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Home My WebLink About203-116Post Office Box 244027 Anchorage, AK 99524-4027 3800 Centerpoint Drive Suite 1400 Anchorage, AK 99503 Phone: (907) 564-4891 02/09/2024 Mr. Mel Rixse Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 Re: Prudhoe Bay Surface Casing by Conductor Annulus Top-offs of Cement, Corrosion Inhibitor through 02/09/2024. Dear Mr. Rixse, Enclosed please find a copy of a spreadsheet with a list of Prudhoe Bay wells that were topped-off with cement, corrosion inhibitor in the surface casing by conductor annulus through 02/09/2024. Cement top-offs are executed as needed to mitigate the void space left at surface by minor cement fallback during the primary surface casing by conductor cement job. The remaining void space between the top of the cement and the top of the conductor is filled with a heavier than water corrosion inhibitor to reduce the risk of external surface casing corrosion. The attached spreadsheets include the well names, API and PTD numbers, treatment dates and volumes. As per previous agreement with the AOGCC, this letter and spreadsheet serve as notification that the treatments took place and meet the requirements of form 10-404 Report of Sundry Operations. If you have any additional questions, please contact me at 564-4891 or oliver.sternicki@hilcorp.com. Sincerely, Oliver Sternicki Well Integrity Supervisor Hilcorp North Slope, LLC Digitally signed by Oliver Sternicki DN: cn=Oliver Sternicki, c=US, o=Hilcorp North Slope LLC, ou=PBU, email=oliver.sternicki@hilcorp.com Date: 2024.02.09 11:15:58 -09'00' Oliver Sternicki Hilcorp North Slope LLC. Surface Casing by Conductor Annulus Cement, Corrosion Inhibitor Top-off Report of Sundry Operations (10-404) 02/09/2024 Well Name PTD # API # Initial top of cement (ft) Vol. of cement pumped (gal) Final top of cement (ft) Cement top off date Corrosion inhibitor (gal) Corrosion inhibitor/ sealant date L-293 223020 500292374900 30 8/29/2023 S-09A 214097 500292077101 2 9/19/2023 S-102A 223058 500292297201 2 9/19/2023 S-105A 219032 500292297701 10 9/19/2023 S-109 202245 500292313500 7 9/19/2023 S-110B 213198 500292303002 35 9/19/2023 S-113B 202143 500292309402 10 9/19/2023 S-115 202230 500292313000 4 9/19/2023 S-116A 213139 500292318301 4 9/19/2023 S-117 203012 500292313700 3 9/19/2023 S-118 203200 500292318800 9 9/19/2023 S-122 205081 500292326500 5 9/19/2023 S-125 207083 500292336100 2 9/19/2023 S-126 207097 500292336300 3 9/19/2023 S-134 209083 500292341300 35 9/19/2023 S-200A 217125 500292284601 7 9/19/2023 S-202 219120 500292364700 13 9/19/2023 S-210 219057 500292363000 10 9/19/2023 S-213A 204213 500292299301 4 9/19/2023 S-215 202154 500292310700 3 9/19/2023 S-216 200197 500292298900 4 9/19/2023 S-41A 210101 500292264501 3 9/19/2023 W-16A 203100 500292204501 2 9/23/2023 W-17A 205122 500292185601 3 9/23/2023 Well Name PTD #API # Initial top of cement (ft) Vol. of cement pumped (gal) Final top of cement (ft) Cement top off date Corrosion inhibitor (gal) Corrosion inhibitor/ sealant date W-19B 210065 500292200602 8 9/23/2023 W-21A 201111 500292192901 8 9/23/2023 W-32A 202209 500292197001 4 9/23/2023 W-201 201051 500292300700 44 9/23/2023 W-202 210133 500292343400 6 9/23/2023 W-204 206158 500292333300 3 9/23/2023 W-205 203116 500292316500 3 9/23/2023 W-207 203049 500292314500 3 9/23/2023 W-211 202075 500292308000 8 9/23/2023 W-213 207051 500292335400 3 9/23/2023 W-214 207142 500292337300 10 9/23/2023 W-215 203131 500292317200 2 9/23/2023 W-223 211006 500292344000 7 9/23/2023 Z-69 212076 500292347100 2.0 27 1.5 10/24/2023 S-128 210159 500292343600 11 12/27/2023 S-135 213202 500292350800 16 12/27/2023 V-113 202216 500292312500 24 12/31/2023 V-114A 203185 500292317801 5 12/31/2023 V-122 206147 500292332800 5 12/31/2023 V-205 206180 500292333800 2 12/31/2023 V-207 208066 500292339000 8 12/31/2023 V-214 205134 500292327500 5 12/31/2023 V-215 207041 500292335100 2 12/31/2023 V-218 207040 500292335000 5 12/31/2023 V-224 208154 500292340000 16 12/31/2023 V-225 209118 500292341900 6 12/31/2023 V-01 204090 500292321000 3 1/1/2024 V-02 204077 500292320900 5 1/1/2024 V-04 206134 500292332200 5 1/1/2024 V-102 202033 500292307000 8 1/1/2024 V-104 202142 500292310300 5 1/1/2024 V-220 208020 500292338300 4 1/1/2024 W-205 203116 500292316500 3 9/23/2023 7. Property Designation (Lease Number): 1. Operations Performed: 2. Operator Name: 3. Address: 4. Well Class Before Work:5. Permit to Drill Number: 6. API Number: 8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071): 10. Field/Pool(s): Susp Well Insp Install Whipstock Mod Artificial Lift Perforate New Pool Perforate Plug Perforations Coiled Tubing Ops Other Stimulate Fracture Stimulate Alter Casing Pull Tubing Repair Well Other: Change Approved Program Operations shutdown 11. Present Well Condition Summary: Casing Length Size MD TVD Burst Collapse Exploratory Stratigraphic Development Service 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 16. Well Status after work: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. OIL GAS WINJ WAG GINJ WDSPL GSTOR Suspended SPLUG Authorized Name and Digital Signature with Date: Authorized Title: Contact Name: Contact Email: Contact Phone: PBU W-205 Surface Casing Repair Hilcorp North Slope, LLC 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 203-116 50-029-23165-00-00 10670 Surface Intermediate Liner Liner 5224 3956 7592 643 3152 10520 10-3/4" 7-5/8" 7-5/8" x 4-1/2" 4-1/2" 5233 29 - 3985 26 - 7618 6892 - 7535 7517 - 10669 29 - 3180 26 - 5184 5016 - 5177 5176 - 5224 Unknown 2480 4790 7500 7500 None 5210 6890 8430 8430 7700 - 10667 4-1/2" 12.6# L80 24 - 6907 5189 - 5224 Conductor 80 20" 29 - 109 29 - 109 4-1/2" Baker Premier Packer 6770, 4966 6770 4966 Stan Golis Sr. Area Operations Manager Claire Mayfield Claire.Mayfield@hilcorp.com 907-564-4375 PRUDHOE BAY, POLARIS OIL Total Depth Effective Depth measured true vertical feet feet feet feet measured true vertical measured measured feet feet feet feet measured true vertical Plugs Junk Packer Measured depth True Vertical depth feet feet Perforation depth Tubing (size, grade, measured and true vertical depth) Packers and SSSV (type, measured and true vertical depth) 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13a.Representative Daily Average Production or Injection Data Oil -Bbl Gas-Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: Subsequent to operation: 15. Well Class after work: Exploratory Development Service StratigraphicDaily Report of Well Operations Copies of Logs and Surveys Run Electronic Fracture Stimulation Data Sundry Number or N/A if C.O. Exempt: ADL 0028263 24 - 5022 Conductor Annulus from Surface Fill 6-bbls 15.8-ppg Arctic Blend Cement 888 915 2540 882 678 375 1350 1186 465 302 322-615 13b. Pools active after work:Polaris Oil No SSSV Installed STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS Sr Pet Eng: Sr Pet Geo: Form 10-404 Revised 10/2022 Submit in PDF format to aogcc.permitting@alaska.gov Sr Res Eng: Due Within 30 days of Operations o the best of my knowle February 13, 2023 By Samantha Carlisle at 9:15 am, Feb 13, 2023 Repair Well DSR-2/13/23 203-116 Surface Casing Repair PRUDHOE BAY, POLARIS OIL 322-615 PBU W-205 RBDMS JSB 021423 Sundry Number Alter Casing MGR03MARCH2023 11/23/2022 Super sucked cellar. Excavated around cellar box for removal. 11/24/2022 Cellar removed. Began excavation around well. 11/25/2022 Excavated to 12' below grade. 11/26/2022 Excavated to 15' below grade. Scaffold platform built, ladder tie-off points, cellar egress installed. 11/27/2022 Swapped to hydro-excavation; began chipping/removing cement from outside of conductor. 11/28/2022 Began installation of lateral bracing on inside of sheet pile shoring at 12'. 11/29/2022 Continued lateral bracing installation. 11/30/2022 Cut small window in conductor at bottom of excavation to assess surface casing condition. Fluid drained from cut window, high LELs. Pause surface casing evaluation until fluid can be circulated from OA through window to mitigate high LELs. 12/1/2022 Continued hydro-excavation while waiting for OA valve installation. 12/2/2022 Continued hydro-excavation to 18' below grade. 12/3/2022 Continued hydro-excavation to 21' below grade. OA valve installed with block valves for pumping. Drilled and tapped existing conductor holes with jewelry/valves for OA purge into conductor. 12/4/2022 Continued hydro-excavation. Purged OA/conductor with compressed air. 12/5/2022 Continued hydro-excavation to 22' below grade. Purged well through the night, conductor taps were opened and about a quart of fluid drained from conductor. 12/6/2022 60/40 KCl and 1 barrel glycol cap were pumped into OA to purge fluid and mitigate LELs. 12/7/2022 Some 60/40 returns were taken into cellar, flash tested and cleaned up with a super sucker. Additional concrete was removed from conductor. An OA leak depth strap was attempted and non-conclusive. 12/8/2022 Scaffolding erected around well to split and remove the outer part of the insulated conductor. 12/9/2022 Outer conductor split; first half removed. 12/10/2022 Standby for Simops/rig move. 12/11/2022 Second half of outer conductor removed. Insulation cleared from inner conductor. Holes drilled at base of conductor at the 12/9/6/3 o'clock positions at 15'. Compressed air pumped into OA. Immediate returns observed out of the flutes, no returns at base of conductor. 12/12/2022 Holes drilled at base of conductor at the 12/9/6/3 o'clock positions at 9', compressed air pumped and observed holes for returns. Drilled holes starting at 9' below OA valve and worked up to 2' below OA valve. At ~4' below returns were observed. Cut a 12" x 12" window, removed cement and visually observed corroded casing. 12/13/2022 Cut 12"x12" windows at 10' and 18'. Surface casing buffed and UT'd. Upper 5' window showed 0% to 60% nominal wall thickness, 10' window showed 70% to nominal wall thickness, 18' window showed nominal wall. At ~4' below returns were observed. Drilled holes starting at 9' below OA valve and worked up to 2' below OA valve 12/14/2022 Prepared pad for well support structure. 12/15/2022 Set well support structure. Pulled 20 kips of tension on well support structure. 12/16/2022 Tied in well support structure to well. 12/17/2022 Cut conductor in half to 10' window, then again to 18' window for a total of 4 sections for removal. Removed top two sections of conductor, removed cement. Cement was soft and fell off easily. 12/18/2022 Removed bottom halves of conductor and cement. Cement on bottom section of removal was difficult to remove. Chiseled cement between surface casing and conductor to ensure good, clean cement was located. Confirmed hole in surface casing at 65" below OA valve. SC hole positively located. -WCB Confirmed hole in surface casing at 65" below OA valve. 12/19/2022 De-scaled and buffed surface casing. While casing was buffed another hole was located at 80" from OA valve. Performed full UT scan of surface casing to ensure sleeve straddled corrosion and verify adequte thickness in wedding band areas. Patched holes with an epoxy for an N2 cap in the OA. At ~8-10 feet down, the SC corrosion vastly minimizes. -WCB While casing was buffed another hole was located at 80" from OA valve. 12/20/2022 N2 cap placed in OA. Set 3 sets of wedding bands in place: at mandrel hanger, at 8' below mandrel hanger and at 16' below mandrel hanger. Vertical seams of bands welded in place. Positioned heat treating equipment in place for welding top and bottom bands to parent material. 12/21/2022 Heat treated and completed top band weld out. N2 cap was held on OA and LELs continually monitored during welding. Heat treated and completed top band weld out. N2 cap was held on OA and LELs continually monitored during welding. 12/22/2022 Attempted to pre-heat treatment. Epoxy patches on holes failed and fluid pushed out. Pre-heat suspended and holes were drilled just above the bottom band. Remaining fluid sucked below bottom band location and holes re-patched. 12/23/2022 Heat treated and completed bottom band weld out. N2 cap held on OA, LELs continually monitored during welding. 12/24/2022 Fit-up sleeves around casing. 12/25/2022 Groove welds on lower sleeves completed. 12/26/2022 Weather standby. 12/27/2022 Continued welding seems on lower sleeve and lower circumference to bottom band. 12/28/2022 Completed seems on lower sleeve and upper circumference weld on middle band. Started welding on upper sleeve section. 12/29/2022 Completed welding on upper sleeve and upper circumference weld on top wedding band. Non- destructive evaluation was completed on welds. All welds passed NDE. 12/30/2022 Leak test performed to 500-psi on OA. Incremental pressure test was performed starting with 10 psi for 3 minutes, then increasing to 50-psi, 100-psi, 200-psi, 300-psi, 400-psi each for 10 minutes and finally up to 500-psi for a 30-minute leak test. 500 psi, 30-minute test passed. Released tension on well support structure and un-tied from well. 7.5 hours after leak test fluid between conductor and surface casing came to surface, after releasing the tension on the well support structure. Placed first half of the new conductor into excavation around well. 12/31/2022 Removed fluids between surface casing and conductor. Minimal returns that would freeze immediately at surface. Placed second half of conductor and fit up. 12' of vertical side seams were welded. 1/1/2023 Final 10' of vertical side seams on conductor welded. Demobilized well support structure. Permafrost cement was placed between casing and conductor and left to cure for 12 hours. Scaffolding removed. 1/2/2023 Backfilling excavation began. 1/3/2023 Backfill continued up to 7' below pad grade. Top of sheet pile was cut off at this depth on North, South and East sides of well. 1/4/2023 West side of sheet pile cut off 7' below pad grade. Backfill complete. Removed fluids between surface casing and conductor. Minimal returns that would freeze immediately at surface. Placed second half of conductor and fit up. 12' of vertical side seams were welded. Non- destructive evaluation was completed on welds Final 10' of vertical side seams on conductor welded. Demobilized well support structure. Permafrost cement was placed between casing and conductor and left to cure for 12 hours. Scaffolding removed Completed welding on upper sleeve and upper circumference weld on top wedding band All welds passed NDE. Leak test performed to 500-psi on OA. Incremental pressure test was performed starting with 10 psi for 3 minutes, then increasing to 50-psi, 100-psi, 200-psi, 300-psi, 400-psi each for 10 minutes and finally up to 500-psi for a 30-minute leak test. 500 psi, 30-minute test passed. ACTIVITY DATE SUMMARY 10/23/2022 ***WELL S/I ON ARRIVAL*** (Wellhead repair) BRUSHED X NIP @ 6835'MD w/ 4 1/2" BLB & 3.80" GAUGE RING ***JOB IN PROGRESS, CONTINUED ON 10/24/22*** 10/24/2022 ***CONTINUED FROM 10/23/22*** (Wellhead repair) SET 3.81" XX PLUG @ 6,835' MD CHECK SET XX PLUG (Sheared) TESTED PLUG w/ 530PSI DDT ***WELL S/I ON DEPARTURE*** 10/27/2022 T/I/O=800/1100/0. Pre WSS. Set 4" H BPV #709. LTT(pass). ND 4" CIW upper tree. Install 4" FMC temp valve. torque to spec. PT temp valve 500 low 5000 high (pass). FWPs=BPV/1100/0. ***RDMO*** 11/23/2022 T/I/O=175/170/0. Pre WSS. Pull 4" H TWC. Bleed T/I/O to 0 psi. Set 4 " H TWC # 143. Remove 4" Dryhole tree from wellhead. Install 2'-4" spool w a 4"x7" XO and inverted THA to wellhead. Torqued to spec. FWPs=0/0/0 ***RDMO*** 11/23/2022 T/I/O= BPV/0/0. RD IA, Companion IA & OA. Install VR Plugs. RU Flanges Torque to API specs. PT Flange against VR Plug 3500 PSI 9PASSED). Hung signs. ***JOB COMPLETE***. Final WHP's BPV/0/0. 12/3/2022 T/I/O=BPV/VR plug/VR plug. RU 2" FMC 120 OA Valve and VR lubricator. Pressure test vavle against VR plug to 3500 psi. (Pass) Pulled 2" FMC (new style) VR plug and perfomr LTT on OA Valve. RD VR lubricator and RU 2" integral and hardline to allow pumping from outside excavation. Final WHP's BPV/VR Plug/0. ***Job Complete*** 12/30/2022 LRS 72 (WELLHEAD REPAIR) Leak Check OA to 500 psi. No Visual Leaks were observed. Stepped the pressure up in 10 minute intervals from 0 psi to 10, 50, 100, 200, 300 400 and 500 psi. Pumped 1.3 bbls of 50*F 60/40 MeOH to achieve max applied pressure of 503 psi. OA lost 18 psi during the first 15 minutes and 14 psi during the second 15 minutes. OA lost 32 psi during the 30 minute test. Bled back 0.6 bbls to Final OA of 0 psi. 1/1/2023 Surface casing repair cement top job of conductor casing Filled annulus of conductor with ~6bbl of arctic blend cement prior to backfilling pit. ***Complete*** 1/5/2023 ***WELL S/I ON ARRIVAL*** WEATHER STBY R/U POLLARD #58 ***WSR CONT ON 1-6-23*** 1/5/2023 Installed Production tree, torqued THAxMV to API specs, Installed production and AL pipe, Torqued to ANSI specs, Pulled BPV #143, Set TWC #444, Tested against TWC 350/5000 PSI (Pass). Pulled TWC #444. Pulled VR plugs from IA valves. RDMO. Daily Report of Well Operations PBU W-205 PT Flange against VR Plug 3500 PSI 9PASSED () BRUSHED X NIP @ 6835'MD w/ 4 1/2" BLB & 3.80" GAUGE RING LRS 72 (WELLHEAD REPAIR) Leak Check OA to 500 psi. No Visual Leaks wereA g g () observed. Stepped the pressure up in 10 minute intervals from 0 psi to 10, 50, 100, 200, 300 400 and 500 psi. Pumped 1.3 bbls of 50*F 60/40 MeOH to achieve max applied pressure of 503 psi. OA lost 18 psi during the first 15 minutes and 14 psig during the second 15 minutes. OA lost 32 psi during the 30 minute test. Bled back 0.6g bbls to Final OA of 0 psi. Install 2'-4" spool w a 4"x7" XO and inverted THA to wellhead. Set 4" H BPV ND 4" CIW upper tree RD IA, Companion IA & OA. Install VR Plugsg This is the post SC repair passing pressure test on the OA, proving the sleeved SC is holding pressure. -WCB Remove 4" Dryhole tree from wellheady TESTED PLUG w/ 530PSI DDT SET 3.81" XX PLUG @ 6,835' MD@ CHECK SET XX PLUG (Sheared)( Daily Report of Well Operations PBU W-205 1/6/2023 ***WSR CONT FROM 1-5-23*** RAN 3.74" CENT, 4-1/2" GS CORE & EQ- PRONG TO 6,835' MD (equlized plug) PULLED 3.81" XX- PLUG @ 6,835' MD, PULLED UP HOLE TO 6,738' SLM (parted wire) RAN 3.70'' CENT, 3' 1-3/4'', 3.75'' CENT, 3.73'' LIB, S/D @ 6634'SLM (IMPRESSION OF RS) RAN 3-1/2'' GR, 3-1/2'' BAIT SUB, 4-1/2'' BLB, 3.50'' BELL GUIDE, 2-1/2'' SPLIT SKIRT JD, PULLED TOOL STRING FROM 6634'SLM (no plug, no wire recovered) RAN 3-1/2'' GR, 3-1/2'' BAIT SUB, 3' x 1-3/4'', 4-1/2'' BLB, 3.67'' 3 PRONG WIRE GRAB TO 6638'SLM, LATCH WIRE, SHEAR OFF (no wire recovered) RAN 3-1/2'' GS (1/4'' brass) LATCH BAITED WIRE GRAB @ 6638'SLM (recovered ~20' of wire) RAN 3-1/2" GR, 3-1/2" BAIT SUB, 3' x 1-3/4" STEM, 4-1/2" BLB, 3.73" LIB, S/D @ 6,655' SLM (impression of wire across face) RAN 3-1/2" GR, 3-1/2" BAIT SUB, 3' x 1-3/4" STEM, 4-1/2" BLB, 3.67" 3 PRONG WIRE GRAB (wg#40), S/D & GRAB WIRE @ 6,498' & 6,655' SLM(sheared gr) RAN 3-1/2" GS, TO ~6,655' SLM & LATCH BAIT SUB (recovered ~12" wire in brush) ***WSR CONT ON 1-7-23*** 1/7/2023 Stand by to assist SL. 1/8/2023 ***WSR CONT FROM 1-7-23*** RAN 3-1/2" GR, 3-1/2" BAIT SUB, 3' x 1-3/4" STEM, 4-1/2" GR. TO 6,655' SLM (unable to latch xx-plug) RAN 3-1/2"GS, 3-1/2" BAIT SUB, 3' x 1-3/4" STEM, 3.67" 3 PRONG WIRE GRAB (wb#40) TO 6,655' SLM (NO WIRE RECOVERED) RAN 3-1/2"GR, 3-1/2" BAIT SUB, 3' x 1-3/4" STEM, 3.73" LIB, S/D @ 6,655' SLM ( slight impression of wire) MADE 3 MORE WIRE GRAB ATTEMPTS RECOVERED 25' OF WIRE (see log) MADE 3 ATTEMPTS 3.81'' XX-PLUG W/ BAITED 4-1/2'' GS(5/16'' steel, 153''oal) (unsuccessful) ***WSR CONT ON 1-9-23*** 1/9/2023 ***WSR CONT FROM 1-8-23*** MADE 3 MORE ATTEMPS JARRING ON 3.81" XX-PLUG w/ SLICKLINE TOTAL OF 6 HOURS (moving plug up hole~24') ***R/U BRAIDED LINE*** RAN 3-1/2'' PRGS, LATCH BAIT SUB @ 6609'BLM, JAR 5000# FOR 3 HOURS BEFORE COMING FREE, (pulled baited assy) ***WSR CONT 1-10-23*** 1/10/2023 Assist Slickline **Job Cancelled** 1/10/2023 ***POLLARD #60 WEATHER HOLD*** (High winds) 1/10/2023 ***WSR CONT FROM 1-9-23*** ATTEMPT TO BEAT DOWN w/ 3.64" WIRE FINDER, 4-1/2" BLB, 4-1/2" GR @ 6,597' BLM ( no movement) RAN 4-1/2" PRGS (5/16" brass) TO 6,601' BLM ( recovered g-fish neck from expander mandrel off 4-1/2" x-lock) ATTEMPTED TO BEAT DOWN w/ 3' x 1-3/4" STEM, 3.64" WIRE FINDER, 4-1/2" BLB, 3' x 2-1/8" STEM, 2.24" BLIND BOX @ 6602'BLM (no movement) RAN 3.70'' CENT, 3'x1-3/4'', 3.75'' CENT, 3.73'' LIB, TAG PLUG @ 6601'BLM ( impression of expander mandrel) ***WELL LEFT S/I*** RAN 3-1/2'' PRGS, LATCH BAIT SUB @ 6609'BLM, JAR 5000# FOR 3 HOURS@ BEFORE COMING FREE, (pulled baited assy) PULLED UP HOLE TO 6,738' SLM (parted wire) RAN 3.70'' CENT, 3' 1-3/4'', 3.75'' CENT,3.73'' LIB, S/D @ 6634'SLM (IMPRESSION ) OF RS) (unable to latch xx-plug) RAN 3.74" CENT, 4-1/2" GS CORE & EQ- PRONG TO 6,835' MD (equlized plug)(g) PULLED 3.81" XX- PLUG @ 6,835' MD, Daily Report of Well Operations PBU W-205 1/11/2023 ***POLLARD #60 WEATHER HOLD*** (High winds) 1/12/2023 ***POLLARD #60 WEATHER HOLD*** (High winds) 1/13/2023 ***CONTINUED FROM 1/12/23 WSR*** (Wellhead repair) JARRED DOWN w/ 40'x1.75" BULLNOSE ON STUCK 3.81" PLUG @ 6592' SLM. ***CONTINUED ON 1/14/22 WSR*** 1/14/2023 ***CONTNUED FROM 1/13/23 WSR*** (Wellhead repair) JARRED FISH DOWNHOLE f/ 6592' - 6650' SLM w/ 3' x 1.75" BULLNOSE STEM RAN 3.25" LIB TO FISH @ 6650' SLM (partial pic of expander mandrel w/ possible small piece of wire) MULTIPLE RUNS TO FISH @ 6650' SLM w/ 3.5" MAGNET (recovered approx 6" of wire in various pieces) SET 4 1/2" WFD RELEASABLE SPEAR ON FISH AT 6,651' MD JARRED FOR ~45 MIN & PULLED SPEAR OUT OF FISH. JARRED FISH DOWNHOLE f/ 6641' - 6674' SLM. RAN 3.5" MAGNET TO 6674' SLM (recovered 2 pieces of wire, 10" & 2.5" pieces) ***CONTINUED ON 1/15/23 WSR*** 1/15/2023 ***CONTINUED FROM 1/14/23 WSR*** RECOVERED 7" OF WIRE f/ TOP OF PLUG @ 6674' SLM w/ MAGNETS & BRUSH RECOVERED REMAINING 3.81" XX PLUG FISH @ 6674' SLM (all parts acounted for) DRIFT TBG TO 6900' SLM w/ FULL BORE BRUSH & 3 PRONG WIRE GRAB, RECOVERED 8" PIECE OF WIRE IN BRUSH ***JOB COMPLETE, WELL LEFT S/I, DSO NOTIFIED*** 1/18/2023 T/I/O = 1410/1150/30. Temp = 30°. Assist Ops w/ POP (post SC repair). AL online. Initial IA FL @ 3910' (2695' above sta # 1 SO). Assisted Ops w/ POP post SC reair. Bled OAP as needed. No signs of leaking. Final IA FL @ 6000' (605' above sta # 1 SO). Final WHPs = 220/1520/10. Ops in control of valves upon departure. 06:00 RECOVERED 7" OF WIRE f/ TOP OF PLUG @ 6674' SLM w/ MAGNETS & BRUSH@ RECOVERED REMAINING 3.81" XX PLUG FISH @ 6674' SLM (all parts acounted for) DRIFT TBG TO 6900' SLM w/ FULL BORE BRUSH & 3 PRONG WIRE GRAB, ) RECOVERED 8" PIECE OF WIRE IN BRUSH ***JOB COMPLETE, WELL LEFT S/I, DSO NOTIFIED JARRED FISH DOWNHOLE f/ 6641' - 6674' SLM. RAN 3.5" MAGNET TO 6674' SLM (recovered 2 pieces of wire, 10" & 2.5" pieces) () JARRED DOWN w/ 40'x1.75" BULLNOSE ON STUCK 3.81" PLUG @ 6592' SLM. 2022-1218_Surface_Csg_Repair_PBU_W-205_bb Page 1 of 1 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg DATE: December 22, 2022 P. I. Supervisor FROM: Brian Bixby SUBJECT: Surface Casing Repair Petroleum Inspector PBU W-205 Hilcorp North Slope LLC PTD 2031160; Sundry 322-615 12/18/2022: I stopped by PBU W-205 and met with Daniel Roberto (Subsidence Team Lead, CRUZ Construction). The well had been excavated to repair corrosion-damaged surface casing. Mr. Roberto. A copy of the was provided; pictures previously provided are included in the Survey Report. We visually inspected the casing repair job and everything looked good. Attachments: Ultrasonic Thickness Survey Report (4 pages) 9 9 9 9 9 James B. Regg Digitally signed by James B. Regg Date: 2023.06.05 14:40:33 -08'00' Performed Ultrasonic thickness testing on W-205 surface casing at 0', 8', and 10'-40' for remaining thickness assessment. 0' (7" Length x 34" circ. area) External Corrosion Pencil Probe Low: 0.330" High: 0.373" Internal Scan Low: 0.370" Average: 0.400" 8' (7" Length x 34" circ. Area) External Corrosion Pencil Probe Low: 0.287" High: 0.364" Internal Scan Low: 0.390" Average: 0.400" 10' (7" Length x 34" circ. Area) Internal Scan Low: 0.384" Average: 0.415" 10' - 16' North (6' length 6" circ. Area)10' - 16' East (6' length 6" circ. Area) Internal Scan Low: 0.400" Average: 0.412" Internal Scan Low: 0.405" Average: 0.415" 10' - 16' South (6' length 6" circ. Area) 10' - 16' West (6' length 6" circ. Area) Internal Scan Low: 0.380" Average: 0.415" Internal Scan Low: 0.399" Average: 0.420" 10' (7" Length x 34" circ. Area) Internal Scan Low: 0.392" Average: 0.417" See pgs. 2, 3, and 4 for drawing and pictures Certificate of Inspection, Ultrasonic Thickness Survey 100-UTTFORM-001 | Rev 1 25. Technician, Level & Date 26. Customer Signature (if applicable)27. Reviewed By (if applicable) Caleb Morgan, Lvl II, 12-19-22 21. Item/Component 22. ISO/Drawing No.23. Area/Unit W-250 Surface Casing N/A W-Pad 24. Test Results 3. Client Contact 5. Purchase Order No.8. Client Reference No. HILCORP ALASKA W-Pad NA 12/19/2022 1 9. Code/Specification 10. NDT Procedure 11. Acceptance Criteria ASME SECTION V, SE-797 536-UT-003 Rev 1 CUSTOMER INFO ONLY Dan Roberto NA AFE# 225-02690.14.11.01 Ultrasonic Thickness Survey Report www.mistrasgroup.com 1. Client 2. Work Location 4. Mistras Job No.6. Date 7. Page of 3 ECHO ULTRASONICS/MED VIS/415-04 14. Presentation 19. Temperature 45 ° F AS FORMED 20. Surface Condition 0.250" - 10 MHZ - 13550 / 68120-2849 Digital w/A-scan Presentation C-scan B-scanDigital Only A-scan Only 13. Instrument Serial No. 16. Calibration Block Thickness Steps 18. Transducer Size Frequency & Serial No. 0.100"-1.000" 12. Instrument Mfr. & Model 15. Calibration Block Material & Serial No. 17. 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Chmielowski Date: 2022.11.04 09:05:13 -08'00' RBDMS JSB 031524 ^ƵƌĨĂĐĞĂƐŝŶŐ>ĞĂŬ ZĞƉĂŝƌ tĞůů͗tͲϮϬϱ Wd͗ϮϬϯͲϭϭϲ tĞůůEĂŵĞ͗tͲϮϬϱ W/EƵŵďĞƌ͗ϱϬͲϬϮϵͲϮϯϭϲϱͲϬϬͲϬϬ ƵƌƌĞŶƚ^ƚĂƚƵƐ͗^/ WƌŽĚƵĐĞƌ ZŝŐ͗^>нt^^ ƐƚŝŵĂƚĞĚ^ƚĂƌƚĂƚĞ͗EŽǀϰ͕ϮϬϮϮ ƐƚŝŵĂƚĞĚƵƌĂƚŝŽŶ͗ϳĚĂǇƐ ZĞŐ͘ƉƉƌŽǀĂůZĞƋ͛ƐƚĚ͍ĂƚĞƉƉƌŽǀĂůZĞĐ͛ǀĚ͗ ZĞŐƵůĂƚŽƌǇŽŶƚĂĐƚ͗ďďŝĞĂƌŬĞƌ WĞƌŵŝƚƚŽƌŝůůEƵŵďĞƌ͗ϮϬϯͲϭϭϲ &ŝƌƐƚĂůůŶŐŝŶĞĞƌ͗tǇĂƚƚZŝǀĂƌĚ ;ϵϬϳͿϳϳϳͲϴϴϰϳ;KͿ ;ϱϬϵͿϲϳϬͲϴϬϬϭ;DͿ ^ĞĐŽŶĚĂůůŶŐŝŶĞĞƌ͗:ĞƐƐtŽƌƚŚŝŶŐƚŽŶ ϵϬϳ͘ϱϲϰ͘ϰϲϮϲ ;KͿ ƵƌƌĞŶƚŽƚƚŽŵ,ŽůĞWƌĞƐƐƵƌĞ͗ DĂǆŽƚƚŽŵ,ŽůĞWƌĞƐƐƵƌĞ͗ DĂǆ͘WƌŽƉŽƐĞĚ^ƵƌĨĂĐĞ WƌĞƐƐƵƌĞ͗ ZĞĐĞŶƚ^/dƵďŝŶŐWƌĞƐƐƵƌĞ͗ DŝŶ/͗ ϭϴϮϴ ƉƐŝΛ ϱ͕ϬϬϬ͛ ds ϭϴϮϴ ƉƐŝΛ ϱ͕ϬϬϬ͛ ds ϭϯϮϴƉƐŝ ϭϲϬϬƉƐŝ Ϯ͘ϳϱ͟ŵŽĚŝĨŝĞĚyEĂƚϳϲϮϳ͛ ;ĂƐĞĚŽŶ^,W^ŽŶ ϴͬϭϴͬϭϴͿ ;ĂƐĞĚŽŶ^,W^ŽŶ ϴͬϭϴͬϭϴͿ ;ĂƐĞĚŽŶ͘ϭƉƐŝͬĨƚŐĂƐŐƌĂĚŝĞŶƚͿ ;dĂŬĞŶŽŶ ϭϬͬϭϴͬϮϮͿ ƌŝĞĨtĞůů^ƵŵŵĂƌǇ͗ tͲϮϬϱŝƐĂŐĂƐůŝĨƚĞĚ^ĐŚƌĂĚĞƌ ůƵĨĨƉƌŽĚƵĐĞƌ͘dŚĞǁĞůůǁĂƐ^/ŽŶ ϳͬϭͬϮϮ ĨŽůůŽǁŝŶŐĂĐŽŶĨŝƌŵĞĚ ƐƵƌĨĂĐĞĐĂƐŝŶŐ ůĞĂŬ ǁŝƚŚdͬ/ͬKƉƌĞƐƐƵƌĞƐ Ăƚ ϴϬͬϭϮϬϬͬϬƉƐŝ͘ dŚĞůĞĂŬǁĂƐŽďƐĞƌǀĞĚĂƚƚŚĞ ƚŽƉŽĨƚŚĞĐŽŶĚƵĐƚŽƌůĂŶĚŝŶŐƌŝŶŐ ĂŶĚ ƐƚŽƉƉĞĚƐŽŽŶĂĨƚĞƌ ƐŚƵƚͲŝŶ͘ tŚŝůĞĂƚƚĞŵƉƚŝŶŐ ƚŽD/dͲK͕ƚŚĞKƐŚŽǁĞĚ 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ƐŚŽƌŝŶŐƐǇƐƚĞŵ ƉĞƌĞŶŐŝŶĞĞƌĞĚĞǆĐĂǀĂƚŝŽŶƉůĂŶ ƚŽ ďĞůŽǁƚĂƌŐĞƚĐŽŶĚƵĐƚŽƌĐƵƚĚĞƉƚŚ ŽĨΕϯϴ͘ϱ͛ ^ƵŶĚƌǇtŽƌŬ;ƉƉƌŽǀĂůƌĞƋƵŝƌĞĚƚŽƉƌŽĐĞĞĚͿ ^ƵƌĨĂĐĞĂƐŝŶŐ ZĞƉĂŝƌ ϭϯ͘ DŽǀĞŝŶĂŶĚƌŝŐƵƉtĞůů^ƵƉƉŽƌƚ^ƚƌƵĐƚƵƌĞ͘ Ă͘ >ĞǀĞůŐƌĂǀĞůĨŽƵŶĚĂƚŝŽŶ͘ ď͘ WůĂĐĞƐƚƌƵĐƚƵƌĂůƌŝŐŵĂƚƐ͘ Đ͘ /ŶƐƚĂůůƐŚŝŵƐďĞƚǁĞĞŶŐŝƌĚĞƌĂŶĚĨŽƵŶĚĂƚŝŽŶďĞĂŵƚŽůĞǀĞůƐƚƌƵĐƚƵƌĞ;ŽŶŽƚ ƵƐĞ ũĂĐŬƐƚŽ ůĞǀĞůƚŚĞƐƚƌƵĐƚƵƌĞͿ͘ Ě͘ :ĂĐŬƐƚŽďĞ>ŽĐŬĞĚKƵƚŝŶŽƌĚĞƌƚŽƉƌĞǀĞŶƚƵƐĞ͘ Ğ͘ EŝƉƉůĞƵƉtĞůůŚĞĂĚ^ƵƉƉŽƌƚ^ƚƌƵĐƚƵƌĞƵƐŝŶŐƚŚĞĂĚũƵƐƚĂďůĞǀĞƌƚŝĐĂůƉŽƐƚĂŶĚŚĂƵŶĐŚĞƐĨŽƌ ƉƌŽƉĞƌŚĞŝŐŚƚƉůĂĐĞŵĞŶƚĂŶĚĐŽŵƉƌĞƐƐŝŽŶůŽĂĚŝŶŐ͘ ϭϰ͘ ĞŐŝŶƚŽĞǆĐĂǀĂƚĞŝŶƐŝĚĞƚŚĞƐŚŽƌŝŶŐƐǇƐƚĞŵƚĂƌŐĞƚŝŶŐΕϭϯ͛ďĞůŽǁƚŚĞ ƚŽƉŽĨĐŽŶĚƵĐƚŽƌ Ă͘ DĂŝŶƚĂŝŶĂĚĂŝůǇŚŝŐŚͲůĞǀĞůĂĐƚŝǀŝƚǇůŽŐƉŚŽƚŽƐĂŶĚ ĚĞƐĐƌŝƉƚŝŽŶŽĨ ŵĂŝŶĂĐƚŝǀŝƚǇĨŽƌƚŚĞĚĂǇƵŶƚŝů ƌĞƉĂŝƌǁŽƌŬŝƐĐŽŵƉůĞƚĞ͘dŚŝƐŝƐƚŽďĞƐƵďŵŝƚƚĞĚƚŽK'ǁŝƚŚϭϬͲϰϬϰĂƚũŽďĐŽŵƉůĞƚŝŽŶ͘ ϭϱ͘ /ŶƐƚĂůů K EϮƉƵƌŐĞĞƋƵŝƉŵĞŶƚĂƚt^>͛ƐĚŝƐĐƌĞƚŝŽŶ͘ Ă͘ hƐĞŽĨĂŶEϮĐĂƉͬƉƵƌŐĞǁŝůůďĞĚĞƚĞƌŵŝŶĞĚŽŶƐŝƚĞ͕ƉƌŝŽƌƚŽƉƌŽĐĞĞĚŝŶŐ͕ǁŝƚŚĂĐĐƵƌĂƚĞŐĂƐ ƌĞĂĚŝŶŐƐĂŶĚĨůƵŝĚƌĞƚƵƌŶƐŽďƐĞƌǀĞĚ͘ ď͘ WƌŝŽƌƚŽĐƵƚƚŝŶŐĐŽŶĚƵĐƚŽƌ͕ŝŶƐƚĂůůĐŽŶƚŝŶƵŽƵƐŐĂƐŵŽŶŝƚŽƌŝŶŐ ĨŽƌ>>͛ƐĨƌŽŵƚŚĞĐŽŶĚƵĐƚŽƌ͘ ϭϲ͘ 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Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Rixse, Melvin G (OGC) To:Wyatt Rivard Subject:20220907 0954 PBU W-205(PTD # 203116) Conductor Top Job & OA Down Squeeze Sundry (#322-442) Change Date:Wednesday, September 7, 2022 9:55:32 AM Wyatt, Hilcorp is approved to POP well PBU W-205 ‘under evaluation’ with OA MOASP at 200 psi. If unsuccessful to maintain OA integrity at MOASP of 200 psi, Hilcorp is approved to downsqueeze the OA to conductor per original sundry 322-442. Mel Rixse Senior Petroleum Engineer (PE) Alaska Oil and Gas Conservation Commission 907-793-1231 Office 907-297-8474 Cell CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Mel Rixse at (907-793-1231 ) or (Melvin.Rixse@alaska.gov). From: Wyatt Rivard <wrivard@hilcorp.com> Sent: Tuesday, September 6, 2022 3:33 PM To: Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov> Subject: W-205(PTD # 203116) Conductor Top Job & OA Down Squeeze Sundry (#322-442) Change Hello Mel, We recently completed a conductor top job and OA injectivity test on W-205 (PTD # 203116) to remediate a surface casing leak per Sundry #322-442 (attached). Unfortunately we were unable to establish injectivity into the OA in order to proceed with OA downsqueeze. We began to see returns from conductor at ~250 psi, eventually establishing 1:1 returns from the leak at ~700 psi/1BPM. We repeated conductor top job through cement return lines and this time were able to achieve a ~30 psi squeeze inside the conductor (vs 10 psi previously). Going forward, we would like to RTP well under eval and confirm if top job successfully isolated SC leak. If top job successfully isolates the leak, we would reduce well’s OA MOASP to 200 psi to minimize chances of reactivating leak in future. If unsuccessful, we would proceed to squeeze cement from OA to conductor per original sundry procedure. Updated procedure with RTP steps attached. Please let me know if we can go ahead and pop well under eval or if you have any questions. Thank You, Wyatt Rivard | Operations Engineer (PBU: J, Q, S, U, W pads)O: (907) 777-8547 | C: (509)670-8001 | wrivard@hilcorp.comHilcorp Alaska, LLC | Anchorage, AK 99503 The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. 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WƌĞƉĂƌĞƚŽƚĂŬĞƌĞƚƵƌŶƐŽĨĨƚŚĞĂŶŶƵůƵƐƚŚƌŽƵŐŚƚŚĞ^ůĞĂŬ͘ ϭϬ͘ WƵŵƉĨƌĞĞǌĞƉƌŽƚĞĐƚĨůƵŝĚǁŝƚŚ>DĚŽǁŶƚŚĞK͘ƚƚĞŵƉƚƚŽĞƐƚĂďůŝƐŚŝŶũĞĐƚŝŽŶƌĂƚĞƵŶĚĞƌŵĂǆƉƌĞƐƐƵƌĞ ŽĨ ϭϬϬϬ ƉƐŝ ǁŚŝůĞŵĂŶĂŐŝŶŐ^ůĞĂŬƌĞƚƵƌŶƐ͘ Ă͘ ƵƌƐƚŽĨ ϭϬͲϯͬϰ͟ ϰϱ͘ϱη>ͲϴϬ͗ϱϮϬϵ ƉƐŝ͕ϴϬйŝƐ ϰϭϲϳ ƉƐŝ ď͘ ŽůůĂƉƐĞŽĨϳͲϱͬϴ͟Ϯϲη>ͲϴϬ͗ ϰϳϵϬ ƉƐŝ͕ϴϬйŝƐ ϯϴϯϮ ƉƐŝ ;tŽƌƐƚĐĂƐĞŚǇĚƌŽƐƚĂƚŝĐĚŝĨĨĞƌĞŶƚŝĂů ǁͬŐĂƐĨŝůůĞĚ/ŝƐΕϭϮϱϬƉƐŝŝŶĐŽůůĂƉƐĞ͘ Đ͘ /Ĩ K ŝŶũĞĐƚŝŽŶĞƐƚĂďůŝƐŚĞĚ͕ĂƚƚĞŵƉƚƚŽ ďƌŝŶŐ KŝŶũĞĐƚŝŽŶ ƌĂƚĞƵƉ ƚŽ ϭWDǁŚŝůĞƐƚĂǇŝŶŐƵŶĚĞƌ ϭϬϬϬƉƐŝ͘ ϭϭ͘ ZDK ĞŵĞŶƚŝŶŐ ʹ KŽǁŶƐƋƵĞĞǌĞ͘ EŽƚĞ͗ŽŶŽƚƉƌŽĐĞĞĚǁŝƚŚĚŽǁŶƐƋƵĞĞǌĞŝĨƵŶĂďůĞƚŽĞƐƚĂďůŝƐŚ K ŝŶũĞĐƚŝŽŶ͘/Ĩ ^ůĞĂŬŵĂŝŶƚĂŝŶƐϭ͗ϭƌĞƚƵƌŶƐĂĨƚĞƌƚŽƉũŽďĂŶĚ>D͕ƉƌŽĐĞĞĚǁŝƚŚĐŽŶƚŝŶŐĞŶƚKǆŽŶĚƵĐƚŽƌƐƋƵĞĞǌĞ ;^ƚĞƉϮϰͿ ϭϮ͘ ZŝŐƵƉĐĞŵĞŶƚĞƌƐƚŽKǀŝĂĂĨůĂŶŐĞĚƵŶŝŽŶ͘ ϭϯ͘ ZŝŐƵƉǀĂĐƚƌƵĐŬǁŝƚŚƐƚŝŶŐĞƌŝŶƚŚĞ ĐŽŶĚƵĐƚŽƌĨůƵƚĞƐ͘ WƌĞƉĂƌĞƚŽƚĂŬĞƌĞƚƵƌŶƐŽĨĨƚŚĞĂŶŶƵůƵƐƚŚƌŽƵŐŚƚŚĞ ^ůĞĂŬ͘ ϭϰ͘ WƵŵƉ ƚŚĞĨŽůůŽǁŝŶŐĚŽǁŶƚŚĞKĂƚ ΕϭWDŽƌ ŵĂǆƉƌĞƐƐƵƌĞŽĨ ϭϬϬϬ ƉƐŝ ǁŚŝĐŚĞǀĞƌĐŽŵĞƐĨŝƌƐƚ͘ dƌĂĐŬ ƉƵŵƉƌĂƚĞǀƐƉƌĞƐƐƵƌĞ ƚŚƌŽƵŐŚŽƵƚĚŝƐƉůĂĐĞŵĞŶƚ͗ ΎΎΎEŽƚĞ͗ ĞŵĞŶƚ ǀŽůƵŵĞƐ ďĂƐĞĚ ŽŶ ĐĂƐŝŶŐͲĐĂƐŝŶŐ ĂŶĚ ĐĂƐŝŶŐͲŽƉĞŶŚŽůĞ ĞƐƚŝŵĂƚĞƐ ŽŶůǇ͘ ĐƚƵĂů ǀŽůƵŵĞƐ ƉƵŵƉĞĚ ǁŝůů ǀĂƌǇ͘ ŐŐƌĞŐĂƚĞ Žƌ >D ŵĂǇ ďĞ ĂĚĚĞĚ ƚŽ ĐĞŵĞŶƚ ďĂƐĞĚ ŽŶ ŝŶũĞĐƚŝǀŝƚǇ ƌĞƐƉŽŶƐĞ͘ΎΎΎ ^ >ĞĂŬ ʹ KŽǁŶƐƋƵĞĞǌĞ tĞůů͗tͲϮϬϱ Wd͗ϮϬϯͲϭϭϲ ϭͿ ϭϬ>ƐŽĨϲϬͬϰϬŽƌŶĞĂƚDĞK, ϮͿ ϯϬďďůƐŽĨƐƵƌĨĂĐƚĂŶƚƉƌĞĨůƵƐŚ ŝ͘ /ĨŝŶũĞĐƚŝǀŝƚǇĚŽǁŶKůŽƐƚĚƵĞƚŽ^ůĞĂŬǁĂƐŚŽƵƚ͕ ĐĂŶĐĞůĐĞŵĞŶƚƐƚĂŐĞƐĂŶĚƉƌŽĐĞĞĚƚŽ &WK͘ ϯͿ ϲϬďďůƐŽĨ ϭϰ ƉƉŐĐĞŵĞŶƚ ǁŝƚŚ ĂŐŐƌĞŐĂƚĞ Žƌ>D ϰͿ ϭϱϱďďůƐŽĨ ϭϰ ƉƉŐ ĐĞŵĞŶƚ͘ ϭϱ͘ WƵŵƉŶŽĚŝƐƉůĂĐĞŵĞŶƚďĞŚŝŶĚĐĞŵĞŶƚ͘^ůŽǁĚŽǁŶƌĂƚĞƚŽĂƉƉƌŽǆŝŵĂƚĞůǇϭWDǁŚĞŶĂŐŐƌĞŐĂƚĞƌĞĂĐŚĞƐ ĐĂƐŝŶŐƐŚŽĞ;ϮϬϬďďůƐŽĨĐĞŵĞŶƚĂǁĂǇͬϭϱ ďďůƐĐĞŵĞŶƚƌĞŵĂŝŶŝŶŐƚŽƉƵŵƉͿ͘ ^ǁĂƉƚŽƚĂŬĞƌĞƚƵƌŶƐ Ăƚ ƐƵƌĨĂĐĞ ǁŚŝůĞƐƚŝůůŽŶĐĞŵĞŶƚ͘ ^ŚƵƚĚŽǁŶƉƵŵƉƐĂŶĚůĞĂǀĞƚŚĞǁĞůů^/͘ Ă͘EŽƚĞ͗'ŽŽĚƐƵĐĐĞƐƐŽŶKĚŽǁŶͲƐƋƵĞĞǌĞƐŚĂƐďĞĞŶƌĞĂůŝǌĞĚďǇƚŚĞŚĞƐŝƚĂƚŝŽŶƐƋƵĞĞǌĞ ŵĞƚŚŽĚ͖ŝ͘Ğ͘ƐŚƵƚƚŝŶŐĚŽǁŶƉƵŵƉĞŶƚŝƌĞůǇĂƐƚŚĞůĂƐƚΕϭϬďďůƐŽĨĐĞŵĞŶƚĂƌĞƉƵŵƉĞĚ͕ǁĂƚĐŚŝŶŐ ƚŽƐĞĞŝĨƉƌĞƐƐƵƌĞŝƐŵĂŝŶƚĂŝŶĞĚŽƌĚƌŽƉƐƌŝŐŚƚŽĨĨƚŚĞŶƉƵŵƉŝŶŐĂĐŽƵƉůĞŵŽƌĞďĂƌƌĞůƐƵŶƚŝů ĐĂƚĐŚŝŶŐĨůƵŝĚĂŶĚƌĞƉĞĂƚŝŶŐƚŚŝƐƚŽŐŝǀĞƚŚĞĂŐŐƌĞŐĂƚĞĞǀĞƌǇŽƉƉŽƌƚƵŶŝƚǇƚŽďƌŝĚŐĞŽĨĨĞŝƚŚĞƌŝŶ ƚŚĞKŽƌĂƚƚŚĞƐŚŽĞ͘ ϭϲ͘ ĨƚĞƌǁĂƐŚŝŶŐƵƉƐƵƌĨĂĐĞůŝŶĞƐ͕ŚŽůĚĂŶŽƉĞŶďůĞĞĚŽŶKĨŽƌϭŚŽƵƌ͕ƐŶŝĨĨĨŽƌ>>͛Ɛ͕ƚŚĞŶƌĞŵŽǀĞK ŐĂƚĞǀĂůǀĞĂŶĚŵĂŶƵĂůůǇĐůĞĂŶĂŶǇƌĞƐŝĚƵĂůĐĞŵĞŶƚĨƌŽŵƚŚĞǀĂůǀĞĂŶĚsZƉƌŽĨŝůĞ͘ ǀŽŝĚĨůƵƐŚŝŶŐĂĐƌŽƐƐ ƚŚĞKǁŝƚŚǁĂƚĞƌĂƐKŵĂǇďĞŽŶĂǀĂĐĂŶĚĐŽƵůĚƉƵůůĨƌĞĞǌĂďůĞĨůƵŝĚƐŝŶƚŽƚŽƉŽĨƚŚĞK͘ ϭϳ͘ ZĞƉůĂĐĞKŐĂƵŐĞƐ ϭϴ͘ ZDKĐĞŵĞŶƚĞƌƐ ϭϵ͘ ĨƚĞƌĐĞŵĞŶƚŝƐĐƵƌĞĚ͕ǀĞƌŝĨǇ/ĂŶĚKƉƌĞƐƐƵƌĞĂƚϬ ƉƐŝƚŚĞŶƌĞŵŽǀĞǀĂůǀĞ͘ ϮϬ͘ dĂŐĂŶĚƌĞĐŽƌĚĐĞŵĞŶƚƚŽƉŝŶƚŚĞKǁŝƚŚƌĞƐƉĞĐƚƚŽKǀĂůǀĞ͘ Ϯϭ͘ZĞƉůĂĐĞKǀĂůǀĞ ϮϮ͘/ĨKĐĞŵĞŶƚƚŽƉ ĨŽƵŶĚ ŵŽƌĞƚŚĂŶϭϬ͛ďĞůŽǁKǀĂůǀĞ͕ƉĞƌĨŽƌŵĂŶKƚŽƉũŽď͗ Ă͘WƵŵƉĨŝŶĞͬƐƋƵĞĞǌĞĐĞŵĞŶƚŽƌĞƉŽǆǇƌĞƐŝŶŝŶƚŚĞKƵŶƚŝůĐůĞĂŶϭ͗ϭƌĞƚƵƌŶƐĂƌĞŽďƐĞƌǀĞĚ͘dĂŬĞ ƌĞƚƵƌŶƐĨƌŽŵKĐŽŵƉĂŶŝŽŶǀĂůǀĞƚŽĂŐƌŽƵŶĚĞĚďƵĐŬĞƚŽƌƚĂŶŬ͘ ď͘&ůƵƐŚĂĐƌŽƐƐKǀĂůǀĞƐǁŝƚŚǁĂƚĞƌƚŽƌĞƚĂŝŶĨƵŶĐƚŝŽŶŽĨKǀĂůǀĞĂŶĚƉƌĞƐƐƵƌĞŐĂƵŐĞƐ͘ Đ͘ZŝŐƵƉŶŝƚƌŽŐĞŶďŽƚƚůĞŵĂŶŝĨŽůĚĂŶĚƉƌĞƐƐƵƌĞƵƉƚŽϭϬϬϬƉƐŝŵĂǆŽƌƵŶƚŝů ĐĞŵĞŶƚͬƌĞƐŝŶƌĞƚƵƌŶƐ ĂƌĞŽďƐĞƌǀĞĚŝŶĐŽŶĚƵĐƚŽƌ͘ Ϯϯ͘ZDK ΎΎΎŽŶƚŝŶŐĞŶĐǇΎΎΎ ĞŵĞŶƚŝŶŐ ʹ KǆŽŶĚƵĐƚŽƌ͞hƉƐƋƵĞĞǌĞ͟ Ϯϰ͘ ZŝŐƵƉĐĞŵĞŶƚĞƌƐƚŽKǀŝĂĂĨůĂŶŐĞĚƵŶŝŽŶ͘ Ϯϱ͘ ZŝŐƵƉǀĂĐƚƌƵĐŬǁŝƚŚƐƚŝŶŐĞƌŝŶƚŚĞ ĐŽŶĚƵĐƚŽƌĨůƵƚĞƐ͘ WƌĞƉĂƌĞƚŽƚĂŬĞƌĞƚƵƌŶƐŽĨĨƚŚĞ ĐŽŶĚƵĐƚŽƌ ĂŶŶƵůƵƐ ƚŚƌŽƵŐŚƚŚĞ^ůĞĂŬ͘ Ϯϲ͘ WƵŵƉ ƚŚĞĨŽůůŽǁŝŶŐĚŽǁŶƚŚĞK ǁŚŝůĞƚĂŬŝŶŐƌĞƚƵƌŶƐŽĨĨƚŚĞĐŽŶĚƵĐƚŽƌ Ăƚ Ă ŵĂǆƉƌĞƐƐƵƌĞŽĨ ϱϬϬ ƉƐŝ ƚŽ ŵŝŶŝŵŝǌĞŝŶũĞĐƚŝŽŶĚŽǁŶK͘ dƌĂĐŬƉƵŵƉƌĂƚĞǀƐƉƌĞƐƐƵƌĞƚŚƌŽƵŐŚŽƵƚĚŝƐƉůĂĐĞŵĞŶƚ͗ ΎΎΎEŽƚĞ͗ĞŵĞŶƚǀŽůƵŵĞƐďĂƐĞĚŽŶ ĐĂƐŝŶŐͲĐĂƐŝŶŐ ĞƐƚŝŵĂƚĞ ŽŶůǇĂƐƐƵŵŝŶŐŵŝŶŝŵĂů^ǆŽŶĚƵĐƚŽƌ ǀŽůƵŵĞ͘ĐƚƵĂůǀŽůƵŵĞƐ ƉƵŵƉĞĚ ŵĂǇ ǀĂƌǇ͘ΎΎΎ ϱͿ ϭϬ ďďůƐŽĨƐƵƌĨĂĐƚĂŶƚƉƌĞĨůƵƐŚ ŝ͘ sĞƌŝĨǇϭͬϭƌĞƚƵƌŶƐĨƌŽŵƚŚĞ^ůĞĂŬ͘ ϲͿ Εϯ ďďůƐŽĨ ϭϮͲϭϰ ƉƉŐĐĞŵĞŶƚ ;ƵŶƚŝůŐŽŽĚĐĞŵĞŶƚƌĞƚƵƌŶƐŽďƐĞƌǀĞĚŝŶĐŽŶĚƵĐƚŽƌͿ ϳͿ ϭ͘ϱďďůƐŽĨǁĞŝŐŚƚĞĚŵƵĚĞƋƵĂůƚŽĐĞŵĞŶƚWW' ŝ͘ ϳͲϱͬϴ͟ǆϭϬͲϯͬϰ͟ĂŶŶƵůĂƌǀŽůƵŵĞƚŽůĞĂŬĂƚϯϳ͛сϭ͘ϰϲďďůƐ͘ ŝŝ͘ ŝƐƉůĂĐŝŶŐǁŝƚŚĞƋƵĂůǁĞŝŐŚƚŵƵĚǁŝůůƉƌĞǀĞŶƚĐĞŵĞŶƚĨƌŽŵhͲƚƵďŝŶŐďĂĐŬŝŶƚŽK͘ Ϯϳ͘ ^/KĂŶĚĂůůŽǁďĂůĂŶĐĞĚĐĞŵĞŶƚŝŶĐŽŶĚƵĐƚŽƌƚŽƐĞƚ͘ Ϯϴ͘ ZDKĐĞŵĞŶƚĞƌƐ Ϯϵ͘ ĨƚĞƌĐĞŵĞŶƚŝƐĐƵƌĞĚ͕ǀĞƌŝĨǇ/ĂŶĚKƉƌĞƐƐƵƌĞĂƚϬƉƐŝƚŚĞŶƌĞŵŽǀĞǀĂůǀĞ͘ ϯϬ͘ ZƵŶƐŵĂůůKƚƵďŝŶŐŝŶƚŽƚŚĞKĚŽǁŶƚŽΕϱϬ͛ĂŶĚĨůƵƐŚͬĚŝƐƉů ĂĐĞKǁŝƚŚĚŝĞƐĞůƚŽƌĞƐƚŽƌĞ&W͘ ^ >ĞĂŬ ʹ KŽǁŶƐƋƵĞĞǌĞ tĞůů͗tͲϮϬϱ Wd͗ϮϬϯͲϭϭϲ ϯϭ͘ZĞƉůĂĐĞKǀĂůǀĞ ϯϮ͘ ZDK , ʹ WKWh ϯϯ͘ KŶĐĞĨŝŶĂůĐĞŵĞŶƚũŽďŝƐĐƵƌĞĚ͕ZdWĂŶĚŵŽŶŝƚŽƌ h ĨŽƌƐŝŐŶƐŽĨ^ ǆ ŽŶĚƵĐƚŽƌƌĞƚƵƌŶƐ ϯϰ͘ /ĨƚŚĞƌĞŝƐŶŽůĞĂŬĂŐĞ͕ĐŽŶǀĞƌƚǁĞůůƚŽŽƉĞƌĂďůĞƐƚĂƚƵƐ ƚƚĂĐŚŵĞŶƚƐ͗ x tĞůůďŽƌĞ^ĐŚĞŵĂƚŝĐ x ^ƵŶĚƌǇŚĂŶŐĞ&Žƌŵ ^ >ĞĂŬ ʹ KŽǁŶƐƋƵĞĞǌĞ tĞůů͗tͲϮϬϱ Wd͗ϮϬϯͲϭϭϲ tĞůůďŽƌĞ ^ĐŚĞŵĂƚŝĐ +L O F R U S 1 R U W K 6 O R S H / / & +L O F R U S 1 R U W K 6 O R S H / / & Ch a n g e s t o A p p r o v e d W o r k O v e r S u n d r y P r o c e d u r e 'D W H - X O \ 6X E M H F W & K D Q J H V W R $ S S U R Y H G 6 X Q G U \ 3 U R F H G X U H I R U : H O O : 6X Q G U \ $Q \ P R G L I L F D W L R Q V W R D Q D S S U R Y H G V X Q G U \ Z L O O E H G R F X P H Q W H G D Q G D S S UR Y H G E H O R Z & K D Q J H V W R D Q D S S U R Y H G V X Q G U \ Z L O O E H F R P P X Q L F D W H G WR W K H $2 * & & E \ W K H Z R U N R Y H U : 2 ³ I L U V W F D O O ´ H Q J L Q H H U $ 2 * & & Z U L W W H Q D S SU R Y D O R I W K H F K D Q J H L V U H T X L U H G E H I R U H L P S O H P H Q W L Q J W K H F K D Q J H 6W H S 3D J H 'D W H 3 U R F H G X U H & K D Q J H +16 3U H S D U H G %\ , Q L W L DO V +1 6 $S SU RY H G %\ , Q L W L D O V $2 * & & : U L W W H Q $S S U R Y D O 5 H F H L Y H G 3 H U V R Q D Q G ' D W H $S S U R Y D O $V V H W 7 H D P 2 S H U D W L R Q V 0 D Q D J H U ' D W H 3U H S D U H G )L U V W & D O O 2 S H U D W L R Q V ( Q J L Q H H U ' D W H From:Rixse, Melvin G (OGC) To:AOGCC Records (CED sponsored) Subject:FW: [EXTERNAL] 20220803 1056 Questions MIT on Inner Casing PTD203-116, W-205 Date:Friday, August 5, 2022 2:04:08 PM Attachments:image001.png image002.png From: Rixse, Melvin G (OGC) Sent: Friday, August 5, 2022 9:21 AM To: Wyatt Rivard <wrivard@hilcorp.com> Subject: RE: [EXTERNAL] 20220803 1056 Questions MIT on Inner Casing PTD203-116, W-205 Wyatt, Approved to proceed as described below. Please report to AOGCC via email, Mel Rixse, the results of the MIT-IA. Mel Rixse Senior Petroleum Engineer (PE) Alaska Oil and Gas Conservation Commission 907-793-1231 Office 907-297-8474 Cell CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Mel Rixse at (907-793-1231 ) or (Melvin.Rixse@alaska.gov). From: Wyatt Rivard <wrivard@hilcorp.com> Sent: Thursday, August 4, 2022 4:38 PM To: Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov> Subject: RE: [EXTERNAL] 20220803 1056 Questions MIT on Inner Casing PTD203-116, W-205 Mel, As discussed we will get on the well in the next couple of days with SL and pull OV to circulate the well, freeze protect then an MIT-T and CMIT-TxIA to 2500 psi. With passing MITs I would like to go ahead and pull the TTP at 6835’ MD while I have slickline on the well. Plug was originally set for securement assuming heating and weld repair of SC leak. With two barriers verified, plug would not be needed in support of OA downsqueeze. Thank You, Wyatt Rivard | Operations Engineer (PBU: J, Q, S, U, W pads)O: (907) 777-8547 | C: (509)670-8001 | wrivard@hilcorp.comHilcorp Alaska, LLC | Anchorage, AK 99503 From: Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov> Sent: Thursday, August 4, 2022 10:47 AM To: Wyatt Rivard <wrivard@hilcorp.com> Subject: RE: [EXTERNAL] 20220803 1056 Questions MIT on Inner Casing PTD203-116, W-205 Wyatt, Can’t you load preferentially through the Station 1 orifice? Mel Rixse Senior Petroleum Engineer (PE) Alaska Oil and Gas Conservation Commission 907-793-1231 Office 907-297-8474 Cell CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Mel Rixse at (907-793-1231 ) or (Melvin.Rixse@alaska.gov). From: Wyatt Rivard <wrivard@hilcorp.com> Sent: Wednesday, August 3, 2022 5:37 PM To: Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov> Subject: RE: [EXTERNAL] 20220803 1056 Questions MIT on Inner Casing PTD203-116, W-205 Mel, Please see answers below in red. For W-205 specifically, I can add a step to remove a GLV, circulate and then get a CMIT-TxIA to 2500 psi against existing plug. Plug was initially set for securement only but it’s not difficult to get a CMIT while we are here. Thank You, Wyatt Rivard | Operations Engineer (PBU: J, Q, S, U, W pads)O: (907) 777-8547 | C: (509)670-8001 | wrivard@hilcorp.comHilcorp Alaska, LLC | Anchorage, AK 99503 From: Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov> Sent: Wednesday, August 3, 2022 10:57 AM To: Wyatt Rivard <wrivard@hilcorp.com> Subject: [EXTERNAL] 20220803 1056 Questions MIT on Inner Casing PTD203-116, W-205 Wyatt, What date was the TT plug set? Plug was set on 7/11/22 with T/IA/OA pressures at 1200/1200/0. Tubing was initially bled down from 1200 psi to 700 psi to confirm plug set. Following initial bleed, TBG and IA slowly equalized with each other (through live GLVs) to ~1000psi What were the fluid levels on tubing and IA after setting the TT plug and bleeding down the IA from 1200 psi to 400 psi? On 7/28 we bled the IA down from 1000 to 400 psi. The pre bleed IA fluid level was on orifice at 6605’ MD. After 30 mins the fluid level and pressures did not change. IA remains at 400 psi currently. OA pressure/ fluid level has remained at 0psi/near surface since leak was detected. We did not have SSV open during IA bleed as focus was on the OA to IA integrity ahead of potential downsqueeze. Why did the leak stop after shut in? SC leaks frequently stop when well is SI even with no pressure on the OA. Assumption is that OA and conductor annulus fluid levels drop at cooler SI temps and/or less ballooning from inner tubulars. What is your maximum estimated IA injection pressure when this well is POP? Well has consistently produced with a gas lift pressure of 1100-1300 psi since initial completion in 2007. For initial unloading after fluid pack, we could expect pressures to max out at ~2000 psi. Guy Schwartz, before he retired, had initiated a production casing integrity check for producers. It has been my observation that Hilcorp was testing IC on a maximum of 8 years on an opportunistic basis. It has been 15 years since a true pressure test on the inner casing. Has something changed? We typically perform opportunistic positive pressure tests of casing ahead of tubing RWOs or during other diagnostics where annuli is fluid packed. I remember discussion with Guy of possible 8 year testing of producers including positive pressure tests for some wells and enhanced TIFLs for others depending on the lift type (Jet pump, ESP, Gas Lift, etc). However, the only cyclical positive pressure tests of producers that I am aware of in practice are for monbore reverse acting jet pumps (4 years) and for packerless ESP wells at MPU which are tested every 4 or 8 years per CO 390A (included below). Mel Rixse Senior Petroleum Engineer (PE) Alaska Oil and Gas Conservation Commission 907-793-1231 Office 907-297-8474 Cell CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Mel Rixse at (907-793-1231 ) or (Melvin.Rixse@alaska.gov). From: Wyatt Rivard <wrivard@hilcorp.com> Sent: Tuesday, August 2, 2022 11:30 AM CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. To: Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov> Subject: RE: [EXTERNAL] MIT on Inner Casing PTD203-116, W-205 Hello Mel, Until the well was SI, the gas lifted IA was consistently operating at ~1200 psi (~900-1200 psi differential over the OA). OA pressure has been steady at 0-250 psi with fluid level at surface and no gas observed in the OA or bubbling in the cellar. TIO plot included below for reference. Following well SI and securement with tubing tail plug, the IA was bled down to ~400 psi, with no change to IA or OA fluid levels. This indicates that production casing has integrity at least to the OA shoe. Thank You, Wyatt Rivard | Operations Engineer (PBU: J, Q, S, U, W pads)O: (907) 777-8547 | C: (509)670-8001 | wrivard@hilcorp.comHilcorp Alaska, LLC | Anchorage, AK 99503 From: Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov> Sent: Monday, August 1, 2022 4:38 PM To: Wyatt Rivard <wrivard@hilcorp.com> Subject: [EXTERNAL] MIT on Inner Casing PTD203-116, W-205 Wyatt, Shouldn’t you perform on integrity test on the IC before squeezing the OA? Mel Rixse Senior Petroleum Engineer (PE) Alaska Oil and Gas Conservation Commission 907-793-1231 Office 907-297-8474 Cell CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Mel Rixse at (907-793-1231 ) or (Melvin.Rixse@alaska.gov). The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entitynamed above. 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ĂŶŶƵůƵƐс͘ϬϯϴϮϱďƉĨ ΎϭϯϴϬ͛сϱϯďďůƐ DĂǆŝŵƵŵ KнK,ŶŶƵůĂƌǀŽůƵŵĞс ϮϭϭďďůƐ WƌŽĐĞĚƵƌĞ͗ ^ƵŶĚƌǇ tŽƌŬ ;ƉƉƌŽǀĂůƌĞƋƵŝƌĞĚƚŽƉƌŽĐĞĞĚͿ ĞŵĞŶƚŝŶŐ ʹ ŽŶĚƵĐƚŽƌdŽƉ:Žď ϭ͘ /ŶƐƚĂůů ũĞǁĞůƌǇ ĂŶĚ ƋƵĂƌƚĞƌƚƵƌŶǀĂůǀĞƐŽŶďŽƚŚŽĨƚŚĞĐŽŶĚƵĐƚŽƌĐĞŵĞŶƚƌĞƚƵƌŶůŝŶĞƐ͘ Ϯ͘ dƌŽǁĞůĐĞŵĞŶƚƚŚƌŽƵŐŚĨůƵƚĞƐŽǀĞƌĞǆŝƐƚŝŶŐĐĞŵĞŶƚĚŽƵŐŚŶƵƚĂŶĚ ĂůůŽǁƚŽĐƵƌĞďĞĨŽƌĞƉƵŵƉŝŶŐƚŚƌŽƵŐŚ ƌĞƚƵƌŶůŝŶĞƐ͘dŚŝƐ ĚŽƵŐŚŶƵƚ ŵĂǇ ƉƌŽǀŝĚĞ Ă ͞ƚŽƉ͟ĨŽƌ ůŽǁƉƌĞƐƐƵƌĞ ĐŽŶĚƵ ĐƚŽƌƐƋƵĞĞǌĞ͘ ϯ͘ WƵŵƉĂĨŝŶĞ͕ƐƋƵĞĞǌĞĐŽŶĐƌĞƚĞ ŽƌƌĞƐŝŶ ƚŚƌŽƵŐŚ ĐŽŶĚƵĐƚŽƌĐĞŵĞŶƚƌĞƚƵƌŶůŝŶĞƐĂŶĚƵƉƚŽĐŽŶĚƵĐƚŽƌĨůƵƚĞ ĚŽƵŐŚŶƵƚƚŽĨŝůůǀŽŝĚƐƉĂĐĞ͘ ϰ͘ ƚƚĞŵƉƚƚŽƉƵŵƉĂŶĂĚĚŝƚŝŽŶĂů ϭďďůŽĨ ĐĞŵĞŶƚŝŶƚŽĐŽŶĚƵĐƚŽƌĂƚůŽǁƉƌĞƐƐƵƌĞ;фϭϬƉƐŝͿ Ă͘ DĂŝŶƚĂŝŶŽƉĞŶďůĞĞĚŽŶƚŚĞKƚŽ ĞŶĐŽƵƌĂŐĞĐĞŵĞŶƚƚŽ ŵŽǀĞ ƚŽǁĂƌĚƐƚŚĞůĞĂŬƐŝƚĞ͘ ϱ͘ KŶĐĞƚŚŝĐŬĞŶŝŶŐƚŝŵĞĂĐŚŝĞǀĞĚŽƌŵĂǆϭďďů;Εϰ͛ŽĨ^ǆŽŶĚƵĐƚŽƌǀŽůƵŵĞͿƐƋƵĞĞǌĞĚ͕^/KĂŶĚĐŽŶĚƵĐƚŽƌ ƌĞƚƵƌŶůŝŶĞƐ͘ ,ŽƚKŝůΘsĂĐdƌƵĐŬ ʹ K/ŶũĞĐƚŝǀŝƚǇƚĞƐƚ ǁŝƚŚ>D ϲ͘ ƐƚĂďůŝƐŚĐŽŶƚĂŝŶŵĞŶƚŝŶǁĞůůĐĞůůĂƌĂƌŽƵŶĚĐŽŶĚƵĐƚŽƌƚŽĐĂƚĐŚƌĞƐŝĚƵĂůƌĞƚƵƌŶƐĨƌŽŵƐƵƌĨĂĐĞĐĂƐŝŶŐůĞĂŬ͘ ϳ͘ ZŝŐƵƉ ,ŽƚKŝůƚƌƵĐŬ ƚŽK ĂŶĚWd͘ ϴ͘ ZŝŐƵƉǀĂĐƚƌƵĐŬǁŝƚŚƐƚŝŶŐĞƌŝŶƚŚĞŽŶĚƵĐƚŽƌ ĨůƵƚĞƐ͘ ϵ͘ 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ƵƚͬĞǆƉĂŶĚǁŝŶĚŽǁƐĂŶĚƌĞŵŽǀĞĐĞŵĞŶƚĂƐŶĞĞĚĞĚƚŽĐŽŶĨŝƌŵǁĞůĚĂďůĞ͕ƵŶĐŽƌƌŽĚĞĚƐƵƌĨĂĐĞĐĂƐŝŶŐ Ăƚ ǁŝŶĚŽǁĚĞƉƚŚƐ ďĞĨŽƌĞĐƵƚƚŝŶŐĐŽŶĚƵĐƚŽƌ͘ ϭϱ͘ /ŶƐƚĂůůEϮƉƵƌŐĞĞƋƵŝƉŵĞŶƚĨŽƌ ƚŚĞ K Ăƚt^>͛ƐĚŝƐĐƌĞƚŝŽŶ͘ Ă͘ hƐĞŽĨĂŶEϮĐĂƉͬƉƵƌŐĞǁŝůůďĞĚĞƚĞƌŵŝŶĞĚŽŶƐŝƚĞ͕ ƉƌŝŽƌƚŽƉƌŽĐĞĞĚŝŶŐ͕ ǁŝƚŚĂĐĐƵƌĂƚĞŐĂƐ ƌĞĂĚŝŶŐƐĂŶĚĨůƵŝĚƌĞƚƵƌŶƐŽďƐĞƌǀĞĚ͘ ď͘ WƌŝŽƌƚŽĐƵƚƚŝŶŐĐŽŶĚƵĐƚŽƌ͕ ŝŶƐƚĂůůĐŽŶƚŝŶƵŽƵƐŐĂƐŵŽŶŝƚŽƌŝŶŐĨŽƌ>>͛ƐĨƌŽŵƚŚĞĐŽŶĚƵĐƚŽƌ͘ ϭϲ͘ ƵƚĂŶĚ ƌĞŵŽǀĞĐŽŶĚƵĐƚŽƌĨƌŽŵ ĂďŽǀĞƚŚĞ ϵ Ĩƚ ŝŶƐƉĞĐƚŝŽŶŚŽůĞƐ͘ Ă͘ WƌŝŵĂƌǇĐƵƚƚŝŶŐŽƉƚŝŽŶŝƐƚŽƵƐĞĂŶĂŝƌĂƌĐƚŽƌĐŚďƵƚƚŚĞ,ŽƚtŽƌŬWĞƌŵŝƚĨŽƌƚŚŝƐƉŽƌƚŝŽŶŽĨƚŚĞ ũŽďǁŝůůĚŝĐƚĂƚĞŝĨĂŶĂůƚĞƌŶĂƚŝǀĞĐƵƚƚŝŶŐŵĞƚŚŽĚǁŝůůďĞƌĞƋƵŝ ƌĞĚ͘ ď͘ dǁŽŚŽƌŝǌŽŶƚĂůĐƵƚƐ;ďĞůŽǁůĂŶĚŝŶŐƌŝŶŐĂŶĚŽŶĞĂƚďŽƚƚŽŵŽĨĐŽŶĚƵĐƚŽƌƐĞĐƚŝŽŶͿĂŶĚƚǁŽǀĞƌƚŝĐĂů ĐƵƚƐǁŝůůďĞƌĞƋƵŝƌĞĚƚŽƌĞŵŽǀĞƚŚĞĐŽŶĚƵĐƚŽƌ͘ ůƚĞƌŶĂƚĞůǇ͕ŝĨƚŚĞƌĞŝƐŶŽƚƐƵĨĨŝĐŝĞŶƚƌŽŽŵƚŽ ĚƌŽƉƚŚĞůĂŶĚŝŶŐƌŝŶŐďĞůŽǁƚŚĞƉĂƚĐŚĂƌĞĂ͕ƚŚĞǀĞƌƚŝĐĂůĐƵƚŵĂǇďĞĐĂƌƌŝĞĚĂůůƚŚĞǁĂǇƵƉĂŶĚ ƚŚƌŽƵŐŚƚŚĞůĂŶĚŝŶŐƌŝŶŐ͘ ϭϳ͘ ŚŝƉĂǁĂǇĞǆĐĞƐƐĐĞŵĞŶƚĨƌŽŵƚŚĞƐƵƌĨĂĐĞĐĂƐŝŶŐ͘ƵĨĨĂŶĚƉƌĞƉĂƌĞƐƵƌĨĂĐĞĐĂƐŝŶŐĨŽƌŝŶƐƉĞĐƚŝŽŶĂŶĚ ǁĞůĚŝŶŐ͘ ϭϴ͘ /ŶƐƉĞĐƚŝŽŶĚĞƉĂƌƚŵĞŶƚƚŽhdƚŚĞĞǆƉŽƐĞĚƐƵƌĨĂĐĞĐĂƐŝŶŐ͘ Ă͘ 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DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE F:~LaserFiche\CvrPgs_Inserts~Microfilm Marker.doc RECEIVED _ STATE OF ALASKA ALAS~IL AND GAS CONSERVATION COMMISa REPORT OF SUNDRY WELL OPERATìð'NS 1. Operations Abandon D Repair Well 0 Performed: Alter Casing D Pull Tubing D Change Approved Program D Opera!. Shutdown D 2. Operator BP Exploration (Alaska), Inc. Name: 3. Address: P.O. Box 196612 'Anchorage, AK 99519-6612 7. KB Elevation (ft): Plug Perforations D Perforate New Pool D Perforate D 4. Current Well Class: Development W Stratigraphic 80.9 KB 8. Property Designation: ADLO-028263 11. Present Well Condition Summary: Total Depth measured 10670 feet true vertical 5223.61 feet Effective Depth measured 10670 feet true vertical 5223.61 feet Casing Length Size MD Conductor 80' 20" 215.5# A53 28' - 108' 3151' 10-3/4" 45.5# L-80 29' - 3180' 7592' 7-5/8" 29.7# L-80 26' - 7618' 3152' 4-1/2" 12.6# L-80 7517' - 10669' 400' 7-5/8" X 4-1/2" 29.7#/12.6# L-8 7135' - 7535' Perforation depth: Measured depth: 7700' - 10667' True Vertical depth: 5189' - 5224' - - Tubing: (size, grade, and measured depth) 4-1/2" 12.6# OCT 1 9 StimulateD Alaska ~Wß.IIDtJ: r.orH'i (~Îtmmìlfç¡¡'¡ì\ WaiverD Time ExtensionlJ Re-enter Suspended well~ChOr3ij~ 5. Permit to Drill Number: 203-1160 Exploratory Service 6. API Number: 50-029-23165-00-00 9. Well Name and Number: PBU W-205 10. Field/Pool(s): PRUDHOE BAY Field! POLARIS OIL Pool Plugs (measured) None Junk (measured) 7610 TVD 28' - 108' 29' - 3180' 26' - 5184' 5176' - 5224' 5101' - 5711' Burst Collapse 5210 6890 8430 8430 2480 4790 7500 7500 - - L-80 27' - 6895' 7-5/8" x 4-1/2" bkr prem pkrm o o o 6770' o o o Packers and SSSV (type and measured depth) 12. Stimulation or cement squeeze summary: Intervals treated (measured): 8(;ANN~Ð Treatment descriptions including volumes used and final pressure: 2 G ZDDS Prior to well operation: Subsequent to operation: 14. Attachments: Copies of Logs and Surveys Run Daily Report of Well Operations Representative Daily Average Production or Injection Data Gas-Mcf Water-Bbl Casing Pressure 37 4372 0 o 0 0 15. Well Class after proposed work: Exploratory Development W 16. Well Status after proposed work: Oil W Gas r WAG r 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. 13. Oil-Bbl 60 Shut in X Contact Gary Preble Tubing pressure 313 o Service GINJ r WINJ WDSPL ISUndry Number or N/A if C.O. Exempt: Printed Name Gary Preble ~ /'"' A_ r / /)9'./ Signature )¿7d ~- /£67 Ó ,/ Phone 564-4944 Title Data Engineer Date 10/18/2006 Form 10-404 Revised 04/2004 np'~!~JÔ RBDMS 8Ft OCT 2 0 100& Submit Original Only ,. . . W-205 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY SHUT IN ON ARRIVAL. BAKER 45 WL "KB" STRADDLE COMPLETION FROM 5685' - 5720'. CORRELATED TO SWS LDL DATED 22-MAY-2005 COMPLETE. WELL LEFT SHUT IN. TURNED OVER TO DSO. FINAL TI 1/0 010/50. Patch min I.D. is 2.45", OAL = 42' Pull wla 41/2" gs FLUIDS PUMPED BBLS 304 2%KCI 32 60/40 MeOH 336 TOTAL qÔ~ DATA SUBMITTAL COMPLIANCE REPORT 12/5/2005 Permit to Drill 2031160 Well Name/No. PRUDHOE BAY UN POL W-205 Operator BP EXPLORATION (ALASKA) INC s~ ~~ ~ ~().~) API No. 50-029-23165-00-00 MD 10670 -TVD 5224/ Completion Date 9/9/2003 Completion Status 1-01L Current Status 1-01L UIC N ~-_. REQUIRED INFORMATION Mud Log No Samples No Directional surv~ ~ DATA INFORMATION Types Electric or Other Logs Run: MWD, GR, IFR, MS, RES, QEN, NEU, PWD, AIM, ope MDT Well Log Information: (data taken from Logs Portion of Master Well Data Maint Log/ Electr . Data Digital Dataset Log Log Run Interval OH/ Z Med/Frmt Number Name Scale Media No Start Stop CH Received Comments C Lis 13199 Production 1 6795 9635 Case 7/14/2005 Z 0 Asc Directional Survey 0 10670 9/29/2003 Directional Survey 0 10670 9/29/2003 Schlumberger Rpt Directional Survey 0 10670 9/29/2003 Anadrill ¡ED 0 Las 12367 Production 6230 10112 Case 1/20/2004 .J ED 0 Las 12367 Spinner 6230 10112 Case 1/20/2004 ED 0 Las 12367 Temperature 6230 10112 Case 1/20/2004 ED 0 Las 12367 Casing collar locator 6230 10112 Case 1/20/2004 I ED 0 Las 12367 Pressure 6230 10112 Case 1/20/2004 Log Production 12 BM 6230 10112 Case 1/20/2004 Production Profile Log Spinner 12 BM 6230 10112 Case 1/20/2004 Production Profile c/ Log Temperature 12 BM 6230 10112 Case 1/20/2004 Production Profile . Log Casing collar locator 12 BM 6230 10112 Case 1/20/2004 Production Profile r Log Pressure 12 BM 6230 10112 Case 1/20/2004 Production Profile .Æog 13199 Production 5 Blu 6795 9635 Case 7/14/2005 v4 C Lis 13321 I nd uction/Resistivity 108 10670 Open 10/17/2005 Vision Res & Dens (LIS format + .pds graphics MD/TVD) v(og Induction/Resistivity 25 Blu 108 10670 Open 10/17/2005 Vision Resistivity ...{og I nd uction/Resistivity 25 Blu 108 10670 Open 10/17/2005 Vision Resistivity ../ I Log Density 25 Blu 108 10670 Open 10/17/2005 Vision Density Neutron ~Og __ Density 25 Blu 108 10670 Open 1 0/17/2005 Vision Density Neutron DATA SUBMITTAL COMPLIANCE REPORT 12/5/2005 Permit to Drill 2031160 Well Name/No. PRUDHOE BAY UN POL W-205 Operator BP EXPLORATION (ALASKA) INC API No. 50-029-23165-00-00 MD 10670 TVD 5224 Well Cores/Samples Information: Name ADDITIONAL INFORMATION Well Cored? y ~ Chips Received? ~ I I~ - Analysis Received? ~ Comments: Compliance Reviewed By: Completion Date 9/9/2003 Completion Status 1-01L ~ w-- Interval Start Stop Sent Received Daily History Received? Formation Tops Current Status 1-01L UIC N Sample Set Number Comments ~/N &)N -----~JJ. .. ----- Date:-- it' -.J. 'J.a..I ^ ~~ )- . . ScblumbepueP Schlumberger-DCS 2525 Gambell St, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Well W-205 W-205 W-205 W-205 W-205 Job# Log Description 40009497 OH EDIT OF LWD DATA ARC, AD & POWERPULSE GR 40009497 MD VISION RESISTIVITY 40009497 TVD VISION RESISTIVITY 40009497 MD VISION DENSITY NEUTRON 40009497 TVD VISION DENSITY NUETRON PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 900 E Benson Blvd. Anchorage AK 99508-4254 Date Delivered: /ì O,}- ^« r- 09/08/03 09/06/03 09/06/03 09/06/03 09/06/03 NO. 3486 Company: Alaska Oil & Gas Cons Comm Altn: Helen Warman 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Polaris Date BL Color Received by: CD J'>j:vt cJlJJ ~~~-II<' 10/06/05 . . F:l<- a STATE OF ALASKA ALASK...... AND GAS CONSERVATION COM.ION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1a. Well Status: IBI Oil 0 Gas 0 Plugged 0 Abandoned 0 Suspended 0 WAG 20AAC 25.105 20AAC 25.110 o GINJ 0 WINJ 0 WDSPL No. of Completions 2. Operator Name: BP Exploration (Alaska) Inc. 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 4a. Location of Well (Governmental Section): Surface: 3703' NSL, 1196' WEL, SEC. 21, T11 N, R12E, UM Top of Productive Horizon: 4185' NSL, 3575' EWL, SEC. 22, T11N, R12E, UM (OBd) Total Depth: 1857' NSL, 3432' EWL, SEC. 15, T11N, R12E, UM 4b, Location of Well (State Base Plane Coordinates): Surface: x- 612049 y- 5958680 Zone- ASP4 --~-_.---_.._---_.. _._..__..,~-_.- TPI: x- 616812 y- 5959234 Zone- ASP4 ---..---------.---.. ..- Total Depth: x- 616618 y- 5962184 Zone- ASP4 18. Directional Survey IBI Yes 0 No 21. Logs Run: MWD, GR, IFR, MS, RES, DEN, NEU, One Other 5. Date Camp., Susp., or Aband. 9/9/2003 6. Date Spudded 8/23/2003 7. Date T.D. Reached 9/6/2003 8. KB Elevation (ft): KBE = 80.90' 9. Plug Back Depth (MD+ TVD) 10670 + 5224 10. Total Depth (MD+TVD) 10670 + 5224 11. Depth where SSSV set (Nipple) 2620' MD 19. Water depth, if offshore N/A MSL CASING SIZE 20" x 34" 10-3/4" 7-5/8" 4-1/2" 7-5/8" x 4-1/2" PWD, AIM, DPC MDT, SCMT CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTH TVD HOLË Top BOTTOM Top BOTTOM SIZE Surface 108' Surface 108' 48" 29' 3985' 29' 3180' 13-112" 26' 7618' 26' 5184' 9-7/8" 7517' 10669' 5176' 5224' 6-3/4" 7135' 7535' 5101' 5711' N/A 22. Wr. PER FT. 215.5# 45.5# 29.7# 12.6# 29.7# /12.6# GRADE A53 L-80 L-80 L-80 L-80 23. Perforations open to Production (MD + TVD of Top and Bottom Interval, Size and Number; if none, state "none"): 4-1/2" Slotted Section MD TVD MD TVD 7700' - 10667' 5189' - 5224' 26. Date First Production: September 19, 2003 Date of Test Hours Tested 11/21/2003 8 PRODUCTION FOR TEST PERIOD .. CALCULATED ....... 24-HoUR RATE""" Flow Tubing Casing Pressure Press. 310 None Form 10-407 Revised 12/2003 24. SIZE 4-1/2", 12.6#, L-80 Revised: After ML's added, New Tubing & Tieback 1b. Well Class: IBI Development 0 Exploratory o Stratigraphic Test 0 Service 12. Permit to Drill Number 203-116 13. API Number 50- 029-23165-00-00 14. Well Name and Number: PBU W-205 15. Field / Pool(s): Prudhoe Bay Field / Polaris Pool Ft Ft 16. Property Designation: ADL 028263 17. Land Use Permit: 20. Thickness of Permafrost 1900' (Approx.) CEMENTING RECORD 260 sx Arctic Set (Approx.) 897 sx PF 'L', 352 sx Class 'G" 561 sx Class 'G' Uncemented Slotted Liner Uncemented Tieback Liner AMOUNT PULLED TUBING RECORD DEPTH SET (MD) 6895' PACKER SET (MD) 6770' 25. ACID, FRACTURE, CEMENT SOUËEZE,ETC. AMOUNT & KIND OF MATERIAL USED DEPTH INTERVAL (MD) 7610' Set IBP (To isolate original perfs while drilling multilaterals) Freeze Protect with 110 Bbls Diesel GAs-McF 26 WATER-BBL -0- PRODUCTION TEST Method of Operation (Flowing, Gas Lift, etc.): Gas Lift Oll-Bsl 1,041 Oll-Bsl 3,123 27. CORE DATA Dïr-rl\/Cn Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or wa'àN:~~J:trYt~~, if necessary). Submit core chips; if none, state "none". GAs-McF 78 W A TER-BBL -0- ORiGiNAL CONTINUED ON REVERSE SIDE Gr CHOKE SIZE I GAS-OIL RATIO 1760 25 Oil GRAVITY-API (CORR) JAN 2 9 2004 Ie 0'\ &. ['."5 C"Os Commission Alas"s II. \Ju IV' . Anchorage ~afl FEB 0 28. GEOLOGIC MARKER. NAME MD TVD Ugnu 4415' 3469' Ugnu M Sandstones 6050' 4565' Schrader Bluff N Sandstones 6424' 4795' Schrader Bluff 0 Sandstones 6784' 4972' OBa 6928' 5030' OBb 7008' 5060' OBc 7177' 5113' OBd 7494' 5174' '.RMATION TESTS Include and briefly summarize test results. List intervals tested, and attach detailed supporting data as necessary. If no tests were conducted, state "None". 29. MDT was ran. Attached is a summary of MDT results. The fluid samples are currently being analyzed, and GOR and oil gravity data are not available at this time, but may be ready in about a month. Greg Bernaski is the Anchorage contact for the fluid testing results. RECE JAN 2 9 ZOOl1 Alaska 30. List of Attachments: Summary of Daily Drilling Reports, Well Schematic Diagram, Surveys & Gas Cons. AIl1,1IUrage 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~ A /I t.-J IJ. M", T'tl T h· I A . t t D t Ol ..,n..()U TerrieHubble /I~v';e.. ~ Ie ec nlca 5515 an ae A^-C -( PBU W-205 203-116 Prepared By Name/Number: Terrie Hubble, 564-4628 Well Number Drilling Engineer: Michael Triolo, 564-5774 Permit No. / Approval No. 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 1a: Classification of Service Wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. ITEM 4b: TPI (Top of Producing Interval). ITEM 8: The Kelly Bushing elevation in feet above mean low low water. Use same as reference for depth measurements given in other spaces on this form and in any attachments. ITEM 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). ITEM 20: True vertical thickness. ITEM 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITEM 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). ITEM 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, or Other (explain). ITEM 27: If no cores taken, indicate "None". ITEM 29: List all test information. If none, state "None". Form 10-407 Revised 12/2003 nQ'h'~L^ . . Well: Field: API: Permit: W-205L 1 & L2 Prudhoe Bay Unit 50-029-23165-60 & -61 203-201 & 203-202 Accept Spud: Release: Rig: 12/10/03 12/14/03 12/28/03 Nabors 9ES ,.,~~,~."... ... .'=~N=. ,..... PRE-RIG WORK 11/30/03 WELL SHUT IN UPON ARRIVAL. DRIFT NEW 1.5" CT WI 0.937" STEEL BALL. MU BAKER MHA W/2.5" JSN. RIH AND JET TUBING W/ HOT CRUDE. TAGGED TOP OF PARRAFIN PLUG AT 3008' CTMD AND MELTED THROUGH VARIOUS PLUGS DOWN TO 3970' CTMD. 12/01/03 CONTINUE JETTING TUBING AND MANDRELS WI HOT CRUDE TO 6580' CTMD. PLACED WELL IN TEST AND RIH TO 10,145 WHERE LOCKUP OCCURED. FLAGGED COIL AT 10,100' CTMD FROM PROD LOGGING RUN AND POOH. MU PDS M GRICCL STP AND RIH TO 6500' CTMD' AND WAIT FOR WELL TO STABILIZE. MADE STP STOP COUNTS AT 6500',7600',8100',8600',9100',9600',10090'; CTMD. LOGGED STP UPIDOWN PASSES AT 30 & 60 FPM. AVERAGE TEST RATE = 917 BPD GFR, 862 BOPD, 2.89 MM GL, 1.2 MM FORMATION GAS, 418 PSI, 59 DEG F. FLAGGED COIL AT 7500' CTMD, AND MADE JEWLERY LOG UP TO 6200'. PULLED SURFACE SAMPLES FROM LIQUID LEG OF TEST SEPARATOR. MADE +30 FT CORRECTION TO TIE-IN TO SWS DENSITY NEUTRON 23-AUG-03 TO 06-SEP-03, RUN #5. LAY DOWN PDS TOOLS AND MU BAKER 2.50" IBP (1-3/8" JDC FN, 2 X 0.53' RUBBER ELEMENT, 5500# PULL RELEASE, OAL=11.58') AND RIH TO FLAG. RESET COUNTER TO CEL @ 7525' AT FLAG. 12/02/03 DROP BALL, WAIT 3 HOURS FOR TEMPERATURE STABILIZATION, AND SET BAKER 2.50" IBP AT 7610'. TAG IBP W/3K, PLUG SET. POOH CHASING OUT AT 80% W/1% KCL TO 2500'. FREEZE PROTECT FROM 2500' TO SURFACE. PRESSURE TEST IBP TO 1000 PSI- PASS. FP FLOWLINE WI 15 BBLS 60/40 MEOH. RDMO. WELL LEFT SHUT IN. JOB COMPLETE. 12/03/03 ATTEMPT TO SET CATCHER, FAILED DUE TO PARAFIN. LRS PUMPED 300 BBLS HOT CRUDE DOWN lA, RETURNS UP TUBING. DRIFT TO TT @ 6650' WI 3.70 GAUGE RING & 41/2" BRUSH. SET 4 1/2" XN CATCHER SUB @ 6534' SLMD. RIH TO PULL SPMG. 12/04/03 PULL 1" SPMG FROM ST A. # 1. @ 6508' MD. BK LATCH. (LEFT POCKET OPEN). PULL 1" SIO FROM ST A. #2. @ 6306' MD. 22/64" PORT. BK LATCH. FIRST ENERGY PUMPED 60 BBL. OF METHANOL TO CLEAR UP HYDRATES. PULL 1" DOME FROM STA. # 4. @ 3015' MD. 16/64" PORT. BK LATCH. SET DGLV STA. #4. BK LATCH. SET DGLV STA. #2. BK LATCH. SHIFT OPEN BAKER CMD SLIDING SLEEVE. PULL XN CATCHER SUB (EMPTY). 12/06/03 LOG SLIM CEMENT BOND LOG. TOOL = 44.2 FT X 1.69" MAX OD. SET DOWN AT 7180' MD (HAW) AND LOG UP TO 6100' MD. ON DESCENT TO LOG REPEAT SECTION OF 4.5" TUBING, TOOL GOT STUCK IN GLM AT 6196 FT. PUMPED 45 BBLS CRUDE DOWN lA, THROUGH SLIDING SLEEVE, RETURNS TO FLOWLlNE- PULLED 1850 LBS (1200 LBS OVER) AND TOOL CAME FREE. TUBING PUNCHER (2ND RIH) = 22.4 FT X 1.69" MAX OD. INTERVAL SHOT = 6454-6456 FT MD. WHP BEFORE AND AFTER SHOT = 200 PSI. lAP BEFORE AND AFTER SHOOT = 300 PSI. 12/07/03 A 3 5/8" CHEMCIAL CUTTER WAS RUN TO CUT THE PREMIER PACKER @ 6440'. DEPTHS FOR CUT ZONE GIVEN BY BAKER. TD NOT TAGGED. WELL WAS LEFT SHUT IN. PAD OPERATOR NOTIFIED. T/I/O= 160/300/40 CIRC-OUT TUBING & IA. (PRE-RIG) PUMPED DOWN THE IA TAKING RETURNS TO THE FLOWLINE; 5 BBL NEAT MEOH SPEAR, 367 BBLS SEAWATER, 5 BBLS MEOH, 105 BBLS DIESEL. U-TUBE TO FREEZE PROTECT. BLEED DOWN TUBING & IA. FREEZE PROTECT FLOWLINE WITH 15 BBLS NEAT MEOH. FINAL WHP'S=OIOIO. Legal Name: W-205 Common Name: W-205 ...-.---........-... Test Date 8/26/2003 8/27/2003 8/28/2003 8/26/2003 9/5/2003 12/21/2003 LOT LOT LOT LOT FIT FIT Test Type Test Depth (TMD) (ft) 4,414.0 (ft) (ft) 3,985.0 (ft) 7,618.0 (ft) 6,956.0 (ft) BP Leak-Off Test Summary Test Depth (TVD) n... ................. .. _00_ ..._. (ft) 3,190.0 (ft) (ft) 3,190.0 (ft) 5,184.0 (ft) 5,031.0 (ft) ..._.n._........__....__... AMW (ppg) 9.20 (ppg) (ppg) 9.20 (ppg) 9.20 (ppg) 9.20 (ppg) I ; Surface Pressure I Leak Off Pressure (BHP) , u_.__ ·.~_.w.........._.... .._._...... (psi) (psi) 825 (psi) 2,350 (psi) (psi) (psi) 825 (psi) 2,350 (psi) 684 (psi) 3,162 (psi) 750 (psi) 3,154 (psi) Page 1 of 1 EMW (ppg) 14.18 (ppg) (ppg) 14.18 (ppg) e. 11.74 (ppg) . 12.07 (ppg) . Printed: 12/29/2003 9:47:07 AM . . Page 1 of 13 BP Operations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: W-205 W-205 REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 9ES Date From - To Hours; Task Code NPT; Phase 12/10/2003 03:00 - 05:30 2.50 MOB P PRE 05:30 - 07:00 1.50 MOB P PRE 07:00 - 10:30 3.50 MOB P PRE 10:30 - 14:00 3.50 RIGU P PRE 14:00 - 16:00 2.00 RIGU P PRE 16:00 - 21:30 5.50 RIGU P PRE 21 :30 - 22:30 1.00 WHSUR P DECOMP 22:30 - 23:30 1.00 WHSUR P DECOMP 23:30 - 00:00 0.50 WHSUR P DECOMP 12/11/2003 00:00 - 01 :30 1.50 WHSUR P DECOMP 01 :30 - 02:00 0.50 WHSUR P DECOMP 02:00 - 02:30 0.50 WHSUR P DECOMP 02:30 - 05:00 2.50 WHSUR P DECOMP 05:00 - 07:30 2.50 BOPSURP DECOMP 07:30 - 08:00 0.50 BOPSURP DECOMP 08:00 - 12:00 4.00 BOPSURP DECOMP 12:00 - 12:30 0.50 BOPSUR P DECOMP 12:30 - 13:30 1.00 BOPSURP DECOMP 13:30 - 14:30 1.00 PULL P DECOMP 14:30 - 16:30 2.00 PULL P DECOMP Start: Rig Release: Rig Number: Spud Date: 8/23/2003 End: 12/28/2003 12/1 0/2003 12/28/2003 Description of Operations Release rig from V-202 at 03:00 hrs on 12-10-03. Held PJSM with Rig Crew & Peak. Move camp, mud pits and shop to W Pad. RID Drill Floor. Move rig off V-202 well. Lower Cattle chute. Lay down 9ES derrick & prepare sub-base for rig move. Move rig off V-Pad location onto Spine road. Rig in transit, arrived on W-Pad @ 10:30 hrs with no problems. Lay mat's & herculite. Move rig's sub base & spot over W-205, level rig. Spot pit module & cuttings tank. Spot camp. PJSM. Raise derrick. Hook-up power, water, steam and mud lines. Accept Rig at 16:00 hrs on December 10, 2003. Take on seawater in pits. R/U cellar & rig floor. Load 4" DP in pipe shed. RlU circulating lines from rig floor to Production Tree for reversing out diesel freeze protection from 4.5" tubing & 4.5" x 7-5/8" annulus. RlU DSM Lubricator. Pull BPV from tubing hanger. UD DSM lubricator. Pressure on well reading 0 psi. SAFETY--- Held PJSM with rig crew & service personnel regarding the displacement of the diesel freeze protect & decompletion of well. Purge HP circulating lines from rig to production tree with seawater. Test to 3500 psi. Line up to reverse out. All returns routed through C/K manifold. Pump 50 bbl seawater @ 4.75 bpm w/ 575 psi down 4.5" x 7-5/8" annulus taking diesel returns & contaminated fluid to cuttings tank. Stop pumping & line up to pump down the 4.5" tubing. Pump 117 bbl down tubing @ 4.75 bpm w/ 200 psi. Recover 63 bbl diesel & 50 bbl contaminated fluid. Monitor well. Well static. Blow down all circulating lines & C/K manifold. RID 2" HP hose coming off Flare line to cuttings tank. Secure Flare line outlet with bull plug. Install TWCV in 4.5" tubing hanger. Test from below to 1000 psi. PJSM. N/D CIW 4-1/16" 5m Production Tree & adapter flange. Inspect TCII threads in hanger-OK. N/U 13-5/8" 5m BOP stack & related equipment. M/U cross-over sub on 4" DP test joint. Screw into tubing hanger. RlU to test BOP. Test BOPE to 250 psi Low / 3500 psi High, Annular 250 psi Low / 3500 psi High. Witnessed of test waived by Chuck Scheve, AOGCC. RID BOP test equipment. Blow down TDS & all surface lines. RlU DSM lubricator & pull TWCV. RID same. FMC back out lock down screws on 11" tubing spool. RlU to pull 4.5" Tubing string. M/U TDS into 4.5" Tubing Landing Joint. Pull 11" x 4.5" tubing hanger free with 1 06k, pull hanger above rotary table. Monitor well. No flow, well static. Break circulation & stage up pumps slowly to 5.8 bpm w/ 100 psi. No gas or oil observed coming from well while circulating. Circulated a total of 253 bbl. Flow check. Well static. Pump slug. Printed: 12/29/2003 9:47:18 AM ,., .. Page 2 of 13 BP Operations Summary Report DECOMP POOH. UD 11" x 4.5" tubing hanger, 152 Joints of 4.5" 12.6# L-80 IBT-M tubing & related completion jewelry. 100% recovery of all items. DECOMP RID tubing handling equipment. Clean up rig floor. DECOMP Clear & clean Rig Floor. DECOMP RlU & test Lower pipe rams (2-7/8" x 5" VBR) TO 250/3500 PSI. Witness of test waived by Chuck Scheve-AOGCC. RID test equipment. Run & install wear bushing. DECOMP Place BOT mills on rig floor. Load Pipe Shed with MWD & other BHA componets. DECOMP Slip & cut 40' of drill line. Re-set & test C-O-M. Service TDS. DECOMP P/U 9 joints of 4" DP & rack in derrick. DECOMP SAFETY--- Held PJSM with Rig Crew, Baker & Schlumberger Service personnel on picking up clean out BHA. DECOMP M/U 6-3/4" Mill assembly. Shallow test MWD. Take on 9.2# MOBM while M/U BHA. DECOMP TIH with 6-3/4" Mill assembly picking up 4" DP from pipe shed. Tag-up @ 7523'. P/U 140k S/O 101k DECOMP Pump HV sweep & circulate hole clean with seawater from 7523' w/ 270 gpm @ 900 psi. Reciprocate drill string while circulating. DECOMP Pump spacer. Displace hole with 9.2 ppg MOBM @ 275 gpm w/ 1640 psi FCP. Reciprocate drill string once MOBM reached bit. DECOMP POOH to 6695'. DECOMP M/U TDS. Break circulation. Circulate & logging down with MWD-GR from 6750' to 7500' to comfirm RA Tag positions for calculating space-out requirements for whipstock. ( Circ rate 270 gpm w/ 1600 psi). Flow Check-OK. Pump slug. POOH for Whipstock. P/U = 135k S/O = 95k Rot = 113k Torque = 5400 FtLb Finish POOH with 4" DP to BHA. POOH with 4" HWDP & 4-3/4" DC. UD 6.75" Mills & MWD tool. Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: W-205 W-205 REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 9ES Date From - To ! Hours I i Task! Code NPT Phase 12/11/2003 16:30 - 23:30 7.00 PULL P 23:30 - 00:00 0.50 PULL P 12/12/2003 00:00 - 01 :00 1.00 PULL P 01 :00 - 02:00 1.00 BOPSURP 02:00 - 02:30 0.50 CLEAN P 02:30 - 04:00 1.50 CLEAN P 04:00 - 04: 15 0.25 CLEAN P 04:15 - 04:30 0.25 CLEAN P 04:30 - 06:30 2.00 CLEAN P 06:30 - 13:00 6.50 CLEAN P 13:00 - 14:00 1.00 CLEAN P 14:00 - 15:30 1.50 CLEAN P 15:30 - 16:30 1.00 CLEAN P 16:30 - 21 :00 4.50 EVAL P 21 :00 - 00:00 3.00 CLEAN P DECOMP 12/13/2003 00:00 - 00:30 0.50 CLEAN P DECOMP 00:30 - 02:00 1.50 CLEAN P DECOMP 02:00 - 03:00 1.00 CLEAN P DECOMP 03:00 - 03:15 0.25 STWHIP P WEXIT 03: 15 - 05:30 2.25 STWHIP P WEXIT 05:30 - 10:00 4.50 STWHIP P WEXIT 10:00 - 11 :00 1.00 STWHIP P WEXIT 11 :00 - 14:30 3.50 STWHIP P WEXIT Start: Rig Release: Rig Number: 12/10/2003 12/28/2003 Spud Date: 8/23/2003 End: 12/28/2003 Description of Operations ..n ___..._ ...._____ P/U 4.5" Memory Pressure gauge. Break connections on pup jt & UD same. SAFETY--- Held PJSM with Rig Crew & Service company personnel regarding whipstock handling & running procedures. M/U Baker 7-5/8" Whipstock assembly #1. Orient MWD with whipstock. TIH with 7-5/8" Whipstock assembly on 4" DP t07460'. P/U = 140k S/O = 95k M/U TDS. Estabish circulation. Orient whipstock 15 deg LHS. Stab dummy seal assembly into tie-back sleeve @ 7523'. Set down 20 k to set whipstock anchor. PU 5k over to verify anchor set. Set down 40k to shear whipstock lug. Test 7-5/8" casing to 1000 psi for 10 minutes-OK. Mill Window in 7-5/8" casing from 7173' to 7185' and drill 12' of new hole to 7197'. RPM = 120 Torque = 5-7k FtLb GPM = 270 @ 1840 psi Printed: 12/29/2003 9:47:18 AM . . Page 3 of 13 BP Operations Summary Report Rotate Wt = 113k Pump hi-vis sweep. Circulate hole clean with 350 gpm @ 2175 psi. Work Mills through Window with pumps, then withouts pumps. Window clean & clear. Perform FIT. Pressure up on formation to 760 psi with 9.2 ppg MOBM @ 5116' TVD = 12.0 ppg EMW. Pumped 1.2 bbl mud. Bleed-back volume = 1 bbl. Flow check. Well static. Pump slug POOH with 4" DP to top of BHA. Continue POOH with BHA. UD MWD & Milling assembly. Clean rig floor. M/U ported sub. Flush out BOP's. UD sub. SAFETY--- Held PJSM with Anadrill and all rig personnel regarding picking up BHA & loading RA source. M/U 6-3/4" Steerable Drilling assembly. Test MWD-OK. TIH with 6-3/4" BHA picking up 4" DP from pipe shed. Continue TIH with 6.750" Steerable Drilling assembly picking up 4" DP (108 Jts) to 4095'. Finish TIH with 4" DP from derrick to 7150'. M/U TDS. Establish circulation. Circulate bottoms-up w/250 gpm @ 2525 psi. P/U = 130k S/O = 98k. Take SPR's & take ECD benchmark reading. Had 10.56 ppg ECD @ 250 GPM + 60 RPM. PROD1 Stop pumps. Slack-off to 7188'. Stage pumps to 250 gpm. Wash down through undergauge hole F/7188'-7197'. PROD1 Drill 6-3/4" directional hole from 7197' to 8568'. Slide as required to maintain inclination & azimuth. Take survey every 30'. WOB = 5-15k RPM = 60 Torque off Btm = 6.7k FtLb, Torque on Btm = 9k FtLb GPM = 275 @ 3100 psi on Btm w/ 100-300 psi Diff Pressure. P/U 135k S/O 81k ROT 108k Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: W-205 W-205 REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 9ES Date From - To Hours Task Code NPT! Phase 12/13/2003 11 :00 - 14:30 3.50 STWHIP P WEXIT 14:30 - 16:00 1.50 STWHIP P WEXIT 16:00 - 16:30 0.50 STWHIP P WEXIT 16:30 - 19:00 2.50 STWHIP P WEXIT 19:00 - 20:30 1.50 STWHIP P WEXIT 20:30 - 21 :00 0.50 STWHIP P WEXIT 21 :00 - 21 :30 0.50 STWHIP P WEXIT 21 :30 - 21:45 0.25 DRILL P PROD1 21 :45 - 23:30 1.75 DRILL P PROD1 23:30 - 00:00 0.50 DRILL P PROD1 12/14/2003 00:00 - 02:30 2.50 DRILL P PROD1 02:30 - 04:00 1.50 DRILL P PROD1 04:00 - 05:00 1.00 DRILL P PROD1 05:00 - 05:30 0.50 DRILL P 05:30 - 00:00 18.50 DRILL P Start: Rig Release: Rig Number: 12/10/2003 12/28/2003 Spud Date: 8/23/2003 End: 12/28/2003 Description of Operations _._._._._--_.__._----~. Backream every stand at 275 gpm and 60 rpm, reducing flow rate to 225 gpm on down stroke. Calculated ECD @ 8568' = 10.5, Actual ECD = 11.3 NOTE: The AIM tool failed at 7822'. Landed wellbore into Obc sand @ 7310' MD/5131' KBTVD. At 8052' came out the bottom of Obc Lower sand. Build to 94 deg. Regain Obc contact @ 8190', Then drilled out the top of zone @ 8290'. Rotate & slide as required. Regained Obc contact @ 8400'. ART = 3.17 Hrs AST = 6.03 Hrs Survey/Connection = 9.30 Hrs Drilling Time last 24 Hrs= 9.20 hrs 12/15/2003 00:00 - 11 :00 11.00 DRILL P PROD1 Drill 6-3/4" directional hole from 8568' to 9284'. Slide as required to maintain inclination & azimuth. Take survey every 30'. Printed: 12/29/2003 9:47:18 AM ~ . BP Operations Summary Report Page 4 of 13 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: W-205 W-205 REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 9ES Start: Rig Release: Rig Number: 12/10/2003 12/28/2003 Spud Date: 8/23/2003 End: 12/28/2003 Date From - To i Hours Task Code NPT Phase Description of Operations n______._..._.. __u_. ......---. ..--.....------ 12/15/2003 00:00 - 11 :00 11.00 DRILL P PROD1 WOB = 15-20k RPM = 60 Torque off Btm = 6k FtLb, Torque on Btm = 10k FtLb GPM = 275 @ 3100 psi on Btm w/ 100-300 psi Diff Pressure. P/U 158k S/O 62k ROT 109k Backream every stand at 275 gpm and 60 rpm, reducing flow rate to 225 gpm on down stroke. Calculated ECD @ 9284' = 10.62, Actual ECD = 11.11 ART = 3.9 Hrs AST = 2.35 Hrs Survey/Connection = 4.75 Hrs Drilling Time last 24 Hrs= 6.25 hrs 11 :00 - 13:30 2.50 DRILL N DFAL PROD1 Note: Due to a unaccceptable amount of pay zone drilled in the L 1 lateral a decision was made by BP Drilling department to perform a Open Hole sidetrack at +/-8200' MD. Pump HV Sweep & circulate hole clean (3.8 x Btm-up vol) from 9284' with 300 gpm @ 3170 psi. Reciprocate & rotate drill string (80 RPM) while circulating. ECD after circulating: Calculated ECD = 10.62 Actual ECD = 10.68. P/U 142k S/O 85k 13:30 - 19:00 5.50 DRILL N DFAL PROD1 POOH. Encountered intermittent tight hole from 8755' to 8000'. Passed through window @ 7173' with no problems. Continue POOH to top of BHA. 19:00-19:15 0.25 DRILL N DFAL PROD1 SAFETY--- Held PJSM with Rig Crew & SWS personnel regarding LID BHA & unloading RA sourse. 19:15 - 20:30 1.25 DRILL N DFAL PROD1 POOH. Stand back Jars. Unload RA sourse. LID BHA #3. 20:30 - 21 :00 0.50 DRILL N DFAL PROD1 Clean Rig Floor of excess MOBM generated from trip. 21 :00 - 22:30 1.50 DRILL N DFAL PROD1 M/U New 6-3/4" Security FM3643 PDC Bit & BHA #4 (Note: BHA #4 consist of all fresh tools ). AIM-MWD-VPWD-ADN. Orient MWD. PJSM. Load RA source. 22:30 - 23:00 0.50 DRILL N DFAL PROD1 TIH to 1100'. Shallow test MWD. MWD Tool transmitting incorrect survey data. Trouble shoot problem. Unable to rectify problem. 23:00 - 00:00 1.00 DRILL N DFAL PROD1 POOH from 1100' to change out MWD tool. 12/16/2003 00:00 - 01 :00 1.00 DRILL N DFAL PROD1 MWD Tool failure--- POOH to BHA. PJSM. Download RA sourse. Change out MWD tools. 01 :00 - 02:30 1.50 DRILL N DFAL PROD1 M/U BHA #5. Orient MWD to Mud-motor. Load RA sourse. TIH to 735'. Shallow test MWD-OK. 02:30 - 04:30 2.00 DRILL N DFAL PROD1 Continue TIH with 6-3/4" Steerable Drilling asembly on 4" DP to 6800'. 04:30 - 06:30 2.00 DRILL N DFAL PROD1 Slip & cut 30' of drill line. Reset & check C-O-M. Checks Brakes. Service TDS. 06:30 - 07:30 1.00 DRILL N DFAL PROD1 TIH to 7100'. Establish circulation. CBU. Orient Bit to 14 deg LHS. 07:30 - 08:30 1.00 DRILL N DFAL PROD1 Stop pumps. Slack off & pass through window with no problems. TIH to 8100'. 08:30 - 12:00 3.50 DRILL N DFAL PROD1 Break circulation. Stage pumps to 275 gpm w/ 2700 psi. Orient TF to low side for Open Hole Sidetrack. Wash down to 8180'. Start trenching from 8180'-8200'. 12:00 - 00:00 12.00 DRILL N DPRB PROD1 Drill 6-3/4" directional hole (L 1-ST #01) from 8200' to 9098'. Slide as required to maintain inclination, azimuth & pay zone Printed: 12/29/2003 9:47: 18 AM . . BP Operations Summary Report Page 5 of 13 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: W-205 W-205 REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 9ES Start: Rig Release: Rig Number: I I I Task ! Code NPT: Phase 12/10/2003 12/28/2003 Spud Date: 8/23/2003 End: 12/28/2003 Date From - To Hours Description of Operations .. - ...,-.--.---- 12/16/2003 12:00 - 00:00 12.00 DRILL N DPRB PROD1 contact. Take survey every 30'. WOB = 15-20k RPM = 60 Torque off Btm = 6.9k FtLb, Torque on Btm = 9.3k FtLb GPM = 275 @ 3150 psi on Btm w/ 100-300 psi Diff Pressure. P/U 148k S/O 77k ROT 105k Backream every stand at 275 gpm and 60 rpm, reducing flow rate to 225 gpm on down stroke. Calculated ECD @ 9098' = 10.50, Actual ECD = 11.05 ART = 3.25 Hrs AST = 5.05 Hrs Survey/Connection = 4.7 Hrs Drilling Time last 24 Hrs= 8.30 hrs 12/17/2003 00:00 - 02:30 2.50 DRILL N DPRB PROD1 Drill 6-3/4" directional hole (L 1-ST #01) from 9098' to 9284'. Slide as required to maintain inclination, azimuth & pay zone contact. Take survey every 30'. 02:30 - 18:00 15.50 DRILL P PROD1 Drill 6-3/4" directional hole (L 1-ST #01) from 9284' to 10680' TO. Slide as required to maintain inclination, azimuth & pay zone contact. Take survey every 30'. WOB = 15-20k RPM = 60 Torque off Btm = 10k FtLb, Torque on Btm = 12k FtLb GPM = 275 @ 3150 psi on Btm w/ 100-300 psi Diff Pressure. P/U 148k S/O 78k ROT 105k Backream every stand at 275 gpm and 40-60 rpm, reducing flow rate to 225 gpm on down stroke. Calculated ECD @ 10530' = 10.64 , Max ECD = 11.40 ART = 4.34 Hrs AST = 3.36 Hrs Survey/Connection = 10.30 Hrs Drilling Time last 24 Hrs= 7.70 hrs 18:00-21:30 3.50 DRILL P PROD1 Circulate & condition mud/hole (4 x Btm-up vol) from 10680' with 295 gpm @ 3335 psi. Reciprocate & rotate drill string (80 RPM) while circulating. Calculated ECD @ 10680 ' = 10.86 , Actual ECD = 11.25 prior to tri p P/U 165k-No pump, S/O 82k-No pump 21 :30 - 00:00 2.50 DRILL P PROD1 POOH for wiper trip to 8451' (Midnight depth). Hole slick from bottom up to 10385', encountered drag increase with intermittent tight hole to from 10385' to 8451'. Tight spots. seem to correspond to slid intervals. 12/18/2003 00:00 - 01 :00 1.00 DRILL P PROD1 Continue POOH for wiper trip from 8451' to 7185'. Had normal drag F/8451 '-8200'. 01 :00 - 03:30 2.50 DRILL P PROD1 Fill drill string. TIH to 8158'. Orient TF to LS. Continue TIH entering L 1 ST #01 @ 8200'. Finish TIH to 10623' with no problems. 03:30 - 07:30 4.00 DRILL P PROD1 Establish circulation. Precautionary wash to bottom @ 10680' with no problems. Circulate bottoms-up with 250 gpm @ 2730 Printed: 12/29/2003 9:47:18 AM ...... . Page 6 of 13 BP Operations Summary Report Start: Rig Release: Rig Number: Phase Legal Well Name: W-205 Common Well Name: W-205 Event Name: REENTER+COMPLETE Contractor Name: NABORS ALASKA DRILLING I Rig Name: NABORS 9ES I Date I From - To Hours Task Code NPT ..______ _....._...._... ...._ .._ J .. .....uno 12/18/2003 03:30 - 07:30 .___. _n __ __._____..n____ ..... -- -"-.. -- -.. ---..- 4.00 DRILL P PROD1 07:30 - 11 :00 3_50 DRILL P PROD1 11 :00 - 12:00 1.00 DRILL N RREP PROD1 12:00 - 13:30 1.50 DRILL P PROD1 13:30 - 16:30 3.00 DRILL P PROD1 16:30 - 16:45 0.25 DRILL P PROD1 16:45 - 18:00 1.25 DRILL P PROD1 18:00 - 18:30 0.50 DRILL P PROD1 18:30 - 19:00 0.50 STWHIP P PROD1 19:00 - 20:00 1.00 STWHIP P PROD1 20:00 - 22:30 2.50 STWHIP P PROD1 22:30 - 23:00 0.50 STWHIP P PROD1 23:00 - 00:00 1.00 STWHIP P PROD1 12/19/2003 00:00 - 03:30 03:30 - 06:30 3.50 STWHIP P 3.00 STWHIP P PROD1 PROD1 06:30 - 07:00 0.50 BOPSURP PROD1 07:00 - 11 :30 4.50 BOPSUR P PROD1 11 :30 - 12:30 12:30 - 12:45 1.00 CASE 0.25 CASE P P LNR1 LNR1 12:45 - 16:30 3.75 CASE P LNR1 16:30 - 17:00 0.50 CASE P LNR1 12/10/2003 12/28/2003 Spud Date: 8/23/2003 End: 12/28/2003 Description of Operations ...---.-----..--....... psi + 80 RPM (Had a large volume of drill cuttings come over shakers on Btm-up). Pump HV sweep. Circulate & condition mud/hole (4 x Btm-up) with 300 gpm @ 3310 psi. Reciprocate & rotate drill string (80 RPM w/ 9.4-1 OK Torq) while circulating. P/U 150k S/O 76k with pumps Calculated ECD @ 10680 ' = 10.80 . Actual ECD = 11.07 Flow check. Well static. Pump slug. POOH to 7160' with no problems. Held PJSM. Change out air boot sealing element on bell-nipple. Break circulation. Stage pumps to 275 gpm. Orient TF to 14 deg LHS. Stop pumping. Slide bit down past window & place circulation sub at 7185'. Drop ball-rod. Break circulation. Open circ sub with 2300 psi. Stage pumps to 550 gpm with 3470 psi. Wash whipstock face 10 minutes. Pull circ sub above whipstock. Pump HV sweep. Circulate hole clean from 7160' with 550 gpm @ 3470 psi. Flow check. Well static. Pump slug. POOH to BHA. SAFETY--- Held PJSM with rig crew & SWS personnel on removing RA sourse & UD BHA. Remove RA sourse from ADN tool. UD BHA. Clean rig floor & removing excess directional equipment. SAFETY--- Held PJSM with rig crew, SWS & Baker personnel regarding M/U Whipstock retrieving tool (WSRT) & BHA. M/U L 1 WSRT & BHA. Shallow test MWD-OK. TIH with WSRT & BHA on 4" DP to 7100'. Break circulation. Stage pumps to 255 gpm w/1470 psi. Orient WSRT to 14 deg LHS. P/U Wt 150k S/O Wt 95k. Slack off on drill string to 7177'. P/U & engage Whipstock. Pull & release whipstock with 200k string weight. P/U another 40k to pull seals out of bottom tie-back receptacle. Pull whipstock up to 7149'. Monitor well-static. Circulate bottoms up from 7149'. Flow check. Well static. Pump slug. POOH with 4" DP to BHA. Stand back 4" HWDP & 4-3/4" DC. UD MWD, Whipstock retrieving tool, L 1 Whipstock & 3.5" DP space-out assembly. 100% recovery of all Whipstock & downhole tools. Clear & clean rig floor. M/U Ported sub on 4" DP. RIH & flush BOP stack. Pull wear bushing RlU to test BOP's with 4" DP. Set test plug. Test BOP's & all surface related equipment to 250/3500 psi. RID test equipment. All test were API. Witness of test waived by Lou Grimaldi-AOGCC. RlU to run 4.5" Slotted liner. SAFETY--- Held PJSM with rig crew & BOT personnel regarding running liner & P/U Hook Hanger assembly. M/U 4-1/2" Float Shoe (Bent) Jt + 82 Jts of 4-1/2" 12.6#, L-80, IBT-M slotted liner & BOT Flanged Hook Hanger assembly. Total length = 3471.72' P/U Wt = 75k S/O Wt = 68k RID 4.5" Liner running equipment. Install DP elevators on TDS. Printed: 12/29/2003 9:47:18 AM ..,. a Page 7 of 13 BP Operations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: W-205 W-205 REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 9ES Date From'" To Hours Task ¡Code NPT Phase I , .___"....____u__ 12/19/2003 17:00 - 19:00 2.00 CASE P LNR1 19:00 -19:30 0.50 CASE P LNR1 19:30 - 20:00 0.50 CASE P LNR1 20:00 - 20:45 0.75 CASE P LNR1 20:45 - 21 :30 0.75 CASE P LNR1 21 :30 - 22:00 0.50 CASE P LNR1 22:00 - 00:00 2.00 CASE P LNR1 12/20/2003 00:00 - 01 :00 1.00 CASE P LNR1 01 :00 - 02:00 1.00 CASE P LNR1 02:00 - 03:00 1.00 CASE P LNR1 03:00 - 04:00 1.00 CASE P LNR1 04:00 - 04:30 0.50 CASE P LNR1 04:30 - 09:30 5.00 CASE N LNR1 09:30 - 12:00 2.50 CASE P LNR1 12:00 -12:15 0.25 CASE P TIEB1 12:15 - 13:30 1.25 CASE P TIEB1 13:30 - 19:30 6.00 CASE P TIEB1 Start: Rig Release: Rig Number: 12/10/2003 12/28/2003 Spud Date: 8/23/2003 End: 12/28/2003 Description of Operations -.-----..-..¥......----.---.-........- TIH with 4-1/2" 12.6# Slotted liner assembly on 4" DP to 7120'. P/U Wt = 124k S/O Wt = 85k M/U TDS. Establish circulation. Circulate one drill pipe volume w/ 166 gpm @ 575 psi. Slack off on drill string with EOT @ 7170'. Rotate string @ 5 rpm. RIH slowly to 7173', observed torque increase. Stop rotating. Continue TIH. Tag up on lower Tie-back sleeve @ 7530'. POOH to 7120' (Attempt #1). Apply 1/4 turn RHT in string. TIH. Tag up @ 7530'. POOH to 7120' (Attempt #2). Apply 1/4 turn RHT in string. TIH. Tag up @ 7530'. POOH to 7120' (Attempt #3). Apply 1/4 turn RHT in string. TIH. Tag up @ 7530'. POOH to 7120' (Attempt #4). Apply 1/4 turn RHT in string. TIH with the 4-1/2" liner sucessfully entering the L 1 lateral @ 7185'. Continue TIH to 8050'. Apply 1/2 turn RHT in string. TIH. Enter L 1 ST #01 lateral @ 8200'. Continue TIH with 4-1/2" Slotted liner on 4" DP to 9350' (Midnight depth). Continue TIH with 4-1/2" Slotted liner on 4" DP in the L 1 ST #01 lateral from 9350' to 10565'. P/U Wt = 165k S/O Wt = 80k M/U TDS into 4" DP. Slack off slowly to put shoe at 10640'. Set down 20k on Hook Hanger. Verify Hook Hanger properly engaged in the window - OK. Drop 29/32" ball & pump on seat. Pressure up to 3000 psi to release HR-running tool. Continue pressuring up to 4500 psi & shear ball seat. P/U Drill string & verify HR-running tool released. Lost 25k string wt. Continue picking up on string & place HR-running tool @ 7120' (48' above Hook Hanger @ 7168'). Circulate bottoms up from 7120' w/ 210 gpm @ 670 psi. Flow check. Well static. Pump slug. Blow down TDS. POOH with 4" DP to 4730'. Note: A glob of hydraulic slush rained out of the derrick & hit a crew member in the back of the neck. The crew member was not injured and declined visiting the PA for examination. SAFETY--- Shut down tripping operations. Perform inspections on TDS service loops & derrick. No damaged equipment observed but the TDS Hydraulic service loop had a developed a twist which could cause it to hang up in the derrick. Change out TDS hydraulic service loop. Finish POOH. UD Baker's Hook Hanger HR-Running tool. Clear rig floor of excess equipment. SAFETY--- Held PJSM with Rig Crew & BOT service personnel on picking up & running the ZXP-LEM assembly. M/U and run mule shoe Jt + 7 Jts of 4-1/2",12.6#, L·80 tubing (Tail pipe to tie back into OBd Liner top packer @ 7524'). M/U LEM and ZXP Packer assembly. Total length = 400.14'. RID Tubing handling equipment. P/U 46k S/O 45k TIH with 4.5" tail-pipe + LEM-ZXP packer assembly on 4" DP to 7485'. Passed through Hook Hanger @ 7168' with no Printed: 12/29/2003 9:47:18 AM . . Page 8 of 13 BP Operations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date W-205 W-205 REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 9ES From - To I Hours I Task Code NPT Start: Rig Release: Rig Number: Phase __. __..______u__..___.____ 12/20/2003 13:30 - 19:30 6.00 CASE P TIEB1 19:30 - 20:30 1.00 CASE P TIEB1 20:30 - 22:00 1.50 CASE P TIEB1 22:00 - 00:00 2.00 CASE P TIEB1 12/21/2003 00:00 - 01 :30 1.50 CASE P TIEB1 01 :30 - 02:30 1.00 CASE P TIEB1 02:30 - 02:45 0.25 STWHIP P WEXIT 02:45 - 05:30 2.75 STWHIP P WEXIT 05:30 - 08:00 2.50 STWHIP P WEXIT 08:00 - 08:30 0.50 STWHIP P WEXIT 08:30 - 09:30 1.00 STWHIP P WEXIT 09:30 - 13:00 3.50 STWHIP P WEXIT 13:00 - 14:00 1.00 STWHIP P WEXIT 14:00 - 14:30 0.50 STWHIP P WEXIT 12/10/2003 12/28/2003 Spud Date: 8/23/2003 End: 12/28/2003 Description of Operations .....---.-- problems. P/U Wt = 143k S/O Wt = 98k Slack off on work string with the 4.5" mule shoe entering the lower tie back sleeve at 7524' with no problems. Continue slacking off on string to set the LEM into the hook hanger collet @ 7168' with the 4.5" mule shoe at 7535'. Land LEM with 30k. P/U 10k to verify set, then slack off 20k & park pipe. Drop the 29/32" setting ball and pump onto seat. Pressure up to 3300 psi to set ZXP packer. Continue pressuring up to blow ball seat, ball seat sheared at 4750 psi. P/U 10', verify packer set. Slack back down on packer with 50k. P/U with 15k on packer. Rotate at 15 rpm for one minute with rotating dogs engaging ZXP Tie back sleeve. Note: Top of L 1 ZXP Tie-back sleeve @ 7135' P/U 140k S/O 94k P/U 20'. Circulate bottoms up with 300 gpm @ 1600 psi. Flow check. Well static. Pump slug. Blow down TDS & surface equipment. POOH with 4" DP to 4000' (Midnight depth). Slip & cut 20' of drill line. Reset & test C-O-M. Service TDS & rig. Finish POOH. UD ZXP packer running tool. Clean rig floor. SAFETY--- Held PJSM with rig crew & BOT Service Rep on picking up & running Whipstock. M/U Baker 7-5/8" (L2) Whipstock assembly. Orient MWD with whipstock. Finish M/U BHA. Shallow test MWD-OK. TIH with 7-5/8" (L2) Whipstock assembly on 4" DP to 6837'-whipstock depth. P/U Wt = 145k S/O Wt = 90k M/U TDS. Estabish circulation. Orient whipstock 13 deg LHS. Stab dummy seal assembly into (L 1) tie-back sleeve @ 7135'. Set down 20 k to set whipstock anchor. PU 5k over to verify anchor set. Set down 40k to shear whipstock lug. Top of whipstock @ 6930'. Circulate bottoms-up from 6930' w/ 250 gpm @ 1365 psi. Test 7-5/8" casing to 1 000 psi for 1 0 minutes-OK. Mill Window in 7-5/8" casing from 6930' to 6942' and drill 14' of new hole in the L2 lateral to 6956'. WOB = 4-7k RPM = 110 Torque = 5-7k FtLb GPM = 275 @ 1700 psi Rotate Wt = 113k Pump a 50 bbl Hi-vis sweep. Circulate hole clean F/ 6956' with 275 gpm @ 1700 psi (Circ 2 x Btm-up). Work Mills through Window with pumps, then with outs pumps. Window clean & clear. Perform FIT. Pressure up on formation to 750 psi with 9.2 ppg MOBM @ 5031' TVD = 12.07 ppg EMW. Pumped 0.9 bbl mud. Flow check. Well static. Take SPR's. Pump slug. Printed: 12/29/2003 9:47: 18 AM . . BP Operations Summary Report Page 9 of 13 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date 12/21/2003 12/22/2003 W-205 W-205 REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 9ES Spud Date: 8/23/2003 End: 12/28/2003 Start: Rig Release: Rig Number: 12/10/2003 12/28/2003 I From - To ¡ Hours Task Code NPT Phase 14:30 - 18:00 3.50 STWHIP P WEXIT 18:00 - 19:30 1.50 STWHIP P WEXIT 19:30 - 20:00 0.50 STWHIP P WEXIT 20:00 - 20: 15 0.25 DRILL P WEXIT 20:15-21:30 1.25 DRILL P WEXIT 21 :30 - 00:00 2.50 DRILL P WEXIT 00:00 - 01 :00 1.00 DRILL P WEXIT 01 :00 - 02:00 1.00 DRILL P WEXIT Description of Operations ---...--------.." 02:00 - 02:30 POOH with 4" DP to top of BHA. Continue POOH with BHA. UD MWD & Milling assembly. Clean & clear Rig Floor. M/U ported sub. Flush out BOP's. UD sub. SAFETY-- Held PJSM with Anadrill and all rig personnel regarding picking up BHA & loading RA source. M/U 6-3/4" Steerable Drilling assembly. Test MWD-OK. TIH with 6-3/4" Steerable Drilling assembly on 4" DP to 4300'. Finish TIH with 6-3/4" Steerable Drilling asembly on 4" DP F/ 4300' to 6890'. M/U TDS. Establish circulation. Circulate bottoms-up w/190-250 gpm @ 1300-1975 psi. P/U = 133k S/O = 95k. Take SPR's & take ECD benchmark reading. Had 10.36 ppg ECD @ 250 GPM + 60 RPM. WEXIT Stop pumps. Slack-off passing through 7-5/8" window (6930'-6942') with no problems. Tag up @ 6950'. Stage pumps to 250 gpm. Wash & ream down through undergauge hole F/ 6950' to 6956'. PROD2 Drill 6-3/4" directional hole in the L2 lateral from 6956' to 8786'. Slide as required to maintain inclination & azimuth. Take survey every 30'. WOB = 10-20k RPM = 60 Torque off Btm = 6k FtLb, Torque on Btm = 10k FtLb GPM = 275 @ 2800 psi on Btm w/ 100-120 psi Diff Pressure. P/U 146k S/O 82k ROT 109k 0.50 DRILL P 02:30 - 00:00 21.50 DRILL P Backream every stand at 250 gpm and 60 rpm, reducing flow rate to 225 gpm on down stroke. Calculated ECD @ 8786' = 10.50 ppg, Actual ECD = 10.85 ppg Landed wellbore into Oba sand @ 6967' MD/5044' KBTVD. ART = 2.46 Hrs AST = 8.09 Hrs Survey/Connection = 10.95 Hrs Drilling Time last 24 Hrs= 10.55 hrs 12/23/2003 00:00 - 20:30 20.50 DRILL P PROD2 Drill 6-3/4" directional hole in the L2 lateral from 8786' to TO at 10670'. Slide as required to maintain inclination & azimuth. Take survey every 30'. WOB = 10-15k RPM = 60 Torque off Btm = 9.5k FtLb, Torque on Btm = 10-11k FtLb GPM = 275 @ 3000 psi on Btm w/ 100-120 psi Diff Pressure. P/U 146k S/O 78k ROT 109k Backream every stand at 250 gpm and 60 rpm, reducing flow rate to 225 gpm on down stroke. Calculated ECD @ 10670' = 10.53 ppg, Actual ECD = 10.97 ppg Printed: 12/29/2003 9:47:18AM . . Page 10 of 13 BP Operations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date W-205 W-205 REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 9ES From -_~oJ_~~~r~~_~~~__u?Ode i NPT ! 00:00 - 20:30 20.50 DRILL P Start: Rig Release: Rig Number: Phase 12/23/2003 PROD2 12/10/2003 12/28/2003 Spud Date: 8/23/2003 End: 12/28/2003 Description of Operations __n___"__._.__·· ART = 7.01 Hrs. AST = 3.34 Hrs. Drilling Time last 24 Hrs= 10.35 hrs PROD2 Circulate & condition mud/hole (2.5 x Btm-up vol) from 10670' with 300 gpm @ 3200 psi. Reciprocate & rotate drill string (80 RPM) while circulating. 20:30 - 22:30 2.00 DRILL P 22:30 - 00:00 1.50 DRILL P Calculated ECD @ 10670' = 10.68, Actual ECD = 10.90 prior to trip PROD2 Monitor well - static. POH for wiper trip to window. Pull 5 stands, slug DP and continue POH. Pulled 5-10k over string weight off bottom. 12/24/2003 00:00 - 01 :00 1.00 DRILL P P/U 160k S/O 88k No Pumps PROD2 Continue short trip. intermittent drag of 5-15k throughout trip. Pulled 25k over at 7965', 7923', 7645', wipe through without any problems. P/U 163k S/O 84k PROD2 Monitorwell- static. Pump out from 7075' to 6982'.275 gpm @ 2388 psi. PROD2 RIH to 10580'. No problems on trip in. PROD2 Wash last stand to TO at 10670'. Circulate & condition mud/hole (2 x Btm-up vol) from 10670' with 275 gpm @ 2940 psi. Reciprocate & rotate drill string (80 RPM) while circulating. Calculated ECD @ 10670' = 10.68, Actual ECD = 10.90 prior to POH PROD2 Monitor well - static. POH to 7167'. Orient to 13 degrees left. Continue POH to 6889, bringing BHA and bit inside casing. RIH placing circ sub at the base of the whipstock. PROD2 Drop ball and rod and pump onto seat, circ sub sheared at 2100 psi. Circulate across whipstock face to clean retrieval slot. 500 gpm at 3000 psi. Stand back 3 stands bringing bit inside of casing at 6889'. Pump hi-vis sweep, 500 gpm at 3000 psi while reciprocating DP at 60 rpm. Continue POH 01 :00 - 01 :30 0.50 DRILL P 01 :30 - 02:30 02:30 - 04:30 1.00 DRILL P 2.00 DRILL P 04:30 - 07:00 2.50 DRILL P 07:00 - 08:00 1.00 DRILL P 08:00 - 11 :30 3.50 DRILL P PROD2 11:30-12:00 0.50 DRILL P PROD2 12:00 - 13:00 1.00 DRILL P PROD2 13:00 - 13:30 0.50 DRILL P PROD2 13:30 - 14:00 0.50 STWHIP P PROD2 14:00 - 15:00 1.00 STWHIP P PROD2 15:00 - 17:00 2.00 STWHIP P PROD2 17:00 - 17:30 0.50 STWHIP P PROD2 P/U 145k S/O 93k PJSM with Anadril and all rig personnel on unloading RA source and laying down BHA. LD BHA #7 Clean and clear rig floor PJSM with Baker, Anadril and all rig personnel on making up whipstock retrieval BHA. MU whipstock retrieving tool and BHA, orient. RIH with collars and HOP from derrick. Shallow test MWD. RIH with DP to 6900' Fill DP. Orient retrieving tool 13 degrees left. 135 klbs up, 95 klbs down. Slack off while circulatingto top of whipstock at 6930', continue down putting retrieval tool below whipstock face. PU and engage retrieval slot, jar 4 times to release Printed: 12/29/2003 9:47: 18 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: . . Page 11 of 13 BP Operati'ons Summary Report W-205 W-205 REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 9ES From - To ! Hours I Task Code NPT Phase , . Start: Rig Release: Rig Number: 12/10/2003 12/28/2003 Spud Date: 8/23/2003 End: 12/28/2003 Date ... ..---.---..------.,.--. -.... 12/24/2003 17:00 - 17:30 17:30 - 18:30 18:30 - 22:00 22:00 - 00:00 12/25/2003 00:00 - 00:30 00:30 - 01 :00 01 :00 - 01 :30 01 :30 - 05:00 05:00 - 05:30 05:30 - 08:00 08:00 - 08: 15 08:15 - 08:30 08:30 - 08:45 08:45 - 09:00 09:00 - 13:15 13:15 -13:45 13:45 - 14:15 14:15 -15:00 15:00 - 16:00 16:00 -19:30 19:30 - 20:30 20:30 - 21 :00 21 :00 - 22:00 22:00 - 00:00 12/26/2003 00:00 - 02:00 02:00 - 02:15 0.50 STWHIP P PROD2 1.00 STWHIP P 3.50 STWHIP P PROD2 PROD2 2.00 STWHIP P 0.50 STWHIP P 0.50 CASE P 0.50 CASE P PROD2 PROD2 LNR2 LNR2 3.50 CASE P LNR2 0.50 CASE P 2.50 CASE P LNR2 LNR2 0.25 CASE P 0.25 CASE P LNR2 LNR2 0.25 CASE P LNR2 0.25 CASE P LNR2 4.25 CASE P LNR2 0.50 CASE P LNR2 0.50 CASE P LNR2 0.75 CASE P 1.00 CASE P 3.50 CASE P LNR2 LNR2 LNR2 1.00 CASE P 0.50 CASE P TIEB2 TIEB2 1.00 CASE P 2.00 CASE P TIEB2 TIEB2 2.00 CASE P 0.25 CASE P TIEB2 TIEB2 Description of Operations ..-...--_..... ---_.----- whipstock anchor. PU pulling seal assembly out of tie back sleeve. PU 30', 7k increase in PU weight. Monitorwell- static. CBU, 300 gpm at 1900 psi. Monitor well - static. Slug DP and POH with whipstock P/U 150k LD retrieving BHA and whipstock assembly. Clean and clear rig floor. RlU to run 4.5" slotted liner. PJSM with rig crew & BOT personnel regarding running liner & PU Hook Hanger assembly. M/U 4-1/2" Float Shoe (Bent) Jt + 87 Jts of 4-1/2" 12.6#, L-80, IBT-M slotted liner & BOT Flanged Hook Hanger ass'y. Total length = 3708.83' P/U Wt = 75k S/O Wt = 62k RID 4.5" Liner running equipment. Install DP elevators on TDS. RIH with 4-1/2" 12.6# Slotted liner assembly on 4" DP to 6936'. Circ DP vol with liner shoe at window. Rotate 5 RPM @ window looking for torque increase - saw slight increase as if window hooked with bent shoe jt. RIH but tag up on liner top of L 1 at 7135'. Attempt #1. POH above window and put 1/4 turn in pipe. Work turn down. RIH looking for window. Tag up on L 1 liner top again. Attempt #2. POH above window and put next 1/4 turn in pipe. Work turn down. RIH looking for window. Exit window successfully into L2. Attempt #3. Continue RIH with liner on DP into open hole. 160 klbs up. 85 klbs down. Engage hook hanger on bottom of window on first attempt. PU 20' above and rotate string 1/2 turn. Run in and run hook 10' below btm of window - OK. Pull up, re-orient hook hanger and re-engage bottom of window on second try - OK. Shoe at 10631'. Top of hook hanger at 6925'. Drop 29/32" ball in DP and circ down on seat at 4 then 2 bpm with 1020 stks. Pressure up to 3200 psi to release from hook hanger - OK. PU Wt = 135 klbs. Pressure up to 4500 psi with mud pump then BOP test pump and shear out ball seat - OK. PU 30' and CBU, 300 gpm at 1300 psi. Monitor well - static. Cut and slip 26' of drill line. Inspect brakes and drawworks. Monitor well - static. slug DP and POH with liner running tool. P/U Wt = 138k S/O Wt = 100k RU liner running equipment. PJSM with BOT and all rig personnel on MU and running ZXP Packer and LEM assembly. MU and run ZXP Packer and LEM assembly Continue RIH with ZXP Packer/LEM assembly on DP. MU top drive to each stand to prevent MOBM from running over. Continue RIH with ZXP Packer/LEM assembly Reduce running speed and pass mule shoe through hook hanger assembly. Establish string weights; 138 klbs up, 95 klbs Printed: 12/29/2003 9:47:18AM . . Page 12 of 13 BP Operations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: W-205 W-205 REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 9ES Date From - To Hours i Task Code NPT Phase ..... --..--'"-...-- -. .---.-.-... ----...--- 12/26/2003 02:00 - 02:15 0.25 CASE P TIEB2 02:15 - 03:00 0.75 CASE P TIEB2 03:00 - 04:30 1.50 CASE N RREP TIEB2 04:30 - 05:00 0.50 CASE P TIEB2 05:00 - 05:30 0.50 CASE P TIEB2 05:30 - 07:30 2.00 CASE P TIEB2 07:30 - 08:00 0.50 CASE P TIEB2 08:00 - 09:30 1.50 CASE P TIEB2 09:30 - 17:30 8.00 CASE P TIEB2 17:30 - 20:30 3.00 CASE P TIEB2 20:30 - 22:00 1.50 CASE P TIEB2 22:00 - 00:00 2.00 CASE P TIEB2 12/27/2003 00:00 - 03:00 3.00 CASE P TIEB2 03:00 - 04:00 1.00 CASE P TIEB2 04:00 - 04:30 0.50 RUNCOMN RREP COMP 04:30 - 12:30 8.00 RUNCOMN RREP COMP 12:30 - 13:00 0.50 BOPSUR.P COMP 13:00 - 15:00 2.00 RUNCOI\IP COMP 15:00 - 15:30 0.50 RUNCOI\IP COMP 15:30 - 00:00 8.50 RUNCOI\IP COMP 12/28/2003 00:00 - 01 :00 1.00 RUNCOI\IP COMP 01 :00 - 02:30 1.50 RUNCOI\IP COMP 02:30 - 05:00 2.50 RUNCOI\IP COMP 05:00 - 06:30 1.50 RUNCOI\IP COMP Start: Rig Release: Rig Number: 12/10/2003 12/28/2003 Spud Date: 8/23/2003 End: 12/28/2003 Description of Operations .....---.--- down. Continue RIH with mule shoe in tie-back sleeve and engaging LEM in hook hanger. PU 10k over string weight verifying LEM is engaged. Drop ball and pump onto seat at 4 bpm, 839 psi. Pressure up to 3000 with rig pump. RU test pump and continue pressuring up to 3300 psi to set packer. Continue pressuring up to 4500 psi to blow ball seat. Rotary hose failed at 4500 psi. The job was stopped a safety assessment was conducted. The rotary hose was rigged down. A head pin with TIW valve was rigged up on the DP. Continue pressure up with the test pump to 5000 psi to blow out ball seat. Reciprocate 20' while circulating and conditioning mud for displacement. Displace well to 9.3 ppg brine. Pumped the following sweeps: 20 bbls LVT-200 base oil 20 bbls viscosified 9.3 ppg brine 50 bbls 9.3 ppg brine with 4 drums Safe Surf 0 25 bbls viscosified 9.3 ppg brine Follow the sweeps with 279 bbls 9.3 ppg brine until clean returns. 430 gpm, 2020 psi. Blow down and RD circulating lines. Load MOBM on trucks. Clean MOBM from rotary table, sumps, shakers and trough. POH laying down DP RIH with 4-3/4" De's and 40 stands of DP from derrick CBU to flush MOBM from DP. 420 gpm, 1265 psi. Monitor well - static, Slug DP and POH laying down. Continue POH laying down DP Clean and clear rig floor of MOBM. PJSM with rig personnel on installing new rotary hose. Bring new rotary hose to the floor and install. Pull wear bushing. Make dummy run with landing joint. Change out bails and elevators. RU I-wire spooling unit and completion equipment. PJSM with Centrilift, Cameo, Tubel, BOT and all rig personnel on running completion with Phoenix and Tubel gauges, I-wire and clamps. Run 4-1/2", 12.6#, L-80 completion and all associated jewelry per running order. Continue Run 4-1/2", 12.6#, L-80, IBT-M completion. Ran 159 jts plus jewelry. PU spaceout joints. Space out tbg string. MU spacer pup. Install 1 foot of blast rings on pup jt below tubing hanger body and lock in place with stop ring. LD spaceout jts. MU hanger and landing joint. MU I-wire to tbg hanger. Install and test Tubel receiver. Test all swagelok fittings to 5000 psi. Land tbg. RILDS. Muleshoe on tailpipe landed at 6901' (9' inside L TP). Reverse circulate in 4 bbls corrosion inhibited brine followed by 180 bbls clean brine to place the corrosion inhibited brine Printed: 12/29/2003 9:47:18 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date From - To .... - Page 13 of 13 BP Operations Summary Report W-205 W-205 REENTER+COMPLETE Start: 12/10/2003 NABORS ALASKA DRILLING I Rig Release: 12/28/2003 NABORS 9ES Rig Number: 'I ' Hours i Task ¡ Code NPT I Phase 12/28/2003 05:00 - 06:30 06:30 - 08:30 i ...___._____._.____0". 1.50 RUNCOMP 2.00 RUNCOMP COMP COMP 08:30 - 09:30 1.00 RUNCOMP COMP 09:30 - 10:00 0.50 RUNCOMP COMP 10:00 - 11 :00 1.00 BOPSURP COMP 11:00-13:30 2.50 WHSUR P COMP 13:30 - 14:30 1.00 WHSUR P COMP 14:30 - 15:00 0.50 WHSUR P COMP 15:00 - 15:30 0.50 WHSUR P COMP 15:30 - 16:00 0.50 WHSUR P COMP 16:00 -17:00 1.00 WHSUR P COMP 17:00 - 18:00 1.00 WHSUR P COMP 18:00 - 19:30 1.50 WHSUR P COMP 19:30 - 20:30 1.00 WHSUR P COMP 20:30 - 21 :00 0.50 WHSUR P COMP Spud Date: 8/23/2003 End: 12/28/2003 Description of Operations .......-......-.----.- between the bottom GLM and the top of the packer. Drop ball & rod. Pressure up to 4200 psi to set packer. Bleed pressure to 3500 psi and hold for 30 minutes for tbg test. Bleed tbg pressure to 2000 psi and pressure up annulus to 3500 psi, hold for 30 minute for annular and packer test. Bleed both tbg and annulus pressure to 0 psi. Pressure up annulus, DCK valve sheared at 2600 psi. Establish circulation; 2bpm, 600 psi. RD circulating equipment. Break out landing joint. Install TWC, pressure test to 1000 psi. RD casing equipment, CO bails, blow down lines. NO BOPE NU tree and adapter flange Pressure test ports in tbg hanger used for I-Wire and Tubel gauge to 5000 psi RU DSM and pull TWC through lubricator. RU Little Red to freeze protect PJSM with Little red and all rig personnel on pumping diesel. Pump 110 bbl diesel down the annulus to freeze protect well at 2 bpm. ICP = 400 psi FCP = 875 psi Allow diesel to U-tube. Final tbg and inner annulus pressure = 225 psi RU DSM and install BPV through lubricator, Test BPV to 1000 psi with Little Red. Install VR plugs in tbg spool outlets. Secure well. Install gauges. RELEASE RIG @ 21 :00 Printed: 12/29/2003 9:47:18 AM · TREE = FMC4-1/6" 5M W8...LHEAO = FMC GS\! 5 AcrüÂî'õFi-;- KB."1=[¡3/ ,d-' -'''·--··ŠÒ-:¡¡Oi ~~!<:~~~Ie..~___9~~~~:' OatumMO= 5713' 'Datum'ïVÖ';-"-~45Õ-Õ;'SS 120# CONDUCTOR H 110-3/4" CSG. 40#. L-80, 10 = 9.95" H 3985' Minimum ID =2.750" @ 7627' 4-112" HES XN NIPPLE 4.5"PHOENIX DSCHRGE-FRESS SUB,IO = 3.85" H 14.5'R--NXMl~~D=3.833' H TUbel Ftessure Gauge. 10 = 3.833" I IRA TAG H 7-5/8" x 5.5" BKR ZXP PACKER, 10 = 5.5" H IBKR HUGHES HOOKWALL HGR, 10= 5.64" H FrQm DR W-20 5 W-20 5 L2 .. I ~ .. I~ .. l /""'" ~ ( II - gfIf r:¿- =~. 689Z ~: -i-~ 6925' vi I ~ ~ ~ 68* ~ H4-1/2" HESX NIP, D =3.813" I GAS LIFT MANORELS TVO OE\! TYPE VL V LA TCH 2503 45 KBG-2 DMY BK-5 4831 57 KBG-2 DMY BK-5 4888 60 KBG-2 DCK2 B8< H4-1/2" BKRCMO SLEEVE. 10= 3.813" I H7.625" X 4.5" BKR PRM FKR, 10 = 3.875" H4-1/2" HESX NIP. D =3.813" I H4-1/2" HESX NIP, 10=3.813" H4-1/2" MJle Shoe I PORT o o OATE 12/28/03 12/28/03 12/28/03 I 7" WNOOW @ 6930' 7003' -1 0631' 6-3/4" OBALATERAL, 10 ::: 3.958" IRA TAGH 7119' ~ 7-5/8" x 5.5" BKRZXPPACKER, 10 =5.5" H 7135' BKR HUGHES HOOKWALL HGR, 10= 5.64" H 7168' _ _ _ _ _ _ _ ~ _ _ ~~ ~ ~ ~ ~J I 7"WINOOW @ 7173' 7246' -10640' 6-3/4" OBC LATERAL, 10 ::: 3.958" 7525' H7.625" X5.5" BKRZXPLNR TOPPKR, 10= 4.810" 7535' "'H4-1/2" Mule Shoe I 7 531' H 5-1 /2" X 4-1/2" XO, 10 = 3.958" I 7627' H4-1/2"HESXNNIP,IO=2.750" I 17610' CTM H 2.5" IBP ~z --~ IRATAG ~I 7461 ÆRFORA TDN SUMMARY REF LOG: ANGLE AT TOP PERF: 67@ 7201' Note: Refer to Production OB for historical perf data SJZE SA" INTER\! AL OpnlSqz OA TE 4-1/2" SLTD OBA 7003 - ~ 12/28/03 4-1/2" SLTD OBC 7246 - ~ 12/20/03 4-1/2" SLTO OBO 7700 - ~ 09/07/03 I I I I I I 1 I U ~ 7700' -1 0667' 6-3/4" OBD LATERAL. ID ::: 3.958" 175/8" CSG, 26#, L-80, 10= 6.276" H 1618' I R3TD H DATE 09/09/03 09/13/03 09/29/03 10/12/03 12/28/03 REV BY COMf\i1ENTS JDrvvKK ORIGINAL COIVPLErION RWUKK GL V C/O JLJffLH Mn 10 & Nipple Correction KCF/TLP R3TO Correction JNC AOO L1 & L2 DATE RE\! BY COMMS\!TS ORION UNIT WELL: W-205, W-205 L 1, W-205 L2 PffiMrr t\b: 203116 (203) (201) AA t\b: 50-029-23165-00 (60) (61) SEC 21, T11 N, R12E, 3703' NSL & 1196' WB... BP Exploration (Alas ka) ids CÆJ " . WEU LOG TRANSMIn-AL . 1:) 03- JJ & ProActive Diagnostic Services, Inc. To: State of Alaska AOGCC 333 W. 7'" Street Suite # 700 Anchorage. Alaska 99501 RE : Distribution - Final Print( s] The technical data listed below is being submitted herewith. Please acknowledgé receipt by returning a signed copy of this transmittal letter to the attention of : Joey Burton / Jeni Thompson ProActive Diagnostic Services, Inc. P. O. Box 1369 Stafford, TX 77497 BP Exploration (Alaska), Inc. Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, AK 99508 WELL DATE loG TyPE DIGITAL OR CD-ROM 1 MYLAR / BLUE LINE REPORT SEPIA PRINT(S) OR FILM CoLD'" 1 1 Open Hole W-205 12-01-03 Res. Eva!. CH 1 . 1 1 J ~ 3£0 T Mech. CH 1 Caliper Survey Signed: .~,\ ~ N~'C Q"t ~""'-r\ Date: RECEIVED Print Name: ~H I 2 (1 l..0QOJ ..... 'I ¡ i -r Alaska Oif & Gas Cons. Commilion Anchorage PRoAcTivE DiAGNOSTic SERvicn, INC., PO Box 1 }69 STAffoRd TX 77477 Phone:(281) 565-9085 Fax.:(281) 565-1369 E-mail: pds@memorylog.com Website: www.memorylog.com ~~~"":b Y'i\Q:, .. STATE OF ALASKA _ ALAS~L AND GAS CONSERVATION COM-.sION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1a. Well Status: 181 Oil 0 Gas 0 Plugged 0 Abandoned 0 Suspended 0 WAG 20AAC 25.105 20AAC 25.110 21. Logs Run: MWD, GR, IFR, MS, RES, DEN, NEU, PWD, AIM, DPC MDT CASING, LINER AND CEMENTING RECORD SETTING 'IOP BOTTOM Surface 108' 29' 3985' 26' 7618' 7517' 10669' o GINJ 0 WINJ 0 WDSPL No. of Completions 2. Operator Name: BP Exploration (Alaska) Inc. 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 4a. Location of Well (Governmental Section): Surface: 3703' NSL, 1196' WEL, SEC. 21, T11N, R12E, UM Top of Productive Horizon: 4185' NSL, 3575' EWL, SEC. 22, T11N, R12E, UM Total Depth: 1857' NSL, 3432' EWL, SEC. 15, T11N, R12E, UM 4b. Location of Well (State Base Plane Coordinates): Surface: x- 612049 y- 5958680 Zone- ASP4 TPI: x- 616812 y- 5959234 Zone- ASP4 Total Depth: x- 616618 y- 5962184 Zone- ASP4 18. Directional Survey 181 Yes 0 No 22. 20" x 34" 215.5# 45.5# 29.7# 12.6# A53 L-80 L-80 L-80 10-3/4" 7-5/8" 4-1/2" 23. Perforations open to Production (MD + TVD of Top and Bottom Interval, Size and Number; if none, state "none"): 4-1/2" Slotted Section MD TVD MD TVD 7700' - 10667' 5189' - 5224' 26. Date First Production: September 19, 2003 Date of Test Hours Tested PRODUCTION FOR 9/18/2003 4 TEST PERIOD ... Flow Tubing Casing Pressure CALCULATED ....... Press. 297 24-HoUR RATE""" One Other 5. Date Camp., Susp., or Aband. 9/9/2003 6. Date Spudded 8/23/2003 7. Date T.D. Reached 9/6/2003 8. Elevation in feet (indicate KB, OF, etc.) KBE = 80.90' 9. Plug Back Depth (MD+ TVD) 10670 + 5224 Ft 10. Total Depth (MD+TVD) 10670 + 5224 Ft 11. Depth where SSSV set (Nipple) 2620' MD 19. Water depth, if offshore NIA MSL 48" 1b. Well Class: 181 Development 0 Exploratory o Stratigraphic 0 Service 12. Permit Number 203-116 13. API Number 50- 029-23165-00-00 14. Well Number PBU W-205 15. Field and Pool Prudhoe Bay Field I Polaris Pool 16. Lease Designation and Serial No. ADL 028263 17. Land Use Permit: 20. Thickness of Permafrost 1900' (Approx.) AMOUNT PULLED 13-1/2" 9-718" 6-3/4" 260 sx Arctic Set (Approx.) 897 sx PF 'L', 352 sx Class 'G" 561 sx Class 'G' Uncemented Slotted Liner SIZE 4-1/2", 12.6#, L-80 25. DEPTH SET (MD) 6590' PACKER SET (MD) 6440' DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED Freeze Protect with 107 Bbls of Diesel PRODUCTION TEST Method of Operation (Flowing, Gas Lift, etc.): Gas Lift OIL-BBL GAs-McF WATER-BBL 832 669 264 OIL-BBL 27. GAs-McF WATER-BBL CHOKE SIZE I GAS-OIL RATIO 1760 804 OIL GRAVITY-API (CORR) CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water (attach sepa~te !)heet, if neces~ary). Submit R~~R!?iI2;~+~r"9one, state "none". t..., i): l,''.),"i~ r L:" ,)\.,,'0 ¡ None .:~~J ..~~ ~ .. . OCT 0 9 2003 OR' G I ~\I !\ f NIJMS 8Ft. Form 10-407 Revised 2/2003 G\(::. CONTINUED ON REVERSE SIDE " ....; ~- .- .28. GEOLOGIC MARKER "- NAME MD TVD Ugnu 4415' 3469' Ugnu M Sandstones 6050' 4565' Schrader Bluff N Sandstones 6424' 4795' Schrader Bluff 0 Sandstones 6784' 4972' OBa 6928' 5030' OBb 7008' 5060' OBc 7177' 5113' OBd 7494' 5174' 30. List of Attachments: Summary of Daily Drilling Reports, Surveys 129. .RMATION TESTS Include and briefly summarize test results. List intervals tested, and attach detailed supporting data as necessary. If no tests were conducted, state "None". MDT was ran. Attached is a summary of MDT results. The fluid samples are currently being analyzed, and GOR and oil gravity data are not available at this time, but may be ready in about a month. Greg Bernaski is the Anchorage contact for the fluid testing results. (, ''>".... -1) " 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~I\I\.", LI. a..fJð_ Ttl T h IA t t D t J D"Öl D3 Terrie Hubble .....-IQJv~J ~~ i e ec nica ssis an a e . PBU W-205 203-116 Prepared By Name/Number: Terrie Hubble, 564-4628 Well Number Drilling Engineer: Michael Triolo, 564-5774 Permit No. I Approval No. 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 1a: Classification of Service Wells: Gas Injection, Water Injection, Water-Altemating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. ITEM 4b: TPI (Top of Producing Interval). ITEM 8: The Kelly Bushing elevation in feet above mean low low water. Use same as reference for depth measurements given in other spaces on this form and in any attachments. ITEM 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). ITEM 20: True vertical thickness. ITEM 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITEM 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). ITEM 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, or Other (explain). ITEM 27: If no cores taken, indicate "None". ITEM 29: List all test information. If none, state "None". Form 10-407 Revised 2/2003 u;\ LJir\JAL . . W-205 MDT RESULTS Depth (ft. Schrader Bluff Formation Fluid Sample Depth (ft. MD) TVDSS) Zone Pressure (psi) Fluid Sample? pump time 6792 4894 OA 2204 6795 4894 OA 2204 yes, 450 ml. 180 min. 6810 4902 OA 2210 6976 4967 OBa 2125 6982 4970 OBa 2125 yes, 1 gal. 130 min. 7193 5036 OBc 2253 7195 5037 OBc 2253 yes, 450 ml. 145 min. 7212 5041 OBc 2323 7250 5051 OBc 2228 yes, 450 ml. 100 min. 7262 5054 OBc 2229 7557 5098 OBd 2257 7571 5100 OBd 2249 7574 5100 OBd 2249 yes, 1 gal. 150 min. Note: Oil gravity and GaR data not available yet. Testing is in progress. BP Leak-Off Test Summary Page 1 of 1 Legal Name: W-205 Common Name: W-205 , . Test Date Test Type Test Depth (TMD) Test Depth (TVD) AMW Surface Pressure ; Leak Off Pressure (BHP) EMW ........ .........n.... -----. _._~ 8/26/2003 LOT (ft) (ft) (ppg) (psi) (psi) (ppg) 8/27/2003 LOT 4,414.0 (ft) 3,190.0 (ft) 9.20 (ppg) 825 (psi) 2,350 (psi) 14.18 (ppg) 8/28/2003 LOT (ft) (ft) (ppg) (psi) (psi) (ppg) 8/26/2003 LOT 3,985.0 (ft) 3,190.0 (ft) 9.20 (ppg) 825 (psi) 2,350 (psi) 14.18 (ppg) . 9/5/2003 FIT 7,618.0 (ft) 5,184.0 (ft) 9.20 (ppg) 684 (psi) 3,162 (psi) 11.74 (ppg) . Printed: 9/15/2003 9:49:02 AM ~ .. Page 1 of 10 BP Operations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: W-205 W-205 DRILL +COMPLETE NABORS ALASKA DRILLING I NABORS 9ES Date i Task : Code NPT Phase From - To Hours 8/22/2003 07:00 - 12:00 5.00 RIGU P PRE 12:00 - 19:00 7.00 BOPSURP 19:00 - 00:00 5.00 BOPSURP 8/23/2003 00:00 - 01 :00 1.00 BOPSURP 01 :00 - 01 :30 0.50 BOPSURP 01 :30 - 05:30 4.00 DRILL P 05:30 - 06:00 0.50 DRILL P 06:00 - 06:30 0.50 DRILL P 06:30 - 08:00 1.50 DRILL P PRE PRE PRE PRE SURF SURF SURF SURF 08:00 - 09:00 1.00 DRILL P SURF 09:00 - 19:30 10.50 DRILL P SURF 19:30 - 20:30 1.00 DRILL P SURF 20:30 - 22:00 1.50 DRILL P SURF 22:00 - 23:30 1.50 DRILL P SURF 23:30 - 00:00 0.50 DRILL P SURF 8/24/2003 00:00 - 01 :00 1.00 DRILL P SURF 01 :00 - 13:30 12.50 DRILL P SURF 13:30 - 14:30 1.00 DRILL P SURF 14:30 -18:00 3.50 DRILL P SURF 18:00 - 20:00 2.00 DRILL P SURF Start: Rig Release: Rig Number: Spud Date: 8/23/2003 End: 9/9/2003 8/22/2003 9/9/2003 Description of Operations ---.----" ---..-.---------- .......--.-.-.- Ready rig for move to W-205. Move and spot rig, pits, camp and shop. Accept rig on W-205 @ 12:00 HRS. N/U 20" diverter system. Take on water and mix spud mud. Change quill and saver sub on top drive. Load pipe in shed and strap same. Pick up 5" D.P. and HWDP and rack back in derrick. Continue to mix spud mud. P/U and rack back DP and HWDP in derrick. Pick up BHA from bottom of beaver slide and strap same. Pick up and rack back Jars and 2 joints of HWDP to make up stand. Function test diverter. Build BHA with 13 1/2 Hughes mill tooth bit and 1.83 motor. Pre-spud / HSE meeting. Fill hole and pressure test lines. Inspect diverter system for leaks. Wash cement from conductor. Spud and drill 13 1/2 surface hole from 108 to 264. (Spud well at 07:00 HRS) GPM==650 @ 800 on bottom and 700 off RPM==45 TRQ==3,OOO on and 1,000 off Circulate bottoms up and TOH to Pick up Jars and 2 jts. HWDP stood back in derrick. RIH Drill from 264 to 1,675. Begin build section at 300 ft.. Sliding app. 70 percent of each stand while building hole angle to 45 degrees. GPM==710 @ 1100 PSI off and 1300 PSI on bottom RPM==45 TRQ==1 ,500 off and 5,000 on bottom ART==3.26 AST==5.02 Circulate 2 X bottoms up. POH with intermittent 10 to 15K overpulls from 1,220 to 500. Wipe away as needed. Stand back HWDP and break and grade bit. Adjust motor from 1.83 to 1.5 degrees and orient with MWD. Clear floor of all excess vendors equipment. Service topdrive. RIH and shallow test BHA. RIH to 1,675 while working intermittent hole drag from 1,100 to bottom. Wash last stand to bottom as precautionary measure. Drill 13 1/2 surface hole from 1,675 to 3,994, while building hole angle to 49 degrees. GPM==750 @ 2,220 PSI off and 2,620 PSI on bottom RPM==80 TRQ==6,500 off and 11,000 on bottom Circulate 2.5 x bottoms up while rotating string at 100 RPM and pumping at 750 GPM. POH to 645 while working intermittent 5 to 20k overpulls. Did not pump or ream. RIH working intermittent 10 to 20K pipe drag. Establish circulation at 3,900 and wash last stand to bottom @ 3,994. Printed: 9/15/2003 9:49:11 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date 8/24/2003 8/25/2003 8/26/2003 .... .. Page'2of 10 BP Operations Summary Report W-205 W-205 DRILL +COMPLETE NABORS ALASKA DRILLING I NABORS 9ES From - To I Hours ¡ Task i Code NPT Start: Rig Release: Rig Number: Phase 18:00 - 20:00 20:00 - 22:00 22:00 - 00:00 00:00 - 01 :00 01 :00 - 03:00 03:00 - 12:30 12:30 - 13:00 13:00 - 16:00 16:00 - 20:00 20:00 - 22:00 22:00 - 00:00 00:00 - 06:00 06:00 - 10:00 10:00 - 10:30 10:30 - 14:00 ..... .- 2.00 DRILL P 2.00 DRILL P 2.00 DRILL P 1.00 DRILL P 2.00 DRILL P 9.50 CASE P 0.50 CASE P 3.00 CASE P 4.00 CEMT P 2.00 CEMT P 2.00 CEMT P 6.00 BOPSURP 4.00 BOPSURP 0.50 BOPSURP 3.50 DRILL P SURF SURF SURF SURF SURF SURF SURF SURF SURF SURF SURF SURF SURF SURF INT1 8/22/2003 9/9/2003 Spud Date: 8/23/2003 End: 9/9/2003 Description of Operations __._.. ..__ . ." ...._...____._____"______n No fill or packing off. Circulate bottoms up until shakers clean up. Pump 30 bbls. weighted sweep at 11.6 ppg.. Pump sweep S-S while rotating and reciprocating string at 100 RPM and pumping 750 GPM. Pull 5 stands and pump dry job. No adverse hole conditons. Continue to POH to 1,500 with hole taking proper fill and no adverse hole conditions. POH from 1,500 to 645. Work / Wipe spot at 1,410 and other small overpulls from 1,400 to 1,100. No washing or reaming required on TOH. Hole took proper fill. Rack back HWDP. Layout MWD and motor. Break and grade bit. Clear floor of all excess vendors equipment. PJSM. Pick up and rig up casing equipment, Franks fill up tool and long bales. Dummy run landing joint and hanger. Record and mark landing depth. M/U 103/445.5 # L-80 shoe track and check floats. RIH with 95 jts. of 10 3/4 surface pipe to 3985 and land on MLSH. (10 to 15K drag seen from 1,850 to 2,500 then intermittent to bottom.) RID and layout Franks fill up tool. Blow down Topdrive and M/U cement head and lines. Circulate and condition mud for cement job. Reciprocate pipe while pumping at 9 BPM 780 PSI. PJSM with crews while treating and conditioning mud. Up wt.==195K Own wt==112K Pump 5 bbls water and pressure test lines to 3,500. Pump 15 water, 75 bbls. weighted Alpha spacer at 10.6 ppg. and kick out bottom plug with 663 bbls., 10.7 ppg lead, (897 sks.) "Type L" permafrost cement with 4.15 yield. Pump 72 bbls., 15.8 tail (350 sks.) "Type G" with 1.15 yield. Drop top plug and kick out with 1 0 bbls. water. Chase with rig pumps and bump plug at calculated displacement. Pressure up to 1,800 and hold for 5 minutes. Bleed of pressure and confirm floats are holding. *Reciprocated string until after app. 200 bbls. of lead had exited shoe. Set on landing ring due to very light hook loads on down stroke* * App. 70 bbls. clabbered cement with 150 bbls. of good "sidewalk cement" back at surface.* *****CIP @ 19:35 RID and layout cement head, Franks tool and long bales. Break out and lay down landing joint. Clear floor of all excess vendors equipment. Flush out hydril, knife valve and surface head. Remove 4 inch valves from conductor and clear of cement. N/D riser and diverter line. Nipple down surface diverter and nipple up stack. Flush and clear system of any residual cement. N/U FMC Gen-5 "Split Unihead" test seals to 1000. N/U 5,000 PSI BOP system. Test BOP to 250-3,500 as per policy with AOGCC rep.,"Jeff Jones". Changed out stem packing on HeR valve on choke side of stack. All other equipment passed test. Install wear bushing and layout test joint. P/U, strap and build BHA # 3 with Hycalog, 97/8", DS70 PDC Printed: 9/15/2003 9:49: 11 AM . . Page 3 of 10 ,ßP Operations Summary Report:: Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: W-205 W-205 DRILL +COMPLETE NABORS ALASKA DRILLING I NABORS 9ES Date From - To , Hours i Task Code NPT Phase --..-..------ .... ---..-..-.-.-..-.....-..-... 10:30 - 14:00 3.50 DRILL P 14:00 - 15:00 1.00 DRILL P 15:00 - 16:00 1.00 DRILL P 16:00 - 17:00 1.00 DRILL P 17:00 - 18:00 1.00 DRILL P 8/26/2003 18:00 - 18:30 0.50 DRILL P 18:30 - 21 :00 2.50 DRILL P 21 :00 - 22:00 1.00 BOPSURP 22:00 - 23:30 1.50 DRILL P 23:30 - 00:00 0.50 DRILL P 8/27/2003 00:00 - 00:30 0.50 DRILL P 00:30 - 01 :00 0.50 DRILL P 01 :00 - 00:00 23.00 DRILL P 8/28/2003 00:00 - 16:00 16.00 DRILL P 16:00 - 17:00 1.00 DRILL P INT1 17:00 - 21:30 4.50 DRILL P INT1 21 :30 - 22:30 1.00 DRILL P INT1 22:30 - 00:00 1.50 DRILL P INT1 INT1 INT1 INT1 INT1 INT1 INT1 INT1 INT1 INT1 INT1 INT1 INT1 INT1 INT1 Start: Rig Release: Rig Number: Spud Date: 8/23/2003 End: 9/9/2003 8/22/2003 9/9/2003 Description of Operations bit, 1.5 degree motor and MWD / PWD. Load source, orient and shallow test BHA. P/U 5" DP from shed 1x1 and rack back in derrick. "Slip and snip" drilling line 83 / 109. Service top drive. Change all handling equipment over to 4", including iron ruffneck and TO. RIH while picking up 4" DP 1x1. Test casing to 1,000 PSI once BHA passed TAM collar. CBU---thick and nasty spud mud returned. Continue to RIH to 2,000 CBU staging pumps up while getting back very thick spud mud. Mud looking better at bottoms up. RIH from 2,000 to 3,720. Screw into TO and wash to 3,823. Pressure test 10 3/4 45.5# L-80 surface pipe to 3,500 while plotting and recording pressures vs. strokes. Hold for 30 minutes with no loss. Drill plugs, F/C, and shoe track plus 20 ft. of new hole, to 4,014. GPM==510 @ 1,790 PSI Displace well to 9.2 LSND mud while rotating and reciprocating string. Displace well to 9.2 LSND mud at 510 GPM @ 1,790 PSI. Rotated and reciprocated string throughout displacement. Pull bit inside casing and perform LOT per RP. MW==9.2 TVD==3,190 Surface pressure==825 EMW==14.17 Obtain benchmark ECD readings of 9.7. Drill ahead from 4,014 to 6,490. Pump Hi-Vis sweeps every 300 ft., backreaming each connection with 650 GPM @ 100 RPM on up stroke and 480 GPM and 100 RPM on down stroke. Maintain < .8 ppg. over calculated ECD on all drilling and backreaming. AST==5.61 ART==7.53 Drilling 9 7/8 intermediate hole from 6,490 to 7,628. Pump Hi-Vis sweeps every 400 ft., backreaming each connection with 650 GPM @ 100 RPM on up stroke and 480 GPM and 100 RPM on down stroke. Maintain < .8 ppg. over calculated ECD on all drilling and backreaming. Up==168K Dwn==105K String==130K GPM==650 @ 2740 on and 2480 off RPM==80-100 TRQ==1 OK off and 13 on WOB==20-25 ART==2.91 AST==7.77 ADT==10.68 Circulate 40 bbls. LO-HI sweep at drilling rate, while rotating and reciprocating string at 110 RPM. Minimal increase in cuttings seen back with sweep. MAD pass from 7,628 to 6,745. Pumping at 650 GPM with 60 RPM. Pump dry job and POH from 6,785 to 5,044. Hole began to swab and pull over 15 to 25K. Backreaming out of the hole from 5,044 to 5,000. Hole packing Printed: 9/15/2003 9:49: 11 AM ~ .. BP Operàtions Summary Report Page 4 of1 0 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: W-205 W-205 DRILL +COMPLETE NABORS ALASKA DRILLING I NABORS 9ES Start: Rig Release: Rig Number: 8/22/2003 9/9/2003 Spud Date: 8/23/2003 End: 9/9/2003 Date From - To Hours Task Code NPT Phase Description of Operations ._---------~--_.. ... u__. _..._n___"_____ 8/28/2003 22:30 - 00:00 1.50 DRILL P INT1 off while backreaming at 650 GPM and 100 RPM. 8/29/2003 00:00 - 00:30 0.50 DRILL P INT1 Backreaming out of hole from 5,000 to 4,985 with 110 RPM and 650 GPM. Intermittent packing off with increased ECD's. 00:30 - 01 :00 0.50 DRILL P INT1 Circulate 40 bbl. weighted Hi-Vis sweep S-S while rotating at 100 RPM and pumping at 600 GPM. Calculated ECD 9.92 with actual 10.6 reducing to 10.16. Some cuttings back with sweep. 01 :00 - 04:30 3.50 DRILL P INT1 Backream out of the hole from 4,985 to 3,850 with 650 GPM @ 2050 and 110 RPM. Intermittent packing off while moving up between 2 to 5 ft. per minute. Hole packed off as "GHOST REAMER" was 90 ft. inside casing. Work up inside casing as hole allowed. Calculated ECD==9.92 Actual ECD==9.98 04:30 - 05:00 0.50 DRILL P INT1 Circulate 40 bbls. weighted HI-Vis sweep at 3,850 while rotating string at 110 RPM and pumping 650 GPM. Lots of wall cake seen while circulating sweep out of the hole. 05:00 - 05:30 0.50 DRILL P INT1 Service top drive. 05:30 - 08:00 2.50 DRILL P INT1 RIH filling pipe at 5,850. Continue to RIH to 7,535. M/U top drive and stage up pumps to 650 GPM. Wash last stand to bottom @ 7,628 with no adverse hole conditions or fill. Hole in good shape on TIH. 08:00 - 10:00 2.00 DRILL P INT1 Circulate 40 bbl. weighted sweep ( 2 ppg. over) S-S while rotating string at 120 RPM. Wall cake and dehydrated mud seen while circulating. RPM==120 GPM==650 TRQ==12,500 Up==163 Dwn== 102 String==127 with pumps on Up==187 Dwn==103 String==N/A with no pumps Calculated ECD==9.93 Actual ECD==9.91 10:00 - 14:30 4.50 DRILL P INT1 POH to casing shoe with no adverse hole conditions. Monitor well. Drop 2 3/8 rabbit. POH to BHA. 14:30 - 17:30 3.00 DRILL P INT1 Layout BHA and grade bit. Clear floor of all excess vendors equipment. 17:30 - 20:30 3.00 .EVAL P INT1 PJSM R/U Schlumberger. M/U MDT E-line tools and test tools latch. Hang and secure sheave in derrick. 20:30 - 00:00 3.50 EVAL P INT1 RIH with TLC MDT E-Line tools on drill string to 3,985. Break circulation at 2,000 and 3,985. 8/30/2003 00:00 - 02:30 2.50 EVAL P INT1 RIH with MDT logging tools on DP to 6,487 with no adverse hole conditions. Broke circulation at 2,000 ft. and 3,985 with 4 BPM @ 200 PSI, then every 500 ft. in open hole. Fluid displacement correct. 02:30 - 04:30 2.00 EVAL P INT1 P/U side entry sub at 6,487 and RIH with E-line to make connection. Confirm latch into MDT. 04:30 - 05:30 1.00 EVAL P INT1 RIH with MDT tools to 6798. 05:30 - 10:30 5.00 EVAL P INT1 Take formation pressure samples as per program at listed depths: 6798.6 6816.6 6988.6 7199.6 7218.6 7256.6 7268.6 7563.6 7575.6 7580.6 10:30 - 15:00 4.50 EVAL P INT1 Take fluid sample #1 in OBd at 7574. Good 15:00 - 16:00 1.00 EVAL P INT1 POH to 6,982 and prepare to take fluid sample #2 in OBa sand. 16:00 - 20:30 4.50 EVAL P INT1 Take fluid sample #2 in OBa sand at 6,982. No sample. Sample pumps failed. Both the main and backup pump will require a trip to the surface to change out. Discuss need for Printed: 9/15/2003 9:49: 11 AM ... - BP Operations Summary Report Page 5 of 10 Legal Well Name: W-205 Common Well Name: W-205 Spud Date: 8/23/2003 Event Name: DRILL +COMPLETE Start: 8/22/2003 End: 9/9/2003 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 9/9/2003 Rig Name: NABORS 9ES Rig Number: Date From - To Hours Task, Code NPT Phase I Description of Operations ., ! ....-.-----. --- ----.. --.-- 8/30/2003 16:00 - 20:30 4.50 EVAL P INT1 remaining samples with Anchorage Geo. group. POH to repair tools and repeat run. 20:30 - 21 :30 1.00 EVAL N DFAL INT1 POH to 6,587 with 5 to 10k intermittent bumps. 21 :30 - 22:30 1.00 EVAL N DFAL INT1 RID clamp, pull out of wet connect and spool E-line. RID side entry sub. 22:30 - 00:00 1.50 EVAL N DFAL INT1 Pump dry job and monitor well. POH at controlled rate with MDT tools. Hole taking proper fill. 170K up and 98K down 8/31/2003 00:00 - 02:30 2.50 EVAL N DFAL INT1 POH to MDT tools. Hole taking proper fill. 02:30 - 05:00 2.50 EVAL N DFAL INT1 PJSM. Layout Schlumberger MDT tools and equipment. 05:00 - 06:00 1.00 EVAL N DFAL INT1 P/U clean out assembly with used MXC-1 bit, NB stab, 13 jts. 5 HWDP Jars, 1 jt. 5 HWDP. 06:00 - 07:00 1.00 EVAL N DFAL INT1 RIH to casing shoe at 3,985. 07:00 - 08:00 1.00 EVAL N DFAL INT1 Slip and snip drilling line while CBU @ 500 GPM with 835 PSI. No losses. Up wt. at shoe==114 Dwn==74 08:00 - 09:00 1.00 EVAL N DFAL INT1 Service top drive and adjust disc brake. 09:00 - 10:00 1.00 EVAL N DFAL INT1 RIH at modest pace to 5,700 with hole giving back proper displacement. 10:00 - 10:30 0.50 EVAL N DFAL INT1 Stage up pumps to 500 GPM @ 1135 PSI. Move 100 bbls. of mud up hole. No losses. Up wt.==156 Dwn==94 10:30 -11:00 0.50 EVAL N DFAL INT1 RIH from 5,700 to 7,532 and M/U top drive. 11:00-13:30 2.50 EVAL N DFAL INT1 Wash to bottom from 7,532 to 7,628 with no adverse hole conditions or fill. CBU at 500 GPM @ 1,280 while rotating string at 80 RPM. Circulate 40 bbl. Hi-vis sweep S-S @ 650 GPM /1,775 PSI with 3 x calculated bottoms up. Rotated / Reciprocated string at 120 RPM. Very minimal amount cutting or wall cake seen while circulating. (Circulate 1 more bottoms up after shakers clean up) RPM== 120 GPM==650 @ 1,775 TRQ==10-12 Up wt. with pumps==170 Own with pumps==98 Up not pumps==185 Own with no pump==1 00 Rotating string wt. with pumps on at 650 GPM==130 13:30 - 17:30 4.00 EVAL N DFAL INT1 Pump dry job and monitor well. POH to casing shoe with no adverse hole conditions with hole taking proper fill. Monitor well. Continue TOH to BHA. At shoe: Up==118 Dwn==73 17:30 - 18:00 0.50 EVAL N DFAL INT1 Layout clean wiper assembly. 18:00 - 19:00 1.00 EVAL N DFAL INT1 PJSM. P/U and M/U MDT logging BHA. 19:00 - 23:30 4.50 EVAL N DFAL INT1 RIH to 6,465 with MDT tools and break circ. at 2,000, 4,000 and every 500 ft. once below the 10 3/4 casing shoe at 3,985. 23:30 - 00:00 0.50 EVAL N DFAL INT1 P/U and M/U side entry sub at 6,369. 9/1/2003 00:00 - 00:30 0.50 EVAL N DFAL INT1 M/U side entry sub at 6,369. No adverse hole condition on TIH. 00:30 - 01 :30 1.00 EVAL N DFAL INT1 RIH with E-line inside DP. Pump down d.p. and latch into wet connect with E-line and confirm contact. 01 :30 - 02:00 0.50 EVAL N DFAL INT1 RIH and position to recover fluid sample at 6,982. 02:00 - 05:00 3.00 EVAL P INT1 Recover 1 gallon fluid sample from OBa @ 6,982. 05:00 - 07:30 2.50 EVAL P INT1 RIH and position tool to recover fluid sample in OBc at 7,250 07:30 - 11 :00 3.50 EVAL P INT1 POH and position tool to recover fluid sample in OBc at 7,195. 11 :00 - 15:30 4.50 EVAL P INT1 POH and position tool to recover fluid sample in OA at 6,795. Printed: 9/15/2003 9:49: 11 AM ..... .. Page 6 of 10 BP Operations $ummary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date 9/1/2003 9/2/2003 W-205 W-205 DRILL +COMPLETE NABORS ALASKA DRILLING I NABORS 9ES From - To Hours Task Code! NPT Phase 15:30 - 16:00 0.50 EVAL P INT1 16:00 - 17:30 1.50 EVAL P INT1 17:30 - 22:00 4.50 EVAL P INT1 22:00 - 00:00 2.00 EVAL P INT1 00:00 - 00:30 0.50 BOPSURP INT1 00:30 - 04:30 4.00 BOPSURP INT1 04:30 - 05:30 1.00 DRILL P INT1 05:30 - 07:30 2.00 DRILL P INT1 07:30 - 09:00 1.50 DRILL P INT1 09:00 - 10:30 1.50 DRILL P INT1 10:30 - 14:30 4.00 DRILL P INT1 14:30 - 15:00 0.50 DRILL P INT1 15:00 - 17:00 2.00 DRILL P INT1 17:00 - 17:30 0.50 DRILL P INT1 17:30 - 21 :00 3.50 DRILL P INT1 21 :00 - 22:00 1.00 DRILL P INT1 22:00 - 00:00 2.00 DRILL P INT1 9/3/2003 00:00 - 00:30 0.50 DRILL P INT1 00:30 - 01 :30 1.00 DRILL P INT1 01 :30 - 02:30 1.00 CASE P INT1 02:30 - 03:30 1.00 CASE P INT1 03:30 - 05:00 1.50 CASE P INT1 05:00 - 05:30 0.50 CASE P INT1 05:30 - 11 :30 6.00 CASE P INT1 11 :30 - 12:30 1.00 CASE P INT1 12:30 - 19:30 7.00 CASE P INT1 19:30 - 20:00 20:00 - 21 :30 0.50 CEMT P 1.50 CEMT P INT1 INT1 Start: Rig Release: Rig Number: Spud Date: 8/23/2003 End: 9/9/2003 8/22/2003 9/9/2003 Description of Operations __. .·____..__n______m..o__".. POH to side entry sub at 6,395 Lay down side entry sub. Pull out of wet connect and spool E-line. Pump dry job and monitor well. POH to logging tools. (Test choke manifold on trip out) Break out and lay down MDT tool, sheaves etc., etc.. Pull wear ring and install test joinl. Pressure test BOP's as per policy 250 low and 3,500 High. Witness of test waived by Chuck Scheve. Pull test joint and install wear bushing. P/U clean out BHA. Surface test MWD / LWD to MAD pass bottom section of hole. RIH to shoe @ 3985'. Fill pipe. PU = 150K, ON = 94K, ROT = 117K RIH to 7590' - No problems. Wash to TO @ 7628'. CBU @ 500 GPM, 1380 psi. & 60 RPM. PU = 175K, ON = 95K, ROT = 129K. TO = 10K. Calc. ECD = 9.99 ppg. Act. ECD = 10.19 ppg. MAD Pass from 7628' to 6785'.600 to 650 GPM, 60 RPM. TO = 1 OK to 11 K. RIH to 7534'. Precautionary wash last stand to bottom @ 7628' Circulate HI-VIS Sweep & CBU 3 times.@ 650 GPM, 1920 psi. & 120 RPM. TQ = 10K to 11K, PU = 170K, ON = 98K, ROT = 128K. Calc ECD = 9.94 ppg., Act ECD = 9.98 ppg. Spot Lube Pill in Open Hole. Chase w/ Dry job. POH UD 5' DP to shoe @ 3986'. Pulling 5K to 10 Kover. CBU @ 650 GPM, 1545 psi & 100 RPM, reciprocating 90 ft. Calc. ECD = 9.98 ppg, Initial ECD = 10.35 ppg. Final ECD = 10.17 ppg. POH UD remainder of 5" DP. Stand back 4" DP in Derrick. PJSM on LID BHA and removing nuclear source. UD BHA - remove source from ADN. Remove wear bushing, Jet BOP and Head, Run test plug. Change to 7 5/8" Casing Rams & test bonnet seals to 3500 psi. R/U to run 7 5/8" Casing. PJSM with all hands on Casing run. M/U Shoe Track, Check Floats, Run 7 5/8" Casing to 10 3/4" shoe @ 3985' @ 1 min per JI. Fill every Jt, Circ 5 min. every 20 Jts. No losses. Stage up pumps & Circulate 1.5 times annular volume. No losses. PU = 142K, ON = 1 06K without pump. Continue running in open hole @ 1 min. per JI. Fill every Jt, break circ. every 5 Jts & circulate 15 min every 15 Jts by circ. down 3 Jts. @ 5 min per JI. CBU @ 6000'. Hole in good shape - No Losses. Mu Landing JI. & Land Casing @ 7618'. Total 178 Jts 7 5/8",29.7#, L-80 BTC-M Casing Ran. R/D Franks Tool & R/U Cement Head & Lines. Break circulation & stage up pumps to 8 BPM. C & C mud. No Losses. Reciprocate Casing 15 ft. PU = 240K, ON = 120K. Printed: 9/15/2003 9:49:11 AM . . BP Operations Summary Report Page 7 of 10 Legal Well Name: W-205 Common Well Name: W-205 Event Name: DRILL +COMPLETE Contractor Name: NABORS ALASKA DRILLING I Rig Name: NABORS 9ES Date I From - To : Hours Task 8/22/2003 9/9/2003 Spud Date: 8/23/2003 End: 9/9/2003 Start: Rig Release: Rig Number: Code NPT I Phase 9/3/2003 20:00 - 21 :30 21 :30 - 23:30 1.50 CEMT P 2.00 CEMT P INT1 INT1 9/4/2003 23:30 - 00:00 00:00 - 01 :00 01 :00 - 02:00 02:00 - 05:00 0.50 CEMT P 1.00 CEMT P 1.00 CASE P 3.00 P INT1 INT1 INT1 PROD1 05:00 - 06:00 PROD1 1.00 DRILL P 06:00 - 07:30 PROD1 1.50 DRILL P 07:30 - 08:30 1.00 DRILL P PROD1 08:30 - 14:30 6.00 DRILL P PROD1 14:30 -15:00 0.50 DRILL P PROD1 15:00 - 16:00 1.00 DRILL P PROD1 16:00 -17:00 1.00 DRILL P PROD1 17:00 - 17:30 0.50 DRILL P PROD1 17:30 - 20:00 2.50 DRILL P PROD1 20:00 - 00:00 4.00 DRILL P PROD1 9/5/2003 00:00 - 03:00 3.00 DRILL P PROD1 03:00 - 03:30 0.50 CASE P INT1 03:30 - 04:00 0.50 DRILL P PROD1 04:00 - 04:30 0.50 DRILL P PROD1 Description of Operations PJSM with Crew, Halliburton & Veco Drivers. Switch over to HOWCO and Cement as follows: Pump 5 bbls 3% KCL water. Test lines to 3500 psi. Mix & pump 30 BBls Alfa Spacer @ 10.2 ppg. Drop Bottom Plug. Mix & pump 122 bbls / 566 sks, Premium class" G " slurry with 3% KCL BWOW, 1% CalSeal & 0.6% LAP-1, weighing 15.6 ppg. Switch back to rig pump & displace with 346 bbls of seawater. Reciprocate pipe throughot Job. Slow pumps as spacer rounded corner and again at tail end of displacement. Final displacement pressure - 978 psi. Bumped plug with 2000 psi. 100% returns throughout job. RID Cement Head & Landing Joint RID Cement Equipment & Clear Floor Set FMC Pack-Off & Test to 5000 psi for 10 min. - OK. C/O Rams to 3.5" X 6" Variables. Test to 250 / 3500 psi. Test 4" safety valve, IBOB, Lower Top Drive Safety Valve to 250/ 3500 psi. Pull Test Plug and Install 7" Wear Bushing. Clean Pits in preparation for VersaPro MOBM. PJSM for Annular LOT & injectivity Perform LOT injecting down 103/4" X 7 5/8" annulus. Shoe TVD = 3190', Leak off at 475 psi with 9.4 ppg. Mud. LOT = 12.26 EMW. Inject 260 Bbls 9.4 ppg LSND mud at following rates and pressures: 1 BPM @ 700 psi. 2 BPM @ 800 psi. 3 BPM @ 875 psi. 4 BPM @ 950 psi. 5 BPM @ 1000 psi. Continue cleaning pits. Test Little Red's lines to 3000 psi. Pump 105 Bbls of dead crude down 10 3/4" X 7 5/8" Annulus to Freeze protect to 2600'. Pumped @ 3 BPM. Bleed Annulus. RID & release Little Red. Continue Cleaning Pits and Solids Equip for VersaPro MOBM Service Top Drive. P/U 21 Jts, 4" HT -40 Drill Pipe Slip & Cut 98' of Drlg. Line, Inspect Draworks & adjust brakes. Stand back 7 stands of 4" DP in Derrick. P/U & M/U BHA # 6, Orient MWD, Load source in ADN, RIH P/U 4" to 950'. Shallow test MWD - Unsuccessful w/ one pump & Seawater. RIH P/U 4" DP from shed to 4750' Test MWD - OK. RIH P/U 4" DP to 7443'. Break Circulation. Test 7 5/8" casing to 3500 psi. for 30 minutes. Good Test. Wash down to Float Collar @ 7533' PJSM with Crew, MI hands, Veco drivers on dispacement with the VersaPro Mineral Oil Based Mud. Printed: 9/15/2003 9:49: 11 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date 9/5/2003 9/6/2003 9/7/2003 . . Page 8 of10 BP Operations Summary Report W-205 W-205 DRILL +COMPLETE NABORS ALASKA DRILLING I NABORS 9ES From - To Hours Task Code NPT Phase 04:30 - 06:00 06:00 - 08:00 08:00 - 09:00 09:00 - 09:30 09:30 - 00:00 00:00 - 06:00 06:00 - 07:00 07:00 - 23:30 23:30 - 00:00 00:00 - 02:30 02:30 - 05:30 05:30 - 06:00 06:00 - 07:00 07:00 - 10:00 10:00 - 12:30 12:30 - 14:00 14:00 - 14:30 14:30 - 17:30 17:30 - 18:00 1.50 DRILL P 2.00 DRILL P PROD1 PROD1 1.00 DRILL P PROD1 0.50 DRILL P PROD1 14.50 DRILL P PROD1 6.00 DRILL P PROD1 1.00 DRILL P 16.50 DRILL P PROD1 PROD1 0.50 DRILL P 2.50 DRILL P PROD1 PROD1 3.00 DRILL P PROD1 0.50 DRILL P 1.00 DRILL P PROD1 PROD1 3.00 DRILL P PROD1 2.50 DRILL P 1.50 CASE P 0.50 CASE P 3.00 CASE P PROD1 PROD1 PROD1 COMP 0.50 CASE P CaMP Start: 8/22/2003 Rig Release: 9/9/2003 Rig Number: Spud Date: 8/23/2003 End: 9/9/2003 Description of Operations . .. ....------ Displace well bore with 9.2 ppg. VersaPro MOBM. Drill out plugs & Shoe Track to 7618'. Clean out rat hole to TO of 7628' Drill 20' of new hole to 7648'. PU = 154K, ON = 90K, ROT = 118K 250 GPM @ 2190 psi, 40 RPM, TQ = 5.5K CBU & Perform FIT to 11.7 ppg. EMW = 684 psi. surface pressure with 9.2 ppg. mud in hole. TVD = 5187'. Circulate & Rotate to take Clean Hole ECD Baseline readings. GPM SPM RPM Pres. ECD 290 117 0 2300 10.43 275 111 60 2550 10.38 290 117 80 2790 10.47 Directional drill 6 3/4" Hole from 7648' to 8750'. PU = 148K, ON = 79K, ROT = 109K ( Pump ON ) PU = 160K, ON = 82K, ROT = 113K (Pump OFF) TQ OFF Btm = 8.8K TQ ON Btm = 9K to 11K 290 GPM @ 2980 psi (ON) - 2870 psi (OFF) RPM = 60, WOB = 5 to 10 K ART = 2 Hrs., AST = 4.58 Hrs. Calc ECD = 10.46 ppg. Actual ECD = 10.72 ppg. Directional Dril6 3/4" Hole from 8750' to 9123'. Calculated ECD = 10.49 ppg. Actual ECD spiked to 11.18 ppg. Stopped Drilling. Circulated Bottoms Up & Dropped ECD to 10.69 ppg. Directional Drill 6 3/4" Hole from 9123' to 10670'. PU = 164K, ON = 66K, ROT = 11 OK ( Pump On) PU = 183K, ON = 71 K, ROT = 11 OK (Pump Off) TQ Off Btm = 1 0.8K, TQ on btm = 11.2K 290GPM @ 3260 psi. (ON), 3160 psi. (OFF) RPM = 60, WOB 3K to 10K AST = 2.74 Hrs. ART = 7.27 Hrs. Calculated ECD = 10.72 ppg. Actual ECD = 11.05 ppg Begin Circulation schedule to clean hole. Circulate Bottoms Up, Circulate HI Vis Sweep & Bottoms up again. Pumping @ 295 GPM, 3040 psi, 80 RPM, Recirocating pipe. Calculated ECD = 10.67 ppg, Final ECD = 10.78 ppg. POH to shoe recording Drag data. Pulled 10 to 15K over @ 10450', 9878', 9450', 9280', 8524', 8500' & 25 over from 8597' to 8555'. Wiped all ares one (1) time & they were clean. Service Top Drive, Blocks & Crown Drop ball & open Baker Circ sub inside 7 5/8" Shoe. CBU No cuttings to surface. Pump dry Job. POH -ADN tool 200' below floor. PJSM for removing source & UD BHA. POH Remove Source & LID BHA Clear & Clean Floor. R/U to run 41/2" Liner. PJSM with Crew & Svc. Hands on running slotted liner. RIH w/4 1/2", 12.6#, L-80 Slotted Liner as per Detail. Run @ 90 ft / min Total of 73 Jts Slotted & 3 Jts Solid. M/U Baker 5.5" X 7.625" HMC Liner Hanger & ZXP Liner Printed: 9/15/2003 9:49: 11 AM .... - Page 9 of 10 BP Operations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date 9/7/2003 9/8/2003 W-205 W-205 DRILL +COMPLETE NABORS ALASKA DRILLING I NABORS 9ES From - To Hours! Task Code NPT: Phase 17:30 - 18:00 0.50 CASE P COMP 18:00-21:30 3.50 CASE P COMP 21 :30 - 22:00 0.50 CASE P COMP 22:00 - 00:00 2.00 CASE P COMP 00:00 - 00:30 0.50 CASE P COMP 00:30 - 02:00 1.50 CASE P COMP 02:00 - 03:30 1.50 CASE P COMP 03:30 - 05:00 1.50 CASE P COMP 05:00 - 10:00 5.00 CASE P COMP 10:00 - 10:30 0.50 CASE P COMP 10:30 - 11 :00 0.50 CASE P COMP 11 :00 - 12:30 1.50 RUNCOMP COMP 12:30 - 13:00 0.50 RUNCOMP COMP 13:00 - 20:00 7.00 RUNCOMP COMP 20:00 - 21 :30 1.50 RUNCOMP COMP 21 :30 - 22:00 0.50 RUNCOMP COMP 22:00 - 23:30 1.50 RUNCOMP COMP 23:30 - 00:00 0.50 RUNCOMP COMP 9/9/2003 00:00 - 01 :30 1.50 RUNCOMP COMP 01 :30 - 02:00 0.50 RUNCOMP COMP 02:00 - 02:30 0.50 RUNCOMP COMP 02:30 - 04:00 1.50 BOPSUR. P COMP 04:00 - 08:00 4.00 WHSUR P COMP 08:00 - 08:30 0.50 WHSUR P COMP 08:30 - 11 :00 2.50 WHSUR P COMP Start: Rig Release: Rig Number: Spud Date: 8/23/2003 End: 9/9/2003 8/22/2003 9/9/2003 Description of Operations .--.---- Packer as per Baker Svc. Rep. RIH w/ Liner on 4" DP. to 7 5/8" Casing shoe. Circulate one DP volume @ 4 BPM & 500 psi. Run Liner into Open Hole @ 60 ft / Min. Take Up & Down weights every 10 Stands. Tag Bottom @ 10,670'. Drop setting Ball & Pump down @ 2 BPM - 460 psi. When Ball seats: Increase pressure to 2500 psi. to set Hanger. Slack off liner wt. + 20K to insure liner set. Rotate 20 turns to the right to put the rotating dog sub in position to se ZXP Packer. Pick up 8 ft to release dogs then slack off 60K to set ZXP. P/U 20 ft. to clear C-2 Tool from TBS. Guide Shoe @ 10,669' XN Nipple @ 7,626' (4.5" stock, cut fo 3.5 XN profile, 2.75" NO-GO) HMC Hanger @ 7,531' ZXP Packer @ 7,525' Top ofTieback @ 7,517' Establish circulation 100% Returns. Pump spacers & Displace MOBM Fluid with 9.2 ppg. Brine. Pumped @ 450 GPM & 2180 psi. Reciprocate pipe throughout job. P/U = 148K ON = 85K Monitor well after dispacement complete. Well Static. Clean out Trough and under Shakers, Trip Tank & Pill Pit. Service Top Drive & Blocks, Slip & Cut Drilling Line POH LID 4" Drill Pipe. Stand back HWDP. Make service breaks & LID packer running tool Clear & clean Floor. Pull wear bushing & Rig Up to run 4 1/2" Completion string PJSM on M/U & RIH with Completion Sting. M/U & RIH w/4 1/2" Completion string as per program. P/U Landing Jt, M/U Hanger. Tubel Pressure Guage Hand & FMC Hand M/U Clamp, accelerometer & thread control line through Hanger. Test through tubing connection to 5000 psi. Land Tubing Hanger. R.I.L.D.S. Reverse Circulate 269 Bbls. Clean 9.2 ppg. Brine, spotting 25 bbls, corrosion inhibited brine between Pkr & shear valve in annulus. Drop ball / rod assy. Back out & LID Landing Jt. Pressue Tubing to 4200 psi to set Packer. Hold for 10 minutes then bleed to 3500 psi & hold for 20 min. for tubing test. Bleed tubing to 2000 psi. pressure Annulus to 3500 psi and hold for 30 min. Test. Bleed annulus then tubing. Press annulus to 2800 psi to shear DCK. Baker Premium Packer set @ 6440' WLEG @ 6589' Install TWC. Test from below to 1000 psi. RID Tbg Equipment. C/O Bails. N/D Riser & BOPE. N/U Adapter Flange & Tree, test metal to metal seal to 5000 psi. Thread & Check Tubel acoustic cable. RU lubricator and pull TWC with DSM RU Little Red. Reverse in 107 bbls diesel at 3 BPM, 2200 psi shut-in pressure to freeze protect. Allow diesel to U-tube. Printed: 9/15/2003 9:49: 11 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: . . BP Operations Summary Report W-205 W-205 DRILL +COMPLETE NABORS ALASKA DRILLING I NABORS 9ES From - To' Hours Task! Code Date 9/9/2003 11:00-12:00 1.00 WHSUR P Start: 8/22/2003 Rig Release: 9/9/2003 Rig Number: I NPT! Phase Page 10 of 10 Spud Date: 8/23/2003 End: 9/9/2003 Description of Operations Rig Released @ 12:00 COMP Install BPV and test from below to 1000 psi. __ _.__nu_ Printed: 9/15/2003 9:49: 11 AM SCHLUMBERGER Survey report Client... .... ........ ....: BP Exploration (Alaska) Inc. Field. . . . . . . . . . . . . . . . . . . .: polaris Well. . . . . . . . . . . . . . . . . . . . .: W-205 API number..... .... ......: 50-029-23165-00 Engineer. ......... .., ....: M. St. Amour RIG:.. ............ ... ....: Nabors 9ES STATE: . . . . . . . . . . . . . . . . . . .: Alaska ----- Survey calculation methods------------- Method for positions.....: Minimum curvature Method for DLS... ... .....: Mason & Taylor ----- Depth reference ----------------------- Permanent datum.... ......: Mean Sea Level Depth reference.... ......: Drill Floor GL above permanent. ......: 52.40 ft KB above permanent.......: N/A (Top Drive) DF above permanent.... ...: 80.90 ft ----- Vertical section origin---------------- Latitude (+N/S-)..... ....: 0.00 ft Departure (+E/W-) ... .....: 0.00 ft ----- Platform reference point---~----------- Latitude (+N/S-) .... .....: -999.25 ft Departure (+E/W-)...... ..: -999.25 ft Azimuth from rotary table to target: 0.00 degrees [(C)~003 IDEAL ID8_1C_01] oJ.) '? ~ 'f.. 7-Sep-2003 04:40:06 Spud date.......... ......: Last survey date. ........: Total accepted surveys...: MD of first survey.......: MD of last survey........: Page 1 of 7 23-Aug-03 07-Sep-03 179 0.00 ft 10670.00 ft . ----- Geomagnetic data ---------------------- Magnetic model. ..........: BGGM version 2002 Magnetic date......... ...: 22-Aug-2003 Magnetic field strength..: 1150.53 HCNT Magnetic dec (+E/W-) .....: 25.54 degrees Magnetic dip..... ........: 80.78 degrees ----- MWD survey Reference Reference G..............: Reference H.... ..........: Reference Dip..... .... ...: Tolerance of G. ..........: Tolerance of H. ..........: Tolerance of Dip.........: Criteria --------- 1002.68 mGal 1150.53 HCNT 80.78 degrees (+/-) 2.50 mGal (+/-) 6.00 HCNT (+/-) 0.45 degrees . ----- Corrections --------------------------- Magnetic dec (+E/W-) .....: 25.54 degrees Grid convergence (+E/W-).: 0.00 degrees Total az corr (+E/W-).. ..: 25.54 degrees (Total az corr = magnetic dec - grid conv) Survey Correction Type ...: I=Sag Corrected Inclination M=Schlumberger Magnetic Correction S=Shell Magnetic Correction F=Failed Axis Correction R=Magnetic Resonance Tool Correction D=Dmag Magnetic Correction SCHLUMBERGER Survey Report 7-Sep-2003 04:40:06 Page 2 of 7 -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ Seq Measured Incl Azimuth Course TVD Vertical Displ Displ Total At DLS Srvy Tool # depth angle angle length depth section +N/S- +E/W- displ Azim (deg/ tool Corr (ft) (deg) (deg) (ft) (ft) (ft) (ft) (ft) (ft) (deg) 100f) type (deg) -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ 1 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 TIP None 2 138.20 0.07 88.07 138.20 138.20 0.00 0.00 0.08 0.08 88.07 0.05 MWD IFR MSA 3 239.52 0.61 54.75 101.32 239.52 0.32 0.32 0.59 0.67 61. 68 0.55 MWD IFR MSA 4 300.39 2.25 63.08 60.87 300.37 1. 04 1. 04 1. 92 2.18 61. 42 2.71 MWD IFR MSA 5 390.94 5.17 82.77 90.55 390.72 2.36 2.36 7.55 7.91 72.62 3.47 MWD IFR MSA 6 483.11 6.93 92.96 92.17 482.38 2.60 2.60 17.22 17.42 81. 42 2.23 MWD IFR MSA - 7 576.06 8.31 96.29 92.95 574.50 1. 57 1.57 29.50 29.54 86.95 1.56 MWD IFR MSA . - 8 671. 50 10.95 97.11 95.44 668.59 -0.31 -0.31 45.35 45.36 90.39 2.77 MWD IFR MSA - 9 765.37 13.56 93.83 93.87 760.31 -2.14 -2.14 65.19 65.22 91. 88 2.88 MWD IFR MSA 10 859.95 15.67 90.40 94.58 851. 83 -2.97 -2.97 89.02 89.07 91.91 2.41 MWD IFR MSA 11 954.66 18.74 90.44 94.71 942.29 -3.18 -3.18 117.03 117.08 91.56 3.24 MWD IFR MSA 12 1050.16 23.91 88.55 95.50 1031.22 -2.81 -2.81 151. 75 151.77 91.06 5.46 MWD IFR MSA 13 1144.14 27.46 91.14 93.98 1115.91 -2.76 -2.76 192.46 192.48 90.82 3.96 MWD IFR MSA 14 1238.39 29.92 90.46 94.25 1198.58 -3.38 -3.38 237.70 237.73 90.81 2.63 MWD IFR MSA 15 1333.55 33.56 88.26 95.16 1279.50 -2.77 -2.77 287.74 287.76 90.55 4.01 MWD IFR MSA 16 1427.00 38.84 92 .23 93.45 1354.89 -3.13 -3.13 342.89 342.90 90.52 6.18 MWD IFR MSA 17 1521. 98 43.73 92.85 94.98 1426.24 -5.92 -5.92 405.47 405.52 90.84 5.17 MWD IFR MSA 18 1616.01 45.76 92.04 94.03 1493.02 -8.73 -8.73 471.60 471.68 91.06 2.24 MWD IFR MSA 19 1709.89 45.49 93.10 93.88 1558.68 -11. 74 -11. 74 538.64 538.76 91. 25 0.86 MWD IFR MSA 20 1803.35 44.15 92.96 93.46 1624.97 -15.22 -15.22 604.42 604.61 91. 44 1.44 MWD IFR MSA 21 1898.67 42.83 93.34 95.32 1694.12 -18.83 -18.83 669.92 670.19 91. 61 1.41 MWD IFR MSA . - 22 1992.58 42.02 93.80 93.91 1763.44 -22.77 -22.77 733.15 733.51 91. 78 0.92 MWD IFR MSA - 23 2087.21 41. 64 93.69 94.63 1833.96 -26.89 -26.89 796.13 796.58 91.93 0.41 MWD IFR MSA - 24 2182.02 42.33 93.42 94.81 1904.43 -30.82 -30.82 859.43 859.98 92.05 0.75 MWD IFR MSA - 25 2276.41 41. 86 93.01 94.39 1974.47 -34.37 -34.37 922.60 923.24 92.13 0.58 MWD IFR MSA 26 2371.24 43.94 92.92 94.83 2043.93 -37.71 -37.71 987.07 987.79 92.19 2.19 MWD IFR MSA - 27 2465.72 44.80 90.69 94.48 2111. 47 -39.78 -39.78 1053.09 1053.84 92.16 1. 88 MWD IFR MSA - 28 2560.07 44.84 89.82 94.35 2178.40 -40.08 -40.08 1119.60 1120.31 92.05 0.65 MWD IFR MSA 29 2654.53 44.98 90.34 94.46 2245.30 -40.17 -40.17 1186.28 1186.96 91. 94 0.42 MWD IFR MSA 30 2750.20 44.95 90.82 95.67 2312.99 -40.86 -40.86 1253.89 1254.55 91. 87 0.36 MWD IFR MSA [(c)2003 IDEAL ID8_1C_01] SCHLCMBERGER Survey Report 7-Sep-2003 04:40:06 Page 3 of 7 -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ Seq Measured Incl Azimuth Course TVD Vertical Displ Displ Total At DLS Srvy Tool # depth angle angle length depth section +N/S- +E/W- displ Azim (deg/ tool Corr (ft) (deg) (deg) (ft) (ft) (ft) (ft) (ft) (ft) (deg) 100f) type (deg) --- ! -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ --- I -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ 31 2845.05 44.48 90.47 94.85 2380.39 -41. 61 -41. 61 1320.62 1321.27 91. 80 0.56 MWD IFR MSA 32 2940.21 44.54 87.54 95.16 2448.26 -40.45 -40.45 1387.30 1387.89 91. 67 2.16 MWD IFR MSA - 33 3034.42 44.39 87.64 94.21 2515.49 -37.67 -37.67 1453.24 1453.73 91. 49 0.18 MWD IFR MSA 34 3129.22 44.11 87.91 94.80 2583.40 -35.11 -35.11 1519.34 1519.74 91. 32 0.36 MWD IFR MSA - 35 3221. 57 44.52 88.27 92.35 2649.48 -32.96 -32.96 1583.82 1584.16 91.19 0.52 MWD IFR MSA 36 3315.03 44.46 88.48 93.46 2716.15 -31.10 -31.10 1649.29 1649.58 91. 08 0.17 MWD IFR MSA - 37 3409.53 44.42 88.46 94.50 2783.62 -29.33 -29.33 1715.43 1715.68 90.98 0.04 MWD IFR MSA . - 38 3504.53 44.80 88.89 95.00 2851.25 -27.79 -27.79 1782.13 1782.34 90.89 0.51 MWD IFR MSA - 39 3598.91 45.06 89.18 94.38 2918.07 -26.67 -26.67 1848.77 1848.96 90.83 0.35 MWD IFR MSA - 40 3694.74 46.75 88.01 95.83 2984.75 -24.97 -24.97 1917.57 1917.73 90.75 1.97 MWD IFR MSA 41 3788.33 46.72 88.07 93.59 3048.90 -22.64 -22.64 1985.68 1985.81 90.65 0.06 MWD IFR MSA 42 3882.04 48.58 88.49 93.71 3112.02 -20.56 -20.56 2054.90 2055.01 90.57 2.01 MWD IFR MSA 43 3935.59 49.24 88.61 53.55 3147.22 -19.54 -19.54 2095.25 2095.34 90.53 1.24 MWD IFR MSA 44 4029.51 47.87 88.73 93.92 3209.38 -17.91 -17.91 2165.63 2165.70 90.47 1.46 MWD IFR MSA - 45 4125.83 47.53 88.86 96.32 3274.21 -16.41 -16.41 2236.86 2236.92 90.42 0.37 MWD IFR MSA - 46 4219.70 47.06 88.57 93.87 3337.87 -14.86 -14.86 2305.82 2305.87 90.37 0.55 MWD IFR MSA 47 4313.18 47.50 90.07 93.48 3401. 29 -14.05 -14.05 2374.49 2374.53 90.34 1.27 MWD IFR MSA 48 4408.39 49.25 90.60 95.21 3464.53 -14.47 -14.47 2445.65 2445.70 90.34 1. 88 MWD IFR MSA 49 4502.06 49.19 90.52 93.67 3525.71 -15.17 -15.17 2516.58 2516.62 90.35 0.09 MWD IFR MSA 50 4596.92 48.95 90.38 94.86 3587.86 -15.73 -15.73 2588.24 2588.29 90.35 0.28 MWD IFR MSA 51 4692.21 48.79 90.24 95.29 3650.54 -16.12 -16.12 2660.02 2660.07 90.35 0.20 MWD IFR MSA . 52 4786.94 48.40 89.75 94.73 3713.19 -16.11 -16.11 2731.07 2731.12 90.34 0.57 MWD IFR MSA 53 4881. 27 47.90 89.49 94.33 3776.13 -15.65 -15.65 2801.33 2801.38 90.32 0.57 MWD IFR MSA 54 4976.33 47.54 89.45 95.06 3840.08 -15.00 -15.00 2871.66 2871.70 90.30 0.38 MWD IFR MSA - 55 5070.70 47.15 89.05 94.37 3904.02 -14.09 -14.09 2941. 06 2941.09 90.27 0.52 MWD IFR MSA 56 5164.92 46.92 88.98 94.22 3968.24 -12.90 -12.90 3010.00 3010.02 90.25 0.25 MWD IFR MSA - 57 5260.11 47.44 91.19 95.19 4032.94 -13.01 -13.01 3079.81 3079.84 90.24 1. 79 MWD IFR MSA - 58 5353.62 47.09 90.56 93.51 4096.40 -14.06 -14.06 3148.48 3148.52 90.26 0.62 MWD IFR MSA 59 5448.04 46.84 90.99 94.42 4160.84 -15.00 -15.00 3217.49 3217.53 90.27 0.43 MWD IFR MSA - 60 5542.45 47.35 93.52 94.41 4225.11 -17.72 -17.72 3286.58 3286.63 90.31 2.04 MWD IFR MSA [(c)2003 IDEAL ID8_1C_01J SCHLUMBERGER Survey Report 7-Sep-2003 04:40:06 Page 4 of 7 -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ Seq Measured Incl Azimuth Course TVD Vertical Displ Displ Total At DLS Srvy Tool # depth angle angle length depth section +N/S- +E/W- displ Azim (deg/ tool Corr (ft) (deg) (deg) (ft) (ft) (ft) (ft) (ft) (ft) (deg) 100f) type (deg) -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ 61 5637.51 48.32 97.51 95.06 4288.94 -24.51 -24.51 3356.68 3356.77 90.42 3.27 MWD IFR MSA 62 5730.86 48.49 102.79 93.35 4350.93 -36.81 -36.81 3425.36 3425.56 90.62 4.23 MWD IFR MSA 63 5827.15 48.36 104.32 96 .29 4414.83 -53.69 -53.69 3495.38 3495.79 90.88 1.20 MWD IFR MSA 64 5922.20 47.21 99.09 95.05 4478.72 -67.99 -67.99 3564.26 3564.91 91. 09 4.25 MWD IFR MSA 65 6018.20 47.43 95.71 96.00 4543.81 -77.07 -77.07 3634.23 3635.05 91. 21 2.60 MWD IFR MSA 66 6113.56 49.51 92.20 95.36 4607.04 -81. 96 -81. 96 3705.42 3706.33 91. 27 3.51 MWD IFR MSA 67 6207.77 51. 06 88.79 94.21 4667.25 -82.56 -82.56 3777.87 3778.77 91. 25 3.23 MWD IFR MSA . 68 6301.13 54.14 83.06 93.36 4723.98 -77 . 22 -77.22 3851. 78 3852.55 91. 15 5.89 MWD IFR MSA 69 6393.40 55.11 76.89 92.27 4777.43 -64.11 -64.11 3925.80 3926.33 90.94 5.55 MWD IFR MSA 70 6486.61 56.60 71.66 93.21 4829.77 -43.19 -43.19 4000.00 4000.24 90.62 4.91 MWD IFR MSA 71 6582.21 60.06 67.40 95.60 4879.97 -14.69 -14.69 4076.17 4076.20 90.21 5.24 MWD IFR MSA 72 6676.53 63.26 62.27 94.32 4924.76 20.64 20.64 4151. 24 4151. 29 89.72 5.87 MWD IFR MSA 73 6771.35 64.85 57.71 94.82 4966.26 63.28 63.28 4225.03 4225.51 89.14 4.64 MWD IFR MSA - 74 i 6865.05 65.91 55.97 93.70 5005.30 109.88 109.88 4296.33 4297.74 88.54 2.03 MWD IFR MSA - 75 6958.08 68.13 53.24 93.03 5041. 62 159.49 159.49 4366.13 4369.04 87.91 3.60 MWD IFR MSA 76 7052.54 70.37 52.60 94.46 5075.09 212.75 212.75 4436.59 4441.69 87.25 2.45 MWD IFR MSA 77 7147.59 73.28 51. 97 95.05 5104.73 267.99 267.99 4508.02 4515.98 86.60 3.13 MWD IFR MSA 78 7242.26 75.87 52.57 94.67 5129.91 323.83 323.83 4580.19 4591.63 85.96 2.80 MWD IFR MSA 79 7336.39 78.82 51.14 94.13 5150.53 380.55 380.55 4652.41 4667.95 85.32 3.47 MWD IFR MSA - 80 7431. 87 82.15 49.46 95.48 5166.31 440.70 440.70 4724.84 4745.35 84.67 3.90 MWD IFR MSA 81 7525.55 85.19 46.56 93.68 5176.64 502.98 502.98 4794.03 4820.34 84.01 4.47 MWD IFR MSA 82 7552.29 85.08 45.37 26.74 5178.91 521. 50 521. 50 4813.18 4841.35 83.82 4.45 MWD IFR MSA . - 83 7670.42 86.46 39.51 118.13 5187.63 608.40 608.40 4892.64 4930.32 82.91 5.08 MWD IFR MSA 84 7702.70 86.63 35.08 32.28 5189.58 634.03 634.03 4912.16 4952.91 82.65 13.71 MWD IFR MSA - 85 7733.37 85.63 31. 99 30.67 5191.65 659.53 659.53 4929.06 4972.99 82.38 10.57 MWD IFR MSA 86 7763.82 86.05 30.25 30.45 5193.86 685.53 685.53 4944.76 4992.05 82.11 5.86 MWD IFR MSA - 87 7795.20 86.74 29.99 31.38 5195.83 712.62 712.62 4960.47 5011.40 81. 82 2.35 MWD IFR MSA 88 7826.99 87.63 30.61 31. 79 5197.39 740.03 740.03 4976.49 5031. 22 81. 54 3.41 MWD IFR MSA - 89 7857.53 87.80 30.09 30.54 5198.61 766.37 766.37 4991. 91 5050.40 81. 27 1. 79 MWD IFR MSA - 90 7888.69 88.21 30.16 31.16 5199.70 793.30 793.30 5007.54 5069.99 81. 00 1. 33 MWD IFR MSA [(c)2003 IDEAL ID8_1C_Ol] SCHLUMBERGER Survey Report 7-Sep-2003 04:40:06 Page 5 of 7 -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ Seq Measured Incl Azimuth Course TVD Vertical Displ Displ Total At DLS Srvy Tool # depth angle angle length depth section +N/S- +E/W- disp1 Azim (deg/ tool Corr (ft) (deg) (deg) (ft) (ft) (ft) (ft) (ft) (ft) (deg) 100f) type (deg) -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ 91 7923.54 90.10 33.25 34.85 5200.21 822.94 822.94 5025.85 5092.78 80.70 10.39 MWD IFR MSA 92 7951.68 89.10 31. 98 28.14 5200.41 846.64 846.64 5041.02 5111.62 80.47 5.74 MWD IFR MSA 93 7983.00 85.57 31.01 31. 32 5201.86 873.32 873.32 5057.36 5132.21 80.20 11.69 MWD IFR MSA 94 8014.05 85.49 29.01 31. 05 5204.28 900.12 900.12 5072 . 84 5152.08 79.94 6.43 MWD IFR MSA 95 8045.36 87.76 28.14 31. 31 5206.13 927.57 927.57 5087.79 5171.65 79.67 7.76 MWD IFR MSA 96 8076.23 86.94 27.38 30.87 5207.55 954.85 954.85 5102.15 5190.73 79.40 3.62 MWD IFR MSA 97 8107.22 87.08 27.25 30.99 5209.17 982.35 982.35 5116.35 5209.81 79.13 0.62 MWD IFR MSA . 98 8138.93 88.14 26.56 31. 71 5210.49 1010.60 1010.60 5130.69 5229.27 78.86 3.99 MWD IFR MSA 99 8169.71 90.34 23.07 30.78 5210.90 1038.53 1038.53 5143.60 5247.40 78.59 13.40 MWD IFR MSA 100 8201. 08 91.92 19.80 31. 37 5210.28 1067.72 1067.72 5155.06 5264.48 78.30 11. 57 MWD IFR MSA 101 8232.18 91.47 17.68 31.10 5209.36 1097.16 1097.16 5165.05 5280.29 78.01 6.97 MWD IFR MSA 102 8263.11 88.69 16.02 30.93 5209.32 1126.76 1126.76 5174.02 5295.28 77.71 10.47 MWD I FR MSA 103 8294.78 87.32 15.99 31. 67 5210.42 1157.18 1157.18 5182.74 5310.36 77 .41 4.33 MWD IFR MSA 104 8325.89 86.32 13 .18 31.11 5212.15 1187.24 1187.24 5190.56 5324.61 77 .12 9.57 MWD IFR MSA 105 8356.08 87.42 10.30 30.19 5213.80 1216.75 1216.75 5196.70 5337.24 76.82 10.20 MWD IFR MSA 106 8387.54 91.20 9.03 31. 46 5214.18 1247.75 1247.75 5201. 98 5349.53 76.51 12.67 MWD IFR MSA - 107 8418.44 94.15 6.96 30.90 5212.73 1278.32 1278.31 5206.27 5360.91 76.20 11.66 MWD IFR MSA - 108 8449.96 93.53 4.40 31. 52 5210.62 1309.61 1309.61 5209.38 5371.47 75.89 8.34 MWD IFR MSA 109 8480.78 91. 61 0.97 30.82 5209.24 1340.36 1340.36 5210.82 5380.45 75.57 12.74 MWD IFR MSA - 110 8512.15 90.96 359.14 31. 37 5208.54 1371.72 1371.72 5210.85 5388.38 75.25 6.19 MWD IFR MSA 111 8543.14 91.13 359.25 30.99 5207.97 1402.70 1402.70 5210.42 5395.93 74.93 0.65 MWD IFR MSA - . 112 8574.67 90.92 358.89 31. 53 5207.41 1434.22 1434.22 5209.91 5403.71 74.61 1.32 MWD IFR MSA - 113 8605.16 91. 20 357.80 30.49 5206.84 1464.69 1464.69 5209.03 5411. 03 74.29 3.69 MWD IFR MSA - 114 8634.83 91. 26 357.58 29.67 5206.21 1494.33 1494.33 5207.83 5417.98 73.99 0.77 MWD IFR MSA - 115 8666.51 90.89 356.93 31. 68 5205.61 1525.97 1525.97 5206.31 5425.34 73.66 2.36 MWD IFR MSA 116 8698.09 90.41 354.38 31. 58 5205.25 1557.45 1557.45 5203.92 5431. 98 73.34 8.22 MWD IFR MSA 117 8729.07 90.85 352.12 30.98 5204.91 1588.21 1588.21 5200.28 5437.40 73.02 7.43 MWD IFR MSA 118 8760.36 90.58 349.70 31. 29 5204.52 1619.11 1619.11 5195.34 5441. 79 72 .69 7.78 MWD IFR MSA - 119 8790.85 88.25 347.49 30.49 5204.83 1648.99 1648.99 5189.31 5445.01 72 .37 10.53 MWD IFR MSA 120 8821.07 87.15 346.00 30.22 5206.05 1678.38 1678.38 5182.39 5447.39 72 .05 6.13 MWD IFR MSA [(c)2003 IDEAL ID8_1C_01J SCHLUYIBERGER Survey Report 7-Sep-2003 04:40:06 Page 6 of 7 -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ Seq Measured Incl Azimuth Course TVD Vertical Displ Displ Total At DLS Srvy Tool # depth angle angle length depth section +N/S- +E/W- displ Azim (deg/ tool Corr (ft) (deg) (deg) (ft) (ft) (ft) (ft) (ft) (ft) (deg) 100f) type (deg) -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ 121 8853.69 86.87 344.26 32.62 5207.75 1709.86 1709.86 5174.03 5449.24 71.71 5.40 MWD IFR MSA - 122 8884.74 87.66 345.47 31.05 5209.23 1739.80 1739.80 5165.93 5451. 03 71.39 4.65 MWD IFR MSA - 123 8916.61 88.18 345.46 31.87 5210.39 1770.63 1770.63 5157.94 5453.39 71. 05 1. 63 MWD IFR MSA 124 8946.32 88.42 345.09 29.71 5211.27 1799.35 1799.35 5150.39 5455.65 70.74 1.48 MWD IFR MSA 125 8977.51 86.46 346.14 31.19 5212.66 1829.53 1829.53 5142.65 5458.39 70.42 7.13 MWD IFR MSA 126 9009.20 86.32 345.56 31. 69 5214.66 1860.20 1860.20 5134.92 5461. 47 70.09 1. 88 MWD IFR MSA - 127 9040.39 86.56 346.02 31.19 5216.59 1890.37 1890.37 5127.27 5464.65 69.76 1.66 MWD IFR MSA . - 128 9071. 04 86.63 345.24 30.65 5218.41 1920.01 1920.01 5119.68 5467.87 69.44 2.55 MWD IFR MSA - 129 9101. 90 86.77 346.08 30.86 5220.19 1949.86 1949.86 5112.05 5471.29 69.12 2.75 MWD IFR MSA - 130 9133.94 87.87 346.40 32.04 5221. 69 1980.95 1980.95 5104.44 5475.35 68.79 3.58 MWD IFR MSA 131 9165.69 88.32 347.25 31. 75 5222.74 2011.84 2011.85 5097.21 5479.87 68.46 3.03 MWD IFR MSA - 132 9196.42 86.74 346.90 30.73 5224.07 2041.77 2041. 77 5090.34 5484.56 68.14 5.27 MWD IFR MSA - 133 9227.68 86.80 347.23 31. 26 5225.83 2072 .19 2072 .19 5083.35 5489.48 67.82 1. 07 MWD IFR MSA 134 9258.01 86.94 346.78 30.33 5227.49 2101.69 2101.69 5076.54 5494.40 67.51 1. 55 MWD IFR MSA 135 9288.59 87.32 347.39 30.58 5229.02 2131. 46 2131.46 5069.72 5499.56 67.20 2.35 MWD IFR MSA 136 9320.56 87.29 347.92 31.97 5230.52 2162.66 2162.66 5062.89 5505.45 66.87 1. 66 MWD IFR MSA 137 9352.13 87.18 347.74 31. 57 5232.04 2193.48 2193.48 5056.24 5511. 53 66.55 0.67 MWD IFR MSA 138 9383.17 87.08 347.85 31. 04 5233.60 2223.78 2223.78 5049.69 5517.66 66.23 0.48 MWD IFR MSA 139 9413.39 87.08 347.42 30.22 5235.14 2253.26 2253.26 5043.22 5523.70 65.93 1.42 MWD IFR MSA - 140 9445.42 87.04 347.04 32.03 5236.78 2284.46 2284.46 5036.15 5530.06 65.60 1.19 MWD IFR MSA 141 9476 .11 87.15 347.48 30.69 5238.33 2314.36 2314.36 5029.39 5536.34 65.29 1.48 MWD IFR MSA 142 9507.64 87.19 347.19 31. 53 5239.89 2345.08 2345.08 5022.49 5543.00 64.97 0.93 MWD IFR MSA . - 143 9539.08 87.15 347.67 31. 44 5241.44 2375.73 2375.73 5015.66 5549.86 64.65 1. 53 MWD IFR MSA - 144 9570.06 87.42 348.35 30.98 5242.91 2406.00 2406.00 5009.23 5557.09 64.34 2.36 MWD IFR MSA - 145 9604.68 87.56 348.52 34.62 5244.43 2439.89 2439.89 5002.29 5565.61 64.00 0.64 MWD IFR MSA 146 9632.72 87.83 347.06 28.04 5245.56 2467.27 2467.27 4996.37 5572.35 63.72 5.29 MWD IFR MSA 147 9663.41 88.59 344.39 30.69 5246.51 2496.99 2496.99 4988.80 5578.81 63.41 9.04 MWD IFR MSA - 148 9694.34 90.20 344.02 30.93 5246.84 2526.75 2526.75 4980.39 5584.69 63.10 5.34 MWD IFR MSA 149 9725.79 92.40 343.02 31. 45 5246.13 2556.90 2556.90 4971.47 5590.46 62.78 7.68 MWD IFR MSA 150 9756.95 92.50 340.61 31. 16 5244.80 2586.48 2586.48 4961. 75 5595.43 62.47 7.73 MWD IFR MSA [(c)2003 IDEAL ID8_1C_01] . SCHL~BERGER Survey Report 7-Sep-2003 04:40:06 Page 7 of 7 I I -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ Seq Measured Incl Azimuth Course TVD Vertical Displ Displ Total At DLS Srvy Tool # depth angle angle length depth section +N/S- +E/W- displ Azim (deg/ tool Corr (ft) (deg) (deg) (ft) (ft) (ft) (ft) (ft) (ft) (deg) 100f) type (deg) -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ 151 9787.94 92.09 339.89 30.99 5243.55 2615.62 2615.62 4951.29 5599.71 62.15 2.67 MWD IFR MSA 152 9819.42 91.13 338.21 31. 48 5242.67 2645.01 2645.00 4940.04 5603.57 61.83 6.14 MWD IFR MSA 153 9850.58 90.72 336.05 31.16 5242.17 2673.71 2673.71 4927.93 5606.53 61. 52 7.05 MWD IFR MSA - 154 9881.18 91. 02 336.51 30.60 5241. 70 2701. 72 2701.72 4915.62 5609.16 61.21 1. 79 MWD IFR MSA 155 9912.90 91. 57 338.05 31. 72 5240.99 2730.97 2730.97 4903.38 5612.60 60.88 5.15 MWD IFR MSA 156 9944.22 91. 81 337.85 31. 32 5240.06 2759.99 2759.99 4891. 62 5616.54 60.57 1. 00 MWD IFR MSA 157 9975.54 90.41 338.25 31. 32 5239.45 2789.03 2789.03 4879.92 5620.70 60.25 4.65 MWD IFR MSA . - 158 10006.39 89.82 338.20 30.85 5239.39 2817.68 2817.68 4868.47 5625.06 59.94 1. 92 MWD IFR MSA 159 10037.84 89.89 338.57 31.45 5239.47 2846.92 2846.92 4856.89 5629.77 59.62 1.20 MWD IFR MSA - 160 10068.74 89.86 337.74 30.90 5239.54 2875.60 2875.60 4845.39 5634.44 59.31 2.69 MWD IFR MSA 161 10100.40 90.03 337.38 31. 66 5239.57 2904.86 2904.86 4833.31 5639.07 58.99 1.26 MWD IFR MSA 162 10130.85 90.17 337.93 30.45 5239.52 2933.02 2933.02 4821. 73 5643.73 58.69 1. 86 MWD IFR MSA 163 10162.47 90.06 337.10 31. 62 5239.45 2962.24 2962.24 4809.64 5648.67 58.37 2.65 MWD IFR MSA - 164 10193.82 90.34 337.89 31. 35 5239.34 2991. 20 2991. 20 4797.64 5653.73 58.06 2.67 MWD IFR MSA - 165 10224.81 90.51 337.91 30.99 5239.11 3019.91 3019.92 4785.98 5659.11 57.75 0.55 MWD IFR MSA 166 , 10256.17 90.51 337.86 31. 36 5238.83 3048.97 3048.97 4774.17 5664.71 57.44 0.16 MWD IFR MSA 167 I - 10287.87 90.65 337.81 31. 70 5238.51 3078.32 3078.32 4762.21 5670.52 57.12 0.47 MWD IFR MSA 168 10319.07 90.78 336.61 31. 20 5238.12 3107.08 3107.08 4750.13 5676.06 56.81 3.87 MWD IFR MSA 169 10350.29 91.30 337.87 31. 22 5237.56 3135.87 3135.87 4738.05 5681. 80 56.50 4.37 MWD IFR MSA - 170 10381.13 91.95 338.42 30.84 5236.68 3164.48 3164.48 4726.58 5688.10 56.20 2.76 MWD IFR MSA 171 10412.55 92.88 338.38 31. 42 5235.36 3193.67 3193.67 4715.02 5694.82 55.89 2.96 MWD IFR MSA 172 10443.98 92.02 339.17 31. 43 5234.02 3222.94 3222.94 4703.65 5701.90 55.58 3.71 MWD I FR MSA . 173 10474.69 90.30 339.30 30.71 5233.39 3251.65 3251. 65 4692.77 5709.23 55.28 5.62 MWD IFR MSA - 174 10505.76 90.13 338.98 31. 07 5233.28 3280.68 3280.68 4681.71 5716.75 54.98 1.17 MWD IFR MSA - 175 10537.74 90.03 338.09 31. 98 5233.23 3310.44 3310.44 4670.00 5724.33 54.67 2.80 MWD IFR MSA 176 10568.62 91. 64 338.68 30.88 5232.78 3339.15 3339.15 4658.63 5731. 73 54.37 5.55 MWD IFR MSA 177 10598.92 95.43 339.10 30.30 5230.92 3367.35 3367.35 4647.74 5739.38 54.08 12.58 MWD IFR MSA - 178 10619.86 95.98 339.77 20.94 5228.83 3386.86 3386.86 4640.42 5744.94 53.88 4.13 MWD IFR MSA 179 10670.00 95.98 339.77 50.14 5223.61 3433.65 3433.65 4623.18 5758.79 53.40 0.00 Projected to TD [(c)2003 IDEAL ID8_1C_01J W-205 Survey Report Schlu beruer Report Date: 7-Sep-03 Survey 1 DLS Computation Method: Minimum Curvature 1 Lubinski Client: BP Exploration Alaska Vertical Section Azimuth: 53.400' Field: Prudhoe Bay Unit - WOA Vertical Section Origin: N 0.000 ft, E 0.000 fI Structure 1 Slot: W-PAD 1 W-205 TVD Reference Datum: KB Well: W-205 TVD Reference Elevation: 80.90 fI relative to MSL Borehole: W-205 Sea Bed 1 Ground Level Elevation: 52.40 fI relative to MSL UWVAPI#: 500292316500 Magnetic Declination: 25.336' Survey Name 1 Date: W-2051 September 7, 2003 Total Field Strength: 57551.736 nT Tort 1 AHD 1 DDII ERD ratio: 300.849' 18123.08 fl/6.696/1.548 Magnetic Dip: 80.805' Grid Coordinate System: NAD27 Alaska State Planes, Zone 04, US Feel Declination Date: September 18, 2003 Location LatILong: N 70.29605863, W 149.09267577 Magnetic Declination Model: BGGM 2003 . Location Grid NIE YIX: N 5958680.130 flUS, E 612048.970 ftUS North Reference: True North Grid Convergence Angle: +0.85420613' Total Corr Mag North -> True North: +25.336' Grid Scale Factor: 0.99991426 Local Coordinates Referenced To: Well Head Comments Measured I Inclination I Azimuth I Course TVD I Sub-Sea TVD I Vertical I NS EW Closure I Closure I DLS I Northing Easting Latitude Longitude Depth Length Section Azimuth (II) (deg) ( deg) (II) (II) (II) (II) (II) (II) (II) ( deg) (deg/100 II) (IIUS) (IIUS) 0.00 0.00 0.00 0.00 0.00 -80.90 0.00 0.00 0.00 0.00 0.00 0.00 5958680.13 612048.97 N 70.29605863 W 149.09267577 138.20 0.07 88.07 138.20 138.20 57.30 0.07 0.00 0.08 0.08 88.07 0.05 5958680.13 612049.05 N 70.29605864 W 149.09267509 239.52 0.61 54.75 101.32 239.52 158.62 0.66 0.32 0.59 0.67 61.68 0.55 5958680.45 612049.55 N 70.29605949 W 149.09267102 300.39 2.25 63.08 60.87 300.37 219.47 2.16 1.04 1.92 2.18 61.42 2.71 5958681.20 612050.87 N 70.29606148 W 149.09266025 390.94 5.17 82.77 90.55 390.72 309.82 7.47 2.36 7.55 7.91 72.62 3.47 5958682.60 612056.48 N 70.29606508 W 149.09261464 483.11 6.93 92.96 92.17 482.38 401.48 15.38 2.60 17.22 17.42 81.42 2.23 5958682.98 612066.15 N 70.29606573 W 149.09253631 576.06 8.31 96.29 92.95 574.50 493.60 24.62 1.57 29.50 29.54 86.95 1.56 5958682.14 612078.44 N 70.29606292 W 149.09243691 671.50 10.95 97.11 95.44 668.59 587.69 36.23 -0.31 45.35 45.36 90.39 2.77 5958680.50 612094.32 N 70.29605779 W 149.09230856 765.37 13.56 93.83 93.87 760.31 679.41 51.05 -2.14 65.19 65.22 91.88 2.88 5958678.96 612114.17 N 70.29605277 W 149.09214800 859.95 15.67 90.40 94.58 851.83 770.93 69.70 -2.97 89.02 89.07 91.91 2.41 5958678.48 612138.02 N 70.29605050 W 149.09195499 954.66 18.74 90.44 94.71 942.29 861.39 92.06 -3.18 117.03 117.08 91.56 3.24 5958678.70 612166.03 N 70.29604994 W 149.09172821 1050.16 23.91 88.55 95.50 1031.22 950.32 120.15 -2.81 151.75 151.77 91.06 5.46 5958679.58 612200.73 N 70.29605095 W 149.09144717 1144.14 27.46 91.14 93.98 1115.91 1035.01 152.87 -2.76 192.46 192.48 90.82 3.96 5958680.24 612241.44 N 70.29605109 W14.1750 1238.39 29.92 90.46 94.25 1198.58 1117.68 188.82 -3.38 237.70 237.73 90.81 2.63 5958680.30 612286.67 N 70.29604939 W 14 5123 1333.55 33.56 88.26 95.16 1279.50 1198.60 229.35 -2.77 287.74 287.76 90.55 4.01 5958681.65 612336.70 N 70.29605105 W 149. 34607 1427.00 38.84 92.23 93.45 1354.89 1273.99 273.41 -3.13 342.89 342.90 90.52 6.18 5958682.12 612391.84 N 70.29605007 W 149.08989959 1521.98 43.73 92.85 94.98 1426.24 1345.34 321.99 -5.92 405.47 405.52 90.84 5.17 5958680.26 612454.45 N 70.29604243 W 149.08939286 1616.01 45.76 92.04 94.03 1493.02 1412.12 373.40 -8.73 471.60 471.68 91.06 2.24 5958678.43 612520.61 N 70.29603473 W 149.08885745 1709.89 45.49 93.10 93.88 1558.68 1477.78 425.43 -11.74 538.64 538.76 91.25 0.86 5958676.42 612587.67 N 70.29602650 W 149.08831472 1803.35 44.15 92.96 93.46 1624.97 1544.07 476.16 -15.22 604.42 604.61 91.44 1.44 5958673.92 612653.50 N 70.29601697 W 149.08778210 1898.67 42.83 93.34 95.32 1694.12 1613.22 526.60 -18.83 669.92 670.19 91.61 1.41 5958671.29 612719.04 N 70.29600711 W 149.08725177 1992.58 42.02 93.80 93.91 1763.44 1682.54 575.01 -22.77 733.15 733.51 91.78 0.92 5958668.29 612782.32 N 70.29599633 W 149.08673983 2087.21 41.64 93.69 94.63 1833.96 1753.06 623.11 -26.89 796.13 796.58 91.93 0.41 5958665.11 612845.34 N 70.29598505 W 149.08622995 2182.02 42.33 93.42 94.81 1904.43 1823.53 671.59 -30.82 859.43 859.98 92.05 0.75 5958662.12 612908.69 N 70.29597429 W 149.08571746 2276.41 41.86 93.01 94.39 1974.47 1893.57 720.19 -34.37 922.60 923.24 92.13 0.58 5958659.52 612971.90 N 70.29596457 W 149.08520597 Version DO 3.1 RT ( d031 rC546 ) 3.1 RT-SP3.03 W-205\W-205\ W-205\W-205 Generated 9/25/2003 4:33 PM Page 1 of 5 2371.24 43.94 92.92 94.83 2043.93 1963.03 769.95 -37.71 987.07 987.79 92.19 2.19 5958657.14 613036.40 N 70.29595543 W 149.08468405 2465.72 44.80 90.69 94.48 2111.47 2030.57 821.72 -39.78 1053.09 1053.84 92.16 1.88 5958656.05 613102.45 N 70.29594975 W 149.08414947 2560.07 44.84 89.82 94.35 2178.40 2097.50 874.94 -40.08 1119.60 1120.31 92.05 0.65 5958656.75 613168.94 N 70.29594891 W149.08361102 2654.53 44.98 90.34 94.46 2245.30 2164.40 928.42 -40.17 1186.28 1186.96 91.94 0.42 5958657.65 613235.62 N 70.29594863 W 149.08307109 2750.20 44.95 90.82 95.67 2312.99 2232.09 982.28 -40.86 1253.89 1254.55 91.87 0.36 5958657.97 613303.22 N 70.29594673 W 149.08252374 2845.05 44.48 90.47 94.85 2380.39 2299.49 1035.41 -41.61 1320.62 1321.27 91.80 0.56 5958658.22 613369.95 N 70.29594464 W 149.08198347 2940.21 44.54 87.54 95.16 2448.26 2367.36 1089.64 -40.45 1387.30 1387.89 91.67 2.16 5958660.37 613436.60 N 70.29594778 W 149.08144355 3034.42 44.39 87.64 94.21 2515.49 2434.59 1144.22 -37.67 1453.24 1453.73 91.49 0.18 5958664.13 613502.48 N 70.29595532 W 149.08090972 3129.22 44.11 87.91 94.80 2583.40 2502.50 1198.82 -35.11 1519.34 1519.74 91.32 0.36 5958667.68 613568.53 N 70.29596230 W 149.08037454 3221.57 44.52 88.27 92.35 2649.48 2568.58 1251.87 -32.96 1583.82 1584.16 91.19 0.52 5958670.79 613632.96 N 70.29596814 W 149.07985248 3315.03 44.46 88.48 93.46 2716.15 2635.25 1305.53 -31.10 1649.29 1649.58 91.08 0.17 5958673.62 613698.39 N 70.29597318 W 149.07932241 3409.53 44.42 88.46 94.50 2783.62 2702.72 1359.69 -29.33 1715.43 1715.68 90.98 0.04 5958676.38 613764.49 N 70.29597796 W 149.07878690 3504.53 44.80 88.89 95.00 2851.25 2770.35 1414.15 -27.79 1782.13 1782.34 90.89 0.51 5958678.91 613831.16 N 70.29598213 W 149.07824687 3598.91 45.06 89.18 94.38 2918.07 2837.17 1468.33 -26.67 1848.77 1848.96 90.83 0.35 5958681.03 613897.77 N 70.29598515 W 149.07770728 3694.74 46.75 88.01 95.83 2984.75 2903.85 1524.57 -24.97 1917.57 1917.73 90.75 1.97 5958683.75 613966.53 N 70.29598974 W 149.026 3788.33 46.72 88.07 93.59 3048.90 2968.00 1580.64 -22.64 1985.68 1985.81 90.65 0.06 5958687.10 614034.59 N 70.29599606 W 149.0 9879 3882.04 48.58 88.49 93.71 3112.02 3031.12 1637.45 -20.56 2054.90 2055.01 90.57 2.01 5958690.20 614103.77 N 70.29600168 W 149.07603834 3935.59 49.24 88.61 53.55 3147.22 3066.32 1670.45 -19.54 2095.25 2095.34 90.53 1.24 5958691.82 614144.09 N 70.29600444 W 149.07571167 4029.51 47.87 88.73 93.92 3209.38 3128.48 1727.93 -17.91 2165.63 2165.70 90.47 1.46 5958694.51 614214.44 N 70.29600885 W 149.07514183 4125.83 47.53 88.86 96.32 3274.21 3193.31 1786.00 -16.41 2236.86 2236.92 90.42 0.37 5958697.07 614285.63 N 70.29601289 W 149.07456516 4219.70 47.06 88.57 93.87 3337.87 3256.97 1842.29 -14.86 2305.82 2305.87 90.37 0.55 5958699.64 614354.55 N 70.29601706 W 149.07400679 4313.18 47.50 90.07 93.48 3401.29 3320.39 1897.90 -14.05 2374.49 2374.53 90.34 1.27 5958701.48 614423.19 N 70.29601921 W 149.07345082 4408.39 49.25 90.60 95.21 3464.53 3383.63 1954.78 -14.47 2445.65 2445.70 90.34 1.88 5958702.12 614494.35 N 70.29601800 W 149.07287463 4502.06 49.19 90.52 93.67 3525.71 3444.81 2011.31 -15.17 2516.58 2516.62 90.35 0.09 5958702.48 614565.27 N 70.29601605 W 149.07230038 4596.92 48.95 90.38 94.86 3587.86 3506.96 2068.51 -15.73 2588.24 2588.29 90.35 0.28 5958702.99 614636.93 N 70.29601444 W 149.07172015 4692.21 48.79 90.24 95.29 3650.54 3569.64 2125.90 -16.12 2660.02 2660.07 90.35 0.20 5958703.67 614708.70 N 70.29601331 W 149.07113904 4786.94 48.40 89.75 94.73 3713.19 3632.29 2182.94 -16.11 2731.07 2731.12 90.34 0.57 5958704.73 614779.74 N 70.29601326 W 149.07056377 4881.27 47.90 89.49 94.33 3776.13 3695.23 2239.63 -15.65 2801.33 2801.38 90.32 0.57 5958706.25 614849.98 N 70.29601446 W 149.06999488 4976.33 47.54 89.45 95.06 3840.08 3759.18 2296.48 -15.00 2871.66 2871 .70 90.30 0.38 5958707.94 614920.28 N 70.29601616 W 149.06942547 5070.70 47.15 89.05 94.37 3904.02 3823.12 2352.73 -14.09 2941.06 2941.09 90.27 0.52 5958709.89 614989.66 N 70.29601857 W 149.06886359 5164.92 46.92 88.98 94.22 3968.24 3887.34 2408. 79 -12.90 3010.00 3010.02 90.25 0.25 5958712.10 615058.56 N 70.29602173 W 149.06830544 5260.11 47.44 91.19 95.19 4032.94 3952.04 2464.77 -13.01 3079.81 3079.84 90.24 1.79 5958713.03 615128.36 N 70.29602136 W 149.06774020 5353.62 47.09 90.56 93.51 4096.40 4015.50 2519.27 -14.06 3148.48 3148.52 90.26 0.62 5958713.00 615197.04 N 70.29601841 W14.419 5448. 04 46.84 90.99 94.42 4160.84 4079.94 2574.12 -15.00 3217.49 3217.53 90.27 0.43 5958713.10 615266.05 N 70.29601578 W 14 547 5542.45 47.35 93.52 94.41 4225.11 4144.21 2627.96 -17.72 3286.58 3286.63 90.31 2.04 5958711.40 615335.16 N 70.29600825 W 14 610 5637.51 48.32 97.51 95.06 4288. 94 4208.04 2680.19 -24.51 3356.69 3356.77 90.42 3.27 5958705.66 615405.35 N 70.29598962 W 149.06549853 5730.86 48.49 102.79 93.35 4350.93 4270.03 2727.99 -36.81 3425.36 3425.56 90.62 4.23 5958694.39 615474.20 N 70.29595594 W 149.06494257 5827.15 48.36 104.32 96.29 4414.83 4333.93 2774.14 -53.69 3495.38 3495.79 90.88 1.20 5958678.56 615544.46 N 70.29590973 W 149.06437569 5922.20 47.21 99.09 95.05 4478.72 4397.82 2820.91 -67.99 3564.26 3564.91 91.09 4.25 5958665.29 615613.54 N 70.29587058 W 149.06381806 6018.20 47.43 95.71 96.00 4543.81 4462.91 2871.67 -77.07 3634.23 3635.05 91.21 2.60 5958657.25 615683.63 N 70.29584567 W 149.06325161 6113.56 49.51 92.20 95.36 4607.04 4526.14 2925.91 -81.96 3705.42 3706.33 91.27 3.51 5958653.42 615754.88 N 70.29583222 W 149.06267521 6207.77 51.06 88.79 94.21 4667.25 4586.35 2983.71 -82.56 3777.87 3778.77 91.25 3.23 5958653.90 615827.32 N 70.29583048 W 149.06208867 6301.13 54.14 83.06 93.36 4723.98 4643.08 3046.24 -77.22 3851.78 3852.55 91.15 5.89 5958660.34 615901.14 N 70.29584497 W 149.06149024 6393.40 55.11 76.89 92.27 4777.43 4696.53 3113.48 -64.11 3925.80 3926.33 90.94 5.55 5958674.55 615974.95 N 70.29588068 W 149.06089087 6486.61 56.60 71.66 93.21 4829.77 4748.87 3185.53 -43.19 4000.01 4000.24 90.62 4.91 5958696.58 616048.82 N 70.29593774 W 149.06029001 6582.21 60.06 67.40 95.60 4879.97 4799.07 3263.66 -14.69 4076.17 4076.20 90.21 5.24 5958726.20 616124.55 N 70.29601547 W 149.05967320 Version DO 3.1 RT ( d031 r'-546 ) 3.1 RT-SP3.03 W-205\W-205\ W-205\W-205 Generated 9/25/2003 4:33 PM Page 2 of 5 6676.53 63.26 62.27 94.32 4924.76 4843.86 3344.99 20.64 4151.24 4151.29 89.72 5.87 5958762.64 616199.08 N 70.29611187 W 149.05906527 6771.35 64.85 57.71 94.82 4966.26 4885.36 3429.66 63.28 4225.03 4225.51 89.14 4.64 5958806.38 616272.22 N 70.29622827 W 149.05846762 6865.05 65.91 55.97 93.70 5005.30 4924.40 3514.68 109.88 4296.33 4297.74 88.53 2.03 5958854.03 616342.81 N 70.29635545 W 149.05789011 6958.08 68.13 53.24 93.03 5041.62 4960.72 3600.30 159.49 4366.13 4369.04 87.91 3.60 5958904.67 616411.85 N 70.29649088 W 149.05732477 7052.54 70.37 52.60 94.46 5075.09 4994.19 3688.62 212.75 4436.59 4441.69 87.25 2.45 5958958.97 616481.51 N 70.29663626 W 149.05675399 7147.59 73.28 51.97 95.05 5104.73 5023.83 3778.90 267.99 4508. 02 4515.98 86.60 3.13 5959015.27 616552.10 N 70.29678706 W 149.05617539 7242.26 75.87 52.57 94.67 5129.91 5049.01 3870.13 323.83 4580.19 4591.63 85.96 2.80 5959072.17 616623.43 N 70.29693949 W 149.05559074 7336.39 78.82 51.14 94.13 5150.53 5069.63 3961.93 380.55 4652.41 4667.95 85.32 3.47 5959129.96 616694.78 N 70.29709433 W 149.05500574 7431.87 82.15 49.46 95.48 5166.31 5085.41 4055.94 440.70 4724.84 4745.35 84.67 3.90 5959191.17 616766.31 N 70.29725852 W 149.05441894 7525.55 85.19 46.56 93.68 5176.64 5095.74 4148.62 502.98 4794.03 4820.34 84.01 4.47 5959254.47 616834.55 N 70.29742855 W 149.05385844 7552.29 85.08 45.37 26.74 5178.91 5098.01 4175.04 521.50 4813.18 4841.35 83.82 4.45 5959273.27 616853.42 N 70.29747911 W 149.05370325 7670.42 86.46 39.51 118.13 5187.63 5106.73 4290.64 608.40 4892.64 4930.32 82.91 5.08 5959361.34 616931.57 N 70.29771638 W 149.05305942 7702.70 86.63 35.08 32.28 5189.58 5108.68 4321.59 634.03 4912.16 4952.91 82.65 13.71 5959387.26 616950.70 N 70.29778636 W 149.05290124 7733.37 85.63 31.99 30.67 5191.65 5110.75 4350.37 659.53 4929.06 4972.99 82.38 10.57 5959413.01 616967.22 N 70.29785600 W 149.05276424 7763.82 86.05 30.25 30.45 5193.86 5112.96 4378.47 685.53 4944.76 4992.05 82.11 5.86 5959439.23 616982.53 N 70.29792700 W 149.701 7795.20 86.74 29.99 31.38 5195.83 5114.93 4407.24 712.62 4960.47 5011.40 81.82 2.35 5959466.55 616997.83 N 70.29800097 W 149. 0961 7826.99 87.63 30.61 31.79 5197.39 5116.49 4436.44 740.03 4976.49 5031.22 81.54 3.41 5959494.20 617013.44 N 70.29807584 W 149.05237975 7857.53 87.80 30.09 30.54 5198.61 5117.71 4464.52 766.37 4991.91 5050.40 81.27 1.79 5959520.76 617028.46 N 70.29814775 W 149.05225476 7888.69 88.21 30.16 31.16 5199.70 5118.80 4493.13 793.30 5007.54 5069.99 81.00 1.33 5959547.92 617043.69 N 70.29822130 W 149.05212806 7923.54 90.10 33.25 34.85 5200.21 5119.31 4525.50 822.94 5025.85 5092.78 80.70 10.39 5959577.83 617061.55 N 70.29830225 W 149.05197963 7951.68 89.10 31.98 28.14 5200.41 5119.51 4551.81 846.64 5041.02 5111.62 80.47 5.74 5959601.75 617076.36 N 70.29836697 W 149.05185670 7983.00 85.57 31.01 31.32 5201.86 5120.96 4580.83 873.32 5057.36 5132.21 80.20 11.69 5959628.66 617092.31 N 70.29843981 W 149.05172422 8014.05 85.49 29.01 31.05 5204.28 5123.38 4609.24 900.12 5072.84 5152.08 79.94 6.43 5959655.69 617107.38 N 70.29851301 W 149.05159872 8045.36 87.76 28.14 31.31 5206.13 5125.23 4637.60 927.57 5087.79 5171.65 79.67 7.76 5959683.35 617121.92 N 70.29858796 W 149.05147752 8076.23 86.94 27.38 30.87 5207.55 5126.65 4665.40 954.85 5102.15 5190.73 79.40 3.62 5959710.85 617135.87 N 70.29866248 W 149.05136107 8107.22 87.08 27.25 30.99 5209.17 5128.27 4693.20 982.35 5116.35 5209.81 79.13 0.62 5959738.55 617149.66 N 70.29873757 W 149.05124592 8138.93 88.14 26.56 31.71 5210.49 5129.59 4721.55 1010.60 5130.69 5229.27 78.86 3.99 5959767.01 617163.58 N 70.29881473 W 149.05112968 8169.71 90.34 23.07 30.78 5210.90 5130.00 4748.57 1 038. 53 5143.60 5247.40 78.59 13.40 5959795.13 617176.07 N 70.29889101 W 149.05102495 8201.08 91.92 19.80 31.37 5210.28 5129.38 4775.18 1067.72 5155.06 5264.48 78.30 11.57 5959824.49 617187.09 N 70.29897073 W 149.05093199 8232.18 91.47 17.68 31.10 5209.36 5128.46 4800.75 1097.16 5165.05 5280.29 78.01 6.97 5959854.06 617196.64 N 70.29905113 W 149.05085096 8263.11 88.69 16.02 30.93 5209.32 5128.42 4825.59 1126.76 5174.02 5295.28 77.71 10.47 5959883.79 617205.16 N 70.29913197 W 149.05077820 8294.78 87.32 15.99 31.67 5210.42 5129.52 4850.74 1157.18 5182.74 5310.36 77.41 4.33 5959914.34 617213.43 N 70.29921507 W 149.05070737 8325.89 86.32 13.18 31.11 5212.15 5131.25 4874.94 1187.24 5190.56 5324.61 77.12 9.57 5959944.51 617220.80 N 70.29929717 W 149.05064386 8356.08 87.42 10.30 30.19 5213.80 5132.90 4897.45 1216.75 5196.70 5337.24 76.82 10.20 5959974.10 617226.49 N 70.29937778 W 14.404 8387.54 91.20 9.03 31.46 5214.17 5133.27 4920.18 1247.75 5201.98 5349.53 76.51 12.67 5960005.18 617231.31 N 70.29946247 W 149.05055111 8418.44 94.15 6.96 30.90 5212.73 5131.83 4941.85 1278.32 5206.27 5360.91 76.20 11.66 5960035.80 617235.15 N 70.29954596 W 149.05051617 8449.96 93.53 4.40 31.52 5210.62 5129.72 4963.00 1309.61 5209.38 5371.47 75.89 8.34 5960067.13 617237.79 N 70.29963144 W 149.05049080 8480.78 91.61 0.97 30.82 5209.24 5128.34 4982.49 1340.36 5210.82 5380.45 75.57 12.74 5960097.90 617238.78 N 70.29971544 W 149.05047895 8512.15 90.96 359.14 31.37 5208.53 5127.63 5001.22 1371.72 5210.85 5388.38 75.25 6.19 5960129.25 617238.34 N 70.29980111 W 149.05047853 8543.14 91.13 359.25 30.99 5207.97 5127.07 5019.34 1402.70 5210.42 5395.93 74.93 0.65 5960160.22 617237.44 N 70.29988575 W 149.05048188 8574.67 90.92 358.89 31.53 5207.41 5126.51 5037.72 1434.22 5209.91 5403.71 74.61 1.32 5960191.73 617236.46 N 70.29997187 W 149.05048585 8605.16 91.20 357.80 30.49 5206.84 5125.94 5055.18 1464.69 5209.03 5411.03 74.29 3.69 5960222.18 617235.13 N 70.30005511 W 149.05049281 8634.83 91.26 357.58 29.67 5206.20 5125.30 5071.89 1494.33 5207.83 5417.98 73.99 0.77 5960251.79 617233.49 N 70.30013609 W 149.05050232 8666.51 90.89 356.93 31.68 5205.61 5124.71 5089.54 1525.97 5206.31 5425.34 73.66 2.36 5960283.40 617231.50 N 70.30022252 W 149.05051443 8698.09 90.41 354.38 31.58 5205.25 5124.35 5106.39 1557.45 5203.92 5431.98 73.34 8.22 5960314.85 617228.64 N 70.30030854 W 149.05053363 8729.07 90.85 352.12 30.98 5204.91 5124.01 5121.81 1588.21 5200.28 5437.40 73.02 7.43 5960345.55 617224.54 N 70.30039259 W 149.05056294 Version DO 3.1 RT ( d031 r'-546 ) 3.1 RT-SP3.03 W-205\W-205\W-205\W-205 Generated 9/25/2003 4:33 PM Page 3 of 5 8760.36 90.58 349.70 31.29 5204.52 5123.62 5136.26 1619.11 5195.34 5441.79 72.69 7.78 5960376.36 617219.14 N 70.30047699 W 149.05060279 8790.85 88.25 347.49 30.49 5204.83 5123.93 5149.24 1648.99 5189.31 5445.01 72.37 10.53 5960406.15 617212.67 N 70.30055864 W 149.05065144 8821.07 87.15 346.00 30.22 5206.04 5125.14 5161.20 1678.38 5182.39 5447.39 72.05 6.13 5960435.43 617205.31 N 70.30063894 W 149.05070734 8853.69 86.87 344.26 32.62 5207.75 5126.85 5173.26 1709.86 5174.03 5449.24 71.71 5.40 5960466.78 617196.48 N 70.30072497 W 149.05077486 8884.74 87.66 345.47 31.05 5209.23 5128.33 5184.61 1739.80 5165.93 5451.03 71.39 4.65 5960496.59 617187.94 N 70.30080677 W 149.05084027 8916.61 88.18 345.46 31.87 5210.38 5129.48 5196.57 1770.63 5157.94 5453.39 71.05 1.63 5960527.30 617179.49 N 70.30089101 W 149.05090483 8946.32 88.42 345.09 29.71 5211.27 5130.37 5207.64 1799.35 5150.39 5455.65 70.74 1.48 5960555.90 617171.51 N 70.30096949 W 149.05096580 8977.51 86.46 346.14 31.19 5212.66 5131.76 5219.42 1829.53 5142.65 5458.39 70.42 7.13 5960585.96 617163.32 N 70.30105195 W 149.05102832 9009.20 86.32 345.56 31.69 5214.65 5133.75 5231.50 1860.20 5134.92 5461.47 70.09 1.88 5960616.50 617155.13 N 70.30113575 W 149.05109076 9040.39 86.56 346.02 31.19 5216.59 5135.69 5243.35 1890.37 5127.27 5464.66 69.76 1.66 5960646.56 617147.04 N 70.30121820 W 149.05115248 9071.04 86.63 345.24 30.65 5218.41 5137.51 5254.93 1920.01 5119.68 5467.87 69.44 2.55 5960676.08 617139.01 N 70.30129919 W 149.05121381 9101.90 86.77 346.08 30.86 5220.19 5139.29 5266.60 1949.86 5112.05 5471.29 69.12 2.76 5960705.81 617130.94 N 70.30138075 W 149.05127544 9133.94 87.87 346.40 32.04 5221.69 5140.79 5279.02 1980.95 5104.44 5475.35 68.79 3.58 5960736.78 617122.86 N 70.30146569 W 149.05133692 9165.69 88.32 347.25 31.75 5222.74 5141.84 5291.64 2011.85 5097.21 5479.87 68.46 3.03 5960767.56 617115.17 N 70.30155011 W 149.32 9196.42 86.74 346.90 30.73 5224.07 5143.17 5303.97 2041.77 5090.34 5484.56 68.14 5.27 5960797.37 617107.86 N 70.30163186 W 149 77 9227.68 86.80 347.23 31.26 5225.83 5144.93 5316.49 2072.19 5083.35 5489.48 67.82 1.07 5960827.68 617100.42 N 70.30171498 W 149. 0718 9258. 0 1 86.94 346.78 30.33 5227.48 5146.58 5328.62 2101.69 5076.54 5494.40 67.51 1.55 5960857.08 617093.17 N 70.30179561 W 149.05156217 9288.59 87.32 347.39 30.58 5229.01 5148.11 5340.89 2131.46 5069.72 5499.56 67.20 2.35 5960886.74 617085.90 N 70.30187694 W 149.05161730 9320.56 87.29 347.92 31.97 5230.52 5149.62 5354.01 2162.66 5062.89 5505.45 66.87 1.66 5960917.83 617078.61 N 70.30196218 W 149.05167242 9352.13 87.18 347.74 31.57 5232.04 5151.14 5367.05 2193.48 5056.24 5511.53 66.55 0.67 5960948.55 617071.51 N 70.30204641 W 149.05172609 9383.17 87.08 347.85 31.04 5233.59 5152.69 5379.85 2223.78 5049.69 5517.66 66.23 0.48 5960978.75 617064.50 N 70.30212920 W 149.05177900 9413.39 87.08 347.42 30.22 5235.13 5154.23 5392.24 2253.27 5043.22 5523.70 65.93 1.42 5961008.13 617057.60 N 70.30220975 W 149.05183118 9445.42 87.04 347.04 32.03 5236.78 5155.88 5405.17 2284.46 5036.15 5530.06 65.60 1.19 5961039.21 617050.07 N 70.30229499 W 149.05188828 9476.11 87.15 347.48 30.69 5238.33 5157.43 5417.56 2314.36 5029.39 5536.34 65.29 1.48 5961069.00 617042.86 N 70.30237667 W 149.05194286 9507.64 87.19 347.19 31.53 5239.89 5158.99 5430.34 2345.08 5022.49 5543.00 64.97 0.93 5961099.62 617035.50 N 70.30246062 W 149.05199861 9539.08 87.15 347.67 31.44 5241.44 5160.54 5443.13 2375.73 5015.66 5549.86 64.65 1.53 5961130.16 617028.21 N 70.30254437 W 149.05205379 9570.06 87.42 348.35 30.98 5242.91 5162.01 5456.01 2406.00 5009.23 5557.09 64.34 2.36 5961160.33 617021.34 N 70.30262707 W 149.05210570 9604.68 87.56 348.52 34.62 5244.43 5163.53 5470.65 2439.89 5002.29 5565.61 64.00 0.64 5961194.10 617013.90 N 70.30271965 W 149.05216167 9632.72 87.83 347.06 28.04 5245.55 5164.65 5482.22 2467.27 4996.37 5572.35 63.72 5.29 5961221.39 617007.57 N 70.30279447 W 149.05220951 9663.41 88.59 344.39 30.69 5246.51 5165.61 5493.87 2496.99 4988.80 5578.81 63.41 9.04 5961251.00 616999.56 N 70.30287569 W 149.05227061 9694.34 90.20 344.02 30.93 5246.84 5165.94 5504.85 2526.75 4980.39 5584.69 63.10 5.34 5961280.62 616990.70 N 70.30295701 W 149.05233863 9725.79 92.40 343.02 31.45 5246.12 5165.22 5515.67 2556.90 4971.47 5590.46 62.78 7.68 5961310.63 616981.33 N 70.30303939 W 149.05241070 9756.95 92.50 340.61 31.16 5244.79 5163.89 5525.50 2586.48 4961.75 5595.43 62.47 7.73 5961340.06 616971.18 N 70.30312020 W 149.05248923 9787.94 92.09 339.89 30.99 5243.55 5162.65 5534.48 2615.62 4951.29 5599.71 62.15 2.67 5961369.04 616960.28 N 70.30319984 W 14.382 9819.42 91.13 338.21 31.48 5242.67 5161.77 5542.97 2645.01 4940.04 5603.57 61.83 6.14 5961398.25 616948.60 N 70.30328014 W 149.0 266479 9850.58 90.72 336.05 31.16 5242.16 5161.26 5550.36 2673.71 4927.93 5606.53 61.52 7.05 5961426.77 616936.06 N 70.30335858 W 149.05276270 9881.18 91.02 336.51 30.60 5241.70 5160.80 5557.18 2701.72 4915.62 5609.16 61.21 1.79 5961454.59 616923.34 N 70.30343512 W 149.05286224 9912.90 91.57 338.05 31.72 5240.98 5160.08 5564.79 2730.97 4903.37 5612.60 60.88 5.15 5961483.65 616910.66 N 70.30351506 W 149.05296128 9944.22 91.81 337.85 31.32 5240.06 5159.16 5572.65 2759.99 4891.62 5616.54 60.57 1.00 5961512.49 616898.48 N 70.30359435 W 149.05305632 9975.54 90.41 338.25 31.32 5239.45 5158.55 5580.57 2789.03 4879.92 5620.70 60.25 4.65 5961541.35 616886.34 N 70.30367371 W 149.05315097 10006.39 89.82 338.20 30.85 5239.39 5158.49 5588.47 2817.68 4868.47 5625.06 59.94 1.92 5961569.82 616874.47 N 70.30375200 W 149.05324351 10037.84 89.89 338.57 31.45 5239.47 5158.57 5596.60 2846.92 4856.89 5629.77 59.62 1.20 5961598.88 616862.45 N 70.30383189 W 149.05333719 10068.74 89.86 337.74 30.90 5239.54 5158.64 5604.47 2875.60 4845.39 5634.44 59.31 2.69 5961627.39 616850.53 N 70.30391027 W 149.05343017 10100.40 90.03 337.38 31.66 5239.57 5158.67 5612.21 2904.86 4833.31 5639.07 58.99 1.26 5961656.46 616838.01 N 70.30399023 W 149.05352790 10130.85 90.17 337.93 30.45 5239.51 5158.61 5619.71 2933.03 4821.73 5643.73 58.69 1.86 5961684.45 616826.02 N 70.30406719 W 149.05362151 10162.47 90.06 337.10 31.62 5239.45 5158.55 5627.42 2962.24 4809.64 5648.67 58.37 2.65 5961713.48 616813.49 N 70.30414703 W 149.05371931 Version DO 3.1 RT ( d031 rC546 ) 3.1 RT-SP3.03 W-205\W-205\W-205\ W-205 Generated 9/25/2003 4:33 PM Page 4 of 5 10193.82 90.34 337.89 31.35 5239.34 5158.44 5635.06 2991.20 4797.64 5653.73 58.06 2.67 5961742.26 616801.06 N 70.30422617 W 149.05381635 10224.81 90.51 337.91 30.99 5239.11 5158.21 5642.82 3019.92 4785.98 5659.11 57.75 0.55 5961770.79 616788.98 N 70.30430463 W 149.05391063 10256.17 90.51 337.86 31.36 5238.83 5157.93 5650.66 3048.97 4774.17 5664.71 57.44 0.16 5961799.66 616776.74 N 70.30438402 W 149.05400611 10287.87 90.65 337.81 31.70 5238.51 5157.61 5658.56 3078.32 4762.21 5670.52 57.12 0.47 5961828.83 616764.35 N 70.30446424 W 149.05410282 10319.07 90.78 336.61 31.20 5238.12 5157.22 5666.01 3107.09 4750.13 5676.06 56.81 3.87 5961857.41 616751.84 N 70.30454284 W 149.05420056 10350.29 91.30 337.87 31.22 5237.56 5156.66 5673.47 3135.87 4738.05 5681.80 56.50 4.37 5961886.00 616739.33 N 70.30462149 W 149.05429822 10381.13 91.95 338.42 30.84 5236.68 5155.78 5681.32 3164.48 4726.58 5688.10 56.20 2.76 5961914.44 616727.43 N 70.30469967 W 149.05439103 10412.55 92.88 338.38 31.42 5235.36 5154.46 5689.45 3193.67 4715.02 5694.82 55.89 2.96 5961943.45 616715.45 N 70.30477943 W 149.05448448 10443.98 92.02 339.17 31.43 5234.01 5153.11 5697.77 3222.94 4703.65 5701.90 55.58 3.71 5961972.54 616703.64 N 70.30485942 W 149.05457641 10474.69 90.30 339.30 30.71 5233.39 5152.49 5706.15 3251.65 4692.77 5709.23 55.28 5.62 5962001.09 616692.33 N 70.30493786 W 149.05466444 10505.76 90.13 338.98 31.07 5233.28 5152.38 5714.58 3280.68 4681.70 5716.75 54.98 1.17 5962029.95 616680.84 N 70.30501720 W 149.05475390 10537.74 90.03 338.09 31.98 5233.23 5152.33 5722.93 3310.44 4670.00 5724.33 54.67 2.80 5962059.53 616668.70 N 70.30509853 W 149.05484854 10568.62 91.64 338.68 30.88 5232.78 5151.88 5730.91 3339.15 4658.63 5731.73 54.37 5.55 5962088.06 616656.90 N 70.30517696 W 149.05494052 10598.92 95.43 339.10 30.30 5230.91 5150.01 5738.99 3367.35 4647.74 5739.39 54.08 12.58 5962116.10 616645.59 N 70.30525404 W 149..59 10619.86 95.98 339.77 20.94 5228.83 5147.93 5744.74 3386.86 4640.42 5744.94 53.88 4.13 5962135.49 616637.98 N 70.30530735 W 149. 78 10670.00 95.98 339.77 50.14 5223.61 5142.71 5758.80 3433.65 4623.18 5758.80 53.40 0.00 5962182.02 616620.04 N 70.30543521 W 149. 722 LeQal Description: NorthinQ (y) mUSl EastinQ (X) [nUSl Surface: 3703 FSL 1197 FEL S21 T11 N R12E UM 5958680.13 612048.97 BHL: 1855 FSL 1846 FEL S15 T11 N R12E UM 5962182.02 616620.04 . Version DO 3.1 RT ( d031 rC546 ) 3.1 RT-SP3.03 W-205\W-205\W-205\ W-205 Generated 9/25/2003 4:33 PM Page 5 of 5 . . 803-11l.p MWD/LWD Log Product Delivery Customer BP Exploration (Alaska) Inc. Dispatched To: Lisa Weepie Well No W-205 Date Dispatche 22-Aug-03 I nstallation/Rig Nabors 9ES Dispatched By: Nate Rose Data No Of Prints No of Floppies Surveys 2 """" ~ Please sign and return to: James H. Johnson Received By: ~Ö \.I;µ. j~'\..\ )~C C':t~C'~ BP Exploration (Alaska) Inc. Petrotechnical Data Center (LR2-1) 900 E. Benson Blvd. Anchorage, Alaska 99508 Fax: 907-564-4005 e-mail address:johnsojh@bp.com LWD Log Delivery V1.1 , Dec '97 -~~~\\\~ r;-;::¡ . lID f !Æ ~!Æ~ ~.«!Æ . / AI/ASIiA OIL AND GAS CONSERVATION COMMISSION Lowell Crane Senior Drilling Engineer BP Exploration (Alaska), Inc. PO Box 196612 Anchorage AK 99519-6612 333 W. 7'" AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 FRANK H. MURKOWSKI, GOVERNOR Re: Prudhoe Bay Unit W-205 BP Exploration (Alaska), Inc. Pennit No: 203-116 Surface Location: 3703' NSL, 1196' WEL, Sec. 21, TIIN, RI2E, UM Bottomhole Location: 1873' NSL, 3469' EWL, Sec.'15, TIIN, RI2E, UM Dear Mr. Crane: Enclosed is the approved application for pennit to drill the above referenced development well. This pennit to drill does not exempt you from obtaining additional pennits or approvals required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required pennits and approvals have been issued. In addition, the Commission reserves the right to withdraw the pennit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the tenns and conditions of this pennit may result in the revocation or suspension of the pennit. Please provide at least twenty-four (24) hours notice for a representative of the Commission to witness any required test. Contact the Commission's North Slope petroleum field inspector at 659-3607 (pager). Sincerely, Rq t'.,- -;J~ ~ Randy Ruedrich Commissioner BY ORDER OF THE COMMISSION DATED this~day of June, 2003 cc: Department ofFish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. Exploration, Production and Refineries Section ìAJ41\- "¡lA../ z,.oo "S 1 a. Type of work 1/ Drill 0 Redrill ORe-Entry 0 Deepen 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface x = 612049, Y = 5958680 3703' NSL, 1196' WEL, SEC. 21, T11N, R12E, UM At top of productive interval x = 617110. Y = 5958975 3920' NSL, 3869' EWL, SEC. 22, T11N, R12E, UM At total depth x = 616655, Y = 5962200 1873' NSL, 3469' EWL, SEC. 15, T11N, R12E, UM 12. Distance to nearest property line 113. Distance to nearest well/ ADL047451, 1810' MD No Close Approach 16. To be completed for deviated wells Kick Off Depth 300' MD Maximum Hole Angle 18. Casing Program S 'f' t' Size pecl Ica Ions Casina Weiaht Grade Couclina 20" x 34" 215.5# A53 Welded 10-3/4" 45.5# L-80 BTC-M 7-5/8" 29.7# L-80 BTC-M 4-1/2" 12.6# L-80 IBT-M . STATE OF ALASKA _ ALASKA O~AND GAS CONSERVATION COMMI~N PERMIT TO DRILL 20 AAC 25.005 11 b. Type of well 0 Exploratory 0 Stratigraphic Test 1/ Development Oil o Service 0 Development Gas 0 Single Zone 0 Multiple Zone 5. Datum Elevation (DF or KB) 10. Field and Pool Plan KBE = 80.9' Prudhoe Bay Field I Polaris 6. Property Designation Pool ADL 028263 7. Unit or Property Name Prudhoe Bay Unit 8. Well Number W-205 / 9. Approximate spud date 07/15/03 / Amount $200,000.00 14. Number of acres in property 15. Proposed depth (MD and TVD) 2560 .......-10681' MD I 5231' TVD o 17. Anticipated pressure {s~ 20 MC 25.035 (e) (2)} 91 Maximum surface 1700 psig, At total depth (TVD) 4900' I 2190 psig Setting Depth Top Bottom Lenath MD TVD MD TVD 80' 29' 29' 109' 109' 3981' 29' 29' 4010' 3206' 7573' 29' 29' 7602' 5181' .~ -7662' 5181' 10681' 5231' 32-0 ' "''160' ~k 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical 11. Type Bond (See 20 AAC 25.025) ... Number 2S 100302630-277 Hole 48" Quantity of Cement (include staae data) 260 sx Arctic Set (Approx.) 822 sx PF 'L', 348 sx Class 'G' 541 sx Class 'G' Uncemented Slotted Liner ../ 13-1/2" 9-718" 6-3/4" feet feet feet feet Plugs (measured) Junk (measured) Casing Structural Conductor Surface Intermediate Production Liner Length Size Cemented MD TVD JUN í) ¿1 true vertical Perforation depth: measured 1/ Filing Fee 0 Property Plat 0 BOP Sketch 0 Diverter Sketch 1/ Drilling Program 1/ Drilling Fluid Program 0 Time vs Depth Plot 0 Refraction Analysis 0 Seabed Report 1/20 AAC 25.050 Requirements Contact Engineer NamelNumber: Michael Tr; 10, 564-5774 Prepared By Name/Number: Terrie Hubble, 564-4628 21. I hereby certify that the foregoi is true an~~ to the best of my knowledge Signed Lowell Crane ~...J..r<..eA f~ Title Senior Drilling Engineer Date b'- .;J3-ù J " . . ;i'Ci¡:':;:r~r!!fÆ\~':+':':"'~~ìfJú;l~~rs?~~;~;~'mt~'"fJt:t.~òni··:".;~~~~f61I)}rG':é':~;;:;f': ' , . ..,",.:::,;~:':;:v.:' . .. Permit Number API Number './ ZprOV?~Date I See cover letter . ¿:,o.3 - /' / ç: 50- 02, / -- ¿.3 / {o S Go ~~r':>3 for other reauirements Conditions of Approval: Samples Required 0 Yes B"No Mud L g Required 0 Yes 'J2J.No Hydrogen Sulfide Measures 0 Yes .g:No Directional Survey Required 121 Yes 0 No Required Working Pressure for BOPE b 2K 0 3K 0 4K 0 5K 0 10K 0 15K 0 3.5K psi for CTU Other: T~c;.t- B(1)E f-o ·~S-OO (Hi', 20. Attachments Approved By Form 10-40\~ JUN 2 7 2903 by order of aRrG1 N Ätommission Date t/2Jl'°3 Submit In Triplicate Well Plan Summary e Greater Prudhoe Bay Polaris W-205 Permit e IWell Name: W-205 I Type of Well (producer or injector): I SH Horizontal Producer Surface Location: FSL, 1,196' FEL, Sec. 21, T11 N, R12E / X = 612,048.97 Y = 5,958,680.13 1,359' FNL, 1,411' FEL, Sec. 22, T11 N, R11 E / X = 617,110 Y = 5,958,975 Z = 5,090' TVDss 3,407' FNL!, 1,81 (y FEL, Sec. 15, T11 N, R11 E / X = 616,655 Y = 5,962,200 Z = 5,150' TVDss W-205 Target Start: W-205 Target End: L AFE Number: I PLD5M1066 I Rig: I Nabors 9ES ./ I Estimated Start Date: I July 15m 2003 I Operating days to complete: 119.20 MD 110,681' I I TVDrkb: TD I 5,231' I I Max Inc. I 91 ° I I KBE I 80.90' Well Design: SH Grassroots Schrader Horizontal Producer. 4-%" BTC-M, L-80 Completion. ,/ Current Well Information General Well Name: API Number: Well Type: Current Status: BHP: BHT: W -205 50-029- ????? Development - Polaris Schrader Horizontal Producer New well, 20" X 34" insulated conductor 2,190 psi @ 4,900' TVDss (8.6 ppg EMW). Underpressured due to regional offtake. 100°F @ 4,900' TVDss Estimated Mechanical Condition W -205: Nabors 9ES: Conductor: Cellar Box above MSL = 52.4' KB / MSL = 28.5' 20" X 34", 215.5Ib/ft, A53 ERW set at 109' RKB Target Estimates Estimated Reserves: Expected Initial Rate: Expected 6 month avg: 700 mstb 2,100 bopd 1,020 bopd Final Approved 6/23/03 Materials Needed Surface Casing: Intermediate Casing: Production Liner: L-80 Completion: . Greater Prudho~ay Polaris W-205 Permit 4,010' 1 each 25 each 1 assembly 1 lot 1 each 10-3,4",45.5#, L-80 BTC Casing 10-3,4", BTC Float Shoe and Float Collar 10-3,4" x 13-Y2" Bow Spring Centralizers FMC 11" 5m Gen 5 Wellhead System 10-3,4" casing pups 5', 10', 20'. 1 0-3,4" TAM Port Collar 7,600' 1 each 60 each 10 each 2 lots 3 each 2 each 7-%" 29.7# L-80 BTC-M Casing 7-%" BTC-M Float Shoe and Float Collar 7-%" x 9- Ys" Rigid Straight Blade Centralizers 7-%" Stop Rings 7-%" casing pups 5', 10', 20' 7-%" RA Tag 7-%" 29.7# L-80 BTC-M Casing Short Joint 3,100' 80 each 7-%" x 4-W' 4-Y2" 1 each 4 W', 12.6#, L-80, IBT-Mod Slotted Liner 4 Y2" x 5 3,4" x 8" Straight Blade Centralizers Baker ZXP Liner Top Packer Baker guide shoe Halliburton 3-Y2" XN-Nipple (2.75" 10) 4-Y2" 12.6 Ib/ft, L-80, BTC-M tubing Baker PRM Production Packer 7" X 4-Y2" Halliburton X-Nipple (3.813" 10) 4-Y2" Baker CMO Sliding Sleeve w/3.813" profile 11" X 4-Y2" FMC tubing hanger 4_1/16", 5m Cameron Tree Camco 4-W' X 1" KBMG Gas Lift Mandrels Camco 4- W' X 1 KBMG GLM w/memory gauge Camco 4- W' X 1 KBMG GLM w/OCK valve 4-Y2" WLEG 6,850' 1 each 4 each 1 each 1 each 1 each 3 each 1 each 1 each 1 each Surface and Anti-Collision Issues Surface Shut-in Wells: W -203 and W -12 do not need to be shut-in for the rig move on and off W -205. Close Approach Shut-in Wells: There are NO close approach wells requiring subsurface isolation for this profile. Close Approach Well List: Well Name Cth.Ctr Distance W -203 35.39-ft W-11 69.78-ft W-12 30.78-ft W-206 71.39-ft W -10 104.35-ft W -207 154.92-ft ""Reference MD' 389.16-ft 484.73-ft 641.04-ft 642.32-ft 736.59-ft 3,479.35-ft Allowable Deviation 29.07-ft 61.29-ft 17.03-ft 58.82-ft 88.31-ft 51.87-ft Precautionary Comment Use Traveling Cylinder (Gyro) Use Traveling Cylinder (Gyro) Use Traveling Cylinder (Gyro) Use Traveling Cylinder (Gyro) Use Traveling Cylinder (Gyro) Use Traveling Cylinder (Gyro) Mud Program Summary: 13-Y2" Surface Hole Mud Properties: I Spud - Freshwater Mud Interval I Density (ppg) Funnel vis YP Tauo PH Plastic Vis FL 0-1,700 8.6-9.2 250-300 50-70 10-18 8.5-9.0 20-45 NC-8 1,700-2,500 9.0-9.5 200-250 30-45 8-16 8.5-9.0 20-40 8 2,500 - 2,865 9.3 - 9.5 200 30 - 40 9 -14 8.5 - 9.0 14 - 20 5.5 - 8 9-%" Intermediate Hole Mud Properties: I Freshwater Mud (LSNO) PH: 9.0 - 9.5 ~~i~~:~;;~(ij~i~~f.~L~~; 1--·lftinõöt~~1(vJ;;i~j~:11~~- Interval I Density (ppg) I Stability I vp I Oil: H20 Ratio I PV I API Filtrate I MBT Interval 9.2 650 - 900 18 - 25 80: 20 15 - 20 4 - 5.5 < 6 2 Final Approved .. Greater Prudho.!..Bay Polaris W-205 Permit Formation Markers ..... ¡i,;; ';';;;;¡, FofmafiôÎ1 Tops:' i'/¡,i FtTVDss' Et ··M D····..);;;.;,;:, . 'Ft TVD Pore psn~ 'EMW (ppg) ~:;;,;;,J-Iydrocarbons'< SV5 1,825 2,180 1,906 821 8.7 No Base Permafrost 1,950 2,352 2,031 878 8.7 No SV4 1,970 2,380 2,051 887 8.7 Poss. Gas Hydr. SV3 2,500 3,109 2,581 1,125 8.7 Poss. Gas Hydr. SV2 2,705 3,391 2,786 1,217 8.7 Poss. Gas Hydr. SV1 3,025 3,860 3,106 1,361 8.7 Poss. Gas Hydr. UG4 3,390 4,407 3,471 1,575 8.9 Poss. Gas UG4A 3,435 4,504 3,536 1,585 8.9 Yes - Heavy Oil UG3 3,790 5,006 3,871 1,740 8.8 Yes - Heavy Oil UG1 4,250 5,695 4,331 1,940 8.8 Yes - Heavy Oil Ma 4,465 6,019 4,546 2,040 8.8 Yes Mb1 4,515 6,097 4,596 2,055 8.8 Maybe - Hvy Oil Mb2 4,575 6,193 4,656 2,070 8.7 Maybe - Hvy Oil Mc 4,635 6,292 4,716 2,095 8.7 Maybe - Hvy Oil Na 4,700 6,404 4,781 2,125 8.7 Yes Nb 4,730 6,458 4,811 2,135 8.7 Maybe - Hvy Oil Nc 4,785 6,561 4,866 2,150 8.6 Yes OA 4,900 6,802 4,981 2,190 8.6 Possibly or wet OBa 4,945 6,911 5,026 2,120 - 2,205 8.3 - 8.6* Yes c:¡.~ OBb 4,975 6,988 5,056 2,215 8.6 Yes OBc 5,030 7,156 5,111 2,235 8.5 Yes OBd 5,090 7,482 5,171 2,130 - 2,250 8.1 - 8.6* Yes TD (OBd) 5,150 10,681 5,231 2,169 - 2,303 8.1 - 8.6* Yes * The OBa and OBd sands could be slightly pressure depleted due to regional offtake. CasingfTubing Program Hole Size;; ,,',..... Csgl WtlFt Grade Co~ i ......tength rop Bottom <,Tbg O.D. /' MD I TVDrkb MD I TVDrkb 48" 20" X 34" 215.5# A53 Welded 80' 29' 1 29' 109' 1109' 13- %" 10-3,4" 45.5# l-80 BTC-M 3,981 29' 1 29' 4,010' 1 3,206' 9-%" 7-%" 29.7# l-80 BTC-M 7,573 29' 1 29' 7,602' 15,181' 6-3,4" 4-%" 12.6# l-80 IBT-M 3,079 7,602' 1 5,181 10,681' 1 5,231' Tubing 4-%" 12.6# l-80 IBT-M 6,821 29' 1 29' 6,850' 15,001' Cement Calculations Casing Size 1)0-3,4 -in 45.5-lb/ft l-80 BTC surface casing Basis 1250% excess in permafrost. 30% excess below permafrost. Top of tail cement 750' MD above shoe Total Cement Vol: Wash 20-bbl Water Spacer Spacer 75-bbI10. Igal Alpha spacer /:) lead 607-bbl, 2 ~x 10.7-lb/gal Permafrost l ~t;j/sx (cemen rface) ./ . ~i Tail 71-bbl, 4 sx 15.8-lb/gal Premium G 2% CaCl ~.. ;j/sx (top of I at 3,253-ft MD) . Temp I BHST =:: 55°F from SOR, BHCT 60"F estimated by Halliburton In the event that cement is not circulated to surface during the initial surface casing cement job, notify the AOGCC of the upcoming remedial cement work for possible witness of cement to surface. 3 Final Approved Greater Prudhoe Bay Polaris W-205 Permit Casing Size /7-% -in 29.7-lb/ft L-80 BTC intermediate casing " ' Basis Top of tail cement 700-ft MD above top of Schrader Ma-sand. 30% excess over gauge. Total Cement Vol: Wash 5-bbl Water Spacer 30-bb:E10 gal Alpha Spacer ~ Tail 118 b ',,541 x 15.8-lb/gal~emium G + LXT -~sx (top at 5,319-ft MD) Top Ma: 6,019' MD T emprŠHST';..120~F'f;~~SÖR, BHÒ,. gO°F ~;ti~~ted by H~I'~burton ..~,-", '. 10-%" Casing Centralizer Placement a) Run (25) 9-%" Bow-spring centralizers attached over the collar of each joint of casing from the casing shoe up to 3,003' MD (1,000' MD above the shoe). b) This centralizer program is subject to change pending actual hole conditions. 7-%" Casing Space Out a) Space 7-%" casing out with pups and long/short joints as required to place the top of a long full joint - 5- 15' above the top of the OBc and OBa sands to allow for the window to be milled just below the top of each sand and in the middle of a full joint of casing. b) Place 1 RA tag above the first window, 1 RA tag above the second window, and 1 RA tag above the third window. RA tags to be spaced out -40 - 80' above window depth. c) Emergency 7-%" casing slips can be used instead of the 7-%" mandrel hanger if required for space out. 7-%" String Centralizer Placement a) Centralizer size: 7-%" X 9-%" (this is different then the norm of W' under gauge hole) b) Do not run centralizers on the window joints spaced at the top of each sand. c) Place 2 rigid straight blade centralizers back to back at the very bottom of the shoe joint. Do not run any centralizers on the next two full joints (see illustration at the end of the wellplan). d) With the exception stated above, alternate 1 rigid straight vane cenralizer floating across a full joint and 2 rigid straight vane centralizers, one floating on the upper half of the joint and one floating on the lower half of the joint separated by a stop collar up to 6,468' MD (320' MD above the top OA sand). Then continue with 1 rigid straight vane centralizer per joint floating to 5,319' MD (700' MD above Ma sand). Zonal isolation with cement is required between the OBa and the OA sands due to the presence of water in the OA sand. The centralizer program is subject to change pending modeling and hole conditions. 4-%" Slotted Liner Centralizer Placement a) Run 1 straight blade rigid centralizers per joint, floating over the full joint. Bit Recommendations BHA,,:,:, Number;":' Surface Surface Interm. Prod. Hole Size and Section 13-%" 13-W 9-W' 6-%" Depths" (MD) 0' - 2,352' 2,352' - 4,010' 4,010' -7,602' 7,602' -10,681' / Nozzles K-Revs!."Hours Hughes MXC-1 Hughes MXC-1 TBD TBD 2x20 1x14 1x12 2x20 1x14 1x12 6x14 3x15 4 Final Approved It Survey and logging Program Greater Prudhoe Bay Polaris W-205 Permit - 13-%" Hole Section: Open Hole Drilling: Cased hole: 9-%" Hole Section: Open Hole Drilling: Open Hole: Cased Hole: 6-%" Hole Section: Open Hole Drilling: Cased Hole: Surface Gyro if needed (have discussion with ODE on photo or E-line Gyro) MWD / GR None Surveys will need to be IFR + MS corrected real time MWD / GR / Res / Den / Neu / PWD (Den Neu recorded only) / AIM DPC MDT (20 pressures + 8 Samples) USIT Bond Lo onl as contin enc if oor cement job Surveys will need to be IFR + MS corrected real time MWD / GR / Res / Azimuthal Den / Neu (Den/Neu recorded only) / AIM None Motors and Required Doglegs Motor Size 'and Motor Required,! 9-%" Anadrill A962M3445SP Mud Motor, 1.5° ABH with 12-14" string stabilizer 6-%" Anadrill A675M4570XP Mud motor, with 1.15° ABH with 7.0" string stabilizer 4-%" Anadrill A475M4570XP Mud motor, with 1.5° ABH with 5.0" string stabilizer ,BHA No. 1&2 3 4 Flåw..Rate 400 - 650 gpm 500 - 600 gpm 250 - 300 gpm 60 - 100 10°/100' build and turn & subsequent geosteer RPMs 40-60 'Required Doglegs 1.5° - 3.5°/100' initial 4°/100' final build 4°/100' build and turn 60 -120 Well Control Well control equipment consisting of 5,000 psi working pressure pipe rams(2), blind/shear rams, and annular preventer will be installed and are capable of handling the maximum potential surface pressures. Based upon calculations below, BOP equipment will be tested to 3,500 psi. / Diverter, BOPE and drilling fluid system schematics on file with the AOGCC. Production Section- · Maximum anticipated BHP: 2,190 psi @ 4,900' TVDss - Schrader · Maximum surface pressure: 1,700 psi @ surface / (based on BHP and a full column of gas from TO @ 0.10 psi/ft) · Planned BOP test pressure: . Planned completion fluid: 3,500 psi (the 7-%" casing will be tested to 3,500 psi) /' Estimated 9.2 ppg Brine / 6.8 ppg Diesel 'TltI" '·.n.fi5I_~,'; 'ilV~.,\.¡¡ , ,^""o,,:¡,,.,.,.,,,Jllililb.,._,.,.%./ ,_.,,", _,.___ __I.,____~%",... ,;.,:.^ 3,500/250 psi Rams & Valves 3,500/250 psi Annular r . / Disposal · No annular injection in this well. · Cuttings Handling: Cuttings generated from drilling operations will be hauled to grind and inject at DS-04. Any metal cuttings will be sent to the North Slope Borough. · Fluid Handling: Haul all drilling and completion fluids and other Class II wastes to DS-04 for injection. Haul all Class I waste to Pad 3 for disposal. 5 Final Approved ., DrillinQ Hazards and ContinQencies Gr~~ter Prudhoe B~y Polaris W-205 Permit POST THIS NOTICE IN THE DOGHOUSE I. Well Control A. The Schrader in this fault block is expected to be underpressured at 8.6 ppg EMW. This pressure is estimated based on offset well pressures and material balance. II. Hydrates and Shallow gas A. Gas hydrates are present below W-pad, but have not been a significant issue thus far during W-Pad drilling. If hydrates are encountered follow the recommended practice and apply good drilling operational practices. III. Lost Circulation/Breathing A. Lost circulation is unlikely within the Schrader interval. B. We do not expect breathing on this well as we are above the more prevalent breathing shale's i.e. Seabee. IV. Kick Tolerancellntegrity Testing A. The 10-%" casing will be cemented to surface. B. The 7-%" casing will be cemented with 15.6Ib/g al cement to 700' MD above the Ma sand -5,361' MD. C. The Kick Tolerance for the surface casing is .6 Is with 9.2 ppg mud, 11.5 ppg LOT, and an 8.8 ppg pore pressure. If the LOT is less then 10.7 pp ,t e kick tolerance will be < 50 bbls. D. The Kick Tolerance for the intermediate casing is' fini with 9.2 ppg mud, 11.5 ppg LOT, and an 8.8 ppg pore pressure. If the FIT is less then 9.6 ppg EM ,t the kick tolerance will be < infinite. E. Integrity Testing 10-3,4 -in shoe 7-% -in shoe 20-ft minimum from 10-%--in shoe 20-ft minimum from 7-%--in shoe LOT FIT 11.5 minimum 11.5 minimum V. Stuck Pipe A. We do not expect stuck pipe. B. There could be slight differential sticking issues across the Ugnu. Centralizers will be run to mitigate. VI. Hydrogen Sulfide / A. W Pad is not designated as an H2S site, however Standard Operating Procedures for H2S precautions should be followed at all times. Water injection on W-Pad was initiated in late 2001, and H2S levels are expected to remain low until the waterflood matures. Recent H2S data from the pad is as follows: B. Adjacent producers at Surface: a. W -12: less than 8 ppm b. W -203: 0 ppm C. Adjacent producers at TD: a. W -200: 0 ppm D. The maximum recorded level of H2S on the pad was under 20 ppm. VII. Faults A. One fault is planned to be crossed up in the UGNU after the surface casing shoe. This fault has been crossed on numerous wells and is not expected to cause any drilling problems. The fault details are listed below for reference: Fault #1: 5,950' MD 4,500' TVD 4,419' TVDss Throw: 50' West CONSULT THE W PAD DATA SHEET AND THE WELL PLAN FOR ADDITIONAL INFORMATION 6 Final Approved .. Greater Prudhoe Bay Polaris W-205 Permit .. e Drill and Complete Procedure Summary Pre-Rh?: Work: 1. A 34" x 20" insulated conductor has already been set and surveyed. 2. Weld an FMC landing ring for the FMC Gen 5 Wellhead on the conductor. 3. If necessary, level the pad and prepare location for rig move. Prepare neighboring wells for the rig move and simops production. Riq Operations: 1. MIRU Nabors 9ES / 2. Nipple up diverter spool and riser. Function test diverter. PU 4" DP as required and stand back in derrick. 3. MU 13-%" drilling assembly with MWD/GR and directionally drill surface hole to approximately 4,010' MD 13,206' TVD. The actual surface hole TD will be +1-100' TVD below the top of the SV1 sand. /" 4. Run and cement the 10-%", 45.5# L-80 surface casing back to surface. Will use TAM p07"ar. 5. ND drilling spool and riser and NU casing 1 tubing head. NU BOPE and test to 3,500 psi. 6. MU 9-~" directional drilling assembly with MWD/GR/Res/Den/Neu/AIM/PWD and a Weatherford Drill-Mill at ±800' from the bit in the HWDP section RIH to float collar. Test the 10-%" casing to 3,500 psi for 30 minutes. /"' 7. Drill out shoe track. Circulate and condition mud. Displace well to new LSND drilling fluid. Drill 20' of new formation below rathole and perform an LOT. 8. Directionally drill ahead to TD (-120' MD below the Top OBd) as per directional profile to 7,602' MD /5,181' TVD. / 9. POOH for open hole DPC MDT, standing back 4" DP, LD drilling BHA 10. RU Schlumberger and run a DPC MDT to collect fluid samples and pressure readings in the OBd, OBc, OBb, OBa, and OA sands. Sample depths to be determined based on real time GRlRes data (planned to acquire 20 pressures and 8 fluid samples). 11. MU 9-~" cleanout assembly and RIH to TD. Work tight spots as seen. Circulate and condition mud at TD. Make sure hole is clean prior to POOH. 12. POOH. Standing back 4" drillpipe. Retrieve bowl protector. 13. MU and run 7-%" 29.7# L-80 BTC long string casing to TD. Cement in one stage to 700' MD above the Schrader Ma (6,019' MD) sand. Bump plug with seawater. Land casing on mandrel hanger. / - 14. Clean pits for displacement. Freeze protect 7-%" x 10-%" annulus with dead crude to 2,200' TVD. 15. PU 6-%" directional assembly with MW DIG R/Resl Azimuthal Den INeu/AIM/PWD and RIH to the float collar picking up 4" DP on the way. Test the 7-%" casing to 3,500 psi for 30 minutes. / 16. Displace well over to new Versapro MOBM. Drill out shoe track, circulate and co~ition mud. / 17. Drill 20' of new formation below rathole and perform an FIT to 11.5 ppg EMW. 18. Directionally drill ahead to TD geosteering through the OBd to TD at 10,681' MD 15,231' TVD (prognosed). 19. Perform wiper trip, circulate and condition mud and POH. Lay down excess drillpipe. 20. MU and run 4-%" 12.6# L-80 BTC-M slotted liner with hanger and liner top packer to TD. 21. PU off liner hanger and circulate and condition mud. Clean pits for displacement. 22. Displace over to 9.2 ppg KCL brine above liner top packer. 23. MU 4-%" 12.6# BTC-M, L-80 completion assembly and RIH. See completion schematic for details. 24. Land tubing hanger and run in lockdown screws. Reverse in brine with Corexit to protect the annulus. 25. Drop RHC ball and rod and set packer as per Baker recommendation and test tubing to 3,500 psi and annulus to . 3,500 psi. Shear DCK-1 valve. / 26. Install two-way check and test to 1,000 psi. Nipple down the BOPE. Nipple up and test the tree to 5,000 psi. 27. Pull two-way check. Freeze protect the well to 2,200' TVD. Install VR plug in 7-%" casing annulus valve. 28. Install BPV. Secure the well and rig down 1 move off Nabors-9ES. Post-Riq Work: 1. MIRU slickline. Pull the ball and rod 1 RHC plug. 2. Pull out DCK-1 shear valve, install DV in the mandrel as per the PE. 3. Test OBd for production as per the strategy. 7 Final Approved Job 1: MIRU: ., Greater Prudho~ay Polaris W-205 Permit , Critical Issues: Þ> Ensure the starting head has been welded on the conductor at the right height and there is adequate space to NU the diverter and subsequently the BOP once the rig is spotted (LL on W-212i). Confirm this requirement prior to the rig moving over the well. Verify that the Diverter does not require any additional spacer spools as well. Þ> Ensure the AOGCC receives 24-hour advance notification of the diverter test and subsequent BOP tests. Þ> W-203 and W-12 will not need to be shut in at the surface prior to the W-205 rig move. The well houses may not need to be removed off of W -203 and W -12 depending on how comfortable the rig team feels moving over W -205. All surface flowlines and gas lift lines will not need to be depressurized to header pressure. Discuss the move at a pre-job safety meeting and designate a spotter to ensure there is no danger of a collision. Nearby Wens Distance to Tar~et Well Rig N9ES Wellhead Separation W-203 34.97 4.97 . W-l2 34.94 4.94 Þ> W Pad is not designated as an H2S site, however Standard Operating Procedures for H2S precautions should be followed at all times. Water injection on W-Pad was initiated in late 2001, and H2S levels are expected to remain low until the waterflood matures. Recent H2S data from the pad is as follows: Adjacent producers at Surface: W -12: less than 8 ppm W -203: 0 ppm Adjacent producers at TD: W -200: 0 ppm The maximum recorded level of H2S on the pad was under 20 ppm. Reference RPs .:. "Drilling/ Work over Close Proximity Surface and Subsurface Wells Procedure" ~.';':;!J¡';;¡;~-~~o-;;!¡;;;'o~. Job 2: Drill 13-1h" Surface Hole: / Critical Issues: Þ> At W-Pad, no significant surface hole drilling problems have been identified. Minor tight hole has been encountered in the clay sections below the permafrost, some lost circulation thought to be in conjunction with the tight hole, possible packing off has been encountered. Þ> Close Approach: No wells are required to be shut in. There are several close tolerance wells in the surface interval. Follow the traveling cylinder / no-go plot per established procedures. Need to run a gyro to a minimum depth of 500' with a maximum depth of 1,000' MD. Magnetic interference is expected to be nonexistent by 1,000' MD. Þ> Directional: Every effort should be made to ensure a 'smooth' well profile that will benefit torque / drag in the later hole sections. A graduated build profile is planned. Obiective is to keep DLS :S;1° over planned. Þ> Hole Cleaning: Good hole cleaning practices will be critical to the success of the well. Surface rotary speeds should be maximized wherever possible. The BHA is limited to 60 to 80-rpm because of the 1.50 motor bend. Vary flowrates 400-650 GPM to achieve the required directional response. However it will be possible at TD to raise the rotary speed to +1 OO-rpm prior to POOH to run casing. At this time flowrates should be increased to 650 -700 GPM to increase hole cleaning. Þ> Drill Pipe specs: from Premium classification, not New. Adjusted weight: 17.39 #/ft 4",15.7#, HT-40, 'S-135' ID Collapse 100% 3.24 18,593 psi 80% 2.688(tool joint) 14,874 psi ***Max Recommended MU Torque: 20,200 ft-Ibs ***Min Recommended MU Torque: 14,100 ft-Ibs 8 Burst Torsional Tensile 21,331 psi 33,600 Ibs 456,900 Ibs 17,065 psi 26,8801bs 365,5201bs Fluid Capacity: 0.419 gaVft Fluid Displacement: 0.266 gal/ft Final Approved /" Greater Prudhoe~ay Polaris W-205 Permit . .... ~ Tight spots: During short trips, work out any tight spots as they are seen IÌVnile pulling out of the hole instead of waiting and reaming them out after running back in the hole as this could lead to accidental sidetracking. Consider back-reaming across initial tight spots only if washing does not alleviate the problem. ~ Critical LWD Tools: It is critical for the landing of this hole section to have the GR to pick the top of the SV1 sand. If this tool fails, it will require an immediate trip out of the hole to replace. It is imperative that the surface casing isolates the upper section of the SV1 sands. In order to do this the casing will need to be set -100' TVD below the top of the SV1 sand in the shale. Reference RPs: .:. "Prudhoe Bay Directional Guidelinesn .:. "Well Control Operations Station Bilr .:. Follow Schlumberger logging practices and recommendations Job 3: Run 10-3,4" Surface CasinQ: / Critical Issues ~ Casing to bottom: It is imperative the casing is set in the shale below the SV1 sands to ensure well bore integrity for the intermediate interval. It may be desirable to stop and roll the mud over half way in the hole to break the gels and reduce surging intensity on the SV sands. This will also help to insure circulation is attained at TD at the desired cementing rates without losses. ~ Casing drift: 10-%" special drift casing is being used. Ensure that casing equipment is properly drifted to ensure adequate ID for the 9-%" bit, Le. float equipment, casing hanger, etc. ~ Cement to surface: A single-stage job will be done on this well using 250% excess in the permafrost and 30% excess below the permafrost. As we will be downsizing the nozzles on the bit this may increase hole erosion slightly due to the extra nozzle velocity. A TAM Port collar will be utilized. ~ Losses during cement job: At W-Pad lost circulation has been experienced while running and cementing surface casing on past wells. The expected frac gradient for the shale below the SV1 sands is 12.5-lb/gal EMW. Follow the Halliburton recommended pumping rates as they have modeled the expected ECD's during the entire cement job to help mitigate the potential for breaking down the formations. Reference RPs .:. "Casing and Liner Running Proceduren .:. "Surface Casing and Cementing Guidelines" .:. "Surface Casing Port Collar Procedure" Job 4: Drill 9-%" Intermediate Hole: / Critical Issues ~ Differential Sticking could be a problem if lost circulation is occurring or if the drill string is left stationary for an extended period or time across the permeable Schrader Sands. ~ LOT: Perform a lOT (minimum 11.5 ppg EMW to satisfy kick tolerance). KICK TOLERANCE: Based upon the expected Schrader reservoir pressure of 8.8 ppg and a 9.2 ppg mud, an 11.5 ppg leak-off will provide just under 100 bbls of kick tolerance. Contact Anchorage personnel if LOT is less than 11.5 ppg. Based upon off-set drilling data on W-Pad, a minimum leak-off of 12.5 ppg is expected at the 10-%" shoe. ~ 7-%" casing landing point: The landing point for the 7-%" casing will be determined by depth based on changes in GR/Res curves associated with the top of the OBd sand. After seeing the top OBd, TD will be picked based on drilling 120' MD past this pick. This footage is critical for future wellwork. If tops are coming in 100' or more out from prognosis, then conduct a short trip and notify town. A Rigsite Geologist will be required on site to pick casing point. ~ Torque: Modeling indicates that high torque values, in the 11,000 to 14,500-ft.lb range can be expected by section TD. Minimize the use of lubricants within this hole interval due to the MDT logging requirements. If weight transfer problems are encountered during sliding, attempt to circulate and rotate for a minimum of 2 BU to test if lubricants are truly needed or if the hole is loading up with cuttings. ~ Critical LWD Tools: It is critical to have the GR tool in order to pick the landing point for this hole section. 9 Final Approved Greate~. Prudhoe Bay Polaris W-205 Permit . , The landing of this well will depend on picking the top of the OBd sand which will be picked by Gamma Ray. If we loose the GR tool, we will need to trip for it. ~ Faults: There is one major fault that will be crossed in this hole section: Fault #1: 5,950' MD 4,500' TVD 4,419' TVDss Throw: 50' West ~ Directional Constraints: It is critical to not let the angle get any higher then planned, due to slickline access requirements and junction requirements. It is critical to design a BHA to minimize inclination walking tendencies and thus minimize wellbore tortuousity. DLS should be kept :;;1 ° over planned. ~ Survey program per JORPS: Dogleg Severity Survey Frequency <1 °/1 00' 90'{Every stand, not exceeding 100') 1 ° - 5°/100' 90'{Every stand, not exceeding 100') >5°/100' 30'{Every joint) Reference RPs .:. Standard Operating Procedure for Leak-off and Formation Integrity Tests .:. Prudhoe Bay Directional Guidelines .:. Lubricants for Torque and Drag Management. Job 5: Loq Intermediate Hole (DPC MDTI: Critical Issues ~ The base plan consists of one DP conveyed MDT run to obtain pressure readings and fluid samples in the OBd, OBc, OBb, OBa, and OA sands. Sample depths will be determined based on real time GR/Res data. It is planned to acquire 20 pressures and 8 fluid samples from these sands and or the sands above the 0 sands if time allows. ~ The minimum fluid sample requirements would be acquire fluid samples from the OA, OBa, OBb and OBd sands. Pressure requirements would be to obtain pressures in the upper sand intervals that we did not get samples in, Le. the M, N, and Ugnu sand intervals to complete the Schrader / Ugnu pressure profiles. ~ Due to the 9-W' hole size a modified open hole dual packer will be needed to obtain the isolation during the fluid sampling. Ensure Schlumberger has the right hook-up to conduct this logging operation in the 9-%" hole. ~ Run an open hole caliper to redefine hole volume for cement excess. ~ Ensure a back-up tool and packer assembly is available in case a failure is encountered. Reference RPs .:. "Drillpipe Conveyed Logging" .:. Follow Schlumberger logging practices and recommendations Job 5: Run and Cement 7-%" Intermediate Casinq Critical Issues ~ Cement Job: It is imperative to achieve a good cement job on this well due to the water wet OA sand and the junction requirements. Good zonal isolation of these sands is imperative to the production success of this well. Therefore reciprocate pipe as long as possible while cementing. A USIT log will be run to confirm the quality of the cement job between the sands if any problems are encountered during the cement job. Keep cementing ECO's below 12.5 ppg EMW during the displacement. ~ Casing Space out: There are 3 important space out zones for this casing run: o There must be a long full joint of casing just starting above the top of the OBa and OBc sands so that the multi-lateral junction window can be milled out as close to the top of the respective sands in the top/middle of a full joint of casing. Run full casing joints across the OBa and OBc sands. Any casing pup joints required for space out should be placed below the base of the sands. o The shoe must be within 10 feet of the bottom when the casing is cemented in place. o The mandrel hanger must be spaced out correctly at surface if it is to be used. Emergency slips may 10 Final Approved / - . be used if necessary to achieve proper space out. Þ Freeze Protection: Ensure the lower production cement has reached at least a 70BC thickening value prior to freeze protecting. After freeze protecting the 7-%" x 10-%" casing outer annulus with 87 bbls of dead crude (2,200' MD, 2,000'TVD), the hydrostatic pressure will be 7.8 ppg vs 8.5 ppg EMW of the formation pressure immediately below the shoe. Ensure a double-barrier at the surface on the annulus exists until the cement has set up for at least 12 hours. Trapped annulus pressure may be present after pumping the dead crude as the hydrostatic pressure of the mud and crude could be 100 psi underbalance to the open hole. (A second LOT will be required prior to displacing freeze protect. This to satisfy AOGCC for future annular pumping permits.) ~ Centralization/Differential Sticking: See centralizer strategy under Section 3: Drilling Program Overview. Differential Sticking could be a problem if lost circulation is occurring or if the casing is left stationary for an extended period or time across the permeable sands. Ensure the casing is centralized across any permeable zones if the casing is left stationary while running in the hole. Þ RA Tags: There will need to be 3 RA tags placed in the 7-%" casing for depth control. Placement strategy is-40 - 80' above each of the respective sands: Pip #1 : Top OBa sand, Pip #2: Top OBc sand, Pip #3: Top OBd sand. Greater Prudhoe...Jiay Polaris W-205 Permit Þ Mud Requirements: Thin the mud as per MI's Mud Program. The thinner the mud the better displacement is achieved and the better the cement job will be. Extra time spent circulating is warranted to ensure optimum mud properties and hole cleaning prior to the cement job. Þ Franks Casing Fill-up tool: Make sure that a casing fill up tool is on location prior to PU 7-%" casing. Þ TIW Valve: Ensure that a TIW valve with a cross over to 7-%" BTC casing is on the rig floor Reference RPs .:. "Intermediate Casing and Cementing Guidelines" .:. "Freeze Protecting an Outer Annulus" Job 6: 6-%" Lower Lateral (OBd Sand) Critical Issues Þ Geosteering: Geosteering in the lateral intervals is expected to be the most challenging aspect of this well. Anadrill AIM will be used and should help mitigate some of this challenge. A 1.50 bent housing motor will be used to help proactively make corrections quicker to avoid unnecessary undulations throughout this interval. There will be a rigsite geologist on location to help with interpretations. The projected formation sand thickness and 'sweet spot' thickness for the OBd sand is listed below for reference: o The OBd sand target is expected to consist of a 20 to 30 foot thick net sand interval, which lies in the upper half of the 65 foot thick OBd parasequence. Within the total 20 to 30 foot thick OBd net sand/net pay target interval, the primary OBd target interval consists of an 8 to 14 foot thick high permeability sand body (300-900 md.) which lies -15 feet below the OBd sand top. The W-205 OBd high angle well section is targeted to drill within this high permeability interval over approximately 60- 70% of the total length of the W-205 polygon. Þ Surveying: Survey density is critical to achieve vertical positional certainty. It is recommended to survey every 30-45' to ensure accurate vertical positional certainty throughout the horizontal section. This survey density should alleviate the errors associated with vertical section creep. Þ ECDlHole Cleaning: Utilize PWD to monitor for good hole cleaning and ECD trends. Cuttings will tend to dune up at the window due to hole geometry. Planned ECD hardline 11.5 ppg EMW. Þ FIT: An FIT of 11.5 ppg EMW is required at the 7-%" shoe. The expected frac gradient for the Schrader is 12.5 ppg EMW. Reference RPs: .:. "Prudhoe Bay Directional Guidelines" .:. "Standard Operating Procedure: Leak-off and Formation Integrity Tests" 11 Final Approved · Job 7: Run 4-%" Slotted Liner (OBd Sand) ----º!~ater Prudhoe Bay Polaris W-205 Permit Critical Issues ~ Liner to bottom: It is imperative that we get this liner to bottom to allow for adequate space-out for the OBc lateral. Liner on bottom will also prevent the sand from collapsing, keeping the entire drilled section in tact, thus capturing all of the reserves possible for this section length. ~ Innerstring: The innerstring should not be needed to help insure the success of getting the liner on bottom. Innerstrings have not been used in Schrader Multilats in Milne for quite some time due to the lack of utilization and the extra weight associated with running them. The use of the innerstring will ultimately be as a contingency only based on actual hole conditions. ~ Centralizer Placement (5-%" OD): o See centralizer strategy on page 4. Do not run any in the liner lap. ~ 4-%" Rams: Keep VBR's in. Can also utilize annular if necessary. ~ Have a Baker completion specialists onsite to engineer and supervise this liner job. 4 W', 12.6#, L-80 IBT-M 100% 80% ID (drift) 3.833 Collapse N/A N/A Burst N/A N/A Tensile 288,000 Ibs 230,4001bs ~ Connection make-up information: o 4-%" IBT - makeup to position Reference RPs: .:. "None Apply" Job 12: Run 4-~" Completion: Critical Issues ~ Thread Dope: BOL 2000 NM or BOL 2000 is the BP approved thread compound for Carbon API connections. All IBT-M pipe should arrive on location with one of these two thread compounds. It would still be good practice to look over each connection in the pipe shed prior to incorporating them into the tally. þ> Shear Valve: We will switch from an RP shear valve to a DCK shear valve due to the RP shear valve failure on numerous wells. The DCK shear valve has had good success due to the locking mechanism that keeps the sleeve from migrating back down over the ports after the tool is sheared open. This valve does require a higher differential pressure to open. Reference RP .:. "Completion Design and Running" RP .:. "Tubing connections" RP Job 13: ND/NUlRelease Riq: Critical Issues ~ See Job 1 for adjacent well spacing. Identify hazards in a pre move meeting, and take every precaution to ensure good communication prior to beginning the rig move. Use spotters when moving the rig. ~ Diesel: Diesel will be used to freeze protect the well. The diesel flash point is 1000 F. Diesel vapor pressure is - 0.1 psia at 1000 F. Reference RP .:. "Freeze Protecting an Inner Annulus" RP "- 12 Final Approved POST-COMPLETION W-205 OBd Only .e TREE: FMC 4-1/16" 5M WELLHEAD: FMC Gen 5 System 11", 5M csg.head wI?" mandrel hanger & packoff 11" x 11", 5M, tbg spool w/ 11" x 4-1/2" tubing hanger with control line ports 11" X4-1/16" Adaptor Flange -I Orig KB elev (N-9ES) = 28.5' .. ... 20" X 34" 215.5Ib/ft, A53 ERW Insulated I 109' .--- --- Halliburton X-Nipple (3.813" ID) /2,200' TVD I 4-1/2", 12.6 Ib/ft, L-80, BTC-M Coupling OD: 5.2" Drift/ID: 3.833"13.958" ..... 10-3/4",45.5# L-80 BTC Csg @4,010' MD Cameo gas lift mandrel 4-1/2" x 1" KBG2 With DCR Shear Valve in mandrel above packer 2,500' TVD, 2 & 4 joints above the sliding sleeve, & just above WLEG 7-5/8",29.7#, L-80, BTC-M Casing Drift: 6.75" Casing ID: 6.875" 4.5" Baker CMO sliding sleeve with 3.813" 10 7-5/8" X 4-1/2" Baker PRM Packer Halliburton X-Nipple (3.813" 10) 4.5" WLEG I -6,000' I Tubel Downhole Pressure gauge Baker ZXP Liner Top Packer & Hanger @ 7-5/8" Casing Shoe @ 7,602' MO 6-3/4" OBd Lateral 17,602'-10,6811 DATE REV. BY COMMENTS GI6JtIt'f .P.mdhlleBì;if 6/2312003 MIK TRIOLO OBd Lateral Completion Polaris WELL: W-205 API NO: 5O~29-XXXXX~O WEU MagneticPinmetef8 Model: BGGM 2002 ò C> c:q II CD (;j <..> en o ¡:: e e Schlumberger W-205 FIElD STRUCTURE W-PAD Prudhoe Bay Unit - WOA Dip: 80.780" Mag Dee: +25.557' ...... Lo<aIIon ...: N7017.t5.811 Lon: W149 5 33.633 NAD27 Alaska State PIanes,Zone04, US Feet Noc1hing: 5958680.13ftUS GridConY; +0,85420613' Easting: 612048.WftUS Scale Fad:: 0.9999142622 TVD Ref: KB (80.90 fI. above MSl) &vy Date: August 05, 2003 """""""'" Slot: F'lanW-105 Pfa'I: W-205(P6) [)ale: ~05.2003 FS: 57525.8 nT o 800 1600 2400 3200 4000 4800 o · . · . · . . . . . . . . H..,......U·....·······..·..··········1········..·..··········..·········..r·······..·....·······......·········~..·······......·······......········f·..··········..·········..·..·······f.·..··········..············....·····r··..·········....·······.. 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US Feet I MIscellaneou. ...,.., BGGM2002 DIp, 80.780' Dale; AugustO!5,2003 Lat N7011<4M11 Northing: 5958680.13nus Grid Conv: +0.85420613" Slot PlanW-205 TVD Ref: KB (80.90 ft above MSl) MagOec: +25.557' FS: 57525.8nT Lon; W149533.633 Eastlng: 812048.97ftUS Scale Fact: 0.9999142622 Plan: W-205(P6) SrvyDate:Junø11.2003 3200 e 2400 1600 800 e 0 -800 6400 6400 5600 · . · . · . · . . · . . · . . . · . . . · . . . · . . . · . . . · . . . · . . . .."....... 'l"'¡~"I"""""""I""""""'''''''L..J.. -.. i F.~~~J '1'-"~I·"I·lt~~J:\~~~"~r'" · . .' . _..m íV" . , ' " ' ,"~,,7íJ"-- \ """''''.',"'''''''''''''' , ' " .m~m'~" \ i ...~~~ , ' . i ' ... ~.~ ". ~:: : 8~99' 340.9S0az. . ' ' " ' -,~, \' -..... ........... ........." ........ i i i ii' \ i·....· · .............' .' .' ..' .~~~~ , . .......... ...,...."......."".."... " ,,\ , "~ ~- · . ......."....' .' ~.m,".. i ¡ ¡"""I ,,,+,,..11" ."LL. ~!.f m.~ , ' ' ' ' ,'''"''''W ' " ~...~_.." , ' ' ' ' ,':i.o¡;.~~,- . , - . mo'" , ' ' ' ' ' . I-+- :'~~#j,ii~~~j:.~;~~~I~;=='JI"j št.".1 I ~;~.M Y. : N=OE=1717 : 46.11 90.65·a' 4010~O"Pt : .: ~"....',....'¡""'''~''':-' . . : : '\. '.._.= ..".. _"0" ' ,- ""'''''''''''' , ' ' ' " 0..·. .., ." ' ' · ...~-~ : : ¡ : \ J =-4 g=2134 5603 MO 4400 TV~ 6920 MO 5029 TY~ : ' : 66.63' 20.70'" i ' ' ' i "." ....." · ". .,,~ ' i ,"""."" , " ,'-". ...-,. ~.:;' : r..".""........"".............. i i ; ¡ \.;, I i , , ¡ , : ' : ,,¡ ..":.'ii\......o " .,' - ,...,.~. , \ ' .... ......... . ' . . -.. : EndCrv ¡ ;;r..:....".. ........".".".." ¡ ..... ¡ i ._ ....¡.. ' ' ". '0 '" .~. : 43.36' 69 95'~ 0 : \ ................. ¡S22 MD: 5183 TVD ¡ N=.1 E=4'6 ¡ 5561 CN 41100 ¡ ..... N~~r.~:.~ez....................... " ~ .~..o ' ' " ~"._. ' ' " ~.,,_ ..~m.':'.~ " " ' .0' ..~. ~.,",œ.~ ' ,l ' ,.~..... .~ "i..\:!:' ..0 , i -.~~ I o 5600 4800 4000 4800 4000 .. 3200 2400 3200 <<< W Scale = 1 :800(ft) E >>> 2400 1600 1600 800 800 o 3200 2400 o -800 1600 800 ^ ^ ^ z e- o o <;q ~ 11 Q) ë5 <.> C/) C/) v v v ~ Õ 4500 0 'R II Q) ro () (/) 0 > I- 5000 bp Schlumberger WELL FIELD Prudhoe Bay Unit - WOA STRUCTURE W-PAD W-205 Magnelic~arameters Model: BGGM2002 SurfaceLocalion Lilt: N70114S.811 Lon: W149 5 33.633 NAD21 Alaska state Plane&, Zone 04, US Feet Northing: 5958680.13 nus Grid Conv; +().85420613' EasUng: 612048.97 nus Scale Fact: 0.9999142622 MIsceIIaO&OUl Slot: PlanW·205 Plan: W·205(P6) Dip: 80.780' MagDec: +25.557' Date: August 05. 2003 FS: 57525.8n1 TVD Ref: KB (80.90 II. above MSl) StvyOate; June1',2003 o 500 1000 1500 2000 2500 3000 3500 4000 f"205 (P6) e 4000 ·"-···········-···"-·····¡G3·Šðöåõ;'jrtVÓ·······-··-j····-"·"·"·"-"·"-"-":"·"-"·"·"·"·"·"-"1"·"-"-.....-..-..........¡-.....-...........-.......-¡-.............-·········"·1·····"············-···"··j····"·······"····"·"·"1 ............ ....................... t····..·..··········..ffi,~~~~~hv"..... .... ··....··········..·..t· .............. ............ ·····..··1···· .......... ······....·········..·t··· ......................... ····..··1·..·······.... ... ..................+.............................. ··...1..··· ............... .......... ······1 I /'6d";;;::144031vD I ¡ I I ¡ I ¡ ,V'""" 4804' :103 57'8Z : : : : : : : ---------~~:f::=------+--------+-------+--------I------------------r--------j ._.: 48;04' :103.57'az . ~ : : : : :. _. _i , .. J . "'-, .'--- .·"::.,·',,..~i·_.':"'......._ ... ___. ___ .. ..._......____._____.__._____ .__...1 -..-..-..... _. .-.....-.. '(1'2'91"m6""IVlr' - .._..~. \~~r.e~~,,=_ ..= ·~r. ~~~~o1~f"~. .t :., ~. .,'~"- ..~.. :..~., ~ ..~. '-.~~ .'~.. ....=...~.... .-.. -..-.....- '1-' .-.....-... ........... _. ·t..·..· ..-..~ ··~..~··=··=:·=1·=···..-······..·..····· ...~....... '·"·"·"·"·"·"1 ., "',''\1 - :~.~~~~ ~.4.i, .._ -.. - -.- : 8$.~3:·20;00az ët7-0:'3Ù":~ ..- : Š8"'9"'9~'~34Õ95:~z"'" 90.00° 341500az ¡ ~ ~ ¡. ~ '¡,'. '. .,...:" '..11 _ " . . _ . .: ... \ I .' _.. :..:.~_ ..__ .~_~.~.:_: ::___.::.: ~.J:c.:ó¡.:ar:~re :;1 '\\ " V "" ~ 6951 MD ~141~~ I ¡ End CÓ! '\ ¡ c.. 411.., "'-end C.. ¡ W-205 (p1) ¡ T~:6f~~' ~~"'TVD ; 6675° 57.26"a:z. 7·518" Cag pt ¡ Cry 4/100 8582 MD 5215 TVþ Target 3! 9186 MD 5241 TVD: 9836 MD 524.1 TVD ¡ 90.670 342.010az : 150 departu~ 7602 MD 5161 TVD: 7766 MD 5 En2d ~ro 7913 Mþ 5195 TVD 87.70° 3.22°~ 6952 M~ 5226T~D : 66.99" 340.95°a%: 90.67° 342.0,£°a% : 3451 departure ; -r-..~:~I-:.=::¡r-~~~"ì~==-I~=I-'"?..lmml-ml 5500 4000 4500 5000 e 5500 o 500 1000 1500 2000 2500 Vertical Section (ft) Azim = 0·, Scale = 1:500 Origin = 0 N/-S. 0 E/-W 3000 3500 4000 W-205 (P6) Proposal Schlumberger Report Date: June 11, 2003 Survey / DLS Computation Method: Minimum Curvature / Lubinski Client: BP Exploration Alaska Vertical Section Azimuth: 0.000° Field: Prudhoe Bay Unit - WOA (Drill Pads) 13 Vertical Section Origin: N 0.000 ft, E 0.000 ft Structure / Slot: W-PAD / Plan W-205 APproved 611' TVD Reference Datum: KB Well: Plan W-205 TVD Reference Elevation: 80.9 ft relative to MSL Borehole: W-205 OBd Sea Bed / Ground Level Elevation: 47.830 ft relative to MSL UWIIAPI#: 50029 Magnetic Declination: 25.557° Survey Name / Date: W-205 (P6) / June 11, 2003 Total Field Strength: 57525.794 nT Tort / AHD / DDI/ ERD ratio: 189.864° /8126.20 ft/6.498/1.551 Magnetic Dip: 80.780° Grid Coordinate System: NAD27 Alaska State Planes, Zone 04, US Feet Declination Date: August 05, 2003 Location LatlLong: N 70 1745.811, W 149 5 33.633 Magnetic Declination MOdel: BGGM 2002 Location Grid N/E Y!X: N 5958680.130 ftUS, E 612048.970 ftUS North Reference: True North e Grid Convergence Angle: '¡().85420613° Total Corr Mag North·) True North: +25.557" Grid Scale Factor: 0.99991426 Local Coordinates Referenced To: Well Head Comments Measured I Inclination I Azimuth I TVD I Sub-Sea TVD I Vertical I NS EW I DLS I Tool Face I Northing Eastlng latitude Longitude Depth Section (ft) (deg) (deg) (ft) (ft) (ft) (ft) (ft) (deg/100 ft) (deg) (ftUS) (ftUS) KBE 0.00 0.00 93.00 0.00 -80.90 0.00 0.00 0.00 0.00 93.00M 5958680.13 612048.97 N 70 1745.811 W 149 5 33.633 KOP Bid 1.5/100 300.00 0.00 93.00 300.00 219.10 0.00 0.00 0.00 0.00 93.00M 5958680.13 612048.97 N 701745.811 W 149 5 33.633 Cry 3.5/100 400.00 1.50 93.00 399.99 319.09 -0.07 -0.07 1.31 1.50 90.80M 5958680.08 612050.28 N 70 1745.810 W 149 5 33.595 500.00 5.00 90.80 499.81 418.91 -0.20 -0.20 6.97 3.50 90.42M 5958680.04 612055.94 N 701745.809 W 149 5 33.430 600.00 8.50 9û.42 599.10 518.20 -0.31 -0.31 18.72 3.50 -0.55G 5958680.10 612067.69 N 701745.808 W 149 5 33.087 700.00 12.00 90.25 697.49 616.59 -0.41 -0.41 36.51 3.50 -0.39G 5958680.26 612085.48 N 701745.807 W 149 5 32.569 800.00 15.50 90.16 794.61 713.71 -0.50 -0.50 60.27 3.50 O.OOG 5958680.53 612109.24 N 70 1745.806 W 149 5 31.876 900.00 19.00 90.11 890.10 809.20 -0.56 -0.56 89.92 3.50 O.OOG 5958680.91 612138.88 N 70 17 45.806 W 149 5 31.012 1000.00 22.50 90.06 983.60 902.70 -0.62 -0.62 125.34 3.50 O.OOG 5958681.38 612174.29 N 70 1745.805 W 149 5 29.980 1100.00 26.00 90.04 1074.77 993.87 -0.65 -0.65 166.40 3.50 O.OOG 5958681.96 612215.34 N 701745.805 W 149 5 28.783 1200.00 29.50 90.01 1163.25 1082.35 -0.67 -0.67 212.95 3.50 O.OOG 5958682.64 612261.89 N 70 17 45.804 W 149 5 27.426 1300.00 33.00 89.99 1248.73 1167.83 -0.67 -0.67 264.81 3.50 O.OOG 5958683.41 612313.74 N 70 1745.804 W149525., 1400.00 36.50 89.98 1330.89 1249.99 -0.66 -0.66 321.80 3.50 O.OOG 5958684.27 612370.72 N 70 1745.805 W149524. 1500.00 40.00 89.96 1409.41 1328.51 -0.63 -0.63 383.70 3.50 O.OOG 5958685.22 612432.60 N 70 1745.805 W 149 5 22.44 End Cry 1596.12 43.36 89.95 1481.19 1400.29 -0.58 -0.58 447.61 3.50 O.OOG 5958686.22 612496.50 N 70 1745.805 W 149 5 20.586 SV5 2180.30 43.36 89.95 1905.90 1825.00 -0.26 -0.26 848.71 0.00 O.OOG 5958692.53 612897.51 N 701745.808 W 149 5 8.895 Base Perm 2352.23 43.36 89.95 2030.90 1950.00 -0.16 -0.16 966.76 0.00 O.OOG 5958694.38 613015.54 N 70 1745.809 W 149 5 5.454 SV4 2379.74 43.36 89.95 2050.90 1970.00 -0.15 -0.15 985.65 0.00 O.OOG 5958694.68 613034.42 N 70 1745.809 W 149 5 4.904 SV3 3108.73 43.36 89.95 2580.90 2500.00 0.26 0.26 1486.18 0.00 O.OOG 5958702.54 613534.85 N 701745.812 W 149 4 50.315 SV2 3390.70 43.36 89.95 2785.90 2705.00 0.41 0.41 1679.78 0.00 O.OOG 5958705.58 613728.41 N 70 1745.813 W 149 4 44.672 Cry 4/100 3444.36 43.36 89.95 2824.91 2744.01 0.44 0.44 1716.62 0.00 6.19G 5958706.16 613765.24 N 70 1745.814 W 149 4 43.598 3500.00 45.58 90.29 2864.61 2783.71 0.36 0.36 1755.60 4.00 5.95G 5958706.66 613804.21 N 70 17 45.813 W 149 4 42.462 3560.93 48.00 90.63 2906.33 2825.43 0.00 0.00 1800.00 4.00 8.94G 5958706.96 613848.61 N 70 1745.809 W 149 4 41.168 End Cry 3563.75 48.11 90.65 2908.22 2827.32 -0.02 -0.02 1802.10 4.00 O.OOG 5958706.97 613850.71 N 70 1745.809 W149441.106 SV1 3859.83 48.11 90.65 3105.90 3025.00 -2.54 -2.54 2022.50 0.00 O.OOG 5958707.74 614071.10 N 70 1745.783 W 149 4 34.682 Version DO 3.1RT (d031rC399) 3.1RT Service Pack 2.03 Plan W-205\Plan W-205\W-205 OBd\W-205 (P6) Generated 6/11/2003 3:37 PM Page 1 of 3 Comments Measured I Inclination I Azimuth I TVD I Sub-Sea TVD I Vertical I NS EW I DLS I Tool Face I Northing Eastlng latitude Longitude Depth Section (ft) (deg) (deg) (ft) (ft) (ft) (ft) (ft) (deg/100 ft) (deg) (ftUS) (ftUS) 10-3/4" Csg Pt 4009.60 48.11 90.65 3205.90 3125.00 -3.81 -3.81 2133.98 0.00 O.OOG 5958708.13 614182.59 N 70 1745.771 W 149 431.433 UG4 4406.49 48.11 90.65 3470.90 3390.00 -7.18 -7.18 2429.43 0.00 O.OOG 5958709.17 614478.03 N 70 1745.737 W 149 4 22.821 UG4A 4503.84 48.11 90.65 3535.90 3455.00 -8.01 -8.01 2501.90 0.00 O.OOG 5958709.42 614550.49 N 70 1745.728 W 149 4 20.709 UG3 5005.58 48.11 90.65 3870.90 3790.00 -12.27 -12.27 2875.39 0.00 O.OOG 5958710.73 614923.97 N 701745.685 W 149 49.823 Crv 4/100 5561.33 48.11 90.65 4241.97 4161.07 -16.99 -16.99 3289.09 0.00 84.62G 5958712.18 615337.66 N 701745.637 W 149357.765 5600.00 48.27 92.72 4267.75 4186.85 -17.83 -17.83 3317.90 4.00 83.25G 5958711.76 615366.47 N 70 17 45.628 W 149 3 56.925 5643.04 48.50 95.00 4296.33 4215.43 -20.00 -20.00 3350.00 4.00 96.93G 5958710.07 615398.60 N 70 17 45.607 W 149 3 55.990 UG1 5695.09 48.28 97.77 4330.90 4250.00 -24.33 -24.33 3388.67 4.00 95.09G 5958706.32 615437.33 N 70 1745.564 W 149 3 54.862 5700.00 48.26 98.03 4334.16 4253.26 -24.83 -24.83 3392.30 4.00 94.92G 5958705.87 615440.96 N 70 1745.559 W 149 3 54.757 5800.00 48.05 103.39 4400.90 4320.00 -38.66 -38.66 3465.45 4.00 91.34G 5958693.14 615514.30 N 70 17 45.423 W 149 3 52.625 End Crv 5803.32 48.04 103.57 4403.12 4322.22 -39.24 -39.24 3467.85 4.00 O.OOG 5958692.60 615516.71 N 7017 45.417 W 149 3 52.5. Crv 4/100 5863.49 48.04 103.57 4443.35 4362.45 -49.74 -49.74 3511.34 0.00 -78.79G 5958682.75 615560.35 N 701745.314 W 149 3 51.2 5900.00 48.35 101.61 4467.69 4386.79 -55.67 -55.67 3537.90 4.10 -77.48G 5958677.21 615587.00 N 70 1745.255 W 149 3 50.51 6000.00 49.36 96.33 4533.51 4452.61 -67.37 -67.37 3612.24 4.10 -74.01G 5958666.62 615661.50 N 70 1745.140 W 149 3 48.347 Ma 6019.07 49.58 95.34 4545.90 4465.00 -68.85 -68.85 3626.66 4.10 -73.36G 5958665.36 615675.93 N 701745.125 W 149 3 47.926 Mb1 6096.95 50.56 91.38 4595.90 4515.00 -72.33 -72.33 3686.26 4.10 -70.82G 5958662.76 615735.58 N 70 1745.091 W 149 3 46.189 6100.00 50.60 91.23 4597.83 4516.93 -72.38 -72.38 3688.62 4.10 -70.72G 5958662.75 615737.93 N 70 17 45.090 W 149 3 46.121 Mb2 6192.80 51.95 86.66 4655.90 4575.00 -71.03 -71.03 3760.97 4.10 -67.87G 5958665.18 615810.25 N 701745.103 W 149 3 44.012 6200.00 52.06 86.32 4660.33 4579.43 -70.68 -70.68 3766.63 4.10 -67.65G 5958665.61 615815.91 N 70 1745.107 W 149 3 43.847 Me 6291.92 53.58 81.98 4715.90 4635.00 -63.19 -63.19 3839.45 4.10 -65.03G 5958674.18 615888.60 N 701745.180 W 149 3 41.724 6300.00 53.72 81.61 4720.69 4639.79 -62.26 -62.26 3845.89 4.10 -64.81G 5958675.21 615895.03 N 70 1745.189 W149341.536 6400.00 55.55 77.11 4778.59 4697.69 -47.18 -47.18 3925.99 4.10 -62.21G 5958691.48 615974.88 N 70 17 45.337 W 149 3 39.201 Na 6404.09 55.62 76.93 4780.90 4700.00 -46.43 -46.43 3929.27 4.10 -62.11G 5958692.29 615978. 15 N 70 1745.344 W 149 3 39.106 Nb 6457.94 56.68 74.60 4810.90 4730.00 -35.42 -35.42 3972.62 4.10 -60.81G 5958703.93 616021.33 N 70 1745.452 W 149 3 37.842 6500.00 57.53 72.81 4833.74 4752.84 -25.51 -25.51 4006.52 4.10 -59.84G 5958714.35 616055.07 N 70 17 45.550 W 149 3 36.854 Ne 6560.97 58.81 70.29 4865.90 4785.00 -9.11 -9.11 4055.65 4.10 -58.50G 5958731.48 616103.95 N 701745.711 W 149 3 35.422 6600.00 59.66 68.71 4885.86 4804.96 2.64 2.64 4087.06 4.10 -57.69G 5958743.69 616135.18 N 70 1745.826 W 149 3 34.506 6700.00 61.91 64.78 4934.68 4853.78 37.12 37.12 4167.20 4.10 -55.78G 5958779.36 616214.79 N 70 1746.165 W 149 3 32.169 6800.00 64.27 61.01 4979.95 4899.05 77.76 77.76 4246.54 4.10 -54.07G 5958821.18 616293.51 N 70 17 46.564 W 149 329.8it OA 6802.18 64.32 60.93 4980.90 4900.00 78.72 78.72 4248.26 4.10 -54.04G 5958822.16 616295.21 N 701746.573 W 149 3 29.8 6900.00 66.72 57.40 5021 .44 4940.54 124.35 124.35 4324.67 4.10 -52.57G 5958868.92 616370.92 N 70 1747.022 W 149 3 27.578 OBa Tgt 6911.34 67.00 57.00 5025.90 4945.00 130.00 130.00 4333.43 4.10 136.40G 5958874.70 616379.60 N 701747.077 W 149 3 27.323 OBa 6911.37 67.00 57.00 5025.91 4945.01 130.01 130.01 4333.45 4.00 136.40G 5958874.72 616379.62 N 70 1747.077 W 149327.322 End Crv 6920.09 66.75 57.26 5029.34 4948.44 134.37 134.37 4340.19 4.00 O.OOG 5958879.17 616386.30 N 70 1747.120 W 149 3 27.126 Crv 4/100 6950.75 66.75 57.26 5041.44 4960.54 149.60 149.60 4363.89 0.00 -32.48G 5958894.75 616409.76 N 70 17 47.270 W 149 3 26.435 OBb 6988.35 68.02 56.39 5055.90 4975.00 168.59 168.59 4392.93 4.00 -32.14G 5958914.17 616438.52 N 70 1747.457 W 149 3 25.588 7000.00 68.41 56.13 5060.22 4979.32 174.60 174.60 4401.93 4.00 -32.05G 5958920.32 616447.42 N 70 1747.516 W 149 3 25.325 7100.00 71.82 53.89 5094.24 5013.34 228.53 228.53 4478.94 4.00 -31.29G 5958975.38 616523.62 N 701748.046 W 149 3 23.080 OBe 7156.29 73.75 52.67 5110.90 5030.00 260.68 260.68 4522.04 4.00 -30.93G 5959008.17 616566.23 N 70 1748.361 W 149 3 21.823 7200.00 75.25 51.75 5122.58 5041.68 286.49 286.49 4555.32 4.00 -30.68G 5959034.46 616599.12 N 70 1748.615 W 149 3 20.852 7300.00 78.70 49.67 5145.12 5064.22 348.18 348.18 4630.70 4.00 -30.21G 5959097.27 616673.55 N 70 17 49.221 W 149 318.654 Version DO 3.1 RT ( d031 rC399 ) 3.1 RT Service Pack 2.03 Plan W-205\Plan W-205\W-205 OBd\W-205 (P6) Generated 6/11/2003 3:37 PM Page 2 of 3 Comments Measured I Inclination Azimuth I TVD I Sub-Sea TVD I Vertical I NS EW I DLS I Tool Face I Northing Easting latitude Longitude Depth Section (It) (deg) (deg) (It) (It) (ft) (It) (It) (degJ100 It) (deg) (ltUS) (ltUS) 7400.00 82.16 47.64 5161.75 5080.85 413.32 413.32 4704.70 4.00 -29.87G 5959163.50 616746.57 N 70 17 49.862 W 149 316.496 End Cry / OBd Tgt 7481.81 85.00 46.00 5170.90 5090.00 468.95 468.95 4763.97 4.00 O.OOG 5959220.00 616805.00 N 70 17 50.408 W 149 314.767 OBd 7481.93 85.00 46.00 5170.91 5090.01 469.03 469.03 4764.05 0.00 O.OOG 5959220.08 616805.08 N 701750.409 W 149 314.765 7-5/8" Csg Pt 7602.00 85.00 46.00 5181.38 5100.48 552.12 552.12 4850.10 0.00 O.OOG 5959304.44 616889.87 N 70 1751.226 W 149 3 12.255 Cry 10/100 7621.81 85.00 46.00 5183.10 5102.20 565.83 565.83 4864.29 0.00 -77.78G 5959318.36 616903.86 N 70 1751.360 W 149 311.841 7700.00 86.69 38.35 5188.77 5107.87 623.58 623.58 4916.60 10.00 -77.22G 5959376.88 616955.30 N 70 17 51.928 W 149 310.315 End Crv 7785.93 88.62 29.97 5192.29 5111.39 694.57 694.57 4964.76 10.00 O.OOG 5959448.57 617002.39 N 70 17 52.626 W 149 3 8.910 Crv 4/100 7913.01 88.62 29.97 5195.34 5114.44 804.63 804.63 5028.22 0.00 -90.07G 5959559.56 617064.19 N 70 17 53.708 W 149 3 7.058 8000.00 88.62 26.48 5197.43 5116.53 881.24 881.24 5069.34 4.00 -89.99G 5959636.77 617104.16 N 70 1754.461 W 149 3 5.858 8100.00 88.63 22.48 5199.83 5118.93 972.21 972.21 5110.76 4.00 -89.89G 5959728.33 617144.22 N 70 1755.356 W 149 3 4.649 Target 2 8144.58 88.63 20.70 5200.90 5120.00 1013.64 1013.64 5127.16 4.00 -93.32G 5959770.00 617160.00 N 70 17 55.763 W 149 3 4.170 8200.00 88.50 18.49 5202.29 5121.39 1065.84 1065.84 5145.74 4.00 -93.26G 5959822.46 617177.80 N 70 17 56.276 W 149 3 3.627 8300.00 88.28 14.49 5205.10 5124.20 1161.67 1161.67 5174.10 4.00 -93.15G 5959918.69 617204.73 N 70 1757.218 W14932.7_ 8400.00 88.06 10.49 5208.29 5127.39 1259.23 1259.23 5195.72 4.00 -93.02G 5960016.56 617224.89 N 70 1758.178 W 149 3 2.1 8500.00 87.86 6.50 5211.85 5130.95 1358.05 1358.05 5210.48 4.00 -92.88G 5960115.58 617238.17 N 7017 59.150 W 149 31.734 End Cry 8582.09 87.70 3.22 5215.03 5134.13 1439.77 1439.77 5217.42 4.00 O.OOG 5960197.39 617243.89 N 701759.953 W 149 3 1.530 Cry 4/100 8595.33 87.70 3.22 5215.57 5134.67 1452.98 1452.98 5218.17 0.00 -84.99G 5960210.61 617244.44 N 70180.083 W 149 3 1.508 8600.00 87.71 3.03 5215.75 5134.85 1457.64 1457.64 5218.42 4.00 -84.98G 5960215.27 617244.62 N 70180.129 W 149 3 1.500 8700.00 88.07 359.04 5219.43 5138.53 1557.53 1557.53 5220.23 4.00 -84.84G 5960315.17 617244.94 N 70 18 1.111 W 149 3 1.446 8800.00 88.43 355.06 5222.49 5141.59 1657.34 1657.34 5215.08 4.00 -84.72G 5960414.88 617238.31 N 70 182.093 W 149 31.594 8900.00 88.80 351.07 5224.90 5144.00 1756.55 1756.55 5203.01 4.00 -84.62G 5960513.90 617224.76 N 70 183.069 W 149 31.944 Target 3 8952.04 89.00 349.00 5225.90 5145.00 1807.80 1807.80 5194.01 4.00 -90.18G 5960565.00 617215.00 N 70183.573 W 149 3 2.205 9000.00 88.99 347.08 5226.74 5145.84 1854.71 1854.71 5184.07 4.00 -90.14G 5960611.75 617204.37 N 70184.034 W 149 3 2.494 9100.00 88.99 343.08 5228.50 5147.60 1951.30 1951.30 5158.34 4.00 -90.07G 5960707.94 617177.20 N 70184.985 W 149 3 3.242 End Crv 9153.34 88.99 340.95 5229.44 5148.54 2002.02 2002.02 5141.87 4.00 O.OOG 5960758.40 617159.98 N 70185.483 W 149 3 3.721 Crv 4/100 9785.66 88.99 340.95 5240.64 5159.74 2599.61 2599.61 4935.49 0.00 28.59G 5961352.79 616944.73 N 70 1811.362 W 149 3 9.727 9800.00 89.49 341.22 5240.84 5159.94 2613.17 2613.17 4930.84 4.00 28.58G 5961366.29 616939.88 N 70 1811.495 W 149 3 9.862 Target 4 9814.55 90.00 341.50 5240.90 5160.00 2626.96 2626.96 4926.19 4.00 37.07G 5961380.00 616935.02 N 70 1811.631 W 149 3 9.997 End Cry 9835.52 90.67 342.01 5240.78 5159.88 2646.87 2646.87 4919.62 4.00 O.OOG 5961399.81 616928.16 N 70 1811.827 W 149 310.188 TO / '-1/2" Lnr pt 10681.17 90.67 342.01 5230.90 5150.00 3451.11 3451.11 4658.40 0.00 O.OOG 5962200.00 616655.00 N 70 18 19.738 W 149 317.7_ LeQal Description: Surface: 3703 FSL 1197 FEL S21 T11N R12E UM 5958680.13 612048.97 OBd Target: 4170 FSL 1712 FEL S22 T11N R12E UM 5959220.00 616805.00 TO / BHL: 1872 FSL 1810 FEL S15 T11N R12E UM 5962200.00 616655.00 Version DO 3.1 RT ( do31 rC399 ) 3.1 RT Service Pack 2.03 Plan W-2051Plan W-205IW-205 OBd1W-205 (P6) Generated 6/11/2003 3:37 PM Page 3 of 3 e e Oilfield Services, Alaska Schlumberger Drilling & Measurements Selllllm_e:pßØ' 3940 Arctic Blvd, Site 300 Anchorage, AK 99503 Tel (907) 273-1766 Fax (907) 561-8357 Wednesday, June 11, 2003 Mike Triolo Prudhoe Bay W-205 (P6) Nabors 9ES BP Exploration Alaska Close Approach Analysis We have examined the potential intersections of subject well with all other potentially conflicting wells, according to the BPA Directional Survey handbook (BPA-D-004) dated 09/99. Method of analvsis: 1. A list of wells to be analyzed is created in Compass by performing a global scan with an initial search radius of two thousand feet with an increment of one hundred feet for every one thousand feet of measured depth in the subject well. 2. Wells are analyzed using the Compass Anti-collision module (BP Company setup) with major risk safety factors applied. For problem wells that are plugged and abandoned or that can be shut in, risk-based safety factor may be used, with client notification. 3. All depths are relative to the planned well profile. Survey ProQram: Instrument Type GYD - GC - SS MWD + IFR + MS Start Depth 28.50'md 1000.00'md End Depth 1000.00'md 10678.18'md Close Approach Analvsis results: Under method (2), all wells may flow./ All data documenting these procedures is available for inspection at the Drilling & Measurements Directional Planning Center. Close Approach DrillinQ Aids to be provided: A drilling map, with any offset wells on the plan view, and a traveling cylinder will be provided. Checked by: Scott Delapp 06/11/03 Comllan)": Field: ncfcrencc SUc: ncfl~relll:c Well: ncfl~rellcc WI~IIJath: BP Amoco Prudhoe Bay PB W Pad Plan W-205 Plan W-205 OBd - NO GLOBAL SCAN: Using user defined selection & scan criteria Interpolation Method: MD Interval: 50.00 ft Depth Range: 28.50 to 10681.17 ft Maximum Radius: 3000.00 ft Survey Program for Definitive Wellpath Date: 4/25/2003 Validated: No Planned From To Survey ft ft 28.50 1000.00 Planned: Plan #f3 V1 1000.00 10681.17 Planned: Plan #f3 V1 Casing Points ) MD' ".,". """'ft 4008.01 7602.00 10681.17 Summary 3204.90 5181.49 5230.95 Diameter In·'''''' 10.750 7.625 5.500 Hole Size in Name .' Hate: 6/13/2003 -.--.------ . e Time: 10:06:41 I)a~e: I . . _ _. .._..n_ . _ ..___ __ __u.. . _ .. . .. ..__ ____....... . .... :X:::." 13.500 9.875 6.750 103/4" 7-5/8" 5 1/2" <--------------- Offscl Wcllpalh ---------------> SUI~ '....cll WI~III'ath PB W Pad PB W Pad PB W Pad PB W Pad PB W Pad PB W Pad PB W Pad PB W Pad PB W Pad PB W Pad PB W Pad PB W Pad PB W Pad PB W Pad PB W Pad PB W Pad PB W Pad PB W Pad PB W Pad PB W Pad PB W Pad PB W Pad PB W Pad PB W Pad PB W Pad PB W Pad PB W Pad PB W Pad PB W Pad PB W Pad PB W Pad PB W Pad PB W Pad PB W Pad PB W Pad PB W Pad PB W Pad PB W Pad PB W Pad PB W Pad PB W Pad PB W Pad W-01 W-02 W-02 W-03 W-03 W-04 W-05 W-06A W-06 W-07 W-08 W-08 W-09 W-10 W-10 W-11 W-12A W-12 W-15 W-15 W-15 . W-15 W-16 W-16 W-17 W-18 W-19 W-19 W-19 W-200PB1 W-200 W-201 W-203 W-203 W-203 W-207 W-207 W-20 W-211 W-212 W-21 W-21 W-01 V1 W-02 V4 W-02A V20 W-03 V4 W-03A V1 W-04 V1 W-05 V1 W-06A V2 W-06 V1 W-07 V1 W-08 V1 W-08A V11 W-09 V1 W-10 V3 W-10A V4 W-11 V1 W-12A V3 W-12 V1 W-15 V1 W-15A V10 W-15PB1 V6 W-15PB2 V1 Plan#6 W-16L 1 VO Plan: W-16 V3 W-17 V1 W-18 V1 Plan#11 W-19AL 1 V1 Pia W-19 V2 W-19A V1 W-200PB1 V7 W-200 V4 Plan: Undefin W-201 V4 W-203 V9 W-203L 1 V7 W-203L2 V3 W-207 V1 0 W-207PB1 V2 W-20 V1 W-211 V8 W-212 V12 W-21 V3 W-21A V12 Co-ordinatc(:'iiE) nefercllce: Vertical (TVD) neference: Well: Plan W-205, True North W-205 plan 80.9 Db: Oracle Version: 4 Toolcode GYD-GC-SS MWD+IFR+MS n(~ferellce MD ft 1168.23 693.15 694.29 645.69 645.69 686.07 733.94 645.78 645.78 1193.35 637.45 643.21 777 .28 693.62 693.62 489.28 645.49 645.49 782.69 782.69 782.69 782.69 735.52 735.52 791.46 791.30 789.89 829.96 789.89 887.37 887.42 748.30 393.73 393.73 393.73 3478.06 3479.74 884.06 3101.77 740.47 784.40 793.32 Offsct ~11) ft 1200.00 700.00 700.00 650.00 650.00 700.00 750.00 650.00 650.00 1250.00 650.00 650.00 800.00 700.00 700.00 500.00 650.00 650.00 800.00 800.00 800.00 800.00 750.00 750.00 800.00 800.00 800.00 850.00 800.00 900.00 900.00 750.00 400.00 400.00 400.00 3650.00 3650.00 900.00 3500.00 750.00 800.00 800.00 .....------ .---... .--.. . .. Reference: Error Model: Scan Method: Error Surface: Principal Plan & PLANNED PROGRAM ISCWSA Ellipse Trav Cylinder North Ellipse + Casing Tool Name Gyrodata gyro single shots MWD + IFR + Multi Station ------...- .... Or-Or :'\io-Go Allowable Dislallœ An'a Dc\hllioll ft ft ft . .-------.-...,..". 408.73 27.68 381.16 386.71 10.60 376.56 386.73 10.62 376.56 350.54 10.88 339.66 350.54 10.88 339.66 315.53 11.17 304.36 281.55 12.50 269.05 210.23 11.08 199.15 210.23 11.08 199.15 215.09 30.47 185.42 176.50 10.44 166.06 176.64 10.31 166.33 137.11 16.13 121.02 103.26 14.82 88.46 103.26 14.82 88.46 69.68 8.55 61.14 31.19 13.85 17.39 31.19 13.85 17.39 743.49 12.67 730.82 743.49 12.67 730.82 743.49 12.67 730.82 743.49 12.67 730.82 776.34 12.31 764.03 776.34 12.14 764.20 809.65 13.54 796.11 845.03 13.71 831.32 880.87 12.98 867.89 881.51 13.50 868.01 880.87 12.81 868.06 1094.22 15.04 1079.18 1094.18 14.96 1079.22 1124.60 11.74 1112.90 35.52 6.38 29.14 35.52 6.16 29.36 35.52 6.16 29.36 170.46 106.51 67.32 153.42 106.26 49.99 918.21 14.36 903.86 673.26 126.45 605.07 675.76 11.05 664.88 953.50 18.40 935.10 953.78 18.65 935.13 Wllrnin¡: .,// Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk e e ..... -..-----.. ----...-----.-- Compan~': BP Amoco Date: 6/13/2003 Time: 10:06:41 I'a!:e: 2 F¡l~ld: Prudhoa Bay Refl~rencc SUe: PB W Pad Co-ordinatc(N I':) I{eference: Well: Plan W-205, True North I{efl'rcncc Well: Plan W-205 Vertical (TV D) ncferellce: W-205 plan 80.9 I{eferem"e Wellpath: Plan W-205 OBd Db: Oracle . - -.-----.. ----... .. ... ---... --.-- Summary ....-.... ...--..----" . .- ----.-- ...--... < Offset Wellpath ------------> Refl~rencc Offset Ctr-Ctr ~o-(;o Allowable SUe Wdl Wellpatb !\11) 1\11) Distance Area Dc\'iation Warn¡n!: ft ft ft ft ft ../ .----... . ....-- ----...... .--.--................. -----..-.....-..... .. ... . ..... ..... ...-. ---.-------- ..--... PB W Pad W-22 W-22 V1 883.47 900.00 984.59 15.92 968.67 Pass: Major Risk PB W Pad W-23 W-23 V3 830.47 850.00 1021.82 13.12 1008.70 Pass: Major Risk PB W Pad W-23 W-23A V5 839.27 850.00 1022.00 13.29 1008.71 Pass: Major Risk PB W Pad W-24 W-24 V1 792.35 800.00 1058.01 14.33 1043.69 Pass: Major Risk PB W Pad W-25 W-25 V1 337.15 350.00 647.17 7.24 639.93 Pass: Major Risk PB W Pad W-26A W-26A V3 372.50 350.00 679.63 7.39 672.24 Pass: Major Risk PB W Pad W-26 W-26 V1 345.65 350.00 679.44 7.06 672.38 Pass: Major Risk PB W Pad W-27 W-27 V1 383.73 400.00 711.58 6.88 704.70 Pass: Major Risk PB W Pad W-29 W-29 V1 427.22 450.00 778.44 8.88 769.56 Pass: Major Risk PB W Pad W-30 W-30 V1 428.50 450.00 810.95 7.72 803.23 Pass: Major Risk PB W Pad W-31 W-31 V1 471.43 500.00 843.07 9.08 834.00 Pass: Major Risk PB W Pad W-32 W-32 V5 428.08 450.00 877.81 9.30 868.51 Pass: Major Risk PB W Pad W-32 W-32A PB1 V12 430.51 450.00 877.84 9.00 868.84 Pass: Major Risk PB W Pad W-32 W-32A V3 430.51 450.00 877.84 9.30 868.54 Pass: Major Risk PB W Pad W-34 Plan#4 W-34A VO Plan: 337.24 350.00 441 .43 6.21 435.22 Pass: Major Risk PB W Pad W-34 W-34 V1 337.24 350.00 441 .43 6.04 435.39 Pass: Major Risk PB W Pad W-35 W-35 V1 384.08 400.00 415.48 8.25 407.23 Pass: Major Risk PB W Pad W-36 W-36 V1 383.74 400.00 387.56 6.40 381.16 Pass: Major Risk PB W Pad W-37 W-37 V3 383.97 400.00 362.08 7.05 355.03 Pass: Major Risk PB W Pad W-37 W-37A V3 383.97 400.00 362.08 7.05 355.03 Pass: Major Risk PB W Pad W-38 W-38 V2 384.21 400.00 337.32 7.00 330.32 Pass: Major Risk PB W Pad W-38 W-38A V10 386.69 400.00 337.36 6.88 330.48 Pass: Major Risk PB W Pad W-39 Plan#4 W-39A VO Plan: 383.89 400.00 318.52 8.25 310.26 Pass: Major Risk PB W Pad W-39 W-39 V1 383.89 400.00 318.52 8.15 310.37 Pass: Major Risk PB W Pad W-40 W-40 V1 382.82 400.00 299.85 7.91 291.94 Pass: Major Risk PB W Pad W-42 W-42 V1 345.06 350.00 271.90 6.00 265.90 Pass: Major Risk PB W Pad W-44 W-44 V1 337.61 350.00 259.45 5.40 254.05 Pass: Major Risk e Field: Prudhoe Bay Site: PB W Pad Well: Plan W-205 Wellpath: Plan W-205 OBd e -335 o JJS / ·-·····100 W-04(W-04) ~ ~~~" '~$t"~ 'Y ~I V -"\ ~ " '2 /~' . ~/~ ç; fA f ~~, V 1/ 'IX '< "". r/, hi .-/~.\~ ' U\ l' '(i" .\r<r. ... ~ :.'~ ". / ~~r ~., ..._. ...... I ~ ''', W-39 ~$\fN/)IM) . .¥¡¡2\~. Ì'.J;' 1-:-1 _ /' .,,)Ø.J.( ~31:--' .' ¡'j ~' '. ~\ 3C ,A·' ";K Yo It? N ~.. .... "17 L '. ~". w,,~ , !ß/ ,,~ .' ç'~/1 ~\~ *. "~ ~. ~\\d l '/ / /~ l'~ ~ /!~'\'iN ~ \\'J'0:'~I\_ IJ··· ! ~~. >':',~~:~'~IIo. " /~ .~' I/r IÅ W-42(W-42)[l ,6 m~~~~~ .~.-/ 'k// [) r \'% J 1~ Il1 "~'ß~~¡ ./J tiJ..".. Q ""'~~:J?\(ty'þ", ~I 'I'\l)( I; \/. vþ /7~'¡'--X'! 0-- / ~""'~ \ A ~f'., V l"{/V(. _;-44(W-44;)_: ~~. !5 y I . // ~.. -\",,~~I ~ \ ~ 1'1~)?0 W-09(W-09) ~ '~ttl· ~ -\-l I". .) ['-" )1¡:¡ \~ 0 J;2_~ ?1). '¡~\+- Á ~~ ; ~-r ¡' 4 ~ /;. \ JJ / ~ f \" lYN/';, 1V: :..e '-\ I ~ I./1-1 , ~~~ Î\ Ì\? k' ~ .' ~".1\ /ì5Á~ V Jj Xì ~I ÞIIYI, íi)j'/1 , . n, "\ . / ..0Z'\. '~I Jj J 7 J¡ '/1 i\i~7\ J; . \' \'.. // ........¡.<..~ '~./ ,\ å \ N~ /K t'" If ~,I,jfyJ Y " ""><' ;\ :. i W-W~~;Y) ~~ ~ 'i K J}~ Hl\(·~;,11 11"+" ~ /" /", 20 " , ~ ~: ~v,1Jj~// . ]/ / 'v?;}: ctr/ , ~;;~I ..~~. ~/ ~//I ~ 1:0 -5Jo W-203 (W-203P) """-200 ········-300 ·········100 -200 21 -JOO -335 Travelling Cylinder Azimuth (TFO+AZI) {deg] vs Centre to Centre Sepamtion {100ft/in] J" ~ ,/ - w'7-H¡ ~ '! I 7~ I ......... _../// . 1<'1<ittt. 1!.n, /. mU __'-_._ : / Site PBWPa( -'¡j I -: W:..n. ,...".. , · : t:u; Plan" -_..'"'I I : - ....................... .l'lan '7 ;,.uu _ 'm. ........................... : I. :: . 6~ .......... ......u / .! ' ! I m_ um· .._ . ... _ ./ : I : : - . /: ····1 .: / 7 · ................. ....................... . I /. : · : , .. I / i i .: m .... ,v. :' / / : 7 : . / . . I / : - ...... ............ , ·····m 7 ......m '. ........... ..m.': : .: .. . .. . / / Y : .. ./ / II ..: : ... ... ./'"' · .---- .I ...... ..... / 'm ...... ... mm ............ : . -- : . - ~ y : J . . I: ' ~ I ... m : ,/ I. . -. · I.: i 1m_I · :/./.J :. ....... ...... .....1 ....... · .... .. · ..! -, . .... ............: , . I ': :: .................. . I · . .... - . .... I . .... m I o ) I I I I I I I I I I I I I I I I I I o 2 ;0 510 7 ;0 I( DO I: 50 1::00 1 '50 2000 2250 Measured Depth [250ft/in c ;¡; Ë c .S ~ ¡¡- en e õ 8 o ~ 8 p055084 DATE INVOICE / CREDIT MEMO DESCRIPTION 6/9/2003 INV# CK060403D PERMIT TO DRill FEE THE ATTACHED CHECK IS IN PAYMENT FOR ITEMS DESCRIBED ABOVE. TOTAL ..... BP EXPLORATION, (ALASKA) INC. PRUDHOE BAY UNIT PO BOX 196612 ANCHORAGE, AK 99519-6612 PAY: B PI:' ",.. . ...!.LI" TO THE ORDER OF: ALASKA Oil & GAS CONSERVATION COMMISSION 333 W 7TH AVENUE SUITE 100 ANCHORAGE, AK 99501-3539 GROSS w·;LQS NATIONAL CITY BANK Ashland, Ohio '."11 'u.' lUlU DATE June 9, 2003 1110 5 50B~1I1 I:O~. 20 :iB9 51: 0.2 ?B9!;IID DATE 6/9/2003 I CHECK NO. I I 055084 VENDOR -'"------ DISCOUNT NET .---.-.-----"- - --_._-_.._-----~- I~ e --'"------.--.-.- ---"."--.- 56-389 412 No. P 0 5 5 0 8 4 CONSOLIDATED COMMEF1CIAL ACCOllNT e AMOUNT I \- *******$100.00*******1 NOT - e TRANSMIT AL LETTER CHECK LIST CIRCLE APPROPRIATE LETTER/PARAGRAPHS TO BE INCLUDED IN TRANSMITTAL LETTER WELL NAME PTD# CHECK WHAT APPLIES ADD-ONS (OPTIONS) MULTI LATERAL (If API number last two (2) digits are between 60-69) PILOT (PH) "CLUE" The permit is for a new well bore segment of existing weD Permit No, API No. Production should continue to be reported as a function' of the original API number stated above. HOLE In accordance with 20 AAC 25.005(t), all records, data and logs acquired for the pilot hole 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 well (name on permit). SPACING EXCEPTION DRY DITCH SAMPLE Rev: 07/10/02 C\jody\templates The permit is approved subject to full compliance with 20 AAC 25.055. Approval to peñorate and produce is contingent upon issuance of a conservation order approving a spacing exception. (Companv Name) assumes the liability of any protest to the spacing exception that may occur. All dry ditch sample sets submitted to the Commission must be in no greater than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. WELL P';IfJø.J'¡£HECKb"" Company BP EXPLORATION (ALASKA) INC Well Name: PRUDHOE BAY UN POL W-205 Program DEV Well bore seg D PTD#: 2031160 Field & Pool PRUDHOE BAY, POLARIS OIL - 640160 Initial ClassfType DEV / 1-01L GeoArea Unit 11650 On/Off Shore ~ Annular Disposal D Administration 1 p~(IT!itfee attaches:l_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Y~s _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 2Leas~_number _appropriate_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Y~s _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 3 _U_nlque weltnarn~_a[1d O~llJb_er _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _Y~s _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 4 WeJUocat~d In_a_d.efjnes:l-pool _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Y~s _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 5 WeJUQcaled pr_oper _dlsta[1ce_ from driJling unilbound_al"y- _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Y~s _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 6 WeJUQcaled proper _dlstance_ from Qtber wells_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _Y~s _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 7 _S_u{ficientjicreag.e_ayailjible lndJilliog unjt _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Y~s _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 8 Rd~viated, js_ weJlbore platJncJu_ded _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Y~s _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 9 _O-perator onl}' affected party _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Y~s _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 10 _O-perator bas_approprlate_b.ond inJQrce _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Y~$ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 11 P~(IT!il ca[1 be lssued witbout co_nserva_tion order _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Y~s _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Appr Date 12 P~rllJilcan be lss~ed wjtbout administrathle_approval _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _Y~s _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ RPC 6/24/2003 13 Can permit be approved before 15-day wait Yes 14 WellJocaled wlthin area an.d_strataauthorlzed byJnjection Ord~r # (pullO# hcornrn~ntsUFoL _NA _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 15 _AJI wells_within Jl4_mile_area_of reyiew jd~ot[fied (For seNj~-,,~eU onlYL _ _ _ _ _ _ _ _ _ _ _ _ _ _ _NA _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 16 PJe-produ_ced.i[1jector; s:luratioRofpre--pros:luctionl~$sthan3montbs_(For_servtcewellonJY) _ _ _NA _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ __ 17 AÇMPFïndjng of Con_stste[1cyh_as beeRissued fortbis pr_ojecl _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _NA _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Engineering 18 _Co[1du_ctor string_PJQvlded _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Y~s _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 19 _S_u¡:fa~ _casing_pJotects alLknown USDWs _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _Y~s _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 20 _CMTvoladequ_ateto circ_ulate_on_cond_uctor_& SUJtC$g _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _Y~s _ _ _ _ _ _ _ Mequate ex.cess. _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 21 _CMTv_oladeq~atetotie-tnJQng_stri[1gto_s!.l¡:fçsg_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ No_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ __ 22 _CMTwill COYer_aU knQw_npro.duetiYe bQrilon_s _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Y~s _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 23 _C_asing desig[1s ad.eQua_te for C,_T" B_&_permafr_ost _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Y~$ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 24 _Mequatetankage_oJ re_serve pit _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Y~s _ _ _ _ _ _ _ NabofS_9ES, _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 25 JtaJe-s:lrilt has_a_ 10-403 for abandonllJent be~o apPJoved _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ NA _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 26 _MeqUjiteJl\leUbore. separatio_n-pro-posed _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Y~s _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 27 Rdjverter Jeq.uiJed, does it meet reguJations_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _Y~s _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Appr Date 28 _Drilling flujd_prQg.rallJ $c.hematic_& eq.uipJistadequale_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Y~$ _ _ _ _ _ _ _ Max. MW_9, 5. ppg._ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ WGA 6/24/2003 29 BOPEs,_doJhey meetreguJation _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Y~s _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 30 _BOPE-Pfe.ss ra_ting ap-propriate;testto_(pu_t psig tncomrnentsL _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _Y~$ _ _ _ _ _ _ Testto_35QO_ psLMSf' 1700 psi._ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 31 _C_hoke_manjfold cQIlJPJies w/APtRf'-53 (May 84)_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Y~s _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 32 Work will occ_ur withoutoperatjon_shutdow.n_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Y_es _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 33 Js prese[1ce o.f H2S gas_ prollable _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ No_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 34 Mecba_nlcaLcondjtio[1 of we.lIs wlthin AOR yerified. (for_ service well onJy) _ _ _ _ _ _ _ _ _ _ _ _ _ _ _NA _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Geology 35 P~rllJit can be lS$l.!ed wlo. hydrogen_ s_ulfide rneas_ures _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Y~$ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 36 _D_ata_PJesented On pote_ntial oveJpressur~ _zones _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _NA _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Appr Date 37 _S~tsrnicanalysjs_ of sballow gas_zooes_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _NA _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ RPC 6/24/2003 38 _S~abed _condjtion s~rvey -<if off-shore) _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ NA _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 39 _ Conta_cl namelphoneJor_weekly progreSUeports [exploratory _o[1IYl _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ NA _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Public ~/ Commissioner Date &/~03 Geologic Commissioner: Engineering Commissioner: ~ Date: G~)~OJ Date ~ I [)¡5 e e