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Home My WebLink About198-059New Plugback Esets 7/31/2024 Well Name API Number PTD Number ESet Number Date CD2-15 PB1 50-103-20386-70-00 201-159 T39326 4-26-2002 CD2-15 PB2 50-103-20386-71-00 201-159 T39327 4-26-2002 1D-42L1 PB1 50-029-22979-70-00 205-078 T39328 8-3-2005 2N-304 PB1 50-103-20382-70-00 201-130 T39329 9-12-2001 Mitre 1 PB1 50-103-20409-70-00 202-026 T39330 7-23-2002 C-26L1 PB1 50-029-22634-70-00 203-076 T39331 9-17-2003 C-26L1 PB2 50-029-22634-71-00 203-076 T39332 9-17-2003 C-26L1 PB3 50-029-22634-72-00 203-076 T39333 9-17-2003 MPU E-32 PB1 50-029-23261-70-00 205-065 T39334 7-7-2005 S-04L1 PB1 50-029-23148-70-00 203-053 T39335 7-14-2005 S-04L1 PB2 50-029-23148-71-00 203-053 T39336 7-14-2005 MPU S-05 PB1 50-029-23100-70-00 202-137 T39337 6-2-2003 B-03 PB1 50-883-20095-70-00 198-059 T39338 11-6-2003 07-28B PB1 50-029-21770-70-00 209-037 T39339 6-29-2009 16-23A PB1 50-029-22050-70-00 201-054 T39340 6-2-2003 W-34A PB1 50-029-21867-70-00 203-058 T39341 2-6-2004 SP30-W01 PB1 50-629-23476-70-00 212-142 T39342 11-14-2012 V-207L4 PB1 50-029-23390-71-00 208-070 T39343 9-11-2008 W-215 PB1 50-029-23172-70-00 203-131 T39344 9-12-2003 B-03 PB1 50-883-20095-70-00 198-059 T39338 11 -6-2003 David Douglas Hilcorp North Slope, LLC Sr. Geotechnician 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 777-8337 E-mail: david.douglas@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: Date: 04/11/2024 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 DATA TRANSMITTAL Submitted To Andrew Dewhurst Via ZentTo Mudlog Image Files for each of the well bores listed in the table below: Well Name PTD # API # NCIU A-13 192106 50883200870000 NCIU B-03 198059 50883200950000 SFTP Transfer - Data Folders: Please include current contact information if different from above. 198-059 T12244 192-106 T20352 NCIU B-03 198059 50883200950000 Meredith Guhl Digitally signed by Meredith Guhl Date: 2024.04.16 10:44:07 -08'00' 1a. Well Status:Oil SPLUG Other Abandoned Suspended 1b. Well Class: 20AAC 25.105 20AAC 25.110 Development Exploratory GINJ WINJ WDSPL No. of Completions: _0 Service Stratigraphic Test 2. Operator Name: 6. Date Comp., Susp., or 14. Permit to Drill Number / Sundry: Aband.: 3. Address: 7. Date Spudded: 15. API Number: 4a. Location of Well (Governmental Section): 8. Date TD Reached: 16. Well Name and Number: Surface: Top of Productive Interval: 9. Ref Elevations: KB: 17. Field / Pool(s): North Cook Inlet Unit GL: N/A BF: N/A Total Depth: 10. Plug Back Depth MD/TVD: 18. Property Designation: 4b. Location of Well (State Base Plane Coordinates, NAD 27): 11. Total Depth MD/TVD: 19. DNR Approval Number: Surface: x- y- Zone- 4 TPI: x- y- Zone- 12. SSSV Depth MD/TVD: 20. Thickness of Permafrost MD/TVD: Total Depth: x- y- Zone- 4 5. Directional or Inclination Survey: Yes (attached) No 13. Water Depth, if Offshore: 21. Re-drill/Lateral Top Window MD/TVD: Submit electronic information per 20 AAC 25.050 (ft MSL) 22. Logs Obtained: 23. BOTTOM 30"5,347' 20" X-56 1,208' 13-3/8" L-80 3,163' 9-5/8" P-110 3,163' 24. Open to production or injection? Yes No 25. 26. Was hydraulic fracturing used during completion? Yes No DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED 27. Date First Production: Method of Operation (Flowing, gas lift, etc.): Hours Tested: Production for Gas-MCF: Test Period Casing Press: Calculated Gas-MCF: Oil Gravity - API (corr): Press. 24-Hour Rate ACID, FRACTURE, CEMENT SQUEEZE, ETC. CASING, LINER AND CEMENTING RECORD List all logs run and, pursuant to AS 31.05.030 and 20 AAC 25.071, submit all electronic data within 90 days of completion, 658 sx12-1/4" TUBING RECORD N/AN/A SIZEIf Yes, list each interval open (MD/TVD of Top and Bottom; Perforation Size and Number; Date Perfd): 1600 sx Surface Driven Surface 1,214' 1364 sx - STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG Hilcorp Alaska, LLC WAG Gas 3800 Centerpoint Drive, Suite 1400, Anchorage, AK 99503 8/5/2022 1253' FNL, 942' FWL, Sec 6, T11N, R9W, SM, AK 4036' FSL, 3282' FEL, Sec 13, T11N, R9W, SM, AK 198-059 / 322-114 Tertiary System Gas Pool 126.6' 3,546' MD / 3,163' TVD HOLE SIZE AMOUNT PULLED 50-883-20095-00-00 NCIU B-03 331991 2586726 N/A CEMENTING RECORDSETTING DEPTH TVD 2576423 BOTTOM TOP 16" Surface 24"Surface CASING WT. PER FT.GRADE 53.5# 327594 TOP SETTING DEPTH MD Surface Per 20 AAC 25.283 (i)(2) attach electronic information 72# 3,546' (TOW) Surface Surface DEPTH SET (MD) N/A PACKER SET (MD/TVD) 547# 133# 461' Surface 3,546' (TOW) Gas-Oil Ratio:Choke Size:Water-Bbl: PRODUCTION TEST N/A Date of Test: Flow Tubing Oil-Bbl: suspension, or abandonment, whichever occurs first. Types of logs to be listed include, but are not limited to: mud log, spontaneous potential, gamma ray, caliper, resistivity, porosity, magnetic resonance, dipmeter, formation tester, temperature, cement evaluation, casing collar locator, jewelry, and perforation record. Acronyms may be used. Attach a separate page if necessary N/A N/A Sr Res EngSr Pet GeoSr Pet Eng Oil-Bbl: Water-Bbl: October 23, 1998 May 3, 1998 ADL 17589 / ADL 37831 N/A N/A 3,546' MD / 3,163' TVD101 N/A 17,864' MD / 13,356' TVD WINJ SPLUG Other Abandoned Suspended Stratigraphic Test No No (attached) No Form 10-407 Revised 3/2020 Submit within 30 days of Completion, Suspension, or Abandonment Originally submitted 10/7/2022 By Meredith Guhl at 10:41 am, Sep 13, 2023 Abandoned 8/5/2023 JSB RBDMS JSB 092223 xGBJM 1/9/24 see note below -bjm Note: The PB for sidetrack P&A work (subject of sundry 322-114) alreadyreported in another 10-407 form. This 10-407 only covers setting the whipstock which was included as part of the PTD for the sidetrack toNCIU B-03A (PTD 222-048)-bjm. DSR-9/29/23 Conventional Core(s): Yes No Sidewall Cores: 30. MD TVD N/A N/A Top of Productive Interval N/A N/A N/A 31. List of Attachments: 32. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Name: Cody Dinger Contact Email:cdinger@hilcorp.com Authorized Contact Phone: 777-8389 General: Item 1a: Item 1b: Item 4b: Item 9: Item 15: Item 19: Item 20: Item 22: Item 23: Item 24: Item 27: Item 28: Item 30: Item 31: FORMATION TESTS Permafrost - Top This form and the required attachments provide a complete and concise record for each well drilled in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. All laboratory analytical reports regarding samples or tests from a well must be submitted to the AOGCC, no matter when the analyses are conducted. Information to be attached includes, but is not limited to: summary of daily operations, wellbore schematic, directional or inclination survey, core analysis, paleontological report, production or well test results, per 20 AAC 25.070. Wellbore Schematic, P&A Reports Signature w/Date: If Yes, list formations and intervals cored (MD/TVD, From/To), and summarize lithology and presence of oil, gas or water (submit separate pages with this form, if needed). Submit detailed descriptions, core chips, photographs, and all subsequent laboratory analytical results per 20 AAC 25.071. Authorized Name: Monty Myers Authorized Title: Drilling Manager Permafrost - Base 29. GEOLOGIC MARKERS (List all formations and markers encountered): Formation at total depth: Yes No Well tested? Yes No 28. CORE DATA If yes, list intervals and formations tested, briefly summarizing test results. Attach separate pages to this form, if needed, and submit detailed test information, including reports, per 20 AAC 25.071. NAME The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). Report the Division of Oil & Gas / Division of Mining Land and Water: Plan of Operations (LO/Region YY-123), Land Use Permit (LAS 12345), and/or Easement (ADL 123456) number. INSTRUCTIONS 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. TPI (Top of Producing Interval). Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, or Other (explain). Provide a listing of intervals tested and the corresponding formation, and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Review the reporting requirements of 20 AAC 25.071 and, pursuant to AS 31.05.030, submit all electronic data within 90 days of completion, suspension, or abandonment, whichever occurs first. Well Class - Service wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Pursuant to 20 AAC 25.070, attach to this form: well schematic diagram, summary of daily well operations, directional or inclination survey, and other tests as required including, but not limited to: core analysis, paleontological report, production or well test results. Report measured depth and true vertical thickness of permafrost. Provide MD and TVD for the top and base of permafrost in Box 29. Attached supplemental records should show the details of any multiple stage cementing and the location of the cementing tool. 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). Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Pursuant to 20 AAC 25.071, submit detailed descriptions, core chips, photographs, and all subsequent laboratory analytical results, including, but not limited to: porosity, permeability, fluid saturation, fluid composition, fluid fluorescence, vitrinite reflectance, geochemical, or paleontology. The Kelly Bushing, Ground Level, and Base Flange elevations in feet above Mean Sea Level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. No NoSidewall Cores: Yes No Form 10-407 Revised 3/2020 Submit within 30 days of Completion, Suspension, or Abandonment 10.6.2022Digitally signed by Monty M Myers DN: cn=Monty M Myers, c=US, o=Hilcorp Alaska, LLC, ou=Technical Services - AK Drilling, email=mmyers@hilcorp.com Reason: I am approving this document Date: 2022.10.06 15:49:35 -08'00' Monty M Myers _____________________________________________________________________________________ Updated By DMA 05-09-22 P&A SCHEMATIC North Cook Inlet Unit Well: NCI B-03 P&A’d: 8/5/22 PTD: 198-059 API: 50-883-20095-00-00 JEWELRY DETAIL No Depth (MD) Depth (TVD)ID OD Item 3,546’ 3,163’--Whipstock 1 4,173’3,578’8.353 CIBP w/ 25ft of cement – TOC @ 4,148 (3/30/22) 2 4,304’3,686’3.00 4.25 Baker 80-40 GBH-22 Locator & seal assembly 4,319 3,696’3.00 3.98 Baker 80-40 Spacer tube and seal assembly w/ ½ Muleshoe Isolation String A1 4,290 3,676’6.37 7.5”7” C-2 liner setting sleeve, 10’ tieback extension 4,305’3,684’3.00 5.0 Baker 80-40 Seal Bore 4” ID x 10’ long 5” BTC pin x pin A 4,431’3,773’2.37 4.5 Baker 450-237 HS Packer #1 w/30k shear release 4,275’3,665’2.441 2-7/8” CIBP w/ 27’ of cement – TOC @ 4,248 (3/15/22) B 4,660’3,929’2.313 3.16 Baker 2-7/8” SLCMU Sliding Sleeve (Closed12/4/21) C 4,873’4,070’2.37 4.5 Baker HS Packer #1, 2-7/8” EUE w/30k shear release C1 4,879’4,072’~1.0 2.44 SL Patch without AA stop or top element, assembly, top, 4,879’ D 5,342’4,378’2.347 4.5 Baker HS Packer #1, 2-7/8” EUE w/30k shear release E 5,591’4,539’2.313 3.16 Baker 2-7/8” SLCMU Sliding Sleeve (Open 12/19/10) F 5,838’4,702’2.37 4.5 Baker HS Packer #1, 2-7/8” EUE w/30k shear release G 6,088’4,875’2.313 3.16 Baker 2-7/8” SLCMU Sliding Sleeve (Open 12/19/10) H 6,337’5,048’2.37 4.5 Baker HS Packer #1, 2-7/8” EUE w/30k shear release J 7,277’5,707’2.37 4.5 Baker HS Packer #1, 2-7/8” EUE w/30k shear release K 7,358’5,765’2.313 3.7 Camco Landing Nipple X Profile L 7,390 5,787’2.375 3.51 2-7/8” WLEG Gravel Pack 8 4,319’3,696’3.880 Baker 190-60 PBR w/ 15’ seal travel 4,336’3,707’4.872 Gravel Pack 4,341’3,711’5.000 Baker KOIV, Busted open on 11/19/03 4,349’3,716’6.000 Baker 9-5/8” 53.5# SC-1R Packer Assy w/ KOIV @4,381’ 9 4,830’4,041’6.000 Baker 9-5/8” 53.5# SC-1R Packer 10 5,308’4,355’6.000 Baker 9-5/8” 53.5# SC-1R Packer 11 5,777’4,661’6.000 Baker 9-5/8” 53.5# SC-1R Packer 12 6,277’5,006’6.000 Baker 9-5/8” 53.5# SC-1R Packer 13 6,855’5,410’4.892 RA Tag in box of 5-1/2”, 17 ppf, L-80 Braden Blank SLHT BxP 14 7,089’5,574’4.892 RA Tag in box of 5-1/2”, 17 ppf, L-80 Braden Blank SLHT BxP 15 7,217’5,665’6.000 Baker 9-5/8” 53.5# SC-1R Packer 16 7,767’6,053’4.892 RA Tag in box of 5-1/2”, 17 ppf, L-80 Braden Blank SLHT BxP 17 8,155’6,327’6.000 Baker 9-5/8” 53.5# SC-1R Packer sump packer 2/MO ext. 18 8,397’6,500’3.813 Landing Nipple X Profile 19 8,430’6,524’4.000 4-1/2” WLEG CASING DETAIL Size Wt Grade Conn ID Top Btm 30”547 Welded 29.000 Surf 461’ 20”133 K-55 Dni-Quip 19.730 Surf 1,214’ 13-3/8”72 L-80 BTC 12.415 Surf 3,546’(TOW) 9-5/8”53.5 P-110 BTC 8.535 Surf 3,546’(TOW) 7”32 P-110 Butt 6.094 11,561’15,301’ 5”18 P-110 VAM FJL 4.270 11,420’17,159’ 3-1/2”13 P-110 PH-6 17,159’17,864’ TUBING DETAIL 3-1/2”9.3 L-80 EUE Mod 2.992 4,187’4,321’ 2-7/8”6.4 L-80 Hyd 511 2.377 4,290’7,391’ 5-1/2” Gravel Pack 17 L-80 SLHT 4,319’ 8,431’ Updated By DMA 05-09-22 SCHEMATIC North Cook Inlet Unit Well: NCI B-03 Last Completed: 12/15/2010 PTD: 198-059 API: 50-883-20095-00-00 PERFORATION DETAIL Zone Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT Date Status CI-1 4,463' 4,547' 3,795' 3,853' 84' 10/21/2003 Closed CI-2 4,570' 4,663' 3,869' 3,931' 93' 10/21/2003 Closed CI-3 4,690' 4,701' 3,949' 3,956' 11' 10/21/2003 Closed CI-4 4,748' 4,820' 3,987' 4,035' 72' 10/21/2003 Isolated CI-4 4,888' 4,918' 4,080' 4,099' 30' 10/21/2003 Isolated CI-5 4,927' 4,955' 4,105' 4,124' 28' 10/21/2003 Isolated CI-7 5,060' 5,090' 4,192' 4,212' 30' 10/21/2003 Isolated CI-8 5,200' 5,214' 4,284' 4,294' 14' 10/21/2003 Isolated CI-9 5,268' 5,291' 4,329' 4,344' 23' 10/21/2003 Isolated CI-11 5,355' 5,402' 4,386' 4,417' 47' 10/21/2003 Open B 5,588' 5,595' 4,538' 4,542' 7' 10/21/2003 Open B 5,688’ 5,708’ 4,602’ 4,616’ 20’ 04/27/2021 Open B 5,752' 5,765' 4,644' 4,653' 13' 10/21/2003 Open C 5,933' 5,939' 4,767' 4,771' 6' 10/21/2003 Open D 6,038' 6,046' 4,840' 4,846' 8' 10/21/2003 Open D 6,048' 6,054' 4,847' 4,851' 6' 10/21/2003 Open E 6,220' 6,227' 4,967' 4,972' 7' 10/21/2003 Open E 6,261' 6,268' 4,995' 5,000' 7' 10/21/2003 Open H 6,628' 6,648' 5,251' 5,265' 20' 10/21/2003 Open H 6,655' 6,672' 5,270' 5,282' 17' 10/21/2003 Open H 6,696’ 6,716’ 5,298’ 5,312’ 20’ 04/26/2021 Open I 6,955' 6,978' 5,480' 5,496' 23' 10/21/2003 Open L 7,180' 7,197' 5,638' 5,650' 17' 10/21/2003 Open N 7,495' 7,517' 5,862' 5,877' 22' 10/21/2003 Covered P 7,700' 7,727' 6,006' 6,025' 27' 10/21/2003 Covered Q 7,955' 7,968' 6,186' 9,195' 13' 10/21/2003 Covered R 8,105' 8,145' 6,291' 6,319' 40' 10/21/2003 Covered OLD COMPLETION BELOW CEMENT Note: Old tubing tally has not been located. Measurements below are approximate. No Depth (MD) Depth (TVD) ID OD Item 11,181’ 8,506’ Calc. Top of Cement 11,354’ 8,631’ BWD Packer w/ seals top 11,362’ 8,636’ Bevel guide over tubing stub from 11,362’ – 11,368’ – Tubing chemically cut at 11,362’ after failed pressure test 11,380 8,649’ AHC Packer 11,398’ 8,662’ Fish – 24’ Wireline fish on X Nipple 11,418’ 8,676’ X Nipple (2.313”) 13,700’ 10,341’ Tubing tail 16,890’ 12,571’ Top of Fill Activity Date Ops Summary 7/28/2022 Continue to clean and flush scalper tank and lines. Hold rig down meeting with OIM, rig support crew, welders and crane crew. Clean rig shakers. Work boat and offload freight for 151, replacement VFD for centrifuge and water for platform.;Continue to clean scalper tank, lines and shakers. Pull beaver slide and walkway and stage on rig pipe deck. Disconnect flowline from rig to scalpers and prep to pull scalper tank roof sections.;Continue to clean scalper tank, lines and shakers. Prep to skid rig - install large jack cylinders and clear area behind rig. Skid rig 8' further back from scalper tank to assist in demobing scalper tank accessories.;Pull roof sections off scalper tank. Remove and loadout to work boat scalper tank shakers (2), transfer pumps (2), flow line header to shakers and scalper tank roof sections (2).;Transverse rig package on white iron to assist in making room to pull scalper tank. Pull handrail sections and secure on shaker platform. Pull discharge line and secure to scalper tank.;Pull scalper tank and offload to work boat for back haul.;Disconnect and coil up hoses from scalper tank and rig to Jackup. Clean platform deck. Disconnect electrical service lines and jumpers and coil up for storage. 7/29/2022 Continue to disconnect electrical service connections for rig. Rig down plumbing from Jackup to rig, break clamps and connections. Remove handrails from HAK rack deck. Skid HAK rack to allow construction crane to reach deck sections. Remove middle and end HAK rack sections and stage for load out.;Remove third HAK rack section and stage. Cut corner braces on HAK rack green iron and prep green iron beams for loadout. Continue to disconnect electrical service connections for rig. Bundle plumbing hard lines and prep for storage.;Install lift plates on HAK deck green iron beams. Remove 6-line stanchion cradles from platform deck. Pull scalper tank rig mats and stage for loadout. Rig down skid jacks and prep decks for offload and backload. Clean platform deck.;Work boat: Offload groceries and supplies for 151. Load out HAK deck green iron beams (4), scalper tank rig mats (2), HAK deck end sections (2), middle deck section and basket with clamps and 6-line stanchions.;Lay out and pull back electrical extension cables to Jackup and prep to pull cable walkway. 7/30/2022 Lay out and pull back electrical extension cables to Jackup and store on overhead rack. Prep deck to skid rig package.;Skid rig package from Leg #2 to just in front of Leg #1, stopping short to provide room to build cantilever deck w/o having to work over water. Remove handrails from port side of cantilever deck.;Prep Jackup deck and cantilever beams for skid out. Remove handrails, stairs and temporary cabling. Skid cantilever forward 19' and replace VFD panel for centrifuge. Offload misc. equipment to boat and wait for tide to change. Cantilever back in to 12' for beam install.;Offload modified Rig 404 beams from boat (1 @ 64', 2 @ 60'), set in place on cantilever and secure. Offload and attempt to install first support frame on top of cantilever beams. Found frame makes contact with support cross members and trough when overhung as designed.;Remaining 2 support frames are not expected to be delivered to the dock until Monday. Meeting scheduled to discuss changing overhang side with Design Engineer.;Move transverse skid cylinder on rig. Move rig skid cylinders to aft side of drill floor in preparation for continuing to skid rig over B-03A. Remove flow line section from rig. General housekeeping and maintenance around rig and platform.;Continue with general maintenance and housekeeping around rig and platform. Clean out sand traps on rig. Dress shakers with 200 screens. Pull and rebuild 4-way valve on accumulator unit for lower pipe rams. Dress service lines going to rig. 7/31/2022 Skid cantilever in. Relocate middle beam on cantilever and secure. Rotate support frame 180 deg and set in place. Mark holes, remove support frame and re-drill new bolt holes. Install support frame and secure with bolts.;Waiting on final 2 support frames and HAK deck plates to arrive - expected at dock for 7am callout. Replace water pump on starboard crane..;Waiting on final 2 support frames and HAK deck plates to arrive. General housekeeping and maintenance - changeout heater in drill shack, work on derrick lights, and cleanout flow ditches.;Waiting on final 2 support frames and HAK deck plates to arrive. General housekeeping and maintenance - Remove suction covers on shakers and inspect. Pull return flow nipple and inspect. Grease choke manifold. Service all rig floor equipment. 8/1/2022 General maintenance and housekeeping. Hang tarps in derrick. Make up DSA and spacer spools to riser and stage on deck. Consolidate equipment on upper pipe deck.;Offload support frames from boat and set in place on beams. Mark holes, remove both support frames and re-drill new bolt holes. Install support frames and secure with bolts.;Offload HAK deck plates and set in place on support frames. Mark holes, remove both deck plates and drill bolt holes. Reset deck plates and secure to support frame with bolts. UOSS stitch welding support frame.;UOSS continuing to weld HAK deck plates and support frames. Skid cantilever into position. Skid rig forward over well house. Pull electrical service cables for rig on HAK deck. Install handrail sections on top of HAK deck. Rig up and transverse rig into position over well B-03A. 8/2/2022 Continue to safe out HAK deck covering gaps. Offload and install steel plate for HAK deck from boat. Continue to assist welders with walkways and stair modifications. Secure deck rig to platform with clamps. Continue pulling cables and hooking up electrical service lines to rig.;Run hoses and hook up plumbing service lines to rig. Run umbilical for secondary BOPE control. Modify beaver slide and install.;Continue to assist welders with walkways and stair modifications. Modify and install flowline from rig, across HAK deck and into flow box. Continue to run hoses and hook up plumbing service lines to rig. Weld up openings in flow box under cantilever deck.;Changing out SALA blocks in derrick. n (LAT/LONG): evation (RKB): API #: Well Name: Field: County/State: NCIU B-03 North Cook Inlet Unit Hilcorp Energy Company Composite Report , Alaska Contractor AFE #: AFE $: Job Name: Spud Date: Note: The PB for sidetrack P&A work (subject of sundry 322-114) alreadyreported in another 10-407 form. This 10-407 only covers setting the whipstock which was included as part of the PTD for the sidetrack toNCIU B-03A (PTD 222-048)-bjm. 8/3/2022 Hang new Sala blocks on rig floor. Test run all equipment rig floor. Troubleshoot TD blower alarm light. Continue to modify handrail, stairs and walkways. Install jet lines on flow line.;Continue to install jet lines on flow lines. Install safety clamps on shock hoses. Troubleshoot and repair derrick lights.;Check well for pressure and nipple down 11" 10M dry hole tree.;Nipple up 11" 10M x 13-5/8" 5M riser and 13-5/8" BOPE stack. Hook up choke and kill lines. Torque all bolts to spec. Hook up Koomy lines and function all components. Install bell nipple.;Fill stack and rig up test equipment. Perform shell test and re-torque all connections on riser and BOPE stack. 8/4/2022 Torque all connections on BOP and riser assembly. Check Koomey bottle pressure.;R/up and test 13-5/8" 5M BOPE as per AOGCC and Hilcorp standards, Witness waived by Jim Regg. 250psi low/ 3000psi high, on 4" and 4-1/2" pipe. Perform Koomey draw down test, functioned BOPE from all stations, performed testing from drillers remote station. Tested rig gas alarms and PVT sensors;Pump out stack. Run wear bushing. L/dn 4-1/2" test assembly. R/dn test pump and cleared floor.;Install bell nipple;Hold PJSM for running CIBP. M/up CIBP as per Baker rep. Test flow to ensure no blockage in tool. RIH with CIBP at 2min per stand as per Baker rep. Conduct Well Control While Tripping drill.;RIH to 3568' w/ 94k up wt/ 88k dn wt. Put 20 turns to the right in pipe and go through setting procedure as per Baker rep. Set down 70k and P/up 130k three times to verify CIBP was set. Turn pipe 10 times to right and saw indication that tool had released. Top of CIBP at 3568';R/up for displacement, Production smoke alarm sounded, closed bag and IBOP on top drive then mustered rig crew. Production noted that it was a false alarm and called an all clear. Held PJSM for wellbore displacement.;Pumped 66 BBL of FIW chased with 16 BBL of hi-vis spacer. At 977 strokes, began pumping 9.0PPG LSND mud. At 3013 strokes, began to see spacer come back. At 3444 strokes, clean mud was noted and pumps were shut down. 207 BBL of LSND mud pumped, and 219 BBL of wellbore fluid displaced to pit #3.;R/up and tested 9-5/8" casing to 2000psi for 30min on chart (good);Pump displaced wellbore fluid from pit #3 to Tyonek production platform. Install wiper rubber hold down plate. POOH with Baker running tool.;Inlet Drill Water Used Today: 250 BBL Inlet Water Used Cumulative: 250 BBL Discharge Today: 0 Discharge Cumulative: 0 Daily Downhole Losses: 0 Total Down Hole Losses: 0 Metal Recovered Today: 0 Metal Recovered Total: 0 8/5/2022 M/U BHA #2, Baker 8.5 milling assembly, Spery directional assembly. Carry Scribe. Test MWD tools at 250 GPM. Good. P/U Baker 9 5/8 whipstock. Check anchor pins. Left in two 6600# shear pins. Install 25K Whipstock shear bolt.;RIH with 9- 4.75 DC, 9- 4'' HWDP & RIH on 4'' dp at 2 min per stand to 2040'.;Fill pipe and test MWD. Good. RIH F/ 2040' T/ 3471'.;Fill pipe and orientate to 60Deg Right. RIH & set down on anchor at 3568'. Set anchor with 15k DN. Saw Good Shear. Over pull 15K. Good. Slack off and shear off of whipstock at 25K.;Establish milling parameters. 80-100 RPM, 5K free TQ. 280 GPM @ 660 psi. Mill window as per baker rep F/ 3546' T/3547.6'. 100 RPM 350 GPM, 1000 PSi, 4500-7000 TQ. Mw 9.0 in and out.;Mill window as per Baker rep F/3547.6' T/3549.4'. 70 RPM, 176 GPM, 265PSI, 3k-9k TQ., 1k-2k WOB, Mw 9.0 in and out;Mill window as per Baker rep F/3549.4 T/3550.1'. 70 RPM, 176 GPM, 265PSI, 4k-10k TQ. , 1k-2k WOB, Mw 9.0 in and out Pump 20 BBL Hi-Vis sweep. came back on-time and increase in metal cuttings.;Had production check 9-5/8" OA gauge, Gauge had signs of damage and was maxed out on pressure (200psi gauge). Production change gauge and increased to 1000psi gauge, New gauge showed 600psi. Shut dn pumps and bleed off SPP.;Brought pumps back on and saw no increase in pressure on 9-5/8" OA. resumed milling window. F/3550.1'. T/3551' 76 RPM, 180 GPM, 280PSI, 7k-9k TQ. , 1k-2k WOB, Mw 9.0 in and out. Total of 7 lbs metal recovered.;Removed bell nipple cover plate. Plate was restricting metal cuttings to flow line. Once plate was removed, approximately 3# of metal recovered from bell nipple flow area.;Resumed milling operations as per Baker rep. F/3550.1' T/3553.8'. 75 RPM, 176 GPM, 265PSI, 5700-10870 TQ., 4k-10k TQ, 3k-4k WOB, Mw 9.0 in and out;Milling operations as per Baker rep. F/3553.8' T/3557'. 75 RPM, 176 GPM, 265PSI, 5000-6500 TQ., 3k-4k WOB, Mw 9.0 in and out. Pump 20 BBL Hi-Viz sweep at 3553.6' at 328 GPM , came back on time with 16 lbs of metal.;Milling operations as per Baker rep. F/ 3557', T/ 3557.7' , Working drilling parameters to establish better milling rates. 50-80 RPM, 176 GPM, 5k-8k TQ, 5k-25k WOB, Mw 9.0 in and out. Pump 20 BBL Hi-Viz sweep at 3557.2' at 328 GPM, came back on time with 15 lbs of metal.;Milling operations as per Baker rep. F/ 3557.22', T/ 3561', Working drilling parameters to establish better milling rates. 50-80 RPM, 325 GPM, 5k-10k TQ, 4k-11k WOB, Mw 9.0 in and out. Pump 20 BBL Hi-Viz sweep at 3557.2' at 328 GPM, came back on time with 8 lbs of metal.;Inlet Drill Water Used Today: 375 BBL Inlet Water Used Cumulative: 625 BBL Discharge Today: 0 Discharge Cumulative: 0 Daily Downhole Losses: 0 Total Down Hole Losses: 0 Metal Recovered Today: 60 lbs Metal Recovered Total: 60 lbs 9-5/8” OA Pressure: 200 psi 9-5/8” OOA Pressure: 1 psi RIH & set down on anchor pp Top of CIBP at 3568';R 3568'. at p Mill window as per baker rep F/ 3546' T/3547.6 Missing pre-rig work and pulling of tubing. P/U Baker 9 5/8 whipstock y RIH with CIBP Kaitlyn Barcelona Hilcorp North Slope, LLC GeoTechnician 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: 907 564-4389 E-mail: kaitlyn.barcelona@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal Received By: Date: DATE: 5/16/2022 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 DATA TRANSMITTAL NCI B-03 (PTD 198-059) Plug/CBL/Cement 3/30/2022 Please include current contact information if different from above. PTD:198-059 T36605 Kayla Junke Digitally signed by Kayla Junke Date: 2022.05.16 10:38:02 -08'00' Kaitlyn Barcelona Hilcorp North Slope, LLC GeoTechnician 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: 907 564-4389 E-mail: kaitlyn.barcelona@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal Received By: Date: DATE: 4/20/2022 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 DATA TRANSMITTAL NCI B-03 (PTD 198-059) Punch 3/16/2022 Please include current contact information if different from above. PTD:198-059 T36585 Kayla Junke Digitally signed by Kayla Junke Date: 2022.05.16 10:36:43 -08'00' 1a. Well Status:Oil SPLUG Other Abandoned Suspended 1b. Well Class: 20AAC 25.105 20AAC 25.110 Development Exploratory GINJ WINJ WDSPL No. of Completions: __________________ Service Stratigraphic Test 2. Operator Name: 6. Date Comp., Susp., or 14. Permit to Drill Number / Sundry: Aband.: 3. Address: 7. Date Spudded: 15. API Number: 4a. Location of Well (Governmental Section): 8. Date TD Reached: 16. Well Name and Number: Surface: Top of Productive Interval: 9. Ref Elevations: KB: 17. Field / Pool(s): GL: N/A BF: N/A Total Depth: 10. Plug Back Depth MD/TVD: 18. Property Designation: 4b. Location of Well (State Base Plane Coordinates, NAD 27): 11. Total Depth MD/TVD: 19. DNR Approval Number: Surface: x- y- Zone- 4 TPI: x- y- Zone- 4 12. SSSV Depth MD/TVD: 20. Thickness of Permafrost MD/TVD: Total Depth: x- y- Zone- 4 5. Directional or Inclination Survey: Yes (attached) No 13. Water Depth, if Offshore: 21. Re-drill/Lateral Top Window MD/TVD: Submit electronic information per 20 AAC 25.050 130 (ft MSL) 22.Logs Obtained: 23. BOTTOM 30"461 20" X-56 1,208 13-3/8" L-80 3,752 9-5/8" P-110 8,918 7" P-110 11,378 5" P-110 12,778 3-1/2" P-110 13,356 24. Open to production or injection? Yes No 25. 26. Was hydraulic fracturing used during completion? Yes No DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED 27. Date First Production: Method of Operation (Flowing, gas lift, etc.): Hours Tested: Production for Gas-MCF: Test Period Casing Press: Calculated Gas-MCF: Oil Gravity - API (corr): Press. 24-Hour Rate 2576423.3 2-7/8" 7,391 See Schematic 11,420 17,150 8,678 8-1/2" Surf 1,214 If Yes, list each interval open (MD/TVD of Top and Bottom; Perforation Size and Number; Date Perfd): ACID, FRACTURE, CEMENT SQUEEZE, ETC. CASING, LINER AND CEMENTING RECORD List all logs run and, pursuant to AS 31.05.030 and 20 AAC 25.071, submit all electronic data within 90 days of completion, N/A Lead 234 sxs, Tail 424 sxs12-1/4" TUBING RECORD 17,864 15,301 Lead 1000 sxs, Tail 600 sxs 8,777 12,785 16" 220 sxs 8-1/2" See Schematic 4,321 8,431 3-1/2" SIZE DEPTH SET (MD) See Schematic PACKER SET (MD/TVD) 5-1/2" GP 13 11,561 17,159 N/A Driven 32 8-1/2" BOTTOM STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG Hilcorp Alaska, LLC WAG Gas 4/18/2022 198-059 / 322-114 50-883-20095-00-00 N Cook Inlet Unit B-03 ADL0017589 / ADL0037831 1251' FNL, 964' FWL, Sec 6, T11N, R9W, SM, AK 1061' FNL, 2006' FWL, Sec 13, T11N, R10W, SM, AK North Cook Inlet Unit / Tertiary Gas Pool N/A 5/3/1998 17864 MD / 13356 TVD 4148 MD / 3578 TVD 132 HOLE SIZE AMOUNT PULLED suspension, or abandonment, whichever occurs first. Types of logs to be listed include, but are not limited to: mud log, spontaneous potential, gamma ray, caliper, resistivity, porosity, magnetic resonance, dipmeter, formation tester, temperature, cement evaluation, casing collar locator, jewelry, and perforation record. Acronyms may be used. Attach a separate page if necessary 3800 Centerpoint Drive, Suite 1400, Anchorage, AK 99503 331983.7 2586728.9 N/A Lead 644 sxs, Tail 720 sxs 10/23/1998 CEMENTING RECORD N/A SETTING DEPTH TVD TOP Surf 24" N/A Surf 200 sxs CASING WT. PER FT.GRADE 53.5 327594.8 TOP SETTING DEPTH MD Surf Surf Per 20 AAC 25.283 (i)(2) attach electronic information 72 11,761 Surf Surf 547 133 461 Surf 4,400 N/A Water-Bbl: PRODUCTION TEST N/A Date of Test: Oil-Bbl: N/A Flow Tubing N/A Gas-Oil Ratio:Choke Size: Sr Res EngSr Pet GeoSr Pet Eng 418 MD/TVD Oil-Bbl: Water-Bbl: 18 Form 10-407 Revised 3/2020 Submit within 30 days of Completion, Suspension, or Abandonment xG Suspended 4/18/2022 MDG RBDMS 5/13/2022 MDG By Meredith Guhl at 1:24 pm, May 13, 2022 SFD 8/12/2022BJM 11/29/22 DSR-5/13/22 Conventional Core(s): Yes No Sidewall Cores: 30. MD TVD Top of Productive Interval 31. List of Attachments: Operations Summary, Schematic 32. I hereby certify that the foregoing is true and correct to the best of my knowledge. Dan Marlowe Contact Name: Chad Helgeson, Operations Engineer Operations Manager Contact Email:chelgeson@hilcorp.com Authorized Contact Phone: 907-777-8405 General: Item 1a: Item 1b: Item 4b: Item 9: Item 15: Item 19: Item 20: Item 22: Item 23: Item 24: Item 27: Item 28: Item 30: Item 31: The Kelly Bushing, Ground Level, and Base Flange elevations in feet above Mean Sea Level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, or Other (explain). Provide a listing of intervals tested and the corresponding formation, and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Pursuant to 20 AAC 25.070, attach to this form: well schematic diagram, summary of daily well operations, directional or inclination survey, and other tests as required including, but not limited to: core analysis, paleontological report, production or well test results. Report measured depth and true vertical thickness of permafrost. Provide MD and TVD for the top and base of permafrost in Box 29. Attached supplemental records should show the details of any multiple stage cementing and the location of the cementing tool. 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). Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Pursuant to 20 AAC 25.071, submit detailed descriptions, core chips, photographs, and all subsequent laboratory analytical results, including, but not limited to: porosity, permeability, fluid saturation, fluid composition, fluid fluorescence, vitrinite reflectance, geochemical, or paleontology. Report the Division of Oil & Gas / Division of Mining Land and Water: Plan of Operations (LO/Region YY-123), Land Use Permit (LAS 12345), and/or Easement (ADL 123456) number. This form and the required attachments provide a complete and concise record for each well drilled in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. All laboratory analytical reports regarding samples or tests from a well must be submitted to the AOGCC, no matter when the analyses are conducted. Information to be attached includes, but is not limited to: summary of daily operations, wellbore schematic, directional or inclination survey, core analysis, paleontological report, production or well test results, per 20 AAC 25.070. 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. TPI (Top of Producing Interval). INSTRUCTIONS Authorized Name: Authorized Title: Signature w/Date: 29. GEOLOGIC MARKERS (List all formations and markers encountered): FORMATION TESTS Review the reporting requirements of 20 AAC 25.071 and, pursuant to AS 31.05.030, submit all electronic data within 90 days of completion, suspension, or abandonment, whichever occurs first. Well Class - Service wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Formation at total depth: If Yes, list formations and intervals cored (MD/TVD, From/To), and summarize lithology and presence of oil, gas or water (submit separate pages with this form, if needed). Submit detailed descriptions, core chips, photographs, and all subsequent laboratory analytical results per 20 AAC 25.071. Yes No Well tested? Yes No 28. CORE DATA If yes, list intervals and formations tested, briefly summarizing test results. Attach separate pages to this form, if needed, and submit detailed test information, including reports, per 20 AAC 25.071. NAME Permafrost - Top Permafrost - Base Form 10-407 Revised 3/2020 Submit within 30 days of Completion, Suspension, or Abandonment Digitally signed by Dan Marlowe (1267) DN: cn=Dan Marlowe (1267), ou=Users Date: 2022.05.10 11:52:10 -08'00' Dan Marlowe (1267) _____________________________________________________________________________________ Updated By DMA 05-09-22 SCHEMATIC North Cook Inlet Unit Well: NCI B-03 Last Completed: 12/15/2010 PTD: 198-059 API: 50-883-20095-00-00 JEWELRY DETAIL No Depth (MD) Depth (TVD)ID OD Item 1 4,173’3,578’8.353 CIBP w/ 25ft of cement – TOC @ 4,148 (3/30/22) 2 4,304’3,686’3.00 4.25 Baker 80-40 GBH-22 Locator & seal assembly 4,319 3,696’3.00 3.98 Baker 80-40 Spacer tube and seal assembly w/ ½ Mule shoe Isolation String A1 4,290 3,676’6.37 7.5”7” C-2 liner setting sleeve, 10’ tieback extension 4,305’3,684’3.00 5.0 Baker 80-40 Seal Bore 4” ID x 10’ long 5” BTC pin x pin A 4,431’3,773’2.37 4.5 Baker 450-237 HS Packer #1 w/30k shear release 4,275’3,665’2.441 2-7/8” CIBP w/ 27’ of cement – TOC @ 4,248 (3/15/22) B 4,660’3,929’2.313 3.16 Baker 2-7/8” SLCMU Sliding Sleeve (Closed 12/4/21) C 4,873’4,070’2.37 4.5 Baker HS Packer #1, 2-7/8” EUE w/30k shear release C1 4,879’4,072’~1.0 2.44 SL Patch without AA stop or top element, assembly, top, 4,879’ D 5,342’4,378’2.347 4.5 Baker HS Packer #1, 2-7/8” EUE w/30k shear release E 5,591’4,539’2.313 3.16 Baker 2-7/8” SLCMU Sliding Sleeve (Open 12/19/10) F 5,838’4,702’2.37 4.5 Baker HS Packer #1, 2-7/8” EUE w/30k shear release G 6,088’4,875’2.313 3.16 Baker 2-7/8” SLCMU Sliding Sleeve (Open 12/19/10) H 6,337’5,048’2.37 4.5 Baker HS Packer #1, 2-7/8” EUE w/30k shear release J 7,277’5,707’2.37 4.5 Baker HS Packer #1, 2-7/8” EUE w/30k shear release K 7,358’5,765’2.313 3.7 Camco Landing Nipple X Profile L 7,390 5,787’2.375 3.51 2-7/8” WLEG Gravel Pack 8 4,319’3,696’3.880 Baker 190-60 PBR w/ 15’ seal travel 4,336’3,707’4.872 Gravel Pack 4,341’3,711’5.000 Baker KOIV, Busted open on 11/19/03 4,349’3,716’6.000 Baker 9-5/8” 53.5# SC-1R Packer Assy w/ KOIV @4,381’ 9 4,830’4,041’6.000 Baker 9-5/8” 53.5# SC-1R Packer 10 5,308’4,355’6.000 Baker 9-5/8” 53.5# SC-1R Packer 11 5,777’4,661’6.000 Baker 9-5/8” 53.5# SC-1R Packer 12 6,277’5,006’6.000 Baker 9-5/8” 53.5# SC-1R Packer 13 6,855’5,410’4.892 RA Tag in box of 5-1/2”, 17 ppf, L-80 Braden Blank SLHT BxP 14 7,089’5,574’4.892 RA Tag in box of 5-1/2”, 17 ppf, L-80 Braden Blank SLHT BxP 15 7,217’5,665’6.000 Baker 9-5/8” 53.5# SC-1R Packer 16 7,767’6,053’4.892 RA Tag in box of 5-1/2”, 17 ppf, L-80 Braden Blank SLHT BxP 17 8,155’6,327’6.000 Baker 9-5/8” 53.5# SC-1R Packer sump packer 2/MO ext. 18 8,397’6,500’3.813 Landing Nipple X Profile 19 8,430’6,524’4.000 4-1/2” WLEG CASING DETAIL Size Wt Grade Conn ID Top Btm 30”547 Welded 29.000 Surf 461’ 20”133 K-55 Dni-Quip 19.730 Surf 1,214’ 13-3/8”72 L-80 BTC 12.415 Surf 4,400’ 9-5/8”53.5 P-110 BTC 8.535 Surf 11,761’ 7”32 P-110 Butt 6.094 11,561’15,301’ 5”18 P-110 VAM FJL 4.270 11,420’17,159’ 3-1/2”13 P-110 PH-6 17,159’17,864’ TUBING DETAIL 3-1/2”9.3 L-80 EUE Mod 2.992 4,187’4,321’ 2-7/8”6.4 L-80 Hyd 511 2.377 4,290’7,391’ 5-1/2” Gravel Pack 17 L-80 SLHT 4,319’ 8,431’ Updated By DMA 05-09-22 SCHEMATIC North Cook Inlet Unit Well: NCI B-03 Last Completed: 12/15/2010 PTD: 198-059 API: 50-883-20095-00-00 PERFORATION DETAIL Zone Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT Date Status CI-1 4,463' 4,547' 3,795' 3,853' 84' 10/21/2003 Closed CI-2 4,570' 4,663' 3,869' 3,931' 93' 10/21/2003 Closed CI-3 4,690' 4,701' 3,949' 3,956' 11' 10/21/2003 Closed CI-4 4,748' 4,820' 3,987' 4,035' 72' 10/21/2003 Isolated CI-4 4,888' 4,918' 4,080' 4,099' 30' 10/21/2003 Isolated CI-5 4,927' 4,955' 4,105' 4,124' 28' 10/21/2003 Isolated CI-7 5,060' 5,090' 4,192' 4,212' 30' 10/21/2003 Isolated CI-8 5,200' 5,214' 4,284' 4,294' 14' 10/21/2003 Isolated CI-9 5,268' 5,291' 4,329' 4,344' 23' 10/21/2003 Isolated CI-11 5,355' 5,402' 4,386' 4,417' 47' 10/21/2003 Open B 5,588' 5,595' 4,538' 4,542' 7' 10/21/2003 Open B 5,688’ 5,708’ 4,602’ 4,616’ 20’ 04/27/2021 Open B 5,752' 5,765' 4,644' 4,653' 13' 10/21/2003 Open C 5,933' 5,939' 4,767' 4,771' 6' 10/21/2003 Open D 6,038' 6,046' 4,840' 4,846' 8' 10/21/2003 Open D 6,048' 6,054' 4,847' 4,851' 6' 10/21/2003 Open E 6,220' 6,227' 4,967' 4,972' 7' 10/21/2003 Open E 6,261' 6,268' 4,995' 5,000' 7' 10/21/2003 Open H 6,628' 6,648' 5,251' 5,265' 20' 10/21/2003 Open H 6,655' 6,672' 5,270' 5,282' 17' 10/21/2003 Open H 6,696’ 6,716’ 5,298’ 5,312’ 20’ 04/26/2021 Open I 6,955' 6,978' 5,480' 5,496' 23' 10/21/2003 Open L 7,180' 7,197' 5,638' 5,650' 17' 10/21/2003 Open N 7,495' 7,517' 5,862' 5,877' 22' 10/21/2003 Covered P 7,700' 7,727' 6,006' 6,025' 27' 10/21/2003 Covered Q 7,955' 7,968' 6,186' 9,195' 13' 10/21/2003 Covered R 8,105' 8,145' 6,291' 6,319' 40' 10/21/2003 Covered OLD COMPLETION BELOW CEMENT Note: Old tubing tally has not been located. Measurements below are approximate. No Depth (MD) Depth (TVD) ID OD Item 11,181’ 8,506’ Calc. Top of Cement 11,354’ 8,631’ BWD Packer w/ seals top 11,362’ 8,636’ Bevel guide over tubing stub from 11,362’ – 11,368’ – Tubing chemically cut at 11,362’ after failed pressure test 11,380 8,649’ AHC Packer 11,398’ 8,662’ Fish – 24’ Wireline fish on X Nipple 11,418’ 8,676’ X Nipple (2.313”) 13,700’ 10,341’ Tubing tail 16,890’ 12,571’ Top of Fill Rig Start Date End Date 3/15/22 4/18/22 Cut 50 foot drill line, string up 2.5 layers drill line on Drawworks drum, lay over mast to headache rack,. Offload work boat. Pick up risers, make up spacer spools 11" 10m x 11" 5m spool & 11" 5m x 13-5/8 5m spool to 13-5/8" 5m riser spool and lower in cellar and make up on well head, make up mud cross to riser. Nipple up 13-5/8 BOPE double ram and annular, R/U mud pump, koomey and choke house, set tongs and subs in place. Raise mast and secure guy wire, R/U rig floor. R/U cellar tarps, mud pits, off load boat, Rig up choke and kill lines. M/U test 3 1/2" jt. and install same, function test BOP's, and shell test to 3000psi. 03/25/2022- Friday Wait on weather due to high winds and seas. prep well head to circulate well. 03/26/2022 - Saturday Continue to wait on weather, Housekeeping and prep to circulate, Modify hand rails and adjust stairs going to the carrier. Off-load boat - Mud pump/ Mix Tank/ BOPE/ Heaters/ HPU/ 2 baskets of pups and X/O's. Spot and rig up mud pump to circulate well. Circulate Drill water @ 2.5 BPM / 0 psi for 300 bbls. Monitor well- tubing and IA both static. R/D circulating equipment and set BPV. N/D production tree, spot pits and offload boat. Clean hanger threads and N/U Riser and BOPE. 03/27/2022 - Sunday AKEL crew assembles and attends morning safety meeting, PJSM. Warm up eline equipment. Fill tubing with 1.5 bbls drill water and monitor IA. Pressure increases from 22 to 23 psi, tubing on very slight vac. Rig up eline. Arm and RIH with 3.5" jet cutter. Correlate to tubing tally and tag high at 4193'. Call town and get permission to cut high. Jet cut tubing at 4187', good indication. POOH and RDMO eline to A-11. 03/24/2022 - Thursday Load Boat on Steelhead platform- Beam package, choke skid, Accumulator house, and hoses, Draw works, A-leg and Carrier. Arrived at Tyonek and sign in, held platform orientation with rig crew, taking measurements from center of beam package, Wait on E-line to finish up, clear decks. Spot front double base beam/ Spot back single base beam, install spreader braces in beam package, set Carrier on beam package, set Draw works on Carrier, set A-leg on carrier, spot Accumulator, house/ spot choke skid. Waiting on weather to backload boat at Steelhead winds at 50 to 55 mph N at rpt time winds blowing 40/45 N. 03/16/2022 - Wednesday AKEL crew assembles and attends morning safety meeting, PJSM. Rig up eline equipment and pressure test lubricator to 250 psi low / 1200 psi high. RIH with CCL / 2.20" gauge ring. Correlate to tubing tally and tag 4297' (top of 3.5" seal assembly). POOH. Lay down and inspect tools. Arm and RIH with 3.5" CIBP setting assembly (2.75" runnning OD). Correlate to tubing tally and set plug at 4275'. POOH. Lay down and inspect tools. Bleed off tubing pressure down to 0 psi stable. Pump down tubing for MIT and IA pressure increases indicating slight TxIA communication, possibly through sliding sleeve. Mix 5 gallons of cement and load into 2" dump bailer. RIH and dump 5 gallons (13.7') of cement on top of CIBP. POOH. Lay down and inspect tools. Mix 5 gallons of cement and load into 2" dump bailer. RIH and dump 5 gallons (13.7') of cement on top of last cement run. POOH. RDMO eline. Calculated TOC: 4248'. Bleed GL pressure off well and load IA with drill water. Final IA pressure before shutting down is 20 psi. Secure well and SDFN. 03/15/2022 - Tuesday Daily Operations: Hilcorp Alaska, LLC Well Operations Summary API Number Well Permit NumberWell Name NCI B-03 50-883-20095-00-00 198-059 Calculated TOC: 4248' RIH with 3.5" CIBP setting assembly (2.75" runnning OD). Correlate to tubing tally and set plug at 4275'. P Jet cut tubing at 4187', Rig Start Date End Date 3/15/22 4/18/22 Daily Operations: Hilcorp Alaska, LLC Well Operations Summary API Number Well Permit NumberWell Name NCI B-03 50-883-20095-00-00 198-059 MIT-IA t/2500psi, charted for 30mins-good test, witness by AOGCC Inspector Lou Laubenstein. 03/30/2022 - Wednesday Cont. POOH w/ e-line, CIBP setting tool sheared as planned. R/U & test plug & casing t/ 2500 f/ 10 min good, rig down & blow down. R/U e-line w/ CBL tool string & calibrate. RIH w/ CCL/CBL/GR tool calibrate in hole RIH tag top of CIBP@ 4173 WLM, Log up t/ surface, send logs to PWL for processing. R/U 5 1/2" cmt bailer & stage cmt. spot rig jacks & make alterations to adapt. while r/u. RIH w/ 5 1/2" bailer with 17lb cmt, tag plug@ 4173'wlm P/U dump 35 gal, POOH. Re dress bailer, fill w/ 17lb cmt, RIH and dump 22.5 gal, POOH. Re dress bailer, fill w/ 17lb cmt, RIH and dump 17.5 gal, POOH. RIH with blanked bailer and tag TOC @ 4148', POOH and R/D E-line. R/D floor, beaver slide, stairs, drain BOP stack and riser, de-energize Koomey, Scope and lower mast, R/U and skid rig off well. Prep BOP's and riser for N/D, assist crane crew R/U slickline on B-02. 03/31/2022 - Thursday Cont. assist rig up W/L on B 02, cont. prep BOPE for N/D, arrange deck. preforming rig maint. & housekeeping while waiting on W/L to finish on B-02;Assist moving w/l onto A-12, cont. rig maint & housekeeping, unload boat and arrange deck. Install 2 3/8 x 3 1/2" Var rams in single gate. R/U additional set of Koomey Lines. 04/18/2022 - Monday 03/28/2022 - Monday Inspect traveling block sheave runout. P/U and install 3- 1/2" test jt. Fill stack, perform shell test and test gas alarms. Test BOP's. test annular to 250 low/ 2500 high for 5 min each. Test all other component's to 250 low/ 3000 high for 5 min each, perform Koomey draw test - initial 2950 psi, after function 1800 psi, 200 psi increase 18 sec, full recharge 81 sec, 4 x N2 bottles @ 2000 psi, AOGCC witness waived by Jim Regg. L/D test jt and pull TWC. R/U floor equipment and M/U landing jt. BOLDS. Pull Hanger free @ 70K, String wt 35K, L/D hanger, and pup jts. Cont to POOH laying control line and all jewelry, recovered 19 SS bands. Clean and clear rig floor of control line equipment. M/U scraper BHA. RIH with work string. 03/29/2022 - Tuesday Cont. rih w/ 9-5/8" scraper on 3 1/2" EUE tubing. t/4190' DPM, tag up wt 35k, dn wt 28k. L/D single, wipe 4190-4157 multiple times, R/U circulating lines. Rev CBU 4x @ 4 BPM 330 psi, clean. R/D circ lines, Blow down, R/U Beaver slide, modify & install stand. POOH l/d 3 1/2" EUE 8rd, 9.3# L-80 tubing f/4178'. L/D BHA. R/U wireline unit. RIH with 9 5/8" CIBP and correlate on depth, set CIBP@ 4174' wlm. POOH l/d 3 1/2" EUE 8rd, 9.3# L-80 tubing f/4178'. & test plug & casing t/ 2500 f/ 10 min good, RIH w/ CCL/CBL/GR tool calibrate in hole RIH tag top of CIBP@ 4173 WLM, MIT-IA t/2500psi, charted for 30mins-good test, witness by AOGCC Inspector Lou Laubenstein. set CIBP@ 4174' wlm. RIH w/ 5 1/2" bailer with 17lb cmt, tag plug@ 4173'wlm P/U dump 35 gal, POOH. Re dress bailer, fill w/ 17lb cmt, RIH and dump 22.5 gal, POOH. Re dress bailer, fill w/ 17lb cmt, RIH and dump 17.5 gal, POOH. RIH with blanked bailer and tag TOC @ 4148', Pull Hanger free @ 70K, String wt 35K, L/D hanger, and pup jts. Cont to POOH laying control line and all jewelry, recovered 19 SS bands. Kaitlyn Barcelona Hilcorp North Slope, LLC GeoTechnician 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: 907 564-4389 E-mail: kaitlyn.barcelona@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal Received By: Date: DATE: 5/09/2022 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 DATA TRANSMITTAL NCI B-03 (PTD 198-059) CBL 3/30/2022 Please include current contact information if different from above. PTD:198-059 T36558 Kayla Junke Digitally signed by Kayla Junke Date: 2022.05.09 14:14:38 -08'00' 1 Regg, James B (OGC) From:Regg, James B (OGC) Sent:Thursday, March 31, 2022 10:46 AM To:edhooter295@gmail.com Cc:Harold Soule - (C); Brooks, Phoebe L (OGC) Subject:RE: Emailing: Hilcorp Rig #404 03-28-22 Attachments:BOP Hilcorp404 3-8-2022 revised.xlsx Changed well name to B‐03; MASP to 654 psi; test date to 3/28. Copy of revised report attached for your records. Jim Regg Supervisor, Inspections AOGCC 333 W. 7th Ave, Suite 100 Anchorage, AK 99501 907‐793‐1236 ‐‐‐‐‐Original Message‐‐‐‐‐ From: edhooter295@gmail.com <edhooter295@gmail.com> Sent: Wednesday, March 30, 2022 8:03 PM To: DOA AOGCC Prudhoe Bay <doa.aogcc.prudhoe.bay@alaska.gov>; Brooks, Phoebe L (OGC) <phoebe.brooks@alaska.gov>; Regg, James B (OGC) <jim.regg@alaska.gov> Cc: Harold Soule ‐ (C) <hsoule@hilcorp.com> Subject: Emailing: Hilcorp Rig #404 03‐28‐22 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. Please see rig 404 test rpt. Thanks Ed Hooter Your message is ready to be sent with the following file or link attachments: Hilcorp Rig #404 03‐28‐22 Note: To protect against computer viruses, e‐mail programs may prevent sending or receiving certain types of file attachments. Check your e‐mail security settings to determine how attachments are handled. NCIU B-03 PTD 1980590 STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION *All BOPE reports are due to the agency within 5 days of testing* Submit to:jim.regg@alaska.gov; AOGCC.Inspectors@alaska.gov; phoebe.brooks@alaska.gov Owner/Contractor:Rig No.:404 DATE:3/28/22 Rig Rep.:Rig Phone:907-776-6974 Operator:Op. Phone:907-776-6970 Rep.:E-Mail Well Name:PTD #1980590 Sundry #322-114 Operation:Drilling:Workover:x Explor.: Test:Initial:x Weekly:Bi-Weekly:Other: Rams:250-3000 Annular:250-2500 Valves:250-3000 MASP:654 MISC. INSPECTIONS:TEST DATA FLOOR SAFETY VALVES: Test Result Test Result Quantity Test Result Location Gen.P Well Sign P Upper Kelly 0 NA Housekeeping P Rig P Lower Kelly 0 NA PTD On Location P Hazard Sec.P Ball Type 1 P Standing Order Posted P Misc.NA Inside BOP 1 P FSV Misc 0 NA BOP STACK:Quantity Size/Type Test Result MUD SYSTEM:Visual Alarm Stripper 0 NA Trip Tank NA NA Annular Preventer 1 13-5/8 5m P Pit Level Indicators P P #1 Rams 1 2-7/8" x 5 1/2"P Flow Indicator NA NA #2 Rams 1 Blinds P Meth Gas Detector P P #3 Rams 0 NA H2S Gas Detector P P #4 Rams 0 NA MS Misc 0 NA #5 Rams 0 NA #6 Rams 0 NA Quantity Test Result Choke Ln. Valves 1 2-1/16 5m P Inside Reel valves 0 NA HCR Valves 1 2-1/16 5m P Kill Line Valves 2 2-1/16 5m P Check Valve 0 NA ACCUMULATOR SYSTEM: BOP Misc 0 NA Time/Pressure Test Result System Pressure (psi)2950 P CHOKE MANIFOLD:Pressure After Closure (psi)1800 P Quantity Test Result 200 psi Attained (sec)18 P No. Valves 11 P Full Pressure Attained (sec)81 P Manual Chokes 1 P Blind Switch Covers:All stations Yes Hydraulic Chokes 1 P Nitgn. Bottles # & psi (Avg.):4@2000 P CH Misc 0 NA ACC Misc 0 NA Test Results Number of Failures:0 Test Time:5.5 Hours Repair or replacement of equipment will be made within days. Remarks: AOGCC Inspection 24 hr Notice Yes Date/Time 3/25/22 1:04 PM Waived By Test Start Date/Time:3/28/2022 8:00 (date)(time)Witness Test Finish Date/Time:3/28/2022 13:30 BOPE Test Report Notify the AOGCC of repairs with written confirmation to: AOGCC.Inspectors@alaska.gov Jim Regg Hilcorp Tested with 3-1/2" test joint, Calibrated & tested gas Alarm , Annular closing time on 3-1/2 T.J. 19 sec. Chad Johnson / Ed Castgine Hilcrop AK Ed Hooter / Sam Menapace NCIU B-03 Test Pressure (psi): Howard.hooter@hilcrop.com Form 10-424 (Revised 02/2022)BOP Hilcorp404 3-8-2022 revised      J. Regg; 3/31/2022 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. From:McLellan, Bryan J (OGC) To:Chad Helgeson Cc:Harold Soule - (C); Donna Ambruz Subject:RE: NCIU B-03 (PTD# 198-059) Sundry # 322-114 Date:Wednesday, March 30, 2022 5:37:00 PM Jake, Hilcorp has approval to dump cement on the CIBP and MIT-IA after the rig moves off the well. Regards Bryan McLellan Senior Petroleum Engineer Alaska Oil & Gas Conservation Commission 333 W 7th Ave Anchorage, AK 99501 Bryan.mclellan@alaska.gov +1 (907) 250-9193 From: Chad Helgeson <chelgeson@hilcorp.com> Sent: Wednesday, March 30, 2022 12:30 PM To: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov> Cc: Harold Soule - (C) <hsoule@hilcorp.com>; Donna Ambruz <dambruz@hilcorp.com> Subject: NCIU B-03 (PTD# 198-059) Sundry # 322-114 Bryan, As we discussed on the phone we may move the step (#11 & 13) to dump cement and conduct the MIT-IA on Tyonek B-03 Workover until after the rig is off the well. (after step 15.) and there will be access to the well again after the workover is completed on Tyonek A-12. The Eline crews have been working through the night and for safety reasons we would like to lay them down for rest and the rig will be able to complete the rig down of the well. We will track this in our Rig workover change form for this job. Thanks Chad Helgeson KEN Operations Engineer Hilcorp Alaska LLC chelgeson@hilcorp.com 907-777-8405 (O) 907-229-4824 (C) The information contained in this email message is confidential and may be legally privileged and is intended only for the use of theindividual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. 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DERYH WRS SHUI GXH WR MXQN DQG SDFNHUV LQ WKH ZD\ 3URYLGH $2*&& RSSRUWXQLW\ WR ZLWQHVV FDVLQJ LQWHJULW\ 0,7 %23 WHVW WR SVL $QQXODU WHVW WR SVL '65 ; dts 3/11/2022 JLC 3/11/2022 RBDMS SJC 031122 Jeremy Price Digitally signed by Jeremy Price Date: 2022.03.11 15:19:28 -09'00' tĞůůtŽƌŬWƌŽŐŶŽƐŝƐ tĞůů͗ͲϬϯ ĂƚĞ͗ϯͬϴͬϮϬϮϮ tĞůůEĂŵĞ͗E/hͲϬϯW/EƵŵďĞƌ͗ϱϬͲϴϴϯͲϮϬϬϵϱͲϬϬͲϬϬ ƵƌƌĞŶƚ^ƚĂƚƵƐ͗^/'ĂƐ>ŝĨƚĞĚWƌŽĚƵĐĞƌ>ĞŐ͗>ĞŐηϭ;EtͿ ƐƚŝŵĂƚĞĚ^ƚĂƌƚĂƚĞ͗ϯͬϮϭͬϮϬϮϮ;ůŝŶĞͿZŝŐ͗Ͳ>ŝŶĞΘZŝŐϰϬϰ ZĞŐ͘ƉƉƌŽǀĂů ZĞƋƵŝƌĞĚ͍ ϰϬϯĂƚĞZĞŐ͘ƉƉƌŽǀĂů ZĞĐĞŝǀĞĚ͗ ZĞŐƵůĂƚŽƌǇŽŶƚĂĐƚ͗ŽŶŶĂŵďƌƵǌ;ϴϯϬϱͿWĞƌŵŝƚƚŽƌŝůůEƵŵďĞƌ͗ϭϵϴͲϬϱϵ &ŝƌƐƚĂůůŶŐŝŶĞĞƌ͗ŚĂĚ,ĞůŐĞƐŽŶ;ϵϬϳͿϳϳϳͲϴϰϬϱ;KͿ;ϵϬϳͿϮϮϵͲϰϴϮϰ;DͿ ^ĞĐŽŶĚĂůůŶŐŝŶĞĞƌ͗<ĂƚŚĞƌŝŶĞK͛ŽŶŶŽƌ;ϵϬϳͿϳϳϳͲϴϯϳϲ;KͿ;ϮϭϰͿϲϴϰͲϳϰϬϬ;DͿ Current Bottom Hole Pressure: 1155 psi @ 5018’ TVD 0.23 psi/ft Current Tubing Pressure: 270 psi Maximum Expected BHP: 1155 psi @ 5,018’ TVD 0.23 psi/ft Max Potential Surface Pressure (MPSP): 654 psi @ 5,018’ TVD Using 0.1 psi/ft gradient 20 AAC 25.280(b)(4) ƌŝĞĨtĞůů^ƵŵŵĂƌǇ dǇŽŶĞŬͲϬϯǁĂƐĐůĞĂŶĞĚŽƵƚǁŝƚŚĐŽŝůƚƵďŝŶŐŝŶƉƌŝůϮϬϮϭ͘dŚĞǁĞůůŝƐĂŐĂƐůŝĨƚĞĚŐĂƐǁĞůůĨůŽǁŝŶŐƐƚĞĂĚǇĂƚ ϵϳϱŵĐĨĚĂŶĚŽŶKĐƚŽďĞƌϲƚŚƚŚĞǁĞůůƐƚĂƌƚĞĚŵĂŬŝŶŐĂůŽƚŽĨǁĂƚĞƌ;хϭ͕ϬϬϬďďůƐͬĚĂǇͿĂŶĚƚŚĞǁĞůůǁĂƐƐŚƵƚͲŝŶ͘ hƐŝŶŐǁŝƌĞůŝŶĞĂƚƵďŝŶŐůĞĂŬǁĂƐĨŽƵŶĚĂƚΕϰ͕ϴϴϯ͛ĂŶĚĂƐůŝĐŬůŝŶĞͬƌĞƚƌŝĞǀĂďůĞƉĂƚĐŚǁĂƐƐĞƚĂĐƌŽƐƐƚŚĞƉĞƌĨƐ͘dŚĞ ǁĞůůĐŽŶƚŝŶƵĞĚƚŽŵĂŬĞǁĂƚĞƌĂƚŚŝŐŚƌĂƚĞƐ͘dŚĞƉĂƚĐŚǁĂƐĂƚƚĞŵƉƚĞĚƚŽďĞƉƵůůĞĚǁŝƚŚƐůŝĐŬůŝŶĞ͕ĂŶĚƚŽŽůƐŐŽƚ ƐƚƵĐŬ͘^ĞǀĞƌĂůĂƚƚĞŵƉƚƐǁĞƌĞŵĂĚĞƚŽŐĞƚďĂĐŬƚŽƚŚĞƉĂƚĐŚĂŶĚƌĞƉĂŝƌƚŚĞǁĞůů͘ dŚĞƉƵƌƉŽƐĞŽĨƚŚŝƐƐƵŶĚƌǇŝƐƚŽƉƵůůƚƵďŝŶŐĂŶĚƉůƵŐďĂĐŬƚŚĞǁĞůůĂŶĚƉƌĞƉĂƌĞƚŚĞǁĞůůĨŽƌĂƌĞĚƌŝůů͘ ,ŝůĐŽƌƉƌĞƋƵĞƐƚƐĂǀĂƌŝĂŶĐĞƚŽϮϬϮϱ͘ϭϭϮ;ĐͿ;ϭͿ;ͿĨŽƌƉůĂĐŝŶŐĐĞŵĞŶƚϭϴϴĨƚĂďŽǀĞƚŚĞƚŽƉƉĞƌĨŽƌĂƚĞĚ ŝŶƚĞƌǀĂůŝŶƚŚĞǁĞůůďĞĐĂƵƐĞŽĨƚŚĞĞǆŝƐƚŝŶŐĐŽŵƉůĞƚŝŽŶĂŶĚŐƌĂǀĞůƉĂĐŬĚĞƐŝŐŶ͘ƉůƵŐǁŝůůďĞƐĞƚũƵƐƚĂďŽǀĞ ƐĂŶĚĨŝůůĂŶĚƐƚƵĐŬǁŝƌĞůŝŶĞƚŽŽůƐŝŶƚŚĞƚƵďŝŶŐǁŝƚŚϮϱĨƚŽĨĐĞŵĞŶƚŽŶŝƚ;ϭϰϯĨƚĂďŽǀĞƚŚĞƚŽƉƉĞƌĨǌŽŶĞͿ͘dƵďŝŶŐ ǁŝůůďĞĐƵƚĂŶĚƌĞŵŽǀĞĚĂďŽǀĞƚŚĞƚŽƉŽĨƚŚĞϱͲϭͬϮ͟ŐƌĂǀĞůƉĂĐŬĐŽŵƉůĞƚŝŽŶĂŶĚĂϵͲϱͬϴ͟/WǁŝƚŚϮϱĨƚŽĨ ĐĞŵĞŶƚǁŝůůďĞĂĚĚĞĚ͘dŚŝƐƉƌŽĐĞĚƵƌĞŝŶĐůƵĚĞƐƚŚĞƐƚĞƉƐƚŽƉůĂĐĞĐĞŵĞŶƚĂƐĚĞĞƉĂƐƌĞĂƐŽŶĂďůĞŝŶƚŚĞƚƵďŝŶŐ ĂŶĚĐĂƐŝŶŐƚŽŵĞĞƚϮϬϮϱ͘ϭϭϮ;ĐͿ;ϭͿǁŚĞƌĞƚŚĞŚǇĚƌŽĐĂƌďŽŶƐĂƌĞĐŽŶĨŝŶĞĚƚŽƚŚĞŝƌŝŶĚŝŐĞŶŽƵƐƐƚƌĂƚĂĂŶĚ ǁŝůůŶŽƚŵŝŐƌĂƚĞƚŽƐƵƌĨĂĐĞ͕ďƵƚƚŚĞǇǁŝůůŶŽƚďĞǁŝƚŚŝŶϭϬϬĨƚŽĨƚŚĞƚŽƉŽĨƉĞƌĨŽƌĂƚŝŽŶƐ͕ĂƐƌĞƋƵŝƌĞĚŝŶƚŚĞ ƌĞŐƵůĂƚŝŽŶƐ͘ ƵƌƌĞŶƚŽŶĚŝƚŝŽŶƐ Ͳ^>ƉĂƚĐŚƐĞƚĂƚϰ͕ϴϳϲ͛͘ƐƚŽƉĂŶĚƉĂĐŬŽĨĨǁĞƌĞƌĞŵŽǀĞĚĞĐϮϬϮϭ͘ Ͳ^>ƚŽŽůƐƚƌŝŶŐƐƚƵĐŬĂƚΕϰ͕ϯϴϬ͘;ĂŝůĞƌĂƐƐĞŵďůǇͿDĂƌĐŚϮϬϮϮ͘ Ͳ^>ƚĂŐŐĞĚϯͲϭͬϮ͟ǆϮͲϳͬϴ͟yKΛϰ͕ϯϭϬ͛ Ͳdͬ/ͬKͬKKсϮϳϬͬϰϰϯͬϳϴͬϬ Ͳ&ůƵŝĚ>ĞǀĞůĨƌŽŵ^>ͲΕϵϰϬ͛ ͲdŽƉŽĨWŽŽůƉĞƌKϲϴͲΕϯ͕ϱϴϭ͛цϮϱ͛;ŶŽůŽŐƐŝŶƚŚŝƐǁĞůůƚŽƚŚĞƚŽƉŽĨƚŚĞƉŽŽů͕ǁĂƐŝƐŽƉĂƚĐŚͲĞĚͿ WƌĞͲƌŝŐǁŽƌŬ͗ ϭ͘ZhͲ>ŝŶĞ Ϯ͘Z/,ĂŶĚƐĞƚϮͲϳͬϴ͟/WΕϰ͕ϯϮϬ͛;ďŽǀĞƚŽƉŽĨ^>&ŝƐŚΘŝŶƐŝĚĞƚŚĞϮͲϳͬϴ͟ƚƵďŝŶŐďĞĨŽƌĞŐƌĂǀĞůƉĂĐŬ ƐƚĂƌƚƐͿ dŚĞƉƵƌƉŽƐĞŽĨƚŚŝƐƐƵŶĚƌǇŝƐƚŽƉƵůůƚƵďŝŶŐĂŶĚ ƉůƵŐďĂĐŬƚŚĞǁĞůůĂŶĚƉƌĞƉĂƌĞƚŚĞǁĞůůĨŽƌĂƌĞĚƌŝůů͘ &RQILUPHG FHPHQW RXWVLGH FDVLQJ DW SOXJ VHWWLQJ GHSWK 6/% 86,7 /RJ 1RY EMP IW 9DULDQFH $SSURYHG WR SODFHG PHFKDQLFDO EULGJH SOXJ DERYH WRS SHUI EMP tĞůůtŽƌŬWƌŽŐŶŽƐŝƐ tĞůů͗ͲϬϯ ĂƚĞ͗ϯͬϴͬϮϬϮϮ Ă͘ůƚĞƌŶĂƚĞƉůĂŶŝĨĐĂŶŶŽƚŐĞƚƚŽĚĞƉƚŚŝƐƚŽƐĞƚĂϯͲϭͬϮ͟/WĂƚϰ͕ϯϬϬ͛;ĂďŽǀĞϳ͟ͲϮůŝŶĞƌ ƐĞƚƚŝŶŐƐƐůĞĞǀĞͿ ϯ͘ƵŵƉϮϱ͛ŽĨĐĞŵĞŶƚŽŶƉůƵŐ ϰ͘WƌĞƐƐƵƌĞƚĞƐƚƉůƵŐĂŶĚƚƵďŝŶŐƚŽϮ͕ϬϬϬƉƐŝ͕ĐŚĂƌƚĨŽƌϯϬŵŝŶ ϱ͘Z/,ĂŶĚĐƵƚƚƵďŝŶŐĂƚΕϰ͕ϮϮϱ͛ ϲ͘ZͲůŝŶĞ ZŝŐWƌŽĐĞĚƵƌĞ͗ ϳ͘D/ZhZŝŐϰϬϰ ϴ͘/ŶƐƚĂůůdt͕EƚƌĞĞ͕EhKW ϵ͘dĞƐƚKW ¾dĞƐƚKWƚŽϮϱϬͬϯϬϬϬƉƐŝĨŽƌϱͬϱŵŝŶ͘dĞƐƚĂŶŶƵůĂƌƚŽϮϱϬͬϮϱϬϬƉƐŝĨŽƌϱͬϱŵŝŶ͘ ;EŽƚŝĨǇK'ϰϴŚŽƵƌƐŝŶĂĚǀĂŶĐĞŽĨƚĞƐƚƚŽĂůůŽǁƚŚĞŵƚŽǁŝƚŶĞƐƐƚĞƐƚͿ͘ ¾/ĨƚŚĞKWŝƐƵƐĞĚƚŽƐŚƵƚŝŶŽŶƚŚĞǁĞůůŝŶĂǁĞůůĐŽŶƚƌŽůƐŝƚƵĂƚŝŽŶŽƌŝĨKWĞƋƵŝƉŵĞŶƚ ĐŽƵůĚďĞĐŽŵƉƌŽŵŝƐĞĚ͕>>KWĐŽŵƉŽŶĞŶƚƐƵƚŝůŝǌĞĚĨŽƌǁĞůůĐŽŶƚƌŽůŽƌĐŽŵƉƌŽŵŝƐĞĚ ŵƵƐƚďĞƚĞƐƚĞĚƉƌŝŽƌƚŽƚŚĞŶĞǆƚƚƌŝƉŝŶƚŽƚŚĞǁĞůůďŽƌĞ͘ ¾KWƐǁŝůůďĞĐůŽƐĞĚĂƐŶĞĞĚĞĚƚŽĐŝƌĐƵůĂƚĞƚŚĞǁĞůůĚƵƌŝŶŐƚŚŝƐǁŽƌŬŽǀĞƌ͘ ϭϬ͘WƵůůdt ϭϭ͘WƵůůŚĂŶŐĞƌĂŶĚƉƵůůƐĞĂůƐ ϭϮ͘ŝƌĐƵůĂƚĞǁĞůůǁŝƚŚ&/t;ϴ͘ϱƉƉŐͿ ϭϯ͘WKK,ǁŝƚŚΕϰ͕ϮϮϱ͛ŽĨϯͲϭͬϮ͟hƚƵďŝŶŐ;ƌĂĐŬďĂĐŬͿ ¾ĂŵĐŽϯͲϭͬϮ͟dDyyͲϱƐĂĨĞƚǇǀĂůǀĞΛϰϵϭ͛ ¾ϰĞĂĂŵĐŽ'ĂƐ>ŝĨƚDĂŶĚƌĞůƐ;ϭ͕ϯϯϱ͕Ϯ͕ϯϳϮ͕Ϯ͕ϰϬϳ͕Θϰ͕ϭϮϴ͛Ϳ ¾ϭĞĂďĂŬĞƌ^ůŝĚŝŶŐ^ůĞĞǀĞΛϰ͕Ϯϭϳ͛ ϳ͘WhϵͲϱͬϴ͟ĐĂƐŝŶŐƐĐƌĂƉĞƌǁŝƚŚďŝƚͬŵŝůůĂŶĚZ/,ĂŶĚƚĂŐƚŽƉŽĨĐƵƚƉŝƉĞĂƚΕϰ͕ϮϮϱ͛ ϴ͘WKK,Θ>ϯͲϭͬϮ͟ƚƵďŝŶŐ͕ƐĐƌĂƉĞƌĂŶĚďŝƚ ϵ͘ZhůŝŶĞ ϭϬ͘Z/,ĂŶĚƐĞƚϵͲϱͬϴ͟/WĂƚϰ͕Ϯϭϱ͛ĂŶĚĚƵŵƉϮϱĨƚŽĨĐĞŵĞŶƚŽŶƉůƵŐ ϭϭ͘ZƵŶ>ĨƌŽŵƉůƵŐƚŽƐƵƌĨĂĐĞ ϭϮ͘ZůŝŶĞ ϭϯ͘WƌĞƐƐƵƌĞƚĞƐƚĐĂƐŝŶŐƚŽϮϱϬϬƉƐŝĂŶĚĐŚĂƌƚĨŽƌϯϬŵŝŶ ϭϰ͘EKWƐ͕EhĚƌǇŚŽůĞƚƌĞĞΘƚĞƐƚ ϭϱ͘ZDK,ŝůĐŽƌƉZŝŐϰϬϰ 3URYLGH $2*&& RSSRUWXQLW\ WR ZLWQHVV FDVLQJ LQWHJULW\ WHVW EMP 7DJ WRS RI FHPHQW DQG UHSRUW GHSWK RI 72& 'HSWK FRUUHFWHG WR SOXJ VHWWLQJ UHFRUG EMP 0363 IRU WKH VLGHWUDFN LV SVL 6HH DWWDFKHG HPDLO &LUFXODWH HQWLUH ZHOOERUH YROXPH ZLWK SSJ IOXLG EHIRUH SXOOLQJ KDQJHUEMP WƌĞƐƐƵƌĞƚĞƐƚĐĂƐŝŶŐƚŽϮϱϬϬƉƐŝĂŶĚĐŚĂƌƚĨŽƌϯϬŵŝŶ tĞůůtŽƌŬWƌŽŐŶŽƐŝƐ tĞůů͗ͲϬϯ ĂƚĞ͗ϯͬϴͬϮϬϮϮ ƚƚĂĐŚŵĞŶƚƐ͗ ϭ͘tĞůů^ĐŚĞŵĂƚŝĐƵƌƌĞŶƚ Ϯ͘tĞůů^ĐŚĞŵĂƚŝĐWƌŽƉŽƐĞĚ ϯ͘tĞůůŚĞĂĚŝĂŐƌĂŵƵƌƌĞŶƚ ϰ͘tĞůůŚĞĂĚŝĂŐƌĂŵWƌŽƉŽƐĞĚ ϱ͘KWƌĂǁŝŶŐʹZŝŐϰϬϰ ϲ͘&ůƵŝĚͬ&ůŽǁŝĂŐƌĂŵƐʹZŝŐϰϬϰ ϳ͘ZtK^ƵŶĚƌǇŚĂŶŐĞ&Žƌŵ BBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBB hƉĚĂƚĞĚǇ͗,ϯͲϳͲϮϮ ^,Dd/ EŽƌƚŚŽŽŬ/ŶůĞƚhŶŝƚ tĞůů͗E/ͲϬϯ >ĂƐƚŽŵƉůĞƚĞĚ͗ϭϮͬϭϱͬϮϬϭϬ Wd͗ϭϵϴͲϬϱϵ W/͗ ϱϬͲϴϴϯͲϮϬϬϵϱͲϬϬͲϬϬ :t>Zzd/> EŽ ĞƉƚŚ ;DͿ ĞƉƚŚ ;dsͿ /K/ƚĞŵ ϰϮ͘ϲ͛ϰϮ͘ϲ͛ ϯ͘ϱϬϬ ϭϬ͘ϳϱ ϱͲϭͬϮ͟sĞƚĐŽ'ƌĂǇ,ĂŶŐĞƌǁͬϱ͘ϴϳϱ͟D>ŝĨƚdŚƌĞĂĚyKƚŽ ϯͲϭͬϮ͟h ϭ ϰϵϭ͛ ϰϵϭ͛ Ϯ͘ϴϭϮ ϱ͘ϭϳϲ ĂŵĐŽϯͲϭͬϮ͟dDyyͲϱ^^^sǁͬϮ͘ϴϭϯ͟yWƌŽĨŝůĞ;ŽƉĞŶϮϰϳϬ ƉƐŝ͕ĐůŽƐĞϭϰϵϯƉƐŝͿ Ϯ ϭ͕ϯϯϱ͛ ϭ͕ϯϮϳ͛ Ϯ͘ϵϮ ϱ͘ϯϵ ĂŵĐŽʹ<D''>Dηϭǁͬ'>s͕<Ͳϱϭ͟ ϯ Ϯ͕ϯϳϮ͛ Ϯ͕Ϯϴϵ͛ Ϯ͘ϵϮ ϱ͘ϯϵ ĂŵĐŽʹ<D''>DηϮǁͬ'>s͕<Ͳϱϭ͟ ϰ ϯ͕ϰϬϳ͛ ϯ͕Ϭϲϴ͛ Ϯ͘ϵϮ ϱ͘ϯϵ ĂŵĐŽʹ<D''>Dηϯǁͬ'>s͕<Ͳϱϭ͟ ϱ ϰ͕ϭϮϴ͛ ϯ͕ϱϲϰ͛ Ϯ͘ϵϮ ϱ͘ϯϵ ĂŵĐŽʹ<D''>Dηϰǁͬ'>sͲKƌŝĨŝĐĞ ϲ ϰ͕Ϯϭϳ͛ ϯ͕ϲϮϲ͛ Ϯ͘ϴϭϯ ϰ͘ϱ ĂŬĞƌ^ůŝĚŝŶŐ^ůĞĞǀĞϮ͘ϴϭϯ͟yƉƌŽĨŝůĞD;ůŽƐĞĚͿ ϳ ϰ͕ϯϬϰ͛ ϯ͕ϲϴϲ͛ ϯ͘ϬϬ ϰ͘Ϯϱ ĂŬĞƌϴϬͲϰϬ',ͲϮϮ>ŽĐĂƚŽƌΘƐĞĂůĂƐƐĞŵďůǇ ϰ͕ϯϭϵ ϯ͕ϲϵϲ͛ ϯ͘ϬϬ ϯ͘ϵϴ ĂŬĞƌϴϬͲϰϬ^ƉĂĐĞƌƚƵďĞĂŶĚƐĞĂůĂƐƐĞŵďůǇǁͬЪDƵůĞƐŚŽĞ /ƐŽůĂƚŝŽŶ^ƚƌŝŶŐ ϭ ϰ͕ϮϵϬ ϯ͕ϲϳϲ͛ ϲ͘ϯϳ ϳ͘ϱ͟ ϳ͟ͲϮůŝŶĞƌƐĞƚƚŝŶŐƐůĞĞǀĞ͕ϭϬ͛ƚŝĞďĂĐŬĞǆƚĞŶƐŝŽŶ ϰ͕ϯϬϱ͛ ϯ͕ϲϴϰ͛ ϯ͘ϬϬ ϱ͘Ϭ ĂŬĞƌϴϬͲϰϬ^ĞĂůŽƌĞϰ͟/ǆϭϬ͛ůŽŶŐϱ͟dƉŝŶǆƉŝŶ ϰ͕ϰϯϭ͛ ϯ͕ϳϳϯ͛ Ϯ͘ϯϳ ϰ͘ϱ ĂŬĞƌϰϱϬͲϮϯϳ,^WĂĐŬĞƌηϭǁͬϯϬŬƐŚĞĂƌƌĞůĞĂƐĞ ϰ͕ϲϲϬ͛ ϯ͕ϵϮϵ͛ Ϯ͘ϯϭϯ ϯ͘ϭϲ ĂŬĞƌϮͲϳͬϴ͟^>Dh^ůŝĚŝŶŐ^ůĞĞǀĞ;ůŽƐĞĚϭϮͬϰͬϮϭͿ ϰ͕ϴϳϯ͛ ϰ͕ϬϳϬ͛ Ϯ͘ϯϳ ϰ͘ϱ ĂŬĞƌ,^WĂĐŬĞƌηϭ͕ϮͲϳͬϴ͟hǁͬϯϬŬƐŚĞĂƌƌĞůĞĂƐĞ ϭ ϰ͕ϴϳϵ͛ ϰ͕ϬϳϮ͛ Εϭ͘Ϭ Ϯ͘ϰϰ ^>WĂƚĐŚǁŝƚŚŽƵƚƐƚŽƉŽƌƚŽƉĞůĞŵĞŶƚ͕ĂƐƐĞŵďůǇ͕ƚŽƉ͕ϰ͕ϴϳϵ͛ ϱ͕ϯϰϮ͛ ϰ͕ϯϳϴ͛ Ϯ͘ϯϰϳ ϰ͘ϱ ĂŬĞƌ,^WĂĐŬĞƌηϭ͕ϮͲϳͬϴ͟hǁͬϯϬŬƐŚĞĂƌƌĞůĞĂƐĞ ϱ͕ϱϵϭ͛ ϰ͕ϱϯϵ͛ Ϯ͘ϯϭϯ ϯ͘ϭϲ ĂŬĞƌϮͲϳͬϴ͟^>Dh^ůŝĚŝŶŐ^ůĞĞǀĞ;KƉĞŶϭϮͬϭϵͬϭϬͿ & ϱ͕ϴϯϴ͛ ϰ͕ϳϬϮ͛ Ϯ͘ϯϳ ϰ͘ϱ ĂŬĞƌ,^WĂĐŬĞƌηϭ͕ϮͲϳͬϴ͟hǁͬϯϬŬƐŚĞĂƌƌĞůĞĂƐĞ ' ϲ͕Ϭϴϴ͛ ϰ͕ϴϳϱ͛ Ϯ͘ϯϭϯ ϯ͘ϭϲ ĂŬĞƌϮͲϳͬϴ͟^>Dh^ůŝĚŝŶŐ^ůĞĞǀĞ;KƉĞŶϭϮͬϭϵͬϭϬͿ , ϲ͕ϯϯϳ͛ ϱ͕Ϭϰϴ͛ Ϯ͘ϯϳ ϰ͘ϱ ĂŬĞƌ,^WĂĐŬĞƌηϭ͕ϮͲϳͬϴ͟hǁͬϯϬŬƐŚĞĂƌƌĞůĞĂƐĞ : ϳ͕Ϯϳϳ͛ ϱ͕ϳϬϳ͛ Ϯ͘ϯϳ ϰ͘ϱ ĂŬĞƌ,^WĂĐŬĞƌηϭ͕ϮͲϳͬϴ͟hǁͬϯϬŬƐŚĞĂƌƌĞůĞĂƐĞ < ϳ͕ϯϱϴ͛ ϱ͕ϳϲϱ͛ Ϯ͘ϯϭϯ ϯ͘ϳ ĂŵĐŽ>ĂŶĚŝŶŐEŝƉƉůĞyWƌŽĨŝůĞ > ϳ͕ϯϵϬ ϱ͕ϳϴϳ͛ Ϯ͘ϯϳϱ ϯ͘ϱϭ ϮͲϳͬϴ͟t>' 'ƌĂǀĞůWĂĐŬ ϴ ϰ͕ϯϭϵ͛ ϯ͕ϲϵϲ͛ ϯ͘ϴϴϬ ĂŬĞƌϭϵϬͲϲϬWZǁͬϭϱ͛ƐĞĂůƚƌĂǀĞů ϰ͕ϯϯϲ͛ ϯ͕ϳϬϳ͛ ϰ͘ϴϳϮ 'ƌĂǀĞůWĂĐŬ ϰ͕ϯϰϭ͛ ϯ͕ϳϭϭ͛ ϱ͘ϬϬϬ ĂŬĞƌ<K/s͕ƵƐƚĞĚŽƉĞŶŽŶϭϭͬϭϵͬϬϯ ϰ͕ϯϰϵ͛ ϯ͕ϳϭϲ͛ ϲ͘ϬϬϬ ĂŬĞƌϵͲϱͬϴ͟ϱϯ͘ϱη^ͲϭZWĂĐŬĞƌƐƐǇǁͬ<K/sΛϰ͕ϯϴϭ͛ ϵ ϰ͕ϴϯϬ͛ ϰ͕Ϭϰϭ͛ ϲ͘ϬϬϬ ĂŬĞƌϵͲϱͬϴ͟ϱϯ͘ϱη^ͲϭZWĂĐŬĞƌ ϭϬ ϱ͕ϯϬϴ͛ ϰ͕ϯϱϱ͛ ϲ͘ϬϬϬ ĂŬĞƌϵͲϱͬϴ͟ϱϯ͘ϱη^ͲϭZWĂĐŬĞƌ ϭϭ ϱ͕ϳϳϳ͛ ϰ͕ϲϲϭ͛ ϲ͘ϬϬϬ ĂŬĞƌϵͲϱͬϴ͟ϱϯ͘ϱη^ͲϭZWĂĐŬĞƌ ϭϮ ϲ͕Ϯϳϳ͛ ϱ͕ϬϬϲ͛ ϲ͘ϬϬϬ ĂŬĞƌϵͲϱͬϴ͟ϱϯ͘ϱη^ͲϭZWĂĐŬĞƌ ϭϯ ϲ͕ϴϱϱ͛ ϱ͕ϰϭϬ͛ ϰ͘ϴϵϮ ZdĂŐŝŶďŽǆŽĨϱͲϭͬϮ͕͟ϭϳƉƉĨ͕>ͲϴϬƌĂĚĞŶůĂŶŬ^>,dǆW ϭϰ ϳ͕Ϭϴϵ͛ ϱ͕ϱϳϰ͛ ϰ͘ϴϵϮ ZdĂŐŝŶďŽǆŽĨϱͲϭͬϮ͕͟ϭϳƉƉĨ͕>ͲϴϬƌĂĚĞŶůĂŶŬ^>,dǆW ϭϱ ϳ͕Ϯϭϳ͛ ϱ͕ϲϲϱ͛ ϲ͘ϬϬϬ ĂŬĞƌϵͲϱͬϴ͟ϱϯ͘ϱη^ͲϭZWĂĐŬĞƌ ϭϲ ϳ͕ϳϲϳ͛ ϲ͕Ϭϱϯ͛ ϰ͘ϴϵϮ ZdĂŐŝŶďŽǆŽĨϱͲϭͬϮ͕͟ϭϳƉƉĨ͕>ͲϴϬƌĂĚĞŶůĂŶŬ^>,dǆW ϭϳ ϴ͕ϭϱϱ͛ ϲ͕ϯϮϳ͛ ϲ͘ϬϬϬ ĂŬĞƌϵͲϱͬϴ͟ϱϯ͘ϱη^ͲϭZWĂĐŬĞƌƐƵŵƉƉĂĐŬĞƌϮͬDKĞǆƚ͘ ϭϴ ϴ͕ϯϵϳ͛ ϲ͕ϱϬϬ͛ ϯ͘ϴϭϯ >ĂŶĚŝŶŐEŝƉƉůĞyWƌŽĨŝůĞ ϭϵ ϴ͕ϰϯϬ͛ ϲ͕ϱϮϰ͛ ϰ͘ϬϬϬ ϰͲϭͬϮ͟t>'Wd͗ ϭϭ͕ϭϴϭ͛ d͗ ϭϳ͕ϴϲϰ͛ $ ´ ϱ͟ /Ͳϭ /ͲϮ /Ͳϯ /Ͳϰ % & ' ( ) + , 7DJJHG VWLFN\ILOO# ¶RQ ϭϯͲϯͬϴ͟ ϵͲϱͬϴ͟ ĂůĐ͘dKΛ ϭϭ͕ϭϴϭ͛ ϭϬͬϭϱͬϬϯ h^/d ϵͬϭϭͬϬϯ ůŽŐŐĞĚ ŐŽŽĚĐŵƚ ƵƉƚŽ ϰ͕ϬϬϬ͛ * ´ ϳ͟ /Ͳϰ /Ͳϱ /Ͳϳ /Ͳϵ /Ͳϭϭ ĞůƵŐĂ ĞůƵŐĂ ĞůƵŐĂ ĞůƵŐĂ ĞůƵŐĂ, ĞůƵŐĂ/ ĞůƵŐĂ> ĞůƵŐĂE ĞůƵŐĂW ĞůƵŐĂY ĞůƵŐĂZ ϯͲϭͬϮ͟ - . / dKΛ ϭϰ͕ϯϬϬ dŽƉŽĨĨŝůůΛ ϭϲ͕ϴϵϬ WĂƚĐŚ ϭͬϮϱͬϮϭ & $ ^ĂŶĚ&ŝůů Λϰ͕ϯϮϯ͛ ϯͬϳͬϮϮ ^>dŽŽů ^ƚƌŝŶŐ ϱ͟ ϭͬϮ͟ ; ; ^/E'd/> ^ŝǌĞ tƚ 'ƌĂĚĞ ŽŶŶ / dŽƉ ƚŵ ϯϬ͟ ϱϰϳ tĞůĚĞĚ Ϯϵ͘ϬϬϬ ^ƵƌĨ ϰϲϭ͛ ϮϬ͟ ϭϯϯ <Ͳϱϱ ŶŝͲYƵŝƉ ϭϵ͘ϳϯϬ ^ƵƌĨ ϭ͕Ϯϭϰ͛ ϭϯͲϯͬϴ͟ ϳϮ >ͲϴϬ d ϭϮ͘ϰϭϱ ^ƵƌĨ ϰ͕ϰϬϬ͛ ϵͲϱͬϴ͟ ϱϯ͘ϱ WͲϭϭϬ d ϴ͘ϱϯϱ ^ƵƌĨ ϭϭ͕ϳϲϭ͛ ϳ͟ ϯϮ WͲϭϭϬ Ƶƚƚ ϲ͘Ϭϵϰ ϭϭ͕ϱϲϭ͛ ϭϱ͕ϯϬϭ͛ ϱ͟ ϭϴ WͲϭϭϬ sD&:> ϰ͘ϮϳϬ ϭϭ͕ϰϮϬ͛ ϭϳ͕ϭϱϵ͛ ϯͲϭͬϮ͟ ϭϯ WͲϭϭϬ W,Ͳϲ ϭϳ͕ϭϱϵ͛ ϭϳ͕ϴϲϰ͛ dh/E'd/> ϯͲϭͬϮ͟ ϵ͘ϯ >ͲϴϬ hDŽĚ Ϯ͘ϵϵϮ ^ƵƌĨ ϰ͕ϯϮϭ͛ ϮͲϳͬϴ͟ ϲ͘ϰ >ͲϴϬ ,ǇĚϱϭϭ Ϯ͘ϯϳϳ ϰ͕ϮϵϬ͛ ϳ͕ϯϵϭ͛ ϱͲϭͬϮ͟ 'ƌĂǀĞůWĂĐŬ ϭϳ >ͲϴϬ ^>,d ϰ͕ϯϭϵ͛ ϴ͕ϰϯϭ͛ hƉĚĂƚĞĚǇDϬϮͲϬϴͲϮϮ ^,Dd/ EŽƌƚŚŽŽŬ/ŶůĞƚhŶŝƚ tĞůů͗E/ͲϬϯ >ĂƐƚŽŵƉůĞƚĞĚ͗ϭϮͬϭϱͬϮϬϭϬ Wd͗ϭϵϴͲϬϱϵ W/͗ ϱϬͲϴϴϯͲϮϬϬϵϱͲϬϬͲϬϬ WZ&KZd/KEd/> ŽŶĞ dŽƉ ;DͿ ƚŵ ;DͿ dŽƉ ;dsͿ ƚŵ ;dsͿ &d ĂƚĞ ^ƚĂƚƵƐ /Ͳϭ ϰ͕ϰϲϯΖ ϰ͕ϱϰϳΖ ϯ͕ϳϵϱΖ ϯ͕ϴϱϯΖ ϴϰΖ ϭϬͬϮϭͬϮϬϬϯ ůŽƐĞĚ /ͲϮ ϰ͕ϱϳϬΖ ϰ͕ϲϲϯΖ ϯ͕ϴϲϵΖ ϯ͕ϵϯϭΖ ϵϯΖ ϭϬͬϮϭͬϮϬϬϯ ůŽƐĞĚ /Ͳϯ ϰ͕ϲϵϬΖ ϰ͕ϳϬϭΖ ϯ͕ϵϰϵΖ ϯ͕ϵϱϲΖ ϭϭΖ ϭϬͬϮϭͬϮϬϬϯ ůŽƐĞĚ /Ͳϰ ϰ͕ϳϰϴΖ ϰ͕ϴϮϬΖ ϯ͕ϵϴϳΖ ϰ͕ϬϯϱΖ ϳϮΖ ϭϬͬϮϭͬϮϬϬϯ /ƐŽůĂƚĞĚ /Ͳϰ ϰ͕ϴϴϴΖ ϰ͕ϵϭϴΖ ϰ͕ϬϴϬΖ ϰ͕ϬϵϵΖ ϯϬΖ ϭϬͬϮϭͬϮϬϬϯ /ƐŽůĂƚĞĚ /Ͳϱ ϰ͕ϵϮϳΖ ϰ͕ϵϱϱΖ ϰ͕ϭϬϱΖ ϰ͕ϭϮϰΖ ϮϴΖ ϭϬͬϮϭͬϮϬϬϯ /ƐŽůĂƚĞĚ /Ͳϳ ϱ͕ϬϲϬΖ ϱ͕ϬϵϬΖ ϰ͕ϭϵϮΖ ϰ͕ϮϭϮΖ ϯϬΖ ϭϬͬϮϭͬϮϬϬϯ /ƐŽůĂƚĞĚ /Ͳϴ ϱ͕ϮϬϬΖ ϱ͕ϮϭϰΖ ϰ͕ϮϴϰΖ ϰ͕ϮϵϰΖ ϭϰΖ ϭϬͬϮϭͬϮϬϬϯ /ƐŽůĂƚĞĚ /Ͳϵ ϱ͕ϮϲϴΖ ϱ͕ϮϵϭΖ ϰ͕ϯϮϵΖ ϰ͕ϯϰϰΖ ϮϯΖ ϭϬͬϮϭͬϮϬϬϯ /ƐŽůĂƚĞĚ /Ͳϭϭ ϱ͕ϯϱϱΖ ϱ͕ϰϬϮΖ ϰ͕ϯϴϲΖ ϰ͕ϰϭϳΖ ϰϳΖ ϭϬͬϮϭͬϮϬϬϯ KƉĞŶ ϱ͕ϱϴϴΖ ϱ͕ϱϵϱΖ ϰ͕ϱϯϴΖ ϰ͕ϱϰϮΖ ϳΖ ϭϬͬϮϭͬϮϬϬϯ KƉĞŶ ϱ͕ϲϴϴ͛ ϱ͕ϳϬϴ͛ ϰ͕ϲϬϮ͛ ϰ͕ϲϭϲ͛ ϮϬ͛ ϬϰͬϮϳͬϮϬϮϭ KƉĞŶ ϱ͕ϳϱϮΖ ϱ͕ϳϲϱΖ ϰ͕ϲϰϰΖ ϰ͕ϲϱϯΖ ϭϯΖ ϭϬͬϮϭͬϮϬϬϯ KƉĞŶ ϱ͕ϵϯϯΖ ϱ͕ϵϯϵΖ ϰ͕ϳϲϳΖ ϰ͕ϳϳϭΖ ϲΖ ϭϬͬϮϭͬϮϬϬϯ KƉĞŶ ϲ͕ϬϯϴΖ ϲ͕ϬϰϲΖ ϰ͕ϴϰϬΖ ϰ͕ϴϰϲΖ ϴΖ ϭϬͬϮϭͬϮϬϬϯ KƉĞŶ ϲ͕ϬϰϴΖ ϲ͕ϬϱϰΖ ϰ͕ϴϰϳΖ ϰ͕ϴϱϭΖ ϲΖ ϭϬͬϮϭͬϮϬϬϯ KƉĞŶ ϲ͕ϮϮϬΖ ϲ͕ϮϮϳΖ ϰ͕ϵϲϳΖ ϰ͕ϵϳϮΖ ϳΖ ϭϬͬϮϭͬϮϬϬϯ KƉĞŶ ϲ͕ϮϲϭΖ ϲ͕ϮϲϴΖ ϰ͕ϵϵϱΖ ϱ͕ϬϬϬΖ ϳΖ ϭϬͬϮϭͬϮϬϬϯ KƉĞŶ , ϲ͕ϲϮϴΖ ϲ͕ϲϰϴΖ ϱ͕ϮϱϭΖ ϱ͕ϮϲϱΖ ϮϬΖ ϭϬͬϮϭͬϮϬϬϯ KƉĞŶ , ϲ͕ϲϱϱΖ ϲ͕ϲϳϮΖ ϱ͕ϮϳϬΖ ϱ͕ϮϴϮΖ ϭϳΖ ϭϬͬϮϭͬϮϬϬϯ KƉĞŶ , ϲ͕ϲϵϲ͛ ϲ͕ϳϭϲ͛ ϱ͕Ϯϵϴ͛ ϱ͕ϯϭϮ͛ ϮϬ͛ ϬϰͬϮϲͬϮϬϮϭ KƉĞŶ / ϲ͕ϵϱϱΖ ϲ͕ϵϳϴΖ ϱ͕ϰϴϬΖ ϱ͕ϰϵϲΖ ϮϯΖ ϭϬͬϮϭͬϮϬϬϯ KƉĞŶ > ϳ͕ϭϴϬΖ ϳ͕ϭϵϳΖ ϱ͕ϲϯϴΖ ϱ͕ϲϱϬΖ ϭϳΖ ϭϬͬϮϭͬϮϬϬϯ KƉĞŶ E ϳ͕ϰϵϱΖ ϳ͕ϱϭϳΖ ϱ͕ϴϲϮΖ ϱ͕ϴϳϳΖ ϮϮΖ ϭϬͬϮϭͬϮϬϬϯ ŽǀĞƌĞĚ W ϳ͕ϳϬϬΖ ϳ͕ϳϮϳΖ ϲ͕ϬϬϲΖ ϲ͕ϬϮϱΖ ϮϳΖ ϭϬͬϮϭͬϮϬϬϯ ŽǀĞƌĞĚ Y ϳ͕ϵϱϱΖ ϳ͕ϵϲϴΖ ϲ͕ϭϴϲΖ ϵ͕ϭϵϱΖ ϭϯΖ ϭϬͬϮϭͬϮϬϬϯ ŽǀĞƌĞĚ Z ϴ͕ϭϬϱΖ ϴ͕ϭϰϱΖ ϲ͕ϮϵϭΖ ϲ͕ϯϭϵΖ ϰϬΖ ϭϬͬϮϭͬϮϬϬϯ ŽǀĞƌĞĚ K>KDW>d/KE>KtDEd EŽƚĞ͗KůĚƚƵďŝŶŐƚĂůůǇŚĂƐŶŽƚďĞĞŶůŽĐĂƚĞĚ͘DĞĂƐƵƌĞŵĞŶƚƐďĞůŽǁĂƌĞĂƉƉƌŽǆŝŵĂƚĞ͘ EŽ ĞƉƚŚ ;DͿ ĞƉƚŚ ;dsͿ /K/ƚĞŵ ϭϭ͕ϭϴϭ͛ ϴ͕ϱϬϲ͛ ĂůĐ͘dŽƉŽĨĞŵĞŶƚ ϭϭ͕ϯϱϰ͛ ϴ͕ϲϯϭ͛ tWĂĐŬĞƌǁͬƐĞĂůƐƚŽƉ ϭϭ͕ϯϲϮ͛ϴ͕ϲϯϲ͛ ĞǀĞůŐƵŝĚĞŽǀĞƌƚƵďŝŶŐƐƚƵďĨƌŽŵϭϭ͕ϯϲϮ͛ʹϭϭ͕ϯϲϴ͛ʹdƵďŝŶŐ ĐŚĞŵŝĐĂůůǇĐƵƚĂƚϭϭ͕ϯϲϮ͛ĂĨƚĞƌĨĂŝůĞĚƉƌĞƐƐƵƌĞƚĞƐƚ ϭϭ͕ϯϴϬ ϴ͕ϲϰϵ͛ ,WĂĐŬĞƌ ϭϭ͕ϯϵϴ͛ ϴ͕ϲϲϮ͛ &ŝƐŚʹϮϰ͛tŝƌĞůŝŶĞĨŝƐŚŽŶyEŝƉƉůĞ ϭϭ͕ϰϭϴ͛ ϴ͕ϲϳϲ͛ yEŝƉƉůĞ;Ϯ͘ϯϭϯ͟Ϳ ϭϯ͕ϳϬϬ͛ ϭϬ͕ϯϰϭ͛ dƵďŝŶŐƚĂŝů ϭϲ͕ϴϵϬ͛ ϭϮ͕ϱϳϭ͛ dŽƉŽĨ&ŝůů BBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBB hƉĚĂƚĞĚǇ͗, ϬϯͲϬϳͲϮϮ WZKWK^ EŽƌƚŚŽŽŬ /ŶůĞƚhŶŝƚ tĞůů͗E/ͲϬϯ >ĂƐƚŽŵƉůĞƚĞĚ͗ϭϮͬϭϱͬϮϬϭϬ Wd͗ϭϵϴͲϬϱϵ W/͗ϱϬͲϴϴϯͲϮϬϬϵϱͲϬϬͲϬϬ :t>Zzd/> EŽ ĞƉƚŚ ;DͿ ĞƉƚŚ ;dsͿ /K/ƚĞŵ ϭ Εϰ͕Ϯϭϱ͛Εϯ͕ϲϮϰ͛ϴ͘ϯϱϯ /WǁͬϮϱĨƚŽĨĐĞŵĞŶƚ Ϯ ϰ͕ϯϬϰ͛ϯ͕ϲϴϲ͛ϯ͘ϬϬ ϰ͘Ϯϱ ĂŬĞƌϴϬͲϰϬ',ͲϮϮ>ŽĐĂƚŽƌ ΘƐĞĂůĂƐƐĞŵďůǇ ϰ͕ϯϭϵ ϯ͕ϲϵϲ͛ϯ͘ϬϬ ϯ͘ϵϴ ĂŬĞƌϴϬͲϰϬ^ƉĂĐĞƌƚƵďĞĂŶĚƐĞĂůĂƐƐĞŵďůǇǁͬЪ DƵůĞ ƐŚŽĞ /ƐŽůĂƚŝŽŶ^ƚƌŝŶŐ ϭ ϰ͕ϮϵϬ ϯ͕ϲϳϲ͛ϲ͘ϯϳ ϳ͘ϱ͟ϳ͟ ͲϮůŝŶĞƌƐĞƚƚŝŶŐƐůĞĞǀĞ͕ϭϬ͛ ƚŝĞďĂĐŬĞǆƚĞŶƐŝŽŶ ϰ͕ϯϬϱ͛ϯ͕ϲϴϰ͛ϯ͘ϬϬ ϱ͘Ϭ ĂŬĞƌϴϬͲϰϬ^ĞĂůŽƌĞϰ͟/ǆϭϬ͛ůŽŶŐϱ͟dƉŝŶǆƉŝŶ ϰ͕ϰϯϭ͛ϯ͕ϳϳϯ͛Ϯ͘ϯϳ ϰ͘ϱ ĂŬĞƌϰϱϬͲϮϯϳ,^WĂĐŬĞƌηϭ ǁͬϯϬŬƐŚĞĂƌƌĞůĞĂƐĞ ϰ͕ϯϮϬ͛Ϯ͘ϰϰϭ ϮͲϳͬϴ͟ /WǁͬϮϱĨƚŽĨĐĞŵĞŶƚ ϰ͕ϲϲϬ͛ϯ͕ϵϮϵ͛Ϯ͘ϯϭϯ ϯ͘ϭϲ ĂŬĞƌϮͲϳͬϴ͟^>Dh^ůŝĚŝŶŐ^ůĞĞǀĞ ;ůŽƐĞĚ ϭϮͬϰͬϮϭͿ ϰ͕ϴϳϯ͛ϰ͕ϬϳϬ͛Ϯ͘ϯϳ ϰ͘ϱ ĂŬĞƌ,^WĂĐŬĞƌηϭ͕ϮͲϳͬϴ͟hǁͬϯϬŬƐŚĞĂƌƌĞůĞĂƐĞ ϭ ϰ͕ϴϳϵ͛ϰ͕ϬϳϮ͛Εϭ͘Ϭ Ϯ͘ϰϰ ^>WĂƚĐŚǁŝƚŚŽƵƚƐƚŽƉŽƌƚŽƉĞůĞŵĞŶƚ͕ĂƐƐĞŵďůǇ͕ƚŽƉ͕ϰ͕ϴϳϵ͛ ϱ͕ϯϰϮ͛ϰ͕ϯϳϴ͛Ϯ͘ϯϰϳ ϰ͘ϱ ĂŬĞƌ,^WĂĐŬĞƌηϭ͕ϮͲϳͬϴ͟hǁͬϯϬŬƐŚĞĂƌƌĞůĞĂƐĞ ϱ͕ϱϵϭ͛ϰ͕ϱϯϵ͛Ϯ͘ϯϭϯ ϯ͘ϭϲ ĂŬĞƌϮͲϳͬϴ͟^>Dh^ůŝĚŝŶŐ^ůĞĞǀĞ;KƉĞŶϭϮͬϭϵͬϭϬͿ &ϱ͕ϴϯϴ͛ϰ͕ϳϬϮ͛Ϯ͘ϯϳ ϰ͘ϱ ĂŬĞƌ,^WĂĐŬĞƌηϭ͕ϮͲϳͬϴ͟hǁͬϯϬŬƐŚĞĂƌƌĞůĞĂƐĞ 'ϲ͕Ϭϴϴ͛ϰ͕ϴϳϱ͛Ϯ͘ϯϭϯ ϯ͘ϭϲ ĂŬĞƌϮͲϳͬϴ͟^>Dh^ůŝĚŝŶŐ^ůĞĞǀĞ;KƉĞŶϭϮͬϭϵͬϭϬͿ ,ϲ͕ϯϯϳ͛ϱ͕Ϭϰϴ͛Ϯ͘ϯϳ ϰ͘ϱ ĂŬĞƌ,^WĂĐŬĞƌηϭ͕ϮͲϳͬϴ͟hǁͬϯϬŬƐŚĞĂƌƌĞůĞĂƐĞ :ϳ͕Ϯϳϳ͛ϱ͕ϳϬϳ͛Ϯ͘ϯϳ ϰ͘ϱ ĂŬĞƌ,^WĂĐŬĞƌηϭ͕ϮͲϳͬϴ͟hǁͬϯϬŬƐŚĞĂƌƌĞůĞĂƐĞ <ϳ͕ϯϱϴ͛ϱ͕ϳϲϱ͛Ϯ͘ϯϭϯ ϯ͘ϳ ĂŵĐŽ>ĂŶĚŝŶŐ EŝƉƉůĞyWƌŽĨŝůĞ >ϳ͕ϯϵϬ ϱ͕ϳϴϳ͛Ϯ͘ϯϳϱ ϯ͘ϱϭ ϮͲϳͬϴ͟t>' 'ƌĂǀĞůWĂĐŬ ϴ ϰ͕ϯϭϵ͛ϯ͕ϲϵϲ͛ϯ͘ϴϴϬ ĂŬĞƌϭϵϬͲϲϬWZǁͬϭϱ͛ƐĞĂůƚƌĂǀĞů ϰ͕ϯϯϲ͛ϯ͕ϳϬϳ͛ϰ͘ϴϳϮ 'ƌĂǀĞůWĂĐŬ ϰ͕ϯϰϭ͛ϯ͕ϳϭϭ͛ϱ͘ϬϬϬ ĂŬĞƌ<K/s͕ƵƐƚĞĚŽƉĞŶŽŶϭϭͬϭϵͬϬϯ ϰ͕ϯϰϵ͛ϯ͕ϳϭϲ͛ϲ͘ϬϬϬ ĂŬĞƌϵͲϱͬϴ͟ϱϯ͘ϱη^ͲϭZWĂĐŬĞƌ ƐƐǇǁͬ<K/sΛϰ͕ϯϴϭ͛ ϵ ϰ͕ϴϯϬ͛ϰ͕Ϭϰϭ͛ϲ͘ϬϬϬ ĂŬĞƌϵͲϱͬϴ͟ϱϯ͘ϱη^ͲϭZWĂĐŬĞƌ ϭϬ ϱ͕ϯϬϴ͛ϰ͕ϯϱϱ͛ϲ͘ϬϬϬ ĂŬĞƌ ϵͲϱͬϴ͟ϱϯ͘ϱη^ͲϭZWĂĐŬĞƌ ϭϭ ϱ͕ϳϳϳ͛ϰ͕ϲϲϭ͛ϲ͘ϬϬϬ ĂŬĞƌϵͲϱͬϴ͟ϱϯ͘ϱη^ͲϭZWĂĐŬĞƌ ϭϮ ϲ͕Ϯϳϳ͛ϱ͕ϬϬϲ͛ϲ͘ϬϬϬ ĂŬĞƌϵͲϱͬϴ͟ϱϯ͘ϱη^ͲϭZWĂĐŬĞƌ ϭϯ ϲ͕ϴϱϱ͛ϱ͕ϰϭϬ͛ϰ͘ϴϵϮ ZdĂŐŝŶďŽǆŽĨϱͲϭͬϮ͕͟ϭϳ ƉƉĨ͕>ͲϴϬ ƌĂĚĞŶůĂŶŬ^>,dǆW ϭϰ ϳ͕Ϭϴϵ͛ϱ͕ϱϳϰ͛ϰ͘ϴϵϮ ZdĂŐŝŶďŽǆŽĨϱͲϭͬϮ͕͟ϭϳƉƉĨ͕>ͲϴϬƌĂĚĞŶůĂŶŬ^>,dǆW ϭϱ ϳ͕Ϯϭϳ͛ϱ͕ϲϲϱ͛ϲ͘ϬϬϬ ĂŬĞƌϵͲϱͬϴ͟ϱϯ͘ϱη^ͲϭZWĂĐŬĞƌ ϭϲ ϳ͕ϳϲϳ͛ϲ͕Ϭϱϯ͛ϰ͘ϴϵϮ ZdĂŐŝŶďŽǆŽĨϱͲϭͬϮ͕͟ϭϳƉƉĨ͕>ͲϴϬƌĂĚĞŶůĂŶŬ^>,dǆW ϭϳ ϴ͕ϭϱϱ͛ϲ͕ϯϮϳ͛ϲ͘ϬϬϬ ĂŬĞƌϵͲϱͬϴ͟ϱϯ͘ϱη^ͲϭZWĂĐŬĞƌƐƵŵƉƉĂĐŬĞƌϮͬDKĞǆƚ͘ ϭϴ ϴ͕ϯϵϳ͛ϲ͕ϱϬϬ͛ϯ͘ϴϭϯ >ĂŶĚŝŶŐEŝƉƉůĞyWƌŽĨŝůĞ ϭϵ ϴ͕ϰϯϬ͛ϲ͕ϱϮϰ͛ϰ͘ϬϬϬ ϰͲϭͬϮ͟t>' ^/E'd/> ^ŝǌĞ tƚ 'ƌĂĚĞ ŽŶŶ 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$VVHW7HDP2SHUDWLRQV0DQDJHU 'DWH 3UHSDUHG )LUVW&DOO2SHUDWLRQV(QJLQHHU 'DWH From:Chad Helgeson To:McLellan, Bryan J (OGC) Cc:Donna Ambruz Subject:RE: [EXTERNAL] NCIU B-03 (PTD 198-059) Pressure Date:Friday, March 11, 2022 8:43:32 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. Bryan, The drilling program has the BHP at TD (5310' TVD) is 2289psi. MASP is 1758 psi assuming gas to surface. Chad -----Original Message----- From: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov> Sent: Thursday, March 10, 2022 3:33 PM To: Chad Helgeson <chelgeson@hilcorp.com> Subject: [EXTERNAL] NCIU B-03 (PTD 198-059) Pressure Chad, Could you let me know what the MPSP for the sidetrack on B-03 will be, assuming max BHP minus gas gradient? Thanks Bryan McLellan Senior Petroleum Engineer Alaska Oil & Gas Conservation Commission 333 W 7th Ave Anchorage, AK 99501 Bryan.mclellan@alaska.gov +1 (907) 250-9193 ________________________________ 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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^ůŝĐŬůŝŶĞĂƚƚĞŶĚĞĚŵŽƌŶŝŶŐŵĞĞƚŝŶŐ͕ƉĞƌŵŝƚĂŶĚ:^͕KƉĞŶƵƉŝŶůŝŶĞ^^sĂŶĚůŽĐŬŽƉĞŶĨŽƌǁŽƌŬ͘Z/,ͬǁϯΖϭ͘ϳϱΗ ƐƚĞŵͬǁϮ͘ϭϱΗ^ůŝĐŬůŝŶĞ^ĐƌĂƚĐŚĞƌƚŽϳϮϴϰΖ^>DǁͬƚĚŽǁŶƚŽϳϮϵϬΖ^>DƉƵůůŝŶŐŽƵƚĞǀĞƌǇĐŽƵƉůĞŚŝƚƐ͕ǁͬƚƚŽϳϮϵϭΖ^>D ;ϳϯϮϬΖZ<ͿŚĂŶŐƵƉ͕ůŽƐĞƐƉĂŶŐĂĐƚŝŽŶǁŽƌŬƚŽŽůƐĨƌĞĞǁŝƚŚũĂƌƐƵƉƚŽϳϮϳϭΖ^>DĐŽŵĞĨƌĞĞ͕ƉŝĐŬƵƉϭϬϬΖƚŚĞŶŐŽďĂĐŬ ĚŽǁŶƚĂŐĂƚϳϮϳϲΖ^>DǁŽƌŬƚŽŽůƐƚŽϳ͕ϮϳϴΖ^>D͘ǀĞƌǇƐƚŝĐŬǇƉŽƐƐŝďůĞďƵŝůĚƵƉ͕ĨĂůůŝŶ͕WKK,͘ŽŶƚĂĐƚŚĂĚ,ĞůŐĞƐŽŶ͕ ƚĂůŬĂďŽƵƚƚƵďŝŶŐƚĂŝůďƵŝůĚƵƉ͘Z/,ǁͬϮͲϭͬϮΗy>ŝŶĞZͬdŝŶĐŽŶƚƌŽůƉŽƐŝƚŝŽŶƉĂƐƚϰ͕ϳϬϬΖ^>DƉŝĐŬƵƉĂŶĚůŽĐĂƚĞyͲEŝƉƉůĞĂƚ ƐůŝĚŝŶŐƐůĞĞǀĞϰ͕ϲϯϭΖ^>D;ϰϲϲϬΖZ<ϮϵΖĐŽƌƌĞĐƚŝŽŶͿ͘^ŚŝĨƚƚŽŽůƐWKK,͘Z/,ǁͬϮͲϭͬϮΗ'^ǁͬϮͲϳͬϴΗͲϮ^ƚŽƉƚŽϰϵϱϬΖ ^ůŵǁŽƌŬƚŽŽůƐƚŽƐŚĞĂƌƉƌĞƐŚĞĂƌ'^͘Z/,ǁͬϮͲϭͬϮΗ'^ƚŽϰϵϱϬΖ^>DƉŝĐŬƵƉͲϮ^ƚŽƉĂŶĚƌĂŐƚŽϰϴϳϬΖ^>D;ϰϴϵϵΖ Z<ͿǁŽƌŬƚŽŽůƐƐĞƚƐŚĞĂƌĂŶĚWKK,͘Z/,ǁͬϮͲϭͬϮΗ'^ǁͬ^ƚŝŶŐĞƌǁͬƉĂƚĐŚǁͬƉĂĐŬŽĨĨƚŽϰϰϳϬΖ^>DƐĞƚĚŽǁŶĐĂŶΖƚ ƉĂƐƐWKK,͘Z/,ǁͬϮͲϳͬϴΗƌĂŝĚĞĚůŝŶĞƌƵƐŚǁͬϮ͘ϮϱΗǆϱΖĂŝůĞƌƚŽϰϰϳϬΖ^>DǁŽƌŬƚŽŽůƐƚŚƌƵƚŚĞŶĨŝŶĚƚŝŐŚƚƐƉŽƚ ĂƚϰϲϳϬΖ^>D͕ϰϳϰϬΖ^>DĂŶĚϰϴϱϬΖ^>DŵĂŬĞŵƵůƚŝƉůĞƉĂƐƐĞƐĐůĞĂŶŝŶŐƵƉƚŚĞŶWKK,͘Z/,ǁͬϮͲϳͬϴΗƌĂŝĚĞĚ>ŝŶĞ 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,ŝůĐŽƌƉƌĞƐĞƌǀŽŝƌƚĞĂŵǁŝƚŚŽƉĞƌĂƚŝŽŶƐĚĞƚĞƌŵŝŶĞĚƚŚĂƚŝƐŽůĂƚŝŶŐǁĂƚĞƌƉƌŽĚƵĐŝŶŐƐĂŶĚŝŶƚŚŝƐǁĞůůƚŽŵĂŬĞƚŚĞǁĞůů ŐĂƐƉƌŽĚƵĐƚŝǀĞǁĂƐƵŶĞĐŽŶŽŵŝĐĂŶĚƚŚĞƌĞĨŽƌĞƐŚŽƵůĚĐůŽƐĞŽƵƚƚŚŝƐƐƵŶĚƌǇĂŶĚƉůĂŶƚŽƉƌĞƉƚŚĞǁĞůůĨŽƌĂƌĞĚƌŝůů͘ BBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBB hƉĚĂƚĞĚǇ͗DϬϮͲϬϴͲϮϮ ^,Dd/ EŽƌƚŚŽŽŬ/ŶůĞƚhŶŝƚ tĞůů͗E/ͲϬϯ >ĂƐƚŽŵƉůĞƚĞĚ͗ϭϮͬϭϱͬϮϬϭϬ Wd͗ϭϵϴͲϬϱϵ W/͗ϱϬͲϴϴϯͲϮϬϬϵϱͲϬϬͲϬϬ :t>Zzd/> EŽĞƉƚŚ ;DͿ ĞƉƚŚ ;dsͿ/K/ƚĞŵ ϰϮ͘ϲ͛ϰϮ͘ϲ͛ϯ͘ϱϬϬϱͲϭͬϮ͟sĞƚĐŽ'ƌĂǇ,ĂŶŐĞƌǁͬ͘ϴϳϱ͟D>ŝĨƚdŚƌĞĂĚ ϭϰϵϭ͛ϰϵϭ͛Ϯ͘ϴϭϮĂŵĐŽϯͲϭͬϮ͟dDyyͲϱ^^^sǁͬϮ͘ϴϭϯ͟yWƌŽĨŝůĞ;ŽƉĞŶϮϰϳϬ ƉƐŝ͕ĐůŽƐĞϭϰϵϯƉƐŝͿ Ϯϭ͕ϯϯϱ͛ϭ͕ϯϮϳ͛ϭ͘ϬϬĂŵĐŽʹ<D''>Dηϭǁͬ'>s ϯϮ͕ϯϳϮ͛Ϯ͕Ϯϴϵ͛ϭ͘ϬϬĂŵĐŽʹ<D''>DηϮǁͬ'>s ϰϯ͕ϰϬϳ͛ϯ͕Ϭϲϴ͛ϭ͘ϬϬĂŵĐŽʹ<D''>Dηϯǁͬ'>s ϱϰ͕ϭϮϴ͛ϯ͕ϱϲϰ͛ϭ͘ϬϬĂŵĐŽʹ<D''>Dηϰǁͬ'>sͲKƌŝĨŝĐĞ ϲϰ͕Ϯϭϳ͛ϯ͕ϲϮϲ͛Ϯ͘ϴϭϮĂŬĞƌ^ůŝĚŝŶŐ^ůĞĞǀĞϮ͘ϴϭϯ͟yƉƌŽĨŝůĞ;ůŽƐĞĚͿ ϳ ϰ͕ϮϵϬ͛ϯ͕ϲϳϲ͛ϲ͘ϯϳϬϳ͘ϱϬϳ͟ͲϮ>ŝŶĞƌƐĞƚƚŝŶŐƐůĞĞǀĞ ϰ͕ϯϬϭ͛ϯ͕ϲϴϲ͛ϰ͘ϭϱϬƌŽƐƐŽǀĞƌ͕ϳ͟ϯϴƉƉĨ>dƉŝŶƵƉǆϱ͟dďŽǆĚŽǁŶ ϰ͕ϯϬϮ͛ϯ͕ϲϴϰ͛ϰ͘ϬϬϬĂŬĞƌϴϬͲϰϬ^ĞĂůŽƌĞϰ͟/ǆϭϬ͛ůŽŶŐϱ͟dƉŝŶǆƉŝŶ ϰ͕ϯϬϱ͛ϯ͕ϲϴϲ͛ĂŬĞƌϴϬͲϰϬ',ͲϮϮ>ŽĐĂƚŽƌͬ^ĞĂůƐƐĞŵďůǇ /ƐŽůĂƚŝŽŶ^ƚƌŝŶŐ ϰ͕ϰϯϭ͛ϯ͕ϳϳϯ͛Ϯ͘ϯϰϳĂŬĞƌ,^WĂĐŬĞƌηϭ͕ϮͲϳͬϴ͟hǁͬϯϬŬƐŚĞĂƌƌĞůĞĂƐĞ ϰ͕ϲϲϬ͛ϯ͕ϵϮϵ͛Ϯ͘ϯϭϯĂŬĞƌϮͲϳͬϴ͟^>Dh^ůŝĚŝŶŐ^ůĞĞǀĞ;ůŽƐĞĚϭϮͬϰͬϮϭͿ ϰ͕ϴϳϯ͛ϰ͕ϬϳϬ͛Ϯ͘ϯϰϳĂŬĞƌ,^WĂĐŬĞƌηϭ͕ϮͲϳͬϴ͟hǁͬϯϬŬƐŚĞĂƌƌĞůĞĂƐĞ ϭϰ͕ϴϳϲ͛ϰ͕ϬϳϮ͛Εϭ͘ϬϮ͘ϰϰ^ƚŽƉΛϰ͕ϴϵϵ͛Ϯϭ͘ϱ͛ŽĨƉĂƚĐŚ͕ĂƐƐĞŵďůǇϮϯ͛K>͘dŽƉ͕ϰ͕ϴϳϲ͛ ϱ͕ϯϰϮ͛ϰ͕ϯϳϴ͛Ϯ͘ϯϰϳĂŬĞƌ,^WĂĐŬĞƌηϭ͕ϮͲϳͬϴ͟hǁͬϯϬŬƐŚĞĂƌƌĞůĞĂƐĞ ϱ͕ϱϵϭ͛ϰ͕ϱϯϵ͛Ϯ͘ϯϭϯĂŬĞƌϮͲϳͬϴ͟^>Dh^ůŝĚŝŶŐ^ůĞĞǀĞ;KƉĞŶϭϮͬϭϵͬϭϬͿ &ϱ͕ϴϯϴ͛ϰ͕ϳϬϮ͛Ϯ͘ϯϰϳĂŬĞƌ,^WĂĐŬĞƌηϭ͕ϮͲϳͬϴ͟hǁͬϯϬŬƐŚĞĂƌƌĞůĞĂƐĞ 'ϲ͕Ϭϴϴ͛ϰ͕ϴϳϱ͛Ϯ͘ϯϭϯĂŬĞƌϮͲϳͬϴ͟^>Dh^ůŝĚŝŶŐ^ůĞĞǀĞ;KƉĞŶϭϮͬϭϵͬϭϬͿ ,ϲ͕ϯϯϳ͛ϱ͕Ϭϰϴ͛Ϯ͘ϯϰϳĂŬĞƌ,^WĂĐŬĞƌηϭ͕ϮͲϳͬϴ͟hǁͬϯϬŬƐŚĞĂƌƌĞůĞĂƐĞ :ϳ͕Ϯϳϳ͛ϱ͕ϳϬϳ͛Ϯ͘ϯϰϳĂŬĞƌ,^WĂĐŬĞƌηϭ͕ϮͲϳͬϴ͟hǁͬϯϬŬƐŚĞĂƌƌĞůĞĂƐĞ <ϳ͕ϯϱϴ͛ϱ͕ϳϲϱ͛Ϯ͘ϮϱϬĂŵĐŽ>ĂŶĚŝŶŐEŝƉƉůĞyWƌŽĨŝůĞ >ϳ͕ϯϵϬϱ͕ϳϴϳ͛Ϯ͘ϰϰϭϮͲϳͬϴ͟t>' 'ƌĂǀĞůWĂĐŬ ϴ ϰ͕ϯϭϵ͛ϯ͕ϲϵϲ͛ϯ͘ϴϴϬĂŬĞƌϭϵϬͲϲϬWZǁͬϭϱ͛ƐĞĂůƚƌĂǀĞů ϰ͕ϯϯϲ͛ϯ͕ϳϬϳ͛ϰ͘ϴϳϮ'ƌĂǀĞůWĂĐŬ ϰ͕ϯϰϭ͛ϯ͕ϳϭϭ͛ϱ͘ϬϬϬĂŬĞƌ<K/s͕ƵƐƚĞĚŽƉĞŶŽŶϭϭͬϭϵͬϬϯ ϰ͕ϯϰϵ͛ϯ͕ϳϭϲ͛ϲ͘ϬϬϬĂŬĞƌϵͲϱͬϴ͟ϱϯ͘ϱη^ͲϭZWĂĐŬĞƌƐƐǇǁͬ<K/sΛϰ͕ϯϴϭ͛ ϵϰ͕ϴϯϬ͛ϰ͕Ϭϰϭ͛ϲ͘ϬϬϬĂŬĞƌϵͲϱͬϴ͟ϱϯ͘ϱη^ͲϭZWĂĐŬĞƌ ϭϬϱ͕ϯϬϴ͛ϰ͕ϯϱϱ͛ϲ͘ϬϬϬĂŬĞƌϵͲϱͬϴ͟ϱϯ͘ϱη^ͲϭZWĂĐŬĞƌ ϭϭϱ͕ϳϳϳ͛ϰ͕ϲϲϭ͛ϲ͘ϬϬϬĂŬĞƌϵͲϱͬϴ͟ϱϯ͘ϱη^ͲϭZWĂĐŬĞƌ 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ŵŽĚĞƌĂƚĞƚŽĚŝĨĨŝĐƵůƚďƵŝůĚƵƉŽŶǁĂůůƐƚŽϱ͕ϯϭϮΖ^>D͕ĨĂůůƚŚƌŽƵŐŚƚŽϱ͕ϱϭϬ^>D͕ĐƵƚůŝŐŚƚďƵŝůĚƵƉƚŽϱ͕ϴϯϰΖ^>D͕ƚŚĞŶ ĐƵƚŵŽĚĞƌĂƚĞďƵŝůĚƵƉƚŽϲ͕ϱϰϬΖ^>D͘>ŝŐŚƚĐƵƚƚŝŶŐƚŽϳ͕ϮϮϯΖ^>D͘ƵƚŚĞĂǀǇďƵŝůĚƵƉƚŽϳ͕ϮϰϳΖ^>D͘WŝĐŬƵƉƚŽϰ͕ϰϬϬΖ ^>D͘ŵĂŬĞϱƉĂƐƐĞƐƚŽϳ͕ϬϬϬΖ^>D͕ĐůĞĂŶŝŶŐƵƉƚƵďŝŶŐĨŽƌƚŚĞƉĂƚĐŚ͘WKK,͘KK,ĐŚĂŶŐĞŽƵƚƚŽŽůƐƚƌŝŶŐƚŽϭͲϭͬϮΗZ^ ǁͬϭϱΖƐƚĞŵǁͬ<:͕K:͕^:͕^ƚĞŵ;K>ϮϵΖͿ͕ƐƚĂďďĂĐŬŽŶǁĞůů͕ƐĞĐƵƌĞǁĞůůĂŶĚůƵďĨŽƌƚŚĞŶŝŐŚƚ͕ůĂǇĚŽǁŶĐƌĞǁ͘ ϭϭͬϮϱͬϮϬϮϭͲdŚƵƌƐĚĂǇ ^ůŝĐŬůŝŶĞĂƚƚĞŶĚĞĚŵŽƌŶŝŶŐŵĞĞƚŝŶŐ͕ƉĞƌŵŝƚĂŶĚ:^͕KƉĞŶƵƉŝŶůŝŶĞ^^sĂŶĚůŽĐŬŽƉĞŶĨŽƌǁŽƌŬ͘Z/,ͬǁϯΖϭ͘ϳϱΗ ƐƚĞŵͬǁϮ͘ϭϱΗ^ůŝĐŬůŝŶĞ^ĐƌĂƚĐŚĞƌƚŽϳϮϴϰΖ^>DǁͬƚĚŽǁŶƚŽϳϮϵϬΖ^>DƉƵůůŝŶŐŽƵƚĞǀĞƌǇĐŽƵƉůĞŚŝƚƐ͕ǁͬƚƚŽϳϮϵϭΖ^>D ;ϳϯϮϬΖZ<ͿŚĂŶŐƵƉ͕ůŽƐĞƐƉĂŶŐĂĐƚŝŽŶǁŽƌŬƚŽŽůƐĨƌĞĞǁŝƚŚũĂƌƐƵƉƚŽϳϮϳϭΖ^>DĐŽŵĞĨƌĞĞ͕ƉŝĐŬƵƉϭϬϬΖƚŚĞŶŐŽďĂĐŬ ĚŽǁŶƚĂŐĂƚϳϮϳϲΖ^>DǁŽƌŬƚŽŽůƐƚŽϳ͕ϮϳϴΖ^>D͘ǀĞƌǇƐƚŝĐŬǇƉŽƐƐŝďůĞďƵŝůĚƵƉ͕ĨĂůůŝŶ͕WKK,͘ŽŶƚĂĐƚŚĂĚ,ĞůŐĞƐŽŶ͕ ƚĂůŬĂďŽƵƚƚƵďŝŶŐƚĂŝůďƵŝůĚƵƉ͘Z/,ǁͬϮͲϭͬϮΗy>ŝŶĞZͬdŝŶĐŽŶƚƌŽůƉŽƐŝƚŝŽŶƉĂƐƚϰ͕ϳϬϬΖ^>DƉŝĐŬƵƉĂŶĚůŽĐĂƚĞyͲEŝƉƉůĞĂƚ ƐůŝĚŝŶŐƐůĞĞǀĞϰ͕ϲϯϭΖ^>D;ϰϲϲϬΖZ<ϮϵΖĐŽƌƌĞĐƚŝŽŶͿ͘^ŚŝĨƚƚŽŽůƐWKK,͘Z/,ǁͬϮͲϭͬϮΗ'^ǁͬϮͲϳͬϴΗͲϮ^ƚŽƉƚŽϰϵϱϬΖ ^ůŵǁŽƌŬƚŽŽůƐƚŽƐŚĞĂƌƉƌĞƐŚĞĂƌ'^͘Z/,ǁͬϮͲϭͬϮΗ'^ƚŽϰϵϱϬΖ^>DƉŝĐŬƵƉͲϮ^ƚŽƉĂŶĚƌĂŐƚŽϰϴϳϬΖ^>D;ϰϴϵϵΖ Z<ͿǁŽƌŬƚŽŽůƐƐĞƚƐŚĞĂƌĂŶĚWKK,͘Z/,ǁͬϮͲϭͬϮΗ'^ǁͬ^ƚŝŶŐĞƌǁͬƉĂƚĐŚǁͬƉĂĐŬŽĨĨƚŽϰϰϳϬΖ^>DƐĞƚĚŽǁŶĐĂŶΖƚ ƉĂƐƐWKK,͘Z/,ǁͬϮͲϳͬϴΗƌĂŝĚĞĚůŝŶĞƌƵƐŚǁͬϮ͘ϮϱΗǆϱΖĂŝůĞƌƚŽϰϰϳϬΖ^>DǁŽƌŬƚŽŽůƐƚŚƌƵƚŚĞŶĨŝŶĚƚŝŐŚƚƐƉŽƚ ĂƚϰϲϳϬΖ^>D͕ϰϳϰϬΖ^>DĂŶĚϰϴϱϬΖ^>DŵĂŬĞŵƵůƚŝƉůĞƉĂƐƐĞƐĐůĞĂŶŝŶŐƵƉƚŚĞŶWKK,͘Z/,ǁͬϮͲϳͬϴΗƌĂŝĚĞĚ>ŝŶĞ ƌƵƐŚǁͬϮ͘ϮϵΗ'ĂƵŐĞƌŝŶŐƚŽϰϰϳϬΖ^>DĐůĞĂŶĂƌĞĂͲϰϲϳϬΖ^>DĐůĞĂŶĂƌĞĂϰϳϰϬΖ^>DĐůĞĂŶĂƌĞĂĂŶĚϰϴϱϬΖ^>DĐůĞĂŶ ĂƌĞĂͲZĞƚĂŐͲϮ^ƚŽƉƐƚŝůůĂƚϰϴϳϬΖ^>DWKK,͘Z/,ǁͬϮͲϭͬϮΗ<:ǁͬ'^ǁͬ>ŽǁĞƌƉĂƚĐŚĂƐƐĞŵďůǇ;'ĨŝƐŚŝŶŐŶĞĐŬ ƐƚŝŶŐĞƌƌĞĐĞƉƚĂĐůĞͬǁƐƉĂĐĞƌƉŝƉĞͬǁƉĂĐŬŽĨĨ;KĂůϭϰϬΗͿƚŽϰϱϰϱΖƐůŵƐĞƚĚŽǁŶǁͬƚĨĂůůƚŚƌƵƚŽϰϲϮϲΖ^>DǁͬƚĨĂůůƚŚƌƵƚŽ ϰϴϱϵΖ^>D;ϰϴϴϴΖZ<ͿƚŽƉŽĨƉĂƚĐŚͲďƚŵĂƚϰϴϳϬ^>DǁͬƚƐĞƚǁͬƚƐŚĞĂƌĂŶĚWKK,͘Z/,ǁͬ<:ǁͬϮͲϭͬϮΗ'^ǁͬhƉƉĞƌ ƉĂƚĐŚĂƐƐĞŵďůǇ;'ĨŝƐŚŝŶŐŶĞĐŬWĂĐŬŽĨĨͬǁƐƉĂĐĞƌƉŝƉĞǁŝƚŚ^ƚŝŶŐĞƌ;KĂůϭϯϲΗͿƚŽϰϴϰϴΖ^>DϰϴϳϳΖZ<ǁŽƌŬƚŽŽůƐ͕ƐĞƚ ǁŽƌŬƚŽŽůƐƐŚĞĂƌ͕WKK,͘Z/,ǁͬϮͲϭͬϮΗ'^ǁͬϮͲϳͬϴΗ^ƚŽƉƚŽϰϴϰϳΖ^>D;ϰϴϳϲΖZ<ͿƐĞƚŽŶƚŽƉŽĨWĂƚĐŚǁͬƚƐŚĞĂƌ͕ ƉŽŽŚ͘ Z/,ǁͬϯͲϭͬϮΗƌĂŝĚĞĚ>ŝŶĞƌƵƐŚĂŶĚZh^,^^^sĨŽƌϭϱŵŝŶƐ;ϰϵϭΖZ<ͿWKK,͘KK,͕ƌĞĂŬĨŽƌdŚĂŶŬƐŐŝǀŝŶŐĚŝŶŶĞƌ͘ >ĂǇĚŽǁŶůƵďƌŝĐĂƚŽƌƚŽƌĞƉĂĐŬͲĐĂƉƌŝƐĞƌƚŚĞŶŚĂǀĞƉƌŽĚƵĐƚŝŽŶƐƚĂƌƚƚĞƐƚŝŶŐǁĞůů͕ƐƚĂŶĚďǇĨŽƌƌĞƐƵůƚƐ >ĂǇĚŽǁŶĐƌĞǁĨŽƌƚŚĞŶŝŐŚƚ͕ǁĞůůŝŶƚĞƐƚ͘ ϭϭͬϮϲͬϮϬϮϭͲ&ƌŝĚĂǇ ZŝŐ ^ƚĂƌƚĂƚĞ ŶĚĂƚĞ ϭϭͬϭϴͬϮϭ ϭͬϮϱͬϮϮ ĂŝůǇKƉĞƌĂƚŝŽŶƐ͗ ,ŝůĐŽƌƉůĂƐŬĂ͕>> tĞůůKƉĞƌĂƚŝŽŶƐ^ƵŵŵĂƌǇ W/EƵŵďĞƌ tĞůůWĞƌŵŝƚEƵŵďĞƌtĞůůEĂŵĞ EŽŽŬ/ŶůĞƚhŶŝƚͲϬϯ ϱϬͲϴϴϯͲϮϬϬϵϱͲϬϬͲϬϬ ϭϵϴͲϬϱϵ ϬϭͬϮϱͬϮϬϮϮͲdƵĞƐĚĂǇ ,ŝůĐŽƌƉƌĞƐĞƌǀŽŝƌƚĞĂŵǁŝƚŚŽƉĞƌĂƚŝŽŶƐĚĞƚĞƌŵŝŶĞĚƚŚĂƚŝƐŽůĂƚŝŶŐǁĂƚĞƌƉƌŽĚƵĐŝŶŐƐĂŶĚŝŶƚŚŝƐǁĞůůƚŽŵĂŬĞƚŚĞǁĞůů ŐĂƐƉƌŽĚƵĐƚŝǀĞǁĂƐƵŶĞĐŽŶŽŵŝĐĂŶĚƚŚĞƌĞĨŽƌĞƐŚŽƵůĚĐůŽƐĞŽƵƚƚŚŝƐƐƵŶĚƌǇĂŶĚƉůĂŶƚŽƉƌĞƉƚŚĞǁĞůůĨŽƌĂƌĞĚƌŝůů͘ BBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBB hƉĚĂƚĞĚǇ͗DϬϮͲϬϴͲϮϮ ^,Dd/ EŽƌƚŚŽŽŬ/ŶůĞƚhŶŝƚ tĞůů͗E/ͲϬϯ >ĂƐƚŽŵƉůĞƚĞĚ͗ϭϮͬϭϱͬϮϬϭϬ Wd͗ϭϵϴͲϬϱϵ W/͗ϱϬͲϴϴϯͲϮϬϬϵϱͲϬϬͲϬϬ :t>Zzd/> EŽĞƉƚŚ ;DͿ ĞƉƚŚ ;dsͿ/K/ƚĞŵ ϰϮ͘ϲ͛ϰϮ͘ϲ͛ϯ͘ϱϬϬϱͲϭͬϮ͟sĞƚĐŽ'ƌĂǇ,ĂŶŐĞƌǁͬ͘ϴϳϱ͟D>ŝĨƚdŚƌĞĂĚ ϭϰϵϭ͛ϰϵϭ͛Ϯ͘ϴϭϮĂŵĐŽϯͲϭͬϮ͟dDyyͲϱ^^^sǁͬϮ͘ϴϭϯ͟yWƌŽĨŝůĞ;ŽƉĞŶϮϰϳϬ ƉƐŝ͕ĐůŽƐĞϭϰϵϯƉƐŝͿ Ϯϭ͕ϯϯϱ͛ϭ͕ϯϮϳ͛ϭ͘ϬϬĂŵĐŽʹ<D''>Dηϭǁͬ'>s ϯϮ͕ϯϳϮ͛Ϯ͕Ϯϴϵ͛ϭ͘ϬϬĂŵĐŽʹ<D''>DηϮǁͬ'>s ϰϯ͕ϰϬϳ͛ϯ͕Ϭϲϴ͛ϭ͘ϬϬĂŵĐŽʹ<D''>Dηϯǁͬ'>s ϱϰ͕ϭϮϴ͛ϯ͕ϱϲϰ͛ϭ͘ϬϬĂŵĐŽʹ<D''>Dηϰǁͬ'>sͲKƌŝĨŝĐĞ ϲϰ͕Ϯϭϳ͛ϯ͕ϲϮϲ͛Ϯ͘ϴϭϮĂŬĞƌ^ůŝĚŝŶŐ^ůĞĞǀĞϮ͘ϴϭϯ͟yƉƌŽĨŝůĞ;ůŽƐĞĚͿ ϳ ϰ͕ϮϵϬ͛ϯ͕ϲϳϲ͛ϲ͘ϯϳϬϳ͘ϱϬϳ͟ͲϮ>ŝŶĞƌƐĞƚƚŝŶŐƐůĞĞǀĞ ϰ͕ϯϬϭ͛ϯ͕ϲϴϲ͛ϰ͘ϭϱϬƌŽƐƐŽǀĞƌ͕ϳ͟ϯϴƉƉĨ>dƉŝŶƵƉǆϱ͟dďŽǆĚŽǁŶ ϰ͕ϯϬϮ͛ϯ͕ϲϴϰ͛ϰ͘ϬϬϬĂŬĞƌϴϬͲϰϬ^ĞĂůŽƌĞϰ͟/ǆϭϬ͛ůŽŶŐϱ͟dƉŝŶǆƉŝŶ ϰ͕ϯϬϱ͛ϯ͕ϲϴϲ͛ĂŬĞƌϴϬͲϰϬ',ͲϮϮ>ŽĐĂƚŽƌͬ^ĞĂůƐƐĞŵďůǇ /ƐŽůĂƚŝŽŶ^ƚƌŝŶŐ ϰ͕ϰϯϭ͛ϯ͕ϳϳϯ͛Ϯ͘ϯϰϳĂŬĞƌ,^WĂĐŬĞƌηϭ͕ϮͲϳͬϴ͟hǁͬϯϬŬƐŚĞĂƌƌĞůĞĂƐĞ ϰ͕ϲϲϬ͛ϯ͕ϵϮϵ͛Ϯ͘ϯϭϯĂŬĞƌϮͲϳͬϴ͟^>Dh^ůŝĚŝŶŐ^ůĞĞǀĞ;ůŽƐĞĚϭϮͬϰͬϮϭͿ ϰ͕ϴϳϯ͛ϰ͕ϬϳϬ͛Ϯ͘ϯϰϳĂŬĞƌ,^WĂĐŬĞƌηϭ͕ϮͲϳͬϴ͟hǁͬϯϬŬƐŚĞĂƌƌĞůĞĂƐĞ ϭϰ͕ϴϳϲ͛ϰ͕ϬϳϮ͛Εϭ͘ϬϮ͘ϰϰ^ƚŽƉΛϰ͕ϴϵϵ͛Ϯϭ͘ϱ͛ŽĨƉĂƚĐŚ͕ĂƐƐĞŵďůǇϮϯ͛K>͘dŽƉ͕ϰ͕ϴϳϲ͛ ϱ͕ϯϰϮ͛ϰ͕ϯϳϴ͛Ϯ͘ϯϰϳĂŬĞƌ,^WĂĐŬĞƌηϭ͕ϮͲϳͬϴ͟hǁͬϯϬŬƐŚĞĂƌƌĞůĞĂƐĞ ϱ͕ϱϵϭ͛ϰ͕ϱϯϵ͛Ϯ͘ϯϭϯĂŬĞƌϮͲϳͬϴ͟^>Dh^ůŝĚŝŶŐ^ůĞĞǀĞ;KƉĞŶϭϮͬϭϵͬϭϬͿ &ϱ͕ϴϯϴ͛ϰ͕ϳϬϮ͛Ϯ͘ϯϰϳĂŬĞƌ,^WĂĐŬĞƌηϭ͕ϮͲϳͬϴ͟hǁͬϯϬŬƐŚĞĂƌƌĞůĞĂƐĞ 'ϲ͕Ϭϴϴ͛ϰ͕ϴϳϱ͛Ϯ͘ϯϭϯĂŬĞƌϮͲϳͬϴ͟^>Dh^ůŝĚŝŶŐ^ůĞĞǀĞ;KƉĞŶϭϮͬϭϵͬϭϬͿ ,ϲ͕ϯϯϳ͛ϱ͕Ϭϰϴ͛Ϯ͘ϯϰϳĂŬĞƌ,^WĂĐŬĞƌηϭ͕ϮͲϳͬϴ͟hǁͬϯϬŬƐŚĞĂƌƌĞůĞĂƐĞ :ϳ͕Ϯϳϳ͛ϱ͕ϳϬϳ͛Ϯ͘ϯϰϳĂŬĞƌ,^WĂĐŬĞƌηϭ͕ϮͲϳͬϴ͟hǁͬϯϬŬƐŚĞĂƌƌĞůĞĂƐĞ <ϳ͕ϯϱϴ͛ϱ͕ϳϲϱ͛Ϯ͘ϮϱϬĂŵĐŽ>ĂŶĚŝŶŐEŝƉƉůĞyWƌŽĨŝůĞ >ϳ͕ϯϵϬϱ͕ϳϴϳ͛Ϯ͘ϰϰϭϮͲϳͬϴ͟t>' 'ƌĂǀĞůWĂĐŬ ϴ 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3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: 907 777-8337 E-mail: kaitlyn.barcelona@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal Received By: Date: DATE: 12/28/2021 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 DATA TRANSMITTAL NCI B-03 (PTD 198-059) Caliper 11/23/2021 Please include current contact information if different from above. 37' (6HW Received By: 12/29/2021 By Abby Bell at 8:57 am, Dec 29, 2021 1.Type of Request: Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Suspend Perforate Other Stimulate Pull Tubing Change Approved Program Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing Other: ___________________ 2.Operator Name:4.Current Well Class:5.Permit to Drill Number: Exploratory Development 3.Address:Stratigraphic Service 6. API Number: 7. If perforating:8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require a spacing exception?Yes No 9.Property Designation (Lease Number):10.Field/Pool(s): 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi):Plugs (MD):Junk (MD): 17,864'None Casing Collapse Structural Conductor 1,500 psi Surface 2,670 psi Intermediate 7,930 psi Liner 10,780 psi Liner 13,450 psi Liner Packers and SSSV Type:Packers and SSSV MD (ft) and TVD (ft): 12. Attachments: Proposal Summary Wellbore schematic 13.Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14.Estimated Date for 15. Well Status after proposed work: Commencing Operations:OIL WINJ WDSPL Suspended 16. Verbal Approval:Date:GAS WAG GSTOR SPLUG AOGCC Representative: GINJ Op Shutdown Abandoned Contact Name: Chad Helgeson Contact Email: Contact Phone: Authorized Title: Conditions of approval: Notify AOGCC so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other: Post Initial Injection MIT Req'd? Yes No Spacing Exception Required? Yes No Subsequent Form Required: APPROVED BY Approved by:COMMISSIONER THE AOGCC Date: Comm.Comm.Sr Pet Eng Sr Pet Geo Sr Res Eng 12,778'13,620 psi 13,356'7,440'5,823'904 psi 11,181' 17.I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name and Digital Signature with Date: AOGCC USE ONLY Dan Marlowe, Operations Manager chelgeson@hilcorp.com (907) 777-8405 Tubing Grade:Tubing MD (ft):Perforation Depth TVD (ft): Tubing Size: See schematic See schematic 4,463 - 8,145 3,795 - 6,319 11/25/2021 3-1/2" / 2-7/8" / 3-1/2" 13,356' PRESENT WELL CONDITION SUMMARY STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0017589 / ADL0037831 198-059 50-883-20095-00-00 N Cook Inlet Unit B-03 North Cook Inlet Unit / Tertiary System Gas Pool N/A 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Hilcorp Alaska, LLC Length Size 461' 461' 9.3# L-80 / 6.4# L-80 / 9.3# P-110 TVD Burst 4,321 / 7,391 / 13,700 11,640 psi MD 10,900 psi 3,060 psi 5,380 psi 1,208' 3,752' 8,918' 1,214' 4,400' 11,378'7" 9-5/8" 461' 30" 20" 13-3/8" 1,214' 11,761' 4,400' 15,301' Perforation Depth MD (ft): 11,761' 3,740' 3-1/2" 17,864'705' 5,739' 5" 17,159' Form 10-403 Revised 10/2021 Approved application is valid for 12 months from the date of approval. By Meredith Guhl at 7:35 am, Nov 12, 2021 321-582 Digitally signed by Dan Marlowe (1267) DN: cn=Dan Marlowe (1267), ou=Users Date: 2021.11.11 16:48:16 -09'00' Dan Marlowe (1267) DSR-11/12/21 SSSV must be replaced and tested within 5 days after return to production. DLB 11/12/2021 X BJM 11/15/21 10-404 dts 11/15/2021 11/15/21 Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2021.11.15 13:53:26 -09'00' RBDMS HEW 11/17/2021 Well Work Prognosis Well: B-03 Date: 11/11/2021 Well Name:NCIU B-03 API Number:50- 883-20095-00-00 Current Status:SI Gas Lifted Producer Leg:Leg #1 (NW) Estimated Start Date:11/25/2021 Rig:E-Line Reg. Approval Required? 403 Date Reg. Approval Received: Regulatory Contact:Juanita Lovett (8332)Permit to Drill Number:198-059 First Call Engineer:Chad Helgeson (907) 777-8405 (O) (907) 229-4824 (M) Second Call Engineer:Katherine O’Connor (907) 777-8376 (O) (214) 684-7400 (M) Current Bottom Hole Pressure:1155 psi @ 5018’ TVD 0.23 psi/ft Current Tubing Pressure:904 psi Maximum Expected BHP:1155 psi @ 5,018’ TVD 0.23 psi/ft Max Potential Surface Pressure (MPSP): 904 psi No new Perfs (SI for 32days) Brief Well Summary Well was cleaned out with coil tubing in April 2021. The well is a gas lifted gas well flowing steady at 975 mcfd and on October 6th the well starting making a lot of water (>1,000 bbls/day) and the well was shut-in. The objective of this project is to perform a spinner survey and find the watered out zone with the well flowing and isolate the zone making water. Pre Sundry Work: 1. MIRU Slickline, PT Lubricator 2. Pull SSSV 3. Make Gauge ring run to bottom (Coil tag depth was 7,440’) 4. RD SL 5. MIRU EL, PT Lubricator 6. Operations start flowing the well into test separator. Note: Obtain steady flowing conditions, (estimated water production of ~1,000 bbls of water/day) 7. Run Spinner survey following separate procedure from engineer. Note: If water rate is too high for spinner to get to bottom, cut back rate and start logging from the bottom of the well. 8. RDMO E-Line 9. If watered out zone can be isolated with a sliding sleeve or PX Plug, Mob slickline to well and shift sleeve closed (Beluga N, P, Q, R,& B sands and Sterling sands). 10. If watered out zone cannot be isolated with a sliding sleeve, set permanent plug over zone (Beluga C and below sands) Sundry Work Procedure: 1.MIRU E-Line, PT Lubricator 250L/1500H SSSV to be replaced and tested within 5 days or return to production. bjm Well Work Prognosis Well: B-03 Date: 11/11/2021 2.PU 2-7/8” CIBP, RIH and set plug in blank joint of tubing below gravel pack packer (the depth will be determined based on which zone watered out.) Note: Possible depths for plug: ~6,344’ or ~5,842’. 3.RD EL 4.Turn well over to operations to POP. Attachments 1. Well Schematic - Current 2. Well Schematic Proposed SSSV to be replaced and tested within 5 days or return to production. bjm _____________________________________________________________________________________ Updated By: JLL 05/24/21 SCHEMATIC North Cook Inlet Unit Well: NCI B-03 Last Completed: 12/15/2010 PTD: 198-059 API: 50-883-20095-00 JEWELRY DETAIL No Depth (MD) Depth (TVD)ID OD Item 42.6’ 42.6’ 3.500 5-1/2” Vetco Gray Hanger w/.875” MCA Lift Thread 1491’491’ 2.812 Camco 3-1/2” TMAXX-5E SSSV w/2.813” X Profile (open 2470 psi, close 1493 psi) 2 1,335’ 1,327’ 1.00 Camco – KBMG GLM #1 w/GLV 3 2,372’ 2,289’ 1.00 Camco – KBMG GLM #2w/GLV 4 3,407’ 3,068’ 1.00 Camco – KBMG GLM #3 w/GLV 5 4,128’ 3,564’ 1.00 Camco – KBMG GLM #4 w/GLV - Orifice 6 4,217’ 3,626’ 2.812 Baker Sliding Sleeve 2.813” X profile (Closed) 7 4,290’ 3,676’ 6.370 7.50 7” C-2 Liner setting sleeve 4,301’ 3,686’ 4.150 Crossover, 7” 38 ppf LTC pin up x 5” BTC box down 4,302’ 3,684’ 4.000 Baker 80-40 Seal Bore 4” ID x 10’ long 5” BTC pin x pin 4,305’ 3,686’ Baker 80-40 GBH-22 Locator/Seal Assembly Isolation String A 4,431’ 3,773’ 2.347 Baker HS Packer #1, 2-7/8” EUE w/30k shear release B 4,660’ 3,929’ 2.313 Baker 2-7/8” SLCMU Sliding Sleeve (Open 1/11/11) C 4,873’ 4,070’ 2.347 Baker HS Packer #1, 2-7/8” EUE w/30k shear release D 5,342’ 4,378’ 2.347 Baker HS Packer #1, 2-7/8” EUE w/30k shear release E 5,591’ 4,539’ 2.313 Baker 2-7/8” SLCMU Sliding Sleeve (Open 12/19/10) F 5,838’ 4,702’ 2.347 Baker HS Packer #1, 2-7/8” EUE w/30k shear release G 6,088’ 4,875’ 2.313 Baker 2-7/8” SLCMU Sliding Sleeve (Open 12/19/10) H 6,337’ 5,048’ 2.347 Baker HS Packer #1, 2-7/8” EUE w/30k shear release I 6,799’ 5,370’ 2.313 Baker 2-7/8” SLCMU Sliding Sleeve (Open 12/19/10) J 7,277’ 5,707’ 2.347 Baker HS Packer #1, 2-7/8” EUE w/30k shear release K 7,358’ 5,765’ 2.250 Camco Landing Nipple X Profile L 7,390 5,787’ 2.441 2-7/8” WLEG Gravel Pack 8 4,319’ 3,696’ 3.880 Baker 190-60 PBR w/ 15’ seal travel 4,336’ 3,707’ 4.872 Gravel Pack 4,341’ 3,711’ 5.000 Baker KOIV, Busted open on 11/19/03 4,349’ 3,716’ 6.000 Baker 9-5/8” 53.5# SC-1R Packer Assy w/ KOIV @4,381’ 9 4,830’ 4,041’ 6.000 Baker 9-5/8” 53.5# SC-1R Packer 10 5,308’ 4,355’ 6.000 Baker 9-5/8” 53.5# SC-1R Packer 11 5,777’ 4,661’ 6.000 Baker 9-5/8” 53.5# SC-1R Packer 12 6,277’ 5,006’ 6.000 Baker 9-5/8” 53.5# SC-1R Packer 13 6,855’ 5,410’ 4.892 RA Tag in box of 5-1/2”, 17 ppf, L-80 Braden Blank SLHT BxP 14 7,089’ 5,574’ 4.892 RA Tag in box of 5-1/2”, 17 ppf, L-80 Braden Blank SLHT BxP 15 7,217’ 5,665’ 6.000 Baker 9-5/8” 53.5# SC-1R Packer 16 7,767’ 6,053’ 4.892 RA Tag in box of 5-1/2”, 17 ppf, L-80 Braden Blank SLHT BxP 17 8,155’ 6,327’ 6.000 Baker 9-5/8” 53.5# SC-1R Packer sump packer 2/MO ext. 18 8,397’ 6,500’ 3.813 Landing Nipple X Profile 19 8,430’ 6,524’ 4.000 4-1/2” WLEG PBTD: 11,181’ TD: 17,864’ A 30” 5” CI-1 CI-2 CI-3 CI-4 B C D E F H I 3 4 5 6 7 8 9 10 11 12 13 Clean out to 7,440 RKB 04/24/ 21 13-3/8” 9-5/8” 1 2 Calc. TOC @ 11,181’ 10/15/03 14 15 16 18 USIT 9/11/03 logged good cmt up to 4,000’ G 20” 7” CI-4 CI-5 CI-7 CI-9 CI-11 Beluga B Beluga C Beluga D Beluga E Beluga H Beluga I Beluga L Beluga N Beluga P Beluga Q Beluga R 3-1/2” 17 19 J K L TOC @ 14,300 Top of fill @ 16,890 5” 1/2” X X CASING DETAIL Size Wt Grade Conn ID Top Btm 30” 547 Welded 29.000 Surf 461’ 20” 133 K-55 Dni-Quip 19.730 Surf 1,214’ 13-3/8” 72 L-80 BTC 12.415 Surf 4,400’ 9-5/8” 53.5 P-110 BTC 8.535 Surf 11,761’ 7” 32 P-110 Butt 6.094 11,561’ 15,301’ 5” 18 P-110 VAM FJL 4.270 11,420’ 17,159’ 3-1/2” 13 P-110 PH-6 17,159’ 17,864’ TUBING DETAIL 3-1/2” 9.3 L-80 EUE Mod 2.992 Surf 4,321’ 2-7/8” 6.4 L-80 Hyd 511 2.377 4,290’ 7,391’ 5-1/2” Gravel Pack 17 L-80 SLHT 4,319’ 8,431’ -00 DLB Updated By: JLL 05/24/21 SCHEMATIC North Cook Inlet Unit Well: NCI B-03 Last Completed: 12/15/2010 PTD: 198-059 API: 50-883-20095-00 PERFORATION DETAIL Zone Top (MD) Btm (MD) Top (TVD) Btm (TVD)FT Date Status CI-1 4,463' 4,547' 3,795' 3,853' 84' 10/21/2003 Open CI-2 4,570' 4,663' 3,869' 3,931' 93' 10/21/2003 Open CI-3 4,690' 4,701' 3,949' 3,956' 11' 10/21/2003 Open CI-4 4,748' 4,820' 3,987' 4,035' 72' 10/21/2003 Open CI-4 4,888' 4,918' 4,080' 4,099' 30' 10/21/2003 Open CI-5 4,927' 4,955' 4,105' 4,124' 28' 10/21/2003 Open CI-7 5,060' 5,090' 4,192' 4,212' 30' 10/21/2003 Open CI-8 5,200' 5,214' 4,284' 4,294' 14' 10/21/2003 Open CI-9 5,268' 5,291' 4,329' 4,344' 23' 10/21/2003 Open CI-11 5,355' 5,402' 4,386' 4,417' 47' 10/21/2003 Open B 5,588' 5,595' 4,538' 4,542' 7' 10/21/2003 Open B 5,688’ 5,708’ 4,602’ 4,616’ 20’ 04/27/2021 Open B 5,752' 5,765' 4,644' 4,653' 13' 10/21/2003 Open C 5,933' 5,939' 4,767' 4,771' 6' 10/21/2003 Open D 6,038' 6,046' 4,840' 4,846' 8' 10/21/2003 Open D 6,048' 6,054' 4,847' 4,851' 6' 10/21/2003 Open E 6,220' 6,227' 4,967' 4,972' 7' 10/21/2003 Open E 6,261' 6,268' 4,995' 5,000' 7' 10/21/2003 Open H 6,628' 6,648' 5,251' 5,265' 20' 10/21/2003 Open H 6,655' 6,672' 5,270' 5,282' 17' 10/21/2003 Open H 6,696’ 6,716’ 5,298’ 5,312’ 20’ 04/26/2021 Open I 6,955' 6,978' 5,480' 5,496' 23' 10/21/2003 Open L 7,180' 7,197' 5,638' 5,650' 17' 10/21/2003 Open N 7,495' 7,517' 5,862' 5,877' 22' 10/21/2003 Open P 7,700' 7,727' 6,006' 6,025' 27' 10/21/2003 Covered Q 7,955' 7,968' 6,186' 9,195' 13' 10/21/2003 Covered R 8,105' 8,145' 6,291' 6,319' 40' 10/21/2003 Covered OLD COMPLETION BELOW CEMENT Note: Old tubing tally has not been located. Measurements below are approximate. No Depth (MD) Depth (TVD)ID OD Item 11,181’ 8,506’ Calc. Top of Cement 11,354’ 8,631’ BWD Packer w/ seals top 11,362’8,636’ Bevel guide over tubing stub from 11,362’ – 11,368’ – Tubing chemically cut at 11,362’ after failed pressure test 11,380 8,649’ AHC Packer 11,398’ 8,662’ Fish – 24’ Wireline fish on X Nipple 11,418’ 8,676’ X Nipple (2.313”) 13,700’ 10,341’ Tubing tail 16,890’ 12,571’ Top of Fill -00 DLB _____________________________________________________________________________________ Updated By: CAH 11/11/21 PROPOSED North Cook Inlet Unit Well: NCI B-03 Last Completed: 12/15/2010 PTD: 198-059 API: 50-883-20095-00 JEWELRY DETAIL No Depth (MD) Depth (TVD)ID OD Item 42.6’ 42.6’ 3.500 5-1/2” Vetco Gray Hanger w/.875” MCA Lift Thread 1491’491’ 2.812 Camco 3-1/2” TMAXX-5E SSSV w/2.813” X Profile (open 2470 psi, close 1493 psi) 2 1,335’ 1,327’ 1.00 Camco – KBMG GLM #1 w/GLV 3 2,372’ 2,289’ 1.00 Camco – KBMG GLM #2w/GLV 4 3,407’ 3,068’ 1.00 Camco – KBMG GLM #3 w/GLV 5 4,128’ 3,564’ 1.00 Camco – KBMG GLM #4 w/GLV - Orifice 6 4,217’ 3,626’ 2.812 Baker Sliding Sleeve 2.813” X profile (Closed) 7 4,290’ 3,676’ 6.370 7.50 7” C-2 Liner setting sleeve 4,301’ 3,686’ 4.150 Crossover, 7” 38 ppf LTC pin up x 5” BTC box down 4,302’ 3,684’ 4.000 Baker 80-40 Seal Bore 4” ID x 10’ long 5” BTC pin x pin 4,305’ 3,686’ Baker 80-40 GBH-22 Locator/Seal Assembly Isolation String A 4,431’ 3,773’ 2.347 Baker HS Packer #1, 2-7/8” EUE w/30k shear release B 4,660’ 3,929’ 2.313 Baker 2-7/8” SLCMU Sliding Sleeve (Open 1/11/11) C 4,873’ 4,070’ 2.347 Baker HS Packer #1, 2-7/8” EUE w/30k shear release D 5,342’ 4,378’ 2.347 Baker HS Packer #1, 2-7/8” EUE w/30k shear release E 5,591’ 4,539’ 2.313 Baker 2-7/8” SLCMU Sliding Sleeve (Open 12/19/10) F 5,838’ 4,702’ 2.347 Baker HS Packer #1, 2-7/8” EUE w/30k shear release G 6,088’ 4,875’ 2.313 Baker 2-7/8” SLCMU Sliding Sleeve (Open 12/19/10) H 6,337’ 5,048’ 2.347 Baker HS Packer #1, 2-7/8” EUE w/30k shear release ±6,344 ±5,053’ 0 2.44 Plug location if necessary (6,344’ or 5,842’) I 6,799’ 5,370’ 2.313 Baker 2-7/8” SLCMU Sliding Sleeve (Open 12/19/10) J 7,277’ 5,707’ 2.347 Baker HS Packer #1, 2-7/8” EUE w/30k shear release K 7,358’ 5,765’ 2.250 Camco Landing Nipple X Profile L 7,390 5,787’ 2.441 2-7/8” WLEG Gravel Pack 8 4,319’ 3,696’ 3.880 Baker 190-60 PBR w/ 15’ seal travel 4,336’ 3,707’ 4.872 Gravel Pack 4,341’ 3,711’ 5.000 Baker KOIV, Busted open on 11/19/03 4,349’ 3,716’ 6.000 Baker 9-5/8” 53.5# SC-1R Packer Assy w/ KOIV @4,381’ 9 4,830’ 4,041’ 6.000 Baker 9-5/8” 53.5# SC-1R Packer 10 5,308’ 4,355’ 6.000 Baker 9-5/8” 53.5# SC-1R Packer 11 5,777’ 4,661’ 6.000 Baker 9-5/8” 53.5# SC-1R Packer 12 6,277’ 5,006’ 6.000 Baker 9-5/8” 53.5# SC-1R Packer 13 6,855’ 5,410’ 4.892 RA Tag in box of 5-1/2”, 17 ppf, L-80 Braden Blank SLHT BxP 14 7,089’ 5,574’ 4.892 RA Tag in box of 5-1/2”, 17 ppf, L-80 Braden Blank SLHT BxP 15 7,217’ 5,665’ 6.000 Baker 9-5/8” 53.5# SC-1R Packer 16 7,767’ 6,053’ 4.892 RA Tag in box of 5-1/2”, 17 ppf, L-80 Braden Blank SLHT BxP 17 8,155’ 6,327’ 6.000 Baker 9-5/8” 53.5# SC-1R Packer sump packer 2/MO ext. 18 8,397’ 6,500’ 3.813 Landing Nipple X Profile 19 8,430’ 6,524’ 4.000 4-1/2” WLEGPBTD: 11,181’ TD: 17,864’ A 30” 5” CI-1 CI-2 CI-3 CI-4 B C D E F H I 3 4 5 6 7 8 9 10 11 12 13 Clean out to 7,440 RKB 04/24/ 21 13-3/8” 9-5/8” 1 2 Plug Depths TBD Calc. TOC @ 11,181’ 10/15/03 14 15 16 18 USIT 9/11/03 logged good cmt up to 4,000’ G 20” 7” CI-4 CI-5 CI-7 CI-9 CI-11 Beluga B Beluga C Beluga D Beluga E Beluga H Beluga I Beluga L Beluga N Beluga P Beluga Q Beluga R 3-1/2” 17 19 J K L TOC @ 14,300 Top of fill @ 16,890 5” 1/2” X X CASING DETAIL Size Wt Grade Conn ID Top Btm 30” 547 Welded 29.000 Surf 461’ 20” 133 K-55 Dni-Quip 19.730 Surf 1,214’ 13-3/8” 72 L-80 BTC 12.415 Surf 4,400’ 9-5/8” 53.5 P-110 BTC 8.535 Surf 11,761’ 7” 32 P-110 Butt 6.094 11,561’ 15,301’ 5” 18 P-110 VAM FJL 4.270 11,420’ 17,159’ 3-1/2” 13 P-110 PH-6 17,159’ 17,864’ TUBING DETAIL 3-1/2” 9.3 L-80 EUE Mod 2.992 Surf 4,321’ 2-7/8” 6.4 L-80 Hyd 511 2.377 4,290’ 7,391’ 5-1/2” Gravel Pack 17 L-80 SLHT 4,319’ 8,431’ -00 DLB Updated By: CAH 11/11/21 PROPOSED North Cook Inlet Unit Well: NCI B-03 Last Completed: 12/15/2010 PTD: 198-059 API: 50-883-20095-00 PERFORATION DETAIL Zone Top (MD) Btm (MD) Top (TVD) Btm (TVD)FT Date Status CI-1 4,463' 4,547' 3,795' 3,853' 84' 10/21/2003 Open CI-2 4,570' 4,663' 3,869' 3,931' 93' 10/21/2003 Open CI-3 4,690' 4,701' 3,949' 3,956' 11' 10/21/2003 Open CI-4 4,748' 4,820' 3,987' 4,035' 72' 10/21/2003 Open CI-4 4,888' 4,918' 4,080' 4,099' 30' 10/21/2003 Open CI-5 4,927' 4,955' 4,105' 4,124' 28' 10/21/2003 Open CI-7 5,060' 5,090' 4,192' 4,212' 30' 10/21/2003 Open CI-8 5,200' 5,214' 4,284' 4,294' 14' 10/21/2003 Open CI-9 5,268' 5,291' 4,329' 4,344' 23' 10/21/2003 Open CI-11 5,355' 5,402' 4,386' 4,417' 47' 10/21/2003 Open B 5,588' 5,595' 4,538' 4,542' 7' 10/21/2003 Open B 5,688’ 5,708’ 4,602’ 4,616’ 20’ 04/27/2021 Open B 5,752' 5,765' 4,644' 4,653' 13' 10/21/2003 Open C 5,933' 5,939' 4,767' 4,771' 6' 10/21/2003 Open D 6,038' 6,046' 4,840' 4,846' 8' 10/21/2003 Open D 6,048' 6,054' 4,847' 4,851' 6' 10/21/2003 Open E 6,220' 6,227' 4,967' 4,972' 7' 10/21/2003 Open E 6,261' 6,268' 4,995' 5,000' 7' 10/21/2003 Open H 6,628' 6,648' 5,251' 5,265' 20' 10/21/2003 Open H 6,655' 6,672' 5,270' 5,282' 17' 10/21/2003 Open H 6,696’ 6,716’ 5,298’ 5,312’ 20’ 04/26/2021 Open I 6,955' 6,978' 5,480' 5,496' 23' 10/21/2003 Open L 7,180' 7,197' 5,638' 5,650' 17' 10/21/2003 Open N 7,495' 7,517' 5,862' 5,877' 22' 10/21/2003 Open P 7,700' 7,727' 6,006' 6,025' 27' 10/21/2003 Covered Q 7,955' 7,968' 6,186' 9,195' 13' 10/21/2003 Covered R 8,105' 8,145' 6,291' 6,319' 40' 10/21/2003 Covered OLD COMPLETION BELOW CEMENT Note: Old tubing tally has not been located. Measurements below are approximate. No Depth (MD) Depth (TVD)ID OD Item 11,181’ 8,506’ Calc. Top of Cement 11,354’ 8,631’ BWD Packer w/ seals top 11,362’8,636’ Bevel guide over tubing stub from 11,362’ – 11,368’ – Tubing chemically cut at 11,362’ after failed pressure test 11,380 8,649’ AHC Packer 11,398’ 8,662’ Fish – 24’ Wireline fish on X Nipple 11,418’ 8,676’ X Nipple (2.313”) 13,700’ 10,341’ Tubing tail 16,890’ 12,571’ Top of Fill -00 DLB Samuel Gebert Hilcorp Alaska, LLC GeoTechnician 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: 907 777-8337 Fax: 907 777-8510 E-mail: sam.gebert@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal or FAX to 907 777.8510 Received By: Date: DATE: 05/10/2021 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 DATA TRANSMITTAL NCI B-03 (PTD 198-059) PERFORATING RECORD 04/26/2021 Please include current contact information if different from above. PTD: 1980590 E-Set: 35113 05/11/2021 1.Type of Request: Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Suspend Perforate Other Stimulate Pull Tubing Change Approved Program Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing 2.Operator Name:4.Current Well Class:5.Permit to Drill Number: Exploratory Development 3.Address: 3800 Centerpoint Drive, Suite 1400 Stratigraphic Service 6.API Number: 7. If perforating:8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require a spacing exception?Yes No 9.Property Designation (Lease Number):10.Field/Pool(s): North Cook Inlet Unit / Tertiary Gas Pool 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi):Plugs (MD):Junk (MD): 17,864'None Casing Collapse Structural Conductor 1,500 psi Surface 2,670 psi Intermediate 7,930 psi Liner 10,780 psi Liner 13,450 psi Liner Packers and SSSV Type:Packers and SSSV MD (ft) and TVD (ft): 12. Attachments: Proposal Summary Wellbore schematic 13.Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14.Estimated Date for 15. Well Status after proposed work: Commencing Operations:OIL WINJ WDSPL Suspended 16. Verbal Approval:Date:GAS WAG GSTOR SPLUG Commission Representative: GINJ Op Shutdown Abandoned Contact Name: Contact Email:Katherine.oconnor@hilcorp.com Contact Phone: (907) 777-8376 Date: Conditions of approval: Notify Commission so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other: Post Initial Injection MIT Req'd? Yes No Spacing Exception Required? Yes No Subsequent Form Required: APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng Other: CTCO CO 68A 3,740' 7" 15,301' 11,378' 11,640 psi 13,356'11,181'8,506'613 psi 705'3-1/2" 12,778'5" 17,864'13,356' 17,150' 461'30" Authorized Title: 17.I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. 4/15/2021 3-1/2" / 2-7/8" / 3-1/2" Daniel E. Marlowe See schematic Perforation Depth MD (ft): 11,761' 4,463 - 8,145 5,739' See schematic Tubing Grade:Tubing MD (ft): 3,795 - 6,319 Perforation Depth TVD (ft): 9.3# L-80 / 6.4# L-80 / 9.3# P-110 20" 13-3/8" 1,214' 9-5/8"11,761' 4,400' Tubing Size: MD 3,060 psi 5,380 psi Size 1,208' 3,752' 8,918' 1,214' 4,400' COMMISSION USE ONLY Authorized Name: TVD Burst 4,321 / 7,391 / 13,700 13,620 psi Authorized Signature: Operations Manager Katherine O'Connor PRESENT WELL CONDITION SUMMARY Length 198-059 50-883-20095-00-00Anchorage, AK 99503 Hilcorp Alaska, LLC N Cook Inlet Unit B-03 10,900 psi 11,181' 461' STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0017589 / ADL0037831 461' Form 10-403 Revised 3/2020 Approved application is valid for 12 months from the date of approval. By Samantha Carlisle at 12:17 pm, Mar 15, 2021 321-129 Digitally signed by Dan Marlowe (1267) DN: cn=Dan Marlowe (1267), ou=Users Date: 2021.03.15 09:32:21 -08'00' Dan Marlowe (1267) CTCO 10-404 SFD 3/15/2021 X Perforate BJM 3/26/21 DSR-3/15/21dts 3/26/2021 3/26/21Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2021.03.26 14:56:22 -08'00' RBDMS HEW 3/26/2021 Well Work Prognosis Well Name:NCIU B-03 API Number:50- 883-20095-00 Current Status:Gas Lifted Producer Leg:Leg #1 (NW) Estimated Start Date:4/15/2021 Rig:Coil Tubing Reg. Approval Required? 403 Date Reg. Approval Received: Regulatory Contact:Juanita Lovett (8332)Permit to Drill Number:198-059 First Call Engineer:Katherine O’Connor (907) 777-8376 (O) (214) 684-7400 (M) Second Call Engineer:Karson Kozub (907) 777-8434 (O) (907) 570-1801 (M) Current Bottom Hole Pressure:680 psi @ 5018’ TVD 0.136 psi/ft Maximum Expected BHP:1085 psi @ 4720’ TVD 0.23 psi/ft Max Potential Surface Pressure (MPSP): 613 psi Using 0.1 psi/ft gradient 20 AAC 25.280(b)(4) Brief Well Summary During recent attempts to drift the well for a production log, solids were encountered and bridged off in the inner 2-7/8” isolation string. Several days have been spent trying to clear the obstruction with slickline without success and the well lost production due to the fill in the well. The objective of this project is to clear out the tubing and regain access to the well and add perforations into the Beluga H and B sands. Safety Concerns: x Discuss nitrogen asphyxiation concerns and identify any areas where nitrogen could collect and people could enter. x Consider tank placement based on wind direction and current weather forecast (venting methane and Nitrogen during this job) x Ensure all crews are aware of stop job authority (Review Standard Well Procedure – Nitrogen Operations) Procedure: 1.MIRU Coil Tubing. 2.NU BOP and test to 250psi low / 2,500psi High. (Note: Notify AOGCC 48 hours in advance of test) 3.RIH cleaning out fill using 6% KCl and N2 and foam as needed. a. Have milling tool string on hand for contingent milling as needed. b. Circulate well clean with 6% KCl using N2 and foam assist if needed. 4.RDMO 5.MIRU EL, PT lubricator to 1500 psi Hi 250 psi Low 6.Perforate per program 7.RD EL 8.Turn well over to operations to POP. Attachments 1. Well Schematic - Current 2. Well Schematic Proposed Well Work Prognosis 3. Wellhead Diagram - Current 4. Coil Tubing BOP Drawing 5. Flow Diagrams 6. Standard Well Procedure – Nitrogen Operations 7. Sundry Revision Change Form _____________________________________________________________________________________ Updated By: JLL 02/09/21 SCHEMATIC North Cook Inlet Unit Well: NCI B-03 Last Completed: 12/15/2010 PTD: 198-059 API: 50-883-20095-00 JEWELRY DETAIL No Depth (MD) Depth (TVD)ID OD Item 42.6’ 42.6’ 3.500 5-1/2” Vetco Gray Hanger w/.875” MCA Lift Thread 1491’491’ 2.812 Camco 3-1/2” TMAXX-5E SSSV w/2.813” X Profile (open 2470 psi, close 1493 psi) 2 1,335’ 1,327’ 1.00 Camco – KBMG GLM #1 w/GLV 3 2,372’ 2,289’ 1.00 Camco – KBMG GLM #2w/GLV 4 3,407’ 3,068’ 1.00 Camco – KBMG GLM #3 w/GLV 5 4,128’ 3,564’ 1.00 Camco – KBMG GLM #4 w/GLV - Orifice 6 4,217’ 3,626’ 2.812 Baker Sliding Sleeve 2.813” X profile (Closed) 7 4,290’ 3,676’ 6.370 7.50 7” C-2 Liner setting sleeve 4,301’ 3,686’ 4.150 Crossover, 7” 38 ppf LTC pin up x 5” BTC box down 4,302’ 3,684’ 4.000 Baker 80-40 Seal Bore 4” ID x 10’ long 5” BTC pin x pin 4,305’ 3,686’ Baker 80-40 GBH-22 Locator/Seal Assembly Isolation String A 4,431’ 3,773’ 2.347 Baker HS Packer #1, 2-7/8” EUE w/30k shear release B 4,660’ 3,929’ 2.313 Baker 2-7/8” SLCMU Sliding Sleeve (Open 1/11/11) C 4,873’ 4,070’ 2.347 Baker HS Packer #1, 2-7/8” EUE w/30k shear release D 5,342’ 4,378’ 2.347 Baker HS Packer #1, 2-7/8” EUE w/30k shear release E 5,591’ 4,539’ 2.313 Baker 2-7/8” SLCMU Sliding Sleeve (Open 12/19/10) F 5,838’ 4,702’ 2.347 Baker HS Packer #1, 2-7/8” EUE w/30k shear release G 6,088’ 4,875’ 2.313 Baker 2-7/8” SLCMU Sliding Sleeve (Open 12/19/10) H 6,337’ 5,048’ 2.347 Baker HS Packer #1, 2-7/8” EUE w/30k shear release I 6,799’ 5,370’ 2.313 Baker 2-7/8” SLCMU Sliding Sleeve (Open 12/19/10) J 7,277’ 5,707’ 2.347 Baker HS Packer #1, 2-7/8” EUE w/30k shear release K 7,358’ 5,765’ 2.250 Camco Landing Nipple X Profile L 7,390 5,787’ 2.441 2-7/8” WLEG Gravel Pack 8 4,319’ 3,696’ 3.880 Baker 190-60 PBR w/ 15’ seal travel 4,336’ 3,707’ 4.872 Gravel Pack 4,341’ 3,711’ 5.000 Baker KOIV, Busted open on 11/19/03 4,349’ 3,716’ 6.000 Baker 9-5/8” 53.5# SC-1R Packer Assy w/ KOIV @4,381’ 9 4,830’ 4,041’ 6.000 Baker 9-5/8” 53.5# SC-1R Packer 10 5,308’ 4,355’ 6.000 Baker 9-5/8” 53.5# SC-1R Packer 11 5,777’ 4,661’ 6.000 Baker 9-5/8” 53.5# SC-1R Packer 12 6,277’ 5,006’ 6.000 Baker 9-5/8” 53.5# SC-1R Packer 13 6,855’ 5,410’ 4.892 RA Tag in box of 5-1/2”, 17 ppf, L-80 Braden Blank SLHT BxP 14 7,089’ 5,574’ 4.892 RA Tag in box of 5-1/2”, 17 ppf, L-80 Braden Blank SLHT BxP 15 7,217’ 5,665’ 6.000 Baker 9-5/8” 53.5# SC-1R Packer 16 7,767’ 6,053’ 4.892 RA Tag in box of 5-1/2”, 17 ppf, L-80 Braden Blank SLHT BxP 17 8,155’ 6,327’ 6.000 Baker 9-5/8” 53.5# SC-1R Packer sump packer 2/MO ext. 18 8,397’ 6,500’ 3.813 Landing Nipple X Profile 19 8,430’ 6,524’ 4.000 4-1/2” WLEG PBTD: 11,181’ TD: 17,864’ A 30” 5” CI-1 CI-2 CI-3 CI-4 B C D E F H I 3 4 5 6 7 8 9 10 11 12 13 13-3/8” 9-5/8” 1 2 Calc. TOC @ 11,181’ 10/15/03 14 15 16 18 USIT 9/11/03 logged good cmt up to 4,000’ G 20” 7” CI-4 CI-5 CI-7 CI-9 CI-11 Beluga B Beluga C Beluga D Beluga E Beluga H Beluga I Beluga L Beluga N Beluga P Beluga Q Beluga R 3-1/2” 17 19 J K L TOC @ 14,300 Topof fill @ 16,890 5” 1/2” X X CASING DETAIL Size Wt Grade Conn ID Top Btm 30” 547 Welded 29.000 Surf 461’ 20” 133 K-55 Dni-Quip 19.730 Surf 1,214’ 13-3/8” 72 L-80 BTC 12.415 Surf 4,400’ 9-5/8” 53.5 P-110 BTC 8.535 Surf 11,761’ 7” 32 P-110 Butt 6.094 11,561’ 15,301’ 5” 18 P-110 VAM FJL 4.270 11,420’ 17,159’ 3-1/2” 13 P-110 PH-6 17,159’ 17,864’ TUBING DETAIL 3-1/2” 9.3 L-80 EUE Mod 2.992 Surf 4,321’ 2-7/8” 6.4 L-80 Hyd 511 2.377 4,290’ 7,391’ 5-1/2” Gravel Pack 17 L-80 SLHT 4,319’ 8,431’ Updated By: JLL 02/09/21 SCHEMATIC North Cook Inlet Unit Well: NCI B-03 Last Completed: 12/15/2010 PTD: 198-059 API: 50-883-20095-00 PERFORATION DETAIL Zone Top (MD) Btm (MD) Top (TVD) Btm (TVD)FT Date Status CI-1 4,463' 4,547' 3,795' 3,853'84' 10/21/2003 Open CI-2 4,570' 4,663' 3,869' 3,931'93' 10/21/2003 Open CI-3 4,690' 4,701' 3,949' 3,956'11' 10/21/2003 Open CI-4 4,748' 4,820' 3,987' 4,035'72' 10/21/2003 Open CI-4 4,888' 4,918' 4,080' 4,099'30' 10/21/2003 Open CI-5 4,927' 4,955' 4,105' 4,124'28' 10/21/2003 Open CI-7 5,060' 5,090' 4,192' 4,212'30' 10/21/2003 Open CI-8 5,200' 5,214' 4,284' 4,294'14' 10/21/2003 Open CI-9 5,268' 5,291' 4,329' 4,344'23' 10/21/2003 Open CI-11 5,355' 5,402' 4,386' 4,417'47' 10/21/2003 Open B 5,588' 5,595' 4,538' 4,542'7' 10/21/2003 Open B 5,752' 5,765' 4,644' 4,653'13' 10/21/2003 Open C 5,933' 5,939' 4,767' 4,771'6' 10/21/2003 Open D 6,038' 6,046' 4,840' 4,846'8' 10/21/2003 Open D 6,048' 6,054' 4,847' 4,851'6' 10/21/2003 Open E 6,220' 6,227' 4,967' 4,972'7' 10/21/2003 Open E 6,261' 6,268' 4,995' 5,000'7' 10/21/2003 Open H 6,628' 6,648' 5,251' 5,265'20' 10/21/2003 Open H 6,655' 6,672' 5,270' 5,282'17' 10/21/2003 Open I 6,955' 6,978' 5,480' 5,496'23' 10/21/2003 Open L 7,180' 7,197' 5,638' 5,650'17' 10/21/2003 Open N 7,495' 7,517' 5,862' 5,877'22' 10/21/2003 Open P 7,700' 7,727' 6,006' 6,025'27' 10/21/2003 Open Q 7,955' 7,968' 6,186' 9,195'13' 10/21/2003 Open R 8,105' 8,145' 6,291' 6,319'40' 10/21/2003 Open OLD COMPLETION BELOW CEMENT Note: Old tubing tally has not been located. Measurements below are approximate. No Depth (MD) Depth (TVD)ID OD Item 11,181’ 8,506’ Calc. Top of Cement 11,354’ 8,631’ BWD Packer w/ seals top 11,362’8,636’ Bevel guide over tubing stub from 11,362’ – 11,368’ – Tubing chemically cut at 11,362’ after failed pressure test 11,380 8,649’ AHC Packer 11,398’ 8,662’ Fish – 24’ Wireline fish on X Nipple 11,418’ 8,676’ X Nipple (2.313”) 13,700’ 10,341’ Tubing tail 16,890’ 12,571’ Top of Fill _____________________________________________________________________________________ Updated By: JLL 02/22/21 PROPOSED North Cook Inlet Unit Well: NCI B-03 Last Completed: 12/15/2010 PTD: 198-059 API: 50-883-20095-00 JEWELRY DETAIL No Depth (MD) Depth (TVD)ID OD Item 42.6’ 42.6’ 3.500 5-1/2” Vetco Gray Hanger w/.875” MCA Lift Thread 1491’491’ 2.812 Camco 3-1/2” TMAXX-5E SSSV w/2.813” X Profile (open 2470 psi, close 1493 psi) 2 1,335’ 1,327’ 1.00 Camco – KBMG GLM #1 w/GLV 3 2,372’ 2,289’ 1.00 Camco – KBMG GLM #2w/GLV 4 3,407’ 3,068’ 1.00 Camco – KBMG GLM #3 w/GLV 5 4,128’ 3,564’ 1.00 Camco – KBMG GLM #4 w/GLV - Orifice 6 4,217’ 3,626’ 2.812 Baker Sliding Sleeve 2.813” X profile (Closed) 7 4,290’ 3,676’ 6.370 7.50 7” C-2 Liner setting sleeve 4,301’ 3,686’ 4.150 Crossover, 7” 38 ppf LTC pin up x 5” BTC box down 4,302’ 3,684’ 4.000 Baker 80-40 Seal Bore 4” ID x 10’ long 5” BTC pin x pin 4,305’ 3,686’ Baker 80-40 GBH-22 Locator/Seal Assembly Isolation String A 4,431’ 3,773’ 2.347 Baker HS Packer #1, 2-7/8” EUE w/30k shear release B 4,660’ 3,929’ 2.313 Baker 2-7/8” SLCMU Sliding Sleeve (Open 1/11/11) C 4,873’ 4,070’ 2.347 Baker HS Packer #1, 2-7/8” EUE w/30k shear release D 5,342’ 4,378’ 2.347 Baker HS Packer #1, 2-7/8” EUE w/30k shear release E 5,591’ 4,539’ 2.313 Baker 2-7/8” SLCMU Sliding Sleeve (Open 12/19/10) F 5,838’ 4,702’ 2.347 Baker HS Packer #1, 2-7/8” EUE w/30k shear release G 6,088’ 4,875’ 2.313 Baker 2-7/8” SLCMU Sliding Sleeve (Open 12/19/10) H 6,337’ 5,048’ 2.347 Baker HS Packer #1, 2-7/8” EUE w/30k shear release I 6,799’ 5,370’ 2.313 Baker 2-7/8” SLCMU Sliding Sleeve (Open 12/19/10) J 7,277’ 5,707’ 2.347 Baker HS Packer #1, 2-7/8” EUE w/30k shear release K 7,358’ 5,765’ 2.250 Camco Landing Nipple X Profile L 7,390 5,787’ 2.441 2-7/8” WLEG Gravel Pack 8 4,319’ 3,696’ 3.880 Baker 190-60 PBR w/ 15’ seal travel 4,336’ 3,707’ 4.872 Gravel Pack 4,341’ 3,711’ 5.000 Baker KOIV, Busted open on 11/19/03 4,349’ 3,716’ 6.000 Baker 9-5/8” 53.5# SC-1R Packer Assy w/ KOIV @4,381’ 9 4,830’ 4,041’ 6.000 Baker 9-5/8” 53.5# SC-1R Packer 10 5,308’ 4,355’ 6.000 Baker 9-5/8” 53.5# SC-1R Packer 11 5,777’ 4,661’ 6.000 Baker 9-5/8” 53.5# SC-1R Packer 12 6,277’ 5,006’ 6.000 Baker 9-5/8” 53.5# SC-1R Packer 13 6,855’ 5,410’ 4.892 RA Tag in box of 5-1/2”, 17 ppf, L-80 Braden Blank SLHT BxP 14 7,089’ 5,574’ 4.892 RA Tag in box of 5-1/2”, 17 ppf, L-80 Braden Blank SLHT BxP 15 7,217’ 5,665’ 6.000 Baker 9-5/8” 53.5# SC-1R Packer 16 7,767’ 6,053’ 4.892 RA Tag in box of 5-1/2”, 17 ppf, L-80 Braden Blank SLHT BxP 17 8,155’ 6,327’ 6.000 Baker 9-5/8” 53.5# SC-1R Packer sump packer 2/MO ext. 18 8,397’ 6,500’ 3.813 Landing Nipple X Profile 19 8,430’ 6,524’ 4.000 4-1/2” WLEG PBTD: 11,181’ TD: 17,864’ A 30” 5” CI-1 CI-2 CI-3 CI-4 B C D E F H I 3 4 5 6 7 8 9 10 11 12 13 13-3/8” 9-5/8” 1 2 Calc. TOC @ 11,181’ 10/15/03 14 15 16 18 USIT 9/11/03 logged good cmt up to 4,000’ G 20” 7” CI-4 CI-5 CI-7 CI-9 CI-11 Beluga B Beluga C Beluga D Beluga E Beluga H Beluga I Beluga L Beluga N Beluga P Beluga Q Beluga R 3-1/2” 17 19 J K L TOC @ 14,300 Top of fill @ 16,890 5” 1/2” X X CASING DETAIL Size Wt Grade Conn ID Top Btm 30” 547 Welded 29.000 Surf 461’ 20” 133 K-55 Dni-Quip 19.730 Surf 1,214’ 13-3/8” 72 L-80 BTC 12.415 Surf 4,400’ 9-5/8” 53.5 P-110 BTC 8.535 Surf 11,761’ 7” 32 P-110 Butt 6.094 11,561’ 15,301’ 5” 18 P-110 VAM FJL 4.270 11,420’ 17,159’ 3-1/2” 13 P-110 PH-6 17,159’ 17,864’ TUBING DETAIL 3-1/2” 9.3 L-80 EUE Mod 2.992 Surf 4,321’ 2-7/8” 6.4 L-80 Hyd 511 2.377 4,290’ 7,391’ 5-1/2” Gravel Pack 17 L-80 SLHT 4,319’ 8,431’ Updated By: JLL 02/22/21 PROPOSED North Cook Inlet Unit Well: NCI B-03 Last Completed: 12/15/2010 PTD: 198-059 API: 50-883-20095-00 PERFORATION DETAIL Zone Top (MD) Btm (MD) Top (TVD) Btm (TVD)FT Date Status CI-1 4,463' 4,547' 3,795' 3,853' 84' 10/21/2003 Open CI-2 4,570' 4,663' 3,869' 3,931' 93' 10/21/2003 Open CI-3 4,690' 4,701' 3,949' 3,956' 11' 10/21/2003 Open CI-4 4,748' 4,820' 3,987' 4,035' 72' 10/21/2003 Open CI-4 4,888' 4,918' 4,080' 4,099' 30' 10/21/2003 Open CI-5 4,927' 4,955' 4,105' 4,124' 28' 10/21/2003 Open CI-7 5,060' 5,090' 4,192' 4,212' 30' 10/21/2003 Open CI-8 5,200' 5,214' 4,284' 4,294' 14' 10/21/2003 Open CI-9 5,268' 5,291' 4,329' 4,344' 23' 10/21/2003 Open CI-11 5,355' 5,402' 4,386' 4,417' 47' 10/21/2003 Open B 5,588' 5,595' 4,538' 4,542' 7' 10/21/2003 Open B ±5,688’ ±5,708’ ±4,602’ ±4,616’ ±20’ Future Proposed B 5,752' 5,765' 4,644' 4,653' 13' 10/21/2003 Open C 5,933' 5,939' 4,767' 4,771' 6' 10/21/2003 Open D 6,038' 6,046' 4,840' 4,846' 8' 10/21/2003 Open D 6,048' 6,054' 4,847' 4,851' 6' 10/21/2003 Open E 6,220' 6,227' 4,967' 4,972' 7' 10/21/2003 Open E 6,261' 6,268' 4,995' 5,000' 7' 10/21/2003 Open H 6,628' 6,648' 5,251' 5,265' 20' 10/21/2003 Open H 6,655' 6,672' 5,270' 5,282' 17' 10/21/2003 Open H ±6,696’ ±6,716’ ±5,298’ ±5,312’ ±20’ Future Proposed I 6,955' 6,978' 5,480' 5,496' 23' 10/21/2003 Open L 7,180' 7,197' 5,638' 5,650' 17' 10/21/2003 Open N 7,495' 7,517' 5,862' 5,877' 22' 10/21/2003 Open P 7,700' 7,727' 6,006' 6,025' 27' 10/21/2003 Open Q 7,955' 7,968' 6,186' 9,195' 13' 10/21/2003 Open R 8,105' 8,145' 6,291' 6,319' 40' 10/21/2003 Open OLD COMPLETION BELOW CEMENT Note: Old tubing tally has not been located. Measurements below are approximate. No Depth (MD) Depth (TVD)ID OD Item 11,181’ 8,506’ Calc. Top of Cement 11,354’ 8,631’ BWD Packer w/ seals top 11,362’8,636’ Bevel guide over tubing stub from 11,362’ – 11,368’ – Tubing chemically cut at 11,362’ after failed pressure test 11,380 8,649’ AHC Packer 11,398’ 8,662’ Fish – 24’ Wireline fish on X Nipple 11,418’ 8,676’ X Nipple (2.313”) 13,700’ 10,341’ Tubing tail 16,890’ 12,571’ Top of Fill Tyonek Platform B-03 Current 03/12/2021 Starting head, Vetco AL-II, 20 x 13 3/8 surface hanger set-up Casing spool, Vetco Gray 21 1/4'’ 2M x 13 5/8 5M, w/ 2- 2 1/16 5M EFO Tubing head, Vetco CWC-T, 13 5/8 5M x 11 10M, w/ 2- 1 13/16 10M SSO Valve, Master, SSV, VG-300, 5 1/8 5M FE, w/ 18'’ Axelson oper, DD trim Valve, Swab, VG-300 5 1/8 5M FE, HWO, DD trim BHTA, Otis, 5 1/8 5M FE x 9 1/2 Otis quick union top Valve, Wing, VG-300, 5 1/8 5M FE, HWO, DD trim Tyonek Platform B-03 30 x 20 x 13 3/8 x 9 5/8 x 3 ½ Tubing hanger, Vetco CWCT- F6JH, 11 x 5 ½ BTC susp x 5.875 MCA lift threads, 5'’ type H BPV profile, 1- CCL port, flex neck Valve, Master, VG-300, 5 1/8 5M FE, HWO, DD trim Valve, Wing, SSV, VG-300, 5 1/8 5M FE, w/ 18'’ Axelson oper, DD trim 30'’ 20'’ 13 3/8'’ 9 5/8'’ 3 ½’’ Coiled Tubing BOP SWAB VALVE MASTER VALVE HilcorpMonopod Rig 56Flow Diagram Fluids Pumped Fluids ReturnedValve Open Valve ClosedGate Valve Ball ValveButterfly Valve Lo Torq ValveAutomatic Choke Manual ChokePressure Gauge Knife ValveChoke LineP PIT SYSTEM SucƟon SHAKER SHAKER CHOKE MANIFOLDGAS BUSTER Panic LineC12 C13 C15 C14 C16 A B C4 C5 C6 C7 C2 C10 C9 C11 C8 C3 P C1 C STANDARD WELL PROCEDURE NITROGEN OPERATIONS 09/23/2016 FINAL v-offshore Page 1 of 1 1.) MIRU Nitrogen Pumping Unit and Liquid Nitrogen Transport. 2.) Notify Facility Operator of upcoming Nitrogen operations. 3.) Perform Pre-Job Safety Meeting. Review operating procedures and appropriate Safety Data Sheets (formerly MSDS). 4.) Document hazards and mitigation measures and confirm flow paths. Include review on asphyxiation caused by nitrogen displacing oxygen. Mitigation measures include appropriate routing of flowlines, adequate venting and atmospheric monitoring. 5.) Spot Pumping Unit and Nitrogen Tank. Confirm liquid N2 volumes in transport. 6.) Rig up lines from the Nitrogen Pumping Unit to the well and returns tank. Secure lines with whip checks. 7.) Place signs and placards warning of high pressure and nitrogen operations at areas where Nitrogen may accumulate or be released. 8.) Place pressure gauges downstream of liquid and nitrogen pumps to adequately measure tubing and casing pressures. 9.) Place pressure gauges upstream and downstream of any check valves. 10.) Wellsite Manager shall walk down valve alignments and ensure valve position is correct. 11.) Ensure portable 4-gas detection equipment is onsite, calibrated, and bump tested properly to detect LEL/H2S/CO2/O2 levels. Ensure supplier has a working and calibrated detector as well that measures O2 levels. 12.) Pressure test lines upstream of well to approved sundry pressure or MPSP (Maximum Potential Surface Pressure), whichever is higher. Test lines downstream of well (from well to returns tank) to 1,500 psi. Perform visual inspection for any leaks. 13.) Bleed off test pressure and prepare for pumping nitrogen. 14.) Pump nitrogen at desired rate, monitoring rate (SCFM) and pressure (PSI). All nitrogen returns are to be routed to the returns tank. 15.) When final nitrogen volume has been achieved, isolate well from Nitrogen Pumping Unit and bleed down lines between well and Nitrogen Pumping Unit. 16.) Once you have confirmed lines are bled down, no trapped pressure exists, and no nitrogen has accumulated begin rig down of lines from the Nitrogen Pumping Unit. 17.) Finalize job log and discuss operations with Wellsite Manager. Document any lessons learned and confirm final rates/pressure/volumes of the job and remaining nitrogen in the transport. 18.) RDMO Nitrogen Pumping Unit and Liquid Nitrogen Tank. Hilcorp Alaska, LLCHilcorp Alaska, LLCChanges to Approved Rig Work Over Sundry ProcedureSubject: Changes to Approved Sundry Procedure for Well: N Cook Inlet Unit B-03 (PTD 198-059)Sundry #: XXX-XXXAny modifications to an approved sundry will be documented and approved below. Changes to an approved sundry will be communicated to theAOGCC by the rig workover (RWO) “first call” engineer. AOGCC written approval of the change is required before implementing the change.Sec Page Date Procedure Change New 403Required?Y / NHAKPreparedBy(Initials)HAKApprovedBy(Initials)AOGCC WrittenApproval Received(Person and Date)Approval:Asset Team Operations Manager DatePrepared:First Call Operations Engineer Date U.JGA- STATE OF ALASKA o f tllIzo li ALASKA. AND GAS CONSERVATION COMMISSO REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Abandon r Repair w ell , Rug Perforations r Stimulate r Other r Alter Casing r Roll Tubing F.% Perforate New Pool r Waiver r Time Extension Change Approved Program r Operat. Shutdow n r Perforate r Re -enter Suspended Well 2. Operator Name: 4. Well Class Before Work: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development R Exploratory r _ * 198 - 059 3. Address: 6. API Number: Stratigraphic r Service "` P. O. Box 100360, Anchorage, Alaska 99510 - 50 00 7. Property Designation (Lease Number): 8. Well Name and Number: ADL 17589, North Cook Inlet Unit 41) L 037 Vat SELyt -- - NCI B - 9. Field /Pool(s): w North Cook Inlet Field / Tyon Pool TEa A GAA f co L 10. Present Well Condition Summary: Total Depth measured 17864 feet Plugs (measured) None true vertical 13356 feet Junk (measured) None Effective Depth measured 14377' feet Packer (measured) see attached schematic true vertical 10783' feet (true vertucal) Casing Length Size MD TVD Burst Collapse Structural 414' 30" 461' 461 Conductor 1167' 20" 1214' 1208 Surface 4360' 13.375" 4400' 3752 Intermediate 11721' 9.625" 11761' 8918 Liner 3741' 7" 15301' 11379 Liner 5730' 5" 17150' 12777 Liner 705' 3.5" 17864' 13356' ''� Perforation depth: Measured depth: 4463' - 8145' �.e► 9 «► True Vertical Depth: 4087' - 7057'54 ED JAN 1 9 ZUl1 Tubing (size, grade, MD, and TVD) 3.5 ", L -80 / P -110, 4321' / 13700' MD, 3700' / 10341' TVD rt€ . „a , n; q ^l c a'i'irs N "scion Packers & SSSV (type, MD, and TVD) see attached schematic for listing of packers Camco TRMAXX -5E SSSV @ 491' MD / 491' TVD 11. Stimulation or cement squeeze summary: Intervals treated (measured): not applicable Treatment descriptions including volumes used and final pressure: 12. Representative Daily Average Production or Injection Data Oil - Bbl Gas - Mcf Water - Bbl Casing Pressure Tubing Pressure Prior to well operation 0 1773 0 -- 119 Subsequent to operation 0 2052 0 -- 115 13. Attachments 14. Well Class after work: Copies of Logs and Surveys run Exploratory r Development P” ` Service r Stratigraphic 15. Well Status after work: Oil r 0 Gas wo WDSPL r Daily Report of Well Operations XXXX GSTOR fl WINJ r WAG r GINJ r SUSP r SPLUG 16. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 310 -349 Contact Brett Packer @ 265 -6845 Printed Name Brett Packer Title Wells Engineer Signature Phone: 265 -6845 Date ((/2/( ( RBDMS JAN 13 2011- 2 Form 10 -404 Revised 10/2010 Submit Original Only • ConocoPhillips Time Log & Summary Weilview Web Reporting Report Well Name: NCI B - 03 Rig Name: CUDD 136 Job Type: RECOMPLETION Rig Accept: 10/21/2010 6:00:00 AM Rig Release: 12/15/2010 3:00:00 PM Time Logs Date From To Dur S. Depth E. Depth Phase Code ' ' Subcode T Comment 10/22/2010 24 hr Summa Pollard slickline still working on B -3. Total of 11 CUDD employees on board. Helped to rig up iron to displace /kill well B -3. Boat w/ first load of CUDD equipment arrived 0400 hrs 10/22/2009, second boat 10/23/2009. Third boat, some CUDD rig parts. Needed boat f/ KCL. 00:00 03:30 3.50 MIRU MOVE OTHR P PJSM. Rigging up CUDD Rig. Continue Wire line work and CUDD standby f/ boat to arrive with 1st load of CUDD equipment. 03:30 03:45 0.25 MIRU MOVE SFTY P Boat arrived. Held safety meeting with crane crew on offloading and back loading boat. 03:45 07:00 3.25 MIRU MOVE MOB P Offload and backload boat. 07:00 08:45 1.75 MIRU MOVE RURD P All structure beams and 1 racking board RU. Standby f/ tide change, clean out racking board. 08:45 12:00 3.25 MIRU MOVE RUNL P Finish RU rest of structure to rotary beams. RU handrails around top of structure boxes. PJSM with oncoming crew. 12:00 12:45 0.75 MIRU MOVE RURD P RD slick line crew. 12:45 14:30 1.75 MIRU MOVE RURD P Rigging up 2" iron to kill well. 14:30 15:30 1.00 MIRU MOVE RURD P Fill lines. PT lines to 3000 psi. 15:30 17:30 2.00 MIRU MOVE RURD P BJ start pumping 6% KCL to kill well. CUDD finish pulling handrail up around top structure. 17:30 19:30 2.00 MIRU MOVE MOB P Boat arrived, offload more CUDD equipment. Continue to RU. 19:30 20:00 0.50 MIRU MOVE RURD P PU and install work window. 20:00 21:00 1.00 MIRU MOVE RURD P PU and install walk- around to work window. 21:00 22:00 1.00 MIRU MOVE RURD P 22:00 00:00 2.00 MIRU MOVE RURD P PU and install hydjack, tighten up nuts and bolts, install and tighten up guide wire f/ Hydraulic j 10/23/2010 Pollard slickline still working on B -3. Total of 11 CUDD employees on board. 00:00 01:00 1.00 MIRU MOVE RURD P PJSM. Reviewed JSA. Finish RU guide wire to hydraulic jack, clearing off deck f/ equipment. 01:00 02:00 1.00 MIRU MOVE OTHR P Service power pack and label slings that are not on equipment. 02:00 03:45 1.75 MIRU MOVE OTHR P Standby f/ boat to come back when tides permit. Page 1 of 48 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 03:45 05:15 1.50 MIRU MOVE MOB P Boat arrived, offloading equipment to continue RU. Prepare work basket to be installed onto hydraulic jack. 05:15 07:00 1.75 MIRU MOVE OTHR P Standby f/ boat to give platform water and take off 2 picks to finish work basket. 07:00 12:00 5.00 MIRU MOVE MOB P Offloaded 2 picks f/ boat. Standby f/ crane operator to finish w/ Pollard wireline work before continuing. RU HWO unit, continue preparing equip to be rigged up whenwhen wire -line work (As per ConocoPhiillips rep). Clean out and organize warehouse connex, install all anti -falls in proper places on unit, work on swivel f/ kelly hose. 12:00 18:00 6.00 MIRU MOVE OTHR P PJSM. Review JSA w/ crew. Standby f/ wireline to finish working before RU of rest of equipment to hyd jack. 18:00 19:00 1.00 MIRU MOVE OTHR P Shut down, wireline rigging down Pollard wireline equipment. 19:00 21:30 2.50 MIRU MOVE MOB P Boat arrives, start offloading pallet material and equipment. 21:30 22:45 1.25 MIRU MOVE RURD P Picking up main hydraulic hoses for the jack. Draining them into used oil drum, then connecting them to the jack. 22:45 23:00 0.25 MIRU MOVE RURD P Preparing to pick up and stab the work basket- winds were blowing 22 mph- crane operator wanted to wait to check weather forecast to see if winds would lay down. 23:00 00:00 1.00 MIRU MOVE RURD P Picking up skidding cylinders out of cargo basket and placing on the skid beams. 10/24/2010 Pollard slickline still working on B -3. Total of 11 CUDD employees on board. Rigging up over leg #2. Preparing rig to skid to Leg #1 (Well B -3). 00:00 03:00 3.00 MIRU MOVE RURD P PJSM and reviewed JSA. Finish rigging up skidding system and put in place. Function test same after getting permits to start power units. 03:00 04:00 1.00 MIRU MOVE RURD P All skidding equipment working properly, fill up both diesel tanks. 04:00 05:30 1.50 MIRU MOVE RURD P Still standby for wind to lay down to rig up workbasket and gin pole as per crane operator. Install guide wire to workbasket. 05:30 06:00 0.50 MIRU MOVE RURD P Prepare to install workbasket. Move diesel tanks out of area to install workbasket to riser. 06:00 07:00 1.00 MIRU MOVE RURD P Install workbasket to riser on deck and bolt down same. 07:00 09:00 2.00 MIRU MOVE RURD P Workbasket installed to hydraulic jack. Bolt down same and install guide wire, tighten same. Page 2 of 48 s Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 09:00 11:00 2.00 MIRU MOVE OTHR P Standby f/ crane operator to finish w/ Pollard wireline. Will remove hoses from work basket and RU gin pole. 11:00 11:15 0.25 MIRU MOVE RURD P Remove hydraulic hoses from workbasket using crane. 11:15 12:00 0.75 MIRU MOVE OTHR P Standby f/ crane operator to finish w/ Pollard wireline again. 12:00 12:30 0.50 MIRU MOVE SFTY P PJSM and review JSA. 12:30 13:30 1.00 MIRU MOVE RURD P Lowered hoses f/ the work basket, untangled them and stretched them out on the deck. 13:30 14:30 1.00 MIRU MOVE OTHR P Pollard has plug set, stand by for crane to rig down Pollard wireline. 14:30 16:00 1.50 MIRU MOVE RURD P Pick up and stab the gin pole, had to take time due to limited crane height. Started BJ pumping operations. 16:00 18:00 2.00 MIRU MOVE RURD P Had the welder fix the bent gin pole bracket and installed before releasing from the crane. 18:00 20:00 2.00 MIRU MOVE RURD P Securing and labeling all hydraulic hoses to the unit for skidding operations. 20:00 21:00 1.00 MIRU MOVE OTHR P Waiting on the crane to fully rig down Pollard wireline equipment from the deck. 21:00 22:30 1.50 MIRU MOVE RURD P Clearing all equipment and pallet material behind unit for a clear pathway for skidding operations. 22:30 00:00 1.50 MIRU MOVE OTHR P Standing by f/ BJ pumping /testing operations. Will be skidding sub to B -3 after testing BPV, SSSV, swab valve, and downhole plug 10/25/2010 BJ pump unit test SSSV to 1000 psi f/ 22 minutes (open to atmosphere) -good, bled pressure below valve to 100 psi, set Cameron 5" type "H" BPV w/ dry rod, open SSSV, pressure test BPV to 1000 psi f/ 30 minutes (open to atmosphere) -good. Bleed off pressure, blow down lines, rig down BJ pumping equipment. Cudd: Prepare to skid rig, help rig down 2" iron, skid rig to B -3, offload Cudd equipment f/ boat, back haul BJ cement unit, laying mats and duck ponds, spotting equipment. Platform fire alarm sounded, report to muster area (Power on platform shut down), continue rigging up, install ladder to work basket. Boat arrived, unload boat. 00:00 00:15 0.25 MIRU MOVE RURD P BJ pump unit testing SSSV to 1000 psi f/ 22 minutes with swab valve open to atmosphere -good, bled pressure to 100 psi, set Cameron 5" type H BPV w/ dry rod, open SSSV, pressure test BPV to 1000 psi f/ 30 minutes -good. Bleed off prerssure, blow down lines, rig down BJ pumping equipment. CUDD: PJSM and reviewed JSA. 00:15 00:30 0.25 MIRU MOVE RURD P Vetco Gray rep set Cameron 5" type H BPV w/ dry rod. CUDD: Prepare deck to skid unit to B -3. Page 3 of 48 • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 00:30 01:00 0.50 MIRU MOVE RURD P Open SSSV (apply 3400 to 3600 psi to hydraulic panel), pressure test BPV to 1000 psi f/ 30 minutes with swab valve open to atmosphere -good. 01:00 02:00 1.00 MIRU MOVE RURD P Bleed off pressure, blow down lines, rig down BJ pumping equipment. CUDD: Rigging down all chicsan 2" iron and install in racks. Remove rack from area to skid rig. 02:00 03:30 1.50 MIRU MOVE RURD P Rigging down BJ equipment, prepare to move unit off platform. 03:30 08:00 4.50 MIRU MOVE SKID P Cudd: Start skidding unit to B -3 @ 0330 hrs. Over well @ 0800 hrs. 08:00 08:30 0.50 MIRU MOVE RURD P Removed hyd hoses f/ cylinders, roll up hoses. 08:30 09:30 1.00 MIRU MOVE MOB P Offload CUDD equipment from boat, backload BJ cement unit and chicksans. 09:30 12:00 2.50 MIRU MOVE RURD P Laying out mats and duck ponds to start installing equipment in place, power pack, diesel tank, mud tank, and mechanic shop. 12:00 14:00 2.00 MIRU MOVE RURD P PJSM and review JSA. Continue to lay out mats and duck ponds, placing equipment where needed. 14:00 14:45 0.75 MIRU MOVE RURD P Install equalizing tube onto the power packs. 14:45 15:15 0.50 MIRU MOVE RURD P Picking up ladder to the work basket, and prepare to install 15:15 16:00 0.75 MIRU MOVE OTHR P Fire alarm sounded. Shut down operations, proceed to muster area. Electricity down on platform. 16:00 17:00 1.00 MIRU MOVE RURD P Pickup and install ladder to workbasket. 17:00 17:45 0.75 MIRU MOVE MOB P Spot pump and choke manifolds. 17:45 20:30 2.75 MIRU MOVE MOB P Boat arrived. Start offloading and spotting equipment on the deck. 20:30 21:30 1.00 MIRU MOVE RURD P Standby f/ tide change. Moving equipment on the deck. 21:30 00:00 2.50 MIRU MOVE RURD P Continue to offload equipment from the boat. 10/26/2010 PJSM, JSA, permit. Moving equipment, install closing unit and trip tank pump. Install hydraulic extension hoses, place remote BOP stations, PJSM, install lift cyl to tong arm, install tongs in the work basket, run 2" iron to pump manifold. Moduspec inspector Albert Cole looking over equipment. Function testing jack, hook up lights to work basket and work window. Hanging tarps on hoses around basket. Noticed leaking connection on hyd fitting on the back side of jack. Spill of less than a cup, with 1 oz to the water. 00:00 00:30 0.50 MIRU MOVE RURD P PJSM, review JSA. 00:30 01:00 0.50 MIRU MOVE RURD P Moving equipment to spot in proper place. 01:00 02:00 1.00 MIRU MOVE RURD P Move closing unit and centrifugal pump into place. 02:00 02:30 0.50 MIRU MOVE RURD P Remove hyd cylinders and place in cargo basket. Put BPO basket on deck. Set two CPAI crossover baskets in front of stucture. Page 4 of 48 • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 02:30 03:30 1.00 MIRU MOVE RURD P Lay out mats to install hydraulic hoses from workbasket to power packs. 03:30 10:30 7.00 MIRU MOVE RURD P Add extension hydraulic hose, connecting equipment on deck. 10:30 12:00 1.50 MIRU MOVE RURD P Removing Koomy hoses from cargo basket, clearing off drill deck w/ equipment not needed on deck. Preparing well control stations. 12:00 12:30 0.50 MIRU MOVE RURD P PJSM and review JSA. 12:30 13:15 0.75 MIRU MOVE RURD P Install hydraulic lift cylinder to tong arm and stab same. 13:15 14:45 1.50 MIRU MOVE RURD P Pull tongs out of the basket and install onto the tong pole in the work basket. 14:45 15:30 0.75 MIRU MOVE RURD P Running pump iron to the manifold, working with Moduspec inspector Albert Cole. 15:30 17:45 2.25 MIRU MOVE RURD T Function testing the equipment. Jack was not working properly. 17:45 19:00 1.25 MIRU MOVE RURD P Hooking up lights to work basket and work window. 19:00 20:30 1.50 MIRU MOVE RURD T Changed out hoses, refunction tested equipment, everything working good. 20:30 22:30 2.00 MIRU MOVE RURD P Hanging tarps on hoses off the work basket. 22:30 23:00 0.50 MIRU MOVE RURD P Preparing to scope out Gin Pole. Noticed leaking 1/4" hydraulic connection on the back of the jack. Shut down and repaired. Re- adjusted tarp on the unit. Spill of less than a cup, with maybe an oz to the Cook Inlet water. 23:00 00:00 1.00 MIRU MOVE RURD P Scoped out gin pole, turned on stobe light on top of the pole. 10/27/2010 PJSM, review JSA, continue to rig up: RU remote BOP panel @ workbasket & on deck. RU tarp around hyd hoses @ workbasket, jack, & back of HWO. Place BOP's on drill deck. Richard Green's crew shut down to attend pre spud meeting at LNG plant. Bradly Brown's crew held PJSM, review JSA. Installing safety pins in shackles, offload boat, changing shackles on the gin pole, change out bad anti fall devices, repair leak on equalizing tube between HPU's, check pre charge on Koomey unit, install lid over pits, secure electrical cables in the basket, remove fluid from tool baskets and the work basket. work on routing 2" iron from choke manifold to gas buster. Checking TIW's, IBOP's, and crossovers. Install slips in the jack head. 00:00 00:30 0.50 MIRU MOVE SFTY P PJSM and review JSA. 00:30 03:00 2.50 MIRU MOVE RURD P Continue to rig up BOP remote panels to work basket and the emergency escape stagging areas w/ cords and air hoses. 03:00 05:30 2.50 MIRU MOVE RURD P Rig up tarps around the HWO unit where there is a chance of a oil spill going into the Cook Inlet. Workbasket area and hyd jack area, plus all hoses on back of HWO unit. Clear off deck to place BOP's. 05:30 06:00 0.50 MIRU MOVE RURD P Move BOP's to the drill deck. Page 5 of 48 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 06:00 12:00 6.00 MIRU MOVE RURD P Richard Green's crew shut down, clean up to go to LNG plant to attend Conocophillips B -3 pre spud meeting. Quadco/Totco rigging up PVT equipment, Total Safety rigging up gas monitoring equipment. Vetco Gray servicing lockdown screws on the tubing hanger. 12:00 12:30 0.50 MIRU MOVE SFTY P PJSM and review JSA. 12:30 13:30 1.00 MIRU MOVE RURD P Installing safety pins in all shackles and pins in the substructure requested by Moduspec inspector Albert Cole. 13:30 15:00 1.50 MIRU MOVE MOB P Offloading equipment from boat. 15:00 16:30 1.50 MIRU MOVE RURD P Changing shackles on the gin pole, lowering tongs to the deck to re -route hydraulic hoses as requested by inspector. Re- installed the tongs in the basket. 16:30 17:30 1.00 MIRU MOVE RURD T Changing out bad fall protection devices, repairing leak on equalizering tube between power pack (HPU). 17:30 19:00 1.50 MIRU MOVE RURD P Checking precharge on nitrogen bottles of the koomey unit. Install lid onto the mud tank. 19:00 20:30 1.50 MIRU MOVE RURD P Securing electrical cables in the basket. Removing fluid from the tool baskets and work basket. 20:30 21:15 0.75 MIRU MOVE RURD P Run 2" iron from the choke manifold to the gas buster on the pits. 21:15 22:00 0.75 MIRU MOVE RURD P Pulled out the handling tools, checking the ATIWs and IBOP's, looking f/ crossovers to the work strings. 22:00 00:00 2.00 MIRU MOVE RURD P Pulled out hyd slips, locate and install the conversion plates to hook the slips to the jack head. Install slipsonto jack head. 10/28/2010 PJSM, review JSA, continue to MU risers and adapter, Koomey function test, remote BOP function tests, weekly safety meeting, test emergency shutoffs on hyd power units, remove old lights f/ work basket, replace bad hose on operators console, re- function test koomey after repairing remote panel in the work basket, test emerg shutdown on fluid pumps, change out kill mechanism, install bolts in flanges on mud tank manifold, assist Quadco and Total Safety w/ PVT and gas detection equipment. Repair emergency shut down on both fluid pumps, secure electrical cables around jack unit, Function emergency shut down on both tong power units, install whip checks onto jack hoses. Hook up agitators in the 100 bbl pit, function test agitators, moving equipment on the deck. 00:00 00:30 0.50 MIRU MOVE SFTY P PJSM and review JSA. 00:30 07:00 6.50 MIRU MOVE RURD P Continue to make up BOP risers and adapters on the deck. Moving equipment on the deck, repair torque wrench. 07:00 12:00 5.00 MIRU MOVE SEQP P Perform Koomey function test. Checking remote panels too. Page 6 of 48 Time Logs • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 12:00 12:30 0.50 MIRU MOVE SFTY P Both CUDD crew having weekly safety meeting. 12:30 13:15 0.75 MIRU MOVE SEQP P Testing emergency shutdowns on both hydraulic power units. 13:15 14:00 0.75 MIRU MOVE RURD T Remove old lights from the work basket, replacing bad hose on the operators console. 14:00 15:00 1.00 MIRU MOVE RURD T Re- function the kommey unit with the moduspec inspector, after repairing the remote panel in the work basket. 15:00 16:15 1.25 MIRU MOVE SEQP P Testing the emergency shutdown on the fluid pumps. Had to change out kill mechanisim, it was not fuctioning properly. 16:15 17:00 0.75 MIRU MOVE RURD P Installing bolts in the flanges of the mud tank manifold as per Moduspec inspector. Also assisting Quadco and Total safety with rig up of pit monitoring systems and H2S and LEL alarm system for the basket area. 17:00 18:30 1.50 MIRU MOVE RURD P Pump repaired, functioned emergency shutdown on both pump units. Securing all electrical cables in the walk around the jack area. 18:30 19:45 1.25 MIRU MOVE SEQP P Function the emergency kill on both poer tong units with inspector. Torque bolts on the mud tank manifold. 19:45 21:15 1.50 MIRU MOVE RURD P Installing whip checks onto the jack hoses on the unit. Hooking up the hydraulics to the pit agitators (100 bbl pit). 21:15 00:00 2.75 MIRU MOVE SEQP P Function test agitators. Moving equipment on the deck, pulling hoses out to finish rig up. 10/29/2010 PJSM, review JSA, con't working on Moduspec punch list. Assist Loomis rigging up tongs, slips dressed f/ 5 -1/2 ".Tighten bolts on risers and BOP adapters. Change rams in BOPS (5 -1/2" bottom, 2 -7/8" x 5" top). start hooking up choke manifold, PJSM, install emergency kill switch in work basket, install stationary slips in the jack. remove 3" kill and choke hoses f/ baskets, lay out on the deck. Top off fuel tank. Noticed lid on one tank not secured. Checked oil w/ paste indicator and drained a little- all ok. Changed rams back to 2 -7/8" x 5" in bottom and 5 -1/2" in the top BOP. Start function testing the jack and agitators. Re- arranged hoses by the traveling slips. Start function testing the jack. 00:00 00:30 0.50 MIRU MOVE SFTY P PJSM, review JSA. 00:30 02:00 1.50 MIRU MOVE RURD T CUDD working on items from Moduspec list, rearranging equipment on the deck, tightening risers on the deck and wrapping hydraulic connections, install whip checks on power jack hoses, clean drip pans and dog house. 02:00 05:00 3.00 MIRU MOVE RURD P Assist Loomis with rigging up their equipment in the work basket, dresssing slips for 5 -1/2" tubing. Page 7 of 48 • • Time Logs Date From To Dugs S. Depth E. Depth Phase Code Subcode T ; Comment 05:00 07:00 2.00 MIRU MOVE RURD P Torquing up bolts on risers and adapters on the deck. Finishing up inspection list in the basket. 07:00 08:30 1.50 MIRU MOVE RURD P Move the single gate and double gate BOP to change rams. 08:30 11:00 2.50 MIRU MOVE RURD P Change single gate to 5 -1/2 ", top of double gate to make sure they are 2 -7/8" x 5 ". 11:00 12:00 1.00 MIRU MOVE RURD P Moved BOP's out of the way of pipe rack. Start hooking up iron to choke manifold. 12:00 12:30 0.50 MIRU MOVE SFTY P PJSM, review JSA. 12:30 14:15 1.75 MIRU MOVE SEQP P Installing emergency kill switch in the work basket. Fixing leaks on the deck. 14:15 16:30 2.25 MIRU MOVE RURD P Install the stationary slips in the jack. 16:30 17:30 1.00 MIRU MOVE RURD P Preparing the Hydraulic power units to start running it for the Moduspec inspector. 17:30 18:30 1.00 MIRU MOVE RURD P Removing 3" kill and choke hoses from the baskets on the top deck and laying them out. 18:30 20:00 1.50 MIRU MOVE RURD P Fuel up the fuel tank. Noticed one of the hydraulic tanks did not have the lid secured. Drained some hydraulic oil to check f/ water, also checked with test paste- no water in the oil indicated. 20:00 21:30 1.50 MIRU MOVE RURD P Changing rams in the BOP's. Put 5 -1/2" in the top, 2 -7/8" x 5" variables in the bottom. 21:30 23:00 1.50 MIRU MOVE SEQP T Start to function test jack- noticed that the traveling slip hoses were not riding right, re- routed hoses and tested to ensure they will work good. 23:00 00:00 1.00 MIRU MOVE RURD P Functioning the jack, up and down. Watching hoses for leaks and how well they are traveling. Note: Quadco working on PVT system and monitors. Total safety working on gas detection system. 10/30/2010 PJSM, review JSA, prepare to function test Hydraulic Jack, check routing of hoses, fix problem with hydraulic slips, repair 3/4" snap tite connection on agitator in pits, watching f/ leaks, repair leak on 3/4" 90 deg fitting on main winch, repair same. Continue running jack and slips up and down observing f/ leaks. Perform pull test to 1500 psi f/ 5 min each- top and bottom position of jack. Perform test twice. Shut down power units and clean drip pans of both hyd units. Clear deck and escape routes, install whip checks on all hoses leaving HPU, install tie down straps on 2" iron f/ pumps, install tee and pop offs. Offload boat, install hand slips in the work window, tally joints and pups f/ testing BOP's. Install nitrogen backup in the accumulator room f/ the Koomey unit. Re measure workbasket handrail to the bottom of window (36.05), to the deck lid ( 63.45'), and to the LDS of tubing hanger (76.55'). Make up crossovers to handle BOPS with the hydraulic slips and then the BOP trolly s stem. 00:00 00:30 0.50 MIRU MOVE SFTY P PJSM and review JSA. Page 8 of 48 Time Logs Date From To Dur S. Depth E. Depth Phase Code _ , Subcode T Comment 00:30 01:30 1.00 MIRU MOVE RURD P Preparing to run Hydraulic jack up and down f/ 4 hrs. Rearrange hoses to make sure they are out of the way of jack. 01:30 03:00 1.50 MIRU MOVE RURD T After getting everything ready to run hydraulic jack up and down, using hydraulic slips as if pipe was in the hole, noticed that the hydraulic slips (both sets) were not working properly. Fixed problem. With everything working properly, slide slips over the hole. 03:00 03:15 0.25 MIRU MOVE RURD T Repair 3/4" snap tite fitting on a agitator in the 100 bbl mud pit. Agitators running off the Hyd unit #2. 03:15 04:00 0.75 MIRU MOVE RURD P Continue to run hydraulic jack up and down, using hydraulic slips and watching for leaks. 04:00 04:15 0.25 MIRU MOVE Found leak on 3/4" 90 deg fitting off the main winch in the work basket. Repaired fitting. 04:15 05:00 0.75 MIRU MOVE Continue to run hydraulic jack up and down, using hydraulic slips and watching for leaks. 05:00 05:30 0.50 MIRU MOVE SEQP P Pull test jack with 1500 psi at top position and 1500 psi at the bottom position f/ 5 minutes each. Performed test twice. 05:30 12:00 6.50 MIRU MOVE RURD P Shut down Hydraulic power units. Cleaned out the drip pans on both. Rearranged deck to prevent tripping hazards. Cleared escape routes. Make room on the deck to rack pipe. 12:00 12:30 0.50 MIRU MOVE SFTY P PJSM and review JSA. 12 :30 13:30 1.00 MIRU MOVE RURD P Continue to clean up and re- arrange equipment on the platform. Install whip checks on all hoses coming from the hydraulic power unit. 13:30 15:00 1.50 MIRU MOVE RURD P Install tie down straps on all the 2" iron from the mud pumps. 15:00 17:30 2.50 MIRU MOVE RURD P Rig up tee in 2" iron, install pop offs. 17:30 20:00 2.50 MIRU MOVE MOB P Offloading equipment from the boat. 20:00 21:00 1.00 MIRU MOVE RURD P Install the hand slips in the work window. Help strap test joints, pups and joints f/ testing. 21:00 22:00 1.00 MIRU MOVE RURD P Install the nitrogen backup system in the Koomey unit. Install light in the work window. 22:00 22:45 0.75 MIRU MOVE RURD P Measure from the workbasket handrail to tubing hanger lockdown screws (76.55'), measure workbasket handrail to the lid on the deck above the wellhead room (63.45'). Measure lid on the deck above the wellhead room to lockdown screws of the tubing hanger (13.10') Page 9 of 48 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 22:45 00:00 1.25 MIRU MOVE RURD P Making up crossovers to pickup BOPS, then handle with the BOP trolley system. 10/31/2010 PJSM, review JSA. Change the 6' 11" 5m spool on riser to a 4' 11" 5m. Install API ring, bolt, and torque with hydraulic torque wrench. Measure length's, OD's, ID's of crossovers, floor safety valves and IBOP needed to test. Rigging up 2" iron to the gas buster and choke manifold. Install haz loc light in the work window. PJSM, review JSA. Change out a 3/4" hydraulic hose f/ the work basket- function tested after changing. Clean drip pans, PU trash, secure 2" iron w/ safety straps. Re -check shackles, air connections, whip checks on hoses. Clean tool box, inventory supplies. 00:00 00:30 0.50 MIRU MOVE SFTY P PJSM and review JSA. 00:30 09:30 9.00 MIRU MOVE RURD P Change the 6' 11" 5m spool on riser to a 4" 11" 5m. Install API ring, bolt, and torque with hydra torque wrench. Measure length's, OD's, ID's of crossovers, floor safety valves and IBOP needed to test. 09:30 12:00 2.50 MIRU MOVE RURD P Rig up 2" iron to the gas buster and both pumps. Rig up iron to the choke manifold. Function test a hazardous location light, then install in the work window. 12:00 12:30 0.50 MIRU MOVE SFTY P PJSM and review JSA. 12:30 15:30 3.00 MIRU MOVE RURD P Change out a 3/4" hydraulic hose f/ the work basket- function tested after changing. Clean drip pans, PU trash, secure 2" iron w/ safety straps. Re -check shackles, air connections, whip checks on hoses. Clean tool box, inventory supplies. 15:30 18:00 2.50 MIRU MOVE RURD P Pump out standing water from drip pans. Clean drip pans. Pick up loose trash so wind would not blow around. 18:00 21:00 3.00 MIRU MOVE RURD P Secure 2" iron w/ safety straps and shackles. 21:00 00:00 3.00 MIRU MOVE RURD P Re -check shackles (wire tie or cotter pins), air connections (pins), whip checks on hoses (hyd and air). Clean tool box, inventory supplies. 11/01/2010 PJSM, review JSA. Check whip checks and safety pins on air and hyd lines. Clean dog house, store flammable in a cabinet, clean drip pans, make cover f/ blinds on the remotes. Remove hoses f/ baskets to rig up to circulate. Test lines w/ air -ok. Circulate up to 3 bpm -OK. Test lines to circ manifold and then the choke manifold to 3500 psi. -OK. Held TapRoot Investigation with crew on tour on 10 -26 -2010 when a spill occurred. Drilling Safety Specialist Mike Rodriguez and CUDD safety Tim Labowe attended the meeting. Trouble shooting air problem with CUDD pump. 00:00 00:30 0.50 MIRU MOVE SFTY P PJSM and review JSA. 00:30 04:30 4.00 MIRU MOVE RURD P Continue checking air and hydraulic fittings f/ safety pins and whip checks. Finish cleaning out the dog house. Removed all flammable cans f/ dog house and put in flammable cabinet in the mechanic shop. Cleaned all drip pans, removed oily pads and placed in proper containment. Page 10 of 48 • • Time Logs Date From To Dur S. Depth E. Depth Phase Code ' Subcode T Comment 04:30 06:30 2.00 MIRU MOVE RURD P Made another cover f/ blinds control on remote station. Both covers made. 06:30 09:00 2.50 MIRU MOVE RURD P Standby for wind to lay down to do crane work. Pickup baskets and set on deck to remove hoses to rig up to CUDD mud tank and platform pits. Work with MI SWACO to get 6% KCL to circulate with mud pump. Clean out the racking board, fixed leak on a JIC fitting. Cleaned oil off plate after repair. 09:00 11:00 2.00 MIRU MOVE RURD P CUDD double checking to make sure they are 100% ready when given word to proceed with well work. 11:00 12:00 1.00 MIRU MOVE RURD P Get basket to drill deck, remove hoses to rig up suction and pump lines. Will test the circulation system. Posted trip drill procedures in proper locations. 12:00 12:30 0.50 MIRU MOVE SFTY P PJSM and review JSA. 12:30 16:45 4.25 MIRU MOVE RURD P Continue to RU hoses for circulating system. 16:45 17:30 0.75 MIRU MOVE RURD P Check system with air to locate leaks rior to circualting fluid. P 9 17:30 19:00 1.50 MIRU MOVE RURD P Circulate through pump lines at .5bpm, then 1 and max of 3 bpm to ensure all lines free of debris. 19:00 20:30 1.50 MIRU MOVE RURD P Pressure testing 2" iron to fluid manifold and then the choke manifold to 3500 psi. Testing valves on the choke manifold. No leaks on choke manifold or manifold. Note: H2S alarm on pits alarmed. Checked out with hand held gas detector - -no indication of H2S. This is the second time alarm has sounded. 20:30 21:30 1.00 MIRU MOVE SFTY P Gather crew that was on tour on 10 -26 -2010 when a spill occurred. Held TapRoot Investigation w/ Drilling Safety Specialist Mike Rodriguez and CUDD safety Tim Labowe. 21:30 00:00 2.50 MIRU MOVE RURD T Touble shooting air system on the mud pump. Replace bad air hose. Run Camlock hoses to the trip tank. Make a blow down line for manifold on the 100 bbl CUDD mud tank. 11/02/2010 PJSM, review JSA. Continue cleaning and organizing unit and deck space. Pump rain water off decks into tanks. Install air governor on circulation pump. Locate & install drain plugs for racking boards. Fabricate walkway for walk way over hose paths. 00:00 00:30 0.50 MIRU MOVE SFTY P PJSM and review JSA. 00:30 12:00 11.50 MIRU MOVE RURD P Continue cleaning, checking and organizing equipment on rig and deck. Crew Change Page 11 of 48 • • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 12:00 12:30 0.50 MIRU MOVE SFTY P PJSM and review JSA. 12:30 15:30 3.00 MIRU MOVE RURD P Continue service equipment. 15:30 18:00 2.50 MIRU MOVE RURD P Rig up vac unit and suck rain water off of decks. 18:00 20:00 2.00 MIRU MOVE RURD P Locate & inspect 5 1/2" tubing elevators. Install air governor on circulating pump. 20:00 00:00 4.00 MIRU MOVE RURD P Locate & drain plugs for racking boards. Crew Change 11/03/2010 PJSM, review JSA's. Continue cleaning and prepping equipment. Clean out rain water in drip pans. Function both power packs, mud pumps and tong unit. Check Swaco generator. Inspect and build procedure for removing tree. Standby for high winds. 00:00 00:30 0.50 MIRU MOVE SFTY P PJSM and review JSA. 00:30 06:00 5.50 MIRU MOVE RURD P Continue cleaning and organizing equipment. Clean out rain water in drip pans 06:00 12:00 6.00 MIRU MOVE RURD P Crank up & run both CUDD power packs, mud pumps, and Loomis tong units. Function Swaco generator verifying power to CUDD. Crew Change 12:00 12:30 0.50 MIRU MOVE SFTY P PJSM and review JSA. 12:30 16:30 4.00 MIRU MOVE RURD P Pump water from mud tank top platform pits. Blow down all lines. 16:30 18:00 1.50 MIRU MOVE RURD P Inspect wellhouse & tree. Write up a procedure for removal of tree. 18:00 00:00 6.00 MIRU MOVE RURD P Standby for high winds and rain. 11/04/2010 PJSM, review JSA's. Continue cleaning and prepping equipment. Crew change today on boat via Billy Pugh. 00:00 00:30 0.50 MIRU MOVE SFTY P PJSM, review JSA's. 00:30 12:00 11.50 MIRU MOVE RURD P Continue cleaning and prepping equipment. Prep crew for change out via Billy Pugh on the boat. 12:00 12:30 0.50 MIRU MOVE SFTY P PJSM, review JSA's. 12:30 00:00 11.50 MIRU MOVE RURD P Continue cleaning and prepping equipment. Prep crew for change out via Billy Pugh on the boat. Load test billy pugh with crane. Change out crew. All safe. Load materials from boat onto deck. Orientation video for all new incoming hands and assignments of lifespheres. 11/05/2010 PJSM, Review JSA's. Continue cleaning and rigging up equipment. Rig up tools with Denali Crane Inspection rep. Pull test winches and trolley system. Inspector noted that the main winch good for only 7600 ft/lbs. Scoped gin pole for 1500 PSI test as raised. Hang BOP rams on trolley system to function & load test same to 13,800 lbs. Insall rotary & slips on jackhead. Held PJSM with Production. Fill out and EIP, with all hands signed off. Nipple down B -3 flowline, and Manumatic wing valve. 00:00 00:30 0.50 COMPZ RPEQP1SFTY P PJSM, review JSA's. 00:30 12:00 11.50 COMPZ RPEQP1RURD P Continue cleaning and prepping equipment. Standby for Crane inspection rep. Page 12 of 48 Time Logs 1 Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 12:00 13:00 1.00 COMPZ RPEQP1SFTY P Held PJSM with Denali Crane Inspector, and crew. Discuss safety & hazard recognition issues. Discuss procedure to rig up and load test equipment. 13:00 15:00 2.00 COMPZ RPEQPI RURD P Rig up, and load test winches and trolley system. Test Main winch to 7600 Ft/Ibs - 5 minutes. Inspector noted that the main winch good for only 7600 Ft/Lbs. Scope Gin pole testing each CB to 1500 PSI for 5 minutes as it scoped. 15:00 16:30 1.50 COMPZ RPEQPI RURD P Install BOP double gates on trolley system for test to 13, 800 Ibs on front, middle and back ends of trolley beam. 5 minutes each test. 16:30 18:30 2.00 COMPZ RPEQPI RURD P Install rotary & slips on jackhead. 18:30 19:30 1.00 COMPZ RPEQP1SFTY P Held PJSM with crew & production reps. Discuss safety & hazard recognition issues. Discuss procedure to nipple down Tree. Make up, and sign EIP for job. All hands signed off and LO/TO performed. 19:30 00:00 4.50 COMPZ RPEQP1NUND P Pull cap off of deck over well room. Nipple down Flow line form B -3 well. Observed 2 bolts that needed to be cut off of flange for removal. Obtain Hot Work Permit, purge line with nitrogen as per Prod. Operator. Utilize band saw to cut last 2 bolts from flange. Nipple down Manumatic Wing Valve assembly. Crew Change 11/06/2010 PJSM, Review JSA's. Continue Nipple down B -3 Tree. NU Riser Spacer spool, and BOP single & double gate rams. When using Manitowc crane to lift Hydril, the crane slipped and dropped the Hydril 4' to the deck. All Manitowoc crane operations suspended until crane inspector flown out for inspection. Continued tightening BOP bolts and attaching lines. 00:00 00:30 0.50 MIRU RPEQP1 SFTY P Held PJSM, and review JSA's. Obtain EIP, and have all oncoming hands sing on. Crew getting off tour, signed off. Re- issue Hot Wiork Permit 00:30 03:30 3.00 COMPZ RPEQP1 NUND P Continue Install Blind flange on Flow line. Continue ND Tree. Production operator verified no pressure & unlocked Master & Wing Valves. SSSV control line bled to Zero. Valve closed. 03:30 05:00 1.50 COMPZ RPEQP1 NUND P Obtain Hot Work permit. Utilize welder to remove grating around tree. Tack weld, and secure grating for foot traffic. 05:00 06:00 1.00 COMPZ RPEQP1NUND P Nipple Down Master Valve & adapter Flange. Production take A -1 & B -1 offline, and secure same. Page 13 of 48 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 06:00 08:30 2.50 COMPZ RPEQP1NUND P Sign off of EIP for B -3, and sign off all hands on second EIP for wellroom. Clean & Inspect hanger threads.Production prepping well room by bleeding lines. Prep to install riser. 08:30 09:30 1.00 COMPZ RPEQP1 NUND P Obtained pictures of hanger threads. Observed corrosion in threads. Continue clean & inspect same. Installed blanking plug. Secured control line with needle valve and pressured same to 5000 PSI to hold open SSSV. 09:30 09:45 0.25 COMPZ RPEQP1SFTY P Reviewed Nipple up JSA. 09:45 12:00 2.25 COMPZ RPEQP1 NUND P Pick up riser spacer spool with crane. Swing into position to load on main winch and lower into position. Set on wellhead, make up same. Crew Change 12:00 12:30 0.50 COMPZ RPEQP1SFTY P HeIs Pre -tour meeting, and reviewd JSA. Handover with relief. 12:30 19:00 6.50 COMPZ RPEQP1NUND P Install BOP's single gate rams, mud cross and double gates utilizing crane to swing components into position for lowering into well bay with trolley. Used Sweeny wrench to torque all BOP bolts. 19:00 21:00 2.00 COMPZ RPEQP1NUND T When utilizing Manitowoc crane to pick up Hydril with mud cross, 13, 500 Ibs, the crane line slipped, and dropped the hydril approximately 4' to the deck. No injuries, spills or equipment damage. All crane operations immediately stopped. Investigation held, with CPAI supervisors, Safety reps, and hands involved. Decision to suspend Manitowoc crane operations until a crane inspector is flown out and able to assure crane is in safe condition. PIR sent out. 21:00 00:00 3.00 COMPZ RPEQP1NUND P Continue torquing BOP bolts. Attach Koomey lines. Attach pump lines to kill line. Make up choke line to choke manifold. Crew Change 400 BBLS of 8.6 ppg 6% KCL on the platform. 11/07/2010 Held Pre -Tour mtg, and review JSA. Continue attaching lines and tightening BOP bolts. Continue clean and prep equipment for nipple up. Move choke manifold and mud manifold closer to sub, and attach all ines. Make up hard lines to from choke to gas buster. Install bell nipple on to double gate rams. Trouble shoot electrical issues with lights going out on rig. Repair same. Continue with Near miss investigation. 00:00 00:30 0.50 COMPZ RPEQP1SFTY P Held Pre -Tour meeting. Review and discuss JSA's. Page 14 of 48 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 00:30 01:30 1.00 COMPZ RPEQP1 NUND P Continue attaching lines, and tightening BOP bolts. Clean & prep equipment for remainder of nipple up. Run Koomey hoses with whips checks. Straighten up under sub structure and deck. 01:30 08:00 6.50 COMPZ RPEQP1 RURD P Make up Target adapters. Start & run power packs. Suck out drip pans, lots of water on deck. Trouble shoot lights went out on rig, and repair same. 08:00 12:00 4.00 COMPZ RPEQP1 RURD P Electrician continue to repair light power issue. Arrange equipment on deck. Fabricate & install grating around riser in cellar. Fabricate & install T Handles for Blind ram ends. Function test remote panel, and function test all rams installed. Rig up 3" hose to kill line. Crew change 12:00 12:30 0.50 COMPZ RPEQP1SFTY P Held Pre -tour meeting. Discuss and review JSA's 12:30 13:00 0.50 COMPZ RPEQP1 RURD P Service & fuel equipment. 13:00 19:00 6.00 COMPZ RPEQP1 RURD P Re -run 3" hoses to kill & choke line. Reposition mud manifold & choke manifold. . 19:00 00:00 5.00 COMPZ RPEQP1 RURD P Continue rigging up choke & kill lines to manifold. Install valves. Make up hard line from choke manifold to gas buster. Make up bell nipple on top of double gates. Crew Change 11/08/2010 Held Pre -Tour Meeting. Review & discuss JSA. Complete rigging up for test. Load lines, to test BOP's. Initial 250 PSI test good. Observed leak in the riser flanges on high test. Retighten all flanges. Obtain good test on Blind rams. Install 2 7/8" test joint. Attenmpt to test 2 7/8" VBR's with no success, after trouble shooting and repeated attempts. Change out VBR's for successful low test, and found leaks on the crossovers. Pull test jnt, tighten connections. Note: Witness of test waived by AOGCC rep -Chuck Scheve. 00:00 00:30 0.50 COMPZ RPEQP1 SFTY P Held Pre -Tour meeting. Review and discuss JSA's. 00:30 03:30 3.00 COMPZ RPEQP1 RURD P Complete rig up of lines and valves for upcoming BOP test.Hang kelly hose from basket. Install secondary annulus valve. 03:30 04:00 0.50 COMPZ RPEQP1 SFTY P Held PJSM. Discuss safety & hazard recognition issues. Discuss procedure to load lines and test BOP's. Discuss proper communication with all hands, and production. 04:00 08:00 4.00 COMPZ RPEQP1 BOPE T Load lines. Verify no leaks. Obtain first low test of Blind rams, good. The high test indicated a leak in the riser flanges. Retighten all flanges with sweeny wrench. Retest Blind rams 250 / 3500 PSI. Bleed pressure. Page 15 of 48 • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 08:00 12:00 4.00 COMPZ RPEQP1BOPE P Make up 2 7/8" test joint with crossovers. RIH to screw into top of blanking plug. Fill stack with water. 12:00 13:00 1.00 COMPZ RPEQP1SFTY P Held weekly safety meeting with both crews, and support crew members. 13:00 19:30 6.50 COMPZ RPEQP1BOPE T Attempt to pressure test 2 7/8" x 5" VBR's. No success. Trouble shoot. Fluid by passing rams. Function test and continue attempts to test. 19:30 23:00 3.50 COMPZ RPEQP1BOPE T Rig up diaphragm pump to suck out stack. Open lower pipe rams inspect VBR's. All good. Make up and attempt retest with no success. Open doors, remove first set of VBR's. Install second set. Retest to success with 250 PSI. On the high test, Crossover leaked. Bleed pressures. 23:00 00:00 1.00 COMPZ RPEQP1BOPE T Held PJSM. Open rams. Back out 2 7/8" test joint to tighten connections. Crew Change 11/09/2010 Held Pre -Tour Meeting. Review & discuss JSA. Continue Test pipe rams with 23 1/2" & 5 1/2" test joints. Test Choke manifold & valves, mud manifold & valves. Crane Inspector arrived and performed preliminary function test and adjustments on Manitowoc. 00:00 00:30 0.50 COMPZ RPEQPI SFTY P Held Pre -Tour meeting. Review and discuss JSA's. 00:30 12:00 11.50 COMPZ RPEQP1BOPE T Continue tighten crossovers on 2 7/8" test joint. Install test joint. Troubleshoot & work on Loomis power pack Troubleshoot & work on Mud pump. Complete test with 2 7/8" test jnt. 250 / 3500 PSI. Lay down 2 7/8" test joint. Make up 3 1/2" test joint. Test with same to 250 3500 PSI. Change out counter balance cable in basket. Crew Change 12:00 12:30 0.50 COMPZ RPEQPI SFTY P Held Pre -Tour meeting. Review and discuss JSA's. 12:30 00:00 11.50 COMPZ RPEQP1BOPE T Lay down 3 1/2" test joint. Make up 5 1/2" test joint. RIH to make up on blanking plug. Test to 250 /3500 PSI. Trouble shoot leaks, and fix them. Back out test joint, lay down same & break crossovers. Crew Change 11/10/2010 Held Pre -Tour Meeting. Review & discuss JSA. Continue testing Floor valves and Dart valves. Prep equipment for scheduled BOP test. Crane inspector working with crane. Load test same with Hydril. ND Bell Nipple for Hydril Installation. Held Weekly Safety Meetings with crews. Standby for orders. 00:00 00:30 0.50 COMPZ RPEQPI SFTY P Held Pre -Tour Meeting. Review & discuss JSA. 00:30 06:30 6.00 COMPZ RPEQP1 BOPE P Continue testing Floor valves and dart valves. Prep equipment scheduled BOP test with AOGCC rep. 06:30 11:30 5.00 COMPZ RPEQP1BOPE T Function tested crane w/ inspector. Crane visually and functionally tested ok. Page 16 of 48 Time Logs Date From To Dur S. Depth _ E. Depth Phase Code Subcode T Comment 11:30 12:00 0.50 COMPZ RPEQPI OTHR P Held pre -tower safety meeting, discuss possible projects while standing by for crane decision. 12:00 00:00 12.00 COMPZ RPEQPI OTHR P Standby waiting for decision from town in regards to crane. 00:00 00:30 0.50 COMPZ RPEQP1SFTY P Held Pre -Tour Meeting. Review & discuss JSA. 00:30 12:00 11.50 COMPZ RPEQP1OTHR P Continue prep equipment, blow down lines. Held Weekly safety meeting. Discuss Working around wellheads presentation. Standby for orders. 11/11/2010 Held Pre -Tour Meeting. Review & discuss JSA. Safety Mtgs. Standby for orders. Prep, inspect & repair equipment. Perform environmental inspection with CPAI rep. Held safety mtgs. Install grating for walkways. 00:00 00:30 0.50 COMPZ RPEQP1SFTY P Held Pre -Tour meeting. Discuss & review JSA's. 00:30 11:30 11.00 COMPZ RPEQP1 OTHR P Blow down Lines. Prep equipment for BOP test. Standby for orders. 11:30 12:00 0.50 COMPZ RPEQP1SFTY P Held Pre -Tour meeting. Discuss & review JSA's. 12:00 00:00 12.00 COMPZ RPCOM OTHR P Standby for word from town in regards to Crane use. Perform environmental inspection with CPAI rep. Service equipment. Install grating fro walkways. 11/12/2010 Held Pre -Tour Meeting. Review & discuss JSA. Safety Mtgs. Standby for orders. 00:00 00:30 0.50 COMPZ RPEQP1SFTY P Held Pre -Tour meeting. Discuss & review JSA's. 00:30 12:00 11.50 COMPZ RPEQP1OTHR P Blow down Lines. Prep equipment for BOP test. Standby for orders. Crew Change 12:00 12:30 0.50 COMPZ RPEQP1SFTY P Held Pre -Tour meeting. Discuss & review JSA's. 12:30 00:00 11.50 COMPZ RPEQP1OTHR P Blow down Lines. Prep equipment for BOP test. Standby for orders. Crew Change 11/13/2010 Held Pre -Tour Meeting. Review & discuss JSA. Safety Mtgs. Standby for orders.. Held PJSM with crews. Perform Lift test with the Manitowoc. Install Hydril. 00:00 00:30 0.50 COMPZ RPEQP1SFTY P Held Pre -Tour meeting. Discuss & review JSA's. 00:30 12:00 11.50 COMPZ RPEQPI OTHR P Blow down Lines. Prep equipment for BOP test. Standby for orders. Crew Change 12:00 20:00 8.00 COMPZ RPEQP1OTHR P Finalize crane procedures, load test crane and perform competency test with operators. 20:00 20:30 0.50 COMPZ RPEQP1SFTY P Held PJSM. Discuss & Review JSA, fill out TRICK card. Discuss safety & hazard recognition issues with crane pics. 20:30 00:00 3.50 COMPZ RPEQPI NUND P Load Hydril onto trolley beam with crane. Observed that we had to split the flow -cross and Hydril for NU. Install studs, and tighten hydril. Crew Change Page 17 of 48 • • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T ' Comment 11/14/2010 24 hr Summary Held Pre -Tour Meeting. Review & discuss JSA. Safety Mtgs. Install Flow Cross. Make up flow riser & lines. Load lines and function test equipment. Test BOP's. Test VBR's and Annular with 2 7/8" & 3 1/2" test jnts. Test all Floor valves and Dart valves in each size of 2 7/8, 3 1/2" and 5 1/2 ". Witness of test by AOGCC rep Bob Noble. All test 250 / 3500 PSI. All tests chart recorded. 00:00 00:30 0.50 COMPZ RPEQP1 SFTY P Held Pre -Tour meeting. Discuss & review JSA's. 00:30 07:30 7.00 COMPZ RPEQP1 NUND P Continue NU & tighten Hydril. Load flow cross with crane, pull into sub base, and NU flow cross. Install flow nipple and lines. Install flow meter. Prep BOP's for test. Load lines, and function test annular, and rams. Install test joint. 07:30 11:30 4.00 COMPZ RPEQP1 NUND P Shut down crane and await for go -ahead from Town. Continue to prep for state witnessed BOP test. State rep Bob Noble is on location. 11:30 18:00 6.50 COMPZ RPEQP1 BOPE P Begin testing of BOP's w/ 5000 psi chart recorder. Also function tested gas detection system and accumulator system. (State witnessed). Test # 1). Tested Blinds w/ 5.5" IBOP C9, P2 & P7 Test #2). Tested Blinds w/ TIW #1 C4, C5, C6 & C7 Test #3). Tested Blinds w/ TIW #2 C1, C2, C3 & P9 Test #4). Tested Blinds w/ 2 7/8" VBR w/ P5 & P8 State rep. leaving location for flight to OSK. Page 18 of 48 Time Logs • 9 Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 18:00 00:00 6.00 COMPZ RPEQPI BOPE P Continue on with testing of BOP's, remainder of test waived by Bob / Noble. Test #5) Tested Annular w/ 2 7/8" test joint w/ P -6 & C -8. Pull 2 7/8" Test jnt. Install 3 1/2" test jnt. Test #6) Tested VBR's w/ 3 1/2" test joint w/ P -3 Pull 3 1/2" test joint. Install 5 1/2" test jnt. Repair Tong heads. Crew Change SIMOPS: With Manitowoc crane, set Pollard slickline unit & baskets in place. Obtain Hot work permit. Attach power. Prep unit & tools for upcoming slickline run. 11/15/2010 Held Pre -Tour Meeting. Review & discuss JSA. Safety Mtgs. Continue install 5 1/2" test jnt. Test Annular & Upper Pipe rams with 5 1/2" test jnts. Troubleshoot leaks. Repair same. Make up 3 1/2" test jnt. Observed failed nipple on Koomey unit when closing annular. PIR sent out. Repair nipple. When attempting to resume test, observed annular valve on Koomey failed. Continue to troubleshoot, repair and reinstall valve. After trouble shooting system, determined internal annular seals had failed allowing fluid to bypass and no pressure build on the Koomey system. Repeat attempts to isolate valve leaking issue with same results as mentioned. 00:00 00:30 0.50 COMPZ RPEQPI SFTY P Held Pre -Tour meeting. Discuss & review JSA's. 00:30 10:30 10.00 COMPZ RPEQP1BOPE P Continue install 5 1/2" test joint with XO's. Test #7 - Tested Annular with 5 1/2" test jnt w/ K -2 & C -9 valves Test #8) - Test Upper pipe rams with 5 1/2" test jnt w/ K -1, C -9 valves. Trouble shoot leak, repair same. 10:30 14:30 4.00 COMPZ RPEQP1 BOPE T Shut down due to hydraulic fitting failure on Accumulator Unit. 20 gallon spill of hydraulic fluid into secondary containment, cleaned area and repaired fitting. Checked remaining fittings on unit, and no problems noted. Continued on w/ BOP test. Page 19 of 48 • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 14:30 00:00 9.50 COMPZ RPEQP1 BOPE T Annular actuator valve on Koomey unit failed and is non - operational. Replace valve and function test.lt was removed and repaired 2 times with the same results. Upon trouble shooting, we observed that when we disconnected the lines from the Koomey to the Annular, and pressure up Koomey, the Annular valve on Koomey would not leak, either in the closed or open position. We inspected the lines to the Annular, and the connections are OK. We contacted a MASSCO technician, and he informed us that we had taken the right steps to trouble shoot the valve, and if it held when lines were disconnected, then the trouble he suspects is the seals in the annular, and not the valve. He told us as well, that the rebuild on location is not recommended and that we change out the annular. 11/16/2010 Held Pre -Tour Meeting. Review & discuss JSA. Safety Mtgs. Breakout & lay down 5 -1/2" test joint. Prep BOP's for ND Annular, and flow riser. Blow down all lines. Stop operation. High winds, unsafe conditions in basket. Standby for weather- high winds. 00:00 00:30 0.50 COMPZ RPEQP1 SFTY P Held Pre -Tour Meeting. Review & discuss JSA. Safety Mtgs. 00:30 05:00 4.50 COMPZ RPEQP1 NUND T Breakout & lay down 5 -1/2" test joint. Prep BOP's for ND Annular, and flow riser. Blow down all lines. 05:00 00:00 19.00 COMPZ RPEQP1SFTY T Stop operation. High winds, unsafe conditions in basket. Standby for weather- high winds. 11/17/2010 Held Pre -Tour Meeting. Review & discuss JSA. Standby for weather- high winds 32 -42 mph. PJSM @ 0400 hrs, wait on winds some more. Once winds had subsided, nipple down bell nipple, flow line, and annular. (Notice sent to Jim Regg that BOP testing will resume tomorrow). Clean deck, prepare f/ Weatherford rental Annular to be delivered in early morning on boat. 00:00 00:30 0.50 MIRU RPEQP1 SFTY P Held Pre -Tour Meeting. Review & discuss JSA. Safety Mtgs. 00:30 06:30 6.00 MIRU RPEQP1SFTY T High winds continue, unsafe conditions in basket. Standby for weather- high winds. Crane work needs 25 mph or less. Held PJSM @ 0400 hrs to nipple down, but wind picked back up. 06:30 06:45 0.25 MIRU RPEQP1 SFTY T Held PJSM to nipple down w/ crane crew and CUDD crew. 06:45 07:45 1.00 MIRU RPEQP1 NUND T Remove bell nipple. 07:45 08:15 0.50 COMPZ RPEQP1 NUND T Rig up to remove fillup line w/ main winch and counter balance. Page 20 of 48 • • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T < : Comment 08:15 09:30 1.25 COMPZ RPEQP1 SFTY T Standby for helicopter to land and depart. 09:30 10:30 1.00 COMPZ RPEQPI NUND T Lower fillup line to deck using both counterbalnace lines, main winch and the manitowoc crane. 10:30 11:30 1.00 COMPZ RPEQP1NUND T Break nuts from bottom of Patterson's Shaffer Annular (ser# P24314) to be removed from the substructure. 11:30 12:00 0.50 COMPZ RPEQP1 SFTY T Hold PJSM for removing Hydril from BOP stack. Weather died down to 9 mph winds. 12:00 12:30 0.50 COMPZ RPEQP1 RGRP T Change out hoses on the LOOMIS _tongs. 12:30 13:00 0.50 COMPZ RPEQP1NUND T Make up 5 -1/2" joints to lifting eye. 13:00 14:30 1.50 COMPZ RPEQP1NUND T Finish unbolting the annular, set on BOP trolley beams, then transfer to the Manitowoc crane. Place the 11" annular on the deck, gather materials to ship out on evening boat. (Notice sent to Jim Regg that BOP testing will resume tomorrow). 14:30 15:00 0.50 COMPZ RPEQP1NUND T Remove connections from the annular. Plug connection ports for transport. 15:00 19:00 4.00 COMPZ RPCOM OTHR T Cleaning deck, breaking crossovers, servicing equipment. 19:00 04:00 9.00 COMPZ RPEQP1OTHR T Grease /service valves on pump and choke manifold, checking equipment while waiting on 11" annular (Rental f/ Weatherford) to arrive on boat. 11/18/2010 Held Pre -Tour Meeting. Review & discuss JSA. Offload and back haul boat. PJSM. Prepare Hydril annular (Weatherford Rental ser # ER1 -108), nipple up 11" 5k annular. Prep 5 -1/2" test joint. While functioning the annular, another fitting on the accumulator broke, spilling a gallon of hyd fluid. Clean up spill. PJSM. Function tested annular with CUDD hyd system- good. Rig up heaters on the top deck. Trouble shoot pressure sensor on the accumulator, repair same. Wrap stack w/ tarps and placed heater trunk in area. Noticed milky oil in the accumulator, drained oil from the accumulator and hoses. Add new hydraulic oil and re- presssuring system to 3000 psi. 00:00 00:30 0.50 MIRU RPEQP1SFTY P Held Pre -Tour Meeting. Review & discuss JSA. 00:30 01:30 1.00 MIRU RPCOM OTHR T Checking equipment while waiting on 11" annular (Rental f/ Weatherford) to arrive on boat. 01:30 01:45 0.25 MIRU RPEQP1SFTY T PJSM for Offloading Boat, backload boat. 01:45 03:00 1.25 MIRU RPEQP1OTHR P Offload Boat, backload boat. 03:00 03:15 0.25 MIRU RPEQP1SFTY T PJSM on nipple up BOPE. 03:15 04:45 1.50 MIRU RPEQP1 NUND T Nipple up BOPE- preparing annular while on the deck. 04:45 05:00 0.25 COMPZ RPEQP1SFTY T PJSM on installing annular. 05:00 08:45 3.75 COMPZ RPEQP1NUND T Install Annular. Torque bolts. 08:45 10:30 1.75 COMPZ RPEQP1 RURD T Prepare 5 -1/2" test joint. Page 21 of 48 • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 10:30 12:00 1.50 COMPZ RPEQP1 RURD T Stroke Koomey to pressure up Annular. Hydraulic fitting failed down stream of the pump causing a one gallon spill. Found pressure regulator switch was bad, Clean up oil spill. 12:00 12:30 0.50 COMPZ RPEQP1SFTY P Held Pre -Tour Meeting. Review & discuss JSA. 12:30 13:30 1.00 COMPZ RPEQP1RURD T Attached hydraulics from CUDD hydraulic unit to function the annular. Pressure held in the open and closed position ok. 13:30 14:30 1.00 COMPZ RPEQP1RURD T Rig up heaters on the deck. 14:30 16:45 2.25 COMPZ RIGMNT RGRP T Pulled the pressure sensor off the Koomey unit. Sensor was stuck, pulled sensor apart, then cleaned up with emery paper. 16:45 18:45 2.00 COMPZ RPEQP1 RURD T Wrap stack with tarps, place a heater in the area to keep stack warm. 18:45 22:00 3.25 COMPZ RIGMNT RGRP T Noticed that the oil in the Koomey unit was milky. Bleed down system and drain all oil in Koomey unit and lines. 22:00 00:00 2.00 COMPZ RIGMNT RGRP T Add new hydraulic oil (ISO 46) to the Koomey unit. Pressure sustem to 3000 psi. 11/19/2010 Held Pre -Tour Meeting. Review & discuss JSA. Add new hydraulic oil and represssuring accumulator system to 3000 psi. Install bell nipple, RU to test w/ 5 -1/2" test joint. Replace 4 way valve f/ annular function. Clear ice plug in standpipe, Test annular to 250 psi low and 3500 psi high, hold each test 5 minutes. Note: two spills: one 3 gallons KCL, one 1 gallon hyd oil. 00:00 00:30 0.50 MIRU RPEQP1 SFTY P Held Pre -Tour Meeting. Review & discuss JSA. 00:30 03:15 2.75 MIRU RIGMNT RGRP T Pump fluid from hydraulic power pack into clean drums. Adding Cheveron Clarity ISO 46 hydraulic oil to the Koomey unit. 03:15 03:30 0.25 MIRU RIGMNT RGRP T Bleed system to zero, check that tank will not run over with side plugs installed- OK. Repressure Koomey system to 3000 psi. Adjust KR valve f/ 1500 psi manifold pressure. 03:30 05:00 1.50 MIRU RPEQP1 RURD T Rig up to test BOPE w/ 5 -1/2" test joint. 05:00 07:00 2.00 MIRU RIGMNT RGRP T Attempt to function 4 -way Barksdale valve to acuate annular. Valve was bypassing fluid. Replaced the rebuilt valve with a new valve. 07:00 08:00 1.00 MIRU RIGMNT RGRP T Function the new 4 -way valve. All OK. 08:00 09:00 1.00 MIRU RPEQP1 OTHR T Attempt to fill hole, pumping thru standpipe. Standpipe hose had a ice plug. Work to remove ice plug, blow down with air. 09:00 10:30 1.50 MIRU RPEQP1 CIRC T Fill stack w/ 6% KCL to test the annular w/ 5 -1/2" test joint. Page22of48 Time Logs • • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 10:30 11:00 0.50 MIRU RPEQP1 BOPE T Perform low test to 250 psi, held 5 minutes- good test. Increased to 3500 psi, leaking off. 11:00 11:30 0.50 MIRU RIGMNT RGRP T Bleed off pressure. Greased all valves on the pump manifold. 11:30 12:00 0.50 MIRU RPEQP1BOPE T Fill stack again, pressured up to 2000 psi, noticed fluid leaking by the annular. 12:00 12:30 0.50 MIRU RPEQP1SFTY P Held Pre -Tour Meeting. Review & discuss JSA. 12:30 13:00 0.50 MIRU RPEQP1BOPE T Tested annular to 250 psi low -good, continue to 3500 psi, noticed leaking by the annular. 13:00 13:30 0.50 MIRU RPEQP1OTHR T Bleed off pressure, blow down lines with air. 13:30 14:00 0.50 MIRU RPEQP1 RURD T Lay down 5 -1/2" test joint. 14:00 15:00 1.00 MIRU RPEQP1NUND T Install mud cross with flow line, on top of the annular. 15:00 15:45 0.75 MIRU RPEQP1 RURD T PU /MU 5 -1/2" test joint. Screw into _ Vetco Gray blanking plug. 15:45 16:00 0.25 COMPZ RPEQP1CIRC T Fill hole w/ 6% KCL. 16:00 19:00 3.00 COMPZ RPEQP1BOPE T Pressure test annular. Good test to 250 psi low, not a good test @ 3500 psi. Bleed off pressure. Add more tarps and heat to the stack. 19:00 19:15 0.25 COMPZ RPEQP1OTHR T Blow down lines w/ air. 19:15 19:30 0.25 COMPZ RPEQP1BOPE T Function annular, opening and closing. 19:30 19:45 0.25 COMPZ RPEQP1CIRC T Fill hole with 6% KCL. Had a 3 gallon spill on the deck from flow line. Flow paddle was not installed. 19:45 20:45 1.00 COMPZ RPEQP1 BOPE T Started testing annular again, 250 psi low- ok. 3500 psi not holding, increased pressure to 1250 psi on hydraulics. Reprerssured to 3500 psi a few times, still noticed the pressure leaking off. Discovered that the lower flange of the annular had a leak. 20:45 22:15 1.50 COMPZ RPEQP1 NUND T Bleed off pressure. Re- torque bolts below annular. Some bolts were loose. 22:15 22:30 0.25 COMPZ RPEQP1 RURD T Install flow paddle in the flow line. 22:30 22:45 0.25 COMPZ RPEQP1CIRC T Fill hole w/ 6% KCL 22:45 23:15 0.50 COMPZ RPEQP1BOPE T Test annular w/ 5 -1/2" test joint. Test to 250 psi low, then 3500 psi high. Held each test 5 minutes. Both good tests. 23:15 00:00 0.75 COMPZ RPEQP1OTHR T Bleed pressure to zero, close top pipe rams, open annular. While Koomey pump was running, fitting off the side of the pump failed. Spill of 1 gallon of hydraulic oil into secondary containment (Building the kommey unit is in. Clean up oil. Page 23 of 48 Time Logs • • Date From To . Dur S. Depth E. Depth Phase Code Subcode T Comment 11/20/2010 24 hr Summary Held Pre -Tour Meeting. Review & discuss JSA. Fix broke fittings on Koomey pump, test top pipe rams to 250 psi low and 3500 psi high- held each test 5 minutes. Witness of tests waived by AOGCC inspector Bob Noble. Function test accumulator- OK. Change out test joint f/ 5 -1/2" to 2 -7/8 ". Test annular to 250 psi low- good test, while trying to test to 3500 psi, leaking by the element -not a good test. Trouble shoot, blow down lines, nipple down mud cross w/ flow line, then nipple down the 11" 5k Hydril (Rental f/ Weatherford ser # ER1 -108), load on boat. Servicing CUDD equipment and making tarps out of herculite to make rig more environmentally friendly while waiting on repairs to a Annular. 00:00 00:30 0.50 MIRU RPEQPI SFTY P Held Pre -Tour Meeting. Review & discuss JSA. 00:30 01:30 1.00 MIRU RIGMNT RGRP T Install a 5000 psi hose in place of where solid fittings had been used on the Koomey pump in the accumulator room. Add hydraulic oil to Hydraulic power pack. Blow down circulating lines. 01:30 02:15 0.75 MIRU RIGMNT RGRP T Function testing accumulator unit to ensure it fuctions properly. 02:15 03:15 1.00 MIRU RPEQP1CIRC T Fill lines and hole, prep to test top pipe rams (5 -1/2 ") with 5 -1/2" test joint. 03:15 03:45 0.50 MIRU RPEQP1BOPE P Pressure test upper pipe rams (5 -1/2 ") to 250 psi low, hold f/ 5 minutes. Good test. Note: Witness of BOPE tests waived by AOGCC inspector Bob Noble. 03:45 04:15 0.50 MIRU RPEQP1 BOPE P Pressure test upper pipe rams (5 -1/2 ") to 3500 psi high, hold f/ 5 minutes. Good test. 04:15 05:00 0.75 MIRU RPEQP1BOPE P Perform Koomey test. Initial system pressure 3100 psi, manifold pressure 1500 psi, annular 1250 psi. Operate top pipe rams (closed- open - close) to simulate functioning 3 sets of rams. Operate HCR on both the kill and choke line. Close the annular. System pressure after closure 1800 psi. 200 psi build up in 10 seconds with just the diesel engine. After 200 psi build up, start air pumps as well. Total system pressure achieved in 3 minutes 5 seconds (system pressure 3000 psi, manifold pressure 1500 psi). 05:00 05:30 0.50 MIRU RPEQP1BOPE T Blow down lines, prep to change out test joints. 05:30 06:30 1.00 COMPZ RPEQP1BOPE T Pull the 5 -1/2" test joint and lay down same. 06:30 08:15 1.75 COMPZ RPEQP1BOPE T Breaking crossovers, then make up 2 -7/8" test joint. 08:15 09:00 0.75 COMPZ RPEQP1 BOPE T Run in the hole w/ 2 -7/8" test joint. Page 24 of 48 Time Logs • • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 09:00 11:00 2.00 COMPZ RPEQPI BOPE T Test the annular w/ the 2 -7/8" test joint. Test to 250 psi low, hold f/ 5 minutes- good. While increasing pressure f/ the high test, fluid started bypassing while at 1500 psi. Increased annular closing pressure to 1500 psi, still leaking by the element and test joint. 11:00 12:00 1.00 COMPZ RPEQP1OTHR T Drained the stack to check the element. 12:00 12:30 0.50 COMPZ RPEQP1SFTY P Held Pre -Tour Meeting. Review & discuss JSA. 12:30 13:00 0.50 COMPZ RPEQP1OTHR T Blow down circulating lines w/ air. 13:00 14:00 1.00 COMPZ RPEQP1PULD T Lay down the 2 -7/8" test joint. 14:00 17:00 3.00 COMPZ RPEQP1 NUND T Nipple down mud cross on top of annular, nipple down Hydril 11" 5k annular (Rental f/ Weatherford ser # ER1 -108). Transfer the Hydril to trolley beams, slide out to edge of sub, connect Manitowoc crane to lower to the deck. 17:00 17:30 0.50 COMPZ RPEQPI OTHR T Load 11" 5k Hydril on boat (Rental f/ Weatherford ser # ER1 -108). 17:30 00:00 6.50 COMPZ RIGMNT SVRG T Servicing CUDD equipment and making tarps out of herculite to make rig more environmentally friendly while waiting on repairs to a Annular. 11/21/2010 Held Pre -Tour Meeting. Review & discuss JSA. Servicing CUDD equipment and making tarps out of herculite to make rig more environmentally friendly while waiting on repairs to a Annular. Housekeeping. 00:00 00:30 0.50 COMPZ RIGMNT SFTY P Held Pre -Tour Meeting. Review & discuss JSA. 00:30 12:00 11.50 COMPZ RIGMNT RGRP T Servicing CUDD equipment and making tarps out of herculite to make rig more environmentally friendly while waiting on repairs to a Annular. Hanging tarps around jack and koomey hoses. Cleaning deck, checking hydraulic connections on power packs. 12:00 12:30 0.50 COMPZ RIGMNT SFTY P Held Pre -Tour Meeting. Review & discuss JSA. 12:30 00:00 11.50 COMPZ RIGMNT RGRP T Servicing CUDD equipment and making tarps out of herculite to make rig more environmentally friendly while waiting on repairs to a Annular. Wipe down drip pans and koomey unit. Break TIWs and IBOP. Run 2" hose to injection well. Page 25 of 48 Time Logs • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 11/22/2010 24 hr summary Held Pre -Tour Meeting. Review & discuss JSA. Servicing CUDD equipment, housekeeping while waiting on 11" 5k annular repairs. Held weekly safety meeting w/ night crew, continue w/ housekeeping. PJSM w/ day crew, MASSCO rep serviced accumulator- changed pressure switch in area of pump where fittings were breaking, adjusted system and manifold pressure. Offload CUDD (Shaffer Annular ser # P24314) and 2 Magtec heaters. Prepare to bring 3 people on board, but because of ice and crane icing, decision to not bring on board. PJSM. Lifted Shaffer annular with crane, transferred to CUDD trolley, installed herculite in the back of structure, ran more heater trunks into structure. Nipple up Annular and mud cross w/ flow line on top. MASSCO rep changing out leaking air pressure switch on accumulator. MU flow line to trip tank. PU /MU 2 -7/8" test joint. 00:00 00:30 0.50 COMPZ RIGMNT SFTY P Held Pre -Tour Meeting. Review & discuss JSA. 00:30 07:00 6.50 COMPZ RIGMNT RGRP T Servicing CUDD equipment, houskeeping while waiting on 11" 5k annular repair. Wipe up oil in Koomey building, clean dog house. 07:00 08:00 1.00 COMPZ RIGMNT SFTY P Held weekly safety meeting with night crew. 08:00 12:00 4.00 COMPZ RIGMNT RGRP T Houskeeping while waiting on 11" 5k annular repair. Pick up tools, put spare equip in connex, add tarps to cover koomey hoses under substructure. Locate crossovers f/ TIWs on the work strings. 12:00 12:30 0.50 COMPZ RIGMNT SFTY P Held Pre -Tour Meeting. Review & discuss JSA. 12:30 14:30 2.00 COMPZ RIGMNT RGRP T MASSCO rep changes out primer pressure switch on Koomey unit, adjusted system pressure to 3000 psi. 14:30 15:45 1.25 COMPZ RIGMNT RGRP T Manifold pressure 1400 psi, system pressure 2950 psi. 15:45 16:30 0.75 COMPZ RIGMNT OTHR T Off load boat CUDD (Shaffer Annular ser # P24314) and 2 Magtec heaters. Was prepared to bring 3 people on board, but because of ice and crane icing, decision to not bring on board. 16:30 18:30 2.00 COMPZ RIGMNT RURD T PJSM. Lifted Shaffer annular with crane, transferred to CUDD trolley, installed herculite in the back of structure, ran more heater trunks into structure. 18:30 00:00 5.50 COMPZ RIGMNT NUND T Nipple up Shaffer Annular and mud cross f/ flow line. Install flow line to trip tank. Install Totco flow line paddle. Put tarps around BOP stack. MASSCO rep replace leaking prerssure switch f/ Koomey air pumps. Make up 2 -7/8" test joint. 11/23/2010 Held Pre -Tour Meeting. Review & discuss JSA. Repairs to accumulator unit, testing annular w/ 2 -7/8" and 3 -1/2" test joints. Tested to 250 psi low and 3500 psi high, held each test f/ 5 minutes. Witness of test waived by AOGCC inspector Bob Noble. Cross threaded 5 -1/2" test joint while making up same. Replace 40' joint and remove collar and install on 5 -1/2" test joint. Check pre charge on all 12 bottles on the accumulator. Check discharge strainers, check valves on triplex pump of accumulator. 00:00 00:30 0.50 MIRU RIGMNT SFTY P Held Pre -Tour Meeting. Review & discuss JSA. Page 26 of 48 a � Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 00:30 06:00 5.50 MIRU RIGMNT RGRP T Put tarps around BOP stack. MASSCO rep replace leaking pressure switch f/ Koomey air pumps, rebuild (2) 4 way valves. Function BOP accumulator unit. Make up 2 -7/8" test joint. 06:00 06:45 0.75 MIRU RIGMNT BOPE T Perform Koomey test with 2 -7/8" test joint in the hole. Initial system pressure 2950 psi, manifold pressure 1500 psi, annular 825 psi. Operate lower pipe rams (closed- open - close) to simulate functioning 3 sets of rams. Operate HCR on both the kill and choke line. Close the annular. System pressure after closure 1500 psi. 200 psi build up in 6 seconds with just the diesel engine. After 200 psi build up, start air pumps as well. Total system pressure achieved in 4 minutes 17 seconds (system pressure 3000 psi, manifold pressure 1450 psi). Witness of BOP test waived by AOGCC inspector Bob Noble. 06:45 09:30 2.75 MIRU RIGMNT RGRP T System pressure kept decreasing on Koomey unit. Checked f/ any leaks on hoses- OK. Change out 1" check valve on triplex pump discharge. Change out one 1/2" check valve of two on the air pumps. 09:30 10:00 0.50 MIRU RIGMNT RGRP T Pressure up the Koomey unit. Pressures did not look to be falling off. Increased system pressure to 3200 psi. 10:00 10:30 0.50 MIRU RIGMNT BOPE T Perform Accumulator test. Total time of 5 minutes 32 seconds. Put MASSCO rep to sleep. 10:30 12:00 1.50 COMPZ RIGMNT BOPE T Filled stack. Test Annular w/ 2 -7/8" test joint to 250 psi low, then 3500 psi high. Both good tests. Held each test 5 minutes. Drain stack, pull test joint. Witness of test waived by AOGCC inspector Bob Noble. 12:00 12:30 0.50 COMPZ RIGMNISFTY P Held Pre -Tour Meeting. Review & discuss JSA. 12:30 14:00 1.50 COMPZ RIGMNT PULD T Break and lay down 2 -7/8" test joint. 14:00 15:30 1.50 COMPZ RIGMNT PULD T MU 3 -1/2" test joint. Install 3 -1/2" TIW on top of test joints to be tested. 15:30 15:45 0.25 COMPZ RIGMNT BOPE T Filled stack, then test annular, pressured to 250 psi low- good. While increasing to 3500, noticed annular pressure decreasing at the Koomey unit. No test, bleed off pressure. Page 27 of 48 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 15:45 16:30 0.75 COMPZ RIGMNT BOPE T Test Annular w/ 3 -1/2" to 250 psi low -good, Increase pressure to 3500 psi- good test. Held each test f/ 5 minutes. Witness of test waived by AOGCC inspector Bob Noble. 16:30 17:30 1.00 COMPZ RIGMNT RGRP T Bleed pressure to zero. blow down lines w/ air. Noticed a leak on the hydraulic power pack from a snap tite fitting. Changed both male and female fittings. 17:30 19:00 1.50 COMPZ RIGMNT PULD T Lay down 3 -1/2" test joint. 19:00 20:00 1.00 COMPZ RIGMNT PULD T Make up 5 -1/2" test joint. 20:00 23:00 3.00 COMPZ RIGMNT RGRP T Cross threaded 5 -1/2" test joint. Lay down test joint. Break collars and crossovers off the bad 40' joint (Pin end was crossed). Remove the collar from the test joint w/ ported hole (Box was crossed), installed the collar which was removed from the 40' joint. Used our spare 40' joint. Check precharge pressure on all 12 bottles in the accumulator. Made sure all bottles were 1000 psi. Only one bottle was really low (550 psi), all others were 800 to 950 psi. 23:00 00:00 1.00 COMPZ RIGMNT RGRP T Make up 5 -1/2" test joint. Checked both high pressure strainers on accumulator- they were good. Checking triplex pump valves and seats. 11/24/2010 Held PJSM, discuss JSA. Repairs to accumulator unit, testing annular w/ 5 -1/2 test joint. Tested to 250 psi low and 3500 psi high, held each test f/ 5 minutes. Witness of test waived by AOGCC inspector Bob Noble. Attempt to test accumulator- no good. Waiting on parts f/ accumulator. Clean deck, break crossovers, re- orient mud cross so flow line pointed to trip tank, torque bolts. Total Safety testing gas alarms (LEL & H2S). TOTCO working on pump pressure, pump strokes, and flow line sensor. CUDD crew preparing for accumulator repairs- break connections to remove both regulator valves, prep to remove /replace triplex pump on accumulator. Waiting on accumulator parts. 00:00 00:30 0.50 MIRU RIGMNT SFTY P Held Pre -Tour Meeting. Review & discuss JSA. 00:30 02:00 1.50 MIRU RIGMNT RGRP T Make up 5 -1/2" test joint. Checking accumulator triplex pump valves and seats. 02:00 03:00 1.00 MIRU RIGMNT BOPE T Test Annular w/ 5 -1/2" test joint to 250 psi low -good, Increase pressure to 3500 psi- good test. Held each test f/ 5 minutes. Witness of test waived by AOGCC inspector Bob Noble. Page 28 of 48 Time Logs • • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 03:00 03:30 0.50 COMPZ RIGMNT BOPE T Attempt to perform Accumulator test. Initial system pressure 3000 psi, manifold pressure 1500 psi, annular 950 psi. Operate top pipe rams (5 -1/2 ") (closed- open - close) to simulate functioning 3 sets of rams. Operate HCR on both the kill and choke line. Close the annular. System pressure after closure 1500 psi. 200 psi build up in 6 seconds with just the diesel engine. After 200 psi build up, start air pumps as well. After 7 minutes, aborted test- - system pressure was 2600 psi, KR valve not fuctioning correctly (manifold pressure 2200). 03:30 08:00 4.50 COMPZ RIGMNT OTHR T Waiting on parts f/ the accumulator. Clean deck. Break crossovers for the TIW valves. Pumping water off the deck. 08:00 12:00 4.00 COMPZ RIGMNT OTHR T Waiting on parts f/ the accumulator. Re oriented mud cross on top off annular to arrange flow line towards trip tank. Install bolts and torque same. 12:00 12:30 0.50 COMPZ RIGMNT SFTY P Held Pre -Tour Meeting. Review & discuss JSA. 12:30 13:00 0.50 COMPZ RPEQP1 BOPE P Total Safety testing H2S and LEL alarms. Waiting on accumulator parts. 13:00 14:00 1.00 COMPZ RIGMNT RURD T Continue to tighten mud cross. Remove flow line sensor. Waiting on accumulator parts. 14:00 14:30 0.50 COMPZ RIGMN1 RURD T TOTCO install new flow line sensor. Waiting on accumulator parts. 14:30 21:00 6.50 COMPZ RIGMNT SEQP T TOTCO Testing flow meter, added a larger paddle, continue to work issues with flow line sensor. Flow sensor not working down to 1/4 bbl flow out. Waiting on accumulator parts. 21:00 22:00 1.00 COMPZ RIGMNT SEQP T Pressure up circulation manifold to 3500 psi to test TOTCO pressure sensors. Pressure reading OK. Waiting on accumulator parts. 22:00 22:30 0.50 COMPZ RIGMNT OTHR T Start other CUDD mud pump. Waiting on accumulator parts. 22:30 00:00 1.50 COMPZ RIGMN1 SEQP T TOTCO checking pump pressure sensors, SPM, total strokes on mud pump by pit room. Waiting on accumulator parts. 11/25/2010 Held PJSM, discuss JSA. Waiting on accumulator parts. TOTCO servicing pump strokes, flow, pump pressure and monitor in the basket. Cleaning deck. 00:00 00:30 0.50 COMPZ RIGMNT SFTY P Held Pre -Tour Meeting. Review & discuss JSA. Page 29 of 48 Time Logs • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 00:30 08:00 7.50 COMPZ RIGMNT SEQP T TOTCO checking pump pressure sensors, SPM, total strokes on mud pump by pit room. Waiting on accumulator parts. 08:00 12:00 4.00 COMPZ RIGMNT RGRP T Repair air leak on ther CUDD pump f/ injection. Cleaning the deck, pumped out the trip tank. Waiting on accumulator parts. 12:00 12:30 0.50 COMPZ RIGMNT SFTY P Held Pre -Tour Meeting. Review & discuss JSA. 12:30 13:30 1.00 COMPZ RIGMNT OTHR T Waiting on accumulator parts. Service equipment 13:30 15:30 2.00 COMPZ RIGMNT OTHR T Waiting on accumulator parts. Sucking up water off the deck. 15:30 00:00 8.50 COMPZ RIGMNT OTHR T Waiting on accumulator parts. _ Cleaning the deck. 11/26/2010 Held PJSM, discuss JSA. Waiting on accumulator parts. Work on accumulator: Change both regulators, triplex pump, pressure switch f/ triplex, two check valves on air pumps. Checking accumulator and hoses f/ leaks. BOP testing, witness of test waived by AOGCC inspector Bob Noble -- Testing Accumulator: System pressure 3000 psi. Closed annular, top pipe rams (5 -1/2 ") were closed- opened- then closed. Kill and choke line HCR's were actuated. System pressure went to 1600 psi. Nitrogen precharge in 12 bottles was 1000 psi. Turned on diesel driven pump- took 8 seconds f/ 200 psi build up, then turned on both air driven pumps. Full system pressure (3000 psi) was achieved in 176 seconds. Remove tools from Accumulator house. System is ready for use. BOP test completed 2330 hrs 11/26/2010. 00:00 00:30 0.50 MIRU RIGMNTSFTY P Held Pre -Tour Meeting. Review & discuss JSA. 00:30 01:30 1.00 MIRU RIGMNT OTHR T Waiting on accumulator parts. Service equipment. 01:30 08:00 6.50 MIRU RIGMNT OTHR T Waiting on accumulator parts. Service equipment. 08:00 10:00 2.00 MIRU RIGMNT RGRP T Repair parts on location. Change out both regulators on the accumulator and the triplex pump. 10:00 12:00 2.00 COMPZ RIGMNT RGRP T Function test accumulator, adjust regulators. Change out the pressure switch for the tripex pump. 12:00 12:30 0.50 COMPZ RIGMNT SFTY P Held Pre -Tour Meeting. Review & discuss JSA. 12:30 13:00 0.50 COMPZ RIGMNT RGRP T Service equipment. Continue changing out pressure switch f/ diesel driven triplex pump. 13:00 14:00 1.00 COMPZ RIGMN1OTHR T Blow down lines from CUDD pump. 14:00 18:30 4.50 COMPZ RIGMN1 RGRP T Adjust pressure switch f/ triplex, rebuild a check valve on one of two air pumps, install rebuilt check valve. Trouble shoot system pressure leaking down. 18:30 19:30 1.00 COMPZ RIGMNT RGRP T Trouble shooting. Unplug hoses on the back of the accumulator house. With hoses unplugged, system pressure holds. 19:30 20:30 1.00 COMPZ RIGMN1 RGRP T Trouble shooting. Connect hoses on the back of the accumulator house. Wrap all connections w/ absorb to help identify any leaks. Page 30 of 48 Time Logs • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 20:30 21:00 0.50 COMPZ RIGMNT BOPE T Testing Accumulator- witness of test waived by AOGCC inspector Bob Noble: System pressure 3000 psi. Manifold pressure 1500 psi. Annular 600 psi. Closed annular, top pipe rams (5 -1/2 ") were closed- opened- then closed. Kill and choke line HCR's were actuated. System pressure went to 1600 psi. Nitrogen precharge in 12 bottles was 1000 psi. Turned on diesel driven pump - took 7 seconds f/ 200 psi build up, then turned on both air driven pumps. Full system pressure (3000 psi) was achieved in 181 seconds. 21:00 22:00 1.00 COMPZ RIGMN1 RGRP T Pressure on system bleed down to 2850 psi. Bleed off to zero and install two new check valves on the air pumps. 22:00 23:00 1.00 COMPZ RIGMNT BOPE T Testing Accumulator, witness of test waived by AOGCC inspector Bob Noble: System pressure 3000 psi. Manifold pressure 1500 psi. Annular 600 psi. Closed annular, top pipe rams (5 -1/2 ") were closed- opened - then closed. Kill and choke line HCR's were actuated. System pressure went to 1600 psi. Nitrogen precharge in 12 bottles was 1000 psi. Turned on diesel driven pump - took 7 seconds f/ 200 psi build up, then turned on both air driven pumps. Full system pressure (3000 psi) was achieved in 184 seconds. 23:00 00:00 1.00 COMPZ RIGMN1 BOPE T Testing Accumulator - Witness of test waived by AOGCC inspector Bob Noble.: System pressure 3000 psi. Closed annular, top pipe rams (5 -1/2 ") were closed- opened- then closed. Kill and choke line HCR's were actuated. System pressure went to 1600 psi. Nitrogen precharge in 12 bottles was 1000 psi. Turned on diesel driven pump- took 8 seconds f/ 200 psi build up, then turned on both air driven pumps. Full system pressure (3000 psi) was achieved in 176 seconds. Remove tools from Accumulator house. System is ready for use. 11/27/2010 Held PJSM, discuss JSA. Pull the VETCO blanking plug, pull BPV, NU shooting flange & Pollard Wireline lubricator, test to 2000 psi. Pollard pull prong f/ "PX" plug @ 4269' (Kuukpick 5 RKB), Change tool string to 5 -1/2" GS, RIH, fluid level fell to 1110' and stabilized. Apply gas lift gas assist to drive fluid down, monitor fluid levels, not much change. RIH w/ 1 -1/2" pump bailer on wireline, POOH, flapper failed to hold- did recover small sliver of a seal. Run # 2- same bailer with different flapper, POOH, blinds closed bleeding off pressure at midnight. Note: Recovered more rubber and some scale. Page 31 of 48 Time Logs • • Date From To Dur S. Depth E. Depth Phase Code - Subcode T Comment 00:00 00:30 0.50 MIRU RPEQPI SFTY P Held Pre -Tour Meeting. Review & discuss JSA. 00:30 01:30 1.00 MIRU WELCTL OTHR P Back out VETCO GRAY blanking plug w/ 5 -1/2" test joint. Lay down test joint. 01:30 02:00 0.50 MIRU WELCTL OTHR P PU "T" bar to pull the 5" Type "H" BPV. Back out BPV. Lay down "T' bar. 02:00 03:30 1.50 MIRU WELCTL NUND P Nipple up Weatherford Rental shooting flange on top of mud cross above the annular. Shooting flange consists of 11" 5k x 13 -5/8" 5k spool and 13 -5/8" x 7" BTC box flange.Torque bolts with torque wrench. 03:30 04:00 0.50 MIRU WELCTL SFTY P Held PJSM w/ Pollard, CUDD, and MI Swaco. Safety meeting on rigging up lubricator and WL BOP. 04:00 07:30 3.50 MIRU RPEQP1 RURD P Rig up Pollard wireline lubricator and tool string to pull "PX" prong. Tool string consists of: rope socket, knuckle joint, stem, stem, knuckle joint, oil jar, spang, knuckle joint. 07:30 08:00 0.50 MIRU WELCTL SEQP P Fill stack and Pollard lubricator w/ 6% filtered KCL. Test to 2000 psi against blind rams- OK. 08:00 09:15 1.25 MIRU RPEQP1SLKL P Run in w/ Pollard Wireline tool string to pull Prong f/ "PX" plug @ 4269' RKB. Latch prong, jar up and pull prong. Pull out of hole. Well is on a vacuum. 09:15 10:00 0.75 MIRU RPEQP1SLKL P With blind rams shut. Change Pollard Wireline tool string to pull the Plug body. 10:00 12:00 2.00 MIRU RPEQP1SLKL P Run in the hole with toolstring and 5 -1/2" GS to fluid level @ 640'. Wait for well to equalize before pulling plug. 12:00 12:30 0.50 MIRU RPEQP1SFTY P Held Pre -Tour Meeting. Review & discuss JSA. 12:30 14:15 1.75 MIRU RPEQP1SVRG P Service CUDD equipment while allowing fluid to equalize. 14:15 14:45 0.50 COMPZ RPEQPI OTHR P Fluid level falling slowly. Rig up to apply lift gas to assist with equalization of fluid. Fluid level @ 1135'. Connect a 1/2" line from platform lift gas to wire line lubricator. Test line to 900 psi. 14:45 15:30 0.75 COMPZ RPEQP1OTHR P Begin lift gas to help drop fluid level in the tubing. Pressured up to 450 psi w/ gas. Fluid level @ 1135'. 15:30 15:45 0.25 COMPZ RPEQP1OTHR P Monitor fluid level @ 1765'. Tubing pressure 450 psi. 15:45 16:00 0.25 COMPZ RPEQPI OTHR P Monitor fluid level @ 2025'. Tubing pressure 600 psi. Pull tool string up to 500'. Page 32 of 48 Time Logs • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 16:00 16:45 0.75 COMPZ RPEQP1OTHR P Apply lift gas on the annulus to allow annulus fluid level to drop as well as the tubing fluid level. Apply 600 psi on annulus. 16:45 18:30 1.75 COMPZ RPEQP1OTHR P Monitor fluid level @ 1110' RKB. Tubing pressure 700 psi. Tbg x csg annulus 700 psi. 18:30 19:00 0.50 COMPZ RPEQP1OTHR P Monitor fluid level @ 1110' RKB- fluid not dropping. Shut off gas, tubing pressure 840 psi. Tbg x csg annulus 840 psi. 19:00 19:45 0.75 COMPZ RPEQP1OTHR P Pressure holding 840 psi. Begin bleeding off gas on both the tubing and csg x tubing annulus. 19:45 21:45 2.00 COMPZ RPEQP1OTHR P Monitor fluid level @ 1110' RKB. Tubing pressure 550 psi. Tbg x csg annulus 550 psi. Stopped bleeding off pressure. 21:45 23:15 1.50 COMPZ RPEQP1BAIL P Pollard Wireline RIH w/ tool string and 1.5" OD pump bailer to 4269' KB. Work tools. Pull out of the hole. Lost material in the bailer. Did recover a sliver of a rubber seal, might have held open flapper. 23:15 00:00 0.75 COMPZ RPEQP1BAIL P Pollard Wireline RIH w/ tool string and 1.5" OD pump bailer to 4269' KB. Work tools. Pull out of the hole. Blind rams closed at midnight. Bleeding of rpessure on the lubricator. 11/28/2010 Held PJSM, discuss JSA. Blinds closed bleed off Pollard lubricator. Lay down pollard crew. Pressure tubing to 820 psi, annulus to 580 psi. Monitor pressures- no change. Tested scale from bailer run #2 w/ HCL acid, continue monitoring pressure- no change. PJSM on working w/ 12% HCL acid. Pollard make two runs, dump approx 3 gallons of 12% HCL acid each time at the "PX" plug body @ 4270' RKB. No changes in tubing pressure. Revise plan forward. PJSM, Bleed off tubing and annulus pressure to zero. Rig up to fill hole and circ 6% KCL. 00:00 00:30 0.50 MIRU RPEQP1SFTY P Held Pre -Tour Meeting. Review & discuss JSA. 00:30 01:00 0.50 MIRU RPEQP1BAIL P Pollard Wireline out of the hole w/ 1.5" OD pump bailer- run #2. Blind rams closed. Bleeding of pressure on the lubricator. 01:00 02:00 1.00 MIRU RPEQP1OTHR P Lay down the Pollard slickline crew. Monitor pressure on tubing and casing- 420 psi each. 02:00 04:00 2.00 MIRU RPEQPI OTHR T Pressure tubing up to 820 psi with lift gas. 9 -5/8" x 5 -1/2" annulus is 580 psi. 04:00 12:00 8.00 MIRU RPEQP1OTHR T Monitor pressure every 30 minutes. Stayed at 820/580 psi. Break crossovers off test joints. Test the scale out of bailer run #2 to see if 15% HCL acid would dissolve. Confirmed. 12:00 12:30 0.50 MIRU RPEQP1SFTY P Held Pre -Tour Meeting. Review & discuss JSA. Page 33 of 48 • • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 12:30 12:45 0.25 MIRU RPEQP1SFTY T Held PJSM on working w/ 15% HCL acid. 12:45 13:00 0.25 MIRU RPEQP1 SVRG P Service CUDD equipment. 13:00 14:00 1.00 MIRU RPEQP1SLKL T Pollard wire line make up 11' x 2 -1/4" dump bailer. 14:00 15:00 1.00 COMPZ RPEQP1SLKL T Fill bailer w/ approx 3 gallons of 12% HCL acid, in the work window. 15:00 15:45 0.75 COMPZ RPEQP1SLKL T Open blind rams, Pollard RIH w/ 2 -1/4" bailer to "PX" plug body @ 4270' RKB. SITP 840 psi. Dump acid, POOH. 15:45 16:00 0.25 COMPZ RPEQP1SLKL T Close blind rams. Bleed off lubricator to production. 16:00 16:45 0.75 COMPZ RPEQP1SLKL T Redress bailer. Fill bailer w/ approx 3 gallons of 12% HCL acid, in the work window. 16:45 17:00 0.25 COMPZ RPEQP1SLKL T Equalize lubricator to 850 psi, open blinds. 17:00 17:45 0.75 COMPZ RPEQP1SLKL T Pollard RIH w/ 2 -1/4" bailer to "PX" plug body @ 4270' RKB. SITP 820 psi. Dump acid, POOH. 17:45 18:00 0.25 COMPZ RPEQP1SLKL T Close blind rams. Bleed off lubricator to production. 18:00 19:45 1.75 COMPZ RPEQP1OTHR T Revise plan forward. 19:45 20:00 0.25 COMPZ RPEQP1SFTY T PJSM w/ MI Swaco, CUDD, Pollard, Loomis, crane operator, rigger. 20:00 22:45 2.75 COMPZ RPEQP1SLKL T Bleed off gas pressure through CUDD gas buster. Initial tubing pressure 820 psi. Annulus was 375 psi after bleeding off the tubing. Bleed annulus to zero. 22:45 00:00 1.25 COMPZ RPEQP1 RURD T Vent tubing and annulus to CUDD gas buster. Permit, then cut a bigger hole in the side of CUDD pump wall to attatch 3" camlock hose from MI Swaco— straight to the pump. 11/29/2010 Held PJSM, discuss JSA. Rig up to fill hole and circ 6% KCL. Pumped 90 bbls to fill (fluid level 1380'), continue to circulate increasing rate to 5 bpm w/ 250 to 300 psi. Circulate to final of 8.9 NTU's (Nephelometer turbidity units) returns. Shut down work on CUDD pump, PJSM, service equipment, waiting on weather (wind 50 mph). 00:00 00:30 0.50 COMPZ RPEQP1 SFTY P Held Pre -Tour Meeting. Review & discuss JSA. Pump procedure discussed w/ MI Swaco, CUDD, Loomis, and crane rigger. Still have high winds 30 -40 mph. 00:30 01:00 0.50 COMPZ RPEQP1 SVRG P Service CUDD equipment, line up circulating manifold to circulate well. Page 34 of 48 Time Logs Date From To Dur S. Depth E. Depth Phase Code `` Subcode T Comment 01:00 06:30 5.50 COMPZ RPEQP1CIRC P Start pumping down tubing with returns f/ below hanger to CUDD gas buster then CUDD pit. Transfer f/ CUDD pit to platform pits w/ 3" air pump. Continue to pump, increasing rate to 5 bpm w/ 200 to 250 psi. Circulated a total of 1458 bbls before achieving a 19.3 NTU's (Nephelometer turbidity units) returns. 06:30 08:00 1.50 COMPZ RPEQP1 CIRC P Continue pumping, pumped another 1.27 hole volumes @ 5 bpm w/ 200 to 250 psi. Circulated a total of 1783 bbls. Circulate to final of 8.9 NTU's (Nephelometer turbidity units) returns. 08:00 12:00 4.00 COMPZ RIGMNI RGRP T Shut down pumping to work on CUDD pump. Blow down lines w/ air. Repair leak on the CUDD pump. 12:00 12:30 0.50 COMPZ RPEQP1SFTY P Held Pre -Tour Meeting. Review & discuss JSA. Weekly safety meeting topic Pulling tubing w/ fluid, working through crew changes, Maintaining positive attitudes. 12:30 13:00 0.50 COMPZ RPEQP1SVRG P Service CUDD equipment. 13:00 14:00 1.00 COMPZ RPEQP1OTHR T Blow down circulating lines again. Wind still blowing 50 mph. 14:00 00:00 10.00 COMPZ RPEQP1 OTHR T Waiting on weather (High winds). Wind still blowing up to 50 mph. 11/30/2010 Held PJSM, discuss JSA.Waiting on weather (wind 50 mph). RD Pollard Slickline. Set BPV and Blanking plug in preparation of Weekly BOP Test. Continue with Housekeeping. 00:00 00:30 0.50 COMPZ RPEQP1SFTY P Held Pre -Tour Meeting. Review & discuss JSA. 00:30 09:30 9.00 COMPZ RPEQP1 OTHR T Waiting on weather (High winds). Wind still blowing up to 50 mph. Not able to RD Pollard Slick line. 09:30 10:00 0.50 COMPZ RPEQP1SFTY T Held PJSM with all personel involved in RD Pollard Slickline. 10:00 13:30 3.50 COMPZ RPEQP1RURD T RD Pollard Slickline and Shooting Flange 13:30 14:00 0.50 COMPZ RPEQP1OWFF T Open up choke line, had 50 psi below Closed blind rams. Bleed off to gas buster and open blinds. 14:00 14:30 0.50 COMPZ RPEQP1SFTY T Held PJSM with all personel involved in Setting BPV and Blanking plug. 14:30 16:00 1.50 COMPZ RPEQP1 MPSP T Install BPV and Blanking plug 16:00 17:00 1.00 COMPZ RPEQP1 NUND T NU Bell Nipple. 17:00 19:00 2.00 COMPZ RPEQP1 OTHR T Clean and Clear work decks of un- needed equipment. 19:00 19:30 0.50 COMPZ RPEQP1OTHR T Off load misc. equipment from work boat. 19:30 00:00 4.50 COMPZ RPEQP1 OTHR T Clean and Clear work decks of un- needed equipment. Page 35 of 48 • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 12/01/2010 24 hr Summary Continue with Housekeeping while on standby for work boat. Conduct weekly BOP Test. Unsuccessful - Pressures flucuating on chart recorder. 00:00 00:30 0.50 COMPZ RPEQP1 SFTY T Held Pre -Tour Meeting. Review & discuss JSA. 00:30 08:00 7.50 COMPZ RPEQP1 OTHR T Clean and Clear work decks of un- needed equipment. 08:00 09:00 1.00 COMPZ RPEQP1 OTHR T Checking and Cleaning drip pans under Power Packs. 09:00 10:30 1.50 COMPZ RPEQP1 BOPE T Rigging up to Conduct weekly BOP Test that is due on Friday December 3,2010. 24 hr notice was given to AOGCC on 11 -30 -10 @ 18:00 hrs and was waived by Jeff Jones @ 08:15 hrs on 12 -1 -10. 10:30 15:30 5.00 COMPZ RPEQP1 BOPE T RIH with 5 1/2" Test jt and screw into Blanking plug, fill stack. Begin Testing Annular, CM -4, CM -5, CM -6, CM -7 and PM -5, PM-4, PM -9. PT to 250 psi. Good Test, Increase to 3,600 psi - Test not good. Found 3 valves leaking on Pump manifold. Greased and Service valves. Re- attempt test - Failed. 15:30 18:00 2.50 COMPZ RPEQP1 BOPE T Change Configuration to UPR 5 1/2 rams, CM -4, CM -5, CM -6, CM -7 and PM -5, PM -4, PM -9. PT to 250 psi. Good Test, Increase to 3,500 psi - Test not good. No visible leaks, Re- attempt test - Failed. 18:00 20:00 2.00 COMPZ RPEQP1 BOPE T Change Configuration to CM-4, CM -5, CM -6, CM -7. PT to 250 psi. Failed Test, No visible leaks, Blow down lines with air. 20:00 22:00 2.00 COMPZ RPEQP1 BOPE T Change Configuration to PM -5, PM -4, PM -9. PT to 250 psi. Failed Test, Increase to 3,500 psi - Test not good. No visible leaks. PT Pressure test pump equipment 250/3,500 psi - Good Test. Fill equipment allowing air to bleed through needle valve on top of TIW valve - (highest elevation pt. in system). 22:00 23:00 1.00 COMPZ RPEQP1 BOPE T Change Configuration to 5 1/2" Annular, TIW, and Choke HCR. PT to 250/3,500 psi - failed. No visible leaks, Blow down lines with air. 23:00 00:00 1.00 COMPZ RPEQP1 BOPE T Change Configuration to Pump manifold. 12/02/2010 Unsuccessful - Pressures flucuating on chart recorder. Change out chart recorders. Continue to conduct weekly BOP test. 00:00 00:30 0.50 COMPZ RPEQP1 SFTY T Held Pre -Tour Meeting. Review & discuss JSA. Page 36 of 48 Ani Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 00:30 11:30 11.00 COMPZ RPEQPI BOPE T Still attempting to find cause of flucuation on chart recorder. Purged line from sensor to chart recorder - First test was successful and next test flucuated. Remove 5,000 psi chart recorder from system and install 15,000 psi chart recorder. 11:30 23:00 11.50 COMPZ RPEQP1BOPE T Re -start weekly BOP test. Testing at 250/3,500 psi. 24 hr notice was given to AOGCC on 11 -30 -10 @ 18:00 hrs and was waived by Jeff Jones @ 08:15 hrs on 12 -1 -10. 23:00 00:00 1.00 COMPZ RPEQPI BOPE T Blow down lines with air and lay down test jts. 12/03/2010 Finish up weekly BOP test. Pull blanking plug. RD Test jts. RU to B -01 a and annuluar inj 65 bbls of Class II fluids. Suspend ops due to foul weather. 00:00 00:30 0.50 COMPZ RPEQP1 SFTY T Held Pre -Tour Meeting. Review & discuss JSA. 00:30 06:30 6.00 COMPZ RPEQPI BOPE T Finish weekly BOP test with TIW valves and IBOP's. Pull blanking plug and break down test jts. 06:30 10:00 3.50 COMPZ RPEQPI OTHR T Clean and clear working areas. Continue with daily housekeeping operations. Coordinating class II injection RU and disposal of waste fluids with Tyonek ops. 10:00 15:00 5.00 COMPZ RPEQP1CIRC T Fill out Cook Inlet Manifest # 1313. Had Tyonek Production Op unlock valves on B -01 a Annulus for class II injection. Clear lines with fluid and PT to 2,500 psi and check for leaks. Begin inj Class II fluids into B -01a. Pumped a total of 65 bbls with max pressure of 1,475 psi. RD injection equipment. 15:00 00:00 9.00 COMPZ RPEQP1OTHR T Suspended all operations, Heliport grounded for weather at 11:00 hrs and Boat grounded at 15:00 hrs. Will wait for to storm to blow over before resuming operations. 12/04/2010 Continue to wait for weather to clear and flew needed personel to begin operations. Circulated well to verify no gas under BPV. Pull BPV and MU landing jt. Mix and pump HEC pill and spot at open GLM at 3,921ft. 00:00 00:30 0.50 COMPZ RPEQPI SFTY T Held Pre -Tour Meeting. Review & discuss JSA. Suspended all operations, Heliport grounded for weather at 11:00 hrs and Boat grounded at 15:00 hrs. Will wait for to storm to blow over before resuming operations. 00:30 10:00 9.50 COMPZ RPEQP1OTHR T Suspended all operations, Heliport grounded for weather at 11:00 hrs and Boat grounded at 15:00 hrs. Will wait for to storm to blow over before resuming operations. Page 37 of 48 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 10:00 12:00 2.00 COMPZ RPEQPI OTHR T Weather hold was lifted at 10:00 hrs. Waiting for Vetco Gray, Pollard, MI and Baker employees to arrive. RU equipment and circulating surface to surface @ 1.5 bpm with KWF through BPV to remove any possiblilty of trap gas below plug. 12:00 12:30 0.50 COMPZ RPEQP1 SFTY T Held Pre -Tour Meeting. Review & • discuss JSA. Discussed circulating surface to surface to insure no trapped gas below BPV. 12:30 13:00 0.50 COMPZ RPEQP1SVRG P Walking pump lines and inspecting valve line do to crew change. 13:00 18:00 5.00 COMPZ RPEQP1CIRC P Clear lines with 8.7 ppg 6% KCL. Pressure test lines at 250/2,500 psi. - no leaks. Open up and begin circulating at 1.5 bpm at 0 psi. Took 1.5 bbls to catch circulation, had 130 NTU's at start and pumped a total of 362 bbls with a hole volume of 272 bbls with FCP of 0 psi and 17.2 NTU. Shut down and blow down all pump lines with air. 18:00 19:30 1.50 COMPZ RPEQPI OTHR P Prepare piperack deck to prepare for pipe laydown. Breakoff 3 1/2 TIW valve from test jt. 19:30 20:00 0.50 COMPZ RPEQP1OTHR P PU Landing jt to screw into hanger. Install Tools needed in work window for working with TBG hanger. 20:00 21:00 1.00 COMPZ RPEQP1MPSP P Pick up dry rod and RIH, Tap into BPV and release same. POOH and remove BPV. Laydown dry rod. 21:00 22:00 1.00 COMPZ RPEQPI OTHR P Repair valve for filling trip tank and fill trip tank. 22:00 23:00 1.00 COMPZ RPEQP1PULD P MU 5 1/2" Landing jt assy. RIH and screw into TBG hanger. PU and MU TIW valve with pump in sub. RU kelly hose. 23:00 23:15 0.25 COMPZ RPEQPI SFTY P Held PJSM on pumping HEC pill. 23:15 00:00 0.75 COMPZ RPEQP1CIRC P RU and preparing to mix and pump 55 bbls HEC pill adding .25 ppb of Sodium Persulfate followed by 35 bbls of 8.7 ppg 6% KCL 12/05/2010 BOLDS. Unland hanger, pull seals from PBR. Allow HEC pill to drop out of 5 1/2 liner. Displace pill outside of tubing without circulation. Pick up HGR 5 ft due to restriction. Pump down IA and fill hole. Layed down hanger. Monitor losses with trip tank. Losses went from 20 bph to 60 bph. Build surface volume, mix and pump 2nd HEC pill. Monitor losses. Fluid loss at 75 bph. Mix 3rd HEC pill increasing the viscosity. 00:00 00:30 0.50 COMPZ RPEQPI SFTY P Held Pre -Tour Meeting. Review & discuss JSA. 00:30 01:00 0.50 COMPZ WELCTI OTHR T Walk pump line and had to change pump line routing in order to monitor pressures after seals were pulled from PBR. Page 38 of 48 Time Logs Date From To Dur S. Depth E. Depth Phase Code - Subcode T Comment 01:00 02:00 1.00 COMPZ WELCTL CIRC P Mix and pump 55 bbls HEC pill adding .25 ppb of Sodium Persulfate at 1.5 bpm at 200 psi ICP. Followed by 35 bbls of 8.7 ppg 6% KCL at 1.5 bpm at 200 psi FCP. 02:00 02:30 0.50 COMPZ WELCTL OTHR P BOLDS for unlanding hanger and pulling seals from PBR 02:30 03:30 1.00 4,335 4,299 COMPZ WELCTL PULL P Unland hanger pulling up to 190k and broke free, dragging the seals from PBR at 4,319 -ft at 125k till out of PBR and weight fell off to 75k, continue to pick to 4,299 -ft. to allow HEC pill to fall out into 5 1/2 liner. 03:30 04:00 0.50 4,299 4,299 COMPZ WELCTL OWFF P Monitor for pressure, no pressure. 04:00 07:00 3.00 4,299 4,299 COMPZ WELCTL CIRC P Close annular and pump down TBG displacing HEC pill outside TBG at 1.5 bpm at 200 psi for 60 bbls with no returns through the choke manifold to the gas buster. Increase rate to 5 bpm at 350 psi for another 10 bbls. Total of 70 bbls with no circulation. Switch to pump down the IA with TBG closed and Annular open for returns to the gas buster. Bring pump on at 1 bpm at 0 psi increase pump rate to 5 bpm at 300 psi. PU TBG string 5 -ft and start pumping down IA at 3.75 bpm at 300 psi fluid at surface for 47 bbls pumped. Total pumped was 117 bbls. Shutdown due to hanger restricting in BOPE. Reland hanger and break off circulation equipment. POOH breaking down pup jts. Install TIW valve in closed and Pull till hanger is in the work window. 07:00 15:30 8.50 4,299 4,299 COMPZ WELCTL OWFF P Switch to trip tank and monitor fluid losses. Pump at 5 bpm at 300 psi for 49 bbls to fill hole, place on trip tank and monitored losses of 20 bph and increased to 60 bph in 18 minutes of continuous fluctuation. Prepare to mix 2nd HEC Pill. while removing TBG hanger with continuous hole fill monitoring with trip tank. Make 2nd 65 bbl HEC pill and build 400 bbl surface volume. 15:30 18:00 2.50 4,299 4,299 COMPZ WELCTL CIRC P Pump 2nd 65 bbl HEC pill at 1.5 bpm at 0 psi and follow with 40 bbls of Just built 400 bbl surface volume at 5 bpm at 300 psi and slow rate to 1 bpm at 0 psi. Seen returns at 84 bbls of the next 100 bbl displacement as HEC is displaced through the 5 1/2 Liner. Page 39 of 48 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 18:00 00:00 6.00 4,299 4,299 COMPZ WELCTL OWFF P Place well on trip tank and Monitor for fluid loss. Establish a fluid loss rate of 20 bph. Continue to monitor loss rate on trip tank. Loss rate increased to 75 bph. Mix 3rd 65 bbl HEC pill with 35 gal / 25 bbls of Safe -Vis OGS. Fill hole prior to pumping HEC pill. Took 55 bbls to fill hole. 12/06/2010 Pump 3rd HEC pill. Monitor loss rate. LD 5 1/2 Liner and RU slickline and lubricator. 00:00 03:00 3.00 4,299 4,299 COMPZ WELCTL CIRC P Pump 3rd 65 bbl HEC pill at 1.5 bpm at 100 psi and follow with 40 bbls at 5 bpm at 400 psi and slow rate to 1 bpm at 100 psi for 91 bbls. Saw returns at 15 bbls into pumping HEC pill. 03:00 04:15 1.25 4,299 4,299 COMPZ WELCTL OWFF P Place well on trip tank and Monitor for fluid loss. Establish a fluid loss rate of 20 bph. Continue to monitor loss rate on trip tank using continuous fill. Loss rate holding steady at 25 to 30 bph for 1 hour. 04:15 05:30 1.25 4,299 4,299 COMPZ RPEQP1RURD P RD and Blowdown all circulating lines and equipment. 05:30 06:30 1.00 4,299 3,947 COMPZ RPEQP1PULD P LD 11 jts of 5 1/2 ", 15.5# BTCM, R -2 Production TBG from 4299 ft to 3,947ft. Spooling control line, recovered 16 SS Bands. 06:30 07:30 1.00 3,947 3,942 COMPZ RPEQP1 PULL P Disconnect control line from SSSV and pull above heavy slips above work window. 07:30 08:00 0.50 3,942 3,942 COMPZ RPEQP1 OWFF P Install TIW valve, place in closed position. Send snubbing crew in for lunch, while pump operator monitors well on trip tank. 08:00 09:00 1.00 3,942 3,932 COMPZ RPEQP1 PULL P Open up and remove TIW valve. Pull SSSV through jack. 09:00 11:00 2.00 3,932 3,911 COMPZ RPEQP1 OTHR P Remove snubbing slips, break out SSSV manually. lay down same. 11:00 14:00 3.00 3,911 2,506 COMPZ RPEQP1 PULL P Continue to POOH laying down 47 jts of 5 1/2 ", 15.5# BTCM, R -2 Production TBG for total of 75 jts down from 3,911- ft to 2,506 -ft. Held Pre tour mtg with crew coming on laying down 5 1/2 Production TBG at 12:00 hrs. Fluid loss at crew change was 117 bbls since midnight. Fluid loss rate is at 14 bph. 14:00 17:30 3.50 2,506 2,506 COMPZ RPEQP1 OTHR P Offload the 75 jts of 5 1/2 on to the boat. 17:30 18:00 0.50 2,506 2,506 COMPZ RPEQP1OTHR P Shut down for dinner will well remained secured. Page 40 of 48 Time Logs • Date From - To Dur S. Depth E. Depth Phase Code Subcode T Comment 18:00 22:00 4.00 2,506 488 COMPZ RPEQP1 PULL P Open up well and Continue to POOH from 2,506 -ft laying down 5 1/2 completion string to 488 -ft. 22:00 00:00 2.00 488 488 COMPZ RPEQP1 SLKL P RU Pollard Slick line unit and lubricator. Fluid loss at crew change was 72 bbls since noon. Fluid loss rate is at 6 bph. 12/07/2010 RU slickline and lubricator. Unable to pull PX plug. RD slickline. Pump fluid out of individual jts with hose and trash pump. Finish laying down 5 1/2" Liner. Offload 5 1/2" to work boat, bring on 3 1/2" and 2 78 ". Prepare and run 2 7/8" lower completion string to 678 ft. 00:00 09:00 9.00 488 488 COMPZ RPEQP1 SLKL P Continue RU Pollard Slick line unit and lubricator. Tested lubricator to 500 psi. Attempt to RIH. Tool not passing TIW valve. Take out TIW valve and connect lubricator to TBG. RIH to 389 -ft and Made 2 attempts, sheared 1 brass pin and 1 steel pin. RD S/L unit. 09:00 11:00 2.00 488 400 COMPZ RPEQP1 PULL P Continue to POOH from 488 -ft to 400 -ft. laying down 2 jts 5 1/2 completion TBG. Had to work GLM #3 through slips. Fluid slowly draining through PX plug body at —1 ft/min. 11:00 15:00 4.00 400 400 COMPZ RPEQP1 PULL P RU hose and pump fluid out of tubing one joint at a time. Continue POOH laying down singles. Lay down sliding sleeve w/ plugged PX plug body. Lay down seal assembly. Filled hole w/ 51 bbls. Continue to circulate across the top. Losses at 12.75 bph. *Lost 102 bbls from midnight to noon. 15:00 19:00 4.00 0 0 COMPZ RPEQP1OTHR P Offload 53 jts of 5 1/2 TBG, 3 GLM's, sliding sleeve, seal assy, and SSSV onto the work boat. Offload Pollard SL Unit onto work boat. Bring on 3 1/2 TBG and 103 jts of 2 7/8 TBG from work boat. Strap 2 7/8 TBG. 19:00 21:30 2.50 0 0 COMPZ RPEQP1OTHR P RU to run lower completion. Dress slips, P/U well control equipment to workbasket. Layout jewelry on rack. 21:30 00:00 2.50 0 678 COMPZ RPCOM RCST P P/U WLEG and landing nipple assy and RIH with lower completion to 678 ft. Ran3jtsof27 /8 "6.5 #EUE, 3200 ft Ibs MU torque, 17 jts of 2 7/8" 6.5# Hyd 511 800 ft Ibs MU torque. Ran HS packer #6 and SLCMU #4. *Lost 145 bbls from noon to midnight. 12.1 bph 12/08/2010 Ran 2 -7/8" isolation string to 3110'. Swapped to 3 -1/2" handling equipment, RIH w/ 3 -1/2" workstring to 6426 ft. Page 41 of 48 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 00:00 05:00 5.00 678 3,059 COMPZ RPCOM RCST P Continue RIH with 2 7/8" 6.5# Hyd 511 lower completion from 678 ft to 3059. Ran 64 jts of tubing for total of 81 jts of Hyd 511. Ran remaining 5 HS packers for total of 6 packers. Ran remaining 3 SLCMU's for total of 4. 05:00 08:00 3.00 3,059 3,059 COMPZ RPCOM OTHR P RD 2 7/8 equipment. RU for running 3 1/2" tubing. Transfer 2 7/8" tubing to upper deck and out of the way. 08:00 11:00 3.00 3,059 3,059 COMPZ RPCOM OTHR T Discovered Cudd did not have tongs big enough to make up the 3.5" IF box x 4.5" IF Pin crossover (6.3" OD) to the 4.5" IF setting tools attached to the liner sleeve. Largest make -up tongs they have is 5.5 ". Mulled over a plethera of ideas, most of which would involve a 12 hour downtime by sending the Liner sleeve & crossovers to Baker to be bucked up, either by sling load or boat. Pulled liner setting sleeve and SBE and layed out on drill deck, used the crane to get weight for sling load (1800 Ibs - -too heavy). Eventually came up with the idea of making up the crossover upside down with a spare pup joint laying around, the crossover can be gripped in Cudd's bottom slips and the pup made up with the rig tongs. 11:00 16:15 5.25 3,059 3,120 COMPZ RPCOM RCST P MU crossover to pup upside down, turn right side up and set aside. Remove snubbing slips to allow liner setting sleeve through. PU and re- install liner setting sleeve. Re- install snubbing slips. MU crossover and pup joint to the liner setting tools. Install final crossover back to 3.5" EUE. Fluid loss from midnight to noon - 137 bbls. Loss rate 11.4 bph. 16:15 19:00 2.75 3,120 4,535 COMPZ RPCOM RCST P Begin running 3.5" EUE workstring, strapping and tallying as RIH. Ran 45 jts of 3.5" 8rd EUE -Mod till 2 -7/8" isolation string is at a depth of —4535' RKB. 19:00 20:30 1.50 4,535 4,535 COMPZ RPCOM RGRP T Shut down power pack and change out 0 -ring on hyd. hose on back of jack up in the air. 20:30 00:00 3.50 4,535 6,426 COMPZ RPCOM RCST P Continue RIH with 3.5" EUE workstring, strapping and tallying as RIH. Ran 60 jts, total of 105 jts of 3.5" 8rd EUE -Mod till 2 -7/8" isolation string is at a depth of 6426' RKB. Fluid loss from noon to midnight - 112 bbls. Loss rate 10 bph. Page 42 of 48 Time Logs • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 12/09/2010 24 hr Summary Finish RIH. RU up a -line for Pkr. correlation logs.Run correlation log and set packers on depth. Drop ball & rod, pressure uo to set packers. Release running tools and POOH standing back 3 -1/2" tubing. 00:00 02:00 2.00 6,426 7,409 COMPZ RPCOM RCST P Continue RIH with 3.5" EUE workstring, strapping and tallying as RIH. Ran 31 jts, total of 136 jts of 3.5" 8rd EUE -Mod till 2 -7/8" isolation string is at a depth of —7391' RKB. 02:00 06:00 4.00 7,409 7,409 COMPZ RPCOM OTHR P Clean up drill deck, remove extra 3.5" tubing from drill deck. RU E -line equipment. 06:00 10:00 4.00 7,409 COMPZ RPCOM RURD P Continue rigging up E -line, RU TIW valve, RU Lubricator. PT lubricator to 500 psi. Good Test. Open TIW valve. 10:00 12:30 2.50 COMPZ RPCOM ELOG P Ran E -line correlation log. Made several passes, good data. Tied into RA tags at 6855' and 7089'. Determined 2 - -7/8" isolation string 16' high. Fluid loss from midnight to noon 136 bbls. 11.3 bph loss rate 12:30 13:00 0.50 COMPZ RPCOM RURD P RD E -line lubricator & TIW valve. 13:00 15:00 2.00 COMPZ RPCOM RCST P Replaced collar damaged by TIW valve. MU 16' pup joints. Lower into hole 16'. RU TIW valve. RU pumping lines 15:00 15:45 0.75 COMPZ RPCOM RCST P Drop ball & rod to seat in RHC plug. Wait 15 min. for ball to drop. Begin pumping, ball on seat, began pressuring up to set packers. At 1000 psi, noticed TIW valve leaking. Shut down pumps. Tightened TIW valve. Begin pressure test again. Slowly ramped pressure up, at 2000 psi, saw bobble as expected for packers to start shifting. Pressure up to 2500 psi. Held for 10 min. 15:45 17:00 1.25 COMPZ RPCOM RCST P Bled off tubing, RU pump lines to annulus. Closed the annular and PT the annulus to 500 psi for 10 min. Bleed off. Disconnect pump lines. Remove TIW valve. Pull 15K lbs on tubing to verify packers set, set down 8K lbs. Confirmed packers set. Install pup joint to top of tubing stub so that the rig tongs have something to bite on. Use rig tongs to rotate setting tools to the right to release. Confirmed liner running tools free. 17:00 19:00 2.00 COMPZ RPCOM OTHR P Boat arrived, offload E -line equipment to allow room to lay down tubing. Service equipment and fuel up. Change back up dies on Loomis tongs. Page 43 of 48 Time Logs • • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 19:00 23:00 4.00 COMPZ RPCOM PULL P Begin pulling 3 -1/2" tubing, lay down 3 pup joints. Lay down first 8 singles. Rack back 50 stands of tubing for final completion. 23:00 23:30 0.50 COMPZ RPCOM OTHR P Change out power tong unit. 23:30 00:00 0.50 COMPZ RPCOM PULL P Continue pull 3 -1/2" tubing. Rack back 14 stands for total of 64 stands. Lost 44 bbls of fluid from noon to time of setting packers @ 15:30 hr. 12/10/2010 RIH w/ 3.5" gas lift completion, landed in PBR w/ one extra joint over calculated tally. PUH and stung out of PBR, mixed and circulated 326 bbls of inhibited 6% Kcl. 00:00 01:00 1.00 COMPZ RPCOM PULL P Back out and laydown x -overs and liner running tool 01:00 02:00 1.00 COMPZ RPCOM OTHR P Service rig. Blowdown all surface lines. 02:00 03:00 1.00 0 179 COMPZ RPCOM RCST P MU seal assy. and RIH w/ 3 -1/2" 9.3# EUE tubing completion to 1st GLM @ 179 ft. Have to pull 1 slip segment when GLM's pass through slips. A segment was dropped and hit the slip hydraulic hose causing it to crack a fitting. 03:00 04:00 1.00 179 179 COMPZ RPCOM RGRP T Repair hydraulic fitting on slips. 04:00 12:00 8.00 179 1,935 COMPZ RPCOM RCST P Continue RIH with 3 -1/2" & GLM's to SCSSV. SLB spooler intalled control line and pressured SSSV to 5000 psi. Continued RIH w/ 3.5" copmpletion 12:00 19:00 7.00 1,935 COMPZ RPCOM RCST P Plan forward with new crew, complete landing on 64th stand of pipe, PU and place Kelly on 4th single jt. (Did not tag as suspected). Add 5th joint and landed 10' into 5th joint. PU to neutral weight plus 2' and flagged pipe. 19:00 21:00 2.00 COMPZ RPCOM COND P PUH one stand and wait for fluid for circulation. Mix 360 bbls of 8.7 ppg 6% KCL with 3 drums of Congor 303A, 150 Ibs of Soduim Meta- bisulfite (oxygen scavenger) 21:00 00:00 3.00 COMPZ RPCOM CIRC P Close annular and attempt to pump down IA. Pressured up to 1700 psi with no returns. Check all surface lines -OK. Open annular and pick up TBG string 5 more ft. Close annular and pump down IA with 326 bbls of corrosion inhibited KCL at 3 bpm, 0 psi 12/11/2010 Land 3.5" tubing & hanger, PT IA to 3500 psi (passed). PT Tbg to 2500 psi (passed). Shear out SOV with 2000 psi. Function tested and PT'd SSSV w/ 1500 psi from below (passed). LD landing joint, install and test BPV 00:00 02:00 2.00 COMPZ RPCOM RCST P Laydown 3 joints of 3 -1/2" TBG. Make up 2 space out pup joints and pick up 1 joint of TBG on top. Page 44 of 48 Time Logs • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 02:00 05:30 3.50 COMPZ RPCOM THGR P MU tubing hanger and control line. Put presssure back on control line. MU landing joint and TIW valve. 05:30 10:30 5.00 COMPZ RPCOM THGR T Space out to land tubing w/ 64 stands, 2 joints and 8' of pups. Having difficulties working hanger through BOP stack. Hanger landed 13' high. 10:30 13:30 3.00 COMPZ RPCOM THGR P Un -sting from seal assemble and lay down 1 joint of 3.5" pipe & pups. Review spaceout and modified tally. 13:30 17:30 4.00 COMPZ RPCOM THGR P RIH w/ 64 stands 1 jt and 24' of pups. Landed Tbg hanger, RI & torque LDS's. 17:30 20:30 3.00 COMPZ RPCOM DHEQ P RU & PT tbg to 2500 psi for 10 minutes (passed), swap over to IA and PT to 3500 psi. Noticed leak in Kelly hose, SD and swap out hose, re- pressure IA to 3500 psi. IAP @ 15 mins = 3500 psi, IAP @ 30 minutes = 3500 psi. (Passed). 20:30 21:00 0.50 COMPZ RPCOM DHEQ P Bled Tbg & IA to 0 psi, online pumping down IA & sheared SD @ 2000 psi. 21:00 21:30 0.50 COMPZ RPCOM DHEQ P Bled control line to 0 psi to close the SSSV. Pump down IA and test SSSV to 1500 psi for 10 minutes (Passed) 21:30 23:00 1.50 COMPZ RPCOM MPSP P LD landing joint, install BPV with dry rod. Open SSSV and pump down IA and test BPV to 1500 psi for 10 minutes (Passed) 23:00 00:00 1.00 COMPZ RPCOM OTHR P Cut and plug of control line. Prepare to ND BOPE. 12/12/2010 Prep for ND BOPE. RU for Class II injection to well B -1. Injected 445 bbls of class II returns fluid down 2 3/8" injection string. ND BOPE and Riser stack. 00:00 02:00 2.00 COMPZ RPCOM OTHR P Prep for ND BOPE. RU for Class II injection to well B -1. Injected 445 bbls of class II returns fluid down 2 3/8" injection string. 02:00 17:00 15.00 COMPZ RPCOM NUND P ND BOPE, load out all MI Swaco & Total Safety equipment equipment. 17:00 23:30 6.50 COMPZ RPCOM NUND P ND riser stack. LD riser to deck. 23:30 00:00 0.50 COMPZ RPCOM NUND P Clean and prep tubing hanger and tubing head for NU. 12/13/2010 NU and test 5.125" 5k tree. Start rigging down and backloading Cudd equipment. Prepare deck for next boatload and for skidding rig. 00:00 00:30 0.50 COMPZ RPCOM NUND P Continue prep tubing hanger and head for NU. 00:30 10:00 9.50 COMPZ RPCOM NUND P NU 5.125" 5k tree. Connect control line and tested to 5000 psi. Left SCSSSV in open position. Tested hanger seals and void to 5000 psi for 10 min. Continue NU tree. Page 45 of 48 • • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 10:00 12:00 2.00 COMPZ RPCOM NUND P RU and PT tree to 2000 psi w/ production tri -plex for 10 minutes (passed). Pulled 2 -way check & released Vetco techs. 12:00 14:00 2.00 DEMOB MOVE RURD P Backload misc equipment to workboat. Broke down landing jts. Get equipment ready to go on boat. Install hatch cover back over well. RD totco equipment. 14:00 15:00 1.00 DEMOB MOVE RURD P Walk- around workbasket, workwindow and clear of all tools. Loaded both Cudd mud pumps, 100 bbl mud tank, and trip tank to workboat. 15:00 16:00 1.00 DEMOB MOVE RURD P Scope down gin pole. Change hyd. jack to 4 -legs and continue backloading workboat. 16:00 21:30 5.50 DEMOB MOVE RURD P Put rental tools and hoses in baskets. Clear off deck of excess equipment in preparation of skidding unit. Place hyd hose baskets on deck for main hyd hoses RD. 21:30 00:00 2.50 DEMOB MOVE RURD P Remove extra nitrogen bottles from koomey unit. Remove tong hoses and tongs from workbasket. Laydown ladder to pipe deck. 2 sets of slips removed, rotary unbolted and ready to remove. 12/14/2010 Continue rigging down and preparing to skid rig over. Wait on weather. High winds 35 - 60 mph 00:00 06:00 6.00 DEMOB MOVE RURD P Continue rigging down and preparing to skid rig over. Remove tarps from jack. Pull console hoses into basket. Disconnecting main and auxiliary hoses and putting in hose baskets. 06:00 14:00 8.00 DEMOB MOVE RURD P Cleaning deck. Finish rig down of trunkline. Get console ready to skid unit. Add hoses to run skidder. Clean out well bay. Change quad seals on skidding bank system. Suspend Crane operations @ 07:00 due to winds in excess of 25 mph. 14:00 00:00 10.00 DEMOB MOVE OTHR T Suspend all operations due to high winds of 35 - 60 mph. 12/15/2010 Continue wait on high winds (weather). Prep to skid rig while waiting on winds. Skid rig 42'. Wait on weather. Continue to skid rig to final position to rig down. 00:00 00:30 0.50 DEMOB MOVE SFTY P Hold safety meeting and review JSA. 00:30 12:00 11.50 DEMOB MOVE OTHR T Continue waiting on weather. (High winds 35 -60 mph) 12:00 12:30 0.50 DEMOB MOVE SFTY P Hold safety meeting and review JSA. 12:30 13:30 1.00 DEMOB MOVE RURD P Remove Vetco Gray rental flange (3 -1/8" 5m x 1502) from tree on B -3 and install blind flange. Page 46 of 48 Time Logs • • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 13:30 15:00 1.50 DEMOB MOVE RURD P Prepare to skid rig. 15:00 16:30 1.50 DEMOB MOVE RURD P Skid rig 42 ft. As far as able to go until winds die down for crane work. Winds at 25 -35 mph. 16:30 20:30 4.00 DEMOB MOVE OTHR T Wait on weather. 20:30 00:00 3.50 DEMOB MOVE RURD P Start crane work. Finish skidding rig to SE corner by unit crane. 12/16/2010 Rig down. Backload equipment to workboat. Continue rigging down and preparing for next boatload. 00:00 00:30 0.50 DEMOB MOVE SFTY P Hold safety meeting and review JSA. 00:30 02:00 1.50 DEMOB MOVE RURD P Rig down gin pole and lay on deck. 02:00 06:30 4.50 DEMOB MOVE RURD P Pick up hoses to workbasket. Put jack hoses in main hose basket. 06:30 12:00 5.50 DEMOB MOVE RURD P Sort out Weatherford equipment. Prep equipment for backloading to workboat. 12:00 12:30 0.50 DEMOB MOVE SFTY P Hold safety meeting and review JSA. 12:30 16:00 3.50 DEMOB MOVE DMOB P Backload equipment to workboat. 16:00 18:30 2.50 DEMOB MOVE RURD P Clear deck to make room for workbasket, jack, and workwindow. 18:30 19:30 1.00 DEMOB MOVE RURD P Hooked onto workbasket and remove nuts and bolts from hyd jack. Remove guide wire from top structure. 19:30 21:00 1.50 DEMOB MOVE RURD P Workbasket on deck. Remove braces from under workbasket and remove riser bolts from workbasket. Break nuts and bolts from hyd jack to workwindow. 21:00 22:45 1.75 DEMOB MOVE RURD P Workbasket separated from riser. Get rigging ready to hook onto hyd jack and remove from workwindow. 22:45 23:00 0.25 DEMOB MOVE RURD P Jack on deck. Remove studs from bottom of jack. Secure slips. Remove guide wire. 23:00 23:45 0.75 DEMOB MOVE RURD P Getting rigging ready for removing workwindow to deck. Hook onto workwindow and walk- around. Lower to deck. 23:45 00:00 0.25 DEMOB MOVE RURD P Workwindow and walk- around on deck. Separate them to be put on workboat. 12/17/2010 Rig down. Backload to workboat. Continue rigging down. Backload 2nd load of day. Clean up and straighten up platform deck. Wait on workboat for last load. 00:00 00:30 0.50 DEMOB MOVE SFTY P Hold safety meeting and review JSA. 00:30 02:00 1.50 DEMOB MOVE RURD P Continue RD. Separate workwindow and walk- around. 02:00 05:00 3.00 DEMOB MOVE DMOB P Backload equipment to workboat. 05:00 12:00 7.00 DEMOB MOVE RURD P Finish RD cat walk, rotary beams, and top substructure. Pick up guy wire. Clean deck and prepare for next workboat to arrive. Page 47 of 48 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 12:00 12:30 0.50 DEMOB MOVE SFTY P Hold safety meeting and review JSA. Sent 9 CUDD personnel in to work on the beach. 12:30 16:00 3.50 DEMOB MOVE DMOB P Backload equipment to workboat. Offload Pollard slickline equipment. 16:00 20:00 4.00 DEMOB MOVE RURD P Clean up platform deck. Get remaining equipment staged for partial boatload. 20:00 00:00 4.00 DEMOB MOVE OTHR P Wait on workboat to backload last load. ETA is —09:00 hr. 12/18/2010 Only one CUDD crew on platform. PJSM @ 1030 am. Backload last boat of CUDD equipment. Helicopter flight for crew to the beach. Last CUDD personnel on platform - Richard Green (Yogi). Rigging up Pollard wireline, fish ball and rod, pull all valves in GLM's, installing valves. 00:00 10:30 10.50 DEMOB MOVE DMOB P One Cudd crew on plaform, laying down. Will work boat in the morning. 10:30 10:45 0.25 DEMOB MOVE SFTY P Pre job safety meeting on loading boat w/ equipment to go to OSK. 10:45 12:30 1.75 DEMOB MOVE DMOB P Backload last of CUDD equipment and mis. equipment associated with working on B -3 well. 12:30 13:30 1.00 DEMOB MOVE DMOB P Cudd crew prepare to leave platform. Start rigging up Pollard wireline on B -3. PJSM with Pollard wireline. 13:30 14:00 0.50 DEMOB MOVE DMOB P 6 CUDD personal to the beach. 14:00 15:00 1.00 DEMOB MOVE DMOB P Finish paperwork w/ CUDD supervisor. CUDD employees preparing stack out site on the beach. 15:00 16:45 1.75 DEMOB MOVE DMOB P Cleaning deck with peak riggers, Rigging up Pollard Wireline. Pressure test lubricator to 2200 psi. 16:45 16:45 0.00 DEMOB MOVE DMOB P Helicopter w/ last CUDD personnel (CUDD Supervisor- Richard Green). Page 48 of 48 NCI B -03 Well Work Summary DATE SUMMARY 12/18/10 Permit, PJSM. RU, PT lubricator to 0 psi -good. RIH to pull ball and rod @ 7 RKB, POOH. RIH, pull top dummy valve (station #1) @ 1334' RKB, POOH. RIH, pull shear out valve (station #4) @ 4128' RKB, POOH. RIH, pull dummy f/ station #3 @ 3407' RKB. RIH, pull dummy f/ station #2 @ 2372' RKB, POOH. RIH, set top valve (station #1) @ 1334' RKB, POOH. RIH, set valve (station #2) @ 2372' RKB, POOH. RIH w/ toolstring, set valve (Station #3) © 3396' RKB. POOH. RIH w/ toolstring, set valve (Station #4) @ 4107' RKB. POOH. Lay down lubricator for the night. Secure well head. Remove fusible cap. Clean up work area. 12/19/10 Pulled 2.313" RHC plug body f /landing nipple @ 7357' RKB (7352' WLM), open all (4) CMU's, close top CMU (Station #1). Station #4 CMU: 6798' RKB (6790' WLM) Station #3 CMU: 6088' RKB (6077' WLM) Station #2 CMU: 5590' RKB (5575' WLM) Station #1 CMU: 4659' RKB (4644' WLM) Rig down, secure well. Prepare to move to well A -16 for more slickline work. 1/10/11 Late Arrive to Platform due to fog. Arrived platform spotted equipment. Unable to begin well work on B -03 due to heavy fog.Attempt to restart in the AM. 1/11/11 Drift tubing with 1.65" swage, tag bottom at 11160' slmd. Shifted CMU open at 4654' SLMD for production of CI 1 -4 sands. (Complete) • • s NCIU B -3 Conoco hilli p 3 -1/2" Tubing & 2 -7/8" Isolation String Completion as run 12/15/10 J BPV (Mke, Type, OD) Cameron 5 "H" RKB -LDS: 42.57 Tbg Hr (Make, Type) Vetco 10 -3/4" x 5 -1/2" BTC box, 5.875" MCA top 491' SSSV J Annulus Fluid: 9.6 ppg KCUCaCL Casing with corrosion inhibitor RKB -MSL: 119.00 PPCO J ( Water Depth: 130.00 ;f-- 1, . ....._ A ` . ._ r ''D ugs �._ ��I'^I�I�" B1�pNm��Nlulw.4'Wk'+ Allowable Ratm9$ pI w r II I.u.�..ljI)I)w' ; I r. ::Mr--. 7 _1101'"' 9 20" 30" 0 461 547 lbs/ft - WELD 4217 Kin ` 133 lbs/ft K-55 uip 13 3/8" 0 4400 72 lbsff< L -80 BT&C = 13-3/8" 9 518" 0 11,761 53.5 Ms/ft P -110 BT &C ME 4349 ■ ► 5 -1/2" Gravel Pk 4319 8431 17 Ibs/ft L-80 SLIT 11 4431 0 0 Cook Inlet Sands 2 -7/8" !so String 4290 7391 6.4 Ibs/ft L -80 Hydril 511 4463 -4547 CI -1 3 -1/2" the 0 4321 9.3 lb/ft L -80 EUE Mod _ 4660' r. _ 4570 -4663 CI -2 4690 -4701 CI -3 Below Cement To. at 11,181 4748 -4820 CI -4 3 -1/2" tbg 11,354 13,700 12.95 lb/ft P -110 - - -_ 4630'1 - 7. - - ------ 11,560 15 301 32 lbs/Ft P -110" - - -- 4873 K 4888 -4918 CI -4 5" liner 11,420 17,150 18 lbs/Ft P -110 BT &C - 4927 -4955 CI -5 3 1/2" 17,159 17,864 13 lbs /Ft P -110 BT &C 5060-5090 CI -7 g p ry 5200 -5214 CI -8 ��l e 01 G. Ts.i1 , . .. . . Ilu m PI `!u L �1 1 I�� Nli l .' A . -y , udhllOIN�I�II��I�IIiI , )r II II): ....;ill .a 5268 - 5291 CI - Top1 Length Description 5308'111. < 0' 4321' 3-1/2" 9.3 ppf, L -80, EUE -Mod Tubing e 5342' 5355 - 5402 CI -11 491' 4.37' Camco TRMAXX -5E 3-1/2" SSSV with 2.813" X profile 1335' 7.01' Camco 3 -1/2" x 1" KBMG GLM with GLV Beluga Sands 2372' 7.01' Camco 3 -1/2" x 1" KBMG GLM with GLV 5591 [D 5588 - 5595 B 3407' 7.02' Camco 3 -1/2" x 1" KBMG GLM with GLV 5752 - 5765 B 4128' 7.01' Camco 3-1/2" x 1" KBMG GLM with GLV 5777' ► 4217' 3.92' Baker CMD 3-1/2" sliding sleeve with 2.813" X profile 5838 0 El 5933 C 4305' 16.94' Baker 80 -40 GBH -22 Locator /Seal Assy. 6038 -6046 D -i ?o 111 pp N ' 6048 -6054 D V�>� �� )etl �) I e r v I )I I� ellUllj 3 � .��l. u+} �, '!« 10� er x,ll III ��III ��I ° � � I G�ti €...... I IN� Il 9 a��'I m 6088' I• 6220 -6227 E Toe Length D 6261 - 6268 E 4290' 11.20' 7" C -2 Liner Setting Sleeve, 7" LTC box down, 10' tie back extension 7.5 "OD 6277 - 4302' 19.28' Baker 80 -40 Seal Bore, 4" ID x 10' long, 5" BTC pin x pin 6337' 0 r 6628 - 6648 Fl 4431' 6.89' Baker HS Packer #1, 2 -7/8" EUE w/ 30k shear release _ 6655 - 6672 J 4660' 3.94' Baker 2 -7/8" SLCMU Sliding Sleeve #1, 2.313" BX profile, Hyd 511 (closed 12/19/10) 6799' [f 6955 - 6978 L 4873' 6.90' Baker HS Packer #2, 2 -7/8" EUE w/ 30k shear release 7180 - 7197 L 5342' 6.90' Baker HS Packer #3, 2 -7/8" EUE w/ 30k shear release 7217'■ 5591' 3.94' Baker 2 -7/8" SLCMU Sliding Sleeve #2, 2.313" BX profile, Hyd 511 (opened 12/19/10) 7277' 7495 - 7517 N 5838' 6.91' Baker HS Packer #4, 2 -7/8" EUE w/ 30k shear release 7700 - 7727 P 6088' 3.94' Baker 2 -7/8" SLCMU Sliding Sleeve #3, 2.313" BX profile, Hyd 511 (opened 12/19/10) 7955 - 7968 Q 6337' 6.90' Baker HS Packer #5, 2 -7/8" EUE w/ 30k shear release • 8105 - 8145 R 6799' 3.95' Baker 2 -7/8" SLCMU Sliding Sleeve #4, 2.313" BX profile, Hyd 511 (opened 12/19/10) 8155' 7277' 6.90' Baker HS Packer #6, 2 -7/8" EUE w/ 30k shear release \ 7358' 1.00' Landing Nipple, 2.313" X Profile 7390' 1.25' 2 -7/8" WLEG a- 1 11 ppppglIlI 1111 G I II r. ... °I Iw.... . .... .. I I 1 INIIIY�mlll N M I uu : ki N _ -. '. -'; ... ' (, c// ., :........ T: Length Description Calc TOC at 4319' 17.35' Baker 190 -60 PBR w/ 15' Seal Travel, 6.000" ID, run on drill pipe on 11/16/03 1 10/15/03 4341' 2.60' Baker KOIV, 5.000" ID, busted open on 11/19/03 - - ---- --- - - - - -- 4348' 0.87' Baker 190 -60 S -22 Anchor Latch Seal Assy 4349' 4.20' Baker 9 -5/8" 53.5# SC-1R packer assy with KOIV @ 4381' •• 4830' 3.07' Baker 9-5/8" 53.5# SC-1L packer 5308' 3.07' Baker 9-5/8" 53.5# SC-1L packer 5777' 3.07' Baker 9 -5/8" 53.5# SC-1L packer 6277' 3.07' Baker 9 -5 /8" 53.5# SC-1L packer 6855' 8.88 RA Tag in box of 5 -1/2 ", 17 ppf, L -80 Braden Blank, SLHT BxP 7089' 8.88 RA Tag in box of 5 -1/2 ", 17 ppf, L -80 Braden Blank, SLHT BxP ' 7217' 3.10' Baker 9 -5/8" 53.5# SC-1L packer 7767' 8.88 RA Tag in box of 5 -1/2 ", 17 ppf, L -80 Braden Blank, SLHT BxP 8155' 13.04' Baker 9 -5/8" 53.5# SC-1R sump packer w/ millout extension 8168' 195.26' 5-1/2" 15.5# BTC tbg, 6 joints 8367' 0.68' Xover, 5-1/2" BTC to 4 -1/2" IBT 8397' 1.20' Landing Nipple, 3.813" X Profile 8430' 0.74' 4-1/2" WLEG . • ■ I Gravel Pack Perfs are 4463' - 8145', see attached for exact details MEN ;47 V, TI v..u1 .eu esa "1'0 iili11 iIi _1 r,... . 1111l'tl 9, III ,...a I ° -,. ; j 9 5/8" Cemented with 2767 sx (914 bbl) 9 -5/8" I 6/17/98 Lead 2342 sx (914 bbl) Tail 424 sx (90 bbl) ® 12 -1/4" hole TD @ 13,315' MD, 9-5/8" casing stuck off bottom by 1554'. No mention of cmt returns to surf but 16,000' of cmt pumped up annulus. /\_/ DO USIT 9/11/03 logged good cmt up to 4000' pp��pp��IIII / DO ',PI, �:li1 ,p`2 j `� -.m44j v- Il, Mir 1 11 �'' .. II; tl�4 il4 - t, r 1 III, Iii I64tVIW1�1III111h,IIll4 _ . :wrrk.'.u. x4vvj _J ( Old Tubing tally has not been located. Measurements below are approximate. 3 - 1/2" 12.95# P - 110 tubing to approximately 13,700' MD 11,181' Calc TOC on 10/15/03 = 11181' 11,354' BWD packer with seals top © approximately 11,354' 11,362' Bevel guide over tubing stub from 11,362' to 11,368' Tubing chemically cut at 11,362' after failed pressure test 11,380' AHC Packer © appx 11,380' (from first attempt, tubing would not hold pressure) 11,398' Top of 24' wireline fish on X- nipple @ 11406' ctm 11,418' X- nipple (2.313 ") © 11,418' wlm 13,700' Tubing tail at 13,700' MD no oil perforations Top of fill @ 16890 Updated By: B. Packer 1/11/2011 Last Tag: Exit TT @ 8500' RKB, No Tag PBTD: 14,377' Well: North Cook Inlet Unit No. B -3 Location: Tyonek Platform - Alaska Field: North Cook Inlet Unit Regg, James B (DOA) Page 1 of,6t— • • From: Regg, James B (DOA) Sent: Thursday December 09, 20105:11 PM '�� To: Tyonek Company Man t I Cc: Aubert, Winton G (DOA); DOA AOGCC Prudhoe Bay 'v eat`` � —0 Subject: RE: NCIU B -03 (PTD #198 -059) Weekly BOP test due 12/10/10 Your request for waiver of requirement to test BOPE (due 12/10) is approved based on passing VBR .i tests 12/2 & 12/3 and timing to complete the remaining work steps (12110). Notify the Commission should you encounter problems that change the steps or delay completing installation of the remainder of your completion. Jim Regg AOGCC 333 W. 7th Avenue, Suite 100 Anchorage, AK 99501 907 - 793 -1236 From: Tyonek Company Man [ mailto :KUUK5CM @conocophillips.com] Sent: Thursday, December 09, 2010 4:24 PM To: Regg, James B (DOA) Subject: NCIU B -03 (PTD #198 -059) Weekly BOP test due 12/10/10 Jim, Sorry it look me a while to email, our scanner takes a rocket scientist to figure out. Attached are the charts from the BOP test that occurred from 12/2 -12/3. Also is a schematic of what this well will look like when completed. Current activities: We just finished running our 2 -7/8" isolation string and set the packers inside the 5 -1/2" gravel pack assembly. We used the 3-1/2" production tubing as a workstring, so currently, the well looks just like the proposed schematic but without the gas lift mandrels and the SSSV installed. Next ,,Steps: • Release the liner running tools w/ right hand rotation. • POOH standing back tubing. Lay down running tools. • MU seal assembly and RIH w/ tubing and gas lift completion. • Sting into SBE, mark pipe, pull out one joint. �� • Load IA w/ corrosion inhibited brine. l • Space out, MU hanger and land the tubing • PT tubing & IA, shear the SOV, Function test the SCSSV. Install BPV. PT BPV in direction of flow. • ND BOPE, NU Tree, PT break to 1500 psi. Install test plug. Test tree to 5000 psi. • Pull test plug, install BPV. RDMO We should be finishing up tomorrow assuming everything goes as planned. We would like to request a waiver for the scheduled weekly BOP test. Please advise if this is possible. Thank You, Brett Packer Tyonek Rig Supervisor 907 - 776 -2081 12/10/2010 Page 2 of e,5 I J vv4J - -- � = '12000 11 000 k 10000 - s QO 90001.-- --..�` 8 oo©�_ --�� 1� p 7000 - - --. �ti o °o 6000- p° 5 - 4000 300 ° o 2000 .. 1000. aV 0 0 . f ' o v 0 o. 0 0 0 0 C LV r \ -Nd \ o 0 °oo s r 0 O C 12/10/2010 2 000 ! , � t ' y ' I,��yy�. L r j 100 t {; •? Ott 1 � f F ! f { �' ? * tAw . ~' Q Cat © 0 00 , 01 d v�t> 0 pp£ 0. v O ,- oo()v o fl ° o °°9 0 0 r ' o � -p O S \ �©© 3004 X00 Y -zo c• V� � y t � t -. a co O` p O1' G A il O 0 y, © Qa �`'- -- oo - '� , ✓ fix,• ^�I�i 1 ' _ pp 00001 - OQO` _ t L}Q4Z L, 2qqq Al AOO 1 qq0. ti 4 4 �p ' 3 ag0 - ° °ao Eqpt? 4A Qvi O k i QQ� 44 .00 r qd�� Q v , • ' �� p `` O- • ! Page 1 of 1 Regg, James B (DOA) c746 -- O S c j From: Tyonek Company Man [KUUK5CM @conocophillips.com] q Sent: Sunday, November 28, 2010 12:10 PMT To: Regg, James B (DOA); Noble, Robert C (DOA); DOA AOGCC Prudhoe Bay; 'bob.fleckenstein @alaska.gov' Attachments: BOP Alaska B -3.xls Gents, Here is the test report from the Tyonek platform. We were finally able to get our a nnular and K oomey problems repaired and everything is working properly. 12/14/2010 STATE OF ALASKA 8/03/09 OIL AND GAS CONSERVATION COMMISSION BOPE Test Report Submit to: iim.regg(c�alaska.gov doa.aogcc. Prudhoe. bav(o)alaska.gov bob.fleckenstein(cDalaska.gov Contractor: Cudd Rig No.: 136 DATE: 11/26/10 Rig Rep.: Brown/Thibodeaux Rig Phone: 776 -2075 Rig Fax: Operator: Conoco Phillips Alaska Op. Phone: 776 -2081 Op. Fax: Rep.: Brake /Rizek E -Mail KUUK5CM @CONOCOPHILLIPS.COM Well Name: NCIU B -3 PTD # 1980590 Operation: Drlg: Workover: X Explor.: Test: Initial: x Weekly: Bi- Weekly Test Pressure: Rams: 250/3500 Annular: 250/3500 Valves: 250/3500 MISC. INSPECTIONS: TEST DATA FLOOR SAFETY VALVES: Test Result Test Result Quantity Test Result Location Gen.: P Well Sign P Upper Kelly 0 NA Housekeeping: P Drl. Rig P Lower Kelly 0 NA PTD On Location P Hazard Sec. P Ball Type 3 P Standing Order Posted P Misc NA Inside BOP 1 FSV Misc 0 NA BOP STACK: Quantity Size /Type Test Result MUD SYSTEM: Visual Alarm Stripper 0 NA Trip Tank Annular Preventer 1 11 "5M FP Pit Level Indicators P P #1 Rams 1 11 "5M PIPE P Flow Indicator P P #2 Rams 1 11" BLINDS P Meth Gas Detector P P #3 Rams 1 11 "5MVBR FP H2S Gas Detector P P #4 Rams 0 NA MS Misc NA NA #5 Rams 0 NA #6 Rams 0 NA Quantity Test Result Choke Ln. Valves 1 21/16 P Inside Reel valves 0 NA HCR Valves 2 21/16 P Kill Line Valves 1 21/16 P Check Valve 0 NA ACCUMULATOR SYSTEM: BOP Misc 2 2" Kill line P Time /Pressure Test Result System Pressure 3000 FP CHOKE MANIFOLD: Pressure After Closure 1500 FP Quantity Test Result 200 psi Attained 7 FP No. Valves 7 P Full Pressure Attained 176 FP Manual Chokes 2 P Blind Switch Covers: All stations Yes Hydraulic Chokes 0 NA Nitgn. Bottles (avg): 2675psi CH Misc 0 NA ACC Misc 0 NA Test Results Number of Failures: 7 Test Time: Hours Repair or replacement of equipment will be made within days. Notify the North Slope Inspector 659 -3607, follow with written confirmation to Supervisor at: jim.regq@alaLka.gov Remarks: Excessive time do to having to change annular out, and changing VBR's ram blocks out. Waiting on parts to repair koomey unit. 24 HOUR NOTICE GIVEN YES X NO Waived By Bob Noble Date 11/13/10 Time Witness Test start 10:45 Finish 2300/11/26/10 BOP 08/03/09 BOP Alaska B -3.xls Page 1 of 5 Regg, James B (DOA) From: Tyonek Company Man [KUUK5CM @conocophillips.com] ( Cie --V J Sent: Sunday, November 28, 2010 12:17 PM NC ,� • � ; To: Regg, James B (DOA); DOA AOGCC Prudhoe Bay; Noble, Robert C (DOA) Subject: Tyonek charts Gentleman, We're having some problems sending the charts from the Platform in a compressed file, please excuse the mul tiple emails for the charts from the Tyonek BOP test finished on 11/26/201 12/14/2010 kn S o• Q tot 1 Q � f ?' �' i , I 1 ,i �C •� 4 ' � ` «r O O O ' O + �p I 011 t� O 1 � IQ TL i-1- 1� D 8 �:tFr �t1 �i l i c4 s o o cj. o J $� r J //� l �.`� i + r + fyi 1 (� +� ,� '�'� VIC r� 1 i l t � , • t � V OO O - CJ 0 OF 000 0? §5 5f of S }� t C� � � o N �n � ^� y O r i n ` : Q � "'.� JQ. 1�od t �-� \ \ s � t t• 1 It 7 O i t r f p..i M 1 � SC t0 A pi� r ' �'�i��l� l':� k� � �� 1{ 7� t , 1 �' I t � I(t v� N I I'I� +� N,I�,�p' 'O^''•irOi 9 r �� -Y j O � � tt � y `' ti •l !t� ifl t rd. �j QUd i 0 Q t�� O l� OS �: Q Q 000! QO O t ti OOS� 00p �s OOS£ • %/ ya q5 Sb OOO °oso / S� 5 SZ pt Sl 0 • N J _. r rr � � � � \,. �, . � O j `b, 1 '{ O� . •, I O � t O O , O O f r � lti - � •' '�i �J \ � r • O � �0 +;� i • YO' �� O O O i i O ss Cox O " V 4 '' O {,' :I O o •s, r x 0 4r O '• - __ - �� oo y O�0 rt OOOZ � y♦ f 0 O O S � OSZ �" VO ON O j 000C S� oos£ 0 000 0? s� 5� Of S {� F � 1 co � O s Q y ti • Page 5 of 5 35 40 45 30 50 25 T rp AS O �5 A0°O O 350 �' 30 _ ~ -t- .:- � '� �•'`' �`s6 �1 O r t \ •� �/ i cy yORTAGE, "N4, s9 x , \ t Q O/C-. f / K ` r I -., I .16, . ' +-�F i r A O 7r $1 l FO p O e5 k x 9 mr �\ fi 4 ` �x '•. k %.X y ! .,4K _ s - �> po s� oOO f °Oy" ss c , Os pt SY Oq 5£ r 12/14/2010 • • Regg, James B (DOA) Page 1 of 5 From: Tyonek Company Man [KUUK5CM @conocophillips.com] Sent: Sunday, November 28, 2010 12:20 PM To: Regg, James B (DOA); DOA AOGCC Prudhoe Bay; Noble, Robert C (DOA) Subject: Tyonek test charts 2 Gentleman, We're having some problems sending the charts from the Platform in a compressed file, please excuse the multiple emails for the charts from the Tyonek BOP test finished on 11/26/2010, these are the final fou charts from t test. 12/14/2010 iesfi C4C� eo c 051 A5 45 400 _ Y i y t0 0 x r USA MWAAt4 k 1 j If 04 46 t� t a�F "o'tl` °" ' 5 000 X r; , 5 { oe S t' OQOf+ 91 os 01 r 1 00 Ync, } i , �, �� / 14 P, � H (� � !-�Q i 1 1 1 � �� 7 � ' \jai. `,. -,�, \, `•,.. `, � ,` `.� p 13 o t� �y 0 1 0 b� t d St ; ��✓� ,r' fi t, OOOy 3r 000t bq 0 0 S aDy14 or 5c sz oz v `� t V 3-`D 15 20 25 e5 A q OF ko � 40 l D OS 1000 k r "a . y4 1 � y ,. o `� 0 S � 4 Vi ° °( �J ry i tolz 1� o\ IA v Ix 4 006 d£ SZ 0Z St 30 35 4 43 45 :- *000 U �o 3500 Soap 4 °QQ rya J 0 A 100 Rho 1 •� € t � f � r t t f f ^� `' ` � 1 j l�Ij � j t • � , , ��t�1"..i ., "� � N w O p i' > c O p ' i iT.,p a © r., i p �O; ' O �,� fir,,. O t• tw r, s , O O O O p p�1i�O ff COO I C4 � Q • • Page 1 of 2 Regg, James B (DOA) From: Tyonek Company Man [KUUK5CM @conocophillips.com]� lZl t4I Zol Sent: Tuesday, November 16, 2010 5:02 PM To: Regg, James B (DOA) AJC_7 Cc: Senden, R. Tyler Subject: RE: Tyonek BOP test Jim, We have a Tap -Root investigation report on the incident if this is what you are looking for. In short what happened is the crane operator removed his foot from a brake pedal while in the rig-up rocess of the C Annular. The drum s ippe on the crane and the Annular fell roughly 4' to the platform deck. We, at that time had no reason to believe there was a justification to send the Annular in for testing since ne equipment was not in a true free fall and it is only an assumption that this may have contributed to our Y p Y current failure. rr In fact, we had already tested the Annular with 2 7/8" pipe, and it tested fine. We were starting to test with a 3 1/2" joint when we had the failure, and can no longer get the valve to function properly. We originally suspected the valving on the Koomey, but have since proven it to be a failed seal on the Annular. We do have a replacement coming from Weatherford once it's testing is complete at Rydril in Anchorage. Please let me know if you require a copy of the Tap -Root, if so I will request the report to be send from the Anchorage office. Jared Brake # 6 Zulb Wells Supervisor ConocoPhillips (907) 776 -2081 From: Regg, James B (DOA) [mailto:jim.regg @alaska.gov] Sent: Tuesday, November 16, 2010 2:33 PM To: Tyonek Company Man Cc: DOA AOGCC Prudhoe Bay; Aubert, Winton G (DOA) Subject: FW: Tyonek BOP test I am requesting CPAI provide the Commission with some additonal information about the dropped annulur preventer at Tyonek platform - the investigation report noting cause is what I have in mind here. If you are not the appropriate contact to assist me with this, please provide the name of individual that I should make the request. Was the annular removed from the platform for an inspection after dropping? From email message below it appears the answer is "no" and the annular was just placed in service for the test. When you send the BOPE test report, also provide images of the test charts for our review. Please use me as your contact for test notification and any updates regarding the annular preventer; see attached Guidance Bulletin. Jim Regg Inspections Supervisor AOGCC 333 W.7th Avenue, Suite 100 Anchorage, AK 99501 907 - 793 -1236 From: Noble, Robert C (DOA) Sent: Tuesday, November 16, 2010 1:56 PM 12/14/2010 . Page 1 of 1 Regg, James B (DOA) From: Regg, James B (DOA) Sent: Tuesday, November 16, 2010 2:33 PM To: 'Kuukpik 5 Company man' Cc: DOA AOGCC Prudhoe Bay; Aubert, Winton G (DOA) Subject: FW: Tyonek BOP test Attachments: Industry Guidance 10- 01.pdf am requesting CPAI provide the Commission with some additonal information about the dropped annulur preventer at Tyonek platform - the investigation report noting cause is what I have in mind here. If you are not the appropriate contact to assist me with this, please provide the name of individual that I should make the request. Was the annular removed from the platform for an inspection after dropping? From email message below it appears the answer is "no" and the annular was just placed in service for the test. When you send the BOPE test report, also provide images of the test charts for our review. Please use me as your contact for test notification and any updates regarding the annular preventer; see attached Guidance Bulletin. Jim Regg Inspections Supervisor AOGCC 333 W.7th Avenue, Suite 100 Anchorage, AK 99501 907 - 793 -1236 From: Noble, Robert C (DOA) Sent: Tuesday, November 16, 2010 1:56 PM To: Regg, James B (DOA) Subject: Fw: Tyonek BOP test Jim I ran into Ken Schramko in the Kenai airport and he told me pretty much what this email has to say. By the time I got to anch I had this email. Bob. From: Tyonek Company Man <KUUK5CM @conocophillips.com> To: Noble, Robert C (DOA) Sent: Tue Nov 16 13:32:19 2010 Subject: Tyonek BOP test Bob, I just wanted to give you a heads up on our BOP test. When we got to the final stages and went to test our Annular, we discovered that is had a bad seal inside and would not function. We're assuming this is a byproduct of the drop it endured from the crane a week prior. We're currently in the process of securing another Annular from Weatehrford in Kenai and hope to have it in on the platform on Thursday. I will let you know or status as soon as we have forward progress. Thanks. Jared Brake ConocoPhillips Wells Supervisor (907) 776 -2081 11/16/2010 To: Regg, James B (DOA) Page 2 of 2 Subject: Fw: Tyonek BOP test Jim I ran into Ken Schramko in the Kenai airport and he told me pretty much what this email has to say. By the time I got to anch I had this email. Bob. From: Tyonek Company Man <KUUK5CM @conocophillips.com> To: Noble, Robert C (DOA) Sent: Tue Nov 16 13:32:19 2010 Subject: Tyonek BOP test Bob, I just wanted to give you a heads up on our BOP test. When we got to the final stages and went to test our Annular, we discovered that is had a bad seal inside and would not function. We're assuming this is a byproduct of the drop it endured from the crane a week prior. We're currently in the process of securing another Annular from Weatehrford in Kenai and hope to have it in on the platform on Thursday. I will let you know or status as soon as we have forward progress. Thanks. Jared Brake ConocoPhillips Wells Supervisor (907) 776 -2081 12/14/2010 • 0 WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. October 26, 2010 Attn.: Christine Shartzer 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Jewelry Log: NCUI B -3 Run Date: 10/19/2010 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of Klinton Wood, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 /V (2 U �- Digital Data in LAS format, Digital Log Image file 1 CD Rom 50- 883 - 20095 -00 �M&U PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating rJ Attn: Klinton Wood 6900 Arctic Blvd. Anchorage, Alaska 99518 a� Office: 907 - 273 -3527 a Fax: 907 - 273 -3535 klinton.wood@halliburton.com Date: Signed: I Well Name Pre 2008 Survey Location NAD27 ASP 4 Northing Easting Post 2008 Survey Location NAD27 ASP4 Northing Easting Distance Moved NCI A-01 2,586,726.69 332,100.19 2,586,726.40 _ 332,102.26 __ 2.09 NCI A-02 2,586,722.85 332,108.29 _ 2,586,721.16 332,111.27 ____ 3.43 ___ NCI A-03 _ __ 2,586,728.60 332,106.22 _ 2,586,728.31 332,109.43 _ 3.22 _ _ _ NCI A-04 _ 2,586,719.62 332,105.09 ____ 2,586,718.58 332,108.09 __ 3.18 NCI A-05 2,586,725.55 332,110.17 2,586,725.14 ______ 332,111.79 1.67 NCI A-06 2,586,719.66 332,102.09 2,586,719.22 332,104.19 2.15 NCI A-07 2,586,727.79 332,103.73 2,586,728.78 332,105.40 1.94 NCI A-08 2,586,720.56 332,098.31 2,586,722.44 332,101.65 3.83 NCI A-09 2,586,666.58 332,039.08 2,586,667.35 332,040.44 1.56 NCI A-10 2,586,670.21 332,040.91 2,586,673.71 332,044.17 4.78 __ _ NCI A-10A 2,586,670.21 332,040.91 ____ 2,586,673.71 332,044.17 4.78 NCI A-11 2,586,670.23 332,039.14 2,586,677.01 ___ 332,041.75 ___ 7.27 __ _ NCI A-12 __ _ 2,586,722.73 _ 331,947.80 _ 2,586,723.59 331,994.15 46.36 NCI A-13 2,586,734.88 331,993.50 ___ 2,586,733.15 331,995.48 2.63 NCI B-01 2,586,730.03 331,999.80 2,586,723.04 331,998.16 7.18 NCI B-01A 2,586,730.03 331,999.80 2,586,723.04 331,998.16 7.18 NCI B-02 2,586,731.14 331,999.29 2,586,729.60 332,001.86 . 3.00 NCI B-03 2,586,731.69 331,986.37 2,586,726.81 331,991.70 7.23 NCI B-03P61 2,586,731.69 331,986.37 2,586,726.81 331,991.70 7.23 • • /9~-- 651 N APR ~ ~ 2D08 r~ REV DATE BY CK APP SCRIPTION REV DATE BY CK DESCRIPTION 1 2/29/08 SAS KWA MODIFY WELL HOUSE SCHEMATIC, SHT.2 ADD MUO LINE ELEV., SHT.3 yo ~ ~ 36 31 T 12 N 31 32 q~ a ~~, ~ zo9i a~ 1 6 _ T 11 N 6 5 N ,w Ro s, rovs• (Y~ sEL. 6 1206' ~ SCALE: I"-1320' --6- --- ~ ~ o ~ ~ 1 6 6 5 12 7 ~ g GENERAL NOTES: ~~~~ ~F /~ \\\+ ~ ~ ~ 1. SEE SHEET 3 FOR COORDINATE TABLE ~''~`S~-~1~ '~P'' i •••'• .• •• ~ 2. SEE SHEET 3 FOR NOTES ON HORIZONTAL AND ':,9 ~j ~ •' ~ ' ~ '~ • VERTICAL SURVEY DATA 49th • ~~ ~ ? 3. SECTION LINES AND TIES ARE BASED ON PROTRACTED ~ ""'°""""""""""""""""""""' j ~ VALUES. ~ ................................. . ....~ i : ~ ~ KENNETH W. AYERS ;' ~o~ • ~ ; • ~• s ',• LS-8535 ~,• ~,~i SURVEYOR'S CERTIFICATE ~ ~ „.....,,, •1\\~ A I HEREBY CERTIFY THAT 1 AM PROPERLY REGISTERED `~P .. ROF AND \\\,;~ ~=~~~~ LICENSED TO PRACTICE LAND SURVEYING IN THE STATE OF ALASKA AND THAT THIS PLAT REPRESENTS A SURVEY DONE BY ME OR UNDER MY DIRECT SUPERVISION AND THAT ALL LOUNSBURY DIMENSIONS AND OTHER DETAILS ARE CORRECT AS OF & nssoclaTES, INC. FEBRUARY 28 2008. SURVEYORS ENGINEERS PLANNERS 907 272 ~ PHONE 54 1 , 1 - : ( 5 AREA: MODULE: UNIT: ConocoPhilli s NORTH COOK INLET p TYONEK PLATFORM Alaska, Inc. WELL CONDUCTOR AS BUILT CADD FILE N0. DRAWING N0: PART: REV: 08-005 AS BUILT 02/27/08 Og-005 AS BU~L_T 1 of 3 1 r~ REV DATE BY CK APP SCRIPTION REV DATE BY CK DESCRIPTION 1 2/29/08 SAS KWA MODIFY WELL HOUSE SCHEMATIC, SHT.2 ADD MUD LINE ELEV., SHT.3 g ~ ~ ,ter ~ ops a ti 9 Rp9 s~ '3 ~ TtlN A9 SO s. row' ~iS SEG 6 ~^ `` ~~ ~Q so 's~, SCALE: 1 "=30' a9 AA' O ESD 600 50 - ESD 600-51 •10 I p •B2 AB A•A• B3~ p5 • • • A3~ A6• AI BI •A5 A 4• • z WELL HOUSE 2 Op ~ zp A1O~ LEGEND: o~ , ~ WELL p WELL CONDUCTOR 0 ESD (EMERGENCY SHUT OFF VALVE( GENERAL NOTES: I. SEE SHEET 3 FOR COORDINATE TABLE 2. SEE SHEET 3 FOR NOTES ON HORIZONTAL AND VERTICAL SURVEY DATA LOUNSBURY 3. NO WELLS EXIST IN WELL HOUSE N0. 4, AND IT WAS NOT & ASSOCIATES, Irrc. A S B UIL T SURVEYORS ENGINEERS PLANNERS 907 272 5451 ~ PH NE J - O : f AREA: MODULE: UML ConocoPhilli s NORT" C°OK INSET TYONEK PLATFORM Alaska, Inc. WELL CONDUCTOR AS BUIET CADD FILE N0. DRAWING N0: PART: REV: 08-005 AS BUILT 02/27/08 ~8~~5 AS BU~~T 2 GE 3 1 1 12/29/08 SAS KWA MODIFY WELL HOUSE SCHEMATIC, SHT.2 A00 MUD LINE ELEV., SHT.3 ASP 20NE4, NAD83, FEES NADI33 GEOGRAPHIC MLLW DESCRIPTION (POINT NO.) NORTHING FASTING LATITUDE LONGITUDE ELEVATION NCIU W ELL TAG NO. WELL HOUSE N0.1 1001 2586492 1472018 61 04 34.38 150 57 03.71 72.0 Conductor 1 1002 2586489 1472017 61 04 34.34 150 57 03.72 73.9 63 1003 2586485 1472019 61 04 34.31 150 57 03.67 74.1 A12 1004 2586485 1472023 61 04 34.31 150 57 03.59 73.8 61 1005 2586487 1472027 61 04 34.33 150 57 03.52 72.0 Conductor 5 1006 2586491 1472027 61 04 34.37 150 57 03.52 73.7 B2 1007 2586495 1472025 61 04 34.41 150 57 03.57 72.1 Conductor 7 1008 2586495 1472021 61 04 34.41 150 57 03.65 73.7 A13 WELL HOUSE N0.2 2001 2586437 1472060 61 04 33.84 150 57 02.83 71.9 Conductor 1 2002 2586433 1472059 61 04 03.38 150 57 02.84 71.9 Conductor 2 2003 2586430 1472062 61 04 33.77 150 57 02.79 71.8 Conductor 3 2004 2586429 1472066 61 04 33.77 150 57 02.71 73.4 A9 2005 2586431 1472069 61 04 33.79 150 57 02.65 71.9 Conductor 5 2006 2586435 1472069 61 04 33.83 150 57 02.64 73.3 A10 2007 2586439 1472067 61 04 33.86 150 57 02.69 73.3 A11 2008 2586439 1472063 61 04 33.87 150 57 02.77 71.9 Conductor 8 WELL HOUSE N0.3 3001 2586488 1472128 61 04 34.36 150 57 01.47 73.0 Al 3002 2586484 1472127 61 04 34.32 150 57 01.48 73.1 A8 3003 2586481 1472130 61 04 34.29 150 57 01.43 73.1 A6 3004 2586480 1472133 61 04 34.28 150 57 01.35 73.0 A4 3005 2586483 1472137 61 04 34.31 150 57 01.29 73.0 A2 3006 2586487 1472137 61 04 34.34 150 57 01.28 73.0 A5 3007 2586490 1472135 61 04 34.38 150 57 01.33 73.0 A3 3008 2586490 1472131 61 04 34.38 150 57 01.41 73.3 A7 50 2586540 1472069 61 04 34.86 150 57 02.69 72.7 ESD Vale 600-50 51 2586501 1472011 61 04 34.46 150 57 03.86 72.6 ESD Val~re 600-51 100 2586572 1472123 61 04 35.18 150 57 01.58 115.3 Top center helipad -101' MUD LINE SURVEY NOTES: 1. ALL COORDINATES ARE ASP ZONE 4, NAD83, US SURVEY FEET. GEOGRAPHIC COORDINATES ARE NAD83. 2. ELEVATIONS ARE IN FEET, BASED ON MLLW, REFERENCED TO DRAWING N0. MPD- TY04-2021, SHEET I OF I, REV. 2 3. ALL AS BUILTS ARE TO THE CENTER OF EXISTING STRUCTURE. 4. WELL CONDUCTOR ARE VERTICALLY AS BUILT TO THE TOP OF A 1/4" STEEL LID, TACK WELDED TO THE TOP OF THE CONDUCTOR. 5. WELLS ARE VERTICALLY AS BUILT TO THE TOP OF THE LOUNSBURY LOWEST HORIZONTAL FLANGE ON THE WELL. & assoclATES, INC. SURVEYORS ENGINEERS PLANNERS ~ PHONE: f907f 272-5451 ~ AREA: MODULE: UNIT: ConocoPhillips NORTH COOK INSET TYONEK PLATFORM Alaska, Inc. WELL CONDUCTOR AS BUILT CADD FILE N0. DRAWING N0: PART: REV: 08-005 AS BUNT 02/27/08 ~8~~5 AS BUILT 3 of 3 1 e e MICROFILMED 07/25/06 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE F:\LaserFidl~\CvrPgs _Inserts\Mícrofilm _ Marker.doc ((Ù Y [f;\ lr- ¡ IF ¡1)i f? '\\ dILl. ¡ ¡þ ¡ii' ¡þ rUI iLl ¡n\ ¡ IL \!ï! \; ~1 .U UW L::::; ~....: f-:-', n in ~'\ ï-~/7 f7"\ ,fH : ¡ i A \ t \i...,,1 , '/' ! fj \ [,\,1, "\ '- " '1\\ LJI Ii. ¡t,', ," i~\ !u Lr-G I ¡ ¡ U~ @) U\} Lr~~ AI1A.SIiA. OILAlVD GAS CONSERVATION COMMISSION October 20, 2004 Wade Gilpin Alaska Dept. of Environmental Conservation 555 Cordova St., 2nd Floor Anchorage, AK 99501 Re: North Cook InletPlatfonn ConocoPhillips Alaska, Inc. Tyonek Deep Well Abandonments Dear Mr. Gilpen: /? c¡(- (/~'1 FRANK H. MURKOWSKI, GOVERNOR 333 W. -¡'IIi AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 This letter is in response to your inquiry regarding the plugging of the "deep" oil wells drilled from ConocoPhillips' North Cook Inlet or Tyonek Platfonn in Cook Inlet. Your message asked if the abandonments were in accord with 20 AAC 25.105. 25.105 is applicable when all operations on a property are completed which is not the case here. Specific well plugging operations must be in accord with 20 AAC 25.112. During the 1990s a total of 4 exploration wells were drilled from the platfonn to determine if developable oil reserves were present. Oil was encountered in the deep formations below 12,000', however it was detennined to be non-commercial. The deep intervals of these wells were subsequently plugged and abandoned and shallower gas intervals completed and placed into production. I have reviewed the infonnation contained in the files for the respective wells. The deep intervals of NCro A-13 (fonnerly Sunfish #2) were abandoned in late 1993 as part of the original work program. An AOGCC Inspector did not witness the plugging operations. Based on my review of the file, the work perfonned confonns to the requirements of 20 AAC 25.112. The deep intervals in the remaining wells, B-OIA, B-02 and B-03, were plugged and abandoned in late 2002. An AOGCC Inspector did witness weight "tags" and pressures tests to verify the competence of the plugs on each well subsequent to the cementing operations. These verifications were in accord with 20 AAC 25.112 (g)(1) and (2) and the Inspector reported that the plugs were satisfactorily verified. SCANNED OCT 2 7 2004 ... Wade Gilpin October 20, 2004 Page 2 of2 Based on my review of the information contained in the AOGCC's wells files, I confirm that any potential oil intervals penetrated by the 4 "deep" exploration wells were satisfactorily plugged and abandoned in compliance with AOGCC regulation 20 AAC 25.112. Please feel free to contact me with any questions. Sincerely, ft~ ~ '- Thomas E. Maunder, PE ~ Sr. Petroleum Engineer cc: Well file: NCIU A-13 PTD 192-106 NCIU B-OIA PTD 198-002 NCIU B-02 PTD 197-210 NCIU B-03 PTD 198-059 Field file: North Cook Inlet Unit SCANNED OCT 2 7 2004 ~E: Tyonek Platform ?'s Subject: RE: Tyonek Platform ?'s From: "Gilpin, Wade" <Wade - Gilpin@dec.state.ak.us> Date: Fri, 08 Oct 200408:28:29 -0800 To: 'Thomas Maunder' <tom_maunder@admin.state.ak.us> Thanks Tom - Here is my snail mail address: Alaska Dept. of Environmental Conservation Attn: Wade Gilpin 555 Cordova St.} 2nd Floor Anchorage, AK 99501 tks wg -----Original Message----- From: Thomas Maunder [mailto:tom_maunder@admin.state.ak.us] Sent: Friday, October 08, 2004 7:30 AM To: Gilpin, Wade Subject: Re: Tyonek Platform ?'s Hi Wade, Sorry not to get back to you sooner. so we can send the letter. Thanks, Tom Maunder, PE Could you please provide me with your snail mail address Gilpin, Wade wrote: HI Tom - I have been working this issue with our FR (Financial Responsibility) folks here. For them to lift the FR requirement for Tyonek (and for us to rescind the C-plan), they need confirmation in writing that all wells were plugged/abandoned iaw 20 AAC 25.105. Can you possibly provide us letter related to this? Thanks Wade -----Original Message----- From: Thomas Maunder rmailto:tommaunder@admin.state.ak.us] Sent: Thursday, September 16, 2004 7:54 AM To: Gilpin, Wade Cc: John D Hartz Subject: Re: Tyonek Platform ?'s Wade, Based on your reply, you are indeed concerned about the "B" or deep wells that were drilled in 1997 - 1998. I have checked our records with regard to the 3 wells. The deeper intervals are plugged in accord with our 1 of3 SCANNED OCT 2 7 2004 10/8/2004 10:18 AM fŒ: Tyonek Platform ?'s 2of3 regulations. I do not have any concern about potential oil leakage. Tom Maunder, PE AOGCC Gilpin, Wade wrote: Thanks Tom - Sounds like I got this all wrong I'm quite the novice. Honestly, I don't know the difference between the B and Deep wells. We are concerned in any of the wells that had perforations into potential oil bearing zones. What I meant was concerns about the mechanical integrity of the well bore (after P&A), and the lack of oil leakage from the plugged perforations. Mostly I need to confirm that you guys don't have any concerns about potential oil leakage. Thanks ; I i Wade -----Original Message----- From: Thomas Maunder fmailto:tom maunder@admin.state.ak.us] Sent: Tuesday, September 14, 2004 12:51 PM To: Gilpin, Wade Cc: John D Hartz Subject: Re: Tyonek Platform ?'s Wade, Are you talking of the "B or deep" wells. As I remember, we did have an Inspector witness the verifications of the plugging activities. CP AI's intent was to convert or re-equip the wells as gas wells from the shallower fonnations. What do you mean by "structural concerns"?? Tom Maunder, PE AOGCC Gilpin, Wade wrote: Hi Tom - I talked with Jack Hartz about this at the end of last week and he mentioned that you are who I should be talking to about Tyonek. I have been talking with Steve Geddes of CPA lately and CPA is interested in deactivating thier C-plan since they are only involved gas production. My questions to you are: Did you guys witness the P&A for the well(s)? If so, was everything done satisfactorily? Do you have any structural integrity concerns? I am just looking to make sure they have covered everything to your satisfaction as well as follow our regs/guideliens for deactivation. SCANNED OCT 2 7 2004. 10/8/2004 10: 18 AM ~E: Tyonek Platform ?'s .. t. ~ Thanks for you help! Wade Gilpin Environmental Specialist Industry Preparedness Program Alaska Dept of Environmental Conservation 555 Cordova St. Anchorage AK 99516 (907) 269-3060 wade ç¡ilpintéV,dec.state.ak.us 30f3 SCANNED OCT2 7 2004 10/8/2004 10: 18 AM )9?J -Q8C¡ ŒI2511. WELL LOG TRANSMITTAL ProActive Diagnðstic Services, Inc. To: State of Alaska AOGCC 333 W. 7thStreet Suite # 700 Anchorage. Alaska 99501 RE: Distribution - Final Print(s) The technical data listed below is being submitted herewith. Please acknowledge 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 LOG DIGITAL MYLAR/ BLUE LINE REPORT WELL DATE TYPE OR SEPIA PRINT(S) OR CD-ROM FILM COLOR Open Hole 8-03 1-17-04 Res. Eva!. CH 1:41/~n 1 1 . -- - - Mech. CH 1 Caliper Survey 1 Signed: ~'U. ~D<--o ~~~"" . , RECEIVED Date: FCß 2 .. ,,00zt '-. , L Print Name: Alaska Oi! & Gas Cons. Commission Þ~n~_e ." .' .,., PRoACIivE DiAGNOSTic SERViCES, INC., PO Box 1 ~69 STAffoRd IX 77477 Phone:(281) 565-9085 Fax:(281) 565'-1369 E-mail: Dds@memorvlog.com Website: www.memorvlog.com ~~bffi ~~:'¡kmlEr:i MA~ 1 5 2004 RE: Tyonek Platform 1'5 Subject: RE: Tyonek Platfonn 1's From: "Gilpin, Wade" <Wade - Gilpin@dec.state.ak.us> Date: Thu, 16 Sep 2004 08:15:16 -0800 To: 'Thomas Maunder' <tom_maunder@admin.state.ak.us> ~C\\j ß-~ Thanks Tom. Wade \C\ ~-Os-'\ -----Original Message----- From: Thomas Maunder [mailto:tom_maunder@admin.state.ak.us] Sent: Thursday, September 16, 2004 7:54 AM To: Gilpin, Wade Cc: John D Hartz Subject: Re: Tyonek Platform ?'S Wade, Based on your reply, you are indeed concerned about the "B" or deep wells that were drilled in 1997 - 1998. I have checked our records with regard to the 3 wells. The deeper intervals are plugged in accord with our regulations. I do not have any concern about potential oil leakage. Tom Maunder, PE AOGCC Gilpin, Wade wrote: Thanks Tom - Sounds like I got this all wrong I'm quite the novice. Honestly, I don't know the difference between the B and Deep wells. We are concerned in any of the wells that had perforations into potential oil bearing zones. What I meant was concerns about the mechanical integrity of the well bore (after P&A), and the lack of oil leakage from the plugged perforations. Mostly, I need to confirm that you guys don't have any concerns about potential oil leakage. Thanks Wade -----Original Message----- From: Thomas Maunder rmailto:tom maunder@admin.state.ak.usl Sent: Tuesday, September 14, 2004 12:51 PM To: Gilpin, Wade Cc: John D Hartz Subject: Re: Tyonek Platform ?'S Wade, Are you talking of the "B or deep" wells. As I remember, we did have an Inspector witness the verifications of the plugging activities. CP AI's intent was to convert or re-equip the wells as gas wells from the shallower fonnations. What do you mean by "structural concerns"?? 10f2 9/16/20048:18 AM RE: Tyonek Platform ?'5 2 of2 Tom Maunder, PE AOGCC Gilpin, Wade wrote: Hi Tom - I talked with Jack Hartz about this at the end of last week and he mentioned that you are who I should be talking to about Tyonek. I have been talking with Steve Geddes of CPA lately and CPA is interested in deactivating thier C-plan since they are only involved gas production. My questions to you are: Did you guys witness the P&A for the well(s)? If so, was everything done satisfactorily? Do you have any structural integrity concerns? I am just looking to make sure they have covered everything to your satisfaction as well as follow our regs/guideliens for deactivation. Thanks for you help! Wade Gilpin Environmental Specialist Industry Preparedness Program Alaska Dept of Environmental Conservation 555 Cordova St. Anchorage AK 99516 (907) 269-3060 wade Qilpin@dec.state.ak.us 9/16/20048:18 AM Paul Mazzolini \( Exploration/Cook Inlet Drilling T earn Leader Drilling & Wells ~ P.O. Box 100360 Gono~oPh.III.lps Anchorage,AK 99510-0360 ~ Phone: 907-263-4603 December 18, 2003 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Subject: Well Completion Report for NCI 8-03 (APD # 198-059/303-137) Dear Commissioner: ConocoPhillips Alaska, Inc. submits the attached Well Completion Report for the North Cook Inlet well 8-03. This report is for the recent workover operations on this well. If you have any questions regarding this matter, please contact me at 263-4603. Sincerely, rrJ¿ rywrl~ P. Mazzolini Exploration/Cook Inlet Drilling Team Leader CPAI Drilling PM/skad RECEIVED DEC 1 8 2003 Alaska Oil & Gas Cons. Commission Anchorage S~NED JJ\N 2 @ 2004 n Q I GIN A L ( STATE OF ALASKA ( ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1a. Well Status: Oil D Gas ~ Plugged D Abandoned D Suspended D WAG D 1b. Well Class: 20AAC 25.105 20AAC 25.110 Development 0 Exploratory D GINJ D WINJ D WDSPL D No. of Completions - Other - Service D Stratigraphic Test D 2. Operator Name: 5. Date Comp., Susp., 12. Permit to Drill Number: ConocoPhillips Alaska, Inc. or Aband.: 11/20103 198-059/303-137 3. Address: 6. Date Spudded: 13. API Number: P. O. Box 100360, Anchorage, AK 99510-0360 May 3,1998 50-883-20095-00 4a. Location of Well (Govemmental Section): Tyonek Platform Leg 1 Slot 2 7. Date TD Reached: 14. Well Name and Number: Surface: 4029' FSL, 4056' FEL, Sec. 6, T11 N, R9W, SM 1998 NCI U B-03 At Top Productive 8. KB Elevation (ft): 15. Field/Pool(s): Horizon: N/A 43' RKB 1119' AMSL North Cook Inlet Field Total Depth: 9. Plug Back Depth (MD + TVD): Tyonek Deep Pool 4036' FSL, 3282' FEL, Sec. 13, T11N, R10W, SM 11181' MD 1 9478' TVD 4b. Location of Well (State Base Plane Coordinates): :;st6 f!J9 10. Total Depth (MD + TVD): 16. Property Designation: Surface: x-~§JJrPo y- 25Z6429' Zone- 4 17864' MD 113356' TVD ADL 17589, North Cook Inlet Unit TPI: NA Zone- 4 11. Depth where SSSV set: 17. Land Use Permit: Total Depth: x- 327586 v- 2576240 Zone- 4 SSSV @ 418' N/A 18. Directional Survey: Yes D No~ 19. Water Depth, if Offshore: 20. Thickness of 130' feet MSL Permafrost: N/A 21. Logs Run: 22. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 30" 547# 47' 461' Driven 20" 133# K-55 47' 1214' 24" 1364sxpremiumClass'G'cement 13.375" 72# L-80 40' 4400' 16" 1600 sx premium Class 'G' cement 9.625" 53.5# P-110 40' 11761' 12.25" 2767 sx premium Class 'G' cement 23. Perforations open to Production (MD + TVD of Top and Bottom 24. TUBING RECORD Interval, Size and Number; if none, state "none"): SIZE DEPTH SET (MD) PACKER SET (MD) 5.5" 14.5" 4317' 1 8430' 4349',4830',5308',5777', 6277',7217',8155' 4463' - 8145' MD 4087' - 7057' TVD 18 spf 25. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED N/A 26. PRODUCTION TEST Date First Injection Method of Operation (Flowing, gas lift, etc.) November 23, 2003 Gas Producer Date of Test Hours Tested Production for OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO 11/23/2003 24 hours Test Period --> n/a 4800 160 Flow Tubing Casing Pressure Calculated OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY - API (corr) press. 250 psi 600 psig 24-Hour Rate -> n/a 4800 160 not available 27. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water (attach separate sheet, if neceRE C E , VE D Submit core chips; if none, state "none". ::";;";,>, ,:::r:¡;,tl DEC 1 82003 ~,'C'TI;, ::'¡:~~ "i" \ NONE ~ _.LL_::W~~~~:A; Alaska Oil & Gas Cons. Commission \ ;:ii:" , A h ;,; :""::'" I, "." < nc orage t ,!, t I,~ ~~~:' , I' ~"lt:,.,~".~:,~~~~::;~3~:", :~( Form 10-407 Revised 2/2003 C~~ÞßE~~~E",Ao~ Submit in duplicate U ;\ ~ ¡." I ~ \j t"i J..,,,~ G ~ . ,;' 28. \ 29. ~ GEOLOGIC MARKERS FORMATION TESTS NAME MD TVD Include and briefly summarize test results. List intervals tested, and attach detailed supporting data as necessary. If no tests were conducted, state "None". Top Open Hole Logs 4323' 3698' Top Beluga Frn. 5418' 4427' Top Tyonek Fm. 10190' 7791' N/A RECEIVED DEC 1 8 Z003 Alaska Oil & Gas Cons. Commission Anchorage 30. LIST OF ATTACHMENTS Surnmary of Daily Operations, Schernatics 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Tim Billingsley Printed NaV'""a~7Ø(:¡;L-, azzolin', Title: Cook Inlet Drillina Tearn Leader (2..-/ '7 > Signature Phone Date / ZCJC:J::!J Prepared by Sharon Allsup-Drake INSTRUCTIONS General: This form is designed for subrnitting a complete and correct well cornpletion 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 cornpletion is defined as a well producing from rnore than one pool with production frorn each pool completely segregated. Each segregated pool is a cornpletion. Item 4b: TPI (Top of Producing Interval). Item 8: the Kelly Bushing elevation in feet abour mean low low water. Use same as reference for depth measurements given in other spaces on this forrn and in any attachrnents. Item 13: The API number reported to AOGCC rnust be 14 digits (ex: 50-029-20123-00-00). Item 20: True vertical thickness. Item 22: Attached supplernental 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 cornpleted for separate production from rnore 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. (Subrnit 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, Subrnersible, Water Injection, Gas Injection, Shut-in, Other (explain). Item 27: If no cores taken, indicate "none". Item 29: List all test inforrnation. If none, state "None". Form 10-407 Revised 2/2003 0 RIG I N A L \ (' Conocó"Phillips Pro osed Perfs yonek Remedial Program 2003 \ L B-03 Well Pkrs, Jewelery Top Base Perfs Blanks CMU 4247' Perf Perf ft ft SC1-R 4349' 4463 4547 84 CI1 23 AIIIIII 4570 4663 93 CI2 27 4690 4701 11 CI3 47 4748 4820 72 CI4 Distance (ft) Between Intervals 68 SC 1-L 4830' 4888 4918 30 CI4 9 4927 4955 28 CI5 105 5060 5090 30 CI7 110 5200 5214 14 CI8 54 5268 5291 23 CI9 Distance (ft) Between Intervals 64 SC1-L 5308' 5355 5402 47 CI11 186 5588 5595 7 BelB 157 5752 5765 13 Bel b Distance (ft) Between Intervals 168 SC 1-L 5777' 5933 5939 6 BelC 99 6038 6046 8 BelD 2 6048 6054 6 BelD 166 6220 6227 7 BelE PBTD=11181' 34 ----------- 6261 6268 7 BelE ------------ ------------ Distance (ft) Between Intervals 360 SC1-L 6277' 6628 6648 20 BelH 7 6655 6672 17 BelJ 283 Braden blank @ 6855'-6864' 6955 6978 23 Bel L 202 Braden blank @ 7089'-7098' 7180 7197 17 Bel L Distance (ft) Between Intervals 298 SC1-L 7217' 7495 7517 22 BelN 183 7700 7727 27 BelP 228 Braden blank @ 7767'-7776' 7955 7968 13 BelQ 137 9-5/8 8105 8145 40 BelR Total TCP 665 3017 Sump 8155' Distance (ft) Between Intervals 355 8500 8516 16 Future E-line, Bel T ) Distance (ft) Between Intervals 356 8872 8900 28 Future E-line, Bel U Total 709 """9-5/8" 53.5# P-110 casing Page 1 - NCIU B-3 ( ( ~ ConocoPhillips NCIU B-3 Gravel Pack Cornpletion as run 11/18/03 \ L BPV (Mke, Type, OD) Cameron 5-"H" I RKB-LDS: 42.57 Tbg Hr (Make, Type) Vet co 10-314" x 5-1/2" w/5-1/2" csg BTC btm, 5.875" MCA top Annulus Fluid: 9.6 ppg KCUCaCL with corrosion inhibitor I RKB-MSL: 119.00 Water Depth: 130.00 OD TOP 8TM WT GRADE. CONN. BURST CO# TRO ......... Casing Strings PPCO Allowable Ratings 30" 0 461 547 Ibslft WELD 20" 0 1214 1331bslft K-55 Dnl-Quip " 133/8" 0 4400 721bslft L-80 BT&C 13-3/8 95/8" 0 11761 53.51bslFt P-110 BT&C 7" liner 11560 15301 321bslFt P-110 5" liner 11420 17150 181bslFt P-110 BT&C 5-1/2" tbg 0 4316 15.51blft L-80 BTC modified casing thread 31/2" 17159 17864 131bs/Ft P-110 BT&C I 1 CEMENTING SUMMARY 95/8" Cemented with 2767 sx (914 bbl) 6/17/98 Lead 2342 sx (914 bbl) Tail 424 sx (90 bbl) 12-114" hole TD @ 13,315' MD, 9-5/8" casing stuck off bottom by 1554'. No mention of cmt returns to surf but 16,000' of cmt pumped up annulus. USIT 9/11/03 logged good cmt up to 4000' Top Length Tubing 0' 4316' 5-1/2" 15.5#/ft, L-80, BTC modified csg thread 418' 5-1/2" Cameo TRM-4E 5-1/2' TRSSSV with 4.562' X profile 1501' 5-1/2" X 1-1/2" Carnco MMG GLM with live valves 2675' 5-1/2" X 1-1/2" Carnco MMG GLM with live valves 3922' 5-1/2" X 1-1/2" Carnco MMG GLM with orifice 4247' Baker CMU 5-1/2" sliding sleeve 4268' 30' One jt of 5-1/2" 15.5#, L-80 BTC rnod csg thread PBTD 4317' 18' Baker Seal Assy, 6" OD X 4.75" ID with 15' of seals @ 11181' 10/15'03 . . :-:-:-:-:-:-:-:-~-:-:-:-:-:- 4319' 17.35' Baker PBR, 6.000" ID, run on dnll pipe on 11/16/03 ---------------------------- 4341' 2.6' Baker KOIV, 5.000" ID, busted open on 11/19/03 4348' 0.87' Baker Anchor Seal Assy 4349' Baker 9-5/8" 53.5# SC-1 R packer assy with KOIV @ 4381' 4830' Baker 9-5/8" 53.5# SC-1 L packer 5308' Baker 9-5/8" 53.5# SC-1 L packer 5777' Baker 9-5/8" 53.5# SC-1 L packer 6277' Baker 9-5/8" 53.5# SC-1 L packer 7217' Baker 9-5/8" 53.5# SC-1L packer 8155' 15' Baker 9-5/8" 53.5# SC-1 R surnp packer w/MOE 8168' 5-1/2" 15.5# BTC tbg, 6 joints 8366' Xover, 5-1/2" BTC to 4-1/2" IBT 8397' Baker 4-1/2" X profile 8430' 4-1/2" 12.6# IBT tbg tail at 8430 Gravel Pack Perfs are 4463' - 8145', see attached for exact details 5-1/2" SLHT blanks and screen have three 9' blanks with RA rnarkers at: 6855', 7089' and 7767' Old Tubing tally has not been located. Measurernents below are approxirnate. 3-1/2" 12.95# P-110 tubing to approximately 13,700' MD 9-5/8 11,181 CalcTOCon 10/15/03= 11181' 11,354 BWD packer with seals top @ approxirnately 11354' 11,362 Bevel guide over tubing stub frorn 11362' to 11368' Tubing chernically cut at 11362' after failed pressure test 11,380 AHC Packer @ appx 11,380' (frorn first attempt, tubing would not hold pressure) j 11,398 Top of 24' wireline fish on X-nipple @ 11406' ctrn 11,418 X-nipple (2.313") @ 11418' wlm 13,700 Tubing tail at 13,700' MD no oil perforations Top of fill @ 16890 Page 1 - NCIU B-3 j"" i' \ II, North Cook Inlet Unit No. B-3 Daily Summary Rig W orkover for Shallow Gas Recompletion 9/29/03 Release rig from A-lOa at 06:00 on 9/29/03. Prep rig f/ move f/ A-lOa to B-3. Skid rig 45' towards office complex. Skid utility & pits to edge of platform by unit crane. Load MV Pioneer boat with rig parts and send same to dock (Boat #1). 9/30/03 Loaded MV Pioneer Service with rig parts and transfer to dock (boat #2). Started loading Boat #3 MV Monarch. High wind and seas interrupted loading of Boat #3 at platform, WOW for 7 hrs. Finished loading MV Monarch- Boat #3 and transfer to dock. 10/01103 Skidded rig to Leg 2 over well B-3 and secured rig. Partially unloaded MV Monarch- Boat #1 on platform until high wind and seas. WOW for 9 hrs. 10/02/03 Unloaded MV Monarch Boat #2 until weather came up again. WOW for 11.5 hrs. Unload boat. RU while boat went to reload. Off loaded boat #3 on platform, all of rig is now on platform. 10/3/03 Unloaded MV Monarch. Set loads in place to clear deck. Unload Pioneer Service. RU. 10/4/03 Rigged up on Well B 3. Accept rig at 12:00 noon 10/4/03. NU BOP. Unload Pioneer Service boat. 10/5/03 Tested BOPE. RU Schlumberger. RIH with string shot to 8808', misfire. 10/6/03 Rill with string shot #2, fired at 8808'-8818'. Ran 2.48" Gauge Ring/Junk Baket to 8897', Ran tubing punch no fire. Ran Chemical cutter to 8814', no cut and cutter stuck on the way out at 1250'. Dragged cutter up to SSSV restriction at 416', pulled out of rope socker. RU slick line and jarred cutter down hole. 10/7/03 Pushed cutter to 1350' and then cutter fell down hole. RIH to 9000' without seeing cutter. Ran Tubing punch and punched holes at 8829' -8831'. U-tube equalized fluid. Ran and shot string shot at 8836' -8847'. Ran Chemical cutter to cut tubing. String parted while applying PU of 150k to apply tension for chemical cut. POOH and laid down cutter and circulated out brine. 10/8/03 POOH and laid down 355 Its. 3 1/2" tubing and completion including seals. 10/9/03 Changed rams to 4-1/2", pick up casing scraper BHA and move DP. RIH picking up drill pipe. B-3 daily summary 11-19-03.doc 1 ~ ( 10/10103 Rill picking up drill pipe. Circulated. POOH with scrapers. RU up loggers. 10/11/03 Ran CHFR (cased hole fonnation resistivity), tool failed with 1000' left to log. POOH with CHFR. Ran USIT log. 10/12/03 Finished USIT log. Tested BOP. Test casing to 3000 psi. RU loggers. Ran CHMDT, obtained two points and plugged same. Plugger shaft failed after last plug. POOH and repair CHMCT. 10/13/03 Ran CHMDT, obtained two points and plugged same, bit failed on second point. POOH and repaired same. Ran CHMDT, obtained 4 points and plugged same, bit failed on fourth point. POOH and repaired same. Ran CHMDT and obtained one point and plugged same. Packer failed on second point attempt, POOH with CHMDT. Ran RST. 10/14/03 RU MDT logging tools, Rill, bit failed- POOH, change drill block, RIH wI MDT- unable to get seal- POOH change pIa, RIH wI MDT-sample 2 zones, RID Schlumb. Rill with 3 1/2" tubing stinger and 4 1/2" dp for cement plug job. 10/15/03 Rill to 11331' dpm, circ out 140 bbls 10.6 brine, mix & pump 10.5 bbls cmt, displace, POH 10 stnd, circ, calc TOC @ 11181', POOH. 10/16/03 Rill wI scrapers, brush and magnet to 9100'. Circ well. Test csg to 2000 psi. Failed. POH. 10/17/03 Rill wI Retrievamatic test pIa. Locate 9-5/8" csg leak at top CHMDT hole at 4900'. POH wI pIa, PU Baker SC-1R sump packer assembly. RIH on 4 1/2" dp. 10/18/03 RU Schlum to correlate packer on depth, set Baker SC-IR sump packer @ 8155' wlm, release running tool with annulus pressure. Clean pits, mix & pump caustic wash, inject wash, pump acid pickle down drill pipe. 10/19/03 BJ finish pumping acid, displace acid to bottom of DP , reverse acid out of DP@ 2 bpm to surface, continue reversing 2 string volumes, circ down dp 2 hole valumes with filtered brine, POOH with DP and pIa running tool, test BOPE--witness waived by AOGCC insp Lou Grimaldi, MU pIa plug BHA. 10/20103 Rill, set plug in SC-IR packer @ 8155'. POOH 24'. Pour 8 gals 12/20 flex sand into dp, chase wI 5 bbls, work pipe, attempt to tag -after 2 hr, no sand, rev out sand, pour 20/40 sand in dp, chase wI 40 bbl KCL, tag, 3' higher at 8152', POOH, PU TCP guns. B-3 daily summary 11-19-03.doc 2 ( ( 10/21/03 Rill with Schlum 7" guns, fill drill pipe with fluid level at 1770' from surface (400 psi overbalance to MDT hole at 4900'), tag sand on top of sump packer, PU to place guns on depth, RU surface firing equipment, monitor well, set packer @ 4235' WLM (= bottom shot @ 8145' WLM, top shot @ 4463' WLM), pressure annulus to 2000 psi to open PTV and expose formation to 1770' fluid level in DP. Pressure test lines, fire guns with two nitrogen pressure pulses down drill pipe, rev 760 bbls, unseat pIa, pull 2 stands,monitor well, 90-70 bph losses, pump 54 bbl HEC pill, losses reduced to 22 bph, POOH with guns. 10/22/03 Serv rig, POOH w/ Schlum 7" guns, RIH with 9-5/8" scraper. 10/23/03 Con't RIH w/ 9 5/8" scraper & magnet to 4289', monitor well-SIDPP = 0 psi, casing = 140 psi, circ, RIH to 5024', circ, shut in well, monitor- SIDPP = 0 psi but climbed to 340 psi, casing = 40 psi and climbed to 140 psi, circ through choke, install dart valve in drill pipe, strip in hole f/ 5024' to 8112', circ dp vol, monitor- SIDPP = 110 psi, SICP = 152 psi, circ BU, shut in, monitor while increasing surf fluids to 9.1 ppg. 10/24/03 Monitor casing pressure w/ increase surf fluids to 9.1 ppg, displace well to 9.1 ppg following pressure schedule, monitor well w/ building surface volume & filtering surface volume, circ 9.1 ppg filtering returns. 10/25/03 Circ 9.1 ppg through gas buster, filtering returns, monitor well losing -12 bph while clean filter press, circ, shut in, monitor, build surface volume, filter, POOH f/ 8112' to 7190', hole fill low, monitor well w/ flow, RIH, to 8112', monitor well- no flow, losses at 5 bph. 10/26/03 Monitor well, taking 10 bph. raising mw to 9.4 ppg in pits and building volume while filtering, losses down to 5-6 bph, start displacing hole to 9.4 ppg, open dart valve w/ 1200 psi, circ at 2.3 bpm through choke. 10/27/03 Displace well to 9.4 ppg brine. Monitor losses at 14 bph. Short trip from 8112' to 4415' with net losses to formation of 10 bph. Monitor well with scraper at 4415', 15 bph losses. RIH to 8112', losses at 12 bph. Circ BU and gas at surface. 10/28/03 Monitor well. taking 12.7 bph. Circ thru choke to remove all gas, losses increased to 25 BPH. Spotted HEC pill across perfs. Raising mw to 9.6 ppg and building volume while filtering. Loss rate 25 BPH. 10/29/03 Raising mw to 9.6 ppg and building volume while filtering. Loss rate 25 BPH. Displaced 9.6 PPG brine from 8112 to 6285'. Monitor well, taking 13.6 bph. Circ 9.6 ppg brine to 5030'. POOH to 5030'. Spotted 68 bbl HEC pill. Monitored well, losses at 13.4 bph. POOH to 4230'. Displace from 4230' to surface w/ 9.6. Unplug press. B-3 daily summary 11-19-03.doc 3 ( ( 10/30/03 Spotted 50 bbl HEC pill. Losses slightly decreased from 20 bph to 18.2 bph in 2 hr. POOH to 4170'. Observed well-losses at 14 bph. POOH and laid down casing scraper BHA. Tested BOP. Laid down DC's. Made up bailer and RIH. 10/31/03 Rill with bailer, tag fill at 8134', bailed debris from 8134' to 8150 and latch plug at 8150', losses at 21 bph. POH to 5501' and observe well, losses = 7.5 bph. Circ BU, Observed well, losses = 13 bph. POH to 5000', losses = 7 bph. POOH and laid down Bailer and plug. RU and made up 5-1/2" Gravel pack screen assembly to 200'. 11/01/03 Rill w/ appx 3772' of 5-1/2" Gravel pack screens, blanks and 6 packers. RU and ran 4" inner string. Trying to work seals through seal bore. 11/02/03 Ran 4" seals with difficulty thru seal bores at 444' and 922' but could not pass thru seal bore at 1392'. POOH and lay down 4" inner string. Inspect seals, no damage, dressed seals and RIH with 4" inner string again with more grease on seals. 11/3/03 Trying to work seals through seal bore, set down at 1392'. POOH, Checked seals and RIH with 4" inner string and only 1 seal set. No success, set down at 1392'. POOH Checked seals. POOH and laid down screens down to 3rd SC- 1L packer assembly. 11/4/03 POOH and laid down screens. Changed out 3rd SC-1L pkr assy and drifted with seals could not pass #4 pkr assy. POOH and changed XO's on pkr #4 & #5, Checked with seals. Checked XO on snap in sub, OK. PU and changed XO on pkr #3. RIH with screens. (XO on top of pkr assy #3, 4 and 5 were 4.69" ID and the 4.75" seals would not pass) 11/5/03 Rill with screens, drifted all pkr assys with seals. RU and ran 4" inner string. 11/6/03 Ran 4" inner string. Spaced out and tested seals. Ran 2 7/8" inner string and spaced out. Tested bypass. MU top packer assy, RIH with GP assembly on DP to 7143'. 11/7/03 Finished RIH with GP assembly on DP to 8128'. Spaced out and snap into sump packer at 8155' wlm, set upper packer at 4348', tested packer. RU for GP while mixing brine. Pump gravel pack stage 1- 24,000 lbs of sand. Did not sand out, Reversed out 300 Bbls. Mixing brine. 11/8/03 Mixing brine and waiting on boat with more salt to arrive. Unloaded salt and sand from boat. Pumped restress of stage 1 at 1.7 bpm and 3600 psi. POOH and RU for stage 2 GP. B-3 daily summary 11-19-03.doc 4 i ~i' ;, I~, \ " 11/9/03 Pumped GP #2- 17,400 lbs of sand. Reversed 270 bbls. POH to GP #3 position. Pump GP #3-16750 lbs of sand. Reversed out 226 bbls. POH to GP #4 position. 11/10/03 Mixing brine for stage 4 GP. WOW for boat to arrive with salt for mixing brine to top off surface volume. 11/11/03 WOW for boat to bring salt, unload boat, Mix 9.6ppg brine fl GP #4, set isolation pIa @5774', trouble shoot BJ Services annulus flow meter-2 hrs., pump GP #4- 13,750# of sand, rev eirc, POH to GP #5 position with severe losses, unable to keep hole full, small flow out annulus and drill pipe, PU to reverse position of GP #5, lost power at driller's console, trouble shoot problem, Mixing/building brine volume, rev eirc 2 string volumes with small amount of gas, attempt to PU to isolation position fl GP #5, blocks fell 17' uncontrolled, stopped with emergency brake. PU to isolation position for GP #5. Mix brine. 11/12/03 Isolation position fl GP #5, mix 9.6 ppg brine volume, WOW & mud products fl boat for 14.5 hrs, unloading boat, mixing 9.6 ppg brine volume. 11/13/03 Mix 534 bbls of 9.6 ppg. Repair filter unit pump motor (15.5 hrs). 11/14/03 Pump gravel pack #5- 13,600 lbs, reverse out. POH to #6 position with 133 bph losses. Mix 9.6 brine to build volume, trouble shoot starter problem wI Swaco transfer pump. Pump GP #6- 11650 lbs sand. 11/15/03 Rev out 151 bbls. POH to top of pkr with losses at 160 bph. KOIV valve did not stop losses. RIH and stab into seal bore to stop losses, spot 50 bbls 100ppb CaCo3 pill. Losses decreased from 140 to 23 bph. POH to innerstrings. Losses incr to 36 bph. Rill and sting into pIa to stop losses, mix brine, repair agitator, mix 25 bbl CaCo3 pill, pump pill. 11/16/03 Noticed rig pits not isolated. Displ CaCo3 pill out of hole, fix leaking valves in rig pits, mix another 25 bbl CaC03 pill, spot pill, pull up, monitor well- 50 bph losses decreased to 16 bph. POOH to inner strings, LID 2 7/8" inner string, LID 4" inner string, PU/MU Baker 5 1/2" anchor assy with KOIV and PBR. 11/17/03 Rill to 4348'. Latch into pIa with andhor/KOIV/PBR. Test annulus to 1500 psi. Shear out of PBR. No losses, 2nd KOIV is holding. POH wI seal assembly. Test BOPE. Offload 5-1/2" tubing fl boat. 11/18/03 Run 5 1/2" 15.5# BTC mod tbg completion with three GLMs loaded with live gas lift valves and 5-1/2" TRSSSV, space out, test control line, land & verify, PU 20', eirc inhib brine to annulus, land, RILDS, set TWC, RID floor equipment. B-3 daily summary 11-19-03.doc 5 ( ( 11/19/03 N/D BOPE, cleaning pits, offloading/loading boat, drift BOPE equip w/ 13 3/8" test plug f/ next well. NU tree, NU wing valves, test hanger to 5000 psi, test tree to 5000 psi. Install rotary table, pull TWC, attempt to pressure up to blowout KOIV -noticed annulus pressure tracking tbg pressure (probably GL V check valve leaking. 11/20/03 Pressure up to tbg to 500 psi, annulus tracked tbg. Blow down tbg pressure to surge possible debris from GL V check valves. Re-pressure trbg to 500 psi and annulus tracked more slowly indicating tbg leak is probably in one or more GL V check valves. Close SSSV and pressure up annulus to 500 psi, tbg stayed at 0 psi indicating tbg leak is below SSSV at 418'. Pressure up casing and tbg to hydraulically break KOIV, KOIV broke at 2000 psi, tbg and annulus went on a strong vacuum. Tbg pressure returned to 550 psi SITP. Annulus remained at 0 psi indicating tbg leak was probably in the GL V check valves and pressuring up to 2000 psi seated the check valves. RD secure well. Release rig from B-3 at 23:59 on 11/20/03 and begin move to B-1. B-3 daily summary 11-19-03.doc 6 ConocoPhillips TRANSMITTAL FROM: Sandra D. Lemke, ATO1486 ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage AK 99510-0360 TO: Steve Davies AOGCC 333 W. 7th Ave, Suite 100 Anchorage, Alaska 99501 RE: NCl B-03 re-completion Permit: 198-059 DATE: 11/06/2003 Transmitted: ....... , , ,, , , CDROM s~Umberger-Digita, log files and PDSview files; Chem Cut/Sump PackerlCHFRIUSITICHDTIRST '~j~/~ ~d B/ack#ne/co/or/o.q prints Schlumberger ~ased hole Dynamic tester-pressure only-live fluid Analyzer, 10/12/2003 ~rvoir Saturation Tool, 10/13/03 ,.~a%~ed Hole Formation Resistivity, 10/10/03 ~l~ion Log/Gamma Ray/CCL, 10/11/03 u-,S'~mp Packer Correlation Gamma Ray/CCL, 10/17/03 o,,C~mmpletion Record; Chem Cut, String shot, tubing punch, Junk, G 10/05/03 Log fi/ms u,,-S'~mp Packer Correlation Gamma Ray/CCL, 10/17/03 ~d Hole Formation Resistivity, 10/10/03 - r~'ion Log/Gamma Ray/CCL, 10/11/03 ,,R'E~ervoir Saturation Tool, 10/13/03 ~'?pletion Record; Chem Cut, String shot, tubing punch, Junk, G 10/05/03 Receipt: Return receipt to: P/ease check off each item as received, romp#j/sign and return the transmittal enclosed to address be/ow. CC: Rick Levinson, CPAI Geologist ,,,'"" ~"'"~-~- Date: /. ConocoPhillips Alaska, Inc. ATTN: S. Lemke, ATO-1486 700 G. Street Anchorage, AK 99501 Sandra. D.Lemke@Conocophillips.com Prepared by: Sandra D. Lemke ConocoPhillips Alaska, Inc. Global Information IT-Tech Data Management 907.265.6947 Page 1 of 2 ConocoPhillips Transmittal #220 Detail Date: 7/9/2003 To (External Party): From (PAI Contact): Email: Howard_Okland@admin.state.ak.us Email: Sandra. D.Lemke@conocophillips.com First First Name: Howard Name: Sandra Last Last Name: O~land Name: Lemke Phone Phone 265-6947 Number: Number: Company: Company: ConocoPhillips Alaska Address: Address: 700 G Street, ATO1486 City: City: Anchorage State: State: Ak Zip Code: Zip Code: 99510 Transmittal Info: RECEIVED Sent Via: hand delivered Tracking JUL #: Justification: per request from AOGCC for NCI B3 log data 6/26/20(~Jaska~' Data Detail: Quantity Description Type LAS, TXT, and .tif image files for NCI B3, Cook Inlet Alaska 508832009500, permit 98- 0059 directional survey hardcopies well schematic showing log runs; drillout borehole 1 cdrom 3 paper 1 paper Attachments: Filename: None Received By: Signature: Filesize: N/A http://www.ak.ppco.com/transmittal/print.asp?transno=22~C/A~NE~:'}~ ~UG (~ ~ 2003 7/9/2003 "-- ff S g3--- /3 315- ] z~ oz. CONSERVATION COMMISSION ,' FRANK H. MURKOWSKI, GOVERNOR 333 W. 7~ AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-35;39 PHONE (907) 279-1433 FAX (907) 276-7542 June 11, 2003 Mr. John Braden ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage Alaska 99510-0360 In Re' North Cook Inlet Unit B-3 (PTD 198-059) Dear John, In mid-2002, ConocoPhillips proposed to abandon the lower portions of this well with the intent of recompleting in the shallower gas zones produced by other wells on the platform. The proposed abandonment was based on the available information from late 1998 that indicated that the well was cased and cemented to TD, but that tubing had never been run nor had the well been perforated. In the course of attempting to abandon as planned, ConocoPhillips discovered that the well was indeed equipped with tubing. In early November, you submitted information documenting the discrepancies in the well equipment and included a completion report ("407") listing the current well status as "Suspended." We have recently audited this file since the well carries a status of "Operations Shut Down" in our records. This status was effective when the drilling operations were finished October 31, 1998. A Report of Sundry Well Operations ("404") was submitted documenting the well status on December 21, 1998. In late December 1998, verbal approval was given to return to well and run tubing and packer. Subsequent to the verbal approval, an Application for Sundry Approvals (Form 403, number 399-012) was submitted in mid-January of 1999 documenting the requested work. That document correctly proposed that the well status after completing the work be "Suspended." It appears that no subsequent 404 was .submitted to document the work. The 407 you submitted November 6, 2002 did document the past work and, as noted, the status you proposed was Suspended. Mr. John Braden June 11, 2003 Page 2 of 2 Based on our review of the Commission's file on this well, we conclude that the correct well status for North Cook Inlet Unit B-3 (198-059) as of ,January 7, 1999 was Suspended. We have edited our records to reflect this corrected well status and effective date. Regulation 20 AAC 25.537(d) states: "... the reports and information required by this chapter to be filed by the operator will be kept confidential by the commission for 24 months following the 30-day filing period after well completion, suspension, or abandonment unless the operator gives written and unrestricted permission to release all of the reports and information at an earlier date." The consequence of revising the well status from Operations Shut Down to SusPended is that all well records for B-3 now become eligible for release to the public. The AOGCC intends to release the well records on dune 27, 2003. Please contact me at 793-1250 or Steve Davies at 793-1224 if you have any questions. Sincerely, Thomas E. Maunder, PE Sr. Petroleum Engineer CC: Brian Seitz, CococoPhillips d. Scott Jepsen, ConocoPhillips TEM~jjc Gyrodata Incorporated 1682 W. Sam Houston Pkwy. N. Houston, Texas 77043 713/461-3146 Fax: 713/461-0920 May 8, 1998 Mr. Paul Dean Phillips Petroleum Company P.O. Box 1967 Houston, Texas 77251-1967 Re: Tyonek Platform, Well #B.3 North Cook Inlet, Alaska Enclosed, please find one (1) original, four (4) copies, and one (1) disk of the completed survey of Well #B-3, We would like to take this opportunity to thank you for using Gyrodata, and we look forward to serving you in the future. Sincerely, Robed J."'Shoup Operations Manager RJS:lnr Serving the Worldwide Energy Industry with Precision Survey Instrumentation A Gyrodat a Di re c t ional Survey for PHILLIPS PETROLEUM COMPANY WELL: #B-3, 5" DRILLPIPE Location: TYONEK PLATFORM, NORTH COOK INLET, ALASKA Job Number:- AK0498GO0458 Run Date: 3-May-98 06:00:00 Surveyor: CARL OETKEN Calculation Method: MINIMUM CURVATURE Survey Latitude: 61.076700 deg. N Azimuth Correction: Gyro: Bearings are Relative to True North Proposed Well Direction: 200.630 deg Vertical Section Calculated from Well Head Location Closure Calculated from Well Head Location Horizontal Coordinates Calculated from Local Horizontal Reference Gyrodata Incorporated 1652 W. Sam Houston Pkwy. N. Houston, Texas 77043 713/461-3146 Fax: 713/461-0920 SURVEY REPORT PHILLIPS PETROLEUM COMPANY WELL #B-3 TYONEK,PLATFORM NORTH COOK INLET, ALASKA AK0498GOO458 MAY 3, 1998 Serving the Worldwide Energy Industry with Precision Survey Instrumentation ~;~OI~,~NE[]:~ ~UG 0,6 2003 A Gyrodat a Di rec t i onal Survey PHILLIPS PETROLEUM COMPANY WELL: #B-3, 5" DRILLPIPE Location: TYONEK PLATFORM, Job Number: AK0498GO0458 NORTH COOK INLET, ALASKA Page MEASURED I N C L AZIMUTH VERTICAL DOGLEG VERTICAL CLOSURE DEPTH SECTION SEVERITY DEPTH DIST. AZIMUTH feet deg. deg. feet deg./ feet feet deg. 100 ft. H 0 R I Z O N T A L COORDINATES feet 0.0 0.00 0.00 0.0 0.00 0.0 0.0' 0 - 1135 FT. RATE GYROSCOPIC MULTISHOT SURVEY RUN INSIDE 5" DRILLPIPE ALL MEASURED DEPTHS AND COORDINATES REFERENCED TO TYONEK R.K.B. 0.0 0.00 N 0.00 E 100.0 .42 324.15 200.0 .34 326.88 300.0 .41 318.98 400.0 1.14 308.30 419.0 1.04 317.45 450.0 .1.42 319.87 481.0 1.66 314.41 511.0 1.85 308.44 542.0 2.15 302.17 573.0 2.52 295.70 605.0 2.85 287.68 636.0 3.24 281.33 667.0 3.53 270.59 699.0 3.67 263.18 731.0 4.25 258.87 763.0 4.79 249.80 795.0 5.65 245.61 826.0 5.83 242.58 857.0 6.36 239.10 888.0 7.29 237.68 -.2 -1.4 ~ -1-;- 5 - -1~.9 r2.'2 ~2~5 -2~8 -3.0 -3.0 -2.8 -2.4 -1.6 --.5 1.0 3.0 5.3 7.8 10.7 .42 100.0 .09 200.0 .09 300.0 .73 400..0 .05 419~0 .1.25 450.0~ .91 481.0' .87 510L9[- 1.20 54t.9 1.47 572.9 1.56 604.9 1.66 635.8 2.25 666.8 1.52 698.7 2.03 730.6 2.80 762.5 2.92 794.4 1.14 825.2 2.10 856.1 3.05 886.8 · 4~1.324.2 .30 N .22 W 1.0-' 324.9 .85 N .60 W 1.7[ 324.0 1.37 N 1.00 W 3..0~.~318.3 2.26 N 2.01 W 3.4~-317.7 2.50 N 2.28 W 4'.07i317.9 4.~9.~.317.7 5~8~1316.7 6~9-~ 314.9 8.1'.312.4 9 .'5 309.2 11.0 305.6 12.6 301.4 14.3 296.9 16.1 292.3 18.2 287.3 20.5 282.1 23.0 277.4 25.7 273.0 28.9 268.8 3.00 N 2.71 W 3.61 N 3.28 W 4.22 N 3.97 W 4.84 N 4.85 W 5.44 N 5.96 W 5.99 N 7.35 W 6.39 N 8.95 W 6.58 N 10.76 W 6.46 N 12.76 W 6.11 N 14.94 W 5.42 N 17.36 W 4.31 N 20.05 W 2.96 N 22.84 W 1.35 N 25.71 W .58 S 28.84 W A Gyrodat a Di re c t i onal Survey - PHILLIPS PETROLEUM COMPANY WELL: #B-3, 5" DRILLPIPE Location: TYONEK PLATFORM, Job Number: AK0498GO0458 NORTH COOK INLET, ALASKA MEASURED I N C L AZIMUTH VERTICAL DOGLEG VERTICAL DEPTH SECTION ~SEVERITY DEPTH feet deg. deg. feet deg./ feet 100 ft. 920.0 7.36 235.21 951.0 7.92 233.63 982.0 8.49 232.22 1012.0 8.90 229.17 1042.0 9.27 227.25 1072.0 9.79 227.50 1103.0 10.43 224.05 1135.0 10.98 223.26 Final Station Closure: 14.0 1.01 17.4 1.93 21.2 1.96 25.1 2.04 29.3 1.61 33.7 1.72 38.7 2.85 44.1 1.76 Distance: 63.15 ft 918.6 949.3 980.0 1009.7 1039.3 1068.9 1099.4 1130.8 Az: Page CLOSURE DIST. AZIMUTH feet deg. HORIZONTAL COORDINATES feet 32.4 265.0 36.0 261.6 39.9 258.6 44.0 255.8 48.2 253.2 52.7 250.8 57.7 248.6 63.1 246.3 2.84 S 32.25 W 5.24 S 35.60 W 7.91 S 39.13 W 10.78 S 42.63 W 13.94 S 46.16 W 17.30 S 49.82 W 21.10 S 53.71 W 25.40 S 57.81 W 246.28 deg. lO,ON PHILLIPS PETR0~EUM COMPANY WELL: #B-8, 5 DI~ILLPIPE Loca[ion' TYONEN PLATFORM, NOI~TH COOK INLET, ALASKA AK0498G00458 DEFINITIVE Z 50N O,ON 5,0~ lO,OS 15,0S ~O,OS ~5,0S BDTTDM H~LE LDCATED MD: 1135,00 50,OW 40IOW 30,OW PO,OW lO,OW 30,0S 60,OW EASTING 3,5 PHILLIPS PETROLEUM COMPANY WELL: #B-3, 5 DI~ILLPIPE Locat~ion' TYONEK PLATFORM, NORTH cooK INLET, ALASKA AK0498GO0458 DEFINITIVE 3,0 0,5 0,0 PO0,O 400,0 600,0 800,0 lO00,O 1200,0 FIEASUAED DEPTH 100,0 PHILLIPS PETROLEUM COMPANY WELL: #B-3, 5 DRILLPIPE Loca[ion' TYONEK PLATFORM, NORTH COON INLET, AI,ASNA AK0498G00458 DEFINITIVE 95,0 90,0 85,0 80,0 I,I I-- 75,0 <CE LLJ F/ ~ 70,0 65,0 60,0 BBTTBN HBLE LDC~TED. ND: 1135,00 800,0 1010,0 0,0 400,0 600,0 MEASURED DEPTH (f-~) 1;:)00,0 PHILLIPS PETR0~EUM COMPANY WELL: #B-3, 5 DRILLPIPE Looa[ion: TYONEN PLATFORM, NORTH COOK INLET, ALASKA AK0498GO0458 DEFINITIVE Z 10,0 8,0 6,0 4,0 2,0 0,0 BOTTOM HOLE 0,0 200,0 400,0 600,0 800,0 1000,0 1200,0 MEASURE~ ]OEPTH (f't) 50,0 PHILLIPS PETROJ,_,EUM COMPANY WELL: #B-3, 5 DRILLPIPE Location' TYONEK PLATFORM NORTH COOK INLET, ALASKA AK0498G00458 DEFINITIVE Z _1 40,0 30,0 80,0 lO,O 0,0 qO,O B~TTOM HSLE ? L~CgT£D / · . . 0,0 800,0 400,0 600,0 800,0 tO00,O 1800,0 MEASURE]3 ]3EPTH (-F't;) 840,0 PHILLIPS PETROJ,_,EUM COMPANY WELL: #]}-3, 5 D1BILLPIPE Looa[ion: TYONEK PI,AT?0RM, NORTH COOK INLET, ALASKA AK0498G00458 DEFINITIVE _L 320,0 300,0 ?80,0 260,0 240,0 220,0 ......... BOTTOM HDL.E - ~ LOCATED 0 0,0 200,0 400,0 600,0 800,0 1000,0 1200,0 MEASURED DEPTH CC-S) AnadrilL Schlumberger ALaska District 1111 East 80th Avenue Anchorage, AK 99518 (907) 349-4511 Fax 344-2160 CLient .... : PHILLIPS PETROLEUM COMPANY Field ..... : Cook Inlet , ,,~ ~ ,ell ...... : NCIU-B3 ?~- ~&,/L ~'~F~L'~P~ Vert sect.: 200.63 deg az- DD engnr..: Eric SroNn Units ..... : FEET 04 Jun 1998 Position calc.: Minimum Curvature DLS calc meth.: Lubinski Survey Date...: 04 Jun 1998 KB ELevation..: 132.00 ft Reference ..... : 8 Magnetic dc[n.: +22.143 (E) WELLHEAD coordinates...: 0,0 S MEASURED INCLN DIRECTION T DEPTH ANGLE AZIMUTH 8 0.00 0.00 0.00 7 100.00 0.42 324.15 7 200.00 0.34 326.88 ? 300.00 0.41 318.98 7 400.00 1.14 308.30 7 419.00 1.04 317.45 7 450.00 1.42 319.87 ? 481.00 1.66 314.41 7 511.00 1.85 308.44 7 542.00 2.15 302.17 7 573.00 - 2.52 295.70 7 605.00 2.85 287.68 7 636.00 3.24 281.33 7 667.00 3.53 270.59 7 699.00 3.67 263.18 7 731.00 4.25 258.87 7 763.00 4.79 249.80 7 795.00 5.65 245.61 7 826.00 5.83 242.58 7 857.00 6.36 239.10 7 888.00 7.29 237.68 7 920.00 7.36 235.21 7 951.00 7.92 233.63 7 982.00 8.49 232.22 7 101Z.00 8.90 ZZ9.17 7 1042.00 9.27 227.25 7 1072.00 9.79 227.50 7 1103.00 10.43 224.05 7 1135.00 10.98 223.26 RECORD OF SURVEY (Calculated from a tie-in station at 0 MD) VERTICAL-DEPTHS SECTION COORDINATES-FROM TVD SUB-SEA DEPART WELLHEAD 0.00 -132.00 0.00 0.00 N 0.00 100.00 -32.00 -0.20 0.30 N 0.21 200.00 68.00 -0.58 0.84 N 0.59 299.99 167.99 -0.93 1.36 N 0.99 399.98 267.98 -1.40 2.25 N 2.00 418.98 286.98 -1.53 2.49 N 2.27 449.97 317.97 -1.85 2.99 N 2.71 480.96 348.96 -2.22 3.60 N 3.27 510.95 378.95 -2.54 4.21 N 3.96 541.93 409.93 -2.81 4.83 N 4.85 572.90 440.90 -2.98 5.43 N 5.96 604.87 472.87 -3.01 5.98 N 7.35 635.83 503.83 -2.82 6.38 N 8.94 666.77 534.77 -2.36 6.57 N 10.75 698.71 566.71 -1.55 6.45 N 12.76 730.63 598.63 -0.45 6.10 N 14.94 762.53 630.53 1.05 5.41 N 17.35 794.40 662.40 3.04 4.30 N 20.04 825.24 693.24 5.29 2.95 N 22.83 856.07 724.07 7.80 1.34 N 25.70 886.85 754.85 10.72 0.59 S 28.84 918.59 786.59 14.02 2.85 S 32.23 949.31 817.31 17.45 5.25 S 35.59 980.00 848.00 21.19 7.92 S 39.11 1009.65 877.65 25.12 10.79 S 42.62 1039.27 907.27 29.32 13.95 S 46.15 1068.86 936.86 33.75 17.31 S 49.80 1099.38 967.38 38.68 21.11 S 53.70 1130.82 998.82 44.15 25.41 S 57.80 Pg: ALASKA Zone 4 X Y 331989.73 2586729.38 331989.52 2586729.68 331989.15 2586730.23 331988.76 2586730.75 331987.76 2586731.66 331987.50 2586731.90 331987.07 2586732.41 331986.51 2586733.03 331985.83 2586733.64 331984.95 2586734.28 331983.85 2586734.90 331982.47 2586735.46 331980.88 2586735.89 331979.07 2586736.10 331977.07 2586736.02 331974.89 2586735.70 331972.46 2586735.04 331969.75 2586733.97 331966.95 2586732.66 331964.05 2586731.09 331960.89 2586729.20 331957.46 2586727.00 331954.08 2586724.65 331950.51 2586722.03 331946.96 2586719.21 331943.39 2586716.10 331939.68 2586712.79 331935.73 2586709.05 331931.57 2586704.81 DL/ 100 <TIE 0.42 0.08 0.09 0.74 1.05 I .24 0.91 0.88 1.20 1.46 1.56 1.66 2.24 1.52 2.04 2.79 2.94 1.14 2.08 3.05 1.01 1.93 I .95 2.06 1.59 1.74 2.84 1.78 1246.94 10.85 1284.24 10.88 1315.81 11.09 1347.91 11.40 1378.81 11.57 3 1409.55 11.83 3 1441.18 12.13 3 1471.15 12.64 3 1502.39 13.29 3 1533.08 13.85 3 1564.20 14.31 3 1595.24 14.76 3 1627.08 15.15 3 1657.79 15.68 3 1690.99 16.42 3 1719.23 17.17 3 1750.27 17.98 3 1781.25 18.89 3 1813.06 19.74 3 1845.29 20.45 3 1879.45 21.10 3 1909.37 21.68 3 1938.02 22.45 3 1970.12 23.36 3 2001.14 24.24 3 2031.59 25.00 3 2063.77 25.64 3 2093.97 26.29 3 2124.90 27.06 3 2155.83 27.80 3 2186.26 28.57 3 2218.89 29.4? 3 2249.46 30.33 3 2280.60 31.06 3 2310.21 31.49 3 2341.49 31.83 3 2374.10 32.47 3 2404.92 33.04 3 2436.36 33.?0 3 246?.5? 34.32 3 2498.48 34.91 3 2528.05 35.33 3 2559.84 35.88 3 2591.44 36.57 3 2622.71 37.09 3 2654.16 37.58 3 2684.37 38.22 3 2715.57 38.81 3 2749.12 39.41 3 2?Z8.58 40.06 3 2809.72 40.60 217.05 1240.74 1108.74 218.45 1277.37 1145.37 215.69 1308.36 1176.36 215.14 1339.85 1207.85 216.74 1370.13 1238.13 64.09 41.58 S 71.46 W 331917.68 2586688.84 1.06 70.81 47.14 $ 75.?6 W 331913.30 2586683.35 0.71 76.58 51.94 S 79.38 W 331909.61 25866?8.60 1.79 82.63 57.04 $ 83.01 W 331905.91 2586673.55 1.02 88.57 62.02 $ 86.62 ~ 331902.22 2586668.62 1.17 67.09 S 90.26 ~ 331898.52 2586663.61 1.64 72.43 S 94.06 W 331894.63 2586658.32 1.45 77.58 S 97.91 W 331890.71 2586653.23 1.82 83.20 $ 102.11 W 331886.43 2586647.68 2.15 89.05 S 106.30 ~ 331882.16 2586641.89 2.21 128.14 95.27 S 110.61 W 331877.76 2586635.73 1.48 135.71 101.71 S 115.01 W 331873.27 2586629.36 1.51 143.72 108.56 S 119.54 W 331868.63 2586622.58 1.53 151.69 115.41 S 123.98 ~ 331864.10 2586615.?9 1.73 160.67 123.13 S 128.94 W 331~59.03 2586608.14 2.24 168.66 130.03 S 133.29 ~ 331~54.58 2586601.30 2.78 177.87 138.03 S 138.19 ~ 331.~49.57 2586593.38 2.69 187.50 146.40 S 143.27 W 331~44.36 2586585.08 2.95 214.61 1400.23 1268.23 94.59 216.29 1431.17 1299.17 100.93 217.18 1460.44 1328.44 107.11 216.44 1490.89 1358.89 113.84 214.80 1520.72 1388.72 120.80 214.62 1550.91 1418.91 214.09 1580.95 1448.95 212.95 1611.71 1479.71 212.85 1641.32 1509.32 212.63 1673.23 1541.23 211.82 1700.26 1568.26 211.16 1729.85 1597.85 211.41 1759.24 1627.24 211.35 1789.26 1657.26 197.83 210.93 1819.53 1687.53 208.72 210.71 1851.47 1719.47 220.65 155.38 S 148.75 W 331838.75 2586576.18 2.67 164.86 S 154.48 W 331832.89 2586566.79 2.25 175.26 S 160.68 ~ 331826.53 2586556.47 1.92 210.52 1879.33 1747.33 231.39 184.66 S 166.24 ~ 331820.84 2586547.17 1.95 209.93 1905.88 1773.88 242.00 193.96 S 171.66 ~ 331815.29 2586537.95 2.80 209.55 1935.45 1803.45 254.34 204.80 S 177.86 ~ 331808.94 2586527.19 2.8? 209.20 1963.83 1831.83 266.71 215.71 S 184.00 W 331802.64 2586516.37 2.87 208.36 1991.51 1859.51 279.27 226.83 S 190.10 W 331796.37 2586505.34 2.75 207.67 2020.60 1888.60 292.92 238.98 S 196.56 W 331789.74 2586493.29 2.19 207.68 204?.75 1915.75 306.04 250.69 S 202.71 W 331783.43 2586481.67 2.15 207.21 2075.39 1943.39 319.83 263.01 S 209.10 ~ 331776.85 2586469.44 2.58 206.97 2102.84 1970.84 333.99 275.70 S 215.59 W 331770.18 2586456.85 2.42 206.72 2129.66 1997.66 348.2? 288.52 S 222.08 W 331763.50 2586444.13 2.56 207.01 2158.19 2026.19 364.01 302.64 S 229.24 ~ 331756.15 2586430.11 2.79 206.86 2184.?0 2052.70 379.16 316.23 S 236.14 W 331749.05 2586416.63 2.82 207.15 2211.47 20?9.4? 394.95 330.39 S 243.36 W 331741.63 2586402.57 2.39 207.45 2236.?8 2104.78 410.22 344.05 S 250.41 W 331734.38 2586389.02 1.54 208.03 2263.40 2131.40 426.51 358.58 S 258.05 ~ 331726.53 25863?4.60 1.46 206.79 2291.01 2159.01 443.74 373.99 S 266.04 W 331718.32 2586359.31 2.82 207.36 2316.93 2184.93 460.31 388.83 S 273.63 W 331710.52 2586344.58 2.10 208.37 2343.19 2211.19 477.4? 404.12 S 281.71 W 331702.21 2586329.41 2.74 207.88 2369.06 2237.06 494.78 419.52 S 289.94 W 331693.?6 2586314.14 2.17 207.04 2394.50 2262.50 512.21 435.10 S 298.03 W 331685.44 2586298.68 2.45 206.57 2418.69 2286.69 529.12 450.28 S 305.71 W 331677.55 2586283.61 1.69 207.31 2444.53 2312.53 547.52 466.78 S 314.09 W 331668.93 2586267.23 2.20 206.51 2470.03 2338.03 566.08 483.43 S 322.54 W 331660.24 2586250.71 2.65 206.90 2495.05 2363.05 584.72 500.18 S 330.97 W 331651.57 2586234.09 1.82 206.64 2520.06 2388.06 603.68 517.21 S 339.56 W 331642.74 2586217.18 1.64 206.47 2543.90 2411.90 622.14 533.81 $ 347.85 W 331634.20 2586200.71 2.15 206.52 2568.31 2436.31 641.47 551.19 S 356.52 W 331625.28 2586183.45 1.89 206.86 2594.34 2462.34 662.52 570.10 S 366.03 W 331615.50 2586164.68 1.90 206.59 2617.00 2485.00 681.24 586.92 S 374.50 W 331606.79 258614?.99 2.28 206.90 2640.74 2508.?4 701.28 604.92 S 383.56 W 331597.46 2586130.12 1.85 ~3 2840.52 41.15 206.86 2664.03 2532.03 721.32 622.90 S 392.68 W 331588.09 2586112.28 1.79 3 2872.34 41.86 3 2902.72 42.45 3 2932.91 43.11 3 2963.49 43.47 3 2997.13 43.88 3 3028.83 44.28 3 3058.62 44.71 3 3089.49 44.94 3 3124.10 45.41 3 3154.93 45.53 3 3213.47 45.46 3 330?.89 45.33 3 3400.73 45.39 3 3493.70 46.01 3 3585.94 46.51 3 3678.47 46.61 3 3770.26 46.65 3 3864.36 46.53 3 3953.15 46.67 3 4046.88 46.81 3 4140.50 46.80 3 4235.29 46.47 3 4329.18 46.47 3 4475.01 46.07 3 4571.57 47.34 3 4666.93 48.55 3 4760.04 48.63 3 4849.55 48.82 3 4944.29 48.83 3 5038.00 49.39 3 5131.76 48.90 3 5224.96 48.60 3 5319.43 49.2? 3 5415.55 49.44 3 5506.57 49.39 3 5601.40 49.68 3 5693.34 49.30 3 5786.64 48.88 3 5879.68 46.78 3 5975.69 45.09 3 6075.26 45.65 3 6164.39 45.99 3 6265.24 46.29 3 6351.87 46.42 3 6449.78 45.27 3 6543.36 45.48 3 6640.60 45.89 3 6734.05 45.85 3 6829.19 45.32 206.69 2687.86 2555.86 742.28 641.72 S 402.18 W 331578.32 2586093.60 2.26 206.86 2710.38 2578.38 762.55 659.93 S 411.36 W 331568.87 2586075.53 1.98 207.12 2?32.54 2600.54 782.93 678.20 S 420.67 ~ 331559.31 2586057.40 2.26 207.27 2?54.?9 2622.79 803.76 696.85 S 430.25 W 331549.45 2586038.89 1.22 207.26 2779.13 2647.13 826.84 717.50 $ 440.89 W 331538.51 2586018.40 1.22 207.38 2801.90 2669.90 848.74 737.09 S 451.01 W 331528.11 2585998.95 1.29 207.56 2823.15 2691.15 869.4? 755.61 S 460.64 W 331518.21 2585980.57 1.50 208.21 2845.04 2713.04 891.06 774.85 S 470.82 W 331507.76 2585961.49 1.66 208.64 2869.44 2737.44 915.38 796.44 S 482.51 W 331495.76 2585940.07 1.62 208.?8 2891.06 2?59.06 937.14 815.71 S 493.07 W 331484.93 2585920.95 0.51 207.77 2932.10 2800.10 978.52 852.48 S 512.84 W 331464.62 2585884.48 1.24 208.02 2998.40 2866.40 1045.20 911.89 S 544.29 W 331432.31 2585825.53 0.23 208.94 3063.63 2931.63 1110.64 969.96 S 575.79 W 331399.98 2585767.94 0.71 209.69 3128.57 2996.57 1176.41 1027.97 S 608.37 W 331366.56 2585710.40 0.88 208.33 3192.34 3060.34 1242.34 1086.25 S 640.69 ~ 331333.41 2585652.60 1.20 208.15 3255.96 3123.96 1308.94 1145.44 S 672.48 W 331300.?? 2585593.88 0.18 207.13 3319.00 3187.00 1375 16 1204.55 S 703.43 ~ 331268.96 2585535.23 0.81 206.19 3383.67 3251.67 1443.14 1265.64 S 734.10 g 331237.41 2585474.60 0.74 203.98 3444.68 3312.68 1507.45 1324.06 S 761.45 ~ 331209.22 2585416.58 1.82 201.89 3508.91 3376.91 1575.65 1386.92 S 788.04 W 331181.?2 2585354.12 1.63 198.77 3573.00 3441.00 1643.88 1450.90 S 811.75 W 33115?.09 2585290.49 2.43 198.48 3638.09 3506.09 1712.75 1516.20 S 833.76 g 331134.14 2585225.52 0.41 198.08 3702.76 35?0.76 1780.77 1580.84 S 855.11 ~ 331111.86 2585161.21 0.31 198.28 3803.56 3671.56 1886.05 1680.96 S 887.99. W 331077.53 2585061.58 0.29 198.23 3869.78 3737.78 1956.26 1747.70 S 910.00 ~ 331054.55 2584995.17 1.32 197.20 3933.65 3801.65 2026.97 1815.14 S 931.54 W 331032.04 2584928.05 1.50 197.83 3995.24 3863.24 2096.70 1881.74 S 952.56 W 331010.0? 2584861.77 0.51 199.31 4054.29 3922.29 2163.93 1945.50 S 973.98 W 330987.72 2584798.33 1.26 199.98 4116.66 3984.66 2235.23 2012.66 S 997.95 W 330962.78 2584731.53 0.53 200.09 4178.01 4046.01 2306.06 2079.22 S 1022.23 ~ 33093?.55 2584665.34 0.60 200.59 4239.34 4107.34 2376.98 2145.71 S 1046.87 W 33'0911.94 2584599.21 0.66 200.29 4300.?9 4168.79 244?.05 2211.37 S 1071.34 W 330886.52 2584533.92 0.40 200.40 4362.85 4230.85 2518.28 2278.15 S 1096.11 W 330860.79 2584467.50 0.71 200.01 4425.46 4293.46 2591.21 2346.60 S 1121.30 ~ 330834.62 2584399.44 0.36 199.60 4484.67 4352.6? 2660.32 2411.63 S 1144.72 W 330810.26 2584334.?5 0.35 199.85 4546.22 4414.22 2?32.46 24?9.55 S 1169.07 W 330?84.93 258426?.20 0.37 200.33 4605.94 4473.94 2802.36 2545.20 S 1193.08 W 330759.97 2584201.91 0.57 201.06 4667.04 4535.04 2872.8? 2611.16 S 1217.99 W 330734.10 2584136.33 0.74 202.60 4?29.50 4597.50 2941.80 2675.17 S 1243.62 W 330707.55 2584072.70 2.5? 203.32 4796.27 4664.27 3010.73 2738.69 S 1270.52 W 330679.73 2584009.58 1.84 203.11 4866.22 4734.22 3081.52 2803.81 S 1298.45 W 330650.86 2583944.87 0.58 203.57 4928.34 4?96.34 3145.37 2862.50 S 1323.78 g 330624.69 2583886.56 0.53 203.34 4998.21 4866.21 3217.99 2929.21 S 1352.72 W 330594.79 2583820.28 0.34 204.06 5058.01 4926.01 3280.59 2986.61 S 1377.92 W 330568.76 2583763.26 0.62 204.04 5126.21 4994.21 3350.71 3050.75 S 1406.55 W 330539.21 2583699.54 1.17 204.50 5191.95 5059.95 3417.18 3111.47 S 1433.92 g 330510.96 2583639.23 0.42 203.81 5259.88 5127.88 3486.62 3174.95 S 1462.39 ~ 330481.58 2583576.17 0.66 203.50 5324.95 5192.95 3553.60 3236.39 S 1489.31 W 330453.78 2583515.13 0.24 202.49 5391.53 5259.53 3621.50 3298.95 S 1515.85 W 330426.33 2583452.97 0.94 6924.04 45.60 7013.74 45.46 7107.86 44.91 7202.89 44.84 7297.01 44.74 7390.71 44.84 7483.00 45.08 7585.53 45.41 7671.87 45.26 7766.20 44.69 7859.75 45.05 7953.15 45.47 8039.20 45.60 8135.83 45.17 8228.18 44.85 8323.66 43.41 8415.45 43.61 8507.35 43.93 8600.36 44.02 8694.69 44.58 8789.93 44.77 8886.86 43.62 8973.41 44.13 9068.33 44.37 9162.65 44.74 9274.72 45.21 9370.94 44.11 9462.91 42.89 9559.73 43.18 9652.84 43.20 9746.17 43.67 9841.05 43.79 9936.23 43.66 10030.01 43.73 10123.80 43.65 10217.83 43.99 10312.84 43.99 10408.61 44.02 10501.09 43.98 10592.50 43.63 10688.04 43.67 10779.20 43.62 10872.26 43.52 10964.70 43.93 11057.74 43.65 11153.70 43.72 11246.44 43.47 11341.68 44.52 11432.21 45.12 11524.70 45.07 203.36 5458.06 5326.06 3689.05 3361.21 S 1542.19 W 330399.09 2583391.10 0.72 202.44 5520.90 5388.90 3753.01 3420.18 S 1567.10 W 330373.34 2583332.50 0.75 202.09 5587.24 5455.24 3819.75 3481.97 S 1592.40 W 330547.15 2583271.09 0.64 200.95 5654.58 5522.58 3886.79 3544.34 S 1616.99 W 330321.65 2583209.09 0.85 200.41 5721.38 5589.38 3953.10 3606.37 S 1640.41 W 3301297.34 2583147.40 0.42 199.81 5787.88 5655.88 4019.11 3668.36 S 1663.10 W 330273.75 2583085.75 0.46 199.43 5853.18 5721.18 4084.31 3729.79 $ 1685.00 ~ 330250.97 2583024.65 0.39 200.74 5925.37 5793.37 4157.11 3798.17 S 1710.01 W 330224.97 2582956.65 0.96 199.77 5986.06 5854.06 4218.52 3855.77 S 1731.27 ~ 330202.88 2582899.36 0.82 200.06 6052.80 5920.80 4285.19 3918.46 S 1753.97 W 330179.27 2582837.02 0.64 200.38 6119.09 5987.09 4351.18 3980.39 S 1776.79 W 330155.56 2582775.43 0.45 199.65 6184.84 6052.84 4417.52 4042.73 S 1799.49 W 330131.96 2582713.43 0.71 198.99 6245.11 6113.11 4478.92 4100.68 S 1819.81 W 330110.81 2582655.78 0.57 198.91 6312.98 6180.98 4547.67 4165.74 S 1842.15 W 330087.53 2582591.06 0.45 199.00 6378.27 6246.27 4612.96 4227.51 S 1863.36 ~ 330065.42 2582529.61 0.35 198.33 6446.80 6314.80 4679.40 4290.49 S 1884.64 W 330043.23 2582466.94 1.59 199.41 6513.37 6381.37 4742.56 4350.29 S 1905.08 ~ 330021.93 2582407.45 0.84 199.69 6579.74 6447.74 4806.12 4410.19 $ 1926.35 W 329999.79 2582347.86 0.41 199.35 6646.67 6514.67 4870.69 4471.06 S 1947.93 W 329977.34 2582287.32 0.27 199.05 6714.18 6582.18 4936.55 4533.28 S 1969.60 W 329954.77 2582225.43 0.63 199.14 6781.91 6649.91 5003.49 4596.56 S 1991.50 W 329931.95 2582162.48 0.21 200.41 6851.40 6719.40 5071.05 4660.14 S 2014.36 ~ 329908.18 2582099.23 1.50 199.79 6913.79 6781.79 5131.03 4716.47 S 2034.97 W 329886.76 2582043.21 0.77 199.60 6981.79 6849.79 5197.26 4778.83 S 2057.29 W 329863.54 2581981.19 0.29 199.82 7049.00 6917.00 5263.42 4841.13 S 2079.61 W 329840.32 2581919.22 0.43 199.89 7128.28 6996.28 5342.62 4915.63 $ 2106.51 W 329812.34 2581845.12 0.42 200.13 7196.71 7064.71 5410.25 4979.18 S 2129.65 ~ 329788.28 2581781.92 1.16 201.60 7263.43 7131.43 5473.55 5038.34 S 2152.19 ~ 329764.89 2581723.10 1.72 201.53 7334.20 7202.20 5539.62 5099.79 S 2176.48 W 329739.72 2581662.01 0.30 202.21 7402.08 7270.08 5603.33 5158.93 S 2200.22 W 329715.13 2581603.23 0.50 202.49 7469.85 7337.85 5667.47 5218.27 S 2224.62 W 329689.87 2581544.25 0.54 201.85 7538.42 7406.42 5733.03 5279.01 S 2249.37 W 329664.25 2581483.88 0.48 201.92 7607.20 7475.20 5798.80 5340.06 S 2273.89 ~ 329638.85 2581423.20 0.15 202.17 7675.00 7543.00 5863.57 5400.11 S 2298.20 W 329613.66 2581363.51 0.20 202.35 7742.82 7610.82 5928.33 5460.06 $ 2322.75 W 329588.26 2581303.92 0.16 201.98 7810.67 7678.67 5993.41 5520.36 S 2347.31 ~ 329562.83 2581243.99 0.45 201.74 7879.02 7747.02 6059.38 5581.60 S 2371.88 W 329537.37 2581183.12 0.18 202.25 7947.91 7815.91 6125.90 5643.29 S 2396.80 W 329511.56 2581121.80 0.37 202.21 8014.43 7882.43 6190.12 5702.76 S 2421.10 W 329486.40 2581062.69 0.05 201.38 8080.40 7948.40 6253.38 5761.51 S 2444.59 W 329462.06 2581004.29 0.74 202.15 8149.54 8017.54 6319.31 5822.75 S 2469.05 W 329436.72 2580943.41 0.56 201.20 8215.50 8083.50 6382.21 5881.22 S 2492.28 W 329412.64 2580885.29 0.72 202.10 8282.93 8150.93 6446.34 5940.83 S 2515.95 ~ 329388.12 2580826.03 0.68 201.20 8349.73 8217.73 6510.23 6000.22 S 2539.52 W 329363.69 2580767.00 0.81 201.46 8416.90 8284.90 6574.61 6060.20 S 2562.94 W 329339.41 258070r.37 0.36 201.31 8486.29 8354.29 6640.88 6121.91 S 2587.10 W 329314.35 2580646.02 0.13 200.87 8553.45 8421.45 6704.83 6181.58 S 2610.12 W 329290.48 2580586.69 0.42 200.69 8621.97 8489.97 6770.98 6243.43 S 2633.58 W 3~29266.12 2580525.20 1.11 200.51 8686.18 8554.18 6834.79 6303.16 S 2656.04 W 329242.81 2580465.80 0.68 199.96 8751.48 8619.48 6900.30 6364.62 S 2678.69 W 329219.26 2580404.67 0.42 '3 11617.41 45.14 3 11709.58 45.39 3 11804.85 45.23 ~~3 11898.72 45.20 11990 86 45.46 3 12083.75 45.71 3 12178.50 45.75 3 12272.43 45.62 3 12366.48 45.11 3 12456.42 45.34 3 12550.89 45.88 3 12641.69 45.86 3 12735.28 46.59 3 12828.70 45.82 3 12919.30 46.34 199.84 8816.91 8684.91 6965.97 6426.38 S 2701.05 W 329196.02 2580343.25 0.12 200.08 8881.78 8749.78 7031.44 6487.92 S 2723.40 W 329172.78 2580282.05 0.33 200.06 8948.78 8816.78 7099.16 6551.54 S 2746.64 ~ 329148.62 2580218.78 0.17 199.65 9014.91 8882.91 7165.78 6614.20 S 2769.27 ~ 329125.08 2580156.45 0.31 198.64 9079.69 8947.69 7231.29 6676.10 S 2790.76 ~ 329102.70 2580094.87 0.83 199.60 9144.70 9012.70 7297.61 6738.79 S 2812.49 ~ 329080.06 2580032.51 0.79 199.85 9210.83 9078.83 7365.45 6802.66 S 2835.39 ~ 329056.24 2579968.99 0.19 199.76 9276.45 9144.45 7432.65 6865.89 S 2858.16 W 329032.56 2579906.09 0.15 199.68 9342.53 9210.53 ~499.57 6928.89 S 2880.75 W 329009.07 2579843.43 0.55 199.44 9405.88 9273.88 7563.40 6989.05 S 2902.12 W 328986.82 2579783.59 0.32 198.78 9471.96 9339.96 7630.89 7052.84 S 2924.22 W 328963.81 2579720.13 0.76 199.56 9535.19 9403.19 7696.04 7114.40 S 2945.62 W 328941.52 2579658.90 0.62 199.16 9599.94 9467.94 7763.60 7178.15 S 2968.02 W 328918.20 2579595.48 0.84 199.29 9664.59 9532.59 7831.01 7241.83 $ 2990.22 ~ 328895.07 2579532.14 0.83 199.22 9727.43 9595.43 7896.25 7303.43 S 3011.75 ~ 328872.66 2579470.85 0.58 3 13011.39 46.35 198.98 9791.01 9659.01 7962.85 7366.39 $ 3033.55 ~ 328849.95 2579408.22 0.19 3 13105.36 46.4? 199.51 9855.80 9723.80 8030.90 7430.65 $ 3055.98 W 328826.59 2579344.29 0.43 3 13197.69 46.58 199.28 9919.32 9787.32 8097.88 ?493.85 $ 3078.23 W 328803.43 2579281.43 0.22 3 13227.25 46.40 199.00 9939.68 9807.68 8119.31 7514.10 S 3085.26 W 328796.11 2579261.28 0.92 J 13315.00 46.40 199.00 10000.19 9868.19 8182.83 7574.19 $ 3105.95 W 328774.55 2579201.51 0.00 ^Station Types: 3/MWDT/GYRO 8/TIE-IN J/PROJECTED Final closure from wellhead: 8186.3 FEET at 202.30 DATA SUBMITTAL COMPLIANCE REPORT 7~3~2003 Permit to Drill '1980590 MD 17864 TVD Well Name/No. N COOK INLET UNIT B-03 13356 Completion Dat 11/1/1998 Operator PHILLIPS PETROLEUM CO APl No. 50-883-20095-00-00 Completion Statu Current Status UIC N REQUIRED INFORMATION Mud Log N__~o Sample N_9o Directional Survey ~ ~/~,., DATA INFORMATION Types Electric or Other Logs Run: Well Log Information: Log/ Data Digital 'ype Media T Digital Fmt Log Log Run Name Scale Media No ~.,PDL 2 ~ET-MD 2 ~,FET-MD F-E(,-- 2 -'"FET-TVD _?E~ 2 ~f~WD-FET-MD 2 ADN4-TVD 2 (.~,FET-MD 2 ~1~VD-FET-MD 2 ~IVVD-FET-TVD 2 'M~)-FET-'I'VD f'~ ~ f_.;~P-MD 2 '-4~P-TVD 2 PEX-3D/LDT/CN ~ALIPER/GR ~3'DL /./15"D L '~'DN4-MD Interval Start Stop 17812 12332 12332 13315 16600 12332 13315 13300 17864 17864 13358 10000 17864 13300 (data taken from Logs Portion of Master Well Data Maint) OH / Dataset CH Received Number Comments 2/9/1 ggg 08871 2/9/1 ggg 2/9/1999 'I~H 2/9/1 g99 BH 2/9/1 g99 .--BFI 2/9/1999 --BH 2/9/1999 BH 2/9/1999 B L 2/9/1999 BH 2/9/1999 BH 2/9/1999 B H 2/9/1999 BH 2/9/1999 BL 2/9/1999 BL 2/9/1999 2/9/1999 2/9/1 g99 6/11/1998 7/23/1998 2/9/1999 2/9/1999 2/9/1999 15246 8918 8918 1260 11761 8918 1260 11400 12064 12064 91:~ 1252 15301 11400 Open OH OH · OH OH OH OH OH OH OH OH OH OH OH 11761 9134 11761 4400 11774 12064 1260 15301 16600 13358 16600 8820 11910 17864 13315 17864 OH OH OH OH CH OH OH OH 15246-17812 BH 8918-12332 BP1 8918-12332 BP1 1260-13315 11761-16600 BP1 8918-12332 BP1 1260-13315 11400-13300 ST1 ][J~ 12064-17864 ST1 12064-17864 ST1 9134-13358 ST1 1252-10000 15301-17864 ST1 11400-13300 ST1 BH 11761-16600- BP1 BH 9134-13358~ST1 ~BH 11761-16600 BP1 BL 4400-8820 ~/~, c~ ~,..,~' BL 11774-11910 BH 121~64-17864 ~S'-T1 BH 1260-13315 15301-17864 ST1 DATA SUBMITTAL COMPLIANCE REPORT 7~3~2003 Permitto Drill 1980590 Well Name/No. N COOK INLET UNIT B-03 Operator PHILLIPS PETROLEUM CO APl No. 50-883-20095-00-00 MD 17864 'I'VD 13356 Completion Dat 11/1/1998 ~-,'~'~ ~ ~=I~T-TvD L RES-MD L RES-'i'VD R SRVY RPT Completion Statu --L-- .............. L ........................................ ~GAUPER/GR- D Current Status OPSHD UIC N 2 9134 13358 OH 2/9/1999 BH 9134-13358 ST1 /.AJ~ ~ 2 I 1530117864 OH 2/9/1999 15301-17864 ST1 /~/~ ~V~.-~_~ 2 I 3750 13300 OH 2/9/1999 3750-13300 ST1 /~d~'-~/ /' o 17864 OH 2/9/1999 SCHLUM 0-17864 /'./,:.~; 5 .......... :'L ........... JJ_774 ..... 1-191-0 .... OFI ........... 2i9i1999' ............ 1'1774;1191'0 ..... D'~.,~ W iq,'/ ~-"~[-c,V,~, 8871 ~',',-,',c~% '~ ~'~-r~~ I OH 2/9/1999 8871 PHILLIPS WIRELINE & DIR SRVY E"'"" "'~ET-TVD 2 ~4~52 10000 OH 2/9/1999 BH 1252-10000 · v Well Cores/Samples Information: Interval Dataset Name Start Stop Sent Received Number Comments Cuttings 1260 17850 }(~ ~ ~ ADDITIONAL INFORMATION Well Cored? Y / ~ Chips Received~ ~ ~ ~ Analysis ~ R~.r~.iv~d? Daily History Received? Formation Tops ~)i N Comments: Compliance Reviewed By: Date: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Abandon E~ Suspend [~ Operational shutdown ~] Perforate E~] Variance E~ Annular Dispos.[] Alter casing n--] Repair well E~ Plug Pedorations ~ Stimulate ~ Time E~ension ~ Other Change approved program ~ Pull Tubing ~ Pedorate New Pool ~ Re-enter Suspended Well ~ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development ~ Exploratory ~ 198-059 3. Address: Stratigraphic ~ Se~ice ~ 6. APl Number: P. O. Box 100360, Anchorage, Alaska 99510 50-883-20095-00 7. KB Elevation (ft): 9. Well Name and Number: 132' RKB NCIU B-03 8. PropeAy Designation: 10. Field/Pool(s): ADL 17589, No~h Cook Inlet Unit / A North Cook Inlet Field / Tyonek Deep Pool 11. Present Well Condition Summary: Total Depth measured 17864 feet Plugs (measured) 11053' true veAical 13356 feet Junk (measured) 11406' wireline fish Effective Depth measured 16890 feet true veAical 12570 feet Casing Length Size MD TVD Burst Collapse St ructu ral 461' 30" 461' 461' Conductor 1214' 20" 1214' 1208' Surface 4400' 13.375" 4400' 3752' Intermediate 11761' 9.625" 11761' 8918' Liner 3741' 7" 15301' 11379' Liner 5730' 5" 17150' 12777' Liner 705' 3.5" 17864' 13356~~ ~ '~ ~rE~:.~j'''~'%~~ ~ ~v[~,'~;~ Perforation depth' Measured depth: None True Vertical depth: None JUN 4 2003 Tubing: (size, grade, and measured depth) 3.5", P-110', 8 13700' AlaS~(8 Oi~ & ~ .... C0~$. t,u~-:, ;,,, P~oke~ ~nd ~S~V (t~pe ~nd measured depth) B~D ~nd AHO p~okem ~ ~ ~254' ~nd ~ ~380', HES ~edes ~0 SSSV ~ 400' ~2. Stimulation o~ oement squeeze summ~w: ~nte~v~s t~e~ted (measured): ~ ~Oeg' - q Treatment descriptions including volumes used and final pressure: 13.5 bbls Class G 13. Representative Daily Average Production or Injecti'~ Data .... OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: N/A Subsequent to operation: N/A 14. Attachments: 15. Well Class after proposed work: Copies of Logs and Surveys Run None Exploratory ~ Development ~ Service ~ Daily Repod of Well Operations Yes 16. Well Status after proposed work: Oil ~ Gas ~ WAG ~ GINJ ~ WINJ~ WDSP~ 17. I hereby ce~ify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.C. Exempt: Contact Printed Name John Braden Title Cook Inlet Engineer Signature ~ ~hone 263-4S36 Date~~ 0~ Form 1C 2003 ORiGiNAL ~MIT IN DUPLICATE WELL SUMMARY p5 v ENTS FOR NCI B-03 9/12/02 SERVICE ALL TREE VALVES PRIOR TO INITIATION OF P&A WORK 9/13/02 UNLOAD BOAT; SPOT CT EQUIPMENT & SL UNIT; LOAD CT W/WATER (17 BBLS). FLANGE-UP SL LUBE TO B-3; DRIFT W/2" CENT; SAT DOWN @ 400' WLM - UNABLE SEE SPANGS OR OIL JARS - WIRE BROKE AT ROPE SOCKET WITH TOOL STRING LEFT IN HOLE - 130 PSI ON WELLBORE WITH HEAVY DRILLING GELS AND SOLIDS - DECIDED TO CHASE DOWNHOLE WITH COIL WHEN RIGGED UP 9/14/02 UNLOAD BOAT - RU PTS TANK TO FLARE/CEMENTERS/CT; STAB PIPE. TEST BOPS TO 4000 PSI. RIH W/SLICK 1.5" BHA. RUN LINE TO CLASS II WELL AND PRESSURE TEST TO INJECT FLUIDS. DUMPED 1000# OF SAND ON TOP OF TOOL STRING FISH ON BRIDGE PLUG @ 11406'; WAIT ON SAND TO SETTLE. 9/15/02 TAG SAND TOP @ 11215' (20' OF SAND) ON TOP OFFISH AND BRIDGE PLUG- LAYED IN 13.5 BBLS OF 15.8# CLASS G CEMENT ON TOP OF SAND (186') FROM 11215' TO 11029' MD - WELL PLUGGED AND ABANDONED 9/26/02 TAG TRSSSV WITH 2.6" GAUGE RING AT 392' SLM (402' RKB). RUN THROUGH TRSSSV W/2.35" GAUGE RING. CLOSE FLAPPER AND SET DOWN ON IT W/ GAUGE RING. OPEN TRSSSV. RIH AND TAG CEMENT IN TUBING AT 3549' SLM (3559' RKB). RD JOB COMPLETE. [SSSV Work, Tag] 9/27/02 RU TO MILL CEMENT [Cement Squeeze] 9/28/02 MILL CEMENT FROM 3500' CTM TO 11069' CTMD USING 2.5" BEARCLAW PILOT MILL AND HAILEY UNDERREAMER. 9/29/02 TAGGED CEMENT TOP @ 11053' WLM - TBG CLEAR AFTER MILL OUT JOB [Tag] CONSERVA~I~ION COPlP[ISSION / ,/ FRANK H. MURKOWSKI, GOVERNOR 333 W. 7TM AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 June 11, 2003 Mr. John Braden ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage Alaska 99510-0360 In Re: North Cook Inlet Unit B-3 (PTD 198-059) Dear John, In mid-2002, ConocoPhillips proposed to abandon the lower portions of this well with the intent of recompleting in the shallower gas zones produced by other wells on the platform. The proposed abandonment was based on the available information from late 1998 that indicated that the well was cased and cemented to TD, but that tubing had never been run nor had the well been perforated. In the course of attempting to abandon as planned, ConocoPhillips discovered that the well was indeed equipped with tubing. In early November, you submitted information documenting the discrepancies in the well equipment and included a completion report ("407") listing the current well status as "Suspended." We have recently audited this file since the well carries a status of "Operations Shut Down" in our records. This status was effective when the drilling operations were finished October 31, 1998. A Report of Sundry Well Operations ("404") was submitted documenting the well status on December 21, 1998. In late December 1998, verbal approval was given to return to well and run tubing and packer. Subsequent to the verbal approval, an Application for Sundry Approvals (Form 403, number 399-012) was submitted in mid-January of 1999 documenting the requested work. That document correctly proposed that the well status after completing the work be "Suspended." It appears that no subsequent 404 was .submitted to document the work. The 407 you submitted November 6, 2002 did document the past work and, as noted, the status you proposed was Suspended. Mr. John Braden June 11, 2003 Page 2 of 2 Based on our review of the Commission's file on this well, we conclude that the correct well status for North Cook Inlet Unit B-3 (198-059) as of January 7, 1999 was Suspended. We have edited our records to reflect this corrected well status and effective date. Regulation 20 AAC 25.537(d) states: "... the reports and information required by this chapter to be filed by the operator will be kept confidential by the commission for 24 months following the 30-day filing period after well completion, suspension, or abandonment unless the operator gives written and unrestricted permission to release all of the reports and information at an earlier date." The consequence of revising the well status from Operations Shut Down to Suspended is that all well records for B-3 now become eligible for release to the public. The AOGCC intends to release the well records on June 27, 2003. Please contact me at 793-1250 or Steve Davies at 793-1224 if you have any questions. Sincerely, Thomas E. Maunder, PE Sr. Petroleum Engineer CC: Brian Seitz, CococoPhillips J. Scott Jepsen, ConocoPhillips TEM~jjc ConocoPhillips Post Office Box 100360 Anchorage, Alaska 99510-0360 Paul Mazzolini Phone (907) 263-4603 Fax: (907) 265-1535 Email: pmazzol@conocophillips.com May 2,2003 Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 (907) 279-1433 Re: Sundry Application to Recomplete, NCIU Well #B-03, Tyonek Platform, Cook Inlet Dear Commissioner: ConocoPhillips Alaska, Inc. hereby applies to re-enter a suspended well, NCIU B-03, and recomplete as a gas well in the Cook Inlet and Beluga Sands. Attached for your review is Sundry Application. Estimated start date is July 15, 2003. Well B-3 was drilled in 1998 as a Tyonek deep exploration well but the casing was never perforated. The B-3 wellbore was suspended on 9/29/02 with a c_ement plug laid in the 3_-1/2_" tubing via coil tubing from 11215' to 11053' to isolate the Tyonek deep intervals. A 10-407 completion re~'-0rt was filed with AOGCC on 11/6/02 to suspend B-03. The proposed recompletion will cut the tubing at 8800' and install a multi-zone gravel pack completion in the Beluga and Cook Inlet sands from 4470' to 8733'. The proposed t__.~ubing tail will overshot the old tubing stub to connect the well to the existing deep casing strings in case-tl~e l yodek deep zones are deemed econo-d'6'"n'fical~ in the future. If you have any questions or require any further information, please contact Tim Billingsley at 265-6531 or myself at 263-4603. Sincerely, Paul Mazzolini Cook Inlet Drilling Team Leader RECEIVED MAY 0 6 2003 Alaska Oil & Gas Cons. Commission Anchorage ORI61NAL STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVAL 20 AAC 25.280 1. Type of Request: Abandon Alter casing Change approved program Suspend ~1 Operational shutdown [] Perforate Repair well F'-I Plug Perforations C~ Stimulate Pull Tubing r-~ Perforate New Pool [] Variance r-'] Annular Dispos. r-'] Time Extension [--] Other ~] Re-enter Suspended Well r'~ 2. Operator Name: ConocoPhillips Alaska, Inc. 3. Address: P. O. Box 100360, Anchorage, AK 99510 4. Current Well Class: Development [-~ Exploratory [--] Stratigraphic E~] Service [] 5. Permit to Drill Number: 98-059 ''~' 6. APl Number: 50-883-20095-00 7. KB Elevation (ft): 132' RKB 8. Property Designation: ADL 17589, North Cook Inlet Unit 9. Well Name and Number: NCIU B-03 lO. Field/Pools(s): North Cook Inlet Field / Tyonek Deep Pool 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured) :Junk (measured): 17864' 13356' 16890' 12570' 11053' 11406' wireline fish Casing Length Size MD TVD Burst Collapse Structural 461' 30" 461' 461' Conductor 1214' 20" 1214' 1208' Surface 4400' 13.375" 4400' 3752' Intermediate 11761' 9.625" 11761' 8918' Liner 3741' 7" 15301' 11379' Liner 5730' 5" 17150' Liner 705' 3-1/2" 17864' Perforation Depth MD (ft): Perforation Depth TVD (ft): None None Packers and SSSV MD (ft): Packers and SSSV Type: HES Series 10 SSSV. BWD and AHC packers 12. Attachments: Description Summary of Proposal [~ Detailed Operations Program ['~ BOP Sketch [-~ 14. Estimated Date for Commencing Operations: 7/15/2OO3 16. Verbal Approval: Commission Representative: Date: 12777' 13356' TubingSize: Tubing Grade: Tubing MD(ft): 3-1~" P-110 13,700' SSSV @ 400', BWD pkr @ 11354', AHC pkr @11380' 13. Well Class after proposed work: Exploratory r-] Development [] 15. Well Status after proposed work: Oil r-'] Gas ~-~ Plugged WAG [-"] GINJ r-~ WINJ E~ Service Abandoned r-~ WDSPL r--1 17. i hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Printed Name Paul Mazzolini Title Cook Inlet Drilling Team Leader Phone 263-4603 COMMISSION USE ONLY Tim Billinqsley 265-6531 Date Conditions of approval: Notify Commission so that a representative may witness Plug Integrity[--1 BOPTest ~ Mechanical Integrity Test Location Clearance r-] Sundry Number: RECEIVED Other: "~0 ~, ~-'~(:~:;~ -~-~,,~ ~- Subsequent Form Required: I~I~'~ ~S EtFL Approved by: ~.. Form 10-403 Revised 2/2003 COMMISSIONER ......... MAY 0 6 2003 ,)(.~ska 0il & Gas Cons. Commission Anchorage BY ORDER OF THE COMMISSION Date: ORIGINAL SUBMIT IN DUPLICATE B-03 Gravel Pack Workover Operation I Move rig from A-10a to B-3, ND Tree / NU and test BOP to 3000 psi 2 Cut 3-1/2" tbg @ 8800' 3 Pull & lay down 8800' of 3-1/2" tubing 4 RU E-line for ,Cased H._.___.~ole Dynamics Tester 5 RIH w/E-line and tag tbg stub at 8800', (correlate depth of stub) 6 Run CHDT pressure/sample stops and POOH, 2 runs with 5 drillholes each 7 RIH with perf guns on E-line 8 Shoot 8731'-8733' and 8574'-8577' select fire, POOH, RD E-line 9 RIH with tbg stub overshot/sump pkr on drill pipe 10 Stab over stub and set lowest sump packer at 8150' 11 POOH with drill pipe and packer setting tool 12 MU and RIH w/TCP guns 13 Tag packer at 8150' with btm of guns, set plug in packer, PU to place guns on depth 14 PU guns as needed to place shots on depth at 4470'-8138' 15 Pressure up drill pipe to shoot guns underbalanced, pump pill if rfecessary, POOH & LD spent guns 16 RIH with Cavins bailer on drill pipe. 17 Bail perf debris from top of plug at 8150', engage and pull plug from packer 18 POOH and lay down Cavin bailer and plug 19 Run Gravel Pack assembly incl inner strings 20 Set top packer at 4400' and pump six Gravel Packs 21 POOH with DP and lay down inner strings 22 Run 4400' of 5-1/2" completion tbg and SSSV 23 Stab into top packer at 4400', PU and pump packer fluid 24 Space out and Land hanger 25 ND BOP / NU Tree 26 Pressure up to knock out KOIV at 4400'. Produce well. B-3 procedure for Sundry 4-16-03.xlssteps Con°c ' hillips I I Top fill 16890' NCIU B-3 As of 9/29/02 BPV (Mke, Type, OD) Not Applicable RKB-THF: Tbg Hr (Make, Type) Not Applicable RKB-BHF Annulus Fluid: 70/30 glycol/water RKB-MSL: 132.00 TOC: Water Depth: 130.00 · . :.'. 0D.:. ".': :' .., :.":i,o.. Casing Strings PPCO Allowable Ratings 30" 0 461 547 Ibs/ft WELD 20" 0 1214 133 Ibs/ft K-55 DnI-Quip 13 3/8" 0 4400 72 Ibs/ft L-80 BT&C 9 518" 0 11761 53.5 Ibs/Ft P-110 BT&C 7" 11560 15301 32 Ibs/Ft P-110 5" 11420 17150 18 Ibs/Ft P-110 BT&C 3 1/2" 17159 17864 13 Ibs/Ft P-110 BT&C CEMENTING SUMMARY 20" Conductor Cement with 1364 sx Premium cement 5/7/98 Lead 644 sx w/3% gel, 0.5% CFR-3, 1% CaCl2 &l/4#/sk FLOCELL mixed @ 12 ppg w/yield of 2.44 cuFT/sk Tail 720 sx w .3%CFR-3, 1%CaC12, 1/4#/sk FLOCEL @ 15.8ppg, yield 1.15 cuFT/sk 13 3/8" Cemented with 1600 sx 12 ppg premium cement 5/12/98 Lead 1000 sx premium + additives @ 12 ppg Tail 600 sx premium cement + additives @ 15.8 ppg 9 5/8" No bond log Cemented with 2767 sx (1004 bbls, lost 80 bbls during displacement) 6/17/98 Lead 2342 sx (914 bbl) Tail 424 sx (90 bbl) 12-1/4" hole TD @ 13,315' MD, 9-5/8" stuck off bottom by 1554'. No mention of cmt returns to surf but 16,000' of cmt pumped up annulus 7" 200 sx Premium cement, 15.6 ppg, 1.18 yld, 5.1 gal/sx 9/28/98 0.4% HRS, Halad 344LXP @ 13 gaV100sx, 0.4% CFR-3 Baker ZXP 7" Liner Packer, top of tieback ext @ 11545 Flexlock liner hanger @ 11561 5" x 3 1/2" Cemented with 500 sx 15.8 lb/gal Class "G"; TOC @ 10,088' 10/26/98 220 sx premium +0.4% CFR-3, 0.13 gal/sx HALAD 344L, 0.4% HR-5 @15.6ppg, 1.18 CF/sx yield Baker ZXP 7" Liner packer, top of tieback ext @ 11420. Flex Lock liner hanger at 11442 7" x 5" x-over @ 11449 5" x 3-1/2" x-over at 17159 .... .,.." ."":'""""" . . .:'., .... · ....::.... : .:.. .. ... .......': ..... .': · .: .......... : . ,. ...... : ............ .. · . .....! ':..:....:. ,. .. , .... ·: · .. · . ·: : .: ~.... '...= Tubing Tubing tally has not been located. Measurements are approximate. 3-1/2" 12.95# P-110 tubing to approximately 13,700' MD 4OO 5 060 7 835 9 725 11 240 11 053 11 215 11 294 11 354 11 362 11,380 11,398 11,418 13,700 9/29/02 TRSSSV @ appx 400' wlm GLM 1 @ appx 5060' (based on proposed schematic) GLM 2 @ appx 7835' (based on proposed schematic) GLM 3 @ appx 9725' (based on proposed schematic) GLM 4 @ appx 11240' (based on proposed schematic) Class G cement from 11053' wire to 11215' wire 20/40 sand from 11,215' - 11418' wlm Sliding Sleeve (assumed) 2 jts above packer BWD packer with seals top @ approximately 11354' Bevel guide over tubing stub from 11362' to 11368' Tubing chemically cut at 11362' after failed pressure test AHC Packer @ appx 11,380' (from first attempt, tubing would not hold pressure Top of 24' wireline fish on X-nipple @ 11406' ctm X-nipple (2.313") @ 11418' wlm Tubing tail at 13,700' MD no perforations Top of fill @ 16890 Page 1 - NCIU B-2 Con°c ' hillips i i I I I ! ! ! I I I I ! ! ! ! , ! i ! i 1/2" tb~ ~ 8800' .~ 11,053 TC 9-5/8 NCIU B-3 Proposed Gravel Pack Completion BPV (Mke, Type, OD) Cameron "H" RKB-THF: ~'bg Hr (Make, Type) ABB Vetco 5-1/2" with 5-1/2' csg BTC RKB-BHF Annulus Fluid: RKB-MSL: 132.00 TOC: Water Depth: 130.00 .'. *.OD.' .. TOp,, '.' BTM:`' .... '. WT '.. GRADE.:,':..'~ONN.i",.,..B~j',RsT i:,:'co~' .. 'TRO Casing Strings PPCO Allowable Ratings 30" 0 461 547 Ibs/ft WELD 20" 0 1214 133 Ibs/ft K-55 !DnI-Quip 13 3/8" 0 4400 72 Ibs/ft L-80 BT&C 9 5/8" 0 11761 53.5 Ibs/R P-110 BT&C 7" liner 11560 15301 32 Ibs/Ft P-110 5" liner 11420 17150 18 Ibs/Ft P-110 BT&C 5-1/2" tbg 0 8800 15.5 Ib/ft 1-80 BTC modified casing thread I 3 112" 17159 17864 13 Ibs/Ft P-110 BT&C I I CEMENTING SUMMARY 9 5/8" No bond log Cemented with 2767 sx (914 bbl) 6/17/98 Lead 2342 sx (914 bbl) Tail 424 sx (90 bbl) 12-1/4" hole TD @ 13,315' MD, 9-5/8" casing stuck off bottom by 1554'. No mention of cmt returns to surf but 16,000' of cmt pumped up annulus. ";, ,, ,,,,,,,, l,l,C.,,.,,,.,,,! ,, ,: ,,~:,,,,,,: ,,~, ,,,,,, Top Btm 0' 8800' 5-1/2" 400' 5-1/2" 2000' 5-1/2" 3000' 5-1/2" 4000' 5-1/2" 4300' Baker 4351' Baker 4835' Baker 5120' Baker 5406' Baker 6306' Baker 7204' Baker 8144' Baker 8200' 8800' Tubing 15.5#/ft, L-80, BTC modified csg thread Camco TRM-4E 5-1/2" TRSSSV with one 1/4" SS contol line x 1-1/2" Camco MMG GLM x 1-1/2" Camco MMG GLM x 1-1/2" Camco MMG GLM CMU 5-1/2" sliding sleeve 9-5/8" 53.5# SC-1R packer assy with KOIV 9-5/8" 53.5# SC-1L packer 9-5/8" 53.5# SC-1L packer 9-5/8" 53.5# SC-1L packer 9-5/8" 53.5# SC-1L packer 9-5/8" 53.5# SC-1L packer 9-5/8" 53.5# F-1 sump packer Baker CMU 5-1/2" sliding sleeve Baker Oil Tools 5-1/2" overshot to swallow 3-1/2" tbg stub Proposed Perfs are 4470' - 8733', see attached for exact details Old Tubing tally has not been located. Measurements below are approximate. 3-1/2" 12.95# P-110 tubing to approximately 13,700' MD 8,800' 9,725 11,240 11,053 11,215 11,294 11,354 11,362 11,380 11,398 11,418 13,700 9/29/02 Proposed Tbg Cut GLM 3 @ appx 9725' (based on proposed schematic) GLM 4 @ appx 11240' (based on proposed schematic) Class G cement from 11053' wlm to 11215' wlm (9/29/02) 20/40 sand from 11,215'- 11418' wlm Sliding Sleeve (assumed) 2 jts above packer BWD packer with seals top @ approximately 11354' Bevel guide over tubing stub from 11362' to 11368' Tubing chemically cut at 11362' after failed pressure test AHC Packer @ appx 11,380' (from first attempt, tubing would not hold pressure Top of 24' wireline fish on X-nipple @ 11406' ctm X-nipple (2.313") @ 11418' wire Tubing tail at 13,700' MD no perforations Top of fill @ 16890 Page I - NCIU B-3 Conoc hillips \ / 13-3/8" cul 9-5/8 Proposed Perfs Tyonek Remedial Program 2003 B-03 Well Top Base Perfs Blanks Perf Pe~ Iff) Iff) 4470 4660 190 100 4760 4810 50 Distance (ft) Between Intervals 90 4900 4923 23 14 4937 4958 21 27 4985 5004 19 66 507O 5074 4 Distance (ft) Between Intervals 136 5210 5220 10 5O 5270 5290 20 76 5366 5400 34 Distance (ft) Between Intervals 362 5762 5770 8 275 6045 6051 6 218 6269 6274 5 Distance (ft) Between Intervals 360 6634 6674 40 36 6710 6718 8 244 6962 6980 18 2O4 7184 7198 14 Distance (ft) Between Intervals 316 7514 7518 4 162 7680 7684 4 34 7718 7726 8 210 7936 7938 2 111 8049 8057 8 61 8118 8138 20 D~tance(fl)Betweenlnterva~ 436 E-line 8574 8577 3 Distance(fl)Betweenlntervals 154 E-line 8731 8733 2 Total 521 3742 Pkrs, Jewele~ CMU 43OO' SCI-R 435O' SCI-L 4835' SC1-L 5120' ~C1-L 54O6' ;C1-L 6306' SC1-L 7204' F-1 8144' CMU 8200' **'9-5/8" 53.5# P-110 casing Page 1 - NCIU B-3 13.400 Kill Line Inlet 3" 5,OOO PSi I 13 5/8" Annular 45" i · 5~8" Double Gate 34" 9.800 Choke Line Outlet 3" 5,000 PSI Mud Cross 20" 3 5~8" Single Gate18" 13 5~8" 5,000 PSi Shaffer BOP Stack Kuukpik Ddlling Rig 5 To Shaker 3" Panic To Gasbuster Manual Choke P res~re Sens Automatic Choke Inlet 3" 5,000 PSI,Choke Manifold Kuu,kpik Drilling Rig 5 ConoCOPhillips November 6, 2002 John C. Braden, PE Cook Inlet Asset Telephone: (907) 263-4536 Facsimile: (907) 265-1441 Email: jbraden@ppco.com 700 G. Street P. O. Box 100360 Anchorage, Alaska 99510-360 Tom Maunder 333 W. 7th Ave #100 Anchorage, Alaska, 99501-3539 phone: (907) 279-1433 fax: (907) 276-7542 RECEIVED NOV o 8 2002 Oil,& Gas ~ns. Comml~lon Anchorage Dear Tom, This letter documents our recent findings on the North Cook Inlet Unit well B-03. NCIU B-03 (APl 508832009500) was drilled in 1998 as a Tyonek deep exploration well prospecting for oil by Phillips Petroleum Corporation. At that time, records were kept in Houston. In 2001, records were sent up to Anchorage to merge all available well data into a single file. In 2001, it was decided that the best use for the three oil wells would be to recomplete them as gas producers. This work was budgeted for 2002 and 2003. All available records (drilling morning report, AOGCC sundries, completion reports, schematics, etc.) showed that the B-03 well was drilled and cased but the planned completion was not installed. A 10-403 was filed for the proposed completion, but no 10-407 or drilling records of the completion existed. We assumed the well had a few joints of tubing below the wellhead. Plans to abandon the deep interval and prepare for a rig completion in 2003 were based on that information. While the coiled tubing abandonment work was in progress, Brian Seitz obtained additional well records from the Houston files, which were still being merged into the Anchorage files. One of the files contained daily drilling reports that indicated after drilling and casing B-03, the rig moved to B-01A for completion and then moved back to B-03 and ran tubing in the well (see attached Operations Summary). Subsequent paperwork regarding the completion of B-03 was not distributed or filed. The attached schematic represents, to the best of my knowledge, the current status of the equipment in the wellbore (see attached Schematic). According to the 10-403, no perforating was planned at that time. ConocoPhillips still plans to recomplete the well as a gas producer in 2003. - Attached for your rewew are the drilling records, a schema - of the current well condition, and a 10-407 (attached) for the current completion. Please let me know if you require further information or action regarding this well. Sincerely, John Braden Cook Inlet Asset Cc~ Brian Seitz, ATO 1284 J. Scott Jepsen, ATO 1220 Central Files: WEXP 508832009500 NCIU B-03, 6-3, State Report Sharon AIIsup-Drake, ATO 1530 Scott Reynolds, ATO 1552 , STATE OF ALASKA , ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of well Classification of Service Well Oil ~'1 Gas F--1 Suspended [~] Abandoned ~1 Service ~1 Water Injector 2. Name of Operator 7. Permit Number Phillips Alaska, Inc. 98-059 3. Address 8. APl Number P. O. Box 100360, Anchorage, AK 99510-0360 50-883-20095-00 4. Location of well at surface: Tyonek Platform Leg 1, Slot 2 9. Unit or Lease Name 4029' FSL, 4056' FEL, Sec. 6, T11N, R09W North Cook Inlet Unit At Top Producing Interval 10. Well Number N/A NClU B-03 At Total Depth 11. Field and Pool 4036' FSL, 3282' FEL, Sec. 13, T11N, R10W North Cook Inlet 5. Elevation in feet (indicate KB, DF, etc.) 16. Lease Designation and Serial No. Exploration/Tyonek Deep RKB 132' feetI NClU 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. Or Aband. 115. Water Depth, if offshore 16. No. of Completions 17. Total Depth (MD + TVD) 18. Plug Back Depth (MD + TVD) 19. Directional Survey 120. Depth where SSSV set 21. Thickness of Permafrost 17,864' MD / 13,356' TVD YES E~] No []I N/A feet MD N/A '22. Type Electric or Other Logs Run 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORDI AMOUNT PULLED 30" Surface 461 Driven 20" K-55 Surface 1214 24" 1364 sx premium Class "G" cement 13 3/8" L-80 Surface 4400 16" 1600 sx premium Class "G" cement 9 5/8" P-110 Surface 11761 12-1/4" 2767 sx premium Class "G" cement 7" (liner) P-110 11560 15301 8-1/2" 200 sx premium Class "G" cement 5" (Prod.) P-110 11420 17150 6" 5"x 3-1/2" crossover 3 1/2" (Prod.) P-110 17159 17864 4/1/4" 500 sx premium Class "G" cement 24. Perforations open to Production (MD + TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 3-1/2" 13,700 ft appx 11,360 ft None 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED none none 27. PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) no test N/A Date of Test Hours Tested Production for OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE IGAS-OIL RATIO I Test Period > Flow Tubing Casing Pressure Calculated OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY - APl (corr) 24-Hour Rate > 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. None NOV 0 82002 Alas~ Oil& Ga8 eons. CommissJt,, Anchorage Form 10-407 Rev. 7-1-80 CONTINUED ON REVERSE SIDE ('~) ~" Submit in duplicate 29. ~ 30. ~, GEOLOGIC MARKERS FORMATION TESTS NAME Include interval tested, pressure data, all fluids recovered and gravity. MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. n/a No test RL 6 IVED NOV 0 8 2002 N~I~ Oil& Gas Cons. Commission Anchorage 31. LIST OF ATTACHMENTS Schematic, Drilling Operations Summary hereby certify that the following is true and correct to the best of my knowledge. ] 32. I Signed/~ Title Sr. OperationsEn.qineer Date/~47~ ~ , ~Z., John C. Braden INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and Icg on all types of lands and leases in Alaska. Item 1: Classification of Service wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10-407 ConocoPhillips Page 62 of 65 OPerations Summary Report Legal Well Name: NORTH COOK INLET UNIT-B 000003 Common Well Name: North Cook Inlet Unit B-3 Spud Date: 05/03/1998 Event Name: Original Drilling Start: 04/30/1998 End: 01/06/1999 Contractor Name: Unocal / Pool Arctic Alaska Rig Release: 01/06/1999 Group: Rig Name: Rig Number: 428 Date From- To Hours Code Subco Phase Description of OPerations 11/01/1998 06:00 - 10:00 4.00 CM e 80CMPL ND BOP, CLEAN UP IN BOP ROOM. 10:00 - 12:00 2.00 CM 6 80CMPL ND & REMOVE RISER, INSTALL DRY HOLE TREE & TEST TO 1500 FOR 20 MIN. RIG RELEASED FROM B-3 AT 12:00 HRS 10-31-98 12/25/1998 00:00 - 03:30 3.50 MV n 80CMPL SKID RIG TO B-3 WELL. 03:30 - 06:00 2.50 MV n 80CMPL SECURE RIG WITH CLAMPS, PUT HAND RAILS IN PLACE AFTER , MOVE. 06:00 - 12:00 6.00 CM 8 80CMPL NU BOP'S, RISER, AND BELL NIPPLE. 12:00 - 16:30 4.50 CM 8 80CMPL REPLACE 7" PIPE RAMS WITH 5"X31/2" VARIABLES. SET TEST PLUG, TEST BOP'S TO 250 LOW AND 5000 PSI HIGH. 16:30 - 18:00 1.50 CR 8 80CMPL PULLED TEST PLUG SET WEAR BUSHING, L/D TEST JOINTS. 18:00 - 23:00 5.00 CM 4 80CMPL :MADE UR RBP RETRIEVING TOOL, TIH TO 11406', LATCHED AND RELEASED RBP. 23:00- 00:00 1.00 CM 5 80CMPL ~WELL. 12/26/1998 00:00 - 03:00 3.00 CM 5 80CMPL FINISHED CIRCULATING WELL. 03:00 - 18:00 15.00 CM 4 80CMPL POOH WITH RBP, L/D 5" DP ON WAY OUT. TOOL HAD BOTH PACKING RUBBERS IN PLACE. REC. 18:00 - 20:30 2.50 CM 1 80CMPL RUN APRS 8.32 GAUGE RING AND JUNK BASKET TO 11,425', POOH TO 10,500', TOOLS HUNG AND PARTED 3/16 BRAIDED LINE AT ROPE SOCKET. RECOVERED ALL WIRE. 20:30 - 00:00 3.50 FI q 80CMPL MADE UP NEW TOOL STRING TO FISH TOOLS LEFT IN HOLE. GUIDE TO GET OVER FISH BEING MADE AT BAKER FISHING TOOL SHOP. LEFT 27.50' OF FISH IN HOLE, 1-7/16" O.D. ROPE SOCKET LOOKING UP. '12/27/1998 00:00 - 12:30 12.50 FI q 80CMPL WAIT ON W/L FISHING TOOLS TO BE SHIPED IN BY BAKER TRI-STATE. FOG DELAYED GE'I-f'ING TOOLS FOR 3 HRS. CLEANED PROD. PITS, REMOVES TBG. PROTECTORS FROM BOX END OF TBG. WHILE WAITING ON TOOLS. 12:30 - 16:30 4.00 FI q 80CMPL MADE UP BAKER FISHING TOOLS ON APRS WIRE LINE, WlH, FAILED TO LATCH FISH. 16:30 - 18:00 1.50 .FI z 80CMPL FABRICATE BELL GUIDE HOUSING FOR 1-7/16" 'GG' OVERSHOT. 18:00 - 22:30 4.50 FI q 80CMPL GIH W/OVERSHOT. LATCH FISH @ 11425'. POOH. ,RECOVERED FI~SH (TOOLSTRING +JUNK BASKET & GAUGE RING). 22:30 - 00:00 1.50 CM f 80CMPL RIH W/4" GAUGE RING. 9000' AT REPORT TIME. 12/28/1998 00:00 - 08:00 8.00 CM f 80CMPL CONTINUE GIH W/4" GAUGE RING TO 14300'. POOH. P/U 2.25" GAUGE RING. RIH. STAND UP SOLID @ 16890'. ATTEMPT TO WORK TOOLS THROUGH. NO FURTHUR PROGRESS. POOH. RIH W/2.25" IMPRESSION BLK. TO 16890'. POOH. NO DEFINEABLE IMPRESSION. R/D WlRELINE EQUIP. 08:00 - 12:00 4.00 CM 6 80CMPL R/U TUBING HANDLING EQUIP. PULLED WEAR BUSHING. HELD PRE-JOB SAFETY MEETING. CUT MULE SHOE ON FIRST JT OF 3.5" TUBING. 12:00 - 00:00 12.00 CM 2 80CMPL P/U & RIH W/3.5" TAIL PIPE (69 JTS. 12.95 # FL4S P-110 TBG. P/U AHC PACKER & SUB-ASSEMBLIES. CONT RIH W/3.5" PH-6 12.95# P-110 TBG. TOTAL RUN @ RPT TIME - 6530'. TORQUE TURN EACH CONNECTION USING WF JAM UNIT. 12/29/1998 00:00 - 15:00 15.00 CM 2 80CMPL P/U & RIH W/3.5" 12.95fl PH-6 FROM 6530' TO 13300'. PICKUP HES . TRSV. TEST TO 7500 PSI. RIG UP DUAL STRING TBG HANDLING : EQUIF;. CONT RIH W/3.5" LONG STRING. P/U & RIH SIMULTANEOUSLY WITH 2-7/8" SHORT STRING 276' WITH BULL PLUGGED BO'I-FOM. 15:00 - 00:00 9.00 CM 6 80CMPL MAKE UP DUAL SPLIT HANGER & 3.5" LANDING JTS. DRAIN STACK. A'I-i'EMPT TO LAND HANGER. SHORT STRING SIDE NOT ENTERING HANGER BOWL. P/U & REMOVE PACKOFF. RE-RUN WITH SAME RESULTS. PULL HANGER TO RIG FLOOR. DISCOVERED OVERALL Printed: 11/05/2002 2:50:21 PM ConocoPhillips Page 63 of 65~ OperatiOns Summary Report Legal Well Name: NORTH COOK INLET UNIT-B 000003 Common Well Name: North Cook Inlet Unit B-3 Spud Date: 05/03/1998 Event Name: Original Drilling Start: 04/30/1998 End: 01/06/1999 Contractor Name: Unocal / Pool Arctic Alaska Rig Release: 01/06/1999 Group: Rig Name: Rig Number: 428 Date From-To Hours Code Subcc Phase BescriPtiOn°fOperations 12/29/1998 15:00 - 00:00 9.00 CM 6 80CMPL :O.D. OF DUAL STRING SIDE BY SIDE OVER 9". X-OVERS EXTENDING BELOW HANGER TOO LARGER O.D. TO GO INSIDE 8.4" DRIFT CASING. 12/30/1998 00:00 - 09:00 9.00 WO u 80CMPL LAY DOWN HANGER. SECURE & MONITOR WELL. WAIT ON NEW SINGLE HANGER. DECISION MADE TO GO WITH SINGLE HANGER & TREE BASED ON AVAILABILITY AND PROBLEMS WITH DUAL HANGER. 09:00 - 12:00 3.00 CM 6 80CMPL L/D LANDING JOINTS. POOH L/D 9 JTS OF 2-7/8" TUBING (SHORT STRING). R/D DUAL HANDLING TOOLS. 12:00 - 15:00 3.00 CM 5 80CMPL RUG UP LINES. REVERSE CIRCULATE TUBING VOLUME @ 2 BBI. JMIN. 15:00 - 18:30 3.50 CM n 80CMPL MAKE UP HANGER & LANDING JTS. LAND VETCO-GRAY SINGLE HANGER. TEST PACKOFF TO 2750 PSI. PUMP 20 BBLS GLYCOLNVATER (70/30) IN ANNULUS. 18:30 - 00:00 5.50 CM f 80CMPL R/U HES SLICKLINE. TEST LUBRICATOR TO 4500 PSI. RIH W/RAC PLUG BODY. SET IN 2.313" X NIPPLE @ 11418' WLM. POOH. RIH & INSTALL PRONG IN RAC PLUG @ 11418' 12/31/1998 00:00 - 03:30 3.50 CM f 80CMPL RIH W/RAC PLUG PRONG. SET IN PLUG @ 11418' WLM. PRESSURE UP ON TBG TO 4500 PSI. SET PACKER. MONITOR ANNULUS. ANNULUS PRESSURE INCREASE TO 700 PSI. POOH W/PLUG PRONG. RIH W/PULLING TOOL. RETRIEVE PLUG BODY F/11418'. :03:30 - 07:30 4.00 CM 9 80CMPL PRESSURE UP TBG TO 3000 PSI. PRESSURE UP ANNULUS TO 5500 PSI TO TEST CSG. HOLD FOR 30 MIN. LOST 500 PSI ON ANNULUS. INCREASE 600 PSI ON TBG. COMMUNICATION BETWEEN TBG & _ ANNULUS. 07:30 - 12:00 4.50 CM f 80CMPL PRESSURE UP TBG & ANNULUS TO 3000 PSI. CLOSE TRSV. BLEED DOWN TBG ABOVE DHSV. ANNULUS PRESSURE STATIC. NO COMMUNICATION ABOVE TRSV. RIH W/2.313" 'XX' PLUG. SET @ 11418' WLM. PRESSURE UP TUBING TO 4500 PSI. LEAK OFF. ANNULUS INCREASE. RIH & RETRIEVE 'XX' PLUG. · 12:00 - 16:30 4.50 CM If 80CMPL RIH W/2.562" 'RR' PLUG. SET IN SLIDING SLEEVE NPPLE PROF'!_E @ , 11340' WLM. POOH. 16:30 - 17:30 1.00 CM 9 80CMPL PRESSURE UP ON TUBING TO 4600 PSI/10 MIN. POSITIVE TEST OF f TBG ABOVE SSD. 17:30 - 00:00 6.50 CM : 80CMPL -RIH W/GS PULLING TOOL. RETRIEVE '2.562" 'RR' PLUG FROM 11430' WLM. RIH W/2.562' 'B' SHIFTING TOOL. RUN THROUGH SLEEVE TO CONFIRM IN CLOSED POSITION. POOH. PRESSURE UP TBG TO 3000 PSI. LOST 500 PSI IN 8 MIN. PRESSURE INCREASE ON ANNULUSTO 5.00 1000 PSI. RIH TO SHIFT SLEEVE TO OPEN POSITION. 01/01/1999 00:00 - 05:00 CM f 80CMPL RIH WfB' SHIFTING TOOL. ATTEMPT TO OPEN SSD SLEEVE @ 11432'. POOH. CHANGE TOOL OVER TO CLOSING POSITION. RIH W/SHIFTING TOOL. ATTEMPT TO CLOSE SLEEVE. 05:00 - 05:30 0.50 CM 9 80CMPL PRSSURE UP ON TUBING. TBG EQUALIZING W/ANNULUS. NO TEST. 05:30 - 12:00 6.50 CM f 80CMPL RIH W/SHIFTING TOOL. JAR DOWN TO CLOSE SLEEVE. ATTEMPT TO TEST TBG. NO TEST. PRESSURE DROP OF 1000 PSI/10 MIN. CHANGE OUT TOOL STRING. 12:00 - 22:00 10.00 CM , f 80CMPL RIH W/SHIFTING TOOL. MADE 3 RUNS ATTEMPTING TO CLOSE SLEEVE. ATTEMPT TO TEST TBG AFTER EACH TRIP. TUBING STILL LEAKING THROUGH TO ANNULUS. SHIFTING TOOL COMING BACK WITH PIN SHEARED AFTER EACH TRIP. 22:00 - 00:00 2.00 CM f 80CMPL RIH W/SHIFTING TOOL. UNABLE TO PASS GLM # 1 (~ 5063'. POOH TO CHECK TOOL. RERUN. 01/02/1999 00:00 - 06:30 6.50 CM , f 80CMPL RIH W?B' SHIFTING TOOL. UNABLE TO PASS GLM @ 5063' WLM. POOH. RIH W/2.47" GAUGE RING. WORK THROUGH GLM @ 5063'. Printed: 11/05/2002 2:50:21 PM ConocoPhillips Page 64 of 65 Operations Summary Report Legal Well Name: NORTH COOK INLET UNIT-B 000003 Common Well Name: North Cook Inlet Unit B-3 Spud Date: 05/03/1998 Event Name: Original Drilling Start: 04/30/1998 End: 01/06/1999 Contractor Name: Unocal / Pool Arctic Alaska Rig Release: 01/06/1999 Group: Rig Name: Rig Number: 428 Date From- To Hours Code Subco Phase . Description;of Operations , ,, 01/02/1999 00:00 - 06:30 6.50 CM f 80CMPL OK. POOH. RIH W/SHIFTING TOOL. STILL UNABLE TO PASS GLM. POOH. R/D HES SLICKLINE. I 06:30 - 19:00 12.50 CM .If 80CMPL R/U APRS. MAKE UP CHEMICAL CUT TOOL. RIH W/CUTTER TO 11360'. FIRE CHARGE. NO CUT. POOH. RIH W/NEW CU-FI-ER AND NEW CCL. MAKE CUT C¢_. 11362' VV~.,_ M. POOH W/CUTTER. HUNG UP IN GLM @ 5063' WORK FREE DOWN HOLE. TOOL STOPPED @ 5264. HUNG UP. MIX 200 BBL 10.5 CaCL2. WORK WIRELINE. 19:00 - 23:30 4.50 CM 5 80CMPL CIRCULATE HOLE WNVORKING WIRE IN A'FrEMPT TO FREE. REVERSE ClRC WORKING WIRE. MIX & PUMP DRY JOB. FILL TRIP TANK. 23:30 - 00:00 0.50 CM 0 80CMPL HELD SAFETY MEETING. GO OVER SAFE PRACTICES OF STRIPPING WIRE. R/U TO PULL TBG. AND STRIP E-LINE. 01/03/1999 00:00 - 18:30 18.50 CM 2 80CMPL CONT PULL TBG/STRIP WIRE. I. JD TRSV + 165 JTS. RECOVER FISH. CONT POOH W/TBG. STAND BACK IN DERRICK. L/D GLM's, SLIDING SLEEVE. 18:30 - 23:00 4.50 CM 8 80CMPL MAKE UP TEST JT. TEST BOPE TO 250/5000 PSI, MAKE UP & TEST SLIDING SLEEVE. NO TEST. LEAKING IN INTERNAL THREADED SEAL. SET WEAR BUSHING. 23:00 - 00:00 1.00 CM z 80CMPL MAKE UP TIW, 10' PUP, DOUBLE PORT F/TESTING. INSPECT DERRICK & TOP DRIVE. HANG OFF TOP DRIVE. SLIP & CUT DRILL LINE. 01/04/1999 00:00 - 02:00 2.00 CM 8 80CMPL COMPLETE SLIP & CUT DRILL LINE. ADJUST BRAKES & INSPECT. TEST TOP DRIVE UPPER & LOWER VALVES & SAFETY VALVE. CLEAR & CLEAN UP RIG FLOOR. 02:00 - 13:00 11.00 CM 4 80CMPL PICKUP & RIH W/'BWD' PKR WITH SEAL RECEPTACLE + 8" BELL GUIDE. RIH W/63 STANDS. P/U & RIH W/SINGLES TO 11358' 13:00 - 17:00 4.00 CM t 80CMPL TAG TBG STUB @ 11358' ATTEMPT TO GO OVER TBG STUB. WORK DN W/10 KLBS. NO INDICATION ON PUMP PRESSURE OF GOING OVER STUB. 17:00 - 00:00 7.00 CM 4 80CMPL MIX & PUMP SLUG. POOH W/PKR & SEAL ASSEMBLY. SLM OUT OF HOLE. 7335' @ RPT TIME. 01/05/1999 : 00:00 - 05:00 5.00 CM 4 80CMPL CONTINUE POOH F/7~.~5' SLM. 05:00 - 06:00 1.00 CM 6 80CMPL B/O BELL GUIDE. M/U i'~t=W BEVEL GUIDE ONTO OVERSHOT ASSEMBLY. CHECK PACKER. 06:00 - 12:00 6.00 CM 4 80CMPL TIH TO TOP OF TBG STUB @ 11362'. 12:00 - 16:30 4.50 CM 1 80CMPL TAG TOP @ 1,1362'. ROTATE SLOWLY OVER STUB. SAW PRESSURE INCREASE. STACK OUT @ 11368'. DROP BALL & SET PACKER. PULL 15 KLBS O/P. TEST ANNULUS T/3000 PSI. TEST GOOD. PULL O/P AND PRESSURE TO 1800 PSI TO RELEASE R/T FROM PACKER. SHEAR OUT BALL SEAT @ 4300 PSI. 16:30 - 18:00 1.50 CM f 80CMPL WELL U-TUBING. PUMP SLUG. WAIT ON FLUID TO BALANCE OUT. PUMP 2ND SLUG. 18:00 - 23:00 5.00 CM 2 80CMPL POOH F/11368'. L/D PKR RUNNING TOOL. 23:00 - 00:00 1.00 CM 6 80CMPL PULL WEAR BUSHING. DRAIN STACK. PUMP OUT TRIP TANK. 01/06/1999 00:00 - 01:00 1.00 CM 2 80CMPL PULL WEAR BUSHING. MAKE UP SEAL ASSEMBLY W/MULESHOE. 01:00 - 11:00 10.00 CM 4 80CMPL TIH W/TUBING + SUB ASSEMBLIES. DRIFT PIPE. PICK UP TRSSV. PRESSURE TEST SAME. CONTINUE TIH. STING IN SEALS TO 11354'. 11:00 - 14:00 3.00 CM n 80CMPL POOH & SPACE OUT. M/U TBG HANGER. & LANDING JTS. HOOK UP & TEST SSSV CONTROL LINE TO 7500 PSI. 14:00 - 16:30 2.50 CM 5 80CMPL CLEAN PITS. MIX & REVERSE IN 25 BBLS 70/30 GLYCOLNVATER MIXTURE. 16:30 - 21:30 5.00 CM 9 80CMPL LAND HANGER. PRESSURE UP ANNULUS TO 1000 PSI TO TEST PKR SEALS. PRESSURE TEST TBG/PKR F/BELOW TO 4500 PSI. TEST TRSSSV W/1500 PSI DIFF. PRESS. PRESSURE UP TBG TO 3000 PSI. PRESSURE UP ON ANNULUS TO 5500 PSI/30 MIN. TO TEST CSG. ALL Printed: 11/05/2002 2:50:21 PM ConocoPhillips Page 65 of 65 Operations Summary Report Legal Well Name: NORTH COOK INLET UNIT-B 000003 Common Well Name: North Cook Inlet Unit B-3 Spud Date: 05/03/1998 Event Name: Original Drilling Start: 04/30/1998 End: 01/06/1999 Contractor Name: Unocal / Pool Arctic Alaska Rig Release: 01/06/1999 Group: Rig Name: Rig Number: 428 Date From, To HOurs Code: Subc© Phase Description of operations , :)1/06/1999 16:30 - 21:30 5.00 CM 9 80CMPL ABOVE TEST POSITIVE. BREAK DOWN LANDING JT. SET BPV. R/D TBG HANDLING EQUIP. 21:30 - 00:00 2.50 CM 6 80CMPL CLEAN RIG FLOOR, PULL BELL NIPPLE, R/U PICKUP LINES TO HYDRIL. N/D BOPE. :)1/07/1999 00:00 - 08:00 8.00 CM 6 80CMPL ND BOPE. MOVED BOPE COMPONENTS FROM BOP ROOM TO TOP DECK. 08:00 - 13:00 5.00 CM x 80CMPL NU ABB VETCO GRAY 3-1/16" 10m TREE. INSTALL TEST PLUG. 13:00 - 14:30 1.50 CM 8 80CMPL TEST ABB VETCO GRAY 3-1/16" 10m TREE TO 7500 PSI FOR 15 MIN. HELD OK. 14:30 - 15:00 0.50 CM 6 80CMPL REMOVED TEST PLUG & BPV, CLOSED MASTER VALVES & SECURED WELL. COMPLETION COMPLETE @ 15:00HRS AST, 01-06-99. Printed: 11/05/2002 2:50:21 PM ConocoPh ll ps I I I I NCIU B-3 BPV (Mke, Type, OD) Not Applicable RKB-THF: Tbg Hr (Make, Type) Not Applicable RKB-BHF Annulus Fluid: 70/30 glycol/water RKB-MSL: 132.00 TOC: Water Depth: 130.00 OD TOP BTM WT GRADE CONN. BURST CO# TRO Casing Strings PPCO Allowable Ratings 30" 0 461 547 Ibs/ft WELD 20" 0 1214 133 Ibs/ft K-55 DnI-Quip 13 3/8" 0 4400 72 Ibs/ft L-80 BT&C 9 5/8" 0 11761 53.5 Ibs/Ft P-110 BT&C 7" 11560 15301 32 Ibs/Ft P-110 5" 11420 17150 18 Ibs/Ft P-110 BT&C 3 1/2" 17159 17864 13 Ibs/Ft P-110 BT&C CEMENTING SUMMARY 20" Conductor Cement with 1364 sx Premium cement 5/7/98 Lead 644 sx w/3% gel, 0.5% CFR-3, 1% CaCI2 &l/4#/sk FLOCELL mixed @ 12 ppg w/yield of 2.44 cuFT/sk Tail 720 sx w .3%CFR-3, 1%CaC12, 1/4#/sk FLOCEL @ 15.8ppg, yield 1.15 cuFT/sk 13 3/8" Cemented with 1600 sx 12 ppg premium cement 5/12/98 Lead 1000 sx premium + additives @ 12 ppg Tail 600 sx premium cement + additives @ 15.8 ppg ~9 5/8" I Cemented with 2767 sx 6/17/98 Lead 2342 sx (914 bbl) Tail 424 sx (90 bbl) 7" 200 sx Premium cement, 15.6 ppg, 1.18 yld, 5.1 gal/sx 9/28/98 0.4% HRS, Halad 344LXP @ 13 gal/100sx, 0.4% CFR-3 Baker ZXP 7" Liner Packer, top of tieback ext @ 11545 Flexlock liner hanger @ 11561 5" x 3 1/2" Cemented with 500 sx 15.8 lb/gal Class "G"; TOC @ 10,088' 10/26/98 220 sx premium +0.4% CFR-3, 0.13 gal/sx HALAD 344L, 0.4% HR-5 @15.6ppg, 1.18 CF/sx yield Baker ZXP 7" Liner packer, top of tieback ext @ 11420. Flex Lock liner hanger at 11442 7" x5" x-over @ 11449 5"x 3-1/2" x-over at 17159 Tubing Tubing tally has not been located. Measurements are approximate. 3-1/2" 12.95# P-110 tubing to approximately 13,700' MD 400 5,060 7,835 9,725 11,240 11,053 11,215 11,294 11,354 11,362 11,380 11,398 11,418 13,700 TRSSSV @ appx 400' wlm GLM 1 @ appx 5060' (based on proposed schematic) GLM 2 @ appx 7835' (based on proposed schematic) GLM 3 @ appx 9725' (based on proposed schematic) GLM 4 @ appx 11240' (based on proposed schematic) Class G cement from 11053' wlm to 11215' wlm 20/40 sand from 11,21 5' - 11418' wlm Sliding Sleeve (assumed) 2 jts above packer BWD packer with seals top @ approximately 11354' Bevel guide over tubing stub from 11362' to 11368' Tubing chemically cut at 11362' after failed pressure test AHC Packer @ appx 11,380' (from first attempt, tubing would not hold pressure Top of 24' wireline fish on X-nipple @ 11406' ctm X-nipple (2.313") @ 11418' wlm Tubing tail at 13,700' MD no pedorations Top offill @ 16890 Page 1 - NCIU B-2 PHILLIPS Alaska, Inc. A Subsidiary of PHILLIPS PETROLEUM COMPANY Post Office Box 100360 Anchorage, Alaska 99510-0360 Aras Worthington Phone (907) 265-6802 Fax'. (907) 265-1158 July 23, 2002 Cammy Oechsli Taylor Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Subject: Sundry Approval Application for NCIU B-1, B-2, B-3, A-10, & A-11 P&A Commissioner: Phillips Alaska, Inc. submits the attached Sundry Approval Applications for the P&A operations on NCIU B-l, B-2, B-3, A-10, & A-11. If you have any questions regarding these matters, please contact Aras Worthington at 265-6802. Thankz~you~ A. Worthington NRWO Engineer PA1 Drilling & Wells CM/skad ORIGINAL RECE 'VED JUL 2.5 2002 Alaska 0il & Gas Cons. Commissia~'~ Anchorage ! STATE OF ALASKA ~ ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of request: Abandon_XX Suspend_ Alter casing _ Repair well _ C, hange approved program _ 2. Name of Operator Phillips Alaska, Inc. 3. Address P. O. Box 100360 Anchorage, AK 99510-0360 4. Location of well at surface 4029' FSL, 4056' FEL Sec. 6 T11 N, R9W At top of productive interval At effective depth At total depth 4036' FSL, 3282' FEL, Sec 13, T11N, R10W Operational shutdown _ Re-enter suspended well _ Plugging_ Time extension _ Stimulate_ Pull tubing _ Vadance _ Pedorate _ 5. Type of Well: Development Exploratory __ Stratigraphic __ Service_ 6. Datum elevation (DF or KB feet) RKB 132 feet 7. Unit or Property name North Cook Inlet 8. Well number NCIU B-3 9. Permit number / approval number 98-059 ¢ 10. APl number 50-883-20095 11. Field / Pool North Cook Inlet Field Development Other _ 12. Present well condition summary Total depth: measured Effective depth: Casing Structural Conductor Surface Intermediate Liner Production Production Perforation depth: true vertical measured true vertical Length 461' 1214' 4400' 11761' measured true vertical Tubing (size, grade, and measured depth Packers & SSSV (type & measured depth) 17864 feet Plugs (measured) 13356 feet 17864 feet Junk (measured) 13356 feet Size Cemented 30" Driven 20" Existing 13-3/8" Existing 9-5/8" Existing 7" Existing 5" Cemented 3.5" Cemented N/A N/A Long String: 3-1/2", 12.95#, PH6 P-110 from surface to 11400' md · 3-1/2", 12·95#, FL4S P-110 11400' to 13700' md Halliburton "AHC" Pkr @ 11400' md Halliburton Series 10 SSSV @ 417' Measured Depth True vertical Depth 461' 461' 1214' 1208' 4400' 3752' 11761' 8918' 15301' 11379' 17150' 12777' 17864' 13356' JUL 2 5 2002 Alaska 0il & Gas (;;o~s. Anchorage 13. Attachments Description summary of proposal __X Detailed operations program __ BOP sketch __ 15. Status of well classification as: 14. Estimated date for commencing operation August 1,2002 16. If proposal was verbally approved Name of approver Date approved Oil _ Gas _ Suspended _ Service 17. I hereby certify that the foregoing is rt ue and correct, theist Signed ,~ Aras Worthin~lton of my knowledge. Title: Well Engineer FOR COMMISSION USE ONLY Questions? Call Aras Worthington 265-6802 Date ~'/~ ~/t~-, Prepared b~/ Sharon A//sup-Drake 263-4612 Commission so represen,~tive may witness ?:~_~,~, ,.,~-.~.,.~.,~.~t~..~(~V..~-t~- [ Approval no,~,0 Z, 'Z ~ 5 Conditions of approval: Notify . Plug integrity ~ BOP Test .~ Location clearance ~Mechanical Integrity Test.~__~,~ Sub uent for.~re~uired 10.~.. ~-~ ¢.,~'~,~ ¢,,5~% ~,,._~.~. (.%-~,~..~ ~-_,~ [ Cammy Oecasli laYl0,' Da~e d/'/~....'?/~,~ Approved by order of the Commission Commissioner / '/ Form 10-403 Rev 06/15/88 · SUBMIT IN TRIPLICATE NCIU B-3 Intended P&A for Completion as a Gas Well Objective: Plug & Abandon all perforations for re-completion as a gas well. Intended P&A Procedure: 1. Spot 20' of sand above the Bridge plug @ 11,406'. 2. Spot 100' of cement on top of the sand. ~ ,~\ 3. Run gas well completion into well. NClU B.3 TEMPORARY SUSPENSION DIAGRAM INole: Liner lap will be negative tested prior to setting RBP. ITop of Sunfish Sand IO ~6,7s0. MD I .12,485' 1'VD ITop of N. Forelands Sand ~ 17,483' MD 13,032' TVD ~i[ ~ 120' e 1214' MD (1208' 'I'VD) 1 ~! Ii'0's PPOI :~.~i · ,.:: ~..,: :F.: :~ ITOL S" ~ 11,450' MD (869T ~) I I~OL'7' e ~,~S' MD (8765'.TVD) ,, I I~-S/s" e 11,761' MD (8918' TVD) :1 I TOc, i~l 14,300' MD (10,734' T'VD) I 71'F"E~,3o~' UO p ~,37~ TVO) 15' ~)"17,150' MD (12,777" TVD) I 1~1~" 4'17,864' MD (13,356' 'I~/D) AI,ASK;k OIL ~ GAS CO~SERYATIO$ COMMISSION / // / TONY KNOWLES, GOVERNOR 333 W. 7TM AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 October 4, 2001 Mr. Robert Watkins Environmental Specialist Alaska Department of Environmental Conservation 555 Cordova Street Anchorage, Alaska 99501 Re: Tyonek Deep Wells B-01A, B-02 and B-03 PPCo Petroleum Company (PPCo) North Cook Inlet Platform (Tyonek) Cook Inlet Alaska Dear Mr. Watkins' In early September, a meeting was held with PPCo representatives, yourself and myself to discuss the status of the subject wells. PPCo is seeking relief from DEC requirements with regard to maintaining spill response plans and equipment since there is no oil production from their platform. In support of their request, PPCo has submitted information regarding the physical condition of the wells and represents that the wells are well secured and that the chance of any release to the environment is remote. I have reviewed the submitted information. My analysis follows. 'All wells are "on board" Tyonek Platform in Northern Cook Inlet. Tyonek is a continuously manned production platform with 13 producing gas wells and the 3 "Tyonek Deep" wells. As described below, the Tyonek Deep wells are physically well secured. The present condition of the wells is beyond simply being shut in and the Deep wells have been physically isolated from any platform production system. B-01A and B-02 are equipped with tubing, packers, SSSVs and wellhead equipment with all appropriate valving including a SSV. Both wells do not have flowlines installed with such attachment locations covered with blind flanges. The SSSV and SSV control lines are not connected to any control system and valves with plugs have been affixed to the terminations. The SSSV in each Tyonek Deep Wells B-01A, B-02 and B-03 October 4, 2001 Page 2 of'2 tubing string is closed. The tubing above the SSSV in each string has been bled down to provide a differential pressure across the valves. The SSV is not closed so the tubing space above the SSSV can be monitored for any leakage across the SSSV. Since the wells were secured, PPCo has not reported that the wells have exhibited any pressure increase that would indicate a leaking SSSV. B-03 has cemented, tested and unperforated casing set to total depth. The well has never been completed and a deep retrievable bridge plug was set in the well during final operations. Based on my knowledge of no oil production equipment existing on board Tyonek Platform, the documentation submitted by PPCo relating to how the wells have been physically secured and isolated, I concur that the subject wells are well secured and that an oil discharge is not likely. I endorse PPCo's request for the relief requested. Please contact me at 793-1250 if you require further information. Sincerely, Thomas E. Maunder, PE Senior Petroleum Engineer j jo CC: Well Files B-01A-198-002 B-02-197-210 B-03-198-059 Subject: Phillips Tyonek Exemption Date: Thu, 20 Sep 2001 15:41:50 -0800 From-"Watkins, Robert" <Robert Watkins@envircon state ak us> To: "'tom_maunder@admin.state.ak.us'" <tom_maunder@admin.state.ak.us> CC: "Harvey, Susan" <Susan_Harvey@envircon.state.ak.us> Tom- Phillip Alaska is requesting DEC's approval to exempt their Tyonek Platfrom facility from oil discharge prevention and contingency plan requirements. Three well were drilled at this platform. In order to deregulate this facility, we are requiring Phillips to obtain a certification from AOGCC that the wells are in suspended classification under you regulations. If AOGCC concurs that the well are in secure, suspended state, incapable of flow to the surface, and do not present any environmental risk. Upon receipt of your certification, we issue a letter exempting the facility from the State's contingency pla approval requirements. We will advise them that a contingency plan will be required to re-enter the wells in order to perform the modifications converting them to gas production. Thanks, Robert Robert Watkins EPR Section Manager Alaska Department of Environmental Conservation 555 Cordova Street Anchorage, AK 99501 Ph: (907) 269-7680 Fax: (907) 269-7687 Mailto: Robert Watkins@envircon. state.ak, us <mailto:Robert Watkins~.envi.rcon.state.ak.us> Name: Clear Day Bkgrd.JPG [~Clear Day Bkflrd,JPG T¥1~: JPEG Image (imageljpeg) Encoding: base64 I of I 9/21/01 10:10 AM Note to File North Cook Inlet Unit Wells B-01A (198-002), B-02 (197-210) and B-03 (198-059) Phillips Petroleum Company (PPCo) is the operator of North Cook Inlet Platform (NCIUP) in upper Cook Inlet. The platform produces gas from 13 producing wells, ships it to shore where it is liquefied for shipment to Japan. In late 1997 and continuing into 1998, PPCo drilled 3 wells and a sidetrack in a second attempt to further delineate the Sunfish prospect that had been identified with 2 ARCO wells drilled in 1991/1992 and a platform well ddlled/'finished in 1993. In the most recent drilling program PPCo completed and tested B-01A and B-02. The wells are equipped with tubing, packers, sub-surface safety valves, surface safety valves and other tree valves. B-03 was drilled to total depth, cased and cemented. An operations shutdown was granted in late 1998 and the well has never been completed. In order to drill and potentially produce oil wells, 'PPCo is required by DEC regulations to have an Oil Spill Discharge Prevention Plan (Spill Plan) in place. PPCo is required to maintain certain equipment and contractor relationships in order to assure available response resources in case of a spill. The current Spill Plan will expire in early October and PPCo is seeking to be released from the need for a plan since the wells have been secured and PPCo does not have oil production equipment available' on board NCIUP. A meeting was held September 10 at DEC offices with Robert Watkins representing DEC, myself representing AOGCC and 4 PPCo representatives. The currently carried status of the wells according to AOGCC records is 2 oil wells and 1 well .in operations shutdown. From the DEC perspective, the 2 oil wells (B-01A and B-02) are the concern. According to Mr. Watkins, based on the information provided by PPCo, he is ready to release PPCo from the Spill Plan. requirements provided AOGCC concurs that the wells are secure and not at risk to flow. Please see his attached email regarding this subject. In conjunction with this determination, it may be appropriate to change the wells' status to Suspended. PPCo was able to fi'ow test the 2 wells. Following the flow tests, the wells were shut in to await further development. With the drastic decline in crude prices, the potential for an offshore development on a platform that could not produce oil without significant capital investment waS erased. Although crude prices have increased, so has the investment cost and a development scenario has not been put forward. At the present time, the physical condition of the wells is as follows: All wells are "on board" NClUP in Northern Cook Inlet. NClUP is a continuously manned production platform with 13 producing gas wells and the 3 "Sunfish" wells. B-01A and B-02--Wells are equipped with tubing, packers, SSSVs and wellhead equipment with all appropriate valving including a $SV. Both wells do not have flowlines installed with such attachment locations covered with blind flanges. The SSSV and SSV control lines are not connected to any control system and valves with plugs have been affixed to the terminations. The SSSV in each tubing string is closed. The tubing above the SSSV in each string has been bled down to provide a differential pressure across the valves. The SSV is not closed so the tubing space above the SSSV can be monitored for any leakage across the SSSV. Since the wells were secured, PPCo has not reported that 'the wells have leaked. B-03 has cemented, tested and unperforated casing Set to total depth. The well has never been completed and a deep retrievable bridge was set in the well during final operations. Through the discussions with PPCo, they have indicated that they do not intend for the wells to remain in their current configuration indefinitely. They have indicated that in their 2003 budget year, they plan to mobilize a rig to NCIUP. They intend to recomplete the wells as gas wells in the shallower Cook Inlet and Beluga sands. The lower oil intervals will be isolated with cement plugs and retainers to preserve the oil production opportunity should such production equipment and a pipeline be available. I recommend that' the status of B-01A and B-02 be. changed to suspended. The wells are mechanically secure on a continuously manned platform. PPCo does nOt have the necessary production or transportation equipment available to allow the Wells to be produced. The wells are equipped with the necessary equipment (tubing, packers, SSSVs and wellheads) to prevent flow. The .wells are not equipped with flow lines and their hydraulic control, systems have been isolated from the active platform system. PPCo has indicated that within about 2 years, they plan to mobilize a rig to the platform to perform well work. At that time they have indicated that they intend to workover these wells., abandon the lOwer oil zones and recomplete the wells in the shallower gas intervals. In support of this recommendation, the following regulations apply. Suspended Wells 20 AAC 25.110 (a) If allowed under 20 AAC 25.105... 20 AAC 25.105 (b) A well ddlled...from a fixed offshore platform must be abandoned before removal of the drill rig unless the well is completed as an oil...well or is suspended, or unless well operations are shut down in accordance with 20 AAC 25.072. Each well drilled for a fixed offshore platform must be abandoned before the platform is removed or dismantled. ...the commission will, upon application by the operator under (b) of this section, approve the suspension of a well if (1) the well (A) encounters hydrocarbons...to indicate the well is capable of producing in paying quanities or (D) is located On a...platform with active producing...wells and (2) the operator justifies...why the well should not be abandoned...or why the well should not be completed; sufficient reasons include (B) unavailability of surface production or transportation facilities (C) need for pool delineation and evaluation to determine the prudence of pool development (d) A well approved for suspension must be plugged in accordance with the requirements of 20 AAC 25.112, except that the requirements of 20 AAC 25.112(d) do not apply if (1) a wellhead is installed...and (2) a bridge plug capped with 50 feet of cement...; the commission will waive the requirement of this paragraph for a development well drilled from a pad or platform, if the commission determines that the level of activity on the pad or platform assures adequate sUrveillance of that development well. 20 AAC 25.112(i) provides that The commission will, in its discretion, approve a variance from the requirements of the section if the variance provides for at least equally effective plugging of the well and prevention of fluid movement into sources of hydrocarbons or freshwater. AI,ASI~k OIL A~D GAS COS~SERYATIO~/COMMISSIO~ TONY KNOWLES, GOVERNOR 333 W, 7TM AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 August 30, 2001 N.P. Omsberg Drilling Manager Phillips Petroleum Company Box 1967 Houston TX 77251-1967 Re: North Cook Inlet Unit Well NCIU B-3 Dear Mr. Omsberg: The AOGCC records currently reflect the status of the North Cook Inlet Unit Well NCIU B-3 as Temporary Shutdown of Drilling Operations since December 1998. Unless the operator applies for an extension of time under 20 AAC 25.072(d), the operator is required to abandon or suspend the well if operations are not resumed within 12 months. Please provide us with an explanation of Phillips' plan for this well by close of business on September 14, 2001. sincerely, Cammy Oechsli Taylor Chair COT.:\jjc II Note to file 5/11/01 North Cook Inlet Field, Well B-3 Permit number 98-59 This well has a completion with a mechanical bridge plug in the · intermediate casing above the the casing has never been perforated. The well has never been flow tested, is not in pressure communication with the reservoir and is in a mechanically condition. Development of appropriate production facilities has been until an unspecified furore date. An application for approval has been made to mn but not perforate the well. The appropriate status is date and the for this well, at this time is:~~a~Ay s~pended: The current shut-down, which explains why the well is still confidential. The suspension should be 11/01/98. A 407 should solicited from Phillips on the well released. RPC A-AC Geologic Tops Rock Uni t- for Cook Inlet Beluga Fm. Sunfish SS. N.Forelands SS. NCIU B-3 4,468' 5,411' 16,800' 17,494' Oil Shows: None Zones of Abnormal Pressure: North Forelands SS. ~"~B 09'19"99 Alaska Oil & Gas Cons. Commission A~chomge PHILLIPS PETROLEUM CO Page I of 61 0 19 9 Operations Summary Report ~' ~il t,'~ ~ '~AA ~"%~ ~ .... r_ Leg~l~rl~~me:' ' ~ORIH COOK INI..fiT UNIT-B 000003 Common Well Name: North Cook Inlet Unit Spud Date: 05/03/08 Fvent Name: Original Drilling Start: 02/0@/08 End: Contractor Name: Rig Release: Group: Rig Name: Rig Number: Date From- To Hours Sub Co Phase Code Description of Operations 05/01/98 12:00- 00:00 12.00 MV v 00MMIR SKIDDED AND ALIGHNED RIG OVER SLOT # 2 OF LEG #1. INSTALLED VETCO GRAY 30" ALT-2 ADAPTER W/RIG WELDERS. ' REROUTE APOLLO INJECTION LINES TO CONTINUE INJECTION IN B-I. REINSTALL FLOOR PLATING AND STAIRWAYS. PREP. TO N/U DIVERTER SYSTEM. 05/02/98 00:00 - 00:00 24.00 MV v 00MMIR FINISH INSTALL VETCO GRAY 30" ALT-2 ADAPTER RING & 4" COLLARS ON EXIXTING 30" DRIVE PIPE. FINISH CLEAN & RINSE MUD PITS, INSTALL 6.5" LINERS IN MUD PUMPS, HELD SAFETY MEETING, N/U 30 RISER, & 30" DIVERTER SYSTEM W/16" DIVERTER LINES. 05/03/98 00:00 - 00:00 24.00 MV v 00MMIR FINISH NU & FUNCTION TEST 30" DIVERTER SYSTEM W/16" DIVERTER LINE. FINISH INSTALL 6.5" LINERS IN #1 & #2 MUD PUMPS. TEST MUD LINES TO 3000 PSI., REPAIR LINER GASKET LEAK ON PUMP #2. RU FILL UP LINE F/TRIP TANK T/BELL NIPPLE. CLEAN OBM OUT OF MOUSE HOLE. MIXING SPUD MUD. 05/04/98 00:00 - 08:30 8.50 DR 2 05Cl DR PICK UP, MAKE UP, & GIH W/24" BIT, DIRECTIONAL BHA,& 8" HWDP. TAG @ 364' 08:30 - 10:30 2.00 DR 1 05ClDR CLEAN OUT30" DRIVE PIPE F/364' T/407'. MUD MOTOR BEGAN STALLING OUT @ 407'. ClRC BU @ 407' 10:30 - 15:30 5.00 DR 4 05C1 DR POOH W/24" BIT, GIH W/24" OD MILL & 8" HWDP ON 5" D.P. TO 407', CLEAN OUT W/24" MILL F/407' T/416'. 15:30 - 16:30 1.00 DR 5 05ClDR ClRC BU, RU & GIH W/GYRO SURVEY. RAN GYRO SURVEY F/ SURFACE T/390'. 16:30 - 18:00 1.50 DR 4 05Cl DR POOH W/24" OD MILL. 18:00 - 19:00 1.00 DR 4 05Cl DR GIH W/24" BIT, DIRECTIONAL BHA, 8" HWDP, & JAR ON 5" D.P.. 19:00 - 20:00 1.00 DR 1 ~05ClDR DRILLING 24" HOLE F/ 416' T/ 441'. ClRC BU @ 441' 20:00 - 20:30 0.50 DR b 05Cl DR RAN GYRO SURVEY F/SURFACE T/400' 20:30 - 00:00 3.50 DR 1 05Cl DR DRILLING SLIDING & ROTATING F/441' T/533°. RUNNING GYRO SURVEYS EVERY 30'. 05/05/98 00:00 - 00:00 24.00 DR q 05Cl DR DRILLING (SLIDING & ROTATING) F/533 T/1214' TAKING MWD SURVEYS EVERY 30' & GYRO SURVEYS EVERY 90'. 05/06/98 00:00 - 00:30 0.50 DR q 05ClDR DIREC DRILLING ROTATE AND SLIDE F/1214' T/1260'. SURVEYING W/MWD & GYRO, EVERY 30' W/MWD & EVERY 90' W/GYRO. STILL GETTII~G MAGNETIC INTERFERENCE FROM DRILL STRING. 00:30 - 01:30 1.00 CS 5 05C1RC PUMP HIGH VIS SWEEP & ClRC BOTTOMS UP AT 23.4 BPM. 01:30 - 02:00 0,50 CS z 05Cl RC SURVEY W/GYRO AT 1260'. 02:00 - 03:00 1.00 CS 4 05Cl RC PULL BIT UP INTO 30" DRIVE PIPE T/400', NO EXCESS DRAG. 03:00 - 03:30 0.50 CS 6 05C1RC RD APRS WIRELINE UNIT AND GYRO DATA SURVEYING TOOLS. 03:30 - 04:30 1.00 CS 4 05ClRC TIH W/DIRECTIONAL ASSEMBLY T/1260' HOLE IN GOOD CONDITION. 04:30 - 06:30 2.00 CS 5 05ClRC PUMPED HIGH VIS SWEEP, ClRC BOTTOMS UP, SPOT HIGH VIS PILL ON BOTTOM. 06:30 - 09:00 2.50 CS 4 05ClRC POOH TO RUN 20" CONDUCTOR PIPE. LD 24" BIT, 24" STABILIZER AND 18-1/2" STABILIZER. 09:00 - 13:30. 4.50 CS 6 05ClRC RU WEATHERFORD CASING CREW & TOOLS.. 13:30 - 14:00 0.50 CS ~0 05Cl RC HELD PRE-JOB SAFETY MEETING FOR RUNNING 20" CASING AND ASSOCIATED OPERATIONS. 14:00 - 20:30 6.50 CS 1 05Cl RC RAN 20" CASING AS FOLLOWS: WEATHERFORD 20" MODEL 323 SURE SEAL FLOAT SHOE (PRE-WELDED ONTO CASING 1.55'), 1 JT Printed: 11/04/98 6:42:37 AM , i PHILLIPS PETROLEUM CO Page 2 of 61 Operations Summa Report !Legal Well Name: - NORTH COOK INLET UNIT-B 000003 Common Well Name: North Cook Inlet Unit B-3 Spud Date: 05/03/98 Event Name: Original Drilling Start: 02/09/98 End: Contractor Name: Rig Release: Group: Rig Name: Rig Number: Date From.- To Hours Sub Co;Phase Code Description of Operations , .. 05/06/98 14:00 - 20:30 6.50 CS 1 05ClRC 20' 133 PPF K-55 FRANKS TENCOM THREAD CASING 38.21', 1 20" PUP JT SAME AS ABOVE 10.25', WEATHERFORD 20" MODEL 402-1L FLOAT COLLAR 2.40' PRE-WELDED ONTO CASING, RAN 27 JTS OF 20" CASING SAME AS ABOVE (1093.90'), PU 9.73" PUP JT, 2.14' VETCO GRAY 20" CASING HANGER, 14.68' PUP JT, 9.20' PUP JT & 1 JT 20" 133 PPF BUTTRESS THREAD CASING. TOTAL LENGTH OF CASING STRING 1222.39'. HUNG OFF CASING IN 20" LANDING COLLAR W/FLOAT SHOE @ 1214.54' AND FLOAT COLLAR @1162'. HOLE TOOK 10-12 BBL MUD DURING RUNNING OF 1ST TEN JTS OF CASING. HOLE STOPPED TAKING MUD. 20:30 - 21:30 1.00 CE 5 05Cl RC CIRC. STAGE PUMPED RATE STARTING AT 25 SPM (3 BPM) INCREASED RATE AT 5 SPM EACH STAEP TO 130 SPM (16 BPM). HAD NO MUD LOSS WHILE CIRCULATING. TOTAL WT OF CASING STRING 105,000 LB W/O BLOCKS AND TOP DRIVE. 21:30 - 00:00 2.50 CE 6 05Cl RC BACKED OUT LANDING JTS & LD SAME. RD WEATHERFORD CASING TOOLS AND CHANGE OUT BAILS. 05/07/98 00:00 - 00:30 0.50 CE 2 05ClRC RU TO RUN DRILL PIPE STAB IN CEMENTING SUB ' 00:30 - 01:30 1.00 CE 4 05Cl RC TIH W/WEATHERFORD STINGER MODEL 154. 01:30 - 02:30 1 .'00CE 5 05ClRC STAB IN AND CIRCULATE FRONT AND BACKSIDE WHILE ADJUSTING MUD PROPERTIES FOR CMNT JOB. HOLD SAFETY MEETNG DURING CIRC. 02:30 - 05:00 2.50 CE 0 05C1RC MIXED CMNT ADDITIVES INTO LEAD CMNT WATER IN 4 - 75 BBL BATCHES AND HELD IN 400 BBL STORAGE TANK. MIXED ADDITIVES IN WATER FOR TAIL CMNT AND HELD IN MUD TANK. TEST H-S-C LINES @2000 PSI. PUMP CMNT JOB AS FOLLOWS: PUMPED 30 BBLS FRESH WTR SPACER FOLLOWED BY 25 BBL SCAVENGER CEMENT SLURRY (10 PPG). MIXED & PUMPED LEAD CMNT - 644 SX PREMIUM CMNT W/3% GEL, .5% CFR-3, 1% CACL2 & 1/4#/SK FLOCELL MIXED @ 12 PPG W/YIELD OF 2.44 CUFT/SK. MIXED & PUMPED TAIL CMNT - 720 SX PREMIUM CMNT W/.3% CFR-3, 1% CACL2, 1/4#/SK FLOCELL MIXED @ 15.8 PPG W/YIELD OF 1.15 CUFT/SK. ENTIRE CMNT JOB PUMPED @ 7 BPM AVG RATE W/MAX PRES OF 290 PSI. ATTEMPTED TO RELEASE DP WIPER PLUG. PLUG FOULED IN PLUG CONTAINER AND FINALLY RELEASED 6 BBL LATE. DISPLACED CMNT 21 BBL(DID NOT BUMP PLUG), SHUT DOWN PUMP, PULLED STINGER OUT OF FLOAT COLLAR. ESTIMATED 4 BBL CMNT LEFT ON TOP OF FLOAT COLLAR. PU APPROX 40' AND CIRCULATE DP. 05:00 - 06:00 1.00 CE 4 05C1RC TOH, LD DS & STAB-IN CMNT TOOL. 06:00 - 14:00 8.00 CS t 05C1RC PICK U P STACK - INSTALL VETCO'S PACK OFF AND LOCK DOWN RINGS FOR 20" CASING. 14:00 - 18:00 4.00 DR 8 05C1RC NU STACK - BELL NIPPLE - DIVERTER LINE - FUNCTION TEST HYDRIL AND KNIFE VALVE ON DIV LINE. GOOD TESTS. 18:00 - 00:00 6.00 DR 2 20SFDR MAKE UP BHA (BIT-MOTOR-XO-FLOAT SUB-NMLC-NMSTAB-NMLC-NMDC-NMSTAB-NMDC-XO-20 HWDP-JARS-5 HWDP-XO= 955.72'. ADJUST MOTOR AND ORIENT MWD. 05/08/98 00:00 - 01:00 1.00 DR 4 20SFDR PICK UP DIRECTIONAL BHA TO DRILL 16" HOLE. 01:00 - 02:00 1.00 DR 4 20SFDR CIRC AND TIH TO TOC. 02:00 - 04:30 2.50 DR r 20SFDR TAG CMNT @1146'. DRILL FLOAT COLLAR @1161' AND CMNTTO 1212'. DRILL THROUGH SHOE @1212'. WASH T/1260'. Printed: 11/04/98 6:42:37 AM PHILLIPS PETROLEUM CO Page 3 of 61 Operations Summar Report Legal Well Name: NORTH COOK INLET UNIT-B 000003 Common Well Name: North Cook Inlet Unit B-3 Spud Date: 05/03/98 Event Name: Original Drilling Start: 02/09/98 End: Contractor Name: Rig Release: Group: Rig Name: Rig Number: Date From - To Hours Sub Co Phase Code Description of Operations 05/08/98 04:30 - 05:00 0.50 DR 5 20SFDR ClRC BU AND CLEAN HOLE. 05:00 - 00:00 19.00 DR q 20SFDR DIRECTIONALLY DRILL BY ROTATING AND SLIDING F/1260' T/2370' : (AVG ROP 58.4'/HR). 05/09/98 00:00 - 00:00 24.00 DR q 20SFDR DIRECTIONAL DRILL BY ROTATION AND SLIDE F/2370' T/3676'. 05/10/98 00:00 - 15:30 15.50 DR q 20SFDR DIRECTIONAL DRLG. ROTATE AND SLIDE FROM 3676' TO 4422'. 15:30 - 17:00 1.50 DR 5 20SFDR CIRC. SAMPLES FOR MUD LOGGER. 17:00 - 19:00 2.00 DR 5 20SFDR PUMPED 35 BBL HI VIS SWEEP AND CIRC. HOLE CLEAN. 19:00 - 21:00 2.00 DR 4 20SFDR PUMPED DRY JOB AND POOH FOR WIPER TRIP. HAD NO EXCESS DRAG. 21:00 - 22:30 1.50 DR 4 20SFDR TIH TO 4410', OK. WASHED 12' TO BOTTOM W/NO FILL. 22:30 - 00:00 1.50 CS 5 20SFRC BREAK CIRC. AND CIRC. BOTTOMS UP, HAD 138u GAS ON BOTTOMS UP. 05/11/98 00:00 - 00:30 0.50 CS 5 20SFRC C & CM. PUMPED DRY JOB. 00:30 - 04:00 3.50 CS 4 20SFRC POOH. 04:00 - 05:00 1.00 CS 2 20SFRC LD BIT/BHA. 05:00 - 07:30 2.50 CS 6 20SFRC RU CSG TOOLS. 07:30 - 08:30 1.00 CS 0 20SFRC HELD PRE JOB SAFETY MEETING. 08:30 - 19:00 10.50 CS 1 20SFRC RAN 13-3/8" CASING AS FOLLOWS: 1 WEATHERFORD 13-3/8" MODEL 323 PDC DRILLABLE FLOAT SHOE, 1.80; 1 FLOAT JT. 13-3/8" 68# HCL80 BTC CASING, 42.25; 1 WEATHERFORD 13-3/8" MODEL 402NT FLOAT COLLAR, 1.55. LENGTH OF FLOATS 45.60'. RAN 103 JTS. OF 13-3/8" 68# HCL80 BTC CASING, 4287.03'; 1 PUP JT, 9.86'; CASING HANGER,.70; PUP JT.,16.07; LANDING JT.,45.30. SHOE @ 4400', FLOAT COLLAR @ 4355'. RAN TOTAL OF 104 JTS, 4329.28' 13 3/8" CSG. 19:00 - 22:30 3.50 CE 5 20SFRC CIRC. AND COND MUD W/FLOAT SHOE @ 4396'. 22:30 - 23:30 1.00 CS n 20SFRC LAND 13 3/8" CSG, RU HALLIBURTON CMTG HEAD & BREAK CIRC @ 7 BPM. 23:30 - 00:00 0.50 CE 0 20SFRC 05/12/98 00:00 - 00:30 0.50 CE 0 20SFRC HELD PRE JOB SAFETY MEETING. PRESSURE TESTED LINES TO 2000 PSI. 00:30 - 04:00 3.50 CE !1 20SFRC PUMPED 30 BBL WATER AHEAD. MIXED & PUMPED 1000 SX LEAD CMT + ADDITIVES @ 12 PPG. TAILED IN W/600 SX PREMIUM CMT + ADDITIVES @ 15.8 PPG. DROPPED TOP PLUG & DISPLACED W/MUD. BUMPED PLUG TO 1800 PSI. HELD OK. 04:00 - 04:30 0:50 CE 9 20SFRC PRESSURED UP & TESTED CSG TO 2000 PSI F/ 30 MIN - OK. 04:30 - 06:00 1.50 CS 6 20SFRC RD CMTG HEAD & LAY OUT LANDING JOINTS. 06:00 - 16:30 10.50 CS 6 20SFRC HELD PREJOB SAFETY MEETINGS @ 0630 & CREW CHANGE @ 11:30. ND BELL NIPPLE, 29 1/2" HYDRIL, DIVERTER LINE, VALVE & RISER SPOOLS 16:30 - 17:30 1.00 CS e 20SFRC INSTALL VETCO GRAY PACK-OFF RING AROUND 13-3/8" CASING. 17:30 - 21:00 3.50 CS e 20SFRC INSTALLED VETCO GRAY 13-3/8" X 21-1/4" 2M X 13-5/8" 5M CASING SPOOL. ENERGIZED PACK-OFF W/3500 PSI. TESTED VOI'D TO 2000 PSI FOR 30 MIN., TESTED OK. 21:00 - 23:00 2.00 WC e 20SFRC CUT LARGER HOLE IN.WELL GUARD PLATE TO FIT 13-5/8" RISER THROUGH. SET FLOOR PLATE IN CELLAR OVER WELL. SET CATWALK BACK IN PLACE. 23:00 - 00:00 1.00 WC e 20SFRC NIPPLE UP 13-5/8" 5M X 13-5/8" 10M DSA. NIPPLED UP 13-5/8" 10M BOP STACK. 05/13/98 00:00 - 02:00 2.00 WC e 20SFRC N/U 13-5/8" 10M RISERS ON WELLHEAD. RISERS NOT LONG .... Printed: 11/04/98 6:42:37 AM PHILLIPS PETROLEUM CO Page 4 of 61 Operations Summa Report Legal Well Name: NORTH COOK INLET UNIT-B 000003 Common Well Name: North Cook Inlet Unit B-3 Spud Date: 05/03/98 Event Name: Original Drilling Start: 02/09/98 End: Contractor Name: 'Rig Release: Group: Rig Name: Rig Number: Date From - To Hours Sub Co Phase! Code Description of Operations 05/13/98 00:00 - 02:00 2.00 WC e 20SFRC ENOUGH TO REACH THRU 2nd DECK TO LAND BOP STACK. ORDERED OUT 2' SPACER SPOOL FROM WEATHERFORD RENTALS. LONGSHOREMEN NEED 2 HOURS NOTICE BEFORE COMING TO DOCK TO LOAD SPOOL. SPOOL LOADED AND BOAT UNDER WAY @ 0400 HRS. 02:00 - 06:30 4.50 WO u 20SFRC WHILE WAITING ON SPACER SPOOL TO ARRIVE @ RIG, CHANGED LINERS IN BOTH RIG PUMPS TO 6". CLEANED ON PLATFORM PITS I TO PREPARE FOR OIL BASE MUD. 06:30 - 14:30 8.00 WC e 20SFRC i INSTALLED 2" SPACER SPOOL AND N/U 13-5/8" 10M SHAFFER BOP STACK AND 13-5/8" 5M HYDRIL GK. INSTALLED CHOKE LINE AND KILL LINE ONTO BOP STACK. : 14:30 - 16:00 1.50 WC 8 20SFRC RIGGED UP BOP TEST EQUIP. AND PICKED UP TEST JTS. AND TEST PLUG. HAD TROUBLE GETTING TEST PLUG TO SEAL IN WELLHEAD. PULLED TEST PLUG AND REPAIRED SAME. RERAN TEST PLUG, NOW SEALS OK. 16:00 - 20:30 4.50 WC 8 20SFRC TESTED CHOKE MANIFOLD, CHOKE LINES, KILL LINES, BLIND RAMS, TOP AND BOTTOM PIPE RAMS, AND FLOOR VALVES TO 250/5000 PSI. ALL TESTED OK. TESTED HYDRIL TO 250/3500 PSI, OK. STATE OIL AND GAS COMMISSION REP. JOHN SPALDING ON BOARD TO WITNESS BOP TEST. 20:30 - 21:00 0.50 WC 8 20SFRC RIGGED DOWN BOP TEST EQUIP. AND LAYED DOWN TEST JTS. INSTALLED WEAR BUSHING IN WELLHEAD. 21:00 - 00:00 3.00 DR 2 3011DR PICKING UP ANADRILS DIR. BHA. 05/14/98 00:00 - 00:30 0.50 DR 2 20SFRC ! PU BHA: BIT, MTR & MU MOTOR STAB. PU NEW MWD & CDR TOOL. 00:30 - 03:00 2.50 DR 9 20SFRC .ORIENT MTR & MWD, FUNCTION TEST SAME. 03:00 - 05:00 2.00 DR 4 20SFRC 'PU 5 JTS 6 5/8" SPIRAL WT & TIH TO 2043'. 05:00 - 06:00 1.00 RM c 20SFRC SLIP & CUT DRLG LINE. 06:00 - 07:30 1.50 DR 4 20SFRC FINISH TIH. 07:30 - 09:00 1.50 CS 9 20SFRC. BROKE CIRC. RU HALLIBURTON. TESTED LINE TO 5000 PSI THEN TESTED CSG TO 4000 PSI F/ 30 MIN - OK. 09:00 - 11:00 2.00 CE s 20SFRC DRILLED FLOAT COLLAR, CMT, FLOAT SHOE + 10 FT OF NEW HOLE TO 4432'. 11:00 - 13:00 2.00 CE 5 20SFRC CIRCULATE & CONDITION MUD PRIOR TO RUNNING LOT. 13:00 - 13:30 0.50 CE r 20SFRC PERFORMED LOT: MW = 9.3 PPG. PRESSURE BROKE AT 690 PSI, WHICH CALCULATES 12.8 PPG EMW. 13:30 - 14:00 0.50 DR 0 20SFRC HELD PREJOB SAFETY MEETING PRIOR TO CLEANING PITS. 14:00 - 15:30 1.50 DR 5 !20SFRC MIXED 34 BBL HI-VIS PILL W/NUT PLUG ADDED TO PILL. PUMPED HI-VIS PILL INTO DRILL PIPE AND SHUT DOWN PUMP. 15:30 - 00:00 8.50 DR z '20SFRC CLEANING MUD PITS,POSSUM BELLY ON SHAKERS, DESILTER, DESANDER, FLUSH GUN LINES AND HOPPER LINES, CLEAN WATER BASE MUD OUT OF CHOKE LINE AND KILL LINE, GREASE I-BOP VALVE, REPLACE DRILLING RECORDER LINE, SEAL CRACKS IN RIG FLOOR, CLEANING OUT TRIP TANKS. 05/15/98 00:00 - 08:00 8.00 DR z 3011 DR CLEAN ACTIVE PITS, PLATFORM MUD PITS, TRIP TANK & SHAKERS. PUMP THROUGH ALL LINES, BLEW OUT STAND PIPE, CHOKE MAN/LINE, MUD/GAS SEPERATOR & MUD PUMPS. DISCONNECTED & BLINDED O/BOARD DUMP LINE FR/ACTIVE PITS. LOCKED OUT DUMP VALVES. 08:00 - 12:00 4.00 DR z 3011 DR TRANSFER OBM FR/GIRDER TANKS & ISO TANKS ON DECK TO PLATFORM & RIG PITS. MIX 40 BBL HI-VIS OBM SWEEP W/HI CONC OF DRILL TREAT. Printed: 11/04/98 6:42:37 AM PHILLIPS PETROLEUM CO Page 5 of 61 Operations Summa Report Legal Well Name: NORTH COOK INLET UNIT-B 000003 Common Well Name: North Cook Inlet Unit B-3 Spud Date: 05/03/98 Event Name: Original Drilling Start: 02/09/98 End: Contractor Name: Rig Release: Group: Rig Name: Rig Number: Date From - To Hours Sub ColPhase Code Description of Operations 05/15/98 12:00 - 12:30 0.50 DR 0 3011DR HELD PREJOB SAFETY MEETING PRIOR TO DISPLACING W/OBM. 12:30 - 13:00 0.50 DR z 3011 DR PRIME MUD PUMPS & TOP OFF ACTIVE PITS. 13:00 - 14:00 1.00 DR 5 3011DR PUMPED 40 BBL HI-VIS OBM SPACER. BROKE CIRC @ 5 BPM, INCR'D :lATE TO 11 BPM. UNABLE TO TRANSFER OBM FR/GIRDER TANKS FAST ENOUGH, SO SLOWED RATE BACK TO 6 BPM. 14:00 - 18:00 4.00 DR 6 3011DR REMOVED OVERBOARD LINE ANDSLIDE AUGER TO APOLLO AND HOOKED UP SAME. FILLED PITS W/OIL BASE MUD. 18:00 - 19:30 1.50 DR 5 3011 DR PUMPED OUT REMAINDER OF WATER BASE MUD AND PUMPED OUT 60 BBLS OF OIL BASE MUD INTERFACE TO APOLLO. 19:30 - 00:00 4.50 DR q 13011DR DIRECTIONAL DRILLING, ROTATE AND SLIDE FROM 4432' TO 4845'. ACTUAL ON BOTTOM ROTATING TIME, 2 HRS. F/354' @ 177 FPH. ACTUAL ON BOTTOM SLIDING TIME, 1 HR. F/59' @ 59 FPH. 05/16/98 00:00 - 17:00 17.00 DR q 3011DR DRILL DIRECTIONALLY (ROTATING & SLIDING) IFR/4845 - 5970'. ROTATED 784' IN 7 HRS. @ 112.0 FPH, SLIDE 341' IN 3.5 HRS. @ 97.4 FPH. CONN. AND SURVEY TIME, 6.5 HRS. 17:00 - 18:30 1.50 DR 5 3011DR CIRC. BOTTOMS UP, PREP. TO POOH TO CHANGE BHA. 18:30 - 22:00 3.50 DR 4 3011 DR BACK REAM WHILE POOH FROM 5970' TO 13-3/8" CASING SHOE @ 4400'. 22:00 - 22:30 0.501 DR 5 3011 DR MIX AND PUMP SLUG, PREP. TO FINISH POOH. 22:30 - 00:00 1.50 DR 4 3011DR POOH TO CHANGE BHA. 05/17/98 00:00 - 02:30 2.50 DR 14 3011 DR FINISHED POOH. DRAINED MOTOR AND INSPECTED BIT. BIT HAD 3 CHIPPED BUTTONS ON OUTER CUTTERS OF EACH BLADE. 02:30 - 04:30 2.00 DR 2 3011DR DOWN LOAD CDR AND REPROGRAM SAME, CHANGED OUT MWD, PICKED UP 12-1/8" STAB. APPROX. 43' ABOVE BIT, PULLED BACK UP AND REPROGRAMED CDR. 04:30 - 06:00 1.50 DR 4 3011 DR TIH W/6-5/8" HWDP AND 1 STD. OF DRILL PIPE. 06:00 - 07:00 1.00 RM rn 3011 DR CHANGED OUT SAVER SUB ON TOP DRIVE. 07:00 - 09:00 2.00 DR 4 3011DR TIH TO 5254', FILLED PIPE @ 13-3/8" CASING SHOE @ 4400'. APOLLO'S FLUID INJECTION PUMP DOWN. 09:00 - 09:30 0.50 DR 4 3011 DR POOH TO 13-3/8" CASING SHOE. 09:30 - 10:30 1.00 we 7 3011DR TROUBLESHOOT APOLLO'S ELECTRICAL POWER PROBLEM, FOUND BAD HEATERS IN SWITCH BOX. REPAIRED SAME NOW WORKING OK. 10:30 - 11:30 1.00 DR 4 3011DR TIH TO 5881' 11:30 - 12:00 0.50 DR d 3011 DR WASHED 69' TO BOTTOM, HAD NO FILL. HAD THICK MUD OVER SHAKERS. 12:00 - 13:00 1.00 DR 5 3011DR CIRC. OUTTHICK MUD. 13:00 - 00:00 11.00 DR q 3011DR DIRECTIONAL DRILLING, ROTATE AND SLIDE FROM 5970"TO 6920'. ROTATED 890' IN 6.0 HRS. @ 148.33 FPH. SLIDE 60' IN 1.5 HRS. @ 40.0. FPH. CONN. AND SURVEY TIME 3.5 HRS. 05/18/98 00:00 - 08:30 8.50 DR q 3011 DR DRLG DIRECTIONAL SLIDING & ROTATING FR/6920 - 7579'. (NOTE: APOLLO'S INJECTION PUMP LOST ELECTRIC POWER @ 06:30. CONT'D DRLG WHILE TROUBLE SHOOTING PROBLEM UNTIL ALL CUTTINGS STORAGE WAS FILLED.) ROTATE: 587ft/5hr = 117.4 ft/hr. SLIDE: 72ft/1.5hr = 48 fi/hr. CONN & SURVEY = 2.5hr. 08:30 - 14:00 5.50 DR 4 3011DR MADE WIPER TRIP TO 6828' (PULLED TIGHT), UNABLE TO BACKREAM OUT DUE TO LACK OF SPACE F/CUTTINGS. FOUND ELECTRIC CABLE SUPPLYING POWER TO APOLLO'S PUMP BURNT AT A CONNECTOR - REPAIR SAME. INJECTED SLURRY FR/SLURRY TANKS, HOLDING TANK & BOTH PLATFORM PITS DEDICATED TO APOLLO. TIH TO 7403'. WASHED THRU TIGHT SPOT F/7403' TO 7435'. WASHED LAST 94' TO BOTTOM, OK. Printed: 11/04/98 6:42:37 AM PHILLIPS PETROLEUM CO Page 6 of 61 Operations Summa Report Legal Well Name: NORTH COOK INLET UNIT-B 000003 Common Well Name: North Cook Inlet Unit B-3 Spud Date: 05/03/98 Event Name: Original Drilling Start: 02/09/98 End: Contractor Name: Rig Release: Group: Rig Name: Rig Number: Date From o To Hours Sub Co Phase: Code Description of Operations 05/18/98 14:00 - 00:00 10.00 DR q' 3011DR DIR. DRLG. ROTATE AND SLIDE FROM 7579' TO 8060'. DRILLED F/10 HRS. ROTATED 432' IN 5.5 HRS. @ 78.54 FPH. SLIDE 49' IN 2.25 HRS. @ 21.78 FPH. CONN. AND SURVEY TIME 2.25 HRS. 05/19/98 00:00 - 00:00 24.00 DR q 3011 DR DIRECTIONAL DRILLING, ROTATE AND SLIDE FROM 8060' TO 9080'. ROTATED 940" IN 14.6 HRS. @ 64.38 FPH. SLIDE 80' IN 2.5 HRS. @ 32.0 FPH. CONN. AND SURVEY TIME 6.9 HRS. NOTE: ROTATE 60.8% OF TIME SLIDE 10.45% OF TIME CONN. & SURVEY 28.75% OF TIME AVG. CONN.& SURVEY TIME 37.6 MIN. PER STD. 05/20/98 00:00 - 06:00 6.00 DR q 3011 DR DIRECTIONAL DRILLING, ROTATE AND SLIDE, FROM 9080' TO 9296'. ROTATED 216' IN 5.6 HRS. @ 38.57 FPH. NO SLIDING TIME. CONN. AND SURVEY TIME, .4 HRS. 06:00 - 07:00 1.00 DR 5 3011 DR CIRC. DO'I-rOMS UP, PREP. TO BACKREAM OUT OF HOLE. 07:00 - 21:30 14.50 DR p 3011DR BACKREAMING OUT OF HOLE FROM 9296' UP TO 2596', 1804' INSIDE 13-3/8" CASING. HAD SEVERAL SPOTS IN OPEN HOLE WHERE DRAG INCREASED 5:10M OVER NORMAL DRAG AND TORQUE INCREASED TO MAX. 850 AMPS IN SAME AREAS. 21:30 - 23:00 1.50 DR p 3011 DR PULLED INTO TIGHT SPOT @ 2596'. BACKREAMED AND WASHED UP i TO 2421'. HOLE PACKED OFF AND LOST COMPLE'FE RETURNS LOST iAPPROX 130 BBLS. WORKED PIPE BACK DOWNHOLE TO 2690' AND REGAINED FULL RETURNS. SEEM TO HAVE PULLED BIT AND STABS. INTO CUTTINGS BED AND PACKED OFF HOLE. 23:00 - 00:00 1.00 DR 5 3011 DR CIRC. HOLE CLEAN @ 2690'. UNLOADED LOTS OF CUTTINGS FROM HOLE, CUTTINGS APPROX. 4" DEEP ON ALL SHAKERS. PUMPED 4000 STKS. @ 17 BPM W/1300 PSI, HOLE CLEANED UP. 05/21/98 00:00 - 05:00 5.00 DR p 3011DR BACK REAM OOH F/2690' T/1115'. POOH F/1115' TO SURFACE. 05:00 - 06:00 1.00 DR z 3011 DR CLEAN OBM FROM DRILL FLOOR AREA. RETRIEVE WEAR BUSHING. 06:00 - 10:00 4.00 WC 8 3011 DR WEEKLY DOPE PRESSURE TEST: INSTALLED TEST PLUG, TEST DRILL PIPE & BLIND RAMS, HCR, CHOKE & KILL EINES, IBOPS, TIW VALVES, & CHOKE MANIFOLD TO 250 PSI LOW & 5000 PSI · HIGH PRESSURE TEST. HELD OK. PRESSURE TEST HYDRIL TO 250 PSI LOW & 3500 PSI HIGH PRESSURE TEST. 10:00 - 10:30 0.50 DR 8 3011 DR RETRIEVE TEST PLUG, INSTALL WEAR BUSHING. SERVICE TOP DRIVE UNIT. 10:30 - 18:30 8.00 RM m 3011 DR REDUCE LINER SIZE IN MUD PUMPS F/6" T/5.5" LINERS. MAX PRESSURE W/5.5" LINERS IN MUD PUMPS WILL BE 4740#. SLIP & CUT DRILLING. RESET CROWN-O-MATIC. 18:30 - 21:30 3.00 DR 2 3011 DR GIH W/BIT 3 & BHA, TEST MWD, ORIENT MUD MOTOR. 21:30 - 00:00 2.50 DR 2 3011DR LAYDOWN 5" D.P. W/ERODED HARDBANDING 05/22/98 00:00 - 05:00 5.00 DR 2 3011DR' FINISH LAYDOWN 42 JTS OF 5" D.P. W/ERODRED HARDBANDING, PICK UP 5" D.P. TO REPLACE D.P. THAT WAS LAYED DOWN. GIH W/BIT #3 T/ 50.46' 05:00 - 06:30 1.50 DR 5 3011DR ESTABLISH ClRC @ 5046' W/FULL RETURNS, PUMP & CIRC OUT' 2 LCM PILL W/FULL RETURNS. 06:30- 11:00 4.50 DR 3011DR GIH W/BIT #3 PICKING UP5" D.P. F/5046' T/8429'. 11:00 - 12:00 1.00 DR ;5 3011DR ESTABLISH CIRC @ 8429' W/FULL RETURNS. Printed: 11/04/98 6:42:37 AM PHILLIPS PETROLEUM CO Page 7 of 61 Operations Summa Report Legal Well Name: NORTH COOK INLET UNIT-B 000003 Common Well Name: North Cook Inlet Unit B-3 Spud Date: 05/03/98 Event Name: Original Drilling Start: 02/09/98 End: Contractor Name: Rig Release: Group: Rig Name: Rig Number: Date From - To Hours !Sub Co Phase Code Description of Operations 05/22/98 12:00 - 12:30 0.50 DR 4 3011 DR GIH W/BIT #3 F/8429' T/9183'. 12:30 - 13:30 1.00 DR p 3011 DR REAMING F/9183' T/9296'. (LOST RIG POWER) 13:30 - 15:00 1.50 RM z 3011 DR LOSS OF RIG POWER DUE TO LOW SUPPLY GAS F/PPCO PIPELINE TO POOL ARTIC ALASKA GAS TURBINE. SUPPLY GAS REGULATOR WAS ADJUSTED TO ALLOW GREATER GAS VOLUME TO FLOW TO GAS TURBINE. 15:00- 18:00 3.00 DR q 3011 DR DRILLING (SLIDING & ROTATING) F/9296' T/9365'. 18:00 - 19:00 1.00 RM z 3011 DR ADJUST SUPPLY GAS F/PPCO T/POOL ARTIC ALASKA GAS TURBINE. 19:00 - 00:00 5.00 DR q 3011 DR DRILLING (SLIDING & ROTATING) F/9365' T/9439'. 05/23/98 00:00 - 09:00 9.00 DR q 3011DR DIRECTIONAL DRILLING (SLIDING & ROTATING) F/9439' T/9684' = 245' IN 6.5 HRS DRILLING TIME = 37 FPH ROP. 09:00 - 15:00 6.00 DR z 3011DR ClRC & COND HOLE & RECIPROCATE DRILL STRING WHILE APOLLO SERVICES THINNED CUTTINGS AND INJECTED IN DISPOSAL ANNULUS OF INJECTION WELL. APOLLO SERVICES TANKS WERE FILLED WITH FINE DRILL CUTTINGS WHEN LOW VIS & HIGH VIS HOLE SWEEP WAS RETURNED TO SURFACE. 15:00 - 00:00 9.00 DR q 3011 DR DIRECTIONAL DRILLING (SLIDING & ROTATING) F/9684' T/9977' = 293' IN 9HRS DRILLING TIME = 32 FPH '05/24/98. 00:00 - 04:00 4.00 DR q 3011 DR DIRECTIONAL DRILLING FROM 9977' TO 10120', 143' @ 35.75 FPH. 04:00 - 05:00 1.00 DR 5 3011 DR LOST POWER, TURBINE LOW FUEL. HAD TROUBLE RESTARTING TURBINE. 05:00 - 12:00 7.00 DR q 3011DR DIRECTIONAL DRILLING FROM 10120'TO 10242', 122' @ 17.43 FPH. 12:00-13:00 1.00 RM rn 3011DR ClRC. W/ #1 PUMP AND WORK PIPE WHILE REPLAClNG ROD & SWAB IN #2 PUMP 13:00 - 16:00 3.00 DR q 3011 DR DIRECTIONAL DRILLING FROM 10242' TO 10342', 100' @ 33.33 FPH. 16:00 - 18:30 2.50 RM m 301'1 DR WASHED OUT AROUND HEAD GASKET ON #2 PUMP (FLUID END). REPAIR SAME W/WELDER. 18:30 - 00:00 5.50 DR q 3011DR DIRECTIONAL DRILLING FROM 10342'TO 10453', 111' @ 20.18 FPH **NOTE** PIT DRILL W/DAY CREW = 95 SECONDS PIT DRILL W/NITE CREW= 89 SECONDS 05/25/98 00:00 - 13:00 13.00 DR q 3011DR DIRECTIONAL DRILLING (ROTATING) F/10452" T/10700'= 248' @ 19 FPH 13:00 - 14:00 1.00 RM m 3011DR RIG REPAIR, REPAIR LEAK ON SUCTION VALVE 14:00- 14:30 0.50 RM z 3011DR RIG REPAIR, LOST RIG POWER, POOL ARTIC ALASKA GAS TURBINE LOST POWER 14:30- 17:00 2.50 DR q 3011DR DIRECTIONAL DRILLING (ROTATING) F/10700' T/10774'= 74' @ 30.8 FPH 17:00 - 00:00 7.~)0 RM m 3011 DR RIG REPAIR, REPAIR MUD PUMP #2, POP OFF VALVE POPPING OFF @ 4200# PSI. CHECK & CLEAN DISCHARGE SCREEN, REBUILD 4" DISCHARGE VALVE, REPLACE SUCTION VALVE, REPLACE WASHED OUT SEAT & CLEANED OUT SUCTION MANIFOLD. 05/26/98 00:00- 15:30 15.50 DR q 3011DR ' DIRECTIONAL DRILLING ROTATING F/10774' T/10907' = 133' @ 21 FPH SLIDING F/10907' T/10933' = 26' @ 12.48 FPH ROTATING F/10933' T/11084' = 151' @ 21 FPH INCREASED FLOW RATE F/750 T/830 GPM 15:30 - 16:00 0.50 RM rn 3011DR ClRC W/MUD PUMP #1 &.RECIPROCATE & ROTATE DRILL STRING. RIG REPAIR, RELPACED GASKET ON VALVE CAP OF DISCHARGE FLUID END OF MUD PUMP #2, TIGHTED RELIEF V^LVE Printed: 11/04/98 6:42:37 AM PHILLIPS PETROLEUM CO Page 8 of 61 Operations Summa Report Legal Well Name: ' NORTH COOK INLET UNIT-B 000003 Common Well Name: North Cook Inlet Unit B-3 Spud Date: 05/03/98 Event Name: Original Drilling Start: 02/09/98 End: Contractor Name: Rig Release: Group: Rig Name: Rig Number: Date From- To Hours Sub Co Phasel Code Description of Operations 05/26/98 ' 15:30 - 16:00 0.50 RM m 3011 DR TO ELIMINATE SMALL LEAK. '16:00 - 20:30 4.50 DR q 3011 DR DIRECTIONAL DRILLING ROTATING F/11084' T/11183' = 99' @ 22 FPH 20:30 - 21:00 0.50 RM m 3011DR RIG REPAIR, REPLACE SWAB IN MUD PUMP #1 21:00 - 00:00 3.00 DR q 3011 DR DIRECTIONAL DRILLING ROTATING F/11183' T/11242' = 59' @ 19.66 FPH DRILLING W/REDUCED FLOW RATE OF 780 GPM. TORQUE= 790 - 900 AMPS 05/27/98 00:00 - 03:00 3.00 DR q 3011DR DIRECTIONAL DRILLING (ROTATING) F/11242' T/11314' = 72' @ 24 FPH 03:00 - 06:30 3.50 DR 5 3011DR PUMP 35 BBL LOW VIS / HIGH VIS HOLE SWEEP, CIRC & COND HOLE. 06:30- 11:00 4.50 DR ~4 3011DR BACK REAM OUT OF HOLE F/11314' T/10408' 11:00 - 12:00 1.00 RM 'm 3011 DR WHILE BACK REAMING OUT OF HOLE @ 10408' TWO OF THE BRAKE PADS ON THE DRILLER SIDE OF THE DRAW WORKS CAME OFF OF THE BRAKE BAND. THE BLOCKS & TOP DRIVE WERE HUNG OFF IN THE DERRICK, THE BRAKE GUARD WAS REMOVED FROM THE DRAW WORKS, THE BRAKE BLOCKS WERE RE-INSTALLED & THE BOLTS WERE TIGHTENED ON THE REMAINDER OF THE BRAKE BLOC'KS. THE BRAKES WERE ADJUSTED AND THE GUARDS WERE REPLACED. 12:00 - 21:00 9.00 DR p 3011 DR CONTINUE TO BACK REAM OUT OF THE HOLE F/10408' T/8335'. 21:00 - 00:00 3.00 RM z 3011DR ROTATE & RECIPROCATE DRILL STRING @ 8335' WHILE CIRCULATING AT REDUCED RATE OF 180 TO 224 GpM, WHILE WAIT ON APOLLO SERVICES TO REPAIR AUGER SYSTEM F/SHALE SHAKERS T/INJECTION PITS. (POOL ARTIC ALASKA RIG WELDER FABRICATED ONE BUSHING TO HOLD CUTTING AUGER TO INNER SHAFT. PRER TO WELD CUTTING AUGER TO INNER SHAFT PULLEY 05/28/98 00:00 - 03:00 3.00 we 7 13011 DR Continue to rotate & reciprocate drill string @ 8335' (circulating at a reduced rate of 180 to 224 GPM), while welding Apollo's cutter auger to ~nner shaft pulley. 03:00 - 11:00 8.00 DR 4 ,3011DR Continue to back ream out of the hole F/8335' T/4400'. (NOTE: Apollo's auger functioning, have ordered required replacement pads for proper repair.) ' 11:00 - 12:30 1.50 DR 5 3011 DR CBU @ Csg. shoe 2 circulations. 12:30 - 16:30 4.00 DR 5 3011 DR Back ream into csg apx. 25' - packed off & torqued pipe. Lost returns, worked pipe down & freed same. Established circulation after 25 bbls loss. Working pipe & circulating while mixing lo-vis pill( 42 vis) followed w/hi-vis pill( 100 vis). Lo-vis pill recovered a good amount of fine cuttings & there were very few cuttings in the hi-vis pill. 16:30 - 20:00 3.50 DR p 3011 DR Back ream F/4400' T/2246'. 20:00 - 20:30 0.50 DR 5 3011DR Circulate hole clean. 20:30 - 21:00 0.50 DR p 3011DR Back ream F/2246' T/1964'. 121:00 - 22:00 1.00 DR 5 3011 DR Circulate hole clean. Clean rig floor. Pump dry job 22:00 - 00:00 2.00 DR p 3011 DR Pooh f/1964' t/1115' (top of BHA), laydown Daily jars, prep to laydown Anadrill MWD & Anadril Mud Motor. '05/29/98 100:00 - 01:30 1.50 DR 2 3011DR Finish pooh w/bit #3 run#3 '01:30 - 02:30 1.00 DR z 3011 DR Clean OBM from dg floor 02:30 - 06:00 3.50 DR 8 3011 DR Pulled wear bushing, install test plug, Weekly BOPE Test. pressure test Printed: 11/04/98 6:42:37 AM PHILLIPS pETROLEUM CO Page 9 of 61 Operations Summa Report Legal Well Name: NORTH COOK INLET UNIT-B 000003 Common Well Name: North Cook Inlet Unit B-3 Spud Date: 05/03/98 Event Name: Original Drilling Start: 02/09/98 End: Contractor Name: Rig Release: Group: Rig Name: Rig Number: Date From - To Hours Sub Co Phase Code Description of Operations 05/29/98 02:30 - 06:00 3.50 DR 8 3011 DR Hyddl to 250 psi iow & 2500 psi high pressure test. =ressure test drill pipe & blind rams, choke manifold, choke & kill lines, HCR valves, Top Drive, Upper & lower Kelly valves to 250 psi Iow & 5000 psi high pressure test. Notified Blair Wondzell w/Alaska Oil & Gas Commission of intent to ~ressure test BOPE @ 1:00 pm 05-26-98'. removed test plug & installed Wear Bushing. 06:00 - 09:30 3.50 DR 2 3011 DR L/D - CDR,MWD,Stabilizer,LC,Motor -Chg out stabilizer blades on motors. 09:30 - 12:00 2.50 DR 2 3011 DR M/U Bit & blade on motor, LC, stabilizer, & CDR - program data into CDR. '12:00 - 15:00 3.00 DR 2 3011 DR Odent tools. TIH w/HWDP to 1200'. Test MWD & CDR, OK. 15:00 - 17:30 2.50 DR 7 3011 DR Rig repair - service draw work brakes. Inspect brake pads & retaining bolts. Service top drive. 17:30 - 00:00 6.50 DR 4 3011 DR RIH (F/1200' T/11100'), filling DP every 20 Stds and establishing circ. for 5 rain.. - Preformed MWD check shot @ 4700' MD (OK). 05/30/98 00:00 - 01:00 1.00 DR p 3011 DR Ream F/11,088' T/11,314'.. 01:00 - 05:30 4.50 DR q 3011 DR Drill rotating F/11,314' T/11,334' (20 ft). (Low ReP +/- 4 FPH w/high fluxing torque, believe bit and BHA balled-up). Mixed & Pumped 40 bbls Low visc. (38)/Low Wt. (9.6#) sweep Continue drill rotating F/11,334' T/11,394' (60 ft). (Sweep appeared to cleaned bit & BHA / ReP increased to 30 FPH, torque stabilized @ 850 amps). 05:30 - 08:00 2.50 RM m 3011DR No. 2 mud pump suction gasket (valve) leaked. Replaced gasket / clean up & welded up wash spot. 08:00 - 12:00 4.00 DR q 3011DR Drill rotating F/11,394' T/11,463' (69 ft). Drill sliding F/11,463' T/11,470' (7 ft). 12:00 - 13:00 1.00 DR p 3011 DR Back reamed & washed hole F/11,385' T/11,470' (Torque fluxing high F/950 amps T/1100 amps). Pumped 40 bbls Iow visc. sweep (38 risc. / 9.6#) while working pipe. Saw good returns and torque dropped. 13:00 - 20:00 7.00 DR q 3011 DR Drill rotating F/11,470' T/11,495' (25ft). Mixed and pumped Iow visc. sweep (38 visc./9.6#) while working pipe. Saw good returns. Drill sliding F/11,495' T/11,505' (10 ft). Drill Rotating F/11,505' T/11,581' (76 ft). Drilled into "Stray Sand" Top @ 11,550' MD/8,770' TVD. ReP 22 FPH Before, ReP during 123 FPH. 20:00 - 23:00 3.00 DR 5 3011DR Mixed and pumped Iow risc. sweep (38 visc./9.6#) while working pipe (tight hole 11,540'-11,582'). CBU, workng pipe thru sand section (pump 2 down for 20 min. / gasket leak / continued circulating with I pump during 20 min.) no problems. Max. gas 281 units at 11,550'. Saw good returns on sweep. 23:00 - 00:00 1.00 DR q 3011DR Drill rotating F/11,581' T/11,607' (26 ft). 05/31/98 i00:00 - 06:00 6.00 DR q 3011DR Drill rotating F/11,607' T/11,743' (152 ft). Printed: 11/04/98 6:42:37 AM ,, PHILLIPS PETROLEUM CO Page 10 of 61 Operations Summary Report Legal Well Name: NORTH COOK INLET UNIT-B 000003 Common Well Name: North Cook Inlet Unit B-3 Spud Date: 05/03/98 Event Name: Original Drilling Start: 02/09/98 End: Contractor Name: Rig Release: Group: Rig Name: Rig Number: Date From- To Hours Sub Co Phase Code Description of Operations 05/31/98 06:00 - 06:30 0.50 RM m 3011DR Swab out on pump No. 1. Repair/replace same. 06:30 - 07:00 0.50 DR q 3011 DR Drill rotating F/11,743' T/11,754' (12 ft) 07:00 - 07:30 0.50 RM m 3011DR Washed out gasket on No. I pump valve cap. Repair/replace same. 07:30 - 09:30 2.00 DR q 3011 DR Drill rotating F/11,754' T/11,822' (51 ft). -- Pumped 40 bbls Iow visc. sweep - 40 risc. / 9.6# @ 11,800' (50% increase in returns over shakers). Conn. Gas @ 11,799'MD = 35Units over Bkgrd 09:30 - 10:00 0.50 DR z 3011 DR Orient directional tool face. 10:00 - 10:30 0.50 DR q 3011DR Drill sliding F/11,822' T/11,828' (6 ft). 10:30 - 11:00 0.50 =IM m 3011. DR Washed out gasket on No. I pump valve cap. Repair/replace same. 11:00- 11:30 0.50 DR q . 3011DR Drill sliding F/11,828'T/11,835' (7ft). 11:30- 22:00 10.50 DR q 3011DR Drill rotating F/11,835' T/12,125' (290 ft). -- Pumped 40 bbls high visc. sweep - 105 visc. / 13.0# @ 11,925' (25% increase in returns over shakers w/large coal cuttings). -- Pumped 40 bbls Iow visc. sweep - 42 visc. / 10.2# @ 12,006' (25% increase in returns over shakers). Max Gas = 369 Units @ 11,870' MD Avg Bkgrd Gas = 250 Units Conn. Gas @ 11,894'MD = 43Units over Bkgrd Conn. Gas @ 11,987'MD = 61Units over Bkgrd Conn. Gas @ 12,079'MD = 25Units over Bkgrd (NOTE: Estimate "Stray Sand" base @ 12,030'MD (9,107'TVD) / Sand in sample dropped to 20%) 22:00 - 22:30 0.50 RM m 3011DR Washed out gasket on No. 1 pump valve cap. Repair/replace same. 22:30 - 23:30 1.00 DR q 3011'DR Drill rotating F/12,125' T/12,145' (20 ft). 23:30 - 00:00 0.50 DR q 3011DR Drill sliding F/12,145' T/12,149' (4 ft). 06/01/98 00:00 - 01:00 1.00 DR q ~3011DR. Drill sliding F/12,149' T/12,159' (10 ft). NOTE: Shut down 15 min. during slide due to gasket failure pump No.1. Repair/replace same. 01:00 - 08:00 7.00 DR q 3011 DR Drill rotating F/12,159' T/12,282' (123 ft). Conn. Gas @ 12,172'MD = 79Units over Bkgrd Conn. Gas @ 12,267'MD = 66units over Bkgrd NOTE: Apollo inj. triplex pump seized-up (no downtime / able to transver slurry volumes to platform tanks). Using Hallibudon to injected. Have Sweco DSR pump mech. and Halliburton charge pump in route. 08:00 - 11:00 3.00 DR q 3011DR Drill Sliding F/12,282' T/12,302' (20 ft). 11:00 - 00:00 13.00 DR q 3011 DR Drill rotating F/12,302' T/12,495' (193 ft). -- Pumped 40 bbls Iow visc. sweep - 42 visc. / 10.2# @ 12,370' (25% increase in returns over shakers). -- Started to weight up mud system to 11.3 heavy @ 12,390'MD. Conn. Gas @ 12,361'MD = 48Units over Bkgrd Max Gas = 446 Units @ 12,452'MD Avg Bkgrd Gas = 280 Units Conn. Gas @ 12,452'MD = 96Units over Bkgrd .... Printed: 11/04/98 6:42:37 AM PHILLIPS PETROLEUM CO Page 11 of 61 Operations Summary Report Legal Well Name: NORTH COOK INLET UNIT-B 000003 Common Well Name: North Cook Inlet Unit B-3 Spud Date: 05/03/98 Event Name: Original Drilling Start: 02/09/98 End: Contractor Name: Rig Release: Group: Rig Name: Rig Number: Date From - To Hours Sub Co Phase Code Description of Operations 06/02/98 100:00 - 06:00 6.00 DR q 3011 DR Drill rotating F/12,495' T/12,595' (100 ft). Washed out gasket on pump No. 2 valve cap. Repair/replace same. 06:00 - 06:30 0.50 RM m 3011 DR I Washed out suction line valve on pump No. 1. '06:30 - 08:00 1.50 DR q 3011 DR Drill rotating F/12,595' T/12,620' (25 ft). 08:00 - 10:30 2.50 DR q 3011 DR Drill sliding F/12,620' T/12,630' (10 ft). ' 10:30 - 12:00 1.50 DR q 3011 DR Drill rotating F/12,630' T/12,635' (5 ft). 12:00 - 12:30 0.50 RM m 3011 DR Washed out gasket on pump No. 2 on valve cap. 12:30 - 14:30 2.00 DR q 3011DR !Drill rotating F/12,635' T/12,669' (34 ft). 14:30 - 16:00 1.50 DR q 3011DR i Drill sliding F/12,669' T/12,674' (5 ft). 16:00 - 16:30 0.50 RM m 3011 DR I Washed out gasket on pump No. 2 on valve cap. Repair / replace same. 16:30 - 17:30 1.00 DR q 3011 DR Drill sliding F/12,674' T/12,678' (4 ft). 17:30 - 22:30 5.00 DR q 3011DR Drill rotating F/12,678' T/12,745' (67 ft). 22:30 - 23:00 0.50 RM m 3011DR Washed out swab on pump No. 1. Repair / replace same. 23:00 - 00:00 1.00 DR q 3011 DR !Drill rotating F/12,745' T/12,756' (11 ft). 06/03/98 00:00 - 01:00 1.00 DR q 3011 DR : Drill rotating F/12,756' T/12,791' (35 ft). 01:00 - 03:30 2.50 DR q 3011 DR Drill sliding F/12,791' T/12,808' (17 ft). 03:30 - 14:00 10.50 DR q 3011DR .Drill rotating F/12,808' T/12,922' (114 ft). Pumped 40 bbls Iow visc. sweep - 38 visc. / 10.0# @ 12,828' (100% ~ncrease in returns over. shakers). -- Pumped 40 bbls Iow visc. sweep - 39 visc./ 10.0# @ 12,918' (50% ~ncrease in returns over shakers). 14:00 - 14:30 0.50 RM m 3011 DR Washed out gasket on pump No. 2 valve cap. 14:30 - 00:00 9.50 DR q 3011DR Drill rotating F/12,922' T/13,051' (129 ft). -- Pumped 40 bbls Iow visc. sweep - 40 visc. / 10.0# @ 12,945' (50% ~ncrease in returns over shakers). -- Pumped 40 bbls Iow visc. sweep - 40 visc. / 10.0# @ 13,012' (50% ~ncrease in returns over shakers). 06/04/98 00:00 - 02:30 2.50 DR q 3011 DR Drill sliding F/13,051' T/13,069' (18 ft). 02:30 - 09:30 7.00 DR q 3011DR Drill rotating F/13,069' T/13,125' (56 ft). -- Pumped 40 bbls Iow visc. sweep - 40 visc. / 10.0# @ 13,07!' (75% ~ncrease in returns over shakers). 09:30 - 10:30 1.00 RM m 3011 DR Washed out liner gasket and valve cap gasket on pump No. 2. 10:30 - 20:30 10.00 DR q 3011DR Drill rotating F/13,125' T/13,244' (119 ft). -- Pumped 40 bbls Iow visc. sweep - 40 visc. / 10.0# @ 13,131' (50% ~ncrease in returns over shakers). Weighted up O.B.M. F/11.4ppg T/11.7ppg. 20:30 - 21:30 1.00 RM m 3011 DR Washed out swab - No. 1 cylinder on No. 2 pump. Clean out rod oiler box. 21:30 - 00:00 2.50 3011DR Drilled rotating F/13,244' T/13,262' (18 ft). 06/05/98 00:00 - 06:30 6.50 DR q 3011DR Drill rotating F/13,262' T/13,315' (53 ft). 12 1/4" hole TD. 06:30 - 09:30 3.00 DR 5 3011 DR Cimulate and condition hole pumping a 40 bbls Iow visc. sweep - 38 visc. / 10.1# @ 13,315' (25% increase in returns over shakers w/some large coal). 09:30 - 15:30 6.00 DR 4 3011DR TOOH -- Back reaming F/13,315' T/12,644' (671 ft)..Recovering large Printed: 11/04/98 6:42:37 AM PHILLIPS PETROLEUM CO Page 12 of 61 Operations Summa Report Legal Well Name: NORTH COOK INLET UNIT-B 000003 ~Common Well Name: North Cook Inlet Unit B-3 Spud Date: 05/03/98 Event Name: Original Drilling Start: 02/09/98 End: Contractor Name: Rig Release: Group: Rig Name: Rig Number: Date From - To Hours Sub Co Phase Code Description of Operations 06/05/98 09:30 - 15:30 6.00 DR :4 3011DR pieces of coal, size ranging from silver dollar to tennis ball. Std #124 tight 12735'- 12644'. Pull std #123, dp stuck @12621' did not pack off. Work pipe free down. ***(1)Note: Hole seems to be taking fluid app 5-7 bbls/hr. Fluid losses determined to being lost over shakers. Swapped out "A" shakers 200 mesh w/180 mesh. ***(2)Note: Turbine limited to an output of only 4000 Hp. Limits power supply to draw-works, top drive, & pumps while back reaming out of the h01e. Pumps limited to +/- 450 GPM. 15:30-18:00 2.50 DR 4 3011DR Mix & pump 40 bbls low visc. sweep-39visc./10.2# @ 12,581'(0.0% ~ncrease in returns over shakers).Work pipe 12,644' - 12,549' while cimulating around sweep. 18:00 - 00:00 6.00 DR 4 ~3011 DR Continue TOOH -- Back reamed F/12,644' T/12,365' (279 ft). 06/06/98 00:00 - 06:30 6.50 DR 4 '3011 DR Continue TOOH -- Back reaming F/12,365' T/11,899' (466 ft). 06:30 - 08:30 2.00 DR 5 3011 DR Cimulate and condition hole pumping a 40 bbls Iow visc. sweep - 40 visc. / 10.2# @ 11,829' (200% increase in returns over shakers w/some large coal). ***NOTE: Pumped sweep at 750 GPM / 210 SPM / 3800#. Maximized turbine Hp on 'pumps by inching DP down slowly dudng pump time. 08:30 - 00:00 15.50 ~)R 4 3011 DR TOOH -- Back reaming F/11,899' T/9,746' (2153 ft). Std #114 tight 11725' - 11700'. Std #113 tight 11672' - 11660'. Std #112 tight at 11603'. Std #106 tight at 11043'. Pull std #99, dp stuck @10325' did not pack off. Work pipe free down. Numerous other tight spots up to 10200'. DP started to pull smoother at +/- 10200' (Time to ream a Std and make a connection 20-30min). 06/07/98 00:00 - 12:30 12.50 DR 4 3011 DR Continue to TOOH -- Back reamed F/9746' T/4569' (5177 ft)o 12:30 - 14:30 2.00 DR 5 3011DR While reciprocating pipe, circulate and condition hole @ 4569' (173' F/Shoe) pumping a 40 bbls Iow visc. sweep -. 41 visc. / 10.2#, followed by a 40 bbls high visc. sweep - 85 visc. / 11.7# (75% increase in returns over shakers w/small pieces of coal). 14:30 - 15:00 0.50 DR 7 3011 DR Pulled 2 Stds, rotating and reciprocating (Bit 11' above shoe). Picked up one single (Bit 20' below shoe).' 15:00 - 17:00 2.00 RM c ~3011DR At shoe (4396!), cut 186' drill line. Serviced top drive and moving parts. Clean top drive / rig floor. 17:00 - 22:30 5.50 DR 4 . 3011DR TOOH -- Back reamed F/4569' T/HWDP @ 1114'. 22:30 - 00:00 1.50 DR z 3011 DR Pumped dry job pill. TOOH w/HWDP. 06/08/98 00:00 - 02:30 2.50 DR 2 3011DR Lay down BHA No. 8. NOTE: Mud motor stabilizer tom up. Two vertical tears 3" away from each other. Both were 4" to 5" from splitting the stabilizer in two. No missing ~ pieces. 02:30 - 03:30 1.00 RM 3 3011DR Clean rig floor. Pull strip-o-matic. 03:30 - 08:00 4.50 LG 1 301'1DR Rig up for wireline equipment. RIH w/GR / LDT-CNL. Unable to drop logs thru tight section at 8820'. Logs stuck at 8820'. Worked logs free w/1200# overpull. Logged openhole section from 8820' to 4400' (13 3/8" csg Shoe). POOH w/logs. 08:00 - 08:30 0.50: LG 6 3011 DR Rig down wireline equipment. 08:30 - 13:00 4.50~ DR 8 3011DR Test choke. Pull wear bushing. Pick-up test plug. Flushed and drained Printed: 11/04/98 6:42:37 AM PHILLIPS PETROLEUM CO Page 13 of 61 Operations Summa Report Legal Well Name: NORTH COOK INLET UNIT-B 000003 Common Well Name: North Cook Inlet Unit B-3 Spud Date: 05/03/98 Event Name: Original Drilling Start: 02/09/98 End: Contractor Name: Rig Release: Group: Rig Name: Rig Number: Date From - To Hours Sub Co Phase Code Description of Operations 06/08/98 08:30- 13:00 4.50 DR 8 3011DR BOPE. Tested hydril Low @ 250psi / High @ 3500psi --OK--. Well started to show flow (weeping that continued after draining the BOPE volume). Recovered 20 gal/1 Hr. Suspended BOPE testing. Pulled test plug and set wear bushing. 13:00-14:00 1.00 DR 2 3011DR PAJBHANo. 9. M/U Bit (121/4" PDC Run #4), NB Stab., NMDC, 121/8" NM Stab., 3 NMDC, 25 HWDP, Jars, 5 HWDP. 14:00 - 17:30 3.50 DR 4 3011 DR TIH w/BHA & HWDP to 3500'. Break circulation. TIH w/DP to shoe (4400'). CBU (11.7 in & out). 17:30 - 18:30 1.00 DR 4 3011 DR TIH T/7,468'. Fill drill pipe. TIH T/7,576' (tight). 18:30 - 19:30 1.00 DR 4 3011 DR TIH, washing and reaming F/7576' T/7649'. 19:30-21:30 2.00 DR 4 3011DR Continue TIH fr/7649' to 10551' (tight). 21:30 - 00:00 2.50 DR 4 3011 DR TIH, washing and reaming fr/10551' to 10661'. 06/09/98 00:00 - 18:00 18.00 DR 4 3011DR TIH -- Washed and reamed F/10,661' T/13315'. Numerous tight spots. Generally slower below 12667'. Note: Had 10' fill on.bottom. Gas peaks -- 615U @ 11550'MD -- Approx. top of Stray Sand. Note: water phase of ONV ratio incr'd to 72/28 fr/75/25 with gas peak from Stray Sand. --495U @ 11682'MD -- 795U @ 11776'MD -- Sand -- 360U @ 12380'MD -- Coal -- 175U @ 13315'MD --TD 18:00 - 00:00 6.00 DR 5 3011 DR Circulate, rotate, and condition mud. Slurry plugged suction of Rental pump, plugged suction of CMT pump & plugged 4" suction hose. Mix polymer to Visc up slurry, transfer 100 bbl slurry fr/Apollo to PLTFM pit. i Mix 80 BBL additional 11.7PPG mud for TOOH. :Change out 75 HP motor on Apollo centrifugal :pump. Clean deck around rental injection pump. 06/10/98 00:00 - 13:00 13.00 DR 7 3011 DR Continue to C&C Mud while rotating & recip DP. Mix another 80 BBL 11.7# mud f/TOOH. Finish changing out Apollo pump motor. Clean out suction hoses on Injection pumps. Repair MP #1 - blown swab # 3 cyl. Clean deck around rental Injection pump again. Transfer & vis up fluid in Apollo system Apollo injected approx 150 BBLS slurry @ 1/4 to 1/2 BPM & 1500 - 1600 PSI. Rental Injection pump is still surging, suction valves not sealing well with heavy concentration of solids. Rate limited to 1/4 to 1/2 BPM. 13:00 - 21:00 8.00 DR 4 3011 DR Backreamed OOH fr/13315'- 12342' (600+ GPM & +/-100 RPM). Lost pump #2 cracked fluid end module #2 mud pump. Continued TOOH backreaming w/1 pump until torque prevented further progress. Repair #2 pump. Tight spot @ 12660' 21:00 - 22:00 1.00 RM m ~3011 DR CIRC & work pipe while finishing repairs on #2 mud pump. 22:00 - 00:00 2.00 DR 4 3011DR Resumed Backreaming OOH fr/12342'- 12061' (600 gpm & +/- 100 RPM). Tight fr/12370 - 12300'. 06/11/98 00:00 - 04:00 4.00 CS 4 3011RC 'Backream OOH fr/12061 '11525' (630 GPM, 100 - 120 TD RPM). Apollo's rental cuttings injection pump would not keep up with cuttings in returns Printed: 11/04/98 6:42:37 AM PHILLIPS PETROLEUM CO Page 14 of 61 Operations Summa Report Legal Well Name: · NORTH COOK INLET UNIT-B 000003 Common Well Name: North Cook Inlet Unit B-3 Spud Date: 05/03/98 Event Name: Original Drilling Start: 02/09/98 End: Contractor Name: Rig Release: Group: Rig Name: Rig Number: Date From - To Hours Sub Co Phase Code Description of Operations 06/11/98 00:00 - 04:00 4.00 CS 4 3011 RC while backreaming. 04:00 - 05:00 1.00 CS 4 3011RC TOOH fr/11525 - 10499'. Pipe pulled tight in numerous places, otherwise pulling pretty free. Well taking proper amount of fill, not swabbing. 05:00 - 07:00 2.00 CS 5 3011RC Circulate & work pipe while mixing dry job. 07:00 - 14:30 7.50 CS 4 3011RC Pumped Dry Job & POOH fr/10499' - 4263'. Pipe pulling free, hole was suprisingly free of tight spots...taking proper fill too. 14:30 - 15:00 0.50 RM m 3011RC Changed out Master bushing in rotary table. 15:00 - 16:00 1.00 CS 4 3011R0 Finish POOH to BHA. 16:00 - 16:30 0.50 'CS 0 3011 RC Held Prejob safety meeting...discussed changing out triplex injection pump & LD 6 5/8" HWDP. 16:30 - 23:00 6.50 CS 4 3011RC LD BHA. Changed out Apollo's triplex injection pump. Serviced Top Drive. 23:00 - 00:00 1.00 WC 2 3011RC MU wear bushing retieving tool on DP. Prepare to pull 5" pipe rams & install 9 5/8" rams. 06/12/98 00:00 - 02:00 2.00 WC 6 3011RC Pull wear bushing, MU test JTS & set test plug. Installed 9 5/8" CSG rams. 02:00 - 04:00 2.00 WC 8 3011RC Closed Hydril & tested breaks to 250/3500 PSI, then tested 9 5/8" rams to 250/3500 PSI. Pulled test plug & broke down test JTS. 04:00 - 05:30 1;50 CS 6 3011RC RU CSG tools & Lefluer fill up/circulating tool. 05:30 - 07:00 1.50 CS 1 3011RC MU float shoe, float collar & 3 JTS 9 5/8" 53.5# P-110 CSG.' Fill pipe & check operation of float equipment. 07:00 - 15:00 8.00 WO 7 3011RC WO Apollo to finish RU new triplex injection pump. Monitor well on trip tank. Clean rig floor. Apollo got their pump running & injected 60 BBL water then started injecting slurry. 15:00 - 16:00 1.00 CS 0 3011RC Held pre-job safety meeting. 16:00 - 19:30 3.50 CS 1 3011RC Ran 24 Jts 9 5/8" CSG to 1115', Sat down on obstruction, PU clean. Worked pipe several times unable to work thru obstruction. 19:30 - 00:00 4.50 CS 5 3011RC Established CIRC thru Lefluer tool. Hole trying to pack off. Reciprocate & CIRC @ 80 SPM, washed CSG down to 1133' (24th JT down). ClRC out cuttings until returns cleaned up. Mix & pump slug while preparing.to POOH LD CSG. 06/13/98 00:00 - 06:30 6.50 CS z 3011RC FINISHED POOH, LD 9 5/8" CSG. NOTE: HOLE WAS NOT SWABBING BUT UNABLE TO FILL FR/BACKSIDE, WE HAD TO FILL HOLE FR/ INSIDE CSG. 06:30 - 07:30 1.00 CS 6 3011RC RD CSG TOOLS. 07:30 - 09:30 2.00 CS 6 3011RC RU FLOOR TO TIH & RAN WEAR BUSHING. 09:30 - 12:30 3.00 CS 4 3011RC PU NEW BIT & BHA. 12:30 - 14:30 2.00 RM m 3011RC CHANGED OUT SWIVEL PACKING & SERVICED TOP DRIVE. 14:30 - 20:00 5.50 CS 4 3011RC TIH TO 2200'. NOTE: OBSERVED PIPE PUSHING SOMETHING DOWN FR/ABOUT 1100'. STOPPED & CIRC'D HOLE CLEAN @ 2200'. TIH TO 4400' (13 3/8" SHOE) & CIRC HOLE CLEAN AGAIN. 2'1:00 - 21:30 0.50 RM 3 3011RC RIG MAINTENANCE...ADJUST PIPE HANDLER CYLINDER ON TOP DRIVE. 21:30 - 00:00 2.50 CS 4 3011RC TIH. WASH & REAM THROUGH TIGHT SPOTS @ 10982', 10997', 11077' & 11707'. NOTE: OBSERVED LARGE CHUNKS OF COAL IN RETURNS FROM TIGHT SPOTS. 06/14/98 00:00 - 02:00 2.00 CS 4 3011RC FINISHED TIH. WASH & REAM THOUGH TIGHT SPOTS @ 11822', 13008' & 13061'. HAD 10' OF FILL ON BOTTOM. 02:00'- 12:00 10.00 CS 5 3011RC CIRC & COND MUD (ADDED 4 PPB SOLTEX TO MUD.) PUMPED LO-VIS/LO-WT SWEEP FOLLOWED BY HI-VIS/HI-WT SWEEP AROUND. HOLE UNLOADED LOTS OF COAL & SAND. 12:00 - 15:00 3.00 CS 4 3011RC PUMPED OOH W/5 STDS (TIGHT @ 12200') THEN POOH W/5 STDS TO 12377'. Printed: 11/04/98 6:42:37 AM PHILLIPS PETROLEUM CO Page 15 of 61 Operations Summa Report Legal Well Name: NORTH COOK INLET UNIT-B 000003 Common Well Name: North Cook Inlet Unit B-3 Spud Date: 05/03/98 Event Name: Original Drilling Start: 02/09/98 End: Contractor Name: Rig Release: Group: Rig Name: Rig Number: Date From - To Hours Sub Co Phase Code Description of Operations 06/14/98 15:00- 16:00 1.00 CS 15 3011RC PUMPED DRY JOB. PULLED 5 STDS DRY. DRAG INCREASED TO 375 / 400M. 16:00 - 22:00 6.00 CS 4 3011RC POOH TO 11868'. HOLE TIGHT. UNABLE TO WORK UP THROUGH TIGHT HOLE WITHOUT PUMP. PUMPED OOH FR/11868' TO 10235'. MAX. DRAG WITH & WITHOUT PUMP 300/400M. 22:00 - 00:00 2.00 CS 5 3011RC & CIRC. B/U AT 10235'. 06/15/98 00:00 - 01:30 1.50 CS 5 3011RC CIRC. HI/LO VIS SWEEP AROUND AT 10235'. NO LARGE COAL PIECES OVER SHAKER, HAD VERY LI'I-['LE FINE CUTTINGS. 01:30 - 05:00 3.50 CS 4 3011RC POOH WITHOUT ROTATING TO 4220', 180' INSIDE 13 3/8" CSG. 05:00 - 08:00 3.00 CS 5 3011RC FILL PIPE & EST. CIRC., MIXED & PUMPED LO/HI VIS SWEEPS AND CIRC. HOLE CLEAN. HAD SMALL AMOUNT OF FINE CUTTINGS. 08:00 - 09:00 1.00 RM c 3011RC SLIP & CUT 120' OF DRILL LINE. CHANGE OUT ROLLERS ON LINE GUIDE. 09:00 - 09:30 0.50 :{M 3 3011RC SERVICE TOP DRIVE. 09:30- 11:00 1.50 CS 4 3011RC ~FINISH POOH TO BHA. ~ 11:00 - 13:00 2.00 CS 4 3011RC PULL & L/D BHA, REMOVE STRIP-O-MATIC. 13:00 - 13:30 0.50 CS z 3011RC PULLWEAR BUSHING. 13:30 - 17:00 3.50 CS 6 3011RC RIG UP CSG TOOLS & CLEAR FLOOR TO RUN 9 5/8" CSG. 17:00 - 17:30 0.50 CS 0 3011RC HELD PRE JOB SAFETY MEETING. 17:30 - 00:00 6.50 CS 1 3011RC RAN WEATHERFORD MODEL 323 PDC DRILLABLE FLOAT SHOE, I FLT JT, AND A WEATHERFORD MODEL 402 PDC DRILLABLE FLOAT COLLAR. CONTINUE RUNNING 9 5/8" CSG, NOW WITH 62 JTS IN THE HOLE TO 2785'. INSTALL lNG BOW SPRING CENTRALIZERS AT ONE PER JT. OVER COUPLINGS. 06/16/98 00:00 - 13:30 13.50 CS I 3011RC CONTINUED RUNNING 9 5/8" 53.3# P110 BT&C CSG. RAN 265 JTS. STUCK CSG WHILE RUNNING IN HOLE @ 11761'. 13:30 - 22:00 8.50 CE 5 3011RC ESTABLISH CIRC THROUGH LEFLUER ClRC'G TOOL. TRIED 400 GPM, LOOSING FLUID REDUCED RATE TO 285 GPM/1100 PSI, ATTEMPTED TO WORK PIPE FREE. WORKED FR/630K - 100K. PIPE WAS STUCK. CLEANED CUTTINGS OUT OF PLATFORM PITS. MIX CMT MIX WATER &WT'D FLOZAN FLUSH. 22:00 - 23:00 1.00 CE 2 3011RC LD LEFLUER CIRC'G TOOL. PU HALCO CMT HEAD. TESTED LINES TO 3000 PSI. ESTABLISHED CIRC. 23:00 - 00:00 1.00 CE 5 3011RC CIRC WHILE RU OBM TRANSFER HOSES TO 400 BBL UPRIGHT TANKS ON DECK. 06/17/98 00:00 - 0'1:00 1.00 CE 1 3011RC CIRC. HOLD PRE-JOB SAFETY MTG. 01:00 - 01:30 0.50 CE 1 3011RC ~UMP 20BBL DIESEL, 20BBL FLOWZAN SPACER, 10BBL H20. 01:30 - 05:00. 3.50 CE 1 !3011RC MIX & PUMP 914BBL (2343 SX) LEAD CEMENT FOLLOWED BY 90BBL (424 SX) TAIL CEMENT. REL. EASE PLUG. PUMP 10BBL H20. 05:00 - 07:30 2.50 CE I 3011RC SWITCHED TO RIG PUMPS TO DISPLACE CEMENT WITH 826BBL I MUD. BUMPED PLUG, PRESSURE - 2350PSI. BLED OFF PRESSURE. iW/7800 STROKES PUMPED, 663 BBLS, STARTED LOSING MUD. LOST iA TOTAL OF 80 BBLS WHILE DISP. CEMENT. 07:30 - 10:00 2.50 CE 6 3011RC R/D CMT LINES & CMT HEAD. DRAIN STACK. CLEAN RIG. FLOOR. 10:00 - 12:00 2.00 CS e 3011RC REMOVE CSG SLIPS. R/D BELL NIPPLE 12:00 - 19:00 7.00 CS e 3011RC UNBOLT DSA. CLEAN, OIL MUD FROM CELLAR PRIOR TO GETTING HOT WORK PERMIT. 19:00 - 20:30 1.50i CS e 3011RC PICK UP STACK AND SET EMERGENCY SLIPS W/195,000 ON SLIPS. 20:30 - 00:00 3.50 CS n 3011RC START CUTTING 9.5/8" CSG. DRAIN WATER FROM CSG AND COMPLETE CUT. PULL & L/D EXCESS CSG. R/D WEATHERFORD POWER TONGS. REMOVE CIRC HEAD FROM 9.5/8". Printed: 11/04/98 6:42:37 AM PHILLIPS PETROLEUM CO Page 16 of 61 Operations Summar Report Legal Well Name: NORTH COOK INLET UNIT-B 000003 Common Well Name: North Cook Inlet Unit B-3 Spud Date: 05/03/98 Event Name: Original Drilling Start: 02/09/98 End: Contractor Name: Rig Release: Group: Rig Name: Rig Number: Date From - To Hours Sub Co Phase Code Description of Operations ., 06/18/98 00:00 - 07:00 7.00 CS e 3011RC DRESS 9.5/8" CSG SPOOL. N/D CHOKE & KILL LINES. DISCONNECT RISER FROM STACK AND SET DOWN BOPs. PULL RISER TO RIG FLOOR AND REMOVE SPACER. SPOOL & DSA. M/U CSG SPOOL & DSA TO RISER. INSTALL PACK-OFF AND M/U CSG SPOOL TO W/H. 07:00 - 09:00 2.00 CS 9 13011RC INJECT SEALANT AND TEST CSG SPOOL TO 5000PSI FOR 15 MINS. 09:00 - 12:00 3.00 WC e !3011RC N/U BOPs TO RISER. INSTALL CHOKE & KILL LINES. HOOK UP ACCUMULATOR HOSES. 12:00 - 20:30 8.50 WC e 3011RC CHANGE RAMS TO 5". DRAIN & CLEAN CUTTINGS FROM PITS 1, 2 & 5. REPLACE FLUID END ON LHS OF #2 MUD PUMP. INSTALL BELL NIPPLE. PICK UP ELEVATORS. 20:30 - 22:30 2.00 WC 2 13011RC MU TEST ASSY & RIH. FILL STACK. HOOK UP TEST LINES. 22:30 - 23:00 0.50 WC 1 . 3011RC TEST HYDRIL TO 250 & 2500PSI..TEST TOP PIPE RAMS, HCR, CHOKE/ KILL LINES TO 250 & 5000PSI. 23:00 - 00:00 1.00 WC 7 3011RC DSA LEAKING. TIGHTENED UP SAME. 06/19/98 00:00 - 04:30 4.50 WC 1 3011RC TEST BOPs - ALL RAMS, CHOKE MANIFOLD, CHOKE & KILL LINES, HCRs & MANUAL VALVES, IBOP, FLOOR VALVES TO 250/8000PS1. ACCUMULATOR TEST. PULL TEST ASSY. INSTALL WEAR BUSHING. 04:30 - 06:00 1.50 CS 6 3011RC INSTALL STRIP-O-MATIC. CLEAN RIG FLOOR. HOLD PRE-JOB SFTY MTG. 06:00 - 07:30 1.50 CS 9 3011RC TEST 9.5/8" CSG TO 5000PSI. HOLD FOR 30MINS - NO LEAK OFF. 07:30 - 12:00 4.50 CE h 3011RC P/U CLEAN-OUT BHA. 12:00 - 12:30 0.50 RM 3 3011RC SERVICE RIG & TOP DRIVE. REPLACE AIR LINE ON AIR SLIPS. 12:30 - 17:00 4.50 CE h 3011RC RIH. HIT CMT STRINGER @ 11,234FT 17:00 - 19:30 2.50 CE h 3011RC DRILL OUT CMT TO FLOAT COLLAR @ 11,709FT. 19:30 - 00:00 4.50 CE h 3011RC DRILL OUT FLOAT COLLAR. DRILL OUT CMT TO SHOE @ 11,761 FT (ROP @ SHOE 1FT/HR) 06/20/98 00:00 - 02:30 2.50 CE s 3011RC DRILL OUT 9.5/8" CSG SHOE & CMT FROM 11,761 FT TO 11,786FT. 02:30 - 06:30 4.00 CE s 3011RC CLEAN OUT/REAM FROM 11,786FT TO 12,210FT. 06:30 - 10:00 3.50 PA 5 3011RC PUMPED RICE PILL TO ESTIMATE HOLE VOLUME. UNSUCCESSFUL AS PILL RETURNED WITHIN CALCULATED STROKES FOR GAUGE HOLE. 10:00 - 11:00 1.00 PA z 3011 RC REAM FROM 12,210FT TO 12,.244FT. HOLE PACKED OFF. WORK PIPE FREE. 11:00 - 00:00 13.00 PA 5 3011RC CIRCULATE & INCREASE MUD WT FROM 11.6 TO 14.0PPG. 06/21/98 00:00 - 05:00 5.00 PA 5 60ABNT CONTINUE TO INCREASE MUD WEIGHT TO 14.0PPG. REAM TO 12,258FT. 05:00 - 07:30 2.50 PA z 60ABNT BACK REAM FROM 12,258FT TO SHOE @ 11,761FT. TIGHT SPOTS @ 12,043', 12,012' & 11,885'. PACKED OFF @ 11,795' BUT WORKED FREE. 07:30 - 12:00 4.50 PA 4 60ABNT PULL 5 STANDS - CHECK FOR SWABBING. PUMP SLUG & CONT POOH w/CLEAN OUT ASSY. 12:00 - 14:00 2.00 PA 2 60ABNT L/D CLEAN OUT ASSY. M/U BJ PARABOW TOOL. 14:00- 19:00 5.00 PA v 60ABNT RIH w/PARABOW. 19:00 - 21:00 2.00 PA v ,60ABNT SET PARABOW @ 12,210FT. DROPPED BALL. PRESSURE INCREASED TO 1600PSI THEN DROPPED TO 800PSI. 21:00 - 23:00 2.00 PA 5 :60ABNT ClRC &WASH FROM 12,200FT TO 11,761FT. 23:00 - 00:00 1.00 PA 5 60ABNT ClRC &WASH FROM 11,761FTTO 12,001FT. 06/22/98 00:00 - 00:30 0.50 PA 5 60ABNT ClRC & WASH FROM 12,2001FT TO 12,203FT. 00:30 - 02:00 1.50 PA 5 60ABNT ClRC BTMS UP. PRE-JOB SFTY MTG 02:00 - 03:30 1.50 PA 1 60ABNT PUMP 30BBL FLOWZAN SPACER, 150BBL CMT, 12BBL SPACER. DISPLACE w/180BBL OBM. 03:30 - 04:30 1.00 PA 1 60ABNT POOH 19 STDS TO 10,411FT (ALL STDS PULLED DRY). 04:30 - 06:00 1.50 PA 5 60ABNT R./U & REVERSE CIRCULATE @ 50SPM. PRESSURE INCREASED - Printed: 11/04/98 6:42:37 AM PHILLIPS PETROLEUM CO Page 17 of 61 Operations Summa Report Legal Well Name: NORTH COOK INLET UNIT-B 000003 Common Well Name: North Cook Inlet Unit B-3 Spud Date: 05/03/98 Event Name: Original Drilling Start: 02/09/98 End: Contractor Name: Rig Release: Group: Rig Name: Rig Number: Date From- To Hours Sub Co Phase Code Description of Operations 06/22/98 04:30 - 06:00 1.50 PA 5 160ABNT BALL FROM PARABOW TOOL WAS PUMPED TO SURFACE PLUGGING OFF CEMENT HEAD. BLEED OFF PRESSURE. 06:00 - 07:30 1.50 PA 5 60ABNT CIRC DOWN DP (NO CMT RETURNS AT SURFACE). PUMP SLUG. 07:30 - 13:00 5.50 PA 4 60ABNT POOH w/PARABOW RUNNING TOOL & L./D SAME. CLEAN RIG FLOOR 13:00 - 21:00 8.00 we j 60ABNT P/U 38 STDS 5" DP 21:00 - 00:00 3.00 RM 3 60ABNT SLIP & CUT DRL LINE (88FT). SERVICE TOP DRIVE. 06/23/98 00:00 - 04:30 4.50 we j 60ABNT WOC. CLEAN TRIP TANK, CHANGE SHAKER SCREENS. 04:30 - 06:30 2.00 DR 2 :50PRDR P/U SIDETRACK BHA & RIH w/HWDP. FUNCTION TEST MWD & MOTOR - OK. 06:30 - 10:30 4.00 DR 4 = 50PRDR RIH TO 11,657FT (104FT ABOVE SHOE). NO CEMENT 10:30 - 13:00 2.50 DR 5 50PRDR CIRC @ 11,657FT. UNCONSOLIDATED CEMENT IN RTNS. 13:00 - 16:00 3.00 DR d 50PRDR WASH & REAM FROM 11,657FT TO 11,923FT. 16:00 - 17:00 1.00 DR w ~50PRDR ORIENT & SLIDE. CHANGE SHAKER SCREENS. 17:00 - 19:30 2.50 DR w .50PRDR SLIDE/WORK LOW SIDE TRENCH 19:30 - 20:00 0.50 DR w 50PRDR TIME DRILL 1"/6 MINS FROM 11,923FT TO 11,923.6FT. 20:00 - 21:30 1.50 RM m 50PRDR CHANGE SWABS #1 MUD PUMP 21:30 - 00:00 2.50 DR w 50PRDR ORIENT TOOL FACE. TIME DRILL FROM 11,923.6FT TO 11,926FT 06/24/98 00:00 - 23:00 23.00 DR w .50PRDR TIME DRILL FROM 11,926FT TO 11,964FT. 11,926' - 11,934' @ 1FT/HR 1'1,934'- 11,944'@ 2FT/HR 11,944' - 11,954' @ 3FT/HR 11,954' - 11,964' @ 5FT/HR SLIDE 11,964' TO 11,983' 23:00 - 00:00 1.00 DR w 50PRDR ROTATE 11,983FT - 11,995 FT (CUTTINGS SAMPLE - 70% FORMATION, 30% CMT) 06/25/98 00:00 - 05:30 5.50 DR w ;50PRDR DRILL (ROTATE) FROM 11,995FT TO 12,033FT. 05:30 - 06:00 0.50 DR 4 : 50PRDR BACK REAM FROM 12,033FT TO SHOE. PULL 12 STDS TO 11,657FT. 06:00- 07:30 1.50 DR 5 50PRDR ClRC BTMS UP 07:30 - 12:00 4.50 DR 8 50PRDR R/U HALLIBURTON. P/TEST LINES - PRESSURE DROPPING AT APPROX. 0.5PSI/SEC. CHECK VALVES. RE-TEST LINES WITH WATER - TESTED OK. 12:00 - 14:00 2.00 DR y 50PRDR PERFORM LOT. SURFACE PRESSURE 890PSI - 15.8PPG EMW @ 9.5/8" SHOE. R/D HALLIBURTON. CLEAN RIG FLOOR. PUMP SLUG. 14:00 - 20:30 6.50 DR 4 50PRDR POOH w/SIDETRACK BHA. L/D MOTOR, MWD & BIT. CLEAN RIG FLOOR. 20:30 - 00:00 3.50 WC 8 50PRDR RETRIEVE WEAR BUSHING. RUN TEST PLUG. TEST RAMS, CHOKE MANIFOLD, HCRs, MANUALS, IBOP, FLOOR VALVES TO 250/5000PSI. TEST HYDRIL TO 250/2500PSI. TEST ACCUMULATOR. 06/26/98 00:00 - 00:30 0.50 WC 1 50PRDR CONT TEST BOPs. PULL TEST PLUG..INSTALL WEAR BUSHING. 00:30 - 02:00 1.50 DR 2 50PRDR P/U BHA. ORIENT & TEST MWD & MOTOR. 02:00- 06:00 4.00 DR 4 50PRDR RIH. TAG @ 11,769FT. 06:00- 08:00 2.00 DR d 50PRDR WASH FROM 11,761FTTO 12,033FT. 08:00- 00:00 16.00 DR q 50PRDR DRILL FROM 12,033FTTO 12,351FT:- ROTATE 12,033'- 12,116' (83FT) SLIDE 12,116'- 12,136' (20FT) ROTATE 12,136'- 12,351FT (215FT) 06/27/98 00:00 - 00:00 24.00 DR q 50PRDR DRILL FROM 12,351FT TO 12,844FT:- ROTATE 12,351'- 12,536' (185FT) SLIDE 12,536'- 12,566' (20FT) ROTATE 12,566'- 12,844' (278FT) 06/28/98 00:00- 07:30 7.50 DR q 50PRDR DRILL FROM 12,844FT- 12,966FT:- ROTATE 12,844'- 12,925' (81FT) SLIDE 12,925'- 12,950' (25FT) Printed: 11/04/98 6:42:37 AM PHILLIPS PETROLEUM CO Page 18 of 61 Operations Summa Report Legal Well Name: NORTH COOK INLET UNIT-B 000003 Common Well Name: North Cook Inlet Unit B-3 Spud Date: 05/03/98 Event Name: Original Drilling Start: 02/09/98 End: Contractor Name: Rig Release: Group: Rig Name: Rig Number: Date From - To Hours Sub Co Phase Code Description of Operations 06/28/98 00:00- 07:30 7.50 DR q 50PRDR ROTATE 12,950'- 12,959FT (9FT) 07:30 - 08:00 0.50 RM m 50PRDR REPLACE VALVE GASKET #1PUMP, VALVE SEAT #2 PUMP 08:00- 09:00 1.00 DR q 50PRDR ROTATE 12,959FT- 12,978FT (19FT) 09:00 - 10:00 1.00 RM m 50PRDR BOTH PUMPS SHUT DOWN TO REPLACE 4" GATE VALVE AND VALVE SEAT #2 PUMP 10:00 - 10:30 0.50 DR 5 50PRDR CIRC BTMS UP TO REMOVE CUTTINGS 10:30- 00:00 13.50 DR q 50PRDR DRILL FROM 12,978FTTO 13,124FT:- ROTATE 12,978FT- 13,009FT (31FT) SLIDE 13,009' - 13,039FT (20FT) ROTATE 13,039' - 13,165FT (126FT) SLIDE 13,165' - 13,185FT (20FT) ROTATE 13,185FT TO 13,214FT (29FT) 06/29/98 00:00- 16:30 16.50 DR q 50PRDR ROTATE FROM 13,214FTTO 13,575FT 16:30 - 17:00 0.50 DR p 50PRDR BACK REAM FOR CONNECTION FROM 13,575FT TO 13,568FT. TOOK 15K OVERPULL - ROTARY STOPPED. SLACK DOWN & WORK FREE. BACK REAM FROM 13,575FT TO 13,568FT. PIPE STUCK 8FT OFF BTM. UNABLE TO MOVE PIPE UP OR DOWN BUT STILL CIRCULATING. 17:00 - 19:30 2.50 DR 5 50PRDR PUMP LO-VIS/HI-VIS PILL & WORK PIPE FREE. 19:30- 21:30 2.00 DR 5 50PRDR ClRC BTMS UP 21:30 - 00:00 2.50 DR p 50PRDR BACKREAM FROM 13,575FTTO 12,826FT 06/30/98 00:00 - 03:30 3.50 DR p 50PRDR BACK REAM FROM 12,826FT TO 11,730FT. 03:30 - 07:30 4.00 RM 3 50PRDR CUT DRL LINE (54FT). SERVICE TOP DRIVE. ADJUST DRAWWORKS BRAKES. ADJUST SERVICE DRILL LINE TIE-DOWN. 07:30 - 11:00 3.50 DR 5 50PRDR MIX & PUMP 40BBL LO-VIS SWEEP AND 35BBL HI-VIS SWEEP. 11:00 - 13:30 2.50 DR d 50PRDR WASH/REAM FROM 11,730FT TO 13,575FT 13:30 - 19:30 6.00 DR Iq 50PRDR DRILL (ROTATE) FROM 13,575 T.O 13,707FT. 19:30 - 23:00 3.50 DR !p 50PRDR HOLE' PACKING OFF. PUMP PRESSURE INCREASED TO 3800PSI - BLEW POP-OFF ON #2 PUMP. REAMED ACROSS SECTION. PUMPED LO-VIS/HI-VIS SWEEP BUT NO SIGNIFICANT RETURNS. PUMP PRESSURE DROPPED BY 100PSI. UNABLE TO DRILL FURTHER. (SUSPECT MOTOR FAILURE) 23:00 - 00:00 1.00 DR p 50PRDR POOH FOR BHA CHANGE. BACKREAM FROM 13,707FT TO 13,667FT. 07/01/98 00:00 - 06:30 6.50 DR p 50PRDR FINISH BACKREAMING OUT OF 8.5" OPEN.HOLE F/13667' T/11761'. 06:30 - 07:30 1.00 DR 5 50PRDR MIX & PUMP SLUG. 07:30- 13:00 5.50: DR 4 50PRDR FINISH POOH. 13:00 - 14:00 1.00i WC 8 50PRDR RETREIVE WEAR BUSHING & INSTALL TEST PLUG. 14:00 - 17:00 3.00 WC 8 50PRDR TEST CLASS V BOPE, WEEKLY TEST, TEST TO 250 LOW/5000 HIGH PRESSURE TEST. NOTIFIED BLAIRE WONDZELL W/AO&GC OF INTENT TO TEST BOPE @ 09:00 AM ADT 6-30-98. 17:00 - 18:00 1.00 WC 8 50PRDR RETREIVE TEST PLUG & INSTALL WEAR BUSHING. 18:00 - 19:30 1.50 DR 4 50PRDR REPLACED MUD MOTOR & MWD. ~ 19:30 - 20:30 ' 1.00 RM m 50PRDR REPLACED STRIP-O-MATIC. '20:§0 - 22:30 2.00 DR 4 50PRDR TRIP IN HOLE TO 3908' 22:30 - 23:30 1.00 DR 9 50PRDR PUMPED CARBIDE PILL - TO CHECK LAG TIME. 500 STROKES OVER DISPLACEMENT. 23:30 - 00:00 0.50 DR 4 50PRDR TRIP IN HOLE TO 4477'. 07/02/98 00:00 - 02:00 2.00 DR 4 150PRDR Continue to TIH to'Shoe @ 11,761' MD. 02:00 - 02:30 0.50 RM 7 50PRDR Fill pipe. Service top drive and greased crown, 02:30 - 07:00 4.50 DR 4 50PRDR Orient tool face. Continue to TIH, washing from 11,761' MD to 13,627' MD. Wash / Ream from 13,627' MD to 13,707' MD. 07:00 - 08:30 1.50 DR q 50PRDR Directionally drill, rotating from 13,707' MD to 13,717' MD (10 ft). , Printed: 11/04/98 6:42:37 AM PHILLIPS PETROLEUM CO Page 19 of 61 Operations Summa Report Legal Well Name: NORTH COOK INLET UNIT-B 000003 Common Well Name: North Cook Inlet Unit B-3 Spud Date: 05/03/98 Event Name: Original Drilling Start: 02/09/98 End: Contractor Name: Rig Release: Group: Rig Name: Rig Number: Date From- To Hours Sub Co Phase Code Description of Operations ,,, 07/02/98 08:30 - 10:30 2.00 DR a 50PRDR i Bit became stuck on bottom at 13,717' MD (NOTE: No increase in ROP prior to sticking. Saw only an increase in pump pressure. Picked-up -- bit stuck). Worked stuck bit free with 85,000# over stdng weight and jardng action both up and down. 10:30- 13:00 2.50 DR 5 50PRDR Circulate and condition ddlling mud. 13:00 - 20:30 7.50 DR 4 50PRDR BHA motor unable to drill. TOOH, backreaming F/13,717' MD T/11,761' MD. NOTE: Worked through tight spot @ 13,100'. 20:30 - 22:30 2.00 DR 5 50PRDR Circulate at shoe (11,761' MD). Clean rig floor. Pumped dry job. 22:30 - 00:00 1.50 DR 4 50PRDR POOH F/11,761' T/9,819'. 07/03/98 00:00 - 05:00 5.00 DR 4 50PRDR TOOH F/9819' T/surf.. (NOTE: Pulled pipe wet starting at 6000') 05:00- 06:00 1.00 DR 2 50PRDR Laydown motor. Clean rig floor. (NOTE: Motor would not turn at surface. Bearing housing was extended from bit box an additional 1.0" - 1.25", indicating damaged / worn beadngs or shattered beadngs -- frozen beadng pack). 06:00 - 07:30 1.50 DR 2 50PRDR Picked-up new motor (4/5 adj. P.Pak XP @ 0.78 (6751034)) and orient MWD / test motor. 07:30 - 12:30 5.00 DR 4 50PRDR TIH to 11,761' MD, filling pipe @ 4688' & 8405'. 12:30 - 18:00 5.50 DR 4 §0PRDR TIH, reamed and washed F/11,761' MD T/13,717' MD. (NOTE: Tight Spot @ 12,950' MD, Mid Std # 127. Worked same free) 18:00 - 21:00 3.00 DR q 50PRDR Drill rotating F/13,717' MD T/13,750' MD (33 ft). ;21:00 - 00:00 3.00 DR q 50PRDR 'Drill sliding F/13,750' MD T/13,760' MD (10 ft). 07/04/98 ;00:00 - 12:00 12.00 DR q 50PRDR Drill rotating F/13,760' MD T/13,890' MD (130 ft). (NOTE: Pump No. I down 2 hours for liner and swab repair -- no down time, was able to use pump No. 2 at 119 SPM / 3250# to continue drilling ahead.) 12:00 - 16:00 4.00 DR q 50PRDR Drill sliding F/13,890' MD T/13,925' MD (35 ft). 16:00 - 22:00 6.00 DR !q 50PRDR Drill rotating F/13,925' MD T/13,990' MD (65 ft). 22:00 - 00:00 2.00 DR q 50PRDR Drill sliding F/13,990' MD T/13,996' MD (6 ft). 07/05/98 00:00 - 04:30 4.50 DR q 50PRDR Drill sliding F/13,996' MD T/14,010' MD (14 ft). 04:30 - 06:30 2.00 DR q 50PRDR Drill rotating F/14,010' MD T/14,025' MD (15 ft). 06:30 - 07:30 1.00 DR q 50PRDR Drill sliding F/14,025' MD T/14,033' MD (8 ft). 07:30 - 10:00 2.50 DR q 50PRDR Drill rotating F/14,033' MD T/14,055' MD (22 ft). 10:00 - 13:00 3.00 DR q 50PRDR Drill sliding F/14,055' MD T/14,077' MD (22 ft). 13:00 - 15:30 2.50 DR q 50PRDR Drill rotating F/14,077' MD T/14,105' MD (28 ft). 15:30-19:00 3.50 DR q 50PRDR Drill sliding F/14,105' MD T/14,118' MD (13 ft). 19:00-20:30 1.50 DR q 50PRDR Drill rotating F/14,118' MD T/14,130' MD (12 ft). 20:30 - 22:30 2.00 DR q 50PRDR Drill sliding F/14,130' MD T/14,141' MD (11 ft). 22:30 - 00:00 1.50 DR q 50PRDR Drill rotating F/14,141' MD T/14,145' MD (4 ft). 07/06/98 00:00 - 00:30 0.50 DR q 50PRDR Drill rotating F/14,145' MD T/14,155' MD (10 ft). 00:30 - 04:00 3.50 DR q 50PRDR Drill sliding F/14,155' MD T/14,170' MD (15 ft). 04:00 - 06:00 2.00 DR q 50PRDR Drill rotating F/14,170' MD T/14,181' MD (11 ft). 06:00 - 07:30. 1.50 DR 5 50PRDR Prepare to TOOH for BHA (current BHA dropping, angle w/poor ROP). Circ. bttms-up. Condition drilling fluid. Mix dry job. 07:30 - 00:00 16.50 DR 4 .50PRDR Back reamed out ofthe hole F/14,181' MD T/13,045' MD (1136 ft). NOTE: Encountered several severe tight spots as follows (W/Est. Printed: 11/04/98 6:42:37 AM PHILLIPS PETROLEUM CO Page 20 of 61 Operations Summa Report Legal Well Name: ' NORTH COOK INLET UNIT-B 000003 Common Well Name: North Cook Inlet Unit B-3 Spud Date: 05/03/98 Event Name: Original Drilling Start: 02/09/98 End: Contractor Name: Rig Release: Group: Rig Name: Rig Number: Date From- To Hours Sub Co Phase Code Description of Operations 07/06/98 07:30 - 00:00 16.50 DR 4 50PRDR Time/Std.): (2.5Hrs)Std # 131 -- 13,335'MD (1.5Hrs)Std # 130-- 13,266'MD (2.5Hrs)Std # 129 -- 13,171'MD & 13,139'MD (2.5Hrs)Std # 128 -- 13,076'MD & 13,050'MD 07/07/98 00:00 - 22:00 22.00 DR 4 50PRDR Back reamed F/13,045' MD T/12,909' MD (136 ft). NOTE: Stds. 128 & 127 extremely tight. Std 128 -- 13,045' to 13,013' Std 127 -- 13,013' to 12,919' 22:00 - 00:00 2.00 DR 4 50PRDR Bit locked-up at 12,909'MD stalling out mud motor and blowing pop-off on pump (instantaneous). Believe formation is sloughing - packing off BHA trapping 1500# press.(could not establish circulation), unable to move pipe up or down. Worked pipe 20 rains, regained circulation. Work pipe jarring down - pipe free F/12,909'MD T/12,926'MD. Continue to work pipe jarring down. 07/08/98 00:00 - 00:30 0.50 DR a 50PRDR Working pipe jarring down. Worked pipe free jarring F/12,909' MD T/ 12,930' MD. Able to move pipe up and down, rotating, and circulating at 12,930' MD. 00:30 - 02:00 1.50 DR 5 50PRDR Circulate bottoms up while rotating pipe at 12,930' MD. Bottoms up returns 50% increase over shakers w/large amount of fines (silt, sand, etc.) and coal fragments ranging in size F/golf ball T/tennis ball. Mixed and pumped Iow visc.(50) /weighted (15 ppg) sweep @ 12,930' MD. Saw 35% increase over shakers w/large amount of fines (silt, sand, etc.) and coal fragments ranging in size F/dime T/golf ball. 02:00 - 00:00 22.00 DR 4 50PRDR Continue back reaming out of the hole F/12,930' MD T/12757' MD (173 ft). NOTE: Stds. 127, 126 & 125 extremely tight. (5 Hrs)Std .127 -- 12,930' to 12,919' (11 ft) (9 Hrs)Std 126 -- 12,919' to 12,825' 94 ft) (10 Hrs)Std 125 -- 12,825' to 12,757' (68 ft) 07/09/98 00:00 - 00:00 24.00 DR ~4 50PRDR Continue back reaming out of the hole F/12,757' MD T/12666' MD (91 ft). (NOTE: Stab. appears to be hanging up in coal sect. @ 12,670' - 12,630' (Stab. 42' above bit)) I NOTE: Std. 125 & 124 extremely tight. (6 Hrs)Std 125 -- 12,75.7' to 12,731' (26 ft) (18 Hrs)Std 124-- 12,731' to 12,666' (65 ft) Printed: 11/04/98 6:42:37' AM PHILLIPS pETROLEUM CO Page 21 of 61 Operations Summary Report Legal Well Name: NORTH COOK INLET UNIT-B 000003 Common Well Name: North Cook Inlet Unit B-3 Spud Date: 05/03/98 Event Name: Original Drilling Start: 02/09/98 End: Contractor Name: Rig Release: Group: Rig Name: Rig Number: Date From - To Hours Sub Co Phase Code Description of Operations _ 07/09/98 00:00 - 00:00 24.00 DR 4 50PRDR Mixed & pumped sweeps as follows: (1 ) (06:00 @ 12,735') 40 bbls Iow visc. (50) hvy. wt. 15.4# - Brought back approx. 1 gal. cuttings (dime size - 1/2" thick) (2) (14:00@ 12,712') 30 bbls Iow visc. (40) hvy. wt. 17# - Brought back approx. 5-6 bbls of cuttings (1st half dollar size, 2nd buck-shot size, finally fine sand silt -- cuttings appear to be grouped together all the same size as they come over the sackers -- may have been grinded up several times and recycled again and again downhole) (3) (20:30@ 12,691 ') 20 bbls diesel followed by 40 bbls high visc. (120) hvy. wt. 17# - Same results as previous sweep ***NOTE: All sweeps immediately upon returns preceeded with increase in coarse cubed coal returns, then significant sand / silt returns in 17.0# sweep. 07/10/98 00:00 - DR 4 50PRDR Continue back reaming out of the hole F/12,666' MD T/12,540' MD (126 ft). NOTE: Std. 124 & 123 reaming extremely tight. (4 Hrs)Std 124 -- 12,666' to 12,636' (30 ft) (20 Hrs)Std 123 -- 12,636' to 12,540' (96 ft) Mixed & pumped sweeps as follows: (1 ) (06:30 @ 12,595') 20 bbis Iow visc. (40) 7.2#, followed by 40 bbls high visc. (120) 17# - Brought back approx. 5-6 bbls of cuttings (1st quarter / dime size, 2nd buck-shot size, finally fine sand silt -- cuttings appear to be getting smaller in size overall. (2) (Immediately following the first) 20 bbls Iow risc. (40) 7.2#, followed by 40 bbls high visc. (120) 17# - Brought back signifactely less than the previous sweep (approx. 1 gal. cuttings - mostly fines) (1) (21:00@ 12,550') 20 bbls Iow visc. (40) 7.2#, followed by 40 bbls high visc. (120) 17# - Brought back approx. 3-4 bbls of cuttings (1st quarter / dime size, 2nd buck-shot size, finally fine sand silt -- cuttings appear to be getting smaller in size overall as before. ***NOTE: Sweeps appear to be bringing up less and less cuttings. Printed: 11/04/98 6:42:37 AM PHILLIPS PETROLEUM CO Page 22 of 61 Operations Summar Report Legal Well Name: NORTH COOK INLET UNIT-B 000003 Common Well Name: North Cook Inlet Unit B-3 Spud Date: 05/03/98 Event Name: Original Drilling Start: 02/09/98 End: Contractor Name: Rig Release: Group: Rig Name: Rig Number: Date From - To Hours Sub Co Phase Code Description of Operations 07/11/98 00:00 - 00:00 24.00 DR 4 50PRDR Continue back reaming out of the hole F/12,540' MD T/12,072' MD (468 ft). NOTE: Std. 122 & 121 reaming extremely tight, but Stds 120 - 118 seem to be reaming a little faster and smoother. (6 Hrs)Std 122 -- 12,540' to 12,446' (94 ft) (5.5 Hrs)Std 121 -- 12,446' to 12,354' (92 ft) (4 Hrs)Std 120 -- 12,354' to 12,260' (94 ft) (4 Hrs)Std 119-- 12,260' to 12,165" (95 ft) (4.5 Hrs)Std 118-- 12,165' to 12,072' (93 ft) (3) (14:00@ 12,295') 15 bbls Iow visc. (40) 7.2#, followed by 30 bbls high visc. (200) 17# - Brought back approx. 3-4 bbls of cuttings (1st quarter / dime size, 2nd buck-shot size, finally fine sand silt -- sweep brought up a larger amount of coal than before. 07/12/98 00:00 - 02:30 2.50 DR 4 ,50PRDR Continue to back ream F/12,072' MD T/11,870' MD (202 ft) (@ 8 1/2" KOP 'did see some add'l, torq. & wt., but not signifacant. Reaming came easier once in 12 1/4" OH). (NOTE: @ 11,873.5' MD Torq. flux. drastically F/550 amps to 1000 amps -- would inch into it 4 times, stop at 600 amps and the torq. would flux. up to 1000 amps, then drop back, then increase over and over again (Rapidly) then stalling out the top drive - never appeared to drill off (no add'l wt or press.). 5th time DP came thru with no problems). 02:30 - 04:00 1.50 DR 5 50PRDR Mixed and pumped sweep while reciprocating pipe F/11,895' T/11,865'. 15 bbls Iow visc. (40) 7.2#, followed by 30 bbls high visc. (200) 17# - Brought back approx. 3-4 bbls of cuttings (1st quarter / dime size, 2nd buck-shot size, finally fine sand'silt -- sweep did not return an expected signifacate amount. 04:00 - 05:00 1.00 DR 4 50PRDR Continue to back ream F/11,870' MD - T/11,761' MD (109 ft). (NOTE: @ 11,825' MD saw same torq. flux. at 11,873.5' w/add'l 200#. Appeared to just disappear after 3 attempts.) 05:00 - 06:00 1.00 DR 7 150PRDR Lowered BHA 40 ft below shoe. Circulated BU while servicing top drive. 06:00-10:00 4.00 DR 4 50PRDR Ream to shoe at11,761' MD. POOH5stdw/oreaming-O.K.. Pumpdry ob. POOH - no problems. 10:00 - 12:30 2.50 DR 2 50PRDR L/D MWD & CDR - Test Motor (rotating fine). Drain & break bit off. L/D lead collar, motor. BHA appeared to be worn but nothing unusual. Motor bearings were worn but still able rotate. Top stab. had a 3" strip of banding worn off one of the blades. 12:30 - 15:00 2.50 DR 2 50PRDR pick-up tools & clean oil F/rig floor. Make-up test equipment to test BOP's Printed: 11/04/98 6:42:37 AM PHILLIPS PETROLEUM CO Page 23 of 61 Operations Summa Report Legal Well Name: NORTH COOK INLET UNIT-B 000003 Common Well Name: North Cook Inlet Unit B-3 Spud Date: 05/03/98 Event Name: Original Drilling Start: 02/09/98 End: Contractor Name: Rig Release: Group: Rig Name: Rig Number: Date From- To Hours Sub Co Phase Code Description of Operations 07/12/98 12:30- 15:00 2.50 DR !2 50PRDR &flrvalves. Fill stack w/ H20. (NOTE: AO&GCC Rep. Jack Hart, waived witnessing BOPE testing) 15:00 - 17:30 2.501 DR 8 50PRDR Pull wear bushing, set test plug. Test BOPE as follows: 1(1)Test Bag Low 250# / High 2500#. (2)Test (all Iow 250# / high 5000#) top pipe rams, choke / kill HCR, manual =valves, Bttm pipe rams, blind rams, choke fir valves, upper / lower IBOP 'valves. Do koomy test. Pull test plug, close bag, set wear bushing, and break down test tools. 17:30 - 19:00 1.50 DR 7 50PRDR Replace nut & bolts on 1 brake pad, inspect and adjust brakes. 19:00 - 21:30 2.50 DR 7 50PRDR Clean and scrub floor etc.. Change dies in pipe handler. 21:30 - 22:30 1.00 DR 6 50PRDR RU Schlumberger to run GR/CAL log. Test equipment. 22:30- 00:00 1.50 DR 0 50PRDR Held pta-job safety meeting. 07/13/98 00:00 - 02:30 2.50 LG z 50PRDR RIH w/GR/CAL logging tools. RIH testing tension 1000' F/shoe (tested CAL arms @ 8,000' MD- OK), 11,840' MD (Ten. = 4500#), and 11,910' MD (NOTE: saw some drag @ 11,880' & 11,840'). Pulled log w/arms out F/11,91 0' MD T/11,810' MD. Retract C^L arms and attempt to trip thru shoe. E-line will not pull thru @ 11,780' (Tool length 36.7 ft). Work E-line up to 7,000# nine times. Comes thru slick on tenth attempt. TOOH. RD E-line. 02:30 - 03:30 1.00 DR 2 50PRDR L/D NM Flex collars. PU Cleanout / wiper trip BHA. 03:30 - 08:00 4.50 DR 4 50PRDR TIH to 9 5/8" shoe @ 11,761' MD. 08:00 ~ 16:30 8.50 DR p 50PRDR TIH washing in 45 ft sections then back reaming same F/11,761' MD T/ 13,000' MD. Worked out fight spots as follows: KOP (11,927'-53') - saw inc. in torq. 800-900 amps w/10K-15K excess drag, did not stall out. 12,246'-12,225' -Saw torq. inc. to 700-800 amps, did not stall out. 12,915'-12,917' - Saw torq. inc. to 800-950amps, did not stall out. 12,920'-!2,940' -Saw torq. inc. to 800-1000amps, but did not stall out. Work area several times. 16:30 - 19:30 3.00 DR 5 50PRDR Circulate hole clean while rotating & recipricating pipe. Pumped 20 bbls Iow visc. (40) 7.2#, followed by 40 bbls high visc. (200) 17# - Brought back approx. 6-7 bbls of cuttings (1st quarter / dime size, 2nd buck-shot size, finally fine sand silt -- overall seemed to be a larger volume of cutting returns - coal volume was larger. 19:30 - 21:30 2.00 DR 4 50PRDR Pumped dry job for short trip. TOOH F/13,000' T/11,870'. Kelly up to wash and ream thru tight spots (coal- F/11,850' T/11,880') and continue to shoe. Printed: 11/04/98 6:42:37 AM PHILLIPS PETROLEUM CO Page 24 of 61 Operations Summa Report Legal Well Name: NORTH COOK INLET UNIT-B 000003 Common Well Name: North Cook Inlet Unit B-3 Spud Date: 05/03/98 Event Name: Original Drilling Start: 02/09/98 End: Contractor Name: Rig Release: Group: Rig Name: Rig Number: Date From - To Hours Sub Co Phase Code Description of Operations 07/13/98 21:30 - 00:00 2.50 DR 4 50PRDR TIH slowly, F/shoe T/13,000' MD. Continued TIH without washing / reaming stds. 129 - 132 (F/13,000' T/13,379'). Kelly up to wash and ream (hole tight @ std 133). Wash / ream F/13,473' T/13,558'. (NOTE: 13,453' & 13,518' tight, Torq= 600-850amps. Worked !hole clean). 07/14/98 00:00 - 03:30 3.50 DR 4 50PRDR .Continue TIH, reaming F/13,558' MD T/14,181' MD. NOTE: Hole reamed tight F/13,578'-13,588' & 13,764' (Torq: 600amps-1000amps, cleaned same out). 03:30 - 05:30 2.00 DR 5 50PRDR Circulate hole clean while rotating & reciprocating pipe. Pumped 20 bbls Iow visc. (40) 7.2#, followed by 40 bbls high visc. (200) 17# - Brought back approx. 6-7 bbls of cuttings (1st quarter / dime size, 2nd buck-shot size, finally fine sand silt -- overall seemed to be a larger volume of cutting returns - coal volume was larger and appeared to be fresh cuttings (thin & edged). 05:30 - 06:00 0.50 DR 4 50PRDR POOH 4 1/2 Stds. slow F/i4,181'-13,619'. Pulled tight at 13,619'. 06:00 - 07:00 1.00 DR 4 50PRDR Kelly up to back ream. TOOH, back reaming F/13,659' MD T/13,000' MD, roaming is very smooth. 07:00 - 08:30 1.50 DR 14 50PRDR POOH F/13,000' MD T/11,683' MD. Pulled slow at KOP and into shoe, saw increase in drag F/10K-20K T/50K at KOP. Trip was very smooth. 08:30 - 09:00 0.50 DR 5 50PRDR Break circ. and pumped dry job. 09:00 - 13:30 4.50 DR 4 50PRDR POOH F/shoe (11,761' MD) T/surf.. 13:30 - 14:30 1.00 DR 2 50PRDR Break bit & LD clean-out BHA. 14:30 - 16:00 1.50 DR 2 50PRDR MU new dir. BHA. Orient and test MWD / CDR / motor (all O.K.). 16:00 - 18:30 2.50 DR 7 50PRDR Set back BHA in derrick. Pull strip-o-matic and clean out coal cuttings -- from trip-tank, flowline plugged off, Change rubbers in strip-o-matic and clean floor. 18:30 - 00:00 5.50 DR 4 50PRDR TIH T/9,521' MD filling pipe at 4838' & 9521'. 07/15/98 00:00 - 00:30 0.50 DR 4 50PRDR TIH TO 11,680', FILL DRILL PIPE. 00:30 - 01:30 1.00 RM c 50PRDR SLIP AND CUT 109' OF DRILLING LINE, SERVICE TOP DRIVE. 01:30 - 03:30 2.00 DR 4 50PRDR TIH TO 13,900', TAGGED LEDGE, HOLE A LITTLE TIGHT. 03:30 - 04:00 0.50 DR d 50PRDR WASH AND REAM THRU TIGHT HOLE FROM 13900' TO 13920'. CONTINUED WASHING TO 14181'. HAD NO' NOTICABLE FILL BUT SEEM TO BE PUSHING SOMETHING TO BOTTOM, POSSIBLY BIG PIECES OF COAL. 04:00- 20:30 16.50 DR q 50PRDR DRILL FROM 14181'TO 14,343':- ROTATE 14,181'- 14,323' SLIDE 14,323'.- 14,343' 20:30 - 22:30 2.00 RM m 50PRDR REPLACE VALVE & SEAT IN CENTRE DISCHARGE OF #1 MUD PUMP. 22:30 - 00:00 1.50 DR q 50PRDR DRILL (ROTATE) FROM 14,343' TO 14,485' 07/16/98 00:00 - 04:00 4.00 DR q 50PRDR DRILL FROM 14,485FTTO 14,533FT:- ROTATE 14,485' - 14,515' SLIDE 14,515' - 14,533' 04:(~0 - 05:00 1.00 DR 4 50PRDR MAKE SHORT TRIP TO 14,181FT - NO BACKREAMING REQUIRED (MAXIMUM OVERPULL 25K BUT NO STICKING). WASH BACK TO BTM - NO REAMING REQUIRED. MIX & PUMP LO VIS/HI VIS PILL. 05:00- 00:00 19.00 DR q 50PRDR DRILL FROM 14,533FTTO 14,733FT:- ROTATE 14,533' - 14,700' SLIDE 14,700'- 14,710' ROTATE 14,710' - 14,733' 07/17/98 00:00 - 05:00 5.00 DR q 50PRDR DRILL FROM 14,727FT TO 14,782FT:- ROTATE 14,782'- 14,751' SLIDE 14,751'- 14,771' Printed: 11/04/98 6:42:37 AM PHILLIPS PETROLEUM CO Page 25 of 61 Operations Summa Report Legal Well Name: NORTH COOK INLET UNIT-B 000003 Common Well Name: North Cook Inlet Unit B-3 Spud Date: 05/03/98 Event Name: Original Drilling Start: 02/09/98 End: Contractor Name: Rig Release: Group: Rig Name: Rig Number: Date From- To Hours Sub CoPhase Code Description of Operations 07/17/98 00:00- 05:00 5.00 DR q 50PRDR ROTATE 14,771'- 14,782' 05:00 - 08:30 3.50 DR 4 50PRDR MAKE SHORT TRIP TO SHOE. TIGHT @ 13,811FT. WORK PIPE FREE. BACK REAM FROM 13,840FT TO 13,751 FT. CONT. POOH TO 11,681FT (30K OVERPULL @ KOP FROM 11,953' TO 11,927'. 08:30- 09:00 0.50 RM 3 50PRDR SERVICETD 09:00 - 12:30 3.50 DR p 50PRDR WASH IN HOLE TO 13,857FT. REAM FROM 13,857FT TO 13,899FT. WASH TO 14,687FT. WASH/REAM TO 14,782FT. 12:30 - 00:00 11.50 DR q 50PRDR DRILL (ROTATE) FROM 14,782FT TO 14,867FT. 07/18/98 00:00- 10:30 10.50 DR q 50PRDR DRILL FROM 14,867FTTO 14,964FT 10:30- 11:00 0.50 DR ~4 50PRDR MAKE SHORT TRIP TO 14,782FT 11:00 - 12:00 1.00 DR q 50PRDR DRILL FROM 14,964FT TO 14,971FT. PUMP LO VIS/HI VIS SWEEP. 12:00- 00:00 12.00 DR q 50PRDR DRILL FROM 14,971FTTO 15,057FT:- ROTATE 14,971' - 15,008' SLIDE 15,008'- 15,028' ROTATE 15,028'- 15,057' 07/19/98 00:00- 12:00 12.00 DR q 50PRDR DRILL (ROTATE) FROM 15,057FTTO 15,137FT 12:00 - 13:00 1.00 DR 4 50PRDR MAKE SHORT TRIP TO 14,782FT (MAXIMUM OVERPULL 25K BUT NO !STICKING). WASH BACK TO BTM. PUMP LO VIS/HI VIS SWEEP. 13:00 - 00:00 11.00 DR q 50PRDR DRILL (ROTATE) FROM 15,137FT TO 15,210FT 07/20/98 00:00- 14:30 14.50 DR q 50PRDR DRILL FROM 15,210FTTO 15,337FT:- ROTATE 15,210'- 15,250' SLIDE 15,250'- 15,270' ROTATE 15,270' - 15,337' 14:30 - 22:00 7.50 DR 4 50PRDR PUMP SWEEP (INCREASED CUTTINGS AT SURFACE). MAKE SHORT TRIP TO SHOE. POOH FROM 15,337FT TO 14,677FT (TIGHT @ 14,667FT). BACKREAM FROM 14,677FT TO 14,407FT. POOH FROM 14,407FT TO 14,129FT. BACKREAM FROM 14,129FT TO 13,659FT (TIGHT @ 13,953FT). POOH FROM 13,695FT TO 11,678FT. 22:00- 00:00 2.00 RM 3 50PRDR SERVICE TD. CLEAN RIG FLOOR. REPAIR PRODUCTION PIT SUCTION VALVE. SERVICE TURBINE. 07/21/98 00:00 - 01:30 1.50 RM m 50PRDR REPLACE HYDRAULIC HOSE ON TOP DRIVE. REPLACE MUD PUMP SENSOR. CHARGE TD NITROGEN SYSTEM. 01:30 - 03:00 1.50 DR 4 50PRDR RIH TO 13,741FT, INSTALLING DP RUBBERS EVERY 2ND JT FROM STD #125. TAG @ 13,741FT. ENGAGE TOP DRIVE - CHAIN SNAPPED ON COUNTERBALANCE. '03:00 - 05:00 2.00 RM m 50PRDR REPLACE COUNTERBALANCE CHAIN. REAM FROM 13,650FT TO 13,760FT 05:00 - 07:30 2.50 DR 4 50PRDR RIH TO 14,926FT (TAG @ 14,926FT). REAM FROM 14,874FTTO 114,964FT. RIH TO 15,337FT. 07:30 - 16:00 8.50 DR q 50PRDR ROTATE FROM 15,337FT TO 15,404FT. 16:00 - 22:00 6.00 DR q 50PRDR ORIENT TOOL FACE. SLIDE FROM 15,404FT TO 15,424FT. 22:00- 00:00 2.00 DR q 50PRDR ROTATE FROM 15,424FTTO 15,441FT 07/22/98 00:00- 07:30 7.50 DR q 50PRDR DRILL (ROTATE) FROM 15,436FT TO 15,504FT. 07:30 - 08:30 1.00 DR 4 50PRDR MAKE SHORT TRIP TO 15,043FT. PUMP SWEEP. 08:30- 12:30 4.00 DR q 50PRDR DRILL (ROTATE) FROM 15,504FTTO 15,529FT. 12:30 - 22:00 9.50 DR 4 50PRDR POOH FROM 15,529FT TO 14,615FT (TIGHT @ 14,615FT). BACK REAM FROM 14,615FT TO 14,500FT (TIGHT @ 14,550FT). PUMP OOH FROM 14,500FT TO 14,221 FT. POOH FROM 14,221FT TO SHOE @ 11,761 FT. (NOTE: DRILL PIPE RUBBERS APPEAR TO BE PERISHING IN OBM) 22:00 - 22:30 0.50 DR 5 50PRDR ClRC BTMS UP. CLEAN RIG FLOOR. PUMP SLUG. 22:30 - 00:00 1.50 DR 4 50PRDR POOH FROM 11,761FT. 07/23/98 00:00 - 05:00 5.00 DR 4 50PRDR 'FINISH POOH F/11761' T) SURFACE 05:00 - 06:00 1.00 DR 2 50PRDR L/D 8.5" SMITH M-32 BIT, CLEAN FLOOR, PULL WEAR BUSHING & ,, Printed: 11/04/98 6:42:37 AM , ,I i PHILLIPS PETROLEUM CO Page 26 of 61 Operations Summar Report Legal Well Name: , NORTH COOK INLET UNIT-B 000003 Common Well Name: North Cook Inlet Unit B-3 Spud Date: 05/03/98 Event Name: Original Drilling Start: 02/09/98 End: Contractor Name: Rig Release: Group: Rig Name: Rig Number: Date From.- To Hours Sub Co Phase Code Description of Operations 07/23/98 05:00 - 06:00 1.00 DR 2 50PRDR INSTALL TEST PLUG. 06:00 - 09:00 3.00 WC 8 50PRDR WEEKLY BOPE TEST. TEST CHOKE MANIFOLD, CHOKE & KILL LINES, HRC VALVES, PIPE & BLIND RAMS, SAFETY VALVES, & INSIDE BOP TO 250# LOW & 5000# HIGH PRESSURE. TEST ANNULAR PREVENTOR TO 250# LOW & 2500# HIGH PRESSURE TEST. NOTIFIED BLAIR WONDZELL W/AO&GC @ 13:00 HRS 7-21-98 OF INTENT TO TEST BOPE. AO&GC DID NOT WITNESS THE TEST. 09:00 - 09:30 0.50 WC 8 50PRDR REMOVE TEST PLUG & INSTALL WEAR BUSHING. 09:30 - 12:30 3.00 DR 2 50PRDR MU 8.5" SMITH M-16 BPX, MUD MOTOR, & 7.5" OD. STABILIZER. DOWN LOAD DATA FROM CDR. TEST MWD. 12:30 - 17:30 5.00 DR 4 50PRDR RIH TO SHOE @ 11,761FT. BREAK CIRC. 17:30- 18:30 1.00 RM c 50PRDR CUT91FTDRLLINE 18:30- 20:00 1.50 RM m 50PRDR INSTALL TD COUNTERBALANCE RAM 20:00- 23:00 3.00. DR 4 50PRDR RIH FROM 11,761FT TO 14,226FT. REAM FROM 14,226FT TO 14,319FT. RIH FROM 14,319FT TO 15,441FT. REAM FROM 15,441FT TO 15,529FT. 23:00 - 00:00 1.00 DR q 50PRDR DRILL (ROTATE) FROM 15,529FT TO 15,550FT. 07/24/98 00:00 - 00:00 24.'00 DR q 50PRDR DRILL FROM 15,550FTTO 15,809FT:- ROTATE 15,550' - 15,657' SLIDE 15,657' - 15,677' (PUMP SWEEP - INCREASED CUTTINGS RETURNED) ROTATE 15,677' - 15,750' SLIDE 15,750' - 15,771' ROTATE 15,771' - 15,809' !07/25/98 00:00- 00:30 0.50 DR 4 50PRDR WIPER TRIP F/15809'T/15524', NO FILL OR TIGHT SPOTS ON WIPER TRIP. PUMP 40 BBL LOW VIS/HIGH VIS SWEEP AFTER WIPER TRIP. 00:30- 03:00 2.50 DR q 50PRDR DRILLING (ROTATE) F/15809'T/15872' AVG. ROP 25 FPH. !RECOVERED PIECES OF COAL IN RETURNS @ BU AFTER WIPER TRIP. NO INCREASE IN CUTTINGS WHEN LOW/HIGH VIS SWEEP WAS RECOVERED @ SURFACE. 03:00 - 04:30 1.50 DR q 50PRDR DRILLING (SLIDING) F/15872' T/15883' AVG. ROP 7 FPH. 04:30 - 00:00 19.50 DR q 50PRDR DRILL FROM 15,883FT TO 16,145FT:- ROTATE 15,883' - 15,929' SLIDE 15,929'- 15,934' ROTATE 15,934' - 15,941' SLIDE 15,941'- 15,961' ROTATE 15,961'- 16,145' 07/26/98 00:00 - 02:00 2.00 DR 4 50PRDR MAKE SHORT TRIP TO 15,802FT. A FEW TIGHT SPOTS - WORKED PIPE FREE (MAX 50K OVERPULL), DID NOT HAVE TO BACK REAM. CIRC BTMS UP (NO INCREASED CUTTINGS RETURNS). 02:00- 00:00 22.00 DR p 50PRDR DRILL FROM 16,145FTTO 16,4lIFT:- ROTATE 16,145' - 16,408' SLIDE 16,408'- 16,411' 107/27/98 00:00- 01:00 1.00 DR q 50pRDR ATTEMPT SLIDE- UNSUCCESSFUL 01:00 - 02:00 1.00 DR q 50PRDR DRILL (ROTATE) FROM 16,411FTTO 16,424FT. 02:00 - 02:30 0.50 DR 4 50PRDR MAKE SHORT TRIP TO 16,100FT. PUMPED CCH - MAX OVERPULL 25K, NO STICKING PROBLEMS. Printed: 11/04/98 6:42:37 AM j ,i, PHILLIPS pETROLEUM CO Page 27 of 61 Operations Summar Report Legal Well Name: NORTH COOK INLET UNIT-B 000003 Common Well Name: North Cook Inlet Unit B-3 Spud Date: 05/03/98 Event Name: Original Drilling Start: 02/09/98 End: Contractor Name: Rig Release: Group: Rig Name: Rig Number: Date From - To Hours Sub Co Phase Code Description of Operations ,, 07/27/98 02:30- 03:00 0.50 DR 5 50PRDR CIRC BTMS UP (NO INCREASED CU'I-I'INGS RETURNED) 03:00- 03:30 0.50 DR q 50PRDR ROTATE FROM 16,424FTTO 16,435FT. 03:30- 04:30 1.00 DR q 50PRDR ATTEMPT SLIDE- UNSUCCESSFUL. 04:30 - 10:30 6.00 DR q 50PRDR ROTATE FROM 16,435FT TO 16,480FT. PUMP SWEEP - 15BBL LO VIS/25BBL HI-VIS. 10:30- 13:30 3.00 DR q 50PRDR SLIDE FROM 16,480FTTO 16,487FT 13:30- 00:00 10.50 DR q 50PRDR ROTATE FROM 16,487FTTO 16,600FT. 07/28/98 00:00- 01:30 1.50 DR 5 50PRDR CIRCULATE BTMS UP FROM 16,600FT 01:30 - 04:30 3.00 DR 14 50PRDR PUMP OOH TO 15,800FT - NO STICKING. PULL OOH, TIGHT @ 15,729FT. BACKREAM FROM 15,758FT TO 15,726FT. PUMP OOH TO 15,450FT. PULL OOH, TIGHT @ 15,415FT. WORK PIPE. 04:30- 07:30 3.00 DR a 50PRDR JAR ON STUCK PIPE @ 15,415FT. 07:30 - 09:00 1.50 DR 5 50PRDR CIRC BTMS UP TO CLEAN HOLE (SIGNIFICANT INCREASE IN COAL RETURNS. LARGE PIECES OF DP RUBBER RETURNED) . 09:00- 14:30 5.50 DR a 50PRDR JAR ON STUCK PIPE @ 15,415FT 14:30 - 18:00 3.50 DR z 50PRDR SPOT DIESEL PILL. PUMP 0.5BBL EVERY 30 MINS. CeNT TO JAR ON STUCK PIPE. 18:00 - 21:00 3.00 DR 5 50PRDR JAR ON PIPE. CIRC BTMS UP TO DISPLACE DIESEL FROM HOLE (COAL & DP RUBBER IN RETURNS). R/U APRS WIRELINE. 21:00 - 23:00 2.00 DR 2 50PRDR CeNT TO R/U APRS 23:00- 00:00 1.00 DR f 50PRDR RIH wNVIRELINE 07/29/98 00:00 - 01:00 1.00 FI f 50PRDR Cont. RIH w/APR's free point tool. 01:00 - 02:00 1.00 FI z 50PRDR Work pipe for free point. 60% stuck @ 15,273' MD and 20% stuck @ 15,242' MD by stretch and I torque. 02:00- 05:00 3.00 FI If 50PRDR POOH w/APRS. 05:00 - 06:00 1.00 FI '5 50PRDR Spot 11 bbls of diesel @ fish. 06:00 - 07:30 1.50 FI f 50PRDR RIH w/APRS - string shot. 07:30 - 09:00 1.50 FI f 50PRDR Work torque in string. Back-off DP w/string shot @ 15,206' MD. Top of fish at 15,206' MD. 09:00 - 10:30 1.50 FI f 50PRDR POOH w/APRS. 10:30 - 18:00 7.50 FI 4 50PRDR TOOH, back reaming F/15,206' MD T/shoe @ 11,761' MD. 18:00 - 19:30 1.50 FI 5 50PRDR Circ. BU at shoe. Clean rig floor. Pump dry job. 19:30 - 00:00 4.50 FI 4 50PRDR Pull OOH, L/D jars, and stand back 23 out of 25 HWDP joints. Fish remaining in hole as follows: Depth Desc. Length I' 15,206' MD 2 Jts HWDP 62' 15,268' MD X-O 1.61' 15,270' MD 2 NM Flex Clr 60.67' 15,330' MD MWD / CDR 51.44' 15,382' MD STB 5.80' 15,388' MD Motor 26.67' 15,414' MD Bit 0.75' 15,415' MD Fish TD NOTE: Removed DP rubbers from DP as TOOH. 6.5 clamps out of 122 total missing, 26 rubbers out of 61 total missing. Found 1 rubber and 1.5 clamps on top of the stdp-o-matic. 07/30/98 00:00 - 01:30 1.50 FI 2 50PRDR PU fishing BHA as follows (Bttm to top): Printed: 11/04/98 6:42:37' AM PHILLIPS PETROLEUM CO Page 28 of 61 Operations Summa Report Legal Well Name: NORTH COOK INLET UNIT-B 000003 Common Well Name: North Cook Inlet Unit B-3 Spud Date: 05/03/98 Event Name: Original Drilling Start: 02/09/98 End: Contractor Name: Rig Release: Group: Rig Name: Rig Number: Date From - To Hours Sub CoiPhase Code Description of Operations .... 07/30/98 00:00 - 01:30 1.50 FI 2 50PRDR 4 1/2" IF Screw in Sub 2.18' 4 1/2" IF Pumpout Sub 1.62' (2700# pump out disc.) 6 1/4" Bumper Sub 9.03' 6 1/8" Hydraulic Jars 11.57' X-Over 1.08' 6-6 1/4" Spiral DC's 184.20' X-Over 1.29' 6 1/4" Intensifer Jars 12.64' 27 Jts 5" HWDP 814.34' Total Fishing BHA = 1037.95' , 01:30 - 04:30 3.00 FI z 50PRDR Unable to get past obstruction at wear bushing (55.5 ft from surface). Sat down BHA weight (4000#) on obstruction - would not budge. i Drain BOP stack. Appears to be blocked w/DP rubbers. Retrieve I pipe rubber cage (metal) w/hooked soft line. Attempt to ease thru with fishing BHA again, saw no resistance by obstruction. Pulled BHA to surface and inspected. Recovered rubber fragments from screw-in sub. Repeated same and saw no rubber in the BHA. 04:30 - 09:00 4.50 FI 4 50PRDR TIH w/fishing BHA to 14,837' MD. 09:00 - 11:00 2.00 FI 4 50PRDR TIH, washing and reaming F/14,837' T/15,206' MD (Top of Fish). 11:00 - 15:30 4.50 FI a 50PRDR Locate fish at 15,206' MD (circulating at 500 psi / 34 SPM). Screw into toP of fish at 15,206' MD, unable to circulation. Work on fish jaring down with bumper sub - no movement. Work on fish jaring up with oil jars. Pulled 245K over stdng weight of 330K. Fish inched free after several attempts. Saw increase of 20K on stdng weight and torque increased from 400 amps to 650 amps. Established circulation @ 700 psi and 34 SPM (122 GPM). 15:30 - 00:00 8.50 FI 4 50PRDR. TOOH, back reaming F/15,415' MD T/15,258' MD (157'). Back reaming is extremely tight. 07/31/98 00:00 - 00:00 24.00 FI 4 50PRDR TOOH F/15,258' MD T/13,354' MD (1904'). Back reaming and jarring as needed. Back reaming is extremely tight, but appears to be loosening up. Mostly have been able to pull OOH slowly while circulating at 1750 psi / 85 SPM / 300 GPM. TOOH summary as follows: (8 Hrs) Back Ream F/15,258' T/15,228' (30') (4 Hrs) Pull OOH Circ. F/15,228' T/14,271' (957') (3 Hrs) Back Ream F/14,271' T/14,108' (163') (6 Hrs) Pull OOH Circ. F/14,108' T/13,414' (694') (3 Hrs) Back Ream F/13,414' T/13,354' (60') 08/01/98 00:00 - 01:30 1.50 FI 4 50PRDR TOOH F/13,354' T/13,100', back reaming and jarring as needed. Pulled into tight spot at 13,100' MD, tight/unable to rotate. 01:30 - 05:00 3.50 FI a 50PRDR Work stuck pipe w/jars - unable to establish movement up or down or rotate. (NOTE: Circulating large coal chunks as big as your fist over the shakers). Printed: 11/04/98 6:42:37 AM PHILLIPS PETROLEUM CO Page 29 of 61 Operations Summa Report !Legal Well Name: NORTH COOK INLET UNIT-B 000003 Common Well Name: North Cook Inlet Unit B-3 Spud Date: 05/03/98 Event Name: Original Drilling Start: 02/09/98 End: Contractor Name: Rig Release: Group: Rig Name: Rig Number: Date From- To Hours Sub Co Phase Code Description of Operations 08/01/98 01:30 - 05:00 3.50 FI a 50PRDR Work on fish jardng up with oil jars. Pulled 400K / string weight 320K. 05:00 - 07:30 2.50 FI 5 50PRDR Pumped HI visc. / HI weight sweep while reciprocating pipe @ 2400# / 350 GPM. Hole packed-off once sweep got +/- 500 ft into annulus. Unable to activate jars. Bled trapped pressure off DP. Worked pipe and regained jarring action. Regained circulation after 30 min. of working pipe. Cimulated sweep to surface -- retums over shaker increased 50% mostly fines w/quarter sized coal fragments. 07:30 - 10:00 2.50 FI a 50PRDR Continue working stuck pipe w/jars - unable to establish movement up or down or rotate. Work on fish jarring up with oil jars. Pulled 575K / string weight 320K. 10:00 - 12:00 2.00 FI 5 50PRDR Pumped HI visc. / HI weight sweep while reciprocating pipe. Cimulated sweep to surface -- returns over shaker increased 50% mostly fines w/quarter sized coal fragments. 12:00 - 19:00 7.00 FI a 50PRDR Continue working stuck pipe w/jars - unable to establish movement up or doWn or rotate. Work on fish jarring up With oil jars. Pulled 575K / string weight 320K. Pumped HI visc./ HI weight sweep while reciprocating pipe at 12:30pm. Circulated sweep to surface -- retums over shaker increased slightly, mostly fines w/quarter sized coal. 19:00 - 20:00 1.00 FI 6 50PRDR Lay down 2 single DP its. Rig up APRS for free point run. 20:00- 20:30 0.50 FI 0 50PRDR Held Safety meeting. 20:30 - 22:00 1.50 FI q 50PRDR RIH w/APRS free point tool. 22:00 - 23:00 1.00 FI q 50PRDR Unable to work thru 2 1/4" I.D. of intensifer @ 12,672' MD. Kelly up to pump tools down at 450#. Work tools down to screw-in sub @ 12,895' MD. Unable to pass tools thru - appears to be plugged off. 23:00 - 00:00 1.00 FI q 50PRDR TOOH w/free point tools. 08/02/98 00:00 - 01:30 1.50 FI q 50PRDR MU E-line spudding assembly (spudding tool, weight bars, and jars). RIH w/APRS tools T/12,895' WLD (screw-in sub). Work thru same T/12,954' WLD (Obstuction appears to be solid fragment - rubber/metal).. 01:30 - 03:00 1.50 FI q 50PRDR POOH w/APRS E-line. 03:00 - 04:30 1.50 FI q 50PRDR Held pre-job safety meeting. Went on radio/telephone silence. MU string shot; RIH 500 ft w/string shot. Radio/telephone on. Cont. TIH w/string shot. String shot on depth at 12,926' WLD. 04:30 - 05:30 1.00 FI q 50PRDR Work left hand toque down DP for back-off @ 12,926' WLD. 'Fired string shot. Pipe Is free / lost 20K on up weight. 05:30 - 06:30 1.00 FI q 50PRDR POOH w/APRS E-line and RD same. 06:30 - 07:30 1.00 FI 5 50PRDR Circ. BU above fish @ +/- 12,926' WLD (no increase in cuttings over I shakers). 07:30 - 09:30 2.00 FI 4 50PRDR TOOH, back reaming / circ. F/12,926' WLD T/11,761' MD (9 5/8" csg shoe). 09:30 - 10:30 1.00 FI 5 50PRDR Circ. BU @ shoe (no increase in cuttings over shakers). Pump dry job. 10:30 - 12:30 2.00 FI 4 50PRDR TOOH F/11,761' MD T/8,002' MD. 12:30 - 15:00 2.50 RM m 50PRDR Change out pneumatic dirctional control valve on top drive. 15:00 - 18:00 3.00 FI 4 50PRDR Cont. TOOH F/8,002' MD T/BHA. Test choke manifold for BOPE test (Hi=5000# / Low=250#). '18:00 - 19:00 1.00 FI 2 50PRDR Lay down fishing BHA. BHA as follows (Top to Bttm): Printed: 11/04/98 6:42:37 AM PHILLIPS PETROLEUM CO Page 31 of 61 Operations Summar Report Legal Well Name: NORTH COOK INLET UNIT-B 000003 Common Well Name: North Cook Inlet Unit B-3 Spud Date: 05/03/98 Event Name: Original Drilling Start: 02/09/98 End: Contractor Name: Rig Release: Group: Rig Name: Rig Number: Date From - To Hours Sub Co Phase Code Description of Operations 08/03/98 16:30 - 00:00 7.50 FI z 50PRDR ROT=75RPM, Wt/Bit=3000#, SPM=67/67,GPM=480 08/04/98 00:00 - 07:00 7.00 FI z 50PRDR Cont. washing & reaming F/12,246' MD T/12,921' MD. (NOTE: Hole appeared to be smooth.) 07:00- 07:30 0.50 FI z 50PRDR Tagged fish @ 12,921' MD. 07:30 - 10:00 2.50 FI 5 '50PRDR Circ. 10-15 min. while working pipe (bit @ 12,902' MD). Pumped Lw/Hi risc. sweep while working pipe. NOTE: Packed off when Lw/Hi visc. sweep was @ 9 5/8" csg shoe (11,761' MD). Saw large increase in cuttings over shakers - 150% increase - large 'amount of coal, half dollar size avg. w/larger and smaller fragments / Recov. silt & Sand 10:00 - 12:30 2.50 FI z 50PRDR TOOH, back reaming F/12,923' MD T/shoe @ 11,761' MD. Torq.=600-700amps UPWt=270K,DWWt=190K,ROTWt=225K ROT=75RPM,BitWt=3K,Pmp=3000#,480GPM,67/67SPM 12:30 - 13:00 0.50 FI 5 50PRDR Circulated hole at shoe for clean returns. 13:00 - 16:30 3.50 FI z 50PRDR Pumped dry job. TOOH F/Shoe (11,761' MD) T/clean-out BHA. 16:30 - 19:00 2.50 FI z 50PRDR Lay down clean-out BHA. Pick-up screw-in #2 fishing BHA as follows (Bttm to top): Descr. Len. 4 1/2" IF Screw in Sub 2.39' 4 1/2" IF Pumpout Sub 1.63' (Bar/sleeve, sleeve I.D.=2") (Bar-ball O.D. = 2 1/8") 6 1/4" Bumper Sub 9.04' 6 1/4" Dailey Hydraulic Jars 32.38' 6 1/8" X-Over 1.08' 6-6 1/4" Spiral DC's 184.20' 16 1/4" X-Over 1.29' 27 Jts 5" HWDP 814.34' Total Fishing BHA = 1046.35' 19:00 - 19:30 0.50 RM 3 50PRDR Service top drive, IBOP, & swivel etc. 19:30 - 23:30 4.00 FI 4 50PRDR TIH w/fishing BHA T/shoe @ 11,761' MD (fill pipe every 3000'). 23:30 - 00:00 0.50 FI 4 50PRDR TIH, washing and rotating F/Shoe T/11,836' MD. 08/05/98 00:00 - 02:00 2.00 FI 4 50PRDR Cont. TIH washing and reaming F/11,836' MD T/12,921° MD. Tagged fill 3' above fish. 02:00 - 02:30 0.50 FI 4 50PRDR Wash down and tag fish @ 12,921' MD. 02:30 - 03:00 0.50 FI 5 50PRDR Circ. above fish to clean off. 03:00- 03:30 0.50 FI z 50PRDR' Screwinto fish. 03:30 - 05:00 1.50 FI z '50PRDR Jar on fish down with bumper sub increasing pressure to 3500psi attempting to establish circulation. Cont. same for I hr with no success. Suspect signs of packing off (slow increase in up weight neccessary to activate jars) o Drop bar to establish circulation while maintaining pipe movement and jar action. 05:00 - 12:30 7.50 FI a 50PRDR Jarring on fish down then up (over pull 100K +) while circulating thru pump-out sub (@12,917' MD). No success. Printed: 11/04/98 6:42:37 AM PHILLIPS PETROLEUM CO Page 32 of 61 Operations Summa Report ~Legal Well Name: NORTH COOK INLET UNIT-B 000003 Common Well Name: North Cook Inlet Unit B-3 Spud Date: 05/03/98 Event Name: Original Drilling Start: 02/09/98 End: Contractor Name: Rig Release: Group: Rig Name: Rig Number: Date From.- To Hours Sub Co Phase: Code Description of Operations 08/05/98 12:30 - 13:00 0.50 FI 16 50PRDR RU Halliburton slick line unit (w/TIH/pump thru sub/lubricator) to retrieve bar (Bar @ 12,917' MD). Test line to 1000psi befor RIH. 13:00 - 16:30 3.50 FI f 50PRDR RIH w/Halliburton slick line over-shot to retdeve bar. Work over-shot on top of bar. 16:30 - 17:00 0.50 FI f 50PRDR TOOH w/slick line (unable to tell if retieving bar). Did not recover bar. Change out over-shot. 17:00 - 19:30 2.50 FI f 50PRDR RIH w/slick line for 2nd attempt to recover bar out of pump-out sub @ 12,917' MD. Work over-shot on top of bar. 19:30 - 20:00 0.50 FI f 50PRDR TOOH w/slick line (unable to tell if retieving bar). Did not recover bar. Add more weight bars. 20:00 - 23:00 3.00 FI f 50PRDR Establish circulation, shut down pumps. RIH w/over-shot for 3rd attempt to recover bar out of pump-out sub @ 12,917' MD. Work over-shot on top of bar while pumping @ 540psi/75GPM. 23:00 - 00:00 1.00 FI f 50PRDR TOOH w/tools. Did not recover bar. 08/06/98 00:00 - 03:30 3.50 FI f 50PRDR RIH w/impression block on slick line, tag at 12,997' SLM. TOOH w/ ~mpression block (no impression on block). RD lubricator. 03:30 - 05:00 1.50 FI 5 50PRDR Kelly-up to establish circulation. Activate jars several times down assure jars work. ~05:00 - 07:00 2.00 FI f 50PRDR RU slick line. RIH w/2 5/16" outside/inside beveled edged overshot. 07:00 - 08:30 1.50 FI f 50PRDR Slick line jumped the schieve - kinked wire RIH. POOH w/slick line - no attempt at bar valve. 08:30 - 09:30 1.00 FI 6 50PRDR RD slick line. RU E-line w/side entry sub lubricator. 09:30 - 12:30 3.00 FI q 50PRDR ~ RIH w/2 5/16" over shot on E-line to depth to +/-12,880' WLM. Overshot will not go thru jars I.D.. TOOH. 12:30 - 15:00 2.50 FI 6 50PRDR Repair E-line reel problem in unit. Change out over shot to 1 1/4" over shot. 15:00 - 18:30 3.50 FI Iq 50PRDR RIH w/1 1/4" over shot on E-line to depth of 12,915' WLM. Attempt to latch onto fish. TOOH, no bar. 18:30 - 19:00 0.50 FI 6 50PRDR RD E-line tools and lubricator. 19:00 - 20:00 1.00 FI a 50PRDR Kelly up. Establish circulation work pipe jarring to ensure jars activate. 20:00 - 21:00 1.00 FI 6 50PRDR RU E-line w/lubricator. 21:00 - 00:00 3.00 FI q 50PRDR RIH w/1.92" over shot on E-line. Wor on bar at 12,916' WLD. TOOH. No bar valve. 08/07/98 00:00 - 02:00 2.00 FI q 50PRDR Held pre-job safety meeting. Went on radio/telephone silence. MU string shot, RIH 500 ft w/string shot. Radio/telephone on. Cont. TIH w/string shot. String shot on depth at 12,925' WLD (unable to get CCL across connection). 02:00 - 02:30 0.50 FI q 50PRDR Work left hand toque (8 raps) down DP for back-off @ 12,925' WLD. Fired string shot. Pipe is free /lost 20K on up weight. 02:30 - 04:00 1.50 FI q 50PRDR TOOH w/wireline string shot. RD APRs lubricator / E-line. 04:00 - 07:00 3.00 FI 5 50PRDR Kelly up. Circ. 4200 stks@ 400gpm while reciprocating / rotating pipe. Mixed and pumped Lw/Hi visc. sweep. Hole attempted to.pack-off slightly 2 times while sweep was inside casing. Cuttings return over shakers increased 75% - large amount of coal and fines with traces of cement. 07:00 - 09:00 2.00 FI 4 50PRDR TOOH, back reaming and circulating F/12,925' WLD T/Shoe (11,761' MD). 09:00- 13:30 4.50 FI 4 50PRDR Pump dry job. TOOH F/ shoe T/ BHA. 13:30 - 14:00 0.50 FI 2 50PRDR I Lay down screw-in fishing BHA. BHA as follows (Top to Bttm): I Descr. Len. 27 Jts 5" HWDP 814.34' , , Printed: 11/04/98 '.6:42:37 AM ,, ,i PHILLIPS pETROLEUM CO Page 33 of 61 Operations Summa Report !Legal Well Name: NORTH COOK INLET UNIT-B 000003 Common Well Name: North Cook Inlet Unit B-3 Spud Date: 05/03/98 Event Name: Original Drilling Start: 02/09/98 End: Contractor Name: Rig Release: Group: Rig Name: Rig Number: Date From - To Hours Sub Co Phase Code Description of Operations 08/07/98 13:30- 14:00 0.50 FI 2 50PRDR 6 1/4" X-Over 1.29' 6-6 1/4" Spiral DC's 184.20' 6 1/8" X-Over 1.08' 6 1/4" Dailey Hydraulic Jars 32.38' Total Recovered 1033.29' Fish in the hole as follows (top to bttm): 6 1/4" Bumper Sub 9.04' 4 1/2" IF Pumpout Sub 1.63' (Bar/sleeve, sleeve I.D.=2") (Bar-ball O.D. = 2 1/8"/Len.=2.63') 4 1/2" IF Screw in Sub 2.39' 1 Jt 5" HWDP 30.21' X-Over 1.61' NM Flex Collar 30.33' NM Flex Collar 30.34' MWD 28.60' CDR 22.84' 7 1/2" lBS NM Stab 5.80' 4/5 Adj. Mtr @ 1.50 deg 26.67' Bit #11 - M16BPX 0.75' Total fish 190.21' Top of fish (Est. MD) 12,907.94' Fish Bit Depth (Est. MD) 13,100.00' 14:00 - 17:00 3.00 FI 2 50PRDR Held pre-job safety meeting. MU wash pipe fishing BHA as follows (Bttm to Top): Cut lip Burn Shoe 3.27' (8 7/16x6 15/16) 6 Jts Wash pipe 181.10' (8 1/8x7 1/4) Top Sub 2.35' Dailey Hydraulic jars 32.14' X-Over 1.06' 6 spiral Stl DC 184.20' X-Over 1.29' 27 HWDP 814.34' Total W.P. BHA 1219.77' 17:00 - 20:00 · 3.00 FI 4 50PRDR TIH, torque up each jt of DC, HWDP, to ensure pipe is tight. 20:00 - 21:30 1.50 RM 3 50PRDR Service top drive, drawworks & clean floor of oil & tools. 21:30 - 00:00 2.50 FI 4 50PRDR TIH w/wash pipe BHA very slowly due to wash pipe displacement / surge effect (estimate 5 min. / Std). 08/08/98 00:00 - 05:30 5.50 FI 4 50PRDR TIH w/wash over pipe (very slowly) F/3936' MD T/11,761' MD. 05:30 - 07:00 1.50 FI 4 50PRDR Wash & ream washpipe F/11,761' MD T/12,009' MD. 07:00 - 09:30 2.50 FI 5 50PRDR With top sub 30' below shoe, circulated 4500 stks @ 400GPM While rotating @ 50RPM and reciprocating pipe 25ft. Mixed & pumped Lw/Hi sweep while working pipe. Saw very little increase in cutting returns - mostly fines. 09:30 - 10:00 0.50 FI 4 50PRDR Attempt to pull top sub and wash pipe into shoe.. Pipe stalls out completely. Printed: 11/04/98 6:42:37 AM PHILLIPS PETROLEUM CO Page 34 of 61 Operations Summary Report Legal Well Name: NORTH COOK INLET UNIT-B 000003 Common Well Name: North Cook Inlet Unit B-3 Spud Date: 05/03/98 Event Name: Original Drilling Start: 02/09/98 End: Contractor Name: Rig Release: Group: Rig Name: Rig Number: Date From - To Hours Sub Co Phase Code Description of Operations 08/08/98 09:30 - 10:00 0.50 FI 4 50PRDR Pull up to 300K (String UpWt = 255K) 45K over string weight. Slack-off to 180K - 200K and break free - 75K to free. Top bushing has not come back into casing w/45K pull. 10:00 - 00:00 14.00 FI 4 50PRDR Wash / ream wash pipe F/12,009' MD T/12,908' MD. Saw no indications of washing over fish. Cont. wash / ream F/12,908' MD T/13,152' MD. Torque increased from 450 amps range to fluxing from 500 amps to 650 amps. No increase in )ressure or set down weight. Pipe would stall out. To restart rotation it would take 15K - 20K increase in drag, then the pipe would rotate and the excess weight would drop off. Cont. washing and reaming F/13,152' MD T/13,209' MD. Still no clear signs of washing over fish. Pipe stalled out and packed off at 13,191' MD. Worked pipe/pumps and regained circulation and pipe is free. 08/09/98 00:00 - 03:30 3.50 FI 4 50PRDR Cont. wash / ream F/13,209 T/13,225' MD. No sign of fish. Extremely slow GIH @ this point 2-5 FPH washing rate (4-8K WOB, 50-60 RPM, 2200#, 114 SPM, 406 GPM, Upwt=305K, Dnwt=205K, Rotwt=240K, torq=600-800amps). Hole attempting to pack-off. Mixed and pumped Lw/Hi visc. sweep @ 13,210' MD. Saw 50% increase in cuttings return - quarter size coal with fines (saw no more than 5 recovered metal shavings, hair thin- 1" to 1.5" long, cutting over shakers - most likely from casing wear). 03:30 - 11:30 8.00 FI 4 50PRDR TOOH, back reaming F/13,225' MD to 13,139' MD (86 ft). 13,225' MD T/13,181' MD (44 ft) reamed smooth (20 min). 13,181' MD T/13,139' MD (42 ft) reamed extremely tight. Had to inch it along reaming and banging into it - lose 20'-30' after stalling out to regain rotation. Repeated process over 7 1/2 Hrs plus. 11:30 - 15:00 3.50 FI 4 50PRDR TOOH, back reaming F/13,139' MD T/11,761' MD. Reamed very smooth. 15:00 - 16:00 1.00 FI 4 50PRDR Try to work pipe back into shoe, washing / back reaming, as before -- Attempt to pull top sub and wash pipe into shoe. Pipe stalls out completely. Pull up to 300K (String UpWt = 255K) 45K over string weight. Slack-off to 180K - 200K and break free - 75K to free. Top bushing has not come back into casing w/45K pull. Attempt to pull up into shoe by rotating and washing just inching the top sub and wash pipe into the shoe. Able to work up thru the shoe. 16:00 - 16:30 0.50 RM m 50PRDR Change out 5" elevators. Clean oil F/floor & pump dry job. 16:30 - 20:00 3.50 FI 4 50PRDR Cont. TOOH F/shoe T/BHA. 20:00 - 23:00 3.00 FI 2 50PRDR Stand back / lay down BHA as follows (Top to Bttm): 27 HWDP 814.34' X-Over 1.29' 6 spiral Stl DC 184.20' X-Over 1.06' Printed: 11/04/98 6:42:37 AM PHILLIPS PETROLEUM CO Page 35 of 61 Operations Summa Report Legal Well Name: NORTH COOK INLET UNIT-B 000003 Common Well Name: North Cook Inlet Unit B-3 Spud Date: 05/03/98 Event Name: Original Drilling Start: 02/09/98 End: Contractor Name: Rig Release: Group: Rig Name: Rig Number: Date From - To Hours Sub Co Phase Code Description of Operations 08/09/98 20:00- 23:00 3.00 FI 2 50PRDR Dailey Hydraulic jars 32.14' Top Sub 2.35' (Box End)Parted jt Wash pipe 26.64' (8 1/8x7 1/4) Recovered W.P. BHA 1062.02' Wash Pipe fish as follows (Top to Bttm): (Pin End) Parted jt Wash pipe 4.05' (8 1/8x7 1/4) 5 Jts Wash pipe 150.41' (8 1/8x7 1/4) Bum Shoe (Cut Lip) 3.27' (8 7/16x6 15/16) Total wash pipe fish 157.73' Bum Shoe Depth (Est.) 13225' :Top of Fish (Est.) 13067' NOTE: F/1st HWDP it. T/top sub & recovered wash pipe, there were both doWnward and upward spiral cuts. Possibly from the casing shoe / casing. Body break in wash pipe appeared to be kinked in some way and then 3 broken off. 23:00 - 00:00 1.00 RM 50PRDR Service top drive, clean rig floor, and test choke. 08/10/98 00:00 - 03:00 3.00 WC 8 50PRDR Pull wear bushing - install test plug - test BOPE: Hydrill - 250# / 2500# Rams, HCR's, Manual valves, top drive, floor valves - 250# / 5000#. Test accumulator, install wear bushing - drain stack. 03:00 - 04:30 1.50 FI 4 50PRDR M/U clean out BHA as follows (Bttm to top): Bit #9 MFD SSH 1.00' (Smith / Open) Bit Sub 1.77' X-Over 0.86' Stl Spiral DC 31.09' Stl Spiral DC 31.07' X-Over 0.89' X-Over 1.16' 7 3/4" lBS Stab (NM) 6.06' X-Over 1.60' 5 HWDP 151.19' Dailey Jars 32.14' 22 HWDP 663.15' Total BHA 921.98' 04:30 - 09:30 5.00 FI 4 50PRDR TIH w/C/O BHA, filling pipe every 3000' T/shoe @ 11,761' MD. Break , circulation. TIH, wash and ream, tag fish at 12,908' MD. , , (NOTE: Appears that wash pipe is beside ddlling BHA fish. Estimate wash pipe top is at 13,067' MD w/burn shoe at 13,225' MD). 09:30 - 11:00 1.50 FI 5 50PRDR I Circulate bottoms up (@ 2900#, 464 GPM, 130 SPM). 11:00 - 12:30 1.50 FI ;4 50PRDR ~TOOH, back reaming F/12,908' MD T/12,181' MD (RPM=50,2100#,SPM-112,400 GPM, UpWt=265K, DnWt=200K, Printed: 11/04/98 6:42:37 AM PHILLIPS PETROLEUM CO Page 36 of 61 Operations Summa Report Legal Well Name: NORTH COOK INLET UNIT-B 000003 Common Well Name: North Cook Inlet Unit B-3 Spud Date: 05/03/98 Event Name: Original Drilling Start: 02/09/98 End: Contractor Name: Rig Release: Group: Rig Name: Rig Number: Date From - To Hours Sub Co Phase Code Description of Operations ..... 08/10/98 11:00 - 12:30 1.50 FI 4' 50PRDR RotWt=235K, Torq.=525-600amps). 12:30 - 14:30 2.00 RM m 50PRDR Replace pipe handler hanger shaft. 14:30 - 15:00 0.50 FI 4 50PRDR TOOH, back reaming F/12,181' MD T/11,618' MD. 15:00 - 17:30 2.50 FI 4 50PRDR Circulate bottoms up, remove wireline sheave F/DRK, clean'floors. 17:30 - 18:00 0.50 FI 4 50PRDR Tdp back in the hole, washing / reaming to 12,908'. Tag fish. 18:00 - 22:00 4.00 FI 5 50PRDR Cimulate BU, had large amount of coal returns (@3000#, 473 GPM, 134 SPM), clean pits, mix 50 bbl bar pill (21.0 ppg). 22:00 - 00:00 2.00 FI z 50PRDR Pump & spot bar pill (21.0 ppg) @ 12,908' MD T/12,195' MD (Est. bar settling for 15 bbl vol. or 214' plug F/12,908' T/12,694). Pumped 50 bbl pill :)lus 10 bbl displacement w/Halliburton & chased w/rig pumps (500 GPM / 3200#) @ 2330 stks / 198 bbls. Pulled 10 stds, TOOH / back reaming to shoe at 11,761' MD. 08/11/98 00:00 - 00:30 0.50 FI 5 50PRDR i Break circ. & pump dry job - clean dg floor. 00:30- 05:00 4.50 FI 4 50PRDR POOH L/D BHA. 05:00 - 10:30 5.50 CE 2 50PRDR P/U cement spot BHA as follows (Bttm to top): 2 7/8" Diverter Jt. 31.02' (Plugged Bttm w/four circ. holes every ft for 16 ft and two 1 ft slits 6 in. F/ Bttm) X-Over 0.83' 20 its 3 1/2" DP 629.72' X-Over 1.91' 5" DP T/surf. RIH T/shoe @ 11,761' MD. 10:30 - 18:00 7.50 CE 4 50PRDR Wash F/11,761' T/12,677'. Circ. BU & tagged bar plug at 12,692' MD. 18:00 - 19:00 1.00 CE v 50PRDR Pumped 20 bbl gel pill (235 stks). Displace in hole, leave 8 bbls in pipe, 780' pill in pipe, 205' pill outside pipe, displace w/(208 bbls) 2444 stks. Pull piPe up to 12,500' MD, reverse circ. (216 bbls) 2537 stks. , NOTE: Reversed circulated to limit contamination of hole and mud due to water based pill. Limited casing pressure to 500-600 psi @ +/- 4BPM. 19:00 - 21:00 2.00 CE 0 50PRDR Pre-job safety meeting: Transfer diesel to rig pit F/gerter tank. Transfer 180 bbls mud F/active pits to platform pits, flush lines. 21:00 - 22:30 1.50 CE v 50PRDR Spot KOP plug F/12,500' T/Il,g00'. Cement job summary as follows: ~ (1) Pump 20 bbl diesel (7.2ppg/2.5BPM/490psi) Tested cement lines to 4000psi. 1(2) Pump 50 bbl Flozan Spacer(14.5ppg/4BPM/600psi) (3) Pump 80 bbl (454 sxs) CFR @ 0.75%, HR-5 @ 0.2% class G cement(17ppg/4BPM/600psi) Time 21:44. (4) Pump 9 bbl Flowzan Spacer (14.5ppg/4BPM/600psi) (5) Pump 7.5 bbl diesel(7.2ppg/2.5BPM/490psi) (6) Displaced w/170 bbls mud (14.5ppg/10BPM/1600psi). Time 22:26. NOTE: Short 10 bbls flozan on tail spacer due to isolation valve leaking on platform pit. Saw small amount of back flow when cmt lines were broke off (may be due to cmt channeling) 22:30 - 00:00 1.50 CE 4 50pRDR TOOH F/12,500' MD T/11,453' MD. 08/12/98 00:00 - 00:30 0.50 CE 4 50PRDR Cont. TOOH T/11,095' MD. Printed: 11/04/98 6:42:37' AM PHILLIPS PETROLEUM CO Page 37 of 61 Operations Summa Report Legal Well Name: NORTH COOK INLET UNIT-B 000003 Common Well Name: North Cook Inlet Unit B-3 Spud Date: 05/03/98 Event Name: Original Drilling Start: 02/09/98 End: Contractor Name: Rig Release: Group: Rig Name: Rig Number: Date From- To Hours Sub Co Phase Code Description of Operations 08/12/98 00:30 - 03:00 2.50 CE 5 50PRDR R/U to reverse circ.. Reversed DP & annulus volume @ 500-600 psi / 4.25 BPM/180GPM. Saw large amount of cement returns starting at 2200 Stks over shakers(+/- 187 bbls reversed out/tbg vol.= 190 bbls & ann vol. = 516 bbls). Cement continued thru complete cimulation (add'l 519 bbls) decreasing to a trace at the end of circ.. Est. based on bbls of mud volume lost +/- 40 bbls of cement reversed out. 03:00 - 06:30 3.50 CE 5 50PRDR RU to circ. conventionally. Circ. I 1/2 annulus / tubing capacities @ 3200# /535 GPM / 12.7 BPM. Saw a large amount of coal cuttings returns over the shaker. Continued to see cement returns until one complete circulation, only a trace there after. 06:30- 07:00 0.50 CE 4 50PRDR POOH T/9670' MD. 07:00 - 07:30 0.50 RM ~0 50PRDR RU to change out drill line. Held pre-job safety meeting. 07:30 - 16:30 9.00 RM m 50PRDR String new line in derrik, remove old drill line F/drum, service iron rough neck, inspect & adjust brakes on drum, etc.. 16:30 - 21:30 5.00 CE 4 50PRDR Cont. POOH F/9670' MD T/BHA. L/D 20 3 1/2" DP singles and diverter joint. 21:30 - 22:00 0.50 DR 2 50PRDR Change out BHA. Picked up CDR to break X-Over. 22:00 - 00:00 2.00 RM m 50PRDR Repair leaks on iron rough neck. 08/13/9~ 00:00 - 03:30 3.50 DR 4 50PRDR PU BHA TOOLS AND ORIENTATE MWD. MOVE JARS HWDP - TEST MWD. 03:30 - 10:30 7.00 DR 4 50PRDR RIH W/5" DP T/11,095'. WASH & ROTATE T/11,980' - STARTED DRILLING CMT STRINGERS. CONT WASHING T/12,050'. 10:30 - 11:30 1.00 DR 5 50PRDR CIRC. BU - HAD GREEN CMT IN SAMPLES F/11,985' 11:30- 12:30 1.00 DR d 50PRDR WASH AND DRILLT/12,100'. 12:30- 13:30 1.00 DR 5 50PRDR ClRC BU & RECIPROCATE @12,100!. 13:30 - 14:00 0.50 DR 4 50PRDR ITOOH W/4 STANDS DP CIRCULATING AND BACK REAMING. 14:00 - 20:00 6.00 DR 5 50PRDR CIRCULATE AND RECIPROCATE WHILE WAITING ON (3MT. 20:00 - 20:30 0.50 DR 4 50PRDR TIH W/4 STANDS DP & TAG CMT @ 12,100' W/30-35K LB. NO ROTATION OR PUMP. 20:30 - 21:00 0.50 DR d 50PRDR DRL CMT T/12,125' W/140 GPM AND 50 RPM @ TD W/10K LB WOB. INC PUMP RATE T/420 GPM & DRL @ APPROX 400 TO 700' INSTANT RATE. CMT IS GETTING HARDER, BUT STILL SOFT. 21:00 - 00:00 3.00 DR q 50PRDR DECIDE TO ATTEMPT SIDETRACK. ALLOW CMT TO CONTINUE TO SET WHILE TIME DRILLING GROVE [GROOVE CUT @ 150 DEG TOOL FACE SETTING]. 08/14/98 00:00 - 02:30 2.50 DR q 50PRDR RECIPROCATE F/12,091' T/12,126' TO FORM TRENCH FOR SIDETRACK. 02:30 - 14:00 11150 DR q 50PRDR TIME DRILL F/12,126' T/12,136' AT 1 FT/HR RATE. 14:00 - 18:00 4.00 DR q 50PRDR TIME DRILL F/12,136' T/12,143' AT 3 MIN TO 1 INCH RATE. 18:00 - 00:00 6.00 DR q 50PRDR TIME DRILL F/12,143' T/12,154 AT 2 MIN TO I INCH RATE. 08/15/98 ' 00:00- 00:30 0.50 DR q 50PRDR TIME DRILL F/12,154' T/12,156'. SLACK OFF T/12,179 AND HOLE WOULD NOT TAKE WEIGHT. 00:30 - 02:30 2.00 DR d 50PRDR WASH & REAM F/12,156' T/12460'. COMPETENT CEMENT WAS NOT ENCOUNTERED. 02:30 - 08:00. 5.50 DR 5 50PRDR CIRCULATE TO CLEAN HOLE - PUMP LOW/HIGH SWEEP AROUND. 08:00 - 09:00 1.00 DR p 50PRDR !BACKREAM F/12,460' T/11,761' SHOE. 09:00- 10:30 1.50 DR 5 50PRDR CIRCULATE WELL CLEAN. PUMP DRY JOB. 10:30 - 16:00 5.50 DR 4. 50PRDR 'POOH L/D XO - BIT. 16:00- 17:00 1.00 RM 3 50PRDR CLEAN RIG FLOOR. I Printed: 11/04/98 6:42:37 AM PHILLIPS PETROLEUM CO Page 38 of 61 Operations Summa Report Legal Well Name: · NORTH COOK INLET UNIT-B 000003 Common Well Name: North Cook Inlet Unit B-3 Spud Date: 05/03/98 Event Name: Original Drilling Start: 02/09/98 End: Contractor Name: Rig Release: Group: Rig Name: Rig Number: Date From - To Hours Sub Co Phase Code Description of Operations 08/15/98 17:00 - 19:00 2.00 CE 4 50PRDR PUI JT 2-7/8" TUBING, X-OVER, 20 JTS 3-1/2" TUBING & X-OVER. 19:00 - 23:00 4.00 CE 4 50PRDR RIH T/11,735'. 23:00 - 00:00 1.00 CE 6 50PRDR MAKE UP CEMENT EQUIP AND LAY BACK DOWN. 08/16/98 00:00 - 02:00 2.00 CE 4 '50PRDR TIH T/11,761' ESTABLISH CIRCULATION AND WASH T/12,460' AT MAX RATE (520 GPM) WHILE ROTATING AT 90 - 100 RPM. 02:00 - 05:30 3.50 CE 5 50PRDR AT 12,460' CIRCULATED 4 TIME BU WHILE RECIPROCATING AND ROTATING TO CONDITION HOLE. 05:30 - 06:00 0.50 CE 0 50PRDR RU CONTROL HEAD & CIRCULATING HOSE - BREAK CIRCULATION. HOLD PRE-JOB SAFETY MEETING AND PROCEDURE REVIEW. 06:00 - 08:30 2.50 CE v 50PRDR PUMP 20 BBL DIESEL SPACER W/RIG PUMP (2-3 BPM) / PUMP APPROXIMATELY 10 BBL FLOZAN AND TEST HALLIBURTON LINES ITC 4000 PSI, THEN PUMP REMAINING 40 BBL FLOZAN SPACER, 88 BBL CLASS G CEMENT W/.75% CFR3 & .2% HR5 MIXED AT 17 PPG (YIELD .99 CUFT/SK) AND 12.5 BBL FLOZAN SPACER WITH HALLIBURTON PUMPS (5-6 BPM) / PUMP 7.5 BBL DIESEL SPACER (2-3 BPM), 108 BBL MUD TO DISPLACE (1270 STROKES AT 10-12 BPM) AND 56 BBL MUD TO DISPLACE (659 STROKES AT 3 BPM) WITH RIG PUMPS. PIPE RECIPROCATED AND ROTATED THROUGH OUT JOB; 08:30 - 09:30 1;00 CE 2 50PRDR RD CONTROL HEAD AND HOSE - POOH W/14 STANDS T/11,144' - WET. 09:30 - 13:30 4.00 CE 4 50PRDR CIRCULATE OUT CEMENT F/11,144'. 13:30 - 18:00 4.50 CE 4 50PRDR PUMP DRY JOB AND POOH WITH DRILL PIPE. 18:00- 19:00 1.00 CE 4 50PRDR L/D20JTS3-1/2" DPAND 1JT2-7/8"TBG. 19:00 - 19:30 0.50 CE 2 50PRDR BREAK DOWN CEMENT HEAD. 19:30 - 22:00 2.50 RM 3 !50PRDR REPLACE THROTTLE ON #2 MUD PUMP, REPLACE PIPE HANDLER DIES, TIGHTEN IRON ROUGHNECK DRIVE WHEEL AND CLEAN OUT PILL PIT. 22:00 - 00:00 2.00 WC 9 50PRDR MAKE UP TEST JT, PULL WEAR RING, TEST CHOKE MANIFOLD, RAM'S TOP / BOTTOM PIPE, HCR'S, MANUAL'S VALVES, 250/LOW 5,000/HIGH, HYDRIL 250/2,500 PSI, ACCUMULATOR TEST. NO PROBLEMS. 08/17/98 00:00 - 01:30 1.50 WC 19 50PRDR 'TEST BLIND RAMS, TOP DRIVE VALVES, FLOOR VALVES 2'50/5000 PSI. PULL TEST PLUG - INSTALL WEAR BUSHING - BLOW DOWN. 01:30 - 06:00 4.50 WO j 50PRDR WOC - POWER WASH DERRICK. 06:00 - 10:00 4.00 DR 2 50PRDR MU BHA AND RIH TO 11,144'. 10:00- 11:30 1.50 DR d 50PRDR WASH F/11,144'T/11,800'. 11:30 - 23:00 11.50 WO j 50PRDR CIRCULATING @ 11,768' - 11,804' WHILE WOC. 23:00 - 00:00 1.00 DR p 50PRDR WASH AND REAM F/11,804' T/11,886'. 08/18/98 00:00 - 01:00 1.00 DR p 50PRDR WASH & REAMED OUT SOFT CMT F/11,886'T/12,050'. 01:00 - 02:30 1.50 DR 5 50PRDR CIRCULATE BU UNTIL HOLE CLEANED UP. GETTING LOTS OF CMNT BACK W/BARITE & FLOZAN CONTAMINATION. ALSO HAD LOTS OF COAL MIXED W/CMNT RETURNS. COAL PEA SIZED TO SILVER DOLLAR SIZED (UP TO 5/8" THICK). 02:30- 10:00 7.50 DR p 50PRDR ATTEMPTTO SIDETRACK HOLE @ 12,050'. RECIPROCATE F/12,020' T/12,050' TO CUT SIDETRACK GROOVE. TOOL FACE @ 180 DEG. TOOL FACE VERY ERRATIC - MOTOR STALLS. UNABLE TO SUCCESSFULLY CUT GROOVE @ 12,050'. WASHED OUT SOFT CMNT TO 12,060'. TOOL FACE STILL ERRATIC. WASHED OUT SOFT CMNT TO 12,065'. 10:00 - 11:00 1.00 DR p 50PRDR STARTED TO CUT GROOVE FOR SIDETRACK. TOOL FACE SET @ 180 DEG DOWN. TOOL FACE STARTED OFF VERY ERRATIC AT FIRST. CONTINUED CUTTING GROOVE & HOLE CLEANED UP. 11:00 - 00:00 13.00 DR w 50PRDR START TIME DRILLING AT 1'/HR TO SIDETRACK HOLE @ 12,065' Printed: 11/04/98 6:42:37 AM PHILLIPS pETROLEUM CO Page 39 of 61 Operations Summa Report Legal Well Name: NORTH COOK INLET UNIT-B 000003 Common Well Name: North Cook Inlet Unit B-3 Spud Date: 05/03/98 Event Name: Original Drilling Start: 02/09/98 End: Contractor Name: Rig Release: Group: Rig Name: Rig Number: Date From - To Hours Sub Co Phase Code Description of Operations 08/18/98 11:00 - 00:00 13.00 DR w 50PRDR T/12,078'. 08/19/98 00:00 - 10:00 10.00 DR w 50PRDR TIME DRILL F/12,078' T/12,088' @ 1'/HR (5 MIN/INCH) RATE. 10:00 - 17:00 7.00 DR w 50PRDR TIME DRILL F/12,088' T/12,100' @ 1.6'/HR (3 MIN/INCH) RATE. 17:00 - 21:30 4.50 DR w 50PRDR TIME DRILL F/12,100' T/12,110' @ 2.5'/HR (2 MIN/INCH) RATE. 21:30 - 22:00 0.50 DR w .50PRDR PU OFF BOTTOM AND ORIENT TOOL FACE 180 DEG DOWN. SET DOWN WITH 30 KLB - FORMATION HELD. PU OFF BOTTOM AND ORIENT TOOL FACE + 116 DEG - RESUME TIME DRILLING. 22:00 - 00:00 2.00 DR w 50PRDR TIME DRILL F/12,110'T/12,113' @ 2.5'/HR (2 MIN/INCH) RATE. 08/20/98 00:00 - 03:00 3.00 DR w 50PRDR TIME DRILL F/12,113' T/12,120' @2.5'/HR. TAKE SURVEY. 03:00 - 06:30 3.50 DR w 50PRDR TIME DRILL F/12,120' T/12,138' @5'/HR. TAKE SURVEY. 06:30 - 07:00 0.50 DR w 50PRDR ROTATE DRILL F/12,138'T/12,145'. 07:00 - 08:30 1.50 DR 5 50PRDR CIRCULATE BOTTOMS UP. 08:30 - 16:30 8.00 DR w 50PRDR SLIDE F/12,146'T/12,180'. 16:30 - 17:00 0.50 DR b 50PRDR SURVEY - WORK BACKT/BOTTOM F/12,175'T/12,180' MAKE CONNECTION. 17:00 - 20:00 3.00 DR q 50PRDR SLIDE F/12,180'T/12,200'. 20:00 - 21:30 1.50 DR q 50PRDR ROTATE F/12,200'T/12,212'. 21:30 - 22:00 0.50 DR b 50PRDR ORIENT TOOL FACE - SURVEY. 22:00- 00:00 2.00 DR q 50PRDR SLIDE F/12,212'T/12,222'. 08/21/98 00:00 - 12:00 12.00 DR q 50PRDR DIRECTIONAL DRILL F/12,222'T/12,325'. 12:00 - 12:30 0.50 DR q 50PRDR SLIDE F/12,325'T/12,331'. 12:30- 17:00 4.50 DR q 50PRDR ROTATE F/12,331'T/12,361'. 17:00- 19:00 2.00 DR 5 150PRDR CIRCULATE HOLE. 19:00 - 20:00 1.00 DR p 50PRDR BACKREAM F/12,361'T/11,761' (9-5/8" CASING SHOE). 20:00 - 21:00 1.00 DR 4 50PRDR TRIP IN HOLE F/SHOE TO BOTTOM. ORIENT TOOL FACE @ 12,166' WHILE GOING IN HOLE. 21:00 - 23:30 2.50 DR 5 50PRDR PUMP LOW/HIGH VIS SWEEP AND CIRC HOLE. 23:30- 00:00 0.50 DR p 50PRDR BACKREAM F/12,361'T/12,185'. 08/22/98 ,00:00 - 00:30 0.50 DR 4 50PRDR BACKREAM F/12,185' T/11,761'(SHOE). 00:30 - 01:30 1.00 DR 5 50PRDR CIRCULATE BU. PUMP DRY JOB. 01:30 ' 05:30 4.00 DR 4 50PRDR !TOOH L/D MOTOR - HWDP SCARRED UP WITH SPIRAL AND LINEAR GROOVES. 05:30 - 06:00 0.50 RM 3 50PRDR CLEAN RIG FLOOR. RU TEST JT. PULL WEAR BUSHING. INSTALL TEST PLUG. 06:00 - 09:30 3.50 WC !9 50PRDR TEST BOPE'S. HYDRIL 250/2500 PSI, RAMS, HCR & MANUAL VALVES, CHOKE, TOP DRIVE IBOP'S, FLOOR VALVES 250/5000 PSI. ACCUM TEST. REMOVE TEST PLUG - INSTALL WEAR BUSHING - BLOW DOWN. 09:30 - 16:00 6.50 LG 50PRDR RU APRS & WEDGE DIALOG WIRELINE EQUIPMENT- HELD SAFETY MEETING - CALIBRATE TOOL - RUN 9-5/8" CASING INSPECTION LOG. 16:00- 17:00 1.00 DR g 50PRDR MONITOR WELL- TIGHTEN DRAWWORKS BOLTS. 17:00 - 20:00 3.00 DR 2 50PRDR MAKE UP BHA, CHANGE OUT JARS, RIH W/HWDP, TEST MWD 20:00- 00:00 4.00 DR 4 50PRDR TRIP IN HOLE T/9,020°. 08/23/98 00:00 - 05:.30 5.50 DR 4 50PRDR TIH F/9,020' T/11,761. INSTALLING DP/CASING POLY SLEEVE PROTECTORS TO COVER F/3,000' T/400' HOLE INTERVAL W/BIT ON BO'I-I'OM (F/85 T/117 = 33 STDS). FILL DP @ SHOE 11,761'. 05:30 - 06:00 0.50 DR 4 50PRDR TIH T/12,361' - ORIENT.TOOLS & SURVEY. 06:00 - 18:00 12.00 DR q 50PRDR ROTATE F/12,361' T/12,587' (226'). - MWD TOOL FAILURE - 18:00 - 20:30 2.50 DR 5 50PRDR CIRCULATE & PUMP LOW/HIGH VIS SWEEP. 20:30- 22:30 2.00 DR p 50PRDR BACKREAM F/12,587'T/11,761'. '22:30 - 00:00 1.50 DR 5 50PRDR ClRC BU AT SHOE WHILE CLEANING RIG FLOOR / ADJUSTING DRAWWORKS BRAKES. PUMP DRY JOB. Printed: 11/04/98 6:42:37 AM PHILLIPS PETROLEUM CO Page 40 of 61 Operations Summa Report Legal Well Name: NORTH COOK INLET UNIT-B 000003 Common Well Name: North Cook Inlet Unit B-3 Spud Date: 05/03/98 Event Name: Original Drilling Start: 02/09/98 End: Contractor Name: Rig Release: Group: Rig Name: Rig Number: Date From - To Hours Sub Co Phase Code Description of Operations 08/24/98 00:00 - 05:30 5.50 DR 4 50PRDR TOOH F/11,761' (9-5/8" SHOE). 05:30 - 06:30 1.00 DR 2 50PRDR CHANGE OUT MWD & MUD MOTOR. 06:30 - 07:30 1.00 DR 2 50PRDR MAKE UP BIT. ORIENT DIRECTIONAL TOOLS. 07:30 - 13:00 5.50 DR 4 !50PRDR TIH - TEST MUD MOTOR & MWD - T/12,030' 13:00- 16:00 3.00 DR d 50PRDR WASH & REAM F/12,030'T/12,587'. 16:00- 18:00 2.00 DR q 50PRDR ROTATE F/12,587'T/12,637'. ~18:00 - 20:00 2.00 DR q 50PRDR SLIDE F/12,637' T/12,645'. ~20:00- 00:00 4.00 DR q 50PRDR ROTATE F/12,645'T/12,720'. 08/25/98 00:00 - 11:00 11.00 DR q 50PRDR DIR DRILL BY ROTATION F/12,720' T/12,900'. PUMP 30 BBL LOW VIS SWEEP FOLLOWED BY 30 BBL HIGH VIS SWEEP. 11:00 - 12:30 1.50 DR q 50PRDR DIR DRILL BY SLIDE F/12,900' T/12,907' 12:30 - 15:30 3.00 DR q 50PRDR DIR DRILL BY ROTATION F/12,907~ T/12,951'. PUMP LOW/HIGH VIS SWEEP. 15:30 - 16:00 0.50 DR p 50PRDR SHORT TRIP - BACKREAM F/12,951' T/12,587'. 16:00- 16:30 0.50 DR p 50PRDR REAM IN HOLE F/12,587'T/12,921'. 16:30- 17:30 1.00 DR !5 50PRDR PUMP LOW/HIGH VIS SWEEP - CIRC BU. 17:30- 00:00 6.50 DR q 50PRDR DIR DRILL BY ROTATION F/12,951' T/13,036'. 08/26/98. 00:00 - 03:00 3.00 DR q 50PRDR DIR DRILL BY ROTATION F/13,036' T/13,075'. 03:00 - 06:00 3.00 DR q 50PRDR DIR DRILL BY SLIDE F/13,075 T/13,089'. PUMP LOW/HIGH VIS SWEEP. 06:00 - 12:00 6.00 DR q 50PRDR DIR DRILL BY ROTATION.F/13,089 T/13,180' 12:00- 12:30 0.50 DR q 50PRDR ATTEMPTTO SLIDE. COULD NOT. 12:30 - 13:00 0.50 DR q 50PRDR DIR DRILL BY ROTATION F/13,180' T/13,186'. 13:00- 15:30 2.50 DR 5 !50PRDR CIRCULATE HOLE CLEAN. 15:30- 17:00 1.50 DR p 50PRDR BACKREAM F/13,186'T/11,761' (SHOE). 17:00 - 18:30 1.50 DR 5 50PRDR CIRCULATE WELL, CLEAN RIG FLOOR, PUMP DRY JOB. 18:30 - 00:00 5.50 DR 4 50PRDR POOH - BREAK OFF BIT. 08/27/98 !00:00 - 01:30 1.50 DR 2 50PRDR I MU BHA #23 (BHA name -- 8.5" Directional #7) and function test mud i motor / MWD. BHA length = 1048.88 ft 01:30 - 06:30 5.00 DR 4 50PRDR TIH (85 STDs) T/9,020' MD. Removed DP rubbers up to STD 103. DP rubber F/STD 103 T/STD 120 (644'). Cont. TIH T/shoe (11,761' MD). 06:30- 11:00 4.50 DR 4 50PRDR Ream/wash F/11,761'T/13,186' MD. Nofillon Bttm. 11:00 - 00:00 13.00 DR q 50PRDR Drill directionally - Rotating F/13,186' MD T/13,347' MD (161 ft). @ 13:00 Pumped Lw/Hi visc. sweep (13.0ppg @45visc./16.0ppg @ 100visc) - 50% increase in cuttings returns over shakers @21:00 Pumped Lw/Hi visc. sweep (13.0ppg @45visc./16.0ppg @ 100visc) - 25% increase in cuttings returns over shakers 08/28/98 00:00 - 10:30 10.50 DR q 50PRDR Dir. drill, rotating F/13,347' MD T/13,530' MD (183 ft). @08:30 Pumped Lw/Hi visc. sweep (12.5ppg @40visc./16.5ppg @95risc) - 25% increase in cuttings returns over shakers 10:30 - 12:00 1.50 DR z 50PRDR Short trip, back reaming F/13,530' T/13,186' - wash and ream to Bttm. No fill / No problems. !12:00 - 00:00 12.00 DR q 50PRDR Dir. drill, rotating F/13,530' MD T/13,651' MD (121 ft). @20:30 Pumped Lw/Hi visc. sweep (12.5ppg @40visc./16.5ppg @95risc) - 25% increase in cuttings returns over shakers 08/29/98 00:00 - 01:30 1.50 DR q 50PRDR Dir. drill, rotating F/13,651' MD T/13,675' MD (24 ft). 01:30 - 04:00 2.50 DR q 50PRDR Dir. drill, sliding F/13,675' MD T/13,684' MD (3 ft actual slide, remaining 6 ft DP compression). Printed: 11/04/98 6:42:37 AM PHILLIPS PETROLEUM CO Page 41 of 61 Operations Summa Report Legal Well Name: NORTH COOK INLET UNIT-B 000003 Common Well Name: North Cook Inlet Unit B-3 Spud Date: 05/03/98 Event Name: Original Drilling Start: 02/09/98 End: Contractor Name: Rig Release: Group: Rig Name: Rig Number: Date From- To -Iours Sub Co Phase Code Description of Operations 08/29/98 01:30 - 04:00 2.50 DR q 50PRDR Attempt to clean up slide area. Pipe stuck - appears to be at the string mill not the bit (motor was still tuming). Work pipe free after 20 min. with torque and stroking pipe. 04:00 - 12:30 8.50 DR q 50PRDR Dir. drill, rotating F/13,684' MD T/13,772' MD (88 ft). @08:30 Pumped Lw/Hi visc. sweep (12.5ppg @40visc./16.5ppg @95visc) - 50% increase in cuttings returns over shakers @ 10:30 Lost Pump #2 - washed out fluid end on cylinder No. 2. Start process of replacing fluid end while utilizing pump No. 1. 12:30 - 15:30 3.00 DR z 50PRDR Short trip, back reaming F/13,772' into shoe @ 11,761' MD - no problems. Cont. pulling DP T/10,616 to Swap out DP w/installed DP rubbers pipe (moved DP rubber pipe up 1128 ft - Rubbers @ Std 115 T/Std 132. Rubbers installed on 1692 ft of DP. DP rubbers 400' from surf, @ current TD). 15:30 - 16:30 1.00 RM 3 50PRDR Service rig & clean dg floor. 16:30 o 17:00 0.50 DR z 50PRDR TIH F/10,616' MD T/11,761' MD (Shoe). 17:00 - 19:30 2.50 DR z 50PRDR TIH, wash and ream F/11,761' (shoe) T/13,157'. - Lost pump No. 1 due tO washed out wear plate. BOTH PUMPS DOWN, NOT ABLE TO CIRCULATE. 19:30 - 21:00 1.50 DR 4 50PRDR TOOH, pulling pipe slowly F/13,157' T/11,761' (Shoe). 21:00 - 22:30 1.50 RM m 50PRDR Cut 96' drill line. Repair pump No.1 wear plate washout. Test pump No. 1 - still unable to hold pressure /leaking. 22:30 o 00:00 1.50 RM m 50PRDR Continue to work on replacing fluid end on pump No. 2. Trouble shoot pump No. 1 wear plate or gasket, etc. failure. 08/30/98 00:00 - 03:00 3.00 RM m 50PRDR Cont. to repair pump No. 1. Replace liner and wear plate gasket. :03:00 - 10:00 7.00 DR 4 50PRDR :TIH, wash / ream F/11,761' (Shoe) T/13,772' MD. (1)NOTE: Saw large increase in cuttings returns over shakers while wash / ream in hole - dollars size / thin coal with large amount of fines (2)NOTE: Worked tight spot while W/R IH @ coal Section 12,920' MD & 13,045' MD. Worked both sections tell clean. Saw no indications of hard fill on bttm. 10:00 - 11:00 1.00 DR 5 50PRDR Mixed & pumped Lw/Hi visc. sweep (12.5ppg @40visc./16.5ppg @95visc) while rotating / reciprocating pipe until sweep in casing - 75% increase in cuttings returns over shakers 11:00 - 00:00 13.00 DR q 50PRDR Dir. drill, rotating F/13,772' MD T/13,863' MD (91 ft). @ 14:30 Mixed & pumped Pumped Lw/Hi visc. sweep in attempt to increase drilling rate (12.5ppg @40visc./16.5ppg @ 95visc) while rotating/ reciprocating pipe until sweep in casing - little increase in cuttings returns over shakers. Saw no increase in ROP. 08/31/98 00:00 - 12:00 12.00 DR q 50PRDR Dir. drill, rotating F/13,863' MD T/13,995' MD (132 ft). 12:00 - 12:30 0.50 DR 5 50PRDR Circulate cuttings up into casing while rotating / reciprocating pipe in prep. for short trip. 12:30 - 13:30 1.00 DR z 50PRDR Short trip, back reaming F/13,995' T/13,772' (223' trip) - wash and ream to Bttm. No fill / No problems. 13:30 - 00:00 10.50 DR q 50PRDR Dir. drill, rotating F/13,995' MD T/14,067' MD (72 ft). Printed: 11/04/98 6:42:37 AM PHILLIPS PETROLEUM CO Page 42 of 61 Operations Summa Report Legal Well Name: NORTH COOK INLET UNIT-B 000003 Common Well Name: North Cook Inlet Unit B-3 Spud Date: 05/03/98 Event Name: Original Drilling Start: 02/09/98 End: Contractor Name: Rig Release: Group: !Rig Name: Rig Number: Date From - To Hours Sub Co Phase Code Description of Operations -- 08/31/98 13:30 - 00:00 10.50 DR q' 50PRDR @14:00 hrs Mixed & pumped Lw/Hi visc. sweep (12.5ppg @40visc./16.5ppg @95visc) while rotating / reciprocating pipe until sweep ~n casing - 100% increase in cuttings returns over shakers. Large increase ~n (large & small fragments) coal cuttings returns over shake~:s. @22:00 hrs Mixed & pumped Lw/Hi visc. sweep (12.5ppg @40visc./16.5ppg @95visc) while cont. to ddll - 25% increase in cuttings returns over shakers. 09/01/98 00:00 - 07:00 7.00 DR q 50PRDR Dir. drill, rotating F/14,067' MD T/14,130' MD (63 ft). 'Prep. to TOOH for BHA change, current BHA continues to build angle. NOTE: Pump #1 swab out @ 03:30 T/04:30. 07:00 - 09:30 2.50 DR 5 50PRDR Circ. / Mixed & pumped Lw/Hi visc. sweep (12.5ppg @40visc./16.Sppg @95visc) while rotating/reciprocating pipe - 50% increase in cuttings returns over shakers (increased amt of large to small coal cuttings). 09:30 - 00:00 14.50 DR 4 50PRDR TOOH, back reaming F/14,130' MD T/12,875' MD. Reaming thru coal section - very tight @ 13439', 13285'-264', 13159'-142', 13044'-032', 13014'-006', 13001'-12998', 12923'-919' MD. Lost Top Drive (due to SCR panel fuse / card blown) after standing back Std # 127. Unable to kelly up to circulate or rotate. POOH F/12,875' T/12,308' slowly - pulled smoothly. Repaired top drive SCR - online after 1 Hr (pulled pipe w/o Top drive, Std 126 - 120). Trip Summary as follows: Std 140-134 (14130'-13535'=1 Hr)smooth Std 133 (13535'-441'=2.5Hr)very tight Std 132 (13441 '-348'=2Hr)tight Std 131 (13348'-253'=1 Hr)tight Std 130 (13253'-158'=2.5Hr)very tight Std 129 (13158'-063'=0.5Hr)smooth Std 128 (13063'-12969'=2.5Hr)tight Std 127 (12969'-875'=1'Hr)tight Std 126-120(12875'-308'=1 Hr)POOH smooth - Top Drive down. 09/02/98 00:00 - 01:00 1.00 DR 4 50PRDR Cont. TOOH (Top Drive back on'line), back reaming F/12,308' MD T/11,761' MD (Shoe). Trip Summary as follows: Std 120-115 (12308'-11761 '=1 Hr)smooth 01:00 - 02:00 1.00 DR 5 50PRDR Circ. bttms-up and clean returns. Saw Large amt of coal cuttings (dollar size and smaller) returns across shakers. Circ. tell cleaned up - 8200 Stks / BU @ 6300 Stks. Pumped dry job. 02:00 - 08:00 6.00 DR 4 50PRDR TOOH F/shoe T/BHA. L/D BHA. String mill was wom but not bad / in gage. 08:00 - 11:00 3.00 WC 8 50PRDR ' Pull wear bushing / set test plug. Test BOPE as follows: Annular 250#/3000# Choke - HCR/Manual & Kill - HCR/Manual / manifold & floor valves 250#/5000#. Top/Bttm/Blind Rams 250#/5000# IBOP / Kelly valve 250#/5000# Printed: 11/04/98 6:42:37 AM PHILLIPS PETROLEUM CO Page 43 of 61 Operations Summa Report Legal Well Name: NORTH COOK INLET UNIT-B 000003 Common Well Name: North Cook Inlet Unit B-3 Spud Date: 05/03/98 ~Event Name: Original Drilling Start: 02/09/98 End: ,Contractor Name: Rig Release: Group: Rig Name: Rig Number: Date From - To Hours Sub Co Phase Code Description of Operations 09/02/98 08:00 - 11:00 3.00 wc 8 50PRDR Pull test plug .set wear bushing. Drain stack. Re-aline choke. 11:00 - 13:00 2.00 RM 3 50PRDR Service top drive, drawworks, Etc. 13:00 - 14:00 1.00 DR 2 50PRDR M/U BHA, gage equipment, test MWD, and orient Mtr. 14:00 - 15:30 1.50 RM 3 50PRDR Clean oil base mud off dg floor & walkway. 15:30 - 00:00 8.50 DR !4 50PRDR TIH T/9121' MD, recording upwt., dnwt.,rotwt,torq., every 10 stds. TIH, installing DP rubbers as follows bttm t/top(depth @ TD of 14130'): BHA = 1055.99' (@14,130') Stds 1-29 (13,074'- 10,356') Slick $tds 30-49 (10,356' - 8,477') I rubber/jJt Stds 50-64 (8,477' - 7,078') Slick Stds 65-86 (7,078' - 5,009') I rubber/jt NOTE: BTTM DP RUBBER 15 STS ABOVE SHOE @ PRESENT TD. 09/03/98 00:00 - 08:30 8.50 DR 4 50PRDR Cont. TIH F/9121' MD T/11,761' MD, recording conn. data every 10 Stds. TIH, installed DP rubbers and re-arranged previously installed DP rubbers @ shoe by TOOH 14 Stds/standing back off driller side. TIH re-arranging rubbers 14 Stds driller side / standing back 8 stands.off driller side. TIH re-arranging rubbers 8 Stds remaining on driller side. (NOTE: This allowed the installation of DP rubbers without having to install rubbers while W/R to Bttm) !Installed remaining DP rubbers as follows bttm T/top (depth @ TD of 14130'): $tds 87-101 (5009'- 3600') Slick $tds 102-136 (3600' - 288') 2 rubbers/it Total DP rubbers in hole = 336 Total collars = 672 Total Std/by DP rubbers = 89 Total Std/by collars = 192 08:30- 09:00 0.50 RM m 50PRDR Re-set drawworks selector / SCR. 09:00 - 21:30 12.50 DR 4 50PRDR TIH, washing / reaming F/11,761' MD T/14,130' MD. Washed smooth tell 12,470' MD - Top Drive stalled out. Worked pipe out of tight spot. Pulled 320K (Upwt = 290K), would not pull free. Pulled to 350K (Upwt = 290K), activated jars on up stroke pipe came free on one hit. Washed smooth very slowly - hole attempting to pack off. Wash T/12,728' & 13,434' MD - very tight - worked areas. Drag TIH has increase F/15K once rubbers installed up to 30K @ 14,130' MD. No weight on bit, constant 600 amp torq. 21:30 - 00:00 2.50 DR 5 50PRDR Circ. 3200 Stks (bttm up 2000' in csg) while rot. / recp. DP. Mixed / pumped Lw/Hi visc. sweep (12.5ppg @40visc./16.5ppg @ 95visc) while rotating / reciprocating pipe - 25% increase in cuttings returns over shakers. 09/04/98 00:00 - 08:30 8.50 DR q 50PRDR Engaged Adj. Stab (8 1/2" Press. losses @400GPM = 400#). Dir. drill, rotating F/14,130' MD T/14,278' MD (148 ft). Off-Bttm Press.=3650# @ 400GPM , , 'Printed: 11/04/98 6:42:37 AM PHILLIPS PETROLEUM CO Page 44 of 61 Operations Summa Report Legal Well Name: · NORTH COOK INLET UNIT-B 000003 Common Well Name: North Cook Inlet Unit B-3 Spud Date: 05/03/98 Event Name: Original Drilling Start: 02/09/98 End: Contractor Name: Rig Release: Group: Rig Name: Rig Number: Date From.- To Hours Sub Co :~hase Code Description of Operations 09/04/98 00:00- 08:30 8.50 DR q 50PRDR On-Bttm Press.=3900# @ 400GPM @08:00 Mixed & pumped Lw/Hi visc. sweep (12.5ppg @40visc./16.5ppg @ 95visc) while rotating / reciprocating pipe - 25% increase in cuttings returns over shakers. 08:30 - 09:30 1.00 DR z 50PRDR Dis-engage Adj. Stab. (7 3/4" Press. losses @400GPM = 175#). Orient Anadrill tool face. 09:30 - 12:30 3.00 DR q 50PRDR I Dir. Drill, sliding F/14,278' MD T/14,285' MD (7 ft). NOTE: Difficult to maintain wt. on bit due to drag. Would establish diff. press., then drill off. Could not get wt back on bit without picking up and re-establishing. Once established diff. would drill off and repeat process. 12:30 - 00:00 11.50 DR q 50PRDR Engaged adj. stab (8 1/2"). Dir. drill, rotating F/14,285' MD T/14,462' MD (177 ft). @ 16:00 Mixed & pumped Lw/Hi visc. sweep (12.5ppg @40visc./16.5ppg @95visc) while rotating / reciprocating pipe - 25% increase in cuttings returns over shakers. 09/05/98 00:00 - 01:30 1.50 DR 5 50PRDR Dis-engage adj. stab (7 3/4"). Mixed & pumped Lw/Hi visc. sweep (12.5ppg @40viscJ16.5ppg @95visc) while rotating / reciprocating pipe (6500 stks up into csg) - small increase in cuttings returns over shakers. 01:30 - 03:00 1.50 DR p 50PRDR Short trip, backreaming F/14,462' MD T/14,130' MD - Wash/ream T/14,462' Bttm (Smooth). 03:00 - 23:00 20.00 DR q 50PRDR Engage adj. stab. (8 1/2"). Dir. drill, rotating F/14,462' MD T/14,750' MD (288 ft). @ 06:00 Mixed & pumped Lw/Hi visc. sweep (12.5ppg @ 40visc./16.5ppg @95visc) while cont. drilling - 25% increase in cuttings returns over shakers. @ 15:00hrs Mixed & pumped Lw/Hi visc. sweep (12.5ppg @40visc./16.5ppg @ 95visc) while cont. drilling - 25% increase in cuttings returns over shakers. 23:00 - 00:00 1.00. DR z 50PRDR Dis-engage adj. stab. (7 3/4). Circ. while rot. / recp. pipe. Prep. to mix and pump Hi/Lo sweep. 09/06/98 00:00 - 03:00 3.00 DR 5 50PRDR Mix & pumped Lw/Hi visc. sweep (12.5ppg @40visc./16.5ppg @95risc) while rotating / reciprocating pipe (6500 stks up into csg) - 25% increase in cuttings returns over shakers. Once sweep up circ. 2 additional BU. NOTE: 1/2 gal bucket of DP rubber chunks coming over shakers and cont.. 03:00 - 13:00 10.00 DR 4 50PRDR TOOH, back reaming F/14,750' T/11,761' (pulled / pumping T/11,714'). Pulled relatively smooth T/12,940'. Pulled exstremely tight F/12,940' T/12,820' & pulled to shoe smooth there after. 13:00 - 14:00 1.00 RM 3 50PRDR Service rig & cean floor. 14:00 - 15:00 1.00 DR 4 50PRDR ^ttempt T/ wash below casing shoe T/11790' MD. Hole packed-off/std. pipe holding press. @ 2000# / Iossing returns. Pipe rotates free but unable to move pipe down hole. Shut down pump with 15 BBI loss. Work pipe up to csg shoe. Pipe rotating free. Worked Printed: 11/04/98 6:42:37 AM PHILLIPS PETROLEUM CO Page 45 of 61 Operations Summa Report Legal Well Name: NORTH COOK INLET UNIT-B 000003 Common Well Name: North Cook Inlet Unit B-3 Spud Date: 05/03/98 Event Name: Original Drilling Start: 02/09/98 End: Contractor Name: Rig Release: Group: Rig Name: Rig Number: Date From - To Hours Sub Co Phase Code Description of Operations 09/06/98 14:00 - 15:00 1.00 DR 4 50PRDR pipe down to 11,785' to break connection. Bleed press off / brake conn. / stand back 1 std. Pulled up pipe to 11730'. Pipe continues to move free. Rotate back down T/ 11790' without pump. Pulled back to 11730'. Established pumps @ 35 SPM, attempt to break cim.. Press. up to 2000# w/no returns. Bleed press. off. 15:00 - 17:00 2.00 DR 4 50PRDR Cont. T/TOOH w/6 Stds DP T/11,511'. Removing DP rubbers. Hole swabbed for 6 Stds / keeping DP full as TOOH. Hole stopped swabbing and began filling hole w/trip tank. After swabbing stopped, drag increased F/290K T/350K (NOTE: Up Wt TIH = 265K @ same depth). 17:00 - 00:00 7.00 DR 4 50PRDR Cont. TOOH F/11,511' T/7238' ((Thru Std 67). NOTE: Drag dropped off F/315UpWt T/260DnWt @ 9682'. Drag cont. to flux, coming out of hole but pulling easier F/9682' on. Std 136-102 (210 rub. & 420 clps) All recovered Std 86-65 (66 rub. & 132 clps) All recovered. 09/07/98 00:00 - 07:30 7.50 DR 4 50PRDR Cont. TOOH F/7238' (Std 67) T/BHA. Drag cont. to flux. TOOH. Lost 35 DP rubbers & 1 1/2 clamps as follows: Began seeing wear on Std 47 @ GIH=8725',TOOH=9345'(spiral cut on clps/Rub bent up @ top). -Missing mid. jt. Top clp & rub Std 44 @ GIH=9002',TOOH=9622' -Missing bttm. jt. rub Std 40 @GIH=9408',TOOH=10028' w/1/2 clp missing -Missing all remaining rub. w/clps pushed to the above ti jt & very worn. Std 39(GIH=9439',TOOH=10059') thru 30(GIH=10356',TOOH=10976') (NOTE: Have recovered on shakers/flowline/apollo/BHA some additional +/- 6 1/4 rubbers & 1/2 clamps stuck on string mill). Est. 29 3/4 rubbers & 1 I clamp left in hole) (NOTE: Clamp on drill pipe pulled wear bushing out of 9 5/8" bowl to surf. on Std 3). 07:30 - 09:30 2.00 DR 14 50PRDR Attempting to pull BHA thru 9 5/8" csg head / BOPE. DP rubbers packed off around BHA / pulling very slowly w/excess drag. Lay down BHA. DP rubbers stacked up at wellhead. 09:30 - 12:00 2.50 DR z 50PRDR Clean up rig floor to rig up to reverse circ. DP rubbers out of, csg head & BOPE by tieing into 9 5/8" csg hd valve. Circ. mud thru BOPE. Recovered only small lose chunks. Pick-up 1 std GIH to hanger, attempt to free more - little success. 12:00 - 12:30 0.50 RM 3 50PRDR clean rig floor & tool of oil base mud. 12:30 - 13:30 1.00 DR z 50PRDR Run and set wear bushing. 13:30 - 14:30 1.00 DR 2 50PRDR Make up clean-out BHA & GIH as follows: Printed: 11/04/98 6:42:37 AM ,, PHILLIPS PETROLEUM CO Page 46 of 61 Operations Summa Report Legal Well Name: NORTH COOK INLET UNIT-B 000003 Common Well Name: North Cook Inlet Unit B-3 Spud Date: 05/03/98 Event Name: Original Drilling Start: 02/09/98 End: Contractor Name: Rig Release: Group: Rig Name: Rig Number: Date From- To Hours Sub Co Phase Code Description of Operations 09/07/98 13:30 - 14:30 1.00 DR 2 50PRDR 8 1/2" Mill toothed (#9 RR MFD SSH) 1.00'/1.00' 8 7/16" NB Stab. 4.83'/5.83' X-Over 0.86'/6.69' 6 1/4" Spiral Steel DC 30.93'/37,62' X-over 0.89'/38.51' X-over 1.16'/39.67' 17 3/4" lBS NM Stab, 6.06'/45.73' X-Over 1.60'/47.33' ; 18 HWDP 543.34'/590.67' i Hydraulic Jars 32.38'/623.05' ' 11 HWDP 331.90'/954.95' 14:30 - 16:00 1.50 DR 4 50PRDR TIH w/BHA & 1 Std HWDP. Tagged DP Rubbers @ 197'/take wt = ~ 10000#. Push rubbers T/1143' wt=15000#, would not push. 16:00 - 17:30 1.50 DR 4 50PRDR W/R F/1143' T/1143'. Flow line plugged w/rubbers, Lift up boot on flowline & repair auger. 17:30 - 18:00 0.50 DR 4 50PRDR W/R F/1143', Turn pumps on - flowline plugged off. 18:00 - 19:30 1.50 DR z 50PRDR Attempting to unplug rubbers in flowline to mud pits, Flowline under rotary plugged. 19:30 - 23:00 3.50 DR 4 50PRDR TOOH F/1143'. Unplug flowline under rotary disassemble flowline to remove DP rubbers. 23:00 - 00:00 1.00 DR z 50PRDR Put flowline together. Recovered an additional 5 1/2 rubbers, leaving an estimated 24 & 1 clamp. Recover mostly the outer rubber and some fragments of the rubber cage. 09/08/98 00:00 - 02:00 2.00 DR z 50PRDR Finish putting flowlines back together. Circ. thru BOPE to ensure flowlines are clean. 02:00 - 04:30 2.50 DR 2 150PRDR Make Up junk mill BHA as follow: 8 3/8" Junk Mill 2.98'/2.98' 8 7/16 NB Stab. 4.83'/7.81' X-Over 0.86'/8.67' Steel Spiral DC 30.93'/39.60' X-Over 0.89'/40.49' X-Over 1.1 6'/41.65' ,, 7 3/4 lBS NM Stab 6.06'/47.71' X-Over 1.60'/49.31' 6' HWDP 181.08'/230.39' Jars 32.38'/262.77' 23 HWDP 694.16'/956.93' TIH, wash/reaming. Tag up on obstruction @ 1061' (sat dwn 10,000#,press. jumped up 200#, and torq. flux). Wt./Torq./Press. burned off. Cont. W/R to 1325'. Saw no futher signs of obstruction. 04:30 - 13:00 8.50 DR 4 50PRDR TIH, without W/R, filling pipe every 3000' ft T/shoe @ 11,761' MD (no signs of obstruction). 13:00 - 00:00 11.00 DR 4 50PRDR Cont. TIH, W/R F/11,761' T/12,718'. Worked thru tight area T/12,740'. W/R F/12,740' T/13,480' (very tight & stalled out F/13,480' T/13,658'). Wash & ream thru tight areas several times. Wash & ream F/13,658' T/14,382' (450GPM/95 RPM). May be washing / pushing junk to bttm. NOTE: Recovered 1 additional rubber across shaker leaving know 23 DP rub. & 1 clamp still in the hole. 09/09/98 00:00 - 03:00 3.00 DR p 50PRDR WASH & REAM (PUSHING JUNK DOWNHOLE) FROM 14,382FT TO Printed: 11/04/98 6:42:37 AM PHILLIPS PETROLEUM CO Page 47 of 61 Operations Summa Report Legal Well Name: NORTH COOK INLET UNIT-B 000003 Common Well Name: North Cook Inlet Unit B-3 Spud Date: 05/03/98 Event Name: Original Drilling Start: 02/09/98 End: Contractor Name: Rig Release: Group: Rig Name: Rig Number: Date From - To Hours Sub Co 3hase Code Description of Operations 09/09/98 00:00- 03:00 3.00 DR p 50PRDR 14,750FT. 03:00 - 06:00 3.00 DR h 50PRDR MILL ON JUNK ON BOTTOM. DRILL 5FT OF FORMATION FROM 14,750FT TO 14,755FT 06:00 - 09:30 3.50 DR 5 50PRDR PUMP 10BBL DIESEL FOLLOWED BY 40BBL LO-VIS AND 40BBL HI-VIS SWEEP. ClRC & COND PRIOR TO POOH 09:30 - 14:00 4.50 DR p 50PRDR BACKREAM FROM 14,755FT TO SHOE @ 11,761FT. (100+ RPM, 450GPM, UP VVT. 280K, DOWN WT. 275K) 14:00 - 15:30 1.50 DR z 50PRDR CLEAN RIG FLOOR. MIX SLUG 15:30 - 21:00 5.50 DR 4 50PRDR PUMP SLUG. PULL CCH (NOTE · @ 10,200FT, DRAG IN CASING INCREASED BY 25K - PROBABLY DRAGGING JUNK UP HOLE). 21:00 - 22:30 1.50 DR 4 50PRDR CONT. POOH, LAYING DOWN IO JTS HWDP WHICH REQUIRE HARD BANDING 22:30. - 00:00 1.50 DR 2 50PRDR L/D BHA. 09/10/98 !00:00 - 04:00 4.00 WC 8 50PRDR CLEAN RIG FLOOR. REMOVE WEAR BUSHING. INSTALL TEST PLUG. TEST HYDRIL 250/2500PSI. TEST RAMS, CHOKE/KILL, ACCUMULATOR, IBOP 250/5000PSI. PULL TEST PLUG. INSTALL WEAR BUSHING. 04:00 - 08:30 4.50= DR 2 50PRDR P/U BHA.(MOTOR HAS 8.3/8" STAB SLEEVE). FUNCTION TEST MWD. 08:30 - 09:30 1.00 RM 3 50PRDR SERVICE RIG. 09:30 - 15:00 5.50 DR 4 50PRDR Rill, FILLING PIPE EVERY 30 STDS, TO SHOE @ 11,761FT. RECORD WT & TORQUE. 15:00 - 15:30 0.50 DR p 50PRDR WASH & REAM FROM' 11,761FT TO 12,042FT. IBOP VALVE LEAKING. WASH & REAM BACK UP TO SHOE. 15:30 - 22:30 7.00 RM m 50PRDR REPAIR IBOP VALVE. REPLACE RUBBERS IN MUD PIT VALVES (DETERIORTED DUE TO OBM). TRANSFER MUD FROM PLATFORM PITS TO RIG PITS. 22:30 - 00:00 1.50 DR p 50PRDR WASH & REAM TO 12,224FT ( WORKED STAND THROUGH TIGHT SPOT @ 12,168FT). 09/11/98 00:00 - 01:00 1.00 DR p 50PRDR WASH & REAM FROM 12,224FT TO 12,511FT 01:00 - 03:00 2.00 we 7 50PRDR BACKREAM FROM 12,511FT TO 12,134FT WHILE WAITING ON PRODUCTION (UNABLE TO START RIG TURBINES DUE TO LOW GAS SUPPLY). : 03:00 - 14:00 11.00 DR p 50PRDR WASH & REAM FROM 12,134FT TO 14,750FT (SEVERAL TIGHT SPOTS) 14:00 - 15:00 1.00 DR d 50PRDR WASH ON BOTTOM TO REMOVE ANY JUNK (NO EVIDENCE OF FILL). DRILL TO 14,762FT. 15:00- 00:00 9.00 DR ,q 50PRDR SETANDERGAUGE. DRILL FROM 14,762FTTO 14,885FT. 09/12/98 00:00- 14:00 14.00 DR q 50PRDR DRILL FROM 14,885FTTO 15,039FT. 14:00- 17:00 3.00 DR p 50PRDR RETRACTANDERGAUGE STABILISER. BACKREAM FROM 15,039FT TO 14,650FT. WASH & REAM BACK TO BTM. 17:00 - 00:00 7.00 DR q 50PRDR PUMP LO-VIS/HI-VIS SWEEP. DRILL FROM 15,039FTTO.15,100FT. 09/13/98 00:00- 17:00 17.00 DR q 50PRDR DRILL (ROTATE) FROM 15,100FTTO 15,305FT. 17:00 - 21:00 4.00 DR 5 50PRDR PUMP LO-VIS/HI-VIS SWEEP & ClRC BTMS UP x 2. 21:00- 00:00 3.00 DR p 50PRDR BACKREAM FROM 15,305FT. TIGHT @ 14,687FT. PICK UP 1 STD AND WORK PIPE, INCREASING ROTARY SPEED TO 100RPM 09/14/98 00:00 - 03:00 3.00 DR 5 50PRDR CENT. TO WORK PIPE & CIRC. FOR 30 MINS. BACKREAM - STILL TIGHT @ 14,687FT. PICK UP 1 STAND, RIH & CIRC BTMS UP x 1.5. 03:00 - 17:30 14.50 DR p 50PRDR BACKREAMED THROUGH TIGHT SPOT. HOLE STICKING FROM 14,666FT TO 14,200FT. TIGHT SPOTS @ 14,350', 14,340', 14,332', 14,312', 14,277', 14,247', 14,228', 14,215' & 14,200FT. 17:30- 19:30 2.00 DR p 50PRDR PIPE STUCK @ 14,200FT. WORKED PIPE FREE BY JARRING DOWN. 19:30- 21:30 2.00 DR p 50PRDR PICK UP 1 STD. REAM IN HOLE TO 14,349FT. Printed: 11/04/98 6:42:37 AM PHILLIPS PETROLEUM CO Page 48 of 61 Operations Summa Report Legal Well Name: NORTH COOK INLET UNIT-B 000003 Common Well Name: North Cook Inlet Unit B-3 Spud Date: 05/03/98 Event Name: Original Drilling Start: 02/09/98 End: Contractor Name: Rig Release: Group: Rig Name: Rig Number: Date From - To Hours Sub Co Phase Code Description of Operations 09/14/98 21:30- 00:00 2.50 DR 5 50PRDR PUMP LO-VIS/HI-VIS SWEEP. ClRC BTMS UP x 2. A FEW FLAT PIECES OF COAL (2" x 3") RETURNED 09/15/98 00:00 - 00:30 0.50 DR 5 50PRDR CeNT TO CIRCULATE OUT SWEEP. 00:30 - 12:00 11.50 DR p 50PRDR BACKREAM FROM 14,349FT TO 13,950FT. TIGHT @ 13,950FT. 12:00 - 14:30 2.50 DR p 50PRDR ATTEMPT TO WORK THROUGH TIGHT SPOT BUT LOSING HOLE - BIT @ 13,954FT. 14:30 - 17:30 3.00 DR 5 50PRDR PICK UP 1 STD & REAM IN HOLE TO 14,067FT. PUMP LO-VIS/HI-VIS SWEEP AND CIRCULATE. 17:30- 00:00 6.50 DR p 50PRDR BACKREAM FROM 14,067FTTO 13,690FT (PULLING FASTER ABOVE 13,800FT). TIGHT SPOTS @ 13,927', 13,898' AND 13,808'. 09/16/98 00:00 - 02:30 2.50 DR p 50PRDR BACKREAM FROM 13,690FT TO 13,420FT (TIGHT @ 13,420FT). PICK UP 1 STD AND REAM IN HOLE TO 13,544FT (TIGHT @ 13,451FT). LARGE QUANTITY OF COAL COMING OVER SHAKERS. 02:30 - 06:00 3.50 DR 5 50PRDR PUMP LO-VIS/HI-VIS SWEEP AND ClRC BTMS UP xl.5. MORE COAL RETURNED WITH SWEEP. 06:00 - 21:30 15.50 DR p 50PRDR BACKREAM FROM 13,544FT TO 11,761FT (TIGHT SPOTS @ 12,992', 12,823', 12,492' & 12,184'). PUMP SWEEP. 21:30 - 00:00 2.50 DR 5 50PRDR CIRCULATE SWEEP. CLEAN RIG FLOOR. REPLACE JAM NUTS ON DRAWWORKS BRAKE. 09/17/98 00:00 - 01:00 1.00 RM c 50PRRC SLIP & CUT DRL LINE WHILE ClRC SWEEP AT SHOE. 01:00 - 08:00 7.00 DR 4 50PRRC PUMP SLUG. POOH FROM 11,761FT. L/D DIRECTIONAL BHA. CLEAN RIG FLOOR. 08:00 - 11:00 3.00 WC 8 50PRRC PULL WEAR BUSHING. INSTALL TEST PLUG. TEST BOPE:- CHOKE MANIFOLD 250/5000PSI, HYDRIL 250/2500PSI, RAMS, HYD CHOKE & KILL, MAN CHOKE & KILL, TD VALVES, IBOP, & FLOOR VALVES 250/5000PSI. PULL TEST PLUG & INSTALL WEAR BUSHING. 11:00 - 12:00 1.00 RM 13 50PRRC REMOVE IRON ROUGHNECK TRACK & PULL MASTER BUSHINGS. INSTALL SCREEN IN TRIP TANK FLOW LINE. 12:00- 14:30 2.50 DR '2 50PRRC P/U CLEAN-OUT BHA. 14:30 - 20:00 5.50: DR 4 50PRRC RIH TO SHOE @ 11,761FT 20:00- 20:30 0.50~ RM 3 50PRRC SERVICETD 20:30 - 00:00 3.50' DR p 50PRRC WASH & REAM TO 12,655FT 09/18/98 00:00 - 09:00 9.00 DR d 50PRDR WASH & REAM IN HOLE FROM 12,655FTTO 15,305FT. 09:00 - 12:30 3.50 DR 5 50PRDR ' MIX & PUMP LO-VIS/HI-VIS SWEEP & CIRC. CHANGE SWAB #2 PUMP. 12:30- 20:30 8.00 DR p 50PRDR BACKREAM FROM 15,305FTTO SHOE @ 11,761FT.- 20:30 - 00:00 3.50 DR 5 50PRDR MIX & PUMP LO-VIS/HI-VIS SWEEP & CIRC BTMS UP. MIX & PUMP SLUG PRIOR TO POOH. 09/19/98 00:00 - 04:30 4.50 DR 4 3512DR POOH WITH CLEAN-OUT ASSY & L/D BHA. 04:30 - 09:30 5.00 WC 1 3512DR INSTALL 7" UPPER PIPE RAMS & TEST TO 250/8000PS1. PULL TEST PLUG & INSTALL WEAR BUSHING. ' ' 09:30 - 12:00 2.50 CS 6 3512RC M/U CMT HEAD. 12:00 - 20:00 8.00 CS 1 3512RC HOLD PRE-JOB SAFETY MTG. RUN 7" CSG 20:00 - 22:30 2.50 CS 1 3512RC M/U HGR ASSY & RIH. RUN I STD OF HWDP. R/D WEATHERFORD CSG TONGS. 22:30 - 23:30 1.00 CS 5 3512RC RUN LNR BELOW BOP STACK & ClRC CSG VOLUME @ 3,853FT. 23:30 - 00:00 0.50 CS 1 3512RC CONT RIH w/HWDP 09/20/98 00:00 - 07:30 7.50 CS 1 :3512RC RIH w/LINER TO 9.5/8" SHOE (11,761FT) FILLING DP EVERY 10 STDS WITH FILL-UP HOSE. 07:30 - 08:30 1.00 CS 5 3512RC BREAK ClRC & BEGIN TO PUMP CSG + LANDING STRING VOL x1.5 08:30 - 10:30 2.00 CS 5 3512RC PUMP PRESSURE INCREASED. BLEED OFF PRESSURE. PUMP OUT & CLEAN PIECES OF DP RUBBER FROM TRIP TANK 10:30 - 12:30 2.00 CS z 3512RC PULL OOH FROM 11,761FTTO 11,109FT. HOLE SWABBING. 12:30 - 20:00 7.50 CS z 3512RC PUMP OOH FROM 11,109FT TO 8,565FT. Printed: 11/04/98 6:42:37 AM PHILLIPS PETROLEUM CO Page 49 of 61 Operations Summa Report Legal Well Name: NORTH COOK INLET UNIT-B 000003 Common Well Name: North Cook Inlet Unit B-3 Spud Date: 05/03/98 ,Event Name: Original Drilling Start: 02/09/98 End: Contractor Name: Rig Release: Group: Rig Name: Rig Number: Date From- To Hours Sub Co Phase Code Description of Operations 09/20/98 20:00 - 00:00 4.00 CS z 3512RC CSG STUCK & 8,565FT. TAKE 80K OVERPULL - UNABLE TO MOVE PIPE. INCREASE PUMP PRESSURE TO 500PSI - UNABLE TO CIRCULATE. PREPARE TO BACK OFF LANDING STRING (TeL @ 4,799FT). 09/21/98 00:00 - 04:30 4.50 CS z 3512RC 'U' OUT OF PACKER WITH SETTING TOOL. 04:30 - 07:00 2.50 CS z 3512RC PUMP SLUG. POOH FROM 4,802' WITH DP. 07:00 - 07:30 0.50 CS z 3512RC L/D PACKER SE'I-rING TOOL (WIPER PLUG RETRIEVED). 07:30 - 12:00 4.50 RM 3 3512RC CHANGE SWIVEL PKG. CLEAN RIG FLOOR. 12:00 - 15:00 3.00 CS z 3512RC M/U CLEAN-OUT MILL ASSY & RIH. TAG FISH @ 4,802FT MD. 15:00- 17:00 2.00 CS z 3512RC ClRC @ 4,801FT. 17:00 - 21:30 4.50 CS z 3512RC POOH w/BHA. CLEAN RIG FLOOR. 21:30 - 00:00 2.50 FI 2 3512RC M/U PACK-OFF/SPEAR FISHING BHA. 09/22/98 00:00 - 01:30 1.50. FI 2 3512RC P/U FISHING BHA (SPEAR & PACK-OFF). 01:30 - 03:30 2.00 FI 4 3512RC RIH TO 4,792FT 03:30 - 04:30 1.00 FI 15 3512RC ClRC BTMS UP. TAKE UP WT (140K LB) & DOWN WT (125K LB) 04:30 - 08:30 4.00 FI ;a 3512RC LATCH SPEAR BELOW LHR HGR. JAR UP (275K - 450K OVERPULL). 08:30 - 09:00 0.50 FI z 3512RC APPLY 1800PSI ON ANNULUS THEN APPLY 1100PSI ON DP TO SIMULATE SETTING HGR. 'J' SPEAR OUT OF CSG. 09:00 - 10:30 1.50 FI 5 3512RC ClRC ABOVE FISH. 10:30 - 13:30 3.00 FI 4 3512RC PUMP SLUG & POOH. L/D FISHING SPEAR ASSY. 13:30 - 14:00 0.50 FI 2 3512RC P/U CUTTER ASSY. 14:00- 18:00 4.00 FI 4 3512RC RIH TO TOP OF FISH @ 4,802FT. ATTEMPTTO SETCUTTER IN PBR @ 4,832FT. NO INDICATION THAT BTM SLIPS HAD SET BUT INCREASE IN TORQUE INDICATED CUT. 18:00 - 20:30 2.50 FI 4 3512RC TRIP OOH WET. CLEAN RIG FLOOR & L/D CUTTER. SOME BLUNTING OF KNIFE EDGES - ONLY 1 KNIFE WITH MARKS INDICATING A DEEPER CUT. 20:30 - 22:30 2.00 FI 2 3512RC P/U SPEAR & PACK-OFF ASSY 22:30 - 00:00 1.50 FI 4 3512RC RIH 09/23/98 00:00 - 00:30 0.50 FI 4 3512RC Cont. TIH w/spear BHA. Tag fish @ 4804' MD. 00:30 - 01:00 0.50 FI 5 3512RC Circ. BU above fish. 01:00 - 03:00 2.00 FI a '3512RC Stab into fish w/1 left hand rap at slack wt. and confirmed stab. Activated jars, jarring up @ 290K (String wt ~- 130K). Straight pulled on fish up to 450K without activating jars. Repeated jarring and straight pulling several times. No success on freeing fish. 03:00 - 05:00 2.00 FI 4 3512RC Released spear by I right hand rap at slack wt. TOOH to BHA. 05:00 - 06:00 1.00 RM c 3512RC Cut ddll line. 06:00 - 07:30 1.50 FI 2 3512RC Lay down spear BHA. 07:30 - 09:00 1.50 we u 3512RC Wait on fishing tools - Clean / service rig. 09:00 - 09:30 0.50 FI 2 3512RC Picked up Mill BHA as follows: · . Mill 6 1/4"x8 3/8"x3" 4.60' Bumper Sub 6 1/4"x3 1/8" 9.05' Oil Jar 6 1/4"x2 1/4" 11.58' X-O 6 1/8"x3" 1.20" 9 D.C. 6 1/4"x2 7/8" 276.53" X-O 6 1/8"x2 7/8" 1.44" TOTAL 304.40" 109:30 - 12:00 2.50 FI 4 3512RC TIH, tagged top of fish at 4804' MD. :12:00-17:00 5.00 FI h 3512RC Milled on 7" liner packer F/. 4804' T/4823' (19'). Maxwt=25K, Rot=120 :RPM, Torq fluxed F/200 amps T/800 amps, press. = 2175#, Rate = 635 GPM. Printed: 11/04/98 6:42:37 AM PHILLIPS PETROLEUM CO Page 50 of 61 Operations Summa Report Legal Well Name: · NORTH COOK INLET UNIT-B 000003 Common Well Name: North Cook Inlet Unit B-3 Spud Date: 05/03/98 Event Name: Original Drilling Start: 02/09/98 End: Contractor Name: Rig Release: Group: Rig Name: Rig Number: Date From - To Hours Sub Co Phase! Code Description of Operations 09/23/98 12:00- 17:00 5.00 FI h 3512RC Wt on bit dropped off at 4823' MD, then picked up 2K T/3K at 4842' MD (19 ft). NOTE: Recovered 2 plus bbls of metal shavings over the shakers. 17:00- 19:30 2.50 FI 5 3512RC Circ. hole clean @ 860 GPM/1900#. Mixed/pumped Lw/Hivisc. sweep. Saw some increase in returns. 19:30 - 22:30 3.00 FI 14 3512RC TOOH F/4842' T/BHA. L/D Mill BHA. Recovered three pieces suspected to be off of the liner packer. 1st piece = 1 Off half milled out 2nd piece = 2ft chewed up and bent 3rd piece = lft chewed up and bent (appeared to have packer slip slots on the top) Recovered also 1 milled up packer slip. 22:30 - 00:00 1.50 FI 2 3512RC Picked up fishing bull nosed spear as follows: Bull Nose 4 3/4"x2 1/4" 0.57' Spear 5 3/4"x2 1/4" 3.45' Stop Sub 6 1/8"x7 13/16"x2 15/16" 1.17' Bumper Sub 6 1/4"x3 1/8" 9.05' Oil Jar 6 1/4"x2 1/4" 11.58" X-O 6 1/8"x3" 1.20' 9 DC 6 1/4"x2 7/8" 276.53' X-O 6 1/8"x 2 7/8" 1.44' Acc. Jar 6 1/4"x2 1/4" 12.99' Total 317.98' NOTE: Added shear pin to spear. Will help keep light wt fish from slipping the grapple.POOH due to hole drag. 09/24/98 00:00 - 02:30 2.50 FI 4 3512RC TIH w/spear fishing BHA. Saw no indication of fish @ 4842' MD. Cont. TIH slowly T/5431' MD. 02:30 - 03:00 0.50 FI 5 3512RC Break circulation @ 5431' MD. 03:00 - 04:00 1.00 FI 4 3512RC Cont. TIH slowly T/5886' MD, tagged fish at same slacked off 20K and repeated to confirm to spear into fish. Picked up no additional weight. Suspected spear set in cut PBR segment. 04:00 - 05:00 1.00 FI 5 3512RC Pulled 5ft off fish circ. BU. 05:00 - 08:00 3.00 FI 4 3512RC Pumped dry job. TOOH w/possible fish (PBR segment). !08:00 - 09:00 1.00 FI 2 3512RC L/D fishing BHA and recovered fish as follows: (1) 11.10' 7 1/8" ODx6" ID PBR piece (had 2 connection remaining on top from liner packer) Fish left to recover (3738ft): I (1)+/-3ft cut PBR :(2)8 1/4"ODx6"ID Baker flex lock liner hanger (9.63ft) (3)86jts of 7" 32# P-110 TKC csg w/float equipment (3725.44ft). 09:00 - 10:30 1.50 FI 2 3512RC MU bull nose/spear/pack-off fishing BHA as follows: Bull Nose 4 3/4"x2 1/4" 0.57' Pack-off 4 3/4"x5 3/4"x2 1/4" 2.42' Spear 5 3/4"x2 1/4" 3.45' Printed: 11/04/98 6:42:37 AM PHILLIPS pETROLEUM CO Page 51 of 61 Operations Summa Report Legal Well Name: NORTH COOK INLET UNIT-B 000003 Common Well Name: North Cook Inlet Unit B-3 Spud Date: 05/03/98 Event Name: Original Drilling Start: 02/09/98 End: Contractor Name: Rig Release: Group: Rig Name: Rig Number: Date From - To Hours Sub Co Phase Code Description of Operations 09/24/98 09:00 - 10:30 1.50 FI 2 3512RC Stop Sub 6 1/8"x7 13/16"x2 15/16" 1.17' Bumper Sub 6 1/4"x3 1/8" 9.05' Oil Jar 6 1/4"x2 1/4" 11.58" X-O 6 1/8"x3" 2.64' 9 DC 6 1/4"x2 7/8" 276.53' X-O 6 1/8"x 2 7/8" 1.44' Acc. Jar 6 1/4"x2 1/4" 12.99' Total 321.84' 10:30 - 13:00 2.50 FI 4 3512RC TIH w/fishing BHA T/5895' MD. Tagged fish at same. Stab into fish w/ spear. Picked up an additional 90k increase in string wt. NOTE: With spear in hanger @ 5895' puts 7" shoe @ +/- 9626.6'. 13:00 - 19:30 6.50, FI 4 3512RC POOH with recovered fish slowly. Hole swabbing F/5895' T/5685'. Pump out of hole to keep hole full (350#/60GPM), unable to circulate. While pulling pipe, monitored hole fill F/5685' T/3432'. 19:30 - 23:30 4.00 FI 5 3512RC Break circ. @ 3432'. Increased pump press, to +/-800# @ 92GPM and circ. 2 BU. NOTE: During 1st BU hole attempting to pack-off slightly. 2nd BU was able to maintain GPM at level 800#. Very fine coal cutting returns over shakers, 23:30 - 00:00 0.50 FI 4 3512RC POOH pumping (500#/86GPM) F/3432' T/3244'(spear)/6975'(shoe), 09/25/98 00:00 - 07:00 7.00 FI 4 3512RC Cont. POOH pumping F/3244' T/liner hanger (puts 7" shoe @ 3738 ft). NOTE: Pmpg @ 500#/GPM increased to 200). 07:00 - 08:30 1.50 FI 2 3512RC Break out 7" Liner hanger - w/spear. Recovered as follows: (1) 6.5ft remaining cut PBR (2) 8 1/4" ODx6"ID Baker Flex lock liner hanger (9.63ft) RU 7" csg (TKC)x5 1/2" DP(4 1/2 IF) swedge w/5' DP pup kellyed up to top ddve. 08:30 - 09:00 0.50 FI 5 3512RC Circ, BU. Held pre-job safety mtg to L/D 7" csg. 09:00 - 18:00 9.00 FI y 3512RC R/U weatherford 7" csg handling tools. Recovered 86 jts of 7" w/float eq. while cleaning / inspecting connection. R/D weatherford & clean rig floor. Rejected 6 joints as follows: (#01) 42.99 ft (galled thrds) (#02) 38.31 ft (galled thrds) (#04) 44.66 ft (galled thrds) (#13) 44.81 ft (galled thrds) (#20) 46.50 fl (galled thrds) (#51) 44.42 ft (galled thrds) Total footage rejected = 261.69' (NOTE: Have 18 spare 7" csg jts on top deck = 98 jts good) 18:00 - 19:00 1.00 RM 3 3512RC Clean rig floor, Clean metal F/possum belly, pumped thru stack, and function tested Hyddl & Rams. 19:00 - 20:00 1.00 DR 2 3512RC M/U cleanout BHA. 20:00 - 00:00 4.00 DR 4 3512RC TIH w/cleanout BHA T/7416' MD, filling pipe every 3000 ft. 09/26/98 00:00 - 01:30 1.50 DR 4 3512RC Cont. TIH w/C/O BHA F/7416' MD T/11761' MD. Break circulation. Printed: 11/04/98 6:42:37 AM PHILLIPS PETROLEUM CO Page 52 of 61 Operations Summa Report Legal Well Name: NORTH COOK INLET UNIT-B 000003 Common Well Name: North Cook Inlet Unit B-3 Spud Date: 05/03/98 Event Name: Original Drilling Start: 02/09/98 End: Contractor Name: Rig Release: Group: Rig Name: Rig Number: Date From - To Hours Sub Co Phase Code Description of Operations 09/26/98 01:30 - 13:00 11.50 DR 4 3512RC TIH, washing / reaming F/11761' MD T/15,305' MD (Hole smooth & clean). 13:00 - 18:00 5.00 DR 5 3512RC Mix & pumped Lw/Hi visc. sweep (12.5ppg @40visc./16.5ppg @95visc) while rotating / reciprocating pipe - small increase in coal cuttings returns over shakers. Once sweep up circ. 2 additional BU. (NOTE: Circ. @ 80RPM,3500#,486GPM) 18:00 - 00:00 6.00 DR 4 3512RC TOOH, back reaming (@3200#/120RPM/486GPM) F/15,305' MD T/12,407' MD. 09/27/98 00:00 - 00:30 0.50 DR 4 3512RC Cont. TOOH, back reaming F/12407' T/11761' (Shoe). NOTE: Back reamed smooth. 00:30 - 01:30 1.00 DR 5 3512RC Circ. BU @ shoe (saw little cutting returns). Pumped dry job. Dropped 2.5" rabbit to check DP/HWDP ID>2.375"). 01:30 - 06:30 5.00 DR 4 3512RC TOOH T/BHA. L/D same. 06:30 - 12:30 6.00 CS 6 3512RC R/U 7" csg running tools. Held safety meeting. Ran shoe it. 12:30 - 19:30 7.00 CS I 3512RC Ran 86 Jts 7" 32ppf, TKC Butt. casing. 19:30 - 20:30 1.00 CS 6 3512RC R/D csg tools & R/U short bales / 5" DP elevators. 20:30 - 22:00 1.50 CS 1 3512RC M/U liner hanger assy., open cover on junk bonnet, fill w/gel, close cover. Liner & hanger as follows: ~ (1)Float Shoe 1.88' (2)Float Shoe Jt. w/2cent.&lnsert 43.22' (3)Csg Jt. 44.02' (4)Landing Collar 44.19' (5)83 its 7" 32# TKC Butt. 3585.92' (NOTE: After 4 Jts., cent. every other it. for 500ft) (6)Flex Lock Liner Hanger 20.43' (7)Running Tool (Length above Hgr) 9.46' Liner = 3739.66' (w/running tool 3749.12') 86 Jts in Hole/18 Jts left on deck. 22:00 - 00:00 2.00 CS 1 3512RC Picked-up 1 Std HWDP, put screen in pipe & circ. one volume of the liner 135 BBLs/1600 Stks @ 3 BPM (140K UpWt/135K DnWt). !09/28/98 00:00 - 06:30 6.50 CS 1 3512RC Cont. TIH w/liner F/3740' T/11761' Shoe (ran 29 its HWDP), filled HWDP, ran 10 stds (filled 5 stds 98 stks) ran 5 stds / filled 5 stds from then on. 06:30 - 09:30 3.00 CS I 3512RC Acquired torq. readings @ shoe as follows (did not circ.): @ 10 RPM = 575 amps @ 20 RPM = 575 amps @ 30 RPM = 575 amps UpWt=275K / DnWt=210K Cont. TIH (saw a few tight spots but relatively smooth to bttm), did not tag btm, btm of 7" shoe @ 15301'. 09:30 - 11:00 1.50 CS z 3512RC Dropped ball circ.@ 3 BPM, seated ball, pressured up to 1500#, set hanger slacking off liner weight plus 60K. Sheared RT @ 2300# working pipe. Picked up pipe 4'/lost 100K on UpWt. Set down 30K on liner. Sheared out ball seat @ 3500#. Liner Hanger set @ 11,561' MD. 11:00 - 12:30 1.50 CS z 3512RC Established circ. @ 5 BPM (1400#) circ. BU / clean returns. Held prejob safety meeting for cement job. 12:30 - 15:30 3.00 CE 1 3512RC Pumped liner cement job (Tested cmt lines to 4500#) as follows: Printed: 11/04/98 6:42:37 AM PHILLIPS PETROLEUM CO Page 53 of 61 Operations Summary Report Legal Well Name: NORTH COOK INLET UNIT-B 000003 Common Well Name: North Cook Inlet Unit B-3 Spud Date: 05/03/98 Event Name: Original Drilling Start: 02/09/98 End: Contractor Name: Rig Release: Group: Rig Name: Rig Number: Date From - To Hours Sub Co Phase Code Description of Operations 09/28/98 12:30 - 15:30 3.00 CE 1 3512RC (Pin/Act) (avg./max.) 10/10BBLs Deisel ( 6.9 ppg) Rig 25/29.5BBLs Flowzan (13.94/14.47) (max4.76BPM/1426#) Hall. 42/42BBLs Cement (15.04/16.24) (max5.02BPM/1560#) Hall. (200 sxs Pemium cement/15.6ppg/1.18yld/5.10gal/sx/pmp time = 06:18 @ 215degF / 0.4% HRS / Halad 344LXP @ 13gal/100sxs / 0.4% CFR 3 Displaced Cement w/5bbl of Fsh Wtr, & 318 bbl of 14.6ppg OBM, max rate 5 bpm @ 1500 psi. bumped plug to 2800 psi., held ok, bled back 3.7 bbl of obm, floats held ok. 15:30 - 16:00 0.50 CE 6 3512RC Rig down Baker cementing equipment. 16:00 - 18:00 2.00 CE z 3512RC Pull pipe 30ft. Circ. BU @ 2200#/394 GPM. 18:00 - 00:00 6.00 CE 4 3512RC Mix / pump dry job. TOOH T/HWDP (875'). 09/29/98 00:00 - 01:00 1.00 CE 4 3512RC Cont. TOOH w/HWDP. Break / lay down 7" running tool. 01:00 - 02:00 1.00 RM m 3512RC Repaired electrical panel (required rig power to be shut down). While repairing changed out top pipe rams to 3 1/2" x 5" var. rams. 02:00 - 06:00 4.00 WC 8 3512RC Test BOPE as follows: Picked up test jts - Pull wear bushing. Set test plug - Test Hydril @ 250#/3000#. Top pipe & HCR - choke / kill @ 250#/5000#, manual choke @ 250#/5000#, Bttm pipe & blinds @250#/5000#. IBOP & kelly valve 250#/5000#. Pulled test plug - set wear bushing. 06:00 - 06:30 0.50 CE 2 3512RC Break / laydown Baker cementing head. 06:30 - 19:00 12.50 CS 1 3512RC Pick up Baker ZXP 7" liner packer 33.75'. TIH w/29 jts HWDP (875.24'). TIH (Slowly 2-3 min/Std) T/4192'. Circ. air out of DP by circ. 1 DP volume @ 274psi / 90 GPM. Cont. TIH Slowly. Tagged liner hanger @ 11561' MD. ' 19:00 - 21:00 2.00 CS 1 3512RC Stab seal assy into hanger Tie-back assy setting down 5K. Closed Hydril, press, tested seals T 500# - O.K.. Bled off same. Slacked off 30K & , Press. up to 3500# setting packer w/70K compression placing top of liner 'packer tie-back ext. @ 11545' MD. Confirmed set by pulling 25K over UpWt. Press. tested 9 5/8" csg liner lap / packer to 1500# and chad iecorder for 30 min.. Held O.K.. Bled off same. Released running tool F/packer w/8 raps and working pipe.. Pulled pipe out of'tie-back ext. +/- 12 ft, then blew out ball seat @ 4200#. Saw good retums. (NOTE: Running tool has four 3/8" ports to circ./drain once released) 21:00 - 00:00 3.00 CS 1 3512RC TOOH @ 6560 ft, slowly & wet,no pill. 09/30/98 00.'00 - 08:30 8.50 CS 1 3512RC Cont. TOOH 123 5" DP stands in Derrick. R/U ramp for laying down 5" DP. Held pre-job safety meeting. Pump dry job. Drop inside drillpipe wiper. L/D 180 jts 5" DP & 29 jts 5" HWDP. 08:30 - 10:30 2.00 CS 1 3512RC Break / Laydown Baker packer setting tools. L/D 6 1/4" Drill collars standing in derrick. 10:30 - 12:00 1.50 DR 2 50PRDR P/U 3 1/2" 15.50# S-135 3 1/2 I.F. Conn. handling tools / floor valves. Printed: 11/04/98 6:42:37 AM PHILLIPS PETROLEUM CO Page 54 of 61 Operations Summa Report ,,, Legal Well Name: NORTH COOK INLET UNIT-B 000003 Common Well Name: North Cook Inlet Unit B-3 Spud Date: 05/03/98 Event Name: Original Drilling Start: 02/09/98 End: Contractor Name: Rig Release: Group: Rig Name: Rig Number: Date From - To Hours Sub Co Phase Code Description of Operations 09/30/98 10:30 - 12:00 1.50 DR 2 50PRDR Clean dg floor. 12:00 - 12:30 0.50 DR 0 50PRDR Pre-job safety meeting on picking-up 3 1/2" DP. 12:30 - 14:00 1.50 DR 2 50PRDR P/U & M/U 6" Dir. BHA. Orient mtr/test MWD - O.K.. 14:00 - 19:30 5.50 DR 4 50PRDR P/U 3 1/2" DP in singles strapping in the hole (174its @ 5366'). 19:30 - 20:00 0.50 DR 6 ~50PRDR Change out air & rough neck slips inserts to 5" DP. 20:00 - 23:30 3.50 DR 4 50PRDR Cont. TIH w/5" DP strapping same T/11,091' MD. 23:30- 00:00 0.50 RM 3 50PRDR Servicetop drive. 10/01/98 00:00 - 03:00 3.00 DR 4 50PRDR ~Cont. TIH w/5" DP strapping same T! 11,545' MD. 103:00 - 03:30 0.50 DR 5 50PRDR Kelly-up, break circ. @ 11,545' MD. Recorded UpWt=265K/DnWt=200K/RotWt=225K/Torq=550 Amps. 03:30 - 05:30 2.00 DR 4 50PRDR Cont. TIH W/R. Tagged cmt (stringer) @ 15,180' MD. Drilled hard cmt @ 15,195' MD. 05:30 - 11:00 5.50 DR z 50PRDR Drill out cmt F/15,195' (landing jt w/Idg clr @ 15,212' & shoe jt) T/15,301' MD. Cleaned out rat hole to 15,310' MD. Drilled 10 ft of new hole to 15,320' MD. 11:00 - 13:30 2.50 DR 5 50PRDR Circ. BU. 13:30 - 15:00 1.50 DR y 50PRDR Performed leak-off test w/14.6ppg OBM. Press. up to 800psi in 0.5bbl increments, press, bled back T/725psi. EMW = 15.8ppg (7" Shoe @ 11,379' TVD) 15:00 - DR q 50PRDR Dir. drill F/15,320' MD T/15,388' MD (68 ft). 10/02/98 00:00 - 02:30 2.50 DR q 50PRDR Drill directionally, rotating F/15,388' T/15,410' MD (22 ft). 02:30 - 05:00 2.50 DR q 50PRDR Drill directionally, sliding F/15,410' T/15,427' MD (17 ft). 05:00 - 12:30 7.50 DR q 50PRDR !Drill directionally, rotating F/15,427' T/15,516' MD (89 ft). @07:00hrs Mixed & pumped Lw/Hi visc. sweep (12.5ppg @40visc./16.5ppg @ 95visc) while cont. drilling - little increase in cuttings returns over shakers. 12:30 - 15:30 3.00 DR :q 50PRDR Drill directionally, sliding F/15,516' T/15,533' MD (17 ft). 15:30 - DR q 50PRDR Drill directionally, rotating F/15,533' T/15,618' MD (85 ft). 10/03/98 00:00 - 07:00 7.00 DR q 50PRDR Drill directionally, rotating F/15,618' T/15,700' MD (82 ft). 07:00 - 09:00 2.00 DR q 50PRDR Drill directionally, sliding F/15,700' T/15,713' MD (13 ft). 09:00 - 12:30 3.50 DR q 50PRDR Drill directionally, rotating F/15,713' T/15,767' MD (54 ft). @09:00hrs Mixed & pbmped Lw/Hi risc. sweep (12.5ppg @40visc./16.5ppg @ 95risc) while cont. drilling -little increase in cuttings returns over shakers. 12:30 - 13:00 0.50 DR 5 =50PRDR Finish circ. out sweep & pumped survey before short trip. 13:00 - 14:00 1.00 DR z 50PRDR Short trip circ. & back reaming out of the hole T/15,206' MD (Hole. acted smooth). 14:00 - 16:00 2.00 RM 3 50PRDR Service Top drive, crown, moving parts on drawworks, IBOP, & slip / tong dies. 16:00 - 17:30 1.50 DR z 50PRDR TIH washing & reaming to bttm @ 15,767' MD (hole smooth). 17::~0 - 18:30 1.00 DR q 50PRDR Drill directionally, rotating F/15,767' T/15,781' MD (14 ft). 18:30 - 20:30 2.00. DR q 50PRDR Drill directionally, sliding F/15,781' T/15,796' MD (15 ft). 20:30 - 00:00 3.50 DR q 50PRDR i Drill directionally, rotating F/15,796' T/15,837' MD (41 ft). 10/04/98 00:00 - 19:00 19.00 DR q 50PRDR Directionally drill, rotating F/15,837' T/16,060' MD (223 ft). 19:00 - 22:30 3.50 DR q 50PRDR Directtonally drill, sliding F/16,060' T/16,075' MD (15 ft). @22:30hrs Mixed & pumped Lw/Hi visc. sweep (12.5ppg @40visc./16.5ppg @95visc)while cont. drilling- @ 1:45am, Sun. saw 25% increase in cutting returns, very few larger pieces of coal - most of increase was in fines - re-ground up fine coals / sands / silts (paste-like). ..... Printed: 11/04/98 6:42:37 AM PHILLIPS PETROLEUM CO Page 55 of 61 Operations Summar Report ,,, Legal Well Name: NORTH COOK INLET UNIT-B 000003 Common Well Name: North Cook Inlet Unit B-3 Spud Date: 05/03/98 Event Name: Original Drilling Start: 02/09/98 End: Contractor Name: Rig Release: Group: Rig Name: Rig Number: Date From - To Hours Sub Co Phase Code Description of Operations ,' 10/04/98 22:30 - 00:00 1.50 DR q 50PRDR Directionally drill, rotating F/16,075' T/16,080' (5 ft). !10/05/98 00:00 - 14:00 14.00 DR q 50PRDR Directionally drill, rotating F/16,080' T/16,231' MD (151 ft). @ 11:30hrs Mixed & pumped Lw/Hi visc. sweep (12.5ppg @40visc./16.Sppg @95visc) while cont. drilling. Finished circ. out sweep F/14:00 T/15:30 - @ 15:30, Sun. saw 25% increase in cutting returns, very few larger pieces of coal - most of increase was in fines - re-ground up fine coals / sands / silts. ,15:30 - 18:00 2.50 DR z 50PRDR Short trip B/R F/16,231' T/15,30:1' (shoe). Tripped out smooth. 18:00 - 19:30 1.50 RM 3 50PRDR Service top drive & rig. 19:30 - 22:30 3.00 DR z 50PRDR TIH, W/R F/15,301' T/16,231' (Tight spot @ 15650' (Coal Sect.) - stalled out top drive, and drove up pump press. T/4100# - stalled mud motor. Cleaned tight area up). Rest of trip T/bttm was smooth. 22:30 - 00:00 1.50 DR q 50PRDR Directionally drill, rotating F/16,231' T/16,244' MD (13 ft). 10/06/98 00:00 - 12:30 12.50 DR q 50PRDR Directionally drill, rotating F/16,244' T/16,392' MD (148 ft). 12:30 - 16:30 4.00 DR 5 50PRDR Mixed & pumped Lw/Hi visc. sweep (12.5ppg @40visc./16.5ppg @95visc) Finished circ. out sweep / clean - saw 25% increase in cutting returns, very few larger pieces of coal - most of increase was in fines - re-ground up fine coals / sands / silts. 16:30 - 19:00 2.50 DR 4 50PRDR :TOOH, B/R T/shoe @ 15,301' MD (smooth). 19:00 - 00:00 5.00 DR 4 50PRDR 'TOOH, washing 7" casing F/15,301' T/12,027' MD (@ 3550#/230GPM). 10/07/98 00:00 - 00:30 0.50 DR d 50PRDR WASH OUT OF HOLE FROM 12,027FT TO 11,545FT. 00:30 - 01:00 0.50 DR p 50PRDR WASH & REAM FROM 11,545FT TO 10,700FT 01:00 - 02:30 1.50 DR 5 50PRDR CIRC BTMS UP 02:30 - 03:30 1.00 RM c 50PRDR SLIP & CUT DRL LINE (104FT) 03:30 - 12:00 8.50 DR 4 50PRDR 'PUMP SLUG. POOH. L/D BHA. CLEAN RIG FLOOR. 12:00 - 13:30 1.50; WC 4 50PRDR M/U PULLING TOOL. RIH & PULL WEAR BUSHING. P/U TEST PLUG. RIH & SET PLUG. 13:30 - 14:30 1.00 WC 8 50PRDR TEST HYDRIL 250/2500PSI. TEST TOP PIPE RAMS, HCRs & MANUAL VALVES TO 250/5000PSI. BTM PIPE RAM FAILED TO TEST ON 3.1/2" PIPE. PULL TEST JT. TEST BLIND RAM 250/5000PSI. 14:30 - 18:30 4.00 WC 8 50PRDR ~DRAIN STACK. C/O BTM RAMS. TEST RAMS TO 250/5000PSI WITH 3.1/2" TEST STRING. 18:30 - 22:30 4.00 WC 8 50PRDR RUN 5" TEST STRING. TEST BTM RAMS TO 250/5000PSI. TEST UPR & !LWR KELLY COCK AND STAND PIPE LINE TO 5000PSI (ISOLATION VALVE LEAKED - REPAIR & TEST). REMOVE METAL FROM TRIP TANK FLOW LINE (MILLING DEBRIS CLOGGING FILTER). 22:30 - 00:00 1.50 RM 3 50PRDR !SERVICE RIG AND CLEAN FLOOR. 10/08/98 00:00 - 09:30 9.50 DR 4 50PRDR ' P/U BHA. FUNCTION TEST MWD. RIH 58 STDS 3.1/2" DP. PICK UP 26 JTS 3.1/2" DP - RABBIT & RIH (TOTAL 3.1/2" = 6168.42FT). CeNT RIH w/5" DP 09:30 - 14:00 4.50, DR p 50PRDR ~WASH & REAM FROM 15,301FTTO 16,392FT 14:00- 14:30 0.50 DR 5 50PRDR ~CIRC BTMS UP 14:30 - 00:00 9.50 DR 'q 50PRDR DRILL (ROTATE) FROM 16,392FT TO 16,630FT 10/09/98 00:00 - 00:00 24.00 DR q 50PRDR DRILL (ROTATE) FROM 16,630FT TO 16,863FT. PUMPED LO-VIS/HI-VIS SWEEPS AT 12:00 & 22:00. HARD FORMATION (CONTAINS CHERT & QuARTz) FROM 16,853FT - ReP 1-3FT/HR 10/10/98 00:00- 04;00 4.00 DR q 50PRDR DRILL (ROTATE) FROM 16,863FTTO 16,865FT. TORQUE DECREASING & UNABLE TO STALL MOTOR - SUSPECT BIT CORED. Printed: 11/04/98 6:42:37 AM PHILLIPS PETROLEUM CO Page 56 of 61 Operations Summa Report ,,, Legal Well Name: ' NORTH COOK INLET UNIT-B 000003 Common Well Name: North Cook Inlet Unit B-3 Spud Date: 05/03/98 Event Name: Original Drilling Start: 02/09/98 End: Contractor Name: Rig Release: Group: Rig Name: Rig Number: Date From.- To Hours Sub Co Phase Code Description of Operations 10/10/98 00:00 - 04:00 4.00 DR q 50PRDR PREPARE TO POOH FOR BIT CHANGE 04:00- 06:00 2.00 DR 5 50PRDR CIRC BTMS UP 06:00 - 09:00 3.00 DR p 50PRDR BACKREAM 16,865FT TO 7" SHOE @ 15,301FT 09:00 - 12:30 3.50 DR d 50PRDR PUMP OOH FROM 15,301FT TO TeL @ 11,545FT 12:30 - 14:00 1.50 DR p 50PRDR BACKREAM IN 9.5/8" CSG FROM 15,301FT TO 10,345FT 14:00 - 16:30 2.50 DR 5 '50PRDR CIRC BTMS UP. CLEAN RIG FLOOR. MIX & PUMP SLUG. 16:30 - 00:00 7.50 DR 4 50PRDR POOH w/5" DP TO 6,524FT. CHANGE SLIP INSERTS, ELEVATORS, ETC. CeNT POOH w/3.1/2" DP. L/D MTR & BIT (BIT RINGED OUT). CLEAN RIG FLOOR 10/11/98 00:00 - 01:00 1.00 DR b 50PRDR DOWNLOAD LWD DATA. CLEAN RIG FLOOR. 101:00 - 02:30 1.50 DR 2 50PRDR M/U BIT & MTR. ORIENTATE MTR. RIH TO 1800FT. FUNCTION TEST MWD/LWD. 02:30 - 08:30 6.00 DR 4 50PRDR RIH TO 7" SHOE @ 15,301FT. 08:30 - 14:00 5.50 DR p 50PRDR IWASH & REAM TO BTM. 14:00- 14:30 0.50 DR !~ 50PRDR CIRCULATE 14:30 - 00:00 9.50 DR q 50PRDR DRILL (ROTATE) FROM 16,865FTTO 16,967FT. PUMP LO-VIS/HI-VIS SWEEP @ 22:00 10/12/98 00:00 - 00:00 24.00 DR q 50PRDR DRILL (ROTATE) FROM 16,967FT TO 17,230FT. PUMP LO/HI-VIS SWEEP @ 13:00 AND 21:30 - NO EXCESS CUTTINGS RETURNED ' 10/13/98 00:00 - 17:30 17.50 DR q 50PRDR DRILL (ROTATE) FROM 17,230FT TO 17,365FT. 17:30- 20:00 2.50 DR 5 50PRDR CIRC BTMS UP 20:00- 21:00 1.00 DR p 50PRDR BACKREAM TO 16,865FT (NO PROBLEMS) 21:00 - 22:30 1.50 DR p 50PRDR WASH & REAM BACK TO BTM. 22:30- 23:00 0.50 DR 5 50PRDR CIRC. 23:00 - 00:00 1.00 DR q 50PRDR DRILL FROM 17,365FT TO 17,370FT 10/14/98 00:00- 00:00 24.00 DR q ' '50PRDR DRILL (ROTATE) FROM 17,370FTTO 17,573FT 10/15/98 00:00 - 00:00 24.00 DR q 50PRDR DRILL (ROTATE) FROM 17,573FT TO 17,780FT. 10/16/98 00:00 - 10:00 10.00 DR q 50PRDR DRILL (ROTATE) FROM 17,780FT TO 17,864FT (TD). 10:00 - 14:30 4.50 DR 5 50PRDR CIRC & COND PRIOR TO BACKREAMING. 14:30 - 21:30 7.00 DR p 50PRDR BACKREAM TO 15,371FT. TIGHT @ 17,550FT, 17,115FT AND 15,501FT TO 15,371 FT. 21:30 - 00:00 2.50 DR 5 50PRDR WORK STD. MIX & PUMP LO/HI-VIS SWEEP. CIRC SWEEP 10/17/98 00:00- 01:00 1.00 DR p 50PRDR CONT. BACKREAM TO LINER SHOE @ 15,301FT 01:00 - 05:00 4.00 DR Id 50PRDR 'PUMP OOH TO TOP OF 7" LINER @ 11,454FT 05:00 - 06:00 1.00 DR p 50PRDR BACKREAM INSIDE 9.5/8" CSG FROM 11,545FT TO 10,645FT. 06:00- 08:30 2.50 DR 5 50PRDR !CIRC & COND 08:30 - 09:30 1.00 DR 4 50PRDR PUMP SLUG. PULL 20 STDS. 09:30 - 10:00 0.50 DR g 50PRDR INCORRECT FILL. MONITOR WELL FOR FLOW. (SLUG U-TUBING) · '10:00 - 16:30 6.50 DR 4 50PRDR CONT. POOH. L/D BHA 16:30 - 20:30 4.00 WC 8 50PRDR PULL WEAR BUSHING. M/U 5" TEST JT. TEST HYDRIL 250/2500PSI. TEST RAMS, CHOKE/HCR/MANUAL/FLOOR VALVES & IBOP 250/5000PSI. PULL 5" TEST JT. TEST BLINDS & ACCUMULATOR. P/U 3.1/2" TEST JT. TEST HYDRIL & TOP/BTM RAMS. PULL TEST JT. INSTALL WEAR BUSHING. 20:30- 23:00 2.50 LG 6 50PRDR R/U SCHLUMBERGER WIRELINE 23:00 - 00:00 1.00 LG 1 50PRDR RIH w/LOGGING TOOLS- GR/SONIC/DEN/NEU/RES (TOTAL TOOL STRING LENGTH - 105FT) 10/18/98 00:00 - 01:00 1.00 LG 1 50PREV RIH w/LOGGING TOOLS (QUAD COMBO). UNABLE TO GET BELOW 15,405FT. 01:00 - 02:30 1.50 LG 1 50PREV POOH WIRELINE 02:30 - 04:30 2.00 LG 1 50PREV RIH w/SHORTENED TOOL STRING - GR & SONIC ONLY. UNABLE TO GET BELOW 15,800FT. Printed: 11/04/98 6:42:37 AM PHILLIPS PETROLEUM CO Page 57 of 61 Operations Summary Report Legal Well Name: NORTH COOK INLET UNIT-B 000003 Common Well Name: North Cook Inlet Unit B-3 Spud Date: 05/03/98 Event Name: Original Drilling Start: 02/09/98 End: Contractor Name: Rig Release: Group: Rig Name: Rig Number: Date From - To Hours Sub Co'Phase Code Description of Operations .... 10/18/98 04:30 - 06:30 2.00 LG '1 50PREV POOH w/LOGGING TOOLS 06:30 - 08:30 2.00 LG 1 50PREV REMOVE STAND-OFFS FROM SONIC TOOL (TO REDUCE TOOL STRING O.D.) & RIH. TOOL STRING HANGING UP @ 15,800FT. 08:30 - 11~00 2.50 LG 1 50PREV POOH w/LOGGING TOOLS & RIG DOWN. 11:00 - 13:00 2.00 LG 4 50PREV PICK UP CLEAN-OUT BHA 13:00 - 19:30 6.50 LG 4 50PREV RIH TO 7" LINER SHOE @ 15,301FT 19:30 - 00:00 4.50 LG 4 50PREV WASH & REAM FROM 15,301 TO 16,203FT. TIGHT FROM 15,392FT TO 15,422FT (STUCK GOING DOWN - JARRED FREE, REAMED SECTION 4-5 TIMES). TIGHT @ 15,611FT - REAMED SECTION 3 TIMES. 10/19/98 00:00 - 04:00 4.00 LG 4 50PREV WASH & REAM FROM 16,203FT TO 16,831FT. TIGHT FROM 16,808FT - 16,831FT. PIPE STUCK @ 16,829FT BUT JARRED FREE. UNABLE TO GET BELOW 16,831FT. PREPARE TO POOH FOR BHA CHANGE ~04:00 - 05:00 1.00 LG 4 50PREV CIRC BTMS UP 05:00 - 07:00 2.00 LG 4 50PREV BACKREAM FROM 16,831FT TO LINER SHOE @ 15,301FT. 107:00- 11:00 4.00 LG 4 50PREV PUMP OUTOF HOLE FROM 15,301FTTO 11,545FT 11:00 - 11:30 0.50 LG 4 50PREV BACKREAM IN 9.5/8" CSG FROM 11,545FT TO 11,245FT 11:30 - 14:00 2.50 LG 4 50PREV CIRC BTMS UP. CLEAN RIG FLOOR 14:00 - 15:00 1.00 LG 4 50PREV POOH WET FROM 11,245FT TO 9,158FT ( BARITE TRANSFER PROBLEMS) 15:00 - 21:00 6.00 LG 4 50PREV PUMP SLUG. POOH FROM 9,158FT (PULL 3.1/2" DP FROM 6,523FT). L/D BHA. CLEAN RIG FLOOR. 21:00 -22:00 1.00 LG '4 50PREV P/U BHA (FLEX COLLARS & MTR) 22:00 - 00:00 2.00 LG 4 50PREV RIH TO 1,93QFT. 10/20/98 00:00 - 05:30 5.50 LG 4 50PREV CeNT RIH TO 7" SHOE @ 15,301FT 05:30- 14:30 9.00 LG 4 50PREV WASH & REAM TO 17,864FT (TD) 14:30- 15:00 0.50 LG 4 50PREV CIRCULATE 15:00 - 21:00 6.00 LG 4 50PREV BACKREAM TO 7" SHOE (TIGHT FROM 15,427FT TO 15,397FT - REAMED UNTIL HOLE SMOOTH) 21:00 - 00:00 3.00 LG 4 50PREV PUMP OUT OF 7" LINER TO 13,869FT. 10/21/98 00:00 - 01:30 1.50 LG 4 50PREV PUMP OOH F/13869' T/11545' 01:30 - 02:00 0.50 LG 4 50PREV BACKREAM F/11545' T/11270'. 02:00- 04:00 2.00 LG 4 50PREV CIRC BU @ 11270', PUMP SLUG. 04:00 - 09:30 5.50 LG 4 :50PREV FINISH POOH F/11270' T/SURFACE. 09:30 - 15:00 5.50 LG 1 50PREV RU SCHLUMBERGER, HELD SAFETY MEETING. GIH W/GR/SONIC. TAG @ +- 15820'. UNABLE TO WORK BELOW 15820'. POOH & RD SCHLUMBERGER. 15:00 - 17:00 2.00 LG 2 50PREV PICK UP & MAKE UP SCHLUMBERGER ADN' LWD, HELD SAFETY MEETING, INSTALL R/A SOURSE. FINISH M/U BHA. 17:00 - 00:00, 7.00 LG 4 50PREV GIH W/'ADN' LWD LOGGING BHA ASSEMBLY ON 3.5" & 5" D.P. T/ 13111'@ REPORT TIME 10/22/98 00:0~) - 01:00 1.00 LG 4 50PREV CONTINUE TO GIH W/SCHLUMBERGER 'ADN' LWD ASSEMBLY ON 3.5" & 5" D.P. F/13111' T/15301' 01:00 - 12:00 11.00. LG z 50PREV ROTATE & LOG W/SCHLUMBERGER 'ADN' @ +-200 FPH F/15301' T/ 168O0' 12:00 - 13:00 1.00 LG z 50PREV DECREASED LOGGING SPEED F/+-200 FPH T/+-80 FPH REAM & LOG F/16800' T/16892' 13:00- 15:00 2.00 LG z 50PREV WORKTHRU TIGHT SPOT W/ 6" BIT F/16892'T/16907' = 15'. W/BIT @ 16892' THE 5-7/8" OD STABILIZER ON THE 'ADN' LOGGING TOOL WOULD BE @ 16832'. THE TOP OF THE SUNFISH FORMATION @ 16800' MD (12500'TVD). 15:00 - 00:00 9.00 LG z 50PREV CONTINUE TO ROTATE & LOG W/SCHLUMBERGER ANADRILL "ADN" Printed: 11/04/98 6:42:37 AM PHILLIPS PETROLEUM CO Page 58 of 61 Operations Summa Report Legal Well Name: NORTH COOK INLET UNIT-B 000003 Common Well Name: North Cook Inlet Unit B-3 Spud Date: 05/03/98 Event Name: Original Drilling Start: 02/09/98 End: I Contractor Name: Rig Release: Group: Rig Name: Rig Number: Date From- To Hours Sub Co Phase Code Description of Operations , ,, 10/22/98 15:00 - 00:00 9.00 LG z 50PREV LOGGING TOOLS F/16,907' T/17,412' MD. AT 65' - 200 FT/HR AS PER ANADRIL RECOMMENDATION. 10/23/98 00:00 - 06:00 6.00. LG z 50PREV CONTINUE TO ROTATE & LOG .W/SCHLUMBERGER/ANADRIL 'ADN' LWD F/17412' T/17864' MD, LOGGING +-80 FPH. 06:00- 09:30 3.50 LG 4 50PREV BACKREAM F/17864'T/15301' MD. 09:30- 12:30 3.00 LG 5 50PREV CIRC BU @ 15300' MD. SLIP & CUT 210' OF DRILLING LINE WHILE CIRCULATING. PUMP SLUG. 12:30 - 21:00 8.50 LG 4 . 50PREV POOH W/SCHLUMBERGER/ANADRIL 'ADN' LOGGING ASSEMBLY 21:00 - 22:30 1.50 LG 2 50PREV REMOVED R.A. SOURCE F/'ADN' LWD TOOL. THE RELEASE ON THE RETRIEVING TOOL FOR THE R.A. SOURCE TWISTED OFF THE RELEASING SCREW, HAD TO CUT THE RETRIEVING TOOL W/HACK SAW TO REMOVE RETRIEVING TOOL FROM R.A. STORAGE CONTAINER. ~ FINISH L/D SCHLUMBERGER/ANADRIL ADN' ASSEMBLY '22:30- 23:00 0.50 DR z 50PREV I CLEAN RIG FLOOR 23:00- 00:00 1.00 DR 2 50PREV M/U CLEAN OUT/SCRAPER ASSEMBLY 10/24/98 00:00 - 02:00 2.00 CS 2 50PRRC M/U & GIH W/6" BIT, 9 JTS OF 3.5" D.P., 6" OD x8.5" OD CLEAN OUT MILL, CASING SCRAPER FOR 9.625" CASING, 4.750" OD JARS, 4-4.750" SPIRAL DC, & 5" D.P.. 02:00 - 07:30 5.50 CS 4 50PRRC GIH W/6" BIT T/11431' 07:30 - 08:30 1.00 CS 5 50PRRC WASH W/6" BIT F/11431' T/11824'. WASH W/6"OD x 8"OD TAPERED CLEAN OUT MILL F/11152' T/11545' (TAG TOP OF 7" x 8.250" OD BAKER ZXP PACKER W/CLEAN OUT MILL) 08:30 - 10:30 2.00 CS 5 50PRRC CIRC BU, RECOVERED FINE SILT WHILE ClRC BU. PUMP SLUG. 10:30- 15:00 4.50 CS 4 50PRRC POOH 15:00 - 16:30 1.50 CS 2 50PRRC L/D CLEAN OUT ASSEMBLY 16:30- 18:00 1.50 CS 6 50PRRC CLEAN RIG FLOOR 18:00 - 20:30 2.50 CS 6 50PRRC R/U WEATHERFORD CASING TOOLS, HELD SAFETY MEETING, M/U BAKER CEMENTING HEAD. 20:30- 00:00 3.50 WO s 50PRRC WAIT ON 3.5" TURBULATORS. (THE TURBULATORS ON LOCATION WOULD NOT FIT ON THE 3.5" LINER.) MODIFY TURBULATORS TO FIT 3.5" LINER. '10/25/98 00:00 - 02:00 2.00 WO s 50PRRC MODIFY 3.5" TURBULATORS TO FIT 3.5" LINER. PRE-JOB SAFETY MEETING. 02:00 - 15:00 13.00 CS 1 50PRRC PU & RIH WITH 3.5" FLOAT SHOE, 2 JTS 3.5" 12.95# LINER, FLOAT COLLAR, 20 JTS 3.5" 12.95# LINER, BAKER PBR, 126 JTS 5" 18# LINER. 15:00 - 16:00 1.00 CS I 50PRRC I RIG DOWN WEATHERFORD TOOLS. MU LINER HANGER, PACKER & PBR. TOTAL LINER STRING = 6426'. 16:00 - 17:00 1.00 CS 5 50PRRC PU 1 STAND OF 5" DP. MU TOP DRIVE & CIRC LINER VOLUME AT 3 BBLS/MIN. 17:00 - 00:00 7.00 CS 1 50PRRC RIH WITH 3.5" X 5" LINER ASSEMBLY ON 5" DRILL PIPE AT 3 MIN/STAND. FILL DP EVERY 5 STAND. TOTAL DEPTH AT REPORT TIME = 11300'. Printed: 11/04/98 6:42:37 AM PHILLIPS PETROLEUM CO Page 59 of 61 Operations Summar Report Legal Well Name: NORTH COOK INLET UNIT-B 000003 Common Well Name: North Cook Inlet Unit B-3 Spud Date: 05/03/98 Event Name: Original Drilling Start: 02/09/98 End: Contractor Name: Rig Release: Group: Rig Name: Rig Number: Date From - To Hours Sub Co Phase Code Description of Operations 10/26/98 00:00- 05:00 5.00 CS 1 50PRRC CONTINUE TO RIH W/3.5' x 5' LINER ASSEMBLY ON 5" DRILL PIPE @ 3 MIN/STAND. FILL DRILL PIPE EVERY 5 STDS. F/11300' T/15301'. TIME CHANGED @ 2:00AM F/ADT T/AST. ACTUAL TIME FOR THIS TASK WAS 6 HRS. 05:00 - 07:30 2.50 CS 1 50PRRC RIH W/3.5" x 5" LINER ASSEMBLY ON 5" DRILL PIPE INTO 6" OPEN HOLE F/15301' T/17854'. FILL DRILL PIPE WHILE GIH. 07:30 - 08:00 0.50 CS 6 50PRRC RU BAKER CEMENTING HEAD & DROP 1" OD SETTING BALL. 08:00 - 09:30 1.50 CS 5 50PRRC A'I-I'EMPT TO GIH AFTER RU BAKER CEMENTING HEAD. UNABLE TO WORK BELOW 17854'. CIRC & COND HOLE. ***LINER & HANGER TOP TO BTM*"* 11420' 7"x9.625" ZXP PACKER TOP 11439' 7" RS TYPE PACKOFF NIPPLE 11442' 7"x9.625" FLEX LOCK HANGER 11449' 7" TKC BOX x 5" VAM FJL PIN 11450' 126 JTS (5689') 5" 18# Pl10 17139' 5" VAM x 5" TKC X-OVER 17141' 4"ID POLISH BORE RECPTICAL 17159' 5" TKC x 3.5" PH-6 X-OVER 17161' 3.5" 12.95# PH-6 SUB 17164' 20 JTS (623') 3.5" 12.95# PH6 17788' WEATHERFORD LANDING CLR '17789' BALL SEAT LANDING SUB 17790' 2 JTS (62') 3.5" 12.95# PH6 17852' 3.5" PH6 FLOAT SHOE 17854' BTM OF FLOAT SHOE 09:.30 - 10:00 0.50 CS !1 50PRRC SET BAKER 7" x 9-5/8" BAKER FLEX LOCK LINER HANGER @ 11442' MD. SETTING BALL SHEARED @ 5200 PSI. 10:00- 10:30 0.50 CS 5 50PRRC CIRC & COND HOLE HELD PRE-JOB SAFETY MEETING 10:30 - 14:00 3.50 CE 1 50PRRC TEST HALLIBURTON LINES TO 5200 PSI. PUMPED 8 BBL DIESEL SPACER, 25 BBL OF HIGH VIS SPACER, MIX & PUMP 220 SXS OF PREMIUM CEMENT + 0.4% CFR-3+ 0.13 GAL/SX HALAD 344L + 0.4% HR-5 MIX @ 15.6 PPG W/1.18 CF/SX YIELD, FOLLOWED BY 7 BBL OF HIGH VIS SPACER. DISPLACED CEMENT & SPACER W/. 298 BBL OF 14.6 PPG MUD. MAX PUMP PSI 2600#. MAX RATE 5 BPM. FINAL PUMP PSI 1900#, BUMPED PLUG TO 3000 PSI. HELD PRESSURE FOR 5 MIN HELD OK. BLED PRESSURE TO ZERO, BLED BACK 2 BBL OF MUD, FLOATS HELD OK. RD BAKER & HALLIBURTON CEMENT EQUIP. 14:00-15:00 1.00 CE n 50PRRC SET BAKER 7" ID x 9.625" OD ZXP LINER PACKER W/ HOLD DOWNS & 10' TIE BACK EXTENSION @ 11420'. CIRC BU F/TOP OF TIE BACK EXTENSION. 15:00 - 16:00 1.00 CS 9 50PRRC RU & TEST BAKER ZXP 7" x 9.625" LINER PACKER, 9.625" CASING, 5" LINER & 3.5" LINER TO 1500 PSI FOR 30 MIN. HELD OK. 16:00 - 17:00 1.00 CS 5 50PRRC CIRC & COND MUD. PUMP SLUG 17:00- 21:00 4.00 CE 4 50PRRC POOH W/BAKER SETTING TOOL:. 21:00 - 22:30 1.50 CE 2 50PRRC LD BAKER EQUIPMENT & CLEAR FLOOR. 22:30 - 00:00 1.50 CE 4 50PRRC MU 3.5" MULE SHOE. TIH WITH 3.5" DRILL PIPE IN DERRICK. (3000' AT REPORT TIME) Printed: 11/04/98 6:42:37 AM PHILLIPS PETROLEUM CO Page 60 of 61 Operations Summar Report Legal Well Name: NORTH COOK INLET UNIT-B 000003 Common Well Name: North Cook Inlet Unit B-3 Spud Date: 05/03/98 Event Name: Original Drilling Start: 02/09/98 End: Contractor Name: Rig Release: Group: Rig Name: Rig Number: Date From - To Hours Sub Co'Phase Code Description Of Operations 10/27/98 00:00 - 01:00 1.00 CE !4 50PRRC FINISH GIH W/3.5' DRILL PIPE 01:00 - 02:00 1.00 RM c 50PRRC SLIP & CUT 200' OF DRILLING LINE 02:00 - 02:30 0.50 RM 3 50PRRC SERVICE RIG 02:30 - 11:30 9.00 CM 2 50PRRC RU LAY DOWN RAMP, L/D 3.5" DRILL PIPE. 11:30 - 14:00 2.50 CS e 50PRRC INSTALL 2-7/8" PIPE RAMS IN TOP CAVITY OF 13-5/8' SCHAFFER SL BOP, PULL WEAR BUSHING, INSTALL TEST PLUG. 14:00 - 17:00 3.00 CS 8 50PRRC WEEKLY BOPE TEST, NOTIFIED BLAIRE WONDZELL W/AOGC OF INTENT TO TEST BOPE ON 10-23-98 @ 13:00 HRS ADT. NO STATE WITNESS REQUIRED. TEST TO 250 PSI LOW & 5000 PSI HIGH PRESSURE TEST, TEST ANNULAR PERVENTOR TO 250 PSI LOW & 2500 PSI HIGH TEST, HELD OK. PULL TEST PLUG, INSTALL WEAR BUSHING. 17:00 - 17:30 0.50 CM 6 150PRRC RU WEATHERFORD TUBING TONGS FOR 2-7/8" 6.50# L-80 BTS-8. 17:30 - 00:00 6.50 CM 2 50PRRC GIH W/4-1/8" BIT, 5" CASING SCRAPER, XO & 140 JTS 2.875" 6.5# L-80 CS HYDRIL TBG. 4400' AT REPORT TIME. (HAVE 49 ADDITIONAL JTS OF TBG TO PU) 10/28/98 00:00 - 02:30 2.50 CE z 50PRRC FINISH PU & RIH 2.875" TBG, BIT & SCRAPER. '02:30 - 03:00 0.50 CE z 50PRRC PU XO, 9-5/8" SCRAPER & BRISTLE BRUSH. 03:00 - 09:00 6.00 CE z 50PRRC TIH WITH 5" DRILL PIPE, TAG PBR WITH 4.125 BIT AT 17140'. ~09:00 - 21:00 12.00 CE z 50PRRC CIRC & COND OBM. WHILE CIRC, SLIP & CUT 277' DRILL LINE. PRE JOB SAFETY MEETING. FINISH BUILD SPACERS. 21:00 - 22:30 1.50 CE z 50PRRC RIG PUMP SPACER #1. 45 BBLS DIESEL MIXED WITH 4 DRUMS ! BARASCRUB. RU HALLIBURTON LINES & TEST TO 6000 PSI. 22:30 - 00:00 1.50 CE z 50PRRC HALLIBURTON PUMP SPACERS 2, 3, & 4 AT 3 BBL/MIN. DISPLACE WITH SALT WATER, HOLDING CONSTANT BHP. 10/29/98 00:00 - 06:30 6.50 CS z 50PRRC HALLIBURTON DISPLACING OBM WITH SW HOLDING CONSTSANT BHP. SHUT DOWN OCCASIONALLY TO ALLOW APOLLO TIME TO CATCH UP THE DISPOSAL OF DIRTY FLUID. 06:30 - 09:00 2.50 CS z 50PRRC PRESSURE TEST CASING, LINER TOP TO 4000 PSI & HOLD 30+ MIN. (GOOD TEST) BLEED OFF THE 4000 PSI IN 500 PSI INCREMENTS UNTIL ZERO PRESSURE. HOLDING FOR 5 MIN AT EACH PRESSURE. MONITOR & CHART FOR 30 MIN AT ZERO PRESSURE. (GOOD NEGITIVE TEST) 09:00 - 13:00 4.00 CM I 50PRRC MONITOR HOLE WHILE CLEANING TRIP TANK, & PILL. PIT STAND PIPE, CHOKE MANIFOLD & MUD PUMPS. 13:00 - 16:00 3.00 OM I 50PRRC PREPARE TO MAKE WIPER TRIP. FLUID U-TUBING UP DRILL PIPE. PUMP CaCl SLUG. ALLOW FLUID TO BALANCE OUT. 16:00 - 21:30 5.50 CM 4 50PRRC PULL 120 STDS UNTIL 9-5/8 SCRAPER & BRUSH TO SURFAC'E & INSPECT SAME. DP PULLED WET. 21:30 - 22:30 1.00 CM 4 50PRRC RIH WITH 25 STANDS UNTIL TRIP TANK FULL. 22:30 - 00:00 1.50 CM 1 50PRRC MONITOR WELL. CLEAN SHAKER & DITCH TO PILL PIT. 10/30/98 00:00 - 05:00 5.00 CM I 80CMPL CLEAN SHALE SHAKERS AND PILL PIT. 05:00 - 08:30 3.50 OM 4 80CMPL TIH FROM 8151 TO 17139. 08:30 - 14:30 6.00 CM 5 80CMPL PUMPED TWO SOAP PILLS FOLLOWED BY SEA WATER. RECOVERSD GREAT AMOUNTS OF BARITE WITH THE RETURN OF EACH PILL. 14:30 - 15:30 1.00 CM 1 80CMPL HELD PREDISPLACEMENT SAFETY MEETING, TRANSFERRED FLUID FROM PLATFORM PITS TO RIG PITS. 15:30 - 00:00 8.50 OM 5 80CMPL PUMPED HI-VIS SWEEP FOLLOWED BY 10.5 CaCl. COMPLETION FLUID. 10/31/98 00:00 - 04:30 4.50 CM 5 80CMPL FINISH DISP. WELL WITH 10.5 CaCI Printed: 11/04/98 6:42:37 AM - w, , PHILLIPS PETROLEUM CO Page 61 of 61 Operations Summa Report 'Legal Well Name: NORTH COOK INLET UNIT-B 000003 ICommon Well Name: North Cook Inlet Unit B-3 Spud Date: 05/03/98 ,Event Name: Original Drilling Start: 02/09/98 End: Contractor Name: Rig Release: Group: ~Rig Name: Rig Number: Date From - To Hours Sub Co Phase Code Description of Operations 10/31/98 04:30- 06:00 1.50 CM 1 80CMPL FILLEDTRIP TANK, PUMPED SLUG BEFORE COMMING OUT OF HOLE 06:00 - 17:00 11.00 CM 4 80CMPL POOH WITH DRILL PIPE, CASING SCRAPPERS AND BRUSHES. LD 27/8" TUBING. I 17:00 - 21:30 4.50 CM 4 80CMPL PU AND RUN 95/8" RBP, SET AT 11406' 21:30 - 00:00 2.50 OM 4 80CMPL POOH WITH SE'I-rING TOOL AT REPORT TIME. ,11/01/98 00:00 - 02:00 2.00 CM 4 80CMPL FINISH POOH WITH SETTING TOOL & LD SAME.. 02:00 - 06:00 4.00 CM 6 80CMPL PULLWEAR BUSHING. RIG DOWN FLOOR. ND BELL NIPPLE. 06:00 - 10:00 4.00 CM e 80CMPL ND BOP, CLEAN UP IN BOP ROOM. I10:00 - 12:00 2.00 CM 6 80CMPL ND & REMOVE RISER, INSTALL DRY HOLE TREE & TEST TO 1500 FOR 20 MIN. RIG RELEASED FROM B-3 AT 12:00 HRS 10-31-98 · Printed: 11/04/98 6:42:37 AM PHILLIPS PETROLEUM HOUSTON, TEXAS 77251-1967 BOX 1967 NORTH AMERICA EXPLORATION AND PRODUCTION COMPANY February 3, 1999 BELLAIRE, TEXAS 6330 WEST LOOP SOUTH PHILLIPS BUILDING Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501-3192 Attn: Mr. Robert Crandall Re' Well Information Tyonek Deep Project Cook Inlet, Alaska Gentlemen: Phillips Petroleum hereby delivers two boxes containing the well information as described on the attached schedule. This information covers the four wells (North Cook Inlet Unit wells B-1, B-2, B-1 ST and B-3/B-3 ST1/B-3 BP1) which have been drilled to date as part of the captioned project. Some of the material included in this package may be redundant with information that was provided to you earlier. Please contact the undersigned at 713-669-2942 if you have any questions. Sincerely, Robert N. Welch Landman cc: J. W. Lachenmaier :' TYONEK DEEP WELL IN~."' 213199) General: Core Sample Report (B-l, B-1ST, B-2, B-3, B-3BP1, B-3ST) Geologic Tops (B-l, B-1ST, B-2, B-3) Folder B-l: Operations Summary Report Well Completion/Re-completion Report and Log Schlumberger LIS Tape Verification Listing Blueline Logs: Fluid Comp. Cement Bond Phasor Induction w/GR Repeat Formation Tester- 32 Pressure Stations Comp. Neutron Litho-Density & Microlog w/GR/Calipers Comp. Neutron Litho-Density (TVD) Comp. Neutron Litho-Density (MD) CDR (TVD) CDR (MD) Repeat Formation Tester 14.-Oct-1997 Army Induction (TVD) Array Induction (MD) Dipole Shear Sonic (MD) Dipole Shear Sonic (TVD) Gamma Ray CCL Formation Evaluation 2" MD Drilling Data Log 2" MD MWD 2" TVD MWD 2" MD Folder B- 1 ST: Folder B-2: Operations Summary Report Well Completion Report Directional Survey Permit to Drill Scan Well Test (Prod. Test # 1) Logs: CDR (TVD) Comp. Neutron Litho-Density w/GR (TVD) and (MD) Pressure Data Log Film: ADNR (TVD) Vellum: Pressure Data Log 1":250' Sepia: Pressure Data Log 1":250' Operations Summary Report Well Completion or Recompletion Report Well Test Results = Short & Long String Diskette: Surveys Diskette: Scan Data NF. ASC and SUN. AS Logs: Army Induction 2" MD Army Induction 5" = 100' MD Comp. Neutron Litho - Density W/GR Digital Sonic Tool - Long Array Dipole Sonic Relabelled Delta T's Formation Evaluation 2" TVD Drilling Data Log 2" MD Formation Evaluation 2"MD MWD Integrated Formation Evaluation 2" TVD MWD Integrated Formation Evaluation 2" MD Blueline Logs: G/R Collar Log Perf. Record 6-Feb-1998 G/R Collar Log Perf. Record 23-Jan-1998 Mechanical Sidewall Coring Tool Folder B-3: Completion Reports 99-021.doe Folder B-3ST: Folder B-3 BPI: i" :rations Summary Report f~' 'vermit to Drill; Sundry Approvals Blueline Logs: Platform Express Three-Detector Lift,o-Density Comp. Neutron/GR Caliper/GR MWD Integrated Formation Evaluation 2M TVD MWD Integrated Formation Evaluation 2" MD Formation Evaluation 2" MD Formation Evaluation 2' TVD Drilling Data 2" MD Film: Caliper Log/GR Sepias: Formation Evaluation 2' TVD Drilling Data Log 2" MD MWD 2" TVD Formation Evaluation 2" MD Pressure Data MWD 2"MD Vellums: Formation Evaluation 2" MD Pressure Data Log MWD 2" TVD Formation Evaluation 2" TVD Drilling Data Log 2" MD MWD 2" MD Blue Line Logs: Diskette: 4MM Tape: Film: Vellums: Direction Survey 0-17864' Formation Evaluation 2' TVD Formation Evaluation 2" MD MWD 2°° MD MWD 2" TVD Pressure Data Log 8918' TVD-12332' TVD Pressure Dta Log 9134' TVD-13368' TVD Drilling Data Log 2" MD Impulse TVD Impulse MD ADN4 MD ADN4 TVD Resistivity TVD 1:600 & 1:240 Resistivity MD 1:600 & 1:240 B3-ST1.LAS and Survey. TXT-Dir. Survey MD & TVD LAS Files (final data) Survey Files Resistivity 1:600 & 1:240 MD ADN4 MD Resistivity 1:600 & 1:240 TVD Formation Evaluation 2" MD Formation Evaluation 2" TVD Drilling Data 2' MD MWD Integ. Formation Evaluation 2" MD MWD Integ. Formation Evaluation 2" TVD Pressure Data Log Blueline Logs: Sepias: Formation Evaluation 2" TVD MWD 2" TVD Pressure Data Log Formation Evaluation 2" MD MWD 2"MD Drilling Data 2" MD MWD 2" MD Pressure Data Log Drilling Data Log 2" MD Formation Evaluation 2" TVD MWD 2" TVD Formation Evaluation 2" MD 99-021.doc 3 (2/3/99) General: Folder B- 1: Core Sample Report (B-l, B-1ST, B-2, B-3, B-3BP1, B-3ST) Geologic Tops (B-l, B-1ST, B-2, B-3) /Operations Summary Report Well Completion/Re-completion Report and Log Schlumberger LIS Tape Verification Listing Blueline Logs: Fluid Comp. Cement Bond Phasor Induction w/GR e' 32'~e~sure Repeat Formation Tester- Stations Comp. Neutron Litho-Density Comp. Neutron Litho-Density (TVD)- Comp. Neutron Litho-Density (MD)'" CDR (TVD). CDR (MD) -' Repeat Formation Tester 14-Oct-1997 Army Induction frVD) .. Army Induction (MD)' Dipole Shear Sonic (MD) Dipole Shear Sonic (TVD)" Gamma Ray CCL, Xt-~ ~ ,~ O ~ Formation Evaluation 2" MD Drilling Data Log 2~ MD MWD 2' TVD e MWD 2"MD e Folder B- 1 ST: Folder B-2: Diskette: Diskette: ~ I,.,.~ I,~ e. Logs: Operations Summary Report Well Completion Report Directional Survey Permit to Drill Scan Well Test (l~'od. Test #1) "' Logs: CDR (TVD) / Comp. Neutron Litho-Density w/GR ' (TVD) and (MD). Pressure Data Log Film: ADNR (TVD) '" Vellum: Pressure Data Log 1":250' e, Sepia: Pressure Data Log I":250'-' Operations Summary Report Well Completion or Recompletion Report Well Test Results = Short & Long String Surveys Scan Data NF. ASC and SUN. AS Array Induction 2" MD" Army Induction 5" = 100' MD" Comp. Neutron Litho - Density W/GR / Digital Sonic Tool - Long Army .' Dipole Sonic Relabelled Delta Ts ' Formation Evaluation 2" TVD - Drilling Data Log 2" MD ." Formation Evaluation 2" MD" MWD Integrated Formation Evaluation 2" TVD ~' MWD Integrated Formation Evaluation 2" MD ~ B lueline Logs: G/R Collar Log Perf. Record 6-Feb-1998 G/R Collar Log Perf. Record 23-Jan-1998 e, Mechanical Sidewall Coring Tool e- Folder B-3: 99-021.doc Completion Reports PHILLIPS PETROLEUM HOUSTON, TEXAS 77251-1967 BOX 1967 NORTH AMERICA EXPLORATION AND PRODUCTION COMPANY BELLAIRE, TEXAS 6330 WEST LOOP SOUTH PHILLIPS BUILDING December 25, 1998 North Cook Inlet Unit "B" No. 3 PPCo. Tyonek Platform North Cook Inlet Unit, Alaska Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Attn: Blair Wondzell Gentlemen: Enclosed for your consideration and approval are three copies of Form 10-403 (Application for Sundry Approval) and a copy of the tentative workover program for the NCIU B-3 well. Included in the program are the BOP schematic and the well control policy for the workover. The workover and the BOP test procedure was given verbal approval on Dec. 18, 1998 by Blair Wondzell. Should you have any questions or require any additional information, please contact Paul R. Dean at (713) 669-3502 or Raj Hingorani at (713) 669-3554. Regards, / N. P. 0msberg North America Drilling Manager CC: J. W. Konst (wenc) L.L. Lyon (w/o enc) P. R. Dean (w/enc) Central Files STATE OF ALASKA '~. OIL AND GAS CONSERVATION COMMISSION~ ,CATION FOR SUNDRY APPRO~,. 1. Type of Request' Abandon Suspend Change Approved Program Time Extension 2. Name of Operator: Phillips Petroleum Co. 3. Address: 6330 W. Loop South~ Bellaire~ Texas 77401 4. Location of well at surface: Tyonek Platform Leg 1 Slot 2 4029' FSL & 4056' FEL SEC 6-T 11N-R09W At top of productive interval: At effective depth: At total depth: ( 17318' MD · 13356' TVD) 4036' FSL & 3282' FEL SEC 13-T11N-R10W 12. Present well condition summary Operation Shutdown __ Re-enter Suspended Well X Alter Casing Plug.cling Stimulate Pull Tubin,cj Amend Order Type of Well Development X Exploratory Strati~raphic ,, Perforate Other 6. Datum Elevation (DF or KB) RKB = 132 feet 7. Unit or Property Name North Cook Inlet Unit 8. Well Number NCIU B-3 9. Permit Number 0. APl Number 50-883-20095 11. Pool North Cook Inlet Unit Field Development Total Depth measured 17,864' feet true vertical 13,356' feet Plugs (measured) Effective Depth measured 17,864' feet true vertical 13,356' feet Junk (measured) Casing Length Size Structural , 30" Conductor 20" Surface 13-3/8" Intermediate 9 5/8" Liner 7" Production 5" Production 3 1/2" Perforation Depth: measured N/A true vertical N/A Cemented Driven Existing Existing Existing Existing Cemented Cemented Measured Depth True Vertical Depth 461' 461' 1214' 1208' 4400' 3752' 11761' 8918' 15301' 11,379' 17150' 12,777 17,864' 13,356' Tubing (size, grade, and measured depth) Packers and SSSV (type and measured depth) Long St. 3 1/2" 12.95~ PH6 P-110 from surface to 11,400 3 1/2" 12.95~ FL4S P-110 from 11,400 to 13,700' Halliburton" AHC" Packer ~ 11,400' Halliburton "Series 10" SSSV {~ 417' Four Camco TMP 3 1/2" x 1" GLM's (~ 5060',7835', 9725', & 11240'. Approval is requested to reenter suspended well and run 3 1/2" production tubing to 13,700'. No perforating will be done at this time. ORIGINAL 13. Attachments · Description summary of proposal _X_ Detailed Operations Program _X_ BOP sketch _X__ t14. Estimated Date for Commencing Operation: ~1 December 25~ 1998 I 16. If proposal was verbally approved .' . Blair Wondzell 12/18/98 Name of Approver Date Approved 17. I hereby~c~( that the foregoing is true and correct to the best of my knowledge Signed~.~""~ ~. ~ Title Sr. Drillin~l Engineer, spec Date Commission Use Only/ Conditions of Approval: Notify Commission so representative may witness __ Plug Integrity __ BOP Test ~" Location Clearance __ Mechanical Integrity Test __ Subsequent Form Required 10-t~O'1 Original $~gn~;u dy David W. Johnston 5. Status of well classification as: Oil Gas Suspended X (TA) Service Approved by Form 10-403 Rev. 12-1-85 by order of Commissioner the commission December 25~ 1998 lApproval No.~"~'~......(~i ~ ,'.i .~, ',It '~ ~,} ~ in triplicate December 23, 1998 Houston, Texas Subject: North Cook Inlet Unit No. "B" - 3 North Cook Inlet Unit Tyonek County, Alaska OBJECTIVE The objective of this workover is to recover the TA RBP and run a 3 ½" production string w/GLM's and SCSSV to 13,700' and set a Halliburton AHC retrievable packer at 11,400'. This work will prepare the well for future testing. PRESENT STATUS The well was originally drilled in 1998 to a total depth of 17,864. This well was temporarily abandoned on 11/1/98 with RBP set at 11,406'. There are no perforations in the well and the fluid in the 9 5/8" casing is 10.5 CaCI. North Cook Inlet Unit B#3 Completion Procedure WELL CONTROL PROCEDURES This well should contain no pressure. Rig up 10M BOP. Test all rams to 250 psi low and 5000 psi high. Test Annular to 250 psi low and 2500 psi high. The BOP equipment is 10000 psi WP Class 4, which exceeds Phillips Well Control Manual requirements. The top set should be 3 ½" x 5" variable pipe rams, and the middle set should be blind rams. The wellhead is rated to 10,000 psi. The Alaska Oil and Gas Conservation Commission (AOGCC) should be notified prior to conducting BOP tests. The notification to AOGCC should be made early for them to witness the test if they desire. Well control drills are to be conducted with each crew as per Phillips well control manual. Drills should be reported on the IADC daily drilling report and on Phillips Daily Drilling Report. North Cook Inlet Unit B#3 Completion Procedure December 23,1998 Page 3 WELL DATA RKB to THF Casing Fluid SCSSV Tubing Hanger Tubing Head : Casing Spool : Retrievable Bridge plug: 53.OO fi 10.5 ppg CaCL Halliburton "Series 10" TRSSV ~ 418' 11" x 3 ½" Vetco Gray 13 5/8" 5M X 11" 10 M 21" 3M X 13 5/8" 5M Halliburton Model 3L - Set at 11,406' CASING PROGRAM SIZE DEPTH (MD) DEPTH (TVD) WT (PPF) GRADE CONN BURST COLLAPSE TENSION 30" 407 407 20" 2579 2571 133 K-55 Tencom 2860 1410 1700 13-3/8" 3760 3521 72 L-80 SL/X 4730 2520 761 9-5/8" 10376 8846 53.5 P-110 BT&C 8710 7500 1159 7" 15301 11379 32 P-110 BT&C 9960 10170 688 5" 17159' 12,782' 18 P-110 VAM 13940 13450 3-1/2" 17854 13350 12.95 P-110 PH-6 14240 17470 232 TUBING PROGRAM SIZE DEPTH (MD)'DEPTH (TVD) WT (PPF) GRADE CONN BURST COLLAPSE TENSION , 3-1/2" 13,700 10310 12.95 P-110 BTS-6 14240 17470 232 SUNFISH PRESSURE N. FORELANDS PRESSURE COMPLETION FLUID 6300 PSI 9600 PSI 10.5 PPG CaCl2 BOTTOM-HOLE 210 F TEMPERATURE North Cook Inlet Unit B#3 Completion Procedure PROCEDURE Skid rig over to NCIU B-3. Open valve on dry hole tree to bleed pressure off (should be static). ND dry hole tree. NU risers, 13 5/8" 10M BOP"s. Test the BOP's as written in the Well Control Procedures section above and as per PPCo. Well Control and AOGCC reccomendations. Service & Equipment: a) BOP's - Specialty Rental b) 11 10Mx 13 5/8" adapter flange - Swaco c) BOP Test - AOGCC -(Blair) 2. RIH w/5" drillpipe w/retrieving tool and retrieve 9 5/8" Halliburton CL3 RBP ~ 11,406'. POOH. Service & Equipment: a) Retrieving tool and Service man - Halliburton (Rex) b) 5" tbg tongs, slips & elevators - Weatherford (T.J.) 3. RU Wireline. RIH w/8.3" gauge ring and junk basket to 11,425'. RIH w/4" gauge ring to 14,000'. RIH w/2.25 gauge ring to 17,550'. RD Wireline. Service & Equipment: a) Wireline Service - Alaska Pipe Recovery - (Billy) b) 8.3" Gauge ring and Junk Basket - Schlumb (Roy) c) 4" and 2.25" gauge ring - Pallard (Freddy) . RIH w~ 3 lA" 12.95# PH-6 P-110 production string (details attached). Test SCSSV control line connection to 10000 psi. Maintain 3000 psi on control line while running in hole. Space out. Land dual hanger. Test control line connections through tubing hanger to 10000 psi. Engage lock down screws. Note: The first 2300 'of3 ~" that are run in the hole shouM be the FL4S flushjoints. Note: Inform service man with Vetco Gray that we will only need one line through the hanger for the long string SSSV, although the initial plans were to run four lines for two SSSV's and two chemical injection lines. Service & Equipment: a) 3 1/2" tbg tongs, slips & elevators (weatherford) b) Dual combination elevators - Weatherford (T.J) c) 3 ½" tubing- Tuboscope (Butch) d) Hanger and service man - Vetco Gray (Merle) e) pin x pin sub - 31/2" x 3 ½" - weatherford f) 3 ½" SSSV, 4 GLM's, Sliding sleeve, packer- Halliburton (Rex) g) 3 crossovers from PH6 BxB, PH6-FL4S BxP, FL4S BxMuleshoe - Unique Machine (Pat) ..... ~ ~ ~. h) Plug Rental to run FL4S-MRO Sales-(Randy) ~ E"~~ North Cook Inlet Unit B#3 Completion Procedure 5. Reverse circulate 15 bbl (300 fi) of 70/30 Glycol/2% KCL Packer fluid at 0.5 BPM. . a) Packer Fluid -Baroid (Wade) RU Slickline. Set plug (rated to 5400 psi) in X-nipple (2.313") at 11,420'. Pressure up continuously w/Halliburton Pump on tubing to 4500 psi (15 minutes) to set 9 5/8" Halliburton AHC Packer. Pressure up on annulus with rig pump to 500 psi (5 minutes) to check if packer is set. Service & Equipment: a) Slickline and plug -Halliburton (Rex) b) Packer and Pump Service man - (Rex & Machado) . Close SSSV with 1000 psi on tubing. Bleed off from above to confirm closure volume bled back. Install BPV w/test plug. Test casing as planned to 5500 psi. ND BOPE and riser. NU 10M tree and flowline. Test tree to 7500 psi for 15 minutes. Pull BPV and test plug. Close master valves on tree. Remove all remaining rental items (choke manifold, BOP's, etc.). Charge Demob of equipment to Demob AFE. Service & Equipment: a) BPV and service man- Vetco Gray (Merle) North Cook Inlet Unit B#3 Completion Procedure NCIU B-3 PROPOSED DIAGRAM 12o" ~ 1214' MD (1208' TVD) 10.5 ppg 1 CaCI2 Casing & Liner ID's 9 5/8" 53.5# - ID - 8.535 Drift - 8.379 5' 18# - ID - 4.276" Drift - 4.151" 3 1/2" 12.95~ ID - 2.75" Drift - 2.625" 113-3/8" li~ 4400' MD (3752' 'FVD) I GLM # 1 5060' (MD) 4200(TVD) GLM # 2 7835'(MD) 6100('rVD) ITubing - ID's & OD's 3 1/2" 12.95~ PH-6 ID - 2.75" OD - 4.313 Drift - 2.625' 3 1/2" 12.95~ FL4S ID -2.75" OD 3.5" Drift - 2.625" GLM # 3 9725'(MD) 7450(TVD) GLM# 4 11240(MD)' 8550(TVD) sliding sleeve below ~ 11,364' AHR 9 5/8' x 4 1/2" Packer ~ 11,400' MD [TOL 5" e 11,450' MD (8697, 'rVD) ITOL 7' ~ 11,545' MD (8765' 'rVD) ] 9-5/8" 53.5# Pl10 ~ 11,761' MD (8918' 'rVD) Burst - 10,900 psi 3 112" PH-6 12.95~ P-110 FL,IS tubing ~ 13,700' MD I TOC li~ 14,300' MD (10,734' 'I'VD) I 7" 32# P-110 {~ 15,301' MD (11,379' TVD) Burst - 10,760 psi Top of Sunfish Sand le 16,780' MD 12,485' TVD ITop of N. Forelands Sand ~ 17,483' MD 13,032' 'i'VD (burst - 10,900 psi) ID - 2.75" 5" 18~ ~ 17,159' MD (12,785' TVD) I Burst - 13,450 psi I 13-1/2" @ 17,854' MD (13,346' 'I'VD) Prepared by: N. Hingorani December 14, 1998 NCIU B-3 TEMPORARY SUSPENSION DIAGRAM 12o" O 1214' MD (1208' 3'VD) I~ 10.5 ppg CaCI2 · INote: Liner lap will be negative tested prior to setting RBP. IRBP i~ 11,406' MD (8680' TVD) I ITOL 5" ~ 11,450' MD (8697' TVD) I ITOL 7" ~ 11,545' MD (8765' TVD) I 11,761' MD (8918' TVD) I I TOC ~ 14,300' MD (10,734' TVD) I 17"O 15,301' MD (11,379' 3'VD) Top of Sunfish Sand @ 16,780' MD 12~485' TVD Top of N. Forelands Sand tl~ 17,483' MD 13~032' TVD m3-1/2- ~ 17,864, MD (13,356' ~D) Prepared by: Shonna Boyer October 17, 1998 Halliburton Energy(' arvices Installation Report , ~ust~e~' ~ustomer R el:~ase~ative ~/atl Field Date Phillips Petroleum CompanylB-3 NCIU 12/21/98 Draw~ t.m # Oe~.m*io~ ~O OD L.~h 1_~--.-~' '-" ,LONG STRING :- lA Dual Hanger (PxB) 3.5" 11" 2 0.0 , ~ 3 1/2" 12.95~ P-110 Pin x Pin Sub 2.75 3.5 2 2.0 3 1/2" PH-6 12.95~ P-110 tb~l. (BxP) 2.75 4.313" 408 4.0 3 1/2" PH-6 12.95# P-110 Pup (BxP) 2.75 4.313 5.78 412.0 ~_ :1 1 HES Sedes 10 TRSV (BxP) 2.562 5.63 8.1 417.8 3 1/2" PH-6 12.95# P-110 Pup IBxP) 2.75 4.313 9.76 425.9 3 1/2" PH-6 12.95# P-110 tb~]. IBxP) 2.75 4.313" 4599 435.6 3 1/2" PH-6 12.95# P-110 Pup (BxP) 2.75 4.313 17.81 5034,6 X-O 3 1/2" PH-6 x CS Hydril (BxP) 2.75 4.313 I 5052.5 2 Camco TMP 3 1/2" x 1" GLM # 1 (BxP) 2.867 4.313 7.69 5053.5 X-O 3 1/2" CS Hydril x PH-6 (BxP) 2.75 4.313 1 5061.1 3 1/2" PH-6 12.95# P-110 Pup (BxP) 2.75 4.313 3.73 5062.1 3 1/2" PH-6 12.95# P-110 tbs. (BxP) 2.75 4.313" 2750 5065.9 3 1/2" PH-6 12.95# P-110 Pup (BxP) 2.75 4.313 17.74 7815.9 X-O 3 1/2" PH-6 x CS Hydril (BxP) 2.75 4.313 I 7833.6 3 Camco TMP 3 1/2" x 1" GLM # 2 (BxP) 2.867 4.313 7.56 7834.6 X-O 3 1/2" CS Hydril x PH-6 (BxP) 2.75 4.313 I 7842.2 2 3 1/2" PH-6 12.95# P-110 Pup (BxP) 2.75 4.313 3.74 7843.2 ~ 13 1/2" PH-6 12.95# P-110 tbs. (BxP) 2.75 4.313" 1860 7846.9 3 1/2" PH-6 12.95# 15-110 Pup (BxP) 2.75 4.313 17.82 9706.9 X-O 3 1/2" PH-6 x CS Hydril (BxP) 2.75 4.313 1 9724.7 4 Camco TMP 3 1/2" x 1" GLM # 3 (BxP) 2.867 4.313 7.71 9725.7 = :3 X-O 3 1/2" CS Hydril x PH-6 (BxP) 2.75 4.313 1 9733.4 , 3 1/2" PH-6 12.95# P-110 Pup (BxP) 2.75 4,313 3.75 9734.4 3 1/2" PH-6 12.95# P-110 tb~l. (BxP) 2.75 4.313" 1480 9738.2 3 1/2" PH-6 12.95# P-110 Pup (BxP) 2.75 4.313 17.74 11218.2 4 X-O 3 1/2" PH-6 x CS H~/dril (BxP) 2.75 4.313 1.01 11235.9 5 Camco TMP 3 1/2" x 1" GLM # 4 (BxP) 2.867 4.313 7.61 11236.9 X-O 3 1/2" CS H~/dril x PH-6 (BxP) 2.75 4.313 1.02 11244.6 5 3 1/2" PH-6 12.95# P-110 Pup (BxP) 2.75 4.313 3.82 11245.6 3 1/2" PH-6 12.95# P-110 tbcj..(BxP) 2.75 4.313" 110 11249.4 .--~ 6 HES RU Slidin~l Sleeve (BxP) 2.562 4.82 3.95 1135.9~4 3 1/2" PH-6 12.95# P-110 tb~l. (BxP) 2.75 4.313" 31 11363.3 3 1/2" PH-6 12.95# P-110 Pup (BxP) 2.75 4.313 8 11394.3 ~ 7 X-O 3 1/2" PH-6 x 4 1/2" EUE (BxP) 2.75 4.313 1 11402.3 __-~,~, 8 HES AHC Packer 4 1/2"EUE (BxP) 3.88 8.3 5.54 11403.3 ~7 9 X-O 4 1/2" EUE x 3 1/2" PH6 (BxP) 2.75 4.313 1 11408.9 13 1/2" PH-6 12.95# P-110 Pup (BxP) 2.75 4.313 3.82 11409.9 13 1/2" PH-6 12.95# P-110 Pup (BxP) 2.75 4.313 10 11413.7 ,~ _..___~3 10 X-O 3 1/2" PH-6 x 2 7/8" EUE (BxP) 2.441 4.313 1 11423.7 11 2 7~8" X-Nipple EUE (B xP) 2.313 3.25 0.88 11424.7 ~ cj 12 X-O 2 7/8" EUE x 3 1/2" FL4S (BxP) 2.441 3.66 0.84 11425.6 3 1/2" 12.95# FL4S P-110 tb~l (BxP) 2.75 3.5 2300 11426.4 _ 1 C 13 3 1/2" Muleshoe (FL4 S Box x M-shoe) 2.992 3.5 0.66 13726.4 _ I Already Made up Length -- 23.64' '~31.23 .- 31.04 31.28 Prepared by N.S.Hingorani December 22, 1998 Flowline Fill-up Line Kill Line I I HCR Valve Gate Valve 13 518" EM Annular Preventer 13 518" 5M x 13 518" 1OM Adaptor I Gate Valve HCR Valve 13 518" 10M Variable Bore Pipe Rams (3 1/2" x 5" variable) 13 $18" 10M Blind Rams 13 5/8" 1OM Flange 13 GIB" 1OM Flange Choke Line 13 $/8" 10M Riser Adapter Flange 13-5/8" 1OM x 11" 1OM Tubing Head 13-518" GM x 11" 1OM 13 518" 1OM Flange 13 $18" 1OM Flange 11" 10M Flange 11" 10M Flange 13 GIB" GM Flange 13 $/8' GM Flange 20" Casing 13 Gl8" 1OM BOP and Riser System 13 318" Casing 9 Gl8" Casing PHILLIPS PETROLEUM COMPANY North Cook Inlet Unit "B" No. 3 NSH / DEC. 25~ 1998 Al3 A7 AiI, A18 A5 A3 A4 Al, A8 ALL DIMENSIONS ARE APPROX. lk II I! SINGLE CHRISTlVlAS TREE ASSEMBLY ACAD -- _L TOTAL P.05 ALASKA PROJECT CONTACT LIST COMPANY POOL ARCTIC PALLARD BAKER BAKER BAKER BAKER HALLIBURTON HALLIBURTON HALLIBURTON VETCO GRAY SCHLUMBERGER SCHLUMBERGER MRO SALES ALASKA PIPE RECOVERY UNIQUE MACHINE TUBOSCOPE WEATHERFORD BAROID FMC SPECIALTY RENTAL GLOBAL COMP. SERV. AOGCC UNOCAL PPCo PPCo PPCo PPCo PPCo PPCo PPCo PPCo PPCo PPCo CONTACT Freddy Pallard Todd Dewey, Creig Boyd ADAM JOHNSTON DANE DUNIGAN CARL SONNIER DAN WUTHRITCH DON HOLCOMBE REX THOMAS JOHN BUSBY MERLE MIKE MACIEJEWSKI RUSSEL WAGSTAFF ROY VANDERSLUIS RANDY ELI_AGE Billy/Howard Mike/Pat FRANK/BUTCH TJ/JD JOHN ROSE/LENUS KING KEVIN HITE JOE VANMATRE MIKE DUHON BLAIR WONDZELL DALE HANES NORM OMSBERG JIM MAGEE LINDSEY LYON RAJ HINGORANI SHONNA BOYER PAUL DEAN J. ADMIRE DAVID BEARDMORE LEN JANSON MARC LEVEQUE PHONE 907-561-7447 (907) 283-7006 (907) 561-1939 (907) 776-8131 713-625-6828 ON) 713-625-6818 ON) 800-451-6231 (P) 713-625-6800 ON) 281-389-5655 (M) 907-344-2929 (W) 907-229-2650 (M) 713-243-2486ON) 907-283-7531 (W) 281-405-3565 (w) 907-522-3940 281-556-7288 (W) 907-776-8155 907-776-8155 ON) 907-344-4452 ON) 1-907-283-9576 (907) 563-3012 ON) 907-776-5137 907-776-8148 (W) 907-248-3511 713-620-7130 (W) 907-563-3990 (W) 318-837-3396 ON) 281-980-4545(W) 907-279-1433 (W) 907-276-7542 (F) 907-263-7660 (W) 713-669-7550 ON) 907-776-6035 ON) 713-669-2173 ON) (713) 202-0255(m) 713-669-3554 ON) 713-626-2532 (H) 713-669-7980 ON) 713-669-3502 ON) 281-980-1557 (H) 907-279-1433 (W) 713-669-2198 ON) 281-261-5554 (H) 907-776-6046 ON) 713-669-2969 ON) (281)- 265-9569 SERVICE CONTRACTOR Gauge rings 281-356-3678 (H) 713-828-9699 (M) 800-425-4577 (P) FISHING TOOLS 907-344-3540 (H) TESTING 907-344-6746 (F) 713-243-2472 (M) PACKERS, SLIDING SLEEVES, SCSSV sarex@ptialaska.net PACKERS, SLIDING SLEEVES, SCSSV 281-434-1254 (p) 713-252-4547 (M) 907-398-2881 907-562-1376 (F) 713-528-6581 (F) x 226 (281) 565-3140 (H) (281) 363-9145 (H) (800) 424-6902 (p) 800-425-1334(p) COIL TUBING WIRELINE Plugs to run FL4s Wireline TUBING CREWS, WORKSTRING FLUIDS WELLHEAD. TREE BOP's BRISTLE BRUSH REGULATORY RIG DRILLING MANAGER MATERIALS SUPERINTENDENT COMPLETIONS ENGR DRILLING ENGINEER Sr. DRILLING ENGR ENVIRONMENTAL BRINE SPECIALIST PRODUCTION ENGR COMP. DIRECTOR · . DIMENSIONAL DATA SHEET ALASKA PART NUMBER/SERIAL DESCRIPTION LENGTH O.D. I.D. DRIFT TEST PSI THREADS NUMBER 3 1/2" 12.95# P-110 Pup Joint 17.82 4.320 2.687 2.52 5000 PH-6 Box x Pin Customer Supplied X/O 3 1/2" PH-6 x CS Hydrill B x P 1.00 4.320 2.687 2.52 5000 Ph-6 x Cs Hyd. B x P 999-081 Camco TMP 3 !12" x !" GLM # 3 7.71 5.620 2.867 2.52 5000 Cs Hydrill B x P 403-2052-000'00 X/O 3 1/2" CS Hydrill x PH-6 B x P 1.00 4.320 2.687 2.52 50[]0 Cs Hydrill x Ph-6 B x P 999-081 3 1/2" 12.95# P-110 Pup Joint 3.75 4.320 2.687 2.52 5000 PH-6 Box x Pin Customer Supplied OVER-ALL LENGTH 31.28" 3 1/2" 12.95# P-110 Pup Joint 17.78 4.320 2.687 2.52 5000 PH-6 Box x Pin Customer Supplied · X/O 3 1/2" PH-6 x CS Hydrill B x P 1.01 4.320 2.687 2.52 5CK~ Ph-6 x Cs Hyd. B x P 999-081 camco TMP 3 !/2" x I" GLM # 4 7.61 5.620 2.867 2.52 5000 Cs Hydrill B x P 403-2052-000-00 X/O 3 1/2" CS Hydrill x PH-6 B x P 1.02 4.320 2.687 2.52 5000 Cs Hydrill x Ph-6 B x P 999-081 3 1/2" 12.95/I P-110 Pup Joint 3.82 4.320 2.687 2.52 50(X] PH-6 Box x Pin Customer Supplied OVER-ALL LENGTH 31.24" HES RU Sliding Sleeve 3.95 4.820 2.562 2.52 5000 Ph-6 B x P 621 RU25604 AHC PACKER ASSEMBLY 3 1/2" 12.95# P-110 Pup Joint 8.00 4.320 2.687 2.52 300 PH-6 Box x Pin Customer Supplied X/O3 1/2" PH-6x4 1/2"EueBxP 1.00 4.320 2.687 2.52 300 3 1/2"Ph-6x41/2"EueBxP 999-081 HES AHC PACKER 5.54 8.300 3.880 2.52 300 4 1/2" EUE Box x Pin 12AHC96380-E X/O4 1/2" EUEx3 1/2" PH-6 BxP 1.00 4.320 2.687 2.52 300 4112"Euex31/2"Ph-6BxP 999-081 3 1/2" 12.95# P-110 Pup Joint 3.82 4.320 2.687 2.52 300 PH-6 Box x Pin Customer Supplied OVER-ALL LENGTH 19.36' MEASURED BY: DATE: CHECKED BY: FIELD TICKET NO. PHONE NO. J 283-7531 Page 2 DIMENSIONAL DATA SHEET ALASKA PART NUMBER/SERIAL DESCRIPTION LENGTH O.D. I.D. DRIFT TEST PSI THREADS NUMBER TRSV ASSEMBL Y 3 1/2" 12.95# P-110 Pup Joint 5.78 4.320 2.687 2.52 50[~ PH-6 Box x Pin Customer Supplied HES Sefle~ 10 Ibg. Retr. Safety VaNe 8.10 5.630 2.562 2.52 ,50(]0 PH-6 BOX x Pin 778FM3501 3 1/2" 12.95# P-110 Pup Joint 9.76 4.320 2.687 2.52 5000 PH-6 Box x Pin Customer Supplied i OVER-ALL LENGTH 23.64" GLM ASSEMBLIES 3 1/2" 12.95# P-110 Pup Joint 17.81 4.320 2.687 2.52 5000 PH-6 Box x Pin Customer Supplied X/O 3 1/2" PH-6 x CS Hydrill B x P 1.00 4.320 2.687 2.52 5000 Ph-6 x Cs Hyd. B x 'P 999-081 Camco TMP 3 1/2"x 1" GLM it I 7.69 5.620 2.867 2.52 5000 Cs Hydrill B x P 403-2052-000-00 X/O 3 1/2" CS Hydrill x PH-6 B x P 1.00 4.320 2.687 2.52 5000 Cs Hydrill x Ph-6 B x P 999-081 3 .1/2" 12.95# P-110 Pup Joint 3.73 4.320 2.687 2.52 50(X] PH-6 Box x Pin Customer Supplied OVER-ALL LENGTH 31.23' .. 3 1/2" 12.95# P-110 Pup Joint 17.74 4.320 2.687 2.52 5000 PH-6 Box x Pin Customer Supplied X/O 3 1/2" PH-6 x CS Hydrill B x P 1 .CI0 4.320 2.687 2.52 5000 Ph-6 x Cs Hyd. B x P 999-081 camco TMP 3 112" x I" GLM it 2 7.56 5.620 2.867 2.52 5000 Cs Hydrill B x P 403-2052-000-00 X/O 3 1/2" CS Hydrill x PH-6 B x P 1.00 4.320 2.687 2.52 5000 Cs Hydrill x Ph-6 B x P 999-081 3 1/2" 12.95# P-110 Pup Joint 3.74 4.320 2.687 2.52 5000 PH-6 Box x Pin Customer Supplied ii OVER-ALL LENGTH 31.04" MEASURED BY: DATE: CHECKED BY: FIELD TICKET NO. PHONE NO. , J 283-7531 Page I ahc963 $0.pdf at ~echweb.cifw.! et. eom Page 1 of 2 .. --" No: 12AHC96380-W Bas~ I~sign and Main~ Instructions Date: 4-3-97 Halliburton AHC Pad(er/Cut-To-Release R/N: 970400 Page 1 of 8 Design Overview The Hall~unoa AHC Packer i~ a retrievable, hydraulic-~t pro4u¢~ion pacl~r with a chemi- cal cut-to-relcas¢ type of ~k;a~, When properly and complemly cut, the packer will re-lease and all o£ the packer componenl~ along with lhe tai¥ipe can be reuieved imm the well. The p~ker is set by pressuring up the mbin~ slfin§ against a plugging device below the packer. An external barrel-type slip holds the packer agains~ well pressures fi, om above and below. The inrtmml slip~ mainzaia the pacier in the set position. Once ~his packer is run and set, it is fcic, used by a chemical curm- and/or a straight pull release by adjusting the shear value o£ the shear ring. A nipple profile must be installed 10 fl or less below the packer for locating the chemical cutter. Ref~r to the F. ngineering Design Specifications for specific design information. Design Principle The packer is made up into the tubing string and Iower~d ~o the desired s~tting depth. Circu- lating a ball down ~o land in a carchex sub assembly or using a wireline plug allows the set- ting s~ng m be pressurized trom the surface m the plugging device below the packer. Pr~sure is applied to the tubing ~tring and ea~ the cylinder/pisrm cavity through a port in the man&el. The pressure forces ~le lower element retainer apw~'d, sheming the setting shear scr~w~. The cie, meats compress, shearing thc dfiv-lok pim ia the bosom wedge and £orci~g ~ slip m ramp ou.tward, biting into the casing. The int,.mai slips seize the stationary piston ,md lock the pack~r in tie set position. The pack~ i~ now completely set and can be rel~_~_~d by a straight pull release orby using a chemical cut, er to part the main mandrel in it~ de~igmteA urger cur zone. Tl~s Halh'but~on packa'im &dgned to be rdessed by chemically cutting ~ packer m`m&'d. When p~perly and completely cur, the pa .cker will release and all packer components and the tailpip¢ can be reuieved from the w¢llbore. This packer does not have an integral l~cating prolile. In tim completion design, it ii recom- mended tha~ a no-go or kr. ating p~file be provided within ten feet of rim packer mandrel cur zone. This distance must be accura~ly measured prior to running the completion and main- ~ned in the well files where it o,, be retrieved f~r £u~we m/erence` http ://techWeb.dfw.halnet.com/cpns2/infofodmi/12/ahe963 80.pdf 12123198 HALLIBURTON AH____C HYDRAULIC-SET RETRIEVABLE PACKER CASE-CARBURIZED BARREL SLIP CASING: TUBING: MAX. OD: MIN. ID: MATERIAL: ELASTOMERS: SERVICE: TEMP. RATING: TENSILE RATING: BURST: COLLAPSE: DIFF. RATING: SE'I'FING PRESSUKE: PISTON AREA: RELEASE: 9 5/8" 43.5-53.5 4 I/2" 12.6 ppf 8.30" 3.88" 9Ct- 1 Mo/Alloy Nitrile/Viton H2S/CO2 275 degr. F. 288,000 lbs 8430 psi 7500 psi 7500 psi 4000 psi .,.- pa 16.27 sq.in. Cut-To- Release or Shear Ring THREE-PIECE MULTI-DUROMETER ELEMENT PACKAGE SETTING PISTON/CYLINDER · · INTERNAL SLIPS START-TO-SET SHEAR SCREWS" ADJUSTABLE SHEAR RING 12AHC96380-W ITEM: 12AHRglB00-V DESCRIPTION. PICK 9 5/8 4%53.5 5 1/2 2 VAM B-S/12AHC97470-V CASING SIZE 9 5/8 WEIGHT RANGE 47-53.5 MAXIMUM OD 8.300 8.300 MAX MrNIMUM ID 4.758 DRIFT SIZE (IN) AND PART NO 4.654 X 18.00 TOP THREAD a'//z. -5-~-20.0 VAM-STD BOTTOM THREAD ~ 4-1/z' VAM-STD LENGTH 72.O7 MATEI~AL ALLOY 80 MY SERVICE H2S TEMPERATURE RATING 275 HANGER TYPE YES TORQUE 5860=7160 TEST FIXTURE MT 203 MT 204 TEST PKESSURE 300 PISTON AREA 16.21 SETTING PRESSURE 4000 7500 (MAX) 12oo (STAXT)- 240 (PER SCR) SHEAR. VALUE PER SCREW, LBS FORCE 3900 (SETTING) SHEAR. VALUE-TOTAL 19,500 (SET) HOLES AVAILABLE FOR SCREWS 1(5 (SETTING) BUR. ST PRESSURE (CALC) 9190 COLLAPSE PRESSURE (CALC) 8395 TENSILE STKENGTH., CALC/1000 465.0 DIFFERENTIAL PRESSURE 7500 (ABOVE) 7500 (BELOW) ELEMENT MATERIAL NITRILE 90=70 O-KING MATERIAL' VITON TYPE RELEASE CHEMICAL CUT OK ADJUSTABLE SHEAX RING REMARKS IT IS RECOMMENDED TO PRE-PLAN FOR CUT TO RELEASE BY PROVIDING A SEPEKATE WIKELINE TOOL STOP NEAR THE BOTTOM OF THE PACKER. SEE BDMI. CHEMICAL CUT DATA SHEET CUT TO RELEASE DATA (SEE BELOW) TOP OF PKK TO BTM OF CUT ZONE 54.78 KEF ONLY LENGTH OF CUT ZONE 12.63 KEF ONLY OD UTZO + ID OF CUT ZONE 4C_/~8. KEF ONLY MATERIAL OF CUT ZONE ALLOY 80MY CHEMICAL CUTTER LINE NO 84P ADAPTER PART # 12 H 9530 o, REPLACES BULLNOSE ON CHEM CUTI~R) . BOTTOM THREAD I 1/16-10UN BOX (ADAPTER) TENSILE STRENGTH AFTEK CUT 407,100 KEMAKKS IT IS RECOM~NED TO PLACE THE MIDDLE OF THE CHEMICAL CUTTEK HEAD 1 TO 2 INCH ABOVE THE BOTTOM OF THE CUT ZONE. AD]'USTABLE SHEAR KING (SEE BELOW) SHEAR. KING SHEARS AT 591.0 K FOR STRAIGHT SHEAR RELEASE THE SHEAR KING CAN BE ADJUSTED BEFORE RUNNING DOWNHOLE ADJUSTABLE SHEAR RING REDUCE SHEAR VALUE BY MACHINING AWAY TEETH. EACH TOOTH SHEARS AT 30.0 K OK 950 DIFF PRESS HALLIBURTO'N DURASLEEVE® CIRCULATION/ PRODUCTION SLEEVE The Halliburton D~RASLEEVE circulation and produc- t'ion sleeve is a full-opening device with an inner sleeve that can be opened or closed using standard slickline methods. This sleeve enables communication between the tubing and tubing/casing annulus. A Halliburton X® or R® nipple profile is featured above' the inner sliding sleeve and a polished packoff area below as an integral part of the assembly. This design provides for an additional landing nipple in the tubing string for a wide variety of Halliburton flow control equipment and the option to pack it off. A three-position collet lock helps keep the sleeve in full open, equalizing or full-closed position. Equalizing ports in the inner sleeve are designed to allow pressure differential between the tubing and casing annulus to equalize while shifting into the full-open or dosed position. Any number of circulation equipment pieces may be run in a single tubing string and all opened or all closed on a single slickline trip. Individual sleeves may also be opened or closed selectively as needed. Compression, tensile, and burst strength of Halliburton drculation equipment are equal to or greater than N-80 tubing. Models are also available in strengths equal to or greater than P-Il0 tubing. The DURA. SLEEVE drculation and production sleeve is used for a variety of installations. It is available in two shifting versions: down to dose and up to open or up to close and down to open. Models are also available for standard and heavyweight tubing and high-temperature service. All have a circulation/production area equivalent to the tubing area. The new DURATEF ECM seal is a non-elastomer engineered composite material (ECM) available only from Halliburton. DURATEF ECM is so advanced that temperature and pressure ranges for testing have been expanded dramatically, resulting in a new specification for sleeves. During testing, DU-RASLEEVE devices were repeatedly opened against 5,000 psi (345 bar) differen- tial pressure with no seal damage. Landing Nipple Profile Closing Sleeve Equalizing Ports Flow Ports Buffer Seal ECM Seal Stack High Strength Body Joints Lower Polished Bore Halliburton DURASLEEVE® Circulation/Production Sleeve i 4-22 sUBsURFACE FLOW CONTROLS " PHILLIPS PETROLEUM HOUSTON, TEXAS 77251-1967 BOX 1967 AMERICAS DIVISION COMPANY December 30, 1998 BELLAIRE, TEXAS 6330 WEST LOOP SOUTH PHILLIPS BUILDING Mr. Blair Wondzell Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive. Anchorage, Alaska 99501 Dear Mr. Wondzell: Phillips Petroleum Company has received approval for an "Operation Shutdown" on the North Cook Inlet Unit B No. 3. I have attached the Daily Operational Reports for this time to accompany the Form 10-404. If you have any queStions regarding this, please contact me at (713) 669-7980. Sincerely, Shonna Boyer Drilling Engineer Phillips Petroleum Company SMB/bcf RECEIVED JAN ~ 1 1999 Nasl~ Oil & Gas Cons. Commission Anchorage Page I of 3 PHILLIPS PETROLEUM CO Daily Drilling Report WELL NAME 24 HRS PROG TMD TVD,35613 DFS REPT NO. DATE North Cook Inlet Unit B-3 17,864 178 179 10/26/98 SUPERVISOR RIG NAME & NO. I FIELD NAME / OCS NO. AUTH MD DAILY TANG CUM. TANG CARRELL / KSW Unocal / Pool Arctic Alaska 428I NORTH COOK INLET 0.00 642,301.76 CURRENT STATUS ACCIDENTS LAST 24 HRS.? DALLY IHT W/O MUD CUM INTANG W/MUD TIH WITH 3.5" DRILL PIPE. NONE 116,513.50 18,570,843.13 124 HR FORECAST DATE OF LAST SAFETY MEE'nNG DAILY TOTAL CUM COST W! MUD L/D 3.5" D.P., TEST BOPE. GIH W/CASING SCRAPER ASSEMB 10/25/98 123,810 19,205,866 LITHOLOGY JAR HRS OF SERVICE BHA HRS SINCE INSP LEAKOFF AFL AUTH. TR CLYST,50% SST,50% SLT,TR 41 23 15.83 P-V140 15,488,000 LAST SURVEY: DATE TMD INC AZlM I LAST CASING NEXT CASING LAST BOP PRES TEST 10/21/98 17,864.0 35.190 190.620I 7.000 (in.) @ 15,301.0 (ft) 5.000 (in.) @ 17,857.0 (ft) 10/16/98 24 HR SUMMARY: FINISH RIH W/3.5" x 5" LINER ASSEMBLY T/17854', SET LINER HANGER, MiX & PUMP 220 SXS CEMENT, TEST CASING & LINER PACKER TO 1500 PSI., POOH W/SETTING TOOL & LD SAME. TIH W/3.5" D.P.- 3000' · . OPERATIONS SUMMARY FROM TO HOURS:CODE TROUBLE SUB PHASE DESCRIPTION , , ,, , , .... 00:00 05:00 5.00 CS P 1 50PRRC CONTINUE TO RIH W/3.5" x 5" LINER ASSEMBLY ON 5" DRILL PIPE @ 3 MIN/STAND. FILL DRILL PIPE EVERY 5 STDS. F/11300' T/15301' TIME C~ANGED @ 2:00AM F/ADT T/AST. ACTUAL TIME FOR THIS TASK WAS 6 HRS. 05:00 07:30 2.50 CS P 1 50PRRC RIH W/3.5" x 5" LINER ASSEMBLY ON 5" DRILL PIPE INTO 6" OPEN HOLE F/15301' T/17854'. FILL DRILL PIPE WHILE GIH. 07:30 08:00 0.50 CS P 6 50PRRC RU BAKER CEMENTING HEAD & DROP 1" OD SETTING BALL. 08:00 09:30 1.50 CS P 5 50PRRC ATTEMPT TO GIH AFTER RU BAKER CEMENTING HEAD. UNABLE TO WORK BELOW 17854'. CIRC &COND HOLE. · **LINER & HANGER TOP TO BTM*** 11420' 7"x9.625" ZXP PACKER TOP 11439' 7" RS TYPE PACKOFF NIPPLE 11442' 7"x9.625" FLEX LOCK HANGER 11449' 7"TKC BOX x 5" VAM FJL PIN 11450' 126 JTS (5689') 5" 18# P110 17139' 5" VAM x 5" TKC X-OVER 17141' 4"ID POLISH BORE RECPTICAL 17159' 5" TKC x 3.5" PH-6 X-OVER 17161' 3.5" 12.95# PH-6 SUB 17164' 20 JTS (623') 3.5" 12.95# PH6 17788' WEATHERFORD LANDING CLR 17789' BALL SEAT LANDING SUB 17790' 2 JTS (62') 3.5" 12.95# PH6 17852' 3.5" PH6 FLOAT SHOE 17854' BTM OF FLOAT SHOE 09:30 10:00 0.50 CS P I 50PRRC SET BAKER 7" x 9-5/8" BAKER FLEX LOCK LINER HANGER @ 11442' MD. SETTING BALL SHEARED @ 5200 PSI. 10:00 10:30 0.50 CS P 5 50PRRC ClRC &COND HOLE HELD PRE-JOB SAFETY MEETING , 10:30 14:00 3.50 CE P 1 50PRRC TEST HALLIBURTON LINES TO 5200 PSI. PUMPED 8 BBL DIESEL SPACER, 25 BBL OF HIGH VIS SPACER, MIX & PUMP 220 SXS OF PREMIUM CEMENT + 0.4% CFR-3+ 0.13 GAL/SX HALAD 344L + 0.4% HR-5 MIX @ 15.6 PPG W/1.18 CF/SX YIELD, FOLLOWED BY 7 BBL OF HIGH VIS '-.':,., ~ "" '"' ",'t ..... ~ ~:::~.. ,,,..:~.: . t '""~ ':' "?'"::"'""?" -~",::'. l,,~ "',,%',. i~ ".77/'.??; r'"¢..~....~,, ,.., ~, -----"!.,, ~"f'..,: ....... " " , .,' .... ' ,...,:.. .... :-~,.,,, '..;'. '"'pto.,~,,. , L,1 (.-,1' -; ": ¢-"?:", "":'";,'"' ' 'i,,; ~ . . ' . .. ~ ,,. !.,,...,:,:..: ..~,, ,.:... ~ , .-~. ,.. .::;". , ~ ,,,,t,., ?,,,;. ," .."..~ ,...:,., ,.,,, 4'-' ~ ,.':'.,0 ,':', ,,,', . Printed: 10/26/98 6:19:49 AM .. Page 2 of 3 PHILLIPS PETROLEUM CO i, Daily Drilling Report w~L..A~E 24..s..oG ~,864 I~ DFs ...T.o. DATE North Cook Inlet Unit B-3 13,356 178 179 10/26/98 OPERATIONS SUMMARY FROM TO HOURS CODE TROUBLE SUB PHASE DESCRIP~ON 10:30 14:00 3.50 CE P 1 50PRRC SPACER. DISP~CED CEMENT & SPACER W/298 BBL OF 14.6 PPG MUD. MAX PUMP PSI 2600~. MAX RATE 5 BPM. FINAL PUMP PSI 1900~, BUMPED PLUG TO 3000 PSI. HELD PRESSURE FOR 5 MIN HELD OK. BLED PRESSURE TO ZERO, BLED BACK 2 BBL OF MUD. FLOATS HELD OK. RD BAKER & HALLIBURTON CEMENT EQUIP. 14:00 15:00 1.00 CE P n 50PRRC SET BAKER 7" ID x 9.625" OD ~P LINER PACKER W/HOLD DOWNS & 10' TIE BACK EXTENSION ~ 11420'. ClRC BU F/TOP OF TIE BACK EXTENSION. 15:00 16:00 1.00 CS P 9 50PRRC . RU & TEST BAKER ~P 7" x 9.625" LINER PACKER, 9.625" CASING, 5' LINER & 3.5" LINER TO 1500 PSI FOR 30 MIN. HELD OK. 16:00 17:00 1.00 CS P ;5 50PRRC ClRC & COND MUD. PUMP SLUG 17:00 21:00 4.00 CE P 4 50PRRC POOH W/BAKER SE~ING TOOL. 21:00 22:30 1.50 CE P 2 50PRRC LD BAKER EQUIPMENT & CLEAR FLOOR. 22:30 00:00 1.50 CE P 4 50PRRC MU 3.5" MULE SHOE. TIH WITH 3.5" DRILL PIPE IN DERRICK. (3000' AT REPORT TIME) ': ::::~ : :::'~' :::~:" :::~::':::~::COMMENTS .....' ' ' ' : : ' WE HAD FULL RETURNS DURING CMT JOB. WE ARE LD 3.5" DP. THE 2.875" RAMS HAVE ARRIVED. "DO THE RIGHT THING, THE FIRST TIME, FOR THE RIGHT REASON" (JAMES CARRELL) ~w. c°.": ~v~. ~"l": ~v~. ~%: MAX. CONN: I MAX. TRIP: ~ MAX. DRL: 48 :;DENSI~(ppg)"::~I 14.60 :'~PP: .EtD 15.2 MUDDATA,::DAi[YcoST.~I 7,296.51 ~[CUMCOS~;~ ~ ~ ~ ~ I : ~ Fv :':":~: 'Pv~P~ I~: :GELS~ ;::::W~HP~ ~:FC~;sOE~:~ ::::'OI~AT~::~[:[::' :%San~MBT:::;: :;::: ::"~PM::?~:"; ~':~: ~:~Pf~f::'::.~[::"'Cl::I:: ;; :~:::::':::C~J ~:;: :~ : 1,292,865'93 H2S :~:~:UM.E;. ~: : ES';::2: 85 45/18 18/29 I /% I I /31.5 I 83/i7 I /I' I / I / I; I ':1: I 4'8 1,205 . : ,. MUD V;OLUMES:::{bbl}: /. . ANNULARVELOClTIES:~fUmin} :~__,_______, :: :' HOLE966.0 PIT65.01: :; PIT65.0:2 :: :: PIT3:70.0 I 48.0"4&5'~ ~ ~ :: :: ~:: TOTAL'~ ~ :~ :1,214.0 :: MUD LOST ::_ MUD:DUMpED ~ 2.0 . ANNVEL':DP: :. 'ANN VEL Dc: ANN::VEL RISER I BNA NO 27 ; , ' ~BHA/HOLECONDITIONS.: :: ::i.::. :: :::;: .: ::::':BIT:NO. 9 .... u I BHA ~.: BELOW'JARS:: :' STRING ~.:UP :: STRING:~. DN : ~ ~: STRING ~.ROT'I[ ? : :TORQUE:/...N~S'. :.: :: :. [ : BHA:LENGTH :955 '00 ~I . ITEM DESCRIPTION" : .: '1 NO JTS : LENGTH : O~D; I.D;, CONNSlZE., CONN.~pE: Smith MT (MFDSSHIL OPEN) 0.80 8;500 4.500 APl REG 8 7/16 NBS 1 4.83 6.250 2.750 4.500 XH SUB - CROSSOVER 1 0.86 6.188 3.000 4.500 H90 DC - STEEL ~ 30.93 6.250 2.813 4.500 H90 SUB - CROSSOVER 1 0.89 6.000 3.000 4.500 FH Printed: 10/26/98 6:19:49 AM Page 3 of 3 PHILLIPS PETROLEUM CO Daily Drilling Report North Cook Inlet Unit B-3 1:3,356 178 179 10/26/98 ITEM DESCRIPTION NO JTS LENGTH O.D. I.D. CONN SIZE CONN TYPE SUB - CROSSOVER 1 1.16 5.938 3.000 4.500 XH 7.3/4" lBS NM STAB 1 6.06 6.500 2.875 4.500 XH SUB - CROSSOVER 1 1.60 6.188 2.750 4.500 1F HWDP 6 181.01 5.000 3.000 4.500 IF DAILEY HYDRAULIC JARS 1 32.63 6.500 2.250 4.500 IF HWDP 23 694.23 5.000 3.000 4.500 IF PERSONNEL DATA COMPANY SERVICE NO. HOURS COMPANY SERVICE NO. HOURS PHILLIPS PETROLEUM SUPERVISION 6 ANADRILL Directional 1 POOL ARCTIC ALASKA RIG CREWS 26 BAKER INTEQ MUD LOGGERS 2 APOLLO CUTTINGS INJECTION 4 VECO PRODUCTION ROUSTA 3 RAY GLENN MUD ENGINEER 1 VAM PTS THREAD INSPECTION 1 BAROID MUD ENGINEER 1 WEATHERFORD CASING CREW 1 SSI CATERING 5 BAKER OIL TOOL LINER HANGER 1 SECORP MEDIC I HALLIBURTON Wireline 3 ' : MUD INVENTORY '. , ITEM UNITS: USAGE' COST . ' ON HAND: BARAFIBER 25.00 LBS ; BARAKLEAN 55.00 GAL 5 BARASCRUB 55.00 GAL 7 BAROID BULK 100.00 LBS 519 5,709.00 2,327 CAL. CHLORIDE 80.00 LBS 818 INVERMUL MUD 42.00 GAL LIME 50.00 LBS 25 LIQUI-VIS 5.00 GAL 1 131.81 31 N-VIS 25.00 LBS 2 397.30 90 OMC 2 5.00 GAL 14 CON-DET 42.00 GAL 3 DRILLTREAT 55.00 GAL 3 BARACARB 50 50.00 LBS BARACARB 25 50.00 LBS GELTONE 50.00 LBS WALNUT PLUG M. 50.00 LBS DURATONE 50.00 LBS STICKLESS LBS STEEL SEAL 50.00 LBS SUSPEND TONE 50.00 LBS EZ-MUL 42.00 GAL INVERMUL NT 42.00 GAL 4 DIESEL 42.00 GAL . 20 1,058.40 -20 DRILLTREAT 5.00 GAL RM-63 42.00 GAL XFOAM 20L ;MIL-POLYMER 303 25 KG SOLTEX 50.00 LBS OMC 42 55GAL AQUAGEL 100.00 LBS 4 Printed: 10/26/98 6:19:49 AM Page 1 of 2 PHILLIPS PETROLEUM CO Daily Drilling Report WELL NAME 24 HRS PROD TMD TVD DFS REPT NO. DATE North Cook Inlet Unit B-3 17,864 . 13,356 179 180 10/27/98 SUPERVISOR RIG NAME & NO. FIELD NAME ! OCS NO. AUTH MD DAILY TANG CUM. TANG CARRELL / KSW Unoca / Pool Arctic Alaska 428 NORTH COOK NLET 0.00 642,301.76 'CURRENT STATUS ACCIDENTS LAST 24 HRS.? DALLY INT W!O MUD CUM INTANG WI MUD PU & RIH W/BIT, SCRAPER & 2.875" TBG. NONE 66,413.50 18,637,256.63 24 HR FORECAST DATE OF LAST SAFETY MEETING DAILY TOTAL CUM COST W! MUD FINISH TIH, ClRC, DISPLACE OBM W/SW. CLEAN PITS. 10/26/98 66,414 19,272,280 LITHOLOGY JAR HRS OF SERVICE BNA HRS SINCE INSP LEAKOFF AFL AUTH. TR CLYST,50% SST,50% SLT,TR 1 15.83 P-V140 15,488,000 LAST SURVEY: DATE TMD INC AZlM LAST CASING NEXT CASING LAST BOP PRES TEST 10/21/98 17,864.0 35.190 190.620 7.000 (n.) @ 15,301.0 (ft) 5.000 (in.) @ 17,857.0 (ft) 10/26/98 24 HR SUMMARY: TIH W/3.5" DP, SLIP & CUT DRLG LINE. LD 3.5" DRILL PIPE. CHANGE UPPER SET OF VBR'S TO 2.875" PIPE RAMS. WEEKLY BOP TEST. SET WB. PU BHA & 2.875" TBG. OPERATIONS SUMMARY FROM TO HOURS CODE TROUBLE SUB PHASE DESCRIPTION 00:00 01:00 1.00 CE P 4 50PRRC FINISH GIH W/3.5" DRILL PIPE 01:00 02:00 1.00 RM P c 50PRRC SLIP & CUT 200' OF DRILLING LINE 02:00 02:30 0.50 RM P 3 50PRRC SERVICE RIG 02:30 11:30 9.00 CM P 2 50PRRC RU LAY DOWN RAMP, L/D 3.5" DRILL PIPE. 11:30 14:00 2.50 CS P e 50PRRC 'INSTALL 2-7/8" PIPE RAMS IN TOP CAVITY OF 13-5/8" SCHAFFER SL BOP, PULL WEAR BUSHING, INSTALL TEST PLUG.. 14:00 17:00 3.00 CS P 8 50PRRC WEEKLY DOPE TEST, NOTIFIED BLAIRE WONDZELL W/AOGC OF INTENT TO TEST DOPE ON 10-23-98 @ 13:00 HRS ADT. NO STATE WITNESS REQUIRED. TEST TO 250 PSI LOW & 5000 PSI HIGH PRESSURE TEST, TEST ANNULAR PERVENTOR TO 250 PSI LOW & 2500 PSI HIGH TEST, HELD OK. PULL TEST PLUG, INSTALL WEAR BUSHING. 17:00 17:30 0.50 CM P 6 50PRRC RU WEATHERFORD TUBING TONGS FOR 2-7/8" 6.50# L-80 BTS-8. 17:30 00:00 6.50 CM P 2 50PRRC GIH W/4-1/8" BIT, 5" CASING SCRAPER, XO & 140 JTS 2.875" 6.5# L-80 CS HYDRIL TBG. 4400' AT REPORT TIME. (HAVE 49 ADDITIONAL JTS OF TBG TO PU) : i .::::. : ' : :COMMENTS . SHOULD BE IN HOLE CIRC BY 08:00 HRS. DO' THE RIGHT THING, THE FIRST TIME, FOR THE RIGHT REASON. (JO) DENSITY(PPg):i: 14.60 i:PP:i .LCD MUD:DATA: DALLY COST 0.00 CUM COST 1,292,865.93 ::FV pV/yp, i: GELS WL/HT.H.P FC/T:SOL .:OIL./WAT:::: :': %sand/MBT. i ph/PM: :: pf/Mf CI : Ca. H2S LIME ES 88 46/20 18/30 /2.2 /31.5 83/17 / / / 5.7 1,346 . MUD VOLUMES;!(b:bl)'/ANNULAR.VELOCITIES (ft/min) . HOLE · PIT I pIT2 PIT 3 "4&5: TOTAL MUD LOST MUD DUMPED ANN VEL DP: ANN VEL DC ANN VEL RISER 819.0 65.0 65.0 70.0 48.0 1,067.0 147.0 BITS BIT/RUN: SIZE MANUF: t TYPE : SERIALNO. JETSORTFA DEPTHIN DATEIN / I-O-D-L-B-G-O-R I 20 / 1 4.125 Smith CFM N46960 17,864.0 10/26/98~ ....... BIT OPERATIONS BIT / RUN WOB RPM GPM PRESS P BIT HRS 24Hr DIST 24Hr ROP CUM HRS 1 CUM DEPTH CUM RO.P I 20 / 1 / / , '~ . ,r ., ..~ ~-; .~. ~"/'"" /.-.,,:'. '"' !!? <" ~: ......... ('I !' ,,, ;'i! i t.~ :~?c I :,....: '..:. "; ..... " ~' . -. ' ........ , · , Printed: 10/27/98 6:41:34. AM Page 2 of 2 PHILLIPS PETROLEUM CO Daily Drilling Report WELL NAME 24 HRS PROG TMD TVD DFS REPT NO. DATE North Cook Inlet Unit B-3 17.864 13.356 179 180 10/27/98 BHA NO. 39 ! BHA / HOLE CONDITIONS I a~m NO. 20 BHA WT. BELOW JARS STRING WT. UP STRING WT. DN I STRING WT. ROT TORQUE / t UNITS BHA LENGTH 0.00 ITEM DESCRIPTION NO JTS LENGTH I O.D. I.D. CONN SIZE CONN TYPE PERSONNEL DATA COMPANY SERVICE NO. HOURS COMPANY SERVICE NO. HOURS PHILLIPS PETROLEUM SUPERVISION 7 SSI CATERING 5 POOL ARCTIC ALASKA RIG CREWS 26 SECORP MEDIC 1 APOLLO CUTTINGS INJECTION 4 BAKER INTEQ MUD LOGGERS 2 RAY GLENN MUD ENGINEER 1 VECO PRODUCTION ROUSTA 3 BAROID MUD ENGINEER 1 HALLIBURTON Wireline 3 MUD INVENTORY ITEM UNITS USAGE COST ON HAND BARAFIBER 25.00 LBS BARAKLEAN 55.00 GAL 5 BARASCRUB 55.00 GAL 7 BAROID BULK 100.00 LBS 2,327 CAL. CHLORIDE 80.00 LBS 81@ : INVERMUL MUD 42.00 GAL LIME 50.00 LBS 25 LIQUI-VlS 5.00 GAL 31 N-VIS 25.00 LBS 90 OMC 2 5.00 GAL 14 CON-DET 42.00 GAL 3 DRILLTREAT 55.00 GAL 3 BARACARB 50 50.00 LBS BARACARB 25 50.00 LBS GELTONE 50.00 LBS WALNUT PLUG M. 50.00 LBS DURATONE 50.00 LBS STICKLESS LBS STEEL SEAL 50.00 LBS SUSPEND TONE 50.00 LBS EZ-MUL 42.00 GAL INVERMUL NT 42.00 GAL 4 DIESEL 42.00 GAL -20 ; DRILLTREAT 5.00 GAL RM-63 42.00 GAL XFOAM 20L MIL-POLYMER 303 25 KG SOLTEX 50.00 LBS OMC 42 55GAL AQUAGEL 100.00 LBS r~ Il-,., E, % # ~D4 JAN 11 1999 Nasla 0ii & Gas Cons. Commission Anchorage Printed: 10/27/98 6:41:34 AM , Page 1 of 2 PHILLIPS PETROLEUM CO Daily Drilling Report WELL NAME 24 HRS PROD TMD 'I'VD DFS REPT NO. DATE North Cook Inlet Unit B-3 17,864 13,356 180 181 10/28/98 SUPERVISOR RIG NAME & NO. FIELD NAME ! OCS NO. AUTH MD DAILY TANG CUM. TANG KSW/WALT CARRICO Unocal / Pool Arctic Alaska 428 NORTH COOK INLET 69,800.00 712,101.76 CURRENT STATUS ACCIDENTS LAST 24 HRS.? DAILY INT W/O MUD CUM INTANG W/MUD DISPLACING OBM WITH SW. 81,353.50 18,740,977.51 24 HR FORECAST DATE OF LAST SAFETY MEETING DAILY TOTAL CUM COST W/MUD DISPLACE OBM W/SW. NED TEST. DISPLACE W/CaCI. 10/27/98 173,521 19,445,801 LITHOLOGY I JAR HRS OF SERVICE BHA HRS SINCE INSP LEAKOFF AFE AUTH. TR CLYST,50% SST,50% SLT,TRI 1 15.83 P-V140 15,488,000 LAST SURVEY: DATE TMD INC AZlM LAST CASING NEXT CASING LAST BOP PRES TEST 10/21/98 17,864.0 35.190 190.620 7.000 (in.) @ 15,301.0 (ft) 5.000 (n.) @ 17,857.0 (ft) 10/26/98 24 HR SUMMARY: FINISH TIH WITH 2.875" TBG & 5" DP WITH SCRAPERS. CIRC & COND MUD BEFORE DISPLACING. PUMP SPACERS & DISPLACING OBM WITH SW AT REPORT TIME. OPERATIONS SUMMARY FROM TO HOURS CODE ,TROUBLE SUB PHASE DESCRIPTION 00:00 02:30 2.50 'CE P z 50PRRC FINISH PU & RIH 2.875" TBG, BIT & SCRAPER. 02:30 03:00 0.50 ~CE P z 50PRRC PU XO, 9-5/8" SCRAPER & BRISTLE BRUSH. 03:00 09:00 6.00 CE P z 50PRRC TIH WITH 5" DRILL PIPE, TAG PBR WITH 4.125 BIT AT 17140'. 09:00 21:00 12.00 CEP z 50PRRC CIRC&CONDOBM. WHILECIRC, SLIP & CUT 277' DRILL LINE. PRE JOB SAFETY MEETING. FINISH BUILD SPACERS. 21:00 22:30 1.50 CE P z 50PRRC RIG PUMP SPACER #1. 45 BBLS DIESEL MIXED WITH 4 DRUMS BARASCRUB. RU HALLIBURTON LINES & TEST TO 6000 PSI. 22:30 00:00 1.50 CE P z 50PRRC HALLIBURTON PUMP SPACERS 2, 3, & 4 AT 3 BBL/MIN. DISPLACE WITH SALT WATER, HOLDING CONSTANT BHP. . ,: : :,:,::~:.:.::::~ : :::::: ~ ,::: :.::: COMMENTS , AFTER DISPLACING OBM WITH SW. WILL HAVE NED TEST ON LINER. PRESSURE TEST CSG TO 5100. BUILD CaCl. DISPLACE SW WITH 10.5 PPG CaCI. DENSITY(Ppg):: 14.60 :::PPi ECD :'MUD DATA :~?DAILY cOsT'~:' 22,367.38 1,315,233.31 FY: Pv/YP: : GELSi: :' i?iW~HTHP~: ~i'Fc~SOL !:i:. :;.O,~AT: ::i':: °/°sand/MaT~ !l:::; ph/PM ~i:. :::: Pf/Mf ::?:~.': :C,~ CUM cOsT'; , , , , ;:::ii Ca: 'H2S' :.LIME: ::ES.. ~ot 4'l'ii::'"'l "-14):~:"1' "i2.':,,,'''' i 'Pi° %~'~ "1 /""'1 i I/ s.~ i,'~'~° : VEL:OClTiES(ft/min): ;;:.:;.::.!. , HOLE. i:' :::!: :P!T::i l:! ?i i iii : 'i:I: PiT2 PIT 3 !' ,,4&5 TOTAL I'MUD LosT MUD DUMPEDi ANN VEL DP i ANN VEL DC lANN VEL RISER ' ;:,! :: ' : i:' ~::::: ::: ':i; '. : .... :i BITS; ' BIT/:RUN: SIZE:.: .:: MANUF;::: :::C~ M:TypE : SERIALNO. : JETS OR'TFA . .DEpTHIN.DATE:iN.::0/26/98 .: I-O-D-L-B,G;O-R 20 / 1 4.125 Smith _F_ N46960 17,864.0 1 ...... : BIT OPERATIONS ': DEPTH' BIT / RUN 'WOB RPM GPM pRESS P BIT : HRS 24Hr DIST 24Hr ROP CUM HRS: CUM CUM ROP 20/ 1 / / BHA NO. 39 BHA / HOLE· CONDITIONS IBIT NO' I 20 BHA WT; BELOW JARS::·, STRING WT; UP STRING WT. DN i STRING WT. ROT TORQUE/UNITS· ::: BHA0.0oLENGTH IT,EM DESCRIPTION NO JTS LENGTH t O.D. I.D. CONN SIZE I CONN TYPE · PERSONNEL DATA . COMPANY SERVICE NO. HOURS COMPANY SERVICE NO. HOURS PHILLIPS PETROLEUM SUPERVISION 6 RAY GLENN MUD ENGINEER 1 POOL ARCTIC ALASKA RIG CREWS 26 BAROID MUD ENGINEER 1 APOLLO CUTTINGS INJECTION 4 SSI CATERING 5 . i::... ':r'z-'~':' .... "" .... ":' ':":".'~: '~ C 1'"' ~ i';.'..!, ,2,. i,,,.." ' ' ' C''¢'7":' ~ ', .,' ."'" ! ~ ;"' :" .... "'" ~ ~'~ , ,~ .... . .... ~. /" . f .,<. '~' '~ .~?' ,'~ "~:'" r £~....~,.,, f;~.It~,,' ',.£,' :,i :;' ~,,.~.'~' ~":;~:.?,.,.>" ,,~-. (-:~ ' --~-' ~-:-.,"'"' ~.., .". ~, ",.i ..::,. ,,, ~.., .-,'~.'" ,,'.__.,'" .~,:).~..z..~.,...,"' .... ,..,..-. ~\ ..., , -- ,, . .,,, ~ ~ ·, / ~ ' ..... .. Page 2 of 2 PHILLIPS PETROLEUM CO Daily Drilling Report WELL NAME 24 HRS PROG TMD 'I'VD DFS I REPT NO. DATE North Cook Inlet Unit B-3 17,864 13,356 180I 181 . 10/28/98 PERSONNEL DATA COMPANY SERVICE NO. HOURS COMPANY I SERVICE NO. HOURS SECORP MEDIC 1 SOLARI PRODUCTION SERVICE 2 BAKER INTEQ MUD LOGGERS 2HALLIBURTON [PUMPING 1 ... VECO PRODUCTION ROUSTA 3 I .., MUD INVENTORY ITEM UNITS USAGE COST ON HAND BARAFIBER 25.00 LBS BARAKLEAN 55.00 GAL 2 1,175.04 3 I BARASCRUB 55.00 GAL 6 3,889.14 1 BAROID BULK 100.00 LBS 300 3,300.00 2,027 CAL. CHLORIDE 80.00 LBS 310 9,238.00 1,908 INVERMUL MUD 42.00 GAL LIME 50.00 LBS 25 LIQUI-VIS 5.00 GAL 31 N-VIS 25.00 LBS 12 2,383.80 78 OMC 2 5.00 GAL 14 CON-DET 42.00 GAL 3 DRILLTREAT 55.00 GAL 3 BARACARB 50 50.00 LBS BARACARB 25 50.00 LBS GELTONE 50.00 LBS WALNUT PLUG M. 50.00 LBS DURATONE 50.00 LBS STICKLESS LBS STEEL SEAL 50.00 LBS SUSPEND TONE 50.00 LBS EZ-MUL 42.00 GAL INVERMUL NT 42.00 GAL 4 DIESEL 42.00 GAL 45 2,381.40 DRILLTREAT 5.00 GAL RM-63 42.00 GAL XFOAM 20L MIL-POLYMER 303 25 KG SOLTEX 50.00 LBS OMC 42 55GAL AQUAGEL 100.00 LBS 4 RECE'IVED ,]AN 11 1999 Nss~ 0il l Gas Cons, Cemmlffio~ Anchorage Printed: 10/28/98 7:14:02 AM Page 1 of 2 PHILLIPS PETROLEUM CO Daily Drilling Report WELL NAME 24 HRS PROD [TMD T~/D DFS REPT NO. DATE North Cook Inlet Unit B-3 17,864 13,356 181 182 10/29/98 SUPERVISOR RIG NAME & NO. FIELD NAME ! OCS NO. AUTH MD DAILY TANG CUM. TANG KSW/WALT CARRICO Unocal / Pool Arctic Alaska 428 NORTH COOK NLET 0.00 712,101.76 'CURRENT STATUS ACCIDENTS LAST 24 HRS.? DAILY INT WlO MUD CUM INTANG WI MUD CLEANING SHAKERS & DITCH BEFORE TIH. 78,938.50 18,836,405.26 24 HR FORECAST DATE OF LAST SAFETY MEETING DAILY TOTAL CUM COST WI MUD TIH. CIRC. DISPLACE W/CaCI. POOH & LD TBG. 10/28/98 95,428 19,541,229 LITHOLOGY JAR HRS OF SERVICE [ BHA HRS SINCE INSP LEAKOFF AFL AUTH. TR CLYST,50% SST,50% SLT,TRI 1 15.83 P-V140 15,488,000 LAST SURVEY: DATE TMD INC AZIM LAST CASING NEXT CASING LAST BOP PRES TEST 10/21/98 17,864.0 35.190 190.620 7.000 (in.) @ 15,301.0 (ft) 5.000 (n.) @ 17,857.0 (ft) 10/26/98 24 HR SUMMARY: DISPLACE OBM WITH SW HOLDING CONSTANT BHP. PRESSURE TEST CSG & NEGITIVE TEST. CLEAN SURFACE EQUIPMENT. PULL 120 STANDS FOR WIPER TRIP. RIH W/20 STANDS. CLEAN SHAKER & DITCH. OPERATIONS SUMMARY FROM TO HOURS CODE TROUBLE! SUB PHASE DESCRIPTION 00:00 06:30 6.50 CS P z 50PRRC HALLIBURTON DISPLACING OBM WITH SW HOLDING CONSTSANT BHP. SHUT DOWN OCCASIONALLY TO ALLOW APOLLO TIME TO CATCH UP THE DISPOSAL OF DIRTY FLUID. 06:30 09:00 2.50 CS P z 50PRRC PRESSURE TEST CASING, LINER TOP TO 4000 PSI & HOLD 30+ MIN. (GOOD TEST) BLEED OFF THE 4000 PSI IN 500 PSi INCREMENTS UNTIL ZERO PRESSURE. HOLDING FOR 5 MIN AT EACH PRESSURE. MONITOR & CHART FOR 30 MIN AT ZERO PRESSURE. (GOOD NEGITIVE TEST) 09:00 13:00 4.00 CM P 1 50PRRC MONITOR HOLE WHILE CLEANING TRIP TANK, & PILL PIT STAND PIPE, CHOKE MANIFOLD & MUD PUMPS. 13:00 16:00 3.00 CM P 1 50PRRC PREPARE TO MAKE WIPER TRIP. FLUID U-TUBING UP DRILL PIPE. PUMP CaCl SLUG. ALLOW FLUID TO BALANCE OUT. 16:00 21:30 5.50 CM P 4 50PRRC PULL 120 STDS UNTIL 9-5/8 SCRAPER & BRUSH TO SURFACE & INSPECT SAME. DP PULLED WET. 21:30 22:30 1.00 CM P 4 50PRRC RIH WITH 25 STANDS UNTIL TRIP TANK FULL. 22:30 00:00 1.50 CUP 1 50PRRC MONITOR WELL. CLEAN SHAKER & DITCH TO PILL PIT. · COMMENTS . WILL NEED OFFICIAL B-1 PROCEDURE SOON. UNABLE TO LOG ONTO NOTES. HAVE MATT CALL. DENSITY(ppg) ::: 8.50 i:PP' LCD: :MUD DATA.: DAILY COST I 16,489.25 : CUM COST I 1,331,722.56 FV PV/YP::: :iW THp FC OIL/WAT °/°Sand/MBT: Ph/PM Pf/Mf Cl Ca H2S LIME ES 28 1/ / / / / / MUD VOLUMES (bbl) / ANNULAR VELOCITIES (ft/min) HOLE' PIT' I PIT 2 PIT 3 4&5 TOTAL MUD LOST MUD DUMPED ANN VEL DP ANN VEL DC ANN VEL RISER 819.0 65.0 65.0 70.0 48.0 1,067.0 BITS 20 / 1 4.125 Smith OFM N46960 17,864.0 10/26/98{ ....... BIT OPERATIONS 20 / 1 / / Printed: 10/29/98 6:22:09 AM Page 2 of 2 PHILLIPS PETROLEUM CO Daily Drilling Report WELL NAME 24 HRS PROG TMD i'I'VD DES REPT NO. DATE North Cook Inlet Unit B-3 17,864I 13,356 181 182 '10/29/98 BNA NO. 39 BHA / HOLE CONDITIONS I BIT NO. 20 aHA WT. BELOW JARS STRING WT. UP STRING WT. DN STRING WT. ROT TORQUE ! UNITS BHA LENGTH 0.00 iTEM DESCR~,T~O. I NO,TS I ,~.GT. I o.D. I.D. CONN SIZE CONN TYPE PERSONNEL DATA COMPANY SERVICE NO. HOURS COMPANY SERVICE NO. HOURS PHILLIPS PETROLEUM SUPERVISION 5 SSI CATERING 5 POOL ARCTIC ALASKA RIG CREWS 26 SECORP MEDIC 1 APOLLO CUTTINGS INJECTION 2 BAKER INTEQ MUD LOGGERS 2 RAY GLENN MUD ENGINEER 1 VECO PRODUCTION ROUSTA 3 BAROID MUD ENGINEER 1 MUD INVENTORY ITEM UNITS USAGE COST ON HAND BARAFIBER 25.00 LBS BARAKLEAN 55.00 GAL 3 BARASCRUB 55.00 GAL 1 BAROID BULK 100.00 LBS 2,027' 'CAL. CHLORIDE 80.00 LBS 520 15,496.00 1,388 INVERMUL MUD 42.00 GAL LIME 50.00 LBS 25 LIQUI-VIS 5.00 GAL 31 N-VIS 25.00 LBS 5 993.25 73 OMC 2 5.00 GAL 14- CON-DET 42.00 GAL 3 DRILLTREAT 55.00 GAL 3 BARACARB 50 50.00 LBS BARACARB 25 50.00 LBS GELTONE 50.00 LBS WALNUT PLUG M. 50.00 LBS DU RATONE 50.00 LBS STICKLESS LBS STEEL SEAL 50.00 LBS SUSPEND TONE 50.00 LBS ~EZ-MUL 42.00 GAL INVERMUL NT 42.00 GAL 4 DIESEL 42.00 GAL DRILLTREAT 5.00 GAL RM-63 42.00 GAL XFOAM 20L MIL-POLYMER 303 25 KG SOLTEX 50.00 LBS OMC 42 55GAL AQUAGEL 100.00 LBS 4 Printed: 10/29/98 6:22:09 AM Page 1 of 2 PHILLIPS PETROLEUM CO Daily Drilling Report WELL NAME 124 HRS PROC ; TMD . TVD ! DFS I REPT NO. I DATE North Cook Inlet Unit B-3. 17,864 13,356 i 182 , 183 ~ 10/30/98 i~b'~'I~VI~S-~, tRIG NAME & NO. = FIELD NAME I OCS NO. ~'AUTH MD I DAILY TANG I CUM. TAN(~ KSW/WALT CARRICO I Unocal / Pool Arctic Alaska 428 NORTH COOK INLET i ', ,, 0.00 712,101.76 CURRENT STATUS ...... :-ACCIDENTS LAST 24 HRS.? : DAILY INT WIO MUD i CUM INTANG WI MdD DISPLACING SEA WATER WITH 10.5 CaCI COMPLETION FLUI ~ 66,863.50 i 18,928,708.02 24 HR FORECAST DATE OF LAST SAFETY MEETING. DAILY TOTAL !CUM COST WI MUD FIN DISP. WITH 10.5 CaCI, COOH L/D 27/8" TBG. ' 10/29/98 92,303 IAUTH' 19,633,532 LITHOLOGY JAR HRS OF SERVICE BHA HRS---~I-NCE INSP I LE/~,KOFF AFL TR CLYST,50% SST,50% SLT,TR 1 [ 15.83 , P-V140 15,488,000 LAST SURVEY: DATE TMD INC AZIM I LAST CASING NEXT CASING i LAST BOP PRES TEST 10/21/98 17,864.0 35.190 190.620 [ 7.000 (in.) @ 15,301.0 (ft) 5.000 (in.) @ 17,857.0 (fi) 10/28/98 24 HR SUMMARY: FINISH SHORT TRIP, CIRC. SWEEPS, DISPLACE SEA WATER WITH 10.5 CaCI. COMPLETION FLUID. OPERATIONS SUMMARY FROM 1 TO HOURS CODE TROUBLE SUB PHASE DESCRIPTION -~30:00 05:00 5.00 CM P' i' ' 80CMPLICLEAN SHAHE SHAKERS AND PILL PIT. '-~! 08:30 3.50 CM P 4 80CMP~'iTIH FROM 8151 TO 17139. 08:30 14:30 6.00 CM P 5 80CMPL PUMPED TWO SOAP PILLS FOLLOWED BY SEA WATER. RECOVERSD ....... j GREAT AMOUNTS OF BARITE WITH THE RETURN OF EACH PILL. "~4i'~0~-;I-~i30 1.00 CM P 1 80CMPL HELD PREDISPLACEMENT SAFETY MEETING, TRANSFERRED FLUID FROM PLATFORM PITS TO RIG PITS. 15:30 00:00 8.50 ICM P 5 80CMPL PUMPED HI-VIS SWEEP FOLLOWED BY 10.5 CaCI. COMPLETION FLUID. DENSITY(ppg):: 10 50 MUD DATA 25 439 26 CUM COST :' 1 357 161 82 "--- "::' :":'.':..'i"..'..:. '". ".=:.'""= :.:" :,!i.:::: ;MUDVOEUMES..(bb~) I ANNULAR. VELOCITIES"(ft/min):." :' :'. :.. '. ;.. '. '. '. · :' ':'.' "HOLE..... ';: · PIT'1 ;'.' '!t; "':PIT"2;:' ":;;:. "r::':;':';'"PIT:':3.:~'.;' :'!':"':".u:;"'a,&5. :: .... ' '"TOTAL"."'." MUD. LOST. MUD. DUMPED :'"ANN VEL DP. · ANN'VEL DC ~ANN VEL RISER ',1__6'5'0':'''' :' ' .... 65.0' ......... :'::.:.i':.::'!'i'=70.~):',.,'.!..=..;:'. ''!':::'''::x 48.0':' ....... '"':: .... "' i'067'0 " ":""::"" "' '" ': ' ' .... "::'' ..... : '"': .... " ...... I "" 819.0 · · ..' .: :!' i.:' "."~ :ii;:./;'? :'~::.:.~';::.:!;::~::?.. 'L.{.::..::.:':...'. :':.?:.!:.:.!':.::..":' :',:'i'.; '::'i.'...:.; :....: ::i:..... · .' ...': BITS. 7 .":..i';.'i:,::. '.. "...:.:.: .:.' ...~. :.. :.'.. ':'.......'. : . ........... ·..: ... · :..: BIT:./. RUN ...::.:..'...... ;.':.. SlZE:.'..'.;:.'...!'}:.':.;::'i..:, ~: MANUF;;..:.;::::::::;.;::. :..::.: i:.TYPEi..;'::".. ':SERIAL'NO; . .' .... .::.;':' .JETS.:OR'.TFA '.".:"..' '.:" .[... ..... DEPTH... ': .....IN. DATE.IN:.':........, ..... :....':: :' .:...I.O.D-L.B'G.O-R. . ~/ "' 1 '" '":'4.'i2;' '~'~'~:~I'' :': ' ....... ~ ":::'":':'"::~'''0~:' '"':"':"N469-60 '" [ Ii ' '' '" ...... ' ' ": ' "' '; ' ' .... '' '"i 17,864.0 10/26/9~ ....... - ". i . .:..'..:.: .' ' .'. '.'..:.'..'?i':;.:.'? ..:.' .':',}{':::.::i :::.".':;';i ::i:.. :i;...?i:;!ili:' .:';' i.::..:':', i::::.::i::.:; :.':.:.'i BIT OPERATIONS · · :' · ' ........ ' '". .... ' .... :. · ":BIT/RUN'.:.'' '"'i':'."WoB :.':}.' :.::.;: ":.::'1~M.::'''''.:=;. '.";GPM' ."..".'PRESS'" "P BIT.' ."'".'' HRS ":'.':. ' ":':" ''''','':'~ :""' ::' 24H'r R'~3P. :.'C'UM"HR~:. ;iC0M.DEpTH :'CuM'ROP ",'. ' . "::." '.' ;' .,: .... '' '""'":" ,':;: }"}',:"',:::.':'.:'~;':.':":".: ;::;.:;':".'.,':, ;'..:'. ::':'"":".'.i:.,."',,.',": .... "';' '""'"": '" "":'"': "1 24H?:D!ST:",, 20 / 1 / /I _ .BHA NO';'.}I 39 :..i: :'.::;."i':iBHA.:/HOLEi;:CONDITIONS'..:. ::.:. :": .: .... ;.:.... :.. :::.'.'."...i' :::..'..;'...i..:..~....}"alT.NO; j 20 "'B-HA'WT': BELOW::JA!~S:"'!"I ";':'"'::?L~TR!NG;:'~i::'UP::::i':'::'?:':':; :;" ;";"i:'::~'~RING'WT. DN:. :':...'. ::. STRING.....:...: .......... WT..ROT~.: .''. . .TORQUEJ"UNITS'.;.::......:... .. ' '"' ," ' '"' .' 'BHAo. 0.oLENGTH. · ' I I'D' " '.CONNSlZE CONN TYPE '' ::' · .'"" ' DESCRIPTION!?"?:::?:::::' ' "'. '. '"':' :' '" · :'. · "':":t', ............ NO JTS:.:.' LENGTH' i: I ..: :O.D.. ',, . . . J PERSONNEL DATA COMPANY j SERVICE NO. i HOURS ii COMPANY i SERVICE NO. : HOURS PHILLIPS PETROLEUM . SUPERVISION 6 SECORP MEDIC 2 ., o vvs -- [-1 POOL ARCTIC ALASKA 26 BAKER INTEQ MUD LOGGERS 2 [ APOLLO CUTT NGS INJECTION 2 I iVECO .... ~PRODUCTION ROUSTA -- 3 1 RAY GLENN MUD ENGINEER 1 I .... ; WEATHERFORD.ITONG OPERATOR I 1 ~ -- BAROID MUD ENGINEER 11 HALLIBURTON iPacker man ' 1i SSI CATERING 5 I I ' __ · ':..: : ,. ::. MUD INVENTORY ITEM;:::,::I ' ' :..: UNITS ':: [ USAGE::: I COST':;ii ON HAND BARAFIBER 25.00 LBS / -- Printed: 10/30/98 6:46:52 AM Page 2 of 2 PHILLIPS PETROLEUM CO Daily Drilling Report WELL NAME i24 HRS PROG I TMO ;'I'VD DFS 1REPT NO. i ELATE ' ' 17,864 I 13,356 182 183 ; 10/30/98 North Cook Inlet Unit B-3 ~ i , MUD INVENTORY ITEM I UNITS I USAGE COST I ON HAND BARAKLEAN .L 55.00 GAL I i 7 BARASCRUB 55.00 GAL 4 2,592.76 5 . BAROID BULK 100.00 LBS I i !~ 2,027 CAL. CHLORIDE I 80.00 LBS 700 20,860.00 i 688 INVERMUL MUD 42.00 GAL LIME [ 50.00 LBS i [ 25 LIQUI-VIS I 5.00 GAL I [ 31 N-VIS~i 25.00 LBS '1 10 i-- 1,986.50 ; 63 OMC 2 ~ 5.00 GALt I I 14 CON-DET 42.00 GAL . _ i 3 '~RILLTREAT 55.00 GAL 3 BARACARB 50 50.00 LBS -~ARACARB 25 50.00 LBS GELTONE 50.00 LBS WALNUT PLUG M. 50.00 LBS DURATONE 50.00 LBS STICKLESS LBS S~EEL SEAL 50.00 LBS SUSPEND TONE 50.00 LBS EZ-MUL 42.00 GAL INVERMUL NT 42.00 GAL 4 DIESEL 42.00 GAL DRILLTREAT 5.00 GAL RM-63 42.00 GAL XFOAM 20L MIL-POLYMER 303 25 KG SOLTEX 50.00 LBS OMC 42 55GAL AQUAGEL 100.00 LBS 4 RECEI VED JAN 1 'l 1999 Alaska Oil & Gas Cons. Commission Anchorage Printed: 10/30/98 6:46:52 AM Page I of 2 PHILLIPS PETROLEUM CO Daily Drilling Report WELL NAME 24 HRS PROG TMD 'rvo,35613 DFS REPT NO. DATE North, Cook Inlet Unit B-3 17,864 183 184 10/31/98 SUPERVISOR I RIG NAME & NO. FIELD NAME / OCS NO. AUTH MD I DAILY TANG CUM. TANG KSWANALT CARRICOI Unocal / Pool Arctic Alaska 428 NORTH COOK INLETI 73,545.92 785,647.68 CURRENT STATUS ACCIDENTS LAST 24 HRS.? DAILY IHT WIO MUD CUM INTANG WI MUD POOH WITH 5"DP AFTER SETTING 95/8" RBP . 222,054.79 19,171,330.21 ~24 HR FORECAST I DATE OF LAST SAFETY MEETING i DAILY TOTAL CUM COST WI MUD FIN POOH W/DP AND RPB SETTING TOOL, REMOVE BOP'S, 10/29/98 316,168 19,949,700 LITHOLOGY JAR HRS OF SERVICE BHA HRS SINCE INSP ILEAKOFF AFE AUTH. TR CLYST,50% SST,50% SLT,TR 1I 15.83 P-V140 15,488,000 LAST SURVEY: DATE TMD INC AZlM LAST CASING NEXT CASING LAST BOP PRES TEST 10/21/98 17,864.0 35.190 190.620 7.000 (in.) @ 15,301.0 (fi) 5.000 (in.) @ 17,857.0 (ft) 10/26/98 24 HR SUMMARY: SLUG DRILL PIPE & POOH. LD 2-7/8" TBG. PU & RIH WITH RBP, SET AT 11406'. POOH WITH SETTING TOOL@ REPORT TIME. OPERATIONS SUMMARY FROM TO HOURS CODE TROUBLE SUB PHASE DESCRIPTION 00:00 04:30 4.50 CM P 5 80CMPL FINISH DISP. WELL WITH 10.5 CaCI 04:30 06:00 1.50 CM P 1 80CMPL FILLED TRIP TANK, PUMPED SLUG BEFORE COMMING OUT OF HOLE 06:00 17:00 11.00 CM P 4 '80CMPL POOH WITH DRILL PIPE, CASING SCRAPPERS AND BRUSHES. LD 27/8" TUBING. I 17:00 21:30 4.50 CM P 4 80CMPL PU AND RUN 95/8" RBP, SET AT 11406' 21:30 00:00 2.50 CM P 4 80CMPL POOH WITH SETTING TOOL AT REPORT TIME. DENSITY(ppg) I 10.50 I:PP ECDI [MUD DATA .: DAILY COST 20,567.40 I CUMCOST I 1,377,729.22 :wU. HP O, WAT %SandIMBT, .:''PhIPM el Ca: .2S: LIME :ESi 29 '1/ / /' ' / / / / : M'UDVOLUMES(bbl} / ANNULAR ::VELOCITIES:! ~ft/min} ::. HOLE: PIT I , PIT.'2::i ::: : ::PIT.3 :i!:[i!, :':_:"4&5::' ::' ":. TOTAL::: i: MUD:LOST:,MUD:DUMPED' --------":!ANN!vEL:DP::': :::ANN:VEL DCANNVEL RISER o.o : : ~ :' :, '::: ! · BITS:: " '~, BIT/RUN : SIZE: .: : MANUF~::::,:::!i: :i'{:::iTypE :i .i:SERIALNO., I JETS ORTFA: DEPTH: IN ? DATE IN ~: I-O-D'L-B-G-O-R ', 20/ 1 4.125 ISmith ' I'OFM tN46960] 17,864.0 10/26/98{/ ....... BIT OPERATIONS:: . :.. BIT/RUN WOB, : RPM . , :: :::pRESS P BIT' : HRS 24HrDISTI 24Hr ROP.';. CUMHRS CUM ROP 20 / 1 / / BNA NO~.I 39 BHA:/HOLE:CONDITIONS BIT NO. 20 BHA WT. BELOW: JARS ': STRING WT. UP: STRING WT. DN STRING' WT: ROT I TORQUE/:UNITS: BHA LENGTH I 0.00 ITEM DESCRIPTION NO JTS ' LENGTH O.D. I.D. CONN SIZE CONN , PERSONNEL DATA COMPANY SERVICE . NO. HOURS COMPANY SERVICE NO. HOURS PHILLIPS PETROLEUM SUPERVISION 6 BAKER INTEQ MUD LOGGERS 2 POOL ARCTIC ALASKA RIG CREWS 26 VECO PRODUCTION ROUSTA 3 APOLLO CUTTINGS INJECTION 4 WEATHERFORD TONG OPERATOR 1 RAY GLENN MUD ENGINEER 1 HALLIBURTON Packer man 1 BAROID MUD ENGINEER 1 SSI CATERING 5 SECORP MEDIC 2 Printed: 10/31/98 6:23:37 AM Page 2 of 2 PHILLIPS PETROLEUM CO Daily Drilling Report 24 HRS PROG ' T VD,35613 WELL NAME TMD DFS REPT NO. DATE North Cook Inlet Unit B-3 17,864 183 ! 184 10/31/98 MUD INVENTORY ITEM UNITS USAGE COST ON HAND BARAFIBER 25.00 LBS BARAKLEAN 55.00 GAL 7 BARASCRUB 55.00 GAL 5 BAROID BULK 100.00 LBS 2,027 CRW-132F 55.00 GAL 10 5,280.00 10 CAL. CHLORI DE 80.00 LBS 513 15,287.40 175 INVERMUL MUD 42.00 GAL LIME 50.00 LBS 25 LIQUI-VIS 5.00 GAL 31 N-VIS 25.00 LBS 63 OMC 2 5.00 GAL 14 CON-DET 42.00 GAL 3 DRILLTREAT 55.00 GAL 3 BARACARB 50 50.00 LBS BARACARB 25 50.00 LBS GELTONE 50.00 LBS WALNUT PLUG M. 50.00 LBS DURATONE 50.00 LBS STICKLESS LBS STEEL SEAL 50.00 LBS SUSPEND TONE 50.00 LBS EZ-MUL 42.00 GAL INVERMUL NT 42.00 GAL 4 DIESEL 42.00 GAL DRILLTREAT 5.00 GAL RM-63 42.00 GAL XFOAM 20L MIL-POLYMER 303 25 KG SOLTEX 50.00 LBS OMC 42 55GAL AQUAGEL 100.00 LBS 4 Printed: 10/31/98 6:23:37 AM Page 1 of 2 PHILLIPS PETROLEUM CO Daily Drilling Report WELL NAME 24 HRS PROG TMD TVD,35613 DFS REPT NO. DATE North Cook Inlet Unit B-3 17,864 184 185 11/01/98 SUPERVISOR RIG NAME & NO. FIELD NAME ! OCS NO. AUTH MD DAILY TANG CUM. TANG KSW/WALT CARRICO Unocal / PoD Arctic Alaska 428 . NORTH COOK INLET 0.00 785,647.68 CURRENT STATUS ACCIDENTS LAST 24 HRS.? DALLY IHT W/O MUD CUM INTANG W/MUD RIG RELEASED FROM B-3 AT NOON. 43,773.55 19,215,103.76 24 HR FORECAST DATE OF LAST SAFETY MEETING 'DAILY TOTAL CUM COST W/MUD 10/29/98 43,774 19,993,474 LITHOLOGY JAR HRS OF SERVICE BHA HRS SINCE INSP LEAKOFF AFL AUTH. TR CLYST,50% SST,50% SLT,TR 1 15.83 P-V140 15,488,000 LAST SURVEY: DATE TMD INC AZlM I LAST CASING NEXT CASING LAST BOP PRES TEST 10/21/98 17,864.0 35.190 190.620I 7.000 (in.) @ 15,301.0 (ft) 5.000 (in.) @ 17,857.0 (ft) 10/26/98 24 HR SUMMARY: FINISH POOH WITH SETTING TOOL. PULL WB. ND BOP & RISER. NU DRY HOLE FLANGE & TEST. RIG RELEASED FROM B-3 AT 12 NOON, 10-31-98 OPERATIONS SUMMARY FROM TO HOURS CODE TROUBLE SUB PHASE DESCRIPTION 00:00 02:00 2.00 CM P 4 80CMPL FINISH POOH WITH SETTING TOOL & LD SAME.. 02:00 06:00 4.00 CM P 6 80CMPL PULL WEAR BUSHING. RIG DOWN FLOOR· ND BELL NIPPLE. 06:00 10:00 4.00 'CM P e 80CMPL ND BOP, CLEAN UP IN BOP ROOM. 10:00 12:00 2.00 CM P 6 80CMPL ND & REMOVE RISER, INSTALL DRY HOLE TREE & TEST TO 1500 FOR 20 MIN. RIG RELEASED FROM B-3 AT 12:00 HRS 10-31-98 COMMENTS NOTIFY BLAIR WENDEZL FROM AOGCC OF RIG SKID FROM B-3 TO B-1 DENSITY(ppg) 10.50 PP LCD MUD DATA DAILY'COST / ~ CUM COST -I~ FV PV/YPI GELS: ::WL/HTHP FC/T~SOL: OIL/WAT %Sand/MBT: : PhipM: Pf/Mf Cl ' : Ca H2S::: LIME: .ES::' 29 1/I / / / / / / / · ::i: i ,,i:::. i MUD::VOLU:MES (bbl)::/ANNULAR.VELOCiTiES: (ft/min): . 819.0HOLE : :.: PIT65.0:1. PIT: 2i:65.0il: i PIT70103:: . i ~i 'i:i: 4810'!i4&5ii:::':::i! ::. 1,067.0TOTAL!:: i.. MUD:LOST: :MUD DUMPED' :. :ANN:VEL DP ": ANN'VEL DC: ANN:VEL: RISER . . · BIT/RUN SIZE. i ::: MANUF.' 'i. :'r~PE: i:;': :i:: SERIAL NO. : i JETS ORTFA DEPTH IN DATEIN ] I,O-D,L,B;G,O-R 20 / 1 ~I' 125 I Smith OFM N46960 17,864.0 10/26/98~/.: .... ::": ' : :BIT OPERATIONS BIT/RUN' .wOB :::':/ 'GPM:: ;:!:PREss: BIT::: HRs' .24HrDIST 24HrROP : CUM.HRS cuM:DEPTH :CUM ROP 20 / / B'HA NO; , :BHA:/HOLE' CONDITIONS: BIT NO. I 20 39 BNA WT. BELOW JARS:it STRING w'r. UP ':STR!NG WT;DN STRING WT; ROT ' TORQUE/UNITS BHA LENGTH ] o.oo ITEM DESCRIPTION NO JTS LENGTH O.D. I.D~ CONN SIZE CONN TYPE PERSONNEL DATA COMPANY SERVICE NO. HOURS COMPANY SERVICE NO. HOURS PHILLIPS PETROLEUM SUPERVISION 6 SECORP MEDIC 2 . POOL ARCTIC ALASKA RIG CREWS 26 BAKER INTEQ MUD LOGGERS 2 APOLLO CU'FFINGS INJECTION 4 VECO PRODUCTION ROUSTA 3 RAY GLENN MUD ENGINEER 1 VETCO GRAY WELL HEAD SERVICE 1 BAROID MUD ENGINEER 1 SSI CATERING 5 ~ '¢ F F iV F D JAN 3 3 1999 Oil & liaS uons~4~,,~,c~}~r~ 10:43:35 AM Anchorage Page 2 of 2 PHILLIPS PETROLEUM CO Daily Drilling Report WELL NAME 24 HRS PROG TMD T~D,35613 DFS REPT NO. DATE North Cook Inlet Unit B-3 17,864 184 185 11/01/98 MUD INVENTORY ITEM UNITS USAGE COST ON HAND BARAFIBER 25.00 LBS BARAKLEAN 55.00 GAL 7 BARASCRUB 55.00 GAL 5 BAROID BULK 100.00 LBS 2,027 CRW-132F 55.00 GAL 10 CAL. CHLORIDE 80.00 LBS 175 INVERMUL MUD 42.00 GAL LIME 50.00 LBS 25 LIQUI-VIS 5.00 GAL 31 N-VIS 25.00 LBS 63 OMC 2 5.00 GAL 14 CON-DET 42.00 GAL 3 DRILLTREAT 55.00 GAL 3 BARACARB 50 50.00 LBS BARACARB 25 50.00 LBS GELTONE 50.00 LBS WALNUT PLUG M. 50.00 LBS DURATONE 50.00 LBS STICKLESS LBS STEEL SEAL 50.00 LBS SUSPEND TONE 50.00 LBS EZ-MUL 42.00 GAL INVERMUL NT 42.00 GAL 4 DIESEL 42.00 GAL DRILLTREAT 5.00 GAL RM-63 42.00 GAL XFOAM 20L MIL-POLYMER 303 25 KG SOLTEX 50.00 LBS OMC 42 55GAL AQUAGEL 100.00 LBS 4 Printed: 11/01/9810:43:35 AM PHILLIPS PETROLEUM HOUSTON, TEXAS 77251-1967 BOX 1967 NORTH AMERICA EXPLORATION AND PRODUCTION COMPANY December 18, 1998 BELLAIRE, TEXAS 6330 WEST LOOP SOUTH PHILLIPS BUILDING Mr. Blair Wondzell Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Wondze!l: Phillips Petroleum Company received approval for an "Operation Shutdown" on the North Cook Inlet Unit B No. 3. In the approval, Form 10-404 was requested as subsequent documentation. I have attached a Report of Sundry Well Operations (Form 10-404). If you have any questions regarding this, please contact Shonna Boyer at (713) 669-7980. Sincerely, N. P. Omsberg Drilling Manager Phillips Petroleum Company NPO/smb CC: P. R. Dean L. L. Lyon ~ S. M. Boyer J. D. Admire REP STATE OF: ALASKA ~ ~SKA OIL AND GAS CONSERVATION~...,..,,MISSION hl' OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation snutdown'<~ Siimulate C] Plugging Q Pgrforate Q Pull tu0ing ~ Alter Casin'g I-10tl~er ~] 2. Name pt Ooerator Phillips Petroleum Company 3. Address 6330 W. Loop South Dellaire'. T× 7740] 4. L~cati0n of we~l at surface Leg 1, Slot 2 Platform, 4029' FSL & 4056' FEL RO9W, N. orth Cook Inlet, Alaska At tO'0 Of productive interval At effective del3th At totalde~th 17864' MD 13356' 4036' FSL & 3282 ' FEL Sec. 11. Present well condition summary Total depth: measured true vertical PPCO. Tyonek Sec. 6 - TIIN- TVD 13-TIIN-RIOW 17864 feet Plugs(measured) 13356 feet Effective depm: measured 17864 feet Junk (measured) true vertical 13356 feet 5. Datum elevation (DF or KB) RKB 1 3 2 Feet 6. Umt or Property name North Cook Inlet Unit 7. Well number NCIU B-3 8. Approvalnum~er 98-059 9. APInum~er 50--883-20095 10'~°lNorth Cook Inlet mit, Field Development Casing Length Size Cemented Measured depth Structural 30" Dr iven 461 Conductor 20" Existing 1214 Surface 13-3/8" Existing 4400 Intermediate 9-.5/8" Existing 11761 ProdUction 5" & 3 1/2" Cemented 17150/17864 Liner 7" Existing 15301 Perforation depth: measured N/A True Vertical depth 461 1208 3752 8918 12777/13356 11379 true vertical N/A Tubing (size, grade and measured deptll)None -JVNJ J O Packers and SSSV (type and measured deptl"t) No n e 12. Stimulation or cement squeeze summary Intervals treated (measured) Treatment,description including volumes usea and final pressure N/A 13. Prior to well operation Subsequent to operation Re0resentative Daily Average Production or Injection Data Oil. Sbl Gas-Mcr Water-Sbl , Casing Pressure N/A Tubing Pressure 14. Attachments Daily Reoort of Well Operations r"l Copies of Logs and Surveys Run C] 15, I here~oy certdy that me foregoing is true and correct to me best pt my knowledge Form 10-404 Rev. 12-1-85 Title Submit in Duplicate - 44 - PROC DEU & PROD TECH PHILLIPS PETROLEUM COMPANY North America Production.Drilling FAX COVER SHEET 6330 West Loop South Bellalre, Texas 77401 · P.O, Box f967 Houston, Texas 7725f.1367 713 669 7917 FAX NUMBERS: 713/~69.3754 713/669-~17~5 7f3/669.2975 PROBLEMS? PLF_4SE CALL 7f~/669.7932 Number of Pages ~_ Including Cover Sheet MESSAGE - [ - 11 i i_ · I I [ i~_ -. _ 1_ iiL ill_ i i1_Il _ IlI ...... "FOR~'INT~ERNAI- U~E ONI. Y -- -- Il I Il II!~~ ,.I ! .... Il II -Tgansmitted I~y: " - '" ...... Date: Time; ·_ Illl ,,, .1_ .,~ I,~ ..__ ,, ,._ OEC 7 998 /sJa~&Gas Cont Comm~ UEC-17-1998 15:55 PROJ DEU & PROD TECH 713 669 7917 P.02/02 N¢IU Izo' e '~2~4' MD (.!zo~' 'rw) _.1 INete: Liner la~) Will be negative teme~ prior to setting RE~P, eliding sleeve below I~ 11,420' AHR 9 SI8" x 4 1/2' Packer ~11t,40o' MD ~.1.,450' MD (8697' TV_D) 7' 32# P-'~'10 ~ 15,301' MD (11,379' 'rvo) lltuml- 10,760_psi JTop of :~Unfi'~h Sand 16,780' MD I2,485' 1'VD ITop afN, Forelands Sand ~ 17,4,~3' MO 13,032' TVD 3 1/2" PH-6 12,95~ P-'Il0 tubing ¢~ 16,800' MD (bUrst - 10,900 Psi) ID - 2,75" ...m - ~3,4s0 r~l Prepared t~: N. Hlngorani December 14,1998 TOTAL P.02 PHILLIPS PETROLEUM HOUSTON, TEXAS 77251-1967 BOX 1967 NORTH AMERICA EXPLORATION AND PRODUCTION COMPANY October 17, 1998 BELLAIRE, TEXAS 6330 WEST LOOP SOUTH PHILLIPS BUILDING Mr. Blair Wondzell Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Wondzell: Phillips Petroleum Company is requesting approval for an "Operation Shutdown" on the North Cook Inlet Unit B No. 3. Phillips has reached total depth on this well and completed logging operations. The decision has been made to run casing. After this takes place, Phillips would like to temporarily suspend this well and move back to the B-1 sidetrack well to begin completion operations. The reason for suspending operations on the B-3 well is due to the questions still surrounding the B-1 Sidetrack. Phillips plans to complete the North Forelands zone in the B-1 Sidetrack. At this time, there are concerns that this zone will not be commercially productive in this well. If it is not, Phillips plans to convert the B-1 Sidetrack into a gas well producing the Beluga and Cook Inlet Sands. In the interest of having enough lead time to order the equipment required to convert the B-1 Sidetrack to a gas well, the following order of operations will allow us to do this. Temporarily Suspend NCIU B-3 Complete and Test North Forelands Zone in B-1 Sidetrack Workover NClU A-13 Convert NClU B-1 Sidetrack to NCIU A-14 Gas Well (if necessary) Complete NClU B-3 Well as a dual in the Sunfish and North Forelands In order to complete the NCIU B-3 at a later date, Phillips plans to leave it ready for completion operations by conducting the following operations (cement liner, test casing and liner lap, clean out wellbore, change fluid from 14.5 ppg OBM to 10.5 ppg CaCI2, set bridge plug above liner top and test). I have attached an Application for Sundry Approvals and wellbore schematic. If you have any questions regarding this, please contact Shonna Boyer at (713) 669-7980. Sincerely, N. P. Omsberg Drilling Manager Phillips Petroleum Company NPO/smb CO: P. R. Dean L. L. Lyon S. M. Boyer J. D. Admire f STATE OF ALASKA i', ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR 1. Type of Request: Abandon Suspend ~ Alter Casing __ Repair Well Change Approved Program 2. Name of Operator: Phillips Petroleum Co. 3. Address: 6330 W. Loop South Bellaire1 Texas 77401 4. Location of well at surface: 4029' FSL & 4056' FEL Sec 6 - T11N - R09W At top of productive interval: SUNDRY APPROVALS Operation Shutdown _X_ Plugging__ Time Extension__ Pull Tubing Variance 5. Type of Well Development X Exploratory Stratigraphic Service Leg 1, Slot 2 PPCo. Tyonek Platform North Cook Inlet, Ak. At effective depth: At total depth: 17864' MD 4036' FSL & 3282' FEL Sec 13-T11N- R10W 12. Present well condition summary: Total Depth: measured 17864 true vertical 13356 13356' TVD feet feet Reenter Suspended Well~ Stimulate Perforate Other (annular inj) 6. Datum elevation (DF or RKB) RKB 132 Feet 7. Unit or Property Name North Cook Inlet Unit 8. Well Number NClU B-3 ! 9. Permit Number / Approval Number 98-059 10. APl Number 50-883-20095 11. Field / Pool North Cook Inlet Unit Field Development Effective Depth: measured 17864 feet true vertical 13356 feet Casing: Length Size Structural 30" Conductor 20" Surface 13-3/8" Intermediate 9-5/8" Liner 7" Production Production 3-1/2" Perforation Depth: measured N/A Cemented Measured Depth True Vertical Depth Driven 461 461 Existing 1214 1208 Existing 4400 3752 Existing 11761 8918 Existing 15301 11379 Cemented 17150 12777 Cemented 17864 13356 true vertical N/A Tubing (size, grade and measured depth) Packers and SSSV ( type and measured depth) 13. Attachments: Description Summary of Proposal X NONE NONE 0Rt61NAL Detailed Operations Program__ BOP Sketch__ 14. Estimated Date for Commencing Operations: Februa~ 1 ~ 1999 16. If Proposal was Verbally Approved: Oil Name of Approver Date Approved Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge: COMMISSION USE ONLY Conditions of Approval: Notify Commission so Representative may witness Plug Integrity . BOP Test Location Clearance 15. Status of Well Classification as: Mechanical. Integrity Test Subsequent Form Required ,x1'0'~O'~ ~ c._~._ _,u_~_ ~ ¢~~ ~,-,~'"~ ~o~..,,,~,.~ Form 10-403 Rev. 06/15/88 SUBMIT IN TRIPLICATE NCIU B-3 TEMPORARY SUSPENSION DIAGRAM 0.5 ppg CaC 2 ,... !1 1~-3/8" ~ 4400' MD (3752' TVD) J Note: Liner Iai) will be negative tested prior to Isettin9 RBP. Top of Sunfish Sand @ 16,780' MD 12,485 TVD Top of N. Forelands Sand @ 17,483' MD 13,032' TVD RBL-~-~.~7',4-25' MD (8680' TVD) I ~E~o~-~.5,,_~ 11,450, MD (8697' TVD) ] [T~-"~O_L ?'~ 11,545' MD (8765' TVD) I ~9-5/8" ~ 11,761' MD (8918' TVD) t I T.__O~..C_._~ '.~1.4,_..~300...._~' I~D (10,734' TVD) ~'7" ~ 15,301' MD (11,379' TVD) J 15'i...~.,150' MD (12,777' TVD) I ~._-_~_.17,864' MD (13,356' TVD) Prepared by: Shonna Boyer October 17, 1998 0CT-19-1998 13:25 PHILLIPS PETROLEUM 7136695755 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS I I IIi I I i iiiii 1. Type of Request: Abandon __ Suspend__ Operation Shutdown _X_ AEe~ Casing ~ Repair Well ~ Plugging ~ Time Extension Change Approved Pro~ffam 2. Name'of Operator: ..... ,Phaips Petroleum Co. 3. Address: 6330 W. Loop South Bel~aire, z.Texas 77401 4. Local~on of well at surface; 4029' FSL & 4056' FEL At top of productive interval: , i,P~l; Tubing Varbnce . Type °f WelF' ....... Development Exploratory Stratigraphic Service Leg 1, Slot 2 PPCo. Tyonek"lSiatform Sec 6 - T11N - Rogw North Cook Inlet, Ak. At effective depth: At total depth: 17864' MD 4036' FSL & 3282' FEL Sec 13-T,,1.,!.N - R10W 12. Presort{ Well condition summary: Total Depth: measured 17864 ~l-ue ve~¢al 13356 13356' TVD feet feet Effective Depth; measured 17864 feet true vertical 13356 feet Casing: Length Size Cemented Structuml 30" Ddven Conductor 20'" Existing Surface 13-318" Existing Intermediate. 9-5/8" Existing Liner 7" Existing Production 5" Cemented Produ~on 3-1/2" Cemented Perforation Depth: measured N/A Measured Depth 461 1214 4400 11761 15301 17150 17864 P. 04/05 Reenter Suspended Well Stimulate Perforate Other (annular inj) 6. Datum elevation (DF or RKB) ............. RKB 132 Feet 7. "0'nit or Property Name North Cook Inlet Unit 8. Well Number NCIU B-3 9. Permi:t ~l~'i~'e~/Approval Number 98-059 10. APl Number 50.883.20095 11. Field I Pool North Cook Inlet Unit ........ Field Development ·aska Oil & 6as Tr.~ ~ 208 3752 8g~8 J J 379 12777 13358 true vertical N/A Tubing (size, grade and measured depth) NONE Packers and $SSV ( type and measured depth) NONE ORIGINAL ii .! ...... II iiii 13, Attachment: DeScription Summary of Proposal _X"-__- ...... 14. Estima~'ed Da~ for Commencing Operatior~;;' ~eb,~ua~/~, !S~e ...... 16. If Proposal was Verbally Approved: Oil .. Name of Approver Date Approved Service BBII,, I I ........... I Iallllll 17, I hereby certify that the foregoing is true and correct to the best of my knowledge: Detailed Operations Program ... 15. Status of Well Classification as: Suspended X (TA) ~iSalon N. P. Omsbe Title Drillin mager FOR COMMISSION USE ONLY Conditions of Approval: Notify Commission so Representative may witness Plug Integrity ...... BOP Test...__ Location Clearance Mechanical Integrity Test ~_ Subsequent Form Required 10 - ~ Date Order of the Commission Form 10,403 Rev, 06115188 Original 5.~g~,,~,, ..,~. u~li~V~6 ~,Jd~aston ~,,~e6 ooeJ Commissioner D~te SUBMIT IN TRIPLICATE 0CT-19-1998 13:25 PHILLIPS PETROLEUM NCtU 8-3 TEMPO,~ARY SUSPENSION DIAGRAM ?136695?55 P.05/05 tNote: Liner lap will b~ negative tested prior tO ~tting RBP..___J ~"F~ ~ ~,4=s, ~,~,{ssso, wp) .... I [TOL"{'t" ~L~_,!~o, MI;;) (8697' TV'D) ....._J To~,?,=.~ ~ 545' Mm (S?s~' TV~)_, J 9~-~i'8'~.,.,~ 11,7~1' MD (8918'. TVD)..,. ITop of SunfiSh Sand {~ 1~,780' MD ~,~s$'...TVD_g..___ fTop of N, FOrelands a~d @ 17,483' MD 3~052' TVD f"To_.c_~ ~4,300' MD (~0:~34' .T..VD) I L~:,.,~ 17.150' MD (1 ;~,???' TVD.~) J Prepared by: Shonna Boyer October 17. 1998 TOTAL P.05 0CT-19-1998 13:24 PHILLIPS PETROLEUM ?136693?55 P.01~05 PHILLIPS PETROLEUM COMP. ANY North America Production-Drilling FAX COVER SHEET 6330 West Loop South Bellaire, Texas 7'/40f P.O. Box 1967 Houston, Texas 77251-f967 FAX NUMBERS: 713/669.3754 713/669-37~5 713/669.2975 PROBLEMS? PLF. ASE CALL 7f3/669-7932 Company; Fa~ Number: Number of Pages 5 Including Cover Sheet .... l! II I Tin. smiled byr ' Time: ' ' ii i · i i RECEIVED OCT ' Alaska 0il & Gas Cons. Commission Anchorage MEMORANDUM TO: THRU: State of Alaska Alaska Oil and Gas Conservation Commission Blair Wondzell, P. I. Supervisor DATE: October 16, 1998 FILE NO: ax8kjpfe.doc FROM: Chuck Scheve, C ~ SUBJECT: Petroleum Inspector BOPE Test Pool 428 NCIU B-3 PTD # 98-0059 Friday. October 16~ 1998: I traveled to the Phillips Tyonek Platform and witnessed the weekly BOPE test on Rig 428. As the attached AOGCC BOPE test report shows the test lasted 3 hours with no failures. The test went well with good test procedures being employed by the Pool crews. The rig was clean and all related equipment appeared to be in good working order. The Platform though extremely crowded was well organized. Summary: I witnessed the weekly BOPE test on Rig 428 Drilling the Phillips NCIU B-3 Well. Pool Rig 428, 10116198, Test time 3 houm, 0 Failures Attachment: ax8kjpfe.xls X Unclassified Confidential (Unclassified if doc. removed ) Confidential STATE OF ALASKA" OIL AND GAS CONSERVATION COMMISSION BOPE Test Report OPERATION: Drlg: ~ Drlg Contractor: Operator: Well Name: Casing Size: 7" Test: Initial X Workover: Pool Rig No. 428 P'iD # 98-059 Philips Rep.: B-3 Rig Rep.: Set ~ 15,301 Location: Sec. 6 Weekly X Other DATE: 10/16/98 Rig Ph.# 772-6013 James Carrell Rick Brumley T. 11N R. 9W Meridian Seward Test MISC. INSPECTIONS: Location Gen.: OK Housekeeping: OK (Gert) P'ID On Location ;YES , Standing Order Posted YES Well Sign OK Dd. Rig OK Hazard Sec. OK FLOOR SAFETY VALVES: Quan. Pressure Upper Kelly I IBOP I ! 250/5,000 Lower Kelly / IBOP . 1! 250/5,000 Ball Type I 250/5,000 Inside BOP I 250/5,000 P/F P P P P BOP STACK: Annular Preventer 1 Pipe Rams 1 Lower Pipe Rams Blind Rams 1 Choke Ln. Valves "/ HCR Valves "2 Kill Line Valves 1 Check Valve Quan. Test Press. P/F 25O/2500 250/5,,000 2 o ,ooo ,,250/s, ooo 250/5,000 250/5~000 N/A P CHOKE MANIFOLD: P No. Valves 14 P No. Flanges 25 P Manual Chokes 1 P Hydraulic Chokes 2 P Test Pressure 250/5,000 Functioned Functioned P/F ACCUMULATOR SYSTEM: , System Pressure 3000 i , Pressure After Closure 1450 i ~,, MUD SYSTEM: Visual Alarm 200 psi Attained After Closure_.___ minutes 25 sec. Trip Tank OK OK System Pressure Attained 2 minutes 30 sec. Pit Level Indicators OK OK Blind Switch Covers: Master: OK Remote: OK Flow Indicator OK OK Nitgn. Btl's: 12 ~ 2000 PSi Meth Gas Detector OK OK Psig. H2S Gas Detector OK OK Number of Failures: 0 ,Test Time: 3.0 Hours. Number of valves tested 22 Repair or Replacement of Failed Equipment will be made within 0 days. Notify the Inspector and follow with Written or Faxed verification to the AOGCC Commission Office at': Fro( No. 276-7542 Inspector North Slope Pager No. 659-3607 or 3687 If your call is not returned by the inspector within 12 hours please contact the P. I. Supervisor at 279-1433 REMARKS: Good test Distribution: orig-Well File c - Oper./Rig c - Database c - Trip Rpt File c - Inspector FI-021L (Rev. 12/94) STATE WITNESS REQUIRED? YES X NO 24 HOUR NOTICE GIVEN YES X NO Waived By: Witnessed By: Chuck Scheve SCHLUMBERGER WELL SERVICES A DIVISION OF SCHLUMBERGER TECNOLOGY CORPORATION HOUSTON, TEXAS 77251-2175 JUN ] ~ 1,9o. 98 Phillips Petroleum Company 6330 West Loop S., Texas Commerce Bank Building, P.O. Box 1647 Houston, TX 77401 ATTENTION: Enclosed are 8 BL/2 films Company Phillips Petroleum Company Well Cook Inlet Unit NCIU.B3 Field North Cook Inlet Additional prints are being sent to: 2 BL prints Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Attn: Blair E. Wondzell prints PLEASE REPLY TO: Schlumberger Well Services HC01, Box 337 Kenai, AK 99611 Attn: Shelley Ramsey Platform Express Three Detector LithoDensity of the Compensated Neutron/GR, Run 1,6/7/98 on: County Kenai State Alaska prints prints prints prints prints PLEASE SIGN AND RETURN ONE COPY OF THIS TRANSMITTAL TO THE ADDRESS INDICATED ABOVE. THANK YOU. prints The film is returned to Phillips Petroleum Received by: We appreciate the privilege of serving you. · , ;..,~,:, ~,~ ,. k!aska ~ ,~ dss Cons. Cor~lmJ~ .:,nchora~e Date: ly yours, 0 / Schlumberger Well Services Rachel Walsh Engineer in Charge SCHLUMBERGER WELL SERVICES A DIVISION OF SCHLUMBERGER TECNOLOGY CORPORATION HOUSTON, TEXAS 77251-2175 JUL :~ '~ 19~8 Phillips Petroleum Company 6330 West Loop S., Texas Commerce Bank Buildin9, P.O. Box 1647 Houston, TX 77401 ATTENTION: PLEASE REPLY TO: Schlumberger Well Services HC01, Box 337 Kenai, AK 99611 Attn: Shelley Ramsey Enclosed are Company Well 8 BL/2 films of the Caliper Log/GR, Run 1,7/11/98 Phillips Petroleum Company North Cook Inlet Unit "B" No. 3 on: Field North Cook Inlet Additional pdnts are being sent to: 2BL prints (-~ Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchora~le, AK 99501 Attn: Blair E. Wondzell prints County Kenai State Alaska prints prints prints prints prints PLEASE SIGN AND RETURN ONE COPY OF THIS TRANSMITTAL TO THE ADDRESS INDICATED ABOVE. THANK YOU. prints The film is returned to Phillips Petroleum Received by: We appreciate the privilege of serving you. Date: Very truly yours, Schlumberger Well Services~ Rachel Welsh ~- Engineer in Charge MEMORANDUM State of Alaska TO: Alas_ka Oil and Gas Conservation Commission David Johnsto ,n~"'~ DATE: July 30,1998 Chairman THRU: FROM: Blair Wondzell, ~ ¢/~f~ FILE NO' P. I. Supervisor ?~f" John Spaulding,~-~' / SUBJECT: Petroleum Insp...f:.7'/?; ! Pool 428 BOPE.doc Confidential: Yes No X Tyonek Plat. BOPE Test Philips Petr. Pool 428 North Cook Inlet Unit B-3 PTD 98-059 July 29, 1998: I traveled this date to Philips Petroleum's North Cook Inlet Unit Tyonek Platform to witness a BOPE test on Pool rig 428. The AOGCC BOPE Test Report Form is attached for referenCe. I received a call approximately 12 noon from James Carrell Philips Company Rep. That they would be out of the hole and ready to test BOP's on Pool rig 428 around 9 PM. After I arrived on the platform at 8:30 PM I was informed that the bottom hole assembly was stuck about 2000' out of the shoe. Needless to say I went to bed anticipating doing the BOP test the following day. July 30: Nothing had changed this AM (still stuck). After conferring with Blair I decided to go on home and do my waiting there. A very'unproductive trip to say the least!! August 1: Received a phone call at 6am from James Carrell Philps Co. Rep. that they would be ready to test BOP's in about 6 to 8 hrs. Departed my residence at 7am. Arrived on the platform shortly after noon and the rig was still coming out of the hole. The top drive broke down and took 2 hours to repair. Finally commenced testing BOP's at 8:30pm. Finished testing BOP's 4.5 hours later. Summary: Witnessed the BOP test on; Pool 428, Tyonek Platform, 4.5 hours test time, 1 failure (upper IBOP) AttachmentS: Pool 428 BOPE.xls STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report OPERATION: Drlg: X Workover: Drlg Contractor: Pool Rig No. Operator: Philips Petroleum (Tyonek PlaL ) Well Name: NCIU B-3 Casing Size: 9 5/8" Set @ 11,771'md Test: Initial Weekly X Other 428 PTD # Rep.: Rig Rep.: Location: Sec. TEST DATA DATE: 8/1/98 98-059 Rig Ph.¢¢ 776-6013 James Carrefl Frank Pluid 6 T. 1 ?N R. 9W Meridian Seward MISC. INSPECTIONS: Location Gen.: ok Housekeeping: ok PTD On Location yes Standing Order Posted (Gen) y~s Well Sign yes Drl. Rig ok Hazard Sec. yes BOP STACK: Annular Preventer Pipe Rams Lower Pipe Rams Blind Rams Choke Ln. Valves HCR Valves Kill Line Valves Check Valve Quan. Test Press. P/F ? 250/2500 P 1 250/5,000 P 1 250/5, 000 P 1 250/5, 000 P 1 250/5,000 P 2 250/5,000 P 1 250/5, 000 P na FLOOR SAFETY VALVES: Upper Kelly/IBOP Lower Kelly/IBOP Ball Type Inside BOP Test Quan. Pressure P/F ? 250/5,000 F* 250/5,000 P 250/5,000 P 250/5,000 P CHOKE MANIFOLD: No. Valves No. Flanges Manual Chokes Hydraulic Chokes Test Pressure P/F 12 250/5,000 P 30 250/5,000 P 2 Functioned Functioned ACCUMULATOR SYSTEM: System Pressure 2,950 I P Pressure After Closure 1,600 I P MUD SYSTEM: Visual Alarm 200 psi Attained After Closure ~ minutes 23 sec. Trip Tank ok ok System Pressure Attained '/ minutes 36 sec. Pit Level Indicators ok ok Blind Switch Covers: Master: x Remote: x Flow Indicator ok ok Nitgn. Btl's: ~2 @ 2200 avg. Meth Gas Detector ok ok Psig. H2S Gas Detector ok ok TEST RESULTSi · Number of Failures: 1 ,Test Time: 4.5 Hours. Number of valves tested '~8 Repair or Replacement of Failed Equipment will be made within 1 days. Notify the Inspector and follow with Written or Faxed verification to the AOCCC Commission Office at: Fax No. 276.7542 Inspector North Slope Pager No. 659-3607 or 3687 If your call is not returned by the inspector within 12 hours please contact the P. I. Supervisor at 279-1433 REMARKS: Upper/BOP failed and was rebuilt and retested prior to my departure from the platform Distribution: Grig-Well File c- Oper./Rig c- Database c - Trip Rpt File c- Inspector STATE WITNESS REQUIRED? YES X NO 24 HOUR NOTICE GIVEN YES X NO Waived By: Witnessed By: John H. Spaulding FI-021L (Rev.12/94) Pool 428 BOPE.XLS PHILLIPS PETROLEUM HOUSTON, TEXAS 77251-1967 BOX 1967 NORTH AMERICA EXPLORATION AND PRODUCTION COMPANY June 19, 1998 BELLAIRE, TEXAS 6330 WEST LOOP SOUTH PHILLIPS BUILDING North Cook Inlet Unit B-3 Permit No. 98-059 PPCo. Tyonek Platform North Cook Inlet Unit, Alaska Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Attn: Mr. Blair Wondzell Gentlemen: The proposed setting depth for the 9-5/8" casing string was 13,529' MD. When running this casing string, problems were encountered and the 9-5/8" had to be cemented in place at a depth of 11,761' MD (10,000' TVD). This casing setting depth was still sufficient to cover all necessary zones (Cook Inlet, Beluga, and Tyonek sands). The original intent was to cover the Middle Ground Shoal with this casing string to prevent any drilling problems through the next hole section. The reasons for abandoning the old hole section (12-1/4")include the following. Sufficient hole cleaning will be difficult because the next hole section will be smaller (8-1/2" vs. 12-1/4"). The old hole continues to come in and try to pack- off the drill pipe. This section needs to be drilled with a heavier mud weight to hold back the formations. The next hole section will be drilled with 14.0 ppg mud and this should hold back the Middle Ground Shoal without any problems. The plan is to set a sidetrack cement plug in the open-hole (see attached diagram). This cement plug will be used to kick-off and go around the old hole. The sidetrack will go just below the old hole and eventually come back up to meet the original targets. Should you have any questions, concerns or require any additional information, please contact Shonna Boyer at (71.3) 669-7980. N. P. Omsberg North America Drilling Manager NCIU B-3 SIDETRACK DIAGRAM i~o.. ~,~.,. ~ o~o~.,v~> I Desired TOC I @ 4350 MD (3717' TVD) i 113-3/8" (~ 4400' MD (3752' TVD) ] [TOC PLUG {~ 11,460' MD I 19-5/6" ~ 11,760' MD (8917' TVD~) I B J, PARA BOW TOOL SET ~ 12,200' MD lTD ~ 13,315' MD (10,000' TVD) I TONY KNOWLE$, GOVERNOR ~L~SKA OIL ~AND GAS CONSERYATION COMMISSION 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 April 24. 1998 Paul R. Dean Senior Drilling Engineer Spec Phillips Petroleum Company 6330 W. Loop South Bellairc, Texas 77401 Rc~ NCIU B-3 Phillips Pctrolcum Company Permit No: 98-59 Sur. Loc. 4029'FSL & 4056'FEL, Sec. 6, T11N, R09W, SM Btmhole Loc. 4036'FSL & 3282'FEL. Sec. 13, T11N, R10W, SM: Dear Mr.'Dean: Enclosed is thc approved application for permit to drill the above rcfcrcnced well. Thc permit to drill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. Your request for conductor depth variance is approved. Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25.035. Sufficient notice (approximately 24 hours) of the BOPE test performed before drilling below the surface casing shoe must be given so that a representative of thc Commission may witness the test. Notice may be given by contacting the Commission at 279-1433. Chairman BY ORDER OF THE COMMISSION dlf/Enclosures CC: Department of Fish & Game, Habitat Section w/o cncl. Department of Environmental Conservation w/o encl. PHILLIPS PI~mROLEUM COMPANY P.O. Box 1967 Houston, T. exas 77251-1967 6330 West Loop South Bellaire, Texas 77401 April 7, 1998 Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 North Cook Inlet Unit B No. 3 PPCo. Tyonek Platform North Cook Inlet Unit, Alaska Attn: Mr. Bob Crandall Gentlemen: Enclosed for your consideration and approval is a Form 10-401 (Application for Permit to Drill), which supplements the North Cook Inlet Unit B No. 3 form dated March 13, 1998. Phillips Petroleum Company, requests a well spacing exception for the cut point in the Sunfish Sand, which would provide a legal location in accordance to the Alaska Oil and Gas Conservation Commission Regulations (20 AAC 25.055 (a)(3) & (b)). There is one affected owner, ARCO Alaska Inc., which has been notified of the requested exception. Evidence of non-objection will be forwarded to the AOGCC upon receipt. The referenced well will be drilled from Phillips' Tyonek platform to develop the Sunfish and North Forelands reservoirs. Enclosed with the application are the following support documents: 1) An amended plat showing the referenced property, leaseholds, surface and proposed target and bottom hole locations. 2) The well will be directionally drilled to reach from the Tyonek Platform to the bottom hole location southwest of the platform as illustrated on the amended proposed directional plan. 3) The referenced well is scheduled to be spud approximately April 22, 1998 or as close thereafter as possible. Please reference the original application, dated March 13, 1998, for the remaining required documents. The AOGCC is requested to keep this application and the attachments confidential. Should you have any questions or require any additional information, please contact Paul. R. Dean at (713) 669-3502 or James C. Shoumaker at (713) 669-2197. Regards, N.P. Omsberg North America Drilling Manager enc: cc: J.W Konst (w/o enc) W.L. Carrico " J.R. Soybel " P.R. Dean (w/enc) STATE OF ALASKA ~, OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 1 a. Type of Work Drill X Redrill -- 1 lb. Type of well Exploratory __ Stratigraphic Test __ Development Oil X Re-Entry _ Deepen __ IService __ Development Gas __ Single Zone __ Multiple Zone X 2. Name of Operator: 5. Datum Elevation (DF or KB) 10. Field and Pool Phillips Petroleum Co. 132 feet North Cook Inlet Unit Field 3. Address: 6. Property Designation Development 6330 W. Loop South, Bellaire, TX 77401 ADL-17589 4. Location of well at surface: Tyonek Platform Leg 1 Slot 2 7. Unit or Property Name 11. Type Bond (SEE20AAC2S.025) 4029' FSL & 4056' FEL SEC 6-T 11N-R09W North Cook Inlet Statewide At top of productive interval: 8. Well Number Number 4780' FSL & 3000' FEL SEC 13-T11N-R10W NCIU B-3 41-0-524 At total depth: 9. Approximate spud date Amount 4036' FSL & 3282' FEL ~;EC 13-T11N-R10W 04/22/98 $200,000 12.Distance to nearest 13. Distance to nearest well 14. No. of acres in property 15. Proposed depth (MD and TVD) property line Surface: 4' 9920 500'FNL SEC 13-T11N-R10W NCIUA-12 17857 MD 13300TVD feet 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035 (e)(2)) Kickoffdepth 400 feet Maximum hole angle 47.99 degrees Maximum surface 7900 psig At total depth (TVD) 9719 psig Casing program Setting Depth size Specifications Top Bottom Quantity of cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) Driven 30" Drive 368' 0 0 407' 407' N/A 24" 20" 131 X-56 Premium 1206' 0 0 1206' 1200' Lead 550 sxs, Tail 690 sxs 16" 13-3/8" 72 L-80 BT&C 4587' 0 0 4587' 3800' Lead 1050 sxs, Tail 605 sxs 12-1/4" 9-5/8" 53.5 P-110 BT&C 13530' 0 0 13530' 10200' Lead 1360 sxs, Tail 190 sxs 8-1/2" 7" 32 P-110 BT&C 4627' 13230 10000 17857' 13300' 690 sxs 8-1/2" 3-1/2" (alt) 12.95 P-110 PH-6 4627' 13230 10000 17857' 13300' 1635 sxs (if used) '19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet Effective depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented Measured depth True Vertical depth Structural Conductor Intermediate Production Perforation depth: measured Anchorage true vertical 20. Attachments Filing fee_X_ Property plat X BOP sketch X Diverter Sketch X Drilling program_X_ Drilling fluid program X Time vs depth plot X Refraction analysis __ Seabed report __ 20 AAC 25.050 requirements (Directional Program) 21. I hereby certify that the f~rue and/correct to the best of my knowledge / Commission Use Only Permit Number IAPI Number IApproval Date ISee cover letter 8 - 05'9 I 50- ~ -" 2-(~09.~ I for other requirements Conditions of Approval: Samples required ~,_ Yes __ No Mud Icg required __ Yes ~ No Hydrogen sulfide measures __ Yes ~ No Directional survey required _~ Yes __ No Required working pressure for BOPE __2M __3M __5M _~ 1OM __15M ~i~._..~~ ~~ Other: by order of Approved by Commissioner the commission Date Form 10-401 Rev. 12-1-85 Submit in triplicate ~OH~ · t North Cook Inlet Unit "B" No. N. -- . I R lO'W PHILLIPS PETROLEUM ! I 1 SUnfish Sand 4'7'80' FSL & ,3000' FEL, SEC. 13,T~ 1N-R10W N. Forlands Sand [ 4326' FSL & 3175' FEL, SEC 13-T11N-R10W I Z~ t ~1 l~'Z. RgW COMPANY COOK INLET BASIN OIL &. GAS LEASE OWNERSHIP MAP ~ ~4~1 4044 North Cook Inlet Unit "B" No. 3, Surface Location:- 4029' FSL & 4056' FEL SEC 6-T11N-R09W Bottom Hole Location:- 4036' FSL & 3282' FEL SEC 13-T11N-R10W AnadrLll 8chi umbe rcjer Alaeka Oietrict 11./1 gaat 80Lb Avenue Anchora~e, AK 99518 (907} 3%9-451.3 laa)~ 344-2L60 WELl, PLAN for PH[bLIPS PETR~ObBUM (I)HPANY Hell ......... : NCIU-B3 Field ........ : Cook [nZet Computation..: Ninimum Curvature Un[ts ........ : gHaT $urface Lat..: 6[.0~676982 Surface L~~al Description Surface ...... : 4029 P~b 4056 ~8b S06 TLIN R09W 8bi 8unELsh TGT..: 4780 F~b 3000 FEL 813 T[LN RiON SM B~ff~ .......... = 4036 F~L 3252 F'I~L SL3 TIIN RI0W SM LOCATIONS - ALASKA Zone; X-Coord 33L989.73 327876.98 327583.8~ 4 Y-Coord 2586729.38 2576990.68 25762~0.85 Prepared ..... : 05 Feb 1998 Vert sect az.: 200.63 KB eLevation.; L3Z.00 fL )lagnetJc Dc[n; .22./26 (E) ~cale Factor.: 0.9999321.2 Convergence..: -0.8304~469 PROPOSED FfllL, I. PROFILE STATION 14EAb-qJR~D £NC~q ~ 0.O0 0.0~ KOP/~ O.75/100 400.00 C~VZ ~.00/]00 500.00 ~fl~ ~.50/200 600.00 ~.74 ~R~ ~.00/[00 700.00 2.93 DIRRCT]ON VERTICAL-DEPT~S AZf141/TH TVD SLrB-$EA 0.00 0.00 -132.00 321.00 399.95 267.95 29[.08 499.~2 ~67.92 25~.07 599.89 467.89 232.63 699.8~ 567.91 gBCT£O~ DEPART 0.00 -2.65 -~.47 0.S6 COORDINATES-PROH ALASKA Zone 4 TOOL DL/ 9T8U.~RAD X Y PAC~ t00 0.00 N 0.00 E 33~989.7) 2586729.38 39L O.O0 4.07 N 3.29 W 33[986.49 258673].50 69~ 0.38 5.52 N 5.22 W ~31984.59 2586734.97 304L 0.75 5.57 N 7.80 [g 33]982.02 2586735.06 [~TL ~.00 3.66 N 11.30 W 33~978.49 258673].20 139L 1.50 tO tD o, I (~) I CURia 2.00/200 800.00 4.79 900.00 6.73 1000.00 8.70 1100.00 10.68 1200.00 12.67 1300.00 L4.66 1~00.00 L6.65 ~21.49 999.58 667.58 6.63 1..02 2L6.67 899.07 767.07 16.t6 8.85 214.01 998.[6 866.16 29.16 19.83 212.]3 1096.73 964.73 45.59 33.93 211.17 1194.65 1062.65 65.45 5L.L4 16.09 W 331973.63 2586728.59 143L 2.00 22.36 W 331967.25 2586720.05 tZb 2.00 30.09 ~ 33[959.36 2586709.99 91, 2.00 39.27 ~ 331949.97 2586696.0] ?L 2.00 49.91 fl 331939.09 2586678.97 6L 2.00 210.32 1.29/.82 l[~9.82 88.70 71.45 S 61.97 H 33L926.74 2586658.85 51, 2.00 209.6? 1388.£1. 1256.11 1.[5.32 9{.82 S 75.45 W 33L9[2.92 2586635.67 5b 2.00 RC]U-B~ (P05) 05 Feb t998 Page 2 £DBNTIP£CATION PROPOS~fl i~L~ P~OPIL~ NEA$ORBD INCLN DIR~CTfON VHRT]C.~E-flBeTH~ SBCTION ROOILDII~THS-PROI4 ALASKA Zone 4 TOOL Ob/ L$O0.00 LS.G4 209.L6 ~483.40 335~.40 345.28 L2~.22 S 90.~3 ~ ~3~897.06 2~86602.49 4~ 2.00 1600.00 20.64 208.74 157~.57 /4JS.57 398.54 L50.64 8 106.59 ~ 331880.9~ 2586580.31 4L 2.00 1700.00 22.63 208.39 £690.52 £538.52 21~.05 ~83.02 S 324.22 X 33~862.88 2586548.19 4L 2.00 1000.00 24.63 208.~0 L762.13 1630.]3 254.79 218.3~ S 143.18 ~ 33LO43.4L 2586513.[~ 3L 2.00 t~ao.g0 26.63 207.84 18S2.29 1720.29 297.69 25~.54 $ 163.46 ~ 33L822.58 2586475.26 35 2.00 BkID 2.00/100 20" CA~INO EOIbiT CURVH 2.00/t00 2000.00 28.63 207.63 3940.8~ 1808.88 343.70 297.58 $ 185.04 H 333800.4L 2586434.53 ]L 2.00 2067.70 2~.98 207.49 L999.99 L867.99 376.63 326.99 S 200.39 N 331984.64 2586405.35 ~8 2.00 2069.79 29.98 207.49 2000.00 L868.00 376.63 326.99 S 200.39 fl 33L784.63 2586105.35 H~ 0.00 2L6~.?fl 29.98 207.49 2086.62 1954.61 426.24 371.3/ S 223.45 R 331760.93 2586361.37 3L 0.00 22OO.00 30.62 207.43 2114.43 1982.43 4J2.38 385.94 S 230.95 ~ 331~53.23 2586349.05 3L 2.00 2300.OO 32.62 20~.26 2/99.58 2067.58 494.45 432.31 S 255.0~ ~ 33[928.47 2586300.84 2L 2.00 2400.00 34.62 207.11 2282.04 2150.84 $49.~ 481.56 $ 280.33 19 331702.~V 2586251.97 2L 2.00 2500.00 36.62 206.97 2364.13 2232.L3 607.32 533.43 S 306.80 ~ 331675.25 2586200.¢9 2L 2.00 2600.00 38.52 206.85 2443.34 2321.34 667.99 S87.85 ~ 334.43 W 33]646.84 2586L46.43 2L 2.00 2700.00 40,6L 206.73 2520,39 2388.37 731.39 644.77 S 363.13 W 33L637.28 258608~.~8 2b 2.00 ~ 2.00/100 CURV~ ~3-3/8" CASINO 2800~00 42.63 206.63 2595.13 2463.L3 797.42 704.11 g 392.98 H 331586.61 25860~].09 2L 2.00 2900.00 44.61 206.53 2667.53 2535.53 866.03 765.79 $ 423.84 ~ 33]554.86 2585969.86 2L 2.00 3000.00 46.6L 206.44 2~37.47 2605.4~ 937.1t 829.95 S 455.71 N 331522.08 2585906.37 2L 2.00 3069.19 47.99 206.38 2784.39 2652.39 989.71 895.30 6 478.32 fl 331498.80 2585861.17 HS 2.00 4437.40 4?.99 20&.38 3700.00 356B.O0 1999.29 L786.13 $ 930,0~ H ~31033.90 258495~.04 [iS 0.00 CURVE 2.00/100 4586.&L 47.99 206.38 3999.99 3669.99 2109.75 1885.59 $ 999.35 ~ 330983.23 2584858.3L 134L 0.00 4600.00 47.81 206.12 3808.83 3676.83 2L19.50 [894.37 S 983.69 ~ 330978.76 2584849.59 /34b 2.00 4700.00 46.~4 204.L4 3876.87 3744.87 2192.54 L960.~L S 1014.82 W 330948.69 2584~83.72 /~SL 2.00 4800.00 45.10 202.06 39~6.63 3814.63 2264.L2 2026.63 ~ L042.94 ~ 330917.60 25847L8.24 131L 2.00 BND 2.00/100 CURVg 4866.05 44.24 200.63 3993.60 3861.60 2310.56 2069.85 8 L059.84 ~ 330900.07 258~675.24 Hg 2.00 9-5/8" CAS rNO [:~]1~1' 13529.46 44.24 200.63 10200.00 10068.00 8354.99 7726.56 8 3189.82 )) 329688.49 2579050.37 H~ 0,00 TARGET SUNFISH 16714.86 44.24 200.63 124~2.00 32350.00 10577.44 9806.45 ~ 3992.9~ ~ 3278~5.32 2576982.L9 HS 0.00 SUN~£b-H ~D8 L6994.O4 44.24 200.63 ]2682.00 22550.00 10792.22 9988.74 8 4041.62 ~I 327804.05 2576800.93 1~ O.00 (Rnadri[t (0)96 ~ICI~P5 3.20 5:02 ~'.J p) NCIU-B3 {?05) 0S Feb L998 eacje 3 eROPO~BD HSb~ PROFITS STA?~ON NWd%St.IR~D INCLN DIRECTIO~ VBRT£CA.f~-DEP?HS SBCT£OH IDBNTIF[CA?~O~ DEP?It ~¢G~E AZtMUTI4 TV~ SUB-~BA OHPART TARGET Il FORt,AND 174L2.SO 44.24 200.63 129~2.00 12850.00 L1064.39 N PO~.I~qD~A~D~ 1~705.94 44.24 200.63 1-3L92.00 13060.00 IL268.gL TD/~" hlN~R PT ]7856.67 44.24 200.~3 ~3299.99 13L6?.99 11-374.08 ALASK~ Zone 4 ~OOL DL/ X Y PACE k00 327697.15 2S76529.04 HS 0.00 327622.~2 2576~3~.71 HS 0.00 327583.B4 2576240.~5 0.00 (AnadriLi (e]98 NC£U~3PS 3.2C $.-02 ~4 p) - PHILLIPS PETROLEUM COMPANY ,,~mmmmm MarKer IOentification ND N/S E/W cl cu~v~ ,.oo/:oo ~oo ~ ~ ~ O] CURVE ~.50/100 SO0 ~ N E) CURVE 2.00/200 700 4 N It w F] CURVE 2.00/100 gOO 9 S 22 W G) ENO 2.00/100 CURVE 2068 327 S 200 w HJ 20' CASING POINT 2068 327 S 200 N I) CURVE 2.00/100 2~68 371S 223 w J) END 2.00/100 CURVE 3069 875 S 478 W K) 13-3/8' CASING POIN? 4437 3785 S 930 W L) CURVE 2.00/100 4587 ~886 S g79 W M) ENO 2,00/100 CURVE 4856 2070 S I060 W N) 9-5/8' C~S[NG POINT O) T&~GET SUNFISH P) TARGET N FORLAND NCZU-B3 (PO5) PLAN VIEW CLOSURE ..... : ~1377 feet at Azimuth 20 DECLINATION.: +22.]25 (E) SCALE ....... : ~ ~nch = JSO0 feet DRAWN ....... : 05 Feb ~998 !3529 772? s 3~o. ,4nad['i]] Schlu~be/'ge/" t6715 9806 S 3973 W ~ ~7413 10262 S 4145 W :~ 1800 ,900 0 900 ]800 <- WEST' E~ST -> (~1 ~ NCIUB3~5 3.26 ~ o~ pw Pi .96 -1 2700 3600 4500 5400 , FEB-~6-!998 11:29 9~37 3...44 2158 97:< F='. 85 PHILLIPS PETROLEUM COMPANY NCIU-B3 (PO5} VERTICAL SECTION VIEW Section at: 200.63 Tvo Scale.' 1 inc~ : 1800 feet __I [Dr'a~n ..... : 05 Fei} ~998 I nsdri]] Schlumberger ~,: )- , ~arker I~entiFication MO BKB SECTN AJ KB 0 0 0 O.O~ ~ B) KOP/CUAVE O. 75/100 400 ~00 -3 Cl CURVE ~.oo/100 500 500 -3 ~.3~ >- . , O} CUAVE 1.50/~00 800 600 -2. ~.7~ El Curve ~.00/~00 700 700 ~ F) CURVE 2.00/~00 gO0 8gB ~8 6.7~ ~ G) ENO 2.0~/100 CURVE 20G8 2000 3~? 2g,g~ } - K ~ HJ 20' CASING POINT 2068 2000 377 ] 'M~ I) CUAvE 2.00/100 2168 2087 4~6 29.~q J} ENO 2.00/~00 CURVE ~06~ 278~ ~Sa l-- ~ K} 13-3/8' CASING POINT ~57 ~700 ~B~ 47.~E L~ CURVE 2.00/1oo 4587 3800 2~10 47.9~ ~] END 2.00/100 CURVE 4866 399~ 23t~ 4a.2~ I-- ~ N] 9-5/8' C~SING POINT 13529 10200 8355 44.24 O) TARGET SUNFISH 16715 ~a~aa 10577 PI TARGET N FO~LAND t7413 12982 11064 ~.2~ O) TD/7" LINE~ PT t7B57 13300 ~1374 4~. ~-- _ .... ', Sun f 0 §00 1800 2700 3600 4500 5400 6300 7200 8:~00 9000 9900 Section Departure ,,, @407, J 30,, Dr~ve.~iiiiii! iiili iiL ~, PROPOSED CASING & CEM[.. t'ING DIAGRAM 20" ,.,... !::i::?: ::i::?: i:i:i ii!iiii ~ .. BPV (Make, Type, OD) ABB Vetco-Gray RKB-THF: @1206' MD ii!iilI [!::!!!:: Tb~.H~lr.(Make,Type) ABB Vetco-Gray RKB-BHF: Annulus Fluid: RKB-MSL · 132.00 iii TOC' Water Dept 132.00 i!iiiii[iiiTOC@4300' ii COl Top I Bottom I WT [GradelConn. I Burst I Collapse I Tension :::::: ::::: 13-3/8" ili!iii !iiiii': Structural Casing: Drive Pipe @ 4587' MD ~iii!i 30" I 5o I 407 I I I I I I ii!ili : Conductor Casing: CooklnletSand~!i i 20"I 50 I 1206 MD /1200 TVD 1133.0ppfI K-55 Iremiul 2860 I 1410 I 1700 ilili! Surface Casing: Upper Beluga ?iii!i iii 13-3/8"I 50 I 4587 MD/3800 TVDintermediate 172'00 PPflCasing:L-80 I BT&C I 4730 ) 2520I 761 iii!~iii 9-5/8"I 50 113529MDI10200TVDI53.5ppflP-1101BT&CI 8710 I 7500 I 1159 iii Production Liner =:::?:i 7" I13230MD/10000TVD I17857MD/13300TVDI32.0ppfIP-1101BT&Cl 8160I 8110 I 528 ill Production Liner (Alternate) Lower Beluga ?:i::i i?:::i 3-1/2"I13230MD/10000TVD 117857 MD I13300 TVD 112.95ppfl P-11oI PH-6I 20630 I 17940 I 365 ~i~ CEMENTING PROGRAM ::::: i i Conductor Cement w/550 sxs H'liburton Premium Cement w/3% ~el +0.25% CFR-3 + 1.0% CaCI2 Followed wi 625 sxs H'burton Premium + 2.0% CaCI2 + 0.1% CFR-3. i Circulate cement to surface. iiiii!ii! Surface Cement w/1050 sxs H'burton Premium Cement w/30/0 ~lel + 0.25% CFR-3 + 1.0°/o CaCI2 ::!::i[ !ii::! Followed w/605 sxs H'burton Premium + 2.0% CaCI2 + 0.1% CFR-3. i iiiiii Circulate cement to surface. i : ::::: Intermediate Cmt w/1650 sxs H'burton Premium Cmt wi 0.20% CFR-3 + 3% gel +0.1 iiili Followed w/230 sxs H'burton Premium Cmt 0.20% CFR-3 + 0.10 ~]als/sx Haled 344L ::::::::::i:: TOC ~ 4587' MD iiilil : Production Cement w/685 sxs H'burton Premium + 0.2% CFR-3 + 0.15 gal/ax Haled 344L + 0.25% HR-5 ii i TOC ~ 12930' MD i!i!!! Production Cement w/1635 sxs H'burton Premium + 0.2% CFR-3 + 0.15 gal/sx Haled 344L + 0.25% HR-5 i:i:i: iiiili 3-1/2" (Alt) TOC (~ 12930' MD :::::: !::!::!:: :::::: :::::: 9-5/8" :::::: ::::: @ 13529' MD 1:::: :::::: Sunfish Sands :::::: ::::: ::::: i:!:i: North Forlands Sa~ iii:::::: iilii TD @,:!:!:ii!i!ii NOTE: Depths measured from KB 17817' MD !i[i::::i PBTD: 17857' MD TVD: 13300' 7' 617857' MD Well: North Cook Inlet Unit "B" No. 3 13300' TVD Location: Tyonek Platform Cook Inlet~ Alaska Field: North Cook Inlet I Date: 03/13/98 tef/jcs Tyonek Deep Proposed Wellbore Schematic 3700' TVD (4437' MD) ::::::::::::::::::::::: .:.:.:.:.:.:.:.;.:.:.:. ::::::::::::::::::::::: ::::::::::::::::::::::: ,..................... :::::::::::::::::::::: Iii':':':':':':':': Beluga Sands 4482' TVD (5565' MD) Tyonek'C'Sand 11025'TVD (14681' MD) Sunfish Sands 12482'TVD (16714' MD) North Forelands Sands 12982'TVD (17413'MD) 20"csg@1200"l'VD (1206' MD) TOC 9 5/8" @ 3608' TVD (4300' MD 13-3/8" csg @ 3800' TVD (4587' MD) tOl 7" @ 10000' TVD (13230' MD) 9-5/8" csg @ 10200,' TVD (13529' MD) 7" liner @ 13300' TVD (17857' MD) CASING DEPTH SETTING VARIANCE REQUEST Phillips Petroleum Company requests a variance to the required setting depth of the conductor casing as specified in 20 AAC 25.030 (c) (2). The planned casing is 20" 133 lb/ft K-55. The intended setting depth is 1200' TVD (1206' MD) which is 1068' below mud line. Phillips is requesting this variance in the conductor setting depth in order to permit optimization of the hole/casing program for reaching the objectives of the well. Arco Alaska conducted extensive shallow hazards surveys over the area in conjunction with the Arco Sunfish No. 1 and the Arco- Phillips North Forelands State No. 1. These surveys did not identify any hazards to a drilling program from the Tyonek platform. There have been no indications of anomalies above 3000' BML in the wells drilled from the platform, the Arco Sunfish No. 1 or' the Arco-Phillips North Foreland St No. 1. The mud weights used in this interval on the recent wells have typically been below 9.0 ppg. The mud weight has been dictated by drilled solids rather than additions of barite. There was no indication of flow in any of the wells through this interval. Mud flow into and out of the well will be monitored by two independent systems, the PVT system installed on the rig and the mudloggers. The diverter system to be utilized in drilling to the 20" casing point is described elsewhere in this application. A 30" diverter with a 16" line will be used. The diverter line will extend in a straight run from the spool. The same 30" Diverter stack will be used for drilling below the 20" casing to the 13 3/8" casing point. The maximum pressure anticipated under diversion mode would be 200-250 psi. Flowline Bell Nipple Fill-up Line 30" 500 psi Annular Diverter 30" Drilling Spool 30" Riser Spool 16" Adapter Spool 16" Hydraulic Valve Opens Automatically when Annular Diverter Closes 30" Structural Pipe 28" x 30" Swage 28" Structural Pipe 30 "Adapter.Flange DSR Rentals 30 "Adapter Spool Vetco-Gray 30" ALT-2 Squnch Joint Connector Vetco.Gray 21" Overall 4" Valve for cement returns FIGURE I 30" WELLHEAD DIVERTER SYSTEM Use while drilling below 30" Structural and and 20" Conductor Casings prd / February 27~ 1998 PHILLIPS PETROLEUM COMPANY North Cook Inlet Unit "B" No. 3 Flowline Fill-up Line 13 518" 5M Annular Preventer Kill Line I ..... Adapter Flange 13-5/8" 10M x 11" 10M Tubing Head 13-5/8" 5M x 11" 10M Casing Spool 2-1/4" 2M x 13-518" 5M 20" Mandrel Hanger wl21-114" Flanged Ring 28" x 30" Swage 28" Structural Pipe 13 5/8" 10M BOP and Riser System Use while Drilling below 13-318" casing 13 5/8" 10M Variable Bore Pipe Rams 13 5/8" 10M Blind Rams Drilling Spool Gate Valve HCR Valve Choke Line 13 5/8" 10M Pipe Rams 13 5/8" 10M Flange 13 5/8" 10M Flange 13 5/8" 10M Riser 13 5/8" 10M Flange 13 518" 10M Flange 11" 10M Flange 11" 10M Flange 13 5/8" 5M Flange 13 5/8" 5M Flange 21 1/4" 2M Flange I Vetco-Gray ALT-2 Connector 20" Casing 13 3~8" Casing PHILLIPS PETROLEUM COMPANY North Cook Inlet Unit "B" No. 3 prd / March 1 1998 DRILLING FLUID PROGRAM Depth TVD 300'-1,200' (1206' MD) I Weight PPG 8.6-9.0 Visc. 50 - 100 FL 10-20 IMud Type Water Base Use pre-hydrated bentonite and extender flocculated in inlet water. Use all solids control equipment, keeping LGS below 6 % if possible. Sweep hole as needed with 50 bbl pills made up of 25 ppb gel and 1/2 ppb caustic in fresh water. Treat system with Drispac if seepage problems occur. Maximize pump rates to provide increased annular velocity. * NOTE Have funnel viscosity 50 - 70 sec/qt while drilling through gravel and when running casing. Depth TVD Weight PPG Visc. PH PV YP FL Mud Type Continue use of conductor mud system. Use fresh water for make-up mud. Continue use of all solids control equipment, sweeping hole as needed with 50 bbl pills. Continue the PAC treatments. Use Kwik-Seal and BaroFibre for any losses or excess seepage. Maximize pump rates to provide increased annular velocity. Depth TVD Weight PPG Oil/Wtr Ratio PV YP HPHT Fluid Mud Type Loss 3,800'-9,300' 9.5-10.0 70130 75~25 10-30 <20-25 3-5 Oil Base (12273' MD) Invermul 9,300-10,200 10.0-11.0 80~20 25-35 15-20 3 - 5 Oil-Base (13529' MD) Invermul Drill out with 9.0 ppg mud. Use soltex for HTHP fluid loss control. Keep Iow gravity solids below 8 %. Increase mud weight as required below 9000', keeping a supply of Barofibre and Steelseal for potential seepage problems. It is very important to have flat gels, 10 for running pipe. Depth TVD Weight PPG Oil/Wtr Ratio PV YP HPHT Fluid Mud Type Loss 10,200'- 13,300' 11.0 - 15.0 80/20 85/15 35-40 15-20 3-6 Oil Base (13529-17857' MD) Invermul Continue program from previous section. Mud weight will need to be brought up to 13.0 - 14.0 after coring the Sunfish Sands. Non progressive gels important. THESE ARE APPROX RHEOLOGICAL VALUES, and WILL VARY DEPENDING ON OWR & TYPE OF SUSP AGENTS. NORTH COOK INLET UNIT "B" No. 3 MUD WEIGHT / CASING POINT / PRESSURE PLOT (TVD) Depth (I'VD) ~PROPOSED ~NCIU B 1 ~ ~Series50:LEAK-OFFTEST ~ ~ ~ 'A'NCIU B 2 ~S'Fish 2 ,~S'Fish 3 PRESSURE ANALYSIS Pore pressure predictions have been made based on the offset well information from other wells drilled in the area and the seismic data. The most important offset wells used in this analysis are the production wells on the platform for the shallow horizons are the Arco Sunfish No. 1, Arco-Phillips North Forelands State No. 1, and the Phillips- Arco Sunfish No's. 2 and 3 wells, and the recently drilled NCIU "B" No's 1 and 2. ,.o, The interval above 7,800' TVD, + 10,179' MD will be the Cook Inlet and Beluga sands that are produced at the platform. The pressures in these sands have declined to a 5 - 6 ppg equivalent mud weight. Based on the results from recently drilled wells and the workovers on the North Cook Inlet Unit Wells A-1 thru the A-13, lost circulation is not expected to be a problem despite the Iow reservoir pressures. Due to the lenticular nature of the Beluga formation, there is the possibility of encountering a Beluga sand at virgin conditions. Virgin pressure in the Beluga interval was 8.5 - 9.5 ppg. The geologic interpretation for the interval below 7800' TVD is that the formations and pressures should be similar to those encountered in the Arco Sunfish No. 1 and the PPCo. NCIU "B" No.1 sidetrack. The Middle Ground Shoal section which is located in the interval between 7800' TVD and the proposed 9 5/8" casing point at 10,200' TVD, 13,529' MD is essentially normally pressured. A pressure transition begins below this depth. The 10,700' Sand and the Tyonek C Sand are anticipated to require mud weights in the 10.5 to 11.5 ppg range (actual mud weight requirements will be dictated by the coal seams throughout this interval). A further pressure transition occurs from slightly below the Sunfish Sands at _+ 12,000' TVD, _+ 16,042' MD,. Pore pressure will increase to about 13.2 ppg during this transition. This abnormal pressure trend is expected to continue to TD. Actual mud weights could be as high as 14.5 ppg. ANTICIPATED SURFACE PRESSURE CALCULATIONS The following presents the information used in the calculation of maximum potential surface pressure for the various hole sections. Casing Setting Depth Rationale 30" 175' BML, 407' RKB Conductor pile, driven when platform was installed in 1968. 20" 1200' TVD, 1206' MD This string of casing will top set in the top hole gravel section. It will provide a good anchor for the BOPE and provides an adequate fracture gradient for drilling to the 13 3/8" casing point. The diverter system will be used for this section of hole. 13-3/8,' 3800' TVD, 4587' MD Surface casing will be set across the disposal zone at 3260'-3370' and across the Upper Cook Inlet Stray, "A" and "B" at 3560'-3780'. The diverter system will be used for this section of hole. 9-5/8" 10200' TVD, 13529' MD Intermediate casing will provide an adequate fracture gradient to drill to total depth. 7" 13300' TVD, 17857' MD Production liner to isolate Sunfish and North Forelands sands for potential testing. Casing Setting Fracture Pore Pressure Maximum Maximum Size Depth Gradient Gradient That Downhole Pressure Potential Surface (ppg) May Be That May Be Pressure Drilling Encountered Encountered Below (psi) (ppg) (psi) 30" 175' BML, 10 8.7 543 200 PSI 407' RKB (Flow Diverted) 20" 1200' TVD, 12.5 9.0 1778 200 PSI 1206' MD (Flow Diverted) 13 3/8" 3800' TVD, 14.5 12.5 6630 3371 4587' MD 9 5/8" 10200' TVD, 17.0 14.5 9682 4568 13529' MD PROCEDURE FOR DETERMINING M~XIMUM DOWNHOLE PRESSURE AND M~XIMUM POTENTIAL SURFACE PRESSURE Maximum Downhole Pressure is determined from the pore pressure predictions of the interval to be drilled below the subject casing. The pore pressure predictions were made from offset well data and the seismic data. The maximum potential surface pressure is determined to be the lesser of the fracture pressure of the formation at the subject casing shoe less a fluid gradient to surface or the bottomhole pressure of the intervals to be drilled less the gradient of the fluid produced from the formation. 1. Drilling Below 30" Conductor Pile: Maximum Bottomhole Pressure (BHP): BHP = PP x 0.052 x D~ BHP = 8.7 x 0.052 x 1200 = 543 psi Maximum potential surface pressure is based on the frac pressure at the shoe less a gas column to surface. At this shallow depth the gas gradient is about 0.015 psi/ft, and the frac gradient is estimated to be 10 ppg.~ MPSP = ((FG x 0.052) - GG)Dcs MPSP = ((10 x 0.052) - 0.015)407 = 206 psi 2. Drilling Below 20" Conductor Casing: BHP = PP x 0.052 x D~ BHP = 9.0 x 0.052 x 3800 = 1778 psi This interval includes the shale and non-productive sand sequences above the Cook Inlet Sands, the Upper Cook Inlet Stray, "A" and "B"sands. Pore p~essures are less than 9.0 lb/gal. The fracture gradient below the 20" shoe is approximately 12.5 lb/gal equivaient. Maximum Potential Surface Pressure is determined based on the pressure that would result if 50% of the mud was displaced by formation fluid, which in this interval could be gas, oil, or water. The maximum pressure is based on the assumption that the formation fluid is gas with a resulting formation fluid gradient of 0.015 psi/ft. The mud weight will be at least 0.5 ppg higher than the pore pressure gradient. The maximum shut-in pressure is: MPSP = BHP - (MW x 0.052)(0.5 x Ddl - (FFG) (0.5 x MPSP = 1778 - (9.0 x 0.052)(0.5 x 3800) - (0.015) (0.5 x 3800) = 860 psi. However, with the 30" diverter, the well will never be shut in. The maximum pressure will be 200-250 psi through the diverter. 3. Drilling Below 13 3/8" Surface Casing' BHP = PP x 0.052 x Dd BHP = 12.5 x 0.052 x 10200 = 6630 psi Maximum Potential Surface Pressure is determined based on the pressure that would result from BHP less a gas gradient back to surface. The mud weight will be at least 0.5 ppg higher than the pore pressure gradient. MPSP = BHP - (MW x 0.052)(0.5 x D~I - (FFG) (0.5 x Dd/ MPSP = 6630 - (12 x 0.052) (0.5 x 10200) - (0.015) (0.5 x 10200) = 3371 psi 4. Drilling Below 9 5/8" Intermediate' BHP = PP x 0.052 x Dd BHP = 14.0 x 0.052 x 13300 = 9682 psi Maximum Potential Surface Pressure is determined based on the pressure that would result from BHP less a gas gradient back to surface. The mud weight will be at least 0.5 ppg higher than the pore pressure gradient. MPSP = BHP - (MW x 0.052)(0.5 x D~i - (FFG) (0.5 x D~/ MPSP = 9682 - (14.5 x 0.052)(0.5 x 13300) - (0.015) (0.5 x i3300) = 4568 psi. SUCTION PI~ MUD CLEANER PIT 80 BBL DF. SAIVDF. R PIT 80 88L 105 TRAP !11 ~ I 1 iii lql CENTRIFUGE POW~'R UNITS CHARGE PUMP PUl, fP ~t i 'I' CENTRIFUGE PUMP~ UNOCAL RIG 428 MUD SYSTEM LAYOUT "~~~--~-~ FUTURE CUTTING~ CONVEYOR ~_ ~ . ~ . z,,,. _,,¥ _ - . ~- . 255 BBL 255 BBL 90 BBL VOL UME//COMPLETIOAIVOLUME PIT SUCTION PIT .~ PIT ~--.. 'I 'i I _ , .. I PHILLIPS' TYONEK PLATFORM , ( MUD SYSTEM LAYOUT COSTS ($ 0 0 L~ 0 © Z 0 Z 0 ~o 0 ~ LO Hid ~G 0~½ QSV}~Pg PHILLIPS PETROLEUM COMPANY NORTH AMERICA E & P DRILLING OPERATIONS MAR 2 0 1998 aska 0il & GasCons. Commissio An meSe WELL: APl NO. FIELD: LOCATION: WORKING INTEREST: AFE: BUDGET ITEM: GROSS AUTHORIZATION: OBJECTIVE: North Cook Inlet Unit "B" No. 3 North Cook Inlet Field Surface: 4,029' FSL & 4,056 FEL Leg No. 1; Slot No. 2 BHL : 4,036' FSL & 3,282' FEL Phillips Petroleum Co: P-V140 2B $ 15,488,000 COUNTY, STATE: NCIU Alaska Permit No. AREA: Kenai, Alaska Sec. 6-T 11 N-R09W Sec. 13-T 11N-R10W 100.000000 % Drill and Complete a 17,857' MD (13,300' TVD) Development Well to the Sunfish and North Forelands Sands. ENGINEER , DRILLING ENGR.DIRECTOR DRILLING SUPERINTENDENT DRILLING MANAGER DATE DATE DATE DISTRIBUTION: J. W. KONST N. P. OMSBERG (R) CENTRAL FILES W. L. CARRICO DEVELOPMENT SUPERVISOR (2) J. R. JACKSON (R) L.D. AIRINGTON M. P. GATES W. B. VIA J.M. JOHNSON (2) POOL ARTIC ALASKA J. W. SPENCER P. R. DEAN (ORIGINAL) ORIGINAL(X)REVISION( ) TIGHT HOLE: YES(X) NO( ) DRILLING PROGRAM SUMMARY Well Name: North Cook Inlet Unit B No. 3 Field: North Cook Inlet Unit AFE No. P-V140 Drill & Equip to Flow Costs: Surface Location: 4,029' FSL & 4,056' FEL Sec. 6-T 11N-R09W Bottom Hole Loc. 4,036' FSL & 3,282' FEL Sec. 13-T 1 1N-R10W Depth: 17,857' MD 13,300' TVD AFE Days: 123 Rig: Unocal Rig 428 with Pool Attic Alaska manpower Type: 2B $15,488,000 Leg 1; Slot2 OBJECTIVE- Drill and complete a 17,857' MD (13,300' TVD) development well to the Sunfish and North Forelands Sands. CASING PROGRAM: size Depth Wt Ib/ft Grade Conn Burst Collapse Tension PSI test MD (TVD) 30" 407' Drive Pipe 20" 1206' (1200') 133 X-56 Premium 2860 1410 1700 13 3/8" 4587' (3800') 72 L-80 BT&C 4730 2520 906 3800 9 5/8" 13529' (10200') 53.50 P-110 BT&C 8710 7500 1159 5000 7" Liner 17857' (13300') 32 P-110 BT&C 9960 10170 688 5000 3-1/2" (Alt) 17857' (13300') 12.95 P-110 PH6 14240 17470 232 8000 Sec. I Sec. II Sec. III Sec. N PROCEDURE SUMMARY . 2. 3. 4. 5. 6. 7. 8. . 10. 11. 12. 13. 14. 15. 16. MIRU Unocal Rig No. 428 over Leg No. 1, Slot No. 2. Install riser and 30" diverter. Function test diverter. Install PVT equip. Drill a 24" directional conductor hole to 1206', following directional plan. Set 20" cond. csg, cmnt to surface, displ w/mud. Do a top job if necessary. Drill out 20" shoe. Drill a 16" hole with directional assembly to 4587' MD. Run 13-3/8" casing. Cement to surface. Top out if necessary. Release diverter. Install packoff and test. NU and test BOPs. Drill out 13-3/8" shoe with rotary assembly. Perform FIT to 13.0 ppg EMW. Drill 12 1/4" hole to 10,200' TVD (13,529' MD) using Oil Base Mud. Circulate and condition hole for logs. Log well as per Geological Prognosis. Run 9-5/8 "casing and hang off in wellhead. Cement 9-5/8 "csg. Install packoff and test. Test BOPs. Install wear bushing. Drill out 9-5/8" casing shoe and perform FIT test to 16 ppg EMW. Drill 8 1/2" hole to 13,300' TVD (17,857' MD), holding angle and direction. Circulate and condition hole for logs. Log hole as per Geological Prognosis. Run and cement 7" production liner (or 3 1/2" production casing ( 3 1/2" monobore tubing )). Clean out production liner to PBTD. Completion/testing program will be planned based upon log evaluation. North Cook Inlet Unit NO. 3 TOTAL TOTAL TOTAL Phase Summary of Operations 05C1 DR Drill Conductor 05Cl RC Run & Cem't Cond. 20SFDR Drill Surface 20SFEV Evaluate Surface 20SFRC Run & Cem't Surface 3011 DR Drill Int'mdte 3011EV Log & Eval Int'mdte 30SFRC Run & Cem't Int Csg. 50PRDR Drill Pr'tin Hole 50PREV Core Pr'dn Hole 50PREV Log & Eval Pr'dn Hole 50PRRC Run & Cem't Pr'dn Csg. 60ABNT Abandonment 80CMPL Completion ALLOCATION (BDH) ALLOCATION (Cased Hole) ALLOCATION (Cased Hole) "Stretch" Days Target Days AFE Days 3.00 3.00 3.00 0.00 3.00 38.00 3.00 3.00 30.00 0.00 3.00 4.00 4.00 30.00 90.00 93.00 123.00 Kenai Profit Center Manager ,, DRILLING PROSPECTUS Location Phillips Petroleum Company's Tyonek Platform located in the North Cook Inlet of Alaska. Drilling will be from Leg No. 1, slot No. 2 (See attached survey and schematics). Drilling Contract The drilling contract is a bare boat charter directly from Unocal for the use of the Rig No. 428. Pool Artic Alaska will provide the manpower and rig crews to install and operate the rig. Well Control Well control procedures will be in accordance with Phillips Petroleum Company's Well Control Manual and State of Alaska Oil and Gas Conservation Commission. Governmental Reporting Notify AOGCC (Blair Wondzell) @ (907) 279-1433 prior to moving in and rig up and prior to spud. Special Considerations This section is intended to clarify and discuss special drilling situations that may occur. Be alert for these potential problems and ready to implement the appropriate contingent actions. Oil Base Mud will be used to drill the interval from 4587' (3800' TVD) to TD. (Refer to Oil Based Mud Handling Procedures - attached in mud program). Extra precaution will be taken to insure that no runoff is allowed. Proximity to Other Wells A safety zone equal to 1.5% of the measured depth below mudline is to be maintained around the North Cook Inlet Unit "B" No. 3. If a producing well intersects this safety zone the producing well should be plugged with a wireline set plug below the potential point of intersection. The producing well will remain plugged and shut in until the risk of intersection has passed. The surface location is in the same wellroom as NCIU A-12, A-13, NCIU B-land B-2 ST. The A- 12 was drilled as a vertical well to about 7000' where it was kicked off to the Southeast. There is a very slight drift to the Southwest in the vertical section above its kick off point. Anadrill has reviewed NClU A-12 directional surveys and the proposed path of the NCIU "B" No. 3 will NOT close approach with the 1.5% MD window. The NCIU A-13 is vertical to 700' where it is kicked off to the West. The NCIU B-2 ST drifts to the North. The NCIU B No. 3 wellbore will close approach the NCIU A-6 at +/- 4000' MD. To avoid any risk of A-6 intersecting the safety zone DO NOT PERMIT NCIU "B" NO. 3 TO DRIFT EAST ABOVE THE 13-3/8" CASING POINT. Take frequent surveys with MWD in this interval. If it does show a tendency to drift to the East, nudge the well to the Southwest. ALL DIRECTIONAL SURVEY DATA POINTS SHOULD BE PLOTTED WHEN TAKEN TO ASSESS CLOSE APPROACH DISTANCES TO ALL OFFSET WELLS, 8. Shallow Gas 10, Shallow gas hazards can have catastrophic consequences. In view of these consequences, drilling of the 24" and '16" hole should be done cautiously. There is no reason to expect a shallow gas hazard at Nodh Cook Inlet based on the drilling history of the previous wells from the platform, and the shallow hazard surveys recently performed for the Arco drilling program. While there are no indications of shallow gas at NCIU, the consequences of a shallow gas event are such that a cautious approach is needed to insure such an event does not occur. A 24" hole will be drilled to the first casing point at 1200' TVD (1206' MD) and 16" hole will be drilled from the 20" casing shoe to 3800' TVD (4587' MD). Both hole sections should be control drilled to further reduce risks and to maintain directional control. The rig crews, mud loggers, and mud engineer should be closely monitoring the mud returns. Prior to spudding the well, review the diverter procedure found on page 7-3 of Phillips Well Control Manual. Verify that the personnel on board understand the shallow gas plan for this well, and that piping is in place to permit pumping seawater into the pits at high rates to facilitate a dynamic kill procedure. Advise the supply boats to stay clear of the dived, er line as much as possible. If a kick is indicated the driller should continue pumping, pick up the kelly above the rotary table, and check for flow. If the well is flowing, the recommended procedure for killing a shallow gas kick is a dynamic kill procedure. This procedure involves pumping kill mud into the well at the highest rate possible. If this does not kill the well pump in seawater at the highest rate possible while continuing to mix kill mud. While attempting the dynamic kill preparations should be made to evacuate the platform. If the well cannot be killed a decision will be made whether to continue with the kill procedure, attempt to deplete the gas by flowing through the diverter or to evacuate the platform. Unconsolidated Sands and Gravel The top section of the hole is unconsolidated sand and gravel. These sands and gravels have a tendency to slough. Good hole cleaning is the best way to handle this problem. Pump high viscosity sweeps at frequent intervals while drilling the 24" and 16" hole sections. Cook Inlet and Beluga Sands The 12 1/4" hole section will include the Cook Inlet and Beluga sands that are produced on the platform. These sands are very permeable and have a relatively Iow pore pressure, 5.5 - 7.0 ppg. The mud used in drilling this section will be at least 3 ppg overbalanced. This leads to a risk for lost circulation and for differential sticking. Lost circulation is not expected to be a serious problem in this interval. The results from drilling the previous Sunfish wells and NClU wells and the sequence of workovers have shown these sands can tolerate a large overbalance without losing circulation, however caution is advised. An adequate stockpile of lost circulation material should be maintained on the rig. A large mud overbalance with permeable sands in a deviated well results in a high risk of differential sticking. To minimize this risk, keep the pipe moving as much as possible, and use the minimum number of drill collars needed for directional control. The collars that are used should be well stabilized to minimize the potential contact area. Mud properties must be well maintained through this section. The fluid loss should be kept Iow. 12, Soltex should be used to assist with borehole stability and to act as a lubricant. Use the solids control equipment, including the centrifuge, to keep drilled solids as Iow as possible. Avoid the temptation to increase mud weight based on high background gas. The formation being drilled is gas saturated sand and coal. A significant volume of gas will be drilled up. This will result in high gas readings. Raising mud weight will not reduce this and will increase the risk of losing returns or getting differentially stuck. The Beluga sands are not continuous across the field, consequently there is the possibility of encountering a virgin Beluga sand. Virgin pressure in the Beluga was 8.5 - 9.5 ppg. A virgin stringer with a pore pressure of about 9.5 ppg was encountered in the Sunfish No. 2. Caution the drillers to be aware of this possibility and ready to react quickly in the event of a kick as the result of a virgin Beluga stringer. COAL SEAMS Stuck pipe due to coal beds has been a frequent occurrence in this and other fields in the Cook Inlet, mainly when using VVBM. Coal generally swells with WBM. These coals will be drilled throughout the well. The most difficult coals to drill are expected in the 12 1/4" hole section. The use of OBM and the use of the top drive should reduce the problems previously associated with coals. The coals may be fractured and have a tendency to cave into the well. A large chunk could result in mechanically sticking the drillstring. Mud weight and soltex have been used with some success to stabilize the coals. Raise mud weight as needed to control the coal seams. For OBM, gelsonite and/or Soltexshould be used to lower HP/HT to 4 cc or less. In the event the pipe does become stuck, spotting fluids have been successful in some cases in freeing the pipe where the mud was water based. The use of oil based mud should help in this regard. DIFFERENTIAL STICKING There are several sands in the 12 1/4" and 8 1/2" hole section that are expected to be normally pressured and permeable. If mud weight has been raised to stabilize the coal seams then these sands will present a risk for differential sticking. To minimize this keep the pipe moving as much as possible and minimize stabilized spiral HWDP and spiral DC's in OBM. Use lost circulation additives such as Barafiber or Steel Seal to reduce seepage losses and to minimize the risk of differential sticking. HIGH BACKGROUND GAS The formations that will be drilled are gas saturated coal, sand, and silt. This will result in unusually high background gas readings. Mud weight should not be increased to suppress the high background gas. PRESSURE ANALYSIS Pore pressure predictions have been made based on the offset well information from other wells ddlled in the area and the seismic data. The most important offset wells used in this analysis are the production wells on the platform for the shallow horizons are the Arco Sunfish No. 1, Arco- Phillips North Forelands State No. 1, and the Phillips-Arco Sunfish No's. 2 and 3 wells, and the recently drilled NCIU "B" No's 1 and 2. The interval above 7,800' TVD, +_ 10,179' MD will be the Cook Inlet and Beluga sands that are produced at the platform. The pressures in these sands have declined to a 5 - 6 ppg equivalent mud weight. Based on the results from recently drilled wells and the workovers on the North Cook Inlet Unit Wells A-1 thru the A-13, lost circulation is not expected to be a problem despite the Iow reservoir pressures. Due to the lenticular nature of the Beluga formation, there is the possibility of encountering a Beluga sand at virgin conditions. Virgin pressure in the Beluga interval was 8.5 - 9.5 ppg. The geologic interpretation for the interval below 7800' TVD is that the formations and pressures should be similar to those encountered in the Arco Sunfish No. I and the PPCo. NCIU "B" No. 1 Sidetrack. The Middle Ground Shoal section which is located in the interval between 7800' TVD and the proposed 9 5/8" casing point at 10,200' TVD, 13,529' MD is essentially normally pressured. A pressure transition begins below this depth. The 10,700' Sand and the Tyonek C Sand are anticipated to require mud weights in the 10.5 to 11.5 ppg range (actual mud weight requirements will be dictated by the coal seams throughout this interval). A further pressure transition occurs from slightly below the Sunfish Sands at + 12,000' TVD, + 16,042' MD,. Pore pressure will increase to about 13.2 ppg during this transition. This abnormal pressure trend is expected to continue to TD. Actual mud weights could be as high as 14.5 ppg. ANTICIPATED SURFACE PRESSURE CALCULATIONS The following presents the information used in the calculation of maximum potential surface pressure for the various hole sections. Casing Setting Depth Rationale 30" 175' BML, 407' RKB Conductor pile, driven when platform was installed in 1968. 20" 1200' TVD, 1206' MD This string of casing will top set in the top hole gravel section. It will provide a good anchor for the BOPE and provides an adequate fracture gradient for drilling to the 13 3/8" casing point. The diverter system will be used for this section of hole. 13-3/8" 3800' TVD, 4587' MD Surface casing will be set across the disposal zone at 3260'-3370' and across the Upper Cook Inlet Stray and the Upper Cook Inlet "A" and "B" at 3560'-3780'. The diverter system will be used for this section of hole. 9-518" 10200' TVD, 13529' MD Intermediate casing will provide an adequate fracture gradient to drill to total depth. 7" 13300' TVD, 17857' MD Production liner to isolate Sunfish and North Forelands sands for potential testing. ,, Casing Setting Depth .Fracture Pore Pressure Maximum Downhole Maximum Size Gradient Gradient That Pressure That May Potential Surface (ppg) May Be Be Encountered Pressure Drilling Encountered Below (psi) (ppg) (psi) 30" 175' BML, 10 8.7 543 250 PSI 407' RKB (Flow Diverted) 20" 1200' TVD, 12.5 9.0 1778 250 PSI 1206' MD (Flow Diverted) 13 3/8" 3800' TVD, 14.5 12.5 6630 3371 4587' MD 9 518" 10200' TVD, 17.0 14.5 9682 4568 13529' MD PROCEDURE FOR DETERMINING MAXIMUM DOWNHOLE PRESSURE AND MAXIMUM POTENTIAL SURFACE PRESSURE Maximum Downhole Pressure is determined from the pore pressure predictions of the interval to be drilled below the subject casing. The pore pressure predictions were made from offset well data and the seismic data. The maximum potential surface pressure is determined to be the lesser of the fracture pressure of the formation at the subject casing shoe less a fluid gradient to surface or the bottomhole pressure of the intervals to be drilled less the gradient of the fluid produced from the formation. 1. Drilling Below 30" Conductor Pile: Maximum Bottomhole Pressure (BHP): BHP = PP x 0.052 x Da BHP = 8.7 x 0.052 x 1200 = 543 psi Maximum potential surface pressure is based on the frac pressure at the shoe less a gas column to surface. At this shallow depth the gas gradient is about 0.015 psi/ft, and the frac gradient is estimated to be 10ppg. MPSP = ((FG x 0.052) - GG) Dcs MPSP = ((10 x 0.052) - 0.015) 407 --206 psi 2. Drilling Below 20" Conductor Casing: BHP = PP x 0.052 x Da BHP = 9.0 x 0.052 x 3800 =1778 psi This interval includes the shale and non-productive sand sequences above the Cook Inlet Sands, the Upper Cook Inlet Stray and the Upper Cook Inlet "A" and "B" sands. Pore pressures are less than 9.0 lb./gal. The fracture gradient below the 20" shoe is approximately 12.5 lb./gal equivalent. Maximum Potential Surface Pressure is determined based on the pressure that would result if 50% of the mud was displaced by formation fluid, which in this interval could be gas, oil, or water. The maximum pressure is based on the assumption that the formation fluid is gas with a resulting formation fluid gradient of 0.015 psi/ff. The mud weight will be at least 0.5 ppg higher than the pore pressure gradient. The maximum shut-in pressure is: MPSP = BHP - (MW x 0.052)(0.5 x Da)- (FFG)(0.5 x Da) MPSP = 1778 -(9.0 x 0.052)(0.5 x 3800) -(0.015)(0.5 x 3800) = 860 psi. However, with the 30" diverter, the well will never be shut in. The maximum pressure will be 200-250 psi through the diverter. 3. Drilling Below 13 3/8" Surface Casing: BHP = PP x 0.052 x Da BHP = 12.5 x 0.052 x 10200 =6630 psi Maximum Potential Surface Pressure is determined based on the pressure that would result from BHP less a gas gradient back to surface. The mud weight will be at least 0.5 ppg higher than the pore pressure gradient. . MPSP = BHP - (MW x 0.052)(0.5 XDd) - (FFG)(0.5 x Dd) MPSP = 6630 -(12 x 0.052)(0.5 x 10200) -(0.015)(0.5 x 10200) = 3371 psi Gas Gradiant Alternative BHP = 6630 psi Max MW = PP / 0. 052 / Dd 6630 / 0.052 / 10200 Max MW = 12.5 lb/gal Maximum Potential Surface Pressure is determined based on the pressure that would result from BHP less a gas gradient back to surface. The mud weight will be at least 0.5 ppg higher than the pore pressure gradient. MPSP = BHP - (gas gradient) (TVD) MPSP = 6630 - (0.15 psi/ft)(10200') = 5100 psi Drilling Below 9 5/8" Intermediate: BHP = PP x 0.052 x Dd BHP = 14.0 x 0.052 x 13300 =9682 psi Maximum Potential Surface Pressure is determined based on the pressure that would result from BHP less a gas gradient back to surface. The mud weight will be at least 0.5 ppg higher than the pore pressure gradient. MPSP = BHP - (MW x 0.052)(0.5 XDd)- (FFG)(0.5 x Dd) MPSP = 9682-(14.5 x 0.052)(0.5 x 13300)-(0.015)(0.5 x 13300) = 4568 psi. Gas Gradiant Alternative BHP = 9682 psi from DST of N. Forelands No. 1 Max MW = PP / 0.052 / Dd 9682 / 0.052 / 12932 Max MW = 14.0 lb/gal Maximum Potential Surface Pressure is determined based on the pressure that would result from BHP less a gas gradient back to surface. The mud weight will be at least 0.5 ppg higher than the pore pressure gradient. MPSP = BHP - (gas gradient)(TVD) MPSP = 9682 - (0.15 psi/ft)(12932') = 7687 psi CASING DEPTH SETTING VARIANCE REQUEST Phillips Petroleum Company requests a variance to the required setting depth of the conductor casing as specified in 20 AAC 25.030 (c)(2). The planned casing is 20" 133 Ib/ft K-55. The intended setting depth is 1200' TVD (1206' MD) which is 1068' below mud line. Phillips is requesting this variance in the conductor setting depth in order to permit optimization of the hole/casing program for reaching the objectives of the well. Arco Alaska conducted extensive shallow hazards surveys over the area in conjunction with the Arco Sunfish No. 1 and the Arco-Phillips North Forelands State No. 1. These surveys did not identify any hazards to a drilling program from the Tyonek platform. There have been no indications of anomalies above 3000' BML in the wells drilled from the platform, the Arco Sunfish No. 1 or the Arco-Phillips North Foreland St No. 1. The mud weights used in this interval on the recent wells have typically been below 9.0 ppg. The mud weight has been dictated by drilled solids rather than additions of barite. There was no indication of flow in any of the wells through this interval. Mud flow into and out of the well will be monitored by two independent systems, the PVT system installed on the rig and the mudloggers. The diverter system to be utilized in drilling to the 20" casing point is described elsewhere in this application. A 30" diverter with a 16" line will be used. The diverter line will extend in a straight run from the spool. This same 30" diverter stack will be used for drilling below the 20" casing to the 13 3/8" casing point. The maximum pressure anticipated under diversion mode would be 200-250 psi. DRILLING PROCEDURE SECTION I: 24" HOLE ( 20" CASING) - DEPTH 1206' MD-RKB (1200' TVD). A. GENERAL REMARKS 1. Intent- Drill a 24" hole to 1206' MD-RKB. The hole will be directional, with kick-off point just below the conductor. Plans are to begin nudging between the bottom of the conductor at 477' MD and 700'. After 700', build angle at 2'deg/100' until casing point at 1200 TVD. Set and cement 20" casing back to the surface. (A Top Job is required if the cement falls back). Notifythe AOGCC at (907) 279-1433 prior to spudding Litholo,q¥ and Anticipated Problems- The lithology is expected to be sand and shale. NOTE: Shale interval between sands at this depth is minimal. The top section of the hole is unconsolidated sand and gravel. These sands and gravels have a tendency to slough. Good hole cleaning is the best way to handle this problem. Pump high viscosity sweeps at frequent intervals while drilling above the 20" casing point. 3. Wellhead Proqram Weld 30" ALT-2 squnch joint onto existing conductor using the 28" x 30" swage adapter. Install riser to drilling deck. Install flange for 30" 500 psi diverter, diverter and then bell nipple riser to rig floor and mud system. Maintain clearance for 16" diverter line. Install 16" diverter line and function test annular and diverter valves. NOTE: Diverter lines are to be installed as straight as possible. Pump water through the diverter lines to insure they are clear. Shallow gas was not a problem in the previous wells, but must not be overlooked as a potential problem. 4. BOPE Test Pressures- Function test of diverter and valves. 5. Casinq Pressure Test & Leak-off Test- Not Required. 6. Directional Drilling Instructions- Follow directional drilling program. RIH with 24" mill to clean up burrs at 30" casing shoe. RIH w/24" bit, steerable motor and BHA, including MWD. Drill a 24" hole to kick off point at just below conductor shoe. With the steerable motor, the hole can be nudged in a south/southwesterly direction above the planned kick off point. Control drill to minimize risk of overloading hole with drilled solids. Make high vis sweeps as needed to clean hole. NOTE: BHA adjustments must be discussed with the Houston Office personnel. Note: The NCIU A-12 well.was drilled from a surface location 4' southeast of the planned NCIU "B" No. 3. This well is essentially vertical, with slight deviation south west. The Sunfish No. 3 was drilled from a surface location 10' east and 2' north of the NCIU "B" No. 3 and deviates to the north. The NCIU "A" No. 13 was drilled from a surface point 5' north and 3.5' east of NOIU "B" No. 3. There should be no proximity problems with any of the offset wells as long as the well does not deviate to the east. Since the kick-off point is shallow, the well will be nudged to the south/southwest. At kickoff point, begin sliding to kick well off per directional plan. Drill to 20" casing point at _+ 1200' TVD, + 1206' MD. This directional plan is based on a maximum build rate of 2°/100 fi.. Dog leg severity in excess of 5°/100 ff could cause both drillpipe fatigue and excessive torque and drag. To minimize the potential for these problems THE DOG LEG SEVERITY CAN NOT BE PERMITTED TO EXCEED 3°/100 FT. CONTROL DRILL WHILE SLIDING TO MINIMIZE THE TENDENCY OF THE BHA TO BUILD ANGLE FASTER THAN DESIRED. A gyro steering tool should be considered to permit the survey instrument to be located closer to the bit than a magnetic tool such as a MWD tool would permit. Report surveys every 30' through the build section. SPECIAL INSTRUCTIONS Zo Insure the following equipment is in place and fully operable prior to beginning drilling operations: ao Pit level monitor with audio and visual warning system. Mud return indicator. Gas detector with audio and visual warning system. Mud volume measuring device (trip tank, etc). Both mud systems are tied'together and shut down detectors are fully functional and operating. B. DRILLING DETAILS ( 24" HOLE TO 1206 MD-RKB) 1. Bottom Hole Assembly 24" Bit, Bit sub, 9 5/8" Steerable Motor set @ 0 degrees with 2.25 deg. Bent Sub. 17.5" Stab., MWD, orientation sub, 60' 9 1/2" Non-Mag collars, long tapered crossover, 30' 8" DC, 15 jts 6-5/8" HWDP, 8" Jars, 3 jts. 6-5/8" HWDP. Have backup BHA available consisting of 24" bit, 9-5/8" SPDM set @ 1.2 deg with 23.5" melon stab, 20" melon stab, UBHO sub, MWD. 2. Bits, WOB, RPM - 24" 1-1-4; or 1-1-5, 5- 25 M, 120-240 3. Hydraulics- 4. Mud Proqram- Maintain adequate circulation rate to clean hole and operate motor. Recommended Range: 800-1200 GPM Depth TVD Weight PPG Visc. PH PV YP FL Mud Type 300'-1200' 8.6 - 9.0 50 - 100 8.5-9.5* 10-15 20-40 10-20 Water (1206' MD) Base Use pre-hydrated bentonite and extender flocculated in inlet water. Use all solids control equipment, keeping LGS below 6 % if possible. Sweep hole as needed with 50 bbl pills made up of 25 ppb gel and 1/2 ppb caustic in fresh water. Treat system with Drispac if seepage problems occur. Maximize pump rates to provide increased annular velocity. NOTE: Have funnel viscosity 50 - 70 sec/qt while drilling through gravel and when running casing. 5. Survey Requirements and Deviation Restrictions A. MWD Surveys: MWD surveys every 30' drilled to 1200'. Run one survey at top of hole to confirm conductor isn't crooked. B. Deviation: Maximum 2 degrees per 100' from vertical through build section. 6. Sampling, Mud Lo_~in.~ & Electric Lo(~s- None Required C. CASING AND CEMENTING DETAILS ( 20" CASING) AT 1206' MD-RKB 1. Casing Specifications: (Top to Bottom) Opt fi-lb ft/I Depth - TVD Description Burst Coil Ten Drift 0'-1200' 20" 133 Ib./ft X-56 w/ 2860 1410 1700 4230 18.54 (0'-1206'MD) Franks Tencom conn. . Float Shoe Float Collar & Loc Centralizers Connection Lock Cementing Plugs Circ, Mix, Displace Rate: Weatherford Model 303 Sure Seal II (PDC drillable) Weatherford Model 371 Double Sure Seal with Model 154 stab-in stinger 1 jt. above shoe Weatherford Model ST-II Non-Weld: 1-7' above shoe;1 on FC;1 on 1st 10 joints, then 1 every 4th joint to surface Thread lock all connections on through top of Float Collar Top plug only (DP wiper plug) Maximum practical . Lead Slurry : Slurry Weight : Mix Water - Type : Pumping Time : Desired TOC : Compressive Strength : 420 sks. Halliburton Premium +3% gel + 0.25% CFR-3 + 2.0% CaCI2 12.0 PPG 14.33 gal/sk. - Fresh Water Surface . Tail Slurry : Slurry Weight : Slurry Yield : Mix Water - Type : Pumping Time : Compressive Strength : 626 sks. Halliburton Premium + 2.0% CaCI2 + 0.10% CFR-3 15.8 PPG 1.1 5 cu.ft/sk 5.0 gal/sk. - Fresh Water 3 - 4 hours 24 Hours - 2500 [)si. Total cement volume based on 100% excess lead slurry and 50% excess tail slurry in open hole. Tail volume slurry based on 500' of casing cemented. SPECIAL INSTRUCTIONS: A. Make wiper trip prior to running casing. Spot Hi-Vis pill prior to POOH. B. Run 20" conductor casing to 1206'. Make sure all casing is drifted to 17-1/2". Fill each joint with W'Ford filling tool while RIH. Make up landing joint above 20" mandrel hanger spaced out so casing is at a convenient height above rotary table when landed. Set down and land casing on landing ring. Install false rotary table. C. D. TIH with stinger for stab-in float collar on drillpipe. Stab into float collar. Break circulation, checking the top of the 20" casing to insure stinger is sealing into stab-in collar. Circulate and condition, reducing mud viscosity to minimum possible for cementing. Circulate until returns are clean, then cement with casing stationary. Displace cement with mud, then unsting from float collar, POOH one stand and clear drill pipe. POOH with drill pipe. WOC a minimum of 8 hours and until surface samples have set up. E, F, Go Verify top of cement is above the top connection on the 20" casing. If it is not, run 1" pipe into the 20" x28" annulus (cut slot in the 28" x30 A adapter) and perform top out cement job. Check slurry density with pressurized mud scales throughout the job. Catch samples of slurry and dry cement periodically while mixing. CEMENT TO BE USED MUST BE LAB TESTED PRIOR TO SENDING SAME TO THE LOCATION. Complete PPCO Casing and Cementing Report and send to the Houston Office. SECTION I1: 16" HOLE ( 13-3/8" CASING) - DEPTH 4587' MD-RKB. A. GENERAL REMARKS . Intent- Drill a 16" hole to 4587' MD-RKB. Log hole. Note: Shale interval between sands at this depth is minimal). Set and cement 13-3/8" casing back to the surface. Perform a top job with 1" tubing if necessary. 2. Litholo.qy and Anticipated Problems- The lithology is expected to be thick sand intervals and shale. 3. Wellhead Proqram- Back off 20" landing joint from 20" mandrel hanger. Disconnect diverter line and release ALT-2 connector. Raise diverter and riser assembly enough to install 20" mandrel packoff. Re-Install ALT-2 connector and diverter assembly and reconnect diverter line. Function test diverter and valves. 4. BOPE Test Pressures- Function test 30" diverter and valves. 5. Casing Pressure Test & Leak-off Test- Not Required. 6. Special Drillinq Instructions- B. DRILLING DETAILS (16" HOLE TO 4587' MD-RKB) 1. Bottom Hole Assembly 16" Bit, Bit sub, 9-5/8" Steerable Motor w/1.15 AKO, 16-1/4" sleeve stab., float 10 ft - 9-1/2" pony DC, 15-1/2" to 15-3/4" stab. ,MWD, orientation sub, 2-9 1/2" NMDC's, XO, 15 jts 6-5/8" HWDP, jars, 3 its 6-5/8" HWDP. 2. Bits, WOB, RPM- 1-1-4, 20-25M, 120-240 3. Hydraulics- Maintain adequate circulation rate to clean hole. Recommended Range: 800- 1200 GPM 4. Mud Proqram- Depth TVD Weight PPG Visc. PH PV YP FL Mud Type 1200'-3800' 8.8 - 9.2 40-50 8.5-9.5' 10-15 15-25 6-10 Water (1206'-4587' MD) Base Continue use of conductor mud system. Use fresh water for make-up mud. Continue use of all solids control equipment, sweeping hole as needed with 50 bbl pills. Continue the PAC treatments. Use Kwik-Seal and BaroFibre for any losses or excess seepage. Maximize pump rates to provide increased annular velocity. 5. Survey Requirements and Deviation Restrictions A. MWD Surveys: Continue MWD surveys every 30' drilled to 4587'. B. Deviation: Maximum 2 degrees per 100'. Hold angle to casing point. 6. SamDlina, Mud Lo,q.qin.q & Electric Lo,qs- None this interval. C. CASING AND CEMENTING DETAILS{ 13 3/8" CASING) AT 4587' MD-RKB 1. Casing Specifications: (Top to Bottom) I PPCo Pw Torque Depth Description Burst Coil Ten Opt ft-lb ft/I Drift 0 - 4587' MD 13 3/8" 72 L-80 4740 2520 1231K 4230 12.25755 BT&C 2. Float Shoe : Float Collar &Loc : Weatherford Model 323 (PDCdrillable) Weatherford Model 402 NT (PDC) ljt. above shoe 3. Landing Collar 4 Centralizers Not Applicable. 1-7' above shoe; 1 on FC; 1 every joint td200', then every ~d joint to surface. 5. Connection Lock Thread lock all connections through top of Float Collar. 6 Cementing Plugs Circ, Mix, Displace Rate Top plug only Maximum practical 7 Lead Slurry : Slurry Weight : Slurry Yield : Mix Water - Type : Pumping Time : Desired TOC : Compressive Strength : 1021 sks. Halliburton Premium +3% gel + 0.25% CFR-3 + 1.0% CaCI2 12.0 PPG 2.53 cu. ft/sk 15.11 gal/sk. - Fresh Water 3 - 4 hours Surface 12 Hours - Tail Slurry : Slurry Weight : Slurry Yield : Mix Water - Type : Pumping Time : Compressive Strength : 608 sks. Halliburton Premium + 0.20% CFR-3 15.8 PPG 1.15 cu.ft/sk 5.00 gal/sk. - Fresh Water 3 - 4 hours 24 Hours - 2500 psi. Total cement volume based on 50% excess in open hole. Tail volume slurry based on 1000' of casing cemented with 50 % excess. Actual volumes to be determined from caliper log. Use caliper plus 20% excess. SPECIAL INSTRUCTIONS A. Make wiper trip prior to running casing if hole conditions require same.. a. Run surface casing and install 13-3/8" landing hanger.. Position the casing with landing joint so that hanger is slightly above landing ring. Pump cement slurries per c below, then set down and land on landing ring when plug bumps. Co Establish circulation and circulate one casing volume. Cement with casing stationary. Displace cement with WBM. Bump plug with 500 psi over the final displacing pressure. If plug is not leaking, increase the pressure to 2000 psi and test casing for 30 minutes. Bleed pressure to 0 psi and check for backflow. D. Notify the AOGCC a minimum of 24 hours prior to the casing job. Also, contact the AOGCC if no cement is circulated to the surface so they may witness top job. E. Check slurry density with pressurized mud scales throughout the job. Catch samples of slurry Fo and dry cement periodically while mixing. CEMENT TO BE USED MUST BE LAB TESTED PRIOR TO SENDING SAME TO THE LOCATION. Complete PPCO Casing and Cementing Report and send to the Houston Office. Nipple down the Riser, diverter and diverter lines. All cuttings grinding, handling and transporting equipment should be functional at this time because OBM will be used from this point to TD. SECTION II1:12 114" HOLE ( 9 5/8" CASING) - DEPTH 10200' TVD (13529' MD) RKB or 11.0 ppg Equivalent Mud Weight GENERAL REMARKS Litholoqy and Anticipated Problems The lithology is expected to be massive sands, shales and abundant sloughing coal seams. This hole section will include the Cook Inlet and Beluga sands that are produced on the platform. These sands are very permeable and have a relatively Iow pore pressure, 5.5 - 7.0 ppg. The mud used in drilling this section will be at least 3 ppg overbalanced. This leads to a risk for lost circulation and for differential sticking. Lost circulation is not expected to be a serious problem in this interval. The results from drilling the Sunfish wells and the sequence ofworkovers have shown these sands can tolerate a large overbalance without losing circulation, however, caution is advised. An adequate stockpile of Barafibre and Steelseal lost circulation material should be maintained on the rig. A large mud overbalance with permeable sands in a deviated well results in a high risk of differential sticking. To minimize this risk keep the pipe moving as much as possible, and use the minimum number of drill collars needed for directional control. Mud properties must be well maintained through this section. The fluid loss should be kept Iow (HP/HT at less than 5 cc). Use the solids control equipment to keep drilled solids as Iow as possible. Avoid the temptation to increase mud Weight based on high background gas. The formation being drilled is gas saturated sand and coal. A significant volume of gas will be drilled up, which will result in high background readings. Raising mud weight will not reduce this and will increase the risk of losing returns or getting differentially stuck. The Beluga sands are not continuous across the field, consequently there is the possibility of encountering a virgin Beluga sand. Virgin pressure in the Beluga was 8.5 - 9.5 ppg. A virgin stringer with a pore pressure of about 9.5 ppg was encountered in the Sunfish No. 2. Caution the drillers to be aware of this possibility and ready to react quickly in the event of a kick as the result of a virgin Beluga stringer. Stuck pipe due to coal beds has been a frequent occurrence in the other wells and fields in the Cook Inlet. Coal beds will be drilled throughout the well, with the most difficult coals expected in the Tyonek portion of the 12 1/4" hole section. The coals in the inlet seem to flow into tl~ellbore shortly after they have been drilled. The coals may be fractured and have a tendency to cave into the well. A large chunk could result in mechanically sticking the drillstring. Mud weight and soltex (with water base systems) have been used with some success to stabilize the coals. Raise mud weight only as needed to control the coal seams. There are several sands in the 12-1/4" and 8-1/2" hole section that are expected to be normally pressured and permeable. If mud weight has been raised to stabilize the coal seams then these sands will present a risk for differential sticking. To minimize this, keep the pipe moving as much as possible. Efforts should be made to avoid directional corrections by sliding with a mud motor. Use lost circulation additives to reduce seepage losses and to minimize to differential sticking risk in these sands. SECTION II1: 1. Intent- . , , o 12 114" HOLE ( 9 5/8" CASING) - DEPTH 10200' TVD (13529' MD) RKB Drill a 12-1/4" hole to 13,529' MD-RKB (10,200' TVD) or 11.0 ppg, holding angle and direction as per directional plan to casing point. Log well as per geological prognosis, then set and cement 9 5/8" casing. Wellhead Pro.qram- Vetco-Gray 21%" 2M x 13 5/8" 5M Casing Spool (Section B) 13 5/8" 5M x 11" 10M Tubing Head (Section C). BOPE Requirements and Test Pressures 13 5/8" 10M BOPE is required. Test pressures are as follows: Initial Installation Weekly Rams: 8000 psi 5000 psi Annular: 3500 psi 2500 psi Casinq Pressure Test & Leak-off Test Pressure test 13 3/8" casing to 4000 psi. GIH with BHA. Drill the float equipment and 10' of new Contact Drilling formation. Perform a Leak-Off Test as per the PPCo. Well Control Manual. Superintendent if leak-off occurs before 13.0 ppg EMW. Special A. B. C. D, E. Drilling Instructions Change out water base mud system to oil base inverted emulsion system. Install a wear bushing before drilling to prevent wear in the casing head. Drill 13 3/8" shoe and float equipment with PDC bit, motor and drilling assembly. Use minimum surface RPM while drilling out to keep from breaking up shoe cement job. Suspend drilling operations when a mud wt. of 11.0 ppg or 10,200' TVD is reached, whichever occurs first. Contact Drilling Superintendent if mud weight requirements exceed 11.0 lb/gal. Backream newly drilled hole on trips. The 13 3/8" casing point is selected based on known water producing sand in the Upper Cook Inlet and to allow change out from the waterbase mud system to the oil base mud system. B. DRILLING DETAILS 12-1/4" HOLE TO 10,200' TVD (13,529' MD-RKB) 1. Bottom Hole Assembly 12 1/4" Bit, 9 5/8" Steerable Tandem XP Type Motor with 0.78- 1.15 degree AKO and 12 1/8" sleeve stab.; 11 3~4" upper stab., 8" pony DC, MWD, 2 -8" Non-Mag DC's, XO, 25 its 6 5/8" HWDP, Jars, 5 its. HWDP, DP. All BHA changes will be discussed and agreed with Houston office. 2. Bits, WOB, RPM- 1-1-4, 20-25M, 120-240 PDC, 20-45M, 60-150 For motor drilling, drill with 50-70% differential on motor; surface RPM should be run where torque is smooth (60-110). 3. Hydraulics- Maintain adequate circulation rate to clean hole. Recommended Range: 750-1000 GPM Start with 6" liners. Run maximum flowrate limited by PDM and 80% liner pressure limitation. Switch to 5-1/2" when pump rate drops below 780 GPM. 4. Mud Proqram Oil Base Inverted Emulsion System Depth TVD Weight PPG OilEVtr Ratio PV YP HPHT Fluid Mud Type Loss 3800'-9300 9.5-10.5 70/30 75/25 10-30 <20-25 3-5 Oil Base (4587' -12273'MD) I nvermul 9300-10200 10.0-12.0 80/20 25-35 15-20 3 - 5 Oil-Base (12273'-13,529' MD) Invermul Drill out with 9.0 ppg mud. Use Soltex for HTHP fluid loss control. Keep Iow gravity solids below 6-8 %. Use frequent hole sweeps as required for hole cleaning, noting frequency of high torque or tightness on trips. Keep PH in the range of 8.5 - 9.0. Increase mud weight as required (light as possible) below 9000', diluting as required to reduce LGS. Keep a supply of Barofibre and Steelseal for potential seepage problems. It is very important to have flat gels, 10-for running pipe. Survey Requirements and Deviation Restrictions A. MWD Surveys: Run one survey every 30' to insure well is tracking proposed wellpath. Once path is predictable, survey frequency may be increased to every 90'. B. Deviation: Maximum 2 degrees per 100'. Sampling, Mud Logging & Electric Loqs Mud loggers on at4587'. 30' samples, washed and dried (4 sets). Electric logging program: INDISoniclGFhleulDensitylGR; RFT andSidewall Cores Possible. Use Anadrill MWD/CDR Tool for GR an(Resistivity logging while drilling. CASING AND CEMENTING DETAILS (9 5/8" CASING) AT 13,529 MD (10,200 TVD-RKB) 1. Casing Specifications: (Top to Bottom) PPCo Pw Torque Depth Description Burst Coil Ten Opt fi-lb ftJl Drift 4587'- 13529' MD 9 5/8" 53.5 lb P-110 BTC 8920 7480 1159 to triangle 8.53 Float Shoe : Float Collar &Loc : Landing Collar : Centralizers : Connection Lock : Cementing Plugs : Circ, Mix, Displace Rate : Spacer : Lead Cement Slurry : Slurry Weight / Yield : Mix Water - Type : Pumping Time : Desired TOC : Compressive Strength , : Tail Slurry : Slurry Weight : Mix Water - Type : Pumping Time : Desired TOC : Compressive Strength : W' ford Model 323 (PDCdrillable). W' ford Model 402 Sure Seal - 1 joint above shoe. Not Anticipated W' ford 1-7' above shoe; next 2 collars; every second collar for 400'; then every 4h joint to 4587' MD Thread lock all connections on landing shoe thru top of Landing Collar. Wipc, r P',ug cr, ly Maximum practical 50 bbls fresh water Actual volume TBA Calc 1665 sk Halliburton Premium + 3% gel + 0.20 % HR-5+ 0.25 % CFR-3 12.00 PPG 2.40 ft3/sk 14.19 gal/sk. - Fresh 5:19 hours 4500' (use 20% excess with caliper log, 50 % excess w/o) 24 Hours - 450 psi; 48 hours :600 psi. Calc 233 sx Halliburton Premium + 0.40 % CFR-3 + 0.10 gaVsx Halad 344L + 0.30 % HR-5 15.8 PPG 4.83 gal/sk. - Fresh 3-4 hours 13030' (use 20% excess) 48 Hours - 450; 72 hours - 2140psi. NOTE: ACTUAL CEMENT TO BE USED MUST BE LAB TESTED PRIOR TO SENDING SAME TO THE LOCATION. SPECIAL INSTRUCTIONS A. Make +/- 20' of rat hole below casing setting depth to space out mandrel hanger. B. Notify the AOGCC a minimum of 24 hours prior to the casing job. C. It is important that hole is not surged while running casing. The casing running speed should be 1 minute /joint, or less. D. Run casing utilizing Weatherford's fillup tool. Circulate one annular volume prior to cementing, if losses are experienced, immediately start cementing. Cement casing. Use recommended spacer. Displace with OBM. Check slurry density with pressurized mud scales throughout the job. Catch samples of slurry and dry cement periodically while mixing. NOTE: CEMENT TO BE USED SHOULD BE LAB TESTED PRIOR TO SENDING SAME TO THE LOCATION. ACTUAL CEMENT TO BE USED SHOULD BE TESTED. E. Displace cement with OBM. Bump plug with 500 psi over the final displacing pressure. If plug is not leaking test the casing to 5000 psi for 30 min (Interm csg test). Bleed pressure to 0 and check for backflow. F. Complete PPCO Casing and Cementing Report and send to the Houston Office. Section IV: 8 112" Hole (7" Casinq)to 13,300'TVD 17,857' MD-RKB A. GENERAL REMARKS 1. Intent Drill an 8 1/2" hole through the Sunfish and North Forelands Sands to 13,300' TVD (17,857' MD). If productive intervals are indicated, set and cement a 7" and 3 %" production liner. 2. Litholoqy and Anticipated Problems Continuation of the sand and shale with interbedded coal seams is prognosed. There is a pressure transition that occurs slightly below the Sunfish Sands at + 12,000' TVD, + 16,042' MD. Pore pressures may increase from 9.8 ppg to about 13.2 ppg during this transition. This abnormal pressure trend is expected to continue to TD. Actual mud weights could be as high as 14.~pg. 3. Wellhead Proqram Install casing hanger seal assembly and test to 5,0q~i. BOPE Requirements and Test Pressures 13 5/8" 10 M BOPE is required. Test pressures are continued from previous section as follows: Initial Installation Weekly Rams: 8000 psi 5000 psi Annular: 3500 psi 2500 psi Casing Pressure Test & Leak-off Test Pressure test 9 5/8" casing prior to drilling float collar to 5000 psi. GIH with BHA. Drill the float equipment and 10' of new formation. Perform a Formation Integrity Test as per well control manual to an EMW of 16.0 ppg. (anticipated L/O = 17.5 -19.0 ppg EMW). Maximum anticipated mud weight in this hole section will be 15.0 ppg. Consider squeezing the shoe if the leakoff is less than 15.0 ppg EMW. Raise MW only as required. Contact Drilling Superintendent if FIT leak-off occurs before 151~g EMW. 6. Special Drillin~ Instructions A. Install a wear bushing before'drilling to prevent wear in the casing head. B. Drill 9 5/8" stage collar, shoe and float equipment with PDC bit and rotary assembly. Use minimum surface RPM while drilling out to keep from breaking up shoe cement job. C, Drill ahead with motor and hold assembly, maintaining angle and direction to the targets. To prevent differential sticking, keep pipe moving as much as possible, especially while making connections. Drilling Jars should be used in this section of the hole. D. At TD, circulate hole clean, C&CM for logging. B. DRILLING DETAILS ( 8 112" HOLE TO 17,857 MD-RKB) 1. Bottom Hole Assembly (Continue Hold Assembly) 8 1/2" PDC bit, Anadrill 6 3/4" 6 stage extended length performance motor, float sub, MWD/LWD equip., 2~ 6 3~4" NMDC, 25 jts. 5" HWDP, Drlg. Jars, 5 jts. HWDP, Drill Pipe. BHA to be discussed and agreed with Houston office. 2. Bits, WOB, RPM IADC Bit Code: PDC Type WOB: 10-20 M RPM: 60 -150 Jets: 20-20-20-20 to be Determined As required for smooth drilling (drill on motor differential) 3. Hydraulics Maintainflowrate at450 - 500 GPM. Maintain stable pump pressure. 3600 - 4000 psi (with motor). Maintain good mud properties. Yield point should be as Iow as possible to keep the ECD as Iow as possible. 4. Mud Proqram Depth TVD Weight PPG OilNVtr PV YP HPHT Mud Type Ratio Fluid Loss 10,200'- 13,300' I 12.5 -15.0 80/20 35-40 I 15-20 3-6 Oil Base (13,529-17,857' MD)I 85/15I Invermul Continue program from previous section. Non progressive gels important. THESE ARE APPROX RHEOLOGICAL VALUES, and WILL VARY DEPENDING ON OWR & TYPE OF SUSP AGENTS. 5. Survey Requirements and Deviation Restrictions A. Continue with directional plan, using MWD surveys for directional control. 6. Samplinq, Mud Lo_qaing, and Electric Logs A. Mud logging to be continued from11,900' TVD to 13,300' TVD (15,800' MD). B. Fax reports every morning to (713) 669-3754 by 5:30 (PDT) and follow with phone report at 06:00 a.m. Openhole logs from 11,900'- TVD to 13,300' TVD (15,800' MD): Array Induction / GR; Compensated Neutron / Litho-Density with GR and Caliper; Dipole Array / Sonic with GR and Caliper; MDT Tools, Dipmeter. Circulate and condition hole for logs. NOTE: See Attached Geological Prognosis 7. Environmental A. Do not spill any Oil Mud. Insure that no mud escapes from ~ area. If any accidents occur advise Houston Office Immediately. B. An SPCC plan is required on rig at all times. CASING AND CEMENTING DETAILS {7" CASING) AT 13,300 TVD (17,857' MD-RKB) 1. Casing Specifications: (Top to Bottom) I PPCo Pw Torque Depth - TVD Description Burst Coil Ten Opt fi-lb ft/I Drift 10,200'-13,300' 7" 321b/ft L-80 BT&C 8160 8110 528 6.0 13,529'-17,857' MD Special Optional 3 %" 12.95 Ib/ft P-110 Float Shoe Float Collar &Lo;; Cbni'iectidh 'Lock ...:. Cemer{~ih'g'.PI. ug~ · '" ..... ..c..i~.~ii'Mi.~; ..D.'i~place..R:a. tle:..:.· :.':. · 1-7' above shoe: next 2 collars: every second collar for 400'. Every joint to intermediate shoe. Thread lock all connections orflt shoe thru top of Float Collar. Drill pipe wiper plug. Maximum practical Spacer First Sta~e Cmt Slurry Slurry Weight Mix Water - TyFe Pumpin.u Ti;ne Des,reel TOC Compressi'v6 St., ch.;tn 23 Dgls of D.ese',:2'Jbb, c~h'v'ls FW ,?iuz.:,:n and [)am ite) FV = 10C. Mix al '14.(.: ppg tact. al m..:.i weLql"t) Acl,-al volume 'rBA Gal,,; 350 sx l.;al,b,,.,:cn Pre;!:lul.'l + 0 20 % CFR-.3 + 0.15 ~]al/sx h'-'--lac 344L -, 0 25 % I-~R-.5 15.'3 PPG 5 C3 ?l;---'k. Flesh :J-,; h :.: a ! -'- !3'?.:0' ~,..s.e 20'.',:~ -~x.'.':~.;~,.'-.: 24 -'~c.,~ s - 214.2 ;;s'. ~'.0...T..E:;:::;.!.I). 'CEMENT DESIGN IS SUBJECT TO CHANGE IF GAS IS PRESENT .... 2).: .: ..: ': :. : ; "A. II..0BM wil! be Circulated'out of annulus. Flush and volumes TBA. SPECIAL INSTRUCTIONS ~ii.;i:.:i;.i':::i.i:!i'i:.'.iM~lke '+.!.-.i'20' of rat hole below casing setting depth to space out liner hanger. E. Notify the AOGCC a minimt.Jm of 24 hours [)[i(~f I()ti"1(.: (.',,',.ising j()b. Check liner hanger assembly on ~ig. It is imporlanl that hole is riot surged wh:le ~urming casing. Auto-Fill (xluiprne~ll will be used. The casing fur'ming speed should be 1 minute i joinL or less. NOTE: A special liner ru[ming procedure will be plovided al the approl)rial(~ lime. DRILLING FLUID PROGRAM Depth '['VD Weight PPG Visc. PH PV YP FL Mud Type Use pre-hydrated bentonite and extender flocculated in inlet water. Use all solids control equipment, keeping LGS below 6 % if possible. Sweep hole as needed with 50 bbl pills made up of 25 ppb gel and 1/2 ppb caustic in fresh water. Treat system with Drispac if seepage problems occur. Maximize pump rates to provide increased annular velocity. * NOTE: Have funnel viscosity 50 - 70 sec/qt while drilling through gravel and when running casing. Depth TVD Weight PPG Visc. PH PV YP FL Mud Type (1206'-4587' MD) Base Continue use of conductor mud system. Use fresh water for make-up mud. Continue use of all solids control equipment, sweeping hole as needed with 50 bbl pills. Continue the PAC treatments. Use Kwik-Seal and BaroFibre for any losses or excess seepage. Maximize pump rates to provide increased annular velocity. Depth TVD Weight PPG OilNVtr Ratio PV YP HPHT Fluid Mud Type Loss 3,800'-9,300' 9.5-10.0 70~30 75~25 10-30 <20-25 3-5 Oil Base (4,587'-12,272' MD) Invermul 9,300'-10,200' 10.0-11.0 80~20 25-35 15-20 3 - 5 Oil-Base (12,272'-13,529' MD) Invermul Drill out with 9.0 ppg mud. Use soltex for HTHP fluid loss control. Keep Iow gravity solids below 8 %. Increase mud weight as required below 9000', keeping a supply of Barofibre and Steelseal for potential seepage problems. It is very important to have flat gels, 10 for running pipe. Depth TVD Weight PPG OiI,VVtr Ratio PV YP HPHT Fluid Mud Type Loss 10,200'- 13,300' 11.0 - 15.0 80/20 85/15 35-40 15-20 3-6 Oil Base (13529-17857' MD) Invermul Continue program from previous section. Mud weight will need to be brought up to 13.0 - 14.0 after coring the Sunfish Sands. Non progressive gels important. THESE ARE APPROX RHEOLOGICAL VALUES, and WILL VARY DEPENDING ON OWR & TYPE OF SUSP AGENTS. SOLIDS CONTROL PROGRAM Riq Ecluil~ment Linear shakers - 3 Derrick Model 58:lo-Line Cleaners Desander Pioneer Model T-86 with 8-6" cones Mud Cleaner Derrick with 16-4" cones Degasser Drilco See-Flow OBM Cuttinqs Handlinq Apollo Services will vacuum the drill cuttings to their catch tank. From there, the cuttings will be ground and disposed into the non-productive sands at a TVD of approximately 3300' TVD. Disposal will be down one of the two 2 3/8" tubing strings attached to the 13 3/8" surface casing. ~/~ Additional Equipment Needed 1) A dedicated steam cleaner is needed at the sl-tmrs to allow for screen cleaning at any time. 2) Coarse (e.g., expanded metal) cages will be installed over the pump intakes in the pits to prevent trash from fouling the valves. 3) A dedicated pump capable of pumping liquids out of the cuttings catch tank back over the shakers will be furnished by Apollo Services. 4) Use Pyramid Plus screens as the first 2 screens on the Derricks. The Plus feature is merely taller corrugations, which allows for more separation in the deep pool section of the shakers. NOTE: Ensure all equipment is fully operational before drilling ahead with oil base fluids. Install an operational pressure gauge on the hydroclone headers. Pressure should be 4 x MW in psi. Upgrade feed pump impeller if necessary. Be sure cones are clean and in spray discharge. Conductor and Surface Hole Use all rig solids control equipment. Run 210 mesh pyramids on the Derricks. Run desander and desilter on surface hole. Intermediate Hole The goals during the OBM sections are to produce dry cuttings (to reduce cuttings slurry volumes), and yet keep Iow gravity solids (Igs) less than 8 vol% with existing rig equipment. In past wells, <8% Igs has been achieved using 210's on the Derricks. Again, the goal is to produce dry cuttings, even during upsets and startups with cold mud. During switch out to OBM, put coarse fiat screens on Derricks (e.g. 80 mesh). After several circulations, start the Derricks with 140 mesh screens. Use Pyramid Plus screens on the first 2 screens, and a regular Pyramid on the last screen. Screen down to 210's in the same arrangement consistent wit[dry cuttings as soon as possible. A major goal is to produce dry cuttings. To prevent whole mud going over the shakers, it may be necessary to bypass the Derricks for the first half circulation after a trip into the hole. When the mud warms up, immediately switch back over the Derricks. Pump liquids that collect in the catch tanks back over the shakers. Lost circulation is possible at any time. It may be necessary to bypass the Derricks for a short time to allow bridging size LCM (e.g., sized calcium carbonate and Steel Seal) tobuild up in the mud to plug the problem zone. Return flow to the Derricks as soon as possible to prevent buildup of Igs. It is better to have to keep adding LCM than to let the Igs build up over 8 vol%. Production Hole Continue with previous program. Lower pump rates may allow 250's on the Derricks. TELEPHONE NUMBERS Drilling Superintendent Drilling Engineer Drilling Manager W.L Carrico Home Mobile Pager Paul Dean Home N. P. Omsberg Mud Specialist Dave Beardmore Panafax - Houston Office Logs Materials Coordinator Larry Airington Materials Coordinator Jim Magee Kenai Office Jim Konst Len Janson Alaska Oil & Gas Conservation Commission Anchorage Office Fax (713) 669-2173 (281) 343-7279 (281) 542-9988 (800) 626-6182 (713) 669-3502 (281) 980-1557 (713) 669-7550 (281) 565-3140 (713) 669-2198 (281) 261-5554 (713) 669-3754 (713) 669-3755 (713) 669-2975 (713) 669-7020 (281) 980-0336 (907) 776-6035 (907) 283-4057 (907) 776-6027 ( 907) 776-6046 (907) 279-1433 (907) 276-7542 PHILLIPS PETROLEUM COMPANY ~,~u~s~. ~.~ ~x~ 3-19-98 DESCRIPTION CHECK NO. 000799 State of Alaska Dept of Revenue 3001 Porcupine Drive Anchorage Alaska 99501 Charge Code AFE P-V140 Purpose' Permit to Drill NCIU B No 3 Alaska COMMODITY LEDGER LOC. EMPLOYEE NO. CL TAX ID NO. REPORTABLE 1099 CODE YES NO THE ATTACHED CHECK IS IN FULL PAYMENT OF ITEMS STATED ABOVE. ENDORSEMENT MUST BE IDENTICAL WITH THE PAYEE DESIGNATED. FORM 9004-14 12-94 DETACH BEFORE DEPOSITING AND RETAIN FOR YOUR FILES. · WELL PERMIT CHECKLIST COMPANY //?~?X~_~ WELL NAME,,/~'~----~//~___,~, FIELD & POOL /?j/, ~,. ' '" ..... * INIT CLASS /¢)~___.~L~' / /'-d:~ ? GEOL AREA ~;:~ UNIT# //)/--)/~'z:::2 ON/OFF SHORE ADMINISTRATION 1. Permit fee attached ....................... (~N '~,,,..~..-, 2. Lease number appropriate ................... ~-Y~ N 3. Unique well name and number .................. 4. Well located in a defined pool .................. _ '-~_~,d"'~l/~ / ' - ~ ,., ' ' ~.,'/~ - ' ~ - ' 5. Well located proper distance from drilling unit boundary... 6. Well located proper distance from other wells .......... 7. Sufficient acreage available in drilling unit ............ 8. If deviated is wellbore plat included ............ - f Y) N 9. Operator o'nly affected party ....... '...' ......... (~N ~_.//'~/ ~ ,~_ /~,e?,¢~ ,// ,'"/~-~/~4 -" /~,~, "- ~'/'~//~'~ /,,.-z,~,~;~...;~; ..... 10. Operator has appropriate bond in force ............. Y(_.~_.~ / ,.,' / ,' , ' / ' ' ,./. 11. _Permit can be issued without conservation order ........ ~(~ 12. Permit can be issued without administrative approval ...... 13. Can permit be approved before 15-day wait ........... Y~..~ ENGINEERING APPR D~T,,,,E/ GEOLOGY 14. 15. 16. 17. 18. 19. 20. 21. 22. 23. 24. 25. 26. 27. 28. 29. 30. Permit can be issued w/o hydrogen sulfide measures ..... ~ "~2/~ - - ' ...... " i'" 31. Data presented on potential overpressure zones,,, ...... T(~ _~. ~J~~,~' ~ _~~_~ 32. Seismic analysis of shallow gas zones.. ,/'(.~.,.~ ...... ~'~ /- '-' "' 33. Seabed condition survey (if off-shore)... ~.,~., ..... 34. Contact name/phone for weekly,progress repo, rts ....... O N {exploratory omy. I ,, i' GEOLOGY: ENGINEERING: COMMISSION: .Comments/Instructions: JDH, .,~f~-_ RNC~ Conductor string provided ................... (~ N ~ f~(__~4~4~L-,,,~_~__; ~ ~'~-t~_ ~ ~'~.~0 ' (~. ~ . / Surface casing protects all known USDWs ........... CMT vol adequate to circulate on conductor & surf csg ..... CMT vol adequate to tie-in long string to surf csg ........ CMT will cover all known productive horizons .......... Casing designs adequate for C, T, S & permafrost ...... o ,.serve ................ ,. Ck.L If a re-drill, has a 10-403 for abandonment been approved./V/,r~ ~ ~.~.,~__.g.,..~,,._~ ~ ~ . / ~ -- ., ,, /2 Adequate wellbore separation proposed ............ ~.~(~ N ~ ~ ~ //~-,,t '~/,,..g ~. ~.~ If diverter required, does it meet regulations .......... Drilling fluid prooram schematic & equip list adequate ..... ~ N BOREs, do they~meet regulation ................ fY BORE press rating appropriate; test to .~ ~'r~psig. ~)N ~ ~ ¢' ~ "/~,, ~ ~ '7' ~/"~ ~'S~.. ~ ~-~'"~"~'--~ Choke manifold complies w/APl RP-53 (May 84')' ........ ..~N -~"')~ ~ / <:2' Work will occur without operation shutdown ........... ~ ' Is presence of H2S gas probable ................. Y HOW/lit - A \FORMS\chekhst rev 09/97 ANNULAR DISPOSAL CHECKLIST COMPANY WELL NAME ann. disposal para 1 [] ann. disposal para 2 It 1. Designation of well to receive waste ................ 2. Depth to base of freshwater aquifers/permafrost ........ Y N Y N 3. Depth/thickness of receiving and confining zone ..... ' .... Y N 4. Sufficient information to demonstrate confinement ........ Y N 5. List of all publicly recorded wells within 1/4 mile .......... Y N 6. List of all publicly recorded water wells within 1 mile ........ Y N 7. Estimate of max. volume & density of waste slurry ........ Y N 8. Description of drilling waste ................ Y N 9. Estimate of max. anticipated pressure at outer casing shoe .... Y N 0. Outer casing shoe set below aquifer/permafrost base ...... Y N 1. Outer casing shoe sufficiently cemented to provide isolation .... Y N 2. Sufficient collapse/burst strength ............ Y N 3. Additional data .......................... Y N Comments/Instructions: