMPL TN RUNT CMPL TN I Continue RIH with ESP, heat trace and power cable on 4.5" tubing I I installing Cannon cable clamps, performing electrical inspections/tests ~ on ESP cable and heat trace every 1000'. 8.50 CMPL TN RUNT CMPL TN I Cont. RIH with new ESP completion. Shoot fluid level= 75'. 1.00 CMPL TN RUNT CMPL TN I Make up hanger w/ full jt to string; isolation sleeve is in place in hanger. I Align hanger, make up landing jt. Prep to make up heat trace/power I cable splice. Conduct pre-job safety meeting. i Shoot fluid level= 204'. Begin making final splice of ESP cable and heat I trace to to penetrators. Perform test cable / motor / heat trace integrity. Landed the tubing with extreme caution and hanger landed smooth. Up !wt.= 49K Dwn wt = 27K. RILDS. Layed down landing jt Tested hanger I and top hydraulic wiper packing and it leaked. I BOLDS. Pull tubing hanger back to rig floor. Redressed hydraulic wiper I packing on hanger. I Lowered hanger back and landed. RILDS. I Pulled side port seal sleave. Installed 2-way check. Nipple down BOPE. Check the ESP cable / motor integrity. I Unable to get packoff test; bleeding from 2500 psi to 1200 psi in approx 110 mins. Pressure up tree to to 5000 psi and test tree-good. Pressure I up void to 5000 psi, watch for bleed off. Held tight, seals below void I holding. Bleed off tbg (tree) pressure to 4000 psi. Void bleeding off I slightly to 4900 psi in 10 mins. Verify hanger neck seal "flexing" I I I 4.00 CMPL TNI DEOT I CMPL TN I I 1.00 I CMPL TNI SOHO I CMPL TN I ! I 3.50 I CMPL TNI SOHO : CMPL TN 0.50 CMPL TN! SEOT I CMPL TN 0.50 WELLS~ PLGM I CMPL TN 5.00 WELCT~ NUND 'CMPL TN 4.00 I CMPL TNI SEOT ! CMPL TN , I I I . i Printed: 10/18/2005 2:50:34 PM ') Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 C-1 04 1 C-1 04 WORKOVER/RECOMP Nabors 3S Start: 9/3/2005 Rig Release: 9/10/2005 Rig Number: Spud Date: 6/24/2002 End: 9/10/2005 Group: 9/10f2005 06:00 - 10:00 4.00 CMPL TN SEQT CMPL TN 10:00 - 13:00 3.00 CMPL TN SEQT CMPL TN 1.50 I CMPL TN SEQT I 13:00 - 14:30 CMPL TN i I I 14:30 - 19:00 4.50 CMPL TN RURD CMPL TN 19:00 - 21 :30 2.50 MOVE RURD MOVE 21 :30 - 00:00 2.50 MOVE MOVE MOVE I I allowing leakoff from void to tbg. Confer w/ WO Engineer & Vetco-Gray Rep in town. Remove checks and bleed void to 0 psi, pressure up tree again to 5000 psi. Slow leak at tree, 2-way check leaking. Redress 2- way check, re-install Replace 1500 series flange on wing valve to 5000 series. Test hanger neck seals at flowing pressure (250 psi), pump up tbg to 250 psi; 0 psi on void. Monitor for 10 mins.- void still reading 0 psi. Bring tree pressure up to 5000' psi, hold for 10 mins flatline- good (0 psi Ion void). . Remove 2-way check, install BPV. Install otis cap, dress out tree. I Release rig at 16:00, 9/10/05. Continue to rig down and prep to move. II Scope derrick down and laid down on carrier. Hook up trucks. Pulled rig forward enough to get 11" Stacka out from behind well. Left location at 121 :30 hrs ! Arrived on 1 D pad @ 22:45 hrs. Unload 11" stack, haul gravel in behind well to level up. Worked 11" stack in behind well before spotting rig. Printed: 10/18/2005 2:50:34 PM Re: 1C-I04 PTD (202-061) ESP failure 07-11-05 ) Tom, ) dO'd-OG\ k dO :)·-oeo d'" '-.. As reported on July 11 2005 the ESP failed on 1 C-1 04. Per your request, ConocoPhìllips Îs notifying the AOGCC that a Rig workover is planned for later this month to pull and run a new pump and motor. Please let me know if you have any questions. MJ Loveland ConocoPhillips Problem Well Supervisor 659-7224 SCANNED AUG ü 2 2005 -----Orig i na I Message----- From: NSK Problem Well Supv Sent: Monday, July 11, 2005 3:05 PM To: 'Thomas Maunder' Cc: NSK Problem Well Supv Subject: FW: lC-l04 PTD (202-061) ESP failure 07-11-05 Tom, The ESP on Westsak well 1 C-1 04 (PTD 202-061/062) failed last night. It appears that the problem is the motor and will require a rig workover to repair. Please let me know if you have any questions. MJ Loveland ConocoPhillips Problem Well Supervisor 659-7224 -----Original Message----- From: Nezaticky, Peter On Behalf Of NSK West Sak Prod Engr Sent: Monday, July 11, 2005 7:23 AM To: CPFl Prod Supv; Rodgers, James T; Jenkins, Lubbie Allen; Ennis, J J; Gober, Howard; Dinkins, Walter R Subject: FW: lC-104 1 C-1 04 went down last night and this time it looks like the motor is done. The pump ran for about 34 hrs and the trends looked good. We lost the down hole pressure and temperature gauges 14 hours 20f3 8/2/2005 8:06 AM Re: 1C-I04 PTD (202-061) ESP failure 07-11-05 ) ) after starting the pump due to burnt fuses caused by current leakage to ground. We new that the current leakage to ground would eventually cause us problems, but ho~ed it would run longer then it did. I I will try to get the pump ASAP to confirm that there were no pump or pump eye problems. This well is a 600 bopd producer, what are we looking at in terms of a workover? Can we use the equipment from one of the other workover candidates and move this one up regarding timing or should I plan on trying to get this well on gas lift if the workover will be several months down the road? Thanks, Peter Nezaticky / Hai Hunt ConocoPhillips Alaska Inc. West Sak Production Engineer Ph: (907) 659-7061 Fax: (907) 659-7314 -----Original Message----- From: NSK Centrilift Fld Srv Sent: Monday, July 11, 2005 12:16 AM To: NSK West Sak Prod Engr; dan.benson@centrilift.com; walter.dinkins@centrilift.com; steve.tetzlaff@centrilift.com; Fisher, Matt A; ro.bert.dowdy@bakerhuqhe~.com Subject: lC-l04 All, An unfortunate event took place tonight after all of our hard work & problems. 1 C-1 04 burnt down hole @ 22:56. All 3 legs to Grnd. Are unbalanced 6.9, 6.5, & 6.2 Ohms. Regards, Dwayne Weythman }?S Tech. Spec. AK E-Mail: !l..136S@?co11.ocophillips.C01TI Phone: (907)659-7257 Cell: (907)448-1484 30f3 8/2/2005 8:06 AM ¥ . ¿Ã9 ~ ~V\ DATA SUBMITTAL COMPLIANCE REPORT 8/2/2004 Permit to Drill 2020620 Well Name/No. KUPARUK RIV U WSAK 1C-104L1 Operator CONOCOPHILLlPS ALASKA INC AP{eo~~029-2;O~!-~OO ~ MD 11539 ~ TVD 3626 --- Completion Date 7/29/2002 /' Completion Status 1-01L REQUIRED INFORMATION Mud Log No Samples No DATA INFORMATION Types Electric or Other Logs Run: GRlRes Well Log Information: Log/ Electr Data Digital Dataset Type Med/Frmt Number Name ~ 01606 See Notes I~ ~D ~D ~ ~D :,{pt Log Log Run Scale Media No 1 Directional Survey ~78 LIS Verification Directional Survey LIS Verification Directional Survey Directional Survey Well Cores/Samples Information: Name Interval Start Stop Sent Received Well Cored? ADDITIONAL INFORMATION Y~' .y Daily History Received? Chips Received? -r I 1<4 Analysis Received? Comments: Formation Tops ~ Compliance Reviewed By: ~ Current Status 1-01L UIC N Directional Survey Yes (data taken from Logs Portion of Master Well Data Maint) Interval OH / Start Stop CH Received Comments 7022 11539 eaae- 3/5/2003 digital well logging data öp..' 7001 11539 Open 8/9/2002 7022 11485 Case 9/27/2002 7001 11539 Open 8/9/2002 MWD 7022 11485 ~'9/27/2002 7001 11539 Open 8/9/2002 7001 11539 Open 8/9/2002 MWD Sample Set Number Comments ~ ('j)/ N ~ Date: ~~~GI ( ( L l d~NOIo~ [ I 00 ~ I c.- , 0 t..J aÖd-' O'lo) Jl(pO¡ I CioL} P6 I a Od-cJ.of 110D<6 WELL LOG TRANSMITfAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Lisa Weepie 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 March 03~ 2003 RE: MWD Fonnation Evaluation Logs: IC-I04, PB 1 & LI AK-MW-22 102 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of Rob Kalish, Sperry-Sun Drilling Se1VÏces, 6900 Arctic Blvd., Anchorage, AK 99518 lC-104: Digital Log Images: 50-029-23076-00 1 CD Rom lC-104 PBl: Digital Log Images: 50-029-23076-70 1 CD Rom lC-104 Ll: Digital Log Images: 50-029-23076-60 1 CD Rom RECEIVED MAR 05 2003 AJasica Oit & Gas Con '\ A. S. ~11 I"Wfchorage ~ :":;":". PHilliPS Alaska, Inc. ~ A Subsidiary of PHILLIPS PETROLEUM COMPANY Post Office Box 100360 Anchorage, Alaska 99510-0360 R. Thomas Phone (907) 265-6830 Fax: (907) 265-6224 October 1,2002 Commissioner Cammy Oechsli Taylor State of Alaska Alaska Oil & Gas Conservation Commission 333 West ih Avenue Suite 100 Anchorage, Alaska 99501 Subject: Completion Report for 1C-104 and 1C-104L1 (202-061 and 202-062) Dear Commissioner: Phillips Alaska, Inc. submits the attached Completion Report for the drilling operations on the Kuparuk well1C-104 and the lateral1C-104Ll. If you have any questions regarding this matter, please contact Steve McKeever at 265-6826. Sincerely, G~~ R. Thomas Greater Kuparuk Team Leader P AI Drilling ---..:::> RT/skad RI€I\\JEÐ OCT 0 12002 """"OI&Ga8QonS. ~ t\I~ AncbOyage STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG ( 1. Status of well Classification of Service Well Oil 0 Gas D 2. Name of Operator Phillips Alaska, Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510-0360 4. Location of well at surface Suspended D Abandoned D Service D 7. Permit Number 202-062 8. API Number J.f"77~~'~~:;~~~.77;';7"V<? 1437'FNL 625'FWL Sec. 12 T11N R10E UMi "'\.c'a,.c.hJ;'; i AtTop prod~cing Interva; , , , ~ 7.D~,~;oÞ~ , ,i1---- ~ 386 FNL, 1017 FWL, Sec. 11, T11 N, R10E, UMf VE'"¡¡¡:JED i At Total Depth 3 . h' \ 425' FSL, 1070' FWL, Sec. 11, T11N, R1OE, UM ~=~~=~:::f: (ASP: 556827, 5965341) 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. DF @ 101.8' AMSL ADL 25649 ALK 467 12. D.:l~lPUd~d 13. Date T.D. Reached /' 14. Date Comp., Susp. Or Aband. ~ 2002 A July 18, 2002 July 29, 2002 17. Total Depth (MD + TVD) 18. Plug Back Depth (MD + TVD) 19. Directional Survey 11539' MD 13626' TVD 11514' 13627' YES 0 No D 22. Type Electric or Other Logs Run GR/Res 23. 50-029-23076-60 9. Unit or Lease Name (ASP: 561631, 5968797) (ASP: 556735, 5969808) Kuparuk River Unit 10. Well Number 1 C-1 04L 1 11. Field and Pool Kuparuk River Field West Sak Oil Pool .-; 15. Water Depth, if offshore 16. No. of Completions N/A ffietMSL 1 20. Depth where SSSV set 21. Thickness of Permafrost N/A feet MD 2419' 7/kJ~,w 7oY.3 / H?þ ~fï" TVJ> 16" WT. PER FT. 62.5# 29.7# 9.5# GRADE H-40 L-80 L-80 CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD TOP BOTTOM Surface 158' Surface 7395' 7063' 11514' HOLE SIZE CASING SIZE 24" CEMENTING RECORD 285 sx AS I AMOUNT PULLED 7.625" 4" 9.875" 6.75" 900 sx ASLite, 290 sx Class G screen 24. Perforations open to Production (MD + TVD of Top and Bottom and interval, size and number) 25. SIZE 4.5" TUBING RECORD DEPTH SET (MD) 6172' PACKER SET (MD) N/A No perfs - pre-pack screens in horizontal laterals 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 11396' - 9809' 111 bbls 10% HCI acid 9736' - 8286' 75 bbls 10% HCI acid 8210' - 7179' 54 bbls 10% HCI acid 27. PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) 9/19/2002 Flowing - shares production with 1 C-1 04 Date of Test Hours Tested Production for OIL.BBL GAS-MCF 9/25/2002 4 hours Test Period> 134 29 Flow Tubing Casing Pressure Calculated OIL-BBL GAS-MCF Press. 411 psi not available 24-Hour Rate> 805 174 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and pressence of oil, gas or water. Submit core chips. WATER.BBL 0 WATER-BBL 4 CHOKE SIZE 100 bean OIL GRAVITY - API (corr) not available GAS-OIL RATIO 216 N/A R~(ErVED Q90MS 8Fl aCT!.4 2002 OCT 01,2002 Alaska OIJ& Gas Oons. Gommtsslon r r::- Anchorqe lJ Submit in duplicate Form 10-407 Rev. 7-1-80 CONTINUED ON REVERSE SIDE 29. ( 30. GEOLOGIC MARKERS FORMATION TESTS NAME MEAS.DEPTH TRUE VERT. DEPTH Include interval tested, pressure data, all fluids recovered and gravity. GOR, and time of each phase. Top West Sak Sand 7045' 3681' N/A RECEI'VED 31. LIST OF ATTACHMENTS Summary of Daily Operations, Directional Survey 32. I hereby certify that the following is true and correct to the best of my knowledge. OCT 0 1..2002 AlasKa ola Gas Qons. Commission Anr.hnn:qre Questions? Call Steve McKeever 265-6826 0-.~ Signed \ ~ -ì"itle Kuparuk Drilling Team Leader D\С{loè ate Randy Thomas Prepared by Sharon Allsup-Drake INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1: Classification of Service wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10-407 ~. I'" f r,~ ;I ~ Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date 7 n 12002 7/8/2002 7/9/2002 PHILLIPS Operations 1 C-1 04 1 C-1 04 ROT - DRILLING n1268@ppco.com Nabors 245 6/20/2002 Spud Date: 6/24/2002 End: Group: Start: Rig Release: Rig Number: 245 Description of. Operations From - To Hours Code Sub Phase Code 16:00 - 18:00 18:00 - 19:00 19:00 - 20:00 20:00 - 21 :30 21 :30 - 22:00 22:00 - 00:00 00:00 - 00:30 00:30 - 04:00 04:00 - 10:30 10:30 - 11 :00 11 :00 - 12:00 12:00 - 13:30 13:30 - 14:00 14:00 - 14:30 14:30 - 15:30 15:30 - 16:00 16:00 - 18:30 18:30 - 22:30 22:30 - 00:00 00:00 - 01 :30 2.00 DRILL CIRC PROD 1.00 DRILL TRIP PROD 1.00 DRILL REAM PROD 1.50 DRILL CIRC PROD 0.50 DRILL TRIP PROD 2.00 DRILL TRIP PROD 0.50 DRILL TRIP PROD 3.50 DRI LL CI RC PROD 6.50 DRILL REAM PROD 0.50 DRILL REAM PROD 1.00 RIGMNT RSRV PROD 1.50 DRILL TRIP PROD 0.50 DRILL SURV PROD 0.50 DRILL REAM PROD 1.00 DRILL CIRC PROD 0.50 DRILL TRIP PROD 2.50 DRILL TRIP PROD 4.00 DRILL CIRC PROD 1.50 DRILL CIRC PROD 1.50 DRILL CIRC PROD Pump up survey. Circ and condition mud and hole @ 8.8 bpm=370 gpm & 2600 psi. for s hort trip. Pump total of 8500 strokes. Set ba ck a stand every 30 min. Monitor well. POOH wet. record PU wt every stand. Hole swabbing f/ 11134' to 10787'. MU top drive. Wash and ream in hole f/ 10,818' to 11,134'. Circ and condition hole wi 87 spm & 100 rpm .Set back a stand every 30 minutes. POOH wet wlo pumps. POOH fl 10845' to 10 561'. Hole still swabbing. RIH fl 10561' to 11115'. Fill pipe, continue i n hole. Taking excess wt @ 11,234'. MU top drive, work through wi 30 spm 900 psi to 11 ,319' . Continue to RIH f/ 11,319'. Pump down fl 11 ,282' to 11,414' wi 30 spm and 800 psi. Pum p & rotate f/ 11,414' to 11,560'. Circulate and clean hole while monitoring E CD's. Pump rate 75 SPM wi 2350 psi and 10 0 RPM wi picking up. Slow pumps to 80 goin g slacking off. Pump sweep around after fir st BU, Got back wall cake in returns. Monitor well, POOH, backreaming out wi 75 spm @ 2300 psi. Rotating wi 100 RPM's. SL M on way out to shoe. Back ream last stand slow into shoe @ 7395 , Circ a bottoms up in doing so. Monitor well and lubricate top drive and dra wworks. RIH. Replace joint off top of stand 96. Conti nue in hole. Tag up @ 9330' (Old hole which was side tracked @ 8860' to 9330'). Pump up survey. We are in wrong hole. Pump out of hole f/ 9330' to 8767'. Orient a nd go into the right well. Circ and condition hole @ sidetrack. Continue to RIH to 8920'. verify in sidetrack ed hole. Cleanup hole POOH f/8920' to 8767', RIH to 8925' wi no p umps. Pump up survey. Continue RIH to 115 60' . Circulate and condition hole @ 87 spm (370 gpm) with 2900 spi. Pump total of 17319 str okes (1749 bbls). PJSM for fluid change out to brine. Flush pumps 1,2,3 , kill line, fillu p line. Working on trip tank pump cleanup. Pump 26 bbls Flovis spacer, followed by 650 bbls 8.9 ppg brine @ 87spm & 2950 psi whi Ie rotating @ 100 rpm. Finish Displacing to 8.9 ppg Brine, Spot 290 Printed: 8/16/2002 4: 18: 11 PM ( ( Legal Well Name: 1 C-1 04 Common Well Name: 1 C-1 04 Event Name: ROT - DRILLING Contractor Name: n1268@ppco.com Rig Name: Nabors 245 Date From- To Hours Code Sub Phase Code 7/9/2002 00:00 - 01 :30 1.50 DRILL CIRC PROD 01 :30 - 02:30 1.00 DRILL OBSV PROD 02:30 - 08:00 5.50 DRILL TRIP PROD 08:00 - 10:30 2.50 DRILL OTHR PROD 10:30 - 14:00 3.50 DRILL OTHR PROD 14:00 - 15:00 1.00 DRILL CIRC PROD 15:00 - 16:00 1.00 RIGMNT RSRV PROD 16:00 - 17:00 1.00 DRILL CIRC PROD 17:00 - 18:30 1.50 DRILL OTHR PROD 18:30 - 00:00 5.50 DRILL TRIP PROD 7/10/2002 00:00 - 02:00 2.00 DRILL TRIP PROD 02:00 - 03:00 1.00 CASE OTHR CMPL TN 03:00 - 04:00 1.00 CASE OTHR CMPL TN 04:00 - 05:30 1.50 CASE OTHR CMPL TN 05:30 - 07:30 2.00 CASE OTHR CMPL TN 07:30 - 08:00 0.50 CASE SFTY CMPL TN 08:00 - 10:30 2.50 CASE OTHR CMPL TN 10:30 - 12:00 1.50 CASE CIRC CMPL TN 12:00 - 13:00 1.00 CASE OTHR CMPL TN 13:00 - 16:00 3.00 CASE OTHR CMPL TN 16:00 - 19:00 3.00 CASE OTHR CMPL TN 19:00 - 19:30 0.50 CASE OTHR CMPL TN 19:30 - 21 :00 1.50 CASE CIRC CMPL TN 6/20/2002 Spud Date: 6/24/2002 End: Group: Start: Rig Release: Rig Number: 245 Description of Operations bbls HEC viscosified pill on btm. while reci procating pipe, 47 spm @ 1400 psi, Up Wt 2 OOK, Could not go down without pump Monitor well while cleaning possum bellies & shakers, Change shaker screens & finish cleaning trip tank POOH slow to 7341', Record torque & drag r eadings every 5 stands, Cleaning mud pits Monitor well, Pull mouse hole & remove flow line, Clean & reinstall same, pull inspectio n plate on lower flow line & clean same (Flo w line was 80 % pack off) Rig & flush all pumps, Choke & Kill lines, M anifold, Gas buster, Mud pits Displace well w/ 9.3 ppg Brine at rate of 6 b pm @ 1300 psi & work pipe (289 bbls) Monitor well (Static), Clean pits, Service Dr awworks Finish displacing well to 9.3 ppg brine (350 b b Is) Monitor well- OK, Clean & fill trip tank, Cha nge shaker screens POOH wet 216', Record torque & drag read in gs every 5 stands, Lay down CBl's on way 0 u t Monitor well at BHA- OK, POOH, Down load & Lay down MWD & BHA Break out saver sub & retrieve corrosion rin gs, Drain Stack & check well head wear bus hing alignment with valves Make up 7-5/8" Scraper BHA RIH w/ DP to 5501' Pick up 36 joints of 4" HWDP & RIH 8 stand s from derrick PJSM with all rig personal prior to Caustic wash Rig & Pump 75 bbls Caustic wash at rate of 4.2 bpm @ 500 psi, Followed by 166 bbls 9. 3 ppg brine at rate of 6.5 bpm @ 950 psi, C heck Torque & drag of 70 RPM w/ 4000 ft/lb TO, UP 155K, DN 145K, ROT 144K, Divert re turns to vac. truck to capture caustic wash Circ clean brine & check NTU's (446 bbls) a t rate of 7.6 bpm @ 1300 psi Rig Dowell, PJSM with all hands Check UP wt. of 162K, DN wt of 127K, Test I ines to 3000 psi, Pump Acid pickle & displa ce to within 1 bbl of bit at rate of 1/2 bpm Reverse out Acid pickle to open top tank & 2 pipe volumes Rig down Dowell, Blow down kill line Change over to HEC viscosified brine w/ 3% Lubetex, UP wt 162K, DN 130K, ROT 144K, 5 Printed: 8/16/2002 4: 18: 11 PM (_.\~ ',~,,,,,, ~ ( PHilliPS ALASKA INC. Operations. Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 C-1 04 1 C-1 04 ROT - DRILLING n1268@ppco.com Nabors 245 Date From - To Hours Code Sub Phase Code 7/1 0/2002 1.50 CASE CI RC CMPL TN 2.00 CASE CIRC CMPL TN 1.00 CASE OTHR CMPLTN 19:30 - 21 :00 21 :00 - 23:00 23:00 - 00:00 7/11/2002 1.50 WELCTL OBSV CMPL TN 00:00 - 01 :30 01 :30 - 07:30 6.00 CASE OTHR CMPL TN 07:30 - 08:00 08:00 - 09:00 0.50 CASE OTHR CMPL TN 1.00 WELCTL BOPE CMPL TN 09:00 - 16:00 7.00 WELCTL BOPE CMPL TN 16:00 - 17:00 1.00 WELCTL BOPE CMPL TN 17:00 - 23:00 6.00 CASE PULR CMPL TN 23:00 - 00:00 1.00 CASE PUTB CMPL TN 7/12/2002 00:00 - 05:00 5.00 CASE PUTB CMPL TN 05:00 - 06:00 1.00 CASE PUTB CMPL TN 06:00 - 06:30 0.50 CASE CIRC CMPL TN 06:30 - 10:30 4.00 CASE RUNL CMPL TN 10:30 - 11 :30 1.00 CASE CIRC CMPL TN 11 :30 - 17:00 5.50 CASE RUNL CMPL TN 17:00 - 19:00 2.00 CASE DEOT CMPL TN 19:00 - 21 :00 2.00 CASE CIRC CMPL TN 21 :00 - 22:30 1.50 WELCTL OBSV CMPL TN 22:30 - 00:00 1.50 WELCTL OTHR CMPL TN 6/20/2002 Spud Date: 6/24/2002 End: Group: Start: Rig Release: Rig Number: 245 Description of. Operations 000 ft/lb TO Circ & add 1% Flow lub to system Check UP wt of 157K, DN wt of 130K, ROT 0 f 142K, TO of 4000 ft/lb Monitor well, Well flowing 2.6 bph decreasei ng to 1.7 bph - due to reversing out Acid an d charging up formation, Pump dry job POOH slow due to mild swabbing if pulled to fast, Started taking good fill after pulling 37 stands Lay down 7-5/8" Scraper BHA Drain stack, Pull wear bushing, Install test plug, Fill stack Test all BOPE to 250 low & 5000 psi high, H ydrill to 250 low & 3500 psi high, Had to re tighten blind flange on diverter spool due to leaking, BOPE test waived by AOGCC Lou Grimaldi Rig down test equip., Set wear bushing, Blo w down all lines PJSM, Rig & run 4" liner Rig to run 2-7/8" inner string Make up Baker wash cups & run 2-7/8" inner string Space out 2-7/8" & Pick up hanger assembly (Tbg. string wt. 94K UP, 86K DN), Clear flo or of tools RIH wi liner 1 stand, Break circ. at 3 bpm @ 450 psi (Total liner string 122K UP, 108K D N) RIH to 7-5/8" shoe, Fill pipe every stand, Br eak circ. & check drag wt's every 5 stands Break circ. & circ BTM's up, 115 bbls at rat e of 3 bpm wi 500 psi RIH to 11550', Fill pipe every stand, Break circ. & check drag wt's every 5 stands, wt's on btm= UP wt. 191 K, DN 93K Drop & pump down ball, Set Hanger & packe r, Test csg to 2000 psi- OK, Pull free wi 16 5K Pressure up to 3800 psi & shear out ball, Pu mp 600 bbls & change over to clean 8.9 ppg brine at rate of 8 bpm @ 3500 psi, (Displace d out 9.3 ppg HEC brine above liner, Btm's up had 15% crude oil & 9% LEL gas) Monitor well, Well flowing (Initially 14.2 bph , decreased to 6.8 bph in 30 min., decrease d to 5.9 bph in 90 min.) Shut well in & observe pressures while build ing 9.3 ppg brine, Sent 8.9 ppg Acid back to Deadhorse to build weight up to 9.3 ppg, ( SID P P = 5 2 psi (H Y d r 0 s tat i cpr e ss u reo f s tan d pip e 3 0 psi), SIC P = 3 0 psi - p re s sur e s s t a Printed: 8/16/2002 4: 18: 11 PM ~.. ~ PHilliPS ALASKA INC. Operations. Summary Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 C-1 04 1 C-1 04 ROT - DRILLING n1268@ppco.com Nabors 245 Sub Hours Code. Code Phase Date From -To 7/12/2002 7/13/2002 22:30 - 00:00 00:00 - 00:30 00:30 - 03:30 1.50 WELCTL OTHR CMPL TN 0.50 WELCTL OTHR CMPL TN 3.00 WELCTL KILL CMPL TN 03:30 - 04:30 04:30 - 06:00 1.00 WELCTL OBSV CMPL TN 1.50 CMPL TN TRIP CMPL TN 06:00 - 09:00 09:00 - 17:00 3.00 CMPLTN TRIP CMPLTN 8.00 CMPL TN AWSH CMPL TN 17:00 - 19:30 2.50 CMPL TN AWSH CMPL TN 19:30 - 21 :00 1.50 RIGMNT RSRV CMPL TN 21 :00 - 23:00 2.00 CMPL TN AWSH CMPL TN 23:00 - 00:00 1.00 CMPL TN CIRC CMPL TN 7/14/2002 00:00 - 02:00 2.00 CMPL TN AWSH CMPL TN 02:00 - 02:30 0.50 CMPL TN OBSV CMPL TN 02:30 - 03:00 0.50 CMPLTN TRIP CMPL TN 03:00 - 05:30 2.50 CMPL TN TRIP CMPL TN 05:30 - 06:30 1.00 CMPL TN DEQT CMPL TN 06:30 - 08:00 1.50 CMPL TN TRIP CMPLTN 08:00 - 13:30 5.50 CMPL TN PULD CMPL TN 13:30 - 14:30 1.00 RIGMNT RSRV PROD 14:30 - 17:00 2.50 WINDOWPULD PROD 17:00 - 17:30 0.50 WINDOWPULD PROD 17:30 - 23:00 5.50 WINDOWTRIP PROD 23:00 - 00:00 1.00 WINDOWCIRC PROD 7/15/2002 00:00 - 01 :00 1.00 WINDOWSETW PROD 01 :00 - 10:00 9.00 WINDOWSTWP PROD 10:00 - 12:00 2.00 WINDOWCIRC PROD 12:00 - 13:30 1.50 WINDOWTRIP PROD 6/20/2002 Spud Date: 6/24/2002 End: Group: Start: Rig Release: Rig Number: 245 Description of Operations ble after 40 min.) Build weight of brine back to 9.3 ppg Bleed off & Open well, Change over to 9.3 p pg brine at 5 bpm @ 1300 psi Monitor well -OK POOH to 7425', Install Safety valve & Dart v a I v e RIH to 11550', Fill every stand PJSM, Rig Dowell, Test lines, Pump total of 210 bbls 10% HCL Acid in 3 stages & wash 4 " liner screens from 11432' to 7446' RIH to 11500' Cut & Slip Drilling line 99, Service top drive Continue to let Acid soak, Initial fluid loss of 7 bph- decrease to 1 bph (Total of 17 bbl s brine lost while soaking Acid) Pump & Change over to 9.3 ppg brine at rate of 5 bpm @ 1225 psi (Taking returns to vac uum trucks) Displace out of hole w/ 9.3 ppg brine at rate of 5 bpm @ 1250 psi (Pump total of 580 bbl s), Taking returns to vacuum trucks Monitor well- (Lossing 11 bph) POOH 10 stands, Monitor well-(Lossing 18 b ph & slowed to 13.5 bph) POOH, Close Sliding sleeve at 7256', POOH to 7141' Rig & Test KOIV to 12.5 ppg EMW w/ 622 psi - 0 K POOH & Lay down liner running tools PJSM, Rig & Lay down 2-7/8" inner string Change out saver sub & Strip-O-Matic Pick up Whipstock BHA Pick up MWD, Orient Whipstock, Program M WD RIH, Shallow test MWD- OK, RIH & Tag @ 72 06' w/ Top of Whipstock @ 7043' Orient Whipstock to 33L, Change over to 9.0 ppg mud Set Baker Whipstock @ 7043', Monitor well ( With 9.0 ppg mud in hole)- OK, Close Choke & Kill valves to keep metal out of same Mill 6-3/4" window f/ 7043' to 7055', Btm of guage hole @ 7058' with 6-1/8" mill @ 7073' , Milled with 300 gpm @ 1300 psi, 6500 ft/lb tq. @ 90 RPM, With pumps on UP wt.= 145 K, DN= 108K, Rot= 125K, With pumps off U P wt.= 150K, DN= 112K Pump sweep & hole clean, Monitor well, Dry pip e POOH to 5469' (Hole not taking proper fill), Monitor well Printed: 8/16/2002 4: 18: 11 PM ~. I~ PHILLIPS ALASKA INC. Operations.Summary Report Legal Well Name: 1 C-1 04 Common Well Name: 1 C-1 04 Event Name: ROT - DRILLING Contractor Name: n1268@ppco.com Rig Name: Nabors 245 From -To Hours Code Sub Phase Code 7/15/2002 13:30 - 15:00 1.50 WINDOWCIRC PROD 15:00 - 16:00 1.00 WINDOWTRIP PROD 16:00 - 17:30 1.50 WINDOWCIRC PROD 17:30 - 21 :30 4.00 WINDOWTRIP PROD 21 :30 - 23:00 1.50 WINDOWPULD PROD 23:00 - 00:00 1.00 WINDOWCIRC PROD 7/16/2002 00:00 - 01 :00 1.00 WINDOWCIRC PROD 01 :00 - 02:00 1.00 RIGMNT RSRV PROD 02:00 - 04:30 2.50 DRILL PULD PROD 04:30 . 07:30 3.00 DRILL TRIP PROD 07:30 - 08:00 0.50 RIGMNT RGRP PROD 08:00 - 08:30 0.50 DRILL TRIP PROD 08:30 - 09:00 0.50 DRILL REAM PROD 09:00 - 10:00 1.00 DRILL DRLG PROD 10:00 - 10:30 0.50 DRILL FIT PROD 10:30 - 00:00 13.50 DRILL DRLG PROD 7/17/2002 00:00 - 00:00 24.00 DRILL DRLG PROD 7/18/2002 00:00 - 10:00 10.00 DRILL DRLG PROD 10:00 - 11 :00 1.00 DRILL CIRC PROD 11 :00 - 20:30 9.50 DRILL WIPR PROD 20:30 - 21 :30 1.00 DRILL CIRC PROD 21 :30 - 22:30 1.00 RIGMNT RSRV PROD 22:30 . 00:00 1.50 DRILL WIPR PROD 7/19/2002 00:00 - 00:30 0.50 DRILL WIPR PROD 00:30 - 01 :30 1.00 DRILL CIRC PROD 01 :30 - 03:00 1.50 DRILL CIRC PROD 03:00 - 04:30 1.50 DRILL CIRC PROD 04:30 . 06:00 1.50 DRILL TRIP PROD 06:00 - 07:00 1.00 DRILL PULD PROD 07:00 - 09:00 2.00 DRILL TRIP PROD 6/20/2002 Spud Date: 6/24/2002 End: Group: Start: Rig Release: Rig Number: 245 Description of Operations Circ. Btm's up, Monitor well POOH to 5394' (Hole not taking proper fill), RIH to 7010' Circ. & raise mud weight to 9.4 ppg Monitor well, POOH ( Tight spot @ 6830'- W ork thru wi 30K over), POOH to BHA Monitor well @ BHA -OK, Lay down Mill Asse m bly Pull wear bushing, Make up BOPE wash tool Flush out BOPE ram cavities, Install wear b ushing Service top drive & Drawworks Pick up 6-3/4" Bit, Motor & BHA, Orient mot or & Program MWD RIH to 6000', Record UP & ON wt's, Fill pipe every 2000' Repair Iron roughneck spinners RIH to 7056' Orient motor & ream fI 7056' to 7073' Drill fl 7073' to 7093' Rig & Perform FIT wi 690 psi, 9.0 ppg mud, 3681' TVD= 12.6 ppg EMW Drill fI 7093' to 8160' AST= 5.27 hrs = 3.67 hrs Drill fl 8160' to 10696' ART= 11.16 hrs A ST= 2.35 hrs Drill fI 10696' to 11539' AST= 1 hr. 4.91 hrs Circ. Btm's up, Monitor well Back Ream out of hole (Precautionary) fI.11 539' to 7258' wi 7.6 bpm, 80 RPM, 2550 psi, Work BHA Thru window @ 7055'.7043' (6-1 2K Drag), Pull up to 7030' Monitor well, Circ. Btm's up @ 6998' wI 7.6 bpm @ 2250 psi, 80 RPM Service top drive RIH to 9291' (Record UP & ON weights every 5 stands) RIH to 11539' (Hole in good shape), Record UP & ON weights every 5 stands Circ. Btm's up 7.7 bpm @ 2575 psi Pump 30 bbls Push Pill, Flush all 3 pumps, Change over to 9.3 ppg Brine at rate of 8.2 bpm @ 2750 psi, Rotate at 80 RPM & Recip. pipe (Total of 580 bbls) Monitor well, Pump & Displace open hole wit h 290 bbls 2.5 ppb HEC viscosified brine at rate of 5 bpm @ 1700 psi fI vacuum truck Monitor well, POOH (15- 20K drag, Good fill ), Stand back 13 stands HWDP POOH & Lay down 18 jts HWDP POOH above window @ 7043' (Hole in good s hape- 15- 20 K drag, Good fill), Monitor we I ART ART= Printed: 8/16/2002 4: 18: 11 PM ~~~ ,~ Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: ( ( PHILLIPS ALASKA OperätlönsSummary Report 1 C-1 04 1 C-1 04 ROT - DRILLING n1268@ppco.com Nabors 245 Date From - To Hours Code Sub Phase Code 7/19/2002 07:00 - 09:00 2.00 DRILL TRIP PROD 09:00 - 10:00 1.00 DRILL OTHR PROD 10:00 - 11 :00 1.00 DRILL CIRC PROD 11 :00 - 15:00 4.00 DRILL TRIP PROD 15:00 - 17:00 2.00 DRILL PULD PROD 17:00 - 00:00 7.00 WELCTL BOPE CMPL TN 7/20/2002 00:00 - 01 :00 1.00 WELCTL OTHR CMPL TN 01 :00 - 09:00 8.00 CMPL TN TRIP CMPL TN 09:00 - 10:30 1.50 CMPL TN CIRC CMPL TN 10:30 - 12:30 2.00 CMPL TN AWSH CMPL TN 12:30 - 16:00 16:00 - 16:30 16:30 - 21 :30 21 :30 - 23:00 23:00 - 00:00 7/21/2002 00:00 - 04:00 04:00 - 05:00 05:00 - 08:00 3.50 CMPL TN CIRC CMPL TN 0.50 RIGMNT RSRV CMPL TN 5.00 CMPL TN AWSH CMPL TN 1.50 CMPL TN CIRC CMPL TN 1.00 CMPL TN TRIP CMPL TN 4.00 CMPL TN TRIP CMPL TN 1.00 RIGMNT RSRV CMPL TN 3.00 FISH OTHR CMPLTN 6/20/2002 Spud Date: 6/24/2002 End: Group: Start: Rig Release: Rig Number: 245 Description of Operations I Pull inspection plate on flow line, Flow line- OK, Clean Possum bellies, Pump thru gas b uster Circ. & Change casing over to 9.3 ppg filter ed brine at rate of 7.5 bpm @ 1900 psi POOH to BHA, Record Torque & drag reads e very 5 stands PJSM, Lay down BHA, Down load MWD, Clea r rig floor Pull wear bushing, Set test plug, Rig & Test all BOPE to 250 psi low & 5000 psi high, T est Hydril to 250 low & 3500 psi high, Test waived by AOGCC John Spaulding, Rig down test equipment, Set wear bushing Blow down choke manifold, Service top drive Make up 7-5/8" scraper BHA & RIH to 7009' (Hole took 16.6 bbls under displacement) Circ. btm's up at rate of 5.5 bpm @ 900 psi (267 bbls) PJSM, Pump 78 bbls Caustic wash pill w/ 73 b b I s 1 30- 1 50 de g. hot wa t e r ,.5 g a I. W D - 2 4 Anti-Foam, 750 Ibs. of caustic soda, 16 gals . of ARDS-9140 Surfactant, 40 gals. of ARD S-9755 Surfactant, Circ. at rate of 5.5 bpm @ 900 psi, Ship returns to vacuum truck Circ. 9.3 ppg brine at rate of 5.5 bpm @ 900 psi until NTU's below 20 Service top drive PJSM, Pump Acid pickle w/ 10 bbls Xanvis h igh vis pill (2.25 Ibs/bbl), 6.3 bbls 9.3 NaCI brine w/ 2 drums CE-101, 500 gal. 15% HCI Acid inhibitor, Pump Acid at rate of .5 bpm to within .5 bbl to bit, Reverse Acid out to 0 pen top tank, Swith returns to pits & check r eturns until NTU's read 19, Check Torque & Drag readings of UP= 178K, DN= 137K, Rot= 156K, TO= 6000 ft/lbs Open well & circ. 9.3 ppg brine w/ 2.5% HEC & 3% Lubetex around to surface, Check To rque & Drag of UP= 176K, DN= 142K, Rot= 1 56K, TO= 5500 ft/lbs Monitor well, POOH checking Torque & Drag every 5 stands POOH, SLM DC's & HWDP - No Correction, R ecord Torque & drag every 5 stands, Lay do wn scraper BHA (7.7 bbls over on displacem en t) Cut & slip drilling line 121', Service top dri ve Make up Baker fixed lug whipstock retrievin g tool, RIH to 7011' (3.7 bbls under displac Printed: 8/16/2002 4: 18: 11 PM ( ~~ (j ~,":¡ ~ Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 C-1 04 1 C-1 04 ROT - DRILLING n1268@ppco.com Nabors 245 Date From - To Hours Code Sub Phase Code 7/21/2002 05:00 - 08:00 3.00 FISH OTHR CMPL TN 08:00 - 09:30 1.50 FISH PULL CMPL TN 09:30 - 10:30 1.00 FISH CIRC CMPL TN 10:30 - 14:30 4.00 FISH TRIP CMPL TN 14:30 - 17:30 3.00 FISH PULD CMPL TN 17:30 - 20:30 3.00 FISH TRIP CMPL TN 20:30 - 21 :00 0.50 FISH JAR CMPL TN 21 :00 - 22:00 1.00 FISH CIRC CMPL TN 22:00 - 00:00 2.00 FISH TRIP CMPL TN 7/22/2002 00:00 - 02:30 2.50 FISH TRIP CMPL TN 02:30 - 03:00 0.50 FISH PULD CMPLTN 03:00 - 09:30 6.50 CMPL TN SCRN CMPL TN 09:30 - 16:00 6.50 CMPL TN OTHR CMPL TN 16:00 - 17:00 1.00 CMPL TN SCRN CMPLTN 17:00 - 23:00 6.00 CMPL TN TRIP CMPL TN 23:00 - 00:00 1.00 CMPL TN OTHR CMPL TN 7/23/2002 00:00 - 01 :00 1.00 CMPL TN SCRN CMPL TN 01 :00 - 02:00 1.00 CEMENT NFL T CMPL TN 02:00 - 02:30 0.50 CEMENT NFL T CMPL TN 6/20/2002 Spud Date: 6/24/2002 End: Group: Start: Rig Release: Rig Number: 245 Description of Operations ement) - (Check Up & Dn weights every 5 st ands) Break circ. at 3 bpm @ 625 psi, Check weig hts = Up 174K, Dn 138K, RIH & orient Fixed lug until latched onto whipstock @ 7048', W ork Jars f/ 225- 235K & Pulling up to max of 250K, Whipstock finally released @ 235K Circ. Btm's up at rate of 5 bpm @ 900 psi, Monitor well POOH wI whipstock, Lay down whipstock and shear release sub, (Whipstock Anchor still in hole TOF @ 7061') Make up Overshot & Fishing tools, Pick up 1 2 4-3/4" DC's RIH to 7051', Check weights = Up 145K, Dn 1 1 1 K Work over & latch onto fish @ 7061', Jar on fish wI 225K then pull to 250K, Fish came fr ee, Had increase of 5K weight & 350 psi inc rease on pump Pull up to 7030', Drop ball & open circ. sub, Circ. btm's up at rate of 7.5 bpm @ 900 psi Moniot well, Pump dry job, POOH wI fish POOH, Lay down whipstock anchor BHA & Fi shing tools (1.8 bbls over on displacement) Lay down 12- 4-3/4" DC's used for fishing PJSM, Rig & run 4" liner & jewelry (1.2 bbls over on displacement), Up wt.= 107K, Dn= 97K PJSM, Rig & run 2-7/8" inner string & jewler y, Space out tools, Up wt.= 88K, Dn= 84K Make up Hook Hanger Up wt.= 125K, Dn wt.= 108K, Clear rig floor RIH wI 4" liner on 4" DP, Surface HWDP & D C's, Up wt.= 225K, Dn= 88K, Set Hook hange r WI top @ 7040' & Shoe @ 11514' Drop Ball, Pump down at rate of 1.7 bpm @ 450 psi & Release from liner Shear ball @ 3800 psi, Bleed off pressure, Pick up & locate Indicator sub, Lower pipe b ack down, Drop pump down plug, Rig Dowell, Hold PJSM Test lines to 3500 psi, Batch mix 5 bbls (24 sxs) Class G Cmt wI .3%D65, .3%S001, .02g allskD47 mixed @ 17.3 ppg, Pump cmt. to ri g floor, Open Drill pipe & Pump cmt. down p ipe followed by 5 bbls fresh water, Displace cmt. wI 46.8 bbls 9.3 ppg brine, Bump plug wI 1500 psi, Bled off pressure Pick up & tag indicator sub @ 7104', switch lines to Dowell, Inflate ECP wI 0.29 bbls cm t., Maximum pressure 1200 psi, Calculated h Printed: 8/16/2002 4: 18: 11 PM ~~~ I~ Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date 7/23/2002 7/24/2002 From - To 02:00 - 02:30 02:30 - 04:00 ( PHilliPS ALASKA INC. Operations Summary 1 C-1 04 1 C-1 04 ROT - DRILLING n1268@ppco.com Nabors 245 Sub Hours Code. Code Phase 0.50 CEMENTNFLT CMPLTN 1.50 CEMENTOTHR CMPL TN 04:00 - 05:00 1.00 CEMENT OTHR CMPL TN 05:00 - 07:30 2.50 CEMENTTRIP CMPL TN 07:30 - 08:00 0.50 CEMENTTRIP CMPL TN 08:00 - 13:30 5.50 CEMENTTRIP CMPL TN 13:30 - 14:30 1.00 CMPL TN OTHR CMPL TN 14:30 - 18:30 4.00 CMPL TN OTHR CMPL TN 18:30 - 19:00 0.50 CMPL TN OTHR CMPL TN 19:00 - 19:30 0.50 CMPL TN OTHR CMPL TN 19:30 - 22:30 3.00 CMPL TN TRIP CMPL TN 22:30 - 00:00 1.50 CMPL TN TRIP CMPL TN 00:00 - 00:30 00:30 - 03:30 03:30 - 04:00 04:00 - 08:30 08:30 - 09:00 09:00 - 13:00 13:00 - 15:00 0.50 CMPLTN TRIP CMPLTN 3.00 CMPLTN TRIP CMPLTN 0.50 CMPL TN OTHR CMPL TN 4.50 CMPLTN TRIP CMPLTN 0.50 CMPL TN OTHR CMPL TN 4.00 CMPL TN TRIP CMPL TN 2.00 CMPL TN CIRC CMPL TN 6/20/2002 Spud Date: 6/24/2002 End: Group: Start: Rig Release: Rig Number: 245 Description of Operations ole size 6-7/8" , Bleed off pressure Pick up above indicator sub, & start revers eing out while stripping thru Hydril at rate 0 f 1 bpm @ 300 psi, Pull upper cups into hoo k hanger @ (7045'), & reverse out at higher rate of 4 bprtt at 700 psi (Total of 10 bbls of cmt. & contaminated brine), Reverse total of 107 bbls. Open well & circ. btm's up @ 7 bpm @ 7045' wI 1500 psi. Pump a total volume of 300 bb Is. POOH wI external casing packer inflation to ols--- 4" HWDP, DC's & 4" DP. RU GBR to LID 2 7/8" Hydril 511 tubing. Hel d pre job meeting. LID 2 7/8" Hydril tubing. RID GBR. Clear ri g floor of small tools. M/U tools f/ setting diverter f/ upper lateral Monitor well. RIH wI diverter on 4" DP & DC' s & 4" HWDP. Set lateral diverter @ 7040'( top). PU weigh t 178 K, SO wt 136 K Drop ball. Ball did not shear out pump out s ub. Monitor well. POOH, LID d i v e r t err un n i n g too Is. C em en t s heath noted- flaking fl inside of drill pipe. Cement plugging up tools. RU to PU 2 7/8" tubing. Make up cup assemb Iy and 5 joints of 2 7/8". Lay down assembly of 200'. Note: Will lay down 44 stands 0 f 4" drill pipe with cement sheath in pipe. RID GBR & RU to LID 4" ,14#/ft, HT38 DP f/ derrick. LID 4", 14#/ft, HT 38 DP from derrick. LID i n mouse hole. This pipe had cement in it fro m packer inflation. LID mouse hole, RU GBR to run 2 7/8" asse mbly f/ acid wash of screens. Held pre job meeting. Hole took 1.8 bbls fluid for last 4 hours. PU 2 7/8" acid washing BHA, RIH wI 2 7/8" s tring to 4476.66'. PU wt 94 K SO wt 9 0 K Hole displacement 5.2 bbls under calcu I ate d. Rig down GBR. RU to run 4" DP f/ derrick. TIH wI 2 7/8" acid wash string on 4" DP. Go by diverter @ 7034' into upper lateral. PU wt 115 K SO wt 94 K Trip slow @ 1.5 min per stand to 11465'. Displace HEC vis brine f/ well. Pump 580 bb Is 9.3 ppg filtered brine @ 5.5 bpm wI 1650 psi. Printed: 8/16/2002 4: 18: 11 PM ~~þ ,~ Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Dáte 7/24/2002 7/25/2002 Page 18 of 22 PI-tILLIPSALASKA INC. Ope[atior1sSlImmary Report 1 C-1 04 1 C-1 04 ROT - DRILLING n1268@ppco.com Nabors 245 From - To Hours Code Sub Phase Code 15:00 - 15:30 15:30 - 16:30 16:30 - 19:00 19:00 - 19:30 19:30 - 21 :00 21 :00 - 22:00 22:00 - 23:00 23:00 - 00:00 00:00 - 02:00 02:00 - 04:00 04:00 - 05:30 05:30 - 06:00 06:00 - 08:00 0.50 CMPL TN SFTY CMPL TN 1.00 CMPL TN AWSH CMPL TN 2.50 CMPLTN AWSH CMPLTN 0.50 CMPL TN AWSH CMPL TN 1.50 CMPL TN AWSH CMPL TN 1.00 CMPL TN AWSH CMPL TN 1.00 CMPL TN AWSH CMPL TN 1.00 CMPL TN TRIP CMPL TN 2.00 CMPL TN TRIP CMPL TN 2.00 CMPL TN OTHR CMPL TN 1.50 CMPL TN OTHR CMPL TN 0.50 CMPL TN SFTY CMPL TN 2.00 CMPL TN CIRC CMPL TN 6/20/2002 Spud Date: 6/24/2002 End: Group: Start: Rig Release: Rig Number: 245 Description PJSM on acid wash wI Co. Rep, Toolpusher, Dowell Schlumberger & Vac truck drivers. RU, pump 5 bbls brine and test lines to 400 0 psi. (Stage # 1) Pump 111 bbls 10% HCL a cid @ 9.33 ppg @ 5.5 bpm & 1900 psi, folio w wI 5 bbls brine. (Stage # 1) POOH wI 2 7/8" wash string to clean screens f/ 11,396' to 9809'. Pump 35 strokes per set @ 3.0 bpm wI 500 psi. RU, pump 5 bbls brine and test lines to 400 0 psi. (Stage # 2) Pump 75 bbls 10% HCL ac id @ 9.33 ppg @ 5.0 bpm & 1100 psi, follow wI 5 bbls brine. (Stage # 2) POOH wI 2 7/8" wash string to clean screens f/ 9736' to 8286'. Pump 35 st rokes per set @ 3.0 bpm wI 500 psi. RU, pump 5 bbls brine and test lines to 400 0 psi. (Stage # 3) Pump 54 bbls 10% HCL ac id @ 9.33 ppg @ 4.7 bpm & 900 psi, follow wI 5 bbls brine. Take returns from this p oint until done washing, into vac truck from well. (Stage # 3) POOH wI 2 7/8" wash string to clean screens fl 8210' to 7179'. Pump 35 st rokes per set @ 3.0 bpm wI 500 psi. Tak e returns to vac truck from well. Trip back in hole to 11465'. Take returns to vac truck from well. Continue to RIH wI 2 7/8" acid wash assemb Iy to wait on 6 hour soaking of acid across screens. RIH to 11465'. Take displacement r eturns to vac truck f/ wellhead. Flush out B OP stack wI 25 bbl soda ash mix to vac truc k. While waiting f/ remainder of 6 hr soak of a cid-- LID 16 stands of 4" drill pipe from off driller side of derrick. Move 16 stands of 4" , 14#/ft, HT-38 drill pipe from off driller's s ide of derrick to driller's side of derrick. Conti n u e to let ac ids 0 a k 0 n s ere ens till 0 5 : 30 hrs. Rig down steam heater on floor to m ake room f/ heat trace cable placement f/ co mpletion run later. Held pre job safety meeting wI drilling crew, vac truck drivers, mud engineer's on displa cing acid from well. Well took total of 10 bbls fluid from 02:00 hrs until 0600 hrs. Circ out 10%, 9.33 ppg HCL from well to 9.3 ppg clean filtered brine. Take returns fl we II head to (2) vac trucks manifolded to 3" out let on wellhead. 6.5 bpm @ 2100 psi. At 2 8 0 b b Iso f b r i n ep u m p ed, r e t urn s f 0 a m e d u p--slowed rate to 3.5 bpm. Pumped total of Printed: 8/16/2002 4: 18: 11 PM ~ìPS.. ,~ Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date 7/25/2002 7/26/2002 From - To 06:00 - 08:00 08:00 - 09:00 09:00 - 10:00 ( PHilliPS ALASKA INC. Operations Summary Report 1 C-1 04 1 C-1 04 ROT. DRILLING n1268@ppco.com Nabors 245 Sub Hours Code Code Phase 2.00 CMPL TN CIRC CMPL TN 1.00 CMPL TN OTHR CMPL TN 1.00 CMPL TN CIRC CMPL TN 10:00 - 14:00 4.00 CMPL TN TRIP CMPL TN 14:00 - 16:30 2.50 CMPL TN TRIP CMPL TN 16:30 - 20:30 4.00 CMPL TN TRIP CMPL TN 20:30 - 21 :00 0.50 CMPL TN SFTY CMPL TN 21 :00 - 00:00 00:00 - 00:00 - 03:00 03:00 - 04:00 04:00 - 04:30 04:30 - 08:00 08:00 - 08:30 3.00 CMPL TN TRIP CMPL TN CMPL TN CMPL TN 3.00 CMPL TN TRIP CMPL TN 1.00 CMPL TN TRIP CMPL TN 0.50 CMPL TN CIRC CMPL TN 3.50 CMPL TN TRIP CMPL TN 0.50 CMPL TN OTHR CMPL TN 6/20/2002 Spud Date: 6/24/2002 End: Group: Start: Rig Release: Rig Number: 245 Description of Operations 533 bbls. Acid returns had a PH of 1 at this point, with both vac trucks full. RU & off load 200 bbls from one vac truck t 0 open top tank outside of rig. Sent other fu II vac truck to offload. Continue to circ out 10%, 9.33 ppg HCL from well to 9.3 ppg clean filtered brine. Take r eturns f/ wellhead to (1) vac truck manifolde d to 3" outlet on wellhead. 5.0 bpm @ 13 25 psi. With 563 bbls total pumped, PH = 2 ----Returns to Vac truck with 650 bbls total pumped, PH = 3----Returns to vac truck Wi th 700 bbls total pumped, PH = 4----Returns to Vac truck With 720 bbls total pumped, P H = 5----Vac true full-----start taking return s to rig With 765 bbls pumped, PH = 5. M onitor well. OK, slight losses. POOH, LID 4" DC's & 4" HWDP. Stand back 44 stands of 4", 14#/ft, HT-38 dr ill pipe on driller's side of derrick. **Clo se sliding sleeve @ 7171' while POOH. RU GBR. Lay down 2 7/8" hydril 511 tubing. Clear rig floor. Pre job safety meeting on running 4 1/2",12 .6 #/ft, L-80, NSTC completion tubing to ret rieve upper lateral diverter. RU GBR equip f/ 4 1/2". MU Baker retrieval tools to fetch upper later al diverter. MU on 4 1/2", 12.6 #/ft, L-80, N STC completion tubing. Run 80 joints in hol e. Note: total fluid loss on trip out of hol e = 24.1 bbls over 10.5 hrs Static 10 ss whle out of hole = 4.5 bbls Note: Well taking approx 2 bbl per hour of 9.3 ppg MI filtered brine. RIH on 4 1/2", 12.6 #/ft, L-80, NSTC compl etion tubing to fetch upper diverter. Run 19 8 joints in hole f/ pipe shed to 6127.30' PUwt122K SOwt102K RIH wi upper diverter retieval tool on 4", 1 4 #/ft, HT-38 dp f/ derrick to 6992'. PU w t 129 K SO wt 106 K Note: on trip in hol e - - 2 0 b b I sun d e r calc u I ate d fir e t urn s. H 0 I e taking 2.6 bbls/hr. Circ @ 2.5 bpm wi 725 psi. Wash to diverter to clean up. Latch on to diverter @ 7037' & pull 20 Kover = 150 K to relase diverter. POOH wi upper diverter to 6992', racking 4" dp in derrick. Rig up GBR f/ 4 1/2". Continu e to POOH standing 4 1/2",12.6 #/ft, L-80, NSCT completion tubing in derrick--ott drille r's side. PU one joint of 4", 14 #/ft, HT-38 drill pipe. Printed: 8/16/2002 4: 18: 11 PM (. Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: ( PHilliPS Operations Summary 1 C-1 04 1 C-1 04 ROT - DRILLING n1268@ppco.com Nabors 245 From - To Hours Code Sub Phase Code 7/26/2002 08:00 - 08:30 08:30 - 09:30 09:30 - 12:30 12:30 - 16:30 16:30 - 20:30 0.50 CMPL TN OTHR CMPL TN 1.00 WELCTL OTHR CMPL TN 3.00 WELCTL BOPE CMPL TN 4.00 CMPL TN RURD CMPL TN 4.00 CMPL TN RUNT CMPL TN 20:30 - 00:00 3.50 CMPL TN OTHR CMPL TN 7/27/2002 00:00 - 00:30 0.50 CMPL TN SFTY CMPL TN 00:30 - 02:30 2.00 CMPL TN OTHR CMPL TN 02:30 - 04:30 04:30 - 07:00 07:00 - 08:30 08:30 - 10:00 10:00 - 12:30 2.00 CMPL TN OTHR CMPL TN 2.50 CMPL TN OTHR CMPL TN 1.50 CMPL TN OTHR CMPL TN 1.50 CMPL TN OTHR CMPL TN 2.50 CMPL TN RUNT CMPL TN 6/20/2002 Spud Date: 6/24/2002 End: Group: Start: Rig Release: Rig Number: 245 Description of Operations Circ through running tool to release diverte r. LID diverter. Pull wear bushing. Rig up test tools f/ weekl y BOPE test. Weekly BOPE test witness waived by AOGCC inspector Chuck Sheve. Test BOPE to low 2 50 psi and high 5000 psi. All tests held f/ 5 minutes. The annular was tested @ 250 psi I ow and 3500 psi high.Tested accumulator. R 10 test equip. Blow down choke manifold. note: Hole took 8.4 bbls during test-- 2.8 b bls per hour. RU to run 4 1/2" ESP completion, with Centr alift pump and Raychem heat trace. PU Baker/Centralift motor assembly to rig fl oor. Assemble motor assembly. Had trouble with filling assembly with oil. Decided to LI 0 and change out intake screen and tandem seal section. Get another seal section and intake screen f I KCS warehouse. Held pre job safety meeting wI Centralift, G BR, Nabors, Phillips Co Rep & Raychem. Assemble new seal section, Finish filling wI oil. check rotation, MU new intake screen. MU motor lead connection. Check continuity, megger motor. LaSalle protectolizer guard f/ motor lead, a nd (2) leads f/ Ph eo nix guage not fitting wel I to hold all three pieces. Wait on decision t 0 run bands to hold guard up tight to body 0 f seal section. Due to inability to hold all t hree lines without bowing the guard and risk ing pinching one of the stainless lines, deci ded to use stainless bands. Total of 6 bands used. Clamp to hold motor lead wires and (2) Ph eo nix guage wires will not fit around the intak e screen body 00 of 5.13" note: Hole has taken 17 bbls in last 7 hours = 2.4 bbl/hou r Pull back up to guard running across inlet s creen opening. Reorient guard so not cover the holes. PU a pup joint (3.82') above the suction screen, so clamp can be installed ac ross a 4 1/2" NSTC collar. Install clamplgua rd on collar of pup joint. Single channel cross coupling clamps that w ere needed, not on location. Wait f/ clamps to arrive. Clamps on location @ 0930 hrs. S et clamps on roof of utility module. PU and MU Pheonix discharge pressure and Ph eon i x t e m per a t u reg u age . When m ad e up- Printed: 8/16/2002 4: 18: 11 PM .~ Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date 7/27/2002 7/28/2002 ALASKA Operations Summary Report 1 C-1 04 1 C-1 04 ROT - DRILLING n1268@ppco.com Nabors 245 From - To Hours Code Sub Phase Code 10:00 - 12:30 12:30 - 16:00 16:00 - 17:30 17:30 - 00:00 00:00 - 01 :30 01 :30 - 02:00 02:00 - 03:30 03:30 - 06:00 06:00 - 07:00 07:00 - 10:00 10:00 - 11 :30 2.50 CMPL TN RUNT CMPL TN 3.50 CMPL TN RUNT CMPL TN 1.50 CMPL TN RURD CMPL TN 6.50 CMPL TN RUNT CMPL TN 1.50 CMPL TN RUNT CMPL TN 0.50 CMPL TN OTHR CMPL TN 1.50 CMPL TN RUNT CMPL TN 2.50 CMPL TN SOHO CMPL TN 1.00 CMPL TN RURD CMPL TN 3.00 CMPL TN OTHR CMPL TN 1.50 CMPL TN SOHO CMPL TN 11 :30 - 14:00 2.50 CMPL TN NUND CMPL TN 14:00 - 15:30 1.50 CMPL TN OTHR CMPL TN 15:30 - 17:00 1.50 CMPL TN RURD CMPL TN 17:00 - 17:30 0.50 CMPL TN OTHR CMPL TN 17:30 - 19:00 1.50 CMPL TN OTHR CMPL TN 19:00 - 20:30 1.50 CMPL TN OTHR CMPL TN 20:30 - 22:00 1.50 CMPL TN OTHR CMPL TN 6/20/2002 Spud Date: 6/24/2002 End: Group: Start: Rig Release: Rig Number: 245 Description of Operations 180 degree out of alignment with ESP motor lead. Break out. Install a 4 1/2", 12.6 31ft, L-80, Huntington NSTC pup joint (3.26') bel ow the pressure sub. MU assembly. Hook up pressure and temp line to Pheonix pressure and temp subs. Test both pressure and temp Ii n e s. RIH wI 4 1/2" ESP completion assembly. Ins tall clamps every other joint. Megger line ev ery row of 4 1/2" tubing ran out of derrick. PJSM. RU to run Raychem heat trace line an d test same. RIH wI 4 1/2" ESP completion string wi heat trace. Install clamps all the way (full joint protection). Megger each row ran out of derr ick. Stand 55 in hole (165 joints) 5210' n ote: hole taking 2.5 bbllhour 9.3 ppg brine. RIH wI 4 1/2" ESP completion string wi heat trace. Install clamps all the way (full joint protection). Megger each row ran out of derr ick to 5990'. Clamping tool fI drawing clamps up tight--no t releasing. Work on tool. RIH wI 4 1/2" ESP completion string wi heat trace. Install clamps all the way (full joint protection). Megger each row ran out of derr ick to 6081'. Install (3) space out pups, MU Vet co gray h anger wi a joint of tubing below hanger fI sp ace out with Raychem heat trace to penetrat or. Megger line, OK. Lay down a stand of 4 1/2",12.6 #/ft, L-80, NSTC tubing fI derrick to pipe shed. Rig do wn ESP and heat trace sheaves and equipme nt fI floor. Splice and install ESP motor lead field conn ector to Penetrator. Megger. OK. Land 4 1/2" ESP completion @ 6172'. Run in lockdown screws. Test upper and lower tubi ng hanger seals to 250 psi low and 5000 psi high fI 15 min each. OK. Lay down landing j oint. PU wt 135 k SO wt 108 K N/D 13 5/8" 5m BOPE. Megger Centralift ESP motor leads and Rayc hem heat trace lines. OK NU Vetco/Gray tree. Megger Centralift ESP motor leads and Rayc hem heat trace lines. OK Test Vetco Tree. No test. Pull tree. Install new seal fI hanger neck. I nstall new API ring. Nipple up Vetco tree. Test tree @ 250 psi low and 5000 psi high fI 10 min. Testing seal neck, penetrations an Printed: 8/16/2002 4: 18: 11 PM ( (' Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date From - To 7/28/2002 20:30 - 22:00 22:00 - 00:00 7/29/2002 00:00 - 01 :00 01 :00 - 03:30 03:30 - 04:00 PHilliPS ALASKA INC. 1 C-1 04 1 C-1 04 ROT - DRILLING n1268@ppco.com Nabors 245 Sub Hours Code Code Phase 1.50 CMPL TN OTHR CMPL TN 2.00 CMPL TN FRZP CMPL TN 1.00 CMPL TN FRZP CMPL TN 2.50 CMPL TN OTHR CMPL TN 0.50 CMPL TN OTHR CMPL TN 6/20/2002 Spud Date: 6/24/2002 End: Group: Start: Rig Release: Rig Number: 245 Description dfOpératibris d API ring @ 5000 psi. Megger lines again. OK. Pull two way check. RU to freeze protect an d pump 145 bbls diesel and "U" tube same. U-tube diesel, Shut in well Tubing & Annulu s press 250 psi, bled back 25 bbls to 150 ps i 0 tubing & annulus. Left 125 bbls in well. Diesel @ 2896' MD, 1970' TVD. 170 psi on t ubing & annulus. Rig down U-tube lines. Rig up lubricator & s et BPV. Megger ESP cable & heat trace line s. Remove Sperry Sun house & Centrilift equ ipment from rig. Rig Down Lubricator, Clean Cellar, put away tools. Rig released from 1c-104 @ 0400 hrs to move to 1c-117. Printed: 8/16/2002 4:18:11 PM AOGCC 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 Re: Distribution of Survey Data for Well 1 C-1 04L 1 Dear Dear Sir/Madam: Enclosed are two survey hard copies and 1 disk Tie-on Survey: 7,001.54' MD Window / Kickoff Survey 7,043.00' MD (if applicable) Projected Survey: 11,539.00' MD Please call me at 273-3545 if you have any questions or concerns. Regards, William T. Allen Survey Manager Attachment( s) ólæ-o~ 05-Aug-02 RECEIVED AUG 0 9 2002 Alaska Oil & Gas Cons. Commission Anchorage Kuparuk/Colville North Slope, Alaska Kuparuk 1 C, Slot 1 C-1 04 1 C-104L 1 Job No. AKZZ22102, Surveyed: 18 July, 2002 SURVEY REPORT 26 July, 2002 ð~~ i¡ !¡Jj I~ /'~\\ Your Ref: API 500292207660 Surface Coordinates: 5968796.65 N, 561631.04 E (70019' 31.0425" N, 149030' 00.8575" W) Kelly Bushing: 101.85ft above Mean Sea Level spe'-'''Y-SUI! DFULLING SÈAVlces A Halliburton Company .~ Survey Ref: svy9938 Sperry-Sun Drilling Services . Survey Report for 1c-104L 1 Your Ref: API 509292207660 D~~ Job No. AKZZ22102, Surveyed: 18 July, 2002 w., #~ Slope, Alaska Kuparuk/Colville . l"?f!rUk 1C Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical . .. Depth Incl. Azim. Depth Depth Northlngs Eastlngs Northlngs Eastlngs Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (o/100ft) 7001.54 76.390 206.030 3569.29 3671.14 1090.09 N 4869.82 W 5969846.70 N 556752.43 E -1090.09 Tie On Point >............" "'7043.00 76.090 203.530 3579.15 3681.00 - 1053.53 N 4886.70 W 5969810.01 N 556735.85 E 5.901 -1053.53 Window Point 7054.28 77.100 203.020 3581.76 3683.61 1043.45 N 4891.04 W 5969799.89 N 556731.60 E 9.976 -1043.45 7086.76 79.420 201.580 3588.37 3690.22 1014.03 N 4903.10 W 5969770.37 N 556719.77 E 8.358 -1014.03 7118.04 83.460 200.220 3593.03 3694.88 985.14 N 4914.13 W 5969741.39 N 556708.98 E 13.612 -985.14 7148.90 85.190 198.900 3596.08 3697.93 956.20 N 4924.41 W 5969712.37 N 556698.94 E 7.039 -956.20 7181.62 89.200 197.500 3597.68 3699.53 925.16 N 4934.62 W 5969681.25 N 556688.99 E 12.979 -925.16 7213.44 90.620 196.150 3597.73 3699.58 894.71 N 4943.83 W 5969650.72 N 556680.03 E 6.157 -894.71 7240.73 92.890 195.000 3596.90 3698.75 868.43 N 4951.15 W 5969624.39 N 556672.92 E 9.324 -868.43 7277.03 92.950 190.250 3595.04 3696.89 833.07 N 4959.07 W 5969588.96 N 556665.29 E 13.069 -833.07 7308.26 90.800 187.600 3594.02 3695.87 802.24 N 4963.91 W 5969558.09 N 556660.71 E 10.923 -802.24 7338.94 89.630 184.490 3593.91 3695.76 771.73 N 4967.14 W 5969527.56 N 556657.73 E 10.830 -771.73 7373.30 88.890 180.810 3594.35 3696.20 737.42 N 4968.73 W 5969493.23 N 556656.42 E 10.924 -737.42 7402.96 91.720 178.110 3594.19 3696.04 707.76 N 4968.45 W 5969463.58 N 556656.94 E 13.187 -707.76 7434.31 92.090 175.780 3593.15 3695.00 676.48 N 4966.78 W 5969432.31 N 556658.87 E 7.521 -676.48 7466.42 93.080 174.020 3591.70 3693.55 644.53 N 4963.93 W 5969400.39 N 556661.98 E 6.284 -644.53 7498.20 94.500 174.320 3589.60 3691.45 612.98 N 4960.71 W 5969368.87 N 556665.46 E 4.566 -612.98 7528.36 94.440 174.340 3587.25 3689.10 583.06 N 4957.74 W 5969338.97 N 556668.68 E 0.210 -583.06 ~, 7592.46 92.590 174.460 3583.32 3685.17 519.39 N 4951.50 W 5969275.36 N 556675.44 E 2.892 -519.39 7623.50 90.740 175.490 3582.42 3684.27 488.49 N 4948.78 W 5969244.47 N 556678.42 E 6.821 -488.49 7717.59 89.690 175.670 3582.07 3683.92 394.68 N 4941.53 W 5969150.73 N 556686.44 E 1.132 -394.68 7760.09 88.770 175.570 3582.64 3684.49 352.31 N 4938.28 W 5969108.39 N 556690.03 E 2.177 -352.31 7812.39 91.420 175.650 3582.55 3684.40 300.16 N 4934.28 W 5969056.28 N 556694.46 E 5.069 -300.16 7906.63 92.280 175.830 3579.51 3681.36 206.23 N 4927.28 W 5968962.41 N 556702.23 E 0.932 -206.23 7940.15 92.650 175.980 3578.07 3679.92 172.83 N 4924.89 W 5968929.03 N 556704.89 E 1.191 -172.83 8001.74 92.830 175.940 3575.12 3676.97 111.46 N 4920.56 W 5968867.70 N 556709.73 E 0.299 -111.46 8094.54 91.230 175.170 3571.84 3673.69 19.01 N 4913.37 W 5968775.30 N 556717.68 E 1.913 -19.01 8189.57 91.110 173.630 3569.90 3671.75 75.55 S 4904.10 W 5968680.83 N 556727.73 E 1.625 75.55 8285.91 91.480 172.590 3567.72 3669.57 171.17 S 4892.54 W 5968585.31 N 556740.07 E 1.146 171.17 8380.67 91.600 171.530 3565.17 3667.02 264.98 S 4879.46 W 5968491.60 N 556753.92 E 1.125 264.98 -.--.--------. -...-----.--..-- 26 July, 2002 - 15:21 Page 2 0(5 DríllQlIest 2.00.08.005 Sperry-Sun Drilling Services . Survey Report for 1C-104L 1 Your Ref: API 500292207660 DS-A"Z Job No. AKZZ22102, Surveyed: 18 July, 2002 KuparuklColville ~J1f~laSka ru k 1 C Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northlngs Eastlngs Northlngs Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (o/100ft) 8475.29 91.230 171.590 3562.84 3664.69 358.55 S 4865.58 W 5968398.15 N 556768.57 E 0.396 358.55 .~ 8570.10 91.230 171.480 3560.80 3662.65 452.31 S 4851.62 W 5968304.51 N 556783.30 E 0.116 452.31 8663.21 91.350 173.580 3558.70 3660.55 544.60 S 4839.52 W 5968212.32 N 556796.15 E 2.259 544.60 8759.50 91.050 172.450 3556.69 3658.54 640.15 S 4827.81 W 5968116.87 N 556808.65 E 1.214 640.15 8852.35 90.800 172.370 3555.19 3657.04 732.17 S 4815.55 W 5968024.95 N 556821.66 E 0.283 732.17 8948.44 90.740 172.570 3553.90 3655.75 827.43 S 4802.96 W 5967929.80 N 556835.04 E 0.217 827.43 9043.31 90.860 178.560 3552.57 3654.42 921.96 S 4195.63 W 5961835.33 N 556843.14 E 6.315 921.96 9138.33 90.180 178.480 3551.71 3653.56 1016.94 S 4193.18 W 5967740.37 N 556846.38 E 0.721 1016.94 9233.11 91.480 178.430 3550.34 3652.19 1111.68 S 4790.62 W 5967645.66 N 556849.71 E 1.373 1111.68 9327.99 92.650 179.040 3546.92 3648.77 1206.47 S 4188.53 W 5961550.89 N 556852.58 E 1.390 1206.47 9422.82 92.400 178.810 3542.74 3644.59 1301.19 S 4786.75 W 5961456.19 N 556855.14 E 0.358 1301 .19 9517.58 91.790 181.270 3539.27 3641.12 1395.88 S 4786.82 W 5961361.50 N 556855.85 E 2.673 1395.88 9600.24 91.970 180.850 3536.56 3638.41 1418.48 S 4788.34 W 5961278.89 N 556855.00 E 0.553 1478.48 9706.07 88.340 181.670 3536.28 3638.13 1584.27 S 4790.67 W 5967173.09 N 556853.54 E 3.516 1584.27 9799.07 89.260 181.850 3538.22 3640.07 1617.20 S 4793.53 W 5961080.13 N 556851.45 E 1.008 1677.20 9892.10 89.200 182.870 3539.47 3641.32 1770.14 S 4791.36 W 5966987.16 N 556848.38 E 1.098 1770.14 9984.31 89.750 181.880 3540.32 3642.17 1862.27 S 4801.18 W 5966895.01 N 556845.32 E 1.228 1862.27 10075.99 88.770 180.970 3541.50 3643.35 1953.91 S 4803.46 W 5966803.35 N 556843.79 E 1.459 1953.91 10168.30 90.000 181.730 3542.49 3644.34 2046.19 S 4805.63 W 5966711.06 N 556842.38 E 1.566 2046.19 10261.13 91.600 182.470 3541.20 3643.05 2138.94 S 4809.03 W 5966618.28 N 556839.74 E 1.899 2138.94 10353.33 91.420 182.080 3538.77 3640.62 2231.04 S 4812.69 W 5966526.16 N 556836.83 E 0.466 2231.04 10445.92 90.310 182.570 3537.37 3639.22 2323.54 S 4816.45 W 5966433.63 N 556833.84 E 1.310 2323.54 10538.87 91.110 182.380 3536.22 3638.07 2416.39 S 4820.46 W 5966340.75 N 556830.59 E 0.885 2416.39 10631.73 90.620 184.040 3534.82 3636.67 2509.09 S 4825.66 W 5966248.01 N 556826.15 E 1.864 2509.09 10694.19 90.740 182.560 3534.08 3635.93 2571.44 S 4829.26 W 5966185.63 N 556823.07 E 2.377 2571.44 10724.30 90.680 182.160 3533.70 3635.55 2601.53 S 4830.50 W 5966155.54 N 556822.07 E 1.343 2601.53 10815.50 92.090 181.560 3531.50 3633.35 2692.65 S 4833.45 W 5966064.39 N 556819.86 E 1.680 2692.65 10908.39 90.860 179.580 3529.11 3630.96 2785.50 S 4834.38 W 5965971.54 N 556819.70 E 2.509 2785.50 11001.20 90.490 180.250 3528.01 3629.86 2878.30 S 4834.24 W 5965818.74 N 556820.60 E 0.825 2878.30 11092.79 90.060 179.900 3527.57 3629.42 2969.89 S 4834.36 W 5965787.16 N 556821.24 E 0.605 2969.89 ~~ ~- --"--.--..--..- ------ 26 July, 2002 - 15:21 Page 3 of5 DrillQlIest 2.00.08.005 Sperry-Sun Drilling Services Survey Report for 1 C-1 04L 1 Your Ref: API 500292207660 Job No. AKZZ22102, Surveyed: 18 July, 2002 KuparuklColville Measured Sub-Sea Vertical Local Coordinates Global Coordinates Depth Inel. Azim. Depth Depth Northlngs Eastlngs Northlngs Eastlngs (ft) (ft) (ft) (ft) (ft) (ft) (ft) 11183.34 88.710 180.310 3528.55 3630.40 3060.43 S 4834.53 W 5965696.62 N 556821.81 E 11277.38 89.570 179.740 3529.96 3631.81 3154.46 S 4834.57 W 5965602.59 N 556822.54 E 11369.60 91.110 179.810 3529.41 3631.26 3246.67 S 4834.20 W 5965510.38 N 556823.66 E 11461.81 91.850 179.000 3527.03 3628.88 3338.85 S 4833.25 W 5965418.22 N 556825.38 E 11470.95 91.910 178.970 3526.73 3628.58 3347.98 S 4833.09 W 5965409.09 N 556825.61 E 11539.00 91.910 178.970 3524.46 3626.31 3415.98 S 4831.86 W 5965341.10 N 556827.40 E All data is in Feet (US) unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to RKB = 101.85' (MSL). Northings and Eastings are relative to 1437' FNL, 625' FWL. The Dogleg Severity is in Degrees per 100 feet (US). Vertical Section is from 1431' FNL, 625' FWL and calculated along an Azimuth of 180.000° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 11539.00ft., The Bottom Hole Displacement is 5917.42ft., in the Direction of 234.741° (True). Comments Measured Depth (ft) Station Coordinates TVD Northings Eastings (ft) (ft) (ft) Comment 7001.54 7043.00 11539.00 3671.14 3681.00 3626.31 1090.09 N 1053.53 N 3415.98 S 4869.82 W 4886.70 W 4831.86 W Tie On Point Window Point Projected Survey ..-.-....----.----- -~._----".'---_..- 26 July, 2002 - 15:21 Page 4 0'5 . Ù«$~~\,,~,~~:s~~ Dogleg Vertical Rate Section Comment (0/100ft) 1.558 3060.43 1.097 3154.46 1.672 3246.67 1.190 3338.85 0.734 3347.98 0.000 3415.98 Projected Survey ~ DrillQuest 2.00.08.005 KuparuklColville Survey tool program for 1C-104L 1 From To Measured Vertical Measured Vertical Depth Depth Depth Depth (ft) (ft) (ft) (ft) 0.00 168.00 0.00 168.00 168.00 11539.00 168.00 Tolerable Gyro (1C-104PB1) 3626.31 AK-6 BP _IFR-AK (1C-104PB1) 26 July, 2002 - 15:21 Sperry-Sun Drilling Services Survey Report for 1C-104L 1 Your Ref: API 500292207660 Job No. AKZZ22102, Surveyed: 18 July, 2002 . '., .;) /~~ ~ . r II. .,,( ~ ;¡ ~bF'(li\ h /1/ .~~¡;.'''~~pe,. Alaska lí".r/I I;uk 1 C ¡¡ '''-"" ~, Survey Tool Description - ~----- --.---- ------_u.---.- . Page 50'5 Dril/Quest 2.00.08.005 AOGCC 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 Re: Distribution of Survey Data for Well 1C-104L 1 MWD Dear Dear Sir/Madam: Enclosed are two survey hard copies and 1 disk Tie-on Survey: 7,001.54' MD Window / Kickoff Survey 7,043.00 I MD (if applicable) Projected Survey: 11,539.00 I MD Please call me at 273-3545 if you have any questions or concerns. Regards, William T. Allen Survey Manager Attachment(s) aoa-00a 05-Aug-02 . (;EtVED 0 9 2002 'iíd~,~ ,,).~ & Gas COns. eommilllan Anœorage ,.(, ,~~ ) ,~ ~ -~ KuparuklColville North Slope, Alaska Kuparuk 1C, Slot 1C-104 1C-104L1 MWD Job No. AKMW22102, Surveyed: 18 July, 2002 SUR VE Y R EP 0 R T 8 August, 2002 Your Ref: API 500292207660 Surface Coordinates: 5968796.65 N, 561631.04 E (70° 19' 31.0425" N, 149030' 00.8575" W) Kelly Bushing: 101.85ft above Mean Sea Level st=1E!I'r"Y-SU" DFULLINS. sèAVIc:es A Halliburton Company Survey Ref: svy9941 Sperry-Sun Drilling Services . Survey Report for 1C-104L 1 MWD Your Ref: API 500292207660 Job No. AKMW22102, Surveyed: 18 July, 2002 North Slope, Alaska KuparuklColville Kuparuk 1 C Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastlngs Northlngs Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (o/100ft) 7001.54 76.390 206.050 3569.33 3671.18 1099.78 N 4862.97 W 5969856.45 N 556759.20 E -1099.78 Tie On Point 7043.00 76.090 203.530 3579.20 3681.05 1063.23 N 4879.85 W 5969819.76 N 556742.62 E 5.948 -1063.23 Window Point 7054.28 77.100 203.020 3581.81 3683.66 1053.15 N 4884.19 W 5969809.65 N 556738.37 E 9.976 -1053.15 7086.76 79.420 201.580 3588.42 3690.27 1023.73 N 4896.25 W 5969780.13 N 556726.54 E 8.358 -1023.73 7118.04 83.460 200.220 3593.07 3694.92 994.84 N 4907.28 W 5969751.15 N 556715.75 E 13.612 -994.84 "~ 7148.90 85.190 198.900 3596.13 3697.98 965.90 N 4917.56 W 5969722.13 N 556705.71 E 7.039 -965.90 7181.62 89.200 198.590 3597.73 3699.58 934.96 N 4928.06 W 5969691.10 N 556695.46 E 12.292 -934.96 7213.44 90.620 197.160 3597.78 3699.63 904.68 N 4937.83 W 5969660.74 N 556685.95 E 6.333 -904.68 7240.73 92.890 195.260 3596.94 3698.79 878.49 N 4945.44 W 5969634.49 N 556678.55 E 10.845 -878.49 7277.03 92.950 191.000 3595.09 3696.94 843.19 N 4953.68 W 5969599.13 N 556670.61 E 11.721 -843.19 7308.26 90.800 188.200 3594.07 3695.92 812.42 N 4958.88 W 5969568.31 N 556665.65 E 11.300 -812.42 7338.94 89.630 185.050 3593.95 3695.80 781.95 N 4962.42 W 5969537.82 N 556662.37 E 10.952 -781.95 7373.30 88.090 101.200 3594.40 3696.25 747.65 N 4964.32 W 5969503.50 N 556660.75 E 11.180 -747.65 7402.96 91.720 178.620 3594.24 3696.09 718.00 N 4964.29 W 5969473.85 N 556661.02 E 13.094 -718.00 7434.31 92.090 175.940 3593.20 3695.05 686.70 N 4962.80 W 5969442.57 N 556662.76 E 8.625 -686.70 7466.42 93.080 174.520 3591.75 3693.60 654.74 N 4960.14 W 5969410.63 N 556665.69 E 5.387 -654.74 7498.20 94.500 174.120 3589.65 3691.50 623.18 N 4957.00 W 5969379.10 N 556669.09 E 4.641 -623.18 7528.36 94.440 173.670 3587.30 3689.15 593.29 N 4953.80 W 5969349.23 N 556672.53 E 1.501 -593.29 7592.46 92.590 173.540 3583.37 3685.22 529.71 N 4946.67 W 5969285.71 N 556680.18 E 2.893 -529.71 7623.50 90.740 175.210 3582.47 3684.32 498.83 N 4943.63 W 5969254.86 N 556683.48 E 8.028 -498.83 7717.59 89.690 175.890 3582.11 3683.96 405.03 N 4936.33 W 5969161.12 N 556691.55 E 1.330 -405.03 7760.09 88.770 176.070 3582.68 3684.53 362.64 N 4933.35 W 5969118.76 N 556694.87 E 2.206 -362.64 7812.39 91.420 176.030 3582.60 3684.45 310.47 N 4929.75 W 5969066.62 N 556698.90 E 5.067 -310.47 7906.63 92.280 176.180 3579.56 3681.41 216.49 N 4923.35 W 5968972.70 N 556706.07 E 0.926 -216.49 7940.15 92.650 176.350 3578.11 3679.96 183.08 N 4921.17 W 5968939.30 N 556708.53 E 1.215 -183.08 8001.74 92.830 176.730 3575.17 3677.02 121.67 N 4917.46 W 5968877.93 N 556712.75 E 0.682 -121.67 8094.54 91.230 176.110 3571.88 3673.73 29.11 N 4911.67W 5968785.42 N 556719.30 E 1.849 -29.11 8189.57 91.110 175.860 3569.94 3671.79 65.66 S 4905.02 W 5968690.70 N 556726.73 E 0.292 65.66 8285.91 91.480 173.090 3567.76 3669.61 161.52 S 4895.74 W 5968594.92 N 556736.79 E 2.900 161.52 8380.67 91.600 172.210 3565.22 3667.07 255.47 S 4883.63 W 5968501.08 N 556749.68 E 0.937 255.47 ~ -- ~- ---._-------- ----_._-~-_._---_.. --- --- 8 August, 2002 - 18:44 Page 2 of5 DrillQuest 2.00.09.003 Sperry-Sun Drilling Services . Survey Report for 1C-104L 1 MWD Your Ref: API 500292207660 Job No. AKMW22102, SU1Veyed~ 18 July, 2002 North Slope, Alaska KuparuklColville Kuparuk 1 C Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azlm. Depth Depth Northlngs Eastlngs Northlngs Eastlngs Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (0/100ft) 8475.29 91.230 172.590 3562.88 3664.73 349.23 S 4871.12W 5968407.42 N 556762.96 E 0.560 349.23 8570.10 91.230 172.150 3560.85 3662.70 443.18 S 4858.53 W 5968313.58 N 556776.31 E 0.464 443.18 8663.21 91.350 175.350 3558.75 3660.60 535.70 S 4848.40 W 5968221.15 N , 556787.21 E 3.438 535.70 8759.50 91.050 174.070 3556.73 3658.58 631.56 S 4839.52 W 5968125.37 N 556796.87 E 1.365 631.56 8852.35 90.800 173.340 3555.23 3657.08 723.83 S 4829.34 W 5968033.18 N 556807.81 E 0.831 723.83 ~ 8948.44 90.740 172.490 3553.94 3655.79 819.18 S 4817.49 W 5967937.93 N 556820.44 E 0.887 819.18 9043.31 90.860 178.570 3552.62 3654.47 913.71 S 4810.10 W 5967843.47 N 556828.60 E 6.409 913.71 9138.33 90.180 178.920 3551.75 3653.60 1008.70 S 4808.02 W 5967748.49 N 556831.47 E 0.805 1008.70 9233.11 91.480 179.640 3550.38 3652.23 1103.46 S 4806.83 W 5967653.75 N 556833.44 E 1.568 1103.46 9327.99 92.650 179.400 3546.96 3648.81 1198.27 S 4806.04 W 5967558.94 N 556835.01 E 1.259 1198.27 9422.82 92.400 179.320 3542.78 3644.63 1293.01 S 4804.98 W 5967464.22 N 556836.84 E 0.277 1293.01 9517.58 91.790 181.640 3539.32 3641.17 1387.69 S 4805.77 W 5967369.53 N 556836.83 E 2.530 1387.69 9600.24 91.970 181.200 3536.61 3638.46 1470.28 S 4807.82 W 5967286.93 N 556835.46 E 0.575 1470.28 9706.07 88.340 182.150 3536.32 3638.17 1576.05 S 4810.91 W 5967181.14 N 556833.24 E 3.546 1576.05 9799.07 89.260 181.800 3538.27 3640.12 1668.97 S 4814.12 W 5967088.20 N 556830.79 E 1.058 1668.97 9892.10 89.200 182.690 3539.52 3641.37 1761.92 S 4817.76 W 5966995.22 N 556827.91 E 0.959 1761.92 9984.31 89.750 182.680 3540.36 3642.21 1854.02 S 4822.08 W 5966903.08 N 556824.35 E 0.597 1854.02 10075.99 88.770 181.730 3541.55 3643.40 1945.63 S 4825.61 W 5966811.45 N 556821.58 E 1.489 1945.63 10168.30 90.000 181.930 3542.54 3644.39 2037.88 S 4828.55 W 5966719.18 N 556819.39 E 1.350 2037.88 10261.13 91.600 182.770 3541.24 3643.09 2130.62 S 4832.36 W 5966626.41 N 556816.34 E 1.947 2130.62 10353.33 91.420 182.490 3538.81 3640.66 2222.69 S 4836.59 W 5966534.31 N 556812.87 E 0.361 2222.69 '''t~' 10445.92 90.310 182.430 3537.42 3639.27 2315.19 S 4840.56 W 5966441.79 N 556809.66 E 1.201 2315.19 10538.87 91.110 182.520 3536.26 3638.11 2408.04 S 4844.58 W 5966348.90 N 556806.41 E 0.866 2408.04 10631.73 90.620 183.870 3534.86 3636.71 2500.74 S 4849.75 W 5966256.16 N 556801.99 E 1.546 2500.74 10694.19 90.740 182.920 3534.12 3635.97 2563.09 S 4853.45 W 5966193.79 N 556798.81 E 1.533 2563.09 10724.30 90.680 182.940 3533.75 3635.60 2593.16 S 4854.99 W 5966163.71 N 556797.51 E 0.210 2593.16 10815.50 92.090 183.000 3531.54 3633.39 2684.21 S 4859.71 W 5966072.62 N 556793.54 E 1.547 2684.21 10908.39 90.860 180.640 3529.15 3631.00 2777.01 S 4862.66 W 5965979.80 N 556791.35 E 2.864 2777.01 11001.20 90.490 180.720 3528.06 3629.91 2869.81 S 4863.76 W 5965886.99 N 556791.01 E 0.408 2869.81 11092.79 90.060 180.450 3527.62 3629.47 2961.39 S 4864.70 W 5965795.40 N 556790.83 E 0.554 2961.39 -- ----.---.---- --~-.._~~- 8 August, 2002 - 18:44 Page 30f5 DrillQuest 2.00.09.003 Sperry-Sun Drilling Services Survey Report for 1C-104L 1 MWD Your Ref: API 500292207660 Job No. AKMW22102, Surveyed: 18 July, 2002 . North Slope, Alaska KuparuklColville Kuparuk 1 C Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (0/100ft) 11183.34 88.710 180.810 3528.59 3630.44 3051.93 S 4865.69 W 5965704.86 N 556790.58 E 1.543 3051.93 11277.38 89.570 179.720 3530.00 3631.85 3145.95 S 4866.13 W 5965610.84 N 556790.92 E 1..4 76 3145.95 11369.60 91.110 179.760 3529.46 3631.31 3238.17 S 4865.71 W 5965518.63 N 556792.09 E' 1.670 3238.17 11461.81 91.850 179.080 3527.07 3628.92 3330.34 S 4864.78 W 5965426.47 N 556793.78 E 1.090 3330.34 11470.95 91.910 178.810 3526.77 3628.62 3339.48 S 4864.61 W 5965417.33 N 556794.02 E 3.025 3339.48 11539.00 91.910 178.970 3524.51 3626.36 3407.47 S 4863.29 W 5965349.35 N 556795.90 E 0.235 3407.47 Projected Survey All data is in Feet (US) unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to RKB = 101.85" (MSL). Northings and Eastings are relative to 1437' FNL, 625" FWL. The Dogleg Severity is in Degrees per 100 feet (US). Vertical Section is from 1437' FNL, 625" FWL and calculated along an Azimuth of 180.000° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 11539.00ft.. The Bottom Hole Displacement is 5938.22ft., in the Direction of 234.983° (True). Comments Measured Depth (ft) Station Coordinates TVD Northings Eastings (ft) (ft) (ft) Comment ~~. 7001.54 7043.00 11539.00 3671.18 3681.05 3626.36 1099.78 N 1063.23 N 3407.47 S 4862.97 W 4879.85 W 4863.29 W Tie On Point Window Point Projected Survey ---- ----.--------- 8 August, 2002 - 18:44 Page 4 of5 DriJIQuest 2.00.09.003 KuparuklColville Survey tool program for 1C-104L 1 MWD From Measured Vertical Depth Depth eft) eft) '>~ 0.00 168.00 0.00 168.00 168.00 11539.00 168.00 Tolerable Gyro (1C-104PB1 MWD) 3626.36 MWD Magnetic (1C-104PB1 MWD) ~~ 8 August, 2002 - 18:44 To Measured Vertical Depth Depth (ft) (ft) Sperry-Sun Drilling Services Survey Report for 1C-104L 1 MWD Your Ref: API 500292207660 Job No. AKMW22102, Surveyed: 18 July, 2002 Survey Tool Description ------'--- Page 5 of5 . North Slope, Alaska Kuparuk 1 C ~---_._._--- DrillQuest 2.00.09.003 a~-OlQ~, (r 07 8' WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Co. Attn.: Lisa Weepie 3 33 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 September 16, 2002 RE: MWD Formation Evaluation Logs lC-104 Ll, AK-MW-22102 1 LDWG formatted Disc with verification listing. PlPI#: 50-029-23076-60 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COpy OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Service Attn: Jim Galvin 6900 Arctic Blvd. Anchorage, Alaska 99518 Date: Si~~~ R 12C€IVED S£p 2 ? AI-aO;i -, 2002 & Gas ¡" 11- "-'Of/s r,- ",ICh"^,, . ""(,'ll!llJit:#o' '>"dUe gtillOn ~J~1Jf illJ~ ( /þ) n r&\\ ~.~ ~ Œ.\ ú u Lbfßù @ U~Lr\J ( ATtASIiA. OIL AND GAS CONSERVATION COlWlISSION TONY KNOWLES, GOVERNOR 333 W. ]TII AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Chuck Mallary Drilling Engineering Supervisor Phillips Alaska, Inc. PO Box 100360 Anchorage AK 99510 Re: Kuparuk River Unit lC-104Ll (Revised) Phillips Alaska, Inc. Permit No: 202-062 Surface Location: 1437' FNL, 625' FWL, Sec. 12 TI1N, RI0E, UM Bottom hole Location. 412' FSL, 1083' FWL, Sec. 11, TIIN, RI0E, UM Dear Mr. Mallary: Enclosed is the revised approved application for permit to drill the above referenced well. The permit to drill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. This permit to drill is a revision to the top of productive interval of the previously approved Permit'No. 202-062, API 50-029-23076. The TD remains unchanged. The change of directional plan is based on information obtained drilling the 1 C-l 04 wellbore. Production should continue to be reported as a function of the original API number stated above. Annular disposal of drilling wastes will not be approved for this well until sufficient data is submitted to ensure that the requirements of 20 AAC 25.080 are met. Annular disposal of drilling waste will be contingent on obtaining a well cemented surface casing confirmed by a valid Formation Integrity Test (FIT). Cementing records, FIT data, and any CQLs must be submitted to the Commission for approval on form 10-403 prior to the start of disposal operations. Please note that any disposal of fluids generated from this drilling operation which are pumped down the surface/production casing annulus of a well approved for annular disposal on Kuparuk River Unit 1 C must comply with the requirements and limitations of 20 AAC 25.080. Approval of this permit to drill does not authorize disposal of drilling waste in a volume greater than 35,000 barrels through the annular space of a single well or to use that well for disposal purposes for a period longer than one year. Permit No. 202-062 July 9, 2002 Page 2 of2 { ( Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25 035. Sufficient notice (approximately 24 hours) must be given to allow a representative of the Commission to witness a test ofBOPE installed prior to drilling new hole. Notice may be given by contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. Sincerely, b' ~'~ Cammy echsli Taylor Chair BY ORDER OF THE COMMISSION DATED thi~day of July, 2002 jjc/Enclosures cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. 1 b. Type of well. Exploratory D Stratigraphic Test D Service D Development Gas D Single Zone 0 5. Datum elevation (DF or KB) RKB 41 feet 6. Property Designation Kuparuk River Field ADL 25649 ALK 467 West Sak Oil Pool 7. Unit or property Name 11. Type Bond (see 20 MC 25.0251) Kuparuk River Unit Statewide 8. Well number/ Number 1 C-1 04L 1 #59 52 180 9. Approximate spud .date Amount July 3, 2002 j $200,000 14. Number of acres in property 15. Proposed depth (MD and TVD) 2560 11539' MD / 3633' TVD 17. Anticipated pressure (seer MC 25.035 (e)(2)) Maximum surface 1290 psig At total depth (TVD) 1696 psig Setting Depth ( STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 1a. Type of work: Drill 0 Redrill D Re-entry DDeepen D 2. Name of Operator Phillips Alaska, Inc. 3. Address P.O. Box 100360 Anchorage, AK 99510-0360 4. Location of well at suriace 1437' FNL, 625' FWL, Sec. 12, T11N, R10E, UM At top of productive interval 387' FNL, 1017' FWL, Sec. 11, T11 N, R10E, UM At total depth 412' FSL, 1083' FWL, Sec. 11, T11 N, R10E, UM 12. Distance to nearest property line 13. Distance to nearest well 412' @ TD feet 1C-104 ( 16. To be completed for deviated wells Kickoff depth: 7045' MD 18. Casing program size feet Maximum hole angle 920 Top Bottom TVD Hole Casing Specifications Grade Coupling Length MD TVD MD Weight 9.875" 6.75" L-80 L-80 BTC Mod HSLHT 41' 7045' 41' 3681' 7400' 3741' 11539'1' .. 3633' 7359' 4494' 7.625" 29.7# 9.5# 4" 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total Depth: measured true vertical feet feet Plugs (measured) Effective Depth: measured true vertical feet feet Junk (measured) Casing Conductor Surface Intermediate Production Liner Size Cemented Measured depth Length Perioration depth: measured true vertical \¡J6/t- 7/,/0 L ~ -¡{:¡/~ Development Oil 0 Multiple Zone D 10. Field and Pool Quantity of Cement (include stage data) 810 sx AS Lite, 290 sx Class G screen True Vertical depth RECEI\fED iJUL 2 2002 Alaska QiI.& Gas Cons. GommlssÎon Anchorage 20. Attachments Filing fee 0 Property Plat D BOP Sketch D Diverter Sketch D Drilling program 0 Drilling fluid program 0Time vs depth plot Qefraction analysis DSeabed report D 20 AAC 25.050 requirements 0 21. I hereby certify that the foregoing is true and correct to the best of my knowledge Questions? CallI om Brockway 263-4135 Signed "í \ ~ ~~ Title: Kuparuk Drilling Team Leader Randy Thomas . \ Commission Use Only Permit Number I API number 3 L' I Approval date 3/" . 1"'\. 2.ð 2. - n t:. 2- 50- ð.2. 9'" 2. 07& - t:Jð }'-I b (/\ Conditions of approval Samples required D Yes ]X] No Mud log required Hydrogen sulfide measures D Yes ~ No Directional survey required ~ Yes Required working pressure for BOPE D2M; D 3M; D 5M; D 10M; D D Other: Të<;t- ßD P 6 ~ .) 000 (ls"'~.. Onglnal Slgnedl3y Cammy Oechsli Taylor Approved by Commissioner by order of the commission Form 10-401 Rev. 12/1/85. ,. R.., ." .7 .~ ~ ~/l1¡j Date 7 ( 2....( O? PrAnArArl hv ShAmn AI/.<mn-nrAkA Isee cover letter for other requirements DYes 31 No D No Date 1, q 0" L Submit in triplicate Appliç::ation for Permit to Drill, Well 1 C-1 04 ( Revision No.2 Saved: 2-Jul-02 Permit It - West Sak Well #1 C-1 04 L 1 Application for Permit to Drill Document Ml)ximizE Well \!gl\JE¡ Table of Contents 1. Well Name.... .......... ..... ........ ..... ..... .................. ............ ...... ... .............. ........... ........ .... 2 Requirements of 20 AAC 25.005 (f).................................... ....................................................................2 2. Location Summary....... ........ ........ ......... .......... ..... ...... .... .......... ............ ... ... .............. 2 Requirements of 20 AAC 25.005(c)(2) .. ...................................... .................................... ....................... 2 Requirements of 20 AAC 25. 050(b)........................................................................................................ 3 3. Blowout Prevention Equipment Information ......................................................... 3 Requirements of 20 AAC 25. 005( c)(3) ............................... ................. .................. ....... .......................... 3 4. Dri II i ng Hazards Information ............. ..................... ....... ... ........ ... ... ......................... 3 Requirements of 20 AAC 25.005 (c)( 4) ..............................................,........ ............... ............................ 3 5. Procedure for Conducting Formation Integrity Tests ........................................... 3 Requirements of 20 AAC 25.005 (c)(5) ...................................... ...................................................... ...... 3 6. Casing and Cementing Program ..... ............ ............................................................4 Requirements of 20 AAC 25. 005( c)(6) ................................................................................................... 4 7. Diverter System Information........................... ................ ............................... ..... .... 4 Requirements of 20 AAC 25. 005( c)(7) ................................................ ................................................... 4 8. Dri II i ng FI u id Program........... ....... ........................ ... .......... ........ ............. ................. 4 Requirements of 20 AAC 25. 005( c)(B) ""'"'''''''''''''''''''''''''''' ............. ...................................... ............. 4 9. Abnormally Pressured Formation Information ...................................................... 5 Requirements of 20 AAC 25.005 (c)(9) ........................................ .......................................................... 5 10. Seismic Analysis..... ................................................ .... .... ... ...... ..... ..... ..... ................. 5 Requirements of 20 AAC 25.005 (c)(1 0) ................................................................................................ 5 11. Seabed Condition Analysis .....................................................................................5 Requirements of 20 AAC 25.005 (c)(11) ..................... ........ ................................................................... 5 12. Evidence of Bond i ng .... ..................... ............... ........... ... .... ....... ............. ........ ......... 5 Requirements of 20 AAC 25.005 (c)(12) ................................................................................................ 5 OW. "~........ ,..' I . ~ 1C-104L 1 PERMIT /T ver.2 7-1-02.doc Page 1 of 7 Printed: 2-Jul-02 ~ ä ~ ( Applic~tion for Permit to Drill, Well 1 C-1 04 ( Revision No.2 Saved: 2-Jul-02 13. Proposed Dri Iii ng 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 ........ .... ..... .......... ........... ....... ... ..... ..... .................................... ...... ... ...... 7 Attachment 1 Directional Plan (6 pages) """"''''''''''''''''''''''''''''''''''''''''''''''''''''''''''''''......................... 7 Attachment 2 Drilling Hazards Summary (1 page) ................................................................................7 Attachment 3 Well Schematics (2 pages) .............................................................................................. 7 1. Well Name Requirements of 20 AAC 25.005 (f) Each wel! must be Identitìed by a unIque name desIgnated by the operator and a unIque API number assIgned by the cÔmmlssion under 20 AAC 25: 040(b). For a well with multiple well branche5~ each branch must sírmla/~v be Identified by a unIque name and API number by adding a suftìx to the name designated for the well by the operator and to the number assigned to the well by the commi!:)'slon. The well for which this Application is submitted will be designated as lC-l04 L1. 2. Location Summary Requirements of 20 AAC 25.oo5(c)(2) An application far a Permit to Dr/I! must be accompanied by each of the followIng Items, except for an Item already on file with the camrm:5.5ion and identified in the application: (2j a plat identifying the property and tile pr()pertY~5 owners and s1lowing (A)the coordinates of the proposed location of the well at the sl1Iface/ at the top of each objeälve törmatkJf}, and at total depth, referenced to governmental seälon line5~ (B) the coordInates or the proposed locatIon of the well at the surface; referenced to the state plane coordinate system for thIs state as maIntained by the National L7eodetic Survey in the National OceanIc and Atmospheric Administration; (C) the proposed depth of the ¡Iv'ell at the top of each objectIve formation and at total depth; Location at Surface NGS Coordinates Northings: 5,968,796.65 Eastings: 561,631.04 1437' FNL, 625' FWL, Section 12, TllN, Rl0E, UM RKB Elevation 101.8' AMSL Pad Elevation 60.8' AMSL Location at Top of Productive Interval (West Sak "D" Sand) NGS Coordinates Northings: 5,969,808.18 387' FNL, 1017' FWL, Section 11, TllN, Rl0E, UM Eastings: 556,735.06 Measured Depth, RKB: Total Vertical Depth, RKB: Total Vertical Depth, 55.' 7045 3681 3580 Location at Total Depth NGS Coordinates Northings.' 5,965,328 Eastings.' 556,840 412' FSL, 1083' FWL, Section 11, TllN, Rl0E, UM Measured Depth, RKB: 11539 Total Vertical Depth, RKB: 3633 Total Vertical Depth, 55: 3531 and (D) other information requIred by 20 AAC2S.050{bj/ 1C-104L 1 PERMIT IT ver.2 7-1-02.doc JRI ,,\t~ 3 A.. ¡ . Page2of7 . . U ,f; L Pnnted: 2-Jul-02 Application for Permit to Drill, We1l1C-104 (Revision No.2 : Saved: 2-Jul-02 Requirements of 20 AAC 25.050(b) If a well is to be intentionally deviatect the application for a Permit to Drill (Fonn 10-401) must (1) incJude a plat drawn to a suitable scale" shovving the path of the proposed wellbore" incJuding all adjacent wellbores within 200 feet of any portion of the proposed vv'ell,,' Please see Attachment 1: Directional Plan and (2) for all weJJs within 200 feet of the proposed wel/tvre (A) list the names of the operators of those we/Is" to the extent that those names are known or discoverable in public record~ and sho}t' that each named operator has been furnished a copy of the application by ce!tlfìed ma¡~' or (B) state that the applicant is the only affeäed 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 f..l')r an item already on file with the commission and identified in the application: (3) a diagram and descfiption otthe blowout prevention equipment (BOPE) as required by 20 AAC 25:035~ 20 AAC 25 036" or 20 AAC 25.037;. as applicable; An API 13-5/8" x 5,000 psi BOP stack will be utilized to drill and complete welllC-l04 Ll. Please see "Diagram and Description of the Blowout Prevention Equipment for Nabors Rig 245e", placed on file with the Commission. 4. Drilling Hazards Information Requirements of 20 AAC 25.005 (c)(4) An application for a Po/771ft to Drill must be accompanied by each of the following item", exæpt for an Item already on file with the commission and identified in the application: (4) information on drilling hazard.s"" inäuding (A) the maximum downhole pressure that may be encountered" criteria used to determine ìt; and maximum potential surface pressure based on a rnethane gj"adient~' The expected reservoir pressures in the West Sak sands in the lC pad area vary from 0.41 to 0.46 psi/ft, or 7.8 to 8.8 ppg EMW (equivalent mud weight). These are pressures obtained from actual well test data from the nearby lC-lll, lC-125, and lC-121 wells. The maximum potential surface pressure (MPSP) based on the above maximum pressure gradient, a methane gradient (0.11) and the vertical depth of the expected base of the West Sak formation is 1290 psi, calculated thusly: MPSP =(3687 ft)(0.46 - 0.11 psi/ft) = 1290 psi ¡ (8) data on potentÙ11 gas zones~' The well bore is not expected to penetrate any gas zones. and (C) data concerning potential causes of hole problems siJeh as abnormally geo-pressured stratal lost circulation zones" and zones that have a propensity for differential sticking,," Please see Attachment 2: Drilling Hazards Summary. 5. Procedure for Conducting Formation Integrity Tests Requirements of 20 AAC 25.005 (c)(5) An application for a Permit to Drill must be accompanied by ead¡ of the ro/lovdng ¡fem5~ except tor an /tern already on file with ihe commission and identified in the applìcatlon: (5) a descrìption or the procedure for ønduäing formation integríty tests" as required under 20 AAC 25,030(1),,' lC-l04 Ll will be completed with 7-5/8" surface casing landed in the West Sak B-Sand, which was permitted as lC-l04. A whipstock will be set to mill a window in the 7 5/8" casing at the top of the West OR. lJ './$111tt,..." l.~' '104 ¡ 1C-104L 1 PERMIT IT ver,2 7-1-02.doc Page 3 of 7 Printed: 2-Jul-02 L Applic;ation for Permit to Drill, We1l1C-104 (Revision NO.2 i Saved: 2-Jul-02 Sak D-Sand. A formation integrity test will be performed in accordance with the "Formation Integrity Test Procedure" that Phillips Alaska placed on file with the Commission. 6. Casing and Cementing Program Requirements of 20 AAC 25.005(c)(6) An applIcatIon for a Permit to Drill must be accompanIed by each of the follovting Item~ except for an Item a!readyon file wIth the commissIon and Identífied In the application: (6j a complete proposed casing and cementing program as required by 20 MC 25.030/ and a descriptIon of any slotted liner; pre- perforated liner; or screen to be installecf' Casing and Cementing Program Hole Top Btm Csg/Tbg Size Weight Length MOfTVO MOfTVO 00 (in) (in) (Iblft) Grade Connection (ft) (ft) (ft) Cement Program 16 24 62.5 H-40 Welded 120 41/41 161 / 161 Cemented to surface with 225 cf ArcticSet 1 7-5/8 9-7/8 29.7 L-80 STCM 7359 41/41 7400/3741 Cemented to Surface with 810 sx ASLite Lead, 290 sx Class G Tail 4 6-3/4" 9.5 L-80 HSLHT 4494 7045/ 3681 11539 / 3633 Screens - screen Upper Inflate ECP Lateral with cement 7. Diverter System Information Requirements of 20 AAC 25.005(c)(7) An application for a Pem7lt to Drill must be accompanied by each of the following item::'~ except fQr an item already on file with the cvmmls:,,1ofl and identilìed in the application: (7j a diagram and desaiption of the diverter system as requIred by 20 AAC25,03.5~ unless this requirement is waived by the commissIon under 20 AAC25.035(h)(2); A diverter system will not be used while drilling the West Sak "D" lateral. 8. Drilling Fluid Program Requirements of 20 AAC 25.005(c)(B) An application for a Permit to Drill must be accompanied by each of the tò!lowlng Item~ except for an Item alrear.1v on tï!e with the commÎ!,,:>ion and identitled 1Í1 the applk'(-]tlon: (8) a drilling fluid program/ including a diagram and description of the drilling f7uid systen& as required by 20 MC 25, 033,' Drilling will be done with a SaradrilN mud system having the following properties over the listed intervals: Density (ppg) Funnel Viscosity (seconds) Yield Point (cP) Plastic Viscostiy (lb/l00 sf) D sand lateral Initial Value Final value/ 8.9-9.0 / 8.9-9.0 45-60 45-60 18-25 18-25 8-14 8-14 C i/GI 1 C-1 04L 1 PERMIT IT ver.2 7-1-02.doc Page 4 of 7 Printed: 2-Jul-02 ¡ ¡ j. Appliçation for Permit to Drill, Well 1 C-1 04 (Revision No.2 ..... Saved: 2-Jul-02 Tau 0 Chlorides pH API filtrate **HTHP filtrate MBT ***Solids ppb ** HTHP to be run at 800 F 4-7 13-15K 8-8.5 <6 <10 <2.5 <12 4-7 13-15K 8-8.5 <6 <10 <2.5 <12 *** The drilled LGS Drilling fluid practices will be in accordance with appropriate regulations stated in 20 AAC 25.033. This drilling fluid system of Nabors Rig 245e consists of: (3) Continental Emsco FB-1600 Mud Pumps, Steel Mud pits with 1100 barrel capacity, Pill Pit, Trip Tank, (3) Derrick Flo-line Shale Shakers (rated at 600 gpm), Brandt Model SRS-2 Desander, Derrick Model 58S Mud Cleaner, (2) Alpha-Laval Model 418-VT- 5 Centrifuges, Degassers, PVT System with visual and audio alarms, Trip Tank, Flow Sensor, and Fluid Agitators. Please see "Diagram of Mud System, Nabors Rig 245e", placed on file with the Commission. 9. Abnormally Pressured Formation Information Requirements of 20 AAC 25.005 (c)(9) An application for a Perrnit to Dnll must be af.-Tompanied by each of the following item~ except for an item already 0/7 t7fe Htith the commission and Identified in the application: (9ì for an exploratory or strat~qraphic test ¡'¡e/~ a tabulation s--etting out the depths of predicted abnormally geo..pressured strata as requíred by 20 AAC 25.033(f); Not applicable: Application is not for an exploratory or stratigraphic test well. 10. Seismic Analysis Requirements of 20 AAC 25.005 (c)(10) An application fòr a Permit to Dnll must be accompanied by each of the to/lowing item~ except tor an item already 0/7 file wIth the commission and Identified //7 the application: (10) for an exploratory or stratigraphic test wel¿ a seismic refraction or reflection analysis as required by 20 AAC 25,061(a); Not applicable: Application is not for an exploratory or stratigraphic test well. 11. Seabed Condition Analysis Requirements of 20 AAC 25.005 (c)(11) An application tor a Pmmlt to Drill must be accompanied by each at the following Item.~ except fòr an item already on file with the commission and identified in the application: (11) for a well drilled from an offshore platform, mobile bottom-founded structure, jack"up rig, or floating drilling vesse¿ an analy!:;"!.,;; of seabed cvnditìof}s as required by 20 AAC 25: 061 (b); Not applicable: Application is not for an offshore well. 12. Evidence of Bonding Requirements of 20 AAC 25.005 (c)(12) An application for a Permit to Drill must be accvmpanied by each at the fòllowing Items~ except fòr an Item already on file with the commission and identified in the appliCt.7tion: (12) evidence ShowlÌ7g that the requirement<; of20 AAC 25, 025 {BondIÌ7g}l7ave been met; Evidence of bonding for Phillips Alaska, Inc. is on file with the Commission. 13. Proposed Drilling Program Requirements of 20 AAC 25.005 (c)(13) An application for a Perrnit to Drill must be accompanied by each of the to/lowing item~ except t'or an item already on file ¡"lith the comm/:,-;;,ion and identified in the application: 0 ~ ,ï I Vi j if, J. 1C-104L 1 PERMIT IT ver.2 7-1-02.doc Page 5 of 7 Printed: 2-Jul-02 Appliç<'\tion for Permit to Drill, We1l1C-104 ( Revision NO.2 Saved: 2-Jul-02 The proposed drilling program is listed below. Please refer also to ~ttachment 3, Well Schematics. This procedure will begin upon completion of the lower lateral, lC-l04. 1. Run and set Baker WindowMasterTM whipstock, 30 degrees to left of high side. 2. Mill starting window with the top of the window located at the top of the D-sand. POOH. 3. Polish and complete window with finishing mill and 2 watermelon mills. 4. Pick up 6-3/4" drilling assembly, RIH, and drill 20-50 feet of new hole. 5. Perform Formation Integrity Test to 12.5 ppg EMW. 6. Clean pits and change over to BaraDril'N drilling mud. 7. Continue to directionally drill to TD of D sand lateral at 11,539' MD / 3,633' TVD. POOH. 8. POOH and lay down MWD, LWD and PWD tools. 9. If needed, RIH with 6" hole opener and ream open hole. 10. Circulate and condition hole to run liner. Displace mud with clean filtered kill weight brine and spot viscosified brine across open hole. POOH and lay down hole opener assembly. 11. RIH with whipstock retrieval tool and casing sea per assembly to whipstock. Perform casing and drill pipe clean-up including Caustic SL Wash and Acid Pickle. Displace casing with kill weight brine. Retrieve whipstock and POOH. 12. PU 4" Liner with flanged hook hanger, ECP and excluder screen and 2-7/8" inner wash string. 13. RIH, until Hook Hanger is just above window. Run gyro tools to orient hook hanger to window and land hanger. 14. Release hanger running tool and place cup tool across ECP and inflate with cement. Reverse out excess cement and POOH. 15. Pick up lateral diverter tool and RIH and set in hook hanger. 16. RIH with cup tool assembly and spot 10% HCI Acid through the screens and allow acid to soak 6 hours. Displace acid with clean filtered brine. POOH, laying down Drill pipe as needeçl. 17. Make up lateral diverter retrieving tool and RIH on 4-1/2" completion tubing( Once at diverter, run dummy ESP through tubing string on wireline. Retrieve diverter, and POOH, standing back tubing. 18. Make up ESP and components as required and RIH. Run heat trace on tubing through permafrost zone. 19. Land tubing with ESP +/- 60 feet above window. Install BPV, nipple down stack, nipple up and test tree. Pull BPV. Freeze protect well with diesel by pumping into annulus, taking returns from tubing and allowing to equalize. 20. Set BPV and move off. 14. Discussion of Mud and Cuttings Disposal and Annular Disposal Requirements of 20 AAC 25.005 (c)(14) An app/ìcatìon for a PermIt to Dli/I mustc be accompanìed by each of the fo/lowlng Items~ e>(cept for an Item already on tile with the commlS5'Ìon and ¡dentltied In the app//cat/on: (14) a general descriptIon of how the operator plans to dispose of dnlllng mud and cuttings and a statement of whether the operator intends to request atlthoríz.:;¡t/on under 20 AAC 25.080 for an annular dt:'iposal ope¡::;¡t/on ìn the we/!./ Waste fluids generated during the drilling process will be disposed of either by pumping authorized fluids into a permitted annulus on lC 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 lC Pad or hauled to the Prudhoe Bay C,i.'GINAL 1C-104L 1 PERMIT IT ver.2 7-1-02.doc Page 6 of 7 Printed: 2-Jul-02 ( APP(I.i...,q~tion for Permit to Drill, We1l1C-104 Revision NO.2 Saved: 2-Jul-02 Grind and Inject Facility for temporary storage and eventual processing for injection down an approved disposal well. Phillips Alaska does not intend to 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 Schematics ~ ,1/ G I 1C-104L 1 PERMIT IT ver.2 7-1-02.doc Page 7 of 7 Printed: 2-Jul-02 L C) ::J:J ~ ~ --....."" ):~ r--- ~;; .~ Kuparuk"River Unit North Slope, Alaska Kuparuk 1C, Slot 1C-104 Plan: 1C-104 - 1C-104 L1 (wp05) Revised: 1 July, 2002 PROPOSAL REPORT 1 July, 2002 c~ Your Ref: Tied into Rig Surveys Surface Coordinates: 5968796.65 N, 561631.04 E (70019' 31.0425" N, 149030' 00.8575" W) Surface Coordinates relative to Project H Reference: 968796.65 N, 61631.04 E (Grid) Surface Coordinates relative to Stucture Referance: 280.27 N, 738.73 W (True) Ke/Iy Bushing: 101.80ft above Mean Sea Level sper''-'Y:-IiLJr1 a1B~íIg;.Ib:IB:.:::,'.:,I!R::2:1:=:.:. A li.ttW4H$!1 ~ïjj~1f Proposal Ref: pr09919 Sperry-Sun Drilling Services Proposal Report for Plan: 1 C-1 04 - 1 C-1 04 L 1 (wp05) Your Ref: Tied into Rig Surveys Revised: 1 July, 2002 Kuparuk River Unit Measured Sub-Sea Vertical Local Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) OOft) 7045.00 76.080 203.410 3579.64 3681.44 1051.71 N 4887.50 W -1051.71 Top of Whipstock in 7-5/8" Csg (To West Sak D) : 7045.00ft MD, 3681.44ft TVD 7-5/8" Csg Window .~, 7057.00 77.959 203.071 3582.34 3684.14 1040.97 N 4892.12 W 556730.54 E 15.900 -1040.97 Begin Rathole in 6-3/4" Hole: 7057.00ft MD, 3684.16ft TVD 7075.00 77.959 203.071 3586.09 3687.89 1024.77 N 4899.02 W 5969781.15 N 556723.77 E 0.000 -1024.77 Begin Dir @ 14.00/1 OOft : 7075.00ft MD, 3687.89ft TVD 7100.00 79.542 199.888 3590.97 3692.77 907.99W 5969758.26 N 556714.99 E 14.000 -1001.96 7200.00 86.136 187.434 3603.48 3705.28 931.29 W 5969661 .89 N 556692.48 E 14.000 -905.77 7282.01 91.691 177.380 3605.03 3706.83 4934.72 W 5969580.08 N 556689.72 E 14.000 -823.99 End Dir, Start Sail @ 91 .690 : 7282.01ft MD, 3706.83ft TVD 7300.00 91.691 177.380 3604.50 3706.30 4933.90 W 5969562.12 N 556690.69 E 0.000 -806.02 7400.00 91.691 177.380 3601.55 3703.35 4929.33 W 5969462.31 N 556696.08 E 0.000 -706.17 7500.00 91 .691 177.380 3598.60 3700.40 4924.76 W 5969362.50 N 556701 .47 E 0.000 -606.32 7600.00 91.691 177.380 3595.65 3691}45 4920.19 W 5969262.69 N 556706.85 E 0.000 -506.47 7700.00 91 .691 177.380 592.7-0.". 3694.50 406.62 N 4915.62 W 5969162.88 N 556712.24 E 0.000 -406.62 7800.00 91 .691 177.380 9.75 3691 .55 306.76 N 4911 .06 W 5969063.07 N 556717.63 E 0.000 -306.76 C 7900.00 91.691 177.380 86.79 3688.59 206.91 N 4906.49 W 5968963.26 N 556723.02 E 0.000 -206.91 8000.00 91.691 177.380 3583.84 3685.64 107.06 N 4901.92 W 5968863.45 N 556728.41 E 0.000 -107.06 :x::J 8100.00 91.691 177.380 3580.89 3682.69 7.21 N 4897.35 W 5968763.64 N 556733.80 E 0.000 -7.21 ~ ~ 8200.00 91.691 177.380 3577.94 3679.74 92.64 S 4892.78 W 5968663.82 N 556739.18 E 0.000 92.64 ,-"". 8300.0 91 :S'91 \FP177.380 3574.99 3676.79 192.50 S 4888.21 W 5968564.01 N 556744.57 E 0.000 192.50 ............. 8400.0 91.691 177.380 3572.04 3673.84 292.35 S 4883.64 W 5968464.20 N 556749.96 E 0.000 292.35 ;c::: 8500.00 91.691 177.380 3569.09 3670.89 392.20 S 4879.08 W 5968364.39 N 556755.35 E 0.000 392.20 ~ 8600.00 91.691 177.380 3566.13 3667.93 492.05 S 4874.51 W 5968264.58 N 556760.74 E 0.000 492.05 r-- 8700.00 91.691 177.380 3563.18 3664.98 591.90 S 4869.94 W 5968164.77 N 556766.13 E 0.000 591.90 8800.00 91.691 177.380 3560.23 3662.03 691.76 S 4865.37 W 5968064.96 N 556771.51 E 0.000 691.76 8900.00 91.691 177.380 3557.28 3659.08 791 .61 S 4860.80 W 5967965.15 N 556776.90 E 0.000 791.61 9000.00 91.691 177.380 3554.33 3656.13 891.46 S 4856.23 W 5967865.34 N 556782.29 E 0.000 891.46 9100.00 91.691 177.380 3551.38 3653.18 991.31 S 4851.67 W 5967765.52 N 556787.68 E 0.000 991.31 1 July, 2002 - 17:16 Page 2 of5 DrillQuest 2.00.09.006 Sperry-Sun Drilling Services Proposal Report for Plan: 1C-104 -1C-104 L 1 (wp05) Your Ref: Tied into Rig Surveys Revised: 1 July, 2002 Kuparuk River Unit Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) OOft) 9200.00 91 .691 177.380 3548.43 3650.23 1091.16 S 4847.10 W 5967665.71 N 556793.07 E .0.000 1091.16 9220.90 91.691 177.380 3547.81 3649.61 1112.03 S 4846.14 W 5967gá~.85 N ,",,,,,556794.19 E 0.000 1112.03 Begin Dir @ 3.00/100ft : 9220.90ft MD, 3649.61ft TVD 9300.00 90.832 179.593 3546.07 3647.87 1191 .08 S 5560/96.93 E 3.000 1191 .08 - 9304.83 90.780 179.728 3546.00 3647.80 1195.91 S 556797.00 E 3.000 1195.91 TARGET (D-Mid Pt) End Dir, , Sail @ 90.78° : 9304.83ft MD, 3647.80ft TVD Target - 1 C-1 04 (D-Mid-Pt), Curren1 Target 9400.00 90.780 179.728 3544.70 3646.50 5967465.84 N 556798.23 E 0.000 1291 .07 9500.00 90.780 179.728 3543.34 3645.14 5967365.86 N 556799.53 E 0.000 1391.06 9600.00 90.780 179.728 3541 .98 3643.78 5967265.88 N 556800.83 E 0.000 1491.05 9700.00 90.780 179.728 3540.62 3642.42 5967165.90 N 556802.12 E 0.000 1591.04 9800.00 90.780 179.728 3539.26 3641 .06 5967065.91 N 556803.42 E 0.000 1691 .03 9900.00 90.780 179.728 3537.90 3639.70 5966965.93 N 556804.71 E 0.000 1791.02 .~:,:;s~~~.::~~t~1: 10000.00 90.780 179.728 3536.54 3638.34 1891 .01 S 4840.73 W 5966865.95 N 556806.01 E 0.000 1891 .01 10100.00 90.780 179.728 35.t8. 3636.98 1991.00 S 4840.25 W 5966765.97 N 556807.31 E 0.000 1991 .00 10200.00 90.780 179.728 3.82 3635.62 2090.99 S 4839.78 W 5966665.98 N 556808.60 E 0.000 2090.99 <:::> 10300.00 90.780 179.728 2.46 3634.26 2190.98 S 4839.30 W 5966566.00 N 556809.90 E 0.000 2190.98 10400.00 90.780 179.728 3531 .1 0 3632.90 2290.97 S 4838.83 W 5966466.02 N 556811 .19 E 0.000 2290.97 :Jl:J 10500.00 90.780 179.728 3529.74 3631.54 2390.95 S 4838.35 W 5966366.04 N 556812.49 E 0.000 2390.95 """'''''''-' 10600.00 90.780 179.728 3528.38 3630.18 2490.94 S 4837.88 W 5966266.06 N 556813.78 E 0.000 2490.94 .~ 10700.0 90~780WP179.728 3527.02 3628.82 2590.93 S 4837.40 W 5966166.07 N 556815.08 E 0.000 2590.93 1iIiim.-T"-':: '- 10800.0 90.780 179.728 3525.65 3627.45 2690.92 S 4836.93 W 5966066.09 N 556816.38 E 0.000 2690.92 -- 10848.10 90.780 179.728 3525.00 3626.80 2739.02 S 4836.70 W 5966018.00 N 556817.00 E 0.000 2739.02 TARGET (D-Crest) Begin Dir @ c 3.00/100ft: 10848.1 Oft MD, 3626.8( TVD r~ Target - 1 C-1 04 (D-Crest-Pt), Curre Target 10900.00 89.630 178.678 3524.81 3626.61 2790.91 S 4835.98 W 5965966.11 N 556818.15 E 3.000 2790.91 10908.40 89.444 178.508 3524.88 3626.68 2799.31 S 4835.77 W 5965957.72 N 556818.42 E 3.000 2799.31 End Dir, Start Sail @ 89.44° : 1 0908.40ft MD, 3626.68ft TVD 11000.00 89.444 178.508 3525.77 3627.57 2890.87 S 4833.39 W 5965866.18 N 556821.56 E 0.000 2890.87 11100.00 89.444 178.508 3526.74 3628.54 2990.84 S 4830.78 W 5965766.24 N 556824.98 E 0.000 2990.84 11200.00 89.444 178.508 3527.71 3629.51 3090.80 S 4828.18 W 5965666.30 N 556828.41 E 0.000 3090.80 1 July, 2002 - 17:16 Page 3 of 5 DrillQuest 2.00.09.006 Kuparuk River Unit Measured Sub-Sea Vertical Local Coordinates Depth Incl. Azim. Depth Depth Northings Eastings (ft) (ft) (ft) (ft) (ft) 11300.00 89.444 178.508 3528.68 3630.48 3190.76 S 11400.00 89.444 178.508 3529.66 3631.46 3290.72 S 11500.00 89.444 178.508 3530.63 3632.43 3390.68 S 11538.52 89.444 178.508 3531.00 3632.80 3429.18 S Sperry-Sun Drilling Services Proposal Report for Plan: 1C-104 - 1C-104 L 1 (wp05) Your Ref: Tied into Rig Surveys Revised: 1 July, 2002 orth Slope, Alaska Kuparuk 1 C Global Coordinates Northings Eastings (ft) (ft) Dogleg Rate OOft) Vertical Section Comment 556831.83 E 56835.26 E 838.68 E 40.00 E TARGET (D-Toe) Total Depth~- 11538.52ft MD, 3632.80ft TVL 4-1/2" Liner Target -1C-104 (D-Toe), Current Target 0.000 3190.76 0.000 3290.72 0.000 3390.68 0.000 3429.18 All data is in Feet (US) unless otherwise stated. Directions and coordinates are relative to 'I Vertical depths are relative to RKB = 101.8' (MSL). Northings and Eastings are relative to Magnetic Declination at Surface is 25.867° (01-Jul-02) The Dogleg Severity is in Degrees per 100 feet (US). ... Vertical Section is from 1437' FNL, 625' FWL and calculated along an Azimuth of 180.000° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 11538.52ft., The Bottom Hole Displacement i~tit1¡1¡~»:8Qft" in the Direction of 234.567° (True). Q :0 "..,.....",,- ~~ ~ ~:~ ~ )~ r-- ion Coordinates Northings Eastings (ft) (ft) 7045.00 3681.44 1051.71 N 4887.50 W 7045.00 3681.44 1051.71 N 4887.50 W 7057.00 3684.14 1040.97 N 4892.12 W 7075.00 3687.89 1024.77 N 4899.02 W 7282.01 3706.83 823.99 N 4934.72 W 9220.90 3649.61 1112.03S 4846.14 W 9304.83 3647.80 1195.91 S 4844.03 W 10848.10 3626.80 2739.02 S 4836.70 W 10908.40 3626.68 2799.31 S 4835.77 W 11538.52 3632.80 3429.18 S 4819.37 W 1 July, 2002 - 17:16 Comment ~ Top West Sak D (Measured) Top of Whipstock in 7-5/8" Csg (Top West Sak D) : 7045.00ft MD, 3681.44ft TVD Begin Rathole in 6-3/4" Hole: 7057.00ft MD, 3684.16ft TVD Begin Dir @ 14.00/100ft: 7075.00ft MD, 3687.89ft TVD End Dir, Start Sail @ 91.69° : 7282.01ft MD, 3706.83ft TVD Begin Dir @ 3.00/100ft : 9220.90ft MD, 3649.61ft TVD TARGET (D-Mid Pt) End Dir, Start Sail @ 90.78° : 9304.83ft MD, 3647.80ft TVD TARGET (D-Crest) Begin Dir @ 3.00/100ft: 1 0848.1 Oft MD, 3626.80ft TVD End Dir, Start Sail @ 89.44° : 10908.40ft MD, 3626.68ft TVD TARGET (D-Toe) Total Depth: 11538.52ft MD, 3632.80ft TVD Page 4 of5 DrillQuest 2.00.09.006 C) =x:;~ ~.. ~"'..> \ £.~~ ~"'~ --..., c:::.~: ~.;.-~ r-- Kuparuk River Unit Casing details Fro m Measured Vertical Depth Depth (ft) (ft) <Surface> <Surface> 7045.00 3681.44 Targets associated with this welJpath Target Name 1 C-1 04 (D-Crest -Pt) 1 C-1 04 (D-Heel) 1 July, 2002 . 17:16 To Measured Vertical Depth Depth (ft) (ft) 7045.00 11538.52 3681 .44 3632.80 Sperry-Sun Drilling Services Proposal Report for Plan: 1C-104 - 1C-104 L 1 (wp05) Your Ref: Tied into Rig Surveys Revised: 1 July, 2002 orth Slope, Alaska Kuparuk 1C Casing Detail -, 7-5/8" Csg Window 4-1/2" Liner Target Entry Coordinates TVD Northings Eastings Target Target (ft) (ft) (ft) Shape Type 3626.80 2739.02 S 4836.70 W Point Current Target Mean Sea Level/Global Coordinates: 3525.00 5966018.00 N 556817.00 E Geographical Coordinates: 700 19' 04.0865" N 1490 32' 21.9976" W 3684.80 603.34 N 4866.25 W Point Current Target Mean Sea Level/Global Coordinates: 3583.00 5969360.00 N 556760.00 E Geographical Coordinates: 700 19' 36.9613" N 1490 32' 22.9232" W 3647.80 1195.91 S 4844.03 W Point Current Target Mean Sea Level/Global Coordinates: 3546.00 5967561 .00 N 556797.00 E Geographical Coordinates: 700 19' 19.2643" N 1490 32' 22.2405" W .~ 3632.80 3429.18 S 4819.37 W Point Current Target Mean Sea Level/Global Coordinates: 3531.00 5965328.00 N 556840.00 E Geographical Coordinates: 700 18' 57.2982" N 1490 32' 21.4789" W Page 50f5 DrillQuest 2.00.09.006 C) ::t:J -....,,.... ~"'å- ~ c-diy::::ì -A"O. -". CJ) ~::~ 3500~ r--~ CD ~ ~ ~ 15. Q) 0 J~ '\.. ~,--- ".-,:. Phillips Alaska, Inc. Kuparuk River Unit 1 C Pad 1 (w 1 C-1 0 Reference is True North Current Well Properties Plan: 1C-104 Horizontal Coordinates: Ref. Global Coordinates: 5968796.65 N. 561631.04 E Ref. Stucture Referance : 280.27 N. 738.73 W Ref. Geographical Coordinates: 70019' 31.0425" N, 149030' 00.8575" W 1437' FNL & 625' FWL. SEC. 12 - T11N - R10E RKB Elevation: North Reference: Top West Sak D (Measured) (387' FNL & 1017' FWL, SEC. 11-T11N-R1OE) 101.800 above Mean Sea Level True North Feet (US) A ( 05) y* $;U 11 ss~vli:es . . À tHðIllL'4IrlW:1Cwfì1þ"Jil1y roved P OAl'.........NG Begin Rathoie In 6-3/4' Hole: 7057.0011 MD, 3684.16ft TVD: Begin Dir @ 14.0"/100" : T075.0Oft MD, :i687.891i'TVD / End Die, Start Saii @ 91.69" : 7282.01ft ~D, 37G6.83ft TVD // // Y /// 0 s. .~--: 7.5/8" Csg Window 7045. C11 MD 3681.411 TVD ~ 4000 - ''¡:¡ ã> > I -1 000 DrillQuest 2.00.09.006 Scale: 1 inch = 500ft !'" /' // /' /,/ 8egin Die @ 3-00110Oft : 9220.901t MD. 3649.6"!fi TVD I -500 I 500 0 Scale: 1 inch = 1 OOOft Eastings -5000 -4000 -3000 I . I I '¡.(',J8" Gsg Window .../ ~.. ;~:~:~~: ~\?') "';/ Top West Sak D (Measured) . ,./(;¡ ij";~.,,% .j,f. (387' FNl. & 1017' FWL, SEG. 11.l11N.H10E) .'..' "" 3692.8 ~ - 1000 f\ .~ \ "- ,\ ." \ "- 3(\94.5. \ ." \ " \ Begin Dil @ 14_0"/10011: 70'75.0011 MD, 3687.891t TVD \ End Dir, Start Sail @ 91.6~1": 72132.01ft MD. 3706.8311 TVD 1000 - ) 0- -1 000 - -2000 - -3000 - . 1C-104 L1 (wp05) I 1000 I 1500 Top of Whipstock in 7-5/8' Csg (Top Wesl Sak D) : 7045.0011 MD, 3681.4411 TVD Begin Ralhele in 6-314' Hole: 7057.0011 MD, 3684.1611 TVD 3676.8 . 3659.1 . /. Begin Dir @ 3.0"/10011: 9220.9OfI MD, 3649.61fl TVD /~ ./ 3645.1 . St;;-Ht :~:(~H ~ 0 .¡::,. ~ 3637.0 .. î "tJ 0 ~ :'~.G-:;i~)nf1 3628.8 . End nil, Start Sllil viP 89.44" : 1090f.!.4011 MD, 3626.6Bft TVD 3630.5 . .í!>l'J.37 H. sre. fI..nl,\'-!Ulil'.; 4~!2" Liner 11537.2fi MD 3632.8« TVD I -5000 I -4000 I -3000 ,41J' . 'I // ~i,f'/:00f! : End Dit, Slart Sail «. 89.44' : 10908.401\ MD, 3626.6811 TVD I 2000 I 2500 I 3000 -0 (/) - -1000 g 1:: t 0 Z --- -2000 -== 0 0 - -3000 ~ II .s:;; 0 .S ':":~- Q) -æ 0 (f) 4ø/2~ Uner 11537.211 MD 3632.8f! T VD ", "4., ? , / I I 3500 C) ::0 --- t7:) ---- ~ ~ r-- ~", Phillips Alaska, Inc. 1 MD Inc Azim. SSTVD TVD N/S EJW Y X DLS V.S. Comment (ft) (Deg) (Deg) (ft) (ft) (ft) (ft) (ft) (ft) (O/100ft) (ft) 7045.00 76.08 203.41 3579.64 3681.44 1051.71 N 4887.50 W 5969808.18 N 556735.06 E 5.93 -1051.71 Top of Whipstock in 7-5/8" Csg (Top West Sak D) 7057.00 77.96 203.07 3582.34 3684.14 1040.97 N 4892.12 W 5969797.40 N 556730.54 E 15.90 -1040.97 Begin Rathole in 6-3/4" Hole 7075.00 77.96 203.07 3586.09 3687.89 1024.77 N 4899.02 W 5969781.15 N 556723.77 E 0.00 -1024.77 Begin Dir @ 14.0"/100ft 7282.01 91.69 177.38 3605.03 3706.83 823.99 N 4934.72 W 5969580.08 N 556689.72 E 14.00 -823.99 End Dir; Start Sail 9220.90 91.69 177.38 3547.81 3649.61 1112.03 S 4846.14 W 5967644.85 N 556794.20 E 0.00 1112.03 Begin Dir @ 3.0"/100ft 9304,83 90,78 179^7~) 3546.00 3647,80 10195.91 <.:'" 4844,03 W 5967561 ,00 ~l 55fr?97.00 E 3.00 i 195.9'¡ TARGET (D~~JÎÍd pt) End Oir; Start Sail ,,) 10848,10 90.78 179.73 3525J)0 3626.80 2739.02 S 4836-70 VV 5966018.00 N 556817.00 E 0,00 273~j,02 TAROET (D-Crest} Ge9ín Dir (Ç{; 3.0"'ílOCft 10908.40 89.44 178.51 3524.88 3626.68 2799.31 S 4835.77 W 5965957.72 N 556818.42 E 3.00 2799.31 End Dìr; Start Sail 11638.62 S9A4 r78.61 3631.00 :3G32~80 ~Y129.18 S .4819,37 \^l [5966328.00 N 656840,00 Ë 0.00 a429.t 8 T ARGFT (OoToe) Total Depth .~ Page 1 of 1 1an1e +N/.S +FJ-W Ian: IC-104 280.366 -738.776 5968796.65 WELL DETAILS ANTI-COLLISION SETTINGS SURVEY PROGRAM COMPANY DEfAJL~ WEU1)A'I11 DmAn.S 1(:.1041.1 (Ri:) Nortl1Ù1g Latitude Longitude SkJt Jepth Fm Depth To SurveylPlan 1045.000 11538.373 Planned: lC-104LI (wp05) VI Tool Ph~)... Ab.4:a Inc r*~ Cak::ubtiun M""thod: MiUnum Cwval~e wÈæ 'Ê~i~~~~~ v.s%~~ ~~~ +\>1J"t ~.~u Easting l'arentWcllpath Tc 00 MJ> IC-I04(RIO) 7045.000 561631.04 70'19'31.042N 149'30'OO.857W NlA ~~~%O~~~~~ ~~~~:~&5,OOO ~~~fYal: î?5~373 Maximum Range: 10000,000 Reference: Plan: lC-I04 LI (wp05) MWD+IFR.AK.CAZ-SC Do}un 19 IC-I04 (g¡ 101.8 R;¡;. Ref. !Ja11ß1 I Ot.HOOR --98 0 ""'90 ''''''80 ""'70 '''''''-60 "'50 -40 -30 -20 -10 -0 270 -10 -20 -30 ~-40 =0 ---..... -50 ~ ~ -60 <:: ~ "70 r--- ""80 "'''90 --98 18098 ~ From Colour ToMD 0 200 200 400 400 600 600 800 800 1000 1000 1500 1500 2000 2000 2500 2500 3500 3500 4500 4500 5500 5500 6500 6500 7500 7500 8500 8500 9500 9500 10500 10500 11500 11500 12500 12500 14000 ~, 90 LEGEND - IC-IIY (lC.IIY), Major Risk - IC-121 (IC-121), Major Risk IC-125 (lC.lè~'1 ~I,i"r R;,k - Plan: IC-I'LJ,IC-I,L¡ ,RI~ PI."", Plan: IC-I,LI 'IC.I,L.I, RIG" f\¡" l - 1(' 11,?(1f:\11,?ì 1-h¡-¡P¡'+ - rlJ" '['IIIIII('lllllt'I.'1 PI.II {.',<<<-»:<<-:- 1'1 J" Ii. II I. , Ii, II I I I r" 'I' " i , ~ - IC-I04L1 (Rig) - IC-I04LI (wp05) Travelling Cylinder Azimuth (TFO+AZI) [deg] vs Centre to Centre Separation [30ft/in] lC-104 I~l (wpOS) Approved Plan (MWD+III?R+CAZ) ~'"'C &:J: ~- ro" I' -<I' Q.- i!'"'C Fen ~» m- :dO) ?2tn m~ ~O) 0'" 0- :S::::::J ~ zO -<- :E en-Cm ::::T-r+ (D!»en ~::s!» wi" oc.:E ""'O(D .þ.o= ;':3ô 0"2.- ~ (D ~ <r+0 (D -. .þ. "°r r::S~ -. en .. ::so» ~::::T'TI c(DO (D3» r+!»" ~.~~ ::r w -~ w ~ - ~ c: ~ f!1IÁi.< ~ ;! 0 :3 Q) ~ en ~ ~~ 6 OJ {g ~l:JaQ) . ::0 () ëi3 ~Þ"'Q. o.,,~o- I\) -I" " (1) Liner Hanger, Baker Flanged Hook Hanger, Size 7-5/8" x 4-1/2",4-1/2", 11.6#, BTC Pin Down (1) Swivel Sub, Baker, 4-1/2", 11.6#, BTC Box x Pin (1) Crossover, Baker, 4-1/2", 11.6#, BTC Box x 4-1/2", 12.6#, IBT Pin (1) ECP I Indicator Sub Assembly, Baker, consisting of: (1) Handling Pup, 8', 4-1/2", 11.6#, L-80, IBTM Box x BTC Pin (1) Indicator Profile Sub, Baker, 1 OK-15K Snap Force, 4-1/2",11.6#, L-80, BTC, Box x Pin (1) Handling Pup, 6' long, 4-1/2", 11.6#, L-80, BTC Box x Pin (1) ECP (External Casing Packer), Baker Model CTC 20' Payzone, 4-1/2", 11.6#, L-80, BTC Box x Box (3.833 Min ID). (1) Bottom Sub, Baker, 3' long, 4-1/2", 11.6#, L-80 BTC Pin x 4-1/2", SLHT Pin (x) Joints 4-1/2" Blank Pipe, 4-1/2", 12.6#, L-80, IBTM. D Sand Heel at +1- 7,045' MD, 3,681' TVD Top of Window at +1-7,045' MD, 3,681' TVD ------ I ~.i'JI'#q;r;r/)! 7/#4 -~*q/;rA "'q;rq"", Liner Top Packer Set @ +1- 7,250' MD 13,725' TVD (1) Joint 4-1/2" Blank Pipe, Baker, 4-1/2", 11.6#, L-80, SLHT (1) Sliding Sleeve, Baker Model 4-1/2" 'CMD', wI 3.43" ID, 4-1/2", 11.6# SLHT Box x Pin (1) Joint 4-1/2" Blank Pipe, Baker, 4-1/2", 11.6#, L-80, SLHT (1) Crossover Sub w/ 4-1/2",11.6#, SLHT Box x 4",9.5#, SLHT Pin (1) Joint 4" Blank Pipe, 4", 9.5#, L-80, SLHT. (x) Joints Screen, 4" x 4-1/2" Baker Excluder 2000,4",9.5#, SLHT (x) Joints 4" Blank Pipe, 4", 9.5#, L-80, SLHT Note: Screen and blank pipe will be run by alternting (1) joint of Excluder screen with (1) joint of Blank pipe through the production zone as required from 'GPV' Set Shoe Assembly to Model 'CMD' Sliding Sleeve. (2) Joints 4" Blank Pipe, 4", 9.5#, L-80, SLHT Blank Pipe. (1) Crossover Sub, Baker, 4", 9.5#, SLHT Box x 5", 18#, SLHT Pin (1) Joint 5" Blank Pipe, 18.5' long, Baker, 5", 18#, L-80, SLHT, wI Drillable Packoff Bushing (for 5" 15-18# casing) and with %" weephole (1) Crossover Sub, Baker, 5", 18#, SLHT Box x 3-1/2",9.2# SLHT Pin (1) Joint 3-1/2" Bent Pipe, Baker, 3-1/2", 9.2#, L-80, SLHT, Length 18.5'. (1) Set Shoe, 3-1/2", Baker Model 'GPV', (4.50" Max OD), 3-1/2", 9.2#, SLHT Box. I~=~=~=~=~=~=~~~=~=~=~= I I~~~~~~~~~~~~~ ~ Surface I Production Casing 7-5/8" 29.7# L-80 BTC Mod Set @ 7,400' MD 13,741 TVD 6-3/4" Open Hole TD: 11,453' MD I 3,633' TVD - I~=~~=~~=~~=~~=~~=;= See Sheet 2 for Lower Lateral Liner Details Tree Assembly, Vetco Gray Gen II, API 13-5 5000 psi Flange Down 1/16" 5000 Studded T with Penetrators Tubing Head Assembly Vetco Gray 18 - x 4- op, , . ~ , . . , . . - ~ '" "'" 16" Conductor: +1- 158' MD ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ I ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ f ~ I ~ ~ ~ ~ ~ ~ ~ I i ~ g ~ § ~ ~.~~¡~;;i)i_1i~;;)':¡;~ ~ ~ ~ ~ A ~ l ~ ~ ~ ! I ~ I I I I I i i § ~ ~ ~ ~ ~ i i ~ ~ ~ ~ ~ ~ ~ I ~ I fE ! I ~ i ~ ~ ~ ~ r.. 11 Port Collar: +1- 1000' MD 1974' TVD M Top of Window: +1- 7,045' MD /3,681' TVD Top of Lower Lateral Liner: +1- 7,250' MD I 3,725' TVD 9-7/8" Hole TD, 7-5/8" Shoe: +1- 7,400' MD I 3,739' TVD ~ ~I ( Nabors Rig 245 RKB @ O' Eastings: 561,631.04 Northings: 5,968,796.65 Elevation: 101.8' AMSL Tubing Hanger, 4-1/2", Vetco Gray wI 4.909" MCA Top Connection, 4-1/2" L-80 NSCT Pup Joint Down ESP Power Cable Penetrator Heat Trace Penetrator (1) Joint Tubing (x) Pup Joints Tubing, as required to spaceout heat trace. Connector, Field Attachable, Power Cable Connector, Field Attachable, Heat Trace Power Cable, Centrilift, #4 AWG Double Armor Heat Trace, Raychem, Surface to +1- 3,000' MD. (x) Joints Tubing (1) Gas Lift Mandrel, CAMCO 4-1/2" x 1" Model KBG-2 with dummy valve installed. 4-1/2" IBT Pin x Pin, with 6 foot 4-1/2" XO Pups, top and bottom. Tubing String: 4-1/2", 12.6#, L-80, NSCT (3) Joints Tubing (1) Sub, Phoenix Discharge Temperature and Pressure (1) Pup Joint Tubing, 10ft length (1) Pup Joint Tubing, 10 ft length (1) Through Tubing Conveyed Electric Submersible Pump (TTCESP) Assembly, Centrilift, consisting of: (1) Slotted Nipple, Centrilift, 4-1/2" (1) Crossover, Centrilift, 4-1/2", TIC (1) Tandem Seal Section, Centrilift Model GST3 DB HL PFS (1) ESP Assembly, Centrilift Model 21 FCNPSH I 140FC2700 (conveyed through tubing) (1) Motor, Centrilift, 190 HP KMH 2415/48 (1) Gauge, Phoenix, Model, MS-1 Gauge (1) Centralizer, Motor, Centrilift, 6.25" 00 to be spaced out at bottom of pump tangent @ +1- 6200' MD I 3,425' TVD IJ~=~=~=~=~~~=~=~=~~=~=~= I I~~~~~~~~~~~~~ ) D-Sand Lateral 6-3/4" Open Hole TD: +1- 11,539' MD I 3,633' TVD fl~=~~~~=~=~=~=~=~=~=~=~ I I~~~~~~~~~~~~~ ) B-Sand Lateral 6-3/4" Open Hole TD: 11,552' MD I 3,689' TVD PHilliPS Alaska, Inc. A Subsidiary of PHilLIPS PETROLEUM COMPANY West Sak Well 1 C-1 04, AFC AK0230 Planned Completion Schematic 0 ril Sheet 2 of 2: Tubing String Details' , . . prepared by I. :.t'....r¡¡......,~..,..:.¡... t.'. as A. Brockway \ I ~ ;;:,,;' . Rev 2 FINAL ~, ¡,,c July 01, 2002 ( ,lC-l04Ll Drillinq Hazards Summary (SEE WELL PLAN AND ATTACHMENTS FOR DETAILED DISCUSSION OF THESE RISKS) 6-3/4" Open Hole / 4" Liner Interval Low I Mitigation Strategy Stripping drills, Shut-in drills, Increased mud weiqht. Good hole cleaning, PWD Tools, Hole Opener, Decreased mud weight Reduced pump rates, Mud rheoloqy, LCM Trip speeds, Proper hole filling (use of trip sheets), Pumping out Hazard Abnormal Reservoir Pressure Stuck Pi pe Risk Level Low Lost Circulation Hole Swabbing on Trips Low Moderate 1 C-1 04 Drilling Hazards Summary 0.. R I IprepaA~: t Todd ~~;~~ ~."... .." ¡j,,- ~ PHILLIP'..., Alaska, Inc. ~ A Subsidiary of PHILliPS PETROLEUM COMPANY Phillips Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510 July 2, 2002 Ms. Cammy Oechsli Taylor Commissioner Alaska Oil and Gas Conservation Commission 333 West ¡th Avenue, Suite 100 Anchorage, AK 99501 (907) 279-1433 Re: Application for Permit to Drill: 1C-104L 1 Surface Location: Target Location: Bottom Hole Location: 1437'FNL,625'FWL,Sec.12,T11N,R10E 387'FNL, 1017' FWL,Sec. 11,T11N,R10E 412' FSL, 1083' FWL,Sec. 11,T11N, R10E Dear Commissioner: Phillips Alaska, Inc. hereby applies for a Permit to Drill to drill the upper lateral section of well 1 C-1 04L 1. The well will be drilled and completed using Nabors 245E. Please utilize documents on file for this rig. The following logs are planned to be run on this well: GR/Res. Subject to AOGCC approval, this permit will replace APD 10-401 #202-061 currently on file with the Commission. Also, subject to AOGCC approval, fluids and cuttings generated from drilling the well will be pumped down an approved and existing annulus on Drillsite 1 C, or hauled to an approved Prudhoe or GKA Class 1\ disposal well. The following people are the designated contacts for reporting responsibilities to the Commission: A) Completion Report Sharon Allsup-Drake, Drilling Technologist (20 AAC 25.070) 263-4612 B) Geologic Data and Logs (20 AAC 25.071) Mike Werner, Geologist 265-6191 If you have any questions or require further information, please contact Tom Brockway at (907) 263-4135. Sincerely, c, ~ \~. R. Thomas Kuparuk Drilling Team Leader .f" RECEIVED JUL 2 2002 Alaska OU & Gas Cons. Commíss'or~ Anchorage AL ¡¡1~o~1:;~~'Iri.jjiÂt~S~A{,oiN~,;;~àSj ¡~iii~j"~'~~\,jlJ:Jfn~~i~¡JI):¡O~:¡f:o~!i;¡f*~J:~j¡ i¡¡"~""'\\ij'2i~ri?'ìf)\! ()ii.~,,;fJ1~Mt~¿~m~~'fJ:'~!$~~~~~~ièM~~ ~¡ ~'¡'~~~;~~¡J;;~~ØG).~~i~Y,/, \" ',I' j)),,,i TofTHE . AOèèc: "~.... ! .ORQE;ROF: '333 W.è]TH VENUE, SUITE 100 VOJDAFTER90 DAYS ~ ~ BANK = ONE. -' BANK ONE, NA - 0710 Chicago, IL Payable through First USA Bank, NA TRACE NUMBER: 20.6002597 EXACTLY **********100 DOLLARS AND 00 CENTS $********100.00 ( frd~ ~~ 118 20 bOO 25 g (118 I:o:ì . .00 28 :ìl: 0 g 2 ( ... ( :ì 118 . VERIFYAI:ITHENTICITY OFTHISCOLOR ..DOC.I:IMENl"BYCflECKING.THEFOI;JRI::IOCUMENTSECURITYFEATURES LISTED .ON BACK. . ~, (' ~~~~E :¡ !Æ~!Æ~~~~ AT1A.SK& OIL AND GAS CONSERVATION COMMISSION Chuck Mallary Drilling Engineering Supervisor Phillips Alaska, Inc. PO Box 100360 Anchorage AK 99510 ( Kuparuk River Unit 1C-104L1 Phillips Alaska, Inc. Permit No: 202-062 Sur Lec: 1437' FNL, 625' FWL, Sec. 12 T11N, R10E, UM Btmhole Loc. 412' FSL, 1083' FL, Sec. 11, T11N, R10E, UM Re: Dear Mr. Mallary: TONY KNOWLES, GOVERNOR 333 w. JTH AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Enclosed is the approved application for permit to drill the above referenced well. The permit to drill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. The permit is for a new wellbore segment of existing well KRU 1C-104, Permit No 202-061, API 50-029-23076. Production should continue to be reported as a function of the original API number stated above. Annular disposal of drilling wastes will. not be approved for. this well until sufficient data is submitted to ensure that the requirements of 20 AAC 25.080 are met. Annular disposal of drilling waste will be contingent on obtaining a well cemented surface casing confirmed by a valid Formation Integrity Test (FIT). Cementing records, FIT data, and any CQLs must be submitted to the Commission for approval on form 10-403 prior to the start of disposal operations. Please note that any disposal of fluids generated from this drilling operation which are pumped . down the surface/production casing annulus of a well approved for annular disposal on Kuparuk River Unit 1C must comply with the reqùirements and limitations of20 AAC 25.080. Approval of this permit to drill does not authorize disposal of drilling waste in a volume greater than 35,000 barrels through the annular space of a single well or to use that well for disposal purposes for a period longer than one year. (" Permit No. 202-062 March 14,2002 . Page 2 af2 Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25035. Sufficient notice (approximately 24 hours) must be given to allow a representative of the Commission to witness a test of BOPE installed prior to drilling new hole. Notice may be given by contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. Sincerely, &n t1U' .k/1f,/ camm~ChSli Tayl~r--d Chair BY ORDER O~ THE COMMISSION DATED this~day of March, 2002 jjcÆnclosures cc: Department ofFish & Game, Habitat Section wlo encl. Department of Environmental Conservation wlo encl. ~ PHILLI( "3 Alaska, Inc. ~, A Subsidiary of PHilLIPS PETROLEUM COMPANY Post Office Box 100360 Anchorage, Alaska 9951~60 C. Mallary Phone (907) 265-6974 Fax: (907) 265-1535 Email: cmallar@ppco.com March 4, 2002 Cammy Oechsli Taylor Chair Alaska Oil and Gas Conservation Commission 333 West ih Avenue Suite 100 Anchorage, Alaska 99501 (907) 279-1433 Re: Application for Permit to Drill, West Sak Multilateral WelllC-l04 and lC-l04 Ll Dear Commissioner: Phillips Alaska, Inc. hereby applies for a Permit to Drill an onshore multilateral development well to the West Sak interval from lC Pad in the Kuparuk River Unit ("KRU"). The well is designed to penetrate and develop the production potential of the West Sak Sands in the vicinity of lC Pad, with two horizontal I penetrations. This application is for the Permit to Drill the main well bore from surface to total depth of the horizontal penetration of the lower West Sak "B" Sand. Another application is also attached for the~ Permit to Drill the upper lateral, designated lC-l04 Ll, a horizontal penetration of the West Sak "D" Sand. The well is designated as a horizontal producer using a 7-5/8" cas~ string. A 4-1/2" Production Liner will be run and the well will be completed with 4-1/2" tubing and ESP. The well will be drilled and completed using Nabors Rig 245e. The expected spud date is May 7, 2002. Please find attached for the review of the Commission Form 10-401 and the information required by 20 ACC 25.005. If you have any questions or require any further information, please contact Todd Mushovic at 265-6974. Sincerely, Jf(~t Chuck Mallary Drilling Engineering Supe isor RE D MAR 0 ~ 2002 Alaska Oil & Gas Cons. Commission Anchorage OR\G\ ~L \tJ c;A- 'S I J z.} 0 1- t- ~h~ STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 1 a. Type of work: Drill 0 Redrill 0 Re-entry []Deepen 0 2. Name of Operator Phillips Alaska, Inc. 3. Address P.O. Box 100360 Anchorage, AK 99510-0360 4. Location of well at surface 1437' FNL, 625' FWL, Sec. 12, T11 N, R10E, UM At top of productive interval 68' FSL, 1266' FWL, Sec. 2, T11N, R10E, UM At total depth 412' FSL, 1083' FWL, Sec. 11, T11N, R10E, UM 12. Distance to nearest property line 13. Distance to nearest well 412' @ TO feet 1C-125, 781' @ 11908' 16. To be completed for deviated wells Kickoff depth: 6740' MO 18. Casing program size Development Oil 0 Multiple Zone 0 10. Field and Pool 1 b. Type of well. Exploratory 0 Stratigraphic Test 0 Service 0 Development Gas 0 Single Zone 0 5. Datum elevation (DF or KB) RKB 41 feet 6. Property Designation Kuparuk River Field AOL 25649 ALK 467 West Sak Oil Pool 7. Unit or property Name 11. Type Bond (see 20 MC 25.0251) Kuparuk River Unit Statewide 8. Well number Number 1 C-1 04L 1 #59 52 180 9. Approximate spud date Amount May 7,2002 ./ $200,000 14. Number of acres in property 15. Proposed depth (MD and TVD) 2560 11910 I MO / 3631' TVO 17. Anticipated pressuryisee 20 MC 25.035 (e)(2)) Maximum surface 1290 psig At total depth (TVO) 1696 psig Setting Depth Maximum hole angle 91 0 Hole Specifications Grade Coupling Length Casing Weight 9.875" BTC Mod HSLHT 7190' 5170' 7.625" 29.7# 9.5# L-80 L-80 6" 4" 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total Depth: feet feet measured true vertical Effective Depth: measured true vertical feet feet Casing Conductor Surface Intermediate Production Liner Length Size Cemented Perforation depth: measured true vertical feet Top Bottom TVD Quantity of Cement (include stage data) MD TVD MD 41' 6740' 41' 3661' 7231' 3740' 11910'/ 3631' open hole screen Plugs (measured) Junk (measured) Measured depth True Vertical depth R 0 5 Alaska Oil & Gas Cons. Commission Anchorage 20. Attachments Filing fee 0 Property Plat 0 BOP Sketch 0 Diverter Sketch 0 Drilling program 0 Drilling fluid program 0Time vs depth plot Qefraction analysis DSeabed report 020 AAC 25.050 requirements 0 21. I hereby certify that the fo going is true an c ct to the best of my knowledge Questions? CallI odd Mushovic 265-6974 Signed C d: Titl.e: Drilling Engineering Supervisor . Date 'f 1AdJC#¡ Jtro 2 Chuck Mallary PrP.nArArl hv ShAron Afl.c:wn-DrAkA Commission Use Only " , Permit Number. I API number I Approval date .11. ' \' J f\~ee cover letter . 202. - t"? b :/ 50- 02..9 - .2. ~ a /b"" 66 V vI V, for other requirements Conditions of approval Samples required 0 Yes ~ No Mud log required . Yes ~ No Hydrogen sulfide measures 0 Yes ~ No Directional survey required [XI Yes 0 No Required working pressure for BOPE D2M; 0 3M; 0 5M; 0 10M; 0 0 Other: ~~~,~~'\~~~ ~C)\> ~~Afl'fYV1. Approved by Original Sìgned Bv Cammy Oechsli Form 10-401 Rev. 12/1/85. Commissioner by order of the commission ~ ì j( b~ DinG/NÞ - Submit in triplicate Date Aí' :ition for Permitto Drill, We1l1C-104 " Revision NO.1 Saved: 22-Feb-02 Permit It - West Sak Well #1 C-1 04 L 1 App/ícatíon for Permít to Drí// Document M(lximizE Well Vglu¡¡ Table of Contents 1. Well Name................................................................................................................. 2 Requirements of 20 AAC 25.005 (f)....................... ............... ......... .................. ........... ............ ..... ...........2 2. Location Summary....... ...................... ..... ... .............. ... ... ...... ............ ......... ... .... ........ 2 Requirements of 20 AAC 25.005(c)(2) ........... ........................... ............. ............. .............. .....................2 Requirements of 20 AAC 25.050(b)... ...... ....... ....... ................. ..... .................... ....... ..... ................... ........3 3. Blowout Prevention Equipment Information ......................................................... 3 Requirements of 20 AAC 25. 005(c) (3) ........................................ ........... .............. ............. .....................3 4. Dri II i ng Hazards Information. ....... ................ ........ ... ........ ........ ..... ....... ........ ...... ...... 3 Requirements of 20 AAC 25.005 (c)( 4) .................... ............................................... ............... ................3 5. Procedure for Conducting Formation Integrity Tests ........................................... 3 Requirements of 20 AAC 25.005 (c)(5) .................................................................................................. 3 6. Casi ngand Cementi ng Program ... ....... ........... ..... .......... ..... ............... ...... ... ....... ..... 4 Requirements of 20 AAC 25.005(c)(6) ................................................................................................... 4 7. Diverter System Information ...................................................................................4 Requirements of 20 AAC 25.005(c)(7) ............ ............. ................. ................... ............ ........ ........ .......... 4 8. Dri II i ng Fluid Program .. ...... ...... ..... ... ...... ..... ..... ........ .... .... ... ...... ......... ....... ......... ..... 4 Requirements of 20 AAC 25.005(c)(B) ................ ............... ........................ ............ ........... .......... ........... 4 9. Abnormally Pressured Formation Information ......................................................5 Requirements of 20 AAC 25.005 (c)(9) ........... .......... ............ ......... ......,.................. .......... ............. ........5 10. Seismic Analysis ..... ........ ...... .... .............. ....... ...... ... ................ ....... ...... ..... ... ... ..... .... 5 Requirements of 20 AAC 25.005 (c)(10) ................................................................................................5 11. Seabed Condition Analysis .....................................................................................5 Requirements of 20 AAC 25.005 (c)(11) ................................................................................................ 5 12. Evidence of Bond i ng ..... ........ .... ....... ...... .... ..... ... ... ...... .... ........ ....... ..... ... ... .......... .... 5 Requirements of 20 AAC 25.005 (c)(12) ...... .......... ...... ...................... ................... ............ ........ .............5 1C-104L 1 PERMIT IT ver.1.doc Page 1 of 7 0 titGIN)~. ( All... . 'ation for Permit to Drill, Well 1 C-1 04 , Revision No.1 , Saved: 4-Mar-02 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. ............. ... ........... ........ ...... ........... ........ ...... .................. .... ....... ............. 7 Attachment 1 Directional Plan (6 pages) ............................................................................................... 7 Attachment 2 Drilling Hazards Summary (1 page) ................................................................................ 7 Attachment 3 Well Schematics (2 pages)............. ......... ....... ........................ ............................. ............ 7 1. Well Name Requirements of 20 AAC 25.005 (f) Each well must be Identitìed by a unique name designated by tlie operator and a unique API number as:.r:.,igned by the commission under 20 MC 25:040(b). For a well vvittJ multiple well branches~ each branch must s/rm!a/~Y be Identifled by a unique name and APi number by adding a suffìx to the name designated for the well by the operator and to the number assigned to the well by the commiS::.70n. The well for which this Application is submitted will be designated as lC-l04 L1. / 2. Location Summary Requirements of 20 AAC 25.005(c)(2) An application for a Permit to Drill must be accompanied by each of the following ¡tem~ except fOr an item already on tÎle ¡!'llth the comm!:,"'Sion and identified in the application: (2) a plat identifying the property and the propertY~5 owners and showing (A)the coordinates of the proposed location of the well at the surface/ at the top of each objectIve formatkJn, and at total depth referenced to govemmental sectIon line!:>"- (8) the coordinates of the prvposed locatIon of the ~';lell at the surface, referenced to the state plane coordfÍ7ate system for thIs state as maintained by the National 6èodetic !:;urvey in the National OceanIc and Atmospheric Adminlstratio/7/ (q the proposed depth of the wel! at the top of each objectIve formation and at total depth; Location at Surface NGS Coordinates Northings: 5/968/796.65 1437' FNL, 625' FWL, Section 12/ TllN, Rl0E, UM RKB Elevation 101.8' AMSL Eastings: 561/631.04 Pad Elevation 60.8' AMSL ':ìl \9\ . ~ FSL, 1084' FWL, Section 2/ TllN, Rl0E, UM Measured Depth, RKB: 6966 Total Vertical Depth, RKB: 3693 Total Vertical Depth, 55: 3591 Eastings: 556/797.97 Location at Top of Productive Interval (West Sak "D" Sand) NGS Coordinates Northings: 5/970/265.05 Location at Total Depth NGS Coordinates Northings: 5/965/328 Eastings: 556/840 412' FSL, 1083' FWL, Section 11/ Tl1N, Rl0E, UM Measured Depth, RKB: 11910 Total Vertical Depth, RKB: 3631 Total Vertical Depth, 55: 3529 and (D) other Information required by 20 MC 25~ 050(b)/ 1C-104L 1 PERMIT IT ver.1.doc Page20f 7 i . Printed: 4-Mar-02 L. t,",\AIIVfi Ai. -'ation for Permit to Drill, We1l1C-104 ~. Revision NO.1 Saved: 22-Feb-02 Requirements of 20 AAC 25.050(b) If a well is to be intentionally deviated, the application for a Permit to Drill (Form 10-40i) must (1) include a plat, drawn to a suitable scale, showing the path of the proposed wellbore, including all adjacent wellbores within 200 feet of any portion of the proposed well' Please see Attachment 1: Directional Plan and (2) for all wells witl7ín 200 feet of the proposed wellbore (A) list the names of the operators of those wel/~ to the extent that those names are known or discoverable in public record~ and show that each named operator has been furnished a copy of the application by certified ma/~' 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 fol/owing item~ except for an item already on file with the commission and identified in the application: (3) a diagram and descliption of the blowout prevention equipment (BOPE) as required by 20 MC 25.03~ 20 MC 25.036; or 20 MC 25.037, as applicable/ / An API 13-5/8" x 5,000 psi BOP stack will be utilized to drill and complete welllC-104 Ll. Please see "Diagram and Description of the Blowout Prevention Equipment for Nabors Rig 245e", placed on file with the Commission. 4. Drilling Hazards Information Requirements of 20 AAC 25.005 (c)(4) An application for a Permit to Drill must be accompanied by each of the following Item~ except for an item already on file with the commission and identified in the application: (4) information on drilling hazard~ including (A) the maximum downhole pressure that may be encounterect criteria used to determine it, and maximum potential surface pressure based on a methane gradient; The expected reservoir pressures in the West Sak sands in the lC pad area vary from 0.41 to 0.46 psi/ft, or 7.8 to 8.8 ppg EMW (equivalent mud weight). These are pressures obtained from actual well test data from the nearby lC-lll, lC-125, and lC-121 wells. The maximum potential surface pressure (MPSP) based on the above maximum pressure gradient, a methane gradient (0.11) and the vertical depth of the expected base of the West Sak formation is 1290 psi, calculated thusly: MPSP =(3687 ft)(0.46 - 0.11 psi/ft) =1290 psi / (8) data on potential gas zones,' The well bore is not expected to penetrate any gas zones. and (C) data concerning potential causes of hole problems such as abnormally geo-pressured strata, lost circulation zones, and zones that have a propensity for differential sticking; Please see Attachment 2: Drilling Hazards Summary. 5. Procedure for Conducting Formation Integrity Tests Requirements of 20 AAC 25.005 (c)(5) An application for a Permit to Drill must be accompanied by each of the following Item5~ except for an item already on file with the commission and identified in the application: (5) a description of the procedure for conducting formation integrity test~ as required under 20 AAC 25. 030(f); j lC-104 Ll will be completed with 7-5/8" surface casing landed in the West Sak B-Sand, which was / permitted as lC-104. A whipstock will be set to mill a window in the 7 5/8" casing in the K-13 shale 1C-104L1 PERMIT ITver.1.doc P~ßt of 7 O~f(j 11( ~ ~ AI . "ation for Permit to Drill, Well 1 C-1 04 I( Revision NO.1 Saved: 22-Feb-02 above the West sak D-sand. A formation integrity test will be performed in accordance with the "Formation Integrity Test Procedure" that Phillips Alaska placed on file with the Commission. 6. Casing and Cementing Program Requirements of 20 AAC 25.005(c)(6) An applicatíon for a Permit to Drill must be accompanied by each of the following Item~ except for an Item already on file with the commission and identified in the applìcation: (6) a complete proposed caslÌ7g and cementing program as required by 20 MC 25.030/ and a description of any slotted linet; pre- pelforated liner; or screen to be installed/ Casing and Cementinq Program Hole Top Btm Csg/Tbg Size Weight Length MD/TVD MD/TVD 00 (in) (in) (Ib/ft) Grade Connection (ft) (ft) (ft) Cement Program 16 24 62.5 H-40 Welded 120 41/41 161 / 161 Cemented to surface with 225 cf ArcticSet 1 7-5/8 9-7/8 29.7 L-80 BTCM 7190 41/41 7231 / 3740 Cemented to Surface with 580 sx AS Lite Lead, 370 sx Class G Tail 4 6" 9.5 L-80 HsLHT 5170 6740/ 3661 11910/3631 Screens - screen Upper Inflate ECP / Lateral with cement 7. Diverter System Information Requirements of 20 AAC 25.005(c)(7) An application for a Permit to Drill must be accompanied by each of the following item:,~ except for an item already on file with the commission and identified in the application: (7) a diagram and description of the diverter ~ystem as required by 20 MC 25.035; unless this requirement is waived by the commission under 20 AAC 25.035(h)(2); A diverter system will not be used while drilling the West Sak "D" lateral. 8. Drilling Fluid Program Requirements of 20 AAC 25.005(c)(B) An application for a Permit to Drill must be accompanied by each of the following item~ except for an item already on file with the commission and Identified in the application: (8) a drilling fluid program/ including a diagram and description of the drilling fluid system/ as required by 20 MC 25,033/ Drilling will be done with a BaradrilN mud system having the following properties over the listed intervals: Density {ppg} Funnel Viscosity {seconds} Yield Point {cP} Plastic Viscostiy (lb/l00 sf) Sidtrack interval {K-13 shale only} Initial Value Final Value 9.0-9.1 9.0-9.1 ./ 40-55 40-55 20-27 20-27 D sand lateral Initial Value Final valu7" 8.9-9.0 8.9-9.0 45-60 45-60 18-25 18-25 Tau 0 Chlorides pH 11-19 11-19 4-7 4-7 13-15K 13-15K 8-9 8-9 8-14 4-7 13-15K 8-8.5 8-14 4-7 13-15K 8-8.5 1C-104L 1 PERM/TIT ver, 1.doc D~4Q17 t~~ ..;t~! Þ - Ai.""-.ation for Permit to Drill, WeIl1C-104 ~ Revision No.1 Saved: 22-Feb-02 API filtrate **HTHP filtrate MBT ***Solids ppb ** HTHP to be run at 80° F <6 <10 <11 <12 <6 <10 <11 <12 <6 <10 <2.5 <12 <6 <10 <2.5 <12 *** The drilled LGS Drilling fluid practices will be in accordance with appropriate regulations stated in 20 MC 25.033. This drilling fluid system of Nabors Rig 245e consists of: (3) Continental Emsco FB-1600 Mud Pumps, Steel Mud pits with 1100 barrel capacity, Pill Pit, Trip Tank, (3) Derrick Flo-line Shale Shakers (rated at 600 gpm), Brandt Model SRS-2 Desander, Derrick Model 58S Mud Cleaner, (2) Alpha-Laval Model 418-Vf- 5 Centrifuges, Degassers, PVf System with visual and audio alarms, Trip Tank, Flow Sensor, and Fluid Agitators. Please see "Diagram of Mud System, Nabors Rig 245e", placed on file with the Commission. 9. Abnormally Pressured Formation Information Requirements of 20 AAC 25.005 (c)(9) An application for a Permit to Drill must be accompanied by each of the following items, e.>rcept for an item already on file with the commission and identified in the application: (9) for an exploratory or stratigraphic test well, a tabulation setting out the depths of predicted abnormally geo-pressured strata as required by 20 MC 25.033(f); Not applicable: Application is not for an exploratory or stratigraphic test well. 10. Seismic Analysis Requirements of 20 AAC 25.005 (c)(10) An application for a Permit to Drill must be accompanied by each of the fol!m~,¡ing Items, except for an item already on file with the commission and identified in the application: (lO) for an exploratory or stratigraphic test well, a seismic refraction or reflection analysis as required by 20 MC 25.061{a); Nofapplicable: Application is not for an exploratory or stratigraphic test well. 11. Seabed Condition Analysis Requirements of 20 AAC 25.005 (c)(11) An application for a Permit to Drill mU::.t be accompanied by each of the following items, except for an Item already on file with the commission and identified in the application: (11) for a well drilled from an offshore platform;, mobile bottom-founded structure;, þ'1ck-up fig;, or floating drilling vessel, an analysis of seabed conditions as required by 20 MC 25.061{b); Not applicable: Application is not for an offshore well. 12. Evidence of Bonding Requirements of 20 AAC 25.005 (c)(12) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified li1 the application: (12) evidence showing that the requirements of 20 MC 25.025 {Bonding}have been met; Evidence of bonding for Phillips Alaska, Inc. is on file with the Commission. 13. Proposed Drilling Program Requirements of 20 AAC 25.005 (c)(13) An application for a Permit to Dlilf must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: The proposed drilling program is listed below. Please refer also to Attachment 3, Well Schematics. This procedure will begin upon completion of the lower lateral, lC-l04. ,I / 1. Run and set Baker WindowMasterTM whipstock, 30 degrees to left of high side. 2. Mill starting window in K-13 shale above the D-sand. POOH. 1C-104L 1 PERMIT IT ver.1.doc OfH~T^~A L All'" 'ation for Permit to Drill, Well 1 C-1 04 , Revision No.1 Saved: 22-Feb-02 3. Polish and complete window with finishing mill and 2 watermelon mills. 4. Pick up 6" drilling assembly, RIH, and drill 20-50 feet of new hole. / 5. Perform Formation Integrity Test to 12.0 ppg EMW. 6. Drill through shale to the D Sand heel. Change over to BaraDril'N drilling mud. j 7. Continue to directionally drill to TO of D sand lateral at 11,910' MD / 3,631' TVD. POOH. 8. POOH and lay down MWD, LWD and PWD tools./ 9. RIH with 6" hole opener and ream entire open hole. 10. Circulate and condition hole to run liner. Displace mud with clean filtered kill weight brine and spot viscosified brine across open hole. POOH and lay down hole opener assembly. 11. RIH with whipstock retrieval tool and casing scaper assembly to whipstock. Perform casing and drill pipe clean-up including Caustic SL Wash and Acid Pickle. Displace casing with kill weight brine. Retrieve whipstock and POOH. 12. PU 4" Liner with flanged hook hanger, ECP's and excluder screen and 2-7/8" inner wash string. 13. RIH, until Hook Hanger is just above window. Run gyro tools to orient hook hanger to window and land hanger. 14. Release hanger running tool and place cup tool across each ECP and inflate with cement. Reverse out excess cement and POOH. /1 15. Pick up lateral diverter tool and RIH and set in hook hanger. 16. RIH with cup tool assembly and spot 8% Formic Acid through the screens and allow acid to soak 6 hours. Displace acid with clean filtered brine. POOH, laying down Drill pipe as needed. 17. Make up lateral diverter retrieving tool and RIH on 4-1/2" completion tubing. Once at diverter, run dummy ESP through tubing string on wireline. Retrieve diverter, and POOH, standing back tubing. 18. Make up ESP and components as required and RIH. Run heat trace on tubing through permafrost zone. 19. Land tubing with ESP +/- 60 feet above window. Install BPV, nipple down stack, nipple up and test tree. Pull BPV. Freeze protect well with diesel by pumping into annulus, taking returns from tubing and allowing to equalize. 20. Set BPV and move off. 14. Discussion of Mud and Cuttings Disposal and Annular Disposal Requirements of 20 AAC 25.005 (c)(14) An app/ìcatìon for a Permit to Dlifl mustc be acr:;vmpanìed by each of the following items¡ except for an item already on file with the commission and Identified in the application: (14) a general descliption of how the operator plans to dispose of dn/llng mud and cuttings and a statement of whether the operator intends to request authorízation under 20 MC 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 lC 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 lC Pad or hauled to the Prudhoe Bay Grind and Inject Facility for temporary storage and eventual processing for injection down an approved disposal well. I Phillips Alaska does not intend to request authorization for the use of this well for annular disposal I operations. 1C-104L 1 PERMIT IT ver.1.doc (~~1f~ L. A~'" ~ation for Permit to Drill, Well 1 C-1 04 \ Revision No.1 Saved: 22-Feb-02 15. Attachments Attachment 1 Directional Plan Attachment 2 Drilling Hazards Summary Attachment 3 Well Schematics 1 C-1 04L 1 ~Prl/'lT.ð'T. 8& 1 doc l M'\l ' rI F ~t" : O(VOI{ ~ .lC-l04 Ll Drillinq Hazards Summa~ (SEE WELL PLAN FOR DETAILED DISCUSSION OF THESE RISKS) 6" Open Hole I 4" Liner Interval Hazard Abnormal Reservoir Pressure Stuck Pi pe Risk Level Low Low Lost Circulation Hole Swabbing on Trips Low Moderate / I Mitiqation Strateqy Stripping drills, Shut-in drills, Increased mud weiqht. Good hole cleaning, PWD Tools, Hole Opener, Decreased mud weight Reduced pump rates, Mud rheology, LCM Trip speeds, Proper hole filling (use of trip sheets), Pumping out 1 C-1 04 L 1 Drilling Hazards Summary pr_~ b~T~G:ff(j - ,m. 11 Kupa;ûk~River Unit North Slope, Alaska Kuparuk 1 C, Slot 1 C-1 04 Plan: 1C-104 - 1C-104 L1 (wp02) Revised: 22 January, 2002 ~" PROPOSAL REPORT 22 January, 2002 c'" Your Ref: Lower KOP to Minimize K13 exposure Surface Coordinates: 5968796.65 N, 561631.04 E (70019' 31.0425" N, 149030' 00.8575" W) Surface Coordinates relative to Project H Reference: 968796.65 N, 61631.04 E (Grid) Surface Coordinates relative to Stucture Referance: 280.27 N, 738.73 W (True) Kelly Bushing: 101.80ft above Mean Sea Level -.'" ....: -- spel'''''Y-su" OAtt.,;..L.tNG seAVlt:GS A ~Uibul'ton Comp<tny ~ """""", -", <: :t~- r--- Proposal Ref: pr09823 Sperry-Sun Drilling Services Proposal Report for Plan: 1C-104 -1C-104 L1 (wp02) Your Ref: Lower KOP to Minimize K13 exposure Revised: 22 January, 2002 Kuparuk River Unit Measured Sub-Sea Vertical local Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) '" !OOft) 6740.00 71.460 222.554 3559.57 3661.37 1694.78 N 4702.85 W -1694.78 Top of Whipstock (7-5/8" Csg) Begh Dir @ 15.9°/100ft : 6740.00ft MD, 3661.37ft TVD ,~, 7-5/8" Csg Window 6752.00 73.115 221.557 3563.23 3665.03 1686.29 N 4710.50 W 556906.85 E 15.900 -1686.29 Begin Rathole @ 73.12° (6" HOI~/' 6752.00ft MD, 3665.03ft TVD 6770.00 73.115 221.557 3568.45 3670.25 1673.40 N 4721.93 W 5970431.21 N 556895.53 E 0.000 -1673.40 P.U. DirTools & Begin Dir @ 15.00/100ft: 6770.00ft MD, 3670.2~ TVD 6800.00 76.235 218.194 3576.38 3678.18 740.47 W 5970408.86 N 556877.17 E 15.000 -1651.20 6900.00 86.894 207.508 3591.07 3692.87 793.86 W 5970325.50 N 556824.46 E 15.000 -1568.28 6944.33 91.675 202.884 3591.63 3693.43 4812.72 W 5970285.26 N 556805.93 E 15.000 -1528.19 Continue Dir @ 8.32°/100ft: 6944.33ft MD, 3693.43ft TVD 6966.06 91.630 201.077 3591 .00 3692.80 1508.05 N 4820.85 W 5970265.05 N 556797.97 E 8.315 -1508.05 Top West Sak D : 6966.06ft MD, 3692.80ft TVD 7000.00 36911a6 1476.10 N 4832.27 W 5970233.02 N 556786.81 E 8.315 -1476.10 7100.00 3689.34 1379.23 N 4856.60 W 5970135.95 N 556763.28 E 8.315 -1379.23 7200.00 3687.27 1279.85 N 4866.67 W 5970036.49 N 556754.03 E 8.315 -1279.85 7226.49 3686.80 1253.37 N 4866.91 W 5970010.00 N 556754.00 E 8.315 -1253.37 (TARGET: D-Heel), Start Sail @ 90.98° : 7226.49ft MD, 3686.80ft TVD Target -1C-104 (D-Heel), Curr~ Target 7300.0~R 90.979?179.428 3583.74 3685.54 1179.87 N 4866.18 W 5969936.51 N 556755.34 E 0.000 -1179.87 7400.0<tyJ 90.979 179.428 3582.04 3683.84 1079.89 N 4865.18 W 5969836.55 N 556757.16 E 0.000 -1079.89 7500.00 90.979 179.428 3580.33 3682.13 979.91 N 4864.18 W 5969736.58 N 556758.98 E 0.000 -979.91 7600.00 90.979 179.428 3578.62 3680.42 879.93 N 4863.18 W 5969636.61 N 556760.80 E 0.000 -879.93 7700.00 90.979 179.428 3576.91 3678.71 779.95 N 4862.18 W 5969536.64 N 556762.62 E 0.000 -779.95 7800.00 90.979 179.428 3575.20 3677.00 679.97 N 4861.18 W 5969436.67 N 556764.44 E 0.000 -679.97 C 7900.00 90.979 179.428 3573.50 3675.30 579.99 N 4860.18 W 5969336.70 N 556766.26 E 0.000 -579.99 ~ 8000.00 90.979 179.428 3571.79 3673.59 480.01 N 4859.18 W 5969236.73 N 556768.08 E 0.000 -480.01 8100.00 90.979 179.428 3570.08 3671.88 380.03 N 4858.18 W 5969136.76 N 556769.90 E 0.000 -380.03 .......... ~:, ~'" ~, <::: ~ r--- 22 January, 2002 -12:31 Page 2 of6 DrillQuest 2.00.09.006 Sperry-Sun Drilling Services Proposal Report for Plan: 1C-104 -1C-104 L1 (wp02) Your Ref: Lower KOP to Minimize K13 exposure Revised: 22 January, 2002 Kuparuk River Unit Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) DOft) 8200.00 90.979 179.428 3568.37 3670.17 280.05 N 4857.18 W 5969036.79 N 556771.72 E 0.000 -280.05 8300.00 90.979 179.428 3566.66 3668.46 180.07 N 4856.19 W 596~,~~:83 N 56773.54 E 0.000 -180.07 8400.00 90.979 179.428 3564.95 3666.75 80.09 N 4855.19 W 5968836.86 N 775.36 E 0.000 -80.09 ~~ 8500.00 90.979 179.428 3563.25 3665.05 19.898 4854.19 W . 5968736.89 N 77.18 E 0.000 19.89 8600.00 90.979 179.428 3561.54 3663.34 119.878 4853~ 19 W ' . '5968~36.92 N 556779.00 E 0.000 119.87 .' 8700.00 90.979 179.428 3559.83 3661.63 4852.19 W. 5968536.95 N 556780.82 E 0.000 219.86 8800.00 90.979 179.428 3558.12 3659.92 4851.19W' 5968436.98 N 556782.64 E 0.000 319.84 8900.00 90.979 179.428 3556.41 3658.21 4850.19W 5968337.01 N 556784.46 E 0.000 419.82 9000.00 90.979 179.428 3554.71 3656.51 849.19 W 5968237.04 N 556786.28 E 0.000 519.80 9100.00 90.979 179.428 3553.00 3654.80 848.19 W 5968137.08 N 556788.10 E 0.000 619.78 9200.00 90.979 179.428 3653.09 4847.19 W 5968037.11 N 556789.92 E 0.000 719.76 9300.00 90.979 179.428 3651.38 4846.19 W 5967937.14 N 556791.74 E 0.000 819.74 9400.00 90.979 179.428 7 4845.20 W 5967837.17 N 556793.56 E 0.000 919.72 9500.00 90.979 179.428 7 4844.20 W 5967737.20 N 556795.38 E 0.000 1019.70 9600.00 90.979 179.428 .6 4843.20 W 5967637.23 N 556797.20 E 0.000 1119.68 9700.00 90.979 179.428 3644.55 1219.668 4842.20 W 5967537.26 N 556799.02 E 0.000 1219.66 9800.00 90.979 179.428 3642.84 1319.648 4841.20 W 5967437.29 N 556800.84 E 0.000 1319.64 9900.00 90.979 179.428 3641.13 1419.62 S 4840.20 W 5967337.32 N 556802.66 E 0.000 1419.62 10000.00 90.979 179.428 3639.42 1519.608 4839.20 W 5967237.36 N 556804.48 E 0.000 1519.60 10100.00 90.979 179.428 3637.72 1619.588 4838.20 W 5967137.39 N 556806.30 E 0.000 1619.58 ~, 10200.00 90.979 179.428 3534.21 3636.01 1719.56 S 4837.20 W 5967037.42 N 556808.12 E 0.000 1719.56 10300.0 90 :ff,9'i)[e 179 .428 3532.50 3634.30 1819.548 4836.20 W 5966937.45 N 556809.94 E 0.000 1819.54 10400.0 . 90.979 179.428 3530.79 3632.59 1919.528 4835.21 W 5966837.48 N 556811.76 E 0.000 1919.52 10500.00 90.979 179.428 3529.08 3630.88 2019.50 8 4834.21 W 5966737.51 N 556813.58 E 0.000 2019.50 10600.00 90.979 179.428 3527.38 3629.18 2119.48 S 4833.21 W 5966637.54 N 556815.40 E 0.000 2119.48 10700.00 90.979 179.428 3525.67 3627.47 2219.46 8 4832.21 W 5966537.57 N 556817.22 E 0.000 2219.46 C) 10797.60 90.979 179.428 3524.00 3625.80 2317.05 8 4831.23 W 5966440.00 N 556819.00 E 0.000 2317.05 (TARGET: D-Mid-Pt) Begin Dir @ 2.0o/100ft: 10797.60ft MD, 3625.8( ::tcJ TVD Target -1C-104 (D-Mid-Pt), Curren1 -....."" .., Target C""-,) 1 0800.00 90.931 179.426 3523.96 3625.76 2319.448 4831.21 W 5966437.60 N 556819.04 E 2.000 2319.44 ~,,",,,., 10861.27 89.706 179.388 3523.62 3625.42 2380.71 S 4830.57 W 5966376.34 N 556820.18 E 2.000 2380.71 8tart Sail @ 89.71 ° : 10861.27ft M[ ----.. 3625.42ft TVD ~~'''3 1 0900.00 89.706 179.388 3523.82 3625.62 2419.448 4830.16 W 5966337.62 N 556820.91 E 0.000 2419.44 À r--- 22 January, 2002 -12:31 Page 3 of6 DrillQuest 2.00.09.006 C ::a::J ....-....... C":> ............ §: r--- Kuparuk River Unit Measured Depth Incl. Azim. (ft) 11000.00 89.706 179.388 11100.00 89.706 179.388 11200.00 89.706 179.388 11300.00 89.706 179.388 11400.00 89.706 179.388 11500.00 89.706 179.388 11600.00 89.706 179.388 11700.00 89.706 179.388 11800.00 89.706 179.388 11900.00 89.706 179.388 11909.80 89.706 179.388 11909.82 89.706 179.388 Sperry-Sun Drilling Services Proposal Report for Plan: 1C-104 -1C-104 L1 (wp02) Your Ref: Lower KOP to Minimize K13 exposure Revised: 22 January, 2002 Sub-Sea Vertical Depth Depth (ft) (ft) 3524.33 3626.13 3524.84 3626.64 3525.36 3627.16 3525.87 3627.67 3526.38 3628.18 3526.90 3628.70 3527.41 3629.21 3527.92 3629.72 3528.44 3630.24 3528.95 3630.75 3529.00 3630.80 3529.00 3630.80 orth Slope, Alaska Kuparuk 1 C Local Coordinates Global Coordinates Dogleg Vertical Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) 'OOft) 2519.43 S 4829.09 W 5966237.64 N 556822.80 E . 0.000 2519.43 2619.42 S 4828.02 W 5966J"~Z.66 N 56824.69 E 0.000 2619.42 2719.41 S 4826.95 W 5966037.68 N 826.58 E 0.000 2719.41 2819.41 S 4825.89 W 5965937.70 N 28.47 E 0.000 2819.41 2919.40 S 4824.82 W 5965837.72 N 556830.36 E 0.000 2919.40 4823.75 W 5965737.74 N 556832.25 E 0.000 3019.39 4822.68 W 5965637.76 N 556834.14 E 0.000 3119.39 ,4821.61 W 5965537.78 N 556836.03 E 0.000 3219.38 820.54 W 5965437.80 N 556837.92 E 0.000 3319.37 819.47 W 5965337.82 N 556839.81 E 0.000 3419.37 4819.37 W 5965328.02 N 556840.00 E 0.000 3429.16 4-1/2" Liner 4819.37 W 5965328.00 N 556840.00 E 0.000 3429.18 (TARGET: D-Toe) Total Depth: 11909.82ft MD, 3630.80ft TVD Target -1C-104 (D-Toe), Current Target All data is in Feet (US) unless otherwise stated. Dif8f5ns and coordinates are relative to True North. Vertical depths are relative to RKB = 101.8' (MSL). Northings and Eastings are relative to 1431' FNL, 625' FWL. The Dogleg Severity is in Degrees per 100 feet (US). Vertical Section is from 1437' FNL, 625' FWL and calculated along an Azimuth of 180.000° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 11909.82ft., The Bottom1r4fé Displace'fffènt is 5914.86ft., in the Direction of 234.567° (True). 22 January, 2002 - 12:31 ,-, Page 4 of6 DrillQuest 2.00.09.006 C ::::0 --- ~ --- ~ :J::::=. .--- 6740.00 3661.37 1694.78 N 4702.85 W 6752.00 3665.03 1686.29 N 4710.50 W 6770.00 3670.25 1673.40 N 4721.93 W 6944.33 3693.43 1528.19 N 4812.72 W 6966.06 3692.80 1508.05 N 4820.85 W 7226.49 3686.80 1253.37 N 4866.91 W 10797.60 3625.80 4831.23 W 10861 .27 3625.42 4830.58 W 11909.82 3630.80 4819.37 W Casing details Kuparuk River Unit Comments Measured Depth (ft) Station Coordinates TVD Northings Eastings (ft) (ft) (ft) To ed Vertical epth Depth (ft) (ft) 6740.00 11909.80 3661.37 3630.80 22 January, 2002 -12:31 Sperry-Sun Drilling Services Proposal Report for Plan: 1C-104 - 1C-104 L 1 (wp02) Your Ref: Lower KOP to Minimize K13 exposure Revised: 22 January, 2002 Comment 15.9°/100ft: 6740.00ft MD, 3661.37ft TVD Begin Rathole @ 73.12' (6" Hole): 6752.00ft MD, 3665.03ft TVD P.U. DirTools & Begin Dir @ 15.0'J/100ft: 6770.00ft MD, 3670.25ft TVD onlinue . @ 8.32°/100ft: 6944.33ft MD, 3693.43ft TVD West. D : 6966.06ft MD, 3692.80ft TVD GET: eel), Start Sail @ 90.98° : 7226.49ft MD, 3686.80ft TVD 'GET: D-Mid-Pt) Begin Dir @ 2.00/100ft: 10797.60ft MD, 3625.80ft TVD tart Sail @ 89.71 ° : 10861.27ft MD, 3625.42ft TVD (TARGET: D-Toe) Total Depth: 11909.82ft MD, 3630.80ft TVD Casing Detail 7-5/8" Csg Window 4-1/2" Liner orth Slope, Alaska Kuparuk 1 C ---" Page 5 of6 DrillQuest 2.00.09.006 C ::tJ ---- ~ --- :<: ~ r--- Kuparuk River Unit Targets associated with this wellpath Target Name 1 C-1 04 (D-Heel) 1 C-1 04 (D-Mid-Pt) 1 C-1 04 (D-Toe) 1C-104 Geo-Poly 22 January, 2002 -12:31 Sperry-Sun Drilling Services Proposal Report for Plan: 1 C-104 - 1 C-104 L 1 (wp02) Your Ref: Lower KOP to Minimize K13 exposure Revised: 22 January, 2002 Target TVD (fUiit&- 3686.80 1'~53.37 N 4866.91 W Mean Sea Level/Global Coordinates: 3585.00 5970010.00 N 556754.00 E Geographical Coordinates: 700 19' 43.3549" N 1490 32' 22.9548" W 3625.80 2317.05 S 4831.23 W Mean Sea Level/Global Coordinates: 3524.00 5966440.00 N 556819.00 E Geographical Coordinates: 70019' 08.2370" N 1490 32' 21.8461" W 3630.80 3429.18 S 4819.37 W Mean Sea Level/Global Coordinates: 3529.00 5965328.00 N 556840.00 E Geographical Coordinates: 700 18' 57.2982" N 149032' 21.4789" W 3739.80 1253.37 N 4866.91 W Mean Sea Level/Global Coordinates: 3638.00 5970010.00 N 556754.00 E Geographical Coordinates: 700 19' 43.3549" N 1490 32' 22.9548" W Target Boundary Point #1 3739.80 1253.16 N 4841.91 W #2 3739.80 2317.25 S 4806.23 W #3 3739.80 3429.39 S 4794.37 W #4 3739.80 3428.98 S 4844.37 W #5 3739.80 2316.84 S 4856.23 W #6 3739.80 1253.57 N 4891.91 W Mean Sea Level/Global Coordinates #1 3638.00 5970010.00 N 556779.00 E #2 3638.00 5966440.00 N 556844.00 E #3 3638.00 5965328.00 N 556865.00 E #4 3638.00 5965328.00 N 556815.00 E #5 3638.00 5966440.00 N 556794.00 E #6 3638.00 5970010.00 N 556729.00 E Geographical Coordinates #1 700 19' 43.3530" N 1490 32' 22.2249" W #2 700 19' 08.2351" N 149032' 21.1165" W #3 700 18' 57.2964" N 149032' 20.7495" W #4 70018' 57.3001" N 1490 32' 22.2084" W #5 700 19' 08.2388" N 1490 32' 22.5756" W #6 700 19' 43.3567" N 1490 32' 23.6847/1 W Page 60f6 orth Slope, Alaska Kuparuk 1 C Target Target Shape Type Point Current Target Point Current Target Point Current Target Polygon Current Target ~~, DrillQuest 2.00.09.006 SpeÍry-Sun Drilling Sd,vices Proposal Data - Plan: 1C-104 -1C-104 L1 (wp02) : MD ¡ Delta I Inclin. Azimuth i TVD Northings I Eastings ; Dogleg: TooIface ! , (ft) ; MD (ft): (°) (O): (ft), (ft) (ft) ¡ (°/1 oatt) (O) ; . ' ;- "-.'.."."...'"'''..''''''''' ,'.. --..'.'.,'¡'~""''''._''.':'''''''. T...'..-..,....."."'."..".:.. --."--'-.-"-. -".".. '.'-.. -c".I_'-....""...........','.".'.'..,..'.'...",.-. ~.'.-. ..-. ''',''.'...'''......'.''.'.... .'-. ..'."..... -". .... ,. , . -,--....'.,".-:'" -. ...., -.-...."': ..,,".. '" '....1. , .... ."" . ..- ... ...j -1 6740.001, 't:71.460'222.554 3661.37 1694.78N' 4702.85W ,: i ""2' "..-- ~75i:Oo"""" '1'2~oòl" 7i{1'!5~-22i55i"'''3665.Ö3-:-1-6åEi;29:N'''''4i1(i5Õ''v.T 15.90'01' 330.ö60'¡ 3 6770.00 18.001 73.115 221.557, 3670.25 1673.40 N 4721.93 W 0.0001 0.0001 4' ' '6944:33, 174.33 91.675 202.884, 3693.43' 1528;19 N 4812.72 W 15.000 313.436! .. . . 1 5T'7226.49 : 282.16 90.979 179.428 3686.80 1253.37 N 4866.91 W 8.315 268.598! ¡ 6T ¡ 10797~6013571.111:90.9791 '179.4281 3625.801 2317.0581 4831.23W 0.0001" 0.0001 ,7 10861.27' 63:67 89.706 179.388 3625.42 2380.71 S 4830.57 W 2.000 181.7981 I, 8T 11909~821048.55 '89.706 179.388' 3630.80 3429.188 4819.37 W 0.000' 0;000\ 25 February, 2002 - 14:51 - 1 - C1/G ~ SpeA-y-Sun Drilling SJrvices Proposal Data - Plan: 1C-104 -1C-104 L1 (wp02) , I I MD Delta I Inclin. Azimuth: TVD ¡ Northings Eastings Dogleg; Toolface : : (ft) MD (ft): (°) (°) i (ft): (ft) (ft) (0/1ooft) (°) , l"."'='1""""'~-'~' 67~~§I.:~:.".~~'~.:7.'~:~:r~~;~~.~222l)83'L~~~~§! :..':'~$~?~~?:~~~~~~~~}-:-~~::~ ! 2 '. 6752.00 12.00173.t15'..22~.Q873563.23. 5970444.20 N.556906.85 E. ! 3 6770.00 18.00 I 73.1.15., 221.087: 3568.45 597~1.21 N 556895.53 E 4' 6944~33:" 174.3~ .91.675" 202.413 3591.63. .5970285;26 N 556805.93 E 5T' " 7226.49' :282.16 90.979 178.957 3585.00 5970010.00 N 556754.00 E I 6T !10797.60j:357f.11 "90.979 17R957 3524.001 5966440.00 NI 556819.00 EI 7 1 0861 ~27 . . 63.67 89.706 . 178.917 3523.62 5966376.34 N 556820.18 E I 8T 11909.82 1048.55 .89.706 178.917 3529.00 5965328.00 N 556840.00 E 25 February, 2002 - 14:51 - 1 - I 15.900' ':'330:"öÖOj 0.0001 0.0001 15.000. . . 313A36 8.315. 268.598 0.0001 0.0001 2.000 181.798\ 0.000 0.000. O"'t ". ... . DrillQLiest . r1'/lifllVA :::J C/) ::2: ~ 0 ..- II CD ~ C ~ J:: ã. ::0 Q) 0 ~""" (ij c-:> 0 :e Q) --.,.,.. > ~~ [i~ Well: Horizontal Coordinates: ReI. Global Coordinates: 5968796.65 N, 561631.04 E Ref. Stucture Referance : 280.27 N, 738.73 W Ref. Geographical Coordinates: 70° 19' 31.0425' N, 149° 30' 00.8575" W 1437' FNL & 625' FWL, SEC. 12 - T11N - R10E t~i~ii~~> ~rtr~\¡ lo... I.-.~_c:" / .. """'"III'" ~. "~""~,~,.."'''- RKB Elevation: North Reference: Units : Phillips Alaska, Inc. Kuparuk River Unit 1 C Pad Eastings -6300 I Scale: 1 inch = 1800ft -9900 I -8100 I -4500 I -2700 I Top 01 Whipstock (7-518" Csg) Begin Dir @ 15.9°/1000: 6740.001t MD, 3661.37ft TVD Begin Rathole @ 73.12° (6" Hole) : 6752.001t MD, 3665.031t TVD P.U. DirTools & Begin Dir @ 15.0o/1001t: 6770.COIt MD, 3670.251t TVD Continue Dir @ 8.32°/1001t: 6944.331t MD, 3693.431t TVD Top West Sak D ~ lel(k¡ (TARGET\ D-H~I), Start San 0 90.98" \ 7226.49ft MD, 3666.'011 lVD ! ~ U.,"" 'M,,~~/) Ii' G77.°1 lfi5' ;~i1.;!J I~I~"~): J;~t/,,,,~~); '~~~~':/y~~ JilFj 1 C-1 04 (wp02) 1800 - Reference is True North 0-""'"'''' ....i.. ~ ã . '." .~3659J} ... ¡ 0 , .f> ' ; ~ .ð ~ (TARGET: D.Mid.Pt), § ¡' Begin Dir @ 2.0o/100ft : 3642.6 10797.601t MD, 3625.8Oft TV~~¡(":5.gfj:'~';;'{):J':;:;~~~~Pj~:¡U,! w ~ II.':?I' 1''<;1.& 10/1' rIft. .,FC. JP'IIS.RlOlt, d~ Start S.' . 69."" \ 106612711 Me, 3625.4211 lV " '''"' g (TARGET: D-Toe) Total Depth: 11909.821t MD, 3630.80ft TV~ n ~, . ~\.~:O,2 ~;~g~.~i;I~D {.lIZ' {',';¡,J( 3630.8ft TVD Current Well Properties Plan: 1C-104 en C> c: :ë t: 0 Z 101.801t above Mean Sea Level True North Feet (US) .1800 - ar"""y-5UI1 C:F:t (L.:L~ I'N G:' 's fE. R V I t:EÙ~ A Hamburton Company ¡ ì$'" : ", '. ~Q ~Q Q0~Q Top of Whipstock (7-5/8" Csg) Begin Dir @ 15.9°/10Oft: 6~40.00ft MD, 3661.37ft TVD -",ò'~,Ç)~~Ç)~ 0" þ..'J,,~ ,\O<Þ~Ç)~ ¡ Q'''''' G 'j:)"fi "\" fJ-';)' 01 ~. End Dir, Start Sail @ 73.12° : 6752.001t MD, 3665.031t TvD Æ'. @'J,,;...,'!3 'ò'?r nJO ^' ,\0 r§:>'S ¡ 0'V-'~ ~V\ . @.~, '.v.~, Begin Dir @ 15.0o/10Oft: 6770.001t MD, 3670.25ft'TVD ^~.~ Çj,Ø' d~A.~"'" r£- ~"". ; \..' ~ (\~ ~-J 'J,,' ~v iv' Continue Dir @ 8.32°/10Oft: 6944.33ft MD, 369?.4311 TVD <Q0 ~'b c",'l} &,1(". ~'f çP'b' ¡ ",<:s ," / Top West Sak D ¡ ~/ (TARGET: D-Heel), Start Sail @ 90.98.~ : 7226.4911 MD, 3686.801t TVD . /0 ~ 4-1/2' Line, f ¡"" <:> ? ~ . r;:,? r;:,? 11909.8HMD ¡§>? ",? d;~9 <§>? $<:>'" 8;,<:>",. ¡¡.()()' fò"() é::'O 1 C-104 L 1 (wp02).<:5 ...:f..f7 .....:.Ji! ,36:,O.8ft TVD ~ 0~. (;/' , <:5 /I ~~ ....... fi ~ .:.. . o¡¡ .. c '<>.. .. q¡ . ~... fi"\ It. z-... ... . ,)' 7.5/8" (''''9 WindOW '1/ 'i1" " "! lC-l04 (wp01) 6'T40.()ft MD " . ," . "".<" TV<> '" !C.IIN ; IC.IM (lJ.MiN't> / . " ,. "I,'.IM ,D. I..,) '" ' 1686.S0 Hi ¡ 3625.80 23J7J}5 483f.23 W . 3(d),f,(j 1 \ V. 3429.18 ./8J.1.3/ H. (/8,)' ~F/:;j, &. FWL, UNTl1NN'IWJEj i (1524' F.5L & f¡'-lIliV.maE) (411' FSL c'( W83' FWL, J.f.Tl¡,V.IWŒ) i 0 -2100 I 2450 - 3150- 3850 - I -2100 Drill Quest 2.00.09.006 Scale: 1 inch = 700ft -3600 - I -9900 I -8100 I -6300 I -4500 I -2700 -1400 I -700 I 0 I 700 I 1400 I 2100 I 2800 I 3500 I I -1400 I -700 I 700 I 1400 I 2100 I 2800 I 3500 SectIon .I\zimuth: iBCLOODG - 1800 .- 0 -... - -1800 - -3600 - 2450 :::J C/) ~, ::2: ~ 0 ..- II - 3150 CD ~ ~ J:: ã. Q) 0 (ij 0 :e Q) > - 3850 C'~' :J: ....""',;C- ~" """"",, ~, <." ::E;:;:::"" ~"""ã Phillips Alaska, Inc. 1C*104 L1 (wp02) MD Inc Azim. SSTVD TVD NIS EIW Y X DLS V.S. Comment (ft) (Deg) (Deg) (ft) (ft) (ft) (ft) (ft) (ft) (0/100ft) (ft) 0.00 0.00 0.00 -101.80 0.00 0.00 N 0.00 E 5968796.65 N 561631.04 E 0.00 0.00 SHL 250.00 0.00 0.00 148.20 250.00 0.00 N 0.00 E 5968796.65 N 561631.04 E 0.00 0.00 Begin Dir @ 3.5°/100ft (9-7/8" Hole) 478.57 8.00 0.00 376.03 477.83 15.93 N O.OOW 5968812.58 N 561630.91 E 3.50 -15.93 Increase in Dir Rate @ 5.00/100ft 1178.57 39.53 308.70 1012.48 1114.28 210.02 N 179.47 W 5969005.18 N 561449.85 E 5.00 -210.02 Decrease in Dir Rate @ 3.00/100ft 1628.57 51.59 300.14 1327.26 1429.06 388.91 N 444.94 W 5969181.89 N 561182.92 E 3.00 -388.91 Increase in Dir Rate @ 6.00/100ft 1868.57 64.34 292.21 1454.44 1556.24 477.47 N 627.37 W 5969268.95 N 560999.77 E "'0.00 -477.47 End Dir; Start Sail 2294.81 64.34 292.21 1639.00 1740.80 622.69 N 983.08 W 5969411.24 N 560642.88 E 0.00 -622.69 Base Permafrost 3569.66 64.34 292.21 2191.00 2292.80 1057.02 N 2046.98 W 5969836.82 N 559575.45 E 0.00 -1057.02 Top K-15 5514.27 64.34 292.21 3033.00 3134.80 1719.54 N 3669.82 W 5970485.99 N 557947.22 E 0.00 -1719.54 Top Ugnu C 5753.57 64.34 292.21 3136.62 3238.42 1801.07 N 3869.53 W 5970565.88 N 557746.85 E 0.00 -1801.07 Begin Dir @ 6.0°/1 0 Oft 6046.31 63.07 272.65 3267.32 3369.12 1857.41 N 4124.04 W 5970620.12 N 557491.89 E 6.00 -1857.41 End Dir; Start Sail 6080.94 63.07 272.65 3283.00 3384.80 1858.83 N 4154.87 W 5970621.29 N 557461.04 E 0.00 -1858.83 Top Ugnu B 6186.91 63.07 272.65 3331.00 3432.80 1863.20 N 4249.25 W 5970624.88 N 557366.63 E 0.00 -1863.20 Top Ugnu A 6248.81 63.07 272.65 3359.04 3460.84 1865.75 N 4304.38 W 5970626.98 N 557311.48 E 0.00 -1865.75 Resume Dir @ 9.5°/100ft 6581.32 66.99 237.96 3503.00 3604.80 1789.48 N 4589.41 W 5970548.37 N 557027.09 E 9.50 M 1789.48 KM13 6740.00 71.46 222.55 3559.57 3661.37 1694.78 N 4702.85 W 5970452.75 N 556914.43 E 9.50 -1694.78 Top of Whipstock (7-5/8" Csg) 6752.00 73.12 221.56 3563.23 3665.03 1686.29 N 4710.50 W 5970444.20 N 556906.85 E -15.90 -1686.29 Begin Rathole (6" Hole) 6770.00 73.12 221.56 3568.45 3670.25 1673.40 N 4721.93 W 5970431.21 N 556895.53 E 0.00 -1673.40 Begin Dir @ 15.00/100ft 6944.33 91.68 202.88 3591.63 3693.43 1528.19 N 4812.72 W 5970285.26 N 556805.93 E 15.00 -1528.19 Continue Dìr @ 8.32"/100ft 6966.06 91.63 201.08 3591.00 3692.80 1508.05 N 4820.85 W 5970265.05 N 556797.97 E 8.32 M1508.05 Top West Sak 0 7226.49 90.98 179.43 3585.00 3686.80 1253.37 N 4866.91 W 5970010,00 N 556754,00 E 8.32 -1253.37 (TARGET: D-Heel); Start Sail 10797.60 90.98 179.43 3524.00 3625.80 2317.05 S 4831.23 W 5966440.00 N 556819.00 E 0.00 2317.05 (TARGET: D-Mld-Pt) Begin Dir @ 2.0o/100ft 10861.27 89.71 179.39 3523.62 3625.42 2380.71 S 4830.58 W 5966376.34 N 556820.18 E 2.00 2380.71 Start Sail @ 89.71" 11909.82 89.71 179.39 3529.00 3630.80 3429.18 S 4819.37 W 5965328.00 N 556840.00 E 0.00 3429.18 (TARGET: O-Toe) Total Depth Sperry-Sun Anticollision Report Company: Field: Reference Site: Reference WeD: Reference WeDpath: Phillips Alaska Inc. Kuparuk River Unit Kuparuk 1 C Pad Plan: 1 C-1 04 1C-104 L1 Date: 2/25/2002 Time: 14:46:14 Page: 1 Co-ordinate(NE) Reference: Vertical (TVD)Reference: Well: Plan: 1C-104, True North 1C-104 @ 101.8101.8 GLOBAL SCAN APPLIED: All weDpaths within 200'+ 100/1000 of reference Interpolation Method: MD Interval: 50.00 ft Depth Range: 6740.00 to 11914.11 ft Maximum Radius: 1387.29 ft Reference: Error Model: Scan Method: Error Surface: Db: Sybase Principal Plan & PLANNED PROGRAM ISCW SA Ellipse Trav Cylinder North Ellipse + Casing Survey Program for Definitive Well path Date: 1/22/2002 Validated: No Planned From To Survey ft ft 41.20 900.00 900.00 6740.00 6740.00 11909.82 Version: Toolcode 0 Tool Name Planned: 1C-104 L1 (wp02) V1 ( Planned: 1C-104 L1 (wp02) V1 ( Planned: 1C-104 L1 (wp02) V1 CB-GYRO-SS Camera based gyro single shots MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC Casing Points 1\10 TVD ft ft 6740.00 3661.51 11909.82 3686.94 Diameter in Hole Size in Name 7.625 4.500 9.875 6.000 7-5/8" 4-1/2" Summary <---------------------- Offset Wellpath ----------------------> Site Well Well path Kuparuk 1 C Pad Kuparuk 1 C Pad Kuparuk 1 C Pad Kuparuk 1 C Pad Kuparuk 1 D Pad 1 C-119 1C-121 1 C-125 Plan: 1 C-1 04 1 D-112 1 C-119 VO 1C-121 V1 1C-125 V3 1C-104 V6 Plan: 1C-104 1D-112 V2 Reference Offset Ctr-Ctr No-Go Allowable MD MD Distance Area Deviation Warning ft ft ft ft ft 8174.51 6350.00 836.18 120.41 716.58 Pass: Major Risk 10031.30 6450.00 835.76 157.55 682.86 Pass: Major Risk 11908.07 7100.00 781.01 237.15 551.39 Pass: Major Risk 6750.00 6750.00 0.00 0.44 -0.44 FAIL: No Errors Out of range ¡ U 'å , \.II Î , ..~ L. Name Plan: IC-I04 <:::) ::0 .............,.... 50 ~ ~ -2Lss ~".. -~ C"~ ~ r--. +N/-S 280.37 .738.78 5968796.65 --:55 -50 "'-"40 -30 ""'''-20 -10 -0 -10 '-20 -30 ---'40 +EI-W WEU.DETAlLS ANTI-COLLISION SETnNGS Deplh I'm DcpUl To Survcyll'lan 6740.00 11909.82 Pbnned: IC.I04 L1 (wp02) VI MWD+IFR-AK.CAi',SC Northing Basting Latitude Long~ude Slot 561631.04 70"19'31.042N 149'30'00.857W NIA nterpolation MethodMD Interval: 50.00 Jepth Range From: 41.20 To: 11909.82 Maximum Range: 1387.29 Reference: Plan: I C-I04 Ll (wp02) 270 See MD Ine 6740.00 71.46 222.56 6752.00 73.12 221.56 6770.00 73.12 221.56 6944.33 91.68 202.88 7226.49 90.98 179.43 10797.60 90.98 179.43 10861.27 89.71 179.39 11909.82 89.71 179.39 Travelling Cylinder Azimuth (TFO+AZI) [deg] vs Centre to Centre Separation [20ft/in] SUR Vb)' PROGRAM Tool From Colour ToMD 6740 6800 6800 6900 6900 7000 7000 7200 7200 7400 7400 7600 7600 7800 7800 8000 8000 8200 8200 8400 8400 8600 8600 8800 8800 9000 9000 9500 9500 10000 10000 10500 10500 II 000 11000 11500 11500 12000 ..-.",,, Plan: IC.104 LI (wp02)(P~Ill: IC- 104/IC-104 LI) Created By: I>ave Egedald Cheekc'<l: 1>.",: 2/2512002 D3Ic:__- Revicwcd:___- (}Jte:_- ()"tc:~- Approved: COMPANY DETAILS 90 I'hill,.s Alaska Inc. I:.nginccring KuparuI< Calculation Method: Mininum CUfY'.tlure Enur System: ISCWSA Scan Method: Trav Cylinder North Error Surface: EII.,ticnl + Casing Wllming Method: Rule>; ßw¡ed WH.LI' A TH )Jif All.~ IC.I04I.1 Parent W clJp¡¡lh: TicoIlMD: IC-I04 674O.(X) Rig: IC.104 @ 101.8 Ref. Datum: 101.801^ V.SC>C~}ß ~~~ ;¡~~ ~'~~:fv Angle 234.57' o.m 0.00 o.m .1C-.1041~.l (wp02) Approved Plan SECTION Dh'TAILS A,j TVD +N/.S +E/.W IJI.cg l1";'acc VSec Target 3661.51 1694.92 .4702.73 (WO O.!X) 2849.21 3665.16 1686.44 .4710.38 15.93 330.07 2860.37 3670.39 1673.55 -4721.81 0.00 0.00 2877.16 3693.55 1528.33 -4812.60 15.()() 313.42 3035.32 3686.91 1253.51 -4866.79 8.31 268.59 3238.79 3625.83 .2316.90 -4831.27 O,()() o,()() 5279.73 3625.45 .2380.57 -4830.61 2.m 181.1!O 5316.11 3630.75 -3429,(14 .4819.45 0.00 0.00 5914.85 DRAFT GEOLOGIC SUMMARY: Primary Target: West Sak B Sand Formation 1C-104 (X7) Heel Mid-point Toe Target Shape: Responsible: Mike Werner - 6191 x y Z (TVD.SS) Porosity 3,638' 3,580' 3,585' Approximate Stepout: Remarks: Target depths are 8 feet below the top of the B Secondary Target: West Sak D Sand Formation 1C-104L1 (X7) Heel Mid-point Toe Target Shape: 556,754 5,970,010 556,819 5,966,440 556,840 5,965,328 Rectangle +/-25' east/west x y Perm 4683 horizontal 1 C-1 04 0 Complete Reservoir Preferred Temp. Tar. Angle Net Pay: 26 Perm 4683 horizontal Remarks: Target depths are 14 feet below the top of the 0 Geological Prognosis: Responsible: Mike Werner - 6191 Formation X Y Z (TVD.SS) MD Pay 1C-104 (wp01) Base Permafrost Top K-15 Top Ugnu C Top Ugnu B Top Ugnu A k13 Top West Sak 0 C B B Sand Heel Mid-point B Sand Toe 556,754 5,970,010 556,819 5,966,440 556,840 5,965,328 Rectangle +/-25' east/west 560,644 559,575 557,948 557,460 557,365 557,023 556,856 556,806 556,767 556,754 556,819 556,840 5,969,411 5,969,837 5,970,486 5,970,621 5,970,624 5,970,544 5,970,372 5,970,276 5,970,150 5,970,010 5,966,440 5,965,328 Responsible: Mike Werner - 6191 Z (TVD.SS) Porosity 3,585 3,522 3,529 Approximate Stepout: 1,639' 2,191' 3,033' 3,283' 3,331' 3,503' 3,588' 3,612' 3,632' 3,638' 3,580' 3,585' 2,295' 3,570' 5,514' 6,081' 6,187' 6,581' 6,838' 6,943' 7,081' 7,231' 10,802' 11,914' 26 26 26 1 C-1 04L 1 (wp02) k13 557,018 5,970,544 3,503' Top West Sak 0 556,818 5,970,312 3,591' 6,966' 0 Sand Heel 556,754 5,970,010 3,585' 7,226' 30 Mid-point 556,819 5,966,440 3,524' 10,798' 31 0 Sand Toe 556,840 5,965,328 3,529' 11,910' 29 Remarks: 1C-104 prognosis based on wp1 dated 1/14/02. Mid-points to 104 and 104L1 added 1/17/02. 1C- 104L 1 West Sak D revised to wp2 dated 1/21/02 Offset Pressure Data: Responsible: Mavriky Kalugin - 4440 0 Date of Meas. 8/26/2001 12/28/2001 11/5/2001 Well Type 1 C-111 1 C-125 1 C-121 Injector Fluid Prod Water Prod Water Prod Water PSI 1560 1705 1777 MD 6,340' 6,900' 6,690' TVD 3,778' 3,706' 4,056' Reservoir Preferred Temp. Tar. Angle Net Pay: 30 0 Complete Frm Press Frac Press Complete Measurement Method SBHP dunk SBHP dunk SBHP dunk Estimated: This Well 1639 tbd 3740 1/15/2002 Estimate. Remarks: Pressure estimate at deepest point in geologica! prognosis plus 102 feet for consistency. 1/22/20026:07 PM ORiGiI L Tubing Head Assy, (497-0055) Vetco-Gray Gen \I for Single Completion, API 13-5/8" 5000 psi Flange up x Vetco 13-5/8" Female Overshot Bottom Casing Head:../' l ~ Vetco-Gray, 16" Weld on Bottom x ~ 13-5/8" Male Overshot Top ~ 16" Conductor ~ @ +/-158' MD Centralization: Weatherford 7-5/8" x 1 0-1/2" Bowspring (1) on each collar from 4000' to Float Collar (1) on a stop collar in the middle of the joint below the float collar (1) on a stop collar in the middle of the joint above the float shoe (1) on each of the three collars above and below the port collar PHILLIPS PHilliPS Alaska, Inc. A Subsidiary of PHILLIPS PETROLEUM COMPANY Nabors Rig 245 RKB @ 0' Eastings: 561,631.04 Northings: 5,968,796.65 Elevation: 101.8' AMSL l-r ~ ~,,~ I I! ~ I I I I I I I I I I I I I I I I I I I ~ ~ ~ I I I I I ~ ~ I I 2 g I I ~ I I ~ (x) Pup Joints Casing: I ~ 7-5/8",29.7#, L-80, BTCM, as ~ I ~ required to space out window I ~ joint. I ~ (498-6805) 4 foot pup I I (498-6800) 6 foot pup I I (498-6795) 10 foot pup I I ~(477-8475) 20 foot pup I I I I (x) Joints Casing: ~ I (463-4825) 7-5/8", 29.7#, L-80, BTCM I I I I I I I ~ I I I I I I I § ~ ~ Float Collar: r- ~ « Weatherford Model 402, 7-5/8", 29.7#,BTCM I ~ (463-4827) Joint with Float Shoe I I (2) Joints Casing: ~ ~ ( 7-5/8",29.7#, L-80, BTCM I ~ (463-4828) Joint with Thread Locked I I Box ~ ~ ~Float Shoe: ~ Weatherford Model 303, 7-5/8", 29.7#, BTCM 7-5/8" Shoe: (463-4826) Joint with Float Shoe 7,231' MD /3,740' TVD +/- 91 degrees TD 9-7/8" Hole: 7,231' MD /3,740' TVD Casing Hanger: (497-0030) Vetco-Gray, with 7-5/8",29.7#, BTC pin down x Acme box up Port Collar: (485-7080) TAM, 7-5/8", 29.7#, L-80, BTC Pin Set @ +/- 1,000' MD / 968' TVD Planned Top of Whipstock @ 6,740' MD West Sak WeIl1C-104, AFC AK xxxx Planned Completion Schematic Sheet 1 of 4: Surface Casing Details prepared by Todd Mushovic DRAFT 0 11/ tir¡V¡ifo1 ~".tJ g::I: ~¡:: -<I f;l.... :E"'tJ t=cn ~» m- ~Q) pm m~ ~Q) 0" 0- 5:::;:, j; zn ,. ~ en"O(þ :T_ø (þD)r+ (þ:Jen r+:JD) N(þ" OQ.~ ;O(þ .. 0 - .3::: O~O c:: (þ I <r+-'" (þ -. 0 "'O.þ. . :J .. -. en » :J(")"11 ~:TO o(þ» (þ3"'r r+D).n !. ~ >< ti(")= >< a~ ~ ~..~ê'. Q) 1 ~ "'" ' CD ~. 0.. ~.~.~ ~ ~ ,:=3 ::-I ~ t:: <:) Q) 0. --""". ~ Q. ,%~:w s: ~? t:q~ ." -.1'1;) ~ ~ ü" --.g " ~ -'- -i ('). Top of Whipstock to be @ +/-6,740' MD See Sheet 1 for Casing Details Liner Top Packer Set @ +/- 7,000' MD Surface / Production Casing 7-5/8" 29.7# L-80 BTC Mod Set @ 7,231' MD (1) Set Shoe Assembly, Baker, consisting of: (1) Set Shoe, Baker Model 'GPV', 5.560" Max 00,5",18# SLHT Box. (1) 18.5 ft Pup Joint, 5", 15#, SLHT, with weephale. (1) Crossover, 4",11.6#, SLHT Box x 5",18#, SLHT Pin (2) Joints 4"Blank Pipe, 4",9.5#, L-80, SLHT. (x) joints 4" x 4-1/2" Screen, Baker Excluder 2000,4",9.5#, SLHT (Screen OD = 4.9") alternating every other joint through the production zone with (x) joints 4" Blank Pipe, 4",9.5#, L-80, SLHT as required from 'GPV' Set Shoe Assembly to 7-5/8" casing shoe. ~ (x) Joints 4" Blank Pipe, 4",9.5#, L-80, SLHT, as required inside the 7-5/8" Casing to space out the packer +/- 80 feet below the bottom trip anchor of the whipstock assembly (i.e. 103 feet below the top of the whipstock. Top of the whipstock is planned for 5942') (1) Crossover Sub, 4-1/2",11.6#, SLHT Box x 4",9.5#, SLHT Pin. (1) Joint 4-1/2" Blank Pipe, 4-1/2",11.6#, L-80, SLHT (1) Sliding Sleeve, Baker Model 4-1/2" 'CMO', w/3.43" ID, 4-1/2", 11.6# SLHT Box x Pin (1) Joint 4-1/2" Blank Pipe, 4-1/2", 11.6#, L-80, SLHT. (1) Crossover Sub, Baker, 5", 18#, SLHT Box x 4-1/2", 11.6#, SLHT Pin (1) KOIV (Knockout Isolation Valve), Baker Model 'C', 5",18#, SLHT Box x Pin (1) Packer Assembly, Baker, cansisiting of: (1) Crossover Sub, Baker, 5-1/2", 17#, SLHT Box x 5" 18# SLHT Pin (1) Mill Out Extension, Baker, 3' Long, 5-1/2", 17# SLHT pin x pin (1) Packer, Baker Model 'SC1-R' (76B2-40), 7-5/8", 24-29.7#, w/5-1/2", 17#, SLHT box down. III~=~~~=~~=~=~=~~=~=~~~= I I~~~~~~~~~~~~~ ~ I~~~~~~~~~~~~~ 3 ) 6-3/4" Open Hole TD: +/-11,914' MD /3,687' TVD ~'"tI &:r:: 15:- iii' .... ~.... 9.- ~'"tI ¡:C/) ~:Þ m- :riD,) ?2cn m~ ~D,) a'" °- ~:1 zn -<. :e ( )-aCD ::r_( ) CD D)"" CD:J( ) "":JD) WCD" OQ.:e ;OCD .. 0 - .3:: 0"2.0 c:::: CD I <.......Jo, CD -. 0 ..,O.þ. . :J .. -. ( ) » :J(')." ~::r0 OCD» CD3-r ....D)~ !. !:to >< -(')>< ( ) >< >< c ~ ::.t:'tJ ~""J Q) -. .;j èi3 ~".., Q.. ~'fu- ~ ~..;:, :::-I ~~i 8- ;:=i' -< Q. - -".<..) :š: ~" ~ Q c: c~~ ÃJ ~ ~~~~ .. -.},. -I õ' (1) Liner Hanger, Baker Flanged Hook Hanger, Size 7-5/8" x 4-1/2",4-1/2", 11.6#, BTC Pin Down (1) Swivel Sub, Baker, 4-1/2", 11.6#, BTC Box x Pin (1) Crossover, Baker, 4-1/2",11.6#, BTC Box x 4-1/2",12.6#, IBT Pin (x) Joints 4-1/2" Blank Pipe, 4-1/2",12.6#, L-80, IBTM. (1) ECP I Indicator Sub Assembly, Baker, consisting of: (1) Handling Pup, 8', 4-1/2",11.6#, L-80, IBTM Box x BTC Pin (1) Indicator Profile Sub, Baker, 10K-15K Snap Force, 4-1/2",11.6#, L-80, BTC, Box x Pin (1) Handling Pup, 6'Iong, 4-1/2",11.6#, L-80, BTC Box x Pin (1) ECP (External Casing Packer), Baker Model CTC 20' Payzone, 4-1/2",11.6#, L-80, BTC Box x Box (3.833 Min ID). (1) Bottom Sub, Baker, 3' long, 4-1/2", 11.6#, L-80 BTC Pin x 4-1/2", IBTM Pin (x) Joints 4-1/2" Blank Pipe, 4-1/2", 12.6#, L-80, IBTM. D Sand Heel at +1- 7,226' MD, 3,687' TVD Top of Window at +1- 6,740' MD, 3,661' TVD Liner Top Packer Set @ +1-7,000' MD 13,724' TVD (1) ECP I Indicator Sub Assembly, Baker, consisting of: (1) Handling Pup, 8', 4-1/2", 11.6#, L-80, IBTM Box x BTC Pin (1) Indicator Profile Sub, Baker, 10K-15K Snap Force, 4-1/2",11.6#, L-80, BTC, Box x Pin (1) Handling Pup, 6' long, 4-1/2",11.6#, L-80, BTC Box x Pin (1) ECP (External Casing Packer), Baker Model CTC 20' Payzone, 4-1/2", 11.6#, L-80, BTC Box x Box (3.833 Min ID). (1) Bottom Sub, Baker, 3' long, 4-1/2", 11.6#, L-80 BTC Pin x 4-1/2", SLHT Pin (1) Joint 4-1/2" Blank Pipe, Baker, 4-1/2", 11.6#, L-80, SLHT (1) Sliding Sleeve, Baker Model 4-1/2" 'CMD', w/ 3.43" ID, 4-1/2", 11.6# SLHT Box x Pin (1) Joint 4-1/2" Blank Pipe, Baker, 4-1/2", 11.6#, L-80, SLHT (1) Crossover Sub w/4-1/2", 11.6#, SLHT Box x 4",9.5#, SLHT Pin (1) Joint 4" Blank Pipe, 4", 9.5#, L-80, SLHT. (x) joints Screen, 4" x 4-1/2" Baker Excluder 2000, 4",9.5#, SLHT alternating every other joint through the production zone with (x) joints 4" Blank Pipe, 4", 9.5#, L-80, SLHT as required from 'GPV' Set Shoe Assembly to Model 'CMD' Sliding Sleeve. (2) Joints 4" Blank Pipe, 4", 9.5#, L-80, SLHT Blank Pipe. (1) Crossover Sub, Baker, 4",9.5#, SLHT Box x 5",18#, SLHT Pin (1) Joint 5" Blank Pipe, 18.5' long, Baker,S", 18#, L-80, SLHT, w/ Drillable Packoff Bushing (1) Crossover Sub, Baker,S", 18#, SLHT Box x 3-1/2",9.2# SLHT Pin (1) Joint 3-1/2" Bent Pipe, Baker, 3-1/2", 9.2#, L-80, SLHT, Length 18.5'. (1) Set Shoe, 3-1/2", Baker Model 'GPV', (4.50" Max OD), 3-1/2", 9.2#, SLHT Box. 1_------------ I I------------~ T~ =~~~~~~~~~~~~ ~~~~~~~~~~~~~ r ) Suñace I Production Casing 7-5/8" 29.7# L-80 BTC Mod Set@ 7,231' MD 13,740' TVD 6" Open Hole TD: 11,910' MD I 3,631' TVD See Sheet 2 for Lower Lateral Liner Details II i I~=~=~~~~=~=~=~=~=~=~;: Tree Assembly, Vetco Gray Gen II, API 13-5 5000 psi Flange Down 1/16" 5000 Studded T with Penetrators 18 - x4- op, " ¡ , ! , ! ' , ¡ ¡ - r!J ' ¡ 'JI VI ~ ~ ~ I ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ I ~ I ~ I I ~ ~ I I I I I ~ I ~ I I I I I I I I I I I I ~- r I I ~ ~ I I I I ~ B Top of Lower Lateral Liner: ~ ~ +1-7,000' MD 13,724' TVD ~ I ~ ~ Tubing Head Assembly Vetco Gray r I I ~ 16" Conductor: +1- 158' MD Port Collar: +1- 1000' MD I 968' TVD Top of Window: +1- 6,740' MD /3,661' TVD r -: ì ¡ I it Z" I I I ~ I ~ I ~ I ~ ~ I ~ ~ I § I ~ ~ I I I ~ I I I ~ I I I ~ ~ Nabors Rig 245 RKB @ 0' Eastings: 561,631.04 Northings: 5,968,796.65 Elevation: 101.8' AMSL Tubing Hanger, 4-1/2", Vetco Gray wI 4.909" MCA Top Connection, 4-1/2" L-80 NSCT Pup Joint Down ESP Power Cable Penetrator (497-6860) Heat Trace Penetrator (497-9275) (1) Joint Tubing ~ ~ ~ ... (x) Pup Joints Tubing, as required to spaceout heat trace. Connector, Field Attachable, Power Cable (497-6850) Connector, Field Attachable, Heat Trace (497 9270) Power Cable, Centrilift, #4 AWG Double Armor (497-6605) Heat Trace, Raychem, Surface to +1- 3,000' MD. (497-6615) (x) Joints Tubing (1) Gas Lift Mandrel, CAMCO 4-1/2" x 1" Model KBG-2 (481-9620), with dummy valve installed. 4- 1/2" IBT Pin x Pin, with 6 foot 4-1/2" XO Pups, top and bottom. Tubing String: 4-1/2", 12.6#, L-SO, NSCT (3) Joints Tubing (1) Sub, Phoenix Discharge Temperature and Pressure (1) Pup Joint Tubing, 10ft length (1) Pup Joint Tubing, 10ft length (1) Through Tubing Conveyed Electric Submersible Pump (TTCESP) Assembly, Centrilift, consisting of: (1) Slotted Nipple, Centrilift, 4-1/2" (1) Crossover, Centrilift, 4-1/2", TTC (1) Tandem Seal Section, Centrilift Model GST3 DB HL PFS (497-6510) (1) ESP Assembly, Centrilift Model 21 FCNPSH I 140FC2700 (conveyed through tubing) (497-6515) (1) Motor, Centrilift, 190 HP KMH 2415/48 (497-6505) (1) Gauge, Phoenix, Model, MS-1 Gauge (497-6500) (1) Centralizer, Motor, Centrilift, 6.25" OD to be spaced out +1. GO' MD above Hook Hanger (497-6550) 9-7/8" Hole TD, 7-5/8" Shoe: +1- 7,231' MD I 3,740' TVD PHilliPS Alaska, Inc. A Subsidiary of PHILLIPS PETROLEUM COMPANY I II I~=~~=~~~=~=~=~=~=~=~= I I~~~~~~~~~~~~~ ) D-Sand Lateral 6" Open Hole TD: +1-11,910' MD 13,631' TVD I~=~=~=~=~=~=~~=~=~~=~=~= I I~~~~~~~~~~~~~ ) B-Sand Lateral 6-3/4" Open Hole TD: 11,914' MD 13,687' TVD West Sak WeIl1C-104, AFC AK xxxx Planned Completion Schematic Sheet 4 of 4: Tubing String Details prepared by Todd Mushovic J i/ /f;/tiÃf lC Pad H2S levels ( Subject: 1 C Pad H2S levels Date: Mon, 11 Mar 2002 11 :01 :54 -0900 From: "Todd J Mushovic" <tmushov@ppco.com> To: <bob - crandall@admin.state.ak.us> CC: "Mavriky Kalugin" <mkalugi@ppco.com>, "Sharon Allsup-Drake" <sallsup@ppco.com> Mr. Crandall, My apologies for the wait in getting this information to you. I was unable to find any West Sak H2S levels on lC. However, offset lD pad has 22 wells and only 3 have minimum amounts of H2S - lD-127 @ 2 ppm, lD-126 @ 1 ppm, and lD-12l @ 1 ppm. The remaining 19 wells have 0 ppm H2S. As we obtain H2S samples on lC West Sak wells I will pass them along to you. Please let me know if there is anything else that you need. Todd J. Mushovic Drilling Engineer Phillips Alaska Inc. (907) 265-6974 - office (907) 240-5740 - cellular tmushov@ppco.com 1~1 3/11/2002 11 :22 AM ( TRANSMIT AL LETTER CHECK LIST CIRCLE APPROPRIATE LETTERlPARAGRAPHS TO BE INCLUDED IN TRANSMITIAL LETTER WELL NAME ttq Ir~ /()'-I LI CHECK 1 STANDARD LETTER DEVELOPMENT CHECK WHAT APPLIES ADD-ONS (OPTIONS) MULTI LATERAL (If api number last two (2) digits are between 60-69) v ~ DEVELOPMENT REDRILL PILOT HOLE (PH) EXPLORATION ANNULAR DISPOSAL . <--J NO INJECTION WELL ANNULAR DISPOSAL L-J YES INJECTION WELL RED RILL ANNULAR. DISPOSAL THIS WELL' "CLUE" The permit is for a new weUbore segment of existing weD ~ Permit No, . API No. . '. Production should continue to be reported as a function of the original API number stated above. . I: l4 I C-/oV~ oZ,- c>:ý So - 02.'1- <,3°7h In accordance with 2,0 AAC 25.005(t), all records, data and logs acquired for the pilot bole must be clearly . differentiated in both name (name. on permit plus PH) and API number (50 -70/80) from records, data and logs acquired for wel~ (n~me on permit). Annular disposal has ~ot been requested. . . Annular Disposal of drilling wastes will not be approved. . . Annular Disposal of drilling wastes will not be approved. . . ... !DISPOSAL INTO OTHER) Please note that an disposal of fluids generated... . \..ANNuLus - /' u¿) YES + SP ACING EXCEPTION Templates are located m drive\jody\templates Enclosed is the approved application for permit to drill the above referenced well. The permit is approved ,sùbject to full compliance with 20 AAC 25.055. Approval to perforate and produce is contingent upon issuance of a conservation order approving a spacing exception. (Companv Name) will assume the liability of any protest to the spacing exception that may occur. WELL PERMIT CHECKLIST COMPANY 1'1¡#'Í!< WELL NAM~ 1r:-/c>t¡I.J PROGRAM: Exp - Dev 2{ Redrll- Se~ - Wellbore seg.Ä:- Ann. disposal para req X FIELD & POOL <rið/.5'~ INITCLASS t:\,v /-e>,./ ~. GEOLAREA 9ft:> UNIT# ///t:O ON/OFF SHORE 0"'; ADMINISTRATION 1. Permit fee attached. . . . . . . . . . . . . . . . . . . . . . . 'I N 2. Lease number appropriate. . . . . . . . . . . . . . . . . . . Y N ~ . / J/ / ~ /, ~I 3. Unique well name and number. .. . . . . . . . . . . . . . . . Y . N '4.-". ¿I.$ .øL ",,,'1. S''ð~ r.. 7.4r "'r (')-1' A'--~"~IVf'~ 4. Well located in a defined pool.. . . . . . . . . . . . . . . . . Y N _.J ) .L' .J/ / I, A ~ 5. Well located proper distance from drilling unit boundary. . . . Y N ~""'...../ ,.;r ~- ~#i/M..#"~ ~-ÄUIOI /7/P/J :/.-- 6. Well located proper distance from other wells.. . . . . . . . . Y N ß' / // / -77 -r: ,/ / / 7. Sufficient acreage available in drilling unit.. . . . . . . . . . . Y N 7'1'.3" ~ /Y"~",/;, ~ / /) "" . ""4""~.f ee-Ã". -".If W1~ 8. If deviated, is well bore plat included. . . . . . . . . . . . . . . Y N ~ .L - ~ .f fl~./ / ¿ , / / j 9. Operatoronlyaffededparty.. . . . . . . . . . . . . . . . . . Y N ¡''k' ~'-;?("" ñ '*",/" 'M~ /--J , ( ~I¡Ø~/ ~ÞJ ~~: ~~~~tt~~a:e~~~~;~~~~~~~~~:~Z:tio'n ~~d~r~ ~ ~ ~ ~ ~ ~ ~ ~ ~ -'~~,,,v-~~ -t'£~ L1 ~:&.\ #e, I c. -/07' J'~Jtø~ ¿"JI- A~R D~ TF 12. Permit can be issued without administrative approval.. . . . . Y N V .A:1" "",. ~¥"'2.... 13. Can permit be approved before 15-day wait.. . . . . . . . . . Y N /V' "- ENGINEERING 14. Conductor string provided. . . . . . . . . . . . . . . . . . . ~) N 15. Surface casing protects all known USDWs. . . . . . . . . . . ~N 16. CMT vol adequate to circulate on conductor & surf csg. . . . . (j) N 17. CMT vol adequate to tie-in long string to surf csg. . . . . . . . ¥-N- SÚ/ If - í 18. CMT will cover all known productive horizons. . . . . . . . . . ~ ~ 19. Casing designs adequate for C, T,. B & permafrost. . . . . . . - N ~ ¡ -i ...., !lS J=:... 20. Adequate tankage or reserve pit.. . . . . . . . . . . . . . . . . N I\UI- Oil S ~"t c..::: 21. If a re-drill, has a 10-403 for abandonment been approved. . . -¥-N-I\I/, . 22. Adequate wellbare separation proposed.. . . . . . . . . .-. . & N 23. If diverter required, does it meet regulations. . . . . . . . . . ~. IÚ/Æ 24. Drilling fluid program schematic & equip list adequate. . . . . . N 25. BOPEs, do they meet regulation . . . . . . . . . . . . . . . . N j~rp Il~/} ,0/ /. APPR" DAt T~ 26. BOPE press rating appropriate; test to 3 000 psig. ~ N I" (, ':;1 --I v r '> to- WG,., ï ;{O L 27. Choke manifold complies w/API RP-53 (May 84). . . . . . . . N 28. Work will occur without operation shutdown. . . . . . . . . . . . ~. 29. Is presence afH2S gas probable.. . . . . . . . . . . . . . . . Y !bV 30. Permit can be issued w/o hydrogen sulfide measures. . . . . YN 31. Data presen.ted on potential overpressure zones. . . . . " . Y ~ J /J 32. Seismic analysis of shallow gas zones. . . . . . . . . . . . . / (~f n .. ..A~ . "pþT~ 33. Seabed condition survey (if off-shore). . . . . . . . . . . . . N ~c:, #f/l"'- 34. Contact name/phone for weekly progress reports [exploratory 0 y] Y N ANNULAR DISPOSAL 35. With proper cementing records, this plan § (A) will contain waste in a suitable receiving zone; . . . . . . . N , ~ }J APPR DATE (B) will not contaminate freshwater; or cause drilling waste. .. Y N ~ _~ífJÞ<.,f/¿~. ,..#JI!.p/ t"¿lJ ..L J to surface; .Q / /Il"- Jr.3/Þ'7 ¡g~ ~:: ~~: =~~~~=~~~~i~~~~~o~f~~fm~~lr~:~~~~:~:S:I~~ '("~~~n" . ,M I ¿-/~ / ¡:, (E) ~~I~~~~ircumvent 20 MC 25.252 or 20 MC 25.412. 6; N .s¿~~/ - He-. GEOLOGY: ENGINEERING: UIC/Annular: COMMISSION: RP~ JDH~ 1ff.J WGA W&!r GEOLOGY / t'. ~.I ¿¡ 1"",.,,/.1 ..O/~L c/rl " ICiI Commentsllnstructions: COT '-Þ)t1l... ..~ DTSO /1 ()L G:\geology\permits\checklist.doc WELL PERMIT CHECKLIST COMPANY /j,ï/ý;.r WELL NAMEq¿¡ /t:- /ô'7 L/ FIELD&POOL Y9ð/$d INITCLASS /)~ ¡"ð.'J ADMINISTRATION 1. Permit fee attached. . . . . . . . . . . . . . . . . . . . . . . r;; N 2. Lease number appropriate. . . . . . . . . . . . . . . . . . . Y N 3. Unique well name and number. .. . . . . . . . . . . . . . . . Y N 4. Well located in a defined pool.. . . . . . . . . . . . . . . . . Y N 5. Well located proper distance from drilling unit boundary. . . . Y N 6. Well located proper distance from other wells.. . . . . . . . . Y N 7. Sufficient acreage available in drilling unit.. . . . . . . . . . . Y N 8. If deviated, is wellbore plat included.. . . . . . . . . . . . . . Y N 9. Operator only affected party.. . . . . . . . . . . . . . . . . . Y N 10. Operator has appropriate bond in force. . . . . . . . . . . . . Y N 11. Permit can be issued without conservation order. . . . . . . . Y N At;fc.5 ql1T9 12. Permit ca~ be issued without administrativ~ approval.. . . . . Y N /(P'" 3/~ 0:2.,- 13. Can permit be approved before 15-day walt.. . . . . . . . . . Y N ENGINEERING 14. Condu ct.or S. trin. g provided '.' . , , , , , , , , , , . , , , , , ~'1 N 1 15. Surface casing protects all known USDWs. . . . . . . . . . . ¥---N-;J. fA- 16. CMT vol adequate to circulate on conductor & surf csg. . . . . .¥-J'r 17. CMT vol adequate to tie-in long string to surf csg. . . . . " . -¥--N- 18. CMT Wil.1 C. over all kno.wn productive horizons. . . . . . . . . . ~ Sw..ee~ ~~: ~~:~~a~:~~~~~::~i~:~~~~ ~it:: ~ ~ :~r~~fr~~t.. : : : : : : ~ ~ ¡J~Iu.y~ ¡tis E. 21. If a. re-drill, h.as a 10-403. for abandonmen.t been approved. . .J;; N N/A 22. Adequate wellbore separation proposed.. . . . . . . . . . . . (¿. N 23. If diverter required, does it meet regulations. . . . . . . . . . -¥-N- ""/A- 24. Drilling flUid. program schematic & equip list adequate. . . . . $. N 25. BOPEs, do they meet regulation. . . . . . . . . . . . . . . . - N ~ 26. BOPE press rating appropriate; test to 5000 psig. N ~\C1..t.-"- a.~~ '\~ ~ \()"t...~ 27. Choke manifold complies w/API RP-53 (May 84). . . . . . . . &2 N 28. Work will occur without operation shutdown. . . . . . . . . . . fi N 29. Is presence of H2S gas probable.. . . . . . . . . . . . . . . . Y <6J? 30. Permit can be issued w/o hydrogen sulfide measures. . . .. Þy N 31. Data presented on potential overpressure zones. . . . . . . Y A J A 32. Seismic analysis of shallow gas zones. . . . . . . . . . . . . N / I ~/' I . AjJ~R .. 9AJE 33. Seabed condition survey (if off-shore). . . . . . . . . . . . . N ~, r' 1/7/ ð¿ 34. Contact name/phone for weekly progress reports [exploratory oni Y N ANNULAR DISPOSAL 35. With proper cementing records, this plan (A) will contain waste in a suitable receiving zone; . . . . . . . (B) will not contaminate freshwater; or cause drilling waste. .. to surface; (C) will not impair mechanical integrity of the well used for disposal; Y N (D). will not damage producing formation or impair recovery from a Y N pool; and (E) will not circumvent 20 MC 25.252 or 20 MC 25.412. Y N GEOLOGY: ENGINEERING: UIC/Annular: COMMISSION: RP~ TEM!Jrt~ ~~ SFD- WGA ~4k APJ:R DATE Vffilt ~ {¡ z.Ürl, ~ '!./t$~o:> GEOLOGY APPR DATE; PROGRAM: Exp - Dev,.à Redrll - Serv - Wellbore seg ')( Ann. disposal para req - GEOL AREA ~ ò UNIT# // If:' (") ON/OFF SHORE c A.J Y N Y N 0 ~ cu..~..JfL\~.JQ,V~ Sf 0 SA.J. Comments/Instructions: l COT j{ / , ~ /'I.lVL/* () ~ JI'. Q$ J ,..J DTSBfYSY~ L r JMH G:\geology\templates\checklist.doc Ie, - It:::> ~ #c. Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simpltfy finding information, information of this nature is accumulated at the end of the file under APPEN.DIX. No special "effort has been made to chronologically " . organize this category of information. ( aC8-0lo~ II DI '6 Sperry-Sun Drilling Services LIS Scan Utility $Revision: 3 $ LisLib $Revision: 4 $ Mon Sep 16 13:20:41 2002 Reel Header Service name..... ....... .LISTPE Date. . . . . . . . . . . . . . . . . . . . . 02/09/16 Origin. . . . . . . . . . . . . . . . . . . STS Reel Name.. """""". . UNKNOWN Continuation Number.... ..01 Previous Reel Name...... . UNKNOWN Comments... ...... ....... .STS LIS Writing Library. Scientific Technical Services Tape Header Service name........... ..LISTPE Da t e. . . . . . . . . . . . . . . . . . . . . 02 / 09 / 16 Origin. . . . . . . . . . . . . . . . . . . STS Tape Name............. ...UNKNOWN Continuation Number..... .01 Previous Tape Name.... ...UNKNOWN Comments............... ..STS LIS Writing Library. Scientific Technical Services Physical EOF Comment Record TAPE HEADER Kuparuk River Unit MWD /MAD LOGS # WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: # JOB DATA 1C-104-L1 500292307660 PHILLIPS Alaska, Inc. Sperry-Sun Drilling Services 16-SEP-02 JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 10 AK-MW-22102 J. PITCHER D. WESTER # SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: 12 11 10 1437 625 MSL 0) 101.85 60.60 # WELL CASING RECORD 1ST STRING 2ND STRING OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 6.750 7.625 7043.0 ( 3RD STRING PRODUCTION STRING # REMARKS: 1. ALL DEPTHS ARE MEASURED DEPTH (MD) UNLESS OTHERWISE NOTED. 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTH (TVD). 3. MWD RUN 9 WAS DIRECTIONAL ONLY TO POSITION THE WHIPSTOCK AND IS NOT PRESENTED. THE TOP OF THE WHIPSTOCK IS 7043'MD/3681'TVD, WITHIN THE 1C-104 PB1 WELL BORE. 4. MWD RUN 10 COMPRISED DIRECTIONAL WITH DUAL GAMMA RAY (DGR) UTILIZING GEIGER-MUELLER TUBE DETECTORS; ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4); AT-BIT-INCLINATION (ABI); AND PRESSURE-WHILE-DRILLING ( PWD) . 5. DEPTH SHIFTING/CORRECTION OF MWD DATA IS WAIVED PER E-MAIL FROM D. SCHWARTZ, PHILLIPS ALASKA, INC., DATED 8/21/02. THIS E-MAIL QUOTES AUTHORIZATION OF THE PAI GEOSCIENCE GROUP. MWD DATA ARE CONSIDERED PDC. 6. MWD RUN 10 REPRESENTS WELL 1C-104 L1 WITH API#: 50-029-23076-60. THIS WELL REACHED A TOTAL DEPTH (TD) OF 11539'MD/3626'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 (SEDP). SLIDE = NON-ROTATED INTERVALS REFLECTING BIT DEPTHS. WBP = WELL BORE PROFILE. $ File Header Service name............ .STSLIB.001 Service Sub Level Name... Version Number. ......... .1.0.0 Date of Generation...... .02/09/16 Maximum physical Record. .65535 File Type............... .LO Previous File Name...... .STSLIB.OOO Corrunent Record FILE HEADER FILE NUMBER: EDITED MERGED MWD Depth shifted and DEPTH INCREMENT: 1 clipped curves; all bit runs merged. .5000 ( # FILE SUMMARY PBU TOOL CODE GR RPX RPS RPM RPD FET ROP $ START DEPTH 7022.0 7028.0 7028.0 7028.0 7028.0 7055.5 7073.5 STOP DEPTH 11485.5 11492.5 11492.5 11492.5 11492.5 11492.5 11538.5 # BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH $ # MERGED DATA PBU TOOL MWD $ SOURCE CODE BIT RUN NO MERGE TOP 10 7022.0 MERGE BASE 11538.5 # REMARKS: MERGED MAIN PASS. $ # Data Format Specification Record Data Record Type........... .......0 Data Specification Block Type.....O Logging Direction... ............. . Down Optical log depth units......... ..Feet Data Reference Point... ......... ..Undefined Frame Spacing.............. ...... .60 .1IN Max frames per record............ . Undefined Absent value. . . . . . . . . . . . . . . . . . . . . . -999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD FT/H 4 1 68 4 2 GR MWD API 4 1 68 8 3 RPX MWD OHMM 4 1 68 12 4 RPS MWD OHMM 4 1 68 16 5 RPM MWD OHMM 4 1 68 20 6 RPD MWD OHMM 4 1 68 24 7 FET MWD HOUR 4 1 68 28 8 Name Service Unit DEPT FT ROP MWD FT/H GR MWD API RPX MWD OHMM RPS MWD OHMM RPM MWD OHMM RPD MWD OHMM FET MWD HOUR Min 7022 1.23 45.58 0.05 0.06 0.42 1.25 0.09 Max 11538.5 870.97 97.84 2000 2000 2000 2000 28.26 Mean 9280.25 242.564 69.8337 33.3266 56.8856 65.7767 71.0995 0.602706 First Reading For Entire File........ ..7022 Last Reading For Entire File.......... .11538.5 Nsam 9034 8931 8928 8930 8930 8930 8930 8875 First Reading 7022 7073.5 7022 7028 7028 7028 7028 7055.5 Last Reading 11538.5 11538.5 11485.5 11492.5 11492.5 11492.5 11492.5 11492.5 (' File Trailer Service name.... ....... ..STSLIB.OOl Service Sub Level Name... Version Number. ........ ..1.0.0 Date of Generation...... .02/09/16 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... ....02/09/16 Maximum Physical Record. .65535 File Type. ...... .... .... .LO Previous File Name..... ..STSLIB.OOl Corrnnent Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE GR RPX RPS RPM RPD FET ROP $ 2 header data for each bit run in separate files. 10 .5000 START DEPTH 7022.0 7028.0 7028.0 7028.0 7028.0 7055.5 7073.5 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE DGR EWR4 $ # STOP DEPTH 11485.5 11492.5 11492.5 11492.5 11492.5 11492.5 11538.5 BOTTOM) TOOL TYPE DUAL GAMMA RAY ELECTROMAG. RESIS. 4 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): 18-JUL-02 Insite 66.37 Memory 11539.0 7022.0 11539.0 77.1 94.5 TOOL NUMBER PB00237HAGR4 PB00237HAGR4 6.750 7043.0 ( # 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: BARADRIL-N 9.10 43.0 9.4 21000 3.8 .200 .140 .130 .310 # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type..................O Data Specification Block Type... ..0 Logging Direction. ............... . Down Optical log depth units.......... .Feet Data Reference Point......... ... ..Undefined Frame Spacing. ................... .60 .1IN Max frames per record............ . Undefined Absent value.... . . . . . . . . . . . . . . . . . . - 999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type. ..0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD100 FT/H 4 1 68 4 2 GR MWD100 API 4 1 68 8 3 RPX MWD100 OHMM 4 1 68 12 4 RPS MWD100 OHMM 4 1 68 16 5 RPM MWD100 OHMM 4 1 68 20 6 RPD MWD100 OHMM 4 1 68 24 7 FET MWD100 HOUR 4 1 68 28 8 Name Service Unit DEPT FT ROP MWD100 FT/H GR MWD100 API RPX MWD100 OHMM RPS MWD100 OHMM RPM MWD100 OHMM RPD MWD100 OHMM FET MWD100 HOUR Min 7022 1.23 45.58 0.05 0.06 0.42 1.25 0.09 Max 11538.5 870.97 97.84 2000 2000 2000 2000 28.26 Mean 9280.25 242.564 69.8337 33.3266 56.8856 65.7767 71.0995 0.602706 Nsam 9034 8931 8928 8930 8930 8930 8930 8875 First Reading For Entire File......... .7022 Last Reading For Entire File.. ....... ..11538.5 63.0 95.0 63.0 63.0 First Reading 7022 7073.5 7022 7028 7028 7028 7028 7055.5 Last Reading 11538.5 11538.5 11485.5 11492.5 11492.5 11492.5 11492.5 11492.5 ( ( File Trailer Service name............ .STSLIB.002 Service Sub Level Name... Version Number..... ..... .1.0.0 Date of Generation...... .02/09/16 Maximum Physical Record. .65535 File Type. . . . . . . . . . . . . . . . LO Next File Name.... ...... .STSLIB.003 Physical EOF Tape Trailer Service name.. .......... .LISTPE Da t e. . . . . . . . . . . . . . . . . . . . . 02 / 09 / 16 Origin. . . . . . . . . . . . . . . . . . . STS Tape Name.. ........ ..... . UNKNOWN Continuation Number.. ....01 Next Tape Name.......... . UNKNOWN Conunents. . . . . . . . . . . . . . . . . STS LIS Writing Library. Scientific Technical Services Reel Trailer Service name.......... ...LISTPE Date. . . . . . . . . . . . . . . . . . . . . 02/09/16 Origin. . . . . . . . . . . . . . . . . . . STS Reel Name.......... ..... . UNKNOWN Continuation Number.. ... .01 Next Reel Name.... ...... . UNKNOWN Conunents. . . . . . . . . . . . . . . . . STS LIS Writing Library. Scientific Technical Services Physical EOF Physical EOF End Of LIS File
